Exhibit PSE-501 Period II John Story. Statement AA - Period II Puget Sound Energy Balance Sheets
|
|
- Esther Willis
- 6 years ago
- Views:
Transcription
1 Statement AA - Period II Balance Sheets Page 1 of 4 FERC 2010 Change 2011 Line No. Account Description Amount Amount Utility Plant Plant in Service $9,793,926,043 $478,686,201 $10,272,612, Property Under Capital Leases Plant Held for Future Use $54,097,762 $54,097, Completed Construction Not Classified $58,822,155 $58,822, Construction Work in Progress $628,385,943 $532,742,706 $1,161,128, Accumulated Provision for Depreciation ($3,524,842,318) ($269,242,297) ($3,794,084,615) Accumulated Provision for Amortization ($118,077,126) ($118,077,126) Electric Plant Acquisition Adjustments $251,782,251 $251,782, Accumulated Provision for Amort. of Acquisition Adjustments ($60,122,543) ($60,122,543) Gas Stored Undergroound - Noncurrent $8,057,045 $8,057, Other Utility Plant 12. Total Utility Plant $7,092,029,212 $742,186,610 $7,834,215,822 Other Property and Investments Nonutility Property $4,213,318 $4,213, Accumulated Provision for Depr. & Amort. Of Nonutility Property ($863,648) ($863,648) Investment in Subsidiary Companies $49,380,155 $49,380, Other Investments $68,718,285 $68,718, Other Special Funds $ Derivative Instrument Assets $8,232,813 $8,232, Derivative Instrument Assets - Hedges $0 20. Total Other Property and Investments $129,680,923 $0 $129,680,923
2 Statement AA - Period II Balance Sheets Page 2 of 4 FERC 2010 Change 2011 Line No. Account Description Amount Amount Current and Accrued Assets Cash $13,672,281 ($746,447) $12,925, Other Special Deposits $4,736,379 ($258,586) $4,477, Working Funds $2,820,588 ($153,992) $2,666, Temporary Cash Investments $15,000,000 ($818,934) $14,181, Notes Receivable $3,461,113 $3,461, Customer Accounts Receivable $265,108,807 $50,893,438 $316,002, Other Accounts Receivable $69,895,436 $12,155,571 $82,051, Accumulated Provision for Uncollectable Accounts ($9,783,914) ($500,564) ($10,284,478) Accounts Receivable form Associated Companies $101,702 $101, Fuel $16,316,797 $16,316, Plant Materials and Operating Supplies $79,805,285 $2,394,159 $82,199, Stores Expense $4,416,676 $132,500 $4,549, Gas Stored Underground - Current $75,272,703 ($10,995,535) $64,277, Liquefied Natural Gas $632,728 $632, Prepayments $22,239,821 $406,011 $22,645, Interest and Dividends Receivable $0 $ Accrued Utility Revenues $194,088,080 ($6,328,140) $187,759, Misc. Current and Accrued Assets $5,924 $5, Derivative Instrument Assets $7,499,503 $7,499, Derivative Instrument Assets - Hedges 21. Total Current and Accrued Assets $765,289,909 $46,179,481 $811,469,390 Deferred Debits Unamortized Debt Expenses $43,900,305 ($2,038,270) $41,862, Extraordinary Property Losses $103,629,756 ($16,351,881) $87,277, Unrecovered Plant and Regulatory Study Costs $7,393,833 $7,393, Other Regulatory Assets $484,399,175 ($1,284,969) $483,114, Preliminary Survey and Investigation Charges $2,195,883 $2,195, $ $ Clearing Accounts $ Temporary Facilities $19,699 $19, Misc. Deferred Debits $364,954,870 ($1,979,469) $362,975, Deferred Losses from Disposition of Utility Plant $539,448 $539, Research, Development and Demonstration Expend. $ Unamortized Loss on Reacquired Debt $18,304,231 $18,304, Accumulated Deferred Income Taxes $549,148,984 $36,646,136 $585,795, Unrecovered Purchase Gas Costs $5,991,769 ($5,890,448) $101, Total Deferred Debits $1,580,477,953 $9,101,099 $1,589,579, Total Assets $9,567,477,997 $797,467,190 $10,364,945,187
3 Statement AA - Period II Balance Sheets Page 3 of 4 FERC 2010 Change 2011 Line No. Account Description Amount Amount Proprietary Capital Common Stock Issued $859,038 $859, Preferred Stock Issued $ Premium on Capital Stock $478,145,250 $478,145, Gain on Resale of Reacquired Capital Stock $ Misc. Paid in Capital $2,488,196,691 $293,000,000 $2,781,196, Capital Stock Expense ($7,133,879) ($7,133,879) Appropriated Retained Earnings $167,604,344 $7,432,406 $175,036, Unappropriated Retained Earnings $4,882,711 $4,882, Accumulated Other Comprehensive Income ($157,646,287) $22,115,530 ($135,530,757) 10. Total Proprietary Capital $2,974,907,868 $322,547,936 $3,297,455,804 Long Term Debt Bonds $3,463,860,000 $240,000,000 $3,703,860, Other Long Term Debt 13. Total Long Term Debt $3,463,860,000 $240,000,000 $3,703,860,000 Other Noncurrent Liabilities Obligations Under Capital Leases - Noncurrent Accum. Provision for Injuries and Damages $300,000 $300, Accum. Provision for Pensions and Benefits $58,748,833 $942,037 $59,690, Accum. Misc. Operating Provisions $75,678,611 ($5,201,089) $70,477, Long Term Portion of Derivative Instrument Liabilities $155,178,787 ($9,098,359) $146,080, Asset Retirement Obligations $25,416,838 $1,342,848 $26,759, Total Other Noncurrent Liabilities $315,323,069 ($12,014,563) $303,308,506 Current and Accrued Liabilities Notes Payable $247,000,000 ($9,224,479) $237,775, Accounts Payable $323,008,525 ($2,156,157) $320,852, Notes Payable to Associated Companies $22,597,785 $22,597, Accounts Payable to Associated Companies $616,351 $616, Customer Deposits $30,153,837 $30,153, Taxes Accrued $19,834,149 $110,655,178 $130,489, Interest Accrued $54,723,144 $5,183,254 $59,906, Tax Collections Payable $2,264,845 $2,264, Misc. Current and Accrued Liabilities $17,573,377 ($2,285,000) $15,288, Obligations Under Capital Leases - Current $0 $ Derivative Instrument Liabilities $243,053,430 ($82,130,851) $160,922, Derivative Instrument Liabilities - Hedges 33. Total Current and Accrued Liabilities $960,825,443 $20,041,945 $980,867,388
4 Statement AA - Period II Balance Sheets Page 4 of 4 FERC 2010 Change 2011 Line No. Account Description Amount Amount Deferred Credits Customer Advances for Construction $94,479,314 $94,479, Other Deferred Credits $150,729,165 $78,686,774 $229,415, Other Regulatory Liabilities $98,077,992 ($6,029,046) $92,048, Accumulated Deferred Investment Tax Credits $115,553 $165,131 $280, Deferred Gains from Disposition of Utility Plant $5,030,945 ($2,212,500) $2,818, Unamortized Gain of Reacquired Debt $10,083 $10, Accum. Deferred Income Taxes - Accel. Amort. $ Accum. Deferred Income Taxes - Other Property $1,202,674,847 $150,279,817 $1,352,954, Accum. Deferred Income Taxes - Other $301,443,718 $6,001,696 $307,445, Total Deferred Credits $1,852,561,617 $226,891,872 $2,079,453, Total Liabilities $9,567,477,997 $797,467,190 $10,364,945,187 Check $0 $0 $0
5 Statement AB - Period II Income Statement Page 1 of 2 FERC Line No. Account Description Amount Utility Operating Income Sales Of Electricity Residential $1,113,312, Commercial & Industrial $1,002,371, Street Lighting $17,347, Sales for Resale $18,562, Total Sales Of Electricity $2,151,594,041 Other Operating Revenues Other Electric Revenues $129,932, Revenues from Transmission of Electricity of Others $24,940, Total Other Operating Revenues $154,872,788 Operating Expenses Operation Expense $1,327,839, Maintenance Expense $100,523, Depreciation Expense $204,563, Depreciation Expense for Asset Retirement Amortization of Limited Term Electric Plant Amortization of Other Electric Plant $13,858, Amortization of Electric Plant Acquisition Adjustments Regulatory Debits $152,349, Regulatory Credits Taxes other than Income Taxes $215,904, Income Taxes $591, Provision for Deferred Income Taxes $117,172, Provision for Deferred Income Taxes - Credit ($20,848,777) Investment Tax Credit Adjustments Gains from Disposition of Utility Property Losses from Disposition of Utility Property Gains from Disposition of Allowances Losses from Disposition of Allowances Accretion Expense $1,114, Total Utility Operating Expenses $2,113,068, Net Utility Operating Income $193,398,072
6 Statement AB - Period II Income Statement Page 2 of 2 FERC Line No. Account Description Amount Other Income Revenues for Merchandizing, Jobbing and Contract Work Costs & Expenses of Merchandizing, Job. & Contract Work Revenues from Nonutility Operations Expenses of Nonutility Operations Nonoperating Rental Income Equity in Earnings of Subsidiary Companies Interest & Dividend Income $10,466, Allowance for Other Funds Used Durring Construction $40,300, Miscellaneous Nonoperating Income $57,692, Gain on Disposition of Property 11. Total Other Income $108,459, Donations Life Insurance ($2,066,466) Penalities Exp. For Civic, Political & Related Activities Other Deductions $8,992, Total Other Deductions $6,926,351 Taxes on Other Income and Deductions Taxes Other than Income Taxes Income Taxes $515, Provision for Deffered Income Taxes Provision for Deffered Income Taxes - Credit 22. Total Taxes on Other Income and Deductions $515,658 Interest Charges Interest on Long Term Debt $132,600, Amort. of Debt Discount & Expense $4,543, Amort. of Loss on Reaquired Debt $799, Amort. of Gain on Reaquired Debt - Credit Interest on Debt to Assoc. Companies Other Interest Expense $17,404, Allowance for Borrowed Funds Used Durring Construction ($31,423,561) 30. Net Interest Charges $123,924, Net Income $170,490,863
7 Statement AC - Period II Retained Earnings Page 1 of 1 (1) (2) Line No. Description Amount 1. Balance-Beginning Of Year $167,604, License Hydro Project Excess Earnings $0 3. Balance Transferred From Income $226,923, Dividends Declared Common Stock $219,490, Transfers from Unappropriated Undistributed Subsidiary Earnings $0 6. Balance End Of the Period $175,036, Total Appropriated Retained earnings -Amortization Reserve Account $8,376, Total Retained Earnings $183,413,211
8 Statement AD - Period II Cost Of Plant Account 101, 102, 106 Page 1 of 3 (1) (2) Line No. Functional Classification Average Balance 1. Production $2,590,701, Transmission $478,449, Distribution $3,612,724, General & Intangible $213,804, Sub Total $6,895,680, Common $265,463, Total Plant $7,161,144,098
9 Statement AD - Period II Cost Of Plant Account 101, 102, 106 Page 2 of 3 (1) (2) (3) (4) (5) (6) Derviation of Production Construction Completed Total Line No. Steam Hydro Other Production Not Classified Production 1. December 2010 $1,139,427,258 $292,346,983 $1,147,323,098 $301,816 $2,579,399, January 2011 $1,138,989,108 $292,521,333 $1,148,096,125 $0 $2,579,606, February 2011 $1,138,691,324 $292,393,868 $1,148,822,239 $0 $2,579,907, March 2011 $1,138,635,370 $292,266,402 $1,149,520,489 $0 $2,580,422, April 2011 $1,138,975,387 $292,138,937 $1,150,195,217 $0 $2,581,309, May 2011 $1,139,972,565 $292,011,471 $1,150,841,636 $0 $2,582,825, June 2011 $1,141,690,244 $291,884,006 $1,151,728,565 $0 $2,585,302, July 2011 $1,144,005,923 $291,756,540 $1,152,414,033 $0 $2,588,176, August 2011 $1,146,492,962 $291,629,074 $1,153,085,305 $0 $2,591,207, September 2011 $1,148,828,213 $291,501,609 $1,153,789,896 $0 $2,594,119, October 2011 $1,150,812,546 $291,374,143 $1,154,387,477 $0 $2,596,574, November 2011 $1,152,591,969 $291,246,678 $1,154,979,185 $0 $2,598,817, December 2011 $1,168,010,804 $314,664,185 $1,158,769,738 $0 $2,641,444, Total $14,887,123,673 $3,817,735,229 $14,973,953,004 $301,816 $33,679,113, Month Average $1,145,163,359 $293,671,941 $1,151,842,539 $23,217 $2,590,701,055 Derviation of Transmission Construction Completed Total Transmission Not Classified Transmission 8. December 2010 $463,546,132 $9,470,735 $473,016, January 2011 $474,409,053 $0 $474,409, February 2011 $475,609,721 $0 $475,609, March 2011 $476,646,626 $0 $476,646, April 2011 $477,561,425 $0 $477,561, May 2011 $478,361,263 $0 $478,361, June 2011 $479,097,013 $0 $479,097, July 2011 $479,728,547 $0 $479,728, August 2011 $480,273,699 $0 $480,273, September 2011 $480,746,444 $0 $480,746, October 2011 $481,143,533 $0 $481,143, November 2011 $481,482,583 $0 $481,482, December 2011 $481,771,483 $0 $481,771, Total $6,210,377,522 $9,470,735 $6,219,848, Month Average $477,721,348 $728,518 $478,449,866
10 Statement AD - Period II Cost Of Plant Account 101, 102, 106 Page 3 of 3 (1) (2) (3) (4) Derviation of Distribution Construction Completed Total Line No. Distribution Not Classified Distribution 1. December 2010 $3,488,607,370 $19,906,526 $3,508,513, December 2011 $3,716,935,352 $0 $3,716,935, Total $7,205,542,722 $19,906,526 $7,225,449, Simple Average $3,602,771,361 $9,953,263 $3,612,724,624 Derviation of General & Intangible General & Construction Completed Total Intangible Not Classified General & Intangible 5. December 2010 $213,043,174 $1,603,014 $214,646, December 2011 $212,963,354 $0 $212,963, Total $426,006,527 $1,603,014 $427,609, Simple Average $213,003,264 $801,507 $213,804,771 Derviation of Common Construction Completed Total Common Not Classified Common 5. December 2010 $245,071,499 $5,384,730 $250,456, December 2011 $280,471,333 $0 $280,471, Total $525,542,832 $5,384,730 $530,927, Simple Average $262,771,416 $2,692,365 $265,463,781
11 Statement AE - Period II Accumulated Depreciation and Amortization Account 108, 111 (1) (2) Line No. Functional Classification Average Balance 1. Production $1,219,749, Transmission $160,662, Distribution $1,263,005, General & Intangible $51,559, Sub Total $2,694,977, Common $92,639, Total Plant $2,787,617,041
12 Statement AE - Period II Accumulated Depreciation and Amortization Account 108, 111 (1) (2) (3) (4) (5) (6) Derviation of Production and Transmission Total Total Line No. Steam Hydro Other Production Production Transmission 1. December 2010 $668,582,183 $140,738,620 $380,448,731 $1,189,769,534 $156,218, January 2011 $669,846,464 $141,111,283 $383,793,046 $1,194,750,793 $156,956, February 2011 $671,110,266 $141,483,645 $387,138,453 $1,199,732,364 $157,695, March 2011 $672,373,791 $141,855,708 $390,485,019 $1,204,714,518 $158,435, April 2011 $673,637,423 $142,227,471 $393,832,832 $1,209,697,726 $159,175, May 2011 $674,901,901 $142,598,934 $397,181,993 $1,214,682,828 $159,916, June 2011 $676,168,249 $142,970,098 $400,533,495 $1,219,671,842 $160,658, July 2011 $677,437,668 $143,340,961 $403,886,938 $1,224,665,567 $161,401, August 2011 $678,711,161 $143,711,524 $407,242,641 $1,229,665,326 $162,143, September 2011 $679,989,591 $144,081,787 $410,601,239 $1,234,672,617 $162,887, October 2011 $681,273,865 $144,451,751 $413,963,214 $1,239,688,830 $163,630, November 2011 $682,566,381 $144,821,414 $417,330,221 $1,244,718,016 $164,374, December 2011 $683,956,859 $145,640,443 $420,711,413 $1,250,308,715 $165,118, Total $8,790,555,802 $1,859,033,639 $5,207,149,235 $15,856,738,676 $2,088,613, Month Average $676,196,600 $143,002,588 $400,549,941 $1,219,749,129 $160,662,551
13 Statement AE - Period II Accumulated Depreciation and Amortization Account 108, 111 (1) (2) Derviation of Distribution Line No. Distribution 1. December 2010 $1,228,598, December 2011 $1,297,413, Total $2,526,011, Simple Average $1,263,005,859 Derviation of General & Intangible General & Intangible 5. December 2010 $47,558, December 2011 $55,561, Total $103,119, Simple Average $51,559,937 Derviation of Common Common 5. December 2010 $91,367, December 2011 $93,911, Total $185,279, Simple Average $92,639,564
14 Steam Production Capital Leases Account 108 Total December 2010 $0 $668,582,183 $668,582,183 January 2011 $0 $669,846,464 $669,846,464 February 2011 $0 $671,110,266 $671,110,266 March 2011 $0 $672,373,791 $672,373,791 April 2011 $0 $673,637,423 $673,637,423 May 2011 $0 $674,901,901 $674,901,901 June 2011 $0 $676,168,249 $676,168,249 July 2011 $0 $677,437,668 $677,437,668 August 2011 $0 $678,711,161 $678,711,161 September 2011 $0 $679,989,591 $679,989,591 October 2011 $0 $681,273,865 $681,273,865 November 2011 $0 $682,566,381 $682,566,381 December 2011 $0 $683,956,859 $683,956,859 Hydro Production Account 108 Account 111 Total December 2010 $140,738,620 $0 $140,738,620 January 2011 $141,111,283 $141,111,283 February 2011 $141,483,645 $141,483,645 March 2011 $141,855,708 $141,855,708 April 2011 $142,227,471 $142,227,471 May 2011 $142,598,934 $142,598,934 June 2011 $142,970,098 $142,970,098 July 2011 $143,340,961 $143,340,961 August 2011 $143,711,524 $143,711,524 September 2011 $144,081,787 $144,081,787 October 2011 $144,451,751 $144,451,751 November 2011 $144,821,414 $144,821,414 December 2011 $145,640,443 $145,640,443 Other Production Account 108 Account 111 Total December 2010 $380,364,820 $83,911 $380,448,731 January 2011 $383,793,046 $383,793,046 February 2011 $387,138,453 $387,138,453 March 2011 $390,485,019 $390,485,019 April 2011 $393,832,832 $393,832,832 May 2011 $397,181,993 $397,181,993 June 2011 $400,533,495 $400,533,495 July 2011 $403,886,938 $403,886,938 August 2011 $407,242,641 $407,242,641 September 2011 $410,601,239 $410,601,239 October 2011 $413,963,214 $413,963,214 November 2011 $417,330,221 $417,330,221 December 2011 $420,711,413 $420,711,413 Source : Financail Model
15 Statement AF - Period II Specified Deferred Credits (Includes 254, 255, 281, 282 and 283) Page 1 of 1 (1) (2) Line No. 254 Other Regulatory Liabilities Total 1. December 2010 $86,597, December 2011 $81,117, Average Balance $83,857, Accumulated Deferred Income Taxes 4. December 2010 $863,499, December 2011 $979,639, Average Balance $921,569, Accumulated Deferred Income Taxes 7. December 2010 $216,956, December 2011 $222,274, Average Balance $219,615,975
16 Statement AG - Period II Specified Plant Accounts and Deferred Debits (Includes 105, 114, 115, 182.1, 182.2, and 190) (1) (2) Line No. 105 Plant Held For Future Use Total 1. December 2010 $29,445, December 2011 $29,445, Average Balance $29,445, Electric Plant Acquistion Adjustment 4. Milwaukee $946, Dupont $302, Encogen $76,622, Mint Farm $156,960, Whitehorn $16,950, Total Average Balance $251,782, Accumulated Provision for Amortization for Electric Plant Acquistion Adjustment 10. Milwaukee $757, Dupont $298, Encogen $46,556, Mint Farm $11,792, Whitehorn $5,511, Total Average Balance $64,916, Extraordinary Property Losses 16. December 2010 $103,629, December 2011 $87,277, Average Balance $95,453, Unrecovered Plant and Regulatory Costs 19. December 2010 $7,393, December 2010 $7,393, Average Balance $7,393, Other Regulatory Assets 22. December 2010 $440,176, December 2011 $438,513, Average Balance $439,345, Accumulated Deferred Income Taxes 25. December 2010 $420,254, December 2011 $449,078, Average Balance $434,666,373
17 Breakdown of Account 114 Dec-10 Dec-11 Average Milwaukee $946,172 $946,172 $946,172 Dupont $302,358 $302,358 $302,358 Encogen $76,622,597 $76,622,597 $76,622,597 Mint Farm $156,960,791 $156,960,791 $156,960,791 Whitehorn $16,950,333 $16,950,333 $16,950,333 Total 114 $251,782,251 $251,782,251 $251,782,251 Breakdown of Account 115 Dec-10 Dec-11 Average Change Milwaukee $744,789 $770,589 $757,689 $25,800 Dupont $293,999 $302,358 $298,178 $8,359 Encogen $45,229,939 $47,882,839 $46,556,389 $2,652,900 Mint Farm $9,484,643 $14,101,142 $11,792,893 $4,616,499 Whitehorn $4,369,173 $6,654,078 $5,511,626 $2,284,905 Total 115 $60,122,543 $69,711,006 $64,916,775 $9,588,463 Certain Account Detail Dec-10 Dec-11 Average Mint Farm Deferral $41,988,654 $39,110,708 $40,549,681 Goldendale Deferred Costs $3,882,142 $413,682 $2,147,912 Sumas Deferral $640,861 $640,861 $640,861 Chelan PUD Contract Initiation $133,888,235 $132,706,885 $133,297,560 Chelan PUD Security Deposit $0 $18,500,000 $9,250,000 Total of Selected $180,399,892 $191,372,136 $185,886,014
18 Page 1 of 8 Statement AH - Period II Electric Operating and Maintenance Expenses (1) (2) Line No. Description Amount 2010 Amount 1. Steam Power Generation $139,745,822 $104,503, Hydraulic Power Production $15,997,694 $18,049, Other Power Generation $297,921,311 $246,653, Other Power Supply Expenses $551,278,469 $758,952, Total Production $1,004,943,296 $1,128,158, Transmission Expenses $90,095,652 $90,430, Distribution Expenses $82,873,044 $82,924, Customer Service and Informational Sales $151,464,231 $138,944, Administrative and General $98,986,822 $93,517, Total $1,428,363,045 $1,533,975, Total Operation Expenses $1,327,839,873 $1,411,705, Total Mainteanance Expenses $100,523,172 $122,269, Total $1,428,363,045 $1,533,975,208
19 Statement AH - Period II Electric Operating and Maintenance Expenses Page 2 of 8 (1) (2) (3) Line No. FERC Account Description Amount 2010 Amount Steam Power Generation Operation Operation Supervision and Engineering $669,053 $544, Fuel $90,062,807 $67,538, Steam Expenses $14,138,094 $7,964, Steam From Other Sources Steam Transferred -Credit Electric Expenses $2,847,263 $2,449, Miscellaneous Steam Power Expenses $8,165,585 $4,672, Rents $70,072 $41, Operation Supplies and Expenses Allowances 11. Total Operation $115,952,874 $83,210,520 Maintenance Maintenance Supervision and Engineering $2,051,433 $1,742, Maintenance of Structures $2,980,777 $2,244, Maintenance of Boiler Plant $12,945,730 $11,587, Maintenance of Electric Plant $2,863,152 $3,281, Maintenance of Miscellaneous Steam Plant $2,951,856 $2,436, Total Maintenance $23,792,948 $21,292, Total Steam Power Generation $139,745,822 $104,503,465
20 Period II Witness Statement AH - Period II Electric Operating and Maintenance Expenses Page 3 of 8 (1) (2) (3) Line No. FERC Account Description Amount 2010 Amount Hydraulic Power Generation Operation Operation Supervision and Engineering $2,934,790 $3,875, Water for Power Hydraulic Expenses $4,072,831 $4,084, Electric Expenses $238,731 $347, Miscellaneous Hydraulic Power Generation Expenses $2,444,195 $3,778, Rents Operation Supplies and Expenses 8. Total Operation $9,690,547 $12,086,327 Maintenance Maintenance Supervision and Engineering $4,857 $2, Maintenance of Structures $787,919 $468, Mainteanance of Reservoirs, Dams and Waterways $775,419 $511, Maintenance of Electric Plant $1,054,855 $609, Maintenance of Miscellaneous Hydraulic Plant $3,684,097 $4,371, Maintenance of Hydraulic Production Plant 15. Total Maintenance $6,307,147 $5,963, Total Hydraulic Power Generation $15,997,694 $18,049,509
21 Statement AH - Period II Electric Operating and Maintenance Expenses Page 4 of 8 (1) (2) (3) Line No. FERC Account Description Amount 2010 Amount Other Power Generation Operation Operation Supervision and Engineering $3,418,211 $3,533, Fuel $254,597,552 $200,608, Generation Expenses $8,462,774 $7,651, Miscellaneous Other Power Generation Expenses $3,699,636 $4,765, Rents $4,810,870 $4,384, Total Operation $274,989,043 $220,943,639 Maintenance Maintenance Supervision and Engineering $970,283 $664, Maintenance of Structures $585,212 $958, Maintenance of Generating and Electric Plant $19,979,178 $23,176, Maintenance of Miscellaneous Other Power Generation Plant $1,397,595 $910, Total Maintenance $22,932,268 $25,709, Total Other Power Generation $297,921,311 $246,653,151 Other Power Supply Expenses Purchased Power $538,232,078 $754,334, System Control and Load Dispatching $2,047,479 $1,350, Other Expenses $10,998,912 $3,267, Total Other Power Supply Expenses $551,278,469 $758,952,084
22 Statement AH - Period II Electric Operating and Maintenance Expenses Page 5 of 8 (1) (2) (3) Line No. FERC Account Description Amount 2010 Amount Transmission Expenses Operation Operation Supervision and Engineering $1,562,016 $1,989, Load Dispatching $2,012,867 $1,515, Load Dispatch -Reliability Load Dispatch - Monitor and Operate Transmission System Load Dispatch - Transmission Service and Scheduling Scheduling, System Control and Dispatch Services Reliability Planning and Standards Development Transmission Service Studies Generation Interconnection Studies Reliability Planning and Standards Development Services Station Expenses $119,789 $112, Overhead Line Expense $427,178 $406, Underground Line Expenses Transmission of Electricity by Others $79,472,619 $78,564, Miscellaneous Transmission Expenses $3,966,319 $3,248, Rents $220,764 $295,946 Total Operation $87,781,552 $86,132,818 Maintenance Maintenance Supervision and Engineering $148, Maintenance of Structures $265, Maintenance of Computer Hardware Maintenance of Computer Software Maintenance of Communication Equipment Maintenance of Miscellaneous Regional Transmission Plant Maintenance of Station Equipment $344,785 $506, Maintenance of Overhead Lines $1,969,315 $3,376, Maintenance of Underground Lines Maintenance of Miscellaneous Transmission Plant Maintenance of Transmission Plant 29. Total Maintenance $2,314,100 $4,297,296 Total Transmission Expenses $90,095,652 $90,430,114
23 Statement AH - Period II Electric Operating and Maintenance Expenses Page 6 of 8 (1) (2) (3) Line No. FERC Account Description Amount 2010 Amount Distribution Expenses Operation Operation Supervision and Engineering $2,654,682 $2,367, Load Dispatching $1,272,395 $2,501, Station Expenses $1,879,810 $1,809, Overhead Line Expenses $22,753,792 $3,597, Underground Line Expenses $3,459,158 $2,338, Street Lighting and Signal System Expenses $1,243,073 $1,286, Meter Expenses $1,539,799 $1,640, Customer Installations Expenses $4,277,854 $3,833, Miscellaneous Distribution Expenses $2,000,862 $2,690, Rents $681,012 $847, Total Operation $41,762,437 $22,912,209 Maintenance Maintenance Supervision and Engineering $ Maintenance of Structures $ Maintenance of Station Equipment $4,282,360 $4,454, Maintenance of Overhead Lines $21,423,574 $40,720, Maintenance of Underground Lines $13,196,479 $12,149, Maintenance of Line Transformers $367,506 $246, Maintenance of Street Lighting and Signal Systems $1,353,653 $1,939, Maintenance of Meters $487,035 $501, Maintenance of Miscellaneous Distribution Plant 24. Total Maintenance $41,110,607 $60,012, Total Distribution Expenses $82,873,044 $82,924,735
24 Statement AH - Period II Electric Operating and Maintenance Expenses Page 7 of 8 (1) (2) (3) Line No. FERC Account Description Amount 2010 Amount Customer Accounts Expenses Operation Supervision $271,672 $241, Meter Reading Expenses $16,656,639 $17,332, Customer Records and Collection Expenses $20,751,194 $21,077, Uncollectible Accounts $11,255,066 $11,596, Miscellaneous Customer Accounts Expenses ($83,330) ($72,315) 6. Total Customer Accounts Expenses $48,851,241 $50,175,907 Customer Service - Informational Expenses Operation Supervision $0 $ Customer Assistance Expenses $101,369,549 $87,151, Informational and Instructional Advertising Expenses $755,747 $1,431, Miscellaneous Customer Service and Informational Expenses $28,033 $41, Total Customer Service -Informational Expenses $102,153,329 $88,624,648 Sales Expenses Operation Supervision $5,304 $3, Demonstrating and Selling Expenses $345,089 $110, Advertising Expenses $198 $ Miscellaneous Sales Expenses $109,070 $29, Total Sales Expenses $459,661 $144, Total Customer Service and Informational Expenses $151,464,231 $138,944,684
25 Statement AH - Period II Electric Operating and Maintenance Expenses Page 8 of 8 (1) (2) (3) Line No. FERC Account Description Amount 2010 Amount Administrative and General Expenses Operation Administrative and General salaries $25,929,717 $24,283, Office Supplies and Expenses $7,024,293 $5,002, Administrative Expenses -Transferred-Credit ($152,704) ($164,288) Outside Service Employed $13,265,164 $12,275, Property Insurance $3,184,255 $4,972, Injuries and Damages $2,963,773 $3,587, Employee Pensions and Benefits $25,124,469 $25,153, Franchise Requirements $ Regulatory Commission Expenses $9,932,769 $5,508, Duplicate Charges - Credit $ General Advertising Expenses $279,881 $264, Miscellaneous General Expenses $1,600,035 $2,747, Rents $5,769,068 $4,890, Total Operation $94,920,720 $88,523,082 Maintenance Maintenance of General Plant $4,066,102 $4,994, Total Maintenance $4,066,102 $4,994, Total Administrative and General Expenses $98,986,822 $93,517,466
26 Allocation of Common Costs Electric Allocation Electric Common Allocation Total Supervision $0 $460, % $271,672 $271,672 Meter Reading Expenses $16,285,946 $585, % $370,693 $16,656,639 Customer Records and Collection Expenses $3,557,831 $29,161, % $17,193,363 $20,751,194 Uncollectible Accounts $11,255,066 $0 0.00% $0 $11,255,066 Miscellaneous Customer Accounts Expenses $0 ($141,333) 58.96% ($83,330) ($83,330) Customer Service and Informational Expenses $0 $ % $0 $0 Supervision $0 $ % $0 $0 Customer Assistance Expenses $14,557,089 $1,238, % $729,925 $15,287,014 Informational and Instructional Advertising Expenses $0 $1,281, % $755,747 $755,747 Miscellaneous Customer Service and Informational Expenses $0 $47, % $28,033 $28,033 Supervision $5,304 $ % $0 $5,304 Demonstrating and Selling Expenses $345,089 $ % $0 $345,089 Advertising Expenses $0 $ % $198 $198 Miscellaneous sales Expenses $109,070 $0 0.00% $0 $109,070 Sales Expenses $0 $0 0.00% $0 $0 Administrative and General salaries $8,163,928 $26,711, % $17,765,789 $25,929,717 Office Supplies and Expenses $1,366,322 $8,506, % $5,657,971 $7,024,293 Administrative Expenses -Transferred-Credit $0 ($229,596) 66.51% ($152,704) ($152,704) Outside Service Employed $3,856,764 $14,145, % $9,408,400 $13,265,164 Property Insurance $655,517 $4,152, % $2,528,738 $3,184,255 Injuries and Damages $262,748 $4,581, % $2,701,025 $2,963,773 Employee Pensions and Benefits $25,124,469 $ % $0 $25,124,469 Franchise Requirements $0 $0 0.00% $0 $0 Regulatory Commission Expenses $7,293,910 $3,967, % $2,638,859 $9,932,769 Duplicate Charges - Credit $0 $0 0.00% $0 $0 General Advertising Expenses $0 $420, % $279,881 $279,881 Miscellaneous General Expenses $240,264 $2,044, % $1,359,771 $1,600,035 Rents $274,894 $8,260, % $5,494,174 $5,769,068 Maintenance of General Plant $0 $ % $0 $0 Maintenance of General Plant $739,944 $5,000, % $3,326,158 $4,066,102
27 Allocation of Common Costs Electric Common Electric Common Gas Supervision 0 460, ,773 Meter Reading Expenses 16,285, ,150 16,285, ,150 11,625,800 Customer Records and Collection Expenses 3,557,831 29,161,064 3,557,831 29,161,064 3,034,659 Uncollectible Accounts 11,255, ,255,066 5,530,369 Miscellaneous Customer Accounts Expenses 0 (141,333) (141,333) Customer Service and Informational Expenses 0 0 Supervision 0 0 Customer Assistance Expenses 14,557,089 1,238,001 14,557,089 1,238,001 4,695,823 Informational and Instructional Advertising Expenses 0 1,281,796 1,281,796 Miscellaneous Customer Service and Informational Expenses 0 47,545 47,545 Supervision 5, ,304 Demonstrating and Selling Expenses 345, , ,760 Advertising Expenses Miscellaneous sales Expenses 109, ,070 Sales Expenses 0 0 Administrative and General salaries 8,163,928 26,711,456 8,163,928 26,711,456 1,382,221 Office Supplies and Expenses 1,366,322 8,506,948 1,366,322 8,506, ,753 Administrative Expenses -Transferred-Credit 0 (229,596) (229,596) Outside Service Employed 3,856,764 14,145,842 3,856,764 14,145, ,780 Property Insurance 655,517 4,152, ,517 4,152, ,931 Injuries and Damages 262,748 4,581, ,748 4,581, ,589 Employee Pensions and Benefits 25,124,469 25,124,469 12,005,932 Franchise Requirements 0 0 Regulatory Commission Expenses 7,293,910 3,967,613 7,293,910 3,967,613 2,389,252 Duplicate Charges - Credit 0 0 General Advertising Expenses 0 420, ,810 Miscellaneous General Expenses 240,264 2,044, ,264 2,044,461 Rents 274,894 8,260, ,894 8,260,674 Maintenance of General Plant 0 0 1,838,690 Maintenance of General Plant 739,944 5,000, ,944 5,000,989 94,094, ,196,604 44,657,559
28 Page 1 of 8 Statement AI - Period II Electric Operating and Maintenance Expenses - Wages and Salaries (1) (2) Line No. Description Amount 2010 Amount 1. Steam Power Generation $1,156, Hydraulic Power Production $8,417, Other Power Generation $11,337, Other Power Supply Expenses $5,367, Total Production $26,278,627 22,674, Transmission Expenses $3,598,461 3,047, Distribution Expenses $25,702,185 21,906, Customer Service and Informational Sales $14,526,154 14,317, Administrative and General $28,032,003 24,490, Total $98,137,430 $86,436, Total Operation Expenses $81,414, Total Mainteanance Expenses $16,722, Total $98,137,430
29 Statement AI - Period II Electric Operating and Maintenance Expenses - Wages and Salaries Page 2 of 8 (1) (2) (3) Line No. FERC Account Description Amount Steam Power Generation Operation Operation Supervision and Engineering $123, Fuel $ Steam Expenses $1, Steam From Other Sources $ Steam Transferred -Credit $ Electric Expenses $ Miscellaneous Steam Power Expenses $ Rents $ Operation Supplies and Expenses $ Allowances $0 11. Total Operation $124,956 Maintenance Maintenance Supervision and Engineering $ Maintenance of Structures $395, Maintenance of Boiler Plant $253, Maintenance of Electric Plant $299, Maintenance of Miscellaneous Steam Plant $83, Maintenance of Steam Production $0 18. Total Maintenance $1,031, Total Steam Power Generation $1,156,775
30 Statement AI - Period II Electric Operating and Maintenance Expenses - Wages and Salaries Page 3 of 8 (1) (2) (3) Line No. FERC Account Description Amount Hydraulic Power Generation Operation Operation Supervision and Engineering $1,917, Water for Power $ Hydraulic Expenses $2,031, Electric Expenses $227, Miscellaneous Hydraulic Power Generation Expenses $1,320, Rents $ Operation Supplies and Expenses $0 8. Total Operation $5,497,674 Maintenance Maintenance Supervision and Engineering $1, Maintenance of Structures $238, Mainteanance of Reservoirs, Dams and Waterways $451, Maintenance of Electric Plant $630, Maintenance of Miscellaneous Hydraulic Plant $1,596, Mainteanance of Hydraulic Production Plant $0 15. Total Maintenance $2,919, Total Hydraulic Power Generation $8,417,416
31 Statement AI - Period II Electric Operating and Maintenance Expenses - Wages and Salaries Page 4 of 8 (1) (2) (3) Line No. FERC Account Description Amount Other Power Generation Operation Operation Supervision and Engineering $2,782, Fuel $ Generation Expenses $5,697, Miscellaneous Other Power Generation Expenses $974, Rents $ Operation Supplies and Expenses $0 7. Total Operation $9,455,010 Maintenance Maintenance Supervision and Engineering $457, Maintenance of Structures $212, Maintenance of Generating and Electric Plant $895, Maintenance of Miscellaneous Other Power Generation Plant $315, Maintenance of Other Power Production Plant $0 13. Total Maintenance $1,882, Total Other Power Generation $11,337,067 Other Power Supply Expenses Purchased Power $ System Control and Load Dispatching $1,439, Other Expenses $3,928, Total Other Power Supply Expenses $5,367,369
32 Statement AI - Period II Electric Operating and Maintenance Expenses - Wages and Salaries Page 5 of 8 (1) (2) (3) Line No. FERC Account Description Amount Transmission Expenses Operation Operation Supervision and Engineering $1,226, Load Dispatch -Reliability $1,505, Load Dispatch - Monitor and Operate Transmission System $ Load Dispatch - Transmission Service and Scheduling $ Scheduling, System Control and Dispatch Services $ Reliability Planning and Standards Development $ Transmission Service Studies $ Generation Interconnection Studies $ Reliability Planning and Standards Development Services $ Station Expenses $59, Overhead Line Expense $105, Underground Line Expenses $ Tranmission of Electricity by Others $ Miscellaneous Transmission Expenses $348, Rents $ Operation Supplies and Expenses $0 17. Total Operation $3,245,117 Maintenance Maintenance Supervision and Engineering $ Maintenance of Structures $ Maintenance of Computer Hardware $ Maintenance of Computer Software $ Maintenance of Communication Equipment $ Maintenance of Miscellaneous Regional Transmission Plant $ Maintenance of Station Equipment $239, Maintenance of Overhead Lines $114, Maintenance of Underground Lines $ Maintenance of Miscellaneous Transmission Plant $ Maintenance of Transmission Plant $0 29. Total Maintenance $353,344 Total Transmission Expenses $3,598,461
33 Statement AI - Period II Electric Operating and Maintenance Expenses - Wages and Salaries Page 6 of 8 (1) (2) (3) Line No. FERC Account Description Amount Distribution Expenses Operation Operation Supervision and Engineering $1,773, Load Dispatching $1,092, Line and Station Expenses $ Station Expenses $871, Overhead Line Expenses $6,083, Underground Line Expenses $430, Street Lighting and Signal System Expenses $72, Meter Expenses $1,371, Customer Installations Expenses $3,553, Miscellaneous Distribution Expenses $776, Rents $117, Total Operation $16,142,993 Maintenance Maintenance Supervision and Engineering $ Maintenance of Structures $ Maintenance of Station Equipment $2,513, Maintenance of Structures and Equipment $ Maintenance of Overhead Lines $2,828, Maintenance of Underground Lines $3,530, Maintenance of Lines $ Maintenance of Line Transformers $146, Maintenance of Street Lighting and Signal Systems $108, Maintenance of Meters $430, Maintenance of Miscellaneous Distribution Plant $0 24. Total Maintenance $9,559, Total Distribution Expenses $25,702,185
34 Statement AI - Period II Electric Operating and Maintenance Expenses - Wages and Salaries Page 7 of 8 (1) (2) (3) Line No. FERC Account Description Amount Customer Accounts Expenses Operation Supervision $223, Meter Reading Expenses $235, Customer Records and Collection Expenses $12,379, Uncollectible Accounts $ Miscellaneous Customer Accounts Expenses $0 6. Total Customer Accounts Expenses $12,838,256 Customer Service - Informational Expenses Operation Customer Service and Informational Expenses $ Supervision $ Customer Assistance Expenses $928, Informational and Instructional Advertising Expenses $343, Miscellaneous Customer Service and Informational Expenses $16, Total Customer Service -Informational Expenses $1,287,832 Sales Expenses Operation Supervision $ Demonstrating and Selling Expenses $294, Advertising Expenses $ Miscellaneous Sales Expenses $105, Sales Expenses $0 18. Total Sales Expenses $400, Total Customer Service and Informational Expenses $14,526,154
35 Statement AI - Period II Electric Operating and Maintenance Expenses - Wages and Salaries Page 8 of 8 (1) (2) (3) Line No. FERC Account Description Amount Administrative and General Expenses Operation Administrative and General Salaries $25,708, Office Supplies and Expenses $ Administrative Expenses -Transferred-Credit $ Outside Service Employed $ Property Insurance $560, Injuries and Damages $294, Employee Pensions and Benefits $ Franchise Requirements $ Regulatory Commission Expenses $491, Duplicate Charges - Credit $ General Advertising Expenses $ Miscellaneous General Expenses $1, Rents $0 14. Total Operation $27,055,363 Maintenance Maintenance of General Plant $976, Total Maintenance $976, Total Administrative and General Expenses $28,032,003
36 Page 1 of 2 Statement AJ - Period II Depreciation and Amortization Expenses Account 403, 404, 406, 407, 411 (1) (2) (3) (4) Average Depreciation & Annual Depreciable Amortization Depreciation Line No. Functional Classification Electric Plant Expense Rate Line No. 1. Account 403, Depreciation Expense (101, 101.1) 2. Production $2,567,179,348 $73,116, % 3. Transmission $470,149,070 $8,443, % 4. Distribution $3,561,017,474 $100,319, % 5. General & Intangible $207,888,197 $8,251, % 6. Sub Total $6,806,234,089 $190,131, Common $14,432,008 * 8. Total Depreciation $6,806,234,089 $204,563, Account 404 Amortization Expense (101) Production $48,325,321 $1,271, % General & Intangible $73,064,000 $3,469, % 12. Common $254,889,077 $24,152, % 13. Total Amortization $376,278,398 $28,893, Account 406 Amortization of Electric Acquisition (114,182.3) 15. Production $250,533,721 $14,842, % 16. Transmission $946,172 $25, % 17. Distribution $302,358 $11, % 18. Total Plant $251,782,251 $14,879, Deferred AFUDC $52,292,405 $2,170, % Colstrip Common $7,465,262 $576, % Colstrip Deferred Depreciation $1,802,126 $139, % Total Amortization $313,342,043 $17,766, Account 407 Amortization of Unrecovered Plant (182.1) 25. Storm Damages $95,453,815 $16,351, % White River Plant Costs $36,536,952 $1,537, % PTC Reg Amort and Wind Grant $83,612,517 $107,104, % ** Total Amortization $215,603,284 $124,993, Total Depreciation and Amortization $7,711,457,814 $376,216,194 *Depreciable balance and depreciation rate included in line 12. **PTC balance is increasing, not decreasing
37 Statement AJ - Period II Depreciation and Amortization Expenses Account 403, 404, 406, 407, 411 (1) (2) (3) (4) Page 2 of 2 Description Certain Account Detail 2011 Amortization Mint Farm Deferral $2,877,946 Goldendale Deferred Costs $3,468,460 Sumas Deferral $0 Chelan PUD Contract Initiation $1,181,350 Chelan PUD Security Deposit $0 Total of Selected $7,527,756 December 2010 December 2011 Average INT Franchises, Baker Project $37,716,588 $37,080,682 $37,398,635 INT Franchises, Snoqualmie $11,244,639 $10,608,733 $10,926,686 HYD, Electron Hatchery $0 $0 $0 Total $48,961,227 $47,689,415 $48,325,321 December 2010 December 2011 Average General & Intangible - Amortized $73,064,000 $73,064,000 $73,064,000 (used 12/2010 as estimate for 12/2011) December 2010 December 2011 Average Deferred AFUDC $53,377,792 $51,207,018 $52,292,405 Colstrip Common $7,753,639 $7,176,885 $7,465,262 Colstrip Deferred Depreciation $1,871,665 $1,732,586 $1,802,126 December 2010 December 2011 Average Storm Damages $103,629,756 $87,277,874 $95,453,815 White River Plant Costs $37,305,563 $35,768,340 $36,536,952 PTC Reg Amort and Wind Grant $27,459,753 $139,765,281 $83,612,517
38 Statement AK - Period II Taxes Other Than Income Taxes Page 1 of 1 (1) (2) Line No. Description Amount 1. State Excise Taxes $85,361, Municipal Taxes $78,368, Property Taxes $41,466, Beneficial Use - Montana $1,775, Payroll Taxes $8,288, Total $215,259,684
39 Statement AL - Period II Working Capital Page 1 of 2 (1) (2) (3) (4) (5) (6) Line No. Description Amount Allocator Production Transmission Distribution 1. Account 151 Fuel Stock $16,020,197 1 $16,020, Account 154 Materials and Supplies $71,994,517 2 $34,039,975 $4,661,260 $33,293, Account 165 Prepayment $18,716,746 2 $8,849,529 $1,211,809 $8,655, Cash Working Capital $58,249,749 $21,106,645 $2,128,988 $35,014, Total Working Capital $164,981,208 $80,016,345 $8,002,057 $76,962,806 Derviation of Cash Working Capital 6. Production Expenses $1,004,943,296 1 $1,004,943, Transmission Expenses $90,095,652 1 $90,095, Distribution Expenses $82,873,044 1 $82,873, Customer Service and Informational Sales $151,464,231 1 $151,464, Administrative and General $98,986,822 2 $46,802,299 $6,408,868 $45,775, Total Operation and Maintenance Expenses $1,428,363,045 $1,051,745,595 $96,504,520 $280,112, Less Purchased Power (555) $538,232,078 1 $538,232, Less Fuel Costs (501, 547) $344,660,359 1 $344,660, Less Transmission of Electricity for Others (565) $79,472,619 1 $79,472, Net Amount $465,997,989 $168,853,158 $17,031,901 $280,112, Cash Working Capital 1/8 $58,249,749 $21,106,645 $2,128,988 $35,014,116 Allocators 17. 1) Direct Assignment 18. 2) Labor Excluding A&G (Statement AI) $55,579,273 $26,278,627 $3,598,461 $25,702, Allocator % % 6.474% %
40 Statement AL - Period I Working Capital Page 2 of 2 (1) (2) (3) (5) Account 151 Account 151 Account 151 Line No. Date Fuel Stock Electric Common 1. December 2010 $16,020, December 2011 $16,020, Total $32,040, Annual Average $16,020,197 Account 154 Account 154 Account 154 Line No. Date Materials and Supplies Electric Common 1. December 2010 $70,906,328 $68,077,414 $4,366, December 2011 $73,082,706 $70,012,635 $4,615, Total $143,989,034 $138,090,050 $8,982, Annual Average $71,994,517 $69,045,025 $4,491,117 Account 165 Account 165 Account 165 Line No. Date Prepayments Electric Common 1. December 2010 $18,487,961 $12,403,275 $9,391, December 2011 $18,945,531 $12,507,431 $9,679, Total $37,433,492 $24,910,706 $19,071, Annual Average $18,716,746 $12,455,353 $9,535,647
41 Statement AM - Period II Construction Work In Progress Page 1 of 1 Line No. 1. None for Production Revenue Requirement. No construction plans for regulation pool.
42 Statement AN - Period II Notes Payable Account 231 and 233 Page 1 of 1 (1) (2) Line No. Date Balance Account 231 Account 233 Total 1. December 2010 $269,597,785 December 2010 $247,000,000 $22,597,785 $269,597, December 2011 $260,373,306 December 2011 $237,775,521 $22,597,785 $260,373, Total $529,971, Average $264,985,546
43 Page 1 of 1 Statement AO - Period II Rate of Allowance for Funds Used During Construction Line No. 1. None for Production Revenue Requirement. No construction plans for regulation pool.
44 Statement AP - Period II Federal Income Tax Deductions - Interest Page 1 of 1 (1) (3) Line No. Description Amount 1. Production-related Rate Base (Schedule BK) $1,703,996, Debt Component of Capital Structure 52.0% 3. Weighted Cost of Debt 6.45% 4. Production-related Interest Deduction $57,152, The interest deduction used in determining the production revenue requirement 6. is calculated by multiplying production-related rate base times the debt 7. component of the capital structure times the weighted cost of debt.
UNIFORM SYSTEM OF ACCOUNTS ACCOUNT LISTING BALANCE SHEET CHART OF ACCOUNTS ASSETS AND OTHER DEBITS
BALANCE SHEET CHART OF ACCOUNTS ASSETS AND OTHER DEBITS 1. UTILITY PLANT 101 Electric plant in service (Major only). 101.1 Property under capital leases. 102 Electric plant purchased or sold. 103 Experimental
More informationThunder Bay Hydro Electricity Distribution Inc. 1-1 GENERAL (Input) Enter general information related to the Application. EDR 2006 MODEL (ver. 2.
Thunder Bay Hydro Electricity Inc. 1-1 GENERAL (Input) Enter general information related to the Application Version: 2.1 Name of Applicant Thunder Bay Hydro Electricity Inc. License EB -0259 File (s) RP
More informationSchedule I-1 Page 1 of 3 Sponsor: Freitas Case No UT
Schedule I1 Page 1 of 3 Case 1600269UT Balance Sheet (4) 1 Utility Plant 2 Utility Plant $ 6,115,284,102 $ 6,869,655,152 $ 754,371,050 3 Construction Work In Progress 277,974,080 (277,974,080) 4 Total
More informationSchedule I-1 Page 1 of 2 Sponsor: Freitas Case No UT
Schedule I1 Page 1 of 2 Balance Sheet (a) (b) No. Account Title Base Period Future Test Year Difference 1 Utility Plant 2 Utility Plant $ 5,372,176,653 $ 6,262,615,190 $ 890,438,537 3 Construction Work
More informationEntergy Services, Inc. Balance Sheet As of December 31, 2002 ( $ 000's )
Section I Statement AA Entergy Services, Inc. Balance Sheet As of December 31, 2002 ( $ 000's ) Ln Item Account Amount Assets and Other Debits 1 Utility Plant 101-106, 114 3,469,270 2 Construction Work
More informationEntergy Louisiana, LLC 2017 Pole Attachment Formula and Calculation for Public Utilities For the Test Year Ended December 31, 2016
2017 Pole Attachment Formula and Calculation for Public Utilities For the Test Year Ended December 31, 2016 Ln Description FF1 Ref. [1] USofA [2] Amount 1 Gross Plant 110.4.c 101-106, 114, 107 19,847,012,044
More informationEntergy Gulf States Louisiana, LLC 2015 Pole Attachment Formula and Calculation for Public Utilities For the Test Year Ended December 31, 2014
Entergy Gulf States Louisiana, LLC 2015 Pole Attachment Formula and Calculation for Public Utilities For the Test Year Ended December 31, 2014 Ln Data Source Reference [1] USofA [2] Amount 1 Gross Plant
More informationAttachment 7A Page 1 of 3
Attachment 7A Page 1 of 3 $ (In Thousands) Dec 31, 2015 Dec 31, 2016 Dec 31, 2017 Assets and Other Debits Utility Plant Electric Utility Plant 101 Electric Utility Plant in Service $ 13,747,438 $ 15,540,571
More informationEntergy Louisiana, LLC (5) 2016 Pole Attachment Formula and Calculation for Public Utilities For the Test Year Ended December 31, 2015.
Entergy Louisiana, LLC (5) 2016 Pole Attachment Formula and Calculation for Public Utilities For the Test Year Ended December 31, 2015 Ln Description FF1 Ref. [1] USofA [2] Amount 1 Gross Plant 110.4.c
More informationExhibit D-1 Page1 PACIFIC GAS AND ELECTRIC COMPANY CONDENSED CONSOLIDATED STATEMENTS OF INCOME
EXHIBIT D PACIFIC GAS AND ELECTRIC COMPANY CONDENSED CONSOLIDATED STATEMENTS OF INCOME Exhibit D-1 Page1 (Unaudited) Three Months Ended March 31, (in millions) 2010 2009 Operating Revenues Electric $ 2,510
More informationVolume V - RECON-1 Page 1 of 1
Minnesota Power RECON-1 Reconcile 2017 Projected FERC Income Statement to COSS per Budget Page 1 of 1 Name of Respondent Volume 4 Volume 4 ALLETE, Inc. 2017 Project Year Work Papers Work Papers STATEMENT
More informationMichigan Public Service Commission The Detroit Edison Company Projected Net Operating Income "Total Electric" and "Jurisdictional Electric"
Projected Net Operating Income Schedule: C1 "Total Electric" and "Jurisdictional Electric" Witness: T. M. Uzenski Projected 12 Month Period Ending March 31, 2012 Page: 1 of 1 ($000) (a) (b) (c) Historical
More informationDuquesne Light Company Distribution Rate Case Docket No. R Filing Index
Duquesne Light Company Distribution Rate Case Docket No. R-2013-2372129 Filing Index Exhibit 1 Summary of Filing Part I General Information Part II Primary Statements of Rate Base & Operating Income Part
More informationANNUAL REPORT. Rockland Electric Company NAME OF RESPONDENT. 4 Irving Place, New York, NY ADDRESS OF RESPONDENT TO THE
ANNUAL REPORT OF NAME OF RESPONDENT 4 Irving Place, New York, NY 13 ADDRESS OF RESPONDENT TO THE STATE OF NEW JERSEY BOARD OF PUBLIC UTILITIES 44 SOUTH CLINTON AVENUE, 9 TH FLOOR POST OFFICE BOX 35 TRENTON,
More informationElectric Utility System of Accounts
National Association of Regulatory Utility Commissioners 3rd Partnership Activity of the Energy Regulation Board of Zambia & Pennsylvania Public Utility Commission March 20-23, 2006 Electric Utility System
More informationMONTANA-DAKOTA UTILITIES CO. INCOME STATEMENT GAS UTILITY - MONTANA TWELVE MONTHS ENDED DECEMBER 31, 2016
Docket No. Rule 38.5.175 Page 1 of 7 MONTANA-DAKOTA UTILITIES CO. INCOME STATEMENT TWELVE MONTHS ENDED DECEMBER 31, 2016 Total Company Montana Other Reference Operating Revenues Sales $196,686,631 $55,781,839
More informationWATER, ELECTRIC, OR JOINT UTILITY ANNUAL REPORT
UTILITY NO. 5370 Class AB WATER, ELECTRIC, OR JOINT UTILITY ANNUAL REPORT OF SHEBOYGAN WATER UTILITY 72 PARK AVE SHEBOYGAN, WI 53081-2958 For the Year Ended: DECEMBER 31, 2017 TO PUBLIC SERVICE COMMISSION
More informationWATER, ELECTRIC, OR JOINT UTILITY ANNUAL REPORT
UTILITY NO. 5370 Class AB WATER, ELECTRIC, OR JOINT UTILITY ANNUAL REPORT OF SHEBOYGAN WATER UTILITY 72 PARK AVE SHEBOYGAN, WI 53081-2958 For the Year Ended: DECEMBER 31, 2016 TO PUBLIC SERVICE COMMISSION
More informationAPPALACHIAN POWER COMPANY Balance Sheets Assets & Other Debits FERC Period II - Beginning & Ending Balances 2008
APPALACHIAN POWER COMPANY Balance Sheets Assets & Other Debits FERC Period II - Beginning & Ending Balances 2008 STATEMENT AA PAGE 1 OF 4 ($000) Line No. Account 12/31/2007 12/31/2008 (a) (b) (c) 1 UTILITY
More informationWATER, ELECTRIC, OR JOINT UTILITY ANNUAL REPORT
UTILITY NO. 3140 Class AB WATER, ELECTRIC, OR JOINT UTILITY ANNUAL REPORT OF LITTLE CHUTE MUNICIPAL WATER DEPT 108 W MAIN ST LITTLE CHUTE, WI 54140-1750 For the Year Ended: DECEMBER 31, 2016 TO PUBLIC
More informationFINANCIAL and STATISTICAL REPORT for FEBRUARY 2013
FINANCIAL and STATISTICAL REPORT for FEBRUARY 2013 PUBLIC UTILITY DISTRICT NO. 1 OF OKANOGAN COUNTY TELEPHONE: (509)422-3310 POST OFFICE BOX 912 FAX: (509)422-4020 OKANOGAN, WASHINGTON 98840 COMPARATIVE
More informationFINANCIAL and STATISTICAL REPORT for MARCH 2013
FINANCIAL and STATISTICAL REPORT for MARCH 213 PUBLIC UTILITY DISTRICT NO. 1 OF OKANOGAN COUNTY TELEPHONE: (59)422-331 POST OFFICE BOX 912 FAX: (59)422-42 OKANOGAN, WASHINGTON 9884 COMPARATIVE STATEMENT
More informationU.S REGULATORY ACCOUNTING SYSTEMS IN PRACTICE
1 U.S REGULATORY ACCOUNTING SYSTEMS IN PRACTICE 15 DECEMBER 2008 ACCRA, GHANA 2 HOW IS REGULATORY ACCOUNTING USED? In order to determine reasonableness of charges Form basis to allocate costs used in determination
More informationBEFORE THE PUBLIC UTILITIES COMMISSION OF THE STATE OF CALIFORNIA
BEFORE THE PUBLIC UTILITIES COMMISSION OF THE STATE OF CALIFORNIA Application of Southern California Gas Company (U 904 G) and San Diego Gas & Electric Company (U 902 G) for Low Operational Flow Order
More informationANNUAL REPORT PUBLIC UTILITIES COMMISSION STATE OF MAINE. YEAR ENDED December 31, 2016 TO THE OF THE FOR THE. Central Maine Power Company.
ANNUAL REPORT OF Name Address 83 Edison Drive, Augusta, ME 04336 TO THE PUBLIC UTILITIES COMMISSION OF THE STATE OF MAINE FOR THE YEAR ENDED December 31, 2016 PART I : IDENTIFICATION 01 Exact Legal Name
More informationANNUAL REPORT WATER, ELECTRIC, OR JOINT UTILITY TO PUBLIC SERVICE COMMISSION OF WISCONSIN
UTILITY NO. 398 Class C 314 (2-5-9) ANNUAL REPORT OF Name: MUKWONAGO MUNICIPAL WATER UTILITY Principal Office: 44 RIVER CREST COURT P.O. BOX 26 MUKWONAGO, WI 53149 For the Year Ended: DECEMBER 31, 28 WATER,
More informationSUMMARY EXPLANATION OF STATEMENTS AND SCHEDULES. The following summary explanations of Statements and Schedules are intended as a general guide.
Black Hills Power, Inc. South Dakota Revenue Requirement Model Description SUMMARY EXPLANATION OF STATEMENTS AND SCHEDULES The following summary explanations of Statements and Schedules are intended as
More information20:10:13:55 D-1 Detailed Cost of Plant Gas Utility 20:10:13:56 D-2 Book Changes in Gas Plant in Service
Docket No. NG15- Index Statement or Rule Schedule Description 2:1:13:51 A Balance Sheet 2:1:13:52 B Income Statement 2:1:13:53 c Retained Earnings 2:1:13:54 D Plant in Service Gas Utility 2:1:13:55 D-1
More informationANNUAL REPORT. Rockland Electric Company NAME OF RESPONDENT. 4 Irving Place, New York, NY ADDRESS OF RESPONDENT TO THE.
ANNUAL REPORT OF NAME OF RESPONDENT 4 Irving Place, New York, NY 13 ADDRESS OF RESPONDENT TO THE. STATE OF NEW JERSEY BOARD OF PUBLIC UTILITIES TWO GATEWAY CENTER, SUITE 81, NEWARK, NEW JERSEY 712 December
More informationANNUAL REPORT. Central Maine Power Company. 83 Edison Drive, Augusta, ME TO THE PUBLIC UTILITIES COMMISSION OF THE STATE OF MAINE FOR THE
ANNUAL REPORT OF Name Address 83 Edison Drive, Augusta, ME 04336 TO THE PUBLIC UTILITIES COMMISSION OF THE STATE OF MAINE FOR THE YEAR ENDED December 31, 2017 PART I : IDENTIFICATION 01 Exact Legal Name
More informationFINANCIAL and STATISTICAL REPORT for JUNE 2014
FINANCIAL and STATISTICAL REPORT for JUNE 214 PUBLIC UTILITY DISTRICT NO. 1 OF OKANOGAN COUNTY TELEPHONE: (59)422-331 POST OFFICE BOX 912 FAX: (59)422-42 OKANOGAN, WASHINGTON 9884 COMPARATIVE STATEMENT
More informationCLASS "A" OR "B" WATER AND/OR WASTEWATER UTILITIES (Gross Revenue of More Than $200,000 Each) ANNUAL REPORT. Exact Legal Name of Respondent
CLASS "A" OR "B" WATER AND/OR WASTEWATER UTILITIES (Gross Revenue of More Than $200,000 Each) ANNUAL REPORT OF Exact Legal Name of Respondent Certificate Number(s) Submitted To The CHARLOTTE COUNTY GOVERNMENT
More informationFINANCIAL and STATISTICAL REPORT for MARCH 2014
FINANCIAL and STATISTICAL REPORT for MARCH 2014 PUBLIC UTILITY DISTRICT NO. 1 OF OKANOGAN COUNTY TELEPHONE: (509)422-3310 POST OFFICE BOX 912 FAX: (509)422-4020 OKANOGAN, WASHINGTON 98840 OPERATING REVENUE
More informationRate Base (Schedule 3) $ 488,114. Rate of Return (Schedule 4) 6.74% 7.78% Operating Income Required $ 32,920
AWC Rosebrook Water Computation of Revenue Deficiency For the Test Year Ended September 30, 2017 Actual Proforma Rate Base (Schedule 3) $ 488,114 $ 625,578 Rate of Return (Schedule 4) 6.74% 7.78% Operating
More information1 GROSS REVENUE REQUIREMENT (page 3, line 31, column 5) $ 121,165,696
Attachment O Page 1 of 5 Formula Rate - Non-Levelized Rate Formula Template For the 12 months ended 12/31/14 Utilizing FERC Form 1 Data Line Allocated No. Amount 1 GROSS REVENUE REQUIREMENT (page 3, line
More informationFormula Rate - Non-Levelized Rate Formula Template For the 12 months ended 12/31/15 Utilizing FERC Form 1 Data
Attachment O Page 1 of 5 Formula Rate - Non-Levelized Rate Formula Template For the 12 months ended 12/31/15 Utilizing FERC Form 1 Data Northern Indiana Public Service Company Line Allocated No. Amount
More informationPublic Service Company of New Mexico Attachment H 1 Current Year Formula Rate
Attachment H 1 Formula Rate Allocators 1 Wages and Salary Allocation Factor 2 Transmission Wages Expense page 354, line 21, column b 5,229,728 3 4 Total Wages Expense page 354, line 28, column b 118,475,166
More informationHistorical Year Historical Year (page 114 of P-521) 5,211,499 1,524,457 1,455, , ,812 43,194 85, ,521 - (1) 859,550
Adjusted Net Operating Income Schedule: C1 For the 12 Months Ended December 31, 2016 Witness: T. M. Uzenski (d) (e) (f) (g) (h) (i) (j) (k) (l) (m) Deprec State & Local Federal Source Fuel & and Property
More informationMonthly Financial Report
AGENDA ITEM NO: 4.C.1 Monthly Financial Report with data through February 2019 (Unaudited) The data contained in this report has not been independently audited. Alameda Municipal Power Financial Report
More informationMonthly Financial Report
AGENDA ITEM NO: 4.C.1 Monthly Financial Report with data through October 2017 (Unaudited) The data contained in this report has not been independently audited. Alameda Municipal Power Financial Report
More information(Internet version) Financial & Statistical Report November 2018
(Internet version) Financial & Statistical Report November 2018 12/17/2018 Statement of Operations For the Period Ended November 30, 2018 (in millions) Current Month Year-to-Date Operating Revenue $ 31.4
More informationFormula Rate - Non-Levelized Rate Formula Template For the 12 months ended 12/31/2019 Utilizing FERC Form 1 Data
Attachment O Page 1 of 5 Formula Rate - Non-Levelized Rate Formula Template For the 12 months ended 12/31/2019 Utilizing FERC Form 1 Data Northern Indiana Public Service Company LLC Line Allocated No.
More informationUtility Description Information
Utility Description Information All data entered is for the Annual Report period. The cells that are outlined in black should have data entered into them. Those cells that are shaded not require the utility
More informationFormula Rate - Non-Levelized Rate Formula Template For the 12 months ended 12/31/17 Utilizing FERC Form 1 Data
Attachment O Page 1 of 5 Formula Rate - Non-Levelized Rate Formula Template For the 12 months ended 12/31/17 Utilizing FERC Form 1 Data Northern Indiana Public Service Company Line Allocated No. Amount
More informationLakes Region Water Company SPS 1-1
Lakes Region Water Company SPS 1-1 Balance Sheet Assets and Other Debits 2015 2015 Proformed Line Year End Year End No. Account Title (Number) Balance Adjustments Balance (a) (b) (c) (d) (e) UTILITY PLANT
More informationFormula Rate - Non-Levelized Rate Formula Template For the 12 months ended 12/31/2016 Utilizing FERC Form 1 Data
Attachment O Page 1 of 5 Formula Rate - Non-Levelized Rate Formula Template For the 12 months ended 12/31/2016 Utilizing FERC Form 1 Data Northern Indiana Public Service Company Line Allocated No. Amount
More informationANNUAL REPORT WATER, ELECTRIC, OR JOINT UTILITY TO PUBLIC SERVICE COMMISSION OF WISCONSIN
UTILITY NO. 328 Class AB 313 (2-5-9) ANNUAL REPORT OF Name: MADISON WATER UTILITY Principal Office: 119 E OLIN AVENUE MADISON, WI 53713-1431 For the Year Ended: DECEMBER 31, 29 WATER,, OR JOINT UTILITY
More informationHistorical Projected Net Operating Net Operating Line Income Income No. Description 12/31/13 6/30/ Revenues 4,428,908 4,429,397
Projected Net Operating Income Schedule: C1 Total Electric and Jurisdictional Electric Witness: T. M. Uzenski Projected 12 Month Period Ending June 30, 2016 Page: 1 of 1 ($000) (a) (b) (c) Historical Projected
More information(Internet version) Financial & Statistical Report December 2017
(Internet version) Financial & Statistical Report December 2017 01/22/2018 Statement of Operations For the Period Ended December 31, 2017 (in millions) Current Month Year-to-Date Operating Revenue & Patronage
More information(Internet version) Financial & Statistical Report December 2016
(Internet version) Financial & Statistical Report December 2016 1/23/2017 Statement of Operations For the Period Ended December 31, 2016 (in millions) Current Month Year-to-Date Operating Revenue & Patronage
More information(Internet version) Financial & Statistical Report September 2017
(Internet version) Financial & Statistical Report September 2017 10/23/2017 Statement of Operations For the Period Ended September 30, 2017 (in millions) Current Month Year-to-Date Operating Revenue &
More informationUNITIL ENERGY SYSTEMS, INC NEW HAMPSHIRE FILING REQUIREMENT SCHEDULES TABLE OF CONTENTS
Unitil Energy Systems, Inc. DE 16-384 Filing Requirement Schedules UNITIL ENERGY SYSTEMS, INC NEW HAMPSHIRE FILING REQUIREMENT SCHEDULES TABLE OF CONTENTS Page Filing Requirement Schedule 1 Schedule -
More informationPUBLIC SERVICE CO. OF COLORADO ANNUAL REPORT CITY OF BOULDER, COLO. FOR THE YEAR ENDED DEC. 31, 2010
ANNUAL REPORT, COLO. FOR THE YEAR ENDED DEC. 31, 2010 METHODOLOGY & DISCLAIMERS THE FOLLOWING CALCULATIONS ARE USED TO DERIVE THE ESTIMATED AMOUNTS IN THIS REPORT: ELECTRIC AND GAS plant INVESTMENT OF
More information2017 Budget. Final. v.2. Passed by Resolution No December 6, 2016
Budget Final v.2 Passed by Resolution No. 2757 December 6, 2016 Blank Page Inserted Intentionally Public Utility District #1 of Lewis County Electric System Budget Final Budget Overview Electric System
More informationPJM Interconnection, L.L.C., Dkt. No. ER (Related to Docket Nos. ER , -1997, -2034)
American Electric Power 801 Pennsylvania Avenue N.W. Suite 320 Washington, DC 20004 AEP.com November 24, 2010 Kimberly D. Bose, Secretary Federal Energy Regulatory Commission 888 First Street, N.E., Room
More informationANNUAL RESULTS OF OPERATIONS REPORT
Class A Water U lity(annual Gross Revenue of 1,000,000 or more) Class B Water U lity(annual Gross Revenue between 200,000 and 999,999) Class C Water U lity(annual Gross Revenue less than 199,999) ANNUAL
More informationANNUAL RESULTS OF OPERATIONS REPORT
Class A Water Utility (Annual Gross Revenue of 1,000,000 or more) Class B Water Utility (Annual Gross Revenue between 200,000 and 999,999) Class C Water Utility (Annual Gross Revenue less than 199,999)
More information2009 PILS / CORPORATE TAX FILING
Page 1 of 44 29 PILS / CORPORATE TAX FILING Sheet Index: Title Page Input Information Summary Tax Rates & Exemptions 28 Adjusted Taxable Income 28 Taxable Income Additions 28 Taxable Income Deductions
More informationGREAT RIVER ENERGY ANNUAL OPERATING REPORT PERIOD ENDED 12/31/16
GREAT RIVER ENERGY ANNUAL OPERATING REPORT PERIOD ENDED 12/31/16 Form 12: Certification We hereby certify that the entries in this reparÿ a re in accordance with the accounts and other records of GRE and
More informationWages & Salary Allocation Factor 1 Transmission Wages Expense p b 18,901,839
Page 1 of 29 Arizona Public Service Company Formula Rate Appendix A Notes Instruction 2014 Shaded cells are input cells Allocators Wages & Salary Allocation Factor 1 Transmission Wages Expense p354.21.b
More informationStatement of Revenues, Expenses, and Changes in Net Position (Income Statement) Page 4
M E M O R A N D U M EUGENE WATER & ELECTRIC BOARD TO: FROM: DATE: August 26, 2016 SUBJECT: OBJECTIVE: Commissioners Simpson, Helgeson, Manning, Mital and Brown Sue Fahey, CFO; Susan Eicher, Accounting
More informationApplications for Participating Transmission Owner Status Attachment C - Transmission Revenue Requirement
Applications for Participating Transmission Owner Status Attachment C - Transmission Revenue Requirement The Transmission Revenue Requirement (TRR) for each Participating TO reflects the Participating
More informationCHUGACH ELECTRIC ASSOCIATION 1 STATEMENT OF OPERATIONS. Allowance for Funds Used During Construction. Total Cost of Electric Service (MTD Actual)
FINANCIAL REPORT MARCH 2014 STATEMENT OF OPERATIONS CATEGORY 2014 MTD ACTUAL 2014 MTD BUDGET Operating Revenue and Patronage Capital Fuel and Purchased Power Expense Power Production Expense Transmission
More informationGridLiance West Transco LLC (GWT) Formula Rate Index
(GWT) Formula Rate Index Appendix III Main Body of the Formula Attachment 1 Revenue Credit Worksheet Attachment 2 Cost Support Attachment 2a Cost Support Attachment 2b Cost Support Attachment 3 Incentives
More information2011 PILS / CORPORATE TAX FILING
Page 1 of 33 2011 PILS / CORPORATE TAX FILING Sheet Index: Title Page Input Information Summary Tax Rates & Exemptions Test Year Sch 8 and 10 UCC&CEC Test Year UCC and CEC Additions & Disposals Test Year
More informationANNUAL RESULTS OF OPERATIONS REPORT
Class A Water Utility(Annual Gross Revenue of 1,000,000 or more) Class B Water Utility(Annual Gross Revenue between 200,000 and 999,999) Class C Water Utility(Annual Gross Revenue less than 199,999) ANNUAL
More information2007 PILS / CORPORATE TAX FILING
Page 1 of 44 27 PILS / CORPORATE TAX FILING Sheet Index: Title Page Input Information Summary Tax Rates & Exemptions 26 Adjusted Taxable Income 26 Taxable Income Additions 26 Taxable Income Deductions
More informationGridLiance West Transco LLC (GWT) Formula Rate Index
(GWT) Formula Rate Index Appendix III Main Body of the Formula Attachment 1 Revenue Credit Worksheet Attachment 2 Cost Support Attachment 2a Cost Support Attachment 2b Cost Support Attachment 3 Incentives
More informationCITY OF BURLINGTON, VERMONT ELECTRIC DEPARTMENT. Financial Statements and Required Supplementary Information. June 30, 2017 and 2016
Financial Statements and Required Supplementary Information (With Independent Auditors Report Thereon) Table of Contents Page(s) Independent Auditors Report 1 2 Management s Discussion and Analysis Required
More informationAEP East Companies Transmission Cost of Service Formula Rate Utilizing Historic Cost Data for 2014 and Projected Net Plant at Year-End 2015
I & M Projected TCOS Page 1 of 48 AEP East Companies Transmission Cost of Service Utilizing Historic Cost Data for 2014 and Projected Net Plant at YearEnd 2015 Line Transmission No. Amount 1 REVENUE REQUIREMENT
More informationFirst Revised Sheet No. 2758L. Formula Rate - Non-Levelized Rate Formula Template For the 12 months ended 12/31/10 Utilizing FERC Form 1 Data VECTREN
Midwest ISO FERC Electric Tariff, Fourth Revised Volume No. 1 First Revised Sheet No. 2758L Superseding Original Sheet No. 2758L Formula Rate - Non-Levelized Rate Formula Template For the 12 months ended
More informationAEP East Companies Transmission Cost of Service Formula Rate Utilizing Historic Cost Data for 2012 and Projected Net Plant at Year-End 2013
Transmission Cost of Service Utilizing Historic Cost Data for 2012 and Projected Net Plant at YearEnd 2013 APCo Projected TCOS Page 1 of 36 Line Transmission No. Amount 1 REVENUE REQUIREMENT (w/o incentives)
More informationPART II Statutory Notifications (S.R.O.) GOVERNMENT OF PAKISTAN National Electric Power Regulatory Authority
PART II Statutory Notifications (S.R.O.) GOVERNMENT OF PAKISTAN National Electric Power Regulatory Authority NOTIFICATION Islamabad, the 25 th August, 2009 S.R.O. 1158(I)/2009. - In exercise of the powers
More informationCH ENERGY GROUP, INC. & CENTRAL HUDSON GAS & ELECTRIC CORP. QUARTERLY FINANCIAL REPORT. for the period ended
CH ENERGY GROUP, INC. & CENTRAL HUDSON GAS & ELECTRIC CORP. QUARTERLY FINANCIAL REPORT for the period ended MARCH 31, 2018 FINANCIAL STATEMENTS (Unaudited) QUARTER ENDED MARCH 31, 2018 TABLE OF CONTENTS
More informationDraft Financial Statements - Unaudited. For the Year Ended September 30, 2016 DRAFT
Draft Financial Statements - Unaudited For the Year Ended September 30, 2016 Financial Statements - Unaudited For the Year Ended September 30, 2016 Contents Overview and Basis of Accounting 2 Management
More informationENMAX POWER CORPORATION Distribution AUC Rule 005: ANNUAL OPERATIONS FINANCIAL AND OPERATING REPORTING For the Year Ended December 31, 2017 $M
ENMAX POWER CORPORATION Distribution AUC Rule 005: ANNUAL OPERATIONS FINANCIAL AND OPERATING REPORTING For the Year Ended December 31, 2017 $M TABLE OF CONTENTS Schedule Schedule Name Page Sch 1 Summary
More information2010 PILS / CORPORATE TAX FILING
Page 1 of 39 21 PILS / CORPORATE TAX FILING Sheet Index: Title Page Input Information Summary Tax Rates & Exemptions 29 Adjusted Taxable Income 29 Taxable Income Additions 29 Taxable Income Deductions
More informationRevenue Requirement Application 2004/05 and 2005/06. Volume 1. Chapter 2. Consolidated Revenue Requirements and Financial Schedules
Revenue Requirement Application 00/0 and 00/0 Volume 1 Chapter. Consolidated Revenue Requirements and Financial Schedules Table of Contents LIST OF FIGURES... -IV LIST OF TABLES... -IV LIST OF SCHEDULES...-V
More informationAPPENDIX X FORMULA FOR CALCULATING THE ALLOCATED COSTS TO THE CITIZENS BORDER EAST LINE RATE UNDER SDG&E S TRANSMISSION OWNER TARIFF
APPENDIX X FORMULA FOR CALCULATING THE ALLOCATED COSTS TO THE CITIZENS BORDER EAST LINE RATE UNDER SDG&E S TRANSMISSION OWNER TARIFF Appendix X sets forth the formula for calculating the Citizens Border
More informationLakes Region Water Company
BPS 1-1 Balance Sheet Assets and Other Debits 2014 2014 Preformed Line Year End Year End No. Account Title (Number) Balance Adjustments Balance (a) (b) (c) (d) (e) UTILITY PLANT 1 Utility Plant (101-106)
More informationConsolidated Edison, Inc. 6-Year Financials and Operating Statistics
Consolidated Edison, Inc. 6-Year Financials and Operating Statistics 2001-2006 Consolidated Edison, Inc. Annual Dividend Growth Dividends Per Share ($)* 2.12 2.14 2.18 2.20 2.22 2.24 2.26 2.28 2.30 2.32
More informationSchedule of Revenues, Expenses, and Changes in Net Position (Income Statement) Page 4
M E M O R A N D U M EUGENE WATER & ELECTRIC BOARD TO: Commissioners Simpson, Helgeson, Manning, Mital and Brown FROM: Sue Fahey, Chief Financial Officer; Susan Eicher, Accounting & Treasury Supervisor
More informationAEP East Companies Transmission Cost of Service Formula Rate Utilizing Historic Cost Data for 2014 and Projected Net Plant at Year-End 2015
KPCo Projected TCOS Page 1 of 34 AEP East Companies Transmission Cost of Service Utilizing Historic Cost Data for 2014 and Projected Net Plant at YearEnd 2015 Line Transmission No. Amount 1 REVENUE REQUIREMENT
More informationAEP East Companies Transmission Cost of Service Formula Rate Utilizing Historic Cost Data for 2013 and Projected Net Plant at Year-End 2014
KPCo Projected TCOS Page 1 of 34 AEP East Companies Transmission Cost of Service Utilizing Historic Cost Data for 2013 and Projected Net Plant at YearEnd 2014 Line Transmission No. Amount 1 REVENUE REQUIREMENT
More informationAEP East Companies Transmission Cost of Service Formula Rate Utilizing Historic Cost Data for 2013 and Projected Net Plant at Year-End 2014
KGPCo Projected TCOS Page 1 of 34 AEP East Companies Transmission Cost of Service Utilizing Historic Cost Data for 2013 and Projected Net Plant at YearEnd 2014 Line Transmission No. Amount 1 REVENUE REQUIREMENT
More informationBEARTOOTH ELECTRIC COOPERATIVE, INC. PROPOSED AMOUNT TO BE WRITTEN OFF $23, Proposed 2012 Write offs on Inactive Accounts (55 Accounts)
BEARTOOTH ELECTRIC COOPERATIVE, INC. PROPOSED AMOUNT TO BE WRITTEN OFF 212 $23,98.1 Proposed 212 Write offs on Inactive Accounts (55 Accounts) $15,474.38 Unretired Capital Credits available to offset write
More informationUNS Electric, Inc. Rates for Transmission Service For June 1, 2016 Through May 31, 2017 Data For Period Ending December 31, 2015
UNS Electric, Inc. Rates for Transmission Service For June 1, 2016 Through May 31, 2017 Data For Period Ending December 31, 2015 Mohave Total Line Division Division Company 1 2016 Revenue Requirements
More informationRegulatory Accounting Manual Volume 2
Regulatory Accounting Manual Volume 2 Project: Regulatory Accounting Report: (Draft for Discussion) Date Revised: 25 September 2007 1 Table of Contents 1 DEFINITIONS AND INSTRUCTIONS 4 1.1 OVERVIEW 4 1.2
More informationPORTLAND GENERAL ELECTRIC COMPANY AND SUBSIDIARIES CONSOLIDATED STATEMENTS OF INCOME
CONSOLIDATED STATEMENTS OF INCOME (Dollars in millions, except per share amounts) Revenues, net $ 2,009 $ 1,923 $ 1,898 Operating expenses: Purchased power and fuel 592 617 661 Generation, transmission
More information(1) (2) (3) (4) (5) 1 GROSS REVENUE REQUIREMENT (page 3, line 47) $
page 1 of 5 Attachment H Formula Rate NonLevelized Rate Formula Template For the 12 months ended 12/31/2018 Utilizing FERC Form 1 Data (1) (2) (3) (4) (5) Line Allocated No. Amount 1 GROSS REVENUE REQUIREMENT
More informationCH ENERGY GROUP, INC. & CENTRAL HUDSON GAS & ELECTRIC CORP. QUARTERLY FINANCIAL REPORT. for the period ended
CH ENERGY GROUP, INC. & CENTRAL HUDSON GAS & ELECTRIC CORP. QUARTERLY FINANCIAL REPORT for the period ended SEPTEMBER 30, 2017 FINANCIAL STATEMENTS (UNAUDITED) QUARTER ENDED SEPTEMBER 30, 2017 TABLE OF
More informationRate Formula Template (A) (B) (C) (D) (E) (F)
Page 1 of 4 Rate Formula Template (A) (B) (C) (D) (E) (F) Line Allocated No. Reference Worksheet/Note Amount A. NETWORK SERVICE 1 GROSS REVENUE REQUIREMENT Page 2, line 26, col. (F) $ 116,851,990 REVENUE
More informationCH ENERGY GROUP, INC. & CENTRAL HUDSON GAS & ELECTRIC CORP. QUARTERLY FINANCIAL REPORT. for the period ended
CH ENERGY GROUP, INC. & CENTRAL HUDSON GAS & ELECTRIC CORP. QUARTERLY FINANCIAL REPORT for the period ended MARCH 31, 2017 FINANCIAL STATEMENTS (Unaudited) QUARTER ENDED MARCH 31, 2017 TABLE OF CONTENTS
More informationMUNICIPALITY OF ANCHORAGE, ALASKA ELECTRIC UTILITY FUND. Financial Statements, Required Supplementary Information and Other Information
Financial Statements, Required Supplementary Information and Other Information (With Independent Auditor s Report Thereon) Table of Contents Financial Section: Independent Auditor s Report 1-3 Management
More informationAEPTCo subsidiaries in PJM Transmission Cost of Service Formula Rate Utilizing Historic Cost Data for 2013 and Projected Net Plant at Year-End 2014
Transmission Cost of Service Utilizing Historic Cost Data for 2013 and Projected Net Plant at YearEnd 2014 Projected TCOS Page 1 of 37 Line Transmission No. Amount 1 REVENUE REQUIREMENT (w/o incentives)
More informationPublic Utility District #1 of Ferry County Budget. December 17, 2018
Public Utility District #1 of Ferry County 2019 Budget December 17, 2018 The Approved Budget for 2019 reflects an overall reduction of approximately 3.2 percent from the 2018 Budget. The District is predicting
More informationAEPTCo subsidiaries in PJM Transmission Cost of Service Formula Rate Utilizing Historic Cost Data for 2014 and Projected Net Plant at Year-End 2015
AEPTCo subsidiaries in PJM Transmission Cost of Service Utilizing Historic Cost Data for 2014 and Projected Net Plant at YearEnd 2015 Projected TCOS Page 1 of 75 AEP OHIO TRANSMISSION COMPANY Line Transmission
More informationJune 13, Informational Filing Public Service Electric and Gas Company, Annual True-Up Adjustment Docket No. ER
Hesser G. McBride, Jr. Associate General Regulatory Counsel Law Department 80 Park Plaza, T5G, Newark, NJ 07102-4194 tel: 973.430.5333 fax: 973.430.5983 email: Hesser.McBride@pseg.com June 13, 2016 VIA
More informationUNS Electric, Inc. Rates for Transmission Service For June 1, 2017 Through May 31, 2018 For Period Ending December 31, 2016
UNS Electric, Inc. Rates for Transmission Service For June 1, 2017 Through May 31, 2018 For Period Ending December 31, 2016 Mohave Total Line Division Division Company 1 2017 Revenue Requirements $5,525,195
More informationAppendix 1 Duquesne Light Company Attachment H -17A Page 1 of 25 Formula Rate - Appendix A True-Up Notes FERC Form 1 Page # or Instruction 2017 Shaded cells are input cells Allocators 1 Transmission Wages
More information