New-York-State-Elec-

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: December 1, 2005

Leaf No. 1 Revision: 1 Superseding Revision: 0

P.S.C. No. 120 - ELECTRICITY
SUPERSEDING P.S.C. NO. 115

NEW YORK STATE ELECTRIC & GAS CORPORATION
RULES, REGULATIONS AND GENERAL INFORMATION

SCHEDULE
FOR

ELECTRIC SERVICE

Applicable In All territory served by this Corporation and In all rate schedules except as otherwise Provided in individual rate schedules

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 2 New York State Electric & Gas Corporation Revision: 7 Initial Effective Date: September 26, 2010 Superseding Revision: 6 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010

TABLE OF CONTENTS GENERAL INFORMATION
1. Territory to Which Schedule Applies 2. Submetering 3. Reserved for Future Use 4. System Benefits Charge 5. Renewable Portfolio Standard Charge 6. Increase in Rates and Charges Applicable Where Service is Supplied 7. Revenue Decoupling Mechanism Adjustment 8. Economic Development Incentive 9. Economic Development "Zone" Incentive 10. Economic Development Power 11. Reserved for Future Use 12. New Allocations of NYPA Power 13. Incubator Development Incentive 14. Competitive Metering Option 15. Power For Jobs 16. General Retail Access Rules 17. Business Retention Incentive 18. High Load Factor Manufacturer Power 19. Incremental Load Incentive (ILI) 20. Emergency Demand Response Program (“EDRP”)

LEAF NO.
4 15 17 18 18

19 21 23 24 26 27 28 39 41 49 50 109 110 111 112

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 26, 2010

Leaf No. 2.1 Revision: 10 Superseding Revision: 9

TABLE OF CONTENTS GENERAL INFORMATION
21. CA$HBACK Program 22. Farm Waste Electric Generating System Option 23. Wind Electric Service Options 24. Electric Hybrid Generating System Option 25. Supply Service Options 26. Solar Residential Electric Service Option 27. Solar Non-Residential Electric Service Option 28. Surcharge to Collect Temporary State Assessment 29. Micro-combined Heat and Power (MCHP) Service Option 30. Fuel Cell Service Option

LEAF NO.
114 116 117.1 117.3 117.6 117.31 117.32 117.34 117.35 117.37

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 1, 2004 TABLE OF CONTENTS Service Classifications as listed below: Applicable To Entire Territory Entire Territory Entire Territory Town of Newcomb Entire Territory Entire Territory Entire Territory Residential Service General Service with Demand Metering Primary Service - 25 KW or more Cancelled Outdoor Lighting Service General Service Large General Service with Time-of-Use Metering Residential - Day Night Service General Service - Day Night Service Cogeneration or Small Power ProductionSale of Energy to the Corporation Standby Service Residential Service with Time-of-Use Metering Competitive Alternative Industrial Service Large Economic Development Service For

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Service Classification 1 2 3 4 5 6

Leaf 118-127 128-153 154-181 182 183-202 203-210

7 8 9 10

211-255 256-266 267-274 275-281

Entire Territory Entire Territory Entire Territory

Entire Territory Entire Territory

11 12

282-294.12 295-304

Entire Territory Entire Territory

13 14

305-311 312-319

Issued in compliance with orders in Case No. 02-E-0779 dated 07/30/03 and Case No. 03-E-1552 dated 11/28/03.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003 GENERAL INFORMATION 1. Territory to which Schedule Applies (Cont'd): BINGHAMTON AREA BROOME COUNTY: City: Binghamton Villages: Endicott Johnson City Lisle Port Dickinson Whitney Point Windsor Towns: Barker Binghamton Chenango Colesville Conklin Dickinson Fenton Kirkwood Lisle Maine Nanticoke Triangle Union Vestal Windsor CHENANGO COUNTY: Village: Afton Towns: Afton Coventry German Greene McDonough Otselic Pharsalia Pitcher Smithville

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CORTLAND COUNTY: Towns: Cincinnatus Freetown Harford Lapeer Marathon (Except that portion served by the Village of Marathon Municipal Lighting Plant Taylor Virgil (Southeastern portion) Willett TIOGA COUNTY: Villages: Newark Valley Nichols Owego Towns: Barton (Eastern Portion) Berkshire Newark Valley Nichols Owego Richford Tioga Candor (Portion between the north and south border lines and within one-half mile of the west branch of Owego Creek)

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003

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GENERAL INFORMATION 1. Territory to which Schedule Applies (Cont'd): EAST CENTRAL AREA BROOME COUNTY: Village: Deposit Town: Sanford CHENANGO COUNTY: City: Norwich Villages Bainbridge New Berlin Oxford Smyrna Towns: Bainbridge Columbus Greene Guilford New Berlin Norwich North Norwich Oxford Plymouth Preston Smerburne Smyrna COLUMBIA COUNTY: Villages: Chatham Philmont Towns: Austerlitz Canaan Chatham (Except Northwest Corner) Claverack (Eastern Portion) COLUMBIA COUNTY (Cont'd): Towns (Cont'd): Copake Ghent Hillsdale New Lebanon Taghkanic (Eastern Portion) DELAWARE COUNTY: Villages: Andes Delhi Fleischmanns Franklin Hancock Hobart Margaretville Sidney Stamford Walton Towns: Andes (Northern Portion) Bovina Colchester (Northern Portion) Davenport Delhi Deposit Franklin Hamden Hancock (Northern Portion) Harpersfield Kortright Masonville Meredith Middleown Roxbury Sidney Stamford Tompkins Walton

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003 GENERAL INFORMATION 1. Territory to which Schedule Applies (Cont'd): EAST CENTRAL AREA (Cont'd) GREENE COUNTY: Towns: Ashland Halcott Jewett (Northern Portion) Prattsville Windham HERKIMER COUNTY: Village: West Winfield Towns: Columbia (Southern Portion) Litchfield (Southern Portion) Warren Winfield MADISON COUNTY: Villages: Earlville Madison Morrisville Towns: Brookefield Eaton Georgetown Hamilton Lebanon Madison Smithfield ONEIDA COUNTY: Villages: Bridgewater Oriskany Falls Waterville Towns: Augusta Bridgewater

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ONEIDA COUNTY (Cont'd): Towns (Cont'd) Kirkland (Southern Portion) Marshall Sangerfield OSTEGO COUNTY: City: Oneonta Villages: Cooperstown Gilbertsville Laurens Milford Morris Otego Richfield Springs Unadilla Towns: Burlington Butternuts Edmeston Exeter Hartwick Laurens Middlefield Milford Morris New Lisbon Oneonta Otego Otsego Pittsfield Plainfield Richfield Springfield Unadilla Westford

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003 GENERAL INFORMATION 1. Territory to which Schedule Applies (Cont'd): EAST CENTRAL AREA (Cont'd) RENSSELAER COUNTY: Towns: Berlin North Greenbush Petersburg Sand Lake Stephentown Nassau (Southeast Corner)

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SCHOHARIE COUNTY: Towns: Conesville Gilboa Jefferson ULSTER COUNTY: Towns: Hardenbergh (Eastern Portion) Shandaken GRANVILLE DISTRICT WASHINGTON COUNTY: Villages: Granville Salem Towns: Granville Greenwich Hebron Jackson Salem

MECHANICVILLE DISTRICT RENSSELAER COUNTY: Town: Schagticoke (Western Portion) SARATOGA COUNTY: City: Mechanicville Village: Round Lake Stillwater SARATOGA COUNTY (Cont'd) Towns: Clifton Park (Northeastern Portion) Half Moon (Northern Portion) Malta (Southern Portion) Stillwater

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003 GENERAL INFORMATION 1. Territory to which Schedule Applies (Cont'd): ELMIRA AREA LIVINGSTON COUNTY (Cont'd): Towns: Leicester Mount Morris Ossian Sparta Springwater West Sparta ONTARIO COUNTY: Village: Naples Towns: Naples SCHUYLER COUNTY: Villages: Montour Falls Odessa Towns: Ctherine Cayuta Dix Montour Orange Reading Tyrone STEUBEN COUNTY: Cities: Corning Hornell Villages: Addison Arkport Avoca Canisteo Cohocton

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ALLEGANY COUNTY: Villages: Alfred Almond Canaseraga Towns: Alfred Almond Birdsall Burns Grove Ward West Almond CHEMUNG COUNTY: City: Elmira Villages: Elmira Heights Horseheads Millport Wellsburg Towns: Ashland Baldwin Big Flats Catlin Chemung Elmira Erin Horseheads Southport Veteran LIVINGSTON COUNTY: Villages: Dansville Leicester

STEUBEN COUNTY (Cont'd): Villages: Hammondsport North Hornell Painted Post Prattsburg Riverside Savona South Corning Wayland Towns: Addison Avoca Bath Bradford Cameron Campbell Canisteo Caton Cohocton Corning Dansville Erwin Fremont Greenwood Hartsville Hornby Hornellsville Howard Jasper Lindley Prattsburg Pulteney Rathbone Thurston Troupsburg Tuscarora Urbana Wayland

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003 GENERAL INFORMATION 1. Territory to which Schedule Applies (Cont'd): ELMIRA AREA (Cont'd) STEUBEN COUNTY (Cont'd): Towns (Cont'd): Wayne (Except Northeast Portion) West Union Wheeler Woodhull

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WYOMING COUNTY: Villages: Gainesville Perry Warsaw Wyoming Towns: Castille Gainesville Genesee Falls Middlebury Perry Warsaw

ITHACA AREA CAYUGA COUNTY: Village: Moravia Towns: Locke Moravia Sempronius Summerhill CHEMUNG COUNTY: Village: Van Etten Town: Van Etten SCHUYLER COUNTY: Village: Burdett Town: Hector SENECA COUNTY: Villages: Interlaken Lodi Ovid Towns: Covert Lodi Ovid Romulus (Southern Portion) TIOGA COUNTY: Villages: Candor Spencer Towns: Barton (Northern Portion) Candor (Except that portion between the North & South Border Line & within one-half mile of the West Branch of Owego Creek) Spencer

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003 GENERAL INFORMATION 1. Territory to which Schedule Applies (Cont'd): ITHACA AREA (Cont'd) TOMPKINS COUNTY: City: Ithaca Villages: Cayuga Heights Dryden Freeville Lansing Trumansburg

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TOMPKINS COUNTY (Cont'd) Towns: Caroline Danby Dryden Enfield Groton Ithaca Lansing Newfield Ulysses NORTH CENTRAL AREA

CAYUGA COUNTY: City: Auburn Villages: Aurora Cayuga Port Byron Union Springs Weedsport Towns: Aurelius Brutus Fleming Genoa Ledyard Mentz Montezuma Owasco Scipio Sennett Springport Throop Venice

ONONDAGA COUNTY: Villages: Elbridge Jordan Marcellus Towns: Camillus Elbridge Marcellus Otisco (Northwestern Portion) Spafford VanBuren (Southern Portion) ONTARIO COUNTY: City: Geneva Villages: Clifton Spring Phelps Rushville

Towns: Geneva Gorham Hopewell (Eastern Portion) Manchester (Eastern Portion) Phelps Seneca ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003 GENERAL INFORMATION 1. Territory to which Schedule Applies (Cont'd): NORTH CENTRAL AREA (Cont'd) SENECA COUNTY: Villages: Seneca Falls Waterloo Towns: Fayette Junius Romulus (Northern Portion) Seneca Falls Tyre Varick Waterloo STEUBEN COUNTY: Town: Wayne (Northeastern Portion) WAYNE COUNTY Villages: Clyde Lyons Macedon Newark Palmyra Savannah

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WAYNE COUNTY (Cont'd) Towns: Arcadia Galen Lyons Macedon Palmyra Savannah (Adjacent to Village) Walworth YATES COUNTY: Villages: Dresden Dundee Penn Yan Rushville Towns: Barrington Benton Italy Jerusalem Middlesex Milo Potter Starkey Torrey

NORTHEAST AREA CLIFTON COUNTY: Villages: Champlain Dannemora Keeseville Mooers Towns: Altona Ausable Beekmantown Black Brook (Northeast and Southeast Corners) CLIFTON COUNTY (Cont'd): Towns: Champlain Chazy Clinton Dannemora Ellenburg Mooers Peru Plattsburgh Saranac Schuyler Falls

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003 GENERAL INFORMATION 1. Territory to which Schedule Applies (Cont'd): NORTHEAST AREA (Cont'd) ESSEX COUNTY: Towns: Chesterfield Elizabethtown Essex Jay Keene Lewis Newcomb Willsboro Wilmington

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FRANKLIN COUNTY: Villages: Burke Chateaugay Towns: Belmont (Eastern and Southern Portions) Burke Chateaugay Constable (Except Northwest Corner) Malone (Highway Northeast Portion) HAMILTON COUNTY: Towns: Indian Lake (Northern Portion) Long Lake SOUTHEAST AREA

DELAWARE COUNTY: Towns: Andes (Southern Portion) Colchester (Southern Portion) Hancock (Southern Portion) DUTCHESS COUNTY: Village Pawling Towns: Amenia Beekman Dover Pawling PUTNAM COUNTY: Village: Brewster

PUTNAM COUNTY (Cont'd): Towns: Carmel Kent Patterson Putnam Valley Southeast SULLIVAN COUNTY: Villages: Jeffersonveille Liberty Monticello Woodridge Towns: Bethel Callicoon Cochecton Delaware

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003 GENERAL INFORMATION 1. Territory to which Schedule Applies (Cont'd): SOUTHEAST AREA (Cont'd) SULLIVAN COUNTY (Cont'd): Towns (Cont'd): Fallsburg Fremont Highland Liberty Neversink (Western Portion) Rockland Thompson Tusten

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ULSTER COUNTY: Town: Hardenbergh (Western Portion) WESTCHESTER COUNTY: Towns: Bedford Lewisboro North Salen Poundridge Somers Yorktown

WALDEN DISTRICT ORANGE COUNTY: Village: Walden Towns: Crawford (Northeastern Portion) Montgomery (Western Portion) ULSTER COUNTY: Town: Shawangunk (Western Portion)

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003 GENERAL INFORMATION 1. Territory to which Schedule Applies (Cont'd): WESTERN AREA CATTARAUGUS COUNTY: Villages: East Randolph Gowanda Perrysburg Randolph South Dayton Towns: Conewango Dayton Leon Napoli New Albion Perrysburg (Eastern Portion) Persia CHAUTAUQUA COUNTY: Villages: Cherry Creek Forestville Silver Creek Towns: Cherry Creek Ellington Hanover Villenova ERIE COUNTY: Villages: Alden Depew East Aurora Gowanda Hamburg Lancaster Orchard Park Sloan

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ERIE COUNTY (Cont'd): Towns: Alden Amherst Aurora Boston Cheektowaga (Eastern and Southern Portion) Clarence Colden Collins (Southwestern Portion) Concord (Except Southeastern Corner) Elma Hamburg (Eastern Portion) Holland Lancaster Marilla Orchard Park Sardinia (Except Southeastern Corner) Wales West Seneca (Eastern Portion) NIAGARA COUNTY: City: Lockport Towns: Lockport Newfane (Portion adjacent to Town of Lockport) Pendleton (Portion adjacent to Town of Lockport) WYOMING COUNTY: Towns: Bennington Java Sheldon

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003 GENERAL INFORMATION 2. Submetering: Non-Residential

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A customer may purchase electricity for resale under any service classification of this rate schedule that would be applicable if such electricity were not for resale and said customer may resell the electricity purchased to tenants on an individually metered basis subject to approval by the Public Service Commission in response to individual proposals concerning electric service furnished to: A. Master metered, new or renovated non-residential buildings; and B. Commercial occupants of cooperatives, condominiums, campgrounds, recreational trailer parks or recreational marinas whose occupants were purchasing individually metered electric service on May 21, 1980. Residential A customer may purchase electricity for resale under any service classification of this rate schedule that would be applicable if such electricity were not for resale and said customer may resell the electricity so purchased to tenants on an individually metered basis (submeter) as provided in 16 NYCRR 96.2, under the following conditions: A. At campgrounds, recreational trailer parks and marinas submetering, as a substitute for master metering, shall be permitted. At new or renovated campgrounds, recreational trailer parks and marinas, submetering shall be permitted. In private, or governmental residential entities as a substitute for master metering inclusive of new or renovated rental units, upon application to the Commission, which shall contain the following: 1. 2. Substantiation of the economic advantages of submetering over direct metering; A description of the submetering system to be installed and validation of its reliability and accuracy; The method and basis for calculating rates to tenants, which will include a maximum rate provision preventing charges from exceeding the Corporations residential rate; Complaint procedures and tenant protections consistent with the Home Energy Fair Practices Act;

B.

C.

3.

4.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003 GENERAL INFORMATION 2. Submetering: (Cont'd) Residential (Cont'd)

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5. A procedure for notifying in writing all tenants of the proposal to submeter, including a summary of the information provided under subparagraphs C.1 through C.4 above and an invitation to comment to the Commission which shall prominently display the address and telephone number of the Commission; 6. A demonstration that an enforcement mechanism is available to the tenants to ensure that their rights are protected under the law; 7. Certification that information provided under subparagraphs C.3, C.4, and C.6 will be incorporated in plain language into all leases governing submetered premises; 8. A description of an appropriate rent reduction formula that reflects the elimination of rent included electric costs resulting from conversion to submetering. D. In new or renovated residential cooperatives and condominiums, where all tenants are or will be shareholders, submetering may be permitted upon application to the commission, which application shall contain: 1. Verification that the building will be a cooperative or condominium; 2. Certification of provisions in subparagraphs C.3, C.4, C.6 and C7. which cap, procedures, and protections shall continue until control of the building is assumed by the appropriate cooperative or condominium Board. Upon transfer of control to the appropriate Cooperative or Condominium Board, such Board shall certify to the utility that the Board will submeter electricity according to a plan that satisfies the conditions set forth in subparagraph C.3 and C.4. E. In residential cooperatives and condominiums where all tenants are shareholders and the shareholders approve a proposal which includes a rate cap at the Corporation's rate for directly metered residential service (and any excess revenues above the cap are used for purposes of energy conservation) and also includes grievance procedures as provided, respectively, in subparagraphs C.3 and C.4 above:

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 1, 2004 GENERAL INFORMATION 2. Submetering: (Cont'd) Residential (Cont'd) 1.

Leaf No. 17 Revision: 1 Superseding Revision: 0

As a substitute for direct metering the submeterer shall certify to the Corporation that 70% of the shareholders voted in favor of the submetering proposal. As a substitute master metering the submeterer shall certify to the Corporation that more than 50% of the shareholders voted in favor of the submetering proposal. In residential cooperatives and condominiums, where one or more tenants are non-shareholders, the shareholder approved submetering may be permitted as a substitute for direct metering or master metering once the sub-meterer certifies to the Corporation that all non-shareholder tenants have approved a plan which includes, as set forth in sub-paragraph C.3, a rate cap of the Corporation's rate for directly metered residential service (and any excess revenue above the cap are used for purposes of energy conservation) and includes, as set forth in sub-paragraph C.4, grievance procedures. Where one or more non-shareholder tenants refuse to approve the plan, submetering to such tenants shall be permitted only upon approval by the Commission of an application meeting the conditions set forth in sub-paragraphs C.1 through C.7.

2.

F.

3. Reserved for Future Use

Issued in compliance with orders in Case No. 02-E-0779 dated 07/30/03 and Case No. 03-E-1552 dated 11/28/03.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: October 1, 2008 GENERAL INFORMATION 4. Surcharge to Collect System Benefits Charge (“SBC”)

Leaf No. 18 Revision: 10 Superseding Revision: 9

Each customer bill for service under Service Classification Nos. 1, 2, 3, 5, 6, 7, 8, 9, 11, 12, 13, and 14 (excluding kilowatt-hours supplied by NYPA) will be increased by multiplying all kilowatt-hours delivered by a surcharge rate (as shown in the System Benefits Charge (SBC) Statement). This surcharge is comprised of two components: a. pursuant to Commission Order Continuing the System Benefits Charge (SBC) and the SBC-funded Public Benefit Programs, issued and effective December 21, 2005, in Case 05-M-0090. One-half the annual amount shall be collected during the first half of calendar year 2011. This component of the surcharge will be effective with usage billed on and after July 1, 2006 through June 30, 2011. pursuant to Commission Order Establishing Energy Efficiency Portfolio Standard and Approving Programs (“the Order”), issued and effective June 23, 2008, in Case 07-M-0548. This component of the surcharge will be effective with usage billed on and after October 1, 2008.

b.

The surcharge will be calculated on an annual basis to collect the Corporation’s allocated fund amounts as set forth in the Orders identified above based on year-by-year projections of the following year’s electric sales. Any over- or under-collections will be trued up on an annual basis. A System Benefits Charge (SBC) Statement setting forth the annual rate will be filed with the Public Service Commission on not less than three (3) days’ notice. Such statement can be found at the end of this Schedule (PSC 120 – Electricity). 5. Surcharge to Collect Renewable Portfolio Standard Charge (“RPS”) Each customer bill for service under Service Classification Nos. 1, 2, 3, 5, 6, 7, 8, 9, 11, 12, 13, and 14 will be increased by multiplying all kilowatt-hours delivered by a surcharge to be determined annually. The surcharge is imposed pursuant to Commission Order Regarding Retail Renewable Portfolio Standard, issued and effective September 24, 2004, in Case 03-E-0188. The surcharge will be calculated on an annual basis to collect the Corporation’s allocated fund amount based on the Order and will be amended each October 1st. The surcharge will be effective with usage billed on and after October 1, 2005 through the term of the program. Any over- or under-collections will be trued up on an annual basis. A Renewable Portfolio Standard Charge (RPS) Statement setting forth the annual rate will be filed with the Public Service Commission on not less than fifteen (15) days’ notice. Such statement can be found at the end of this Schedule (PSC 120 – Electricity).

Issued in compliance with Order in Case 07-M-0548 dated 06/23/08 and Order in Case 03-E-0188 dated 09/24/04.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2006 Effective date postponed to 02/01/06. See Supplement No. 4.

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GENERAL INFORMATION

6. Increase in Rates and Charges Applicable Where Service is Supplied: The rates and charges for service under all Service Classifications, including minimum charges, will be increased to collect taxes pursuant to: a) Section 186-a and Article 9 of the Tax Law (Gross Income Tax “GIT”). b) Chapter 60, Article 9 and, where applicable, Section 20-b of the General City Law and Section 5-530 of the Village Law. The rates and charges for retail access service are not subject to the 1% Municipal Tax (“Muni Tax”) imposed on the Company. c) Section 186-c and Section 209-b under Article 9 of the Tax Law -- Metropolitan Business Tax Surcharge. For the counties of Westchester, Putnam, Dutchess and Orange, the surcharge percentages will be adjusted to reflect the Temporary Metropolitan Business Tax Surcharge (“MTA Tax”) as charged to the Corporation under Section 186-c and Section 209-b under Article 9 of the Tax Law. A revised surcharge percentage will be filed for each year the MTA Tax surcharge is applicable. The actual tax surcharge expense will be reconciled with the amount collected during each 12-month period and a reconciling adjustment will be made, if necessary, for the last two months of each 12-month period. Aggregate percentage tax rates will be separately calculated for rates and charges for: 1) Residential Non-Retail Access Delivery Service 2) Non-Residential Non-retail Access Delivery Service 3) Non-Retail Access Commodity Service (Residential and Non-Residential) 4) Residential Retail Access Delivery Service 5) Non-Residential Retail Access Delivery Service

Issued by: James A. Lahtinen, Vice President - Rates & Regulatory Economics, Binghamton, NY

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2006 Effective date postponed to 02/01/06. See Supplement No. 4. GENERAL INFORMATION 6.

Leaf No. 20 Revision: 2 Superseding Revision: 1

Increase in Rates and Charges Applicable Where Service is Supplied: (Cont’d.) The effective aggregate percentage tax rates will be computed as follows: Areas not subject to MTA Tax: a) Within cities or villages subject to 1% Municipal Tax: [[1/(1 - (GIT + Muni Tax))] – 1] * 100 b) Outside of cities or villages subject to 1% Municipal Tax: [(1/(1 - GIT) ) – 1] * 100 Areas subject to MTA Tax: a) Within cities or villages subject to 1% Municipal Tax: [[1/[1/[(1 + MTA Tax) / [1 – (GIT + Muni Tax)]]]] – 1] * 100 b) Outside of cities or villages subject to 1% Municipal Tax: [[1/[1/[(1 + MTA Tax) / (1 - GIT)]]] – 1] * 100

The applicable tax surcharge percentages will be set forth on a statement (Tax Surcharge Percentage Statement or “TSP Statement”) filed with the Public Service Commission. Whenever the legislature, city or village levies a new tax on the Company, repeals such tax, or changes the rate of such tax, the Company will file a new statement. Every such statement will be filed not less than fifteen (15) business days before the date on which the statement is proposed to be effective, and no sooner than the date when the tax enactment to which the statement responds; will become effective no sooner than the date when the tax enactment is filed with the Secretary of State; will be applicable to bills subject to the tax enactments that are rendered on or after the effective date of the statement; and will be canceled not more than five (5) business days after the tax enactment either ceases to be effective or is modified so as to reduce the tax rate. Such statement will be duly filed with the Public Service Commission, apart from this rate schedule, and will be available to the public at the Company offices at which application for service may be made.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 21 New York State Electric & Gas Corporation Revision: 5 Initial Effective Date: September 26, 2010 Superseding Revision: 3 Issued in compliance with Order in Case 09-E-0715, dated September 21, 2010 GENERAL INFORMATION 7. Revenue Decoupling Mechanism Adjustment (“RDM”)
1. Applicable to: a. All customers taking service under Service Classification Nos. 1, 2, 3 (Primary), 6, 7, 8, 9, and 12, except as noted in (c.) below, whether receiving electricity supply from NYSEG or an ESCO, will be subject to a RDM Adjustment as described below. All customers taking service under Service Classification No. 11 and choose to be subject to the otherwise applicable service class rates (pursuant to Section 3 under “Optional Standby Service Rate Phase-In is Applicable To;”. All other customers taking service under Service Classification No. 11 will be excluded from the RDM Adjustment. The following customers will be excluded from the RDM Adjustment: customers taking Seasonal Service under the Special Provisions in Service Classification Nos. 1 and 8, Service Classification 3 (Substation), Service Classification No. 7-4 Transmission, Service Classification Nos. 5, 10, 13, and 14.

b.

c.

2. Definitions: a. “Delivery Service Revenue Target” for each service classification is based on service classification base delivery revenues for each month. Delivery Service Revenue Targets for each of the Rate Years are set forth in the Joint Proposal dated July 14, 2010 in Case Nos. 09-E-0715, 09-G-0716, 09-E-0717, and 09-G-0718, and approved by the Commission on September 21, 2010. The Delivery Service Revenue Target for Rate Year 3 will repeat annually until changed by the Commission. For the purposes of determining the Delivery Service Revenue Target, revenues recovered under Industrial/High Load Factor rates will be combined with standard service class revenues. b. “Actual Billed Delivery Service Revenue”: For the purpose of RDM, will be measured as the sum of the billed base delivery revenues from all customers for each service classification. Base delivery revenues include revenues related to the Customer Charge, Demand Charge (per kW), Reactive Charge (per rkvah), and the Energy Charge for delivery (per kWh). For purposes of this calculation, revenues related to the System Benefits Charge (SBC), Renewable Portfolio Standard charge (RPS), Merchant Function Charge (MFC), Transition Charge (NBC), Temporary State Assessment Surcharge (TSAS), and New York Power Authority (NYPA)-supplied usage are excluded. All sales to customers with economic development discounts or low income bill credits will be calculated at standard service classification rates. c. “Rate Year”: for the purposes of RDM, Rate Year 1 will be effective through August 31, 2011. Each Rate Year thereafter will begin on September 1 in all subsequent 12-month periods. 3. Calculation: Beginning October 1, 2010: a. The RDM will reconcile per service class actual billed delivery service revenue to allowed delivery service revenue. b. For each service classification or sub classification subject to the RDM, each month, the Company will compare the Actual Billed Delivery Service Revenue and the Delivery Service Revenue Target. If the monthly Actual Billed Delivery Service Revenue exceeds the Delivery Service Revenue Target, the delivery service revenue excess will be accrued for refund to customers at the end of the Rate Year. Likewise, if the monthly Actual Billed Delivery Service Revenue is less than the Delivery Service Revenue Target, the delivery revenue shortfall will be accrued for recovery from customers at the end of the Rate Year. c. At the end of the Rate Year, total delivery service revenues will be compared to cumulative monthly target revenues for each service classification or sub classification. Any variance from cumulative target revenues will be either refunded or surcharged to customers over the twelve monthly periods of the immediately succeeding Rate Year. Any surcharge or credit amount will reflect interest at the then effective other customer deposit rate and will be either recovered or returned on a service classification or sub classification basis

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 22 New York State Electric & Gas Corporation Revision: 7 Initial Effective Date: September 26, 2010 Superseding Revision: 5 Issued in compliance with Order in Case 09-E-0715, dated September 21, 2010 GENERAL INFORMATION 7. Revenue Decoupling Mechanism Adjustment (“RDM”) (cont.)
3. Calculation (cont.) c. The surcharge or credit for each applicable service classification or sub classification shall be determined by dividing the amount to be refunded or surcharged to customers in that service classification or sub classification by estimated kWh or kW deliveries to customers in that service classification or sub classification over a twelve (12) month period. A per kW surcharge or credit will be applied for those classes that do not have a kWh delivery charge. A per kWh surcharge or credit will apply for all other service classifications. Following each RDM Adjustment period, any difference between the amounts required to be charged or credited to customers in each service classification or sub classification and amounts actually charged or credited will be charged or credited to customers in that service classification or sub classification, with interest, over the subsequent RDM Adjustment period, or as determined by the Public Service Commission, if no RDM is in effect. The first two months of the Rate Year will be adjusted upward to reverse the effect of proration of changes in effective delivery rates. If a customer qualifies for and takes service under Service Classification Nos. 13 or 14, or receives an allocation of NYPA Power, or if a customer taking service under Service Classification Nos. 13 or 14 switches to another service classification subject to the RDM, or has an allocation of NYPA power that expires, such customer customer migration will be treated symmetrically using the following methodology: i. If a customer moves from a flexible rate contract to an RDM class, the RDM target will increase by the level of revenue forecast for that customer in the rate year under the flexible rate contract pro-rated by the number of months in the new service class, making the Company whole for delivery revenues below the level forecast in the rate year. Any revenue in excess of the forecast will be credited to the RDM class. ii. If a customer moves from a RDM class to a flexible rate contract, the RDM target will be decreased by that customer's sales in the flexible rate contract priced out at full tariff rates, making the RDM class whole for delivery revenues from the migrating customer. iii. In situation (a) and (b) above, the Companies will adjust the RDM targets for the remaining months of the current rate year, and in the subsequent rate years. If at any time during Rate Year, the actual total accumulated billed delivery service revenues vary plus or minus 1.25% or more from the total accumulated Delivery Service Revenue Targets, the Company will file an interim RDM Adjustment for each service classification and sub classification. For the Rate Years listed below, the amounts by Rate Year (positive or negative) will trigger an interim RDM Adjustment for each service classification and sub classification: i. Rate Year 1: $5.89 million; ii. Rate Year 2: $6.63 million; iii. Rate Year 3: $6.89 million Such interim RDM Adjustment will be limited to no more than one per Rate Year and will occur over four (4) months or until the end of the Rate Year, whichever is longer. 4. A Revenue Decoupling Mechanism (RDM) Statement setting forth the rate adjustment will be filed with the Public Service Commission on not less than thirty (30) days’ notice to be effective November 1. Should the Company file an interim RDM Adjustment as described above, such filing will occur on not less than ten (10) days’ notice. Such statement can be found at the end of this Schedule (PSC No. 120 – Electricity).

d.

e. f.

g.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2007

Leaf No. 23 Revision: 2 Superseding Revision: 0

GENERAL INFORMATION 8. Economic Development Incentive: This incentive is no longer available to additional customers on or after January 1, 2007. Customers being served under this provision as of December 31, 2006, will be permitted to continue such service until the customer’s incentive term expires. Upon application, a prospective customer, or an existing customer investing in additional electricity-utilizing equipment, that is a Commercial or Industrial customer eligible for service under Service Classification Nos. 2, 3 or 7 may qualify for the Economic Development Incentive ("EDI"). The EDI will be in the form of a reduction, as stated in the applicable Special Provision, to the rates of the respective service classifications for qualified electric use during a term of 60 months. An eligible "prospective customer" is hereby defined as a business entity which demonstrates that: a) its activities are largely or entirely different in nature from that of the previous customer or b) if the activities are not different, the owner(s) is different; or c) business has not been conducted at the premises for at least 6 months prior to the application for EDI benefits, or (d) the predecessor customer is in bankruptcy and the applicant has obtained the business in a liquidation sale. An eligible "existing customer" is hereby defined as a business entity that does not qualify as a prospective customer and is presently taking electric service from the Corporation's system, thus establishing a base load. Such customer, upon application and qualification, must add equipment to increase its facility's existing load to qualify for this incentive, which is solely applicable to such increased load. All such above-described eligible customers, except "Retail Trade" customers, taking service under Service Classification Nos. 2, 3 or 7 will qualify for this incentive by installing equipment with a nameplate rating of at least 25 kW for Service Classification No. 2 or 100 kW for Service Classification Nos. 3 and 7. Retail Trade customers are classified by the Standard Industrial Classification Manual (1972 edition as amended or superceded) as "Retail Trade" under Division G encompassing Major Groups 52 through 59. A qualified customer will have its monthly service bills reduced by the per kilowatt-hour (kWh) amount stated in the applicable Special Provision, for all kWh (excluding kWh associated with load supplied by the New York Power Authority) in excess of a base amount of kWh established for each monthly billing period. For an existing customer, the base amount of kWh will be based on a one year historical period, actual or estimated as determined by the Corporation prior to qualification for this incentive. For a prospective customer, the base amount of kWh will be zero. Each month, the excess kWh qualifying for this incentive will be limited to a monthly average of 730 hours times the nameplate or rated demand of the equipment initially installed to qualify for this incentive. A qualified customer may choose to take its entire service under Service Classification No. 7 for the duration of the 60-month incentive term and at the end of the incentive term, such customer may either remain on the Service Classification No. 7 or revert to the otherwise applicable service classification.

Issued in compliance with order in Case No. 05-E-1222 dated 08/23/06.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010 GENERAL INFORMATION 8. Economic Development Incentive: (Cont’d) Eligibility for Rate Options

Leaf No. 24 Revision: 4 Superseding Revision: 3

Customers receiving an Economic Development Incentive (EDI) for load qualified on or after July 1, 2003 may select one of the following rate options as specified in General Information Section 25, Supply Service Options, for all of their load: 1) NYSEG Supply Service (NSS), 2) ESCO Supply Service (ESS), or 3) Hourly Pricing. The incentive rate reduction applicable to the qualified incented load under each rate option is set forth in the applicable Special Provision for Economic Incentives of the respective service classifications. If a prospective customer applying for service and also applying for this incentive has not elected a rate option by the time of billing, NYSEG will bill the customer on the NSS rate. A customer electing ESS must adhere to the process set forth in Section 25.I.I., Changing Supply Service Options. The Energy Services Company (“ESCO”) will contact NYSEG directly to convey the customer’s ESS rate selection and Retail Access enrollment. 9. Economic Development Zone Incentive: Upon application, a prospective or existing non-residential customer located in an approved Economic Development Zone ("Empire Zone"), that is eligible for service under Service Classification Nos. 2, 3, 6, 7 or 9, may qualify for the Economic Development Zone Incentive ("EDZI"), as stated in the applicable Special Provision for Economic Incentives of the respective service classifications for qualified electric use. Such eligible customer may qualify for the EDZI by operating or adding equipment at the premises with a nameplate rating equal to the lesser of: (a) 25 percent of the existing Contract Demand (or "Connected Load" for a non-Demand Charge service classification customer), or (b) 25 kilowatts (kW). An eligible "prospective customer" is hereby defined as a business entity which demonstrates that: a) its activities are largely or entirely different in nature from that of the previous customer or b) if the activities are not different, the owner(s) is different; or c) business has not been conducted at the premises for at least 6 months prior to the application for EDZI benefits; or (d) the predecessor customer is in bankruptcy and the applicant has obtained the business in a liquidation sale. An eligible "existing customer" is hereby defined as a business entity that does not qualify as a prospective customer and is presently taking electric service from the Corporation's system, thus establishing a base load. Such customer, upon application and qualification, must add equipment to increase its facility's existing load, as stated above, to qualify for this incentive, which is solely applicable to such increased load.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 25 Revision: 4 Superseding Revision: 3

GENERAL INFORMATION 9. Economic Development Zone Incentive: (Cont'd) A qualified customer may choose to take its entire service under S.C. No. 7 for the duration of the incentive term, and at the end of the incentive term such customer may either remain on the Service Classification No. 7 or revert to the otherwise applicable service classification. A customer who otherwise would be billed under S.C. No. 6 or 9, who does not choose to take service under S.C. No 7, will be billed under S.C. No. 2 – General Service (Secondary Voltages with Demand Billing). To qualify for the EDZI, an eligible customer, upon application, must present the Corporation with the appropriate certification from the approved Economic Development Zone Administrator. For customer load that qualified prior to July 1, 2003, the EDZI will be applied for a period of ten (10) years, beginning on the date of the qualifying load installation and operation, unless the customer's initial zone certification(s) becomes invalid, notwithstanding the expiration of the designation of an Economic Development Zone in the area where the customer is located. For customer load that qualifies on or after July 1, 2003, the EDZI will be applied for a period of ten (10) years following initial zone certification, beginning with the eligibility date on the certificate, unless the customer’s initial zone certification(s) becomes invalid, notwithstanding the expiration of the designation of an Economic Development Zone in the area where the customer is located. A qualified customer will have his monthly service bills reduced by the amount per kilowatt-hour (kWh) stated in the applicable Special Provision for Economic Incentives, for all kWh (excluding kWh associated with load supplied by the New York Power Authority) in excess of a base amount of kWh established for each monthly billing period. For an existing customer, the base amount of kWh will be based on a one-year historical period, actual or estimated, as determined by the Corporation prior to qualification for the incentive. For a prospective customer, the base amount of kWh will be zero. For load qualified prior to July 1, 2003, each month, the excess kWh qualifying for the incentive will be limited to 730 hours times the nameplate or rated demand of the equipment initially installed to qualify for the incentive. For load qualified on or after July 1, 2003, there will be no such limitation (e.g., 730 hours use) on the kWhs to which the incentive will apply. Such economic incentive rate per kWh in effect at the time of qualification will be applied to that customer's bill for the duration of the customer's valid certification, as specified above. Eligibility for Rate Options Customers receiving an Economic Development Zone Incentive (EDZI) for load qualified on or after July 1, 2003 may select one of the following rate options, as specified in General Information Section 25, Supply Service Options, for such qualified incented load: 1) NYSEG Supply Service (NSS) or2) ESCO Supply Service (ESS) or 3) Hourly Pricing. The incentive rate reduction applicable to the qualified incented load under each rate option is set forth in the applicable Special Provision for Economic Incentives of the respective service classifications.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010 GENERAL INFORMATION 9. Economic Development Zone Incentive (Cont'd.) Eligibility for Rate Options (Cont'd.)

Leaf No. 26 Revision: 7 Superseding Revision: 6

If a prospective customer applying for service and also applying for this incentive has not elected a rate option by the time of billing, NYSEG will bill the customer on the NSS rate. A customer electing ESS must adhere to the process set forth in Section 25.I.I., Changing Supply Service Options. The Energy Services Company ("ESCO") will contact NYSEG directly to convey the customer's ESS rate selection and Retail Access enrollment. 10. Economic Development Power ("EDP"): Economic Development Power within Service Classification No. 7 is available under the following conditions: As of March 1, 2003, customers were taking deliveries of 36.1 MW of EDP pursuant to FERC Rate Schedule No. 179. Subject to the provisions of this Section, those customers will continue to be billed for delivery in accordance with FERC Rate Schedule No. 179. If any EDP allocation comprising part of the 36.1 MW being delivered in accordance with FERC Rate Schedule No. 179 as of March 1, 2003 is surrendered, terminated, withdrawn or otherwise relinquished, renewed or extended, and is then re-allocated by NYPA, i. such allocation shall be delivered by NYSEG at the standard ESCO Supply Service (ESS) rate (as specified in Section 25, Supply Service Options), which includes the Transition Charge (NonBypassable Charge), and ii. the 36.1 MW level billed in accordance with FERC Rate Schedule No. 179 shall be reduced accordingly. Beginning on August 1, 2007, customers taking deliveries of “New Allocations” of EDP will be exempt from the Transition Charge (Non-Bypassable Charge) in accordance with General Information Section 12. EDP deliveries will be exempt from the System Benefits Charge and the Renewable Portfolio Standard Charge effective January 1, 2007. The rates and conditions provided in this provision are subject to review by, acceptance by or approval from the Federal Energy Regulatory Commission ("FERC") to the extent of the FERC's jurisdiction.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010 GENERAL INFORMATION 11. Reserved for Future Use

Leaf No. 27 Revision: 3 Superseding Revision: 2

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010
GENERAL INFORMATION

Leaf No. 28 Revision: 9 Superseding Revision: 8

12.

New Allocations of NYPA Power Pursuant to the Commission’s Order Adopting Joint Proposal on New York Power Authority Issues, issued and effective July 20, 2007: “New Allocations” are defined as all allocations of NYPA Power made to customers within the Company’s service territory for whom deliveries commenced on or after June 1, 2006, and does not include allocations made under NYSEG’s Federal Energy Regulatory Commission (FERC) Rate Schedule Nos. 110 or 179. For customers receiving New Allocations of NYPA Power, such NYPA load will be served under the applicable Service Classification Nos. 2, 3, or 7 at the Company’s standard ESCO Supply Service (ESS) tariff rates. a. New Allocations of NYPA Power (i.e., Expansion Power, Replacement Power, High Load Factor Manufacturer Power, Economic Development Power, Preservation Power), and New Allocations of power under any future NYPA power program for customers served under Service Classification Nos. 2, 3, or 7, as applicable, up to a total of 100 MW, will be exempt from the Transition Charge (Non-Bypassable Charge). Such exemption will be effective with the customer’s usage beginning on or after August 1, 2007.

b.

Should NYPA’s Power For Jobs program, by that or some other name, be extended by Statute that does not include a provision for full recovery of lost revenues by NYSEG through a revenue tax credit or other mechanism, power allocations to customers participating in such NYPA program would be considered New Allocations and would contribute to the 100 MW total.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2007

Leaf No. 29 Revision: 5 Superseding Revision: 2

GENERAL INFORMATION 12. Reserved for Future Use

Issued in compliance with order in Case No. 05-E-1222 dated 08/23/06.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2007
GENERAL INFORMATION 12. Reserved for Future Use

Leaf No. 30 Revision: 3 Superseding Revision: 1

Issued in compliance with order in Case No. 05-E-1222 dated 08/23/06.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2007 GENERAL INFORMATION
12. Reserved for Future Use

Leaf No. 30.1 Revision: 2 Superseding Revision: 0

Issued in compliance with order in Case No. 05-E-1222 dated 08/23/06.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2007
GENERAL INFORMATION 12. Reserved for Future Use

Leaf No. 31 Revision: 3 Superseding Revision: 1

Issued in compliance with order in Case No. 05-E-1222 dated 08/23/06.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2007

Leaf No. 32 Revision: 5 Superseding Revision: 3

GENERAL INFORMATION 12. Reserved for Future Use

Issued in compliance with order in Case No. 05-E-1222 dated 08/23/06.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2007 GENERAL INFORMATION 12. Reserved for Future Use

Leaf No. 33 Revision: 3 Superseding Revision: 1

Issued in compliance with order in Case No. 05-E-1222 dated 08/23/06.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2007 GENERAL INFORMATION 12. Reserved for Future Use

Leaf No. 33.1 Revision: 2 Superseding Revision: 0

Issued in compliance with order in Case No. 05-E-1222 dated 08/23/06.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2007 GENERAL INFORMATION 12. Reserved for Future Use

Leaf No. 34 Revision: 3 Superseding Revision: 1

Issued in compliance with order in Case No. 05-E-1222 dated 08/23/06.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2007
GENERAL INFORMATION 12. Reserved for Future Use

Leaf No. 35 Revision: 3 Superseding Revision: 1

Issued in compliance with order in Case No. 05-E-1222 dated 08/23/06.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2007
GENERAL INFORMATION
12. Reserved for Future Use

Leaf No. 36 Revision: 3 Superseding Revision: 1

Issued in compliance with order in Case No. 05-E-1222 dated 08/23/06.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2007

Leaf No. 37 Revision: 4 Superseding Revision: 2

GENERAL INFORMATION 12. Reserved for Future Use

Issued in compliance with order in Case No. 05-E-1222 dated 08/23/06.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2007

Leaf No. 38 Revision: 4 Superseding Revision: 2

GENERAL INFORMATION 12. Reserved for Future Use

Issued in compliance with order in Case No. 05-E-1222 dated 08/23/06.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2007
GENERAL INFORMATION 13. Incubator Development Incentive (IDI):

Leaf No. 39 Revision: 2 Superseding Revision: 0

This incentive is no longer available to additional customers on or after January 1, 2007. Customers being served under this provision as of December 31, 2006 will be permitted to transition to the Incremental Load Incentive as described in General Information Section 19 and set forth in the Special Provision for Economic Incentives of the respective Service Classifications. Business incubators contribute to economic development by facilitating the development, growth and success of fledgling business enterprises, often associated with new technology initiatives, by providing appropriate start-up facilities, with support resources and services, including assistance in developing a viable business plan, with quantifiable objectives for successful graduation from the incubator. Upon application, verification of eligibility, and 30 days' notice to the Corporation, a multi-tenant business incubator facility that is eligible for service under Service Classification Nos. 2, 3, or 7 may qualify for the Incubator Development Incentive in the form of a reduction, as stated in the applicable Special Provision of each service classification, to the energy rate (per kWh charge) in the respective service classification. To be eligible, the customer must meet the following requirements: • the applicant must be a multi-tenant business incubator facility, owned and operated by a not-for-profit corporation or a public benefit corporation, as defined in Section 201 of New York State Not-For-Profit Corporation Law, but not limited to customers previously qualified for the Industrial Incubator Incentive due to having received authorized financing under Section 26 of Chapter 839 of the Laws of the State of New York, 1987 and the Urban Development Corporation Act 174/68, as amended, within the Corporation's service territory. Additionally, incubator facilities which are owned, wholly or in part, by a university for the purposes of developing or demonstrating the business viability of new technological developments may be eligible for service under this Incubator Development Incentive. at least 50% of the leased floor space in the facility must be to tenants actively engaged in: 1. developing or demonstrating the business viability of new technological processes; and/or 2. manufacturing activity and/or 3. developing a manufacturing process as classified in Division D, encompassing Major Groups 20 through 39 or services as specified in Section I, Major Group 87, of the Standard Industrial Classification Manual (1987 edition or supplements thereto) the facility must have a graduation policy requiring tenants to relocate outside of the facility after a specified period of time, not to exceed five (5) years upon application, the customer must present to the Corporation appropriate documentation confirming their corporate status and demonstrating their intended operation as a business incubator facility.

•

• •

For customers who qualify: • • All use for incubator participants and administration, including support service and anchor tenants will be qualified to receive the incentive. The incentive rate will apply to the customer's total monthly kilowatt-hour usage (excluding kWh associated with load supplied by the New York Power Authority).

Issued in compliance with order in Case No. 05-E-1222 dated 08/23/06.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010 GENERAL INFORMATION

Leaf No. 40 Revision: 4 Superseding Revision: 3

13.

Incubator Development Incentive (IDI): (Cont'd) For customers who qualify: (Cont'd) • The Incubator Development Incentive per kWh in effect at the time of qualification, as stated in the Special Provision of the applicable service classification, will be applied to the customer's bill for the duration of the customer's qualification. However, the incentive rate will be subject to periodic (not to exceed annual) review and possible modification, with Public Service Commission approval. NYSEG reserves the right to discontinue the availability of this incentive, on one year's notice, upon determination it is no longer economically or financially needed or feasible. Upon discontinuation of the incentive, NYSEG will provide the incentive on a pro-rata basis to the remaining qualified tenants for 5 years after the notification of intent to discontinue the incentive provision. A qualified customer may choose to take their entire service under Service Classification No. 7, for the duration of the incentive term. At the end of this term the customer may elect either to remain on the SC7 rate, or revert to the otherwise applicable service classification. The customer agrees to undergo a NYSEG-supplied energy audit or similar site-specific technical information program and to assess in good faith the resulting recommendations for inclusion in the customer's facility.

• •

•

•

Eligibility for Rate Options Customers qualifying for the Incubator Development Incentive (IDI) on or after July 1, 2003 may select the NYSEG Supply Service (NSS) rate or the ESCO Supply Service (ESS) rate for such qualified incented load. The incentive rate reduction applicable to the qualified incented load under NSS or ESS is set forth in the Special Provision for Economic Incentives of the respective service classifications.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003 GENERAL INFORMATION

Leaf No. 41 Revision: 0 Superseding Revision:

14.

Competitive Metering Option: (Cont’d.) (a) This Section contains the rates, terms and conditions of the Corporation’s Competitive Metering Option, consistent with the Commission’s New York Practices and Procedures for The Provision of Electric Metering In A Competitive Environment, set forth within Addendum-MET of PSC 119 (“Manual”), or superseding issues thereof. Qualified Customers, defined as those who have a metered demand of at least 50 kW at each meter in any two consecutive months during the most recent twelve (12) month period, may select the Competitive Metering Option as set forth in this Schedule. Once the PSC issues a list of Meter Service Providers (MSPs) and Meter Data Service Providers (MDSPs), both of which have met the PSC’s eligibility requirements for competitive metering, Qualified Customers can elect the Competitive Metering Option. Note that a Direct Customer, defined as a customer eligible for electric retail access, with 1 MW or greater of load in any hour that there is a scheduled transaction that acts without an ESCO and acts to procure Electric Power Supply solely for its own use and not for resale, is prohibited from acting as its own MSP or MDSP. Qualified Customers may obtain electric metering services from NYSEG or an entity other than NYSEG (“competitive metering services”) consistent with the provisions of this Schedule and PSC 119 Electricity. Competitive metering services may be obtained directly from a MSP which meets the requirements of Section 14.d below.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: December 1, 2008 GENERAL INFORMATION

Leaf No. 42 Revision: 3 Superseding Revision: 2

14.

Competitive Metering Option: (Cont’d.) (b) Customer Qualification Qualified Customers whose entire or partial load is served under any of NYSEG’s economic development incentive rates (ERI, IDI, EDI, EDZI or ILI) and who select the Competitive Metering Option must elect the Competitive Metering Option on their entire load. Similarly, Qualified Customers who receive a portion of their Electric Power Supply from NYPA (Expansion, Replacement Power, EDP, HLFM, PFJ and Preservation Power) and who select the Competitive Metering Option must elect the Competitive Metering Option on their entire load. Customers whose entire load is served under NYSEG’s S.C. 13 or S.C. 14 contracts may be eligible for the Competitive Metering Option after their contracts expire, unless their contracts with NYSEG permit such customer to become eligible earlier. (c) Competitive Metering Charges Qualified Customers who obtain competitive metering service(s) from an MSP/MDSP which has met the PSC’s eligibility requirements for competitive metering will not be charged the Meter Ownership, Meter Service and/or Meter Data Service Charge for the specific service(s) provided by the competitive metering provider.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003 GENERAL INFORMATION

Leaf No. 43 Revision: 0 Superseding Revision:

14.

Competitive Metering Option: (Cont’d.) (d) MSP/MDSP Eligibility Requirements A prospective MSP or MDSP must first submit an application to the Department of Public Service. Once determined to be eligible by the PSC, an MSP/MDSP may provide competitive metering services to Qualified Customers. An MSP/MDSP must have signed and delivered to NYSEG an Operating Agreement for Competitive Metering prior to their providing competitive metering services to a Qualified Customer. The entity providing competitive metering services to the Qualified Customer must provide MSPand MDSP-type services, as defined in the Manual, in one total package for the customer. An MSP/MDSP must comply with the applicable requirements, performance standards and regulations as determined by the Commission in Case 00-E-0165, and as set forth in the Manual. Consistent with the Manual, an MSP will provide PSC-approved meters as well as meter installations, testing and maintenance. An MDSP will provide meter reading, meter data translation, and Customer Association, Validating, Estimating and Editing (“CAVEE”). Consistent with the Manual, the Commission may remove the eligibility of an MSP/MDSP for certain reasons, including, but not limited to, unsatisfactory performance, failure to employ qualified personnel or to comply with applicable regulations.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003 GENERAL INFORMATION

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14.

Competitive Metering Option: (Cont’d.) (e) Sign-up/Enrollment: The MSP shall provide the Qualified Customer a statement of the MSP’s terms and conditions that detail the Qualified Customer's rights, responsibilities, and expected costs (“Disclosure Statement”). A Qualified Customer’s sign-up with the MSP shall not be effective until three (3) calendar days after the Qualified Customer’s receipt of the Disclosure Statement. With a minimum notification time of ten (10) calendar days prior to the Qualified Customer’s next scheduled meter reading date, the MSP must provide NYSEG with notice, using Electronic Data InterChange (“EDIC”) mechanisms, stating that the MSP will provide the Qualified Customer with competitive metering services beginning on a certain date. The MSP shall provide to NYSEG the name of the customer who is financially responsible for the account, service address, mailing address, account number, and meter number of the Qualified Customer to be enrolled. Until EDIC mechanisms are functional NYSEG will accept the above-specified information by E-mail at [email protected]. (f) Switching To and From Competitive Metering Consistent with the Manual, the effective date of initial enrollment and switching to and from Competitive Metering will be as follows. When a Qualified Customer initially enrolls in the Competitive Metering Option, makes a change in MSP, or returns to NYSEG for electric metering services, the change will become effective on the Qualified Customer's next meter reading date, unless a Special Meter Reading date is requested as provided for in this Schedule at Section 16.D.11(f). This process will apply to both Voluntary and Involuntary Switches. The mechanism or medium used for conveying information for enrollments, confirmations, other requests and reports shall be E-mail until EDIC is functional, as agreed to by the parties. Once functional, EDIC will be used to transmit this information.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003 GENERAL INFORMATION 14. Competitive Metering Option: (Cont’d.) (g) Meter Data Transfer

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For revenue cycle meter data transfer (meter readings), the MSP/MDSP shall provide the Corporation, at no cost, all data required to issue a bill for NYSEG’s services using Electronic Data InterChange (“EDIC”) mechanisms. Until Electronic Data InterChange (“EDIC”) mechanisms are functional, the means for such revenue cycle meter data transfer will be mutually agreed upon by the parties, consistent with the Manual, and as further clarified in the Operating Agreement for Competitive Metering. A PSC-eligible MSP/MDSP shall read meters it owns/controls at the frequency specified by the Corporation, and shall provide NYSEG-required billing data within the time limits specified by the Corporation as further clarified in the Operating Agreement for Competitive Metering. (h) Repair or Replacement of Defective Equipment Consistent with the Manual, the PSC-eligible MSP/MDSP shall repair or replace any unsafe, inoperative or defective metering equipment under its control within twenty-four (24) hours of receipt of notice of such defect. (i) Meter Testing, Resolution of Billing Errors, and Competitive Meter Disputes If a Qualified Customer, MSP/MDSP, and/or utility dispute the accuracy of the meter, the testing procedures outlined in the Manual shall apply. Likewise, the resolution of billing errors and equipment malfunctions shall follow the procedures in the Manual.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003 GENERAL INFORMATION 14. Competitive Metering Option: (Cont’d.) (j) Qualified Customer Complaints

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Note: all the below rules should be applied consistent with the Commission’s Manual. i. Receipt of Complaints: if a Qualified Customer directs a complaint concerning a competitive meter to the utility, the utility shall inform the customer of its right to the complaint handling procedures provided by the MSP/MDSP, and its right to present its complaint to the Commission if it is not resolved. The MSP/MDSP must respond in accordance with the complaint handling procedures it has filed with the Commission.

ii.

iii. Resolution of Complaints: at the time the MSP/MDSP informs the Qualified Customer of its response to the customer’s complaint concerning a competitive meter, it shall advise the customer of the Commission’s complaint-handling procedures, including the Commission’s address and tollfree telephone number. iv. If a Qualified Customer is unable to reach a satisfactory resolution of a dispute concerning a competitive meter with the utility, MSP or MDSP, the customer may complain, either orally or in writing, to the Commission. v. Upon receipt of the complaint, the Commission, or its designee, shall have the authority to request and witness the test of a meter or metering device or otherwise to call for the removal of a metering device to determine device performance under controlled conditions such as those in a meter shop.

(k) Auditing Consistent with the Manual, the overall responsibility for the auditing of the Competitive Metering infrastructure shall reside with the Department of Public Service Staff. At the direction of Staff, the utility will conduct audits of metering sites and of meter maintenance work performed by MSPs. A utility may, at its own expense, audit the performance of MSPs/MDSPs by witnessing the work performed and/or by performing follow-up inspections.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003

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GENERAL INFORMATION 14. Competitive Metering Option: (Cont’d.) (l) Insurance Coverage PSC-eligible MSPs/MDSPs must satisfy the insurance requirements specified in the Manual. (m) Indemnity and Limitation on Liability: i. Indemnification: MSPs/MDSPs agree to indemnify, defend and save NYSEG harmless from and against any and all liabilities, losses, damages, costs, expenses, causes of action, suits, judgments and claims, including, but not limited to, reasonable attorneys fees and the costs of investigation, (collectively "claims"), in connection with any action, suit or proceeding by or on behalf of any person, firm, corporation or other entity arising from, caused by or relating to the (1) curtailment or interruption of services to the MSP/MDSP or its Qualified Customers, due to causes beyond the control of NYSEG (including, without limiting the generality of the foregoing, executive or administrative rules or orders issued from time to time by State or Federal officers, commissions, boards or bodies having jurisdiction) or (2) interruption, irregularity, failure or defective character of services to the MSP/MDSP, its Qualified Customers, due to causes beyond the control of NYSEG (including, without limiting the generality of the foregoing, executive or administrative rules or orders issued from time to time by State or Federal officers, commissions, boards or bodies having jurisdiction) or (3) failure by MSP/MDSP to perform any of the agreements, terms, covenants or conditions of the Competitive Metering Program to be performed by MSP/MDSP or (4) failure of MSP/MDSP to perform any agreement between MSP/MDSP and its Qualified Customers. ii. Limitation on Liability: NYSEG will endeavor at all times to provide regular and uninterrupted service to the MSP/MDSP, its Qualified Customers, but in case the service shall be interrupted or irregular or defective or shall fail, from causes beyond the control of NYSEG (including, without limiting the generality of the foregoing, executive or administrative rules or orders issued from time to time by State or Federal officers, commissions, boards, or bodies having jurisdiction) or because of the ordinary negligence of NYSEG or its employees, servants or agents, NYSEG shall not be liable to the MSP/MDSP, its Qualified Customers, therefor. Compliance with directives of the NYISO shall, without limitation by reason of specification, constitute a circumstance beyond the control of NYSEG for which NYSEG shall not be liable; provided, however, that NYSEG shall not be absolved from any liability to which it may otherwise be subject for gross negligence or intentional wrongdoing in the manner in which it carries out the NYISO instructions.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003 GENERAL INFORMATION 14. Competitive Metering Option: (Cont’d.) (n) Competitive Metering Fees

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Consistent with the Manual, NYSEG will assess the following fees associated with the Competitive Metering Option: i. If an MSP/MDSP requests an off-cycle meter read of a NYSEG-provided or NYSEG-controlled meter, the MSP will be charged a fee of $20. If NYSEG removes an MSP meter, unless otherwise agreed to, the MSP will be charged a fee of $150.

ii.

iii.To provide an MSP access to high-voltage CTs and PTs, NYSEG will charge the MSP a fee of $20. iv. If an MSP fails to keep a site visit appointment with NYSEG within 15 minutes of the agreed to time, the MSP will be charged a fee of $20. v. If an MSP switched a customer to competitive metering services without their authorization, the MSP will be charged fees amounting to all reasonable costs incurred by NYSEG.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2007 GENERAL INFORMATION 15. Power for Jobs:

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Upon application and no less than 30 days' notice to the Corporation, a customer otherwise qualifying under Service Classification Nos. 2, 3 or 7, that has met the requirements of the New York State Economic Development Power Allocation Board ("EDPAB") and received an allocation of Power for Jobs ("PFJ") power from the New York Power Authority's ("NYPA") Board of Trustees, may purchase from the Corporation the allocated power. NYPA shall advise NYSEG of such allocation and provide to the Corporation a copy of the applicable signed allocation contract. The power allocation shall be defined as the customer's "NYPA Contract Demand". The Corporation will purchase the allocated power from NYPA for subsequent sale to the customer pursuant to the contract between the Corporation and NYPA for PFJ service. NYPA shall provide no less than 30 days prior written notice to NYSEG for initial delivery of a PFJ allocation to each individual customer, changes in the amount of such allocations to an individual customer, and termination of any such allocation by NYPA, unless otherwise agreed upon. The portion of the customer's demand and energy needs met by the delivered PFJ will be billed in accordance with Special Provision (d) - Economic Incentives, Sub-Section No. 7 - Power for Jobs, within Service Classification No. 7. The customer's power requirements in excess of the PFJ service will be billed at the Service Classification No. 7 rates applicable to the customer's voltage level. However, PFJ customers will be exempt from paying the System Benefit Charge or Renewable Portfolio Standard Charge on the NYPA portion of their energy, effective January 1, 2007. For the purpose of identifying the portion of the customer's demand and energy supplied by NYPA, the capacity and energy provided by NYPA will be adjusted for losses from point of the Corporation wholesale purchase of NYPA power to the point of the sale to the customer. Service under this provision will be available to customers pursuant to Chapter 316 of the Laws of 1997, as amended by Chapter 386 of the Laws of 1998, Chapter 63 of the Laws of 2000, Chapter 226 of the Laws of 2002, Chapter 59 of the Laws of 2004, Chapters 63 and 313 of the Laws of 2005 and Chapter 645 of the Laws of 2006, provided they meet established eligibility requirements. Service under this provision is available to customers approved by EDPAB, subject to the partial or complete withdrawal of such allocation by NYPA or the EDPAB, in the event the customer fails to maintain mutually agreed upon terms of their contracts. Service under this provision will be available to qualified customers for the duration that such a power allocation, specifically designated for the purpose of the PFJ program, is made available through NYPA.

Issued in compliance with order in Case No. 05-E-1222 dated 08/23/06.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: November 1, 2007 GENERAL INFORMATION 16. General Retail Access: A. Introduction: 1.

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This Section contains the terms and conditions pertaining to General Retail Access. The rate options under which customers may take retail access are detailed in Section 25, Supply Service Options.

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003 GENERAL INFORMATION 16. General Retail Access: (Cont’d.) A. Introduction: (Cont’d.)

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2.

Because the New York Independent System Operator ("NYISO") commenced operations on November 18, 1999 pursuant to a FERC-approved NYISO Tariff and related agreements (“NYISO Tariff”), all transmission service within New York State is obtained through the NYISO pursuant to the NYISO Tariffs. This General Retail Access tariff may be revised, modified, clarified, supplemented, amended or superseded as may be necessary as a result of the NYISO Tariffs. NYSEG may seek to revise the terms and conditions of the tariff, the Supplier Manual and the Operating Agreement (including any pricing terms) as necessary to comply with the requirements of the NYISO Tariffs.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 19, 2004 GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont’d.) B. Definitions:

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As used herein, the following terms shall have the meanings set forth below. Additionally, other terms used within this Schedule are defined in the Uniform Business Practices (“UBPs”) (UPB Addendum). Ancillary Services: Those services necessary to support the transmission of energy from generation resources to loads while maintaining reliability of the electric system. Ancillary Services are described and provided for in the NYISO (defined below). Auction: NYSEG's auction of coal-fired generation assets as set forth in the Agreement approved in the Settlement Order. Balancing and Settlement: Load Balancing and Settlement is the process of reconciling (1) scheduled deliveries of Electric Power Supply by an ESCO/DC to serve their own needs or those of Eligible Customers, to (2) total actual customer load of the ESCO or a DC’s load, on an hourly basis. The NYISO provides energy imbalance service (also known as Balancing and Settlement) in accordance with the NYISO Market Services Tariff. Business Days: As defined in NYSEG's Tariff, P.S.C. No. 119 - Electricity, as the same may be revised, modified, amended, supplemented, clarified or superseded. Combination Account: A common account for both gas and electric service for the purpose of combined gas and electric billing by the Company. A Combination Account is served under PSC No. 87 - Gas or PSC No. 88 - Gas, and under this Schedule. Commission or PSC: Public Service Commission of the State of New York, or any successor agency thereto.

Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010 GENERAL INFORMATION 16. General Retail Access: (Cont’d.) B. Definitions: (Cont’d.)

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Department of Public Service (“DPS”): The Public Service Commission Staff which is responsible for developing and implementing New York State regulatory and energy policies; receiving, investigating, and resolving complaints on billing, services, or other utility practices; and administering regulations issued by the Commission. (For example, ESCOs must file their initial eligibility application with the Commission’s Consumer Services Division, a part of DPS.) Electric Power Supply: The electricity required to meet the Eligible Customer’s needs, including energy, Energy Losses, Unaccounted for Energy (“UFE”), Capacity, Capacity Reserves, Capacity Losses, ancillary services, NYPA Transmission Access Charges (“NTAC”),and a Supply Adjustment Charge. ESCOs/DCs are responsible for providing the full Electric Power Supply requirements of their eligible customers. Eligible Customer: A customer that takes service through an account that meets the customer eligibility criteria set forth in Section 16.D. Eligible Industrial Customer: An account of a customer which is coded Revenue Class 30 as defined by Division "D" of the Standard Industrial Classification ("SIC") Manual that is engaged in manufacturing (SIC Codes 20-39) or Division “B” mining (SIC Major Codes 10-14) and which does not qualify for the Industrial/High Load Factor provision within SC 2, 3 and 7 of this tariff as more particularly described herein. Energy Losses: The unusable energy that results from the generation, transformation, transmission and distribution of Electric Power Supply to an Eligible Customer’s meter. Unaccounted For Energy (“UFE”) is also included.

FERC: Federal Energy Regulatory Commission, or any successor agency thereto.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 19, 2004 GENERAL INFORMATION 16. General Retail Access: (Cont’d.) B. Definitions: (Cont’d.)

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Interruptible Service: Special Provision (c) of S.C.7 sets forth the terms under which NYSEG will provide a monthly billing credit to customers who agree to reduce their demand to a specified level when service interruption is requested by NYSEG. Involuntary Switch: A process or situation where an Eligible Customer's ESCO is changed from one provider e.g., ESCO or utility, to another without the Eligible Customer's authorization. An involuntary switch that is not in accord with the "Discontinuance of Service" provision set forth in this tariff is referred to as "slamming." Examples of involuntary switches include, but are not limited to, situations where a customer returns to NYSEG service as a result of an ESCO’s failure to deliver, the ESCO going out of business, or the termination of the ESCO’s participation in NYSEG’s Program. New York Independent System Operator ("NYISO"): An organization formed under FERC approval to provide equal access to the transmission system of New York State and to maintain system reliability, and any successor organization thereto. NYISO Open Access Transmission Tariff (“NYISO OATT”): The tariff filed with and approved by FERC as the same may be revised, modified, amended, clarified, supplemented or superseded, that sets forth the rates, terms and conditions under which the NYISO provides open access transmission service. NYISO Tariffs: The NYISO OATT (defined above) and the NYISO Market Services Tariff, as well as NYISO technical bulletins, procedures and any other guidelines issued by the NYISO that set forth the rates, terms and conditions under which the NYISO provides open access transmission services.

Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003

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GENERAL INFORMATION 16. General Retail Access: (Cont’d.) B. Definitions: (Cont’d.) Operating Agreement: The standard form agreement between NYSEG and the ESCO or the DC setting forth the duties, responsibilities and obligations of NYSEG and the ESCO or the DC, which agreement must be executed and delivered by the ESCO or the DC as a condition to participate in the Program. Opinion No. 97-5: The Commission's Opinion and Order Establishing Regulatory Policies for the Provision of Retail Energy Services, issued and effective May 19, 1997, in Case No. 94-E-0952, as the same may be revised, modified, amended, clarified, supplemented or superseded. Opinion No. 99-3: The Commission’s Opinion and Order concerning Uniform Business Practices, in Case 98-M-1343, issued February 16, 1999 (the “UBP Order”) as the same may be revised, modified, amended, clarified, supplemented or superseded. Order: The Commission's Order Establishing Retail Access Pilot Programs , issued and effective June 23, 1997, Case No. 96-E-0948, as the same may be revised, modified, amended, clarified, supplemented or superseded. Partial Requirements Customers: Those customers that are taking service for a portion of their load under NYSEG’s economic incentives, Interruptible Service or NYPA service. POLR: The Provider Of Last Resort as defined in Section 16.D.15 of this General Retail Access tariff.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 19, 2004

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GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont’d.) B. Definitions: (Cont’d.) Segment Load Profiles: The electric power consumption (kWh) as measured in one hour intervals, statistically valid for a specified group of Eligible Customers. Standard Load: Load served at NYSEG’s standard tariff rates, terms and conditions.

Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: November 1, 2007 GENERAL INFORMATION 16. General Retail Access: B. Definitions: (Cont’d.)

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Supplier Manual: The Customer Advantage Supplier Manual dated August 1, 1998, as the same may be revised, modified, amended, supplemented, clarified or superseded. Uniform Business Practices (UBPs) shall mean those practices set forth in the UBP Addendum, which are incorporated herein by reference. Unforced Capacity (“UCAP”): power supply resources (maximum realizable generator capabilities adjusted for forced outage rates, also may include special case resources) obtained by an ESCO/DC to meet the peak load the ESCO/DC will serve in a given Obligation Procurement Period. Unforced Capacity Losses (“UCAP Losses”): The unusable energy and associated capacity that results from the generation, transformation, transmission and distribution of energy to meet peak load. Unforced Capacity Reserves (“UCAP Reserves”): power supply resources (maximum realizable generator capabilities adjusted for forced outage rates, also may include special case resources) in excess of the system peak load required by the NYISO. The UCAP Reserves amount is set annually by the New York State Reliability Council (“NYSRC”) or the NYISO. Voluntary Switch: A process or situation where an Eligible Customer's ESCO is changed from one provider to another with the customer's authorization or where an Eligible Customer returns to NYSEG on its own initiation. A Voluntary Switch is any switch authorized by the Eligible Customer. An ESCO may act as the customer’s authorized designee in a voluntary switch situation. C. Implementation 1. See Section 25 of this Schedule, Supply Service Options, to elect a Retail Access Rate Option.

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010 GENERAL INFORMATION 16. General Retail Access: (Cont’d.) D. Eligible Customer Participation: (Cont’d.) 1. Eligibility Requirements:

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Eligibility to participate in General Retail Access is open to all customers subject to requirements set forth in Section Nos. 16 (General Retail Access) and 25 (Supply Service Options.) (a) For customers taking service under an economic incentive provision (EDI, EDZI, IDI, or ILI), the Company will bill such incented or discounted load at the applicable rate option as specified in the applicable Special Provision for Economic Incentives of the respective service classifications, subject to Section 25, Supply Service Options. The customer shall select the same Supply Service Option for all of their load, including the portion of their load receiving the incentive. (b) Customers whose entire load is served under Service Classification Nos. 13 or 14 may be eligible for retail access after their contracts expire, unless their contracts with NYSEG permit such customer to become eligible earlier. Upon expiration of such SC 13 or SC 14 contracts, customers may be eligible to select any Supply Service Option in accordance with Section 25, Supply Service Options.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: December 1, 2008 GENERAL INFORMATION 16. General Retail Access: (Cont’d.) D. Eligible Customer Participation: (Cont’d.) 1. Eligibility Requirements: (Cont’d.) (d)

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Customers who receive a portion of their Electric Power Supply from NYPA, (Expansion, EDP, HLFM, PFJ, Replacement or Preservation Power), with Standard Load (non-NYPA load), shall be permitted to take service under any rate option for their Standard Load subject to the provisions of Section 25, Supply Service Options. The NYPA load will continue to be billed at the appropriate NYPA rate as specified in the Special Provision of Service Classification No. 7. If the NYPA allocation expires or is terminated, the customer will have 30 days to elect a Supply Service option for that load, subject to the provisions of Section 25, Supply Service Options.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: November 1, 2007 GENERAL INFORMATION 16. General Retail Access: (Cont’d.) D. Eligible Customer Participation: (Cont’d.) 1. Eligibility Requirements: (Cont’d.)

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(e) The following customer eligibility requirements also apply: i. An Eligible Customer, whose Electric Power Supply and delivery would otherwise be provided by NYSEG, under S.C. Nos. 1, 2, 3, 5, 6, 7, 8, 9, 11 or 12, may arrange for Electric Power Supply only from an ESCO that meets the requirements set forth herein.

ii. An Eligible Customer may select only one ESCO at a time per customer account, regardless of the number of meters.

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 19, 2004 GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont’d.) D. Eligible Customer Participation: See UBP Addendum

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Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: February 19, 2004 GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont’d.) RESERVED FOR FUTURE USE

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Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 19, 2004 GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont’d.) D. Eligible Customer Participation: 1. Customer Information - Current:

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All information to be furnished by NYSEG will be provided electronically to ESCOs/DCs when the data is acceptable to NYSEG for the purposes of billing its Eligible Customers for service provided by NYSEG. Where estimated meter readings are used, the estimates must also be provided to ESCOs/DCs when the data is acceptable by NYSEG to bill its Eligible Customers for service provided by NYSEG. All subsequent changes or corrections and adjustments to previously supplied data will be made available to the ESCOs/DCs when the data is acceptable to be used for its Eligible Customers. 2. Historical & Current Information Available Free of Charge: For usage & billing information, NYSEG will provide up to 24 months of the most recent historic usage and billing information (billing determinants, as described above) except as provided for in paragraph 3 below. For credit information, NYSEG will provide information on whether the Eligible Customer had late payments and/or disconnections due to nonpayment during the immediately preceding 24 months or life of the account, whichever is shorter. 3. Historical & Current Information Available For A Fee: For historical usage and billing information and credit information, see UBP Addendum, Section 4.E. Should an Eligible Customer and/or its designee request historical usage and billing information for more than 24 consecutive months, NYSEG will provide this information (if available) for a fee of $15 for each additional twelve (12) month period or portion thereof. Information not identified in this paragraph shall be supplied, if available, at NYSEG’s incremental cost. Should an Eligible Customer or its authorized designee request historical interval data in special customized formats, a fee will apply. Detailed interval data for an account, if available, will be provided at a fee of $40 per meter, per request, for data up to 24 months. For credit information, a $15 fee will be charged for credit information beyond the twenty-four (24)month period. The fees detailed in this section shall be payable by the requestor.

Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 19, 2004 GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont’d.) D. Eligible Customer Participation: (Cont’d.) 4. Sending Customer Information:

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Usage and billing information will be sent to the requestor. ESCOs will be required to obtain and retain proper customer authorization for such information. Credit information will be mailed to the Eligible Customer's address unless NYSEG receives the proper written customer authorization from the ESCO. 5. Confidentiality: The ESCO must keep confidential any customer information (usage and billing and credit information) obtained from NYSEG. This information shall not be disclosed to any party, unless otherwise authorized by the Eligible Customer in writing. All other customer information, such as account numbers (and any passwords used, if applicable), telephone numbers and service addresses, shall also be kept confidential and not disclosed to others, unless otherwise authorized in writing by the Eligible Customer. NYSEG will not disclose a customer's usage and billing and credit information to an ESCO if that Eligible Customer has notified NYSEG, in writing, that such information should not be disclosed. The information may thereafter be disclosed to an ESCO only with the Eligible Customer's written authorization.

Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 19, 2004 GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont’d.) D. Eligible Customer Participation: (Cont’d.) RESERVED FOR FUTURE USE

Leaf No. 65 Revision: 1 Superseding Revision: 0

Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 19, 2004 GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont’d.) D. Eligible Customer Participation: (Cont’d.) RESERVED FOR FUTURE USE

Leaf No. 66 Revision: 1 Superseding Revision: 0

Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: February 19, 2004 GENERAL INFORMATION 16. General Retail Access: (Cont’d.) D. Eligible Customer Participation: (Cont’d.)

Leaf No. 67 Revision: 1 Superseding Revision: 0

RESERVED FOR FUTURE USE

Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 19, 2004 GENERAL INFORMATION

Leaf No. 68 Revision: 1 Superseding Revision: 0

16.

Customer Advantage Program - General Retail Access: (Cont’d.) D. Eligible Customer Participation: (Cont’d.)

RESERVED FOR FUTURE USE

Issued in compliance with orders in Case 98-M-1343 da ted 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003..

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2006 Effective date postponed to 02/01/06. See Supplement No. 4. GENERAL INFORMATION

Leaf No. 69 Revision: 2 Superseding Revision: 1

16.

Customer Advantage Program - General Retail Access: (Cont’d.) D. Eligible Customer Participation: (Cont’d.) 6. Changes in Supplier: (a) Voluntary Switch Back to NYSEG Service If an Eligible Customer voluntarily chooses to switch back to NYSEG service for Electric Power Supply, such Eligible Customer must notify NYSEG at least fifteen (15) calendar days before the Eligible Customer’s next scheduled meter reading date, interim estimated meter reading date or a requested Special Meter Reading date. (b) Involuntary Switch A process or situation where an Eligible Customer’s ESCO is changed from one provider e.g., ESCO or utility, to another without the Eligible Customer’s authorization. An involuntary switch that is not in accord with the “Discontinuance of Service” provisions set forth in the UBP Addendum, Section 2.F. is referred to as “slamming.” Examples of involuntary switches include, but are not limited to, situations where a customer returns to NYSEG service as a result of an ESCO’s failure to deliver, the ESCO going out of business, or the termination of the ESCO’s participation in NYSEG’s Program.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 19, 2004 GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont’d.) D. Eligible Customer Participation: (Cont’d.) 6. Changes in Supplier: (Cont’d.) RESERVED FOR FUTURE

Leaf No. 70 Revision: 1 Superseding Revision: 0

.
Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2006 Effective date postponed to 02/01/06. See Supplement No. 4.

Leaf No. 71 Revision: 2 Superseding Revision: 1

GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont’d.) D. Eligible Customer Participation: (Cont’d.) 6. Changes in Supplier: (Cont’d.) (c) Special Meter Reading Fees A $20 fee per customer location, per meter, per read attempt, will be charged to the party requesting a Special Meter Reading. A Special Meter Reading is a meter reading performed on a date other than the Eligible Customer's regularly scheduled meter reading date. Requests for Special Meter Reading dates must be made not less than fifteen (15) calendar days in advance of the requested meter reading date. (d) Budget Billing Adjustments NYSEG Budget Billings, as set forth in NYSEG’s tariff, PSC No. 119 Electricity, at Section 4.O, may be adjusted at the switch dates as required to reflect changes in NYSEG’s service and, if adjusted, shall be reflected in the Eligible Customer’s next bill.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 19, 2004 GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont’d.) D. Eligible Customer Participation: (Cont’d.) 7. Metering: (a)

Leaf No. 72 Revision: 1 Superseding Revision: 0

The metering requirements set forth in NYSEG's Tariff, P.S.C. No. 119 - Electricity, General Information Section 3 - Service Connections, apply here. Eligible Customers will continue to use existing meters. . An Eligible Customer that does not take service under an economic incentive provision that requests a meter other than that provided by the Corporation, commensurate with the Eligible Customer's Service Classification, is subject to the additional requirements set forth in the above referenced tariff. Meter upgrades, subject to the availability of equipment, will be installed and operated by NYSEG at the Eligible Customer's expense. NYSEG will continue to own, install, maintain, and read Eligible Customers' meters used for billing purposes, with the exception of large commercial and industrial time-of-use customers who have the option of owning a Commissionapproved meter as set forth in P.S.C. No. 119, with NYSEG retaining sole control of that meter. Eligible large commercial and industrial time-of-use customers, or their designees, shall be allowed to receive meter data on a real-time or other basis, without incurring a fee, provided that such customers install and maintain, at their own expense, the necessary ancillary equipment required to receive such data. Such access may require the installation by NYSEG of a different type of meter/recorder that will allow multiple access, with the cost responsibility of such meter/recorder and installation to be borne by the customer and with NYSEG retaining sole control of the meter and responsibility for the installation and maintenance of the meter and compliance with applicable Commission regulations.

(b)

(c)

Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 19, 2004 GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont’d.) D. Eligible Customer Participation: (Cont’d.) 7. Metering: (c) (Cont’d.)

Leaf No. 73 Revision: 1 Superseding Revision: 0

A schedule of meter upgrade charges shall be provided by NYSEG upon the request of the Eligible Customer or its authorized designee. NYSEG maintains a schedule of meter upgrade charges that covers standard metering options, and such schedule is available upon request. (d) NYSEG will perform meter readings in accordance with established reading cycles and current practices, and provide relevant meter reading information to the ESCO. Information provided to an ESCO may be used solely by the ESCO for the purpose of billing the Eligible Customer.

Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: November 1, 2007 GENERAL INFORMATION 16. General Retail Access: (Cont’d.) D. Eligible Customer Participation: (Cont’d.) 12. Billing (a)

Leaf No. 74 Revision: 4 Superseding Revision: 2

Except as specified in Section J. of this Schedule, Consolidated Billing and Payment Processing, NYSEG will bill an Eligible Customer only for the delivery of Electric Power Supply and other services provided by NYSEG. The ESCO is responsible for billing its Eligible Customer for the Electric Power Supply and other services the ESCO provides to the Eligible Customer. The NYSEG bill will be issued to an Eligible Customer in accordance with established billing cycles and practices applicable to such Eligible Customer. A DC or the ESCO acting as an agent for Eligible Customers, is responsible for: (i) obtaining and scheduling Electric Power Supply with the NYISO, and (ii) complying with the provisions herein relating to Scheduling, Balancing and Settlement as specified in Section 16.E.9 of this Schedule, with respect to its or an Eligible Customer’s Electric Power Supply requirements.

(b)

(c)

13.

Reserved for Future Use

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: November 1, 2007 GENERAL INFORMATION 16. General Retail Access: (Cont’d.) D. Eligible Customer Participation: (Cont’d.) 13. Reserved for Future Use (Cont’d.)

Leaf No. 75 Revision: 4 Superseding Revision: 2

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: November 1, 2007 GENERAL INFORMATION 16. General Retail Access: (Cont’d.) D. Eligible Customer Participation: (Cont’d.) 14. Customer’s Agent: (a)

Leaf No. 76 Revision: 3 Superseding Revision: 1

Participation by an Eligible Customer in the Program shall be deemed an election by such customer for the ESCO selected by the Eligible Customer, to act as such customer's agent and attorney-in-fact for all matters relating to acquisition of Electric Power Supply, power scheduling, and transmission service (including, but not limited to, designation by such customer's ESCO or another ESCO to take responsibility for scheduling, Balancing and Settlement), and Eligible Customers shall be bound by any determinations, decisions, understandings or agreements reached by such ESCO with respect to scheduling, Balancing and Settlement.

15.

Provider of Last Resort ("POLR"): (a) NYSEG will be the POLR for those customers: (i) for whom competition is not a viable option, (ii) who choose not to participate in retail access, (iii) who terminate their agreements with an ESCO and fail to designate a substitute ESCO, (iv) who are acting as a DC, or (v) who are impacted by an ESCO’s discontinuance of service. As a POLR, NYSEG will: i. Accept customers, subject to Commission consumer protection rules, and provide related customer services; Obtain and deliver Electric Power Supply for such customers, consistent with the then-current NYISO Tariffs and retail tariffs; and Provide for any programs, as approved by the Commission to assist low-income customers.

(b)

ii.

iii.

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 19, 2004 GENERAL INFORMATION 16. General Retail Access: (Cont’d.) E. ESCO/DC Participation: 1. Eligibility Criteria:

Leaf No. 77 Revision: 1 Superseding Revision: 0

(a) To be eligible to participate in General Retail Access, an ESCO/DC must meet the requirements specified in the UBP Addendum.

Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 19, 2004 GENERAL INFORMATION 16. General Retail Access: (Cont’d.) E. ESCO/DC Participation: (Cont’d.) 2. ESCO or DC Requirements: (a)

Leaf No. 78 Revision: 1 Superseding Revision: 0

ESCOs and DCs must sign and deliver to NYSEG an Operating Agreement.

Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: January 1, 2010 GENERAL INFORMATION 16. General Retail Access: (Cont’d.) E. ESCO/DC Participation: (Cont’d.) 2. ESCO or DC Requirements: (Cont’d.) (k)

Leaf No. 79 Revision: 1 Superseding Revision: 0

ESCOs and DCs must plan to meet the full Electric Power Supply requirements of the Eligible Customer. Electric Power Supply is defined as the electricity required to meet the Eligible Customer’s needs, including energy, Energy Losses, Unaccounted for Energy, Capacity, Capacity Losses, Capacity Reserves, ancillary services, and NTAC. ESCOs/DCs must provide enough Electric Power Supply to cover Energy Losses, Unaccounted For Energy (“UFE”), and UCAP Losses associated with their load. The Loss and UFE factors are as set forth below. Energy Loss Factor 1.0000 1.0150 1.0377 1.0728 Capacity Loss Factor 1.0000 1.0200 1.0480 1.0738

Voltage Service Classification Level Transmission 7-4 Subtransmission 3S, 7-3 Primary 3P, 7-2 Secondary 1, 2, 6, 7-1, 8, 9, 12, Outdoor/Street Lighting

In the event there is a material change or an anticipated substantial increase in the Electric Power Supply requirement of an Eligible Customer or Eligible Customers, ESCO or DC will notify NYSEG of such change prior to such change or increase according to the details set forth in the Supplier Manual, and will cooperate with NYSEG, as reasonably required by NYSEG, to accommodate such change or increase.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 19, 2004 GENERAL INFORMATION 16. General Retail Access: (Cont’d.) E. ESCO or DC Participation: (Cont’d.) 2. ESCO or DC Requirements: (Cont’d.) (b)

Leaf No. 80 Revision: 1 Superseding Revision: 0

ESCOs must provide Home Energy Fair Practices Act (HEFPA) protections to residential customers, in compliance with the Commission’s Order Relating to Implementation of Chapter 686 of the Laws of 2003 and Pro-Ration of Consolidated Bills, Case Nos. 99-M-0631 and 03-M-0017, issued June 20, 2003, together with the rules and regulations implementing the same, as may be revised, modified, amended, clarified, supplemented or superseded. Further information is available at the New York Public Service Commission’s website (http://www.dps.state.ny.us/hefpa.htm).

Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 19, 2004 GENERAL INFORMATION 16. General Retail Access: (Cont’d.) E. ESCO or DC Participation: See UBP Addendum

Leaf No. 81 Revision: 1 Superseding Revision: 0

Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/1 9/2003.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 19, 2004 GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont’d.) E. ESCO or DC Participation: (Cont’d.) RESERVED FOR FUTURE USE

Leaf No. 82 Revision: 1 Superseding Revision: 0

Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 19, 2004

Leaf No. 83 Revision: 1 Superseding Revision: 0

GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont’d.) E. ESCO or DC Participation: (Cont’d.) RESERVED FOR FUTURE USE

Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 19, 2004 GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont’d.) E. ESCO or DC Participation: (Cont’d.) RESERVED FOR FUTURE USE

Leaf No. 84 Revision: 1 Superseding Revision: 0

Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 19, 2004 GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont’d.) E. ESCO or DC Participation: (Cont’d.) RESERVED FOR FUTURE USE

Leaf No. 85 Revision: 1 Superseding Revision: 0

Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 19, 2004 GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont’d.) E. ESCO or DC Participation: (Cont’d.) RESERVED FOR FUTURE USE

Leaf No. 86 Revision: 1 Superseding Revision: 0

Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 19, 2004

Leaf No. 87 Revision: 1 Superseding Revision: 0

GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont’d.) E. ESCO or DC Participation: (Cont’d.) RESERVED FOR FUTURE USE

Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 19, 2004 GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont’d.) E. ESCO or DC Participation: (Cont’d.) RESERVED FOR FUTURE USE

Leaf No. 88 Revision: 1 Superseding Revision: 0

Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 19, 2004 GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont'd.) E. ESCO or DC Participation: (Cont'd.) RESERVED FOR FUTURE USE

Leaf No. 89 Revision: 1 Superseding Revision: 0

Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 19, 2004 GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont'd.) E. ESCO or DC Participation: (Cont'd.) RESERVED FOR FUTURE USE

Leaf No. 90 Revision: 1 Superseding Revision: 0

Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 19, 2004 GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont'd.) E. ESCO or DC Participation: (Cont'd.) RESERVED FOR FUTURE USE

Leaf No. 91 Revision: 1 Superseding Revision: 0

Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010 GENERAL INFORMATION
16. General Retail Access: (Cont'd.) E. ESCO or DC Participation: (Cont'd.) 8. Billing: (a) Reserved for Future Use

Leaf No. 92 Revision: 2 Superseding Revision: 1

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: January 1, 2010 GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont'd.) E. ESCO or DC Participation: (Cont'd.) 8. Billing: (Cont'd.) (j) Reserved for Future Use

Leaf No. 93 Revision: 1 Superseding Revision: 0

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: January 1, 2010 GENERAL INFORMATION 16. General Retail Access: (Cont'd.) E. ESCO or DC Participation: (Cont'd.) 8. Billing: (Cont'd.) (j) Reserved for Future Use

Leaf No. 94 Revision: 1 Superseding Revision: 0

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: January 1, 2010 GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont'd.) E. ESCO or DC Participation: (Cont'd.) 8. Billing: (Cont'd.) (k)

Leaf No. 95 Revision: 1 Superseding Revision: 0

Once EDIC for Consolidated Billing and Payment Processing is operational, the Company will provide mechanisms that will allow customers to choose, through their ESCO, a Consolidated Billing and Payment Processing option, consistent with Section 16.J of this Schedule.

9.

Scheduling, Balancing and Settlement: (a) The following applies to scheduling, balancing and settlement with the NYISO: i. ii. ESCOs/DCs will schedule Electric Power Supply directly with the NYISO. NYSEG will calculate customer load including NYSEG System Losses and UFE, by hour, and combine accounts by ESCO/DC and by subzone. NYSEG will adjust the sum of all ESCO/DC load so that the hourly usage equals the NYISO-supplied subzone loads. NYSEG will communicate the hourly load calculations to the NYISO, in accordance with the NYISO's Billing Schedule requirements for true-ups. The NYISO will balance those hourly load calculations with the ESCO/DC bulk power deliveries, price the imbalance, and invoice or credit the ESCO/DC for the cost of the imbalance.

iii.

iv.

v.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 19, 2004 GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont'd.) See UBP Addendum

Leaf No. 96 Revision: 1 Superseding Revision: 0

Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003. .

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 19, 2004 GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont'd.) RESERVED FOR FUTURE USE

Leaf No. 97 Revision: 1 Superseding Revision: 0

Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003. .

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 19, 2004 GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont'd.) RESERVED FOR FUTURE USE

Leaf No. 98 Revision: 1 Superseding Revision: 0

Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 19, 2004 GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont'd.) RESERVED FOR FUTURE USE

Leaf No. 99 Revision: 1 Superseding Revision: 0

Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 19, 2004 GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont'd.) RESERVED FOR FUTURE USE

Leaf No. 100 Revision: 1 Superseding Revision: 0

Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 19, 2004 GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont'd.) RESERVED FOR FUTURE USE

Leaf No. 101 Revision: 1 Superseding Revision: 0

Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 19, 2004 GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont'd.) RESERVED FOR FUTURE USE

Leaf No. 102 Revision: 1 Superseding Revision: 0

Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 19, 2004 GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont'd.) RESERVED FOR FUTURE USE

Leaf No. 103 Revision: 1 Superseding Revision: 0

Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 19, 2004 GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont’d.) RESERVED FOR FUTURE USE

Leaf No. 104 Revision: 1 Superseding Revision: 0

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Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 19, 2004 GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont'd.) RESERVED FOR FUTURE USE

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Issued in compliance with orders in Case 98-M-1343 dated 11/21/2003 and Cases 99-M-0631 and 03-M-0117 dated 12/19/2003.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003 GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont'd.) I. Indemnity and Limitation on Liability: 1. Indemnification:

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ESCO and DC, as applicable, agree to indemnify, defend and save harmless NYSEG from and against any and all liabilities, losses, damages, costs, expenses, causes of action, suits, judgments and claims, including, but not limited to, reasonable attorneys fees and the costs of investigation, (collectively "claims"), in connection with any action, suit or proceeding by or on behalf of any person, firm, corporation or other entity arising from, caused by or relating to the (i) curtailment or interruption of services to the ESCO or its Eligible Customers, or a DC, as applicable, due to causes beyond the control of NYSEG (including, without limiting the generality of the foregoing, executive or administrative rules or orders issued from time to time by State or Federal officers, commissions, boards or bodies having jurisdiction) or (ii) interruption, irregularity, failure or defective character of services to the ESCO, its Eligible Customers, or a DC, as applicable, due to causes beyond the control of NYSEG (including, without limiting the generality of the foregoing, executive or administrative rules or orders issued from time to time by State or Federal officers, commissions, boards or bodies having jurisdiction) or (iii) failure by ESCO or DC, as applicable, to perform any of the agreements, terms, covenants or conditions of the Customer Advantage Program to be performed by ESCO or DC, as applicable, or (iv) failure of ESCO to perform any agreement between ESCO and its Eligible Customers. 2. Limitation on Liability: NYSEG will endeavor at all times to provide regular and uninterrupted service to the ESCO, its Eligible Customers, or a DC, as applicable, but in case the service shall be interrupted or irregular or defective or shall fail, from causes beyond the control of NYSEG (including, without limiting the generality of the foregoing, executive or administrative rules or orders issued from time to time by State or Federal officers, commissions, boards, or bodies having jurisdiction) or because of the ordinary negligence of NYSEG or its employees, servants or agents, NYSEG shall not be liable to the ESCO, its Eligible Customers, or a DC, as applicable, therefor. Compliance with directives of the NYISO shall, without limitation by reason of specification, constitute a circumstance beyond the control of NYSEG for which NYSEG shall not be liable; provided, however, that NYSEG shall not be absolved from any liability to which it may otherwise be subject for gross negligence or intentional wrongdoing in the manner in which it carries out the NYISO instructions.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003 GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont'd.) I. Indemnity and Limitation on Liability: (Cont'd.) 2. Limitation on Liability: (Cont'd.)

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Without limiting the generality of the foregoing, NYSEG may, without liability therefor, interrupt, reduce or impair service to any ESCO, its Eligible Customers, or the DC, in the event of an emergency threatening the integrity of NYSEG's system, or any other systems with which it is directly or indirectly interconnected, if in NYSEG's sole judgment or that of the NYISO, such action will prevent, alleviate or reduce the emergency condition, for such period of time as NYSEG or the NYISO deems necessary. NYSEG shall not be liable for any special, incidental, indirect, exemplary, punitive or consequential damages, including, but not limited to, lost profits, purchased power costs, or amounts owed by a DC or an Eligible Customer to its ESCO, suffered by an ESCO, its Eligible Customers, or a DC or to any other persons or entities caused by, arising from or related to the performance of or failure to perform any of the services or obligations of NYSEG under the Program as set forth in NYSEG's tariff or the Supplier Manual, even if NYSEG has been advised of the possibility of such damages.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 108 New York State Electric & Gas Corporation Revision: 5 Initial Effective Date: September 26, 2010 Superseding Revision: 3 Issued in compliance with Order in Case No. 09-E-0715 dated September 21, 2010. GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont'd.) J. Consolidated Billing and Payment Processing 1. Description: A Customer may elect Consolidated Billing and Payment Processing, consistent with the Commission's Order Establishing Uniform Retail Access Billing and Payment Processing Practices, Case 99-M-0631, issued May 18, 2001, as the same may be revised, modified, amended, clarified, supplemented or superseded. Further information is available at the New York Public Service Commission's website (http://www.dps.state.ny.us/ubr.htm) Company specific terms and conditions regarding Consolidated Billing and Payment Processing are detailed in the Billing Services Agreement and Supplier Manual. 2. Customer Eligibility: Once EDIC for Consolidated Billing and Payment Processing is operational, Customers taking service under this Schedule, Service Classification Nos. 1, 2, 3, 5, 6, 7, 8, 9, or 12; or PSC No. 121 Electricity, may elect a Consolidated Billing and Payment Processing option, consistent with the above-referenced PSC Order. 3. Bill Issuance Charge: A Customer electing Consolidated Billing and Payment Processing pursuant to this Section will not be billed the monthly Bill Issuance Charge for the electric service for which Consolidated Billing and Payment Processing has been elected. All other customers receiving electric, gas, or combination service will be billed one Bill Issuance Charge per bill. 4. Bill Processing Charges: ESCOs will be assessed a bill processing charge of $0.73 per bill for a Company rendered consolidated bill for those customers with electric-only or gas-only service. ESCOs will be assessed a bill processing charge of $0.37 for electric service and $0.36 for gas service for a Company rendered consolidated bill for those customers with a combination of electric and gas service. 5. Purchase of ESCO Accounts Receivable Program (POR): (a) ESCOs that elect the Company’s consolidated billing option for all or a portion of their customers will be required to sell their accounts receivable for such customers to NYSEG under the terms of the POR. ESCOs continue to have the right to issue their own bill using dual billing for all or a portion of their customers. Such ESCOs will be precluded from participating in the POR for customers receiving dual billing. (b) The POR obviates the need for NYSEG to prorate partial customer payments among ESCOs that are participating in the POR.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 108.1 New York State Electric and Gas Corporation Revision: 2 Initial Effective Date: September 26, 2010 Superseding Revision: 0 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 GENERAL INFORMATION
16. Customer Advantage Program - General Retail Access: (Cont'd.) J. Consolidated Billing and Payment Processing 6. Account Separation Fee In accordance with Section 9.C.4 of the UBP addendum to this schedule, an ESCO desiring to issue the Consolidated Bill for a customer with a Combination Account may request the Company to establish a separate account for the electric or gas service to be supplied by the ESCO. A fee of $18.00 will be charged to the ESCO requesting establishment of a separate electric or gas account. K. Purchase of ESCO Accounts Receivable Program (POR): In accordance with the Joint Proposal on Purchase of Accounts Receivable (“POR JP”) dated October 28, 2005, in Case 05-M-0453, as approved by the Public Service Commission’s Order Adopting the Terms and Conditions of the Joint Proposal for the Purchase of Accounts Receivable, issued December 27, 2005, and as amended with the Joint Proposal dated July 14, 2010 in Cases 09-E-0715, 09-G-0716, 09-E-0717, and 09-G0718. NYSEG will purchase accounts receivable at a discount and without recourse for commodity sales by ESCOs that provide commodity service in NYSEG’s territory. Eligibility Requirements: ESCOs that elect the Company’s consolidated billing option for all or a portion of their customers will be required to sell their accounts receivable for such customers to NYSEG under the terms of the POR. ESCOs continue to have the right to issue their own bill using dual billing for all or a portion of their customers. Such ESCOs will be precluded from participating in the POR for customers receiving dual billing. Purchase Price: Electric accounts receivable will be purchased at a discount off face value of the ESCO receivable. The discount rate will be sufficient to compensate the Company for its financial risk in purchasing electric receivables, and be comprised of the following components: a) Commodity-related Uncollectible percentage based on total Company uncollectible costs for the most recent available twelve-month period divided by the sum of the total retail, retail access,and purchased ESCO receivables revenue for the same twelve-month period. b) Financial Risk Adder set at 20% of the applicable uncollectible percentage; c) Commodity-related credit and collections and call center percentage. Discount rates will be adjusted each year to reflect RG&E’s most recent twelve-month experience for uncollectible expense. Additionally, the credit and collections and call center allocation included in the discount rate will be reconciled annually, with any under- or over-collections included in the following years discount rate. A POR Discount (DISC) Statement setting forth the electric discount and the gas discount will be filed with the Publice Service Commission sixty days prior to the September 1, effective date of each annual update.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: February 1, 2006 GENERAL INFORMATION 16. Customer Advantage Program - General Retail Access: (Cont'd.)

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K. Purchase of ESCO Accounts Receivable Program (POR): (Cont’d.) Payments: As specified in Appendix B of the POR JP, payments to ESCOs will be made, via ACH (Automated Clearing House), 20 days after acceptance of the EDI 810 transaction. Other Considerations: The POR shall be subject to modifications based upon Commission orders, rules, and regulations applicable to retail access, including, but not limited to, the Uniform Business Practices, proration of customer payments under a single bill, and provisions of Home Energy Fair Practices Act. The POR obviates the need for NYSEG to prorate partial customer payments among ESCOs that are participating in the POR. 17. Business Retention Incentive ("BRI") This provision expired on March 2, 2003. Any customers who were receiving the BRI discount as of that date may transition to the Economic Revitalization Incentive (ERI), as described in General Information Section 7 of this Schedule, for the remainder of their five-year term. The transition, which will be based on the start date of their BRI discount, is set forth in the Special Provision for Economic Incentives of the respective service classifications.

Issued in compliance with order in Case 05-M-0453 dated 12/27/05/

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2005 GENERAL INFORMATION 18. High Load Factor Manufacturer Power ("HLFM")

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Before service will commence under this Special Provision the Corporation and the New York Power Authority ("NYPA") must execute an agreement governing additional terms of HLFM service. Subject to the execution of that agreement by the Corporation with NYPA related to the provision of HLFM service, NYSEG will deliver NYPA HLFM power for customer loads not previously served by NYSEG, at the rates set forth in Special Provision (d) - Economic Incentives, Sub-Section No. 9 - High Load Factor Manufacturer Power within Service Classification No. 7. HLFM service for all other customers who receive HLFM allocations shall be provided pursuant to the General Retail Access provision as set forth in Section 16 in the General Information section of this Schedule. The rates and conditions provided in this provision are subject to review by, acceptance by, or approval of, the Federal Energy Regulatory Commission to the extent of the Federal Energy Regulatory Commission's jurisdiction. The portion of the customer's demand and energy needs met by the delivered HLFM power will be billed in accordance with Special Provision (d)(8), - High Load Factor Manufacturer Power, within Service Classification No. 7. The customer's power requirements in excess of the HLFM power will be billed at the Service Classification No. 7 rates applicable to the customer's voltage level.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2007 GENERAL INFORMATION 19. Incremental Load Incentive (ILI)

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PURPOSE: This service is designed to encourage business customers to locate or expand their facilities in the Company’s service territory. ELIGIBILITY CRITERIA: 1) The Incremental Load Incentive (“ILI”) is available to prospective or existing non-residential and nonpublic authority customers with SIC codes 01-14 (Agriculture, Forestry, Fishing, and Mining), 20-39 (Manufacturing), 50 (Wholesale trade – durable goods), 51 (Wholesale trade – non-durable goods), 60-67 (Finance, Insurance, and Real Estate) or 73 (Business Services) and who qualifies for service under and in accordance with the provisions of Service Classification Nos. 2, 3, or 7. The eligible Prospective Customer or Existing Customer must add new or additional load of at least 25 kilowatts by constructing a new facility, expanding an existing facility, or redeveloping an existing facility that has been vacant for at least six months. 2) A Prospective Customer is defined as an applicant a) whose activities are largely or entirely different in nature from those of the previous customer; or b) whose activities are the same as those of a previous customer but who is a different owner of the business, or c) that will conduct business at a premise where business has not been conducted for at least six months prior to the application for ILI benefits; or d) that has obtained a business in a bankruptcy liquidation sale from the previous customer. 3) Existing Customer - Any current customer that a) satisfies the usage thresholds for additional qualifying equipment set forth below and b) does not satisfy the definition of a Prospective Customer above, will be deemed an eligible Existing Customer, entitled to receive an ILI incentive on increased usage in the qualified block(s) above a historic monthly base load of usage established before the addition of qualifying equipment. 4) Customers transitioning from the Incubator Development Incentive that continue to meet the requirements set forth in General Information Section 13 will be eligible to receive ILI benefits. TERM: ILI will be applied for a period of five years, to the qualified customer without extension. Effective January 1, 2011, the ILI program will terminate. Such termination will not affect a customer who initiates ILI service by December 31, 2010; such qualified customer will continue ILI service until the completion of its five-year term.

Issued in compliance with order in Case No. 05-E-1222 dated 08/23/06.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010 GENERAL INFORMATION 19. Incremental Load Incentive (ILI) ELECTRIC SUPPLY PRICING OPTIONS

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Customers qualifying for an ILI may select one of the following rate options, as specified in General Information Section 25, Supply Service Options: (1) ESCO Supply Service (ESS), (2) NYSEG Supply Service (NSS), or (3) Hourly Pricing. The qualified ILI customer must choose the same rate option for its incentive load, non-incentive load, and any future ILI load at the facility. If the customer has not elected a rate option by the time of billing, NYSEG will bill customers on the NSS or Hourly Pricing rate as appropriate. A customer electing the ESS must adhere to the process set forth in Section 25.I.I., Changing Supply Service Options. The Energy Services Company (“ESCO”) will contact NYSEG directly to convey the customer’s ESS rate option selection and Retail Access enrollment. BILLING The Company will calculate bills for service supplied under the ILI in accordance with the applicable Special Provision under Service Classification Nos. 2, 3, and 7. A qualified customer will have its monthly service bill reduced by the amount stated in the applicable Special Provision for Economic Incentives, in excess of a base amount established for each monthly billing period. For an existing customer, the base amount will be based on a one-year historical period, actual or estimated, as determined by the Corporation prior to qualification for the incentive. For a prospective customer, the base amount will be zero. Customers transitioning from the Incubator Development Incentive will be phased in as set forth in the applicable Special Provision under the above listed Service Classifications.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003 GENERAL INFORMATION 20. Emergency Demand Response Program ("EDRP") PURPOSE:

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In response to the Commission Orders of December 20, 2000, and April 18, 2001, in Case No. 00-E-2054 as the same may be revised, modified, amened, clarified, supplemented or superseded, the Company seeks to provide customers with an economic incentive to respond to Emergency Operating Conditions as identified by the New York Independent System Operator ("NYISO"). EDRP can provide the NYISO, through the Company, with the ability to request voluntary load curtailment or replacement by participating customers for electric usage. APPLICABLE TO THE USE OF SERVICE FOR: Commercial, Industrial and Public Authority customers. Applicability is limited to customers who agree voluntarily, and have the capability to, curtail and/or replace at a single meter at least 100 kW per hour of electric usage. Customers may be simultaneously eligible for more than one load curtailment program. TERM: The customer shall complete NYSEG's "C.A.$.H.BACK Program Customer Registration Form" and execute a one-year "Participation Agreement." The Company will process any application within no more than seven calendar days, subject to any processing time required by the NYISO, and will notify customers as to when their load may first be offered to the NYISO. Any customer under contract to participate in this Emergency Demand response Program may not participate in EDRP through another Curtailment Service Provider ("CSP") including as a Direct Customer or end use customer of the NYISO. CUSTOMER BASELINE LOAD ("CBL") The CBL will provide a reference to verify customer compliance with a scheduled curtailment. The CBL is determined in accordance with the NYISO EDRP Manual, Calculation of Customer Baseline. Load curtailments will be measured based on this CBL methodology. ADDITIONAL METERING: The customer shall have installed the necessary equipment, including interval metering at each participating meter location. Such metering will be installed, controlled, operated and maintained by the Company at the customer's expense. Regardless of which CSP the customer may choose, the Company may require installation of additional communication equipment, software and a monthly subscription service needed for the determination of CBL and for the administration of this and any other curtailment program. A customer that participates in the EDRP will be responsible for only those metering costs not covered by discounts provided by NYSERDA, or any other non-NYSEG source. Qualified participating customers receiving metering from competitive metering providers may participate in the EDRP using metering equipment and communications capabilities that the Company has determined can provide the necessary hourly interval usage data.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003 GENERAL INFORMATION 20. Emergency Demand Response Program ("EDRP"): (Cont'd.) ADDITIONAL METERING: (Cont'd.)

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Qualified/eligible on-site generators used to replace load may require additional metering as determined by the NYISO to confirm curtailment and to demonstrate that emergency generating equipment was in effect for the entire EDRP event. ADDITIONAL NYISO REQUIREMENTS: In addition to these program requirements, the customer shall meet any additional requirements as specified in the NYISO Emergency Demand Response Program Manual. BILL CREDIT: 1. The customer will be subject to all rates and charges and other terms/conditions of the customer's otherwise applicable service classification. The customer will receive a bill credit for verified load curtailment or replacement under this program during any NYISO requested EDRP curtailment event equal to at least 90% of the NYISO payment to the Company, in accordance with the NYISO EDRP Manual, for the customer's participation in each NYISO curtailment event.

2.

EDRP EVENT: All EDRP curtailment events will be determined solely by the NYISO and communicated to the customer through the Company. The Company will provide as much advance notice as possible subject to a minimum of 2 hours notice provided to the Company by the NYISO. The NYISO may implement the EDRP in accordance with the NYISO EDRP Manual for the following conditions: (a) (b) (c) (d) As part of the In-day Peak Hour Forecast response to an "Operating Reserve Peak Forecast Shortage;" in conjunction with Special Case Resources; to support the New York power system during emergency periods; or at the NYISO's discretion to relieve system or zonal emergencies.

There are no penalties for non-compliance associated with this EDRP. OTHER TERMS AND CONDITIONS: Applicable payment to a customer simultaneously participating in both the EDRP and any other curtailment program(s) will be the highest payment under any of those programs, except where explicitly prohibited elsewhere in the tariff or contract.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003 GENERAL INFORMATION 21. C.A.$.H.BACK Program: PURPOSE:

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In response to the Commission Order of March 20, 2001, in Case 00-E-2054, and the New York Independent System Operator's (NYISO) Day-Ahead Demand Response Program Manual, both of which may be revised, modified, amended, clarified, supplemented or superseded, the Company will provide a voluntary program, for load normally supplied and delivered by NYSEG, for eligible customers to curtail load. NYSEG's program, entitled C.A.$.H.BACK, implements the NYISO's day-ahead economic load-curtailment program. Under this program, a customer agrees to curtail load when their bid is submitted and accepted by the NYISO. The Company, at its discretion, will aggregate customer load reduction bids in whole 1 MW blocks, and submit them to the NYISO for consideration in the Day-Ahead market. The NYISO will determine if the submitted bids will reduce the total bid production costs and inform NYSEG of accepted bids. NYSEG will inform each customer if their bid is accepted and the applicable time period(s). APPLICABLE TO THE USE OF SERVICE FOR: For load normally supplied and delivered by NYSEG, this service applies to Commercial, Industrial and Public Authority customers taking service under S.C. 2, 3, 7, 13, or 14. This service is limited to customers who voluntarily agree to curtail and/or displace load at a single NYSEG service meter, amounting to at least 100 kW per hour of electric usage. TERM: The customer shall complete NYSEG's "C.A.$.H.BACK Program Customer Registration Form" and execute a "Participation Agreement." Any customer under contract to participate in this Day-Ahead Demand Response Program may not participate through another Demand Reduction Provider, including as a directcustomer or end-user of the NYISO. CUSTOMER BASELINE LOAD ("CBL"): The CBL will provide a reference to verify customer compliance with a scheduled curtailment. The CBL is determined in accordance with the NYISO Day-Ahead Demand Response Program Manual, Calculating Customer Baseline Load for DADRP. Load curtailments will be measured based on this CBL methodology. BIDS: A participating customer shall provide the Company with hourly demand reduction bids for a specific curtailment (minimum of 100 kW per hour of electric usage) and a bid price above which the load would not be consumed. Each bid of kW and price(s) must be received by the Company in accordance with the Participation Agreement and in time for NYSEG to meet NYISO Day-Ahead Economic Load Curtailment Program requirements.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003 GENERAL INFORMATION 21. C.A.$.H.BACK Program: (Cont'd.) ADDITIONAL METERING:

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The customer shall have installed the necessary equipment, including interval metering at each participating meter location. A participating customer with a generator also will require a separate interval meter to verify curtailment is not supplied by that generator. Such metering will be installed, controlled, operated and maintained by the Company at the customer's expense. Participating customers will be responsible for only those metering costs not covered by discounts provided by NYSERDA, or any other non-NYSEG source. Regardless of which Demand Reduction Provider the customer may choose, the Company may require installation of additional communication equipment, and an internet based software subscription service necessary for the determination of CBL and for the administration of this and any other curtailment program (e.g., Emergency Demand Response Program). This subscription service will also provide the customer with the ability to review and monitor their energy consumption patterns on a daily basis. The customer is responsible for making adequate arrangements with their telecommunications provider for communication equipment. NYSEG's monthly charge for the software subscription service is $40 per month. Customers receiving metering from competitive metering providers may participate in this program using metering equipment and communications capabilities that the Company has determined can provide the necessary hourly interval usage data. DETERMINING AMOUNT OF LOAD REDUCTION: The amount of actual Real-Time curtailment will be equal to the CBL less the actual Real-Time consumption during the specified curtailment period, as verified by the NYISO. PAYMENT SHARING & PENALTIES: The customer will receive a bill credit for an accepted bid under this program equal to at least 90% of the NYISO Demand Reduction payment for the customer's accepted and scheduled curtailment. More specifically, NYSEG will pay the customer 90% of the demand reduction payment which is based on scheduled curtailment, and then charge the customer for any imbalance charge/penalty. The NYISO DayAhead Demand Reduction Program Manual specifies a non-performance penalty of 110%. Any charges or penalties assessed by the NYISO to NYSEG for a customer's failure to curtail load will be fully passed through to the customer. OTHER TERMS AND CONDITIONS: This program will be periodically evaluated for potential modifications and improvements. Modifications will be filed and approved by the PSC prior to the next capability period. Customers taking service under NYSEG's interruptible special provision are only eligible for payments for verified curtailment of their contracted non-interruptible load.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 28, 2010 GENERAL INFORMATION 22. Farm Waste Electric Generating System Option

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Applicable to any customer who owns or operates farm waste electric generating equipment ("Facility"), that generates electric energy from biogas produced by the anaerobic digestion of agricultural wastes with a rated capacity of not more than one thousand kilowatts (1000 kW), located and used at his or her "farm operation" as defined in Subdivision 11 of Section 301 of the Agriculture and Markets Law. Such definition states that a "farm operation" means the land and on-farm buildings, equipment, manure processing and handling facilities, and practices which contribute to the production, preparation and marketing of crops, livestock and livestock products as a commercial enterprise, including a "commercial horse boarding operation" as defined in subdivision thirteen of this Section 301 of the Agriculture and Markets Law. The Facility must be manufactured, installed and operated in accordance with applicable government and industry standards. Such Facility must be connected to NYSEG's electric system and operated in parallel with NYSEG's transmission and distribution facilities. The Facility must be fueled, at a minimum of 90% on an annual basis, by biogas produced from the anaerobic digestion of agricultural waste such as livestock manure materials, crop residues and food processing waste. The Facility must be fueled by biogas generated by anaerobic digestion with at least 50% by weight of its feedstock being livestock manure materials on an annual basis. The customer, at its expense, shall promptly provide to NYSEG all relevant, accurate and complete information, documents, and data, as may be reasonably requested by NYSEG, to enable NYSEG to determine whether the customer is in compliance with these requirements. The Farm Waste Electric Generating System Option will be available to eligible customers, on a first come, first served basis, until the total rated generating capacity for solar, farm waste, MCHP and fuel cell electric generating equipment owned, leased or operated by customer-generators in NYSEG's service area is equivalent to 28,260 kW (one percent of NYSEG's electric demand for the year 2005). Customers electing service under this Section 22 must operate in compliance with standards and requirements set forth in the Distributed Generation Interconnection Requirements found in PSC 119 - Electricity, Section 9 and Addendum-SIR to PSC 119. In addition, customers must execute the NYS Standardized Contract For Interconnection of New Distributed Generation Units With Capacity of 2 MW or Less Connected in Parallel with Utility Distribution Systems ("SIR Contract"), as contained within Addendum-SIR of PSC 119 - Electricity. For a net metered customer, the Corporation will install metering appropriate for the customer’s service classification that enables the Corporation to measure the electricity delivered to the customer and measure the electricity supplied by the customer to the Corporation. Where the Corporation determines that a second meter should be installed, no additional costs shall be billed to the customer. When a second meter is requested by the customer that is not required by the Corporation, the customer will be responsible for the cost of the meter, the installation and any additional costs. For each billing period during the term of the SIR Contract, the Corporation will net the electricity (kWh) delivered to the customer with the electricity (kWh) supplied by the customer to the Corporation. If the electricity (kWh) supplied by the Corporation exceeds the electricity supplied by the customer to the Corporation during the billing period, the customer shall be billed for the net kWh supplied by the Corporation to the customer at the standard service class rates. For customers billed on time-differentiated rates (TOU meter), e.g., On-Peak/Off-Peak or Day/Night, netting will occur in each time period.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: April 1, 2009 GENERAL INFORMATION 22. Farm Waste Electric Generating System Option (Cont'd.) b)

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c)

If the electricity (kWh) supplied by the customer to the Corporation during the billing period exceeds the electricity (kWh) supplied by the Corporation to the customer, a kWh credit will be carried forward for the next billing period. For customers billed on time-differentiated rates (TOU meter), e.g., On-Peak/Off-Peak or Day/Night, the kWh credit will be carried forward as a credit to the appropriate time period. For a demand-billed farm waste customer, prior to carrying forward any kWh credit, the kWhs will be converted to a dollar value using the applicable tariff per kWh rate and applied as a credit to the current utility bill. If the dollar value of the kWh exceeds the current utility bill, any remaining dollars will be converted back to kWhs and carried forward for the next billing period as a kWh credit.

For customers billed on TOU rates, if the electricity (KWh) supplied by the customer to the Corporation is not metered for each TOU period and until such time as metering is installed to measure electricity supplied to the Corporation in each TOU period, an allocation of the electricity supplied to the Corporation will be done according to the allocation factors as set forth in a Special Provision provided in each service classification in this Schedule. If, (a) on an annual basis, during the term of the SIR Contract or (b) on the date the SIR Contract is terminated pursuant to the terms and conditions of said Contract, there exists a positive (kWh) balance for an accumulation of excess generation provided to the Corporation, then a cash payment will be issued to the customer. The payment shall be for an amount equal to the product of the excess balance times the average avoided cost for energy over the most recent 12-month period. Upon the Corporation’s determination that the customer has taken service under this Section 22 while in violation of the conditions of service set forth in General Information Section 22 of this Schedule, the customer shall forfeit any positive balance accrued during the annual period in which the violation occurred. In the event that NYSEG determines that it is necessary to install a dedicated transformer or transformers or other equipment to protect the safety and adequacy of electric service provided to other customers, the customer shall pay NYSEG's actual costs of purchasing and installing such transformer(s) or other equipment located and used at customer's "farm operation," in an amount not to exceed five thousand dollars ($5,000) per "farm operation."

Issued in compliance with order in Case No. 08-E-1310 dated 02/13/09.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: July 1, 2009

Leaf No. 117.1 Revision: 2 Superseding Revision: 1

GENERAL INFORMATION 23. Wind Electric Service Options A. Wind Residential Electric Service Option

Applicable to any Residential Customer (as defined by HEFPA) who operates wind generating equipment located and used at his or her primary, legal residence. Wind generating equipment is defined as a wind system, with a rated capacity of not more than 25 kilowatts that is manufactured, installed and operated in accordance with applicable government and industry standards. Such system must be connected to the customer's electric system and operated in parallel with NYSEG's transmission and distribution facilities. Application of the Wind Residential Service Option will be available to eligible customers, on a first come, first served basis, until the total rated generating capacity for all wind electric generating equipment owned or operated by customer-generators in NYSEG's service area is equivalent to 8,478 kW (three-tenths percent of NYSEG's electric demand for the year 2005) and is available only in non-network areas of the Corporation's territory. Customers electing service under this provision must execute a New York State Standardized Contract for Interconnection of New Distributed Generation Units with Capacity of 2 MW or Less Connected in Parallel with Utility Distribution Systems (“SIR Contract”). In addition, customers must operate in compliance with standards and requirements set forth in the New York State Standard Interconnection Requirements and Application Process for New Distributed Generators 2 MW or Less Connected in Parallel with Utility Distribution Systems, as set forth within Addendum-SIR of Schedule PSC 119. For a net metered customer, the Corporation will install metering appropriate for the customer’s service classification that enables the Corporation to measure the electricity delivered to the customer and measure the electricity supplied by the customer to the Corporation. Where the Corporation determines that a second meter should be installed, no additional costs shall be billed to the customer. When a second meter is requested by the customer that is not required by the Corporation, the customer will be responsible for the cost of the meter, the installation and any additional costs. For each billing period during the term of the SIR Contract, the Corporation will net the electricity (kWh) delivered to the customers with the electricity (kWh) supplied by the customer to the Corporation. If the electricity (kWh) supplied by the Corporation exceeds the electricity supplied by the customer to the Corporation during the billing period the customer shall be billed for the net kWh supplied by the Corporation to the customer at the standard service class rates. For customers billed on timedifferentiated rates (TOU meter), e.g., On-Peak/Off-Peak or Day/Night, netting will occur in each time period. b) If the electricity (kWh) supplied by the customer to the Corporation during the billing period exceeds the electricity (kWh) supplied by the Corporation to the customer, a kWh credit will be carried forward for the next billing period. For customers billed on time-differentiated rates (TOU meter), e.g., OnPeak/Off-Peak or Day/Night, the kWh credit will be carried forward as a credit to the appropriate time period. For customers billed on TOU rates, if the electricity (kWh) supplied by the customer to the Corporation is not metered for each TOU period and until such time as metering is installed to measure electricity supplied to the Corporation in each TOU period, an allocation of the electricity supplied to the Corporation will be done according to allocation factors as set forth in a Special Provision provided in each service classification in this Schedule. a)

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: July 23, 2010 GENERAL INFORMATION 23. Wind Electric Service Options (Cont’d.) A. Wind Residential Electric Service Option (Cont’d.)

Leaf No. 117.2 Revision: 3 Superseding Revision: 2

At the end of a year, or annualized over the period that service is supplied under this provision, the value of any credit remaining on a customer’s account for excess electricity produced by the customer-generator shall be paid to the customer at the Corporation’s avoided cost for energy. A cash payment will be issued to the customer. Upon the Corporation’s determination that the customer has taken service under this Section while in violation of the conditions of service set forth herein, the customer shall forfeit any positive balance accrued during the annual period in which the violation occurred. Pursuant to the Standard Interconnection Requirements set forth within Addendum-SIR of P.S.C. No. 119, customers are responsible for providing all meter boxes and sockets. In the event that NYSEG determines that it is necessary to install a dedicated transformer or transformers, or other equipment to protect the safety and adequacy of electric service provided to other customers, the customer-generator shall pay for the cost of installing the transformer or transformers, or other equipment up to a maximum amount of $750.00. The Corporation will not charge any additional wind electric specific interconnection costs incurred by NYSEG other than $750.00 for dedicated transformers or other equipment, if necessary. Customers are responsible for any costs related to the installation of their wind generating equipment. Notwithstanding the provisions herein, residential wind electric customers are responsible for meeting all otherwise applicable provisions and requirements of P.S.C. Nos. 119 and 120. B. Wind Non-Residential Electric Service Option Applicable to any Non-Residential Customer who operates wind generating equipment located and used at its premises. Wind generating equipment is defined as a wind system that is manufactured, installed and operated in accordance with applicable government and industry standards with a rated capacity of not more than two thousand kilowatts. Such system must be connected to the customer's electric system and operated in parallel with NYSEG's transmission and distribution facilities. Application of the Wind Non-Residential Electric Service Option be available to eligible customers, on a first come, first served basis, until the total rated generating capacity for all wind electric generating equipment owned or operated by customer-generators in NYSEG's service area is equivalent to 8,478 kW (three-tenths percent of NYSEG's electric demand for the year 2005) and is available only in non-network areas of the Corporation's territory. Customers electing service under this provision must execute a New York State Standardized Contract for Interconnection of New Distributed Generation Units with Capacity of 2 MW or Less Connected in Parallel with Utility Distribution Systems (“SIR Contract”). In addition, customers must operate in compliance with standards and requirements set forth in the New York State Standard Interconnection Requirements and Application Process for New Distributed Generators 2 MW or Less Connected in Parallel with Utility Distribution Systems, as set forth within Addendum-SIR of Schedule PSC 119.
Issued in compliance with order in Case No. 10-E-0135 dated 3/31/10.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: July 23, 2010

Leaf No. 117.2.1 Revision: 2 Superseding Revision: 1

GENERAL INFORMATION 23. Wind Electric Service Options (Cont’d.) B. Wind Non-Residential Electric Service Option (Cont’d.) For a net metered customer, the Corporation will install metering appropriate for the customer’s service classification that enables the Corporation to measure the electricity delivered to the customer and measure the electricity supplied by the customer to the Corporation. For non-residential customers with generators less than 25 kW where the Corporation determines that a second meter should be installed, no additional costs shall be billed to the customer. For non-residential customers with generators equal to or greater than 25 kW, the customer will be responsible for one-half of any interconnection costs, including the cost of a second meter where the Corporation determines a second meter is necessary and installation costs. When a second meter is requested by the customer that is not required by the Corporation, the customer will be responsible for the cost of the meter, the installation and any additional costs. For each billing period during the term of the SIR Contract, the Corporation will net the electricity (kWh) delivered to the customers with the electricity (kWh) supplied by the customer to the Corporation. a) If the electricity (kWh) supplied by the Corporation exceeds the electricity supplied by the customer to the Corporation during the billing period the customer shall be billed for the net kWh supplied by the Corporation to the customer at the standard service class rates. For customers billed on time-differentiated rates (TOU meter), e.g., On-Peak/Off-Peak or Day/Night, netting will occur in each time period. If the electricity (kWh) supplied by the customer to the Corporation during the billing period exceeds the electricity (kWh) supplied by the Corporation to the customer, a kWh credit will be carried forward for the next billing period. For customers billed on time-differentiated rates (TOU meter), e.g., On-Peak/Off-Peak or Day/Night, the kWh credit will be carried forward as a credit to the appropriate time period. For demand-billed customers, prior to carrying forward any kWh credit, the kWhs will be converted to a dollar value using the applicable tariff per kWh rate and applied as a credit to the current utility bill. If the dollar value of the kWh exceeds the current utility bill, any remaining dollars will be converted back to kWhs and carried forward for the next billing period as a kWh credit.

b)

c)

For customers billed on TOU rates, if the electricity (kWh) supplied by the customer to the Corporation is not metered for each TOU period and until such time as metering is installed to measure electricity supplied to the Corporation in each TOU period, an allocation of the electricity supplied to the Corporation will be done according to allocation factors as set forth in a Special Provision provided in each service classification in this Schedule. Upon the Corporation’s determination that the customer has taken service under this Section while in violation of the conditions of service set forth herein, the customer shall forfeit any positive balance accrued during the annual period in which the violation occurred. Pursuant to the Standard Interconnection Requirements set forth within Addendum-SIR of P.S.C. No. 119, customers are responsible for providing all meter boxes and sockets. In the event that NYSEG determines that it is necessary to install a dedicated transformer or transformers, or other equipment to protect the safety and adequacy of electric service provided to other customers, a customer-generator with a combined rating less than 25 kW shall pay for the cost of installing such transformer(s) or other equipment, up to a maximum amount of $750. A customer-generator with a combined rating equal to or greater than 25 kW shall pay for the cost of installing the transformer(s) or other equipment. Notwithstanding the provisions herein, non-residential wind electric customers are responsible for meeting all otherwise applicable provisions and requirements of P.S.C. Nos. 119 and 120.
Issued in compliance with order in Case No. 10-E-0135 dated 3/31/10.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: July 1, 2009 GENERAL INFORMATION 23. Wind Electric Service Options (Cont’d.) C. Farm Wind Electric Generating System Option

Leaf No. 117.2.2 Revision: 1 Superseding Revision: 0

Applicable to any customer who owns or operates farm wind electric generating equipment ("Facility"), that generates electric energy with a rated capacity of not more than five hundred kilowatts (500 kW); where the customer’s primary residence is located on the same land used for his or her "farm operation" as defined in Subdivision 11 of Section 301 of the Agriculture and Markets Law. Such definition states that a "farm operation" means the land and on-farm buildings, equipment, manure processing and handling facilities, and practices which contribute to the production, preparation and marketing of crops, livestock and livestock products as a commercial enterprise, including a "commercial horse boarding operation" as defined in subdivision thirteen of this Section 301 of the Agriculture and Markets Law. The Facility must be manufactured, installed and operated in accordance with applicable government and industry standards. Such Facility must be connected to NYSEG's electric system and operated in parallel with NYSEG's transmission and distribution facilities. The Farm Wind Electric Generating System Option will be available to eligible customers, on a first come, first served basis, until the total rated generating capacity for all wind electric generating equipment owned or operated by customer-generators in NYSEG's service area is equivalent to 8,478 kW (three-tenths percent of NYSEG's electric demand for the year 2005). Customers electing service under this Section 23 must operate in compliance with standards and requirements set forth in the Distributed Generation Interconnection Requirements found in PSC 119 - Electricity, Section 9 and Addendum-SIR to PSC 119. In addition, customers must execute the NYS Standardized Contract For Interconnection of New Distributed Generation Units With Capacity of 2 MW or Less Connected in Parallel with Utility Distribution Systems ("SIR Contract"), as contained within Addendum-SIR of PSC 119 - Electricity. For a net metered customer, the Corporation will install metering appropriate for the customer’s service classification that enables the Corporation to measure the electricity delivered to the customer and measure the electricity supplied by the customer to the Corporation. Where the Corporation determines that a second meter should be installed, no additional costs shall be billed to the customer. When a second meter is requested by the customer that is not required by the Corporation, the customer will be responsible for the cost of the meter, the installation and any additional costs. For each billing period during the term of the SIR Contract, the Corporation will net the electricity (kWh) delivered to the customer with the electricity (kWh) supplied by the customer to the Corporation. a) If the electricity (kWh) supplied by the Corporation exceeds the electricity supplied by the customer to the Corporation during the billing period, the customer shall be billed for the net kWh supplied by the Corporation to the customer at the standard service class rates. For customers billed on time-differentiated rates (TOU meter), e.g., On-Peak/Off-Peak or Day/Night, netting will occur in each time period.

Issued in compliance with order in Case No. 09-E-0296 dated 6/22/09.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: July 23, 2010 GENERAL INFORMATION 23. Wind Electric Service Options (Cont’d.) C. Farm Wind Electric Generating System Option (Cont'd.)

Leaf No. 117.2.3 Revision: 1 Superseding Revision: 0

b) If the electricity (kWh) supplied by the customer to the Corporation during the billing period exceeds the electricity (kWh) supplied by the Corporation to the customer, a kWh credit will be carried forward for the next billing period. For customers billed on time-differentiated rates (TOU meter), e.g., On-Peak/Off-Peak or Day/Night, the kWh credit will be carried forward as a credit to the appropriate time period. c) For a demand-billed farm wind customer, prior to carrying forward any kWh credit, the kWhs will be converted to a dollar value using the applicable tariff per kWh rate and applied as a credit to the current utility bill. If the dollar value of the kWh exceeds the current utility bill, any remaining dollars will be converted back to kWhs and carried forward for the next billing period as a kWh credit. For customers billed on TOU rates, if the electricity (KWh) supplied by the customer to the Corporation is not metered for each TOU period and until such time as metering is installed to measure electricity supplied to the Corporation in each TOU period, an allocation of the electricity supplied to the Corporation will be done according to the allocation factors as set forth in a Special Provision provided in each service classification in this Schedule. If, (a) on an annual basis, during the term of the SIR Contract or (b) on the date the SIR Contract is terminated pursuant to the terms and conditions of said Contract, there exists a positive (kWh) balance for an accumulation of excess generation provided to the Corporation, then a cash payment will be issued to the customer. The payment shall be for an amount equal to the product of the excess balance times the average avoided cost for energy over the most recent 12-month period. Upon the Corporation’s determination that the customer has taken service under this Section while in violation of the conditions of service set forth herein, the customer shall forfeit any positive balance accrued during the annual period in which the violation occurred. In the event that NYSEG determines that it is necessary to install a dedicated transformer or transformers or other equipment to protect the safety and adequacy of electric service provided to other customers, a customer with a Facility with a rated capacity not more than 25 kW shall pay NYSEG’s actual costs of purchasing and installing such transformer(s) or other equipment in an amount not to exceed $750. A customer with a Facility with a rated capacity equal to or greater than 25 kW (up to 500 kW) shall pay NYSEG's actual costs of purchasing and installing such transformer(s) or other equipment located and used at customer's "farm operation," in an amount not to exceed five thousand dollars ($5,000) per "farm operation."

Issued in compliance with order in Case No. 10-E-0135 dated 3/31/10.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 26, 2010 GENERAL INFORMATION 24. Electric Hybrid Generating System Option

Leaf No. 117.3 Revision: 5 Superseding Revision: 4

Applicable to any customer who owns or operates two types of electric generating equipment as defined in General Information Sections 22, 23, 26, or 27 of this Schedule (“Hybrid Facility”) at the same location. The Hybrid Facility Option is intended to allow hybrid facilities the benefit of net metering for qualified generation. Customers electing service under this Section must operate in compliance with standards and requirements set forth in the Distributed Generation Interconnection Requirements found in PSC 119 - Electricity, Section 9 and Addendum-SIR to PSC 119. In addition, customers must execute the NYS Standardized Contract For Interconnection of New Distributed Generation Units With Capacity of 2 MW or Less Connected in Parallel with Utility Distribution Systems ("SIR Contract"), as contained within Addendum-SIR of PSC 119 - Electricity. Metering The Corporation will install metering appropriate for the customer’s service classification that enables the Corporation to measure the electricity delivered to the customer and measure the qualified electricity supplied by the customer to the Corporation. Billing, netting or compensation for generation will be consistent for the qualified generation as defined in General Information Sections 22, 23, 26, or 27. Where the Corporation determines additional meters should be installed, no additional meter costs shall be billed to the customer. When a second meter is requested by the customer that is not required by the Corporation, the customer will be responsible for all additional costs.

Issued in compliance with order in Case 09-E-0829 dated 02/12/10.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: July 1 2009 GENERAL INFORMATION

Leaf No. 117.4 Revision: 3 Superseding Revision: 2

Reserved for future use.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: July 1, 2009 GENERAL INFORMATION

Leaf No. 117.5 Revision: 2 Superseding Revision: 1

Reserved for future use.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010 GENERAL INFORMATION 25. Supply Service Options I. Supply Service Options A. Supply Service Options

Leaf No. 117.6 Revision: 4 Superseding Revision: 3

NYSEG will offer a Retail Access choice and a Non-Retail Access choice, as described below. These Supply Service Options are available to all customers, except as noted herein and in Section 25.I.F. 1. ESCO Supply Service (ESS): This Retail Access choice includes fixed charges for NYSEG delivery service and a Transition Charge (Non-Bypassable Charge [NBC] described in Section 25.I.B.). An ESCO provides Electric Power Supply to the customer. NYSEG Supply Service (NSS): This Non-Retail Access Choice includes fixed components for NYSEG delivery service, a Transition Charge (Non-Bypassable Charge [NBC] as described in Section 25.I.B.), a fluctuating commodity charge for electricity supplied by NYSEG, and a Merchant Function Charge (MFC) as described in Section 25.I.D. The commodity charge for customers billed at a non-demand metered rate, which includes residential Service Classification Nos. 1, 8 and 12, non-residential Service Classification Nos. 5, 6 and 9, and non-demand billed SC11 customers within PSC No. 120, and PSC No. 121 Street Lighting customers, will reflect a managed mix of supply resources. The commodity charge for customers billed at a demand metered rate, which includes non-residential Service Classification Nos. 2, 3, and 7 who are not mandatorily participating in Hourly Pricing, and demand billed SC11 customers within PSC No. 120, will reflect the market price of electricity.

2.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010 GENERAL INFORMATION 25. Supply Service Options: (cont’d.) I. Supply Service Options (cont’d.) A. Supply Service Options: (cont’d.)

Leaf No. 117.7 Revision: 4 Superseding Revision: 3

3. Hourly Pricing: This choice is for customers billed at a demand metered rate, which includes nonresidential Service Classification Nos. 2, 3, and 7, and demand billed Service Classification No. 11 customers within PSC No. 120. Customers may take service with an ESCO or with NYSEG under this choice. For customers taking service with an ESCO, such customers will be responsible for fixed charges for NYSEG delivery service, a Transition Charge (Non-Bypassable Charge [NBC] as described in 25.I.B.), and an incremental meter charge as further described in the applicable Service Classification. For customers taking service with NYSEG, such customers will be responsible for fixed charges for NYSEG delivery service, a Transition Charge (Non-Bypassable Charge [NBC] as described in 25.I.B.), a commodity charge for electricity supply that fluctuates hourly with the market price (including losses, unaccounted for energy, capacity and capacity reserve), a Merchant Function Charge (MFC) as described in Section 25.I.D., and an incremental meter charge, as further described in the applicable Service Classification. .

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 117.8 New York State Electric & Gas Corporation Revision: 7 Initial Effective Date: September 26, 2010 Superseding Revision: 6 Issued in compliance with Order in Case 09-E-0715, dated September 21, 2010 GENERAL INFORMATION 25. Supply Service Options: (cont’d.) I. Supply Service Options (cont’d.) B. Transition Charge (Non-Bypassable Charge [NBC]) 1. Calculation of the Transition Charge (Non-Bypassable Charge [NBC]) This charge will sum together the market value of NYSEG’s owned hydro plant output at the generation source; the net market value of the purchased power contracts of the NUG, NYPA and NMP2 resources (market value of the purchased power contract costs determined at the generation source less the contract costs); all actual transmission wheeling expenses; certain actual wholesale transmission-related revenues (A $55 million estimate of transmission revenues was included in the delivery revenue requirements calculated in Case No. 09-E-0715. Any difference between the actual amount of transmission revenues and the $55 million embedded in base delivery rates, calculated on a historical monthly average basis, will be captured in the NBC. ). The Company will credit the NBC with the following amounts from the Positive Benefit Account, shaped based on the historical monthly average, in each of the Rate Years: Rate Year 1 (09/26/2010 through 08/31/2011): $30 million; Rate Year 2 (09/01/2011 through 08/31/2012): $15 million; Rate Year 3 (09/01/2012 through 08/31/2013): $0 million.

The NBC will be set monthly based on a forecast and subject to a monthly true-up for all components based on the actual after-the-fact costs and load subject to the NBC. (i) The NBC will include the Lost Revenue Recovery Mechanism (LRRM) as described in Section 25.I.E. (ii) All service classes will pay the same charge on a volumetric basis, except customer classes who will also receive the benefits, if any, of NYPA purchased power provided for customer classes consistent with NYSEG’s contract with NYPA.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010
GENERAL INFORMATION 25. Supply Service Options: (cont’d.) I. Supply Service Options (cont’d.) B. 1. Transition Charge (Non-Bypassable Charge [NBC])

Leaf No. 117.9 Revision: 9 Superseding Revision: 8

Calculation of the Transition Charge (Non-Bypassable Charge [NBC]): (cont’d.) (iii) All items collected through the NBC will be symmetrically reconciled and trued-up monthly in a competitively neutral manner. The credits or charges related to the reconciliation will be included in a subsequent monthly NBC.

A Transition Charge Statement setting forth the Transition Charge (NBC) will be filed with the Public Service Commission on not less than one (1) day’s notice. C. Calculation of the Commodity Charge 1. Non-Demand Metered Customers (S.C. Nos. 1, 5, 6, 8, 9, 11 [Non-Demand], 12, and PSC No. 121 Street Lighting) The charge for Electric Power Supply provided by NYSEG will fluctuate with the market price of electricity and will include the following components; Energy, Energy Losses, Unaccounted For Energy, Capacity, Capacity Reserves, Capacity Losses, Ancillary Services/NTAC, Hedge Adjustment and a Supply Adjustment Charge. The methodology for calculating the Energy and Capacity components of the charge for Electric Power Supply is as follows: Energy Component: For each day of the customer’s billing cycle, a daily average value of market supply is derived from forward trading market prices of electricity for the region (East or West of the NYISO Total East Interface) in which the Customer is located and previous true-ups, weighted to reflect hourly usage based on load studies for the calendar month and day-type (Weekday, Saturday or Sunday/Holiday). Separate calculations will be made for each metered time period for the Customer’s individual Service Classification. The daily load weighted market price of energy will be adjusted to reflect losses. These daily average market supply values are used in conjunction with the service classification daily load study usage data to develop a weighted average value of market supply for each metered time period within the Customer’s specific billing period. The weighted average of market supply is multiplied by the Customer’s metered kWh usage for each metered time period to determine the value of market supply. Capacity Component: The Capacity component is calculated using the market-clearing price of capacity converted to $/kWh as determined from the NYISO’s monthly and spot capacity auctions. The capacity price will also include capacity losses and reserves. Ancillary Services/NYPA Transmission Adjustment Charge (NTAC) Component: The ancillary services/NTAC will be forecasted each month and included in the supply price and subsequently reconciled.

Issued in compliance with order in Case No. 09-E-0227 dated 09/28/09.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010
GENERAL INFORMATION 25. Supply Service Options: (cont’d.) I. Supply Service Options (cont’d.) C. Calculation of the Commodity Charge (cont’d.)

Leaf No. 117.10 Revision: 4 Superseding Revision: 3

1. Non-Demand Metered Customers (cont’d.) (S.C. Nos. 1, 5, 6, 8, 9, 11 [Non-Demand], 12, and PSC No. 121 Street Lighting) Hedge Adjustment: The hedge adjustment will pass through to customers the impact of any hedge position entered into on behalf of such customers. Supply Adjustment Charge Component: Unaccounted For Energy and all costs incurred related to supply will be reconciled and recovered or refunded through a subsequent Supply Adjustment Charge incorporated in the supply charge. 2. Non-Hourly Pricing Demand Metered Customers (S.C. Nos. 2, 3, 7, and 11 [Demand]) The charge for Electric Power Supply provided by NYSEG will fluctuate with the market price of electricity and will include the following components: Energy, Energy Losses, Unaccounted for Energy, Capacity, Capacity Reserves, Capacity Losses, Ancillary Services/NTAC, and a Supply Adjustment Charge. The methodology for calculating the Energy and Capacity components of the charge for Electric Power Supply is as follows: Energy Component: For each day of the customer's billing cycle, a daily average value of market supply is derived from the day ahead NYISO posted Locational Based Marginal Prices (LBMP) of electricity for the region (East or West of the NYISO Total East Interface) in which the Customer is located, weighted to reflect hourly usage based on load studies for the calendar month and day-type (Weekday, Saturday or Sunday/Holiday). Separate calculations will be made for each metered time period for the Customer’s individual Service Classification. LBMP in Zone C will be used for customers electrically connected West of the Total East NYISO Interface. LBMP in Zone G will be used for customers electrically connected East of the NYISO Total East Interface. The daily load weighted market price of energy will be adjusted to reflect losses and Unaccounted For Energy. These daily average market supply values are used in conjunction with the service classification daily load study usage data to develop a weighted average value of market supply for each metered time period within the Customer's specific billing period. The weighted average value of market supply is multiplied by the Customer's metered kWh usage for each metered time period to determine the value of market supply. Capacity Component: The Capacity component is calculated using the market-clearing price of capacity converted to $/kWh as determined from the NYISO's monthly and spot capacity auctions. The capacity price will also include capacity losses and reserves. Ancillary Services/NYPA Transmission Adjustment Charge (NTAC) Component: The ancillary services/NTAC will be forecasted each month and included in the supply price and subsequently reconciled. Supply Adjustment Charge Component: All costs incurred related to supply will be reconciled and recovered or refunded through a subsequent Supply Adjustment Charge incorporated in the supply charge.
Issued in compliance with orders in Case No. 09-E-0227 dated 09/28/09.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 117.11 New York State Electric & Gas Corporation Revision: 6 Initial Effective Date: September 26, 2010 Superseding Revision: 4 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 GENERAL INFORMATION 25. Supply Service Options: (cont’d.)

I. Supply Service Options (cont’d.) D. Merchant Function Charge (MFC): The MFC will be applicable to only those customers taking supply service from the Company (i.e., NSS and Hourly Pricing) and is set forth in a statement at the end of this Schedule (PSC No. 120 – Electricity). A separate MFC will be calculated for small (SC Nos. 1, 8, 12, 5, 6, 9, and street lighting) and large (SC Nos. 2, 3 & 7) customers. For Service Classification Nos. 11, 13, and 14, the customer’s otherwise applicable service classification will determine the applicable MFC. 1.) The MFC will include the following rate components as described in the Joint Proposal dated July 14, 2010 in Case Nos. 09-E-0715, 09-G-0716, 09-E-0717, and 09-G-0718. a) Commodity-related Uncollectible Costs b) Commodity-related Credit and Collections and Call Center costs; c) Commodity-related Administrative costs; d) Cash Working Capital on Purchased Power costs, if the New York Independent System Operator moves to weekly billing and e) Cash Working Capital on Commodity Hedge Margin costs. .

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 117.12 New York State Electric & Gas Corporation Revision: 6 Initial Effective Date: September 26, 2010 Superseding Revision: 4 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 GENERAL INFORMATION 25. Supply Service Options: (cont’d.)

I. Supply Service Options (cont’d.) D. Merchant Function Charge (MFC): (cont’d.) 2.) The MFC components will be updated and reconciled as stated below in accordance with the Joint Proposal dated July 14, 2010 in Case Nos. 09-E-0715, 09-G-0716, 09-E-0717, and 09-G-0718. a) Commodity-related Uncollectible Costs The commodity related uncollectible percentage rate will be reset annually based on the most recent available twelve-month period of actual uncollectibles The commodity-related uncollectible component of the MFC will be calculated each month by multiplying the uncollectible percentage rate for each of the groups described above by the associated monthly electric supply cost. b) Commodity-related Credit and Collections and Call Center costs Any over/under collections related to the credit and collections and call center costs component will be added to any over/under collections related to the credit and collections and call center costs component charged through the POR Administration Charge and POR Discount and reconciled through both the POR Discount and MFC in the subsequent rate year. The unit rate will be reset annually based on recent MFC and POR sales forecasts. c) Commodity-related Administrative costs The Administrative Component will be reconciled annually for differences in actual versus design sales only. The unit rate will be reset annually based on recent sales forecasts. d) Cash Working Capital on Purchased Power costs If the New York Independent System Operator starts weekly billing, the electric MFC will include a component for Cash Working Capital on Purchase Power. Working Capital on Purchase Power will be calculated based on the Companies’pre-tax rate of return. The Companies will reconcile the Working Capital on Purchased Power to actual applicable costs. This component will be updated annually to reflect actual costs from the most recently available twelve month period and the most recent sales forecast. e) Cash Working Capital on Commodity Hedge Margin costs The cash working capital on Commodity Hedge cost component will be based on the Companies' pre-tax rate of return and will be reconciled to actual costs annually. Additionally, this component will be updated annually to reflect actual costs from the most recently available twelve month period and the most recent sales forecast. E. Lost Revenue Recovery Mechanism (LRRM) The LRRM will be a component of the NBC. The LRRM will consist of the the collection/return of the under- or over-recovered unavoidable costs embedded in the MFC for any period up to and including 8/25/10. Under or over collection of MFC related costs for MFC’s in effect after 8/25/11 will be collected through the MFC reset.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010 GENERAL INFORMATION 25. Supply Service Options: (cont’d.) I. Supply Service Options (cont’d.) F. Customer Eligibility Exceptions: 1.

Leaf No. 117.13 Revision: 5 Superseding Revision: 4

Incentive Rate and Non-Incentive Rate Load: Customers receiving an Economic Incentive may select a Supply Service option, as specified in the applicable Special Provision for Economic Incentives of the respective service classifications. The customer must choose the same Supply Service option for all of their load. NYPA Customers Customers who receive a portion of their Electric Power Supply from NYPA, (Expansion, EDP, HLFM, PFJ, Replacement or Preservation Power), with Standard Load (non-NYPA load), shall be permitted to take service under any Supply Service option for their Standard Load. The NYPA load will continue to be billed at the appropriate NYPA rate as specified in the Special Provision of Service Classification No. 7. If the NYPA allocation expires or is terminated, the customer will have 30 days to elect a Supply Service option for that load. If the customer does not elect a Supply Service option, the NYPA load will be billed at the appropriate default option. Customers Applying for Service If a customer applying for service has not elected a Supply Service option by the time of billing, NYSEG will bill the customer at the appropriate default option as explained in Section 25.I.H. When a customer contacts NYSEG with their choice, that Supply Service option will be applicable to usage on and after the next regularly-scheduled estimated or actual meter reading date after such contact.

2.

3.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010
GENERAL INFORMATION 25. Supply Service Options: (cont’d.)

Leaf No. 117.14 Revision: 4 Superseding Revision: 3

I. Supply Service Options (cont’d.) F. Customer Eligibility Criteria: (cont’d.)

4. Service Classification No. 11 (“SC 11”)
A customer taking service under SC 11 is eligible to select a Supply Service option as follows: a. “OASC”: A customer taking service under SC 11 as an Existing Customer having elected the Phase-In, or as a Designated Technology Customer having elected the one-time exemption, both as defined in SC 11, will be billed at otherwise applicable service classification (“OASC”) rate. Such customers are eligible for only: 1) the NYSEG Supply Service (NSS), unless the customer is required to participate in mandatory Hourly Pricing or voluntarily elects Hourly Pricing, or 2) the ESCO Supply Service (ESS). SC 11 “New”: A customer taking service under SC 11, and will be billed at the SC 11 rates set forth under the section “RATES”. Such customers are eligible for only: 1) the NYSEG Supply Service (NSS), unless the customer is required to participate in mandatory Hourly Pricing or voluntarily elects Hourly Pricing, or 2) the ESCO Supply Service (ESS). SC 11 “Old”: A customer that is taking service under SC 11, Special Provision (d) Previous SC 11 Tariff is not eligible to select a Supply Service option. These customers are billed at the rates set forth in the Special Provision.

b.

c.

5. Service Classification Nos. 13 or 14 (“SC 13” or “SC 14”) Contracts
A customer taking service under SC Nos. 13 or 14 whose contract expires during the Enrollment Period is eligible for a Supply Service option as described in Section 25.I.A. A customer taking service under SC Nos. 13 or 14 whose contract expires on or after January 1, 2008, may select a Supply Service option, upon expiration of their contract, subject to the rules specified in Section 25.I.I.5, SC 13 or SC 14 Contracts Expiring. A customer receiving service under such SC 13 or SC 14 contract will not be eligible to select a Supply Service option during the term of the contract, unless the contract so provides.

6. Hourly Pricing
Hourly Pricing is mandatory for certain non-residential demand billed customers in Service Classification Nos. 2, 3, and 7, and demand billed Service Classification No. 11 as follows: January 1, 2010 – December 31, 2010 – Customers with billed demand greater than or equal to 300 kW in any two months within the twelve months prior to September 1, 2009. Customers that received an Economic Incentive or NYPA allocation on or before December 31, 2006 are exempt from mandatory Hourly Pricing.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010 GENERAL INFORMATION 25. Supply Service Options: (cont’d.) I. Supply Service Options (cont’d.) G. Reserved for Future Use H. Default Process:

Leaf No. 117.15 Revision: 4 Superseding Revision: 3

If a customer applying for service has not elected a Supply Service option, NYSEG will bill the customer under the NYSEG Supply Service option or Hourly Pricing, as appropriate.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010 GENERAL INFORMATION 25. Supply Service Options: (cont’d.)

Leaf No. 117.16 Revision: 3 Superseding Revision: 2

I. Supply Service Options (cont’d.) H. Reserved for Future Use

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010 GENERAL INFORMATION 25. Supply Service Options: (cont’d.)

Leaf No. 117.17 Revision: 3 Superseding Revision: 2

I. Supply Service Options (cont’d.) I. Changing Supply Service Options 1. A customer can switch to and from retail access at any time subject to the requirements set forth in General Information Section 16 – Customer Advantage Program – General Retail Access and the Uniform Business Practices, and as detailed below: a) ESCO Supply Service (ESS) A customer taking service under the ESS may switch to the NYSEG Supply Service (NSS). NYSEG Supply Service (NSS) A customer taking service under the NSS may switch to the ESCO Supply Service (ESS). b) Hourly Pricing A customer mandatorily participating in Hourly Pricing, who is taking service under the ESS, may switch only to the NYSEG Day-Ahead Market Pricing Option. A customer mandatorily participating in Hourly Pricing, who is taking service under the NYSEG Day-Ahead Market Pricing Option, may switch only to ESS.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010 GENERAL INFORMATION 25. Supply Service Options: (cont’d.)

Leaf No. 117.18 Revision: 3 Superseding Revision: 2

I. Supply Service Options (cont’d.) I. Changing Supply Service Options (cont’d.) 2. Process for Changing to a Retail Access Supply Service Option To effectuate the switch to retail access, the customer’s ESCO must contact NYSEG to submit the customer’s Retail Access enrollment information. Upon NYSEG's receipt of notice that the customer is enrolling in Retail Access, NYSEG will notify the customer of such enrollment by sending the customer a letter. 3. Process for Changing to a Non-Retail Access Supply Service Option A customer that is changing from a retail access option to a non-retail access option may do so by first contacting its ESCO to discontinue Retail Access service. (Alternatively, a customer may contact NYSEG directly with its request.) Upon NYSEG's receipt of notice from the ESCO that the customer is canceling Retail Access, NYSEG will notify the customer of such cancellation by sending the customer a letter. 4. ESCO Discontinuance of Sales to Individual Customer: If an ESCO cancels a customer's Retail Access service, such ESCO must follow the procedures set forth in the UBP Addendum to this Schedule. Upon receipt of the notice of discontinuance from the ESCO, NYSEG will verify this request with the customer by sending a letter to the customer.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010 GENERAL INFORMATION 25. Supply Service Options: (cont’d.) I. Supply Service Options (cont’d.) I. Changing Supply Service Options (cont’d.) 5. SC 13 or SC 14 Contracts Expiring Customers required to take mandatory Hourly Pricing:

Leaf No. 117.19 Revision: 3 Superseding Revision: 2

A customer taking service under SC 13 or 14, who would otherwise qualify for mandatory Hourly Pricing, will be billed at Hourly Pricing rates upon expiration of their SC 13 or 14 contract, unless a retail access enrollment is received from an ESCO at least 15 calendar days prior to the contract end date. If such retail access enrollment has been received, the customer will be billed at the ESCO Supply Service (ESS) option effective with the contract end date meter reading. Customers not required to take Hourly Pricing: If the customer is not required to be served at Hourly Pricing, upon expiration of their SC13 or 14 contract, the customer would be eligible to select a Supply Service Option described in Section 25.I.A. If the customer does not enroll in a Supply Service Option, and no retail access enrollment has been received from an ESCO at least 15 calendar days prior to the contract end date, the customer will be billed at the NYSEG Supply Service (NSS) option effective with the contract end date meter reading.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010 GENERAL INFORMATION 25. Supply Service Options: (cont’d.) II. Reserved for Future Use

Leaf No. 117.20 Revision: 3 Superseding Revision: 2

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010 GENERAL INFORMATION 25. Supply Service Options: (cont’d.) II. Reserved for Future Use

Leaf No. 117.21 Revision: 1 Superseding Revision: 0

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010 GENERAL INFORMATION 25. Supply Service Options: (cont’d.) II. Reserved for Future Use

Leaf No. 117.22 Revision: 1 Superseding Revision: 0

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010 GENERAL INFORMATION 25. Supply Service Options: (cont’d.) II. Reserved for Future Use

Leaf No. 117.23 Revision: 1 Superseding Revision: 0

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010 GENERAL INFORMATION 25. Supply Service Options: (cont’d.) II. Reserved for Future Use

Leaf No. 117.24 Revision: 1 Superseding Revision: 0

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010 GENERAL INFORMATION 25. Supply Service Options: (cont’d.) II. Reserved for Future Use

Leaf No. 117.25 Revision: 1 Superseding Revision: 0

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010 GENERAL INFORMATION 25. Supply Service Options: (cont’d.) II. Reserved for Future Use

Leaf No. 117.26 Revision: 1 Superseding Revision: 0

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010
GENERAL INFORMATION 25. Supply Service Options: (cont’d.) II. Reserved for Future Use

Leaf No. 117.27 Revision: 1 Superseding Revision: 0

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010
GENERAL INFORMATION 25. Supply Service Options: (cont’d.) II. Reserved for Future Use

Leaf No. 117.28 Revision: 1 Superseding Revision: 0

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010
GENERAL INFORMATION 25. Supply Service Options: (cont’d.) II. Reserved for Future Use

Leaf No. 117.29 Revision: 1 Superseding Revision: 0

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010 GENERAL INFORMATION 25. Supply Service Options: (cont’d.) II. Reserved for Future Use

Leaf No. 117.30 Revision: 1 Superseding Revision: 0

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: February 26, 2010 GENERAL INFORMATION 26. Solar Residential Electric Service Option

Leaf No. 117.31 Revision: 3 Superseding Revision: 2

Applicable to any Residential Customer (as defined by HEFPA) who operates solar generating equipment located and used at his or her primary, legal residence. Solar generating equipment is defined as a solar system, with a rated capacity of not more than 25 kilowatts that is manufactured, installed and operated in accordance with applicable government and industry standards. Such system must be connected to the customer's electric system and operated in parallel with NYSEG's transmission and distribution facilities. Application of the Solar Residential Service Option will be available to eligible customers, on a first come, first served basis, until the total rated generating capacity for solar, farm waste, MCHP and fuel cell electric generating equipment owned, leased or operated by customer-generators in NYSEG's service area is equivalent to 28,260 kW (one percent of NYSEG's electric demand for the year 2005) and is available only in non-network areas of the Corporation's territory. Customers electing service under this provision must execute a New York State Standardized Contract for Interconnection of New Distributed Generation Units with Capacity of 2 MW or Less Connected in Parallel with Utility Distribution Systems (“SIR Contract”). In addition, customers must operate in compliance with standards and requirements set forth in the New York State Standard Interconnection Requirements and Application Process for New Distributed Generators 2 MW or Less Connected in Parallel with Utility Distribution Systems, as set forth within AddendumSIR of Schedule PSC 119. For a net metered customer, the Corporation will install metering appropriate for the customer’s service classification that enables the Corporation to measure the electricity delivered to the customer and measure the electricity supplied by the customer to the Corporation. Where the Corporation determines that a second meter should be installed, no additional costs shall be billed to the customer. When a second meter is requested by the customer that is not required by the Corporation, the customer will be responsible for the cost of the meter, the installation and any additional costs. For each billing period during the term of the SIR Contract, the Corporation will net the electricity (kWh) delivered to the customers with the electricity (kWh) supplied by the customer to the Corporation. If the electricity (kWh) supplied by the Corporation exceeds the electricity supplied by the customer to the Corporation during the billing period the customer shall be billed for the net kWh supplied by the Corporation to the customer at the standard service class rates. For customers billed on timedifferentiated rates (TOU meter), e.g., On-Peak/Off-Peak or Day/Night, netting will occur in each time period. b) If the electricity (kWh) supplied by the customer to the Corporation during the billing period exceeds the electricity (kWh) supplied by the Corporation to the customer, a kWh credit will be carried forward for the next billing period. For customers billed on time-differentiated rates (TOU meter), e.g., OnPeak/Off-Peak or Day/Night, the kWh credit will be carried forward as a credit to the appropriate time period. For customers billed on TOU rates, if the electricity (kWh) supplied by the customer to the Corporation is not metered for each TOU period and until such time as metering is installed to measure electricity supplied to the Corporation in each TOU period, an allocation of the electricity supplied to the Corporation will be done according to allocation factors as set forth in a Special Provision provided in each service classification in this Schedule. a)

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: July 23, 2010

Leaf No. 117.32 Revision: 4 Superseding Revision: 3

GENERAL INFORMATION

26. Solar Residential Electric Service Option (Cont’d.) At the end of a year, or annualized over the period that service is supplied under this provision, the value of any credit remaining on a customer’s account for excess electricity produced by the customer-generator shall be paid to the customer at the Corporation’s avoided cost for energy. Payment will occur in the form of a voucher which will be issued under authority of Order of the Public Service Commission to the customer-generator, for use in offsetting any of the issuing utility’s bills directed to that customer during the year following the date of the voucher. Upon the Corporation’s determination that the customer has taken service under this Section 26 while in violation of the conditions of service set forth herein, the customer shall forfeit any positive balance accrued during the annual period in which the violation occurred. Pursuant to the Standard Interconnection Requirements set forth within Addendum-SIR of P.S.C. No. 119, customers are responsible for providing all meter boxes and sockets. In the event that NYSEG determines that it is necessary to install a dedicated transformer or transformers, or other equipment to protect the safety and adequacy of electric service provided to other customers, the customer-generator shall pay for the cost of installing the transformer or transformers, or other equipment up to a maximum amount of $350.00. The Corporation will not charge any additional solar electric specific interconnection costs incurred by NYSEG other than $350.00 for dedicated transformers or other equipment, if necessary. Customers are responsible for any costs related to the installation of their solar generating equipment. Notwithstanding the provisions herein, residential solar electric customers are responsible for meeting all otherwise applicable provisions and requirements of P.S.C. Nos. 119 and 120. 27. Solar Non-Residential Electric Service Option Applicable to any Non-Residential Customer who operates solar generating equipment located and used at its premises. Solar generating equipment is defined as a solar system that is manufactured, installed and operated in accordance with applicable government and industry standards with a rated capacity of not more than two thousand kilowatts. Such system must be connected to the customer's electric system and operated in parallel with NYSEG's transmission and distribution facilities. Application of the Solar Non-Residential Electric Service Option be available to eligible customers, on a first come, first served basis, until the total rated generating capacity for solar, farm waste, MCHP and fuel cell electric generating equipment owned, leased or operated by customer-generators in NYSEG's service area is equivalent to 28,260 kW (one percent of NYSEG's electric demand for the year 2005) and is available only in non-network areas of the Corporation's territory. Customers electing service under this provision must execute a New York State Standardized Contract for Interconnection of New Distributed Generation Units with Capacity of 2 MW or Less Connected in Parallel with Utility Distribution Systems (“SIR Contract”). In addition, customers must operate in compliance with standards and requirements set forth in the New York State Standard Interconnection Requirements and Application Process for New Distributed Generators 2 MW or Less Connected in Parallel with Utility Distribution Systems, as set forth within Addendum-SIR of Schedule PSC 119.
Issued in compliance with order in Case No. 10-E-0135 dated 3/31/10.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: July 23, 2010

Leaf No. 117.33 Revision: 3 Superseding Revision: 2

GENERAL INFORMATION 27. Solar Non-Residential Electric Service Option (Cont’d.) For a net metered customer, the Corporation will install metering appropriate for the customer’s service classification that enables the Corporation to measure the electricity delivered to the customer and measure the electricity supplied by the customer to the Corporation. Where the Corporation determines that a second meter should be installed, no additional costs shall be billed to the customer. When a second meter is requested by the customer that is not required by the Corporation, the customer will be responsible for the cost of the meter, the installation and any additional costs. For each billing period during the term of the SIR Contract, the Corporation will net the electricity (kWh) delivered to the customers with the electricity (kWh) supplied by the customer to the Corporation. a) If the electricity (kWh) supplied by the Corporation exceeds the electricity supplied by the customer to the Corporation during the billing period the customer shall be billed for the net kWh supplied by the Corporation to the customer at the standard service class rates. For customers billed on timedifferentiated rates (TOU meter), e.g., On-Peak/Off-Peak or Day/Night, netting will occur in each time period. b) If the electricity (kWh) supplied by the customer to the Corporation during the billing period exceeds the electricity (kWh) supplied by the Corporation to the customer, a kWh credit will be carried forward for the next billing period. For customers billed on time-differentiated rates (TOU meter), e.g., OnPeak/Off-Peak or Day/Night, the kWh credit will be carried forward as a credit to the appropriate time period. c) For demand-billed customers, prior to carrying forward any kWh credit, the kWhs will be converted to a dollar value using the applicable tariff per kWh rate and applied as a credit to the current utility bill. If the dollar value of the kWh exceeds the current utility bill, any remaining dollars will be converted back to kWhs and carried forward for the next billing period as a kWh credit. For customers billed on TOU rates, if the electricity (kWh) supplied by the customer to the Corporation is not metered for each TOU period and until such time as metering is installed to measure electricity supplied to the Corporation in each TOU period, an allocation of the electricity supplied to the Corporation will be done according to allocation factors as set forth in a Special Provision provided in each service classification in this Schedule. Upon the Corporation’s determination that the customer has taken service under this Section 27 while in violation of the conditions of service set forth herein, the customer shall forfeit any positive balance accrued in its Credit Account during the annual period in which the violation occurred. Pursuant to the Standard Interconnection Requirements set forth within Addendum-SIR of P.S.C. No. 119, customers are responsible for providing all meter boxes and sockets. In the event that NYSEG determines that it is necessary to install a dedicated transformer or transformers, or other equipment to protect the safety and adequacy of electric service provided to other customers, a customer-generator with a combined rating less than 25 kW shall pay for the cost of installing such transformer(s) or other equipment, up to a maximum amount of $350. A customergenerator with a combined rating equal to or greater than 25 kW shall pay for the cost of installing the transformer(s) or other equipment. Notwithstanding the provisions herein, non-residential solar electric customers are responsible for meeting all otherwise applicable provisions and requirements of P.S.C. Nos. 119 and 120.
Issued in compliance with order in Case No. 10-E-0135 dated 3/31/10.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 117.34 Revision: 1 Superseding Revision: 0

GENERAL INFORMATION 28. Surcharge to Collect Temporary State Assessment (“TSAS”) Each customer bill for service under Service Classification Nos. 1, 2, 3, 5, 6, 7, 8, 9, 11, 12, 13, and 14 will be increased to collect a Temporary State Energy and Utility Service Conservation Assessment pursuant to the Commission’s Order Implementing Temporary State Assessment, issued June 19, 2009. Unless prohibited by contract, the surcharge rate will be multiplied by all kWh delivered, including usage subject to Economic Incentives and kWh’s supplied by NYPA. For customers taking service under Service Classification Nos. 11 Special Provision (d), 13, and 14, and customers that have received a NYPA allocation or an economic incentive, the customer’s otherwise applicable service classification will determine the applicable surcharge. For customers taking service under Service Classification 11, the surcharge will be applied to the Contract Demand. Each year a reconciliation of the amounts to be recovered through the surcharge and the actual amounts collected will be reflected in the establishment of the TSAS for the following year. A Temporary State Assessment Surcharge (TSAS) Statement setting forth the surcharges by service classification will be filed with the Public Service Commission on not less than fifteen (15) days’ notice. Such statement can be found at the end of this Schedule (PSC 120 – Electricity).

Issued in compliance with order in Case No. 09-M-0311 dated 6/19/09.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: February 26, 2010 GENERAL INFORMATION 29. Micro-combined Heat and Power (MCHP) Service Option

Leaf No. 117.35 Revision: 2 Superseding Revision: 1

Applicable to any Residential Customer (as defined by HEFPA) who owns, leases or operates MCHP generating equipment. MCHP generating equipment is defined as an integrated, cogenerating building heating and electrical power generation system, operating on any fuel and of any applicable engine, fuel cell, or other technology, with a rated capacity of at least one kilowatt and not more than ten kilowatts electric and any thermal output that at full load has a design total fuel use efficiency in the production of heat and electricity of not less than eighty percent, and annually produces at least two thousand kilowatt hours of useful energy in the form of electricity that may work in combination with supplemental or parallel conventional heating systems, that is manufactured, installed and operated in accordance with applicable government and industry standards, that is connected to the electric system and operated in conjunction with an electric corporation’s transmission and distribution facilities. Such system must be connected to the customer's electric system and operated in parallel with NYSEG's transmission and distribution facilities. Application of the MCHP Residential Service Option will be available to eligible customers, on a first come, first served basis, until the total rated generating capacity for solar, farm waste, MCHP and fuel cell electric generating equipment owned, leased or operated by customer-generators in NYSEG's service area is equivalent to 28,260 kW (one percent of NYSEG's electric demand for the year 2005) and is available only in non-network areas of the Corporation's territory. Customers electing service under this provision must execute a New York State Standardized Contract for Interconnection of New Distributed Generation Units with Capacity of 2 MW or Less Connected in Parallel with Utility Distribution Systems (“SIR Contract”). In addition, customers must operate in compliance with standards and requirements set forth in the New York State Standard Interconnection Requirements and Application Process for New Distributed Generators 2 MW or Less Connected in Parallel with Utility Distribution Systems, as set forth within Addendum-SIR of Schedule PSC 119. For a net metered customer, the Corporation will install metering appropriate for the customer’s service classification that enables the Corporation to measure the electricity delivered to the customer and measure the electricity supplied by the customer to the Corporation. Where the Corporation determines that a second meter should be installed, no additional costs shall be billed to the customer. When a second meter is requested by the customer that is not required by the Corporation, the customer will be responsible for the cost of the meter, the installation and any additional costs. For each billing period during the term of the SIR Contract, the Corporation will net the electricity (kWh) delivered to the customers with the electricity (kWh) supplied by the customer to the Corporation. a) If the electricity (kWh) supplied by the Corporation exceeds the electricity supplied by the customer to the Corporation during the billing period the customer shall be billed for the net kWh supplied by the Corporation to the customer at the standard service class rates. For customers billed on timedifferentiated rates (TOU meter), e.g., On-Peak/Off-Peak or Day/Night, netting will occur in each time period. b) If the electricity (kWh) supplied by the customer to the Corporation during the billing period exceeds the electricity (kWh) supplied by the Corporation to the customer, the Corporation will provide a credit on the next bill for net electricity supplied at the Corporation’s avoided cost Service Classification 10 energy rate. For customers billed on time-differentiated rates (TOU meter), e.g., On-Peak/Off-Peak or Day/Night, the kWh credit will be a credit for the appropriate time period.

Issued in compliance with order in Case 09-E-0829 dated 02/12/10.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: February 26, 2010 GENERAL INFORMATION 29. Micro-combined Heat and Power (MCHP) Service Option (cont’d.)

Leaf No. 117.36 Revision: 1 Superseding Revision: 0

Upon the Corporation’s determination that the customer has taken service under this Section while in violation of the conditions of service set forth herein, the customer shall forfeit any positive balance accrued during the period in which the violation occurred. Pursuant to the Standard Interconnection Requirements set forth within Addendum-SIR of P.S.C. No. 119, customers are responsible for providing all meter boxes and sockets. In the event that NYSEG determines that it is necessary to install a dedicated transformer or transformers, or other equipment to protect the safety and adequacy of electric service provided to other customers, the customer-generator shall pay for the cost of installing the transformer or transformers, or other equipment up to a maximum amount of $350.00. The Corporation will not charge any additional MCHP electric specific interconnection costs incurred by NYSEG other than $350.00 for dedicated transformers or other equipment, if necessary. Customers are responsible for any costs related to the installation of their solar generating equipment. Notwithstanding the provisions herein, residential MCHP electric customers are responsible for meeting all otherwise applicable provisions and requirements of P.S.C. Nos. 119 and 120.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: February 26, 2010 GENERAL INFORMATION 30. Fuel Cell Residential Electric Service Option

Leaf No. 117.37 Revision: 2 Superseding Revision: 1

Applicable to any Residential Customer (as defined by HEFPA) who owns, leases or operates fuel cell generating equipment. Fuel cell generating equipment is defined as a solid oxide, molten carbonate, proton exchange membrane or phosphoric acid fuel cell with a combined rated capacity of not more than ten kilowatts that is manufactured, installed and operated in accordance with applicable government and industry standards, that is connected to the electric system and operated in parallel with an electric corporation’s transmission and distribution facilities, and that is operated in compliance with any standards and requirements established under this section. Such system must be connected to the customer's electric system and operated in parallel with NYSEG's transmission and distribution facilities. Application of the Fuel Cell Residential Service Option will be available to eligible customers, on a first come, first served basis, until the total rated generating capacity for solar, farm waste, MCHP and fuel cell electric generating equipment owned, leased or operated by customer-generators in NYSEG's service area is equivalent to 28,260 kW (one percent of NYSEG's electric demand for the year 2005) and is available only in non-network areas of the Corporation's territory. Customers electing service under this provision must execute a New York State Standardized Contract for Interconnection of New Distributed Generation Units with Capacity of 2 MW or Less Connected in Parallel with Utility Distribution Systems (“SIR Contract”). In addition, customers must operate in compliance with standards and requirements set forth in the New York State Standard Interconnection Requirements and Application Process for New Distributed Generators 2 MW or Less Connected in Parallel with Utility Distribution Systems, as set forth within Addendum-SIR of Schedule PSC 119. For a net metered customer, the Corporation will install metering appropriate for the customer’s service classification that enables the Corporation to measure the electricity delivered to the customer and measure the electricity supplied by the customer to the Corporation. Where the Corporation determines that a second meter should be installed, no additional costs shall be billed to the customer. When a second meter is requested by the customer that is not required by the Corporation, the customer will be responsible for the cost of the meter, the installation and any additional costs. For each billing period during the term of the SIR Contract, the Corporation will net the electricity (kWh) delivered to the customers with the electricity (kWh) supplied by the customer to the Corporation. If the electricity (kWh) supplied by the Corporation exceeds the electricity supplied by the customer to the Corporation during the billing period the customer shall be billed for the net kWh supplied by the Corporation to the customer at the standard service class rates. For customers billed on timedifferentiated rates (TOU meter), e.g., On-Peak/Off-Peak or Day/Night, netting will occur in each time period. b) If the electricity (kWh) supplied by the customer to the Corporation during the billing period exceeds the electricity (kWh) supplied by the Corporation to the customer, the Corporation will provide a credit on the next bill for net electricity supplied at the Corporation’s avoided cost Service Classification 10 energy rate. For customers billed on time-differentiated rates (TOU meter), e.g., On-Peak/Off-Peak or Day/Night, the kWh credit will be a credit for the appropriate time period. a)

Issued in compliance with order in Case 09-E-0829 dated 02/12/10.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: February 26, 2010 GENERAL INFORMATION 30. Fuel Cell Residential Electric Service Option (cont’d.)

Leaf No. 117.38 Revision: 1 Superseding Revision: 0

Upon the Corporation’s determination that the customer has taken service under this Section while in violation of the conditions of service set forth herein, the customer shall forfeit any positive balance accrued during the period in which the violation occurred. Pursuant to the Standard Interconnection Requirements set forth within Addendum-SIR of P.S.C. No. 119, customers are responsible for providing all meter boxes and sockets. In the event that NYSEG determines that it is necessary to install a dedicated transformer or transformers, or other equipment to protect the safety and adequacy of electric service provided to other customers, the customer-generator shall pay for the cost of installing the transformer or transformers, or other equipment up to a maximum amount of $350.00. The Corporation will not charge any additional fuel cell electric specific interconnection costs incurred by NYSEG other than $350.00 for dedicated transformers or other equipment, if necessary. Customers are responsible for any costs related to the installation of their solar generating equipment. Notwithstanding the provisions herein, residential fuel cell electric customers are responsible for meeting all otherwise applicable provisions and requirements of P.S.C. Nos. 119 and 120.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010 SERVICE CLASSIFICATION NO. 1 APPLICABLE TO THE USE OF SERVICE FOR:

Leaf No. 118 Revision: 5 Superseding Revision: 4

Residential Customers in individual private dwellings, flats or apartments, and Religious Customers utilizing service exclusively in connection with religious purposes by a corporation or association organized and conducted in good faith for religious purposes. Applicable also to use exclusively in connection with a community residence for the mentally disabled, as defined in subdivision 28, 28-a, or 28-b of section 1.03 of the mental hygiene law, provided that such residence is operated by a not-for-profit corporation and, if supervisory staff is on site 24 hours a day, that the residence provides living accommodations for 14 or fewer residents. Also applicable to any not-for-profit corporation that is a veterans' organization that owns or leases a post or hall. CHARACTER OF SERVICE: Residential Customers: Continuous - Alternating Current, 60 Cycle; 120, 120/208, or 120/240 Volts - Single Phase. (Characteristics depend upon available circuits.) Religious, Veterans' Organizations, and Community Residence Supportive Living Facility Customers: Continuous - Alternating current, 60 cycle; Single or Three Phase. (Characteristics depend upon available circuits and equipment.) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: Pursuant to General Information Section 25, Supply Service Options, customers served under this Service Classification will choose from different electric rate choices offered by the Company as described below. NYSEG will offer a Retail Access rate choice and a Non-Retail Access rate choice. The Retail Access choice is the ESCO Supply Service (ESS). The Non-Retail Access choice is the NYSEG Supply Service (NSS). NYSEG will provide Delivery Service regardless of the customer’s supply service option.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 119 New York State Electric & Gas Corporation Revision: 11 Initial Effective Date: September 26, 2010 Superseding Revision: 9 Issued in compliance with Order in Case 09-E-0715, dated September 21, 2010 SERVICE CLASSIFICATION NO. 1 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (Cont'd.) 1. ESCO Supply Service (ESS) This Retail Access choice includes fixed charges for NYSEG delivery service and a Transition Charge (NonBypassable Charge [NBC]). Supply Service will be provided by an Energy Services Company (ESCO). Customers that elect ESS and receive a Consolidated Bill will not be subject to the Bill Issuance Charge. RATE: (Per Meter, Per Month) Delivery Service: Effective Date 09/01/2011 $15.11 $0.0318

Customer Charge Energy Charge
(All kilowatt-hours, per kilowatt-hour)

09/26/2010 $15.11 $0.0306

09/01/2012 $15.11 $0.0333

Transition Charge All kilowatt-hours, per kilowatt-hour

See Transition Charge Statement

Bill Issuance Charge (per bill):

$0.73, as described in General Information Section 16.J.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2008

Leaf No. 120 Revision: 6 Superseding Revision: 4

SERVICE CLASSIFICATION NO. 1 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (Cont'd.) Reserved for Future Use

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 121 Revision: 17 Superseding Revision: 15

SERVICE CLASSIFICATION NO. 1 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (Cont'd.) NYSEG will provide Delivery and Supply Service for the Non-Retail Access choice. 2. Reserved for Future Use

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2008

Leaf No. 121.1 Revision: 2 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 1 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (Cont'd.) Reserved for Future Use

Issued in compliance with order in Case No. 07-E-0749 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 122 New York State Electric & Gas Corporation Revision: 10 Initial Effective Date: September 26, 2010 Superseding Revision: 8 Issued in compliance with Order in case 09-E-0715, dated September 21, 2010 SERVICE CLASSIFICATION NO. 1 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (Cont'd.) 3. NYSEG Supply Service (NSS) This Non-Retail Access choice includes fixed charges for NYSEG delivery service, a Transition Charge (Non-Bypassable Charge [NBC]), a fluctuating commodity charge for electricity supplied by NYSEG, and a Merchant Function Charge. RATE: (Per Meter, Per Month)

09/26/2010 Delivery Charges Customer Charge Energy Charge
(All kilowatt-hours, per kilowatt-hour)

Effective Date 09/01/2011 $15.11 $0.0318

09/01/2012 $15.11 $0.0333

$15.11 $0.0306

Transition Charge All kilowatt-hours, per kilowatt-hour

See Transition Charge Statement

Commodity Service The charge for Electric Power Supply provided by NYSEG will fluctuate each month as further described in General Information Section 25.I.C., Calculation of the Commodity Charge. Merchant Function Charge All kilowatt-hours, per kilowatt-hour See Merchant Function Charge Statement Bill Issuance Charge (per bill): $0.73, as described in General Information Section 16.J.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 123 New York State Electric & Gas Corporation Revision: 21 Initial Effective Date: September 26, 2010 Superseding Revision: 19 Issued in compliance with Order in Case 09-E-0715, dated September 21, 2010 SERVICE CLASSIFICATION NO. 1 (Continued) MERCHANT FUNCTION CHARGE:
The Merchant Function Charge reflects the administrative costs of obtaining electricity supply, as further explained in General Information Section 25.D. Customers whose electricity is supplied by an ESCO are not charged for this service.

MINIMUM CHARGE:
The minimum charge for service under this Service Classification is the monthly Customer Charge plus the Bill Issuance Charge, if applicable, as listed above.

SURCHARGE TO COLLECT SYSTEM BENEFITS CHARGE ("SBC"):
A surcharge will be added to each customer bill for service under this Service Classification to collect the System Benefits Charge (as explained in this Schedule, General Information Section 4). See SBC Statement.

RENEWABLE PORTFOLIO STANDARD CHARGE (“RPS”):
A surcharge will be added to each customer bill for service under this Service Classification to collect the Renewable Portfolio Standard (as explained in this Schedule, General Information Section 5). See RPS Statement.

SURCHARGE TO COLLECT TEMPORARY STATE ASSESSMENT (“TSAS”):
A surcharge will be added to each customer bill for service under this Service Classification to collect the Temporary State Assessment (as explained in this Schedule, General Information Section 28). See TSAS Statement.

REVENUE DECOUPLING MECHANISM (“RDM”):
A customer taking service under this Service Classification shall be subject to a Revenue Decoupling Adjustment (as explained in this Schedule, General Information Section 7). See RDM Statement.

INCREASE IN RATES AND CHARGES:
The rates and charges under this Service Classification, including minimum charges, will be increased by a surcharge pursuant to Section 6 of this Schedule to reflect the tax rates applicable within the municipality where the customer takes service.

TERMS OF PAYMENT:
All bills are rendered at the above "Unit Prices" and that amount is due on bills paid on or before the past due date indicated on the bill. A late payment charge at the rate of one and one-half percent (1 1/2%) per month will be billed on all amounts not paid by that date. (Further details in Section 4 of P.S.C. No. 119 - Electricity or superseding issues thereof.)

TERM:
One month and thereafter until terminated by 48 hours' written notice.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 124 New York State Electric & Gas Corporation Revision: 19 Initial Effective Date: September 26, 2010 Superseding Revision: 17 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010
SERVICE CLASSIFICATION NO. 1 (Continued) SPECIAL PROVISIONS: (a) Seasonal Service: Upon request, customers who, during a period of six or more consecutive months, make only occasional (compared to the balance of the year) or no use of electric service at their premises may have their service maintained throughout the period, not to exceed eight months, and will be billed for the kilowatt-hours consumed during this period at the following unit prices per kWh: Effective Date 9/26/2010 Delivery Charges
(All kilowatt-hours, per kilowatt-hour)

09/01/2011 $0.0318

09/01/2012 $0.0333

$0.0306

Transition Charge
(All kilowatt-hours, per kilowatt-hour)

See Transition Charge Statement

The total bill for delivery service, however, for the year shall in no case be less than $181.32 plus actual billed Bill Issuance Charges. Commodity Service Customers served under this special provision will be billed for supply service in accordance with the customer’s Supply Service Option (ESS or NSS). Merchant Function Charge Customers served under this special provision taking service under the NSS will be required to pay the Merchant Function Charge set forth on the Merchant Function Charge Statement.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2008

Leaf No. 125 Revision: 6 Superseding Revision: 4

SERVICE CLASSIFICATION NO. 1 (Continued) SPECIAL PROVISIONS: (Cont'd) (b) Multiple Dwellings: Two or more individual flats, apartments or dwelling units presently supplied service through one meter may be billed under this service classification. (c) Commercial Use: When a customer operates a commercial establishment (incidental to his residence) in the same building or on the same premises as his residence and takes his entire service through one meter, this classification will apply for the entire service only if the connected load in the residential portion exceeds that in the commercial portion, provided that the connected load in the commercial portion does not exceed 1.5 kW. If the reverse is true, the general classification will apply to the entire service. However, the customer may elect to take service under both the residential and general rates, in which case there will be a separate meter for the residential portion and a separate meter for the general portion. (d) Budget Billing: Customers may, by signing an application, be billed monthly in accordance with the plan set forth in Section 4-0 of P.S.C. No. 119 - Electricity or superseding issues thereof. (e) Quarterly Payment Plan: Effective November 29, 1985, as required by Public Service Law Section 38, the Company will offer any residential customer, 62 years of age or older, a plan for payment on a quarterly basis of charges for service rendered, provided that such customer's average annual billing is not more than $150. (f) Reserved for Future Use

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2007

Leaf No. 125.1 Revision: 2 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 1 (Continued) SPECIAL PROVISIONS: (Cont'd) (f) Reserved for Future use (g) Reserved for Future Use

Issued in compliance with order in Case No. 05-E-1222 dated 08/23/06.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: February 5, 2009 Effective date postponed to 02/27/09. See Supplement No. 13.

Leaf No. 126 Revision: 3 Superseding Revision: 2

SERVICE CLASSIFICATION NO. 1 (Continued) SPECIAL PROVISIONS: (Cont'd): (h) Solar Residential Electric Service Option: This option is for a customer qualifying for the Solar Residential Generating Service Option pursuant to General Information Section 26 of this Schedule and taking service under SC1.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 26, 2010

Leaf No. 127 Revision: 7 Superseding Revision: 6

SERVICE CLASSIFICATION NO. 1 (Continued) SPECIAL PROVISIONS: (Cont'd): (i) Farm Waste Electric Generating System Option: This option is for a customer qualifying for the Farm Waste Electric Generating System Option pursuant to General Information Section 22 of this Schedule and taking service under SC 1. (j) Wind Electric Service Option:

This option is for a customer qualifying for the Wind Electric Service Option pursuant to General Information Section 23 of this Schedule and taking service under SC 1. (k) Electric Hybrid Generating System Option: This option is for a customer qualifying for the Electric Hybrid Generating System Option pursuant to General Information Section 24 of this Schedule and taking service under SC 1. (l) Micro-combined Heat and Power (MCHP) Service Option: This option is for a customer qualifying for the MCHP Service Option pursuant to General Information Section 29 of this Schedule and taking service under SC 1. (m) Fuel Cell Residential Electric Service Option: This option is for a customer qualifying for the Fuel Cell Service Option pursuant to General Information Section 30 of this Schedule and taking service under SC 1.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010 SERVICE CLASSIFICATION NO. 2 APPLICABLE TO THE USE OF SERVICE FOR:

Leaf No. 128 Revision: 7 Superseding Revision: 6

General Services - with Demand Billing. (For estimated metered demands of more than 5 kilowatts but less than 500 kilowatts.) CHARACTER OF SERVICE: Continuous - Alternating Current, 60 Cycle; 120, 120/208, 120/240, 208, 240, 240/416, 277/480 or 480 Volts Single or Three Phase. (Also Two Phase in Walden District.) (Characteristics depend upon available circuits and equipment.) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: Pursuant to General Information Section 25, Supply Service Options, customers served under this Service Classification will choose from different electric rate choices offered by the Company as described below. NYSEG will offer a Retail Access rate choice and Non-Retail Access rate choices. The Retail Access choice is the ESCO Supply Service (ESS). The Non-Retail Access choices include the NYSEG Supply Service (NSS) and Hourly Pricing. NYSEG will provide Delivery Service regardless of the customer’s Supply Service Option. 1. ESCO Supply Service (ESS) This Retail Access choice includes fixed charges for NYSEG delivery service and a Transition Charge (NonBypassable Charge [NBC]). Supply Service will be provided by an Energy Services Company (ESCO). Customers that elect ESS and receive a Consolidated Bill will not be subject to the Bill Issuance Charge.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: September 26, 2010 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010

Leaf No. 129 Revision: 14 Superseding Revision: 13

SERVICE CLASSIFICATION NO. 2 (Continued)
SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (Cont'd.) 1. ESCO Supply Service (ESS) (Cont'd.) RATE: (Per Meter, Per Month) Delivery Charges: Effective Date 09/26/2010 Customer Charge Meter Ownership Charge Meter Service Charge Meter Data Service Charge
(Meter Reading)

09/01/2011 $3.87 $1.68 $8.48 $2.08

09/01/2012 $5.37 $1.68 $8.48 $2.08

09/01/2013 $5.37 $1.68 $8.48 $2.08

09/01/2014 $5.37 $1.68 $8.48 $2.08

09/01/2015 $5.37 $1.68 $8.48 $2.08

09/01/2016 $5.37 $1.68 $8.48 $2.08

$2.84 $1.68 $8.48 $2.08

Demand Charge
(All kilowatts, per kilowatt)

$8.08 $0.00311

$8.13 $0.00344

$8.32 $0.00340

$8.31 $0.00339

$8.30 $0.00338

$8.29 $0.00337

$8.29 $0.00337

Energy Charge
(All kilowatt-hours, per kilowatthour)

Reactive Charge
Reactive kilovolt-ampere hours, per billing reactive kilovoltampere hour

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

Transition Charge All kilowatt-hours, per kilowatt-hour Bill Issuance Charge (per bill):

See Transition Charge Statement $0.73, as described in General Information Section 16.J

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 130 Revision: 11 Superseding Revision: 10

SERVICE CLASSIFICATION NO. 2 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (Cont'd.) NYSEG will provide Delivery and Supply Service for the Non-Retail Access choices. 2. Reserved for Future Use

Issued in compliance with order in Case No. 09-E-0227 dated 09/28/09.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 131 New York State Electric & Gas Corporation Revision: 21 Initial Effective Date: September 26, 2010 Superseding Revision: 20 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 2 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (Cont'd.) 3. NYSEG Supply Service (NSS) This Non-Retail Access choice includes fixed charges for NYSEG delivery service, a Transition Charge (NonBypassable Charge [NBC]), a commodity charge for electricity supplied by NYSEG which fluctuates with the market price of electricity, and a Merchant Function Charge. RATE: (Per Meter, Per Month)

Effective Date 09/26/2010 Customer Charge Meter Ownership Charge Meter Service Charge Meter Data Service Charge
(Meter Reading)

09/01/2011 $3.87 $1.68 $8.48 $2.08

09/01/2012 $5.37 $1.68 $8.48 $2.08

09/01/2013 $5.37 $1.68 $8.48 $2.08

09/01/2014 $5.37 $1.68 $8.48 $2.08

09/01/2015 $5.37 $1.68 $8.48 $2.08

09/01/2016 $5.37 $1.68 $8.48 $2.08

$2.84 $1.68 $8.48 $2.08

Demand Charge
(All kilowatts, per kilowatt)

$8.08 $0.00311

$8.13 $0.00344

$8.32 $0.00340

$8.31 $0.00339

$8.30 $0.00338

$8.29 $0.00337

$8.29 $0.00337

Energy Charge
(All kilowatt-hours, per kilowatthour)

Reactive Charge
Reactive kilovolt-ampere hours, per billing reactive kilovoltampere hour

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

Transition Charge All kilowatt-hours, per kilowatt-hour

See Transition Charge Statement

Commodity Service The charge for Electric Power Supply provided by NYSEG will fluctuate each month as further described in General Information Section 25.I.C., Calculation of the Commodity Charge. Merchant Function Charge All kilowatt-hours, per kilowatt-hour Bill Issuance Charge (per bill):

See Merchant Function Charge Statement $0.73, as described in General Information Section 16.J.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010 .

Leaf No. 131.1 Revision: 4 Superseding Revision: 3

SERVICE CLASSIFICATION NO. 2 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (Cont'd.)
4. Hourly Pricing – Mandatory and Voluntary Hourly Pricing is voluntary for any customer taking service under Service Classification No. 2 except as follows: Effective January 1, 2010, Hourly Pricing is mandatory for any customer taking service under Service Classification No. 2 with a billed demand greater than or equal to 300 kW in any two months within the twelve months beginning prior to September 1, 2009, including customers that received an economic incentive or NYPA allocation on or after January 1, 2007. A customer taking service under Hourly Pricing will remain subject to this provision until their monthly metered demand has been less than 300 kW for 12 consecutive months. Customers served under this provision must select ESCO Supply Service (ESS) or NYSEG Hourly Day-Ahead Market Pricing (“Hourly Pricing”) described within this Service Classification. Customers that received an economic incentive or NYPA allocation beginning on or prior to December 31, 2006 and does not have a restriction for the Supply Service Option may opt to participate in Hourly Pricing. If such customer opts to participate in Hourly Pricing, the customer must choose the same Supply Service Option for its incentive, non-incentive and any future load. DELIVERY CHARGES: The delivery charges set forth in this Service Classification for the NSS shall apply to a customer taking service under Hourly Pricing. A customer that qualifies for the Industrial/High Load Factor Special Provision will pay the delivery charges as set forth in Special Provision (l). HOURLY METERING CHARGE: Hourly priced customers are required to pay an incremental meter charge of $7.07 per month, regardless of the Electric Supply Pricing Option chosen. Customers that have paid for their own meter are exempt from this charge. NYSEG Hourly Day-Ahead Market Pricing Option (“Hourly Pricing”) This Non-Retail Access choice includes fixed charges for NYSEG delivery service, a Transition Charge (Non-Bypassable Charge [NBC] as described above and in further detail in General Information Section 25.I.B.), the Merchant Function Charge, and a commodity charge for electricity supply that fluctuates hourly with the market price of electricity including losses, unaccounted for energy, capacity, and capacity reserves, as further described herein. Electricity supply is provided by NYSEG.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 132 Revision: 7 Superseding Revision: 6

SERVICE CLASSIFICATION NO. 2 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (Cont'd.)
4. Hourly Pricing – Mandatory and Voluntary (Con’t.) NYSEG Hourly Day-Ahead Market Pricing Option (“Hourly Pricing”) (Cont’d.) Electricity Supply Charge: All kilowatthours, per kilowatthour Customers served under this provision will be charged for the energy component of supply based on their hourly metered usage and the hourly supply cost. The electricity supply charge is equal to the sum of the hourly metered usage multiplied by the New York Independent System Operator (NYISO) Day-Ahead Market (DAM) Location Based Marginal Price (LBMP) for the Zone in which the customer is electrically connected, adjusted for system losses (Distribution Loss Factor of 1.0728), ancillary services, NTAC, and a Supply Adjustment Charge. Capacity charges will also be based on interval meter data. The DAM LBMP prices will be the initial published DAM LBMP prices acquired by the Company. The customer's bill will not be recalculated if such prices are modified by the NYISO at a later date.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 132.1 Revision: 4 Superseding Revision: 3

SERVICE CLASSIFICATION NO. 2 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (Cont'd.) 4. Hourly Pricing – Mandatory and Voluntary (Cont'd.) NYSEG Hourly Day-Ahead Market Pricing Option (“Hourly Pricing”) (Cont’d.) Electricity Capacity Charge: per month The capacity and capacity reserves are specific to the customer. When hourly data is not available the appropriate service class profile will be used to determine the customer’s capacity responsibility. A new capacity responsibility amount will be established for each customer each April. Customers new to Hourly Pricing that begin the service prior to April will be assigned their capacity responsibility based on their service class profile until the first April where the required hourly data is available. Capacity Charge = UCAP Charge + Demand Curve Reserve Charge UCAP Charge = ((UCAPreq * Lc) * (1 + Reservereq)* Pricemonthlyauc) UCAPreq = The customer specific demand that occurred at the time of the New York system peak of the prior year. When the customer specific information is not available the appropriate service class profile information will be used. Lc = Capacity Loss Factor of 1.0738 Reservereq = Additional reserve requirement as required by NYISO. Pricemonthlyauc = Monthly NYISO auction price.

Demand Curve Reserve Charge = ((UCAPreq * Lc) * DemandCurveReservereq)* Pricespotauc) UCAPreq = Described above. Lc = See above. DemandCurveReservereq = Allocation of additional capacity requirement as required by the NYISO’s demand curve. Pricespotauc = Monthly NYISO auction price.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2008

Leaf No. 132.2 Revision: 0 Superseding Revision:

SERVICE CLASSIFICATION NO. 2 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (Cont'd.) 4. Hourly Pricing – Mandatory and Voluntary (Cont'd.)

DETERMINATION OF DEMAND: Customers taking service under this Special Provision will pay a demand charge calculated as described in Service Classification No. 7, Determination of Demand section. METERING AND COMMUNICATION REQUIREMENTS: 1. All customers subject to this special provision are required to have interval metering and remote meter reading capability. Such customers will be responsible for the following: a. the costs of providing remote meter reading capability through dedicated telecommunications to and from the meter; and b. the dedicated telecommunications shall be a land-line connection unless the customer is directed by the Company that a cellular connection is required, and c. all costs associated with the installation, operation and maintenance of the telecommunications line, including but not limited to, all telecommunications service bills. If the Company is unable to read the meter through a customer provided connection, and NYSEG has determined that the problem is not caused by the Company's equipment, the customer shall be responsible for resolution of the problem. The customer shall also be responsible for reimbursement of NYSEG expenses incurred for visits to the meter location to ascertain the cause of the problem, including reimbursing the Company for any expenses the Company incurs, such as, but not limited to, the cost to provide a manual meter read.

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 133 New York State Electric & Gas Corporation Revision: 22 Initial Effective Date: September 26, 2010 Superseding Revision: 20 Issued in compliance with Order in Case 09-E-0715, dated September 21, 2010 SERVICE CLASSIFICATION NO. 2 (Continued) RATE CHOICES AVAILABLE TO CUSTOMERS: (CONT'D.) MERCHANT FUNCTION CHARGE: The Merchant Function Charge reflects the administrative costs of obtaining electricity supply. Customers whose electricity is supplied by an ESCO are not charged for this service. MINIMUM CHARGE: The minimum charge for service under this Service Classification is the Customer Charge plus the Bill Issuance Charge, if applicable, as listed above, or as otherwise stated in the applicable special provisions. The minimum charge for customers who choose to take all or part of their back-up or maintenance service under this service classification rather than under Special Provision (d) of NYSEG's Service Classification No. 11 is described in the "DETERMINATION OF DEMAND" section. SURCHARGE TO COLLECT SYSTEM BENEFITS CHARGE ("SBC"): A surcharge will be added to each customer bill for service under this Service Classification to collect the System Benefits Charge (as explained in this Schedule, General Information Section 4). See SBC Statement. RENEWABLE PORTFOLIO STANDARD CHARGE (“RPS”): A surcharge will be added to each customer bill for service under this Service Classification to collect the Renewable Portfolio Standard (as explained in this Schedule, General Information Section 5). See RPS Statement. SURCHARGE TO COLLECT TEMPORARY STATE ASSESSMENT (“TSAS”): A surcharge will be added to each customer bill for service under this Service Classification to collect the Temporary State Assessment (as explained in this Schedule, General Information Section 28). See TSAS Statement. COMPETITIVE METERING OPTION: Qualified Customers who select the Competitive Metering Option must comply with the requirements specified in PSC 119 - Electricity and specified in General Information Section 14 of this Schedule, and will not be charged the Meter Ownership, Meter Services, and Meter Data Service Charges. METER OWNED BY CUSTOMER, INSTALLED AND MAINTAINED BY THE CORPORATION Customers electing to own their own meters, as described in Section 3.A.2 of PSC 119 - Electricity, will not be charged the Meter Ownership Charge. This provision is separate and distinct from Competitive Metering.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 134 New York State Electric and Gas Corporation Revision: 7 Initial Effective Date: September 26, 2010 Superseding Revision: 6 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010
SERVICE CLASSIFICATION NO. 2 (Continued) REVENUE DECOUPLING MECHANISM (“RDM”): A customer taking service under this Service Classification shall be subject to a Revenue Decoupling Mechanism adjustment as explained in this Schedule, General Information Section 7. See RDM Statement INCREASE IN RATES AND CHARGES: The rates and charges under this Service Classification, including minimum charges, will be increased by a surcharge pursuant to section 6 of PSC No. 120 to reflect the tax rates applicable within the municipality where the customer takes service. DETERMINATION OF DEMAND: The billing demand will be the metered demand, which is the highest average kilowatts used in a thirty-minute interval during the month. (For customers whose meters are read bi-monthly, the metered demand will be 95% of the metered demand.) Customers who choose to take all or part of their back-up or maintenance service under this service classification rather than under Special Provision (d) of NYSEG's Service Classification No. 11 will pay a minimum demand charge as described in NYSEG's Service Classification No. 11. Customers will pay a minimum demand charge related to generation, ancillary, and transmission costs. The minimum demand charge is based on a rate per kW of the contract demand and is accumulated over a 12-month period. The accumulated contract demand charge component will be compared to the accumulated demand charge in this service classification. If the contract demand charge is greater than the demand charge in this service classification, then the customer will only pay the contract demand charge in that month. If it is less than the demand charge in this service classification, then the customer will pay that difference in that month. DETERMINATION OF REACTIVE KILOVOLT-AMPERE HOURS: Whenever the customer’s metered demand is 200 kW or more for two billing periods in any two of the previous twelve (12) months, the reactive kilovolt-ampere hours shall thereafter be metered. The billing reactive kilovolt-ampere hours will be the reactive kilovolt-ampere hours in excess of one-fourth of the metered kilowatt-hours. TERMS OF PAYMENT: All bills are rendered at the above "unit prices" and that amount is due on bills paid on or before the "past due" date indicated on the bill. A late payment charge at the rate of one and one-half percent (1 1/2%) per month will be billed on all amounts not paid by that date. (Further details in Section 4 of P.S.C. No. 119 - Electricity or superseding issues thereof.) TERM: Single Phase Service: One month and thereafter until terminated by 48 hours' written notice. Three Phase (or Two Phase) Service: One year and thereafter until terminated by 48 hours' written notice.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: September 26, 2010 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010

Leaf No. 135 Revision: 15 Superseding Revision: 12

SERVICE CLASSIFICATION NO. 2 (Continued) SPECIAL PROVISIONS: (a) Space Heating Service: (Service under this provision will no longer be available to new customers after November 1, 1977.) Any customer using general service under this Service Classification and also using electricity as the sole source of space heating in a premises or segregated portion of a premises may, upon written application to the Corporation, have the energy used for such space heating, as well as air conditioning and water heating for such electrically heated space, separately metered. The separately metered space heating service will be charged under the same rate choice the customer selected for their non-heating service under this Service Classification. The per kilowatt-hour rate for such separately metered space heating service under the selected rate choice is as shown below. There is a separate minimum charge. A complete description of these rate choices appears previously in this Service Classification.
Effective Date 09/26/2010 Energy Charge
(All kilowatt-hours, per kilowatt-hour)

09/01/2011 $0.01124

09/01/2012 $0.01112

$0.01017

Customers are responsible for a separate per kilowatt-hour Transition Charge (Non-Bypassable Charge) and any Commodity and Merchant Function Charges at the same rate associated with the selected rate choice for their non-heating service. The minimum charge is the Demand Charge based on the current month's actual billing demand. Service under this Special Provision (a) will be supplied on an annual basis for as long as non-heating service is supplied under this Service Classification.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 136 Revision: 7 Superseding Revision: 6

SERVICE CLASSIFICATION NO. 2 (Continued)
SPECIAL PROVISIONS: (Cont'd) (b) Fluctuating Loads: When service is rendered solely for equipment having a highly fluctuating or large instantaneous demand, such as Xrays, welders, etc., and a separate or larger transformer for such service is required, the minimum monthly charge will not be less than 50c per KVA of such additional transformer capacity. / (c ) Billing Duration: Billing for service under this Service Classification shall continue for at least 11 months after the establishment of a demand in excess of 5 kW unless service is terminated for not less than one year under the terms of the "Cessation of Service" section of P.S.C. No. 119 or superseding issues thereof. (d) Budget Billing: Customers may, by signing an application, be billed monthly in accordance with the plan set forth in Section 4-O of P.S.C. No. 119 - Electricity or superseding issues thereof. (e) Submetering: Submetering may be available according to certain conditions as explained in the general information leaves of this schedule, Section 2. Submetering. (f) Economic Incentives: Customer load supplied by the New York Power Authority (NYPA) is not eligible to receive an economic incentive. (1) (2) Reserved for Future Use Economic Development Incentive: As provided in General Information Section 8, this provision is no longer available to additional customers on or after January 1, 2007.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 137 Revision: 5 Superseding Revision: 4

SERVICE CLASSIFICATION NO. 2 (Continued) SPECIAL PROVISIONS: (Cont'd.) (f) Economic Incentives: (Cont'd.) (2) Economic Development Incentive: (Cont'd.) Customers who qualify, under the Economic Development Incentive (EDI) in Section 8 of the General Information section of this Schedule, to receive an incentive for load qualified on or after July 1, 2003 may select one of the following rate options, as specified in this Service Classification and Section 25, Supply Service Options, for all of their load: 1) NYSEG Supply Service (NSS), 2) ESCO Supply Service (ESS), or 3) Hourly Pricing. Such customers will receive the incentive for a term of 60 months. Such customers will be exempt from paying the Transition Charge. If it is determined that a bill calculated with the incentive exceeds a bill calculated under the otherwise applicable standard service classification rates, the customer will pay the lower of the two bills. (3) Economic Development Zone Incentive: Customers who qualify, under the Economic Development Zone Incentive (EDZI) in Section 9 of the General Information section of this Schedule, to receive an incentive for load qualified prior to July 1, 2003 shall take service under the NSS or ESS rate, as specified in this Service Classification and Section 25, Supply Service Options, for all of their load. Such customers will have their service bills reduced, for a term of ten (10) years beginning on the date of the qualifying load installation and operation (unless the customer's initial zone certification(s) becomes invalid), by $0.0225 per kilowatt-hour for all qualified kilowatt-hours used thereunder.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: September 26, 2010
Issued in compliance with Order in Case No. 09-E-0715 dated September 21, 2010.

Leaf No. 138 Revision: 6 Superseding Revision: 5

SERVICE CLASSIFICATION NO. 2 (Continued)
SPECIAL PROVISIONS: (Cont'd) (f) Economic Incentives: (Cont'd) (3) Economic Development Zone Incentive: (Cont'd.)

Customers who qualify, under the Economic Development Zone Incentive (EDZI) in Section 9 of the General Information section of this Schedule, to receive an incentive for load qualified on or after July 1, 2003 may select one of the following rate options, as specified in this Service Classification and Section 25, Supply Service Options, for all of their load: 1) NYSEG Supply Service (NSS), 2) ESCO Supply Service (ESS) or 3) Hourly Pricing. Such customers will receive the incentive for a term of ten (10) years following initial zone certification, beginning with the eligibility date on the zone certificate (unless the customer's initial zone certification(s) becomes invalid).

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: September 26, 2010
Issued in compliance with Order in Case No. 09-E-0715 dated September 21, 2010.

Leaf No. 139 Revision: 20 Superseding Revision: 19

SERVICE CLASSIFICATION NO. 2 (Continued) SPECIAL PROVISIONS: (Cont'd) (f) Economic Incentives: (Cont'd) (3) Economic Development Zone Incentive: (Cont'd.) For a customer qualifying for the Economic Development Zone Incentive will be subject to the otherwise applicable standard service classification rates, including the Transition Charge, Commodity, Merchant Function and Bill Issuance Charges, if applicable, System Benefits Charge, Renewable Portfolio Standard, Temporary State Assessment Surcharge, and Revenue Decoupling Mechanism in accordance with the standard NSS, ESS, or Hourly Pricing rates for this Service Classification. Hourly Pricing customers will also be billed the Hourly Metering Charge and Electric Capacity Charge in accordance with the Hourly Pricing rates for this Service Classification. The qualified load receiving the incentive will be billed at the following applicable NSS, ESS, or Hourly Pricing delivery rates:
Effective Date 09/26/2010 Delivery Charges Customer Charge Meter Ownership Charge Meter Service Charge Meter Data Service Charge
(Meter Reading)

09/01/2011

09/01/2012

$ 2.84 $ 1.68 $ 8.48 $ 2.08 $ 8.08

$ 3.87 $ 1.68 $ 8.48 $ 2.08

$5.37 $ 1.68 $ 8.48 $ 2.08

Demand Charge
(All kilowatts, per kilowatt)

$8.13

$8.32

Energy Charge
(All kilowatt-hours, per kilowatthour)

$0.00311

$0.00344

$0.00340

Reactive Charge
Reactive kilovolt-ampere hours, per billing reactive kilovolt-ampere hour

$0.00078

$0.00078

$0.00078

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 140 Revision: 7 Superseding Revision: 6

SERVICE CLASSIFICATION NO. 2 (Continued) SPECIAL PROVISIONS: (Cont'd) (f) Economic Incentives: (Cont'd) (4) Economic Development Power: Customers who qualify for the special Economic Development Power rate provision pursuant to Section 10 of the General Information Section of this Schedule, will have such power billed in accordance with the Special Provision therein. The customer's power requirements in excess of the Economic Development Power will be billed at SC No. 7 rates applicable to the customer's voltage level.

Issued in compliance with order in Case No. 09-E-0227 dated 09/28/09.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 141 Revision: 7 Superseding Revision: 6

SERVICE CLASSIFICATION NO. 2 (Continued)
SPECIAL PROVISIONS: (Cont'd) (f) Economic Incentives: (Cont'd) (5) (6) Reserved for Future Use Incubator Development Incentive ("IDI"): As provided in General Information Section 13, this provision is no longer available to additional customers on or after January 1, 2007. Existing customers will be permitted to transition to the Incremental Load Incentive (ILI) as described in Special Provision (f).(8). Incremental Load Incentive and General Information Section 19. Customers who qualify under the Incubator Development Incentive (IDI) in Section 13 of the General Information section of this Schedule prior to July 1, 2003 shall take service under the applicable NSS or ESS rate, as specified in this Service Classification and Section 25, Supply Service Options, for all of their load.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 142 New York State Electric & Gas Corporation Revision: 9 Initial Effective Date: September 26, 2010 Superseding Revision: 7 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 2 (Continued)
SPECIAL PROVISIONS: (Cont'd) (f) Economic Incentives: (Cont'd) (7) Reserved for Future Use

(8) Incremental Load Incentive (“ILI”) Customers who qualify under the Incremental Load Incentive (ILI) in Section 19 of the General Information section may select one of the following rate options, as specified in this Service Classification and Section 25, Supply Service Options, for such qualified incentive load: 1) NYSEG Supply Service (NSS), or 2) ESCO Supply Service (ESS), or 3) Hourly Pricing. For a customer qualifying for the Incremental Load Incentive (ILI), all customers will be subject to the otherwise applicable standard service classification rates, including the Transition Charge, Commodity, and Merchant Function and Bill Issuance Charges, if applicable, System Benefits Charge, Renewable Portfolio Standard, Temporary State Assessment Surcharge, and Revenue Decoupling Mechanism in accordance with the standard NSS, ESS, or Hourly Pricing rates for this Service Classification. Hourly Pricing customers will also be billed the Hourly Metering Charge and Electric Capacity Charge in accordance with the Hourly Pricing rates for this Service Classification. The qualified load receiving the incentive will be billed at the following applicable NSS, ESS, or Hourly Pricing delivery rates:
Effective Date 09/26/2010 Delivery Charges Customer Charge Meter Ownership Charge Meter Service Charge Meter Data Service Charge
(Meter Reading)

09/01/2011

09/01/2012

$ 2.84 $ 1.68 $ 8.48 $ 2.08 $ 8.08

$ 3.87 $ 1.68 $ 8.48 $ 2.08

$5.37 $ 1.68 $ 8.48 $ 2.08

Demand Charge
(All kilowatts, per kilowatt)

$8.13

$8.32

Energy Charge
(All kilowatt-hours, per kilowatthour)

$0.00311

$0.00344

$0.00340

Reactive Charge
Reactive kilovolt-ampere hours, per billing reactive kilovolt-ampere hour

$0.00078

$0.00078

$0.00078

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2007

Leaf No. 143 Revision: 2 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 2 (Continued) SPECIAL PROVISIONS: (Cont'd)
(f) Economic Incentives: (Cont'd)

(9)

Incremental Load Incentive (“ILI”) (Cont’d.) Customers transitioning from the Incubator Development Incentive (IDI) to ILI will be phased-in as follows: Per kilowatthour, for all qualified kilowatthours Effective Date 01/01/2007 $0.0250 01/01/2008 $0.020 01/01/2009 $0.015 01/01/2010 $0.010 01/01/2011 $0.005

At any time during the phase-in, an IDI customer may make a one-time election to receive the ILI discount on the qualified kilowatthours instead of the phase-in. Once a customer had made this election, they will not be allowed to return to the phase-in. (g) Complementary E.T.S. Service: This service is available for customers with common areas pertaining to individually metered multiple dwelling units taking individually metered residential service under this Schedule and utilizing Electric Thermal Storage (E.T.S.) installations as the principal space-conditioning medium. This service will be billed under Service Classification No. 9 of this Schedule. However, the 5 kW metered demand and 2000 kWh monthly use limitations from the "Applicable to the Use of Service For" section will be waived, as long as the total metered demand requirements will not exceed 25 kW, in order to allow annual complementary E.T.S. space-conditioning and other electric service in the common areas of such multiple dwellings. (h) Time-Of-Use Service Option: Non-residential customers who qualify for service under S.C. No. 2 may voluntarily opt for Time-of-Use service under Service Classification No. 7 (Secondary Service). A customer who chooses to transfer to Service Classification No. 7 must initially remain on that rate for a minimum of 6 months prior to becoming eligible for a one-time return to Service Classification No. 2. This Special Provision is not available to Service Classification No. 2 customers, effective December 3, 2002.

Issued in compliance with order in Case No. 05-E-1222 dated 08/23/06.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2007

Leaf No. 144 Revision: 3 Superseding Revision: 1

SERVICE CLASSIFICATION NO. 2 (Continued) SPECIAL PROVISIONS: (Cont'd) (i) Agricultural Customers Time-of-Use Service Option: Any Agricultural customer producing a "farm product" as defined in Subdivision 5 of Section 2 of the Agriculture and Markets Law may choose to take their entire service under Service Classification No. 7 with Time-of-Use metering. (j) (k) RESERVED FOR FUTURE USE RESERVED FOR FUTURE USE

Issued in compliance with order in Case No. 05-E-1222 dated 08/23/06.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2007

Leaf No. 144.1 Revision: 2 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 2 (Continued) SPECIAL PROVISIONS: (Cont'd) (k) Reserved for Future Use

Issued in compliance with order in Case No. 05-E-1222 dated 08/23/06.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2008

Leaf No. 145 Revision: 2 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 2 (Continued) SPECIAL PROVISIONS: (Cont'd) (l) Industrial/High Load Factor ("I/HLF") Rate Provision: (1) Availability: Available to a customer's account that meets usage eligibility as defined in (2) or (3) of this section. Customers who are taking service under NYSEG's Economic Development Incentive, Economic Development Zone Incentive, New York Power Authority (NYPA) programs (Expansion Power, Economic Development Power, Replacement Power, High Load Manufacturer Power, Power for Jobs and Preservation Power), or S.C. 14 may take service under this rate provision, only for that portion of their load served at NYSEG's standard tariff rate, provided that the non-discounted load meets the eligibility requirements of this special provision. Allocation of billing units (kW, kWh, rkvah) for partial load is explained in (4) of this section. Recipients of other NYSEG incentive rates, applicable to their entire load, may qualify for this special provision by relinquishing eligibility under the incentive, provided that they meet the eligibility requirements of this special provision. Any customer taking service under the Economic Revitalization Incentive and choosing instead to take service under this Rate Provision, must have met or agrees to continue to meet its Economic Revitalization commitments. (2) Eligibility: (i) Industrial Rate Provision: Not applicable to customers in this service classification. Customers with average annual demands in excess of 500 kW, are served under S.C. No. 7.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003

Leaf No. 146 Revision: 0 Superseding Revision:

SERVICE CLASSIFICATION NO. 2 (Continued) SPECIAL PROVISIONS: (Cont'd) (l) Industrial/High Load Factor Rate Provision (Cont'd.): (ii) High Load Factor Rate Provision: Applicable to an existing customer's account having an annual load factor of 68.0% or greater (approximately 500 hours' average use of kW demand per month). Also applicable to a new customer's account with an estimated annual load factor of 68.0% or greater. Annual load factor for this provision is calculated as follows: A/(D*H) A = Annual kWh. For existing customers this will be the actual total energy usage billed during the most recent 12 consecutive months. For new customers or customers with incomplete history, the annual usage will be estimated by the Corporation from engineering and operating estimates to fit within the time period. D = Maximum demand. For existing customers this will be the highest billed demand during the most recent 12 consecutive months. For new customers or customers with incomplete history, the demand will be estimated by the Corporation from engineering and operating estimates to fit within the time period. H = Number of total hours in the annual billing period. (3) Rate Qualification Review: Each account will be reviewed annually for continued qualification, based on the load factor during the previous year. Such review shall occur 12 months after the initiation of this Special Provision, and shall be repeated each year thereafter. To maintain qualification for this rate, a customer account's annual load factor must be 68.0% or greater. (4) Allocation of Billing Units for Partial Load: Billing units (kW, kWh, rkvah) will be allocated between the Industrial/High Load Factor and Economic Incentive portions of the customer's bill based on the following formula: B T EKWH ' EKW NKW =Billing kW =Total kWh = Incented kWh = Incented kW = Non-incented kW

(EKWH / T) x B = EKW B - EKW = NKW ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 147 New York State Electric & Gas Corporation Revision: 13 Initial Effective Date: September 26, 2010 Superseding Revision: 12 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 2 (Continued) SPECIAL PROVISIONS: (Cont'd.) (l) Industrial/High Load Factor Rate Provision (Cont'd.): (4) Rate for Qualified High Load Factor Service A complete description of these Supply Service Options appears previously in this Service Classification. (a) ESCO Supply Service (ESS) RATE: (Per Meter/Per Month) Rates under the High Load Factor Special Provision are as follows:
Delivery Service Customer Charge Meter Ownership Charge Meter Service Charge Meter Data Service Charge
(Meter Reading)

09/26/2010 $ 2.84 $ 1.68 $ 8.48 $ 2.08

09/01/2011 $ 3.87 $ 1.68 $ 8.48 $ 2.08

09/01/2012 $ 5.37 $ 1.68 $ 8.48 $ 2.08

09/01/2013 $5.37 $ 1.68 $ 8.48 $ 2.08

09/01/2014 $5.37 $ 1.68 $ 8.48 $ 2.08

09/01/2015 $5.37 $ 1.68 $ 8.48 $ 2.08

09/01/2016 $5.37 $ 1.68 $ 8.48 $ 2.08

Demand Charge
(All kilowatts, per kilowatt)

$ 3.11

$ 4.12

$ 4.88

$ 5.73

$ 6.58

$ 7.43

$ 8.29

Energy Charge
(All kilowatt-hours, per kilowatt-hour)

$0.00091 $0.00078

$0.00115 $0.00078

$0.00187 $0.00078

$0.00224 $0.00078

$0.00261 $0.00078

$0.00298 $0.00078

$0.00337 $0.00078

Reactive Charge
Reactive kilovolt-ampere hours, per billing reactive kilovoltampere hour

Transition Charge All kilowatt-hours, per kilowatt-hour Bill Issuance Charge (per bill):

See Transition Charge Statement $0.73, as described in General Information Section 16.J

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 148 Revision: 19 Superseding Revision: 18

SERVICE CLASSIFICATION NO. 2 (Continued) SPECIAL PROVISIONS: (Cont'd.) (l) Industrial/High Load Factor Rate Provision (Cont'd.): (4) Rate for Qualified High Load Factor Service (Cont'd.) (b) Reserved for Future Use

Issued in compliance with order in Case No. 09-E-0227 dated 09/28/09.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2008

Leaf No. 148.1 Revision: 2 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 2 (Continued) SPECIAL PROVISIONS: (Cont'd.) (l) Industrial/High Load Factor Rate Provision (Cont'd.): (4) Rate for Qualified High Load Factor Service (Cont'd.) Reserved for Future use

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 149 New York State Electric & Gas Corporation Revision: 12 Initial Effective Date: September 26, 2010 Superseding Revision: 11 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 2 (Continued) SPECIAL PROVISIONS: (Cont'd.) (l) Industrial/High Load Factor Rate Provision (Cont'd.): (4) Rate for Qualified High Load Factor Service (Cont'd.) (c ) NYSEG Supply Service (NSS) Rates under the High Load Factor Special Provision are as follows:
Effective Date Delivery Charges Customer Charge Meter Ownership Charge Meter Service Charge Meter Data Service Charge
(Meter Reading)

09/26/2010 $ 2.84 $ 1.68 $ 8.48 $ 2.08

09/01/2011 $ 3.87 $ 1.68 $ 8.48 $ 2.08

09/01/2012 $ 5.37 $ 1.68 $ 8.48 $ 2.08

09/01/2013 $5.37 $ 1.68 $ 8.48 $ 2.08

09/01/2014 $5.37 $ 1.68 $ 8.48 $ 2.08

09/01/2015 $5.37 $ 1.68 $ 8.48 $ 2.08

09/01/2016 $5.37 $ 1.68 $ 8.48 $ 2.08

Demand Charge
(All kilowatts, per kilowatt)

$ 3.11

$ 4.12

$ 4.88

$ 5.73

$ 6.58

$ 7.43

$ 8.29

Energy Charge
(All kilowatt-hours, per kilowatt-hour)

$0.00091 $0.00078

$0.00115 $0.00078

$0.00187 $0.00078

$0.00224 $0.00078

$0.00261 $0.00078

$0.00298 $0.00078

$0.00337 $0.00078

Reactive Charge
Reactive kilovolt-ampere hours, per billing reactive kilovoltampere hour

Transition Charge All kilowatt-hours, per kilowatt-hour

See Transition Charge Statement

Commodity Service The charge for Electric Power Supply provided by NYSEG will fluctuate each month as further described in General Information Section 25.I.C., Calculation of the Commodity Charge. Merchant Function Charge All kilowatt-hours, per kilowatt-hour Bill Issuance Charge (per bill):

See Merchant Function Charge Statement $0.73, as described in General Information Section 16.J.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: January 1, 2008

Leaf No. 150 Revision: 4 Superseding Revision: 2

SERVICE CLASSIFICATION NO. 2 (Continued) SPECIAL PROVISIONS: (Cont'd.) (m) Reserved for Future Use

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: January 1, 2008

Leaf No. 151 Revision: 4 Superseding Revision: 2

SERVICE CLASSIFICATION NO. 2 (Continued) SPECIAL PROVISIONS: (Cont'd.) (m) Reserved for Future Use

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: January 1, 2008

Leaf No. 152 Revision: 2 Superseding Revision: 1

SERVICE CLASSIFICATION NO. 2 (Continued)
SPECIAL PROVISIONS: (Cont'd.)
(m) Reserved for Future Use

(n) Reserved for Future Use (o) Emergency Demand Response Program ("EDRP") The EDRP seeks to provide customers with an economic incentive to respond to Emergency Operating Conditions as identified by the NYISO. EDRP can provide the NYISO, through the Company, with the ability to request voluntary load curtailment or replacement by participating customers for electric usage normally supplied and delivered by the Company. Customers who are qualified under EDRP in Section 20 of the General Information section of this Schedule may participate in the NYSEG EDRP as set forth therein.

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: July 1, 2009

Leaf No. 153 Revision: 3 Superseding Revision: 2

SERVICE CLASSIFICATION NO. 2 (Continued) SPECIAL PROVISIONS: (Cont'd.) m. C.A.$.H.BACK Special Provision The Company will provide a voluntary program for load normally supplied and delivered by NYSEG, for eligible customers to curtail load. NYSEG's program, entitled C.A.$.H.BACK, implements the NYISO's day-ahead economic load-curtailment program. Under this program, a customer agrees to curtail load when their bid is submitted and accepted by the NYISO. Customers who are qualified under C.A.$.H.BACK in Section 21 of the General Information section of this Schedule may participate in the NYSEG C.A.$.H.BACK Program as set forth therein. n. Farm Waste Electric Generating System Option: This option is for a customer qualifying for the Farm Waste Electric Generating System Option pursuant to General Information Section 22 of this Schedule, and taking service under SC 2. o. Wind Electric Service Option: This option is for a customer qualifying for the Wind Electric Service Option pursuant to General Information Section 23 of this Schedule and taking service under SC 2.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: July 1, 2009

Leaf No. 153.1 Revision: 2 Superseding Revision: 1

SERVICE CLASSIFICATION NO. 2 (Continued) SPECIAL PROVISIONS: (Cont'd.) p. Solar Non-Residential Electric Service Option: This option is for a customer qualifying for the Solar Non-Residential Generating Service Option pursuant to General Information Section 27 of this Schedule and taking service under SC 2. q. Electric Hybrid Generating System Option: This option is for a customer qualifying for the Electric Hybrid Generating System Option pursuant to General Information Section 24 of this Schedule and taking service under SC 2.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010 SERVICE CLASSIFICATION NO. 3
APPLICABLE TO THE USE OF SERVICE FOR:

Leaf No. 154 Revision: 6 Superseding Revision: 5

Primary Service for any customer with a demand of 25 kilowatts or more but less than 500 kilowatts. CHARACTER OF SERVICE: Continuous - Alternating Current, 60 Cycle; Primary (Distribution) Service at 2,400, 4,160, 4,800, 7,200, 8,320, 12,000, 12,470, 13,200, 34,500 (Regulated) Volts; Subtransmission Service at 34,500 or 46,000 (Both Non-Regulated) Volts; or 34,500 (Regulated) Volts for "Grandfathered Customers" only; (see Special Provisions (a)); Single or Three Phase. (Characteristics depend upon available circuits and equipment.)

SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: Pursuant to General Information Section 25, Supply Service Options, customers served under this Service Classification will choose from different electric rate choices offered by the Company as described below. NYSEG will offer a Retail Access rate choice and Non-Retail Access rate choices. The Retail Access choice is the ESCO Supply Service (ESS). The Non-Retail Access choices include the NYSEG Supply Service (NSS) and Hourly Pricing. NYSEG will provide Delivery Service regardless of the customer’s supply service option. 1. ESCO Supply Service (ESS) This Retail Access choice includes fixed charges for NYSEG delivery service and a Transition Charge (NonBypassable Charge [NBC]). Supply service will be provided by an Energy Services Company (ESCO). Customers that elect ESS and receive a Consolidated Bill will not be subject to the Bill Issuance Charge.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 155 New York State Electric & Gas Corporation Revision: 13 Initial Effective Date: September 26, 2010 Superseding Revision: 12 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 3 (Continued)
SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.)

1. ESCO Supply Service (ESS) (cont'd.)
RATE: (Per Meter, Per Month)

PRIMARY VOLTAGE Delivery Charges Customer Charge Meter Ownership Charge Meter Service Charge Meter Data Service Charge
(Meter Reading)

Effective Date 09/26/2010 $50.59 $2.29 $11.58 09/01/2011 $53.91 $2.29 $11.58 09/01/2012 $55.41 $2.29 $11.58 09/01/2013 $55.41 $2.29 $11.58 09/01/2014 $55.41 $2.29 $11.58 09/01/2015 $55.41 $2.29 $11.58 09/01/2016 $55.41 $2.29 $11.58

$3.53 $4.59 $0.00364

$3.53 $4.62 $0.00384

$3.53 $4.87 $0.00356

$3.53 $4.86 $0.00355

$3.53 $4.85 $0.00354

$3.53 $4.85 $0.00353

$3.53 $4.85 $0.00352

Demand Charge
(All kilowatts, per kilowatt)

Energy Charge
(All kilowatt-hours, per kilowatt-hour)

Reactive Charge
Reactive kilovolt-ampere hours, per billing reactive kilovoltampere hour

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

Transition Charge All kilowatt-hours, per kilowatt-hour Bill Issuance Charge (per bill):

See Transition Charge Statement $0.73, as described in General Information Section 16.J.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 156 New York State Electric & Gas Corporation Revision: 12 Initial Effective Date: September 26, 2010 Superseding Revision: 11 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 3 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.) 1. ESCO Supply Service (ESS) (cont'd.)
RATE: (Per Meter, Per Month)

SUBTRANSMISSION VOLTAGE Delivery Charges Customer Charge Meter Ownership Charge Meter Service Charge Meter Data Service Charge
(Meter Reading)

Effective Date 09/26/2010 $212.09 $2.36 $11.91 $2.67 09/01/2011 $218.73 $2.36 $11.91 $2.67 09/01/2012 $225.57 $2.36 $11.91 $2.67

Demand Charge
(All kilowatts, per kilowatt)

$3.86 $0.00080 $0.00078

$4.00 $0.00053 $0.00078

$4.14 $0.00039 $0.00078

Energy Charge
(All kilowatt-hours, per kilowatt-hour)

Reactive Charge
Reactive kilovolt-ampere hours, per billing reactive kilovolt-ampere hour

Transition Charge All kilowatt-hours, per kilowatt-hour Bill Issuance Charge (per bill):

See Transition Charge Statement $0.73, as described in General Information Section 16.J.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 157 New York State Electric & Gas Corporation Revision: 21 Initial Effective Date: September 26, 2010 Superseding Revision: 20 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 3 (Continued)
SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.)

2. Reserved for Future Use 3. NYSEG Supply Service (NSS) This Non-Retail Access choice includes fixed charges for NYSEG delivery service, a Transition Charge (NonBypassable Charge [NBC]), a commodity charge for electricity supplied by NYSEG which fluctuates with the market price of electricity, and a Merchant Function Charge.
RATE: (Per Meter, Per Month)

PRIMARY VOLTAGE Delivery Charges Customer Charge Meter Ownership Charge Meter Service Charge Meter Data Service Charge
(Meter Reading)

Effective Date 09/26/2010 $50.59 $2.29 $11.58 09/01/2011 $53.91 $2.29 $11.58 09/01/2012 $55.41 $2.29 $11.58 09/01/2013 $55.41 $2.29 $11.58 09/01/2014 $55.41 $2.29 $11.58 09/01/2015 $55.41 $2.29 $11.58 09/01/2016 $55.41 $2.29 $11.58

$3.53 $4.59 $0.00364

$3.53 $4.62 $0.00384

$3.53 $4.87 $0.00356

$3.53 $4.86 $0.00355

$3.53 $4.85 $0.00354

$3.53 $4.85 $0.00353

$3.53 $4.85 $0.00352

Demand Charge
(All kilowatts, per kilowatt)

Energy Charge
(All kilowatt-hours, per kilowatt-hour)

Reactive Charge
Reactive kilovolt-ampere hours, per billing reactive kilovoltampere hour

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

Transition Charge All kilowatt-hours, per kilowatt-hour

See Transition Charge Statement

Commodity Service The charge for Electric Power Supply provided by NYSEG will fluctuate each month as further described in General Information Section 25.I.C., Calculation of the Commodity Charge. Merchant Function Charge All kilowatt-hours, per kilowatt-hour Bill Issuance Charge (per bill):

See Merchant Function Charge Statement $0.73, as described in General Information Section 16.J.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 158 New York State Electric & Gas Corporation Revision: 21 Initial Effective Date: September 26, 2010 Superseding Revision: 20 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010
SERVICE CLASSIFICATION NO. 3 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.)

3. NYSEG Supply Service (NSS) RATE: (Per Meter, Per Month)

SUBTRANSMISSION VOLTAGE Delivery Charges Customer Charge Meter Ownership Charge Meter Service Charge Meter Data Service Charge
(Meter Reading)

Effective Date 09/26/2010 $212.09 $2.36 $11.91 $2.67 09/01/2011 $218.73 $2.36 $11.91 $2.67 09/01/2012 $225.57 $2.36 $11.91 $2.67

Demand Charge
(All kilowatts, per kilowatt)

$3.86 $0.00080 $0.00078

$4.00 $0.00053 $0.00078

$4.14 $0.00039 $0.00078

Energy Charge
(All kilowatt-hours, per kilowatt-hour)

Reactive Charge
Reactive kilovolt-ampere hours, per billing reactive kilovolt-ampere hour

Transition Charge All kilowatt-hours, per kilowatt-hour

See Transition Charge Statement

Commodity Service The charge for Electric Power Supply provided by NYSEG will fluctuate each month as further described in General Information Section 25.I.C., Calculation of the Commodity Charge. Merchant Function Charge All kilowatt-hours, per kilowatt-hour Bill Issuance Charge (per bill):

See Merchant Function Charge Statement $0.73, as described in General Information Section 16.J.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 158.1 Revision: 3 Superseding Revision: 2

SERVICE CLASSIFICATION NO. 3 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.)

4.

Hourly Pricing – Mandatory and Voluntary
Hourly Pricing is voluntary for any customer taking service under Service Classification No. 3 except as follows: Effective January 1, 2010, Hourly Pricing is mandatory for any customer taking service under Service Classification No. 3 with a billed demand greater than or equal to 300 kW in any two months within the twelve months prior to September 1, 2009, including customers that received an economic incentive or NYPA allocation on or after January 1, 2007. A customer taking service under Hourly Pricing will remain subject to this provision until their monthly metered demand has been less than 300 kW for 12 consecutive months. Customers served under this provision must select the ESCO Supply Service (ESS) or NYSEG Hourly Day-Ahead Market Pricing (“Hourly Pricing”) described within this Service Classification. Customers that received an economic incentive or NYPA allocation beginning on or prior to December 31, 2006 and does not have a restriction for the Supply Service Option may opt to participate in Hourly Pricing. If such customer opts to participate in Hourly Pricing, the customer must choose the same Supply Service Option for its incentive, non-incentive and any future load.

DELIVERY CHARGES: The delivery charges set forth in this Service Classification for the NSS shall apply to a customer taking service under Hourly Pricing. A customer that qualifies for the Industrial/High Load Factor Special Provision will pay the delivery charges as set forth in Special Provision (h). HOURLY METERING CHARGE: Hourly priced customers are required to pay an incremental meter charge of $7.07 per month, regardless of the Electric Supply Pricing Option chosen. Customers that have paid for their own meter are exempt from this charge. NYSEG Hourly Day-Ahead Market Pricing Option (“Hourly Pricing”) This Non-Retail Access choice includes fixed charges for NYSEG delivery service, a Transition Charge (Non-Bypassable Charge [NBC] as described above and in further detail in General Information Section 25.I.B.), the Merchant Function Charge, and a commodity charge for electricity supply that fluctuates hourly with the market price of electricity including losses, unaccounted for energy, capacity, and capacity reserves, as further described herein. Electricity supply is provided by NYSEG.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 159 Revision: 6 Superseding Revision: 5

SERVICE CLASSIFICATION NO. 3 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.) 4. Hourly Pricing -– Mandatory and Voluntary (Cont’d.)
NYSEG Hourly Day-Ahead Market Pricing Option (“Hourly Pricing”) (Cont’d.) Electricity Supply Charge: All kilowatthours, per kilowatthour Customers served under this provision will be charged for the energy component of supply based on their hourly metered usage and the hourly supply cost. The electricity supply charge is equal to the sum of the hourly metered usage multiplied by the New York Independent System Operator (NYISO) Day-Ahead Market (DAM) Location Based Marginal Price (LBMP) for the Zone in which the customer is electrically connected, adjusted for system losses (in table below), ancillary services, NTAC, and a Supply Adjustment Charge. Capacity charges will also be based on interval meter data. The DAM LBMP prices will be the initial published DAM LBMP prices acquired by the Company. The customer's bill will not be recalculated if such prices are modified by the NYISO at a later date.

Distribution loss factor: Voltage Level Subtransmission Primary Service Classification 3S 3P Energy Loss Factor 1.0150 1.0377

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 159.1 Revision: 1 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 3 (Continued)
SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.)

4.

Hourly Pricing – Mandatory and Voluntary (Cont'd.)
NYSEG Hourly Day-Ahead Market Pricing Option (“Hourly Pricing”) (Cont’d.) Electricity Capacity Charge: per month The capacity and capacity reserves are specific to the customer. When hourly data is not available the appropriate service class profile will be used to determine the customer’s capacity responsibility. A new capacity responsibility amount will be established for each customer each April. Customers new to Hourly Pricing that begin the service prior to April will be assigned their capacity responsibility based on their service class profile until the first April where the required hourly data is available. Capacity Charge = UCAP Charge + Demand Curve Reserve Charge UCAP Charge = ((UCAPreq * Lc) * (1 + Reservereq)* Pricemonthlyauc) UCAPreq = The customer specific demand that occurred at the time of the New York system peak of the prior year. When the customer specific information is not available the appropriate service class profile information will be used. Lc = Capacity loss factor: Voltage Level Subtransmission Primary Service Classification 3S 3P Capacity Loss Factor 1.0200 1.0480

Reservereq = Additional reserve requirement as required by NYISO. Pricemonthlyauc = Monthly NYISO auction price.

Demand Curve Reserve Charge = ((UCAPreq * Lc) * DemandCurveReservereq)* Pricespotauc) UCAPreq = Described above. Lc = See table above. DemandCurveReservereq = Allocation of additional capacity requirement as required by the NYISO’s demand curve. Pricespotauc = Monthly NYISO auction price.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: January 1, 2008

Leaf No. 159.2 Revision: 0 Superseding Revision:

SERVICE CLASSIFICATION NO. 3 (Continued)
SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.)

4.

Hourly Pricing – Mandatory and Voluntary (Cont'd.)

DETERMINATION OF DEMAND: Customers taking service under this Special Provision will pay a demand charge calculated as described in Service Classification No. 7, Determination of Demand section. METERING AND COMMUNICATION REQUIREMENTS: 1. All customers subject to this special provision are required to have interval metering and remote meter reading capability. Such customers will be responsible for the following: a. the costs of providing remote meter reading capability through dedicated telecommunications to and from the meter; and b. the dedicated telecommunications shall be a land-line connection unless the customer is directed by the Company that a cellular connection is required, and c. all costs associated with the installation, operation and maintenance of the telecommunications line, including but not limited to, all telecommunications service bills. If the Company is unable to read the meter through a customer provided connection, and NYSEG has determined that the problem is not caused by the Company's equipment, the customer shall be responsible for resolution of the problem. The customer shall also be responsible for reimbursement of NYSEG expenses incurred for visits to the meter location to ascertain the cause of the problem, including reimbursing the Company for any expenses the Company incurs, such as, but not limited to, the cost to provide a manual meter read.

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 160 New York State Electric & Gas Corporation Revision: 17 Initial Effective Date: September 26, 2010 Superseding Revision: 15 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010
SERVICE CLASSIFICATION NO. 3 (Continued) MERCHANT FUNCTION CHARGE: The Merchant Function Charge reflects the administrative costs of obtaining electricity supply. Customers whose electricity is supplied by an ESCO are not charged for this service. MINIMUM CHARGE: The minimum charge for service under this Service Classification is the Customer Charge plus the Bill Issuance Charge, if applicable, as listed above, or as otherwise stated in the applicable special provisions. The minimum charge for customers who choose to take all or part of their back-up or maintenance service under this service classification rather than under Special Provision (d) of NYSEG's Service Classification No. 11 is described in the "DETERMINATION OF DEMAND" section. REVENUE DECOUPLING MECHANISM (“RDM”): A customer taking service under this Service Classification shall be subject to a Revenue Decoupling Mechanism adjustment as explained in this Schedule, General Information Section 7. Customers taking Subtransmission service are excluded from the RDM. See RDM Statement

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 161 Revision: 10 Superseding Revision: 9

SERVICE CLASSIFICATION NO. 3 (Continued) RATE CHOICES AVAILABLE TO CUSTOMERS: (CONT'D.) SURCHARGE TO COLLECT SYSTEM BENEFITS CHARGE ("SBC"): A surcharge will be added to each customer bill for service under this Service Classification to collect the System Benefits Charge (as explained in this Schedule, General Information Section 4). See SBC Statement. RENEWABLE PORTFOLIO STANDARD CHARGE (“RPS”): A surcharge will be added to each customer bill for service under this Service Classification to collect the Renewable Portfolio Standard (as explained in this Schedule, General Information Section 5). See RPS Statement. SURCHARGE TO COLLECT TEMPORARY STATE ASSESSMENT (“TSAS”): A surcharge will be added to each customer bill for service under this Service Classification to collect the Temporary State Assessment (as explained in this Schedule, General Information Section 28). See TSAS Statement. COMPETITIVE METERING OPTION: Qualified Customers who select the Competitive Metering Option must comply with the requirements specified in PSC 119 - Electricity and specified in General Information Section 14 of this Schedule, and will not be charged the Meter Ownership, Meter Services, and Meter Data Service Charges. METER OWNED BY CUSTOMER, INSTALLED AND MAINTAINED BY THE CORPORATION Customers electing to own their own meters, as described in Section 3.A.2 of PSC 119 - Electricity, will not be charged the Meter Ownership Charge. This provision is separate and distinct from Competitive Metering. INCREASE IN RATES AND CHARGES: The rates and charges under this Service Classification, including minimum charges, will be increased by a surcharge pursuant to Section 6 of PSC No. 120 to reflect the tax rates applicable within the municipality where the customer takes service.

Issued in compliance with order in Case No. 09-M-0311 dated 6/19/09.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: November 1, 2009

Leaf No. 162 Revision: 3 Superseding Revision: 1

SERVICE CLASSIFICATION NO. 3 (Continued) DETERMINATION OF DEMAND: The billing demand will be the metered demand, which is the highest average kilowatts used in a fifteen-minute interval during the month. For subtransmission customers also served by the Corporation under Special Provision F of Service Classification No. 10, the measured demand of the output provided by the customer's generating facility will be added to the measured demand as determined by the Corporation's meter for service under this Classification. Customers who choose to take all or part of their back-up or maintenance service under this service classification rather than under Special Provision (d) of NYSEG's Service Classification No. 11 will pay a minimum demand charge as described in NYSEG's Service Classification No. 11. Customers will pay a minimum demand charge related to generation, ancillary, and transmission costs. The minimum demand charge is based on a rate per kW of the contract demand and is accumulated over a 12-month period. The accumulated contract demand charge component will be compared to the accumulated demand charge in this service classification. If the contract demand charge is greater than the demand charge in this service classification, then the customer will only pay the contract demand charge in that month. If it is less than the demand charge in this service classification, then the customer will pay that difference in that month. DETERMINATION OF REACTIVE KILOVOLT-AMPERE HOURS: Whenever the customer's metered demand is 200 kW or more for two consecutive billing periods, the reactive kilovolt-ampere hours shall thereafter be metered. The billing reactive kilovolt-ampere hours shall be the reactive kilovolt-ampere hours in excess of one-third of the metered kilowatt hours. Effective 05/01/2010: Whenever the customer’s metered demand is 200 kW or more for two billing periods in any two of the previous twelve (12) months, the reactive kilovolt-ampere hours shall thereafter be metered. The billing reactive kilovolt-ampere hours will be the reactive kilovolt-ampere hours in excess of one-fourth of the metered kilowatt-hours. TERMS OF PAYMENT: All bills are rendered at the above "unit prices" and that amount is due on bills paid on or before the "past due" date indicated on the bill. A late payment charge at the rate of one and one-half percent (1 1/2%) per month will be billed on all amounts not paid by that date. (Further details in Section 4 of P.S.C. No. 119 - Electricity or superseding issues thereof.) TERM: One year and thereafter until terminated by 30 days' written notice. However, the Corporation may, with the permission of the Public Service Commission, require the customer to agree to take service at rates from time to time effective for a longer term dependent upon the amount of investment required or other unusual conditions incident to the service.

Issued in compliance with order in Case No. 08-E-0751 dated 09/22/09.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2007

Leaf No. 163 Revision: 2 Superseding Revision: 1

SERVICE CLASSIFICATION NO. 3 (Continued) SPECIAL PROVISIONS: (a) Primary Discounts: This provision is no longer available to additional customers on or after January 1, 2007. The above subtransmission rates reflect a discount for a customer who furnishes and maintains the necessary substation and purchases energy at 34,500 or 46,000 (both Non-Regulated) Volts. Customers receiving service prior to February 15, 2000 ("Grandfathered Customers"), will receive the stated Primary Discounts when the customer furnishes and maintains the necessary substation and purchases energy at 34,500 (Regulated). (b) Budget Billing: Customers may, by signing an application, be billed monthly in accordance with the plan set forth in Section 4-0 of P.S.C. No. 119 - Electricity or superseding issues thereof. (c) Submetering: Submetering may be available according to certain conditions as explained in the general information leaves of this schedule, Section 2. Submetering.

Issued in compliance with order in Case No. 05-E-1222 dated 08/23/06.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 164 Revision: 6 Superseding Revision: 5

SERVICE CLASSIFICATION NO. 3 (Continued)
SPECIAL PROVISIONS: (Cont'd) (d) Economic Incentives: Customer load supplied by the New York Power Authority (NYPA) is not eligible to receive an economic incentive. (1) (2) Reserved for Future Use Economic Development Incentive: As provided in General Information Section 8, this provision is no longer available to additional customers on or after January 1, 2007. Customers who qualify, under the Economic Development Incentive (EDI) in Section 8 of the General Information section of this Schedule, to receive an incentive for load qualified on or after July 1, 2003 may select one of the following rate options, as specified in this Service Classification and Section 25, Supply Service Options, for all of their load: 1) 1) NYSEG Supply Service (NSS), 2) ESCO Supply Service (ESS), or 3) Hourly Pricing. Such customers will be exempt from paying the Transition Charge. If it is determined that a bill calculated with the incentive exceeds a bill calculated under the otherwise applicable standard service classification rates, the customer will pay the lower of the two bills.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 165 New York State Electric & Gas Corporation Revision: 6 Initial Effective Date: September 26, 2010 Superseding Revision: 5 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 3 (Continued) SPECIAL PROVISIONS: (Cont'd.) (d) Economic Incentives: (Cont'd) (3) Economic Development Zone Incentive: Customers who qualify, under the Economic Development Zone Incentive (EDZI) in Section 9 of the General Information section of this Schedule, to receive an incentive for load qualified prior to July 1, 2003 shall take service under the NSS or ESS rate, as specified in this Service Classification and Section 25, Supply Service Options, for all of their load. Such customers will have their service bills reduced, for a term of ten (10) years beginning on the date of the qualifying load installation and operation (unless the customer's initial zone certification(s) becomes invalid), by $0.0225 per kilowatt-hour for all qualified kilowatt-hours used thereunder. Customers who qualify, under the Economic Development Zone Incentive (EDZI) in Section 9 of the General Information section of this Schedule, to receive an incentive for load qualified on or after July 1, 2003 may select one of the following rate options, as specified in this Service Classification and Section 25, Supply Service Options, for all of their load: 1) NYSEG Supply Service (NSS), 2) ESCO Supply Service (ESS), or 3) Hourly Pricing. Such customers will have their service bills reduced, for a term of ten (10) years following initial zone certification, beginning with the eligibility date on the zone certificate (unless the customer's initial zone certification(s) becomes invalid.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: November 1, 2010
Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010.

Leaf No. 166 Revision: 21 Superseding Revision: 20

SERVICE CLASSIFICATION NO. 3 (Continued)
SPECIAL PROVISIONS: (Cont'd.) (d) Economic Incentives: (Cont'd) (3) Economic Development Zone Incentive: (Cont'd.)

Effective through 8/31/12: All customers will be subject to the otherwise applicable standard service classification rates, including the Transition Charge, Commodity, and Merchant Function and Bill Issuance Charges, if applicable, System Benefits Charge, Renewable Portfolio Standard, Temporary State Assessment Surcharge, and Revenue Decoupling Mechanism in accordance with the standard NSS, ESS, or Hourly Pricing rates for this Service Classification.
Effective 9/01/12: All customers will be required to pay the Commodity, Merchant Function and Bill Issuance Charges, if applicable, System Benefits Charge, Renewable Portfolio Standard, Temporary State Assessment Surcharge, and Revenue Decoupling Mechanism in accordance with the standard NSS, ESS, or Hourly Pricing rates for this Service Classification. Hourly Pricing customers will also be billed the Hourly Meter Charge and Electric Capacity Charge in accordance with the Hourly Pricing rates for this Service Classification.

Such customers will be exempt from paying the Transition Charge. If it is determined that a bill calculated with the incentive exceeds a bill calculated under the otherwise applicable standard service classification rates, the customer will pay the lower of the two bills.
The qualified load receiving the incentive will be billed at the following applicable delivery rates: Effective Date PRIMARY VOLTAGE Delivery Charges Customer Charge Meter Ownership Charge Meter Service Charge Meter Data Service Charge
(Meter Reading)

9/26/10 $50.59 $2.29 $11.58 $3.53

9/01/11 $53.91 $2.29 $11.58 $3.53

9/01/12 $55.41 $2.29 $11.58 $3.53

Demand Charge
(All kilowatts, per kilowatt)

$4.59 $0.00364 $0.00078

$4.62 $0.00384 $0.00078

$4.70 $0.00356 $0.00078

Energy Charge
(All kilowatt-hours, per kilowatt-hour)

Reactive Charge
Reactive kilovolt-ampere hours, per billing reactive kilovolt-ampere hour

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 167 New York State Electric & Gas Corporation Revision: 20 Initial Effective Date: September 26, 2010 Superseding Revision: 19 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010
SERVICE CLASSIFICATION NO. 3 (Continued) SPECIAL PROVISIONS: (Cont'd.) (d) Economic Incentives: (Cont'd) (3) Economic Development Zone Incentive: (Cont'd.)

All customers will be subject to the otherwise applicable standard service classification rates, including the Transition Charge, Commodity, and Merchant Function and Bill Issuance Charges, if applicable, System
Benefits Charge, Renewable Portfolio Standard, Temporary State Assessment Surcharge, and Revenue Decoupling Mechanism in accordance with the standard NSS, ESS, or Hourly Pricing rates for this Service

Classification.

SUBTRANSMISSION VOLTAGE Delivery Charges Customer Charge Meter Ownership Charge Meter Service Charge Meter Data Service Charge
(Meter Reading)

Effective Date 09/26/2010 $212.09 $2.36 $11.91 $2.67 09/01/2011 $218.73 $2.36 $11.91 $2.67 09/01/2012 $225.57 $2.36 $11.91 $2.67

Demand Charge
(All kilowatts, per kilowatt)

$3.86 $0.00080 $0.00078

$4.00 $0.00053 $0.00078

$4.14 $0.00039 $0.00078

Energy Charge
(All kilowatt-hours, per kilowatt-hour)

Reactive Charge
Reactive kilovolt-ampere hours, per billing reactive kilovolt-ampere hour

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 168 Revision: 10 Superseding Revision: 9

SERVICE CLASSIFICATION NO. 3 (Continued) SPECIAL PROVISIONS: (Cont'd.) (d) Economic Incentives: (Cont'd) (4) Economic Development Power: Customers who qualify for the special Economic Development Power rate provision pursuant to Section 10 of the General Information Section of this Schedule, will have such power billed in accordance with the Special Provision therein. The customer's power requirements in excess of the Economic Development Power will be billed at SC No. 7 rates applicable to the customer's voltage level. (5) Reserved for Future Use

Issued in compliance with order in Case No. 09-E-0227 dated 09/28/09.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 169 Revision: 7 Superseding Revision: 6

SERVICE CLASSIFICATION NO. 3 (Continued) SPECIAL PROVISIONS: (Cont'd.) (d) Economic Incentives: (Cont'd) (6) Incubator Development Incentive ("IDI"):
As provided in General Information Section 13, this provision is no longer available to additional customers on or after January 1, 2007. Existing customers will be permitted to transition to the Incremental Load Incentive as described in General Information Section 19.

Customers who qualify under the Incubator Development Incentive (IDI) in Section 13 of the General Information section of this Schedule prior to July 1, 2003 shall take service under the NSS or DSS rate, as specified in this Service Classification and Section 25, Supply Service Options, for all of their load. (7) Reserved for Future Use

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 170 New York State Electric & Gas Corporation Revision: 9 Initial Effective Date: September 26, 2010 Superseding Revision: 8 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010
SERVICE CLASSIFICATION NO. 3 (Continued) SPECIAL PROVISIONS: (Cont'd.) (d) Economic Incentives: (Cont'd) (8) Incremental Load Incentive (“ILI”): Customers who qualify under the Incremental Load Incentive (ILI) in Section 19 of the General Information section may select one of the following rate options, as specified in this Service Classification and Section 25, Supply Service Options, for all of their load: 1) NYSEG Supply Service (NSS), 2) ESCO Supply Service (ESS), or 3) Hourly Pricing. Such customers will receive the incentive for a term of 60 months.

Effective through 8/31/11: All customers will be subject to the otherwise applicable standard service classification rates, including the Transition Charge, Commodity, and Merchant Function and Bill Issuance Charges, if applicable, System Benefits Charge, Renewable Portfolio Standard, Temporary State Assessment Surcharge, and Revenue Decoupling Mechanism, if applicable, in accordance with the standard NSS, ESS, or Hourly Pricing rates for this Service Classification.
Effective 9/01/12 for customers taking Primary service only:

Such customers will be exempt from paying the Transition Charge. If it is determined that a bill calculated with the incentive exceeds a bill calculated under the otherwise applicable standard service classification rates, the customer will pay the lower of the two bills. Effective 09/01/12
$55.41 $2.29 $11.58 $3.53

PRIMARY VOLTAGE Delivery Charges Customer Charge Meter Ownership Charge Meter Service Charge Meter Data Service Charge
(Meter Reading)

Demand Charge
(All kilowatts, per kilowatt)

$4.78 $0.00356 $0.00078

Energy Charge
(All kilowatt-hours, per kilowatt-hour)

Reactive Charge
Reactive kilovolt-ampere hours, per billing reactive kilovolt-ampere hour

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 170.1 New York State Electric & Gas Corporation Revision: 3 Initial Effective Date: September 26, 2010 Superseding Revision: 2 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 3 (Continued) SPECIAL PROVISIONS: (Cont'd.)
(d) Economic Incentives: (Cont'd) (8) Incremental Load Incentive (“ILI”): (Cont’d) Customers transitioning from the Incubator Development Incentive will be phased in as follows:
Effective Date 01/01/2010 01/01/2011 $0.010 $0.005

Per kilowatt hour, for all qualified kilowatthours

At any time during the phase in, an IDI customer may make a one-time election to receive the ILI discount on the qualified kilowatt-hours i nstead of the phase in. Once a customer had made this election, they will not be allowed to return to the phase in. (e) Controlled Load Time-of-Use Service Option: Customers who have a total connected load of at least 25 kW, with at least 12.5 kW of that load being newly installed controlled equipment, may choose to take their entire service under Service Classification No. 7 with Time-of-Use metering. Controlled Load equipment will include, but not be limited to, Electric Thermal Storage equipment (E.T.S.), Air Conditioning equipment, Water Heating or other Heating/Cooling installations which are designed to operate advantageously during off-peak hours as defined in Service Classification No. 7.

(f)

Reserved for Future Use

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2007

Leaf No. 170.2 Revision: 2 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 3 (Continued) SPECIAL PROVISIONS: (Cont'd.) (f) (g) Reserved for Future Use Reserved for Future Use

Issued in compliance with order in Case No. 05-E-1222 dated 08/23/06.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 171 New York State Electric and Gas Corporation Revision: 4 Initial Effective Date: September 26, 2010 Superseding Revision: 2 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 3 (Continued) SPECIAL PROVISIONS: (Cont'd.) (h) Industrial/High Load Factor ("I/HLF") Rate Provision: (1) Available to a customer's account that meets usage eligibility as defined in (2) or (3) of this section. Customers who are taking service under NYSEG's Economic Development Incentive, Economic Development Zone Incentive, New York Power Authority (NYPA) programs (Expansion Power, Economic Development Power, Replacement Power, High Load Manufacturer Power, Power For Jobs and Preservation Power) or S.C. 14 may take service under this rate provision, only for that portion of their load served at NYSEG's standard tariff rate, provided that the non-discounted load meets the eligibility requirements of this special provision. Allocation of billing units (kW, kWh, rkvah) for partial load is explained in (3) of this section. I/HLF rates are not available for Subtransmission Voltage service. Recipients of other NYSEG incentive rates applicable to their entire load, may qualify for this special provision by relinquishing eligibility under the incentive, provided that they meet the eligibility requirements of this special provision.

(2) Eligibility: Eligibility will be determined based on the total metered demand and energy excluding the NYPA portion of that metered amount. (i) Industrial Rate Provision: Not applicable to customers in this service classification. Customers with average annual demands in excess of 500 kW, are served under S.C. No. 7.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003

Leaf No. 172 Revision: 0 Superseding Revision:

SERVICE CLASSIFICATION NO. 3 (Continued) SPECIAL PROVISIONS: (Cont'd.) (h) Industrial/High Load Factor Rate Provision: (Cont'd.) (2) Eligibility: (Cont'd.) (ii) High Load Factor Rate Provision: Applicable to an existing customer's account having an annual load factor of 68.0% or greater (approximately 500 hours' average use of kW demand per month). Also applicable to a new customer's account with an estimated annual load factor of 68.0% or greater. Annual load factor for this provision is calculated as follows: A/(D*H) A = Annual kWh. For existing customers this will be the actual total energy usage billed during the most recent 12 consecutive months. For new customers or customers with incomplete history, the annual usage will be estimated by the Corporation from engineering and operating estimates to fit within the time period. D = Maximum demand. For existing customers this will be the highest billed demand during the most recent 12 consecutive months. For new customers or customers with incomplete history, the demand will be estimated by the Corporation from engineering and operating estimates to fit within the time period. H = Number of total hours in the annual billing period. (3) Allocation of Billing Units for Partial Load: Billing units (kW, kWh, rkvah) will be allocated between the Industrial/High Load Factor and Economic Incentive portions of the customer's bill based on the following formula: B T EKWH EKW NKW = Billing kW = Total kWh = Incented kWh = Incented kW = Non-incented kW (EKWH / T) x B = EKW B - EKW = NKW

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 173 New York State Electric & Gas Corporation Revision: 13 Initial Effective Date: September 26, 2010 Superseding Revision: 12 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 3 (Continued) SPECIAL PROVISIONS: (Cont'd.)
(h) Industrial/High Load Factor Rate Provision: (Cont'd.) (3) Rate Qualification Review: Each account will be reviewed annually for continued qualification, based on the load factor during the previous year. Such review shall occur 12 months after the initiation of this rate provision, and shall be repeated each year thereafter. To maintain qualification for this rate, a customer account's annual load factor must be 68.0% or greater. (4) Rate for Qualified High Load Factor Service: A complete description of these Supply Service Options appears previously in this Service Classification. (a) ESCO Supply Service (ESS) Rates under the High Load Factor Special Provision are as follows: Effective Date 09/26/2010 $50.59 $2.29 $11.58 $3.53 09/01/2011 $53.91 $2.29 $11.58 $3.53 09/01/2012 $55.41 $2.29 $11.58 $3.53 09/01/2013 $55.41 $2.29 $11.58 $3.53 09/01/2014 $55.41 $2.29 $11.58 $3.53 09/01/2015 $55.41 $2.29 $11.58 $3.53 09/01/2016 $55.41 $2.29 $11.58 $3.53

PRIMARY VOLTAGE Delivery Charges Customer Charge Meter Ownership Charge Meter Service Charge Meter Data Service Charge
(Meter Reading)

Demand Charge
(All kilowatts, per kilowatt)

$2.23 $0.00160

$2.72 $0.00202

$3.26 $0.00245

$3.66 $0.00272

$4.06 $0.00299

$4.46 $0.00326

$4.85 $0.00352

Energy Charge
(All kilowatt-hours, per kilowatthour)

Reactive Charge
Reactive kilovolt-ampere hours, per billing reactive kilovolt-ampere hour

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

Transition Charge All kilowatt-hours, per kilowatt-hour Bill Issuance Charge (per bill):

See Transition Charge Statement $0.73, as described in General Information Section 16.J.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 174 Revision: 19 Superseding Revision: 18

SERVICE CLASSIFICATION NO. 3 (Continued) SPECIAL PROVISIONS: (Cont'd.)
(h) Industrial/High Load Factor Rate Provision: (Cont'd.) (4) Rate for Qualified High Load Factor Service: (Cont'd.) (b) Reserved for Future Use

Issued in compliance with order in Case No. 09-E-0227 dated 09/28/09.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 175 Revision: 19 Superseding Revision: 18

SERVICE CLASSIFICATION NO. 3 (Continued) SPECIAL PROVISIONS: (Cont'd.)
(h) Industrial/High Load Factor Rate Provision: (Cont'd.) (4) (b) Rate for Qualified High Load Factor Service: (Cont'd.) Reserved for Future Use

Issued in compliance with order in Case No. 09-E-0227 dated 09/28/09.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 176 New York State Electric & Gas Corporation Revision: 12 Initial Effective Date: September 26, 2010 Superseding Revision: 11 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 3 (Continued) SPECIAL PROVISIONS: (Cont'd.)
(h) Industrial/High Load Factor Rate Provision: (Cont'd.) (4) Rate for Qualified High Load Factor Service: (Cont'd.) (c) NYSEG Supply Service (NSS) Rates under the High Load Factor Special Provision are as follows: Effective Date 09/26/2010 $50.59 $2.29 $11.58 $3.53 09/01/2011 $53.91 $2.29 $11.58 $3.53 09/01/2012 $55.41 $2.29 $11.58 $3.53 09/01/2013 $55.41 $2.29 $11.58 $3.53 09/01/2014 $55.41 $2.29 $11.58 $3.53 09/01/2015 $55.41 $2.29 $11.58 $3.53 09/01/2016 $55.41 $2.29 $11.58 $3.53

PRIMARY VOLTAGE Delivery Charges Customer Charge Meter Ownership Charge Meter Service Charge Meter Data Service Charge
(Meter Reading)

Demand Charge
(All kilowatts, per kilowatt)

$2.23 $0.00160

$2.72 $0.00202

$3.26 $0.00245

$3.66 $0.00272

$4.06 $0.00299

$4.46 $0.00326

$4.85 $0.00352

Energy Charge
(All kilowatt-hours, per kilowatthour)

Reactive Charge
Reactive kilovolt-ampere hours, per billing reactive kilovolt-ampere hour

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

Transition Charge All kilowatt-hours, per kilowatt-hour

See Transition Charge Statement

Commodity Service The charge for Electric Power Supply provided by NYSEG will fluctuate each month as further described in General Information Section 25.I.C., Calculation of the Commodity Charge. Merchant Function Charge All kilowatt-hours, per kilowatt-hour

See Merchant Function Charge Statement

Bill Issuance Charge (per bill):

$0.73, as described in General Information Section 16.J.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2007

Leaf No. 177 Revision: 2 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 3 (Continued) SPECIAL PROVISIONS: (Cont'd.)
(h) Industrial/High Load Factor Rate Provision: (Cont'd.)

(4)

Rate for Qualified High Load Factor Service (Per Month) (Cont'd.) Primary Discounts: This provision is no longer available to additional customers on or after January 1, 2007. The above subtransmission rates reflect a discount for a customer who furnishes and maintains the necessary substation and purchases energy at 34,500 or 46,000 (both Non-Regulated) volts. Customers receiving service prior to February 15, 2000 ("Grandfathered Customer"), will receive the stated Primary Discounts when the customer furnishes and maintains the necessary substation and purchases energy at 34,500 (Regulated).

Issued in compliance with order in Case No. 05-E-1222 dated 08/23/06.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: January 1, 2008

Leaf No. 178 Revision: 4 Superseding Revision: 2

SERVICE CLASSIFICATION NO. 3 (Continued) SPECIAL PROVISIONS: (Cont'd.) (i) Reserved for Future Use

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: January 1, 2008

Leaf No. 179 Revision: 4 Superseding Revision: 2

SERVICE CLASSIFICATION NO. 3 (Continued) SPECIAL PROVISIONS: (Cont'd.) (i) Reserved for Future Use

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: January 1, 2008

Leaf No. 180 Revision: 2 Superseding Revision: 1

SERVICE CLASSIFICATION NO. 3 (Continued) SPECIAL PROVISIONS: (Cont'd.) (j) Emergency Demand Response Program ("EDRP") The EDRP seeks to provide customers with an economic incentive to respond to Emergency Operating Conditions as identified by the NYISO. EDRP can provide the NYISO, through the Company, with the ability to request voluntary load curtailment or replacement by participating customers for electric usage. Customers who are qualified under EDRP in Section 20 of the General Information section of this Schedule may participate in the NYSEG EDRP as set forth therein.

Issued in compliance with order in Case No. 07-E-0749 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: July 1, 2009

Leaf No. 181 Revision: 3 Superseding Revision: 2

SERVICE CLASSIFICATION NO. 3 (Continued) SPECIAL PROVISIONS: (Cont'd.) j. C.A.$.H.BACK Special Provision The Company will provide a voluntary program for load normally supplied and delivered by NYSEG, for eligible customers to curtail load. NYSEG's program, entitled C.A.$.H.BACK, implements the NYISO's day-ahead economic load-curtailment program. Under this program, a customer agrees to curtail load when their bid is submitted and accepted by the NYISO. Customers who are qualified under C.A.$.H.BACK in Section 21 of the General Information section of this Schedule may participate in the NYSEG C.A.$.H.BACK Program as set forth therein. k. Farm Waste Electric Generating System Option: This option is for a customer qualifying for the Farm Waste Electric Generating System Option pursuant to General Information Section 22 of this Schedule, and taking service under SC 3. l. Wind Electric Service Option: This option is for a customer qualifying for the Wind Electric Generating System Option pursuant to General Information Section 23 of this Schedule and taking service under SC 3.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: July 1, 2009

Leaf No. 181.1 Revision: 2 Superseding Revision: 1

SERVICE CLASSIFICATION NO. 3 (Continued) SPECIAL PROVISIONS: (Cont'd.)

m. Solar Non-Residential Electric Service Option: This option is for a customer qualifying for the Solar Non-Residential Generating Service Option pursuant to General Information Section 27 of this Schedule and taking service under SC 3. n. Electric Hybrid Generating System Option: This option is for a customer qualifying for the Electric Hybrid Generating System Option pursuant to General Information Section 24 of this Schedule and taking service under SC 3.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003 SERVICE CLASSIFICATION NO. 4

Leaf No. 182 Revision: 0 Superseding Revision:

This Service Classification is hereby cancelled. On and after the effective date hereof, customers formerly served under this Service Classification will be served under Service Classification No. 7.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010 SERVICE CLASSIFICATION NO. 5

Leaf No. 183 Revision: 5 Superseding Revision: 4

APPLICABLE TO THE USE OF SERVICE FOR: Outdoor lighting for residential and general service customers where applicable electric service is available. CHARACTER OF SERVICE: Unmetered service from dusk to dawn of approximately 4,200 hours per year. The Corporation will own, operate and maintain the facilities required and will supply the following types of service: (a) Overhead Service: Luminaires will be mounted on available wood or fiberglass poles owned by the Corporation or on Corporation-approved customer-owned poles. Underground Service: Luminaires will be mounted on metal, fiberglass or wood poles owned by the Corporation or on Corporation-approved customer-owned poles using the Corporation's existing distribution facilities or where the Corporation is in the process of constructing a new underground distribution system. The customer will be responsible for the construction and maintenance of the underground wire, cable and conduit facilities dedicated to serving the underground lighting system. All such facilities will be constructed in accordance with Company standards. Poles, luminaires, brackets and screw-in bases will be installed and maintained by the Corporation, unless the customer elects to pay for such facilities and be billed therefore under Special Provision K "Contributory Provisions". Energizing or de-energizing of any such underground system will be the responsibility of and performed only by the Corporation. The Company reserves the right to refuse service to any part of such customer-provided facility that does not meet general Corporation specifications.

(b)

SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: Pursuant to General Information Section 25, Supply Service Options, customers served under this Service Classification will choose from different electric rate choices offered by the Company as described below. NYSEG will offer a Retail Access rate choice and a Non-Retail Access rate choice. The Retail Access choice is the ESCO Supply Service (ESS). The Non-Retail Access choice is the NYSEG Supply Service (NSS).

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 184 New York State Electric & Gas Corporation Revision: 13 Initial Effective Date: September 26, 2010 Superseding Revision: 11 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 5 (Continued)
SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.) NYSEG will provide Delivery Service regardless of the customer’s Supply Service Option. 1. ESCO Supply Service (ESS) This Retail Access choice includes fixed charges for NYSEG delivery service and a Transition Charge (Non-Bypassable Charge [NBC]). Kilowatt-hour use will be determined for the customer’s billing period based on the monthly kilowatt-hours for each type of luminaire and lumen rating as set forth in this Service Classification. Delivery Service:

Delivery Charges Energy Charge
(All kilowatt-hours, per kilowatt-hour)

$0.02500 See Transition Charge Statement

Transition Charge
(All kilowatt-hours, per kilowatt-hour)

Bill Issuance Charge (per bill): $0.73, as described in General Information Section 16.J. and applicable to those customers where charges for this service classification are the only charges that appear on the customer’s bill.
RATE: (Per Month) Lamp Charge: (Area Lights) Available only for Mercury Vapor Safeguard Luminaires served under Special Provision A below, and in service prior to effective date of this leaf, which are converted to HPS by use of special lamping. Monthly Unit Rate Effective Date Lamp Style & Size Safeguard Luminaires (Post-2/1/88) 14,500 Nominal Lumen 150 Watt H.P.S. (replacing 7,000 L. 175 Watt M.V.) 43,000 Nominal Lumen 400 Watt H.P.S. (replacing 17,200 L. 400 Watt M.V.) 123,000 Nominal Lumen 940 Watt H.P.S. (replacing 48,000 L. 1,000 Watt M.V.) Lamp Charge: (Area Lights) 3,300 Nominal Lumen (50 Watt) H.P.S.* (PACKLITE) 5,200 Nominal Lumen (70 Watt) H.P.S.* (PACKLITE) 8,500 Nominal Lumen (100 Watt) H.P.S.* 3,200 Nominal Lumen (100 Watt) Mercury (PACKLITE)* 5,200 Nominal Lumen (70 Watt) H.P.S. Power Bracket 8,500 Nominal Lumen (100 Watt) H.P.S. Power Bracket 14,400 Nominal Lumen (150 Watt) H.P.S. 24,700 Nominal Lumen (250 Watt) H.P.S. 45,000 Nominal Lumen (400 Watt) H.P.S. 126,000 Nominal Lumen (1,000 Watt) H.P.S. 10,500 Nominal Lumen (175 Watt) Metal Halide Power Bracket 16,000 Nominal Lumen (250 Watt) Metal Halide 28,000 Nominal Lumen (400 Watt) Metal Halide 09/26/2010 09/01/2011 09/01/2012

$5.81 $8.54 $7.08

$5.94 $8.72 $7.23

$6.09 $8.94 $7.41

$3.16 $3.11 $3.08 $2.99 $5.96 $6.48 $10.89 $10.48 $10.25 $9.55 $4.41 $11.36 $11.21

$3.22 $3.17 $3.14 $3.05 $6.09 $6.62 $10.91 $10.70 $10.46 $9.75 $4.50 $11.60 $11.45

$3.31 $3.26 $3.23 $3.13 $6.24 $6.79 $11.20 $10.98 $10.73 $10.01 $4.62 $11.90 $11.75

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 185 New York State Electric & Gas Corporation Revision: 10 Initial Effective Date: September 26, 2010 Superseding Revision: 8 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 5 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.) 1. ESCO Supply Service (ESS) (Cont'd.) RATE: (Per Month) (Continued)
Monthly Unit Rate Effective Date Lamp Style & Size Lamp Charge: (Flood Lights)** 14,400 Nominal Lumen (150 Watt) H.P.S. 24,700 Nominal Lumen (250 Watt) H.P.S 45,000 Nominal Lumen (400 Watt) H.P.S. 126,000 Nominal Lumen (1,000 Watt) H.P.S. 16,000 Nominal Lumen (250 Watt) Metal Halide 28,000 Nominal Lumen (400 Watt) Metal Halide 88,000 Nominal Lumen (1,000 Watt) Metal Halide Lamp Charge: ("Shoebox" Luminaire) 14,400 Nominal Lumen (150 Watt) H.P.S. 24,700 Nominal Lumen (250 Watt) H.P.S. 45,000 Nominal Lumen (400 Watt) H.P.S. 16,000 Nominal Lumen (250 Watt) Metal Halide 28,000 Nominal Lumen (400 Watt) Metal Halide 88,000 Nominal Lumen (1,000 Watt) Metal Halide Lamp Charge: (Post Tops) 3,300 Nominal Lumen (50 Watt) H.P.S.* 5,200 Nominal Lumen (70 Watt) H.P.S. 8,500 Nominal Lumen (100 Watt) H.P.S. High Pressure Sodium Cobra: (non-residential only) 5,200 Nominal Lumen (70 Watt) H.P.S. 8,500 Nominal Lumen (100 Watt) H.P.S. Brackets - standard (up to 16') Brackets -16' and over Additional Wood Pole Installed for Lamp Wire Service (Overhead) (Per circuit foot of extension) 18' Fiberglass Pole - Direct Embedded 20' Fiberglass Pole - Pedestal Mount 20' Metal Pole - Pedestal Mount 30' Metal Pole - Pedestal Mount 30' Fiberglass Pole - Pedestal Mount 30' Fiberglass Pole - Direct Embedded Screw Base for Pedestal Mounted Pole - Light Duty Screw Base for Pedestal Mounted Pole - Heavy Duty H.P.S. - High Pressure Sodium PACKLITE/Power Bracket - for pole mount only. *Luminaires are no longer available for new installations. Upon failure and fulfillment of contract, lights will not be replaced in kind. Customer may select an alternative luminaire. Note: The rating of lamps in lumens is for identification purposes only and shall approximate the manufacturer's standard rating. 09/26/2010 $11.40 $11.20 $11.01 $12.26 $10.62 $11.71 $12.21 $12.04 $14.20 $15.08 $11.38 $11.22 $16.16 $8.75 $8.75 $8.73 $6.51 $6.51 $0.00 $2.14 $10.94 $0.031 $11.29 $39.21 $39.21 $39.21 $39.21 $17.17 $11.94 $15.24 09/01/2011 $11.64 $11.44 $11.24 $12.52 $10.84 $11.95 $12.47 $12.29 $14.50 $15.38 $11.62 $11.46 $16.50 $8.94 $8.94 $8.92 $6.65 $6.65 $0.00 $2.19 $11.17 $0.031 $11.53 $40.04 $40.04 $40.04 $40.04 $17.53 $12.19 $15.56 09/01/2012 $11.94 $11.74 $11.53 $12.84 $11.13 $12.26 $12.79 $12.61 $14.88 $15.78 $11.92 $11.76 $16.93 $9.17 $9.17 $9.15 $6.82 $6.82 $0.00 $2.24 $11.46 $0.032 $11.83 $41.08 $41.08 $41.08 $41.08 $17.99 $12.51 $15.96

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2008

Leaf No. 186 Revision: 5 Superseding Revision: 3

SERVICE CLASSIFICATION NO. 5 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.) Reserved for Future Use

Issued in compliance with order in Case No. -07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 187 Revision: 12 Superseding Revision: 10

SERVICE CLASSIFICATION NO. 5 (Continued)
SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.)

NYSEG will provide Delivery and Commodity Service for the Non-Retail Access choice. 2. Reserved for Future use

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 188 Revision: 12 Superseding Revision: 10

SERVICE CLASSIFICATION NO. 5 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.)

2. Reserved for Future Use

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 189 Revision: 9 Superseding Revision: 8

SERVICE CLASSIFICATION NO. 5 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.) 2. Reserved for Future Use

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 190 Revision: 7 Superseding Revision: 6

SERVICE CLASSIFICATION NO. 5 (Continued)

SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.) 2. Reserved For Future Use

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 191 Revision: 9 Superseding Revision: 8

SERVICE CLASSIFICATION NO. 5 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.)
2.

Reserved For Future Use

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 192 Revision: 6 Superseding Revision: 5

SERVICE CLASSIFICATION NO. 5 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.) 2. Reserved For Future Use

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 193 Revision: 7 Superseding Revision: 6

SERVICE CLASSIFICATION NO. 5 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.) 2. Reserved For Future Use

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 193.1 Revision: 5 Superseding Revision: 4

SERVICE CLASSIFICATION NO. 5 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.) 2. Reserved For Future Use

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 193.2 Revision: 6 Superseding Revision: 5

SERVICE CLASSIFICATION NO. 5 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.) 2. Reserved For Future Use

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 193.3 Revision: 5 Superseding Revision: 4

SERVICE CLASSIFICATION NO. 5 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.) 2. Reserved For Future Use

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 193.4 New York State Electric & Gas Corporation Revision: 11 Initial Effective Date: September 26, 2010 Superseding Revision: 9 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 5 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.) 3. NYSEG Supply Service (NSS) This Non-Retail Access choice includes fixed charges for NYSEG delivery service, a Transition Charge (NonBypassable Charge [NBC]), a fluctuating commodity charge for electricity supplied by NYSEG, and a Merchant Function Charge. Kilowatt-hour use will be determined for the customer’s billing period based on the monthly kilowatt-hours for each type of luminaire and lumen rating as set forth in this Service Classification. RATE: (Per Month) Delivery Charges
Energy Charge
(All kilowatt-hours, per kilowatt-hour)

$0.02500

Transition Charge All kilowatt-hours, per kilowatt-hour

See Transition Charge Statement

Commodity Service The charge for Electric Power Supply provided by NYSEG will fluctuate each month as further described in General Information Section 25.I.C., Calculation of the Commodity Charge. Merchant Function Charge All kilowatt-hours, per kilowatt-hour See Merchant Function Charge Statement Bill Issuance Charge (per bill): $0.73, as described in General Information Section 16.J. and applicable to those customers where charges for this service classification are the only charges that appear on the customer’s bill.

Monthly Unit Rate Effective Date

Lamp Style & Size
Safeguard Luminaires (Post-2/1/88) 14,500 Nominal Lumen 150 Watt H.P.S. (replacing 7,000 L. 175 Watt M.V.) 43,000 Nominal Lumen 400 Watt H.P.S. (replacing 17,200 L. 400 Watt M.V.) 123,000 Nominal Lumen 940 Watt H.P.S. (replacing 48,000 L. 1,000 Watt M.V.)

09/26/2010
$5.81 $8.54 $7.08

09/01/2011
$5.94 $8.72 $7.23

09/01/2012
$6.09 $8.94 $7.41

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 194 New York State Electric & Gas Corporation Revision: 13 Initial Effective Date: September 26, 2010 Superseding Revision: 11 Issued in compliance with Order in Case 09-E-0915 dated September 21, 2010 SERVICE CLASSIFICATION NO. 5 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.) 3. NYSEG Supply Service (NSS) (Cont'd.) RATE: (Per Month) Monthly Unit Rate Effective Date Lamp Style & Size
Lamp Charge: (Area Lights) 3,300 Nominal Lumen (50 Watt) H.P.S.* (PACKLITE) 5,200 Nominal Lumen (70 Watt) H.P.S.* (PACKLITE) 8,500 Nominal Lumen (100 Watt) H.P.S.* 3,200 Nominal Lumen (100 Watt) Mercury (PACKLITE)* 5,200 Nominal Lumen (70 Watt) H.P.S. Power Bracket 8,500 Nominal Lumen (100 Watt) H.P.S. Power Bracket 14,400 Nominal Lumen (150 Watt) H.P.S. 24,700 Nominal Lumen (250 Watt) H.P.S. 45,000 Nominal Lumen (400 Watt) H.P.S. 126,000 Nominal Lumen (1,000 Watt) H.P.S. 10,500 Nominal Lumen (175 Watt) Metal Halide Power Bracket 16,000 Nominal Lumen (250 Watt) Metal Halide 28,000 Nominal Lumen (400 Watt) Metal Halide Lamp Charge: (Flood Lights)** 14,400 Nominal Lumen (150 Watt) H.P.S. 24,700 Nominal Lumen (250 Watt) H.P.S 45,000 Nominal Lumen (400 Watt) H.P.S. 126,000 Nominal Lumen (1,000 Watt) H.P.S. 16,000 Nominal Lumen (250 Watt) Metal Halide 28,000 Nominal Lumen (400 Watt) Metal Halide 88,000 Nominal Lumen (1,000 Watt) Metal Halide Lamp Charge: (“Shoebox” Luminaire) 14,400 Nominal Lumen (150 Watt) H.P.S. 24,700 Nominal Lumen (250 Watt) H.P.S. 45,000 Nominal Lumen (400 Watt) H.P.S. 16,000 Nominal Lumen (250 Watt) Metal Halide 28,000 Nominal Lumen (400 Watt) Metal Halide 88,000 Nominal Lumen (1,000 Watt) Metal Halide High Pressure Sodium Cobra: (non-residential only) 5,200 Nominal Lumen (70 Watt) H.P.S. 8,500 Nominal Lumen (100 Watt) H.P.S.

09/26/2010
$3.16 $3.11 $3.08 $2.99 $5.96 $6.48 $10.89 $10.48 $10.25 $9.55 $4.41 $11.36 $11.21

09/01/2011
$3.22 $3.17 $3.14 $3.05 $6.09 $6.62 $10.91 $10.70 $10.46 $9.75 $4.50 $11.60 $11.45

09/01/2012
$3.31 $3.26 $3.23 $3.13 $6.24 $6.79 $11.20 $10.98 $10.73 $10.01 $4.62 $11.90 $11.75

$11.40 $11.20 $11.01 $12.26 $10.62 $11.71 $12.21

$11.64 $11.44 $11.24 $12.52 $10.84 $11.95 $12.47

$11.94 $11.74 $11.53 $12.84 $11.13 $12.26 $12.79

$12.04 $14.20 $15.08 $11.38 $11.22 $16.16

$12.29 $14.50 $15.38 $11.62 $11.46 $16.50

$12.61 $14.88 $15.78 $11.92 $11.76 $16.93

$6.51 $6.51

$6.65 $6.65

$6.82 $6.82

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 195 New York State Electric & Gas Corporation Revision: 10 Initial Effective Date: September 26, 2010 Superseding Revision: 8 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010
SERVICE CLASSIFICATION NO. 5 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.) 3. NYSEG Supply Service (NSS) (Cont'd.) Monthly Unit Rate Effective Date Lamp Style & Size
Lamp Charge: (Post Tops) 3,300 Nominal Lumen (50 Watt) H.P.S.* 5,200 Nominal Lumen (70 Watt) H.P.S. 8,500 Nominal Lumen (100 Watt) H.P.S. Brackets - standard (up to 16') Brackets - 16' and over Additional Wood Pole Installed for Lamp Wire Service (Overhead) (Per circuit foot of extension) 18' Fiberglass Pole - Direct Embedded 20' Fiberglass Pole - Pedestal Mount 20' Metal Pole - Pedestal Mount 30' Metal Pole - Pedestal Mount 30' Fiberglass Pole - Pedestal Mount 30' Fiberglass Pole - Direct Embedded Screw Base for Pedestal Mounted Pole - Light Duty Screw Base for Pedestal Mounted Pole - Heavy Duty

09/26/2010
$8.75 $8.75 $8.73 $0.00 $2.14 $10.94 $0.031 $11.29 $39.21 $39.21 $39.21 $39.21 $17.17 $11.94 $15.24

09/01/2011
$8.94 $8.94 $8.92 $0.00 $2.19 $11.17 $0.031 $11.53 $40.04 $40.04 $40.04 $40.04 $17.53 $12.19 $15.56

09/01/2012
$9.17 $9.17 $9.15 $0.00 $2.24 $11.48 $0.032 $11.83 $41.08 $41.08 $41.08 $41.08 $17.99 $12.51 $15.96

H.P.S. - High Pressure Sodium PACKLITE/Power Bracket - for pole mount only. *Luminaires are no longer available for new installations. Upon failure and fulfillment of contract, lights will not be replaced in kind. Customer may select an alternative luminaire. Note: The rating of lamps in lumens is for identification purposes only and shall approximate the manufacturer's standard rating.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2007

Leaf No. 195.1 Revision: 0 Superseding Revision:

SERVICE CLASSIFICATION NO. 5 (Continued)

MERCHANT FUNCTION CHARGE: The Merchant Function Charge reflects the administrative costs of obtaining electricity supply. Customers whose electricity is supplied by an ESCO are not charged for this service.

Issued in compliance with order in Case No. 05-E-1222 dated 08/23/06.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2008

Leaf No. 196 Revision: 2 Superseding Revision: 1

SERVICE CLASSIFICATION NO. 5 (Continued) RATE: (Per Month) (Cont'd) Monthly Kilowatt-hours for Each Type of Luminaire and Lumen Rating Metal Halide Mercury Vapor 3200 7000 17200 48000 10500 16000 28000 Lumen Rating Hours Month January 442 56 92 203 487 93 138 215 February* 370 47 77 170 408 78 116 180 March 367 47 76 169 404 77 115 178 April 309 39 64 142 341 65 97 150 May 285 36 59 131 314 60 89 132 June 258 33 54 119 284 54 81 125 July 271 34 56 125 299 57 85 132 August 306 39 64 141 337 64 96 149 September 340 43 71 156 375 71 106 165 October 395 50 82 182 435 83 124 192 November 420 53 87 193 463 88 131 204 December 447 57 93 206 493 94 140 217 *Leap Year February 382 49 79 176 421 80 120 186

88000 482 403 400 337 311 281 295 334 371 431 458 487 416

Lumen Rating Month January February March April May June July August September October November December *Leap Year February

3300 Hours 442 370* 367 309 285 258 271 306 340 395 420 447 382 26 21 21 18 17 15 16 18 20 23 24 26 22

5200 37 31 30 26 24 21 22 25 28 33 35 37 32

High Pressure Sodium 8500 14400 24700 52 43 43 36 33 30 32 36 40 46 49 52 45 76 63 63 53 49 44 46 52 58 68 72 76 65 138 116 115 97 89 81 85 96 106 124 131 140 120

45000 215 180 178 150 139 125 132 149 165 192 204 217 186

126000 489 409 406 342 315 285 300 338 376 437 465 494 422

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 197 New York State Electric & Gas Corporation Revision: 20 Initial Effective Date: September 26, 2010 Superseding Revision: 18 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010
SERVICE CLASSIFICATION NO. 5 (Continued) SURCHARGE TO COLLECT SYSTEM BENEFITS CHARGE ("SBC"): A surcharge will be added to each customer bill for service under this Service Classification to collect the System Benefits Charge (as explained in this Schedule, General Information Section 4). See SBC Statement. RENEWABLE PORTFOLIO STANDARD CHARGE (“RPS”): A surcharge will be added to each customer bill for service under this Service Classification to collect the Renewable Portfolio Standard (as explained in this Schedule, General Information Section 5). See RPS Statement. SURCHARGE TO COLLECT TEMPORARY STATE ASSESSMENT (“TSAS”): A surcharge will be added to each customer bill for service under this Service Classification to collect the Temporary State Assessment (as explained in this Schedule, General Information Section 28). See TSAS Statement. INCREASE IN RATES AND CHARGES: The rates and charges under this Service Classification, including minimum charges, will be increased by a surcharge pursuant to Section 6 of PSC No. 120 to reflect the tax rates applicable within the municipality where the customer takes service. MINIMUM CHARGES: Minimum monthly charge shall be the Monthly Luminaire Charge computed under the above rate plus the Bill Issuance Charge, if applicable. In the event service is terminated at the customer's request, prior to completion of the initial term for that customer as specified below, the customer shall be obligated to pay the minimum monthly charge for each of the remaining months of the unexpired initial term plus any balance due on service rendered to the time of termination. ALLOWANCE FOR LAMP OUTAGES: If a lamp is out for more than three business days (Monday through Friday) after a notice of such outage has been given the Corporation by the customer, a pro rata adjustment of the lamp charge shall be allowed. TERMS OF PAYMENT: All bills are rendered at the above "unit prices" and that amount is due on bills paid on or before the "past due" date indicated on the bill. A late payment charge at the rate of one and one-half percent (1 1/2%) per month will be billed on all amounts not paid by that date. (Further, details in Section 4 of P.S.C. No. 119 - Electricity or superseding issues thereof.) TERM: (a) Luminaire-only-service supplied overhead, shall be 24 months and thereafter until terminated by five days' written notice, for an initial applicant and customer for such luminaire. All other luminaire service with additional facilities (other than just bracket) shall be sixty months and thereafter until terminated by five days' written notice, for an initial applicant and customer for such luminaire service with additional facilities. For a subsequent applicant and customer, where luminaire, and additional facilities if applicable, have been previously installed, one month, and thereafter until terminated by five days’ written notice.

(b)

(c)

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 198 New York State Electric & Gas Corporation Revision: 20 Initial Effective Date: September 26, 2010 Superseding Revision: 18 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 5 (Continued)
SPECIAL PROVISIONS: A complete description of these Supply Service Options appears previously in this Service Classification. All customers will be required to pay the Transition Charge and Commodity, Merchant Function and Bill Issuance Charges if applicable, in accordance with the standard ESS or NSS rates for this Service Classification. (a) (Area Lights-Mercury Vapor) Service under this provision will no longer be available for new installations subsequent to February 1, 1988. Upon failure of the luminaire, luminaires will not be replaced in kind. Customer may select an alternative luminaire. (i) ESCO Supply Service (ESS) Delivery Charges Energy Charge
(All kilowatt-hours, per kilowatt-hour)

$0.02500 Monthly Unit Rate Effective Date

09/26/2010
Mercury Vapor (M.V.) Safeguard Luminaires (special provision for installations prior to 2/1/88) 7,000 Lumen 17,200 Lumen 48,000 Lumen Additional Facilities: Additional Wood Pole Wire Service (per Circuit foot)

09/01/2011

09/01/2012

$9.19 $11.87 $12.76 $4.15 $0.012

$9.38 $12.12 $13.03 $4.23 $0.012

$9.63 $12.44 $13.37 $4.34 $0.012

(ii) Reserved for Future use

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2008

Leaf No. 198.1 Revision: 5 Superseding Revision: 3

SERVICE CLASSIFICATION NO. 5 (Continued) Reserved for Future Use

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 198.2 New York State Electric & Gas Corporation Revision: 8 Initial Effective Date: September 26, 2010 Superseding Revision: 6 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 5 (Continued) SPECIAL PROVISIONS: (Cont’d) (iii) NYSEG Supply Service (NSS) Delivery Charges Energy Charge (All kilowatt-hours, per kilowatthour)

$0.02500
Monthly Unit Rate Effective Date

09/26/2010
Mercury Vapor (M.V.) Safeguard Luminaires (special provision for installations prior to 2/1/88) 7,000 Lumen 17,200 Lumen 48,000 Lumen Additional Facilities: Additional Wood Pole Wire Service (per Circuit foot)

09/01/2011

09/01/2012

$9.19 $11.87 $12.76 $4.15 $0.012

$9.38 $12.12 $13.03 $4.23 $0.012

$9.63 $12.44 $13.37 $4.34 $0.012

(b) (c)

Lamp replacement and repairs will be made only during regular working hours, Monday through Friday. Any customer-owned pole on which a lamp is to be mounted or to which wire is to be attached must be approved by the Corporation. If a customer-owned pole on which such equipment is mounted deteriorates, is damaged, or has its use impaired so that it no longer is approved by the Corporation, service may be terminated.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2006 Effective date postponed to 02/01/06. See Supplement No. 4.

Leaf No. 199 Revision: 1 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 5 (Continued)
SPECIAL PROVISIONS: (Cont'd) (d) The Corporation shall not be required to relocate any of its existing facilities to provide service under this Service Classification nor shall it be required to replace existing operational fixtures unless the cost of such relocation or replacement is paid by the customer. The Corporation will furnish and install such lighting fixtures provided: 1. 2. 3. (f) (g) The customer shall have first assured the Corporation that the service will be on a continuous and reasonably permanent basis, and The customer has signed a contract agreeing to the provisions of this service classification, and Where applicable, the customer has provided Corporation-approved facilities in accordance with Special Provision (k) below.

(e)

The customer shall furnish the Corporation with all easements or rights-of-way necessary to provide service to the desired location before any installation or construction will be started. A customer may apply for service hereunder for a proposed residential subdivision or commercial or industrial development in which all electric facilities will be underground. Such application, as shown within Section 2.I. of General Information Schedule P.S.C. No. 119 - Electricity, shall be signed by the customer and the builder or developer and when accepted by the Corporation, shall constitute an agreement between the Corporation, customer and builder or developer subject to the terms and provisions hereunder. The builder or developer shall pay to the Corporation prior to the commencement of any construction all costs, if any, which the Corporation may incur associated with the installation of the underground lighting facilities required to render service hereunder, and shall prepay six times the total monthly charge for all luminaires, brackets, bases, wiring and poles installed. Said monthly charges shall be determined using rates in effect at the time said costs and charges are determined. The Corporation shall not bill the customer for the first six months of service of the facilities installed under this Special Provision.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 200 Revision: 2 Superseding Revision: 1

SERVICE CLASSIFICATION NO. 5 (Continued) SPECIAL PROVISIONS: (Cont'd) (h) Upon prior written notice to the Corporation (as specified in "TERM" above), the customer may require that the lighting of any luminaire or luminaires be discontinued. The Corporation shall have the right to remove all Corporation-owned facilities serving such luminaires. For each luminaire and its pertinent facility removed prior to the end of the initial term of service, the customer shall pay the charge as specified in "MINIMUM CHARGES" above. (i) Upon termination of service hereunder, the Corporation shall have the right within a reasonable time thereafter to remove all facilities placed, installed or used by it pursuant to the service hereunder. As a condition of receiving service hereunder, the customer shall authorize the Corporation insofar as it lawfully may, to trim, cut and remove any and all trees and other obstructions, which in the opinion of the Corporation, interfere with, or may tend to interfere with, the construction, operation and maintenance of the Corporation's facilities for rendering service hereunder. At times other than original installation, tree trimming necessary for light distribution shall be the responsibility of the customer and shall be done by the customer or at the customer's expense. Contributory Provisions for New Residential and New Commercial or Industrial Developments: Customers desiring lighting service under this service classification may opt to pay the capital costs of the entire lighting system devoted to rendering this service. (See Determination of Capital Costs*.) Under this provision, the ownership and the responsibility for operation and maintenance of the luminaire, pole, bracket and screw-in base rests with the Corporation. In the case of customer-provided facilities, the Corporation reserves the right to reject all or any part of such lighting facilities that do not meet general Corporation specifications, or are not compatible with the type and nature of Corporation facilities. The Corporation reserves the right to refuse ownership of systems subject to extraordinary maintenance requirements or unusually high incidents of physical damage. The rates specified in this provision do not provide for replacement due to expiration of the service life of installed fixtures, standards or other equipment. All customers will be required to pay the Transition Charge, and Commodity and Merchant Function Charges, if applicable, in accordance with the standard ESS or NSS rates for this Service Classification. Under the terms of this provision, the customer pays a monthly operation and maintenance fee according to the schedule as follows:

(j)

(k)

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 201 New York State Electric & Gas Corporation Revision: 20 Initial Effective Date: September 26, 2010 Superseding Revision: 18 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010
SERVICE CLASSIFICATION NO. 5 (Continued) SPECIAL PROVISIONS: (Cont'd)
(k) Contributory

Provisions for New Residential and New Commercial or Industrial Developments: (Cont’d)

(i) ESCO Supply Service (ESS)
Delivery Charges Energy Charge
(All kilowatt-hours, per kilowatt-hour)

$0.02500

Monthly Operation and Maintenance Charges

09/26/2010
Mercury Vapor: 3,200 (100 Watt)* High Pressure Sodium: 3,300 (50 Watt) 5,200 (70 Watt) 8,500 (100 Watt) 14,400 (150 Watt) 24,700 (250 Watt) 45,000 (400 Watt 126,000 (1,000 Watt) Metal Halide: 5,800 (100 Watt) 12,000 (175 Watt) 16,000 (250 Watt) 28,000 (400 Watt) 88,000 (1,000 Watt)**

09/01/2011 $1.69
$2.28 $2.18 $2.09 $1.91 $1.43 $0.89 $0.17 $1.68 $1.68 $1.68 $1.25 $0.34

09/01/2012 $1.74
$2.34 $2.23 $2.14 $1.96 $1.47 $0.91 $0.18 $1.73 $1.73 $1.73 $1.28 $0.35

$1.66
$2.23 $2.13 $2.04 $1.88 $1.40 $0.87 $0.17 $1.65 $1.65 $1.65 $1.22 $0.34

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010 .

Leaf No. 201.1 Revision: 9 Superseding Revision: 7

SERVICE CLASSIFICATION NO. 5 (Continued) SPECIAL PROVISIONS: (Cont'd) (ii) Reserved for Future Use

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2008

Leaf No. 201.2 Revision: 2 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 5 (Continued) SPECIAL PROVISIONS: (Cont'd) (ii) Reserved for Future Use

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 202 New York State Electric & Gas Corporation Revision: 12 Initial Effective Date: September 26, 2010 Superseding Revision: 10 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010
SERVICE CLASSIFICATION NO. 5 (Continued) SPECIAL PROVISIONS: (Cont'd)
(k) Contributory

Provisions for New Residential and New Commercial or Industrial Developments: (Cont’d)

(iii) NYSEG Supply Service (NSS) Delivery Charges Energy Charge
(All kilowatt-hours, per kilowatt hour)

$0.02500

Monthly Operation and Maintenance Charges 09/26/2010 09/01/2011 09/01/2012 Mercury Vapor: 3,200 (100 Watt)* $1.66 $1.69 $1.74 High Pressure Sodium: $2.34 $2.28 $2.23 3,300 (50 Watt) $2.23 $2.18 $2.13 5,200 (70 Watt) $2.14 $2.09 $2.04 8,500 (100 Watt) $1.96 $1.91 $1.88 14,400 (150 Watt) $1.47 $1.43 $1.40 24,700 (250 Watt) $0.91 $0.89 $0.87 45,000 (400 Watt $0.18 $0.17 $0.17 126,000 (1,000 Watt) Metal Halide: $1.73 $1.68 $1.65 5,800 (100 Watt) $1.73 $1.68 $1.65 12,000 (175 Watt) $1.73 $1.68 $1.65 16,000 (250 Watt) $1.28 $1.25 $1.22 28,000 (400 Watt) $.035 $0.34 $0.34 88,000 (1,000 Watt)**

Determination of Capital Costs: In the case of newly constructed facilities, capital cost shall include all labor, transportation, material and applicable overheads as defined in the charges for special services contained in Schedule P.S.C. No. 119 - Electricity, or superseding issues thereof, and utilized in recording the cost of such facilities on the books and records of the Corporation. * No longer available for new installations or replacements. ** Available only in Commercial and Industrial Floodlighting applications with base-down orientation of the bulb.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2008

Leaf No. 202.1 Revision: 2 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 5 (Continued) SPECIAL PROVISIONS: (Cont'd) (l) Vandalism: If in the sole opinion of the Corporation, Corporation-owned facilities providing outdoor lighting service similar to Public Street Lighting Service but along private lanes, streets, roads or other such commonly used by-ways become subject to excessive vandalism, the customer shall be required to reimburse the Corporation for all maintenance costs incurred as a result of such vandalism. (m) Budget Billing: Customers may, by signing an application, be billed monthly in accordance with the plan set forth in Section 40 of P.S.C. No. 119 - Electricity or superseding issues thereof. (n) Reserved For Future Use

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 203 New York State Electric & Gas Corporation Revision: 10 Initial Effective Date: September 26, 2010 Superseding Revision: 8 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 6 APPLICABLE TO THE USE OF SERVICE FOR: General Service - Non-Residential Service. (For estimated metered demand of 5 kW or less and use of 2,000 kWh or less per month for any two consecutive months.) CHARACTER OF SERVICE: Continuous - Alternating Current, 60 Cycle; 120, 120/208, 120/240, 208, 240, 240/416, 277/480 or 480 Volts Single or Three Phase. (Also Two Phase in Walden District.) (Characteristics depend upon available circuits and equipment.) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: Pursuant to General Information Section 25, Supply Service Options, customers served under this Service Classification will choose from different electric rate choices offered by the Company as described below. NYSEG will offer a Retail Access rate choice and a Non-Retail Access rate choice. The Retail Access choice is the ESCO Supply Service (ESS). The Non-Retail Access choice is the NYSEG Supply Service (NSS). NYSEG will provide Delivery Service regardless of the customer’s supply service option. 1. ESCO Supply Service (ESS) This Retail Access choice includes fixed charges for NYSEG delivery service and a Transition Charge (NonBypassable Charge [NBC]). Supply service will be provided by an Energy Services Company (ESCO). Customers that elect ESS and receive a Consolidated Bill will not be subject to the Bill Issuance Charge. RATE: (Per Meter, Per Month) Delivery Service: Effective Date 09/01/2011 $17.04 $0.03193

Customer Charge Energy Charge
(All kilowatt-hours, per kilowatt-hour)

09/26/2010 $16.60 $0.03149

09/01/2012 $17.60 $0.03248

Transition Charge All kilowatt-hours, per kilowatt-hour Bill Issuance Charge (per bill):

See Transition Charge Statement $0.73, as described in General Information Section 16.J.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2008

Leaf No. 204 Revision: 5 Superseding Revision: 3

SERVICE CLASSIFICATION NO. 6 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.) Reserved for Future Use

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2008

Leaf No. 205 Revision: 6 Superseding Revision: 4

SERVICE CLASSIFICATION NO. 6 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.) Reserved for Future Use

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 206 Revision: 16 Superseding Revision: 14

SERVICE CLASSIFICATION NO. 6 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.) NYSEG will provide Delivery and Commodity Service for the Non-Retail Access choice. 2. Reserved for Future use

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2008

Leaf No. 206.1 Revision: 2 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 6 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (Cont'd.) Reserved for Future Use.

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 207 New York State Electric & Gas Corporation Revision: 9 Initial Effective Date: September 26, 2010 Superseding Revision: 7 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010
SERVICE CLASSIFICATION NO. 6 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.) 3. NYSEG Supply Service (NSS) This Non-Retail Access choice includes fixed charges for NYSEG delivery service, a Transition Charge (NonBypassable Charge [NBC]), a fluctuating commodity charge for electricity supplied by NYSEG, and a Merchant Function Charge. RATE: (Per Meter, Per Month)

Customer Charge Energy Charge
(All kilowatt-hours, per kilowatt-hour)

09/26/2010 $16.60 $0.03149

Effective Date 09/01/2011 $17.04 $0.03193

09/01/2012 $17.60 $0.03248

Transition Charge All kilowatt-hours, per kilowatt-hour
Commodity Service

See Transition Charge Statement

The charge for Electric Power Supply provided by NYSEG will fluctuate each month as further described in General Information Section 25.I.C., Calculation of the Commodity Charge.

Merchant Function Charge All kilowatt-hours, per kilowatt-hour Bill Issuance Charge (per bill):

See Merchant Function Charge Statement $0.73, as described in General Information Section 16.J.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 208 New York State Electric & Gas Corporation Revision: 22 Initial Effective Date: September 26, 2010 Superseding Revision: 20 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010
SERVICE CLASSIFICATION NO. 6 (Continued) MERCHANT FUNCTION CHARGE: The Merchant Function Charge reflects the administrative costs of obtaining electricity supply, as further explained in General Information Section 25.D. Customers whose electricity is supplied by an ESCO are not charged for this service. MINIMUM CHARGE: The minimum charge for service under this Service Classification is the monthly Customer Charge plus the Bill Issuance Charge, if applicable, as listed above. SURCHARGE TO COLLECT SYSTEM BENEFITS CHARGE ("SBC"): A surcharge will be added to each customer bill for service under this Service Classification to collect the System Benefits Charge (as explained in this Schedule, General Information Section 4). See SBC Statement. RENEWABLE PORTFOLIO STANDARD CHARGE (“RPS”): A surcharge will be added to each customer bill for service under this Service Classification to collect the Renewable Portfolio Standard (as explained in this Schedule, General Information Section 5). See RPS Statement. SURCHARGE TO COLLECT TEMPORARY STATE ASSESSMENT (“TSAS”): A surcharge will be added to each customer bill for service under this Service Classification to collect the Temporary State Assessment (as explained in this Schedule, General Information Section 28). See TSAS Statement.

REVENUE DECOUPLING MECHANISM (“RDM”):
A customer taking service under this Service Classification shall be subject to a Revenue Decoupling Adjustment (as explained in this Schedule, General Information Section 7). See RDM Statement.
INCREASE IN RATES AND CHARGES: The rates and charges under this Service Classification, including minimum charges, will be increased by a surcharge pursuant to Section 6 of PSC No. 120 to reflect the tax rates applicable within the municipality where the customer takes service. TERMS OF PAYMENT: All bills are rendered at the above "unit prices" and that amount is due on bills paid on or before the "past due" date indicted on the bill. A late payment charge at the rate of one and one-half percent (1 1/2%) per month will be billed on all amounts not paid by that date. (Further details in Section 4 of P.S.C. No. 120 - Electricity or superseding issues thereof.) TERM: Single Phase Service: One month and thereafter until terminated by 48 hours' written notice. Three Phase (or Two Phase) Service:

One year and thereafter until terminated by 48 hours' written notice.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 208.1 New York State Electric & Gas Corporation Revision: 6 Initial Effective Date: September 26, 2010 Superseding Revision: 3 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 6 (Continued) SPECIAL PROVISIONS: (Cont’d.) (a) Space Heating Service:
(Service under this provision will no longer be available to new customers after November 1, 1977.)

Any customer using general service under this Service Classification and also using electricity as the sole source of space heating in a premises or segregated portion of a premises may, upon written application to the Corporation, have the energy used for such space heating, as well as air conditioning and water heating for such electrically heated space, separately metered. The separately metered space heating service will be charged under the same rate choice the customer selected for their non-heating service under this Service Classification. The per kilowatt-hour delivery rate for such separately metered space heating service under the selected rate choice is as shown below. There is a separate minimum charge. A complete description of these rate choices appears previously in this Service Classification.
Effective Date 09/26/2010 Energy Charge
(All kilowatt-hours, per kilowatt-hour)

09/01/2011 $0.01124

09/01/2012 $0.01112

$0.01017

Customers are responsible for a separate per kilowatt-hour Transition Charge (Non-Bypassable Charge) and any Commodity and Merchant Function Charges at the same rate associated with the selected rate choice for their non-heating service. The minimum charge is the monthly Customer Charge plus Bill Issuance Charge, if applicable, as listed above.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2007

Leaf No. 209 Revision: 13 Superseding Revision: 12

SERVICE CLASSIFICATION NO. 6 (Continued)
SPECIAL PROVISIONS: (Cont'd.)

(b) Fluctuating Loads: When service is rendered solely for equipment having a fluctuating or large instantaneous demand, such as X-Rays, welders, etc., and a separate or larger transformer for such service is required, the minimum monthly charge will be not less than $.50 per KVA of such additional transformer capacity. (c) Budget Billing: Customers may, by signing an application, be billed monthly in accordance with the plan set forth in Section 4-O of P.S.C. No. 119 - Electricity or superseding issues thereof. (d) Submetering: Submetering may be available according to certain conditions as explained in the general information leaves of this schedule, Section 2. Submetering.

(e) RESERVED FOR FUTURE USE

Issued in compliance with order in Case No. 05-E-1222 dated 08/23/06.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2007

Leaf No. 209.1 Revision: 2 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 6 (Continued) SPECIAL PROVISIONS: (Cont'd.)

(f)

RESERVED FOR FUTURE USE

Issued in compliance with order in Case No. 05-E-1222 dated 08/23/06.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2007

Leaf No. 209.2 Revision: 2 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 6 (Continued) SPECIAL PROVISIONS: (Cont'd.)

(f)

RESERVED FOR FUTURE USE

Issued in compliance with order in Case No. 05-E-1222 dated 08/23/06.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: July 1, 2009

Leaf No. 210 Revision: 7 Superseding Revision: 6

SERVICE CLASSIFICATION NO. 6 (Continued) SPECIAL PROVISIONS: (Cont'd) (g) Economic Incentives: (1) (2) Reserved for Future Use Economic Development Zone Incentive ("EDZI") Customers served under this service classification may qualify for the EDZI Special Provision. See General Information Section 9 of this Schedule for a complete description of the EDZI. (h) Farm Waste Electric Generating System Option: This option is for a customer qualifying for the Farm Waste Electric Generating System Option pursuant to General Information Section 22 of this Schedule and taking service under SC 6. (i) Wind Electric Service Option: This option is for a customer qualifying for the Wind Electric Service Option pursuant to General Information Section 23 of this Schedule and taking service under SC 6. Solar Non-Residential Electric Service Option: This option is for a customer qualifying for the Solar Non-Residential Generating Service Option pursuant to General Information Section 27 of this Schedule and taking service under SC 6. (k) Electric Hybrid Generating System Option: This option is for a customer qualifying for the Electric Hybrid Generating System Option pursuant to General Information Section 24 of this Schedule and taking service under SC 6.

(j)

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 211 New York State Electric and Gas Corporation Revision: 1 Initial Effective Date: September 26, 2010 Superseding Revision: 0 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 7 APPLICABLE TO THE USE OF SERVICE FOR: Large General Service (Primary and Secondary) with Time-of-Use Metering for any customer with a billing demand equal to or greater than 500 KW during any two of the previous twelve months and for continuing service thereafter. Also optional for: This option is not available to Service Classification No. 2 customers, effective December 3, 2002. Customers who qualify under the Economic Development Incentive or the Economic Development "Zone" Incentive Provision of the General Information Section of this Schedule; Customers who qualify under the Controlled Load Service Option of Service Classification No. 3; Customers who qualify under the Agricultural Customers Time-of-Use Service Option of Service Classification No. 2. Note: Other than as set forth above, this service classification is not available to customers otherwise eligible for Residential Service, unless the size and/or nature of the customer's load or its impact on our system requires three phase service.

CHARACTER OF SERVICE: Continuous - Alternating Current, 60 Cycle; Secondary Service at 120, 120/208, 120/240, 208, 240, 240/416, 277/480, or 480 Volts; or Primary (Distribution) Service at 2,400, 4,160, 4,800, 7,200, 8,320, 12,000, 12,470, 13,200, 34,500 or 46,000 Volts; or Subtransmission Service* at 34,500 or 46,000 (Both Non-Regulated) Volts; and 34,500 (Regulated) Volts for "Grandfathered Customers" only*; or Transmission Service at 115,000 Volts and above. Single or Three Phase. (Characteristics depend upon available circuits and equipment.) * Effective September 26, 2010, Subtransmission Service will no longer be available to new service locations. However, grandfathering at the subtransmission rates contained herein will apply to the service location of the current subtransmission class customer, including the site as well as the existing buildings where the customer was taking Subtransmission Service before September 26, 2010. Grandfathering is applicable to any new owner acquiring possession of a grandfathered service location, as long as that customer meets the qualification criteria for grandfathered Subtransmission Service above. The grandfathering may apply to facility replacements and or expansions by customers taking grandfathered Subtransmission Service, if accomplished through existing subtransmission metering points at the service location. . RATE PERIODS: On-peak hours are defined as the hours between 7:00 A.M. and 10:00 P.M. (Local Time), Monday through Friday with the exception of the following holidays: New Year's Day, Memorial Day, Independence Day, Labor Day, Thanksgiving Day and Christmas Day. Those hours not designated as on-peak are defined as off-peak. ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 212 New York State Electric & Gas Corporation Revision: 13 Initial Effective Date: September 26, 2010 Superseding Revision: 12 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010
SERVICE CLASSIFICATION NO. 7 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: Pursuant to General Information Section 25, Supply Service Options, customers served under this Service Classification will choose from different electric rate choices offered by the Company as described below. NYSEG will offer a Retail Access rate choice and Non-Retail Access rate choices as described below. NYSEG will provide Delivery Service regardless of the customer’s Supply Service Option. 1. ESCO Supply Service (ESS) This Retail Access choice includes fixed charges for NYSEG delivery service and a Transition Charge (Non-Bypassable Charge [NBC]). Supply Service will be provided by an Energy Services Company (ESCO). Customers that elect ESS and receive a Consolidated Bill will not be subject to the Bill Issuance Charge. Rate: (Per Meter, Per Month) Delivery Service:
Effective Date VOLTAGE SECONDARY S.C. 7-1 DISTRIBUTION 09/26/2010 $52.66 $2.21 $11.14 $3.10 $8.40 $0.00029 09/01/2011 $70.66 $2.21 $11.14 $3.10 $8.37 $0.00012 09/01/2012 $100.66 $2.21 $11.14 $3.10 $8.24 $0.00000 09/01/2013 $100.66 $2.21 $11.14 $3.10 $8.17 $0.00000 09/01/2014 $100.66 $2.21 $11.14 $3.10 $8.10 $0.00000 09/01/2015 $100.66 $2.21 $11.14 $3.10 $8.03 $0.00000 09/01/2016 $100.66 $2.21 $11.14 $3.10 $7.96 $0.00000

Customer Charge
Meter Ownership Charge Meter Service Charge Meter Data Service Charge (Meter Reading)

Demand Charge
On-Peak Service

Energy Charge
(All kilowatt-hours, per kilowatt-hour)

Reactive Charge
Reactive kilovolt-ampere hours, per billing reactive kilovolt-ampere hour $0.00078 $0.00078 $0.00078 $0.00078 $0.00078 $0.00078 $0.00078

Transition Charge All kilowatt-hours, per kilowatt-hour Bill Issuance Charge (per bill):

See Transition Charge Statement $0.73, as described in General Information Section 16.J

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 213 New York State Electric & Gas Corporation Revision: 12 Initial Effective Date: September 26, 2010 Superseding Revision: 11 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 7 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS (CONT'D.):
. 1. ESCO Supply Service (ESS) (cont’d) Rate: (Per Meter, Per Month) Delivery Service:
Effective Date VOLTAGE PRIMARY S.C. 7-2 DISTRIBUTION 09/26/2010 09/01/2011 09/01/2012 09/01/2013 09/01/2014 09/01/2015 09/01/2016

Customer Charge
Meter Ownership Charge Meter Service Charge Meter Data Service Charge (Meter Reading)

$351.98 $4.91 $24.85 $7.37 $7.27 $0.00129

$367.98 $4.91 $24.85 $7.37 $7.51 $0.00030

$371.98 $4.91 $24.85 $7.37 $7.51 $0.00000

$371.98 $4.91 $24.85 $7.37 $7.18 $0.00000

$371.98 $4.91 $24.85 $7.37 $6.86 $0.00000

$371.98 $4.91 $24.85 $7.37 $6.54 $0.00000

$371.98 $4.91 $24.85 $7.37 $6.20 $0.00000

Demand Charge
On-Peak Service

Energy Charge
(All kilowatt-hours, per kilowatt-hour)

Reactive Charge
Reactive kilovolt-ampere hours, per billing reactive kilovolt-ampere hour

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

Transition Charge All kilowatt-hours, per kilowatt-hour Bill Issuance Charge (per bill):

See Transition Charge Statement $0.73, as described in General Information Section 16.J

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 214 New York State Electric & Gas Corporation Revision: 13 Initial Effective Date: September 26, 2010 Superseding Revision: 12 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010
SERVICE CLASSIFICATION NO. 7 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.) 1. ESCO Supply Service (ESS) (cont’d) Rate: (Per Meter, Per Month) Delivery Service:
Effective Date VOLTAGE PRIMARY S.C. 7-3 SUBTRANSMISSION 09/26/2010 09/01/2011 09/01/2012 09/01/2013 09/01/2014 09/01/2015 09/01/2016

Customer Charge
Meter Ownership Charge Meter Service Charge Meter Data Service Charge (Meter Reading)

$705.25 $5.31 $26.80 $6.75

$779.25 $5.31 $26.80 $6.75

$810.25 $5.31 $26.80 $6.75

$810.25 $5.31 $26.80 $6.75

$810.25 $5.31 $26.80 $6.75

$810.25 $5.31 $26.80 $6.75

$810.25 $5.31 $26.80 $6.75

Demand Charge
On-Peak Service

$3.69 $0.00106

$3.62 $0.00025

$3.37 $0.00000

$3.03 $0.00000

$2.69 $0.00000

$2.35 $0.00000

$1.93 $0.00000

Energy Charge
(All kilowatt-hours, per kilowatt-hour)

Reactive Charge
Reactive kilovolt-ampere hours, per billing reactive kilovolt-ampere hour

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

Transition Charge All kilowatt-hours, per kilowatt-hour Bill Issuance Charge (per bill):

See Transition Charge Statement $0.73, as described in General Information Section 16.J

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 215 New York State Electric & Gas Corporation Revision: 21 Initial Effective Date: September 26, 2010 Superseding Revision: 20 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010
SERVICE CLASSIFICATION NO. 7 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.) 1. ESCO Supply Service (ESS) (cont’d) Rate: (Per Meter, Per Month) Delivery Service:
Effective Date VOLTAGE PRIMARY S.C. 7-4 TRANSMISSION 09/26/2010 09/01/2011 09/01/2012 09/01/2013 09/01/2014 09/01/2015 09/01/2016

Customer Charge
Meter Ownership Charge Meter Service Charge Meter Data Service Charge (Meter Reading)

$1570.05 $9.92 $50.53 $18.61 $1.54 $0.00092

$1770.05 $9.92 $50.53 $18.61 $1.41 $0.00064

$1835.05 $9.92 $50.53 $18.61 $1.48 $0.00000

$1835.05 $9.92 $50.53 $18.61 $1.28 $0.00000

$1835.05 $9.92 $50.53 $18.61 $1.08 $0.00000

$1835.05 $9.92 $50.53 $18.61 $0.88 $0.00000

$1835.05 $9.92 $50.53 $18.61 $0.71 $0.00000

Demand Charge
On-Peak Service

Energy Charge
(All kilowatt-hours, per kilowatt-hour)

Reactive Charge
Reactive kilovolt-ampere hours, per billing reactive kilovolt-ampere hour

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

Transition Charge All kilowatt-hours, per kilowatt-hour Bill Issuance Charge (per bill):

See Transition Charge Statement $0.73, as described in General Information Section 16.J

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 215.1 Revision: 7 Superseding Revision: 6

SERVICE CLASSIFICATION NO. 7 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.)

2. Reserved for Future Use

Issued in compliance with order in Case No. 09-E-0227 dated 09/28/09.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 216 New York State Electric & Gas Corporation Revision: 21 Initial Effective Date: September 26, 2010 Superseding Revision: 20 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 7 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.) 3. NYSEG Supply Service (NSS) This Non-Retail Access choice includes the same fixed charges for NYSEG Delivery Service as the ESCO Supply Service (ESS), a Transition Charge (Non-Bypassable Charge [NBC]), a commodity charge for electricity supplied by NYSEG which fluctuates with the market price of electricity, and a Merchant Function Charge. RATE: (Per Meter, Per Month) Transition Charge All kilowatt-hours, per kilowatt-hour
Commodity Service The charge for Electric Power Supply provided by NYSEG will fluctuate each month as further described in General Information Section 25.I.C., Calculation of the Commodity Charge.

See Transition Charge Statement

Merchant Function Charge All kilowatt-hours, per kilowatt-hour Bill Issuance Charge (per bill):

See Merchant Function Charge Statement $0.73, as described in General Information Section 16.J.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 216.1 Revision: 3 Superseding Revision: 2

SERVICE CLASSIFICATION NO. 7 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.)
4. Hourly Pricing – Mandatory and Voluntary Mandatory Hourly Pricing will be phased in and mandatory for any customer as follows: Effective January 1, 2010 – Customers with billed demand greater than or equal to 300 kW in any two months within the twelve months prior to September 1, 2009. A customer taking service under Hourly Pricing will remain subject to this provision until their monthly metered demand has been less than 300 kW for 12 consecutive months. Customers that received an Economic Incentive or NYPA allocation on or before December 31, 2006, are exempt from mandatory Hourly Pricing as set forth under Voluntary Hourly Pricing.
Economic Development Program SUPPLY SERVICE OPTIONS for customers having a billed demand as set forth above and began receiving the Economic Incentive on or after January 1, 2007 Electricity Supply Pricing Options for the load not receiving the incentive Economic Development Zone Incentive * Incremental Load Incentive * ESS or Hourly Pricing ESS or Hourly Pricing Electricity Supply Pricing Options for load receiving the incentive ESS or Hourly Pricing ESS or Hourly Pricing

* The customer must choose the same Supply Service Option for its incentive, non-incentive load and any future load.
Voluntary: Hourly Pricing is voluntary for any customer taking service under Service Classification No. 7 who does not meet the requirements for Mandatory Hourly Pricing set forth above. Once a customer voluntarily elects Hourly Pricing, they will remain subject to this provision until their monthly metered demand has been less than 300 kW for 12 consecutive months. Hourly Pricing is also voluntary to a customer with load supplied by NYPA beginning on or prior to December 31, 2006, and would have otherwise qualified for Mandatory Hourly Pricing. These customers will have the following Supply Service Options, all described herein, for the non-NYPA load, NSS, ESS, or Hourly Pricing, until the end of their participation in the NYPA program at which time they will be subject to Mandatory Hourly Pricing and have the two supply options ESS or Hourly Pricing, as described below.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 217 Revision: 15 Superseding Revision: 14

SERVICE CLASSIFICATION NO. 7 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.) 4. Hourly Pricing – Mandatory and Voluntary (Cont'd.) Voluntary: (Cont’d.) Additionally, Hourly Pricing is voluntary to a customer that is participating in any of the Company’s Economic Incentives that received the Economic Incentive beginning on or prior to December 31, 2006, and would have otherwise qualified for Mandatory Hourly Pricing until the term of the customer’s Economic Incentive expires. The customer must choose the same Supply Service Option for its incentive, non-incentive load and any future load. Upon the conclusion of their participation in the Economic Incentive, the customer will be subject to Mandatory Hourly Pricing and have two supply options, ESS or Hourly Pricing option, as described below.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 217.1 Revision: 3 Superseding Revision: 2

SERVICE CLASSIFICATION NO. 7 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.)
4. Hourly Pricing – Mandatory and Voluntary (Cont'd.) DELIVERY CHARGES: The delivery charges set forth in this Service Classification for standard service shall apply to a customer taking service under Hourly Pricing. A customer that qualifies for the Economic Development Zone Incentive will pay the delivery charges set forth in the Special Provision (d)(3) Economic Development Zone Incentive. A customer that qualifies for the Industrial/High Load Factor Special Provision will pay the delivery charges as set forth in the Special Provision (h). HOURLY METERING CHARGE: Hourly priced customers are required to pay an incremental meter charge of $7.07 per month, regardless of the Supply Service Option chosen. Customers that have paid for their own meter are exempt from this charge. SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: Customers served under this provision must select from the different electricity Supply Service Options offered by the Company as described below. NYSEG will offer a Retail Access rate choice and a Non-Retail Access rate choice. The Retail Access choice (see 1 below) is the ESCO Supply Service (ESS). The Non-Retail Access choice (see 2 below) is the NYSEG Hourly Day-Ahead Market Pricing Option (“Hourly Pricing”). NYSEG will provide only delivery service for the Retail Access choice. Electricity supply is provided by an Energy Services Company (“ESCO”). Hourly Pricing customers are able to select ESCO commodity service at any time. NYSEG will provide delivery service and commodity service for the Non-Retail Access choice. A customer who has not chosen an option, and for whom NYSEG has not received a retail access enrollment from an ESCO, will default to the NYSEG Hourly Day-Ahead Market Pricing Option. 1. ESCO Supply Service (ESS) This Retail Access choice includes fixed charges for NYSEG delivery service and a Transition Charge set forth on the Transition Charge Statement. Electricity supply is provided by an ESCO. Customers that elect ESS and receive a Consolidated Bill will not be subject to the Bill Issuance Charge. 2. NYSEG Hourly Day-Ahead Market Pricing Option (“Hourly Pricing”) This Non-Retail Access choice includes fixed charges for NYSEG delivery service, a Transition Charge set forth on the Transition Charge Statement, a Merchant Function Charge, and a commodity charge for electricity supply that fluctuates hourly with the market price of electricity including losses, unaccounted for energy, capacity, and capacity reserves, as further described herein. Electricity supply is provided by NYSEG.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 218 Revision: 15 Superseding Revision: 14

SERVICE CLASSIFICATION NO. 7 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.) 4. Hourly Pricing – Mandatory and Voluntary (Cont'd.) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (Cont’d.) 2. NYSEG Hourly Day-Ahead Market Pricing Option (“Hourly Pricing”) (Cont’d.) Electricity Supply Charge: All kilowatthours, per kilowatthour Customers served under this provision will be charged for the energy component of supply based on their hourly metered usage and the hourly supply cost. The electricity supply charge is equal to the sum of the hourly metered usage multiplied by the New York Independent System Operator (NYISO) Day-Ahead Market (DAM) Location Based Marginal Price (LBMP) for the Zone in which the customer is electrically connected, adjusted for system losses (in table below), ancillary services, NTAC, and a Supply Adjustment Charge. Capacity charges will also be based on interval meter data. The DAM LBMP prices will be the initial published DAM LBMP prices acquired by the Company. The customer's bill will not be recalculated if such prices are modified by the NYISO at a later date. Distribution loss factor: Voltage Level Transmission Subtransmission Primary Secondary Service Classification 7-4 7-3 7-2 7-1 Energy Loss Factor 1.0000 1.0150 1.0377 1.0728

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 218.1 Revision: 4 Superseding Revision: 3

SERVICE CLASSIFICATION NO. 7 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.)
4. Hourly Pricing – Mandatory and Voluntary (Cont'd.) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (Cont’d.) 2. NYSEG Hourly Day-Ahead Market Pricing Option (“Hourly Pricing”) (Cont’d.) Electricity Capacity Charge: per month The capacity and capacity reserves are specific to the customer. When hourly data is not available the appropriate service class profile will be used to determine the customer’s capacity responsibility. A new capacity responsibility amount will be established for each customer each April. Customers new to Hourly Pricing that begin the service prior to April will be assigned their capacity responsibility based on their service class profile until the first April where the required hourly data is available. Capacity Charge = UCAP Charge + Demand Curve Reserve Charge UCAP Charge = ((UCAPreq * Lc) * (1 + Reservereq)* Pricemonthlyauc) UCAPreq = The customer specific demand that occurred at the time of the New York system peak of the prior year. When the customer specific information is not available the appropriate service class profile information will be used. Lc = Capacity loss factor: Voltage Level Transmission Subtransmission Primary Secondary Service Classification 7-4 7-3 7-2 7-1 Capacity Loss Factor 1.0000 1.0200 1.0480 1.0738

Reservereq = Additional reserve requirement as required by NYISO. Pricemonthlyauc = Monthly NYISO auction price.

Demand Curve Reserve Charge = ((UCAPreq * Lc) * DemandCurveReservereq)* Pricespotauc) UCAPreq = Described above. Lc = See table above. DemandCurveReservereq = Allocation of additional capacity requirement as required by the NYISO’s demand curve. Pricespotauc = Monthly NYISO auction price.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: January 1, 2008

Leaf No. 219 Revision: 6 Superseding Revision: 4

SERVICE CLASSIFICATION NO. 7 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.)
4. Hourly Pricing – Mandatory and Voluntary (Cont'd.)

METERING AND COMMUNICATION REQUIREMENTS: 1. All customers subject to this special provision are required to have interval metering and remote meter reading capability. Such customers will be responsible for the following: a. the costs of providing remote meter reading capability through dedicated telecommunications to and from the meter; and b. the dedicated telecommunications shall be a land-line connection unless the customer is directed by the Company that a cellular connection is required, and c. all costs associated with the installation, operation and maintenance of the telecommunications line, including but not limited to, all telecommunications service bills. If the Company is unable to read the meter through a customer provided connection, and NYSEG has determined that the problem is not caused by the Company's equipment, the customer shall be responsible for resolution of the problem. The customer shall also be responsible for reimbursement of NYSEG expenses incurred for visits to the meter location to ascertain the cause of the problem, including reimbursing the Company for any expenses the Company incurs, such as, but not limited to, the cost to provide a manual meter read.

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 220 New York State Electric & Gas Corporation Revision: 8 Initial Effective Date: September 26, 2010 Superseding Revision: 6 Issued in compliance with order in Case 09-E-0715 dated September xx, 2010
SERVICE CLASSIFICATION NO. 7 (Continued)

MERCHANT FUNCTION CHARGE: The Merchant Function Charge reflects the administrative costs of obtaining electricity supply. electricity is supplied by an ESCO are not charged for this service. MINIMUM CHARGE: The minimum charge for service under this Service Classification is the monthly Customer Charge as listed above plus the Bill Issuance Charge, if applicable, or unless otherwise stated in the applicable special provisions. The minimum charge for customers who choose to take all or part of their back-up or maintenance service under this service classification rather than under Special Provision (d) of NYSEG's Service Classification No. 11 is described in the "DETERMINATION OF DEMAND" section. REVENUE DECOUPLING MECHANISM (“RDM”): A customer taking service under this Service Classification shall be subject to a Revenue Decoupling Mechanism adjustment as explained in this Schedule, General Information Section 7. Customers taking Transmission service (SC 7-4) are excluded from the RDM. See RDM Statement Customers whose

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 221 Revision: 20 Superseding Revision: 19

SERVICE CLASSIFICATION NO. 7 (Continued)
SURCHARGE TO COLLECT SYSTEM BENEFITS CHARGE ("SBC"): A surcharge will be added to each customer bill for service under this Service Classification to collect the System Benefits Charge (as explained in this Schedule, General Information Section 4). See SBC Statement. Kilowatt-hours

supplied by NYPA are exempt from the System Benefits Charge. RENEWABLE PORTFOLIO STANDARD CHARGE (“RPS”): A surcharge will be added to each customer bill for service under this Service Classification to collect the Renewable Portfolio Standard (as explained in this Schedule, General Information Section 5). See RPS Statement. Kilowatt-hours supplied by NYPA are exempt from the Renewable Portfolio Standard Charge. SURCHARGE TO COLLECT TEMPORARY STATE ASSESSMENT (“TSAS”): A surcharge will be added to each customer bill for service under this Service Classification to collect the Temporary State Assessment (as explained in this Schedule, General Information Section 28). Kilowatt-hours supplied by NYPA are also subject to this surcharge. See TSAS Statement.
COMPETITIVE METERING OPTION: Qualified Customers who select the Competitive Metering Option must comply with the requirements specified in PSC 119 - Electricity and specified in General Information Section 14 of this Schedule, and will not be charged the Meter Ownership, Meter Services and Meter Data Service Charges. METER OWNED BY CUSTOMER, INSTALLED AND MAINTAINED BY THE CORPORATION Customers electing to own their own meters, as described in Section 3.A.2 of PSC 119 - Electricity, will not be charged the Meter Ownership Charge. This provision is separate and distinct from Competitive Metering. INCREASES IN RATES AND CHARGES: The rates and charges under this Service Classification, including the minimum charge, will be increased by a surcharge pursuant to Section 6 of P.S.C. No. 120 to reflect the tax rates applicable within the municipality where the customer takes service. DETERMINATION OF DEMAND: The Determination of Demand will be derived from the on-peak hours only. The metered demand will be the highest average kilowatts used in a fifteen-minute interval during the month. (For customers whose meters are read bi-monthly, the billing demand will be 95% of the metered demand.) For subtransmission and transmission customers also served by the Corporation under Special Provision F of Service Classification No. 10, the measured demand of the output provided by the customer's generating facility will be added to the measured demand as determined by the Corporation's meter for service under this Classification.

Issued in compliance with order in Case No. 09-M-0311 dated 6/19/09.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: November 1, 2009

Leaf No. 222 Revision: 4 Superseding Revision: 2

SERVICE CLASSIFICATION NO. 7 (Continued) DETERMINATION OF DEMAND: (Cont’d.) Customers who choose to take all or part of their back-up or maintenance service under this service classification rather than under Special Provision (d) of NYSEG's Service Classification No. 11 will pay a minimum demand charge as described in NYSEG's Service Classification No. 11. Customers will pay a minimum demand charge related to generation, ancillary, and transmission costs. The minimum demand charge is based on a rate per kW of the contract demand and is accumulated over a 12-month period. The accumulated contract demand charge component will be compared to the accumulated demand charge in this service classification. If the contract demand charge is greater than the demand charge in this service classification, then the customer will only pay the contract demand charge in that month. If it is less than the demand charge in this service classification, then the customer will pay that difference in that month. DETERMINATION OF REACTIVE KILOVOLT-AMPERE HOURS: Whenever the customer's metered demand is 200 KW or more for two consecutive billing periods, the reactive kilovoltampere hours shall thereafter be metered. The billing reactive kilovolt-ampere hours shall be the reactive kilovoltampere hours in excess of one-third of the metered kilowatt hours. Effective 05/01/2010: Whenever the customer’s metered demand is 200 kW or more for two billing periods in any two of the previous twelve (12) months, the reactive kilovolt-ampere hours shall thereafter be metered. The billing reactive kilovoltampere hours will be the reactive kilovolt-ampere hours in excess of one-fourth of the metered kilowatt-hours. TERMS OF PAYMENT: All bills are rendered at the above "unit prices" and that amount is due on bills paid on or before the past due date indicated on the bill. A late payment charge at the rate of one and one-half percent (1 1/2%) per month will be billed on all amounts not paid by that date. (Further details in Section 4 of P.S.C. No. 119 - Electricity or superseding issues thereof.) TERM: One year and thereafter until terminated by 30 days' written notice. However, the Corporation may, with the permission of the Public Service Commission, require the customer to agree to take service at rates from time to time effective for a longer term dependent upon the amount of investment required or other unusual conditions incident to the service. Time-of-use metering and billing will continue even if the customer's demands should remain below 500 KW and as set forth in Special Provision (e) herein. VOLTAGE OPTION: Customers taking service at other than the stated Secondary Voltages shall furnish and maintain the necessary transformer substation. At the discretion of the Corporation, metering for Transmission Service may be on the secondary side of the customer's transformers and calculated transformer losses will be added to measured demand and energy prior to billing. When metering is on the secondary side of the customer's transformers, no load transformer losses will be based on manufacturer's published data for customer's transformers, or equivalent, assuming 730 hours per month. Load losses based on manufacturer's published data for customer's transformer, or equivalent, will be determined by multiplying metered demand and metered energy, respectively, by individually calculated factors developed in accordance with generally accepted engineering principles assuming 730 hours per month and taking cognizance of full load capacity of the customer's transformer, the customer's average peak load and the load factor and average power factor of the load. Such factors will be reviewed annually or as load changes require.

Issued in compliance with order in Case No.08-E-0751 dated 09/22/09.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: January 1, 2006 Effective date postponed to 02/01/06. See Supplement No. 4.

Leaf No. 223 Revision: 1 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 7 (Continued)

SPECIAL PROVISIONS: (a) Budget Billing: Customers may, by signing an application, be billed monthly in accordance with the plan set forth in Section 4-0 of P.S.C. No. 119 - Electricity or superseding issues thereof. (b) Submetering: Submetering may be available according to certain conditions as explained in the General Information leaves of this Schedule, Section 2. Submetering.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 224 Revision: 3 Superseding Revision: 1

SERVICE CLASSIFICATION NO. 7 (Continued)

SPECIAL PROVISIONS: (Cont'd) (c) Reserved for Future Use

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003

Leaf No. 225 Revision: 0 Superseding Revision:

SERVICE CLASSIFICATION NO. 7 (Continued) SPECIAL PROVISIONS: (Cont'd) Service may be interrupted at any time at the discretion of the Corporation; however, interruptions will not exceed 100 hours during any billing month or 600 hours during the billing year. Interruption may be required if the Corporation must purchase Supplemental or Emergency Power from the N.Y. Power Pool, implement voltage reduction, shed load or declare a system emergency due to any other event on its system or within the State. When interruption is required, the load shall be reduced to a level not greater than the contract non-interruptible demand. The Corporation will give as much notice of interruption as possible, but not less than one hour. Notwithstanding this provision, reduction of load greater than the aforementioned amount may be required on a pro rata basis at any time when the Corporation is required to reduce firm loads. Buy-Out Option: If off-system capacity is available, if the Corporation is able to deliver the power to the customer, and if the customer agrees to payment in accordance with this Buy-Out Option of the Interruptible Service Provision, the Corporation will provide power to Transmission Level customers with an interruptible load of 1 MW or more in lieu of interruption. The customer's monthly bill will be calculated in accordance with the applicable Interruptible Service Provision, except that the customer's metered demand levels during the periods in which the "BuyOut" Option is in place will be excluded in determining the customer's highest, monthly, on-peak demand. The customer's monthly bill will then be adjusted as described below to compensate the Corporation for each time the Corporation is able to fulfill the customer's request for power in lieu of interruption. The billing adjustment for energy exceeding the customer's non-interruptible demand will be equal to: (1) The actual cost to the Corporation for the highest cost of energy incurred during the period in which the Buy-Out Option was invoked, adjusted by the factor of adjustment for losses and including components for capacity-related and out-of-pocket costs, plus; $.0165/kWh delivered; less $.02369/kWh delivered, reflecting the Corporation's cost of fuel in base rates; plus $200 administrative fee for each fulfilled purchase-power request during the month.

(2) (3) (4)

The customer will provide the name and telephone number of the customer's representative and a back-up representative to whom the Corporation will provide a price estimate of the "Buy-Out". The customer will also provide a letter to the Corporation authorizing the customer's representatives to authorize the "Buy-Out" Option based on the estimate provided by the Corporation. While the Corporation will endeavor to provide the best available estimate at the time of the "Buy-Out" request, the customer will be obligated to pay the Corporation based on actual costs as described above.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 226 Revision: 6 Superseding Revision: 5

SERVICE CLASSIFICATION NO. 7 (Continued) SPECIAL PROVISIONS: (Cont'd) (d) Economic Incentives: Customer load supplied by the New York Power Authority (NYPA) is not eligible to receive an economic incentive. (1) (2) Reserved for Future Use Economic Development Incentive: As provided in General Information Section 8, this provision is no longer available to additional customers on or after January 1, 2007. Customers who qualify, under the Economic Development Incentive (EDI) in Section 8 of the General Information section of this Schedule, to receive an incentive for load qualified on or after July 1, 2003 may select one of the following rate options, as specified in this Service Classification and Section 25, Supply Service Options, for all of their load: 1) NYSEG Supply Service (NSS) 2) ESCO Supply Service (ESS), or 3) Hourly Pricing. Such customers will receive the incentive for a term of 60 months. Such customers will be exempt from paying the Transition Charge. If it is determined that a bill calculated with the incentive exceeds a bill calculated under the otherwise applicable standard service classification rates, the customer will pay the lower of the two bills.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 227 New York State Electric & Gas Corporation Revision: 6 Initial Effective Date: September 26, 2010 Superseding Revision: 5 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010
SERVICE CLASSIFICATION NO. 7 (Continued) SPECIAL PROVISIONS: (Cont'd) (d) Economic Incentives: (Cont'd) (3) Economic Development Zone Incentive: Customers who qualify, under the Economic Development Zone Incentive (EDZI) in Section 9 of the General Information section of this Schedule, to receive an incentive for load qualified prior to July 1, 2003 shall take service under the NSS or ESS rate, as specified in this Service Classification and Section 25, Supply Service Options, for all of their load. Such customers will have their service bills reduced, for a term of ten (10) years beginning on the date of the qualifying load installation and operation (unless the customer's initial zone certification(s) becomes invalid), by $0.0225 per kilowatt-hour for all qualified kilowatt-hours used thereunder. Customers who qualify, under the Economic Development Zone Incentive (EDZI) in Section 9 of the General Information section of this Schedule, to receive an incentive for load qualified on or after July 1, 2003 may select one of the following rate options, as specified in this Service Classification and Section 25, Supply Service Options, for all of their load: 1) NYSEG Supply Service (NSS), 2) ESCO Supply Service (ESS), or 3) Hourly Pricing. Such customers will receive the incentive for a term of ten (10) years following initial zone certification beginning with the eligibility date on the zone certificate (unless the customer's initial zone certification(s) becomes invalid).

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 228 New York State Electric & Gas Corporation Revision: 20 Initial Effective Date: September 26, 2010 Superseding Revision: 19 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 7 (Continued)
SPECIAL PROVISIONS: (Cont'd) (d) Economic Incentives: (Cont'd) (3) Economic Development Zone Incentive: (Cont'd) All customers will be required to pay Commodity, Merchant Function and Bill Issuance Charges, if applicable, in accordance with the standard NSS, ESS, or Hourly Pricing rates for this Service Classification. Hourly Pricing customers will also be billed the Hourly Metering Charge and Electric Capacity Charge in accordance with the Hourly Pricing rates for this Service Classification. Customers taking service under S.C. 7-1, S.C. 7-2 and S.C. 7-4 will be exempt from paying the Transition Charge. If it is determined that a bill calculated with the incentive exceeds a bill calculated under the otherwise applicable standard service classification rates, the customer will pay the lower of the two bills.

The qualified load receiving the incentive will be billed at the following applicable delivery rates:

Effective Date

VOLTAGE SECONDARY S.C. 7-1 DISTRIBUTION Customer Charge Meter Ownership Charge Meter Service Charge Meter Data Service Charge (Meter Reading) Demand Charge On-Peak Service Energy Charge (All kilowatt-hours, per kilowatt-hour) Reactive Charge Reactive kilovolt-ampere hours, per billing reactive kilovolt-ampere hour

09/26//10 $52.66 $2.21 $11.14 $3.10 $6.47

09/01/11 $70.66 $2.21 $11.14 $3.10 $6.31

09/01/12 $100.66 $2.21 $11.14 $3.10 $6.01

$0.00029 $0.00078

$0.00012 $0.00078

$0.00000 $0.00078

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 229 New York State Electric & Gas Corporation Revision: 19 Initial Effective Date: September 26, 2010 Superseding Revision: 18 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 7 (Continued)
SPECIAL PROVISIONS: (Cont'd) (d) Economic Incentives: (Cont'd) (3) Economic Development Zone Incentive: (Cont'd)

The qualified load receiving the incentive will be billed at the following applicable delivery rates: (Cont’d)

Effective Date VOLTAGE PRIMARY S.C. 7-2 DISTRIBUTION Customer Charge Meter Ownership Charge Meter Service Charge Meter Data Service Charge (Meter Reading) Demand Charge On-Peak Service Energy Charge (All kilowatt-hours, per kilowatt-hour) Reactive Charge Reactive kilovolt-ampere hours, per billing reactive kilovolt-ampere hour 09/26//10 $351.98 $4.91 $24.85 $7.37 09/01/11 $367.98 $4.91 $24.85 $7.37 09/01/12 $371.98 $4.91 $24.85 $7.37

$6.98 $0.00129 $0.00078

$7.33 $0.00030 $0.00078

$7.39 $0.00000 $0.00078

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 230 New York State Electric & Gas Corporation Revision: 19 Initial Effective Date: September 26, 2010 Superseding Revision: 18 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 7 (Continued)
SPECIAL PROVISIONS: (Cont'd) (d) Economic Incentives: (Cont'd) (3) Economic Development Zone Incentive: (Cont'd)

The qualified load receiving the incentive will be billed at the following applicable delivery rates: (Cont’d)

Customers taking service under S.C. 7-3 will be subject to the otherwise applicable standard service classification rates, including the Transition Charge, Commodity, Merchant Function and Bill Issuance Charges, if applicable, System Benefits Charge, Renewable Portfolio Standard, Temporary State Assessment Surcharge, and Revenue Decoupling Mechanism, if applicable, in accordance with the standard NSS, ESS, or Hourly Pricing rates for this Service Classification. Effective Date VOLTAGE PRIMARY S.C. 7-3 SUBTRANSMISSION
Customer Charge Meter Ownership Charge Meter Service Charge Meter Data Service Charge (Meter Reading) Demand Charge On-Peak Service Energy Charge (All kilowatt-hours, per kilowatt-hour) Reactive Charge Reactive kilovolt-ampere hours, per billing reactive kilovolt-ampere hour

09/26/2010
$705.25 $5.31 $26.80 $6.75

09/01/2011
$779.25 $5.31 $26.80 $6.75

09/01/2012
$810.25 $5.31 $26.80 $6.75

$3.69 $0.00106

$3.62 $0.00025

$3.37 $0.00000

$0.00078

$0.00078

$0.00078

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 231 New York State Electric & Gas Corporation Revision: 19 Initial Effective Date: September 26, 2010 Superseding Revision: 18 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 7 (Continued)
SPECIAL PROVISIONS: (Cont'd) (d) Economic Incentives: (Cont'd) (3) Economic Development Zone Incentive: (Cont'd)

The qualified load receiving the incentive will be billed at the following applicable delivery rates: (Cont’d)

Effective Date

VOLTAGE PRIMARY S.C. 7-4 TRANSMISSION Customer Charge Meter Ownership Charge Meter Service Charge Meter Data Service Charge (Meter Reading) Demand Charge On-Peak Service Energy Charge (All kilowatt-hours, per kilowatthour) Reactive Charge Reactive kilovolt-ampere hours, per billing reactive kilovolt-ampere hour

09/26/10 $1,570.05 $9.92 $50.53 $18.61

09/01/11 $1,770.05 $9.92 $50.53 $18.61

09/01/12 $1,835.05 $9.92 $50.53 $18.61

$0.84 $0.00092

$0.91 $0.00064

$1.11 $0.00000

$0.00078

$0.00078

$0.00078

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 232 Revision: 8 Superseding Revision: 7

SERVICE CLASSIFICATION NO. 7 (Continued)
SPECIAL PROVISIONS: (Cont'd) (d) Economic Incentives: (Cont'd) (3) Economic Development Zone Incentive: (Cont'd)

Reserved for Future Use

Issued in compliance with order in Case No. 09-E-0227 dated 09/28/09.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 233 Revision: 9 Superseding Revision: 8

SERVICE CLASSIFICATION NO. 7 (Continued)
SPECIAL PROVISIONS: (Cont'd) (d) Economic Incentives: (Cont'd) (3) Economic Development Zone Incentive: (Cont'd)

Reserved for Future Use

Issued in compliance with order in Case No. 09-E-0227 dated 09/28/09.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: November 1, 2010
Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010.

Leaf No. 234 Revision: 3 Superseding Revision: 2

SERVICE CLASSIFICATION NO. 7 (Continued)
SPECIAL PROVISIONS: (Cont'd) (d) (4) Economic Development Power: Customers who qualify for this special Economic Development Power (EDP) provision pursuant to Section 10 of the General Information section of this Schedule will have such power billed in accordance with the following rate schedule: Unit RATE: (Per Month) Price Customer Charge, Meter Ownership Charge, Meter Service Charge, Meter Data Service Charge Delivery Charge - All kilowatts, per kW (applied to the customer's monthly NYPA Billing Demand) On-Peak Transmission Additional Charge for service below 34.5 kV Primary Secondary Demand Charge - All kilowatts, per kW (applied to the customer's monthly NYPA Billing Demand) NYSEG will charge the customer these charges in accordance with the customer’s Service Classification (S.C.’s 7-1, 7-2, 7-3 or 7-4)

$2.86 $3.81 $4.32

(subject to FERC review, acceptance or approval)

NYSEG will charge the customer a NYPA Demand Charge, for EDP service, equal to the demand and capacity charges that NYSEG is required to pay NYPA for EDP power purchased from NYPA for the customer. NYSEG will charge the customer a NYPA Energy Charge for EDP service equal to the energy charge that NYSEG is required to pay NYPA for EDP power purchased from NYPA for the Customer. $0.00078

Energy Charge - per kWh (applied to the customer's monthly NYPA Billing Energy)

Reactive Charge: Reactive kilovolt-ampere hours, per billing reactive kilovolt-ampere hours

EDP customers may obtain energy loss compensation service, Operating Reserve - Spinning Reserve Service, and Operating Reserve - Supplemental Reserve Service (collectively referred to as "voluntary ancillary services") from NYPA or another supplier other than NYSEG. If such EDP customer chooses to obtain the voluntary ancillary services from NYSEG, they will be provided at the rates and charges included in the then effective OATT, or for loss compensation services at rates and terms mutually agreed upon by NYSEG and such customer. Billing Period:

The billing period for customers served under this special provision shall be the calendar month. When a customer's eligibility for EDP expires, that customer shall revert back to the billing period of the applicable service classification.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003

Leaf No. 235 Revision: 0 Superseding Revision:

SERVICE CLASSIFICATION NO. 7 (Continued) SPECIAL PROVISIONS: (Cont'd) (d) (4) Economic Development Power: (Cont'd) Billing Period: The billing period for customers served under this special provision shall be the calendar month. When a customer's eligibility for EDP expires, that customer shall revert back to the billing period of the applicable service classification. NYPA Contract Demand: In any month that NYPA is unable to deliver to the Corporation, any portion or all of the customer's NYPA Contract Demand, the NYPA Contract Demand shall be adjusted based on the amount of reduced deliveries allocated on a prorata basis across all current EDP contract demands. In such cases, an Adjusted NYPA Contract Demand will be utilized in billing calculations as specified below. Calculation of the Billing Ratio: A Billing Ratio shall be developed for the purpose of identifying the portion of the customer's actual metered demand and energy which was supplied by the Corporation and that supplied by NYPA. The Billing Ratio shall equal the NYPA Contract Demand, or Adjusted NYPA Contract Demand in any month that NYPA is unable to deliver any portion of the customer's NYPA contract demand, divided by the greater of a) the customer's current month maximum metered demand or b) the NYPA Contract Demand, or Adjusted NYPA Contract Demand as appropriate. This Billing Ratio, or the Adjusted Billing Ratio in those months when the Adjusted NYPA Contract Demand is used, will be used to apportion both demand and energy between NYPA and the Corporation. Calculation of Billing Demand: NYPA Billing Demand: The NYPA generated portion of the customer's metered peak demand shall be calculated as the product of multiplying the Billing Ratio (or Adjusted Billing Ratio) by the current month's metered peak demand (as determined under S.C. No. 7, metered peak demand is the highest average kilowatts used in a fifteenminute on-peak interval during the month). The NYPA Billing Demand to be billed at the Economic Development Power rates of this Special Provision shall equal the greater of: a) The above determined NYPA portion of metered peak demand; or b) 75% of the customer's NYPA Contract Demand. In no case shall the NYPA Billing Demand exceed 100% of the NYPA Contract Demand, or Adjusted NYPA Contract Demand, as appropriate. ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 236 Revision: 7 Superseding Revision: 6

SERVICE CLASSIFICATION NO. 7 (Continued) SPECIAL PROVISIONS: (Cont'd.) (d) (4) Economic Development Power: (Cont'd) Non-NYPA Billing Demand: The portion of the customer's metered peak demand Corporation ("Non-NYPA Peak") to be billed at regular Service Classification No. 7 rates shall be calculated by subtracting the above determined NYPA generated portion of the customer's peak demand from the customer's actual metered peak demand. Calculation of Billing Energy: NYPA Billing of Energy: The portion of the customer's monthly metered on-peak and off-peak energy to be billed at the Economic Development Power rates of this Special Provision shall be the product of the customer's metered energy times the above determined Billing ration (or Adjusted Billing Ratio). Non-NYPA Billing of Energy The portion of the customer's metered on-peak and off-peak energy to be billed at regular Service Classification No. 7 rates shall equal metered energy minus the portion identified above as billed at Economic Development rates. Other Billing Adjustments: Increase in Rates applicable in Municipality where serve is supplied shall be applied to the total billing amount. (d) (5) Incubator Development Incentive ("IDI"): As provided in General Information Section 13, this provision is no longer available to additional customers on or after January 1, 2007. Existing customers will be permitted to transition to the Incremental Load Incentive (ILI) as described in Special Provision (d)(10) Incremental Load Incentive and General Information Section 19. Customers who qualify under the Incubator Development Incentive (IDI) in Section 13 of the General Information section of this Schedule prior to July 1, 2003 shall take service under the NSS or ESS rate, as specified in this Service Classification and Section 25, Supply Service Options, for all of their load.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 237 Revision: 6 Superseding Revision: 5

SERVICE CLASSIFICATION NO. 7 (Continued) SPECIAL PROVISIONS: (Cont'd.)

(d) (6)

Reserved for Future Use

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 238 New York State Electric and Gas Corporation Revision: 3 Initial Effective Date: September 26, 2010 Superseding Revision: 2 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 7 (Continued)
SPECIAL PROVISIONS: (Cont'd.) (d) (7) Power for Jobs: Customers who qualify for Power for Jobs ("PFJ") pursuant to Section 15 of the General Information section of this Schedule will have such power billed in accordance with the following rate schedule: Unit Price NYSEG will charge the customer these charges in accordance with the customer’s Service Classification (S.C.’s 7-1, 7-2, 7-3 or 7-4) NYSEG will charge the customer a NYPA Demand Charge for PFJ service. In any month the NYPA demand charge shall be equal to the capacity charge that NYSEG is required to pay to NYPA for PFJ power purchased from NYPA. NYSEG will charge the customer a NYPA Energy Charge for PFJ service. In any month the NYPA energy charge shall be equal to the energy charge that NYSEG is required to pay to NYPA for PFJ power purchased from NYPA. NYSEG will charge the customer a NYPA Energy Charge Adjustment for PFJ service. In any month the NYPA energy charge adjustment shall be equal to the energy charge adjustment that NYSEG is required to pay to NYPA for PFJ power purchased from NYPA

RATE: (Per Month) Customer Charge, Meter Ownership Charge, Meter Service Charge, Meter Data Service Charge Demand Charge, per kW (applied to the customer's monthly NYPA Billing Demand, adjusted for losses)

Energy Charge, per kWh (applied to the customer's monthly NYPA Billing Energy, adjusted for losses)

Energy Charge Adjustment per kWh (applied to the customer's monthly NYPA Billing Energy, adjusted for losses)

Delivery Charge below 34.5kV, per kW (applied to the customer's monthly NYPA billing demand, adjusted for losses) Primary Secondary

$3.81 $4.32

Reactive Charge: Reactive kilovolt-ampere hours, per billing reactive kilovolt-ampere hours

$0.00078

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003

Leaf No. 239 Revision: 0 Superseding Revision:

SERVICE CLASSIFICATION NO. 7 (Continued) SPECIAL PROVISIONS: (Cont'd.) (d) (7) Power for Jobs: (Cont'd) Billing Period: The billing period for customers served under this special provision shall be the customer's regular billing cycle, provided that the customer is billed on a monthly basis. Customer accounts billed normally on a bimonthly basis, will be billed monthly for the duration the customer continues service under the PFJ program. When a customer's eligibility for PFJ expires, that customer shall revert back to the rates, terms, and allowed billing period of an otherwise applicable service classification. NYPA PFJ Contract Demand and NYPA Adjusted PFJ Contract Demand: NYPA Contract Demand is the Allocation approved for each customer per the customer's contract with NYPA. In any month that NYPA is unable to deliver to the Corporation, any portion or all of the customer's NYPA Contract Demand, the NYPA Contract Demand shall be adjusted based on the amount of reduced deliveries allocated on a pro rata basis across all current PFJ Contract Demands. In such cases, an Adjusted NYPA Contract Demand will be utilized in billing calculations as specified below. Calculation of the Billing Ratio for PFJ Customers : A Billing Ratio will be developed for the purpose of identifying the portion of the customer's actual metered demand and energy which was supplied by the Corporation and that supplied by NYPA. The Billing Ratio will equal the NYPA Contract Demand, or Adjusted Contract Demand in any month that NYPA is unable to deliver any portion of the customer's NYPA Contract Demand, divided by the greater of a) the customer's current month maximum metered demand or b) the NYPA Contract Demand, or Adjusted NYPA Contract Demand, as appropriate. This Billing Ratio, or the Adjusted Billing Ratio in those months when the Adjusted NYPA Contract Demand is used, will be used to apportion both demand and energy between NYPA and the Corporation.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003

Leaf No. 240 Revision: 0 Superseding Revision:

SERVICE CLASSIFICATION NO. 7 (Continued) SPECIAL PROVISIONS: (Cont'd.) (d)(7) Power for Jobs: (Cont'd) Calculation of Billing Demand: NYPA Billing of PFJ Demand: The NYPA provided portion of the customer's metered peak demand shall be calculated as the product of multiplying the appropriate Billing Ratio by the current month's maximum metered demand. In no case shall the NYPA Billing Demand exceed 100% of the NYPA Contract Demand, or Adjusted NYPA Contract Demand, as appropriate. Non-NYPA Billing Demand: The portion of the customer's metered peak demand ("Non-NYPA Peak") to be billed at standard S.C. No, 7 rates will be calculated by subtracting the above determined NYPA provided portion of the customer's metered on-peak demand from the customer's actual metered on-peak demand. Calculation of Billing Energy: NYPA Billing of PFJ Energy: The portion of the customer's monthly metered on-peak and off-peak energy to be billed at the PFJ rates will be the product of the appropriate Billing Ratio times both the customer's metered on-peak energy and off-peak energy. Non-NYPA Billing of Energy: The portion of the customer's monthly metered on-peak and off-peak energy to be billed at standard S.C. No. 7 rates shall equal metered on-peak energy and off-peak energy minus the portion identified above as billed at PFJ rates.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003

Leaf No. 241 Revision: 0 Superseding Revision:

SERVICE CLASSIFICATION NO. 7 (Continued) SPECIAL PROVISIONS: (Cont'd.) (d)(7) Power for Jobs: (Cont'd) Minimum Bill: In any billing period each customer is subject to a minimum bill as follows: 1. 2. 3. Monthly minimum billed charges of the standard S.C. No. 7 retail service classification. Bundled commodity and transmission charges billed by NYPA and incurred by NYSEG on the customer's behalf. Energy Adjustment Charge as applicable.

Increases in Rates and Charges: Increase in rates applicable in Municipality where service is supplied shall be applied to the individual rates and charges applied to service provided herein. (d)(8) Business Retention Incentive ("BRI") This provision expired on March 2, 2003. Any customers who were receiving the BRI discount as of that date may transition to the Economic Revitalization Incentive (ERI), as described in General Information Section 7 of this Schedule, for the remainder of their five-year term. The transition will be based on the start date of their BRI discount, and the following incentive rate reductions will apply: ! ! ! A customer in the first, second, or third year of BRI would receive the full ERI reduction for those years. A customer in the fourth year of BRI would receive the ERI reduction multiplied by a factor of .66 for that year. A customer in the fifth (and final) year of BRI would receive the ERI reduction multiplied by a factor of .33 for that year.

(d)(9)

High Load Factor Manufacturer Power ("HLFM") Before service will commence under this Special Provision, the Corporation and NYPA must execute an agreement governing additional terms of HLFM service. During the Price Cap Period (March 3, 1998 through March 2, 2003) customers who qualify for this special HLFM power provision, pursuant to Section 18 of the General Information section of this Schedule, provided such load was not previously served by NYSEG, will have such power billed in accordance with the following rate schedule:

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: November 1, 2009

Leaf No. 242 Revision: 2 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 7 (Continued) SPECIAL PROVISIONS: (Cont'd.) (d) (9) High Load Factor Manufacturer Power ("HLFM") (Cont'd.) RATE: (Per Month) Unit Price

The Customer Charge Per Meter is set forth in the non-special provision rates section of this service classification. Delivery Charge - All kilowatts, per kW (applied to the customer's monthly NYPA Billing Demand, adjusted for losses) On-Peak Transmission

NYSEG's then applicable OATT service rate (subject to FERC review, acceptance or approval) $ 3.81 $ 4.32 NYSEG will charge the customer for a NYPA Demand Charge for HLFM service subject to the execution of an agreement with NYPA for HLFM service. NYSEG will charge the customer a NYPA Energy Charge for HLFM service subject to the execution of an agreement with NYPA for HLFM service. $0.00095

Additional Charge for service below 34.5 kV Primary Secondary Demand Charge - All kilowatts, per kW (applied to the customer's monthly NYPA Billing Demand, adjusted for losses) Energy Charge - per kWh (applied to the customer's monthly NYPA Billing Energy, adjusted for losses) Reactive Charge: * Reactive kilovolt-ampere hours, per billing reactive kilovolt-ampere hours

* Effective 05/01/2010, the Reactive Charge will be $0.00078. HLFM customers may obtain energy loss compensation service, Operating Reserve - Spinning Reserve Service, and Operating Reserve - Supplemental Reserve Service (collectively referred to as "voluntary ancillary services") from NYPA or another supplier other than NYSEG. If such HLFM customer chooses to obtain the voluntary ancillary services from NYSEG, they will be provided at the rates and charges included in the then effective OATT, or for loss compensation services at rates and terms mutually agreed upon by NYSEG and such customer. Other Billing Adjustments: Increase in Rates applicable to Municipality where service is supplied shall be applied to the amounts billed. Billing: Billing provisions related to HLFM service will be subject to the execution of an agreement by the Corporation with NYPA related to the provision of HLFM service.
Issued in compliance with order in Case No. 08-E-0751 dated 09/22/09.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 243 New York State Electric & Gas Corporation Revision: 8 Initial Effective Date: September 26, 2010 Superseding Revision: 7 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010
SERVICE CLASSIFICATION NO. 7 (Continued) SPECIAL PROVISIONS: (Cont'd.) (d) (10) Incremental Load Incentive (ILI) Customers who qualify under the Incremental Load Incentive (ILI) in Section 19 of the General Information section may select one of the following rate options, as specified in this Service Classification and Section 25, Supply Service Options, for all of their load: 1) NYSEG Supply Service (NSS), 2) ESCO Supply Service (ESS), or 3) Hourly Pricing. Such customers will receive the incentive for a term of 60 months. Customers taking service under S.C. 7-1, S.C. 7-2 and S.C. 7-4 will be exempt from paying the Transition Charge. If it is determined that a bill calculated with the incentive exceeds a bill calculated under the otherwise applicable standard service classification rates, the customer will pay the lower of the two bills. Customers taking service under S.C. 7-3 will be subject to the otherwise applicable standard service classification rates, including the Transition Charge (Non-Bypassable Charge), Commodity, Merchant Function and Bill Issuance Charges, if applicable, System Benefits Charge, Renewable Portfolio Standard, Temporary State Assessment Surcharge, and Revenue Decoupling Mechanism, if applicable Qualified load receiving the incentive will be billed at the following applicable delivery rates: Effective Date

VOLTAGE SECONDARY S.C. 7-1 DISTRIBUTION Customer Charge Meter Ownership Charge Meter Service Charge Meter Data Service Charge (Meter Reading) Demand Charge On-Peak Service Energy Charge (All kilowatt-hours, per kilowatt-hour) Reactive Charge Reactive kilovolt-ampere hours, per billing reactive kilovolt-ampere hour

09/26//10 $52.66 $2.21 $11.14 $3.10 $7.43

09/01/11 $70.66 $2.21 $11.14 $3.10 $7.34

09/01/12 $100.66 $2.21 $11.14 $3.10 $7.13

$0.00029 $0.00078

$0.00012 $0.00078

$0.00000 $0.00078

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 243.1 New York State Electric & Gas Corporation Revision: 4 Initial Effective Date: September 26, 2010 Superseding Revision: 2 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 7 (Continued) SPECIAL PROVISIONS: (Cont'd.)
(d) (10) Incremental Load Incentive (ILI) (Cont’d) Qualified load receiving the incentive will be billed at the following applicable delivery rates: Effective Date VOLTAGE PRIMARY S.C. 7-2 DISTRIBUTION Customer Charge Meter Ownership Charge Meter Service Charge Meter Data Service Charge (Meter Reading) Demand Charge On-Peak Service Energy Charge (All kilowatt-hours, per kilowatt-hour) Reactive Charge Reactive kilovolt-ampere hours, per billing reactive kilovolt-ampere hour 09/26//10 $351.98 $4.91 $24.85 $7.37 09/01/11 $367.98 $4.91 $24.85 $7.37 09/01/12 $371.98 $4.91 $24.85 $7.37

$7.12 $0.00129 $0.00078

$7.42 $0.00030 $0.00078

$7.45 $0.00000 $0.00078

Effective Date VOLTAGE PRIMARY S.C. 7-4 TRANSMISSION Customer Charge Meter Ownership Charge Meter Service Charge Meter Data Service Charge (Meter Reading) Demand Charge On-Peak Service Energy Charge (All kilowatt-hours, per kilowatt-hour) Reactive Charge Reactive kilovolt-ampere hours, per billing reactive kilovolt-ampere hour 09/26/10 $1,570.05 $9.92 $50.53 $18.61 $1.19 $0.00092 $0.00078 09/01/11 $1,770.05 $9.92 $50.53 $18.61 $1.16 $0.00064 $0.00078 09/01/12 $1,835.05 $9.92 $50.53 $18.61 $1.30 $0.00000 $0.00078

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 243.2 New York State Electric & Gas Corporation Revision: 3 Initial Effective Date: September 26, 2010 Superseding Revision: 2 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010

SERVICE CLASSIFICATION NO. 7 (Continued) SPECIAL PROVISIONS: (Cont'd.)
(d) (10) Incremental Load Incentive (ILI) (Cont’d)

Customers transitioning from the Incubator Development Incentive will be phased in as follows: Per kilowatt-hour, for all qualified kilowatt-hours Effective Date 01/01/2010 01/01/2011 $0.010 $0.005

At any time during the phase in, an IDI customer may make a one-time election to receive the ILI discount on the qualified kilowatt-hours instead of the phase in. Once a customer has made this election, they will not be allowed to return to the phase in. (e) Billing Duration: Service Classification No. 2 customers who opt for service under Service Classification No. 7 for the first time must remain on the Time-Of-Use rate for a period of not less than six months prior to becoming eligible to return to Service Classification No. 2. If a customer returns to Service Classification No. 2, the customer must remain a Service Classification No. 2 customer for at least 18 months before again becoming eligible for Service Classification No. 7. If the customer again opts for Service Classification No. 7, the customer must remain on Service Classification No. 7 in conformance with the TERM as set forth herein.

(f) (g)

RESERVED FOR FUTURE USE RESERVED FOR FUTURE USE

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2008

Leaf No. 244 Revision: 2 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 7 (Continued)
SPECIAL PROVISIONS: (Cont'd.) (h) Industrial/High Load Factor ("I/HLF") Rate Provision: (1) Available to a customer's account that meets usage eligibility as defined in (2) or (3) of this section. Customers who are taking service under NYSEG's Economic Development Incentive, Economic Development Zone Incentive, New York Power Authority (NYPA) programs (Expansion Power, Economic Development Power, Power for Jobs, Replacement Power, High Load Factor Manufacturer and Preservation Power), Interruptible Service or S.C. 14 may take service under this rate provision, only for that portion of their load served at NYSEG's standard tariff rate, provided that the non-discounted load meets the eligibility requirements of this special provision. Allocation of billing units (kW, kWh, rkvah) for partial load is explained in (4) of this section. Any customer taking service under the Economic Revitalization Incentive and choosing instead to take service under this Rate Provision, must have met or agrees to continue to meet its Economic Revitalization commitments. Recipients of NYSEG incentive rates applicable to their entire load may qualify for this special provision by relinquishing eligibility under the incentive, provided that they meet the eligibility requirements of this special provision. (2) Eligibility: Eligibility will be determined based on the total metered demand and energy excluding the NYPA portion of that metered amount. (i) Industrial Rate Provision: Applicable to new or existing Industrial customers' accounts (NYSEG's Revenue Class 30) as defined in Division "D" of the Standard Industrial Classification Manual that are engaged in manufacturing (SIC Major Codes 20-39) or mining (SIC Major Codes 10-14), and that have an average annual demand of 500 kilowatts or greater during the previous 12 months. Average annual demand for this provision is calculated as follows: D/M D= Annual demands. For existing customers this will be the sum of the actual billed on-peak demands during the most recent 12 consecutive months. For new customers or customers with incomplete history, the 12 months of on-peak demand will be estimated by the Corporation from engineering and operating estimates to fit within the annual time period.

M=

Total number of billing months. For existing customers this will be the sum of the actual number of billing periods during the most recent 12 consecutive months. For new customers with 12 estimated demands this will be 12.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003

Leaf No. 245 Revision: 0 Superseding Revision:

SERVICE CLASSIFICATION NO. 7 (Continued) SPECIAL PROVISIONS: (Cont'd.) (h) Industrial/High Load Factor Rate Provision (Cont'd.): (2) Eligibility (Cont'd.) (ii) High Load Factor Rate Provision : Applicable to an existing customer's account having an annual load factor of 68.0% or greater (approximately 500 hours' average use of kW demand per month). Also applicable to a new customer's account with an estimated annual load factor of 68.0% or greater. Annual load factor for this provision is calculated as follows: A/(D*H) A = Annual kWh. For existing customers this will be the actual total energy usage billed during the most recent 12 consecutive months. For new customers or customers with incomplete history, the annual usage will be estimated by the Corporation from engineering and operating estimates to fit within the time period. D = Maximum demand. For existing customers this will be the highest billed on-peak demand during the most recent 12 consecutive months. For new customers or customers with incomplete history, the demand will be estimated by the Corporation from engineering and operating estimates to fit within the time period. H = Number of total hours in the annual billing period. Any customer taking service under the Business Retention Incentive or the Economic Revitalization Incentive may, if otherwise qualified, choose instead to take service under this Rate Provision, provided that the customer has met or agrees to continue to meet its Business Retention or Economic Revitalization commitments. (3) Rate Qualification Review: Each account will be reviewed annually to verify continued qualification, based on usage during the previous year. Such review shall occur 12 months after the initiation of this rate provision, and shall be repeated each year thereafter. (i) To maintain qualification for the Industrial provision, the average annual demand of a customer's account, as determined above, must be 500 kW or greater. To maintain qualification for the High Load Factor provision, the annual load factor for a customer's account, as determined above, must be 68.0% or greater.

(ii)

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003

Leaf No. 246 Revision: 0 Superseding Revision:

SERVICE CLASSIFICATION NO. 7 (Continued) SPECIAL PROVISIONS: (Cont'd.) (h) Industrial/High Load Factor Rate Provision (Cont'd.): (4) Allocation of Billing Units for Partial Load Billing units (kW, kWh, rkvah) will be allocated between the Industrial/High Load Factor and Economic incentives or Interruptible portions of the customer's bill based on the following formulas: (i) Economic Incentive B T EKWH EKW NKW = Billing kW = Total kWh = Incented kWh = Incented kW = Non-incented kW (EKWH / T) x B = EKW B - EKW = NKW (ii) Interruptible Incentive D C A H IKW R K T NKWH = = = = = = = = = Maximum on-peak metered demand Contract non-interruptible demand. This is the firm power contracted for by the customer for use during periods of interruption. Average interruptible hours per month (600/12=50) Average number of hours per month (730) Interruptible KW. This is the on-peak demand minus the contract noninterruptible demand Ratioed interruptible KW KWH associated with the interruptible demand Total KWH for the billing period Non-interruptible KWH (eligible for the Industrial/HLF discount)

(A / H) x IKW = R (R / D) x T = K T - K = NKWH

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 247 New York State Electric & Gas Corporation Revision: 13 Initial Effective Date: September 26, 2010 Superseding Revision: 12 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 7 (Continued) SPECIAL PROVISIONS: (Cont'd) (h) Industrial/High Load Factor Rate Provision (Con'td.): (4) Rate for Industrial/High Load Factor Service: (Per Month) A complete description of the Supply Service Options appears previously in this Service Classification. Customers taking service under NSS will pay Commodity and Merchant Function Charges in accordance with the standard NSS rates for the Service Classification. Delivery Rates for ESS and NSS under the Industrial/High Load Factor Special Provision are as follows: Rate: (Per Meter, Per Month)
Effective Date VOLTAGE SECONDARY SC 7-1 DISTRIBUTION Customer Charge Meter Ownership Charge Meter Service Charge Meter Data Service Charge (Meter Reading) Demand Charge On-Peak Service Energy Charge All kilowatt-hours, per kilowatt-hour Reactive Charge Reactive kilovolt-ampere hours, per billing reactive kilovolt-ampere hour $4.38 $0.00069 $5.11 $0.00060 $6.04 $0.00000 $6.52 $0.00000 $7.00 $0.00000 $7.48 $0.00000 $7.96 $0.00000 09/26/2010 $52.66 $2.21 $11.14 $3.10 09/01/2011 $70.66 $2.21 $11.14 $3.10 09/01/2012 $100.66 $2.21 $11.14 $3.10 09/01/2013 $100.66 $2.21 $11.14 $3.10 09/01/2014 $100.66 $2.21 $11.14 $3.10 09/01/2015 $100.66 $2.21 $11.14 $3.10 09/01/2016 $100.66 $2.21 $11.14 $3.10

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

Transition Charge All kilowatt-hours, per kilowatt-hour Bill Issuance Charge (per bill):

See Transition Charge Statement $0.73 as described in General Information Section 16.J.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 248 New York State Electric & Gas Corporation Revision: 21 Initial Effective Date: September 26, 2010 Superseding Revision: 20 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010
SERVICE CLASSIFICATION NO. 7 (Continued) SPECIAL PROVISIONS: (Cont'd) (h) Industrial/High Load Factor Rate Provision (Cont’d.): (4) Rate for Industrial/High Load Factor Service: (Per Month) (Cont'd.)

Delivery Rates for ESS and NSS under the Industrial/High Load Factor Special Provision are as follows (cont’d): Rate: (Per Meter, Per Month)
Effective Date VOLTAGE PRIMARY SC 7-2 DISTRIBUTION Customer Charge Meter Ownership Charge Meter Service Charge Meter Data Service Charge (Meter Reading) Demand Charge On-Peak Service Energy Charge All kilowatt-hours, per kilowatt-hour Reactive Charge Reactive kilovolt-ampere hours, per billing reactive kilovolt-ampere hour $3.29 $0.00202 $3.86 $0.00166 $5.07 $0.00000 $5.35 $0.00000 $5.63 $0.00000 $5.91 $0.00000 $6.20 $0.00000 09/26/2010 $351.98 $4.91 $24.85 $7.37 09/01/2011 $367.98 $4.91 $24.85 $7.37 09/01/2012 $371.98 $4.91 $24.85 $7.37 09/01/2013 $371.98 $4.91 $24.85 $7.37 09/01/2014 $371.98 $4.91 $24.85 $7.37 09/01/2015 $371.98 $4.91 $24.85 $7.37 09/01/2016 $371.98 $4.91 $24.85 $7.37

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

Transition Charge All kilowatt-hours, per kilowatt-hour Bill Issuance Charge (per bill):

See Transition Charge Statement $0.73 as described in General Information Section 16.J.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2008

Leaf No. 248.1 Revision: 2 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 7 (Continued) SPECIAL PROVISIONS: (Cont’d.) (h) Industrial/High Load Factor Rate Provision (Cont’d.): (4) Rate for Industrial/High Load Factor Service: (Per Month) (Cont'd.) Reserved for Future Use

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 249 New York State Electric & Gas Corporation Revision: 21 Initial Effective Date: September 26, 2010 Superseding Revision: 20 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 7 (Continued) SPECIAL PROVISIONS: (Cont’d.) (h) Industrial/High Load Factor Rate Provision (Cont’d.): (4) Rate for Industrial/High Load Factor Service: (Per Month) (Cont'd.) Delivery Rates for ESS and NSS under the Industrial/High Load Factor Special Provision are as follows (cont’d): Rate: (Per Meter, Per Month)
Effective Date VOLTAGE PRIMARY SC 7-3 SUBTRANSMISSION Customer Charge Meter Ownership Charge Meter Service Charge Meter Data Service Charge (Meter Reading) Demand Charge On-Peak Service Energy Charge All kilowatt-hours, per kilowatt-hour Reactive Charge Reactive kilovolt-ampere hours, per billing reactive kilovolt-ampere hour $0.42 $0.00145 $0.78 $0.00102 $1.43 $0.00000 $1.55 $0.00000 $1.67 $0.00000 $1.79 $0.00000 $1.93 $0.00000 09/26/2010 $705.25 $5.31 $26.80 $6.75 09/01/2011 $779.25 $5.31 $26.80 $6.75 09/01/2012 $810.25 $5.31 $26.80 $6.75 09/01/2013 $810.25 $5.31 $26.80 $6.75 09/01/2014 $810.25 $5.31 $26.80 $6.75 09/01/2015 $810.25 $5.31 $26.80 $6.75 09/01/2016 $810.25 $5.31 $26.80 $6.75

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

Transition Charge All kilowatt-hours, per kilowatt-hour Bill Issuance Charge (per bill):

See Transition Charge Statement $0.73 as described in General Information Section 16.J.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2008

Leaf No. 249.1 Revision: 2 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 7 (Continued) SPECIAL PROVISIONS: (Cont’d.) (h) Industrial/High Load Factor Rate Provision (Cont’d.): (4) Rate for Industrial/High Load Factor Service: (Per Month) (Cont'd.) Reserved for Future Use

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 250 New York State Electric & Gas Corporation Revision: 21 Initial Effective Date: September 26, 2010 Superseding Revision: 20 Issued in compliance with Order in Case 9-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 7 (Continued) SPECIAL PROVISIONS: (Cont’d.) (h) Industrial/High Load Factor Rate Provision (Cont’d.) (4) Rate for Industrial/High Load Factor Service: (Per Month) (Cont’d.) Delivery Rates for ESS and NSS under the Industrial/High Load Factor Special Provision are as follows (cont’d): Rate: (Per Meter, Per Month)
Effective Date VOLTAGE PRIMARY SC 7-4 TRANSMISSION Customer Charge Meter Ownership Charge Meter Service Charge Meter Data Service Charge (Meter Reading) Demand Charge On-Peak Service Energy Charge All kilowatt-hours, per kilowatt-hour Reactive Charge Reactive kilovolt-ampere hours, per billing reactive kilovolt-ampere hour $0.15 $0.00107 $0.29 $0.00076 $0.59 $0.00000 $0.62 $0.00000 $0.65 $0.00000 $0.68 $0.00000 $0.71 $0.00000 09/26/2010 $1570.05 $9.92 $50.53 $18.61 09/01/2011 $1770.05 $9.92 $50.53 $18.61 09/01/2012 $1835.05 $9.92 $50.53 $18.61 09/01/2013 $1835.05 $9.92 $50.53 $18.61 09/01/2014 $1835.05 $9.92 $50.53 $18.61 09/01/2015 $1835.05 $9.92 $50.53 $18.61 09/01/2016 $1835.05 $9.92 $50.53 $18.61

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

$0.00078

Transition Charge All kilowatt-hours, per kilowatt-hour Bill Issuance Charge (per bill):

See Transition Charge Statement $0.73 as described in General Information Section 16.J.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2008

Leaf No. 250.1 Revision: 2 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 7 (Continued) SPECIAL PROVISIONS: (Cont’d.) (h) Industrial/High Load Factor Rate Provision (Cont’d.): (4) Rate for Industrial/High Load Factor Service: (Per Month) (Cont'd.) Reserved for Future Use

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 251 Revision: 20 Superseding Revision: 19

SERVICE CLASSIFICATION NO. 7 (Continued) SPECIAL PROVISIONS: (Cont'd.) (h) Industrial/High Load Factor Rate Provision (Cont’d.): (4) Rate for Industrial/High Load Factor Service: (Per Month) (Cont'd.) b. Reserved for Future Use

Issued in compliance with order in Case No. 09-E-0227 dated 09/28/09.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2008

Leaf No. 251.1 Revision: 2 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 7 (Continued) SPECIAL PROVISIONS: (Cont’d.) (h) Industrial/High Load Factor Rate Provision (Cont’d.): (4) Rate for Industrial/High Load Factor Service: (Per Month) (Cont'd.) Reserved for Future Use

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 252 New York State Electric & Gas Corporation Revision: 12 Initial Effective Date: September 26, 2010 Superseding Revision: 11 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 7 (Continued) SPECIAL PROVISIONS: (Cont'd) (h) Industrial/High Load Factor Rate Provision (Cont’d.): (4) Rate for Industrial/High Load Factor Service: (Per Month) (Cont'd.) Reserved for Future Use

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: January 1, 2008

Leaf No. 253 Revision: 4 Superseding Revision: 2

SERVICE CLASSIFICATION NO. 7 (Continued) SPECIAL PROVISIONS: (Cont'd) Reserved for Future Use

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: January 1, 2008

Leaf No. 254 Revision: 4 Superseding Revision: 2

SERVICE CLASSIFICATION NO. 7 (Continued) SPECIAL PROVISIONS: (Cont'd) Reserved for Future Use

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: January 1, 2008

Leaf No. 254.1 Revision: 2 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 7 (Continued) SPECIAL PROVISIONS: (Cont'd) Reserved for Future Use

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: January 1, 2008

Leaf No. 254.2 Revision: 1 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 7 (Continued) SPECIAL PROVISIONS: (Cont'd) Reserved for Future Use

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: January 1, 2008

Leaf No. 254.3 Revision: 2 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 7 (Continued) SPECIAL PROVISIONS: (Cont'd) Reserved for Future Use

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: January 1, 2008

Leaf No. 254.4 Revision: 1 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 7 (Continued) SPECIAL PROVISIONS: (Cont'd) Reserved for Future Use

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: July 1, 2009

Leaf No. 255 Revision: 3 Superseding Revision: 2

SERVICE CLASSIFICATION NO. 7 (Continued) SPECIAL PROVISIONS: (Cont'd.) (k) C.A.$.H.BACK Special Provision The Company will provide a voluntary program for load normally supplied and delivered by NYSEG, for eligible customers to curtail load. NYSEG's program, entitled C.A.$.H.BACK, implements the NYISO's day-ahead economic load-curtailment program. Under this program, a customer agrees to curtail load when their bid is submitted and accepted by the NYISO. Customers who are qualified under C.A.$.H.BACK in Section 21 of the General Information section of this Schedule may participate in the NYSEG C.A.$.H.BACK Program as set forth therein. (l) Farm Waste Electric Generating System Option: This option is for a customer qualifying for the Farm Waste Electric Generating System Option pursuant to General Information Section 22 of this Schedule and taking service under SC 7. If electricity (kWh) supplied by the customer to the Corporation is not metered for the time-differentiated periods, an allocation to each TOU period will be done according to allocation factors as described herein. Forty-seven percent (47%) of the excess electricity (kWh) supplied by the customer will be considered On-Peak. Fifty-three percent (53%) of the excess electricity (kWh) will be considered Off-Peak. (m) Wind Electric Service Option: This option is for a customer qualifying for the Wind Non-Residential Service Option pursuant to General Information Section 23 of this Schedule and taking service under SC 7. If electricity (kWh) supplied by the customer to the Corporation is not metered for the time-differentiated periods, an allocation to each TOU period will be done according to allocation factors as described herein. Forty-seven percent (47%) of the excess electricity (kWh) supplied by the customer will be considered On Peak. Fifty-three percent (53%) of the excess electricity (kWh) will be considered Off Peak. (n) Solar Non-Residential Electric Service Option: This option is for a customer qualifying for the Solar Non-Residential Generating Service Option pursuant to General Information Section 27 of this Schedule and taking service under SC 7. If electricity (kWh) supplied by the customer to the Corporation is not metered for the time-differentiated periods, an allocation to each TOU period will be done according to allocation factors as described herein. Forty-seven percent (47%) of the excess electricity (kWh) supplied by the customer will be considered On Peak. Fifty-three percent (53%) of the excess electricity (kWh) will be considered Off Peak. (o) Electric Hybrid Generating System Option: This option is for a customer qualifying for the Electric Hybrid Generating System Option pursuant to General Information Section 24 of this Schedule and taking service under SC 7.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010 SERVICE CLASSIFICATION NO. 8

Leaf No. 256 Revision: 5 Superseding Revision: 4

APPLICABLE TO THE USE OF SERVICE FOR: Residential Service customers who: (1) have opted for "Day-Night" metering and service rates, prior to May 27, 1988; or (2) for new customer installations which will use 1000 kWh or more per month; or (3) existing residential customers, presently served under S.C. No. 1, who use 1000 kWh or more per month, in individual private dwellings, flats or apartments, and such religious customers utilizing service exclusively in connection with religious purposes by a corporation or association organized and conducted in good faith for religious purposes. Applicable also to use exclusively in connection with a community residence for the mentally disabled, as defined in subdivision 28, 28-a, 28-b of section 1.03 of the mental hygiene law, provided that such residence is operated by a not-for-profit corporation and, if supervisory staff is on site 24 hours a day, that the residence provides living accommodations for 14 or fewer residents. Also applicable to any not-for-profit corporation that is a veterans' organization that owns or leases a post or hall. After application from a qualified customer, the Corporation will meter and bill all energy used during the meter controlled "night" hours of approximately 11:30 P.M. to 7:00 A.M. Eastern Standard Time at the below stated "Night" Service Rate. Energy used during all other hours will be metered and billed at the below stated "Day" Service Rate. CHARACTER OF SERVICE: Residential Customers: Continuous - Alternating current, 60 Cycle; 120, 120/208, or 120/240 Volts - Single Phase. (Characteristics depend upon available circuits.) Religious, Veterans' Organizations, and Community Residence Supportive Living Facility Customers: Continuous - Alternating Current, 60 Cycle; Single or Three Phase. (Characteristics depend upon available circuits and equipment.) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: Pursuant to General Information Section 25, Supply Service Options, customers served under this Service Classification will choose from different electric rate options offered by the Company as described below. NYSEG will offer a Retail Access rate choice and a Non-Retail Access rate choice. The Retail Access choice is the ESCO Supply Service (ESS). The Non-Retail Access choice is the NYSEG Supply Service (NSS). NYSEG will provide Delivery Service regardless of the customer’s Supply Service Option.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 257 New York State Electric & Gas Corporation Revision: 10 Initial Effective Date: September 26, 2010 Superseding Revision: 8 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010
SERVICE CLASSIFICATION NO. 8 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (Cont'd.) 1. ESCO Supply Service (ESS) This Retail Access choice includes fixed charges for NYSEG delivery service and a Transition Charge (Non-Bypassable Charge [NBC]). Supply Service will be provided by an Energy Services Company (ESCO). Customers that elect ESS and receive a Consolidated Bill will not be subject to the Bill Issuance Charge. RATE: (Per Meter, Per Month) Delivery Service: Effective Date 09/01/2011 $17.40

Customer Charge Energy Charge
(All kilowatt-hours, per kilowatt-hour)

09/26/2010 $17.40

09/01/2012 $17.40

“Day” Service “Night” Service

$0.0276 $0.0276

$0.0286 $0.0286

$0.0298 $0.0298

Transition Charge All kilowatt-hours, per kilowatt-hour

See Transition Charge Statement

Bill Issuance Charge (per bill):

$0.73, as described in General Information Section 16.J.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2008

Leaf No. 258 Revision: 6 Superseding Revision: 4

SERVICE CLASSIFICATION NO. 8 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (Cont'd.) Reserved for Future Use

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 259 Revision: 17 Superseding Revision: 15

SERVICE CLASSIFICATION NO. 8 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (Cont'd.)

2. Reserved for Future Use

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 259.1 Revision: 3 Superseding Revision: 2

SERVICE CLASSIFICATION NO. 8 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (Cont'd.)

2. Reserved for Future Use

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 260 New York State Electric and Gas Corporation Revision: 9 Initial Effective Date: September 26, 2010 Superseding Revision: 7 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010
SERVICE CLASSIFICATION NO. 8 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (Cont'd.) 3. NYSEG Supply Service (NSS) This Non-Retail Access choice includes fixed charges for NYSEG delivery service, a Transition Charge (Non-Bypassable Charge [NBC]), a fluctuating commodity charge for electricity supplied by NYSEG, and a Merchant Function Charge. RATE: (Per Meter, Per Month) Delivery Service: Effective Date 09/01/2011 $17.40

Customer Charge Energy Charge
(All kilowatt-hours, per kilowatt-hour)

09/26/2010 $17.40

09/01/2012 $17.40

“Day” Service “Night” Service

$0.0276 $0.0276

$0.0286 $0.0286

$0.0298 $0.0298

Transition Charge All kilowatt-hours, per kilowatt-hour
Commodity Service

See Transition Charge Statement

The charge for Electric Power Supply provided by NYSEG will fluctuate each month as further described in General Information Section 25.I.C., Calculation of the Commodity Charge.

Merchant Function Charge All kilowatt-hours, per kilowatt-hour See Merchant Function Charge Statement Bill Issuance Charge (per bill): $0.73, as described in General Information Section 16.J.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 261 New York State Electric & Gas Corporation Revision: 21 Initial Effective Date: September 26, 2010 Superseding Revision: 19 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010
SERVICE CLASSIFICATION NO. 8 (Continued) MERCHANT FUNCTION CHARGE: The Merchant Function Charge reflects the administrative costs of obtaining electricity supply, as further explained in General Information Section 25.D. Customers whose electricity is supplied by an ESCO are not charged for this service. MINIMUM CHARGE: The minimum charge for service under this Service Classification is the monthly Customer Charge plus the Bill Issuance Charge, if applicable, as listed above. SURCHARGE TO COLLECT SYSTEM BENEFITS CHARGE ("SBC"): A surcharge will be added to each customer bill for service under this Service Classification to collect the System Benefits Charge (as explained in this Schedule, General Information Section 4). See SBC Statement. RENEWABLE PORTFOLIO STANDARD CHARGE (“RPS”): A surcharge will be added to each customer bill for service under this Service Classification to collect the Renewable Portfolio Standard (as explained in this Schedule, General Information Section 5). See RPS Statement. SURCHARGE TO COLLECT TEMPORARY STATE ASSESSMENT (“TSAS”): A surcharge will be added to each customer bill for service under this Service Classification to collect the Temporary State Assessment (as explained in this Schedule, General Information Section 28). See TSAS Statement.

REVENUE DECOUPLING MECHANISM (“RDM”):
A customer taking service under this Service Classification shall be subject to a Revenue Decoupling Adjustment (as explained in this Schedule, General Information Section 7). See RDM Statement INCREASE IN RATES AND CHARGES: The rates and charges under this Service Classification, including minimum charges, will be increased by a surcharge pursuant to Section 6 of P.S.C. No. 120 to reflect the tax rates applicable within the municipality where the customer takes service. TERMS OF PAYMENT: All bills are rendered at the above "unit prices" and that amount is due on bills paid on or before the past due date indicated on the bill. A late payment charge at the rate of one and one-half percent (1 1/2%) per month will be billed on all amounts not paid by that date. (Further details in Section 4 of P.S.C. No. 119 - Electricity or superseding issues thereof.) TERM:

One month and thereafter, or for customers initiating service on or after June 1, 1988, one year and thereafter, until terminated by 48 hours' written notice. Service under this Service Classification, once terminated by the customer, will be unavailable to said customer at the same premises for one year from the date of such cancellation.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 262 New York State Electric & Gas Corporation Revision: 19 Initial Effective Date: September 26, 2010 Superseding Revision: 17 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 8 (Continued) SPECIAL PROVISIONS: (a) Seasonal Service: Upon request, customers who, during a period of six or more consecutive months, make only occasional (compared to the balance of the year) or no use of electric service at their premises may have their service maintained throughout the period, not to exceed eight months, and will be billed for the kilowatthours consumed during this period at the following unit prices per kWh:
Effective Date 9/26/2010 Delivery Charges
(All kilowatt-hours, per kilowatt-hour)

09/01/2011 $0.0286

09/01/2012 $0.0298

$0.0276

Transition Charge
(All kilowatt-hours, per kilowatt-hour)

See Transition Charge Statement

The total bill for delivery service, however, for the year shall in no case be less than $208.80 plus actual billed Bill Issuance Charges. Commodity Service Customers served under this special provision will be billed for supply service in accordance with the customer’s Supply Service Option (ESS or NSS).

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 263 Revision: 7 Superseding Revision: 6

SERVICE CLASSIFICATION NO. 8 (Continued) SPECIAL PROVISIONS: (Cont'd) (a) Seasonal Service (Cont’d.) Merchant Function Charge All customers served under this Service Classification taking service under the NSS will be required to pay a Merchant Function Charge as set forth on the Merchant Function Charge Statement. (b) Multiple Dwellings: Two or more individual flats, apartments or dwelling units presently supplied service through one meter may be billed under this service classification. (c) Commercial Use: When a customer operates a commercial establishment (incidental to his residence) in the same building or on the same premises as his residence and takes his entire service through one meter, this classification will apply for the entire service only if the connected load in the residential portion exceeds that in the commercial portion, provided that the connected load in the commercial portion does not exceed 1.5 kW. If the reverse is true, the general classification will apply to the entire service. However, the customer may elect to take service under both the residential and general rates, in which case there will be a separate meter for the residential portion and a separate meter for the general portion. (d) Budget Billing: Customers may, by signing an application, be billed monthly in accordance with the plan set forth in Section 4-0 of P.S.C. No. 119 - Electricity or superseding issues thereof. (e) Quarterly Payment Plan: Effective November 29, 1985, as required by Public Service Law Section 38, the Company will offer any residential customer, 62 years of age or older, a plan for payment on a quarterly basis of charges for service rendered, provided that such customer's average annual billing is not more than $150. (f) Reserved For Future Use

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2007

Leaf No. 263.1 Revision: 2 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 8 (Continued) SPECIAL PROVISIONS: (Cont'd) (f) RESERVED FOR FUTURE USE (g) RESERVED FOR FUTURE USE

Issued in compliance with order in Case No. 05-E-1222 dated 08/23/06.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: February 5, 2009 Effective date postponed to 02/27/09. See Supplement No. 13.

Leaf No. 264 Revision: 5 Superseding Revision: 4

SERVICE CLASSIFICATION NO. 8 (Continued) SPECIAL PROVISIONS: (Cont'd) (h) Residential Solar Electric Service Option: This option is for a customer qualifying for the Residential Solar Electric Service Option pursuant to General Information Section 26 of this Schedule and taking service under SC 8. If electricity (kWh) supplied by the customer to the Corporation is not metered for the time-differentiated periods, an allocation to each TOU period will be done according to allocation factors as set forth below: Month Jan, Feb, Mar, Oct, Nov and Dec Apr May Jun Jul Aug Sep Day 100% 94.6% 89.8% 88.3% 89.8% 93.1% 97.5% Night 5.4% 10.2% 11.7% 10.2% 6.9% 2.5%

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: February 5, 2009 Effective date postponed to 02/27/09. See Supplement No. 13.

Leaf No. 265 Revision: 3 Superseding Revision: 2

SERVICE CLASSIFICATION NO. 8 (Continued) SPECIAL PROVISIONS: (Cont'd.) Reserved for Future Use

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: July 1, 2009

Leaf No. 266 Revision: 5 Superseding Revision: 4

SERVICE CLASSIFICATION NO. 8 (Continued) SPECIAL PROVISIONS: (Cont'd.) (i) Farm Waste Electric Generating System Option: This option is for a customer qualifying for the Farm Waste Electric Generating System Option pursuant to General Information Section 22 of this Schedule and taking service under SC 8. If electricity (kWh) supplied by the customer to the Corporation is not metered for the time-differentiated periods, an allocation to each TOU period will be done according to allocation factors as described herein. Sixty-seven percent (67%) of the excess electricity (kWh) supplied by the customer will be considered “Day” kWh. Thirty-three percent (33%) of the excess electricity (kWh) supplied by the customer will be considered “Night” kWh.

(j)

Wind Electric Service Option: This option is for a customer qualifying for the Wind Electric Service Option pursuant to General Information Section 23 of this Schedule and taking service under SC 8. If electricity (kWh) supplied by the customer to the Corporation is not metered for the time-differentiated periods, an allocation to each TOU period will be done according to allocation factors as described herein. Sixty-seven percent (67%) of the excess electricity (kWh) supplied by the customer will be considered “Day” kWh. Thirty-three percent (33%) of the excess electricity (kWh) supplied by the customer will be considered “Night” kWh.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 26, 2010

Leaf No. 266.1 Revision: 3 Superseding Revision: 2

SERVICE CLASSIFICATION NO. 8 (Continued) SPECIAL PROVISIONS: (Cont'd.)

(k) Electric Hybrid Generating System Option: This option is for a customer qualifying for the Electric Hybrid Generating System Option pursuant to General Information Section 24 of this Schedule and taking service under SC 8. (l) Micro-combined Heat and Power (MCHP) Service Option: This option is for a customer qualifying for the MCHP Service Option pursuant to General Information Section 29 of this Schedule and taking service under SC 8. (m) Fuel Cell Residential Electric Service Option: This option is for a customer qualifying for the Fuel Cell Service Option pursuant to General Information Section 30 of this Schedule and taking service under SC 8.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010 SERVICE CLASSIFICATION NO. 9 APPLICABLE TO THE USE OF SERVICE FOR:

Leaf No. 267 Revision: 5 Superseding Revision: 4

General Service - Non-Residential customers who: (for Estimated "Day" Service metered demand of 5 kW or less and "Day" Service use for 2000 kWh or less per month for any two consecutive months.) (1) Have opted for "Day-Night" metering and service rates prior to February 1, 1991; or (2) for new customer installations which will use a minimum of 1000 kWh per month; or (3) existing non-residential customers, presently served under S.C. No. 6, who use a minimum of 1000 kWh per month. After application from a qualified customer, the Corporation will meter and bill all energy used during the meter controlled "Night" hours of approximately 11:30 P.M. to 7:00 A.M. Eastern Standard Time at the below stated "Night" Service Rate. Energy used during all other hours will be metered and billed at the below stated "Day" Service Rate. CHARACTER OF SERVICE: Continuous - Alternating Current, 60 Cycle; 120, 120/208, 120/240, 208, 240, 240/416, 277/480 or 480 Volts Single Phase. (Characteristics depend upon available circuits and equipment.) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: Pursuant to General Information Section 25, Supply Service Options, customers served under this Service Classification will choose from different electric rate choices offered by the Company as described below. NYSEG will offer a Retail Access rate choice and a Non-Retail Access rate choice. The Retail Access choice is the ESCO Supply Service (ESS). The Non-Retail Access choice is the NYSEG Supply Service (NSS).

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 268 New York State Electric & Gas Corporation Revision: 10 Initial Effective Date: September 26, 2010 Superseding Revision: 8 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010
SERVICE CLASSIFICATION NO. 9 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (CONT'D.) NYSEG will provide Delivery Service regardless of the customer’s Supply Service Option. 1. ESCO Supply Service (ESS) This Retail Access choice includes fixed charges for NYSEG delivery service and a Transition Charge (Non-Bypassable Charge [NBC]). Supply service will be provided by an Energy Services Company (ESCO). Customers that elect ESS and receive a Consolidated Bill will not be subject to the Bill Issuance Charge. RATE: (Per Meter, Per Month) Delivery Service: Effective Date 09/01/2011 $19.77

09/26/2010 Customer Charge Energy Charge
(All kilowatt-hours, per kilowatt-hour)

09/01/2012 $20.41

$19.25

“Day” Service “Night” Service

$0.03022 $0.03022

$0.03075 $0.03075

$0.03140 $0.03140

Transition Charge All kilowatt-hours, per kilowatt-hour

See Transition Charge Statement

Bill Issuance Charge (per bill):

$0.73, as described in General Information Section 16.J.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2008

Leaf No. 269 Revision: 6 Superseding Revision: 4

SERVICE CLASSIFICATION NO. 9 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS Reserved for Future Use

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 270 Revision: 16 Superseding Revision: 14

SERVICE CLASSIFICATION NO. 9 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS NYSEG will provide Delivery and Commodity Service for the Non-Retail Access choice. 2. Reserved for Future Use

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 270.1 Revision: 3 Superseding Revision: 2

SERVICE CLASSIFICATION NO. 9 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (Cont'd.) NYSEG will provide Delivery and Commodity Service for the Non-Retail Access choice. 2. Reserved for Future Use

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 271 New York State Electric & Gas Corporation Revision: 9 Initial Effective Date: September 26, 2010 Superseding Revision: 7 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010
SERVICE CLASSIFICATION NO. 9 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS 3. NYSEG Supply Service (NSS) This Non-Retail Access choice includes fixed charges for NYSEG delivery service, a Transition Charge (Non-Bypassable Charge [NBC]), a fluctuating commodity charge for electricity supplied by NYSEG, and a Merchant Function Charge. RATE: (Per Meter, Per Month) Delivery Service: Effective Date 09/26/2010 09/01/2011 $19.77 09/01/2012 $20.41

Customer Charge Energy Charge
(All kilowatt-hours, per kilowatt-hour)

$19.25

“Day” Service “Night” Service

$0.03022 $0.03022

$0.03075 $0.03075

$0.03140 $0.03140

Transition Charge All kilowatt-hours, per kilowatt-hour
Commodity Service

See Transition Charge Statement

The charge for Electric Power Supply provided by NYSEG will fluctuate each month as further described in General Information Section 25.I.C., Calculation of the Commodity Charge.

Merchant Function Charge All kilowatt-hours, per kilowatt-hour See Merchant Function Charge Statement Bill Issuance Charge (per bill): $0.73, as described in General Information Section 16.J.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 272 New York State Electric & Gas Corporation Revision: 23 Initial Effective Date: September 26, 2010 Superseding Revision: 21 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 9 (Continued)
MERCHANT FUNCTION CHARGE: The Merchant Function Charge reflects the administrative costs of obtaining electricity supply, as further explained in General Information Section 25.D. Customers whose electricity is supplied by an ESCO are not charged for this service. SURCHARGE TO COLLECT SYSTEM BENEFITS CHARGE ("SBC"): A surcharge will be added to each customer bill for service under this Service Classification to collect the System Benefits Charge (as explained in this Schedule, General Information Section 4). See SBC Statement. RENEWABLE PORTFOLIO STANDARD CHARGE (“RPS”): A surcharge will be added to each customer bill for service under this Service Classification to collect the Renewable Portfolio Standard (as explained in this Schedule, General Information Section 5). See RPS Statement. SURCHARGE TO COLLECT TEMPORARY STATE ASSESSMENT (“TSAS”): A surcharge will be added to each customer bill for service under this Service Classification to collect the Temporary State Assessment (as explained in this Schedule, General Information Section 28). See TSAS Statement.

REVENUE DECOUPLING MECHANISM (“RDM”):
A customer taking service under this Service Classification shall be subject to a Revenue Decoupling Adjustment (as explained in this Schedule, General Information Section 7). See RDM Statement
INCREASE IN RATES AND CHARGES: The rates and charges under this Service Classification, including minimum charges, will be increased by a surcharge pursuant to Section 6 of P.S.C. No. 120 to reflect the tax rates applicable within the municipality where the customer takes service. TERMS OF PAYMENT: All bills are rendered at the above "unit prices" and that amount is due on bills paid on or before the "past due" date indicated on the bill. A late payment charge at the rate of one and one-half percent (1 1/2%) per month will be billed on all amounts not paid by that date. (Further details in Section 4 of P.S.C. No. 119 - Electricity or superseding issues thereof.) TERM: One month and thereafter until terminated by 48 hours' written notice.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 272.1 New York State Electric & Gas Corporation Revision: 4 Initial Effective Date: September 26, 2010 Superseding Revision: 1 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 9 (Continued) SPECIAL PROVISIONS: (a) Space Heating Service:
(Service under this provision will no longer be available to new customers after November 1, 1977.) Any customer using general service under this Service Classification and also using electricity as the sole source of space heating in a premises or segregated portion of a premises may, upon written application to the Corporation, have the energy used for such space heating, as well as air conditioning and water heating for such electrically heated space, separately metered. The separately metered space heating service will be charged under the same rate choice the customer selected for their non-heating service under this Service Classification.

The per kilowatt-hour delivery rate for such separately metered space heating service under the selected rate choice is as shown below. There is a separate minimum charge. A complete description of these rates choices appears previously in this Service Classification.
Effective Date 09/26/2010 Energy Charge
(All kilowatt-hours, per kilowatt-hour)

09/01/2011 $0.01124

09/01/2012 $0.01112

$0.01017

Customers are responsible for a separate per kilowatt-hour Transition Charge (Non-Bypassable Charge) and any Commodity and Merchant Function Charges at the same rate associated with the selected rate choice for their non-heating service. The minimum charge is the monthly Customer Charge plus the Bill Issuance Charge, if applicable, as listed above.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2007

Leaf No. 273 Revision: 13 Superseding Revision: 12

SERVICE CLASSIFICATION NO. 9 (Continued)
SPECIAL PROVISIONS (CONT'D.) (b) Fluctuating Loads: When service is rendered solely for equipment having a fluctuating or large instantaneous demand, such as X-Rays, welders, etc., and a separate or larger transformer for such service is required, the minimum monthly charge will be not less than $.50 per KVA of such additional transformer capacity. (c ) Budget Billing: Customers may, by signing an application, be billed monthly in accordance with the plan set forth in Section 4-O of P.S.C. No. 119 - Electricity or superseding issues thereof. (d) Submetering: Submetering may be available according to certain conditions as explained in the general information leaves of this schedule, Section 2. Submetering. (e) Reserved For Future Use

Issued in compliance with order in Case No. 05-E-1222 dated 08/23/06.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2007

Leaf No. 273.1 Revision: 2 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 9 (Continued) SPECIAL PROVISIONS (CONT'D.) (f) RESERVED FOR FUTURE USE

Issued in compliance with order in Case No. 05-E-1222 dated 08/23/06.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2007

Leaf No. 273.2 Revision: 2 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 9 (Continued) SPECIAL PROVISIONS (CONT'D.) (f) RESERVED FOR FUTURE USE

Issued in compliance with order in Case No. 05-E-1222 dated 08/23/06.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 5, 2009 Effective date postponed to 02/27/09. See Supplement No. 13.

Leaf No. 274 Revision: 6 Superseding Revision: 5

SERVICE CLASSIFICATION NO. 9 (Continued)
SPECIAL PROVISIONS: (Cont'd) (g) Economic Incentives: (1) RESERVED FOR FUTURE USE (2) Economic Development Zone Incentive ("EDZI") Customers served under this service classification may qualify for the EDZI Special Provision. Information Section 9 of this Schedule for a complete description of the EDZI. (h) Farm Waste Electric Generating System Option: See General

This option is for a customer qualifying for the Farm Waste Electric Generating System Option pursuant to General Information Section 22 of this Schedule and taking service under SC 9. If electricity (kWh) supplied by the customer to the Corporation is not metered for the time-differentiated periods, an allocation to each TOU period will be done according to allocation factors as described herein. Sixty-seven percent (67%) of the excess electricity (kWh) supplied by the customer will be considered “Day” kWh. Thirty-three percent (33%) of the excess electricity (kWh) supplied by the customer will be considered “Night” kWh.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: July 1, 2009

Leaf No. 274.1 Revision: 4 Superseding Revision: 3

SERVICE CLASSIFICATION NO. 9 (Continued) SPECIAL PROVISIONS: (Cont'd)
(i) Wind Electric Service Option:

This option is for a customer qualifying for the Wind Non-Residential Service Option pursuant to General Information Section 23 of this Schedule and taking service under SC 9. If electricity (kWh) supplied by the customer to the Corporation is not metered for the time-differentiated periods, an allocation to each TOU period will be done according to allocation factors as described herein. Sixty-seven percent (67%) of the excess electricity (kWh) supplied by the customer will be considered “Day” kWh. Thirty-three percent (33%) of the excess electricity (kWh) supplied by the customer will be considered “Night” kWh. (j) Solar Non-Residential Electric Service Option: This option is for a customer qualifying for the Solar Non-Residential Generating Service Option pursuant to General Information Section 27 of this Schedule and taking service under SC 9. If electricity (kWh) supplied by the customer to the Corporation is not metered for the time-differentiated periods, an allocation to each TOU period will be done according to allocation factors as described herein. Sixty-seven percent (67%) of the excess electricity (kWh) supplied by the customer will be considered “Day” kWh. Thirty-three percent (33%) of the excess electricity (kWh) supplied by the customer will be considered “Night” kWh. (k) Electric Hybrid Generating System Option: This option is for a customer qualifying for the Electric Hybrid Generating System Option pursuant to General Information Section 24 of this Schedule and taking service under SC 9.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003 SERVICE CLASSIFICATION NO. 10

Leaf No. 275 Revision: 0 Superseding Revision:

APPLICABLE TO THE USE OF SERVICE FOR: All customers with qualifying (or non-qualifying, as applicable) cogeneration or small power production facilities, with or without the requirement for supplemental service, back-up service, or maintenance service who choose to sell all or any excess energy to the Corporation whether or not engaging in simultaneous purchase, under the appropriate Service Classification, from the Corporation. The Corporation's meters registering any sales by the Corporation to such customers will be, at the sole discretion of the Corporation, modified or installed in such a configuration as to prevent reverse registration. Prior to connection and operation, such a customer must sign an agreement and have approved by the Corporation the installation and all protective devices required under the Corporation's policy for such service. Also, prior to interconnection under this service classification, the customer shall pay for all costs of interconnection and protective devices which exceed the costs ordinarily incurred in rendering the same Contract Demand under the otherwise applicable Service Classification. Appropriate agreement(s) in the form(s) of those on file with the Public Service Commission, signed by the customer and accepted by the Corporation, is (are) required under this classification. Customers over 100 Kw with firm or long term Capacity and Energy for sale to the Corporation may negotiate a Special Contract with the Corporation. Customers may request a copy of NYSEG's guidelines for soliciting short-term capacity by writing to: Manager, Power Supply, New York State Electric & Gas Corporation, 4500 Vestal Parkway East, Binghamton, New York 13903. CHARACTER OF SERVICE: Continuous - Alternating Current, 60 Cycle; Secondary Service at 120, 120/208, 120/240, 208, 240, 240/416, 277/480, or 480 Volts; or Primary (Distribution) Service at 2,400, 4,160, 4,800, 7,200, 8,320, 12,000, 12,470, 13,200, or 34,500 (Regulated) Volts; or Subtransmission Service at 34,500 or 46,000 (both Non-Regulated) Volts; or Transmission Service at 115,000 Volts and above (Non-Regulated*). Single Phase (not to exceed 15 kW or Three Phase. (Characteristics depend upon available circuits and equipment.) *Effective February 15, 2000.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 276 New York State Electric and Gas Corporation Revision: 2 Initial Effective Date: September 26, 2010 Superseding Revision: 0 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 10 (Continued) RATE TO BE PAID BY THE CORPORATION: (Per Month) Energy Payment
n

Σ
h=1

((Day Ahead LBMPh * Sh) + (Real Time LBMPh * (Qh-Sh)) – Incurred Costh

Whereby: 1) If the customer’s generator is PTID Eligible but has not obtained a PTID Day Ahead Locational Based Marginal Price (“Day Ahead LBMPh”) is the NYISO hourly Day Ahead LBMP applicable to the lowest priced generator bus in the same zone as the customer’s generator: Hourly Real Time Locational Based Marginal Price ("Real Time LBMPh") is the NYISO hourly Real Time LBMP applicable to the lowest priced generator bus in the same zone as the customer’s generator;; Incurred Cost is any charges assessed by the NYISO applicable to the customer; Sh is the Cogenerated Energy quantity scheduled, in MWh, by NYSEG upon the written request of cogenerator, for each specific hour, in the NYISO in the Day Ahead market, whereas the cogenerator shall provide a written schedule by noon two business days prior to the day for which the schedule applies; Qh is the Cogenerated Energy quantity delivered, in MWh, to the Delivery Point for a specific hour; h is the respective hour in each month; and n is the number of hours in each month. 2) If the customer’s generator has a PTID Day Ahead Locational Based Marginal Price (“Day Ahead LBMPh”) is the NYISO hourly Day Ahead LBMP applicable to the customer’s generator bus;: Hourly Real Time Locational Based Marginal Price ("Real Time LBMPh") is the NYISO hourly Real Time LBMP applicable to the customer’s generator bus; Incurred Cost is any charges assessed by the NYISO applicable to the customer; Sh is the Cogenerated Energy quantity scheduled, in MWh, by NYSEG upon the written request of cogenerator, for each specific hour, in the NYISO in the Day Ahead market, whereas the cogenerator shall provide a written schedule by noon two business days prior to the day for which the schedule applies; Qh is the Cogenerated Energy quantity delivered, in MWh, to the Delivery Point for a specific hour; h is the respective hour in each month; and n is the number of hours in each month. ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 276.1 New York State Electric and Gas Corporation Revision: 1 Initial Effective Date: September 26, 2010 Superseding Revision: Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 10 (Continued) RATE TO BE PAID BY THE CORPORATION: (Per Month)

3) If the customer’s generator is not PTID Eligible: Day Ahead Locational Based Marginal Price (“Day Ahead LBMPh”) is the NYISO hourly Day Ahead LBMP applicable to the NYISO Zone in which the customer’s generator is located Hourly Real Time Locational Based Marginal Price ("Real Time LBMPh") is the NYISO hourly Real Time LBMP applicable to the NYISO Zone in which the customer’s generator is located; Incurred Cost is any charges assessed by the NYISO applicable to the customer; Sh is the Cogenerated Energy quantity scheduled, in MWh, by NYSEG upon the written request of cogenerator, for each specific hour, in the NYISO in the Day Ahead market, whereas the cogenerator shall provide a written schedule by noon two business days prior to the day for which the schedule applies; Qh is the Cogenerated Energy quantity delivered, in MWh, to the Delivery Point for a specific hour; h is the respective hour in each month; and n is the number of hours in each month.

Capacity Payment, if applicable: (UCAPm * Capacitym) Unforced Capacity ("UCAPm") is the Market-Clearing Price of capacity in $/kW-month as determined from the NYISO's monthly UCAP Auction. Monthly Capacity ("Capacitym") is the Unforced Capacity (“UCAP”) recognized by the NYISO as applicable to capability requirements for the respective calendar month, as set forth in the NYISO Tariff, in kW.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 277 New York State Electric and Gas Corporation Revision: 2 Initial Effective Date: September 26, 2010 Superseding Revision: 0 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 10 (Continued) RATE TO BE PAID BY THE CORPORATION: (Per Month) (Cont'd) (1) Qualifying small, random suppliers of energy, limited to secondary single phase service voltage, may elect to sell their output to the Company on a non-time differentiated basis. Deliveries will be measured using a standard kWh meter and energy payments based on the average NYISO Day Ahead LBMP applicable to the zone within which deliveries are made; (2) In the event the NYISO does not require a Dependable Maximum Net Capability, any applicable capacity payment shall be made based upon the LBMCPm divided by the number of hours in the respective month, times the energy delivered for the respective month.

(3) The customer may be entitled to receive direct payment from the NYISO for (1) NYISO Tariff Schedule II Reactive Supply and Voltage Control, and/or (2) NYISO Tariff Schedule III Regulation and Frequency Response, and/or (3) NYISO Tariff Schedule V Operating Reserve, and/or (4) NYISO Tariff Schedule VI Black Start Service. Payment from the NYISO for each of these services is conditioned upon the customers meeting the requirements of the NYISO and making the appropriate contractual arrangements directly with the NYISO.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 278 New York State Electric and Gas Corporation Revision: 2 Initial Effective Date: September 26, 2010 Superseding Revision: 0 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 10 (Continued)

Customer Charge and Demand Charge: (Per Meter, Per Month) A customer taking service solely under this Service Classification shall pay the appropriate customer charges and demand charges listed in Service Classification No. 11, Standby Service.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 279 New York State Electric and Gas Corporation Revision: 2 Initial Effective Date: September 26, 2010 Superseding Revision: 0 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 10 (Continued)

MINIMUM CHARGE: The minimum charge for service under this Service Classification is the applicable Contract Demand Charge plus the Customer Charge. INCREASES IN RATES AND CHARGES: The rates and charges to customers under this Service Classification, including fuel adjustment and minimum charges, will be increased by a surcharge pursuant to Section 6 of P.S.C. No. 120 to reflect the tax rates applicable within the municipality where the customer takes service. DETERMINATION OF DEMAND: The Determination of Demand will be in accordance with Service Classification No. 11, Standby Service.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003

Leaf No. 280 Revision: 0 Superseding Revision:

SERVICE CLASSIFICATION NO. 10 (Continued) TERMS OF PAYMENT: All bills are rendered at the above "unit prices" and that amount is due on bills paid on or before the "past due" date indicated on the bill. A late payment charge at the rate of one and one-half percent (1 1/2%) per month will be billed on all amounts not paid by that date. (Further details in Section 4 of P.S.C. No. 119 - Electricity or superseding issues thereof.) TERM: One year and thereafter until terminated by 48 hours' written notice. A customer resuming service within one year will be reassigned the same contract demand. SPECIAL PROVISIONS: A. The customer and the Corporation shall agree as to the operating mode, interconnection and equipment specifications as set forth in "Requirements for the Installation of Electric Services and Meters" (superseding "Specifications for Electric Installations") and the Corporation's requirements for parallel operation of on-site non-utility generation as on file with the Public Service Commission. The Commission may review the specifications and arbitrate, if a dispute should arise. B. The Corporation will be relieved of its obligation to purchase energy during any period in which the Corporation suffers a System Emergency. In such circumstances, the Corporation will notify the customer to cease supplying energy to the Corporation. For purposes of this Provision, a System Emergency is defined as a condition which is imminently likely to endanger life or property or result in significant disruption of service to any customer. C. Service under this Special Provision will no longer be available to new customers after July 5, 1989.) A customer with a Secondary Voltage, Single Phase generating facility, with a nameplate capacity rating of 15 kW or less and choosing to sell all or any excess energy to the Corporation without time differentiation may operate under the terms of the Corporation's "Alternate Generation Agreement" applicable to such facilities which is on file with the Public Service Commis sion. Instead of the energy charge under the "Rate to Be Paid By the Corporation" customers will receive payment of $.02447 per kilowatt-hour, for the energy sold during all hours. Under this provision the Meter Charge or Customer Charge will be $3.00 or $4.50 per month, respectively, instead of such charges under the "Rate to Be Paid By the Customer".

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: December 1, 2003

Leaf No. 281 Revision: 0 Superseding Revision:

SERVICE CLASSIFICATION NO. 10 (Continued) SPECIAL PROVISIONS: (Cont'd) D. At the time of Agreement, the customer with on-site non-utility generation facilities greater than 15 kW may choose to pay the Corporation actual charges for maintenance, as they may occur, on interconnection equipment paid for by the customer and owned by the Corporation; or the customer may choose to pay an annual carrying charge of 9% (subject to review in the Corporation's rate case proceedings) on the total investment in such equipment which shall be payable upon the initiation of service and on the annual anniversary of the agreement for service hereunder. If the interconnection costs charged by the Corporation are disputed by the customer, such dispute will be subject to arbitration by the Public Service Commis sion. E. Customers who deliver power to the Corporation at subtransmission or transmission service voltage during on-peak periods and, at the same site, also purchase power from the Corporation at such voltages during on-peak periods shall, to the extent such purchases are matched by deliveries of power to the Corporation, have the following demand payments added to the on-peak kWh payments above: Transmission Subtransmission $.01074/kWh $.01095/kWh

Customers electing to deliver power to the Corporation under this Special Provision are required to record both deliveries and purchases with suitable time differentiated kilowatt-hour metering devices satisfactory to the Corporation. F. If the measured demand exceeds the current Contract Demand by 10 percent or less, a surcharge equal to 12 times the monthly Contract Demand charge for such excess demand will apply to that monthly bill, and the Contract Demand will then be determined in accordance with the provisions of Determination of Demand above. If the measured demand exceeds the current Contract Demand by more than 10 percent, a surcharge equal to 24 times the monthly Contract Demand charge for such excess demand will apply to that monthly bills, and the Contract Demand will then be determined in accordance with the provisions of Determination of Demand above. G. A customer operating a qualifying facility, construction of which commenced prior to November 9, 1978, may negotiate a special contract with the Corporation, at the termination of any existing contract or when permitted by an express provision in the contract, to begin to receive a rate that would in 1986 be set at 50% of full avoided costs and in each succeeding year would increase by five percentage points such that by 1996 all such facilities would receive 100% of full avoided costs.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 1, 2004 STANDBY SERVICE RATE SERVICE CLASSIFICATION NO. 11

Leaf No. 282 Revision: 1 Superseding Revision: 0

APPLICABLE TO USE OF SERVICE FOR: Delivery of standby service for any customer where all or a portion of a customer's electricity is supplied from On-Site Generating facilities (“OSG”) without using the Company’s delivery system (defined as the distribution and/or transmission system, regardless of voltage or functional classification). An OSG, whether owned by the customer or a third party, can produce electricity primarily to serve the customer’s native load, to sell in the wholesale market or to carry out a combination thereof. Such OSG may be connected with the Company’s delivery system for parallel operation, or operate under the control of a single pull, double-throw switch (or similar device). For customers with multiple electrical services, this tariff applies to each of the customer’s electrical services that are not electrically isolated from the OSG. All separately metered electricity supply and/or delivery service not otherwise served by the OSG (e.g., separate delivery service to the facility’s guardhouse or other facilities electrically isolated from the OSG) will be provided under the Otherwise Applicable Service Classification (“OASC”). Before a customer is allowed to install and operate an OSG, the customer must submit design and operating information for the proposed OSG in accordance with the appropriate application and review process described in NYSEG’s “Bulletin 86-01 Requirements for Independent Power Producers of Electricity” (“Bulletin 86-01”). A customer operating OSG with a total nameplate rating equal to, or expected to be equal to, fifteen percent (15%) or less of its maximum potential demand served by all sources, as that maximum potential demand is reasonably determined by the Company, will take service under the OASC. NYSEG may disqualify a customer from Standby Service if the Company can demonstrate that the customer (a) has installed OSG with a total nameplate rating greater than fifteen percent (15%) of its load, but (b) has not operated or is not operating that OSG in a material manner in order to serve the customer’s load. A customer who declines service under this tariff is required to electrically isolate its facility from the Company’s delivery system, and the Company will not be required to maintain electric delivery service to that customer’s facility. A facility will be deemed “electrically isolated” as set forth below. Electrically Isolated Loads: If a customer elects to electrically isolate and serve its load with OSG without connection to the Company's system, the isolated portion of that customer's load will not be subject to standby service -- provided that the customer executes a letter agreement with the Company that provides for the following: a) the Company will be entitled to inspect the electrical configuration of the OSG facilities upon a customer's request for this exemption; b) if, at any time, the Company has a reasonable concern that the customer’s OSG facilities have not remained isolated from the Company's system, the Company is authorized to inspect the electrical configuration of such facilities, and the customer must cooperate with that inspection; and

Issued in compliance with orders in Case No. 02-E-0779 dated 07/30/03 and Case No. 03-E-1552 dated 11/28/03.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: July 1, 2009

Leaf No. 283 Revision: 2 Superseding Revision: 1

SERVICE CLASSIFICATION NO. 11 (Continued) Electrically Isolated Loads: (Cont’d.) c) if the Company discovers, through billing data and/or the inspection of the customer's OSG facilities, that any of the electrically isolated OSG facilities have been reconnected to NYSEG’s system, the Company will backbill the customer. A contract demand will be established by the Company and the backbill will consist of NYSEG’s standby service rates, applied back to the time of OSG interconnection to NYSEG’s system, and include the surcharge as set forth below in the Unauthorized OSG Interconnection by Customer section, with Late Payment Charges as applicable, set forth in the Terms of Payment section of this Service Classification. A facility shall be considered “electrically isolated” if: (a) the electrical points of contact where interconnection with the Company could occur are separated and at least 100 feet from any other interconnected electrical service utilized by such customer, or (b) the isolated service is not within the same building or structure as any other interconnected electrical service of the customer and not housed within a common enclosure with other interconnected breakers and/or fuses of the customer. At its discretion, the Company may consider a separation of less than 100 feet between a customer’s facilities and the Company’s system to be electrically isolated if there are site-specific configuration circumstances warranting such a determination. Compliance: A customer taking standby service shall comply with all federal, state and local laws, regulations, and requirements, including the requirements listed below in the Interconnection Requirements paragraphs 1 through 8. STANDBY SERVICE NOT APPLICABLE TO: 1a. Net Metered Solar Generating System Option Standby service will not apply to a customer operating solar generating equipment and taking service under General Information Section 26 or 27. 1b. Farm Waste Electric Generating System Option Standby service will not apply to a customer taking service under the Farm Waste Electric Generating System Option, provided such customer meets criteria for service under General Information Section 22 of this Schedule. 1c. Net Metered Wind Generating System Option Standby service will not apply to a customer operating wind generating equipment and taking service under General Information Section 23. 1d. Net Metered Hybrid Generating System Option Standby service will not apply to a customer operating hybrid generating equipment and taking service under General Information Section 24.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: July 1, 2009

Leaf No. 284 Revision: 5 Superseding Revision: 4

SERVICE CLASSIFICATION NO. 11 (Continued)
STANDBY SERVICE NOT APPLICABLE TO: (Cont’d)

2. Emergency Generators Standby service rates shall not apply to customers whose only generating units are emergency generators. For the purpose of this Service Classification, a generating unit must meet each of the following two criteria to be considered an emergency generator: a) The emergency generator is used exclusively for purposes of supplying electrical power to the Customer when electrical power is not available from the Company. b) No load is served by the emergency generator while electric service is available from the Company to the premises, except for regularly scheduled tests when the generator is required to operate under load or participation in the NYISO’s Special Case Resource Program or the Emergency Demand Response Program.
Excluding residential customers, the customer must submit a one-line diagram and specification sheet on the switch for the OSG for NYSEG’s review and approval. In addition, the customer must enter into a letter agreement with NYSEG stating that the emergency generator will not operate in parallel with the utility’s system. The customer shall maintain an operating log for each emergency generator indicating the date, time, hours, and purpose of each operation of each such facility. This log shall be made available to the Company upon request. Failure to do so will permit the Company to (a) bill the customer under this Service Classification for the amount of standby service which the Company can reasonably estimate was delivered to and/or available to the customer during times when the Company did not charge the customer for such service due to this emergency generator exemption; and (b) establish a contract demand for one year, and thereafter as applicable. 3. New York Power Authority Allocations Standby service will not apply to that portion of a customer’s delivery service associated with the delivery of electricity supply pursuant to applicable New York Power Authority (“NYPA”) programs. OPTIONAL STANDBY SERVICE RATE PHASE-IN IS APPLICABLE TO: 1. Existing Customers An Existing Customer is defined as a customer operating OSG (including renewable, Combined Heat and Power (“CHP”), and wholesale generators) as of January 31, 2003, or who, as of that date: a) had commenced construction of an OSG facility; b) had been named by the New York State Energy Research and Development Authority ("NYSERDA") as an OSG project grant recipient as listed in the Commission Order Establishing Electric Standby Rates, issued and effective July 30, 2003, Attachment A, paragraph 4; c) had been named by NYSERDA as an OSG feasibility study grant recipient, as listed in the Commission Order Establishing Electric Standby Rates, issued and effective July 30, 2003, Attachment A, paragraph 4; d) had received a binding, written financial commitment from a lending institution for the construction and installation of an OSG; or e) was being billed at standby rates as of January 31, 2003 as set forth in this Service Classification at Special Provision (d) below. To remain qualified as an Existing Customer, a customer under (c) or (d), above, must commence operation of its OSG by May 31, 2015.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: August 3, 2009

Leaf No. 285 Revision: 3 Superseding Revision: 2

SERVICE CLASSIFICATION NO. 11 (Continued) OPTIONAL STANDBY SERVICE RATE PHASE-IN IS APPLICABLE TO: (Cont’d.)
2. A Designated Technology Customer is defined as: a) A customer operating OSG that exclusively uses one or more of the following technologies and/or fuels for producing electricity: fuel cell; wind; solar thermal; photovoltaics (“PV”); sustainable managed biomass; tidal; geothermal; or methane waste, or Uses small, efficient types of combined heat and power (“CHP”) generation that do not exceed 1 MW of capacity, and conforms with the following criteria: i. Sized to serve no more than 100% of the Customer’s maximum potential demand. ii. Annual overall efficiency should not be less than 60% based on the higher heating value (HHV) of the fuel input; iii. The usable thermal energy component should absorb a minimum of 20% of the CHP facility’s total usable annual energy output; iv. The size limits shall be determined by aggregating the nameplate ratings of the generation units, installed at its location, excluding emergency generation units used only during a utility distribution system failure or in response to the NYISO Emergency Demand Response Program: v. An eligible CHP facility shall demonstrate to the utility that its generation installation meets an environmental standard of no more than 4.4 lbs./MWh of NOx emissions, based on its electrical and mechanical output or its rated capacity, or as updated by the Department of Environmental Conservation (DEC); vi. Customers shall comply with the above criteria and; 1. Monitor and record efficiency data, which shall include the annual quantity of fuel fired, the annual quantity of generated electricity, and the annual quantity of the thermal heat recovered in the heat recovery process. Have records available for utility inspection, Retain the records for a 3-year period.

b)

2. 3.

Issued in compliance with order in Case No. 09-E-0109 dated 07/20/09.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: June 1, 2009

Leaf No. 286 Revision: 4 Superseding Revision: 3

SERVICE CLASSIFICATION NO. 11 (Continued) OPTIONAL STANDBY SERVICE RATE PHASE-IN IS APPLICABLE TO: (Cont’d.) 3. Phase-In and/or Designated Technology Exemption of Standby Rates a) Existing Customers shall take service under this Service Classification and be subject to a phase-in of these standby service rates, as discussed below, unless they make a one-time election to take service at the full standby service rates, providing thirty (30) days written notice, no later than March 1, 2004, subject to the availability of interval metering, if applicable. b) Customers whose facilities are placed in service between July 29, 2003 and May 31, 2015, and meet the definitions of both Existing Customers and Designated Technology Customers, will be considered to be Designated Technology Customers for purposes of this section. c) Designated Technology Customers whose facilities are placed in service between July 29, 2003 and May 31, 2015, have the option to make a one-time election to be permanently exempt from standby service rates rather than electing the phase-in or full standby service rates upon providing thirty (30) days written notice before commencing operation of the OSG facility; provided, however, that if operation commenced between July 29, 2003 and January 31, 2004, the Customer must make its one-time election by March 1, 2004. d) Existing OSG projects that upgrade by installing designated technology components, or hybrid projects comprised in part of designated technology components, are eligible for the designated technology exemption only for the upgraded components and only if those components are separately metered.

Issued in compliance with order in Case No. 09-E-0109 dated 05/18/09.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: June 1, 2009

Leaf No. 286.1 Revision: 1 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 11 (Continued) OPTIONAL STANDBY SERVICE RATE PHASE-IN IS APPLICABLE TO: (Cont’d.) 4. Standby Rate Phase-In During the phase-in, the first four years in which standby rates are effective (February 2004 through January 2008) will continue to be billed at the OASC rates which could be standby rates, terms and conditions as set forth in this Service Classification at Special Provision (d) below. The final four years of the phase-in will be billed based on the OASC rates, plus a percentage of the difference, if greater than zero, between the standby service rates and the OASC rates or rates pursuant to Special Provision (d), where the percentage will be determined from the table set for the below: Existing Customers Ending Billed at: January 31, 2005 OASC rates or rates pursuant to Special Provision (d) January 31, 2006 January 31, 2007 January 31, 2008 January 31, 2009 January 31, 2010 January 31, 2011 OASC rates or rates pursuant to Special Provision (d) OASC rates or rates pursuant to Special Provision (d) OASC rates or rates pursuant to Special Provision (d) OASC rates or rates pursuant to Special Provision (d), plus 25% of bill differential OASC rates or rates pursuant to Special Provision (d), plus 50% of bill differential OASC rates or rates pursuant to Special Provision (d), plus 75% of bill differential Standby service rates

Year 1 2 3 4 5 6 7 8

Beginning February 1, 2004 February 1, 2005 February 1, 2006 February 1, 2007 February 1, 2008 February 1, 2009 February 1, 2010 February 1, 2011

CHARACTER OF SERVICE Continuous - Alternating Current, 60 cycle; Secondary Service at 120, 120/208, 120/240, 208, 240, 240/416, 277/480, or 480 Volts; or Primary (Distribution) Service at 2,400, 4,160, 4,800, 7,200, 8,320, 12,000, 12,470, 13,200, or 34,500 (Regulated) Volts; or Subtransmission Service at 34,500 or 46,000 (Both Non-Regulated) Volts; or Transmission Service at 115,000 Volts and above (Non-Regulated). Single or Three Phase. (Characteristics depend upon available circuits and equipment.)

Issued in compliance with order in Case No. 09-E-0109 dated 05/18/09.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 287 New York State Electric & Gas Corporation Revision: 23 Initial Effective Date: September 26, 2010 Superseding Revision: 22 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 11 (Continued) RATES (Per Month) Delivery Charges: There are up to four rate components of the delivery rate portion of this Standby Service: Customer Charge, Contract Demand Charge, As-Used Demand Charge, and Reactive Charge, as applicable. Transition Charge: The customer’s Otherwise Applicable Service Classification (“OASC”) will determine the applicable charge. The charge will apply to all kilowatt-hours, per kilowatt-hour.

Service Classification Nos. 1 and 6: SC1 Residential Service Per Meter Customer Charge Delivery Charge Contract Demand Charge Delivery Charge As-Used Demand Charge (All kilowatt-hours, per kilowatt-hour) Delivery Charge Transition Charge All kilowatt-hours, per kilowatt-hour Bill Issuance Charge (per bill): 09/26/10 $22.87 $5.69 Effective Date 09/01/11 $22.87 $6.09 09/01/12 $22.87 $6.68

$0.0078

$0.0084

$0.0091

See Transition Charge Statement $0.73, as described in General Information Section 16.J

SC6

General Service w/o Demand 09/26/10 $22.54 $3.42

Effective Date 09/01/11 $23.14 $3.56 09/01/12 $23.90 $3.65

Per Meter Customer Charge Delivery Charge Contract Demand Charge Delivery Charge As-Used Demand Charge (All kilowatt-hours, per kilowatt-hour) Delivery Charge Transition Charge All kilowatt-hours, per kilowatt-hour Bill Issuance Charge (per bill):

$0.00671

$0.00685

$0.00694

See Transition Charge Statement $0.73, as described in General Information Section 16.J.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 287.1 New York State Electric & Gas Corporation Revision: 9 Initial Effective Date: September 26, 2010 Superseding Revision: 8 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 11 (Continued) RATES (Per Month) (Cont’d.) Delivery Rates for Service Classification Nos. 8 and 9: SC 8 – Residential Day/Night Per Meter Customer Charge Delivery Charge Contract Demand Charge Delivery Charge As-Used Demand Charge (All kilowatt-hours, per kilowatt-hour) Delivery Charge Day Night Transition Charge All kilowatt-hours, per kilowatt-hour Bill Issuance Charge (per bill): 09/26/10 $23.63 $13.24 Effective Date 09/01/11 $23.63 $13.87 09/01/12 $23.63 $14.78

$0.0084 $0.0084

$0.0088 $0.0088

$0.0093 $0.0093

See Transition Charge Statement $0.73, as described in General Information Section 16.J.

SC 9 - General Service Day/Night Per Meter Customer Charge Delivery Charge Contract Demand Charge Delivery Charge As-Used Demand Charge (All kilowatt-hours, per kilowatt-hour) Delivery Charge Day Night Transition Charge All kilowatt-hours, per kilowatt-hour Bill Issuance Charge (per bill): 09/26/2010 $23.01 $13.07

Effective Date 09/01/2011 $23.63 $13.67 09/01/2012 $24.40 $14.16

$0.00987 $0.00987

$0.01006 $0.01006

$0.01028 $0.01028

See Transition Charge Statement $0.73, as described in General Information Section 16.J.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 287.2 New York State Electric & Gas Corporation Revision: 0 Initial Effective Date: September 26, 2010 Superseding Revision: Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 11 (Continued) RATES (Per Month) (Cont’d.) Delivery Rates for Service Classification No. 12: SC 12 – Residential Time of Use Per Meter Customer Charge Delivery Charge Contract Demand Charge Delivery Charge As-Used Demand Charge (All kilowatt-hours, per kilowatt-hour) Delivery Charge On-Peak Mid-Peak Off-Peak Transition Charge All kilowatt-hours, per kilowatt-hour Bill Issuance Charge (per bill): 09/26/10 $25.84 $73.51 Effective Date 09/01/11 $25.84 $75.59 09/01/12 $25.84 $78.72

$0.0135 $0.0135 $0.0135

$0.0139 $0.0139 $0.0139

$0.0143 $0.0143 $0.0143

See Transition Charge Statement $0.73, as described in General Information Section 16.J.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 288 New York State Electric & Gas Corporation Revision: 24 Initial Effective Date: September 26, 2010 Superseding Revision: 23 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010
SERVICE CLASSIFICATION NO. 11 (Continued) RATES (Per Month) (Cont’d.) Service Classification No. 2 with Interval Metering: Effective Date 09/01/2011 $20.93 $1.68 $8.48 $2.08

Per Meter Customer Charge Delivery Charge Meter Ownership Charge Meter Service Charge Meter Data Service Charge (Meter Reading) Contract Demand Charge (Contract kilowatts, per kilowatt) Delivery Charge As-Used Demand Charge (Per kilowatt, per day) Delivery Charge Reactive Charge Reactive kilovolt-ampere hours, per billing reactive kilovolt-ampere hour

09/26/2010 $18.82 $1.68 $8.48 $2.08

09/01/2012 $24.02 $1.68 $8.48 $2.08

$4.13

$4.19

$4.25

$0.18853

$0.19127

$0.19405

$0.00078

$0.00078

$0.00078

Transition Charge All kilowatt-hours, per kilowatt-hour Bill Issuance Charge (per bill):

See Transition Charge Statement $0.73, as described in General Information Section 16.J.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 288.1 New York State Electric & Gas Corporation Revision: 17 Initial Effective Date: September 26, 2010 Superseding Revision: 16 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 11 (Continued) RATES (Per Month) (Cont’d.) Service Classification No. 3 with Interval Metering: SC 3P – Primary
Per Meter Customer Charge Delivery Charge Meter Ownership Charge Meter Service Charge Meter Data Service Charge (Meter Reading) Contract Demand Charge (Contract kilowatts, per kilowatt) Delivery Charge As-Used Demand Charge (Per kilowatt, per day) Delivery Charge Reactive Charge Reactive kilovolt-ampere hours, per billing reactive kilovolt-ampere hour 09/26/2010 $64.39 $2.29 $11.58 $3.53 Effective Date 09/01/2011 $68.38 $2.29 $11.58 $3.53 09/01/2012 $70.18 $2.29 $11.58 $3.53

$2.80

$2.85

$2.93

$0.13619

$0.13870

$0.14245

$0.00078

$0.00078

$0.00078

Transition Charge All kilowatt-hours, per kilowatt-hour Bill Issuance Charge (per bill):

See Transition Charge Statement $0.73, as described in General Information Section 16.J.

SC 3S – Subtransmission
Per Meter Customer Charge Delivery Charge Meter Ownership Charge Meter Service Charge Meter Data Service Charge (Meter Reading) Contract Demand Charge (Contract kilowatts, per kilowatt) Delivery Charge As-Used Demand Charge (Per kilowatt, per day) Delivery Charge Reactive Charge Reactive kilovolt-ampere hours, per billing reactive kilovolt-ampere hour 09/26/2010 $59.02 $2.36 $11.91 $2.67

Effective Date 09/01/2011 $61.22 $2.36 $11.91 $2.67 09/01/2012 $63.49 $2.36 $11.91 $2.67

$1.95

$1.97

$2.01

$0.17612

$0.17830

$0.18149

$0.00078

$0.00078

$0.00078

Transition Charge All kilowatt-hours, per kilowatt-hour Bill Issuance Charge (per bill):

See Transition Charge Statement $0.73, as described in General Information Section 16.J.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 288.2 New York State Electric & Gas Corporation Revision: 9 Initial Effective Date: September 26, 2010 Superseding Revision: 8 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 11 (Continued) RATES (Per Month) (Cont’d.) Service Classification No. 7 with Interval Metering:

SC 7-1 Secondary
Per Meter Customer Charge Delivery Charge Meter Ownership Charge Meter Service Charge Meter Data Service Charge (Meter Reading) Contract Demand Charge (Contract kilowatts, per kilowatt) Delivery Charge As-Used Demand Charge (Per kilowatt, per day) Delivery Charge Reactive Charge Reactive kilovolt-ampere hours, per billing reactive kilovolt-ampere hour 09/26/2010 $74.10 $2.21 $11.14 $3.10

Effective Date 09/01/2011 $97.68 $2.21 $11.14 $3.10 09/01/2012 $136.99 $2.21 $11.14 $3.10

$3.70

$3.68

$3.81

$0.19976

$0.19840

$0.19446

$0.00078

$0.00078

$0.00078

Transition Charge All kilowatt-hours, per kilowatt-hour Bill Issuance Charge (per bill):

See Transition Charge Statement $0.73, as described in General Information Section 16.J.

SC 7-2 Primary Distribution
Per Meter Customer Charge Delivery Charge Meter Ownership Charge Meter Service Charge Meter Data Service Charge (Meter Reading) Contract Demand Charge (Contract kilowatts, per kilowatt) Delivery Charge As-Used Demand Charge (Per kilowatt, per day) Delivery Charge Reactive Charge Reactive kilovolt-ampere hours, per billing reactive kilovolt-ampere hour 09/26/2010 $231.27 $4.91 $24.85 $7.37

Effective Date 09/01/2011 $242.31 $4.91 $24.85 $7.37 09/01/2012 $242.31 $4.91 $24.85 $7.37

$3.15

$3.20

$3.27

$0.14182

$0.14408

$0.14733

$0.00078

$0.00078

$0.00078

Transition Charge All kilowatt-hours, per kilowatt-hour Bill Issuance Charge (per bill):

See Transition Charge Statement $0.73, as described in General Information Section 16.J.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 288.3 New York State Electric & Gas Corporation Revision: 0 Initial Effective Date: September 26, 2010 Superseding Revision: Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 11 (Continued) RATES (Per Month) (Cont’d.) Service Classification No. 7 with Interval Metering:

SC 7-3 Subtransmission
Per Meter Customer Charge Delivery Charge Meter Ownership Charge Meter Service Charge Meter Data Service Charge (Meter Reading) Contract Demand Charge (Contract kilowatts, per kilowatt) Delivery Charge As-Used Demand Charge (Per kilowatt, per day) Delivery Charge Reactive Charge Reactive kilovolt-ampere hours, per billing reactive kilovolt-ampere hour 09/26/2010 $499.79 $5.31 $26.80 $6.75

Effective Date 09/01/2011 $553.36 $5.31 $26.80 $6.75 09/01/2012 $575.80 $5.31 $26.80 $6.75

$0.86

$0.86

$0.87

$0.05737

$0.05730

$0.05809

$0.00078

$0.00078

$0.00078

Transition Charge All kilowatt-hours, per kilowatt-hour Bill Issuance Charge (per bill):

See Transition Charge Statement $0.73, as described in General Information Section 16.J.

SC 7-4 Transmission
Per Meter Customer Charge Delivery Charge Meter Ownership Charge Meter Service Charge Meter Data Service Charge (Meter Reading) Contract Demand Charge (Contract kilowatts, per kilowatt) Delivery Charge As-Used Demand Charge (Per kilowatt, per day) Delivery Charge Reactive Charge Reactive kilovolt-ampere hours, per billing reactive kilovolt-ampere hour 09/26/2010 $1,112.07 $9.92 $50.53 $18.61

Effective Date 09/01/2011 $1,256.53 $9.92 $50.53 $18.61 09/01/2012 $1,303.48 $9.92 $50.53 $18.61

$0.10

$0.10

$0.10

$0.03359

$0.03341

$0.03397

$0.00078

$0.00078

$0.00078

Transition Charge All kilowatt-hours, per kilowatt-hour Bill Issuance Charge (per bill):

See Transition Charge Statement $0.73, as described in General Information Section 16.J.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 289 New York State Electric & Gas Corporation Revision: 37 Initial Effective Date: September 26, 2010 Superseding Revision: 35 Issued in compliance with Oorder in Case 9-E-0715 dated September 21, 2010
SERVICE CLASSIFICATION NO. 11 (Continued)

Billing of Reactive Kilovolt Hours: Unless it is determined by the Company that system operations require that the customer take reactive power from the Company's system, all metered reactive energy used by the customer will be billed at the rate specified above. This includes reactive power used during normal operation of the customer's OSG or Wholesale Generator as well as that used when NYSEG provides standby service. Rate Periods: For a customer whose OASC is SC 2, 3, or 7, On-Peak hours are defined as the hours between 7:00 A.M. and 10:00 P.M. (Local Time), Monday through Friday with the exception of the following holidays: New Year's Day, Memorial Day, Independence Day, Labor Day, Thanksgiving Day and Christmas Day. Those hours not designated as On-Peak are defined as Off-Peak. Other rate periods are as defined in the customer’s OASC, i.e., SC 8, 9 or 12. SURCHARGE TO COLLECT SYSTEM BENEFITS CHARGE ("SBC"): A surcharge will be added to each customer bill for service under this Service Classification to collect the System Benefits Charge (as explained in this Schedule, General Information Section 4). See SBC Statement. RENEWABLE PORTFOLIO STANDARD CHARGE (“RPS”): A surcharge will be added to each customer bill for service under this Service Classification to collect the Renewable Portfolio Standard (as explained in this Schedule, General Information Section 5). See RPS Statement. SURCHARGE TO COLLECT TEMPORARY STATE ASSESSMENT (“TSAS”): A surcharge will be added to each customer bill for service under this Service Classification to collect the Temporary State Assessment (as explained in this Schedule, General Information Section 28). See TSAS Statement.

REVENUE DECOUPLING MECHANISM (“RDM”):
A customer billed at OASC as provided in this Service Classification shall be subject to a Revenue Decoupling Adjustment (as explained in this Schedule, General Information Section 7). See RDM Statement. The RDM Adjustment for the customer’s OASC will apply.
MERCHANT FUNCTION CHARGE: The Merchant Function Charge reflects the administrative costs of obtaining electricity supply. Customers whose electricity is supplied by an ESCO are not charged for this service. MINIMUM CHARGE: The minimum charge per month for service under this Service Classification is the Contract Demand Charge if applicable, plus the Customer Charge and the Bill Issuance Charge, if applicable, as listed above. For demand-billed customers with less than 50 kW Contract Demand, the minimum charge is the Customer Charge, plus the Bill Issuance Charge, if applicable.. INCREASE IN RATES and CHARGES:

The rates and charges under this Service Classification, including the minimum charge, will be increased by a surcharge pursuant to General Information Section 6 of this Schedule to reflect the taxes applicable within the municipality where the customer takes service.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: July 1, 2009

Leaf No. 289.1 Revision: 1 Superseding Revision:

SERVICE CLASSIFICATION NO. 11 (Continued) TERMS OF PAYMENT: Bills rendered under this Service Classification are payable on receipt. A late payment charge of one and one half percent (1 1/2%) per month will be billed on all amounts not paid by the "past due" date. For additional information, see NYSEG’s tariff, PSC No. 119 – Electricity, Section 4.

Issued in compliance with order in Case No. 09-M-0311 dated 6/19/09.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 1, 2004

Leaf No. 290 Revision: 1 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 11 (Continued) TERM A minimum of one year and thereafter until terminated by 60 days written notice. DETERMINATION OF DEMAND Contract Demand: A customer will have the option of accepting a contract demand (maximum potential demand at the facility to be provided standby service) established by the Company or the customer can establish the contract demand. Regardless of which party sets the customer’s contract demand, upon the occurrence of an exceedence, the contract demand will be increased (“ratcheted”) by the amount of the exceedence. 1. Company Established Contract Demand: For an Existing Customer, the contract demand will be established based on the maximum metered demand of that customer over the twelve (12) months prior to February 1, 2004, taking into consideration the output of existing OSG, the addition and/or removal of equipment, and the coincidence and diversity of the customer’s load. For a new customer (i.e., a customer for whom historical metered demand does not exist) or an Existing Customer where historical metered demand does not represent a reasonable contract demand level, the contract demand will be determined, in consultation with the customer, by assessing the nameplate rating of the equipment to be served, and projecting, through an engineering analysis, the coincidence and diversity of the customer’s load. The contract demand of a wholesale generator, who is connected to and provides electricity supply to a customer who would otherwise take delivery service from the Company, will be set at the maximum potential metered demand of the station loads of the wholesale generator when the generator is out of service, plus the maximum potential metered demand of the customer connected to, and generally provided electricity supply by, the wholesale generator. Surcharge: Where a customer elects to have NYSEG establish the contract demand, that customer will not incur a surcharge if that contract demand is exceeded except as described in this paragraph. However, a customer shall be obligated to provide NYSEG with written notice prior to the installation or removal of equipment, or any change in operation, that can be reasonably expected to change in a material fashion (defined as a change of more than twelve and one-half percent (12.5%)) the system capacity required to deliver electricity to the customer. If the customer fails to provide written notice, and the customer exceeds the contract demand, NYSEG has the right to include a surcharge in the customer's subsequent bill equal to the product of the applicable Contract Demand Charge, the amount of the exceedence, and the number of billing periods from, and including, the billing period in which the customer first commenced taking standby service from NYSEG at the understated contract demand, i.e., the billing period in which the customer installed the equipment or changed the operation that caused the exceedence (as demonstrated by the customer to NYSEG in writing), through the billing period that includes the date of the exceedence. If the customer fails to demonstrate in writing when it installed such equipment or changed such operation, then NYSEG will apply the surcharge, each month, from the first billing period in which the customer commenced taking standby service from NYSEG.
Issued in compliance with orders in Case No. 02-E-0779 dated 07/30/03 and 01/23/04, and Case No. 03-E-1552 dated 11/28/03.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 1, 2004

Leaf No. 291 Revision: 1 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 11 (Continued) Contract Demand: (Cont’d.) 2. Customer Established Contract Demand: A customer may establish the contract demand based on analysis and expected operation of the customer’s facility and OSG. Subsequently, a customer may revise its contract demand downward by written notice to NYSEG once every twelve (12) months. The revised contract demand level cannot be set at a level lower than the highest demand metered in the previous twelve (12) months unless the customer demonstrates in writing to NYSEG's reasonable satisfaction that electricity-consuming equipment is removed or disabled in place (not simply disconnected). NYSEG has the right to inspect the premises of a customer upon reasonable notice and at reasonable times in order to confirm that such energy-consuming equipment has been so removed or disabled in place (not simply disconnected). A customer may revise its contract demand upwards at any time upon written notice to NYSEG. Surcharge: Where the customer elects to establish its own contract demand and then exceeds the contract demand, a surcharge will apply to the current monthly bill equal to the following: Exceeding Contract Demand 0% to less than 10% 12 times the sum of the monthly contract demand charge amount calculated for the excess demand Exceeding Contract Demand 10% to less than 20% 18 times the sum of the monthly contract demand charge amount calculated for the excess demand Exceeding Contract Demand 20% or more occurs 24 times the sum of the monthly contract demand charge amount calculated for the excess demand

Where a new customer installs OSG, or an Existing Customer initially adds OSG, during a two (2) year period beginning February 1, 2004, one excedence in the first year of OSG operation of less than ten percent (10%) in magnitude would be excused from the above surcharge. For purposes of this paragraph, the OSG shall be deemed to have commenced operation when the OSG first delivers electricity to serve the customer’s load. As-Used Demand: 1. The as-used demand for customers with interval metering will be the aggregate of the highest daily 15minute integrated demand (measured in kW) occurring during the On-Peak hours as defined in “Rate Periods” above, during the billing period. If in any billing period, there is a failure in the metered usage data acquisition that results in the failure to record daily as-used demand data, NYSEG reserves the right to estimate reasonable values for the missing data for recording and billing purposes. 2. The daily as-used demand, for customers without demand metering, and not billed at the OASC will be the monthly metered kilowatt hours.

Issued in compliance with orders in Case No. 02-E-0779 dated 07/30/03 and Case No. 03-E-1552 dated 11/28/03

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 1, 2004

Leaf No. 292 Revision: 1 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 11 (Continued) METERING AND COMMUNICATION REQUIREMENTS: 1. A customer who provides telecommunications to the meter shall be responsible for all costs associated with the installation, operation and maintenance of the telecommunications line, including but not limited to, all telecommunications service bills. If the Company is unable to read the meter through a customer provided connection, and NYSEG has determined that the problem is not caused by the Company's equipment, the customer shall be responsible for resolution of the problem. The customer shall also be responsible for reimbursement of NYSEG expenses incurred for visits to the meter location to ascertain the cause of the problem. 2. A customer with demand metering and with 50 kW or more of Contract Demand is required to have interval metering and remote meter reading capability. Such customers will be responsible for the following: a) the incremental costs of interval metering equipment and its installation; b) the costs of providing remote meter reading capability through telecommunications to and from the meter; and c) the costs associated with resolution of any problems with the telecommunications provider, including reimbursing the Company for any expenses the Company incurs. 3. Meter Credits: A customer may be eligible for only one of the following. A customer eligible for one of the following meter credits will receive a monthly credit as described below: a) Competitive Metering Option: A qualified customer that selects the Competitive Metering Option must comply with the requirements specified in PSC No. 119 – Electricity, and specified in General Information Section 14 of this Schedule, and will receive a Competitive Metering Credit as set forth in Section 2 of Addendum-MET of PSC No. 119, or superseding issues thereof. b) Meter Owned By Customer, Installed And Maintained By The Company: A qualified customer that elects to own its own meters, as described in Section 3.A.2 of PSC No. 119 - Electricity, Service Connections, Meter Owned by Customer, Installed and Maintained by the Corporation, will receive a Meter Ownership Credit as described in Section 3.A.2.a.i. of that Schedule. This provision is separate and distinct from the Competitive Metering option above.

Issued in compliance with orders in Case No. 02-E-0779 dated 07/30/03 and Case No. 03-E-1552 dated 11/28/03

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 293 New York State Electric & Gas Corporation Revision: 23 Initial Effective Date: September 26, 2010 Superseding Revision: 22 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 11 (Continued) METERING AND COMMUNICATION REQUIREMENTS: (CONT’D.) 3. Meter Credits: (Cont’d.) c) Customers That Have Fully Paid for Meter and Instrument Transformation Costs: A demand billed customer taking service under these standby rates that has fully paid for their meter and instrument transformation costs will receive a monthly credit to the currently applicable monthly Customer Charge (excluding Special Provision (d)), as well as a portion of the standby service transition dollars allocated for collection in the Customer Charge. Below are the customer credits:

Customer Charge Credit Delivery Charge

SC 2 $1.82

SC 3P $29.53

SC 3S $43.15

SC 7-1 $3.02

SC 7-2 $29.11

SC 7-3 $94.65

SC 7-4 $347.97

ELECTRICITY SUPPLY A Customer taking service under SC 11 will have the choice of the following Supply Service Options for its Electricity Supply: For customers whose OASC is Service Classification No. 1, 6, 8, 9, or 12: 1. ESCO Supply Service (ESS); or 2. NYSEG Supply Service (NSS) For a customer whose OASC is Service Classification No. 2, 3, or a Service Classification No. 7: 1. ESCO Supply Service (ESS); or 2. NYSEG Supply Service (NSS); or 3. Hourly Pricing* * As set forth in General Information Section 25.I.F., Customer Eligibility Criteria, certain demand billed customers are required to participate in Mandatory Hourly Pricing. Terms and conditions applicable to these rate choices are explained in the customer’s OASC. With the exception of customers taking service under Special Provision (d) Previous SC 11 Tariff, all customers served under this Service Classification taking electricity supply service from the Company will be required to pay a Merchant Function Charge as set forth in the customer’s OASC. INTERCONNECTION REQUIREMENTS 1. A customer may connect an OSG facility for parallel operation with the Company’s delivery system, or isolate for operation with standby service provided by a wholesale generator by means of a double throw transfer switch, or another transfer switching scheme acceptable to the Company.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: December 31, 2004

Leaf No. 294 Revision: 2 Superseding Revision: 1

SERVICE CLASSIFICATION NO. 11 (Continued) INTERCONNECTION REQUIREMENTS (CONT’D.) 2. A customer must complete an Application for Service and must operate in compliance with standards and requirements set forth in either the Distributed Generation Interconnection Requirements found in Section 9 of Schedule PSC 119, and in Addendum-SIR of Schedule PSC 119 – Electricity entitled “New York State Standard Interconnection Requirements for New Generation Units 2 MW or Less Connected in Parallel with Utility Distribution Systems” or NYSEG Bulletin 86-01, entitled “Requirements for Independent Power Producers of Electricity.” In addition, customers must execute either the New York State Standardized Contract For Interconnection of New Distributed Generation Units With Capacity 2 MW or Less Connected in Parallel with Utility Distribution Systems(“SIR Contract”), as contained within Addendum-SIR of PSC 119 - Electricity, or the applicable contract. 3. A customer and the Company shall agree as to the operating mode, interconnection and equipment specifications for the OSG facility pursuant to either a or b below, as may be amended or superseded: a) the SIR Contract contained within Addendum-SIR of PSC 119, or b) b) NYSEG’s Bulletin 86-01. 4. A customer will be responsible for all costs associated with its OSG interconnection as set forth in the requirements listed in paragraphs 3a or 3b above, as applicable. 5. Contribution toward CT & VT Costs: For installations requiring Current Transformers (CTs) and Voltage (or Potential) Transformers (VTs), to the extent that a customer, as part of its original interconnection with the NYSEG’s system, paid for and installed CTs and VTs or compensated the Company for those costs up-front, the customer will receive a monthly bill credit, as mutually agreed upon by NYSEG and the customer. 6. Maintenance Schedules: A customer applying for standby service with a standby contract demand greater than 1000 kW is required to provide the Company with a schedule of OSG maintenance. A schedule must include the dates and times for the beginning and ending of all planned outages. A customer may revise the schedule one (1) month prior to the effective date of the outage. However, modifications communicated with less than one (1) month’s notice will not be allowed, unless the customer obtains Company approval. The annual provision of planned maintenance schedules by the customer will take place on October 1 of each year for standby service for the following calendar year. Such schedule will be utilized by NYSEG for planning functions. This provision does not take precedence with respect to any OSG maintenance provision in a power purchase agreement that may be in effect with the Company.

Issued in compliance with Order in Case 02-E-1282 dated 11/17/04.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: December 28, 2010 . Issued in compliance with order in Case 09-E-0715, dated September 21, 2010

Leaf No. 294.1 Revision: 5 Superseding Revision: 4

SERVICE CLASSIFICATION NO. 11 (Continued) INTERCONNECTION REQUIREMENTS (CONT’D.) 7. At the time of agreement, the customer with an OSG greater than 300 kVA, excluding Net Metered Farm Waste Generators less than 1000 kW, may select the payment method for paying the Company operations and maintenance charges on the interconnection equipment paid for by the customer but owned by NYSEG. The customer may select to pay either the actual charges for maintenance, as they may occur, or the customer may choose to pay an annual carrying charge of 9% (subject to review in the Company’s rate case proceedings) on the total investment in such equipment. The operations and maintenance costs on such equipment is billed on a monthly basis pursuant to the applicable contract or agreement. 8. NAERC Guidelines: A customer taking standby service shall comply with all reliability criteria, guidelines, and procedures established by the North American Electric Reliability Council (“NAERC”) as the same may be amended or superseded. Such compliance is necessary to ensure the continued reliability of North America's interconnected electric transmission electric systems. UNAUTHORIZED OSG INTERCONNECTION BY CUSTOMER: If a customer connects OSG to its electric system without: (a) notifying the Company; and (b) executing an appropriate standby service Application, and thereafter the Company discovers the interconnection, NYSEG will backbill the customer for all standby service rendered subsequent to the estimated connection of such OSG. In preparing such backbills, the Company will assess a standby service contract demand surcharge provision equal to two times that which would otherwise be computed under the Determination of Demand Provision, paragraph 1 (Company Established Contract Demand) of this Service Classification, and assume the standby contract demand had been inappropriately established at 0 kW. SPECIAL PROVISIONS (a) Demand Metered Customer With Less Than 50 kW of Contract Demand: A customer with a contract demand of less than fifty (50) kW without interval metering will be billed at the OASC. A customer with a contract demand of less than fifty (50) kW can choose to be served at the standby rate, provided that the customer pays all one-time and ongoing costs associated with the purchase and installation of an interval meter, and telecommunication equipment as discussed in the “Metering and Communications Requirements” section of this SC 11 tariff. (b) Small Customer Exclusion: Small customers, defined as those customers qualifying for service under Service Classification Nos. 1, 6, 8, 9, and 12, will be billed at the OASC rate instead of the standby service rate in SC 11. This exemption will be discontinued on May 31, 2015, or upon the date that 200 such standby customers located east of Total East or 250 such standby customers west of Total East are billed under this provision, provided, however, that the discontinuance of this exemption shall not affect any customer that received the exemption prior to the date of discontinuance, which customers will continue to receive the exemption until the conclusion of the phase-in described in the “Optional Standby Service Rate Phase-ins is Applicable to” section of this Service Classification.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 1, 2004

Leaf No. 294.2 Revision: 0 Superseding Revision:

SERVICE CLASSIFICATION NO. 11 (Continued) SPECIAL PROVISIONS (CONT’D.) (c) Individually Negotiated Contracts 1) Individual Agreements for Customers Considering Isolation NYSEG is authorized to offer individually negotiated agreements for standby service to customers that may install back-up generation and disconnect their premises from the NYSEG system in lieu of taking tariff standby service. The customer must document that it can physically, environmentally, and economically isolate from NYSEG's grid by installing and operating back-up generation at a lower cost than paying for standby service, and that such option is the alternative the customer will select if NYSEG does not offer a negotiated rate alternative. At a minimum, the negotiated rate agreement must provide for recovery of NYSEG’s marginal costs plus a reasonable contribution to NYSEG's recovery of its fixed costs. NYSEG will use its existing authorization under Service Classification No. 14 to gain contribution from any customer presently isolated from its delivery system. NYSEG will respond to a customer application for a negotiated rate agreement within ninety (90) days of its receipt, with a negotiated rate agreement offer or a written explanation for its rejection of the application. Either party may seek from Staff a non-binding resolution of a dispute over the negotiation of such an individual rate agreement In the event of a conflict between any provisions of an agreement negotiated pursuant to this authority and any provision of NYSEG’s Joint Proposal filed April 7, 2003 in Case 02-E-0779 or the standby rates provisions of NYSEG's tariff on the same subject, the provision of the negotiated agreement shall take precedence and control. 2) Individual Agreements for Customers Selling into the Wholesale Market NYSEG is authorized to offer individually negotiated agreements for standby service with customers that sell into the market, or to a third party, no less than 90% of their site's energy output, net of station power requirements, from generators located on the site having a total name plate rating equal to or greater than 50 MW. The rates and charges negotiated will reflect, where applicable, the characteristics of the specific interconnection arrangements, including, but not limited to, the voltage level of the interconnection, whether the interconnection is bi-directional, and the nature of the NYSEG facility where the generator is interconnected with the NYSEG system. NYSEG will respond to a customer application for a negotiated rate agreement within ninety (90) days of its receipt with a negotiated rate agreement offer or a written explanation for its rejection of the application. Either party may seek from Staff a non-binding resolution of a dispute over the negotiation of such an individual rate agreement. In the event of a conflict between any provision of an agreement negotiated pursuant to this authority and any provision of NYSEG’s Joint Proposal filed April 7, 2003 in Case 02-E-0779 or the standby rates provisions of NYSEG's tariff on the same subject, the provision of the negotiated agreement shall take precedence and control.

Issued in compliance with orders in Case No. 02-E-0779 dated 07/30/03 and Case No. 03-E-1552 dated 11/28/03

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 1, 2004

Leaf No. 294.3 Revision: 0 Superseding Revision:

SERVICE CLASSIFICATION NO. 11 (Continued) SPECIAL PROVISIONS (CONT’D.) (d) Previous SC 11 Tariff This provision contains the standby service rates, terms and conditions for existing customers as defined in Section 2 above, billed under Service Classification No. 11 standby service rates prior to February 1, 2004. The rates, terms and conditions in this provision will only apply, to the extent required, to existing customers who choose the “Optional Standby Service Rate Phase-in is Applicable to” option. DEFINITIONS: SUPPLEMENTAL SERVICE: Electric capacity and energy supplied by the Company on a regular basis to supplement the customer's power requirement in addition to that ordinarily supplied by the on-site nonutility generation facilities. All customers taking Supplemental Service shall be billed at the appropriate voltage level rate under Service Classification No. 7. BACK-UP SERVICE: Electric capacity and energy supplied by the Company during an unscheduled outage of the customer's source of on-site non-utility generation to replace power ordinarily generated by the onsite non-utility generation facilities. Customers taking backup service shall notify the Company within fortyeight hours after the initiation of each outage of the customer's source of on-site non-utility generation. MAINTENANCE SERVICE: Electric capacity and energy supplied by the Company during a scheduled outage of the customer's source of on-site non-utility generation to replace power ordinarily generated by the on-site non-utility generation facilities. Maintenance service will be provided for outages: a) scheduled with the Company pursuant to a power purchase agreement between the Corporation and the customer; or b) scheduled with the Company thirty (30) days in advance. Maintenance service will not be permitted during the months of December, January, July, and August during On-Peak hours. During other periods, the Company will not unreasonably withhold approval of maintenance. AVAILABILITY AND TYPES OF SERVICE: Service under this Service Classification is available to any qualifying customer in NYSEG's service territory. Supplemental, Backup and/or Maintenance power will be provided to the customer and/or the customer's source of on-site non-utility generation. The customer may elect to 1) take all service under this Service Classification, 2) take all service under another firm Service Classification for which the customer is eligible, or 3) segregate its total power requirement into portions so that a portion is served under this Service Classification, while the other is served under another appropriate firm Service Classification for which the customer is eligible. Prior to receiving service under this Service Classification, appropriate agreement(s) in the form(s) of those on file with the Commission must be signed by the customer and accepted by the Company.

Issued in compliance with orders in Case No. 02-E-0779 dated 07/30/03 and Case No. 03-E-1552 dated 11/28/03

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 1, 2004

Leaf No. 294.4 Revision: 0 Superseding Revision:

SERVICE CLASSIFICATION NO. 11 (Continued) SPECIAL PROVISIONS (CONT’D.) (d) Previous SC 11 Tariff (Cont’d.) RATES: (Per Month) RATES FOR SUPPLEMENTAL SERVICE: Customers taking the Supplemental Service shall be billed at the appropriate voltage level rate under Service Classification No. 7. RATES FOR BACKUP AND MAINTENANCE SERVICE: CUSTOMER CHARGE (PER METER)(1): For customers who would otherwise be eligible for service under Service Classification No. 7: Transmission Subtransmission Primary Secondary $ 35.65 $ 34.58 $ 49.11 $ 35.81

For customers who would otherwise be eligible for service under Service Classification No. 3: Subtransmis sion Primary $ 34.58 $ 49.11

For customers who would otherwise be eligible for service under Service Classification No. 2: Secondary (1) $ 35.81

For installations requiring current transformers (CTs) and voltage transformers (VTs), the customer shall pay CT and VT costs as part of the interconnection costs. Customers will also pay the remaining costs of any facility constructed solely to serve that customer.

Issued in compliance with orders in Case No. 02-E-0779 dated 07/30/03 and Case No. 03-E-1552 dated 11/28/03

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 1, 2004

Leaf No. 294.5 Revision: 0 Superseding Revision:

SERVICE CLASSIFICATION NO. 11 (Continued) SPECIAL PROVISIONS (CONT’D.) (d) Previous SC 11 Tariff (Cont’d.) RATES FOR BACK-UP AND MAINTENANCE SERVICE: (Cont'd) DEMAND CHARGES, PER KW: Contract Demand Charges: Related to Generation, Ancillary, and Transmission Facilities: For customers who would otherwise be eligible for service under Service Classification No. 7:

Transmission Subtransmission Primary Secondary

$ 0.35 $ 0.35 $ 0.32 $ 0.23

For customers who would otherwise be eligible for service under Service Classification No. 3:

Subtransmmission Primary

$ 0.32 $ 0.29

For customers who would otherwise be eligible for service under Service Classification No. 2:

Secondary Related to Primary Facilities:

$ 0.24

For customers who would otherwise be eligible for service under Service Classification No. 7: Primary Secondary $ 1.43 $ 0.72

For customers who would otherwise be eligible for service under Service Classification No. 3: Primary $ 1.29

For customers who would otherwise be eligible for service under Service Classification No. 2: Secondary $ 0.78

Issued in compliance with orders in Case No. 02-E-0779 dated 07/30/03 and Case No. 03-E-1552 dated 11/28/03

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 1, 2004

Leaf No. 294.6 Revision: 0 Superseding Revision:

SERVICE CLASSIFICATION NO. 11 (Continued) SPECIAL PROVISIONS (CONT’D.) (d) Previous SC 11 Tariff (Cont’d.) RATES FOR BACK-UP AND MAINTENANCE SERVICE: (Cont'd) DEMAND CHARGES, PER KW: (Cont'd) Contract Demand Charges, per KW: (Cont'd) Related to Secondary Facilities: For customers who would otherwise be eligible for service under Service Classification No. 7: Secondary $ 3.34

For customers who would otherwise be eligible for service under Service Classification No. 2: Secondary $ 2.45

As-Used Demand Charges, per KW (Back-Up Service Only): For the use of Generation, Ancillary and Transmission Facilities: For customers who would otherwise be eligible for service under Service Classification No. 7: Transmission Subtransmission Primary Secondary $ 1.31 $ 1.33 $ 1.20 $ 0.85

For customers who would otherwise be eligible for service under Service Classification No. 3: Subtransmission Primary $ 1.20 $ 1.11

For customers who would otherwise be eligible for service under Service Classification No. 2: Secondary $ 0.89

Issued in compliance with orders in Case No. 02-E-0779 dated 07/30/03 and Case No. 03-E-1552 dated 11/28/03

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: November 1, 2009

Leaf No. 294.7 Revision: 2 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 11 (Continued) SPECIAL PROVISIONS (CONT’D.) (d) Previous SC 11 Tariff (Cont’d.) RATES FOR BACK-UP AND MAINTENANCE SERVICE: (Cont'd) DEMAND CHARGES, PER KW: As-Used Demand Charges, per KW (Back-Up Service Only): (Cont'd) For the use of Primary Facilities: For customers who would otherwise be eligible for service under Service Classification No. 7: Primary Secondary $ 1.43 $ 0.72

For customers who would otherwise be eligible for service under Service Classification No. 3: Primary $ 1.29

For customers who would otherwise be eligible for service under Service Classification No. 2: Secondary $ 0.78

REACTIVE CHARGE*, (per metered RKVAH):
* Effective 05/01/2010, the Reactive Charge will be $0.00078.

$0.00095

Issued in compliance with order in Case No. 08-E-0751 dated 09/22/09.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 1, 2004

Leaf No. 294.8 Revision: 0 Superseding Revision:

SERVICE CLASSIFICATION NO. 11 (Continued)
SPECIAL PROVISIONS (CONT’D.) (d) Previous SC 11 Tariff (Cont’d.) RATES FOR BACK-UP AND MAINTENANCE SERVICE: (Cont'd) ENERGY CHARGES, PER KWH: Energy charges will be the sum of the energy component of the energy charge and the demand component of the energy charge. Energy Component of Energy Charge: For Back-Up Service: For customers who would otherwise be eligible for service under Service Classification No. 7: On-Peak Transmission Subtransmission Primary Secondary Off-Peak Transmission Subtransmission Primary Secondary

$ .06827 $ .06968 $ .07312 $ .08075 $ .04586 $ .04695 $ .04923 $ .05102

For customers who would otherwise be eligible for service under Service Classification No. 3: Subtransmission: All kilowatt-hours, per kilowatt-hour up to a point equaling 200 hours' metered demand Over 200 hours' use and up to a point equaling 350 hours' use of metered demand Over 350 hours' use of metered demand Primary: All kilowatt-hours, per kilowatt-hour up to a point equaling 200 hours' metered demand Over 200 hours' use and up to a point equaling 350 hours' use of metered demand Over 350 hours' use of metered demand

$ .06830 $ .05889 $ .04623

$ .07102 $ .06231 $ .04923

For customers who would otherwise be eligible for service under Service Classification No. 2: Secondary: All kilowatt-hours, per kilowatt-hour up to a point equaling 200 hours' metered demand Over 200 hours' use and up to a point equaling 350 hours' use of metered demand Over 350 hours' use of metered demand

$ .07397 $ .06310 $ .05102

Issued in compliance with orders in Case No. 02-E-0779 dated 07/30/03 and Case No. 03-E-1552 dated 11/28/03

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 1, 2004

Leaf No. 294.9 Revision: 0 Superseding Revision:

SERVICE CLASSIFICATION NO. 11 (Continued)
SPECIAL PROVISIONS (CONT’D.) (d) Previous SC 11 Tariff (Cont’d.) RATES FOR BACK-UP AND MAINTENANCE SERVICE: (Cont'd) ENERGY CHARGES, per KWH: (Cont'd) Energy Component of Energy Charge: (Cont'd) For Maintenance Service: For customers who would otherwise be eligible for service under Service Classification No. 7: On-Peak Transmission Subtransmission Primary Secondary Off-Peak Transmission Subtransmission Primary Secondary

$ .06827 $ .06968 $ .07312 $ .08075

$ .04586 $ .04695 $ .04923 $ .05102

For customers who would otherwise be eligible for service under Service Classification No. 3: Subtransmission: All kilowatt-hours, per kilowatt-hour up to a point equaling 200 hours' metered demand Over 200 hours' use and up to a point equaling 350 hours' use of metered demand Over 350 hours' use of metered demand Primary: All kilowatt-hours, per kilowatt-hour up to a point equaling 200 hours' metered demand Over 200 hours' use and up to a point equaling 350 hours' use of metered demand Over 350 hours' use of metered demand

$ .06830 $ .05889 $ .04623

$ .07102 $ .06231 $ .04923

For customers who would otherwise be eligible for service under Service Classification No. 2: Secondary: All kilowatt-hours, per kilowatt-hour up to a point equaling 200 hours' metered demand Over 200 hours' use and up to a point equaling 350 hours' use of metered demand Over 350 hours' use of metered demand

$ .07397 $ .06310 $ .05102\

Issued in compliance with orders in Case No. 02-E-0779 dated 07/30/03 and Case No. 03-E-1552 dated 11/28/03

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 1, 2004

Leaf No. 294.10 Revision: 0 Superseding Revision:

SERVICE CLASSIFICATION NO. 11 (Continued) SPECIAL PROVISIONS (CONT’D.) (d) Previous SC 11 Tariff (Cont’d.) RATES FOR BACK-UP AND MAINTENANCE SERVICE: (Cont'd) ENERGY CHARGES, per KWH: (Cont'd) Demand Component of Energy Charge: For Back-Up Service: For customers who would otherwise be eligible for service under Service Classification No. 7: On-Peak Transmission Subtransmission Primary Secondary

$ .03441 $ .03201 $ .02955 $ .02493

For customers who would otherwise be eligible for service under Service Classification No. 3: Subtransmission: All kilowatt-hours, per kilowatt-hour up to a point equaling 200 hours' metered demand Over 200 hours' use and up to a point equaling 350 hours' use of metered demand Over 350 hours' use of metered demand Primary: All kilowatt-hours, per kilowatt-hour up to a point equaling 200 hours' metered demand Over 200 hours' use and up to a point equaling 350 hours' use of metered demand Over 350 hours' use of metered demand

$ .03172 $ .03172 $ .00000

$ .02224 $ .02224 $ .00000

For customers who would otherwise be eligible for service under Service Classification No. 2: Secondary: All kilowatt-hours, per kilowatt-hour up to a point equaling 200 hours' metered demand Over 200 hours' use and up to a point equaling 350 hours' use of metered demand Over 350 hours' use of metered demand

$ .01973 $ .01973 $ .00000

For Maintenance Service: There is no charge related to a demand component in the energy charge.

Issued in compliance with orders in Case No. 02-E-0779 dated 07/30/03 and Case No. 03-E-1552 dated 11/28/03

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 1, 2004

Leaf No. 294.11 Revision: 0 Superseding Revision:

SERVICE CLASSIFICATION NO. 11 (Continued) SPECIAL PROVISIONS (CONT’D.) (d) Previous SC 11 Tariff (Cont’d.) MINIMUM CHARGE: The Customer Charge plus the Contract Demand Charge related to Ge neration, Transmission, Ancillary and Distribution Facilities, unless the as-used demand charges exceed the rolling 12-month minimum contract demand charge as described later in this Service Classification. DETERMINATION OF CONTRACT DEMAND: The Contract Demand for calculating the monthly bill under this Service Classification shall be the demand set forth in the customer's application for service. Thereafter, it will be increased to the highest metered demand within the term of the contract. The metered demand will be the highest average kilowatts used in any fifteen-minute interval during the month. Customers can change their contract demand nominations annually or whenever a new rate design is implemented, except that the nomination: 1) shall not be demonstrably unreasonable in light of likely usage by the customer should the customer take back-up and/or maintenance service from NYSEG; and 2) shall not be lower then the maximum demand achieved by the customer in the twelve months prior to the date of the contract nomination. Customers will be subject to a monthly contract demand surcharge if the customer's metered demand exceeds the contract demand. The surcharge will be equal to nine (9) times the product of a) the applicable contract demand charge; and b) the difference between the actual demand for that month and the nominated demand. DETERMINATION OF MINIMUM FOR CONTRACT DEMAND CHARGE FOR GENERATION, ANCILLARY, AND TRANSMISSION (G,A,T): Customers will pay a minimum demand charge related to generation, ancillary, and transmission costs. It is based on a $ per kW of the contract demand and is accumulated over a rolling 12-month period. This component will be compared to the as used demand charge (G,A,T) plus the demand (G,A,T) cost that is rolled into the energy charge, also accumulated over a rolling 12-month period. If the contract demand charge is greater than the as-used demand plus the demand (G,A,T) cost that is rolled into the energy charge then the customer will only pay the contract demand charge in that month. If it is less than the asused demand plus the demand (G,A,T) cost that is rolled into the energy charge, then the customer will pay that difference in that month. DETERMINATION OF MONTHLY AS-USED BILLING DEMAND: For the use of the Company's generation, ancillary, and transmission facilities, the customer's kW billing demand for calculating the As-Used demand-related charges under this Service Classification shall be the current month's highest metered On-Peak demand. For the use of the Company’s distribution facilities, the customer's kW billing demand for calculating the As-Used demand-related charges under this Service Classification shall be the current month's highest metered peak demand in the On-Peak or Off-Peak period.

Issued in compliance with orders in Case No. 02-E-0779 dated 07/30/03 and Case No. 03-E-1552 dated 11/28/03

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 1, 2004

Leaf No. 294.12 Revision: 0 Superseding Revision:

SERVICE CLASSIFICATION NO. 11 (Continued) SPECIAL PROVISIONS (CONT’D.) (d) Previous SC 11 Tariff (Cont’d.) Interconnection Facilities The customer and the Company shall agree to the operating mode, interconnection and equipment specifications as contained in the following documents on file with Public Service Commission; the Commission may review the specifications and arbitrate if a dispute should occur: "Requirements for the Installation of Electric Services and Meters," "Specifications for Customer Electric Service 2.4 kV to 34.5 kV," (SP-1099), and NYSEG's Bulletin 86-01. Interconnection Charge At the time the Company and an on-site generation facility owner enter into a Purchase Power Agreement, the owner of the on-site non-utility sources of generation with capacity greater than 15 KW may choose to 1) pay the Company for actual charges for maintenance on interconnection equipment paid for by the facility owner and owned by the Company, at the time the Company incurs those charges, or 2) pay an annual carrying charge of 9% (subject to review in the Company's rate case proceedings) on the total investment in such equipment. Such carrying charges shall be payable upon the initiation of service and annually thereafter upon the anniversary of service pursuant to this Service Classification. Parallel Service Option The customer has the option of 1) segregating the load supplied by cogeneration or small power production facility from the load supplied by the Company’s Supplemental Service, so that the nonutility source of generation, for which the customer would need Backup or Maintenance Service by the Company could not be operated in parallel with the Supplemental Service supplied by the Company or 2) providing service from the cogeneration and small power production facility in parallel with the Supplemental Service provided by the Company. If option No. 2 is chosen, the Backup or Maintenance for the cogeneration or small power production supply shall be metered separately from the Supplemental Service provided by the Company, and any additional meter and switching costs shall be paid by the customer. Load Factor Ceiling If energy billed hereunder as On-Peak Back-up and Maintenance Service during the most recent twelve (12) billing periods exceeds 10% of On-Peak hours (384) times the Contract Demand, or if energy billed hereunder as Off-Peak Back-up Service during the most recent twelve (12) billing periods exceeds 10% of Off- Peak (492) hours times the Contract Demand, thereafter billing shall be for Supplemental Service only until the load factor is less than 10 percent in both the On-Peak and Off-Peak periods for twelve (12) consecutive months.

Issued in compliance with orders in Case No. 02-E-0779 dated 07/30/03 and Case No. 03-E-1552 dated 11/28/03

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: January 1, 2008
SERVICE CLASSIFICATION NO. 12

Leaf No. 295 Revision: 1 Superseding Revision: 0

APPLICABLE TO THE USE OF SERVICE FOR: Existing or new, large residential service customers who have used, or are estimated to use, a minimum of 35,000 KWH during a twelve month period in individual private dwellings, flats or apartments, and such religious customers utilizing service exclusively in connection with religious purposes by a corporation or association organized and conducted in good faith for religious purposes. Applicable also to use exclusively in connection with a community residence for the mentally disabled, as defined in subdivision 28, 28-a, or 28-b of section 1.03 of the mental hygiene law, provided that such residence is operated by a not-for-profit corporation and, if supervisory staff is on site 24 hours a day, that the residence provides living accommodations for 14 or fewer residents. Also applicable to any notfor-profit corporation that is a veterans' organization that owns or leases a post or hall. After application from a qualified customer, the Corporation will meter and bill all energy used during the On-Peak, Mid-Peak, and Off-Peak periods at the associated rates, as defined below. CHARACTER OF SERVICE: Residential: Continuous - Alternating Current, 60 Cycle; 120, 120/208, or 120/240 volts - Single Phase. (Characteristics depend upon available circuits.) Religious, Veterans' Organizations, and Community Residence Customers: Continuous - alternating current, 60 cycle - Single or Three Phase. (Characteristics depend upon available circuits and equipment.) RATE PERIODS: (Stated in Eastern Standard Time) Winter: December through February On-Peak: 7:00 AM to 10:00 AM, Monday through Friday 5:00 PM to 10:00 PM, Monday through Friday Mid-Peak: 10:00 AM to 5:00 PM, Monday through Friday 10:00 PM to 11:30 PM, Monday through Friday 7:00 AM to 11:30 PM, Saturday, Sunday and Holidays (Defined Below) 11:30 PM to 7:00 AM, Monday through Sunday and Holidays

Off-Peak:

Summer: June through August On-Peak: 10:00 AM to 6:00 PM, Monday through Friday Mid-Peak: 7:00 AM to 10:00 AM, Monday through Friday 6:00 PM to 11:30 PM, Monday through Friday 7:00 AM to 11:30 PM, Saturday, Sunday and Holidays 11:30 PM to 7:00 AM, Monday through Sunday and Holidays

Off-Peak:

Off-Season: March, April, May, September, October, November Mid-Peak: 7:00 AM to 11:30 PM, Monday through Sunday and Holidays Off-Peak: 11:30 PM to 7:00 AM, Monday through Sunday and Holidays Holidays: New Year's Day, Memorial Day, Independence Day, Labor Day, Thanksgiving Day and Christmas Day.

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 296 New York State Electric & Gas Corporation Revision: 10 Initial Effective Date: September 26, 2010 Superseding Revision: 8 Issued in compliance with Order in Case 09-E-0915 dated September 21, 2010 SERVICE CLASSIFICATION NO. 12 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: Pursuant to General Information Section 25, Supply Service Options, customers served under this Service Classification will choose from different electric rate choices offered by the Company as described below. NYSEG will offer a Retail Access rate choice and a Non-Retail Access rate choice. The Retail Access choice is the ESCO Supply Service (ESS). The Non-Retail Access choice is the NYSEG Supply Service (NSS). NYSEG will provide Delivery Service regardless of the customer’s Supply Service Option. 1. ESCO Supply Service (ESS) This Retail Access choice includes fixed charges for NYSEG delivery service and a Transition Charge (NonBypassable Charge [NBC]). Supply service will be provided by an Energy Services Company (ESCO). Customers that elect ESS and receive a Consolidated Bill will not be subject to the Bill Issuance Charge. RATE: (Per Meter, Per Month) Delivery Service: Effective Date 09/01/2011 $24.11

Customer Charge Energy Charge
(All kilowatt-hours, per kilowatt-hour)

09/26/2010 $24.11

09/01/2012 $24.11

On-Peak Service Mid-Peak Service Off-Peak Service Transition Charge All kilowatt-hours, per kilowatt-hour

$0.0317 $0.0317 $0.0317

$0.0326 $0.0326 $0.0326

$0.0336 $0.0336 $0.0336

See Transition Charge Statement

Bill Issuance Charge (per bill):

$0.73, as described in General Information Section 16.J.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2008

Leaf No. 297 Revision: 5 Superseding Revision: 3

SERVICE CLASSIFICATION NO. 12 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (Cont'd.)

Reserved for Future Use

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Leaf No. 298 Revision: 16 Superseding Revision: 14

SERVICE CLASSIFICATION NO. 12 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (Cont'd.) NYSEG will provide Delivery and Commodity Service for the Non-Retail Access choice. 2. Reserved for Future Use

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2008

Leaf No. 298.1 Revision: 4 Superseding Revision: 3

SERVICE CLASSIFICATION NO. 12 (Continued) SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (Cont'd.) NYSEG will provide Delivery and Commodity Service for the Non-Retail Access choices.

Reserved for Future Use

Issued in compliance with order in Case No. 07-E-0479 dated 08/29/07.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 299 New York State Electric & Gas Corporation Revision: 9 Initial Effective Date: September 26, 2010 Superseding Revision: 7 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 12 (Continued)
SUPPLY SERVICE OPTIONS AVAILABLE TO CUSTOMERS: (Cont'd.) 3. NYSEG Supply Service (NSS) This Non-Retail Access choice includes fixed charges for NYSEG delivery service, a Transition Charge (Non-Bypassable Charge [NBC]), a fluctuating commodity charge for electricity supplied by NYSEG, and a Merchant Function Charge. RATE: (Per Meter, Per Month)

Customer Charge Energy Charge
(All kilowatt-hours, per kilowatt-hour)

09/26/2010 $24.11

Effective Date 09/01/2011 $24.11

09/01/2012 $24.11

On-Peak Service Mid-Peak Service Off-Peak Service Transition Charge All kilowatt-hours, per kilowatt-hour
Commodity Service

$0.0317 $0.0317 $0.0317

$0.0326 $0.0326 $0.0326

$0.0336 $0.0336 $0.0336

See Transition Charge Statement

The charge for Electric Power Supply provided by NYSEG will fluctuate each month as further described in General Information Section 25.I.C., Calculation of the Commodity Charge.

Merchant Function Charge All kilowatt-hours, per kilowatt-hour See Merchant Function Charge Statement Bill Issuance Charge (per bill): $0.73, as described in General Information Section 16.J.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 300 New York State Electric & Gas Corporation Revision: 21 Initial Effective Date: September 26, 2010 Superseding Revision: 19 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010
SERVICE CLASSIFICATION NO. 12 (Continued) MERCHANT FUNCTION CHARGE: The Merchant Function Charge reflects the administrative costs of obtaining electricity supply, as further explained in General Information Section 25.D. Customers whose electricity is supplied by an ESCO are not charged for this service. MINIMUM CHARGE: The minimum charge for service under this Service Classification is the monthly Customer Charge plus the Bill Issuance Charge, if applicable, as listed above. SURCHARGE TO COLLECT SYSTEM BENEFITS CHARGE ("SBC"): A surcharge will be added to each customer bill for service under this Service Classification to collect the System Benefits Charge (as explained in this Schedule, General Information Section 4). See SBC Statement. RENEWABLE PORTFOLIO STANDARD CHARGE (“RPS”): A surcharge will be added to each customer bill for service under this Service Classification to collect the Renewable Portfolio Standard (as explained in this Schedule, General Information Section 5). See RPS Statement. SURCHARGE TO COLLECT TEMPORARY STATE ASSESSMENT (“TSAS”): A surcharge will be added to each customer bill for service under this Service Classification to collect the Temporary State Assessment (as explained in this Schedule, General Information Section 28). See TSAS Statement.

REVENUE DECOUPLING MECHANISM (“RDM”):
A customer taking service under this Service Classification shall be subject to a Revenue Decoupling Adjustment (as explained in this Schedule, General Information Section 7). See RDM Statement
INCREASE IN RATES AND CHARGES: The rates and charges under this service classification, including minimum charges, will be increased by a surcharge pursuant to Section 6 of P.S.C. No. 120 to reflect the tax rates applicable within the municipality where the customer takes service. TERMS OF PAYMENT:

All bills are rendered at the above "unit prices" and that amount is due on bills paid on or before the past due date indicated on the bill. A late payment charge at the rate of one and one-half percent (1 1/2%) per month will be billed on all amounts not paid by that date. (Further details in Section 4-B of P.S.C. No. 119 - Electricity or superseding issues thereof.)

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity Leaf No. 301 New York State Electric & Gas Corporation Revision: 6 Initial Effective Date: September 26, 2010 Superseding Revision: 3 Issued in compliance with Order in Case 09-E-0715 dated September 21, 2010 SERVICE CLASSIFICATION NO. 12 (Continued)
TERM: Single and Three Phase Service: Term of Service: One month and thereafter until terminated by 48 hours' written notice. Duration of Service: Customers selecting service under this service classification on or after November 17, 1997, must remain on this rate for one year before transferring to another service classification. Service under this service classification, once terminated by the customer, will be unavailable to said customer at the same premises for one year from the date of such cancellation. SPECIAL PROVISIONS: (a) Multiple Dwellings: Two or more individual flats, apartments or dwelling units presently supplied service through one meter may be billed under this service classification.

(b)

Commercial Use: When a customer operates a commercial establishment (incidental to his residence) in the same building or on the same premises as his residence and takes his entire service through one meter, this classification will apply for the entire service only if the connected load in the residential portion exceeds that in the commercial portion, provided that the connected load in the commercial portion does not exceed 1.5 KW. If the reverse is true, the general classification will apply to the entire service. However, the customer may elect to take service under both the residential and general rates, in which case there will be a separate meter for the residential portion and a separate meter for the general portion.

(c)

Budget Billing: Customers may, by signing an application, be billed monthly in accordance with the budget plan set forth in Section 4-O of P.S.C. No. 119 - Electricity or superseding issues thereof.

(d)

RESERVED FOR FUTURE USE

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2007

Leaf No. 301.1 Revision: 2 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 12 (Continued) SPECIAL PROVISIONS: (Cont'd) (d) RESERVED FOR FUTURE USE

(e) RESERVED FOR FUTURE USE (f) RESERVED FOR FUTURE USE

Issued in compliance with order in Case No. 05-E-1222 dated 08/23/06.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: February 5, 2009 Effective date postponed to 02/27/09. See Supplement No. 13.

Leaf No. 302 Revision: 3 Superseding Revision: 2

SERVICE CLASSIFICATION NO. 12 (Continued) SPECIAL PROVISIONS: (Cont'd) (g) Residential Solar Electric Service Option: This option is for a customer qualifying for the Residential Solar Electric Service Option pursuant to General Information Section 26 of this Schedule and taking service under SC 12. If electricity (kWh) supplied by the customer to the Corporation is not metered for the time-differentiated periods, an allocation to each TOU period will be done according to the allocation factors as set forth below. For customers billed on time-differentiated rates, if the electricity (kWh) supplied by the customer to the Corporation is not metered for the time-differentiated periods, an allocation to each TOU period will be done according to allocation factors as set forth below: Winter and summer – December, January, February, June, July, August: 24 % [for On-Peak] 45% [for Mid-Peak] 31% [for Off-Peak] Off-Season – March, April, May, September, October, November: 67% [for Mid-Peak] 33% [for Off-Peak]

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: February 5, 2009 Effective date postponed to 02/27/09. See Supplement No. 13.

Leaf No. 303 Revision: 3 Superseding Revision: 2

SERVICE CLASSIFICATION NO. 12 (Continued) Reserved for Future Use

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: May 29, 2005

Leaf No. 303.1 Revision: 0 Superseding Revision:

SERVICE CLASSIFICATION NO. 12 (Continued) (g) Residential Solar Electric Service Option: (Cont'd.) The following generating credit allocations reflect a pro ration to the On-Peak, Mid-Peak, and Off-Peak TOU periods based upon the number of hours in each month the PV generation is estimated to occur during each period. The PV meter outflow is allocated to the various time-differentiated periods according to the allocation factors below and will be prorated for billing periods which cover more than one month. Month Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec On Peak 13.6% 29.9% Mid Peak 86.4% 70.1% 100% 100% 97.8% 51.5% 51.7% 54.4% 100% 100% 100% 84.2% Off Peak

44.3% 45.8% 45.6%

2.2% 4.2% 2.5%

15.8%

At the end of the year, or annualized over the period that service is supplied under this provision, the value of any credit remaining on a customer's account for excess electricity produced by the customer-generator shall be paid to the customer at the Corporation's avoided cost for energy. Payment will occur in the form of a voucher which will be issued to the customer-generator, for use in offsetting any of the issuing utility's bills directed to that customer during the year following the date of the voucher.

Issued in compliance with Order in Case 04-E-0917 dated 12/15/04.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric and Gas Corporation Initial Effective Date: February 5, 2009 Effective date postponed to 02/27/09. See Supplement No. 13.

Leaf No. 304 Revision: 5 Superseding Revision: 4

SERVICE CLASSIFICATION NO. 12 (Continued) (h) Farm Waste Electric Generating System Option: This option is for a customer qualifying for the Farm Waste Electric Generating System Option pursuant to General Information Section 22 of this Schedule and taking service under SC 12. For customers billed on time-differentiated rates, if the electricity (kWh) supplied by the customer to the Corporation is not metered for the time-differentiated periods, an allocation to each TOU period will be done according to allocation factors as set forth below: Winter and summer – December, January, February, June, July, August: 24 % [for On-Peak] 45% [for Mid-Peak] 31% [for Off-Peak] Off-Season – March, April, May, September, October, November: 67% [for Mid-Peak] 33% [for Off-Peak]

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: February 26, 2010

Leaf No. 304.1 Revision: 3 Superseding Revision: 2

SERVICE CLASSIFICATION NO. 12 (Continued) (i) Wind Electric Service Option:

This option is for a customer qualifying for the Wind Electric Service Option pursuant to General Information Section 23 of this Schedule and taking service under SC 12. For customers billed on timedifferentiated rates, if the electricity (kWh) supplied by the customer to the Corporation is not metered for the time-differentiated periods, an allocation to each TOU period will be done according to allocation factors as set forth below: Winter and summer – December, January, February, June, July, August: 24 % [for On-Peak] 45% [for Mid-Peak] 31% [for Off-Peak] Off-Season – March, April, May, September, October, November: 67% [for Mid-Peak] 33% [for Off-Peak] (j) Electric Hybrid Generating System Option: This option is for a customer qualifying for the Electric Hybrid Generating System Option pursuant to General Information Section 24 of this Schedule and taking service under SC 12. (k) Micro-combined Heat and Power (MCHP) Service Option: This option is for a customer qualifying for the MCHP Service Option pursuant to General Information Section 29 of this Schedule and taking service under SC 12. (l) Fuel Cell Residential Electric Service Option: This option is for a customer qualifying for the Fuel Cell Service Option pursuant to General Information Section 30 of this Schedule and taking service under SC 12.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: July 1, 2009

Leaf No. 304.2 Revision: 1 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 12 (Continued)

Reserved for future use.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: August 29, 2005 Effective date postponed to 09/29/2005. See Supplement No. 1. SERVICE CLASSIFICATION NO. 13 APPLICABLE TO THE USE OF SERVICE FOR:

Leaf No. 305 Revision: 1 Superseding Revision: 0

Electric service to retain an existing non-residential customer, including commercial, industrial or public authority, that can demonstrate a viable competitive alternative, and that: (1) is currently taking service or would meet the eligibility requirements as a secondary, primary, sub-transmission, or transmission customer under Service Classification No. 2, 3 or 7; (2) with regard to an industrial customer, the final cost of whose product includes at least 4% in electricity costs, demonstrated in the documented needs analysis for non-standard tariff electric rates as detailed in this service classification, or which has an annual high billing demand of 1,000 kilowatts or greater; (3) is a non-retail commercial business customer with an annual high billing demand of 3,000 kilowatts or greater; or (4) is a retail commercial or public authority customer with an annual high billing demand of 5,000 kilowatts or greater. CHARACTER OF SERVICE: Continuous - Alternating Current, 60 Cycle; Secondary Service at 120, 120/208, 120/240, 208, 240, 240/416, 277/480, or 480 Volts; or Primary (Distribution) Service at 2,400, 4,160, 4800, 7,200, 8,320, 12,000, 12,470, 13,200, or 34,500 (Regulated)* Volts; or Subtransmission Service at 34,500 or 46,000 (Both Non-Regulated) Volts; and 34,500 (Regulated) Volts for "Grandfathered Customers" only*; or Transmission Service at 115,000 Volts and above (Non-Regulated*). Single or Three Phase. (Characteristics depend upon available circuits and equipment.) *Effective February 15, 2000. INDIVIDUAL ELECTRIC SERVICE AGREEMENT: Determination as to whether or not the Corporation will enter into an Individual Electric Service Agreement will be based on an assessme nt of the need to retain or expand a Customer’s load and the demonstration of economic benefits to non-participating customers. Upon 30 days notice to the Corporation, and upon acceptance of the application by the Corporation, a Customer may qualify for an Individual Electric Service Agreement pursuant to this Service Classification. The Individual Electric Service Agreement shall contain and specify all terms and conditions necessary for the Corporation to provide service to the Customer, including but not limited to: (A) The term of service. (B) The characteristics of service in addition to Character of Service listed above. (C) A listing of the rates and charges to be paid for services rendered.

Issued in compliance with order in Case 03-E-1761 dated 04/14/05.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: August 29, 2005 Effective date postponed to 09/29/2005. See Supplement No. 1.

Leaf No. 306 Revision: 1 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 13 (Continued) INDIVIDUAL ELECTRIC SERVICE AGREEMENT: (Cont'd) (D) A statement that the Customer has met all of the requirements of this tariff including the following requirements: (1) If relocation is Customer's Competitive Viable Alternative: (a) Customer must provide historic financial documentation as the basis for future financial projections presented for the period for which an Individual Electric Service Agreement is being requested. The historic financial data and the financial projections should support the need for rate relief to operate in a manner consistent with past practices within the service territory of the Corporation. (b) Customer must submit a strategic operating plan for the Customer to continue to operate in a manner consistent with past practices at the existing facility, or to expand at the existing facility within the Corporation's service territory. b.1. The plan shall include an appropriate showing to the Corporation of the favorable economics and the viability of alternative electricity options. In so doing, the plan shall include an assessment of competitive factors including cost factors within the Customer's market.

Issued in compliance with order in Case 03-E-1761 dated 04/14/05.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: August 29, 2005 Effective date postponed to 09/29/2005. See Supplement No. 1.

Leaf No. 307 Revision: 1 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 13 (Continued) INDIVIDUAL ELECTRIC SERVICE AGREEMENT: (Cont'd) (D) A statement that the Customer has met all of the requirements of this tariff including the following requirements: (1) If relocation is Customer's competitive viable alternative (b)(1): (Cont'd) b.1. These cost factors may include, but are not limited to, the following: b.1.a. Costs of shipping raw materials (industrial), or service resources (public authorities) to the production site. b.1.b. Costs of shipping product to the Customer delivery points. b.1.c. Material costs. b.1.d. Property and other applicable local and state taxes. b.1.e. Employee costs. b.1.f. Electricity costs. b.1.g. The potential cost to the Customer of complying with environmental regulations sufficient to meet minimum environmental permitting requirements. b.1.h. Other energy costs. b.2. The Customer agrees to evaluate and assess in good faith the implementation of energy efficiency improvements in the Customer's facility. This assessment may be accomplished through recommendations from a comprehensive production analysis or energy audit performed for the facility.

Issued in compliance with order in Case 03-E-1761 dated 04/14/05.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: August 29, 2005 Effective date postponed to 09/29/2005. See Supplement No. 1.

Leaf No. 308 Revision: 1 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 13 (Continued) INDIVIDUAL ELECTRIC SERVICE AGREEMENT: (Cont'd) (D) A statement that the customer has met all of the requirements of this tariff including the following requirements: (Cont'd) (2) If Self Generation or Co-Generation is the Customer's competitive viable alternative: (a) Customer must submit a strategic operating plan. a.1. The plan shall provide an appropriate justification to the Corporation of the favorable economics and the viability of the self-generation or co-generation alternative. This plan shall include, but not be limited to, the following: If on-site generation exists: A description of existing thermal and electric generation equipment, including all thermal and electric loads; ii. A description of the electric generating equipment, including size, annual and hourly electric output, and annual and hourly fuel consumption and costs; iii. A listing of annual non-fuel operating expenses for the energy facility, including, but not limited to, operating labor, maintenance, consumables, and O&M contract services; iv. A detail of other costs for energy facility, including, but not limited to, labor overheads, taxes, insurance, capital improvements, permit fees, and financing on existing equipment; and v. A description of areas of concern or difficulty which are adversely impacting current operations of the energy facility. i.

a.1.a.

a.1.b. If on-site generation is being favorably considered: i. A description of the proposed self generation/co-generation facility, including the facility’s electric output, heat rate, and fuel consumption; ii. A breakdown of the estimated cost of the proposed facility; iii. A description of the intended operation of the proposed facility; iv. A detail of non-fuel operating costs, including, but not limited to, operating labor, general maintenance, overhaul maintenance, consumables and O&M contract services; v. A projection of annual electricity requirements and costs for Standby Service; vi. vii. a.1.c. A description of the environmental impacts of the proposed facility; and A Projected Cash Flow Analysis, detailing the financial data for the project life. The Customer agrees to evaluate and assess in good faith the implementation of energy efficiency improvements in the Customer’s facility. This assessment may be accomplished through recommendations from a comprehensive production analysis or energy audit performed for the facility.

Issued in compliance with order in Case 03-E-1761 dated 04/14/05.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: August 29, 2005 Effective date postponed to 09/29/2005. See Supplement No. 1.

Leaf No. 309 Revision: 1 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 13 (Continued) INDIVIDUAL ELECTRIC SERVICE AGREEMENT: (Cont'd) (E) The documentation, including the historic and projected financial information, will demonstrate, in a form acceptable to the Corporation, the competitive alternatives and the pricing objective needed to retain the Customer. The pricing objective shall specify the relief from the otherwise applicable standard tariff rate that is necessary to retain the Customer’s load, recognizing contributions towards achieving that objective from other economic development entities. (F) The documentation shall also demonstrate the customer’s participation in, or efforts to participate in, available State and/or local economic development programs as reviewed and attested to by the appropriate agency(ies) and Economic Development staff employed by the Corporation. To that end, the Corporation will coordinate a comprehensive program of development initiatives that are available and applicable from the private and/or public sector(s). Each Individual Electric Service Agreement will identify billing procedures provided under the economic development tariff, contract, and programs (including NYPA economic development programs), as appropriate. (-G) The strategic operating plan must be accompanied by a sworn affidavit of the senior manager or officer at the Customer's facility, representing that the information submitted is true and that absent the Individual Electric Service Agreement, the Customer could no longer continue to operate its existing facility in a manner consis tent with recent historical practices in the Corporation's service territory. The affidavit submitted by the Customer shall also include a commitment to continue to assess in good faith the resulting recommendations from any comprehensive production analysis and energy audit for inclusion in the Customer's facility, throughout the term of the Individual Electric Service Agreement. Terms and conditions of service included in each Individual Electric Service Agreement required for service hereunder will be established in a manner which does not unduly discriminate between similarly situated customers. Each Individual Electric Service Agreement will be jointly filed with the Public Service Commission (“PSC) by the Corporation and the Customer pursuant to Commission Order Approving Guidelines For Flexible Rate Service Contracts, issued and effective April 14, 2005 in PSC Case 03-E-1761 (the “April 2005 Order”). The filing and any subsequent information requested by the Public Service Commission or its Staff regarding the Individual Electric Service Agreement will be subject to full confidentiality protection as a trade secret. A quarterly report will be filed with the PSC pursuant to the April 2005 Order. The report will be subject to full confidentiality protection as a trade secret.

Issued in compliance with order in Case 03-E-1761 dated 04/14/05.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: August 29, 2005 Effective date postponed to 09/29/2005. See Supplement No. 1.

Leaf No. 309.1 Revision: 0 Superseding Revision:

SERVICE CLASSIFICATION NO. 13 (Continued) INDIVIDUAL ELECTRIC SERVICE AGREEMENT: (Cont'd) RATES: The specific charges for service under this Service Classification will be stated in the Individual Electric Service Agreement executed for each Customer served hereunder. DELIVERY RATE: The rate contained in an Individual Electric Service Agreement will, at a minimum, recover the Corporation's marginal costs plus a contribution toward system costs (“Marginal Cost Floor”). The Marginal Cost Floor is defined as: MCtrans + MCdist + MCancillary + NTAC + contribution toward system costs Where: MCtrans MCdist MCancillary is the Corporation’s FERC-approved Transmission Service Charge is the Corporation’s marginal distribution costs is the Corporation’s system load weighted average of the NYISO ancillary services charges for Schedules 1 (fixed and variable), 2, 3, 5, and 6, is the NYPA Transmission Access Charge

NTAC

Unless an updated marginal cost study is attached to the Individual Electric Service Agreement, the marginal costs that were approved by the PSC for use in the development of the Corporation’s Economic Development Zone Incentive (“EDZI”) rates will be used for determining the Marginal Cost Floor.

Issued in compliance with order in Case 03-E-1761 dated 04/14/05.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: August 29, 2005 Effective date postponed to 09/29/2005. See Supplement No. 1.

Leaf No. 309.2 Revision: 1 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 13 (Continued) INDIVIDUAL ELECTRIC SERVICE AGREEMENT: (Cont'd) RATES: (Cont’d) COMMODITY RATE: Customer Options: • The Corporation may provide electric commodity service at the rate for commodity available in the otherwise applicable Service Classification, as amended or superseded; or • The Corporation will facilitate a Customer’s access to market commodity options available from ESCOs by offering the Customer assistance with linking the Customer with an ESCO that will offer, at a minimum, fixed price commodity for a period of at least six months. If the Customer’s pricing objective, as demonstrated by the Customer, cannot be met by a combination of the above delivery and commodity offerings and other economic development offers, the Corporation will evaluate innovative solutions and pursue alternatives in an effort to achieve the Customer’s pricing objective, provided that if the Corporation is the provider of the commodity, then the Corporation shall not be required to supply that commodity below cost, the commodity shall not be drawn from the Corporation’s existing supply portfolio, and the pursuit of commodity service shall not result in an economic detriment to other customers.

Issued in compliance with order in Case 03-E-1761 dated 04/14/05.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: July 1, 2009

Leaf No. 310 Revision: 17 Superseding Revision: 16

SERVICE CLASSIFICATION NO. 13 (Continued) SERVICE AGREEMENT: (Cont'd) SURCHARGE TO COLLECT SYSTEM BENEFITS CHARGE ("SBC"): A System Benefits Charge (as explained in this Schedule, General Information Section 4) will be added to each customer bill, as set forth in, and as permitted by, the individual Service Agreement, under this Service Classification. See SBC Statement. RENEWABLE PORTFOLIO STANDARD CHARGE (“RPS”): A surcharge will be added to each customer bill for service under this Service Classification to collect the Renewable Portfolio Standard (as explained in this Schedule, General Information Section 5). See RPS Statement. SURCHARGE TO COLLECT TEMPORARY STATE ASSESSMENT (“TSAS”): A surcharge will be added to each customer bill for service under this Service Classification to collect the Temporary State Assessment (as explained in this Schedule, General Information Section 28). See TSAS Statement. INCREASE IN RATES AND CHARGES: The rates and charges under this service classification will be increased by a surcharge pursuant to Section 6 of P.S.C. No. 120 to reflect the tax rates applicable within the municipality where the customer takes service. COMPETITIVE METERING OPTION: For Service Agreements negotiated after March 1, 2001, NYSEG will not require as a condition of contract, that a customer obtain its electric metering services from NYSEG. A customer whose Service Agreement allows and who otherwise qualifies for NYSEG's Competitive Metering Option pursuant to General Information Section 14 of this Schedule, will receive a Competitive Metering Credit consistent with their otherwise applicable Service Classification. TERMS OF PAYMENT: All bills are rendered at the above rates and that amount is due on bills paid on or before the past due date indicated on the bill. A late payment charge at the rate per month specified in the Service Agreement will be billed on all amounts not paid by that date.

Issued in compliance with order in Case No. 09-M-0311 dated 6/19/09.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: December 1, 2005

Leaf No. 311 Revision: 3 Superseding Revision: 2

SERVICE CLASSIFICATION NO. 13 (Continued) INDIVIDUAL ELECTRIC SERVICE AGREEMENT (Cont'd.) TERM: The term of delivery service shall be limited to no more than five years, unless a longer term is approved by the PSC. Prospective adjustments to delivery service rates may be negotiated by the Corporation and the Customer, as defined within the Individual Electric Service Agreement. The term of standard Corporation-offered commodity service supplied by the Corporation shall be reflected in the Individual Electric Service Agreement and shall remain in effect for the time periods established in the otherwise applicable Service Classification. Other commodity options may provide for prospective price changes and term limitations, as defined within the Individual Electric Service Agreement. If a Customer terminates or breaches an Individual Electric Service Agreement with the Corporation prior to the expiration of the term in which the price for a non-tariffed commodity option was to remain in effect, the Customer shall be responsible for compensating the Corporation for any obligations the Corporation has, or any damages the Corporation incurs, to a commodity supplier or provider of a financial hedge relating to that price. SPECIAL PROVISIONS (a) C.A.$.H.BACK SPECIAL PROVISION The Corporation will provide a voluntary program for load normally supplied and delivered by NYSEG, for eligible customers to curtail load. The Corporation’s program, entitled C.A.$.H.BACK, implements the NYISO's day-ahead economic load-curtailment program. Under this program, a customer agrees to curtail load when their bid is submitted and accepted by the NYISO. Customers who are qualified under C.A.$.H.BACK in Section 21 of the General Information section of this Schedule may participate in the Corporation’s C.A.$.H.BACK Program as set forth therein. (b) Previous SC 13 Tariff This provision is applicable to Individual Electric Service Agreements in effect prior to September 29, 2005.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: August 29, 2005 Effective date postponed to 09/29/2005. See Supplement No. 1. SERVICE CLASSIFICATION NO. 13 SPECIAL PROVISIONS (Cont.) (b) Previous SC 13 Tariff SERVICE AGREEMENT:

Leaf No. 311.1 Revision: 0 Superseding Revision:

Upon 30 days notice to the Corporation, and upon acceptance of the application by the Corporation, a customer may qualify for an individual Service Agreement pursuant to this service classification. The Service Agreement shall contain and specify all terms and conditions necessary for the Corporation to provide service to the customer, including but not limited to: (A) The term of service. (B) The characteristics of service in addition to Character of Service listed above. (C) A listing of the rates and charges to be paid for services rendered. (D) A statement that the customer has met all of the requirements of this tariff including the following requirements: (1) If relocation is Customer's Competitive Viable Alternative: (a) Customer must provide future projections for the period for which this tariff is being requested, presented in a form as defined by the American Institute of Certified Public Accountants (AICPA). The financial projections must be examined and reported upon by the customer's independent certified public accountants, indicating the projections to be in accordance with standards for the examination of financial projections established by the AICPA, and consis tent with past practices and results. The required projections must support the need for rate relief to operate in a manner consistent with past practices within the service territory of New York State Electric & Gas Corporation. The customer through their independent certified public accountants will provide upon request to Coopers & Lybrand, or another CPA as determined by the Corporation, for review, work papers and supporting documentation. All information provided by the customer to the Company, whether printed, written or verbal, in compliance with this service classification, shall be held in confidence and used only for the purpose of business transacted between the Company and the Customer. Without limiting the foregoing, information furnished by the Customer and required to be submitted to the New York State Public Service Commission shall not be submitted without a request by NYSEG that such information shall be given trade secret protection in accordance with 16 NYCRR, 6-1.3. When any such information is required to be submitted to the NYS P.S.C., NYSEG will notify the customer of such request prior to its submittal.
Issued in compliance with order in Case 03-E-1761 dated 04/14/05.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: August 29, 2005 Effective date postponed to 09/29/2005. See Supplement No. 1. SERVICE CLASSIFICATION NO. 13 SPECIAL PROVISIONS (Cont’d) (b) Previous SC 13 Tariff (Cont’d) SERVICE AGREEMENT: (Cont’d)

Leaf No. 311.2 Revision: 0 Superseding Revision:

(D) A statement that the customer has met all of the requirements of this tariff including the following requirements: (Cont’d) (1) If relocation is Customer's Competitive Viable Alternative: (Cont’d) (b) Customer must submit a strategic operating plan for the customer to continue to operate in a manner consistent with past practices at the existing facility, or to develop a new or existing facility within the Corporation's service territory. b.1. The plan shall include an appropriate showing to the Corporation of the favorable economics and the viability of alternative power options. In so doing, the plan shall include an assessment of competitive factors including cost factors within the customer's market. These cost factors may include, but are not limited to, the following: b.1.a. b.1.b. b.1.c. b.1.d. b.1.e. b.1.f. b.1.g. b.1.h. b.2. Costs of shipping raw materials (industrial), or service resources (public authorities) to the production site. Costs of shipping product to the customer delivery points. Material costs. Property and other applicable local and state taxes. Employee costs. Employee costs The potential cost to the customer of complying with environmental regulations sufficient to meet minimum environmental permitting requirements. Other energy costs.

The plan shall also include the results of a comprehensive production analysis and energy audit, including, but not limited to: b.2.a. Process usage. b.2.b. Lighting and HVAC requirements as presented by independent consultants, licensed in New York State as Professional Engineers, or as otherwise acceptable to the Corporation.

b.3. The customer agrees to assess in good faith the resulting recommendations from the comprehensive production analysis and energy audit for inclusion in the customer's facility.

Issued in compliance with order in Case 03-E-1761 dated 04/14/05.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: August 29, 2005 Effective date postponed to 09/29/2005. See Supplement No. 1.

Leaf No. 311.3 Revision: 0 Superseding Revision:

SERVICE CLASSIFICATION NO. 13 (Continued) SPECIAL PROVISIONS (Cont’d) (b) Previous SC 13 Tariff (Cont’d) SERVICE AGREEMENT: (Cont'd) (D) A statement that the customer has met all of the requirements of this tariff including the following requirements: (Cont'd) (2) If Self Generation or Co-Generation is the Customer's Competitive Viable Alternative: (a) Customer must submit a strategic operating plan. a.1. The plan shall provide an appropriate justification to the Corporation of the favorable economics and the viability of the self-generation or co-generation alternative. This plan shall include, but not be limited to, the following: If on-site generation exists: A description of existing thermal and electric generation equipment, including all thermal and electric loads; A description of the electric generating equipment, including size, annual and hourly fuel consumption and costs. Line pressure of fuel, if natural gas, to site shall also be included; A listing of annual non-fuel operating expenses for the energy facility,including, but not limited to, operating labor, maintenance, consumables, and O&M contract services; A detail of other costs for energy facility, including, but not limited to, labor overheads, taxes, insurance, capital improvements, permit fees, and financing on existing equipment; A description of areas of concern or difficulty which are adversely impacting current operations of the energy facility.

a.1.a. i. ii.

iii. iv. v.

a.1.b. If on-site generation is being favorably considered: i. A description of the proposed self generation/co-generation facility, including fuel consumption; ii. A breakdown of the estimated cost of the proposed facility; iii. A description of the intended operation of the proposed facility; iv. A detail of non-fuel operating costs, including, but not limited to, operating labor, general maintenance, overhaul maintenance, consumables and O&M contract services; v. A projection of annual electricity requirements and costs for supplemental, back-up, and maintenance service; vi. A description of performance effects on ambient temperature, and annual capacity/efficient degradation from recoverable and non-recoverable losses; vii. A description of the environmental impacts of the proposed facility; viii. A Projected Cash Flow Analysis, detailing the financial data for the project life. a.1.c. The plan shall also include an energy audit whether the customer is considering, or has already installed, self-or co-generation facilities.

Issued in compliance with order in Case 03-E-1761 dated 04/14/05.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: August 29, 2005 Effective date postponed to 09/29/2005. See Supplement No. 1.

Leaf No. 311.4 Revision: 0 Superseding Revision:

SERVICE CLASSIFICATION NO. 13 (Continued) SPECIAL PROVISIONS (Cont’d) (b) Previous SC 13 Tariff (Cont’d) SERVICE AGREEMENT: (Cont'd) (E) The overall plan must be accompanied by a sworn affidavit of the senior manager or officer at the customer's facility, representing that the information submitted is true and that absent the Service Agreement, the customer could no longer continue to operate its existing facility in a manner consis tent with recent historical practices or to commence operations of a facility in the Corporation's service territory. The affidavit submitted by the customer shall also include a commitment to continue to assess in good faith the resulting recommendations from the comprehensive production analysis and energy audit for inclusion in the customer's facility, throughout the term of the agreement. (F) For Service Agreements negotiated after August 1, 1998, NYSEG will not require as a condition of contract, that a customer purchase its Electric Power Supply from the Corporation. An Eligible Customer whose Service Agreement allows and who otherwise qualifies for General Retail Access pursuant to NYSEG's General Information Section 16 of this Schedule may elect to purchase Electric Power Supply from an ESCO. Terms and conditions of service included in each Service Agreement required for service hereunder will be established in a manner which does not unduly discriminate between similarly situated customers. The first negotiated Service Agreement between the Corporation and Customer will be submitted to the Public Service Commission Staff for review. For the initial and subsequent contracts, a summary of each Service Agreement in effect shall be included on a listing appended to this tariff rate schedule, Service Classification No. 13, pursuant to Commission Order Concerning Tariffs Authorizing Individually Negotiated Contracts, issued and effective May 8, 1992 in PSC Case 91-M-0927. RATE: The specific charges for service under this service classification will be stated in the negotiated Service Agreement executed for each customer served hereunder. A summary of the Rates and Charges will be filed with the Public Service Commission, as required, as an addendum to this schedule. The rate contained in any Service Agreement will, at a minimum, recover the Corporation's marginal cost plus at least 1 cent per kWh ("Marginal Cost Floor"). Such recovery under each Service Agreement will be calculated by using a rolling 12-month methodology. As part of calculating a customer's monthly bill, the Corporation will compare the customer's previous 12-month contracted Service Agreement billed amount to the previous 12-month Marginal Cost Floor amount for the applicable contracted electric usage during that 12-month period. When the contracted Service Agreement billed amount is less than the Marginal Cost Floor amount for that same period, the Corporation will adjust the customer's current bill to recover that deficiency.

Issued in compliance with order in Case 03-E-1761 da ted 04/14/05.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2007

Leaf No. 311.5 Revision: 1 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 13 (Continued) SPECIAL PROVISIONS (Cont’d) (b) Previous SC 13 Tariff (Cont’d) SERVICE AGREEMENT (Cont'd.) TERM: The term of service shall be limited to no more than three years, but may include provision for renegotiation when additional guidelines are established by the Public Service Commission. If the following three conditions are met to the satisfaction of the Corporation: a) b) c) adequate competitive justification is demonstrated by the customer; adequate guarantee of availability of cost effective supply is documented by the Corporation; and the longer term would provide additional net benefits to non-participating customers;

the term of service may be up to seven years, and may contain appropriate reopener conditions.

(c) Customer Charge - Individual Service Agreements Effective Prior to January 1, 2007: If an Individual Service Agreement that became effective prior to January 1, 2007 refers to the Customer Charge contained within Service Classification Nos. 2, 3 or 7, such Customer Charge shall be defined as including the Meter Ownership, Meter Service, Meter Data Service and Bill Issuance Charges, in addition to the Customer Charge, as set forth in the referenced Service Classification Nos. 2, 3 or 7. This definition is necessitated by the Company’s unbundling of the Meter Ownership, Meter Service, Meter Data Service and Bill Issuance Charges from the Customer Charge, effective January 1, 2007.

Issued in compliance with order in Case No. 05-E-1222 dated 08/23/06.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: August 29, 2005 Effective date postponed to 09/29/2005. See Supplement No. 1. SERVICE CLASSIFICATION NO. 14 APPLICABLE TO THE USE OF SERVICE FOR:

Leaf No. 312 Revision: 1 Superseding Revision: 0

Electric service to a new or existing non-residential customer that can demonstrate a competitive viable alternative. A. New Customer: 1. That develops or constructs new facilities, or extensively refurbishes an existing or mothballed facility and has electric equipment with a total connected demand of at least 300 kilowatts, except at least 250 kilowatts in areas served by the Corporation where distribution facilities are "underutilized" (as determined solely by the Corporation). - OR 2. Certain industrial customers that participate in the Alfred University Incubator Facilities program as described in Section 26 of Chapter 839 of the Laws of 1987 (New York), and "graduate" therefrom, and locate within the developing "Ceramics Corridor" envisioned by the legislation to promote new and emerging technology enterprises in conjunction with the University and the region's industry and local government which are certified as eligible by Alfred Technology Resources Incorporated, and accepted by the Corporation.

Issued in compliance with order in Case 03-E-1761 dated 04/14/05.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: August 29, 2005 Effective date postponed to 09/29/2005. See Supplement No. 1.

Leaf No. 313 Revision: 1 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 14 (Continued) APPLICABLE TO THE USE OF SERVICE FOR: (Cont'd) B. Existing Customer: 1. That expands its use of electric equipment at its existing facility, requiring: (a) the installation of additional electric equipment with a total connected demand of at least 300 kilowatts, except at least 250 kilowatts in areas served by the Corporation where distribution facilities are "underutilized" (as determined solely by the Corporation). -OR(b) the increased use of existing electric equipment by scheduling, staffing and operating an additional shift, that has not been operated, as such, for at least 1 year utilizing equipment with a total connected demand of at least 300 kilowatts, except at least 250 kilowatts in areas served by the Corporation where distribution facilities are "underutilized" (as determined solely by the Corporation).

2.

Which has already installed and operates on site self or co-generation facilities; Customer must submit the following documentation: a. A description of existing thermal and electric generation equipment, including all thermal and electric loads; A description of the electric generating equipment, including size, annual and hourly fuel consump tion and costs. Line pressure of fuel, if natural gas, to site shall also be included; A listing of annual non-fuel operating expenses for the energy facility, including, but not limited to, operating labor, maintenance, consumables, and O&M contract services; A detail of other costs for energy facility, including, but not limited to, labor overheads, taxes, insurance, capital improvements, permit fees, and financing on existing equipment; A description of areas of concern or difficulty which are adversely impacting current operations of the energy facility.

b.

c.

d.

e.

Issued in compliance with order in Case 03-E-1761 dated 04/14/05.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: August 29, 2005 Effective date postponed to 09/29/2005. See Supplement No. 1.

Leaf No. 314 Revision: 1 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 14 (Continued) APPLICABLE TO THE USE OF SERVICE FOR: (Cont'd)

CHARACTER OF SERVICE: Continuous - Alternating Current, 60 Cycle; Secondary Service at 120, 120/208, 120/240, 208, 240, 240/416, 277/480, or 480 Volts; or Primary (Distribution) Service at 2,400, 4,160, 4800, 7,200, 8,320, 12,000, 12,470, 13,200, or 34,500 (Regulated)* Volts; or Subtransmission Service at 34,500 or 46,000 (Both Non-Regulated) Volts; and 34,500 (Regulated) Volts for "Grandfathered Customers" only*; or Transmission Service at 115,000 Volts and above (Non-Regulated*). Single or Three Phase. (Characteristics depend upon available circuits and equipment.) *Effective February 15, 2000.

Issued in compliance with order in Case 03-E-1761 dated 04/14/05.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: August 29, 2005 Effective date postponed to 09/29/2005. See Supplement No. 1.

Leaf No. 315 Revision: 1 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 14 (Continued)

INDIVIDUAL ELECTRIC SERVICE AGREEMENT: Determination as to whether or not the Corporation will enter into an Individual Electric Service Agreement will be based on an assessment of the need to attract a Customer’s load or expand the Customer’s usage and the demonstration of economic benefits to non-participating customers. Upon 30 days notice to the Corporation, and upon acceptance of the application by the Corporation, such a Customer's eligible load may qualify for an Individual Electric Service Agreement, pursuant to this Service Classification. The Individual Electric Service Agreement will be negotiated to avoid undue dis crimination between similarly situated customers. The Individual Electric Service Agreement shall contain and specify all terms and conditions necessary for the Corporation to provide such service to the Customer, including but not limited to: (A) The term of service. (B) The characteristics of service in addition to Character of Service listed above. (C) A listing of the rates and charges to be paid for services rendered. (D) A statement that the Customer has met all of the requirements of this tariff, including the following: (1) Customer must provide documentation as to its eligibility under “Applicable to the Use of Service For,” Sections A and B of this tariff. Customer must also demonstrate proof of the existence of a competitive viable alternative, and its planned procedure to disregard same.

Issued in compliance with order in Case 03-E-1761 dated 04/14/05.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: August 29, 2005 Effective date postponed to 09/29/2005. See Supplement No. 1.

Leaf No. 316 Revision: 1 Superseding Revision: 0

SERVICE CLASSIFICATION NO. 14 (Continued) SERVICE AGREEMENT: (Cont'd) (D) (Cont'd.) (2) The Customer agrees to evaluate and assess in good faith the implementation of energy efficiency improvements in the Customer's facility. This assessment may be accomplished through recommendations from a comprehensive production analysis or energy audit performed for the facility. (E) The Customer will provide, in a form acceptable to the Corporation, its pricing objective needed to attract the Customer or expand its usage. The pricing objective shall specify the relief from the otherwise applicable standard tariff rate that is necessary to attract the Customer or expand the Customer’s load, recognizing contributions towards achieving that objective from other economic development entities.

(F) The documentation shall demonstrate the Customer's participation in, or efforts to participate in, available State and/or local economic development programs as reviewed and attested to by the appropriate agency(ies) and Economic Development staffemployed by the Corporation. To that end, the Corporation will coordinate a comprehensive program of development initiatives that are available and applicable from the private and/or public sector(s). Each Individual Electric Service Agreement will identify billing procedures provided under the economic development tariff, contract, and programs (including NYPA economic development programs), as appropriate. (G) The Individual Electric Service Agreement must be accompanied by a sworn affidavit of the senior manager or officer at the Customer's facility, representing that the information submitted is true and that absent the Individual Electric Service Agreement, the Customer would not have commenced taking or increased the use of electric service from the Corporation. The affidavit submitted by the Customer shall also include a commitment to continue to assess in good faith the resulting recommendations from any comprehensive production analysis and energy audit for inclusion in the Customer's facility, throughout the term of the Individual Electric Service Agreement. Each Individual Electric Service Agreement will be jointly filed with the Public Service Commission (“PSC”), by the Corporation and the Customer pursuant to the PSC’s Order Approving Guidelines For Flexible Rate Service Contracts, issued and effective April 14, 2005 in PSC Case 03-E-1761 (the “April 2005 Order”). The filing and any subsequent information requested by the PSC or its Staff regarding the Individual Electric Service Agreement will be subject to full confidentiality protection as a trade secret. A quarterly report will be filed with the PSC pursuant the April 2005 Order. The report will be subject to full confidentiality protection as a trade secret.

Issued in compliance with order in Case 03-E-1761 dated 04/14/05.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: August 29, 2005 Effective date postponed to 09/29/2005. See Supplement No. 1.

Leaf No. 317 Revision: 2 Superseding Revision: 1

SERVICE CLASSIFICATION NO. 14 (Continued) RATE: The specific charges for service under this Service Classification will be stated in the Individual Electric Service Agreement executed for each Customer served hereunder. DELIVERY RATE: The rate contained in an Individual Electric Service Agreement will, at a minimum, recover the Corporation's marginal costs plus a contribution toward system costs ("Marginal Cost Floor"). The Marginal Cost Floor is defined as: MCtrans + MCdist + MCancillary + NTAC + contribution toward system costs Where: MCtrans MCdist is the Corporation’s FERC-approved Transmission Service Charge is the Corporation’s marginal distribution costs

MCancillary is the Corporation’s system load weighted average of the NYISO ancillary services charges for Schedules 1 (fixed and variable), 2, 3, 5, and 6, NTAC is the NYPA Transmission Access Charge

Unless an updated marginal cost study is attached to the Individual Electric Service Agreement, the marginal costs that are approved by the PSC for use in the development of the Corporation’s Economic Development Zone Incentive (“EDZI”) rates will be used for determining the Marginal Cost Floor. COMMODITY RATE: Customer Options: • The Corporation may provide electric commodity service at the rate for commodity available in the otherwise applicable Service Classification, as amended or superseded; or • The Corporation will facilitate a Customer’s access to market commodity options available from ESCOs by offering the Customer assistance with linking the Customer with an ESCO that will offer, at a minimum, fixed price commodity for a period of at least six months. If the Customer’s pricing objective, as demonstrated by the Customer, cannot be met by a combination of the above delivery and commodity offerings and other economic development offers, the Corporation will evaluate innovative solutions and pursue alternatives in an effort to achieve the Customer’s pricing objective, provided that if the Corporation is the provider of the commodity, then the Corporation shall not be required to supply that commodity below cost, the commodity shall not be drawn from the Corporation’s existing supply portfolio, and the pursuit of commodity service shall not result in an economic detriment to other customers.
Issued in compliance with order in Case 03-E-1761 dated 04/14/05.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: July 1, 2009

Leaf No. 318 Revision: 18 Superseding Revision: 17

SERVICE CLASSIFICATION NO. 14 (Continued) SURCHARGE TO COLLECT SYSTEM BENEFITS CHARGE ("SBC"): A System Benefits Charge (as explained in this Schedule, General Information Section 4) will be added to each customer bill, as set forth in, and as permitted by, the individual Service Agreement, under this Service Classification. See SBC Statement. RENEWABLE PORTFOLIO STANDARD CHARGE (“RPS”): A surcharge will be added to each customer bill for service under this Service Classification to collect the Renewable Portfolio Standard (as explained in this Schedule, General Information Section 5). See RPS Statement. SURCHARGE TO COLLECT TEMPORARY STATE ASSESSMENT (“TSAS”): A surcharge will be added to each customer bill for service under this Service Classification to collect the Temporary State Assessment (as explained in this Schedule, General Information Section 28). See TSAS Statement. COMPETITIVE METERING OPTION: For Service Agreements negotiated after March 1, 2001, NYSEG will not require as a condition of contract, that a customer obtain its electric metering services from NYSEG. A customer whose Service Agreement allows and who otherwise qualifies for NYSEG's Competitive Metering Option pursuant to General Information Section 14 of this Schedule, will receive a Competitive Metering Credit consistent with their otherwise applicable Service Classification. INCREASE IN RATES AND CHARGES: The rates and charges under this service classification will be increased by a surcharge pursuant to Section 6 of P.S.C. No. 120 to reflect the tax rates applicable within the municipality where the customer takes service. TERMS OF PAYMENT: All bills are rendered at the above rates and that amount is due on bills paid on or before the past due date indicated on the bill. A late payment charge at the rate per month specified in the Service Agreement will be billed on all amounts not paid by that date. TERM: The term of delivery service shall be limited to no more than five years, unless a longer term is approved by the PSC. Prospective adjustments to delivery service may be negotiated by the Corporation and the Customer, as defined within the Individual Electric Service Agreement. The term of standard Corporation-offered commodity service supplied by the Corporation shall be reflected in the Individual Electric Service Agreement and shall remain in effect for the time periods established in the otherwise applicable Service Classification. Other commodity options may provide for prospective price changes and term limitations, as defined within the Individual Electric Service Agreement. If a Customer terminates or breaches an Individual Electric Service Agreement with the Corporation prior to the expiration of the term in which the price for a non-tariffed commodity option was to remain in effect, the Customer shall be responsible for compensating the Corporation for any obligations the Corporation has, or any damages the Corporation incurs, to a commodity supplier or provider of a financial hedge relating to that price.

Issued in compliance with order in Case No. 09-M-0311 dated 6/19/09.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: December 1, 2005

Leaf No. 319 Revision: 2 Superseding Revision: 1

SERVICE CLASSIFICATION NO. 14 (Continued) SPECIAL PROVISIONS: C.A.$.H.BACK The Corporation will provide a voluntary program for load normally supplied and delivered by the Corporation, for eligible customers to curtail load. The Corporation's program, entitled C.A.$.H.BACK, implements the NYISO's day-ahead economic load-curtailment program. Under this program, a Customer agrees to curtail load when their bid is submitted and accepted by the NYISO. Customers who are qualified under C.A.$.H.BACK in Section 21 of the General Information section of this Schedule may participate in the NYSEG C.A.$.H.BACK Program as set forth therein.

Emergency Demand Response Program ("EDRP"): The EDRP seeks to provide customers with an economic incentive to respond to E mergency Operating Conditions as identified by the NYISO. EDRP can provide the NYISO, through the Corporation, with the ability to request voluntary load curtailment or replacement by participating customers for electric usage. Customers who are qualified under EDRP in Section 20 of the General Information section of this Schedule may participate in the NYSEG EDRP as set forth therein unless the customer's contract specifically prohibits participation in the program. Previous SC 14 Tariff This provision is applicable to Individual Electric Service Agreements in effect prior to September 29, 2005. APPLICABLE TO THE USE OF SERVICE FOR: Electric service required to respond to non-residential customers' needs at a time when the electricity service markets become increasingly competitive. Through Individual Service Agreements signed under this tariff, the Corporation proposes to provide incentives and thus promote the location of new business ventures within the Corporation's territory, as well as promote the expansion of existing new or current non-residential customers. The customer shall assert via a sworn affidavit that it would not locate or expand in the Corporation's service territory, but for the combination of a comprehensive package of economic incentives or real property tax incentives and/or the award of an S.C. 14 contract. The corporation will make an independent verification of the customer's assertion. The potential cost to the customer of complying with environmental regulations sufficient to meet minimum environmental permitting requirements will be taken into consideration when determining whether a customer has a realistic competitive alternative.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: August 29, 2005 Effective date postponed to 09/29/2005. See Supplement No. 1.

Leaf No. 320 Revision: 0 Superseding Revision:

SERVICE CLASSIFICATION NO. 14 (Continued) SPECIAL PROVISIONS: Previous SC 14 Tariff (Cont’d) APPLICABLE TO THE USE OF SERVICE FOR: (Cont’d) The baseload (load not subject to reduced pricing under this service classification), of S.C. 14 customers will be eligible for the "Industrial/High Load Factor Rate" Provision as set forth in the otherwise applicable S.C. No. 2, 3 or 7, if such baseload meets those eligibility requirements. A. New Customer: 1. That develops or constructs new facilities, or extensively refurbishes an existing or mothballed facility and has electric equipment with a total connected demand of at least 300 kilowatts, except at least 250 kilowatts in areas served by the Corporation where distribution facilities are "underutilized" (as determined solely by the Corporation). - OR 2. Certain industrial customers that participate in the Alfred University Incubator Facilities program as described in Section 26 of Chapter 839 of the Laws of 1987 (New York), and "graduate" therefrom, and locate within the developing "Ceramics Corridor" envisioned by the legislation to promote new and emerging technology enterprises in conjunction with the University and the region's industry and local government which are certified as eligible by Alfred Technology Resources Incorporated, and accepted by the Corporation.

B.

Existing Customer: 1. That expands its use of electric equipment at its existing facility, requiring: (a) the installation of additional electric equipment with a total connected demand of at least 300 kilowatts, except at least 250 kilowatts in areas served by the Corporation where distribution facilities are "underutilized" (as determined solely by the Corporation). -OR(b) the increased use of existing electric equipment by scheduling, staffing and operating an additional shift, that has not been operated, as such, for at least 1 year utilizing equipment with a total connected demand of at least 300 kilowatts, except at least 250 kilowatts in areas served by the Corporation where distribution facilities are "underutilized" (as determined solely by the Corporation).

Issued in compliance with order in Case 03-E-1761 dated 04/14/05.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: August 29, 2005 Effective date postponed to 09/29/2005. See Supplement No. 1.

Leaf No. 321 Revision: 0 Superseding Revision:

SERVICE CLASSIFICATION NO. 14 (Continued) SPECIAL PROVISIONS: Previous SC 14 Tariff (Cont’d) APPLICABLE TO THE USE OF SERVICE FOR: (Cont’d) B. Existing Customer: (Cont’d) 2. Which has already installed and operates on site self or co-generation facilities; customer must submit the following documentation: a. A description of existing thermal and electric generation equipment, including all thermal and electric loads; A description of the electric generating equipment, including size, annual and hourly fuel consump tion and costs. Line pressure of fuel, if natural gas, to site shall also be included; A listing of annual non-fuel operating expenses for the energy facility, including, but not limited to, operating labor, maintenance, consumables, and O&M contract services; A detail of other costs for energy facility, including, but not limited to, labor overheads, taxes, insurance, capital improvements, permit fees, and financing on existing equipment; A description of areas of concern or difficulty which are adversely impacting current operations of the energy facility.

b.

c.

d.

e.

C.

The first negotiated Service Agreement between the Corporation and Customer will be submitted to the Public Service Commission for review. For the initial and subsequent contracts, a summary of each Service Agreement in effect shall be included on a listing appended to this tariff rate schedule, Service Classification No. 14, pursuant to Commission Order Concerning Tariffs Authorizing Individually Negotiated Contracts, issued and effective May 8, 1992 in PSC Case 91-M-0927. Customers, not meeting the above criteria, may be eligible for the Company's Economic Development Incentive as set forth in Section 8 of the General Information Section of this Schedule.

D.

Issued in compliance with order in Case 03-E-1761 dated 04/14/05.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: August 29, 2005 Effective date postponed to 09/29/2005. See Supplement No. 1.

Leaf No. 322 Revision: 0 Superseding Revision:

SERVICE CLASSIFICATION NO. 14 (Continued) SPECIAL PROVISIONS: Previous SC 14 Tariff (Cont’d) SERVICE AGREEMENT: Upon 30 days notice to the Corporation, and upon acceptance of the application by the Corporation, such a customer's eligible load m qualify for an individual Service Agreement, pursuant to this service classification. ay The Individual Service Agreement will be negotiated to avoid undue dis crimination between similarly situated customers. The Service Agreement shall contain and specify all terms and conditions necessary for the Corporation to provide such service to the customer, including but not limited to: (A) The term of service. (B) The characteristics of service in addition to Character of Service listed above. (C) A listing of the rates and charges to be paid for services rendered. (D) A statement that the customer has met all of the requirements of this tariff, including the following: (1) Customer must provide documentation as to its eligibility under Sections A and B 1. of this tariff. Additionally, customer must agree to the exclusive use of the Corporation's electric energy service during the term of the contract. Customer must also demonstrate proof of the existence of a viable alternative, and its planned procedure to disregard same. (2) The documentation shall demonstrate the customer's appropriate participation in available State and/or local economic development programs as reviewed and attested to by the appropriate agency(ies) and a Certified Economic Developer employed by New York State Electric & Gas Corporation. To that end, the Corporation will coordinate a comprehensive program of development initiatives that are available and applicable from the private and/or state and/or local public sector(s). (3) The documentation shall also include the results of a comprehensive production analysis and energy audit, including, but not limited to process usage, lighting, and HVAC requirements as presented by independent consultants, licensed in New York State as professional engineers, or as otherwise acceptable to the Corporation. The customer agrees to assess in good faith the resulting recommendations from the comprehensive production analysis and energy audit for inclusion in the customer's facility.

Issued in compliance with order in Case 03-E-1761 dated 04/14/05.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: August 29, 2005 Effective date postponed to 09/29/2005. See Supplement No. 1.

Leaf No. 323 Revision: 0 Superseding Revision:

SERVICE CLASSIFICATION NO. 14 (Continued) SPECIAL PROVISIONS: Previous SC 14 Tariff (Cont’d) SERVICE AGREEMENT: (Cont’d) (E) The executed Service Agreement must be accompanied by a sworn affidavit of the senior manager or officer at the customer's facility, representing that the documented information submitted is true and that but for the Service Agreement, the customer would not have commenced taking or increased the use of electric service from the Corporation with the attendant economic development benefits to the Corporation and its other customers, the Community and the State. (F) For Service Agreements negotiated after August 1, 1998, NYSEG will not require as a condition of contract, that a customer purchase its Electric Power Supply from the Corporation. An Eligible Customer whose Service Agreement allows and who otherwise qualifies for General Retail Access pursuant to NYSEG's General Information Section 16 of this Schedule may elect to purchase Electric Power Supply from an ESCO. CONFIDENTIALITY AND TRADE SECRETS: All information provided by the customer to the Corporation, whether printed, written or verbal, in compliance with this service classification, shall be held in confidence and used only for the purpose of business transacted between the Corporation and the Customer. Without limiting the foregoing, information furnished by the Customer and required to be submitted to the New York State Public Service Commission shall not be submitted without a request by NYSEG that such information shall be given trade secret protection in accordance with 16 NYCRR 6-1.3. When any such information is required to be submitted to the New State Public Service Commission, New York State Electric & Gas Corporation will notify the customer of such request prior to its submittal. RATE: The specific charges for service under this service classification will be stated in the negotiated Service Agreement executed for each customer served hereunder. A summary of the Rates and Charges will be filed with the Public Service Commission, as required, as an addendum to this schedule. The rate contained in any Service Agreement will, at a minimum, recover the Corporation's marginal cost plus at least 1 cent per kWh ("Marginal Cost Floor"). Such recovery under each Service Agreement will be calculated by using a rolling 12-month methodology. As part of calculating a customer's monthly bill, the Corporation will compare the customer's previous 12-month contracted Service Agreement billed amount to the previous 12month Marginal Cost Floor amount for the applicable contracted electric usage during that 12-month period. When the contracted Service Agreement billed amount is less than the Marginal Cost Floor amount for that same 12-month period, the Corporation will adjust the customer's current bill to recover that deficiency.
Issued in compliance with order in Case 03-E-1761 dated 04/14/05.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New Yo rk

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2007

Leaf No. 324 Revision: 0 Superseding Revision:

SERVICE CLASSIFICATION NO. 14 (Continued) SPECIAL PROVISIONS: (Cont’d.) Customer Charge - Individual Service Agreements Effective Prior to January 1, 2007: If an Individual Service Agreement that became effective prior to January 1, 2007 refers to the Customer Charge contained within Service Classification Nos. 2, 3 or 7, such Customer Charge shall be defined as including the Meter Ownership, Meter Service, Meter Data Service and Bill Issuance Charges, in addition to the Customer Charge, as set forth in the referenced Service Classification Nos. 2, 3 or 7. This definition is necessitated by the Company’s unbundling of the Meter Ownership, Meter Service, Meter Data Service and Bill Issuance Charges from the Customer Charge, effective January 1, 2007.

Issued in compliance with order in Case No. 05-E-1222 dated 08/23/06.

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Binghamton, New York

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: April 1, 2010

Statement Type: TSP Statement Number: 12

STATEMENT OF EFFECTIVE TAX SURCHARGE PERCENTAGES The rates and charges for service under all Service Classifications will be increased by the following surcharge percentages to collect Gross Income Tax in accordance with Section 6 (a) of PSC No. 120 and Section 3 (a) of PSC No. 121; plus, where applicable, the 1% municipal tax rate and/or the Temporary Metropolitan Transportation Business Tax Surcharge, in accordance with Sections 6 (b) and (c) of PSC No. 120 and Sections 3 (b) and (c) of PSC No. 121. For cities, villages or other areas served, the applicable surcharge percentages are as follows:

Non-Retail Access
Applicable Surcharge Percentages Residential Delivery Non-Residential Delivery and Residential and Non-Residential Commodity

Retail Access
Residential Delivery Non-Residential Delivery

Counties of Westchester, Putnam, Dutchess and Orange
Cities or Villages:
Village of Walden

3.2121%

1.1270%

2.1589%

0.1157%

All Other Areas:

2.1589%

0.1157%

2.1589%

0.1157%

All Other Counties
Cities:
Auburn, Binghamton, Corning, Elmira, Geneva, Hornell, Ithaca, Lockport, Mechanicville, Norwich, Oneonta

3.0928%

1.0101%

2.0408%

0%

Villages:
Addison, Alden, Alfred, Almond, Arkport, Aurora, Blasdell, Burdett, Canaseraga, Canisteo, Cayuga, Cayuga Heights, Cherry Creek, Cooperstown, Clyde, Dannemora, Danville, Delhi, Depew, Deposit, Dryden, Dundee, East Aurora, Elbridge, Elmira Heights, Forestville, Franklin, Gowanda, Hamburg, Hammondsport, Hobart, Horseheads, Interlaken, Johnson City, Jordan, Keeseville, Lancaster, Lansing, Leicester, Liberty, Lyons, Macedon, Marcellus, Monticello, Montour Falls, Moravia, Morrisville, Newark, Newark Valley, North Hornell, Odessa, Orchard Park, Owego, Painted Post, Palmyra, Penn Yan, Perry, Philmont, Port Byron, Port Dickinson, Richfield Springs, Riverside, Round Lake, Seneca Falls, Sidney, Silver Creek, Sloan, South Dayton, Stamford, Trumansburg, Unadilla, Union Springs, Van Etten, Walton, Warsaw, Waterloo, Weedsport, Woodridge All Other Areas

3.0928%

1.0101%

2.0408%

0%

2.0408%

0%

2.0408%

0%

Issued by: James A. Lahtinen, Vice President - Rates & Regulatory Economics, Binghamton, NY

PSC NO: 120 – Electricity New York State Electric & Gas Corporation Initial Effective Date: April 1, 2010

Statement Type: TCS Statement Number: 63

Transition Charge Statement
Pursuant to NYSEG’s Supply Service Options, General Information Section 25 of Schedule PSC No. 120 Electricity, the following Transition Charge (also known as the Non-Bypassable Charge or “NBC”) is applicable to energy deliveries [all kilowatt-hours (kWhs)] under the service classifications listed below, other than as specified below. For customers taking service under the ESCO Supply Service (ESS) rate, the NYSEG Supply Service (NSS) rate, or Hourly Pricing: PSC No. 120 - Electricity; Service Classification Nos. 1, 8, 12 2, 3, 5, 6, 7, 9 PSC No. 121 - Electricity; Service Classification Nos. 1, 2, 3 ($0.00475) Charge per kWh ($0.0084) ($0.00475)

1. The Transition Charge will not apply to:
a. All Power For Jobs (PFJ) customer allocations (i.e., associated kilowatt-hours) and Economic Development Power (EDP) deliveries up to the MW levels delivered as of January 1, 2007, as specified in General Information Section 10 of PSC 120 – Electricity, Economic Development Power. All new NYPA allocations as specified in Section 12 of PSC No. 120 – Electricity, New Allocations of NYPA Power.

b.

Issued in compliance with order in Case No. 09-E-0227 dated 9/28/09.

Issued by: James A. Lahtinen, Vice President - Rates & Regulatory Economics, Binghamton, NY

PSC NO: 120 – Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Statement Type: MFC Statement Number: 04

Merchant Function Charge Statement

For customers taking service under the NYSEG Supply Service (NSS) rate or Hourly Pricing with supply provided by NYSEG, pursuant to NYSEG’s Supply Service Options, General Information Section 25 of Schedule PSC No. 120 - Electricity, the following Merchant Function Charge is applicable to energy supplied [all kilowatt-hours (kWhs)] under the service classifications listed below.

PSC No. 120 - Electricity; Service Classification Nos. 1, 8, 12 2, 5, 6, 7-1, 9 3, 7-2, 7-3, 7-4 PSC No. 121 - Electricity; Service Classification Nos. 1, 2, 3

Charge per kWh $0.0028 $0.0028 $0.0018

$0.0028

For further information regarding the Merchant Function Charge, see General Information Section 25 I.E. of PSC No. 120 - Electricity.

Issued in compliance with order in Case No. 05-E-1222 dated 08/23/06.

Issued by: James A. Lahtinen, Vice President - Rates & Regulatory Economics, Binghamton, NY

PSC NO: 120 – Electricity New York State Electric & Gas Corporation Initial Effective Date: October 1, 2009

Statement Type: RPS Statement Number: 02

Renewable Portfolio Standard Charge Statement

Pursuant to Surcharge to Collect Renewable Portfolio Standard Charge (“RPS”), General Information Section 5 of Schedule PSC No. 120 - Electricity and General Information Section 17 of Schedule PSC No. 121 – Electricity, the following RPS is applicable to energy deliveries [all kilowatt-hours (kWhs)] under the service classifications listed below, other than as specified below.

PSC No. 120 - Electricity Service Classification Nos. 1, 2, 3, 5, 6, 7, 8, 9, 11, 12, 13, and 14 PSC No. 121 - Electricity Service Classification Nos. 1, 2, 3

Charge per kWh $0.0009

$0.0009

Kilowatt-hours supplied by NYPA are exempt from the Renewable Portfolio Standard Charge.

Issued in compliance with Order in Case 03-E-0188 dated 09/24/04.

Issued by: James A. Lahtinen, Vice President - Rates & Regulatory Economics, Binghamton, NY

PSC NO: 120 – Electricity New York State Electric & Gas Corporation Initial Effective Date: March 1, 2010

Statement Type: SBC Statement Number: 04

System Benefits Charge Statement

Pursuant to Surcharge to Collect System Benefits Charge (“SBC”), General Information Section 4 of Schedule PSC No. 120 - Electricity and General Information Section 16 of Schedule PSC No. 121 – Electricity, the following SBC, which is comprised of two components, is applicable to energy deliveries [all kilowatt-hours (kWhs)] under the service classifications listed below, other than as specified below. PSC No. 120 - Electricity; Service Classification Nos. 1, 2, 3, 5, 6, 7, 8, 9, 11, 12, 13, and 14 a. System Benefits Charge b. System Benefits Charge (Energy Efficiency) PSC No. 121 - Electricity; Service Classification Nos. 1, 2, 3 a. System Benefits Charge b. System Benefits Charge (Energy Efficiency) $0.0017 $0.0017 Charge per kWh

$0.0017 $0.0017

Kilowatt-hours supplied by NYPA are exempt from the System Benefits Charge.

Issued in compliance with Order in Case 05-M-0090 dated 12/21/05 and Order in Case 07-M-0548 dated 06/23/08.

Issued by: James A. Lahtinen, Vice President - Rates & Regulatory Economics, Binghamton, NY

PSC NO: 120 – Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Statement Type: TSAS Statement Number: 03 Page 1 of 2

Temporary State Assessment Surcharge Statement
The following charges are applicable to energy delivered [all kilowatt-hours (kWhs) and kilowatts (kW), if applicable] under the service classifications listed below. For customers taking service under Service Classification Nos. 13 and 14 and customers receiving NYPA allocations, the Temporary State Assessment Surcharge(s) listed below for the customer’s otherwise applicable service classification will apply. See General Information Section 28. Surcharge to Collect Temporary State Assessment for further details.

Service Classification Nos. 1 – Residential Regular 8 – Residential Day/Night 12 – Residential Time-of-Use 5 – Outdoor Lighting 6 – General Service Regular 9 – General Service Day/Night 2 – General Service with Demand 3P – Primary Service with Demand 3S – Subtransmission Service with Demand 7-1 – Time-of-Use Secondary Service 7-2 – Time-of-Use Primary Service 7-3 – Time-of-Use Subtransmission Service 7-4 – Time-of-Use Transmission Service

Charge per kWh, all kWhs $0.0025 $0.0022 $0.0019 $0.00384 $0.00348 $0.00301 $0.00238 $0.00192 $0.00277 $0.00190 $0.00172 $0.00120 $0.00198

Issued by: James A. Lahtinen, Vice President - Rates & Regulatory Economics, Binghamton, NY

PSC NO: 120 – Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2010

Statement Type: TSAS Statement Number: 03 Page 2 of 2

Service Classification No. 11 Otherwise Applicable Service Classification 1 – Residential Regular 8 – Residential Day/Night 12 – Residential Time-of-Use 6 – General Service Regular 9 – General Service Day/Night 2 – General Service with Demand 3P – Primary Service with Demand 3S – Subtransmission Service with Demand 7-1 – Time-of-Use Secondary Service 7-2 – Time-of-Use Primary Service 7-3 – Time-of-Use Subtransmission Service 7-4 – Time-of-Use Transmission Service

Charge per Contract Demand $1.50 $2.26 $7.85 $1.26 $2.38 $0.66 $0.63 $0.57 $0.66 $0.73 $0.55 $0.76

Issued in compliance with order in Case No. 09-M-0311 dated 6/19/09.

Issued by: James A. Lahtinen, Vice President - Rates & Regulatory Economics, Binghamton, NY

PSC NO: 120 – Electricity New York State Electric & Gas Corporation Initial Effective Date: January 1, 2007

Statement Type: DISC Statement Number: 2

Purchase of ESCO Accounts Receivable (POR) Discount

Electric accounts receivable will be purchased at a discount off face value of the ESCO receivable.

Discount

1.15%

Issued by: James A. Lahtinen, Vice President - Rates & Regulatory Economics, Binghamton, NY

PSC No: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: November 1, 2008

Addendum Type: UBP Addendum No. 5

Issued in compliance with orders in Case 98-M-1343, Case 07-M-1514, and Case 08-G-0078 dated October 27, 2008

UNIFORM BUSINESS PRACTICES CASE 98-M-1343

OCTOBER 2008

ISSUED BY: James A. Lahtinen, Vice President Rates and Regulatory Economics, Rochester, New York

STATE OF NEW YORK PUBLIC SERVICE COMMISSION

UNIFORM BUSINESS PRACTICES CASE 98-M-1343

October 2008

TABLE OF CONTENTS

SECTION 1: DEFINITIONS............................................................................................. 1 SECTION 2: ELIGIBILITY REQUIREMENTS .............................................................. 6 SECTION 3: CREDITWORTHINESS ........................................................................... 17 SECTION 4: CUSTOMER INFORMATION................................................................. 23 SECTION 5: CHANGES IN SERVICE PROVIDERS................................................... 27 SECTION 6: CUSTOMER INQUIRIES......................................................................... 41 SECTION 7: DISTRIBUTION UTILITY INVOICES ................................................... 43 SECTION 8: DISPUTES INVOLVING DISTRIBUTION UTILITIES, ESCOs OR DIRECT CUSTOMERS ................................................................................................... 45 SECTION 9: BILLING AND PAYMENT PROCESSING ............................................ 47 SECTION 10: MARKETING STANDARDS................................................................. 61

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SECTION 1: DEFINITIONS
As used in the Uniform Business Practices (UBP), the following terms shall have the following meanings: Assignment – Transfer by one ESCO to another ESCO of its rights and responsibilities relating to provision of electric and/or gas supply under a sales agreement. Bill ready – A consolidated billing practice that requires each non-billing party, after receiving customers’ usage data, to calculate its charges and send via EDI charges, billing information, and bill messages to the billing party in a form that allows the transfer of the information to the bill in a format the billing party selects. Billing cycle – The period for which a customer is billed for usage of electricity or natural gas. Billing services agreement (BSA) – An agreement between the distribution utility and the ESCO stating the billing practices and procedures and the rights and responsibilities of billing and non-billing parties relating to issuance of consolidated bills to customers. Budget billing – A billing plan that provides for level or uniform amounts due each billing period over a set number of periods, typically 12 months, and determined by dividing projected annual charges by the number of periods. Installment amounts may be adjusted during the period and may include reconciliations at the end of the budget period to account for differences between actual charges and installment amounts. Business day – Monday through Friday, except for public holidays. Consolidated billing – A billing option that provides customers with a single bill combining charges from more than one service provider and issued by a distribution utility providing delivery service (utility consolidated bill) or by a commodity supplier (ESCO consolidated bill). Customer inquiry – A question or request for information from a customer relating to a rate, term, or condition of service provided by an ESCO, distribution utility or other service provider. Cramming – The addition of unauthorized charges to a customer’s bill. Deferred payment agreement (DPA) – A fair and equitable payment plan agreed upon by a customer and utility and/or a customer and an ESCO that allows a customer to pay an overdue amount in installments. A DPA is based upon the customer's financial circumstances and ability to pay the overdue amount while making payment on current charges. Demand – The amount of electricity or natural gas that is or could be immediately needed by a customer at any given point in time referred to as customer load. For consolidated billing, the term is used in the context of “billing period demand” for customer bills. Electric – The amount of electricity, measured in kilowatts (kW), that a customer uses at a point in time, the customer’s usage averaged over a period, or capacity of facilities reserved for the customer for stand-by or other service.

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Natural Gas – The amount of gas measured in cubic feet or therms that a customer uses or may use over a period, or capacity of facilities reserved for the customer for stand-by or other service. Direct customer – An entity that purchases and schedules delivery of electricity or natural gas for its own consumption and not for resale. A customer with a minimum peak connected load of 1 MW at a single service point qualifies for direct purchase and scheduling of electricity provided the customer complies with NYISO requirements. A customer with annual use of a minimum of 3,500 dekatherms of natural gas at a single service point qualifies for direct purchase and scheduling of natural gas. Distribution utility – A gas or electric corporation owning, operating or managing electric or gas facilities for the purpose of distributing gas or electricity to end users. Distribution utility customer account number – A number used by a distribution utility to identify the account of a utility customer. Distribution utility tariff – A schedule of rates, terms and conditions of services provided by a distribution utility. Drop – A transaction that closes a customer’s account with a provider. This term is used when: (1) a customer’s enrollment is pending and the customer rescinds the enrollment; (2) a customer enrolled with an ESCO returns to distribution utility service or enrolls with another ESCO; or (3) the ESCO discontinues service to a customer. Dual billing – A billing option that provides for separate calculation of charges and presentation of bills to the customer by the distribution utility and ESCO. Electronic data interchange (EDI) – The computer-to-computer exchange of routine information in a standard format using established data processing protocols. EDI transactions are used in retail access programs to switch customers from one supplier to another or to exchange customers’ history, usage or billing data between a distribution utility or MDSP and an ESCO. Transaction set standards, processing protocols and test plans are authorized in orders issued by the Public Service Commission in Case 98-M0667, In the Matter of Electronic Data Interchange and available on the Department of Public Service website at: www.dps.state.ny.us/98m0667.htm. Energy broker – A non-utility entity that performs energy management or procurement functions on behalf of direct customers or ESCOs but does not make retail energy sales to customers. Energy services company (ESCO) – An entity eligible to sell electricity and/or natural gas to end-use customers using the transmission or distribution system of a utility. ESCOs may perform other retail service functions. Sometimes, other terms are used for such entities, such as, ESCO/Marketer to describe a supplier of both commodities, ESCO to describe a supplier of electricity and marketer to describe a supplier of natural gas. For simplicity, the term ESCO is used in the UBP to refer to suppliers of natural gas and/or electricity. ESCO marketing representative – An entity that is either the ESCO or a contractor/vendor conducting, on behalf of the ESCO, any marketing activity that is designed to enroll customers with the ESCO. -2-

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Enroll/Enrollment – The process used to switch a customer from a distribution utility to an ESCO or from one ESCO to another. Enrollment date – The effective date for commencement of electric or natural gas service from an ESCO or distribution utility. Guarantor – An entity that agrees to pay another’s debt or perform another’s duty, liability or obligation. Interval data – Actual energy usage for a specific time interval for a specific period recorded by a meter or other measurement device. Load profile – Actual or estimated customer energy usage by interval over a period representing usage for a customer or average usage for a customer class. Lockbox – A billing payment receipt method agreed upon by a distribution utility and an ESCO, involving use of a third party financial institution to receive and disburse customer payments. Marketer – The term marketer typically refers to the supplier of natural gas. In the UBP, the term ESCO is used to refer to a supplier of either or both electricity and natural gas. Meter – A device for determination of the units of electric or natural gas service supplied to consumers. Meter Data Service Provider (MDSP) – An entity that provides meter data services, consisting of meter readings, meter data translations, and customer association, validation, editing and estimation. Meter Service Provider (MSP) – An entity that installs, maintains, tests and removes meters, or other measurement devices and related equipment. Multi-retailer model – A model for retail access that involves provision of electric or natural gas supply and of delivery service, provided separately to end use customers by two or more entities. New York State Independent System Operator (NYISO) - An independent management organization, authorized by the Federal Energy Regulatory Commission, operating the bulk electric transmission system. New delivery customer – A customer initiating delivery service by a distribution utility. Nomination – A request for delivery of a physical quantity of natural gas or for its delivery at a specific point under a purchase, sale, or transportation agreement. Office of Consumer Services – Office, within the Department of Public Service, which receives and makes determinations concerning customer complaints. Office of Consumer Services (OCS) identifies the exiting Office or its successor in the event the Office name is changed. Pay-as-you-get-paid method – A payment processing method offered by a billing party presenting consolidated bills, whereby the billing party forwards payment to the nonbilling party after receiving payment from the customer.

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Pending enrollment – A stage in processing an enrollment that commences with validation of an enrollment transaction request and ends on the enrollment date that the new supplier is expected to deliver energy. Pending ESCO – An ESCO is a pending ESCO from the date of receipt of an EDI notice containing the effective date for a customer’s enrollment until the ESCO commences commodity service for that customer. Plain Language – Written in clear and coherent manner using words with common and everyday meaning and avoiding legal or energy industry terms, acronyms and abbreviations that a person of ordinary intelligence would not be expected to understand. If use of a technical term is necessary, the term is clearly defined in the portion of the text where it is used. Purchased accounts receivable – A debt owed to an ESCO by a customer for receipt of supplies of gas or electricity and transferred to a distribution utility in exchange for consideration. With recourse – Purchase of accounts receivable with recourse by a distribution utility means that the ESCO remains liable if its customers fail to make payments. A distribution utility that purchases accounts receivable with recourse sends payments to an ESCO at predetermined intervals for amounts billed that are not in dispute and may offset subsequent purchase payments against or obtain reimbursement from an ESCO of any unpaid amounts. Without recourse – Purchase of accounts receivable without recourse by a distribution utility means that the ESCO is not liable if its customers fail to make payments. A distribution utility that purchases accounts receivable without recourse sends payments to an ESCO at predetermined intervals for amounts billed that are not in dispute and has no right to seek reimbursement from an ESCO of any unpaid amounts. Rate ready – A consolidated billing practice that requires each non-billing party to furnish in advance of the billing cycle, rates, rate codes or prices (fixed and/or variable), tax rates, billing information, and bill messages to the billing party. The billing party, after receipt of usage data from the MDSP, uses the information on record to calculate the non-billing party’s charges. Sales agreement – An agreement between a customer and an ESCO that contains the terms and conditions governing the supply of electricity and/or natural gas provided by an ESCO. The agreement may be a written contract signed by the customer or a statement supporting a customer’s verifiable verbal or electronic authorization to enter into an agreement with the ESCO for the services specified. Single retailer model – A model for retail access that involves provision of electric and/or natural gas service to end users by an ESCO that purchases delivery service from the distribution utility and resells it along with electricity and/or natural gas to end users. Slamming – Enrollment of a customer by an ESCO without authorization. Special meter reading – An actual meter reading performed, upon request, on a date that is different than the regularly scheduled meter reading date. -4-

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Special needs customer – A customer who has a certified medical emergency condition, who is elderly, blind or physically challenged, or who may suffer serious impairment to health or safety as a result of service termination during cold weather periods and, thus, is eligible for special procedures before termination of service under the Home Energy Fair Practices Act (HEFPA) (Public Service Law §32(3)). Switch – Transfer of a customer from one ESCO to another, from a distribution utility to an ESCO, or from an ESCO to a distribution utility. Switching cycle – For electric service, the period between the date of the last meter read and the next regularly scheduled meter read. For gas customers, the period between the date of the last meter read and the next regularly scheduled meter read or the first day of the month and the first day of the following month. Termination Fee – An amount specified in an ESCO sales agreement where such agreement permits the ESCO to assess and collect a charge in such amount to a customer who terminates the agreement before the end of a term described in that agreement, regardless of whether the assessed amount is identified as a fee, a charge, liquidated damages or a methodology for the calculation of damages, and regardless of whether it is fixed, scaled or subject to calculation based on market factors. Verification Agent - An entity that is either the ESCO or a contractor/vendor conducting, on behalf of the ESCO, verification of a telephonic agreement with a customer to initiate service and begin enrollment or to obtain customer authorization for release of information, as required by Section 5, Attachment 1 of the UBP.

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SECTION 2: ELIGIBILITY REQUIREMENTS
A. Applicability This Section sets forth the process that an applicant is required to follow for a Department of Public Service (the Department) finding of eligibility to sell natural gas or electricity as an ESCO, that an ESCO is required to follow to maintain eligibility, and that a distribution utility is required to follow for discontinuance of an ESCO’s or Direct Customer's participation in a distribution utility’s retail access program. B. Application Requirements 1. Applicants seeking eligibility to sell natural gas and/or electricity as ESCOs are required to submit to the Department an application package containing the following information and attachments: a. A completed Retail Access Eligibility Form, available on the Department website: www.dps.state.ny.us. b. A sample standard Sales Agreement for each customer class that includes the following information written in plain language: 1. Terms and conditions applicable to the business relationship between the ESCO and the customer which includes: i. provisions governing the process for rescinding or terminating an agreement by the ESCO or the customer including provisions stating that a residential customer may rescind the agreement within three business days after its receipt; ii. the placeholder for the price or how the price is determined, the terms and conditions of the agreement, including the term and end date, if any, of the agreement, the amount of the termination fee and the method of calculating the termination fee, if any, the amount of late payment fees, if applicable, and the provisions, if any, for the renewal of the agreement; and, iii. a clear description of the conditions, if any, that must be present in order for savings to be provided to the customer, if savings are guaranteed. 2. Such contract shall also include on the first page thereof a Customer Disclosure Statement (the Statement). The text within this Statement shall state in plain language the terms and conditions described above (see Section 2, Attachment 1, infra). When the form contract is used by the ESCO as its agreement with the customer, the Customer Disclosure Statement shall also contain the price term of the agreement. In the event that the text in this Statement differs from or is in conflict with a term stated elsewhere in the agreement, the term described by the text in the Statement shall constitute the agreement with the customer notwithstanding a conflicting term expressed elsewhere in the agreement.

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3. Procedures for resolving disputes between the ESCO and a customer; 4. Consumer protections provided by the ESCO to the customer; 5. Method for applying payments and consequences of non-payment; 6. Any charges and fees, services, options or products offered by the ESCO; 7. Department contact information, including the Department ESCO hotline at 1-888-697-7728; 8. ESCO contact information, including a local or toll-free number from the customer’s service location, and procedures used for after-hours contacts and emergency contacts, including transfer of emergency calls directly to a distribution utility and/or an answering machine message that includes an emergency number for direct contact with the distribution utility. 9. A statement that the ESCO shall provide at least 15 calendar days notice prior to any cancellation of service to a customer; and 10. If a condition of service, a statement that the ESCO reserves the right to assign the contract to another ESCO. c. Sample forms of the notices sent upon assignment of sales agreements, discontinuance of service, or transfer of customers to other providers. d. A sample ESCO bill used when dual billing is in effect and, if applicable, a sample ESCO consolidated bill, with terms stated in clear, plain language; e. Procedures used to obtain customer authorization for ESCO access to a customers' historic usage or credit information; f. Sample copies of informational and promotional materials that the ESCO uses for mass marketing purposes; g. Proof of registration with the New York State Department of State; h. Internal procedures for prevention of slamming and cramming; i. Name, postal and e-mail addresses, and telephone and fax numbers for the applicant’s main office; j. Names and addresses of any entities that hold ownership interests of 10% or more in the ESCO, including a contact name for corporate entities and partnerships; k. Detailed explanation of any criminal or regulatory sanctions imposed during the previous 36 months against any senior officers of the ESCO or any entities holding ownership interests of 10% or more in the ESCO; l. A copy of the ESCO’s quality assurance program, which is designed to monitor (a) compliance with Section 10 of the UBP and (b) accuracy of the ESCO marketing materials provided to prospective customer s; and, m. A completed Service Provider Contact Form, which can be found on the Department’s website (http://www.dps.state.ny.us/ocs.html), identifying the

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ESCO’s employee(s) responsible for resolving consumer complaints received by the Department and referred to the ESCO. 2. Applicants shall submit to the Department Test Moderator designated EDI transactions required for syntactical verification in the Phase I testing program. The Department shall maintain a list of ESCOs that successfully complete Phase I test requirements by transaction type. 3. An ESCO that knowingly makes false statements in its application package is subject to denial or revocation of eligibility. 4. If the application package contains information that is a trade secret or sensitive for security reasons, the applicant may request that the Department withhold disclosure of the information, pursuant to the Freedom of Information Law (Public Officers Law Article 6) and Public Service Commission regulations (16 NYCRR §6-1.3). C. Department Review Process The Department shall review the application package and conduct EDI Phase I testing as required for each applicant. An ESCO shall notify the Department of any major changes in the information submitted in the Form and/or application package that occurs during the Department review process. The Department shall advise the applicant, in writing, if the applicant submitted the required information and EDI testing is successfully completed. 1. ESCOs deemed eligible to provide commodity service by the Department must begin serving customers within two-years from the date of the letter notifying the ESCO of their eligibility status (eligibility letter). The ESCO that does not begin serving customers within such two-year period may be required to conduct additional Phase I testing before enrollments will be processed. D. Maintaining ESCO Eligibility Status 1. An ESCO shall submit by January 31 each year (January 31 Statement): a. a statement that the information and attachments in its Retail Access Eligibility Form and application package are current; or b. a description of revisions to the Form and application package and a copy of the revised portions or, at the ESCO’s option, a copy of the revised portions identifying the revisions by highlighting or other means. 2. An ESCO shall update all the information it submitted in its original application package to the Department every three years, starting from the date of its eligibility letter, consistent with the requirements of UBP Section 2.B. An ESCO’s status as an eligible supplier is continuous from the date of the Department eligibility letter, unless revoked or otherwise limited in accordance with UBP Section 2.D.5. If the three year anniversary date falls within one month of January 31, the ESCO shall resubmit its application package in lieu of the January 31 statement. 3. An ESCO shall submit at other times during the year:

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a. A description of any major change in the Form and/or application package and a copy of the revised portions or, at the ESCO's option, a copy of the revised portions identifying the revisions by highlighting or other means. For purposes of Subdivision D of this Section, the term, "major change," means a revision in the terms and conditions applicable to the business relationship between the ESCO and its customers, including provisions governing the process for termination of sales agreements. b. Changes in the ESCO’s business and customer service information displayed on the Department’s Website. c. No later than the 5th day of each month, each price, on a per unit basis, that the ESCO offered and would have charged for each of its services generally available to eligible residential customers as of the 1st day of that month, along with such other information about each price as is required to complete the standardized price reporting format developed by the Department. d. Changes in personnel responsible for resolving consumer complaints received by the Department and referred to the ESCO. 4. An ESCO may be subject to the consequences listed in UBP Section 2.D.5.b for reasons, including, but not limited to: a. false or misleading information in the application package; b. failure to adhere to the policies and procedures described in its Sales Agreement; c. failure to comply with required customer protections; d. failure to comply with applicable NYISO requirements, reporting requirements, or Department oversight requirements; e. failure to provide notice to the Department of any material changes in the information contained in the Eligibility Form or application package; f. failure to comply with the UBP terms and conditions, including discontinuance requirements; g. failure to comply with EDI transaction set standards and processing protocols and/or use properly functioning EDI systems; h. repeated failures to comply with price reporting requirements, reporting misleading price information, or continuing to fail to comply with price reporting requirements after withdrawal of eligibility to enroll new customers; i. failure to comply with the Commission’s Environmental Disclosure Requirements or failure to comply with other Commission Orders, Rules or Regulations; j. failure to reply to a complaint filed with the Department and referred to the ESCO within the timeframe established by the Department’ Office of Consumer Services which is not less than five days; k. any of the reasons stated in Subdivision F of this Section; or

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l. failure to comply with any of the Marketing Standards set forth in Section 10 of the UBP. 5. In determining the appropriate consequence for a failure or non-compliance in one or more of the categories set forth in UBP Section 2.D.4, the Commission or Department may take into account the nature, the circumstances, including the scope of harm to individual customers, and the gravity of the failure or noncompliance, as well as the ESCO’s history of previous violations. a. The Commission or Department shall: 1. Notify the ESCO in writing of its failure to comply and request that the ESCO take appropriate corrective action or provide remedies within the directed cure period, which will be based on a reasonable amount of time given the nature of the issue to be cured. 2. Upon failure of the ESCO to take corrective actions or provide remedies within the cure period, the Commission may impose the consequences listed in subparagraph b of this paragraph. 3. Consequences shall not be imposed until after the ESCO is provided notice and an opportunity to respond. 4. The notice of consequences imposed by the Commission will be published on the Department’s website. b. Consequences for non-compliance in one or more of the categories set forth in UBP Section 2.D.4 may include one or more of the following restrictions on an ESCO’s opportunity to sell gas and/or electricity to retail customers: 1. Suspension from a specific Commission approved retail program in either a specific service territory or all territories in New York; 2. Suspension of the ability to enroll new customers in either a specific service territory or all service territories in New York; 3. Imposition of a requirement to record all telephonic marketing presentations, which shall be made available to the Department for review; 4. Reimbursements to customers who did not receive savings promised in the ESCO’s sales agreement/Customer Disclosure Statement or substantially demonstrated to have been included in the ESCO’s marketing presentation or to customers who incurred costs as a result of the ESCO’s failure to comply with the marketing standards set forth in Section 10 of the UBP; 5. Release of customers from sales agreements without imposition of early termination fees; 6. Revocation of an ESCO’s eligibility to operate in New York; and, 7. Any other measures that the Commission may deem appropriate. c. Consequences imposed pursuant to this paragraph shall continue to apply until the ESCO’s failure to comply with the UBP has been cured or the Commission or Department has determined that no further cure is necessary.

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6. An ESCO’s eligibility to serve customers is valid unless: the ESCO abandons its eligibility status; or such status is revoked by the Commission through a final order pursuant to UBP Section 2.D.5. 7. The Department shall notify distribution utilities upon notice to the ESCO, and the NYISO if applicable, of any determination to revoke an ESCO's eligibility to sell natural gas and/or electricity. The distribution utility shall notify the ESCO’s customers, in accordance with paragraph 3 of Subdivision F of this Section, of any Department revocation of an ESCO's eligibility. E. Distribution Utility Requirements 1. After receipt of the Department’s compliance letter, the ESCO shall notify the distribution utility, and NYISO if applicable, of its eligibility status and intent to complete the process to commence operation in the distribution utility's service area, including execution of any operating agreement that is required. 2. Upon satisfaction of the distribution utility's and, if applicable the NYISO's requirements, and successful completion of EDI testing conducted by the distribution utility, the ESCO may enter into an operating agreement, if any is required, with the distribution utility to commence operations in its service territory. F. Discontinuance of an ESCO’s and Direct Customer's Participation in a Retail Access Program 1. In accordance with the procedures established in this Subdivision, a distribution utility may discontinue an ESCO’s or Direct Customer’s participation in its retail access program for the following reasons: a. Failure to act that is likely to cause, or has caused, a significant risk or condition that compromises the safety, system security, or operational reliability of the distribution utility's system, and the ESCO or Direct Customer failed to eliminate immediately the risk or condition upon verified receipt of a non-EDI notice; b. Failure to provide natural gas (provided zero quantity) to the distribution utility’s city gate; c. Failure to pay an invoice upon the due date; d. Failure to provide for delivery of at least 95% of the amount of natural gas directed by a distribution utility for delivery or at least 80% of the daily metered usage of the ESCO's customers or a Direct Customer’s specified load or lower percentages included in a balancing program established in a distribution utility's tariff and/or any operating agreement; e. Failure to maintain a creditworthiness standard or provide required security; f. Failure to comply with the terms and conditions of a distribution utility’s tariff, operating agreement, or Gas Transportation Operating Procedures (GTOP) Manual to the extent that said documents are consistent with the provisions of the UBP;

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g. Discontinuance of an ESCO’s or Direct Customer's participation in a distribution utility’s retail access program by the NYISO; or, h. Commission determination that an ESCO is not eligible to sell natural gas or electricity to retail customers. 2. To initiate the discontinuance process, a distribution utility shall send a non-EDI discontinuance notice by overnight mail and verified receipt, to the ESCO or Direct Customer and the Department. The notice shall contain the following information: a. The reason, cure period, if any, and effective date for the discontinuance; b. A statement that the distribution utility shall notify the ESCO’s customers of the discontinuance if the ESCO fails to correct the deficiency described in the notice within the cure period, unless the Department directs the distribution utility to stop the discontinuance process; c. The distribution utility may suspend the ESCO’s right to enroll customers until correction of the deficiency; and d. Correction of the deficiency within the cure period, or a Department directive, will end the discontinuance process. 3. The distribution utility shall send notices to the ESCO’s customers informing them of the discontinuance and providing the following information: a. The discontinuance shall or did occur on one of the following dates selected by the distribution utility: the scheduled meter read date, the first day of the month, or another date, if readings are estimated, or on the date of a special meter read; b. Customers have the option to select another ESCO or return to full utility service or, if a program authorizing random assignment is in effect, to enroll with a designated ESCO through that program; c. Names and telephone numbers of ESCOs offering service to retail customers in the distribution utility’s service territory; d. Any ESCO selected by a customer may file an enrollment request on the customer’s behalf with the distribution utility, and the distribution utility shall charge no fee for changing the customer’s provider to the new ESCO; and, e. During any interim between discontinuance of a customer’s current ESCO and enrollment with a new ESCO, the distribution utility shall provide service under its applicable tariff, unless the distribution utility notified the customer that it is terminating its delivery services to the customer on or before the discontinuance date. 4. The distribution utility shall submit a sample copy of its discontinuance notice to the Department for review and approval prior to distribution to customers. 5. The distribution utility may request permission from the Department to expedite the discontinuance process, upon a showing that it is necessary for safe and

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adequate service or in the public interest. Any expeditious discontinuance process shall include the ESCO or Direct Customer, and the distribution utility. 6. Upon any discontinuance, an ESCO or Direct Customer shall remain responsible for payment or reimbursement of any and all sums owed under the distribution utility tariffs, any tariffs on file with the FERC and service agreements relating thereto, or any agreements between the ESCO and the distribution utility. 7. The notice requirements and time limits for a distribution utility to discontinue an ESCO’s or Direct Customer’s participation in a distribution utility’s retail access program (discontinue participation) are: a. Upon a distribution utility determination that an ESCO’s or Direct Customer’s action, or failure to act, is likely to cause, or has caused, a significant risk or condition that compromises the safety, system security, or operational reliability of the distribution utility's system and that the ESCO or Direct Customer failed to eliminate immediately the risk or condition upon verified receipt of a non-EDI notice, the distribution utility may discontinue participation as soon as practicable. b. Upon a distribution utility determination that an ESCO or Direct Customer responsible for the delivery of natural gas failed, except under force majeure conditions, to deliver natural gas (provided zero quantity) to the distribution utility’s service territory for its load, the distribution utility may discontinue participation no sooner than two business days after receipt by the ESCO or Direct Customer of a discontinuance notice. c. Upon a distribution utility determination that an ESCO or Direct Customer failed to pay an invoice on the due date, as specified in the distribution utility’s tariff, and the ESCO’s or Direct Customer’s required security or credit limit is insufficient to cover the unpaid amount, with interest, the distribution utility may discontinue participation no sooner than ten business days (cure period) after receipt by the ESCO or Direct Customer of a discontinuance notice. If the ESCO or Direct Customer pays the amount due on or before the expiration of the cure period, the distribution utility shall stop the process to discontinue participation. d. Upon a distribution utility determination that an ESCO or Direct Customer responsible for the nomination and delivery of natural gas failed, except in force majeure conditions, to nominate and/or deliver sufficient natural gas to the distribution utility’s service territory to satisfy at least 95% of the amount of natural gas directed by a distribution utility for delivery or at least 80% of the daily metered usage of the ESCO's customers or the Direct Customer’s specified load or lower percentages included in a balancing program established in a distribution utility's tariffs and/or any operating agreement on any three days during any month, the distribution utility may initiate a discontinuance process no sooner than five business days (cure period) after receipt by the ESCO or Direct Customer of a discontinuance notice. If the ESCO or Direct Customer provides adequate assurances and a description of any necessary process changes that ensure adequate nominations and

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deliveries on or before the expiration of the cure period, the distribution utility shall stop the discontinuance process. Upon a determination to continue the discontinuance process because the assurances and proposed process changes are inadequate, the distribution utility shall notify the ESCO or Direct Customer that it will discontinue participation no later than 15 business days from the expiration of the cure period. The distribution utility shall notify the ESCO’s customers that the distribution utility will discontinue participation on or before the expiration of 15 business days from the end of the cure period. If a failure to provide sufficient natural gas for any 3 days during a calendar month occurred during the past 12 months and the distribution utility sent a related discontinuance notice for each occurrence, it may discontinue participation no sooner than two business days after receipt by an ESCO or Direct Customer of a discontinuance notice. e. Upon a distribution utility determination that an ESCO or Direct Customer failed to provide or maintain a creditworthiness standard or required security, the distribution utility may initiate a discontinuance process no sooner than five business days (cure period) after receipt by the ESCO or Direct Customer of a discontinuance notice. If the ESCO or Direct Customer satisfies the creditworthiness standard or provides the required security on or before the expiration of the cure period, the distribution utility shall stop the discontinuance process. Upon a determination to continue with the discontinuance process because the ESCO or Direct Customer failed to comply with the creditworthiness standard or provide adequate security, the distribution utility shall notify the ESCO or Direct Customer that it will discontinue participation no later than 15 business days from the expiration of the cure period. The distribution utility shall notify the ESCO’s customers that it will discontinue participation on or before 15 days from the expiration of the cure period. If a failure to comply with the creditworthiness standard or provide adequate security occurred twice during the past 12 months and the distribution utility sent a related discontinuance notice for each failure, it may discontinue participation no sooner than two business days after receipt by an ESCO or Direct Customer of a discontinuance notice. f. Upon a distribution utility determination that an ESCO or Direct Customer failed, except in force majeure conditions, to comply with any other applicable provision of the distribution utility's tariff, operating agreement, or GTOP manual, the distribution utility may initiate a discontinuance process no sooner than ten business days (cure period) after receipt by the ESCO or Direct Customer of a discontinuance notice. If the ESCO or Direct Customer provides adequate assurances and a description of any necessary process changes that ensure compliance on or before the expiration of the cure period, the distribution utility shall stop the discontinuance process. Upon a determination to continue the discontinuance process because the assurances and proposed process changes are inadequate, the distribution utility shall notify the ESCO or Direct Customer that it will discontinue participation no later than 15 business days from the expiration of the cure period. The distribution utility shall notify the ESCO’s customers that it will discontinue - 14 -

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participation on or before the expiration of 15 business days after the end of the cure period.

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SECTION 2 SECTION 2, ATTACHMENT 1

SAMPLE CUSTOMER DISCLOSURE STATEMENT

Price

Fixed or Variable and, if variable, how the price is determined Length of the agreement and end date

Process customer may use to rescind the agreement without penalty

Amount of Early Termination Fee and method of calculation

Amount of Late Payment Fee and method of calculation

Provisions for renewal of the agreement

Conditions under which savings to the customer are guaranteed

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SECTION 3

SECTION 3: CREDITWORTHINESS
A. Applicability This Section establishes creditworthiness standards that apply to ESCOs and Direct Customers. An ESCO’s and Direct Customer's participation in a distribution utility's retail access program is contingent upon satisfaction of creditworthiness requirements and provision of any security. B. ESCOs 1. An ESCO shall satisfy a distribution utility’s creditworthiness requirements if: a. The ESCO, or a guarantor, maintains a minimum rating from one of the rating agencies and no rating below the minimum from one of the other two rating agencies. For the purposes of this Section, minimum rating shall mean “BBB” from Standard & Poor's, “Baa2” from Moody's Investor Service, or “BBB” from Fitch Ratings (minimum rating); or, b. The ESCO enters into a billing arrangement with the distribution utility, whereby the distribution utility bills customers on behalf of the ESCO and retains the funds it collects to offset any balancing and billing service charges provided that the distribution utility has a priority security interest with a first right of access to the funds. The ESCO shall submit an affidavit from a senior officer attesting to such utility interest and right. Except that an ESCO serving customers outside of such billing arrangement, must satisfy the security requirements of UBP Section 3.D with respect to those customers. 2. If an ESCO, or a guarantor, is not rated by Standard & Poor’s, Moody’s Investor Service or Fitch Ratings, it shall satisfy a distribution utility’s creditworthiness requirements if the ESCO, or a guarantor: a. Maintains a minimum “1A2” rating from Dun & Bradstreet (Dun and Bradstreet minimum rating) and the ESCO maintains 24 months good payment history with the distribution utility; and, b. Provides any security required by the distribution utility, calculated in accordance with Subdivision D, after deduction of the following unsecured credit allowances:

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Rating 5A1 or 5A2

Unsecured Credit Allowance 30% of an ESCO's tangible net worth, up to 5% of the distribution utility's average monthly revenues for the applicable service 30% of an ESCO's tangible net worth, up to 5% of the distribution utility's average monthly revenues for the applicable service 30% of an ESCO's tangible net worth, up to 5% of the distribution utility's average monthly revenues for the applicable service 50% of an ESCO's tangible net worth, up to $500,000 50% of an ESCO's tangible net worth, up to $375,000

4A1 or 4A2

3A1 or 3A2

2A1 or 2A2

1A1 or 1A2

An ESCO shall provide information, upon request of the distribution utility, to enable the distribution utility to verify the ESCO’s equity. The distribution utility may request reasonable information to obtain the verification and shall safeguard it as confidential information and protect it from public disclosure. The distribution utility may deny the unsecured credit allowance to any ESCO that fails to provide the requested information. 3. A distribution utility may require an ESCO to provide and maintain security in the full amount of the distribution utility’s credit risk, calculated in accordance with Subdivision D, if: a. The ESCO, or a guarantor, is not rated; b. The ESCO, or a guarantor, with a minimum rating is placed on credit watch with negative implications or is rated below the minimum rating; c. The ESCO, or a guarantor, is rated below the Dun & Bradstreet minimum rating or the ESCO fails to maintain 24 months good payment history with the distribution utility; or, d. An ESCO issuing consolidated bills fails to render timely bills to customers or to make timely payments to the distribution utility. 4. If a distribution utility’s credit risk, associated with an ESCO’s participation in its retail access program, exceeds 5% of the distribution utility’s average monthly revenues for the applicable service, the distribution utility may require the ESCO, in addition to maintaining a minimum rating, to provide and maintain security in the amount of such excess credit risk.

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C. Direct Customers A Direct Customer shall satisfy a distribution utility’s creditworthiness requirements if: 1. Its account is current and remained current for the past 12 months; and, 2. If its debt is rated, it maintains a minimum rating of its long-term unsecured debt securities from one of the rating agencies and no rating below the minimum rating from one of the other two rating agencies. D. Calculation of Credit Risk and Security The distribution utility shall calculate its credit risk and establish its security requirements as follows: 1. Delivery Service Risk a. For an ESCO that issues a consolidated bill under a multi-retailer model, a distribution utility may require security in an amount no greater than 45 days of peak usage of the ESCO's customers' projected energy requirements during the next 12 months, priced at the distribution utility's applicable delivery service rate and including relevant customer charges. b. For an ESCO that bills customers for delivery and commodity services under a single retailer model, a distribution utility may require security in an amount no greater than 60 days of peak usage of the ESCO’s customers’ projected energy requirements during the next 12 months, priced at the distribution utility's applicable delivery service rate and including relevant customer charges. c. Upon an ESCO request, the distribution utility shall establish separate security requirements for summer (April 1 - October 31) and winter (November 1 March 31) and may retain winter security until the end of two months (April and May) after the end of the winter period. 2. Natural Gas Imbalance Risk a. The distribution utility may require an ESCO or Direct Customer to provide security in an amount no greater than the ESCO’s customers’ or a Direct Customer’s projected maximum daily quantity times peak forecasted NYMEX price for the next 12 months and for upstream capacity to the city gate times 10 days. b. Upon the request of an ESCO or Direct Customer, the distribution utility shall establish separate security requirements for summer (April 1 - October 31) and winter (November 1 - March 31) and may retain winter security until the end of two months (April and May) after the end of the winter period. 3. Major Change in Risk a. A major change shall mean a change in credit risk of more than the greater of 10% or $200,000.

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b. The ESCO or Direct Customer shall promptly notify the distribution utility and the Department of any major change in credit and or rating risk. c. The distribution utility may require an ESCO or a Direct Customer, within five days, to provide additional amounts of security if a major change occurs to increase its credit risk, as follows: 1. If Standard & Poors, Moody’s Investor Service, or Fitch Ratings downgrades an ESCO’s, or its guarantor’s, rating or a Direct Customer’s debt below the minimum rating or Dun & Bradstreet downgrades an ESCO’s, or its guarantor’s, rating or a Direct Customer’s debt; or, 2. An increase occurs in customer usage or in energy prices and such increase is sustained for at least 30 days. d. In the event that a major change occurs to decrease a distribution utility’s credit and/or rating risk, results in compliance by an ESCO or Direct Customer with creditworthiness requirements, and elimination of the basis for holding some or all of the security, the distribution utility shall return or release the excess amount of the ESCO’s or Direct Customer’s security with accumulated interest, if applicable. The distribution utility shall return such amount within five business days after receipt of an ESCO or Direct Customer notice informing the distribution utility of the occurrence of such major change. E. Security Instruments 1. The following financial arrangements are acceptable methods of providing security: a. Deposit or prepayment, which shall accumulate interest at the applicable rate per annum approved by the Public Service Commission for “Other Customer Capital”; b. Standby irrevocable letter of credit or surety bond issued by a bank, insurance company or other financial institution with at least an “A” bond rating; c. Security interest in collateral; or, d. Guarantee by another party or entity with a credit rating of at least “BBB” by S&P, “Baa2” by Moody's, or “BBB” by Fitch; or e. Other means of providing or establishing adequate security. 2. A distribution utility may refuse to accept any of these methods for just cause provided that its policy is applied in a nondiscriminatory manner to any ESCO. 3. If the credit rating of a bank, insurance company, or other financial institution that issues a letter of credit or surety bond to an ESCO or Direct Customer falls below an "A" rating, the distribution utility shall allow a minimum of five business days for an ESCO or Direct Customer to obtain a substitute letter of credit or surety bond from an "A" rated bank, insurance company, or other financial institution.

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F. Lockbox If the distribution utility and ESCO arrange for a lockbox, security requirements are reduced by 50% provided that the arrangement includes the following: 1. Agreement on allocation of funds and the first right of the distribution utility, in the event of an ESCO’s financial difficulty, to obtain funds in the lockbox deposited to the credit of the ESCO; 2. Establishment of rules for managing the lockbox; 3. Agreement on conditions for terminating the lockbox for non-compliance with the rules or for failure to receive customer payments on a timely basis; and, 4. Responsibility of an ESCO for any costs associated with implementing and administering the lockbox. G. Calling on Security 1. If an ESCO or Direct Customer fails to pay the distribution utility, in accordance with UPB Section 7, Invoices, the distribution utility may draw from security provided that the distribution utility notifies the ESCO or Direct Customer five business days' in advance of the withdrawal and the ESCO or Direct Customer fails to make full payment before the expiration of the five business days. 2. If an ESCO receives a discontinuance notice or elects to discontinue service to customers and owes amounts to the distribution utility, the distribution utility may draw from the security provided by the ESCO without prior notice. 3. If an ESCO files a petition or an involuntary petition is filed against an ESCO under the laws pertaining to bankruptcy, the distribution utility may draw from security, to the extent permitted by applicable law. H. Application by Distribution Utilities 1. Within ten business days after receipt of a complete ESCO application, a distribution utility shall complete its evaluation of initial creditworthiness, state the rationale for its determination, and provide the calculation supporting the credit limit and any resulting security requirement. 2. A distribution utility shall perform, at least annually, an evaluation, at no charge, of an ESCO’s satisfaction of creditworthiness standards and security requirements. 3. A distribution utility shall perform evaluations of creditworthiness, security requirements, and security calculations in a non-discriminatory and reasonable manner. 4. Pending resolution of any dispute, the ESCO or Direct Customer shall provide requested security within the time required in this Section. 5. A distribution utility may reduce or eliminate any security requirement provided that it reduces or eliminates the requirement in a nondiscriminatory manner for any ESCO or Direct Customer. The distribution utility may request reasonable information to evaluate credit risk. If an ESCO or Direct Customer fails to - 21 -

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provide the requested information, a distribution utility may deny the ESCO or Direct Customer an opportunity to provide lower or no security.

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SECTION 4

SECTION 4: CUSTOMER INFORMATION
A. Applicability This Section establishes practices for release of customer information by distribution utilities or MDSPs to ESCOs and Direct Customers and identifies the content of information sets. The distribution utility or MDSP and an ESCO shall use EDI standards, to the extent developed, for transmittal of customer information and may transmit data, in addition to the minimum information required, via EDI or by means of an alternative system. B. Customer Authorization Process The distribution utility or MDSP shall provide information about a specific customer requested by an ESCO authorized by the customer to receive the information. 1. An ESCO shall obtain customer authorization to request information, in accordance with the procedures in UBP Section 5, Changes in Service Providers, Attachments 1, 2, and 3. An ESCO shall inform its customers of the types of information to be obtained, to whom it will be given, how it will be used, and how long the authorizations will be valid. The authorization is valid for no longer than six months unless the sales agreement provides for a longer time. 2. A distribution utility and a MDSP shall assume that an ESCO obtained proper customer authorization if the ESCO is eligible to provide service and submits a valid information request. 3. An ESCO shall retain, for a minimum of two years or for the length of the sales agreement whichever is longer, verifiable proof of authorization for each customer. Verification records shall be provided by an ESCO, upon request of the Department, within five calendar days after a request is made. Locations for storage of the records shall be at the discretion of the ESCOs. 4. Upon request of a customer, a distribution utility and/or MDSP shall block access by ESCOs to information about the customer. 5. An ESCO and its agent shall comply with statutory and regulatory requirements pertaining to applicable state and federal do-not-call registries. C. Customer Information Provided to ESCOs 1 1. Release of Information. A distribution utility and a MDSP shall use the following practices for transferring customer information to an ESCO: a. A distribution utility shall provide the information in the Billing Determinant Information Set upon acceptance of an ESCO’s enrollment request and the

1

Upon enrollment of a customer, an ESCO shall receive usage data and any subsequent changes, corrections and adjustments to previously supplied data or estimated consumption for a period, at the same time that the distribution utility validates them for use. An ESCO issuing consolidated bills is entitled to receive billing information, in accordance with UBP Section 9, Billing and Payment Processing.

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information in the Customer Contact Information Set and the Credit Information Set, upon ESCO request. b. The distribution utility or MDSP shall respond within two business days to valid requests for information as established in EDI transaction standards and within five business days to requests for data and information for which an EDI transaction standard is not available. The distribution utility or MDSP shall provide the reason for rejection of any valid information request. 2. Customer Contact Information Set. The distribution utility or MDSP, to the extent it possesses the information, shall provide, upon an ESCO request, consumption history for an electric account and consumption history and/or 2 a gas profile for a gas account. a. Consumption history 3 for an electric or gas account shall include: 1. Customer’s service address; 2. Electric or gas account indicator; 3. Sales tax district used by the distribution utility; 4. Rate service class and subclass or rider by account and by meter, where applicable; 5. Electric load profile reference category or code, if not based on service class; 6. Usage type (e.g., kWh or therm), reporting period, and type of consumption (actual, estimated, or billed); 7. 12 months, or the life of the account, whichever is less, of customer data via EDI and, upon separate request, an additional 12 months, or the life of the account, whichever is less, of customer data via EDI or an alternative system at the discretion of the distribution utility or MDSP, and, where applicable, demand information; 4 if the customer has more than one meter associated with an account, the distribution utility or MDSP shall provide the applicable information, if available, for each meter; and 8. Electronic interval data in summary form (billing determinants aggregated in the rating periods under a distribution utility's tariffs) via EDI, and if requested in detail, via an acceptable alternative electronic format. b. A gas profile for a gas account shall include: 1. Customer’s service address;
2

3

4

If a distribution utility or MDSP offer a gas profile and consumption history, an ESCO may choose either option. A distribution utility or MDSP shall make available, upon request, class average load profiles for electric customers. A distribution utility or MDSP, in addition to EDI transmittal, may provide Web based access to customer history information. A distribution utility may provide data for a standard 24 months or life of the account, whichever is less, as part of its Customer Contract Information Set.

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2. Gas account indicator; 3. Sales tax district used by the distribution utility for billing; 4. Rate service class and subclass or rider, by account and by meter, where applicable; 5. Date of gas profile; and, 6. Weather normalization forecast of the customer’s gas consumption for the most recent 12 months or life of the account, whichever is less, and the factors used to develop the forecast. 3. Billing Determinant Information Set. Upon acceptance of an ESCO enrollment request, a distribution utility shall provide the following billing information for an electric or gas account, as applicable 5 : a. Customer’s service address, and billing address, if different; b. Electric and/or gas account indicator; c. Meter reading date or cycle and reporting period; d. Billing date or cycle and billing period; e. Meter number, if available; f. Distribution utility rate class and subclass, by meter; g. Description of usage measurement type and reporting period; h. Customer’s load profile group, for electric accounts only; i. Life support equipment indicator; j. Gas pool indicator, for gas accounts only; k. Gas capacity/assignment obligation code; l. Customer’s location based marginal pricing zone, for electric accounts only; and, m. Budget billing indicator. 6 4. Credit Information Set. The distribution utility or MDSP shall provide credit information for the most recent 24 months or life of the account, whichever is less, upon receipt of an ESCO's electronic or written affirmation that the customer provided authorization for release of the information to the ESCO. Credit information shall include number of times a late payment charge was assessed and incidents of service disconnection.

5

6

As specified in the EDI standard for an enrollment request and response, the distribution utility may transmit additional data elements, based upon the request, the responding distribution utility, and the commodity type. This indicator is limited to 12 month levelized payment plans and does not include other payment plans.

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D. Direct Customer Information A Direct Customer shall receive usage data and any subsequent changes, corrections and adjustments to previously supplied data, and estimated consumption for a period, at the same time that the distribution utility validates them for use. The distribution utility or MDSP shall make available, upon request, to an electric Direct Customer, a class load profile for its service class. E. Charges for Customer Information No distribution utility or MDSP shall impose charges upon ESCOs or Direct Customers for provision of the information described in this Section. The distribution utility may impose an incremental cost based fee, authorized in tariffs for an ESCO’s request for customer data for a period in excess of 24 months or for detailed interval data per account for any length of time. F. Unauthorized Information Release An ESCO, its employees, agents, and designees, are prohibited from selling, disclosing or providing any customer information obtained from a distribution utility or MDSP, in accordance with this Section, to others, including their affiliates, unless such sale, disclosure or provision is required to facilitate or maintain service to the customer or is specifically authorized by the customer or required by legal authority. If such authorization is requested from the customer, the ESCO shall, prior to authorization, describe to the customer the information it intends to release and the recipient of the information.

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SECTION 5

SECTION 5: CHANGES IN SERVICE PROVIDERS
A. Applicability This Section establishes practices for receiving, processing, and fulfilling requests for changing a customer’s electricity or natural gas provider and for obtaining a customer’s authorization for the change. A change in a provider includes transfer from: (1) one ESCO to another; (2) an ESCO to a distribution utility; and (3) a distribution utility to an ESCO. This Section also establishes practices for: an ESCO’s drop of a customer or a customer’s drop of an ESCO, retention of an ESCO after a customer’s relocation within a distribution utility’s service area, assignment of a customer, and initiation or discontinuance of procurement of electricity or natural gas supplies by a Direct Customer. This Section does not establish practices for obtaining other energy-related services or changing billing options. The process of changing a service provider is comprised of two steps. For enrollment with an ESCO, the first step is obtaining customer agreement to accept electric or natural gas service, or both, according to the terms and conditions of an offer. A sales agreement establishes the terms and conditions of the customer’s business arrangement with the ESCO. The second step is enrollment and the distribution utility's modification of its records to list the customer’s transfer to a provider on a specific date. This transaction is primarily between the ESCO and the distribution utility. B. Customer Agreement Procedures An ESCO, or its agent, may solicit and enter into a sales agreement with a customer subject to the following requirements. 1. The ESCO shall obtain a customer agreement to initiate service and enroll a customer and customer authorization to release information to the ESCO by means of one of the following methods. a. Telephone agreement and authorization, preceded or followed within three business days by provision of a sales agreement, in accordance with requirements in Attachment 1 – Telephonic Agreement and Authorization; b. Electronic agreement and authorization, attached to an electronic version of the sales agreement, in accordance with requirements in Attachment 2 – Electronic Agreement and Authorization; or c. Written agreement bearing a customer’s signature on a sales agreement (original or fax copy of a signed document), in accordance with requirements in Attachment 3 – Written Agreement and Authorization. 2. The ESCO shall provide residential customers the right to cancel a sales agreement within three business days after its receipt (cancellation period).

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C. Provision of List of ESCOs to Customers Distribution utilities shall offer to provide a customer who requests initiation of delivery service with an up-to-date list of ESCOs and provide the list at any time, upon request of any customer. D. Customer Enrollment Procedures 1. An ESCO shall transmit an enrollment request 7 to a distribution utility no later than 15 calendar days prior to the effective date of the enrollment. The enrollment request shall contain as a minimum, the information required for processing set forth in Attachment 4, Enrollment Request. 2. The distribution utility shall process enrollment requests in the order received. 3. The distribution utility shall accept only one valid enrollment request 8 for each commodity per customer during a switching cycle. If the distribution utility receives multiple enrollment requests for the same customer during a switching cycle, it shall accept the first valid enrollment request and reject subsequent requests. 4. An ESCO shall submit an enrollment request after it provides the sales agreement to the customer and, for residential customers, after the expiration of the cancellation period. 9 5. After receipt of an enrollment request, the distribution utility shall, within one business day, acknowledge its receipt, and, within two business days, provide a response indicating rejection and the reason, or acceptance and the effective date for the change of provider. 6. Upon acceptance of an enrollment request, the distribution utility shall send a notice to any incumbent ESCO that the customer's service with that ESCO will be terminated on the effective date of the new enrollment. In the event that the distribution utility receives notice from the pending ESCO or the customer, no later than three business days before the effective date that a pending enrollment is cancelled, the distribution utility shall transmit a request to reinstate service to any incumbent ESCO, unless the ESCO previously terminated service to the customer or the customer requests a return to full utility service. 7. With the exception of a new installation use of an interim estimate of consumption or a special meter reading, 10 a change of providers is effective: for

7

8

9

When a utility customer selects, or agrees to be randomly assigned to an ESCO through participation in an ESCO Referral Program, an enrollment request from an ESCO is not sent. The utility will enroll the participating customer, notify the ESCO of the customer selection or designation, and provide customer account details via a response transaction. Criteria for determining the validity of an EDI transaction are described in the EDI processing protocols adopted in Case 98-M-0667, Electronic Data Interchange. When the utility enrolls the customer with an ESCO, in conjunction with the customer's participation in an ESCO Referral Program, it is the responsibility of the ESCO to provide the customer with a sales agreement. A customer enrolled by the utility will continue to have the opportunity to cancel prior to the expiration of the initial incentive period established by the utility.

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an electric customer, on the next regularly scheduled meter reading date; and, for a gas customer, on the next regularly scheduled meter reading date or the first day of the month, in accordance with provisions set forth in the distribution utility’s tariff. 11 The distribution utility shall set the effective date, which shall be no sooner than 15 calendar days after receipt of an enrollment request. Service to new delivery customers is effective after the installation is complete and, if necessary, inspected. 8. An off-cycle change of an electric service provider is allowed no later than 15 calendar days before the date requested for the change if a new ESCO or a customer arranges for a special meter reading or agrees to accept an interim date for estimating consumption. The ESCO or customer is required to pay the cost for any special meter reading, in accordance with provisions set forth in the distribution utility’s tariff. A change based upon an interim estimate of consumption or a special meter reading is effective on the date of the interim estimate or special meter reading. Off-cycle changes of gas service providers are allowed if the incumbent and new ESCO agree on an effective date no later than 15 calendar days following the request. E. Customer Notification 1. The distribution utility shall send no later than one calendar day after acceptance of an enrollment request a verification letter to the customer notifying the customer of the acceptance. The notice shall inform the customer that if the enrollment is unauthorized or the customer decides to cancel it, the customer is required immediately to so notify the distribution utility and the pending ESCO. 2. Upon receipt of such cancellation, the distribution utility shall cancel the pending enrollment and reinstate the customer with the incumbent ESCO, if any, or the distribution utility, provided that no less than three business days remain before the planned effective date. If less than three business days remain, the change to the new provider shall occur and remain effective for one billing cycle. The customer shall return to full utility service at the end of the next switching cycle, unless the customer is enrolled by another ESCO at least 15 days before the beginning of the next switching cycle. 3. If a customer notifies the pending ESCO of such cancellation, the pending ESCO shall send a customer's drop request to the distribution utility at least three business days prior to the effective date for the pending enrollment. F. Rejection of Enrollment Requests The distribution utility may reject an enrollment request for any of the following reasons:
10

11

If meters are read bimonthly and bills are issued monthly using estimated usage, the effective date for the interim months is the date usage is estimated for billing purposes. If meters are not read within two business days of the scheduled meter reading day, the distribution utility or MDSP shall estimate usage as of the scheduled meter reading day. The effective date for a change of provider is that date, except where changes of natural gas suppliers are scheduled for the first of the month.

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1. Inability to validate the transaction; 2. Missing or inaccurate data in the enrollment request; 3. ESCO’s ineligibility to provide service in the specified territory; 4. No active or pending delivery service; 5. A pending valid prior enrollment request; or 6. The account is coded as ineligible for switching. G. Customer Relocations Within a Service Territory 1. A customer requesting relocation of service within a distribution utility’s service territory and continuation of its ESCO service, arranges for continuation at the new location of delivery service by contacting the distribution utility and of commodity service by contacting the ESCO. 12 Each provider contacted by the customer shall remind the customer of the need to contact the other provider to initiate the change in service or arrange for a conference call with the other provider and customer, and within two days, notify the other provider that a customer requested relocation of service. 2. The distribution utility’s representative shall inform the customer, or the customer’s agent, and the ESCO of the effective dates, contingent upon the customer’s approval, for discontinuance of service at one location and commencement of service at the new location. The ESCO shall confirm to the distribution utility that it shall continue service to the customer at the new location. 3. In the event that the ESCO is unable, or does not wish to continue service to the customer at the new location, the distribution utility shall provide full utility service to the customer. H. Customers Returning to Full Utility Service 1. A customer arranges for a return to full utility service by contacting either the ESCO or the distribution utility in accordance with this paragraph. An ESCO contacted by the customer shall, within two days, process the customer’s request to return to full utility service. A utility contacted by a customer shall remind the customer to contact the ESCO about their returning to full utility service provided, however, that if the customer has already contacted the ESCO or wants to proceed without contacting the ESCO, the utility shall, within two days, process the customer’s request to return to full utility service. If a change to full utility service results in restrictions on the customer’s right to choose another supplier or application of a rate that is different than the one applicable to other full service customers, the distribution utility shall provide advance notice to the customer.

12

In the Single Retailer Model, the customer contacts only its ESCO. The ESCO notifies the distribution utility of the customer’s new service location and mailing address, if applicable. Direct customers contact only the distribution utility.

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2. A Direct Customer that intends to change from procuring its own supplies to full utility service shall notify the distribution utility. 3. No ESCO shall transfer 5,000 or more customers during a billing cycle to full utility service, unless it provides no less than 60 calendar days notice to the distribution utility and Department. The transfers shall occur on the customers' regularly scheduled meter reading dates, unless the distribution utility and ESCO agree to a different schedule. 4. The following process sets forth the steps for an ESCO's return of a customer to full utility service. a. An ESCO may discontinue service to a customer and return the customer to full utility service provided that the ESCO notifies the customer and the distribution utility no later than 15 calendar days before the effective date of the drop. The ESCO’s right to discontinue service to any customer is subject to any limitations contained in its sales agreement. b. An ESCO’s notice to retail customers shall provide the following information: 1. Effective date of the discontinuance, established by the distribution utility, unless the ESCO arranged for an off-cycle date; 2. Statement that the customer has the option to select another ESCO, receive full utility service from the distribution utility, or, if available in the distribution utility’s service area and the customer is eligible, accept random assignment by the distribution utility to an ESCO; and, 3. Statement that customer shall receive full utility service until the customer selects a new ESCO and the change in providers is effective, unless the distribution utility notified the customer that it will terminate its delivery service on or before the discontinuance date. c. The ESCO shall provide a sample form of the notice it plans to send to its customers when it transfers 5,000 or more customers to the Department for review no later than five calendar days before mailing the notice to customers. I. New Delivery Customers 1. A customer may initiate distribution utility delivery service and subsequently enter into a customer agreement with an ESCO for commodity supply, or arrange for both services at the same time. 2. A customer may initiate commodity supply through programs offered by some distribution utilities that involve assignments of customers to ESCOs that have agreed to accept additional customers. 3. A customer may authorize an ESCO to act as the customer’s agent (ESCO agent) in establishing distribution utility service. The ESCO agent shall retain, and produce upon request, documentation that the customer authorized the ESCO to act as the customer’s agent.

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4. An ESCO acting as a customer’s agent shall establish a new delivery account on behalf of the customer and enroll the customer with the distribution utility so that ESCO commodity service commences when distribution utility delivery service begins. The ESCO shall retain, and produce upon request, documentation that the customer authorized the ESCO to act as the customer’s agent. An ESCO that is a customer’s agent is authorized to submit the customer’s application for new delivery service, in compliance with requirements for such applications stated in the law, rules and distribution utility tariffs. An ESCO shall provide the customer’s name, service address and, if different, mailing address, telephone number, customer’s requested service date for initiation of delivery service, and information about any special need customers, including any need for life support equipment. An ESCO shall refer a customer directly to a distribution utility for arrangement of distribution related matters, such as contribution-in-aid of construction and construction of facilities necessary to provide delivery service and settling of arrears and posting security. 5. Upon a customer's application for service, the distribution utility shall provide an ESCO with the effective date for initiation of delivery service and any other customer information provided to an ESCO in an acceptance of an enrollment request. The distribution utility may notify the customer of the acceptance. J. Multiple Assignments of Sales Agreements 1. An ESCO may assign all or a portion of its sales agreements to other ESCOs provided that the assigned sales agreements clearly authorize such assignments or the ESCO provides notice to its customers prior to the assignments and an opportunity for each customer to choose another ESCO or return to full utility service. An ESCO shall provide a written notice no later than 30 calendar days prior to the assignment or transfer date to each customer and distribution utility. The notice to the distribution utility shall include a copy of the assignment document, with financial information redacted, executed by the officers of the involved ESCOs, and a copy of the notice sent to the customer, or, if a form notice, a copy of the form and a list of recipients. 2. The assignment documents shall specify the party responsible for payment or reimbursement of any and all sums owed under any distribution utility tariff or Federal Energy Regulatory Commission tariff and any service agreements relating thereto, and under any agreements between ESCOs and distribution utilities and between ESCOs and their customers. 3. An ESCO’s notices to customers shall provide the following information: a. Effective date of the assignment; b. The name, mailing and e-mail addresses, and telephone number of the assigned ESCO; and, c. Any changes in the prices, terms and conditions of service, to the extent permitted by the sales agreement.

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4. The ESCO shall provide sample forms and any major modifications of such notices to the Department for review no later than five calendar days before mailing them to customers. 5. The distribution utility shall, within two business days after receipt of an assignment request, acknowledge and initiate processing of the request and send written notice of the request to the ESCO’s assigned customer. K. Unauthorized Customer Transfers 1. A change of a customer to another energy provider without the customer’s authorization, commonly known as slamming, is not permitted. The distribution utility shall report slamming allegations to the Department on at least a monthly basis. 2. An ESCO that engages in slamming shall refund to a customer the difference between charges imposed by the slamming ESCO that exceed the amount the customer would have paid its incumbent provider and pay any reasonable costs incurred by the distribution utility to change the customer’s provider from the ESCO that engaged in slamming to another provider. 3. ESCOs shall retain for two years or for the length of the sales agreement whichever is longer, documentation of a customer’s authorization to change providers. Such documentation shall comply with the requirements described in Attachments 1, 2 or 3. L. Lists of ESCO Customers, Budget Billing, Charges and Fees 1. A distribution utility, upon an ESCO’s request, shall provide at no charge, once each calendar quarter, a list of the ESCO’s customers at the time of the request and, monthly, the number of accounts enrolled with an ESCO and the ESCO's sales (kWh and/or dekatherms). ESCOs may obtain such customer lists at other times for cost-based fees set forth in distribution utility tariffs. 2. A distribution utility shall adjust its bills rendered under a budget billing plan on the effective date for changing a provider and include the adjustments in the customer’s next bill. 3. Upon enrollment of a distribution utility customer with an ESCO or return of an ESCO customer to full utility service, a distribution utility shall impose no restrictions on the number or frequency of changes of gas or electricity providers, except as provided in this paragraph. The distribution utility shall accept only one valid enrollment request for each commodity per customer during a switching cycle. If multiple requests are received for the same customer during a switching cycle, the distribution utility shall accept the first valid enrollment request and reject subsequent enrollment requests. 4. A distribution utility shall impose no charge for changing a customer’s gas or electricity provider. 5. A distribution utility may establish a $20 fee in its tariffs for a special meter reading.

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Attachment 1 Telephonic Agreement and Authorization Requirements A. To enter into a telephonic agreement with a customer to initiate service and begin enrollment or to obtain customer authorization for release of information, an ESCO or its agent, shall audio record the telephone conversation with the potential customer. The conversation shall contain the following information, as applicable, to substantiate the customer’s agreement or authorization: 1. A statement that the conversation is recorded and that oral acceptance of the ESCO’s offer is an agreement to initiate service and begin enrollment; 2. A description in plain language of the prices, terms and conditions of the ESCO’s offer, including a statement of the circumstances, if any, under which the ESCO may assess an early termination fee and the amount of any such assessment or how the assessment is calculated; 3. If savings are guaranteed, or guaranteed under only certain circumstances, the ESCO must provide a plain language description of the conditions that must be present in order for the savings to occur; 4. A statement from the ESCO that energy supply will be provided by the ESCO, and that energy delivery shall continue to be provided by the customer’s utility; and that said utility will also be available to respond to leaks or other emergencies should they occur; 5. A statement from the customer, in response to a question from a verification agent, accepting such terms and conditions; 6. A description of the types of information that the ESCO needs to obtain from a distribution utility or MDSP and the purposes of its use, a request that the customer provide authorization for release of this information, and effective the effective duration of the authorization; 7. A statement from the customer providing such authorization; 8. A statement in plain language that a customer will receive a written copy of the sales agreement by mail, e-mail or fax; that a residential customer may rescind the agreement within three business days after its receipt; how such rescission can be accomplished, and that in the absence of such rescission, an enforceable agreement will be created; a statement that a customer may rescind the authorization for release of information at any time; provision of a local or tollfree telephone number or e-mail address to the customer for these purposes; upon cancellation of the agreement, the ESCO shall provide a cancellation number to the customer during the telephone call or in response to an e-mail message; 9. A statement from the customer verifying the date and time of the telephone call; and 10. A statement from the customer providing or verifying the customer’s name, postal and any e-mail address (if the customer chooses to provide it), distribution -34-

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utility customer account number, and any additional information needed to verify the customer’s identity. B. The ESCO, or its agent, shall provide a copy of any Customer Disclosure Statement and sales agreement to the customer by mail, e-mail or fax within three business days after the telephone agreement and authorization occurs. The sales agreement shall set forth the customer’s rights and responsibilities and describe the offer in detail, including the specific prices, terms, and conditions of ESCO service. Such agreement shall be substantially the same, in form and content, as the sample contract submitted to the Department pursuant to Section 2.B.1.b. C. The ESCO, or its agent, shall conduct the telephone conversation in the same language used in marketing or sales materials presented to the customer, and communicate clearly and in plain language. D. An ESCO shall retain telephonic agreement and/or authorization records for two years from the effective date of the agreement and/or authorization or for the length of the sales agreement whichever is longer. In the event of any dispute involving a telephonic agreement or authorization, the ESCO shall make available the audio recording of the customer’s agreement and/or authorization within five business days after a request from the Department.

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Attachment 2 Electronic Agreement and Authorization Requirements A. To enter into an electronic agreement with a customer to initiate service and begin enrollment or to obtain customer authorization for release of information, an ESCO, or its agent, shall electronically record communications with the potential customer. An ESCO shall provide the following electronic information, as applicable, to substantiate the customer’s agreement and/or authorization: 1. A statement that electronic acceptance of a sales agreement is an agreement to initiate service and begin enrollment; 2. The Customer Disclosure Statement and the sales agreement containing the prices, terms and conditions applicable to the customer, which, if printed as a physical document, would be substantially the same, in form, and content, as the sample contract submitted to the Department pursuant to Section 2.B.1.b. 3. If savings are guaranteed, or guaranteed under only certain circumstances, the ESCO must provide a written statement which includes a plain language description of the conditions that must be present in order for the savings to be provided; 4. An identification number and date to allow the customer to verify the specific sales agreement to which the customer assents; 5. A statement from the ESCO that energy supply will be provided by the ESCO, and that energy delivery shall continue to be provided by the customer’s utility; and that said utility will also be available to respond to leaks or other emergencies should they occur; 6. A requirement that the customer accept or not accept the sales agreement by clicking the appropriate box, displayed as part of the terms and conditions; after the customer clicks the appropriate box to accept the sales agreement, the system shall display a conspicuous notice that the ESCO accepts the customer; 7. Use of an electronic process that prompts a customer to print or save the sales agreement and provides an option for the customer to request a hard copy of the sales agreement; an ESCO shall send the hard copy by mail within three business days after a customer’s request; 8. A description of the types of information that the ESCO needs to obtain from a distribution utility or MDSP and the purposes of its use, a request that the customer provide authorization for release of this information, and the effective duration of the authorization; 9. A requirement that the customer agree or not agree to provide such authorization by clicking the appropriate box, displayed as part of the terms and conditions; 10. A statement that a residential customer may rescind the agreement and authorization within three business days after electronic acceptance of the sales agreement; a statement that a customer may rescind the authorization for release -36-

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of information at any time; provision of a local or toll-free telephone number, and/or an e-mail address for these purposes; upon cancellation of the agreement, the ESCO shall provide a cancellation number; 11. Verification of the date and time of the electronic agreement and authorization; and 12. Provision by the customer of the customer’s name, address, distribution utility customer account number, and any additional information to verify the customer’s identify. B. The ESCO shall, within three business days of any final agreement to initiate service to a customer, send an electronic confirmation notice to the customer at the customer’s e-mail address. C. The ESCO shall use an encryption standard that ensures the privacy of electronically transferred customer information, including information relating to enrollment, renewal, re-negotiation, and cancellation. D. Upon request of a customer, the ESCO shall make available additional copies of the sales agreement throughout its duration. An ESCO shall provide a toll-free telephone number and e-mail address for a customer to request a copy of the sales agreement. E. An ESCO shall retain documentation of a customer’s agreement, in a retrievable format for two years from the effective date of the customer’s acceptance and/or authorization or for the length of the sales agreement whichever is longer. In the event of any dispute involving an electronic agreement or authorization, the ESCO shall provide a copy of the customer’s acceptance of the sales agreement and/or authorization for release of information or provide on-line access to the acceptance and/or authorization within five calendar days after a request from the Department.

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Attachment 3 Written Agreement and Authorization Requirements A. An ESCO may enter into a written agreement (original or fax copy of a signed document) with a customer to initiate service and begin enrollment or to obtain customer authorization for release of information. A sales agreement shall contain, in addition to the Customer Disclosure Statement discussed in UBP Section 2.B.1.b.2, the following information, as applicable: 1. A statement that a signature on a sales agreement is an agreement to initiate service and begin enrollment; 2. A description of the specific prices, terms, and conditions of ESCO service applicable to the customer, which is substantially the same, in form and content, as the sample contract submitted to the Department pursuant to Section 2.B.1.b and, if savings are guaranteed, or guaranteed under only certain circumstances, the ESCO must provide a plain language description of the conditions that must be present in order for the savings to be provided; 3. A description of the types of information that the ESCO needs to obtain from a distribution utility or MDSP, the purposes of its use, and effective duration of the authorization; 4. A statement that acceptance of the agreement is an authorization for release of such information; 5. A customer signature and date; the sales agreement shall be physically separate from any check, prize or other document that confers any benefit on the customer as a result of the customer’s selection of the ESCO; 6. A statement that a residential customer may rescind the agreement within three business days after signing the sales agreement; a statement that a customer may rescind the authorization for release of information at any time; provision of a local, toll-free telephone number, and/or e-mail address for these purposes; the customer may fax a copy of a signed sales agreement to the ESCO; upon cancellation of the agreement, the ESCO shall provide a cancellation number; and 7. The customer’s name, mail and any e-mail address (if the customer chooses to provide it), distribution utility account number, and any additional information to verify the customer’s identify. 8. A statement from the ESCO that energy supply will be provided by the ESCO, and that energy delivery shall continue to be provided by the customer’s utility; and that said utility will also be available to respond to leaks or other emergencies should they occur; B. ESCOs shall retain written agreements and/or authorizations for two years from the effective date of the agreement and/or authorization or for the length of the agreement whichever is longer. In the event of any dispute involving a sales agreement or

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authorization, the ESCO shall provide a copy of the sales agreement and/or authorization within five business days after a request from the Department.

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Attachment 4 Enrollment and Drop Requests Information Requirements A. An ESCO shall provide the following information for enrollment requests, and an ESCO or distribution utility shall provide the following information for drop requests: 1. Utility ID (DUNS# or tax ID); 2. ESCO ID (DUNS# or tax ID); 3. Commodity requested (electric or gas); and, 4. Customer’s utility account number (including check digit, if applicable). B. The following information is required for enrollment requests: 1. Customer’s bill option; 2. For distribution utility rate ready consolidated billing: a. an ESCO’s fixed charge, commodity price, sales and use tax rate or rate code; b. ESCO customer account number; c. budget billing status indicator; and, d. tax exemption percent and portion taxed as residential. 3. For Single Retailer Model: special needs indicator; 4. For gas service: gas capacity assignment/obligation indicator, and, if applicable, gas pool ID, gas supply service options, and human needs indicator; 5. For electric service: indicator for a partial requirements customer, if applicable. C. The following information is required for drop requests: 1. Reason for the drop; 2. For distribution utility request, service end date; 3. For ESCO initiated request, effective date of customer move, if applicable; and 4. For ESCO initiated request in Single Retailer Model, customer’s service and mailing address.

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SECTION 6

SECTION 6: CUSTOMER INQUIRIES
A. Applicability This Section establishes requirements for responses by an ESCO or distribution utility to retail access customer inquiries. An ESCO or distribution utility shall respond to customer inquiries sent by means of electronic mail, telecommunication services, mail, or in meetings. The subjects raised in inquiries may result in the filing of complaints. B. General 1. Distribution utilities and ESCOs shall provide consistent and fair treatment to customers. 2. Distribution utilities and ESCOs shall maintain processes and procedures to resolve customer inquiries without undue discrimination and in an efficient manner and provide an acknowledgement or response to a customer inquiry within 2 days and, if only an acknowledgement is provided, a response within 14 days. 3. Distribution utilities and ESCOs shall provide local or toll-free telephone access from the customer’s service area to customer service representatives (CSRs) responsible for responding to customer inquiries and complaints. 4. CSRs shall obtain information from the customer to access and verify the account or premises information. Once verification is made, the CSR shall determine the nature of the inquiry, and, based on this determination, decide whether the distribution utility or the ESCO is responsible for assisting the customer. 5. The CSR shall follow normal procedures for responding to inquiries. If the inquiry is specific to another provider’s service, the CSR shall take one of the following actions: a. Forward/transfer the inquiry to the responsible party; b. Direct the customer to contact the responsible party; or, c. Contact the responsible party to resolve the matter and provide a response to the customer. 6. Each distribution utility and ESCO shall maintain a customer service group to coordinate and communicate information regarding customer inquiries and designate a representative to provide information relating to customer inquiries to the Department. 7. ESCOs may provide a teletypewriter (TTY) system or access to TTY number, consistent with distribution utility tariffs.

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C. Specific Requests for Information 1. A distribution utility or ESCO shall respond directly to customer inquiries for any information that is related to commodity supply and/or delivery service, to the extent it has the necessary information to respond. 2. The entity responsible for the accuracy of meter readings shall respond to customer inquiries related to usage. 3. The distribution utility and ESCO shall respond to customer inquiries about billing and payment processing, in accordance with UBP Section 9, Billing and Payment Processing. D. Emergency Contacts 1. An emergency call means any communication from a customer concerning an emergency situation relating to the distribution system, including, but not limited to, reports of gas odor, natural disaster, downed wires, electrical contact, or fire. 2. The ESCO CSR shall transfer emergency telephone calls directly to the distribution utility or provide the distribution utility’s emergency number for direct contact to the distribution utility. If no ESCO CSR is available, the ESCO shall provide for after-hours emergency contacts, including transfer of emergency calls directly to a distribution utility or an answering machine message that includes an emergency number for direct contact to the distribution utility. 3. Each ESCO shall provide periodic notices or bill messages to its customers directing them to contact the distribution utility in emergency situations and providing the emergency number.

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SECTION 7

SECTION 7: DISTRIBUTION UTILITY INVOICES
A. Applicability This Section establishes procedures for invoices of charges for services provided by the distribution utility directly to an ESCO or Direct Customer. A distribution utility and ESCO or Direct Customer may agree to establish other arrangements and procedures for presentation and collection of invoices for services rendered. B. Invoices 1. An ESCO or Direct Customer shall pay the full amount due, without deduction, set-off or counterclaim, within 20 calendar days after the date of electronic transmittal or postmarked date (due date). Subsequent to the due date, charges are overdue and subject to late payment charges at the rate of 1.5% per month. The overdue charges include the amount overdue, any other arrears, and unpaid late payment charges. The distribution utility may provide, upon request, supporting or back-up data in electronic form, if available on its computer system. 2. A distribution utility shall provide interest at the rate of 1.5% on an overpayment caused by the distribution utility’s erroneous billing, provided that it may, without applying interest, credit all or a portion of the overpayment to the next bill issued within 30 days and/or refund all or a portion of the overpayment, upon request, within 30 days after its receipt. The distribution utility shall refund any credit balances, upon request. 3. An ESCO or Direct Customer shall make payments by means of an electronic funds transfer. A distribution utility shall use any partial payments first to pay any arrears and second to pay current charges. C. Billing Inquiries and Disputes 1. An ESCO or Direct Customer shall make any claims relating to inaccuracies of invoices in writing no later than 90 calendar days after the date of electronic transmittal or postmarked date. ESCOs and/or Direct Customers are responsible for payment of disputed charges during any pending dispute. 2. A distribution utility shall designate an employee and provide a telephone number and e-mail address for receipt of inquiries from an ESCO or Direct Customer relating to invoices. The employee shall direct an ESCO or Direct Customer that presents an inquiry or complaint to the responsible and knowledgeable person able to explain charges on an invoice. 3. A distribution utility shall acknowledge in writing receipt of an inquiry within five calendar days after its receipt. A distribution utility shall investigate and respond in writing to the inquiry within 20 calendar days after its receipt. 4. A distribution utility shall refund any overpayments, including interest, within five calendar days after it makes a determination that an ESCO or Direct Customer made an overpayment. It may provide the refund by applying a credit to any overdue amounts or making direct payment of any remainder. The - 43 -

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distribution utility shall provide refunds by means of an electronic funds transfer. Interest is calculated at the rate of 1.5 % per month from the date of the overpayment to the refund. 5. No interest is required on overpayments voluntarily made by an ESCO or Direct Customer to an account, unless an overpayment is applied to security.

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SECTION 8

SECTION 8: DISPUTES INVOLVING DISTRIBUTION UTILITIES, ESCOs OR DIRECT CUSTOMERS
A. Applicability This Section describes the dispute resolution processes available at the Department to resolve disputes relating to competitive energy markets involving utilities, ESCOs and/or Direct Customers, including disputes alleging anti-competitive practices. The processes are not available to resolve disputes between retail customers and ESCOs or distribution utilities. They are also not applicable to matters that, in the opinion of the Department Staff, should be submitted by formal petition to the Public Service Commission for its determination or are pending before a court, state or federal agency. The availability of the processes does not limit the rights of a distribution utility, ESCO or Direct Customer to submit any dispute to another body for resolution. B. Dispute Resolution Processes The parties shall in good faith use reasonable efforts to resolve any dispute before invoking any of these processes. Distribution utility tariffs and operating and service agreements between the parties shall identify the processes used to resolve disputes, and shall refer to the dispute resolution processes described in this Section as acceptable processes to resolve disputes. 1. Standard Process The parties shall use a method to send documents described in this paragraph that will verify the date of receipt. Any distribution utility, ESCO or Direct Customer may initiate a formal dispute resolution process by providing written notice to the opposing party and Department Staff. Such notice shall include a statement that the UBP dispute resolution process is initiated, a description of the dispute, and a proposed resolution with supporting rationale. Department Staff may participate in the process at this or any later point to facilitate the parties' discussions and to assist the parties in reaching a mutually acceptable resolution. a. No later than ten calendar days following receipt of the dispute description, if no mutually acceptable resolution is reached, the opposing party shall provide a written response containing an alternative proposal for resolution with supporting rationale and send a copy to Department Staff. b. No later than ten days after receipt of the response, if no mutually acceptable resolution is reached, any party or Department Staff may request that the parties schedule a meeting for further discussions. The parties shall meet no later than 15 calendar days following such request, upon advance notice to Department Staff, unless the parties and Department Staff agree upon another date. The Department may assign one or more Staff members to assist the parties in resolving the dispute.

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c. If no mutually acceptable resolution is reached within 40 calendar days after receipt of the written description of the dispute, any party may request an initial decision from the Department. A party to the dispute may appeal the initial decision to the Public Service Commission. d. If the parties reach a mutually acceptable resolution of the dispute, they shall provide to Department Staff a description of the general terms of the resolution. 2. Expedited Process In the event that an emergency situation arises to justify immediate resolution of a dispute, any party may file a formal dispute resolution request with the Secretary to the Public Service Commission asking for expedited resolution. An emergency situation includes, but is not limited to, a threat to public safety or system reliability or a significant financial risk to the parties or the public. The filing party shall provide a copy of the request to other involved parties and the Department Staff designated to receive information related to dispute resolution under this Section. The request shall describe in detail the emergency situation requiring expedited resolution, state in detail the facts of the dispute, and, to the extent known, set forth the positions of the parties.

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SECTION 9

SECTION 9: BILLING AND PAYMENT PROCESSING
A. Applicability This Section establishes requirements 13 for billing and payment processing options offered by a distribution utility and ESCO in a multi-retailer model. This Section does not establish requirements for billing and payment processing in the single retailer model. A distribution utility and ESCO shall comply with the requirements established in this Section, unless they agree upon modifications or other procedures for billing and payment processing in a Billing Services Agreement. B. Billing and Payment Processing Options: General Requirements 1. A distribution utility shall offer to ESCOs without undue discrimination the billing and payment processing options available in its service territory. 2. A customer participating in a retail access program shall select from the billing and payment processing options offered by ESCOs. 3. A distribution utility shall allow its customers to select, through their ESCOs, one of the billing and payment options available in the distribution utility’s service territory. An ESCO may offer to its customers billing and payment processing options available in the customer’s service territory and shall maintain or provide for the capability of issuing a separate bill for its services under the dual billing option. An ESCO customer may direct the billing party to send its consolidated bills or dual bills to a third party for processing and payment. 4. A distribution utility or ESCO may perform the responsibilities of a billing party for a customer and the other provider (non-billing party) based upon the billing and payment processing options available to the customer and the customer’s choice. 5. A distribution utility or MDSP shall make validated usage information available to the billing and non-billing parties at the time that the distribution utility or MDSP determines that the information is acceptable. 14 6. Information on customer usage, billing, and credit is confidential. A distribution utility or MDSP may release such information, upon a customer’s authorization, in accordance with the UBP Section 5, Changes in Service Providers. 7. A distribution utility and ESCO shall demonstrate the technical capability to exchange information electronically for their billing and payment processing options. 8. An ESCO shall provide 60 calendar days notice by mail, e-mail or fax to a distribution utility of any plan to offer a billing option that is not currently offered to its customers. The distribution utility may agree to a shorter notice period preceding initiation of the option. The 60 calendar-day notice shall not impose any obligation on any party to proceed without
13

14

The requirements are applicable when EDI is available upon issuance by the Commission of data standards applicable to a bill model and operational upon successful completion of the testing required for a bill model. A distribution utility or MDSP shall provide electronic interval data in summary form (billing determinants aggregated in the rating periods under a distribution utility’s tariffs) via EDI and, if requested, in detail via an acceptable alternative electronic format if retrieved from meters.

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a successful test of data exchange capability and the fulfillment of other obligations described in this Section. If an ESCO later changes its system, it shall provide adequate advance notice and conduct any additional testing required. 9. A distribution utility and an ESCO are responsible for separately remitting their tax payments to the appropriate taxing authorities. C. Consolidated Billing: General Requirements 1. A distribution utility and ESCO shall establish in a billing services agreement (BSA) detailed expectations for their responsibilities, including consequences for any failure to carry out such responsibilities. 2. A distribution utility may use the bill ready or rate ready method 15 for issuing consolidated bills. An ESCO that offers consolidated billing shall use a bill ready method. 3. A customer receiving delivery service from a distribution utility that is a combination natural gas and electric corporation (combination retail access customer) may receive a consolidated bill for both energy services if: a. The distribution utility issues the consolidated bill; b. One ESCO supplies the customer with both natural gas and electricity; c. An ESCO supplying only one of the commodities agrees to bill for charges for the service provided by the other ESCO; or, d. Separate distribution utility accounts are established for each service. 4. A combination retail access customer may receive separate consolidated bills for each commodity or a dual bill for one commodity and a consolidated bill for the other provided that the distribution utility’s system is capable of providing separate accounts for each commodity. A distribution utility shall establish bill cycles and payment due dates. A distribution utility may charge a fee, as set forth in its tariff, to an ESCO to establish, upon the ESCO’s request, a separate account for one of the commodities the distribution utility provides. D. Consolidated Billing: Functions and Responsibilities 1. A billing party shall perform the following functions and responsibilities: a. If the bill ready method is used, receive bill charges and other billing information from the non-billing party; b. If the rate ready method is used, receive rates, rate codes and/or prices (fixed and/or variable) and other billing information from the non-billing party; c. Receive bill messages and bill inserts from the non-billing party; d. If the bill ready method is used, acknowledge receipt of the non-billing party’s information and accept or reject it;

15

A distribution utility electing the rate ready method for utility consolidated billing is not obligated to calculate or bill separately for other goods and services that an ESCO may provide.

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e. If the rate ready method is used, 16 calculate billed charges, including sales and use taxes; the non-billing party is required to provide the customer’s sales and use tax rate to the billing party; f. Print or make available electronically consolidated bills that state the non-billing party’s charges, including taxes, arrearages, late fees, and bill messages; g. Insert in bill envelopes consolidated bills and inserts required by statute, regulation or Public Service Commission order; h. Stamp, sort and mail consolidated bills or, if authorized, transmit bills electronically; i. Cancel and rebill charges; j. Notify the non-billing party of amounts billed, by account, within two business days after rendering bills to customers; k. Receive and record customer payments; l. Allocate and transmit the non-billing party’s share of receipts, by account, to the nonbilling party; m. Respond to general inquiries and complaints about the bill and its format; refer customers to the non-billing party for inquiries and complaints related to the non-billing party’s rates, charges, services, or calculations; and, n. Maintain records of billing information, including amounts collected, remaining and transferred, and dates. 2. If the bill ready method is used, each party shall calculate and separately state sales and use taxes applicable to its charges; if the rate ready method is used, the billing party shall calculate and separately state the state sales and use taxes applicable to its charges and the non-billing party's charges. 3. A party that requires a customer’s deposit shall administer it. If a non-billing party applies a customer deposit to an outstanding balance, it shall notify the billing party. 4. Upon receipt of payments, a non-billing party shall notify the billing party. 5. To initiate consolidated billing using the rate ready method, the non-billing party shall provide the billing party with the rates, rate codes, and/or prices (fixed and/or variable) and tax rates necessary to calculate the non-billing party’s charges. The billing party shall specify in the BSA the number of prices for each service class per commodity accepted, deadline for transmission, effective date, and acceptable frequency of changes. 17 6. The billing party may process special handling requests from customers provided that it obtains agreement from the non-billing party for requests that affect it;

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17

A distribution utility is not required to calculate or bill for ESCO services that are not directly related to the commodity it delivers. If a billing party’s billing system is capable of providing the service, a billing party shall, upon request, apply a different rate, rate code, and/or price and tax rate to usage during different portions of the billing cycle to service provided after the effective date of the change. The non-billing party shall request a change in the rate, rate code, and/or price no later than four business days prior to the effective date requested.

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7. The billing party is not required to calculate or provide separate statements to customers regarding gross receipts taxes applicable to a non-billing party’s charges. The non-billing party may calculate and provide information on the gross receipts taxes applicable to its charges in a bill message or, if the bill ready method is used, as a line item on the bill. 8. The non-billing party may offer special billing features, such as budget billing or average payment plans. E. Consolidated Billing: Initiation, Changes or Discontinuance 1. Initiation a. An ESCO that proposes to issue consolidated bills shall establish and provide to a distribution utility written procedures for billing and payment processing that ensure billing accuracy and timeliness, proper distribution of a distribution utility’s bill messages and inserts, and proper allocation and transfer of distribution utility funds. b. No distribution utility may impose a fee on an ESCO to process its application to offer consolidated billing. 2. Changes A request to change a customer’s billing option shall be made on or before 15 calendar days prior to the scheduled meter reading date. 3. Suspension and Discontinuance a. A distribution utility may suspend or discontinue an ESCO’s right to offer consolidated billing as a billing party or a non-billing party for failure to comply with a BSA. Suspension of the right to offer consolidated billing means that the ESCO is prohibited from offering consolidated billing to new customers. b. Upon a determination by a distribution utility to suspend or discontinue an ESCO’s right to offer consolidated billing to customers, it shall provide notice on or before 15 calendar days prior to the proposed date for the suspension or discontinuance (cure period) to the ESCO and state the reason for its determination. Upon failure of the ESCO to correct the deficiency on or before the expiration of the cure period, the distribution utility may require a change to dual billing for the ESCO’s customers. c. Upon discontinuance of consolidated billing rights, an ESCO may reapply to the distribution utility to offer consolidated billing. A distribution utility shall expedite consideration of such requests. Customers may begin receiving consolidated bills again after requirements are satisfied, including submission of transaction requests to establish consolidated billing for customers. F. Consolidated Billing: Customer Requests 1. A customer may request an ESCO to change its billing option. The ESCO shall request the bill option change on or before 15 calendar days prior to the scheduled meter reading date. An EDI change request is used to request a change in a customer’s bill option. After receipt of the change request, a distribution utility shall, within one business day, acknowledge receipt of the request and, within two days, provide a response indicating rejection and the reason or acceptance and the effective date.

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2. No distribution utility may impose a charge on a customer or an ESCO for changing a billing option. 3. When more than one request to change a customer’s billing option is transmitted for a billing cycle, a billing party shall accept the last timely request received. 4. A distribution utility may deny a request to initiate consolidated billing or discontinue consolidated billing for a customer with an amount past due for at least 38 calendar days, unless the past due amount is subject to a DPA and the customer is fulfilling DPA obligations. G. Consolidated Billing: Content 1. A billing party may decide upon the format for its consolidated bill provided that it states a summary of total charges and separately states distribution utility and ESCO charges in sufficient detail to allow a customer to judge their accuracy. Such separate statements shall appear in clearly separated portions of the bill and identify their source, distribution utility or ESCO. An ESCO that provides consolidated billing shall state on its consolidated bill the unadjusted distribution utility charges for delivery services provided by a distribution utility, without change. 2. A consolidated bill shall contain the information listed in Attachment 1, General Information, preferably in a summary section. The billing party may place the information on the bill in any order or location. 3. A consolidated bill shall contain the information listed in Attachment 2, Distribution Utility Content, separately stated for each distribution utility. 4. A consolidated bill shall contain the information listed in Attachment 3, ESCO Content, separately stated for each ESCO. 5. If the rate ready method is used, the ESCO shall provide to the distribution utility information listed in Attachment 3, ESCO Section Content, to the extent necessary for the distribution utility to calculate and issue bills. To initiate utility consolidated billing using the rate ready method, an ESCO shall provide the information to the distribution utility on or before 15 calendar days prior to the scheduled meter reading date. An ESCO may request a price or rate change no later than four business days prior to its effective date. 6. If a billing party and non-billing party agree to show the non-billing party’s logo on the bill, the non-billing party shall provide it in an acceptable electronic format at least thirty days before its initial use. 7. If the rate ready method is used, a non-billing party is not required to provide information after it is initially submitted, except when a change is made. 8. When an ESCO issues a consolidated bill and the distribution utility transmits bill ready data, the distribution utility shall transmit to the ESCO at the appropriate time the applicable information listed in Attachment 2, Distribution Utility Content, items d – q, and the customer’s name and service address. 9. When an ESCO issues consolidated bills on behalf of other ESCOs and distribution utilities and the other ESCOs provide information, the non-billing ESCOs shall provide bill ready information listed in Attachment 3, ESCO Content to the billing ESCO.

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SECTION 9

10. No party shall engage in cramming. 11. A non-billing party may display its bill messages up to 480 characters in length on the bill provided that the billing party raises no reasonable objection to the message. There is no limit in message length for the billing party. If the bill ready method is used, the non-billing party shall transmit the text of the messages or agreed upon message codes in the same EDI transaction as the billed charges. If the rate ready method is used, a non-billing party shall submit a common bill message on or before 15 calendar days before the date used. Unless a final print date is provided, the billing party shall continue to print the message on bills until the non-billing party transmits a different message or requests its discontinuance. In emergencies requiring printing of messages on bills, the billing party shall accommodate the needs of the non-billing party, if practicable. 12. The billing party shall, in a timely manner, print on bills or insert into bill envelopes information that a statute, regulation, or Public Service Commission order requires a distribution utility or ESCO to send to its customers. The billing party may not assess charges for inclusion of required inserts that do not exceed one-half ounce. A distribution utility may charge for any excess weight in accordance with its tariff. The party responsible for providing the information shall submit it to the billing party. If the information is provided in a bill insert, the responsible party shall deliver the inserts in preprinted bulk form in a proper size on or before 15 calendar days before the date requested for initiation of distribution to customers to a location designated by the billing party. 13. Due dates and other general payment terms and conditions shall be identical for distribution utility and ESCO charges, unless different terms and conditions would have no impact on them. In the event of a conflict, the distribution utility’s payment terms and conditions shall govern. H. Consolidated Billing: Bill Issuance 1. No late charge may be applied to customers’ bills for distribution utility charges, if payment is received by the billing party within the grace period. 2. If the bill ready method is used, the non-billing party shall transmit its charges and other information to the billing party on or before two business days after receipt of valid usage data for a customer account. If the rate ready method is used, the non-billing party shall transmit any revisions in rate and/or price data to the billing party on or before four business days prior to the prescribed date. 3. If the bill ready method is used, a billing party that receives a non-billing party’s transaction within the prescribed time and rejects the transaction for cause shall, within one business day after receipt of the transaction, send the non-billing party an EDI reject transaction and state the reason for the rejection. The non-billing party may, if time permits, submit a corrected file containing billing charges for inclusion in the current billing statement. 4. If a non-billing party’s transaction is sent to the billing party outside the prescribed time frame, the billing party may reject the transaction and shall notify the non-billing party on or before two business days after its receipt that the charges were not billed. The non-billing party may resubmit its charges the following billing period in accordance with prescribed time limits and without late charges. If the bill ready method is used, the non-billing party may submit a separate bill to the customer and notify the billing party of the action. The - 52 -

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parties may also agree that the billing party shall hold the non-billing party’s charges for inclusion in the next bill. 5. If a non-billing party’s transaction is accepted using the bill ready method, the billing party shall render a bill within two business days after receipt of the transaction. If a rate ready method is used, a billing party shall render a bill in accordance with the distribution utility’s regular bill issuance schedule. A bill is rendered upon transfer to the custody of the U.S. Postal Service or other delivery service or, if authorized by a customer, sent electronically to a valid e-mail address or telefax number, displayed on a secure website, or presented directly to the customer or customer’s representative. 6. If the billing party has not purchased a non-billing party’s accounts receivable, is able to process the non-billing party’s transaction, and is unable to render a bill within the prescribed time, the billing party shall notify the non-billing party immediately. A billing party shall afford customers the same grace period to pay the bill. 7. If the rate ready method is used, the billing party shall provide to the non-billing party within two business days after bill issuance, a statement of the accounts billed, date of issuance and amount of the non-billing party’s charges shown on the bill (past due, current, and late payment charges and taxes). I. Consolidated Billing: Cancellations and Rebills 1. If non-billing party errors occur and are not corrected before the bill is issued, a billing party is not required to cancel bills or issue new bills. The non-billing party shall provide any necessary explanations to the customer and billing party and make any necessary adjustments on the next bill. 2. If billing party errors cause the non-billing party charges to miss the billing window, the billing party shall cancel and reissue the bills within two business days after notification, unless the billing party and non-billing party arrange an alternative bill correction process. 18 A billing party shall afford customers the same grace period to pay bills. 3. If no party errs, the parties may agree to cancel and rebill. 4. To cancel a bill, a billing party shall: a. Cancel usage by billing period; b. Send consumption in the cancel transaction that matches consumption sent in the original transaction; c. Send cancelled usage at the same level of detail as the original usage; d. Using the rate ready method, if a bill is to be cancelled and reissued, recalculate charges and issue revised bills to customers within two business days after receipt of the revised usage data; e. Using the bill ready method, if a bill is to be cancelled and reissued, issue the revised bill to customers within two business days after receipt of the revised usage data.

18

Such errors do not include usage-related adjustments necessary when an actual meter reading becomes available to replace an estimated reading required, for example, because a customer denies access to a meter.

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5. To restate usage for a period, the distribution utility or MDSP shall first cancel usage for that period and then send the full set of restatement transactions. J. Consolidated Billing: Payment Processing and Remittance 1. The parties shall set forth their responsibilities, performance parameters, financial arrangements and other details associated with payment processing and remittance in a BSA, subject to the requirements in this Section. a. In the Pay-as-You-Get-Paid Method, the billing party sends payments to the non-billing party, within two business days of receipt and posting of the funds and processes the payments in accordance with the required priority for application of payments established in this Section. b. A BSA shall establish procedures for processing payments made on any purchased accounts receivable. 2. Payment Processing a. The billing party shall notify the non-billing party that payment is received and send payments to the non-billing party, within two business days after receipt and posting, by use of Electronic Funds Transfer (EFT), Automated Clearing House (ACH), or similar means to banks or other entities as agreed upon by the parties. The notice shall include, in account detail, the payments received from customers, the date payments are posted, the date payments are transferred, and the amounts allocated to the non-billing party’s charges. b. The billing party may impose late payment charges on unpaid amounts not in dispute for the non-billing party provided the terms of the late payment charges are stated in a tariff or a sales agreement and previously disclosed to the customers. If the bill ready method is used, each party shall calculate its late payment charges. If the rate ready method is used, the billing party shall calculate the non-billing party’s late payment charges under terms agreed upon by the parties. If a customer’s check is returned for any reason, the billing party may charge the customer’s account for the return fee and any reasonable administrative fee. c. Upon failure of the billing party to pay the non-billing party its proper share of customer payments within two business days after their receipt and posting or at the time agreed upon when accounts receivable are purchased, the billing party shall pay interest on the unremitted amount. The billing party shall calculate the interest at the rate of 1.5 percent per month from the date the payment was due to be received by the non-billing party or its bank. 19 The payment of interest is in addition to, and not in lieu of, the rights and remedies otherwise available to the parties. 3. Collections The billing party is not responsible for collection of non-billing party funds, unless agreed to in a BSA.

19

Upon request, the billing party shall provide the non-billing party with a verified copy of the posting log of payments received and transferred to the non-billing party during any calendar month specified by the non-billing party.

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CASE 98-M-1343

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4. Application of payments a. The billing party 20 shall allocate customer payments to the following categories of charges on the bill or contained in a notice that are not in dispute in this order of priority of payment: (1) amounts owed to avoid termination, suspension or disconnection of commodity or delivery service; (2) amounts owed under a DPA, including installment payments and current charges; (3) arrears; and (4) current charges not associated with a DPA. The billing party shall pro-rate payments to the charges within each category in proportion to each party's charges in that category. After satisfaction of the charges in a category, assuming available funds, the remainder of the payment shall apply to the next highest category according to the priority of payments and in the same manner as described above until the payment is exhausted. b. The billing party may retain any payment amounts in excess of the amounts due as prepayments for future charges or return the excess amounts to customers. The billing party shall, in a timely manner, combine any excess payment amounts with the customer's payment on the next bill, and allocate and pro-rate the sum as set forth in Section 9.J.4.a. 21 c. When the billing or non-billing party enters into a multi-month payment agreement with a customer or waives any charges, that party shall notify the other party of such action. d. The billing party shall hold payments received without account numbers or enough information for the billing party to identify the accounts and attempt to obtain information to identify the payer. If sufficient information is not obtained to identify the account information prior to the next bill, the billing party shall present the unpaid amount and late charge, if applicable, on the bill. If the customer contacts the billing party to inquire about the late charge and the lack of payment credit, the billing party shall resolve the matter and reverse the late charges. The billing party shall notify the non-billing party of the matter and its resolution and then allocate payments as necessary to balance the account. 5. Multiple Account Payment Processing Processing of a single customer payment for multiple accounts requires proactive action on the part of the billing party and the non-billing party to apply payments correctly. The parties shall set forth arrangements for multiple account payment processing in a BSA. 6. Non-billing Party’s Balance a. Except as provided in Section 9.J.6 d., when a final bill is issued, the billing party shall maintain a current and past due balance for each account of the non-billing party until payment of the last bill issued for service provided by the non-billing party or 23 days
20

21

Distribution utilities supplying delivery service for both natural gas and electricity to customers receiving consolidated bills shall apply the receipts to the separate services in accordance with their regular procedures. Where a consolidated bill displays delivery charges for separate gas and electric distribution utilities, the customer’s payments shall be first prorated between the utility accounts in accordance with the amount each is due compared with the total amount due both distribution utilities. Where the customer elects to make a charitable donation, such as funding a low income program, satisfaction of the donation shall be made prior to allocation and pro-ration of the customer's excess payment.

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SECTION 9

after issuance of such bill, whichever is sooner. After such time, the account shall be considered “inactive.” b. Except as provided in Section 9.J.6 d., when a customer changes to a new ESCO, the billing party shall continue to receive and apply a customer’s payments for the active account of the prior ESCO. If the customer does not pay the outstanding balance owed to the prior ESCO on or before 23 days after the final bill containing the prior ESCO’s charges is issued, the billing party shall notify the ESCO and report the balance due. c. With regard to a new distribution utility/ESCO relationship following a change of ESCOs or a change in a distribution utility, the new billing party shall, upon request of the new non-billing party, bill for the balances that may exist at the time of the change. The new billing party may include the arrears on current bills or in a separate bill if its billing system is not capable of accepting prior charges. If a change of providers occurs, a distribution utility is not required to post any arrears of the prior ESCO on consolidated bills issued after the final billing of its charges, unless the arrears become the property of the new ESCO and it provides documentation of its property right to the distribution utility. d. Upon ESCO termination of the commodity supply of a residential customer due to failure to pay charges, the billing party shall maintain a current and past due balance for the account of the terminating ESCO for one year from the date of termination by the ESCO. In the event that the terminating ESCO seeks suspension of delivery service within one year of the termination, or the residential customer has a DPA, the billing party shall maintain a current and past due balance for each account of the terminating ESCO until the arrears are paid in full. 7. Customer Disputes: Initiating a Bill Complaint a. A customer or authorized representative may initiate a customer complaint regarding some or all of the charges on the customer’s bill at any time. b. When a complaint relates to the entire bill, to only the billing party’s charges or services, or, using the rate ready method, to calculation of the billing or non-billing party’s charges, the customer should contact the billing party. The billing party shall resolve the complaint and, if appropriate, place the customer’s account in dispute. In the event the inquiry concerns only a non-billing party’s bill, charges, services, or calculations, the billing party shall refer the customer to the non-billing party. 8. Customer Complaints: Notification a. Upon a determination that a complaint affects the entire bill, the billing party shall notify the non-billing party of the subject and amount in dispute, if known. b. The non-billing party shall inform the billing party of disputes related to non-billing party charges that would affect the billing process. c. Once such complaints are resolved and the billed amounts are no longer in dispute, the other party shall be notified.

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SECTION 9

K. Consolidated Billing: Call Centers A billing party shall provide call centers with toll-free or local telephone access available 24 hours a day and an answering machine or voice mail service during the hours when call center staff is not available. A billing party shall maintain adequate staff to respond to customers’ inquiries or refer inquiries to the non-billing party, where appropriate, within two business days. L. Dual Billing 1. The distribution utility and ESCO, acting as separate billing parties, shall render separate bills directly to the customer or the customer’s representative. The customer or its representative shall pay the distribution utility and the ESCO separately. 2. The distribution utility’s bill shall conform to the standards set by the Public Service Commission. 3. The distribution utility or MDSP shall transmit usage data to the ESCO at the time the information is available for rendering bills to customers, which may or may not coincide with meter reading cycle dates. 4. The ESCO may decide upon its bill format provided that it states its charges in sufficient detail to allow customers to judge the accuracy of their bills. At a minimum, an ESCO shall provide the following information: a. Customer’s name and billing address and, if different, service address; b. Customer’s account number or ID; c. Period or date associated with each product or service billed; d. Name of the entity rendering the bill; e. Address to which payments should be sent or the location where payments may be made; f. Local or toll free number for billing inquiries; if an ESCO enrolls and communicates with customers electronically, an e-mail address and telephone number with area code; g. Due date for payment and a statement that late payment charges shall apply to payments received after the due date; and h. Amount and date of payments received since the last bill. 5. Whenever a distribution utility or MDSP cancels consumption for an account, it shall provide a notice of cancellation and restated billing parameters for the account to an ESCO and a distribution utility, if applicable, and shall: a. Cancel usage by billing period; b. Send consumption in the cancel transaction that matches consumption sent in the original transaction; c. Send cancelled usage at the same level of detail as the original usage; and, d. To restate usage for a period, cancel usage for that period and send the full set of billing parameter restatements.

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Attachment 1 General Information A. Customer name B. Service address C. Billing address, if different than service address D. Billing party account number, if any E. Start of billing cycle period (prior meter reading date for metered customers) F. Starting period meter reading (for metered customers) G. End of billing cycle period (current meter reading date for metered customers) H. Ending period meter reading (for metered customers) I. Billing period metered usage, any multiplier necessary to convert usage to billing units and resulting billing units (for metered customers) J. Billing period demand, if applicable K. Indicators, if usage is estimated, actual or customer provided L. Total current charges (total of billing and non-billing party charges, including late charges and taxes) M. Total prior billed charges (total of billing and non-billing party prior bill charges, including prior late charges and taxes) N. Total credits since last bill (total of billing and non-billing party credits); O. Date through which the credits are applied P. Total current bill (total of billing and non-billing party charges plus prior bill charges less credits) Q. Billing party name (and billing party logo, if billing party wishes it shown) R. Billing party address S. Billing party toll-free or local telephone number, and for a billing party that enrolls and communicates electronically with customers, an e-mail address and telephone number with area code, in lieu of a toll-free or local telephone number T. Distribution utility toll free-or local telephone number and emergency telephone number U. Method and location for payments V. Date of bill W. Payment due date X. Billing party messages of any length that apply in general to the bill and services provided by billing and non-billing parties, that are not reasonably objectionable to the parties

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Attachment 2 Distribution Utility Content A. Distribution utility name, and logo, if the parties agree B. Distribution utility address, if the distribution utility is not the billing party C. Distribution utility toll-free or local telephone number for inquiries about the distribution utility portion of the bill, if the distribution utility is not the billing party, and distribution utility emergency number D. Distribution utility customer account number, if the distribution utility is not the billing party E. Distribution utility rate classification identifier F. Distribution utility rates per billing unit, if applicable G. Distribution utility rates not based on billing units, if applicable, and unbundled, if applicable H. Distribution utility charge adjustments and adders, separately stated I. Taxes on distribution utility charges, if separately stated J. Billing period total distribution utility charges K. Prior billing period total distribution utility charges, including any prior late charges L. Credits on prior distribution utility charges M. Net prior distribution utility balance remaining, unless included in total prior billed charges stated in the General Information Section N. Late charge for unpaid prior distribution utility balance, unless included in total prior billed charges stated in the General Information Section O. Total amount due for distribution utility services P. If a budget bill, applicable billing information and resulting budget bill amount due for distribution utility services Q. The distribution utility’s bill message, if any, up to 480 characters, if the distribution utility is not the billing party

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Attachment 3 ESCO Content A. ESCO name and logo, if parties agree B. ESCO address, if the ESCO is not the billing party C. ESCO toll-free or local telephone number for billing inquiries if the ESCO is not the billing party; ESCOs that enroll and communicate electronically with customer may provide an e-mail address and telephone number with area code in lieu of a toll-free or local telephone number; if a rate ready method is used, the billing party shall include a notice directing ESCO customers to call the billing party first to clarify bill calculations D. ESCO account number, if the ESCO is not the billing party and has a unique account number E. ESCO rate classification, if applicable F. ESCO rate per billing unit, if applicable G. ESCO rate not based on distribution utility unit, if applicable H. ESCO charge adjustments and adders, if any, separately stated I. Taxes on ESCO charges, if required to be separately stated J. Billing period total ESCO charges K. Prior billing period total ESCO charges, including any prior late charges, unless included in total prior billed charges stated in the General Information Section L. Credits on prior ESCO charges M. Net prior ESCO balance remaining N. Total amount due for ESCO services O. If a budget bill, applicable billing information and resulting budget bill amount due P. The ESCO’s bill message, if any, up to 480 characters, if the ESCO is the non-billing party.

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CASE 98-M-1343

SECTION 10

SECTION 10: MARKETING STANDARDS
A. Applicability This Section describes the standards that ESCOs and ESCO marketing representatives must follow when marketing to customers in New York. B. Training of Marketing Representatives ESCOs shall ensure that the training of their marketing representatives includes: 1. Knowledge of this Section and awareness of the other Sections of the New York Uniform Business Practices; 2. Knowledge of the ESCO’s products and services; 3. Knowledge of ESCO rates, payment options and the customers’ right to cancel, including the applicability of an early termination fee; 4. Knowledge of the applicable provisions of the Home Energy Fair Practices Act that pertains to residential customers; and, 5. The ability to provide the customer with a toll-free number from which the customer may obtain information about the ESCO’s mechanisms for handling billing questions, disputes, and complaints. C. Contact with Customers 1. In-Person Contact with Customers ESCO marketing representatives who contact customers in person at a location other than the ESCO’s place of business for the purpose of selling any product or service offered by the ESCO will, as soon as possible and prior to describing any products or services offered for sale by the ESCO: a. Produce identification, to be visible at all times thereafter, which: 1. Prominently displays in reasonable size type face the full name of the marketing representative; 2. Displays a photograph of the marketing representative and depicts the legitimate trade name and logo of the ESCO they are representing; 3. Provides the ESCO telephone number for inquires, verification and complaints. b. Shall identify the ESCO which they represent as an independent energy marketer, and shall identify him or herself as a representative of that specific ESCO. During the sales presentation, the marketing representative must also state that if customer purchases natural gas and/or electricity from the ESCO, that the customer’s utility will continue to deliver their energy and will respond to any leaks or emergencies. This requirement may be fulfilled either (a) by an oral statement by the ESCO marketing representative, or (b) written material left by the ESCO marketing representative. Further, ESCOs that are affiliates of distribution utilities should not describe or disclose their relationship to the distribution utility unless such information is specifically requested by the customer.

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c. Never represent that the ESCO marketing representative is an employee or representative or acting on behalf of a distribution utility. In addition, the ESCO marketing representative must clearly indicate that taking service from an ESCO will not affect the customer’s distribution service and such service will continue to be provided by the customer’s distribution utility; d. An ESCO marketing representative shall leave the premises of a customer when requested to do so by the customer or the owner or occupant of the premises. e. An ESCO marketing representative will provide the customer with written information regarding ESCO products and services immediately upon request which shall include the ESCOs name and telephone number for inquires, verification and complaints. f. Where it is apparent that the customer’s English language skills are insufficient to allow the customer to understand and respond to the information conveyed by the ESCO representative or where the customer or another third party informs the ESCO marketing representative of this circumstance, the ESCO marketing representative shall either find a representative in the area who is fluent in the customer’s language to continue the marketing activity in his/her stead or terminate the in-person contact with the customer. The use of translation services and language identification cards is permitted. 2. Telephone Contact with Customers ESCO marketing representatives who contact customers by telephone for the purpose of selling any product or service offered by the ESCO shall: a. Provide the ESCO marketing representative’s first name and, on request, the identification number; b. State the name of the ESCO on whose behalf the call is being made; c. Never represent that the ESCO marketing representative is an employee or representative or acting on behalf of a distribution utility. In addition, the ESCO marketing representative must clearly indicate that taking service from an ESCO will not affect the customer’s distribution service and such service will continue to be provided by the customer’s distribution utility; d. State the purpose of the telephone call; e. Where it is apparent that the customer’s English language skills are insufficient to allow the customer to understand and respond to the information conveyed by the ESCO representative or where the customer or another third party informs the ESCO marketing representative of this circumstance, the ESCO marketing representative will immediately transfer the customer to a representative who speaks the customer’s language, if such a representative is available, or terminate the call; and, f. Remove Customers’ names from the marketing database upon Customers’ request. 3. Conduct ESCOs shall: a. Not engage in misleading or deceptive conduct as defined by State or federal law, or by Commission rule, regulation or Order;

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SECTION 10

b. Not make false or misleading representations including misrepresenting rates or savings offered by the ESCO; c. Provide the customer with written information, upon request, or with a website address at which information can be obtained, if the customer requests such information via the internet; d. Use reasonable efforts to provide accurate and timely information about services and products. Such information will include information about rates, contract terms, early termination fees and right of cancellation consistent with Section 2 of the UBP and any other relevant Section; e. Ensure that any product or service offerings that are made by an ESCO contain information written in plain language that is designed to be understood by the customer. This shall include providing any written information to the customer in a language in which the ESCO representative has substantive discussions with the customer or in which a contract is negotiated; f. Investigate customer inquiries and complaints concerning marketing practices within five days of receipt of the complaint; and, g. Cooperate with the Department and PSC regarding marketing practices proscribed by the UBP and with local law enforcement in investigations concerning deceptive marketing practices. 4. Dispute Resolution ESCOs will maintain an internal process for handling customer complaints and resolving disputes arising from marketing activities and shall respond promptly to complaints forwarded by the Department.

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PSC NO: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: March 6, 2004

Addendum Type: SC13 Addendum Number: 1

New York State Electric & Gas Corporation (the Company) has requested trade secret protection pursuant to Public Officers Law Section 87.2(c) and (d) and Section 6-1.3 of the Commission’s Rules of Procedure (16NYCRR Section 6-1.3) for portions of the Individual Service Agreement between the Company and the Customer. APPLICABILITY Applicable to an individual Energy Service Agreement ("ESA") between New York State Electric & Gas Corporation ("NYSEG" or the "Company") and an eligible customer that applied to the Company for such service pursuant to NYSEG's Service Classification ("SC") No. 13 tariff, approved by the New York Public Service Commission (the "Commission") in its Order Approving Tariff Filing Subject To Conditions, issued and effective January 12, 1993 in Case 92-E-0893. This addendum complies with the Commission's Order Concerning Tariffs Authorizing Individually Negotiated Contracts, issued May 8, 1992 and its Order Denying Rehearing/Exemption and Granting Clarification, issued July 13, 1992, both Orders in Case 91-M-0927, and Opinion No. 94-15, issued July 11, 1994 in Case 92-M0229, and Opinion No. 96-12, issued July 24, 1998 in Case 96-E-0891, and any other applicable laws, regulations or Commission determinations. SERVICE DESCRIPTIONS AND CHARACTERISTICS The type of service provided for under the ESA is Continuous-Alternating Current, 60 cycle. The Customer will be served at [trade secret status has been sought for this information]. RATE The weighted average cost for the term of the ESA is [trade secret status has been sought for this information]. Customer is also required to pay its equitable share of: (a) any surcharge imposed pursuant to Paragraph 6 of the General Information section of P.S.C. No. 115 to reflect any taxes levied by the municipality in which Customer's manufacturing facility is located; and (b) any tax or surcharge imposed by any regulatory body or governmental entity on the capacity or energy, or its source, that otherwise would be borne by NYSEG. TERM [Trade secret status has been sought for this information.]

Issued by: James A. Lahtinen, Vice President – Rates & Regulatory Economics, Binghamton, NY

PSC NO: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: July 18, 2004

Addendum Type: SC13 Addendum Number: 2

New York State Electric & Gas Corporation (the Company) has requested trade secret protection pursuant to Public Officers Law Section 87.2(c) and (d) and Section 6-1.3 of the Commission’s Rules of Procedure (16NYCRR Section 6-1.3) for portions of the Individual Service Agreement between the Company and the Customer. APPLICABILITY Applicable to an individual Energy Service Agreement ("ESA") between New York State Electric & Gas Corporation ("NYSEG" or the "Company") and an eligible customer that applied to the Company for such service pursuant to NYSEG's Service Classification ("SC") No. 13 tariff, approved by the New York Public Service Commission (the "Commission") in its Order Approving Tariff Filing Subject To Conditions, issued and effective January 12, 1993 in Case 92-E-0893. This addendum complies with the Commission's Order Concerning Tariffs Authorizing Individually Negotiated Contracts, issued May 8, 1992 and its Order Denying Rehearing/Exemption and Granting Clarification, issued July 13, 1992, both Orders in Case 91-M-0927, and Opinion No. 94-15, issued July 11, 1994 in Case 92-M0229, and Opinion No. 96-12, issued July 24, 1998 in Case 96-E-0891, and any other applicable laws, regulations or Commission determinations. SERVICE DESCRIPTIONS AND CHARACTERISTICS The type of service provided for under the ESA is Continuous-Alternating Current, 60 cycle. The Customer will be served at [trade secret status has been sought for this information]. RATE The weighted average cost for the term of the ESA is [trade secret status has been sought for this information]. Customer is also required to pay its equitable share of: (a) any surcharge imposed pursuant to Paragraph 6 of the General Information section of P.S.C. No. 120 to reflect any taxes levied by the municipality in which Customer's manufacturing facility is located; and (b) any tax or surcharge imposed by any regulatory body or governmental entity on the capacity or energy, or its source, that otherwise would be borne by NYSEG. TERM [Trade secret status has been sought for this information.]

Issued by: James A. Lahtinen, Vice President – Rates & Regulatory Economics, Binghamton, NY

PSC NO: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: March 6, 2004

Addendum Type: SC14 Addendum Number: 1

New York State Electric & Gas Corporation (the Company) has requested trade secret protection pursuant to Public Officers Law Section 87.2(c) and (d) and Section 6-1.3 of the Commission’s Rules of Procedure (16NYCRR Section 6-1.3) for portions of the Individual Service Agreement between the Company and the Customer. APPLICABILITY Applicable to an individual Energy Service Agreement ("ESA") between New York State Electric & Gas Corporation ("NYSEG" or the "Company") and an eligible customer that applied to the Company for such service pursuant to NYSEG's Service Classification ("SC") No. 14 tariff, approved by the New York Public Service Commission (the "Commission") in its Order Approving Tariff Filing Subject To Conditions, issued and effective June 2, 1994 in Case 93-E-0990, and modified in its Order issued and effective January 18, 1996 in Case No. 95-E-1010. This addendum complies with the Commission's Order Concerning Tariffs Authorizing Individually Negotiated Contracts, issued May 8, 1992 and its Order Denying Rehearing/Exemption and Granting Clarification, issued July 13, 1992, both Orders in Case 91-M-0927, Opinion No. 94-15, issued July 11, 1994 in Case 92-M-0229, and Opinion No. 96-12, issued July 24, 1998 in Case 96-E-0891, and any other applicable laws, regulations or Commission determinations. SERVICE DESCRIPTIONS AND CHARACTERISTICS The type of service provided for under the ESA is Continuous-Alternating Current, 60 cycle. The Customer will be served at [trade secret status has been sought for this information]. RATE The weighted average cost for the term of the ESA is [trade secret status has been sought for this information]. Customer is also required to pay its equitable share of: (a) any surcharge imposed pursuant to Paragraph 6 of the General Information section of P.S.C. No. 120 to reflect any taxes levied by the municipality in which Customer's manufacturing facility is located; and (b) any tax or surcharge imposed by any regulatory body or governmental entity on the capacity or energy, or its source, that otherwise would be borne by NYSEG. TERM [Trade secret status has been sought for this information.]
Issued by: James A. Lahtinen, Vice President – Rates & Regulatory Economics, Binghamton, NY

PSC NO: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: April 18, 2004

Addendum Type: SC14 Addendum Number: 2

New York State Electric & Gas Corporation (the Company) has requested trade secret protection pursuant to Public Officers Law Section 87.2(c) and (d) and Section 6-1.3 of the Commission’s Rules of Procedure (16NYCRR Section 6-1.3) for portions of the Individual Service Agreement between the Company and the Customer. APPLICABILITY Applicable to an individual Energy Service Agreement ("ESA") between New York State Electric & Gas Corporation ("NYSEG" or the "Company") and an eligible customer that applied to the Company for such service pursuant to NYSEG's Service Classification ("SC") No. 14 tariff, approved by the New York Public Service Commission (the "Commission") in its Order Approving Tariff Filing Subject To Conditions, issued and effective June 2, 1994 in Case 93-E-0990, and modified in its Order issued and effective January 18, 1996 in Case No. 95-E-1010. This addendum complies with the Commission's Order Concerning Tariffs Authorizing Individually Negotiated Contracts, issued May 8, 1992 and its Order Denying Rehearing/Exemption and Granting Clarification, issued July 13, 1992, both Orders in Case 91-M-0927, Opinion No. 94-15, issued July 11, 1994 in Case 92-M-0229, and Opinion No. 96-12, issued July 24, 1998 in Case 96-E-0891, and any other applicable laws, regulations or Commission determinations. SERVICE DESCRIPTIONS AND CHARACTERISTICS The type of service provided for under the ESA is Continuous-Alternating Current, 60 cycle. The Customer will be served at [trade secret status has been sought for this information]. RATE The weighted average cost for the term of the ESA is [trade secret status has been sought for this information]. Customer is also required to pay its equitable share of: (a) any surcharge imposed pursuant to Paragraph 6 of the General Information section of P.S.C. No. 120 to reflect any taxes levied by the municipality in which Customer's manufacturing facility is located; and (b) any tax or surcharge imposed by any regulatory body or governmental entity on the capacity or energy, or its source, that otherwise would be borne by NYSEG. TERM [Trade secret status has been sought for this information.]
Issued by: James A. Lahtinen, Vice President – Rates & Regulatory Economics, Binghamton, NY

PSC NO: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: July 18, 2004

Addendum Type: SC14 Addendum Number: 3

New York State Electric & Gas Corporation (the Company) has requested trade secret protection pursuant to Public Officers Law Section 87.2(c) and (d) and Section 6-1.3 of the Commission’s Rules of Procedure (16NYCRR Section 6-1.3) for portions of the Individual Service Agreement between the Company and the Customer. APPLICABILITY Applicable to an individual Energy Service Agreement ("ESA") between New York State Electric & Gas Corporation ("NYSEG" or the "Company") and an eligible customer that applied to the Company for such service pursuant to NYSEG's Service Classification ("SC") No. 14 tariff, approved by the New York Public Service Commission (the "Commission") in its Order Approving Tariff Filing Subject To Conditions, issued and effective June 2, 1994 in Case 93-E-0990, and modified in its Order issued and effective January 18, 1996 in Case No. 95-E-1010. This addendum complies with the Commission's Order Concerning Tariffs Authorizing Individually Negotiated Contracts, issued May 8, 1992 and its Order Denying Rehearing/Exemption and Granting Clarification, issued July 13, 1992, both Orders in Case 91-M-0927, Opinion No. 94-15, issued July 11, 1994 in Case 92-M-0229, and Opinion No. 96-12, issued July 24, 1998 in Case 96-E-0891, and any other applicable laws, regulations or Commission determinations. SERVICE DESCRIPTIONS AND CHARACTERISTICS The type of service provided for under the ESA is Continuous-Alternating Current, 60 cycle. The Customer will be served at [trade secret status has been sought for this information]. RATE The weighted average cost for the term of the ESA is [trade secret status has been sought for this information]. Customer is also required to pay its equitable share of: (a) any surcharge imposed pursuant to Paragraph 6 of the General Information section of P.S.C. No. 120 to reflect any taxes levied by the municipality in which Customer's manufacturing facility is located; and (b) any tax or surcharge imposed by any regulatory body or governmental entity on the capacity or energy, or its source, that otherwise would be borne by NYSEG. TERM [Trade secret status has been sought for this information.]
Issued by: James A. Lahtinen, Vice President – Rates & Regulatory Economics, Binghamton, NY

PSC NO: 120 - Electricity New York State Electric & Gas Corporation Initial Effective Date: September 26, 2004

Addendum Type: SC14 Addendum Number: 4

New York State Electric & Gas Corporation (the Company) has requested trade secret protection pursuant to Public Officers Law Section 87.2(c) and (d) and Section 6-1.3 of the Commission’s Rules of Procedure (16NYCRR Section 6-1.3) for portions of the Individual Service Agreement between the Company and the Customer. APPLICABILITY Applicable to an individual Energy Service Agreement ("ESA") between New York State Electric & Gas Corporation ("NYSEG" or the "Company") and an eligible customer that applied to the Company for such service pursuant to NYSEG's Service Classification ("SC") No. 14 tariff, approved by the New York Public Service Commission (the "Commission") in its Order Approving Tariff Filing Subject To Conditions, issued and effective June 2, 1994 in Case 93-E-0990, and modified in its Order issued and effective January 18, 1996 in Case No. 95-E-1010. This addendum complies with the Commission's Order Concerning Tariffs Authorizing Individually Negotiated Contracts, issued May 8, 1992 and its Order Denying Rehearing/Exemption and Granting Clarification, issued July 13, 1992, both Orders in Case 91-M-0927, Opinion No. 94-15, issued July 11, 1994 in Case 92-M-0229, and Opinion No. 96-12, issued July 24, 1998 in Case 96-E-0891, and any other applicable laws, regulations or Commission determinations. SERVICE DESCRIPTIONS AND CHARACTERISTICS The type of service provided for under the ESA is Continuous-Alternating Current, 60 cycle. The Customer will be served at [trade secret status has been sought for this information]. RATE The weighted average cost for the term of the ESA is [trade secret status has been sought for this information]. Customer is also required to pay its equitable share of: (a) any surcharge imposed pursuant to Paragraph 6 of the General Information section of P.S.C. No. 120 to reflect any taxes levied by the municipality in which Customer's manufacturing facility is located; and (b) any tax or surcharge imposed by any regulatory body or governmental entity on the capacity or energy, or its source, that otherwise would be borne by NYSEG. TERM [Trade secret status has been sought for this information.]
Issued by: James A. Lahtinen, Vice President – Rates & Regulatory Economics, Binghamton, NY