B R I T IS H C O LU M B I A U T IL I T IE S C O M M I S S I O N O R D E R a N U M B E R G-133-97 SIXTH FLOOR, 900 HOWE STREET, BOX 250 TELEPHONE: (604) 660-4700 VANCOUVER, B.C. V6Z 2N3 BC TOLL FREE: 1-800-663-1385 CANADA FACSIMILE: (604) 660-1102 IN THE MATTER OF the Utilities Commission Act, R.S.B.C. 1996, Chapter 473 and IN THE MATTER OF the Special Direction to the British Columbia Utilities Commission by the Lieutenant Governor in Council through Order in Council No.Ê1510, dated DecemberÊ13, 1995 and An Application by Centra Gas British Columbia Inc. for Approval of its 1998/99 Revenue Requirements BEFORE: L.R. Barr, Deputy Chair ) and Acting Chair ) December 11, 1997 K.L. Hall, Commissioner ) P.G. Bradley, Commissioner ) O R D E R WHEREAS: A. On August 12, 1997, Centra Gas British Columbia Inc. ("Centra Gas") applied, pursuant to Section 23 of the Utilities Commission Act ("the Act") and Order in Council No.Ê1510, 1995, for approval of its 1996 actual revenue deficiency and its forecasted 1998 and 1999 revenue deficiencies ("the Application") for its Vancouver Island and Sunshine Coast service areas. The Application is a result of an increase in rate base which is required to serve new customers when actual rates are less than the cost of service; and B. The Commission, by Order No.ÊG-95-97, held a Pre-Hearing Conference in Vancouver on SeptemberÊ29, 1997 which allowed participants to discuss potential issues in the Application, procedural matters and timing of the Alternative Dispute Resolution (ÒADRÓ) or public hearing process; and C. Following input from the Pre-hearing Conference the Commission, by Order No.ÊG-102-97, scheduled an ADR process to commence on NovemberÊ17, 1997 and, if required, a public hearing would be set by way of a subsequent Order; and .../2
B R IT IS H C O L U M B I A U T IL I T I E S C O M M I S S I O N O R D ER N U M B E R G-133-97 2 D. On NovemberÊ25, 1997, the terms of a proposed Settlement Agreement were circulated to all Registered Intervenors, Centra Gas and the Commission. Comments were received from three registered intervenors. Mr. Bob Jones of the Elphinstone Community Association of Gibsons provided verbal support, the Consumers Association of Canada et al did not take issue with the Settlement Agreement and the Vancouver Island Gas Joint Venture ("the Joint Venture") provided conditional support; and E. The Joint Venture did not object to the Settlement Agreement subject to the toll setting and service that Centra Gas would provide to new industrial customers and an unresolved dispute between the Joint Venture and Centra Gas regarding the calculation of demand charges; and F. The Commission has reviewed the proposed Settlement Agreement and considers its approval to be in the public interest. NOW THEREFORE the Commission orders as follows: 1. Neither of the issues raised by the Joint Venture affect the Settlement Agreement. The Commission considers that the Joint VentureÕs concerns about toll setting and service to new industrial customers will be addressed in the Certificate of Public Convenience and Necessity applications that Centra Gas will file separately as contemplated in the Settlement Agreement. The Commission also considers the issue of demand charges to be a contract dispute between the Joint Venture and Centra Gas. 2. The Commission approves for Centra Gas the terms of the proposed Settlement Agreement, attached as AppendixÊI to this Order. 3. Centra Gas is to comply with all the terms and conditions of the Settlement Agreement.. 4. Centra Gas is to inform all customers of the Settlement Agreement's effect on rates to both Pioneer and New Customers. DATED at the City of Vancouver, in the Province of British Columbia, this ÊÊ 12thÊÊÊÊday of December, 1997. BY ORDER Original signed by: Lorna R. Barr Deputy Chair and Acting Chair Attachment Orders/CG-NSP-98/99RR
APPENDIX I to Commission Order No. G-133-97 Page 1 of 11 IN THE MATTER OF the Utilities Commission Act, RSBC 1996, c. 473, Section 23 - and IN THE MATTER OF the Special Direction to the British Columbia Utilities Commission issued by the Lieutenant Governor in Council through Order in Council 1510, dated December 13, 1995 - and IN THE MATTER OF an Application by Centra Gas British Columbia Inc. for approval of it's Forecast Revenue Requirement and Revenue Deficiency NEGOTIATED SETTLEMENT November 20, 1997 TO: British Columbia Utilities Commission 6th Floor, 900 Howe Street Vancouver, B.C. V6Z 2N3 Attention: Mr. W. J. Grant E xecutive Director. Regulatory Affairs & Planning On August 15, 1997, Centra Gas British Columbia Inc. ("Centra Gas" or the "Company") filed a Revenue Requirements Application (the "Application") with the British Columbia Utilities Commission (the "Commission"). The Application was for approval of Centra Gas' actual revenue requirement and revenue deficiency for 1996 and forecast revenue requirement and revenue deficiency for the test period 1998 and 1999. Customers were advised of the Application through bill messages and through public notices published in local community newspapers and in the Victoria Times Colonist, Vancouver Sun and Vancouver Province. Copies of the Application were made available for viewing in the Company's local offices and at the Utilities Commission office. A publicly advertised Pre-Hearing Conference to discuss the Application was held at the Commission's Offices in Vancouver on September 30, 1997, and a publicly advertised workshop was also held in the Commission's offices in Vancouver on October 17, 1997.
APPENDIX I to Commission Order No. G-133-97 Page 2 of 11 The Commission Staff issued information requests in writing on September 25, 1997, October 2, 1997, and October 22, 1997. In addition to these, Centra Gas also received information requests from the Elphinstone Community Association (ECA) on October 23, 1997, the Vancouver Island Gas Joint Venture (VIGJV) on November 5, 1997, and Beata Jahrig on November 12, 1997. Centra Gas responded to these information requests between October 15, 1997 and November 14, 1997. A settlement conference was held in Vancouver on November 17 and 18, 1997. In attendance were Commission Staff, representatives of the VIGJV, the ECA (November 17 only), BC Hydro and Centra Gas, all of whom participated in the settlement discussions. The following is a settlement arrived at between Centra Gas and the intervenors attending the settlement conference. This settlement was achieved with the participation of the Commission Staff. Centra Gas' actual revenue requirement and revenue deficiency for 1996 are accepted as filed except for the following: · The 1996/1997 deferral account Regulatory Expense has been reduced $61,300. Centra Gas and the above mentioned intervenors agree to the 1998 and 1999 forecast revenue requirement and revenue deficiency as shown on the Negotiated Settlement schedules 1 through 7 attached to and forming a part of this agreement. This agreed settlement includes the following adjustments to Centra Gas' Application: · Gross Operating, Maintenance and Administrative (OM&A) expense is to be reduced from $30,931,441 to $29,479,630 in 1998. The gross OM&A for 1999 is to be reduced from $32,261,131 to $30,376,220. · The capitalization of gross OM&A in 1998 shall be limited to a maximum of 24% of gross OM&A ($7,075,111). For 1999, capitalization of gross OM&A shall be limited to a maximum of 22% of gross OM&A ($6,682,768). · Legal fees associated with the 1998/1999 deferral account Regulatory Expense are limited to $6,100. · A deferral account will be established in which to record actual customer grants for residential new construction and conversion incentives estimated to be $505,638 in 1998 and $515,750 in 1999. Centra Gas will amortize these amounts the following year.
APPENDIX I to Commission Order No. G-133-97 Page 3 of 11 · In 1999, Centra Gas intends to conduct an external marine pipeline inspection. This inspection may be coordinated with similar work for BC Hydro or others to minimize mobilization costs. If the Company considers that the inspection must take place in that year, Centra Gas will justify the project to the Commission and record the cost of this marine inspection in a deferral account. Amortization of the deferral account will be over a one year period commencing in the year 2000 following the Commission's review of these costs. · Centra Gas will file with the Commission and intervenors it's business case supporting a consolidation of the Call Centre and Customer Enquiry staff, including $253,000 for the telephone system upgrade. · Centra Gas proposed a new office/warehouse facility in the Courtenay area for 1999. Centra Gas will file with the Commission a CPCN Application for approval of the proposed facility. The participants also agreed to the following items: · The settled OM&A expenses include an allowance for the cost of shared services provided by the corporate parent, Westcoast Energy Inc. which was established on a similar basis to the Commission's findings with respect to Pacific Northern Gas (PNG). The PNG amounts were established through Order G-92-97. · The settled level of gross OM&A, overhead capitalized, and allowed capital additions established above and supported by the attached schedules exclude any impact of the proposed two cogeneration facilities and other CPCN projects. The agreed upon level of gross OM&A, overhead capitalized and allowed capital additions can be adjusted to include, on a forecast basis, Commission approved cogeneration and CPCN projects. The cost of these CPCN projects is to be tracked in a construction work in progress account. If these projects result in a change in gross OM&A or capitalized overhead from the amounts approved in this settlement, Centra Gas will justify these changes in the CPCN applications. Copies of the CPCN applications will be distributed to all registered intervenors. · The Commission and participating intervenors agree to the two year test period put forth in this Revenue Requirement Application. · Centra Gas agrees that any compensation received from the insurance claim for the Qualicum and Indian River washout restoration projects will be applied as a credit to the restoration costs recorded in plant account 465. · Centra Gas agrees to arrange a public meeting on the Sunshine Coast to determine potential customer interest in receiving natural gas service.
APPENDIX I to Commission Order No. G-133-97 Page 4 of 11 The Company and the participants agree to hold confidential the discussions held on November 17 and 18, 1997. Agreement to this settlement is on a without prejudice basis. Any position taken or statement made during the discussions, by the participants or the Company, will not be made public or restrict in any way, positions taken in future proceedings should this settlement not be approved by the Commission, or in future proceedings concerning other applications. All of which is respectfully submitted. Dated at Victoria, this 20th day of November, 1997. Mr. Lindsay A. Hall Vice President, Finance, Centra Gas British Columbia Inc.
APPENDIX I to Commission Order No. G-133-97 Page 5 of 11 CENTRA GAS BRITISH COLUMBIA INC. 1998/99 REVENUE REQUIREMENT APPLICATION Schedule 11 NEGOTIATED SETTLEMENT REVENUE DEFICIENCY CONTINUITY SCHEDULE 1995 1996 1997 1998 1999 LINE Actual Actual Forecast Forecast Forecast Reference 1 Annual Revenue Deficiency 16,904,100 9,135,807 4,611,632 5,562,413 7,637,408 2 2 Deemed Preferred Share Dividend - 1996 0 1,195,503 1,195,503 1,195,503 1,195,503 3 Deemed Preferred Share Dividend - 1997 0 0 620,485 620,485 620,485 4 Deemed Prelerred Share Dividend - 1998 0 0 0 386,035 386,035 5 Deemed Preferred Share Dividend - 1999 0 0 0 0 466,322 6 Deemed Preferred Share Dividends 0 1,195,503 1,815,988 2,202,022 2,668,344 7 Sub-Total 16,904,100 10,331,310 6,427,619 7,764,436 10,305,753 8 Interim Revenue Deficiency Financing Rate (Note 1) 6.839% 5.836% 5.836% 5.836% 5.836% 9 Interim Revenue Deficiency Financing 576,565 301,447 187,545 226,551 300,701 10 Total Deferral 17,480,665 10,632,757 6,615,165 7,990,986 10,606,454 11 Cumulative Deferral 17,480,665 28,113,422 34,728,586 42,719,573 53,326,026 12 Note 1: Calculation of Rate: 5 Year Canada Bond Rate at June 30 of Following 13 Year Published by Bank of Canada Review 7.05% 5.32% 5.32% 5.32% 5.32% 14 Multiply by 58% 58% 58% 58% 58% 15 4.089% 3.086% 3.086% 3.086% 3.086% 16 Add 2.750% 2.750% 2 .750% 2.750% 2.750% 17 Equals Interim Revenue Deficiency Financing Rate 6.839% 5.836% 5.836% 5.836% 5.836%
APPENDIX I 1998/99 REVENUE REQUIREMENT APPLICATION Schedule 2 to Commission Order No. G-133-97 NEGOTIATED SETTLEMENT REVENUE REQUIREMENT Page 6 of 11 1996 1997 Negotiated 1996 Negotiated 1997 1998 1999 LINE Settlemen t Actual Settlement Outlook Forecast Forecast Reference 1 Cost of Sales 23,079,000 $23,078,708 $21,895.299 $24,498,266 $27,343,206 $28,958,546 52-55 2 Gross O&M Expenses 28,900,000 28,900,000 29,070,000 29,070,000 29,479,630 30,376,220 56 3 Operating and Maintenance Cap. (9,300,000) (9,300,000) (7,884,000) (7,884,000) (7,075,111) (6,682,768) 56 4 Direct Charges and Allocations to Affiliates (753,436) (753,436) (766,334) (530,079) (348,943) (184,423) 60 5 B.C. Gas Wheeling Charge 3,694,000 3,693,800 3,859,876 3,859,876 3,794,521 3,794,521 49-50 6 Depreciation 14,283,943 14,286,774 15,063,927 15,063,437 15,839,773 17,047,066 9-12 7 Amortization - CIAC (6,301,907) (6,301,907) (6,300,548) (6,300,548) (6,301,548) (6,303,088) 13-16 8 Municipal Taxes 3,943,376 3,943,072 4,418,000 4,204,132 4,706,393 5,041,729 18 Amortization of Deferreds 9 Financing Costs 251,121 253,872 251,121 253,872 253,872 253,872 26-27 10 Unamortized Manufactured Gas Plant 0 0 157,140 157,140 314,280 314,280 26-27 11 NGV Conversion Expense 0 0 0 4,286 12,619 32,619 26-27 12 Generic Ut. Systems Ext. Hrg Costs 15,046 15,046 15,046 15,046 0 0 26 13 Regulatory Expense 186,500 166,199 186,500 104,899 153,500 153,500 26-27 14 PCEC Start Up Costs 43,900 43,900 43,900 43,900 43,900 43,900 26-27 15 Dfd Joint Venture Refund(G-104-93) 60,585 60,585 0 0 0 0 26 16 Gaa Supply Management Study 0 0 0 0 17,630 17,630 27 17 Intergrated Resource Plan Expenses 8,000 7,926 8,000 7,926 0 0 26 18 Customer Grants and Incentives 0 0 0 0 0 505,638 27 19 Marine Inspection 0 0 0 0 0 0 27 20 Large Corporations Tax 755,260 791,438 802,599 971,798 1,056,306 1,091,789 68 21 British Columbia Capital Tax 1,870,395 1,925,215 1,914,583 632,615 1,408,409 1,455,718 69 22 Motor Fuel Tax 368,978 366,780 370.900 370.900 382,621 391,181 49-50 23 Provincial Sales Tax 19,000 19,322 20,002 20,002 20,152 20,702 49-50 24 Proposed Return on Rate Base 29,632,480 29,542,612 31,735,894 30,995,027 32,050,153 34,151,503 28-31 25 Less Special Direction Provision (1,867,000) (1,867,000) (1,867,000) (1,867,000) (1,867,000) (1,867,000) 26 Income Tax Expense 0 0 0 0 0 0 67 88,889,241 88,872,905 92,994,905 93,691,493 101,284,361 108,613,134 Reconciliation of Revenue Requirement 27 Natural Gas Sales Revenue 58,741,000 58,740,967 61,406,179 68,055,071 74,933.372 80,682,414 32-39 28 Transportation Revenue 14,427,000 14,427,369 14,326,177 14,447,768 13,881,584 13,262,590 48 29 Royalty income 6,127,000 5,715,592 5,583,300 5,827,944 6,148.262 6,248,744 51 30 Other Revenue 411,000 853,170 349,07 9 749,079 758,729 781,977 51 31 Total Revenue 79,706,000 79,737,098 81,664,735 89,079,862 95,721,948 100,975.726 32 Revenue (Surplus)/Deficiency 9,183,241 9,135,807 11,33O,170 4,611,63 2 5,562,413 7,637,408 33 Total Revenue Requirement 88,889,241 88,872.905 92,994,905 93,691,493 101,284,361 108,613,134
APPENDIX I to Commission Order No. G-133-97 Page 7 of 11 CENTRA GAS BRITISH COLUMBIA INC. 1998/99 REVENUE REQUIREMENT APPLICATION Schedule 3 NEGOTIATED SETTLEMENT RATE BASE 1996 1997 Negotiated 1996 Negotiated 1997 1998 1999 LINE S ettlement Actual Settlement Outlook Forecast F orecast R eference 1 Beginning of Year 623,802,878 623,802,878 657,538,278 657,538,278 686,796,209 732,625.960 5-8 2 End of Year 657,538,278 657,538,278 687,415,064 686,796,209 732,625,960 759,778.324 5-8 3 13 Month Average Adjustment - V1 Compressor 0 0 0 0 (5,919,231 ) 0 4 Average Balance - Mid-Year 640,670,57 8 640.670.578 672,476,671 6 72,167.244 703,791,854 746,202,14 2 ACCUMULATED DEPRECIATION 5 Beginning of Year (28,337,307)(28,337,307)(41,644,074)(41,644.074)(59,170,167)(74,146,504) 9-12 6 End of Year ( 41,644,074 )(4 1,644,07 4)( 59,170,167 )( 59,170,16 7)( 74,146,504 ) (90,208,134 ) 9-12 7 Average Balance - Mid Year ( 34,990,691 )(3 4,990,69 0)( 50,407,121 )( 50,407,120 )(6 6,658,33 6) (82,177,319 ) 8 NET MID-YEAR PLANT IN SERVICE 605,679,888 605,679,888 622,069,551 621,760.123 637,133,518 664,024,823 MID-YEAR ALLOCATED NET COMMON PLANT 9 Centra Gas Fort St John Inc. (373,128) (373,128) (348,130) (346,130) 0 0 10 Centra Gas Whistler Inc. (128,000) (128,000) (128,000) (128,000) (128.000 ) (128,000) 11 Centra Gas Port Alice Inc. (8,600 ) (8,600 ) (8,600 ) (8,600 ) (8.600 ) (8,600) 12 (509,728) (509,728) (482,730) (482,730) (136,600) (138,600) 13 MID-YEAR CONTRIBUTIONS (287,793,904)(287,793,904)(281,483,710)(281,483,710)(275,246,162)(269,020,844) 13-16 14 WORKING CAPITAL 8,080,57 1 1l,034,48 4 10,432,197 13,657,54 4 15,387,186 15,434,51 0 17 15 MID-YEAR RATE BASE 3 25,456,827 328,410,740 350,535,30 8 3 53,451,227 377,137,94 2 410,301,889 Thirteen Month Adjustment: 16 Total Project Costs for Compressor Addition 17,100,000 17 13 Month Average X 2 Months (Nov & Dec) 2,630,769 18 Mid Year Effect of Compressor Addition 8,550,000 19 Adjustment (Line 17 - Line 18) (5,919,231 )
APPENDIX I to Commission Order No. G-133-97 Page 8 of 11 CENTRA GAS BRITISH COLUMBIA INC. 1998/99 REVENUE REQUIREMENT APPLICATION Schedule 4 NEGOTIATED SETTLEMENT WORKING CAPITAL SUMMARY 1996 1997 1998 1998 LINE Actual Outlook F orecast Forecast Reference 1 Cash Working Capital Requirements $1,774,264 $2,013,969 $2,127,499 $2,280,787 18 2 Inventory - Materials and Supplies 2,652,351 2,792,039 3,631,538 3,631,538 19 3 Line Pack/Gas Storage 1,592,454 1,491,757 1,268,769 1,268,769 20 4 Employee Housing Loans 186,077 130,385 103,462 116,923 21 5 Finance Contracts Receivable 3,483,728 3,713,621 3,399,660 3,399,660 22 6 Customer Deposits (95,327) (103,921) (103,921) (103,921) 23 7 Refundable Contribution (427,147) (459,186) (459,186) (459,186) 24 8 Employee Witholdings (962,520 ) ( 1,002,10 0) (1 ,002,100 ) ( 1,002,100 ) 25 8 ,203,882 8,576,563 8,965,721 9,132,47 1 Deferred Expenses, Mid-Year: 10 Financing Costs 962,068 1,797,199 1,543,327 1,289,455 26-27 11 Unamortized Manufactured Gas Plant 0 1,492,828 2,828,516 2,514,236 26-27 12 NGV Conversion Costs 0 12,857 44,405 96,786 26-27 13 Direct Purchase Administration Costs 4,774 4,774 4,774 4,774 26-27 14 Pipe Sampling Survey 18,829 0 0 0 26 15 Generic Utility Systems Extension Hearing Costs 22,568 7,523 0 0 26 16 Regulatory Expense 55,878 55,878 76,750 76,750 26~27 17 PCEC Start Up Costs 1,732,230 1,688,330 1,644,430 1,600,530 26-27 18 Deferred Joint Venture Refund (G-104-93) 30,293 0 0 0 26 19 Gas Supply Management Study 0 17,630 26,444 8,815 26-27 20 Intergrated Resource Plan Expenses 3,963 3,963 0 0 26 21 Customer Grants and Incentives 0 0 252,819 510,694 27 22 Marine Inspection 0 0 0 200,000 27 23 Total 2,830,602 5,080,981 6,421,46 5 6,302,039 24 Total Working Capital Requirements 11,034,484 13,657,544 15,387,186 15,434,510
APPENDIX I to Commission Order No. G-133-97 Page 9 of 11 CENTRA GAS BRITISH COLUMBIA INC. 1998/99 REVENUE REQUIREMENT APPLICATION Schedule 6 NEGOTIATED SETTLEMENT Deferred Expenses Account Opening Ending Mid-Year Line Yea r Number Description Balance Additions A mortization Interest B alance Balance 1996: 1 17001 Financing Costs $0 $2,178,007 ($253,872) $0 $1,924,135 $962,068 2 17924 Direct Purchase Administration Costs 4,774 0 0 4,774 4,774 3 17930 Pipe Sampling Survey 37,658 (37,658) 0 0 0 18,829 4 17940 Generic Utility Systems Extension Hearing Cost 30,091 0 (15,046) 0 15,046 22,568 5 17945 1996/97 Regulatory Expense 0 277,956 (166,199) 0 111,756 55,878 6 17959 PCEC Start Up Costs 1,754,180 0 (43,900) 0 1,710,280 1,732,230 7 17960 Deferred Joint Venture Refund(G-104-93) 60,585 0 (60,585) 0 0 30,293 8 17920 Intergrated Resource Plan Expenses 0 15,851 (7,926 ) 0 7,926 3,963 $1,887,288 $2,434,15 6 ( $547,527 ) $ 0 $ 3,773,916 $ 2,830,602 1997: 10 17001 Financing Costs 1,924,135 0 (253,872) 0 1,670,263 1,797,199 11 17500 Unamortized Manufactured Gas Plant 0 3,142,795 (157,140) 0 2,985,655 1,492,828 12 17501 NGV Conversion Expense 0 30,000 (4,286) 0 25,714 12,857 13 17924 Direct Purchase Administration Costs 4,774 0 0 0 4,774 4,774 14 17940 Generic Utility Systems Extension Hearing Cost 15,046 0 (15,046) 0 0 7,523 15 17945 1996/97 Regulatory Expense 111,756 (6,857) (104,899) 0 0 55,878 16 17959 PCEC Start Up Costs 1,710,280 0 (43,900) 0 1,666,380 1,688,330 17 17964 Gas Supply Management Study 0 33,942 0 1,317 35,259 17,630 18 17920 Intergrated Resource Plan Expenses 7,926 0 (7,926 ) 0 0 3,963 19 $ 3,773,91 6 $ 3,199,880 ( $587,068 ) $1,317 $6,388,04 6 $5,080,981
APPENDIX I to Commission Order No. G-133-97 Page 10 of 11 CENTRA GAS BRITISH COLUMBIA INC. 1998/99 REVENUE REQUIREMENT APPLICATION Schedule 6 NEGOTIATED SETTLEMENT Deferred Expenses Account Opening Ending Mid-Year Lin e Year N umber D escription Balanc e Additions Amortization Interest B alance Balance 1998: 1 17001 Financing Costs 1,670,263 0 (253,872) 0 1,416,391 1,543,327 2 17500 Unamortized Manufactured Gas Plant 2,985,655 0 (314,280) 0 2,671,376 2,828,516 3 17501 NGV Conversion Expense 25,714 50,000 (12,619) 0 63,095 44,405 4 17924 Direct Purchase Administration Costs 4,774 0 0 0 4,774 4,774 5 17945 1998/99 Regulatory Expense 0 307,000 (153,500) 0 153,500 76,750 6 17959 PCEC Start Up Costs 1,666,380 0 (43,900) 0 1,622,480 1,644,430 7 17964 Gas Supply Management Study 35,259 0 (17,630) 0 17,630 26,444 8 Customer Grants and Incentives 0 505,638 0 0 505,638 252,81 9 $ 6,388,046 $862,63 8 ( $795 800 ) $ 0 $ 6,454,883 $ 6,421,465 1999: 10 17001 Financing Costs 1,416,391 0 (253,872) 0 1,162,519 1,289,455 11 17500 Unamortized Manufactured Gas Plant 2,671,376 0 (314,280) 0 2,357,096 2,514,236 12 17501 NGV Conversion Expense 63,095 100,000 (32,619) 0 130,476 96,786 13 17924 Direct Purchase Administration Costs 4,774 0 0 0 4,774 4,774 14 17945 1998/99 Regulatory Expense 153,500 0 (153,500) 0 0 76,750 15 17959 PCEC Start Up Costs 1,622,480 0 (43,900) 0 1,578,580 1,600,530 16 17964 Gas Supply Management Study 17,630 0 (17,630) 0 0 8,815 17 Customer Grants and Incentives 505,633 515,750 (505,638) 0 515,750 510,694 18 Marine Inspection 0 400,000 0 0 400,000 200,00 0 19 $ 6,454,863 $ 1,015,75 0( 1,321,438 ) $0 $6 ,149,195 $ 6,302,039
APPENDIX I to Commission Order No. G-133-97 1998/99 REVENUE REQUIREMENT APPLICATION Schedule 7 Page 11 of 11 NEGOTIATED SETTLEMENT OPERATING & MAINTENANCE EXPENSES - SUMMARY 1997 1996 Adjusted 1998 1999 LINE S ettlement S ettlement Forecast Forecast Referenc e OPERATING 1 Manufactured Gas $0 $0 $0 $0 57 2 Transmission 1,532,772 1,776,167 1,717,066 2,116,749 57 3 Distribution 6,778,817 7,130,612 7.508,904 7,813,003 57 4 General Operation 4,649,080 4,729,868 4,751,45 9 5,038,053 57 5 TOTAL OPERATING 12,960,669 13,636,647 13,977,429 14,967,805 ADMINISTRATION & GENERAL 6 Sales Promotion 3,332,545 3,686,497 3,742,002 3,314,106 58 7 Customer Accounting 2,063,282 2,332,209 2,617,685 2,855,514 58 8 Administration & General 9,782,85 4 8,420,183 8,437,914 8,731,005 58 9 TOTAL ADMINISTRATION & GENERAL 15,178,681 14,438,889 14,797,600 15,400,624 MAINTENANCE EXPENSE 10 Transmission 908,958 893,292 1,537,536 1,221,336 59 11 Distribution 508,832 519,014 613,761 666,148 59 12 General 38 4 392 5,115 5,217 59 13 TOTAL MAINTENANCE EXPENSE 1,418,174 1,412,698 2,156,412 1,892,702 14 NEGOTIATED SETTLEMENT ADJUSTMENT (657,524 ) (418,23 4) ( 1,451,81 1) (1 ,884,911 ) 15 TOTAL GROSS EXPENSES 28,900,00 0 29,070,000 29,479,630 3 0,376,220 CAPITALIZATION 16 Gross O & M Capitalization (9,300,000 ) (7,884,000 ) (7,075,11 1) (6,682,768 ) 17 TOTAL O & M CAPITALIZATION ( 9,300,000 ) (7,884,00 0) (7,075,11 1) (6,682,768 ) NET CHARGES TO AFFILIATES 19 Fort St John (1) (561,847) (334,656) (168,135) 0 60 20 Whistler (176,483) (180,015) (166,534) (169,863) 60 21 Port Alice (15,10 6) (15,408 ) (14,274 ) (14,560 ) 60 22 TOTAL CHARGES TO AFFILIATES (753,436 ) (530,079 ) (348,943 ) (184,42 3) 23 TOTAL NET DIRECT O & M EXPENSES $ 18,846,564 $2 0,655,92 1 $ 22,055,57 6 $ 23,509,03 1 24 Average Number of Customers 43,139 49,761 57,672 64,460 25 Average Gross Expenses Per Customer 670 584 511 471 26 Average Net Direct Cost Per Customer 437 415 382 365 (1) Adjusted to reflect the sale of Centra Gas Fort St. John Inc.
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