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Home My WebLink AboutAIO 022 C AREA INJECTION ORDER FILE COVER PAGE XHVZE This page identifies oversize material and digital information available for this individual Order file and weather or not it is available in the LaserFiche file. Please insure that it remains as the first page in this file. ~j) ~:J..¿ Area Injection Order File Scan Date. ¥ '1 1IDt.~ Color Materials # Scanned in: B/W Color Init. Circle one 0 Added (date) Ini t. Greyscale #~ Digital Data 0 CD's - # 0 DVD's - # 0 Diskettes - # OCompleted (date) Init. Added to LaserFiche File 0 YesD No 0 YesO No 0 YesD No Init. Init. Init. Oversized Material Added to LaserFiche File Maps Mud Logs Other # # - # 0 Yes 0 No 0 Yes 0 No 0 Yes 0 No Init. Init. Init. General Notes or Comments about this file. If any of the information listed above is not available in the LaserFiche file, or if you have any questions or information requests regarding this file, you may contact the Alaska Oil & Gas Conservation Commission to request copies at 279-1433, or email us at: AOGCC_Lìbrarian@admin.state.ak.us INDEX AREA INJECTION ORDER NO. 22C Prudhoe Bay Field Aurora Oil Pool 1. March 25, 2004 BPXA's application to expand Aurora Area 2. April 2, 2004 Notice of Public Hearing, Affidavit of Publication, email distribution list, and mailings 3. April 12, 2004 BPXA's supplemental information 4. September 27, 2004 Public Notice to Amend Underground Injection Orders to Incorporate Consistent Language Addressing the Mechanical Integrity of Wells 5. October 19, 2005 BPXA's proposed Aurora FOR expansion (AIO 22C.001) 6. November 13, 2006 BPXA's request to allow commingled injection within the Aurora and Prudhoe Oil Pool (AIO 22C.002) 7. July 3, 2007 BPXA's request to continue water injection in PBU S- 111 (AIO 22C.003) 8. January 22, 2010 BPXA's request to allow commingled injection in the Aurora Oil Pool and Prudhoe Oil Pool (AID 22C.002 Amended) 9. January 1, 2014 BPXA's request for cancellation of AIO 22C.003 (AIO 22C.003 Cancellation) 10. January 6, 2015 BPXA's request for cancellation of AIO 22C.002 (AIO 22C.002 Cancellation) CONFIDENTIAL DOCUMENTS ARE HELD IN SECURE STORAGE INDEX AREA INJECTION ORDER NO. 22C ~ /~..\ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue, Suite 100 Anchorage Alaska 99501 Re: THE APPLICATION OF BPXA EXPLORATION (ALASKA) INc. for an order expanding the area in which injection is authorized in the Aurora Oil Pool, Prudhoe Bay Field, North Slope, Alaska ) Area Injection Order No. 22C ) ) Prudhoe Bay Field ) Aurora Oil Pool ) ) June 25, 2004 IT APPEARING THAT: 1. BP Exploration (Alaska), Inc. ("BPXA") by application dated March 26, 2004, applied for expansion of the area in which injection is authorized in the Aurora Oil Pool ("AOP") ; 2. BPXA provided supplemental information at the Commission's request on April 12, 2004; 3. Notice of a public hearing, tentatively scheduled for May 6, 2004, was duly published in the Anchorage Daily News on April 2, 2004; and 4. No requests for hearing or objections concerning the application were received. FINDINGS: 1. Ala 22, effective September 7, 2001 approved water injection for enhanced recovery purposes within the AOP and set forth rules for conducting injection operations. 2. Ala 22B effective May 6, 2003 approved injection of enriched hydrocarbon gas for enhanced recovery purposes and amended reporting requirements for reservoir surveillance. 3. The Commission has issued CO 457B, which finds that subsurface wireline log data, pressure measurements, and newly reprocessed seismic data indicate that the AOP extends beyond the area specified in CO 457 and expands the area subject to pool rules governing the development and operation of the AOP. 4. BPXA proposes to expand water and enriched hydrocarbon gas injection operations to include the additional area defined by CO 457B. 5. The previously issued rules governing injection within the AOP continue to be appropriate for that pool. ¡-, ~ Ala 22C June 25, 2004 Page 2 CONCLUSION: The area within which injection into the AOP is authorized should be expanded to conform to the pool rules area defined by CO 457B. NOW, THEREFORE, IT IS ORDERED: Underground injection of fluids as described in BPXA's applications for Ala 22, Ala 22A, and Ala 22B is permitted subject to the conditions, limitations, and requirements established in the rules set out below, in Conservation Order 457B and statewide requirements contained in 20 AAC 25. The affected area ofthis order is: Umiat Meridian Township Range. UM TIIN-RI2E Sections Tl2N-Rl2E Sec 2: Wl/2 Sec 3: All Sec 4: E 1/2, NW 1/4, E 1/2 SW 1/4 Sec 5: E l/2l/2NEl/4 Sec. 9: NEI/4, Nl/2SEl/4 Sec 10: NWl/4SWl/4, Wl/2NWI/4 Sec 15: Sl/2SEl/4, SWI/4 Sec 16: NWl/4, SI/2 Sec 17: Sl/2, NEl/4 Sec 18: SEl/4 Sec 19: Nl/2 NEl/4 Sec 20: E1/2, Nl/2NWl/4 Sec 21: All Sec 22: All Sec 23: Sl/2, SI/2NWl/4,SI/2NEI/4 Sec 25; Sl/2, Sl/2NWl/4 Sec 26; All Sec 27: All Sec 28: All Sec 29: El/2NEl/4, SEl/4 Sec 32: E1/2 Sec 33: All Sec 34: All Sec 35: All Sec 36: All "~ ~ AIO 22C June 25, 2004 Page 3 Rule 1. Authorized Injection Strata for Enhanced Recovery (Source AIO 22) Injection is permitted into the accumulation of hydrocarbons that is common to, and correlates with, the interval between 6765'- 7765' measured depth ("MD") in the Mobil Oil Corporation Mobil-Phillips North Kuparuk State No. 26-12-12 well. Rule 2 Injection Pressures (Source AIO 22B) The injection operations shall not allow fractures to propagate into the confining intervals. Surface wellhead injection pressures shall be limited to 2800 psi for water and 3800 psi for gas. Rule 3. Fluid Iniection Wells (Source AIO 22B) a. The underground injection of fluids must be through a well permitted for drilling as a service well for injection in conformance with 20 AAC 25.005, or through a well approved for conversion to a service well for injection in conformance with 20 AAC 25.280. b. An application to drill or convert a well for injection must be accompanied by the information required by 20 AAC 25.402(c), and must include cementing records, cement quality log or formation integrity test records. Rule 4. Monitorine: the Tubin2-Casin2 Annulus Pressure Variations (Source AIO ill The tubing-casing annulus pressure and injection rate of each injection well must be checked at least weekly to confirm continued mechanical integrity. Rule 5. Demonstration of Tubine:-Casine: Annulus Mechanical Intee:ritv (Source AIO 22) A schedule shall be developed and coordinated with the Commission that ensures that the tubing-casing annulus for each injection well is pressure tested prior to initiating injection, following well workovers affecting mechanical integrity, and at least once every four years thereafter. Rule 6. Notification of Improper Class II In.iection (Source AIO 22) The operator shall notify the Commission if it learns of any improper injection of fluids into a Class II well. Additionally, compliance with the notification requirements of any other State or Federal agency remains the operator's responsibility. ~. ~ Ala 22C June 25, 2004 Page 4 Rule 7. Other conditions (Source AIO 22) a. It is a condition of the authorization granted by this Order that the operator shall comply with all applicable Commission regulations. b. The Commission may suspend, revoke, or modify this authorization if injected fluids fail to be confined within the designated injection strata. Rule 8. Administrative Action (Source AIO 22B) Unless notice and public hearing are otherwise required, the Commission may administratively waive the requirements of any rule herein or administratively amend any rule as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in an increased risk of fluid movement into freshwater. Rule 9. Authorized Fluids for Enhanced Recovery (Source AIO 22B) The fluids authorized by this Order for injection and conditions of the authorization are as follows: a. produced water from the AOP or Prudhoe Bay Unit processing facilities; b. source water from the Prince Creek formation provided that the water is shown to be compatible with the AOP formation and administrative approval to inject is obtained from the Commission; c. enriched hydrocarbon gas processed within the Prudhoe Bay Unit processing facilities, with the following conditions: 1. reservoir pressure must be maintained to ensure miscibility of the injectant, and 2. expansion of injection outside of the North of Crest and West Blocks must be administratively approved prior to long-term injection; d. immiscible hydrocarbon gas from the AOP or Prudhoe Bay Unit processing facilities provided that Commission approval of the associated depletion strategy and surveillance plans is obtained prior to start of injection; ."'--"'\ ~ AIO 22C June 25, 2004 Page 5 e. tracer survey fluid to monitor reservoir performance; and f. non-hazardous filtered water collected from AOP well house cellars and well pads. 5th day June 2004. . orman, air Alaska Oil and Gas Conservation Commission rJ~ Daniel T. Seamount, Jr., Commissioner 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 10-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., 10th day after the application for rehearing was filed). AlO #22C and SIO #2A .~ ,~ 10f2 6/25/20043:07 PM AlO #22C and SIO #2A ,~ ~. , Content-Type: applicationlmsword SIO2A.doc' i Content-Encoding: base64 . Content-Type: applicationlmsword ; AIO22C.doc Content-Encoding: base64 .- 2 of2 6/25/20043:07 PM Website /""" . ~. 2 orders to add to r\\7eþ¡;ite~cþeerf3 Jody- i ; Content-Type: applicationlmsword : SIO2A.docl I I Content-Encoding: base64 ,. - .-.-.......-.........--....... Content-Type: applicationlmsword AIO22C.doc Content-Encoding: base64 1 of 1 6/25/20043:07 PM 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 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 .~. 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 Schlumberger Drilling and Measurements 3940 Arctic Blvd., Ste 300 Anchorage, AK 99503 Ciri Land Department PO Box 93330 Anchorage, AK 99503 Jack Hakkila PO Box 190083 Anchorage, AK 99519 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 Cliff Burglin PO Box 70131 Fairbanks, AK 99707 North Slope Borough PO Box 69 Barrow, AK 99723 .~. 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 David Cusato 200 West 34th PMB 411 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Darwin Waldsmith PO Box 39309 Ninilchick, AK 99639 Penny Vadla 399 West Riverview Avenue Soldotna, AK 99669-7714 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 ~ ell \d . ' (.Q R3 O~ \ I ') ~íì Œ\ Tire rTIl ~ !EJ 1,1 ,/A\ ~,~~,' 11( Œ\ // W U £~ Ll L6 © u !AJ b/i ~1, cY) u\~lfü ,J i AlASKA OIL AND GAS I,' CONSERVATION COMMISSION ) FRANK H. MURKOWSKI, GOVERNOR 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRA TIVE APPROVAL NUMBERS C0457B.OOl and AI022C.OOl Mr. Oil Beuhler OPB Waterflood Resource Manager BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, AK 99519-6612 Dear Mr. Beuhler: c By letter dated October 19, 2005, BP Exploration (Alaska), Inc. ("BPXA") requested authorization to extend current pilot miscible injection (MI) operations in the Aurora Oil Pool ("AOP") to the full area of the AOP. Rule 9( c) of AIO 22C and Rule 7 of CO 457B require that administrative approval be obtained prior to long term injection of MI in wells outside of the North of Crest and West Blocks of the AOP. On May 11, 2004 the Commission approved pilot MI injection into wells S-112, S-110, and S-116, which lie outside of the North of Crest and West Blocks. On December 22, 2004, the Commission extended these pilot operations to September 30, 2005. MI slugs have been injected into six wells in the AOP. Offset producers to all these injectors have shown some beneficial response. In addition, MI injection has a beneficial effect upon injectivity of water, and reservoir pressures are increasing as a result. The Commission approves injection of MI throughout the AOP area subject to the conditions of AIO 22C and CO 457B and statewide regulations under 20 AAC 25 (to the extent not otherwise superseded by AIO 22C and Conservation Order 457B. AIO 22B Rule 9 (c) and CO 457B Rule 7) are amended to eliminate the restriction of MI injection to only the North of Crest and West Blocks. As provided in AS 31.05.080(a), within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or w~ekend. A person may not appeal a Co mission decision to Superior Court unless, reheari~~~~~~f~~o;,~,_ requested ~~... '....~-oJr.-;¡~,...; , "'" /~ or /~;1:!~~r-\"T~7~\r';' ~~!' (jr~:þ,}:- ' '. :. , :; "~I . . :' ß ~ .1. ~ '. _, , " , .' > :! Cathy p\ .,pet.,$ter,· - . . ::.'.~.>'.'j Commis; ~~~~~l§~"i~§ß/ Daniel T. Seamô'únt, J r. Commissioner Citgo Petroleum Corporation PO Box 3758 Tulsa, OK 74136 Mona Dickens 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 I nformation Service, Inc PO Box 45738 Los Angeles, CA 90045-0738 Mark Wedm an Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Ciri Land Department PO Box 93330 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 ) 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 Schlumberger Drilling and Measurements 2525 Gambell Street #400 Anchorage, AK 99503 Ivan Gillian 9649 Musket Bell Cr.#5 Anchorage, AK 99507 Jack Hakkila PO Box 190083 Anchorage, AK 99519 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 Cliff Burglin PO Box 70131 Fairbanks, AK 99707 North Slope Borough PO Box 69 Barrow, AK 99723 ) 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, 10 83702 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle, WA 98119-3960 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Darwin Waldsmith PO Box 39309 Ninilchick, AK 99639 Penny Vadla 399 West Riverview Avenue Soldotna, AK 99669-7714 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 C0457B.OO 1 and AI022C.00 1 PBU Aurora Oil Pool ) ) lof2 11/10/2005 3:37 PM C0457B.001 and AI022C.001 PBD Aurora Oil Pool ) ) 10f2 11/10/2005 3:37 PM 11/10/2005 3:37 PM 20f2 ) C0457B.OOl and AI022C.OOl PBU Aurora Oil Pool ') C0457B.00l and AI022C.00l PBU Aurora Oil Pool ) ) 20f2 11/10/2005 3:37 PM C0457B.00 1 and AI022C.00 1 PBU Aurora Oil Pool ) ) Subject: C0457B.00l and AI022C.001 PBUAurora QilPool From: JodyColombie <j ody_ colombie@admin.ståte.ak.us> Date: Thu, 10 Nov 200515:36:11 .;.0900 1ì ',;,3' ""1 ~ 1111 . .1,' 1"tlllllll"~'1 " I I 'I" II', III I', '" 1,,11 ","1,,1,1' III I 'II ", I ' I" I' II '10:' unulS,C pse~- clpte:p. SI:1 , '1," ,1111, 1"'1,1, III "1111 I I, III '111' I' ': ,II II "I ,11' " 'I , I ,1,',11,' ,,1111 'II:~ J ,11'11' 1111 "'111:11 :11,1 111"I:I:li I I~I III 111', I~ I: I I '11, I HII!".' ",1,1'" 11,'1'" 111'1,1' 1111" I ,,1 1)1'1 II II II! 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Bawortl1'I" <jolin'~s.hawortli@exxonmopil.çom>, 'ni~" I ',' '1,,1" I " " I ,~,r'" I I I , I I I I'I' 'I <marty@rkindustrial.co~>, ghammons <ghammons@aol.com>, rmclean ~~cl~~@R9~ox~'låla~ka.net>, mkni729P '~mk11i7fOO@~o¡1.c?Ill>,Brian 9illF,spie'~~fbmg@~~.~aslq~~~4~~'II?~Y~â.,H',I,~ë,~~~~~::;'\"'1.,,1 <dboelen~(@aurorapo\yer"?<?rn>' To49.P~~Ç~~Q{.J~E@KMG.~om:>,; ¥aIJ;.~~hwt~.",., ': . <gary _ schultz@dnr.st~te.ak. us>,W ayne RaJ1cie~<]{AN~IER@petro-cap.aø~.~~,'·Bill¥iller <Bill_Miller@xtQalaska.com>,Brandon Gagnon<þgagnon@brenalaw.com>, Paul'Yinsl9w <pmwinslow@forestoi1.com>, Garry Catron, <catröµgr@bp.com>, Sharmaine Copeland., <copelasv@bp.cQm>, Ktistin Dirks <kristiri _ dirks@dnr.state.ak.us>, KayneU Zeman" <kjzeman@marathonoil.com>, John Tower <John. Tow~r@~ia.doe.gov>, Bill. F9w~er <Bill_Fo"Wler@ana~~ko.COM>, Vaughn, ~w~~yaughn.s~~@rb,ccm·~qm::>, ~Ç2nJ:f~~.wick <scott.cranswick@mms.gov>, Brad McKim <mckimbs@BP.com>, Steye ~~þe ' <lambes@u..noca1.com>, Jack new~U <jack.~ewell@~q§a1aska~net:>, Jat11.e~Sç4~rr.. <james_scherr@yahoo.com>, david roby <Daviq,.Roby@nµns.gov>, Tirµ ~a'Yl~~':,;;:·,"' <Tim_Lawlor@ak.blm.gov>, Lynnda Kalµ1 <Lynn4a_Kahn@fWs.gov>, J~rry Rethlefs,ii\ <Jerry. C,.Deth~~fs@cqn()cophillips~cotn>, J erryPetblefs <n J617 @~op.ocQ~h1Uip~~ç()ro?::;:: lof2 11/10/2005 3:39 PM 11/10/2005 3:39 PM 20f2 ) ~0457B.OO I and AI022C.OO 1 PBU Aurora Oil Pool ) · SIAIE OF ALAS~ ALASKA OIL AND GAS CONSERVATION COMMISSION ADMINISTRATIVE APPROVAL NUMBERS AIO 22C.002 and AIO 3.010 SARAH PALIN, GOVERNOR 333 W. 7'b A VENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-75423 Mr. Frank Paskvan GPB West Manager BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, AK 99519-6612 Re: Request for modification to AIO 22C and AIO 3 to allow for commingled injection within the Aurora and Prudhoe (Western Operating Area) Oil Pools in S-31A Dear Mr. Paskvan: By letter dated November 13, 2006, BP Exploration (Alaska) Inc. ("BPXA") requested approval to allow water injection into both the Aurora Oil Pool and the Sag River Fonnation of the Prudhoe Oil Pool through multiple completions in Well S-31A. In accordance with 20 AAC 25.210, Rule 9 of Area Injection Order ("AIO") 003.000, and Rule 8 of AIO 22C the Alaska Oil and Gas Conservation Commission ("Commission") hereby grants BPXA's request with the following conditions: 1. An approved Application for Sundry Approval (Fonn 10-403) is required prior to commencement of commingled injection. 2. A downhole injection survey for purposes of allocation of injection by pool is required within 60 days of sustained injection and at least once per year thereafter so long as commingled injection continues. 3. Monthly reports of injected volumes by pool must be submitted on the Monthly Injection Report (Fonn 10-406) 4. Annual and total cumulative volumes injected by pool and results of logs or surveys used for detennining the allocation of water injection between pools must be supplied in the annual reservoir surveillance report. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. . AlO 22C.002 andAIO 3.010 December 7, 2006 Page 2 of2 DONE at Anchorage, Alaska and dated December 7, 2006. Daniel T. Seamount, Jr. Commissioner . Cathy P. oerster Commi sioner AI022C-02, Al03-1O PBU and C0329B-02 s.ver . Subject: AI022C-02, AI03-10 PBU and C0329B-02 Sag River From: Jody Colombie <:jody _ colombie@admin.state.ak.us> Date: Fri, 08 Dec 2006 09:52:23 -0900 To: undisclosed-recipients:; BCC: Cynthia B Mciver <bren _ mciver@admin.state.ak.us>, Christine Hansen <c.hansen@iogcc.state.okus>, Terrie Hubble <hubblet1@bp.com>, Sondra Stewman <StewmaSD@BP.com>, stanekj <stanekj@unoca1.com>, ecolaw <ecolaw@trustees.org>, tnnjrl <tnnjrl @ao1.com>, jdarlington <:jdarlington@forestoi1.com>, nelson <knelson@petroleumnews.com>, cboddy <cboddy@usibelli.com>, Mark Dalton <markdalton@hdrinc.com>, Shannon Donnelly <shannon.donnelly@conocophillips.com>, "Mark P . Worcester" <markp.worcester@conocophillips.com>, Bob <bob@inletkeeper.org>, wdv <wdv@dnr.state.ak.us>, tjr <tjr@dnr.state.ak.us>, bbritch <bbritch@alaska.net>, mjnelson <mjnelson@purvingertz.com>, Charles O'Donnell <charles.o'donnell@veco.com>, "Randy L. Skillern" <SkilleRL@BP.com>, "Deborah J. Jones" <JonesD6@BP.com>, "Steven R. Rossberg" <RossbeRS@BP.com>, Lois <lois@inletkeeper.org>, Dan Bross <kuacnews@kuac.org>, Gordon Pospisil <PospisG@BP.com>, "Francis S. Sommer" <SommerFS@BP.com>, Mikel Schultz <Mike1.Schultz@BP.com>, "Nick W. Glover" <GloverNW@BP.com>, "Daryl J. Kleppin" <KleppiDE@BP.com>, "Janet D. Platt" <PlattJD@BP.com>, "Rosanne M. Jacobsen" <JacobsRM@BP.com>, ddonkel <ddonkel@cfl.rr.com>, mckay <mckay@gci.net>, Barbara F Fullmer <barbara.f.fullmer@conocophillips.com>, Charles Barker <barker@usgs.gov>, doug_schultze <doug_schultze@xtoenergy.com>, Hank Alford <hank.alford@exxonmobi1.com>, Mark Kovac <yesnol@gci.net>, gspfoff <gspfoff@aurorapower.com>, Gregg Nady <gregg.nady@shell.com>, Fred Steece <fred.steece@state.sd.us>, rCfotty <rcrotty@ch2m.com>, jejones <:jejones@aurorapower.com>, dapa <dapa@alaska.net>,jroderick <:jroderick@gci.net>, eyancy <eyancy@seal-tite.net>, "James M. Ruud" <:james.m.ruud@conocophillips.com>, Brit Lively <mapalaska@ak.net>, jah <:jah@dnr.state.ak.us>, buonoje <buonoje@bp.com>, Mark Hanley <mark_hanley@anadarko.com>, , Julie Houle <:julie_houle@dnr.state.ak.us>, John W Katz <:jwkatz@sso.org>, tablerk <tablerk@unocal.com>, Brady <brady@aoga.org>, Brian Havelock <beh@dnr.state.ak.us>, bpopp <bpopp@borough.kenai.ak.us>, Jim White <:jimwhite@satx.rr.com>, "John S. Haworth" <:john.s.haworth@exxonmobi1.com>, marty <marty@rkindustrial.com>, ghammons <ghammons@ao1.com>, nnclean <nnc1ean@pobox.alaska.net>, mkm7200 <mkm7200@ao1.com>, Brian Gillespie <ifbmg@uaa.alaska.edu>, David L Boelens <dboelens@aurorapower.com>, Todd Durkee <TDURKEE@KMG.com>, Gary Schultz <gary_schultz@dnr.state.ak.us>, Wayne Rancier <RANCIER@petro-canada.ca>, Brandon Gagnon <bgagnon@brenalaw.com>, Paul Winslow <pmwinslow@forestoi1.com>, Sharmaine Copeland <copelasv@bp.com>, Kristin Dirks <kristin_dirks@dnr.state.ak.us>, Kaynell Zeman <kjzeman@marathonoi1.com>, John Tower <John.Tower@eia.doe.gov>, Bill Fowler <Bill_Fowler@anadarko.COM>, Scott Cranswick <scott.cranswick@mms.gov>, Brad McKim <mckimbs@BP.com>, Steve Lambe <lambes@unoca1.com>, jack newell <:jacknewell@acsalaska.net>, James Scherr <:james.scherr@mms.gov>, nI617@conocophillips.com, Tim Lawlor <Tim_Lawlor@ak.blm.gov>, Lynnda Kahn <Lynnda_Kahn@fws.gov>, Jerry Dethlefs <Jerry.C.Dethlefs@conocophillips.com>, crockett@aoga.org, Tamera Sheffield <sheffield@aoga.org>, Jon Goltz <Jon.Goltz@conocophillips.com>, Roger Belman <roger.belman@conocophillips.com>, Mindy Lewis <mlewis@brenalaw.com>, Kari Moriarty <moriarty@aoga.org>, Patty Alfaro <palfaro@yahoo.com>, Jeff <smetankaj@unocal.com>, Gary Rogers <gary Jogers@revenue.state.ak.us>, Arthur Copoulos <Arthur _ Copoulos@dnr.state.ak.us>, Ken <ken@secorp-inc.com>, Steve Lambert <salambert@unocal.com>, Joe Nicks <news@radiokenai.com>, Jerry McCutcheon <susitnahydronow@yahoo.com>, Bill Walker <bill-wwa@ak..net>, Iris Matthews <Iris_Matthews@legis.state.ak.us>, Paul Decker <paul_decker@dnr.state.ak.us>, Aleutians East Borough 10f2 12/8/2006 9:52 AM AJ022C-02, AJOJ- 10 PBU and COJ29B-02 S¡iV"" . <admin@aleutianseast.org>, Marquerite kremer <marguerite_kremer@dnr.state.ak.us>, Mike Mason <mike@kbbi.org>, Garland Robinson <gbrobinson@marathonoil.com>, Cammy Taylor <Camille_Taylor@law.state.ak.us>, Winton GAubert <winton_aubert@admin.state.ak.us>, Thomas E Maunder <tom_maunder@admin.state.ak.us>, Stephen F Davies <steve_davies@admin.state.ak.us>, Keith Wiles <kwiles@marathonoi1.com>, Deanna Gamble <dgamble@kakivik.com>, James B Regg <:jimJegg@admin.state.ak.us>, Catherine P Foerster <cathy_foerster@admin.state.ak.us>, Bob <Bob@fairweather.com>, gregory micallef <micallef@clearwire.net>, Laura Silliphant <laura ~ silliphant@dnr.state.ak.us>, David Steingreaber <david.e.steingreaber@exxonmobi1.com>, akpratts@acsalaska.net, Robert Campbell <Robert.Campbel1@reuters.com>, Steve Moothart <steve _ moothart@dnr.state.ak.us>, Anna Raff <anna.raff@dowjones.com>, Cliff Posey <cliff@posey.org>, Paul Bloom <paul_bloom@ml.com>, Meghan Powell <Meghan.Powell@asrcenergy.com>, Temple Davidson <temple_davidson@dnr.state.ak.us>, Walter Featherly <WFeatherly@PattonBoggs.com>, Tricia Waggoner <twaggoner@nrginc.com>, Mike Stockinger <Mike.Stockinger@anadarko.com>, , Arthur C Saltmarsh <art _ saltmarsh@admin.state.ak.us> Jody Colombie <iody colombie~admin.state.ak. us> Special Staff Assistant Alaska Oil and Gas Conservation Commission Department of Administration Content-Type: applicationlpdf c0329B-02.pdf . Content-Encodmg: base64 Content-Type: applicationlpdf ai022C-02.pdf Content-Encoding: base64 Content-Type: applicationlpdf ai03-10.pdf Content-Encoding: base64 20f2 12/8/2006 9:52 AM . Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 John Levorsen 200 North 3rd Street, #1202 Boise,ID 83702 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Ciri Land Department PO Box 93330 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 North Slope Borough PO Box 69 Barrow, AK 99723 David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 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 Schlumberger Drilling and Measurements 2525 Gambell Street #400 Anchorage, AK 99503 Ivan Gillian 9649 Musket Bell Cr.#5 Anchorage, AK 99507 Jack Hakkila PO Box 190083 Anchorage, AK 99519 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 Cliff Burglin PO Box 70131 Fairbanks, AK 99707 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 . Mona Dickens Tesoro Refining and Marketing Co. Supply & Distribution 300 Concord Plaza Drive San Antonio, TX 78216 Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle, WA 98119-3960 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Darwin Waldsmith PO Box 39309 Ninilchick, AK 99639 Penny Vadla 399 West Riverview Avenue Soldotna, AK 99669-7714 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 .. \ u Q. !\\{}~ W \ {J G \ \ \1\ u \ • • a O ~ ~ a SEAN PARNELL, GOVERNOR t>u1~-7~ OII/ ~ ~ 333 W. 7th AVENUE, SUITE 100 COI~TSERQATIOI~T CO1~II~i155IO1Q ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL NUMBERS AIO 2X.002 (Amended) and AIO 3.010 (Amended) Mr. Scott Digert WF Subsurface Resource Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Ms. Diane Richmond GPB West Subsurface Resource Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Request to Amend AIO 2X.002 and AIO 3.010 to allow for commingled WAG injection within the Aurora and Prudhoe (Western Operating Area) Oil Pools Dear Mr. Digert and Ms. Richmond: On December 7, 2006 the Alaska Oil and Gas. Conservation Commission (Commission) issued Area Injection Order (AIO) 2X.002 and AIO 3.010 approving comingled water injection in Prudhoe Bay Unit (PBU) 5-31 A. By letter dated January 22, 2010, BP Exploration (Alaska) Inc. (BP) requested approval to amend AIO 2X.002 to allow field-wide, comingled Water- Alternating Gas (WAG) injection into both the Aurora and Prudhoe Oil Pools. In accordance with Rule 9 of AIO 003.000, and Rule 8 of AIO 22C the Commission hereby denies BP's request authorizing pool wide WAG injection and grants BP's request specifically for PBU S- 31 A. WAG injection is authorized by the individual injection orders and commingling for water was allowed by the cited administrative approvals. BP Exploration Alaska has complied with the rules established that allowed commingled injection into Well S-31A and proposes to determine the necessary allocation to the pools using techniques similar to those employed while injecting water only. Since administrative approvals were issued for both oil pools, any modifications need to be made to both approvals. However, since the original approvals only applied to PBU S- 31A, the requested amendment is not appropriate for pool wide application. The following conditions apply: L An approved Application for Sundry Approval (Form 10-403) is required prior to commencement of commingled injection. 2. A downhole injection survey for purposes of allocation of injection by pool is required within 60 days of sustained injection and at least once per year thereafter so long as AIO 22C.002 (amended) and AIO 3.00 (Amended) February 2, 2010 Page 2 of 2 commingled injection continues. 3. Monthly reports of injected volumes by pool must be submitted on the Monthly Injection Report (Form 10-406) 4. Annual and total cumulative volumes injected by pool and results of logs or surveys used for determining the allocation of water injection between pools must be supplied in the annual reservoir surveillance report. ~~- DONE at Anchorage, AID and dated February 2, 2010 -~~~ ~.~. +~ . r`.. ,~ ~, Cathy . Foerster ` --' ~' "'" ` _ Commissioner RECONSIDERATION AND APPEAL As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs unti15:00 p.m. on the next day that does not fall on a weekend or state holiday. • Mary Jones David McCaleb Cindi Walker XTO Energy, Inc. IHS Energy Group Tesoro Refining and Marketing Co. Cartography GEPS Supply & Distribution 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 300 Concord Plaza Drive Ft. Worth, TX 76102-6298 Houston, TX 77056 San Antonio, TX 78216 George Vaught, Jr. Jerry Hodgden Richard Neahring PO Box 13557 Hodgden Oil Company NRG Associates Denver, CO 80201-3557 408 18th Street President Golden, CO 80401-2433 PO Box 1655 Colorado Springs, CO 80901 Mark Wedman Schlumberger Ciri Halliburton Drilling and Measurements Land Department 6900 Arctic Blvd. 2525 Gambell Street #400 PO Box 93330 Anchorage, AK 99502 Anchorage, AK 99503 Anchorage, AK 99503 Baker Oil Tools Ivan Gillian Jill Schneider 4730 Business Park Blvd., #44 9649 Musket Bell Cr.#5 US Geological Survey Anchorage, AK 99503 Anchorage, AK 99507 4200 University Dr. Anchorage, AK 99508 Gordon Severson Jack Hakkila Darwin Waldsmith 3201 Westmar Cr. PO Box 190083 PO Box 39309 Anchorage, AK 99508-4336 Anchorage, AK 99519 Ninilchick, AK 99639 James Gibbs Kenai National Wildlife Refuge Penny Vadla PO Box 1597 Refuge Manager 399 West Riverview Avenue Soldotna, AK 99669 PO Box 2139 Soldotna, AK 99669-7714 Soldotna, AK 99669-2139 Richard Wagner Cliff Burglin Bernie Karl PO Box 60868 PO Box 70131 K&K Recycling Inc. Fairbanks, AK 99706 Fairbanks, AK 99707 PO Box 58055 Fairbanks, AK 99711 North Slope Borough PO Box 69 Barrow, AK 99723 ~ul~, ti Guy1~io ~ • • Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Tuesday, February 02, 2010 1:39 PM To: 'Aaron Gluzman'; caunderwood@marathonoil.com; 'Dale Hoffman'; Frederic Grenier; 'Gary Orr'; Jerome Eggemeyer; 'Joe Longo'; 'Lamont Frazer'; Marc Kuck; 'Mary Aschoff; Maurizio Grandi; Ostrovsky, Larry Z (DNR); P Bates; Richard Garrard; 'Sandra Lemke'; 'Scott Nash'; 'Tiffany Stebbins'; 'Wayne Wooster'; 'Willem Vollenbrock'; 'William Van Dyke'; Woolf, Wendy C (DNR); (foms2@mtaonline.net); (michael.j.nelson@conocophillips.com); (Von.L.Hutchins@conocophillips.com); alaska@petrocalc.com; Anna Raff; Barbara F Fullmer; bbritch; Becky Bohrer; Bill Walker; Bowen Roberts; Brad McKim; Brady, Jerry L; Brandon Gagnon; Brandow, Cande (ASRC Energy Services); Brian Gillespie; Brian Havelock; Bruce Webb; carol smyth; Charles O'Donnell; Chris Gay; Cliff Posey; Crandall, Krissell; Dan Bross; dapa; Daryl J. Kleppin; David Boelens; David House; David Steingreaber; 'ddonkel@cfl.rr.com'; Deborah J. Jones; doug_schultze; Elowe, Kristin; Evan Harness; eyancy; Francis S. Sommer; Fred Steece; Garland Robinson; Gary Laughlin; Gary Rogers; Gary Schultz; ghammons; Gordon Pospisil; Gorney, David L.; Gregg Nady; gspfoff; Hank Alford; Harry Engel; Jdarlington Qarlington@gmail.com); Jeff Jones; Jeffery B. Jones Qeff.jones@alaska.gov); Jerry McCutcheon; Jim White; Jim Winegarner; Joe Nicks; John Garing; John S. Haworth; John Spain; John Tower; John W Katz; Jon Goltz; Joseph Darrigo; Julie Houle; Kari Moriarty; Kaynell Zeman; Keith Wiles; Laura Silliphant; Marilyn Crockett; Mark Dalton; Mark Hanley (mark.hanley@anadarko.com); Mark Kovac; Mark P. Worcester; Marquerite kremer; Michael Jacobs; Mike Bill; Mike Mason; Mikel Schultz; Mindy Lewis; MJ Loveland; mjnelson; mkm7200; nelson; Nick W. Glover; NSK Problem Well Supv; Patty Alfaro; Paul Decker (paul.decker@alaska.gov); PORHOLA, STAN T; Rader, Matthew W (DNR); Raj Nanvaan; Randall Kanady; Randy L. Skillern; Rob McWhorter; rob.g.dragnich@exxonmobil.com; Robert A. Province (raprovince@marathonoil.com); Robert Campbell; Roberts, Susan M.; Rudy Brueggeman; Scott Cranswick; Shannon Donnelly; Sharmaine Copeland; Shellenbaum, Diane P (DNR); Slemons, Jonne D (DNR); Sondra Stewman; Steve Lambert; Steve Moothart; Steven R. Rossberg; Suzanne Gibson; tablerk; Tames Sheffield; Taylor, Cammy O (DNR); Ted Rockwell; Temple Davidson; Teresa Imm; Terrie Hubble; Thor Cutler; Todd Durkee; Tony Hopfinger; trmjr1; Walter Featherly; Williamson, Mary J (DNR); Winslow, Paul M; Aubert, Winton G (DOA); Ballantine, Tab A (LAW); Brooks, Phoebe; Crisp, John H (DOA); Darlene Ramirez; Davies, Stephen F (DOA); Foerster, Catherine P (DOA); Grimaldi, Louis R (DOA); Johnson, Elaine M (DOA); Jones, Jeffery B (DOA); Laasch, Linda K (DOA); Mahnken, Christine R (DOA); Maunder, Thomas E (DOA); McIver, Bren (DOA); McMains, Stephen E (DOA); Noble, Robert C (DOA); Norman, John K (DOA); Okland, Howard D (DOA); Paladijczuk, Tracie L (DOA); Pasqual, Maria (DOA); Regg, James B (DOA); Roby, David S (DOA); Saltmarsh, Arthur C (DOA); Scheve, Charles M (DOA); Schwartz, Guy L (DOA); Seamount, Dan T (DOA) Subject: AIO 2X.002 (Amended) and AIO 3.010 (Amended) Attachments: S45C-210020213220. pdf Jody J. Colombie Special Assistant Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, .Suite 100 Anchorage, AK 99501 ~90~~~93-laze (phone) (907)276-7542 (fax) THE STATE °fALASKA GOVERNOR BILL WALKER Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov ADMINISTRATIVE APPROVAL AREA INJECTION ORDER NO. 22C.002 CANCELLATION Mr. Doug Cismoski Well Intervention Manager BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Docket Number: AIO-15-003 Request to cancel Area Injection Order (AIO) 22C.002 Prudhoe Bay Unit (PBU) S-31A (PTD 1982200) Prudhoe Bay Field Aurora Oil Pool, Prudhoe (Western Operating Area) Oil Pool Dear Mr. Cismoski: By letter dated January 6, 2015, BP Exploration (Alaska) Inc. (BPXA) requested cancellation of administrative approval (AA) Area Injection Order (AIO) 22C.002. In accordance with Rule 8 of AIO 22C.000, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS BPXA's request to cancel the AA. On December 7, 2006 the AOGCC issued AIO 22C.002 and AIO 3.010 approving comingled water injection in PBU S-31A. On February 2, 2010 the AOGCC amended these orders to authorize Water Alternating Gas (WAG) injection in PBU S-31A. BPXA has performed a rig workover of S-31A completed in August 2014 which plugged and abandoned the perforations in the Prudhoe Oil Pool and the well is now injecting only into the Aurora Oil Pool. AA AIO 22C.002 is no longer necessary to the operation of S-31 A and is hereby CANCELLED. Injection into PBU S-31A will be governed by provisions of AIO No. 22E.000. AIO 22C.002 Cancellation January 8, 2015 Page 2 of 2 DONE at Anchorage, Alaska and dated January 8, 2015 Cathy . Foerster Daniel T. Se ount, Jr. Chair, Commissioner Commissioner Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Singh, Angela K (DOA) From: Carlisle, Samantha J (DOA) Sent: Friday, January 09, 2015 9:53 AM To: AKDCWellIntegrityCoordinator, Alexander Bridge; Allen Huckabay; Andrew VanderJack; Anna Raff; Barbara F Fullmer, bbritch; bbohrer@ap.org; Barron, William C (DNR); Bill Penrose; Bill Walker; Bob Shavelson; Brian Havelock, Burdick, John D (DNR); Carrie Wong; Cliff Posey; Colleen Miller, Corey Cruse; Crandall, Krissell; D Lawrence; Dave Harbour; David Boelens; David Duffy; David Goade; David House; David McCaleb; David Scott; David Steingreaber; David Tetta; Davide Simeone; ddonkel@cfl.rr.com; Dean Gallego; Delbridge, Rena E (LAA); Donna Ambruz; Ed Jones; Elowe, Kristin; Evans, John R (LDZX); Francis S. Sommer; Frank Molli; Gary Oskolkosf; George Pollock; ghammons; Gordon Pospisil; Greg Duggin; Gregg Nady; gspfoff, Jacki Rose; Jdarlington Oarlington@gmail.com); Jeanne McPherren; Jones, Jeffery B (DOA); Williams, Jennifer L (LAW); Jerry Hodgden; Jerry McCutcheon; Solnick, Jessica D (LAW); Jim Watt; Jim White; Joe Lastufka; news@radiokenai.com; John Adams; Easton, John R (DNR); John Garing; Jon Goltz; Jones, Jeffrey L (GOV); Juanita Lovett; Judy Stanek, Houle, Julie (DNR); Julie Little; Kari Moriarty; Keith Wiles; Kelly Sperback; Klippmann; Gregersen, Laura S (DNR); Leslie Smith; Lisa Parker; Louisiana Cutler; Luke Keller, Marc Kovak; Dalton, Mark (DOT sponsored); Mark Hanley (mark.hanley@anadarko.com); Mark Landt; Mark Wedman; Kremer, Marguerite C (DNR); Michael Duncan; Michael Jacobs; Michael Moora; Mike Bill; mike@kbbi.org; Mikel Schultz; MJ Loveland; mjnelson; mkm7200; Morones, Mark P (DNR); knelson@petroleumnews.com; Nichole Saunders; Nick W. Glover; Nikki Martin; NSK Problem Well Supv; Oliver Sternicki; Patty Alfaro; Paul Craig; Decker, Paul L (DNR); Paul Mazzolini; Pike, Kevin W (DNR); Randall Kanady; Randy L. Skillern; Randy Redmond; Renan Yanish; Robert Brelsford; Ryan Tunseth; Sara Leverette; Scott Griffith; Shannon Donnelly; Sharmaine Copeland; Sharon Yarawsky, Shellenbaum, Diane P (DNR); Slemons, Jonne D (DNR); Smart Energy Universe; Smith, Kyle S (DNR); Sondra Stewman; Stephanie Klemmer; Moothart, Steve R (DNR); Suzanne Gibson; sheffield@aoga.org; Tania Ramos; Ted Kramer, Davidson, Temple (DNR); Terence Dalton; Teresa Imm; Thor Cutler, Tim Mayers; Tina Grovier; Todd Durkee; Tony Hopfinger; trmjrl; Tyler Senden; Vicki Irwin; Vinnie Catalano; Walter Featherly; yjrosen@ak.net; Aaron Gluzman; Aaron Sorrell; Ajibola Adeyeye; Alan Dennis; Andrew Cater, Anne Hillman; Bruce Williams; Bruno, Jeff J (DNR); Casey Sullivan; David Lenig; Diane Richmond; Dickenson, Hak K (DNR); Donna Vukich; Eric Lidji; Erik Opstad; Gary Orr; Smith, Graham O (PCO); Greg Mattson; Hans Schlegel; Heusser, Heather A (DNR); Holly Pearen; James Rodgers; Jason Bergerson; Jennifer Starck; jilt.a.mcleod@conocophillips.com; Jim Magill; Joe Longo; John Martineck; Josh Kindred; Kenneth Luckey; King, Kathleen J (DNR); Laney Vazquez; Lois Epstein; Longan, Sara W (DNR); Marc Kuck, Marcia Hobson; Steele, Marie C (DNR); Matt Armstrong; Matt Gill; Franger, James M (DNR); Morgan, Kirk A (DNR); Pat Galvin; Bettis, Patricia K (DOA); Peter Contreras; Richard Garrard; Robert Province; Ryan Daniel; Sandra Lemke; Pexton, Scott R (DNR); Peterson, Shaun (DNR); Pollard, Susan R (LAW); Talib Syed; Terence Dalton; Todd, Richard 1 (LAW); Tostevin, Breck C (LAW); Wayne Wooster, William Hutto; William Van Dyke; Ballantine, Tab A (LAW); Bender, Makana K (DOA); Brooks, Phoebe L (DOA); Carlisle, Samantha J (DOA); Colombie, Jody J (DOA); Crisp, John H (DOA); Davies, Stephen F (DOA); Eaton, Loraine E (DOA); Foerster, Catherine P (DOA); Frystacky, Michal (DOA); Grimaldi, Louis R (DOA); Guhl, Meredith D (DOA); Herrera, Matthew F (DOA); Hill, Johnnie W (DOA); Hunt, Jennifer L (DOA); Kair, Michael N (DOA); Konkler, Stacey L (DOA); Loepp, Victoria T (DOA); Mayberry, David J (DOA); Mumm, Joseph (DOA sponsored); Noble, Robert C (DOA); Paladijczuk, Tracie L (DOA); Pasqual, Maria (DOA); Regg, James B (DOA); Roby, David S (DOA); Scheve, Charles M (DOA); Schwartz, Guy L (DOA); Seamount, Dan T (DOA); Singh, Angela K (DOA); Skutca, To: Joseph E (DOA); Wallace, Chris D (DOA) Subject: AIO 2C.010, AIO 2C.011, AIO 3.010 Cancellation, AIO 22C.002 Cancellation (Kuparuk River Field) Attachments: aio2c-010.pdf, aio2c-011.pdf; aio3-010 cancellation.pdf; aio22c-002 cancellation.pdf Please see attached. Thank you! Samantha CarlisCe Executive Secretary II Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 (907) 793-1223 (phone) (907) 276-7542 (fax) CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Samantha Carlisle at (907) 793-1223 or Samantha.Carlisle@alaska.gov. James Gibbs Jack Hakkila Bernie Karl Post Office Box 1597 Post Office Box 190083 K&K Recycling Inc. Soldotna, AK 99669 Anchorage, AK 99519 Post Office Box 58055 Fairbanks, AK 99711 Gordon Severson Penny Vadla George Vaught, Jr. 3201 Westmar Cir. 399 W. Riverview Ave. Post Office Box 13557 Anchorage, AK 99508-4336 Soldotna, AK 99669-7714 Denver, CO 80201-3557 Mr. Doug Cismoski Richard Wagner Darwin Waldsmith Well Intervention Manager Post Office Box 60868 Post Office Box 39309 BP Exploration (Alaska), Inc. Fairbanks, AK 99706 Ninilchik, AK 99639 Post Office Box 196612 Anchorage, AK 99519-6612 cLk 2olS Angela K. Singh . ~1f~1fŒ (ID~ ~~~~[{~ . A .,.4.SIiA. OIL AlQ) GAS CONSERVATION COMMISSION SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRA TIVE APPROVAL AIO 22C.003 Mr. Steve Rossberg Wells Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 RE: PBU S-111 (PTD 2050510) Request for Administrative Approval Dear Mr. Rossberg: In accordance with Rule 8 of Area Injection Order ("AIO") 22.000, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants BP Exploration (Alaska) Inc. ("BPXA")'s request for administrative approval to continue water injection in the subject well. PBU S-111 exhibits slow tubing by inner annulus communication. AOGCC finds that BPXA has elected to perform no corrective action at this time on PBU S-111. The Commission further finds that, based upon reported results of BPXA's diagnostic procedures, PBU S-111 exhibits two competent barriers to release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's administrative approval to continue water injection only in PBU S-111 IS conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injection rates; 3. BPXA shall perform an MIT - IA every 2 years to 1.2 times the maXImum anticipated well pressure; 4. BPXA shall limit the well's IA pressure to 2,000 psi; 5. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; . . AIO 22C.003 July 17,2007 Page 2 of2 6. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection, and 7. The MIT anniversary date is May 13,2007. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DONE at Anchorage, Alaska and dated July 17,2007. Daniel T. Seamount, Jr. Commissioner . Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Wednesday, July 18, 2007 8:42 AM Subject: aio3-019 and aio22c-003 Attachments: Colombie, Jody J (DOA).vcf; aio3-019.pdf; aio 22c-003.pdf Jody J. Colombie Special Assistant to the Commission I State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Tel: (907) 793-1221 Fax:(907)276-7542 7/18/2007 . Page 1 of 1 Mary Jones XTO Energy. Inc. Cartography 810 Houston Street. Ste 2000 Ft. Worth, TX 76102-6298 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 John Levorsen 200 North 3rd Street, #1202 Boise, 10 83702 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 Ivan Gillian 9649 Musket Bell Cr.#5 Anchorage, AK 99507 Jack Hakkila PO Box 190083 Anchorage, AK 99519 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 Cliff Burglin PO Box 70131 Fairbanks, AK 99707 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 . David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 Jerry Hodgden Hodgden Oil Company 408 18th Street Golden, CO 80401-2433 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle, WA 98119-3960 Schlumberger Drilling and Measurements 2525 Gambell Street #400 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Darwin Waldsmith PO Box 39309 Ninilchick, AK 99639 Penny Vadla 399 West Riverview Avenue Soldotna, AK 99669-7714 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 . Mona Dickens Tesoro Refining and Marketing Co. Supply & Distribution 300 Concord Plaza Drive San Antonio, TX 78216 Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Ciri Land Department PO Box 93330 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 North Slope Borough PO Box 69 Barrow, AK 99723 / /( / 1 /)~ ¡l\\N~0: \S0 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: THE APPLICATION OF BP ) Area Injection Order No. 22D.003 and EXPLORATION (ALASKA) INC. ) 22C.003 Cancellations for cancellation of Administrative ) Approvals 22D.003 and 22C.003 ) Prudhoe Bay Unit allowing well S-111 (PTD 2050510) ) Prudhoe Bay Field to return to water alternating gas ) Aurora Oil Pool injection (WAGIN) service. ) January 22, 2014 By letter dated January 1, 2014, BP Exploration (Alaska) Inc. (BPXA) requested cancellation of administrative approval (AA) Area Injection Order (AIO) 22D.003 to allow well S-I I I (PTD 2050510) to return to normal water alternating gas injection (WAGIN) service. In accordance with Rule 9 of AID 022D.000, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS BPXA's request to cancel the AA and return the well to WAGIN service as detailed below. S-111 exhibited a slow inner annulus repressurization while on gas injection. However, the Commission determined that water injection could safely continue if BPXA complied with the restrictive conditions set out in AA AIO 22D.003. BPXA has performed a well intervention to eliminate the repressurization. S-111 passed a Mechanical Integrity Test of the Inner Annulus (MITIA) on October 6, 2013. BPXA then requested a 60 day gas injection monitoring period for inner annulus repressurization. The monitoring period was completed December 18, 2013. No indication of inner annulus repressurization was observed. AA AIO 22C.003 was issued July 17, 2007 for slow tubing by inner annulus communication. AIO 22D superseded and replaced AID 22C January 30, 2008. AID 22D.003 was issued February 9, 2011 for S-I I I and AIO 22C.003 should have been cancelled at that time. AA AIO 22C.003 is no longer necessary to the operation of this well and is hereby CANCELLED. BPXA provided wellhead pressure data and injection rates and pressures demonstrating the elimination of inner annulus repressurization while injecting gas. AA AID 22D.003 is no longer necessary to the operation of this well and is hereby CANCELLED. Injection into PBU S-1 I I will be governed by provisions of AIO No. 22D. AIO 22D.003 and AIO 22C.0030ncellations January 22, 2014 Page 2 of 2 DONE at Anchorage, Alaska and dated January 22, 2014. Cathy Y. Foer er Daniel T. Seam, unt, Jr. Chair, Commissioner Commissioner TION AND APPEAL As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Carlisle, Samantha J (DOA) From: Carlisle, Samantha J (DOA) Sent: Thursday, January 23, 2014 8:08 AM To: Ballantine, Tab A (LAW); Bender, Makana K (DOA); Bettis, Patricia K (DOA); Brooks, Phoebe L (DOA); Carlisle, Samantha 1 (DOA); Colombie, Jody J (DOA); Crisp, John H (DOA); Davies, Stephen F (DOA); Eaton, Loraine E (DOA); Ferguson, Victoria L (DOA); Foerster, Catherine P (DOA); Frystacky, Michal (DOA); Grimaldi, Louis R (DOA); Hunt, Jennifer L (DOA); Johnson, Elaine M (DOA); Jones, Jeffery B (DOA); Mumm, Joseph (DOA sponsored); Noble, Robert C (DOA); Norman, John K (DOA); Paladijczuk, Tracie L (DOA); Pasqual, Maria (DOA); Regg, James B (DOA); Roby, David S (DOA); Scheve, Charles M (DOA); Schwartz, Guy L (DOA); Seamount, Dan T (DOA); Singh, Angela K (DOA); Turkington, Jeff A (DOA); Wallace, Chris D (DOA); (michael.j.nelson@conocophillips.com); AKDCWellIntegrityCoordinator; Alexander Bridge; Andrew VanderJack; Anna Raff; Barbara F Fullmer; bbritch; bbohrer@ap.org; Barron, William C (DNR); Bill Penrose; Bill Walker; Brian Havelock; Burdick, John D (DNR); Cliff Posey; Colleen Miller; Crandall, Krissell; D Lawrence; Daryl J. Kleppin; Dave Harbour; Dave Matthews; David Boelens; David Duffy; David Goade; David House; David Scott; David Steingreaber; Davide Simeone; ddonkel@cfl.rr.com; Donna Ambruz; Dowdy, Alicia G (DNR); Dudley Platt; Elowe, Kristin; Evans, John R (LDZX); Francis S. Sommer; Frank Molli; Schultz, gary (DNR sponsored); ghammons; Gordon Pospisil; Gorney, David L.; Greg Duggin; Gregg Nady; gspfoff, Jacki Rose; Jdarlington oarlington@gmail.com); Jeanne McPherren; Jerry McCutcheon; Jim White; Jim Winegarner; Joe Lastufka; news@radiokenai.com; Easton, John R (DNR); John Garing; Jon Goltz; Jones, Jeffrey L (GOV); Juanita Lovett; Judy Stanek; Houle, Julie (DNR); Julie Little; Kari Moriarty; Keith Wiles; Kelly Sperback; Klippmann; Gregersen, Laura S (DNR); Leslie Smith; Lisa Parker; Louisiana Cutler; Luke Keller; Marc Kovak; Dalton, Mark (DOT sponsored); Mark Hanley (mark.hanley@anadarko.com); Mark P. Worcester; Kremer, Marguerite C (DNR); Michael Jacobs; Mike Bill; mike@kbbi.org; Mikel Schultz; Mindy Lewis; MJ Loveland; mjnelson; mkm7200; knelson@petroleumnews.com; Nick W. Glover, Nikki Martin; NSK Problem Well Supv; Patty Alfaro; Decker, Paul L (DNR); Paul Mazzolini; Pike, Kevin W (DNR); Randall Kanady; Randy L. Skillern; Randy Redmond; Rena Delbridge; Renan Yanish; Robert Brelsford; Ryan Tunseth; Sandra Haggard; Sara Leverette; Scott Griffith; Shannon Donnelly; Sharmaine Copeland; Sharon Yarawsky; Shellenbaum, Diane P (DNR); Slemons, Jonne D (DNR); Smart Energy Universe; Smith, Kyle S (DNR); Sondra Stewman; Stephanie Klemmer; Steve Kiorpes; Moothart, Steve R (DNR); Steven R. Rossberg; Suzanne Gibson; sheffield@aoga.org; Tania Ramos; Ted Kramer; Davidson, Temple (DNR); Terence Dalton; Teresa Imm; Thor Cutler; Tim Mayers; Tina Grovier; Todd Durkee; Tony Hopfinger; trmjrl; Tyler Senden; Vicki Irwin; Vinnie Catalano; Walter Featherly; yjrosen@ak.net; Aaron Gluzman; Aaron Sorrell; Ajibola Adeyeye; Alan Dennis; Andrew Cater; Anne Hillman; Bruce Williams; Bruno, Jeff J (DNR); Casey Sullivan; David Lenig; Perrin, Don J (DNR); Donna Vukich; Eric Lidji; Erik Opstad; Gary Orr; Smith, Graham 0 (PCO); Greg Mattson; Hans Schlegel; Heusser, Heather A (DNR); Holly Pearen; James Rodgers; Jason Bergerson; Jennifer Starck; jilt.a.mcleod@conocophillips.com; Jim Magill; Joe Longo; Josh Kindred; King, Kathleen J (DNR); Laney Vazquez; Lois Epstein; Longan, Sara W (DNR); Marc Kuck; Marcia Hobson; Steele, Marie C (DNR); Matt Armstrong; Matt Gill; Franger, James M (DNR); Morgan, Kirk A (DNR); Pat Galvin; Bettis, Patricia K (DOA); Peter Contreras; Pollet, Jolie; Richard Garrard; Ryan Daniel; Sandra Lemke; Pexton, Scott R (DNR); Peterson, Shaun (DNR); Pollard, Susan R (LAW); Talib Syed; Terence Dalton; Todd, Richard J (LAW); Tostevin, Breck C (LAW); Wayne Wooster; Woolf, Wendy C (DNR); William Hutto; William Van Dyke Subject: AI022D.003 and AI022C.003 cancellations (Prudhoe Bay Unit) Attachments: ab d-003 and aio22c-003 cancel lations.pdf Samantha Carlisle Executive Secretary II .Alaska OiCandGas Conservation Commission 333 West Irk ..Avenue, Suite wo .Anchorage, AX 99501 (907) 793-1223 (yhone) (907) 276-7542 fax) 0 Doug Cismoski Well Intervention Manger BP Exploration (Alaska), Inc. Post office Box 196612 Anchorage, AK 99519-6612 VV&k e David McCaleb Penny Vadla IHS Energy Group 399 W. Riverview Ave. GEPS Soldotna, AK 99669-7714 5333 Westheimer, Ste. 100 Houston, TX 77056 Jerry Hodgden Richard Neahring Hodgden Oil Company NRG Associates 408 18`h St. President Golden, CO 80401-2433 Post Office Box 1655 Colorado Springs, CO 80901 Bernie Karl CIRI K&K Recycling Inc. Land Department Post Office Box 58055 Post Office Box 93330 Fairbanks, AK 99711 Anchorage, AK 99503 North Slope Borough Planning Department Richard Wagner Post Office Box 69 Post Office Box 60868 Fairbanks, AK 99706 Barrow, AK 99723 Jack Hakkila Darwin Waldsmith Post Office Box 190083 Post Office Box 39309 Anchorage, AK 99519 Ninilchik, AK 99639 George Vaught, Jr. Post Office Box 13557 Denver, CO 80201-3557 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Baker Oil Tools 795 E. 941h Ct. Anchorage, AK 99515-4295 Gordon Severson 3201 Westmar Cir. Anchorage, AK 99508-4336 James Gibbs Post Office Box 1597 Soldotna, AK 99669 ML& `LsCS 10 BP Exploration (Alaska) Inc. Doug Cismoski, Well Intervention Manager Post Office Box 196612 Anchorage, Alaska 99519-6612 January 6, 2015 RECEIVED by JAN 0 7 2015 AOGCC 4> Ms. Cathy P. Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Aurora Unit S-31A (PTD1982200) Request for cancellation of administrative approval (AA) Area Injection Order 22C.002 and 3.010 allowing comingled injection in well AURA S- 31 A. Dear Ms. Foerster, BP Exploration (Alaska) Inc. requests cancellation of administrative approval (AA) Area Injection Order 22C.002 and 3.010 allowing comingled injection in well AURA S-31A. In August of 2014 the Sag perforations in AURA S-31A were plugged and abandoned per Sundry 314-389 and the well is now injecting only into the Kuparuk. If you require any additional information, please contact me at 564-4303 or Kevin Parks/ Laurie Climer at 659-5102. Sincerely, Doug 7ismoski Well Intervention Manager Attachments Wellbore Schematic TIO Pressure Plot Injection Plot Tom- 4'CM V�ELLHEA,D RC ACTUATOR - OTIS S-31A OKB, 2-EV = 66.5D' KOPz 2449' Max Angle z 98'a 110DEY UMumMD= 13919* Fi33J8- cm &w. W -soum i2-4-15'�27w�l (9-5�TX7"BKR ZXPLTRV=4890- w9r MiniRTTum ID - 2.813" @ 8659- NIPPLE 1, 0152 bpfl) = 3 �OW 9 _12 M. L:�O, �T 10* - I I MI 1. 11 .. L . � �U - 2 870--14- U"--1 PJNCH (ON07114) H 861 Ir - 8621* J;-lrZ-PtWKWJ0RTw/l8X31frFK)LES 1--L SCAB LW M, L-K TG-k MW bpf. ID -5276- 14-irrTBG,12-69,L-BOTC-t,0152bpf, 0=3.95r -[_10458• 14-M- TBG SRJU (11 - F —1 0-4—w— 7 L-W TC-t.0D87 bpf. 10 = 2192-_H:1046s3' X4 lr2-TTWFKRwlANCHCP,1D=4-0W 104W -F-1-0610 -1 TEIG, 126#, NI-13CR-80, B152 bpf, ID = 3,958- WMP :C"=-E,=iO782* 9-518'CSG, 47#, NT-WS, K) = 8.681' -j 107-83' r LW 20, NT- 13-CR .0383 bpf. V = 6216- 1-, 14 PBWORATK)N SLMMITY REF LOG, SWS GR-OL-BHCS ON 12JI0190 ANIIFATTOPPFW 40-@7999' We: Refer to Production DB for hi5torical perf data SIZE I SPF INTEWAL OpriSqz DATE 4-112'; 5 7999-8089- C 12IM06 4-1111-1 :) 8149-81139- C 1210GO6 SLMLNR 11097-12618 0 11105198 --Mlll- Ur 1 K5 CTJRM--1: I ED PER APE JOW17109 "Al Lj, F039EBBEED USIT GAT El 11127106 COMECTED DEPT iS SAFETY NOTES: 142S READINGS AVERAGE 125 ppirn VM84 ON Mi. WELLARPqlWRE4 A SS$V WHOV ON Mt WELL ANGLE - 70* & 10869'. •'"Cf9i0N E TRG A LNR- GAS LIFT MANDRELS MD IV017 1 (-H,PORTJ, DATE io IIYW li�l 4 MO 3419 Mw' QMY K 7* x 4 1/7 BKR PFU" FKR, 1) !.I �70 77-03' SILD SLV, I OPENEI)(0114111114) 7759" 4- 10 X 3-10 XO, ID = 2 7921* 3 - M* HES X NP, 1) = 2.8 ti'-] WA TFR AAA NIFIARR R ST MID TVD DEV, TYPE VLV LATCH PORT DATE 3 7802 1650 1 40 M11C, Wl DM Y RK 0 1-2113106 2 71180 I e554 1 40 1 WAG OW RK I 1 0 IV113416 _L 6599 7121 M WX-W OW Ric 12/13/0e 3-lfrl-MXNP.lD=2.813' r OF CEPJENT (0-8t71(04) 1 X X 4-i/2'BKR - 6—vb;i7t]6f"76---Tb0-F1 D- CP H4.lrr BKR 4-1 r2- PKR SYvS NP, K) = 3,81ir (MM PIPE) 2.313' Sn NIP U = 3 125- (BB4NO PIPE) pf --Klia TBGTAIL.W1LM(86iiW' MLLOUl WINDOW (S-31A) 10785'- 10792' WE 121MMI I VOWN 01121199 1216106 0610111 REV BY COME DATE REV BY COMMITS PRMHOE MY UNIT WELL: S-31A FEFUT lib: 19B-2200 AR W: 50-02D-22109-M SEC 35,Tl2N.Tl2F-1639FN-&1450FVA-. OFF 0MUNRL GEIIEPLETM 07/15(14PMJK CLOSESLDSLV (07IM14) NHrTL0V SK)ETPACK-A- 071151114 AC FULL PX R-UG (07M 0M) GEM LASTWORKOVER OW7/14 JSI PJC � RMI T IVE9 RM MM()0]I114 PJC FM (CMT I" PL SCT PX LK, (10" 'WI MIEV11) IJ14 C-JR PJC OPEN SILD SLV RIP Explwadon (Alaska) SAFETY NOTE Attachment 1: S-31A wellbore schematic S-31 Tiff Plat i IfC 2XC �'y..14 .+lIS114 ,+ 'iS-391,00,It :IVIIIII:,13 12flllT3 IT)DIri5 Attachment 2: S-31A TIO pressure plot —0 Tbg - ■ Li —A - OA OCIA ♦ COCA On Date Start'End 1/g/2014 11GrZ015 Reload Plot TIO God Save to ward Cursor Value X 121d8812013 Y 4,537 4,60& 4,40LI 4,2 J 4' 3 80C, 3.6CO 3.400 3.27M) 3. 2,3M 2,6W 2.400 3� 2,2D1 $f�G 1,60D 1.441t 1,200 1.f16U BW GM 40D 200 Sag perforations plugged and abandoned. vl+z++� _ _ ."J"ZW4 tAZ6t4 Ut,Z*14 £PIa2';14 073w14 3&30:14 09:3,14 13,1114 12PSi1114 411t'i11 115 Attachment 3: S-31A injection plot Dace Stwt/&ul 1/G/M14 Fkk at_ ky God Log Scale M KC CUMee Value 2.4M X 02/16/2014 2,20D � P Y 4,248 2:e — R, - MI , - GI -off '.. L40D on 1.2C� 6W #9 0 BP Exploration (Alaska) Inc. Doug Cismoski, Well Intervention Manager Post Office Box 196612 Anchorage, Alaska 99519-6612 January 01, 2014 Ms. Cathy Foerster, Chairman Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 RECEIVED by JAN 0 6 2014 AOGCG 0 Subject: Prudhoe Bay Unit Well S-111 (PTD #2050510) Application for Cancellation of AIO Administrative Approval 22D.003 Dear Ms. Foerster, BP Exploration (Alaska) Inc. requests cancellation of Administrative Approval 22.D.00date d 02/09/2011. The Administrative Approval limits the well to water Injection only due to slow inner annulus repressurization while on miscible gas injection. S-111 underwent a rig workover completed on 06/25/2013. The tubing was replaced during the workover to eliminate tubing x inner annulus communication. An AOGCC witnessed MIT -IA passed to 2500 psi on 10/06/2013 following the workover. The passing test indicates the tubing and production casing are competent. BP received permission from the AOGCC to place the well on miscible gas injection for a period of 60 days to monitor for inner annulus repressurization. The monitoring period began on 10/20/2013 and ended on 12/18/2013. There was no indication of inner annulus communication during the monitoring period. A nitrogen cap was placed in the inner annulus on 12/10/2013 for UIC compliance. In summary, BP believes Prudhoe Bay well S-111 is safe to operate while injecting miscible gas and requests AIO Administrative Approval 22D.003 be cancelled. If you require any additional information, please contact me at 564-4303 or Jack Disbrow / Laurie Climer at 659-5102. Sincerely, Doug Cismoski Well Intervention Manager BE 'T XE loctor S-1 11 (PTD #2050510) TIO A welLS-111 Injector S-1 11 (PTD #2050510) Injection Plot WC11:S-111 12&13 1 1'QV i 3 11123,13 11,X13 12CI13 121473 12211131 12291.3 1 Tbg 1A --4-04 004 —4— M — on 6 DEC, —PW -M 5 X-c' Z —G1 —Oa 4 005 on 3 OCO 2 Xf TREE = CtW VVELLHEAD = FMC ACTUATOR= HES LEO NML KB. ELE 64.40' BF. ELEV = 35.60' KOP= 62(Y Max Angle = 98° @ 12270 Datum MD = 11371' Datum TVD = 6700' SS 10-3/4' CSG, 45.5#, L-80 BTC, D = 9.95" 47 Minimum ID = 3.813" ta@ 2124' 4-1/2" HES X NIPPLE S-111 SAFETY NOTES: H2S READINGS AVERAGE 125 ppm WHEN ON MI — WELL REQUIRES A SSSV WHEN ON MI — WELL ANGLE> 70" @ 11636' ""'_� 7" TAM PORT COLLAR 244-1/2" D 11124' 11160' 1—{ 7-5/8" X 4-1 /2" BKR S-3 PKR, D = 3.875" 4-1/2" TBG, 12.6#, L-80 TG11, 11261' .0152 bpf, D = 3,958' -1/2" TUBING STUB (05/28/13) 11271' 11188' —�4 1/2' HES X NP, D = 3.813" 11274' 7-5/8' X 4 1!2" UNK2UEOVERSHOI 11320' 4-1/2" HES X NP, D = 3.813" 11341' 11364' 4-1/2' HES X NP, D = 3.813" 11385' 4-1/2' HIS X NP, D= 3.813' 11387' 7-5l8' X 5-1 /2" BKR HRO ZXP LTP D = 5.580' -1/2' TBG,12.6#, L-80 TGIt 11398' r 11398'152 bpf, D = 3.958" 11409' 7-518" X 5-1/2' BKR FLEX LOCK HGR, D = 4.830" 11419' S•1/2' X 4-1/2" XO, D = 3.93" WHPSTOCK (05/31/05) 11636' 7-5l8' CSG, 29.7#, L-80 BTC-M, —11535 0459 bpf, D = 6.875' PERFORATION SUAWARY REF LOG: SLB MVVD 10/12/04 ANGLE AT TOP PERF 66° @ 11534' Note: Refer to Production DB for historical perf data SQE SPF I INTERVAL I Opn/Sgz I SHOT SOZ SEEPAGE 2 FOR PERFORATION DATA PB_M 1795V 4-1/2" LNR, 12.6#, L-80, HYD 521, 18040' -0152 bpf, D = 3.958" MLLOUT WINDOW (S-111) 11535' - 11545' 1179Z I -IRA TAG (MIDDLEOF PUPJOINT) 16791' 1 RA TAG (MIDDLE OF PUP JOINT) 17100' 4-1/2" BKRCBP(09/14/08) AURORA UNT WELL: S-111 PERNT No: 2050510 AR No: 50-029-23257-00 SEC 35, T12K R12E, 753' FNL 8 783 FWL DATE 07/08/05 I RFV BY 0DK*A3,1TS DATE REV BY CON6134TS WES ORIGINAL COMPLETION 08/15/13 JTG/JAD BALED SLUGGITS/PlA_LED PLUG 06/26113 D•16 RWO 06/28/13 ?/JMD DRLG HO COR1RBC"T10NS 06/30/13 PJC TBG D CORRE� 07/03/13 MPJC 1 FINALODEAPPROVAL BP Exploration (Alaska) L08/15/131 JTG/JMD I JUNK CATCHEi2 PILL BY S-111 PBTORATION SLK" RY REF LOG: SLB I D 10/12/04 ANGLEAT TOP PEW: 66' @ 11534' Note: Refer to Production DB for historical pert data SIZE SPF K ERVAL Opn/Sqz SHOT SOZ 3-3/8" 6 11534 - 11559 O 09/16/08 3-3/8" 6 11550 - 11565 O 10/18105 3-3/8" 6 11602 - 11627 O 09/16/08 3-3/8" 6 11672 - 11697 O 09/16/08 3-3/8" 6 12973 - 12998 O 09/15/08 3-3/8" 6 13200 - 13215 O 10/18105 3-3/8" 6 14537 - 14562 O 09/15108 3-3/8" 6 16180 - 16250 O 07/04/05 3-3/8" 6 16330 - 16450 O 07/04/05 3-3/8" 6 16550 - 16590 O 07/04/05 3-3/8'1 6 17200 - 17300 C 07/04/05 3-3/8" L 17520 - 17950 C 07104/05 DATE 07/08/05 06126113 06/28/13 06/30/13 07/03/13 08/15/13 ALRORA LUT WELL S-111 PER?AT No: 2050510 AN No: 50-029-23257-00 SEC 35, T12K R12E, 753' FNL & 783' FWL REV BY COMANTS DATE REV BY COMMENTS WE5 ORIGINAL COMPLETION 08/15/13 JTGIJMD BAIL® SLLlGGrTS/PULLED PLUG I D-16 RWO ?1JKU DRLG HO CORRECTIONS PJC TBG ID CORRECTIONS W PLIC FN1AL ODE APPROVAL BP Exploration (Alaska) JTG/JM) I JLW CATCHER PULL BY #$ ~ECEIVE® IAN 2 7 2010 January 22, 2010 Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Alaska 0~ & Gas Ceps. Commission Ancherape RE: Amendment to Area Injection Order 2X.002 -Commingled injection in the Aurora Oil Pool and Prudhoe Oil Pool BP Exploration (Alaska) Inc. respectfully requests administrative approval for an amendment to AIO 2X.002 to allow multiple completions of Water Alternating Gas (WAG) injection wells within the Aurora and Prudhoe Western Operating Oil pools. It is currently approved for commingled water injection only and we'd like to expand to cover WAG service. Injector S-31A is an injector completed in both the Sag River formation of the Prudhoe pool and the Aurora pool where we plan to commence commingled WAG injection upon approval. Results of logs, surveys or downhole monitoring used to determine the allocation of water and gas injection between the two pools, if applicable, will be supplied in the annual reservoir surveillance report. Please call Danielle Ohms 564-5759 if you have any questions or wish to discuss further. Sincerely, ,.;~~ t r .,t ~ + -~' cot art/ Diane Richmond Subsurface Resource Managers, WF/ GPB WEST cc: Judy Buono (BPXA) Dan Kruse (CPAI) Mark Agnew (Exxon-Mobil) Glen Fredrick (Chevron-Texaco) -:t:f7 · REC~ED JUL 0 9 2007 ò BP Exploration (Alaska) Inc. Steve Rossberg, Wells Manager Post Office Box 1 9661 Z Anchorage, Alaska 99519-661 Z :~íaska Oil & Gas Cons. Gammissìon Anchorage July 03, 2007 Mr. John Norman, Chairman Alaska Oil and Gas Conservation Commission 333 West ih Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay Unit S-111 (PTD # 2050510) Request for Administrative Approval: Continue Water Injection Operations Dear Mr. Norman, BP Exploration (Alaska) Inc. requests approval to continue water injection operations into Prudhoe Bay well S-111. Well S-111 exhibits slow inner annulus repressurization when on gas I MI injection indicated by wellhead pressure trends on a TIO plot. However, a pressure test of the inner annulus passed to 3000 psi, indicating the tubing and production casing are competent. Based upon sound engineering practice, two competent barriers have been established and thus the well can be safely operated. Observed annulus operating pressures do not exceed 45% of the casing's rated burst pressure. Consequently, no repairs are planned at this time. In summary, BPXA believes Prudhoe Bay well S-111 is safe to operate as stated above and requests administrative approval for continued water injection operations. If you require any additional information, please contact me at 564-5637 or Anna Dube / Andrea Hughes at 659-5102. Sincerely, ~ Steve Rossberg Wells Manager . . Attachments: Technical Justification TIO Plot Wellbore Schematic Cc: Bixby/Olsen Dube/Hughes West Area Manager Jim Young Harry Engel John Kurz . . Prudhoe Bay Unit 5-111 Technical Justification for Administrative Approval Request July 03, 2007 Well History and Status Prudhoe Bay Unit well S-111 (PTD # 2050510) exhibits slow inner annulus repressurization when on gas / MI injection indicated by wellhead pressure trends on a TIO plot. An MIT -IA to 3000 psi passed on 05/13/07 indicating competent tubing and production casing. Recent Well Events: · 02/01/07: PPPOT-T Passed to 5000 psi · 03/18/07: DGLV's · 03/26/07: MITIA Passed to 4000 psi · 05/13/07: AOGCC MITIA Passed to 3000 psi Barrier and Hazard Evaluation The primary and secondary barrier systems consist of tubing and production casings and associated hardware. A pressure test of the inner annulus passed to 3000 psi, demonstrating competent primary and secondary barrier systems. Proposed Operating and Monitoring Plan 1. Allow water injection only. 2. Record wellhead pressures and injection rate daily. 3. Submit a report monthly of well pressures and injection rates to the AOGCC. 4. Perform a 4-year MIT -fA to 1.2 times maximum anticipated injection pressure. 5. The well will be shut-in and the AOGCC notified if there is any change in the wells mechanical condition. - , TREE= WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = 7-1/16" erN FMC LEO' 64.10' 35.60' 620' 98 @ 15164' 11624' 8800' SS 8-111 S NOTES: ***70 0 ANGLE @ 11635 & HORIZONTAL @ 15358"*** 26' -17" x 5-1/2" XO, 10=4.892" I 2219' H5-1/2" HESX NIP,ID=4.562 -15-1/2" X 4-112" XO, 10= 3.938'1 GAS LIFT MANDRELS ST MD TVD DEV 1YÆ VLV LATCH PORT 2 5414 3702 58 KGB2 *DMY BK 0 1 9527 5815 68 KGB2 *DMY BK 0 *NOTE 4-1/2" GLM IN 5-1/2" TBG "STATIONs 2 & 1 = DGLVs W/EXTENDED PACKING 5431' -14-1/2" x 5-112" XO, ID = 3.938"1 DATE 03/18/07 03/18/07 110-3/4" CSG, 45.5#, L-80 BTC, ID = 9.95" Minimum ID = 3.813" @ 11320 4-1/2" HES XN NIPPLE 4-1/2" TBG, 12.6#, L-80, TC-II, .0152 bpf, 10 = 3.958" 5-1/2" TBG, 17#, L-80, TC-II, 9516' .0232 bpf, ID = 3.958" 4-1/2" TBG, 12.6#, L-80, TC-II, 9544' .0152 bpf, ID = 3.958" 5-1/2" TBG, 17#, L-80, TC-II, -1 11223' I .0232 bpf, ID = 3.958" 4-1/2" TBG, 12.6#, L-80, TC-II, .0152 bpf, ID = 3.958" ÆRFORA TION SUMMARY REF LOG: SLB MWD 10/12/04 ANGLEATTOPÆRF: 68° @ 11550 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 11550 - 11565 0 10/18/05 3-3/8" 6 13200 - 13215 0 10/18/05 3-3/8" 6 16180 - 16250 0 07/04/05 3-3/8" 6 16330 - 16450 0 07/04/05 3-3/8" 6 16550 - 16590 0 07/04/05 3-3/8" 6 17200 - 17300 0 07/04/05 3-3/8" 6 17520 - 17950 0 07/04/05 WHIPSTOCK (05/31/05) I I EZSV (05/31/05) I 7-5/8" CSG, 29.7#, L-80, BTC-M, .0459 bpf, ID = 6.875" DATE 07/08/05 10/19/05 06/25/06 01/10/07 03/18/07 REV BY COrvYIIIENTS N7ES ORIGINAL COM PLETION JGIINPJC ÆRFORA TIONS DTRlPJC GL V C/O JY I PJC DRLG DRAFT CORRECTIONS SWc/PAG GLV C/O DATE REV BY 9516' -15-1/2" X 4-1/2 XO,ID=3.938"1 9544' -f4-1I2" X 5-1/2" XO, ID = 3.938"1 11223' -15-1/2" X 4-1/2" XO, ID = 3.938" I 11320' -14-1/2" HES X NIP, 10 = 3.813" I 11341' -17-5/8" X 4-1/2" BKR S-3 PKR. ID = 3.875" 11364' -14-1/2"HESXNIP,ID=3.813" I -14-1/2" HES X NIP, ID = 3.813" I -17-5/8" X 5-1/2" BKR HRDZXP LTP, ID= 5.580' -14-1/2" WLEG, 10 = 3.958" I -17-5/8" X 5-1/2" BKR FLEX LOCK HGR. 10 = 4.830" MILLOUTWINDOW(S-111) 11535'-11545' -fRA TAG (MIDDLE OF PUP JOINT) -1 RA TAG (MIDDLE OF pup JOM) 4-112" LNR, 12.6#, L-80, HYD521, .0152 bpf, ID = 3.958" COMrltENTS PRUDHOE BAY UNIT WB-L: S-111 PERMIT No: "2050510 API No: 50-029-23257-00 SEC 35, T11 N, R15E, 2352.57' FEL & 2465.03' FNL BP Exploration (Alaska) .to ~ . A .to 06/29/07 06/28107 11 Pressure Rate ,. 10,000 Injection Rate, MCFPD Volume MCFPD) 7,794 8,980 (psi) 0> ¡;; <:>. ri" ~ 8-111 TIO Plo! OA 4/27/07 1,11, Press (psi) 0,11, Press 1,875 ,875 8,553 06/21/07 1,875 900 1 900 340 06/19/07 780 8,835 06/16/07 9,365 06/16/07 9,026 800 1/07 WHP Date 7118/07 360 40 8,165 360 02/21/07 02120/07 02/19/07 380 02/19/07 6,764 440 02/18/07 7,350 380 02/1 02/16/07 02/15/07 8,083 7,699 7,633 02/11/07 02/10/07 380 11 Pressure \IS. Rate " Ii. t " ". ¡¡¡¡I¡J ~ 41. ,II. A ¿À AI. ¿ A A Date Pressure (psi) 02/28/07 02/27/07 7,842 - TIOPlot Tbg Press 1.11. Press (psi) WHP Date 4t;./p BP Exploration (Alaska), .1' 900 East Benson Boulevard Post Office Box 196612 Anchorage, Alaska 99519-6612 Telephone (907) 564 581 . ObP Jane Williamson Winton Aubert Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 RECEIVEr) NI]V J G 2006 Alaska Oil & Gas Cons Cq<r,"", . Þ. .."l" . "" iJml!gkm ."V ...., iOraa&:! u. ,~4¥ November 13, 2006 We respectfully request administrative approval for modification of Area Injection Orders 3 & 22 to allow multiple completions of water injection wells with the Aurora and Prudhoe Western Operating Area Oil pools. Well S-3IA, an injector completed within the Sag river fonnation of the Prudhoe pool is proposed to be re-completed to inject in the Aurora pool and we plan to combine injection into the two pools as detailed below. Prior to initiation of co·mingled injection, mechanical isolation between pools will be demonstrated by a cement evaluation log and approved by the Commission. Results of logs, surveys or down-hole monitoring used for detennining the allocation of water injection between pools, if applicable, will be supplied in the annual reservoir surveillance report. The expected injection requirements will be 2-8 MBWIPD for Aurora and 1-3 MBWIPD for the Sag, depending on future off-take. Hydraulic modeling indicates that adequate bottom-hole pressure can be supplied to meet required injection rates into both reservoirs with either boosted produced water or Prince Creek water. Because injectivity is dependent on off-take, the S-31A completion will allow for the ability to limit rates to each or both reservoirs if necessary. Please call Jim Young 564-5754 if you have any questions. Sincerely, Ftd:: !?~ GPB WEST Manager CC: Ellen Stevens (BPXA) Dan Kruse (CP AI) G. Frosthoff(Chevron-Texaco) Sonny Rix (Exxon-Mobil) P. Winslow (Forest Oil) #5 BP Exploration (Alaska), InL 900 East Benson Boulevard Post Office Box 196612 Anchorage, Alaska 99519-6612 Telephone (907) 564 581 ) ObP October 19,2005 Jane Williamson Robert P. Crandall Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 RE: Proposed Aurora EOR expansion As per CO 457B, rule 7, expansion of miscible gas injection outside of the North of Crest and West Blocks must be administratively approved by the Commission prior to long- term injection. Your approval is requested for long-term EOR expansion into the remaining depletion areas within the Aurora field. The following infonnation is provided to supplement the application for an Area Injection Order for the AOP, dated June 15, 2001. Included are updated EOR results and observations from the pilot completed on injection wells S-11 0 and S-112. Please call Jim Young 564-5754 if you have any questions. Sincerely, ~~ Gil Beuhler GPB Satellites Manager Attachments CC: JeffFarr (ExxonMobil) Don Ince (CP AI) Initial MI slugs have been placed into wells S-101i, S-104i, S-107i, S-l 14Ai (ongoing) and smaller MI slugs into S-llOi·and 8-112i for the EOR pilot. 8hown below is a summary of results from these wells as of October 2005. * EOR volumes are estimated from decline curve analysis & may include waterflood acceleration benefits. Table 1 EOR volume summary RMI, BCF Estimated * Producer response (RMIR) L1EOR, mbo 0.5(30%) 200 1.6(50%) 300 In progress .45 (22%) .04 (16%) .04 (16%) Wells 8-10 1 i S-107i 8-l14Ai 8-104i 8-IIOi 8-112i ) EOR Results update MI,BCF (%HCPV) 2 (9%) 3.3 (5%) 0.5 (I %) 2 (7%) 0.093(.4%) 0.17(.5%) 150 S-100,8-102LI 8-100,S-102Ll 95% from 8-100 8-103,105 8-109 8-109, possibly 8-115 10 20-30 In the West block, EOR benefits have been dominated by S-1 00 due its excellent productivity & connectivity to injection. 8-113B was shut-in during MI injection to enhance repressurization of the reservoir, but was placed on production recently to improve conformance. 8-106 appears to be isolated from S-107 and S-1 0 I as no RMI has been measured in the well to date, but S-114A is early in its MI cycle. Figure 1 Pressure Map with overlay of cumulative MIIRMI by well 5993000- 5992000 - 5991000- 5990000- - 5989000- 5988000- - 5987000- 5986000- ..:~¡¡. 5985000- 5984000- 5983000- 5982000- 5981000- 5980000- 5979000- t. G.. 10' C... MMSCf / 8-106 / . / 9Î1ÜJ,/ .. 5978000- \ 606000 60800J 6100X1 612000 614001 2 ) ) Expansion to remaining areas proposed based on WF & pilot EOR performance. In order to increase injection rates and verify long-term feasibility, pilot injection of MI was initiated in wells S-11 Oi and S-112i. In this block, EOR benefits were seen in S-109 as shown below. Crest well 8-115 was thought to be isolated from 8-112; however, traces of RMI have been detected, suggesting that the Crest & Southeast Crest portions of the field are in communication. Producers 8-108 and S-118 were shut-in during MI injection to enhance repressurization of the reservoir, and after the tubing is replaced, these wells will be placed on production to improve confonnance. 2000 Figure 4 8-109 Well test history 1\ -S..112GAS -+-S-1;23H20 I 1800 1600 1400 ! 1200 ~ 1000 · ~ 800 600 } / / \\ ~-1 ß9 -GFR . GOR _RMI -S-11OGAS ''\ 400 200 ~ o <~~ ~ \ ... . 08101/04 09/20/04 11/09/04 12/29104 02/17/05 04108105 05128105 07/17/05 . . 09/05/05 4000 3600 3200 2800 800 400 o 10/25105 Below is a production history for Crest wells S-115, 8-117 and 8-118. 8-118 only produced in May & July 2004 before being 81 for high GOR, similar to 8-1 08. Water injection into S-116i and S-120i has stabilized production in this area, and MI injection is proposed for these areas based on waterflood performance. Figure 5 Crest well Liquid/RMI production and GORNRR 11. ~ 4000 ~ Q) i It 'C 300)- e ........ CL ~ It 200)- ~ Q III . ¡o I- (J) 1000- Q) ã It 'C e 0 Il. ~ Feb 04 ÃI ! õ -6.0 s: (11 () '1 VJ -4.0 ~ i ÃI .. -- - - .. , .. - 2.0 ~ .. J -.. (D '-:;<::- '~~-~.-~ ÃI ..,,01"" ........,-~ ......__. <:: --...-----.,,- m 0.0 ~ ~ - AURCIt lPR1 -- AURCIt GPRRMII - - . . AURCIt GOR1 . . . - AURCR.. VRRRI \ ( .. .. .. ". .,.____1 ¡. .,.-~ ·····--t . ···'-'r'-v~--"'r~"----i'r'-+ Apr04 Dee 04 Feb 05 Jun 05 Apr05 Jill 04 Aug04 Oct 04 w " 8.0 Õ Aug 05 4 ) ) A pending work-over of 8-31Ai to will provide an addition Kuparuk injection point in this area and will enhance pressure support to both 8-118 and 8-108. Due to low reservoir permeability and water injection pressures, ann increase of injection rates was one of the goals of starting MI early at Aurora. This has been demonstrated in all the wells thus far, with injection improvement of 30-100% on MI, and continued improvement after going back to water injection. Shown below is a comparison of reservoir injection rates before, during, and after MI for pilot wells 8-110i and 8-112i. 2000 - s:-110_.....UR..... GIR, Figure 6 8-110 MI (green) and reservoir barrel equivalent (blue) rates s:-"O_.....UR..... TIR' I I 1800- ~ 1S00- Q S! ~ 1400- 1ã 0=: ~ 1200- 1Ii!i 15 t- ~ 1 000- Q La.. M 800- :::!!!: (I) ~ soo- ~ (;) (3 400- :f; ¡ I ..! ~,: 't:. l! ì f ~', f . . '(>J r~ I I 200- o 1 Mar 04 ,I I '1 Jul04 "I Nav 04 !' I· , I I· ~ ~, -r~ I r" J . ! i ::\Jtt , Mar 05 , I ~ "-\. , Jul05 The MI rate improvement in 8-112i in September 2005 was due to increased gas pressure supply made available by line repairs completed at Prudhoe Central Gas Facility. All Aurora MI injectors will benefit ftom this. 5000 - c·na".AUAAQlR1 Figure 7 8-112 MI (green) and reservoir barrel equivalent (blue) rates 4000- ;;: Q ~ i 3000- .!' ~ ?< Q ¡ ! 2000- "I!' ~ ''':r Jfv~ '\þ~1 o , . . ,! Jen Feb Apr M... May -¡ .·'....AURATIA. l j \I ~ I I ~ ~ j \ ~ ~ ~ I '! ~,~ Jqf1vv ( . ~ Jun J.... Äug Sap 5 #4 ) ) ,.:(--.....:.,.lÙ.l'..: ":"".Îr.·¡,~.·.\ ~~,I :'i,I..,.r ,<\ :J ¡ .,) \ . ,[ :11 ~ ',,)., ··'U·. .iW;,: :,'\ :j)J,: .,: ),/ I~\ '\ :u.' :1.1.... ~,·;..;¡:U' ~ ....-. ' ".~", rn\ .1,...., :.1 :. 1. '¡.j ¡'I ,~I '- . :/ Jj.¡ .;-oJ : 'J" I \~." U r1 (r\ (?Q 1: J iJ, \\,'>\. L~ Lr-cj C~) ¡r-;:\ ,i FI" '.\ '¡}j \ ,iliJ FRANK H. MURKOWSKI, GOVERNOR A.ItA.~HA. OIL AlQ) GAS CONSERVATION COMMISSION 333 w. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 September 27, 2004 Proposals to Amend Underground Injection Orders to Incorporate Consistent Language Addressing the Mechanical Integrity of Wells The Alaska Oil and Gas Conservation Commission ("Commission"), on its own motion, proposes to amend the rules addressing mechanical integrity of wells in all existing area injection orders, storage injection orders, enhanced recovery injection orders, and disposal injection orders. There are numerous different versions of wording used for each of the rules that create confusion and inconsistent implementation of well integrity requirements for injection wells when pressure communication or leakage is indicated. In several injection orders, there are no rules addressing requirements for notification and well disposition when a well integrity failure is identified. Wording used for the administrative approval rule in injection orders is similarly inconsistent. The Commission proposes these three rules as replacements in all injection orders: Demonstration of Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before injection begins, at least once every four years thereafter (except at least once every two years in the case of a slurry injection well), and before returning a well to service following a workover affecting mechanical integrity. Unless an alternate means is approved by the Commission, mechanical integrity must be demonstrated by a tubing/casing annulus pressure test using a surface pressure of 1500 psi or 0.25 psi/ft multiplied by the vertical depth of the packer, whichever is greater, that shows stabilizing pressure and does not change more than 10 percent during a 30 minute period. The Commission must be notified at least 24 hours in advance to enable a representative to witness mechanical integrity tests. Well Integrity Failure and Confinement Whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, log, or other evidence, the operator shall immediately notify the Commission and submit a plan of corrective action on a Form 10-403 for Commission approval. The operator shall immediately shut in the well if continued operation would be unsafe or would threaten contamination of freshwater, or if so directed by the Commission. A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating well integrity failure or lack of injection zone isolation. Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. The following table identifies the specific rules affected by the rewrite. Injection Order "Demonstration of .Mechanical Integrity" Affected Rules "Well Integrity Failure and Confinement" " Administrative Action" Area Injection Orders AIO 1 - Duck Island Unit AIO 2B - Kuparuk River Unit; Kuparuk River, Tabasco, Ugnu, West Sak Fields AIO 3 - Prudhoe Bay Unit; Western Operating Area AIO 4C - Prudhoe Bay Unit; Eastern Operating Area AIO 5 - Trading Bay Unit; McArthur River Field AIO 6 - Granite Point Field; Northern Portion AIO 7 - Middle Ground Shoal; Northern Portion AIO 8 - Middle Ground Shoal; Southern Portion AIO 9 - Middle Ground Shoal; Central Portion AIO lOB - Milne Point Unit; Schrader Bluff, Sag River, Kuparuk River Pools AIO 11 - Granite Point Field; Southern Portion AIO 12 - Trading Bay Field; Southern Portion AIO I3A - Swanson River Unit AIO 14A - Prudhoe Bay Unit; Niakuk Oil Pool AIO 15 - West McArthur 6 7 9 6 7 9 6 7 9 6 7 9 6 6 9 6 7 9 6 7 9 6 7 9 6 7 9 4 5 8 5 6 8 5 6 8 6 7 9 4 5 8 5 6 9 ) ) Affected Rules "Demonstration of "Well Integrity "Administrati ve Injection Order Mechanical Failure and Action" Integrity" Confinement" River Unit Ala 16 - Kuparuk River 6 7 10 Unit; Tarn Oil Pool 6 8 Ala 17 - Badami Unit 5 AIO 18A - Colville River 6 7 11 Unit; Alpine Oil Pool AIO 19 - Duck Island Unit; 5 6 9 Eider Oil Pool AIO 20 - Prudhoe Bay Unit; 5 6 9 Midnight Sun Oil Pool AIO 21 - Kuparuk River 4 No rule 6 Unit; Meltwater Oil Pool Ala 22C - Prudhoe Bay 5 No rule 8 Unit; Aurora Oil Pool 6 9 AIO 23 - Northstar Unit 5 Ala 24·- Prudhoe Bay Unit; 5 No rule 9 Borealis Oil Pool Ala 25 - Prudhoe Bay Unit; 6 8 13 Polaris Oil Pool Ala 26 - Prudhoe Bay Unit; 6 No rule 13 Orion Oil Pool Disposal Injection Orders DIO 1 - Kenai Unit; KU No rule No rule No rule WD-l 010 2 - Kenai Unit; KU 14- No rule No rule No rule 4 010 3 - Beluga River Gas No rule No rule N ò rule Field; BR WD-l oro 4 - Beaver Creek Unit; No rule No rule No rule BC-2 DIO 5 - Barrow Gas Field; No rule No rule No rule South Barrow #5 010 6 - Lewis River Gas No rule No rule 3 Field; WD-l DIO 7 - West McArthur 2 3 5 River Unit; Wl\1RU D-l DIO 8 - Beaver Creek Unit; 2 3 5 BC-3 0109 - Kenai Unit; KU 11- 2 3 4 17 DIO 10 - Granite Point 2 3 5 Field; GP 44-11 Injection Order "Demonstration of Mechanical Integrity" 2 010 11 - Kenai Unit;KU 24-7 010 12 - Badami Unit; WD- 1, WD- 2 010 13 - North Trading Bay Unit; S-4 010 14 - Houston Gas Field; Well #3 oro 15 - North Trading Bay Unit; S-5 010 16 - West McArthur River Unit; WMRU 40 010 17 - North Cook Inlet Unit; NCro A-I2 DIO 19 - Granite Point Field; W. Granite Point State 17587 #3 01020 - Pioneer Unit; Well 1702-15DA WOW DIO 21 - Flaxman Island; Alaska State A - 2 DIO 22 - Redoubt Unit; RU 01 010 23 - Ivan River Unit; IRU 14-31 010 24 - Nicolai Creek Unit; NCU #5 01025 - Sterling Unit; SU 43-9 010 26 -Kustatan Field; KFI Storage Injection Orders SIO 1 - Prudhoe Bay Unit, Point McIntyre Field #6 SIO 2A- Swanson River Unit; KGSF #1 SIO 3 - Swanson River Unit; KGSF #2 Enhanced Recovery Injection Orders ErO 1 - Prudhoe Bay Unit; Prudhoe Bay Field, Schrader Bluff Formation Well V-I05 2 2 2 2 2 2 3 3 3 3 No rule " ..) 3 No rule 2 2 No rule Affected Rules "Well Integrity Failure and Confinement" "Administrative Action" 3 4 3 5 3 6 3 5 3 Rule not numbered 3 5 3 6 4 6 4 6 4 7 No rule 6 No rule 6 Order expired 4 7 4 7 No rule No rule No rule 6 N o rule 7 No rule 8 Injection Order EIO 2 - Redoubt Unit; RU-6 "Demonstration of Mechanical Integrity" 5 ) Affected Rules "Well Integrity Failure and Confinement" 8 "Administrati ve Action" 9 I 02-902 (Rev. 3/94) Publisher/Original Copies: Department Fiscal, Department, Receiving AO.FRM STATE OF ALASKA ADVERTISING ORDER SEE BOTTOM FOR'.INVOICE ADDRESS NOTICE TO PUBLISHER ADVERTISING ORDER NO. INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTIFIED AO-02.S14016 AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COpy OF ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE F AOGCC 333 West th Avenue, Suite 100 Au1chorage,AJ( 99501 907-793-1221 AGENCY CONTACT DATE OF A.O. R o M Joòy Colomhie September 77,7004 PHONE PC\J (907) 793 -] 7) ] DATES ADVERTlSEME~T REQUIRED: T o Journal of Commerce 301 Arctic Slope Ave #350 Anchorage, AK 99518 October 3, 2004 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: United states of America AFFIDAVIT OF PUBLICATION 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 2004, and thereafter for _ consecutive days, the last publication appearing on the _ day of , 2004, 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 2004, Notary public for state of My commission expires 9/29/2004 1: 10 PM 10f2 ) ') Public. Notices Public Notices <scott.cranswick@I11f.(ls.gov>, Brad McKim <rnckimbs@BP ..com> ~'Ll.~~s~.fiJ:lª .th.e ...,$f:.t~çhed . Nqtice ... aridÁt:tåç~tnep.t ·.....fdr.t~~~rt"?f>C>$~c1 ~meriàment of µnd~:r-ground ··injection orderE) andthe·1?ublic Notice~appyValley #.10. i.T6ciYColonlbie ,.."...."". ,,,..,,,.,,,:,..,,,.,,,..,,. ...".'-.."'."'."...""'.""".".'''''...........:.:.........'..'.......'.'.".......'............'....'.................'.'...,.'.'...........':".............,.....'.........''''''..:.. " .' .".'.'.'.'.' .'.' " : ............ .... ....... ... .,)Co~tent~Type: applicâtion/msworcI !Mechanlcal·lntegrlty:prop()~al..doc.: ....... ...... '...'....,.... ........... ,.....'..". ., ..........,.... .., ..... .. .......'..,..,....,....'.,.........'..,'....'.,. .,.... ~...'..........., .. ....·..6,.....·.,...A...... ..,' 'Content~Enc.odmg:uase <Of ,'" ,'-'~" ..-.",.."....,'..".--.,-.-.-...--.- ~' ,.. .-.,. ~,':"'-...". '-'.-.-. f:, ' ' ','''', ",'. "", :,:< :,.;" " ::' .:' , ::', ": . ,:,::,::',:::',~:)'::,:::":', . ,;-:""::;":" ..:::,.,'....,...::',.::,: .,...~,.,' '::',' ....,.:.":::',..,",.'.: '::..::"":',;':"", :'",':::';::".': :';':'.":,'.H'::,:".:'.' , ~..i.....·..···....···....·.........··..··.··....·· ..... ... ...... .....<. .>. ................·¡Cøßteptb17yp~: applicatiqn/msWø:çâ Mecharllcallntegrlty øfWellsNotIC~.doCi· ...... ...... .. ......... ....·r.......··..·.·.·. ..... ···Þ·· ... .6...4. !Content-Ellcø<!lng: ... ase : Content-'I'ype: app'licatiøwmswortt ßappyVaUeyl0_HearingNotice.doc .......... . : . çODtent"7E..ço(J.itîg:lJas~64 . . '''''.'"'' '..~'..~,~'" ",. ,_._~. .......... ~'.. ._~ ..~'.. '...~......_.- .......-,. ... ..-...,'~" ..~...,,~ . '.,. '. .-.. -~.~...., '. . . ."". _.,,~'. ..~".. ...,~-,.,.~..,..~.,.:. .~..... .-'.....~ -. ..,.",.,' .--. .~.......-"'..,.,~.__...._~..."..._''''',..-._-,. ~-"''''.'"_.'.'-_._. .__...... , . ..'," .~.." .....~_........¥ 20f2 9/29/2004 1: 10 PM Public;; Notice ') ) Subject: Public Notice From: lody Colombie <jody _ colombie@admin.state.ak.us> ~~te:..VY e~, 2?S:~g?o.o.~...~...~.,:.55:26 -080.0. ~'~~·l~g~l@*l~skiljp:LÏJ;I1lal~*)D) . . Please publish the attached Notice on October 3, 2004. Thank you. Jody Colombie · Mechanical Integrity of Wells Content-Type: applicationlmsword Content-Encoding: base64 Content-Type: applicationlmsword Ad Order form.doc Content-Encoding: base64 1 of 1 9/29/2004 1: 10 PM 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 /'r¡t:tl/¿d ItJ/(I1~ David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 Kelly Valadez Tesoro Refining and Marketing Co. Supply & Distribution 300 Concord Plaza Drive San Antonio, TX 78216 Robert Gravely 7681 South Kit Carson Drive Littleton, CO 80122 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 Jerry Hodgden Hodgden Oil Com pany 408 18th Street Golden, CO 80401-2433 Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 John Levorsen 200 North 3rd Street, #1 202 Boise, 10 83702 Kay Munger Munger Oil Information Service, Inc PO Box 45738 Los Angeles, CA 90045-0738 Samuel Van Vactor Economic Insight Inc. 3004 SW First Ave. Portland, OR 97201 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle, WA 98119-3960 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Schlumberger Drilling and Measurements 2525 Gambell Street #400 Anchorage, AK 99503 David Cusato 200 West 34th PMB 411 Anchorage, AK 99503 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage. AK 99503 Ciri Land Department PO Box 93330 Anchorage, AK 99503 Jill Schneíder 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 Darwin Waldsmith PO Box 39309 Ninilchick, AK 99639 James Gibbs PO Box 1597 Soldotna, AK 99669 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 Penny Vadla 399 West Riverview Avenue Soldotna, AK 99669-7714 Richard Wagner PO Box 60868 Fairbanks, AK 99706 Cliff Burglin PO Box 70131 Fairbanks, AK 99707 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks. AK 99711 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 North Slope Borough PO Box 69 Barrow, AK 99723 ) JFwd~'Re: Consistent Wording for InjectiOl ~ers - Well Integrity... ) ~ulJject:.. [Fwd:· Re': ·C9~sistèI1tW örqiq.~för Itlj¢ctiOtl. .Ördet~-Well~t¢gtitY.<R~\ri$~cl)J F~om: John N0l111an<jo~n0I'IIlan(@atlmiIi~state'*'11~> Uate: Fri, 01 Oct 200411:09:26;,.0800, j'~·;J9ªYJçgIºÌÌ1þi~<j9~ýbÇQl~ffi~j~@~g~jft.::~t~i~.~~µš~ more -------- Original Message -------- Subject:Re: Consistent Wording for Injection Orders - Well Integrity (Revised) Date:Wed, 25 Aug 2004 16:49:40 -0800 From:Rob Mintz <robert lTIintz@law.state.ak.us> To:.i im regg@admin.state.ak. us CC:dan seamount@admin.state.ak.us, john norman@admin.state.ak.us Jim, looks good, but I still think maybe it would be good to include the following sentence or something like it in the well integrity and confinement rule: "The operator shall shut in the well if so directed by the Commission." My thinking is that otherwise, an operator might argue that the Commission can only require the well to be shut in by going through an enforcement action, issuing an order after notice and opportunity for hearing, or meeting the strict requirements for an emergency order under the regulations. The proposed language makes clear that it is a condition of the authorization to inject, that the operator must shut in the well if directed by the Commission after a notification of loss of integrity, etc. »> James Regg <jim regg@admin.state.ak.us> 8/25/2004 3: 15:06 PM »> Rob - Thanks for the review; here's a redraft after considering your comments. I have accepted most of the suggested edits; also attached is response to questions you pose (responses are embedded in the comments, using brackets [JBR - ...] to set apart from your questions). Jim Regg Rob Mintz wrote: Jim, I have some questions about the draft language, which are shown as comments on the first document attached. Based on my current guesses about what the answers will be to my questions, I also have some suggested edits, which are shown as redlines on the second document attached. »> James Regg <jim regg~admin.state.ak.us> 8/17/20044:33:52 PM »> Please delete previous version (email sent 8/9/04); I found another inconsistency in the injection orders regarding well integrity that I have integrated into the proposed fix. Attached is a proposal for consistent language in our injection orders addressing 3 rules related to well integrity: - "Demonstration of Tubing/Casing Annulus Mechanical Integrity" - "Well Integrity Failure" - "Administrative Actions". This proposal includes input from all Sr. staff (except Jack). If you agree with the approach, I'll work with Jody to prepare the public notice. Main points - Demonstration of Tubing/Casing Annulus Mechanical Integrity - standardizes the wording used for mechanical integrity demonstrations, and establishes abililty to grant alternate methods (e.g., temp survey, logging, pressure monitoring in lieu of pressure testing 10f2 10/2/2004 4:07 PM [Fwd: Re: Consistent Wording for Injection ( 1"S -Well Integrity ... - specific to AIO 2C for Kuparuk, there is wording that is more appropriately included in Well Integrity Failure (i.e., more frequent MITs when communication demonstrated) - establishes more frequent MIT schedule for slurry injection wells (every 2 yrs) which is consistent with our current practice (but not addressed in regulations) Well Integrity Failure - retitles to "Well Integrity Failure and Confinement"; inserted language regarding injection zone integrity (see DIO 25 and 26) - consistent language regardless of type of injection (disposal, EOR, storage); - eliminates requirement for immediate shut in and secure; allows continued injection until Commission requires shut in if there is no threat to freshwater; - eliminates delay in notifying Commission after detect leakage or communication ("i.e., "immediately notify"); - removes language about notifying "other state and federal" agencies; - requires submittal of corrective action plan via 10-403; - requires monthly report of daily injection rate and pressures (tubing and all casing annuli); this is a requirement we currently impose when notified of leak or pressure communication; - notice and action not restricted to leaks above casing shoe as stated in several DIOs Administrative Actions - adopts" Administrative Actions" title (earlier rules used" Administrative Relief'); - consistent language regardless of type of injection (disposal, EOR, storage); - uses "administratively waive or amend" in lieu of terms like "revise''; "reissue", etc.; - adds geoscience to "sound engineering principles"; - language is more generic regarding fluid movement out of zone; existing versions mention varying combinations of protecting "freshwater", "aquifers", "USDWs"; "risk off1uid movement"; "fluid escape from disposal zone" Jim Regg John K. Norman <John Norman@;admin.state.us> Commissioner Alaska Oil & Gas Conservation Commission 20f2 10/2/20044:07 PM ..[Fwd:'Re: Consistent Wording for Injectior )lers - Well Integrity... ) S~bject: [Fwd: . Re: . ConsistentW ordingfor Irijection()rder$ -Wél1Ihtègrity (R.evis~d)] ~~ºrn: John NOffilan <jQhn~nonnan($admiIl.state.ak.l1s> ~~~e:F~i,ql()?t ~99,111 :08:55-0~qº, ... ...... ... .... ... ...... 'f..~#····1P(ty··.·.J.<q.·gIQmb~~i...fj9PYLßOlô#l{6i:ê@.~~iÍi·~.~.t~~~~·~.µs>··· please print all and put in file for me to review just prior to hearing on these amendments. thanx -------- Original Message -------- Subject:Re: Consistent Wording for Injection Orders - Well Integrity (Revised) Date:Thu, 19 Aug 2004 15:46:31 -0800 From:Rob Mintz <robert mintz(ã?law.state.ak.us> To:dan seamount(ã?admin.state.ak.us, jim regg(ã?admin.state.ak.us, john norman(ã?admin.state.ak.us Jim, I have some questions about the draft language, which are shown as comments on the first document attached. Based on my current guesses about what the answers will be to my questions, I also have some suggested edits, which are shown as redlines on the second document attached. »> James Regg <jim regg@¿admill.state.ak.us> 8/17/20044:33:52 PM »> Please delete previous version (email sent 8/9/04); I found another inconsistency in the injection orders regarding well integrity that I have integrated into the proposed fix. Attached is a proposal for consistent language in our injection orders addressing 3 rules related to well integrity: - "Demonstration of Tubing/Casing Annulus Mechanical Integrity" - "Well Integrity Failure" - "Administrative Actions". This proposal includes input from all Sr. staff (except Jack). If you agree with the approach, I'll work with Jody to prepare the public notice. Main points ~ Demonstration of Tubing/Casing Annulus Mechanical Integrity - standardizes the wording used for mechanical integrity demonstrations, and establishes abililty to grant alternate methods (e.g., temp survey, logging, pressure monitoring in lieu of pressure testing - specific to AIO 2C for Kuparuk, there is wording that is more appropriately included in Well Integrity Failure (i.e., more frequent MITs when communication demonstrated) - establishes more frequent MIT schedule for slurry injection wells (every 2 yrs) which is consistent with our current practice (but not addressed in regulations) Well Integrity Failure - retitles to "Well Integrity Failure and Confinement"; inserted language regarding injection zone integrity (see DIG 25 and 26) - consistent language regardless of type of injection (disposal, EOR, storage); - eliminates requirement for immediate shut in and secure; allows continued injection until Commission requires shut in if there is no threat to freshwater; - eliminates delay in notifying Commission after detect leakage or communication ("i.e., "immediately notify"); - removes language about notifying "other state and federal" agencies; - requires submittal of corrective action plan via 10-403; - requires monthly report of daily injection rate and pressures (tubing and all casing annuli); this is a requirement we currently impose when notified of leak or pressure communication; - notice and action not restricted to leaks above casing shoe as stated in several DIOs Administrative Actions 1 of2 10/2/20044:07 PM [Fwd: Re: Consistent Wording for Injection C s - Well Integrity... - adopts "Administrative Actions" title (earlier rules used "Administrative Relier'); - consistent language regardless of type of injection (disposal, EOR, storage); - uses "administratively waive or amend" in lieu oftenns like "revise", "reissue", etc.; - adds geoscience to "sound engineering principles"; - language is more generic regarding fluid movement out of zone; existing versions mention varying combinations of protecting "freshwater", "aquifers", "USDWs"; "risk of fluid movement"; "fluid escape from disposal zone" Jim Regg John K. Noonan <John Norman@admin.state.us> · Commissioner Alaska Oil & Gas Conservation Commission Content-Type: application/msword Injection Order language - questions.doc ' Content-Encoding: base64 Content-Type: applicationlmsword Injection Orders language edits. doc b 6 Content-Encoding: ase 4 20f2 10/2/2004 4:07 PM ') Standardized Language for Injection Orders Date: August 17, 2004 Author: Jim Regg Demonstration ofTubing/Casin~ Annulus Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before injection begins, after a workover affecting mechanical integrity, and at least once every 4 years while actively injecting. For slurry injection wells, the tubing/casing annulus must be tested for mechanical integrity every 2 years. The MIT surface pressure must be 1500 psi or 0.25 psi/ft multiplied by the vertical depth, whichever is greater, must show stabilizing pressure and may not change more than 10% during a 30 minute period. Any alternate means of demonstrating mechanical integrity must be approved by the Commission. The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests. Well Integrity Failure and Confinement The tubing, casing and packer of an injection well must demonstrate integrity during operation. The operator must immediately notify the Commission and submit a plan of corrective action on FOnTI 10-403 for Commission approval whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, or log. If there is no threat to freshwater, injection may continue until the Commission requires the well to be shut in or secured. A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating pressure communication or leakage. Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. Standardized Language for Injection Orders Date: August 17, 2004 Author: Jim Regg Demonstration of Tubing/Casing Annulus Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before injection begins, at least once e'very four years thereafter (except at least once every two years in the case of a slurry injection well), and before returnin,g a \veIl to service follo\vin.gafte.¡: a workover affecting mechanical integrity, and at leaSt once every (1 years \vhile actively injecting. .For slurry injection \-,>'ells, the tubing/casing annulus l11USt b~-sfèd for mechanical integrity every 2 years. Unless an alternate 11leanS is apprc)"ved by the COlTIDlission. lTIechanical integrity rnust be demonstrated by a tubing pressure test using a +fl€. Ml+-surface pressure of must be 1500 psi or 0.25 psi/ft multiplied by the vertical depth, whichever is greater, that fB-H5É-show3. stabilizing pressure that does::md ll1ay not change more than 10%- percent during a 30 minute period. -Aflÿ alten1ate nleans of demonstrating Inechanical integrity rrlu~~t be approved by the COlnnlission. The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests. Well Integrity Failure and Confinement Except as othenvise provided in this rule, =Hhe tubing, casing and packer of an injection well must demorrst.::ate Inaintain integrity during operation. \Vhenever any pressure con1ffiunication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, log, or other evidence, t+he operator ffH:±St-shall immediately notify the Commission and submit a plan of corrective action on a Form 10-403 for Commission approval.:. \\rhenever any pressure conl1nunication~ 1~J.kage or lack of injection zone isolation is indicated by injection ratc. operating pressure observation, test, survey, or log. The operator shall shut in the wel! if so directed bv the COlnn1ission. The operator shall shut in the \-veU \vithout awaitin,g a response from the ComlnissÎol1 if continued operation \.vould be unsafe or would threaten contamination of fresh\.vaterIf there is no threat to freshwater, injection lnay continue until the C01TI1TIission requires the \vell to be shut in or secured. Until corrective action is successfully cornpleted, Aª monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating pressure communication or leakage. Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. .[Fwd:. Re: [Fwd: AOGCC Proposed WI La. )ge for Injectors]] ) $tJ.~~.ect: [Fwd: Re: [Fwd: AOGCCProposed WI Language for Injectors]] ~rQ:m:Winton.Aube~ <~inton~aubert@admin.state.ak.us> l)~'~~:'fÞ:,3~···A~~~8~499:!~:.?f~O~gq,.,.......· ......... ......... .......... ........,. ......................................... )}~·;J()gyJ..<l1~:J.9~~~~~9~YJlçºìcJìn~,~~@~ª~Ì1;l;~~~t~:~~~$~ This is part of the record for the Nov. 4 hearing. WGA -------- Original Message -------- Subject: Re: [Fwd: AOGCC Proposed WI Language for Injectors] Date: Thu, 28 Oct 2004 09:41:55 -0800 From: James Regg <jim regg@admin.state.ak.us> Organization: State of Alaska To: Winton Aubert <winton aubert@admin.state.ak.us> References: <41812422.8080604@admin.state.ak.us> These should be provided to Jody as part of public review record Jim Winton Aubert wrote: FYI. -------- Original Message -------- AOGCC Proposed WI Language for Tue, 19 Oct 2004 13:49:33 -0800 Engel, Harry R <EngeIHR@BP.com> winton aubert@admin.state.ak.us Injectors Subject: Date: From: To: Winton... Here are the comments we discussed. Harry *From: * NSU, ADW Well Integrity Engineer *Sent: * Friday, October 15, 2004 10:43 PM *To: * Rossberg, R Steven; Engel, Harry R¡ Cismoski, Doug A¡ NSU, ADW Well Operations Supervisor *Cc: * Mielke, Robert L.¡ Reeves, Donald F¡ Dube, Anna T¡ NSU, ADW Well Integrity Engineer *Subject: * AOGCC Proposed WI Language for Injectors Hi Guys. John McMullen sent this to us, it's an order proposed by the AOGCC to replace the well integrity related language in the current Area Injection Orders. Listed below are comments, not sure who is coordinating getting these in front of Winton/Jim. Overall, looks okay from an Operations perspective. We do have a few comments, but could live with the current proposed language. Note the proposed public hearing date is November 4. The following language does not reflect what the slope AOGCC inspectors are currently requiring us to do: "The mechanical integrity of an injection well must be demonstrated before injection begins, at least once every four years thereafter (except at least once every two years in the case of a slurry injection well), and___* before* ** 1 of 3 10/28/2004 11:09 AM [Fwd: Re: [Fwd: AOGCC Proposed WI Lang for Injectors]] returnj.ng a well to service following a workover affecting mechanical integrity." After a workover, the slope AOGCC inspectors want the well warmed up and on stable injection, then we conduct the AOGCC witnessed MITIA. This language requires the AOGCC witnessed MITIA before starting injection, which we are doing on the rig after the tubing is run. Just trying to keep language consistent with the field practice. If "after" was substituted for "before", it would reflect current AOGCC practices. It would be helpful if the following language required reporting by the "next working day" rather than "immediately", due to weekends, holidays, etc. We like to confer with the APE and get a plan finalized, this may prevent us from doing all the investigating we like to do before talking with the AOGCC. "Whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, log, or other evidence, the operator shall * immediately* ** notify the Commission" This section could use some help/wordsmithing: "A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating well integrity failure or lack of injection zone isolation." Report content requirements are clear, but it's a little unclear what triggers a well to be included on this monthly report. Is it wells that have been reported to the AOGCC, are currently on-line and are going through the Administrative Action process? A proposed re-write would be: "All active injection wells with well integrity failure or lack of injection zone isolation shall have the following information reported monthly to the Commission: daily tubing and casing annuli pressures, daily injection rates." Requirements for the period between when a well failure is reported and when an administrative action is approved are unclear. This document states "the operator shall immediately notify the Commission and submit a plan of corrective action on a Form 10-403". If we don't plan to do any corrective action, but to pursue an AA, does a 10-403 need to be submitted? The AOGCC has stated they don't consider an AA as "corrective action". Let me know if you have any questions. Joe -----Original Message----- From: Kleppin, Daryl J Sent: Wednesday, September 29, 2004 1:37 PM To: Townsend, Monte A¡ Digert, Scott A¡ Denis, John R (ANC) ¡ Miller, Mike E¡ McMullen, John C Subject: FW: Public Notices FYI -----Original Message----- From: Jody Colombie [ mailto:jody colombie@admin.state.ak.us Sent: Wednesday, September 29, 2004 1:01 PM Subject: Public Notices Please find the attached Notice and Attachment for the proposed amendment of underground injection orders and the Public Notice Happy Valley #10. Jody Colombie «Mechanical Integrity proposal. ZIP» «Mechanical Integrity of Wells Notice.doc» 2 of3 10/28/2004 11:09 AM 11/1 0/2005 3 :39 PM 20f2 J :04578.001 and AI022C.00l PBU Aurora Oil Pool ) 3 ..~ ..- bp --8 -.8 RECEIVED APR 1 3 2004 BP Exploration (Alaska) Inc. 900 East Benson Boulevard PO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 April 12, 2004 Alaska Oil & Gas Cons. Commission Anchorage John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West ¡th Avenue, Suite 100 Anchorage, AK 99501 RE: Supplemental Information - Amendments to Aurora Pool Rules and Area Injection Order CO 457 A and AIO 228 Dear Chair Norman: On March 26, 2004 the Prudhoe Bay Unit (PBU) Working Interest Owners filed with the Alaska Oil & Gas Conservation Commission (Commission) an March 25, 2004 application for Amendments to Conservation Order 457A (as amended by Conservation Order 492) and Area Injection Order 22B, the Aurora Pool Rules and the Area Injection Order for the Aurora reservoir. During subsequent conversations, Commission staff have requested additional information in support of this application. Therefore, please accept the attached April 12, 2004 Supplementary Information to the March 25, 2004 application and incorporate this information into the record. The attachments, referenced data and other supporting information referenced in this Supplementary Information were provided to the Commission in the March 25, 2004 application submittal. Please also maintain the attachments referenced in this Supplemental Information as confidential in accord with AS 31.05.035 and 20 AAC 25.537. Please contact Gary Gustafson at 564-5304 or Frank Paskvan at 564-5749 if you have any questions or need additional information. Sincerely. yours, ~~ Gil Beuhler GPB Waterflood Manager Attachment: April 12, 2004 Supplementary Information to the March 25, 2004 Amendments to the Aurora Pool Rules and Area Injection Order 1 /"-', 8 Cc: Francis Sommer, BPXA Marc Vela, ExxonMobil Dan Kruse, ConocoPhillips G.P. Forsthoff, Chevron Bradley Brice, Forest Oil Jane Williamson, AOGCC Mike Kotowski, DO&G Gil Beuhler, BPXA Frank Paskvan, BPXA Gary Gustafson, BPXA Jim Copen, BPXA Leslie Senden, BPXA Rosy Jacobsen, BPXA Gary Benson, BPXA Steve Luna, ExxonMolbil Jeff Farr, ExxonMobil Mark Menghini, ConocoPhillips Mark Worcester, ConocoPhillips ~ e 2 /"', 8 ------, 8 Aulrora Pool Rules And Area Injection Order SuPIJ~lemental Information April 12, 2004 1/12 .r---, ~ 8 8 I. GEOLOGY.............. ................ ......... ................ ............................ ..... ................... .......... 3 Introduction .... ................................... ....... ...................................... ......... ......... ......... ...... 3 Stratigraphy. """""""""""""'" ............ ......... ................ ........ ....... ............... ..... """"""'" 3 Structure """""""""""""""""""""""""""....................................................................7 Fluid Contacts ................................................................................................................. 8 Pool Limits ..... """"""""""""""""" ..................... ............................. ...... ...... ................. 8 Hydrocarbons in Place............................................................................................ ........ 9 II. PLAN OF DEVELOPMENT AND OPERATIONS.................................................... 10 Wells...... ......... .......................... .... ............... ...... ............ ............. ................... ................ 10 Drill Sites and Pipelines...................... ............ ...................... ................. .............. ......... 10 Support Facilities........................................................................................................... 11 Production..................................................................................................................... 11 Waterflood.....................................................................................................................11 Production Allocation. ..... ......................... ..... ..... ........... ............... ..... .............. ............. 11 Enhanced Recovery Techniques ........ ................. ......... ........................... ..... ....... .......... 11 2/12 ~, ~ 8 8 I. GEOLOGY Introduction The Aurora Pool is located on Alaska's North Slope and was confirmed in 1999 by the drilling of the V - 200 well. The reservoir interval for the Aurora Pool is the Kuparuk River Formation. The Aurora Pool overlies the Prudhoe Bay Unit (PBU) Sadlerochit Group reservoirs in the vicinity of S-Pad. In addition to the V-200 well, the wells listed in Table 1 are recent Kuparuk River Formation penetrations in this area. The North Kuparuk 26-12-12 and Beechey Point State #1 wells, both drilled in 1969, were the first wells to penetrate and test hydrocarbons in the Aurora Pool. A number of PBU Sag River/lvishák development wells also penetrated the overlying Kuparuk River Formation. The S-24Ai well confirmed the presence of oil on the east side of the N-S dividing fault. Four S-Pad and M-Pad well penetrations and Term Well C define the southeastern limit of the Aurora accumulation. As shown in Attachment 4, the top of the Aurora structure crests at about 6450 feet true vertical depth sub-sea (tvdss). The deepest interpreted oil- water contact (OWC) is at 6835 feet (tvdss) in the Beechey Point State # 2 well. Attachment 1 shows the location of the Aurora Participating Area (AP A), including proposed expansion areas. Stratigraphy The productive interval of the Aurora Pool is the Kuparuk River Formation, informally referred to as the "Kuparuk Formation". This formation was deposited during the Early Cretaceous geologic time period, between 120 and 145 million years before present. Attachment 3 shows a portion of the open-hole wire line logs from the V -200 well. This "type log" illustrates the stratigraphic definition of the Aurora Pool. The log is scaled in true vertical depth subsea and also has a measured depth (md) track. In the V -200 well, the top of Kuparuk Formation occurs at 6,693 f1. tvdss (6,858.5 f1. md) and the base occurs at 7,070 f1. tvdss (7,253.5 f1. md). The Kuparuk Formation was deposited as marine shoreface and offshore sediments, and is composed of very fine to medium grained quartz-rich sandstone, which is interbedded with siltstone and mudstone. The sandstones typically have higher resistivity (3-50 ohm-meters) than the surrounding lithologic units. The Kuparuk Formation base is bounded by its contact with the Early 3/12 r-', ~. 8 8 Cretaceous Miluveach Formation and is distinguished by a change in lithology and conventional electric log character. The Miluveach Formation is shale with low resistivity (1 to 3 ohm-meters). The Kuparuk Formation top is defined by its contact with the Early Cretaceous Kalubik Formation or the overlying Early Cretaceous High Radioactive Zone (HRZ) Formation. Both are shales and they are distinguished from the Kuparuk River Formation by a change in lithology and conventional electric log character. The Kalubik Formation is a dark gray shale with a Gamma Ray log signature of 80 to 135 API units, and the HRZ is a black, organic-rich shale with a Gamma Ray log signature typically greater than 150 gamma API units. The Kuparuk Formation in the Aurora Pool is stratigraphically complex, characterized by multiple unconformities, changes in thickness and sedimentary facies, and local diagenetic cementation. As shown on the type log in Attachment 3, the Kuparuk Formation is divided into three stratigraphic intervals, from oldest to youngest, the A, B, and C intervals, with the A and C intervals divided into a number of sub-intervals. An overlying unit, called the D Shale, is locally present in the northern part of the Aurora Pool. Three unconformities affect Kuparuk thickness and stratigraphy. The Lower Cretaceous Unconformity (LCU) at the base of the Kuparuk C interval has erosional topography. It truncates downward and dips to the east where it successively removes the Kuparuk B and Kuparuk A intervaJls. The C-4 Unconformity at the base of the C-4 sub-interval also truncates downward to the east progressively removing the, C-3, C-2, and C-l sub- intervals before merging with the LCU. A younger unconformity, called the Pre-Aptian Unconformity also affe:cts the Aurora Pool. At the Beechey Point wells in the western portion of the Aurora Pool, the Kuparuk Formation is unaffected and the HRZ interval above this unconformity is in contact with the Kalubik Formation. However, this unconformity also truncates downward to the east. At the V-200 well and other S-Pad wells to the east, the Kalubik Formation is eroded, and the HRZ interval is in contact with the Kuparuk C-4B sub-jnterval. This Pre-Aptian Unconformity eventually truncates the Kuparuk C4 locally and merges with the C-4 Unconformity and the Lower Cretaceous Unconformity at the eastern edge of the Aurora area. 4/12 ,,--., ~ 8 8; The Kuparuk A and B units have a distinctly different stratigraphic thickness trend than the Kuparuk C units. ,:V here not truncated, the lower A unit maintains a nearly uniform thickness throughout the Aurora area, suggesting that its deposition pre-dates significant fault movement. In contrast, the thickness, lithofacies, and diagenesis of the C units are variable and have been influenced by differential erosion, and variable diagenetic fluid effects. As a result of these processes, the entire Kuparuk C interval thins south and southeastward and reservoir quality varies laterally and vertically. The lower Kuparuk A interval contains two reservoir quality sub-intervals; the A-4 and A-5 sand units, which are 30 feet and 20 feet thick, respectively. In the V-200 well, these sands are wet. In structurally higher portions of the field to the east, these A sand units are expected to be oil-bearing and productive. The A-5 sand appears to be higher quality reservoir than the A-4 sand. The overlying Kuparuk B interval is dominated by siltstone and sandy mudstone with numerous discontinuous thin sandstone lenses, the thickest of which are up to 3 feet thick. In the V -200 we:ll, wireline logs (Attachment 3) show these thin B interval sands to be wet. The uppermost unit, the Kuparuk C interval, contains the primary reservoir sands of the Aurora Pool. The thickness of this interval is variable and ranges from 0 feet at the eastern truncation to 210 feet at the Beechey Point wells in the northwestern portion of the Aurora Pool. The lithology of this upper unit is variable, consisting of interbedded very fine-grained to mt~dium-grained sandstone with minor amounts of muddy siltstone and sandy-silty mudstone. The Kuparuk C sands are generally very quartzose and moderately sorted. The Kuparuk C interval is intensely bioturbated, contributing to the heterogeneous nature of the Kuparuk C. The Kuparuk C is further subdivided into the following sub-intervals from oldest to youngest: C-l, C-2, C-3 and C-4. The C-l overlies the Lower Cretaceous Unconformity. The Kuparuk C-l and C-4 sub-intervals are coarser grained and contain variable amounts of glauconite and diagenetic siderite. The volume and distribution of siderite and glauconite plays an important role in the reservoir quality of the Kuparuk C-l and C-4 intervals. These minerals are unevenly distributed and may affect a portion of the rock volume in the C-l and C-4 sub-intervals. Due to the increase 5/12 ,...--... "-', 18 8 in structural clay volume, compaction, and cementation, the porosity, permeability, and productivity of these sub-intervals are reduced. The C-l is the coarsest grained sub-interval. It is well-sorted medium-grained sandstone with occasional coarse and very-coarse grains. The C-l has a fairly uniform thickness of 14 feet to 18 feet except to the southeast where it thins due to truncation. The upper portion of the C-l sub-interval gradationally fines upward into the C-2 sub-interval. The C-2 sub-interval is the finest grained unit of the Kuparuk C interval and is considered non-reservOIr. In the western portion of the Aurora Pool, it is dominated by silty mudstone with occasional very fine-grained sand laminations and interbeds. In the eastern part of Aurora, the C-2 lithology transitions to very fine-grained muddy-silty sandstone, indicating a lateral facies change from west to east. The C-2 interval has a somewhat uniform thickness of 28 feet to 36 feet in the western part of the field. The C-2 thins to the southeast and is eventually truncated. The C-3 sub-interval is composed of a coarsening upward serIes of sandstone beds interbedded with silty mudstone. The sandstone beds range from 1 to 2 feet thick, silty, very fine-grain sand at the base up to 10 feet thick, fine-grained sand at the top. The mudstone interbeds display lateral facies variation, similar to the underlying C-2 sub- interval, in that they coarsen eastward to silty very fine-grained sandstone toward the truncation. The C-4 sub-interval continues the coarsening upward trend with fine-grained sandstone at the base to medium-grained sandstone toward the top. Due to the relatively coarse grain size and low volume of clay matrix, the C-4 sub-interval has the highest net to gross and reservoir quality in the Kuparuk Formation in the Aurora Pool area. The C-4 and C- 3 sub-intervals are separated by an intra-formational unconformity that marks the end of the coarsening upward trend. This unconformity, called the C-4 Unconformity, is a disconformity in the western half of the accumulation. However, it truncates downward through the stratigraphic: section in the eastern half of Aurora, where it eventually merges with the Lower Cretaceous Unconformity. The top portion of the C-4 is a fining upward sequence into the overlying Kalubik Formation. C-4 interval thickness varies due to 6/12 /-~ .~ ~4 'ft interaction by unconformities. The interval is thickest at the Beechey Point area where total C-4 thickness exceeds 60 feet. The interval thins southeastward and is eventually truncated. Structure Attachment 4 is a structure map on the top of the Kuparuk Formation with a contour interval of 50 feet. Top Kuparuk structure in the Aurora area is essentially a northwest- southeast oriented ridge, which is broken up by north-south striking faults. Gentle slopes dipping 2.5 to 6.5 degrees away from the structural crest characterize the northeast and southwest flanks of the ridge. In contrast, rotated fault blocks characterize the southern and western flanks of the ridge. A major north-south striking fault with up to 200 feet of down-to-the-west displacement effectively bisects the Aurora Pool area into an eastern half, which contains the S-Pad Sag River/Ivishak development wells, and a western half, which contains the V-200 well. This fault is best seen on Attachment 4, the Top Kuparuk Structure map, lying immediately west of the S-1 03, S-120i and S-117 well locations. The southeastern terminus of the Aurora Pool is coincident with the "Prudhoe High", a large basement-involved structural uplift that underlies the Prudhoe Bay field. Early Cretaceous and older sediments lapped over this structural high, and were later uplifted and subsequently beveled off by unconformities. Thus, this major structural high east of the Aurora accumulation is devoid of Kuparuk. The Kuparuk Formation thins t southeastward to a zero edge against the Prudhoe High. The erosional truncation is orthogonal to the northwestern orientation of the overall structural ridge Attachments 5 and 9 are north-south oriented structural cross-sections through the western and eastern portions of the Aurora field, respectively (see Attachment 4 for location). These cross-sections illustrate the continuation of the Aurora reservoir beyond the northern and southern boundaries of the existing AP A. Attachment 6 and 10 are seismic traverses along the same lines of section. Attachment 7 is a northwest-southeast oriented structural cross-section paralleling the northern periphery of the Aurora field (see Attachment 4 for location). It, too, illustrates the presence of Kuparuk reservoir north of the existing AP A. Attachment 8 is a seismic traverse along the same line of section. 7/12 /'---... ~ ~ ~ Fluid Contacts Attachment 13 shows the interpreted Oil/Water Contact (OWC) and Gas/Oil Contact (GOC) in the Aurora Pool. Based on wireline logs, the OWC has been interpreted at 6835 feet tvdss. A common GOC for the Aurora Pool is not present. Based on well tests, mudlog and wireline logs, a GOC of 6678 feet tvdss is interpreted in the West Block. The North of Crest and Crest Block are gas-free based on production flow tests, sidewall core saturations and staining, and RFT pressure gradient data and fluid samples. In the Southeast of Crest Block logs from well S-16a indicate a local gas accumulation with a GOC of 6631 feet tvdss. Pool Limits The trap for oil and gas in the Aurora Pool is created by a combination of structural and stratigraphic features. as illustrated on the attached structure map and cross sections. The accumulation is bounded to the west by several faults where the reservoir is juxtaposed against impermeable shales of the overlying Kalubik Formation and HRZ Shale. To the southwest and north, the pool limit is defined by the down-dip intersection of the top of reservoir with the oil-water contact. Data acquired since the formation of the Aurora Participating Area indicate that the intersection actually lies beyond the northern and southern boundaries of the current P A. To the east and southeast the reservoir is truncated by the Pre-Aptian, C-4, and Lower Cretaceous Unconformities. unconformities merge at the southeastern limit of the field. These Subsurface well data and reprocessed seismic indicates that the recoverable hydrocarbon accumulation at Aurora. Field extends beyond the boundaries of the existing Participating Area. The boundary of the proposed expanded Aurora PAis within the proposed boundary of the Aurora Pool. Attachment 11 is a net hydrocarbon pore foot map of the Aurora Pool with a contour interval of 2 feet. Attachment 12 is a net pay map of the Aurora Pool with a contour interval of 20 feet. Both maps show the extent to which recoverable hydrocarbons extend beyond the limits of the current P A. The geologic cross sections and seismic sections in Attachments 5 through 10 further illustrate the geological continuity from the cunent P A into the proposed expansion areas. 8/12 r'\ ,..-., e 8 Reprocessing of the vinltage 2000 Aurora seismic dataset greatly improved imaging of top Kuparuk structure. Attachment 6A provides an example of seismic data before and after reprocessing. As a result, the ability to more accurately predict top reservoir depth, and the location and magnitude of faults is greatly improved. Well S-1O2 was successfully sidetracked in October 2003 to within 1000' of the northern AP A boundary confirming the structural interpretation of the reprocessed data. Log data from the sidetrack, S- 1O2Ll, indicate reservoir quality Kuparuk sands extend northward and lie above the regional free water level. Well S-116i was drilled to within 1900' of the southern AP A boundary. Interpreted log data and pressure measurements from S-116i and logs from Term Well C, about 1400 feet south of the current PA, indicate that the Kuparuk A sand reservoir is present above the regional free water level south of the existing APA. Hydrocarbons in. P]lace Estimates of hydrocarbons in place for the Aurora Pool reflect current well control, stratigraphic and structural interpretation, and rock and fluid properties. The current estimate of original oil in place (OOIP) ranges between 165 mmstbo and 201 mmstbo. Formation gas in place ranges from 112 to 137 bscf, and gas cap gas ranges from 15 to 75 bscf. 9/12 /""""" ~. -' ~ II. PLAN OF [ÞEVELOPMENT AND OPERATIONS Development of the Aurora Reservoir includes phased drilling of approximately twenty (20) to twenty five (25) production and injection wells from S-Pad. Initial (Phase I) drilling commenced July 2000 with production startup in November 2000. Water injection started in January 2002. Production is commingled with IP A production on S- Pad and processed at GC-2. Phase II drilling began in 2Q 2001. A total of nineteen (19) Aurora development wells have been drilled through end of January 2004. See Table 1, below. The Phase II program will continue through 2005. Tertiary recovery, utilizing IP A miscible gas for \V AG (Water-Alternating-Gas injection) was started in the S-1O4i and S-101i wells during 4Q 2003. Wells Six wells were drilled during Phase I development (S-1O0, lOli, 102, 103, 104i, 105). Two Phase I wells (S-lOli and S-104i) were drilled as pre-produced injectors. Phase II drilling commenced in mid-2001 and through January 2004 thirteen (13) Phase II wells have been drilled (S-1O6, S-1O7i, S-1O8, S-1O9, S-llOi, $-112i, S-I13B, S-114Ai, S-115, S-116i, S-I17, S-118 and S-120i). Currently, five wells are on injection S-lOli (WAG), S-1O4i (WAG), S-1O7i, S-llOi, and S-112i. Injectors S-116i and S-120i will be pre- produced for 10 days then converted to water injection 1 Q 2004. As part of a proposed PA expansion for 2004 an additional well is being considered along the northern periphery of the current P A. Depending on its results, additional development in the northern P A area will be evaluated. The Aurora Owners will continue to evaluate optimal well count and well locations as development and depletion of the reservoir progresses. Unutilized IP A well-bores will also be evaluated to access Aurora reservoir targets. Although pattern spacing is expected to be irregular, minimum nominal inter-well spacing is estimated to be 80 acres. Drill Sites and Pipelines Aurora development wiill use the existing WOA infrastructure of pipelines, roads and pads. Initial development from S-Pad utilizes existing low-pressure pipelines from S-Pad to GC-2. Additional gravel was laid to expand the northern part of S-Pad to accommodate wells and drilling beyond Phase I. Aurora Owners installed vertical 10/12 r""-. ~ 8 8 support members (VSMs) and trunk lines to the north of S-200 to extend the production/test/produced water and artificial gas lift headers. Aurora Owners have approved the expansion of an MI trunk to allow water injectors to be converted to WAG injection for the tertiary recovery project. Support Facilities Aurora will share North Slope infrastructure with the IP A as needed to support Aurora Operations, minimizing duplication of facilities. These include camp facilities, potable water and waste disposal facilities, shop and maintenance facilities, airstrip, construction pad, storage and warehouse space, oily waste disposal facilities and telecommunications systems. Production The wells at Aurora have a current combined production of approximately 10-15 MBD. The current water injection rate is approximately 20-25 MBWPD. The current miscible gas injection rate is approximately 20 MMCFPD. production and injection history. Attachment 14 shows Aurora Waterflood Waterflood operations began in January 2002. A waterflood configuration is anticipated to conform to the minimum nominal inter-well spacing of 80 acres. Injection water is obtained from the IP A for use in the Aurora waterflood. Production Allocation Aurora production allocation is being performed according to the PBU Western Satellite Production Metering Plan. Allocation relies on performance curves to determine the daily theoretical production from each well. The GC-2 allocation factor is applied to adjust the total Aurora production. A minimum of one well test per month is used to check the performance curves and to verify system performance. No NGLs are allocated to Aurora. Enhanced Recovery Techniques Miscible gas injection is expected to increase economic recovery of Aurora hydrocarbons by approximately 3-5 mmbo. 11/12 ,...-"'-., ~. 8 8 Table 1: Aurora Wells Completed in the Kuparuk Formation ~."""...'....'.~'.....~~.~-'~._W~~..~w'.'w'.._....-..w_.""m."...w Well Status Desc I Producer Flowing j ect ?E,Qe~~~!wi~J~L,_ww__ww~ I Producer Gas Lift I Producer Gas Lift oducer Gas Lift tor Opera!!.~W~"'~'...w_~~"",w.w.__www~,.,w~, cer Gas Lift rGas r Injector Injecting IOil Producer Shut-In ~~~'~lÖ i 1"P"rõêruêe"rGãswTTf~w.w~~"W"Ww" . ,...w"..w.ww~_ww_w__._...~._~w_.",-,~_.,.,~-w.~" I Water Injector Injecting ,~~~~~~n j e~~.?w~,.!~! ect i nJL.,_~W"~W"-'~~~~~'W" IOil Producer Shut-In -"..w.".".ww...W..w_.~,~,~ - ..,,~w...~....,""~.w.,...,_.._w~,"~w~~..,~w~,Ww_..~wWwW.~w" w_, Water Injector Injecting .'w."'.""w.',_w'..'Ww~~~...~~~"..~~".""...M..'~'~~,w~".'w Oil Prod~,~~E,~~!,~~i~~, w~ w~w,~.."w'w~.. ~ r Injector, Not Yet Completed Oil Producer Gas Lift Oil Producer, Not Yet completed t Yet Completed 12/12 2 STATE OF ALASKA ADVERTISING ORDER F AOGCC R 333 W 7th Ave, Ste 100 0 Anchorage, AK 99501 M ¿ Anchorage Daily News P a Box 149001 Anchorage, AK 99514 Type of Advertisement REF TYPE 1 VEN 2 ARD 3 4 NUMBER 02910 FIN AMOUNT SY 04 2 3 4 REQUISITIONED BY: 02-902 (Rev. 3/94) /'-...... ",..-....., . NOTICE TO PUBLISHER ~ ADVERTISING ORDER NO. ~F~t..;: ~~BI~C:~~~cf:¡R~~O~N~~D~~~~~~~~~~~~;~I~~ A 0-0241402 5 ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE x Legal 0 Display AGENCY CONTACT Jodv Colombie PHONE DATE OF A.O. March 31. 2004 PCN (907) 793 -1 ?21 DATES ADVERTISEMENT REQUIRED: April 2, 2004 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: STOF0330 Advertisement to be published was e-mailed 0 Classified DOther (Specify) SEE ATTACHED AOGCC, 333 W. 7th Ave., Suite 100 Anchorage, AK 99501 \MOUNT DATE cc PGM I TOTALOF I PAGE 1 OF ALL PAGES$ 2 PAGES COMMENTS LC ACCT NMR 02140100 ,/ t.. ..'--- FY DIST LID 73540 Publisher/Original Copies: Department Fiscal, Department, Receiving AO.FRM /""-.., ~ 18 ~ Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: Aurora Oil Pool, Prudhoe Bay Field Request for expansion of area subject to pool rules and area injection order BP Exploration (Alaska), Inc. by application dated March 26, 2004, has applied for expansion of the affected area for the Aurora Oil Pool pool rules as defined in Conservation Order No. 457 A and for Area Injection Order No. 22B. The Commission has tentatively scheduled a public hearing on this application for May 6, 2004 9:00 am at the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. A person may request that the tentatively scheduled hearing be held by filing a written request with the Commission no later than 4:30 pm on April 19, 2004. If a request for a hearing is not timely filed, the Commission will consider the issuance of an order without a hearing. To learn if the Commission will hold the public hearing, please call 793-1221. In addition, a person may submit a written protest or written comments regardin~ this application to the Alaska Oil and Gas Conservation Commission at 333 West 7t Avenue, Suite 100, Anchorage, Alaska 99501. Written protest or comments must be received no later than May 3, 2004 except that ifthe Commission decides to hold a public hearing, written protest or comments must be received no later than the conclusion of the May 4, 2004 hearing. If you are a person with a disability ~. o. a need a special modification in order to comment or to attend the pub 0 on, pre contact Jody Colombie at 793-1221 before April 30, 2004. ? i Published Date: April 2, 2004 AO# 02414025 -.-.... Anchorage Daily News Affidavit of Publication 1001 Northway Drive, Anchorage, AK 99508 " .-----~ PRICE OTHER OTHER OTHER OTHER OTHER GRAND AD# DATE PO ACCOUNT PER DAY CHARGES CHARGES#2 CHARGES #3 CHARGES #4 CHARGES #5 TOTAL 115260 04/02/2004 02414025 STOF0330 $121.18 $121.18 $0.00 $0.00 $0.00 $0.00 $0.00 $121.18 STATE OF ALASKA THIRD JUDICIAL DISTRICT 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. 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. Signed ~¡7a/f~ Subscribed and sworn to me before this date: I1t uJ J. d-.Có Y Notary Public in and for the State .of Alaska. Third Division. Anchorage, Alaska MY COMMISSION EXPIRES: DC} / )~) ¿1CO? II ). )~ f} ) / ,0 I ~~~~~~~ÿ~:~,~ ~Hl1h<A- OJ{ vU)f/ f~"~O.~~~~ V :.¡ :. PusUC : ~ \~'~~~-;"4f~~ ~ . , . . .:...... " :\" ;1.1 .... 'é\IIf~,\\ ~.I)Jljjjji \" Iwltll "~ed . ".,' , lfl(¡~" , till" in ,9rC!lr:toCÍll1'1m~nt 'or tQ(¡ttéhdthepubIlC' Jí~' . , /"', ,~ RE: Notice 8 ( Subject: RE: Notice From: legalads <legalads@adn.com> Date: 01 pr 2004 13:51:25 - 0 Hi Jody: Following is the confirmation information on your legal notice. Please let me know if you have any questions or need additional information. Account Number: STOF 0330 Legal Ad Number: 115260 Publication Date(s): April 2, 2004 Your Reference or PO#: 02414025 Cost of Legal Notice: $121.18 Additional Charges Web Unk: E-Mail Link: Bolding: Total Cost to Place Legal Notke: $121.18 Ad Will Appear on the web, www.adn.com: XXXX Ad Will Not Appear on the web, 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 ColombiÐ Sent: Wednesday, March 31, 20044:35 PM To: legalads Subject: Notice «File: Ad Order form.doc»«File: Aurora AIO.doe»«File: jody colombie.vef» Please publish on April 2, 2004. -lody 1 of 1 4/1/2004 2:32 PM STATE OF ALASKA ADVERTISING ORDER ""--"', ~ . NOTICE TO PUBLISHER ,. ADVERTISING ORDER NO. INV" ST BE IN TRIPLICATE SHOWING ADVERTISING ORDER RTIFIED AO-O2414025 AFF~ OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED . rOF ADVEFtTISEMENT 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. Jody Colombie March 31, ?004 PHONE PCN (907) 793 -1 ).).1 DATES ADVERTISEMENT REQUIRED: T 0 Anchorage Daily News P a Box 149001 Anchorage, AK 99514 April 2, 2004 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: United states of America AFFIDAVIT OF PUBLICATION 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 2004, and thereafter for -- consecutive days, the last publication appearing on the - day of , 2004, 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 2004, Notary public for state of My commission expires 02-901 (Rev. 3/94) Page 2 AO.FRM PUBLISHER 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 Ciri Land Department PO Box 93330 Anchorage, AK 99503 David Cusato 600 West 76th Ave., #508 Anchorage, AK 99518 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 ~ .'8 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 Schlumberger Drilling and Measurements 3940 Arctic Blvd., Ste 300 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Jack Hakkila PO Box 190083 Anchorage, AK 99519 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 ~ .8 David McCaleb IHSEnergy 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 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 Darwin Waldsmith PO Box 39309 Ninilchick, AK 99639 Penny Vadla 399 West Riverview Avenue Soldotna, AK 99669-7714 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 í!JiY lied t;Ø¡b ~ Notice ~ ~ 18 .8 Subject: Notice Fro' Date: Please publish online. -,Jody Jody Colombie <jody colombie@}admin.state.ak.us> Special Staff Assistant Alaska Oil and Gas Cooservation Commission Department of Administration II Content-Type: application/msword Aurora AIO.doc,: ,I Content-Encoding: base64 1 of 1 3/31/20044:35 PM Notice ;---, ,~ ~8 8 Subject: Notice From: Jody Colombie <jody__colombie@admin.state.ak.us> Date: Wed, ar 2004 16:35:03 -0900 Please publish on April :2, 2004. -Jody Jody Colombie <jody colombie@admin.state.ak.us> Special Staff Assistant Alaska Oil and Gas Conservation Commission Department of Administration Content-Type: application/msword Content-Encoding: base64 ,..... " . .1 Content-Type: application/msword. Aurora AIO.doc:í ' -- :[ Content-Encoding: base64 ..fl..................... ................."""""".................."...... 1 of 1 3/31/20044:36 PM ~ .~. Notice ~8 8 Subject: Notice From: y Colombie <jody__colombie@admin.state.ak.us> Date: ed, 31 Mar 2004 16:34:07 -0900 . Jody Colombie <iody colombie@admin.state.ak.us> 10f2 3/31/2004 4:36 PM Notice 2 of2 ~ /~. ~8 8 Special Staff Assistant Alaska Oil and Gas Conservation Commission Department of Administration .¡ Content-Type: applicationlmsword Aurora AIO.doc:: ,I Content-Encoding: base64 3/31/20044:36 PM 1 " bp ~. ., /"'--"", .~ 0 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 March 25, 2004 Commissioners Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 1100 Anchorage, AK 99501 RE: Amendments to Aurora Pool Rules and Area Injection Order CO 457 A and AIO 228 Dear Commissioners: Enclosed for your review and action is the Prudhoe Bay Unit (PBU) Working Interest Owners' application for amendments to Conservation Order 457A (as amended by Conservation Order 492) and Area Injection Order 22B, the Aurora Pool Rules and the Area Injection Order for the Aurora reservoir. These amendments are necessary because BP Exploration (Alaska) Inc. (BPXA) , as Aurora Operator and Unit Operator, has applied to the Department of Natural Resources to expand the Aurora Participating Area and the Prudhoe Bay Unit. Accordingly, BPXA hereby petitions the Commission to amend the above referenced rules as necessary to accommodate this expansion. BPXA requests that Section #4 of Conservation Order 457 A and Section #4 of Area Injection Order 228 be amended as follows to reflect the revised legal description describing the expanded area affected by these orders. Umiat Meridian Townshipll Range !ISections Sec. 2 WY2 Sec. 3: All R12E Sec. 4: EY2, NW%, EY2SW~ Sec. 5: EY2NE1A Sec. 9: NE1A, NY2SE% Sec. 10: NW1ASW%, WY2NW~ Sec. 15: SY2SE%, SW1A Sec. 16: NW~, SY2 Sec 17: SY2, NE%, R12E Sec 18: SE% Sec 19: NY2NE% Sec 20: EY2, NY2NW% Sec 21: All T11N T12N 1 v T12N r, ~ Sec 22: All Sec 23: SV2, SV2NW%, SV2NE% Sec 25: SV2, SY2NW% Sec 26: All Sec 27: All; R12E Sec 28: All Sec 29: EY2NE%, SE% Sec 32: EY2 Sec 33: All Sec 34: All Sec 35: All Sec 36: All ~ " Information in support of these amendments is attached. Please maintain as confidential those certain attachments attached and labeled "Confidential" in accord with AS 31.05.035 and 20 AAC 25.537. Please contact Gary Gustafson at 564-5304 or Frank Paskvan at 564-5749 if you have any . questions or need additional information. Sincerely, ~~ Gil Beuhler GPB Waterflood Manager Attachments: Attachment 1 Attachment 2 Attachment 3 Attachment 4 Attachment 5 Attachment 6 Attachment 6A Attachment 7 Attachment 8 Attachment 9 Attachment 1 0 Attachment 11 Attachment 12 Attachment 13 Attachment 14 location Map of the AP AIPBU Expansion Areas lease Map of Expanded AP AIPBU Aurora Type log - Well V-200 - Confidential Top Kuparuk Structure with Cross Section Index - Confidential Cross Section A - A' - Confidential Seismic Section A - A' - Confidential Detail from Seismic Section A - A' - Confidential Cross Section B - B' - Confidential Seismic Section B - B' - Confidential Cross Section C - C' - Confidential Seismic Section C - C' - Confidential Aurora Field - Composite Net Oil Pore Foot Map - Confidential Aurora Field - Composite Net Pay Map - Confidential Fluid Contact Data - Confidential Aurora Production and Injection Plot 2 ,r'", ., Cc: Francis Sommer, BPXA Marc Vela, ExxonMobii Dan Kruse, ConocoPhillips G.P. Forsthoff, Chevron Bradley Brice, Forest Oil Jane Williamson, AOGCC Mike Kotowski, DO&G Gil Beuhler, BPXA Frank Paskvan, BPXA Gary Gustafson, BPXA Jim Copen, BPXA Leslie Senden, BPXA Rosy Jacobsen, BPXA Gary Benson, BPXA Steve Luna, ExxonMobil Jeff Farr, ExxonMobil James Rodgers, Con()coPhillips Mark Worcester, ConocoPhillips ~ '" 3 -, / , "..-..., 8 . - March 25, 2004 Commissioners Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 RE: Amendments to Aurora Pool Rules and Area Injection Order CO 457 A and AIO 228 Dear Commissioners: Enclosed for your review and action is the Prudhoe Bay Unit (PBU) Working Interest Owners' application for amendments to Conservation Order 457A (as amended by Conservation Order 492) and Area Injection Order 22B, the Aurora Pool Rules and the Area Injection Order for the Aurora reservoir. These amendments are necessary because BP Exploration (Alaska) Inc. (BPXA), as Aurora Operator and Unit Operator, has applied to the Department of Natural Resources to expand the Aurora Participating Area and the Prudhoe Bay Unit. Accordingly, BPXA hereby petitions the Commission to amend the above referenced rules as necessary to accommodate this expansion. BPXA requests that Section #4 of Conservation Order 457 A and Section #4 of Area Injection Order 22B be amended as follows to reflect the revised legal description describing the expanded area affected by these orders. Umiat Meridian -~. T12N tions ¡Sec. 2 WY2 ¡Sec. 3: All R12E ¡Sec. 4: EY2, NW1A, EY2SW1A !Sec. 5: EY2NE1A ! ec. 9: NE1A, NY2SE1A ec. 10: NW1ASVY1A, WY2NW1A ec. 15: SY2SE1A, SW1A ec. 16: NW1A, SY2 ec 17: SY2, NE1A, ec 18: SE1A ec 19: NY2NE1A Sec 20: EY2, NY2NW1A Sec 21: All I¡ T11N R12E 1 T12N r\ ~ R12E Ii !! " ¡~ Ii , ",.~.w,._--,w,- --.. .- -, -.--,,---"'" All SY2, SY2NW%, SY2NE% SY2, SY2NW% All All; All EY2NE%,SE% EY2 All All All All ec 22: ec 23: ec 25: Sec 26: ¡ ec 27: 'ec 28: ec 29: ec 32: ec 33: ec 34: ec 35: ec 36: Ii ¡. " ! i: Ii Ii it Information in.support of these amendments is attached. Please maintain as confidential those certain attachments attached and labeled "Confidential" in accord with AS 31.05.035 and 20 AAC 25.537. Please contact Gary Gustafson at 564-5304 or Frank Paskvan at 564-5749 if you have any questions or need additional information. Sincerely, Gil Beuhler GPB Waterilood Manager Attachments: Attachment 1 Attachment 2 Attachment 3 Attachment 4 Attachment 5 Attachment 6 Attachment 6A Attachment 7 Attachment 8 Attachment 9 Attachment 10 Attachment 11 Attachment 12 Attachment 13 Attachment 14 Location Map of the APA/PBU Expansion Areas Lease Map of Expanded AP A/PBU Aurora Type Log - Well V-200 - Confidential Top Kuparuk Structure with Cross Section Index - Confidential Cross Section A - A' - Confidential Seismic Section A - A' - Confidential Detail from Seismic Section A - A' - Confidential Cross Section B - B' - Confidential Seismic Section B - B' - Confidential Cross Section C - C' - Confidential Seismic Section C - C' - Confidential Aurora Field - Composite Net Oil Pore Foot Map - Confidential Aurora Field - Composite Net Pay Map - Confidential Fluid Contact Data - Confidential Aurora Production and Injection Plot 2 ~ 'fJt Cc: Francis Sommer, BPXA Marc Vela, ExxonMobil Dan Kruse, ConocoPhillips G.P. Forsthoff, Chevron Bradley Brice, Forest Oil Jane Williamson, AOGCC Mike Kotowski, DO&G Gil Beuhler, BPXA Frank Paskvan, BPXA Gary Gustafson, BPXA Jim Copen, BPXA Leslie Senden, BPXA Rosy Jacobsen, BPXA Gary Benson, BPXA Steve Luna, ExxonMobil Jeff Farr, ExxonMobil James Rodgers, ConocoPhillips Mark Worcester, ConocoPhillips ~ " 3 r, ff ~' / k- g 10 I I ~A,NSION I ( I 1 I i ' .15 ) ~ ft 11 1 r. ,¿ 7 ------ ------ 1 ~ I \ I ì P U BcPUNDARY I~~ - /)NrrJ ;<l~ 24 ~ ~ 19 J'~~ ..3 ~-'~o- 13 18 -- 'f '- ........ J 6 --- r 12~ /,\ '\ - /' -7 ìì i ':'400" ,TRTUTE ,I iL Ec, fJ " J.v<TriTUTE MilES ~ I<ILOI'1EER5 q . ~ f\iLC.,IETERS D Current Aurora . ..../, Participating Area ~ AP A Expansion III APA & PBU Expansion . Producer Â Injector . Type Well . I Top Kuparuk Structure Attachment 1: Location Map of the AP AIPBU Expansion Areas 4 . i ~ - --I ..., . i . I I : . . MPU ; -'- - - - ....J- . . , - I I PR U~HOE BAl UNIT , I ¡ I I I ! \.......- -} u.J II ,. ~:rj ,.- ,.. ŒŒ Attachment 2: Lease Map of Expanded APAIPBU 5 ~) 12i'J 6) BP EXPLORATION (ALASKA) INC. Prudhoe Bay Unit Aurora PA DATE: I February 2004 I ATTAC:MENT SCALE: 1:78,000 BPXA Ca!1o;;¡raphyilm1'18S3b.dg" 70000 60000- 50000- 40000- 30000- 20000- 10000 - 0 2000 - - GAS INJ RATE - GAS RATE - OIL RATE \ }' / r/ ~ vi J ~ 'Ã .'_i~' ,.,': ~~I ., " 1'- ,-r-f. 1 " 2001 2002 Attachment 14: Aurora Production and Injection Plot - - WATER INJ RATE - WATER RATE f Î . ...., , . "... . II II II '-1 2003 18 t ~ , ~ ~ ~, ~I hL:~ I \ 1.' I~~ 1..'i'11f 2004 . - . ~) 6) ~ .--.., bp ~ IE (Çj IE ~ ìW lE 'r¡î ,I! MAR 2 6 2004 j) ==" '~ March 25, 2004 DIVISION OF OIL AND GAS BP Exploration'(Alaska) Inc. 900 East Benson Boulevard P.O, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Mark D. Myers, Director Division of Oil and Gas Alaska Department of Natural Resources 550 West ih Avenue, Suite 800 Anchorage, AK 99501-3560 RE: Application to Expand the Aurora Participating Area and the Prudhoe Bay Unit - ADL's 028255,028256,028257,028260,028261,047448 and 047450 Dear Dr. Myers: Pursuant to Sections 5.3 and 9.1 of the Prudhoe Bay Unit Agreement (PBUA) and the provisions of 11 AAC 83.303, 83.351 and 83.356, BP Exploration (Alaska) Inc. ("BPXA") , acting in its capacity as Operator of the Prudhoe Bay Unit (PBU) and on 'behalf of itself and the other PBU Working Interest Owners, Chevron U.S.A. Inc., ConocoPhillips Alaska, Inc., ExxonMobil Alaska Production, Inc. and Forest Oil Corporation, hereby applies to the Department of Natural Resources for approval of the expansion of the Aurora Participating Area (APA) and the corresponding expansion of the Prudhoe Bay Unit (PBU). The proposed APA expansion area encompasses approximately 2,240 acres while the PBU expansion includes about 1,120 acres (Attachment 1). These expansion areas are located within ADL's 028255, 028256, 028257, 028260, 028261, 047448 and 047450 (Attachment 2). As demonstrated by the additional attachments, the areas within the proposed AP A and PBU expansions are capable of contributing to the production of hydrocarbons in paying quantities sufficient to justify the development and production of the Aurora Reservoir in these areas. BPXA respectfully submits that the proposed expansion of the APA and PBU meets the criteria of 11 AAC 83.303 because it will promote conservation of natural resources, promote the prevention of economic and physical waste, and will protect all parties, including the State of Alaska. It also provides for the protection of the environment through planned development that optimizes the use and minimizes duplication of existing facilities. The following attachments are provided in support of this APA and PBU expansion: Attachment 1 Attachment 2 Attachment 3 Attachment 4 Attachment 5 Attachment 6 Attachment 7 Location Map of the AP A/PBU Expansion Areas Lease Map of Expanded AP A/PBU Amended Aurora Participations and Tract Allocations Amended Aurora Plan of Development and Operations Aurora Type Log - Well V-200 - Confidential Top Kuparuk Structure with Cross Section Index. Confidential Cross Section A - A' - Confidential March 25, 2004 ~. ~ . -- Mark D. Myers, Director Division of Oil and Gas Alaska Department of Natural Resources 550 West ih Avenue, Suite 800 Anchorage, AK 99501-3560 RE: Application to Expand the Aurora Participating Area and the Prudhoe Bay Unit - ADL's 028255, 028256, 028257, 028260, 028261,047448 and 047450 . Dear Dr. Myers: Pursuant to Sections 5.3 and 9.1 of the Prudhoe Bay Unit Agreement (PBUA) and the provisions of 11 AAC 83.303, 83.351 and 83.356, BP Exploration (Alaska) Inc. ("BPXA"), acting in its capacity as Operator of the Prudhoe Bay Unit (PBU) and on behalf of itself and the other PBU Working Interest Owners, Chevron U.S.A. Inc., ConocoPhillips Alaska, Inc., ExxonMobil Alaska Production, Inc. and Forest Oil Corporation, hereby applies to the Department of Natural Resources for approval of the expansion of the Aurora Participating Area (AP A) and the corresponding expansion of the Prudhoe Bay Unit (PBU). The proposed APA expansion area encompasses approximately 2,240 acres while the PBU expansion includes about 1,120 acres (Attachment 1). These expansion areas are located within ADL's 028255, 028256, 028257, 028260, 028261, 047448 and 047450 (Attachment 2). As demonstrated by the additional attachments, the areas within the proposed AP A and PBU expansions are capable of contributing to the production of hydrocarbons in paying quantities sufficient to justify the development and production of the Aurora Reservoir in these areas. BPXA respectfully submits that the proposed expansion of the APA and PBU meets the criteria of 11 AAC 83.303 because it will promote conservation of natural resources, promote the prevention of economic and physical waste, and will protect all parties, including the State of Alaska. It also provides for the protection of the environment through planned development that optimizes the use and minimizes duplication of existing facilities. The following attachments are provided in support of this APA and PBU expansion: Attachment 1 Attachment 2 Attachment 3 Attachment 4 Attachment 5 Attachment 6 Attachment 7 Location Map of the APA/PBU Expansion Areas Lease Map of Expanded AP A/PBU Amended Aurora Participations and Tract Allocations Amended Aurora Plan of Development and Operations Aurora Type Log - Well V-200 - Confidential Top Kuparuk Structure with Cross Section Index - Confidential Cross Section A - A' - Confidential 1 Attachment 8 Attachment 8A Attachment 9 Attachment 10 Attachment 11 Attachment 12 Attachment 13 Attachment 14 Attachment 15 Attachment 16 Attachment 17 r-- ~, ., 8 Seismic Section A - A' - Confidential Detail from Seismic Section A - A' - Confidential Cross Section B - B' - Confidential Seismic Section B - B' - Confidential Cross Section C - C'- Confidential Seismic Section C - C' - Confidential Aurora Field - Net Oil Pore Foot Map - Confidential Aurora Field - Net Pay Map - Confidential Fluid Contact Data - Confidential Production Plot Notice of Intent to Enlarge PBU Attached are five (5) copies of the non-confidential portions of this application and three (3) copies of the confidential portion. We request that the geological, geophysical, and engineering portions of this application marked as "Confidential" be kept confidential under AS 38.05.035(a)(9). Should you have questions regarding this application or should you require additional information to aid in your review please do not hesitate to contact Gary Gustafson at (907) 564-5304. Technical inquires should be directed to Frank Paskvan at (907) 564-5749. Thank you for your timely consideration. Best regards, Gil Beuhler GPB Waterflood Manager Attachments Cc: Marc Vela - ExxonMobil Bradley Brice - Forest Dan Kruse - ConocoPhillips G.M. Forsthoff - Chevron Francis Sommer, BPXA Gil Beuhler, BPXA Frank Paskvan, BPXA Jim Copen, BPXA Gary Gustafson, BPXA Leslie Senden, BPXA Gary Benson, BPXA Rosy Jacobsen, BPXA Mark Worcester, ConocoPhillips Steve Luna, ExxonMobil Jeff Farr, ExxonMobil James Rodgers, ConocoPhillips Jane Williamson, AOGCC Mike Kotowski, DO&G 2 /""'. .~ - ) )" 9 .t 10 11 12 7 ( I ---- ----- þ-9 > \ \ ) /30 (\ ',' 1 . 13 (p U BOUNbARY ~-)~~ ;<!Á:) ./ 24 '.-4 19 t,~~ ~~-~-'-- ~ 18 - 30 j \1 ) ~T 12N JIN 31 '- ......... J --- I } "- I I ~Á:)5 II ~ <:'+Á:) - ~~ { J Q}O~ f 'Ol~"-\-.~ ì -1 ~"f - "- + 07 - iß,- /rv . < «~~ M~~' - .,¡.~ {5. i ti OJ "'----' \ ),) 6 J 6 ----- 7 1 2------ /,\ \ - /' --+ I ìl 1: 24ØØØ STriTUTE ¡'1JLES ø .:, ].0 :,TRTUTE HILES ~ KILDHETERS; 'I l hlLDHETERS Top Kuparuk Structure [] Current Aurora . Participating Area It~~~il¡1 AP A Expansion . APA & PBU Expansion . Producer . Injector . Type Well Attachment 1: Location Map of the AP A/PBU Expansion Areas 3 I [ L___¡-, , i , i I I . I 'J ,. [ .... 'MPUl, ,. --- [ - I I I I l 'I I ~) ,T. -) BP EXPLORATION (ALASKA) INC. Prudhoe Bay Unit Aurora PA "'" DATE: I February 2004 I ATTAC~MENT ...._-~.. SCALE: 1:78,000 'r Attachment 2: Lease Map of Expanded APA/PBU BPXA Carto;¡raDhyilm14853b.d'gn 4 '. Attachment 3: Amended Aurora Participations and Tract Allocations Working Interest Ownership (%) Tract Tract Lease Township/Range Section Acres Royalty BPXA CPAI EM Chevron Forest Participation % % 10 47448 12N-12E Sec. 23: S1/2, 480 12.5 26.35536 36.069385 36.39549 1.160000 0.019768 2.394 S1/2NW1/4, S1/2NE1/4 11 28256 12N-12E Sec. 15: SW1/4, 2,000 12.5 26.35536 36.069385 36.39549 1.160000 0.019768 24.164 S1/2SE1/4 & ) Sec. 16: S1/2, NW1/4 Sec. 21: All Sec. 22: All 12 28255 12N-12E Sec. 17: NE1/4, 1,120 12.5 26.35536 36.069385 36.39549 1.160000 0.019768 5.112 S1/2 Sec. 18: SE1/4 Sec. 19: N1/2NE1/4 Sec. 20: E1/2, N1/2NW1/4 20 28259 12N-12E Sec. 29: SE1/4, 560 12.5 26.35536 36.069385 36.39549 1.160000 0.019768 2.789 E1/2NE1/4 Sec. 32: E1/2 21 28258 12N-12E Sec. 27: All 2,560 12.5 26.35536 36.069385 36.39549 1.160000 0.019768 44.447 Sec. 28: All 8 ) Sec. 33: All Sec. 34: All 22 28257 12N-12E Sec. 25: S1/2, 2,320 12.5 26.35536 36.069385 36.39549 1.160000 0.019768 19.063 S1/2NW1/4 Sec. 26: All Sec. 35: All Sec. 36: All 47 28260 11N-12E Sec. 2: W1/2 320 12.5 26.35536 36.069385 36.39549 1.160000 0.019768 0.085 48 28261 11N-12E Sec. 3: All 1,560 12.5 26.35536 36.069385 36.39549 1.160000 0.019768 1.927 Sec. 4: E1/2, 5 49 47450 Total 11N-12E E1/2SW1/4, NW1/4 Sec. 9: NE1/4, N1/2SE1/4 Sec. 10: W1/2NW1/4 NW1/4SW1/4 Sec. 5: E1/2NE1/4 80 12.5 11000 BPXA - BP Exploration Alaska Inc. Chevron - Chevron U.S.A. Inc. CPAI - ConocoPhillips Alaska, Inc. EM - ExxonMobii Alaska Production, Inc. Forest - Forest Oil Corporation 26.35536 36.069385 36.39549 6 1.160000 0.019768 " 0.019 100 6) ~) ~ ~ " ~ Attachment 4: Amended Aurora Plan of Development and Operations PLAN OF DEVELOPMENT AND OPERATIONS (2004) FOR THE AURORA PARTICIPATION AREA Development of the Aurora Reservoir includes phased drilling of approximately eighteen (18) to twenty five (25) production and injection wells from S.:Pad. Initial (Phase I) drilling commenced July 2000 with production startup in November 2000. Water injection started in January 2002. Production is commingled with IP A production on S-Pad and processed at GC-2. Phase II drilling began in 2Q 2001. A total of nineteen (19) Aurora development wells have been drilled through end of January 2004. See Table 1, below. The Phase II program will continue through 2005. Tertiary recovery, utilizing IPA miscible gas for WAG (Water-Alternating-Gas injection) was started in the S-104i and S-101i wells during 4Q 2003. Wells Six wells were drilled during Phase I development (S-lOO, 10li, 102, 103, 1O4i, 105). Two Phase I wells (S-1O1i and S-1O4i) were drilled as pre-produced injectors. Phase II drilling commenced in mid-2001 and through January 2004 thirteen (13) Phase II wells have been drilled (S-1O6, S-1O7i, S-1O8, S-1O9, S-llOi, S-112i, S-I13B, S-114Ai, S-115, S-116i, S-117, S-118 and S-120i). Currently, five wells are on injection S-lOli (WAG), S-1O4i (WAG), S-107i, S-llOi, and S-112i. Pre-produced injectors S-116i and S-120i will be pre-produced for 10 days then converted to water injection 1 Q 2004. As part of a proposed P A expansion for 2004, well S-119 will be drilled near the current northern PA boundary. Depending on its results, additional development in the northern PA area will be evaluated. The Aurora Owners will continue to evaluate optimal well count and well locations as development and depletion of the reservoir progresses. Unutilized IPA well-bores will also be evaluated to access Aurora reservoir targets. Although pattern spacing is expected to be iuegular, minimum nominal inter-well spacing is estimated to be 80 acres. Drill Sites and Pipelines Aurora development will use the existing WOA infrastructure of pipelines, roads and pads. Initial development from S-Pad utilizes existing low-pressure pipelines from S-Pad to GC-2. Additional gravel was laid to expand the northern part of S-Pad to accommodate wells and drilling beyond Phase 1. Aurora Owners installed Vertical Support Members (VSMs) and trunk lines to the north of S-200 to extend the production/test/produced water and artificial gas lift headers. Aurora Owners have approved the expansion of an MI trunk to allow water injectors to be converted to WAG injection for the tertiary recovery project. Support Facilities Aurora will share North Slope infrastructure with the IP A as needed to support Aurora Operations, minimizing duplication of facilities. These include camp facilities, potable water and waste disposal facilities, shop and maintenance facilities, airstrip, construction pad, storage and warehouse space, oily waste disposal facilities and telecommunications systems. 7 ~ ~ .' .- ~ Production The wells at Aurora have a current combined production of approximately 10-15 MBD. The current water injection rate is approximately 20-25 MBWPD. Waterflood Waterflood operations began in January 2002. A waterflood configuration is anticipated to conform to the minimum nominal inter-well spacing of 80 acres. Injection water is obtained from the IP A for use in the Aurora waterflood. For more details on waterflood surveillance and upcoming activities, see the attached AOGCC Annual Surveillance Report for the year 2003. Production Allocation Aurora production allocation is being performed according to the PBU Western Satellite Production Metering Plan. Allocation relies on performance curves to determine the daily theoretical production from each well. The GC-2 allocation factor is applied to adjust the total Aurora production. A minimum of one well test per month is used to check the performance curves and to verify system performance. No NGLs are allocated to Aurora. Enhanced Recovery Techniques Miscible gas injection is expected to increase economic recovery of Aurora hydrocarbons by approximately 3-5 mmbo. Table 1: Aurora Wells Completed in the Kuparuk Formation Sw Name Api Spud Date Well Status Desc 8-1 00 500292296200 7/9/2000 Oil Producer Flowing 8-101 500292296800 8/9/2000 Miscible Injector Operating 8-102 500292297200 9/14/2000 Oil Producer Gas Lift 8-102L1 500292297260 1 0/26/2003 Oil Producer Gas Lift 8-1 03 500292298100 11 /6/2000 Oil Producer Gas Lift 8-1 04 500292298800 1/11/2001 Miscible Injector Operating 8-1 05 500292297700 1 0/25/2000 Oil Producer Gas Lift 8-106 500292299900 5/5/2001 Oil Producer Gas Lift 8-1 07 500292302300 6/29/2001 Water Injector Injecting 8-1 08 500292302100 6/11/2001 Oil Producer 8hut-ln 8-1 09 500292313500 12/31/2002 Oil Producer Gas Lift 8-110 500292303000 8/13/2001 Water Injector Injecting 8-112 500292309900 7/22/2002 Water Injector Injecting 8-1138 500292309402 7/8/2002 Oil Producer 8hut-ln 8-114A 500292311601 9/19/2002 Water Injector Injecting 8-115 500292313000 12/20/2002 Oil Producer Flowing 8-116 500292318300 12/6/2003 Water Injector 8hut-ln 8-117 500292313700 2/17/2003 Oil Producer Gas Lift 8-118 500292318800 1/2/2004 Oil Producer 8hut-ln 8-120 500292318600 12/21/2003 Not Yet Completed / Td Not Yet Reached. 8 70000 60000- 50000 - 40000- 30000- 20000- 10000- 0 2000 - - GAS INJ RATE - GAS RATE - OIL RATE - - WATER INJ RATE - WATER RATE \ tl ~ f }'~ ..., , ~ ~""_i~' I ~~~, . , . r>-. f, 1 ,I 2001 2002 Attachment 16: Aurora Production and Injection Plot \11 1 21 r t J . I ' ¡ ~ I ~ ' it ,~\ I If. ~ ~ y .J...... :'1111 \ I; .:1 ' : II, 'If~ ~I\ ¡ - II I ...~ pi I ~II ~ ¡'III '\' I I '11 . 11.,1" .~ ~I I ~ iJr. II II .1, I I 1\\."" j I II . I " 'I L , '~I. - II I I _I J I 2003 2004 " tÞ) -) ~ "'-""'. 8 8 " bp A Tf ACHMENT 17 0 .¡:F E"tojlo),~k.F"4i&'1M ""-t ~¡¡':;¡;'L_.ßto....u,~"'d ¡¡;'{'i 90:'" i~o(H~ . Ald""".."AIiI>t.t %!1~'!~Kl '.ÞìJ71 ~lIr;i!,~tl! VI.A CERT1F.ED "'All"" RElUR.N REC1EIPTREOUESfED Mat'th '17. 2004 Mark Myere. Diroo:1/J1f Division of Oil & Gas Departmen~ iQl Nstu~ RœQurcee ,550 W~. 7'" Avenue, S~lte 800 Anchorsp. AK 99501 Rè: NdtK:e of intern t'D Enlarge 'the PrudOOB Bay Unit to Eoo:>mp~ Expa~lon$ 10 the Aurora andOñön P-artkiþàting Areas {)ear Dr-Mye-rs: PumtJan3 to Sectiion9. 1 of theP~hoe BaylJflí. Agrnemernand StD.n 1..0000. the Prudhoe BaylJnit Opera!!ing Agrøemen.,. '6P E;q:.loratlon {Ah*a) 100". ~in it$ capacily æ Opera.lof o.f the Prudhoe Bay Unit.. h~~ gIveSõOO'l~. of thèpropœ&d enlargement of t.t'le Pro.ctboo Bay Unit AI1Hi lo €toooo}þus proposmd flxpaJ>1Siònskl the Aurorn Ø'ld Orion Partiolpnling .Àttl'ti$. The prop~ fJtflJ3'clivG dale fur the enlar'~n.Sõ 1$ the- f~ .dãy of thèc~.ru:târ mMttlfôltöwmglhè date of thetinal apprO\l,SJ oJ tn.lnhll'gl)rnt.mtl~' tha. A~ O.pattmonl 01 Nltml Rgsou~ The teasM or poltioM of leas~ conktm~t¡£d for inclUsion in the Prudhoe Bay Unit Ama ("Enlargement Araas"') are listed on Exhibit A and depièted on :Exhibi'tB. 00th of ..mieh are a'tt~d hereCoandine1XpJ;Þfated herein, As provided by SectiiQn 9,1 1;11 ~he Prudhoe Bay Unit Agreement, the trads ~Id In the Enlargemenc Areas Mite been rea.sooabty ò..rmlf'*:l to .be wll'lin tht'J Aurora and' Orion R~IVOIf'$, a, poolœ! of whk:Ì'I a~ wìh1n IhePNdhoe Bay Unit Area. the IDclu~n 01 ttw EnlargÐmMt Áreasln the Prudhoe aa~( Unit Area '!Mil enable the timety dllWekJpment of the Auront i:1f}d Orion ReøfV()Î~ by 'Ð.~ 1he sharift.g ofe)(i~ng PrudOOB Bay Unitfaöillties. The èxpatWõn of the Prudhlóè &;1 UnFt Area mine-tude the Eniargennent Areas MIl promote conservation of natura1 resources. prom~e the preverrtioo Qf eç(iftQmic and ph)lsicaJ we_e, and wIt prot&ct aU fnrtie5õ, indudjng ~ Smte of ,A.Ia$1œ. Theexpaneioo ..0 providee for the ~1(Þr o.f eho otWimnl"JMjm ttYo~ptanned de'veloprnenl Whiehoptlnizes che u~ of ex<is1I"9 fa.dltjes i'1nd p~ unmK:essary duplication ofhilcllttles. 22 ~ ,~ - 8 '- PurSuant tÐ Sèotion 9.1 (b) of '\be Prudhoe Bay Un;tt Agreement, ;ß!ny Inter¡¡;:fi¡1ed party may file wiílh the Unit Operebx written ooj~::tions, and rea$ooslh~ree'of8. 10 thè pß,opQKtd .e~rgefn>e,n~$ withio 'thIrty (30) da,ys of ~~ da.ethi$ Notlo'l!! was fr)iltUtKi. U )'00 have å"YÙ<Ot'Jit'Jioots Or( quo:slionð. pk3aæ èootàcl Gåf'j GustafBtmal (OO7) 5e4,~ 5304. Sincerely, , ' ,'..' l\ "f " /'! ..-'-~ " " ] "'...- :./ A, ' " ,I -",/" ,¡}ø-'15, ' ~~. .J ...¡Pl/i' ,.;r-.-. Maura'ên l\-J: n Greater prudf1ioŠBay Per10mianCB Unit leadBf ^"a.chment~ Exhibit A - peUEnla~n' Ama~'o EN"...omp;a$1 ,t'¡¡.t .A.urøm & Orion Pañlci~ti~ Ar~ Exp~$loni Exhibit B - Mðp ~ Prop~d PBU Erdl.u~mm)t Ar.eM Oc: t.1a;rk Vela. EM via certified mail 0..... Kru$8. CPAI via e:ettffled maU L GuMe. F~'" Oil via.certlfttdmall G.M. ForB1hoff, Chevron Vis èertffied mail Gary Bef1lSl:>ß, B.PXA ROO)! J~Ktn,BPXA t"ttrit Worœsœr, CPAI Stew Luna, EM Gary GU$takon. BPXA LÐSII& Sendon, BF'XA Mike Kotowski. DO&G deft flIT. EM James AodgtIra. CPAI Judy Buono. 8PXA l' 23 ~ ~\ 8 8 'w EXHIBIT A PDt} ENLARGI!MENl" ARRAS 1'O.ENCOMIPASS Till': AUROR..o\. Ái"4D ORION PARTICIPA TU~G AREA .I!:XPANSIONiS I. ¡i\UROiRA PAl'nClri\TIN(i AREAlf'B{' EX:fANSION -lþUO j'\'~ Ïr.xl lÀ~ctifìlÍt)[¡ ArJL Rr..t1.'.aII'" AL"'re;ll(è H T12N-R11E ~tì.oo 1;5; Sl.I1SIH!4, SWI14 ~,ctiOfJ Hi: SIll, NWl/4 ~tioo :u~ EHt2NW 1~4, NEI/4 960 018.236 j 2.:5% 12 II ZN-RI2E S«tioo 17: NIUl4 160 Ü2,;8255 lZ,5~ 11+ ORION PARl1CIPATING AJU;MPBlJ £XPAN-~10N - 240 A,c~ ~ l&f(!rmQQm t~~ .~L?L ~~ B Tl2N-RI LE Soctioo 23: SW1l4, W:l!2NW Mt 240 3-'510061 12.5'J, Lqemð EM- E.xx onMobH AJil5b PrOOQ~ ÌIJ.m. 1m, CPAI - C~MILip¡¡ AWb. mc. BPXA - BP E.xplŒiition (AI1!sk~) 1m; CT- Qìe'Vt'tK) U _S.A lrtc - ~st - Fl)œ~t Oil CorpoJ"c;¡ti(1{1 WIO%J EM :Y6-J9;54'1~ CPAI 36.069385%> BPXA 2i5.3S53~ CT ],l~ F(¡f'£,st (to] 9168~ EM 306_395491 % CJJAI ~6,~:3$5~ BPXA 2ti.355356% CT 1 wl~ P:ø.re.S't 0.0 I 9161f"" ly¡g~ EM3ó..395491 ~ CP AI $6.ó69'~8S~ BPXA 26.355356% cr I.l~ ~ 4)J'}I9163% J Bf'XA. CPAlmò EM IitOW Qwn the tloovc: refeJC~ Amrom P,oVPBU (';~pæ1sioo a..::ro.agt: in ADL>!i;O2ß2SS andO2ß:236ìD Ê""ðdiffíCl'œtot.\'M~p pefL~,~ (5(~CPAIlSO'l.E).t and ;5(}%BPXM5~(':~^VZS~æM). 1~s ~re. i8 in prt)ÇtSS or be:ing <:ros5.ssigned by Bf'XA. CPA' ;mð EM in;", UK~ aljg~d PBU Q"~nc:ræ¡p dtcirmJs imiie:ate:d tloovc. ;. 24 " L.....- J] r ! - i ¡ + ], '~,- :,' ... ~ ,,'_m" r-'" - e ~f .--~ ",... I I I .__.~ ---- -'" -. ._-~. 25 ~ 8 u '7 .:(' ~ {f} .::r ,.,J <:.:( Z 0 r-- <[ a: 0 -1 û.... X LLJ Cl.. co ..!-I C' -3 u:' e OJ :;..... ~ ...... ,..... .-\ :gWW .t::: G) x 0 =:;. W..c1Il -oD.. :J ... D CL (i¡ (Jj 0 0... e 0... Ii ¡ -;,1) m ':þ ~ <t c ð ", ,- " :; ..,' <:. " ',' , " ;" ~ ~-ci 'j, :; .. ----- ,It.. n"øøJ j ; ! í , j I I ; ~ ~ bp ~ --- BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 March 25, 2004 Commissioners Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 RE: Amendments to Aurora Pool Rules and Area Injection Order CO 457 A and AIO 228 Dear Commissioners: Enclosed for your review and action is the Prudhoe Bay Unit (PBU) Working Interest Owners' application for amendments to Conservation Order 457A (as amended by Conservation Order 492) and Area Injection Order 22B, the Aurora Pool Rules and the Area Injection Order for the Aurora reservoir. These amendments are necessary because BP Exploration (Alaska) Inc. (BPXA), as Aurora Operator and Unit Operator, has applied to the Department of Natural Resources to expand the Aurora Participating Area and the Prudhoe Bay Unit. Accordingly, BPXA hereby petitions the Commission to amend the above referenced rules as necessary to accommodate this expansion. BPXA requests that Section #4 of Conservation Order 457 A and Section #4 of Area Injection Order 22B be amended as follows to reflect the revised legal description describing the expanded area affected by these orders. Umiat Meridian ITownship]! T11N Ran~rSectio~s '" ¡Sec.2 W1f2 Sec. 3: All R12E Sec. 4: E1f2, NW%, E1f2SW% Sec. 5: E1f2NE% Sec. 9: NE%, N1f2SE% .Sec. 10: NW%_SW%, W1f2NW% Sec. 15: S1f2SE%, SW% Sec. 16: NW%, SY2 Sec 17: S%, NE%, R12E Sec 18: SE% , Sec 19: N1f2NE% ¡;Sec 20: E1f2, N1f2NW% flSec 21: All , M., . ,._-- . 1 I { it - T12N T12N ~ "'" I 8 _Sec 22: All Sec 23: S¥2, S¥2NW%, S¥2NE% Sec 25: S¥2, S¥2NW% Sec 26: All Sec 27: All; R12E Sec 28: All Sec 29: E¥2NE%, SE% Sec 32: E¥2 ISec 33: All Sec 34: All Sec 35: All Sec 36: All .~ -8 Information in support of these amendments is attached. Please maintain as confidential those certain attachments attached and labeled "Confidential" in accord with AS 31.05.035 and 20 AAC 25.537. Please contact Gary Gustafson at 564-5304 or Frank Paskvan at 564-5749 if you have any . questions or need additional information. Sincerely, ~~ Gil Beuhler GPB Waterflood Manager Attachments: Attachment 1 Attachment 2 Attachment 3 Attachment 4 Attachment 5 Attachment 6 Attachment 6A Attachment 7 Attachment 8 Attachment 9 Attachment 10 Attachment 11 Attachment 12 Attachment 13 Attachment 14 Location Map of the AP A/PBU Expansion Areas Lease Map of Expanded APA/PBU Aurora Type Log - Well V-200 - Confidential Top Kuparuk Structure with Cross Section Index - Confidential Cross Section A - A' - Confidential Seismic Section A - A' - Confidential Detail from Seismic Section A - A' - Confidential Cross Section B - B' - Confidential Seismic Section B - B' - Confidential Cross Section C - C' - Confidential Seismic Section C - C' - Confidential Aurora Field - Composite Net Oil Pore Foot Map - Confidential Aurora Field - Composite Net Pay Map - Confidential Fluid Contact Data - Confidential Aurora Production and Injection Plot 2 ~, -. Cc: Francis Sommer, BPXA Marc Vela, ExxonMobil Dan Kruse, ConocoPhillips G.P. Forsthoff, Chevron Bradley Brice, Forest Oil Jane Williamson, AOGCC Mike Kotowski, DO&G Gil Beuhler, BPXA Frank Paskvan, BPXA Gary Gustafson, BPXA Jim Copen, BPXA Leslie Senden, BPXA Rosy Jacobsen, BPXA Gary Benson, BPXA Steve Luna, ExxonMobil Jeff Farr, ExxonMobil James Rodgers, ConocoPhillips Mark Worcester, ConocoPhillips ~ " 3 ".--.., 8 ~ bp 8 0 . BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 March 25, 2004 Commissioners Alaska Oil and Gas Conservation Commission 333 West ¡th Avenue, Suite 100 Anchorage, AK 99501 RE: Amendments to Aurora Pool Rules and Area Injection Order CO 457 A and AIO 228 Dear Commissioners: Enclosed for your review and action is the Prudhoe Bay Unit (PBU) Working Interest Owners' application for amendments to Conservation Order 457A (as amended by Conservation Order 492) and Area Injection Order 22B, the Aurora Pool Rules and the Area Injection Order for the Aurora reservoir. . These amendments are necessary because BP Exploration (Alaska) Inc. (BPXA), as Aurora Operator and Unit Operator, has applied to the Department of Natural Resources to expand the Aurora Participating Area and the Prudhoe Bay Unit. Accordingly, BPXA hereby petitions the Commission to amend the above referenced rules as necessary to accommodate this expansion. BPXA requests that Section #4 of Conservation Order 457 A and Section #4 of Area Injection Order 22B be amended as follows to reflect the revised legal description describing the expanded area affected by these orders. Umiat Meridian . ITownshiplr Range Sections Sec. 2 WY2 Sec. 3: All R12E Sec. 4: EY2, NW*, EY2SW* Sec. 5: EY2NE* Sec. 9: NE*, NY2SE* Sec. 10: NW*SW*, WY2NW* Sec. 15: SY2SE*, SW* Sec. 16: NW*, SY2 ,See 17: S%, NE*, R12E Sec 18: SE* Sec 19: NY2NE* Sec 20: EY2, NY2NW* Sec 21: All T11N , T12N .~, 1 ~. . Cc: . . ~8 Francis Sommer, BPXA Marc Vela, ExxonMobil Dan Kruse, ConocoPhillips G.P. Forsthoff, Chevron Bradley Brice, Forest Oil Jane Williamson, AOGCC Mike Kotowski, DO&G Gil Beuhler, BPXA FrankPaskvan, BPXA Gary Gustafson, BPXA Jim Copen, BPXA Leslie Senden, BPXA Rosy Jacobsen, BPXA Gary Benson, BPXA Steve Luna, ExxonMobil Jeff Farr, ExxonMobil James Rodgers, ConocoPhillips Mark Worcester, ConocoPhillips 3 ~ 8 ) ,...--, ~ 8 8 J 9~ 11 12 NSION ; ( \ I -- 13 7 7 1 18 . (p U BOUNbARY -..r- \ ~ ~ - JNtfJ .11/0 ;' 2~ ~ ~ 19 (~~~ ~---'-- ~ 30 '- ........ I \ " --<1/05 I --<1 ~+/O 1- ~~ ~ J O}O~ ( - /" "--' ~ ":; ~~~ '- . ':- ~'" /"'~'. -1 .-«~, ~"" '-" v~ ~ ' I \ y) < ~~ 6 . I 6 7 - -'" --7- I ~' J :24ØØØ 51R1U1E MJLE5 ø .5 1.ø S1RTUH MILES ~ K J LOMEHRS ~ J 2 K J LOMEHRS I J I Top Kuparuk Structure ^ .... Curr.e~t A.urora 1 IZ!:!I Participating Area l' II AP A Expansion II AP A & PBU Expansion . Producer . Injector . Type Well Attachment 1: Location Map of the APAIPBU Expansion Areas . .~ 4 ~ V f A 1 \ . ,( ~J ,.~II~\ ~I ~ 1 I~ J ~ I . .. , ,I' It' ~ T' "', \ . II , I' I 'I' ' II i t III .' I I I .. J ,q I! , II II ~ 1 ~,\ It n. I, I~ I :::. ~ ~ I, I ~ ,", 1- .~..,r;.f~, .,,~..~l.L:. .: .~~tl.~" .' LtLJlL.ì, ~ntiM¥III,,' I \,111,'~.. , rc.. ~ "I ' . / 'f~fiIV I f ~ 200 .' I, ,,' ~ ,I ~' 1 ' ;;!1 II ¡, Attachment 14' 2002 . . J..~..;'..nl ""'J 1,Ii . Aurora Prod' ' "~I"~ \ I uctlon and In. . 2003"' J ectlon Plot ' . 70000 - - GAS INJ RATE - GAS RATE 60000- 1 50000- \ \ - 40000- ,I ¡f - 30000- 20000- / \ 10000- 0 2000 . . - Oil RATE - - WATER INJ RATE - WATER RATE . r ,~ J - C ' I J ~ 2004 18 " . ~