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Home My WebLink AboutO 024 --- ~, Image Project Order File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. _O dlf Order File Identifier Organizing (done) D Two-sided ""llfllll ""1111 D Rescan Needed 1111/11111111111111 RESCAN DIGITAL DATA OVERSIZED (Scannable) D Maps: D Color Items: 0 Greyscale Items: D Diskettes, No. D Other, Noffype: D Other Items Scannable by a Large Scanner 0 Poor Quality Originals: 0 Other: OVERSIZED (Non-Scannable) D Logs of various kinds: NOTES: BY: ~ Helen Maria D Other:: Date: ~ .1-5.04 151 ~^- IIIIIIIIIIII~IIIII Project Proofing ~fn Helen Maria Date:Cf. ¥'O~ IS/~ Scanning Preparation 1LL- x 30 = 90 + /8 BY: Helen Maria Production Scanning 1111111111111111111 Stage 1 Page Count from Scanned File: /°1 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: v- YES NO BY: Helen Maria /~ Date: 151 If NO in stage 1, page(s) discrepancies were found: YES Helen Maria '~/.2i? /?J i Date: Scanning is complete at this point unless rescanning is required. ~ I ~ ~ ~ 1111/11111111111111 Stage 1 BY: NO 151 (111111111111111111 ReScanned BY: Helen Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 8/24/2004 Orders File Cover Page.doc ~ ~ INDEX OTHER ORDER NO. 24 REGULATORY COST CHARGES FOR FISCAL YEAR 2004 1. August 13, 2003 Working copies ofInvoice and Notice of Estimated Regulatory cost charge for 8/13/03 public meeting 2. October I, 2003 Explanation of Regulatory Cost Charge Changes and Notice 3. October I, 2003 Meeting Agenda and backup and Minutes 4. October 3, 2003 Notice of hearing, Affidavit of pub lication, bulk mailing list for the Anchorage Daily News 5. November 4, 2003 Sign in sheet 6. November 4, 2004 Transcript Other #24 Order Establishing fiscal year 2004 Regulatory Cost ,r--, /"""'., STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West Seventh Avenue, Suite 100 Anchorage Alaska 99501-3539 Re: Regulatory Cost Charges for Fiscal Year 2004. ) ) Other No. 024 November 4, 2003 ORDER ESTABLISHING FISCAL YEAR 2004 REGULATORY COST CHARGES IT APPEARING THAT: 1. On October 1, 2003, pursuant to 20 AAC 25.615 the Commission gave written notice of proposed fiscal year 2004 regulatory cost charges under AS 31.05.093 to operators subject to those charges. 2. Notice of public hearing on the proposed fiscal year 2004 regulatory cost charges was published in the Anchorage Daily News on October 3,2003. 3. A public hearing was held at the Commission's offices on November 4,2003. FIND IN GS: 1. The appropriation, other than of federal receipts, made for the operating costs of the Commission for this fiscal year is $4,162.900.00 2. The lapsed amount of the fiscal year 2003 appropriation that is included in this fiscal year's appropriation under AS 31.05.093(d) is $469,027.42. 3. A reasonable estimate of the total fees to be collected under AS 31.05.090 during this fiscal year is $20,000.00. 4. The amounts constituting VOP under 20 AAC 25.605(a) for the operators subject to a fiscal year 2004 regulatory cost charge are as follows: Aurora Gas, LLC. BP Exploration (Alaska) Inc. ConocoPhillips Alaska, Inc. Forest Oil Corporation Marathon Oil Company 100,842 1,919,138,727 452,672,899 1,671,589 6,558,673 Bbl Bbl Bbl Bbl Bbl .~ ~ RCC FY 2003 Page 2 of 3 November 4, 2003 North Slope Borough Phillips Petroleum Co. Unocal XTO Energy Inc. 234,080 9,097,757 66,515,440 4,241,237 Bbl Bbl Bbl Bbl CONCLUSIONS: 1. The Commission chooses not to include in its calculation of fiscal year 2004 regulatory cost charges an allowance to cover charges that the Commission may be unable to collect. 2. Using the formula set out in 20 AAC 25.605, the fiscal year 2004 regulatory cost charges for the operators subject to those charges are as follows: Aurora Gas, LLC. BP Exploration (Alaska) Inc. ConocoPhillips Alaska, Inc. Forest Oil Corporation Marathon Oil Company North Slope Borough Phillips Petroleum Co. Uocal XTO Energy Inc. $150.59 $2,865,857.41 $675,978.22 $2,496.19 $9,794.09 $349.55 $13,585.72 $99,327.77 $6,333.46 3. Appropriate payments dates under 20 AAC 25.620 are November 30, 2003, for the second quarter of the fiscal year; January 15,2004, for the third quarter, and March 15,2004, for the fourth quarter. NOW THEREFORE IT IS ORDERED that the operators listed in Conclusion 2 of this order shall pay their respective regulatory cost charges set out therein, less their respective estimated fiscal year 2004 regulatory cost charges that have previously been paid, by paying one third of the amount owed by each payment date set out in Conclusion 3 of this order or sooner. r--- RCC FY 2003 Page 3 of 3 .-, November 4, 2003 DONE at Anchorage, Alaska and dated November 4, 2003. ~~:::: " :: . A ion Commission anie T. Seam nt, Jr., Commissioner Alaska Oil and Gas Conservation Commission !:::6nCh' t:.f: ~ Alaska Oil and Gas Conservation Commission AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23rd day following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the lO-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30-day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., loth day after the application for rehearing was filed). Citgo Petroleum Corporation PO Box 3758 Tulsa, OK 74136 Kelly Valadez Tesoro Refining and Marketing Co. Supply & Distribution 300 Concord Plaza Drive San Antonio, TX 78216 Jerry Hodgden Hodgden Oil Company 408 18th Street Golden, CO 80401-2433 Kay Munger Munger Oil Information Service, Inc PO Box 45738 Los Angeles, CA 90045-0738 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 David Cusato 600 West 76th Ave., #508 Anchorage, AK 99518 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 Cliff Burglin PO Box 131 Fairbanks, AK 99707 North Slope Borough PO Box 69 Barrow, AK 99723 ~ Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 Robert Gravely 7681 South Kit Carson Drive Littleton, CO 80122 Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 Samuel Van Vactor Economic Insight Inc. 3004 SW First Ave. Portland, OR 97201 Ciri Land Department PO Box 93330 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Jack Hakkila PO Box 190083 Anchorage, AK 99519 Penny Vadla 399 West Riverview Avenue Soldotna, AK 99669-7714 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 ~ David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 John Levorsen 200 North 3rd Street, #1202 Boise, ID 83702 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle, WA 98119-3960 Schlumberger Drilling and Measurements 3940 Arctic Blvd., Ste 300 Anchorage, AK 99503 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 James Gibbs PO Box 1597 Soldotna, AK 99669 Richard Wagner PO Box 60868 Fairbanks, AK 99706 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 /lJp t! Ø- / / 1/Ø3 Other 24 ~ r--, Subject: Other 24 Date: Tue, 04 Nov 200309:18:26 -0900 From: jody - colombie@admin.state.ak.us Organization: Alaska Oil and Gas Conservation Commission To: Cynthia B Mciver <bren - mciver@admin.state.ak.us> Please add to web site. Jody ! Name: I Othcr24.doc ~ 1 Other24.doc Type: WINWORD File (applicationlmsword) Encoding: base64 1 of! 11/4/20039:18 AM Other 24 r-- /""- Subject: Other 24 Date: Tue, 04 Nov 2003 09:17:58 -0900 From: jody - colombie@admin.state.ak.us Organization: Alaska Oil and Gas Conservation Commission lof2 11/4/20039:18 AM Other 24 ~ ~ Order Establishing Fiscal 2004 Regulatory Cost Charges. -,...-..---...........-.....................................................................""""""""'--""'-""'-""""""""----"'-"""--""""'-""""........ ......... . . .' . I ¡ 'amc: Othcr24.pdf ! I CJOthcr~4.pdf T)'pc: Acrobat (application pdt): Encoding: base64 2 of2 11/4/2003 9: 18 AM #6 /"" 1 2 3 4 5 6 7 8 9 10 11 12 13 r-., 14 15 16 17 18 19 20 21 22 23 24 25 "",,--, , In Re: ALASKA OIL AND GAS CONSERVATION COMMISSION PUBLIC HEARING 2004 Regulatory Cost Charges TRANSCRIPT OF PROCEEDINGS Anchorage, Alaska November 4, 2003 9:00 o'clock a.m. COMMISSIONERS: SARAH PALIN, Chairperson DAN SEAMOUNT RANDY RUEDRICH * * * (\ * * METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 C¡ R \ G \ \~ A \ ------- 1 2 3 4 5 6 7 8 9 10 11 12 13 ~-. 14 15 16 17 18 19 20 21 22 23 24 25 --. ~ TABLE OF CONTENTS INTRODUCTION BY COMMISSIONER PALIN Page 2 END OF PROCEEDINGS Page 6 * * * * METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 .r-. 1 2 3 4 5 6 7 8 9 10 11 12 13 ~. 14 15 16 17 18 19 20 21 22 23 24 25 ~. 1 PRO C E E DIN G S (On record) CHAIR PALIN: We'll call this meeting to order. Today is Tuesday, November 4th, 2003, the time is approximately 9:03 a.m. We're at the AOGCC offices at 333 West Seventh Avenue, Suite 100. The subject of today's hearing is a proposed Regulatory Cost Charges for fiscal year '04. First let me introduce my fellow Commissioners. To my left is Randy Ruedrich. To my right is Dan Seamount. I'm Sarah Palin, and to my very far right is Jan Scott from Metro Court Reporting. This proceeding is being recorded and transcribed. If anybody wishes a copy of the transcript, they may ask for copies directly from Metro. On October 1st, 2003, notice of Proposed Regulatory Cost Charges for fiscal year '04 were sent by certified mail to persons subject to the Regulatory Cost Charge, under Alaska Statute 31.05.093. Notice of the public hearing was published in the Anchorage Daily News on October 3rd, 2003, and the Commission has received no comment and no request to revise the proposed Regulatory Cost Charges. These proceedings will be held in accordance with 20.AAC.25540. And in the audience currently, Linda Berg, our administrative manager, and Jody Colombie. And also, our METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 r-.. 1 2 3 4 5 6 7 8 9 10 11 12 13 ",-. 14 15 16 17 18 19 20 21 22 23 24 25 .r-. ! sign-in sheet shows just AOGA representative Teresa Rockhill. Thank you. I see no other members from the public out there, and we don't think there are anymore in the lobby, or do we? Jody is going to check. All right. Thanks. No? Any persons present who wish to make comments or provide testimony? Hearing and seeing none, do either of you Commissioners, have any comments or additions on the Regulatory Cost Charges issue? COMMISSIONER RUEDRICH: The only comment I'll make is I think the staff has done a very good job putting the cost charge together, and I have reviewed it and I believe it to be correct. CHAIR PALIN: Commissioner Seamount, anything? COMMISSIONER SEAMOUNT: I would like to say that -- or make note that our budget has gone down slightly from last year, and I think that we should work hard over the next year to make more significant and appropriate reductions in the budget. CHAIR PALIN: Well said. COMMISSIONER RUEDRICH: I fully agree. CHAIR PALIN: Okay. All right. And I guess we're ready for a motion, and I'll make that motion. I move that we adopt the Regulatory Cost Charges for fiscal year '04, by operator as set out in the Notice of METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 ",-. 3 4 5 6 7 8 9 10 11 12 13 ./""",-. 14 15 16 17 18 19 20 21 22 23 24 25 .,--.. . .ê. 1 Proposed Regulatory Cost Charges for fiscal year 2004, that 2 was signed on October 1st, 2003. And I move that we order each operator to pay the respective regulatory cost charges, less their respective estimated fiscal year '04 regulatory cost charges that have previously been paid, by paying one- third of the amount owed on November 30th, 2003, for the second quarter of the fiscal year; and January 15th, 2004, for the third quarter; and March 15th, 2004, for the fourth quarter. Is there a second to that motion? COMMISSIONER RUEDRICH: So moved. CHAIR PALIN: We have to take a vote on this record. Is there any more discussion? Hearing no more Okay. discussion, Mr. Ruedrich, how do you vote? COMMISSIONER RUEDRICH: Affirmative. CHAIR PALIN: Mr. Seamount? COMMISSIONER SEAMOUNT: Yes. CHAIR PALIN: And I vote yes also. And we'll follow that up then with a written order. Is there anything further for today's hearing? Just approval of our last open meeting minutes, which we've already approved in our last meeting. Then there is nothing Okay. else. We can adjourn in these proceedings and we'll go off record. METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 .§. .r- 1 2 3 4 5 6 7 8 9 10 11 12 13 ,,-.. 14 15 16 17 18 19 20 21 22 23 24 25 ,,---.. (Off record) * * * END OF PROCEEDINGS * * * METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 ,,-.. 1 2 3 4 5 6 7 8 9 10 11 12 13 ,,-.. 14 15 16 17 18 19 20 21 22 23 24 25 r---... 1 C E R T I F I CAT E SUPERIOR COURT ) ) ss. ) STATE OF ALASKA I, Janice S. Scott, Notary Public in and for the State of Alaska, do hereby certify: THAT the annexed and foregoing pages numbered 2 through 5 contain a full, true and correct transcript of the Public Hearing before the Alaska Oil and Gas Conservation Commission, taken by Janice S. Scott and transcribed by Janice S. Scott: THAT the Transcript has been prepared at the request of the Alaska Oil and Gas Conservation Commission, 333 West Seventh Avenue, Anchorage, Alaska, DATED at Anchorage, Alaska this 17th day of November, 2003. SIGNED AND CERTIFIED TO BY: '7 // I' \. ¿.¿t.e (-" .",." (1~"'--¿-7;Z-ct':. Janicé'S:. Scott NotarY-in and for Alaska My Commission Expires: 2/02/04 METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 {'-\ ~ ~~~1íŒ fffi~ ~~~~æfÆ 4 I .4SIIAQ,1I., A5D GAS CONSBRVADON COJDIISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. AlASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF REGULATORY COST CHARGE To: Aurora Gas LLC A~tion: Ed Jones, Vice President 10333 Richmond Avenue, Suite 710 Houston, TX 77042 YOU ARE NOTIFIED that, ,pursuant to AS 31.05.093 and 20 MC 25.615, the Alaska Oil and Gas ConservationConunission has determined your regulatory cost charge and payment dates for the current fiscal year 2004. A Copy of the Commission's order determining regulatory cost charges and payll1ent dates is enclosed. Your regulatory cost charge is $150.59. You previously Paid an estimated regulatory cost charge of$69.66,.leaving It balance of $80.93. One third of this balánce, $26.98, is due no later than November 30, 2003. A second payment of $26.98 is due no later than January 15, 2004. A third paYl11ent of$26.9Tis dUe no later than March 15,2004. Under 20 MC 25.620, you are required to pay each payment by its specified payment date. '(Note:' you may prepay all or part of the regulatory costchargê at any time.) Plea$e make your checks payable to: State of Alaska! AOGCC Mail or deliver payments to: AOGCC 333 West 7th Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, pl~ call the Commission for instructions. Your regulatory cost charge has been calculated on the basis described in the October 1, 2003, Notice offroposed Regulatory Cost Charges for Fiscal year 2004. Date: November 4, 2003 ... (\ ,^, ~1f fÆ 1T. ŒlID ~ fÆ ~ fÆ ~[\ fÆ A. .f.SIiA OIL AlVD GAS CONS.RVADOlV COJDDSSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ÁLASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF REGULATORY COST CHARGE BP Exploration (Alaska), Inc. Attention: Steve Marshall, President P.O. Box 196612 Anchorage,Aù( 99519-6612 YOU ARE NOTIFIED that, pursuant to AS 31.05.093 and 20 MC 25.615, the Alaska Oil and Gas Conservation Conunission has determined your regulatory cost charge and payment dates for the current fiscal year 2004.,' A copy of the Commission's order determUûng regulatory cost charges and payment dates is enclosed. To: Your regulatory cost charge is $2,865,857.41. You previously paid an estimated regulatory cost chargeof$712,148~50, leaving a balance of $2,153,708.91. One third of this balance, $717,902.97, is dUe no later than November 30, 2003. A second payment of $71 7,902.97 is due no later than January 15,2004. A third payment of $717,092.97 is due no later than Maréh 15,2004. Under 20 MC 25.620, you are required to pay each payment by its specified .payment date. (Note: you may prepay all or part of the regulatory cost charge at any time.) , Please make your checks payable to: State of Alaska! AOGCC Mail or deliver payments to: AOGCC 333 West 7th Avenue, Suite 100 Anchorage, Aù( 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. Date: Your regulatory cost charge has been calculated on the basis described in the October 1, 2003, Notice of Proposed Regulatory Cost Charges for Fiscal year 2004. ~. November 4, 2003 " (\. ~ 1f~1f Œ lID ~ ~~~~ [( ~ ~I ASIi&OIL A1Q) GAS COlVSBRVADOlW COJDIISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF REGULATORY COST CHARGE ConocoPhilljps Alaska, Inc. Attention: Noel Dike, Prod Rev Acctg Accounts Payable, A TO-I668 P.O. Box 100360-- Anchorage~ AK 99510-0360 YOU ARE NOTIFIED that, pursuant to AS 31.05.093 and 20 MC 25.615, the Alaska Oil and Gas Conservation Commission has detennined your regulatory cost charge and payment dates for the curreht fiscal. year 2004. A copy of the Commission's order determining regulatory cost charges and payment dates is. enclosed. To: Your regulatory cost charge is $675,978.22. You previously paid an estimated regulatory cost charge of$171,753.73~ leaving a balance of $504,224.49. One third ofthi~ balance, $168~O74.83, is due no later than November 30, 2003. A second payment of $168,074.83 is due no laterthán January 15,4004. A third.payment of $168,074.83 is due no later than March 15, 2004. Under 20AAC 25.620, you are required to pay each payment by its specified payment date.. (Note: you may prepay all or part of the regulatory cost charge at any time.) Please make your checks payable to: State of Alaska! AOGCC Mail or deliver payments to: AOOCC 333 West 7th Avenue, Suite 100 Anchorage, AK99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. . Your regulatory cost charge has been calculated on. the basis described in the October 1, 2003, Notice of Proposed Regulatory Cost Charges for Fiscal year 2004. Date: November 4, 2003 r-, .1"'\ ~1fIA\1fŒ ffi) ~ IA\~IA\~~IA\ A.I~SIlA OIL A5D GAS CONSBRYAD ON COJDIISSION FRANK H. MURKOWSKl, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, AlASKA 99601-3539 PHONE (907) 279-1433 FAX (907)276-7542 INVOICE AND NOTICE OF REGULATORY COST CltARGE To: Forest Oil Corporation. . Attn: Carl Schnake, Accounts Payable 1600 Broadway, Suite 2200 Denver, CO 80202 YOU ARE NOTIFIED that, pursuant to AS 31.05.093 and 20 MC 25.615, the Alaska Oil and QasConservation Commission has determined your regulatory cost charge and payment dates for the current fiscal year 2004. A copy of the Commission's order determining regulatory cost charges and paymertt dates is enclosed. . Your regulatory.cost charge is $2,496.19. You previously paid an estimated regulatory cost charge of$872.85, leaving a balance of $1,623.34. One third of this balance, $541.12, is due no later than November 30, 2003. A second payment of$541.11 is due no later than January 15,2004. A third payment of $541.1 1 is due no later than March 15, 2004. Under 20 MC 25.620, you are required to pay each payment by its sPeCifiedpayrhent date. (Note: you may prepay all or part of the regulatory cost charge at any time.) Please make your checks payable to: State of Al~AOGCC Mail or deliver payments to: AOGCC 333 West 7th Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. Your regulatory cost charge has been'calculated on the basis described in the October 1, 2003, Notice of Proposed Regulatory Cost Charges for Fiscal year 2004. Date: November 4, 2003 " ,r"\ ~1f~1fŒ (IDŒ ~~~~æ~ AJ..\SIU. OIL AND GAS ~OlVSBRVA'D OlW COJDIISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 1'" AVENUE, SUITE 100 ANCHORAGE, AlASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF REGULATORY COST CHARGE Marathon Oil Company Attention: Accounting Analyst P.O. Box 196168 . Anchorage, AK 99519-6168 YOU ARE NOTIFIED that, pursuant to AS 31.05.093 and 20 MC 25.615, the Alaska Oil and Gas Conservation Commission bas determined your regulatory cost charge and payment dates for the current fiscal year 2004. A copy of the Commission's order determining regulatory cost charges and payment dates is enclosed. .. To: Your regulatory cost charge is $9,794.09. You previously paid an estimated regulatory cost chargeof$2,142.75, leaving a balance of $7,651.34. One third of this balance, $2,550.45, is due no later than November 30, 2003. A Second payment of $2,550.45 is due no later than January 15, 2004. A third payment of $2,550.44 is due no later than March 15, 2004. Under 20 MC 25.620, you are required to pay each payment by its specified payment date. (Note: you may prepay all or part of the regulatory cost charge at any time.) Please make your checks payable to: . State of Alaska! AOGCC Mail or deliver payments to: AOGCC 333 West 7th Avenue; Suite 100 Anchoraget AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. Your regulatory cost charge has been calculated on the basis described in the October I, 2003, Notice of Proposed Regulatory Cost Charges for Fiscal year 2004. Date: . . November 4, 2003 f"'" 1"'\ ~1f~1fŒ lIDŒ ~~~~[[fÆ 4J.4SIi& GIlt UDGAS COlV5BRVA'DOlW ~OJDDSSI OlW FRANK H. MURKOWSKI, GOVERNOR 333 W. 1'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF REGULATORY COST CHARGE North Slope Borough Attention: DorothySavok, Manager Barrow Gas Fields P.O. Box 69 Barrow, AK. 99723 YOU ARE NOTIFIED that, pursuant to AS 31.05.093 and 20 MC 25.615, the Alaska Oil and Gas Conservation Commission bas determined your regulatory cost charge and payment dates for the current fiscal year 2004. A copy of the Commission's order determining regulatory cost charges and payment dates is enclosed. To: Your regulàtory cost charge is $349.55. You previously paid an estimated regulatory cost crn.rgeof$369.97~leaving a credit balance of$20,42. Your refund will be issued to you before.Dêcember 31,2003. Your regulatory cost charge bas been calculated on the basis described in the October 1, 2003, Notice of Proposed Regulatory Cost Charges for Fiscal year. 2004. Date: November 4, 2003 , f' ~ ~ 1f~1fæ ŒJ ~ ~[~ ~ [K{ ~ ~'.ASIU. OIL A5D GAS ~ONSBRVATlOlV COmoSSIOlW FRANK H. MURKOWSKI, GOVERNOR 333 W. 1'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 219-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF REGULATORY COST CHARGE To: Phillips Petroleum Company Attention: Steven Arbelovsky, Cook Inlet. Ops Mgr P.O. Box 66 Kenai, AK 99611 YOU ARE NOTIFIED that, pursuant to AS 31.05.093 and 20 AAC 25.6 15, the Alaska Oil and Gas Conservation Commission has determined your regulatory cost charge and payment dates for the current fiscal year 2004. A copy of the Commission's order determining regulatory cost charges and payment dates is enclosed. . Your regulatory cost charge is'$I3,585.72. You previously paid an estimated regulatory cost charge of $3,481.09, leaving a balance of $10,104.63. One third of this balance, $3,368.21, is due no later _November 30,2003. A second payment of $3,368.21 is due no later than January 15,2004. A third payment of$3,368.21 is due no later than March 15,2004. Under 20 MC 25.620, you are required to pay each payment by its specified payment date. (Note: you may prepay all or part of the regulatory cost charge at any time.) Please make your checks payable to: State of Alaska! AOGCC Mail or deliver payments to: AOGCC 333 West 7th Avenue, Suite 100 . Anchorage,AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions~ Your regulatory cost charge bas been calculated on the basis described in the October I, 2003, Notice of Proposed Regulatory Cost Charges for Fiscal year 2004. Date: November 4, 2003 " f'. f'\ $1f /Å\ 1fŒ ffiJ ~ /Å\ ~/Å\ $ [K{ /Å\ .I',ASJU. OIL A5D GAS CONSBRVATI OlV COJDIISSIOl¥ FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, AlASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF REGULATORY COST CHARGE UNOCAL Attention; Martin Morell, Mgr Oil & Gas P.O. Box 196247 Anchorage, AK. 995 I 9-6247 YOU An NO""""JED that, pursuant to AS 31.05.093 and 20 AAC 25.615, the Alaska Oil and Gas Conservation Commission has. determìned your regulatory cost charge and payment dates for the current fiscal year 2004. A copy of the Commission's order determining regulatory cost crn.rges and payment dates is enclosed. To: Your. regulatory cost charge is $99,327.77. You previously paid an estimated regulatory cost charge of$29,825.53, leaving a balance of $69,502.24. One third of this balance, $23,167.42, is due no later than November 30,2003. A second payment of $23,167.41 is due no later than January 15,2004. A third payment of $23,167.41 is due no later than March 15,2004. Under 20 AAC 25.620, you are required to pay each payment by its specified payment date. (Note: you may prepay all or. part of the regulatory cost charge at any time.) Please make your checks payable to: . State of AlaskalAOGCC Mail or deliver payments.to: AOGCC 333 West 7th Avenue, Suite I 00 Anchorage, AK. 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. Date: Your regulatory costcbarge has. been calculated on the basis described in the Octobq I, 2003, Notice of Proposed Regulatory Cost Charges for Fiscal year 2004. . . ~ ......'.. ~ ~H. .' . air November 4, 2003 ,....., ~ $1f~1fŒ (ID~ ~~~$æ~ :4.1fASIU. OIL A5D GAS ~OlWS.RVA.'DOlW ~OJDDSSIOlW FRANK H. MURKOWSKI, GOVERNOR 333 W. 1'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 219-1433 FAX (907) 276-7542 ,INVOICE AND NOTICE OF REGULATORY COST CHARGE XTO Energy Inc . Attn: William A.. Miller, District Admin Mgr 52260 Shell Road Kenai, AK 9961 1..9704 YOU ARE NOTIFIED that, pursuant to AS 31.05.093 and 20 AAC 25.6 IS, the Alaska Oil and Gas Conservation Commission has determined your regulatory cost charge and payment dates for the current fiscal year 2004. A copy of the Commission's order determining regulatory cost charges and payment dates is enclosed. To: . Your regulatory cost charge is $6,333.46. You previously paid an estimated regulatory cost charge of$I,638.22 leaving a.balance of$4,695.24. One third of this balance, $1,565.08, is due no later than November 30, 2003. A seCond payment of $1,565.08 is due no later than January 15,2004. A third payment of$1,565.08 is due no later than March 15,2004. Under 20 AAC 25.620, you are required to pay each payment by its specified payment date. (Note: you may prepay all or part of the regulatory cost charge at any time.) Please make your checks payable to: State of AlaskalAOGCC Mail or deliver payments to: AOGCC 333 West 7th Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. Your regulatory cost charge bas been calculated on the basis described in the October I, 2003, Notice of Proposed Regulatory Cost Charges for Fiscal year 2004. Date: November 4, 2003 #5 ~ ---.. STATE OF ALASKA OIL AND GAS CONSERV A TION COMMISSION 2004 Regulatory Cost Charges November 4, 2003 9:00 am NAME-AFFILIATION ADDRESS/PHONE NUMBER TESTIFY (Yes or No) (PLEASE PRINT) ~~~;/) ~ð~ Y COIf¡ 11'78/ -é ~¿2 - 7:!Z </ ~(!.C C[ O,'jCC Ai /'10 \Meeting Sign-In #4 STATE OF ALASKA ~ NOTICE TO PUBLISHER ~ ADVERTISING ORDER NO. ADVERTISING INVOll -,ST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NL mFIED AO-O2414008 AFFIDAVIT OF PUBLICATION (PART2 OF THIS FORM) WITH ATTACHED COpy OF ORDER ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE SEE BOTTOM FOR INVOICE ADDRESS F AOGCC AGENCY CONTACT DATE OF A.O. R 333 W 7th Ave, Ste 100 lodv Colombie October 2. 2003 0 Þu1chorage,AJ( 99501 PHONE PCN M - (Q07) 7Q1 -1 ?? 1 DATES ADVERTISEMENT REQUIRED: T Þu1chorage Daily News October 3, 2003 0 POBox 149001 Þu1chorage, AJ( 99514 THE MA TERJAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: Advertisement to be published was e-mailed Type of Advertisement X Legal 0 Display 0 Classified DOther (Specify) SEE ATTACHED SEND INVOICE IN TRIPLICATE ¡,\OGee. ~J.' \\,,'th :\\l'.. Suitc 100 PAGE 1 OF TOTAL OF 51 TO Anchoragc. ,\K 99501 2 PAGES ALL PAGES$ REF TYPE NUMBER AMOUNT DATE COMMENTS 1 VEN 2 ARD 02910 3 4 FIN AMOUNT SY CC PGM LC ACCT FY NMR 015T LlO 1 04 02140100 73540 2 3 4 ^ /"'0 1.....- " "- REQUISITIONED BY( ') \ ~vbJM j r--/ IDI~ W% !I ^--" v"--'" ( .........'-' '" v f/ \) 02-902 (Rev. 3/94) Publisher/Original Copies: Department Fiscal, Department, Receiving AO.FRM ~ ~ Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: Proposed Regulatory Cost Charges for Fiscal Year 2004 The Alaska Oil and Gas Conservation Commission ("Commission") will hold a public hearing on November 4,2003 at 9:00 am at the Commissions offices, 333 West 7th Avenue, Suite 100, Anchorage AK 99501. The purpose ofthe hearing will be to receive testimony and statements on the fiscal year 2004 regulatory cost charges that the Commission proposes to impose on operators pursuant to 20 AAC 25 540. Copies of the Commission's proposal may be obtained from the Commission at the address set out above. If you are a person with a disability who may need a special modification in order to comment or to attend the public hearing, please contact Jody Colombie at 793-1221 before October 30,2003. Sarah Palin Chair Published Date: 10/03/03 AO# 02414008 ~ ~ anchorage Daily News Affidavit of Publication 1001 Northway Drive, Anchorage, AK 99508 PRICE OTHER OTHER OTHER OTHER OTHER GRAND AD# DATE PO ACCOUNT PERDAY CHARGES CHARGES #2 CHARGES #3 CHARGES #4 CHARGES #5 TOTAL 963103 1O/Œ/2003 02414008 STOF0330 $67.68 $67.68 $0.00 $0.00 $0.00 $0.00 $0.00 $67.68 STATE OF ALASKA THIRD JUDICIAL DISTRICT ';1\RItlce at Public ""orlng STATE OF ALASKA Alaska OU,ahd Gas ., Conservation Commission 1 That said newspaper has been approved by the Third Judicial Court, Anchorage, Alaska, and it now and has been published in the English language continually as a daily newspaper in Anchorage, Alaska, and it is now and during all said time was printed in an office maintained at the aforesaid place of publication of said newspaper. That the annexed is a copy of an advertisement as it was published in regular issues (and not in supplemental form) of said newspaper on the above dates and that such newspaper was regularly distributed to its subscribers during all of said period. That the full amount of the fee charged for the foregoing publication is not in excess of the rate charged private individuals. R'-:'ProPOMd Regulatory cost Charóesfor Fiscal Year2004 ' 'The "'I,.~a 011 an,d Gas.cons....vation Cóm- mission ("Commission") will hold a public hearing on November 4, 2003 at 9:00omot theCommis- sions offices, 333 West 7th A,lÌenue, Sliite 100. An- chorage AK 99501. Tile purpose of the hearing will be to receive testi- mony and statements on the fiscal year 2004 reglf- 10 tory cost charges that' the Commission proPO'" to iinpose on operator. pursuant to 20 AAC 25 540. Teresita Peralta, being first duly sworn on oath deposes and says that she is an advertising representative of the Anchorage Daily News, a daily newspaper. Signed ~fI~ v C~ples of the com- mission's proposal may b,e obtained from the C9mmlumn at the od- .~. set o.t above. ,If YOU are a person wIth a disability who maY nteil'o special modlfico' tlonlll oroerto comment or .to attend the pubilc II',flng, please contact JICIV Colombie ,at 793-1221 btfòre October 30, 2003. ""- Subscribed and sworn to me before this date: /q;1 /o.~ Sarah Poiin ,. 't:-tRItr- , Aat02414Q08 Pub: October 3. 2003 Notary Public in and for the State of Alaska. Third Division. Anchorage, Alaska MY COMMISSION EX RES: ~/õ?9 p '5 \\(((Ift I. \\\\ þo\:\~,~: 0:7,-. ~ 0." --- "~"'" ~~, ~OTA" j;~~ ~ ". --- - .... . ' - .... . ðt. .t-- 0 - - 0 "'-uBL\v ' ~ ~~, 0" '::..z, ' ~ - - ;./,; 0 , - , :t JI... 0:"00 - '.~ 0 .=" -;::.~.~o,CF '~" ~.;., ~.... ' , . ' :\" :/,;,,;, ~ ", IJJ}JJ)J)\\ RE: Notice ,--.., /""""'-- Subject: RE: Notice Date: Wed, 01 Oct 2003 15:51:34 -0800 From: legalads <legalads@adn.com> To: Jody Colombie <jody_colombie@admin.state.ak.us> Hi Jody: Following is the confirmation information on your legal notice. Please let me know if you have any questions or need any further information. Account Number: STOF 0330 Legal Ad Number: 963103 Publication Date(s): October 3,2003 Your Reference or PO#: AO-02414008 Cost of Legal Notice: $67.68 Additional Charges Web Link: E-Mail Link: Bolding: Total Cost to Place Legal Notice: $67.68 Add Will Appear on www.adn.com: XXXX Add Will Not Appear on www.adn.com : Thank You, Kim Kirby Anchorage Daily News Legal Classified Representative E-Mail: legalads@adn.com Phone: (907) 257-4296 Fax: (907) 279-8170 ---------- From: Jody Colombie Sent: Wednesday, October 1, 2003 1 :34 PM To: legalads Subject: Notice «File: Regulatory Cost Hearing 2004.doc»«File: Ad Order form.doc»«File: jody colombie.vcf» Please publish the attached Notice on October 3,2003. lody 1 of 1 10/1/20034:00 PM Notice -----.. Subject: Notice Date: Wed, 01 Oct 2003 13:34:33 -0800 From: Jody Colombie <jody_colombie@admin.state.ak.us> Organization: Alaska Oil and Gas Conservation Commission To: Legal Ads Anchorage Daily News <legalads@adn.com> Please publish the attached Notice on October 3, 2003. Jody Name: Regulatory Cost Hearing 2004.doc ~Regulatory Cost Hearing 2004.doc Type: WINWORD File-(applicationlmsword) Encoding: base64 Name: Ad Order form.doc ~Ad Order form. doc Type: WINWORD File (applicationlmsword) Encoding: base64 L ~~ Colombie <iody colombie@admin.state.ak.us> 10f1 10/1/2003 1:39 PM STATE OF ALASKA ADVERTISING ORDER SEE BOTTOM FOR INVOICE ADDRESS ~ NOTICE TO PUBLISHER ~ ADVERTISING ORDER NO. INVOIL ,ST BE IN TRIPLICATE SHOWING ADVERTISING ORDER Nc nlFIED AO-O2414008 AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COt-y OF ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE F AOGCC R 333 West 7th Avenue, Suite 100 0 Anchorage, AK 99501 M 907-793-1221 AGENCY CONTACT DATE OF A.O. PCN ¿ Anchorage Daily News POBox 149001 Anchorage, AK 99514 October 3,2003 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: AFFIDAVIT OF PUBLICATION United states of America REMINDER State of ss INVOICE MUST BE IN TRIPLICATE AND MUST REFERENCE THE ADVERTISING ORDER NUMBER. A CERTIFIED COpy OF THIS AFFIDAVIT OF PUBLICATION MUST BE SUBMITTED WITH THE INVOICE. ATTACH PROOF OF PUBLICATION HERE. division. Before me, the undersigned, a notary public this day personally appeared who, being first duly sworn, according to law, says that he/she is the of Published at in said division and state of and that the advertisement, of which the annexed is a true copy, was published in said publication on the day of 2003, and thereafter for - consecutive days, the last publication appearing on the - day of , 2003, and that the rate charged thereon is not in excess of the rate charged private individuals. Subscribed and sworn to before me This - day of 2003, Notary public for state of My commission expires 02-901 (Rev. 3/94) Page 2 AO.FRM PUBLISHER SD Dept of Env & Natural Resources Oil and Gas Program 2050 West Main, Ste 1 Rapid City, SD 57702 David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 Robert Gravely 7681 South Kit Carson Drive Littleton, CO 80122 Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 Samuel Van Vactor Economic Insight Inc. 3004 SW First Ave. Portland, OR 97201 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 David Cusato 600 West 76th Ave., #508 Anchorage, AK 99518 Kenai Peninsula Borough Economic Development Distr 14896 Kenai Spur Hwy #103A Kenai, AK 99611-7000 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 ------.. Citgo Petroleum Corporation PO Box 3758 Tulsa, OK 74136 Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 W. Allen Huckabay ConocoPhillips Petroleum Company Offshore West Africa Exploration 323 Knipp Forest Street Houston, TX 77079-1175 Kelly Valadez Tesoro Refining and Marketing Co. Supply & Distribution 300 Concord Plaza Drive San Antonio, TX 78216 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 Jerry Hodgden Hodgden Oil Company 408 18th Street Golden, CO 80401-2433 John Levorsen 200 North 3rd Street, #1202 Boise, ID 83702 Kay Munger Munger Oil Information Service, Inc PO Box 45738 Los Angeles, CA 90045-0738 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle, WA 98119-3960 Trustees for Alaska 1026 West 4th Ave., Ste 201 Anchorage, AK 99501-1980 Schlumberger Drilling and Measurements 3940 Arctic Blvd., Ste 300 Anchorage, AK 99503 Ciri Land Department PO Box 93330 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 Jack Hakkila PO Box 190083 Anchorage, AK 99519 Kevin Tabler Unocal PO Box 196247 Anchorage, AK 99519-6247 Penny Vadla Box 467 Ninilchik, AK 99639 James Gibbs PO Box 1597 Soldotna, AK 99669 Richard Wagner PO Box 60868 Fairbanks, AK 99706 Cliff Burglin PO Box 131 Fairbanks, AK 99707 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 .--... North Slope Borough PO Box 69 Barrow, AK 99723 .----.. Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 Regulatory Cost Charges ,.-.. , Subject: Regulatory Cost Charges Date: Wed, 01 Oct 2003 13:38:22 -0800 From: Jody Colombie <jody_colombie@admin.state.ak.us> Organization: Alaska Oil and Gas Conservation Commission To: Cynthia B Mciver <bren_mciver@admin.state.ak.us>, Nancy Norton <Nancy - Norton@admin.state.ak.us> Please publish. Jody --------------..----------..-----.. Name: Regulatory - Cost- Hearing- 2004.doc ~Regulatory Cost Hearing 2004.doc Type: WINWORD File (applicationlmsword) Encoding: base64 Jody Colombie <iodv colombie@admin.state.ak.us> lofl 10/1/2003 1:38 PM Proposed Regulatory Cost Charges for Fiscal Y ear 20~ --... Subject: Proposed Regulatory Cost Charges for Fiscal Year 2004 Date: Wed, 01 Oct 2003 13:37:32 -0800 From: Jody Colombie <jody_colombie@admin.state.ak.us> Organization: Alaska Oil and Gas Conservation Commission lof2 10/1/2003 1 :38 PM Proposed Regulatory Cost Charges for Fiscal Year 20~ ~ Name: Regulatory - Cost- Hearing- 2004.doc ~Regulatorv Cost Hearing 2004.doc Type: WINWORD File (applicationlmsword) Encoding: base64 > 2 of2 10/112003 I :38 PM #3 , '-, /~ \-; J .".' MEETING AGENDA ** Date October 1, 2003 Time 9:00 am OLD BUSINESS 1. Approve minutes of last meeting. GENERAL COMMISSION BUSINESS: 1. 2. 3. 4. 5. 6. 7. Draft regulations to implement SB 185 Regulatory Cost Charges 20 AAC 25.001 Alternate Compliance and Waivers Funding options for the geological sample repository To fund a Project analysis for a permanent geological sample repository CBM Field Trip Personnel Issues ** Circumstances may cause items to be either added or deleted from the agenda or a meeting cancellation. Please contact lody Colombie at (907) 793-1221 for confirmation. SIGN IN SHEET NAME AFFILIATION (PLEASE PRINT) SCANNED OCT 1 3 2003 ) ~ '-Ì AOGCC Public Meeting October 1, 2003 , Agenda Item 3. Funding options for the geological material project DNR's Geologic Materials Center in Eagle River has outgrown its available space and current space in now inadequate for storing and examining samples. DNR/DGGS made a FY2005 CIP request for $50,000 in General Funds for a one-time project to hire a qualified engineering firm to develop design criteria, estimate construction costs, address land-acquisition and permitting issues, and evaluate options for long-term operational funding. Funding for construction and moving the collection would be pursued through a federal appropriation request. Costs anticipated are: Personal Services $5,000 Prepare RFP, oversee selection process, manage contract, and review deliverables. Meet with contractor. Contract to develop design criteria, estimate construction costs, address land-acquisition and permitting issues, and evaluate options for long-term operational funding. Travel Contractual Services $1,000 $45,000 $50,000 Total The DNR/DGGS has requested that the AOGCC assist with the funding of the project. The AOGCC has declined to submit a CIP request in favor of using funding from the existing operating budget. Two options are: 1. Assign a Contract Manager from AOGCC to prepare the RFP and oversee the contract. Funds would come from the line items indicated above. 2. Prepare a Reimbursable Services Agreement (RSA) with DNRlDGGS contracting with them to perform all work and report findings and actual expenses back to us. All funds would come from Contractual Services. Contractual Services funds would come from the Data Management and Technical Professional Services portion of the AOGCC budget. CIP R~est Format - FY2005 Budget Request ~ar Project Title: Project analysis forfrpermanent geological sample repository '-' Location of Project: Anchorage FY2005 Amount: FY2006 Amount: FY2007 Amount: FY2008 Amount: FY2009 Amount: FY2010 Amount: $ 50,000 $0 $0 $0 $0 $0 Estimated Start Date: July 1, 2004 Estimated Completion Date: June 30, 2005 Project Manager: Rod Combellick Phone Number: 907-451-5007 Fund Source: General Fund Brief Project Summary: DNR's Geologic Materials Center in Eagle River is the state's archive of geologic samples for supporting energy- and mineral-related exploration and development in Alaska. However, it has outgrown its available space and does not provide adequate permanent facilities for storing and examining samples. On the basis of a conceptual plan already developed by an advisory committee, this one-time project would support a qualified engineering firm to develop design criteria, estimate construction costs, address land-acquisition and permitting issues, and evaluate options for long-term operational funding. Funding for construction and moving the collection would be pursued through a federal appropriation request. Prior Funding History and Status: New Project - No Prior Funding History Detailed Project Justification: An ad hoc advisory group of DNR division representatives and industry users has developed a conceptual plan for replacing the existing Geologic Materials Center (GMC) in Eagle River with a more accessible and usable permanent facility at minimal cost to the state. The GMC is the state's permanent archive of geologic samples for encouraging and supporting energy- and mineral-related exploration and development in Alaska. Its facilities and services are provided as part of the state geologist's statutory responsibility to make available geological information ".. .to determine the potential of Alaskan land for production of metals, minerals, fuels, and geothermal resources" (AS 41.08.020). Virtually all mineral- and fuel-exploration companies examine samples at the GMC before pursuing new exploration programs in Alaska. Many of these exploration programs have resulted in new discoveries of mineral and energy resources, partly on the basis of results of sample examinations at the GMC. Numerous private-sector jobs are devoted wholly or in part to analyzing samples at the GMC for exploration companies. Although numbers are difficult to predict, an expanded, more accessible, and usable facility will likely increase private-sector use of the GMC. More importantly, the GMC allows private- sector exploration companies to examine samples that would cost them thousands or even millions of dollars to re-collect. This lowers their exploration costs and helps to make Alaska a more attractive exploration investment. The GMC holdings contain rock core and cuttings that represent 10 million feet of private-sector exploration and production drilling that were derived from Federal, State, and private lands of Alaska, including the Alaska outer continental shelf. This collection includes rock materials from over 1, 130 oil and gas exploratory and/or production wells, rock core from over 774 exploratory hard-rock mineral holes, and surface samples. Additionally, there are 95,000 feet of diamond-drilled hard rock mineral core stored at the GMC. Cooperating government agencies are the u.S. Bureau of Land Management, u.S. Geological Survey, u.S. Minerals Management Service, and Alaska Oil and Gas Conservation Commission. The current sample storage occupies about 35,000 square feet of space, approximately half of which is in portable, unheated 40x8 ft containers, on roughly 20 acres of state land. The advisory group proposes that a new 70,000 sq ft facility be built to house the existing sample collection under one roof and accommodate expected growth for the next 30-50 years. Funding for construction, moving the existing collection, and the first year or two of operation would be pursued through a federal supplemental appropriation request. However, developing a detailed project plan requires the services of qualified architectural, engineering, and planning professionals to develop design criteria, estimate construction costs, address land-acquisition and permitting issues, and evaluate options for long-term operational funding. This is a one-time CIP for contracting with a qualified civil engineering company to perform the analysis. Total project cost was estimated by contacting several engineering companies, describing the general project scope, and obtaining their estimates on the basis of similar projects they have performed in the past. The other alternative evaluated was for advisory board members or participating state agencies to perform this analysis. File: cip fonnat.doc Updated: ant2002 The advisory board concluded that these personnel do not possess the required expertise, and that this work is more appropriately and efficientlY.~ formed by the private sector. The reqUeCUnding includes minimal salary expense for a state emplo.~to oversee this contract. No other state tional costs are expected. Why is this Project Needed Now: The Geologic Materials Center has outgrown its current facility and is having to put all incoming sample collect.;ons in portable storage. Many oil companies are donating their core sample collections to public storage .facilities as part of their efforts to reduce costs by vacating and selling their warehouse space or converting it to other uses. If Alaska does not soon provide adequate sample-storage space, many of these collections will remain or move out of state, making them far less useful and accessible to companies pursuing exploration programs in Alaska. There is an immediate opportunity to obtain federal funding for a new facility, an opportunity that may no longer exist if the state does not take advantage of it immediately. This project is needed now to provide the detailed project plans to pursue this funding. Specific Spending Detail: Line Item Expenditures: Personal Services Travel Contractual Services $4,000.00 $1,000.00 $45,000.00 Prepare RFP, oversee selection process, manage contract, and review deliverables. Meet with contractor. Contract to develop design criteria, estimate construction costs, address land-acquisition and permitting issues, and evaluate options for long-term operational funding. None required None required Supplies Equipment $0.00 $0.00 $50,000.00 Project Support: Division of Oil & Gas, Division of Mining Land and Water, u.S. Bureau of Land Management, u.S. Geological Survey, u.s. Minerals Management Service, Alaska Oil & Gas Conservation Commission, Alaska Oil & Gas Association, major oil companies, independent oil companies, Alaska Miners Association, mining companies, geological consultants. Project Opposition: None known State Match Required: No match required Annual Ongoing Operating and Maintenance Costs: None Project Status: One-time Historical Category: Natural Resources Project Type: Planning File: cip format.doc Updated: 8/7/2002 c: ~ August 13, 2003 - Open Meeting ATTENDEES Sarah Palin Randy Ruedrich Daniel T Seamount Linda Berg Jody Colombie Chair Commissioner Commissioner Administrative Manager Special Staff Assistant Palin: Any adjustments to this mornings meeting? Ruedrich: Defers HB 69 to next meeting. Palin: Hearing no objections. Palin defers until next meeting. Palin: Any objection to approving today agenda? Seamount: Seconds. Palin: Hearing no objection, agenda is approved. Old Business: . Approve minutes of June 25, 2003. . Ruedrich: Moves to approve the minutes of June 25, 2003. . Seamount: Seconds the motion. . Palin: No objections. Minutes are approved. Under Commission General Business: . Regulatory Cost Charges 2004 . Linda Berg - Need to approve the regulatory cost charges . Discussion . There is a $400,000 reduction from last fiscal year. . We should know the costs lapsed figure by the end of September to set the final figures. . Reudrich: Moves to adopt the regulatory costs charge as proposed and we mail $3,687,900. as the interim number. Seamount: Seconds Palin: Approves the regulatory costs charges. Votes: Seamount Yes, Reudrich, Yes. . Ruedrich: Makes comments on the overall budget. . Seamount: Recommends that we include cover letter that indicates the funds that we have lapsed; reviewing ways to cuts costs and update operators on the current projects. Summary for our clients, how we are spending the money. . Ruedrich: We should do this with the full year charge after we figure out what we have lapsed. The letter that we are sending out for the current purposes is adequate. Weare expecting to give our clients a different level of detail with the full year request. . Palin: Lets vote on the regulatory cost charges. . Ruedrich: In favor of approval. Ruedrich: Seamount: Palin: ,~ c . Seamount: Yes Palin: Yes, it is approved. . . Discussion: ~ 90 (Orphan well fund) . Ruedrich agreed to work on this issue. . Discussion on: Personnel Issues . Needs for the agency. . Discussion: Variances and waivers. . Jody is going to continue working regulation. . Discussion: Tom Marshall wants to have lunch with all of us . Dan will set up . Discussion: Permanent Fund Resolution . Mark Meyers working on a letter. . Discussion. . Discussion: Purchase of a vault for the confidential data. . Linda has purchased the vault from surplus. . Discussion: Contact person for alarm . Randy Ruedrich will be the back up caller to Linda Berg. Moves to adjourn. Agrees. Adjourned. AP~ GR ál, Chair ~) ~ 'j Date' ( ~ ~ October 1, 2003 - Open Meeting ATTENDEES Sarah Palin Randy Ruedrich Daniel T Seamount Linda Berg Jody Colombie Robert Mintz Robert Fleckenstein Winton Aubert Jack Hartz James Regg Chair Commissioner Commissioner Administrative Manager Special Staff Assistant Assistant Attorney General Statistical Technician Senior Petroleum Engineer Senior Petroleum Engineer Senior Petroleum Engineer Old Business: . Approve minutes of August 23,2003. Under Commission General Business: 1. 2. 3. 4. 5. 6. 7. Draft Regulation to implement SB 185 Regulatory Cost Charges 20 AAC 25.001 Alternate Compliance and Waivers Funding options for the Geological Sample Repository To fund a project analysis for a permanent Geological Sample Repository CBM Field Trip Personnel Issues . Ruedrich: Moves to adopt today's agenda . Seamount: Seconds the motion . Palin: No objections. Today's agenda is approved . Ruedrich: Moves to approve minutes of August 23, 2003 . Seamount: Seconds . Palin: No objections. Minutes are approved. Coal Bed Methane Field Trip Ruedrich: Requests staffs meet with Commissioners at 1 :00 pm for slide show on his recent trip. Ruedrich gives highlights of his visit to Colorado, Wyoming and Colorado last week. The Commissioner of Natural Resources, Director of Oil and Gas, Head of Permitting Section for Oil and Gas and Commissioner Ruedrich were on this field trip. They went through Evergreen's operations in the Raton Basin. Met with the regulatory and land people of the State of Wyoming and went to the BLM office in Buffalo, WY to talk about their perspective of regulation of Coal Bed Methane and then to the field with two operators in Northern Wyoming and Southern Montana and then came back to Colorado and viewed a ranch with well sites. Discussion followed. ~ ~ Draft ree:ulation to implement SB 185 Ruedrich: Moves to publish regulations adopting 20 AAC 25.233 Seamount: Seconds Motion to publish Palin: Will move forward with publcation of SB 185 Commissioners: All voted yes Ree:ulatorv Cost Chare:es Ruedrich: Moves to forward this to the publication process Seamount: Seconds Motion Palin: no objection. Approved to move to publication Commissioners: All voted yes 20 AAC 25.001 Alternate Compliance and Waivers Ruedrich: Moves to publish regulations adopting 20 AAC 25.001 Seamount: Seconds Motion Palin: no objection. Approved to move to publication Commissioners: All voted yes Fundine: Options for the Geoloe:ical Sample Repository Seamount: Gives background information on the GMC Build a super one stop shop for Center. It would stimulate even more industry investment. Have computers that access our information, anything DNR has, plus access to the cores. Geological workstations that the public can use. Commissioner Ruedrich indicated that we could possibly get federal appropriations from Senator Ted Stevens, multi-million dollars to build a new one. There are a number of questions. Should it be built? Should we be involved? How much involvement? Should we run the GMC? What are the statutory obligations? Add another $250,000 to the regulatory cost charges to run the center out in Eagle River and take it off ofDNR's hands. It is mainly industry used. Industry supports the GMC. ~ ---, 10% mining information 90% oil and gas GMC wants us to take it over. What does Senator Stevens need to seek federal funding. Ruedrich: He needs a nominal size structure; description of what it is being used for; and estimates of cost. When Commissioner Ruedrich spoke to Senator Stevens about this project in May, his comment was to get a number to one of his staffers to include in the budget. That is all he said he needed. Commissioner Ruedrich can visit with one of his staffers to see what else is needed. Ruedrich indicated that Senator Stevens needs the information in the beginning of appropriation process as to where it can be included so that the Senator won't be accused of adding a last minute write. We should try and have something to Senator Stevens before Christmas. Commission needs to be involved and move this through the budget process. We would need super facility. We need at least 10 acres of land and lots of parking. To fund a project analysis for a permanent eeoloeical sample repository Discussion. Continue exploring this. Commissioner Ruedrich will talk to a Senator Stevens staffer. Personnel Issues Petroleum Inspector Position. Discussion. James Regg has four candidates. Will interview next week for the position. Natural Resources Technician I/II Range 10/12. Administrative Manager is working on PDQ. Discussion. Special Assistant made comments on range and level of expertise that is expected. Is 10/12 an adequate range? OPA 90 (Orphan well fund) It's a Task Force on IOGCC. Coast Guard has one (1) billion dollars in the budget for this. AOGCC needs to be involved in this task force. 150 orphaned wells. 137 belong to the federal government, but they are not taking responsibility for them. Permanent Fund Issue Jim Clark wants us to look at what we can do to establish a regulatory regime on production facility tariffing, i.e.: facility sharing, and Ruedrich asked Mark Johnson ~ '--"', to send over stuff that would be related to how they establish their regime for tariffing. We have been asked to generate some concepts. Discussion. Palin: Adjoumed. s . , Chair /rj2q /03 Date #2 r----- ---~ ~1f~1fŒ (ffi~ ~~~~[K\~ AI.ASHA OIL AM) GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 October 1, 2003 CERTIFIED MAIL All Operators Subject: Explanation of Regulatory Cost Charge Changes Enclosed is the Notice of Proposed Regulatory Cost Charges for Fiscal Year 2004. Upon reviewing the report attached, you will notice changes in the volumes that were reported in July. The volumes used in the July report were for the calendar year 2001 and not for calendar year 2002. The report attached corrects that error. Sincerely, Enclosures: 1. Notice of Proposed Regulatory Cost Charges for Fiscal Year 2004 2. Operator Annual Production, Injection and Disposal Volumes for Allocation of Regulatory Cost Charges ~CANNEr OCT 2 0 2003 ~~ ~1f~1fŒ (ID~ ~~~~[K\~ AltASHA OIL AM) GAS CONSERVATION COMMISSION ~, FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 NOTICE OF PROPOSED REGULATORY COST CHARGES FOR FISCAL YEAR 2004 Pursuant to AS 31.05.093 and 20 AAC 25.615, the Alaska Oil and Gas Conservation Commission proposes to impose Fiscal Year 2004 regulatory cost charges as set out below: Operator Aurora Gas LLC BP Exploration (Alaska) Inc. ConocoPhillips Alaska, Inc. Forest Oil Corporation Marathon Oil Company North Slope Borough Phillips Petroleum Company UNOCAL XTO Energy, Inc. Proposed Regulatory Cost Charge $150.59 $2,865,857.41 $675,978.22 $2,496.19 $9,794.09 $349.55 $13,585.72 $99,327.77 $6,333.46 These proposed regulatory cost charges have been calculated using the formula set out in 20 AAC 25.605(a) and using the following values in that formula: VOP for Aurora Gas LLC = VOP for BP Exploration (Alaska) Inc. = VOP for ConocoPhillips Alaska, Inc VOP for Forest Oil Corporation VOP for Marathon Oil Company VOP for North Slope Borough VOP for Phillips Petroleum Company = VOP for UNOCAL VOP for XTO Energy, Inc. = 100,842 Bbl 1,919,138,727 Bbl 452,672,899 Bbl 1,671,589 Bbl 6,558,673 Bbl 234,080 Bbl 9,097,757 Bbl 66,515,440 Bbl 4,241,237 Bbl = VTOT = 2,460,231,244 Bbl A = $4,162,900.00 F = $20,000.00 L = $469,027.42 .~- .-- -- The attached spreadsheets provide more detail on the production and injection volumes that determine each operator's VOP and on the calculation of the proposed regulatory cost charges. If you are listed above as an operator subject to proposed regulatory cost charges, you may submit comments on, or request a revision to, the proposed regulatory cost charges by writing the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501- 3539. Any comments or requests must be received within 30 days from the date of this notice as shown below. A request for a revision to the regulatory cost charges must be accompanied by an explanation of the basis for the requested revision. A public hearing on the proposed regulatory cost charges will be held in accordance with 20 AAC 25.540 on November 4, 2003, at the offices of the Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Suite 100, Anchorage, Alaska. This notice is not an invoice. After the public hearing, the Commission will issue an order determining actual regulatory cost charges and will notify each operator subject to a regulatory cost charge of the amount of the person's actual regulatory cost charge and the payment dates. Operators will be credited for any estimated regulatory cost charges for the first quarter of fiscal year 2004 that have already been paid. October 1, 2003 Date: r--, ~1f~1fŒ @~ ~~~~[K(~ ~..ASBA. OIL AlQ) GAS CONSBRVATION COMMISSION r--'\ FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 NOTICE OF PROPOSED REGULATORY COST CHARGES FOR FISCAL YEAR 2004 Pursuant t.o AS 31.05.093 and 20 MC 25.615, the Alaska Qiland Gas Conservati.on C.ommissi.on pr.op.oses to impose Fiscal Year 2004 regulatory cost charges as set.outbel.ow: Operàt.or Aur.ora Gas LLC BP Expl.orati.on (Alaska) Inc. C.onocoPhillip$ Alaska, Inc. F.orest Oil C.orporati.on Marath.on Oil Company N.orth SI.ope'B.or.ough . Phillips Petroleum C.ompany UNOCAL XTO Energy, Inc. Pr.oPOsed Re~latorv Cast Charge $150.59 $2,865,857.41 $675,978.22 $2,496.19 $9,794.09 $349.55 $13,585.72 $99,327.77 $6,333.46 These pr.oposed regulat.ory cast charges have been calculated using the f.ormula. set .out in 20 MC 25.605(a) and using the f.oll.owing values in that f.ormula: VOP far Aur.ora Gas LLC = Vop far BP Expl.orati.on (Alaska) Inc. = VOP farCanocaPhillips Alaska, Inc = VOP far Farest Oil'C.orporati.on = VOP far. Marathan Oil Campany = VOP far N.orth Slape Bar.ough = VOP far Phillips Petroleum Campany = VopfarUNOCAL = VOP far XTO Energy, Inc. = 100,842 Bbl 1,919,138,727 Bbl 452,672,899 Bbl 1,671,589 Bbl 6,558,673 Bbl 234,080 Bbl 9,097,757 Bbl '66,515,440 Bbl 4,241,237 Bbl VTOT = 2,460,231,244 Bbl A = . $4,162,900.00 F = $20,000.00 L = $469,027.42 " ~ ,~ The attached spreadsheets pravide mare detail an the praductian and injectian v.olumes that determine each aperat.or's VOP and an the calculatian .of the proposed regula.tary cost charges. Ifyau are listed above as an aperatar subject ta pr.opased regulatory cast charges, yau may submit c.omments .on, .or request a revisian ta, the praposed regulatory cast charges by writing the Alaska Oil and Gas C.onservatian Cammissi.on at 333 West 7th Avenue, Suite 100, Anch.orage, Alaska 99501- 3539. Any camments.or requests l11ust be received within 30 days fram the date .of this n.otice as sh.own bel.ow. A request far a revisian ta the regula.tory cast charges must be acc.ompanied by an explanati.on .of the basis far the requested revi.si.on. A public hearing .on the pr.oposed re~atary cast charges will be held in accordance with 20 AAC 25.540 on N.ovember 4, 2003, at the offices .of the Alaska Oil and Gas Canservati.on Cammissi.on, 333 West 7th Avenue, Suite 100, Anch.orage, Ala.ska. This notice is n.ot aninvaice. Mterthe public hearing, the Cammissian will issue an .order determining actual regulatory cast charges and will n.otify each .operatar subject ta a regulatory cast charge .of theam.ount .of the pers.on's actual regulatary cast charge and the payment dates. Operat.ors will be credited far any estimated regulatary . cost charges far the fIrSt quarter .of fiscal year 2004 that have already been paid. Date: October 1, 2003 r----, ~ ~~!ftà~Œ (m~ ~fu~~[[~ ~.t.SU 0& .&5D GAS COlVSBRVATIOl\l COJDIISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 FRANK H.' MURKOWSKI, GOVERNOR Octaber 1, 2003 CERTIFIED MAIL All Operatars Subject: Explanati.on of Regulatory Cast Charge Changes Enclased is. the Natice .of Pr.opasedRegulatary Cast Charges far Fiscal Year 2004. . Upon reviewing the report attached, yöu will natice changes in the v.olumesthat were reported in July. The v.olumes used in the July report were for the.ca1endar year 2001 and nat far calendar year 2002. The report attached c.orrects that error. Enclosures: 1. .N.otice .of Proposed Regulat.ory Cost Charges far Fiscal Year 2004 2. Operator AnnUå.l Productian,.Injectianand'Disposal V.olumes far Allocation .of Regulatary Cost Charges 2003 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2004 $3,673,873.00 Finalized Budget OperalorName Field/Pool Name Gros~' Liquid (Sib) Gros~' Gm' (Mscf) Ga.f BOE Tolal Volume (Liq+BOE) Allocated CO,\'t AURORA GAS LLC NICOLAI CREEK, UNDEFINED GAS Field/Pool Quantities and Allocated Costs Totals: 0 0 605,050 605,050 100,841.67 100,842 100,842 100,842 $150.59 $150,59 Summaryfo/" AURORA GAS LLC (I de/ail record) Operator Quantities and Allocated Costs Totals: 0 605,050 100,842 100,842 $150.59 ( ( ( Tuesday, September 23, 20 8:43 AM Pagelof17 2003 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2004 $3,673,873.00 Finalized Budget OperatorName FieltVPool Name Gro.ss Liquid (Stb) Gros.s Ga.s (Mscf) Ga,s BOE Total Volume (Liq+BOE) Allocated Co.\'t BP EXPLORATION (ALASKA) INC BADAMI. BADAMI OIL 579,271 13,788,183 2,298,030.50 2,877,302 $4,296.69 Field/Pool Quantities and Allocated Costs Totals: 579,271 13,788,183 2,298,031 2,877,302 $4,296.69 BADAMI, UNDEFINED WDSP 36,468 0 0.00 36,468 $54.46 Field/Pool Quantities and Allocated Costs Totals: 36,468 0 0 36,468 $54.46 ENDICOTT, ElDER OIL 1,721,270 3,657,804 609,634.00 2,330,904 $3,480.75 Field/Pool Quantities and Allocated Costs Totals: 1,721,270 3,657,804 609,634 2,330,904 $3,480.75 ENDICOTT, ENDICOIT OIL ( 90,779,038 259,094,459 43,182,409.83 133,961,448 $200,045.16 ( Field/Pool Quantities and Allocated Costs Totals: 90,779,038 259,094,459 43,182,410 133,961,448 $200,045.16 ENDICOTT, IVISHAK OIL 3,461,186 95,579 15,929.83 3,477,116 $5,192.39 Field/Pool Quantities and Allocated Costs Totals: 3,461,186 95,579 15,930 3,477,116 $5,192.39 ENDICOTT, UNDEFINED WDSP 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 MILNE POINT. KUPARUK RIVER OIL 37,004,894 15,751,275 2,625,212.50 39,630,107 $59,179.79 Field/Pool Quantities and Allocated Costs Totals: 37,004,894 15,751,275 2,625,213 39,630,107 $59,179.79 MILNE POINT, SAG RIVER OIL 783,098 179,126 29,854.33 812,952 $1,213.98 Field/Pool Quantities and Allocated Costs Totals: 783,098 179.126 29,854 812,952 $1,213.98 MILNE POINT, SCHRADER BLFF OIL 14,490,757 3,117,113 519,518.83 15,010,276 $22,414.90 FieldIPool Quantities and Allocated Costs Totals: 14,490,757 3,117,113 519,519 15,010,276 $22,414.90 ( MILNE POINT, TERTI UNDEF WTRSP 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 Tuesday, September 23, 20 8:43 AM Page 2 of 17 2003 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2004 $3,673,873.()() Finalized Budget OperatorName Field/Pool Name Gros,~ Liquid (Stb) Gr(}s,~ Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Co.\.t BP EXPLORATION (ALASKA) INC MILNE POINT, UGNU UNDEF WTRSP 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 MILNE POINT, UGNU UNDEFINE OIL 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 NORTHSTAR. NORTHSTAR OlL 17,902,653 112,011,927 18,668,654.50 36,571,308 $54,612.08 Field/Pool Quantities and Allocated Costs Totals: 17,902,653 112,011,927 18,668,655 36,571,308 $54,612.08 NORTHSTAR, UNDEFINED WDSP { 935,119 0 0.00 935,119 $1,396.42 ( Field/Pool Quantities and Allocated Costs Totals: 935,119 0 0 935,119 $1,396.42 PRUDHOE BAY. AURORA OIL 5,882,847 12,609,285 2,101,547.50 7,984,395 $11,923.13 Field/Pool Quantities and Allocated Costs Totals: 5,882,847 12,609,285 2,101,548 7,984,395 $11,923.13 PRUDHOE BAY. BOREALIS OlL 11,542,132 9,680,877 1,613,479.50 13,155,612 $19,645.33 Field/Pool Quantities and Allocated Costs Totals: 11,542,132 9,680,877 1,613,480 13,155,612 $19,845.33 PRUDHOE BAY. LIS UNDEFINE WDSP 30,449,188 0 0.00 30,449,188 $45,469.89 Field/Pool Quantities and Allocated Costs Totals: 30,449,188 0 0 30,449,188 $45,469.89 PRUDHOE BAY. LISBURNE OIL 3,065,191 115,958,730 19,326,455.00 22,391,646 $33,437,53 Field/Pool Quantities and Allocated Costs Totals: 3,065,191 115,958,730 19,326,455 22,391,846 $33,437.53 PRUDHOE BAY. MIDNIGHT SUN OIL 9,866,876 9,878,600 1,646,433.33 11,513,309 $17,192,87 f Field/Pool Quantities and Allocated Costs Totals: 9,866,876 9,878,600 1,846,433 11,513,309 $17,192.87 PRUDHOE BAY. N PRUDHOE BAY OlL ( 0 0 0.00 0 $0,00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 Tu!j'day, September 23, 20 8:43 AM Page30f17 2003 Annual ProductžonllnjectžonlDžsposal Volumes For Allocatžon of Regulatory Cost Charge For FY 2004 $3,673,873.00 Finalized Budget OperatorName Field/Pool Name Gros.f Liquid (Stb) Gross Ga,f (M~'cf) Gas BOE Total Volume (Liq+BOE) Allocated CO.ft BP EXPLORATION (ALASKA) INC ( PRUDHOE BAY, NIAK IV-SR UN OIL 2 0 0.00 Field/Pool Quantities and Allocated Coats Tota13: 2 0 0 PRUDHOE BAY, NIAKUK OIL 23,937,817 4,287,368 714,561.33 Field/Pool Quantities and Allocated Coats Totala: 23,937,817 4,287,368 714,561 PRUDHOE BAY, ORION UNDEF OIL 97,105 57,905 9,650.83 Field/Pool Quantities and Allocated Coats Totala: 97,105 57,905 9,651 PRUDHOE BAY, POLARIS OIL 765,900 1,181,670 196,945.00 FieldIPool Quantities and Allocated Coats Totala: 765,900 1,181,670 196,945 PRUDHOE BAY, PRUD UNDEFIN WDSP 56,279,190 0 0.00 Field/Pool Quantities and Allocated Coats Totala: 56,279,190 0 0 PRUDHOE BAY, PRUDHOE OIL 538,502,390 5,332,416,590 888,736,098.33 FieldIPool Quantities and Allocated Coats Totala: 538,502,390 5,332,416,590 888, 736, 098 PRUDHOE BAY, W BCH TR UN WTRSP 0 0 0.00 Field/Pool Quantities and Allocated Coats Totala: 0 0 0 PRUDHOE BAY, W BEACH OIL 2,609,580 47,901 7,983.50 Field/Pool Quantities and Allocated Coats Totala: 2,609,580 47,901 7,984 PT MCINTYRE, PT MCINTYRE OIL FieldIPool Quantities and Allocated Coats Totala: 67,387,084 67,387,084 112,543,640 112,543,640 18,757,273.33 18,757,273 2 $0.00 2 $0.00 24,652,378 $36,813.49 24,652,378 $36,813.49 106,756 $159.42 106,756 $159.42 962,845 $1,437.82 962,845 $1,437.82 56,279,190 $84,041.94 56,279,190 $84,041.94 1,427,238,488 $2,131,300.85 1,427,238,488 $2,131,300.85 0 $0.00 0- $0.00 2,617,564 $3,908.82 2,617,564 $3,908.82 86,144,357 $128,639.71 86,144,357 $128,639.71 1,919,138,728 $2,865,857.4 ( ( mnarv/or BP EXPLOR4T10N (ALASKA) fNC (29 recordsj Operator Quantities and Allocated C03t3 Tota/a: 918,079,056 6,006,358,032 1,001,059,672 Tuesday, September 23, 20 8:43 AM Page4of17 2003 Annual ProductžonllnjectžonlDžsposal Volumes For Allocatžon of Regulatory Cost Charge For FY 2004 $3,673,873.00 Finalized Budget OperatorName Field/Pool Name Gros~' Liquid (Stb) Gros~' Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated CO,\.t CONOCOPHILLIPS ALASKA INC BELUGA RIVER, UNDEFINED GAS 0 44,038,839 7,339,806.50 7,339,807 $10,960.56 Field/Pool Quantitiea and Allocated Coats Tota13: 0 44,038,839 7,339,807 7,339,807 $10,960.56 BELUGA RIVER, UNDEFINED WDSP 11,169 0 0.00 11,169 $16.68 Field/Pool Quantitiea and Allocated Coat3 Totala: 11,169 0 0 11,169 $16.68 COLVILLE RIVER, ALPINE OIL 67,076,815 74,881,440 12,480,240.00 79,557,055 $118,802.86 Field/Pool Quantities and Allocated Coats Totala: 67,076,815 74,881,440 12,480,240 79,557,055 $118,802.86 / COLVILLE RIVER, NANUQ UNDF OIL 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Coats Totala: 0 0 0 0 $0.00 COLVILLE RIVER, UNDEFINED WDSP 421,143 0 0.00 421,143 $628.89 Field/Pool Quantities and Allocated Coat3 Totala: 421,143 0 0 421,143 $628.89 KUP ARUK RIVER, CRETACEO U WDSP 468,872 0 0.00 468,872 $700.17 Field/Pool Quantities and Allocated Coats Totala: 468,872 0 0 468,872 $700.17 KUP ARUK RIVER, KUP ARUK RV OIL 277,152,042 182,095,129 30,349,188.17 307,501,230 $459,192.80 Field/Pool Quantities and Allocated Coats Totala: 277,152,042 182,095, 129 30,349,188 307,501,230 $459,192.80 KUPARUK RIVER, MELTWATER OIL 2,901,883 10,489,658 1,748,276.33 4,650,159 $6,944.10 Field/Pool Quantities and Allocated Coats Tota13: 2,901,883 10,489,658 1,748,276 4,650,159 $6,944.10 KUP ARUK RIVER, TABASCO OIL 6,616,362 158,610 26,435.00 6,642,797 $9,919.71 FieldIPool Quantities and Allocated Coats Totala: 6,616,362 158,610 26,435 6,842,797 $9,919.71 ( KUPARUK RIVER, TARN OIL ( 33,481,211 29,856,741 4,976,123.50 38,457,335 $57,428.49 Field/Pool Quantities and Allocated Coats Totala: 33,481,211 29,856,741 4,976,124 38,457,335 $57,428.49 Tuesday, September 23, 20 8:43 AM Page50f17 2003 Annual ProductžonllnjectžonlDžsposal Volumes For Allocatžon of Regulatory Cost Charge For FY 2004 $3,673,873.00 Finalized Budget OperatorName Field/Pool Name Gros,f Liquid (Stb) Gross Gas (Mscf) Ga.s BOE Total Volume (Liq+BOE) Allocated Co~.t CONOCOPHILLIPS ALASKA INC KUP ARUK RIVER, WEST SAK OIL Field/Pool Quantitiea and Allocated Coats Totala: 7,517,489 7,517,489 635,063 635,063 105,843.83 105,844 7,623,333 7,623,333 $11.383.95 $11,383.95 Summary/or CONOCOPl1lLUPS ALASKA lNC (l ¡ records) Operator Quantities and Allocated Costs Totals: 395,646,986 342,155,480 57,025,913 452,672,899 $675,978.22 ( / ~ Tuesltay, September 23, 20 8:43 AM Page6of17 2003 Annual ProductžonllnjectžonlDžsposal Volumes For Allocatžon of Regulatory Cost Charge For FY 2004 $3,673,873.00 Finalized Budget OperatorName Field/Pool Name Gros.\' Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost FOREST OIL CORP REDOUBT SHOAL, UNDEFINED OIL 46,328 7,829 1,304.83 47,633 $71.13 Field/Pool Quantities and Allocated Costs Totals: 46,328 7,829 1,305 47,633 $71.13 REDOUBT SHOAL, UNDEFINED WDSP 99,172 0 0.00 99,172 $148.09 Field/Pool Quantities and Allocated Costs Tota13: 99,172 0 0 99,172 $148.09 W FORELAND, UNDEFINED GAS 0 60,065 10,010.83 10,011 $14.95 Field/Pool Quantities and Allocated Costs Totala: 0 60,065 10,011 10,011 $14.95 W MCARTHRIV UNDEFINED WDSP ( 456,488 0 0.00 456,488 $681.68 ( Field/Pool Quantities and Allocated Costs Tota13: 456,488 0 0 456,488 $681.68 W MCARTH RIV, W MCARTH RIV OIL 1,018,398 239,324 39,887.33 1,058,285 $1,580.34 Field/Pool Quantities and Allocated Costs Totals: 1,018,398 239,324 39,887 1,058,285 $1,580.34 Summary/or FOREST OIL CORP (5 record,) Operator Quantities and Allocated Costs Totals: 1,620,386 307,218 51,203 1,671,589 $2,496.19 r ( Tuesday, September 23, 20 8:43 AM Page 70f17 2003 Annual ProductžonllnjectžonlDžsposal Volumes For Allocatžon of Regulatory Cost Charge For FY 2004 $3,673,873.00 Finalized Budget OperatorName Field/Pool Name Gro.f.\' Liquid (Stb) Gros.s Gas (Mscf) Ga.s BOE Total Volume (Liq+BOE) Allocated Co.\'t MARATHON OIL CO BEAVER CREEK, BEAVER CREEK OIL 79,481 23,082 3,847.00 83,328 $124.43 Field/Pool Quantities and Allocated Costs Totals: 79,481 23,082 3,847 83,328 $124.43 BEAVER CREEK, BELUGA GAS 0 7,603,847 1,267,307.83 1,267,308 $1,892.48 Field/Pool Quantities and Allocated Costs Totals: 0 7,603,847 1,267,308 1,267,308 $1,892.48 BEA VER CREEK, STERLING GAS 0 292,152 48,692.00 48,692 $72.71 Field/Pool Quantities and Allocated Costs Totals: 0 292,152 48,692 48,692 $72.71 BEA VE."'R CREEK, TYONEK UNDEF GAS ( 0 629,103 104,850.50 104,851 $156.57 Field/Pool Quantities and Allocated Costs Tota13: 0 629,103 104,851 104,851 $156.57 BEA VER CREEK, UNDEFINED WDSP 27,200 0 0.00 27,200 $40.62 Field/Pool Quantities and Allocated Costs Totala: 27,200 0 0 27,200 $40.62 KENAI, BELUGA UNDEFINED GAS 0 5,445,233 907,538.83 907,539 $1,355.23 Field/Pool Quantities and Allocated Costs Totals: 0 5,445,233 907,539 907,539 $1,355.23 KENAI, c.L. U. BELUGA GAS 0 1,341,468 223,578.00 223,578 $333.87 Field/Pool Quantities and Allocated Costs Totals: 0 1,341,468 223,578 223,578 $333.87 KENAI, c.L. U. STERLING UND GAS 0 3,343,610 557,268.33 557,268 $832.17 Field/Pool Quantities and Allocated Costs Totals: 0 3,343,610 557,268 557,268 $832.17 KENAI, c.L.u. UPPER TYONEKGAS 0 330,578 55,096.33 55,096 $82.28 Field/Pool Quantities and Allocated Costs Tota13: 0 330,578 55,096 55,096 $82.28 ( KENAI, STERLING 3 GAS ( 0 1,368,955 228,159.17 228,159 $340.71 Field/Pool Quantities and Allocated Costs Total3: 0 1,368,955 228,159 228,159 $340.71 Tuesday, September 23, 20 8:43 AM Page 8 of 17 2003 Annual ProductžonllnjectžonlDžsposal Volumes For Allocatžon of Regulatory Cost Charge For FY 2004 $3,673,873.00 Finalized Budget OperatorName Field/Pool Name Gross Liquid (Stb) Gross Gus (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Co.\'t MARATHON OIL CO KENAI, STERLING 4 GAS 0 3,667,281 611,213.50 611,214 $912.73 Field/Pool Quantities and Allocated Costs Totals: 0 3,667,281 611,214 611,214 $912.73 KENAI, STERLING 5.1 GAS 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Tota13: 0 0 0 0 $0.00 KENAI, STERLING 6 GAS 0 6,622,640 1,103,773.33 1,103,773 $1,648.27 Field/Pool Quantities and Allocated Costs Totals: 0 6.622,640 1,103,773 1,103,773 $1,648.27 KENAI, TYONEK GAS ( 0 5,050,052 841,675.33 841,675 $1,256.88 Field/Pool Quantities and Allocated Costs Tota13: 0 5,050,052 841,675 841,675 $1,256.88 KENAI, UNDEFINED WDSP 163,684 0 0.00 163,684 $244.43 Field/Pool Quantities and Allocated Costs Tota13: 183,684 0 0 183,684 $244.43 KENAI, UNDEFINED WDSP G&I 193,386 0 0.00 193,386 $288.78 Field/Pool Quantities and Allocated Coats Totals: 193,386 0 0 193,386 $288.78 STERLING, BELUGA UNDEFINED GAS 0 220,213 36,702.17 36,702 $54.81 Field/Pool Quantities and Allocated Costs Totals: 0 220,213 36,702 36,702 $54.81 STERLING, TYONEK UNDEFINED GAS 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Tota13: 0 0 0 0 $0.00 STERLING, UNDEFINED GAS 0 331,792 55,298.67 55,299 $82.58 FieldIPool Quantities and Allocated Costs Totala: 0 331,792 55,299 55,299 $82.58 ( TRADING BAY, G-NE/HEMLK-NE OIL ( 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 Tuesday, September 23, 20 8:43 AM Page 9 of 17 2003 Annual ProductžonllnjectžonlDžsposal Volumes For Allocatžon of Regulatory Cost Charge For FY 2004 $3,673,873.00 Finalized Budget OperatorName Field/Pool Name Gro,ss Liquid (Stb) Gros~' Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated co.\.t MARATHON OIL CO TRADING BAY, HEMLOCK OIL 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 TRADING BA Y, MID KENAI D OIL 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Tota13: 0 0 0 0 $0.00 TRADING BAY, MID KENAI E OIL 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 10.00 TRADING BAY, UNDEFINED GAS ( 0 0 0.00 0 $0.00 ( Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 10.00 TRADING BAY, UNDEFINED WDSP 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 10.00 TRADING BAY, W FORELAND OIL 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 WOLF LAKE, BEL-TYON UNDEF GAS 0 299,527 49,921.17 49,921 $74.55 Field/Pool Quantities and Allocated Costs Totals: 0 299,527 49,921 49,921 174.55 SummwJ'}òr MARATHON OIL CO (27 records) Operator Quantities and Allocated Costs Totals: 463,751 36,569,533 6,094,922 6,558,673 $9,794.09 ! \ ( Tuesday, September 23, 20 8:43 AM Page 10 of 17 2003 Annual ProductžonllnjectžonlDžsposal Volumes For Allocatžon o.fRegulatory Cost Charge For FY 2004 $3,673,873.00 FinalizedBudget OpemtorName Field/Pool Name Gron' Liquid (Stb) Gro.ss Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost NORTH SLOPE BOROUGH BARROW, EAST BARROW GAS Field/Pool Quantities and Allocated Costs Totals: BARROJ1~ SOUTH BARROW GA.S 0 0 92,511 15,418.50 92,511 15,419 60,933 10,155.50 60,933 10,156 1,251,033 208,505.50 1,251,033 208,506 1,404,477 234,080 15,419 $23.02 15,419 $23.02 10,156 $15.17 10,156 $15.17 208,506 $311.36 208,506 $311.36 234,080 $349.55 Field/Pool Quantities and Allocated Costs Totals: WALAKPA, WALAKPA GAS 0 0 Field/Pool Quantities and Allocated Costs Totals: 0 0 SlImmw}'jÓr ;VORIHSLOPEBOROUC;lJ(3 records) ( ( Operator Quantities and Allocated Costs Totals: 0 ( ( Tue,,-day, September 23, 20 8:43 AM Page 11 of17 2003 Annual ProductžonllnjectžonlDžsposal Volumes For Allocatžon of Regulatory Cost Charge For FY 2004 $3,673,873.()() Finalized Budget OperatorName Field/Pool Name Gros.\' Liquid (Stb) Gros.s Ga,f (Mscf) Gas BOE Total Volume (Lic¡+BOE) Allocated Co.\'t PHILLIPS PETROLEUM CO NORTH COOK IlVLET, TERTIARY GAS Field/Pool Quantities and Allocated Costs Totals: NORTH COOK INLET, UNDEF WDSP 0 0 54,574,242 9,095,707.00 54,574,242 9,095,707 0 0.00 0 0 54,574,242 9,095,707 9,095,707 $13,582.66 9,095,707 $13,582.66 2,050 $3.06 2,050 $3.06 9,097,757 $13,585.72 Field/Pool Quantities and Allocated Costs Tota13: 2,050 2,050 SummmJ'jòr PHILLIPS PETROLEUM CO!2 recordsj Operator Quantities and Allocated Coats Totals: 2,050 { I \ Tuesday, September 23, 20 8:43 AM Pagel2 of 17 2003 Annual ProductžonllnjectžonlDžsposal Volumes For Allocatžon of Regulatory Cost Charge For FY 2004 $3,673,873.()() Finalized Budget OperatorName Field/Pool Name Grtm Liquid (Stb) Gross Ga.\' (M~'cf) Ga,s BOE Total Volume (Liq+BOE) Allocated Cost UNION OIL CO OF CALIFORNIA GRANITE PT, HEMLOCK UlI/DEF OIL 45,554 49,187 8,197.83 53,752 $80.27 Field/Pool Quantities and Allocated Costs Totals: 45,554 49,187 8,198 53,752 $80.27 GRANITE PT, MIDDLE KENAI OIL 2,851,943 1,508,608 251,434.67 3,103,378 $4,634.29 Field/Pool Quantities and Allocated Costs Totals: 2,851,943 1,508,608 251,435 3,103,378 $4,634.29 GRANITE PT, UNDEFINED GAS 0 99,776 16,629.33 16,629 $24.83 Field/Pool Quantities and Allocated Costs Totals: 0 99, 776 16,629 16,629 $24.83 GRANITE PT, UNDEFINED WDSP G&I ( 113,135 0 0.00 113,135 $168.94 ( Field/Pool Quantities and Allocated Costs Totala: 113,135 0 0 113,135 $168.94 IV AN RIVER, UNDEFINED GAS 0 4,303,293 717,215.50 717,216 $1,071.02 Field/Pool Quantities and Allocated Costs Tota13: 0 4,303,293 717,216 717,216 $1,071.02 IVAN RIVER, UNDEFINED WDSP 24,675 0 0.00 24,675 $36.85 Field/Pool Quantities and Allocated Costs Totals: 24,675 0 0 24,675 $36.85 LEWIS RIVER, UNDEFINED GAS 0 898,166 149,694.33 149,694 $223.54 Field/Pool Quantities and Allocated Coats Tota13: 0 898,166 149,694 149,694 $223.54 LEWIS RIVER, UNDEFINED WDSP 2,486 0 0.00 2,486 $3.71 Field/Pool Quantities and Allocated Costs Totals: 2,486 0 0 2,486 $3.71 MCARTHUR RIVER HEMLOCK OIL 33,370,365 1,977,203 329,533.83 33,699,899 $50,324.19 Field/Pool Quantities and Allocated Costs Tota13: 33,370,365 1,977,203 329,534 33,699,899 $50,324.19 ( MCARTHUR RIVER, MIDKENAI G OIL ( 7,631,209 796,228 132,704.67 7,763,914 $11,593.88 Field/Pool Quantities and Allocated Costs Tota13: 7,631,209 796,228 132,705 7,763,914 $11,593.88 Tuesltay, September 23, 20 8:43 AM Page 13 of 17 2003 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2004 $3,673,873.00 Finalized Budget OperatorName FieldIPool Name Gro,s.\' Liquid (Stb) Gros~' Ga,~ (Mscf) Ga,~ HOE Total Volume (Liq+HOE) Allocated Co~,t UNION OIL CO OF CALIFORNIA MCARTHUR RIVER, MIDKENAI GAS 0 48,674,161 8,112,360.17 8,112,360 512,114.22 Field/Pool Quantities and Allocated Costs Totals: 0 48.674,161 8,112,360 8.112,360 $12,114.22 MCARTHUR RIVER, UNDEFINED OIL 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 MC4RTHUR RIVER, W FORELAND OIL 2,809,520 67,483 11,247.17 2,820,767 $4,212.26 Field/Pool Quantities and Allocated Costs Totals: 2,809,520 67,483 11.247 2,820,767 $4,212.26 ( MIDDLE GROUND SHOAL, A OIL 788,593 67,938 11,323.00 799,916 $1,194.52 Field/Pool Quantities and Allocated Costs Totals: 788,593 67.938 11,323 799,916 $1,194.52 MIDDLE GROUND SHOAL, B,C,D OIL 238,390 45,639 7,606.50 245,997 $367.35 Field/Pool Quantities and Allocated Costs Totals: 238,390 45,639 7,607 245,997 $367.35 MIDDLE GROUND SHOAL, E,F,G OIL 636,023 150,181 25,030.17 661,053 $987.15 Field/Pool Quantities and Allocated Costs Totals: 636,023 150,181 25,030 661,053 $987.15 MIDDLE GROUND SHOAL, UNDEF GAS 0 186,116 31,019.33 31,019 $46.32 Field/Pool Quantities and Allocated Costs Totals: 0 186,116 31,019 31,019 $46.32 PRETTY CREEK, UNDEFINED GAS 0 1,358,634 226,439.00 226,439 $338.14 Field/Pool Quantities and Allocated Costs Totals: 0 1,358,634 226,439 226,439 $338.14 STUMP LAKE, UNDEFINED GAS 0 0 0.00 0 $0.00 ( Fieid/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 ( SWANSON RIVER, GAS STORAGE 0 1,627,339 271,223.17 271,223 $405.02 Field/Pool Quantities and Allocated Costs Totals: 0 1.627,339 271.223 271.223 $405.02 Tuest/ay. September 23, 20 8:43 AM Page 14 of] 7 2003 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2004 $3,673,873.00 Finalized Budget OperatorName Field/Pool Name Gros,\' Ga.~ (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost Gross Liquid (Stb) UNION OIL CO OF CALIFORNIA SWANSON RIVER, HÐ.4UX'K OIL Field/Pool Quantities and Allocated Costs Totals: SWANSON RIVER, UNDEFINED GAS Field/Pool Quantities and Allocated Costs Totals: SWANSON RIVER, UNDEFINED WDSP ( Field/Pool Quantities and Allocated Costs Totals: TRADING BA Y, HEMLOCK OIL Field/Pool Quantities and Allocated Costs Totals: TRADING BAY, MID KENAI BOIL Field/Pool Quantities and Allocated Costs Totals: TRADING BAY, MID KENAI COIL Field/Pool Quantities and Allocated Costs Totals: TRADING SA Y, MID KENAI D OIL Field/Pool Quantities and Allocated Costs Totals: TRADING SA Y, MID KENAI E OIL Field/Pool Quantities and Allocated Costs Totals: TRADING BAY, UNDEFINED OIL r ( Field/Pool Quantities and Allocated Costs Totals: mmarv,Íor UNION OiL CO OF CALIFORNIA (29 records) Operator Quantities and Allocated Costs Totals: Tuesday, September 23. 20 8:43 AM 476,552 476,552 2,577,467 2,577,467 1,622,155 1,622,155 110,056 110,056 175,847 175,847 53,644,060 78,368 78,368 76,381 76,381 15,341 15,341 0 0 13,136,517 2,189,419.50 2,665,972 $3,981.11 13,136,517 2,189,420 2,665,972 $3,981.11 1,832,360 305,393.33 305,393 $456.05 1,832.360 305,393 305,393 $456.05 0 0.00 2,577,467 $3,848.94 0 0 2,577,467 $3,848.94 220,568 36,761.33 1,658,916 $2,477.27 220,568 36,761 1,658,916 $2,477.27 37,133 6,188.83 84,557 $126.27 37,133 6,189 84,557 $126.27 88,833 14,805.50 124,862 $186.46 88,833 14,806 124,862 $186.46 70,200 11,700.00 187,547 $280.06 70,200 11,700 187,547 $280.06 24,307 4,051.17 80,432 $120.11 24,307 4,051 80,432 $120.11 8,408 1,401.33 16,742 $25.00 8,408 1,401 16,742 $25.00 77,228,278 12,871,380 66,515,440 $99,327.77 Page 15 of 17 2003 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2004 $3,673,873.00 Finalized Budget OperatorName Field/Pool Name Gross Liquid (Stb) Gros~' Gas (M~'cf) Gas BOE Total Volume (Liq+BOE) Allocated co~.t XTO ENERGY INC MIDDLE GROUND SHOAL, B,C,D OIL Field/Pool Quantities and Allocated Costs Totals: MIDDLE GROUND SHOAL, E,F,G OIL 6,176 6,176 4,347 724.50 4,347 725 463,293 77,215.50 463,293 77,216 0 0.00 0 0 467,640 77,940 6,901 $10.30 6,901 $10.30 4,181,981 $6,244.97 4,181,981 $6,244.97 52,356 $78.18 52,356 $78.18 4,241,237 $6,333.46 Field/Pool Quantities and Allocated Costs Totals: MIDDLE GROUND SHOAL, UNDF WDSP 4,104,765 4,104,765 Field/Pool Quantities and Allocated Costs Totals: 52,356 52,356 ( SllmmClly!Òr XTO ENERGY IlYC (3 record'j Operator Quantities and Allocated Costs Totals: 4,163,297 ( ( Tuest/ay, September 23, 20 8:43 AM Page 16 of 17 2003 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2004 $3,673,873.00 Finalized Budget OperatorName Field/Pool Name Gro.f.~ Liquid (Stb) Gross Ga,~ (M~'cf) Gas BOE Total Volume (Liq+BOE) Allocated co.~t Report Qualltities am! Allocated Costs Totals: LJ:373:6Ï'9J86] ¡--6:519:669~95Ol1 ],O86,¡;i¡;;ji¡ 1----- --------],460,23 ],2441 i~73:OOl ( ( ( Tuesllay, September 23. 20 8:43 AM Page 17of17 #1 "..--.. FY 04 Regulatory Cost Charges Estimate FY2004 Operating Appropriation $ FY2004 Capital Appropriation $ FY2004 Appropriation $ Less Federal Receipts $ Total Designated Program Rec $ Less Estimated Permit Fees $ Less Estimated 2003 Lapse $ Total to use for Reg Cost Chgs $ Final FY20 Operating Appropriation $ , FY2004 C 'tal Appropriation FY2004 Appro' tion Less Federal Rece Total Design Program Less Es' ated Permit Fees Les ctual 2003 Lapse $ Total to use for Reg Cost Chgs $ -.- SCANNED SEP 052003 .~ ~\o\ \C- 1Y\e¿f1(\~ 9h6 q ÜU'Y\ 4,232,800 50,000 4,282,800 119,900 4,162,900 20,000 455,000 3,687,900 4, ,00 50,000 $ 4,282,800 $ 119,900 $ 4,162,900 0,000,00 t\1o\- V\~QL llV\,"\-"\L t\À'lc\ -~. 4,142,900 ~" AOGCC Authorized Budget Explanation of Changes in Budget AOGCC Receipts Only Capital Budget Ch 2/SLA 99 Sec 61 FY 2000 FY 2001 $ 321,900 Operating Budget Ch 84/SLA99 $ 2,601,300 Ch 133/SLAOO $ 2,768,300 Ch 89/SLAOO Ch 105/SLAOO Ch /SLAOO Did not charge operators $ $ $ $ 200 2,200 35,900 38,300 FY01 Final Authorized $ 2,806,600 FY02 Increments Tech Staff Increases ($61.9); Reclass 2 stat techs ($6.9); reclass acctg clerk ($4.6); addtl travel for meetings/training ($25.0); addt'l training costs ($8.0) Additional Lease Costs Dbase Dev, Implementation & Data Mgt (Adm Ck I) Additional Contract Labor Costs FY02 Budget Request Budget Am - Tech Staff Salary Increases Budget Am - North Slope Lease Space Costs Ch 60/SLA01 FY03 Increments Increased Drilling Activity Costs Salary Adjustments & Position Reclassification Costs Year 3 Labor Costs FY03 Operating Budget Request Estimated FY03 Capital Costs: Ch 1/SLA02 -- AR 07588 AK Gas Development Study Ch 1/SLA02 -- AR 07594 Electronic Permitting Initiative FY03 Total FY 2002 $ 106,400 $ 50,000 $ 137,700 $ 10,600 $ 3,111,300 $ 1 80,000 $ 26,000 $ 3,31 7,300 FY04 Increments Continuation COLA Funding (Commissioners & Technical Staff) Annualize FY2003 COLA Increase for Gen Govt & Supvr Bargaining Units Health Insurance Increase for Non-covered Staff Health Insurance Increase for Bargaining Unit Staff FY04 Operating Budget Request Estimated FY04 Capital Costs: Ch 1/SLA02 -- AR 07588 AK Gas Development Study Ch 1/SLA02 -- AR 07594 Electronic Permitting Initiative FY04 Total ~ FY 2003 $ 562,500 $ 118,100 $ 48,300 $ 4,046,200 $ 1 50,000 $ 140,000 4,336,200 FY 2004 $ 40,000 $ 3,300 $ 1 7,1 00 $ 6,300 $ 4,112,900 $ $ 50,000 $ 4,162,900 A $ 2,923,200 $ 2,768,300 $ 3,317,300 $ 4,336,200 $ 4,162,900 Regulatory Cost Charge 5 year Comparison FY 2000 FY 2001 FY 2002 FY 2003 FY 2004 Aurora Gas LLC $ - $ - $ - $ 79.44 $ 69,66 BP Exploration (Alaska), Inc $ 839,499.00 $1,960,829.69 $2,475,365,81 $ 3,248,915.69 $ 2,848,594.00 ( ConocoPhillips Alaska Inc $1,955,178.00 $ 441,678.51 $ 499,158.60 $ 783,548.36 $ 687,014.91 Exxon Corporation $ - $ - $ - $ 11,09 $ 9.72 Forest Oil Corporation $ 2,616.00 $ 2,369.06 $ 2,616.38 $ 3,981.96 $ 3,491.38 Marathon Oil Company $ 3,494.00 $ 2,990,72 $ 4,979.44 $ 9,775.34 $ 8,571.01 North Slope Borough $ 255.00 $ 243,78 $ 300.30 $ 421.95 $ 369,97 Ocean Energy $ - $ . 2,81 $ - $ - $ - Phillips Petroleum Company $ 10,326.00 $ 8,631.55 $ 10,728,63 $ 15,880,91 $ 13,924.37 Union Oil Company of California $ 96,319,00 $ 87,313.06 $ 95,304,39 $ 136,111,66 $ 119,302.12 XTO Energy Inc (Cross Timbers) $ 5,513,00 $ 4,589.68 $ 5,330.66 $ 7,473.60 $ 6,552.86 Totals $ 2,913,200.00 $ 2,508,648.86 $ 3,093,784.21 $ 4,206,200.00 $ 3,687,900.00 ( A F L Totals $2,923,200.00 $2,768,300.00 $3,317,300.00 $4,336,200.00 $4,162,900.00 $ 10,000,00 $ 15,000.00 $ 20,000.00 $ 20,000.00 $ 20,000,00 $ - $ 244,651,14 $ 203,515.79 $ 121,200,74 $ 455,000.00 $2,913,200.00 $2,508,648.86 $3,093,784,21 $4,194,999,26 $ 3,687,900.00 FYO4 AOGCC Regulatory Cost Charges t. Aurora Gas LLC BP Exploration (Alaska), Inc ConocoPhillips Inc Exxon Corporation Forest Oil Corporation Marathon Oil Company North Slope Borough Phillips Petroleum Company Union Oil Company of California XTO Energy Inc Totals ( Total Projected Due $ 69.66 $ 2,848,594.00 $ 687,014.91 $ 9,72 $ 3,491,38 $ 8,571,01 $ 369.97 $ 13,924.37 $ 119,302.12 $ 6,552,86 $ 3,687,900,00 1/4 Payment Remainder Due $ 17.42 $ 52,25 $ 712,148,50 $ 2,136,445.50 $ 171,753.73 $ 515,261.18 $ 2.43 $ 7.29 $ 872,85 $ 2,618,54 $ 2,142.75 $ 6,428,26 $ 92.49 $ 277.48 $ 3,481,09 $ 10,443,28 $ 29,825.53 $ 89,476,59 $ 1,638,22 $ 4,914.65 $ 921,975.00 $ 2,765,925.00 ~ "..--.. INVOICE AND NOTICE OF ESTIMATED REGULATORY COST CHARGE To: Aurora Gas LLC Attention: Ed Jones, Vice President 10333 Richmond Avenue, Suite 710 Houston, TX 77042 YOU ARE NOTIFIED that the Alaska Oil and Gas Conservation Commission has determined pursuant to AS 31.05.093 and 20 MC 25.610 that your estimated regulatory cost charge for the first quarter of fiscal year 2004 is $17.42 and the payment date for this charge is September 15, 2003. Under 20 MC 25.610, you are required to pay this charge not later than the payment date. Please make your check payable to: Mail or deliver payment to: State of Alaska/AOGCC AOGCC 333 West th Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. In accordance with 20 MC 25.610, your estimated cost charge was computed as one-fourth of the Commission's reasonable estimate, based on available information, of what your actual annual regulatory cost charge will be for fiscal year 2004, using the formula set out in 20 MC 25.605. For your information, the volume data and calculations used for this purpose are summarized in the attached spreadsheet. The appropriation for the Commission's operating and capital costs for fiscal year 2004, less federal receipts of $119,900 is $4,162,900. The Commission's estimate of the total fees to be collected under AS 31.05.090 (permit to drill fees) is $20,000. The Commission's estimate of the lapsed amount of fiscal year 2003 appropriations included in the fiscal 2004 appropriation is $455,000. Later in the fiscal year, after final information is available to the Commission for calculating actual regulatory cost charges, you will receive notice of your proposed actual annual regulatory cost charge for fiscal year 2004. At that time you will have an opportunity to submit comments on or request a revision to the proposed regulatory cost charge, and a hearing will be held before the Commission determines the final charges. Your estimated first quarter regulatory cost charge payment will be credited against your final charge. The Commission's regulations do not provide for objections or revisions to estimated regulatory cost charges. However, if you find what you believe may be errors in the Commission's determination of your estimated regulatory cost charge, you are invited to inform the Commission so that the Commission will be better prepared to determine actual regulatory cost charges in an expeditious manner. Date: August 13, 2003 Sarah H. Palin, Chair ~ /' INVOICE AND NOTICE OF ESTIMATED REGULATORY COST CHARGE To: BP Exploration (Alaska), Inc Attention: Richard Campbell, President P.O. Box 196612 Anchorage, AK 99519-6612 YOU ARE NOTIFIED that the Alaska Oil and Gas Conservation Commission has determined pursuant to AS 31.05.093 and 20 AAC 25.610 that your estimated regulatory cost charge for the first quarter offiscal year 2004 is $712,148.50 and the payment date for this charge is September 15, 2003. Under 20 AAC 25.610, you are required to pay this charge not later than the payment date. Please make your check payable to: Mail or deliver payment to: State of Alaska/AOGCC AOGCC 333 West ih Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. In accordance with 20 AAC 25.610, your estimated cost charge was computed as one-fourth of the Commission's reasonable estimate, based on available information, of what your actual annual regulatory cost charge will be for fiscal year 2004, using the formula set out in 20 AAC 25.605. For your information, the volume data and calculations used for this purpose are summarized in the attached spreadsheet. The appropriation for the Commission's operating and capital costs for fiscal year 2004, less federal receipts of $119,900 is $4,162,900. The Commission's estimate of the total fees to be collected under AS 31.05.090 (permit to drill fees) is $20,000. The Commission's estimate of the lapsed amount of fiscal year 2003 appropriations included in the fiscal 2003 appropriation is $455,000. Later in the fiscal year, after final information is available to the Commission for calculating actual regulatory cost charges, you will receive notice of your proposed actual annual regulatory cost charge for fiscal year 2004. At that time you will have an opportunity to submit comments on or request a revision to the proposed regulatory cost charge, and a hearing will be held before the Commission determines the final charges. Your estimated first quarter regulatory cost charge payment will be credited against your final charge. The Commission's regulations do not provide for objections or revisions to estimated regulatory cost charges. However, if you find what you believe may be errors in the Commission's determination of your estimated regulatory cost charge, you are invited to inform the Commission so that the Commission will be better prepared to determine actual regulatory cost charges in an expeditious manner. Date: August 13, 2003 Sarah H. Palin, Chair ~. r--- INVOICE AND NOTICE OF ESTIMATED REGULATORY COST CHARGE To: ConocoPhillips Inc. Production Revenue Accounting Attention: Noel Dike ATO-1668 P.O. Box 100360 Anchorage, AK 99510 YOU ARE NOTIFIED that the Alaska Oil and Gas Conservation Commission has determined pursuant to AS 31.05.093 and 20 AAC 25.610 that your estimated regulatory cost charge for the first quarter of fiscal year 2004 is $171,753.73 and the payment date for this charge is September 15, 2003. Under 20 AAC 25.610, you are required to pay this charge not later than the payment date. Please make your check payable to: Mail or deliver payment to: State of Alaska/AOGCC AOGCC 333 West 7th Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. In accordance with 20 AAC 25.610, your estimated cost charge was computed as one-fourth of the Commission's reasonable estimate, based on available information, of what your actual annual regulatory cost charge will be for fiscal year 2004, using the formula set out in 20 AAC 25.605. For your information, the volume data and calculations used for this purpose are summarized in the attached spreadsheet. The appropriation for the Commission's operating and capital costs for fiscal year 2004, less federal receipts of $119,900 is $4,162,900. The Commission's estimate of the total fees to be collected under AS 31.05.090 (permit to drill fees) is $20,000. The Commission's estimate of the lapsed amount of fiscal year 2003 appropriations included in the fiscal 2004 appropriation is $455,000. Later in the fiscal year, after final information is available to the Commission for calculating actual regulatory cost charges, you will receive notice of your proposed actual annual regulatory cost charge for fiscal year 2004. At that time you will have an opportunity to submit comments on or request a revision to the proposed regulatory cost charge, and a hearing will be held before the Commission determines the final charges. Your estimated first quarter regulatory cost charge payment will be credited against your final charge. The Commission's regulations do not provide for objections or revisions to estimated regulatory cost charges. However, if you find what you believe may be errors in the Commission's determination of your estimated regulatory cost charge, you are invited to inform the Commission so that the Commission will be better prepared to determine actual regulatory cost charges in an expeditious manner. Date: August 13, 2003 Sarah H. Palin, Chair ...--" ~ INVOICE AND NOTICE OF ESTIMATED REGULATORY COST CHARGE To: Exxon Corporation Attn: John Erickson P.O. Box 2180 Houston, TX 77252-2180 YOU ARE NOTIFIED that the Alaska Oil and Gas Conservation Commission has determined pursuant to AS 31.05.093 and 20 AAC 25.610 that your estimated regulatory cost charge for the first quarter of fiscal year 2004 is $2.43 and the payment date for this charge is September 15, 2003. Under 20 AAC 25.610, you are required to pay this charge not later than the payment date. Please make your check payable to: Mail or deliver payment to: State of Alaska/AOGCC AOGCC 333 West ih Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. In accordance with 20 AAC 25.610, your estimated cost charge was computed as one-fourth of the Commission's reasonable estimate, based on available information, of what your actual annual regulatory cost charge will be for fiscal year 2004, using the formula set out in 20 AAC 25.605. For your information, the volume data and calculations used for this purpose are summarized in the attached spreadsheet. The appropriation for the Commission's operating and capital costs for fiscal year 2004, less federal receipts of $119,900 is $4,162,900. The Commission's estimate of the total fees to be collected under AS 31.05.090 (permit to drill fees) is $20,000. The Commission's estimate of the lapsed amount of fiscal year 2003 appropriations included in the fiscal 2004 appropriation is $455,000. Later in the fiscal year, after final information is available to the Commission for calculating actual regulatory cost charges, you will receive notice of your proposed actual annual regulatory cost charge for fiscal year 2004. At that time you will have an opportunity to submit comments on or request a revision to the proposed regulatory cost charge, and a hearing will be held before the Commission determines the final charges. Your estimated first quarter regulatory cost charge payment will be credited against your final charge. The Commission's regulations do not provide for objections or revisions to estimated regulatory cost charges. However, if you find what you believe may be errors in the Commission's determination of your estimated regulatory cost charge, you are invited to inform the Commission so that the Commission will be better prepared to determine actual regulatory cost charges in an expeditious manner. Date: August 13, 2003 Sarah H. Palin, Chair .---. /""'- INVOICE AND NOTICE OF ESTIMATED REGULATORY COST CHARGE To: Forest Oil Corporation Attention: Accounts Payable 1600 Broadway, Suite 2200 Denver, CO 80202 YOU ARE NOTIFIED that the Alaska Oil and Gas Conservation Commission has determined pursuant to AS 31.05.093 and 20 AAC 25.610 that your estimated regulatory cost charge for the first quarter of fiscal year 2004 is $872.85 and the payment date for this charge is September 15, 2003. Under 20 AAC 25.610, you are required to pay this charge not later than the payment date. Please make your check payable to: Mail or deliver payment to: State of Alaska/AOGCC AOGCC 333 West ih Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. In accordance with 20 AAC 25.610, your estimated cost charge was computed as one-fourth of the Commission's reasonable estimate, based on available information, of what your actual annual regulatory cost charge will be for fiscal year 2004, using the formula set out in 20 AAC 25.605. For your information, the volume data and calculations used for this purpose are summarized in the attached spreadsheet. The appropriation for the Commission's operating and capital costs for fiscal year 2004, less federal receipts of $119,900 is $4,162,900. The Commission's estimate of the total fees to be collected under AS 31.05.090 (permit to drill fees) is $20,000. The Commission's estimate of the lapsed amount of fiscal year 2003 appropriations included in the fiscal 2004 appropriation is $455,000. Later in the fiscal year, after final information is available to the Commission for calculating actual regulatory cost charges, you will receive notice of your proposed actual annual regulatory cost charge for fiscal year 2004. At that time you will have an opportunity to submit comments on or request a revision to the proposed regulatory cost charge, and a hearing will be held before the Commission determines the final charges. Your estimated first quarter regulatory cost charge payment will be credited against your final charge. The Commission's regulations do not provide for objections or revisions to estimated regulatory cost charges. However, if you find what you believe may be errors in the Commission's determination of your estimated regulatory cost charge, you are invited to inform the Commission so that the Commission will be better prepared to determine actual regulatory cost charges in an expeditious manner. Date: August 13, 2003 Sarah H. Palin, Chair ~ ~ INVOICE AND NOTICE OF ESTIMATED REGULATORY COST CHARGE To: Marathon Oil Company Attention: Accounting Analyst P.O. Box 196168 Anchorage, AK 99519-6168 YOU ARE NOTIFIED that the Alaska Oil and Gas Conservation Commission has determined pursuant to AS 31.05.093 and 20 AAC 25.610 that your estimated regulatory cost charge for the first quarter of fiscal year 2004 is $2,142.75 and the payment date for this charge is September 15, 2003. Under 20 AAC 25.610, you are required to pay this charge not later than the payment date. Please make your check payable to: Mail or deliver payment to: State of Alaska/AOGCC AOGCC 333 West ih Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. In accordance with 20 AAC 25.610, your estimated cost charge was computed as one-fourth of the Commission's reasonable estimate, based on available information, of what your actual annual regulatory cost charge will be for fiscal year 2004, using the formula set out in 20 AAC 25.605. For your information, the volume data and calculations used for this purpose are summarized in the attached spreadsheet. The appropriation for the Commission's operating and capital costs for fiscal year 2004, less federal receipts of $119,900 is $4,162,900. The Commission's estimate of the total fees to be collected under AS 31.05.090 (permit to drill fees) is $20,000. The Commission's estimate of the lapsed amount of fiscal year 2004 appropriations included in the fiscal 2004 appropriation is $455,000. Later in the fiscal year, after final information is available to the Commission for calculating actual regulatory cost charges, you will receive notice of your proposed actual annual regulatory cost charge for fiscal year 2004. At that time you will have an opportunity to submit comments on or request a revision to the proposed regulatory cost charge, and a hearing will be held before the Commission determines the final charges. Your estimated first quarter regulatory cost charge payment will be credited against your final charge. The Commission's regulations do not provide for objections or revisions to estimated regulatory cost charges. However, if you find what you believe may be errors in the Commission's determination of your estimated regulatory cost charge, you are invited to inform the Commission so that the Commission will be better prepared to determine actual regulatory cost charges in an expeditious manner. Date: August 13, 2003 Sarah H. Palin, Chair ~. /"'- INVOICE AND NOTICE OF ESTIMATED REGULATORY COST CHARGE To: North Slope Borough Attention: Richard Glenn, Energy Manager P.O. Box 1120 Barrow, AK 99723 YOU ARE NOTIFIED that the Alaska Oil and Gas Conservation Commission has determined pursuant to AS 31.05.093 and 20 AAC 25.610 that your estimated regulatory cost charge for the first quarter of fiscal year 2004 is $92.49 and the payment date for this charge is September 15, 2003. Under 20 AAC 25.610, you are required to pay this charge not later than the payment date. Please make your check payable to: Mail or deliver payment to: State of Alaska/AOGCC AOGCC 333 West th Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. In accordance with 20 AAC 25.610, your estimated cost charge was computed as one-fourth of the Commission's reasonable estimate, based on available information, of what your actual annual regulatory cost charge will be for fiscal year 2004, using the formula set out in 20 AAC 25.605. For your information, the volume data and calculations used for this purpose are summarized in the attached spreadsheet. The appropriation for the Commission's operating and capital costs for fiscal year 2004, less federal receipts of $119,900 is $4,162,900. The Commission's estimate of the total fees to be collected under AS 31.05.090 (permit to drill fees) is $20,000. The Commission's estimate of the lapsed amount of fiscal year 2003 appropriations included in the fiscal 2004 appropriation is $455,000. Later in the fiscal year, after final information is available to the Commission for calculating actual regulatory cost charges, you will receive notice of your proposed actual annual regulatory cost charge for fiscal year 2004. At that time you will have an opportunity to submit comments on or request a revision to the proposed regulatory cost charge, and a hearing will be held before the Commission determines the final charges. Your estimated first quarter regulatory cost charge payment will be credited against your final charge. The Commission's regulations do not provide for objections or revisions to estimated regulatory cost charges. However, if you find what you believe may be errors in the Commission's determination of your estimated regulatory cost charge, you are invited to inform the Commission so that the Commission will be better prepared to determine actual regulatory cost charges in an expeditious manner. Date: August 13, 2003 Sarah H. Palin, Chair ~, ~ INVOICE AND NOTICE OF ESTIMATED REGULATORY COST CHARGE To: Phillips Petroleum Company Attention: Steve Arbelovsky, Cook Inlet Operations Manager P.O. Box 66 Kenai, AK 99611 YOU ARE NOTIFIED that the Alaska Oil and Gas Conservation Commission has determined pursuant to AS 31.05.093 and 20 AAC 25.610 that your estimated regulatory cost charge for the first quarter of fiscal year 2004 is $3,481.09 and the payment date for this charge is September 15, 2003. Under 20 AAC 25.610, you are required to pay this charge not later than the payment date. Please make your check payable to: Mail or deliver payment to: State of Alaska/AOGCC AOGCC 333 West 7th Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. In accordance with 20 AAC 25.610, your estimated cost charge was computed as one-fourth of the Commission's reasonable estimate, based on available information, of what your actual annual regulatory cost charge will be for fiscal year 2004, using the formula set out in 20 AAC 25.605. For your information, the volume data and calculations used for this purpose are summarized in the attached spreadsheet. The appropriation for the Commission's operating and capital costs for fiscal year 2004, less federal receipts of $119,900 is $4,162,900. The Commission's estimate of the total fees to be collected under AS 31.05.090 (permit to drill fees) is $20,000. The Commission's estimate of the lapsed amount of fiscal year 2003 appropriations included in the fiscal 2004 appropriation is $455,000. Later in the fiscal year, after final information is available to the Commission for calculating actual regulatory cost charges, you will receive notice of your proposed actual annual regulatory cost charge for fiscal year 2004. At that time you will have an opportunity to submit comments on or request a revision to the proposed regulatory cost charge, and a hearing will be held before the Commission determines the final charges. Your estimated first quarter regulatory cost charge payment will be credited against your final charge. The Commission's regulations do not provide for objections or revisions to estimated regulatory cost charges. However, if you find what you believe may be errors in the Commission's determination of your estimated regulatory cost charge, you are invited to inform the Commission so that the Commission will be better prepared to determine actual regulatory cost charges in an expeditious manner. Date: August 13, 2003 Sarah H. Palin, Chair ~ .--- INVOICE AND NOTICE OF ESTIMATED REGULATORY COST CHARGE To: Union Oil Company of California Attention: Martin Morell, Mgr Oil & Gas P.O. Box 196247 Anchorage, AK 99519-6247 YOU ARE NOTIFIED that the Alaska Oil and Gas Conservation Commission has determined pursuant to AS 31.05.093 and 20 AAC 25.610 that your estimated regulatory cost charge for the first quarter of fiscal year 2004 is $29,825.53 and the payment date for this charge is September 15, 2003. Under 20 AAC 25.610, you are required to pay this charge not later than the payment date. Please make your check payable to: Mail or deliver payment to: State of Alaska/AOGCC AOGCC 333 West th Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. In accordance with 20 AAC 25.610, your estimated cost charge was computed as one-fourth of the Commission's reasonable estimate, based on available information, of what your actual annual regulatory cost charge will be for fiscal year 2004, using the formula set out in 20 AAC 25.605. For your information, the volume data and calculations used for this purpose are summarized in the attached spreadsheet. The appropriation for the Commission's operating and capital costs for fiscal year 2004, less federal receipts of $119,900 is $4,162,900. The Commission's estimate of the total fees to be collected under AS 31.05.090 (permit to drill fees) is $20,000. The Commission's estimate of the lapsed amount of fiscal year 2003 appropriations included in the fiscal 2004 appropriation is $455,000. Later in the fiscal year, after final information is available to the Commission for calculating actual regulatory cost charges, you will receive notice of your proposed actual annual regulatory cost charge for fiscal year 2004. At that time you will have an opportunity to submit comments on or request a revision to the proposed regulatory cost charge, and a hearing will be held before the Commission determines the final charges. Your estimated first quarter regulatory cost charge payment will be credited against your final charge. The Commission's regulations do not provide for objections or revisions to estimated regulatory cost charges. However, if you find what you believe may be errors in the Commission's determination of your estimated regulatory cost charge, you are invited to inform the Commission so that the Commission will be better prepared to determine actual regulatory cost charges in an expeditious manner. Date: August 13, 2003 Sarah H. Palin, Chair ~ /-- INVOICE AND NOTICE OF ESTIMATED REGULATORY COST CHARGE To: XTO Energy Inc. Attention: William A. Miller, District Administration Mgr 52260 Shell Road Kenai, AK 99611-9704 YOU ARE NOTIFIED that the Alaska Oil and Gas Conservation Commission has determined pursuant to AS 31.05.093 and 20 AAC 25.610 that your estimated regulatory cost charge for the first quarter of fiscal year 2004 is $1,638.22 and the payment date for this charge is September 15, 2003. Under 20 AAC 25.610, you are required to pay this charge not later than the payment date. Please make your check payable to: Mail or deliver payment to: State of Alaska/AOGCC AOGCC 333 West 7'h Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. In accordance with 20 AAC 25.610, your estimated cost charge was computed as one-fourth of the Commission's reasonable estimate, based on available information, of what your actual annual regulatory cost charge will be for fiscal year 2004, using the formula set out in 20 AAC 25.605. For your information, the volume data and calculations used for this purpose are summarized in the attached spreadsheet. The appropriation for the Commission's operating and capital costs for fiscal year 2004, less federal receipts of $119,900 is $4,162,900. The Commission's estimate of the total fees to be collected under AS 31.05.090 (permit to drill fees) is $20,000. The Commission's estimate of the lapsed amount of fiscal year 2003 appropriations included in the fiscal 2004 appropriation is $455,000. Later in the fiscal year, after final information is available to the Commission for calculating actual regulatory cost charges, you will receive notice of your proposed actual annual regulatory cost charge for fiscal year 2004. At that time you will have an opportunity to submit comments on or request a revision to the proposed regulatory cost charge, and a hearing will be held before the Commission determines the final charges. Your estimated first quarter regulatory cost charge payment will be credited against your final charge. The Commission's regulations do not provide for objections or revisions to estimated regulatory cost charges. However, if you find what you believe may be errors in the Commission's determination of your estimated regulatory cost charge, you are invited to inform the Commission so that the Commission will be better prepared to determine actual regulatory cost charges in an expeditious manner. Date: August 13, 2003 Sarah H. Palin, Chair 2002 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2004 $3,687,9(}().()(} Proposed Budget OperatorName ( -\URORA GAS LLC Field/Pool Name Gros~' Liquid (Stb) Grm's Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Co.~t NICOLAI CREEK, UNDEFINED GAS 0 277,798 46,299.67 46,300 $69.66 Field/Pool Quantities and Allocated Costs Totals: 0 277,798 46,300 46,300 $69.66 Operator Quantities and Allocated Costs Totals: 0 277,798 46,300 46,300 $69.66 SummaryloJ" AURORA GAS LLC rl dell/il recordj ( Monday, JII(V 28, 201/.1 7:0.5 AM Page / 01/9 2002 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2004 $3,687,900.00 Proposed Budget OperatorName ( QP EXPLORATION (ALASKA) INC ( MOlldIlY. Ju(y 28, 20/1.1 7:05 AM Field/Pool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Co.~t BADAMI. BADAMI OIL 674,763 10,098,831 1,683,138.50 2,357,902 $3,547.38 Field/Pool Quantities and Allocated Costs Totals: 674,763 10,098,631 1,663,139 2,357,902 $3,547.38 BADAMI. WDSP UNDEFINED 28,233 0 0.00 28,233 $42.48 Field/Pool Quantities and Allocated Costs Totals: 28,233 0 0 28,233 $42.48 ENDICOTT, EIDER OIL 1,619,552 6,493,705 1,082,284.17 2,701,836 $4,064.82 Field/Pool Quantities and Allocated Costs Totals: 1,619,552 6,493,705 1,082,284 2,701,636 $4,084.82 ENDICOTT, ENDICOTT OIL 92,653,830 260,036,859 43,339,476.50 135,993,307 $204,597.28 Field/Pool Quantities and Allocated Costs Totals: 92,653,630 260,036,859 43,339,477 135,993,307 $204,597.28 ENDICOTT, IVISHAK OIL 3,681,522 93,232 15,538.67 3,697,061 $5,562.10 Field/Pool Quantities and Allocated Costs Totals: 3,681,522 93,232 15,539 3,697,061 $5,562.10 ENDICOTT, WDSP UNDEFINED 3,714 0 0.00 3,714 $5.59 Field/Pool Quantities and Allocated Costs Totals: 3,714 0 0 3,714 $5.59 MILNE POINT. KUPARUK RIVER OIL 42,044,538 15,970,524 2,661,754.00 44,706,292 $67,259.09 Field/Pool Quantities and Allocated Costs Totals: 42,044,538 15,970,524 2,661,754 44,708,292 $67,259.09 MILNE POINT. SAG RIVER OIL 248,017 220,080 36,680.00 284,697 $428.32 Field/Pool Quantities and Allocated Costs Totals: 248,017 220,080 36,680 284,697 $428.32 MILNE POINT. SCHRADER BLFF OIL 10,752,788 2,331,167 388,527.83 11,141,316 $16,761.73 Field/Pool Quantities and Allocated Costs Totals: 10,752,788 2,331,167 388,528 11,141,316 $16,761.73 MILNE POINT. TERTL4RY UNDF OIL 0 0 0.00 0 $0.00 Page 2 of/9 2002 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2004 $3,687,900.00 Proposed Budget Mo/lllay, Ju(y 28, 2/1/1.1 7:/15 AM Field/Pool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost . Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 MILNE POINT. UGNU OIL UNDEFINE 0 2,000 333.33 333 $0.50 Field/Pool Quantities and Allocated Costs Totals: 0 2,000 333 333 $0.50 MILNE POINT. UGNU WTR UNDEFINE 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 NORTHSTAR, NORTHSTAR OIL 1,265,552 6,382,841 1,063,806.83 2,329,359 $3,504.44 Field/Pool Quantities and Allocated Costs Totals: 1,265,552 6,362,841 1,063,807 2,329,359 $3,504.44 NORTHSTAR, WDSP UNDEFINED 290,113 0 0.00 290,113 $436.47 Field/Pool Quantities and Allocated Costs Totals: 290,113 0 0 290,113 $436.47 PRUDHOE BAY. AURORA OIL 1,846,931 12,051,741 2,008,623.50 3,855,555 $5,800.55 Field/Pool Quantities and Allocated Costs Totals: 1,846,931 12,051,741 2,008,624 3,855,555 $5,800.55 PRUDHOE BA Y. BOREALIS OIL 1,345,639 935,791 155,965.17 1,501,604 $2,259.11 Field/Pool Quantities and Allocated Costs Totals: 1,345,639 935,791 155,965 1,501,604 $2,259.11 PRUDHOE BAY. LIS WDSP UNDEFINE 33,342,602 0 0.00 33,342,602 $50,162.80 Field/Pool Quantities and Allocated Costs Totals: 33,342,602 0 0 33,342,602 $50,162.80 PRUDHOE BAY. LISBURNE OIL 3,053,500 113,018,726 18,836,454.33 21,889,954 $32,932.69 Field/Pool Quantities and Allocated Costs Totals: 3,053,500 113,018,726 18,636,454 21,889,954 $32,932.69 PRUDHOE BAY. MIDNIGHT SUN OIL 8,885,750 6,750,499 1,125,083.17 10,010,833 $15,060.96 Field/Pool Quantities and Allocated Costs Totals: 8,885,750 6,750,499 1,125,083 10,010,833 $15,060.96 PRUDHOE BAY. N PRUDHOE BAYOIL Page 3 of 19 OperatorName t " BP EXPLORATION (ALASKA) INC ( 2002 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2004 $3,687,900.00 Proposed Budget OperatorName FieldIPool Name Gros.\' Liquid (Stb) Gros~' Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated co.~t { BP EXPLORATION (ALASKA) INC \ 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0,00 PRUDHOE BAY. NIAK IV-SR UN OIL 65,386 504,427 84,071.17 149,457 $224.85 Field/Pool Quantities and Allocated Costs Totals: 65,386 504,427 84,071 149,457 $224.85 PRUDHOE BAY. NIAKUK OIL 25,187,539 5,835,838 972,639.67 26,160,179 $39,357.09 Field/Pool Quantities and Allocated Costs Totals: 25,187,539 5,635,638 972,840 26,160,179 $39,357.09 PRUDHOE BAY. POLARIS OIL 418,999 581,239 96,873.17 515,872 $776.11 Field/Pool Quantities and Allocated Costs Totals: 418,999 581,239 96,873 515,872 $776,11 PRUDHOE BAY. PRUD WDSP UNDEFIN 62,657,216 0 0.00 62,657,216 $94,265.64 Field/Pool Quantities and Allocated Costs Totals: 62,657,216 0 0 62,657,216 $94,265.64 PRUDHOE BAY. PRUDHOE OIL 536,393,175 5,335,146,880 889,191,146.67 1,425,584,322 $2,144,742.83 ( Field/Pool Quantities and Allocated Costs Totals: 536,393,175 5,335,146,880 889,191,147 1,425,584,322 $2,144,742.63 PRUDHOE BAY. W BEACH OIL 2,754,928 1,453,206 242,201.00 2,997,129 $4,509.08 Field/Pool Quantities and Allocated Costs Totals: 2,754,928 1,453,206 242,201 2,997,129 $4,509.08 PRUDHOE BAY. W BEACH TERTI OIL 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 PT MCINTYRE, PT MCINTYRE OIL 83,541,452 106,111,524 17,685,254.00 101,226,706 $152,292.12 Field/Pool Quantities and Allocated Costs Totals: 63,541,452 106,111,524 17,685,254 101,226,706 $152,292,12 .s'/Immary/o/" HI' E\'PLOflATfON (,/LASKAi liVC (28 recordsj Operator Quantities and Allocated Costs Totals: 912,755,739 5,884,019,110 980,669,852 1,693,425,591 $2,848,594.00 MOlldllY, Ju(y 28, 2003 7:/15 AM Page" of 19 2002 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2004 $3,687,900.00 Proposed Budget MOIllIIlY, Ju(¡' 28, 20/13 7:{J.5AM Field/Pool Name Gros.\' Liquid (Stb) Gros.~ Gas (M~'cf) Ga,~ BOE Total Volume (Liq+BOE) Allocated Cost BELUGA RIVER, UNDEFINED GAS 0 41,785,753 6,964,292.17 6,964,292 $10,477.54 Field/Pool Quantities and Allocated Costs Totals: 0 41,785,753 6,984,292 6,964,292 $10,477.54 BELUGA RIVER, WDSP UNDEFINED 9,380 0 0.00 9,380 $14.11 Field/Pool Quantities and Allocated Costs Totals: 9,380 0 0 9,380 $14.11 COLVILLE RIVER, ALPINE OIL 55,210,887 58,680,096 9,780,016.00 64,990,903 $97,776.59 Field/Pool Quantities and Allocated Costs Totals: 55,210,887 58,680,096 9,780,016 64,990,903 $97,776.59 COLVILLE RIVER, NANUQ UNDF OIL 19,312 298,472 49,745.33 69,057 $103.89 Field/Pool Quantities and Allocated Costs Totals: 19,312 298,472 49,745 69,057 $103.89 COLVILLE RIVER, WDSP UNDEFINED 446,862 0 0.00 446,862 $672.29 Field/Pool Quantities and Allocated Costs Totals: 446,862 0 0 446,862 $672.29 KUPARUK RIVER, KUPARUK RV OIL 314,368,162 197,128,583 32,854,763.83 347,222,926 $522,385.01 Field/Pool Quantities and Allocated Costs Totals: 314,368,162 197,128,583 32,854,764 347,222,926 $522,365.01 KUPARUK RIVER, MELTWATER OIL 148,855 80,612 13,435.33 162,290 $244.16 Field/Pool Quantities and Allocated Costs Totals: 148,855 80,612 13,435 162,290 $244.16 KUPARUK RIVER, TABASCO OIL 6,357,625 180,047 30,007.83 6,387,633 $9,609.98 Field/Pool Quantities and Allocated Costs Totals: 6,357,625 180,047 30,008 6,387,833 $9,609.98 KUPARUKRIVER, TARN OIL 19,459,807 30,577,502 5,096,250.33 24,556,057 $36,943.75 Field/Pool Quantities and Allocated Costs Totals: 19,459,807 30,577,502 5,096,250 24,558,057 $36,943.75 KUPARUK RIVER, WDSP CRETA CEO U 714,325 0 0.00 714,325 $1,074.68 Page.5 of 19 OperatorName ( CO NO CO PHILLIPS ALASKA INC ( 2002 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2004 $3,687,900.00 Proposed Budget OperatorName Field/Pool Name GrtJs.~ Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated co.~t ( \ CONOCOPHILLIPS ALASKA INC Field/Pool Quantities and Allocated Costs Totals: KUPARUKRIVER, WEST SAK OIL 714,325 Field/Pool Quantities and Allocated Costs Totals: 5,055,200 5,055,200 0 0 714,325 $1,074.68 428,875 71,479.17 5,126,679 $7,712.91 428,875 71,479 5, 126,679 $7,712.91 329,159,940 54,859,990 458,650,405 $687,014.91 SIImnwlyjÓr CONOCOI'HILUPS ALASKA INC (II records) Operator Quantities and Allocated Costs Totals: 401,790,415 ( MontlllY, Ju(y 28, 2/J()3 7:0,5 AM Page 6 of 19 2002 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2004 $3,687,900.00 Proposed Budget Operat(}rName Field/Po(}l Name Gr(}ss Liquid (Stb) Gros.~ Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost PT THOlvlSON, WDSP UNDEFINED 6,464 0 0.00 6,464 $9.72 Field/Pool Quantities and Allocated Costs Totals: 6,464 0 0 6,464 $9.72 Operator Quantities and Allocated Costs Totals: 6,464 0 0 6,464 $9.72 ( EXXON CORP SllInlllwylo/" EïXO,v CORP (I detail recordj ( MOlldllY, JU(f' 28, 2/1/13 7:05 AM Page 7 of 19 2002 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2004 $3,687,900.00 Proposed Budget OperatorName Field/Pool Name Gross Liquid (Stb) Gron' Gas (Mscf) Ga,~ BOE Total Volume (Liq+BOE) Allocated co.~t REDOUBT SHOAL, UNDEFINED OIL 1,221 0 0.00 1,221 $1.84 Field/Pool Quantities and Allocated Costs Totals: 1,221 0 0 1,221 $1.84 REDOUBT SHOAL, WDSP UNDEFINED 26,409 0 0.00 26,409 $39.73 Field/Pool Quantities and Allocated Costs Totals: 26,409 0 0 26,409 $39.73 W FORELAND, UNDEFINED GAS 0 58,539 9,756.50 9,757 $14.68 Field/Pool Quantities and Allocated Costs Totals: 0 58,539 9,757 9,757 $14.68 W MCARTH RIV, W MCARTH RIV OIL 1,222,254 287,949 47,991.50 1,270,246 $1,911.04 Field/Pool Quantities and Allocated Costs Totals: 1,222,254 287,949 47,992 1,270,246 $1,911.04 W MCARTH RIV, WDSP UNDEFINED 1,013,047 0 0.00 1,013,047 $1,524.09 Field/Pool Quantities and Allocated Costs Totals: 1,013,047 0 0 1,013,047 $1,524.09 Operator Quantities and Allocated Costs Totals: 2,262,931 346,488 57,748 2,320,679 $3,491.38 FOREST OIL CORP ( Sllmma~v/or FOREST OIL CORP (5 records! ( Mollday, Ju(¡' 28, 2003 7:{JSAM Page 8 of 19 2002 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2004 $3,687,900.00 Proposed Budget OperatorName Mollday, Ju(¡' 28, 2003 7:05AM Field/Pool Name Gross Liquid (Stb) Gross Gas (M~'cf) Gas BOE Total Volume (Liq+BOE) Allocated Cost BEA VER CREEK. SEA VER CREEK OIL 84,562 21,450 3,575.00 88,137 $132.60 Field/Pool Quantities and Allocated Costs Totals: 84,562 21,450 3,575 88,137 $132.60 BEAVER CREEK, BELUGA GAS 0 4,479,889 746,648.17 746,648 $1,123.31 Field/Pool Quantities and Allocated Costs Totals: 0 4,479.889 746,648 746,648 $1,123.31 BEA VER CREEK, STERLING GAS 0 433,727 72,287.83 72,288 $108.75 Field/Pool Quantities and Allocated Costs Totals: 0 433,727 72,288 72,288 $108.75 BEA VER CREEK, TYONEK UNDEF GAS 0 426,492 71,082.00 71,082 $106.94 Field/Pool Quantities and Allocated Costs Totals: 0 426,492 71,082 71,082 $106.94 BEA VER CREEK. WDSP UNDEFINED 21,084 0 0.00 21,084 $31.72 Field/Pool Quantities and Allocated Costs Totals: 21,064 0 0 21,084 $31.72 KENAL BELUGA UNDEFINED GAS 0 2,392,450 398,741.67 398,742 $599.89 Field/Pool Quantities and Allocated Costs Totals: 0 2,392,450 398,742 398,742 $599.89 KENAL CoL. u. BELUGA GAS 0 1,860,945 310.157.50 310,158 $466.62 Field/Pool Quantities and Allocated Costs Totals: 0 1,880,945 310,158 310,158 $466.62 KENAL CoL. u. STERLING UND GAS 0 2,128,370 354,728.33 354,728 $533.68 Field/Pool Quantities and Allocated Costs Totals: 0 2,128,370 354,728 354,728 $533.68 KENAL CoL. u. UPPER TYONEK GAS 0 2,314,362 385,727.00 385,727 $580.31 Field/Pool Quantities and Allocated Costs Totals: 0 2,314,362 385,727 385,727 $580.31 KENAI. STERLING 3 GAS 0 1.908,782 318,130.33 318,130 $478.62 Page 9 of 19 MARATHON OIL CO ( \ ( 2002 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2004 $3,687,900.00 Proposed Budget OperatorName MOlldllY, July 28, 20fJ3 7:05 AM Field/Pool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated co.~t Field/Pool Quantities and Allocated Costs Totals: 0 1.908,782 318,130 318,130 $478.62 KENAI, STERLING 4 GAS 0 2,417,268 402,878.00 402,878 $606.12 Field/Pool Quantities and Allocated Costs Totals: 0 2,417,268 402,878 402,878 $606.12 KENAI, STERLING 5.1 GAS 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 KENAI, STERLING 6 GAS 0 7,517,770 1,252,961.67 1,252,962 $1,885.04 Field/Pool Quantities and Allocated Costs Totals: 0 7,517,770 1,252,962 1,252,962 $1,885.04 KENAI, TYONEK GAS 0 5,728,207 954,701.17 954,701 $1,436.32 Field/Pool Quantities and Allocated Costs Totals: 0 5,728,207 954,701 954,701 $1,436.32 KENAI, WDSP G&I UNDEFINED 191,433 0 0.00 191,433 $288.00 Field/Pool Quantities and Allocated Costs Totals: 191,433 0 0 191,433 $288.00 KENAI, WDSP UNDEFINED 84,543 0 0.00 84,543 $127.19 Field/Pool Quantities and Allocated Costs Totals: 84,543 0 0 84,543 $127.19 STERLING, BELUGA UNDEFINED GAS 0 25,173 4,195.50 4,196 $6.31 Field/Pool Quantities and Allocated Costs Totals: 0 25,173 4,196 4,196 $6.31 STERLING, TYONEK UNDEFINED GAS 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 STERLING, UNDEFINED GAS 0 123,451 20,575.17 20,575 $30.95 Field/Pool Quantities and Allocated Costs Totals: 0 123,451 20,575 20,575 $30.95 TRADING BA Y, G-NE/HEMLK-NE OIL Page 10 of 19 MARATHON OIL CO I \ ( 2002 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2004 $3,687,900.0() Proposed Budget OperatorName Field/Po(}l Name Grim' Liquid (Stb) Gr(}ss Gas (Mscf) Gas BOE Total Volume (Liq+BOE) All(}cated Co.\.t \ l\1ARATHON OIL CO 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 TRADING BAY. HEMLOCK OIL 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 TRADING BA Y, MID KENAI D OIL 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 TRADING BAY. MID KENAI E OIL 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 TRADING BAY. UNDEFINED GAS 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 TRADING BAY. W FORELAND OIL 0 0 0.00 0 $0.00 ( Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 TRADING BA Y. WDSP UNDEFINED 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 WOLF LAKE, TYONEK UNDEF GAS 0 114,210 19,035.00 19,035 $28.64 Field/Pool Quantities and Allocated Costs Totals: 0 114,210 19,035 19,035 $28.64 Summarv/"r MAflATlfO,'v' OIL CO (17 records) Operator Quantities and Allocated Costs Totals: 381,622 31,892,546 5,315,424 5,697,046 $8,571.01 MO/lllllY, July 28, 2003 7:fJ5AM Page 11 of 19 2002 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2004 $3,687,900.00 Proposed Budget OperatorName I Field/Pool Name Gros.f Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Co~.t NORTH SLOPE BOROUGH ( BARROW, EAST BARROW GAS 0 85,780 14,296.67 14,297 $21.51 Field/Pool Quantities and Allocated Costs Totals: 0 85,780 14,297 14,297 $21.51 BARROW, SOUTH BARROW GAS 0 42,139 7,023.17 7,023 $10.57 Field/Pool Quantities and Allocated Costs Totals: 0 42,139 7,023 7,023 $10.57 WALAKPA, WALAKPA GAS 0 1,347,554 224,592.33 224,592 $337.89 Field/Pool Quantities and Allocated Costs Totals: 0 1,347,554 224,592 224,592 $337.89 Summar)'}i,r NORTII SLOPE I!OI/OUGH (3 records) Operator Quantities and Allocated Costs Totals: 0 1,475,473 245,912 245,912 $369.97 ( Monday, Ju(v 28, 20IJ.! 7:05 AM Page 120f19 2002 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2004 $3,687,900.00 Proposed Budget OperatorName Field/Pool Name Gros.f Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost PHILLIPS PETROLEUM CO (, NORTH COOK INLET, TERTIARY GAS ° 55,530,531 9,255,088.50 9,255,089 $13,923.96 Field/Pool Quantities and Allocated Costs Totals: o 55,530,531 9,255,089 9,255,089 113,923.96 NORTH COOK INLET, WDSP UNDEF 271 ° 0.00 271 $0.41 Field/Pool Quantities and Allocated Costs Totals: 271 o o 271 10.41 Sumn/m}'/or PHIL/.II'S PETROLEUM CO (2 records) Operator Quantities and Allocated Costs Totals: 271 55,530,531 9,255,089 9,255,360 113,924.37 ( Monday, Ju(V 28, 201)3 7:05 AM Page 13 of 19 2002 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2004 $3,687,9()().()() Proposed Budget OperatorName Monday, Ju(V 28, 2003 7:05AM Field/Pool Name Gro.fs Liquid (Stb) Gros~' Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated co~.t GRANITE PT, HEJ1LOcK UNDEF OIL 59,725 98.939 16,489.83 76,215 $114.66 Field/Pool Quantities and Allocated Costs Totals: 59,725 98,939 16,490 78,215 $114.68 GRANITE PT, MIDDLE KENAI OIL 3,407,855 1,687,890 281,315.00 3,689,170 $5.550.23 Field/Pool Quantities and Allocated Costs Totals: 3,407,855 1,687,890 281,315 3,889,170 $5,550.23 GRANITE PT, UNDEFINED GAS 0 149,359 24,893.17 24.893 $37.45 Field/Pool Quantities and Allocated Costs Totals: 0 149,359 24,893 24,893 137.45 GRANITE PT, WDSP G&I UNDEFINED 47.978 0 0.00 47.978 $72. 18 Field/Pool Quantities and Allocated Costs Totals: 47,978 0 0 47,978 $72.18 IVAN RIVER, UNDEFINED GAS 0 3,799.122 633,187.00 633,187 $952.61 Field/Pool Quantities and Allocated Costs Totals: 0 3,799,122 833,187 833,187 $952.81 IVAN RIVER, WDSP UNDEFINED 14,987 0 0.00 14,987 $22.55 Field/Pool Quantities and Allocated Costs Totals: 14,987 0 0 14,987 $22.55 LEWL') RIVER, UNDEFINED GAS 0 220.682 36,780.33 36,780 $55.33 Field/Pool Quantities and Allocated Costs Totals: 0 220,682 38,780 38,780 $55.33 LEWIS RIVER, WDSP UNDEFINED 1.481 0 0.00 1.481 $2.23 Field/Pool Quantities and Allocated Costs Totals: 1,481 0 0 1,481 $2.23 MCARTHUR RIVER, HEMLOCK OIL 37,881,522 2,429,253 404,875.50 38,286,398 $57,600.57 Field/Pool Quantities and Allocated Costs Totals: 37,881,522 2,429,253 404,878 38,288,398 $57,800.57 MCARTHUR RIVER, MID KENAI G OIL 8,005,839 992,815 165,469.17 8,171,308 $12,293.45 Page 14 of 19 UNION OIL CO OF CALIFORNIA ( ( 2002 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2004 $3,687,9()0.()() Proposed Budget Operat(JrName Monday, JU(f' 28, 20113 7:05AM Field/P(Jol Name Gr(Jss Liquid (Stb) Gros~' Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost Field/Pool Quantities and Allocated Costs Totals: 8,005,639 992,815 185,469 8,171,308 $12,293.45 MCARTHUR RIVER, MIDKENAI GAS 0 58,770,285 9,795,047.50 9,795,048 $14,736.31 Field/Pool Quantities and Allocated Costs Totals: 0 58,770,285 9,795,048 9,795,048 $14,736.31 MCARTHUR RIVER, UNDEFINED OIL 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 MCARTHUR RIVER, W FORELAND OIL 2,991,519 71,484 11,914.00 3,003,433 $4,518.56 Field/Pool Quantities and Allocated Costs Totals: 2,991,519 71,464 11,914 3,003,433 $4,518.56 MIDDLE GROUND SHOAL, A OIL 1,107,961 62,172 10,362.00 1,118,323 $1,682.48 Field/Pool Quantities and Allocated Costs Totals: 1,107,981 82,172 10,382 1,118,323 $1,682.48 MIDDLE GROUND SHOAL, B,C,D OIL 367,566 51,578 8,596.33 376,162 $565.92 Field/Pool Quantities and Allocated Costs Totals: 367,568 51,578 8,598 378,182 $565.92 MIDDLE GROUND SHOAL, E,F,G OIL 896,565 214,262 35,710.33 932,275 $1,402.58 Field/Pool Quantities and Allocated Costs Totals: 898,585 214,262 35,710 932,275 $1,402.58 MIDDLE GROUND SHOAL, UNDEF GAS 0 533,479 88,913.17 88,913 $133.77 Field/Pool Quantities and Allocated Costs Totals: 0 533,479 88,913 88,913 $133.77 PRETTY CREEK, UNDEFINED GAS 0 80,465 13,410.83 13,411 $20.18 Field/Pool Quantities and Allocated Costs Totals: 0 80,465 13,411 13,411 $20.18 STUMP LAKE, UNDEFINED GAS 0 482 80.33 80 $0.12 Field/Pool Quantities and Allocated Costs Totals: 0 482 80 80 $0.12 SWANSON RIVER, GAS STORAGE Page 150f19 UNION OIL CO OF CALIFORNIA ( ( 2002 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2004 $3,687,900.00 Proposed Budget Monday, JU(f' 28, 2003 7:05 AM Field/PofJl Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated cO.ft 0 896,748 149,458.00 149,458 $224.85 Field/Pool Quantities and Allocated Costs Totals: 0 898,748 149,458 149,458 $224.85 SWANSON RIVER, HEMLOCK OIL 609,444 36,499,264 6,083,210.67 6,692,655 $10,068.87 Field/Pool Quantities and Allocated Costs Totals: 609,444 38,499,264 8,063,211 8,692,655 $10,068.87 SWANSON RIVER, UNDEFINED GAS 0 1,202,519 200,419.83 200,420 $301.52 Field/Pool Quantities and Allocated Costs Totals: 0 1,202,519 200,420 200,420 $301.52 SWANSON RIVER, WDSP UNDEFINED 2,819,985 0 0.00 2,819,985 $4,242.57 Field/Pool Quantities and Allocated Costs Totals: 2,819,985 0 0 2,819,985 $4,242.57 TRADING BAY, HEMLOCK OIL 1,465,511 185,495 30,915.83 1,496,427 $2,251.32 Field/Pool Quantities and Allocated Costs Totals: 1,485,511 185,495 30,918 1,498,427 $2,251.32 TRADING BAY, MID KENAI BOIL 70,451 23,648 3,941.33 74,392 $111.92 Field/Pool Quantities and Allocated Costs Totals: 70,451 23,648 3,941 74,392 $111.92 TRADING BA Y, MID KENAI C OIL 685,883 96,827 16,137.83 702,021 $1,056.17 Field/Pool Quantities and Allocated Costs Totals: 685,883 96,827 16,138 702,021 $1,056.17 TRADING BAY, MID KENAI DOlL 742,121 82,441 13,740.17 755,861 $1,137.17 Field/Pool Quantities and Allocated Costs Totals: 742,121 82,441 13,740 755,861 $1,137.17 TRADING BAY, MID KENAI E OIL 78,334 25,713 4,285.50 82,620 $124.30 Field/Pool Quantities and Allocated Costs Totals: 78,334 25,713 4,288 82,820 $124.30 TRADING BAY, UNDEFINED OIL 13,865 5,478 913.00 14,778 $22.23 Field/Pool Quantities and Allocated Costs Totals: 13,885 5,478 913 14,778 $22.23 Page 16 of 19 OperatorName ( UNION OIL CO OF CALIFORNIA ( 2002 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2004 $3,687,900.00 Proposed Budget OperatarName Field/Pool Name Gross Liquid (Stb) Grass Gas (Mscf) Ga,f BOE Total Volume (Liq+BOE) Allocated Cost ( UNION OIL CO OF CALIFORNIA IImmarl'for UNION Oil. CO OF C'LIFORNIA 129 records) Operator Quantities and Allocated Costs Totals: 61,268,592 108,180,400 18,030,087 79,298,859 $119,302.12 ( Monday, Ju(V 28, 2003 7:05 AM Page 170f19 2002 Annual Production/Injection/Disposal Volumes For Allocation o.fRegulatory Cost Charge For FY 2004 $3,687,900.00 Proposed Budget OperatorName Field/Pool Name GTlJ.f.\' Liquid (Stb) GTfJSS Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated co.\'t MIDDLE GROUND SHOAL, B,C,D OIL 14,625 13,424 2,237.33 16,862 $25.37 Field/Pool Quantities and Allocated Costs Totals: 14,825 13,424 2,237 16,862 $25.37 MIDDLE GROUND SHOAL, E,F,G OIL 4,181,748 444,112 74,018.67 4,255,767 $6,402.66 Field/Pool Quantities and Allocated Costs Totals: 4,181,748 444,112 74,019 4,255,787 $8,402.66 MIDDLE GROUND SHOAL, WDSP UNDE 82,974 0 0.00 82,974 $124.83 Field/Pool Quantities and Allocated Costs Totals: 82,974 0 0 82,974 $124.63 Operator Quantities and Allocated Costs Totals: 4,279,347 457,536 76,256 4,355,603 $6,552.86 XTO ENERGY INC ( Slimmal)'}Ór .Y70 ENERGY liVC!] record,) ( Monday, JI/(f' 28, 2003 7:05 AM Page 18 of 19 2002 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2004 $3,687,900.00 Proposed Budget OperatarName FieÜVPaal Name Gros.f Liquid (Stb) Gro~"S Ga.f (M~'cf) Gas BOE Total Volume (Liq+BOE) Allocated cO.ft ( Report Qllalltitie,f and Allocated Costs Totills: I 1,382.745,3811 I 6,411,339,822 II 1,068,556,6371 I 2,451,302,0181 I $3,687,900.0(J ! ( Mollllay, JU(f' 28, 2003 7:05 AM Page190f19