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Home My WebLink AboutCO 457 A Image )rOject Order File Cover paÓe XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ' ()C) V¡S7 A Order File Identifier Organizing (done) D Two-sided III II 11111111111111 ~escan Needed'" 1111111111111111 R~CAN Ø'5?lor Items: c1" Greyscale Items: D Poor Quality Originals: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Diskettes, No. D Other, NolType: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: BY: Helen ~ D Other;: Date:/ ifl os- 151 M!J 1111111111111111111 Date: 1 :J.. I 05' 151 rn-LJ NOTES: BY: Helen CMari'a ') Project Proofing Scanning Preparation BY: Helen ~ \ x 30 = + =, TOTAL PAGES rt~ (Count ""es n~t include cover /'e~) VI A In Date:} J-.I OS 151 r V ~r 1111111111111111111 Production Scanning Stage 1 Page Count from Scanned File: 7 0 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YçS Date: ~I ()S NO NO Is! VL1-.? Stage 1 BY: Helen~ If NO in stage 1, page(s) discrepancies were found: YES BY: Helen Maria Date: 151 111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Helen Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 12/1/2004 Orders File Cover Page.doc ) '1 INDEX CONSERVATION ORDER NO. 457A AURORA OIL POOL 1. April 4, 2003 2. April 28, 2003 3. May 6, 2003 4. April 26, 2004 5. December 6, 2004 Notice of Hearing, Affidavit of Publication, mailing list Operator's response to proposed amendment of Aurora Pool Rules (Confidential portion in Confidential Room) Notice of Cancellation of Hearing, Affidavit of Publication, Mailing list BPXA request for Proposed Aurora EOR Pilot BPXA request to extend pilot miscible injection (AIO 22B.002) Corrected Administrative issued 1/10/05 Conservation Order No 457 A ) ì STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue, Suite 100 Anchorage Alaska 99501 Re: Revision to pool rules governing the Aurora Oil Pool, Prudhoe Bay Field, North Slope, Alaska. ) Prudhoe Bay Field ) Aurora Oil Pool ) ) Conservation Order No. 457 A ) ) May 15,2003 IT APPEARING THAT: 1. The Alaska Oil and Gas Conservation Commission on its own motion proposed to amend Conservation Order No. 457 ("CO 457") that governs development of the Aurora Oil Pool and to revoke Conservation Order No. 98-A. 2. Rule 10 of CO 457 provides that upon proper application or its own motion, the Commission may administratively waive the requirements of any rule stated in the order or administratively amend the order as long as the change does not promote waste or jeopardize correlative rights, and is based on sound engineering and geosciences principles. 3. On April 4, 2003, notice of pu blic hearing was pu blished in the Anchorage Daily News. 4. BP Exploration (Alaska), Inc. ("BPXA") as Operator of the Aurora Oil Pool submitted comments upon the Commission's proposed modifications to CO 457 on April 28, 2003 and stated they are prepared to have the Commission rule on the basis of the record without further hearing. 5. No other comments were received concerning the proposed amendment. 6. The Commission has determined that a hearing is not necessary. The Commission cancelled the scheduled hearing on May 6, 2003. FINDINGS: 1. The [mdings of Area Injection Order No. ("AIO") 22B and CO 457 (with the exception of CO 457 Findings 27, 36, and 42), and Finding 10 of CO 471 are incorporated by reference. ) ) 2. CO 98-A issued February 12, 1971, was largely superseded by CO 457 and no longer applies to any producing pool within the Prudhoe Bay Field. The Commission's statewide regulations are appropriate for operations in the remaining area covered by CO 98-A pending future development of any additional pool. 3. CO 457 refers to CO 98-A for the definition of the Aurora Oil Pool ("AOP"). 4. The AOP is defined as the accumulation of hydrocarbons common to and correlating with the interval between 6765 feet - 7765 feet measured depth ("MD") in the Mobil Oil Corporation Mobil-Phillips North Kuparuk State No. 26-12-12 well. 5. Production from the Aurora Oil Pool is processed, along with production from several other pools, within Prudhoe Bay Unit Gathering Center 2. The criteria for allocation of production have been revised for Aurora and all other satellite oil pools within the western portion of the Prudhoe Bay Unit. Commission approval of these changes was provided in Conservation Order No.4 71, the pool rules for the Borealis Oil Pool. 6. Area Injection Order No. 22B ("AIO 22B"), dated May 6, 2003, authorized underground injection of miscible injectant ("MI") for enhanced oil recovery in the AOP, Prudhoe Bay Field, on the North Slope of Alaska. 7. BPXA supplied a plan to acquire reservoir pressure measurements in 2003. The plan provides adequate information to assess the progress of the depletion plan for the coming year. 8. Annual review of the reservoir depletion plan and the status of reservoir repressurization activity within the AOP will help ensure greater ultimate recovery . CONCLUSIONS: 1. The conclusions of AIO 22B, and CO 457 and Conclusions 9, 10 and 11 of CO 471 are incorporated by reference. 2. CO 98-A should be revoked and the definition of the Aurora Oil Pool should be moved to CO 457 to prevent confusion. 3. Implementation of a miscible gas project will result in greater ultimate recovery from the West and North of Crest Blocks of the AOP so long as average reservoir pressure is maintained above minimum miscibility. Flood performance will dictate whether expansion beyond these blocks is appropriate. 4. Production allocation criteria for the Western Operating Area and satellite pools of the Prudhoe Bay Unit as approved for the Borealis Oil Pool in Conservation Order 471, dated May 29, 2002, should be adopted for the AOP. 5. Annual review of the reservoir depletion pIan and the status of reservoir depressurization activity within the AOP will help ensure greater ultimate recovery . Conservation Order 457 A Page 2 of6 5/15/2003 } NOW, THEREFORE, IT IS ORDERED THAT: 1. This Conservation Order No. 457 A supersedes Conservation Order No. 457 dated September 7,2001. 2. The AOP is defined as the accumulation of hydrocarbons common to and correlating with the interval between interval between 6765 feet - 7765 feet measured depth ("MD") in the Mobil Oil Corporation Mobil-Phillips North Kuparuk State No. 26-12-12 well within the affected area. 3. CO 98-A is revoked. 4. The following rules, in addition to statewide requirements under 20 AAC 25 (to the extent not superseded by these rules), apply to the following affected area: Umiat Meridian Township Range TIIN R12E T12N R12E Sections N ~ Sec. 3 S Y2 Sec 17; SE Y4 Sec 18; E ~ Sec 19; All Sec 20; All Sec 21;W 1/2NW 1/4,S ~ Sec 22; SW Y4 Sec 23; SW Y4 Sec 25; A11 Sec 26; All Sec 27; All Sec 28; N ~, Se Y4 Sec 29; E ~ Sec 32; All Sec 33; A11 Sec 34; All Sec 35; N ~, SW Y4 Sec 36 Rule 1 Well Spacin2 (C0457, 9/7/01) Spacing units within the pool shall be a minimum of 40 acres. 20 AAC 25.055(a)(1) and (2) shall not apply to property lines within the external boundaries of the Aurora Participating Area. Rule 2 Casin2 and Cementin¡!: Practices (C0457, 9/7/01) In addition to the requirements of 20 AAC 25.030, the conductor casing must be set at least 75 feet below the surface. In addition to the requirements of 20 AAC 25.030, the surface casing must be set at least 500' tvdss below the permafrost. Rule 3 Automatic Shut-in Equipment (C0457, 9/7/01) a) A11 wells must be equipped with a fail-safe automatic surface safety valve system capable of detecting and preventing an uncontrolled flow. b) The wells must be equipped with a landing nipple at a depth below permafrost, which is suitable for the future installation of a downhole flow control device to control subsurface flow. The Commission may require such installation by administrative action. c) Safety Valve Systems must be maintained in good working order at all times and must be tested at maximum six-month intervals or other schedule prescribed by the Commission. Conservation Order 457 A Page 3 of6 5/15/2003 ) Rule 4 Common Production Facilities and Surface ComminÆling (Revised this order) PBU Western Satellite Production Metering Plan, approved by the Commission in CO 471 effective August 1, 2002 governs satellite production within the Western Operating Area of Prudhoe Bay Unit, including the Aurora Oil Pool. a) The Prudhoe Bay Unit Gathering Center 2 well allocation factor for oil, gas, and water shall be applied to adjust total Aurora Oil Pool production. b) All wells must be tested a minimum of once per month. A11 new Aurora wells must be tested a minimum of two times per month during the first three months of production. The Commission may require more frequent or 10nger tests if the allocation quality deteriorates. c) Technical process review meetings shall be held quarterly to review progress of the implementation of the plan. d) The operator shall submit a monthly report and file(s) containing daily allocation data and daily test data for agency surveillance and evaluation. e) Commission approval of the Prudhoe Bay Unit Western Operating Metering PIan will expire on August 31, 2003. Continued authorization of metering and allocation procedures will be determined at a hearing to be scheduled no later than July 31, 2003. Rule 5 Reservoir Pressure Monitoring (C0457, 9/7/01) Prior to regular production or injection, an initial pressure survey must be taken in each well. a) Prior to regular production or injection, an initial pressure survey must be taken in each well. e) The minimum number of bottom-hole pressure surveys acquired each year shall equal the number of governmental sections within the Aurora Oil Pool that contain active wells. A minimum of four surveys will be required each year in representative areas of the Aurora Oil Pool. Bottom-hole surveys in paragraph (a) may fulfill the minimum requirement. The reservoir pressure datum will be 6,700 feet tvdss. Pressure surveys may be stabilized static pressure measurements at bottom-hole or extrapolated from surface (single phase fluid conditions), pressure fall-off, pressure buildup, multi-rate tests, drill stem tests, and open - hole formation tests. Data and results from all relevant reservoir pressure surveys must be reported quarterly on Form 10-412, Reservoir Pressure Report. All data necessary for analysis of each survey need not be submitted with the Form 10-412, but must be available to the Commission upon request. b) c) d) Conservation Order 457 A Page 4 of6 5/15/2003 ) } J f) Results and data from special reservoir pressure monitoring tests or surveys shall also be submitted in accordance with paragraph (e) of this rule. Rule 6 Gas-Oil Ratio Exemption (C0457, 9/7/01) Wells producing from the AOP are exempt from the gas-oil-ratio limits of 20 AAC 25.240(a) so long as requirements of 20 AAC25.240 (b) are met. Rule 7 Enhanced Oil Recovery or Reservoir Pressure Maintenance Operations (Revised this Order) Water and enriched hydrocarbon gas injection are authorized to enhance oil recovery within the Aurora Oil Pool. Average reservoir pressure must be maintained above minimum miscibility pressure. Expansion of miscible gas injection outside of the North of Crest and West Blocks must be administratively approved prior to 10ng-term injection. Commission approval is required prior to implementing major changes in reservoir depletion strategy. Rule 8 Reservoir Surveillance Report and Depletion Plan Update (Revised this order) An annual reservoir surveillance report for the prior calendar year will be required after one year of regular production and annually thereafter. The report shall include, but is not limited to, the following: a) Progress of enhanced recovery project implementation and reservoir management summary including results of reservoir simulation techniques; b) Voidage balance by month of produced fluids and injected fluids and cumulative status by major fault blocks; c) Summary and analysis of reservoir pressure surveys within the pool; d) Results and, where appropriate, analysis of production and injection 10g surveys, tracer surveys, observation well surveys, and any other special monitoring; e) Review of pool production allocation factors and issues over the prior year; and f) Review of the Annual Plan of Operations and Development including discussion of the reservoir depletion pIan and the status of reservoir repressurization activity. Rule 9 Production Anomalies (C0457, 9/7/01) In the event of oil production capacity proration at or from the Prudhoe Bay Unit facilities, all commingled reservoirs produced through the Prudhoe Bay Unit facilities will be prorated by an equivalent percentage of oil production, unless this will result in surface or subsurface equipment damage. Conservation Order 457 A Page 5 of6 5/15/2003 ) } / Rule 10 Administrative Action (C0457. 9/7/01) Upon proper application or its own motion, the Commission may administratively waive the requirements of any rule stated above or administratively amend this order as long as the change does not promote waste or jeopardize correlative rights, and is based on sound engineering and geoscience principles. AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may fIle with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23rd day following the date of the order, or next working day if a holiday or weekend, to be timely fIled. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the lO-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by non action of the Commission, the 30-day period for appeal to Superior Court runs from the date on which the request is deemed denied (Le., 10th day after the application for rehearing was fIled). Conservation Order 457 A Page 6 of6 5/13/2003 C0457A ) Subject: CO 457A Date: Thu, 15 May 2003 17:33:27 -0800 From: Jody Colombie <jody_colombie@admin.state.ak.us> Organization: Alaska Oil and Gas Conservation Commission To: Cynthia B Mciver <bren_mciver@admin.state.ak.us> Thanks Bren. Jody J ....-.-- ----.----- . -~- - - ---..--.----._..-..--.--..--. -.-----.---.. -, Name: C0457 A.doc ~C0457A.doc: Type: WINWORD Pile (applicationlmsword): ~,.,....ww, '..N..__,.."....,. """';.,~~~~.,~~~~:,~~~~.~~'~',"m""'''m'''"'''>.".".""»'"..'m~,'''m»».' -_..-..-.-.--- .-._-- - - --- .-~- -- -- - .-. -. ---- ------ - - --- - -.- -.- --- -.- I , Name: jody_colon1bie.vcf ~. d 1 b. f',¡ Type: VCard (text/x-vcard) UJo y co om le.VC¡ E do 7b't . - ! nco lng: 1 ; .. ...I~~~~~!e,!~~!:.."£~~>,!~E,~>~~~,,~~.~~~~.i~J 1 of 1 5/15/2003 5:33 PM Conservation Order No 457 A '\ Subject: Conservation Order No 457 A Date: Thu, 15 May 2003 17:32:46 -0800 From: Jody Colombie <jody_colombie@admin.state.ak.us> Organization: Alaska Oil and Gas Conservation Commission To: Robert E Mintz <robert_mintz@law.state.ak.us>, John Tanigawa <JohnT@EvergreenGas.com>, Terrie Hubble <hubbletl@bp.com>, Duane Vaagen <duane@fairweather.com>, Sondra Stewman <StewmaSD@BP.com>, stanekj <stanekj@unoca1.com>, ecolaw <ecolaw@trustees.org>, roseragsdale <roseragsdale@gci.net>, trmjrl <trmjrl@ao1.com>, jbriddle <jbriddle@marathonoi1.com>, rockhill <rockhill@aoga.org>, shaneg <shaneg@evergreengas.com>, rosew <rosew@evergreengas.com>, jdarlington <jdarlington@forestoi1.com>, nelson <nelson@gci.net>, cboddy <cboddy@usibelli.com>, "mark.dalton" <mark.dalton@hdrinc.com>, "shannon.donnelly" <shannon.donnelly@conocophillips.com>, "mark. p. worcester" <mark. p. worcester@conocophillips.com>, "jerry.c.dethlefs" <jerry.c.dethlefs@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>, burgin - d <burgin - d@niediak.com>, "charles. o'donnell" <charles.o'donnell@veco.com>, "Skillern, Randy L" <SkilleRL@BP.com>, "Dickey, Jeanne H" <DickeyJH@BP.com>, "Jones, Deborah J" <JonesD6@BP.com>, "Hyatt, Paul G" <hyattpg@BP.com>, "Rossberg, R Steven" <RossbeRS@BP.com>, "Shaw, Anne L (BP Alaska)" <ShawAL@BP.com>, "Kirchner, Joseph P" <KirchnJP@BP.com>, "Pospisil, Gordon" <PospisG@BP.com>, "Sommer, Prancis S" <SommerPS@BP.com>, "Schultz, Mikel" <Mike1.Schultz@BP.com>, "Jenkins, David P" <JenkinDP@BP.com>, "Glover, Nick W" <GloverNW@BP.com>, "Kleppin, Daryl J" <KleppiDE@BP.com>, "Platt, Janet D" <PlattJD@BP.com>, "Wuestenfeld, Karen S" <WuesteKS@BP.com>, "Jacobsen, Rosanne M" <JacobsRM@BP.com>, ddonkel <ddonkel@cfl.rr.com>, collins_mount <collins - mount@revenue.state.ak.us>, mckay <mckay@gci.net>, "barbara. f. fullmer" <barbara. f. fullmer@conocophillips.com>, bocastwf <bocastwf@bp.com>, cowo <cowo@chevrontexaco.com>, aj iii88 <ajiii88@hotmai1.com> , doug_schultze <doug- schultze@xtoenergy.com>, "hank.alford" <hank.alford@exxonmobi1.com>, yesno 1 <yesno 1 @gci.net>, "john. w .hanes" <john. w .hanes@exxonmobi1.com>, gspfoff <gspfoff@aurorapower.com>, "gregg.nady" <gregg.nady@shel1.com>, "fred. steece" <fred. steece@state.sd.us>, rcrotty <rcrotty@ch2m.com>, jejones <jejones@aurorapower.com>, dapa <dapa@alaska.net>, jack _laasch <jack _laasch@natchiq.com>, jimwhite <jimwhite@satx.rr.com>, wrholton <wrholton@marathonoi1.com>, "richard. prentki" <richard. prentki@mms.gov>, eyancey <eyancey@seal-tite.net>, markleypa <markleypa@alyeska-pipeline.com>, "jeffrey.walker" <jeffrey.walker@mms.gov>, tressler <tressler@ciri.com>, claire - caldes <claire - caldes@fws.gov>, jacobsenje <jacobsenje@alyeska-pipeline.com>, pcraig <pcraig@gci.net>, babsonandsheppard <babsonandsheppard@earthlink.net>, "james.m.ruud" <james.m.ruud@conocophillips.com>, greg_noble <greg- noble@ak.blm.gov>, ghavran <ghavran@gaffney-cline.com>, JohnstRA <JohnstRA@BP.com>, "sheila.mcnulty" <sheila.mcnulty@ft.com> 10f2 5/15/20035:33 PM Conservation Order No 457 A ) JohnstRA <JohnstRA@BP .com> "sheila.mcnulty" <sheila.mcnulty@ft.com> The attached Conservation Order was signed by the Commissioners May 15, 2003. ..m..V ........v... --_._~-- ~ Name: C0457 A.doc ~C0457 A.doc Type: WINWORD Pile (applicationlmsword)~ Encoding: base64 .....~'''ý .w.,.w...w.W'W""'W'W'"f'W"'W.w~.;.;.;,¡i.««i.'~""""o;¡;,;i.';'¡'~>;¡¡<>~:":":";"""...'.'""","'i..:,.;¡;..:,.x"",^.".. ¡------..-------- ...-.........--......,....,----...........-- .._.._~-".._"..........._._..._..._.~.... ---...-...- , Name: jody_colombie.vcf r~. d 1 b. f...:.i. Type: VCard (text/x-vcard) ...:...'.:.. UJo y_co om le.vCi Encoding: 7bit: _"0- . . ... ... .... .w..~~~~?!:,,~~~!():!()~?,ç()!()~!:J 2 of2 5/15/20035:33 PM SO Dept of Env & Natural Resources Oil and Gas Program 2050 West Main, Ste 1 Rapid City, SO 57702 Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 W. Allen Huckabay ConocoPhillips Petroleum Company Offshore West Africa Exploration 600 North Dairy Ashford Houston, TX 77079-1175 Donna Williams World Oil Statistics Editor PO Box 2608 Houston, TX 77252 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 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle, WA 98119-3960 Susan Hill State of Alaska, ADEC EH 555 Cordova Street Anchorage, AK 99501 ) ) John Katz State of Alaska Alaska Governor's Office 444 North Capitol St., NW, Ste 336 Washington, DC 20001 Christine Hansen Interstate Oil & Gas Compact Comm Excutive Director PO Box 53127 Oklahoma City, OK 73152 Citgo Petroleum Corporation PO Box 3758 Tulsa, OK 74136 Paul Walker Chevron 1301 McKinney, Rm 1750 Houston, TX 77010 David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 Texico Exploration & Production PO Box 36366 Houston, TX 77236 Chevron USA Alaska Division PO Box 1635 Houston, TX 77251 Chevron Chemical Company Library PO Box 2100 Houston, TX 77252-9987 Shawn Sutherland Unocal Revenue Accounting 14141 Southwest Freeway Sugar Land, TX 77478 Robert Gravely 7681 South Kit Carson Drive Littleton, CO 80122 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 John Levorsen 200 North 3rd Street, #1202 Boise,lD 83702 Samuel Van Vactor Economic Insight Inc. 3004 SW First Ave. Portland, OR 97201 Thor Cutler OW-137 US EPA egion 10 1200 Sixth Ave. Seattle, WA 98101 Julie Houle State of Alaskan DNR Div of Oil & Gas, Resource Eva!. 550 West 7th Ave., Ste 800 Anchorage, AK 99501 Cammy Taylor 1333 West 11th Ave. Anchorage, AK 99501 Trustees for Alaska 1026 West 4th Ave., Ste 201 Anchorage, AK 99501-1980 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 /l¡a//ed 5#6ß5 Schlumberger Drilling and Measurements 3940 Arctic Blvd., Ste 300 Anchorage, AK 99503 Ciri Land Department PO Box 93330 Anchorage, AK 99503 Mark Hanley Anadarko 3201 C Street, Ste 603 Anchorage, AK 99503 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 Judy Brady Alaska Oil & Gas Associates 121 West Fireweed Lane, Ste 207 Anchorage, AK 99503-2035 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Jim Scherr US Minerals Management Service Resource Evaluation 949 East 36th Ave., Ste 308 Anchorage, AK 99508 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 David Cusato 600 West 76th Ave., #508 Anchorage, AK 99518 Jeanne Dickey BP Exploration (Alaska), Inc. Legal Department PO Box 196612 Anchorage, AK 99518 Tesoro Alaska Company PO Box 196272 Anchorage, AK 99519 Jack Hakkila PO Box 190083 Anchorage, AK 99519 Kevin Tabler Unocal PO Box 196247 Anchorage, AK 99519-6247 BP Exploration (Alaska), Inc. Land Manager PO Box 196612 Anchorage, AK 99519-6612 Sue Miller BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Kenai Peninsula Borough Economic Development Distr 14896 Kenai Spur Hwy #103A Kenai, AK 99611-7000 Penny Vadla Box 467 Ninilchik, AK 99639 James Gibbs PO Box 1597 Soldotna, AK 99669 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 Richard Wagner PO Box 60868 Fairbanks, AK 99706 Cliff Burglin PO Box 131 Fairbanks, AK 99707 Harry Bader State of Alaska Department of Natural Resources 3700 Airport Way Fairbanks, AK 99709 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 Kurt Olson State of Alaska Staff to Senator Tom Wagoner State Capitol Rm 427 Juneau, AK 99801 Lt Governor Loren Leman State of Alaska PO Box 110015 Juneau, AK 99811-0015 ,.,. ) ,Co t57 A- ) FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA. OIL AlWD GAS CONSERVATION COMMISSION 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL NO 457 A.OO3 and 22B.OOl Mr. Gil Beuhler GPB Waterflood Resource Manager BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, AK 99519-6612 Dear Mr. Beuhler, By letter dated April 26, 2004, BP Exploration (Alaska), Inc. ("BPXA") requested authorization to conduct a pilot miscible injection (MI) project in Aurora Oil Pool ("AOP") Wells S-112, S-110 and S-116. The Commission approved AOP miscible gas injection for enhanced recovery purposes by Conservation Order 457 A (CO 457 A), dated May 15, 2003 and Area Injection Order (AIO 22B) dated May 6, 2003. Rule 7 of CO 457 A and Rule 9 of AIO 22B require that approval be obtained prior to expansion outside of the North of Crest and West Blocks of the AOP. Wells proposed for the pilot are outside of this approved area. Injection is planned to start mid-May in Well S-112 and S-110, within the South East of Crest Block, and in mid-September in Well S-116i, within the Crest Block of the AOP. Pilot miscible injection for 4-6 weeks is proposed to verify long-term feasibility of MI injection, and to stimulate the formation, improving water injection rates for these wells. The reservoir pressure in the injectors appears to be above the minimum miscibility pressure ("MMP") of 2700 psi, although the same producers have reservoir pressures lower than the MMP. Pilot operations for short-term injection may provide valuable information for later long term expansion of the area under MI flood, potentially enhancing recovery. 20 ) ADMINISTRATIVE APPROVAL NO 457A.00l and 22B.00l May 11,2004 Page 2 of2 The Commission approves BPXA's request to inject miscible gas into AOP Wells S-112, S-110 and S-116 subject to the conditions, limitations, and requirements set out below and statewide requirements under 20 AAC 25 (to the extent not otherwise superseded by AIO 22B and Conservation Order 457 A). . Separate sundry approval for conversion to MI injection service must be obtained. . Miscible gas injection is limited to no more than 3 months duration in each well. . Review of the information obtained during the test period must be presented to the Commission before April 1, 2005. This approval expires on December 31, 2004. a;~ chor ~~~ddatedMaøP J~- ~, Chair D~iel T. Seamount, Jr. Commissioner Commissioner SC/.~NNE[ J.'IUf 'Í\,~ '1 f:,: 200/; ..t\.. .L ~~¡i . . }~~" ) / FRANK H. MURKOWSKI, GOVERNOR A..,A.SKA. OIL AlÐ) GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE ACTION NO. 457A.02 ADMINISTRATIVE ACTION NO. 471.02 ADMINISTRATIVE ACTION NO. 484.02 ADMINISTRATIVE ACTION NO 452.02 Mr. Gil Beuhler PBU Satellite Engineering Manager BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, AK 99519-6612 Re: PBU Western Satellite Production Metering Plan Amendment of Conservation Orders 457 A, 471, 484, and 452 Dear Mr. Beuhler: By letter dated April 23, 2002, BPXA requested approval of the Prudhoe Bay Unit Western Operating Metering Plan for allocation of production from satellite oil pools in the Western region of the Prudhoe Bay Unit. The Commission conditionally approved this plan for one year beginning August 1, 2002. Rule 4 of Conservation Order No. 471 for the Borealis Oil Pool, Conservation Order No. 457 A for the Aurora Oil Pool, and Conservation Order No. 484 for the Polaris Oil Pool addresses the metering and allocation of production under this plan. Continued authorization of metering and allocation procedures was to be determined at a hearing to be scheduled no later than July 31, 2003. BPXA provided the Commission with a detailed metering and allocation procedures document on August 1, 2002. BPXA provided the Commission with a thorough review of the allocation performance of the Prudhoe Bay Unit Western Operating Metering Plan at technical meetings held on May 22 and June 5, 2003. In addition, well test and allocation information of all production fluids within the GC 1 and GC2 areas were provided as required. The Commission finds that continued use of the Prudhoe Bay Unit Western Operating Metering Plan is appropriate and that a further hearing is unnecessary. In addition, the Commission finds that technical process review meetings, required by the Commission to take place quarterly, need only take place annually. Accordingly, the Conservation Orders 471, 457, 484, and 452 are amended as follows. Borealis Oil Pool (CO 471)., Aurora Oil Pool (CO 457A) and Polaris Oil Pool (CO 484) SCANNED AUG 212003 Mr. Gil Buehler August 11, 2003 Page 2 of2 '\ } Rule 4 of Conservation Orders Nos. 471, 457 A, and 484 is amended to provide that approval of the Prudhoe Bay Unit Western Operating Metering Plan is permanent. Rule 4 of Conservation Orders Nos. 471, 457A, and 484 is amended to require technical process review meetings to be held at least annually. Midnieht Sun Oil Pool (CO 452) Rule 7 of Conservation Order No 452 ("CO 452"), approved November 15, 2000, requires revision to conform to the allocation procedures of the approved Prudhoe Bay Unit Western Operating Metering Plan, and is amended as follows: CO 452 - Rule 7 Common Production Facilities and Surface Commineline a. Production from the Midnight Sun Oil Pool may be commingled with production from Prudhoe Bay, and other oil pools located in the Prudhoe Bay Unit in surface facilities prior to custody transfer. The Prudhoe Bay Unit Western Operating Metering Plan, described in the letter dated April 23, 2002 and detailed within the "Prudhoe Bay Unit (PBU) Western Satellite Production Metering Plan - Policies and Procedures Document" dated August 1, 2002 is approved for allocation of production from Midnight Sun Wells. All Midnight Sun wells must use the Gathering Center 1 well allocation factor for oil, gas, and water. All wells must be tested a minimum of once per month. All new Midnight Sun wells must be tested a minimum of two times per month during the first three months of production. The Commission may require more frequent or longer tests if the allocation quality deteriorates. Technical process review meetings shall be held at least annually. The operator shall submit a monthly report and file(s) containing daily allocation data and daily test data for agency surveillance and evaluation. b. c. d. e. f. DATED at Anchorage, Alaska, nunc pro tunc August 11,2003. ~~: . n17, C-:/'?OA-Ø-/{-i\iX -~ sarah Palin \J Chair ') ') FRANK H. MURKOWSKI, GOVERNOR AI¡ASIiA OILAlWD GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE ACTION NO. 457A.Ol ADMINISTRATIVE ACTION NO. 471.01 ADMINISTRATIVE ACTION NO. 484.01 ADMINISTRATIVE ACTION NO 452.01 Mr. Gil Buehler PBU Satellite Engineering Manager BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, AK 99519-6612 Re: PBU Western Satellite Production Metering Plan Amendment of Conservation Orders 457 A, 471, 484, and 452 Dear Mr. Beuhler: By letter dated April 23, 2002, BPXA requested approval of the Prudhoe Bay Unit Western Operating Metering Plan for allocation of production from satellite oil pools in the Western region of the Prudhoe Bay Unit. The Commission conditionally approved this plan for one year beginning August 1, 2002. Rule 4 of Conservation Order No. 471 for the Borealis Oil Pool, Conservation Order No. 457 A for the Aurora Oil Pool, and Conservation Order No. 484 for the Polaris Oil Pool addresses the metering and allocation of production under this plan. Continued authorization of metering and allocation procedures was to be determined at a hearing to be scheduled no later than July 31, 2003. BPXA provided the Commission with a detailed metering and allocation procedures document on August 1, 2002. BPXA provided the Commission with a thorough review of the allocation performance of the Prudhoe Bay Unit Western Operating Metering Plan at technical meetings held on May 22 and June 5, 2003. In addition, well test and allocation information of all production fluids within the GC 1 and GC2 areas were provided as required. The Commission finds that continued use of the Prudhoe Bay Unit Western Operating Metering Plan is appropriate and that a further hearing is unnecessary. In addition, the Commission finds that technical process review meetings, required by the Commission to take place quarterly, need only take place annually. Accordingly, the Conservation Orders 471, 457, 484, and 452 are amended as follows. Borealis Oil Pool (CO 471)'1 Aurora Oil Pool (CO 457 A) and Polaris Oil Pool (CO 484) 5CANNED AUG 2 1 2003 Mr. Gil Buehler August 11, 2003 Page 2 of2 ') Rule 4 of Conservation Orders Nos. 471, 457 A, and 484 is amended to provide that approval of the Prudhoe Bay Unit Western Operating Metering Plan is permanent. Rule 4 of Conservation Orders Nos. 471, 457 A, and 484 is amended to require technical process review meetings to be held at least annually. Midnieht Sun Oil Pool (CO 452) Rule 7 of Conservation Order No 452 ("CO 452"), approved November 15, 2000, requires revision to conform to the allocation procedures of the approved Prudhoe Bay Unit Western Operating Metering Plan, and is amended as follows: CO 452 - Rule 7 Common Production Facilities and Surface Commineline a. Production from the Midnight Sun Oil Pool may be commingled with production from Prudhoe Bay, and other oil pools located in the Prudhoe Bay Unit in surface facilities prior to custody transfer. The Prudhoe Bay Unit Western Operating Metering Plan, described in the letter dated April 23, 2002 and detailed within the "Prudhoe Bay Unit (PBU) Western Satellite Production Metering Plan - Policies and Procedures Document" dated August 1, 2002 is approved for allocation of production from Midnight Sun Wells. All Midnight Sun wells must use the Gathering Center 1 well allocation factor for oil, gas, and water. All wells must be tested a minimum of once per month. All new Midnight Sun wells must be tested a minimum of two times per month during the first three months of production. The Commission may require more frequent or longer tests if the allocation quality deteriorates. Technical process review meetings shall be held at least annually. The operator shall submit a monthly report and file(s) containing daily allocation data and daily test data for agency surveillance and evaluation. b. c. d. e. f. gDATED:;Õ;laSkaand~3' --sarãh alin Y Daniel ¿amount, Jr. Chai\) Commissioner BY ORDER OF THE COMMISSION ) ) FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA. OIL AlWD GAS CONSERVA.TION COMMISSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Corrected ADMINISTRATIVE APPROVAL NUMBERS C0457A.OO4 and AI022B.OO2 Mr. Gil Beuhler G PB Waterflood Resource Manager BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, AK 99519-6612 Dear Mr. Beuhler: By letter dated December 6, 2004, BP Exploration (Alaska), Inc. ("BPXA") requested authorization to extend current pilot miscible injection (MI) operations in Aurora Oil Pool ("AOP") Wells 8-112, 8-110 and 8-116 ("Pilot Operations"). The Commission on May 11 gave approval for Pilot Operations through December 31,2004. Due to operational delays and 10w injection rates, only 8-110 has been on miscible gas injection, and only 1/3 of the total miscible injectant volume planned for the Pilot Operations has been injected. You have stated that, with favorable conclusive results from the Pilot Operations, you will apply for a larger scale project. The Commission finds that the requested change will 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. The Commission approves continuation of MI injection through 8eptember 30, 2005 into AOP Wells 8-112, 8-110 and S-116, subject to the conditions, limitations, and requirements set out in AIO 22B and CO 457 A and statewide regulations under 20 AAC 25 (to the extent not otherwise superseded by AIO 22B and Conservation Order 457 A). It is a condition of this approval that BPXA provide written documentation to the Commission of the results of the Pilot Operations no later than October 31, 2005. ,-~ (/JD ~- orage, Alaska and dated JanU~10' 00 . .. ~. Y~.'.;....!:...~../'.~.f.".'.~....~...f..f....:.':~!.;.i~.~.;~.'~'.'.!.:~.'.~"'..?'.'.'.::.':(~\ ,') CJ I {""" \A¡ \ ¡ , I: " "--C' I . I '. ~:JIßt'~~~.~:-~~-~.~\~;:.!<\\ ~ '{ H ~~~~. .".¡. ."."'" """,,. ,., , ~ .~ ~..- '~~~~Jinf1~ \}~~þ~.~¡ ~ r~"j.~,. . ~t "/, ,~'.~"'~~' ~ Jo . rman aniel T. Seamount Jr.~, ..... q ¿? '?;~ :(~"";<':~"~.>.~:,;:;:i\ß- ~ ¡ h . C .. ' \ \,~. \ ~ ~;.;.;; ú{.~7 ';~i~:-('''-? J mrman omilllSSloner \';:" '~.í . !;;-'..:~. \<..,.~¡,,"; ¡,~ \~~~~\'~'!~f~~ ') ) ~ æ/Æ FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA. OIL AlWD GAS CONSBRVATION COMMISSION / 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907).279-1433 FAX (907) 276-7542 January 14,2005 Mr. Gil Beuhler GPB Waterflood Resource Manager BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, AK 99519-6612 Dear Mr. Beuhler: This replaces the Administrative Approval that was issued on December 22, 2004. The only substantial correction is in the last sentence, which corrects the date that BPXA is to provide written documentation to the Commission of the results of the Pilot Operations. Sincerely, ..-.~~ . "\ vL- \...., ('----) ¡ I '~'~'.6clJv~~C~~ . J y J .~ok)Jhbie Special Staff Assistant 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 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 David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 Robert Gravely 7681 South Kit Carson Drive Littleton, CO 80122 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 John Levorsen 200 North 3rd Street, #1202 Boise,ID 83702 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 Schlumberger Drilling and Measurements 2525 Gambell Street #400 Anchorage, AK 99503 David Cusato 200 West 34th PMB 411 Anchorage, AK 99503 Ciri Land Department PO Box 93330 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Jack Hakkila PO Box 190083 Anchorage, AK 99519 Darwin Waldsmith PO Box 39309 Ninilchick, AK 99639 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 Penny Vadla 399 West Riverview Avenue Soldotna, AK 99669-7714 Cliff Burglin PO Box 70131 Fairbanks, AK 99707 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 North Slope Borough PO Box 69 Barrow, AK 99723 Various AA's ) ) Subject: .Various...AA's From: Jody Colombie <jody - colombie@admin.state~ak.us> Date: Fri, 14 Jan 200516:19:21 -0900 'Fø :41ictisclos~ct- I'eçipients:; BCC:Cyp.!mä I3Mciyer<bI'ênLm.ciVer@admin.statê~ak.û$?~.. R.oþertpMiritz -<rQbëri_mþ1tz@law.st~t~.ak.us>, ChristineHans~n<~.l1ah~el1.@iogcc~state.ok.us>~.. Te!tiefIÜþble %b.l1bÞletl@þp.c()1l1.> ,Sol1Qra St~Wt11afl<Ste\YPi~SD@BP .00111> ,Sc()tt L\tGaÏri1UY T£lylor ~~taylQr@alásl<a.net:>,stan.~t(j<stanekj@tlitoç~Lc()111»;.. ~çplaWf~qöl~w@ttl1st~þs.()tg?,.ros~r~g~ct~l~ %rp$~r~gsdale@gci.llet:>, tmjI' l<!ID1jrl@~òl.êqrrïè~jÞ~!ctdle<jþriddle@ri1ár~!h()rioil.còri1?,.. ~l1~Ï1eg <s~?l1êg@êvetgreêngas~c9~ ,jdwlingtOl1<jdilI'lil'igtþn@fØtt(sfoiLcom> ,rteIsÓn <1qiels()n@pç!r()I~U1rii1ews.cþt}J.?,C þogdy <:9bQ<id.Y@lJsibenì~com>, Mark Dalton <qtþar~.çia.ltQn@hdtinc.co1.n>,Sh~n.ri()n DOmi~tty ~sl1atmon.dÓtlI1~Uy@collQçophillips.çonl,?, "Ma,rl<.p. \V'°rcester"%l11ark.p~wòtcesteI'@çÓÏ1òcophillipš;còm:>, I3ob-<bôp@inletkeeper.()I'g?, wdv -<WdY@clri+.state~ak.u~?,tjtftjr@dnr.state.ak.4s? ,bÞri tçl1:<:bbri!cl1@al?Ska.net>,trljti~lšoll <:rrtjnêls()n@piliving~rtz,com>, Çl1arles (YDoImell<çhafles.o'donnell@veco.colll», "Randy L. Skilletij" <SkilleRL@BP.ç()m>,"Dëbörah J; J ones"<J ÓIiesp6@I~P . com:>, "}>al1l9. . .Hy~ttlt fliy~ttpg@BP .cÒ111:>' .." $tevþJjR. .Rös~bþI'g"<Rpsšbe~S @Bg~cÓfl1?~Lois. flois@inlétkeepër.()~g:>, pan :erö~~<kuacnews@kuåç.org>, G()rdon PÓspisit<gq~pisG@I3P ;COl11>,> "Jfl'ån.cišS~S()l11111ër' <SommeI'FS@BP~côm.> ~MikeISchu1tz<Mikel.Sêhtilti@BP.êotn»~ ?Nick Y{... Glqyër" <GloverNW@BP.com>, "Daryl J. Kleppin" <KleppiDE@BP.corp?,'UanetD.platt" <q'plattJD@BP.çom:>, "Ro~.anne M;JacoQsen" <:JacQbsR.M:@~r.com», ddotil(el <d.donk:ël@cP.rr.c0111?' C()llil1~Ñ1ooþt<:c()llins~mount@r~venue.state.ak.uš>~ 111ckay <mckay@gci.net>,..:eår'bara.F Fulllllet..<barbara~f.fullmeI'@9011ocophillips.com>,. bòcastwf <bocastwf@bþ~colll>~Cha.rlësB~ker <barkër@ûsgs~goV?' qoug-ischtiltie <doug..ßcþultze@xtoetiergy;coIll> ,HankA~fotd <ha,nk:~alforc.t@exx()l1l11obiLcom.> , Mark KØvac <yesnol@gci.l1et>,gspföff<gspfoff@aurotapQwer.col11>,QreggNady<grëggmad.y@sliell.com>, Ft~9Stëþqèf::ftèd.steþêe@stä-tè.sct.ils~, .I'qrÓtty<qrçrÓt1:Y@ChQm.com>, j ej ones <j ~jôll~š@a"Ur()rapoWer.colD> ,dapa.(d~pa@~I?S~a.net:>~ jrQq~rick<jr0gerick@gci.n~t> ,.. ~yaI1cy <qeyançy@sëal.;tit~.net>," Jam.ësM. Ruud '~<jameš~l11iru.ud@êÓïiocophinìps.com:>/I3ï1t Liv~ly <rrtapalaska@ak.Iie~>, Jah <j ah@dnr.sta,te.ak.us>,K.iliiE .Olsoïi<:kl.lr1::- olson@legis.state.ak.us>, buonöje.<buonoje@bp.com.>,Mark Hanley <markihat1ley@ariadarko.com>, lören~.Jemal1 <loren_lem.all@gov.statë.ak.tts>,. Julie Houle<julie--l1otlle@c.tnr.state,ak.us>,Jph.nWK.ätz <jwkatz@ssö.QJ;'g>, SuzallJHill%suzari_hill@dec.státe.ak.us>, tablerk. <tabler}<:@unocaLcpm>, Brady <brady@aoga.ol'g>,...Brian Havelock<beh@dnr.state.ak;us>,bpöpp <bpopp@bqtöugh.kel1ai.£lk.u$>, Jim Whìte <jìniwmte@sabcIT.com?-,"Jo@S.ijaworth" <j()hn.s.haworih@exxonmobiLcom>, marty <marty@rkindustriaLco111.>, ghammol1s <ghammons@ao1.com>,rtnclean<rmc1ean@pobox.alaska.net>, mlan 7200 <mlan 7200@åoLcom>, 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>, Bill Miller <Bill_Miller@xtoalaska.com>, Brandon Gagnon <bgagnon@brenalaw.com>, Paul Winslow <pmwinslow@forestoi1.com>, Garry .Catron <catrongr@bp.com>, Sharmaine Copeland <copelasv@bp.com>,Kristin Dirks <kristin - dirks@dnr.state.ak. us> ,KaynellZeIllan<kjzemari@marathonoi1.com>,]öh.i1Tower <John.Tower@eia.doe.gov>, Bill Fowler <Bill- Fowler@anadarko.COM>, Vaugh.i1 Swartz <v~ughn.swartz@rbccm.com>, ScotlCranswick <scottcranswick@mms.gov>,Brad McKim <mckimbs@BP.com>, Steve Lambe <lambes@unoca1.com>, jack newell <jack.newell@acsalaska.net>, . James Scherr <James.Scherr@mms.gov>, david .roby lof2 1/14120054: 19 PM Various AA's ) ) 2of2 1/14/20054:19 PM ) FRANK H. MURKOWSKI, GOVERNOR A..,A.SIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL NUMBERS C0457 A.OO4 and AI022B.OO2 Mr. Gil Beuhler GPB Waterflood Resource Manager BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, AK 99519-6612 Dear Mr. Beuhler: By letter dated December 6, 2004, BP Exploration (Alaska), Inc. ("BPXA") requested authorization to extend current pilot miscible injection (MI) operations in Aurora Oil Pool ("AOP") Wells S-112, S-110 and S-116. Approval was given by the Commission on May 11 for pilot operations through December 31, 2004. Due to operational delays and low injection rates, only S-11 0 has been on miscible gas injection, and only 1/3 of the total miscible injectant volume planned for the pilot has been injected. You've stated that, with favorable conclusive results from the pilot, you will apply for a larger scale project. The Commission finds that the requested change will 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 The Commission approves continuation of Ml injection through September 30, 2005 into AOP Wells S-112, S-110 and S-116, subject to the conditions, limitations, and requirements set out in AlO 22B and CO 457 A and statewide regulations under 20 AAC 25 (to the extent not otherwise superseded by AlO 22B and Conservation Order 457 A). It is a condition of this approval that BPXA provide written documentation of the results of the pilot no later than October 31, 2004. age, Alaska and dated December 22, 2004 fJJ~ Daniel T. Seamount, Jr. Commissioner Orders ) Subject: Orders From: Jody Colombie <jody - colombie@admin.state.akus> Date: Thu, 23 Dee 2004 06:52:48 -0900 To: undisclosed-recipients:; BCC: Robert E Mintz <robert_mintz@law.state.ak.us>, Christine Hansen <c.hansen@iogcc.state.okus>, Terrie Hubble <hubbletl@bp.com>, Sondra Stewman <StewmaSD@BP.com>, Scott & Cammy Taylor <staylor@alaska.net>, stanekj <stanekj@unocal.eom>, ecolaw <ecolaw@trustees.org>, roseragsdale <roseragsdale@gci.net>, tnnjrl <trmjr 1 @aol.com>, jbriddle <jbriddle@marathonoil.com>, rockhill <rockhill@aoga.org>, shaneg <shaneg@evergreengas.com>, jdarlíngton <jdarlington@forestoi1.com>, nelson <k:nelson@petroleumnews.com>, cboddy <cboddy@usibelli.com>, Mark Dalton <mark.dalton@hdrinc.com>, Shannon Donnelly <shannon.donnel1y@conocophillips.com>, "Mark P. Worcester" <markp.worcester@.conocophillips.com>, Bob <bob@inletkeeper.org>, wdv <w'dv@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>, "Paul G. Hyatt" <hyattpg@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" <SolnmerFS@BP.com>, Mikel Schultz <Mikel.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>, Collins Mount <collins - mount@revenue.state.ak.us>, mckay <mckay@gci.net>, Barbara F Fullmer <barbara.ffullmer@conocophillips.com>, bocastwf <bocastwf@bp.com.>, Charles Barker <barker@usgs.gov>, doug_schultze <doug_schultze@xtoenergy.com>, Hank Alford <hank.alford@exxonmobiLcom>, Mark Kovac <yesnol@gci.net>, gspfoff <gspfoff@aurorapower.com>, Gregg Nady <gregg.nady@shell.com>, Fred Steece <fred.steece@state.sd.us>, rcrotty <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>, Kurt E Olson <kurt_olson@legis.state.ak.us>, buonoje <buonoje@bp.com>, Mark Hanley <mark_hanley@anadarko.com>, 10ren_Iernan <loren_leman@gov.state.akus>, Julie Houle <julie_houle@dnr.state.ak.us>, John W Katz <jwkatz@sso.org>, Suzan J Hill <suzan_hiH@dec.state~ak.us>, 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@exxonmobil.com>, marty <marty@rkindustrial.com>, ghamrnons . <ghammons@ao1.com>, rmc1ean <rmc1ean@pobox.alaska.net>, mkm7200 <mkm7200@aol.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>, Bin Miller <Bill- Miller@xtoalaska.com>, Brandon Gagnon <bgagnon@brenalaw.com>, Paul Winslow <pmwinslow@forestoil.com>, Garry Catron <catrongr@bp.com>, Sharmaine Copeland <copelasv@bp.com>, Kristin Dirks <kristin_dirks@dnr.state.ak.us>, Kaynell Zeman <kjzeman@marathonoil.com>, John Tower <John.Tower@eia.doe.gov>, Bill Fowler <Bill_Fowler@anadarko.COM>, Vaughn Swartz <vaughn.swartz@rbccm.com>, Scott Cranswick <scott.cranswick@mms.gov>, Brad McKim <mckimbs@BP.com>, Steve Lambe <lambes@unocal.com>, jack newell <jack.newell@acsalaska.net>, James Scherr <James.Scherr@mms.gov>, david roby lof2 12/23/20046:53 AM Orders 20f2 ) <David.Roby@mms.gov>, Tim La\vlor <Tim - Lawlor@ak.blm.gov>, Lynnda Kahn <Lynnda_Kahn@fws.gov>, Jerry Dethlefs <Jerry.C.Dethlefs@conocophillips.com>, Jerry Dethlefs <n1617@conocophillips.com>, Cynthia B Mciver <bren_mciver@admin.state.ak.us> ..---....----.. - --'---'1.'''--''.'' .--"...,.. ''''':_~. ~ -~ .,......,,:..":'..- .. , C0457 A.004.pdf ' Content-Type: applicatio~~df ! Content-Encoding: base64 ' . ---~". ,. ._--~---~ n _.-------, -_..-. -.,---..------ "---~~- . -----~-,_., --~'--' "__'h' "~ ..-.--. "-'--.- .._--.- ..~" --T' . ~~~-_. . ~.,'_L__- -~_. ",------- ': . Content-Type: application/pdf ; :C0543.pdf . , Content-Encoding: base64 12/23/20046:53 AM 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 David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 Robert Gravely 7681 South Kit Carson Drive Littleton, CO 80122 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 John Levorsen 200 North 3rd Street, #1202 Boise,ID 83702 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 Schlumberger Drilling and Measurements 2525 Gambell Street #400 Anchorage, AK 99503 David Cusato 200 West 34th PMB 411 Anchorage, AK 99503 Ciri Land Department PO Box 93330 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Jack Hakkila PO Box 190083 Anchorage, AK 99519 Darwin Waldsmith PO Box 39309 Ninilchick, AK 99639 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 Penny Vadla 399 West Riverview Avenue Soldotna, AK 99669-7714 Cliff Burglin PO Box 70131 Fairbanks, AK 99707 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 North Slope Borough PO Box 69 Barrow, AK 99723 I1l (,t I '/~ c:K:.- / Pj;~cj ::t:t: v. ') BP Exploration (Alaska), Inc. 900 East Benson Boulevard Post Office Box 196612 Anchorage, Alaska 99519-6612 Telephone (907) 564 581 bp December 6, 2004 Jane Williamson .,Bob Crandall Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AI( 99501 RECEIVED DEC 0'82004 RE: Aurora EOR Pilot extension Alaska Oil & Gas Cons. Commission Anchorage We respectfully request permission to extend the current EaR pilot for Aurora injection wells S-112, S-110, and S-116 until June 30, 2005. The extension beyond 2004. is needed to complete the originally proposed pilot and allow the project to be bridged until a full- field EaR expansion can be applied for and approved next year. Due to operational delays and low injection rates, only S-11 0 has been on miscible gas injection with 30 of the proposed 90 MMSCF injected to date. Based on results so far it is clear that 3 months injection into each well will be required to fully evaluate each of the pilot wells. Please call Jim Young 564-5754 if you have any questions. Sincerely, ~~~~ ",..-1' ..-..r. _.,.,~ /,./" '. ~ Gil Beuhler GPB WEST Manager Attachments CC: Mark Vela (ExxonMobil) Dan Kruse (CP AI) Bradley Brice (Forest Oil) Steve Wright (Chevron-Texaco) ::t:t:: ~ BP Exploration (Alaska), Inc. 900 East Benson Boulevard Post Office Box 196612 Anchorage, Alaska 99519-6612 i Telephone (907) 564 581 !J~ bp ) :if. ",,,..1 ) ) . April 26, 2004 Jane Williamson Bob Krandall Alaska Oil and Gas Conservation Commission' 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 RE: Proposed Aurora EOR Pilot In order to enhance water injection rates and fine-tune enhanced oil recovery benefits, a 4 to 6 week pilot is proposed for Aurora injection wells S-112, S-110, and S-116. Attached are details and supporting info for the proposed test which will help to provide justification for full EOR expansion into 2 new areas within the Aurora field. Please call Jim Young 564-5754 if you have any questions. Sincerely, ~~ Gil Beuhler GPB Satellites Manager Attachments CC: Mark Vela (ExxonMobil) Dan Kruse (CP AI) Leonard Gurule (Forest Oil) Steve Wright (Chevron-Texaco) ('''I'. f\1f\iE~'r- ¡U¡e..f; i f!: 200~ t>~' (~l :'-è t \j ~~" :.00"5 tJ ~ \~~ J~ ,:)! - ,~"W (- o~~ p~. y RECEIVED APR 2 8 2004- Alaska Oi\ & Gas Cons. Commissíon Anchorage :q .:iOiI .'tI' ~ ') VRR > 1 to be obtained is the goal, and a pressures in the injectors as well as the offset producers. will be obtained and analyzed to verify results. Analysis of Reservoir Pressure Surveys within the proposed Pilot areas Two pressure maps covering the proposed pilot area wells are shown below. Refer to 2003. ASR for details on pressure surveys and analysis. 5985000- 5980000- \ \ 605000 610000 615000 620000 625000 Figure 1 Simulation based dymamic pressure map, psig at 6700' ss AOP datum, April'04 5990000-- 5985000-- 5980000-- 3300 '3000 2700 605000 610000 615000 620000 625000 - 2400 Figure 2 Static Pressure map with last SBHP date, psig at 6700' ss AOP datum 2 Sf" II¡, t\!t:\IiE~- .--\ ", \,¡!fj'w'd'¥J =L 1 6 2004 ::t:I:: w STATE OF ALASKA ADVERTISING ORDER SEE BOTTOM FOR INV~ ~.DR~' : . , . - fF. ,. I ~.-...... '.;11:. - . - ~',:-' ~:. ".. '-")--.. NOTICE TO PUBLISHER ") INVOICE. _I BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO." ".11FIED AFFIDAVIT OF PUBLICATION (PART2 OF THIS FORM) WITH ATTACHED COpy OF ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE ADVERTISING ORDER NO. AO-02314046 F AOGCC R 333 W 7th Ave, Ste 100 0 Anchorage, AK 99501 M AGENCY CONTACT Jody Colombie PHONE DATE OF A.O. May 5, 2003 PCN ¿ Anchorage Daily News POBox 149001 Anchorage, AK 99514 (907) 793. -1 ??l DATES ADVERTISEMENT REQUIRED: May 6, 2003 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: Type of Advertisement X Legal D Display Account #STOF0330 Advertisement to be published was e-mailed D Classified DOther (Specify) SEE ATTACHED PUBLIC HEARING SEND INV()I~.I<~..Jl~teqç~r~: AOGCC. 333 W. 7th Ave., Suite 100 « ..'.;.. .., ':.'TO':':; ',.';' .,:.->;t"-,,.~">7~>'::'. Anchorage, AK 99501 REF TYPE NUMBER AMOUNT 1 VEN DATE PAGE 1 OF TOTAL OF 2 PAGES ALL PAGES$ COMMENTS 2 ARD 3 4 02910 FIN AMOUNT SY CC PGM LC ACCT FY NMR DIST LlO 03 02140100 73540 2 3 4 ~ REQUISITIONED BY: S) l,/j rf'. I ' 17 ¥ ..\Þ( O~.L----- / ( \ DIV~O~<-t ./ "" 02-902 (Rev. 3/94) Publisher/Original Copies: Department Fiscal, Department, Receiving AO.FRM ') Notice of Cancellation of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: Proposed Amendment of Conservation Order No. 457 (Aurora Oil Pool, Prudhoe Bay Field) and Proposed Revocation of Conservation Order No. 98-A (Prudhoe Bay Kuparuk River Oil Pool, Prudhoe Bay Field) The public hearing on this proposal that was previously scheduled for May 8, 2003, at 9:00 a.m., has been CANCELED. ~/-y~ÞA Randy Ruedrich Commissioner Published Date: May 6, 2003 AO # 02314046 n.C. rtU VI UCl Subject: Re: Ad Order Date: 05 May 200309:53:43 -0800 From: Legal Ads Anchorage Daily News <legalads@adn.com> To: Jody Colombie <jody - colombie@admin.state.ak.us> ') L, () Hi Jody: Following is the confirmation information on your legal notice. Please let me know if you have any questions or need anything further. Account Number: STOF 0330 Legal Ad Number: 793048 Publication Date(s): May 6, 2003 Your Reference #: 02314046 Total: $39.48 Thank You, Kim Kirby Anchorage Daily News Legal Classified Representative E-Mail: legalads@adn.com Phone: (907) 257-4296 Fax: (907) 279-8170 On Friday, May 2, 2003, Jody Colombie <jody_colombie@admin.state.ak.us> wrote: >Please publish the attached on Tuesday may 6th. > >Jody loft 5/5/2003 11 :29 AM 'nChOrage 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 ŒARGES#3 CHARGES #4 CHARGES #5 TOTAL 793048 05/06/2oæ 02314046 þTOF0330 $39.48 $39.48 $0.00 $0.00 $0.00 $0.00 $0.00 $39.48 STATE OF ALASKA THIRD JUDICIAL DISTRICT Kimberly A. Kirby, 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 Anchora~e, Alaska, and it is now and durin~ 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. N6ticeof¡Cancellatioll' of . Public-Hearing." . ST ATEO:FA~AsKA . Àld~kajj'iT'àhi:fGas' , Cons.ervanonq~rijrtl'i"Ssjön Signed ;¿~bú{ / ¡Jff Subscribed and sworn to me before this date: .~~~ . ~ .. , R e;pr.6 posed'Arne'l1d- m~nt ofCon~er\lcit1on:Qr-: . der"No.~{Au r'órÖ.Qi I. . Pool,Pr;u(lfió~;BáYF¡elclr .' 'aiídPropó~edrRevocò-' . tlOriofCQnservatiO!1' 01"- dèrNÔ~:-98;èA[pryd h.oe Bay KupårukCRiverQil ,Poo;:,Pruc:lI1ÔéBciyj=ield) . The'public'hearing on th is, proposaUhat was.previ- 'ouSly scheduled fÓr May ,S;2003,dat9.;00a.m;; has' , beenCANCE;LED~. RàndyRuedrich ':Com~issiori~r fJ ..' . \ . : . '.' ",~' . . 'Publish: May 6, 2003<" Notary Public in and for the State of Alaska. Third Division. Anchorage, Alaska MYCOMMISSIONEXPlRE: ~~~ {çt'~~/~ /J .~~ ~~<&/. \\\; ...\ o\E 8. \." O!Þ~ . . '. ~.:.~ ~~.. --- '.~ ~ S :'y.OTA/fj,:.-'S ,,-. --. . ~ - . 1:1.. '- ~ : .-cjBLtC : ~ -~"~ --;./;:1g~ -'~Å. . ~.."'" ~ ':~OF .' ':\' ~ '" . . '.~dct\'\ :,,1/.1 Exlie&J"'~,\\ :/})J))J)}1" RECEIVED MAY 2 7 2003 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ADVERTISING ORDER . .. '. NOTICE TO PUBLISHER " ADVERTISING ORDER NO. INVOICE )r BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO.. )rIFlED AO 02314046 AFFIDAV,., ..J' PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED CO," .' OF - ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE . ".':. :S~'.~~~~:r~~'.~~~'~~.::"." F AOGCC R 333 West 7th Avenue, Suite 100 0 ~chorage,AJ( 99501 M ¿ ~chorage Daily News POBox .149001 ~chorage, AJ( 99514 AGENCY CONTACT Jony C010mbie PHONE DATE OF A.O. M~y 5, ?003 PCN (907) 793 - t ??1 DATES ADVERTISEMENT REQUIRED: May 6, 2003 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: Account #STOF0330 AFFIDAVIT OF PUBLICATION REMINDER United states of America State of ss 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 state of and that the advertisement, of which the annexed is a true copy, was published in said publication on the day of 2003, and thereafter for - consecutive days, the last publication appearing on the - day of . 2003, and that the rate charged thereon is not in excess of the rate charged private individuals. Subscribed and sworn to before me This - day of 2003, Notary public for state of My commission expires 02-901 (Rev. 3/94) Page 2 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. and AO.FRM PUBLISHER Cancellation of Public hearing ) Subject: Cancellation of Public hearing Date: Fri, 02 May 2003 17: 17 :31 -0800 ~ From: Jody Colombie <jody - colombie@admin.state.ak.us> Organization: Alaska Oil and Gas Conservation Commission To: Robert E Mintz <robert_mintz@law.state.ak.us>, John Tanigawa <JohnT@EvergreenGas.com>, Terrie Hubble <hubblet1@bp.com>, Duane Vaagen <duane@fairweather.com>, Sondra Stewman <StewmaSD@BP.com>, stanekj <stanekj@unocal.com>, ecolaw <ecolaw@trustees.org>, roseragsdale <roseragsdale@gci.net>, trmjr 1 <trmjr 1 @aol.com>, jbriddle <jbriddle@marathonoi1.com>, rockhill <rockhill@aoga.org>, shaneg <shaneg@evergreengas.com>, rosew <rosew@evergreengas.com>, jdarlington <jdarlington@forestoi1.com>, nelson <nelson@gci.net>, cboddy <cboddy@usibelli.com>, "mark.dalton" <mark.dalton@hdrinc.com>, "shannon.donnelly" <shannon.donnelly@conocophillips.com>, "mark. p. worcester" <mark.p. worcester@conocophillips.com>, "jerry.c.dethlefs" <j erry.c.dethlefs@conocophillips.com>, arlenehm <arlenehm@gci.net>, bob <bob@inletkeeper.org>, wdv <wdv@dnr.state.ak.us>, tjr <tjr@dnr.state.ak.us>, bbritch <bbritch@alaska.net>, greg-noble <greg-noble@blm.gov>, mjnelson <mjnelson@purvingertz.com>, burgin - d <burgin- d@niediak.com>, "charles. o'donnell " <charles.o'donnell@veco.com>, "Skillern, Randy L" <SkilleRL@BP.com>, "Dickey, Jeanne H" <DickeyJH@BP.com>, "Jones, Deborah J" <JonesD6@BP.com>, "Hyatt, PaulG" <hyattpg@BP.com>, "Rossberg, R Steven" <RossbeRS@BP.com>, "Shaw, Anne L (BP Alaska)" <ShawAL@BP.com>, "Kirchner, Joseph F" <KirchnJF@BP.com>, "Pospisil, Gordon" <PospisG@BP.com>, "Sommer, Francis SIt <SommerFS@BP.com>, "Schultz, Mikel" <Mikel. Schultz@BP .com>, "Jenkins, David pIt <JenkinDP@BP.com>, "Glover, Nick WIt <GloverNW@BP.com>, "Kleppin, Daryl J" <KleppiDE@BP.com>, "Platt, Janet D" <PlattJD@BP.com>, "Wuestenfeld, Karen S" <WuesteKS@BP .com>, " Jacobsen, Rosanne M" <J acobsRM@BP .com>, ddonkel <ddonkel@cfl.rr.com>, collins_mount <collins - mount@revenue.state.ak.us>, mckay <mckay@gci.net>, "barbara.f.fullmer" <barbara.£fullmer@conocophillips.com>, bocastwf <bocastwf@bp.com>, cowo <cowo@chevrontexaco.com>, ajiii88 <ajiii88@hotmail.com>, doug_schultze <doug_schultze@xtoenergy.com>, "hank.alford" <hank.alford@exxonmobi1.com>, yesno 1 <yesno 1 @gci.net>, "john. w.hanes" <john. w.hanes@exxonmobil.com>, gspfoff <gspfoff@aurorapower.com>, "gregg.nady" <gregg.nady@shell.com>, "fred.steece" <fred.steece@state.sd.us>, rcrotty <rcrotty@ch2m.com>, jejones <jejones@aurorapower.com>, dapa <dapa@alaska.net>, jack _laasch <jack _laasch@natchiq.com>, jimwhite <jimwhite@satx.rr.com>, wrholton <wrholton@marathonoil.com>, "richard.prentki" <richard.prentki@mms.gov>, eyancey <eyancey@seal-tite.net>, markleypa <markleypa@alyeska-pipeline.com>, "jeffrey. walker" <jeffrey. walker@mms.gov>, tressler <tressler@ciri.com>, claire - caldes <claire - caldes@fws.gov>, jacobsenje <jacobsenje@alyeska-pipeline.com>, pcraig <pcraig@gci.net>, babsonandsheppard <babsonandsheppard@earthlink.net>, "james.m.ruud" <james.m.ruud@conocophillips.com> ] of2 5/2120035:] 7 PM Cancellation of Public hearing ) "james.m.ruud" <james.m.ruud@conocophillips.com> I.."'''_N___'__-",._"----,._._.".",--"",,,-,,---,,--,,----,,----"--_w_w,'M',W"",_"",,,'_m_,__-"-'""-----__,""'M'_N,_"-.---_w_-~__,_.M,_""..""m',.",,_,-,,---' INotice of Cancellation of Aurora Public Hearing.doc Name: Notice of Cancellation of Aurora Public Hearing.doc Type: WINWORD File ( applicationlmsword) base64 f .N "'" ,,,,w ';.' Name: Jody~~~lombie.~cf n. d 1 b' f1, Type: VCard (text/x-vcard) ¡ UJo y co om le.VC ~ Encoding: 7bit ~ .".. ,~-"" "...._",,"'" -.... j ~~~~~~~!~~~:" Ca;?~~?r J?~~~~~?,~~~~j 20f2 5/2/2003 5:17 PM Notice ) ') Subject: Notice Date: Pri, 02 May 2003 17:15:57 -0800 , From: Jody Colombie <jody_colombie@admin.state.ak.us> Organization: Alaska Oil and Gas Conservation Commission To: Howard D Okland <howard - okland@admin.state.ak.us>, j ill- daniels@admin.state.ak.us, "Aaron Poschman, Classifieds Manager" <classifieds@gci.net> Please publish the attached notice. Jody L...............-........................................,....,.......,,,-,,,,,,',""H._''''.'''''''''''''''''''.'''''''',,,,,, .....",...",...,",'...,...."..;.......'.....;...........,.......~""""""""''''','.................",,,.....'...........'......,... """"""""""-""',"""";'"'''''''.''''''''''''''' 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Type: VCard (textlx-vcard) ;.' íUJo y co om le.VC, E dO .7b't f J nco mg. 1 , t ¡ Description: Card for Jody Colombiel "''''(''''j'''~'~''''''''''''''''''')''''''''W~t'"'"W¥..)"~.",,,,^,,~~I''>I''»:.''''WII'"~''V'''{-'¡V'",,'''''''''~:_~'~''''v->''''~'''''''''^''''u'r''''''v'''''.00.~t't',*,N\»'{"I')iI.',j0:""""""""'i1"''''''''''''''''"I1"»:-'II''1''''j'''''''''''U''J'~''''''"."....Y":~ 1 of 1 ¡ ! j ! I ! ! .....) 5/2/20035: 17 PM Ad Order ) ) Subject: Ad Order Date: Fri, 02 May 2003 17:12:29 -0800 From: Jody Colombie <jody_colombie@admin.state.ak.us> Organization: Alaska Oil and Gas Conservation Commission To: Legal Ads Anchorage Daily News <legalads@adn.com> Please publish the attached on Tuesday may 6th. Jody 1........,................ . \, ~ ,. " ., )-~ .. .'rl I. i . .t'.. . 'I . ."" .. - 1.~' . Name: ADNAd Order form.doc f ~ADNAd Order form.docf Type: WINWORD File (application/msword)~ L."_..........."~,...."..._..",,, '>,."",,"">',--,-"'".'''.'''~-''',..,.."-,......,..,..,...,J<~"...n.,,,..c,...,?..~_Ï!1.J~..:....~..~"~,..,,,?4.'~,..,,_..., .... "..J ,- -, ,,,' ,_,-"m" , '""-' "", ,.'" .,- ".--- ,,-~ - '" v , ""'""" v'" v"., ."..,. -- ,.." I.'''. r.'i"'''''-,¡,'',y.'v.''''''''''~''''v.:fM'"n¡(i',......>:tIÍ1^'>''''''>ÄV'''1'>¡'i':''XYlr.{''"Z¡,,,,,,",,,.~~.:«~..... ".v~ ~Notice of Cancellation of Aurora Public Hearing.doc Name: Notice of Cancellation of Aurora Public Hearing.doc Type: WINWORD File ( application/msword) base64 ,"""""..., "W ~h""V' ........' "w,,'~ "'V"w', ,'~ ~w..,.......,,, ''''-' V'" .... ."",, ..,,'u..~ ,._~.v-v..,,,,..,....ww... .~w_,..,., '-N"" v........" ..,..". 'N''''''''' 'v~'I-' 'h""I'" w.v .., '.'" "'''1' w~...,..,.."... ',... .....~."w. ""'W"'~" v..,.. ',,~ ," '~~"1 , ~ Name: jody_colombie.vcf ~ l,' [jjody colombie.vcÐ E Td~pe: V7b~tard (text/x-vcard) ',' r' : 'nco mg: 1 t l ,Description: Card for Jody Colombiet \.,~,",~"."..,.....~..,."....~..~~..........."._.,,....,,....""_.~,, "",-,~",-~"",,,,-,,,-,,,"..,~......_.,..,,,._,.....,...,,....."""""",,,,"'~w._-,_...-.,,..-_..............~.,,,,rm" 1 of 1 5/2/20035: 17 PM =+t 1'0 bp ) BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 April 28, 2003 Sarah Palin, Chair Randy Ruedrich, Commissioner Daniel T. Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Application for Rehearing - Area Injection Order No. 22A Response to Proposed Amendment of Conservation Order No. 457 Aurora Oil Pool - Prudhoe Bay Field Dear Commissioners: Pursuant to AS 31.05.080(a), BP Exploration (Alaska) Inc. (BPXA), as Operator of the Aurora Oil Pool (AOP) on behalf of the Aurora Owners, timely submits this application for rehearing of Area Injection Order 22A (AIO 22A) issued by the Alaska Oil and Gas Conservation Commission (the "Commission") on April 3, 2003 and responds to the Commission's April 3, 2003 notice of public hearing concerning the Proposed Amendment of Conservation Order No. 457 (CO 457) and the Proposed Revocation of Conservation Order No. 98-A (CO 98-A). BPXA respectfully submits that approval of its application for the amendment to AIO 22 is essential to enhancing ultimate oil recovery within the AOP. BPXA hereby supplements the record in response to the above matters and requests that Attachments 1 and 2 to this rehearing application be maintained as confidential pursuant to AS 31.05.035(d). This material is not information that is required to be submitted under AS 31.05.035(a), and contains trade secrets and engineering, geological and other information, and interpretations thereof. BPXA initially addresses and responds to Area Injection Order No. 22A, followed by comments in response to the proposed amendments to Conservation Order No. 457. RECEIVED APR 2 8 2003 Alaska Oil & Gas Cons. Commission Anchorage Application for Rehearin¡¡ ) AIO 22A 4/28/2003 Page 2 ') I. Response to Area Injection Order No. 22A A. Background On December 9, 2002 BPXA requested an Order from the Commission modifying Area Injection Order No. 22 to authorize the underground injection of miscible injectant ("MI") for enhanced oil recovery in the AOP. On March 4,2003 the Commission conducted a hearing on BPXA's request and on April 3, 2003 issued its decision denying the request (Area Injection Order No. 22A) without prejudice to BPXA's right to renew the application at a later date. The Commission's April 3, 2003 Order indicated that the Commission felt certain issues were outstanding. BPXA hereby responds to the Order and supplements the record with the materials and information concerning AOP well pressures and additional information on the current reservoir management plan, including depletion strategy, which is contained herein and in Attachments 1 through 4. BPXA believes this material provides a more comprehensive understanding of AOP reservoir pressures and depletion strategy than is indicated by certain findings and conclusions contained in the Order. Before addressing the conclusions contained in AIO 22A, BPXA provides the following information related to certain findings by the Commission. B. Response to Certain Findings in AIO 22A 1. Operators/Surface Owners (20 AAC 25.402(c)(2) and 20 AAC 25.403(c)(3)) This paragraph should be updated to reflect the current PBU and Aurora aligned Working Interest Owners as follows: BP Exploration (Alaska) Inc. ExxonMobil Alaska Production Inc. ConocoPhillips Alaska, Inc. Chevron U.S.A. Inc. Forest Oil Corporation 6. Injection Fluid and Rates (20 AAC 25.402(c)(9)) a.) Additional Source Water AIO 22A does not anticipate the potential that exists for using source water that may be obtained from the Prince Creek Formation in the Application for Rehearin\ ) AIO 22A 4/28/2003 Page 3 ) GC-2 area from dedicated source water production wells and used for injection into the AOP. Based upon Milne Point experiences, compatibility between the source water and the AOP Formation fluids will not be an issue. We therefore request that the Order also authorize the injection of Prince Creek source water. The following table depicts Prince Creek source water chemistry profiles from Milne Point source water wells. Well Units MPB-1 MPCFP-1 Sodium mg/I 1046 1083 Calcium mg/I 138 96 Magnesium mg/I 11 19 Barium mg/I 10 4 Chloride mg/I 1800 1820 Sulfate mg/I 4 0 Carbonate mg/I 0 0 Bicarbonate mg/I 151 140 Total Dissolved Solids mg/I 3160 3162 b.) Other Fluids AIO 22A also does not anticipate the possibility that fluids other than MI and water may be injected into the AOP at some future date during the life of the project in order to enhance recovery of oil and gas. We therefore request that the Order also authorize the injection of: 1. Solution gas associated with oil production - reinjected for reservoir pressure maintenance. 2. Tracer survey fluid - to monitor reservoir performance. 3. Non-hazardous water collected from PBU reserve pits, well house cellars and standing ponds. 11. Hydrocarbon Recovery and Reservoir Impact (20 AAC 25.402(c)(14)) Finding 11 does not capture the current technical understanding and development strategy for the AOP, which we are setting forth herein to provide context. Application for Rehearin8 ) AIO 22A 4/28/2003 Page 4 ) Recovery Mechanisms Evaluation of hydrocarbon recovery mechanisms for the Aurora Oil Pool has been the subject of ongoing analysis. The technical characteristics of considerable faulting, low initial oil rates, gas cap presence and thin oil column indicate a phased development program is appropriate and will maximize ultimate recovery. Phased development of the AOP employs three reservoir mechanisms over field life. Initial development involves a period of primary production to determine reservoir performance and drainage areas. Primary production under solution gas and aquifer influx d~ive from both floodable and non-waterflood pay intervals provides information used to improve the depletion plan, including production pressure data to evaluate compartmentalization and conformance. This drilling and surveillance data influences the next steps in reservoir development, including proper injection pattern layout. In areas where injection is indicated, secondary water flood is initiated to improve recovery by reducing residual oil saturation and maintaining well productivity via reservoir pressure support. Water injection should be initiated to maintain average reservoir pressure above 2400 psi in the flood area to ensure recovery targets are achieved. Tertiary EaR MWAG (miscible water alternating gas) provides additional oil recovery by further reducing residual oil saturation via injection of miscible gas alternating with water injection. In addition to enhancing oil recovery, injection of miscible gas provides additional reservoir benefits (Attachment 2). Slim tube study and compositional modeling indicate the Aurora reservoir fluid miscibility pressure with the Prudhoe Bay miscible gas supply is 2700 psi. Miscible gas injection will be operated to maintain miscibility between the reservoir fluid and the injected miscible gas. There will be higher pressure around injection wells and a pressure sink around the producers, which, in some cases can be below MMP. It is common practice in EOR projects to maintain pressure below MMP in the area of the producers due to several reasons: a) The low-pressure region around the producers is of generally small pore volume relative to the flooded area pore volume. This occurs for two reasons, both related to radial flow: first the pressure profile drops in a non-linear fashion near the wellbore (depending on skin) and secondly, pore volume is a function of the radius from the wellbore and increases at a rate proportional to ¡2. The variables determining the steady state pressure distribution in the reservoir include injection pattern geometry, formation permeability, formation Application for Rehearin!,j ) AIO 22A 4/28/2003 Page 5 --) b) heterogeneities, injector and producer skin damage, maximum allowable injection pressure, and artificial lift method and efficiency. Maximum sweep efficiency occurs in most reservoirs when producing bottom-hole pressure is minimized, increasing the contribution and sweep of low permeability intervals. Analysis of the miscible displacement mechanism that has been performed shows that additional oil recovery by the miscible displacement mechanism is evident in all cases studied (Attachment 2). With average reservoir pressures above the MMP, incremental EOR recovery is essentially the same even though producer region pressures below the MMP are maintained. As a consequence, reservoir management guidelines for EOR should be based on average reservoir pressure rather than producer pressure. Early implementation of the secondary and tertiary injection processes allows adequate time for producers to capture mobilized oil. Proper field management includes monitoring of productivity, GOR, water cut, pressure, of injection voidage replacement ratios and other measurements. Reservoir data gathering employed in AOP development includes: 1) an Aurora seismic survey in the year 2000, 2) basic and enhanced well log data gathering, 3) whole and sidewall core analysis of reservoir properties, 4) a single-well chemical tracer test for initial oil saturation, residual oil saturation to water, oil-water fractional flow, and residual oil saturation to miscible gas injection, 5) well flow and pressure tests, 6) surface and subsurface PVT sample gathering, 7) black oil PVT experiments, and 8) slim tube miscibility experiments. Data gathering combined with early construction of the reservoir framework and appropriate evaluation tools has been employed by a multi-disciplinary team to insure proper field management. The quality of the six types of pressure data measurements taken at Aurora have been reviewed and ranked according to accuracy. Two of the data types require corrections for insufficient shut-in time and one for wellbore pressure gradients. These corrections and the resulting pressure database are shown in Attachment 4. To determine current field average pressure, these well data are integrated with a reservoir simulation model. The Aurora field average reservoir pressure is 3142 psi as of April 2003 (Attachment 2). Application for Reheariny ) AID 22A 4/28/2003 Page 6 A high quality of match between field data and the reservoir model is evident in well-level comparisons of predicted versus measured pressures. Field Development Field development areas for the AOP have been defined by geological and reservoir performance data interpretation. Differing initial gas-oil and oil-water contacts and pressure behavior during primary production led to the definition of these field development management areas. These areas include the: 1) West Area (comprised of the previously separated V-200 and Beechey Areas) , 2) North of Crest Area, 3) South East of Crest Area, and 4) Crest Area. An effective water injection flood has been established in the West and North of Crest areas providing pressure support and reducing residual oil saturations. Other development activities include: 1) Initiating water injection into the South East of Crest area with the pending conversion of pre-produced injectors S-11 0 and S-112 to injection. Crest area production began in mid-March 2003 with startup of Aurora well S-115; well S-117 production startup is imminent. These wells' primary production performance and other well data will be considered in the evaluation of drilling a supporting injection well, i.e. the potential S-116 well. Evaluation of a local water injection booster pump to increase water injection throughput rates by raising the available Aurora wellhead water injection pressure. 2) 3) Finally, an Aurora field development case history was published in the May 2002 SPE paper 76739, "Proactive Surveillance And Phased Development Yields Promising Results From The Aurora Field 30-Years After Discovery" (see Attachment 3). This paper discusses development learnings and plan modifications made to "improve rate, increase reserves, and meet economic hurdles." C. Response to AIO 22A Conclusions The paragraph numbers below correspond with the numbered Conclusions in AIO 22A. Application for Rehearir,~) AIO 22A 4/28/2003 Page 7 ) 1. The AOP average reservoir pressure is currently 3142 psia. The Minimum Miscibility Pressure (MMP) is 2700 psia, with 90% of the field area above MMP. Areas below the MMP are limited to the producing well areas and as discussed above, low pressures near producers are expected and are consistent with mechanistic simulation models that show incremental oil recovery due to the miscible displacement enhanced oil recovery mechanism. As a result, the proposed injection of fluids will act to enhance recovery and is an integral part of the AOP Plan of Development as outlined in the response to Finding 11. 2. Concerning current reservoir pressures and MMP, all areas of the AOP are of sufficient pressure for initiating an MWAG process, beginning in the West and North of Crest areas. In the South East of Crest area where water injection has not yet begun, the current reservoir pressure is also far above the MMP. Initiating water injection in the S-112i and S-11 Oi wells will restore near-wellbore area pressure that declined during pre-production. 3. Current development plans and development strategy are fully consistent with testir:neny provided to the Commission in support of CO 457 and AIO 22. Testimony and analysis provided to the Commission in support of CO 457 indicated that primary production would be employed initially and that primary production less than 18 months would not jeopardize ultimate recovery. Updated information using current field evaluation tools, an updated reservoir description and the wells drilled in support of field development indicates that average reservoir pressures down to 2400 psi during primary production do not substantially impact ultimate recovery. This pressure corresponds with 24 months of primary production with full well density at startup; while field development has not occurred as rapidly and involves staggered production and injection timing. The current field pressure of 3142 psi is well above the limits established by these analyses. Water injection startup in the field was initiated within the 18- month period indicated to the Commission in support of CO 457 and AIO 22. Field development and operation are being conducted in a manner consistent with sound engineering and geosciences practices and with CO 457 and AIO 22. With Commission approval of the modifications requested by the Operator to AIO 22, including increasing to the maximum allowable surface water injection pressure and to allow the injection of EOR miscible gas injection, AOP oil recovery will be maximized. 4. Regarding cumulative voidage, voidage calculations made by the Commission used gas rate data that included artificial lift gas in the Application for Rehearing) AIO 22A 4/28/2003 Page 8 calculation, whereas the calculation should have been made using data that excluded artificial lift gas volumes. This may have occurred because BPXA volume accounting for November 2002 through February 2003 in wells S-1 02 and S-1 05 did not differentiate gas lift gas from formation gas. The combined total lift gas for these two wells, approximately 4,000 equivalent reservoir barrels per day, should not be included in the voidage calculation. BPXA has now reconciled this information with Commission staff. As shown in Attachment 1, over 90% of AOP voidage to date has occurred in the West and North of Crest areas that currently have a VRR greater than 1.0. In the South East of Crest area water injection startup is imminent with the two pre-produced injection wells, S-11 0 and S-112, shut-in for conversion to injection. In the Crest area, production voidage began in March of 2003 and continued primary production is necessary to determine drainage areas and injection plans consistent with the Aurora development plan described above in the response to Finding 11 included in Section B. 5. BPXA's current reservoir management strategy is discussed above and additional details are attached. 6. Current reservoir pressure and incremental EOR recovery are discussed above, with additional data regarding current average reservoir pressure set forth in Attachments 1 , 2 and 4. 7. Regarding additional well pressure measurements, the plan for acquiring additional well pressure surveillance data is included in Attachment 1. This plan addresses field-wide and area specific pressure data gathering in order to insure proper field development and operation. II. Notice of Public Hearing - Proposed Amendment of CO 457 The paragraph numbers below correspond to the proposed amendments to CO 457 included in the Commission's April 4, 2003 Notice of Public Hearing. 1. BPXA agrees that CO 457 should contain a definition of the AOP, as follows: "The AOP is defined as the accumulation of oil that is common to and correlates with the accumulation found in the interval between 67651and 77651 measured depth in the Mobil Oil Corporation Mobil- Phillips North Kuparuk State No. 26-12-12 well." Application for Rehearing) AIO 22A 4/28/2003 Page 9 '\ J 2. BPXA agrees that Conservation Order 457 should be revised to recognize the applicability of the PBU Western Satellite Production Metering Plan as described and adopted by the Commission in CO 471. 3. BPXA does not believe Rule 5 should be specifically modified as the Commission is considering. Continued production of all Aurora producers is consistent with the AOP development plan as described above and is necessary to maximize economic recovery. Surveillance pressure data gathering is planned for the field as described in Attachment 1. 4. BPXA does not believe Rule 7 should be specifically modified as the Commission is considering. The miscible gas injection project at Aurora will be operated to maintain the flood with an average reservoir pressure that insures miscible displacement recovery is achieved. 5. BPXA recommends that Rule 8 of Conservation Order No. 457 be revised to add the following: g) Review of Annual Plan of Operations and Development, including discussion of the reservoir depletion plan and the status of reservoir repressurization activity. As demonstrated in the information submitted in support of AIO 22A, as supplemented herein, the Aurora field development plan promotes greater field ultimate recovery under waterflood and miscible gas EOR injection. The planned miscible gas injection project will recover a significant incremental amount of oil over and above the expected waterflood incremental recovery. III. Summary BPXA respectfully requests that the Commission reconsider AIO 22A and grant this application for rehearing. BPXA has addressed herein the findings and conclusions that should be reconsidered and has submitted additional information for the record to address the issues raised in the Order. We believe the additional information provided demonstrates that because of the reservoir quality and fluid contact risks at Aurora, implementation of the development strategy as proposed is essential to enhancing ultimate oil recovery within the AOP. Further refinement of our understanding of the AOP and adjustments to the development plan highlight the need to accelerate EOR start-up. The surveillance plan and additional well pressure information should resolve the concerns expressed in AIO 22A. Application for Rehearing) AIO 22A 4/28/2003 Page 10 Therefore, we respectfully request that, based upon the additional information, the Commission withdraw and void the April 3, 2003 AIO 22A decision and issue an Order approving BPXA's application for injection of enriched gas in the AOP and for an increase in allowable water injection pressure. In addition, we conclude, as discussed herein, that several of the proposed amendments to CO 457 are unnecessary or should be revised as indicated herein. BPXA is prepared to have the Commission rule on the basis of the record as supplemented herein and without further public hearings, unless the Commission's concerns have not been resolved by the information supplemented herein. Please contactGil Beuhler (564-5143) or Gary Gustafson (564-5304) if you have any questions regarding this correspondence. Mau reen son Performance Unit Leader Greater Prudhoe Bay Attachments: Attachment 1 - April 17, 2003 BPXA Aurora Reservoir Presentation to AOGCC Attachment 2 - April 23, 2003 BPXA Aurora Reservoir Presentation to AOGCC Attachment 3 - SPE 76739 "Proactive Surveillance and Phased Development Yields Promising Results From the Aurora Field 3D-Years After Discover" (J.P. Young, F.E. Bakun, F.K. Paskvan, SPE, E.H. Westergaard, BP Exploration (Alaska) Inc.). Attachment 4 - Aurora Representative Well Pressures (BPXA) Application for Rehearin~ ) AIO 22A 4/28/2003 Page 11 cc: ) M. Vela, ExxonMobil K. Griffin, Forest Oil J. Johnson, CPAI G.M. Forsthoff, ChevronTexaco Francis Sommer, BPXA Gil Beuhler, BPXA Frank Paskvan, BPXA Rosy Jacobsen, BPXA Gary Gustafson, BPXA Mark Worcester, CPAI Steve Luna, ExxonMobil ) ATTACHMENT 3 ) Society of Petroleum Engineers SPE 76739 Proactive Surveillance And Phased Development Yields Promising Results From The Aurora Field 30- Years After Discovery. (J. P. Young, F. E. Bakun, F. K. Paskvan, SPE), E. H. Westergaard, BP Exploration. Copyright 2002, Society of Petroleum Engineers Inc. This paper was prepared for presentation at the SPE Westem RegionaVAAPG Pacific Section Joint Meeting held in Anchorage, Alaska. U.SA, 20-22 May 2002. This paper was selected for presentation by an SPE Program Committee following review of Information contained in an abstract submitted by the author(s). Contents of the paper, as presented. ha\'e not been reviewed by the Society of Petroleum Engineers and are subject to corvection by the auttIor(s). The material. as presented. does not necessarily reflect any posiIion of the Society of Petroleum Engineers, its officers. Of members. Papers presented at SPE meetings are subject to publication review by Editorial Committees of the Society of PeIroieum Engineers. Electronic reproduction. distribution. or storage of any part of this paper for oommerciai purposes without the written consent of the SocIety of Petroleum Engineers is proIIìbIted. Permission to reproduce in print is restricted to an abstract of not more than 300 words; illustrations may not be copied. The abstract must contain conspicuous ackI'Iow!edgmen of where and by whom the paper was presented. Write Ubrarian. SPE, P.O. Box 833836. Richardson. TX 75083-3836. U.S.A.. fax 01-972-952-9435. Abstract Although three 1969 exploration wells discovered hydrocarbons in the Aurora structure, development was not possible until a scope change to the V-2OO exploration well demonstrated commerciality 30-years later. Commencing in June 2000, an aggressive 6-well horizontal and vertical development/appraisal program yielded over 1.75 million barrels of oil in the first year and provided a better understanding of a reservoir previously thought marginally commercial. Investment in reservoir description and proactive surveillance led to accurate decision-making, and with innovations, yielded significant return from a ~~marginal" field. Introduction The Aurora Pool is located on Alaska's North Slope and produces from the Kuparuk River Fonnation. See location map, Figure 1. Hydrocarbons were discovered in 1969 with three exploration wells: Beechey Point State # I, #2 and North Kuparuk 26-12- 12. Results from these wells, shown in table 1, did not give any confidence that commercial rates could be achieved from the field, and exploration work was minimal until 1999. The following key points were recognized from seismic data and exploration results: I) Severe faulting and compartmentalization with variable fluid contacts 2) Significant variations in reservoir pay thickness, quality, and mineralogy 3) Marginal quality, damage prone fonnation with gas-cap present. Table 1 Exploration Well Test Results Well (date) Gross Oil Oil GOR Estimated Column ~ ~ S!i!l BPS#I (1969) 60' (+ gas) 18 >70,000 50+ BPS#2 (1969) 15' 0 0 50+ NKUP 26-12-12 30' 32 <700 50+ (1969) V -200 (I 999) 58' 1915 718 +12 In 1999, a late scope change was made to extend the V-2oo exploration well, a dry hole in the Schrader Bluff, to penetrate and test the Kuparuk. The V -200 encountered approximately 58' of oil column and was tested in four stages while progressively adding perforations up hole with a final production test rate of 1915 bopd with a GOR of 718 sct/stb. By achieving commercial rates with the initial completion, V- 200 results unlocked development of the Aurora field. Due to Aurora's proximity with existing Ivishak Participating Area (IPA) infrastructure, an accelerated development path was taken. Instead of building a new development drilling pad centered on the V -200 well, which would require pipelines, power and access roads, the field was developed from the existing IP AS-pad. To date, ten development wells have been completed in the Aurora structure. The first three wells, located in the V -200 fault block, were drilled horizontally to take advantage of the relatively large and continuous block. The eastern segments of the field have been developed with vertical fractured wells to access separate producing intervals. The western portion of the field was accessed with extended reach drilling technology and a single U-shaped injector that was drilled to provide water flood support to two discrete fault blocks. The Aurora reservoir description has matured significantly over the last 2 years. An enhanced 3-D seismic survey acquired early in 2000 improved fault resolution, a new sequence stratigraphic framework more accurately describes the geology of the structure and a single well tracer test was 2 J. p, YOUNG, F. E. BAKUN, F. K. PASKVAN, E. H. WESTERGAARD SPE 76739 utilized to improve estimates of connate water, residual oil saturation to water flood and residual oil saturation to miscible gas flood. Future development well locations will be based on the integration of the above, plus surveillance data from existing wells and continued 3D fluid flow simulation. This paper provides a development case history and discusses learnings made along the way. Structure Top Kuparuk structure in the Aurora area is essentially a northwest-southeast oriented antiform broken up by north- south striking faults. Gentle slopes dipping 2.5 to 6.5 degrees characterize the northeast and southwest flanks of the structure. In contrast, rotated fault blocks characterize the southern and western flanks of the structure. 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, and Beechey Point State I. See figure 2 for a top of structure map showing various development blocks within the field. Stratigraphy The Kuparuk River Formation was deposited as deltaic and shore face to shelf sediments. The Kuparuk is composed of very fine to medium grained quartz-rich sandstone, interbedded with siltstone and mudstone. See figure 3 for the V-200 type log. The uppermost unit, the Kuparuk C interval, contains the primary reservoir sands of the Aurora Pool and was selected for initial development with horizontal wells in the V -200 block. The Kuparuk C is characterized as lower to middle shore face sands deposited in a basal transgression (C-I ) a middle progradational package (C-2 and C-3) and a capping transgressive package (C-4). The thickness of the C-sands 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 Kuparuk C-l and C-4 Megazones are coarser grained and contain variable amounts of glauconite and digenetic siderite. The volume and distribution of siderite and glauconite can significantly reduce reservoir quality of the Kuparuk C-l and C-4 intervals. These minerals are unevenly distributed and challenge open hole log interpretation of fluid contacts and pay. New Reservoir Description. Post Phase I Development, it became apparent that the maps, stratigraphic framework and resultant reservoir description required refmement. In conjunction with early appraisal and development drilling at the nearby sister field, Borealis, the decision was made to pull together a new integrated sub-regional Kuparuk River Formation geologic model and reservoir description. This new geologic model relied heavily on new cores taken at Aurora and Borealis as well data from the vast Kuparuk River Unit (KRU) dataset. The goal of this effort was to build an early reservoir description that is updateable and flexible enough to address a range of issues from well planning in undeveloped portions of the field to water flood implementation in more mature areas. Petrophysics, biostratigraphy, petrologic data, core analysis, ichnology and production data were integrated into a sequence stratigraphic framework to produce a robust geologic model. The business challenge was to build a geologic description early in the fields' history while simultaneously planning and managing ongoing development/appraisal drilling. The resultant stratigraphic framework and maps have had a significant impact in development planning at Aurora. See rIgure 4 for stratigraphic framework. Rock and Fluid Properties Field oil-water contacts have been interpreted to vary from 6812 feet tvdss to 6835 feet tvdss between the East and Northwest end of the field. Based on RFT data, core analysis saturations, and core staining, a gas-oil contact (OOC) is interpreted to vary from 6631 feet tvdss to 6678 feet tvdss between the East and Northwest end of the field. The reservoir description for the Aurora Pool is developed from the Aurora Log Model. Oeolog's Multimin is used as the porosity/litho logy solver and is based on density, neutron, and sonic porosity logs. Quality control procedures include normalization of the gamma ray, density and neutron logs. The Waxman-Smits correlation is used to model water saturations. Results from the log model are calibrated with core data, including litho logic descriptions, X-Ray diffraction and point count data, obtained from wells in the Aurora Pool and the nearby Borealis reservoir. Supplemental core data was analyzed from wells in the eastern portion of the Kuparuk River Unit (KRU). Wells with Aurora cored intervals in the data set are Beechey Point State # I, S-04, S-I04, and S-16. Porosity and Permeability. Porosity and permeability measurements were based upon routine core analysis (air permeability with Klinkenberg correction) from the following well set: S-16, S-04, Beechey Point State # I, S-I04, NWE 1- 01, NWE 1-02, and NWE 2-01. The ratio of vertical to horizontal permeability (kv/kh) was 0.006 per 20 feet interval, based on the harmonic average of routine core data. Typical single plug kvlkh ratios ranged from 0.4 to 1.2. ) SPE 76739 ) NEW DEVELOPMENT CASE HISTORY: AURORA 3 Hydrocarbons in Place 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 110 mmstbo and 146 mmstbo primarily due to uncertainty in the GOC. Fonnation gas in place ranges from 75 to 100 bscf, and gas cap gas ranges from 15 to 75 bscf. Field Development Plan The Aurora accumulation had been recognized as a development target as far back as the late 1960's, but due to expected low production rates and uncertainty in fluid contacts, development was not aggressively pursued. As mentioned earlier, favorable results from the V-200 exploration well generated sufficient enthusiasm to proceed with field development in 1999. An accelerated development plan utilizing existing Prudhoe Bay infrastructure with three separate phases was generated. Phase 1 Development Six wens were planned for the Phase 1 development drilling program with three wells located in the V -200 Fault Block and three wells in the North of Crest Fault Block. V -200 Fault Block. The Aurora seismic survey indicated that the V-200 Fault Block was one of the least faulted in the field. In order to take advantage of the relatively large structure and thin reservoir, three horizontal wells were drilled for initial development, originally two producers, S-IO 1 and S-102, and one pre-produced injector, S-I 00. Gas-cap. A GOC was screened as possibility in the V-2OO Fault Block but considered unlikely. S-101 was drilled into a GOC at approximately 6678' tvdss, confinned by an initial production test at over 20,000 scf/stb. The high producing GOR plus the need to conserve reservoir energy led to S-IOI being shut in shortly after initial production. Compartmentalization. Compartmentalization was recognized prior to development, however its extent was underestimated and has had an impact on development plans. The first indication of this was encountering a significant change in the Kuparuk structure at the S-102 well that could not be determined with seismic data. Top Kuparuk was encountered 50' shallower than expected in this well, and at least two faults were crossed, forcing the horizontal section to be shortened due to missing fonnation. Initial pressure data and subsequent production data suggest that S-102 is in tortuous communication with the main V -200 block. See figure 5. Figure 5: $-102 Compartmentalization ALma tq¡8úIl'cIm8Ian""-' 11161 anJ1 i ì I æo(- ! I 1/1 I i ¡ ~6m1 ~ . i '-III'TDoIo- t GøOo8- i 1Jt~ l(-~~~Io_~vr ~t ~,~~~~ ¿ I ami 3BI ~ v.:;m c:i leg . &~ R9iU'eS - v.:;m 01 Gcdert .. &102 Aess.re 3W 3D) 3410 "6 30m 3«Ð Pattern Reconfiguration. S-100, originally planned as the injector to support S-101 and S-102, was the best perfonning well in the fault block with initial rates in excess of 7000 bopd. There was considerable discomfort with converting the best producer in the block to injection service plus off take from S-I 0 I would be limited for several years due to gas influx. A proposal was made to re-configure the V -200 fault block to retain S-IOO as a producer and convert the S-l 0 I well to injection. The final configuration had to meet three objectives: improve rate, increase reserves, and meet economic hurdles. Injection from S-IO I would provide excellent sweep to the south of S-l 00 but would not provide pressure support to the north. As the evaluation progressed on the V -200 fault block, the S-107i well was in the planning stages to provide injection support to the Northern Beechey fault block.. The well trajectory passed over the mid-point between the S-102 and S- 100 well locations. An additional injector was simulated in this location and it provided over 1.2 MMSTBO of additional reserves. Further it allowed S-IOO to remain on production, substantially increasing off take from the V -200 fault block in 2001-2004. Once the location had been identified and benefits established, an economic way to access the target had to be found. A stand alone well, a multilateral, and a high angle dual injection target well were evaluated in tenns of cost, ease of drilling and operability. The best option was a U-shaped well passing down through the Kuparuk in the V -200 fault block then climbing back up to hit the Northern Beechey target from below. The dual target injection well met all three objectives of a successful reconfiguration: keeping S-100 on production, increasing reserves in the V -200 fault block, and was an 4 J. P. YOUNG, F. E. BAKUN, F. K. PAS KVAN, E. H. WESTERGAARD SPE 76739 economically viable project (development cost less than $ I .001bbl for V -200 target). See Figures 6a and 6b for the S- 107i u-shaped well along with base case and reconfigured patterns. The complete evaluation, approval, and implementation process for V -200 pattern reconfiguration took place in less than 4-months and did not delay the development schedule. Early partner involvement and multi-disciplinary teamwork we're crucial to timeliness of this project. The North of Crest Fault Block. The North of Crest (NOC) area on the east side of Aurora was the next most favorable development target at Aurora. Because the NOC area is smaller and has a higher degree of structural complexity, it was developed with two vertical producers, S-103 and S- 105, and one dual target injector, S-I04. Several well placement scenarios were simulated at various gas oil contacts. The final well locations were based on mitigating the risk of gas in the S- I 03 location. S-103, located at the highest point in the structure, was the first development well in the block. Interpreted log data suggested a possible GOC in the C-4 sand at 663 I' tvdss. To avoid high GOR production, initial perforations were limited to the C- I sand and had initial production of over 3000 bopd and proved excellent reservoir quality in the C-I in this fault block. Subsequent static pressures have suggested that there is a very active aquifer in the NOC area. S-I04, drilled in central portion of the block, was a pre- produced injection well and initial unstimulated production was over 700 bopd. With slight modifications in the directional plan and completion equipment (tubing straddle), S-I04 was able to access injection targets in both the Kuparuk and shallower Schrader Bluff reservoirs for a fraction of the cost of 2 stand-alone wells. S- I 05, structurally the lowest of the three wells, was drilled very close to the low productivity NKUP 26- I 2- 12 well and did not produce commercial rates initially due to a truncation of the higher quality C-4 sand. A fracture treatment in S-105 yielded sustained production of over 1000 bopd, and highlighted the fonnation damage concerns in the C-sand. Phase 2 Development The Phase 2 development program was initiated in 2001 to appraise and develop the remaining blocks in the Aurora field and reconfigure the V -200 water flood pattern. The second phase of development drilling is expected to continue through 2003-4. Beechey. The Beechey Fault Block, on the western edge of the Aurora field, had very high potential reserves but an uncertain gas oil contact. Mud logs from the Beechey State # I exploration well had a broad range of interpreted GOC's ranging from 6648' tvdss down to 6705' tvdss. It was recognized that if the GOC was shallow, then up to 7 wells could be drilled in this portion of the field. A phased drilling approach was chosen for this block to help mitigate development risk. S-106 was drilled first, in mid 200 I, to define the gas oil contact and prove up productivity. Post hydraulic fracturing, the well tested at over 6000 bopd confirming the presence of high quality Kuparuk C-Sands. While the well did not intersect the GOC, production results suggest a GOC at approximately 6678' tvdss, consistent with the V-200 Fault Block. As mentioned earlier, the S-1 07i well was drilled as a u-shaped injector to provide injection support to the S-106 well and reconfigure the V -200 fault block. Based on the results of the S-106 producer, two additional wells are being evaluated for the Mid-Beechey Fault Block target (producer/injector pair) and three wells for the South Beechey Fault Block target. Additional simulation and further production testing are required before the development will continue in this block. Southeast Crest. The Southeast Crest (SEC) Fault Block was the next development target. The Kuparuk C-sands thin significantly moving towards the southeast and a key uncertainty was well deliverability. Limited core data from the S-16 well suggested that a hydraulically fractured well could produce at economic rates. Two wells were drilled in 2001 in the northern portion of the block, S-108 and S-IIO. Both wells had post hydraulic fracture rates in excess of 1500 bopd. Based on the deliverability of the first two wells an injector and an additional producer are being evaluated. The two additional wells are expected to encounter thinner, but generally higher permeability rock in the central and southwest portions of the block. Crest. The Crest Fault Block carries significant structural uncertainty and has not been drilled as part of the Aurora development. The block has been penetrated several times with Prudhoe Bay Ivishak wells and open hole logs have demonstrated that Kuparuk sands are present. Unfortunately, the dense faulting raises serious concerns about the connectivity of each small compartment. It is expected that one well will eventually be drilled to test this area and if multiple blocks are communicating then up to 3 more wells could be drilled. Phase 3 Enhanced Oil Recovery The final Phase of development will occur concurrently with Phase 2 Development in which miscible gas will be utilized at Aurora to improve ultimate recovery. Early screening indicates EOR benefits on the order of 5% incremental oil recovery. The S-104 single well tracer test was utilized to prove in-situ miscibility. See the Single Well Tracer Test section. ) 5PE 76739 ) NEW DEVELOPMENT CASE HISTORY: AURORA 5 Facilities design Aurora wells were drilled from an existing IP A drill site, S- Pad, and utilized existing IP A pad facilities and pipelines to produce Aurora reservoir fluids for processing and shipment to the Transalaska Pipeline System (TAPS). Aurora fluids are commingled with IP A fluids on the surface at S-Pad to maximize use of existing IP A infrastructure, minimize environmental impacts and to reduce costs to help maximize recovery. Use of existing facilities, reduced capital expenditure and allowed the project to be accelerated by providing early access to test separation equipment, injection water, and miscible injectant for EOR. The disadvantages were added drilling cost to reach reservoir targets, and close proximity of surface well locations, which caused delays due to equipment and simultaneous operations limitations. Well Design and Completions The horizontal well completions were designed to reach targets from existing infrastructure while maximizing horizontal displacement in the reservoir for increased productivity. Because formation damage was a concern, "banzai" completions, a combination of slotted and cemented/perforated liner, were used to minimize damage while allowing for fracture stimulation if necessary. The initial wells were completed with 7" production casing in vertical wells 4-1/2" liners in horizontal wells. All the wells were perforated at 6spf with 60 degree, deep penetrating charges, and 0-1500 psi under-balance, depending on operational limitations. Field Development Learnings Because of the pay quality and fluid contact risks at Aurora, evolvement of the development plan was critical. In addition to the stratigraphic framework mentioned earlier, we feel the following learnings had a favorable impact on, and were key to sustaining Aurora field development. Single well tracer test. As a small satellite Aurora does not have the scale to warrant a significant investment for the collection of native state core and special core analysis. Therefore properties like relatively permeability were based on analog data. The single well tracer test (SWTT) provided an economic way to collect the following key reservoir parameters in-situ: initial water saturation, water-oil rel~tive permeability, residual oil saturation to water flood and resIdual oil saturation to miscible gas. S-I04 was drilled in 1 Q 200 I and was selected to be the key data well for the Aurora field. The well was cored and standard core analysis was performed, plus a full suite of open hole logs was run including nuclear magnetic. resonance. and focused microresistivity. The well was consIdered an Ideal candidate for a single well tracer test as it had a quality cement job and a detailed near well bore description. The SWIT was performed over a 30' interval in the S-1 04 well. The connate water saturation test returned a value of 13.5%, considerably lower than the predicted 25-30%. This suggests a higher OOIP in reservoir. The residual oil saturation to water flood plus the water-oil relative permeability data suggested that the system was more oil-wet than analog data had suggested. The residual oil saturation to miscible gas was very low even with a minimal pressure delta at the perforations. The miscible gas entered the upper 80% of the open zone and swept it down to a residual oil saturation of 4.5%. Information from the SWTI impacted injector spacing, rate and recovery estimates and highlighted the need to accelerate EOR startup. Productivity Data. Following promising results of the V -200 exploration well, the initial development began at ~urora with three horizontal wells followed by three conventIOnal wells. Substantial log, core, and production da~ including pressure transient analysis (PT A) was collected and is summarized in table 2. Table 2 Aurora Phase I Well Results kll kh Total ImUal !Jet Avg loglcore PTA Well Type (rnd-ft) . (.md-..f.t.)' .', ....S...k.,in. - " . .B..O PD. . K md V.200 J:xpl. 10,000 3,000 12.0 1,915 100 5-100 Horiz. 10,204 4,000 0.7 7,213 109 5-101 t-Ioriz. 6,063 1,925 0.4 2.600 78 S-102 Horiz. No data 600 8.0 - 600 30-80 Conv. -S-1 03 (C-1) 10,262 3,000 5-104 Cored 3362 S-105 Conv. 769 8-105 Frac'd 769 Pressure buildup and production log analysis showed significant skins in perforated completions, even when steps were taken to minimize formation damage with the use of KCL drilling fluid and under balanced perforatingl. The inability to achieve extreme under balance conditions requ~r~d for perforation cleanup resulted in the lower permeablhty layers not communicating with the well bore. See figur~ 7 for a comparison of perforation skin and under balanc~ tn the Aurora wells relative to published under balance reqUIrements for 0 perforation skin in Berea sandstone2. After fTacturing S-105 and performing PT A, it was apparent that the permeability-thickness (kh) increased dramatically, even without correcting for relative permeability. Increased kh resulting from fracturing into lower permeability layers has been documented at the Kuparuk River Unie. 6 J. P. YOUNG, F. E. BAKUN, F. K. PASKVAN, E. H. WESTERGAARD SPE 76739 The low kv/Kh also hindered productivity from horizontal wells relative to fractured wells. Shown in figure 8 is a plot of productivity index, nonnalized to kh for Phase 1 and 2 Aurora wells versus net horizontal length or fracture length. Even when great care was taken to maximize productivity with long, open-hole completion horizontal wells, the stimulation benefit did not compete with a high conductivity propped fracture. By providing excellent vertical communication to the full reservoir, high conductivity, tip screenout (TSO) fractures provided superior productivity at a much lower cost than horizontal wells. Conclusions The following advancements were key to development at the Aurora field: I) Success of the V -200 exploration well in attracting investment by achieving a commercial rate well test. 2) Use of existing facilities to minimize construction impacts and costs. 3) Reprocessed seismic data continually updated with well control to refine structural description, compartmentalization issues, and well placement. 4) Stratigraphic framework using log, core, and analogue data to map reservoir quality variations and refine reservoir description. 5) Fit-for-purpose well trajectory and completion designs to match reservoir description (horizontal/dual target wells and TSO fracturing). 6) A single well tracer test provided key in-situ reservoir parameters in a timely manner that allowed for impact on development plans. 7) Investment in reservoir description led to significant changes in the development plan. 8) Proactive surveillance leads to accurate decision-making, innovation and opportunity. Acknowledgements The authors would like to thank the management of BP, Exxon Mobil and Phillips for pennission to publish this paper. We would also like to acknowledge the contributions of staff in Exxon Mobil, Phillips and BP who have worked on developing Aurora over the last 3 years. Specific thanks to Frank Paskvan for reservoir modelling and initial development planning, Gary Molinero for geophysical interpretation of the structure, Ray Eastwood for developing the Aurora log model, and Bruce Weiler for facility planning. References 1. Bloys, J.B., Murphy, J., Weingarten, J.S., Wheatall, "Drilling and Completing Wells for High Productivity in the Point McIntyre field: Strategy, Implementation and Verification", SPE 30461 presented at the Annual Technical Conference, Dallas, TX, Oct., 1995. 2. Behnnann, L.A., "Underbalance Criterita for Minimum Fonnation Damage", SPE 30081 presented at the SPE European Fonnation Damage Conference, Hague, Netherlands, May, 1995. 3. Pospisill, G., Lynch, K.W., Pearson, C.W., and Rugen, lA.: "Results of a Large-Scale Refracture Stimulation Program, Kuparuk River Unit, Alaska," SPE 24857 presented at the Annual Technical Conference, Washington, D.C., Oct., 1992. Nomenclature Bopd = stock tank barrels of oil per day EOR = enhanced oil recovery GOR = Gas oil ratio Kv/Kh = ratio of vertical to horizontal permeability koil = Permeability to oil md-ft = millidarcy-feet OOIP = Original Oil in Place RFT = Repeat formation tester 81 Metric Conversion Factors Bbl x 1.587873 E-O I m3 Ft x 3.048 E-OI=m Psi x 6.894757 E+OO=KPa SPE 76739 Appendix Figure 1: location Map ) ) NEW DEVELOPMENT CASE HISTORY: AURORA 1 '~-"'---_.._- - . ~"""'~~ ,,,":;r"'-'----;",,,,,,--,, ,- dHj::~/::."" '.: ;"':T-n4~~~'i~:..~r~~': ":- ~ :",=::';::; .¡.'._.~--;-.: ~. - '. -.-:-~ ~.f --. -,. --"'-;':. . .- .-". .- ._~ .,.\.... >." . c.."":. " , " . . :" ~~2-.~~~>" ""'~:~.--~:'.~~_':""~.':~:.'."'-'~-,:,'"'~;':"..:_'--.~:''-'~_::.-~" -- .:- - -'. ~ .~ ~" L I'- ~ . r-~ '-- 'IiI(,,: - : -~."~- t.~':~;.'..;-'~_..-.:_-,--~.,::..~-~.:'.,'.-~-',t...'.-.'_:.',.:,".'.~':'_"-:-"~:"'.'.'.='- ..~'!'~È{;.E.. .. . . ...' "'. . .--.,-:-.; ,.-1,"." . -::-. ':'." - ~ ,". - ",.. --';"';":;.',. -- ~ -~ {.~ i-~-!~~ ~ 7~~~-.- .. . . '. - - - . - - ~ -. ;.~--..-::~ ~.. -':~~1.f-~.-..~- -::- .. '#c '.C : ',,, Š::-~~ Figure 2: Top Structure IIK-.paruk 0 ~_'KÛPa",k Reservoir Properties Deposition Shore face GOC 6631 - 6678 tvdss owe 6812 - 6835 tvdss OOIP 110 -140 MMBO GOIP 50 - 75 BSCF Permeability 10 -150 md Kv/Kh .001 - 1.0+ Porosity 16 - 25 % # Wells17-25 ...--- "u"c~" ,,: E1. 0 T:I' I\U~RR~K C S-:'R~crURE !'!~" c. t. . ZI FT ;:. I I I I 8 Figure 3: Type log TVD ~\Jí4.~ <".~> C3 ",Jr'c. C2 #J'!i' Ti... B J. P. YOUNG, F. E. BAKUN, F. K. PAS KVAN, E. H. WESTERGAARD SPE 76739 2001 AURORA-BOREALXS RESERVOXR DESCRXPTXON AURORA TYPE LOG V-200 ~ H N ~ a ~ H N NPH¡.~L.', n:¡"~(J'f:3I. Dr.:.tl~" j .'."""""'''-'''''-':-.:;r--1'''''-~------:-''':'- .o.i PERM ~ "",,' vcuw _OA,.' MD ~- P\Ji o.,~ tØClCt\,:;':;"-"- -. - :'!.:~.'~'.~.-'---"------:" OR_OIL,. , ""'" II..O_DtL- , <.Mo8M ~z ~ ~~r'-,. c.~'-'-':~-;-H~r;",~-;-,J~".,."....',.,".~','f~~'~,:,., -}jF'-;~- -~,',r~: : \ . ,..'. '," ...f ._~. '-<H '."'<...".,. a," . ': "', . :}-t-. ~ '. ~ \; ~'~'d-- ,.,.., ".','~" ',"'~-~ -'. '~;~'<'.",';~",<..... " --~ ~ :Li=:- ~- ,---~~.~ ~o - d ~" , . "n~ --=:=:- ~<~,. c. -, ~ -.- ., ',',,'J"«." ".~. -, .c. b .~' --. " Æi-" "3 ~('" a' , ; ?-. . 1 : ;> \- ' """" - ~7-",-" J., -. ~:",'. J", ..<;'"..,,' " : - . - ,,',' ,- x Y",'.,,-, (r,,'," :... ',> ~J!-~,"'~'-,~,' ~".~" 7'~..- .,' ~"'- ,." ~-" . ~ \ ,',. '.',' ..~ ...;<"!' ,.--' - """'- W<I"'mgNI,d '111°' C~ . C1 !';', Figure 4: Stratigraphic Framework :::~~/.;',I\;);T::"Õ;;' "/4.;-:,;;\.,; z -< >.- ~~ "C:a: "'-'cc < ~ 6'" ;)tG':O<.€ !1:~'S'''1(i~:: J:' :;:) :i~ ¡?ï ~ ~ C-4 g~ ZOo: C-3 ~ ? z ~ < ~~ Cf. -a. 0 <t:J Ì -J"'- =- ~ C-2 Z <.: >-~ -.)..... I::lClf. <"" wI>- =- <.: J: ".... '< :.u .0 ~ :) !Ø ..J C-1 :. .j~~f (.' :"~~~':';' Þ.&.fIJ.Á RAe" f-...., ~ J t.-~. C5? Estuary ? 1 'l'~arÍs¡tional Shelf Lower Sho,.dau C4 Middle: Shore face C3e Midd~ Shoreface A~.""'- '1t C3d . ?eH~t(1¡ 55 fcclI~s. m~d'u!";1 t.:) c::>arse g'-cHr. wIth exte"'s,.~t: nm- cernert , Comþlleated Interval wI Se¡era! stcÖ'cd trorsg!"essl'l'i: ~~¡rf(lçE:$ t7ratn s'ze more coarse above Bro",,1'i d.sccr,t'I'¡,¡ity . Overall fi!'\in9 upwo,.d . Giaucol\ife or:d siderIte cOfl".mO!1 , Oyerall progradation of c:;:Jr's~r,¡r'g upward ,ydes C3, . Each ,-yell: typically bouro(kd by fload,r>g e...er;rs C3b Proximol Lower Shoreface . Façi-es ¡rter-tol'lgue II' ove1"oil clear'I'9 upwor'd tref'd ...---........................."",.,..",",,/ C3a . cxtertSive bioturbat¡cr, hc:s mixed s~d¡me!'1r to e:>< ter,t th(;' there cOfltir,uum of laye.r rod< properties Distal Lower . Shoreface \ T'.nsiti....' Shalf 1 Transitional Shelf , Slow f'ates of d~pc$i!¡a,", C2e C2d ac I.,tD (.ca . Laye,.s dewr lap Ol':to Green MFS . Loyers progressively tr;,¡"cat~d by g'-owr from I'orth to 5o.!th . Prcgrcrålrg NNW C!y . Choroc~er¡li':d by sta(~ed fll"r'1 u;;w:.~d cycles w.th e"oS'CI'Cl-SM . G..air S'le rar}es from VCS to sdt . PotentIal true, lone . Odaps pr~e)(i$tl"'g LCV ropo9~Qphy C1x ..ower Shoreface ~ SPE 76739 ) ') NEW DEVELOPMENT CASE HISTORY: AURORA 9 Figures 6a and 6b: Pattern Reconfiguration and 8-107 Well '-:-::;;:;:::;::;;;'-:::':-:~'~~:~:;~;:::.~è.-:-::-::;';~---- Base !lll :m sm Em ,m :m 2J¿4 ~m i -- 5-1 07 -N~~- SE_xsect_BSO r--=;--; .:--j .; ... ~, :~~~- ~ ¿NH c '.., '- ...' ¡ ~, '. ! '\ . II! ¡ i '~¡ I j ,J ~ ¡ : ¡ t, I ,¡ :, , "", . I I ' ¡ 1, !I ¡ - ' 1;4' '¡, ¡"\ ¡ i ¡ ; i'" \ ;l\f .] . ' ¡,> I ~t!l I , 'I, . ¡L." ¡ '-.' --' ';.. I,' I ". . (~t N:~.::;:~: ~tf'l¡ ¡ I ¡ ¡ kL ":~¡'~!C:'':¿:~ì!:11, . ~¡ ¡~ ¡ iI1\'.k:,V(..... ~<. I I '. 1 Vi! ¡., '.Live. '1,.., A '!. I ".,=; ""l"'r%~ll" ~1 1[;0"'0.,, ~I?~~ ;(-~::, ~~ ~"I)" - ..bu/;¡~'i'f"1 '~;~Út%ÿ '07:~1 "'?œ"'~jf. : "". 'f, ,', ;'..,¡, '~:) k',""~::,, ,~.¡~ ~ y, ~1lli2'~.1 -r'?¡[lli, ' Ii"::!" .. . :! SE '. IC ~;~~~: 10 J. P. YOUNG, F. E. BAKUN, F. K. PASKVAN, E. H. WESTERGAARD Figure 7: Perforation Skin Aurora Perforating results 100 . . . ff-mfi!tr~4 lextreme US required for lower perm I . -- .--- . . . . Skin calc. from Test . . . Underbalance, psi . . . -SPE30081 UB for askin, BereaSS . 1 i 1 -----------------.-------------------- 10 100 Fm. permeability, md Aurora Hz VS. Frae Well results 3.0 2.5 î 2.0 t ! 1.5 I )( . i ¡ ~ 1.0 1 .. . 0.5 ¡ Î . I . I '8-------1 . ! . Open holelCmtd Hz Wells 8 Fracs,S-105(no TSO),6,8,10 . S-1 02 Heel Frac ~1QO petl'd, damaged'? 0.0 0 400 600 800 1000 1200 Effective Horiz. Length in Pay -or- Free 1/2 Length (ft) 1400 200 SPE 76739 10,000 ãi ~ If c 1,000 .¡ " ~ 'a c: ::;) 100 1,000 . 1600 ') AURORA REPRESENTATIVE WELL PRESSURES Attachment 4 ) Description 4 5 Unstable static Fluid level ::tt ~ ') IÎI,.. ) A Lega.INotice NOtice- -of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission. Re: Proposed AlT)endmentof Conservation Order No. 457(Aurora Oil Pool, Prudhoe Bay. Field)and Pròposed Revocation of. Conservation' Order No. ~8-A. (Prudhoe Bay Kuparuk River Oil Pool, Prudhoe BayField)The Alaska Oil and Gas Conservation Gommissionon its own motion propQses to amend Gonservation Order No. 457 and to revok~ Conservation Order No. 98-A. Among the Changes to Conservation Order No. 457 that the Commission may consider are:.1. Adding a def-. ¡nitipn of the Aurora Oil Pool, which is. currently contained in Conservation Order No. 98-A;2. Revising Rule 4 to recognize the applicability ofJhe PBUWestern Sat~lIite Production Metering Plan, for allo- cation of production, well test frequency, and reporting requirements, as adoptedwithin Conservation Order471;3. Revising Rule 5 to require wells S-100¡S-102¡ S-105, S-106, and S-108 to be tem- porarily shut in for reservoir pressure measl:irements, to require those wells torêmain shut in if the pressure is below 2700 psi, and to require the submission for Commission approval of aplan for water injection, repressurization,' and enriched gas injection; 4. Revising Rule 7 to provide for approval 0 '.' . '. . . .' - of a watetflood program and to require the reservoir pressure to bel11aintained above 2700 psi; 5. Revising Rule 8 to require submission for Commission approval of a reservoir depletion plan that pro- videsfor reservoir repressurization' to a . level that will, allow for future miscible gas injectign and will ensure greater ultimatè recovery under watetflood. A public hearing on this proposal will be held before the Commission at 9:00 a.m. on'May 8, 2003, at the Commission's offices, 333 W.7th Avenue, Suite 100, Anchorage, Alaska 99501. If you are a person with a disability who may need a special modification in order to é\ttend the public hearing, please.contact JodyGolombié at 793"1230 1^...~;....a..L :- ^-...:I ~" f")lV'\t;) Qo__-:LM',.' ,"7""', "~. <_.. ",',.--',". '''''.''':<''''::'-'---'''::'-''ðiAn I .mé40¡ alqa aq ~sn~ :ÐNI~V;:íH ïaau> JO doo¡spua~swJa pua ~pua4 4¡!M 40aaJ ~>tlaM ~pua¡s ~¡!s O¡ pa':/lnbàJ aaÆoldw::¡ al nls:l()W'SUOI1Oun~ lalluassa aUI wJo,IJad 01 sallllqaslp UIIM Slanpl^IPUlaloaua I STATE OF ALASKA ADVERTISING ORDER SEE BOTTOM FOR INVOICE ADDRESS ').. NOTICE TO PUBLISHER \ INV! .V1UST BE IN TRIPLICATE SHOWING ADVERTISING ORDER 'I, f,ERTIFIED AFFIUAVIT OF PUBLICATION (PART2 OF THIS. FORM) WITH ATTACHED COPY OF ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE ADVERTISING ORDER NO. AO-02314041 F AOGCC R 333 W 7th Ave, Ste 100 0 Anchorage, AK 99501 M AGENCY CONTACT Jody Colombie PHONE DATE OF A.O. April 3, 2003 PCN ~ Anchorage Daily News POBox 149001 Anchorage, AK 99514 (907) 793 -1 ??1 DATES ADVERTISEMENT REQUIRED: April 4, 2003 THE MATERIAL BE1WEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: Type of Advertisement X Legal D Display Account #STOF0330 Advertisement to be published was e-mailed D Classified DOther (Specify) SEE ATTACHED PUBLIC HEARING SEND INVOICE IN TRIPLICATE AOGCC. 333 W. 7th Ave., Suite 100 , TO'." Anchorage, AK 99501 REF TYPE NUMBER AMOUNT 1 VEN DATE PAGE 1 OF TOTAL OF 2 PAGES ALL PAGES$ COMMENTS 2 ARD 3 4 02910 FIN AMOUNT SY CC PGM LC ACCT FY NMR DIST LlO 03 02140100 73540 2 3 4 REQUISITIONED BY: DI~ APUL: í/, L: :~ê~ 02-902 (Rev. 3/94) Publisher/Original Copies: Department Fiscal, Department, Receiving AO.FRM ) Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: Proposed Amendment of Conservation Order No. 457 (Aurora Oil Pool, Prudhoe Bay Field) and Proposed Revocation of Conservation Order No. 98-A (Prudhoe Bay Kuparuk River Oil Pool, Prudhoe Bay Field) The Alaska Oil and Gas Conservation Commission on its own motion proposes to amend Conservation Order No. 457 and to revoke Conservation Order No. 98-A. Among the changes to Conservation Order No. 457 that the Commission may consider are: 1. adding a defmition of the Aurora Oil Pool, which is currently contained in Conservation Order No. 98-A; 2. revising Rule 4 to recognize the applicability of the PBU Western Satellite Production Metering Plan, for allocation of production, well test frequency, and reporting requirements, as adopted within Conservation Order 471 ; 3. revising Rule 5 to require wells S-lOO, S-102, S-105, S-106, and S-108 to be temporarily shut in for reservoir pressure measurements, to require those wells to remain shut in if the pressure is below 2700 psi, and to require the submission for Commission approval of a plan for water injection, repressurization, and enriched gas injection; 4. revising Rule 7 to provide for approval of a waterflood program and to require the reservoir pressure to be maintained above 2700 psi; 5. revising Rule 8 to require submission for Commission approval of a reservoir depletion plan that provides for reservoir repressurization to a level that will allow for future miscible gas injection and will ensure greater ultimate recovery under waterflood. A public hearing on this proposal will be held before the Commission at 9:00 a.m. on May 8,2003, at the Commission's offices, 333 W. ih Avenue, Suite 100, Anchorage, Alaska 99501. If you are a person with a disability who may need a special modification in order to attend the public hearing, please contact Jody Colombie at 793-1230 no later than April 30, 2003. ---' ¥ ~- ')í7 . c -,-,,- ~ v ~ Sarah~ . Chair, Alaska Oil and Gas Conservation Commission Published Date: April 4, 2003 ADN AO # 02314041 ') '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 760133 04/04/2003 02314041 STOF0330 $219.96 $219.96 $0.00 $0.00 $0.00 $0.00 $0.00 $219.96 '~;:;',,;¡~, STATE OF ALASKA THIRD JUDICIAL DISTRICT Nottce, ofPuþlicHéttrh"lQ ",,',' '" . ,i< ".',,'.,..., ","STATE q¡:::A.L.,~Þ!<A.,;i'. Alaska Oil and Gas Conservation CommissIOn Proposed Amendment of Conservation Order No. 457 (Aurora Oil Pool, Prudhoe Bay Field) and Proposed Revocation of Conservation Order No. 98.-A (Prudhoe Bay Kuparuk River Oil Pool. Prudnoe Boy Fle-Id) , The Alaska oÌl and Gas COllservationCorr,rnissibr"! Óhits owhmot!on proposes to amend, Consérvation Order No. 457 and to, revoke Conservation Order No. 98-A. Among the changes to Conservation Order No. 457 thatt!)e Comm~ssioritnaY~onsiderare: ',' ", ' , 1. "ôddihg'ödèÚ¡'Îf¡örioffhe'AuyordOi IPÔOf.Whithi~f9D[~ntJ'f:;7:~.~;t~¡~~~, in Conservation Order No. 98.A; , ".', '.>, , 2. revising Rule .¡ to recognize the applic?bility qfJh!!!~~y.8¥~~,tt~t~, Sotellite Production Metering Pion, tor ollocotlon .of pro\¡\uct\o'''h'o/!!!,e~\ ! frequency, ond reporting requirements. as adopled wlthlnPB~s!!!rYClt;~g,~8~~~!~ 471; , 3. revising Rule 5 to require wells 5-100, 5"102~ 5-105,5-106" and 5: 108 ~,I),e,-: temporarilY shut in for reservoir pressure meClsurements,to reqUIr:~ t . r~:: wells to remain shut in if the pressure is beloW,2700 psi, and 0 r:e,!ulrf. 1'1 submission for Commission a,?p.ro~al of a pl'an for water Inlec 10 , repressurizafion, and e.nrichep 9as inJection;: 4. revising Rule 7 to provide for a'ppr~~al ofa lIYaterfl°C!~ program and to require the reservoir pressure to be maintained above 2700 PSI, 5 revising Rule 8 to require submission for Commissi(;1n approval of a reservåir depletion plan that provides for ~e~ervC?ir repress.urlzatlon to a le~el that will allow for future miscible gas Inlectlon and will ensure grea er i ultimate recovery under waterflood. I Á public hearing on th:is proPosdl wÎnb~ heldbef()r~thecomn:\,¡~~lê)ri.~t j 9:00 a.m. on May 8, 2003,:at the commission'saffices,333vy;7thAVe~u~r~~I)~. ' lOP, Anchorage, Alaska 99501.. " :if yOU a~è a persônWith a disability who may need a spècid'.mdd¡tic:ó~íØoi':~Þ: r order toottènd the public hearing, please contact Jodv Colombie at793,-12~0~9 , later thon April 30, 2003. ' , , Kimberly A. Kirby, 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. Si~ed /!~~#fcf Subscribed and.ø}~befOre this date: Notary Public in and for the State of Alaska. Third Division. Anchorage, Alaska -'"2 L MY COM NEXPIR: Ø/ð§, ---"",;",,~ ""';'~'-' ,4~'...:.,,-"'~:""':;"-. i $0 fci!)P a lin, Chair, Alå$ka.QiJ and Gqs conServQti~n Commission Publish : April 4, 2003 ' , \\\\(~E S. 011,1'r. \.\\:&.~,,=.. . .. ~A ~ ," ..,. .-- . ~¿"". ~tf..' OTAR~?-~ .... .~, r.- "'- . ~ --- ........ - . ..~- . = ::: . ðtlftl ~ . - - . ruuloo .~ ~ -. ~."" ~ . \P.:a. ..- . ~ ....' .~ . ..~ ~~. ~Of . ~_:e""" ~ . . . .' ~;.':\ " ~/.I e~ ", :lJ}J))))J)\\' RECEIVED APR 1 1 2003 A\aska 0\\ &. Gas Cons. Convnission Anchorage STATE OF ALASKA ADVERTISING ORDER SEE BOTTOM FOR INVOICE ADDRESS -. o. .' t . .. .. " , 1 NOTICE TO PUBLISHER) ADVERTISING ORDER NO. INv~.i::. MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER f\\..,. CERTIFIED AO 02314041 AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COPY OF - ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE ~ Anchorage Daily News POBox 149001 Anchorage, AK 99514 AGENCY CONTACT 10dy Colombie PHOI\IE (907) 793 -1 ,)?1 DATES ADVERTISEMENT REQUIRED: April 4, 2003 DATE OF A.O. F AOGCC R 333 West 7th Avenue, Suite 100 0 Anchorage, AK 99501 M Anri] 3, ?003 PèN THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: Account #STOF0330 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 2003, and thereafter for - consecutive days, the last publication appearing on the - day of . 2003, and that the rate charged thereon is not in excess of the rate charged private individuals. Subscribed and sworn to before me This - day of 2003, Notary public for state of My commission expires 02-901 (Rev. 3/94) Page 2 AO.FRM PUBLISHER Re: Notice ') ') Subject: Re: Notice Date: 03 Apr 2003 16:05:36 -0900 From: Legal Ads Anchorage Daily News <legalads@adn.com> To: Jody Colombie <jody_colombie@admin.state.ak.us> Hi Jody: Following is the confirmation information on your legal notice. Please let me know if you need anything further. Account Number: STOF 0330 Legal Ad Number: 760133 Publication Date{s): April 4, 2003 Your Reference #: AO-02314041 Total: $219.96 Thank You, Kim Kirby Anchorage Daily News Legal Classified Representative E-Mail: legalads@adn.com Phone: (907) 257-4296 Fax: (907) 279-8170 On Thursday, April > >Please publish in > >Thank You. Jody 3, 2003, Jody Colombie <jody_colombie@admin.state.ak.us> wrote: tomorrow paper if possible. 10fl 4/3/2003 4:05 PM