ELECTRIC AND/OR GAS UTILITIES CLASSES A AND B ANNUAL REPORT

OF Niagara Mohawk Power Corporation Exact legal name of reporting electric and/or gas utility (If name was changed during year, show also the previous name and date of change)

300 Erie Boulevard West

Syracuse, New York 13202 (Address of principal business office at end of year)

FOR THE

Year ended 12/31/2009

TO THE

STATE OF NEW YORK

PUBLIC SERVICE COMMISSION

Name, title, address and telephone number (including area code), of the person to contact concerning this report:

Form 182-96 Annual Report of Niagara Mohawk Power Corporation Year ended 12/

Comment Sheet

Please use this sheet to record any changes you made to this file. If you altered this file in anyway, except by entering data, you must record those changes here. You may also use this sheet to make any comments about this file or the joint cost file.

Item Description Schedule Page Number Number Number

Comments Annual Report of Niagara Mohawk Power Corporation Year ended 12/31/2

GENERAL INSTRUCTIONS

1. The completed original of this report form, properly filled out, shall be filed with the Public Service Commission, Albany, NY, on or before the 31st of March next following the end of the year to which the report applies. At least one additional copy shall be retained in the files of the reporting utility.

2. All utility companies upon which this report form is served are required by statute to complete and to file the report. The statute further provides that when any such report is defective or believed to be erroneous, the reporting utility shall be duly notified and given a reasonable time within which to make the necessary amendments or corrections.

3. All accounting terms and phrases used in this form are to be interpreted in accordance with the Uniform Systems of Accounts prescribed by this Commission. Whenever the term respondent is used, it shall be understood to mean the reporting utility.

4. If the report is made for a period other than the calendar year, the period covered must be clearly stated on the front cover and elsewhere throughout the report where the period covered is shown. When operations cease during the year because of the disposition of property the balance sheet and supporting schedules should consist of balances and items immediately prior to transfer (for accounting purposes). If the books are not closed as of that date, the data in the report should nevertheless be complete and the amounts reported should be supported by information set forth in, or as part of the books of account.

5. Every inquiry must be definitely answered. If "none" or "not applicable" states the fact, such an answer may be used. The annual report should be complete in itself. Reference to reports of previous years or to any paper or document should not be made in lieu of required entries except as specifically outlined.

6. Upon filing, the report may, if desired, be permanently bound. If it is so bound, the requirement for page by page identification of the reporting company set forth in paragraph 9 below, may be disregarded. Extra copies of any page will be furnished upon request.

7. If the utility conducts operations both within and without the State of New York, data should be reported so that there will be shown the quantities of commodities sold within this State, and (separately by accounts) the operating revenues from sources within this State, the operating revenue deductions applicable thereto and the plant investment as of the end of the year within this State.

8. All entries shall be made in black or dark blue except those of a contrary or opposite nature, which should be made in red or enclosed in parentheses. Inserts, if any, should be appropriately identified with the schedules to which they relate.

9. Insert the initials of the reporting utility and the year which the report covers in the space provided on each page.

10. Cents are to be omitted on all schedules except where they apply to averages and figures per unit where cents are important. The amounts shown on all supporting schedules shall agree with the item in the statement they support.

NYPSC 182-95 Name of Respondent The report is Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 LIST OF SCHEDULES Enter in column (d) the terms "none," "not applicable," or "NA," as appropriate, where no information or amounts have been reported for certain pages. Omit pages where the respondents are "none," "not applicable," or "NA". Title of Schedule Reference Date Remarks Page No. Revised (a) (b) (c) (d) General Corporate Information and Financial Statements General Information 101 12-87 Control over Respondent 102 12-96 Corporations Controlled by Respondent 103 12-96 Officers and Directors 104-105 NYSPSC-95 Security Holders and Voting Powers 106-107 12-96 Important Changes During the Year 108-109 12-96 NYPSC Modified Comparative Balance Sheet 110-113 12-94 Statement of Income for the Year 114-117 12-96 Statement of Retained Earnings for the Year 118-119 12-96 Statement of Cash Flows 120-121 12-96 Notes to the Financial Statements 122-123 12-96

Balance Sheet Supporting Schedules (Assets and Other Debits)

Summary of Utility Plant and Accumulated Provision for Depreciation, Amortization, and Depletion 200-201 12-89 Nuclear Fuel Materials 202-203 12-89 Electric Plant in Service 204-207 12-95 Electric Plant Leased to Others 213 12-95 Electric Plant Held for Future Use 214 12-89 Construction Work in Progress 216 12-87 NYPSC Modified Construction Overheads 217 12-89 NYPSC Modified General Description of Construction Overheads Procedures 218 12-88 Accumulated Provision for Depreciation of Electric Plant 219 12-88 Non-Utility Property 221 12-95 Investment in Subsidiary Companies 224-225 12-89 Material & Supplies 227 12-96 Allowances 228-229 12-95 Extraordinary Property Losses 230 12-93 Unrecovered Plant and Regulatory Study Costs 230 12-93 Other Regulatory Assets 232 12-95 Miscellaneous Deferred Debits 233 12-94 Accumulated Deferred Income Taxes (Account 190) 234 12-88

Balance Sheet Supporting Schedules (Liabilities and Other Credits)

Capital Stock 250-251 12-91 NYPSC Modified Capital Stock Subscribed, Capital Stock Liability for Conversion, Premium on Capital Stock, and Installments Received on Capital Stock 252 12-95 NYPSC Modified Other Paid In Capital 253 12-87 NYPSC Modified Discount on Capital Stock 254 12-87 Capital Stock Expense 254 12-86 Long-Term Debt 256-257 12-96 NYPSC Modified

FERC FORM NO. 1 (ED. 12-96) NYPSC MODIFIED-97 Page 2 Name of Respondent The report is Date of Report Year of Report (1) [ ] An Original (Mo, Da, Yr) Niagara Mohawk Power Corporation (2) [ ] A Resubmission 6/01/2010 12/31/2009

LIST OF SCHEDULES (Continued)

Title of Schedule Reference Date Remarks Page No. Revised (a) (b) (c) (d) Balance Sheet Supporting Schedules (Liabilities and Other Credits) (Continued)

Reconciliation of Reported Net Income with Taxable Income for Federal Income Taxes 261 12-96 Taxes Accrued, Prepaid and Charged During the Year 262-263 12-96 NYPSC Modified Accumulated Deferred Investment Tax Credits 266-267 12-89 NYPSC Modified Other Deferred Credits 269 12-88 Accumulated Deferred Income Taxes - Accelerated Amortization 272-273 12-96 Accumulated Deferred Income Taxes - Other Property 274-275 12-96 Accumulated Deferred Income Taxes - Other 276-277 12-96 Other Regulatory Liabilities 278 12-94

Income Account Supporting Schedules

Electric Operating Revenues 300-301 12-96 Sales of Electricity by Rate Schedules 304 12-95 Sales for Resale 310-311 12-88 NYPSC Modified Electric Operation and Maintenance Expenses 320-323 12-95 Number of Electric Department Employees 323 12-93 Purchased Power 326-327 12-95 NYPSC Modified Transmission of Electricity for Others 328-330 12-90 NYPSC Modified Transmission of Electricity by Others 332 12-90 NYPSC Modified Miscellaneous General Expenses 335 12-94 NYPSC Modified Depreciation and Amortization of Electric Plant 336-337 12-95 Particulars Concerning Certain Income Deduction and Interest Charges Accounts 340 12-87 NYPSC Modified

Common Section

Regulatory Commission Expenses 350-351 12-96 NYPSC Modified Research, Development, and Demonstration Activities 352-353 12-87 Distribution of Salaries and Wages 354-355 12-88 Common Utility Plant and Expenses 356 12-87 NYPSC Modified

Electric Plant Statistical Data

Electric Energy Account 401 12-90 Monthly Peaks and Output 401 12-90 Steam - Electric Generating Plant Statistics (Large Plants) 402-403 12-95 Hydroelectric Generating Plant Statistics (Large Plants) 406-407 12-89 Pumped Storage Generating Plant Statistics (Large Plants) 408-409 12-88 Generating Plant Statistics (Small Plants) 410-411 12-87

FERC FORM NO. 1 (ED. 12-96) NYPSC MODIFIED-97 Page 3 Name of Respondent The report is Date of Report Year of Report (1) [ ] An Original (Mo, Da, Yr) Niagara Mohawk Power Corporation (2) [ ] A Resubmission 6/01/2010 12/31/2009

LIST OF SCHEDULES (Continued)

Title of Schedule Reference Date Remarks Page No. Revised (a) (b) (c) (d) Electric Plant Statistical Data (Continued)

Transmission Line Statistics 422-423 12-87 Transmission Lines Added During Year 424-425 12-86 Substations 426-427 12-96 Electric Distribution Meters and Line Transformers 429 12-88 Environmental Protection Facilities 430 12-88 Environmental Protection Expenses 431 12-88 Footnote Data 450 12-87 Stockholders' Reports Check appropriate box:

Two copies will be submitted

No annual report to stockholders is submitted

PSC Supplemental Filing 1-94 12-96

FERC FORM NO. 1 (ED. 12-96) NYPSC MODIFIED-97 Page 4 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 GENERAL INFORMATION 1. Provide the name and title of the officer having custody of the general corporate books of account and the address of the office where the general corporate books are kept, and the address of the officer where any other corporate books of account are kept, if different from that where the general corporate books are

Martin Wheatcrft - Controller The official books of record are kept at: National Grid USA Service Co. Niagara Mohawk - A National Grid Company One Metrotech Center 300 Erie Boulevard West Brooklyn, NY 11201 Syracuse, NY 13202

2. Provide name of the State under the laws of which respondent is incorporated, and date of incorporation. If incorporated under a special law, give reference to such law. If not incorporated, state that fact and give the type of organization and the date organized.

New York - Certificate of Consolidation filed January 5, 1950, pursuant to sections 26-a and 86 of the Stock Corporation Law and to Subdivision 4 of Section II of the Transportation Corporation Law of the State of New York.

3. If at any time during the year the property of respondent was held by a receiver or trustee, give (a) the name of the receiver or trustee, (b) the date such receiver or trustee took possession, (c) the authority by which the receivership or trusteeship was created, and (d) the date when possession by the receiver or

Not applicable.

4. State the classes of utility and other services furnished by respondent during the year in each State in which the respondent operated.

Purchase, transmission, distribution and sale of electricity and purchase, transmission, distribution and sale of natural gas in the State of New York.

5. Have you engaged as the principal accountant to audit your financial statements an accountant who is not the principal accountant for your previous year's certified financial statements?

(1) ____ Yes. Enter the date when such independent accountant was initially engaged: ______. (2) __X__ No.

FERC FORM NO.1 (ED. 12-87) Page 101 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 CONTROL OVER RESPONDENT

1. If any corporation, business trust, or company organization, show the chain of ownership similar organization or combination of or control to the main parent company or such organizations jointly held control organization. If control was held by a trustee(s), over the respondent at the end of the state the name of the trustee(s), name of the year, state the name of the controlling beneficiary or beneficiaries for whom the trust was corporation or organization, manner in maintained, and the purpose of the trust. which control was held and the extent of control. If control was in a holding

On March 18, 1999, Niagara Mohawk Power Corporation ("Niagara Mohawk") was reorganized into a holding company structure in accordance with an Agreement and Plan of Exchange between Niagara Mohawk and Niagara Mohawk Holdings, Inc. ("Holdings"). Niagara Mohawk's outstanding common stock was exchanged on a share-for-share basis for Holding's common stock making Niagara Mohawk a wholly-owned subsidiary of Holdings. Niagara Mohawk's preferred stock and debt were not exchanged as part of the share exchange and continue as obligations of Niagara Mohawk.

On January 30, 2002, Holdings was acquired by National Grid USA for approximately $3 billion in cash and American Depository shares in exchange for all of Holdings common outstanding shares. National Grid USA is a wholly owned subsidiary of National Grid plc.

FERC FORM NO. 1 (ED. 12-96) Page 102 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 CORPORATIONS CONTROLLED BY RESPONDENT

1. Report below the names of all 2. If control was by other means than a direct corporations, business trusts, and similar holding of voting rights, state in a footnote the manner organizations, controlled directly or indirectly in which control was held, naming any intermediaries by the respondent at any time during the involved. year. If control ceased prior to the end of the year, give particulars (details) in a footnote. 3. If control was held jointly with one or more other interests, state the facts in a footnote and name the other interests.

DEFINITIONS 1. See the Uniform System of Accounts for where the voting control is equally divided between two a definition of control. holders, or each party holds a veto power over the 2. Direct control is that which is exercised other. Joint control may exist by mutual agreement or without interposition of an intermediary. understanding between two or more parties who 3. Indirect control is that which is exercised together have control within the meaning of the by the interposition of an intermediary which definition of control in the Uniform System of Accounts, exercises direct control. regardless of the relative voting rights of each party. 4. Joint control is that in which neither interest can effectively control or direct action without the consent of the other, as Line Percent Voting Footnote No. Name of Company Controlled Kind of Business Stock Owned Ref. (a) (b) (c) (d) 1 2 NM Uranium, Inc. 3 (1) Owns 50% undivided interest in a jointly (1) 100 4 owned uranium mining venture (presently 5 in the reclamation stage in Live Oak 6 County, Texas.) 7 8 NM Properties, Inc. (2) 100 9 (2) A real estate subsidiary operating 10 exclusively in the State of New York that 11 owns 100% of Land Management and 12 Development, Inc., Landwest, Inc., 13 Riverview, Inc., Upper Hudson 14 Development, Inc., and 65 Willis Lane, Inc. 15 16 17 18 19 20 21 22 23 24 25 26 27 FERC FORM NO. 1 (ED. 12-96)

Page 103 Niagara Mohawk Power Corporation 12/31/2009

OFFICERS AND DIRECTORS (Including Compensation)

1. Furnish the indicated data with respect to each executive officer and director, whether or not they received any compensation from the respondent.

2. Executive officers include a company's president, secretary, treasurer and vice president in charge of a principal business unit, division or function (such as sales, administration, or finance), and any other person who performs similar policy making functions.

3. Indicate with an asterisk (*) in column (a) those directors who were members of the executive committee, if any, and by a double asterisk (**) the chairman, if any, of that committee, at the end of the year. Title and Department Term Expired Salary Line Over Which Jurisdiction or Current Rate at Paid During No. Name of Person Is Exercised Term Will Year End Year (a) (b) Expire (d) (e) (c) 1 Robert K. Schellberg Assistant Controller $154,785 2 Gregory Barone Assistant Secretary 156,295 3 Alfred C. Bereche Assistant Secretary 239,337 4 Timothy E. McAllister Assistant Secretary 205,000 5 James P. Meehan Assistant Secretary 174,000 6 David Charles Bonar Assistant Treasurer 7 Charles V. Derosa Assistant Treasurer 260,000 8 Lorraine Lynch Assistant Treasurer 168,000 9 Julie Vernon-Parry Assistant Treasurer 10 Thomas B. King President 1,050,000 11 Masheed H. Saidi Senior Vice President 309,000 12 Nickolas Stavropoulos Senior Vice President 445,667 13 Raymond C. Schlaff Senior Vice President 14 Malcolm Charles Cooper Treasurer 15 Paul J. Cianchetti Vice President 166,600 16 William E. Flynn Vice President 152,904 17 Mark Lissimoe Vice President 18 Kathy Lyford Vice President 166,595 19 Keith Mcafee Vice President 168,200 20 Gary W. Panebianco Vice President 177,003 21 Mary Ellen Paravalos Vice President 165,000 22 Ross Turrini Vice President 186,500 23 Martin Wheatcroft Vice President & Controller NOTES:

Please complete the information on this schedule for all copies (paper and electronic version) of the report.

A Salary paid by National Grid USA Service Company (an associated company) B Salary paid by National Grid plc (an associated company)

NYPSC 182-95 104 Niagara Mohawk Power Corporation 12/31/2009

OFFICERS AND DIRECTORS (Including Compensation - Continued)

4. If any person reported in this schedule received remuneration directly or indirectly other than salary shown in column (e) list the amount in column (f) through (k) with the footnotes necessary to explain the essentials of the plan, the basis of determining the ultimate benefits receivable and the payments or provisions made during the year to each person reported herein. If the word "none" correctly states the facts in regard to the entries for column (f) through (k), so state.

5. If any person reported hereunder received compensation from more than one affiliated company or was carried on the payroll of an affiliated company, details shall be given in a note.

Foot- Deferred Incentive Pay Savings Stock Life Insurance Other Total Line note Compensation (Bonuses, etc.) Plans Options Premiums (Explain Below) (e thru k) No. Ref. (f) (g) (h) (i) (j) (k) (l)

A $36,909 $112 $191,806 1 A 48,322 296 204,914 2 A 147,024 339 386,700 3 A 121,735 431 327,165 4 A 225 174,225 5 06 A 164,606 252 424,858 7 A 91,384 140 259,524 8 09 A 541,650 616,153 540 2,208,343 10 A 334,558 419,761 718 1,064,038 11 A 626,340 7,748 1,079,755 12 A 013 014 B 115,836 326 282,762 15 B 87,559 288 240,751 16 017 B 133,271 213 300,079 18 B 128,708 216 297,124 19 B 101,976 93,384 661 373,024 20 A 103,968 125 269,093 21 A 103,183 248 289,931 22 023 NOTES:

Column (f) Deferred Compensation represents Incentive Compensation Deferred.

NYPSC 182-95 105 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 SECURITY HOLDERS AND VOTING POWERS

1. Give the names and addresses of the 10 security explain in a footnote the circumstances holders of the respondent who, at the date of the latest clos- whereby such security became vested with voting rights and ing of the stock book or compilation of list of stockholders give other important particulars (details) concerning the voting of the respondent, prior to the end of the year, had the rights of such security. State whether voting rights are actual highest voting powers in the respondent, and state the or contingent; if contingent, describe the contingency. number of votes which each would have had the right to 3. If any class or issue of security has any special cast on that date if a meeting were then in order. If any privileges in the election of directors, trustees or managers, or such holder held in trust, give in a footnote the known in determination of corporate action by any method, explain particulars of the trust (whether voting trust, etc.), briefly in a footnote. duration of trust, and principal holders of beneficiary 4. Furnish particulars (details) concerning any options, interests in the trust. If the stock book was not closed or a warrants, or rights outstanding at the end of the year for list of stockholders was not compiled within one year prior others to purchase securities of the respondent or any securities to the end of the year, or if since the previous compilation or other assets owned by the respondent, including prices, of a list of stockholders, some other class of security has expiration dates, and other material information relating to become vested with voting rights, then show such 10 exercise of the options, warrants, or rights. Specify the amount security holders as of the close of the year. Arrange the of such securities or assets so entitled to be purchased by any names of the security holders in the order of voting power, officer, director, associated company, or any of the ten largest commencing with the highest. Show in column (a) the titles security holders. This instruction is inapplicable to convertible of officers and directors included in such list of 10 security securities or to any securities substantially all of which are out- holders. standing in the hands of the general public where the options, 2. If any security other than stock carries voting rights, warrants, or rights were issued on a prorata basis.

1. Give date of the latest closing of the stock book prior 2. State the total number of votes cast 3. Give the date and to end of year, and state the purpose of such closing: at the latest general meeting prior to place of such meeting: end of year for election of directors of the respondent and number of such votes cast by proxy. Total: By proxy: VOTING SECURITIES Line Number of votes as of (date): No. Name (Title) and Address of Security Total Common Preferred Holder Votes Stock Stock Other (a) (b) (c) (d) (e) 4 TOTAL votes of all voting securities 187,364,863 187,364,863 5 TOTAL number of security holders 1 1 6 TOTAL votes of security holders listed below 187,364,863 187,364,863 7 Niagara Mohawk Power Corporation ("Niagara Mohawk") has 187,364,863 shares outstanding, which are all 8 held by Niagara Mohawk Holdings, Inc. ("Holdings") and are not traded. 9 10 On July 11, 2003, Holdings, the sole shareholder of common stock of Niagara Mohawk, elected the Board 11 of Directors and appointed PricewaterhouseCoopers LLP as its auditor by written consent in lieu of an 12 annual meeting of shareholders, as permitted by the by-laws of the Corporation and by the New York 13 State Business Corporation Law. 14 15 16 17 18

FERC FORM NO. 1 (ED. 12-96) Page 106 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 SECURITY HOLDERS AND VOTING POWERS (Continued) Line Name (Title) and Address of Security Total Common Preferred No. Holder Votes Stock Stock Other (a) (b) (c) (d) (e) 19 Niagara Mohawk Holdings, Inc. 187,364,863 187,364,863 20 300 Erie Boulevard West 21 Syracuse, NY 13202 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53

FERC FORM NO.1 (ED. 12-96) Page 107 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 IMPORTANT CHANGES DURING THE YEAR Give particulars (details) concerning the matters indicated development, purchase contract or otherwise, giving location and below. Make the statements explicit and precise, and number approximate total gas volumes available, period of contracts, and them in accordance with the inquiries. Each inquiry should be other parties to any such arrangements etc. answered. Enter "none", "not applicable," or "NA" where 6. Obligations incurred as a result of issuance of securities or applicable. If information, which answers an inquiry, is given assumption of liabilities or guarantees including issuance of short- elsewhere in the report, make a reference to the schedule in term debt and commercial paper having a maturity of one year or which it appears. less. Give reference to FERC or State Commission authorization, as appropriate, and the amount of obligation or 1. Changes in and important additions to franchise rights: guarantee. Describe the actual consideration given therefore and state from whom the franchise rights were acquired. If acquired 7. Changes in articles of incorporation or amendments to without the payment of consideration, state that fact. charter: Explain the nature and purpose of such changes or amendments. 2. Acquisition of ownership in other companies by reorganization, merger, or consolidation with other companies: Give names of companies involved, particulars concerning the 8. State the estimated annual effect and nature of any transactions, name of the Commission authorizing the important wage scale changes during the year. transaction, and reference to Commission authorization.

3. Purchase or sale of an operating unit or system: Give a 9. State briefly the status of any materially important legal brief description of the property, and of the transactions relating proceedings pending at the end of the year, and the results of any thereto, and reference to Commission authorization, if any was such proceedings culminated during the year. required. Give date journal entries called for by the Uniform System of Accounts were submitted to the Commission. 10. Describe any materially important transactions of the 4. Important leaseholds (other than leaseholds for natural respondent, not disclosed elsewhere in this report, in which an gas lands) that have been acquired or given, assigned or officer, director, security holder reported on page 6, voting surrendered: Give effective dates, lengths of terms, names of trustee, associated company or known associate of such persons parties, rents, and other conditions. State name of Commission authorizing lease and give reference to such was a party or in which such person had a material interest.

5. Important extension or reduction of transmission or 11. (Reserved) distribution system: State territory added or relinquished and date operations began or ceased and give reference to 12. If the important changes during the year relating to the Commission authorization, if any was required. State also the respondent company appearing in the annual report to approximate number of customers added or lost and stockholders are applicable in every respect and furnish the data approximate annual revenues of each class of service. Each required by instructions 1 to 11 above, such notes may be natural gas company must also state major new continuing included on this page (Paper Copy Only). sources of gas made available to it from purchases,

PAGE 108 INTENTIONALLY LEFT BLANK. SEE PAGE 109 FOR REQUIRED INFORMATION.

FERC FORM NO.1 (ED. 12-96) NYPSC Modified-96 Page 108 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 IMPORTANT CHANGES DURING THE YEAR (Continued) 1. Changes in Franchise Rights:

None

2. Information on consolidations, mergers and reorganizations:

None

3. Purchase or sale of an operating unit or system:

None

4. Important leaseholds:

None

5. Important extension or reduction of transmission or distribution system:

None

6. Issuance of securities or assumption of liabilities or guarantees:

None

7. Changes in Articles of Incorporation:

None

8. Wage Scale Increase:

Calendar year 2009, non-union management employees received based rate increase averaging 1.5%

9. Status of Legal Proceedings:

Refer to Page 122 - Notes to Financial Statements - Note D - Commitments and Contingencies.

10. Additional Material Transactions Not Reported Elsewhere in this report:

None

11. Reserved:

None

FERC FORM NO.1 (ED. 12-96) NYPSC Modified-96 Page 109 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 COMPARATIVE BALANCE SHEET (ASSETS AND OTHER DEBITS) Ref. Balance at Balance at Line Title of Account Page No. Beg. of Year End of Year No. (a) (b) (c) (d) 1 UTILITY PLANT 2 Utility Plant (101-106, 114) 200-201 $8,208,859,480 $8,485,885,574 3 Construction Work in Progress (107) 200-201 113,401,293 209,726,174 4 TOTAL Utility Plant (Enter Total of lines 2 and 3) 8,322,260,773 8,695,611,748 5 (Less) Accum. Prov. for Depr. Amort. Depl. (108,111,115) 200-201 2,922,147,774 3,051,901,859 6 Net Utility Plant (Enter Total of line 4 less 5) - 5,400,112,999 5,643,709,889 7 Nuclear Fuel (120.1-120.4, 120.6) 202-203 0 0 8 (Less) Accum. Prov. for Amort. of Nucl. Fuel Assemblies (120.5) 202-203 0 0 9 Net Nuclear Fuel (Enter Total of line 7 less 8) - 0 0 10 Net Utility Plant (Enter Total of lines 6 and 9) - 5,400,112,999 5,643,709,889 11 Utility Plant Adjustments (116) 122 0 0 12 Gas Stored Underground - Noncurrent (117) - 0 0 13 OTHER PROPERTY AND INVESTMENTS 14 Nonutility Property (121) 221 11,312,576 10,985,343 15 (Less) Accum. Prov. for Depr. and Amort. (122) - 810,922 811,363 16 Investments in Associated Companies (123) - 0 0 17 Investment in Subsidiary Companies (123.1) 224-225 6,079,348 5,519,424 18 (For Cost of Account 123.1, See Footnote Page 224, line 42) - 19 Noncurrent Portion of Allowances - 0 0 20 Other Investments (124) 3,138,329 2,090,001 21 Special Funds (125-128) - 23,997,125 25,573,193 22 Derivative Instrument Assets (175) - 0 1,750 23 TOTAL Other Property and Investments (Total of lines 14-17, 19-21) 43,716,456 43,358,348 24 CURRENT AND ACCRUED ASSETS 25 Cash (131) - 18,899,039 8,338,978 26 Special Deposits (132-134) - 51,919,428 30,607,937 27 Working Fund (135) - 19,000 64,000 28 Temporary Cash Investments (136) - 0 0 29 Notes Receivable (141) 72,976 72,976 30 Customer Accounts Receivable (142) - 516,667,265 462,447,255 31 Other Accounts Receivable (143) - 27,226,956 31,894,296 32 (Less) Accum. Prov. for Uncollectible Acct.-Credit (144) - 165,548,900 173,735,300 33 Notes Receivable from Associated Companies (145) - 0 78,350,000 34 Accounts Receivable from Assoc. Companies (146) - 4,836,811 13,340,933 35 Fuel Stock (151) 227 0 0 36 Fuel Stock Expenses Undistributed (152) 227 0 0 37 Residuals (Elec) and Extracted Products (153) 227 0 0 38 Plant Materials and Operating Supplies (154) 227 30,472,776 31,396,604 39 Merchandise (155) 227 0 0 40 Other Materials and Supplies (156) 227 0 0 41 Nuclear Materials Held for Sale (157) 202-203/227 0 0 42 Allowances (158.1 and 158.2) 228-229 0 0 43 (Less) Noncurrent Portion of Allowances 228-229 0 0 44 Stores Expense Undistributed (163) - (202,231) 141,012 45 Gas Stored Underground - Current (164.1) - 147,545,128 63,998,984 46 Liquefied Natural Gas Stored and Held for Processing(164.2-164.3) - 0 0 47 Prepayments (165) - 21,288,517 384,221,020 48 Advances for Gas (166-167) - 0 0 49 Interest and Dividends Receivable (171) - 0 14,916 50 Rents Receivable (172) - 2,739,466 10,409,650 51 Accrued Utility Revenues (173) - 165,871,000 157,195,000 52 Miscellaneous Current and Accrued Assets (174) 2,287,740 1,299,032 53 Derivative Instrument Assets (175) 0 3,636,445 54 Derivative Instrument Assets- Hedges (176) 2,685,280 96,000 55 TOTAL Current and Accrued Assets (Enter Total of lines 24 thru 51) $826,780,251 $1,103,789,738

FERC FORM NO.1 (ED. 12-94) Page 110 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 COMPARATIVE BALANCE SHEET (ASSETS AND OTHER DEBITS) (Continued) Ref. Balance at Balance at Line Title of Account Page No. Beg. of Year End of Year No. (a) (b) (c) (d) 56 DEFERRED DEBITS 57 Unamortized Debt Expense (181) - $22,635,618 $25,982,764 58 Extraordinary Property Losses (182.1) 230 0 0 59 Unrecovered Plant and Regulatory Study Costs (182.2) 230 0 0 60 Other Regulatory Assets (182.3) 232 3,543,792,189 3,315,956,477 61 Prelim. Survey and Investigation Charges (Electric) (183) - 6,415,208 10,298,662 62 Prelim. Survey and Investigation Charges (Gas) (183.1, 183.2) - (206) 544 63 Clearing Accounts (184) - (3,289,445) 2,019,903 64 Temporary Facilities (185) - 0 0 65 Miscellaneous Deferred Debits (186) 233 21,946,204 2,721,255 66 Def. Losses from Disposition of Utility Plt. (187) - 0 0 67 Research, Devel. and Demonstration Expend. (188) 352-353 0 0 68 Unamortized Loss on Reacquired Debt (189) - 38,770,644 32,019,130 69 Accumulated Deferred Income Taxes (190) 234 988,443,965 1,049,954,541 70 Unrecovered Purchased Gas Costs (191) - 0 0 71 TOTAL Deferred Debits (Enter Total of lines 54 thru 67) 4,618,714,177 4,438,953,276 72 TOTAL Assets and Other Debits (Enter Total of lines 10, 11, 12, 22, 52, and 68) $10,889,323,883 $11,229,811,251

FERC FORM NO.1 (REVISED 12-93) Page 111 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 COMPARATIVE BALANCE SHEET (LIABILITIES AND OTHER CREDITS) Ref. Balance at Balance at Line Title of Account Page No. Beg. of Year End of Year No. (a) (b) (c) (d) 1 PROPRIETARY CAPITAL 2 Common Stock Issued (201) 250-251 $187,364,863 $187,364,863 3 Preferred Stock Issued (204) 250-251 28,984,700 28,984,700 4 Capital Stock Subscribed (202, 205) 252 0 0 5 Stock Liability for Conversion (203, 206) 252 0 0 6 Premium on Capital Stock (207) 252 0 0 7 Other Paid-in Capital (208-211) 253 1,645,136,034 1,624,008,331 8 Installments Received on Capital Stock (212) 252 0 0 9 (Less) Discount on Capital Stock (213) 254 0 0 10 (Less) Capital Stock Expense (214) 254 0 0 11 Retained Earnings (215, 215.1, 216, 219) 118-119 1,320,343,404 941,634,765 12 Unappropriated Undistributed Subsidiary Earnings (216.1) 118-119 (1,677,875) (1,737,800) 13 (Less) Reacquired Capital Stock (217) 250-251 0 0 14 TOTAL Proprietary Capital (Enter Total of lines 2 thru 13) - 3,180,151,126 2,780,254,859 15 LONG-TERM DEBT 16 Bonds (221) 256-257 236,305,000 1,486,305,000 17 (Less) Reacquired Bonds (222) 256-257 0 0 18 Advances from Associated Companies (223) 256-257 1,200,000,000 850,000,000 19 Other Long-Term Debt (224) 256-257 413,760,000 413,760,000 20 Unamortized Premium on Long-Term Debt (225) - 0 0 21 (Less) Unamortized Discount on Long-Term Debt-Debit (226) - 539,266 477,312 22 TOTAL Long-Term Debt (Enter Total of Lines 16 thru 21) - 1,849,525,734 2,749,587,688 23 OTHER NONCURRENT LIABILITIES 24 Obligations Under Capital Leases - Noncurrent (227) - 2,380,918 1,785,678 25 Accumulated Provision for Property Insurance (228.1) - 0 0 26 Accumulated Provision for Injuries and Damages (228.2) - 5,390,000 4,514,570 27 Accumulated Provision for Pensions and Benefits (228.3) - 0 0 28 Accumulated Miscellaneous Operating Provisions (228.4) - 0 0 29 Asset Retirement Obligations (230) - 11,184,635 10,448,955 30 TOTAL Other Noncurrent Liabilities (Enter Total of lines 24 thru 29) 18,955,553 16,749,203 31 CURRENT AND ACCRUED LIABILITIES 32 Notes Payable (231) - 0 0 33 Accounts Payable (232) - 272,614,652 243,436,478 34 Notes Payable to Associated Companies (233) - 722,700,000 0 35 Accounts Payable to Associated Companies (234) - 38,256,145 92,563,055 36 Customer Deposits (235) - 36,200,611 35,780,394 37 Taxes Accrued (236) 262-263 89,470,926 120,837,580 38 Interest Accrued (237) - 16,980,892 48,824,295 39 Dividends Declared (238) - 0 0 40 Matured Long-Term Debt (239) - 0 0 41 Matured Interest (240) - 0 0 42 Tax Collections Payable (241) - 22,859 1,508,421 43 Miscellaneous Current and Accrued Liabilities (242) - 120,329,872 103,230,839 44 Obligations Under Capital Leases - Current (243) - 595,242 595,242 45 Derivative Instrument Liabilities (244) - 52,759,939 53,556,040 46 Derivative Instrument Liabilities-Hedges (245) - 2,621,650 0 47 TOTAL Current and Accrued Liabilities (Enter Total of lines 32 - 44) $1,352,552,788 $700,332,344

M NO.1 (ED. 12-89) Page 112 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 COMPARATIVE BALANCE SHEET (LIABILITIES AND OTHER CREDITS) (Continued) Ref. Balance at Balance at Line Title of Account Page No. Beg. of Year End of Year No. (a) (b) (c) (d) 48 DEFERRED CREDITS 49 Customer Advances for Construction (252) $4,038,635 $4,161,224 50 Accumulated Deferred Investment Tax Credits (255) 266-267 30,081,597 27,063,097 51 Deferred Gains from Disposition of Utility Plant (256) 0 0 52 Other Deferred Credits (253) 269 1,502,651,885 1,642,148,980 53 Other Regulatory Liabilities (254) 278 532,709,484 585,233,843 54 Unamortized Gain on Reacquired Debt (257) 269 0 0 55 Accumulated Deferred Income Taxes (281 - 283) 272-277 2,418,657,081 2,724,280,013 56 TOTAL Deferred Credits (Enter Total of lines 47 thru 53) $4,488,138,682 $4,982,887,157 57 58 59 60 61 62 63 64 65 66 67 68 69 70 TOTAL Liabilities and Other Credits (Enter Total of lines 14, 22, 30, 45 and 54) $10,889,323,883 $11,229,811,251

Note: Please use the appropriate accounts under the heading "Other Noncurrent Liabilities" for accounts that the PSC classifies as "Operating Reserves".

FERC FORM NO.1 (REVISED 12-93) Page 113 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 STATEMENT OF INCOME FOR THE YEAR

1. Report amounts for accounts 412 and 413, Revenue and 5. Give concise explanations concerning unsettled rate proceedings Expenses from Utility Plant Leased to Others, in another utility where a contingency exists such that refunds of material amount may column (i, k, m, o) in a similar manner to a utility department. need to be made to the utility's customers or which may result in a Spread the amount(s) over lines 02 through 24 as appropriate. material refund to the utility with respect to power or gas purchases. Include these amounts in columns (c) and (d) totals. State for each year affected the gross revenues or costs to which the 2. Report amounts in account 414, Other Utility Operating contingency relates and the tax effects together with an explanation of Income, in the same manner as accounts 412 and 413. the major factors which affect the rights of the utility to retain such revenues or recover amounts paid with respect to power and gas 3. Report data for lines 7, 9, and 10 for Natural Gas companies purchases. using accounts 404.1, 404.2, 404.3, 407.1, and 407.2. 6. Give concise explanations concerning significant amount of any 4. Use page 122-123 for important notes regarding the statement refunds made or received during the year resulting of income or any account thereof. (Ref.) TOTAL Line Account Page Current Year Previous Year No. No. (a) (b) (c) (d) 1 UTILITY OPERATING INCOME 2 Operating Revenues (400) 300-301 $3,761,366,757 $4,238,567,840 3 Operating Expenses 4 Operation Expenses (401) 320-323 2,186,829,581 2,645,798,701 5 Maintenance Expenses (402) 320-323 199,748,730 211,847,416 6 Depreciation Expense (403) 336-337 221,459,832 214,549,533 7 Depreciation Expense for Asset Retirement Costs (403.1) 336-337 26,792 31,167 8 Amort. & Depl. of Utility Plant (404-405) 336-337 3,421,858 7,118,257 9 Amort. of Utility Plant Acq. Adj. (406) 336-337 36,913 36,913 10 Amort. of Property Losses, Unrecovered Plant and 0 Regulatory Study Costs (407) 00 11 Amort. of Conversion Expenses (407) 00 12 Regulatory Debits (407.3) 629,245,866 505,880,968 13 (Less) Regulatory Credits (407.4) 00 14 Taxes Other Than Income Taxes (408.1) 262-263 222,293,298 220,961,952 15 Income Taxes -- Federal (409.1) 262-263 (182,256,727) 103,732,435 16 -- Other (409.1) 262-263 (2,335,772) (2,293,626) 17 Provision for Deferred Income Taxes (410.1) 234,272-277 570,935,050 160,974,287 18 (Less) Provision for Deferred Income Taxes -Cr. (411.1) 234,272-277 331,621,377 193,532,563 19 Investment Tax Credit Adj. -- Net (411.4) 266 0 0 20 (Less) Gains from Disp. of Utility Plant (411.6) 0 0 21 Losses from Disp. of Utility Plant (411.7) 465,874 232,938 22 (Less) Gain from Disposition of Allowances (411.8) 0 0 23 Losses from Disposition of Allowances (411.9) 0 0 24 Accretion Expense (411.10) 0 (1,067,615) 25 TOTAL Utility Operating Expenses (Enter Total of lines 4 thru 22) 3,518,249,918 3,874,270,763 26 Net Utility Operating Income (Enter Total of line 2 less 23) (Carry forward to page 117, line 25) $243,116,839 $364,297,077

FERC FORM NO.1 (REV. 12-96) Page 114 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 STATEMENT OF INCOME FOR THE YEAR (Continued) from settlement of any rate proceeding affecting revenues received or costs 9. Explain in a footnote if the previous year's figures are different incurred for power or gas purrevenues received or costs incurred for power or from that reported in prior reports. gas purchases, and a summary of the adjustments made to balance sheet, 10. If the columns are insufficient for reporting additional utility income, and expense accounts. departments, supply the appropriate account titles, lines 2 to 23, and report the information in the blank space on page 122-123 or in 7. If any notes appearing in the report to stockholders are applicable to this a footnote. Statement of Income, such notes may be included on page 122-123.

8. Enter on page 122-123 a concise explanation of only those changes in accounting methods made during the year which had an effect on net income, including the basis of allocations and apportionments from those used in the preceding year. Also give the approximate dollar effect of such changes. Electric Utility Gas Utility Other Utility Current Year Previous Year Current Year Previous Year Current Year Previous Year Line No. (e) (f) (g) (h) (i) (j) 1 $2,977,100,572 $3,328,816,448 $783,670,115 $909,751,392 $596,070 2 3 1,587,891,964 1,928,960,979 598,937,617 716,837,722 4 165,763,799 178,714,903 33,984,931 33,132,513 5 180,215,295 173,793,702 41,244,537 40,755,831 6 11,430 15,017 15,362 16,150 7 3,105,977 6,265,247 315,881 853,010 8 36,913 36,913 0 0 9 10 00 00 00 00 11 620,192,521 505,880,968 9,053,345 0 12 00 00 13 175,731,018 174,801,369 46,562,280 46,160,583 14 (179,099,920) 126,345,070 (3,156,807) (22,612,635) 15 (1,666,694) (128,571) (669,078) (2,165,055) 16 570,600,032 145,182,705 335,018 15,791,582 17 331,385,619 195,966,857 235,758 (2,434,294) 18 00 00 19 00 00 20 395,993 197,997 69,881 34,941 21 00 00 22 00 00 23 0 (505,212) 0 (562,403) 24 2,791,792,709 3,043,594,230 726,457,209 830,676,533 0 0 25 26 $185,307,863 $285,222,218 $57,212,906 $79,074,859 $596,070 $0

FERC FORM NO.1 (REVISED 12-96) Page 115 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 STATEMENT OF INCOME FOR THE YEAR (Continued)

Other Utility Other Utility Other Utility Line Current Year Previous Year Current Year Previous Year Current Year Previous Year No. (k) (l) (m) (n) (o) (p) 1 2 3 4 5 6 7 8 9 10

11 12 13 14 15 16 17 18 19 20 21 22 23 24 25000000 26 $0 $0 $0 $0 $0 $0

FERC FORM NO. 1 (REVISED 12-96) Page 116 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 STATEMENT OF INCOME FOR THE YEAR (Continued) (Ref). TOTAL Line Account Page No. Current Year Previous Year No. (a) (b) (c) (d) 25 Net Utility Operating Income (Carried forward from page 114) - - $243,116,839 $364,297,077 26 OTHER INCOME AND DEDUCTIONS 27 Other Income 28 Nonutility Operating Income 29 Revenues From Merchandising, Jobbing and Contract Work (415) 0 0 30 (Less) Costs and Exp. of Merchandising, Job. & Contract Work (416) 0 0 31 Revenues From Nonutility Operations (417) 0 0 32 (Less) Expenses of Nonutility Operations (417.1) 11,431,331 2,626,384 33 Nonoperating Rental Income (418) 779,911 2,878,065 34 Equity in Earnings of Subsidiary Companies (418.1) 119 (59,924) (48,851) 35 Interest and Dividend Income (419) 4,152,622 3,250,575 36 Allowance for Other Funds Used During Construction (419.1) (384) 0 37 Miscellaneous Nonoperating Income (421) (252,629) (9,150) 38 Gain in Disposition of Property (421.1) 0 0 39 TOTAL Other Income (Enter Total of lines 29 thru 38) (6,811,735) 3,444,255 40 Other Income Deductions 41 Loss on Disposition of Property (421.2) 326,874 0 42 Miscellaneous Amortization (425) 340 0 0 43 Miscellaneous Income Deductions (426.1 - 426.5) 340 6,568,870 2,825,841 44 TOTAL Other Income Deductions (Total of lines 41 thru 43) 6,895,744 2,825,841 45 Taxes Applic. to Other Income and Deductions 46 Taxes Other Than Income Taxes (408.2) 262-263 874,645 810,643 47 Income Taxes -- Federal (409.2) 262-263 299,200 1,397,650 48 Income Taxes -- Other (409.2) 262-263 72,773 281,456 49 Provision for Deferred Inc. Taxes (410.2) 234,272-277 0 0 50 (Less) Provision for Deferred Income Taxes -- Cr. (411.2) 234,272-277 4,070,188 1,643,437 51 Investment Tax Credit Adj. -- Net (411.5) 0 0 52 (Less) Investment Tax Credits (420) 3,018,500 3,151,000 53 TOTAL Taxes on Other Income and Deduct. (Total of 46 thru 52) (5,842,070) (2,304,688) 54 Net Other Income and Deductions (Enter Total of lines 39, 44, 53) (7,865,409) 2,923,102 55 INTEREST CHARGES 56 Interest on Long-Term Debt (427) 27,781,051 68,854,681 57 Amort. of Debt Disc. and Expense (428) 2,023,893 2,986,731 58 Amortization of Loss on Reacquired Debt (428.1) 6,648,300 7,442,278 59 (Less) Amort. of Premium on Debt-Credit (429) 0 0 60 (Less) Amortization of Gain on Reacquired Debt-Credit (429.1) 60,460 60,460 61 Interest on Debt to Assoc. Companies (430) 340 51,905,743 66,591,577 62 Other Interest Expense (431) 340 25,512,951 10,907,586 63 (Less) Allowance for Borrowed Funds Used During Construction-Cr. (432) 797,204 2,403,155 64 Net Interest Charges (Enter Total of lines 56 thru 63) 113,014,274 154,319,238 65 Income Before Extraordinary Items (Total of lines 25, 54 and 64) 122,237,156 212,900,941 66 EXTRAORDINARY ITEMS 67 Extraordinary Income (434) 68 (Less) Extraordinary Deductions (435) 69 Net Extraordinary Items (Enter Total of line 67 less line 68) 0 0 70 Income Taxes -- Federal and Other (409.3) 262-263 71 Extraordinary Items After Taxes (Enter Total of line 69 less line 70) 0 0 72 Net Income (Enter Total of lines 65 and 71) $122,237,156 $212,900,941

FERC FORM NO.1 (ED. 12-96) Page 117 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 STATEMENT OF RETAINED EARNINGS FOR THE YEAR 1. Report all changes in appropriated retained earnings, 5. Show dividends for each class and series of capital stock. unappropriated retained earnings, and unappropriated undistributed subsidiary earnings for the year. 6. Show separately the State and Federal income tax effect of 2. Each credit and debit during the year should be identified as items shown in account 439, Adjustments to Retained Earnings. to the retained earnings account in which recorded (Accounts 433, 436 - 439 inclusive). Show the contra primary account 7. Explain in a footnote the basis for determining the amount affected in column (b). reserved or appropriated. If such reservation or appropriation is to 3. State the purpose and amount of each reservation or be recurrent, state the number and annual amounts to be reserved appropriation of retained earnings. or appropriated as well as the totals eventually to be accumulated. 4. List first account 439, Adjustments to Retained Earnings, 8. If any notes appearing in the report to stockholders are reflecting adjustments to the opening balance of retained applicable to this statement, include them on pages 122-123. earnings. Follow by credit, then debit items in that order. Contra Primary Line Item Account Amount No. Affected (a) (b) (c) UNAPPROPRIATED RETAINED EARNINGS (Account 216) 1 Balance -- Beginning of Year $1,322,282,327 2 Changes (Identify by prescribed retained earnings accounts) 3 Adjustments to Retained Earnings (Account 439) 4 Credit: 5 Credit: 6 Credit: 7 Credit: 8 Credit: 9 TOTAL Credits to Retained Earnings (Acct. 439) (Total of lines 4 thru 8) 0 10 Debit: 11 Debit: 12 Debit: 13 Debit: 14 Debit: 15 TOTAL Debits to Retained Earnings (Acct. 439) (Total of lines 10 thru 14) 0 16 Balance Transferred from Income (Account 433 less Account 418.1) 122,297,080 17 Appropriations of Retained Earnings (Account 436) 18 19 20 21 22 TOTAL Appropriations to Retained Earnings (Acct. 436) (Total of lines 18 thru 21) 0 23 Dividends Declared -- Preferred Stock (Account 437) 24 (3.4%=$195.6k); (3.6%=$493.7k); (3.9%=$371.2k) (1,060,497) 25 26 27 28 29 TOTAL Dividends Declared -- Preferred Stock (Acct. 437) (Total of lines 24 thru 28) (1,060,497) 30 Dividends Declared -- Common Stock (Account 438) 31 (500,000,000) 32 33 34 35 36 TOTAL Dividends Declared -- Common Stock (Acct. 438) (Total of lines 31 thru 35) (500,000,000) 37 Transfers from Acct. 216.1, Unappropriated Undistributed Subsidiary Earnings 38 Balance -- End of year (Total of lines 01, 09, 15, 16, 22, 29, 36 and 37) 943,518,910

FERC FORM NO. 1 (ED. 12-96) Page 118 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 STATEMENT OF RETAINED EARNINGS FOR THE YEAR (Continued) Line Item Amount No. (a) (b)

APPROPRIATED RETAINED EARNINGS (Account 215) State balance and purpose of each appropriated retained earnings amount at end of year and give accounting entries for any applications of appropriated retained earnings during the year.

39 Balance as of January 1, 2009 (1,938,923) 40 Unrealized Gains/Losses - Available for Sale 2,178,786 41 Minimum Pension Liability Adjustment 248,440 42 Deferred Gains/(Losses) on Hedging Activities - Future Gas Supply (2,372,448) 43 44 45 TOTAL Appropriated Retained Earnings (Account 215) (1,884,145)

APPROPRIATED RETAINED EARNINGS - AMORTIZATION RESERVE, FEDERAL (Account 215.1)

State below the total amount set aside through appropriations of retained earnings, as of the end of the year, in compliance with the provisions of Federally granted hydroelectric project licenses held by the respondent. If any reductions or changes other than the normal annual credits hereto have have been made during the year, explain such items in a footnote. 46 TOTAL Appropriated Retained Earnings -- Amortization Reserve, Federal(Account 215.1) 47 TOTAL Appropriated Retained Earnings (Account 215, 215.1) (Enter Total of lines 45 and 46) (1,884,145) 48 TOTAL Retained Earnings (Account 215, 215.1, 216) (Enter Total of lines 38 and 47) 941,634,765

UNAPPROPRIATED UNDISTRIBUTED SUBSIDIARY EARNINGS (ACCOUNT 216.1)

49 Balance -- Beginning of Year (Debit or Credit) (1,677,875) 50 Equity in Earnings for Year (Credit) (Account 418.1) (59,924) 51 (Less) Dividends Received (Debit) 52 Other Changes (Explain) 53 Balance -- End of Year (Total of Lines 49 thru 52) (1,737,799)

FERC FORM NO. 1 (ED. 12-96) Page 119 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 STATEMENT OF CASH FLOWS 1. If the notes to the cash flow statement in the respondents annual stockholders report are applicable to 3. Operating Activities -- Other: Include gains and losses pertaining this statement, such notes should be included on pages 122-to operating activities only. Gains and losses pertaining to investing 123. Information about noncash investing and financing and financing activities should be reported in those activities. Show activities should be provided on pages 122-123. Provide on page 122-123 the amounts of interest paid (net of amounts also on page 122 a reconciliation between "Cash and Cash capitalized) and income taxes paid. Equivalents at End of Year" with related amounts on the balance sheet. 2. Under "Other" specify significant amounts and group others.

Line Description (See Instructions for Explanations of Codes) Amounts No. (a) (b) 1 Net Cash Flow from Operating Activities: 2 Net Income (Line 72(c) on page 117) $122,237,156 3 Noncash Charges (Credits) to Income: 4 Depreciation and Depletion 224,945,395 5 Amortization of Regulatory debits 629,245,866 6 Amoritzation of Loss on Reacquired Debt 6,751,512 7 Amortization of Debt Discount and Expense 2,023,894 8 Deferred Income Taxes (Net) 235,243,486 9 Investment Tax Credit Adjustment (Net) (3,018,500) 10 Net (Increase) Decrease in Receivables 41,549,847 11 Net (Increase) Decrease in Inventory (1,267,071) 12 Net (Increase) Decrease in Allowances Inventory 13 Net Increase (Decrease) in Payables and Accrued Expenses 12,820,287 14 Net (Increase) Decrease in Other Regulatory Assets (401,410,154) 15 Net Increase (Decrease) in Other Regulatory Liabilities 52,524,359 16 (Less) Allowance for Other Funds Used During Construction 17 (Less) Undistributed Earnings from Subsidiary Companies (59,924) 18 Other: (230,037,940) 19 Net Increase (Decrease) in Deferred Credits 139,497,098 20 21 22 Net Cash Provided by (Used in) Operating Activities (Total of lines 2 thru 21) 831,165,159 23 24 Cash Flows from Investment Activities: 25 Construction and Acquisition of Plant (including Land): 26 Gross Additions to Utility Plant (less nuclear fuel) (415,617,624) 27 Gross Additions to Nuclear Fuel 28 Gross Additions to Common Utility Plant (8,321,954) 29 Gross Additions to Nonutility Plant 327,233 30 (Less) Allowance for Other Funds Used During Construction 31 Utility Plant Retirement cost (37,241,568) 32 33 34 Cash Outflows for Plant (Total of lines 26 thru 33) (460,853,913) 35 36 Acquisition of Other Noncurrent Assets (d) 37 Proceeds from Disposal of Noncurrent Assets (d) (527,300) 38 39 Investments in and Advances to Assoc. and Subsidiary Companies 500,000 40 Contributions and Advances from Assoc. and Subsidiary Companies 41 Disposition and Investments in (and Advances to) 42 Associated and Subsidiary Companies 43 44 Purchase of Investment Securities (a) 45 Proceeds from Sales of Investment Securities (a)

FERC FORM NO. 1 (ED. 12-96)

Page 120 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 STATEMENT OF CASH FLOWS (Continued) 4. Investing Activities 5. Codes used: Include at Other (line 31) net cash outflow to acquire other (a) Net proceeds or payments. companies. Provide a reconciliation of assets acquired with (b) Bonds, debentures and other long-term debt. liabilities assumed on pages 122-123. (c) Include commercial paper. (d) Identify separately such items as investments, fixed assets, intangibles, etc. Do not include on this statement the dollar amount of leases capitalized per USOA General Instruction 20; instead 6. Enter on pages 122-123 clarifications and explanations. provide a reconciliation of the dollar amount of leases capitalized with the plant cost on pages 122-123.

Line Description (See Instruction No. 5 for Explanations of Codes) Amounts No. (a) (b) 46 Loans Made or Purchased 47 Collections on Loans 48 49 Net (Increase) Decrease in Receivables 50 Net (Increase) Decrease in Inventory 51 Net (Increase) Decrease in Allowances Held for Speculation 52 Net Increase (Decrease) in Payables and Accrued Expenses 53 Other: 54 Decrease (Increase) in Special Deposits 21,311,491 55 56 Net Cash Provided by (Used in) Investing Activities 57 (Total of lines 34 thru 55) (439,569,722) 58 59 Cash Flows from Financing Activities: 60 Proceeds from Issuance of: 61 Long-Term Debt (b) 1,250,000,000 62 Preferred Stock 63 Common Stock 64 Other: 65 66 Net Increase in Short-Term Debt (c) 67 Other: 68 69 70 Cash Provided by Outside Sources (Total of lines 61 thru 69) 1,250,000,000 71 72 Payments for Retirement of: 73 Long-term Debt (b) (350,000,000) 74 Preferred Stock 75 Common Stock 76 Other: 77 78 Net Decrease in Short-Term Debt (c) (801,050,000) 79 80 Dividends on Preferred Stock (1,060,497) 81 Dividends on Common Stock (500,000,000) 82 Net Cash Provided by (Used in) Financing Activities 83 (Total of lines 70 thru 81) (402,110,497) 84 85 Net Increase (Decrease) in Cash and Cash Equivalents 86 (Total of lines 22, 57 and 83) (10,515,060) 87 88 Cash and Cash Equivalents at Beginning of Year 18,918,039 89 90 Cash and Cash Equivalents at End of Year $8,402,979 FERC FORM NO.1 (ED. 12-96) Page 121 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 NOTES TO FINANCIAL STATEMENTS 1. Use the space below for important notes regarding the and plan of disposition contemplated, giving reference to Balance Sheet, Statement of Income for the year, Commission orders or other authorizations respecting classification Statement of Retained Earnings for the year, Statement of of amounts as plant adjustments and requirements as to disposition Cash Flows, or any account thereof. Classify the notes thereof. according to each basic statement, providing a subheading for each statement except where a note is applicable to 4. Where Accounts 189, Unamortized Loss on Reacquired Debt, more than one statement. and 257, Unamortized Gain on Reacquired Debt, are not used, give 2. Furnish particulars (details) as to any significant an explanation, providing the rate treatment given these items. See contingent assets or liabilities existing at end of year, General Instruction 17 of the Uniform System of Accounts. including a brief explanation of any action initiated by the 5. Give a concise explanation of any retained earnings restrictions Internal Revenue Service involving possible assessment of and state the amount of retained earnings affected by such additional income taxes of material amount, or of a claim for restrictions. refund of income taxes of a material amount initiated by the utility. Give also a brief explanation of any dividends in 6. If the notes to financial statements relating to the respondent arrears on cumulative preferred stock. company appearing in the annual report to the stockholders are 3. For Account 116, Utility Plant Adjustments, explain the applicable and furnish the data required by instructions above and origin of such amount, debits and credits during the year, on pages 114-121, such notes may be included herein.

FERC FORM N0.1 (ED. 12-96) Page 122 Name of Respondent This Report is: Date of Report Year of Report Please fill in the following: (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 NOTES TO FINANCIAL STATEMENTS (Continued)

FERC FORM N0.1 (ED. 12-96) Next Page is 200 Page 123 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo., Day, Yr.) (2) [ ] A Resubmission 6/01/2010 12/31/2009 SUMMARY OF UTILITY PLANT AND ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION

Line Item Total Electric No. (a) (b) (c) 1 UTILITY PLANT 2 In Service 3 Plant in Service (Classified) $8,224,327,916 $6,178,639,653 4 Property Under Capital Leases 2,380,920 2,023,782 5 Plant Purchased or Sold 0 6 Completed Construction not Classified 255,772,921 204,020,861 7 Experimental Plant Unclassified 0 8 TOTAL (Enter Total of lines 3 thru 7) 8,482,481,757 6,384,684,296 9 Leased to Others 3,403,816 3,403,816 10 Held for Future Use 0 11 Construction Work in Progress 209,726,174 182,718,008 12 Acquisition Adjustments 0 13 TOTAL Utility Plant (Enter Total of lines 8 thru 12) 8,695,611,747 6,570,806,120 14 Accum. Prov. for Depr., Amort., & Depl. 3,051,901,859 2,310,218,855 15 Net Utility Plant (Enter Total of line 13 less 14) $5,643,709,888 $4,260,587,265 16 DETAIL OF ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION 17 In Service 18 Depreciation $2,969,237,349 $2,236,919,607 19 Amort. and Dep. of Producing Natural Gas Land and Land Rights 0 20 Amort. of Underground Storage Land and Land Rights 0 21 Amort. of Other Utility Plant 82,103,082 72,737,820 22 TOTAL In Service (Enter Total of lines 18 thru 21) 3,051,340,431 2,309,657,427 23 Leased to Others 24 Depreciation 561,428 561,428 25 Amortization and Depletion 0 26 TOTAL Leased to Others (Enter Total of lines 24 and 25) 561,428 561,428 27 Held for Future Use 28 Depreciation 0 29 Amortization 0 30 TOTAL Held for Future Use (Enter Total of lines 28 and 29) 0 0 31 Abandonment of Leases (Natural Gas) 0 32 Amort. of Plant Acquisition Adj. 0 33 TOTAL Accumulated Provisions (Should agree with line 14 above) $3,051,901,859 $2,310,218,855 (Enter Total of lines 22, 26, 30, 31 and 32)

FERC FORM NO.1 (ED. 12-89) Page 200 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo., Day, Yr.) (2) [ ] A Resubmission 6/01/2010 12/31/2009 SUMMARY OF UTILITY PLANT ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION Other (Specify) Other (Specify) Other (Specify) Gas ______Common Line (d) (e) (f) (g) (h) No. 1 2 $1,753,318,398 $292,369,865 3 357,138 4 5 34,877,884 16,874,176 6 7 1,788,553,420000309,244,041 8 9 10 14,497,120 12,511,046 11 12 1,803,050,540000321,755,087 13 638,982,672000102,700,332 14 $1,164,067,868 $0 $0 $0 $219,054,755 15 16

17 $629,617,410 $102,700,332 18 19 20 9,365,262 21 638,982,672000102,700,332 22 23 24 25 00000 26 27 28 29 00000 30 31 32 $638,982,672 $0 $0 $0 $102,700,332 33

FERC FORM NO.1 (ED. 12-89) Page 201 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo., Day, Yr.) (2) [ ] A Resubmission 6/01/2010 12/31/2009 NUCLEAR FUEL MATERIALS (Accounts 120.1 through 120.6 and 157) 1. Report below the costs incurred 2. If the nuclear fuel stock is obtained under leasing arrangements, for nuclear fuel materials in process of attach a statement showing the amount of nuclear fuel leased, the fabrication, on hand, in reactor, and in quantity used and quantity on hand, and the costs incurred under cooling; owned by the respondent. such leasing arrangements. Changes During Year

Line Description of Item Balance No. Beginning of Year Additions

(a) (b) (c) Nuclear Fuel in process of Refinement, 1 Conversion, Enrichment, & Fabrication (120.1) 2 Fabrication 3 Nuclear Materials 4 Allowance for Funds Used during Construction 5 (Other Overhead Construction Costs) 6 SUBTOTAL (Enter Total of lines 2 thru 5) 0 7 Nuclear Fuel Materials and Assemblies 8 In Stock (120.2) 9 In Reactor (120.3) 10 SUBTOTAL (Enter Total of lines 8 thru 9) 0 11 Spent Nuclear Fuel (120.4) 12 Nuclear Fuel Under Capital Leases (120.6) 13 (Less) Accum. Prov. for Amortization of Nuclear Fuel Assemblies (120.5) 14 TOTAL Nuclear Fuel Stock $0 (Enter Total of lines 6, 10, 11, and 12 less line 13) 15 Estimated net Salvage Value of Nuclear Materials in line9 16 Estimated net Salvage Value of Nuclear Materials on line 11 17 Estimated net Salvage Value of Nuclear Materials Chemical Processing 18 Nuclear Materials held for Sale (157) 19 Uranium 20 Plutonium 21 Other 22 TOTAL Nuclear Materials held for Sale $0 (Enter Total of lines 19, 20, and 21)

FERC FORM NO.1 (ED. 12-89) Page 202 Name of Respondent This Report is: Year of Report Date of Report Niagara Mohawk Power Corpora(1) [ ] An Original Mo., Day, Yr.) (2) [ ] A Resubmission 6/01/2010 12/31/2009 NUCLEAR FUEL MATERIALS (Accounts 120.1 through 120.6 and 157) (Continued)

Changes During Year Other Reductions Balance Line Amortization (Explain in a End of Year No. footnote) (d) (e) (f)

$0 1 02 03 04 05 06 7 08 09 010 011 012 013 014

15 16 17 018 019 020 021 $0 22

FERC FORM NO.1 (ED. 12-89) Page 203 Name of Respondent This Report Is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Day, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 ELECTRIC PLANT IN SERVICE (Accounts 101, 102, 103, and 106)

1. Report below the original cost of electric plant in service according to the prescribed accounts.

2. In addition to Account 101, Electric Plant in Service (Classified), this page and the next include Account 102, Electric Plant Purchased or Sold; Account 103, Experimental Electric Plant Unclassified; and Account 106, Completed Construction Not Classified - Electric.

3. Include in column (c) or (d), as appropriate, corrections of additions and retirements for the current or preceding year.

4. Enclose in parentheses credit adjustments of plant accounts to indicate the negative effect of such accounts.

5. Classify Account 106 according to prescribed accounts, on an estimated basis if necessary, and include the entries in column (c). Also to be included in column (c) are entries for reversals of tentative distributions of prior year reported in column (b). Likewise, if the respondent has a significant amount of plant retirements which have not been classified to primary accounts at the end of the year, include in column (d) a tentative distribution of such retirements, on an estimated basis, with appropriate contra entry to the account for accumulated depreciation provision. Include also in column (d) reversals of tentative distributions of prior year unclassified retirements. Show in a footnote the account distributions of these tentative classifications in columns (c) and (d), including the

Balance at Line Account Beginning of Year Addition No. (a) (b) (c) 1 1. INTANGIBLE PLANT 2 (301) Organization 3 (302) Franchises and Consents $77,175,727 4 (303) Miscellaneous Intangible Plant 5 TOTAL Intangible Plant (Enter Total of lines 2, 3, and 4) 77,175,727 0 6 2. PRODUCTION PLANT 7 A. Steam Production Plant 8 (310) Land and Land Rights 9 (311) Structures and Improvements 10 (312) Boiler Plant Equipment 11 (313) Engines and Engine-Driven Generators 12 (314) Turbogenerator Units 13 (315) Accessory Electric Equipment 14 (316) Misc. Power Plant Equipment 15 TOTAL Steam Production Plant (Enter Total of lines 8 thru 14) 0 0 16 B. Nuclear Production Plant 17 (320) Land and Land Rights 18 (321) Structures and Improvements 19 (322) Reactor Plant Equipment 20 (323) Turbo generator Units 21 (324) Accessory Electric Equipment 22 (325) Misc. Power Plant Equipment 23 TOTAL Nuclear Production Plant (Enter Total of lines 17 thru 22) 0 0 24 C. Hydraulic Production Plant 25 (330) Land and Land Rights 26 (331) Structures and Improvements 27 (332) Reservoirs, Dams, and Waterways 28 (333) Water Wheels, Turbines, and Generators 29 (334) Accessory Electric Equipment 30 (335) Misc. Power Plant Equipment 31 (336) Roads, Railroads, and Bridges 32 TOTAL Hydraulic Production Plant (Enter Total of lines 25 thru 31) 0 0 33 D. Other Production Plant 34 (340) Land and Land Rights 35 (341) Structures and Improvements 36 (342) Fuel Holders, Products, and Accessories 37 (343) Prime Movers 38 (344) Generators 39 (345) Accessory Electric Equipment

FERC FORM NO. 1 (REV. 12-95) Name of Respondent This Report Is: Date of Report Year of Report Niagara Mohawk Power Corp (1) [ ] An Original (Mo, Day, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 ELECTRIC PLANT IN SERVICE (Accounts 101, 102, 103, and 106) (Continued)

reversals of the prior years tentative account distributions of these amounts. Careful observance of the above instructions and the texts of Accounts 101 and 106 will avoid serious omissions of the reported amount of respondent's plant actually in service at end of year.

6. Show in column (f) reclassifications or transfers within utility plant accounts. Include also in column (f) the additions or reductions of primary account classifications arising from distribution of amounts initially recorded in Account 102. In showing the clearance of Account 102, include in column (e) the amounts with respect to accumulated provision for depreciation, acquisition adjustments, etc., and show in column (f) only the offset to the debits or credits distributed in column (f) to primary account classifications.

7. For Account 399, state the nature and use of plant included in this account and if substantial in amount submit a supplementary statement showing subaccount classification of such plant conforming to the requirements of these pages.

8. For each amount comprising the reported balance and changes in Account 102, state the property purchased or sold, name of vendor or purchaser, and date of transaction. If proposed journal entries have been filed with the Commission as required by the Uniform System of Accounts, give also date of such filing.

Balance at Retirements Adjustments Transfers End of Year Line (d) (e) (f) (g) No. 1 $0 (301) 2 77,175,727 (302) 3 0 (303) 4 0 0 0 77,175,727 5 6 7 0 (310) 8 0 (311) 9 0 (312) 10 0 (313) 11 0 (314) 12 0 (315) 13 0 (316) 14 000015 16 0 (320) 17 0 (321) 18 0 (322) 19 0 (323) 20 0 (324) 21 0 (325) 22 000023 24 0 (330) 25 0 (331) 26 0 (332) 27 0 (333) 28 0 (334) 29 0 (335) 30 0 (336) 31 000032 33 0 (340) 34 0 (341) 35 0 (342) 36 0 (343) 37 0 (344) 38 0 (345) 39

FERC FORM NO. 1 (REV. 12-88) Page 204

Name of Respondent This Report Is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Day, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 ELECTRIC PLANT IN SERVICE (Accounts 101, 102, 103, and 106) (Continued) Balance at Line Account Beginning of Year Additions No. (a) (b) (c) 40 (346) Misc. Power Plant Equipment 41 TOTAL Other Production Plant (Enter Total of lines 34 thru 40) 0 0 42 TOTAL Production Plant (Enter Total of lines 15, 23, 32, and 41) 0 0 43 3. TRANSMISSION PLANT 44 (350) Land and Land Rights 96,358,238 459,329 45 (352) Structures and Improvements 31,004,576 483,724 46 (353) Station Equipment 666,350,677 32,374,452 47 (354) Towers and Fixtures 133,237,659 (6,294,707) 48 (355) Poles and Fixtures 365,859,185 21,162,925 49 (356) Overhead Conductors and Devices 236,780,774 20,815,932 50 (357) Underground Conduit 29,049,970 281,904 51 (358) Underground Conductors and Devices 102,159,262 4,754,787 52 (359) Roads and Trails 2,348,571 (9,555) 53 TOTAL Transmission Plant (Enter Total of lines 44 thru 52) 1,663,148,912 74,028,791 54 4. DISTRIBUTION PLANT 55 (360) Land and Land Rights 19,576,009 6,406,835 56 (361) Structures and Improvements 35,412,715 43,227 57 (362) Station Equipment 460,290,035 14,504,103 58 (363) Storage Battery Equipment 59 (364) Poles, Towers, and Fixtures 788,801,034 45,399,525 60 (365) Overhead Conductors and Devices 875,984,992 42,326,931 61 (366) Underground Conduit 134,517,260 2,256,897 62 (367) Underground Conductors and Devices 415,936,368 18,850,655 63 (368) Line Transformers 691,656,257 28,579,464 64 (369) Services 395,566,012 16,963,059 65 (370) Meters 110,693,975 2,770,405 66 (371) Installations on Customer Premises 8,074,220 179,365 67 (372) Leased Property on Customer Premises 220 68 (373) Street Lighting and Signal Systems 189,772,802 11,912,881 69 (374) Assets Retirement Costs for Distribution Plant 116,000 70 TOTAL Distribution Plant (Enter Total of lines 55 thru 69) 4,126,397,899 190,193,347 71 5. GENERAL PLANT 72 (389) Land and Land Rights 2,487,206 28,237 73 (390) Structures and Improvements 89,809,731 642,444 74 (391) Office Furniture and Equipment 9,802,219 11,287 75 (392) Transportation Equipment 76 (393) Stores Equipment 2,143,249 77 (394) Tools, Shop and Garage Equipment 41,504,502 5,234,041 78 (395) Laboratory Equipment 20,437,793 371,762 79 (396) Power Operated Equipment 80 (397) Communication Equipment 75,923,661 41,009 81 (398) Miscellaneous Equipment 51,182,084 (134,518) 82 SUBTOTAL (Enter Total of lines 72 thru 81) 293,290,445 6,194,262 83 (399) Other Tangible Property 84 (399.1) Asset Retirement Costs for General Plant 467,500 85 TOTAL General Plant (Enter Total of lines 82, 83 and 84) 293,757,945 6,194,262 86 TOTAL (Accounts 101 and 106) (lines 5,15,23,32,41,53,69,83) 6,160,480,483 270,416,400 87 (102) Electric Plant Purchased (See Instr. 8) 88 (Less) (102) Electric Plant Sold (See Instr. 8) 89 (103) Experimental Plant Unclassified 90 TOTAL Electric Plant in Service (Enter Total of lines 84 thru 87) $6,160,480,483 $270,416,400

FERC FORM NO. 1 (REV. 12-94) Page 206 Page 205

Name of Respondent This Report Is: Date of Report Year of Report Niagara Mohawk Power Corp (1) [ ] An Original (Mo, Day, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 ELECTRIC PLANT IN SERVICE (Accounts 101, 102, 103, and 106) (Continued) Balance at Retirements Adjustments Transfers End of Year Line (d) (e) (f) (g) No. $0 (346) 40 000041 000042 43 3,930 96,813,637 (350) 44 3,442 31,484,858 (352) 45 5,805,477 $17,405 692,937,057 (353) 46 1,202,789 125,740,163 (354) 47 2,315,447 (4,037) 384,702,626 (355) 48 412,897 (1,254) 257,182,555 (356) 49 29,331,874 (357) 50 335,832 106,578,217 (358) 51 2,339,016 (359) 52 10,079,814 0 12,114 1,727,110,003 53 54 27,224 25,955,620 (360) 55 12,721 35,443,221 (361) 56 3,032,744 (17,405) 471,743,989 (362) 57 0 (363) 58 7,140,034 4,037 827,064,562 (364) 59 4,299,448 (550,334) 913,462,141 (365) 60 277,578 136,496,579 (366) 61 1,062,979 (1,644) 433,722,400 (367) 62 13,010,139 551,851 707,777,433 (368) 63 1,770,779 410,758,292 (369) 64 1,451,480 112,012,900 (370) 65 58,246 (272) 8,195,067 (371) 66 220 (372) 67 2,511,846 272 199,174,109 (373) 68 116,000 (374) 69 34,655,218 0 (13,495) 4,281,922,533 70 71 1,123 2,514,320 (389) 72 593,902 89,858,273 (390) 73 540,991 (47,269) 9,225,246 (391) 74 0 (392) 75 2,143,249 (393) 76 46,738,543 (394) 77 20,809,555 (395) 78 0 (396) 79 292,888 75,671,782 (397) 80 51,047,566 (398) 81 1,428,904 0 (47,269) 298,008,534 82 0 (399) 83 467,500 (399.1) 84 1,428,904 0 (47,269) 298,476,034 85 46,163,936 0 (48,650) 6,384,684,297 86 (102) 87 88 0 (103) 89 $46,163,936 $0 ($48,650) $6,384,684,297 90

FERC FORM NO. 1 (REV. 12-88) Next Page is 213 Page 207 Name of Respondent This Report Is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Day, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 ELECTRIC PLANT LEASED TO OTHERS (Account 104) 1. Report below the information called for concerning electric plant leased to others.

2. In column (c) give the date of Commission authorization of the lease of electric plant to others. Name of Lessee (Designate associated Expiration companies with a Description of Commission Date of Balance at Line double asterisk) Property Leased Authorization Lease End of Year No. (a) (b) (c) (d) 1 Mill Street Hydro Land and Water Rights 2/19/1919 12/14/2026 $105,000 2 Watertown, NY 3 Authorized by NYS PSC 4 Case 10150 5 6 Hydro Development Group, Inc. Hydroelectric Plant and Land 12/16/1993 12/31/2023 390,790 7 Rights 8 Theresa, NY 9 Authorized by NYS PSC 10 Case 28629 11 12 Hydro Development Group, Inc Hydroelecric Plant and Land 12/16/1993 12/31/2023 415,013 13 Rights, Watertown, NY 14 Authorized by NYS PSC 15 Case 28689 16 17 Union Falls Hydropower Hydroelectic Plant and Land 9/15/1986 6/30/2024 388,904 18 Limited Partnership Rights, Town of Black Brook, NY 19 Authorized by NYS PSC 20 Case 28689 21 22 Middle Falls Limited Partnership Hydroelectric Plant and Land 8/19/1988 4/25/2029 514,602 23 Rights, Town of Easton and 24 Greenwich 25 Authorized by NYS PSC 26 Case 88-E-087 27 28 South Glens Falls Limited Water and Land Rights 12/17/1991 9/20/2034 142,198 29 Partnership Village of South Glens Falls 30 Case 91-E-1119 31 32 Northern Electric Power Land and Water Rights, former 12/17/1991 11/20/2035 280,335 33 Company, L.P. Hudson Falls Hydro Station 34 Authorized by NYS PSC 35 Case 91-E-1119 36 37 Northern Electric Power Land and Water Rights, former 12/17/1991 11/20/2035 1,166,974 38 Company, L.P. Moreau Hydro Station 39 Town of Moreau 40 Authorized by NYS PSC 41 Case 91-E-1119 42 43 44 45 46 47 TOTAL $3,403,816

FERC FORM NO. 1 (ED. 12- 95) Page 213 Name of Respondent This Report Is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Day, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 ELECTRIC PLANT HELD FOR FUTURE USE (Account 105) 1. Report separately each property held for future use at end of the year having an original cost of $250,000 or more. Group other items of property held for future use. 2. For property having an original cost of $250,000 or more previously used in utility operations, now held for future use, give in column (a), in addition to other required information, the date that utility use of such property was discontinued, and the date the original cost was transferred to Account 105.

Date Originally Date Expected Balance at Description and Location Included in to be Used in End of Line of Property This Account Utility Service Year No. (a) (b) (c) (d) 1 Land and Rights: 2 3 4 5 6 8 9 10 11 12 13 14 15 16 17 18 19 20 21 Other Property: 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 TOTAL $0

FERC FORM NO.1 (ED. 12-89) Next Page is 216 Page 214 Name of Respondent This Report Is: Date of Report Year of Report Niagara Mohawk Power Corpora(1) [ ] An Original (Mo, Day, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 CONSTRUCTION WORK IN PROGRESS-ELECTRIC AND GAS (Account 107)

1. Report below descriptions and balances at end of the year for each projects in process, of construction (107). for Electric, Gas and Common, respectively. 2. Show items relating to "research, development, and demonstration" projects last, under a caption Research, Development, and Demonstration (see Account 107 of the Uniform System of Accounts). 3. Minor projects (5% of the Balance End of the Year for Account 107 or $100,000, whichever is less) may be grouped.

Construction Work in Line Description of Each Project for Electric, Gas and Common, respectively Progress-Electric/Gas (Account 107) No. (a) (b) 1Electric 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 From Insert Page 19 Subtotal $182,718,008 20 21 Gas 22 23 Distribution: C NY-Gas-Main Repl-Age-NM Blnk 2,086,718 24 E NY-Gas-Main Repl-Age-NM Blan 1,857,191 25 East NY-Gas-New Mtr Lg-NM Blan 1,615,077 26 NiMo GAS Meter Purchases 1,470,517 27 Misc 7,467,617 28 29 30 From Insert Page 31 Subtotal $14,497,120 32 33 Common 34 35 General: IN1041-NY EMS REPLACEMENT 3,756,853 36 Large SC3 Customers to RTP 2,180,754 37 Misc 6,573,439 38 39 40 41 From Insert Page 42 Subtotal $12,511,046 43 TOTAL $209,726,174

FERC FORM NO.1 (ED. 12- 87) NYPSC Modified-96 Page 216 If applicable, see insert page below Niagara Mohawk Power Corporation 6/01/2010 12/31/2009

CONSTRUCTION WORK IN PROGRESS-ELECTRIC AND GAS (Account 107)

ELECTRIC

TRANSMISSION: Capture RDV Costs-TSA,CoreTeam 5,322,703 Hudson - Replace TB4 1,644,844 Digital Fault Recorder Program 1,404,352 Clay Station 1,273,567 Lowville-Boonville #22 Rebuild 1,110,773 Fort Covington Protection Upgr 1,103,928 Akwesasne Station 115kV Engine 1,047,941 Tri-Lakes 46kV Subtransmission 27,704,282 Tri-Lakes 115kV Work 9,159,239 Packard(Paradise) 115 kV Break 5,692,167 New Gardenville-Repl TB3 & TB4 5,521,920 New Gardenville - TB2 Failure 4,181,355 Program - Remote Terminal Unit 4,066,790 Mobile Substations in NY 2,918,794 Oneida - TB#3 Failure 1,744,224 Packard - Replace TB3 & TB4 1,672,979 Station Failures - Transmissio 1,450,948 Paradise Station - Station Wor 1,439,437 Riv-Part #9 and #37 repl cable 1,030,861 Misc 30,938,923

DISTRIBUTION: Buffalo Indoor Sub. #29 Refurb 3,910,105 Buffalo Indoor Sub. #23 Refurb 3,782,024 Buffalo Indoor Sub. #43 Refurb 3,718,948 Buffalo Indoor Sub. #52 Refurb 3,578,046 Cent NY-Dist-Asset Replace Bla 2,274,153 DA Dist. line Central Div 1,937,135 Buffalo Sta. 63 bank replaceme 1,254,563 Riverside TB2 - Repl. Failed T 2,186,562 I&M - NE D-Line OH Work From I 2,080,760 Replace Metal Clad at Springfi 1,815,340 NY RTU Program - DxT Subs 1,555,636 Metering Data Comm Transition 1,490,266 East NY-Dist-Reliability Blank 1,189,019 NiMo Transformer Purchases 1,088,390 East NY-Dist-Subs Blanket 1,034,033 Misc 30,870,850

GENERAL: Cent NY-General-Genl Equip Bla 2,158,848 Telecom and Radio Equipment 2,650,231 West NY-General-Genl Equip Bla 1,090,830 Misc 2,622,242

Total Electric $182,718,008

FERC FORM NO.1 (ED. 12- 87) NYPSC Modified-96 Page 216-A Name of Respondent This Report Is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Day, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 CONSTRUCTION OVERHEADS ELECTRIC, GAS AND COMMON

1. List in column (a) the kinds of overheads according to the titles used by the respondent. Charges for outside professional services for engineering fees and management or supervision fees capitalized should be shown as separate items.

2. On page 218 furnish information concerning construction overheads, for electric, gas and common operations respectively.

3. A respondent should not report "none" to this page if no overhead apportionments are made, but rather should explain on page 218, the accounting procedures employed and the amounts of engineering, supervision and administrative costs, etc., which are directly charged to construction, for electric, gas and common operations respectively.

4. Enter on this page engineering, supervision, administrative, and allowance for funds used during construction, etc., which are first assigned to a blanket work order and then prorated to construction jobs for electric, gas and common operations respectively.

Total Amount Charged Line Description of Overhead for the Year No. (a) (b)

1Electric 2 3 Engineering, Supervision, and Administration 101,073 4 Allowances for Funds Used During Construction 745,932 5 Payroll Taxes 6,887,540 6 Compensation Insurance 886,175 7 Pension Costs 15,959,876 8 Employee Insurance Benefit Plan 863,880 9 Medical Care Plan 8,149,738 10 Employee Savings Fund Plan 1,833,332 11 12 13 14 15 16 17 18 From Insert Pages 19 Subtotal $35,427,546 20 Gas 21 22 Engineering, Supervision, and Administration 7,793 23 Allowances for Funds Used During Construction 51,271 24 Payroll Taxes 1,723,145 25 Compensation Insurance 209,252 26 Pension Costs 4,222,845 27 Employee Insurance Benefit Plan 221,760 28 Medical Care Plan 2,058,518 29 Employee Savings Fund Plan 448,999 30 31 From Insert Pages 32 Subtotal $8,943,583 33 Common 34 35 36 37 38 39 40 41 42 43 44 From Insert Pages 45 Subtotal $0 46 TOTAL $44,371,129 FERC FORM NO. 1 (ED. 12-89) NYPSC Modified-96 Page 217 Name of Respondent This Report Is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Day, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 GENERAL DESCRIPTION OF CONSTRUCTION OVERHEAD PROCEDURE 1. For each construction overhead explain: (a) the nature 2. Show below the computation of allowance for funds and extent of work, etc. the overhead charges are intended used during construction rates, in accordance with the to cover, (b) the general procedure for determining the provisions of Electric Plant Instructions 3(17) of the amount capitalized, (c) the method of distribution to construc- U. S. of A., if applicable. tion jobs, (d) whether different rates are applied to different 3. Where a net-of-tax rate for borrowed funds is used, types of construction, (e) basis of differentiation in rates for show the appropriate tax effect adjustment to the computa- different types of construction, and (f) whether the overhead tions below in a manner that clearly indicates the amount is directly or indirectly assigned (Paper Copy Only). of reduction in the gross rate for tax effects. Description of Each Construction Overhead for Electric, Gas and Common, respectively

COMPUTATION OF ALLOWANCE FOR FUNDS USED DURING CONSTRUCTION RATES For line 1(5), column (d) below, enter the rate granted in the last rate proceeding. If such is not available, use the average rate earned during the preceding three years. 1. Components of Formula (Derived from actual book balances and actual cost rates): Capitalization Cost Rate Line Title Amount Ratio (Percent) Percentage No. (a) (b) (c) (d) 1 Average Short-Term Debt 2 Short-Term Interest 3 Long-Term Debt 4 Preferred Stock 5 Common Equity 6 Total Capitalization 0 0.00% 7 Average Construction Work in Progress Balance

2. Gross Rate for Borrowed Funds =>

3. Rate for Other Funds

4. Weighted Average Rate Actually Used for the Year: a. Rate for Borrowed Funds - => b. Rate for Other Funds - => FERC FORM NO.1 (ED.12-88) NYSPSC Modified

Page 218 Name of Respondent This Report Is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Origina (Mo, Day, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 ACCUMULATED PROVISION FOR DEPRECIATION OF ELECTRIC UTILITY PLANT (Account 108)

1. Explain in a footnote any important adjustments during yea

2. Explain in a footnote any difference between the amount for book cost of plant retired, line 11, column (c), and that reported electric plant in service, pages 204-207, column (d), excluding retirements of non-depreciable prope

3. The provisions of Account 108 in the Uniform System of Accounts require that retirements of depreciable plant be recorded when su plant is removed from service. If the respondent has a significant amount of plant retired at year end which has not been recorded an classified to the various reserve functional classifications, make preliminary closing entries to tentatively functionalize the book cost of plant retired. In addition, include all costs included in retirement work in progress at year end in the appropriate functional classificatio

4. Show separately interest credits under a sinking fund or similar method of depreciation accountin

Section A. Balances and Changes During Yea Total Electric Plant Electric Plant Held Electric Plant Line Item (c+d+e) in Service for Future Use Leased to Others No. (a) (b) (c) (d) (e) 1 Balance Beginning of Year $2,148,908,471 $2,148,411,308 $497,163 2 Depreciation Provisions for Year, Charged to 3 (403) Depreciation Expense 180,215,295 180,215,295 4 (403.1) Deprecation Expense for Asset Retirement Costs 11,430 11,430 5 (413) Exp. of Elec. Plt. Leas. to Othe 64,265 64,265 6 Transportation Expenses-Clearing 0 7 Other Clearing Accounts 0 8 Other Accounts (Specify): 0 90 10 TOTAL Deprec. Prov. for Year 180,290,990 180,226,725 0 64,265 (Total of lines 3 thru 9) 11 Net Charges for Plant Retired: 12 Book Cost of Plant Retired 46,168,957 46,168,957 13 Cost of Removal 40,422,160 40,422,160 14 Salvage (Credit) 5,127,309 5,127,309 15 TOTAL Net Chrgs. for Plant Ret. 91,718,426 91,718,426 0 0 (Enter Total of lines 12 thru 14) 16 Other Dr. or Cr. Items (Describe): 0 17 0 18 Balance End of Year (Enter Total of $2,237,481,035 $2,236,919,607 $0 $561,428 lines 1, 10, 15, 16, and 17) Section B. Balances at End of Year According to Functional Classifications 19 Steam Production $0 20 Nuclear Production 0 21 Hydraulic Production - Conventional 536,753 (24,675) 561,428 22 Hydraulic Production - Pumped Storag 0 23 Other Production 0 24 Transmission 540,285,426 540,285,426 25 Distribution 1,521,310,052 1,521,310,052 26 General 175,348,804 175,348,804 27 TOTAL (Enter Total of lines 19 thru 2 $2,237,481,035 $2,236,919,607 $0 $561,428

FERC FORM NO. (ED. 12-88) Next Page is 221 Page 219 Name of Respondent This Report Is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Day, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 NONUTILITY PROPERTY (Account 121)

1. Give a brief description and state the location of nonutility property included in Account 121. 2. Designate with a double asterisk any property which is leased to another company. State name of lessee and whether lessee is an associated company. 3. Furnish particulars (details) concerning sales, purchases, or transfers of Nonutility Property during the year.

4. List separately all property previously devoted to public service and give date of transfer to Account 121, Nonutility Property.

5. Minor items (5% of the Balance at the End of the Year for Account 121 or $100,000, whichever is less) may be grouped by (1) previously devoted to public service (line 44), or (2) other nonutility property (line 45).

Balance at Purchases, Sales, Balance at Line Description and Location Beginning of Year Transfers, etc. End of Year No. (a) (b) (c) (d) 1 Scanadaga Reservoir Assessments - Hadley and Stillwater 1,245,051 $1,245,051 2 Development, E-145 (Town of Hadley) 0 3 0 4 Former Fort Edward Hydro Plant, E-309 (Village of Fort Edward) 742,457 742,457 5 Transferred to A/C 121 in January, 1979 0 6 0 7 Land Future Tonawanda Steam Station Transmission Line 326,874 326,874 8 Right of Way, W-114 (City of North Tonawanda) 0 9 0 10 Rome Sentinel Purchase .54 Acres of Land (City of Rome) 179,444 179,444 11 0 12 Town of Bellmont 5,462,828 5,462,828 13 0 14 City of Saratoga Springs 1,037,807 1,037,807 15 0 16 Town of Hadley 225,616 225,616 17 0 18 Town of Amherst 308,650 308,650 19 0 20 City of Fulton 126,673 126,673 21 0 22 Minor Item Previously Devoted to Public Service 1,657,176 1,657,176 23 0 24 Other nonutility property (327,233) (327,233) 25 0 26 0 27 Changes During the Year (column c) 0 28 Sales 0 29 Transfers (327,233) 0 30 OPP CWIP 0 31 0 32 Net Changes During the Year (327,233) 0 33 0 34 0 35 0 36 0 37 0 38 0 39 0 40 0 41 Minor Item Previously Devoted to Public Service 0 42 Minor Items-Other Nonutility Property 0 43 TOTAL $11,312,576 ($327,233) $10,985,343

FERC FORM NO. 1 (ED. 12-95) Next Page is 222 Page 221 Niagara Mohawk Power Corporation 6/01/2010 12/31/2009

THIS PAGE LEFT BLANK INTENTIONALLY

Next Page is 224 Page 222 Name of Respondent This Report Is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 INVESTMENT IN SUBSIDIARY COMPANIES (Account 123.1)

1. Report below investments in Account 123.1, Investment in Subsidiary Companies. (b) Investment Advances - Report separately the amounts 2. Provide a subheading for each company and list of loans or investment advances which are subject to thereunder the information called for below. Subtotal by repayment, but which are not subject to current settlement. company and give a total in columns (e), (f), (g) and (h). With respect to each advance show whether the advance is a note or open account. List each note giving date of issuance, (a) Investment in Securities - List and describe each maturity date, and specifying whether note is a renewal. security owned. For bonds give also principal amount, 3. Report separately the equity in undistributed subsidiary date of issue, maturity and interest rate. earnings since acquisition. The total is column(e) should equal the amount entered for Account 418.1. Amount of Line Date Date of Investment at No. Description of Investment Acquired Maturity Beginning of Year (a) (b) (c) (d) 1 NM Uranium, Inc. 2 Common Stock, 2000 shares, $10 par value 1996 20,000 3 Advances-open Account (72,279) 4 Reserve for Environmental Restoration 5 6 NM Properties, Inc. 1993-1997 7 Common Stock, 3075 shares, $1 par value 3,075 8 Paid-in-Capital 6,422,807 9 Unappropriated undistributed subsidiary (1,422,675) 10 earnings since acquisition 11 12 UMICO Holdings, Inc. 2001 1,128,420 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 TOTAL Cost of Account 123.1: $ TOTAL $6,079,348 FERC FORM NO.1 (ED. 12-89) Page 224 Name of Respondent This Report Is: Date of Report Year of Report Niagara Mohawk Power Corporation(1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 INVESTMENT IN SUBSIDIARY COMPANIES (Account 123.1) (Continued)

disposed of during the year. 4. For any securities, notes, or accounts that were pledged, 7. In column (h) report for each investment disposed of designate such securities, notes, or accounts in a footnote, during the year, the gain or loss represented by the and state the name of pledgee and purpose of the pledge. difference between cost of the investment (or the other 5. If Commission approval was required for any advance amount at which carried in the books of account if difference made or security acquired, designate such fact in a footnote from cost) and the selling price thereof, not including interest and give name of Commission, date of authorization, and case adjustment includible in column (f). or docket number. 8. Report on Line 42, column (a) the total cost of Account 6. Report column (f) interest and dividend revenues from 123.1. investments, including such revenues from securities Equity in Amount of Gain or Loss Subsidiary Revenues Investment at from Investment Earnings for Year for Year End of Year Disposed of Line (e) (f) (g) (h) No. 1 20,000 2 (72,279) 3 4 5 06 3,075 7 (500,000) 5,922,807 8 (59,924) (1,482,599) 9 10 11 1,128,420 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 ($559,924) $0 $5,519,424 $0 FERC FORM NO.1 (ED. 12-89) Next Page is 227 Page 225 Name of Respondent This Report Is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 MATERIALS AND SUPPLIES 1. For Account 154, report the amount of plant materials and operating supplies under the primary functional classifications as indicated in column (a); estimates of amounts by function are acceptable. In column (d), designate the department or departments which use the class of material.

2. Give an explanation of important inventory adjustments during the year (in a footnote) showing general classes of material and supplies and the various accounts (operating expenses, clearing accounts, plant, etc.) affected - debited or credited. Show separately debits or credits to stores expense-clearing, if applicable.

Balance Department or Line Account Beginning of Balance Departments No. Year End of Year Which Use Material (a) (b) (c) (d) 1 Fuel Stock (Account 151) 2 Fuel Stock Expenses Undistributed (Account 152) 3 Residuals and Extracted Products (Account 153) 4 Plant Materials and Operating Supplies (Account 154) 5 Assigned to - Construction (Estimated) 22,104,952 22,775,097 Electric / Gas 6 Assigned to - Operations and Maintenance 7 Production Plant (Estimated) 8 Transmission Plant (Estimated) 3,047,278 3,139,660 Electric 9 Distribution Plant (Estimated) 5,320,546 5,481,847 Electric / Gas 10 Assigned to - Other 11 TOTAL Account 154 (Total of lines 5 thru 10) $30,472,776 $31,396,604 12 Merchandise (Account 155) 13 Other Material and Supplies (Account 156) 14 Nuclear Materials Held for Sale (Account 157) (Not applicable to Gas Utilities) 15 Stores Expense Undistributed (Account 163) (202,231) 141,012 Electric / Gas 16 17 18 19 20 TOTAL Materials and Supplies (per Balance Sheet) $30,270,545 $31,537,616

FERC FORM NO.1 (ED. 12-96) Page 227 Name of Respondent This Report Is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 Allowances (Accounts 158.1 and 158.2)

1. Report below the particulars (details) called for concerning are first eligible for use: the current year's allowances in allowances. columns (b)-(c), allowances for the three succeeding years in 2. Report all acquisitions of allowances at cost. columns (d)-(i), starting with the following year, and allowances for the remaining succeeding years in columns (j)- 3. Report allowances in accordance with a weighted average (k). cost allocation method and other accounting as prescribed by 5. Report on line 4 the Environmental Protection Agency General Instruction No. 21 in the Uniform System of Accounts. (EPA) issued allowances. Report withheld portions on lines 4. Report the allowances transactions by the period they 36-40. Line Allowances Inventory Current Year 19__ No. (Account 158.1) No. Amt. No. Amt. (a) (b) (c) (d) (e) 01 Balance- Beginning of Year 02 03 Acquired During Year: 04 Issued (Less Withheld Allow.) 05 Returned by EPA 06 07 Purchases/Transfers: 08 09 10 11 12 13 14 15 Total 16 17 Relinquished During Year: 18 Charges to Account 509 19 Other: 20 21 Cost of Sales/Transfers: 22 23 24 25 26 27 28 Total 29 Balance-End of Year 30 31 Sales: 32 Net Sales Proceeds (Assoc. Co.) 33 Net Sales Proceeds (Other) 34 Gains 35 Losses Allowances Withheld (Account158.2) 36 Balance-Beginning of Year 37 Add: Withheld by EPA 38 Deduct: Returned by EPA 39 Cost of Sales 40 Balance-End of Year 41 42 Sales: 43 Net Sales Proceeds (Assoc. Co.) 44 Net Sales Proceeds (Other) 45 Gains 46 Losses FERC FORM NO. (ED. 12- 95) Page 228 Name of Respondent This Report Is: Date of Report Year of Report Niagara Mohawk Power Corpor (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 Allowances (Accounts 158.1 and 158.2) 6. Report on lines 5 allowances returned by the EPA. Report on line 39 the EPA's sales of the withheld allowances. 8. Report on lines 22-27 the name of purchasers/transferees of Report on lines 43-46 the net sales proceeds and gains/losses allowances disposed of and identify associated companies. resulting from the EPA's sale or auction of withheld 9. Report the net costs and benefits of hedging transactions on a allowances. separate line under purchases/transfers and sales/transfers. 7. Report on lines 8-14 the names of vendors/transferors of 10. Report on lines 32-35 & 43-46 the net sales proceeds and allowances acquired and identify associated companies (See gains or losses from allowance sales. "associated company" under "Definitions" in the Uniform System of Accounts). 19__ 19__ Future Years Totals Line No. Amt. No. Amt. No. Amt. No. Amt. No. (f) (g) (h) (i) (j) (k) (l) (m) 01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35

36 37 38 39 40 41 42 43 44 45 46 FERC FORM NO. (ED. 12- 95) Page 229 Name of Respondent This Report Is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 EXTRAORDINARY PROPERTY LOSSES (Account 182.1) Description of Extraordinary Loss Total Losses WRITTEN OFF DURING [Include in the description the date of loss, the date of Amount Recognized THE YEAR Commission authorization to use Account 182.1 and period of Loss During Year Account Balance at Line of amortization (mo, yr to mo, yr.).] Charged Amount End of Year No. (a) (b) (c) (d) (e) (f) 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 TOTAL $0 $0 $0 $0 UNRECOVERED PLANT AND REGULATORY STUDY COSTS (Account 182.2) Description of Unrecovered Plant and Regulatory Study Costs Total Amount Costs WRITTEN OFF DURING [Include in the description of costs, the date of Commission of Recognized THE YEAR Lineauthorization to use Account 182.2, and period of Charges During Year Account Balance at No. amortization (mo, yr to mo, yr).] Charged Amount End of Year (a) (b) (c) (d) (e) (f) 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 TOTAL $0 $0 $0 $0 FERC FORM NO. 1 (ED. 12- 88) Next Page is 232 Page 230 This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Day, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 OTHER REGULATORY ASSETS (Account 182.3)

1. Report below the particulars (details) called for concerning other regulatory assets which are created through the ratemaking actions of regulatory agencies (and not includable in other amounts). 2. For regulatory assets being amortized, show period of amortization in column (a). 3. Minor items ( 5% of the Balance at End of Year for account 182.3 or amounts less than $50,000, whichever is less) may be grouped by classes. Credits Description and Purpose of Other Account Balance at Line Regulatory Assets Debits Charged Amount End of Year No. (a) (b) (c) (d) (e) 1 Fuel Cost Deferred (182501) $0 $0 $924,400 2 3 Regulatory Tax Asset (FAS 109) (182302) 0 282/283 17,242,605 185,504,045 4 5 Gas Adjustment Clause (Surcharge or Refund Deferred 31,257,520 804 33,384,878 44,919,105 6 7 Excess AFUDC- Electric Plant in Service 19,671 406 17,242 230,742 8 9 Deferred Environmental Restoration Costs 56,137,435 253 46,471,963 448,707,190 10 11 Other Post Retirement Benefits- Electric 0 926 2,766,000 8,782,640 12 13 Other Post Retirement Benefits- Gas 0 926 660,000 968,559 14 15 Storm Restoration Costs Deferred 6,204,800 571,593 583,648 172,035,891 16 17 Electric Plant in Services Excess AFUDC 0 406 39,342 557,344 18 19 NYS Sales Tax Audit Assessment (1988-1992) 0 254 184,583 0 20 21 NIMO Case 08-G-0609 JP Amort 46,589,584 407 9,053,346 37,536,238 22 23 Customer Service Backout Credit (prior to 9/01) 0 0 10,309,579 24 25 Index Swap Contracts 0 0 0 26 27 NYPA Transmission Access Charge (NTAC) 0 0 13,050,967 28 29 NYISO Tariff Schedule 1 Costs 0 0 85,451,012 30 31 NYISO Tariff Schedule 2 Costs 0 0 13,286,552 32 33 Fossil/Hydro Auction Incentive 0 0 18,556,040 34 35 State Regulatory Asset (SFAS109) 23,625,347 283 18,340,043 (53,252,638) 36 37 Customer Service Backout Credit (prior to 9/01 to 8 5,617,004 0 111,284,085 38 39 Electronic Data Interchange (EDI) Costs 0 0 3,849,300 40 41 Merger Rate Plan Stranded Costs 0 407 496,604,404 1,077,269,521 42 From Insert Page A 203,608,165 180,354,797 849,855,313 43 From Insert Page B 719,848,668 515,041,055 286,130,592 44 TOTAL $1,092,908,194 $1,320,743,906 $3,315,956,477

FERC FORM NO.1 (ED. 12-94) Page 232

If applicable, see insert page below Niagara Mohawk Power Corporation 6/01/2010 12/31/2009

OTHER REGULATORY ASSETS (Account 182.3)

Credits Description and Purpose of Other Account Balance at Line Regulatory Assets Debits Charged Amount End of Year No. (a) (b) (c) (d) (e) 1 Merger Fair Value Pension & OPEB Adjustment $0 $0 $176,089,729 2 3 Pension Expense Deferred- Electric 22,346,522 926 2,838,069 169,995,509 4 5 OPEB Expense Deferred- Electric 62,565,078 253 549,038 286,479,502 6 7 Voluntary Early Retirement Offer (VERO) 0 926 1,114,505 2,334,153 8 9 City of Buffalo Settlement Agreement 0 0 684,320 10 11 SBC Program Cost Deferred 8,198,579 0 9,057,772 12 13 Enhanced Severance Plan 0 926 28,676 60,056 14 15 SC7 Standby Service Lost Revenue 0 456 1,098,474 516,013 16 17 SIR Expenditures Deferred- Electric 30,887,776 456 118,934 89,114,042 18 19 Generation Stranded Costs Adjustments 2,304,593 131 1,822,769 35,523,450 20 21 Additional Minimum Pension Liability Deferral 0 0 0 22 23 Pension Expense Deferred- Gas 4,674,246 253/254 28,361,017 4,663,045 24 25 OPEB Expense Deferred- Gas 8,556,424 253/254 53,468,563 5,723,682 26 27 Incentive Return on Retirement Funding 12,384,853 254 13,383,057 73,174,913 28 29 Pension Settlement Loss 0 254/926 50,418,040 (56,819,249) 30 31 NIMO Acctg Change Capital Item 0 0 0 32 33 RPS Program Cost Deferred 586,981 0 1,771,100 34 35 Commodity Adjustment Clause 35,045,670 254/431/450 10,956,730 44,634,146 36 37 Disputed Station Service 0 0 0 38 39 NIMO- Merchant Function Charge 409,917 0 409,917 40 41 SIR Expenditures Deferred - Gas 4,687,942 431/930 9,942,534 1,738,020 42 43 Transmission Revenue Adjustment Clause 10,959,584 419/456 6,254,391 4,705,193 44 TOTAL $203,608,165 $180,354,797 $849,855,313

FERC FORM NO.1 (ED. 12-94) Page 232-A Niagara Mohawk Power Corporation 6/01/2010 12/31/2009

OTHER REGULATORY ASSETS (Account 182.3)

Credits Description and Purpose of Other Account Balance at Line Regulatory Assets Debits Charged Amount End of Year No. (a) (b) (c) (d) (e) 1 Elevated Voltage Deferral $6,842,306 $0 $14,618,398 2 3 Low Income Allowance Discount Program 1,258,834 0 4,154,119 4 5 Asset Retirmeent Obligation Reg Asset 610,500 230 1,130,180 8,992,955 6 7 Gas Futures Reg Asset 0 0 0 8 9 PFJ Tax Credit 0 0 3,633,275 10 11 80/20 Revenue Sharing Mechanism 5,267,159 5,756,342 7,290,022 12 13 Amortization of Deferral Recoveries 0 407 123,588,117 (547,176,225) 14 15 Religious Rate Revenue 149,351 0 4,062,275 16 17 FAS 158 - Pension 301,640,184 926 18,972,558 494,496,318 18 19 FAS 158- OPEB 92,910,689 926 87,336,912 201,015,097 20 21 Customer Outreach & Education 0 0 0 22 23 Temp State Assessment 18-A 81,172,958 419/431/450 46,196,960 34,975,998 24 25 Deferred Loss- Sale Oswego 0 411 465,874 931,749 26 27 Electric Swaps - Electric Supply 160,624,294 176/244/240 147,511,308 38,285,522 28 29 Gas Futures- Gas Supply 64,854,020 244 84,082,804 16,332,716 30 31 RMD Revenue Decoupling 4,475,604 0 4,475,604 32 33 NIMO- Low Income Program 42,769 0 42,769 34 35 36 37 38 39 40 41 42 43 44 TOTAL $719,848,668 $515,041,055 $286,130,592

FERC FORM NO.1 (ED. 12-94) Page 232-B Name of Respondent This Report Is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Day, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 MISCELLANEOUS DEFERRED DEBITS (Account 186)

1. Report below the particulars (details) called for concerning miscellaneous deferred debits. 2. For any deferred debit being amortized, show period of amortization in column (a). 3. Minor items ( 1% of the Balance at End of Year for Account 186 or amounts less than $50,000, whichever is less) may be grouped by classes. CREDITS Bal. Beginning Account Balance at Line Description of Miscellaneous Deferred Debits of Year Debits Charged Amount End of Year No. (a) (b) (c) (d) (e) (f) 1 CTI Freight Bill Payments $0 $0 2 0 0 3 Pension Intangible Asset 22,347,312 253/232 22,347,312 0 4 0 0 5 Cash Over and Short (638,964) 3,117,526 2,478,562 6 0 0 7 Miscellaneous (6,279) 10,365 4,086 8 0 0 9 Stillwater Development Receivable 244,135 142 5,528 238,607 10 0 11 0 12 0 13 0 14 0 15 0 16 0 17 0 18 0 19 0 20 0 21 0 22 0 23 0 24 0 25 0 26 0 27 0 28 0 29 0 30 0 31 0 32 0 33 0 34 0 35 0 36 0 37 0 38 0 39 0 40 0 41 0 42 0 43 0 44 0 45 0 46 From Insert Page A Below 0 0 0 0 47 Misc. Work in Progress 21,946,204 2,721,255 48 DEFERRED REGULATORY COMM. 0 EXPENSES (See pages 350-351) 49 TOTAL $21,946,204 $0 $0 $2,721,255

FERC FORM NO.1 (ED. 12-94 ) Page 233 Name of Respondent This Report Is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Day, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 ACCUMULATED DEFERRED INCOME TAXES (Account 190) 1. Report the information called for below, concerning the respondent's accounting for deferred income taxes. 2. At Other (Specify), include deferrals relating to other income and deductions. Balance at Balance Line Account Subdivisions Beginning End No. of Year of Year (a) (b) (c) 1Electric 2 See Supporting Detail Pages $854,640,360 $910,316,537 3 4 5 6 7Other 8 TOTAL Electric (Enter Total of lines 2 thru 7) $854,640,360 $910,316,537 9Gas 10 See Supporting Detail Pages $133,800,604 $139,638,004 11 12 13 14 15 Other 16 TOTAL Gas (Enter Total of lines 10 thru 15) $133,800,604 $139,638,004 17 Other (Specify) 18 TOTAL (Acct 190)(Total of lines 8,16 and 17) $988,440,965 $1,049,954,541 NOTES

FERC FORM NO. 1 (ED. 12-88) Page 234 Next Page 250 If applicable, see insert page below: Niagara Mohawk Power Corporation 6/01/2010 12/31/2009

ACCUMULATED DEFERRED INCOME TAXES (Account 190)

Balance at Balance Line Account Subdivisions Beginning End No. of Year of Year (a) (b) (c) Electric

ACCRUED INCOME TAXES 35,796,586 36,193,933 ACCRUED INTEREST 3,396,000 4,152,809 BAD DEBTS 50,927,000 53,408,462 DEBT (121,000) (121,000) DECOMMISSIONING / NUCLEAR COST PROV 0 0 DEFERRED COMPENSATION (10,995,661) (9,466,767) DERIVATIVES 00 EMPLOYEE COMPENSATION AND BENEFITS 11,315,000 7,388,205 FAS 109 13,963,652 13,963,652 FAS 109 REG ASSET 0 956,340 INVESTMENT TAX CREDIT 0 0 OPEB LIABILITY 287,971,620 287,971,620 OTHER CURRENT ASSETS 56,000 56,000 PENSION LIABILITY (111,393,662) (68,708,051) PROPERTY RELATED (2,478,302) (9,349,333) PROPERTY TAXES (4,721,000) (6,360,416) REG ASSET - ENVIRONMENTAL 0 (0) REG ASSET - PENSION/OPEB 144,158,103 144,158,103 REG ASSET - STORM COST 0 0 REGULATORY ASSETS 138,795,024 157,353,919 REGULATORY ASSETS - X Rate Base 72,329,000 72,329,000 UNAMORTIZED DEBT DISCOUNT OR PREMIUM 7,527,000 7,527,000 UNBILLED REVENUE 10,061,000 10,061,000 RESERVE - ENVIRONMENTAL 203,526,000 203,526,000 REG ASSET - DECOMMISSIONING 807,000 807,000 OTHER ITEMS 3,721,000 4,469,062 Total Electric 854,640,360 910,316,537

Gas

ACCRUED INCOME TAXES 8,384,577 7,513,057 ACCRUED INTEREST 695,000 850,009 BAD DEBTS 20,888,000 21,853,013 DEBT 00 DECOMMISSIONING / NUCLEAR COST PROV 0 0 DEFERRED COMPENSATION (2,377,699) (2,064,552) DERIVATIVES (3,832,000) (3,832,000) EMPLOYEE COMPENSATION AND BENEFITS 2,464,000 1,659,717 FAS 109 10,580,000 10,580,000 FAS 109 REG ASSET 0 195,877 INVESTMENT TAX CREDIT 0 0 OPEB LIABILITY 50,839,585 50,839,585 OTHER CURRENT ASSETS 0 0 PENSION LIABILITY (22,853,434) (14,110,598) PROPERTY RELATED 1,069,000 (338,320) PROPERTY TAXES (768,000) (768,000) REG ASSET - ENVIRONMENTAL (665,000) (665,000) REG ASSET - PENSION/OPEB 26,044,575 26,044,575 REG ASSET - STORM COST 0 0 REGULATORY ASSETS 13,669,000 12,206,065 REGULATORY ASSETS - X Rate Base 11,911,000 11,911,000 UNAMORTIZED DEBT DISCOUNT OR PREMIUM 0 0 UNBILLED REVENUE 17,574,000 17,574,000 RESERVE - ENVIRONMENTAL 0 0 REG ASSET - DECOMMISSIONING 0 0 OTHER ITEMS 178,000 189,577 133,800,604 139,638,004

Page 234-A Name of Respondent This Report Is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Day, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 CAPITAL STOCK (Accounts 201 and 204)

1. Report below the particulars (details) called for concerning common and preferred stock at end of year, distinguishing separate series of any general class. Show separate totals for common and preferred stock. If information to meet the stock exchange reporting requirement outlined in column (a) is available from the SEC 10-K Report Form filing, a specific reference to report form (i.e. year and company title) may be reported in column (a) provided the fiscal years for both the 10-K report and this report are compatible. 2. Entries in column (b) should represent the number of shares authorized by the articles of incorporation as amended to end of year. 3. Give particulars (details) concerning shares of any class and series of stock authorized to be issued by a regulatory commission which have not yet been issued.

Number Par Call Class and Series of Stock and of Shares or Stated Price at Name of Stock Exchange Authorized Value End of Year by Charter Per Share

Line No. (a) (b) (c) (d) 1 Common - Account 201 2 Common 250,000,000 $1.00 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 Total 250,000,000 21 22 Preferred - Account 204 23 Cumulative Preferred 3,400,000 24 3.40% Series $100.00 $103.50 25 3.60% Series $100.00 $104.85 26 3.90% Series $100.00 $106.00 27 28 29 Cumulative Preferred 19,600,000 30 31 32 33 34 35 36 37 38 39 40 41 Total 23,000,000 42

FERC FORM NO. 1 (ED. 12- 91) NYPSC-Modified-96 Page 250 Name of Respondent This Report Is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Day, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 CAPITAL STOCK (Accounts 201 and 204) (Continued)

4. The identification of each class of preferred stock should show the dividend rate and whether the dividends are cumulative or noncumulative. 5. State in a footnote if any capital stock which has been nominally issued is nominally outstanding at end of year. Give particulars (details) in column (a) of any nominally issued capital stock, reacquired stock, or stock in sinking and other funds which is pledged, stating name of pledgee and purposes of pledge.

OUTSTANDING PER BALANCE SHEET HELD BY RESPONDENT (Total amount outstanding without reduction for amounts held by AS REACQUIRED STOCK IN SINKING AND respondent.) (Account 217) OTHER FUNDS

Shares Amount Shares Cost Shares Amount Line (e) (f) (g) (h) (i) (j) No. 1 187,364,863 $187,364,863 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 187,364,863 $187,364,863 0 $0 0 $0 20 21 22 23 57,524 5,752,400 24 137,152 13,715,200 25 95,171 9,517,100 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 289,847 $28,984,700 0 $0 0 $0 41 42

FERC FORM NO. 1 (ED. 12- 91) NYPSC-Modified-96 Page 251 This Report Is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Day, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 CAPITAL STOCK SUBSCRIBED, CAPITAL STOCK LIABILITY FOR CONVERSION, PREMIUM ON CAPITAL STOCK, AND INSTALLMENTS RECEIVED ON CAPITAL STOCK (Accounts 202 and 205, 203 and 206, 207, 212) 1. Show for each of the above accounts the amounts Common Stock Liability for Conversion, or applying to each class and series of capital stock. Account 206, Preferred Stock Liability for Conversion, 2. For Account 202, Common Stock Subscribed, and at the end of the year. Account 205, Preferred Stock Subscribed, show the subscription 4. For Premium on Account 207, Capital Stock, price and the balance due on each class at the end of year. designate with a double asterisk any amounts 3. Describe in a footnote the agreement and transactions representing the excess of consideration received over stated values of stocks without par value. Line Name of Account and Description of Item Number of Shares Amount No. (a) (b) (c) 1 Common Stock Subscribed (Account 202) 2 3 4 5 6 Subtotal 0 $0 7 8 Preferred Stock Subscribed (Account 205) 9 10 11 12 13 Subtotal 0 $0 14 15 Common Stock Liability for Conversion (Account 203) 16 17 18 19 20 Subtotal 0 $0 21 22 Preferred Stock Liability for Conversion (Account 206) 23 24 25 26 27 Subtotal 0 $0 28 29 Premium on Capital Stock (Account 207) 30 31 32 33 34 35 36 Subtotal 0 $0 37 38 Installments Received on Capital Stock (Account 212) 39 40 41 42 43 44 45 Subtotal 0 $0 46 TOTAL 0$0

FERC FORM NO. 1 (ED. 12-95) NYPSC Modified-96 Page 252 Name of Respondent This Report Is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Day, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 OTHER PAID-IN CAPITAL (Accounts 208-211, inc.) Report below the balance at the end of the year and the information specified below for the respective other paid-in capital accounts. Provide a subheading for each account and show a total for the account, as well as total of all accounts for reconciliation with balance sheet, page 112. Add more columns for any account if deemed necessary. Explain changes made in any account during the year and give the accounting entries effecting such change. (a) Donations Received from Stockholders (Account 208) - State amount and give brief explanation of the origin and purpose of each donation. (b) Reduction in Par or Stated Value of Capital Stock (Account 209) - State amount and give brief explanation of the capital change which gave rise to amounts reported under this caption including identification with the class and series of stock to which related. (c) Gain on Resale or Cancellation of Reacquired Capital Stock (Account 210) - Report balance at beginning of year, credits, debits, and balance at end of year with a designation of the nature of each credit and debit identified by the class and series of stock to which related. (d) Miscellaneous Paid-In Capital (Account 211) - Classify amounts included in this account according to captions which, together with brief explanations, disclose the general nature of the transactions which gave rise to the reported amounts.

Line Item Amount No. (a) (b) 1 Donations Received from Stockholders (Account 208) 2 3 4 5 6 7 8 Subtotal $0 9 10 Reduction in Par or Stated Value of Common Stock (Account 209) 11 12 13 14 15 16 17 Subtotal $0 18 19 Gain on Resale or Cancellation of Reacquired Capital Stock (Account 210) 20 Balance @ 12/31/2007 $11,109,695 21 22 Net Loss on reacquisition of preferred stock (243,707) 23 24 25 26 Subtotal $10,865,988 27 28 Miscellaneous Paid-In Capital (Account 211) 29 See pages 253-A $1,613,142,343 30 31 32 33 34 35 Subtotal $1,613,142,343 36 37 38 39 40 TOTAL $1,624,008,331

FERC FORM NO.1 (ED. 12-87) NYPSC Modified-96 Page 253 Name of Respondent This Report Is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Day, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 OTHER PAID-IN CAPITAL (Accounts 208-211, inc.) Report below the balance at the end of the year and the information specified below for the respective other paid-in capital accounts. Provide a subheading for each account and show a total for the account, as well as total of all accounts for reconciliation with balance sheet, page 112. Add more columns for any account if deemed necessary. Explain changes made in any account during the year and give the accounting entries effecting such change. (a) Donations Received from Stockholders (Account 208) - State amount and give brief explanation of the origin and purpose of each donation. (b) Reduction in Par or Stated Value of Capital Stock (Account 209) - State amount and give brief explanation of the capital change which gave rise to amounts reported under this caption including identification with the class and series of stock to which related. (c) Gain on Resale or Cancellation of Reacquired Capital Stock (Account 210) - Report balance at beginning of year, credits, debits, and balance at end of year with a designation of the nature of each credit and debit identified by the class and series of stock to which related. (d) Miscellaneous Paid-In Capital (Account 211) - Classify amounts included in this account according to captions which, together with brief explanations, disclose the general nature of the transactions which gave rise to the reported amounts.

Line Item Amount No. (a) (b) 1 Miscellaneous Paid-In Capital (Account 211) 2 Amount set up on 1/5/50, as adjusted 12/58, recording certain investments . 3 contributed by Niagara Hudson Power Corporation, former parent holding 4 company in accordance with its "Dissolution Plan" which was approved by the 5 Securities and Exchange Commission under date of 8/25/49 and by the District 6 Court of the United States for the Northern District of New York State 7 under date of 11/4/49. $2,137,110 8 Amount of cash received upon liquidation of Niagara Hudson Power Corporation 9 in excess of estimated liabilities . 500,000 10 Contributions in aid of construction transferred from Account 217, per order 11 of the Public Service Commission of the State of New York dated 3/8/52 12 in case 13343. 28,773 13 Capital surplus of the Oswego Canal Company, merged as of 3/31/52, 14 $276,296 less write-down of electric plant of $67,212. 209,084 15 Excess of book value over the purchase price of the capital stock of the 16 Woodville Electric Light and Power Company, Inc. 5,164 17 Refund of deposits for script certificates of Niagara Hudson Power Corporation 18 which expired on 1/5/58. 124,121 19 Proceeds from the sale of 5,173shares of common stock held for distribution 20 to holders of unexchanged certificates of Niagara Hudson Power Corporation 21 common stock. Sold pursuant to order of the United States District Court for 22 the Northern District of New York dated 1/23/61. 204,267 23 To record subsidiaries on the "Equity" basis: 24 Excess book value over the cost of investments at the sate of acquisition of 25 Canadian Niagara Power Co., Ltd.($3457,284) and St. Lawrence Power 26 Co. ($903,145) as previously recorded on the Company's books. Ownership 27 of these companies was transferred to Opinac Energy Corporation (formerly 28 Opinac Investments Limited) during 1982. 4,360,429 29 Excess of the cost of investment carried on the Company's books over the 30 book value at date of acquisition of Beebee Island Corporation. (62,872) 31 Excess of the book value at the date of acquisition over the cost of investments 32 carried on the Company's books of Moreau Manufacturing Corp. 477,984 33 National Grid Merger Purchase Accounting Adjustments 1,382,244,317 34 35 Return of capital dividend on common stock (7/02) (86,086,034) 36 37 Equity contribution made by parent company, Niagara Mohawk Holdings (09/03) 309,000,000 38 39 40 Subtotal $1,613,142,343

FERC FORM NO.1 (ED. 12-87) NYPSC Modified-96 Page 253-A Name of Respondent This Report Is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Day, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 DISCOUNT ON CAPITAL STOCK (Account 213) 1. Report the balance at end of the year of discount on capital stock for each class and series of capital stock. 2. If any change occurred during the year in the balance with respect to any class or series of stock, attach a statement giving particulars (details) of the change. State the reason for any charge-off during the year and specify the amount charged.

Balance at Line Class and Series of Stock End of Year No. (a) (b) 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 TOTAL $0 CAPITAL STOCK EXPENSE (Account 214) 1. Report the balance at end of year of capital stock expenses for each class and series of capital stock. 2. If any change occurred during the year in the balance with respect to any class or series of stock, attach a statement giving particulars of the change. State the reason for any charge-off of capital stock expense and specify the account charged.

Balance at Line Class and Series of Stock End of Year No. (a) (b) 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 TOTAL $0

FERC FORM NO. 1 (ED. 12-87 ) Next Page is 256 Page 254 Name of Respondent This Report Is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Day, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 LONG-TERM DEBT (Accounts 221, 222, 223, and 224)

1. Report by balance sheet account the particulars (details) 6. In column(b) show the principal amount of bonds or other concerning long-term debt included in Accounts 221, Bonds, 222, long-term debt originally issued. Reacquired Bonds, 223, Advances from Associated Companies, 7. In column (c) show the expense, premium or discount with and 224, Other Long-Term Debt. respect to the amount of bonds or other long-term debt 2. In column (a), for new issues, give Commission authorization originally issued. numbers and dates. 8. For column (c) the total expenses should be listed first 3. For bonds assumed by the respondent, include in column(a) for each issuance, then the amount of premium (in parentheses) the name of the issuing company as well as a description of or discount. Indicate the premium or discount with a notation, the bonds. such as (P) or (D). The expenses, premium or discount should 4. For advances from Associated Companies, report not be netted. separately advances on notes and advances on open accounts. 9. Furnish in a footnote particulars (details) regarding Designate demand notes as such. Include in column(a) names the treatment of unamortized debt expense, premium or discount of associated companies from which advances were received. associated with issues redeemed during the year. Also, give in 5. For receivers' certificates, show in column(a) the name of a footnote the date of the Commission's authorization of the court and date of court order under which such certificates treatment other than as specified by the Uniform System of were issued. Accounts.

Class and Series of Obligation, Coupon Rate Principal Total Expense, Line (For new issue, give Commission Authorization numbers and dates) Amount of Premium or No. Debt Issued Discount

(a) (b) (c) 1 Bonds (Account 221) 2 3.55% Series $500,000,000 $1,751,131 3 4.88% Series 750,000,000 3,805,177 4 5.15% Series (Note 1) 75,000,000 4,253,106 5 Floating Series A (Note 2) 115,705,000 4,505,193 6 Floating Series K 45,600,000 2,430,247 7 8 9 10 11 12 13 14 15 16 17 18 19 20 Subtotal $1,486,305,000 $16,744,854 21 22 Reacquired Bonds (Account 222) 23 24 25 26 27 28 Subtotal $0 $0 29 30 From Insert Page 31 Advances from Associated Companies (Account 223) 850,000,000 0 32 Other Long Term Debt (Account 224) 413,760,000 18,690,608 33 TOTAL $2,750,065,000 $35,435,462

FERC FORM NO.1 (ED. 12-96) NYPSC Modified-96 Page 256 Name of Respondent This Report Is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Day, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 LONG-TERM DEBT (Accounts 221, 222, 223, and 224) (Continued)

10. Identify separate indisposed amounts applicable to securities give particulars (details) in a footnote issues which were redeemed in prior years. including name of pledgee and purpose of the pledge. 11. Explain any debits and credits other than amortiza- 14. If the respondent has any long-term debt securities tion debited to Account 428, Amortization of Debt which have been nominally issued and are nominally Discount and Expense, or credited to Account 429, outstanding at end of year, describe such securities in Amortization of Premium on Debt - Credit. a footnote. 12. In a footnote, give explanatory 15. If interest expense was incurred during the year on particulars (details) for Accounts 223 and 224 of net any obligations retired or reacquired before end of year, charges during the year. With respect to long-term include such interest expense in column (i). Explain in a advances, show for each company: (a) principal footnote any difference between the total of column (i) and advanced during year, (b) interest added to principal the total of Account 427, Interest on Long-Term Debt and amount, and (c) principal repaid during year. Give Account 430, Interest on Debt to Associated Companies. Commission authorization numbers and dates. 16. Give particulars (details) concerning any long-term debt 13. If the respondent has pledged any of its long-term debt authorized by a regulatory commission but not yet issued

AMORTIZATION PERIOD Outstanding Nominal Date Date of (Total amount Interest for Year of Issue Maturity Date From Date To outstanding Amount Line without reduction No. for amounts held by respondent) (d) (e) (f) (g) (h) (i) 1 10/1/2009 10/1/2014 10/1/2009 10/1/2014 $500,000,000 $4,589,292 2 8/1/2009 8/15/2019 8/1/2009 8/15/2019 750,000,000 14,236,250 3 11/1/1998 11/1/2025 11/1/1998 11/1/2025 75,000,000 3,862,500 4 7/1/1994 7/1/2029 7/1/1994 7/1/2029 115,705,000 998,100 5 12/1/2003 10/1/2013 12/1/2003 10/1/2013 45,600,000 408,804 6 7 8 9 10 11 12 13 14 15 16 17 18 19 $1,486,305,000 $24,094,946 20 21 22 23 24 25 26 27 $0 $0 28 29 30 850,000,000 42,405,000 31 413,760,000 3,686,106 32 $2,750,065,000 $70,186,052 33

FERC FORM NO.1 (ED. 12-96) NYPSC Modified-96 Next Page is 261 Page 257 Niagara Mohawk Power Corporation 6/01/2010 12/31/2009

LONG-TERM DEBT (Accounts 221, 222, 223, and 224)

Class and Series of Obligation, Coupon Rate Principal Total Expense, Line (For new issue, give Commission Authorization numbers and dates) Amount of Premium or No. Debt Issued Discount

(a) (b) (c) 1 Advances from Associated Companies (Account 223) 2 Niagara Mohawk Holdings, Inc 5.8% Note, Due 11/01/2012 (Note 3) $500,000,000 3 Niagara Mohawk Holdings, Inc 3.83% Note, Due 06/30/2010 (Note 4) 350,000,000 4 5 6 7 8 Subtotal $850,000,000 $0 9 10 Other Long Term Debt (Account 224) 11 NYSERDA Adjustable Rate Notes: 12 Due 07/01/15 100,000,000 1,725,340 13 Due 12/01/23 69,800,000 646,808 14 Due 12/01/25 75,000,000 12,131,987 15 Due 12/01/26 50,000,000 603,701 16 Due 3/01/27 25,760,000 2,357,271 17 Due 07/01/27 93,200,000 1,225,501 18 19 Subtotal $413,760,000 $18,690,608 20 21 22 23 24 25 26 27 Note (1) - Redemption provisions follow NYSERDA Pollution Control Revenue Bonds per PSC Case 98-M-1236, dated 09/17/1998. 28 Note (2) - Redemption provisions follow NYSERDA Pollution Control Revenue Bonds per PSC Case 91-M-0640, dated 08/20/1992. 29 Note (3) - Interest Expense of $29,000,000 was recorded in PSC/FERC Account 430. 30 Note (4) - Interest Expense of $13,405,000 was recorded in PSC/FERC Account 430. 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 FERC FORM NO.1 (ED. 12-96) NYPSC Modified-96 Page 256-A Niagara Mohawk Power Corporation 6/01/2010 12/31/2009

LONG-TERM DEBT (Accounts 221, 222, 223, and 224) (Continued)

AMORTIZATION PERIOD Outstanding Nominal Date Date of (Total amount Interest for Year of Issue Maturity Date From Date To outstanding Amount Line without reduction No. for amounts held by respondent) (d) (e) (f) (g) (h) (i) 1 10/27/2003 11/1/2012 $500,000,000 $29,000,000 2 10/27/2003 6/30/2010 350,000,000 13,405,000 3 4 5 6 7 $850,000,000 $42,405,000 8 9 10 11 7/1/1985 7/1/2015 7/1/1985 7/1/2015 100,000,000 955,983 12 12/1/1988 12/1/2023 12/1/1988 12/1/2023 69,800,000 594,539 13 12/1/1985 12/1/2025 12/1/1985 12/1/2025 75,000,000 640,641 14 12/1/1986 12/1/2026 12/1/1986 12/1/2026 50,000,000 441,746 15 3/1/1987 3/1/2027 3/1/1987 3/1/2027 25,760,000 228,477 16 7/1/1987 7/1/2027 7/1/1987 7/1/2027 93,200,000 824,720 17 18 $413,760,000 $3,686,106 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 FERC FORM NO.1 (ED. 12-96) NYPSC Modified-96 Page 257-A Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Day, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009

RECONCILIATION OF REPORTED NET INCOME WITH TAXABLE INCOME FOR FEDERAL INCOME TAXES

1. Report the reconciliation of reported net income for the year with taxable income used in computing Federal income tax accruals and show computation of such tax accruals. Include in the reconciliation, as far as practicable, the same detail as furnished on Schedule M-1 of the tax return for the year. Submit a reconciliation even though there is no taxable income for the year. Indicate clearly the nature of each reconciling amount. 2. If the utility is a member of a group which files a consolidated Federal tax return, reconcile reported net income with taxable net income as if a separate return were to be filed, indicating, however, intercompany amounts to be eliminated in such consolidated return. State names of group members, tax assigned to each group member, and basis of allocation, assignment, or sharing of the consolidated tax among group members. 3. A substitute page, designed to meet a particular need of a company, may be used as long as the data is consistent and meets the requirements of the above instructions. For electronic reporting purposes complete line 27 and provide the substitute page in the context of a footnote. Line Particulars (Details) Amount No. (a) (b)

1 Net Income for the Year (Page 117) $122,237,156 2 Reconciling Items for the Year 3 4 Taxable Income Not Reported on Books 5 See Supporting Footnote 41,169,647 6 7 8 9 Deductions Recorded on Books Not Deducted for Return 10 See Supporting Footnote 873,076,748 11 12 13 14 Income Recorded on Books Not Included in Return 15 See Supporting Footnote 283,692 16 17 18 19 Deductions on Return Not Charged Against Book Income 20 See Supporting Footnote 674,916,537 21 22 23 24 25 26 27 Federal Tax Net Income $361,283,323 28 Show Computation of Tax: 29 Tax @ Statutory Rates: 137,500,449 30 Service Company Tax Allocation 3,065,789 31 Prior Period Adjustments & Allocation Items (322,523,765) 32 Provision for FIT (181,957,527) 33 34 Provision for Deferred FIT 526,300,284 35 Income Tax Deferred- Prior Year (312,768,154) 36 Total Federal Income Taxes 31,574,603 37 38 39 40 41 42 43 44

FERC FORM NO.1 (ED. 12-96) Page 261

If applicable, see insert pages below: Niagara Mohawk Power Corporation 6/01/2010 12/31/2009

RECONCILIATION OF REPORTED NET INCOME WITH TAXABLE INCOME FOR FEDERAL INCOME TAXES

Particulars (Details) Amount (a) (b) Taxable Income not Recorded on Books: Contribution In Aid of Construction 25,999,999 NYPA Hydropower Benefit Rentals 15,169,648 41,169,647

Expenses Recorded on Books not Included on Return: Amortization of Deferral Recoveries 123,588,117 Merger Rate Plan Stranded Costs 496,604,404 Pension 6,395,608 FAS106 OPEB Amortization 111,763,310 Economic Development Fund 14,379,414 CTC Reset Reserve 20,755,981 Deferred SBC Program Costs 19,202,281 Bad Debt Reserve 8,186,400 MCG - Tariff Customer Refund (2002) 11,047,426 Loss on Reaquired Debt 8,611,734 Postretirements Benefits 3,426,000 Rate Reserves 4,716,119 KS Merger Savings 13,956,374 Deferred Compensation 2,350,159 Fuel Deferral 2,127,359 Interest 2,165,837 Officer's Insurance 3,987,916 AFUDC Debt 811,796 Service Lost Revenues 1,098,474 Lobbying Expenses 983,000 80/20 Revenue Sharing Mechanism 489,182 State Taxes 16,429,857 873,076,748

Income Recorded on Books not included on Return: Tax Exempt Interest Income 283,692 283,692

FERC FORM NO.1 (ED. 12-88) Page 261-A Niagara Mohawk Power Corporation 6/01/2010 12/31/2009

RECONCILIATION OF REPORTED NET INCOME WITH TAXABLE INCOME FOR FEDERAL INCOME TAXES

Particulars (Details) Amount (a) (b) Deductions on Return not Charged Against Book Income: Depreciation Related Differences 271,058,523 Cost of Removal 11,996,696 Medicare Income 18,570,983 Amortization Expense 20,576,033 Casualty Loss 49,000,000 Pensions 123,752,109 SIR Expenditures Deferred - Electric & Gas 25,514,249 TCC Auction Revenues/Expenses (net) 62,478,258 Transmission Revenue Adjustment 10,389,105 Storm Contingency 5,621,151 Commodity Adjustment Clause 24,088,940 Exit Fees Deferred 2,539,126 ESOP Dividends 3,966,936 Stock Appreciation Rights 1,065,047 GRT Customer Refund 7,216,256 Gas Contingency Reserve 23,005,074 Other Reserves 9,404,192 Other 2,973,858 Environmental Insurance Recoveries 1,700,000 674,916,537

FERC FORM NO.1 (ED. 12-88) Page 261-B Name of Respondent (1) [ ] An Original (Mo, Day, Yr) Year of Report Niagara Mohawk Power Corporation (2) [ ] A Resubmission 6/01/2010 12/31/2009 TAXES ACCRUED, PREPAID AND CHARGED DURING YEAR 1. Give particulars (details) of the combined prepaid and accrued tax accounts and show the total taxes charged to operations and other accounts during the year. Do not include gasoline and other sales taxes which have been charged to the accounts to which the taxed material was charged. If the actual or estimated amounts of such taxes are known, show the amounts in a footnote and designate whether estimated or actual amounts. 2. Include on this page, taxes paid during the year and charged direct to final accounts, (not charged to prepaid or accrued taxes). Enter the amounts in both columns (d) and (e). The balancing of this page is not affected by the inclusion of these taxes. 3. Include in column (d) taxes charged during the year, taxes charged to operations and other accounts through (a) accruals credited to taxes accrued, (b) amounts credited to proportions of prepaid taxes chargeable to current year, and (c) taxes paid and charged direct to operations or accounts other than accrued and prepaid tax accounts. 4. List the aggregate of each kind of tax under the appropriate heading of "Federal," "State," and "Local" in such manner that the total tax for each State and subdivision can readily be ascertained. BALANCE BEGINNING OF YEAR Prepaid Taxes Kind of Tax Taxes Accrued (Include in Taxes Charged Taxes Paid Line (See Instruction 5) (Account 236) Account 165) During Year During Year Adjustments No. (a) (b) (c) (d) (e) (f) Federal: 1 Income Taxes $78,390,623 ($163,388,068) $163,421,422 ($44,249,343) 2 FICA Contribution (133,947) 25,053,622 24,612,368 3 Unemployment 4,930 234,751 235,019 4 Other 4,436,745 5 Total 78,261,606 0 (138,099,695) 188,268,809 (39,812,598) State: 6 Franchise - Gross Income - 186a 10,493,744 1,672,758 7,000,000 (8,318) 7 Franchise - Gross Earnings - 186 8,241,284 20,994,388 28,083,754 8 Franchise - Excess Dividends - 186 Temporary Surcharges 9 Sec. 186a (Gross Income) 10 Sec. 186 (Gross Earnings) 11 Sec. 186 (Excess Dividends) 12 MTA Surcharge 13 Unemployment Insurance 8,174 460,209 459,797 14 Disability Insurance 15 Sales and Use 926,929 5,115,555 3,721,495 16 Petroleum Business Tax - New York 17 Other 18 Total 9,176,387 15,609,299 23,127,355 39,265,046 (8,318) Local: 19 Real Estate 165,489,192 165,489,192 20 Special Franchise 21 Municipal Gross Income 1,361,709 13,628,582 13,303,153 22 NYC Special Franchise 23 Public Utility Excise 24 Sales and Use 671,224 3,704,368 2,694,876 25 Other 26 Total 2,032,933 3,704,368 179,117,774 181,487,221 0 Other (list): 27 Use Tax from STS (7,597,960) 28 29 30 31 32 33 34 35 36 37 38 39 40 TOTAL $89,470,926 $19,313,667 $64,145,434 $409,021,076 ($47,418,876)

FERC FORM NO.1 (ED. 12-96) NYPSC Modified-96 Page 262 Name of Respondent (1) [ ] An Original (Mo, Day, Yr) Year of Report Niagara Mohawk Power Corporation (2) [ ] A Resubmission 6/01/2010 12/31/2009 TAXES ACCRUED, PREPAID AND CHARGED DURING YEAR (Continued) 5. If any tax covers more than one year, show the required information separately for each tax year, identifying the year in column (a). 6. Enter all adjustments of the accrued and prepaid tax accounts in column (f) and explain each adjustment in a footnote. Designate debit adjustments by parentheses. 7. Do not include on this page entries with respect to deferred income taxes or taxes collected through payroll deductions or otherwise pending transmittal of such taxes to the taxing authority. 8. Report in columns (i) through (q) how the taxes were distributed.

9. For any tax apportioned to more than one utility department or account, state in a footnote the basis (necessity) of apportioning such tax.

BALANCE AT END OF YEAR DISTRIBUTION OF TAXES CHARGED (Show utility dept. where applicable and acct. charged.) Other Utility (Taxes Accrued Prepaid Taxes Electric Gas Other Utility Depts. Operating Income Account 236) (Incl. in Acct. 165) (Account 408.1,409.1) (Account 408.1,409.1) (Account 408.1,409.1) (Account 408.1,409.1) Line (g) (h) (i) (j) (k) (l) No.

$108,373,977 $316,980,246 ($179,099,920) $15,711,852 1 307,307 18,659,920 6,393,702 2 4,661 261,480 (26,729) 3 4 108,685,945 316,980,246 (160,178,520) 22,078,825 0 0 5

15,812,668 (1,666,694) 3,339,452 6 1,151,918 20,983,315 11,073 7 8

9 10 11 12 8,583 460,209 13 14 989,501 8,899,623 15 16 17 2,150,002 24,712,291 19,776,830 3,350,525 0 0 18

129,578,037 35,911,155 19 20 1,687,137 13,628,582 21 22 23 716,536 6,444,554 24 25 2,403,673 6,444,554 143,206,619 35,911,155 0 0 26

7,597,960 27 28 29 30 31 32 33 34 35 36 37 38 39 $120,837,580 $348,137,091 $2,804,929 $61,340,505 $0 $0 40

FERC FORM NO.1 (ED. 12-96) NYPSC Modified-96 Page 263 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Day, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 TAXES ACCRUED, PREPAID AND CHARGED DURING YEAR (Continued) DISTRIBUTION OF TAXES CHARGED (Show utility dept. where applicable and acct. charged.) Other Income Extraordinary Adjustment to Kind of Tax and Deductions Items Ret. Earnings Line (See Instruction 5) Account 408.2,409.2 (Account 409.3) (Account 439) Other Other No. (a) (m) (n) (o) (p) (q) Federal: 1 Income Taxes $299,200 2 FICA Contribution 3 Unemployment 4 Other 5 Total 299,200 0 0 0 0 State: 6 Franchise - Gross Income - 186a 72,773 7 Franchise - Gross Earnings - 186 8 Franchise - Excess Dividends - 186 Temporary Surcharges 9 Sec. 186a (Gross Income) 10 Sec. 186 (Gross Earnings) 11 Sec. 186 (Excess Dividends) 12 MTA Surcharge 13 Unemployment Insurance 14 Disability Insurance 15 Sales and Use 16 Petroleum Business Tax - New York 17 Other 18 Total 72,773 0 0 0 0 Local: 19 Real Estate 20 Special Franchise 21 Municipal Gross Income 22 NYC Special Franchise 23 Public Utility Excise 24 Sales and Use 25 Other 26 Total 0 0 0 0 0 Other (list): 27 28 29 30 31 32 33 34 35 36 37 38 39 40 TOTAL $371,973 $0 $0 $0 $0

FERC FORM NO.1 (ED. 12-96) NYPSC Modified-96 Page 262-A NOTES:

Page 262, line 6, column d: Taxes Charged During the Year: Current Year 5,324,571 2008 Amended True up (3,651,813) 1,672,758

Page 262, line 6, column f: Adjustments: Other states not charged to 408.1, 409.1 (8,318)

(8,318)

Page 262, line 1, column d:

Taxes Charged During the Year: Current Year 137,500,449 Service Company Allocation 3,065,789 2008 and 2009 True-up (303,954,306) (163,388,068)

Page 262, line 1, column f: Adjustments: - Reclass fin 48 (47,315,132) Service Company Taxes booked directly to P& 3,065,789 (44,249,343)

NYPSC Modified-96 Next Page is 266 Page 263-A Name of Respondent This Report Is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 ACCUMULATED DEFERRED INVESTMENT TAX CREDITS (Account 255) for Electric, Gas, Common, and non-utility respectively Report below information applicable to Account 255. Where appropriate, segregate the balances and transactions by utility and nonutility operations. Explain by footnote any correction adjustments to the account balance shown in column (g). Include in column (i) the average period over which the tax credits are amortized.

Line Deferred Allocations to No. Balance at for Year Current Year's Income Account Beginning Account Account Subdivisions of Year No. Amount No. Amount Adjustments (a) (b) (c) (d) (e) (f) (g) 1 Electric Utility 23% 34% 47% 5 10% 24,757,597 420 2,435,635 6 7 8 9 10 11 12 SUBTOTAL $24,757,597 $0 $2,435,635 $0 13 Gas Utility 14 3% 15 4% 172,000 420 19,955 16 7% 5,152,000 420 562,910 17 10% 18 19 20 21 22 23 24 SUBTOTAL $5,324,000 $0 $582,865 $0 25 Common Utility 26 3% 27 4% 28 7% 29 3% 30 31 32 33 34 35 36 SUBTOTAL $0 $0 $0 $0 37 Nonutility 38 3% 39 4% 40 7% 41 10% 42 43 44 45 46 47 SUBTOTAL $0 $0 $0 $0 48 TOTAL $30,081,597 $0 $3,018,500 $0

FERC FORM NO.1 (ED. 12-89) NYPSC Modified-96 Page 266 If applicable, see insert page below.

Name of Respondent This Report Is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 ACCUMULATED DEFERRED INVESTMENT TAX CREDITS (Account 255) for Electric, Gas, Common, and non-utility respectively Report below information applicable to Account 255. Where appropriate, segregate the balances and transactions by utility and nonutility operations. Explain by footnote any correction adjustments to the account balance shown in column (g). Include in column (i) the average period over which the tax credits are amortized.

Line Deferred Allocations to No. Balance at for Year Current Year's Income Account Beginning Account Account Subdivisions of Year No. Amount No. Amount Adjustments (a) (b) (c) (d) (e) (f) (g) 1 Electric Utility 23% 34% 47% 5 10% 6 7 8 9 10 11 12 SUBTOTAL $0 $0 $0 $0 13 Gas Utility 14 3% 15 4% 16 7% 17 10% 18 19 20 21 22 23 24 SUBTOTAL $0 $0 $0 $0 25 Common Utility 26 3% 27 4% 28 7% 29 3% 30 31 32 33 34 35 36 SUBTOTAL $0 $0 $0 $0 37 Nonutility 38 3% 39 4% 40 7% 41 10% 42 43 44 45 46 47 SUBTOTAL $0 $0 $0 $0 48 TOTAL $0 $0 $0 $0

FERC FORM NO.1 (ED. 12-89) NYPSC Modified-96 Page 266-A Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 ACCUMULATED DEFERRED INVESTMENT TAX CREDITS (Account 255) for Electric, Gas, Common, and non-utility respectively (Continued)

Adjustment Explanation Line Balance at Average Period No. End of Allocation Year to Income (h) (i) 1 $0 2 0 3 0 4 22,321,962 5 0 6 0 7 0 8 0 9 0 10 0 11 $22,321,962 12 13 0 14 152,045 15 4,589,090 16 0 17 0 18 0 19 0 20 0 21 0 22 0 23 $4,741,135 24 25 0 26 0 27 0 28 0 29 0 30 0 31 0 32 0 33 0 34 0 35 $0 36 37 $0 38 0 39 0 40 0 41 0 42 0 43 0 44 0 45 0 46 $0 47 $27,063,097 48

FERC FORM NO.1 (ED. 12-89) NYPSC Modified-96 Next Page is 269 Page 267 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 ACCUMULATED DEFERRED INVESTMENT TAX CREDITS (Account 255) for Electric, Gas, Common, and non-utility respectively (Continued)

Adjustment Explanation Line Balance at Average Period No. End of Allocation Year to Income (h) (i) 1 $0 2 0 3 0 4 0 5 0 6 0 7 0 8 0 9 0 10 0 11 $0 12 13 0 14 0 15 0 16 0 17 0 18 0 19 0 20 0 21 0 22 0 23 $0 24 25 0 26 0 27 0 28 0 29 0 30 0 31 0 32 0 33 0 34 0 35 $0 36 37 $0 38 0 39 0 40 0 41 0 42 0 43 0 44 0 45 0 46 $0 47 $0 48

FERC FORM NO.1 (ED. 12-89) NYPSC Modified-96 Next Page is 269 Page 267-A Name of Respondent This Report Is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 OTHER DEFERRED CREDITS (Account 253) 1. Report below the particulars (details) called for concerning other deferred credits. 2. For any deferred credit being amortized, show the period of amortization. 3. Minor items (5% of the Balance of End of Year for Account 253 or amounts less than $10,000, whichever is greater) may be grouped by classes. Balance at Debits Balance at Description of Other Beginning Contra Credits End of Year Line Deferred Credits of Year Account Amount No. (a) (b) (c) (d) (e) (f) 1 Energy Service Company Deposits $1,647,925 $0 $0 $1,647,925 2 3 Unregulated Generator Capital 4 Work Reimbursement 10,728,687 Various 675,760 431,791 10,484,718 5 6 Capital Work Reimbursement 705,693 0 0 705,693 7 8 Pension AML 0 0 0 0 9 10 NYS Gross Receipts Tax Audit 11 Refund 0 0 0 0 12 13 Transmission Congestion 14 Contract Auction Revenues 0 0 0 0 15 16 Demutualization - UMICO Holdings 1,128,420 0 0 1,128,420 17 18 Liability for Environmental 19 Restoration Costs 439,041,718 182 47,917,488 57,582,960 448,707,190 20 21 Supplemental Executive 22 Retirement Plan Liability 3,584,744 Various 1,594,431 2,748,009 4,738,322 23 24 FAS 106 797,904,447 131/128/182 92,340,090 137,984,812 843,549,169 25 26 Liability for Nuclear Fuel 27 Disposal Costs 167,029,060 0 235,628 167,264,688 28 29 All Other 4,341,825 Various 4,304,557 4,331,947 4,369,215 30 31 Accrued Pension (97,991,906) 131 198,669,504 343,243,444 46,582,034 32 33 Other Post Employment Benefit 34 Liability 31,918,310 926 2,628,888 927,354 30,216,776 35 36 Def Incentive Comp - Pensions 7,812,630 128 3,608,222 1,867,307 6,071,715 37 38 Fin48Sit - Timing Issues 1,177,042 0 0 1,177,042 39 Fin48Fit - Permanent Issues 63,430,539 114 47,315,132 0 16,115,407 40 Fin48Sit - Permanent Issues 9,404,416 114 9,404,192 0 224 41 Long Term Interest Payable 38,441,023 431 23,644,369 5,820,445 20,617,099 42 NYPA-Tri-Lakes 22,347,312 28,945,185 45,371,216 38,773,343 43 0 44 0 45 0 46 From Insert Page A 0 0 0 0 47 TOTAL $1,502,651,885 $461,047,818 $600,544,913 $1,642,148,980 FERC FORM NO. 1 (ED. 12-88) Next Page is 272 Page 269 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 ACCUMULATED DEFERRED INCOME TAXES-ACCELERATED AMORTIZATION PROPERTY (Account 281) 1. Report the information called for below concerning the respondent's accounting for deferred income taxes relating to amortizable property 2. For Other (Specify), include deferrals relating to other income and deductions. CHANGES DURING YEAR Balance at Amounts Amounts Line Account Beginning Debited To Credited To No. of Year Account 410.1 Account 411.1 (a) (b) (c) (d) 1 Accelerated Amortization (Account 281) 2 Electric 3 Defense Facilities 4 Pollution Control Facilities 5 Other 6 7 8 TOTAL Electric (Enter Total of lines 3 thru 7) $0 $0 $0 9 Gas 10 Defense Facilities 11 Pollution Control Facilities 12 Other 13 14 15 TOTAL Gas (Enter Total of lines 10 thru 14) 0 0 0 16 Other (Specify) 17 TOTAL (Account 281)(Total of 8, 15 and 16) $0 $0 $0

18 Classification of TOTAL 19 Federal Income Tax 20 State Income Tax 21 Local Income Tax NOTES

FERC FORM NO.1 (ED 12-96) Page 272 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 ACCUMULATED DEFERRED INCOME TAXES-ACCELERATED AMORTIZATION PROPERTY (Account 281) (Continued) 3. Use footnotes as required.

CHANGES DURING YEAR ADJUSTMENTS Amounts Amounts Debits Credits Balance at Debited To Credited To Acct. Acct. End of Year Line Account 410.2 Account 411.2 Credited Amount Debited Amount No. (e) (f) (g) (h) (i) (j) (k) 1 2 $0 3 04 05 06 07 $0 $0 $0 $0 $0 8 9 $0 10 011 012 013 014 0000015 016 $0 $0 $0 $0 $0 17

18 $0 19 020 $0 21 NOTES (Continued)

FERC FORM NO.1 (ED 12-96) Page 273 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009

ACCUMULATED DEFERRED INCOME TAXES - OTHER PROPERTY (Account 282)

1. Report the information called for below concerning the respondent's accounting for deferred income taxes relating to property not subject to accelerated amortization. 2. For Other (Specify), include deferrals relating to other income and deductions.

CHANGES DURING YEAR

Balance at Amounts Amounts Line Account Subdivisions Beginning Debited To Credited To No. of Year Account 410.1 Account 411.1 (a) (b) (c) (d) 1 Account 282 2 Electric $783,203,946 $299,581,325 3 Gas 283,414,786 70,065,156 4 Other (Define) 5 TOTAL (Enter Total of lines 2 thru 4) 1,066,618,732 369,646,481 0 6 Other (Specify) 7 8 9 TOTAL Account 282 (Enter Total of lines 5 thru 8) $1,066,618,732 $369,646,481 $0

10 Classification of TOTAL 11 Federal Income Tax $1,066,771,819 $357,461,180 12 State Income Tax (153,087) 12,185,301 13 Local Income Tax NOTES

FERC FORM NO.1 (ED 12-96) Page 274 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009

ACCUMULATED DEFERRED INCOME TAXES - OTHER PROPERTY (Account 282) (Continued)

3. Use separate pages as required.

CHANGES DURING YEAR ADJUSTMENTS Debits Credits Balance at Amounts Amounts End of Year Debited To Credited To Account Amount Account Amount Line Account 410.2 Account 411.2 Credited Debited No. (e) (f) (g) (h) (i) (j) (k) 1 $1,082,785,271 2 353,479,942 3 04 0 0 0 0 1,436,265,213 5 06 07 08 $0 $0 $0 $0 $1,436,265,213 9

10 $1,424,232,999 11 12,032,214 12 $0 13 NOTES (Continued)

FERC FORM NO.1 (ED 12-96) Page 275 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 ACCUMULATED DEFERRED INCOME TAXES - OTHER (Account 283)

1. Report the information called for below concerning the respondent's accounting for deferred income taxes relating to amounts recorded in Account 283. 2. For Other (Specify), include deferrals relating to other income and deductions.

CHANGES DURING YEAR Line Balance at Amounts Amounts No. Account Subdivisions Beginning Debited To Credited To of Year Account 410.1 Account 411.1 (a) (b) (c) (d) 1 Account 283 2 Electric 3 See Supporting Detail Pages $1,274,361,700 $186,429,277 $273,774,130 4 5 6 7 8 Other 9 TOTAL Electric (Total of lines 3 thru 8) $1,274,361,700 $186,429,277 $273,774,130 10 Gas 11 See Supporting Detail Pages $77,676,649 $36,284,186 $12,962,882 12 13 14 15 16 Other 17 TOTAL Gas (Total of lines 11 thru 16) $77,676,649 $36,284,186 $12,962,882 18 Other (Specify) 19 TOTAL (Acct 283) (Enter Total of Lines 9,17 and 18) $1,352,038,349 $222,713,463 $286,737,012 20 Classification of TOTAL

21 Federal Income Tax $1,184,669,632 $173,759,467 $221,879,129 22 State Income Tax 167,368,717 48,953,996 64,857,883 23 Local Income Tax NOTES

FERC FORM NO.1 (ED. 12-96) Page 276

If applicable, see insert page below: Niagara Mohawk Power Corporation 6/01/2010 12/31/2009 ACCUMULATED DEFERRED INCOME TAXES - OTHER (Account 283)

CHANGES DURING YEAR Line Balance at Amounts Amounts No. Account Subdivisions Beginning Debited To Credited To of Year Account 410.1 Account 411.1 (a) (b) (c) (d) 1 Account 283 2 Electric 3 Accrued Income Taxes $20,220,655 $0 $0 4Bad Debts 000 5 Deferred Compensation 2,000 0 0 6 Derivatives (2,991,100) 0 0 7 FAS 109 (4,180,008) 0 0 8 OPEB Liability 0 0 42,825,580 9 Pension Liability 37,000 4,641,892 0 10 Property Related 0 32,090,733 0 11 Rabbi Trust (5,056,354) 0 3,193 12 Reg Asset - Environmental 227,813,000 12,953,682 0 13 Reg Asset - Merger Rate Stranded 589,099,000 0 173,393,355 14 Reg Asset - Pension/OPEB 401,360,169 104,739,668 2,244,837 15 Reg Asset - Storm Cost 63,285,000 2,366,505 0 16 Regulatory Assets (39,467,000) 81,292 51,960,747 17 Regulatory Assets - X Rate Base 2,697,340 15,195,583 0 18 Unamortized Debt Discount or Premium 18,431,000 0 2,650,341 19 Unbilled Revenue 0 0 0 20 Property Tax 2,640,998 0 0 21 Other Items 470,000 14,359,922 696,077 22 23 24 TOTAL Electric $1,274,361,700 $186,429,277 $273,774,130 25 Gas 26 Accrued Income Taxes $0 $0 $0 27 Bad Debts 0 0 0 28 Deferred Compensation 0 0 0 29 Derivatives 4,603,622 0 0 30 FAS 109 (40,531,308) 0 0 31 OPEB Liability 0 0 8,772,503 32 Pension Liability 3,000 0 0 33 Property Related 0 0 0 34 Rabbi Trust (979,733) 0 654 35 Reg Asset - Environmental 2,704,000 0 2,212,183 36 Reg Asset - Merger Rate Stranded 0 0 0 37 Reg Asset - Pension/OPEB 75,290,068 21,452,703 459,786 38 Reg Asset - Storm Cost 0 0 0 39 Regulatory Assets 15,246,000 16,650 1,330,480 40 Regulatory Assets - X Rate Base 20,156,000 4,955,262 0 41 Unamortized Debt Discount or Premium 1,551,000 0 187,276 42 Unbilled Revenue 389,000 9,859,571 0 43 Property Tax 0 0 0 44 Other Items (755,000) 0 0 45 TOTAL Gas $77,676,649 $36,284,186 $12,962,882 46 Other 47 48 49 50 51 52 53 54 TOTAL Other $0 $0 $0

Page 276-A Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 ACCUMULATED DEFERRED INCOME TAXES - OTHER (Account 283) (Continued)

3. Provide in the space below explanations for pages 276 and 277. Include amounts relating to insignificant items listed under Other. 4. Use footnotes as required.

CHANGES DURING YEAR ADJUSTMENTS Amounts Amounts Debits Credits Balance at Line Debited To Credited To Acct. Amount Acct. Amount End of Year No. Account 410.2 Account 411.2 Credited Debited (e) (f) (g) (h) (i) (j) (k) 1 2 $1,187,016,847 3 04 05 06 07 08 $0 $0 $0 $0 $1,187,016,847 9 10 $100,997,953 11 012 013 014 015 016 $0 $0 $0 $0 $100,997,953 17 018 $0 $0 $0 $0 $1,288,014,800 19 20

$1,136,549,970 21 151,464,830 22 $0 23 NOTES (Continued)

FERC FORM NO.1 (ED. 12-96) Page 277 Niagara Mohawk Power Corporation 6/01/2010 12/31/2009 ACCUMULATED DEFERRED INCOME TAXES - OTHER (Account 283) (Continued)

CHANGES DURING YEAR ADJUSTMENTS Amounts Amounts Debits Credits Balance at Line Debited To Credited To Acct. Amount Acct. Amount End of Year No. Account 410.2 Account 411.2 Credited Debited (e) (f) (g) (h) (i) (j) (k) 1 2 $20,220,655 3 04 2,000 5 (2,991,100) 6 (4,180,008) 7 (42,825,580) 8 4,678,892 9 32,090,733 10 (5,059,547) 11 240,766,682 12 415,705,645 13 503,855,000 14 65,651,505 15 (91,346,455) 16 17,892,923 17 15,780,659 18 019 2,640,998 20 14,133,845 21 022 023 $0 $0 $0 $0 $1,187,016,847 24 25 $0 26 027 028 4,603,622 29 (40,531,308) 30 (8,772,503) 31 3,000 32 033 (980,387) 34 491,817 35 036 96,282,985 37 038 13,932,170 39 25,111,262 40 1,363,724 41 10,248,571 42 043 (755,000) 44 $0 $0 $0 $0 $100,997,953 45 46 $0 47 048 049 050 051 052 053 $0 $0 $0 $0 $0 54

Page 277-A Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 OTHER REGULATORY LIABILITIES (Account 254)

1. Reporting below the particulars (details) called for concerning other regulatory liabilities which are created through the ratemaking actions of regulatory agencies (and not includable in other amounts). 2. For regulatory liabilities being amortized, show period of amortization in column (a). 3. Minor items (5% of the Balance at End of Year for Account 254 or amounts less than $50,000, whichever is less) may be grouped by classes.

DEBITS Description and Purpose of Account Amount Credits Balance Line Other Regulatory Liabilities Credited End of Year No. (a) (b) (c) (d) (e) 1 Proceeds from Sale of Emissions Allowances $0 $90,100 $1,907,035 2 3 Clean Air Act- Roseton 0 8,400 179,080 4 5 Purchase of Emission Reduction Credits 0 0 951,300 6 7 Federal Reg. Liab (SFAS 109) 190 1,003,100 0 17,730,552 8 9 Gain on Redemption of 8.35 Series Bond 429 60,460 0 361,386 10 11 IRS Audit Refund 0 0 307,485 12 13 Unbilled Gas Revenue 173 0 1,947,000 18,799,000 14 15 Gas Non-core Revenue Sharing 182 3,262,986 3,450,417 1,134,706 16 17 Electric Customer Service Penalty 426/456 1,006,262 992,500 23,999,476 18 19 Gas Contingency Reserve 182/431/488/ 25,998,391 2,993,317 1,150,156 20 21 IBM Customer System Settlement Agreement182 1,089,715 0 0 22 23 Environment Insurance Recoveries 930 1,700,000 0 4,741,379 24 25 Powerchocie Appendex E Netting Proposal 0 0 79,599,407 26 27 Electric Revenue Property Tax Credit 0 1,537,661 1,537,661 28 29 MRA Interest Rate Savigns 0 0 92,534,022 30 31 Petroleum Bus tax Audit Refund 0 0 5,752,659 32 33 Exit Fees 456 2,799,427 260,301 2,682,388 34 35 Affiliate Rule Employee Transfer Credit 0 0 166,725 36 37 38 From Insert Page A 75,000,185 95,106,243 273,501,430 39 From Insert Page B 94,632,436 152,691,383 58,197,996 40 41 TOTAL $206,552,962 $259,077,322 $585,233,843

FERC FORM NO.1 (ED. 12-94) Next Page is 300 Page 278

If applicable, see insert page below: Niagara Mohawk Power Corporation 6/01/2010 12/31/2009

OTHER REGULATORY LIABILITIES (Account 254)

DEBITS Description and Purpose of Account Amount Credits Balance Line Other Regulatory Liabilities Credited End of Year No. (a) (b) (c) (d) (e) 1 Pension / OPEB Curtailment Gains $0 $0 $25,552,091 2 3 IRS Audit Refund 0 0 48,100 4 5 NYPA ISO Memeorandum of Understanding 0 0 16,676,906 6 7 State Reg. Liabiltiy (SFAS 109) 190 39,000 222,000 32,664,135 8 9 Diana Dolgeville- IPP Settlement 0 0 4,922,128 10 11 Electric Service Reestablishment Charges 0 0 464,158 12 13 Commodity Adjustment Clause 0 0 0 14 15 Merger Rate Plan Delay 0 0 12,555,000 16 17 Incidental Service Revenues Deferred 451 30 111,931 508,073 18 19 New York State Sales Tax Refund 0 0 1,477,332 20 21 Economic Development Fund Various 3,710,084 18,089,498 38,083,976 22 23 Meter Read Connect/ Disconnect Service Chg 0 4,353 128,205 24 25 GRT Customer Refund - Electric 0 0 0 26 27 GRT Customer Refund - Gas 182 7,732,956 516,700 376,415 28 29 Gas Millenium Fund Deferral 495/885 2,255 86,037 218,703 30 31 NYPA Residential Hydropower Benefit 182/456/550 39,721,015 32,982,082 15,169,647 32 33 Bonus Depreciation Adjustment 182/431/495 9,174,003 3,882,545 25,093,881 34 35 Loss on Sale of Building 182/431/495 209,385 558,445 2,914,369 36 37 Medicare Act Tax Benefit 182 14,106,439 18,008,053 73,398,363 38 39 Electric R&D Ventures Deferral 0 375 28,707 40 41 Gas R&D Ventures Deferral 182 305,018 263 (1) 42 43 SBC Program Cost 456 0 20,643,961 23,221,242 44 45 RPS Program Cost Deferred 0 0 0 46 47 Other Gas Futures 0 0 0 48 49 TOTAL $75,000,185 $95,106,243 $273,501,430

FERC FORM NO.1 (ED. 12-94) Next Page is 300 Page 278-A Niagara Mohawk Power Corporation 12/31/2009

OTHER REGULATORY LIABILITIES (Account 254)

DEBITS Description and Purpose of Account Amount Credits Balance Line Other Regulatory Liabilities Credited End of Year No. (a) (b) (c) (d) (e) 1 Trans Revenue Adjustment Clause 419456 $32,139,784 $21,750,679 $0 2 3 Pension/OPEB interest on Recovery 0 0 4,145,621 4 5 STA Service Sale Growth Deferral 0 0 2,350,188 6 7 GRT Aud Ref (91-94) Electric 0 0 3,300,423 8 9 GRT Aud Ref (91-94) Gas 675,990 0 0 10 11 MHP Program Deferral 0 138,976 435,316 12 13 SERV Aggreg Lost Revenues 456 65,284 75,657 155,664 14 15 NEG Merger Savings 0 2,974,005 4,250,591 16 17 Gas Customer Service Penalty 182/495 678,435 199,000 83,748 18 19 CTC Reset Reserve 253 1 20,755,982 0 20 21 KS Merger Savings- Electric 0 8,467,229 5,153,183 22 23 Gas Futures- Gas Supply 175 25,354,773 28,638,251 3,638,195 24 25 Electric Swaps - Electric Supply 176 152,160 248,160 96,000 26 27 KS Merger Savings- Gas 0 2,211,956 1,559,261 28 29 Voltage Migration Fee Deferral 456 1,368 0 18,448 30 31 CSS Conv Saving Dist 456 194,321 250,016 1,400,206 32 33 Long Term Debt true up 495 0 5,413,194 5,413,194 34 35 Gratwick Park Prop Transf 0 1,829 1,829 36 37 Fed Tax Refund 1991-1996 456/495 13,136,221 39,095,233 25,959,012 38 39 CSS Conv Savings Gas 495 0 237,117 237,117 40 41 SBC Program Cost Deferred 182/456 254,244 254,244 0 42 43 SBC Program Cost Deferred- Gas 182/495 0 0 0 44 45 Gas Surcharge/ Ref Adjustment Deferral 182 11,076,221 11,076,221 0 46 47 Commodity Adjustment Clause 182/431 10,903,634 10,903,634 0 48 49 TOTAL $94,632,436 $152,691,383 $58,197,996

FERC FORM NO.1 (ED. 12-94) Next Page is 300 Page 278-B Name of Respondent This Report Is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 ELECTRIC OPERATING REVENUES (ACCOUNT 400)

1. Report below operating revenues for each prescribed account, of twelve figures at the close of each month. and manufactured gas revenues in total. 3. If increases or decreases from previous 2. Report number of customers, columns (f) and (g), on the basis year (columns (c), (e), and (g)), are not of meters, in addition to the number of flat rate accounts; except that derived from previously reported figures, where separate meter readings are added for billing purposes, one explain any inconsistencies in a footnote. customer should be counted for each group of meters added. The average number of customers means the average

OPERATING REVENUES Line Title of Account Amount for Year Amount for Previous Year No. (a) (b) (c) 1 Sales of Electricity 2 (440) Residential Sales $1,399,401,703 $1,489,141,455 3 (442) Commercial and Industrial Sales 4 Small (or Commercial) (See Instr. 4) 486,504,548 673,537,238 5 Large (or Industrial) (See Instr. 4) 188,727,396 286,851,543 6 (444) Public Street and Highway Lighting 29,547,898 32,069,099 7 (445) Other Sales to Public Authorities 8 (446) Sales to Railroads and Railways 9 (448) Interdepartmental Sales 10 TOTAL Sales to Ultimate Consumers 2,104,181,545 2,481,599,335 11 (447) Sales for Resale 20,379,897 37,241,266 12 TOTAL Sales of Electricity 2,124,561,442 2,518,840,601 13 (Less) (449.1) Provision for Rate Refunds 14 TOTAL Revenues Net of Provision for Refunds 2,124,561,442 2,518,840,601 15 Other Operating Revenues 16 (450) Forfeited Discounts 14,977,010 17,921,036 17 (451) Miscellaneous Service Revenues 2,230,866 2,538,804 18 (453) Sales of Water and Water Power 19 (454) Rent from Electric Property 12,777,824 12,592,114 20 (455) Interdepartmental Rents 21 (456) Other Electric Revenues 676,030,611 647,053,475 22 (456.1_ Revenues from Transmission of Electricity of Others 146,522,819 129,870,418 23 24 25 26 TOTAL Other Operating Revenues 852,539,130 809,975,848 27 TOTAL Electric Operating Revenues $2,977,100,572 $3,328,816,448

FERC FORM NO.1 (ED. 12-96) Page 300 Name of Respondent This Report Is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 ELECTRIC OPERATING REVENUES (ACCOUNT 400) (Continued)

4. Commercial and Industrial Sales, Account 442, may 5. See pages 108-109, Important Changes During Year, for be classified according to the basis of classification important new territory added and important rate increases (Small or Commercial, and Large or Industrial) regularly or decreases. used by the respondent if such basis of classification 6. For lines 2, 4, 5, and 6, see page 304 for amounts is not generally greater than 1000 Kw of demand. (See relating to unbilled revenue by accounts. Account 442 of the Uniform System of Accounts. Explain 7. Include unmetered sales. Provide details of such sales basis of classification in a footnote). in a footnote.

MEGAWATT HOURS SOLD AVG. NO. CUSTOMERS PER MONTH Amount for Year Amount for Previous Year Number for Year Number for Previous Year Line

(d) (e) (f) (g) No. 1 9,360,205 9,636,989 1,245,334 1,273,848 2 3 3,967,532 4,295,294 100,198 109,107 4 4,861,099 5,689,199 728 742 5 109,299 108,572 4,002 4,051 6 7 8 9 18,298,135 19,730,054 1,350,262 1,387,748 10 507,781 493,164 131 127 11 18,805,916 20,223,218 1,350,393 1,387,875 12 13 18,805,916 20,223,218 1,350,393 1,387,875 14

Line 12, Column (b) includes $____0_____ of unbilled revenues.

Line 12 Column (d) includes _____0_____ MWH relating to unbilled revenues.

FERC FORM NO.1 (ED. 12-96) Next Page is 304 Page 301 This Report Is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 SALES OF ELECTRICITY BY RATE SCHEDULES 1. Report below for each rate schedule in effect during tion (such as a general residential schedule and an off the year the MWh of electricity sold, revenue, average peak water heating schedule), the entries in column (d) for number of customers, average KWh per customer, and average the special schedule should denote the duplication in revenue per KWh, excluding data for Sales for Resale which number of reported customers. is reported on pages 310-311. 4. The average number of customers should be the 2. Provide a subheading and total for each prescribed number of bills rendered during the year divided by the operating revenue account in the sequence followed in number of billing periods during the year (12 if all billings "Electric Operating Revenues," pages 300-301. If the sales are made monthly). under any rate schedule are classified in more than one 5. For any rate schedule having a fuel adjustment revenue account, list the rate schedule and sales data under clause state in a footnote the estimated additional revenue each applicable revenue account subheading. billed pursuant thereto. 3. Where the same customers are served under more than 6. Report amount of unbilled revenue as of end of year one rate schedule in the same revenue account classifica- for each applicable revenue account subheading. Line Average Number KWh of Sales Revenue per No. Number and Title of Rate Schedule MWh Sold Revenue of Customers per Customer KWh Sold (a) (b) (c) (d) (e) (f) 1 213-S.C.1 2,828 $584,683 2,359 1,199 $0.2067 2 207-S.C.1 9,135,892 1,373,075,669 1,239,059 7,373 0.1503 3 207-S.C.1b 4 207-S.C.1c 209,980 23,721,842 4,660 45,060 0.1130 5 207-S.C.2 Demand 4,902 649,899 104 47,135 0.1326 6 207-S.C.2 Non-Demand 6,603 1,369,610 1,510 4,373 0.2074 7 207-S.C.3 8 207-S.C.7 9 Subtotal (Account 440) 9,360,205 1,399,401,703 1,247,692 7,502 0.1495 10 11 COMMERCIAL AND INDUSTRIAL: 12 Sch. 213 S.C.1 15,833 2,992,184 3,804 4,162 0.1890 13 Sch. 207 S.C.2 Demand 1,953,298 240,261,056 25,575 76,375 0.1230 14 Sch. 207 S.C.2 Non-Demand 411,705 78,266,770 73,925 5,569 0.1901 15 Sch. 207 S.C.3 1,463,583 165,027,368 1,249 1,171,804 0.1128 16 Sch. 207 S.C.3a 474,152 34,197,147 37 12,814,919 0.0721 17 Sch. 207 S.C.4 47,504 5,246,214 51 931,451 0.1104 18 Sch. 207 S.C.7 77,403 7,768,557 27 2,866,778 0.1004 19 Sch. 207 S.C.11 331,017 24,957,000 26 12,731,423 0.0754 20 Sch. 207 S.C.12 296,452 20,525,462 14 21,175,143 0.0692 21 NYPA-Contracts NS-1 3,757,119 95,941,891 0.0255 22 Special Contracts 566 48,296 0.0853 23 Subtotal (Account 442) 8,828,632 675,231,945 104,708 84,317 0.0765 24 25 PUBLIC STREET & HIGHWAY: 26 Sch. 213 S.C.2 92,361 27,460,252 1,052 87,796 0.2973 27 Sch. 213 S.C.3 3,357 352,620 131 25,626 0.1050 28 Special Contracts 13,580 1,735,025 2,820 4,816 0.1278 29 30 Subtotal (Account 444) 109,298 29,547,897 4,003 27,304 0.2703 31 32 Other Revenues: 33 Forfeited Discounts (AC 450) 14,977,010 34 Miscellaneous Service Revenues (AC 451) 2,230,866 35 Rent from Electric Properties (AC 454) 12,777,824 36 Other Electric Revenues (AC 456) 146,522,819 37 Revenues from Transmision of Electricity of Others (456.1) 676,030,611 38 Subtotal - Other Revenues 852,539,130 39 40 41 Total Billed 18,298,135 2,956,720,675 1,356,403 13,490 0.1616 42 Total Unbilled Rev. (See Instr. 6) 0 0 0 43 TOTAL 18,298,135 $2,956,720,675 1,356,403 13,490 0.1616

FERC FORM NO. 1 (ED. 12-95) Next Page is 310 Page 304 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 SALES FOR RESALE (Account 447)

1. Report all sales for resale (i.e. sales to purchasers other than ultimate consumers) transacted on a settlement basis other than power exchanges during the year. Do not report exchanges of electricity (i.e.., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on the Purchased Power schedule (pages 326-327).

2. Enter the name of the purchaser in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the purchaser.

3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (ie., the supplier includes projected load for this service in its system resource planning). In addition, the reliability of requirements service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for long-term service, "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g.., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service which meets the definition of RQ service. For all transactions identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service except that "intermediate-term" means longer than one year but less than five years. SF - for short-term firm service. Use this category for all firm services where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service except that "intermediate-term" means longer than one year but less than five years.

Actual Demand (MW) Name of Company FERC Rate Average Average Average Line or Public Authority Statistical Schedule or Monthly Billing Monthly Monthly No. (Footnote Affiliations) Classification Tariff Number Demand (MW) NCP Demand CP Demand (a) (b) (c) (d) (e) (f) 1 RQ Statistical Classifications: 2 Borderline Sales RQ Various 3 4 Non-RQ Statistical Classifications: 5 NON-ESCO's 6 7 New York Independent System OperatoOS ISO-MKT-SVC 8 9 10 11 Subtotal - RQ's 12 Subtotal - Non-RQ's 13 14 Total

FERC FORM NO.1 (REVISED. 12-90) NYPSC Modified-96 Page 310 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 SALES FOR RESALE (Account 447) (Continued)

OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the length of the contract and service from designated units of less than one year. Describe the nature of the service in a footnote. AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. Group requirements RQ sales together and report them starting at line number one. After listing all RG sales, enter "Subtotal - RQ" in column (a). The remaining sales may then be listed in any order. Enter "Subtotal-Non-RQ" in column (a) after this listing. Enter "Total" in column (a) as the last line of the schedule. Report subtotals and total for columns (g) through (k). 5. In column (c), identify the FERC Rate Schedule or Tariff Number. On separate lines, list all FERC rate schedules or tariffs under which service, as identified in column (b), is provided. 6. For requirements RQ sales and any type of service involving demand charges imposed on a monthly (or longer) basis, enter the average monthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 7. Report in column (g) the megawatthours shown on bills rendered to the purchaser. 8. Report demand charges in column (h), energy charges in column (i), and the total of any other types of charges, including out-of-period adjustment, in column (j). Explain in a footnote all components of the amount shown in column (j). Report in column (k) the total charge shown on bills rendered to the purchaser. 9. The data in column (g) through (k) must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4), and then totaled on the last line of the schedule. The "Subtotal - RQ" amount in column (g) must be reported as Requirements Sales for Resale on page 401, line 23. The "Subtotal - Non-RQ" amount in column (g) must be reported as Non- Requirements Sales for Resale on page 401, line 24. 10. Footnote entries as required and provide explanations following all required data.

REVENUE

Megawatthours Demand Charges Energy Charges Other Charges Total ($) Line Sold ($) ($) ($) (h + i + j) No. (g) (h) (i) (j) (k) $0 1 5,007 645,167 645,167 2 03 04 05 06 502,774 19,734,731 19,734,731 7 08 09 010 5,007 645,167 645,167 11 502,774 19,734,731 19,734,731 12 13 507,781 $0 $20,379,898 $0 $20,379,898 14

FERC FORM NO.1 (REVISED. 12-90) NYPSC Modified-96 Next Page is 320 Page 311 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 ELECTRIC OPERATION AND MAINTENANCE EXPENSES If the amount for previous year is not derived from previously reported figures, explain in footnotes. Account Amount for Amount for Line Current Year Previous Year No. (a) (b) (c) 1 1. POWER PRODUCTION EXPENSES 2 A. Steam Power Generation 3Operation 4 (500) Operation Supervision and Engineering 5 (501) Fuel 6 (502) Steam Expenses 7 (503) Steam from Other Sources 8 (Less) (504) Steam Transferred-Cr. 9 (505) Electric Expenses 10 (506) Miscellaneous Steam Power Expenses 11 (507) Rents 12 (509) Allowances 13 TOTAL Operation (Enter Total of Lines 4 thru 12) 0 0 14 Maintenance 15 (510) Maintenance Supervision and Engineering 16 (511) Maintenance of Structures 17 (512) Maintenance of Boiler Plant 18 (513) Maintenance of Electric Plant 19 (514) Maintenance of Miscellaneous Steam Plant 20 TOTAL Maintenance (Enter Total of lines 15 thru 19) 0 0 21 TOTAL Power Production Expenses-Steam Power (Enter Total of Lines 13 and 20) 0 0 22 B. Nuclear Power Generation 23 Operation 24 (517) Operation Supervision and Engineering 25 (518) Fuel 26 (519) Coolants and Water 27 (520) Steam Expenses 28 (521) Steam from Other Sources 29 (Less) (522) Steam Transferred-Cr. 30 (523) Electric Expenses 31 (524) Miscellaneous Nuclear Power Expenses 32 (525) Rents 33 TOTAL Operation (Enter Total of lines 24 thru 32) 0 0 34 Maintenance 35 (528) Maintenance Supervision and Engineering 36 (529) Maintenance of Structures 37 (530) Maintenance of Reactor Plant Equipment 38 (531) Maintenance of Electric Plant 39 (532) Maintenance of Miscellaneous Nuclear Plant 40 TOTAL Maintenance (Enter Total of lines 35 thru 39) 0 0 41 TOTAL Power Production Expenses-Nuclear Power (Enter Total of lines 33 and 40) 0 0 42 C. Hydraulic Power Generation 43 Operation 44 (535) Operation Supervision and Engineering 45 (536) Water for Power 46 (537) Hydraulic Expenses 47 (538) Electric Expenses 48 (539) Miscellaneous Hydraulic Power Generation Expenses 49 (540) Rents 50 TOTAL Operation (Enter Total of lines 44 thru 49) $0 $0

FERC FORM NO.1 (REVISED. 12-93) Page 320 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 ELECTRIC OPERATION AND MAINTENANCE EXPENSES (Continued) Line Amount for Amount for No. Current Year Previous Year (b) (c) 51 C. Hydraulic Power Generation (Continued) 52 Maintenance 53 (541) Maintenance Supervision and Engineering 54 (542) Maintenance of Structures 55 (543) Maintenance of Reservoirs, Dams, and Waterways 56 (544) Maintenance of Electric Plant 57 (545) Maintenance of Miscellaneous Hydraulic Plant 58 TOTAL Maintenance (Enter total of lines 53 thru 57) 0 0 59 AL Power Production Expenses-Hydraulic Power (Enter total of lines 50 and 58) 0 0 60 D. Other Power Generation 61 Operation 62 (546) Operation Supervision and Engineering 63 (547) Fuel 64 (548) Generation Expenses 65 (549) Miscellaneous Other Power Generation Expenses 66 (550) Rents 67 TOTAL Operation (Enter total of lines 62 thru 66) 0 0 68 Maintenance 69 (551) Maintenance Supervision and Engineering 70 (552) Maintenance of Structures 71 (553) Maintenance of Generating and Electric Plant 72 (554) Maintenance of Miscellaneous Other Power Generation Plant 73 TOTAL Maintenance (Enter Total of Lines 69 thru 72) 0 0 74 TOTAL Power Production Expenses--Other Power (Enter Total of Lines 67 and 73) 0 0 75 E. Other Power Supply Expenses 76 (555) Purchased Power 893,468,338 1,317,555,078 77 (556) System Control and Load Dispatching 78 (557) Other Expenses 79 TOTAL Other Power Supply Expenses (Enter Total of Lines 76 thru 78) 893,468,338 1,317,555,078 80 TOTAL Power Production Expenses (Enter total of lines 21, 41, 59, 74, and 79) 893,468,338 1,317,555,078 81 2. TRANSMISSION EXPENSES 82 Operation 83 (560) Operation Supervision and Engineering 2,417,396 1,862,971 84 (561) Load Dispatching 2,549,318 3,239,670 85 (561.1)Load Dispatch-Reliability 00 86 (561.2)Load Dispatch-Monitor and Operate Transmission System 2,238,754 1,875,839 87 (561.3)Load Dispatch-Transmission Service and Scheduling 00 88 (561.4)Scheduling, System Control and Dispatch Services 3,413,097 3,912,403 89 (561.5)Reliability, Planning and Standards Development 1,552,052 936,896 90 (561.6)Transmission Service Studies 0 2,107 91 (561.7)Generation Interconnection Studies 5,198 2,209 92 (561.8)Reliability, Planning and Standards Development Services 872,819 982,534 93 (562) Station Expenses 4,436,919 3,348,267 94 (563) Overhead Lines Expenses 2,974,095 2,846,043 95 (564) Underground Lines Expenses 29,001 50,240 96 (565) Transmission of Electricity by Others 171,356 266,900 97 (566) Miscellaneous Transmission Expenses 9,551,613 9,174,553 98 (567) Rents 10,034,509 8,617,893 99 TOTAL Operation (Enter total of lines 83 thru 99) 40,246,127 37,118,525 100 Maintenance 101 (568) Maintenance Supervision and Engineering 2,046,865 1,902,787 102 (569) Maintenance of Structures 59,081 103,468 103 (569.1)Maintenance of Computer Hardware 467,498 811,869 104 (569.2)Maintenance of Computer Software 581,014 890,451 105 (569.3)Maintenance of Communication Equipment 40,602 72,717 106 (569.4)Maintenance of Miscellaneous Regional Transmission Plant 120 84 107 (570) Maintenance of Station Equipment 9,721,269 8,752,908 108 (571) Maintenance of Overhead Lines 22,016,059 21,666,684 109 (572) Maintenance of Underground Lines 269,004 301,594 110 (573) Maintenance of Miscellaneous Transmission Plant 332,109 632,588 111 TOTAL Maintenance (Enter total of lines 101 thru 110) 35,533,621 35,135,150 112 TOTAL Transmission Expenses (Enter total of lines 99 and 111) 75,779,748 72,253,675

FERC FORM NO. 1 (REVISED 12-93) 321 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 ELECTRIC OPERATION AND MAINTENANCE EXPENSES (Continued) Amount for Amount for Line Account Current Year Previous Year No. (a) (b) (c) 113 3. REGIONAL MARKET EXPENSES 114 Operation 115 (575.1) Operation Supervision $ - $ - 116 (575.2) Day-Ahead and Real-Time Market Facilitation 00 117 (575.3) Transmission Rights Market Facilitation 00 118 (575.4) Capacity Market Facilitation 00 119 (575.5) Ancillary Services Market Facilitation 5,925,157 0 120 (575.6) Market Monitoring and Compliance 00 121 (575.7) Market Facilitation, Monitoring and Complinace Services 0 5,717,538 122 (575.8) Rents 00 123 TOTAL Operation (Enter Total of lines 115 thru 122) 5,925,157 5,717,538 124 Maintenance 125 (576.1) Maintenance of Structures and Improvements - - 126 (576.2) Maintenance of Computer Hardware 00 127 (576.3) Maintenance of Computer Software 00 128 (576.4) Maintenance of Communication Equipment 00 129 (576.5) Maintenance of Miscellaneous Market Operation Plant 00 130 TOTAL Maintenance (Enter Total of lines 125 thru 129) 0 0 131 TOTAL Regional Transmission and Market Ops Expns (Total lines 123 and 130) 5,925,157 5,717,538 132 4. DISTRIBUTION EXPENSES 133 Operation 134 (580)Operation Supervision and Engineering 6,768,831 5,123,049 135 (581) Load Dispatching 12,221,738 10,285,085 136 (582) Station Expenses 12,224,480 6,169,449 137 (583) Overhead Line Expenses 9,192,041 6,479,842 138 (584) Underground Line Expenses 5,628,764 6,168,378 139 (585) Street Lighting and Signal System Expenses 1,262,361 1,178,754 140 (586) Meter Expenses 11,407,823 8,442,425 141 (587) Customer Installations Expenses 5,795,815 5,627,198 142 (588) Miscellaneous Expenses 49,185,390 47,128,402 143 (589) Rents 841,924 193,148 144 TOTAL Operation (Enter Total of lines 134 thru 143) 114,529,167 96,795,730 145 Maintenance 146 (590) Maintenance Supervision and Engineering 173,296 143,815 147 (591) Maintenance of Structures 1,002,996 1,066,118 148 (592) Maintenance of Station Equipment 10,157,492 8,594,119 149 (593) Maintenance of Overhead Lines 99,268,953 121,058,260 150 (594) Maintenance of Underground Lines 3,380,868 1,440,743 151 (595) Maintenance of Line Transformers 1,945,362 2,115,179 152 (596) Maintenance of Street Lighting and Signal Systems 4,672,694 5,464,344 153 (597) Maintenance of Meters 934,113 832,096 154 (598) Maintenance of Miscellaneous Distribution Plant 232,856 309,950 155 TOTAL Maintenance (Enter Total of lines 146 thru 154) 121,768,630 141,024,624 156 TOTAL Distribution Expenses (Enter Total of lines 144 and 155) 236,297,797 237,820,354 157 5. CUSTOMER ACCOUNTS EXPENSES 158 Operation 159 (901) Supervision 2,643,468 2,286,035 160 (902) Meter Reading Expenses 4,606,263 5,582,389 161 (903) Customer Records and Collection Expenses 39,838,790 39,200,043 162 (904) Uncollectible Accounts 59,499,795 65,629,392 163 (905) Miscellaneous Customer Accounts Expenses 1,069,573 929,964 164 TOTAL Customer Accounts Expenses (Enter Total of lines 159 thru 163) 107,657,889 113,627,823 165 6. CUSTOMER SERVICE AND INFORMATIONAL EXPENSES 166 Operation 167 (907) Supervision (452) 359,728 168 (908) Customer Assistance Expenses 105,569,317 76,759,340 169 (909) Information and Instructional Expenses 551,277 221,244 170 (910) Miscellaneous Customer Service and Information Expenses 3,591,589 3,351,027 171 TOTAL Cust. Service and Informational Expenses (Enter Total of Lines 167 thru 170) 109,711,731 80,691,339 172 7. SALES EXPENSES 173 Operation 174 (911) Supervision 322 147 175 (912) Demonstrating and Selling Expenses 24,333 230,527 176 (913) Advertising Expenses 3,164 55,481 177 (916) Miscellaneous Sales Expenses 11,130 5,674 178 TOTAL Sales Expenses (Enter Total of lines 134 thru 177) 38,949 291,829 179 8. ADMINISTRATIVE AND GENERAL EXPENSES 180 Operation 181 (920) Administrative and General Salaries 63,009,698 50,709,004 182 (921) Office Supplies and Expenses 55,647,754 45,469,444 183 (Less) (922) Administrative Expenses Transferred-Credit (48) (4,311)

FERC FORM NO.1 (REVISED. 12-93) Page 322 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 ELECTRIC OPERATION AND MAINTENANCE EXPENSES (Continued) Account Amount for Amount for Line Current Year Previous Year No. (a) (b) (c) 184 8. ADMINISTRATIVE AND GENERAL EXPENSES (Continued) 185 (923) Outside Services Employed $12,737,383 $7,573,148 186 (924) Property Insurance 110,662 114,702 187 (925) Injuries and Damages 15,311,171 18,094,156 188 (926) Employee Pensions and Benefits 94,953,663 105,135,888 189 (927) Franchise Requirements 67,948 5,725 190 (928) Regulatory Commission Expenses 53,037,289 16,060,589 191 (929) (Less) Duplicate Charges-Cr. 1,693 241 192 (930.1) General Advertising Expenses (991,280) 2,334,644 193 (930.2) Miscellaneous General Expenses 16,046,581 17,826,745 194 (931) Rents 12,307,155 13,834,522 195 TOTAL Operation (Enter Total of lines 181 thru 194) 322,239,765 277,163,119 196 Maintenance 197 (935) Maintenance of General Plant 2,536,389 2,555,127 198 TOTAL Administrative and General Expenses 324,776,154 279,718,246 (Enter total of lines 195 and 197) 199 TOTAL Electric Operation and Maintenance Expenses $1,753,655,763 $2,107,675,882 (Enter total of lines 80, 112, 131, 156, 164, 171, 178 and 198)

NUMBER OF ELECTRIC DEPARTMENT EMPLOYEES

1. The data on number of employees should be reported for the payroll period ending nearest to October 31, or any payroll period ending 60 days before or after October 31. 2. If the respondent's payroll for the reporting period includes any special construction personnel, include such employees on line 3, and show the number of such special construction employees in a footnote. 3. The number of employees assignable to the electric department from joint functions of combination utilities may be determined by estimate, on the basis of employee equivalents. Show the estimated number of equivalent employees attributed to the electric department from joint functions.

1. Payroll Period Ended (Date) 12/31/2009 2. Total Regular Full-Time Employees 2,957 3. Total Part-Time and Temporary Employees 49 4. Total Employees 3,006

FERC FORM NO.1 (REVISED. 12-93) Next Page is 326 Page 323 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 PURCHASED POWER (Account 555) (INCLUDING POWER EXCHANGES)

1. Report all power purchases made during the year. Also report exchanges of electricity (i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. 2. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projected load for this service in its system resource planning). In addition, the reliability of requirements service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service which meets the definition of RQ service. For all transactions identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service except that "intermediate-term" means longer than one year but less than five years. SF - for short-term firm service. Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service except that "intermediate-term" means longer than one year but less than five years. EX - for exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS - for other service. Use this category only for those services which cannot be placed in the above-

Actual Demand (MW) Name of Company FERC Rate Average Average Average or Public Authority Statistical Schedule or Monthly Billing Monthly Monthly Line (Footnote Affiliations) Classification Tariff Number Demand NCP Demand CP Demand No. (a) (b) (c) (d) (e) (f) 1 Non-Associated Utilities 2 Other Non-Utilities 3 Municipalities 4 Windmills 5 Photovoltaic Generation 6Farm Waste 7 New York State Independent System Operator 8 Energy Marketers 9 10 11 12 13 From Insert Page 14 Total

FERC FORM NO.1 (REVISED 12-90) NYPSC Modified-96 Page 326 If applicable, see insert pages below: Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 PURCHASED POWER (Account 555) (Continued) (Including power exchanges)

defined categories, such as all nonfirm service regardless of the length of the contract and service from designated units of less than one year. Describe the nature of the service in a footnote for each adjustment. AD - for out-of-period adjustment. Use this code for any accounting adjustment or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for nonFERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. 5. For requirements RQ purchases and any type of services involving demand charges imposed on a monthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non- coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 6. Report in column (g) the megawatthours shown on bills rendered to the respondent. Report in columns (h) and (i) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. 7. Report demand charges in column (j), energy charges in column (k), and the total of any other types of charges, including out-of-period adjustments, in column (l). Explain in a footnote all components of the amount shown in column (l). Report in column (m) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (m) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (1) includes credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. 8. The data in column (g) through (m) must be totaled on the last line of the schedule. The total amount in column (g) must be reported as Purchases on page 401, line 10. The total amount in column (h) must be reported as Exchange Received on page 401, line 12. The total amount in column (i) must be reported as Exchange Delivered on page 401, line 13. 9. Footnote entries as required and provide explanations following all required data. POWER EXCHANGES COST/SETTLEMENT OF POWER Demand Energy Other Megawatthours Megawatthours Megawatthours Charges Charges Charges Total (j + k + l) Line Purchased Received Delivered ($) ($) ($) or Settlement ($) No. (g) (h) (i) (j) (k) (l) (m) 3,478 $0 $359,674 $0 $359,674 1 1,718,978 8,581,021 136,732,657 367,738 145,681,416 2 5,347,109 0 118,130,272 92,306 118,222,578 3 00450454 96 0 5,764 31 5,795 5 90 0 8,762 64 8,826 6 6,307,229 0 378,613,926 0 378,613,926 7 6,481,686 0 250,576,078 0 250,576,078 8 9 10 11 12 13 19,858,666 0 0 $8,581,021 $884,427,178 $460,139 $893,468,338 14

FERC FORM NO.1 (REVISED 12-90) NYPSC Modified-96 Page 327 Niagara Mohawk Power Corporation 6/01/2010 12/31/2009

PURCHASED POWER (Account 555) (INCLUDING POWER EXCHANGES)

Actual Demand (MW) Name of Company FERC Rate Average Average Average or Public Authority Statistical Schedule or Monthly Billing Monthly Monthly Line (Footnote Affiliations) Classification Tariff Number Demand NCP Demand CP Demand No. (a) (b) (c) (d) (e) (f) 1 NON-ASSOCIATED UTILITIES: 2 Central Hudson Gas&Elec Co(Borderli RQ NM-41 3 NYS Elec&Gas Corp. (Borderline) RQ NM-37 4 Rochester Gas&Elec Co. (Borderline) RQ NM-44 5 6 OTHER NON-UTILITIES: 7 Middle Falls (Boralex) LU NM-548 8 South Glens Falls Ltd Ptnshp (Boralex)LU NM-862 9 Northern Electric Power Co LP-Hudso LU NM-863 10 Algonquin - Adler Creek (Kayuta) LU NM-366 11 Burt Dam Power Co Partnership OS NM-460 7965 12 Algonquin - Christine Falls LU NM-374 13 Algonquin - Cranberry Lake OS NM-495 4061 14 Algonquin - Forestport OS NM-496 24400 15 Algonquin - Ogdensburg OS NM-506 24586 16 Azure Mountain Power Co-St Regis FaOS NM-717 5002 17 Battenkill Hydro Inc-Middle Greenwich OS NM-411 18 Battenkill Hydro Inc-Upper Greenwich OS-note 2 NM-410 19 Black River Assoc -Port Leyden LU NM-343 20 Black River Hydro Assoc - Denley Old LU NM-342 21 Black River Hydro Assoc - Rock IslandLU NM-341 22 Algonquin Power Beaver Fall LLC (LowLU NM-360 23 Algonquin Power Beaver Fall LLC (Up LU NM-361 24 Cal Ban Power Corporation OS NM-1374 148 25 Cellu-Tissue Corp. (Natural Dam) OS NM-294 26 Champlain Spinners Power Co., Inc. OS NM-672 4506 27 Chittenden Falls Hydro Power Co. Inc. LU NM-223 6349 28 Hydro Development Group Inc-CopenhLU NM-845A 29 Cottrell Paper Co-Rock City Falls HydrOS-note 2 NM-477 649 30 Curtis/Palmer Hydro Electric Co. LU NM-338 31 Dahowa Hydro Division-Stevens&ThomLU NM-483 32 Empire Hydro Partners LU NM-315 33 Erie Boulevard Hydropower LP (HewittLU NM-277 H 34 Erie Boulevard Hydropower LP (Union LU NM-277 U 35 Finch,Pryun and Co. Inc. OS-note 2 NM-798 36 Fort Miller Assoc-Hudson River LU NM-367 37 FortisUS Energy Corp (Diana) IU-note 2 NM-1317 16170 38 FortisUS Energy Corp (Dolgeville) IU-note 2 NM-1316 32875 39 FortisUS Energy (Moose River) IU-note 2 NM-1210 104953 40 FortisUS Energy (Phil. Hydro) IU-note 2 NM-1209 21816 41 Fortistar North Tonawanda, Inc. OS-note 2 NM-498 42 Fourth Branch Associates-MechanicvillOS NM-1368 35325 43 General Mills Operations Inc IU NM-487 44 Hollingsworth&Vose - Upper IU NM-797 634 45 Hollingsworth&Vose - Center IU NM-857 2806 46 Hollingsworth&Vose - Lower IU NM-858 10322 47 Hollow Dam Power Co. Partnership OS-note 2 NM-435 6442 48 49 50 Total

FERC FORM NO.1 (REVISED 12-90) NYPSC Modified-96 Page 326-A Niagara Mohawk Power Corporation 6/01/2010 12/31/2009

PURCHASED POWER (Account 555) (Continued) (Including power exchanges)

POWER EXCHANGES COST/SETTLEMENT OF POWER Demand Energy Other Megawatthours Megawatthours Megawatthours Charges Charges Charges Total (j + k + l) Line Purchased Received Delivered ($) ($) ($) or Settlement ($) No. (g) (h) (i) (j) (k) (l) (m) 1 221 6,795 6,795 2 2,716 278,871 278,871 3 541 74,008 74,008 4 05 06 17,720 1,998,357 1,998,357 7 87,194 7,718,105 7,718,105 8 252,592 22,328,674 22,328,674 9 618 17,325 17,325 10 2,450 (15,343) 7,965 (7,378) 11 4,035 4,412 152,826 157,238 12 1,948 72,303 4,061 76,364 13 12,844 450,819 24,400 475,219 14 11,829 426,519 24,586 451,105 15 2,444 89,748 5,002 94,750 16 1,042 3,123 38,990 42,113 17 1,237 4,704 42,836 47,540 18 17,521 1,051,246 1,051,246 19 2,082 124,899 124,899 20 5,334 320,014 320,014 21 10,171 18,974 247,233 266,207 22 5,182 11,555 118,789 130,344 23 85 2,378 148 2,526 24 36 3,132 3,132 25 2,164 93,772 4,506 98,278 26 2,923 1,470 118,037 6,349 125,856 27 11,510 1,307,312 1,307,312 28 310 12,116 649 12,765 29 355,767 36,933,468 36,933,468 30 43,292 95,414 1,926,262 2,021,676 31 5,250 10,267 128,633 138,900 32 17,262 44,995 560,350 605,345 33 11,097 35,482 329,624 365,106 34 5,504 240,253 240,253 35 22,803 1,961,069 1,961,069 36 7,706 284,434 16,170 300,604 37 14,817 512,708 32,875 545,583 38 50,233 1,844,635 104,953 1,949,588 39 11,016 430,027 21,816 451,843 40 4,830 7,364,288 13,975,234 21,339,522 41 17,830 734,533 35,325 769,858 42 1,719 4,174 81,936 86,110 43 8,171 390,574 634 391,208 44 498 25,797 2,806 28,603 45 1,387 42,500 10,322 52,822 46 2,757 94,361 6,442 100,803 47 48 49 1,038,688 0 0 $7,598,858 $97,576,159 $309,009 $105,484,026 50

FERC FORM NO.1 (REVISED 12-90) NYPSC Modified-96 Page 327-A Niagara Mohawk Power Corporation 6/01/2010 12/31/2009

PURCHASED POWER (Account 555) (INCLUDING POWER EXCHANGES)

Actual Demand (MW) Name of Company FERC Rate Average Average Average or Public Authority Statistical Schedule or Monthly Billing Monthly Monthly Line (Footnote Affiliations) Classification Tariff Number Demand NCP Demand CP Demand No. (a) (b) (c) (d) (e) (f) 1 Hydro Development Group-Dexter LU NM-845C 2 Hydro Development Group-Diamond IsLU NM-845F 3 Hydro Development Group-Hailesboro LU NM-845B 4 Hydro Development Group-Hailesboro LU NM-845G 5 Hydro Development Group-Hailesboro LU NM-845D 6 Hydro Development Group-Theresa LU NM-845E 7 Hydro Power Inc. (Hoosick Falls) OS NM-516 5701 8 Kinetic Energy LLC LU NM-399 9 Tug Hill Energy (King Falls) OS NM-1292 2944 10 LaChute Hydro Co., Inc. (Upper/LowerLU NM-420 11 Lake Algonquin Hydro Elec Project LU NM-458 12 Little Falls Hydroelectric Associates LU NM-307 13 Lyonsdale Associates-Burrows Hydro LU NM-297 14 MM Albany Energy LLC OS-note 2 NM-1001 15 Edison Hydroelectric LU-note 1 NM-1671 1793 16 Finch Paper LLC LU-note 1 NM-1670 17 Oakvale Construction LTD. OS-note 1 NM-1692 575 18 Mt. Ida Associates LU NM-299 19 Newport Hydro Associates-Bridge St. LU NM-484 20 North Country Community College FdnIU NM-396 1289 21 Onondaga Power Swap Holding LLC OS-note 5 NM-507 22 Onondaga County Resource RecoveryLU NM-320 23 Onondaga Energy Partners, LP IU NM-511 24 Oswego Hydro Partners (Phoenix Hyd LU NM-618 25 Oswego, City of - High Dam LU NM-805 26 Oswego County Energy Recovery LU NM-358 27 Potsdam, Village of OS-note 2 NM-395 10108 28 Pyrites Associates LU NM-362 29 Riverrat Glass & Electric OS NM-425 4874 30 Sandy Hollow Hydro Assoc. OS NM-383 4431 31 US Gypsum Company OS-note 1 NM-1691 32 Stillwater Associates LU NM-369 33 Stillwater Hydro Partners LU NM-617 34 Tannery Island Power Corp. OS-note 2 NM-380 19407 35 Laidlaw Energy & Environm. LU-note 1 NM-519 36 Tug Hill Energy Inc (Otter Creek) IU NM-1301 4021 37 Union Falls Hydropower LTD Prtnrship LU NM-429 38 Utica Board of Water Supply-Sand Rd OS-note 2 NM-670 39 Utica Board of Water Sup-Trenton Fal IU NM-669 40 Valatie Falls Hydro Power Inc. LU NM-679 198 41 Valley Falls Associates LU NM-368 42 Victory Mills Hydro Co, Inc.-Pine St. LU NM-453 43 Gouverneur, Village of OS NM-236 44 Village of Saranac Lake, Inc. OS NM-913 45 Wamco 31 Ltd. LU NM-575 46 Watervliet, City of OS-note 6 NM-393 3388 47 Watertown, City of OS NM-662 48 West End Dam Associates LU NM-377 49 50 Total

FERC FORM NO.1 (REVISED 12-90) NYPSC Modified-96 Page 326-B Niagara Mohawk Power Corporation 6/01/2010 12/31/2009

PURCHASED POWER (Account 555) (Continued) (Including power exchanges)

POWER EXCHANGES COST/SETTLEMENT OF POWER Demand Energy Other Megawatthours Megawatthours Megawatthours Charges Charges Charges Total (j + k + l) Line Purchased Received Delivered ($) ($) ($) or Settlement ($) No. (g) (h) (i) (j) (k) (l) (m) 23,466 $2,661,002 $2,661,002 1 7,042 798,613 798,613 2 4,907 556,449 556,449 3 12,458 1,412,748 1,412,748 4 5,735 650,369 650,369 5 7,251 822,275 822,275 6 2,997 123,683 5,701 129,384 7 1,322 3,048 43,352 46,400 8 1,572 58,350 2,944 61,294 9 35,128 122,515 1,298,319 1,420,834 10 6,778 366,979 366,979 11 47,218 4,064,216 4,064,216 12 12,833 962,955 962,955 13 953 44,982 44,982 14 745 23,949 1,793 25,742 15 4,430 6,291 200,348 206,639 16 (575)575 0 17 10,287 686,947 686,947 18 8,247 496,184 496,184 19 916 39,644 1,289 40,933 20 14,876 634,603 634,603 21 182,793 642,311 6,107,703 6,750,014 22 1,818 4,686 63,073 67,759 23 11,884 1,093,929 1,093,929 24 38,804 2,134,203 2,134,203 25 4,888 75,551 191,913 267,464 26 4,755 168,990 10,108 179,098 27 29,448 1,766,860 1,766,860 28 2,310 97,486 4,874 102,360 29 2,201 75,436 4,431 79,867 30 666 21,683 21,683 31 6,325 514,463 514,463 32 16,333 1,560,806 1,560,806 33 9,100 312,252 19,407 331,659 34 1,592 1,59235 1,779 59,041 4,021 63,062 36 11,524 32,931 345,363 378,294 37 1,503 3,581 56,229 59,810 38 826 1,969 30,729 32,698 39 201 6,869 198 7,067 40 11,485 999,217 999,217 41 5,826 327,348 327,348 42 329 6,819 6,819 43 517 1,502 18,252 19,754 44 10,136 29,084 295,870 324,954 45 1,842 87,153 3,388 90,541 46 9,823 1,457,763 1,457,763 47 21,975 58,694 645,364 704,058 48 049 598,252 0 0 $982,163 $34,391,798 $58,729 $35,432,690 50

FERC FORM NO.1 (REVISED 12-90) NYPSC Modified-96 Page 327-B Niagara Mohawk Power Corporation 6/01/2010 12/31/2009

PURCHASED POWER (Account 555) (INCLUDING POWER EXCHANGES)

Actual Demand (MW) Name of Company FERC Rate Average Average Average or Public Authority Statistical Schedule or Monthly Billing Monthly Monthly Line (Footnote Affiliations) Classification Tariff Number Demand NCP Demand CP Demand No. (a) (b) (c) (d) (e) (f) 1 Wheelabrator Hudson Falls, LLC LU NM-445 2 Burrstone Energy Center (Luke) OS NM-1673 3 Allied Frozen Storage OS NM-1607 4 5 MUNICIPALITIES: 6 Brocton, Village of (Borderline) RQ NM-184 7 Frankfort Power&Light (Borderline) RQ 8 Richmondville, Village of (Borderline) RQ NM-113 9 Solvay, Village of (Borderline) RQ NM-7 10 Constellation Zone F Swap RQ 11 Wellsville, Village of (Borderline) RQ 12 New York Power Authority-Fitzpatrick LF NM-152 13 New York Power Authority-Niagara LF NM-76 14 New York Power Authority-Power for JIF 15 New York Power Authority-St LawrencLF NM-76 16 Green Island Power Authority IU NM-1305 92306 17 Dynegy INC RQ 18 19 WINDMILLS: 20 VanStrander, Michael OS-note 3 NM-226 21 Albert Snyder OS 22 23 PHOTOVOLTAIC GENERATION: 24 Resident Net Meter Annual Trueup (38OS 25 Mountainaire Massage Spa OS-note 2 NM-1413 13 26 Tri-City JATC, Inc. OS NM-1484 18 27 28 FARM WASTE: 29 Ridgeline Farms LLC OS NM Rule 36/13 64 30 31 NEW YORK STATE ISO ISO-MKT-SVC 32 33 34 ENERGY MARKETERS 35 Constellation - NMP1 SF DIV-244 36 Constellation - NMP2 LF DIV-244 37 Electric Swap Settlement NYMEX OS 38 Constellation Zone F Swap LF 39 Dynegy Inc. OS-note 4 40 41 Note 1 - Other Charges - Indexed SWAP contract payments under the MRA, net of gas futures. 42 Note 2 - Service from designated generating units of less than 1 year remaining on contract. 43 Note 3 - Effective 9/30/05 Power Purchase Agreements terminated and Rule 37-Net Metering for Residential and Farm Serv 44 Generating Systems is in effect. 45 Note 4 - Contract has terminated under this name in current year. 46 Note 5 - OS statistical classification and amounts included in other charges as they are indexed swap contract payments und 47 Note 6 - OS statistical classification - service from designated generating units of less than 1 year remaining on contract. 48 49 50 Total

FERC FORM NO.1 (REVISED 12-90) NYPSC Modified-96 Page 326-C Niagara Mohawk Power Corporation 6/01/2010 12/31/2009

PURCHASED POWER (Account 555) (Continued) (Including power exchanges)

POWER EXCHANGES COST/SETTLEMENT OF POWER Demand Energy Other Megawatthours Megawatthours Megawatthours Charges Charges Charges Total (j + k + l) Line Purchased Received Delivered ($) ($) ($) or Settlement ($) No. (g) (h) (i) (j) (k) (l) (m) 85,249 $5,114,645 $5,114,645 1 12 605 605 2 255 9,124 9,124 3 4 5 19 1,462 1,462 6 361 27,348 27,348 7 85 8,200 8,200 8 9 866 866 9 11,336,922 11,336,92210 13 1,185 1,185 11 181,833 8,433,870 8,433,870 12 4,174,202 73,225,581 73,225,581 13 260,576 14,750,586 14,750,586 14 686,313 7,070,740 7,070,740 15 43,698 1,873,512 92,306 1,965,818 16 1,400,000 1,400,00017 18 19 2 220 43 4321 22 23 81 5,176 5,176 24 7 240 13 253 25 8 348 18 366 26 27 28 90 8,762 64 8,826 29 30 6,307,229 378,613,926 378,613,926 31 32 33 34 3,132,648 116,890,461 116,890,461 35 3,349,038 119,087,033 119,087,033 36 8,450,792 8,450,79237 5,587,792 5,587,79238 560,000 560,00039 40 41 42 vice Wind 43 44 45 er MRA, net of gas futures. 46 47 48 49 18,221,726 0 0 $0 $752,459,221 $92,401 $752,551,622 50

FERC FORM NO.1 (REVISED 12-90) NYPSC Modified-96 Page 327-C Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456) (Including transactions referred to as "wheeling") 1. Report all transmission of electricity, i.e. wheeling, provided for other electric utilities, cooperatives, municipalities, other public authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers. 2. Use a separate line of data for each distinct type of transmission service involving the entities listed in columns (a), (b) and (c). 3. Report in column (a) the company or public authority that paid for the transmission service. Report in column (b) the company or public authority that the energy was received from and in column (c) the company or public authority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation the respondent has with the entities listed in columns (a), (b) or (c). 4. In column (d) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows:

LF - for long-term firm transmission service. "Long-term" means one year or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. For all transactions identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract.

SF - for short-term firm transmission service. Use this category for all firm services, where the duration of each period of commitment for service is less than one year.

Payment By Energy Received From Energy Delivered To (Company or Public Authority) (Company or Public Authority) (Company or Public Authority) Statistical Line [Footnote Affiliations] [Footnote Affiliations] [Footnote Affiliations] Classification No. (a) (b) (c) (d) 1 New York Power Authority (TSC) New York Power Authority NYPA NYS Municipal Customers OS 2 New York Power Authority New York Power Authority NYPA Industrial Customers OLF 3 New York Power Authority New York Power Authority Niagara Frontier Transit Authorit OLF 4 New York Power Authority New York Power Authority NYPA NYS Municipal Customers OLF 5 New York Power Authority New York Power Authority Consolidated Edison OS 6 Central Hudson Gas & Electric Central Hudson Gas & Electric Central Hudson Gas & Electric OLF 7 Central Hudson Gas & Electric Central Hudson Gas & Electric Central Hudson Gas & Electric OS 8 LIPA New York Power Authority Long Island Power Authority OLF 9 LIPA Long Island Power Authority Long Island Power Authority OLF 10 New York State Gas & Electric New York State Electric & Gas New York State Electric & Gas OLF 11 City - Watertown City - Watertown City - Watertown OLF 12 City - Jamestown City - Jamestown City - Jamestown OS 13 Selkirk Co-Gen Selkirk Co-Gen Consolidated Edison OLF 14 Sithe Independence, LP Sithe Independence, LP Consolidated Edison OLF 15 16 From Insert Page 17 Total

FERC FORM NO.1 (REVISED 12-90) NYPSC Modified-96 Page 328 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456) (Continued) (Including transactions referred to as "wheeling") OS - for other transmission service. Use this category only for those services which cannot be placed in the above-defined categories, such as all nonfirm transmission service, regardless of the length of the contract. Describe the nature of the service in a footnote. AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment.

5. In column (e), identify the FERC Rate Schedule or Tariff Number. On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided.

6. Report receipt and delivery locations for all single contract path, "point to point" transmission service. In column (f), report the designation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation, or other appropriate identification for where energy was delivered as specified in the contract.

7. Report in column (h) the number of megawatts of billing demand that is specified in the firm transmission service contract. Demandreported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain.

FERC Rate Billing TRANSFER OF ENERGY Schedule or Point of Receipt Point of Delivery Demand Megawatthours Megawatthours Line Tariff Number (Substation or Other Designation) (Substation or Other Designation) (MW) Received Delivered No. (e) (f) (g) (h) (i) (j) NYISO OATT Various NYPA NYS Municipal 667,314 667,314 1 174-177 Various NYPA Industrial Cust 55 0 0 2 136 Various NIagara Frontier TA 1 0 0 3 18 Various NYPA NYS Municipal 3 0 0 4 180 Various Crescent-Vischer-Jar 65,468 65,468 5 141 Nine Mile 2 Station Central Hudson G&E 103 0 0 6 55 North Catskill North Catskill 0 0 7 142 Fitzpatrick Consolidated Edison 160 0 0 8 142 Nine Mile 2 Station Consolidated Edison 206 0 0 9 165 Various Various 0 0 10 174 Watertown Hydro Watertown Municipal 11,097 11,097 11 NYISO OATT Jamestown Jamestown 0 0 12 171 Selkirk Station Consolidated Edison 270 0 0 13 178 Sithe Station Consolidated Edison 853 0 0 14 15 16 1,651 743,879 743,879 17

FERC FORM NO.1 (REVISED 12-90) NYPSC Modified-96 FERC FORM Page 329 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporatio (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456) (Continued) (Including transactions referred to as "wheeling") 8. Report in columns (i) and (j) the total megawatthours received and delivered.

9. In columns (k) through (n), report the revenue amounts as shown on bills or vouchers. In column (k), provide revenues from demand charges related to the billing demand reported in column (h). In column (l), provide revenues from energy charges related to the amount of energy transferred. In column (m), provide the total revenues from all other charges on bills or vouchers rendered, including out of period adjustments. Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills rendered to the entity listed in column (a). If no monetary settlement was made, enter zero ("0") in column (n). Provide a footnote explaining the nature of the nonmonetary settlement, including the amount and type of energy or service rendered.

10. Provide total amounts in columns (i) through (n) as the last line. Enter "TOTAL" in column (a) as the last line. The total amounts in columns (i) and (j) must be reported as Transmission Received and Delivered on page 401, lines 16 and 17, respectively.

11. Footnote entries and provide explanations following all required data.

REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS Demand Charges Energy Charges Other Charges Total Revenues ($) Line ($) ($) ($) (k + l + m) No. (k) (l) (m) (n) $0 $2,979,800 $2,979,800 1 1,251,826 0 1,251,826 2 30,400 0 30,400 3 21,397 0 21,397 4 0 158,465 158,465 5 2,175,360 0 2,175,360 6 0 195,300 195,300 7 2,999,040 0 2,999,040 8 4,350,720 0 4,350,720 9 9,354,240 0 9,354,240 10 0 81,862 81,862 11 00012 5,702,400 0 5,702,400 13 18,015,360 0 18,015,360 14 015 016 $43,900,743 $0 $3,415,427 $47,316,170 17

M NO.1 (REVISED 12-90) NYPSC Modified-96 Next Page is 332 Page 330 If applicable, see insert pages below

Niagara Mohawk Power Corporation 6/01/2010 12/31/2009

TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456) (Including transactions referred to as "wheeling")

Payment By Energy Received From Energy Delivered To (Company or Public Authority) (Company or Public Authority) (Company or Public Authority) Statistical Line [Footnote Affiliations] [Footnote Affiliations] [Footnote Affiliations] Classification No. (a) (b) (c) (d) 1 Indeck Indeck Consolidated Edison OLF 2 Muni Wheels/OATT Various Various OS 3 Rocester Gas & Electric Exit AgreeVarious Various OLF 4 ISO External Trans. (TSC) Various Various OS 5 NYMPA, Misc. Villages & JamestoVarious Various OS 6 TSC Refund per settlement 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59 60 61 62 63 64 65 Total

FERC FORM NO.1 (REVISED 12-90) NYPSC Modified-96 Page 328-A Niagara Mohawk Power Corporation 6/01/2010 12/31/2009

TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456) (Continued) (Including transactions referred to as "wheeling")

FERC Rate Billing TRANSFER OF ENERGY Schedule or Point of Receipt Point of Delivery Demand Megawatthours Megawatthours Line Tariff Number (Substation or Other Designation) (Substation or Other Designation) (MW) Received Delivered No. (e) (f) (g) (h) (i) (j) 175 Indeck Station Consolidated Edison 129 1 Various Various Various 7 2,943 2,943 2 178 Various Various 3 NYISO OATT Various Various 456,272 456,272 4 NYISO OATT Various Various 2,073,491 2,073,491 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59 60 61 62 63 64 1,787 3,276,585 3,276,585 65

FERC FORM NO.1 (REVISED 12-90) NYPSC Modified-96 Page 329-A Niagara Mohawk Power Corporation 6/01/2010 12/31/2009

TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456) (Continued) (Including transactions referred to as "wheeling")

REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS Demand Charges Energy Charges Other Charges Total Revenues ($) Line ($) ($) ($) (k + l + m) No. (k) (l) (m) (n) $2,731,520 $0 $0 $2,731,520 1 207,433 0 13,956 221,389 2 0 0 319,896 319,896 3 0 0 2,060,288 2,060,288 4 0 0 9,564,205 9,564,205 5 0 0 (6,938,765) (6,938,765) 6 0 7 0 8 0 9 010 011 012 013 014 015 016 017 018 019 020 021 022 023 024 025 026 027 028 029 030 031 032 033 034 035 036 037 038 039 040 041 042 043 044 045 046 047 048 049 050 051 052 053 054 055 056 057 058 059 060 061 062 063 064 $46,839,696 $0 $8,435,007 $55,274,703 65

FERC FORM NO.1 (REVISED 12-90) NYPSC Modified-96 Page 330-A Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009

TRANSMISSION OF ELECTRICITY BY OTHERS (Account 565) (Including transactions referred to as "wheeling")

1. Report all transmission, i.e., wheeling, of electricity provided to respondent by other electric utilities, cooperatives, municipalities, or other public authorities during the year. 2. In column (a) report each company or public authority that provided transmission service. Provide the full name of the company; abbreviate if necessary, but do not truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation with the transmission service provider. 3. Provide in column (a) subheadings and classify transmission service purchased from other utilities as: "Delivered Power to Wheeler" or "Received Power from Wheeler." 4. Report in columns (b) and (c) the total megawatthours received and delivered by the provider of the transmission service. 5. In columns (d) through (g), report expenses as shown on bills or vouchers rendered to the respondent. In column (d), provide demand charges. In column (e), provide energy charges related to the amount of energy transferred. In column (f), provide the total of all other charges on bills or vouchers rendered to the respondent, including any out of period adjustments. Explain in a footnote all components of the amount shown in column (f). Report in column (g) the total charge shown on bills rendered to the respondent. If no monetary settlement was made, enter zero ("0") in column (g). Provide a footnote explaining the nature of the nonmonetary settlement, including the amount and type of energy or service rendered. 6. Enter "TOTAL" in column (a) as the last line. Provide a total amount in columns (b) through (g) as the last line. Energy provided by the respondent for the wheeler's transmission losses should be reported on the Electric Energy Account, page 401. If the respondent received power from the wheeler, energy provided to account for losses should be reported on line 19. Transmission By Others Losses, on page 401. Otherwise, losses should be reported on line 27, Total Energy Losses, page 401. 7. Footnote entries and provide explanations following all required data.

TRANSFER OF ENERGY EXPENSES FOR TRANSMISSION OF ELECTRICITY BY OTHERS Name of Company or Public Authority Megawatthours Megawatthours Demand Charges Energy Charges Other Charges Total Cost of Line [Footnote Affiliations] Received Delivered ($) ($) ($) Transmission ($) No. (a) (b) (c) (d) (e) (f) (g) 1 HydroPower LP $171,356 $171,356 2 0 3 0 4 0 5 0 6 0 7 0 8 0 9 0 10 0 11 0 12 0 13 0 14 0 15 From Insert Page 0 16 Total 0 0 $0 $0 $171,356 $171,356

FERC FORM NO.1 (REVISED. 12-90) NYPSC Modified-96 Next Page is 335 Page 332 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 MISCELLANEOUS GENERAL EXPENSES (Account 930.2) (ELECTRIC and GAS)

Line Description Amount No. (a) (b) 1 Industry Association Dues 2 Nuclear Power Research Expenses 3 Other Experimental and General Research Expenses 4 Publishing and Distributing Information and Reports to Stockholders; Trustee, Registrar, and Transfer Agent Fees and Expenses, and Other Expenses of Servicing Outstanding Securities of the Respondent 5 Other Expenses (List items of $5,000 or more in this column showing the (1) purpose, (2) recipient and (3) amount of such items. Group amounts of less than $5,000 by classes if the number of items so grouped is shown). 6Electric 7 Industry association dues 8 Nuclear power research expenses 9 Other experimental and general research expenses 1,511,260 10 Pub & Dist info to stkhldrs… expn servicing outstanding securities 11 Other Expn >= 5,000 show purpose, recipient, amount. Group if < $5,000 12 National Grid Service Co allocation 1,849,068 13 Meter Data Services Operation 838,068 14 Economic Development Activities 886,453 15 Corporate Matters / Contracts (legal) 1,093,709 16 Environmental Activities Expense 9,545,018 17 Community Development 658 18 Miscellaneous 322,347 19 20 21 22 23 24 Subtotal 16,046,581 25 Gas 26 Community Development 61 27 Economic Development Activities 167,284 28 Environmental Activities Expense 3,765,398 29 Corporate Matters / Contract (Legal) 229,611 30 Other Experimental And General Research Expenses 900,506 31 32 33 34 35 36 37 38 39 40 41 Subtotal 5,062,860 42 Other 43 44 45 46 47 48 49 50 Subtotal 0 51 Total $21,109,441 FERC FORM NO.1 (ED. 12-94) NYPSC Modified-96 Page 335 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Accounts 403, 404, 405) (Except amortization of acquisition adjustments) 1. Report in Section A for the year the amounts for: (a) Depreciation Expense (Account 403); (b) Amortization of Limited-Term Electric Plant (Account 404); and (c) Amortization of Other Electric Plant (Account 405). 2. Report in section B the rates used to compute amortization charges for electric plant (Accounts 404 and 405). State the basis used to compute charges and whether any changes have been made in the basis or rates used from the preceding report year. 3. Report all available information called for in section C every fifth year beginning with report year 1971, reporting annually only changes to columns (c) through (g) from the complete report of the preceding year. Unless composite depreciation accounting for total depreciable plant is followed, list numerically in column (a) each plant subaccount, account or functional classification, as appropriate, to which a rate is applied. Identify at the bottom of section C the type of plant included in any subaccounts used. In column (b) report all depreciable plant balances to which rates are applied showing subtotals by functional classifications and showing a composite total. Indicate at the bottom of section C the manner in which column balances are obtained. If average balances, state the method of averaging used. For columns (c), (d), and (e) report available information for each plant subaccount, account or functional classification listed in column (a). If plant mortality studies are prepared to assist in estimating average service lives, show in column (f) the type mortality curve selected as most appropriate for the account and in column (g), if available, the weighted average remaining life of surviving plant. If composite depreciation accounting is used, report available information called for in columns (b) through (g) on this basis. 4. If provisions for depreciation were made during the year in addition to depreciation provided by application of reported rates, state at the bottom of section C the amounts and nature of the provisions and the plant items to which related. A. Summary of Depreciation and Amortization Charges Depreciation Amortization Amortization Depreciation Expense for Asset of Limited-Term of Other Line Functional Classification Expense Retirement Costs Electric Plant Electric Plant Total No. (Account 403) (Account 403.1) (Acct. 404) (Acct. 405) (a) (b) (c) (d) (e) (f) 1 Intangible Plant $2,329,861 $2,329,861 2 Steam Production Plant 0 3 Nuclear Production Plant 0 4 Hydraulic Production Plant-Conventional 64,266 64,266 5 Hydraulic Production Plant-Pumped Storage 0 6 Other Production Plant 0 7 Transmission Plant 29,595,042 2,349 29,597,391 8 Distribution Plant 124,514,067 9,081 124,523,148 9 General Plant 13,070,078 13,070,078 10 Common Plant-Electric 12,971,842 776,116 13,747,958 11 TOTAL $180,215,295 $11,430 $776,116 $2,329,861 $183,332,702 B. Basis for Amortization Charges

FERC FORM NO. 1 (ED. 12-88) Page 336 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued) C. Factors Used in Estimating Depreciation Charges Depreciable Estimated Applied Average Account Plant Base Avg. Service Net Salvage Depr. Rates Mortality Curve Remaining Line No. (In thousands) Life (Percent) (Percent) Type Life No. (a) (b) (c) (d) (e) (f) (g) 12 Transmission: 13 350.40 27,126 37.86 14 352 31,485 45.43 15 353 692,937 42 16 353.55 42,522 8.16 17 354 125,740 33.65 18 355 384,703 38.17 19 356.10 103,182 45.35 20 356.20 154,000 39.96 21 357 29,332 35.63 22 358 106,578 35.25 23 359 2,339 66 24 Subtotal 1,699,944 25 26 Distribution: 27 360.25 16,532 50.98 28 361 35,443 47.23 29 362 442,077 38.79 30 362.55 29,663 9.12 31 364 827,065 31 32 365 913,462 20.26 33 366 136,497 50.66 34 367 433,723 38.41 35 368 707,777 24.95 36 369.10 291,743 24.98 37 369.20 9,711 35.09 38 369.21 109,304 31.06 39 370.10 49,955 26.32 40 370.20 62,058 29.55 41 371 8,195 6 42 373 199,174 20.87 43 374 116 14 44 Subtotal 4,272,495 45 46 47 48 49 50 FERC FORM NO. 1 (ED. 12-95) Next Page is 340 Page 337 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued) C. Factors Used in Estimating Depreciation Charges Depreciable Estimated Applied Average Account Plant Base Avg. Service Net Salvage Depr. Rates Mortality Curve Remaining Line No. (In thousands) Life (Percent) (Percent) Type Life No. (a) (b) (c) (d) (e) (f) (g) 12 General: 13 390 89,858 39.84 14 391 4,609 29.81 15 391.10 2,812 19 16 391.20 1,805 2.21 17 393 2,143 27.13 18 394 2,519 33.63 19 394.10 6,082 19.72 20 394.20 38,138 28.41 21 395 20,810 28.97 22 396 0 0 23 397.20 54,190 14 24 397.40 3,443 0.12 25 397.60 18,038 8.89 26 398 9,121 7.28 27 398.10 1,978 31.48 28 398.56 39,949 4.31 29 399.1 468 24 30 Subtotal 295,963 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 FERC FORM NO. 1 (ED. 12-95) Next Page is 340 Page 337-A Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 PARTICULARS CONCERNING CERTAIN INCOME DEDUCTIONS AND INTEREST CHARGES ACCOUNTS

Report the information specified below, in the order Deductions, of the Uniform System of Accounts. Amounts given, for the respective income deduction and interest of less than 5% of each account total for the year (or $1,000, charges accounts. Provide a subheading for each whichever is greater) may be grouped by classes within account and a total for the account. Additional columns the above accounts. may be added if deemed appropriate with respect to any (c) Interest on Debt to Associated Companies (Account account. 430)-For each associated company to which interest on (a) Miscellaneous Amortization (Account 425)-Describe debt was incurred during the year, indicate the amount and the nature of items included in this account, the contra interest rate respectively for (a) advances on notes, (b) account charged, the total of amortization charges for the advances on open account, (c) notes payable, (d) accounts year, and the period of amortization. payable, and (e) other debt, and total interest. Explain the (b) Miscellaneous Income Deductions-Report the nature, nature of other debt on which interest was incurred during payee, and amount of other income deductions for the year the year. as required by Accounts 426.1, Donations; 426.2, Life (d) Other Interest Expense (Account 431)-Report Insurance; 426.3, Penalties; 426.4, Expenditures for Certain particulars (details) including the amount and interest rate Civic, Political and Related Activities; and 426.5, Other for other interest charges incurred during the year.

Line Item Amount No. (a) (b) 1 Miscellaneous Amortization (Account 425) 2 3 4None 5 6 7 8 9 10 Total $0 11 Donations (Account 426.1) 12 13 Cultural Organizations $7,024 14 Health and Human Services 56,804 15 Civic Organizations 800 16 Educational Activities 17,620 17 Environmental Organizations 670 18 Economic Development Organizations 5,000 19 Service Company Allocations 226,497 20 All Other Donations 770,317 21 22 Total $1,084,731 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 FERC FORM NO. 1 (ED. 12-87) NYPSC Modified-96 Next Page is 350 Page 340

If applicable, see insert pages below: Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 REGULATORY COMMISSION EXPENSES FOR ELECTRIC AND GAS

1. Report particulars (details) of regulatory commission expenses 2. Report in columns (b) and (c) only the current year's incurred during the current year (or incurred in previous years, expenses that are not deferred and the current year's if being amortized) relating to formal cases before a regulatory amortization of amounts deferred in previous years. body, or cases in which such a body was a party. Identify this expense as Electric, Gas or Common.

Description (Furnish name of regulatory commission or body Assessed by Expenses Total Deferred in Line the docket or case number, and a description Regulatory of Expenses for Account 182.3 No. of the case.) Commission Utility Current Year Beginning (b) + (c) of Year (a) (b) (c) (d) (e) 1 PUBLIC SERVICE COMMISSION OF THE STATE 2 OF NEW YORK 3 4 Expense of the New York State Public Service Commission 55,999,960 55,999,960 5 in accordance with 18-A of the Public Service Law. 6 7 8 MISCELLANEOUS: 9 10 Miscellaneous FERC and PSC expenses relating to permit 9,438,685 9,438,685 11 fees, regulatory requirements, legal fees, environmental 12 activities and other various matters. 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 TOTAL $55,999,960 $9,438,685 $65,438,645 $0 FERC FORM NO. 1 (ED. 12-96) NYPSC Modified-96 Page 350 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 REGULATORY COMMISSION EXPENSES FOR ELECTRIC AND GAS (Continued)

3. Show in column (k) any expenses incurred in prior years 4. List in column (f), (g), and (h) expenses incurred which are being amortized. List in column (a) the period of during year which were charged currently to income, amortization. plant, or other accounts. 5. Minor items (less than $25,000) may be grouped.

Expenses Incurred During Year Amortized During Year Charged Currently to Deferred to Contra Amount Deferred in Department Account Amount Account 182.3 Account Account 182.3 Line No. End of Year No. (f) (g) (h) (i) (j) (k) (l) 1 2 3 Electric 928 45,023,407 4 Gas 928 10,976,553 5 6 7 8 9 Electric 928 8,013,883 10 Gas 928 1,424,802 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 $65,438,645 $0 $0 $0 46 FERC FORM NO. 1 (ED. 12-96) NYPSC Modified-96 Page 351 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 RESEARCH, DEVELOPMENT, AND DEMONSTRATION ACTIVITIES (Electric and Gas)

1. Describe and show below costs incurred and accounts charged b. Fossil-fuel steam during the year for technological research, development, and c. Internal combustion or gas turbine demonstration (R, D & D) project initiated, continued, or concluded d. Nuclear during the year. Report also support given to others during the e. Unconventional generation year for jointly-sponsored projects. (Identify recipient regardless f. Siting and heat rejection of affiliation.) For any R, D & D work carried on by the respondent (2) System Planning, Engineering and Operation in which there is a sharing of costs with others, show separately (3) Transmission the respondent's cost for the year and cost chargeable to others. a. Overhead (See definition of research, development, and demonstration in b. Underground Uniform System of Accounts.) (4) Distribution 2. Indicate in column (a) the applicable classification, as shown (5) Environment (other than equipment) below. Classifications: (6) Other (Classify and include items in excess of A. Electric and Gas R, D & D Performed Internally $5,000.) (1) Generation (7) Total Cost Incurred a. Hydroelectric B. Electric and Gas R, D & D Performed Externally i. Recreation, fish, and wildlife (1) Research Support to the Electrical Research ii. Other hydroelectric Council or the Electric Power Research Institute

Line Classification Description No. (a) (b) 1 Electric Utility 2 A. R &D Performed Internally: 3 4 6. Other R & D Operations 5 6 B. R & D Performed Externally R & D Operations 7 NYSERDA Electric - 8 (*253,597 is Transmission) 9 10 Relay Grade CTs and PTs Rev Me 11 12 13 Gas Utility 14 A. R &D Performed Internally: 15 16 6. Other R & D Operations 17 18 B. R & D Performed Externally R & D Operations 19 NYSERDA Gas 20 Relay Grade CTs and PTs Rev Me 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 Total FERC FORM NO. 1 (ED. 12-87) Page 352 If applicable, see insert pages below: Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 RESEARCH, DEVELOPMENT, AND DEMONSTRATION ACTIVITIES (Continued)

(2) Research Support to Edison Electric 4. Show in column (e) the account number charged Institute with expenses during the year or the account to which (3) Research Support to Nuclear Power amounts were capitalized during the year, listing Account Groups 107, Construction Work in Progress, first. Show in column (f) (4) Research Support to Others (Classify) the amounts related to the account charged in column (e). (5) Total Cost Incurred 5. Show in column (g) the total unamortized accumulation 3. Include in column (c) all R, D & D items performed of costs of projects. This total must equal the balance internally and in column (d) those items performed in Account 188, Research, Development, and Demonstration outside the company costing $5,000 or more, briefly Expenditures, Outstanding at the end of the year. describing the specific area of R, D & D (such as safety, 6. If costs have not been segregated for R, D & D activities corrosion control, pollution, automation, measurement, or projects, submit estimates for columns (c), (d), and (f) with insulation, type of appliance, etc.). Group items under such amounts identified by "Est." $5,000 by classifications and indicate the number of 7. Report separately research and related testing items grouped. Under Other, (A.(6) and B.(4)) classify facilities operated by the respondent. items by type of R, D & D activity.

Costs Incurred Internally Costs Incurred Externally AMOUNTS CHARGED IN CURRENT YEAR Unamortized Current Year Current Year Account Amount Accumulation Line (c) (d) (e) (f) (g) No. 01 02 03 57,257 930 57,257 4 05 82,482 930 82,482 6 2,113,309 930 2,113,309 7 08 09 57,741 930 57,741 10 011 012 013 014 015 11,727 880 11,727 16 017 32,965 32,965 18 844,147 880 844,147 19 11,826 880 11,826 20 021 022 023 024 025 026 027 028 029 030 031 032 033 034 035 036 037 $68,984 $3,142,470 $3,211,454 $0 38 FERC FORM NO. 1 (ED. 12-87) Page 353 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 DISTRIBUTION OF SALARIES AND WAGES

Report below the distribution of total salaries and wages lines and columns provided. In determining this segregation for the year. Segregate amounts originally charged to clearing of salaries and wages originally charged to clearing accounts, accounts to Utility Departments, Construction, Plant Removals, a method of approximation giving substantially correct results and Other Accounts, and enter such amounts in the appropriate may be used.

Allocation of Line Classification Direct Payroll Payroll Charged for Total No. Distribution Clearing Accounts (a) (b) (c) (d) 1Electric 2Operation 3 Production 4 Transmission 9,005,984 5 Distribution 62,720,850 6 Customer Accounts 7 Customer Service and Informational 3,495,678 8 Sales 9 Administrative and General 29,262,397 10 TOTAL Operation (Enter Total of lines 3 thru 9) 104,484,909 11 Maintenance 12 Production 13 Transmission 9,363,635 14 Distribution 50,195,511 15 Administrative and General 1,544,394 16 TOTAL Maint. (Total of lines 12 thru 15) 61,103,540 17 Total Operation and Maintenance 18 Production (Enter Total of lines 3 and 12) 0 19 Transmission (Enter Total of lines 4 and 13) 18,369,619 20 Distribution (Enter Total of lines 5 and 14) 112,916,361 21 Customer Accounts (Transcribe from line 6) 0 22 Customer Service and Informational (Transcribe from line 7) 3,495,678 23 Sales (Transcribe from line 8) 0 24 Administrative and General (Enter Total of lines 9 and 15) 30,806,791 25 TOTAL Oper. and Maint. (Total of lines 18 thru 24) 165,588,449 8,668,644 174,257,093 26 Gas 27 Operation 28 Production - Manufactured Gas 29 Production - Natural Gas (Including Expl. and Dev.) 30 Other Gas Supply 31 Storage, LNG Terminaling and Processing 32 Transmission 33 Distribution 7,685,437 34 Customer Accounts 5,241,609 35 Customer Service and Informational 662,879 36 Sales 37 Administrative and General 4,362,896 38 TOTAL Operation (Enter Total of lines 28 thru 37) 17,952,821 39 Maintenance 40 Production - Manufactured Gas 41 Production - Nat. Gas 42 Other Gas Supply 43 Storage, LNG Terminaling and Processing 44 Transmission 45 Distribution 17,506,473 46 Administrative and General 80,783 47 TOTAL Maint. (Enter Total of lines 40 thru 46) 17,587,256 FERC FORM NO. 1 (ED. 12-88) Page 354 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 DISTRIBUTION OF SALARIES AND WAGES (Continued) Allocation of Line Classification Direct Payroll Payroll Charged for Total No. Distribution Clearing Accounts (a) (b) (c) (d) Gas (Continued) 48 Total Operation and Maintenance 49 Production - Manufactured Gas (Enter Total of lines 28 and 40) 0 50 Production - Nat. Gas (Including Expl. and Dev.) (Total of lines 29 and 41) 0 51 Other Gas Supply (Enter Total of lines 30 and 42) 0 52 Storage, LNG Terminaling and Processing (Total of lines 31 and 43) 0 53 Transmission (Lines 32 and 44) 0 54 Distribution (Lines 33 and 45) 25,191,910 55 Customer Accounts (Line 34) 5,241,609 56 Customer Service and Informational (Line 35) 662,879 57 Sales (Line 36) 0 58 Administrative and General (Lines 37 and 46) 4,443,679 59 TOTAL Operation and Maint. (Total of lines 49 thru 58) 35,540,077 2,009,777 37,549,854 60 Other Utility Departments 0 61 Operation and Maintenance 0 62 TOTAL All Utility Dept. (Total of lines 25, 59, and 61) 201,128,526 10,678,421 211,806,947 63 Utility Plant 64 Construction (By Utility Departments) 65 Electric Plant 69,821,312 8,052,141 77,873,453 66 Gas Plant 19,460,312 1,677,382 21,137,694 67 Other 0 68 TOTAL Construction (Total of lines 65 thru 67) 89,281,624 9,729,523 99,011,147 69 Plant Removal (By Utility Departments) 70 Electric Plant 10,051,009 865,747 10,916,756 71 Gas Plant 1,676,076 128,455 1,804,531 72 Other 0 73 TOTAL Plant Removal (Total of lines 70 thru 72) 11,727,085 994,202 12,721,287 74 Other Accounts (Specify): 75 Other Work in Progress 938,313 37,180 975,493 76 Preliminary Survey and Investigation 1,375,779 1,375,779 77 Misc AP and Accurals 1,011,646 1,011,646 78 Deferred Credits 145,992 888 146,880 79 Expense of non Utility Operation 1,739,370 1,739,370 80 Misc Income Deductions 296,714 296,714 81 0 82 0 83 0 84 0 85 0 86 0 87 0 88 0 89 0 90 0 91 0 92 0 93 0 94 0 95 TOTAL Other Accounts 5,507,814 38,068 5,545,882 96 TOTAL SALARIES AND WAGES 307,645,049 21,440,214 329,085,263 FERC FORM NO. 1 (ED. 12-88) Page 355 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 COMMON UTILITY PLANT AND EXPENSES

1. Describe the property carried in the utility's accounts as to which such accumulated provisions relate, including common utility plant and show the book cost of such plant at explanation of basis of allocation and factors used. end of year classified by accounts as provided by Plant 3. Give for the year the expenses of operation, Instruction 13, Common Utility Plant, of the Uniform System maintenance, rents, depreciation, and amortization for of Accounts. Also show the allocation of such plant costs to common utility plant classified by accounts as provided by the respective departments using the common utility plant the Uniform System of Accounts. Show the allocation of and explain the basis of allocation used, giving the allocation such expenses to the departments using the common utility factors. plant to which such expenses are related. Explain the basis 2. Furnish the accumulated provisions for depreciation and of allocation used and give the factors of allocation. amortization at end of year, showing the amounts and 4. Give date of approval by the Commission for use of the classifications of such accumulated provisions, and amounts common utility plant classification and reference to order of allocated to utility departments using the common utility plant the Commission or other authorization.

Acct. Beginning Ending No. Item Balance Additions Retirements Transfers Balance 301 Organization $0 302 Franchises & Consents 0 303 Miscellaneous Intangible Plant Total Intangible Plant00000

Other (Specify) Total Other 00000

389 Land & Land Rights 5,281,231 (13,522) 0 0 5,267,709 390 Structures & Improvements 165,704,874 2,944,498 (678,853) 0 167,970,519 391 Office Furniture & Equipment 47,291,503 (570,790) (2,077,177) 47,270 44,690,806 392 Transportation Equipment 4,972,721 (789,474) 0 0 4,183,247 393 Stores Equipment 5,195,1200005,195,120 394 Tools, Shop & Garage Equipmt. 11,040,006 (871,024) 0 0 10,168,982 395 Laboratory Equip 108,149000108,149 396 Power Operated Equipment 2,556 0 (2,556) 0 0 397 Communication Equipment 71,596,577 645,366 (351,336) (1,265,171) 70,625,436 398 Misc. Equipment 1,592,412 (558,339) 0 0 1,034,073 399 Other Tangible Property 00000 Total General Plant 312,785,149 786,715 (3,109,922) (1,217,901) 309,244,041

Total Common Utility Plant $312,785,149 $786,715 ($3,109,922) ($1,217,901) $309,244,041

Departmental Allocation of Common Items

Allocations to Electric 85% Allocation to Gas 15%

FERC FORM NO. 1 (ED. 12-87) NYPSC MODIFIED-97 Next Page is 401 Page 356 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 COMMON UTILITY PLANT AND EXPENSES (CONTINUED)

RESERVE FOR DEPRECIATION OF COMMON UTILITY PLANT

Balance January 1, 2009 92,889,927 Depreciation and Amortization Provisions for year charged to: Depreciation - Electric 17,320,537 Depreciation - Gas 1,866,679 Amortization - Electric Amortization - Gas Transportation - Clearing Account

Total Depreciation and Amortization Provisions 19,187,216

Net Charges for Plant Retired: Book Cost of Plant Retired (12,971,842) Cost of Removal 579,387 Salvage (Credit)

Net Charges for Plant Retired (12,392,455)

Other Debit or Credit Items: Net increase in Retirement Work in Progress 3,015,644 Transfer of Provisions to Electric Department Accum. Amortization-Limited Term Property-Johnson Bldg.

Balance December 31, 2009 $102,700,332

Common Utility Expenses and Departmental Allocation

Inquiry 3- Operation and Maintenance expense of common utility plant are charged directly to the electric and gas departments on the basis of customers in the various districts.

Inquiry 4- Prescribed by the Public Service Commision of the State of New York in its Uniform System of Accounts for the Electric and Gas.

FERC FORM NO. 1 (ED. 12-87) NYPSC MODIFIED - 97 Next Page is 401 Page 356-A Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 ELECTRIC ENERGY ACCOUNT

Report below the information called for concerning the disposition of electric energy generated, purchased, exchanged and wheeled during the year.

Line Item Megawatthours Line Item Megawatthours No. (a) (b) No. (a) (b) 1 SOURCES OF ENERGY 21 DISPOSITION OF ENERGY 2 Generation (Excluding Station Use): 22 Sales to Ultimate Consumers 18,298,135 3 Steam (Including Interdepartmental Sales) 4 Nuclear 23 Requirements Sales for Resale 5,007 5 Hydro - Conventional (See Instruction 4, page 311.) 6 Hydro - Pumped Storage 24 Non-Requirements Sales for Resale 502,774 7 Other (See Instruction 4, page 311.) 8 Less Energy for Pumping 25 Energy Furnished Without Charge 9 Net Generation (Enter Total 26 Energy Used by the Company (Electric 22,353 of lines 3 through 8) 0 Department Only, Excluding Station Use) 10 Purchases 19,858,666 27 Total Energy Losses 1,030,397 11 28 TOTAL (Enter Total of Lines 22 12 Received Through 27)(MUST EQUAL LINE 20) 19,858,666 13 Delivered 14 Net Exchanges (Line 12 minus line 13) 0 15 Transmission for Other (Wheeling) 16 Received 3,276,585 17 Delivered 3,276,585 18 Net Transmission for Other (Line 16 minus line 17) 0 19 Transmission by Other Losses 20 TOTAL (Enter Total of lines 9, 10, 14, 18 and 19) 19,858,666 MONTHLY PEAKS AND OUTPUT

1. If the respondent has two or more power systems which are sales so that the total of line 41 exceeds the amount on line 24 not physically integrated, furnish the required information for by the amount of losses incurred (or estimated) in making each non-integrated system. the Non-Requirements Sales for Resale. 2. Report in column (b) the system's energy output for each 4. Report in column (d) the system's monthly maximum megawatt month such that the total on line 41 matches the total on line 20. load (60-minute integration) associated with the net energy for 3. Report in column (c) a monthly breakdown of the Non- the system defined as the difference between columns (b) and (c). Requirements Sales for Resale reported on line 24. Include in 5. Report in columns (e) and (f) the specified information for each the monthly amounts any energy losses associated with the monthly peak load reported in column (d).

Name of System: Monthly Non-Requirements MONTHLY PEAK Line Month Total Monthly Energy Sales for Resale Megawatts Day of Month Hour No. & Associated Losses (See Instruction 4) (a) (b) (c) (d) (e) (f) 29 January 1,846,802 40,781 5,508 15 19 30 February 1,685,922 31,039 5,425 5 19 31 March 1,675,765 44,010 5,311 2 19 32 April 1,550,768 48,018 4,349 7 21 33 May 1,525,133 53,159 4,333 21 15 34 June 1,626,311 49,084 4,223 25 14 35 July 1,651,390 42,303 5,454 29 14 36 August 1,836,008 46,064 6,194 17 15 37 September 1,549,304 38,825 4,988 23 20 38 October 1,508,448 42,414 4,784 15 20 39 November 1,585,506 48,562 5,035 30 18 40 December 1,817,309 51,327 5,680 17 18 41 TOTAL 19,858,666 535,586 FERC FORM NO. 1 (REVISED 12-90) Page 401 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 STEAM-ELECTRIC GENERATING PLANT STATISTICS (Large Plants)

1. Report data for Plant in Service only. 6. If gas is used and purchased on a therm basis, report 2. Large plants are steam plants with installed capacity (name plate the Btu content of the gas and the quantity of fuel burned rating) of 25,000 Kw or more. Report on this page gas-turbine and converted to Mcf. internal combustion plants of 10,000 Kw or more, and nuclear plants. 7. Quantities of fuel burned (line 37) and average cost per 3. Indicate by a footnote any plant leased or operated as a joint facility. unit of fuel burned (line 40) must be consistent with charges 4. If net peak demand for 60 minutes is not available, give data which to expense accounts 501 and 547 (line 41) as shown on is available, specifying period. line 19. 5. If any employees attend more than one plant, report on line 11 the 8. If more than one fuel is burned in a plant, furnish only the approximate average number of employees assignable to each plant. composite heat rate for all fuels burned.

Plant Name: Plant Name: Line Item No. (a) (b) (c) 1 Kind of Plant (Steam, Internal Combustion, Gas Turbine or Nuclear) 2 Type of Plant Construction (Conventional, Outdoor Boiler, Full Outdoor, Etc.) 3 Year Originally Constructed 4 Year Last Unit was Installed 5 Total Installed Capacity (Maximum Generator Name Plate Ratings in MW) 6 Net Peak Demand on Plant - MW (60 minutes) 7 Plant Hours Connected to Load 8 Net Continuous Plant Capability (Megawatts) 9 When Not Limited by Condenser Water 10 When Limited by Condenser Water 11 Average Number of Employees 12 Net Generation, Exclusive of Plant Use - KWh 13 Cost of Plant: Land and Land Rights 14 Structures and Improvements 15 Equipment Costs 16 Total Cost $0 $0 17 Cost per KW of Installed Capacity (Line 5) 18 Production Expenses: Oper. Supr. & Engr. 19 Fuel 20 Coolants and Water (Nuclear Plants Only) 21 Steam Expenses 22 Steam From Other Sources 23 Steam Transferred (Cr.) 24 Electric Expenses 25 Misc. Steam (or Nuclear) Power Expenses 26 Rents 27 Allowances 28 Maintenance Supervision and Engineering 29 Maintenance of Structures 30 Maintenance of Boiler (or Reactor) Plant 31 Maintenance of Electric Plant 32 Maintenance of Misc. Steam (or Nuclear) Plant 33 Total Production Expenses $0 $0 34 Expenses per Net KWh 35 Fuel: Kind (Coal, Gas, Oil, or Nuclear) 36 Unit: (Coal - tons of 2,000 lb.)(Oil - barrels of 42 gals.)(Gas - Mcf)(Nuclear - indicate) 37 Quantity (Units) of Fuel Burned 38 Avg. Heat Cont. of Fuel Burned (Btu per lb. of coal per gal. of oil, or per Mcf of gas)(Give unit if nuclear) 39 Average Cost of Fuel per Unit, as Delivered f. o. b. Plant During Year 40 Average Cost of Fuel per Unit Burned 41 Avg. Cost of Fuel Burned per Million Btu 42 Avg. Cost of Fuel Burned per KWh Net Gen. 43 Average Btu per KWh Net Generation FERC FORM NO. 1 (REV. 12-95) Page 402 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 STEAM-ELECTRIC GENERATING PLANT STATISTICS (Large Plants) (Continued)

9. Items under Cost of Plant are based on U. S. of A. accounts. Production However, if a gas-turbine unit functions in a combined cycle operation with expenses do not include Purchased Power, System Control and Load Dispatching, a conventional steam unit, include the gas-turbine with the steam plant. and Other Expenses classified as Other Power Supply Expenses. 12. If a nuclear power generating plant, briefly explain by footnote (a) 10. For IC and GT plants, report Operating Expenses, Account Nos. 548 and 549 accounting method for cost of power generated including any excess costs on line 24 "Electric Expenses," and Maintenance Account Nos. 553 and 554 on line attributed to research and development; (b) types of cost units used for the 31 "Maintenance of Electric Plant." Indicate plants designed for peak load service. various components of fuel cost; and (c) any other informative data Designate automatically operated plants. concerning plant type, fuel used, fuel enrichment by type and quantity for 11. For a plant equipped with combinations of fossil fuel steam, nuclear steam, hy- the report period, and other physical and operating characteristics of the dro, internal combustion or gas-turbine equipment, report each as a separate plant. plant.

Plant Name: Plant Name: Plant Name: Line (d) (e) (f) No. 1

2

3 4 5

6 7 8 9 10 11 12 13 14 15 $0 $0 $0 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 $0 $0 $0 33 34 35 36

37 38

39

40 41 42 43 FERC FORM NO. 1 (REV. 12-95) Next Page is 406 Page 403 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 HYDROELECTRIC GENERATING PLANT STATISTICS (Large Plants)

1. Large plants are hydro plants of 10,000 Kw or more of 3. If net peak demand for 60 minutes is not available, give installed capacity (name plate ratings). that which is available, specifying period. 2. If any plant is leased, operated under a license from the 4. If a group of employees attends more than one Federal Energy Regulatory Commission, or operated as a generating plant, report on line 11 the approximate average joint facility, indicate such facts in a footnote. If licensed number of employees assignable to each plant. project, give project number.

FERC Licensed Project No. ______FERC Licensed Project No. ______Line Item Plant Name ______Plant Name ______No. (a) (b) (c) 1 Kind of Plant (Run-of-River or Storage) 2 Type of Plant Construction (Conventional or Outdoor) 3 Year Originally Constructed 4 Year Last Unit was Installed 5 Total Installed Capacity (Generator Name Plate Ratings in MW) 6 Net Peak Demand on Plant - Megawatts (60 minutes) 7 Plant Hours Connected to Load 8 Net Plant Capability (In megawatts) 9 (a) Under the Most Favorable Oper. Conditions 10 (b) Under the Most Adverse Oper. Conditions 11 Average Number of Employees 12 Net Generation, Exclusive of Plant Use - KWh 13 Cost of Plant: 14 Land and Land Rights 15 Structures and Improvements 16 Reservoirs, Dams, and Waterways 17 Equipment Costs 18 Roads, Railroads and Bridges 19 Total Cost (Enter Total of lines 14 thru 18) $0 $0 20 Cost per KW of Installed Capacity (Line 5) 21 Production Expenses: 22 Operation Supervision and Engineering 23 Water for Power 24 Hydraulic Expenses 25 Electric Expenses 26 Misc. Hydraulic Power Generation Expenses 27 Rents 28 Maintenance Supervision and Engineering 29 Maintenance of Structures 30 Maintenance of Reservoirs, Dams, and Waterways 31 Maintenance of Electric Plant 32 Maintenance of Misc. Hydraulic Plant 33 Total Production Expenses (Total lines 22 thru 32) $0 $0 34 Expenses per Net KWh

FERC FORM NO. 1 (ED. 12-88) Page 406 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 HYDROELECTRIC GENERATING PLANT STATISTICS (Large Plants) (Continued)

5. The items under Cost of Plant represent accounts or 6. Report as a separate plant any plant equipped with combinations of accounts prescribed by the Uniform Systemcombinations of steam, hydro, internal combustion engine, of Accounts. Production Expenses do not include Purchaseor gas turbine equipment. Power, System Control and Load Dispatching, and Other Expenses classified as "Other Power Supply Expenses."

__ FERC Licensed Project No. ______FERC Licensed Project No. ______FERC Licensed Project No. ______Plant Name ______Plant Name ______Plant Name ______Line No. (d) (e) (f) 1 2 3 4 5

6 7 8 9 10 11 12 13 14 15 16 17 18 $0 $0 $0 19 20 21 22 23 24 25 26 27 28 29 30 31 32 $0 $0 $0 33 34

FERC FORM NO. 1 (ED. 12-89) Page 407 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 PUMPED STORAGE GENERATING PLANT STATISTICS (Large Plants)

1. Large plants and pumped storage plants of 10,000 Kw or more 4. If a group of employees attends more than one of installed capacity (name plate ratings). generating plant, report on line 8 the approximate average 2. If any plant is leased, operated under a license from the number of employees assignable to each plant. Federal Energy Regulatory Commission, or operated as a joint 5. The items under Cost of Plant represent accounts or facility, indicate such facts in a footnote. Give project number. combinations of accounts prescribed by the Uniform System 3. If net peak demand for 60 minutes is not available, give that of Accounts. Production Expenses do not include Purchased which is available, specifying period. Power, System Control and Load Dispatching, and Other Expenses classified as "Other Power Supply Expenses."

FERC Licensed Project No. ______Line Item Plant Name ______No. (a) (b) 1 Type of Plant Construction (Conventional or Outdoor) 2 Year Originally Constructed 3 Year Last Unit was Installed 4 Total Installed Capacity (Generator Name Plate Ratings in MW) 5 Net Peak Demand on Plant - Megawatts (60 minutes) 6 Plant Hours Connected to Load While Generating 7 Net Plant Capability (In megawatts) 8 Average Number of Employees 9 Generation, Exclusive of Plant Use - KWh 10 Energy Used for Plumbing - KWh 11 Net Output for Load (line 9 minus line 10) - KWh 12 Cost of Plant: 13 Land and Land Rights 14 Structures and Improvements 15 Reservoirs, Dams, and Waterways 16 Water Wheels, Turbines, and Generators 17 Accessory Electric Equipment 18 Miscellaneous Powerplant Equipment 19 Roads, Railroads and Bridges 20 Total Cost (Enter Total of lines 13 thru 19) 21 Cost per KW of Installed Capacity (line 20 / line 4) 22 Production Expenses 23 Operation Supervision and Engineering 24 Water for Power 25 Pumped Storage Expenses 26 Electric Expenses 27 Miscellaneous Pumped Storage Power Generation Expenses 28 Rents 29 Maintenance Supervision and Engineering 30 Maintenance of Structures 31 Maintenance of Reservoirs, Dams, and Waterways 32 Maintenance of Electric Plant 33 Maintenance of Misc. Pumped Storage Plant 34 Production Exp. Before Pumping Exp. (Enter Total lines 23 thru 33) 35 Pumping Expenses 36 Total Production Expenses (Enter Total of lines 34 and 35) 37 Expenses per Net KWh (Enter result of line 36 divided by line 9)

FERC FORM NO. 1 (ED. 12-88) Page 408 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 PUMPED STORAGE GENERATING PLANT STATISTICS (Large Plants) (Continued)

6. Pumping energy (line 10) is that energy measured station or other source that individually provides more than as input to the plant for pumping purposes. 10 percent of the total energy used for pumping, and 7. Include on line 35 the cost of energy used in production expenses per net MWH as reported herein for pumping into the storage reservoir. When this item each source described. Group together stations and other cannot be accurately computed, leave lines 35, 36 sources which individually provide less than 10 percent of and 37 blank and describe at the bottom of the total pumping energy. If contracts are made with others to schedule the company's principal sources of pumping purchase power for pumping, give the supplier, contract power, the estimated amounts of energy from each number, and date of contract.

FERC Licensed Project No. ______FERC Licensed Project No. ______FERC Licensed Project No. ______Plant Name ______Plant Name ______Plant Name ______Line No. (c) (d) (e) 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37

FERC FORM NO. 1(ED. 12-88) Page 409 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 GENERATING PLANT STATISTICS (Small Plants)

1. Small generating plants are steam plants of less than 2. Designate any plant leased from others, operated under a license 25,000 Kw; internal combustion and gas-turbine plants, from the Federal Energy Regulatory Commission, or operated as a conventional hydro plants and pumped storage plants of joint facility, and give a concise statement of the facts in a footnote. less than 10,000 Kw installed capacity (name plate rating). If licensed project, give project number in footnote.

Installed Net Net Year Capacity- Peak Generation Line Name of Plant Orig. Name Plate Demand Excluding Cost of Plant No. Const. Rating MW Plant (in MW) (60 Min.) Use (a) (b) (c) (d) (e) (f) 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46

FERC FORM NO. 1 (ED. 12-87) Page 410 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 GENERATING PLANT STATISTICS (Small Plants)(Continued)

3. List plants appropriately under subheadings for steam, 5. If any plant is equipped with combinations of steam, hydro, hydro, nuclear, internal combustion and gas turbine plants. internal combustion or gas turbine equipment, report each as a For nuclear, see instruction 11, page 403. separate plant. However, if the exhaust heat from the gas turbine 4. If net peak demand for 60 minutes is not available, give is utilized in a steam turbine regenerative feed water cycle, or for that which is available, specifying period. preheated combustion air in a boiler, report as one plant.

Plant Production Expenses Cost Kind Fuel Cost Per MW Operation of (In cents Line Inst Exc'l. Fuel Fuel Maintenance Fuel per million No. Capacity Btu) (g) (h) (i) (j) (k) (l) 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46

FERC FORM NO. 1 (ED. 12-87) Next Page is 422 Page 411 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (2) [ ] A Resubmission 6/01/2010 12/31/2009 TRANSMISSION LINE STATISTICS

1. Report information concerning transmission lines, cost of lines, line has more than one type of supporting structure, indicate and expenses for year. List each transmission line having nominal the mileage of each type of construction by the use of brackets voltage of 132 kilovolts or greater. Report transmission lines below and extra lines. Minor portions of a transmission line of a these voltages in group totals only for each voltage. different type of construction need not be distinguished from 2. Transmission lines include all lines covered by the definition the remainder of the line. of transmission system plant as given in the Uniform System of 6. Report in columns (f) and (g) the total pole miles of each Accounts. Do not report substation costs and expenses on this page. transmission line. Show in column (f) the pole miles of line on 3. Report data by individual lines for all voltages if so required by structures the cost of which is reported for the line designated; a State commission. conversely, show in column (g) the pole miles of line on structures 4. Exclude from this page any transmission lines for which plant the cost of which is reported for another line. Report pole miles costs are included in Account 121, Nonutility Property. of line on leased or partly owned structures in column (g). 5. Indicate whether the type of supporting structure reported in In a footnote, explain the basis of such occupancy and state column (e) is: (1) single pole, wood or steel; (2) H-frame, wood, or steel whether expenses with respect to such structures are included poles; (3) tower; or (4) underground construction. If a transmission in the expenses reported for the line designated.

Voltage (KV) Length (Pole Miles) Designation (Indicate where other than Type of (In the case of underground Number Line 60 cycle, 3 phase) Supporting lines, report circuit miles) of No. From To Operating Designed Structure On Structures of On Structures of Circuits Line Designated Another Line (a) (b) (c) (d) (e) (f) (g) (h) 1 Homer City Stolle 37 345 345 Wood H Frames 37.30 1 2 Steel Towers 3 4 Edic New Scotland 1 345 345 Steel Towers 83.24 1 5 6 Nine Mile Point Clay 8 & 9 345 345 Wood H Frames 26.47 1 7 Steel Towers 8 9 Clay Dewitt 13 345 345 Steel Towers 15.07 1 10 11 Marcy New Scotland 1 345 345 Steel Towers 1.35 1 12 13 Marcy New Scotland 1 345 345 Steel H Frame 82.99 1 14 15 16 Oswego Lafayette 17 345 345 Wood H Frames 47.85 1 17 Steel Towers 18 19 Oswego Volney 11 345 345 Wood H Frames 13.40 1 20 Steel Towers 21 22 Oswego Volney 12 345 345 Wood H Frames 13.42 1 23 Steel Towers 24 25 Independence Scriba 25 Clay 345 345 Towers 29.52 2.80 1 26 Wood H Frames 27 28 29 30 31 32 33 34 35 36 SubTotal 350.61 2.80 10

FERC FORM NO. 1 (ED. 12-87) Page 422

If applicable, see insert pages below Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 TRANSMISSION LINE STATISTICS (Continued)

7. Do not report the same transmission line structure twice. shares in the operation of, furnish a succinct statement explaining Report lower voltage lines and higher voltage lines as one line. the arrangement and giving particulars (details) of such matters as Designate in a footnote if you do not include lower voltage lines percent ownership by respondent in the line, name of co-owner, with higher voltage lines. If two or more transmission line basis of sharing expenses of the line, and how the expenses structures support lines of the same voltage, report the pole borne by the respondent are accounted for, and accounts affected. miles of the primary structure in column (f) and the pole miles Specify whether lessor, co-owner, or other party is an associated of the other line(s) in column (g). company. 8. Designate any transmission line or portion thereof for which 9. Designate any transmission line leased to another company the respondent is not the sole owner. If such property is leased and give name of lessee, date and terms of lease, annual rent for from another company, give name of lessor, date and terms of year, and how determined. Specify whether lessee is an associated lease, and amount of rent for year. For any transmission line other company. than a leased line, or portion thereof, for which the respondent 10. Base the plant cost figures called for in columns (j) to (l) on is not the sole owner but which the respondent operates or the book cost at end of year.

Cost of Line Size of (Include in column (j) land, land rights, and EXPENSES, EXCEPT DEPRECIATION AND TAXES Conductor clearing right-of-way) Line and Material Land Construction and Total Cost Operation Maintenance Rents Total No. Other Costs Expenses Expenses Expenses (i) (j) (k) (l) (m) (n) (o) (p) 2-1192.5 ACSR $1,897,017 $10,844,257 $12,741,274 $0 1 002 003 2-795 ACSR 3,376,364 27,221,677 30,598,041 0 4 005 2167 ACSR 1,220,567 5,232,827 6,453,394 0 6 007 008 2167 ACSR 661,934 661,934 0 9 0010 2-1351.5 ACSR 154,118 154,118 0 11 0012 4-1351.5 ACSR 2,322,341 29,049,757 31,372,098 0 13 2-1192.5 ACSR 0 0 14 0015 2-1192.5 ACSR 5,625,110 19,628,216 25,253,326 0 16 2-2500 CU 0 0 17 0018 2-1192.5 ACSR 1,743,552 3,742,667 5,486,219 0 19 0020 0021 2-1192.5 ACSR 3,985,557 3,985,557 0 22 0023 0024 2-1192.5 ACSR 27,953,252 27,953,252 0 25 0026 0027 0028 0029 0030 0031 0032 0033 0034 0035 $16,184,951 $128,474,262 $144,659,213 $0 $0 $0 $0 36

FERC FORM NO. 1 (ED. 12-87) Page 423 Niagara Mohawk Power Corporation 6/01/2010 12/31/2009 TRANSMISSION LINE STATISTICS (Continued) Voltage (KV) Length (Pole Miles) Designation (Indicate where other than Type of (In the case of underground Number Line 60 cycle, 3 phase) Supporting lines, report circuit miles) of No. From To Operating Designed Structure On Structures of On Structures of Circuits Line Designated Another Line (a) (b) (c) (d) (e) (f) (g) (h) 1 Volney Clay 6 345 345 Wood H Frames 18.50 1 2 Steel Towers 3 4 Dewitt Lafayette 3 345 345 Wood H Frames 8.49 1 5 Steel Towers 6 7 Lafayette Oakdale 4 345 345 Wood H Frames 38.64 1 8 Steel Towers 9 Volney Marcy 19 345 345 Wood H Frames 64.19 1.14 1 10 Steel Towers 11 12 Scriba Volney 20 & 21 345 345 Wood Poles 8.90 8.81 1 13 14 15 Nine Mile Point Scriba 9 345 345 Wood Poles 0.86 1 16 Steel Towers 17 18 New Scotland Alps 2 - Berksh 345 345 Steel H Frame 30.81 2 19 20 21 Reynolds Road Alps 1 345 345 Wood Poles 11.12 1 22 Wood H Frames 23 Steel Towers 24 25 Leeds Hurley 301 Ros 345 345 Steel Towers 0.06 1 26 27 New Scotland Leeds 91-95 345 345 Steel Towers 78.34 1 28 29 Dunkirk - S Ripley Ripley - Erie 69 230 230 Wood Poles 31.38 1 30 Wood H Frames 31 Steel Towers 32 33 Gardenville Dunkirk 73&74 230 230 Wood Poles 47.22 47.22 2 34 Wood H Frames 35 Steel Towers 36 37 Niagara Packard 61 230 230 Steel Towers 3.42 1 38 39 Niagara Packard 62 230 230 Steel Towers 3.47 1 40 41 Packard Huntley 77&78 230 230 Steel Towers 12.14 12.14 2 42 43 44 45 Edic Porter 17 230 230 Wood Poles 0.42 1 46 Wood H Frames 47 Steel Towers 48 49 50 51 52 53 SubTotal 357.96 69.31 19

Page 422A Niagara Mohawk Power Corporation 6/01/2010 12/31/2009 TRANSMISSION LINE STATISTICS (Continued) Cost of Line Size of (Include in column (j) land, land rights, and EXPENSES, EXCEPT DEPRECIATION AND TAXES Conductor clearing right-of-way) Line and Material Land Construction and Total Cost Operation Maintenance Rents Total No. Other Costs Expenses Expenses Expenses (i) (j) (k) (l) (m) (n) (o) (p) 2167 ACSR 855,362 855,362 0 1 002 003 2-1192.5 ACSR 544,977 4,522,940 5,067,917 0 4 005 006 2-1192.5 ACSR 523,794 26,866,134 27,389,928 0 7 008 4-1351.5 ACSR 2,640,639 393,744 3,034,383 0 9 2-1192.5 ACSR 0 0 10 0011 2-1192.5 ACSR 208,643 3,535,970 3,744,613 0 12 2167 ACSR 0 0 13 0014 2-1192.5 ACSR 442,025 442,025 0 15 2167 ACSR 0 0 16 0017 2-1192.5 ACSR 2,587,038 9,483,888 12,070,926 0 18 3-1590 ACSR 0 0 19 0020 2-1192.5 ACSR 608,370 4,415,647 5,024,017 0 21 0022 0023 0024 2-1033.5 ACSR 59,438 59,438 0 25 0026 2-795 ACSR 1,756,918 12,597,644 14,354,562 0 27 0028 1192.5 ACSR 588,034 2,064,354 2,652,388 0 29 0030 0031 0032 1192.5 ACSR 3,629,162 5,698,011 9,327,173 0 33 0034 0035 0036 1431 ACSR 68,648 574,375 643,023 0 37 0038 1431 ACSR 347,181 347,181 0 39 0040 1192.5 ACSR 1,050,528 4,363,480 5,414,008 0 41 1158.4 ACSR 0 0 42 1192.5 ACSR 0 0 43 0044 2-795 ACSR 114,101 114,101 0 45 2167 ACSR 0 0 46 0047 0048 0049 0050 0051 0052 14,206,751 76,334,294 90,541,045 0 0 0 0 53

Page 423A Niagara Mohawk Power Corporation 6/01/2010 12/31/2009 TRANSMISSION LINE STATISTICS (Continued) Voltage (KV) Length (Pole Miles) Designation (Indicate where other than Type of (In the case of underground Number Line 60 cycle, 3 phase) Supporting lines, report circuit miles) of No. From To Operating Designed Structure On Structures of On Structures of Circuits Line Designated Another Line (a) (b) (c) (d) (e) (f) (g) (h) 1 Adirondack Porter 11 230 230 Wood H Frames 54.47 1 2 Steel Towers 3 4 Adirondack Porter 12 230 230 Wood H Frames 54.37 1 5 Steel Towers 6 7 Porter Rotterdam 30 230 230 Wood H Frames 24.89 1 8 Steel Towers 9 10 Porter Rotterdam 30 230 230 Wood H Frames 46.64 1 11 Steel Towers 12 13 Porter Rotterdam 31 230 230 Wood H Frames 47.39 1 14 Wood Poles 15 16 Porter Rotterdam 31 230 230 Wood H Frames 24.77 1 17 Steel Towers 18 19 Rotterdam Bear Swamp E2 230 230 Wood H Frames 43.78 1 20 Steel Towers 21 22 Beck Packard 76 230 230 Wood H Frames 4.55 1 23 Steel Towers 24 25 Elm St. Gardenville 71& 230 230 Wood H Frames 12.26 2 26 Steel Towers 27 28 New Scotland Feura Bush 3 230 230 Wood H Frames 46.05 1 29 Steel Towers 30 31 Rotterdam New Scotland 1 230 230 Wood H Frames 62.39 1 32 Steel Towers 33 34 Lines Operated at 115kV Wood H Frames 17.99 0.00 0 35 Wood Poles 8.43 0.00 0 36 Steel Towers 4,421.39 121.43 0 37 Underground 27.60 0.00 0 38 39 Lines Operated at 69kV Steel Poles 245.01 24.19 0 40 41 Lines Operated at 46kV Wood Poles 317.32 0.41 0 42 43 Lines Operated at 34.5kV Wood H Frames 3,508.52 81.04 0 44 Wood Poles 10.36 0.00 0 45 46 Lines Operated at 23kV Wood Poles 473.40 7.94 0 47 48 Lines Operated at <23kV Wood Poles 112.45 0.96 0 49 Underground 14.20 0.00 0 50 51 52 SubTotal 9,477.22 336.98 12 53 Total 10,185.79 409.09 41

Page 422B Niagara Mohawk Power Corporation 6/01/2010 12/31/2009 TRANSMISSION LINE STATISTICS (Continued) Cost of Line Size of (Include in column (j) land, land rights, and EXPENSES, EXCEPT DEPRECIATION AND TAXES Conductor clearing right-of-way) Line and Material Land Construction and Total Cost Operation Maintenance Rents Total No. Other Costs Expenses Expenses Expenses (i) (j) (k) (l) (m) (n) (o) (p) 795 ACSR 523,366 2,075,813 2,599,179 0 1 002 003 795 ACSR 2,016,243 2,016,243 0 4 005 006 795 ACSR 531,172 1,386,454 1,917,626 0 7 008 009 795 ACSR 257,202 1,892,279 2,149,481 0 10 0011 0012 795 ACSR 153,649 5,938,525 6,092,174 0 13 0014 0015 795 ACSR 24,660 1,624,638 1,649,298 0 16 0017 0018 795 ACSR 1,048,577 4,121,594 5,170,171 0 19 1033.5 ACSR 0 0 20 0021 1158.4 ACSR 26,140 508,904 535,044 0 22 1192.5 ACSR 0 0 23 0024 750 CU 70,236 229,276 299,512 0 25 1500 CU 0 0 26 0027 795 ACSR 683,615 1,683,581 2,367,196 0 28 0029 0030 795 ACSR 235,415 1,465,698 1,701,113 0 31 0032 0033 36,550,064 295,774,173 332,324,237 0 34 19,707 125,222,744 125,242,451 0 35 36,569,771 420,996,917 457,566,688 0 36 000 037 000 038 2,292,986 13,702,662 15,995,648 0 39 000 040 1,221,609 23,863,533 25,085,142 0 41 000 042 8,748,924 102,123,827 110,872,751 0 43 000 044 000 045 4,191,467 21,836,658 26,028,125 0 46 000 047 1,692,857 2,327,972 4,020,829 0 48 000 049 0050 0051 94,841,417 1,028,791,491 1,123,632,908 0 52 125,233,119 1,233,600,047 1,358,833,166 0 0 0 0 53

Page 423B Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 TRANSMISSION LINES ADDED DURING YEAR

1. Report below the information called for concerning underground construction and show each transmission line transmission lines added or altered during the year. separately. If actual costs of completed construction are not It is not necessary to report minor revisions of lines. readily available for reporting columns (l) and (o), it is permissible 2. Provide separate subheadings for overhead and to report in these columns the estimated final completion

SUPPORTING CIRCUITS PER LINE DESIGNATION Line STRUCTURE STRUCTURE Length Average Line in Number No. From To Miles Type per Present Ultimate Miles (a) (b) (c) (d) (e) (f) (g) 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 Total 0 0 0

FERC FORM NO. 1 (ED. 12-86) Page 424 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 TRANSMISSION LINES ADDED DURING YEAR (Continued)

costs. Designate, however, if estimated amounts are report- 3. If design voltage differs from operating voltage, ed. Include costs of Clearing Land and Rights-of-Way, and indicate such fact by footnote; also where line is Roads and Trails, in column (l) with appropriate footnote, and other than 60 cycle, 3 phase, indicate such other costs of Underground Conduit in column (m). characteristic.

Conductors Line Cost Voltage Land Poles, Configuration KV and Towers, Conductors Line Size Specifications and (Operating) Land and and Total No. Spacing Rights Fixtures Device (h) (i) (j) (k) (l) (m) (n) (o) $0 1 02 03 04 05 06 07 08 09 010 011 012 013 014 015 016 017 018 019 020 021 022 023 024 025 026 027 028 029 030 031 032 033 034 035 036 037 038 039 040 041 042 043 $0 $0 $0 $0 44

FERC FORM NO. 1 (ED. 12-86) Page 425 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 SUBSTATIONS

1. Report below the information called for concerning be grouped according to functional character, but the substations of the respondent as of the end of the number of such substations must be shown. year. 4. Indicate in column (b) the functional character of each 2. Substations which serve only one industrial or street substation, designating whether transmission or distribution railway customer should not be listed below. and whether attended or unattended. At the end of the page, 3. Substations with capacities of less than 10 MVa, summarize according to function the capacities reported for except those serving customers with energy for resale, may the individual stations in column (f).

VOLTAGE (In MVa)

Line Name and Location of Substation Character of Substation No. Primary Secondary Tertiary

(a) (b) (c) (d) (e) 1 Albany High School Station 403 - C Albany Distr - Unattended 34.00 13.00 2 Albion Station 80 - V Albion Distr - Unattended 34.00 5.00 3 Alder Creek Station 701, T Boonville Distr - Unattended 46.00 13.00 4 Alder Creek Station 701, T Boonville Distr - Unattended 46.00 5.00 5 Altamont 283 - T Guilderland Distr - Unattended 115.00 13.00 6 Altamont 283 - T Guilderland Distr - Unattended 115.00 34.00 5.00 7 Amsterdam - T Florida Trans - Unattended 115.00 13.00 8 Andover Station - V Andover Trans - Unattended 115.00 34.00 9 Andover Station - V Andover Trans - Unattended 34.00 5.00 10 Antwerp Station 801 - V Antwerp Distr - Unattended 23.00 5.00 11 Arnold Station #4746 - C Utica Distr - Unattended 46.00 13.00 12 Arnold Station #4746 - C Utica Distr - Unattended 46.00 5.00 13 Ash Street Station #223 - C Syracuse Trans - Unattended 115.00 34.00 14 Ash Street Station #223 - C Syracuse Trans - Unattended 115.00 12.00 15 Ash Street Station #223 - C Syracuse Trans - Unattended 34.00 4.00 16 Ash Street Station #223 - C Syracuse Trans - Unattended 115.00 13.00 17 Ash Street Station #223 - C Syracuse Trans - Unattended 13.00 12.00 18 Ashley Station 331 - T Fort Ann Distr - Unattended 34.00 13.00 19 Attica Station 12 - V Attica Distr - Unattended 34.00 5.00 20 Ausable Forks Station 846 - T Blackbrook Distr - Unattended 46.00 5.00 21 Avenue "A" - C Albany Distr - Unattended 34.00 4.00 22 Avon Station 43 - V Avon Distr - Unattended 34.00 5.00 23 Baker Street Station 150 - T Busti Distr - Unattended 115.00 13.00 24 Ballina Station 221 - T Cazenovia Distr - Unattended 34.00 13.00 25 Ballston Station 12 - V Ballston Spa Trans - Unattended 115.00 34.00 13.00 26 Ballston Station 12 - V Ballston Spa Trans - Unattended 115.00 13.00 27 Ballston Station 12 - V Ballston Spa Trans - Unattended 34.00 4.00 28 Balmat Station 904 - Town of Fowler Trans - Unattended 115.00 23.00 29 Balmat Station 904 - Town of Fowler Trans - Unattended 23.00 5.00 30 Barker Station 78 - T Somerset Distr - Unattended 34.00 4.00 31 Bartell Station 325 - T Cicero Distr - Unattended 115.00 14.00 32 Basom Station 15 - T Alabama Distr - Unattended 34.00 5.00 33 Batavia Station 01 - C Batavia Trans - Unattended 115.00 34.00 34 Batavia Station 01 - C Batavia Trans - Unattended 115.00 5.00 35 Batavia Station 01 - C Batavia Trans - Unattended 115.00 13.00 36 Battenkill Station 342 - T Easton Trans - Unattended 115.00 34.00 13.00 37 Battenkill Station 342 - T Easton Trans - Unattended 115.00 13.00 38 Battle Hill Station 949- T Fowler Trans - Unattended 115.00 23.00 39 Belmont Station 260 - T Clay Distr - Unattended 115.00 13.00 40

FERC FORM NO. 1 (ED. 12-96) Page 426

If applicable, see insert page below Niagara Mohawk Power Corporation 6/01/2010 12/31/2009 SUBSTATIONS (Continued)

VOLTAGE (In MVa)

Line Name and Location of Substation Character of Substation No. Primary Secondary Tertiary

(a) (b) (c) (d) (e) 1 Bemus Point Station 159 - T Ellery Distr - Unattended 34.00 5.00 2 Bennett Rd Station 99 - T Dunkirk Distr - Unattended 115.00 14.00 3 Berry Road Station 153 - T Pomfret Distr - Unattended 115.00 13.00 4 Bethlehem Station 21 - T Bethlehem Trans - Unattended 115.00 34.00 5.00 5 Bethlehem Station 21 - T Bethlehem Trans - Unattended 115.00 13.00 6 Bevis Hill Station 286 - T Niskayuna Distr - Unattended 34.00 4.00 7 Birch Ave Station 322 - T Lake George Distr - Unattended 34.00 13.00 8 Black River Station 70 - T LeRay Trans - Unattended 115.00 23.00 9 Bloomington Station 841 - T St Armand Distr - Unattended 46.00 5.00 10 Blue Stores Station 303 - T Livingston Distr - Unattended 115.00 13.00 11 Bolton Station 284 - T Bolton Distr - Unattended 34.00 13.00 12 Bombay Station 897 - T Bombay Distr - Unattended 34.00 5.00 13 Booneville Station 707 - T Leyden Trans - Unattended 115.00 48.00 14 Booneville Station 707 - T Leyden Trans - Unattended 115.00 23.00 15 Booneville Station 707 - T Leyden Trans - Unattended 115.00 46.00 16 Boyntonville Station 333 - T Pittstown Distr - Unattended 115.00 13.00 17 Brady Station 957 - T Madrid Distr - Unattended 115.00 13.00 18 Brasher Falls Station 851 - T Brasher Distr - Unattended 34.00 5.00 19 Bremen Station 815 - T New Bremen Distr - Unattended 115.00 13.00 20 Brewerton Station 7 - T Cicero Distr - Unattended 34.00 5.00 21 Bridge Street Station 295 - T Dewitt Distr - Unattended 115.00 13.00 22 Bridgeport Station 168 - T Sullivan Distr - Unattended 115.00 13.00 23 Brier Hill Station 953 - T Morristown Distr - Unattended 23.00 5.00 24 Brigham Road Station 64 - T Dunkirk Distr - Unattended 115.00 13.00 25 Brighton Avenue Station 8 - C Syracuse Distr - Unattended 34.00 4.00 26 Bristol Hill Station 109 - T Volney Trans - Unattended 115.00 34.00 27 Brockport Station 74 - V Brockport Trans - Unattended 115.00 34.00 28 Brockport Station 74 - V Brockport Trans - Unattended 115.00 13.00 29 Brooks Road Station 369 - C Saratoga Distr - Unattended 115.00 14.00 30 Brooks Road Station 369 - C Saratoga Distr - Unattended 115.00 34.00 7.00 31 Browns Fall Station 711 - T Fine Trans - Unattended 115.00 34.00 32 Browns Fall Station 711 - T Fine Trans - Unattended 34.00 14.00 33 Brunswick Station 264 - T Brunswick Distr - Unattended 34.00 13.00 34 Buckbee Mears Station 300 - C Cortland Distr - Unattended 115.00 13.00 35 Buckley Corners Station 454 - Greenport Distr - Unattended 115.00 13.00 37 Buckley Road Station 140 - T Clay Distr - Unattended 34.00 5.00 38 Burdeck Street Station 265 - T Rotterdam Distr - Unattended 115.00 14.00 39 Burgoyne Ave Station 337 - T Kingsbury Distr - Unattended 115.00 13.00 40 Busti Station 68 - T Busti Distr - Unattended 34.00 5.00 41 Butler Station 362 - T Moreau Distr - Unattended 115.00 14.00 42 Butternut Station 255 - T Dewitt Distr - Unattended 115.00 14.00 43 Butts Road Station 72 - T Albion Distr - Unattended 34.00 13.00 44 Byron Station 18 - T Byron Distr - Unattended 34.00 5.00 45 Caledonia Station 44 - T Caledonia Distr - Unattended 34.00 0.00 46 Camillus Station 10 - T Camillus Distr - Unattended 34.00 4.00 47 Canajoharie Station 31 - V Canajoharie Distr - Unattended 69.00 5.00 48 Canawagus Station - T Caledonia Distr - Unattended 34.00 0.00 49 Cardiff Station 13 - T Lafayette Distr - Unattended 34.00 4.00 50 Caroga Lake Station 219 - T Caroga Distr - Unattended 23.00 5.00 51 Carthage Station 717 - V Carthage Distr - Unattended 23.00 5.00 52 Case Supply Station 142 - C Syracuse Distr - Unattended 13.00 0.00 53 Cassadaga Station 61 - V Cassadaga Distr - Unattended 34.00 5.00 54 Castleton Station 36 - T Schodack Distr - Unattended 34.00 5.00 55 Cattaraugus Station 15 - T New Albion Distr - Unattended 34.00 5.00 56 Cavanaugh Rd. Station 616 - T Marcy Distr - Unattended 115.00 13.00 57 Cazenovia Station 220 - V Cazenovia Distr - Unattended 34.00 5.00 58 Cedar Station 453 - T Queensbury Distr - Unattended 115.00 13.00 59 Center Street Station 379 - T Mohawk Distr - Unattended 115.00 13.00

Page 426-A Niagara Mohawk Power Corporation 6/01/2010 12/31/2009 SUBSTATIONS (Continued)

VOLTAGE (In MVa)

Line Name and Location of Substation Character of Substation No. Primary Secondary Tertiary

(a) (b) (c) (d) (e) 1 Central Square Station 15 - T Hastings Distr - Unattended 34.00 5.00 2 Chadwicks Station 668 - T New Hartford Distr - Unattended 115.00 14.00 3 Charley Lake Station 254 - T Wells Distr - Unattended 23.00 0.00 4 Chasm Falls Station 852 - T Malone Trans - Unattended 34.00 13.00 5 Chautaugua Station 57 - T Chautauqua Distr - Unattended 34.00 5.00 6 Chestertown Station 42 - T Chester Trans - Unattended 34.00 13.00 7 Chittenango Station 16 - V Chittenango Distr - Unattended 34.00 5.00 8 Chrisler Ave Station 257 - C Schenectady Distr - Unattended 34.00 4.00 9 Church Street Station 43 - Amsterdam Distr - Unattended 115.00 13.00 10 Clay Station 229 - T Clay Trans - Unattended 345.00 115.00 13.00 11 Cleveland Station 11 - V Cleveland Distr - Unattended 34.00 5.00 12 Clinton Rd Station 366 - T Canajoharie Distr - Unattended 115.00 13.00 13 Clinton Station 604 - V Clinton Distr - Unattended 46.00 13.00 14 Clover Bank Station 91 - Hamburg Distr - Unattended 115.00 13.00 15 Clymer Station 55 - T Clymer Distr - Unattended 34.00 5.00 16 Cobleskill Station 214 - V Cobleskill Distr - Unattended 69.00 5.00 17 Coffeen Street Station 760 - T Watertown Trans - Unattended 115.00 24.00 18 Coffeen Street Station 760 - T Watertown Trans - Unattended 115.00 14.00 19 Collins Station 83 - T Collins Distr - Unattended 34.00 5.00 20 Collinsville Station 716 - T West Turin Distr - Unattended 23.00 5.00 21 Colosse Station 321 - T Mexico Distr - Unattended 34.00 13.00 22 Colvin Avenue Station 313 - Albany Distr - Unattended 34.00 4.00 23 Commerce Ave Station 235 - C Albany Distr - Unattended 34.00 13.00 24 Comstock Station 48 - T Fort Ann Distr - Unattended 115.00 5.00 25 Conesus Lake Station 52 - T Conesus Distr - Unattended 34.00 5.00 26 Conkling Station 652 - C Utica Distr - Unattended 46.00 4.00 27 Constantia Station 19 - T Constantia Distr - Unattended 34.00 2.00 28 Corfu Station 22 - V Corfu Distr - Unattended 34.00 5.00 29 Corinth Station 285 - V Corinth Distr - Unattended 34.00 13.00 30 Corliss Park Station 338 - C Troy Distr - Unattended 34.00 4.00 31 Corning Station 970 Distr - Unattended 115.00 13.00 32 Cortland Line Station 277 - T Cortlandville Distr - Unattended 34.00 5.00 33 Cortland Station 502 -T Cortlandville Distr - Unattended 115.00 34.00 34 Cortland Station 502 -T Cortlandville Distr - Unattended 34.00 5.00 35 Court Street Substation Salina Distr - Unattended 34.00 4.00 37 Crouse Hinds Station 239 Morgan Road Distr - Unattended 34.00 13.00 38 Crown Point Station 249 Distr - Unattended 115.00 13.00 39 Cuba Lake Station 37 Distr - Unattended 34.00 4.00 40 Cuba Station 05 Distr - Unattended 34.00 4.00 41 Curry Road Station - T Rotterdam Distr - Unattended 115.00 14.00 42 Curry Road Station - T Rotterdam Distr - Unattended 115.00 13.00 43 Curtis Street - T Granby Trans - Unattended 115.00 34.00 44 Cuyler Station 24 - T Cuyler Distr - Unattended 34.00 4.00 45 Darien Station 16 - T Darien Distr - Unattended 34.00 5.00 46 David Station 979 - C Odgensburg Distr - Unattended 23.00 5.00 47 Debalso Station 684 - T New Hartford Distr - Unattended 115.00 14.00 48 Deerfield - T Deerfield Trans - Unattended 115.00 46.00 49 Deerfield - T Deerfield Trans - Unattended 115.00 14.00 50 Dekalb Station 984 - T Dekalb Distr - Unattended 115.00 14.00 51 Delameter No. 93 - T Evans Distr - Unattended 115.00 14.00 52 Delanson Station 269 - T Duanesburg Distr - Unattended 69.00 14.00 53 Delaware Ave Station 330 - C Albany Distr - Unattended 34.00 4.00 54 Delaware Ave Station 330 Dist - Unattended 34.00 14.00 55 Delevan Station 11 Distr - Unattended 34.00 4.00 56 Delmar Station 279 - T Bethlehem Distr - Unattended 34.00 5.00 57 Delphi Station 262 - T Cazenovia Distr - Unattended 115.00 14.00 58 Depot Rd Station 425 - T Guilderland Distr - Unattended 34.00 13.00 59 Dewitt Station 241 - T Dewitt Trans - Unattended 345.00 115.00 13.00

Page 426-B Niagara Mohawk Power Corporation 6/01/2010 12/31/2009 SUBSTATIONS (Continued)

VOLTAGE (In MVa)

Line Name and Location of Substation Character of Substation No. Primary Secondary Tertiary

(a) (b) (c) (d) (e) 1 Dexter Station 726 - T Hounsfield Distr - Unattended 23.00 5.00 2 Dorwin Station 26 - T Onondaga Distr - Unattended 34.00 4.00 3 Dugan Road Station 22 - T Olean Distr - Unattended 115.00 13.00 4 Duguid Station 265 Distr - Unattended 115.00 14.00 5 Dunkirk Station - C Dunkirk Trans - Attended 115.00 34.00 6 Dunkirk Station - C Dunkirk Trans - Attended 230.00 115.00 13.00 7 E.J. West Station 38 - T Hadley Trans - Unattended 115.00 14.00 8 Eagle Bay Station 382 - T Inlet Distr - Unattended 46.00 5.00 9 Eagle Harbor Station 92 - T Albion Distr - Unattended 34.00 5.00 10 East Batavia No. 28 - T Batavia Distr - Unattended 115.00 13.00 11 East Dunkirk Station 63 - C Dunkirk Distr - Unattended 115.00 14.00 12 East Fulton Station 100 - T Volney Distr - Unattended 34.00 5.00 13 East Golah Station 51 - T Rush Distr - Unattended 115.00 14.00 14 East Molloy Road Station 151 - T Dewitt Distr - Unattended 115.00 13.00 15 East Norfolk Station 913 - T Norfolk Trans - Unattended 23.00 5.00 16 East Oswegatchie Station 982 - T Gouverneur Trans - Unattended 115.00 23.00 17 East Otto Station 28 - T East Otto Distr - Unattended 34.00 5.00 18 East Pulaski Station 324 - T Richland Distr - Unattended 115.00 13.00 19 East Schodack Station 501 - T Schodack Distr - Unattended 34.00 5.00 20 East Springfield Station 477 - T Springfield Distr - Unattended 115.00 14.00 21 East Syracuse Station 27 - V East Syracuse Distr - Unattended 34.00 4.00 22 East Watertown Station 817 - T Watertown Distr - Unattended 115.00 13.00 23 East Worcester Station 430 - T Worcester Distr - Unattended 34.00 13.00 5.00 24 Eden Center Station 88 - T Eden Distr - Unattended 34.00 5.00 25 Edic Station 662 - T Marcy Trans - Unattended 345.00 230.00 13.00 26 Edic Station 662 - T Marcy Trans - Unattended 345.00 115.00 13.00 27 Edwards Station 916 - T Edwards Distr - Unattended 34.00 5.00 28 Elba Station 20 - V Elba Distr - Unattended 34.00 5.00 29 Elbridge Station 312 - T Elbridge Trans - Unattended 345.00 115.00 13.00 30 Elbridge Station 312 - T Elbridge Trans - Unattended 115.00 34.00 31 Ellicott Station 65 - T EllicotElm Street Station - Distr - Unattended 34.00 5.00 32 Elm Street Station - C Buffalo Trans - Unattended 230.00 23.00 33 Elm Street Station 898 - T Malone Distr - Unattended 34.00 5.00 34 Elnora Station 344 - T Clifton Park Distr - Unattended 115.00 13.00 35 Elsmere Station 407 - T Bethlehem Distr - Unattended 34.00 5.00 37 Emmet Street Station 256 - C Schenectady Distr - Unattended 34.00 4.00 38 Ephratah Station 18 - T Ephratah Trans - Unattended 69.00 23.00 39 Ephratah Station 18 - T Ephratah Trans - Unattended 69.00 5.00 40 Euclid Station 267 - T Clay Distr - Unattended 115.00 13.00 41 Everett Road Station 420 - T Colonie Distr - Unattended 115.00 13.00 42 Fabius Station 55 - T Fabius Distr - Unattended 34.00 5.00 43 Fairdale Station 55 - T Hannibal Distr - Unattended 34.00 5.00 44 Falconer Station - V Falconer Trans - Unattended 115.00 5.00 45 Farmersville Station 27 - T Farmersville Distr - Unattended 34.00 5.00 46 Farnan Rd Station 476 - T Moreau Distr - Unattended 34.00 13.00 47 Fayette Street Station - C Syracuse Distr - Unattended 34.00 5.00 48 Fayetteville Station 18 - V Fayetteville Distr - Unattended 34.00 2.00 49 Fine Station 978 - T Fine Distr - Unattended 34.00 5.00 50 Findley Lake Station 71 - T Mina Distr - Unattended 34.00 5.00 51 Firehouse Road Station 449 - T Halfmoon Distr - Unattended 115.00 13.00 52 Fisher Ave Station 270 - T Cortlandville Distr - Unattended 34.00 13.00 53 Fly Road Station 261 - T Dewitt Distr - Unattended 115.00 13.00 54 Fort Covington Station 896 - T Fort Covington Trans - Unattended 34.00 13.00 55 Fort Gage Station 319, T Lake George Distr - Unattended 34.00 13.00 56 Fort Gage Station 319, T Lake George Distr - Unattended 34.00 5.00 57 Forts Ferry - T Colonie Distr - Unattended 115.00 13.00 58 Frankfort Station 677 - V Frankfort Distr - Unattended 46.00 4.00 59 Franklin Falls Station 843 - T Franklin Trans - Unattended 46.00 5.00

Page 426-C Niagara Mohawk Power Corporation 6/01/2010 12/31/2009 SUBSTATIONS (Continued)

VOLTAGE (In MVa)

Line Name and Location of Substation Character of Substation No. Primary Secondary Tertiary

(a) (b) (c) (d) (e) 1 Franklinville Station 24 - V Franklinville Distr - Unattended 34.00 5.00 2 French Creek Station 56 - T French Creek Distr - Unattended 34.00 13.00 3 Frewsburg Station 69 - T Carroll Distr - Unattended 34.00 5.00 4 Front Street Station - C Schenectady Distr - Unattended 115.00 13.00 5 Gabriels Station 835 - T Brighton Distr - Unattended 46.00 5.00 6 Galeville Station 213 - T Salina Distr - Unattended 34.00 4.00 7 Gardenville Station - T West Seneca Trans - Attended 69.00 2.00 8 Gardenville Station - T West Seneca Trans - Attended 230.00 115.00 13.00 9 Gasport Station 90 - T Royalton Distr - Unattended 34.00 5.00 10 Genesee Street Station 260 - C Albany Distr - Unattended 34.00 4.00 11 Geneseo Station 55 - T Geneseo Distr - Unattended 34.00 13.00 12 Gibson Station 106 - T Niagara Trans - Unattended 115.00 12.00 13 Gibson Station 106 - T Niagara Trans - Unattended 13.00 12.00 14 Gilbert Mills Station 247 - T Schroeppel Distr - Unattended 115.00 13.00 15 Gilmantown Road Station 154 - V Speculator Distr - Unattended 23.00 13.00 16 Gilpin Bay Station 956 - T Santa Clara Distr - Unattended 46.00 5.00 17 Glen Falls Hospital Station 14 - C Glens Falls Distr - Unattended 34.00 4.00 18 Glen Falls Hospital Station 14 - C Glens Falls Distr - Unattended 34.00 5.00 19 Glens Falls - C Glens Falls Trans - Unattended 34.00 4.00 20 Glenwood Station 227 - C Syracuse Distr - Unattended 35.00 4.00 21 Gloversville Station 72 - C Gloversville Distr - Unattended 69.00 4.00 22 Gloversville Station 72 - C Gloversville Distr - Unattended 69.00 13.00 23 Golah Station - T Rush Trans - Unattended 115.00 34.00 24 Golah Station - T Rush Trans - Unattended 69.00 34.00 25 Granby Center Station 293 - T Granby Distr - Unattended 34.00 13.00 26 Grand Street Station 433 - V Cobleskill Distr - Unattended 69.00 13.00 27 Greenbush Station 78 - Town of East Greenbush Trans - Unattended 115.00 34.00 13.00 28 Greenbush Station 78 - Town of East Greenbush Trans - Unattended 115.00 13.00 29 Greenhurst Station 60 - T Ellery Distr - Unattended 34.00 5.00 30 Grooms Road Station 345 - T Clifton Park Distr - Unattended 115.00 13.00 31 Groveland Station 41 - T Groveland Distr - Unattended 34.00 5.00 32 Guy Park Station 239 - C Amsterdam Distr - Unattended 13.00 4.00 33 Hague Road Station 418 - T Ticonderoga Distr - Unattended 115.00 13.00 34 Hammermill Station 280 - C Oswego Distr - Unattended 115.00 13.00 35 Hammond Station 370 - V Hammond Distr - Unattended 23.00 5.00 37 Hancock Station No. 137 - T Salina Distr - Unattended 34.00 4.00 38 Harper Station - C Niagara Falls Trans - Unattended 115.00 12.00 39 Harper Station - C Niagara Falls Trans - Unattended 12.00 5.00 40 Harper Station - C Niagara Falls Trans - Unattended 69.00 12.00 41 Harris Road Station 235 - T Onondaga Trans - Unattended 115.00 34.00 42 Harris Road Station 235 - T Onondaga Trans - Unattended 115.00 13.00 43 Hartfield Station 79 - T Chautauqua Trans - Unattended 115.00 13.00 44 Hartfield Station 79 - T Chautauqua Trans - Unattended 115.00 34.00 45 Headson Station - V East Syracuse Trans - Unattended 115.00 34.00 46 Hedley Park Place Station - C Troy Distr - Unattended 34.00 4.00 47 Hemlock Station 38 - T Livonia Distr - Unattended 34.00 13.00 48 Hemstreet Station 328 - T Schaghticoke Distr - Unattended 115.00 13.00 49 Henry Street Station 316 - C Glens Falls Distr - Unattended 34.00 4.00 50 Heuvelton Station 923 - V Heuvelton Trans - Unattended 23.00 5.00 51 Higley Station 473 - T Colton Trans - Unattended 115.00 13.00 52 Hill Street Station 311 - C Gloversville Distr - Unattended 69.00 4.00 53 Hinsdale Station 218 - T Camillus Distr - Unattended 34.00 4.00 54 Hoag Station 221 - T Nassau Distr - Unattended 34.00 5.00 55 Homer Hill Switching Station - C Olean Trans - Unattended 115.00 34.00 56 Homer Hill Switching Station - C Olean Trans - Unattended 34.00 2.00 57 Homer Station 129 - V Homer Distr - Unattended 34.00 5.00 58 Hoosick Station 314 - T Hoosick Trans - Unattended 115.00 34.00 13.00 59 Hopkins Road Station 253 - T Salina Distr - Unattended 115.00 13.00

Page 426-D Niagara Mohawk Power Corporation 6/01/2010 12/31/2009 SUBSTATIONS (Continued)

VOLTAGE (In MVa)

Line Name and Location of Substation Character of Substation No. Primary Secondary Tertiary

(a) (b) (c) (d) (e) 1 Hudson Falls Station 88 - T Fort Edward Distr - Unattended 34.00 13.00 4.00 2 Hudson Station 87 - T Greenport Trans - Unattended 115.00 34.00 3 Hudson Station 87 - T Greenport Trans - Unattended 115.00 13.00 4 Hudson Station 87 - T Greenport Trans - Unattended 115.00 14.00 5 Huntley Station - T Tonawanda Trans - Unattended 115.00 23.00 6 Indian Lake Station 310 - T Indian Lake Distr - Unattended 34.00 5.00 7 Indian River Station 323 - T Leray Distr - Unattended 115.00 13.00 8 Indian River Station 323 - T Leray Distr - Unattended 115.00 23.00 9 Industry Station 47 - T Rush Distr - Unattended 34.00 5.00 10 Inghams Station 20 - T Manheim Trans - Unattended 115.00 115.00 115.00 11 Inghams Station 20 - T Manheim Trans - Unattended 115.00 13.00 12 Inghams Station 20 - T Manheim Trans - Unattended 115.00 46.00 13 Inman Road Station 370 - T Niskayuna Distr - Unattended 115.00 13.00 14 Jewett Road Station 281 - T Skaneateles Distr - Unattended 34.00 13.00 15 Johnson Road Station 352 - T Colonie Distr - Unattended 115.00 13.00 16 Johnstown Station 61 - C Johnstown Distr - Unattended 69.00 4.00 17 Juniper Station 500 - T Bethlehem Distr - Unattended 34.00 13.00 18 Karner Station 317 - V Colonie Distr - Unattended 34.00 4.00 19 Kenmore Terminal Station 158 - T Tonawanda Distr - Unattended 115.00 23.00 20 Kensington Terminal Station - C Buffalo Trans - Unattended 115.00 23.00 21 Knapp Road Station 226 - T Newstead Distr - Unattended 115.00 13.00 22 Knights Creek Station 06 - T Scio Distr - Unattended 34.00 5.00 23 Labrador Station 230 - T Truxton Trans - Unattended 115.00 34.00 24 Labrador Station 230 - T Truxton Trans - Unattended 34.00 13.00 25 Lake Colby Station 927 - T St. Armand Trans - Unattended 115.00 46.00 26 Lake Colby Station 927 - T St. Armand Trans - Unattended 115.00 13.00 27 Lake Colby Station 927 - T St. Armand 115.00 15.00 28 Lakeville Station 40 - T Livonia Distr - Unattended 34.00 5.00 29 Langford Station 180 - T North Collins Distr - Unattended 34.00 13.00 30 Lansingburg Station 93 - C Troy Distr - Unattended 34.00 13.00 31 Lansingburg Station 93 - C Troy Distr - Unattended 13.00 4.00 5.00 32 Lapp Station 26 - V Leroy Distr - Unattended 115.00 4.00 33 Latham Station 282 - T Colonie Distr - Unattended 34.00 13.00 34 Lawrence Ave Station - V Potsdam Distr - Unattended 115.00 13.00 35 Leeds Station 377 - T Athens Trans - Unattended 345.00 13.00 37 Lehigh Station 669 - V Camden Distr - Unattended 115.00 13.00 38 Lenox Station 513 - C Oneida Distr - Unattended 13.00 4.00 39 Leray Station 813 - V Black River Distr - Unattended 23.00 5.00 40 Levant Station 98 - T Poland Distr - Unattended 34.00 5.00 41 Levitt Station 665 - C Rome Distr - Unattended 115.00 5.00 42 Liberty Street Station - C Troy Distr - Unattended 35.00 13.00 43 Liberty Street Station - C Troy Distr - Unattended 35.00 4.00 44 Lighthouse Hill Station 61 - T Orwell Trans - Unattended 115.00 34.00 45 Lima Station 36 - V Lima Distr - Unattended 34.00 5.00 46 Linden Station 21 - T Bethany Distr - Unattended 34.00 5.00 47 Lisbon Station 963 - T Lisbon Distr - Unattended 23.00 5.00 48 Little River Station 955 - T Canton Distr - Unattended 23.00 5.00 49 Little River Station 955 - T Canton Distr - Unattended 115.00 23.00 50 Little River Station 955 - T Canton Distr - Unattended 115.00 13.00 51 Livingston Correctional Station 130 - T Groveland Distr - Unattended 34.00 13.00 52 Livonia Station 37 - V Livonia Distr - Unattended 34.00 5.00 53 Lockport Station - C Lockport Trans - Unattended 115.00 12.00 54 Loon Lake Station 837 - T Franklin Distr - Unattended 46.00 5.00 55 Lords Hill Station 150 - T Onondaga Distr - Unattended 34.00 5.00 56 Lorings Station 276 - T Cortlandville Distr - Unattended 34.00 13.00 57 Lowville Station 773 - T Lowville Trans - Unattended 115.00 23.00 58 Lowville Station 773 - T Lowville Trans - Unattended 115.00 13.00 59 Lyme Station 733 - T Lyme Distr - Unattended 115.00 13.00

Page 426-E Niagara Mohawk Power Corporation 6/01/2010 12/31/2009 SUBSTATIONS (Continued)

VOLTAGE (In MVa)

Line Name and Location of Substation Character of Substation No. Primary Secondary Tertiary

(a) (b) (c) (d) (e) 1 Lyndonville Station 95 - V Lyndonville Distr - Unattended 34.00 5.00 2 Lynn Street Station 320 - T Rotterdam Distr - Unattended 34.00 4.00 3 Lynn Street Station 320 - T Rotterdam Distr - Unattended 34.00 13.00 4 Lysander Station 297 - T Lysander Distr - Unattended 115.00 13.00 5 Machias Station 13 - T Machias Trans - Unattended 115.00 34.00 6 Machias Station 13 - T Machias Trans - Unattended 34.00 5.00 7 Madison Station 654 - C Rome Distr - Unattended 115.00 5.00 8 Mallory Road Station 40 - T Hastings Trans - Unattended 115.00 34.00 9 Malone Station 895 - T Malone Trans - Unattended 115.00 34.00 10 Malone Station 895 - T Malone Trans - Unattended 115.00 13.00 11 Malta Station 443 - T Malta Distr - Unattended 115.00 13.00 12 Maplehurst Station 04 - T Hinsdale Distr - Unattended 34.00 5.00 13 Maplewood Station 307 - T Colonie Trans - Unattended 115.00 13.00 14 Maplewood Station 307 - T Colonie Trans - Unattended 115.00 34.00 13.00 15 Market Hill Station 324 - T Amsterdam Distr - Unattended 69.00 4.00 16 Marshville Station 299 - T Canajoharie Trans - Unattended 115.00 69.00 13.00 17 Marshville Station 299 - T Canajoharie Trans - Unattended 115.00 69.00 23.00 18 Mayfield Station 356 - V Mayfield Distr - Unattended 69.00 13.00 19 McAdoo Station 914- T Canton Distr - Unattended 115.00 13.00 20 McBride Street Station 123 - C Syracuse Distr - Unattended 34.00 4.00 21 McClellan Street Station 304 - C Schenectady Distr - Unattended 34.00 13.00 22 McCrea Street Station 272 - V Fort Edward Distr - Unattended 34.00 5.00 23 McGraw Station 228 - V McGraw Distr - Unattended 34.00 5.00 24 McIntyre Station 969 - T Oswegatchie Trans - Unattended 115.00 23.00 25 McKownville - T Guilderland Distr - Unattended 115.00 13.00 26 Meco Station 318 - T Johnstown Trans - Unattended 115.00 69.00 5.00 27 Menands Station 101 - V Menands Trans - Unattended 115.00 13.00 28 Menands Station 101 - V Menands Trans - Unattended 115.00 34.00 9.00 29 Menands Station 101 - V Menands Trans - Unattended 115.00 4.00 30 Menands Station 101 - V Menands Trans - Unattended 13.00 4.00 31 Merrillsville Station 838 - T Franklin Distr - Unattended 46.00 2.00 32 Messina Station 42 - T Dewitt Distr - Unattended 34.00 4.00 33 Mexico Station 43 - V Mexico Distr - Unattended 34.00 5.00 34 Middleburg Station 390 - V Middleburgh Distr - Unattended 69.00 13.00 35 Middleport Station 77 - V Middleport Distr - Unattended 34.00 5.00 37 Middleville Station 666 - V Middleville Distr - Unattended 46.00 4.00 38 Midler Station 145 - T Dewitt Distr - Unattended 34.00 4.00 39 Mill Street Station 748 - C Watertown Trans - Unattended 23.00 5.00 40 Miller Street Station 117 - C Cortland Distr - Unattended 34.00 5.00 41 Milton Avenue Station 266 - T Camillus Distr - Unattended 115.00 13.00 42 Mine Road Station 777 - T Edwards Trans - Unattended 34.00 23.00 43 Minoa Station 44 - V Minoa Distr - Unattended 34.00 5.00 44 Mohican Station 247 - T Moreau Trans - Unattended 115.00 34.00 5.00 45 Mohican Station 247 - T Moreau Trans - Unattended 115.00 34.00 13.00 46 Moira Station 859 - T Moira Distr - Unattended 34.00 5.00 47 Monarch Machine Tool Station - T Cortlandville Distr - Unattended 34.00 2.00 48 Morristown Station 933 - V Morristown Distr - Unattended 23.00 5.00 49 Mortimer Station - T Brighton Trans - Unattended 115.00 69.00 12.00 50 Mountain Station - T Lewiston Trans - Unattended 115.00 34.00 51 Mumford Station 50 - T Wheatfield Distr - Unattended 115.00 13.00 52 Nassau Station 113 - V Nassau Distr - Unattended 34.00 5.00 53 Nestle Company Station 245 - C Fulton Distr - Unattended 115.00 2.00 54 New Haven Station 256 - T New Haven Distr - Unattended 115.00 13.00 55 New Scotland Station 325 - T New Scotland Trans - Unattended 345.00 120.00 56 Newark Street Station 300 - C Cohoes Distr - Unattended 34.00 13.00 57 Newton Falls Station 774 - T Clifton Distr - Unattended 34.00 2.00 58 Newtonville Station 305 - T Colonie Distr - Unattended 34.00 13.00 59 Newtonville Station 305 - T Colonie Distr - Unattended 34.00 4.00

Page 426-F Niagara Mohawk Power Corporation 6/01/2010 12/31/2009 SUBSTATIONS (Continued)

VOLTAGE (In MVa)

Line Name and Location of Substation Character of Substation No. Primary Secondary Tertiary

(a) (b) (c) (d) (e) 1 Nicholville Station 860 - T Lawrence Trans - Unattended 115.00 34.00 2 Nicholville Station 860 - T Lawrence Trans - Unattended 34.00 5.00 3 Nile Station - T Friendship Trans - Unattended 115.00 34.00 4 Niles Station 294 - T Skaneateles Distr - Unattended 34.00 13.00 5 Norfolk Station 934 - T Norfolk Trans - Unattended 115.00 23.00 6 North Akron Station - T Newstead Trans - Unattended 115.00 34.00 7 North Angola Station - V Angola Trans - Unattended 115.00 34.00 8 North Ashford Station 36 - T Ashford Trans - Unattended 34.00 5.00 9 North Bangor Station 864 - T Bangor Distr - Unattended 34.00 5.00 10 North Bombay Station 866 - T Bombay Distr - Unattended 34.00 13.00 11 North Carthage Station 816 - T Wilna Distr - Unattended 115.00 23.00 12 North Carthage Station 816 - T Wilna Distr - Unattended 115.00 13.00 13 North Chautauqua Station - T Chautauqua Distr - Unattended 34.00 5.00 14 North Collins Station 92 - T Brant Distr - Unattended 34.00 5.00 15 North Creek Station 122 - T Johnsburg Distr - Unattended 115.00 13.00 30.00 16 North Creek Station 122 - T Johnsburg Distr - Unattended 115.00 34.00 13.00 17 North Eden Station 82 - T Eden Distr - Unattended 34.00 13.00 18 North Gouverneur Station 983 - T Gouverneur Distr - Unattended 115.00 13.00 19 North Lakeville Station - T Geneseo Trans - Unattended 115.00 34.00 20 North Lawrence Station 861 - T Lawrence Distr - Unattended 34.00 5.00 21 North LeRoy Station - V Leroy Trans - Unattended 115.00 34.00 22 North LeRoy Station - V Leroy Trans - Unattended 115.00 13.00 23 North Olean Station 30 - C Olean Distr - Unattended 34.00 5.00 24 North Troy Station 123 - T Brunswick Trans - Unattended 115.00 34.00 13.00 25 North Troy Station 123 - T Brunswick Trans - Unattended 115.00 34.00 5.00 26 Northville Station 332 - T Northhampton Distr - Unattended 69.00 13.00 27 Northville Station 332 - T Northhampton Distr - Unattended 69.00 23.00 28 Norwood Station 928 - V Norwood Trans - Unattended 23.00 5.00 29 Oak Hill Station 62 - T Ellicott Distr - Unattended 34.00 5.00 30 Oakfield Station 03 - V Oakfield Trans - Unattended 34.00 5.00 31 Oakfield Station 03 - V Oakfield Trans - Unattended 115.00 34.00 32 Oakwood Ave Station - T Pendleton Distr - Unattended 115.00 13.00 33 Oathout Station 402 - T Colonie Distr - Unattended 34.00 13.00 34 Ogden Brook - T Queensbury Distr - Unattended 115.00 13.00 35 Ogdensburg Station 938 - C Ogdensburg Trans - Unattended 115.00 13.00 37 Old Forge Station 383 - T Webb Distr - Unattended 46.00 5.00 38 Oneida Station 501 - T Vernon Trans - Unattended 115.00 13.00 39 Orangeville Station 19 - T Orangeville Distr - Unattended 34.00 5.00 40 Oriskany Station 648 - V Oriskany Distr - Unattended 46.00 4.00 41 Otten Station 412 - T Dresden Distr - Unattended 115.00 5.00 42 Packard - C Niagara Falls Trans - Unattended 230.00 115.00 13.00 43 Paloma Station 254 - C Oswego Distr - Unattended 115.00 13.00 44 Panama Station 70 - T Harmony Distr - Unattended 34.00 5.00 45 Parish Station 49 - V Parish Distr - Unattended 34.00 5.00 46 Parishville Station 939 - T Parishville Trans - Unattended 5.00 2.00 47 Park Street Station 144 - C Syracuse Distr - Unattended 34.00 4.00 48 Partridge Street Station 128 - C Albany Distr - Unattended 34.00 4.00 49 Patroon Station 323 - C Albany Trans - Unattended 115.00 34.00 50 Patroon Station 323 - C Albany Trans - Unattended 115.00 13.00 51 Paul Smiths Station 384 - T Brighton Distr - Unattended 46.00 5.00 52 Peat Street Station - C Syracuse Distr - Unattended 115.00 13.00 53 Pebble Hill Station 290 - T Dewitt Trans - Unattended 115.00 34.00 54 Pebble Hill Station 290 - T Dewitt Trans - Unattended 115.00 13.00 55 Perryville Station 50 - T Sullivan Distr - Unattended 34.00 4.00 56 Peterboro Station 514 - V Canastota Distr - Unattended 115.00 13.00 57 Petrolia Station 19 - T Scio Distr - Unattended 34.00 5.00 58 Phoenix Station 51 - V Phoenix Distr - Unattended 34.00 5.00 59 Piercefield Station 502 - T Piercefield Trans - Unattended 46.00 5.00

Page 426-G Niagara Mohawk Power Corporation 6/01/2010 12/31/2009 SUBSTATIONS (Continued)

VOLTAGE (In MVa)

Line Name and Location of Substation Character of Substation No. Primary Secondary Tertiary

(a) (b) (c) (d) (e) 1 Pine Bush - T Guilderland Distr - Unattended 115.00 13.00 2 Pine Grove Station 59 - T Cicero Distr - Unattended 115.00 13.00 3 Pleasant Station 664 - C Utica Distr - Unattended 46.00 4.00 4 Poland Station 621 - V Poland Distr - Unattended 46.00 13.00 5 Poland Station 621 - V Poland Distr - Unattended 34.00 5.00 6 Pompey Station 120 - T Pompey Distr - Unattended 34.00 4.00 7 Port Henry Station 385 - T Moriah Distr - Unattended 115.00 13.00 8 Port Leyden Station 755 - T Leyden Distr - Unattended 23.00 5.00 9 Portage Street Station 754 - C Watertown Distr - Unattended 23.00 5.00 10 Porter Station 657- T Marcy Trans - Unattended 230.00 115.00 13.00 11 Pottersville Station 424 - T Chester Distr - Unattended 34.00 13.00 12 Prices Corners Station 14 - T Randolph Distr - Unattended 34.00 13.00 13 Prospect Hill Station 413 - T Waterford Distr - Unattended 115.00 13.00 14 Pulaski Station 68 - V Pulaski Distr - Unattended 34.00 5.00 15 Queensbury Station 295 - T Queensbury Trans - Unattended 115.00 34.00 5.00 16 Queensbury Station 295 - T Queensbury Trans - Unattended 113.00 13.00 17 Raquette Lake Station 398 - T Long Lake Distr - Unattended 46.00 5.00 18 Raybrook Station 839 - T North Elba Distr - Unattended 115.00 13.00 19 Renaissance Drive Station 229 - T Amherst Distr - Unattended 115.00 13.00 20 Rensselaer Station - T Rensselaer Trans - Unattended 34.00 13.00 21 Reservoir Station 102 - T Cold Springs Distr - Unattended 34.00 13.00 22 Reynolds Road Station 334 - T Greenbush Trans - Unattended 115.00 13.00 23 Reynolds Road Station 334 - T Greenbush Trans - Unattended 345.00 115.00 13.00 24 Richmond Station 32 - T Richmond Distr - Unattended 34.00 13.00 25 Ridge Road Station 219 - T Cazenovia Distr - Unattended 34.00 5.00 26 Ridge Station 142 - T Lackawanna Trans - Unattended 115.00 34.00 27 Ripley Station 53 - T Ripley Distr - Unattended 34.00 5.00 28 Riverside Station 288 - C Albany Distr - Unattended 115.00 34.00 13.00 29 Riverside Station 288 - C Albany Distr - Unattended 115.00 13.00 30 Riverview Station 847 - T Blackbrook Distr - Unattended 46.00 5.00 31 Roberts Road Station 154 - C Dunkird Distr - Unattended 115.00 13.00 32 Rock City Falls Station 404 - T Milton Distr - Unattended 34.00 5.00 33 Rock City Station 623 - C Little Falls Distr - Unattended 46.00 4.00 34 Rock Cut Station 286 - C Syracuse Distr - Unattended 115.00 13.00 35 Rome Station 762 - C Rome (Inside) Trans - Attended 115.00 13.00 37 Rosa Road Station 137 - T Niskayuna Trans - Unattended 115.00 34.00 5.00 38 Rosa Road Station 137 - T Niskayuna Trans - Unattended 115.00 13.00 39 Rotterdam Station 138 - T Rotterdam Trans - Unattended 115.00 13.00 40 Rotterdam Station 138 - T Rotterdam Trans - Unattended 115.00 34.00 13.00 41 Rotterdam Station 138 - T Rotterdam Trans - Unattended 115.00 69.00 13.00 42 Rotterdam Station 138 - T Rotterdam Trans - Unattended 115.00 34.00 43 Rotterdam Station 138 - T Rotterdam Trans - Unattended 230.00 115.00 13.00 44 Royalton Station 98 - T Royalton Distr - Unattended 34.00 5.00 45 Ruth Road Station 381 - T Colonie Distr - Unattended 115.00 13.00 46 St Johnsville Station 335 - V St Johnsville Distr - Unattended 115.00 13.00 5.00 47 St Peters Hospital 411 - C Albany Distr - Unattended 34.00 4.00 48 St Regis Station 977 - T Bombay Distr - Unattended 34.00 5.00 49 Salisbury Station 678 - T Manheim Distr - Unattended 115.00 13.00 50 Sanborn Station - T Lewiston Trans - Unattended 115.00 34.00 51 Sand Creek Station 452 - V Colonie Distr - Unattended 115.00 13.00 52 Sand Road Station 131 - T Salina Distr - Unattended 34.00 4.00 53 Sandy Creek Station 66 - V Sandy Creek Distr - Unattended 34.00 13.00 54 Saratoga Station 142 - C Saratoga (inside) Distr - Unattended 34.00 4.00 55 Saratoga Station 142 - C Saratoga (inside) Distr - Unattended 34.00 13.00 56 Sawyer Avenue Station - T Tonawanda Trans - Unattended 230.00 23.00 57 Sawyer Avenue Station - T Tonawanda Trans - Unattended 23.00 13.00 58 Schenevus Station 261 - V Schenevus Distr - Unattended 23.00 5.00 59 Schodack Station 451 - T Schodack Distr - Unattended 115.00 13.00

Page 426-H Niagara Mohawk Power Corporation 6/01/2010 12/31/2009 SUBSTATIONS (Continued)

VOLTAGE (In MVa)

Line Name and Location of Substation Character of Substation No. Primary Secondary Tertiary

(a) (b) (c) (d) (e) 1 Schoharie Station 234 - T Schoharie Trans - Unattended 69.00 13.00 2 Schroon Lake Station 429 - T Schroon Distr - Unattended 34.00 13.00 3 Schuyler Station 663 - T Frankfort Trans - Unattended 115.00 46.00 4 Schuyler Station 663 - T Frankfort Trans - Unattended 115.00 13.00 5 Schuylerville Station 39 - V Schuylerville Trans - Unattended 34.00 5.00 6 Schofield Road Station 450 - T Lake Luzerne Distr - Unattended 115.00 13.00 7 Scotia Station 255 - V Scotia Distr - Unattended 34.00 4.00 8 Sealright Station 273 - C Fulton Distr - Unattended 115.00 3.00 9 Selkirk Station 149 - T Bethlehem Distr - Unattended 34.00 13.00 10 Seminole Station 339 - C Albany Distr - Unattended 34.00 4.00 11 Seneca Terminal Station - C Buffalo Distr - Unattended 115.00 23.00 12 Sentinel Heights Station 128 - T Onondaga Distr - Unattended 34.00 4.00 13 Seventh Avenue Station 244 - C Troy Distr - Unattended 34.00 4.00 14 Seventh North Street Station 231 - T Clay Distr - Unattended 34.00 5.00 15 Sewalls Island Station 766 - C Watertown Trans - Unattended 23.00 5.00 16 Shaleton Station 81 - T Hamburg Trans - Unattended 115.00 34.00 17 Shaleton Station 81 - T Hamburg Trans - Unattended 34.00 5.00 18 Sharon Station 363 - T Sharon Distr - Unattended 69.00 13.00 19 Shelby Station 76 - T Shelby Distr - Unattended 115.00 13.00 20 Sheppard Road Station 29 - T Pavilion Distr - Unattended 34.00 13.00 21 Sherman Station 333 - V Sherman Distr - Unattended 46.00 13.00 22 Sherman Station 54 - V Sherman Distr - Unattended 34.00 5.00 23 Shore Road Station 281 - T Ballston Distr - Unattended 34.00 5.00 24 Silver Lake Station 845 - T Blackbrook Distr - Unattended 46.00 2.00 25 Sinclairville Station 72 - V Sinclairville Distr - Unattended 34.00 5.00 26 Smith Bridge Station 464 - T Wilton Distr - Unattended 115.00 13.00 27 Solvay Station 57 - T Solvay Trans - Attended 115.00 34.00 28 Solvay Station 57 - T Solvay Trans - Attended 115.00 34.00 12.00 29 Sorrell Hill Station 269 - T Baldwinsville Distr - Unattended 115.00 12.00 30 South Philadelphia Station 764 - T Philadelphia Distr - Unattended 23.00 5.00 31 South Randolph Station 32 - T Randolph Distr - Unattended 34.00 5.00 32 South Street Station 297 - C Saratoga Springs Distr - Unattended 34.00 13.00 33 S Washington Street Station 614 - V Herkimer Distr - Unattended 46.00 13.00 34 South Wellsville Station 23 - T Wellsville Distr - Unattended 34.00 5.00 35 Southland Station 84 - T Somerset Distr - Unattended 34.00 5.00 37 Southwood Station 244 - T Dewitt Distr - Unattended 115.00 13.00 38 Spier Falls Station 34 - T Moreau Trans - Unattended 115.00 34.00 5.00 39 Springfield Station 167 - T Dewitt Distr - Unattended 34.00 4.00 40 Star Lake Station 727 - T Clifton Distr - Unattended 34.00 5.00 41 Starr Road Station 334 - T Cortlandville Distr - Unattended 115.00 13.00 42 State Street Station 954 - T Canton Distr - Unattended 23.00 5.00 43 Station 012 - C Buffalo Distr - Unattended 23.00 2.00 44 Station 014 - C Buffalo Distr - Unattended 23.00 2.00 45 Station 021 - T Amherst Distr - Unattended 23.00 4.00 46 Station 022 - C Buffalo Distr - Unattended 23.00 4.00 47 Station 023 - C Buffalo Distr - Unattended 23.00 4.00 48 Station 024 - C Buffalo Distr - Unattended 23.00 4.00 49 Station 025 - C Buffalo Distr - Unattended 23.00 4.00 50 Station 026 - C Buffalo Distr - Unattended 23.00 4.00 51 Station 027 - C Buffalo Distr - Unattended 23.00 4.00 52 Station 028 - C Buffalo Distr - Unattended 23.00 4.00 53 Station 029 - C Buffalo Distr - Unattended 23.00 4.00 54 Station 030 - C Buffalo Distr - Unattended 23.00 4.00 55 Station 031 - C Buffalo Distr - Unattended 23.00 4.00 56 Station 032 - C Buffalo Distr - Unattended 23.00 4.00 57 Station 033 - C Buffalo Distr - Unattended 23.00 4.00 58 Station 034 - C Buffalo Distr - Unattended 23.00 4.00 59 Station 035 - C Buffalo Distr - Unattended 23.00 4.00

Page 426-I Niagara Mohawk Power Corporation 6/01/2010 12/31/2009 SUBSTATIONS (Continued)

VOLTAGE (In MVa)

Line Name and Location of Substation Character of Substation No. Primary Secondary Tertiary

(a) (b) (c) (d) (e) 1 Station 036 - C Buffalo Distr - Unattended 23.00 4.00 2 Station 037 - C Buffalo Distr - Unattended 23.00 4.00 3 Station 038 - C Buffalo Distr - Unattended 23.00 4.00 4 Station 039 - C Buffalo Distr - Unattended 23.00 4.00 5 Station 040 - C Buffalo Distr - Unattended 23.00 4.00 6 Station 041 - C Buffalo Distr - Unattended 23.00 4.00 7 Station 042 - C Buffalo Distr - Unattended 23.00 4.00 8 Station 043 - C Buffalo Distr - Unattended 23.00 4.00 9 Station 044 - C Buffalo Distr - Unattended 23.00 4.00 10 Station 045 - C Buffalo Distr - Unattended 23.00 4.00 11 Station 046 - C Buffalo Distr - Unattended 23.00 4.00 12 Station 047 - C Buffalo Distr - Unattended 23.00 4.00 13 Station 048 - C Buffalo Distr - Unattended 23.00 4.00 14 Station 049 - C Buffalo Distr - Unattended 23.00 4.00 15 Station 050 - C Buffalo Distr - Unattended 23.00 4.00 16 Station 051 - C Buffalo Distr - Unattended 23.00 4.00 17 Station 052 - C Buffalo Distr - Unattended 23.00 4.00 18 Station 053 - C Buffalo Distr - Unattended 23.00 4.00 19 Station 054 - T Amherst Distr - Unattended 115.00 4.00 20 Station 055 - T Lackawanna Distr - Unattended 115.00 4.00 21 Station 056 - T Tonawanda Distr - Unattended 23.00 4.00 22 Station 057 - T Tonawanda Distr - Unattended 23.00 4.00 23 Station 058 - T Amherst Distr - Unattended 34.00 4.00 24 Station 059 - C Buffalo Distr - Unattended 23.00 4.00 25 Station 060 - C Buffalo Distr - Unattended 115.00 13.00 26 Station 061 - T Cheektowaga Distr - Unattended 115.00 4.00 27 Station 063 - T Tonawanda Distr - Unattended 23.00 4.00 28 Station 064 - T Grand Island Distr - Unattended 115.00 13.00 29 Station 066 - T Cheektowaga Distr - Unattended 34.00 5.00 30 Station 067 - T Amherst Distr - Unattended 34.00 4.00 31 Station 068 - C Buffalo Distr - Unattended 23.00 4.00 32 Station 071 - C North Tonawanda Distr - Unattended 34.00 5.00 33 Station 074 - C Tonawanda Distr - Unattended 23.00 4.00 34 Station 076 - C Tonawanda Distr - Unattended 115.00 13.00 35 Station 077 - C Tonawanda Distr - Unattended 23.00 4.00 37 Station 078 - C North Tonawanda Distr - Unattended 115.00 23.00 38 Station 079 - C North Tonawanda Distr - Unattended 23.00 4.00 39 Station 080 - C Niagara Falls Distr - Unattended 12.00 4.00 40 Station 081 - C Niagara Falls Distr - Unattended 12.00 4.00 41 Station 082 - C Niagara Falls Distr - Unattended 12.00 4.00 42 Station 083 - C Niagara Falls Distr - Unattended 12.00 4.00 43 Station 087 - V Lewiston Distr - Unattended 34.00 5.00 44 Station 121 - T West Seneca Distr - Unattended 34.00 5.00 45 Station 122 - C North Tonawanda Distr - Unattended 23.00 4.00 46 Station 124 - T Amherst Distr - Unattended 34.00 4.00 47 Station 126 - C Tonawanda Distr - Unattended 23.00 4.00 48 Station 127 - T Tonawanda Distr - Unattended 23.00 4.00 49 Station 129 - T Tonawanda Distr - Unattended 115.00 4.00 50 Station 130 - T Amherst Distr - Unattended 115.00 13.00 51 Station 132 - T Cheektowaga Distr - Unattended 34.00 5.00 52 Station 133 - T Tonawanda Distr - Unattended 115.00 4.00 53 Station 138 - T Pendleton Distr - Unattended 115.00 5.00 54 Station 139 - C Lackawanna Distr - Unattended 115.00 4.00 55 Station 140 - T Amherst Distr - Unattended 115.00 14.00 56 Station 146 - T Cheektowaga Distr - Unattended 34.00 13.00 57 Station 146 - T Cheektowaga Distr - Unattended 34.00 5.00 58 Station 149 - T Hamburg Distr - Unattended 34.00 4.00 59 Station 154 - T Cheektowaga Distr - Unattended 115.00 4.00

Page 426-J Niagara Mohawk Power Corporation 6/01/2010 12/31/2009 SUBSTATIONS (Continued)

VOLTAGE (In MVa)

Line Name and Location of Substation Character of Substation No. Primary Secondary Tertiary

(a) (b) (c) (d) (e) 1 Station 155 - C Buffalo Distr - Unattended 115.00 4.00 2 Station 157 - T Cheektowaga Distr - Unattended 23.00 4.00 3 Station 160 - C Buffalo Distr - Unattended 23.00 4.00 4 Station 162 - C Buffalo Distr - Unattended 23.00 4.00 5 Station 201 - C Buffalo Distr - Unattended 23.00 4.00 6 Station 202 - C Buffalo Distr - Unattended 23.00 4.00 7 Station 203 - C Buffalo Distr - Unattended 23.00 4.00 8 Station 205 - C Buffalo Distr - Unattended 23.00 13.00 9 Station 207 - T Amherst Distr - Unattended 34.00 13.00 10 Station 208 - Buffalo Distr - Unattended 23.00 4.00 11 Station 219 - T Amherst Distr - Unattended 115.00 13.00 12 Steamburg Station 17 - T Cold Spring Distr - Unattended 34.00 5.00 13 Stiles Station 58 - T Van Buren Distr - Unattended 34.00 5.00 14 Stittville Station 670 - T Marcy Distr - Unattended 115.00 13.00 15 Stoner Station 358 - T Johnstown Distr - Unattended 115.00 13.00 16 Stow Station 52 - T North Harmony Distr - Unattended 34.00 5.00 17 Stuyvesant Station 977 - T Stuyvesant Trans - Unattended 34.00 13.00 18 Summit Station - T Richmondville Distr - Unattended 69.00 23.00 19 Summit Station - T Richmondville Distr - Unattended 69.00 5.00 20 Sunday Creek Station 876 - T Webb Distr - Unattended 115.00 13.00 21 Swaggertown Station 364- T Glenville Distr - Unattended 115.00 13.00 22 Sweden Station - T Sweden Trans - Unattended 115.00 34.00 23 Sycaway Station 372 - T Brunswick Distr - Unattended 115.00 13.00 24 Taylorville Station 770 - T Croghan Trans - Unattended 115.00 23.00 25 Teall Avenue Station 72 - T Salina Trans - Unattended 115.00 13.00 26 Teall Avenue Station 72 - T Salina Trans - Unattended 115.00 34.00 27 Telegraph Road Station - T Royalton Trans - Unattended 115.00 34.00 28 Temple Station 243 - C Syracuse Distr - Unattended 115.00 13.00 29 Terminal Station "D" - C Buffalo Trans - Unattended 69.00 23.00 30 Terminal Station 651 - C Buffalo Distr - Unattended 115.00 13.00 31 Third Street Station 216 - C Fulton Distr - Unattended 34.00 5.00 32 Thousand Islands Station 814 - T Alexander Distr - Unattended 115.00 13.00 33 Tibbets Avenue Station 292 - C Troy Distr - Unattended 34.00 4.00 34 Tilden Station 73 - T Onondaga Trans - Unattended 115.00 34.00 35 Trinity Station 164 - C Albany Distr - Unattended 115.00 13.00 37 Trinity Station 164 - C Albany Distr - Unattended 13.00 4.00 38 Truxton Station 74 - T Truxton Distr - Unattended 34.00 5.00 39 Tuller Hill Station 246 - T Virgil Distr - Unattended 115.00 13.00 40 Tully Center Station 278 - T Tully Distr - Unattended 115.00 13.00 41 Tupper Lake Station 830 - V Tupper Lake Distr - Unattended 46.00 13.00 42 Turin Station 653 - T Lee Trans - Unattended 115.00 13.00 43 Union Falls Station 844 - T Blackbrook Trans - Unattended 46.00 2.00 44 Union Street Station 376 - Town of Cambridge Distr - Unattended 34.00 13.00 45 Unionville Station 276 - T New Scotland Distr - Unattended 34.00 13.00 46 University Station 81 - V Brockport Distr - Unattended 115.00 13.00 47 Vail Mills Station 392 - T Mayfield Distr - Unattended 115.00 69.00 48 Vail Mills Station 392 - T Mayfield Distr - Unattended 115.00 13.00 49 Valkin Station 427 - T Kinderhook Distr - Unattended 115.00 13.00 50 Valley Station 594 - V Herkimer Distr - Unattended 115.00 4.00 51 Valley Station 594 - V Herkimer Distr - Unattended 115.00 46.00 52 Valley Station - T Great Valley Distr - Unattended 115.00 13.00 53 Vandalia Station 104 - T Allegany Distr - Unattended 34.00 13.00 54 Veterans Hospital - C Albany Distr - Unattended 34.00 13.00 55 Voorhees Station 83 - V Camden Distr - Unattended 115.00 34.00 56 Voorheesville Station 178 - V Voorheesville Distr - Unattended 115.00 13.00 57 Walesville Station 331 - T Whitestown Distr - Unattended 115.00 13.00 58 Warrensburg Station 321 - T Warrensburg Distr - Unattended 115.00 13.00 59 Warrensburg Station 321 - T Warrensburg Distr - Unattended 115.00 34.00 13.00

Page 426-K Niagara Mohawk Power Corporation 6/01/2010 12/31/2009 SUBSTATIONS (Continued)

VOLTAGE (In MVa)

Line Name and Location of Substation Character of Substation No. Primary Secondary Tertiary

(a) (b) (c) (d) (e) 1 Waterport Station 73 - T Carlton Trans - Unattended 34.00 5.00 2 Watt Street Station 380 - T Rotterdam Distr - Unattended 34.00 13.00 3 Weaver Street Station - C Schenectady Distr - Unattended 34.00 13.00 4 Weibel Avenue Station 415 - C Saratoga Distr - Unattended 115.00 13.00 5 Wells Station 208 - T Wells Distr - Unattended 23.00 5.00 6 West Adams Station 875 - T Adams Distr - Unattended 115.00 13.00 7 West Albion Station 79 - T Albion Distr - Unattended 34.00 13.00 8 West Cleveland Station - T Constantia Distr - Unattended 34.00 13.00 9 West Hamlin Station 82 - T Hamlin Distr - Unattended 115.00 13.00 10 West Herkimer Station 676 - V Herkimer Distr - Unattended 46.00 13.00 11 West Monroe Station 274 - T West Monroe Distr - Unattended 34.00 13.00 12 West Olean Station 33 - C Olean Distr - Unattended 115.00 13.00 13 West Oswego Station 209 - C Oswego Distr - Unattended 34.00 5.00 14 West Oswego Station 209 - C Oswego Distr - Unattended 5.00 2.00 15 West Salamanca Station 16 - T Salamanca Trans - Unattended 34.00 5.00 16 West Valley Station 25 - T Ashford Distr - Unattended 34.00 5.00 17 Westvale Station 133 - T Geddes Distr - Unattended 34.00 4.00 18 Westville Station 885 - T Westville Distr - Unattended 34.00 5.00 19 Wethersfield Station 23 - T Wethersfield Distr - Unattended 34.00 5.00 20 Whittaker Station 296 - T Volney Distr - Unattended 115.00 13.00 21 White Lake Station 399 - T Forestport Distr - Unattended 46.00 5.00 22 Whitehall Station 187 - T Whitehall Trans - Unattended 115.00 13.00 23 Whitesboro Station 632 - V Yorksville Distr - Unattended 46.00 4.00 24 Whitesville Station 101 - T Independence Distr - Unattended 34.00 5.00 25 Whitman Station 671 - T Lincoln Trans - Unattended 115.00 34.00 26 Wilton Station 329 - T Wilton Distr - Unattended 34.00 13.00 27 Wine Creek Station 283 - C Oswego Distr - Unattended 115.00 13.00 28 Wolf Road Station - T Colonie Distr - Unattended 115.00 13.00 29 Woodard Station 233 - T Clay Trans - Unattended 115.00 34.00 30 Woodlawn Station 188 - T Colonie Trans - Unattended 115.00 34.00 13.00 31 Worcester Station 189 - T Worcester Distr - Unattended 23.00 13.00 5.00 32 Yahundasis Station 646 - T New Hartford Trans - Unattended 115.00 46.00 33 Yahundasis Station 646 - T New Hartford Trans - Unattended 115.00 13.00 34 York Center Station 53 - T York Distr - Unattended 69.00 13.00 35 Youngman Terminal Station - T Amherst Trans - Unattended 115.00 34.00 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59

Page 426-L Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 SUBSTATIONS (Continued)

5. Show in columns (i), (j), and (k) special equipment such of lessor, date and period of lease, and annual rent. For any as rotary converters, rectifiers, condensers, etc. and auxiliary substation or equipment operated other than by reason of sole equipment for increasing capacity. ownership or lease, give name of co-owner or other party, explain 6. Designate substations or major items of equipment leased basis of sharing expenses or other accounting between the from others, jointly owned with others, or operated otherwise parties, and state amounts and accounts affected in respon- than by reason of sole ownership by the respondent. For dent's books of account. Specify in each case whether lessor, any substation or equipment operated under lease, give name co-owner, or other party is an associated company.

CONVERSION APPARATUS AND Capacity of Number of Number of SPECIAL EQUIPMENT Substation Trans- Spare (In Service) formers Trans- Number Total Capacity Line (In MVa) in Service formers Type of Equipment of Units (in MVa) No.

(f) (g) (h) (i) (j) (k) 4.00 1 1 8.00 2 Capacitor Bank 1 5 2 4.00 1 3 2.00 3 4 12.00 1 5 15.00 3 6 12.00 1 7 20.00 1 8 1.00 1 9 4.00 1 10 5.00 1 11 5.00 1 12 60.00 2 13 56.00 2 14 23.00 3 15 40.00 2 16 15.00 2 17 8.00 1 18 5.00 1 Capacitor Bank 1 34 19 2.00 1 20 10.00 2 21 4.00 1 Capacitor Bank 1 5 22 15.00 1 23 6.00 1 24 30.00 1 25 16.00 1 26 5.00 1 27 8.00 1 28 2.00 1 29 4.00 1 30 15.00 1 31 3.00 2 32 30.00 2 Capacitor Bank 2 149 33 8.00 2 34 40.00 2 35 30.00 1 36 13.00 1 37 8.00 1 38 20.00 1 39 55 0 5 193 40

FERC FORM NO. 1 (ED. 12-96) Next Page is 429 Page 427 Niagara Mohawk Power Corporation 6/01/2010 12/31/2009 SUBSTATIONS (Continued) CONVERSION APPARATUS AND Capacity of Number of Number of SPECIAL EQUIPMENT Substation Trans- Spare (In Service) formers Trans- Number Total Capacity Line (In MVa) in Service formers Type of Equipment of Units (in MVa) No.

(f) (g) (h) (i) (j) (k) 4.00 1 1 40.00 2 2 15.00 1 3 60.00 2 Capacitor Bank 1 34 4 15.00 1 5 10.00 2 6 10.00 1 7 15.00 1 Capacitor Bank 1 115 8 2.00 3 9 12.00 1 10 10.00 1 Capacitor Bank 1 34 11 3.00 1 12 20.00 4 13 8.00 1 14 20.00 1 15 8.00 1 16 15.00 1 17 6.00 3 18 6.00 1 19 4.00 1 20 18.00 1 21 13.00 1 22 1.00 1 23 8.00 1 24 12.00 6 25 20.00 1 26 30.00 2 Capacitor Bank 1 34 27 28.00 2 28 40.00 2 29 30.00 1 30 15.00 4 31 1.00 1 32 8.00 1 33 10.00 1 34 8.00 1 35 5.00 1 37 12.00 1 38 22.00 1 39 2.00 1 40 12.00 1 41 12.00 1 42 9.00 2 43 3.00 2 44 1.00 1 Capacitor Bank 1 34 45 4.00 3 46 10.00 4 47 2.00 1 48 2.00 3 49 3.00 1 50 8.00 4 51 2.00 3 52 4.00 1 53 5.00 1 54 3.00 1 55 15.00 1 56 4.00 3 57 25.00 1 58 15.00 1 59

Page 427-A Niagara Mohawk Power Corporation 6/01/2010 12/31/2009 SUBSTATIONS (Continued) CONVERSION APPARATUS AND Capacity of Number of Number of SPECIAL EQUIPMENT Substation Trans- Spare (In Service) formers Trans- Number Total Capacity Line (In MVa) in Service formers Type of Equipment of Units (in MVa) No.

(f) (g) (h) (i) (j) (k) 3.00 1 1 13.00 1 2 1.00 1 3 5.00 1 4 4.00 1 5 8.00 1 6 4.00 1 7 6.00 2 8 18.00 1 9 544.00 2 Capacitor Bank 1 115 10 2.00 3 11 12.00 1 12 8.00 1 13 20.00 2 14 4.00 1 15 7.00 4 Capacitor Bank 1 69 16 30.00 2 Capacitor Bank 1 115 17 27.00 2 18 4.00 1 19 4.00 1 20 6.00 1 21 10.00 2 22 8.00 1 23 5.00 1 24 3.00 1 25 5.00 1 26 3.00 1 27 3.00 2 28 8.00 1 29 5.00 1 30 15.00 1 31 4.00 1 32 60.00 2 Capacitor Bank 1 115 33 5.00 3 34 6.00 3 35 2.00 3 37 8.00 1 38 3.00 1 39 4.00 3 Capacitor Bank 1 5 40 40.00 2 41 13.00 1 42 30.00 2 43 1.00 6 44 4.00 1 45 6.00 3 46 15.00 1 47 20.00 1 48 12.00 1 49 8.00 1 50 12.00 1 51 8.00 1 52 5.00 1 53 10.00 0 54 3.00 2 55 13.00 2 56 8.00 1 57 10.00 1 58 514.00 2 59

Page 427-B Niagara Mohawk Power Corporation 6/01/2010 12/31/2009 SUBSTATIONS (Continued) CONVERSION APPARATUS AND Capacity of Number of Number of SPECIAL EQUIPMENT Substation Trans- Spare (In Service) formers Trans- Number Total Capacity Line (In MVa) in Service formers Type of Equipment of Units (in MVa) No.

(f) (g) (h) (i) (j) (k) 2.00 3 1 5.00 1 2 30.00 2 3 20.00 1 4 50.00 2 5 175.00 2 6 6.00 1 7 4.00 3 8 3.00 1 9 25.00 2 10 15.00 2 11 4.00 1 12 15.00 1 13 15.00 1 14 3.00 3 15 8.00 1 16 3.00 1 Capacitor Bank 1 5 17 8.00 1 18 4.00 1 19 6.00 1 20 5.00 1 21 12.00 1 22 5.00 1 23 4.00 1 24 304.00 1 Capacitor Bank 1 345 25 848.00 2 26 1.00 1 27 3.00 2 28 448.00 1 29 20.00 1 30 3.00 1 31 204.00 6 32 5.00 3 33 15.00 1 34 8.00 1 35 8.00 2 37 5.00 1 38 5.00 3 39 40.00 2 40 15.00 1 41 2.00 3 42 3.00 1 43 18.00 2 44 2.00 3 45 5.00 1 46 24.00 2 47 5.00 1 48 1.00 1 49 3.00 1 50 15.00 1 51 5.00 1 52 12.00 1 53 5.00 1 54 5.00 1 55 4.00 1 56 15.00 1 57 4.00 1 58 1.00 2 59

Page 427-C Niagara Mohawk Power Corporation 6/01/2010 12/31/2009 SUBSTATIONS (Continued) CONVERSION APPARATUS AND Capacity of Number of Number of SPECIAL EQUIPMENT Substation Trans- Spare (In Service) formers Trans- Number Total Capacity Line (In MVa) in Service formers Type of Equipment of Units (in MVa) No.

(f) (g) (h) (i) (j) (k) 4.00 1 1 4.00 1 2 5.00 1 3 51.00 2 4 1.00 1 5 5.00 1 6 2.00 3 7 474.00 3 8 4.00 1 9 10.00 2 10 4.00 1 11 50.00 3 12 45.00 6 13 8.00 1 14 5.00 1 15 5.00 1 16 3.00 1 17 3.00 1 18 5.00 1 Capacitor Bank 1 34 19 5.00 1 20 8.00 1 Capacitor Bank 1 69 21 15.00 1 22 40.00 2 Capacitor Bank 1 34 23 15.00 2 24 5.00 1 25 5.00 1 26 50.00 2 27 38.00 2 28 3.00 1 29 40.00 2 30 1.00 4 31 3.00 1 32 13.00 1 33 12.00 1 34 4.00 1 35 4.00 3 37 80.00 2 38 3.00 6 39 32.00 3 40 20.00 1 41 20.00 1 42 8.00 1 43 15.00 1 44 60.00 2 45 2.00 3 46 4.00 1 47 10.00 1 48 10.00 2 49 3.00 3 50 5.00 1 51 10.00 1 52 5.00 1 53 2.00 3 54 15.00 2 Capacitor Bank 2 149 55 1.00 2 56 8.00 3 57 28.00 4 58 36.00 2 59

Page 427-D Niagara Mohawk Power Corporation 6/01/2010 12/31/2009 SUBSTATIONS (Continued) CONVERSION APPARATUS AND Capacity of Number of Number of SPECIAL EQUIPMENT Substation Trans- Spare (In Service) formers Trans- Number Total Capacity Line (In MVa) in Service formers Type of Equipment of Units (in MVa) No.

(f) (g) (h) (i) (j) (k) 5.00 1 1 30.00 1 2 12.00 1 3 18.00 1 4 38.00 1 5 3.00 3 6 15.00 1 7 15.00 1 8 1.00 1 9 156.00 1 10 8.00 1 11 20.00 1 12 18.00 1 13 10.00 1 14 24.00 2 15 15.00 2 16 4.00 1 17 10.00 2 18 27.00 2 19 120.00 4 Capacitor Bank 2 46 20 15.00 1 21 2.00 1 22 8.00 1 23 2.00 1 24 38.00 2 Capacitor Bank 1 115 25 13.00 1 26 50.00 1 27 4.00 1 28 5.00 1 29 8.00 1 30 5.00 2 31 5.00 1 32 10.00 1 33 24.00 2 34 360.00 4 Capacitor Bank 2 690 35 12.00 1 37 6.00 1 38 2.00 1 39 1.00 1 40 8.00 1 41 10.00 1 42 15.00 3 43 15.00 2 44 3.00 1 Capacitor Bank 1 5 45 2.00 1 46 2.00 1 47 4.00 1 48 10.00 1 49 15.00 1 50 2.00 3 51 4.00 1 52 8.00 1 53 1.00 2 54 4.00 1 55 4.00 1 56 12.00 1 57 15.00 1 58 15.00 1 59

Page 427-E Niagara Mohawk Power Corporation 6/01/2010 12/31/2009 SUBSTATIONS (Continued) CONVERSION APPARATUS AND Capacity of Number of Number of SPECIAL EQUIPMENT Substation Trans- Spare (In Service) formers Trans- Number Total Capacity Line (In MVa) in Service formers Type of Equipment of Units (in MVa) No.

(f) (g) (h) (i) (j) (k) 4.00 1 1 5.00 1 2 8.00 1 3 12.00 1 4 40.00 2 5 4.00 1 6 10.00 4 7 36.00 2 8 18.00 2 Capacitor Bank 1 115 9 12.00 1 10 15.00 1 11 4.00 1 12 15.00 1 Capacitor Bank 1 345 13 30.00 1 14 10.00 2 15 30.00 1 16 50.00 1 17 8.00 1 18 12.00 1 19 6.00 2 20 10.00 1 21 3.00 1 22 3.00 3 23 27.00 2 Capacitor Bank 1 115 24 27.00 2 25 40.00 1 Capacitor Bank 1 115 26 27.00 2 Capacitor Bank 2 149 27 20.00 1 28 8.00 1 29 6.00 1 30 1.00 1 31 13.00 4 32 3.00 1 33 8.00 1 34 4.00 1 35 4.00 1 37 5.00 1 38 15.00 3 39 8.00 3 40 12.00 1 41 8.00 1 42 4.00 1 Capacitor Bank 1 34 43 30.00 1 44 20.00 3 45 3.00 1 46 2.00 3 47 2.00 1 48 20.00 1 Capacitor Bank 2 230 49 15.00 2 50 15.00 1 51 5.00 1 52 22.00 2 53 8.00 1 54 538.00 2 Capacitor Bank 3 1,035 55 20.00 2 56 1.00 3 57 5.00 1 58 5.00 1 59

Page 427-F Niagara Mohawk Power Corporation 6/01/2010 12/31/2009 SUBSTATIONS (Continued) CONVERSION APPARATUS AND Capacity of Number of Number of SPECIAL EQUIPMENT Substation Trans- Spare (In Service) formers Trans- Number Total Capacity Line (In MVa) in Service formers Type of Equipment of Units (in MVa) No.

(f) (g) (h) (i) (j) (k) 10.00 1 1 4.00 3 2 8.00 1 3 4.00 1 4 10.00 1 5 15.00 2 6 30.00 2 7 2.00 1 8 15.00 1 9 5.00 1 10 15.00 1 11 12.00 1 12 1.00 1 13 3.00 1 14 10.00 1 15 30.00 1 Capacitor Bank 1 34 16 4.00 1 17 12.00 1 18 25.00 1 Capacitor Bank 1 34 19 3.00 1 20 8.00 1 21 10.00 1 22 4.00 3 23 15.00 1 24 30.00 1 25 10.00 1 26 10.00 1 27 4.00 3 28 3.00 1 29 4.00 1 30 28.00 1 31 30.00 2 32 10.00 1 33 12.00 1 34 15.00 1 35 9.00 4 37 27.00 2 Capacitor Bank 1 115 38 3.00 1 39 4.00 1 40 4.00 1 41 250.00 2 42 12.00 1 43 2.00 1 44 3.00 1 45 1.00 2 46 5.00 1 47 20.00 2 48 30.00 1 49 15.00 1 50 3.00 1 51 12.00 1 52 20.00 1 53 20.00 1 54 3.00 1 55 30.00 2 56 3.00 3 57 5.00 1 58 1.00 3 59

Page 427-G Niagara Mohawk Power Corporation 6/01/2010 12/31/2009 SUBSTATIONS (Continued) CONVERSION APPARATUS AND Capacity of Number of Number of SPECIAL EQUIPMENT Substation Trans- Spare (In Service) formers Trans- Number Total Capacity Line (In MVa) in Service formers Type of Equipment of Units (in MVa) No.

(f) (g) (h) (i) (j) (k) 27.00 2 1 38.00 2 2 10.00 2 3 10.00 1 4 3.00 1 5 3.00 3 6 8.00 1 7 3.00 3 8 5.00 1 9 534.00 2 Capacitor Bank 1 115 10 5.00 1 11 1.00 3 12 12.00 1 13 4.00 3 14 30.00 1 15 34.00 2 16 1.00 3 17 15.00 1 18 40.00 2 19 10.00 1 20 2.00 3 21 15.00 1 Capacitor Bank 1 115 22 400.00 1 23 8.00 1 24 3.00 3 25 40.00 2 Capacitor Bank 1 34 26 4.00 1 27 80.00 2 28 45.00 2 29 1.00 1 30 13.00 1 31 4.00 1 32 6.00 1 33 20.00 1 34 47.00 4 Capacitor Bank 1 115 35 30.00 1 Capacitor Bank 1 34 37 12.00 1 38 15.00 1 Capacitor Bank 3 575 39 27.00 4 40 34.00 1 41 20.00 1 42 883.00 3 43 3.00 2 44 18.00 1 45 10.00 2 46 8.00 2 47 5.00 1 48 13.00 2 49 8.00 1 50 15.00 1 51 4.00 1 52 5.00 1 53 5.00 1 54 8.00 1 55 180.00 3 56 6.00 3 57 2.00 3 58 15.00 1 59

Page 427-H Niagara Mohawk Power Corporation 6/01/2010 12/31/2009 SUBSTATIONS (Continued) CONVERSION APPARATUS AND Capacity of Number of Number of SPECIAL EQUIPMENT Substation Trans- Spare (In Service) formers Trans- Number Total Capacity Line (In MVa) in Service formers Type of Equipment of Units (in MVa) No.

(f) (g) (h) (i) (j) (k) 8.00 1 Capacitor Bank 1 69 1 5.00 1 2 42.00 2 Capacitor Bank 2 92 3 20.00 1 4 5.00 1 5 8.00 1 6 10.00 2 7 10.00 1 8 8.00 1 9 5.00 1 10 120.00 4 Capacitor Bank 2 46 11 1.00 3 12 5.00 1 13 6.00 1 14 8.00 1 15 8.00 1 16 4.00 1 17 8.00 1 18 30.00 2 19 4.00 1 20 10.00 1 Capacitor Bank 2 68 21 3.00 1 22 5.00 1 23 1.00 1 24 3.00 1 25 15.00 1 26 45.00 9 27 15.00 3 28 15.00 1 29 2.00 3 30 2.00 1 31 10.00 1 32 5.00 1 33 4.00 1 Capacitor Bank 1 34 34 4.00 1 35 12.00 1 37 50.00 1 38 10.00 2 39 4.00 1 40 15.00 1 41 6.00 2 42 10.00 4 43 5.00 2 44 11.00 4 45 15.00 4 46 10.00 4 47 15.00 4 48 10.00 4 49 15.00 4 50 10.00 4 51 15.00 4 52 10.00 4 53 10.00 4 Capacitor Bank 1 4 54 10.00 4 55 10.00 4 56 15.00 4 57 10.00 4 Capacitor Bank 1 4 58 10.00 4 59

Page 427-I Niagara Mohawk Power Corporation 6/01/2010 12/31/2009 SUBSTATIONS (Continued) CONVERSION APPARATUS AND Capacity of Number of Number of SPECIAL EQUIPMENT Substation Trans- Spare (In Service) formers Trans- Number Total Capacity Line (In MVa) in Service formers Type of Equipment of Units (in MVa) No.

(f) (g) (h) (i) (j) (k) 15.00 4 1 10.00 4 2 10.00 4 3 15.00 4 4 15.00 4 5 10.00 4 6 8.00 3 7 10.00 4 8 15.00 4 9 10.00 4 10 15.00 4 11 11.00 3 12 15.00 4 13 15.00 4 14 11.00 3 15 10.00 4 16 10.00 4 17 8.00 3 18 15.00 2 19 8.00 2 20 10.00 4 21 11.00 3 22 15.00 4 23 8.00 3 24 24.00 2 25 15.00 2 26 12.00 3 27 24.00 2 28 2.00 1 29 8.00 2 30 10.00 4 31 3.00 3 32 8.00 3 33 10.00 1 34 9.00 2 35 100.00 6 37 8.00 3 38 11.00 3 39 11.00 3 40 11.00 3 41 14.00 4 42 3.00 3 Capacitor Bank 1 5 43 3.00 3 44 12.00 4 45 17.00 4 46 5.00 2 47 8.00 3 48 15.00 2 49 40.00 2 50 4.00 1 51 13.00 1 52 4.00 1 53 8.00 2 54 36.00 2 55 4.00 1 56 2.00 1 57 3.00 1 58 8.00 2 59

Page 427-J Niagara Mohawk Power Corporation 6/01/2010 12/31/2009 SUBSTATIONS (Continued) CONVERSION APPARATUS AND Capacity of Number of Number of SPECIAL EQUIPMENT Substation Trans- Spare (In Service) formers Trans- Number Total Capacity Line (In MVa) in Service formers Type of Equipment of Units (in MVa) No.

(f) (g) (h) (i) (j) (k) 8.00 1 1 5.00 1 2 12.00 3 3 6.00 2 4 2.00 1 5 4.00 1 6 2.00 1 7 15.00 4 8 4.00 1 9 11.00 3 10 5.00 1 11 2.00 1 Capacitor Bank 1 5 12 5.00 3 13 8.00 1 14 12.00 1 15 3.00 1 16 10.00 1 17 8.00 1 18 8.00 1 19 3.00 1 20 12.00 1 21 15.00 1 22 12.00 1 23 20.00 1 24 18.00 1 Capacitor Bank 2 149 25 60.00 12 26 60.00 2 27 75.00 3 28 32.00 3 29 54.00 2 30 4.00 1 31 30.00 2 32 5.00 1 33 40.00 2 34 64.00 2 35 8.00 1 37 2.00 6 38 5.00 1 39 12.00 1 40 10.00 1 41 15.00 1 42 1.00 3 43 8.00 1 44 10.00 1 45 12.00 1 46 30.00 1 47 12.00 1 48 12.00 1 49 15.00 2 50 30.00 3 51 35.00 2 52 5.00 1 53 15.00 2 54 15.00 2 55 15.00 1 56 15.00 1 57 10.00 1 Capacitor Bank 1 34 58 30.00 1 59

Page 427-K Niagara Mohawk Power Corporation 6/01/2010 12/31/2009 SUBSTATIONS (Continued) CONVERSION APPARATUS AND Capacity of Number of Number of SPECIAL EQUIPMENT Substation Trans- Spare (In Service) formers Trans- Number Total Capacity Line (In MVa) in Service formers Type of Equipment of Units (in MVa) No.

(f) (g) (h) (i) (j) (k) 4.00 1 1 8.00 1 2 10.00 1 3 40.00 2 4 3.00 1 5 15.00 1 6 4.00 1 7 6.00 3 8 15.00 1 9 5.00 1 10 5.00 1 11 27.00 2 12 6.00 3 13 2.00 6 14 2.00 1 15 3.00 1 16 8.00 1 17 2.00 3 18 2.00 2 19 18.00 1 20 2.00 3 21 11.00 1 Capacitor Bank 1 115 22 12.00 5 23 2.00 1 24 8.00 1 25 10.00 1 26 12.00 1 27 36.00 2 28 60.00 2 Capacitor Bank 1 34 29 50.00 4 30 6.00 1 31 41.00 2 32 18.00 1 33 8.00 1 34 40.00 2 35 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59

Page 427-L Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 ELECTRIC DISTRIBUTION METERS AND LINE TRANSFORMERS

1. Report below the information called for concerning under a lease, give name of lessor, date and period of lease, distribution watt-hour meters and line transformers. and annual rent. If 500 or more meters or line transformers 2. Include watt-hour demand distribution meters, but not are held other than by reason of sole ownership or lease, external demand meters. give name of co-owner or other parties, explain basis of accounting 3. Show in a footnote the number of distribution watt-hour for expenses between the parties, and state amounts and meters or line transformers held by the respondent under accounts affected in respondent's books of account. Specify lease from others, jointly owned with others, or held in each case whether lessor, co-owner, or other party is an otherwise than by reason of sole ownership by the respon- associated company. dent. If 500 or more meters or line transformers are held

LINE TRANSFORMERS Line Item Number of Watt-Hour No. Meters Number Total Capacity (In MVa) (a) (b) (c) (d) 1 Number at Beginning of Year 1,699,808 442,828 16,841 2 Additions During Year 3 Purchases 2,299 11,688 445 4 Associated with Utility Plant Acquired 5 TOTAL Additions (Enter Total of Lines 3 and 4) 2,299 11,688 445 6 Reductions During Year 7 Retirements 21,469 32,720 1,244 8 Associated with Utility Plant Sold 9 TOTAL Reductions (Enter Total of Lines 7 and 8) 21,469 32,720 1,244 10 Number at End of Year (Lines 1 + 5 - 9) 1,680,638 421,796 16,042 11 In Stock 927 20,721 788 12 Locked Meters on Customers' Premises 13 Inactive Transformers on System 14 In Customers' Use 15 In Company's Use 1,679,711 401,075 15,253 16 TOTAL End of Year (Enter Total of lines 11 to 15. This line should equal line 10.) 1,680,638 421,796 16,041

FERC FORM NO. 1 (ED. 12-88) Page 429 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 ENVIRONMENTAL PROTECTION FACILITIES

1. For purposes of this response, environmental protection or low sulfur fuels including storage and facilities shall be defined as any building, structure, equipment, handling equipment facility, or improvement designed and constructed solely for (3) Monitoring equipment control, reduction, prevention or abatement of discharges or (4) Other. releases into the environment of gaseous, liquid or solid B. Water pollution control facilities: substances, heat, noise or for the control, reduction, (1) Cooling towers, ponds, piping, pumps, etc. prevention, or abatement of any other adverse impact of an (2) Waste water treatment equipment activity on the environment. (3) Sanitary waste disposal equipment 2. Report the differences in cost of facilities installed for (4) Oil interceptors environmental considerations over the cost of alternative (5) Sediment control facilities facilities which would otherwise be used without environmental (6) Monitoring equipment considerations. Use the best engineering design achievable (7) Other. without environmental restrictions as the basis for determining C. Solid waste disposal costs: costs without environmental considerations. It is not intended (1) Ash handling and disposal equipment that special design studies be made for purposes of this (2) Land response. Base the response on the best engineering (3) Settling ponds judgment where direct comparisons are not available. (4) Other. Include in these differences in costs the costs or estimated D. Noise abatement equipment: costs of environmental protection facilities in service, constructed (1) Structures or modified in connection with the production, transmission, and (2) Mufflers distribution of electrical energy and shall be reported herein for (3) Sound proofing equipment all such environmental facilities placed in service on or after (4) Monitoring equipment January 1, 1969, so long as it is readily determinable that such (5) Other. facilities were constructed or modified for environmental rather E. Esthetic costs: than operational purposes. Also report similar expenditures for (1) Architectural costs environmental plant included in construction work in progress. (2) Towers Estimate the cost of facilities when the original cost is not (3) Underground lines available or facilities are jointly owned with another utility, (4) Landscaping provided the respondent explains the basis of such estimations. (5) Other. Examples of these costs would include a portion of the costs F. Additional plant capacity necessary due to of tall smokestacks, underground lines, and landscaped restricted output from existing facilities, or substations. Explain such costs in a footnote. addition of pollution control facilities. 3. In the cost of facilities reported on this page, include G. Miscellaneous: an estimated portion of the cost of plant that is or will be used (1) Preparation of environmental reports to provide power to operate associated environmental protection (2) Fish and wildlife plants included in facilities. These costs may be estimations on a percentage of Accounts 330, 331, 332, and 335. plant basis. Explain such estimations in a footnote. (3) Parks and related facilities 4. Report all costs under the major classifications provided (4) Other. below and include, as a minimum, the items listed hereunder: 5. In those instances when costs are composites of A. Air pollution control facilities: both actual supportable costs and estimates of costs, (1) Scrubbers, precipitators, tall smokestacks, etc. specify in column (f) the actual costs that are included (2) Changes necessary to accommodate use of in column (e). environmentally clean fuels such as low ash 6. Report construction work in progress relating to environmental facilities at line 9.

CHANGES DURING YEAR Balance Line Classification of Cost Additions Retirements Adjustments at End Actual No. of Year Cost (a) (b) (c) (d) (e) (f) 1 Air Pollution Control Facilities 2 Water Pollution Control Facilities 3 Solid Waste Disposal Costs 4 Noise Abatement Equipment 5 Esthetic Costs 6 Additional Plant Capacity 7 Miscellaneous (Identify significant) 8 TOTAL (Total of lines 1 thru 7) 0 0 0 0 0 9 Construction Work in Progress

FERC FORM NO. 1 (ED. 12-88) Page 430 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 ENVIRONMENTAL PROTECTION EXPENSES

1. Show below expenses incurred in connection with addition of pollution control equipment, use of alternate the use of environmental protection facilities, the cost of environmentally preferable fuels or environmental which are reported on page 430. Where it is necessary regulations of governmental bodies. Base the price of that allocations and/or estimates of costs be made, state replacement power purchased on the average system the basis or method used. price of purchased power if the actual cost of such 2. Include below the costs incurred due to the operation replacement power is not known. Price internally of environmental protection equipment, facilities, and generated replacement power at the system average programs. cost of power generated if the actual cost of specific 3. Report expenses under the subheadings listed replacement generation is not known. below. 6. Under item 8 include ad valorem and other taxes 4. Under item 6 report the difference in cost between assessed directly on or directly relatable to environmental environmentally clean fuels and the alternative fuels facilities. Also include under item 8 licensing and similar that would otherwise be used and are available for fees on such facilities. use. 7. In those instances where expenses are composed of 5. Under item 7 include the cost of replacement both actual supportable data and estimates of costs, power, purchased or generated, to compensate for the specify in column (c) the actual expenses that are deficiency in output from existing plants due to the included in column (b).

Line Classification of Expenses Amount Actual Expenses No. (a) (b) (c) 1 Depreciation 2 Labor, Maintenance, Materials, and Supplies Cost Related to Env. Facilities and Programs 3 Fuel Related Costs 4 Operation of Facilities 5 Fly Ash and Sulfur Sludge Removal 6 Difference in Cost of Environmentally Clean Fuels 7 Replacement Power Costs 8 Taxes and Fees 9 Administrative and General 10 Other (Identify significant) 11 TOTAL 00

FERC FORM NO. 1 (ED. 12-88) Next Page is 450 Page 431 Name of Respondent This Report is: Date of Report Year of Report Niagara Mohawk Power Corporation (1) [ ] An Original (Mo, Da, Yr) (2) [ ] A Resubmission 6/01/2010 12/31/2009 FOOTNOTE DATA Page Item Column Number Number Number Comments (a) (b) (c) (d)

FERC FORM NO. 1 (ED. 12-87) Page 450

If applicable, see insert page below Niagara Mohawk Power Corporation 12/31/2009 FOOTNOTE DATA Page Item Column Number Number Number Comments (a) (b) (c) (d)

FERC FORM NO. 1 (ED. 12-87) Page 450-A