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Home My WebLink AboutAIO 022 A .~ ~. AREA INJECTION ORDER FILE COVER PAGE XHVZE This page identifies oversize material and digital information available for this individual Order file and weather or not it is available in the LaserFiche file. Please insure that it remains as the first page in this file. Ilfo ¿Jtf¡;( A Area Injection Order File Scan Date.f )rInit.~ Color Materials #~ Scanned in:W Color Circle ~ 0 Added (date) Init. ~ Init. Greyscale # - Digital Data 0 CD's - # 0 DVD's - # 0 Diskettes - # OCompleted (date) Init. Added to LaserFiche File 0 YesO No 0 YesO No 0 YesO No Init. Init. Init. Maps Mud Logs Other # ¡ # # Added to LaserFiche File 0 Yes'\(No Initl/¡v-J 0 Yes 0 No Init. 0 Yes 0 No Init. Oversized Material General Notes or Comments about this file. If any of the information listed above is not available in the LaserFiche file, or if you have any questions or information requests regarding this file, you may contact the Alaska Oil & Gas Conservation Commission to request copies at 279-1433, or email us at: AOGCC_Librarian@admin.state.ak.us .~ 1) December 9, 2002 2) January 28,2003 3) February 26,2003 4) March 3, 2003 5) March 4, 2003 6) March 4, 2003 7) March 6, 2003 ~ Aro ORDER NO. 22A AURORA OIL POOL BPXA's Aurora pool Area Injection Order Modification request Notice of Hearing, Affidavit of Publication, mailing list BPXA's non-confidential version ofEOR forecast Confidential portion located in Confidential room Agency request to operator for more information and Confidential Memo to File from Engineer Sign in Sheet for hearing Transcript BPXA's submittal of Aurora Cume Voidage by Fault Block AREA INJECTION ORDER 22A Dated April 3, 2003 . r"" ~, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue, Suite 100 Anchorage Alaska 99501 Re: THE APPLICATION OF BP EXPLORATION (ALASKA) INC. for an order allowing underground injection of fluids for enhanced oil recovery in Aurora Oil Pool, Prudhoe Bay Field, North Slope, Alaska ) Prudhoe Bay Field ) Aurora Oil Pool ) ) ) ) ) Order Granting Rehearing of Area Injection Order No. 22A and Decision upon Rehearing On April 3, 2003, the Commission issued Area Injection Order No. 22A, denying the application of BP Exploration (Alaska) Inc. ("BPXA") for authorization of underground injection of miscible injectant for enhanced oil recovery in the Aurora Oil Pool, Prudhoe Bay Field. On April 28, 2003, BPXA applied for rehearing under AS 31.05.080(a). The Commission has considered BPXA's application for rehearing and the written materials submitted in support of that application and has determined that they are sufficient to justify rehearing of Area Injection Order No. 22A. The Commission has further determined that the documents submitted are sufficient to rule on the merits of the application without need for a further oral hearing. The Commission's ruling on the merits is contained in Area Injection Order No. 22B, which is incorporated herein by reference. IT IS SO ORDERED. DONE at Anchorage, Alaska and dated May 6, 2003. -, n, Chair Alaska Oil and Gas nservation Commission ~ £4'</{ Randy Ruedrich, Commissioner Al..,:{ka, O~d3as Conservation Commission ø~~~ Daniel T. Seañí"'óunt, Jr., Commissioner Alaska Oil and Gas Conservation Commission I This is the Commission's fmal order in this matter. A party has 30 days from the date the Commission mails I (or otherwise distributes) this order to appeal the decision to Superior Court. SD Dept of Env & Natural Resources Oil and Gas Program 2050 West Main, Ste 1 Rapid City, SD 57702 Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 G. Havran Gaffney, Cline & Associations Library 1360 Post Oak Blvd., Ste 2500 Houston, TX 77056 Chevron USA Alaska Division PO Box 1635 Houston, TX 77251 Shelia McNulty Financial Times PO Box 25089 Houston, TX 77265-5089 Robert Gravely 7681 South Kit Carson Drive Littleton, CO 80122 Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 Samuel Van Vactor Economic Insight Inc. 3004 SW First Ave. Portland, OR 97201 Susan Hill State of Alaska, ADEC EH 555 Cordova Street Anchorage, AK 99501 ~, Christine Hansen Interstate Oil & Gas Compact Comm Excutive Director PO Box 53127 Oklahoma City, OK 73152 Paul Walker Chevron 1301 McKinney, Rm 1750 Houston, TX 77010 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 Shawn Sutherland Unocal Revenue Accounting 14141 Southwest Freeway Sugar Land, TX 77478 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 John Levorsen 200 North 3rd Street, #1202 Boise, ID 83702 Thor Cutler OW-137 US EPA agion 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 r"' John Katz State of Alaska Alaska Governor's Office 444 North Capitol St., NW, Ste 336 Washington, DC 20001 Citgo Petroleum Corporation PO Box 3758 Tulsa, OK 74136 David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 Texico Exploration & Production PO Box 36366 Houston, TX 77236 Chevron Chemical Company Library PO Box 2100 Houston, TX 77252-9987 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 Cammy Taylor 1333 West 11th Ave. Anchorage, AK 99501 Trustees for Alaska 1026 West 4th Ave., Ste 201 Anchorage, AK 99501-1980 John Harris NI Energy Development Tubular 3301 C Street, Ste 208 Anchorage, AK 99503 Schlumberger Drilling and Measurements 3940 Arctic Blvd., Ste 300 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Jeanne Dickey BP Exploration (Alaska), Inc. Legal Department PO Box 196612 Anchorage, AK 99518 Kevin Tabler Unocal PO Box 196247 Anchorage, AK 99519-6247 Kenai Peninsula Borough Economic Development Distr 14896 Kenai Spur Hwy #103A Kenai, AK 99611-7000 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 9966g.:.2139 Harry Bader State of Alaska Department of Natural Resources 3700 Airport Way Fairbanks, AK 99709 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 ~ Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Ciri Land Department PO Box 93330 Anchorage, AK 99503 Judy Brady Alaska Oil & Gas Associates 121 West Fireweed Lane, Ste 207 Anchorage, AK 99503-2035 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 Jack Hakkila PO Box 190083 Anchorage, AK 99519 Sue Miller BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Penny Vadla Box 467 Ninilchik, AK 99639 Richard Wagner PO Box 60868 Fairbanks, AK 99706 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 Kurt Olson State of Alaska Staff to Senator Tom Wagoner State Capitol Rm 427 Juneau, AK 99801 ~, Mark Hanley Anadarko 3201 C Street, Ste 603 Anchorage, AK 99503 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 Jim Scherr US Minerals Management Service Resource Evaluation 949 East 36th Ave., Ste 308 Anchorage, AK 99508 David Cusato 600 West 76th Ave., #508 Anchorage, AK 99518 Tesoro Alaska Company PO Box 196272 Anchorage, AK 99519 BP Exploration (Alaska), Inc. Land Manager PO Box 196612 Anchorage, AK 99519-6612 James Gibbs PO Box 1597 Soldotna, AK 99669 Cliff Burglin PO Box 131 Fairbanks, AK 99707 North Slope Borough PO Box 69 Barrow, AK 99723 Lt Governor Loren Leman State of Alaska PO Box 110015 Juneau, AK 99811-0015 New orders ~, ~ Subject: New orders Date: Wed, 07 May 2003 15:13:02 -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> ,"""""""""""""""<""~"'ë<"«""""""""<""T'~'"""""""<"«"'" ""'«'m~"""'«-""""~'< , i Name: AIO 22 B.doc I ~AIO 22 B.docl Type: WINWORD File (applicationlmsword)i ,«..~..,~~~ ~~~~~i~~~,?~~64 ; ,,"'f """"",.. .-,<""..,..,......-."....""""." ,« < "'T""""'" ""<""""'" ! Name: aurora rehearing decision.doc ~aurora rehearing decision.doc! Type: WINWORD File (applicationlmsword) I Encoding: base64 """'«,,'~~'" <.~..,'" ,-,«.. ' " Name: jody_colombie.vcf ]jody colombie.vcf E Td~pe: V7b~tard (text/x-vcard) , nco mg: 1 'Description: Card for Jody Colombie! "",.."«"'....""",,, """""""w"~-,",..",, ,<""...,<",..<,w~" """" ..<..,..,.""", '<m,,' 1 of! 5/7/20033:13 PM Ala 22A and Ala 228 ~, ,~ Subject: AIO 22A and AIO 22B Date: Wed, 07 May 2003 15:12:12 -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>, trmjr 1 <trmjr I @ao1.com>, jbriddle <jbriddle@marathonoi1.com>, rockhill <rockhill@aoga.org>, shaneg <shaneg@evergreengas.com>, rosew <rosew@evergreengas.com>, jdarlington <jdarlington@forestoi1.com>, nelson <nelson@gcLnet>, cboddy <cboddy@usibellLcom>, "markdalton" <markdalton@hdrinc.com>, "shannon.donnelly" <shannon.donnelly@conocophillips.com>, "mark. p. worcester" <markp. 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 F" <KirchnJF@BP.com>, "Pospisil, Gordon" <PospisG@BP.com>, "Sommer, Francis S" <SommerFS@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>, ajiii88 <ajiii88@hotmai1.com>, doug_schultze <doug_schultze@xtoenergy.com>, "hank.alford" <hank.alford@exxonmobi1.com>, yesnol <yesnol@gcLnet>, "john.w.hanes" <john.w.hanes@exxonmobi1.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>, jackJaasch <jackJaasch@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" <j effrey. walker@mms.gov>, tressler <tressler@cirLcom>, claire caldes <claire caldes@fws.gov>, jacobsenje <jacobseñje@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.com> lof2 5/7/20033:13 PM AIO 22A and AIO 22B ~, ~ Orders processed on May 6, 2003 at the AOGCC. Jody "---,-"_www_w..~"-_www,,ww.w~w,w,'~,,w~-,~w_w,"'~,ww-~'w,'-"" ,Ww,ww",w,"_w.'"" '" "_w-.-w" w'-'_' --~""ww,-""" ,w'w~-,J ,', '",w,-""" , "",'w""" ", '" w , "..""" , Name: Ala 22 B.doc . ~AIO 22 B.doci Type: WINWORD File (applicationlmsword)i "",JEnc.?ding.: base64 ,-.", ,,', ,. ,,' "'"w,w,ww.",,-' "w""--"'-_w_",,,,, ,w ,""""'". """."""""-,,,.. "w""""""" ! Name: aurora rehearing decision.doc '~aurora rehearing decision.doc! Type: WINWORD File (applicationlmsword)1 w" " , .' J,~nco~~~: base64 ," "-' , """"....1 Name: jody _colombie. vcf D. d , I b. , f', Type: VCard (text/x-vcard) Jo Y co om le.VC' E d. 7b't ; nco fig: 1 '))es~~~ptio~~ Card~owr Jo~~~?~?~1Ji~) 2 of2 5/7/20033:13 PM -.. r"i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue, Suite 100 Anchorage Alaska 99501 Re: THE APPLICATION OF BPXA EXPLORATION (ALASKA) INC. for an order allowing underground injection of fluids for enhanced oil recovery in Aurora Oil Pool, Prudhoe Bay Field, North Slope, Alaska ) Prudhoe Bay Field ) Aurora Oil Pool ) ) Area Injection Order No. 22A ) ) April 3, 2003 IT APPEARING THAT: 1. By letter and application dated December 9,2002, BPXA Exploration (Alaska) Inc. ("BPXA") requested an order from the Alaska Oil and Gas Conservation Commission ("Commission") modifying Area Injection Order No. 22 (corrected version, dated September 17, 2001) authorizing underground injection of miscible injectant ("MI") for enhanced oil recovery in the Aurora Oil Pool ("AOP"), Prudhoe Bay Field, on the North Slope of Alaska. Notice of opportunity for public hearing was published in the Anchorage Daily News on January 28,2003. The Commission did not receive any protests or comments concerning this application. A hearing concerning BPXA's request was convened in confonnance with 20 AAC 25.540 at the Commission's offices, 333 W. ih Avenue, Suite 100, Anchorage, Alaska 99501 on March 4,2003. 2. 3. 4. 5. BPXA provided additional information on February 28, 2003 and on March 7, 2003. FINDINGS: 1. Operators/Surface Owners (20 AAC 25.402(c)(2) and 20 AAC 25.403(c)(3)) BPXA is the designated operator of the AOP. BPXA, ExxonMobil Production Company, ConocoPhillips Inc., Chevron USA Production, and Forest Oil Corporation are working interest owners. The State of Alaska is the landowner. ~ ,---, Area Injection Order 22 . . April 3, 2003 Page 2 of 11 2. Project Area Requested for Enhanced Recovery: The AOP is defined as an accumulation of oil that is common to, and correlates with, the interval between 6765'- 7765' measured depth ("MD") in the Mobil Oil Corporation Mobil-Phillips North Kuparuk State No. 26-12-12 well. The geology of the AOP is described in Conservation Order 457 ("CO 457") and Area Injection Order No. 22 ("AIO 22"). Description of Operation (20 AAC 25.402(c)(4)) The AOP is developed from the Prudhoe Bay S-Pad. Tract operations within the pool began in November 2000. The Commission approved water injection with the issuance of AIO 22 on September 7, 2001. The proposed project involves the cyclical injection of water alternating with enriched hydrocarbon gas into the oil column of the Kuparuk River Formation of the AOP. The injectant will be comprised of hydrocarbon gas, enriched with intermediate hydrocarbons, principally ethane and propane, which is designed to be miscible with the reservoir oil. The proposed source of this enriched gas is offtake from pools within the Prudhoe Bay Unit and processed within the Prudhoe Bay Central Gas Facility. Requested timing for injection of enriched gas into the AOP is second quarter of 2003 with initial conversion of S-1O4i. Wells S-lOli, S-1O4i, S-107i, S-1l2i, and S-114Ai would be converted to allow for future injection of enriched gas. Well Logs (20 AAC 25.402(c)(7)) 3. 4. 5. W ell logs for the proposed injection wells are on file with the Commission. Mechanical Integrity (20 AAC 25.402(c)(8)) All newly drilled and converted injection wells have been completed in accordance with 20 AAC 25.412, thus satisfying mechanical integrity requirements. Thecasing programs for S-lOli, S-1O4i, S-1O7i, S-112i, and S-114Ai were permitted and completed in accordance with 20 AAC 25.030. Injection well tubulars have premium threads to prevent tubing leaks and maintain integrity during injection of enriched gas. Cement bond logs (ultra sonic imaging tool) run in Wells S-1O4i and S-112i indicate good cement bond across and above the Kuparuk River Formation. The Commission has approved water-flow logs completed in Wells S-IOli, S-107i and S- I 14Ai to confirm injection containment into the target zone. Injection Fluid and Rates (20 AAC 25.402(c)(9)) a. Source Water and Produced Water: The Aurora waterflood project uses produced water from GC-2. The composition of GC-2 produced water and compatibility issues were addressed in the original AIO 22 application. With increased surface pressures, maximum water injection capacity at AOP is estimated at 40,000 BPD. 6. ,~~, ,,-.... Area Injection Order 22 .- April3, 2003 7. 8. 9. Page 3 of 11 b. Miscible Hydrocarbon Gas: The proposed project requests approval for injection of enriched gas from the Prudhoe Bay Central Gas Facility. The enriched gas is hydrocarbon with similar composition to reservoir fluids in the AOP and therefore no compatibility issues are anticipated in the formation or confining zones. Planned maximum enriched gas injection at AOP are estimated at 20 million SCF per day. Injection Pressures (20 AAC 25.402(c)(1O)) Enriched gas and water injection operations at the AOP are expected to be above the Kuparuk River Formation parting pressure to enhance injectivity and improve recovery of oil. Maximum proposed surface injection pressure is 2800 psi for water and 3800 psi for gas. Fracture Information (20 AAC 25.402(c)(lI)) With a maximum surface water injection pressure of 2800 psi, the injection gradient will be 0.85 psi/ft, assuming no friction losses, which will not propagate fractures through the confining layers. The overlying Kalubik and HRZ shales, which have a combined thickness of approximately 110 feet, have a fracture gradient 0.8 to 0.9 psi/ft. The underlying Miluveach/Kingak shale sequence has a fracture gradient of approximately 0.85 psi/ft. Water Analysis (20 AAC 25.402(c)(12)) 10. The compositions of injection water and AOP connate water were provided in Exhibit IV -4 of the original AIO application. Aquifer Exemption (20 AAC 25.402(c)(13)) On July 11, 1986, the Commission approved Aquifer Exemption Order I ("AEO 1 ") for Class II injection activities within the Western Operating Area of the Prudhoe Bay Unit. The AOP is entirely within the area covered by AEO-l. Hydrocarbon Recovery and Reservoir Impact (20 AAC 25.402(c)(l4)) On September 7, 200 I, BPXA testified the in place oil was 110-146 million barrels, and free gas was 15 to 75 billion standard cubic feet. BPXA projected primary and watertlood recovery to be 30-40 million STB (roughly 27% with an upside potential of approximately 34%). A recovery percentage of 12% was projected for primary only. Additional reserves of 3-5% were projected with miscible gas injection, suggesting about 4 million barrels recovery if applicable to the entire AOP. These recovery percentages are consistent with those reported for other Kuparuk River Formation pools. The projected enhanced recovery reserves from watertlood plus miscible gas is roughly 12 to 26 million barrels, more than double that expected from primary production (13-18 million barrels). BPXA testified that the reservoir pressure at which the enriched gas is miscible with the reservoir oil is about 2700 psi. BPXA testified that the reservoir pressures are about 2000 to 2500 psi within the West block, and 3000 and 3100 psi within the 11. ~ ~ Area Injection Order 22 o. April 3, 2003 Page 4 oft 1 North of Crest Block, and South-East of Crest Block, respectively. However, Commission records of well reservoir pressure measurements for 2002 show some wells (S-1O5 and 8-108) within the North of Crest Blocks and South-East of Crest Blocks to be below 2700 psi. These pressures may not be representative due to factors such as insufficient shut-in time or inaccurate method of gathering. Figures I, 2, and 3 illustrate pressures by well and block as compared to minimum miscibility pressure. Table I and Figure 4 show the AOP production history compiled from the Commission's production database. Net voidage calculations were performed using the fluid volume factors supplied by BPXA. Through January 31,2003, cumulative production was 4.6 million stock tank barrels ("8TB") of oil, 1.1 million barrels of water, and 26.7 billion standard cubic feet ("SCF") of gas. Produced water injection from Gathering Center 2 ("GC-2") was 3.9 million barrels. Cumulative net voidage is approximately 22 million reservoir barrels, excluding gas cap expansion and aquifer influx. Aurora produced gas is currently used within the Prudhoe Bay Unit facilities as fuel or injected into the Sadlerochit gas cap. Current net voidage rates reported within the West, North of Crest and South-East of Crest Blocks are 25,000, 6,000 and 5,000 reservoir barrels per day, respectively. Cumulative net voidage within these blocks is 17 million barrels, 3.7 million barrels, and 1.7 million barrels, respectively. BPXA plans to begin water injection within S-114Ai of the West Block soon, at an expected injection rate of 10,000-15,000 barrels per day. Additionally, wells S-112 and S-llO are planned for injection. Facilities projects are currently being "considered" to increase the water source volume for injection and to increase water injection pressure. With these "considered" additions, BPXA projects that AOP water injection rates will increase to 40,000 barrels per day from the current injection rate of 10,000 barrels per day. While BPXA testified that reservoir simulation shows reservoir pressure within the West Block will be restored to above minimum miscibility by the end of 2003, it is not apparent how this will be accomplished without curtailment of production. AOP production and waterftood operations are not being conducted in a manner consistent with testimony provided in support of Conservation Order 457. BPXA on behalf of the Aurora Working Interest Owners, testified that their "reservoir management strategy is, once water injection commences, we will inject at a VRR of greater than 1.0 to restore reservoir pressure." BPXA further committed to inject at a balanced VRR to maintain reservoir pressure. Enhanced recovery reserves from miscible injection and from waterflood may be jeopardized if reservoir pressure is not restored. Additional reservoir pressure information appears needed to set an appropriate path forward for the depletion of the reservoir. The following wells are recommended for shut-in bottom hole pressure measurements to insure the reservoir is not overdepleted. If the wells shut- in reservoir pressure are below the reported minimum miscibility pressure, further .~ ----" Area Injection Order 22 ~ ~ April 3, 2003 Page 5 of 11 production curtailment should be considered. Wells in order of priority and concern are as follows: . S-106 West Block. Low measured reservoir pressures (2254 psi (2/9/02)), high GORs indicating possible over depletion. . S-102 West Block. Low measured reservoir pressures (2199 psi (4/10/02)), high GORs (10,000 scf/STB in December). This well is currently being curtailed. Pressure measurement would not impact production. . S-1O5 NOC block. This is the initial block planned for miscible injection. Reservoir pressure measurement suggests this well to be near or below 2700 pSI. . S-IOO West Block. Extremely high voidage cumulative and overall rates (12 MMRVB). . S-108 High GOR. Low recorded reservoir pressure. communication with remaining wells in block. May not be in *The above evaluation is based upon information supplied to the Commission as of March 7,2003. 12. Mechanical Condition of Adjacent Wells (20 AAC 25.402(c)(l~j) Mechanical integrity has been established for the wells within ~ mile radius of proposed injectors. Mechanical integrity is based upon calculated cement tops being at an adequate height above the injection zone to prevent fluid that is injected into the AOP from flowing into other zones or to the surface. CONCLUSIONS: 1. BPXA's application and testimony fulfills the general requirements of 20 AAC.25.402, except that the proposed injection of fluids has not been shown to function primarily to enhance recovery of oil and gas under current reservoir conditions. The project has been represented as a miscible injection project and, as such, it is implied that the reservoir pressure is above minimum miscibility pressure. Measurements suggest reservoir pressures are below minimum miscibility in the West Block and possibly within portions of the Southeast of Crest Block and North of Crest Block. 2. 3. AOP production and waterflood operations are not being conducted in a manner consistent with testimony provided in support of Conservation Order 457 Cumulative net reservoir voidage is 22.4 million barrels, and is increasing by 4. ~ /--', Area Injection Order 22 L L April 3, 2003 Page 6 of 11 5. approximately 26,000 barrels each day. BPXA's current reservoir management strategy is unclear. A comprehensive reservoir management plan is required which addresses water injection and repressurization of the reservoir in preparation for miscible gas injection to ensure greater ultimate recovery of the oil in the AOP. Enhanced oil recovery operations may be jeopardized unless reservoir voidage is replenished and reservoir pressure is increased. Additional reservoir pressure measurements are required to determine if enriched gas should be injected, and the course of action to take for repressurization if measurements show the blocks to be below minimum miscibility pressure. Reservoir pressure measurements within the following wells are needed. . West Block: S-106, S-lOO, 8-102 . SE of Crest Block: S-108 . North of Crest Block: 8-105 6. 7. NOW, THEREFORE, IT IS ORDERED THAT: BPXA's application for injection of enriched gas in Aurora Oil Pool is denied without prejudice to BPXA's right to renew its application at a later date. ""-----" DONE at Anchorage, Alaska and dated APn",,',,~.,~,,-,~_OO3. , /,'" )¡ ~, I~ Øt\\ ~<> ~I ~,:¡ , Sarah fa!' ,Chai; \J . /. ~ ~III ~~!> Alaska Oil and Gas Conservat~on Commission - ~ .~~;~-~ 4-.~ ~k~ ,-~ ) " . ~ 0. ; ¿;? : ' '. - Randy Ru rIch, CommIssIoner % ¡ J :;:.. - Alaska Oil and Gas Conservation Commission . Jj Jj)~. . DanIel T. Seamøùnt, Jr., CommIssIoner Alaska Oil and Gas Conservation Commission AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23rd day following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the lO-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or othetWise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30 day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., 10th day after the application for rehearing was filed). ".-' '-\Du..",-C\ \ ~~~- A- ~(. Area Injection Order 22 A Page 7 of 11 April 3, 2003 TABLE 1 Production Aurora Wells - January 2003 * Well Oil, Water, Gas, WI,BD Cum Oil, Cum Water, Cum Gas Cum WI, """ Cum Net STBD BPD MSCFD MSTB MB Prod, MSCF MBBL Voidage, Million Barrels 5-103 2,179 1,555 2,748 0 959 589 1,029 0 2.2 5-105 510 63 3,096 0 331 418 828 0 1.4 5-104 0 0 0 3,238 75 5 64 554 -0.51 ( Total NOC 2,689 1,618 5,844 3,238 1,365 1,012 1,921 554 3.1 5-108 389 23 5,465 0 164 9 1,427 0 1.3 5-110 0 0 0 0 131 9 267 0 0.3 5-112 272 10 285 0 43 0 35 0 0.1 5-109 0 0 0 0 0 0 0 0 0.01 SE 661 33 5,750 0 339 18 1,729 0 1.7 5-100 2,638 120 10,248 1,641 11 12,979 0 12.2 5-106 1,478 323 9,501 789 53 5,579 0 5.3 5-102"""* 324 9 2,869 0 2.7 5-113B 1,083 0 3,465 110 0 275 0 0.3 5-114A 0 0 1 0 0.0 5-101 1,348 61 1 1,316 2,186 -2.2 5-107 5,066 4 13 7 1,150 -1.21 Total West 5,199 443 23,214 6,414 2,929 87 23,026 3,336 17.1 ( Total Aurora 8,549 2,094 34,808 9,652 4,632 1,117 26,675 3,890 21.9 '" January 2003 production numbers in Commission database. Further validation is required. """ Commission 5taff computation using V-200 PVT Data Exhibit 11-3 of Aurora Pool Rules submittal of July 23, 2001 Compares with BP 5ubmittal Voidage Calculations of 3.7 Million RVB, 1.7 Million RVB and 17 Million RVB at NOC, 5EC and West Fault Blocks These voidage volumes do not account for effects of Aquifer Influx or gas-cap expansion Area Injection Order 22 A April 3, 2003 390D 3700 3500 3300 31 CJD p = 2900 27T LL 2500 2300 21 CO 19C0 1700 Figure 1 ftstem Aurora 5-100 ' S-101 i --f'5-102 �... S-106 �— 5-1071 14 krra n Msdb&ty Pressure = 2 700 psi i 15rJ] 11`20:10 4f C 10D 712:0-1 9iJ100 12rS100 ;A,'2 T1 6.Q001 9f21i1:r1 120DR1 Y2C i 12 &2002 912002 12C2002 3003 htdhh'ear Page 8 of 11 Area Injection Order 22 A April 3, 2003 Page 9 of I I Figure 2 North of Crest 3500 3300 3100 a t/J w 2900 0 0 ti 0 2700 m 2500 a 0 2300 m w m 2100 m 1` 0 4 1900 w 1700 1500 1 i i I 1/2000 4/2000 7/2000 9/2000 12/2000 3/2001 6/2001 9/2001 12/2001 3/2002 6/2002 9/2002 12/2002 3/2003 Date Area Injection Order 22 A April 3, 2003 3500 3300 a 3100 a 0 2900 �o 2700 a a a 2500 'o m 2300 m 2100 0 a 1900 1700 Figure 3 South East Of Crest Crest Minimum Miscibility Pressure = 2700 psi x X S-110 — - —S-108 1500 1/2000 4/2000 7/2000 9/2000 12/2000 3/2001 6/2001 9/2001 12/2001 3/2002 6/2002 9/2002 12/2002 3/2003 Date Page 10 of 11 Area Injection Order 22 A April 3, 2003 70000 60000 50000 m 0 40000 d 'e c 30000 10000 0 1 /2000 Figure 4 Aurora Production and Injection —o —Gas, MSCFD Resemir Voidage, BPD Q A Water Injection, .� Q'CS . BPD -e Oil, STBD . . ♦ Water, BPD —Cumulative� • 4 Q Resemir Voidage, MBBL • W_. 4/2000 7/2000 9/2000 12/2000 3/2001 6/2001 9/2001 12/2001 3/2002 6/2002 9/2002 12/2002 3/2003 Date Page I I of I I Daniel Donkel 2121 North Bayshore Drive, Ste 1219 Miami, FL 33137 Jim Yancey Seal-Tite International 500 Deer Cross Drive Madisonville, LA 70447 Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 Paul Walker Chevron 1301 McKinney, Rm 1750 Houston, TX 77010 David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 T.E. Alford ExxonMobii Exploration Company PO Box 4778 Houston, TX 77210-4778 Chevron USA Alaska Division PO Box 1635 Houston, TX 77251 Shelia McNulty Financial Times PO Box 25089 Houston, TX 77265-5089 James White Intrepid Prod. Co.lAlaskan Crude 4614 Bohill SanAntonio, TX 78217 "---- SD Dept of Env & Natural Resources Oil and Gas Program 2050 West Main, Ste 1 Rapid City, SD 57702 Christine Hansen Interstate Oil & Gas Compact Comm Excutive Director PO Box 53127 Oklahoma City, OK 73152 Gregg Nady Shell E&P Company Onshore Exploration & Development PO Box 576 Houston, TX 77001-0576 G. Scott Pfoff Aurora Gas, LLC 10333 Richmond Ave, Ste 710 Houston, TX 77042 William Holton, Jr. Marathon Oil Company Law Department 5555 San Fecipe St. Houston, TX 77056-2799 Texico Exploration & Production PO Box 36366 Houston, TX 77236 Donna Williams World Oil Statistics Editor PO Box 2608 Houston, TX 77252 Shawn Sutherland Unocal Revenue Accounting 14141 Southwest Freeway SugarLand,TX 77478 Doug Schultze XTO Energy Inc. 3000 North Garfield, Ste 175 Midland, TX 79705 ~ John Katz State of Alaska Alaska Governor's Office 444 North Capitol St., NW, Ste 336 Washington, DC 20001 Alfred James 200 West Douglas, Ste 525 Wichita, KS 67202 Citgo Petroleum Corporation PO Box 3758 Tulsa, OK 74136 Michael Nelson Purvin Gertz, Inc. Library 600 Travis, Ste 2150 Houston, TX 77002 G. Havran Gaffney, Cline & Associations Library 1360 Post Oak Blvd., Ste 2500 Houston, TX 77056 W. Allen Huckabay ConocoPhillips Petroleum Company Offshore West Africa Exploration 600 North Dairy Ashford Houston, TX 77079-1175 Corry Woolington ChevronTexaco Land-Alaska PO Box 36366 Houston, TX 77236 Chevron Chemical Company Library PO Box 2100 Houston, TX 77252-9987 Kelly Valadez Tesoro Refining and Marketing Co. Supply & Distribution 300 Concord Plaza Drive San Antonio, TX 78216 Robert Gravely 7681 South Kit Carson Drive Littleton, CO 80122 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 John Levorsen 200 North 3rd Street, #1202 Boise, ID 83702 Samuel Van Vactor Economic Insight Inc. 3004 SW First Ave. Portland, OR 97201 Cammy Taylor 1333 West 11th Ave. Anchorage, AK 99501 Duane Vaagen Fairweather 715 L Street, Ste 7 Anchorage, AK 99501 Tim Ryherd State of Alaska Department of Natural Resources 550 West 7th Ave., Ste 800 Anchorage, AK 99501 Ed Jones Aurora Gas, LLC Vice President 1029 West 3rd Ave., Ste 220 Anchorage, AK 99501 Mark Dalton HDR Alaska 2525 C Street, Ste 305 Anchorage, AK 99503 Mark Hanley Anadarko 3201 C Street, Ste 603 Anchorage, AK 99503 Schlumberger Drilling and Measurements 3940 Arctic Blvd., Ste 300 Anchorage, AK 99503 r-'" 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 Thor Cutler OW-137 US EPA agion 10 1200 Sixth Ave. Seattle, WA 98101 Richard Mount State of Alaska Department of Revenue 500 West 7th Ave., Ste 500 Anchorage, AK 99501 Jim Arlington Forest Oil 310 K Street, Ste 700 Anchorage, AK 99501 William VanDyke State of Alaska Department of Natural Resources 550 West 7th Ave., Ste 800 Anchorage, AK 99501 Trustees for Alaska 1026 West 4th Ave., Ste 201 Anchorage, AK 99501-1980 Jack Laasch Natchiq Vice President Government Affairs 3900 C Street, Ste 701 Anchorage, AK 99503 John Harris NI Energy Development Tubular 3301 C Street, Ste 208 Anchorage, AK 99503 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 .~ Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 John F. Bergquist Babson and Sheppard PO Box 8279 Long Beach, CA 90808-0279 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle, WA 98119-3960 Julie Houle State of Alaskan DNR Div of Oil & Gas, Resource Eva!. 550 West 7th Ave., Ste 800 Anchorage, AK 99501 Susan Hill State of Alaska, ADEC EH 555 Cordova Street Anchorage, AK 99501 Robert Mintz State of Alaska Department of Law 1031 West 4th Ave., Ste 200 Anchorage, AK 99501 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Rob Crotty C/O CH2M HILL 301 West Nothern Lights Blvd Anchorage, AK 99503 Ciri Land Department PO Box 93330 Anchorage, AK 99503 Judy Brady Alaska Oil & Gas Associates 121 West Fireweed Lane, Ste 207 Anchorage, AK 99503-2035 Arlen Ehm 2420 Foxhall Dr. Anchorage, AK 99504-3342 Rose Ragsdale Rose Ragsdale & Associates 3320 E. 41st Ave Anchorage, AK 99508 Jim Scherr US Minerals Management Service Resource Evaluation 949 East 36th Ave., Ste 308 Anchorage, AK 99508 Chuck O'Donnell Veco Alaska,lnc. 949 East 36th Ave., Ste 500 Anchorage, AK 99508 Barbara Fullmer ConocoPhillips Alaska, Inc. Legal Department A TO 2084 PO Box 100360 Anchorage, AK 99510-0360 Jordan Jacobsen Alyeska Pipeline Service Company Law Department 1835 So. Bragaw Anchorage, AK 99515 Jeanne Dickey BP Exploration (Alaska), Inc. Legal Department PO Box 196612 Anchorage, AK 99518 Bill Bocast PACE Local 8-369 c/o BPX North Slope, Mailstop P-8 PO Box 196612 Anchorage, AK 99519 Sue Miller BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Bob Shavelson Cook Inlet Keeper PO Box 3269 Homer, AK 99603 ~ Greg Noble Bureau of Land Management Energy and Minerals 6881 Abbott Loop Rd Anchorage, AK 99507 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Paul L. Craig Trading Bay Energy Corp 5432 East Northern Lights, Ste 610 Anchorage, AK 99508 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 Kristen Nelson IHS Energy PO Box 102278 Anchorage, AK 99510-2278 Robert Britch, PE Northern Consulting Group 2454 Telequana Dr. Anchorage, AK 99517 Jack Hakkila PO Box 190083 Anchorage, AK 99519 J. Brock Riddle Marathon Oil Company Land Department PO Box 196168 Anchorage, AK 99519-6168 BP Exploration (Alaska), Inc. Land Manager PO Box 196612 Anchorage, AK 99519-6612 Peter McKay 55441 Chinook Rd Kenai, AK 99611 .~ Jeff Walker US Minerals Management Service Regional Supervisor 949 East 36th Ave., Ste 308 Anchorage, AK 99508 Richard Prentki US Minerals Management Service 949 East 36th Ave., 3rd Floor Anchorage, AK 99508 Thomas R. Marshall, Jr. 1569 Birchwood Street Anchorage, AK 99508 Jim Ruud ConocoPhillips Alaska, Inc. Land Department PO Box 100360 Anchorage, AK 99510 Perry Markley Alyeska Pipeline Service Company Oil Movements Department 1835 So. Bragaw - MS 575 Anchorage, AK 99515 David Cusato 600 West 76th Ave., #508 Anchorage, AK 99518 Tesoro Alaska Company PO Box 196272 Anchorage, AK 99519 Kevin Tabler Unocal PO Box 196247 Anchorage, AK 99519-6247 Dudley Platt D.A. Platt & Associates 9852 Little Diomede Cr. Eagle River, AK 99577 Shannon Donnelly Phillips Alaska, Inc. HEST -Enviromental PO Box 66 Kenai, AK 99611 Kenai Peninsula Borough Economic Development Distr 14896 Kenai Spur Hwy #103A Kenai,AK 99611-7000 James Gibbs PO Box 1597 Soldotna, AK 99669 John Tanigawa Evergreen Well Service Company PO Box 871845 Wasilla, AK 99687 Cliff Burglin PO Box 131 Fairbanks, AK 99707 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 Lt Governor Loren Leman State of Alaska PO Box 110015 Juneau, AK 99811-0015 .~ Penny Vadla Box 467 Ninilchik, AK 99639 Claire Caldes US Fish & Wildlife Service Kenai Refuge PO Box 2139 Soldotna, AK 99669 Charles Boddy Usibelli Coal Mine, Inc. 100 Cushman Street, Suite 210 Fairbanks, AK 99701-4659 Harry Bader State of Alaska Department of Natural Resources 3700 Airport Way Fairbanks, AK 99709 North Slope Borough PO Box 69 Barrow, AK 99723 ,,-..., Marc Kovac PACE 8-369, Prudhoe Bay Vice-Chair PO Box 2973 Seward, AK 99664 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 Richard Wagner PO Box 60868 Fairbanks, AK 99706 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 Kurt Olson State of Alaska Staff to Senator Tom Wagoner State Capitol Rm 427 Juneau, AK 99801 7 8~ANNED JON 2 ~ 2004 Supplemental Data requested for Ala 22 mod ,~ .~ Subject: Supplemental Data requested for AIO 22 mod Date: Thu, 6 Mar 2003 20:13:37 -0600 From: "Young, Jim" <YoungJ3@BP.com> To: "Jane Williamson (E-mail)" <Jane- Williamson@admin.state.ak.us> CC: "Copen, James D" <CopenJD@BP.com>, "Paskvan, Frank A" <PaskvaFA@BP.com>, "Beuhler, Gil G" <BeuhleGG@BP.com> Jane, heres the info requested by Randy at the hearing Friday. I'm leaving on vacation tonight for a week, so if you need color copies of this and/or a cover letter, please contact one of the above. Verbage on including the additional fluids (Prince Creek, pit water, lean gas, etc) in the injection order is still being finalized, so I'm asking Jim Copen to follow up on that with you next week. Thanks Jim Young «Young, Jim.vcf» «Addendum to application exhibit V-l.ppt» Fault Block.ppt» «Aurora Cume voidage by Young, Jim <YoungJ3@BP.com> Production Engineer BPXA GPBIWEND Name: Addendum to application exhibit V-l.ppt 0' ... . Type: Microsoft PowerPoint Show Addendum to applIcatIOn exhIbIt V -l.ppt ( I. t. nI d . t) app Ica 10 vn .ms-powerpom Encoding: base64 -_'_-_'."_".'."."~~"_-_.'-'_._.'."'.."'.'~ I of2 4/4/20032:21 AM Fr 0 riA- if Aurora Cume Void age by Fault Block 01/03 01/0~.~ -- 01/03--' --Õ1/Õ~ stb Mcf stb stb I Oil~_~~~_~~m Gas Prod Cum Water Prod Cum Water Inj Cum ¡Net Res Void age (rb) 1,364,639 1,921,058 1,018,028. 553,637. 3,672,096 ---- _.-~_.- 338,527 1,728,657 17,976. O. 1,710,363 -.------ 2,929,005 23,025,655 86,790. 3,336,352. 17,032,718 4,632,171 26,675,370 1,122,794. 3,889,989. 22,415,177 'ì month ending: Block ¡Well ---...--....-k...---.- NOC Total S EC Total West Total ..._.~.._.... .........-..----.-.-- Grand Total - Formation Volume factors (based on V-200 PVTdata at initjalreservon-pressure) Bo 1.32 This tb oil 0.72 rblMcfgas 1.05 rb/stb water ) ~J ~ '- ~þ \TYJi'~. cd J~ V ?---bU 'i * Does not include aquifer influx or gas-cap expansion f~ (j-~()O ~'r r:>.- - I .3/(., 1<;,) 6 - ' B ð ;: . 8'<.{"3 (j2.<¡; ~. .~¿¡'i 6 SC/\NNEC' JUN 2 9 2004 ¡r---- 1 2 3 4 5 6 7 8 9 10 11 12 13 ~-- 14 15 16 17 18 19 20 21 22 23 24 25 ,~-- ~ - , , ALASKA OIL AND GAS CONSERVATION COMMISSION PUBLIC HEARING ) ) Commission's consideration of application) from BP Exploration, Alaska, for a ) Modification of Area Injection, Order 22, ) to Authorize Miscible Injectant to Enhance) Recovery from the Aurora Pool. ) ) In Re: TRANSCRIPT OF PROCEEDINGS Anchorage, Alaska March 4, 2003 9:00 o'clock a.m. COMMISSIONERS: DAN SEAMOUNT, Chairperson RANDY RUEDRICH SARAH PALIN * * * * * METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 ^ ^ ^ ORIGINAL 1 v v v /~ .~ :~" 1 TABLE OF CONTENTS 2 TESTIMONY BY MR. BEUHLER 3 TESTIMONY BY MR. COPEN 4 TESTIMONY BY MR. YOUNG 5 TESTIMONY BY MR. PASKVAN 6 7 Page 4 Page 6 Page 12 Page 15 8 9 10 11 12 13 ~" 14 15 16 17 18 19 20 21 22 23 24 25 /--". METRO COURT REPORTING 745 West Fourlh Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 2 r" /"'~' ~ .-"'\ 1 PRO C E E DIN G S 2 (On record) 3 CHAIR SEAMOUNT: Okay. This hearing is called to 4 order. The date is March 4th, 2003, the time approximately 5 9:08 a.m. Our location is 333 West Seventh Street, Anchorage, 6 7 Alaska. I'll start out Those are the offices of the AOGCC. 8 by introducing us at the front, the three Commissioners. My 9 name is Dan Seamount. At this time a chair has not been 10 designated yet, but I am presiding at this hearing by 11 agreement of the Commissioners, who are to my right, 12 Commissioner Sarah Palin, to my left, Commissioner Randy 13 Ruedrich. 14 We have present today, Assistant Attorney General Rob 15 Mintz in the back. He's going to be there to advise the 16 Commission on legal and procedural questions. Jan Scott of 17 Metro Court Reporting is making a transcript of the 18 proceedings. You can get a copy from Metro Court Reporting. 19 The subject of this hearing is to consider application 20 from BP Exploration Alaska, for a modification of area 21 injection order 22 to authorize the use of miscible injectant 22 to enhance recovery from the Aurora pool, Prudhoe Bay Field on 23 the North Slope of Alaska. 24 Notice of the hearing was published on January 28th, 25 2003, in the Anchorage Daily News. These proceedings will be METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 3 r-~, 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 ,/--', /'"""'" .~ held in accordance with 20 AAC 25.540, those are regulations that govern public hearings. This hearing will be recorded. The hearing regulations provide that we consider sworn testimony or unsworn statements. Greater weight is given to sworn statements. In addition, the application supporting materials will be entered into the hearing record. Have any written comments on the application been submitted, other than what the applicants have submitted? I don't believe so. Okay. If you wish to be considered expert, you must state your qualifications and the Commission will rule whether to consider you as an expert. We'll hear from the applicant first, then there will be an opportunity for any person in attendance to submit written questions. The way to do that is to write your questions, you should include your name, the name of the witness and forward these questions to our designated Commission representatives, which are Steve Davies and Jane Williamson, in the back there. If you two could raise your hand, if no one knows them by now. And, then the Commission will review the written questions and ask those that it believes to be helpful in eliciting the needed information. After hearing from the applicant, the Commission will hear from any other person or persons who wish to provide a statement or testimony. We have a sign-up sheet. Let's see, we have -- it METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 4 ~, 1 2 3 4 5 6 7 8 9 10 11 12 13 .'r--~ 14 15 ,,--, /""""', looks like those that will testify, BP, BP, BP and BP, so it looks like it's only the applicant's representatives that wish to testify? MR. BEUHLER: Correct. CHAIR SEAMOUNT: Okay. Okay. Does BP have any oral testimony they wish to present in support of your application? MR. BEUHLER: Yes, we do. CHAIR SEAMOUNT: Okay. So, what -- who's your first? MR. BEUHLER: I'll be going first. CHAIR BEUHLER: Okay. Raise your right hand? (Oath administered) MR. BEUHLER: I do. CHAIR SEAMOUNT: Please state your name? MR. BEUHLER: Yes, my name is Gilbert Beuhler. First- name, G-i-l-b-e-r-t, last name, B-e-u-h-l-e-r. 16 17 18 Alaska. 19 20 witness? 21 22 23 24 25 ,r~" CHAIR SEAMOUNT: And, who do you represent? MR. BEUHLER: I represent BP, British Petroleum of CHAIR SEAMOUNT: And, you wish to be an expert MR. BEUHLER: Yes, I do. CHAIR SEAMOUNT: What is the subject? MR. BEUHLER: Okay. In -- I have a prepared statement, if you prefer. CHAIR SEAMOUNT: Okay. METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 5 r----- 1 2 3 4 5 6 7 8 9 10 11 12 13 ~" 14 15 16 17 18 19 20 21 22 23 24 25 ~~-. /'"" , ~ MR. BEUHLER: Okay. I'm the greater Prudhoe Bay water flood resource manager for BP Exploration Alaska. I received a Bachelor of Science degree in petroleum engineering from the University of Kansas in 1983. I have worked in the oil industry for over 19 years with a variety of experience in the Lower 48 and Alaska. I've worked in Alaska since 1997, and have been with British Petroleum since 1998. I have testified as an expert witness in Texas, New Mexico and before the Department of Natural Resources and Oil and Gas Conservation Commission in Alaska, and I would like to be acknowledged as an expert witness? CHAIR SEAMOUNT: Commissioner Palin, do you have any questions or objections? COMMISSIONER PALIN: No objection. CHAIR SEAMOUNT: Mr. Ruedrich? COMMISSIONER RUEDRICH: No. CHAIR SEAMOUNT: Okay. Mr. Beuhler, you are accepted as an expert witness. Go ahead and proceed with your testimony. MR. BEUHLER: Thank you very much. We have prepared the Aurora Area Injection Order Modification, application submitted on December 9th, 2002, which requests modification of the area injection order number 22, to encompass injection of miscible injectant to enhance recovery from the area and to increase maximum allowable METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 6 r-. /.r---.. ~-. ,"--"" /"'" , 1 surface injection pressure from 2600 pounds to 2800 pounds 2 during water injection. And, we ask the Commission to enter 3 this application in its entirety into the record. 4 Do the Commissioner's have any CHAIR SEAMOUNT: 5 objection to have it entered into the record? 6 No objection. COMMISSIONER PALIN: 7 COMMISSIONER RUEDRICH: Sure. 8 CHAIR SEAMOUNT: Okay. It is entered into the record. 9 Thank you. And, for the purposes of MR. BEUHLER: 10 this hearing, if it pleases the Commission, we offer to 11 present excerpts of that application. 12 CHAIR SEAMOUNT: Okay. 13 MR. BEUHLER: And oral testimony. And, the Okay. 14 first section entitled "Geology and Development Drilling" will 15 be presented by James Copen. 16 CHAIR SEAMOUNT: Do you wish to be considered an 17 expert witness? 18 MR. COPEN: Yes, I do. And, I have a prepared 19 statement as well, which I would be happy to state my 20 qualifications. 21 CHAIR SEAMOUNT: Okay. Please raise your right hand. 22 (Oath administered) 23 I do. MR. COPEN: 24 CHAIR SEAMOUNT: What is your name? 25 My name is Jim Copen, that's C-o-p-e-n. MR. COPEN: METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 7 ,~, 1 2 3 4 5 6 7 8 9 10 11 12 ~, 13 14 15 16 17 18 19 20 21 22 23 24 25 .r---- r--. ~ I'm a senior development geologist with BP Exploration, Alaska. I hold a Bachelor of Science degree is geology from the University of Wyoming. I'm a registered professional geologist, certificate PG-2464. I have over 22 years in the oil and gas industry experience, including exploration and development projects in the Lower 48, in the Middle East and in Alaska. Since 1988, both as an employee and as a consultant, I have worked various development and -- or geo- science projects at Prudhoe Bay and associated fields, and I joined the Prudhoe Bay Satellites team in July of 2000. CHAIR SEAMOUNT: Mr. Ruedrich, do you have any questions or objections? COMMISSIONER RUEDRICH: No, I do not. CHAIR SEAMOUNT: I do not either, therefore, you are accepted as an expert witness, Mr. Copen. Please proceed with your testimony. MR. COPEN: Thank you. Exhibit 1-2, and by the way, we have hard copies of these if any of the Commissioners would like to refer to those during my testimony. CHAIR SEAMOUNT: Where are the hard copies? MR. COPEN: They are with Mr. Paskvan. CHAIR SEAMOUNT: Okay. Thank you. Okay. MR. COPEN: Exhibit 1-2 is a geologic structure map on the top of the Kuparuk formation. The Kuparuk formation is the producing formation at Aurora field. Contour interval on METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 8 _r---.. 5 6 7 8 9 10 11 12 13 r-'. 14 15 16 17 18 19 20 21 22 23 24 25 /~-- r--.. ~, 1 the map is 25 feet. The top of the Kuparuk structure in the 2 Aurora field area is essentially a northwest/southeast 3 trending and decline that plunges from southeast to northwest. 4 Gentle dips off to the northeast, and likewise to the southwest. The structure is broken by a -- several series of large normal faults, the most prominent of which are a north/south series here, here and then a lesser one off to the east. These will be become more relevant as my testimony continues. The major north/south fault that you see here, that bisects essentially the -- the Aurora structure, has about 200 feet of down to the west. That is, this block is down-thrown. And, as I mentioned, it effectively bisects the Aurora structure into an eastern and western halves. The west -- or the east half, excuse me, contains most, if not all of the S- pad, Prudhoe Bay, Greater Prudhoe Bay S-pad Sag and Ivishak development wells. And, the western half contains the V-200 well located right there on that really wiggly dot, which was essentially the discovery well for the Aurora accumulation. Figure 1-5 is essentially, it covers the same area, the fault pattern that we saw in that previous map. It's carried over to this exhibit, and we've taken some of the other geology off simply to clarify the picture. As shown Exhibit 5, Aurora can be divided into five structurally defined blocks. The first is the Beechey Block, western most, METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 9 ,~' 1 2 3 4 5 6 7 8 9 10 11 12 13 r--. 14 15 16 17 18 19 20 21 22 23 24 25 ~'- r---~ .'~ and its complexly faulted area and it's up-thrown to a major - - to one of these major north/south fault systems that we discussed earlier. The Beechey Point wells were drilled in this area up in here. And additionally, the 8-113, 8-114, the 8-106 and 8-107 wells have been drilled in this area. The V-200 Block is the next, to the east. It is an area of relatively simple structure between the Beechey Block on the west and the large fault on the east. The V-200 well and the first group of horizontal development wells, which include 8-100, 8-101 and 8-102 penetrate this block. Now, taken together, the Beechey Block and the V-200 Block, we often refer to these as just the west block and that -- the reasons behind that will become apparent as my testimony continues. The Crest Block shown here, is an intensely faulted area. There's far more faults in this area than there are actually depicted on the map, on the up-thrown side of this large north/south fault. The top of the Kuparuk reaches its structural quest, it's shallowest depth there, at about a depth of 6,450 feet, TVD sub C. There's about ten 8-pads, 8ag River Ivishak wells that have penetrated this block. The North of Crest Block is north of the Crest Block, not surprisingly. And again, is east of the major north/south bisecting fault. The north Kuparuk 26-12-12 exploration well and Aurora development wells 8-103, 8-104, and 8-105 provide METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 10 .~ 2 3 4 5 6 7 8 9 10 11 12 13 ,r---. 14 15 16 17 18 19 20 21 22 23 24 25 r-. ~ ~ 1 well control in the North of Crest Block. The fifth block is the 8outheast of Crest area, shown down here. It's another area east of the north -- it's actually east of yet another north/south trending fault system here, which is used to sub-divide the two. The block is less structurally complex than the Crest Block. It includes the southeastward thinning and truncation of the Kuparuk formation reservoir. There's eight 8-pad Ivishak wells penetrating the Kuparuk formation in this block, as well as more recent drilling, 8-108, 8-109, 8-110 and 8-112 development wells. The Beechey Block, again, on the western edge of the field was anticipated to contain considerable reserves¡ however, there was some question as to where the oil and gas contact was located in the Beechey Block. Well 8-106, up here on the north, was drilled in the middle of 2001, to define a gas/oil contact and prove the productivity could be realized from -- from the fault block. While the well did not intersect the GOC, production results suggested a GOC at approximately 6,678 feet TVD, sub C, which is consistent with the level found in the V-200 well, which was drilled right over here. Well, 8-107 is a horizontal well, actually aU-shaped horizontal injector, which was drilled by an injection support to 8-106 and to help reconfigure the V-200 fault block by providing another injection point north of 8-100. That is to METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 11 .~' 13 r--. 14 15 16 17 18 19 20 21 22 23 24 25 ~-, ,~ ,r", 1 say it provides injection in the Beechey Block and in the V- 2 200 Block. 3 The 80utheast of Crest Fault Block was the next 4 development area, down here. The Kuparkuk sands thinned, as we 5 mentioned earlier, significantly from northwest to southeast, 6 and are in fact truncated southeast of the field. 80, the key 7 uncertainty then is the -- is well deliver-ability, in that 8 there is less available reservoir there. Two wells were 9 drilled there in 2001 in the northern portion of that block. 10 Wells 8-108 and 8-110. 11 Through 2002, which is to say last year, three 12 additional wells have been drilled in the field, they include 8-113, 8-114 and 8-112. 8-113 was drilled in the Beechey Block and it encountered a GOC, gas oil contact, again at about 6,678 feet TVD sub-C, consistent with the findings in V- 200 and the V-200 Block and 8-106 to the north. Additionally, MDT pressures were acquired from 8-113 and showed the reservoir pressure to be about 2,950 pounds per square inch. The well was actually side-tracked to the southeast a bit to a deeper structural location to minimize any potential free gas accumulation or -- or production. 8-114 was drilled on the Beechey Block between Wells 8-106 and 8-113, and it too encountered a gas oil contact at about 6,678 feet TVD sub-C. This well was also side-tracked with a deeper structural location, an 8-114a, which is METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 12 /"'-- 12 13 ~, 14 15 16 17 18 19 20 21 22 23 24 25 ,r-. ~ ,~ 1 actually what is the location depicted on the map, was 2 completed for a short clean-up period and is awaiting 3 injection start up, pending AOGCC review and approval. 4 Well S-112 was drilled in the southeast of Crest 5 Block, it's a horizontal injector, a pre-produced injector. 6 It was drilled late last year in 2002, and will commence water 7 injection following the pre-production sometime in the second 8 quarter of this year, of 2003, after something like six to 9 nine months of production. 10 Now, this year in 2003, we have drilled the S-109 11 producer over here in the southeast of Crest Block. It currently is awaiting production start up. The final two wells that have been drilled on the development are the S-115 and S-117 wells, which were drilled as conventional producers in the Crest Block and they too await production start up. This concludes my testimony on the structure and development drilling at the Aurora field. CHAIR SEAMOUNT: Are there any questions at this time? Okay. Thank you, Mr. Copen. MR. COPEN: You're welcome. CHAIR SEAMOUNT: We may have some questions for you later. Okay. Who is the next? MR. YOUNG: That will be me, Jim Young. CHAIR SEAMOUNT: And, who do you represent? MR. YOUNG: I have a prepared script, if you would METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 13 ,~- 1 2 3 4 5 6 7 8 9 10 11 12 13 /~----- 14 15 16 17 18 19 20 21 22 23 24 25 r--. ~, ~- like me to present that. I represent BP. CHAIR SEAMOUNT: Please raise your right hand? (Oath administered) MR. YOUNG: I do. CHAIR SEAMOUNT: Thank you. Could you give us your qualifications, please? MR. YOUNG: Yes, sir. I'm an My name is Jim Young. engineer for BP Exploration, Alaska. I'm currently working as a petroleum engineer for the Aurora development project. I received a Bachelor of Science degree in petroleum engineering from Montana Tech. I joined BP in 2000, via the acquisition of ARCO, and I've worked in Alaska in a variety of petroleum engineering projects since 1992. I have been working with the Greater Prudhoe Bay Satellite Development Team since August, 1999, and I have also testified in the original pool world (ph) application for Aurora field. I would like to be acknowledged today as an expert witness in petroleum engineering. CHAIR SEAMOUNT: Commissioner Palin, questions or objections? COMMISSIONER PALIN: No objections. No questions. CHAIR SEAMOUNT: Commissioner Ruedrich? COMMISSIONER RUEDRICH: None. CHAIR SEAMOUNT: Okay. I have no questions or objections either. You are accepted as an expert witness. METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 14 ,r---- ,~, ,-------'- ,---- ,r----.. 1 Please proceed, Mr. Young. 2 My testimony today will be covering a MR. YOUNG: 3 description of the operation and describing the wells proposed 4 for DR injection. Contemplated operation addressed in this 5 application is a tertiary recovery project using the enhanced 6 oil recovery technique of miscible displacement to increase 7 recoverable oil. 8 The project involves cyclical injection of water 9 alternating with injection of enriched hydrocarbon gas into 10 the oil column of the Kuparuk River sandstone, omission of the 11 Aurora pool. 12 The miscible gas to be used in the project or MI, will 13 be comprised of hydrocarbon gas enriched with intermediate 14 hydrocarbons, principally ethane and propane. Aurora wells 15 were drilled from the existing Prudhoe Bay unit S-pad and 16 currently MI is delivered to S-pad as part of the Prudhoe Bay 17 miscible gas project. Implementation of the Aurora project 18 will consist of construction of an MI header from the existing 19 IPA line that is at S-pad to the northern trunk and lateral 20 system and the conversion up to ten water injection wells to 21 water alternating gas injection. 22 Regional water injection laterals were fabricated to 23 meet WAG (ph) specifications, therefore, the only surface 24 modifications required to implement the project will be to the 25 header-riser spools. The first injection of MI into the METRO COURT REPORTING 745 West Fourlh Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 15 .~" 2 3 4 5 6 7 8 9 10 11 12 13 r" 14 15 16 17 18 19 20 21 22 23 24 25 ,r--, .~ ~, 1 Aurora pool is expected to occur in the second quarter of 2003, pending approval. The proposed wells for injection are S-101, 104, 107, 112 and 114i, as shown on this map; 101, 104 injection, 107, 112 and 114. Cement bonding logs, using the ultra-sonic imaging tool were run in wells S-104 and S-112, and indicate good cement bond across the Kuparuk River formation. The Commission has also approved of water flow logs, completed in wells S-101 and S-104 to confirm injection containment into the target zone. S-114i and future conversions will be conducted in accordance with 20 AAC 25.412. I did want to correct that the water flow logs were completed in Wells S-101 and S-107. The maximum injection rates in the pool are anticipated to be 20 million standard cubic feet per day of miscible injectant, and with increased surface pressures, maximum water injection requirements at the Aurora pool are estimated at 40,000 barrels of water per day. This concludes my testimony on the description of operation and wells. CHAIR SEAMOUNT: Thank you, Mr. Young. Do either of the Commissioners have any questions at this time? COMMISSIONER PALIN: No, sir. CHAIR SEAMOUNT: Okay. MR. YOUNG: The next section, hydrocarbon recovery, METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 16 r---. .~- ,/"~- ~ r--, 1 will be presented by Frank Paskvan. 2 Raise your right hand? CHAIR SEAMOUNT: 3 (Oath administered) 4 I do. MR. PASKVAN: 5 All right. please proceed. CHAIR SEAMOUNT: 6 My name is Frank Paskvan, that's spelled MR. PASKVAN: 7 P-a-s-k-v-a-n. I'm a reservoir engineer for BP Exploration, 8 Alaska, and currently working as the team lead and reservoir 9 engineer for the Aurora Development. I received a Bachelor of 10 Science degree in petroleum engineering from the University of 11 Alaska, Fairbanks in 1985. In that year I joined ARCO Alaska, 12 which was later acquired by BP. I've worked as a reservoir 13 engineer on a variety of Alaskan projects, including the 14 Prudhoe Bay, Kuparuk, Lisburne, Midnight Sun, Aurora and 15 Borealis fields. 16 In 1994, I transferred to ARCO Indonesia, Inc., as a 17 reservoir engineering specialist, and there I was responsible 18 for training Indonesian reservoir engineers and for appraisal 19 and development to the Tongu gas fields there. I've been 20 working with the Greater Prudhoe Bay Water Flood Satellite's 21 Team since November of 1998. 22 I would like to be acknowledged today as an expert 23 witness. 24 Commissioner Palin, questions or CHAIR SEAMOUNT: 25 objections? METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 17 r---', 1 2 3 4 5 6 7 8 9 10 11 12 13 ,.r--" 14 15 16 17 18 19 20 21 22 23 24 25 ~-, r--- ~, COMMISSIONER PALIN: No questions or objections. CHAIR SEAMOUNT: Commissioner Ruedrich? COMMISSIONER RUEDRICH: None. CHAIR SEAMOUNT: Okay. Mr. Paskvan, you are accepted as an expert witness. Please proceed. MR. PASKVAN: Thank you. It is estimated that the implementation of EOR will increase recovery by approximately three to five million barrels of oil in the Aurora pool. This estimate is based upon fine scale fully compositional reservoir simulation, using fluid properties and reservoir description from Well V-200. The rate forecast from this simulation work, showing the EOR volumes, as shown in Exhibit 5-1, which was included in the application. This is the original application's enclosure, and it provides a summary of the EOR oil production and base oil production with the miscible injection forecast and returned MI, going from the year 2000 to 2030. And, since this application on December 9th, we have filed with the Commission an addendum to this exhibit, which is our latest forecast of EOR oil, miscible injectant and returned MI, so you should have this on file. And, what this does, it provides the EOR oil rate stream as a separate diagram so that it's not an incremental on top of the water floods, so it more clear to what the rates are expected for the project. METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 18 ,r---, 1 2 3 4 5 6 7 8 9 10 11 12 13 r--, 14 15 16 17 18 19 20 21 22 23 24 25 ,r--- ~ ~, The EaR projects in the Prudhoe Bay and the Point McIntyre oil pools in Prudhoe Bay have a history of success and are considered good analogues for the Aurora EaR project. This Exhibit 4-1, illustrates the compositional similarity between the Aurora and Prudhoe Bay oil. You can -- this is the mol-fraction of the respective components, the components are identified on an index to the right. The Aurora composition is shown in the triangles and is a close match to the composition of a typical Prudhoe Bay fluid. Because of this, the Prudhoe Bay 12 component equation estate, a model was selected, and when tuned to the Well V-200 fluid properties, was used in the reservoir simulation. And, relative permeability was used in the simulation derived from the Point McIntyre core of flood data. A completed slim tube experiment defines the minimum miscibility of enrichment of the MI, and confirms miscibility of the Aurora oil pool oil with the proposed miscible injectant over the expected range of reservoir pressures. The slim tube experiment behavior matches predictions by the equation estate. And, the minimum miscibility pressure of the Aurora oil, with the miscible injectant, predicated by the equation estate is 2,700 PSI. In addition, a single well tracer test was performed in Aurora to define the residual oil saturation to water, and METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 19 /,"",', 1 2 3 4 5 6 7 8 9 10 11 12 13 ,r--, 14 15 16 17 18 19 20 21 22 23 24 25 /', ~ ~ the residual oil saturation to miscible injectant by measuring return fluids following a short term injection and production cycle in the 8-104 injector. This test provides an insitu confirmation of the miscibility of Aurora oil with the miscible injectant. The test also provided field data that was used to calculate expected water flood and EOR recoveries for the Aurora pool, as was shown in the addendum to Exhibit 5-1. For the surveillance plan, to insure the efficient allocation of MI for the Aurora EOR project, rate and pressure response to injection will be monitored. Production fluid samples will be taken at least annually to assess to pattern efficiency based on the returned MI ratio. Injection of MI into patterns that do not achieve minimum recovery levels, based on comparison to all the patterns; i.e., the marginal patterns, will be discontinued until recovery issues are resolved. A significant amount of surveillance work has already been completed to assess producer injector conductivity. This work has included static pressure monitoring, material balance estimates and the acquisition of repeat formation tester pressure data. All wells planned for MI have confirmed communication to the offset producers by that data. Injector well pressures will be closely monitored to identify any patterns that METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 20 /'- 1 2 3 4 5 6 7 8 9 10 11 12 13 /.r----- 14 15 16 17 18 19 20 21 22 23 24 25 ~-- ~ ~ exhibit a lack of communication to the production wells. That concludes our prepared testimony; and in addition, we've received several questions from the Commission in a letter dated Friday, February 28th, and are prepared to answer those questions at this time if it does please the Commission. CHAIR SEAMOUNT: That would be fine, Mr. paskvan. Thank you. MR. PASKVAN: What I'll do is briefly read the question and then where we're at with the response on that. For the first two overview questions; please provide a quick overview of the current development status of the Aurora pool and a map of top structure with producers and injectors. We believe we addressed these two questions by modifying and expanding our testimony in the geology and development drilling section of the testimony, and the two exhibits that were distributed in that. For a question regarding a summary of overall MI project plans for the Aurora, including timing, this is addressed in a more detailed response to follow; however, we are preparing for first miscible injection in the second quarter of this year, pending the AOGCC's approval. With regards to the results of water injection, the question was asked; please provide a summary level overview of current production, reservoir voidage replacement and METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 21 '~" 2 3 4 5 6 7 8 9 10 11 12 13 ~. 14 15 16 17 18 19 20 21 22 23 24 25 ,~-. /""'. ~ 1 reservoir pressure by a major fault block. And, we've prepared this for that and that summarizes that response. 80, this figure has been prepared to answer that question, and what you'll note is the -- what we've broken this down into by -- by fault block, is the West, the North of Crest and the 80utheast of Crest area with the current voidage rate, which is the sum of the oil, water and gas production from the wells converted into reservoir barrels per day units, using the perspective fluid formation volume factors. The current injection rate, this is water injection at this time, and a current range of pressures that -- pressures or range of pressures that have been seen recently in production tests. Note that in the West Block, the pending conversion of the 8-114 injector will -- that's pending with the Commission's approval on the -- of the water flow log that was completed just this past weekend. With the start of 8-114 injection, that will increase injection by about 15,000 barrels of water per day and enable injection at a VRR equal to or greater than one. The North of Crest area is partly offset by aquifer influx, so a portion of this, -- this is the 8-104's water injection rate; in addition, the aquifer provides some pressure support and water support to -- this is an area that would benefit from increased voidage replacement by injection of miscible gas. And, facility modifications to increase the METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 22 r', 3 4 5 6 7 8 9 10 11 12 13 ,r--, 14 15 16 17 18 19 20 21 22 23 24 25 .r--', --, ~ 1 wellhead water injection pressure are also being considered 2 for this area of Aurora, which may include water booster pumps for increased pressure. In the Southeast of Crest Block, you'll note there's currently no water injection at this time; however, we have drilled injectors 8-112 and 8-110, which are planned for water injection start up later this year. Continuing on then with regards to reservoir pressure and voidage replacement there is a question: our records suggest rather low reservoir pressures in the area, could you update us on the pressures and anticipated time to replace voidage with water? As shown in this summary by Fault Block, only the West Block has pressures below the MMP of 2,700 pounds. In the West Block we have intervened in the following ways to consider reservoir energy. The producers 8-100 and 8-102 were curtailed through the year 2002 to preserve reservoir energy. Well 8-100's GaR has dropped from 15,000 standard cubic feet per barrel to 3,000 standard cubic feet per barrel since 8-101 started injection in November of 2001. The lowest observed pressure in the Western Block is in the 8-106 well, which is this approximately 2,000 P8I pressure. This well has had high GaR's due to gas cap production. 8ince we started injection in the 8-107 injector, the gross fluid rates in 8-106 have stabilized and the well -- METRO COURT REPORTING 745 West Founh Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 23 ~- 1 2 3 4 5 6 7 8 9 10 11 12 13 /"'""- 14 15 16 17 18 19 20 21 22 23 24 25 ~', ~ .~ producing well has exhibited a slight increase in water cut. In addition in the West Block, the 8-114, as mentioned, is pending start-up and that should produce reduce the GaR's of the producer 8-106 and 8-100. And, just as we've seen, 8-101's injection has reduced the 8-100 GaR and enable injection rates in the West Block to achieve a VRR of 1.0. With the addition of 8-114i injector's injection rate, reservoir simulation predicts that pressure will be above 3,000 P8I by the end of this year. In the other Fault Blocks, those do currently have reservoir pressures that are above the minimum miscibility pressure and when put on miscible injection, these will benefit from the miscible gas injectant which will help to increase the voidage replacement ratio in those blocks. There is another question. Your pool rules testimony stated that there would be injection capacity of approximately 28,000 barrels water per day available, yet our records suggest only 11,000 barrels water per day currently. Do you have plans to increase the water injection within Aurora? When and how? Well, I would start by noting that the current area injection remodification section in our application, we note that our maximum water injection rates are now anticipated to be as high as 40,000 barrels per day. And, Well 8-114 is estimated to inject at 10 to 15,000 barrels water per day as METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 24 "r---- 4 5 6 7 8 9 10 11 12 13 ..r---- 14 15 16 17 18 19 20 21 22 23 24 25 r---. ~ .~ 1 soon as we have 2 water injectors 3 this year. approval to inject; that we have the pending S-112 and 110 starting water injection later And, in addition, we're currently considering facility debottlenecking projects to increase water injection pressures and rates into the area. And note too, that this area injection modification application, it includes a request for increasing the maximum water injection pressure from 2,600 PSI to 2,800 PSI at the wellhead, to address some of these replacement questions. Continuing on then, the -- with regards to miscible injection; which wells are you planning to inject MI into and when? We will start with the S-104 injector and anticipate an initial injection period of four to six months. And, the other patterns will receive MI after the facilities are in place for those wells and the pressures are acceptable for miscibility and sufficient water has been injected for mobility control. There's a question, are you planning to inject MI with the current reservoir pressures? And the answer is yes, but only in those patterns above the minimum miscibility pressure. Can you give a rough estimate of the expected miscibility of injectant for the conditions of injection? The MMP of Aurora oil with the miscible injectant is estimated at 2,700 PSI. METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 25 ,r---, 1 2 3 4 5 6 7 8 9 10 11 12 13 r-.. ./ 14 15 16 17 18 19 20 21 22 23 24 25 ,""'--' ,~ ~ And, will the gas remain miscible at the current reservoir pressures? If not, will ultimate recovery be compromised? This slim tube simulation of MMP indicates slight losses in recovery as reservoir pressure drops below the MMP, so as to maximize recovery, significant amounts of MI will only be injected into those patterns that are above the MMP. However, in some injection wells, a small volume of miscible injectant may be used as a water injection stimulation treatment, but that would reduce the oil saturation in the near well bore area, and this will increase water injection and accelerate voidage replacement and allow us to move forward, allowing all patterns to have MI allocated for them as their pressures achieve minimum miscibility threshold. Well, this concludes our planned testimony, and we would like to address any questions that may be remaining with the Commission. CHAIR SEAMOUNT: At this time, I'd like to call a short recess. Normally we say ten minutes, but we've never made that ten minutes, so how about we count on 20 minutes and we'll try real hard to get back here at 10:10. So, we'll go off the record. (Off record) (On record) METRO COURT REPORTING 745 West Fourlh Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 26 r' 1 2 3 4 5 6 7 8 9 10 11 12 13 r--. 14 15 16 17 18 19 20 21 22 23 24 25 r--. ~. ,~, CHAIR SEAMOUNT: It looks like we made it back in time. It's probably a first. Before we get to questions, I had a request, and that was -- I believe it was Mr. paskvan -- no, it wasn't, it was -- let's see, I believe it was Mr. Young that showed Exhibits 4-1 and 5-1, am I correct? MR. PASKVAN: I think -- I think I showed those. CHAIR SEAMOUNT: Mr. Paskvan? MR. PASKVAN: Yes. CHAIR SEAMOUNT: Okay. The exhibits you showed were in color, and what we received originally was in black and white, would it be possible to get those exhibits in color for the record? MR. PASKVAN: Certainly. CHAIR SEAMOUNT: Okay. Thank you. Do we have any questions from Commissioner Palin? COMMISSIONER PALIN: No. CHAIR SEAMOUNT: Also for the record, we received no written questions from people other than the applicants. Commissioner Ruedrich, do you have any questions? COMMISSIONER RUEDRICH: I do. First, I want to just compliment the four presenters for doing an outstanding job of having concise constructive presentations. Thank you very much. My first question is in conjunction with the pressure data that we have received, which indicates that 106 appears METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 27 .' /""-" 1 2 3 4 5 6 7 8 9 10 11 12 13 ,r---- 14 15 16 17 18 19 20 21 22 23 24 25 ~-- r"---. ~-\ to be actually below 2,000 in October. Do you have additional data on that well at this time? Any insight as to what's happening there? MR. YOUNG: I can't say that that pressure that was acquired at that time was based on fluid level measurement because what we do -- we had to obtain a (indiscernible) pressure gauge from that well earlier in the year and we've had an opportunity to -- well, with the short term shut-in -- get a -- just a pressure, try to get an idea if the pressure was changing at all. And, the well was shut-in a shorter period than it normally is and we didn't get an opportunity to get pressure data to see if it was continuing to build, but based on the gross fluid rates in the well that they have stabilized, basically since the middle of June, we feel that that pressure is probably actually in the 2,000 range, closer to the, you know, what it was when we measured it earlier in the year. COMMISSIONER RUEDRICH: Okay. You Thank you. mentioned your plans to do some facility debottlenecking to transport more water and obviously increase the pressure, what are the general elements of that activity? MR. PASKVAN: I can cover that question. In part, we're pursuing a tie-line that connects GC-1 to GC-2, so that -- the water that tied up locally at the GC-2 plant and therefore, must disposed of into a crustaceous disposal well METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 28 ; -----, 1 2 3 4 5 6 7 8 9 10 11 12 13 ""-'-- 14 15 16 17 18 19 20 21 22 23 24 25 "'--', ..-.., ,-..,. will be made available to the GC-2 area through -- by putting a tie-line back in operation and make that water previously disposed of available for injection into the GC-2 injection areas. In addition, we're considering in doing conceptual design on potential water injection booster pumps to increase the wellhead injection pressure for the Aurora project. COMMISSIONER RUEDRICH: Will that only affect the Aurora project? MR. PASKVAN: It would be a local pump on S-pad and so it would be avail -- installed possibly on the northern header and any wells that happen to be drilled from that area, which are predominately the Aurora wells, would be affected. COMMISSIONER RUEDRICH: Okay. That's it. MR. PASKAVAN: Those are two items that are..... COMMISSIONER RUEDRICH: You noted that by bringing S- 114 onto injection as requested herein, you would be getting into essentially balancing the current rate of voidage¡ what is the net voidage in the three principle fault blocks? Do you have those numbers handy? MR. PASKVAN: Yes, we do. It's as summarized in this table. So, the West Block is where the S-114 injector will be put on injection. And, I believe it was taking, during the water flow log, about 12;000 barrels of water per day at -- what was the well head? METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 29 r-- 11 12 13 ~-. 14 15 16 17 18 19 20 21 22 23 24 25 ~" .~ "'-"", 1 would imagine, for this data. 2 MR. BEUHLER: Could we set that at this Friday? Would 3 that be an appropriate time? 4 CHAIR SEAMOUNT: And, that would be the 7th? 5 MR. BEUHLER: Yes. 6 COMMISSIONER RUEDRICH: Thank you. By virtue of the 7 West Block, at this time being somewhere between 2,000 and 8 2,700, when do you expect with the planned water injection 9 enhancement to get back to your minimum miscible pressures so 10 you can actually start MI in the West Block? MR. PASKVAN: By the simulation work done on that area, it suggests that by the end of 2003, we would be restoring pressure above the MMP. COMMISSIONER RUEDRICH: Okay. The end of 2003, okay. And, you mentioned that you're going to be bringing some additional water over from further east, do you have any other sources of water to accomplish this? What would be the expected resource plan? MR. PASKVAN: There are a number of potential options that are under consideration right now. And, to bring water into GC-l, we're currently reviewing the conceptual design basis and the value of tying in Point Mac into G-l through a project that's sometimes termed Water Wheel I, it's a debottlenecking project, which will take a portion of the Point Mac production from the Lisburne Production Center, LPC, METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 31 r--'-- 1 2 3 4 5 6 7 8 9 10 11 12 13 -~-- 14 15 16 17 18 19 20 21 22 23 24 25 ~- ~ '-""- into GC-l. That, in conjunction with the previously described tie-line from GC-l to GC-2, will provide a substantial volume of water from the Point Mac project, produced water, into the GC-2 area for injection. COMMISSIONER RUEDRICH: Okay. What about the MI, will it have any impact on any of the other current users of MI? MR. PASKVAN: Now, the -- will what? COMMISSIONER RUEDRICH: The miscible injection that you will be using in this project, what is its particular source? MR. PASKVAN: The source of the MI is from the Prudhoe Bay Central Gas Facility. COMMISSIONER RUEDRICH: And, is it dedicated currently to other recovery projects? MR. PASKVAN: There are a number of miscible injection wells to which that source is being injected currently, yes. COMMISSIONER RUEDRICH: Has the Commission received any information as to how they will be impacted by this transfer of resource? MR. PASKVAN: We've had -- we've had some conversations about the project and we intend to follow-up as a part of the upcoming Prudhoe Bay unit plan and development discussion with the DNR, which will be later this month, review those aspects of this project in more detail. COMMISSIONER RUEDRICH: Okay. We will look forward to METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 32 ,~-, 1 2 3 4 5 6 7 8 9 10 11 12 13 ~--, 14 15 16 17 18 19 20 21 22 23 24 25 ~- -. , , ~. seeing that. Do we have anything else that anybody.. ... CHAIR SEAMOUNT: Is there anybody else who wishes to make a statement regarding this hearing? Does the Applicant have anything further to say? MR. BEUHLER: No, sir. CHAIR SEAMOUNT: We will leave the hearing record open until we receive the total voidage data, and that should be on Friday, and I believe that's March 7th, 2003. I too, would like to commend you on a very good presentation and testimony. And, if there's nothing else, we are off the record. (Off record) * * * END OF PROCEEDINGS * * * METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 33 r---- , 1 2 3 4 5 6 7 8 9 10 ~" ,r--" r--'\ ,~ C E R T I FIe ATE SUPERIOR COURT ) ) ss. ) STATE OF ALASKA I, Janice S. Scott, Notary Public in and for the State of Alaska, do hereby certify: THAT the annexed and foregoing pages numbered 2 through 30 contain a full, true and correct transcript of the Public Hearing before the Alaska Oil and Gas Conservation Commission, taken by Janice S. Scott and transcribed by Janice S. Scott: THAT the Transcript has been prepared at the request of the Alaska Oil and Gas Conservation Commission, 333 West Seventh Avenue, Anchorage, Alaska, 11 12 2003. 13 14 15 16 17 18 19 20 21 22 23 24 25 DATED at Anchorage, Alaska this 14th day of March, SIGNED AND CERTIFIED TO BY: ~ j )/~ J i e S. Scott ~: .'" ' N t ry Public in and for- ~lask; M Commission Expires 02:¡~2j Ó4-- -,' - < , - METRO COURT REPORTING 745 West Fourlh Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 5 ""'\./ ,...~ ¡'---- STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION AIO 22 AMENDMENT March 4, 2003 at 9:00 am NAME-AFFILIATION ADDRESS/PHONE NUMBER TESTIFY (Yes or No) (pLEASE PRINT) J ¿ ),( j M l / () [} AJ ~ -!Sp '/ør:; &o:.õtý5i? f. 5'74 I f?~ L-.Tefr I-ú/'r-' .1Jð/- C-Jkl; .Gd~ ~~o j.:rtr-JtIP /1/0 Morja r ¿,-{ vJ, n(;T ef!/4n Mob;'! ,30/ (! 5-(- <) t¿ 11 'I ðr) / 'Jr.'!- 37¡& /J 0 traV\k ra~;)<VQV1- 8P cìá'ö F B<f'r'SDv¡ t)bt~57L¡, Yes \/;m êC/jJen - ì3P 9Pð E<6~~')5'on -5¿;4~5/tPZ Yé'S ~// ~elA-t..J{V-~ 15(/ ) }) 5~ )I-S/L/3 'Ic.;> ~\;\~~(xr~-1Ct\JQ9z'l' IJ C;~.JA-M~C/ NCf fYÎ~"'-J ¡?~1~~~ crCe? I:: !f~f15??V\.)Ç!Jri-f/-$,)J N" t<v l ~ ~FeJ>b>" P NA ~ c'ict ;:z '+ fj-:>' (" d-..~ Aj () tJ^~ ~G~Gr¿ \ C(}tDGf~,t1\fj '2~~ b f5 CJ1 tJ G fJ{C1V~ ~V<h(~ ~ ( ( 7 h cÇ~(; ('l( '( tV rJ ~f--e-v~ ÌP: (/(~~ AC(;>C~c 773-1?7Ý ~ð 'i~ ~A - ~tC- 77'7-(Z--"Jl- ¡tIó UMvt W~ ktrucc í1J'/;L2(.. No \HeB'~_Sign-In 4 ,,-.....--.., ~ ¡ì\e ~YìO ~ F)Î¿ ~e' OW2ZA Cònyidø/JlCt ¿ , O~G- Ad \ '" QÚN( ~ ~ - ~ ~ ~~~~I (ill} ~~~~.~~~ ¡tl4A.SKA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 February 28, 2003 Gil Buehler GPB Satellites Manager BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Dear Mr. Buehler: Per your request a public hearing has been scheduled for March 4, 2003 at 9:00 am concerning approval of your application to inject miscible gas into the Aurora Oil Pool. We have attached a few questions pertaining to the hydrocarbon recovery projections indicated in the application. If you have any questions, please contact Jane Williamson at 793-1226. AJU Sincerely, Daniel T. Seamount, Jr. Commissioner fJ "'-- N~¿{) ~ pC~Þ1 C-~~" Randy Ruedrich Sãrãn-Patín .), Commissioner Commissioner cc: Neil McCleary (BP) D. Rosier (Chevron-Texaco) G. Carlson (Forest Oil) M. Vela (ExxonMobil) J. P. Johnson (CPAI) ,,-.... Questions Aurora Oil I-"..,1 - Modifications to ATO22 Page 2 February 28,2003 ~, Aurora Oil Pool - Modifications to AIO22 Questions In order to approve your application, we must technically defend that injection wi1llead to greater ultimate recovery. While you have indicated that you anticipate 4-5 MMSTB additional reserves, there are a few areas we need to get clear. As such, the following are the types of questions you should be prepared for at the hearing. Overview . Please provide a quick overview of the current development status of the Aurora Pool. . Map with top of structure, producers and injectors. Summary of overall MI project plans for Aurora including timing. Results of water injection: . Please provide summary level overview of current production, reservoir void age replacement, and reservoir pressure by major fault block. Reservoir Pressure and Voidage Replacement . Our records suggest rather low reservoir pressures in the area. Could you update us on the pressures, and anticipated time to replace void age with water? . Your pool rules testimony stated that there would be injection capacity of approximately 28,000 BWPD available, yet our records suggest only 11,000 BWPD currently. Do you have plans to increase the water injection within Aurora? When? How? Miscible iniection . Which wells are you planning to inject MI into and when? . Are you planning to inject MI with the current reservoir pressures? . Can you give a rough estimate of the expected miscibility of the injectant for the expected conditions of injection? . Will the gas remain miscible at the current reservoir pressures? If not, will the ultimate recovery be compromised? ~ ~. ALASKA OIL & GAS CONSERVATION COMMISSION FAX 907-276-7542 PHONE 907-279-1433 FACSIMILE TRANSMITTAL SHEET. TO' . C:J~ 'h~ j~ h \--eJí COMPANY: 0,-- 0 l:J L C~ FAX NUMBER: 5LDL\-C:(xx) FROM: . DAre Jm.\] QO\ombt~ ¿:j I LP> IO~ TOT ALNO. OF PAGES INCLUDING COVER: ~~ PHONE NUMBER: ~\.,p\~ 5\\ \ RE: ~ .. . '.'" .. .' YOUR REFERENCE NUMBER, ~L \-\CO'_A~~ n.. .. - n 0 URGENT ~ REVIEW 0 PLEASE COMMENT 0 PLEASE REPLY SENDER'S REFERENCE NUMBER, 0 PLEASE RECYCLE NOTES/COMMENTS: AOGCC 333 WEST 7TH AVENUE,SUITE 100 ANCHORAGE, AK 99501-3935 3 r- --... LO\\n(jQ~R Eot}-, 'I ~ , Cù\'\~,~OO~ -- Addendum to application exhibit V -l.ppt /"""' ' ~ Subject: Addendum to application exhibit V -1.ppt Date: Wed, 26 Feb 2003 14:09:16 -0600 From: "Young, Jim" <Y oungJ3@BP . com> To: "Jane Williamson (E-mail)" <Jane- Williamson@admin.state.ak.us> CC: "Paskvan, Frank A" <PaskvaFA@BP.com>, "Hey, Michael-James" <HeyMJ@BP.com> Here is a NON-CONFIDENTIAL version of the EOR forecast to add to the application. Jim Addendum to application exhibit V-l.ppt «Addendum to application exhibit V-l.ZIP» Name: Addendum to application exhibit V-l.ZIP ~Addendum to application exhibit V-1.ZIP Type: Zip ~ompresse~ Data (apphcatlOn/x -zIp-compressed) Encoding: base64 lofl 3/3/2003 4:32 PM 14 12 10 ;e (.) CJ) E 8 E ~ 6 a::: - ~ 4 2 0 2000 JI 2005 Addendum to application exhibit V-I Represents latest EaR forecast :1' : J : -.: : 1:H\ : !\..H, ¡ : : - ; :: : 2010 ~, 1 2015 1050 - Mllnjection Rate mmscf/d 900 - RMI Rate mmscf/d 750 - EOR Oil Rate bpd 600 450 300 .,- 150 :~ r-- 0 2020 2025 2030 ) 0 a.. ce .sa co ~ ð ~ 0 w ) 2 STATE OF ALASKA ADVERTISING ORDER ~ NOTICE TO PUBLISHER ~ ADVERTISING ORDER NO. INVc..-.", MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER "',-" CERTIFIED AO-O23140'28 AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COpy OF ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE F AOGCC R 333 W 7th Ave, Ste 100 0 Anchorage, AK 9950 I M AGENCY CONTACT Jody Colombie PHONE DATE OF A.O. January 24, 2003 PCN ¿ AnchorageDailyNews POBox 149001 Anchorage, AK 99514 (907) 793 -1 ?21 DATES ADVERTISEMENT REQUIRED: January 28, 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 REF TYPE 1 VEN 2 ARD 3 4 NUMBER AOGCC, 333 W. 7th Ave., Suite 100 Anchorage, AK 99501 AMOUNT DATE I ITOTALOF I ~~~~~~F ALL PAGES$ COMMENTS 02910 FIN AMOUNT Sy cc PGM LC ACCT FY - NMR DIST LID 1 2 3 03 02140100 73540 R:QU~ITIONED ~~-À U~Ow'-- V IDI~Õ~~ ~J,' ~ 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: Aurora Oil Pool, Prudhoe Bay Field Area Injection Order Modification BP Exploration (Alaska), Inc. by application dated December 9,2002, has applied for a modification to Area Injection Order No. 22 to authorize use of miscible injectant to enhance recovery from the Aurora Oil Pool, Prudhoe Bay Field, on the North Slope of Alaska. The Commission has tentatively set a public hearing on this application for March 4,2003 at 9:00 am at the Alaska Oil and Gas Conservation Commission at 333 West ih Avenue, Suite 100, Anchorage, Alaska 99501. A person may request that the tentatively scheduled hearing be held by filing a written request with the Commission no later than 4:30 pm on February 19, 2003. If a request for a hearing is not timely filed, the Commission will consider the issuance of an order without a hearing. To learn if the Commission will hold the public hearing, please call 793-1221. In addition, a person may submit written comments regarding this application to the Alaska Oil and Gas Conservation Commission at 333 West ih Avenue, Suite 100, Anchorage, Alaska 99501. Written comments must be received no later than 4:30 pm on February 28,2003 except that ifthe Commission decides to hold a public hearing, written comments must be received no later than 9:00 am on March 4,2003. If you are a person with a disability who may need a special modification in order to comment or to attend the public hearing, please contact Jody Colombie at 793-1221 before January 31,2003. ~ ~.) . cam~chsli Taylor ~ Chair Published Date: January 28, 2003 ADN AO 02314028 STATE OF ALASKA ADVERTISING ORDER ;P"'- NOTICE TO PUBLISHER ,~ ADVERTISING ORDER NO. INVOll,t: MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER Nv.. CERTIFIED AO-.02 314028 AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATIACHED COpy OF ADVERTISEMENT MUST BE SUBMITIED WITH INVOICE F AOGCC R 333 West 7th Avenue, Suite 100 0 Anchorage, AK 99501 M AGENCY CONTACT DATE OF A.O. ¿ Anchorage Daily News POBox 149001 Anchorage, AK 99514 Jody Colombie JRmmry ?4, 2003 PHOI'IE PCN (907) 793 -1 1?, 1 DATES ADVERTISEMENT REQUIRED: January 28,2003 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 Daniel Donkel 2121 North Bayshore Drive, Ste 1219 Miami, FL 33137 Christine Hansen Interstate Oil & Gas Compact Comm Excutive Director PO Box 53127 Oklahoma City, OK 73152 Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 Paul Walker Chevron 1301 McKinney, Rm 1750 Houston, TX 77010 David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 T.E. Alford ExxonMobil Exploration Company PO Box 4778 Houston, TX 77210-4778 Chevron USA Alaska Division PO Box 1635 Houston, TX 77251 Shelia McNulty Financial Times PO Box 25089 Houston, TX 77265-5089 James White Intrepid Prod. Co.lAlaskan Crude 4614 Bohill SanAntonio, TX 78217 "..-..... SD Dept of Env & Natural Resources Oil and Gas Program 2050 West Main, Ste 1 Rapid City, SD 57702 Citgo Petroleum Corporation PO Box 3758 Tulsa, OK 74136 Gregg Nady Shell E&P Company Onshore Exploration & Development PO Box 576 Houston, TX 77001-0576 G. Scott Pfoff Aurora Gas, LLC 10333 Richmond Ave, Ste 710 Houston, TX 77042 William Holton, Jr. Marathon Oil Company Law Department 5555 San Fecipe St. Houston, TX 77056-2799 Corry Woolington ChevronTexaco Land-Alaska PO Box 36366 Houston, TX 77236 Donna Williams World Oil Statistics Editor PO Box 2608 Houston, TX 77252 Shawn Sutherland Unocal Revenue Accounting 14141 Southwest Freeway SugarLand,TX 77478 Doug Schultze XTO Energy Inc. 3000 North Garfield, Ste 175 Midland, TX 79705 ..-, John Katz State of Alaska Alaska Governor's Office 444 North Capitol St., NW, Ste 336 Washington, DC 20001 Alfred James 200 West Douglas, Ste 525 Wichita, KS 67202 Conoco Inc. PO Box 1267 Ponca City, OK 74602-1267 Michael Nelson Purvin Gertz, Inc. Library 600 Travis, Ste 2150 Houston, TX 77002 G. Havran Gaffney, Cline & Associations Library 1360 Post Oak Blvd., Ste 2500 Houston, TX 77056 W. Allen Huckabay ConocoPhillips Petroleum Company Offshore West Africa Exploration 600 North Dairy Ashford Houston, TX 77079-1175 Texico Exploration & Production PO Box 36366 Houston, TX 77236 Chevron Chemical Company Library PO Box 2100 Houston, TX 77252-9987 Kelly Valadez Tesoro Refining and Marketing Co. Supply & Distribution 300 Concord Plaza Drive San Antonio, TX 78216 Robert Gravely 7681 South Kit Carson Drive Littleton, CO 80122 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 John Levorsen 200 North 3rd Street. #1202 Boise, ID 83702 Samuel Van Vactor Economic Insight Inc. 3004 SW First Ave. Portland, OR 97201 Williams VanDyke State of Alaska Department of Natural Resources 550 West 7th Ave., Ste 800 Anchorage, AK 99501 Susan Hill State of Alaska, ADEC EH 555 Cordova Street Anchorage. AK 99501 Jim Arlington Forest Oil 310 K Street. Ste 700 Anchorage, AK 99501 Julie Houle State of Alaskan DNR Div of Oil & Gas, Resource Eva!. 550 West 7th Ave., Ste 800 Anchorage. AK 99501 Ciri Land Department PO Box 93330 Anchorage. AK 99503 Schlumberger Drilling and Measurements 3940 Arctic Blvd., Ste 300 Anchorage, AK 99503 Mark Hanley Anadarko 3201 C Street, Ste 603 Anchorage, AK 99503 ".-..., 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 Thor Cutler OW-137 US EPA egion 10 1200 Sixth Ave. Seattle, WA 98101 Cammy Taylor 1333 West 11th Ave. Anchorage, AK 99501 Ed Jones Aurora Gas, LLC Vice President 1029 West 3rd Ave., Ste 220 Anchorage, AK 99501 Duane Vaagen Fairweather 715 L Street. Ste 7 Anchorage, AK 99501 Trustees for Alaska 1026 West 4th Ave., Ste 201 Anchorage. AK 99501-1980 John Harris NI Energy Development Tubular 3301 C Street. Ste 208 Anchorage. AK 99503 Mark Dalton HDR Alaska 2525 C Street. Ste 305 Anchorage, AK 99503 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 ~ Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 John F. Bergquist Babson and Sheppard PO Box 8279 Long Beach. CA 90808-0279 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle, WA 98119-3960 Tim Ryherd State of Alaska Department of Natural Resources 550 West 7th Ave.. Ste 800 Anchorage, AK 99501 Richard Mount State of Alaska Department of Revenue 500 West 7th Ave., Ste 500 Anchorage. AK 99501 Robert Mintz State of Alaska Department of Law 1031 West 4th Ave.. Ste 200 Anchorage, AK 99501 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage. AK 99502 Rob Crotty C/O CH2M HILL 301 West Nothern Lights Blvd Anchorage, AK 99503 Jack Laasch Natchiq Vice President Government Affairs 3900 C Street, Ste 701 Anchorage, AK 99503 Judy Brady Alaska Oil & Gas Associates 121 West Fireweed Lane, Ste 207 Anchorage, AK 99503-2035 Arlen Ehm 2420 Foxhall Dr. Anchorage, AK 99504-3342 Thomas R. Marshall, Jr. 1569 Birchwood Street Anchorage, AK 99508 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Chuck O'Donnell Veco Alaska,lnc. 949 East 36th Ave., Ste 500 Anchorage, AK 99508 Kristen Nelson IHS Energy PO Box 102278 Anchorage, AK 99510-2278 Robert Britch, PE Northern Consulting Group 2454 Telequana Dr. Anchorage, AK 99517 Tesoro Alaska Company PO Box 196272 Anchorage, AK 99519 BP Exploration (Alaska), Inc. land Manager PO Box 196612 Anchorage, AK 99519-6612 Bob Shavelson Cook Inlet Keeper PO Box 3269 Homer, AK 99603 Kenai Peninsula Borough Economic Development Distr 14896 Kenai Spur Hwy #103A Kenai, AK 99611-7000 ~ Greg Noble Bureau of Land Management Energy and Minerals 6881 Abbott Loop Rd Anchorage, AK 99507 Jeff Walker US Minerals Management Service Regional Supervisor 949 East 36th Ave., Ste 308 Anchorage, AK 99508 Richard Prentki US Minerals Management Service 949 East 36th Ave., 3rd Floor Anchorage, AK 99508 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 Perry Markley Alyeska Pipeline Service Company Oil Movements Department 1835 So. Bragaw- MS 575 Anchorage, AK 99515 David Cusato 600 West 76th Ave., #508 Anchorage, AK 99518 J. Brock Riddle Marathon Oil Company Land Department PO Box 196168 Anchorage, AK 99519-6168 Sue Miller BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Shannon Donnelly Phillips Alaska, Inc. HEST -Enviromental PO Box 66 Kenai, AK 99611 Penny Vadla Box 467 Ninilchik, AK 99639 ~. Rose Ragsdale Rose Ragsdale & Associates 3320 E. 41st Ave Anchorage, AK 99508 Paul L. Craig Trading Bay Energy Corp 5432 East Northern Lights, Ste 610 Anchorage, AK 99508 Jim Scherr US Minerals Management Service Resource Evaluation 949 East 36th Ave., Ste 308 Anchorage, AK 99508 Jim Ruud Phillips Alaska, Inc. Land Department PO Box 100360 Anchorage, AK 99510 Jordan Jacobsen Alyeska Pipeline Service Company law Department 1835 So. Bragaw Anchorage, AK 99515 Jeanne Dickey BP Exploration (Alaska), Inc. Legal Department PO Box 196612 Anchorage, AK 99518 Kevin Tabler Unocal PO Box 196247 Anchorage, AK 99519-6247 Dudley Platt DA Platt & Associates 9852 Little Diomede Cr. Eagle River, AK 99577 Peter McKay 55441 Chinook Rd Kenai, AK 99611 James Gibbs PO Box 1597 Soldotna, AK 99669 Claire Caldes US Fish & Wildlife Service Kenai Refuge PO Box 2139 Soldotna, AK 99669 Charles Boddy Usibelli Coal Mine, Inc. 100 Cushman Street, Suite 210 Fairbanks, AK 99701-4659 Harry Bader State of Alaska Department of Natural Resources 3700 Airport Way Fairbanks, AK 99709 North Slope Borough PO Box 69 Barrow, AK 99723 ,/'- "-", Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 Richard Wagner PO Box 60868 Fairbanks, AK 99706 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 Kurt Olson State of Alaska Staff to Senator Tom Wagoner State Capitol Rm 427 Juneau, AK 99801 John Tanigawa Evergreen Well Service Company PO Box 871845 Wasilla, AK 99687 Cliff Burglin PO Box 131 Fairbanks, AK 99707 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 Senator Loren Leman State of Alaska State Capitol Rm 113 Juneau, AK 99801-1182 --- -' Notice of Public Hearing , ' STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: Aurora Oil Pool, Prudhoe Bay Field Area Injection Order Modification BP Exploration (Alaska), Inc. by application dated December 9,2002, has applied for a modification to Area Injection Order No. 22 to authorize use of miscible injectant to enhance recovery from the Aurora Oil Pool, Prudhoe Bay Field, on the North Slope of Alaska. The Commission has tentatively set a public hearing on this application for March 4,2003 at 9:00 am at the Alaska Oil and Gas Conservation Commission at 333 West ih Avenue, Suite 100, Anchorage, Alaska 99501. A person may request that the tentatively scheduled hearing be held by filing a written request with the Commission no later than 4:30 pm on February 19,2003. If a request for a hearing is not timely filed, the Commission will consider the issuance of an order without a hearing. To learn if the Commission will hold the public hearing, please call 793-1221. In addition, a person may submit written comments regarding this application to the Alaska Oil and Gas Conservation Commission at 333 West ih Avenue, Suite 100, Anchorage, Alaska 9950 I. Written comments must be received no later than 4:30 pm on February 28,2003 except that if the Commission decides to hold a public hearing, written comments must be received no later than 9:00 am on March 4,2003. If you are a person with a disability who may need a special modification in order to comment or to attend the public hearing, please contact Jody Colombie at 793-1221 before January 31,2003. Cam.~. ., ~. 'j¿l/ c~~~;dìchsli Taylor' Chair Published Date: January 28, 2003 ADN AO 02314028 _._~.. a~Z{1 - -' f." ffl;!fi;ï' J "". ~'oc1i, -.;~--'Ir;,,-;~,' ,~¡¡, ,..I" , "~-~'. . k ":"';;""',:+:" ?>"'1:",,::-,':- 1M. ,.-,.J'ì'SW&'t¡~ 7Jã;~&;j¿/lJ,ÓJ ¿ Re: Legal Ad Order ,~ ~ Subject: Re: Legal Ad Order Date: 24 Jan 2003 14:12:20 -0900 From: Amy Heath <aheath@adn.com> To: Jody Colombie <jody_colombie@admin.state.ak.us> Account Number: STOF0330 Legal Ad Number: 699873 (Public Notice) Run Dates: January 28, 2003 (everything you gave me says the 28th which is Tuesday. You requested Monday in your e-mail. Please verify which date you want. :) Total Amount: $160.74 Thanks Jody. Please verify the run date and then we'll be good to go! Amy L. Heath Legal Customer Service Representative Phone: (907) 257-4296 Fax: (907) 279-8170 Office Hours 8:00am - 5:00pm legalads@adn.com On Friday, January 24, 2003, Jody Colombie <jody_colombie@admin.state.ak.us> wrote: >Amy, please publish in monday's paper. > > Jody > 1 of 1 1/24/2003 4:08 PM 1 or"" "-"", BP Exploration (Alaska), Inc. 900 East Benson Boulevard Post Office Box 196612 Anchorage, Alaska 99519-6612 Telephone (907) 564 5111 ObP December 9,2002 Commissioners Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 RE: Aurora Pool Area Injection Order Modification Dear Commissioners: Enclosed is the application which requests modification of Area Injection Order No. 22 to encompass injection of miscible injectant to enhance recovery from the AOP and to increase maximum allowable surface injection pressure from 2600 to 2800 psi during water injection. The following information is provided to supplement the application for an Area Injection Order for the AOP, dated June 15,2001. We look forward to discussing this report with you further and setting a hearing date after the 30-day public notice period has ended. BP Exploration (Alaska) Inc., in its capacity as Aurora Operator and Unit Operator, respectfully requests that a hearing commence as early as possible in order to gain approval. Facilities to begin miscible flood operations are expected to be available in March 2003. Please contact Jim Young at 564-5754 if you have any questions or comments regarding this request. Sincerely, ~~~ RECEIVED DEe 0 9 2002 Gil Beuhler GPB Satellites Manager Attachments Alaska OiJ& Gas Cons. Commission Anchorage CC: Neil McCleary (BP) J. P. Johnson (CPAI) G. Carlson (Forest Oil) M. Vela (ExxonMobil) D. Rosiere ( Chevron-Texaco) ORIGINAL ."-"'. Aurora Area Injection OrdL .v1odification "-', 12/912002 Modification of Aurora Area Injection Order 22 Decem her 9, 2002 Area Injection Operations .............,.....................................................................................2 Plat of Project Area """"""""""""""""""""""""""""""""""'"..................................2 Operators/Surface Owners """""""""""""""""""""""""""........................................2 Description of Operation.................................................................................................2 Geologic Information """"""""""""""""""""""""""'"...............................................3 Mechanical Integrity of Injection .Wells......................................................................... 3 Injection Fluids........................................................"""" """""""'" """""""'" ..............4 Type of Fluid/Source............................................""""""""""""""""""""""""""'" 4 Composition """""""""""""""""""""""""""'".......................................................4 Maximum Injected Rate """"""""""""""""""""""""""""'"...................................4 Compatibility with Formation and Confining Zones """"""""""""""""""""""""" 5 Injection Pressures..............................................""""""""""""""""""""""""""'"......5 Fracture Information """""""""""""""""""""""""""""'"..........................................5 Formation Water Quality """"""""""""""""""""""""""""'".....................................6 Fresh Water Strata.......................................................................................................6 Hydrocarbon Recovery """"""""""""""""""""""""""".............................................6 Surveillance Plan.........................................................................................................8 Mechanical Condition of Wells Within a One-quarter Mile Radius of Injectors ...........8 List of Exhibits ................................................,......"""""""""""""""""""""""""""'".... 9 1/9 ~ ~ Aurora Area Injection Ord, ¡odification 12/912002 Area Injection Operations This application, prepared in accordance with 20 AAC 25.402 (Enhanced Recovery Operations) and 20 AAC 25.460 (Area Injection Orders), requests modification of Area Injection Order No. 22 to encompass injection of miscible injectant to enhance recovery from the Aurora Oil Pool ("AOP") and to increase maximum allowable surface injection pressure from 2600 to 2800 psi during water injection. The following information is provided to supplement the application for an Area Injection Order for the AOP, dated June 15,2001. Plat of Project Area 20 AAC 25.402(c)(l) Exhibits 1-1 shows the general location of the pool and Exhibit 1-2 shows all existing and planned injection wells, production wells, abandoned wells, dry holes, and any other wells within the AOP as of October I, 2002. Specific approvals for any new injection wells or existing wells to be converted to injection service will be obtained pursuant to 20 AAC 25.005, 25.280 and 25.507, or any applicable successor regulation. Operators/Surface Owners 20 AAC 25.402(c)(2) and 20 AAC 25.402(c)(3) BP Exploration (Alaska) Inc. is the designated operator of the Aurora Participating Area. Surface Owners within a one-quarter mile radius of injectors within the Aurora Participating Area are as followings: State of Alaska Department of Natural Resources P.O. Box 107034 Anchorage, AK 99510 Exhibit II-I is an affidavit showing that the Operators and Surface Owners within a one- quarter mile radius of injectors within the Aurora Participating Area have been provided a copy of this application. Description of Operation 20 AAC 25.402(c)(4) Development plans for the AOP are described in Section II of the Pool Rules application, dated June 15,2001, with drill site facilities and operations described in Section III of that 2/9 f_~ ~, /"'" Aurora Area Injection Orde.,~odification "'-"" 12/9/2002 , application. The contemplated operation addressed in this application is a tertiary recovery project using the enhanced oil recovery (EOR) technique of miscible gas displacement to increase recoverable oil. The project involves the cyclical injection of water alternating with injection of enriched hydrocarbon gas into the oil column of the Kuparuk River sandstone formation of the AOP. The miscible gas to be used in the project ("Miscible Injectant" or "MI") will be comprised of hydrocarbon gas, enriched with intermediate hydrocarbons, principally ethane and propane. Injected MI forms a miscible bank with reservoir oil through the exchange of hydrocarbon components, effectively displacing nearly all of the contacted oil, resulting in residual oil saturations significantly lower than with waterflood alone. Injected water helps maintain reservoir pressure, retards gravity segregation of the miscible injectant, and controls gas channeling. Aurora wells are drilled from the existing Prudhoe Bay Unit S-Pad. Currently, MI is delivered to S-Pad as part of the Prudhoe Bay Miscible Gas Project (PBMGP). Implementation of the Aurora EOR project will consist of construction of an MI header from the existing IP A MI line to the northern S-Pad trunk and lateral system, and the conversion of up to ten water injection wells to water alternating gas (WAG) injection. Original water injection laterals were fabricated to meet WAG specifications. Therefore, the only surface modifications required to implement the Aurora EOR project will be to the header riser spools. First injection of MI into the Aurora Oil Pool is expected to occur in 2Q of 2003. Procurement of materials for the trunk and lateral along with preliminary engineering is anticipated to begin by 1 Q 2003, with installation soon after. Geologic Information 20 AAC 25.402(c)(6) The Geology of the AOP is described in Section I of the Pool Rules application. Mechanical Integrity of Injection Wells 20 AAC 25.402(c)(8) All newly drilled and converted injection accordance with 20 AAC 25.412, thus requirements. wells have been completed in satisfying mechanical integrity 3/9 r--.... ~ Aurora Area Injection Ordc -,wdification 12/912002 estimated 40,000 bwpd. Compatibility with Formation and Confining Zones Miscible gas is hydrocarbon with similar composition to reservoir fluids in the AOP and therefore no compatibility issues are anticipated in the formation or confining zones. Injection Pressures 20 AAC 25.402(c)(1O) The average surface miscible gas injection pressure for the project is estimated to be approximately 3400 psi. The estimated maximum surface injection pressure for the Aurora EOR project is estimated to be approximately 3800 psi. The resulting bottom hole pressure will be limited by hydraulic pressure losses in the well tubing, with a maximum expected bottom hole pressure of approximately 5000 psi. Installation of a water booster pump anticipated to occur in 2003 would result in a maximum surface injection pressure estimated to be approximately 2800 psi during water injection. Fracture Information 20 AAC 25.402(c)(ll) The Kuparuk River Formation at the AOP is overlain by the Kalubik and HRZ shales, which have a combined thickness of approximately 110 feet. The HRZ is a thick shale sequence, which tends to behave as a plastic medium and can be expected to contain significantly higher pressures than sandstones of the Kuparuk River Formation. Mechanical properties determined from log and core data for the HRZ and Kalubik intervals indicate a fracture gradient from approximately 0.8 to 0.9 psi/ft. A leakoff test that was conducted in Well S-IOI to determine the formation breakdown pressure of the AOP suggests a fracture gradient of approximately 0.73 psi/ft at initial reservoir conditions. This data agrees with data from offset fields containing wells completed in the Kuparuk River Formation. The Kuparuk River Formation is underlain by the Miluveach/Kingak shale sequence. A leakoff test in the Kingak shale formation demonstrated a fracture gradient of approximately 0.85 psi/ft. Miscible gas and water injection operations at the AOP are expected to be above the Kuparuk River Formation parting pressure to enhance injectivity and improve recovery 5/9 r-" Aurora Area Injection Ord,,- -,yfodification ~, 12/912002 of oil. Fracture propagation models and fracturing operations for stimulating wells in the AOP have involved injecting highly viscous fluids at high rates, 25-30 barrels per minute (bpm), and surface pressures up to 6000 psi. During both actual and simulated cases, the operations have not created net pressures sufficient to exceed the integrity of the confining layers. Conditions for planned injection will be at lower rates, less than 10 bpm, and utilize lower viscosity fluids. These operations will result in lower net pressures, and will not cause fracturing to occur through the confining layer. No evidence exists of out of zone injection for analogous Kuparuk miscible gas or high- pressure water flood operations on the North Slope. Formation Water Quality 20 AAC 25.402(c)(12) The compositions of injection water from GC-2 and AOP connate water were provided in Exhibit VI-4 of the original AIO application. The composition of Aurora produced water will be a mixture of connate water and injection water. Fresh Water Strata 20 AAC 25.402(c)(13) There are no fresh water strata in the area of issue (see Section N of the Application for Modification to Area Injection Order No.4, dated April 5, 1993). Additionally, calculations of water salinity from open hole resistivity logs acquired in the Prudhoe Bay Well E-16 indicate a salinity range of 40,000 to 45,000 ppm for Cretaceous and Tertiary sands above the Kuparuk River Formation. Hydrocarbon Recovery 20 AAC 25.402(c)(14) Estimates for original oil in place ("OOIP") for the Aurora accumulation reflect current well control, stratigraphic and structural interpretation, and rock and fluid properties. The current estimates of OOIP range between 110 and 146 MMSTB. The extent of the range of estimates is due primarily to uncertainty in the AOP structural definition and initial oil saturation values. Estimates of formation gas in place range from 75 to 100 BSCF, with 15 to 75 BSCF of this gas residing in the gas cap. Primary and water flood recovery is estimated at 30-40 MMSTB oil, based on reservoir modeling. A fine-scale three-dimensional geologic model of the Aurora accumulation has been constructed 6/9 ,.r-, ~, Aurora Area Injection Ord.... iv1odification 12/9/2002 based on detailed stratigraphic and structural interpretation. This model provides the bulk reservoir volume and porosity distribution for the Aurora reservoir model. The model area encompasses the known extent of the Aurora accumulation. The model has 300 feet by 300 feet (2 acre) cells and is defined vertically with five layers. Faults and structural juxtapositions are honored in the model through the use of corner point geometry and non-local grid connections. Water saturations in the reservoir model were established by capillary pressure equilibrium. Oil water contacts were varied across the pool based on available log data from each fault block. It is estimated that implementation of EaR will increase recovery by approximately 3-5 MMSTB of oil. This estimate is based on fine-scale fully compositional reservoir simulation, using fluid properties and reservoir description from well V -200. A rate forecast from this simulation work showing EOR volumes is shown in Exhibit V -I. The EOR projects in the Prudhoe Bay and Pt. McIntyre Oil Pools Prudhoe Bay have a history of success and are considered good analogs for Aurora. The Pt. McIntyre EOR project commenced in 2001 and has a predicted incremental EaR recovery of approximately 5-7%. Geochemical analysis of Aurora oil samples indicates similarity to Pt. McIntyre and Prudhoe Bay oil characteristics for bulk composition, wettability, and relative permeability effects. Exhibit N -1 illustrates the compositional similarity between Aurora and Prudhoe Bay oil. The Prudhoe Bay 12-component equation of state (EaS), tuned for Well V-200 fluid properties, was used in the reservoir simulation. Relative permeability utilized in the simulation was derived from Pt. McIntyre core flood data. A completed slim-tube experiment defines the minimum miscibility enrichment (MME) of the MI, and confirms miscibility of AOP oil with the proposed MI over the expected range of reservoir pressures. A single well tracer test was performed to define residual oil to waterflood and to MI by measuring returned fluids following a short-term injection and production cycle in the S-104i well. This test provided field data that was used to calculate expected incremental water flood and EOR recoveries, as well as to refine relative permeability curves. A reservoir simulation study will scale up the Well V-200 pattern model results for application to the full pool. Scale up results will be utilized for 7/9 .-- , .... --\ Aurora Area Injection Or<. lv1odification 12/9/2002 optimizing parameters such as WAG ratio, slug volume, optimum MI start-up time, and the required volume of MI. Surveillance Plan To ensure the efficient allocation of MI for the Aurora EOR project, rate and pressure response to injection will be monitored. Production fluid samples will be taken at least annually to assess pattern efficiency based on the returned MI (RMI) ratio. Injection of MI into patterns that do not achieve minimum recovery levels based on comparison to all patterns (i.e., marginal patterns) will be discontinued until recovery issues are resolved. A significant amount of surveillance has been completed to assess producer-injector connectivity. This work has included static pressure monitoring, material balance estimates and acquisition of repeat-formation tester (RFf) data to assess layered depletion effects prior to initiation of water injection. Due to strategic placement of injection wells using this data, all injection wells planned for MI have confirmed communication to offset producers. Injector well pressures will be closely monitored to identify any patterns that exhibit a lack of communication to production. Mechanical Condition of Wells Within a One-quarter Mile Radius of Injectors 20 AAC 25.402(c)(l5) Five injection wells are proposed for MI service: Wells S-lOli, S-I04i, S-1O7i, S-1l2i and S-1l4i. A map showing all penetrations through the AOP, and wells within a one- quarter-mile radius of the injection wells are shown on Exhibit 1-2. A report on the mechanical condition of each well that has penetrated the injection zone within a one- quarter mile radius of a proposed injection well is included as Exhibit VI-I, with a copy of the most recent schematic diagram for each well included as Exhibit VI-2. Mechanical integrity has been established for the subject wells based on calculated cement tops being at an adequate height above the injection zone to prevent fluid that is injected into the AOP from flowing into other zones or to the surface. Exhibits VI-l and VI-2 contain mechanical integrity data only for wells within a one-quarter mile radius of the injectors. However, static pressure and repeat formation tester data support the conclusion that the completions in offset wells beyond this radius are sufficient to contain 8/9 r-', Aurora Area Injection Ord('!odification ~ 12/9/2002 high pressure fluids, including gas, within the AOP. Although injection pressure will exceed average AOP reservoir pressure, reservoir modeling indicates rapid reservoir pressure falloff away from the injector during water and MI injection. Reservoir modeling indicates a radius of pressure influence less than 1000 feet from the injector at the end of the MI cycle. List of Exhibits I-I 1-2 II-I Aurora Pool Location Top Structure Map with offset penetrations Affidavit III-l S-lO 1i Completion Schematic 1II-2 S-104i Completion Schematic III-3 S-1O7i Completion Schematic 111-4 S-112i Completion Schematic 111-5 S-114i Completion Schematic IV -I Aurora and Prudhoe Bay Oil, MI Properties V -I Production and Recovery Profiles for Miscible gas Injection VI-la Offset Integrity: Wells Within 14 mile of Injectors VI-lb Mechanical condition of Wells Within 14 mile of Injectors VII -1-12 Schematics of Wells Within 1A mile of Injectors 9/9 Exhibit 1-1 Au rora Location COLVILLE RIVER UNIT .r-- r- '-, l. l '--J"---J . ~--- , r , I I , r ,_.r- ¡...I SANDPIPER UNIT ^-~ MILNJ;. P?INT UNIT '""1 ":",.".. - """"t:;.7c-<.::<::, ........... L L_\ . -' NORTHSTAR UNIT i-'~'l '¡ )~¡ '~'-r~l L ,~ ..<> , '"'1 AURORA POOL .--1 -L, ""'L - - , , ) ~~" - , I PRUDHOE BAY U~ - - . J ' , r- -- . -' ~ - J I r _..J KUPARUK RIVER UNIT '1 . , I l~.1 ) 10 15 Miles BPXA Cartoaraohv/4-12-2001/1m14369,dan Aurora Enhanced Oil Recovery Project ,"""', ---- U) CD 3: c 0 .- +- 0 CD .- C E 0 ~ 't- -',- .- .- -c c ~ .- E 1"""--. .-" Exhibit II-I AFFIDA VIT STATE OF ALASKA THIRD JUDICIAL DISTRICT I, Oil Beuhler, declare and affirm as follows: 1. I am the Supervisor of the Greater Prudhoe Bay Satellite Development for BP Exploration (Alaska) Inc., the designated operator of the Aurora Participating Area, and as such have responsibility for Aurora operations. 2. On / J. /cJ/O;;' , I caused copies of the Aurora Oil Pool, Modification of Area Injection Application to be provided to the following surface owners and operators of all land within a quarter mile radius of the proposed injection areas: Operators: BP Exploration (Alaska) Inc. Attention: N. McCleary P.O. Box 196612 Anchorage, AK 99519-6612 Surface Owners: State of Alaska Department of Natural Resources 550 West 7th Avenue, Suite 800 Anchorage, AK 99501-3510 Lease Owners: ExxonMobil Production Company Attention: M. Vela 3301 C. Street, Suite 400 P.O. Box 196601 Anchorage, AK 99519-6601 Phillips Alaska, Inc. Attention: Jim P. Johnson 700 G. Street P.O. Box 100360 Anchorage, AK 99510-0360 Chevron USA Production Attention: D. Rosiere 3601 C. Street, Suite 822 Anchorage, AK 99503 Forest Oil Corporation Attention: G. Carlson 310 K Street, Suite 700 Anchorage, AK 99501 Dated: / ~ ~;)... ~\\\\\II"I"lillJ/j¡1 ~ ~1e 8b~ ~~«-:,.".....,.':!/)' ~ ~~"" "'~ ~ §~.. " ~ § , ~' ~ ~ i NOTAK1 \ !æ ¡ \ PUBLIC} *~ :~* '¡;"" ..,"q ~ J:{';."""",~\..~~~ ~ If OF r' ~ ~III"'I/I!I \\\\\~. -~ ß~~ Oil Beuhler ~ Declared and affirmed before me this ~ay Of~ ~. ~ Notary Public in and ~ My commission expires: /'/ 7/ DC:. (' TREE=4>;1/16" - 5M CIW, Cf-ROME Wa.LHEAD=13-5I8" - 5M FMC SH ACTU\ TOR= BAKER KB. B.EV = 64.45' BF. B.EV = KOP; Max An~e = DatumMD= DatumlVD= 1046' 97 @ 9343' 9592' 6764' 110-314" CSG, 45.5#1fl. L-BO 1-1 BTC, ID= 9.950" I Minimum ID = 2.75" @ 2206' 3.112" HES 'X' NIPPLE I 3-112"lBG, 9.2#, 13Q-80 FOX I .0087 bpf, D=2.992" r TOP OF 4112" LNR I 7" CSG, 26#1ft, L-80-BTC-M .0383 bpf, ID= 6.276" /"""' 1[. , .---. 5-101 SAFElY OOTES: WB.L HAS 3-1/2" Cf-ROME TUBING 4014' rJ 8712' g / I 8736' \ 8880' t- ÆRFORA TION SUMIo1ARY REF LOG: MND 8/8100 ANGLE AT TOP ÆRF: I 96 flbte: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSqz DATE 4-/12" 6 8850-8960 0 03/30/01 4-112" S 9535-11699 SLOT 08/31/00 I TOP OF 4 1/2" SLOTlED Lt\R I 12.6#, L-BO IBT, ID= 3.958" I BOTTOM OF SlOTTED Lt\R I 4-112" It\R, 12.6#/ft, L-80 I Do\ TE 08124/00 11/13/2000 1/26/2001 03107/01 4.9/2001 REV BY ORIGINAL COfvPLEfION SIS-SL T COrwERfffi TO CANVAS SIS-LG REVISION ŒI/KAK CORRECTIONS KAK ÆRFS 9535' I I 11700' 1 I 11721' I COMIvENTS I - 1 3-1/2"HES "X" Nipple, ID= 2.75" I 2206' ~ GAS lFT M\NDRElS STA MD lVD DBI lYPEMAN LA TCH 4 4437 3690 44 CA MM3 BXP RK I 3 7309 5786 40 CA MM3 BXP RK 2 8248 6487 52 CA MM3 BXP RK - 1 8553 6634 65 CA MM3 BXP RK 8661' 3-1/2" H6S 'X' Nipple, ID= 2.75" I :8: :8:--1 8674' 8699' I \ g I 8709' I I 8713' I 8'--1 8724' I I 8731' I 7" x 4-112" Baker 'S-3' A<R-NSCT with XOPUPSto 3-1/2", D= 3.875 I 3-1/2"'X'Nipple, ID=2.75" r I I BOT 7 X 5' lner Hanger-HYDR. ID=4.437" I BOn" x4-1/2"XO,ID=3.938 I TT a.M NOT LOGGED 7" BAKERZXP A<R, ID=4.437" I WLEGw /41/2" XO I ~ . . 9402' H Profile Nipple-BOTIND. SUB I I ID= 3.844" 9410' H BOT HtvCV, ID= 3.958" I I I - . 9421' H Profile Nippie-BOllND.SUB,ID= 3.844" I . 18 H EXTERNð.l CSG PACKER I I ID= 3.958" ~ 9429' I 11699 H 41/2" ffilLlABLE I ' I P.O. BUSHNG AURORA UNIT WELL: S-101 PERfI.1fT No: 200-1150 AA No: 50-029-22968-00 SEC35, Tt2N, R12E BP Exploration (Alas ka) r. " TR!:¡E = . ' WB.LHEAD = ACTU\TOR= KB. B.EV = 'BF. B.EV = KOP= ~ax Ange = Datum MD = OatumlVD = 4-1/16"CIW FMC NA 64.50' 38.22' 750' 57 ~ 3230' 9100' 7000' SS 19-518" CSG, 4O#,l-BO, ID =: 8.835" H 3736' Minimum ID = 3.725"@ 8724' 4-112" HES XN NIPPLE 17" M\~ERJT(20') WI RA TAG H 6499' 4-1/2"TBG JT#40 W/ RA TAG H 6681' ÆRFORA TON SUMIo1ARY REF LOG: SWS PlATFORM EXPRESS GR'R6S 01/27/01 ANGLE AT TOP PERF: 29 @ 6920' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSqz Do\ TE 4-518" 6 6920 - 6980 0 02,Q4/01 4-518" 6 7018-7050 0 02,Q4/01 4-518" 6 7070 - 7094 0 02,Q4/01 4-518" 6 7114 - 7124 0 02,Q4/01 4-518" 6 7162 - 7182 0 02,Q4/01 4-518" 6 7216-7266 0 02,Q4/01 4-518" 6 7280 - 7302 0 02,Q4/01 4-518" 6 7325 - 7346 0 02,Q4/01 3-318" 6 8810- 8840 0 03126/01 4-112"lBG, 12.6#, l-BO, .0152 bpf ,10 = 3.958" H 8736' ~ "-2.. 5-1 04 - - =--i t- ----1 It , - ----l ~ z-i ~ -!-L.. ïJ -l-l- 1 ; z-I I ~ I I - I] z :;:s f-; '----1 U I 9100' I ~ 9186' ~ I 7" CSG, 26#, L-80, M-BTC, D = 6.276" H Do\ TE RBI BY COMlo18'JTS 02,Q9/01 ORGINð.L COfvPLETION 02/10/01 Cismoski CORRECTIONS 06/11/01 GRC/th PERFCORRECTION 09,Q3/01 KSB/th NIPA.E ID CORRECTION 04,Q9/02 RNICHITP CORRECTIONS Do\TE REV BY ,--. I SAFEfY NOTES: 1008' H 9-5/8" TAMPORf COllAR 2403' H 4-1/Z'HESXNP,ID=3.813" ~ ST MD 5 4839 4 6731 GAS lFT M\NDRElS lVD DEV TYPE VlV LATCH PORT Do\TE 3495 54 KBG-2- T/L DOME BK 16 03112/01 4883 31 KBG-2-T/l SIO BK 20 03112/01 PRODUCllON MANffia.S lVO DEV TYPE VLV lATCH PORT Do\TE 5046 29 KBG-2-T/l DMY BK 0 02/07101 5218 30 KBG-2-T/l DMY BK 0 02/07101 5347 30 KBG-2-T/L DMY BK 0 02/07/01 ST MD 3 6920 2 7117 1 7266 6842' H 4-1/2" H6S X NIP, 10 = 3.813" I 6853' H 7" X 4-1/2" BKRSABL-3 A<R. ID= 3.875' I 7035' H 4-1IZ' BKR QAU SUDING Sl V, 011S ffiOF., 10 = 3.812" I 7061' H 7"X4-112"BKRSABL~3A<R,ID=:3.875'1 7175' H 4-1/Z'BKRCMJSlIDNGSlV,OTISPROF,ID=3.812" 1 7201' H 7"X4-112"BKRSABl-3A<R,ID=3.875' I 7333' H 4-1/2" BKR QAU SLDING Sl V, 011S ffiOF, ID = 3.812" 1 8679' H 7"X4-1/Z'BKRSABL-3PKR,ID=3.875" H 4-1/2"H6SXNIP, 10=3.813" I 8703' 8724' H 4-112" HES XN NIP, ID = 3.725' I 8736' H 4-1/Z' WLEG, 10 = 4.00" I H a.MDTTNOTlOGGED I COMIvENTS PRUŒiOE BAY UNIT / AURORA RB.D WELL: $0104 PERMIT No: 200-1960 AA No: 50-029-22988-00 SEC35, T12N, R12E, 4646' NSl & 4494'Wa. BP Exploration (Alaska) - . /"\ 1lC.. 3 8-1 07 ~ ! T.ÆE=, NA - 'WElLHEAD=: FtvC ACTU\ TOR= NA KB. a.EV = 69.4' 'BF. a.EV = 35.9' KOP = 700' M3x Angle = 101 @ 1,5229' DatumMD= 12155' DatumlVD= 6745 SS SAFElY OOTES: Wa.l> 70 deg @ 12483' AND> 90 deg @ 13601'. - - =-f 1 993' H10-314" TAM PORT COllAR I H 4-1/Z' H6S HXO SSSVN, ID = 3.813" 2277' 110-3/4" CSG, 45.5#, L-BO, ID = 9.9BO" H 4265' ~ IMinimum ID = 3.725" @ 12250' I 4-112" HES XN NIPPLE ST MD 4 6491 3 11628 GAS lFT M\NDRElS TVD DEV TYPE VlV LATCH PORT Do\TE 3810 57 KBG-2 DV BK 08l09,Q1 6522 58 KBG-2 DV BK 08l09,Q1 PRODUC110N MANffia.S lVD DEV TYPE VlV LATCH 6714 67 KBG-2 DV BK 6740 68 KBG-2 DV BK PORT Do\ TE 08l09,Q1 08l09,Q1 - L -ST MD - 2 12030 1 12096 IRATAGSINJT#10 H 11665' I I 11654' H4-1/2" H6S X NIP, ID= 3.813" I . z z---i 11718' H7" x 4-1/2" BKR PREM PKR, ID =: 3.890" I ;& Z"--J 11823' H7" x 4-1/2" BKR PREM PKR, ID =: 3.890" I ~ I 1196T H4-112" a.1USLIDING SlV,ID= 3.81Z' I ;& I 12202' H4-112" /-ESX NIP, ID =3.813" I z----i 12223' H 7" x 4-1/2" BKR PREM PKR, D =: 3.890"1 I 12250' H 4-1/Z' /-ES XN NIP, ID = 3.725' 1 ~ 12259' H 7" X 5" BKRZXP PKR W/ ìlEBACK. 10 = 5.250" I 12263' H4-1/Z' WLEG, ID = 3.958" I H a.MD OOT lOGGED 1 12274' H 7" X 5' BKR HMC LNR H<\ NGER, ID = 4.430" I ~ 4-1/Z'lBG,12.6#,L-BO,.0152bpf,D=3.958" H 12262' I ~ 17" CSG, 26#, L-80, ID = 6,276" H 12421' t..--.... PERFORATION SUMIo1ARY REF LOG: SPERRY-SUN MWD OF 7-28-01 :;--4 15019' H4-1/Z' EXTCSG PKR, ID =3.937"1 ANGlEATTOPPERF: 59 @ 11730' ~---¡ flbte:RefertoA'oductionDBforhistoricalperfdata ~~rl 15127' HTOPOF4-112"Sll'DLiNER I SIZE SPF INTERo/ Al OpnlSqz Do\ TE ... ... Nt>. 4 11730-11732 S 07/17,Q1 """'... Nt>. 6 11735 -11737 0 07131,Q1 ....' , ... .... Nt>. 6 11850-11852 0 07131,Q1 "'..."'... 4-518" 5 11900-12150 0 07131,Q1 ""... """'... ~ Nt>. 4 11950-11952 S 07/17,Q1 """.......""" ~Î 15938' I 4-518" 5 15127-15938 0 08,Q3,Q1 """... ~ r 4-1/2" SLOTTED lNR. 12.6#, l-80,ID = 3.958" H 15938' ~ 4-1/2"Lt\R,12.6#, l-80, 0.0152 bpCAf, ID=3.958"H 15980' DATE REV BY COMM8'JTS 08/09/01 ORIGNAL COMR.ETION 08/18/01 CH/Uh COMR.ETION SŒlEMA l1C 02/07/02 JY/KAK PERFCORRECTON/ADD. 05/09/02 Do\atlh MANffia. CORRECTIONS DA TE RBI BY COWM8'JTS PRUDHOEBAY UNIT WELL: S-107i ÆRMT fib: 201-113 API fib: 50-029-23023-00 4556' NSL & 4496' Wa., Sec. 35, T12N, R12E BP Exploration (Alaska) ,.,--., ; TREE= ' Wa.LHEAD =: ACTU\ TOR = KB. B.EV = BE ELEV'~ KOP= Max Ange = Datum MD = DatumlVD = 120" x 34", 215.51b1ft. A53 ERIN INSULATED H FMC4-1/16" 5M FMCGEN 5 69.60' 5626' 96 @ 7457' 19-5/8" CSG,40#, L-80, BTc, ID = 8.750" H I Minimum ID = 3.725" @ 6706' 4-112" HES XN NIPPLE 14-1/Z' TOO, 12.6#, L-80, .0152 bpf, ID =: 3.958" H IT' CSG, 26#, L-BO, ID = 6.276" H, 6825' 14-1/2" lNR. 12.6#, l-80, .0152 bpf, ID= 3.958" H PERFORA 110N SLMMt\RY REF LOG: ANGlE AT TOP PERF: 95 @ 7650' Note: Refer 10 A'oduction œ for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE SL TO 7650 - 8535 0 14-1/Z' Sl TO LNR, 12.6#, L-80, .0152 bpf, ID = 3,958" H Do\ 1E RBI BY COMfI£NTS 08107/02 JDM/KAK ORiGINt>.L COMA...E1l0N 08115102 RLI1P GLV C/O 1Jr- 4 5-112 114' I I r---- 2915' ST MD - 3 3850 L 2 5654 - - 1 6529 ::8: z----J 6717' ~ ~ ~ ~ ~ . ,.-, 7650' -- I I I I I I I I I I I I I , I I I I I I I I 8535' r - - - - I DATE REV BY COMIvENTS .. .. 6863 7542' ~ I SAÆTY NOTES 2257' H 4-1/2"HESXNIP,ID=:3.813" I GAS LIFT MANDRElS lVD DBI TYPE VlV lATCH 3813 1 KBM3-M OOIvE BK 5617 1 KBM3-M OOIvE BK 6451 35 KBM3-M SO BK PORT Do\ TE 16 08113102 16 08113102 20 08113102 6658' H 7"X5"BKRPRfI.1A<R.ID=3.875' I 6685' H4-1/2"HESXNIP, ID= 3.813" I H4-112"I-ESXNNIP,ID=:3.725'1 6706' 6710' 6718' H 5" X 7" BKR ZXP lNR TOP A<R, ID = 4.390" 1 H I 4-1/2" Wlffi, ID =: 3.958" 1 ELMDTTNOTlOGGED I H 4-1/2" SHORT JOINTW/RA TAG 1 H 4-1/2" Cßo.1ENTED PAYZONE ECP,ID = 3.937" I PRUDHOE BAY UNIT WELl: S-112 PERfI.1fT No: 2021350 AA No: 50-029-23099-00 SEC. 35, T12N, R12E4332'FSL, 45O1'FB. BP Expbration (Alaska) Exhibit V-1 Rate Forecast Aurora WF+EOR Production Forecast 12 'C - (,) I/) E E 8 IWWMÞA1I EOR Oil Production c:::::::J Oil Production 6 .. 0 'C .J:l - I/) E 4 - 2 - g RJ & RJ g¡ 0 r:v <0 ~ ;;g RJ & 0 r:v 0 ,... RJ r:v ,... RJ <0 ,... RJ co ,... RJ "1" ,... 0 r:v 0 & r:v ~ ~ ~ ~ <0 & r:v 14 Aurora Waterflood Production Forecast c:::::::J Oil Production - Water Production "~"'kM'"Water Injection - Gas Production -------------------------------- c 10 0 :;:: (.) -5 8 u 0 ... 0- :g 6- - I/) E 4 - 2 - O~N~~~~~ro~O~N~~~~~ro~O~N~~~~~ro~o oooooooooo~~~~~~~~~~NNNNNNNNNN~ 0000000000000000000000000000000 NNNNNNNNNNNNNNNNNNNNNNNNNNNNNNN '. ) 0 ~ 35 30 " - (,) III 25 E E ) ... 0 c 0 :¡:: (,) G> :s 10 " ~ - III 5 E 20 15 Aurora Enhanced Oil Recovery Project . , ,r-- ,TREE= , - Wa.LHEAD = ACTlJA TOR = ¡(B. ELEv = BF. ELEV'; Ï(OP= MõIX Anglll = DatumMD= Datum lYD = 41116"5MCW 13.5JI3"SMFMC -jG.5o1 31' "1169' 75 @ 3497', 13040' 67011 S5 11D-3J4" CSG, 46.5#, L.aO, ID = 9.050" H 6140' ¡Minimum ID = 3.725" @ 14258" 4-112" HES XN NIPPLE 14112" TBG, 12.6#. L.BO, .0153 bpf,lD =3.958" H 14269' I PERFORATION SUht1v1ARY REF LOG: ANGLEA T TOP PERF: Note: Refer to Production DB for hiÞtorioal perf data SIZE SPF INTERVAL Opn/Sqz DA iE ""'-15' S-114A - - ~ L - 8: ~ I Œ!Ðl 14410' 1 .~ 7"CSß,26#,L.ao,ID=6.27t1' H 14555' ~ DA iE REV BY {:OtJMENTS 09130102 JLtvW::K ORIGINAL COMPLE1l0N 11/26102 DTRfTP GLV C/O DATE REV BY COMM8'J~ ~ I SAFETY NOTES: :---1 991' H TAM PORT COLLAR 1 2323' H 4112"HESXNIP,ID=3.813" 1 GAS LIFT Wo.NDRELS ST MD WD DBI TYPE VLV LATCH PORT DATE 2 74G6 3713 73 KBß DOME BK 16 11/26/02 1 14127 6436 33 KBG SO BK 24 11r.æ1U2 I 14193' H 4112" HESX NIP.ID =3.813" I 1 14213' H 7" x 4112" BAKER 5-3 PKR,ID = 3.'"5" I 14237' H 4112" HE5X NIP, ID =3.813" I 14258' H 4112"HESXNNIP,ID=3.725" 1 1 14270' H 4112"WLEG,ID=3.958" I ELND NOT LOGGED I 14309' H 7" Wo.RKffi JT I I 14371' H 7" Wo.RKffi JT I AURORA UNIT WELL: S-114A PffiMT No: 20219130 API Nil: 5D-029-21807-60 SEe 35, T12N, R12E. 4617' NSL&44Q6' WEL BP B<plerati.n (Alaska) Exhibit IV-1 Comparison of Aurora and Prudhoe Bay Fluid Composition 50% 45% 40% 35% 30% c 0 :¡:: u ca &! 25% Q) Õ :æ 20% I Prudhoe Composition . Aurora Composition 15% 10% 5% A . 0% A .. 2 3 4 5 6 7 8 9 10 11 12 Component Number 13 14 15 16 17 18 19 . Component number Name 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 CO2 N2 C1 C2 C3 -C4 N-C4 I-C5 N-C5 C6 C7 C8 C9 C10 C11-13 C14-'19 C20-26 C27 -35 C36+ ') ) Aurora Enhanced Oil Recovery Project , " ,.... Exhibit VI-1 Offset Well Integrity: Wells within 1320' of injection ) S-112i only current AOP injector w/offsets within lA mi. radius Well I Meas Subsea TOC Est. (30%) Job' Comment, other Status .11 Depth at Depth at Offset (30%wash Cement abo\e Flags e\ñdence of Name Well Status Desc TKUP (ft) TKUP (ft) (ft) out) MD AOP (ft) ? confinement ) w_--,-----,-, " 8-24 8-25A 8-26 8-32 8-33 8-35 8-36 8-37 8-38 8-42 8-43 Exhibit VI-1 b Integrity Report of Offset Wells Problem 401 Tubing x IA comm, tubing hole at 7062' 1,280 810w IA x OA communication 925 810w IA x OA communication 564 None 1,192 None 397 None 1,139 None 568 None 883 T x IA comm, TlFL failed 11/2/02, FTS. 846 None S112 offset Well,~m, :&: (ft) 8-10A 843 Note: Does not show up on the WOA 81 Well Report. 617 810w Tubing x IA communication, MITIA's pass. Status No tubing, perfs are cemented oft None Planned Action On injection Low OA FL - Priority 1 81 as of 10/00, RWO scheduled 1. DHD: Check OA FL every 6 months. Waivered IAxOA comm [10/13/02] See "137 List" Temporary IAxOA comm waiver issued 03/15/01 None None None None PAL None None 1. WDE: Eval for OA downsqz- done r Down sqz on holdl None APE requested TlFL, rapid production rate loss None None Eval possible IA x OA communication (07/14/02) Obj: Eval for TxlA waiver None I " , , ) ) ~~~ ~\,,~.,~, ~~:f ~~. bp ..'r~ i-:'. . Þl;,.~~"" -,y..- ~, -m - , ,~. ENGINEERING DATA A ' SHEET NO. -L OF L SUBJECT S-JO St{sp-eY\('j.~ð'I Lct'\ðìhöY\. J BASED ON ])-¡\\illj rtfðr1S f(,~\Jì(),^.\ ltJR<) J l')Q.\\ Ç-ik-') BUDGET/AFENO. Q30....0ð<¡S1 ENGINEER ..r«ì~-t,.... DEPT. APP'VL DATE 4-d.ö-o \ FILENO. L1'~"P.t~if}ft hv.'\j:;',";.'.1 It/: (~ \('ee~ L{1l/, s::t:1f- VQ\~ eA~ o.Ç. tb~ ~~{¡r ;~?,:. .' //,,/~,:~¿:;/{: li>e/fbJ: ßS)ð'/5lX:ú~ t11cL /--;'/ ~ ()(.e~>~cr:,,/~~ f'clu~k( ~ ? - VJ 1<ß: &7.Sl.9' ~ GL: 31. "ð(/ wh;p:s.bc.l:. L.ùn;fI:::'\c::c..k. f>OL<:..l-e..- l'1ÓO' lOp of c.t::t....J{>I~-T\à 'i.O:5:3¡ ','" ' . íOf o~ 1 L ¡roe-I'"" ~C::o Z "",~ " ",Z I W: 'fJ-I\I# , L.'~C>, eJ:12S ( 51("'1') A. ~\"'" ~'~ /)/~ '// // (k% / / / /' / /',,/./ ,/ . / / ./ /OfJ 9t, ì)' /, .././ ')!Ø""/'~"'~~~'U,í?/'" , f//'-:/:/( f:XÎí:j/'l'þ.J a I' I~I/J. X. . ,.lÙ/;i.rt,¡ 17/5 íD . " Iz,!>/gl', ldiFj.r+ ,L-'to 1 ßT{:5:,'" \cY 10 7'1'\ -- Töf ~f c.rvvt. rh.tj ~ ì7<11 ïll.;J&~/ff ¿-go .1J4S ) I AI< 2337 (11100) ~~\ --= V\ ~l#'V GcJ 7r¿8:;- 72nc¡ I ~ Sìd.~~ \ TD ~lP~/MÖ ~4~' TV{)SS, 5vO API 50- o~~ -dO7lPS'"-()\ sect. 3S-¡ T\dtJ 1 R\dt:: Minimum ID = 3.725" @ 9996' 4-1/2" XN NIPPLE 19-5/8" EZSV H 3020' 10LD 9-5/8" CSG r-- ¡--... . . 1REE = !dWEÛ~HEÁD= AC1UA TOR = KB. 8..BI = BF. B...EV = KOP= Max Angle = Datum M:> = Datum lVD= 4-1/8" CÞN McBlOY AXa.SOÑ 64.77' 35,43' 2782' 97 @ 12411' 10430' 8800' SS 1 TOP OF Cev18'JT H 113-318" CSG, 68#, N-80, ID = 12.415" H 2669' 2668' 1- ,~ 5-24A SAFETY NOTES: 9-518" CgG CUT, PlLLIÐ & MILLED FROM SURFACE TO STlB @ 2739' HORIZONTAL LNR 70. @ 10383' AND90" @ 11758" . - 2195' H4-1/Z'HESSSSVNP,ID=3.813" 1 9941' H4-112" X NIP, ID = 3.813"1 H7" BAKER S-3 A<R. 10= 3.875' 1 H4-112" X NIP, ID= 3.813" 1 9996' H4-1/Z' XN NP, D =3.725"1 1 10004' Ha.MDTTLOGGED09/24/99 1 10008' H4-1/2"W/LEG,ID:4.00" 4-1/Z'lBG,12.6#,L-BO,0.0152bpf,ID=3.958" H 10008' TOPOF4-1/2"lNR H 10003' I 17" Lt\R, 26#, L-BO WOO, 0.0383 bpf, D = 6.276" H 10180' PERFORA 110N SUMM\RY REF LOG: ANGLEA TTOP PERF: 97 @ 12377' flbte: Refer to A'oductbn œ for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 12377 - 12597 0 09199 ~ 12599' 1 14-1/Z'LNR,12.6#,L-BO,O.0152 bpf,ID=3.958" H 12687 I - RBI BY COMlo18'JTS Do\TE REV BY COMIvENTS Do\TE 05/12/90 ORGINAl COfvPLEfION 09,Q1/99 SIDETRACK COMR.E1lON 03/14/01 SIS-M-i cOtWERTEDTO CAtWAS 03/15/01 SIS-M:> FINAL 03,Q2/02 RIIVTP CORRECTIONS PRUDHOE BAY UNIT WB.l: S-24A PERMIT No: 198-2450 AA No: 50-029-22044-01 SEC 35, T12N. T12E BP Exploratbn (Alaska) SAFETY NOTES: PORTIONS OF THIS WB.l'S FLOWLINE ARE 3" AND SUBJECT TO EROSION. THE GC SHOULD BE NOTIFIED OF A NY Wa.L OPERA 110N THA T COULD INCREASE THE FLOW OR EROSION RATES. WELL EXCEEDS 70° @ 9350' & GOES HORIZONTAL @ 9650'. TBG PATCH & RUNNING TOOL (FISH) @ 7032'. TOOLS LOST ON 06/02/00. r--- .3 !' TREE= ' ~ W8.LHEAD = ACTUATOR = - -, .. KB. B.EV = BF. B.EV = KOP= Max Angle = Datum MD = Datum lYD = 4-1/16" CIW FMC OTIS 65.75' 36.15' 5000' 92 @ 10996', 9253' " 8800' SS 2091' 5-2 SA . [I3-3/8" CSG, 68#, NT-80, BTRS, ID = 12.415" 1-1 ~ ~I 2680' Minimum 10 = 2.37"@ 8923' I 2-7/8" LNR TOP STA MD lYD I 5 3102 3036 V-- 4 5217 5149 - 3 7016 6812 2 8622 8258 1 8848 8459 ~ 7O:~74~ I TOP OF 7" LINER 1-1 8509' r-. . :8 I TOP OF 2-7/8" LNR. ID = 2.37" H 8923' ~ . I 8877' ~ 8882' :8 I 8884' I 8916' , 8940' 8961' I 9-5/8" CSG, 47#, NT-80S, NSCC, ID = 8.681" H Œ1I2" TBG, 12.6#, L-80, 0.0152 bpf,lD = 3.958" Ii 8730' 8973' ~ 8974' 8980' PERFORATION SUMMARY REF lOG: BAKER MWD RESISTIVITY ON 11/11/98 ANGLEATTOPÆRF: 90 @ 11364 Note: Refer to Production DB for historical perf data I SIZE I SPF I INTERVAL I Opn/Sqz I DATE I 2 4 11364-11434 0 11/24/98 I 7" LNR. 26#, L-80, .0383 bpf, ID = 6.276" 1--1 9671' .--.., H 4-1/2" OTIS SSSV LANDING NIP, ID = 3.813" 1 GAS LIFT MANDRB.S DEV TYPE MAN LATCH SIZE Vl V 0 OTIS RA 1-112" DOME 10 OTIS RA 1-1/2" S/O 24 OTIS RA 1-1/2" OPEN 27 OTIS RA 1-1/2" DV 27 OTIS RA 1-1/2" DV DATE 11/27/98 11/27/98 02/11/01 11/27/98 11/27/98 TOP OF OWEN RUNNING TOOL (FISH) I 4-1/2" HES PERMANENTTBG PATCH 1 1--1 4-1/2" PARKERSWS NIP, ID= 3.813" I 1--1 BAKER TUBING ANCHOR 1--1 9-5/8" BAKER PKR, ID = 3.99" I H 3-3/4" BKR lNR DEPLOY SL V, ID = 3.00" I 1--1 4-1/2"PARKERSWSNIP,ID=3.813" I 1--1 4-1/2" OTIS XN NIP, ID = 3.725" I l-i 4-1/2" TUBING TAIL WLEG I l-i ELMD TT - lOGGED 11/09/90 I I 7" MILLOUT WINDOW I 9162'- 9167' 1--1 TOP OF WHIPSTOCK I l-i RA MARKER I I PBm(œ~ H 1148T I ~ I 2-7/8"LlNER.6.16#,l-80,ST-l,.0068bpf,ID=2.37" H 11554' I DATE REV BY COMMENTS DATE REVBY COMMENTS OB/17/90 HF ORIGINAL COMR..ETION 06/27/01 CHITP CORRECTIONS 11/24/98 CTO SIDETRACK 01/20/99 GLM UPDATE TO PC 12/05/00 SIS-JLH CONVERTED TO CANVAS 12/12/00 SIS-JLH REV IS ED PRUDHOE BA Y UNIT WB.l: S-25A PERMIT No: 98-214 APt No: 50-029-22077-01 1633' SNL & 4158' WEL, SEe 35; T12N; RG12E BP Exploration (Alaska) r"-. 4- 5-26 ,~ .- ~T~= , .. WB.,LHEAD = ACTU\ TOR = KB.-ELEV -;;-- BF. ELEV =: KõP;------ - Max An~e =. Datum MD = Datum lVD = 4"CIW FMC OTIS ---65.0g 37.49' .,.., -MOÓ' 23jL53...~6', 9073' 8800' SS SAFElY OOTES: 3" FLOWLINE IN SKID POR110NS OF THIS WB.L'S FLOWLINEARE 3" AND SUBJECT TO EROSION. THEGC SH)ULD BE NOTIFIED OF ANY WB.L OÆRA TION WHIŒI COULD INffiEASE FLOW OR EROSION RATES . 2104' H4-112" OTIS SSSV NIp, ID = 3.813" 1 8524' 8539' GAS LIFT M\NDRElS lVD DBI TYPE V LV LATCH PORT Do\ TE 3052 1 011S RA 4981 23 011S RA 6828 18 011S RA 7851 7 011S RA 8232 6 011S RA H4-1/Z' PARKERSWS NP, D =3.813" 1 HOTIS RATCH-LATŒI ANCH)R I 113-318" CSG, 68#, NT-80, ID = 12.415' H 2683' ~ Minimum ID = 3.80" @ 8613 4-1/2" OTIS XN NIP, MILLED OUT L - .. ST M) 5 3119 4 5078 3 7071 2 8121 1 8504 14-1/Z' lBG, 12.6#, L-BO IDS, 0.0152 bpf, ID = 3.958" H 8624' --I Z-I 8540' H 9-5/8" 011S PKR. ID = 3.85' I I ---1 8593' H4-1/Z' PARKERSWS NP, D =3.813" I 8613' H4-1/Z' 011S XN NIP, ID = 3.725' MllED TO 3.80" I 8624' H4-1/Z' W/Lffi I 8627' H a.MD TT LOGGED 06/15/90 I I TOP OF T' Lt\R H Z 8570' I---) 19-5/8" CSG, 47#, L-BO, ID = 8.681" H 8816' r-- ~ PERFORA 110N SUMM\ RY REF lOG: SWS BHCS ON 05124190 ANGlEATTOPÆRF:4@ 8951' Note: Refer to Production œ for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8951-8961 0 08/26/90 3-3/8" 4 8965-9053 0 08/26/90 3-3/8" 4 9085-9130 S 09/10/94 3-3/8" 4 9184-9186 S 09/10/94 ~ ~ 9030' HZIPW/ RUNNNGTooLS 1 " 9139' HBAKER ECP, SCOOP GUIDES, I I RUI\NING TOOL, AND OLD IBP ..---¡ 9181' HM\RKERJOINT 1 [§]-i 9390' I . ¡:z:: It\R, 26#, L-80 U4S, 0.0383 bpf, ID = 6.276" H 9433' I [}II. TE RBI BY COMIvENTS DATE REV BY COMIvENTS 06/04190 ORiGINt>.L COMA.E1l0N 03/09101 SIS-M- CONVERTED TO CANV AS 03/12/01 SIS-M) FINt>.l 09/07/01 RNI1P CORREC110NS PRUDH)EBAY UNIT WB.L: S-26 PERMT 1\1:): 90..Q5BO API 1\1:): 50..Q29-22O47-00 Sec35, T12N, RG12E 8P Exploration (Alaska) r----. ~- ~'TRŒ=:' 4-1/16"5MCIW . ï.iiiã.lHEAD = FMC ACTUATOR = OTIS KB. B.E'i = 64.53' 2800' 36.63' KOP= 3100' Max Angle = 41 @ 10567' Õãtllm MD = 10170" õãi"lImlVD= 8800' SS [13-3/8" CSG, 68#, NT-80, ID= 12.415" I- ~ 2685' I Minimum 10 = 3.725" @ 9900' 4-1/2" PARKERSWN NIPPLE TOPOFTIW 7" lNR H 9860' 4-1/2" TBG, 12.6#, NT 13CR.80, 0.0152 bpf, ID = 3.958" H 19-5/8" CSG, 47#, NT-80S,ID = 8.681" H 10099' r-- ÆRFORA TION SUMMARY REF LOG: BHCS ON 11/20/90 ANGLE AT TOP PERF: 39 @ 10104' Note: Refer to Production DB for historical perf data SIZE SPF INTERV Al Opn/Sqz DATE 2-1/2" 4 10104-10144 0 05/15/94 3-3/8" 6 10269-10335 0 02/08/92 3-3/8" 4 10345-10386 0 12/21/90 I PBTD H 10647' 1 ~rBG, 26#, NT13CR-80, 0.0383 bpf, 1D=6.276 -f 10688' I DATE 12t21190 03/09/01 03/12/01 09/07/01 10/26/02 COMMENTS ORIGINAL COMPLETION SIS-MH CONVERTEDTOCANVAS SIS-MD FINAL RNITP CORRECTIONS CO/KAK MAX ANGLE CORRECTION DATE REV BY 9913' S' 5-32 . L :8: I I ZI t-¡ ,~ I SAFElY NOTE: 13 CHROMELNRDO NOT ACiDIZE 2102' H4-1/2" OTIS SSSV NIP, ID = 3.813" I ~ GAS LIFT M\NDRB.S TYÆ VlV LATCH PORT 9-CR-1MO RK 9-CR-1MO RK 9-CR-1MO RK 9-CR-1MO RK 9-CR-1MO RK DATE ST MD 5 3101 4 5551 3 7718 2 9461 1 9797 lVD DEV 3033 9 5127 39 6832 36 8242 36 8509 38 9826' 9830' 9832' H4-1/2" PARKERSWS NIP, ID= 3.813" I H RIGHT HAND RB.EASE 1 H9-5/8" x 4-1/2" TIW A<R, ID = 3.99" I I - ---j 9880' -f4-1/2" PARKERSWS NIP,ID = 3.813" I I 9900' -f4-1/2"PARKERSWNNIP,ID=3.725" I ~ 9913' -f4-1/2" W/LEG I I 9902' H ElMD TT LOGGED 02/08/92 I h ~ REV BY COMMENTS ~ 10333' H3-3/8" BAKER BP, 1-3/4" EXT FN - 05/18/92 PRUDHOE BA Y UNIT WB.L: S-32 PERMIT No: 90-1490 API No: 50-029-22099-00 Sec.35, T12N, T12E BP Exploration (Alaska) r--- .--- . TI~E= '4-1/16" 5M McEVOY . Wa.LHEAD = FMC ACTU\ TOR = OTIS KB. l~lEV = ' 69' BE !:LEV = ji KoP= ------- u500-6' Max Ange = ._~.~.6 <$ 81,~.~: Datum MD = 9123' Datum lVD = 8BOO'SS [10-314" eSG, 45.5#, Nf-BO, ID =: 9.953" H 2958' Minimum D = 3.725" @ 8811' 4-1/2" PARKER SWN NIPPLE TOPOF5-1/2"Lt\R H 14-112" 1BG, 12.6#, NSCT13CR, 0.0152 bpf,ID= 3.958" H [I5/8" CSG, 29.7#, L-BO, 0.0459 bpf,lD = 6.875' H PERFORA 110N SUMM\ RY REF LOG: BHCS ON 10119192 ANGLEA TTOP PffiF: 25 @ 9044' Note: Refer 10 Production œ for historical perf data SIZE SPF INTERV AL Opn/Sqz 3-3/8" 4 9044-9084 0 3-3/8" 6 916.6-9252 0 ~ 15-1/Z'lt\R,17#, 13CR. FL4S, 0.0232 bpf, ID= 4.892" H ~ 8815' 9018' 07/03/93 01/06/92 9430' 9510' , 5-33 . --'= :g I--w 8824' h ~ I SAFElY OOTES: 1970' . ST MJ 5 2944 4 5052 3 6591 2 8141 1 8675 8705' .8: 8763' J...4 ~ ~ 8793' 8811' I 8824' 8826' '" ~ 9199' Do\TE RBI BY COMWENTS DATE REV BY COMIvENTS 11/06192 ORiGINt>.L COMA.E1l0N 03109101 SIS-M-i CONVERTED TO CANV AS 03112101 SIS-MJ FINt>.l õ9iõ7/01 RN/lP CORRECllONS T'TREECAP H4-1/Z' 0115 SSSV NP, ID = 3.813" 1 GAS LIFT M\NDRa.S lVD DEV TYÆ VLV LATCH PORT D<\TE 2871 3 KBM3 BK 4976 3 KBM3 BK 6494 19 KBM3 BK 7889 26 KBM3 BK 7393 25 KBM3 BK H4-1/Z' PARKERSWS NP, D =3.813" 1 H7-5/8" x 4-112" BKRPERM PKR. ID = 3.9Z' I H4-1/Z' PARKERSWS NP, D =3.813" I H4-1/ZPARKERSWNNP, ID=3.725" I H4-1/Z' W/LEG I H a.MDTTLOGGED12131/92 H JUNK 4-BLADES FROM SWS, FULLBORE SPNNffi PRUDHOE BAY UNIT WELl: S-33 PERMT fib: 92-1020 API fib: 50-029-22293-00 Sec. 35, T12N, T12E BP Exploration (Alaska) r----. 7 ~ . .t Tlõ1IiE=' >, W8.LHEAD = Acn..I<\ TOR :: Ki3. ElEv = B'F:' B.EV = K'õiJ= Max Ange = õãtùm MD = DatumlVD = 7"5MCIW 13-5/8" 5M CIW BAKER 69.07 35.74' 177Z 28@3517' 9619' 8800' SS 5-35 I SAFElY OOTES . - 2102' H 5-1/Z' OTIS HQR SSSV LAND NIP, ID = 4.562" I 1 13-3/8"CSG,68#,L-BO,ID=12.415'H 2986' ~ .. GAS LIFT M\NDRa.S ST MD lVD DEV TYÆ VLV LATCH PORT Do\TE L 4 2996 2924 26 MM3 RK 3 5685 5307 28 MM3 RK - 2 7868 7289 26 MM3 RK 1 9281 8555 24 MM3 RK 9229' H5-1/2" PARKERSWS NP, D =4.562" I ~ 9315' HTIN ANa;OR LATŒI, D =4.766" I ~ 9317' H9-5/8" x 5-112"1lW HBBP A<R. ID = 4.750" I -, 9348' H5-1/Z' PARKERSWS t-IP, D =4.562" I Minimum 10 = 4.455" @ 9365' 5-1/2" OTIS XN NIPPLE - ---1 9365' HS-1/2" 011S XN NIP, ID =4.455" J ITOPOF7" LNR H 9372' r-I I 15-1/2" lBG, 17#, L-80 NSCc, 0,0232 bpf, ID = 4.892" H 9377 r-, L 9377' ~5-1/Z' W/LEG, ID=4.875" 1 9386' a.MDTTLOGGED03/11/93 I 19-5/8" CSG,47#, L-80,ID= 8.681"H 9536' J-..4 ~ PERFORA 110N SLMM\RY REF LOG: BHCS ON 01/20193 ANGlEA TTOP PERF: 22 @ 9546' Note: Refer 10 Production œ for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9546-9586 0 06/30/93 3-3/8" 10 9680-9778 0 02/09/93 ~ ~ 9940' I 17" lNR, 26#, L-80, 0.0382 bpf, ID = 6.276" H 10020' I ~ - COMIvENTS DATE REV BY COMIvENTS Do\ TE RBI BY Õ1/24193 ORiGINt>.L COMR.ETlON Õ3I09/01 SIS-M-i CONVERTED TO CANV AS 0:3112/01 SIS-M) FINt>.L õ'9I07/01 RN/TP CORRECllONS PRUD/-oEBAY UNIT WELl: S-35 PERMT fib: 92-1480 API fib: 50-029-22324-00 Sec. 35, T12N, T12E BP Exploration (Alaska) ~ . ,~ ,- -, T~E=' . WB.LHEAD = ACi'u\ TOR = KB. B.EV = 'BE B.EV ;. ro'= Max Ange = DatumMD= DatumlVD = 6" 5M CIW 11" 5M FMC BAKER 70.00' 35.84' 5338' 51 @7118' 9855' 8800' SS [13-3I8"CSG, 68#, l-BO, D = 12.415' H 2930' Minimum 10 = 3.725" @ 9868' 4-1/2" OTIS XN NIPPLE rTOPOF7"LNR H 15-1/2" TBG, 17#, l-BO NSCC, 0.0232 bpf. ID = 4.892" H 9545' f-¡ 9558' t-----J 19-5/8" CSG, 47#, L-80, ID = 8.681" H 9721' PERFORATION SUM\o1ARY REF LOG: BHCS ON 11/20/92 ANGLE AT TOP PERF: 40 @ 9738' flbte: Refer to Production DB for historical perf data SIZE SA' INTERVAL OpnlSqz Do\ TE 3-318" 4 9738-9788 0 10/15193 3-318" 6 9918-9926 0 02,Q4193 3-318" 6 9934-10076 0 02,Q4193 ~ 10221' 1 E lBG, 26#, L-80 NSCc. 0.0383 bpf, ID = 6.276" H 10300' 1 IY>. TE RBI BY COMIvENTS DATE REVBY 11/23192 ORiGINt>.L COMA...E1l0N 03/09101 SIS-M-I CONVERTED TO CANV AS 03/12/01 SIS-M) FINt>.L 09/07/01 RN/TP CORREC110NS ß ~ 5-36 I SAFElY OOTES 2011' . - A ~ ST M) 5 3029 4 5313 3 7677 2 9371 1 9443 L - 9463' H5-1/2" OTS SSSV LAND NIP, ID = 4.562" 1 GA S LIFT MANffia.S lVD ŒV TYPE VlV lATOi R)Rf DATE 2954 1 M\o1G RK 5233 8 M\o1G RK 7140 42 M\o1G RK 8431 42 M\o1G RK 8485 42 M\o1G RK H5-1/2" PA~ER SWS NIp, ID= 4.562" I &-I 9487' H9 5I8"x 5-lIZ' SABl-3 ÆRfI.1 A<R, ID =4.750" I 9525' H5-1/2"PA~ERSWSNIP, ID=4.562" 1 "( 9545' H5-1/2" OTS XN NP, D =4.455" I 9558' H5-1/2" W/lEG 1 9568' H ELMD TT lOGGED 02/04/931 :g r- .. 0 :;g ~--I 9845' I 9859' L 9868' I I 9870' 1 9870' . COMIvENTS H4-1/2"BAKERPERMFB-1 PKR, I liD = 4.00" Mill OUT TO 4.50" H4-1/2" OTS X NIp, ID = 3.813" H4-1/2" OTS XN NP, D = 3.725" 1 H4-1/2" W/LEG I H B.MD TT LOGGED 11/27/941 PRUDI-OEBAY UNIT WELL: S-36 PERMTfIb: 92-1160 API fib: 50-029-22301-00 Sec. 35, T12N, T12E BP Exploration (Alaska) ~ . 9 r"". . "AT~E=' 4-1/16"5MCIW .. Wã:'LHEAD = 11" 5M FMC ACTIJA. TOR = OTIS "Ki3:iã:EV = 65' B'F:ËiêJ = 3Z KOP;; " 5654' ~An~e = 34 @ 7177' Datum MD = 9366' Datum lVD = 8800' SS 5-37 . - 0::0-3/4" CSG, 45.5#, NT80, D = 9.953" H .. 2923' ---1 Minimum 10 = 3.725" @ 8890' 4-1/2" PARKER SWN NPPLE :::g:: \4-1IZ' TOO, 12.6#, NSCT 13CR. ~ 8902' 0.0152 bpf, D = 3.958" LTOP OF 5-1/Z' LNR H 8894' --- I I 7-518" CSG, 29.7# NT-95HS, ID = 6.875" H 9108' ¡-- PERFORATION SUM\o1ARY REF LOG: SWS SONC ON 11/03192 ANGLE AT TOP ÆRF: 31 @ 9255' Note: Refer to A'oduction DB for historical perf data SIZE SFF INlERVAL Opn/Sqz Do\TE 3-318" 4 9255-9360 0 02/10/93 3-318" 6 9255-9285 0 04/19/93 3-318" 4 9418-9426 0 02/1 0/93 ~ 9692' 15-1/2"TBG, 17#, 13CR FL4S, 0.0232 bpf,lD =4.892" H 9770' Do\ TE RBI BY COMrÆNTS DATE REV BY 11/06192 ORiGINt>.L COMR..E1l0N 03109101 SIS-M1 CONVERTED TO CANV AS 03112101 SIS-M) FINt>.L 0910'7/01 RNIlP CORREC110NS COMIvENTS :&. 0 ï /--.,' I SAFElY OOTES: 13 CR CHROIvE lBG AND LNR . ST M) 6 3018 5 5104 4 6712 3 7885 2 8333 1 8438 110. 2228' H4-1/Z' 011S SSSV NP,ID = 3.813" I GAS UFT MANDRElS lVD DEV TYPE VLV LATŒI PORf DATE 2940 0 CAMCO BK 5026 2 CAMOO BK 6555 29 CAMCO BK 7543 33 CAMCO BK 7917 33 CAMCO BK 8005 33 CAMCO BK 8777' H4-1/Z' PARKERSWS NP, D =3.813" I 8837' H7-5/8" BAKERÆRMSABL-3PKR I 8870' H4-1/Z'PARKERSWSNlP,D=3.813" I H4-1/Z PARKER SWN NP, ID= 3.725" I 8890' 8902' 8898' H4-1/Z' W/LEG H a.MD TT LOGGED 02/08/93 I 9400' H TOP OF CElvENT/SANOOACK I PRUDHOE BAY UNIT WELL: S-37 PERMT fib: 92-0990 API fib: 50-029-22291-00 Sec. 35, T12N, T12E BP Exploration (Alaska) /---. .r--- - ~ ~ 'TREE-' J . "WEL.l~EAD = ACTUATOR = KB. a.EV = BF. I3...EV = KOP= ~ Angle = Datum MD = Datum lVD = 6" 5M CrN 11" 5MFMC BAKER 69.99' 36.8' 4441' 28 @ 6155' 9259' 8800' S8 If) À. 5-38 I SAFElY NOTES 0 ~ 113-3/8" CSG, 68#,l-80, ID= 12.415" - r--4 2893' I Minimum 10 = 3.725" @ 9330' 4-1/2" XN NIPPLE :8: æl/2"lBG, 17#, L-80, 0.0232 bpf, ID = 4.892" H 9084' I TOPOF7"LNRH 9092' 1 I 19-5/8" CSG, 47#, L-80, ID = 8.681" H 9221' ¡--- PERFORATION SUMMARY REF LOG: BHCS ON 12/10/92 ANGLE AT TOP PERF: 26 @ 9241' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9241-9291 0 12/29/92 3-3/8" 4 9364-9422 0 12/29/92 3-3/8" 4 9434-9474 0 12/29/92 3-3/8" 4 9474-9483 0 12/29/92 I PBTD H 9570' 17" TBG, 26#, L-80 NSCC, 0.0383 bpf, ID = 6.276" H 9649' 2098' H5-1I2" OTIS SSSV LAND NIP, ID = 4.562" I . L ~ ST MD 4 3032 3 5354 2 7638 1 8931 GAS lIFT MANDRB.S lVD DEV 1YÆ VLV lATCH PORT DATE 2961 0 CAMCO RK 5247 21 CAMCO RK 7330 24 CAMCO RK 8504 26 CAMCO RK 8961' -5-1/2" PARKERSWS NIP,ID=4.562" I ~ 9024' -9-5/8" x 5-1/2" BKR HYDROSET A<R, ID = 4.75" I :8: 9047' 1-15-1/2" PARKER SWS NIP, ID = 4.562" I 9071' H5-1/2" PARKER SWN NIP, ID = 4.455" I 9084' -5-1/2" W/LEG. ID = 4.562" I 9091' HELMDTTLOGGED07/19/97 I I ... ~ :8:~ 9312' H7" x 4" BAKER FB-1 A<R. ID = 4.00" 1 I 9326' H4-1/2" X NIP,ID= 3.813"1 I 9330' H4-1/2" XN NP, ID = 3.725" I \- H4-1/2" W/LEG I H B.MD TT LOGGED 06/21/94 I 9333' 9332' DATE REVBY COMMENTS DATE REV BY COMMENTS 12/:29/92 ORIGINAL COMPLE1l0N 03109/01 SIS-MH CONVERTED TO CANVAS 03/'12/01 SIS-MD FINAL 09107/01 RNITP CORRECTIONS 01102/02 DAV/KK D8...ETE CHOKElXN LOCK PRUDHOE BA Y UNIT WELL: S-38 PERMIT No: 92-1270 API No: 50-029-22310-00 Sec. 35, T12N, T12E BP Exploration (Alaska) /--, II A r-- ~ -l,'TÆE= ^ Wa.LHEAD = ACTU\ TOR = KB. ELEV = BF:E:LEV = - KõP= Max Ange = DatumMD= Datum lVD = 4"CIW FMC BAKER 71.79' 37.1' 3787' 87 ~ 10139' 9549' 8800' SS 5-42 SAFETY NOTES: SSSVN ST. #6,#5,& #4 COULD BE DE~ERBY APPROX. 80'. CHROMETBGAND LNR, 70° @ 9536' . - 2170' H4-1/2" HES HXO SSSVN, 10= 3.813" 19-5/8" CGS, 4O#lFT, l-BO, BUTTRESS H 3077' r-J 7"lBGi, 29#/FT BB.OW, 26#1FT ABOVE, ~D BlITT H 8407' ~ ~ GAS LIFT M\Nffia.S ST MJ lVD DEV TYPE VlV LATa-t PORf DATE 6 3476 3474 6 KBG-2-LS DOME BTM 16/64 08/20/02 5 5635 5254 44 KBG-2-LS DOME BTM 16/64 07/19/98 L 4 6770 6253 9 KBG-2-LS DMY BTM 0 04/29/96 3 7513 6994 1 KBG-2-LS DOME BTM 16/64 07/19/98 , 2 8264 7745 1 KBG-2-LS S/O BTM 24/64 04/29/96 1 9014 8492 19 KBG-2-LS DMY BTM 0 07/19/98 MinimumID=3.725"@9137' I 4-1/2" HES XN NIPPLE 9081' H4-1/2"HESX-NIP, ID= 3.813" 1 ~ z-t 9092' H7" X 4-1/Z' BKR S-3 PKR. ID= 3.ß75" I 9115' H4-1/2"HESXNIP, ID= 3.813" I H4-1/2" HES XN NP, ID = 3,725" I 913T 14-1/2" TOO, 12.6#/FT, Œ, NSCT, ~ 9149' ------¡ 0,0152 bpf. D =3.958" l. :8: 17" Sf-OE, 29#1FT, ~D BUTT H 9375' ¡-- 9149' 9152' H4-1/2" WlEG I H B.MJ TT LOGGED 08111/96 I H7" X 4-1/Z' TlWl1EBACKSLV,lD =5.277" I H7" X 4-1IZ' TIWWT SETPKRW/ HYDRO H3R I PERFORATION SUMM\RY REF lOG: ANGLEA TTOP ÆRF: 46 @ 9378' flbte: Refer to A'oductbn œ for historical perf data ~;IZE SA" INTERVAL OpnlSqz Do\TE 2.314'" 4 9378 - 9410 0 04127/96 2.3/4" 4 9490 - 9528 0 04127/96 2.3/4" 4 9690 - 9752 0 04127/96 2..3/4" 4 9770 - 9790 0 04127/96 2..314'" 4 9850 - 10086 0 04127/96 2..3/4" 4 10110-10290 0 04127/96 2..3/4" 4 10415 - 10530 0 04127/96 9218' 9224' H4-112" CTCPAYZONEPKR I 4-1/2"lt\R. 12.6#, Œ-NCST, .0152 bpf, ID=3.958" H 10692' I RBI BY DATE REV BY COM~NTS PRUDf-OEBAY UNIT WELl: S-42 PERMT fib: 1960540 API f\b: 50-029-22662-00 SEC 35, T12N, T12E Do\TE 04129/96 0311 :3,Q1 03l14,Q1 "õ1iõ4,Q2 0410'1,Q2 08l31,Q2 COM\o18'JTS ORiG f-ORIZ COfvPLEfION S6-CS CONVERTEDTOCAtWAS S6-MJ FINt>.L RNIlP CORREC110NS DAV/KK GLV CORRECTIONS DlRIlP MIN ID CORRECTONIGL V C/O BP Exploration (Alaska) ",;, /-""'" "'\ 1- . - ." me=.. ë' .\ -l WB.LHEAD= ACTUATOR = "Kß':Ei. BI = BF. B..BI = KOP= MiXÅngle = ~M)= Q¡tum lVO= 4-1/16" aN FtvC BA KER 68.1' 37.2' 1BOO' 98 @ 12BO9' I 9762' 8BOO'SS 9-518" ES CMf'R H 9-5/8" CSG, 40#, L-BO, ID = 8.835" H Minimum 10 = 3.725" @ 9799' 4-1/2" HES XN NIPPLE Q-1/Z' lBG,12.6#, l-BO, .0152 bpf, ID = 3.958" H I RA APTAG H I T'X4-112"BKRMLPKR,ID=3.875" H I 4-112" HES X NP,ID = 3.813" H I 4-112" HES XN NIp, ID = 3.725' H I 4-112" Wl83, D =3.958" H I RA APTAG H I TOPOFTIWTIEBACKSLV,ID= 5.374" H I 7" X 4-1/Z' 1lW S-6 PKR. ID = 3.868" H I 7"X4-1/2"TIWDTH-SHGR,ID=3.925' H [ 7" CSG, 26#, L-80, .0383 bpf, ID = 6.276" H PERFORATION SUM\o1ARY REF lOG: PDS JßVa.RY lOG OF 09/15/99 ANGLE AT TOP PERF: 68 @ 9807' Note: Refer to Production DB for historcal perf data SIZE SPF INTER\! AL Opn/Sqz Do\ TE SEE PAGE 2 FOR PERF BREAKDOWN r ' ....£A TE" REV BY COM\o18'JTS 06/:221f(J7 ORiGNAl COMR.E1lON õ3714101 S6-OAA CONVERTED TO CANVAS õ3716101 SIS-CS FINt>.L õ3i:Z6I02 ætKAK CORREC110NS õf:im02 ATDA<K AŒ'ERFS 2197' 3121' 9088' 9578' 9774' 9792' 9799' 9808' 9824' 10059' 10065' 10070' 10196' DATE /2- ~ 5-43 L 1 SAFETY NOTES: WELL ANGLE> 70 DEG@ 9820' & > 90 DEG@ 9875'. -= r- --II I~ I 1 I r--- tA ¡.-- . H4-1/2" H6S HXOSSSVN, ID= 3.813" I 2209' L ~ ST M) 7 3028 6 5308 5 6508 4 7205 3 8063 2 8507 1 8952 GAS LIFT MANDRElS lVD DEV TYPE VlV LTOi FORf 2909 19 KBG-2LS DOIvE BTM 16 5076 19 KBG-2LS DOIvE BTM 16 6211 17 KBG-2lS DV BTM 0 6873 19 KBG-2LS DOIvE BTM 16 7688 21 KBG-2lS DV BTM 0 8105 25 KBG-2lS DV BTM 0 8450 54 KBG-2lS S/O 8TM 24 DATE 04/02/01 04/02/01 04/02/01 04/02/01 04/02/01 04/02/01 04/02/01 z 9021' 9032' H4-1/2"HESXNIP, ID=3.813" I U7" x 4-1IZ' BKRS-3 PKR. ID= 3.875" I H4-1/2" H6S X NIP, ID= 3.813" I H4-1/2"H6S X NIp, ID=3.813" I !-14-1/2"WLEG, ID= 3.958" I I I B.MD TT LOGGED 09/15/99 I ~ / 9055' 9077' 9089' 9086' " I 7" CSG MlLOUT WINOOW / 9749' - 9761' (5-43 L 1) ~ I 9784' HBKRSETTINGSLV,ID=S.2S0" I --- I 9807' HTOPOF 4-1/2" Sl 1"D LNR -'-- -'-, ~ -, --'- - ¡T'--- ---- --- -'- - --- -'-, --, \ .S-43l1ISANOHSlTDLNR --, ) I BTM OF 4-1/2" Sl T'D LNR H 13912' I I 4-1/Z'SLTD LNR.12.6#,L-BO,.0152bpf, ID = 3.958" H 13945' I W/O lNR TOPPKR OR HGR. WEll OOTWlACCESSIBLE ~ 12884' HCTCEXTCSGA<R.ID=3.885" I ~ 12913' HTOPOF4-1/Z'SlrDlt\R I " " 6S Qv11"R H 12872' I" ", " , , , '" 'f' " L B1M OF 4-112" Sl TD LNR H 13805' ~ 4-112" Sl TD It\R, 12.6#, l-BO, .0152 bpf, ID = 3.958" H 13807' RBI BY COM'v1mTS PRUDHOE BAY UNIT WB.L: S-43 L 1 PERMIT" I\b: 1970530 API fib: 50-029-22754-60 Sec. 35, T12N, T12E BP Exploration (Alaska)