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Home My WebLink AboutAIO 024 BAREA INJECTION ORDER NO. 24B Prudhoe Bay Unit Borealis Field Borealis Oil Pool 1. December 20, 2007 Notice of Hearing, Affidavit of Publication and mailings 2. April 9, 2008 BPXA’s request for Continued Water Injection Operations (AIO No. 24B.001) 3. July 15, 2008 BPXA’s request to cancel AIO No. 24B.001 4. September 9, 2008 BPXA’s request for Continued Water Injection Operations (AIO No. 24B.002) 5. April 30, 2012 BPXA’s request for standardization of authorized fluids for EOR and pressure maintenance (AIO No. 24B.003 and AIO No. 24B.003 Amended) 6. June 8, 2013 BPXA’s request to cancel AIO No. 24B.002 7. -------------------- Emails: Under Evaluation – Injector L-111 (PTD #2020300) Ready for Miscible Gas Injection and Not Operable – 60 Day Monitoring Period Complete 8. May 14, 2013 BPXA’s request for Administrative Approval to introduce radioactive tracer into the Gathering Center 2 (GC2) production facility for the purpose of oil production, plant operations, and plant/piping integrity (AIO 24B.004) 9. -------------------- Emails 10. June 6, 2013 Letter from BPXA to AOGCC regarding clarification regarding the RCRA status of the radioactive tracers to be used in the upcoming study at GC2 11. February 9, 2016 BPXA request to amend AIO 24.004 for continued gas injection into PBU L-105. (AIO 24B-005) Corrected 3/8/16 12. January 10, 2017 BPXA request to amend administrative approval AIO24B-005. Corrected on 1/25/17 13. February 22, 2019 BPXA request for Admin Approval for WAG Injection Operations 14. March 9, 2020 BPXA request to amend defined inner annulus normal operating limits on injectors operating under administrative approval 15. October 2, 2020 AOGCC approval of March 9, 2020 request 16. May 27, 2021 Hilcorp requests Admin Approval to continue WAG Injection Operations (PTD 219-155) (AIO 24B.007) 17. June 9, 2021 Emails about Mechanical Integrity Tests 18. August 31, 2022 BPXA’s Request for amendment to continue WAG injection operations (AIO 24B.005) ORDERS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue, Suite 100 Anchorage Alaska 99501 Re: AMENDMENT of the order ) Area Injection Order 24B allowing underground injection of ) Prudhoe Bay Field, Borealis Oil Pool fluids for enhanced oil recovery in ) Borealis Oil Pool, Prudhoe Bay ) January 30, 2008 Field, North Slope, Alaska IT APPEARING THAT: 1. On its own motion the Commission proposed to amend the rules addressing mechanical integrity in all existing orders authorizing underground injection. The Commission published notice of opportunity for public hearing on the proposal in the Anchorage Daily News on October 3, 2004 to consider amendment of underground injection orders to incorporate consistent language addressing the mechanical integrity of injection wells. A hearing was tentatively scheduled for November 4, 2004. 2. By e-mail dated October 15, 2004, BPXA suggested edits to the Commission's proposed language addressing the mechanical integrity of injection wells. 3. No protests to the Commission's proposal or requests for hearing were received, and the scheduled hearing was vacated. 4. All orders authorizing injection in Prudhoe Bay Unit oil pools, with the exception of Area Injection Orders 22C (Aurora Oil Pool) and 24A (Borealis Oil Pool) include specific instructions for well integrity failures. 5. Area Injection Order 24A rules governing well mechanical integrity are inconsistent with other orders issued for underground injection operations in the State of Alaska. 6. The Commission published notice of opportunity for public hearing on the proposed amendments to Area Injection Order 24A in the Anchorage Daily News on December 20, 2007. A hearing was tentatively scheduled for January 31, 2008. 7. No protests to the Commission's proposal or requests for hearing were received, and the scheduled hearing was vacated. CONCLUSIONS: 1. The exclusion of a rule addressing well integrity failure appears to have been an oversight by the Commission in the writing of Area Injection Order No. 24A. Area Injection Order 2400 January 30, 2008 0 Page 2 2. Requirements for the demonstration of mechanical integrity are unclear as written in Area Injection Order 24A, specifically regarding the testing frequency. 3. It is appropriate both to amend Area Injection Order No. 24A to include requirements governing an injection well integrity failure, and to clarify the mechanical integrity demonstration requirements to be consistent with other injection orders issued by the Commission. NOW, THEREFORE, IT IS ORDERED: In addition to statewide requirements under 20 AAC 25 (to the extent not superseded by these rules), the following rules govern Class II injection operations in the affected area described below and supersede and replace the rules adopted in Area Injection Order No. 24A dated April 22, 2005: Umiat Meridian T12N-R10E: ADL 25637 Sec 13, 24 T12N-RI IE: ADL 47447 Sec 16 (SW/4 and W/2 NW/4 and W/2 SE/4), 21, 22 SW/4 and W/2 NW/4 and S/2 SE/4 ADL 47446 Sec 17, 18, 19, 20 ADL 28238 Sec 26 S/2 and W/2 NW/4 and SE/4 NW/4, 35, 36 ADL 28239 Sec 27, 28, 33, 34 ADL 47449 Sec 29, 30, 32 T11N-R1IE: ADL 28240 Sec 1, 2, 11, 12 ADL 28241 Sec 3, 4, 9, 10 ADL 28245 Sec 13, 14, 24 ADL 28244 Sec 15 ADL 28246 Sec 25 T11N-R12E: ADL 28261 Sec 9 W/2 ADL 47450 Sec 5 S/2, 6 S/2 and NW/4 and W/2 NE/4, 7, 8 ADL 28263 Sec 16 W/2,21 W/2 ADL 28262 Sec 17, 18, 19, 20 ADL 47452 Sec 28 W/2,33 W/2 ADL 47453 Sec 29, 30, 31, 32 T12N-R12E: ADL 28259 Sec 31 W/2 and W/2 SE/4 Area Injection Order 2400 • Page 3 January 30, 2008 Rule 1 Authorized Iniection Strata for Enhanced Recovery Injection of authorized fluids for purposes of pressure maintenance and enhanced recovery is permitted into strata that are common to, and correlate with, the interval between 6534' and 6952' MD in the West Kuparuk State #1 well in the Prudhoe Bay Field. Rule 2 Authorized Injection Fluids Fluids authorized for injection within the affected area are: a. produced water from Borealis Oil Pool or Prudhoe Bay Unit production facilities for the purposes of pressure maintenance and enhanced recovery; b, non -hazardous water collected from Borealis well house cellars and standing ponds; c. tracer survey fluid to monitor reservoir performance; d. source water from a seawater treatment plant; enriched hydrocarbon gas from the Prudhoe Bay Unit processing facilities, with the condition that the average Borealis Oil Pool reservoir pressure must be maintained above the minimum miscibility of the injectant; and f. source water from the Prince Creek Formation. Rule 3 Fluid Iniection Wells The underground injection of fluids must be through a well that has been permitted for drilling as a service well for injection in conformance with 20 AAC 25.005, or through a well approved for conversion to a service well for injection in conformance with 20 AAC 25.280 and 20 AAC 25.412. The application to drill or convert a well for injection must be accompanied by sufficient information to verify the mechanical condition of wells within one-quarter mile radius. The information must include cementing records, cement quality log or formation integrity test records. Rule 4 Monitoring the Tubing -Casing Annulus Pressure Variations The tubing by casing annulus pressure and injection rate of each injection well must be checked at least weekly to confirm continued mechanical integrity. Rule 5 Demonstration of Tubing -Casing Annulus Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before injection begins, and before returning a well to service following a workover affecting mechanical integrity. A Commission -witnessed mechanical integrity test must be performed after injection is commenced for the first time in a well, to be scheduled when injection conditions (temperature, pressure, rate, etc.) have stabilized. Subsequent tests must be performed at least once every four years thereafter (except at least once every two years Area Injection Order 2400 January 30, 2008 0 Page 4 in the case of a slurry injection well). The Commission must be notified at least 24 hours in advance to enable a representative to witness mechanical integrity tests. Unless an alternate means is approved by the Commission, mechanical integrity must be demonstrated by a tubing by casing annulus pressure test using a surface pressure of 1500 psi or 0.25 psi/ft multiplied by the vertical depth of the packer, whichever is greater, that shows stabilizing pressure and does not change more than 10 percent during a 30 -minute period. Results of mechanical integrity tests must be readily available for Commission inspection. Rule 6 Well Integrity Failure Whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, log, or other evidence, the Operator shall notify the Commission by the next business day and submit a plan of corrective action on a Form 10-403 for Commission approval. The Operator shall immediately shut in the well if continued operation would be unsafe or would threaten contamination of freshwater, or if so directed by the Commission. A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating well integrity failure or lack of injection zone isolation. Rule 7 Notification of Improper Class II Iniection Injection of fluids other than those listed in Rule 2 without prior authorization is considered improper Class II injection. Upon discovery of such an event, the operator must immediately notify the Commission, provide details of the operation, and propose actions to prevent recurrence. Additionally, notification requirements of any other State or Federal agency remain the operator's responsibility. Rule 8 Other conditions a. It is a condition of this authorization that the operator complies with all applicable Commission regulations. b. The Commission may immediately suspend, revoke, or modify this authorization if injected fluids fail to be confined within the designated injection strata. Area Injection Order 240 Page 5 January 30, 2008 Rule 9 Administrative Action Unless notice and public hearing is otherwise required, the Commission may administratively waive the requirements of any rule stated above or administratively amend any rule as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in an increased risk of fluid movement into freshwater. DONE at Anchorage, Alaska, and c Cathy P. oerster, Commissioner 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 reconsideration. A request for reconsideration must be received by 4:30 PM on the 23rd day following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the 10 -day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon reconsideration, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for reconsideration 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 reconsideration was filed). 0 0 Page 1 of 1 Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Thursday, January 31, 2008 9:08 AM Subject: C0532B (West Foreland #2), AIO 32 (Redoubt Unit),A1024B (Prudhoe Bay -Borealis), A1022D (Prudhoe Bay - Aurora) Attachments: aio32.pdf; co532b.pdf; aio22d.pdf; aio24b.pdf BCC:Cynthia B Mciver (bren.mciver@alaska.gov); 'Alan Birnbaum <""Alan J Birnbaum "> (alan. bimbaum@alaska. gov)'; 'Aleutians East Borough'; 'Anna Raff; Arion, Teri A (DNR); 'Arthur C Saltmarsh'; 'Arthur Copoulos'; 'Barbara F Fullmer'; 'bbritch'; 'Bill Walker'; 'Brad McKim'; 'Brandon Gagnon'; 'Brian Gillespie'; 'Brian Havelock'; 'Brit Lively'; 'Bruce Webb'; 'buonoje'; 'Cammy Taylor'; 'Cande.Brandow'; 'carol smyth'; 'Cary Carrigan'; 'Catherine P Foerster'; caunderwood@marathonoil.com; 'Charles O'Donnell'; 'Chris Gay'; 'Christian Gou- Leonhardt'; 'Cliff Posey'; 'Dan Bross'; 'daps'; 'Daryl J. Kleppin'; 'David Brown'; 'David L Boelens'; 'David Steingreaber'; 'ddonkel'; 'Deanna Gamble'; 'Deborah J. Jones'; 'doug_schultze'; 'Evan Harness'; 'eyancy'; 'f6ms2@mtaonline.net'; 'Francis S. Sommer'; 'Fred Steece'; 'Garland Robinson'; 'Gary Laughlin'; 'Gary Rogers'; 'Gary Schultz'; 'ghammons'; 'Gordon Pospisil'; 'Gregg Nady'; 'gregory micallef; 'gspfoff; 'Hank Alford'; 'Harry Engel'; Jah'; 'James B Regg'; 'James M. Ruud'; 'James Scherr'; 'Janet D. Platt'; Jdarlington'; Jejones'; 'Jerry McCutcheon'; 'Jim White'; 'Jim Winegamer'; 'Joe Nicks'; 'John Garing'; 'John S. Haworth'; 'John Spain'; 'John Tower'; 'John W Katz'; johnny.aiken@north-slope.org;'Jon Goltz'; 'Julie Houle'; 'Kari Moriarty'; 'Kaynell Zeman'; 'Keith Wiles'; knelson@petroleumnews.com; 'Kristin Dirks'; 'Laura Silliphant'; 'Lois'; 'Lynnda Kahn'; 'mail=akpratts@acsalaska.net'; 'mail=crockett@aoga.org'; 'mail=foms@mtaonline.net'; 'Mark Dalton'; 'Mark Hanley'; 'Mark Kovac'; 'Mark P. Worcester'; 'Marguerite kremer'; 'marty'; 'Matt Rader'; 'mckay'; 'Meghan Powell'; 'Mike Bill'; 'Mike Mason'; 'Mikel Schultz'; 'Mindy Lewis'; 'MJ Loveland'; 'mjnelson'; 'mkm7200'; 'Nick W. Glover'; NSK Problem Well Supv; NSU, ADW Well Integrity Engineer; 'Patty Alfaro'; 'Paul Decker'; 'Paul Winslow'; Pierce, Sandra M (DNR); 'Randall Kanady'; 'Randy L. Skillern'; 'rcrotty'; Rice, Cody J (DNR); 'rmclean'; rob.g.dragnich@exxonmobil.com; 'Robert Campbell'; 'Robert Province'; 'Roger Belman'; 'Rudy Brueggeman'; 'Scott Cranswick'; 'Shannon Donnelly'; 'Sharmaine Copeland'; 'Sondra Stewman'; 'Sonja Frankllin'; 'stanekj'; 'Stephen F Davies'; 'Steve Lambert'; 'Steve Moothart'; 'Steven R. Rossberg'; 'tablerk'; 'Tamera Sheffield'; 'Temple Davidson'; 'Terrie Hubble'; 'Thomas E Maunder'; 'Tim Lawlor'; 'Todd Durkee'; 'trmjrl'; 'Walter Featherly'; 'Walter Quay'; 'Wayne Rancier' Attachments: aio32.pdf;co532b.pdf;aio22d.pdf;aio24b.pdf, Jody Colombie Special Assistant Alaska Oil & Gas Conservation Commission Direct: 907-793-1221 Fax: 907-276-7542 *Note new email address 1/31/2008 Kenai National Wildlife Refuge Penny Vadla Richard Wagner Refuge Manager 399 West Riverview Avenue PO Box 60868 PO Box 2139 Soldotna, AK 99669-7714 Fairbanks, AK 99706 Soldotna, AK 99669-2139 Cliff Burglin Bernie Karl North Slope Borough PO Box 70131 K&K Recycling Inc. PO Box 69 Fairbanks, AK 99707 PO Box 58055 Barrow, AK 99723 Fairbanks, AK 99711 Williams Thomas Arctic Slope Regional Corporation Land Department Box 129 Ba Barrow, AK 99723 9 0 Mary Jones David McCaleb Cindi Walker XTO Energy, Inc. IHS Energy Group Tesoro Refining and Marketing Co. Cartography GEPS Supply & Distribution 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 300 Concord Plaza Drive Ft. Worth, TX 76102-6298 Houston, TX 77056 San Antonio, TX 78216 George Vaught, Jr. Jerry Hodgden Richard Neahring PO Box 13557 Hodgden Oil Company NRG Associates Denver, CO 80201-3557 408 18th Street President Golden, CO 80401-2433 PO Box 1655 Colorado Springs, CO 80901 John Levorsen Michael Parks Mark Wedman 200 North 3rd Street, #1202 Marple's Business Newsletter Halliburton Boise, ID 83702 117 West Mercer St, Ste 200 6900 Arctic Blvd. Seattle, WA 98119-3960 Anchorage, AK 99502 Baker Oil Tools Schlumberger Ciri 4730 Business Park Blvd., #44 Drilling and Measurements Land Department Anchorage, AK 99503 2525 Gambell Street #400 PO Box 93330 Anchorage, AK 99503 Anchorage, AK 99503 Ivan Gillian Jill Schneider Gordon Severson 9649 Musket Bell Cr.#5 US Geological Survey 3201 Westmar Cr. Anchorage, AK 99507 4200 University Dr. Anchorage, AK 99508-4336 Anchorage, AK 99508 Jack Hakkila Darwin Waldsmith James Gibbs PO Box 190083 PO Box 39309 PO Box 1597 Anchorage, AK 99519 Ninilchick, AK 99639 Soldotna, AK 99669 Kenai National Wildlife Refuge Penny Vadla Richard Wagner Refuge Manager 399 West Riverview Avenue PO Box 60868 PO Box 2139 Soldotna, AK 99669-7714 Fairbanks, AK 99706 Soldotna, AK 99669-2139 Cliff Burglin Bernie Karl North Slope Borough PO Box 70131 K&K Recycling Inc. PO Box 69 Fairbanks, AK 99707 PO Box 58055 Barrow, AK 99723 Fairbanks, AK 99711 Williams Thomas Arctic Slope Regional Corporation Land Department Box 129 Ba Barrow, AK 99723 :7 • z Q E 0F A11ASKA / SARAH PoLI.GOVERNOR Ai4 SKA OIL A" GAS 333 W 7th AVENUE, SUITE 100 CONSERVATION COMUSSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL 2413.001 Mr. Steve Rossberg Wells Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 RE: PBU V-112 (PTD 2060200) Request for Administrative Approval Borealis Oil Pool Dear Mr. Rossberg: Pursuant to Rule 9 of Area Injection Order ("AIO") 2413.000, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants BP Exploration (Alaska) Inc. ("BPXA")'s request for administrative approval to continue water injection in the subject well. AOGCC finds that BPXA has elected to perform no corrective action at this time on Prudhoe Bay Unit ("PBU") V-112. The Commission further finds that the well demon- strates inner annulus ("IA") repressurization while on miscible gas injection that can be safely managed with periodic pressure bleeds. Outer annulus pressures do not indicate anomalous conditions or loss of pressure integrity. The Commission believes that the well's condition does not compromise overall well integrity so as to threaten the envi- ronment or human safety, if the well's operation is subject to the constraints enumerated below. AOGCC's administrative approval to continue water injection only in PBU V-112 is con- ditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injec- tion rates, and shall flag the well's periodic pressure bleeds on the report; 3. BPXA shall perform an MIT - IA every 2 years to the maximum anticipated in- jection pressure; AI024B-001 • April 21, 2008 Page 2 of 2 4. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 7. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 8. The MIT anniversary date is March 16, 2008. a and dated April 21, 2008. Cathy P Foerster Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of re- consideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Com- mission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by in- action, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on re- consideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on re- consideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the pe- riod; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Kenai National Wildlife Refuge Penny Vadla Richard Wagner Refuge Manager 399 West Riverview Avenue PO Box 60868 PO Box 2139 Soldotna, AK 99669-7714 Fairbanks, AK 99706 Soldotna, AK 99669-2139 Cliff Burglin Bernie Karl North Slope Borough PO Box 70131 K&K Recycling Inc. PO Box 69 Fairbanks, AK 99707 PO Box 58055 Barrow, AK 99723 Fairbanks, AK 99711 Williams Thomas Arctic Slope Regional Corporation Land Department Box Ba fC , � �C51� Barrow, AKK 99723 //'/�/ Mary Jones David McCaleb Cindi Walker XTO Energy, Inc. IHS Energy Group Tesoro Refining and Marketing Co. Cartography GEPS Supply & Distribution 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 300 Concord Plaza Drive Ft. Worth, TX 76102-6298 Houston, TX 77056 San Antonio, TX 78216 George Vaught, Jr. Jerry Hodgden Richard Neahring PO Box 13557 Hodgden Oil Company NRG Associates Denver, CO 80201-3557 408 18th Street President Golden, CO 80401-2433 PO Box 1655 Colorado Springs, CO 80901 John Levorsen Michael Parks Mark Wedman 200 North 3rd Street, #1202 Marple's Business Newsletter Halliburton Boise, ID 83702 117 West Mercer St, Ste 200 6900 Arctic Blvd. Seattle, WA 98119-3960 Anchorage, AK 99502 Baker Oil Tools Schlumberger Ciri 4730 Business Park Blvd., #44 Drilling and Measurements Land Department Anchorage, AK 99503 2525 Gambell Street #400 PO Box 93330 Anchorage, AK 99503 Anchorage, AK 99503 Ivan Gillian Jill Schneider Gordon Severson 9649 Musket Bell Cr.#5 US Geological Survey 3201 Westmar Cr. Anchorage, AK 99507 4200 University Dr. Anchorage, AK 99508-4336 Anchorage, AK 99508 Jack Hakkila Darwin Waldsmith James Gibbs PO Box 190083 PO Box 39309 PO Box 1597 Anchorage, AK 99519 Ninilchick, AK 99639 Soldotna, AK 99669 Kenai National Wildlife Refuge Penny Vadla Richard Wagner Refuge Manager 399 West Riverview Avenue PO Box 60868 PO Box 2139 Soldotna, AK 99669-7714 Fairbanks, AK 99706 Soldotna, AK 99669-2139 Cliff Burglin Bernie Karl North Slope Borough PO Box 70131 K&K Recycling Inc. PO Box 69 Fairbanks, AK 99707 PO Box 58055 Barrow, AK 99723 Fairbanks, AK 99711 Williams Thomas Arctic Slope Regional Corporation Land Department Box Ba fC , � �C51� Barrow, AKK 99723 //'/�/ 0 0 Page 1 of 1 Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Tuesday, April 22, 2008 2:52 PM Subject: aio2b-030 (KRU) and aio24b-001 (PBU) Administrative Approvals Attachments: A1024B-001.pdf; aio2b-030.pdf BCC:'Dale Hoffman'; Joseph Longo; Maurizio Grandi; Tom Gennings; 'Aleutians East Borough'; 'Anna Raff; Arion, Teri A (DNR); 'Arthur Copoulos'; 'Barbara F Fullmer'; 'bbritch'; 'Bill Walker'; 'Brad McKim'; 'Brandon Gagnon'; 'Brian Gillespie'; 'Brian Havelock'; 'Brit Lively'; 'Bruce Webb'; 'buonoje'; 'Cammy Taylor'; 'Cande.Brandow'; 'carol smyth'; 'Cary Carrigan'; caunderwood@marathonoil.com; 'Charles O'Donnell'; 'Chris Gay'; 'Christian Gou-Leonhardt'; 'Cliff Posey'; 'Dan Bross'; 'dapa'; 'Daryl J. Kleppin'; 'David Brown'; 'David Hall'; David House; 'David L Boelens'; 'David Steingreaber'; 'ddonkel'; 'Deanna Gamble'; 'Deborah J. Jones'; 'doug_schultze'; 'Eric Lidji '; 'Evan Harness'; 'eyancy'; Toms2@mtaonline.net'; 'Francis S. Sommer'; 'Fred Steece'; 'Garland Robinson'; 'Gary Laughlin'; 'Gary Rogers'; 'Gary Schultz'; 'ghammons'; 'Gordon Pospisil'; Gould, Greg M (DEC); 'Gregg Nady'; 'gregory micallef ; 'gspfoff ; 'Hank Alford'; 'Harry Engel'; Jah'; 'James Scherr'; 'Janet D. Platt'; 'jejones'; 'Jerry McCutcheon'; 'Jim Arlington'; 'Jim White'; 'Jim Winegamer'; 'Joe Nicks'; 'John Garing'; 'John S. Haworth'; 'John Spain'; 'John Tower'; 'John W Katz'; johnny.aiken@north-slope.org; 'Jon Goltz'; 'Julie Houle'; 'Kari Moriarty'; 'Kaynell Zeman'; 'Keith Wiles'; knelson@petroleumnews.com; 'Krissell Crandall'; 'Kristin Dirks'; 'Laura Silliphant'; 'Lois'; 'Lynnda Kahn'; 'mail=akpratts@acsalaska.net'; 'mail=foms@mtaonline.net'; 'Marilyn Crockett'; 'Mark Dalton'; 'Mark Hanley'; 'Mark Kovac'; 'Mark P. Worcester'; 'Marquerite kremer'; 'marty'; 'Matt Rader'; 'mckay'; 'Meghan Powell'; 'Mike Bill'; 'Mike Mason'; 'Mikel Schultz'; 'Mindy Lewis'; 'MJ Loveland'; 'mjnelson'; 'mkm7200'; 'Nick W. Glover'; NSK Problem Well Supv; NSU, ADW Well Integrity Engineer; 'Patty Alfaro'; 'Paul Decker'; 'Paul Winslow'; Pierce, Sandra M (DNR); 'Randall Kanady'; 'Randy L. Skillern'; 'rcrotty'; Rice, Cody J (DNR); 'rmclean'; 'Rob McWhorter'; rob.g.dragnich@exxonmobil.com; 'Robert Campbell'; 'Robert Fowler'; 'Robert Province'; 'Roger Belman'; 'Rudy Brueggeman'; 'Scott Cranswick'; 'Shannon Donnelly'; 'Sharmaine Copeland'; 'Sondra Stewman'; 'Sonja Frankllin'; 'Stan Porhola'; 'stanekj'; 'Steve Lambert'; 'Steve Moothart'; 'Steven R. Rossberg'; 'tablerk'; 'Tamera Sheffield'; 'Temple Davidson'; 'Terrie Hubble'; 'Tim Lawlor'; 'Todd Durkee'; Tony Hopfinger; 'trmjrl'; 'Walter Featherly'; 'Walter Quay'; 'Wayne Rancier'; Birnbaum, Alan J (LAW); Crisp, John H (DOA); Davies, Stephen F (DOA); Fleckenstein, Robert J (DOA); Foerster, Catherine P (DOA); Grimaldi, Louis R (DOA); Johnson, Elaine M (DOA); Jones, Jeffery B (DOA); Laasch, Linda K (DOA); Mahnken, Christine R (DOA); Maunder, Thomas E (DOA); McIver, C (DOA); McMains, Stephen E (DOA); Noble, Robert C (DOA); Norman, John K (DOA); Okland, Howard D (DOA); Paladijczuk, Tracie L (DOA); Pasqual, Maria (DOA); Regg, James B (DOA); Roby, David S (DOA); Saltmarsh, Arthur C (DOA); Scheve, Charles M (DOA); Seamount, Dan T (DOA); Smith, Chasity R (DOA); Williamson, Mary J (DOA) Attachments: AI02413-001.pdf;aio2b-030.pdf, Jody Colombie Special Assistant Alaska Oil & Gas Conservation Commission Direct: 907-793-1221 Fax: 907-276-7542 *Note new email address 4/22/2008 • 7-3 SARAH PALIN, GOVERNOR U ATjASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMPIISSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 CANCELLATION ADMINISTRATIVE APPROVAL NO. AIO 2413.001 Mr. Steve Rossberg, Wells Manager Attention: Well Integrity Engineer, PRB-20 BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 RE: Cancellation of Administrative Approval AIO 2413.001 Prudhoe Bay Unit Well V-112 (PTD 2060200) Borealis Oil Pool Dear Mr. Rossberg: Pursuant to BP Exploration (Alaska) Inc. (BPXA)'s request dated July 15, 2008 Alaska Oil and Gas Conservation Commission (AOGCC) hereby cancels Administrative Approval AIO 2413.001, which allows continued water injection in Prudhoe Bay Unit (PBU) well V-112. This well exhibited tubing by inner annulus communication and BPXA did not at the time propose repairing the well to eliminate the problem. The Commission determined that water injection could safely continue in the well, but subject to a number of restrictive conditions set out in the administrative approval. BPXA has since performed a well intervention to install new dummy gas lift valves with extended packing in PBU V-112. BPXA provided wellhead pressure data demonstrating the elimination of tubing by inner annulus pressure communication while injecting miscible gas. Consequently, Administrative Approval AIO 2413.001 no longer applies to operation of this well. Instead, injection into PBU V-112 will be governed by provisions of the underlying AIO No. 24B. DONE at Anchorage, Alaska and The Alaska Oil an G Cathyoerster Comr4sioner vz Bernie Karl North Slope Borough Williams Thomas K&K Recycling Inc. PO Box 69 Mary Jones David McCaleb Cindi Walker XTO Energy, Inc. IHS Energy Group Tesoro Refining and Marketing Co. Cartography GEPS Supply & Distribution 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 300 Concord Plaza Drive Ft. Worth, TX 76102-6298 Houston, TX 77056 San Antonio, TX 78216 George Vaught, Jr. Jerry Hodgden Richard Neahring PO Box 13557 Hodgden Oil Company NRG Associates Denver, CO 80201-3557 408 18th Street President Golden, CO 80401-2433 PO Box 1655 Colorado Springs, CO 80901 John Levorsen Mark Wedman Baker Oil Tools 200 North 3rd Street, #1202 Halliburton 4730 Business Park Blvd., #44 Boise, ID 83702 6900 Arctic Blvd. Anchorage, AK 99503 Anchorage, AK 99502 Schlumberger Ciri Ivan Gillian Drilling and Measurements Land Department 9649 Musket Bell Cr.#5 2525 Gambell Street #400 PO Box 93330 Anchorage, AK 99507 Anchorage, AK 99503 Anchorage, AK 99503 Jill Schneider Gordon Severson Jack Hakkila US Geological Survey 3201 Westmar Cr. PO Box 190083 4200 University Dr. Anchorage, AK 99508-4336 Anchorage, AK 99519 Anchorage, AK 99508 Darwin Waldsmith James Gibbs Kenai National Wildlife Refuge PO Box 39309 PO Box 1597 Refuge Manager Ninilchick, AK 99639 Soldotna, AK 99669 PO Box 2139 Soldotna, AK 99669-2139 Penny Vadla Richard Wagner Cliff Burglin 399 West Riverview Avenue PO Box 60868 PO Box 70131 Soldotna, AK 99669-7714 Fairbanks, AK 99706 Fairbanks, AK 99707 Bernie Karl North Slope Borough Williams Thomas K&K Recycling Inc. PO Box 69 Arctic Slope Regional Corporation PO Box 58055 Barrow, AK 99723 Land Department Fairbanks, AK 99711 PO Box 129 Barrow, AK 99723 Page 1 of 1 • Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Friday, July 25, 2008 8:20 AM Subject: aio2B-034 (KRU) and aio24B-001 (PBU) cancellation Attachments: aio2B-034.pdf; aio24B-001 cancellation. pdf BCC:'Dale Hoffman'; Fridiric Grenier; Joseph Longo; 'Lamont Frazer'; 'Mary Aschoff; Maurizio Grandi; 'Scott Nash'; Tom Gennings; 'Willem Vollenbrock'; 'Aleutians East Borough'; 'Anna Raff; Arion, Teri A (DNR); 'Arthur Copoulos'; 'Barbara F Fullmer'; 'bbritch'; 'Bill Walker'; 'Brad McKim'; 'Brandon Gagnon'; 'Brian Gillespie'; 'Brian Havelock'; 'Brit Lively'; 'Bruce Webb'; 'buonoje'; 'Cammy Taylor'; 'Cande.Brandow'; 'carol smyth'; 'Cary Carrigan'; caunderwood@marathonoil.com; 'Charles O'Donnell'; 'Chris Gay'; 'Christian Gou-Leonhardt'; 'Cliff Posey'; 'Dan Bross'; 'dapa'; 'Daryl J. Kleppin'; 'David Brown'; 'David Hall'; David House; 'David L Boelens'; 'David Steingreaber'; 'ddonkel'; 'Deborah J. Jones'; 'doug_schultze'; 'Eric Lidji '; 'Evan Harness'; 'eyancy'; Toms2@mtaonline.net'; 'Francis S. Sommer'; 'Fred Steece'; 'Garland Robinson'; 'Gary Laughlin'; 'Gary Rogers'; 'Gary Schultz'; 'ghammons'; 'Gordon Pospisil'; Gould, Greg M (DEC); 'Gregg Nady'; 'gregory micallef; 'gspfoff; 'Hank Alford'; 'Harry Engel'; 'jah'; 'James Scherr'; 'Janet D. Platt'; Jejones'; 'Jerry McCutcheon'; 'Jim Arlington'; 'Jim White'; 'Jim Winegarner'; 'Joe Nicks'; 'John Garing'; 'John S. Haworth'; 'John Spain'; 'John Tower'; 'John W Katz'; johnny.aiken@north-slope.org; 'Jon Goltz'; 'Julie Houle'; 'Kari Moriarty'; 'Kaynell Zeman'; 'Keith Wiles'; knelson@petroleumnews.com; 'Krissell Crandall'; 'Kristin Dirks'; 'Laura Silliphant'; 'Lois'; 'Lynnda Kahn'; 'mail=akpratts@acsalaska.net'; 'mail=foms@mtaonline.net'; 'Marilyn Crockett'; 'Mark Dalton'; 'Mark Hanley'; 'Mark Kovac'; 'Mark P. Worcester'; 'Marguerite kremer'; 'marty'; 'Matt Rader'; 'Meghan Powell'; Melanie Brown; 'Mike Bill'; 'Mike Mason'; 'Mikel Schultz'; 'Mindy Lewis'; 'MJ Loveland'; 'mjnelson'; 'mkm7200'; 'Nick W. Glover'; NSK Problem Well Supv; NSU, ADW Well Integrity Engineer; 'Patty Alfaro'; 'Paul Decker'; 'Paul Winslow'; Pierce, Sandra M (DNR); 'Randall Kanady'; 'Randy L. Skillern'; 'rcrotty'; Rice, Cody J (DNR); 'rmclean'; 'Rob McWhorter'; rob.g.dragnich@exxonmobil.com; 'Robert Campbell'; 'Robert Fowler'; 'Robert Province'; 'Roger Belman'; 'Rudy Brueggeman'; 'Scott Cranswick'; 'Shannon Donnelly'; 'Sharmaine Copeland'; 'Sondra Stewman'; 'Sonja Frankllin'; 'Stan Porhola'; 'stanekj'; 'Steve Lambert'; 'Steve Moothart'; 'Steven R. Rossberg'; 'tablerk'; 'Tamera Sheffield'; 'Temple Davidson'; 'Terrie Hubble'; 'Tim Lawlor'; 'Todd Durkee'; Tony Hopfinger; 'trmjrF; 'Walter Featherly'; 'Walter Quay'; 'Wayne Rancier'; Birnbaum, Alan J (LAW); Crisp, John H (DOA); Davies, Stephen F (DOA); Fleckenstein, Robert J (DOA); Foerster, Catherine P (DOA); Grimaldi, Louis R (DOA); Johnson, Elaine M (DOA); Jones, Jeffery B (DOA); Laasch, Linda K (DOA); Mahnken, Christine R (DOA); Maunder, Thomas E (DOA); McIver, C (DOA); McMains, Stephen E (DOA); Noble, Robert C (DOA); Norman, John K (DOA); Okland, Howard D (DOA); Paladijczuk, Tracie L (DOA); Pasqual, Maria (DOA); Regg, James B (DOA); Roby, David S (DOA); Saltmarsh, Arthur C (DOA); Scheve, Charles M (DOA); Seamount, Dan T (DOA); Smith, Chasity R (DOA); Williamson, Mary J (DOA) Attachments: aio2B-034.pdf;aio24B-001 cancellation.pdf, Jody Jaylene Colombie Special Assistant to the Commission Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 (907) 793-1221 Direct Line (907) 276-7542 Fax 7/25/2008 • ME ALASKA SARAH PAL/N, GOVERNOR A14A►7IrLA OIL AND GALS 333 W 7th AVENUE, SUITE 100 CONSERVATION COMDIISSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL AIO 2411.002 Mr. Steve Rossberg Wells Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 RE: PBU L-111 (PTD 2020300) Request for Administrative Approval Borealis Oil Pool Dear Mr. Rossberg: Pursuant to Rule 9 of Area Injection Order (AIO) 24B.000, the Alaska Oil and Gas Conservation Commission (AOGCC or Commission) hereby grants BP Exploration (Alaska) Inc. (BPXA)'s request for administrative approval to continue water injection in the subject well. The Commission was notified by BPXA of tubing by inner annuls communication while injecting miscible gas in PBU L-111. Gas lift valves with extended packing were installed to remedy the pressure communication in July 2008 and subsequent pressure tests were performed to prove primary and secondary barriers in the well. An AOGCC witnessed test to 4000 psi passed on August 8, 2008. Subsequent to returning the well to miscible gas injection, the well demonstrates inner annulus repressurization that can be safely managed with periodic pressure bleeds. Outer annulus pressures do not indicate anomalous conditions or loss of pressure integrity. AOGCC finds that BPXA has elected to perform no corrective action at this time on PBU L-111. The Commission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety, if the well's operation is subject to the constraints enumerated below. AOGCC's administrative approval to continue water injection only in PBU L-111 is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injection rates, and shall flag the well's periodic pressure bleeds on the report; AIO 24B.002 September 19, 2008 Page 2 of 2 3. BPXA shall perform an MIT - IA every 2 years to the maximum anticipated injection pressure; 4. BPXA shall immediately notify the AOGCC and shut in the well if there is any continued deterioration in well integrity, indicated by increased inner or outer annulus pressure, increased repressure rate, or increased bleed frequency; 5. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 6. The MIT anniversary date is August 8, 2008. DONE at Anchorage, Alaska and dated September 19, 2008. )46� M, d,-) " 1 —7p Daniel T. Sei5rmount, Jr. CathyP. Foerster Chair Commissioner cc: BPXA Well Integrity Coordinator, PRB-20 P.O. Box 196612 Anchorage, AK 99519-6612 RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of re- consideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Com- mission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by in- action, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on re- consideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on re- consideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the pe- riod; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Page 1 of 1 0 Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Monday, September 22, 2008 7:57 AM Subject: aio24b-002 (Borealis) and aiol-008 (Endicott) Attachments: aio24B-002.pdf; aiol-008.pdf BCC:'Dale Hoffman'; Fridiric Grenier; Joseph Longo; 'Lamont Frazer'; 'Mary Aschoff; Maurizio Grandi; P Bates; 'Scott Nash'; Tom Gennings; 'Willem Vollenbrock'; 'William Van Dyke'; 'Aleutians East Borough'; 'Anna Raff; Arion, Teri A (DNR); 'Arthur Copoulos'; 'Barbara F Fullmer'; 'bbritch'; 'Bill Walker'; 'Brad McKim'; 'Brandon Gagnon'; 'Brian Gillespie'; 'Brian Havelock'; 'Brit Lively'; 'Bruce Webb'; 'buonoje'; 'Cammy Taylor'; 'Cande.Brandow'; 'carol smyth'; 'Cary Carrigan'; caunderwood@marathonoil.com; 'Charles O'Donnell'; 'Chris Gay'; 'Christian Gou-Leonhardt'; 'Cliff Posey'; 'Dan Bross'; 'dapa'; 'Daryl J. Kleppin'; 'David Brown'; 'David Hall'; David House; 'David L Boelens'; 'David Steingreaber'; 'ddonkel'; 'Deborah J. Jones'; 'doug_schultze'; 'Eric Lidj i '; 'Evan Harness'; 'eyancy'; Toms2@mtaonline.net'; 'Francis S. Sommer'; 'Fred Steece'; 'Garland Robinson'; 'Gary Laughlin'; 'Gary Rogers'; 'Gary Schultz'; 'ghammons'; 'Gordon Pospisil'; Gould, Greg M (DEC); 'Gregg Nady'; 'gregory micallef ; 'gspfoff ; 'Hank Alford'; 'Harry Engel'; Jah'; 'James Scherr'; 'Janet D. Platt'; Jejones'; 'Jerry McCutcheon'; 'Jim Arlington'; 'Jim White'; 'Jim Winegarner'; 'Joe Nicks'; 'John Garing'; 'John S. Haworth'; 'John Spain'; 'John Tower'; 'John W Katz'; johnny.aiken@north-slope.org; 'Jon Goltz'; 'Julie Houle'; 'Kari Moriarty'; 'Kaynell Zeman'; 'Keith Wiles'; knelson@petroleumnews.com; 'Krissell Crandall'; 'Kristin Dirks'; 'Laura Silliphant'; 'Lois'; 'Lynnda Kahn'; 'mail=akpratts@acsalaska.net'; 'mail=foms@mtaonline.net'; 'Marilyn Crockett'; 'Mark Dalton'; 'Mark Hanley'; 'Mark Kovac'; 'Mark P. Worcester'; 'Marguerite kremer'; 'marty'; 'Matt Rader'; 'Meghan Powell'; Melanie Brown; 'Mike Bill'; 'Mike Mason'; 'Mikel Schultz'; 'Mindy Lewis'; 'MJ Loveland'; 'mjnelson'; 'mkm7200'; 'Nick W. Glover'; NSK Problem Well Supv; NSU, ADW Well Integrity Engineer; 'Patty Alfaro'; 'Paul Decker'; 'Paul Winslow'; Pierce, Sandra M (DNR); 'Randall Kanady'; 'Randy L. Skillern'; 'rcrotty'; Rice, Cody J (DNR); 'rmclean'; 'Rob McWhorter'; rob.g.dragnich@exxomnobil.com; 'Robert Campbell'; 'Robert Fowler'; 'Robert Province'; 'Roger Belman'; 'Rudy Brueggeman'; 'Scott Cranswick'; 'Shannon Donnelly'; 'Sharmaine Copeland'; 'Sondra Stewman'; 'Sonja Frankllin'; 'Stan Porhola'; 'stanekj'; 'Steve Lambert'; 'Steve Moothart'; 'Steven R. Rossberg'; 'tablerk'; 'Tamera Sheffield'; 'Temple Davidson'; 'Terrie Hubble'; 'Tim Lawlor'; 'Todd Durkee'; Tony Hopfinger; 'trmjrl'; 'Walter Featherly'; 'Walter Quay'; 'Wayne Rancier'; Birnbaum, Alan J (LAW); Crisp, John H (DOA); Davies, Stephen F (DOA); Fleckenstein, Robert J (DOA); Foerster, Catherine P (DOA); Grimaldi, Louis R (DOA); Johnson, Elaine M (DOA); Jones, Jeffery B (DOA); Laasch, Linda K (DOA); Mahnken, Christine R (DOA); Maunder, Thomas E (DOA); McIver, C (DOA); McMains, Stephen E (DOA); Noble, Robert C (DOA); Norman, John K (DOA); Okland, Howard D (DOA); Paladijczuk, Tracie L (DOA); Pasqual, Maria (DOA); Regg, James B (DOA); Roby, David S (DOA); Saltmarsh, Arthur C (DOA); Scheve, Charles M (DOA); Seamount, Dan T (DOA); Smith, Chasity R (DOA); Williamson, Mary J (DOA) Attachments: aio24B-002.pdf;aio 1-008.pdf, Jody J. Colombie Special Assistant to the Commission Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 (907) 793-1221 Direct Line (907) 276-7542 Fax 9/22/2008 Bernie Karl North Slope Borough Williams Thomas K&K Recycling Inc. PO Box 69 Arctic Slope Regional Corporation PO Box 58055 Barrow, AK 99723 Land Department Fairbanks, AK 99711 PO Box 129 Barrow, AK 99723 Mary Jones David McCaleb Cindi Walker XTO Energy, Inc. IHS Energy Group Tesoro Refining and Marketing Co. Cartography GEPS Supply & Distribution 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 300 Concord Plaza Drive Ft. Worth, TX 76102-6298 Houston, TX 77056 San Antonio, TX 78216 George Vaught, Jr. Jerry Hodgden Richard Neahring PO Box 13557 Hodgden Oil Company NRG Associates Denver, CO 80201-3557 408 18th Street President Golden, CO 80401-2433 PO Box 1655 Colorado Springs, CO 80901 John Levorsen Mark Wedman Baker Oil Tools 200 North 3rd Street, #1202 Halliburton 4730 Business Park Blvd., #44 Boise, ID 83702 6900 Arctic Blvd. Anchorage, AK 99503 Anchorage, AK 99502 Schlumberger Ciri Ivan Gillian Drilling and Measurements Land Department 9649 Musket Bell Cr.#5 2525 Gambell Street #400 PO Box 93330 Anchorage, AK 99507 Anchorage, AK 99503 Anchorage, AK 99503 Jill Schneider Gordon Severson Jack Hakkila US Geological Survey 3201 Westmar Cr. PO Box 190083 4200 University Dr. Anchorage, AK 99508-4336 Anchorage, AK 99519 Anchorage, AK 99508 Darwin Waldsmith James Gibbs Kenai National Wildlife Refuge PO Box 39309 PO Box 1597 Refuge Manager Ninilchick, AK 99639 Soldotna, AK 99669 PO Box 2139 Soldotna, AK 99669-2139 Penny Vadla Richard Wagner Cliff Burglin 399 West Riverview Avenue PO Box 60868 PO Box 70131 Soldotna, AK 99669-7714 Fairbanks, AK 99706 Fairbanks, AK 99707 Bernie Karl North Slope Borough Williams Thomas K&K Recycling Inc. PO Box 69 Arctic Slope Regional Corporation PO Box 58055 Barrow, AK 99723 Land Department Fairbanks, AK 99711 PO Box 129 Barrow, AK 99723 0 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 cancellation of Administrative Approval 2413.002 allowing well L- I I I (PTD 2020300) to return to miscible injectant (MI) for water alternating gas (WAG) service. Area Injection Order No. 2413.002 Cancellation Prudhoe Bay Unit Borealis Field Borealis Oil Pool June 19, 2013 By letter dated June 8, 2013, BP Exploration (Alaska) Inc. (BPXA) requested cancellation of administrative approval (AA) Area Injection Order (AIO) 2413.002 to allow well L-111 (PTD 20203 00) to inject both water and miscible gas injectant for water alternating gas (WAG) service. In accordance with Rule 9 of AIO 02413.000, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS BPXA's request to cancel the AA and return the well to WAG service as detailed below. This well exhibited a slow inner annulus repressurization. Because BPXA at that time did not propose repairing the well to eliminate the problem, the Commission determined that only water injection could safely continue in the well, and imposed a number of restrictive conditions set out in the administrative approval. BPXA has since performed a well intervention to install a tubing patch and an MITIA passed to 4070 psi on July 8, 2012. A witnessed MITIA passed to 2660 psi with water on August 10, 2012. BPXA requested a 60 day miscible gas injection monitoring period for inner annulus repressurization which was completed June 2, 2013 and no indication of inner annulus repressurization was observed. BPXA provided wellhead pressure data and injection rates and pressures demonstrating the elimination of tubing by inner annulus communication while injecting miscible gas. Consequently, Administrative Approval AIO 2413.002 is no longer necessary to the operation of this well. Injection into PBU L-111 will be governed by provisions of the underlying AIO No. 24B. DONE at Anchorage, Alaska and dated June 19, 2013. 4Cathvy JP . Foerster Chair, Commissioner Daniel T. Seamount, Jr. Commissioner AIO 24B.002 Cancellatiol June 19, 2013 Page 2 of 2 RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[tlhe questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Singh, Angela K (DOA) i • From: Colombie, Jody J (DOA) Sent: Wednesday, June 19, 2013 1:17 PM To: (michael j.nelson@conocophillips.com); AKDCWellIntegrityCoordinator, alaska@petrocalc.com; Alexander Bridge; Andrew VanderJack; Anna Raff; Barbara F Fullmer, bbritch; bbohrer@ap.org; Bill Penrose; Bill Walker; Bowen Roberts; Brian Havelock, Burdick, John D (DNR); caunderwood@marathonoil.com; Cliff Posey; Crandall, Krissell; D Lawrence; Daryl J. Kleppin; Dave Harbour, Dave Matthews; David Boelens; David Duffy, David House; David Scott; David Steingreaber; Davide Simeone; ddonkel@cfl.rr.com; Donna Ambruz; Dowdy, Alicia G (DNR); Dudley Platt; Elowe, Kristin; Evans, John R (LDZX); Francis S. Sommer; Gary Laughlin; Schultz, gary (DNR sponsored); ghammons; Gordon Pospisil; Gorney, David L.; Greg Duggin; Gregg Nady; Gregory Geddes; gspfoff, Jdarlington Oarlington@gmail.com); Jeanne McPherren; Jones, Jeffery B (DOA); Jerry McCutcheon; Jim White, Jim Winegarner, Joe Lastufka; news@radiokenai.com; Easton, John R (DNR); John Garing; Jon Goltz; Jones, Jeffrey L (GOV); Juanita Lovett; Judy Stanek; Houle, Julie (DNR); Julie Little; Kari Moriarty, Kaynell Zeman; Keith Wiles; Kelly Sperback; Gregersen, Laura S (DNR); Leslie Smith; Louisiana Cutler, Luke Keller, Marc Kovak; Dalton, Mark (DOT sponsored); Mark Hanley (mark.hanley@anadarko.com); Mark P. Worcester, Kremer, Marguerite C (DNR); Michael Jacobs; Mike Bill; mike@kbbi.org; Mikel Schultz, Mindy Lewis; MJ Loveland; mjnelson; mkm7200; knelson@petroleumnews.com; Nick W. Glover, Nikki Martin; NSK Problem Well Supv; Patty Alfaro; Decker, Paul L (DNR); Paul Mazzolini; Pike, Kevin W (DNR); Pioneer, Randall Kanady; Randy L. Skillern; Randy Redmond; Rena Delbridge; Renan Yanish; Robert Brelsford; Robert Campbell; Ryan Tunseth; Sandra Haggard; Sara Leverette; Scott Cranswick; Scott Griffith; Shannon Donnelly, Sharmaine Copeland; Sharon Yarawsky; Shellenbaum, Diane P (DNR); Slemons, Jonne D (DNR); Smith, Kyle S (DNR); Sondra Stewman; Stephanie Klemmer, Steve Kiorpes; Moothart, Steve R (DNR); Steven R. Rossberg; Suzanne Gibson; sheffield@aoga.org; Tania Ramos; Ted Kramer, Davidson, Temple (DNR); Teresa Imm; Thor Cutler, Tim Mayers; Tina Grovier (tmgrovier@stoel.com); Todd Durkee; Tony Hopfinger, trmjrl; Vicki Irwin; Walter Featherly; yjrosen@ak.net; Aaron Gluzman; Aaron Sorrell; Bruce Williams; Bruno, Jeff J (DNR); Casey Sullivan; David Lenig; David Martin; Donna Vukich; Eric Lidji; Erik Opstad; Franger, James M (DNR); Gary Orr, Smith, Graham O (PCO); Greg Mattson; Heusser, Heather A (DNR); Holly Pearen; James Rodgers; Jason Bergerson; Jennifer Starck; jill.a.mcleod@conocophillips.com; Jim Magill; Joe Longo; King, Kathleen J (DNR); Laney Vazquez; Lois Epstein; Marc Kuck, Steele, Marie C (DNR); Matt Gill; Ostrovsky, Larry (DNR sponsored); Bettis, Patricia K (DOA); Perrin, Don J (DNR); Peter Contreras; Pexton, Scott R (DNR); Pollard, Susan R (LAW); Pollet, Jolie; Richard Garrard; Ryan Daniel; Sandra Lemke; Talib Syed; Wayne Wooster, Woolf, Wendy C (DNR); William Hutto; William Van Dyke; Singh, Angela K (DOA); Ballantine, Tab A (LAW); Bettis, Patricia K (DOA); Brooks, Phoebe L (DOA); Colombie, Jody J (DOA); Crisp, John H (DOA); Davies, Stephen F (DOA); Ferguson, Victoria L (DOA); Fisher, Samantha J (DOA); Foerster, Catherine P (DOA); Grimaldi, Louis R (DOA); Hunt, Jennifer L (DOA); Johnson, Elaine M (DOA); Jones, Jeffery B (DOA); Laasch, Linda K (DOA); Bender, Makana K (DOA); Mumm, Joseph (DOA sponsored); Noble, Robert C (DOA); Norman, John K (DOA); Okland, Howard D (DOA); Paladijczuk, Tracie L (DOA); Pasqual, Maria (DOA); Regg, James B (DOA); Roby, David S (DOA); Scheve, Charles M (DOA); Schwartz, Guy L (DOA); Seamount, Dan T (DOA); Wallace, Chris D (DOA) Subject: aio24b.002 (PBU, Borealis Field) Attachments: aio24b.002.pdf A ® Bend along line to I • Feed Paper expose Pop-up EdgeTm 0 Douglas A. Cismoski, P.E. GWO Wells Interventions Manager BP Exploration (Alaska) Inc Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, AK 99519-6612 A Repfiez A la hachure afin de Sena tle..+ rev6ler le rebord Pon-uDTm ®AVERY , ® 5960TH ; It www.avery.com 1 -900 -GO -AVERY Easy Peet® Labels i A l�I Bend alonghne to ' Use Avery® Template 51600 Feed Paper "I expose Pop -p EdgeTM U AVERY® 5960T"" David McCaleb Penny Vadla IHS Energy Group George Vaught, Jr. 399 W. Riverview Ave. GEPS Post Office Box 13557 Soldotna, AK 99669-7714 5333 Westheimer, Ste. 100 Denver, CO 80201-3557 Houston, TX 77056 Jerry Hodgden Richard Neahring Mark Wedman HodgdNn Oil Company President NRG Associates Halliburton 40818 St. 6900 Arctic Blvd. Golden, CO 80401-2433 Post Office Box 1655 Anchorage, AK 99502 Colorado Springs, CO 80901 Bernie Karl CIRI K&K Recycling Inc. Land Department Baker Oil Tools Post Office Box 58055 Post Office Box 93330 795 E. 94 Ct. Fairbanks, AK 99711 Anchorage, AK 99503 Anchorage, AK 99515-4295 North Slope Borough Planning Department Richard Wagner Gordon Severson Post Office Box m69 Post Office Box 60868 3201 Westmar Cir. Barrow, AK 99723 Fairbanks, AK 99706 Anchorage, AK 99508-4336 Jack Hakkila Darwin Waldsmith James Gibbs Post Office Box 190083 Post Office Box 39309 Post Office Box 1597 Anchorage, AK 99519 Ninilchik, AK 99639 Soldotna, AK 99669 Irtiquettes faales paler ; A Repiiez a la hachure ann de U® � i Sens de tm tilisez le gabarit AVERYO 5160 , h„a.e.„e... reveler le rebord Pole-ua www.avery.com ; 1 -900 -GO -AVERY ! • • 6 0 ALASKA SEAN PARNELL, GOVERNOR 7�TALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMUSSIO ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 ADMINISTRATIVE APPROVAL FAX (907) 276-7542 AREA INJECTION ORDER NO. 2411.003 Ms. Allison Cooke UIC Compliance Advisor BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 RE: Authorized Fluids for EOR and Pressure Maintenance of the Borealis Oil Pool Dear Ms. Cooke: By letter dated April 30, 2012, BP Exploration (Alaska) Inc. (BPXA) requested that the Alaska Oil and Gas Conservation Commission (AOGCC) administratively amend the following Area Injection Orders (AIO): 3A, 4E, 14A, 20, 22E, 24B, 25A, 26B and 31. BPXA requested the amendments in an effort to standardize the fluids authorized for injection for enhanced recovery and pressure maintenance for the oil pools in the Prudhoe Bay Field. BPXA requested the standardization due to the complexity of managing injection operations for multiple pools, with different lists of authorized fluids, which are served by common production facilities. In accordance with terms set forth below, BPXA's request is APPROVED, with a minor change to the wording proposed by BPXA. BPXA proposes that AIO No. 24B be modified to approve the following for EOR and pressure maintenance injection. - Produced water and gas; - Enriched hydrocarbon gas; - Non -hazardous water and water based fluids — (includes seawater, source water, freshwater, domestic wastewater, equipment washwater, sump fluids, hydrotest fluids, firewater, and water with trace chemicals, and other water based fluids with a pH greater than or equal to 2 or less than or equal to 12.5 and flashpoint greater than 10 degrees F); - Fluids introduced to production facilities for the purpose of oil production, plant operations, plant/piping integrity or well maintenance that become entrained in the produced water stream after oil, gas, and water separation in the facility. Includes but not limited to: o Freeze protection fluids; O Fluids in mixtures of oil sent for hydrocarbon recycle; o Corrosion/scale inhibitor fluids; o Anti-foams/emulsion breakers; AIO 24B.003 • • September 4, 2012 Page 2 of 3 o Glycols Non -hazardous glycols and glycol mixtures; Fluids that are used for their intended purpose within the oil production process. Includes: o Scavengers; o Biocides Fluids to monitor or enhance reservoir performance. Includes: o Tracer survey fluids; o Well stimulation fluids; o Reservoir profile modification fluids. As shown above, the list of fluids for which BPXA seeks approval uses the terms "includes" and "includes but not limited to." Words such as "includes" and "including" along with phrases such as "includes but is not limited to" inappropriately delegate to BPXA the authority to determine what additional fluids are approved. Therefore, this approval modifies BPXA's proposal to delete the use of any such language as set forth below. In support of its application, BPXA submitted a fluid compatibility review based on previous orders and laboratory testing. This review showed that the proper handling and treating, including the use of scale inhibitors, of the injection fluids as well as the proper operation and maintenance, including the pumping of scale remover and acid treatments, of the injection wells will prevent or counteract incompatibility effects. Thus there are no operational risks associated with injection of the proposed fluids in this pool. The change proposed by BPXA will result in increased production, is based on sound engineering and geotechnical reasons, does not promote waste or jeopardize correlative rights, and will not result in increased risk of fluid movement into freshwater. Correlative rights are protected because all lands subject to these orders have been unitized. Freshwater is protected by the proper design and completion of the wells, ongoing/periodic mechanical integrity evaluation required for all injection wells and review of the offset wells to ensure that they won't act as conduits to fluid movement. NOW THEREFORE IT IS ORDERED THAT: Rule 2 of AIO 24B is repealed and replaced by the following: Rule 2 Authorized Iniection Fluids Fluids authorized for injection within the affected area are: a) Produced water and gas from Prudhoe Bay Unit processing facilities; b) Enriched hydrocarbon gas; c) Non -hazardous water and water based fluids — (specifically seawater, source water, freshwater, domestic wastewater, equipment washwater, sump fluids, hydrotest fluids, firewater, and water with trace chemicals, and other water based AIO 24B.003 • • September 4, 2012 Page 3 of 3 fluids with a pH greater than or equal to 2 or less than or equal to 12.5 and flashpoint greater than 10 degrees F); d) Fluids introduced to production facilities for the purpose of oil production, plant operations, plant/piping integrity or well maintenance that become entrained in the produced water stream after oil, gas, and water separation in the facility. Specifically: i. Freeze protection fluids; ii. Fluids in mixtures of oil sent for hydrocarbon recycle; iii. Corrosion/scale inhibitor fluids; iv. Anti-foams/emulsion breakers; V. Glycols e) Non -hazardous glycols and glycol mixtures; f) Fluids that are used for their intended purpose within the oil production process. Specifically: i. Scavengers; ii. Biocides g) Fluids to monitor or enhance reservoir performance. Specifically: i. Tracer survey fluids; ii. Well stimulation fluids; iii. Reservoir profile modification fluids. In addition administrative approval A10 24A.001, which specified additional authorized fluids, is hereby repealed. DONE at Anchorage, Alaska and dated September 4, 2 Daniel T. amount, Jr. Commissioner AND APPEAL As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[tlhe questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. 0 Fisher, Samantha J (DOA) • From: Fisher, Samantha J (DOA) Sent: Thursday, September 06, 2012 1:52 PM To: 'Aaron Gluzman'; 'Aaron Sorrell'; 'Bruce Williams'; Bruno, Jeff J (DNR); 'CA Underwood'; 'Casey Sullivan'; 'Dale Hoffman'; 'David Lenig'; 'Donna Vukich'; 'Eric Lidji'; 'Erik Opstad'; Franger, James M (DNR); 'Gary Orr; 'Graham Smith'; 'Greg Mattson'; Heusser, Heather A (DNR); 'Jason Bergerson'; 'Jennifer Starck'; 'Jill McLeod'; 'Joe Longo'; King, Kathleen J (DNR); 'Lara Coates'; 'Lois Epstein'; 'Marc Kuck'; 'Marie Steele'; 'Mary Aschoff; 'Matt Gill'; 'Maurizio Grandi'; OilGas, Division (DNR sponsored); 'Patricia Bettis'; Perrin, Don J (DNR); 'Peter Contreras'; Pexton, Scott R (DNR); 'Richard Garrard'; 'Ryan Daniel'; 'Sandra Lemke'; 'Talib Syed'; 'Wayne Wooster'; 'Wendy Wollf; 'William Hutto'; 'William Van Dyke'; '(michael.j.nelson@conocophill ips.com)'; '(Von.L.Hutch ins@conocophill ips.com)'; 'AKDCWellintegrityCoordinator; 'alaska@petrocalc.com'; 'Anna Raff; 'Barbara F Fullmer; 'bbritch'; 'Becky Bohrer'; 'Bill Penrose'; 'Bill Walker'; 'Bowen Roberts'; 'Bruce Webb'; 'Claire Caldes'; 'Cliff Posey'; 'Crandall, Krissell'; 'D Lawrence'; 'dapa'; 'Daryl J. Kleppin'; 'Dave Harbour'; 'Dave Matthews'; 'David Boelens'; 'David House'; 'David Scott'; 'David Steingreaber; 'ddonkel@cfl.rr.com'; 'Dennis Steffy'; 'Elowe, Kristin'; 'Erika Denman'; 'Francis S. Sommer'; 'Gary Laughlin'; 'Gary Schultz (gary.schultz@alaska.gov)'; 'ghammons'; 'Gordon Pospisil'; 'Gorney, David L.'; 'Greg Duggin'; 'Gregg Nady'; 'Gregory Geddes'; 'gspfoff; 'Jdarlington (jarlington@gmail. com)'; 'Jeanne McPherren'; 'Jeff Jones'; 'Jeffery B. Jones (jeff.jones@alaska.gov)'; 'Jerry McCutcheon'; 'Jill Womack'; 'Jim White'; 'Jim Winegarner'; 'Joe Lastufka'; 'Joe Nicks'; 'John Easton'; 'John Garing'; 'John S. Haworth'; 'John Spain'; 'Jon Goltz'; Jones, Jeffrey L (GOV); 'Judy Stanek'; 'Julie Houle'; 'Julie Little'; 'Kari Moriarty'; 'Kaynell Zeman'; 'Keith Wiles'; 'Kelly Sperback'; 'Laura Silliphant (laura.gregersen@alaska.gov)'; 'Luke Keller'; 'Marc Kovak'; 'Mark Dalton'; 'Mark Hanley (mark.hanley@anadarko.com)'; 'Mark P. Worcester'; 'Marquerite kremer (meg.kremer@alaska.gov)'; 'Michael Jacobs'; 'Mike Bill'; 'Mike Mason'; 'Mike Morgan'; 'Mike[ Schultz'; 'Mindy Lewis'; 'MJ Loveland'; 'mjnelson'; 'mkm7200'; 'nelson'; 'Nick W. Glover; 'NSK Problem Well Supv'; 'Patty Alfaro'; 'Paul Decker (paul.decker@alaska.gov)'; 'Paul Figel'; 'Paul Mazzolini'; 'Randall Kanady'; 'Randy L. Skillern'; 'Rena Delbridge'; 'Renan Yanish'; 'Robert Brelsford'; 'Robert Campbell'; 'Ryan Tunseth'; 'Scott Cranswick'; 'Scott Griffith'; 'Shannon Donnelly'; 'Sharmaine Copeland'; Shellenbaum, Diane P (DNR); Slemons, Jonne D (DNR); 'Sondra Stewman'; 'Stephanie Klemmer'; 'Steve Moothart (steve.moothart@alaska.gov)'; 'Steven R. Rossberg'; 'Suzanne Gibson'; 'Tamera Sheffield'; Taylor, Cammy O (DNR); 'Temple Davidson'; 'Teresa Imm'; 'Terrie Hubble'; 'Thor Cutler; 'Tim Mayers'; 'Tina Grovier'; 'Todd Durkee'; 'Tony Hopfinger; 'trmjr1'; 'Vicki Irwin'; 'Walter Featherly'; Williamson, Mary J (DNR); 'Yereth Rosen'; Ballantine, Tab A (LAW); Bender, Makana K (DOA); 'Brooks, Phoebe L (DOA) (phoebe.brooks@alaska.gov)'; 'Colombie, Jody J (DOA) (jody.colombie@alaska.gov)'; 'Crisp, John H (DOA) (john.crisp@alaska.gov)'; 'Davies, Stephen F (DOA) (steve.davies@alaska.gov)'; Ferguson, Victoria L (DOA); 'Foerster, Catherine P (DOA) (cathy.foerster@alaska.gov)'; 'Grimaldi, Louis R (DOA) (lou.grimaid i@alaska.gov)'; 'Johnson, Elaine M (DOA) (elaine.johnson@alaska.gov)'; 'Laasch, Linda K (DOA) (linda.laasch@alaska.gov)'; 'McIver, Bren (DOA) (bren.mciver@alaska.gov)'; 'McMains, Stephen E (DOA) (steve.mcmains@alaska.gov)'; Mumm, Joseph (DOA sponsored); 'Noble, Robert C (DOA) (bob. noble@alaska.gov)'; 'Norman, John K (DOA) Qohn.norman@alaska.gov)'; 'Okland, Howard D (DOA) (howard.okland@alaska.gov)'; 'Paladijczuk, Tracie L (DOA)(tracie.paladijczuk@alaska.gov)'; 'Pasqua[, Maria (DOA) (maria.pasqual@alaska.gov)'; 'Regg, James B (DOA) Qim.regg@alaska.gov)'; 'Roby, David S (DOA) (dave.roby@alaska.gov)'; 'Scheve, Charles M (DOA) (chuck.scheve@alaska.gov)'; 'Schwartz, Guy L (DOA) (guy.schwartz@alaska.gov)'; 'Seamount, Dan T (DOA) (dan.seamount@alaska.gov)'; Wallace, Chris D (DOA) Subject: aio24b-003 Borealis Oil Pool Attachments: aio24b-003.pdf Mary Jones David McCaleb XTO Energy, Inc. IHS Energy Group George Vaught, Jr. Cartography GEPS P.O. Box 13557 810 Houston Street, Ste 200 5333 Westheimer, Suite 100 Denver, CO 80201-3557 Ft. Worth, TX 76102-6298 Houston, TX 77056 JerryHod den Richard Neahring g NRG Associates Mark Wedman Hodgden Oil Company Halliburton 408 18th Street President 6900 Arctic Blvd. Golden, CO 80401-2433 P.O. Box 1655 Anchorage, AK 99502 Colorado Springs, CO 80901 Bernie Karl CIRI Baker Oil Tools K&K Recycling Inc. Land Department 795 E. 94th Ct. P.O. Box 58055 P.O. Box 93330 Anchorage, AK 99515-4295 Fairbanks, AK 99711 Anchorage, AK 99503 North Slope Borough Richard Wagner Gordon Severson Planning Department P.O. Box 60868 3201 Westmar Circle P.O. Box 69 Fairbanks, AK 99706 Anchorage, AK 99508-4336 Barrow, AK 99723 Jack Hakkila Darwin Waldsmith James Gibbs P.O. Box 190083 P.O. Box 39309 P.O. Box 1597 Anchorage, AK 99519 Ninilchick, AK 99639 Soldotna, AK 99669 Penny Vadla 399 West Riverview Avenue Soldotna, AK 99669-7714 • THE STATE °'ALASKA Alaska Oil and Gas Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 ADMINISTRATIVE APPROVAL AREA INJECTION ORDER NO. 24B.003 AMENDED Ms. Alison Cooke UIC Compliance Advisor BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 RE: Authorized Fluids for EOR and Pressure Maintenance of the Borealis Oil Pool Dear Ms. Cooke: The Alaska Oil and Gas Conservation Commission has amended the Administrative Approval to correct an error in the description of non -hazardous water based fluids. The correction occurs in two locations and is shown in underlined text below. By letter dated April 30, 2012, BP Exploration (Alaska) Inc. (BPXA) requested that the Alaska Oil and Gas Conservation Commission (AOGCC) administratively amend the following Area Injection Orders (AIO): 3A, 4E, 14A, 20, 22E, 24B, 25A, 26B and 31. BPXA requested the amendments in an effort to standardize the fluids authorized for injection for enhanced recovery and pressure maintenance for the oil pools in the Prudhoe Bay Field. BPXA requested the standardization due to the complexity of managing injection operations for multiple pools, with different lists of authorized fluids, which are served by common production facilities. In accordance with terms set forth below, BPXA's request is APPROVED, with a minor change to the wording proposed by BPXA. BPXA proposes that AIO No. 24B be modified to approve the following for EOR and pressure maintenance injection. - Produced water and gas; - Enriched hydrocarbon gas; - Non -hazardous water and water based fluids — (includes seawater, source water, freshwater, domestic wastewater, equipment washwater, sump fluids, hydrotest fluids, firewater, and water with trace chemicals, and other water based fluids with a pH greater than 2 and less than 12.5 and flashpoint greater than 140 degrees F); - Fluids introduced to production facilities for the purpose of oil production, plant operations, plant/piping integrity or well maintenance that become entrained in the produced water stream after oil, gas, and water separation in the facility. Includes but not limited to: AIO 24B.003 Amended • October 9, 2012 Page 2 of 4 o Freeze protection fluids; o Fluids in mixtures of oil sent for hydrocarbon recycle; o Corrosion/scale inhibitor fluids; o Anti-foams/emulsion breakers; o Glycols - Non -hazardous glycols and glycol mixtures; - Fluids that are used for their intended purpose within the oil production process. Includes: o Scavengers; o Biocides - Fluids to monitor or enhance reservoir performance. Includes: o Tracer survey fluids; o Well stimulation fluids; o Reservoir profile modification fluids. As shown above, the list of fluids for which BPXA seeks approval uses the terms "includes" and "includes but not limited to." Words such as "includes" and "including" along with phrases such as "includes but is not limited to" inappropriately delegate to BPXA the authority to determine what additional fluids are approved. Therefore, this approval modifies BPXA's proposal to delete the use of any such language as set forth below. In support of its application, BPXA submitted a fluid compatibility review based on previous orders and laboratory testing. This review showed that the proper handling and treating, including the use of scale inhibitors, of the injection fluids as well as the proper operation and maintenance, including the pumping of scale remover and acid treatments, of the injection wells will prevent or counteract incompatibility effects. Thus there are no operational risks associated with injection of the proposed fluids in this pool. The change proposed by BPXA will result in increased production, is based on sound engineering and geotechnical reasons, does not promote waste or jeopardize correlative rights, and will not result in increased risk of fluid movement into freshwater. Correlative rights are protected because all lands subject to these orders have been unitized. Freshwater is protected by the proper design and completion of the wells, ongoing/periodic mechanical integrity evaluation required for all injection wells and review of the offset wells to ensure that they won't act as conduits to fluid movement. NOW THEREFORE IT IS ORDERED THAT: Rule 2 of AIO 24B is repealed and replaced by the following: Rule 2 Authorized Iniection Fluids Fluids authorized for injection within the affected area are: a) Produced water and gas from Prudhoe Bay Unit processing facilities; b) Enriched hydrocarbon gas; AIO 24B.003 Amended a • October 9, 2012 Page 3 of 4 c) Non -hazardous water and water based fluids — (specifically seawater, source water, freshwater, domestic wastewater, equipment washwater, sump fluids, hydrotest fluids, firewater, and water with trace chemicals, and other water based fluids with a pH greater than 2 and less than 12.5 and flashpoint greater than 140 degrees F); d) Fluids introduced to production facilities for the purpose of oil production, plant operations, plant/piping integrity or well maintenance that become entrained in the produced water stream after oil, gas, and water separation in the facility. Specifically: i. Freeze protection fluids; ii. Fluids in mixtures of oil sent for hydrocarbon recycle; iii. Corrosion/scale inhibitor fluids; iv. Anti-foams/emulsion breakers; V. Glycols e) Non -hazardous glycols and glycol mixtures; f) Fluids that are used for their intended purpose within the oil production process. Specifically: i. Scavengers; ii. Biocides g) Fluids to monitor or enhance reservoir performance. Specifically: i. Tracer survey fluids; ii. Well stimulation fluids; iii. Reservoir profile modification fluids. In addition administrative approval AIO 24A.001, which specified additional authorized fluids, is hereby repealed. NUNC PRO TUNC September 4, 2012 DONE at Anchorage, Alaska and dated October 9, 20 Daniel T. Seamount, Jr. Commissioner AIO 24B.003 Amended • • October 9, 2012 Page 4 of 4 RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[tlhe questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. __ MaryJones David McCaleb XTO Energy, Inc. IHS Energy Group Cartography GEPS 810 Houston St., Ste. 200 5333 Westheimer, Ste. 100 Ft. Worth, TX 76102-6298 Houston, TX 77056 Jerry Hodgden Richard Neahring Hodgden Oil Company NRG Associates :n President 40818 St. P.O. Box 1655 Golden, CO 80401-2433 Colorado Springs, CO 80901 Bernie Karl CIRI K&K Recycling Inc. Land Department P.O. Box 58055 P.O. Box 93330 Fairbanks, AK 99711 Anchorage, AK 99503 North Slope Borough Richard Wagner Planning Department P.O. Box 60868 P.O. Box 69 Barrow, AK 99723 Fairbanks, AK 99706 Jack Hakkila Darwin Waldsmith P.O. Box 190083 P.O. Box 39309 Anchorage, AK 99519 Ninilchik, AK 99639 Penny Vadla 399 W. Riverview Ave. Soldotna, AK 99669-7714 • George Vaught, Jr. P.O. Box 13557 Denver, CO 80201-3557 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Baker Oil Tools 795 E. 94`h Ct. Anchorage, AK 99515-4295 Gordon Severson 3201 Westmar Cir. Anchorage, AK 99508-4336 James Gibbs P.O. Box 1597 Soldotna, AK 99669 0 Fisher, Samantha J (DOA) From: Fisher, Samantha J (DOA) Sent: Tuesday, October 09, 2012 3:41 PM To: '(michael.j.nelson@conocophillips.com)'; '(Von. L. Hutchins@conocophillips.com)'; 'AKDCWelllntegrityCoordinator; 'alaska@petrocalc.com'; 'Anna Raff; 'Barbara F Fullmer'; 'bbritch'; 'Becky Bohrer; 'Bill Penrose'; 'Bill Walker'; 'Bowen Roberts'; 'Bruce Webb'; 'caunderwood'; 'Claire Caldes'; 'Cliff Posey'; 'Crandall, Krissell'; 'D Lawrence'; 'dapa'; 'Daryl J. Kleppin'; 'Dave Harbour'; 'Dave Matthews'; 'David Boelens'; 'David Duffy'; 'David House'; 'David Scott'; 'David Steingreaber'; 'Davide Simeone'; 'ddonkel@cfl.rr.com'; 'Dennis Steffy'; 'Elowe, Kristin'; 'Francis S. Sommer; 'Gary Laughlin'; 'Gary Schultz (gary.schultz@alaska.gov)'; 'ghammons'; 'Gordon Pospisil'; 'Gorney, David L.'; 'Greg Duggin'; 'Gregg Nady'; 'Gregory Geddes'; 'gspfoff; 'Jdarlington Qarlington@gmail. com)'; 'Jeanne McPherren'; 'Jeffery B. Jones Qeff.jones@alaska.gov)'; 'Jerry McCutcheon'; 'Jill Womack'; 'Jim White'; 'Jim Winegarner'; 'Joe Lastufka'; 'Joe Nicks'; 'John Easton'; 'John Garing'; 'John Spain'; 'Jon Goltz'; Jones, Jeffrey L (GOV); 'Judy Stanek'; 'Julie Houle'; 'Julie Little'; 'Kari Moriarty'; 'Kaynell Zeman'; 'Keith Wiles'; 'Kelly Sperback'; 'Laura Silliphant (laura.gregersen@alaska.gov)'; 'Luke Keller'; 'Marc Kovak'; 'Mark Dalton'; 'Mark Hanley (mark.hanley@anadarko.com)'; 'Mark P. Worcester'; 'Marguerite kremer (meg.kremer@alaska.gov)'; 'Michael Jacobs'; 'Mike Bill'; 'Mike Mason'; 'Mike Morgan'; 'Mike) Schultz'; 'Mindy Lewis'; 'MJ Loveland'; 'mjnelson'; 'mkm7200'; 'nelson'; 'Nick W. Glover'; 'NSK Problem Well Supv'; 'Patty Alfaro'; 'Paul Decker (paul.decker@alaska.gov)'; 'Paul Figel'; 'Paul Mazzolini'; 'Randall Kanady'; 'Randy L. Skillern'; 'Rena Delbridge'; 'Renan Yanish'; 'Robert Brelsford'; 'Robert Campbell'; 'Ryan Tunseth'; 'Scott Cranswick'; 'Scott Griffith'; 'Shannon Donnelly'; 'Sharmaine Copeland'; Shellenbaum, Diane P (DNR); Slemons, Jonne D (DNR); 'Sondra Stewman'; 'Stephanie Klemmer'; 'Steve Moothart (steve.moothart@alaska.gov)'; 'Steven R. Rossberg'; 'Suzanne Gibson'; 'Tamera Sheffield'; Taylor, Cammy O (DNR); 'Temple Davidson'; 'Teresa Imm'; 'Thor Cutler; 'Tim Mayers'; 'Tina Grovier'; 'Todd Durkee'; 'Tony Hopfinger'; 'trmjr1'; 'Vicki Irwin'; 'Walter Featherly'; 'Yereth Rosen'; 'Aaron Gluzman'; 'Aaron Sorrell'; 'Bruce Williams'; Bruno, Jeff J (DNR); 'Casey Sullivan'; 'Dale Hoffman'; 'David Lenig'; 'Donna Vukich'; 'Eric Lidji'; 'Erik Opstad'; Franger, James M (DNR); 'Gary Orr; 'Graham Smith'; 'Greg Mattson'; Heusser, Heather A (DNR); 'James Rodgers'; 'Jason Bergerson'; 'Jennifer Starck'; 'Jill McLeod'; 'Joe Longo'; King, Kathleen J (DNR); 'Lara Coates'; 'Lois Epstein'; 'Marc Kuck'; 'Marie Steele'; 'Matt Gill'; 'Ostrovsky, Larry Z (DNR)'; 'Patricia Bettis'; Perrin, Don J (DNR); 'Peter Contreras'; Pexton, Scott R (DNR); 'Richard Garrard'; 'Ryan Daniel'; 'Sandra Lemke'; 'Talib Syed'; 'Wayne Wooster'; 'Wendy Wollf; 'William Hutto'; 'William Van Dyke'; Ballantine, Tab A (LAW); Bender, Makana K (DOA); 'Brooks, Phoebe L (DOA) (phoebe.brooks@alaska.gov)'; 'Colombie, Jody J (DOA) (jody.colombie@alaska.gov)'; 'Crisp, John H (DOA) Qohn.crisp@alaska.gov)'; 'Davies, Stephen F (DOA) (steve.davies@alaska.gov)'; Ferguson, Victoria L (DOA); 'Foerster, Catherine P (DOA) (cathy.foerster@alaska.gov)'; 'Grimaldi, Louis R (DOA) (lou.grimaldi@alaska.gov)'; 'Johnson, Elaine M (DOA) (elaine.johnson@alaska.gov)'; 'Laasch, Linda K (DOA) (linda.laasch@alaska.gov)'; 'McIver, Bren (DOA) (bren.mciver@alaska.gov)'; 'McMains, Stephen E (DOA) (steve.mcmains@alaska.gov)'; Mumm, Joseph (DOA sponsored); 'Noble, Robert C (DOA) (bob. noble@alaska.gov)'; 'Norman, John K (DOA) (john.norman@alaska.gov)'; 'Okland, Howard D (DOA) (howard.okland@alaska.gov)'; 'Paladijczuk, Tracie L (DOA)(tracie.paladijczuk@alaska.gov)'; 'Pasqual, Maria (DOA) (maria.pasqual@alaska.gov)'; 'Regg, James B (DOA) Qim.regg@alaska.gov)'; 'Roby, David S (DOA) (dave.roby@alaska.gov)'; 'Scheve, Charles M (DOA) (chuck.scheve@alaska.gov)'; 'Schwartz, Guy L (DOA) (guy.schwartz@alaska.gov)'; 'Seamount, Dan T (DOA) (dan.seamount@alaska.gov)'; Singh, Angela K (DOA); Wallace, Chris D (DOA) Subject: aio24b-003 amended Attachments: aio24b-003 amended. pdf STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue, Suite 100 Anchorage Alaska 99501 Re: THE APPLICATION OF BP ) Docket Number: AIO-13-11 EXPLORATION (ALASKA) INC. for ) Area Injection Order No. 24B.004 Administrative Approval to inject ) radioactive tracers used for surface facility ) Prudhoe Bay Unit optimization in enhanced oil recovery ) Borealis Oil Pool injection wells. North Slope, Alaska June 20, 2013 By letter dated May 14, 2013, BP Exploration (Alaska) Inc. (BPXA) requested administrative approval to introduce radioactive tracers into the Gathering Center 2 (GC2) production facility for the purpose of facility optimization. After passing through the production facility the radioactive tracers would be entrained in the produced water injection system and injected in enhanced oil recovery and disposal wells. Radioactive tracers are not regulated by the Resource Conservation and Recovery Act (RCRA). The volume of radioactive tracer material will be exceedingly small in proportion to the millions of gallons of produced water that GC2 handles on a daily basis. The half-life of the proposed tracers is less than two days. The exceedingly small volume and low concentration of the radioactive tracer material in the produced water stream will have no impact on its performance as an enhanced oil recovery injectant, and will not result in any formation or reservoir fluid compatibility issues. Therefore, amending the list of approved fluids to include radioactive tracer fluids introduced to production facilities is appropriate. NOW THEREFORE IT IS ORDERED THAT: Rule 2 of AIO 24B is repealed and replaced by the following: Rule 2. Authorized Injection Fluids The fluids authorized by this Order for injection are as follows: a) Produced water and gas from Prudhoe Bay Unit processing facilities; b) Enriched hydrocarbon gas; c) Non -hazardous water and water based fluids — (specifically seawater, source water, freshwater, domestic wastewater, equipment washwater, sump fluids, hydrotest fluids, firewater, and water with trace chemicals, and other water based AIO 2B-004 June 20, 2013 Page 2 of 2 fluids with a pH greater than 2 and less than 12.5 and flashpoint greater than 140 degrees F); d) Fluids introduced to production facilities for the purpose of oil production, plant operations, plant/piping integrity or well maintenance that become entrained in the produced water stream after oil, gas, and water separation in the facility. Specifically: i. Freeze protection fluids; ii. Fluids in mixtures of oil sent for hydrocarbon recycle; iii. Corrosion/scale inhibitor fluids; iv. Anti-foams/emulsion breakers; V. Glycols; vi. Radioactive tracer survey fluids e) Non -hazardous glycols and glycol mixtures; f) Fluids that are used for their intended purpose within the oil production process. Specifically: i. Scavengers; ii. Biocides g) Fluids to monitor or enhance reservoir performance. i. Tracer survey fluids; ii. Well stimulation fluids; iii. Reservoir profile modification fluids. DONE at Anchorage, Alaska and da dun�' 20, 2,013. Daniel T.�S� eamount, Jr. �o /' Norman Commissioner l�dir�m. sioner Specifically: RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[tlhe questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. l� Singh. Angela K (DOA) From: Fisher, Samantha J (DOA) Sent: Thursday, June 20, 2013 1:20 PM To: (michael j.nelson@conocophillips.com); AKDCWeIIIntegrityCoordinator, alaska@petrocalc.com; Alexander Bridge; Andrew VanderJack, Anna Raff; Barbara F Fullmer; bbritch; bbohrer@ap.org; Bill Penrose; Bill Walker, Bowen Roberts; Brian Havelock; caunderwood@marathonoil.com; Cliff Posey; Crandall, Krissell; D Lawrence; Dave Harbour, Dave Matthews; David Boelens; David Duffy, David House; David Scott; David Steingreaber; Davide Simeone; ddonkel@cfl.rr.com; Donna Ambruz; Dowdy, Alicia G (DNR); Dudley Platt; Elowe, Kristin; Francis S. Sommer, Gary Laughlin; schultz, gary (DNR sponsored); ghammons; Gordon Pospisil; Gorney, David L.; Greg Duggin; Gregg Nady; Gregory Geddes; gspfoff; Jdarlington oarlington@gmail.com); Jeanne McPherren; Jones, Jeffery B (DOA); Jerry McCutcheon; Jim White; Jim Winegarner; Joe Lastufka; news@radiokenai.com; Burdick, John D (DNR); Easton, John R (DNR); John Evans; John Garing; Jon Goltz; Jones, Jeffrey L (GOV); Juanita Lovett; Judy Stanek, Houle, Julie (DNR); Julie Little; Kari Moriarty; Kaynell Zeman; Keith Wiles; Kelly Sperback; Gregersen, Laura S (DNR); Luke Keller, Marc Kovak; Dalton, Mark (DOT sponsored); Mark Hanley (mark.hanley@anadarko.com); Mark P. Worcester; Kremer, Marguerite C (DNR); Michael Jacobs; Mike Bill; mike@kbbi.org; Mikel Schultz; Mindy Lewis; MJ Loveland; mjnelson; mkm7200; knelson@petroleumnews.com; Nick W. Glover, Nikki Martin; NSK Problem Well Supv; Patty Alfaro; Decker, Paul L (DNR); Paul Mazzolini; Pike, Kevin W (DNR); Pioneer; Randall Kanady; Randy L. Skillern; Randy Redmond; Rena Delbridge; Renan Yanish; Robert Brelsford; Robert Campbell; Ryan Tunseth; Sara Leverette; Scott Cranswick; Scott Griffith; Shannon Donnelly; Sharmaine Copeland; Sharon Yarawsky; Shellenbaum, Diane P (DNR); Slemons, Jonne D (DNR); Smith, Kyle S (DNR); Sondra Stewman; Stephanie Klemmer; Moothart, Steve R (DNR); Steven R. Rossberg; Suzanne Gibson; Sheffield@aoga.org; Tania Ramos; Ted Kramer, Davidson, Temple (DNR); Teresa Imm; Thor Cutler, Tim Mayers; Tina Grovier; Todd Durkee; Tony Hopfinger; trmjr1; Vicki Irwin; Walter Featherly; yjrosen@ak.net; Aaron Gluzman; Aaron Sorrell; Bruce Williams; Bruno, Jeff J (DNR); Casey Sullivan; David Lenig; Donna Vukich; Eric Lidji; Erik Opstad; Franger, James M (DNR); Gary Orr, Smith, Graham O (PCO); Greg Mattson; Heusser, Heather A (DNR); James Rodgers; Jason Bergerson; Jennifer Starck; jill.a.mcleod@conocophillips.com; Jim Magill; Joe Longo; Jolie Pollet; King, Kathleen J (DNR); Laney Vasquez, Lois Epstein; Louisiana Cutler, Marc Kuck; Steele, Marie C (DNR); Matt Gill; Ostrovsky, Larry (DNR sponsored); Bettis, Patricia K (DOA); Perrin, Don J (DNR); Peter Contreras; Pexton, Scott R (DNR); Pollard, Susan R (LAW); Richard Garrard; Ryan Daniel; Sandra Lemke; Talib Syed; Wayne Wooster, Woolf, Wendy C (DNR); William Hutto; William Van Dyke; Ballantine, Tab A (LAW); Bender, Makana K (DOA); Bettis, Patricia K (DOA); Brooks, Phoebe L (DOA); Colombie, Jody J (DOA); Crisp, John H (DOA); Davies, Stephen F (DOA); Ferguson, Victoria L (DOA); Fisher, Samantha J (DOA); Foerster, Catherine P (DOA); Grimaldi, Louis R (DOA); Hunt, Jennifer L (DOA); Johnson, Elaine M (DOA); Laasch, Linda K (DOA); Mumm, Joseph (DOA sponsored); Noble, Robert C (DOA); Norman, John K (DOA); Okland, Howard D (DOA); Paladijczuk, Tracie L (DOA); Pasqual, Maria (DOA); Regg, James B (DOA); Roby, David S (DOA); Scheve, Charles M (DOA); Schwartz, Guy L (DOA); Seamount, Dan T (DOA); Singh, Angela K (DOA); Turkington, Jeff A (DOA); Wallace, Chris D (DOA) Subject: AIO 3A.002, AIO 26B.002, AIO 25A.016, AIO 24B.004, AIO 22E.002 (Prudhoe Bay Unit) Attachments: aio3a-002.pdf, aio26b-002.pdf, aio25a-016.pdf, aio24b-004.pdf, aio22e-002.pdf Samantha Fisher Executive Secretary II Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue, Suite 100 Anchorage, AK 99501 (907) 793-1223 (phone) (907) 276-7542 (fax) Easy Peel® Labels i A Bend along line to I Q AVERY® 596OTM ; Use Avery® Template 51600 �� Feed Paper ® expose Pop-up Edgerm• 1 L_Q_ 2,� ( 2_'t.' V3 Q>c Alison Cooke UIC Compliance Advisor BP Exploration (Alaska)Inc. Post Office Box 196612 Anchorage, AK 99519-6612 hiquettes faciles 6 peter i A Repllez h la hachure afin de ; www.avery.com Utilisez le gabarit AVERY® 51600 ; lhsena ftn+ r6v6ler le rebord Poo'uoTm ! t-Rnn.c n.AVFRv Easy Peel® Labels Use Avery® Template 51604D Penny Vadla 399 W. Riverview Ave. Soldotna, AK 99669-7714 Jerry Hodgden Hodgden Oil Company 40818`h St. Golden, CO 80401-2433 Bernie Karl K&K Recycling Inc. Post Office Box 58055 Fairbanks, AK 99711 North Slope Borough Planning Department Post Office Box 69 Barrow, AK 99723 Jack Hakkila Post Office Box 190083 Anchorage, AK 99519 A Bend along line to AVERY® 5960TM Feed Paper expose Pop-up EdgeTm David McCaleb IHS Energy Group George Vaught, Jr. GEPS Post Office Box 13557 5333 Westheimer, Ste. 100 Denver, CO 80201-3557 Houston, TX 77056 Richard Neahring Mark Wedman NRG Associates Halliburton President 6900 Arctic Blvd. Post Office Box 1655 Anchorage, AK 99502 Colorado Springs, CO 80901 CIRI Baker Oil Tools Land Department 795 E. 94`h Ct. Post Office Box 93330 Anchorage, AK 99515-4295 Anchorage, AK 99503 Richard Wagner Gordon Severson Post Office Box 60868 3201 Westmar Cir. Fairbanks, AK 99706 Anchorage, AK 99508-4336 Darwin Waldsmith James Gibbs Post Office Box 39309 Post Office Box 1597 Ninilchik, AK 99639 Soldotna, AK 99669 ftiquettes faciles a peter ; A Repliez a la hachure afin de ; vlrww.averycom I itilisei le nabarit AVERY® 5160 Sens de 1-Bo0.co-AVERY r6v6ler le rebord Poo-uoT� ! � �h�rwa�nnnt THE STATE 'ALASKA GOVERNOR BILL WALKER Mr. Oliver Sternicki CORRECTED ADMINISTRATIVE APPROVAL Alaska Oil and Gas Conservation Commission AREA INJECTION ORDER NO. 24.004 (Cancelled) AREA INJECTION ORDER NO. 2413.005 Well Integrity Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Docket Number: AIO-16-007 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov Request for administrative approval to amend conditions of AIO 24.004 that allow well L-105 (PTD 2020580) to be online in water alternating gas (WAG) injection service with an outer annulus (OA) repressurization. Prudhoe Bay Unit (PBU) L-105 (PTD 2020580) Prudhoe Bay Field Borealis Oil Pool Dear Mr. Sternicki: By letter dated February 19, 2016, received on February 29, 2016, BP Exploration (Alaska), Inc. (BPXA) requested administrative approval to amend conditions of AIO 24.004 and continue WAG injection in the subject well. In accordance with Rule 9 of Area Injection Order (AIO) 24B.000, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS BPXA's request for administrative approval to continue WAG injection in the subject well. AA AIO 24.004 is no longer necessary to the operation of L-105 and is hereby CANCELLED. Injection into PBU L-105 will be governed by provisions of AIO No. 2413.005. AIO No. 24A superseded AIO 24 on April 22, 2005. AIO No. 24B superseded AIO 24A on January 30, 2008. BPXA completed a passing state witnessed Mechanical Integrity Test of the Inner Annulus (MITIA) on January 9, 2016 which indicates that L-105 exhibits at least two competent barriers to the release of well pressure. Accordingly, the AOGCC believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AIO 24B.005 March 8, 2016 Page 2 of 2 AOGCC's approval to continue WAG injection in PBU L-105 is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli. Bleeds to be flagged on the report; 3. BPXA shall perform a mechanical integrity test of the inner annulus every two (2) years to 4000 psi; 4. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 5. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 6. The MIT anniversary date is January 9, 2016. "�' > DONE at Anchorage, Alaska and dajpEWarch 8, 2016. &ter�Seamount, PCathy P Daniel T. Jr. ,, '�• Chair, ommissioner Commissioner `�•�?,.,, �' TION AND APPEAL As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which die AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. THE STATE 'ALASKA GOVERNOR BILL WALKER Mr. Oliver Sternicki CORRECTED ADMINISTRATIVE APPROVAL Alaska Oil and Gas Conservation Commission AREA INJECTION ORDER NO. 24.004 (Cancelled) AREA INJECTION ORDER NO. 2411.005 Well Integrity Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Docket Number: AIO-16-007 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Request for administrative approval to amend conditions of AIO 24.004 that allow well L-105 (PTD 2020580) to be online in water alternating gas (WAG) injection service with an outer annulus (OA) repressurization. Prudhoe Bay Unit (PBU) L-105 (PTD 2020580) Prudhoe Bay Field Borealis Oil Pool Dear Mr. Sternicki: By letter dated February 19, 2016, received on February 29, 2016, BP Exploration (Alaska), Inc. (BPXA) requested administrative approval to amend conditions of AIO 24.004 and continue WAG injection in the subject well. In accordance with Rule 9 of Area Injection Order (AIO) 24B.000, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS BPXA's request for administrative approval to continue WAG injection in the subject well. AA AIO 24.004 is no longer necessary to the operation of L-105 and is hereby CANCELLED. Injection into PBU L-105 will be governed by provisions of AIO No. 2411.005. AIO No. 24A superseded AIO 24 on April 22, 2005. AIO No. 24B superseded AIO 24A on January 30, 2008. BPXA completed a passing state witnessed Mechanical Integrity Test of the Inner Annulus (MITIA) on January 9, 2016 which indicates that L-105 exhibits at least two competent barriers to the release of well pressure. Accordingly, the AOGCC believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AIO 24B.005 March 8, 2016 Page 2 of 2 AOGCC's approval to continue WAG injection in PBU L-105 is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli. Bleeds to be flagged on the report; 3. BPXA shall perform a mechanical integrity test of the inner annulus every two (2) years to 4000 psi; 4. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 5. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 6. The MIT anniversary date is January 9, 2016.r.r�CWL DONE at Anchorage, Alaska and dated March 8, 2016. //signature on fileH //signature on fileH Cathy P. Foerster Daniel T. Seamount, Jr. Chair, Commissioner Commissioner RECONSIDERATION AND As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Singh, Angela K (DOA) From: Carlisle, Samantha J (DOA) Sent: Wednesday, March 09, 2016 3:44 PM To: Ballantine, Tab A (LAW); Bender, Makana K (DOA); Bettis, Patricia K (DOA); Bixby, Brian D (DOA); Brooks, Phoebe L (DOA); Carlisle, Samantha 1 (DOA); Colombie, Jody J (DOA); Cook, Guy D (DOA); Davies, Stephen F (DOA); Eaton, Loraine E (DOA); Foerster, Catherine P (DOA); Frystacky, Michal (DOA); Grimaldi, Louis R (DOA); Guhl, Meredith D (DOA); Herrera, Matthew F (DOA); Hill, Johnnie W (DOA); Jones, Jeffery B (DOA); Kair, Michael N (DOA); Link, Liz M (DOA); Loepp, Victoria T (DOA); Mumm, Joseph (DOA sponsored); Noble, Robert C (DOA); Paladijczuk, Tracie L (DOA); Pasqual, Maria (DOA); Quick, Michael J (DOA); Regg, James B (DOA); Roby, David S (DOA); Scheve, Charles M (DOA); Schwartz, Guy L (DOA); Seamount, Dan T (DOA); Singh, Angela K (DOA); Wallace, Chris D (DOA); AKDCWellIntegrityCoordinator, Alan Bailey; Alex Demarban; Alexander Bridge; Allen Huckabay; Amanda Tuttle; Andrew Vandedack, Anna Raff; Barbara F Fullmer, bbritch; bbohrer@ap.org; Bob Shavelson; Brian Havelock; Bruce Webb; Burdick, John D (DNR); Caleb Conrad; Cliff Posey; Colleen Miller; Crandall, Krissell; D Lawrence; Dave Harbour; David Boelens; David Duffy; David House; David McCaleb; David Steingreaber; David Tetta; ddonkel@cfl.rr.com; Dean Gallegos; Delbridge, Rena E (LAS); DNROG Units (DNR sponsored); Donna Ambruz; Ed Jones; Elowe, Kristin; Evans, John R (LDZX); Frank Molli; Gary Oskolkosf, George Pollock, Gordon Pospisil; Gregg Nady; gspfoff, Hyun, James J (DNR); Jacki Rose; Jdarlington Oarlington@gmail.com); Jeanne McPherren; Jerry Hodgden; Jerry McCutcheon; Jim Watt; Jim White; Joe Lastufka; Radio Kenai; Easton, John R (DNR); Jon Goltz; Juanita Lovett; Judy Stanek, Houle, Julie (DNR); Julie Little; Karen Thomas; Kari Moriarty; Kazeem Adegbola; Keith Wiles; Kelly Sperback; Gregersen, Laura S (DNR); Leslie Smith; Louisiana Cutler, Luke Keller, Marc Kovak; Dalton, Mark (DOT sponsored); Mark Hanley (mark.hanley@anadarko.com); Mark Landt; Mark Wedman; Kremer, Marguerite C (DNR); Mary Cocklan-Vendl; Mealear Tauch; Michael Calkins; Michael Duncan; Michael Moora; Mike Bill; MJ Loveland; mkm7200; Morones, Mark P (DNR); Munisteri, Islin W M (DNR); knelson@petroleumnews.com; Nichole Saunders; Nick W. Glover, Nikki Martin; NSK Problem Well Supv; Oliver Sternicki; Patty Alfaro; Paul Craig; Decker, Paul L (DNR); Paul Mazzolini; Pike, Kevin W (DNR); Randall Kanady; Randy L. Skillern; Renan Yanish; Richard Cool; Robert Brelsford; Ryan Tunseth; Sara Leverette; Scott Griffith; Shannon Donnelly; Sharmaine Copeland; Sharon Yarawsky; Shellenbaum, Diane P (DNR); Skutca, Joseph E (DNR); Smart Energy Universe; Smith, Kyle S (DNR); Sondra Stewman; Stephanie Klemmer; Stephen Hennigan; Moothart, Steve R (DNR); Suzanne Gibson; sheffield@aoga.org; Tania Ramos; Ted Kramer; Davidson, Temple (DNR); Terence Dalton; Teresa Imm; Thor Cutler; Tim Mayers; Todd Durkee; trmjrl; Tyler Senden; Vicki Irwin; Vinnie Catalano; Aaron Gluzman; Aaron Sorrell; Ajibola Adeyeye; Alan Dennis; Andrew Cater, Anne Hillman; Brian Gross; Bruce Williams; Bruno, Jeff J (DNR); Caroline Bajsarowicz, Casey Sullivan; Diane Richmond; Don Shaw; Donna Vukich; Eric Lidji; Garrett Haag; Smith, Graham O (DNR); Dickenson, Hak K (DNR); Heusser, Heather A (DNR); Holly Pearen; Jason Bergerson; Jim Magill; Joe Longo; John Martineck; Josh Kindred; Kenneth Luckey; King, Kathleen 1 (DNR); Laney Vazquez; Lois Epstein; Longan, Sara W (DNR); Marc Kuck; Marcia Hobson; Steele, Marie C (DNR); Matt Armstrong; Franger, James M (DNR); Morgan, Kirk A (DNR); Pat Galvin; Pete Dickinson; Peter Contreras; Richard Garrard; Robert Province; Ryan Daniel; Sandra Lemke; Pollard, Susan R (LAW); Talib Syed; Terence Dalton; Tina Grovier (tmgrovier@stoel.com); Todd, Richard 1 (LAW); Tostevin, Breck C (LAW); Wayne Wooster, William Van Dyke Subject: Area Injection Order 24.004 (Canceled) and 25B.005 (Corrected) (PBU, BPXA) Attachments: aio24-004 canceled.pdf, aio24b-005 corrected.pdf Please see attached. Samantha Carlisle Executive Secretary III Alaska Oil and Gas Conservation Commission 333 West 711, Avenue Anchorage, AK 99501 (907)793-1223 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Samantha Carlisle at (907) 793-1223 or Samantha.Carlisle@alaska.ggv. James Gibbs Jack Hakkila Bernie Karl P.O. Box 1597 P.O. Box 190083 K&K Recycling Inc. Soldotna, AK 99669 Anchorage, AK 99519 P.O. Box 58055 Fairbanks, AK 99711 Gordon Severson Penny Vadla George Vaught, Jr. 3201 Westmar Cir. 399 W. Riverview Ave. P.O. Box 13557 Anchorage, AK 99508-4336 Soldotna, AK 99669-7714 Denver, CO 80201-3557 Mr. Oliver Sternicki Richard Wagner Darwin Waldsmith Well Integrity Engineer P.O. Box 60868 P.O. Box 39309 BP Exploration (Alaska), Inc. Fairbanks, AK 99706 Ninilchik, AK 99639 P.O. Box 196612 Anchorage, AK 99519-6612 \A« —acct Vo t 20\Lv,- Angela K. Singh THE STATE °'ALASKA GOVERNOR BILL WALKER Mr. Oliver Sternicki Alaska Oil and Gas Conservation Commission ADMINISTRATIVE APPROVAL AREA INJECTION ORDER NO. 2413.005 Well Integrity Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Docket Number: AIO-16-007 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.cogcc.alaska.gov Request for administrative approval to amend conditions of AIO 24.004 that allow well L-105 (PTD 2020580) to be online in water alternating gas (WAG) injection service with an outer annulus (OA) repressurization. Prudhoe Bay Unit (PBU) L-105 (PTD 2020580) Prudhoe Bay Field Borealis Oil Pool Dear Mr. Sternicki: By letter dated February 19, 2016, received on February 29, 2016, BP Exploration (Alaska), Inc. (BPXA) requested administrative approval to amend conditions of AIO 24.004 and continue WAG injection in the subject well. In accordance with Rule 9 of Area Injection Order (AIO) 2413.000, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS BPXA's request for administrative approval to continue WAG injection in the subject well. AA AIO 24.004 is no longer necessary to the operation of L-105 and is hereby CANCELLED. Injection into PBU L-105 will be governed by provisions of AIO No. 2413.005. AIO No. 24A superseded AIO 24 on April 22, 2005. AIO No. 24B superseded AIO 24A on January 30, 2008. BPXA completed a passing state witnessed Mechanical Integrity Test of the Inner Annulus (MITIA) on April 3, 2015 which indicates that L-105 exhibits at least two competent barriers to the release of well pressure. Accordingly, the AOGCC believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AIO 24B.005 March 4, 2016 Page 2 of 2 AOGCC's approval to continue WAG injection in PBU L-105 is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli. Bleeds to be flagged on the report; 3. BPXA shall perform a mechanical integrity test of the inner annulus every two (2) years to 4000 psi; 4. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 5. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 6. The MIT anniversary date is April 3, 2015. DONE at Anchorage, Alaska and dated March 4, 2016. 1�t 4Mil Cath P. Foerster D ' IT Sedjnount, Jr. Chair, Commissioner Commissioner RECONSIDERATION AND APPEAL As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which die AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. THE STAIT. °1ALASK--A- GOVERNOR DILL NVALKER Mr. Oliver Sternicki Alaska Oil and Gas Conservation Commission ADMINISTRATIVE APPROVAL AREA INJECTION ORDER NO. 24B.005 Well Integrity Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Docket Number: AIO-16-007 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 aogcc.alaska.gov Request for administrative approval to amend conditions of AIO 24.004 that allow well L-105 (PTD 20205 80) to be online in water alternating gas (WAG) injection service with an outer annulus (OA) repressurization. Prudhoe Bay Unit (PBU) L-105 (PTD 2020580) Prudhoe Bay Field Borealis Oil Pool Dear Mr. Sternicki: By letter dated February 19, 2016, received on February 29, 2016, BP Exploration (Alaska), Inc. (BPXA) requested administrative approval to amend conditions of AIO 24.004 and continue WAG injection in the subject well. In accordance with Rule 9 of Area Injection Order (AIO) 24B.000, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS BPXA's request for administrative approval to continue WAG injection in the subject well. AA AIO 24.004 is no longer necessary to the operation of L-105 and is hereby CANCELLED. Injection into PBU L-105 will be governed by provisions of AIO No. 24B.005. AIO No. 24A superseded AIO 24 on April 22, 2005. AIO No. 24B superseded AIO 24A on January 30, 2008. BPXA completed a passing state witnessed Mechanical Integrity Test of the Inner Annulus (MITIA) on April 3, 2015 which indicates that L-105 exhibits at least two competent barriers to the release of well pressure. Accordingly, the AOGCC believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AIO 24B.005 March 4, 2016 Page 2 of 2 AOGCC's approval to continue WAG injection in PBU L-105 is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli. Bleeds to be flagged on the report; 3. BPXA shall perform a mechanical integrity test of the inner annulus every two (2) years to 4000 psi; 4. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 5. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 6. The MIT anniversary date is April 3, 2015. DONE at Anchorage, Alaska and dated March 4, 2016. //signature on file// //signature on file// Cathy P. Foerster Daniel T. Seamount, Jr. Chair, Commissioner Commissioner RECONSIDERATION AND APPEAL As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Friday, March 04, 2016 9:36 AM To: 'Ballantine, Tab A (LAW) (tab.ballantine@alaska.gov)'; 'Bender, Makana K (DOA) (makana.bender@alaska.gov)'; 'Bettis, Patricia K (DOA) (patricia.bettis@alaska.gov)'; 'Bixby, Brian D (DOA)'; 'Brooks, Phoebe L (DOA) (phoebe.brooks@alaska.gov)'; Carlisle, Samantha J (DOA); 'Colombie, Jody J (DOA) Oody.colombie@alaska.gov)'; 'Cook, Guy D (DOA)'; 'Davies, Stephen F (DOA) (steve.davies@alaska.gov)'; Eaton, Loraine E (DOA); Toerster, Catherine P (DOA) (cathy.foerster@alaska.gov)'; Trystacky, Michal (michal.frystacky@alaska.gov)'; 'Grimaldi, Louis R (DOA) (lou.grimaldi@alaska.gov)'; 'Guhl, Meredith (DOA sponsored) (meredith.guhl@alaska.gov)'; Herrera, Matthew F (DOA); 'Hill, Johnnie W (DOA)'; 'Jones, Jeffery B (DOA) Oeffjones@alaska.gov)'; Kair, Michael N (DOA); 'Link, Liz M (DOA)'; Loepp, Victoria T (DOA); 'Mumm, Joseph (DOA sponsored) Ooseph.mumm@alaska.gov)'; 'Noble, Robert C (DOA) (bob.noble@alaska.gov)'; 'Paladijczuk, Tracie L (DOA) (tracie.paladijczuk@alaska.gov)'; 'Pasqual, Maria (DOA) (maria.pasqual@alaska.gov)'; 'Quick, Michael (DOA sponsored)'; 'Regg, James B (DOA) Oim.regg@alaska.gov)'; 'Roby, David S (DOA) (dave.roby@alaska.gov)'; 'Scheve, Charles M (DOA) (chuck.scheve@alaska.gov)'; 'Schwartz, Guy L (DOA) (guy.schwartz@alaska.gov)'; 'Sea mount, Dan T (DOA) (dan.seamount@alaska.gov)'; 'Singh, Angela K (DOA) (angela.singh@alaska.gov)'; 'Wallace, Chris D (DOA) (chris.wallace@alaska.gov)'; 'Aaron Gluzman'; 'Aaron Sorrell'; Ajibola Adeyeye; Alan Dennis; Andrew Cater, Anne Hillman; Bajsarowicz, Caroline J; Brian Gross; 'Bruce Williams'; Bruno, Jeff J (DNR); Casey Sullivan; David Tetta; 'Don Shaw'; 'Donna Vukich'; Eric Lidji; Garrett Haag; 'Graham Smith'; Hak Dickenson; Heusser, Heather A (DNR); Holly Pearen; Hyun, James J (DNR); 'Jason Bergerson'; 'Jim Magill'; Joe Longo; John Martineck; Josh Kindred; Kenneth Luckey; King, Kathleen J (DNR); Laney Vazquez; Lois Epstein; Longan, Sara W (DNR); 'Louisiana Cutler'; Marc Kuck; Marcia Hobson; 'Marie Steele'; Matt Armstrong; 'Mike Franger'; Morgan, Kirk A (DNR); Pat Galvin; 'Pete Dickinson'; Peter Contreras; Richard Garrard; Richmond, Diane M; Robert Province; 'Ryan Daniel'; 'Sandra Lemke'; 'Susan Pollard'; Talib Syed; Terence Dalton; Tina Grovier (tmgrovier@stoel.com); Todd, Richard J (LAW); Tostevin, Breck C (LAW); 'Wayne Wooster'; 'William Van Dyke'; 'AKDCWellIntegrityCoordinator'; 'Alan Bailey'; 'Alex Demarban'; 'Alexander Bridge'; 'Allen Huckabay'; 'Amanda Tuttle'; 'Andrew VanderJack'; 'Anna Raff'; 'Barbara F Fullmer'; 'bbritch'; 'Becky Bohrer'; 'Bob Shavelson'; 'Brian Havelock'; 'Bruce Webb'; Burdick, John D (DNR); 'Caleb Conrad'; 'Cliff Posey'; 'Colleen Miller'; 'Crandall, Krissell'; 'D Lawrence'; 'Dave Harbour'; 'David Boelens'; 'David Duffy'; 'David House'; 'David McCaleb'; 'David Steingreaber'; 'ddonkel@cfl.rr.com'; 'Dean Gallegos'; Delbridge, Rena E (LAS); DNROG Units (DNR sponsored); 'Donna Ambruz'; 'Ed Jones'; 'Elowe, Kristin'; 'Evans, John R (LDZX)'; 'Frank Molli'; 'Gary Oskolkosf'; 'George Pollock'; 'Gordon Pospisil'; 'Gregg Nady'; 'gspfoff'; 'Jacki Rose'; 'Jdarlington Oarlington@gmail.com)'; 'Jeanne McPherren'; 'Jerry Hodgden'; 'Jerry McCutcheon'; 'Jim Watt'; 'Jim White'; 'Joe Lastufka'; 'Joe Nicks'; 'John Easton'; 'Jon Goltz'; 'Juanita Lovett'; 'Judy Stanek'; 'Julie Houle'; 'Julie Little'; 'Karen Thomas'; 'Kari Moriarty'; 'Kazeem Adegbola'; 'Keith Wiles'; 'Kelly Sperback'; 'Laura Silliphant (laura.gregersen@alaska.gov)'; 'Leslie Smith'; 'Luke Keller'; 'Marc Kovak'; 'Mark Dalton'; 'Mark Hanley (mark.hanley@anadarko.com)'; 'Mark Landt'; 'Mark Wedman'; 'Marquerite kremer (meg.kremer@alaska.gov)'; 'Mary Cocklan-Vendl'; 'Mealear Tauch'; 'Michael Calkins'; 'Michael Duncan'; 'Michael Moora'; 'Mike Bill'; 'MJ Loveland'; 'mkm7200'; Morones, Mark P (DNR); Munisteri, Islin W M (DNR); 'nelson'; 'Nichole Saunders'; 'Nick W. Glover'; 'Nikki Martin'; 'NSK Problem Well Supv'; 'Oliver Sternicki'; 'Patty Alfaro'; 'Paul Craig'; 'Paul Decker (paul.decker@alaska.gov)'; 'Paul Mazzolini'; Pike, Kevin W (DNR); 'Randall To: Kanady'; 'Randy L. Skillern'; 'Renan Yanish'; 'Richard Cool'; 'Robert Brelsford'; 'Ryan Tunseth'; 'Sara Leverette'; 'Scott Griffith'; 'Shannon Donnelly'; 'Sharmaine Copeland'; 'Sharon Yarawsky'; Shellenbaum, Diane P (DNR); Skutca, Joseph E (DNR); Smart Energy Universe; Smith, Kyle S (DNR); Sondra Stewman; 'Stephanie Klemmer'; 'Stephen Hennigan'; Steve Moothart (steve.moothart@alaska.gov); 'Suzanne Gibson'; Tamera Sheffield; 'Tania Ramos'; 'Ted Kramer'; Temple Davidson; Teresa Imm; Thor Cutler; 'Tim Mayers'; Todd Durkee; trmjrl; 'Tyler Senden'; Vicki Irwin; Vinnie Catalano Subject: AIO 2413-005 Attachments: aio24b.005.pdf James Gibbs Jack Hakkila Bernie Karl P.O. Box 1597 P.O. Box 190083 K&K Recycling Inc. Soldotna, AK 99669 Anchorage, AK 99519 P.O. Box 58055 Fairbanks, AK 99711 Gordon Severson Penny Vadla George Vaught, Jr. 3201 Westmar Cir. 399 W. Riverview Ave. P.O. Box 13557 Anchorage, AK 99508-4336 Soldotna, AK 99669-7714 Denver, CO 80201-3557 Mr. Oliver Sternicki Richard Wagner Darwin Waldsmith Well Integrity Engineer P.O. Box 60868 P.O. Box 39309 BP Exploration (Alaska), Inc. Fairbanks, AK 99706 Ninilchik, AK 99639 P.O. Box 196612 Anchorage, AK 99519-6612 Angela K. Singh THE STATE (ALASKA GOVERNOR BILL WALKER Alaska Oil and Gas Conservation Commission ADMINISTRATIVE APPROVAL AREA INJECTION ORDER NO. 24B.005 Amended Mr. Ryan Daniel Well Integrity Engineering Team Lead BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Docket Number: AIO-17-002 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Request for administrative approval to amend conditions of AIO 2413.005 that allow well L-105 (PTD 2020580) to be online in water alternating gas (WAG) injection service with an outer annulus (OA) repressurization. Prudhoe Bay Unit (PBU) L-105 (PTD 2020580) Prudhoe Bay Field Borealis Oil Pool Dear Mr. Daniel: By letter dated January 10, 2017, BP Exploration (Alaska), Inc. (BPXA) requested administrative approval to amend conditions of AIO 2413.005 and continue WAG injection in the subject well. In accordance with Rule 9 of Area Injection Order (AIO) 2413.000, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS BPXA's request for administrative approval to continue WAG injection in the subject well. BPXA completed a passing state witnessed Mechanical Integrity Test of the Inner Annulus (MITIA) on January 9, 2017 which indicates that L-105 exhibits at least two competent barriers to the release of well pressure. Accordingly, the AOGCC believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AIO 24B.005 Amended January 25, 2017 Page 2 of 2 AOGCC's approval to continue WAG injection in PBU L-105 is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli. Bleeds to be flagged on the report; 3. BPXA shall perform a mechanical integrity test of the inner annulus every two (2) years to 4. 5. 6. 7. 4000 psi; BPXA shall limit the well's IA operating pressure to 2000 psi and the OA operating pressure to 1500 psi; BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and The MIT anniversary date is January 9, 2017. DONE at Anchorage, Alaska and dated January 25, 2017. �41 Cathy/. Foerster Chair, Commissioner -.14 Daniel T. Seamount, Jr. Commissioner Commissioner AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. T1 -I1: STATI., °'ALASKA (,,)\1.RW,t latt_t, !%`A€KFR Alaska Oil and Gas Conservation Commission ADMIMSTRATIVE APPROVAL AREA INJECTION ORDER NO. 24B.005 Amended Mr. Ryan Daniel Well Integrity Engineering Team Lead BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Docket Number: AIO-17-002 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 aogcc.alaska.gov Request for administrative approval to amend conditions of AIO 24B.005 that allow well L-105 (PTD 20205 80) to be online in water alternating gas (WAG) injection service with an outer annulus (OA) repressurization. Prudhoe Bay Unit (PBU) L-105 (PTD 2020580) Prudhoe Bay Field Borealis Oil Pool Dear Mr. Daniel: By letter dated January 10, 2017, BP Exploration (Alaska), Inc. (BPXA) requested administrative approval to amend conditions of AIO 24B.005 and continue WAG injection in the subject well. In accordance with Rule 9 of Area Injection Order (AIO) 24B.000, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS BPXA's request for administrative approval to continue WAG injection in the subject well. BPXA completed a passing state witnessed Mechanical Integrity Test of the Inner Annulus (MITIA) on January 9, 2017 which indicates that L-105 exhibits at least two competent barriers to the release of well pressure. Accordingly, the AOGCC believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AIO 24B.005 Amended January 25, 2017 Page 2 of 2 AOGCC's approval to continue WAG injection in PBU L-105 is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli. Bleeds to be flagged on the report; 3. BPXA shall perform a mechanical integrity test of the inner annulus every two (2) years to 4000 psi; 4. BPXA shall limit the well's lA oyeratine pressure to 2000 psi and the OA operating pressure to 1500 psi; 5. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 6. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 7. The MIT anniversary date is January 9, 2017. DONE at Anchorage, Alaska and dated January 25, 2017. //signature on file// Cathy P. Foerster Chair, Commissioner //signature on file// Daniel T. Seamount, Jr. Commissioner //signature on file// Hollis French Commissioner RECONSIDERATION AND APPEAL NOTICE SOI z ' ATrON As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Wednesday, January 25, 2017 2:37 PM To: aogcc.inspectors@alaska.gov, 'Bender, Makana K (DOA) (makana.bender@alaska.gov)'; 'Bettis, Patricia K (DOA) (patricia.bettis@alaska.gov)'; 'Brooks, Phoebe L (DOA) (phoebe.brooks@alaska.gov)'; Carlisle, Samantha J (DOA); 'Colombie, Jody J (DOA) Oody.colombie@alaska.gov)'; 'Davies, Stephen F (DOA) (steve.davies@alaska.gov)'; Eaton, Loraine E (DOA); 'Foerster, Catherine P (DOA) (cathy.foerster@alaska.gov)'; 'French, Hollis (DOA)'; Trystacky, Michal (michal.frystacky@alaska.gov)'; 'Guhl, Meredith (DOA sponsored) (meredith.guhl@alaska.gov)'; Kair, Michael N (DOA); 'Link, Liz M (DOA)'; Loepp, Victoria T (DOA); 'Mumm, Joseph (DOA sponsored) Ooseph.mumm@alaska.gov)'; 'Pa lad ijczu k, Tracie L (DOA) (tracie.pa lad ijczu k@a laska.gov)'; 'Pasqua 1, Maria (DOA) (maria.pasqual@alaska.gov)'; 'Quick, Michael (DOA sponsored)'; 'Regg, James B (DOA) Oim.regg@alaska.gov)'; 'Roby, David S (DOA) (dave.roby@alaska.gov)'; 'Schwartz, Guy L (DOA) (guy.schwartz@alaska.gov)'; 'Seamount, Dan T (DOA) (dan.seamount@alaska.gov)'; Singh, Angela K (DOA); 'Wallace, Chris D (DOA) (chris.wallace@alaska.gov)'; AK, GWO Projects Well Integrity; 'AKDCWellIntegrityCoordinator'; 'Alan Bailey'; 'Alex Demarban'; 'Alexander Bridge'; 'Allen Huckabay'; 'Andrew VanderJack'; 'Ann Danielson'; Anna Raff; 'Barbara F Fullmer'; bbritch; Becky Bohrer; 'Ben Boettger'; 'Bill Bredar'; Bob; Brandon Viator; 'Brian Havelock'; 'Bruce Webb'; 'Caleb Conrad'; 'Candi English'; Cocklan- Vendl, Mary E; Colleen Miller, 'Connie Downing'; Crandall, Krissell; 'D Lawrence'; 'Dale Hoffman'; 'Dave Harbour'; David Boelens; 'David Duffy'; David House; 'David McCaleb'; 'David McCraine'; 'David Tetta'; 'ddonkel@cfl.rr.com'; 'DNROG Units'; 'Donna Ambruz'; 'Ed Jones'; 'Elizabeth Harball'; Elowe, Kristin; 'Evan Osborne'; Evans, John R (LDZX); 'Gary Oskolkosf'; 'George Pollock'; Gordon Pospisil; Greeley, Destin M (DOR); 'Gretchen Stoddard'; gspfoff, Hurst, Rona D (DNR); Hyun, James J (DNR); 'Jacki Rose'; Jdarlington Oarlington@gmail.com); 'Jeanne McPherren'; 'Jerry Hodgden'; 'Jim Watt'; Jim White; 'Joe Lastufka'; Joe Nicks; 'John Burdick'; 'John Easton'; John Larsen; 'John Stuart'; Jon Goltz; Josef Chmielowski; 'Juanita Lovett'; 'Judy Stanek'; 'Julie Little'; Kari Moriarty; 'Kasper Kowalewski'; 'Kazeem Adegbola'; 'Keith Torrance'; Keith Wiles; Kelly Sperback; Kevin Frank; Kruse, Rebecca D (DNR); Laura Silliphant (laura.gregersen@alaska.gov); Leslie Smith; Lori Nelson; Louisiana Cutler, 'Luke Keller'; 'Marc Kovak'; Mark Dalton; Mark Hanley (mark.hanley@anadarko.com); 'Mark Landt'; 'Mark Wedman'; 'Mealear Tauch'; 'Michael Bill'; Michael Calkins; 'Michael Moora'; MJ Loveland; mkm7200; Mueller, Marta R (DNR); Munisteri, Islin W M (DNR); nelson; Nichole Saunders; Nikki Martin; NSK Problem Well Supv; Patty Alfaro; 'Paul Craig'; Paul Decker (paul.decker@alaska.gov); 'Paul Mazzolini'; Pike, Kevin W (DNR); Randall Kanady; 'Rena Delbridge'; 'Renan Yanish'; 'Richard Cool'; 'Robert Brelsford'; 'Ryan Tunseth'; Sara Leverette; 'Scott Griffith'; Shahla Farzan; Shannon Donnelly, Sharmaine Copeland; 'Sharon Yarawsky'; Shellenbaum, Diane P (DNR); Skutca, Joseph E (DNR); Smart Energy Universe; Smith, Kyle S (DNR); 'Stephanie Klemmer'; 'Stephen Hennigan'; Sternicki, Oliver R; Steve Moothart (steve.moothart@alaska.gov); 'Steve Quinn'; 'Suzanne Gibson'; Tamera Sheffield; 'Ted Kramer'; 'Temple Davidson'; 'Teresa Imm'; 'Thor Cutler'; 'Tim Jones'; 'Tim Mayers'; 'Todd Durkee'; 'trmjrl'; 'Tyler Senden'; Umekwe, Maduabuchi P (DNR); 'Vinnie Catalano'; 'Well Integrity'; 'Well Integrity'; 'Weston Nash'; 'Whitney Pettus'; 'Aaron Gluzman'; 'Aaron Sorrell'; Ajibola Adeyeye; Alan Dennis; Assmann, Aaron A; Bajsarowicz, Caroline J; 'Bruce Williams'; Bruno, Jeff J (DNR); Casey Sullivan; Catie Quinn; 'Don Shaw'; Eric Lidji; Garrett Haag; 'Graham Smith'; Hak Dickenson; Heusser, Heather A (DNR); Holly Fair; Holly Pearen; Jamie M. Long; 'Jason Bergerson'; Jesse Chielowski; 'Jim Magill'; Joe Longo; John Martineck; Josh Kindred; Laney Vazquez; Lois Epstein; Longan, Sara W (DNR); Marc Kuck, Marcia Hobson; 'Marie Steele'; Matt Armstrong; 'Mike Franger'; Morgan, Kirk A (DNR); Pascal Umekwe; Pat Galvin; 'Pete Dickinson'; Peter Contreras; Richard Garrard; Richmond, Diane M; Robert Province; 'Ryan Daniel'; 'Sandra Lemke'; 'Susan Pollard'; Talib Syed; Tina Grovier (tmgrovier@stoel.com); Tostevin, Breck C (LAW); 'Wayne Wooster'; 'William Van Dyke' Subject: AIO 2B.005 Amended and AIO 3.024 Amended Attachments: aio24b.005 Amended .pdf, aio3.024 Amended.pdf Re: Docket Number: AIO-17-002 Request for administrative approval to amend conditions of AIO 24B.005 that allow well L-105 (PTD 2020580) to be online in water alternating gas (WAG) injection service with an outer annulus (OA) repressurization. Prudhoe Bay Unit (PBU) L-105 (PTD 2020580) Prudhoe Bay Field Borealis Oil Pool Re: Docket Number: AIO-17-001 Request for administrative approval to amend conditions of AIO 3.024 that allow well R-1 1A (PTD 1982060) to be online in water alternating gas (WAG) injection service with an outer annulus (OA) repressurization. Prudhoe Bay Unit (PBU) R -11A (PTD 1982060) Prudhoe Bay Field Prudhoe Oil Pool Jodi, J. Cotombie .AOGCC Special -Assistant .Ataska Oit and C as Conservation Commission 333 hest 7"' .Avenue .Anchorage, .Alaska 99501 Office: (907) 793-1221 fax: (,C) 0;7) 276-7542 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jody Colombie at 907.793.1221 or iody.colombie@alaska.gov. Bernie Karl K&K Recycling Inc. Gordon Severson Penny Vadla P.O. Box 58055 3201 Westmar Cir. 399 W. Riverview Ave. Fairbanks, AK 99711 Anchorage, AK 99508-4336 Soldotna, AK 99669-7714 George Vaught, Jr. Darwin Waldsmith Richard Wagner P.O. Box 13557 P.O. Box 39309 P.O. Box 60868 Denver, CO 80201-3557 Ninilchik, AK 99639 Fairbanks, AK 99706 ,c�u��L �_'2--1-zC.)�1 THE STATE 'ALASKA GOVERNOR BILL WALKER Alaska Oil and Gas Conservation Commission CORRECTED ADMINISTRATIVE APPROVAL AREA INJECTION ORDER NO. 24B.005 Amended Mr. Ryan Daniel Well Integrity Engineering Team Lead BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Docket Number: AIO-17-002 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Request for administrative approval to amend conditions of AIO 2413.005 that allow well L-105 (PTD 20205 80) to be online in water alternating gas (WAG) injection service with an outer annulus (OA) repressurization. Prudhoe Bay Unit (PBU) L-105 (PTD 2020580) Prudhoe Bay Field Borealis Oil Pool Dear Mr. Daniel: By letter dated January 10, 2017, BP Exploration (Alaska), Inc. (BPXA) requested administrative approval to amend conditions of AIO 24B.005 and continue WAG injection in the subject well. In accordance with Rule 9 of Area Injection Order (AIO) 2413.000, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS BPXA's request for administrative approval to continue WAG injection in the subject well. BPXA completed a passing state witnessed Mechanical Integrity Test of the Inner Annulus (MITIA) on January 9, 2016 which indicates that L-105 exhibits at least two competent barriers to the release of well pressure. Accordingly, the AOGCC believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AIO 24B.005 Amended January 25, 2017 Page 2 of 2 AOGCC's approval to continue WAG injection in PBU L-105 is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli. Bleeds to be flagged on the report; 3. BPXA shall perform a mechanical integrity test of the inner annulus every two (2) years to 4000 psi; 4. BPXA shall limit the well's IA operating pressure to 2000 psi and the OA operating pressure to 1500 psi; 5. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 6. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 7. The MIT anniversary date is January 9, 2016. DONE at Anchorage, Alaska and dated nunc pro tunc Janu 4P-�� y Cathy . Foerster Daniel T. Se mount, Jr Chair, Commissioner Commissioner TION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. I'IIE STAIT. {'ALASKA E,ON'I:i2Iv'i�R. BILL WAI KI R Alaska Oil and Gas Conservation Commission CORRECTED ADMINISTRATIVE APPROVAL AREA INJECTION ORDER NO. 24B.005 Amended Mr. Ryan Daniel Well Integrity Engineering Team Lead BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Docket Number: AIO-17-002 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 aogcc.alaska.gov Request for administrative approval to amend conditions of AID 24B.005 that allow well L-105 (PTD 2020580) to be online in water alternating gas (WAG) injection service with an outer annulus (OA) repressurization. Prudhoe Bay Unit (PBU) L-105 (PTD 2020580) Prudhoe Bay Field Borealis Oil Pool Dear Mr. Daniel: By letter dated January 10, 2017, BP Exploration (Alaska), Inc. (BPXA) requested administrative approval to amend conditions of AIO 24B.005 and continue WAG injection in the subject well. In accordance with Rule 9 of Area Injection Order (AIO) 24B.000, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS BPXA's request for administrative approval to continue WAG injection in the subject well. BPXA completed a passing state witnessed Mechanical Integrity Test of the Inner Annulus (MITIA) on January 9, 2016 which indicates that L-105 exhibits at least two competent barriers to the release of well pressure. Accordingly, the AOGCC believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AIO 24B.005 Amended January 25, 2017 Page 2 of 2 AOGCC's approval to continue WAG injection in PBU L-105 is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli. Bleeds to be flagged on the report; 3. BPXA shall perform a mechanical integrity test of the inner annulus every two (2) years to 4000 psi; 4. BPXA shall limit the well's IA operating pressure to 2000 psi and the OA operating pressure to 1500 psi; 5. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 6. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 7. The MIT anniversary date is January 9. 2016. DONE at Anchorage, Alaska and dated nunc pro tunc January 25, 2017. //signature on file// //signature on file// //signature on file// Cathy P. Foerster Daniel T. Seamount, Jr. Hollis French Chair, Commissioner Commissioner Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Friday, February 10, 2017 10:47 AM To: aogcc.inspectors@alaska.gov, 'Bender, Makana K (DOA) (makana.bender@alaska.gov)'; 'Bettis, Patricia K (DOA) (patricia.bettis@alaska.gov)'; 'Brooks, Phoebe L (DOA) (phoebe.brooks@alaska.gov)'; Carlisle, Samantha J (DOA); 'Colombie, Jody J (DOA) Oody.colombie@alaska.gov)'; 'Davies, Stephen F (DOA) (steve.davies@alaska.gov)'; Eaton, Loraine E (DOA); Toerster, Catherine P (DOA) (cathy.foerster@alaska.gov)'; 'French, Hollis (DOA)'; Trystacky, Michal (michal.frystacky@alaska.gov)'; 'Guhl, Meredith (DOA sponsored) (meredith.guhl@alaska.gov)'; Kair, Michael N (DOA); 'Link, Liz M (DOA)'; Loepp, Victoria T (DOA); 'Mumm, Joseph (DOA sponsored) Ooseph.mumm@alaska.gov)'; 'Paladijczuk, Tracie L (DOA) (tracie. pa lad ijczu k@ a laska.gov)'; 'Pasqual, Maria (DOA) (maria.pasqual@alaska.gov)'; 'Quick, Michael (DOA sponsored)'; 'Regg, James B (DOA) Oim.regg@alaska.gov)'; 'Roby, David S (DOA) (dave.roby@alaska.gov)'; 'Schwartz, Guy L (DOA) (g uy.schwa rtz@ a laska.gov)'; 'Sea mount, Dan T (DOA) (dan.seamount@alaska.gov)'; Singh, Angela K (DOA); 'Wallace, Chris D (DOA) (ch ris.wa I lace@ a laska.gov)'; AK, GWO Projects Well Integrity; 'AKDCWellIntegrityCoordinator'; 'Alan Bailey'; 'Alex Demarban'; 'Alexander Bridge'; 'Allen Huckabay'; 'Andrew VanderJack'; 'Ann Danielson'; Anna Raff; 'Barbara F Fullmer'; bbritch; Becky Bohrer; 'Ben Boettger'; 'Bill Bredar'; Bob; Brandon Viator; 'Brian Havelock'; 'Bruce Webb'; 'Caleb Conrad'; 'Candi English'; Cocklan- Vendl, Mary E; Colleen Miller, 'Connie Downing'; Crandall, Krissell; 'D Lawrence'; 'Dale Hoffman'; 'Dave Harbour'; David Boelens; 'David Duffy'; David House; 'David McCaleb'; 'David McCraine'; 'David Tetta'; 'ddonkel@cfl.rr.com'; 'DNROG Units'; 'Donna Ambruz'; 'Ed Jones'; 'Elizabeth Harball'; Elowe, Kristin; 'Evan Osborne'; Evans, John R (LDZX); 'Gary Oskolkosf'; 'George Pollock'; Gordon Pospisil; Greeley, Destin M (DOR); 'Gretchen Stoddard'; gspfoff; Hurst, Rona D (DNR); Hyun, James J (DNR); 'Jacki Rose'; Jdarlington Oarlington@gmail.com); 'Jeanne McPherren'; 'Jerry Hodgden'; Jill Simek; 'Jim Watt'; Jim White; 'Joe Lastufka'; Joe Nicks; 'John Burdick'; 'John Easton'; John Larsen; 'John Stuart'; Jon Goltz; Josef Chmielowski; 'Juanita Lovett'; 'Judy Stanek'; Kari Moriarty; 'Kasper Kowalewski'; 'Kazeem Adegbola'; 'Keith Torrance'; Keith Wiles; Kelly Sperback; Kevin Frank, Kruse, Rebecca D (DNR); Laura Silliphant (laura.gregersen@alaska.gov); Leslie Smith; Lori Nelson; Louisiana Cutler, 'Luke Keller'; 'Marc Kovak'; Mark Dalton; Mark Hanley (mark.hanley@anadarko.com); 'Mark Landt'; 'Mark Wedman'; 'Mealear Tauch'; 'Michael Bill'; Michael Calkins; 'Michael Moora'; MJ Loveland; mkm7200; Mueller, Marta R (DNR); Munisteri, Islin W M (DNR); nelson; Nichole Saunders; Nikki Martin; NSK Problem Well Supv; Patty Alfaro; 'Paul Craig'; Paul Decker (paul.decker@alaska.gov); 'Paul Mazzolini'; Pike, Kevin W (DNR); Randall Kanady; 'Renan Yanish'; 'Richard Cool'; 'Robert Brelsford'; 'Ryan Tunseth'; Sara Leverette; 'Scott Griffith'; Shahla Farzan; Shannon Donnelly; Sharmaine Copeland; 'Sharon Yarawsky'; Skutca, Joseph E (DNR); Smart Energy Universe; Smith, Kyle S (DNR); 'Stephanie Klemmer'; 'Stephen Hennigan'; Sternicki, Oliver R, Steve Moothart (steve.moothart@alaska.gov); 'Steve Quinn'; 'Suzanne Gibson'; 'Tamera Sheffield'; 'Ted Kramer'; 'Teresa Imm'; 'Thor Cutler'; 'Tim Jones'; 'Tim Mayers'; 'Todd Durkee'; 'trmjrl'; 'Tyler Senden'; Umekwe, Maduabuchi P (DNR); 'Vinnie Catalano'; 'Well Integrity'; 'Well Integrity'; 'Weston Nash'; 'Whitney Pettus'; 'Aaron Gluzman'; 'Aaron Sorrell'; Ajibola Adeyeye; Alan Dennis; Assmann, Aaron A; Bajsarowicz, Caroline J; 'Bruce Williams'; Bruno, Jeff J (DNR); Casey Sullivan; Catie Quinn; 'Don Shaw'; Eric Lidji; Garrett Haag; 'Graham Smith'; Hak Dickenson; Heusser, Heather A (DNR); Holly Fair, Holly Pearen; Jamie M. Long; 'Jason Bergerson'; Jesse Chielowski; 'Jim Magill'; Joe Longo; John Martineck, Josh Kindred; Laney Vazquez•, Lois Epstein; Longan, Sara W (DNR); Marc Kuck; Marcia Hobson; 'Marie Steele'; Matt Armstrong; 'Mike Franger'; Morgan, Kirk A (DNR); Pascal Umekwe; Pat Galvin; 'Pete Dickinson'; Peter Contreras; Richard Garrard; Richmond, Diane M; Robert Province; 'Ryan Daniel'; 'Sandra Lemke'; 'Susan Pollard'; Talib Syed; Tina Grovier (tmgrovier@stoel.com); Tostevin, Breck C (LAW); 'Wayne Wooster'; 'William Van Dyke' Subject: Corrected AI024B-005 Amended Attachments: aio24b.005 Amended and Corrected.pdf Please see attached, Re: Docket Number: AIO-17-002 Request for administrative approval to amend conditions of AIO 24B.005 that allow well L-105 (PTD 2020580) to be online in water alternating gas (WAG) injection service with an outer annulus (OA) repressurization. Prudhoe Bay Unit (PBU) L-105 (PTD 2020580) Prudhoe Bay Field Borealis Oil Pool Jody J. Cotombie �OyCC Spec -Assistant _Alaska_Alaska 0itand (yas Conservation Commission 333 1Nest 7"' A -Venue -Anchorage, Alaska 995oi Of fine: (�)07) 793-1221 fax: (907) 276-7542 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jody Colombie at 907.793.1221 or iodv.colombie@alaska.c�ov. Bernie Karl K&K Recycling Inc. Gordon Severson Penny Vadla P.O. Box 58055 3201 Westmar Cir. 399 W. Riverview Ave. Fairbanks, AK 99711 Anchorage, AK 99508-4336 Soldotna, AK 99669-7714 George Vaught, Jr. Darwin Waldsmith Richard Wagner P.O. Box 13557 P.O. Box 39309 P.O. Box 60868 Denver, CO 80201-3557 Ninilchik, AK 99639 Fairbanks, AK 99706 THE STATE 01ALASKA GOVERNOR MIKE DUNLEAVY Mr. Oliver Sternicki Alaska Oil and Gas Conservation Commission ADMINISTRATIVE APPROVAL AREA INJECTION ORDER NO. 2411.006 Senior Well Integrity Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Docket Number: AIO-19-004 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Request for administrative approval to allow well Z-116 (PTD 2111240) to be online in water alternating gas (WAG) injection service with an inner annulus (IA) repressurization. Prudhoe Bay Unit (PBU) Z-116 (PTD 2111240) Prudhoe Bay Field Borealis Oil Pool Dear Mr. Stemicki: By letter dated February 22, 2019, BP Exploration (Alaska), Inc. (BPXA) requested administrative approval to continue WAG injection in the subject well. In accordance with Rule 9 of Area Injection Order (AIO) 24B.000, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS BPXA's request for administrative approval to continue WAG injection in the subject well. BPXA reported to AOGCC a potential inner annulus repressurization in January 2018 and initiated additional diagnostics and monitoring. BPXA completed a passing state witnessed Mechanical Integrity Test of the Inner Annulus (MITIA) on February 23, 2018 which indicates that Z-116 exhibits at least two competent barriers to the release of well pressure. The well has a recorded IA build up rate of 5 psi/day. BPXA has replaced the dummy gas lift valves to mitigate the IA repressurization and installed wireless gauges on Z -pad wells that allow for real time monitoring and alarm notifications of IA and outer annulus (OA) pressures. AOGCC finds that BPXA is able to manage the IA pressure with periodic pressure bleeds. Accordingly, the AOGCC believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AIO 24B.006 March 5, 2019 Page 2 of 2 AOGCC's approval to continue WAG injection in PBU Z-116 is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli. Bleeds to be flagged on the report; 3. BPXA shall perform a mechanical integrity test of the inner annulus (MITIA) every 2 years to the maximum anticipated injection pressure, but not less than 1500 psi; 4. BPXA shall limit the well's IA operating pressure to 2000 psi and the OA operating 5. W pressure to 1000 psi; BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and The MIT anniversary date is February 23, 2018. DONE at Anchorage, Alaska and dated March 5, 2019. 6 4, A�t� Ca P. oerster Daniel T. Seamount, Jr. Commissioner Commissioner As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days atter the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. TI IF STATE "ALASKA GOVERNOR MICHA11- I- DUNLLAVY Mr. Oliver Sternicki Alaska Oil and Gas Conservation Commission ADMINISTRATIVE APPROVAL AREA INJECTION ORDER NO. 2413.006 Senior Well Integrity Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Docket Number: AIO-19-004 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.claska.gov Request for administrative approval to allow well Z-116 (PTD 2111240) to be online in water alternating gas (WAG) injection service with an inner annulus (IA) repressurization. Prudhoe Bay Unit (PBU) Z-116 (PTD 2111240) Prudhoe Bay Field Borealis Oil Pool Dear Mr. Sternicki: By letter dated February 22, 2019, BP Exploration (Alaska), Inc. (BPXA) requested administrative approval to continue WAG injection in the subject well. In accordance with Rule 9 of Area Injection Order (AIO) 2413.000, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS BPXA's request for administrative approval to continue WAG injection in the subject well. BPXA reported to AOGCC a potential inner annulus repressurization in January 2018 and initiated additional diagnostics and monitoring. BPXA completed a passing state witnessed Mechanical Integrity Test of the Inner Annulus (MITIA) on February 23, 2018 which indicates that Z-116 exhibits at least two competent barriers to the release of well pressure. The well has a recorded lA build up rate of 5 psi/day. BPXA has replaced the dummy gas lift valves to mitigate the IA repressurization and installed wireless gauges on Z -pad wells that allow for real time monitoring and alarm notifications of IA and outer annulus (OA) pressures. AOGCC finds that BPXA is able to manage the IA pressure with periodic pressure bleeds. Accordingly, the AOGCC believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AIO 24B.006 March 5, 2019 Page 2 of 2 AOGCC's approval to continue WAG injection in PBU Z-116 is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli. Bleeds to be flagged on the report; 3. BPXA shall perform a mechanical integrity test of the inner annulus (MITIA) every 2 years to the maximum anticipated injection pressure, but not less than 1500 psi; 4. BPXA shall limit the well's IA operating pressure to 2000 psi and the OA operating pressure to 1000 psi; 5. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 6. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 7. The MIT anniversary date is February 23, 2018. DONE at Anchorage, Alaska and dated March 5, 2019. //signature on file// Cathy P. Foerster Commissioner //signature on file// Daniel T. Seamount, Jr. Commissioner AND APPEAL NOTICE As provided in AS 31.05.080(x), within 20 days after written notice of the entry of this order or decision, in such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant in refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. if the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration we FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend in state holiday. Carlisle, Samantha J (DOA) From: Carlisle, Samantha J (DOA) Sent: Tuesday, March 5, 2019 1:56 PM To: 'AOGCC_Public_Notices@list.state.ak.us' Subject: Area Injection Order 248.006 Attachments: aio24B.006 Request for administrative approval to allow well Z-116 (PTD 2111240) to be online in water alternating gas (WAG) injection service with an inner annulus (IA) repressurization. Prudhoe Bay Unit (PBU) Z-116 (PTD 2111240) Samantha Carlisle Executive Secretary III Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 (907) 793-1223 CONFIDENTIALITY NOTICE. This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC. is aware of the mistake in sending it to you, contact Sam amha Carlisle at (907) 793-1223 or Sarnarrtha.Carlisle(,falaska.aov. Bernie Karl Gordon Severson Penny Vadla K&K Recycling Inc. 3201 Westmar Cir. 399 W. Riverview Ave. P.O. Box 58055 Anchorage, AK 99508-4336 Soldotna, AK 99669-7714 Fairbanks, AK 99711 George Vaught, Jr. P.O. Box 13557 Denver, CO 80201-3557 Darwin Waldsmith P.O. Box 39309 Ninilchik, AK 99639 Richard Wagner P.O. Box 60868 Fairbanks, AK 99706 THE STATE Alaska Oil and Gas 'ALASKA Conservation Commission GOO F R NO R M I K I 1)U M EA V Y 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogec.alaska.gov June 9, 2021 ADMINISTRATIVE APPROVAL AREA INJECTION ORDER NO.24B.007 Mr. Stan Golis PBW Operations Manager Hilcorp North Slope, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Docket Number:AIO-21-012 Request for Administrative Approval to Area Injection Order 2413: Water Alternating Gas Injection Operations Prudhoe Bay Unit L-119A (PTD 2191550), Borealis Oil Pool Dear Mr. Golis: By letter dated May 26, 2021, Hilcorp North Slope, LLC (Hilcorp) requested administrative approval to continue water alternating gas (WAG) injection in the subject well. In accordance with Rule 9 of Area Injection Order (AIO) 24B.000, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS, subject to conditions, Hilcorp's request for administrative approval to continue WAG injection in the subject well. On March 17, 2021, Hilcorp reported that the well experienced possible slow tubing by inner annulus (TxIA) pressure communication while on gas injection. Hilcorp performed diagnostics and monitoring including a passing state witnessed Mechanical Integrity Test (MIT) of the Inner Annulus (IA) on May 25, 2021, which indicates that L-119A exhibits at least two competent barriers to the release of well pressure. AOGCC believes Hilcorp can safely manage the TxIA with periodic pressure bleeds. Accordingly, the AOGCC believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's approval to continue WAG injection in L-119A is conditioned upon the following: 1. Hilcorp shall record wellhead pressures and injection rate daily; 2. Hilcorp shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli. Bleeds to be flagged on the report; AIO 2413.007 June 9,2021 Page 2 of 2 Hilcorp shall perform a MIT of the IA every two years to the greater of the maximum anticipated injection pressure or 0.25 x packer TVD, but not less than 1500 psi; 4. Hilcorp shall limit the well's IA operating pressure to 2100 psi and the outer annulus (OA) operating pressure to 1000 psi; 5. Hilcorp shall monitor the IA and OA pressures with wireless pressure gauges; 6. Hilcorp shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 7. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and The next required MIT shall be completed before or during the month of May 2023. AOGCC must be provided the opportunity to witness the MIT for a test to establish a new test due date. DONE at Anchorage, Alaska, and dated June 9, 2021. Dlglhllysi9md Jeremy Price by Jeremy Me Date:2021.06.09 16:03:24-0a'00' Jeremy M. Price Chair, Commissioner Dan Digitally signed by Dan Seamount Seamount Date: 2021.06.09 1635:26 08'00' Daniel T. Seamount, Jr. Commissioner Jessie L. DgItAys'gnedby k.kL Chm lelowsk Chmlel0wsa Date:2021.%6 1433:12-08'00' Jessie L. Chmielowski Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Bernie Karl K&K Recycling Inc. P.O. Box 58055 Fairbanks, AK 99711 George Vaught, Jr. P.O. Box 13557 Denver, CO 80201-3557 Gordon Severson 3201 Westmar Cir. Anchorage, AK 99508-4336 Darwin Waldsmith P.O. Box 39309 Ninilchik, AK 99639 Richard Wagner P.O. Box 60868 Fairbanks, AK 99706 Salazar, Grace (CED) From: Sent: To: Subject: Attachments: Please see attached. Salazar, Grace (CED) Thursday, June 10, 2021 7:52 AM AOGCC Public Notices AOGCC AIO 246.007 A1024B.007.pdf Re: Docket Number:AlO-21-012 Request for Administrative Approval to Area Injection Order 24B: Water Alternating Gas Injection Operations Prudhoe Bay Unit L-119A (PTD 2191550), Borealis Oil Pool Respectfully, M. Grace Salazar, Special Assistant Alaska Oil and Gas Conservation Commission 333 West 7t' Avenue Anchorage, AK 99501 Direct: (907) 793-1221 Email: grace.salazar@alaska.gov https://www.commerce.alaska.goy/web/aogcc/ 1 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov ADMINISTRATIVE APPROVAL AREA INJECTION ORDER 24B.005 AMENDED Mr. Stan Golis PBW Operations Manager Hilcorp North Slope, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Docket Number: AIO-22-026 Request to Amend Area Injection Order 24B.005: Water Alternating Gas Injection Operations Prudhoe Bay Unit (PBU) L-105 (PTD 2020580), Borealis Oil Pool Dear Mr. Golis: By emailed letter dated August 29, 2022, Hilcorp North Slope, LLC (Hilcorp) requested administrative approval to amend Area Injection Order (AIO) 24B.005 to include water alternating gas (WAG) injection with a known outer annulus (OA) hydrate repressurization and a new tubing by inner annulus (TxIA) pressure communication. In accordance with 20 AAC 25.556(d), the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS, subject to conditions, Hilcorp’s request to amend the administrative approval to continue WAG injection in the subject well. BP Exploration (Alaska), Inc (BPXA) first reported an OA repressurization to AOGCC in October 2004. AOGCC issued AIO 24.004 on January 18, 2006 which was replaced by AIO 24B.005 on March 8, 2016 and the restrictive conditions were amended on January 25, 2017. Hilcorp reported to AOGCC on August 1, 2022 a new slow TxIA pressure communication. Hilcorp has performed additional diagnostics including a passing state-witnessed mechanical integrity test (MIT) of the inner annulus (to a test pressure of 4,120 psi) on August 14, 2022. This indicates that L-105 exhibits at least two competent barriers to the release of well pressure. Hilcorp maintains live transmitters on the inner and outer annulus and alarm functions in the Supervisory Control and Data Acquisition (SCADA) system that create layers of protection from an over-pressure event. These inner and outer annulus alarms combined with the planned inner and outer annulus operating pressure limits enable AOGCC to continue to authorize gas injection. AOGCC believes Hilcorp can safely manage the existing OA hydrate repressurization and new TxIA communication with periodic pressure bleeds by maintaining the IA to a pressure not to exceed 2,100 psi and OA to a pressure not to exceed 1,500 psi. Accordingly, the AOGCC believes that the well’s condition does not compromise overall well integrity so as to threaten human safety or the environment. AIO 24B.005 Amended September 28, 2022 Page 2 of 2 AOGCC’s approval to continue WAG injection in PBU L-105 is conditioned upon the following: 1) Hilcorp shall record wellhead pressures and injection rate daily; 2) Hilcorp shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli. Bleeds to be flagged on the report; 3) Hilcorp shall perform a MIT of the inner annulus every two years to the greater of the maximum anticipated injection pressure or 0.25 x packer TVD, but not less than 4,000 psi; 4) Hilcorp shall limit the well’s inner annulus operating pressure to 2,100 psi and the outer annulus operating pressure to 1,500 psi. Audible control room alarms shall be set at or below these limits; 5) Hilcorp shall monitor the inner and outer annulus pressures in real time with its SCADA system; 6) Hilcorp shall maintain the Production Control Center (PCC) remote shut down capability for L-105 when on gas or miscible injectant (MI) operation. During gas/MI injection, the IA protocols will include a drill site operator and PCC alarm set at 2,100 psi, and a high alarm set at 3,000 psi that will prompt the PCC to remotely shut in the well; 7) Hilcorp shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 8) After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 9) The next required MIT shall be completed before or during the month of August 2024. DONE at Anchorage, Alaska and dated September 28, 2022. Jessie L. Chmielowski Greg C. Wilson Commissioner Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Gregory Wilson Digitally signed by Gregory Wilson Date: 2022.09.28 16:22:11 -08'00' Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2022.10.03 09:54:41 -08'00' From:Carlisle, Samantha J (OGC) To:AOGCC_Public_Notices Subject:[AOGCC_Public_Notices] Area Injection Order 24B.005 amended (PBU) Date:Monday, October 3, 2022 10:49:48 AM Attachments:aio24B.005 amended 2.pdf Docket Number: AIO-22-026 Request to Amend Area Injection Order 24B.005: Water Alternating Gas Injection Operations Prudhoe Bay Unit (PBU) L-105 (PTD 2020580), Borealis Oil Pool Samantha Carlisle AOGCC Special Assistant Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 (907) 793-1223 __________________________________ List Name: AOGCC_Public_Notices@list.state.ak.us You subscribed as: samantha.carlisle@alaska.gov Unsubscribe at: https://list.state.ak.us/mailman/options/aogcc_public_notices/samantha.carlisle%40alaska.gov Bernie Karl K&K Recycling Inc. P.O. Box 58055 Fairbanks, AK 99711 mailed 10/3/22 INDEXES 18 Hilcorp North Slope, LLC Stan Golis, PBW Operations Manager 3800 Centerpoint Dr, Suite 1400 Anchorage, Alaska 99503 08/29/2022 Chairman Jeremy Price Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Borealis Well L-105 (PTD#202058). Request for amendment to AIO 24B.005 for continue WAG injection operations. Dear Chairman Price, Hilcorp North Slope, LLC requests amendment to AIO 24B.005 to allow for continued WAG injection into Borealis well L-105 with slow tubing x inner annulus (IA) communication. L-105 currently operates under AIO 24B.005, approved 01/25/2017 for continued operation with outer annulus (OA) hydrate repressurization and an increased OA MOASP of 1500 psi. L-105 was reported to the AOGCC on 08/01/2022, at which time the well was placed under evaluation for suspected slow tubing by IA pressure communication based on IA pressure trends while on MI service and energized fluid in an IA bleed. On 08/05/2022 a tubing hanger pack-off test (PPPOT-T) passed to 5000 psi and a casing hanger pack-off test (PPPOT-IC) passed to 3500 psi. An online AOGCC witnessed MIT-IA passed to 4120 psi on 08/14/2022. The passing test confirms both the primary and secondary well barrier integrity. Hilcorp North Slope, LLC has determined that well L-105 is safe to operate in its current condition and requests an amendment to AIO 24B.005 for WAG injection based on the following: x IA pressure can be maintained below MOASP by managing the IA repressurization with periodic annular bleeds. x Passing pressure test of the primary and secondary barriers. x IA and OA pressures will be monitored with wireless pressure gauges. If you have any questions, please call me at 907-777-8356 or Oliver Sternicki at 907-564-4891. Sincerely, Stan Golis PBW Operations Manager Attachments Technical Justification TIO/ Injection Plot Wellbore Schematic Sincerely, Stan Golis By Samantha Carlisle at 10:21 am, Aug 31, 2022 Borealis Well L-105 Technical Justification for Administrative Approval Request 08/29/2022 Well History and Status Borealis well L-105 (PTD# 202058) is a WAG injector originally drilled 07/21/2002. In October of 2004 the well began showing sustained outer annulus (OA) pressure due to hydrates entering the surface casing shoe. On 01/18/2006, AIO 24.004 was approved for continued operation with OA repressurization. AIO 24.004 was canceled and AIO 24B.005 approved on 03/08/2016, on the basis of removing the annual liquid leak rate (LLR) requirement and changing the MIT-IA requirement to every 2-years. On 01/25/2017, AIO 24B.005 was amended to increase the OA operating pressure to 1500 psi. Anomalous IA repressurization was first noted in L-105 on 7/31/2022, when bled the IA returned energized fluid indicating possible communication to the tubing. The AOGCC was notified on 08/01/2022 and the well was placed under evaluation for diagnostics. On 08/05/2022 the well passed a PPPOT-T to 5000 psi and a PPPOT-IC to 3500 psi. On 08/14/2022 the well passed a AOGCC witnessed MIT-IA to 4125 psi. Variable MI injection rates, pressures and ambient temperature swings during the evaluation period have created inconsistent IA repressurization rates, but an additional IA bleed on 08/25/2022 again produced a small amount of energized fluid indicating the repressurization is not just thermally induced. Recent Well Events: 08/14/2022 Online AOGCC witnessed MIT-IA passed to 4120 psi. 08/05/2022 PPPOT-T passed to 5000 psi, PPPOT-IC passed to 3500 psi. 08/01/2022 Notification sent to the AOGCC, well placed under evaluation. 07/31/2022 IA bleed with energized fluid, possible TxIA pressure communication noted. 01/17/2022 Passed online AOGCC witnessed MIT-IA to 4125 psi. Barrier and Hazard Evaluation The primary and secondary barriers systems consist of the tubing and production casing and associated hardware. A passing online pressure test conducted on 08/14/2022, which tested both barriers, demonstrates competent primary and secondary barrier systems. Due to the low IA repressurization rate no logging or repair attempt is planned at this time due to the low likelihood of locating the leak point. Proposed Operating and Monitoring Plan 1. Record wellhead pressures and injection rates daily; 2. Submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli. Bleeds to be flagged on the report; 3. Perform a MITIA every two years to the greater of the maximum anticipated wellhead injection pressure or 0.25 x packer TVD, but not less than 1,500 psi; 4. Limit the well’s inner annulus operating pressure to 2,100 psi. Audible control room alarms shall be set at or below these limits; 5. Limit the well’s outer annulus operating pressure to 1,500 psi. Audible control room alarms shall be set at or below these limits; 6. Monitor the inner and outer annulus pressures in real time with its SCADA system; 7. Maintain the Production Control Center (PCC) remote shut down capability for L-105 when on gas or miscible injectant (MI) operation; 8. Immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 9. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; TIO/ Injection Plot Wellbore Schematic CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Oliver Sternicki To:Wallace, Chris D (OGC); Abbie Barker Subject:RE: [EXTERNAL] RE: PBU L-105 (PTD # 202-058) Request for AIO Amendment Date:Wednesday, August 31, 2022 11:35:38 AM Attachments:MIT PBU L-105 08-14-22.xlsx Chris, Here is the test. Ryan is putting together the monthly email with all the completed August tests which will include this one to go to the normal distribution list. Oliver From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Wednesday, August 31, 2022 11:22 AM To: Abbie Barker <abbie.barker@hilcorp.com> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: [EXTERNAL] RE: PBU L-105 (PTD # 202-058) Request for AIO Amendment Abbie, We have received the amendment request and are processing this. The request mentions the passing AOGCC witnessed MITIA of 8/14/2022 which I have not yet received and is not included in the request. Please send the excel Form 10-426 to its distribution list and we can continue our reviews. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Abbie Barker <Abbie.Barker@hilcorp.com> Sent: Tuesday, August 30, 2022 9:48 AM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov>; Carlisle, Samantha J (OGC) <samantha.carlisle@alaska.gov> Cc: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; Brodie Wages <David.Wages@hilcorp.com>; Wyatt Rivard <wrivard@hilcorp.com> Subject: PBU L-105 (PTD # 202-058) Request for AIO Amendment CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Hello, Please find the attached Request for amendment to AIO 24B.005 to continue WAG injection operations for L-105 (PTD # 202-058). If you have any questions, please contact Stan Golis at 907-777-8356 or Oliver Sternicki at 907-564- 4891. Thanks, Abbie Abbie Barker Regulatory Tech, Prudhoe Bay West Team Hilcorp North Slope Email: Abbie.Barker@hilcorp.com Office: (907)564-4915 Cell: (907)351-2459 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 17 Wallace, Chris D (CED) From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Wednesday, June 9, 2021 9:59 AM To: Wallace, Chris D (CED) Subject: RE: [EXTERNAL] RE: V-218, L-119 AA 90 day plots Attachments: MIT PBU L-119 L-218 05-25-21.xlsx; MIT PBU V-218 V-219 05-25-21.xlsx Chris, The forms for these 2 wells were sent in on 6/1 so they probably just haven't been uploaded yet. See the attached sheets for another copy. Oliver From: Wallace, Chris D (CED) <chris.waIlace@alaska.gov> Sent: Wednesday, June 9, 2021 8:58 AM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: (EXTERNAL) RE: V-218, L-119 AA 90 day plots Oliver— I do not seem to have these MITs so could you please send. Maybe they were sent on the 5`n in a batch but they haven't been uploaded into our database and so I do not have a record. Thanks, Chris From: Oliver Sternicki <Oliver.Sternicki anhilcorp.com> Sent: Thursday, June 3, 20219:55 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.aov> Subject: V-218, L-119 AA 90 day plots Chris, Something must have happened when the documents got signed where it cut out a couple pages. Here are unsigned copies that include the TIO/ Injection plots. Oliver Sternicki Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the senders phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submitto: iim.reOotMalaska.0ov; AOGCC. InspectorsA&alaskea. ohoebe brooks0alaska.nov OPERATOR: Hilcorp Alaska LLC FIELD / UNIT / PAD: Prudhoe Bay / PBU / L Pad DATE: 05/25/21 OPERATOR REP: Ryan Holt Al REP: Lou Laubenstein Wall L-319 Pressures'. Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2071480 Type Inl W Tubing 728 1 730 726 724 Type Test P Packer ND 4328 BBLPump 1.3 IA 250 1806 1744 17M Interval 4 Test psi tuml 1.3 1 OA 1 737 1 920 1 908 1 900 Result P Notes: 4 year AOGCC MIT -IA Well L-119A Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. fiO Min. PTD 2191550 Type Inj G Tubing 2284 1 2288 1 2288 2286 Type Tasl P Packer ND 6446 BBLPump 1.3 IA 910 3359 3305 3291 Interval 0 Test psi 1612 BBL Return 1.3 OA 13 1 17 17 17 Result P Notes: AOGCC MITJA to 3200 psi submit for AA for slaw TAN continued MI injection Well Pressures: Pretest Initial 15 Min. 30 Min, 45 Min. 80 Min. PTD Type lnj Tubing Type TesI Packer ND BBLPump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min, 30 Min. 45 Min. 60 Min. PTD Type lnj Tubing Type Test Packer ND BBLPump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTO Type Inj Tubing Type Test Packer ND BBLPumpl I IA IInterval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer ND BBLPump IA Interval Test psi BBL Return OA Result Notes: Well Pressures'. Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer ND BBI_Pumpj IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min, 30 Min. 45 Min. 60 Min. PTD Typ;I Tubing Type Test Packer ND BBLPump IA I Interval Test psi BBL Return OA Result Netea: TYPE INJ Codas w=weer G=Gas s=slue, I = Iadustrul waAewatar N =Net Injects, TYPE TEST Codes INTERVALCones P=Pascal Ted 1=Initial Test O= Cher (descdbe In None) 4=Four Year Cycle V=Ra lred W Vanance 0= Gtner (dose icein nines) Result Goaded P = Pans F=Fvl I=Iresuid.s. Form 10426 (Revised 01/2017) MIT PBU title L-218 0535-21 also 16 Hilcorp North Slope, LLC Stan Golis, PBW Operations Manager 3800 Centerpoint Dr, Suite 1400 Anchorage, Alaska 99503 RECEIVED By Grace Salazar at 11:23 am, May 27, 2021 05/26/2021 Mr. Jeremy Price, Chair Alaska Oil and Gas Conservation Commission 333 West 71h Avenue Anchorage, Alaska 99501 Subject: Borealis Well L-119A (PTD# 219155) Request for Administrative Approval to continue WAG Injection Operations Dear Mr. Price, Hilcorp North Slope, LLC requests administrative approval for continued WAG injection into Borealis well L-119A with slow tubing by inner annulus communication. No increase to Maximum Operating Annulus Surface Pressure (MOASP) is required. L-119A was flagged on 03/17/2021 as having possible slow TAA communication while on MI and was placed under evaluation at which time it was reported to the AOGCC. To confirm the primary and secondary barriers a passing AOGCC witnessed M IT4A was conducted on 05/25/2021 to 3291 psi while on MI. Hilcorp North Slope, LLC has determined that well L-119A is safe to operate in its current condition and requests an AA for continued WAG injection based on the following: • IA pressure can be maintained below MOASP by managing the IA repressuftation with periodic annular bleeds. • MIT -IA passed to 3291 psi. • IA and CA pressures will be monitored with wireless pressure gauges. If you have any questions, please call me at 907-564-5231 or Ryan Holt/ Andy Ogg at 659- 5102. Sincerely, Stan Golis PBW Operations Manager Borealis Well L-119A Technical Justification for Administrative Approval Request 05/26/2021 Well History and Status Well L-119A is a WAG injector that was originally drilled in April 2002 and coil sidetracked in February 2020. L-119A was flagged on 03/17/2021 as having possible slow TxIA communication while on MI at which time it was reported to the AOGCC and placed under evaluation. A negative pack -off test of the tubing hanger passed on 03/1912021 with the well on MI. On 05/05/2021 the IA was loaded with 9.8 ppg brine and extended packing dummy gas lift valves were set in station #2 and #3 in an attempt to mitigate the IA repressurization. After this work was completed the well was placed back on MI beginning 05/09/2021 to monitor for repressurization, but the well continued to show slow TxIA communication based on IA pressure trends. To confirm the primary and secondary barriers a passing AOGCC witnessed MIT -IA was conducted on 05/25/2021 to 3291 psi while on MI. Recent Well Events: 05/25/2021 AOGCC witnessed MIT -IA passed to 3291 psi. 05/05/2021 IA loaded with 9.8 ppg brine and extended packing dummy gas lift valves set. MIT -IA to 2500 psi passed. 03/19/2021 Negative tubing hangerpack-off test while on MI passed 03/1712021 IA pressure anomaly noted and reported to AOGCC 04/1012020 AOGCC witnessed MIT -IA passed to 1937 psi. 04/02/2020 Offline MIT -IA passed to 3253 psi. Barrier and Hazard Evaluation The primary and secondary barriers systems consist of the tubing and production casing and associated hardware. A passing pressure test of the inner annulus to 3291 psi on 05/25/2021, which tests both barriers, demonstrates competent primary and secondary barrier systems. No further diagnostics/ repair attempts are proposed at this time due to the low probability of success in being able to locate the communication point based on the low leak rate. Pressure on the inner annulus will be maintained below MOASP of 2100 psi when the well is on-line with periodic bleeds of the IA. Proposed Operating and Monitoring Plan 1. Record wellhead pressures and injection rate daily. 2. Submit a report monthly of well pressures and injection rates to the AOGCC. 3. Perform a 2-year MIT -IA to maximum anticipated injection pressure. 4. IA MOASP= 2100 psi, OA MOASP= 1000 psi 5. The well will be shut-in and the AOGCC notified if there is any change in the wells mechanical condition. Borealis Well L-119A Technical Justification for Administrative Approval Request 05/26/2021 Well History and Status Well L-119A is a WAG injector that was originally drilled in April 2002 and coil sidetracked in February 2020. L-119A was flagged on 03/17/2021 as having possible slow TxIA communication while on MI at which time it was reported to the AOGCC and placed under evaluation. A negative pack -off test of the tubing hanger passed on 03/19/2021 with the well on MI. On 05/05/2021 the IA was loaded with 9.8 ppg brine and extended packing dummy gas lift valves were set in station #2 and #3 in an attempt to mitigate the IA repressurization. After this work was completed the well was placed back on MI beginning 05/09/2021 to monitor for repressurization, but the well continued to show slow TxIA communication based on IA pressure trends. To confirm the primary and secondary barriers a passing AOGCC witnessed MIT -IA was conducted on 05/25/2021 to 3291 psi while on MI. Recent Well Events: 05/25/2021 AOGCC witnessed MIT -IA passed to 3291psi'. 05/05/2021 IA loaded with 9.8 ppg brine and extended packing dummy gas lift valves set. MIT -IA to 2500 psi passed. 03/19/2021 Negative tubing hangerpack-off test while on MI passed 03/17/2021 IA pressure anomaly noted and reported to AOGCC 04/10/2020 AOGCC witnessed MIT -IA passed to 1937 psi. 04/02/2020 Offline MIT -IA passed to 3253 psi. Barrier and Hazard Evaluation The primary and secondary barriers systems consist of the tubing and production casing and associated hardware. A passing pressure test of the inner annulus to 3291 psi on 05/25/2021, which tests both barriers, demonstrates competent primary and secondary barrier systems. No further diagnostics/ repair attempts are proposed at this time due to the low probability of success in being able to locate the communication point based on the low leak rate. Pressure on the inner annulus will be maintained below MOASP of 2100 psi when the well is on-line with periodic bleeds of the IA. Proposed Operating and Monitoring Plan 1. Record wellhead pressures and injection rate daily. 2. Submit a report monthly of well pressures and injection rates to the AOGCC. 3. Perform a 2-year MIT -IA to maximum anticipated injection pressure. 4. IA MOASP= 2100 psi, OA MOASP= 1000 psi 5. The well will be shut-in and the AOGCC notified if there is any change in the wells mechanical condition. TIO/ Injection Plots yyy+Iw4_ T7EE - 'NJELLNEAD- IVFMC ACTUATOR - IOKB.ELEV- Lee BF.ELEV- 50.51' KOP • 940, !M.4AryY. IorpwlB iDMUR MD = Baer !DNMATVO- asor ss Minimum ID N 2.31" Q 8727' 2-7I8" X NIPPLE IN LTP w/ PTSA 1i2 X3 IWk2-7N•T(%'J7oL — 8724' Wellbore Schematic L-119A 41?' TSO. 12 Y, Ld0 MI 1. 0152 W. 0-2 Wr Nsi' r NElPaiaCKliZ/iv1a1 �-{ �— NOB �i-csa,2N,L-BD,67CLffO,O•Bne• J:.py�-� }IN_LNR.O.Y,ISCRN TCI OwBepLO-Z OS' I-y 0204• PERFORATERJSIAINARY REF LOG'. BM MMO-0R ON (12A71O0 ANGLE AT TOP PER': N• p T283S NoY: fib b ProwsMn Oe blwnnului Pam l,-- 13000' INAI'LNR,!l, ISCILNNwall. J iIN{• .awe MPL o • 244r BAPBTY NOTES: fin "AM=AVERAGE 1N Saw WHEN on all. ow"I�111111111[SASSSV WHEN ON •7. WELL ANGLE -TO-p MVr. MO Llf • 1014' JHSSN•TAN Po-Gou AR I oEV TYPE VLV IATCNI PORE 3 3 14e0 0 NS7 N Real pYY 4*r ER 0 wuANB uum ] )4A A]O3 4] NS62 TNIY IN 0 04N2O0 •1 BTa4 6373. 24 KBO2 MY ER 0 0702M %TA BI • COVERED BY A-IN-LNR 8717' I— j4WSSKRLIPrNSPulABTBgENjDR ) �Ji! 7w� z wig, 0.})1• i�11/I•xw• D-2iir MLLOMT ~OVV(L-I /M)BMM -NM' BIM' n Wlr x 27.B-Ko.0.2m- DATE REV BY I COMMENTS DATE R.EVBY COMMENTS BOTMA 3LALIOL OIg11L COMLt71DK COMM 1 JTC"MO IIUPERFS@WZ20)... _ - 'YMiM Iwoo C70 Bi µ.nMj OIIONlD JPktJMD OLV CN p/N7/t0) OL12N0 AO A N_ IWO7AM -=Tkl -- OLQ 3tCA2 - OSN4O GUSU BOREALIS UNIT WELL: L-11SA PERMIT No: ZLS-155 API No 50402843077411 NKewp NwY SYp, LLC I'HE S'I'A'1'E Alaska Oil and Gas °fALASKA Conservation Commission GOVERNOR MIKE'' DUNLEAVY 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov October 2, 2020 Mr. Oliver Sternicki Well Integrity Engineer Hilcorp North Slope, LLC. 3800 Centerpoint Drive Anchorage, AK 99503 Re: Docket Number: AIO-20-005 Request to amend the maximum allowable inner annulus operating limits on injectors which operate under existing administrative approvals. Area Injection Orders 3C, 4G, 22F, and 24B Prudhoe Bay Unit (PBU) Dear Mr, Sternicki: By letter dated March 9, 2020, BP Exploration (Alaska) Inc. (BPXA) requested administrative approval to change the inner annulus (IA) maximum operating pressure on 36 wells. This was requested in parallel with a BPXA request to increase the IA operating pressure for producing wells under Conservation Order CO 492. After the initial request was received from BPXA, Hilcorp North Slope, LLC (HNS) acquired BPXA North Slope assets July 1, 2020 and became operator of the PBU. On July 29, 2020, AOGCC received an email from HNS stating "Hilcorp, as the new operator of the BPXA assets has reviewed and approve of the submitted request to the AOGCC pertaining to increasing lA NOL in GPB." AOGCC issued CO 492A on October 1, 2020 that increased the notification IA operating pressure from 2000 psi to 2100 psi for PBU wells not processed through the Lisburne Production Facility. In accordance with Rule 9 of Area Injection Order (AIO) 4G and 24B, Rule 10 of AIO 3C, and Rule 11 of AIO 22F, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS HNS's request for administrative approval to change the maximum IA operating pressure for the 36 wells to 2100 psi as detailed in the accompanying table. The administrative action rules contained within the Area Injection Orders allow the AOGCC to administratively waive or amend the requirements of any rule as long as the change does not promote waste of jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in an increased risk of fluid movement into freshwater. DONE at Anchorage, Alaska and dated October 2, 2020. awn+�hn�es, Daniel T. . meq *. Jessie L. sly 10,V nW by mm rmmi.m,.va Jeremy kn,,,,a„e, r.„„,,,s,,. ou.:�o.�en,�,«,: Seamount,Jr. Chmielowski oxo.,uor was M. Price «� iza,:,a-mna Jeremy M. Price Daniel T. Seamount, Jr. Jessie L. Chmielowski Chair, Commissioner Commissioner Commissioner APPEAL As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall giant or refuse the application for reconsideration in whole or in pan within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is am included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on die next day that does not fall on a weekend or state holiday. AID # PTD Well AA Date AA mandated max IA pressure (psi) New AA mandated max. IA pressure (psi) 3C.001 1710380 A-03 12/19/2019 2000 2100 4E.024 1750690 NGI-04 4/29/2007 2500 2100 4E.032 1760140 NGI-05 6/9/2008 2500 2100 4F.002 1810740 17-08 4/3/2015 2000 2100 4G.009 1811770 11'07 12/12/2019 2000 2100 4F.006 1820260 13'17 12/7/2015 2000 2100 4F.008 1831700 14'27 5/23/2016 2000 2100 4G.001 1840280 0945 8/2/2016 2000 2100 38.001 1880700 W-24 3/15/2016 2000 2100 4E.017 1931850 14-01 2/21/2007 2000 2100 4G.006 1940130 04"13 4/6/2017 2000 2100 4F.007 1961440 x-33 4/11/2016 2000 2100 4F.004 1972180 13-06 7/9/2015 2000 2100 3.024 1982060 R-11 1/25/2017 2000 2100 4F.005 1982140 S-25 10/2/2015 2500 2100 38.008 1990530 S-11 3/6/2018 2000 2100 38.003 1991250 X'24 8/2/2016 2000 2700 4E.020 1991310 17'15 3/17/2007 2000 2100 3.025 2000090 N-08 1/14/2011 2000 2100 3.029 2001570 B-22 4/28/2010 2000 2100 22F.001 2011130 5-I07 1/7/2020 2000 2100 4F.001 2021240 PSI-09 3/6/2015 2000 2100 3.015 2051380 P-06 3/13/2007 2000 2100 4G.003 2051600 13-31 9/1/2016 2000 2100 38.006 2061050 Z-19 2/14/2017 2000 2100 38.009 2080930 V-05 11/14/2018 2000 2100 4E.039 2091390 0337 9/6/2011 2000 2100 3B.002 2101010 S-41 8/2/2016 2000 2100 24B.006 2111240 2-116 3/5/2019 2000 2100 4G.008 2141640 R-22 2/15/2018 2000 2100 3.03 2150660 P-10 9/11/2015 2000 2100 3C.002 1880330 W-35 4/27/2020 2000 2100 4G.008 2141640 R-22A 7/23/2020 2000 2100 4G.008 2141650 R-22AL1 7/23/2020 2000 2100 4G.010 2021450 PS1-01 8/10/2020 2000 2100 4G.011 2050200 17-13A 8/10/2020 2000 2100 Bernie Karl K&K Recycling Inc. P.O. Box 58055 Fairbanks, AK 99711 George Vaught, Jr. P.O. Box 13557 Denver, CO 80201-3557 Gordon Severson 3201 Westmar Cir. Anchorage, AK 99508-4336 Darwin Waldsmith P.O. Box 39309 Ninilchik, AK 99639 Richard Wagner P.O. Box 60868 Fairbanks, AK 99706 14 BP Exploration (Alaska) Inc. Ryan Daniel, Well Integrity Engineering Team Lead Post Office Box 196612 Anchorage, Alaska 99519-6612 March 9, 2020 RECEIVED Mr. Jeremy Price MAR 0 9 2020 Alaska Oil and Gas Conservation Commission 333 West 7'h Avenue A.OGICC Anchorage, Alaska 99501 Subject: Request to amend defined inner annulus normal operating limits on injectors operating under administrative approval. Dear Mr. Price, BP Exploration (Alaska) Inc. requests an amendment to the injection well administrative approvals listed in Table 1 such that the inner anulus (IA) normal operating limits (NOL) are changed to 2100 psi. The request to amend the IA NOLs of the wells listed in Table 1 is in parallel with a request to amend CO 492 such that IA NOL can be increase to 2100 psi for the majority of development wells in the Prudhoe Bay field. For consistency across the field the intent is to change IA NOL for all injection wells excluding: Class I disposal wells, Lisburne Injection wells, Well 09-16 (PTD: 1770370). Upon review of the AIOs governing Class II injection wells operated by BPXA there is no defined IA NOL except in the case of some select administrative approvals that have been granted. These defined IA NOLs are listed in Table 1. ORIGINAL Table 1: Administrative Approval List A 10 # PTD wall AA Date AA rrtandated �x IA pressure (psi) Current IA NOL (psi) 3C.001 171038D A-03 12/19/2019 2000 260C 4E.024 1750690 NGI-04 4/29/2007 2500 2000 4E.032 1760140 NGI-05 6/9/2008 2500 2000 4F.002 1810740 17-08 4/3/2015 2000 2000 46.009 18117/0 11-07 12/12/2019 2000 2600 4F.006 18202611 1317 12/7/2015 2000 2000 4F.008 1831700 14-27 5/23/2016 2000 2000 4G.001 184023D 09-25 8/2/2016 2000 2000 38.001 188D70D IW 24 3/15/2016 2000 2000 4E.017 1931850 14-01 2/21/2007 2000 2000 46.006 1910136 P443 4/6/2017 2000 2000 4F.007 1961440 X-33 4/11/2016 2000 2000 4F.004 1972180 13-06 7/9/2015 2000 2000 3.024 1982060 P-11 1/25/2017 2000 2000 4F.005 1982140 S-25 10/2/2015 2500 2600 3B.0D8 1990530 S-11 3/6/2018 2DD0 2000 38.003 1991250 X44 8/2/2016 2C00 2000 4E.020 1991310 17.15 3/17/2007 2000 2000 3.025 2060090 N-08 1/14/2011 20DD 2000 3.029 2001570 8-22 4/28/2010 2000 2000 22F.001 2011130 S-107 1/7/2020 2000 2000 4F.001 2021240 PSI -09 3/6/2015 2000 2000 3.015 21151380 P-06 3/13/2007 2000 2000 G.003 2D516W 13-31 9/1/2016 2000 2000 38.006 2DG1050 Z-19 2/14/2017 2000 -'- 38.009 2680930 V-05 11/14/2018 2006 - 4E.039 2091390 DM7 9/6/2011 2000 - 38.002 2101010 S-41 8/2/20162000 - -- 248.006 2111240 Z -11E 3/5/2019 2000 ---u 4G.008 2141540 R-22 2/15/2018 2000 =- 3.03 2150660 P -1C 9/11/2015 1200C If you have any questions, please call me at 564-5430 Sincerely -w, Ryan Daniel BPXA Well Integrity Team Lead Attachments: Technical Justification Technical Justification for Administrative Approval Amendment March 9, 2020 History and Status: BPXA is currently in the process of requesting an amendment to Conservation Order No. 492 rule 3(a) and 6(a) (Docket Number: CO -20-004) to facilitate the increase of IA NOL to 2100 psi for Prudhoe Bay field development wells excluding those processed through the Lisburne Processing Center and jet pump wells based on the following. Gas lift header pressure at many of the drill sites and pads in the Prudhoe Bay field (excluding wells processed through the Lisburne Process Center) regularly exceeds the 2000 psi IA NOL set for development wells. Gas lift compressor outlet pressures are commonly set at 2100 psi. Historical gas lift pressures can be seen in Figure 1 & 2 for reference. The legacy IA NOL value of 2000 psi was set to remain compliant with Conservation Order No. 492 rule 3(a) and 6(a). Prior to the installation and monitoring of wireless annulus pressure gauges this was not as large of a problem due to one IA pressure read being recorded via mechanical gauge daily per well. If a pressure read exceeded the 2000 psi NOL it was reported to Well Integrity and evaluated to determine if the excursion was SCP or not. Currently all wells in the Prudhoe Bay field have the inner annulus pressures monitored in real-time by either the EOA or WOA production center board operators. The board operators are notified with an alert when the IA pressure of a well exceeds the set NOL value of 2000 psi. This ensures a timely notification and response to any potential excursion event. With the utilization of the wireless annulus pressure gauge alerting it has become an ongoing problem where wells supplied with gas lift pressure are regularly setting off alerts due to the gas lift supply pressure exceeding the 2000 psi NOL and not due to SCP as intended. This excessive alerting has the potential to desensitize workers to possible hazardous occurrences. Increasing IA NOL from 2000 psi to 2100 psi for development wells would eliminate the majority of these false NOL excursion alerts and allow resources to be more focused on response and evaluation of probable SCP events. All development wells are included in this request in an effort to reduce the complexity of the IA NOL change and management across the Prudhoe Bay field. This reasoning for reduced complexity in management of IA NOLs extends to injection wells in the Prudhoe Bay field. Alignment with the change applied to development wells is important to minimize variability of IA NOLs and simplify the management of all wells. The majority of injection wells in the Prudhoe Bay field currently have IA NOLs set to 2000 psi. This 2000 psi NOL was applied by BPXA for consistency across the field and is not tied to a requirement in an Area Injection Order other than for specific Administrative Approvals on individual wells listed in Table 1 which is what BPXA is requesting amendment to. The intent is to change IA NOLs for all injectors to 2100 psi excluding Class I disposal wells, Lisburne Injection wells and Well 09-16 (PTD: 1770370). This increase of 100 psi to the IA NOL is well within the design parameters of injection wells across the Prudhoe Bay field and the IA NOL increase would not reduce the ability to identify possible annular communication in these wells. I.. 3ti}/p35 Figure 1- EOA DS Gas Lift Header Pressure EOA Gas Lift Pressure 5/1/}03s 6/}W 1035 BS/E015 9/}&}O15 ..iJ'/dL5 .6t30.6 Figure 2- WOA Pad Gas Lift Header Pressure WOA Gas Lift Pressure }/1ID5 6_u.03 Bry/}y5 9)RYA15 IIJI)/3035 1/6/}Ol6 Mle —os m —cs m —cs m —os cs —os:} —os:< —DS±6 —02:1 —Tip —B Pad — n Pad —t Pad Pad ad —x Pae P Pad P Pad —s Pm —u Pae PPO I Pad 11. . Pad Z Pad 13 BP Exploration (Alaska) Inc. Ryan Daniel, Well Integrity Engineering Team Lead Post Office Box 196612 Anchorage, Alaska 99519-6612 February 22, 2019 'Es`�' iva Hollis French, Chair FEB G ��.� Alaska Oil and Gas Conservation Commission 333 West 7th Avenue ,., Anchorage, Alaska 99501 �,�GICL.e Subject: Prudhoe Bay Well Z-116 (PTD #2111240) Request for an Administrative Approval for WAG Injection Operations Dear Mr. French, BP Exploration (Alaska) Inc. requests an Administrative Approval (AA) for water alternating gas (WAG) injection into Prudhoe Bay well Z-116. No increase to normal operating limit (NOL — formerly MOASP) is required. Z-116 was identified to have anomalous IA repressurization in January 2018. At that time, the repressurization rate was 15 psi/day. Before applying for an AA, BPXA replaced the existing dummy gas lift valves with extended packing dummy gas lift valves, in an attempt to mitigate the IA repressurization. This slowed the repressurization rate to 5 psi/day. In preparation for the administrative approval request, an AOGCC witnessed MIT -IA was performed on 02/23/18 and passed to 3,238 psi. Wireless gauges have been installed on Z -pad wells that allow for real time monitoring of IA and OA pressures. BPXA has determined that well Z-116 is safe to operate in its current condition and requests an AA for WAG (including MI) injection based on the following: • IA pressure stabilizes below NOL and should not require bleeds during normal operation. • MIT -IA passed to 1.1 times maximum anticipated injection pressure. • IA and OA pressures will be monitored with wireless pressure gauges. If you have any questions, please call me at 907-564-4301 or Jack Lau/Adrienne McVey at 559- 5102. Sincerely, Oliver Sternicki BPXA Senior Well Integrity Engineer Attachments Technical Justification TIO Plot Injection Plot Wireless Gauge Plot Wellbore Schematic Cc: Doug Cismoski Lau/McVey GC2 Operations Team Leader Cale Peru Ryan Daniel Oliver Sternicki Beau Obrigewitch Prudhoe Bay Well Z-116 Technical Justification for Administrative Approval Request February 22,2019 Well History and Status Well Z-116 is a horizontal Kuparuk WAG injector that was drilled and completed in December 2011. The well has perforations in 3 different fault blocks. The well has been on Miscible Gas Injection since August of 2016. IA repressurization occurred in January of 2018 and is currently classified as Not Operable. Recent Well Events: >11/19/2018 Put on MI Injection w/ IA build-up rate — 4 psi/day >5/19/2018 DGLVs w/extended packing set in STA #1,2&3; Verified set with passing IA pressure test to 1259 psi >2/23/2018 AOGCC MIT -IA Passed to 3238 psi >2/14/2018 PPPOT-T Passed >1/18/2017 MIT -IA Passed to 3151 psi >1/17/2017 PPPOT-T passed >1/7/2017 PPPOT-IC passed >7/31/2016 AOGCC MITIA passed to 2700 psi >5/27/2014 PPPOT-IC Passed >8/2/2012 AOGCC MITIA Passed to 2500 psi >4/8/2012 Treated conductor w/22.1 gal RG2401 >3/29/2012 MIT -IA Passed to 3000 psi >3/28/2012 Set DGLV in #2 & #3 >2/16/2012 Set LGLV #3 & OGLV #2. pulled RHC @ 12309' >12/26/2011 Rig MIT -IA Passed to 4000 psi Barrier and Hazard Evaluation The primary and secondary barriers systems consist of the tubing and production casing and associated hardware. A passing pressure test of the inner annulus to 3,238 psi, which tests both barriers, demonstrates competent primary and secondary barrier systems. Pressure on the inner annulus will be maintained below the normal operating limit of 2000 psi when the well is on-line. Proposed Operating and Monitoring Plan 1. WAG injection (including MI). 2. Record wellhead pressures and injection rate daily. 3. Submit a report monthly of well pressures and injection rates to the AOGCC. 4. Perform a 2 -year MIT -IA to 1.1 x maximum anticipated injection pressure. 5. The well will be shut-in and the AOGCC notified if there is any change in the wells mechanical condition. e CB: }kn l a(t 12fX r� tW1JI 2a 22N 2WP :x 6A fA) Yf TIO Plot 1'/un L116 The range on the left shows TIO pressures during previous The range on the right shows TIO injection period (before setting extended packing DGLVs) pressures during trial injection period (after setting extended packing DGLVs). T10 plm 1m f Tbg 14 t IA —� OA 1A� Opp ♦ OOOA W@ —On ■ Need W + 0"61. + Not Oper ♦ Under EvI Temperature W A The range on the left shows TIO pressures during previous The range on the right shows TIO injection period (before setting extended packing DGLVs) pressures during trial injection period (after setting extended packing DGLVs). Injection Plot Well Z-116 122&. '.1 G9+8 i-ue elCEo .RAIe .lSI51C 0125@ C+Z,19 Ot '1P, P5PIPP .81518 '529118 M1213 C526'19 W189 0 _ ..., ... 11 _.. _11_ The range on the left shows injection pressure and rate during previous injection period (before setting extended packing DGLVs). C 3^G iCn6 lq iOCC —WHIP —Av W a —MI GI —pyla The range on the right shows injection pressure and rate during trial injection period (after setting extended packing DGLVs). Wireless Gauge TIO Plot :: c o r Real time pressure data during same time frame, transmitted via wireless gauges. e w X55. 12415' 9518' CSG. 400, L-80 BTO, D = k835' —F -6345 - Minimum ID =3.725' @ 12309' 4.12" HES XM NPPLE 7 -CSG, 2fi#,L-90 VAMTOPNC 11953' XD 70 LSO TCtt P9FCRATDN SL941MRY ni LOU SL600J GFV 13C ON 1222111 ANGLEATTOP f6i'' 98-a 1283P NDW fifer b Produc50n DA far hsbricat pert date SIZE I SPF I METHAL OpNS4z DATE 2-714 6 12430-f29D O 1223!11 2-716' 6 12880-132W O 1225'11 2-718 6 15250 -15459 O 1225'1 i 2-718 6 15600-1590D O 122321 2-78' 6 16050-1540D O 1223711 2-718' 6 17180-17UD O 122V11 Z-116 "M -W NOTES: W ELLANOLE- 70' ® 2954• .015260(. D=3-956' D=3.813' GAS LFT 1MNDR3-S St MD 7VD LTeV TYPE VLY LA F iT DATE -3 ®521 3361 8B 1®G2 CW BK 0 05119/16 7 10600 5901 43 1®62 pM BK 0 05119118 '1 12097 6489 46 KOW OLN BK 0 052926 'STA 9 3.2. i 1 -E aE/M FTSID&83863 PHS FESX MLLOUT WNDO.a(Z-116) 12602 - 13616' DATE REV BY I OMANT5 H cAiE-T FLv BY i COWARaS 127/11 M14 OFNGMLCOMPLEr= 0523/18 O"JMGGLVO'O05119/18) 0wm PJC Of8.0 CRA" COfalB. RFu 017J1N2 M47 RIC FML CRG OOFWaHONS 02RNi2 SWCI OlV rlO (07/18!12) 0407/12 M351PJCGLV0O(329012) 07/1527 WAD Ar ANGYfCOfS>BCIDN SEr. PR D)DEBAY Wr WELL: Z-116 FDSAT Na: 2111246 An M: 50.02943455-00 DA BB11orM1w (Alskal 12 BP Exploration (Alaska) Inc. Ryan Daniel, Well Integrity Engineer Team Lead Post Office Box 196612 Anchorage, Alaska 99519-6612 January 10, 2017 Ms. Cathy P. Forester Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 ECEIV E� by JAN 13 2017 AnGCC 0 Aw Subject: Prudhoe Bay Well L-105 (PTD # 2020580) Request for Amendment to Administrative Approval AIO 246.005 Dear Ms. Forester, BP Exploration (Alaska) Inc. requests an amendment to Administrative Approval (AA) Area Injection Order (AIO) 24B.005 for continued water alternating gas (WAG) injection into Prudhoe Bay well L-105 with an increase in outer annulus (OA) normal operating limit (NOL — formerly MOASP) to 1500 psi. Well L-105 was approved for continued WAG injections per AA AIO 246.005 on March 4, 2016 for OA repress u rization. The OA pressure now stabilizes at 1100 psi. BPXA requests an amendment to AIO 246.005 to include raising the OA NOL from 1000 psi to 1500 psi. An engineering analysis and well barrier risk assessment have been completed and it has been determined that raising OA NOL to 1500 psi is well within the design limits of the installed equipment. In summary, BPXA has determined that Prudhoe Bay well L-105 is safe to operate with the increase in OA (7" x 9-5/8") NOL to 1500 psi. BPXA requests amendment to AIO 246.005 for continued WAG injection operations. If you have any questions, please call me at 748-1140 or Jack Lau/ Adrienne McVey at 659- 5102. Sincerely, t' Ryan Da BPXA Well Integrity Engineering Team Lead Attachments Technical Justification TIO Plot Injection Plot Wellbore Schematic Cc: Doug Cismoski Lau/McVey GC2 Operations Team Leader Ryan Rupert Ryan Daniel Prudhoe Bay Well L-105 Technical Justification for Administrative Approval Request January 10, 2016 Well History and Status L-105 was drilled and completed in 2002. The initial primary cement job of the 7" casing was aborted when the cement began setting up in the batch mixer. An attempt was made to circ out the approximately 8 bbl of cement that had been pumped prior to abandoning the job, and it was initially thought to be successful. After circing, 20 bbl of drilling mud was pumped down the 7"x9- 5/8" annulus to ensure injectivity in the event freeze protect was required. For the next 10 hours, mud was pumped, 10 bbl at a time, every 20 minutes while the 7" was reciprocated. The primary cement job was then pumped, with the assumption that —148 bbl cement was placed behind pipe (calculated TOC — 2827'; SC Shoe at 2856'). The day after the cement job, an attempt was made to inject in the 7"x9-5/8" annulus. It pressured up to 4,200 psi. The casing head was removed and a "doughy mix" of cement and drilling mud was encountered. Attempts were made to dissolve/flush the substance, but were unsuccessful. The annulus would pressure up to 4,200 psi with no injectivity, and then bleed off to 3,000 - 3,200 psi, until pressure was finally intentionally bled off to zero. Once the well was put on injection, the OA would pressure up to 1,000 — 1,100 psi, but periodic bleeds were unable to manage pressure below NOL of 1,000 psi. The OA pressure source is 99.3% methane and less than .1 % CO2 (sample taken 11/5/11) which indicates that the gas is from shallow hydrates. In 2006, an Administrative Approval was granted by AOGCC for continued operation of L-105 with elevated OA pressure. This AA was amended in 2016 to remove the OA injection testing and changed the MIT -IA frequency to every 2 years. Historically this well has exhibited very low OA LLRs between 0.06 gpm to 0.73 gpm @ 3,000 psi. Based on the verification of mechanical integrity of two barriers via multiple passing MIT-IAs and the established very low LLRs of the OA, a deviation is warranted to raise the OA NOL to 1,500 psi. Raising NOL will also reduce the risk associated with multiple and repetitive OA pressure bleeds currently required to maintain OA pressure below current NOL of 1,000 psi. Recent Well Events: > 07/20/02: Rig MITIA Passed to 4000 psi > 11/01/02: MITIA Passed to 2250 psi, AOGCC. Initial IA FL @ 1050' > 03/23/03: MITOA Passed to 2000 psi > 06/14/04: CITOA Passed to 3000 psi, LLR = 0.75 gpm > 06/17/04: PPPOT-T Passed to 5000 psi, PPPOT-IC Passed to 3200 psi > 06/24/04: AOGCC MITIA Passed to 4000 psi > 10/19/05: MITOA Failed LLR < 1 gpm > 11/28/05: AOGCC MITIA Passed to 4000 psi > 01/18/06: AOGCC approved AA 24.004 for continued injection with SCP on the OA > 11/21/06: LLR-OA=0.063 gpm > 11/26/06: MITIA Passed to 4000 psi > 12/11/06: AOGCC MIT -IA Passed to 4000 psi > 10/12/07: MITIA Failed on stabilization > 10/17/07: MITIA Passed to 2000 psi > 11/04/07: AOGCC MITIA Passed to 4000 psi, LLRT OA to 3000 psi =.38 gpm > 10/02/08: AOGCC MITIA Passed to 4000 psi > 10/03/08: LLRT OA 0.6 gpm 3000 psi > 10/01/09: MITIA Passed to 4000 psi > 10/07/09: MIT -OA Failed, LLR— 0.31 gpm > 10/30/09: AOGCC MITIA Passed to 4000 psi, LLR-OA for AA = .31 gpm > 09/05/10: MIT -IA Passed to 4000 psi > 09/06/10: AOGCC MIT -IA Passed to 4000 psi > 09/23/10: LLR-OA for AA = 0.46 gpm > 02/10/11: MIT -IA Passed to 4000 psi > 02/20/11: AOGCC MIT -IA Passed to 2500 psi > 03/03/11: LLR-OA for AA = 0.73 gpm > 11/05/11: OA gas sample 99% ME > 11/30/11: CMIT-TxIA Passed to 3000 psi > 01/03/12: Pre-AOGCC MIT -IA Passed > 01/28/12: AOGCC MITIA Passed to 4000 psi, LLR-OA (AOGCC waived) of 0.12 gpm @ 3000 psi > 01/17/13: PPPOT-IC Passed to 3500 psi, pre AOGCC MIT -IA Passed to 4000 psi > 01/20/13: AOGCC MITIA Passed to 4150 psi, MIT -OA Failed (C. Scheve) > 01/27/13: AOGCC MIT -OA Failed, LLR= 0.4 gpm @ 3000 psi (B. Noble) > 12/30/13: MIT -IA Passed to 4000 psi > 01/08/14: AOGCC MIT -IA Passed to 4000 psi; LLR-OA 0.09 gpm @ 3000 psi > 07/02/14: PPPOT-T Passed, PPPOT-IC Passed > 09/19/14: MIT -IA Passed to 2500 psi > 03/26/15: MIT -IA Passed to 4100 psi > 04/03/15: AOGCC MIT -IA Passed to 4100 psi LLR OA 0.374 gpm @ 3000 psi > 01/05/16: MIT -IA Passed to 4200 psi > 01/09/16: AOGCC MIT -IA Passed to 4114 psi, AOGCC OA LLR=0.187 gpm Barrier and Hazard Evaluation The primary and secondary barriers systems consist of the tubing and production casing and associated hardware. A passing pressure test of the inner annulus to 4,200 psi, which tests both barriers, demonstrates competent primary and secondary barrier systems. Pressure on the inner annulus will be maintained below the normal operating limit of 2000 psi when the well is on-line. Proposed Operating and Monitoring Plan BP will continue to comply with the conditions provided by the AOGCC from AA AIO 24B.005. BPXA shall limit the well's outer annulus pressure to 1500 psi. Well L-105 TIO Plot --f Tbg S._ L -OA ODA -- OOOA On 2 7,00 2.640 2.560 24W 2.306 2200 2,100 z4M soy 1-100 Cm +.404 s '.200 i:Jfk^ KO 5th .00 600 500 400 306 246 t40 01.4 Well L-105 Injection Plot 5,500 5.600 5.400 5 200 5,000 4 F 4w 4,400 4200. c.ca, NC' 3.61k 2,40D 20C X0 "Sw T 2,400 2200 2,Ow 1300 1600 1 400 740 i 00O 2100 1w AOD 200 — WHIP SW — pw —M1 --GI Ot- �(M TFfE = 4-1116' aW MBLHFAD= FMC ACTl14TOR= BAKURC m -B. My = Mr BF. ELEV a 24.94' K(* -m- khx A-4- 4W 46* 6446 [ Datum AAD 815C L DaiurrNd . C,,,I�DUCTop L-WBTC, lD=&83S- Minimum ID = 3.72F@ T873- 4-1/Z'HES XN NIPPLE 41 r TBG, I2.60. L-80 TC! 0152 bpf, K) = 1958' FERFORkTION SUL&VJ;rY WF LOGS: SCAJEEZE F13iF FWDOFID ANGLEATTOPPEW: 31*@8017 ND*: Refer W Roductoo DB for hisiomd pert data SIZE SPF KrERV-kL qxv'Sw SkM SQZ 4-112' 6 7700 - 77" S 07117114 07118W 4-112' 6 7785-7805 5 0 WI% 07118102 3-38" 6 8012-8032 0 owlaw 4112' 6 8023 - BM 0 0719102 3-318' 6 8040- 8074 0 ffinaw 3-38r 6 8104-8110 0 SAFETY NOTES: H2S READINGS AVERAGE 125 ppm L- 05 VA*N ON MI — WELL REQUIRES A SSSV WHEN ON 1 Ul- -j9--WTAM "ff0MLMj 3 1755669 16166 137 IKBG-2I I1aO9/I07r1 DOW BK 0 10/1302 TUG' H4-lrzMixwlD=3.8IT U 3.89' 78ir h4.112"HESXHP.ID=3.913' 1 7873' H4-irr"is xNNP, ID=&72s* I wl - I BOF FA LIS UNT vyrLL, L-105 Fgasr w: %20w API No; 5"29-23075-W SM 34, T12K Rl I� 2416'FSL & 110T FWL SP 8KPI0raUM (Akokis) 6712I102 WAR OPIGNIAL COMPLETION 101117)12 TMWJLMD A MS SArM NOTE 08IM02 RLMh G-VLlPCATE &i"j[WK- 2�7130114 nVWJJRE 08127114 TBIDI PJC SET RIWTHRU SM (07113114) PULL GAUGM 10M302 JaKAK GLV GO Ml2M4 JAW PJC SET CW VALVFJ FS 0410603 Dr3fTP TVDM 03W43CTIONS 09115M4 AN PJG UMY GLV # 3 02115111 MIMAWD ADDED, SSSV SAFETY fIOTE wl - I BOF FA LIS UNT vyrLL, L-105 Fgasr w: %20w API No; 5"29-23075-W SM 34, T12K Rl I� 2416'FSL & 110T FWL SP 8KPI0raUM (Akokis) 11 BP Exploration (Alaska) Inc. Oliver Sternicki, BPXA Well Integrity Engineer Post Office Box 196612 Anchorage, Alaska 99519-6612 February 19, 2016 Ms. Cathy P. Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 RECEIVED by FEB 2 9 2016 AOGCC 0 Subject: Prudhoe Bay Unit Well L-105 (PTD #202058) Request for amendment to NO 24.004 Dear Ms. Foerster, BP Exploration (Alaska) Inc. requests an amendment to Administrative Approval NO 24.004 for continued gas injection into PBU L-105 (PTD #202058) Well L-105 was approved for continued gas injection on January 18, 2006 per NO 24.004 due to high OA pressure. BPXA would like to request two amendments to A10 24.004, these are to change the MIT -IA frequency from 12 months to 24 months and eliminate the LLR-OA requirement. The first requested change is to the required condition for BPXA to perform an annual MIT -IA to 4000 psi. L-105 has passed 19 MIT-IAs to 4000 psi since 2006. Competent primary and secondary barriers have been proven over the last 10 years with no evidence of impairment. BPXA requests to change the required MIT -IA frequency to every 24 months. The second requested change is to the required condition that BPX perform an annual LLR-OA to 3000 psi. The purpose of the required LLR test was brought into question in correspondence between BPXA and the AOGCC in January 2014. The AOGCC response was that testing the OA holds no value. The AOGCC recommendation was to revise NO 24.004 to remove this requirement. In summary, BPXA requests to revise conditions 3 and 4 of NO 24.004 for continued gas injection. If you have any questions, please call me at 564-4301 or Whitney Pettus/ Kevin Parks at 659-5102. Sincera� OliverStem BPXA Well Integrity Engineer Attachments: Email Correspondence TIO Injection Plot Wellbore Schematic Cc: Pettus/ Parks GC2 Operations Team Leader James Schrider Ryan Daniel Doug Cismoski L-105 Email Correspondence between BPXA and AOGCC: From: Regg, James B (DOA) [mailtoJim.recIg@)alaska.gov] Sent: Wednesday, February 05, 2014 12:01 PM To: AK, D&C Well Integrity Coordinator; Wallace, Chris D (DOA) Cc: Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Subject: RE: PBU L-105 (Admin Approval 24.004) Based on your response, I see zero value in the LLRT-OA (no analysis; no criteria; no standardized approach). My recommendation is to revise the Admin Approvals that rely on LLRT's as condition of approval. Specific to PBU L-105 (AIO 24.004), confirming tubing and IA as barriers to injected fluid release should be sufficient justification for continued injection. There is no value in testing the OA when you know it will fail; gas sample analysis is option as required in AIO 3.025. Spreadsheet is attached in Excel and pdf versions. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: AK, D&C Well Integrity Coordinator[mailto:AKDCWellIntegritvCoordinator@bp com] Sent: Wednesday, February 05, 2014 11:11 AM To: Regg, James B (DOA) Cc: Brooks, Phoebe L (DOA); Wallace, Chris D (DOA) Subject: RE: PBU L-105 (Admin Approval 24.004) Good morning Jim, I apologize for the delay. Below is a summary of my findings. A leak rate test is typically done to determine what type of diagnostic/intervention work needs to be done when investigating an anomaly. The purpose of the annual liquid leak rate for L-105 was to ascertain if downhole conditions changed. No criteria was established for what an acceptable rate would be. The rate has changed slightly from year to year due to how small a volume used, temperatures, etc. If there was a change on some order of magnitude, this would not necessarily indicate a deterioration in the wellbore integrity; rather a change in condition of the OA shoe. The annual MIT -IA confirms integrity, not the OA test. There is another WAG well that has an external hydrate source: N -08A (PTD #2000090). For this well AIO 3.025 requires a 2 year MIT -IA and a 2 yr OA gas sample. This would be an alternative method to confirm the OA gas is dissimilar to the injected gas. 4. The spreadsheet you sent has become corrupted — do you mind resending it? Thank you, Laurie Climer (Alternate: Jack Disbrow) BP Alaska Well Integrity Coordinator GuIV r WIC Office: 907.659.5102 WIC Email: AKDCWellintegrityCoordinatorgBP.com From: Regg, James B (DOA) [mailtoJim.regg alaska.gov] Sent: Tuesday, February 04, 2014 11:21 AM To: AK, D&C Well Integrity Coordinator Cc: Brooks, Phoebe L (DOA); Wallace, Chris D (DOA) Subject: RE: PBU L-105 (Admin Approval 24.004) Any progress addressing my 3 questions? Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Regg, James B (DOA) Sent: Wednesday, January 15, 2014 10:32 AM To: 'AK, D&C Well Integrity Coordinator' Subject: RE: PBU L-105 (Admin Approval 24.004) Laurie — Thanks for your time investment in gathering this information and for discussing Leak Loss Rate (LLR) tests with me this morning. As noted during our conversation, ultimately I am trying to understand the LLR test in the context of what we are doing with injection well administrative approvals where the conditions of approval establish boundaries for continued operation. Typically we have a pass -fail criteria associated with a test that allow us to determine when conditions warrant further evaluation or suspending injection activities until repairs can be completed. According to our records, there are only 2 wells that have the LLR test as part of an AA condition of approval — PBU L-105 (PTD 2020580; AIO 24.004) and PBU 11-29 (PTD 1940520; Sundry 303-288), so the LLR test is unusual (from the injection waiver standpoint). To reiterate my questions: 1) What is the purpose of a LLR test? 2) Is there any pass -fail criteria for the LLR test? If just used to trend the rate, what deviation from the trend becomes a concern? 3) Is there something else (other than LLR test) that assures us the well has proper integrity to continue injection operations? Also as mentioned, I have attached a simple spreadsheet that calculates the LLR from info presented in the MIT forms and WSR's you provided. Several of the tests calculate differently than reported — these are highlighted. Thanks again for your help. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: AK, D&C Well Integrity Coordinator[mailto:AKDCWeIIIntegrityCoordinator(cbbp com] Sent: Tuesday, January 14, 2014 12:36 PM To: Regg, James B (DOA) Subject: RE: PBU L-105 (Admin Approval 24.004) Jim, Volumes pumped were recorded in the WSR, however were not documented on all of the spreadsheets provided. I have amended the reports that did not include the volume used, and added copies of the WSR for those years. Regards, Laurie Climer (Alternate: Jack Disbrow) BP Alaska - Well Integrity Coordinator GW WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator(a.,BP.com From: Regg, James B (DOA) [mailto:jim.regg alaska.gov] Sent: Tuesday, January 14, 2014 10:11 AM To: AK, D&C Well Integrity Coordinator Subject: RE: PBU L-105 (Admin Approval 24.004) How are you calculating a leak rate without knowing the volumes of fluid pumped? Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: AK, D&C Well Integrity Coordinator [mailto:AKDCWellIntegrityCoordinator@bp.com] Sent: Monday, January 13, 2014 3:48 PM To: Regg, James B (DOA) Cc: Wallace, Chris D (DOA) Subject: RE: PBU L-105 (Admin Approval 24.004) Jim, Attached is a zip file with the OA-LLR forms enclosed. The form for the test performed on 9/23/10 was not in our archives, however I used the Well Service Report (enclosed) to put the data into standard formatting. Regards, Laurie Climer (Alternate: Jack Disbrow) BP Alaska - Well Integrity Coordinator / w1v.7 WIC Office: 907.659.5102 WIC Email: AKDCWelllntegri!yCoordinator@BP.com From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, January 13, 2014 2:56 PM To: AK, D&C Well Integrity Coordinator Subject: RE: PBU L-105 (Admin Approval 24.004) Yes, provide the data that substantiates the leak rates. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: AK, D&C Well Integrity Coordinator [mailto:AKDCWeI[IntegrityCoordinator@bp.com] Sent: Monday, January 13, 2014 2:51 PM To: Regg, James B (DOA) Cc: DOA AOGCC Prudhoe Bay; Wallace, Chris D (DOA) Subject: RE: PBU L-105 (Admin Approval 24.004) Jim, Below are the recorded dates and rates for the requested OA liquid leak rates obtained on Injector L-105 (PTD #2020580) from 2007 onwards. Do you need copies of the report spreadsheets? Date Pressure Notes 1/8/2014 3000 LLR-OA 0.09 gpm, witnessed by Jeff Turkington 1/27/2013 3000 LLR-OA.4gpm, witnessed by Bob Noble 1/28/2012 1 3000 LLR-OA .012 gpm, witness waived by C. Schieve 3/3/2011 3000 LLR-OA 0.73 gpm, witnessed by Lou Grimaldi 9/23/2010 3000 LLR-OA 0.46 gpm, witness waived 10/30/2009 3000 LLR —.31 gpm witnessed by Chuck Scheve 10/3/2008 3000 LLR OA =.60 gpm witnessed by John Crisp 11/4/2007 3000 LLR OA = .38 gpm, witness waived by John Crisp Regards, Laurie Climer (Alternate: Jack Disbrow) �B^P+Alaska Well Integrity Coordinator 1.]N WIC Office: 907.659.5102 WIC Email: AKDCWe111ntegrilyCoordinatorkBP.com From: Regg, James B (DOA) [mailtoJim.regg@alaska.gov] Sent: Monday, January 13, 2014 11:54 AM To: AK, D&C Well Integrity Coordinator Cc: DOA AOGCC Prudhoe Bay; Wallace, Chris D (DOA) Subject: PBU L-105 (Admin Approval 24.004) Admin Approval 24.004 (effective 1/18/2006) requires an annual LLR-OA and MITIA. AOGCC records include the results of the required annual MITIAs; the LLR-OA records are incomplete. Please provide data from the LLR tests beginning in 2007. 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ELEV = KCIP= Frex AACIS = 24.84• 400r 49- C 8448 Datum KC 8158' jDalumfVD—= WWSS --M BTG 9)=8.835' [Fikii-n6u-tiT6 3.726r@7873'-" 44-112" HES XN NIPPLE 4 -Ur 796,12.6#, L-80 TM .0152W,10=3.958' FERFC)PATKM SUMMARY Fff LOG SOUEEZE PEW RMORD ANGLEATTOPPERF. 31-@80I2' Note: Te riD Pmducim DB for historical ped data SIZE SPF KFERVAL nfflW SHN SM 4-I2• 6 7700 - 7720 S 07/17/14 07118W 4-12• 6 7785 - 7805 S OM 7114 OVUM 3-38' 6 8012 - SM2 0 olviaw 417 6 SM - 0043 0 07118w 3 -MW 6 aM -8074 0 08118/02 3-318' a 8104-8110 0 061 7 - CSG, 2j9#.L-ODBTr—K.0383W,K)=6.27ir L-105 Schematic "FM WTM; 009 IVAUMM "M%GE In ppm WH84 ON M I — WEL L RE40WRES A S3$V WWM ON L-1 05 At# TAM PORT 65ED�Rj . TOW 4-112• HES 76W 7- X,& I!rE-- BWMR FFREEM F ID =3.89 fair 4 IZ HEM X NP, 0 = 3.813r- 7'X4-12•WRS-3P0tI)=3.875l 7652' -d4-IMHBs XNP. 6;T8l3-j 7=�Mwp MTE REV By OCIAMENTS CATE REV BY COM MS GAS LIFT MANOR IS OV17112 V MD TVD DEV TYPE VLV LARCH PORT DAM 3 3966 3489 rj_ 41 KBG-2 DW 0 I 09M5114 14014302l 2 5 5 44911 42 KBG-2 OW OK 0 S 072M 1 7569 6186 37 KBG-2 OMY BK n . TOW 4-112• HES 76W 7- X,& I!rE-- BWMR FFREEM F ID =3.89 fair 4 IZ HEM X NP, 0 = 3.813r- 7'X4-12•WRS-3P0tI)=3.875l 7652' -d4-IMHBs XNP. 6;T8l3-j 7=�Mwp MTE REV By OCIAMENTS CATE REV BY COM MS 0721102 NKK ONGMLCOMPLEFION OV17112 ADDO H25 SAFEFY ROM 0805102 -.!��Av--Tlp �TE MI&02 JLYKK ADFa*S 07Wl4SVJQU W27114 TBO SUFLOWTHM SUB (07113114) ------- RJLL GALXXS 10/002 JMAK GLV(YO 09M114 AM SET CFC VALV 0 FS 041081DRSW TMIADOURFECTKAS 09115114 JTW PJJDW GLV Al 3 .02115111, MEYJMD,ADDEDSSSV SAFETY NOTE I i BOFFALIS LW WELL L-105 PffW W: 02020580 AFllNo: 50-029-23075-M Sir, 34, T12K RIlF- 2416 FSL & 1707 HP EkpkwaMm (Alaska) June 6, 2013 Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue Suite 100 Anchorage, AK 99501 Attention Mr. David Roby Dear Mr. Roby: Thank you for your request for clarification regarding the RCRA status of the radioactive tracers to be used in the upcoming study at GC2. The GC2 Capacity Study involves the injection of low level radioactive tracers upstream of the slug catchers in GC2 to study the separation efficiency of various vessels. Once injected into the vessels, the tracer will be commingled with production fluids at the gathering center, follow the normal separation process, and be routed to the Class 11 well system for either enhanced oil recovery or injection. The project is scheduled to start June 20, 2013. Here are responses to your questions: 1. Evidence and legal authority in support of BP's assertion that radioactive tracer wastes are not regulated under RCRA; RCRA regulates hazardous solid wastes. Therefore, the threshold question when determining the RCRA status of a material is whether it is a "solid waste." In order to be a solid waste, a material must be "discarded." RCRA section 1004(27).1 Therefore, products being used for their intended purposes are not wastes because they are not being discarded. In this case, the facility will be injecting low level radioactive tracers upstream of the slug catchers in GC2 to study the separation efficiency of various vessels. The purpose of this injection is not to discard or dispose of the tracers, but to utilize them for their intended, useful purpose (conducting the separation efficiency study). RCRA does not regulate this activity because the purpose of the injection is not to discard the tracers. 1 42 U.S.C. § 6903(27). BP Exploration (Alaska) Inc. 900 E. Benson Blvd P. 0. Box 196612 Anchorage, AK 99519-6612 USA Main 907 561 5111 Fax 907 564 5020 Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue Suite 100 Anchorage, AK 99501 Attention Mr. David Roby Dear Mr. Roby: Thank you for your request for clarification regarding the RCRA status of the radioactive tracers to be used in the upcoming study at GC2. The GC2 Capacity Study involves the injection of low level radioactive tracers upstream of the slug catchers in GC2 to study the separation efficiency of various vessels. Once injected into the vessels, the tracer will be commingled with production fluids at the gathering center, follow the normal separation process, and be routed to the Class 11 well system for either enhanced oil recovery or injection. The project is scheduled to start June 20, 2013. Here are responses to your questions: 1. Evidence and legal authority in support of BP's assertion that radioactive tracer wastes are not regulated under RCRA; RCRA regulates hazardous solid wastes. Therefore, the threshold question when determining the RCRA status of a material is whether it is a "solid waste." In order to be a solid waste, a material must be "discarded." RCRA section 1004(27).1 Therefore, products being used for their intended purposes are not wastes because they are not being discarded. In this case, the facility will be injecting low level radioactive tracers upstream of the slug catchers in GC2 to study the separation efficiency of various vessels. The purpose of this injection is not to discard or dispose of the tracers, but to utilize them for their intended, useful purpose (conducting the separation efficiency study). RCRA does not regulate this activity because the purpose of the injection is not to discard the tracers. 1 42 U.S.C. § 6903(27). Once used, the radioactive tracers are not regulated under RCRA because they are specifically excluded from the definition of "solid waste" under 40 CFR 261.4(a)(4). Radioactive tracers are instead regulated under the Atomic Energy Act. As you note in your letter, radioactive tracer waste is not E&P exempt because such waste is not uniquely associated with oil and gas; many other industries use radioactive tracers. 2. Evidence to support a determination whether radioactive tracer waste is hazardous or whether it exhibits hazardous characteristics under 40 CFR Part 261 As noted above, radioactive waste is excluded from the definition of "solid waste" under RCRA. Therefore, such waste is not a "hazardous solid waste" regulated under the statute. 3. Evidence and legal authority to support a claim that radioactive tracer waste may otherwise fall under a RCRA exemption. Disposal of the mixture comprised of produced water and the radioactive tracers is covered under the RCRA Mixture Rule, which allows non -hazardous, non- E&P exempt waste (e.g., used radioactive tracers) to be commingled with E&P exempt waste (produced water), with the resulting mixture retaining the E&P exemption.(See page 17 of the EPA RCRA E&P Guidance Document you cited in your May 31, 2013 email.) Note that this result is consistent with how produced water exposed to radioactive tracers injected during well logging is regulated as E&P exempt waste. We hope that this explanation satisfies your request for clarification. As noted above, the study is scheduled to begin June 20, 2013. Please contact as soon as possible if you have additional questions or want to discuss further at 907-564-5501 or contact Alison Cooke at 564-4838. J Janet D Platt Director, Regulatory Compliance and Environment, Alaska Cc: Alison Cooke, BP Cc Cathy Foerster, AOGCC Cc: Jim Begg, AOGCC 17W wait WS i samom I/ Colombie, Jody J (DOA) From: Roby, David S (DOA) Sent: Friday, May 31, 2013 12:45 PM To: Cooke, Alison D Cc: Regg, James B (DOA); Wallace, Chris D (DOA); Lau, Glenn L; Crandall, Krissell Subject: RE: BPXA Request for Administrative Approval Alison, BP's assertion that "Radioactive tracers are not regulated under the Resource Conservation and Recovery Act (RCRA) so the fluids would not be designated hazardous or non -hazardous. Therefore, the diluted radioactive tracer which BP proposes to use at GC2 would not be categorized as hazardous or non -hazardous under RCRA ..." cannot be reconciled with a RCRA Guidance document which lists "radioactive tracer wastes" as a Non -Exempt Waste. See, http://www.epa.gov/osw/nonhaz/industrial/special/oil/oil-gas.pd at page 13 of 40. As a result, the AOGCC requests BP provide the following: 1. Evidence and legal authority in support of BP's assertion that radioactive tracer wastes are not regulated under RCRA; 2. Evidence to support a determination whether radioactive tracer waste is hazardous or whether it exhibits hazardous characteristics under 40 CFR Part 261. 3. Evidence and legal authority to support a claim that radioactive tracer waste may otherwise fall under a RCRA exemption. Regards, Dave Roby (907) 793-1232 From: Cooke, Alison D [mailto:Alison.Cooke(&bp.com] Sent: Tuesday, May 14, 2013 11:38 AM To: Foerster, Catherine P (DOA) Cc: Roby, David S (DOA); Regg, James B (DOA); Wallace, Chris D (DOA); Lau, Glenn L; Crandall, Krissell Subject: BPXA Request for Administrative Approval Ms. Foerster: Attached is a request from BPXA for administrative approval to inject dilute volumes of radioactive tracer that has been used for the purposes of studying vessel inefficiencies in Gathering Center 2 in the Prudhoe Bay Field in either EOR wells or Class II disposal wells. A hard copy of the letter is also being sent to you by certified mail. BPXA had a teleconference with your staff on April 25,2013 to discuss this project and our request. We would appreciate the Commission's timely review of this request. If possible we would appreciate a response by May 31. <<BPXA to AOGCC GC2 Tracer.pdf>> If you or your staff have any questions please contact me at 440-8167 or alison.cooke@bp.com. 1 R gards, Alison Alison D. Cooke 907-564-4838 tel. 907-440-8167 cell 907-564-5020 fax. cookead(aMp.com bp ECirl.-VV' im I 15 2013 BP Exploration (Alaska) Inc. P. O. Box 196612 CERTIFIED MAIL: 7011 2970 0001 9241 2635 Anc E.o Benson Boulevard Anchorage, AK 99519-6612 USA May 14, 2013 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Radioactive Tracer Injection: PBU 2013 GC2 Optimization Administrative Approval Request: Prudhoe Oil Pool, Area Injection Order 3A Aurora Oil Pool, Area Injection Order 22E Borealis Oil Pool, Area Injection Order 24B Polaris Oil Pool, Area Injection Order 25A Orion Oil Pool, Area Injection Order 26B Dear Ms. Foerster: BP Exploration (Alaska) Inc. (BPXA) requests approval under Area Injection Order (AIO) 3A Rule 1, NO 22E Rule 10, NO 24B Rule 2, NO 25A Rule 3, and NO 26B Rule 3 to introduce radioactive tracer into the Gathering Center 2 (GC2) production facility for the purpose of oil production, plant operations, and plant/piping integrity. Radioactive tracers are not regulated under the Resource Conservation and Recovery Act (RCRA) so the fluids would not be designated hazardous or non -hazardous. Therefore, the diluted radioactive tracer which BP proposes to use at GC2 would not be categorized as hazardous or non -hazardous under RCRA. The tracer will comingle with produced fluids and be diluted prior to enhanced oil recovery (EOR) reservoir injection. Mixing the radioactive tracer with produced fluids meets the criteria of fluids suitable for Class II disposal well injection. The tracer has been deemed to have no negative impact on the reservoir. Alyeska Pipeline Service Company has been informed of the test and noted no concerns with handling the diluted tracer. In order to keep standardized and consistent language referencing the fluids authorized for injection for enhanced recovery and pressure maintenance for all Prudhoe Bay Field (PBF) AIOs, BPXA also requests that radioactive tracer fluids Ms. Cathy Foerster May 14, 2013 Page 2 be specifically included as fluids introduced to production facilities for the purpose of oil production, plant operations, and plant/piping integrity in AIO 4E Rule 1, AIO 14A Rule 1, AIO 20 Rule 1, and AIO 31 Rule 3. GC2 Optimization The West End Developments program consists of several projects to debottleneck base production and increase future GC2 production. As part of the program, the optimization of GC2 and its separation capabilities will be reviewed. The current separation and sand handling capabilities will be evaluated in the study and changes will likely be recommended to process future production streams. Capacity Study The study will determine current vessel inefficiencies and propose upgrades to the facility. Radioactive tracer is needed to calculate the residence time of the oil and water phases in the slugcatchers and the water residence time in the skim tanks. For this determination, a total of 300 mL of radioactive tracer (lanthanum nitrate hexahydrate) will be injected upstream of the GC2 slugcatchers and skim tanks to trace the water phase. It is expected that minor amounts of the 200 mL bromoanthracene oil tracer will be carried into the produced water system. The half-lives of each tracer used in this study will be less than 2 days. Reservoir tracers typically used include cobalt -57, cobalt 60, carbon-14, or tritium which have half-lives of 270 days, 5.26 years, 5730 years, and 12.32 years, respectively. The shorter half-life in conjunction with the smaller injection sizes proposed exposes the reservoir to minimal radioactivity for a short duration (see table and chart Appendix 1). Alternatives to radioactive tracer have been considered. The main benefit of a tracer is the ability to detect concentration as a function of time, which correlates to vessel residence time and can characterize inefficiencies of internals. A non -radioactive tracer would require frequent sampling, and there is a possibility the tracer would pass through the system between samples, yielding no data. The ability to characterize vessel inefficiencies would be compromised with a non -radioactive tracer. Correct assessment of the separation capabilities of GC2 is necessary to determine appropriate upgrades to the facility for increased separation capacity. The most effective way to evaluate the separation capability of the facility is to use a radioactive tracer. To summarize, BPXA requests Commission approval to Ms. Cathy Foerster May 14, 2013 Page 3 inject dilute volumes of radioactive tracer (that have been used in production facilities for diagnostic purposes) in all PBF AIOs and in Class II disposal wells. Should you have any questions, or require additional information, please contact me at 564-4838 or alison.cooke@bp.com. Sincerely, '/ Z'Z/ 2 Alison Cooke UIC Compliance Advisor Attachment: Appendix 1 — Tracerco Information cc: James Regg, AOGCC Dave Roby, AOGCC Chris Wallace, AOGCC Ms. Cathy Foerster May 14, 2013 Page 5 Aaoendix 1 — Tracerco Information Tracerco Tracers Reservoir Tracers B-82 La -140 Co-57 Co -60 C-14 Tritium Injection Size (mCi) 120" 160* 200** 500*' 2000"" 10000" Half Life 35 hrs 40 hrs 270 days 5.26 yrs 5730 yrs 12.32 yrs * Proposed Amount to be Used for Study ** Typical Amounts Used for Reservoir Studies The following decay chart assumes starting activities of 200 mCi for comparison. Actual activities are shown in the chart above. 250 200 Decay Chart - Tracerco Tracers vs. Other Reservoir Tracers 50 0 5 10 15 20 25 30 35 Time (Days) —0---Br-82(Tracerco) —6—La-140 (Tracerco) —1 C-14 -0—H-3 —*--Co-60 —*--Co-57 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWeillntegrityCoordinator@bp.com] Sent: Wednesday, June 05, 2013 7:53 AM To: Regg, James B (DOA); Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator Subject: FW: NOT OPERABLE: Injector L-111 (PTD #2020300) 60 Day Monitoring Period Complete Jim, Chris, Please see below, the Not Operable note for Injector L-111 (PTD #2020300). 1 sent it out this morning and didn't include you on the distribution list by mistake. Jack Disbrow BP Alaska - Well Integrity Coordinator GWGlobal Wells Organization, Office: 907.659.5102 WIC Email: AKDCWeIIlntesrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Wednesday, June 05, 2013 7:19 AM To: AK, OPS GC2 OSM; AK, OPS GC2 Field 0&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad LV; 'Oshiro, Joleen' Cc: AK, D&C DHD Well Integrity Engineer; Walker, Greg (D&C); Holt, Ryan P; AK, D&C Well Integrity Coordinator Subject: NOT OPERABLE: Injector L-111 (PTD #2020300) 60 Day Monitoring Period Complete All, Injector L-111 (PTD #2020300) has completed an AOGCC requested 60 day monitoring period while on miscible gas injection. There was no sign of tubing by inner annulus communication during the 60 day period. BP will pursue a cancellation of Administrative Approval AIO 2413.002 which limits the well to water injection only. The well is reclassified as Not Operable until the Administrative Approval is cancelled and the well can be put back on miscible gas injection. Please call with any questions. Thank you, Jack Disbrow BP Alaska - Well Integrity Coordinator Global Wells GW Organization Office: 907.659.5102 WIC Email: AKDCWelllnteerityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Friday, March 08, 2013 9:18 PM To: AK, D&C Well Integrity Coordinator; AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, 1 OPS Prod Controllers; Cismoski, DoW Daniel, Ryan; AK, D&C Wireline OperatidTfs Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad LV; Oshiro, Joleen; 'jim.regg@alaska.goV; 'chris.wallace@alaska.gov'; Weiss, Troy D Cc: AK, D&C DHD Well Integrity Engineer (AKD&CDHDWeIIIntegri(albp.com); 'Ryan P Holt (Ryan.Holt@bp.com)'; Arend, Jon; Oxner, Gary Subject: UNDER EVALUATION: Injector L-111 (PTD #2020300) Ready for Miscible Gas Injection All, Injector L-111 (PTD #2020300) is currently operating under Administrative Approval AIO 2413.002 for TxIA communication when the well was on miscible gas injection. A tubing patch was set and a subsequent MIT -IA to 4070 psi passed on 07/08/2012. We have permission from the AOGCC to place the well on miscible gas injection for 30 days in order to evaluate the TxIA repair. The well is reclassified as Under Evaluation, and will be placed on a 28 -day clock. Miscible gas injection can begin. Plan forward: Well Integrity: Monitor pressure response while well is on miscible gas injection Well Integrity Coordinator: Apply to cancel Administrative Approval AIO 2413.002 if pressure response during 30 day monitoring period is acceptable Please call with any questions. Thank you, ,lack Disbrow BP Alaska - Well Integrity GINGlobal Wells Organization Office: 907.659.5738 • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 June 8, 2013 Ms. Cathy Foerster, Chairman Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay Unit well L-111 (PTD #2020300) Application for Cancellation of Administrative Approval 2413.002 Dear Ms. Foerster, by 0 BP Exploration (Alaska) Inc. requests cancellation of Administrative Approval number 246.002 dated September 19, 2008. The administrative approval was for continued water injection into well L-111 with slow inner annulus repressurization. A tubing patch was set and a MITIA passed to 4070 psi on July 8, 2012. BP received permission from the AOGCC to place the well on miscible gas injection for a period of 60 days to monitor for inner annulus repressurization. The monitoring period began on April 04, 2013 and ended June 2, 2013, during which no inner annulus repressurization was observed. Therefore it is requested to cancel the Administrative Approval and allow the well to return to WAG injection operations. A plot of wellhead pressures and a plot of injection rates and pressures have been included for reference. If you require any additional information, please contact me at 564-4303 or Jack Disbrow / Lori Climer at 659-5102. Sincerely, ;/oug71s A. Cismoski,P. GWO Wells Intervention Manager 0 Attachments: TIO Plot Injection Rate and Pressure Plot Cc: Disbrow/Climer West Area Manager Joleen Oshiro Ryan Daniel Bruce Williams 0 L-111 (PTD #2020300) TIO Plot Well: L-111 • f Tbg -w-- M :..X-C OA OOA OOOA. qn 1C+ v4.,Dg-, 3 3419 13 GM7CR73 OlQ"'dR3 iYa981f13 05-r'7,73�+16'13 ,1_d13 rcF31113 '.. L-111 (PTD #2020300) Injection Plot ,,4a_t-111 9.XC sw PW w— 4,xe ` G1 —011M 3.M0, On 2'DIC 1,DLC 14%,13 34773'13 D41MI3 L417,13 D5r*,?3 C51TY3 35'S6+'f3 V52512 fi. DI i3 E2 CERTIFIED MAIL # 7011 2970 0003 5821 9955 April 30, 2012 Kathy Foerster, Commissioner Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 • 0 BP Exploration (Alaska) Inc. P O. Box 196612 900 E. Benson Boulevard Anchorage, AK 99519-6612 USA RECEI V Y E MAY 022012 AOG%.# ; Re: Prudhoe Bay Field Area Injection Orders, Standardization of Authorized Fluids for EOR and Pressure Maintenance Dear Ms. Foerster, This letter is to request a change to Prudhoe Bay Field (PBF) Area Injection Orders (AIO) to standardize the language in the rule referencing the fluids authorized for injection for enhanced recovery and pressure maintenance. BP Exploration (Alaska) Inc. (BPXA) is requesting this change in order to address the complexity of field operations with multiple pools serviced by common facilities and potential confusion that results from the differing language in the various orders. This proposed change is intended to clarify and document the fluids that are authorized for enhanced oil recovery (EOR) and pressure maintenance injection within the PBF and provide greater compliance assurance for our field operations. A review of AIOs for pools in the PBF indicates that some contain very general language and some are very specific in defining which fluids are authorized for injection. The language defining fluids that may be injected has changed over time in successive versions of some of the orders. For instance, NO 4 language has changed from "non -hazardous fluids", to "Class II fluids" to "authorized fluids". In addition, some fluids have received specific authorization via administrative approvals. The diversity of language and changes over time has resulted in confusion over which fluids are actually authorized for injection. The enclosed list (Attachment A) shows the various PBF pools, AIOs, and a summary of the current rule and/or administrative approvals that authorize fluids that may be injected for purposes of pressure maintenance and enhanced recovery. Also included is a summary of findings regarding the compatibility of fluids authorized for injection. As discussed with your staff, BPXA proposes to standardize the list of authorized fluids for the various pools within the PBF. Attachment B is proposed language for this change. In some pools, additional clarification may be required to capture specific conditions or restrictions contained in current orders. Attachment C is a list of historical fluids injected for EOR and pressure maintenance • • Alaska Oil and Gas Conservation Commission April 30, 2012 Page 2 Should you have any questions, or require additional information, please contact me at 564- 4838. Sincerely, Alison Cooke UIC Compliance Advisor Attachments cc: Jim Regg AOGCC Dave Roby AOGCC • • Alaska Oil and Gas Conservation Commission April 30, 2012 Page 3 Attachment A Prudhoe Bay Field: fluids specifically authorized for enhanced recovery and pressure maintenance in Area Injection Orders AIO Rule Pool Fluids Authorized Compatibility with Formation 3 1 Prudhoe non -hazardous fluids; Area Injection Order Application for PBU WOA Bay AIO 3.03 rinsate (minus EOR and Fluid Disposal Wells: Section I: 1. (West) solids) from cleaning aerial Water: Beaufort Sea water and Produced gas coolers; Sadlerochit water; Compatibility: Water AIO 3.018 filtered and sensitivity tests on core samples showed no chemically treated lake significant problems with formation plugging or water used for hydrotesting clay swelling over the anticipated operating range replacement pipeline of salinities for produced and Beaufort Sea water; segments; 2. Miscible Gas from CGF; Compatibility: Full AIO 3.028 mixtures of glycol compatibility - reinjected into producing zone; 3. and water Produced Gas from Sadlerochit and Sag River reservoirs; Compatibility: Full compatibility - rein'ected into producing zone 4E 1 Prudhoe authorized fluids; A104D, Finding 12: The main fluid source will be Bay (East) AIO 4C.02 rinsate (minus source water from the Seawater Treatment Plant. Put River solids) from cleaning aerial No significant compatibility issues are anticipated Lisburne gas coolers; between the formation and injected fluid. Pt. AIO 4E.022 filtered and Analyses of core samples from Put River McIntyre chemically treated lake Formation sandstone in Prudhoe Bay West water used for hydrotesting Unit Well 2-14 demonstrate similar clay mineral Beach replacement pipeline types and proportions as those in Kuparuk River Stump segments for Greater Point Formation reservoirs in adjacent North Slope Island McIntyre; fields. Each of the analog fields has a successful AIO 4E.023 filtered and history of waterflooding and based on these chemically treated lake comparisons the water used for hydrotesting Put River Formation is not anticipated to have replacement pipeline compatibility issues related to seawater injection. segments for Prudhoe Bay A104C, Finding 20: Seawater is currently injected Unit fields; in the Pt. McIntyre waterflood. It is possible that AIO 4E.034 mixtures of produced water will be used later in the project. glycol and water Both water sources have previously been approved in Area Injection Order No. 413 Finding 34: Laboratory testing, core analyses and geochemical modeling indicate no significant problems are likely due to clay swelling or in-situ fluid compatibility problems between WBOP and Tertiary formation waters. Finding 35: WBOP waterflood source water from the Sagavanirktok Formation is expected to have excess barium ion which could precipitate barium sulfate scale if mixed with PMOP produced water. WBOP produced water will be inhibited upstream of the commingling point with PMOP fluids to prevent scale precipitation. • • Alaska Oil and Gas Conservation Commission April 30, 2012 Page 4 PBU EOA Area Injection Order Application, Section I Enhanced Recovery type of fluid: A. source water - treated seawater; Compatibility: no significant problems with formation plugging or clay swelling due to fluid incompatibilities are anticipated; B. produced water from Flow Stations and LPC; Compatibility: Fluid is returned to the reservoir from which it was produced, no compatibility problems anticipated; C. Natural Gas and NGL; Compatibility: Fluid is returned to the reservoir from which it was produced, no compatibility problems anticipated; D. Miscibile Injectant; Compatibility: Fluid is returned to the reservoir from which it was produced, no compatibility roblems anticipated. 14A 1 Niakuk produced water from LPC, A1014A, Finding 7: Injection will utilize either Beaufort seawater, produced or source water. The wells are currently trace amounts of scale configured to allow 60,000 Barrels of Water per inhibitor, corrosion inhibitor, Day ("BWPD") total, with a maximum injection of emulsion breakers, other up to 70,000 BWPD. The produced water will be products used in production a mix of Pt. McIntyre, West Beach, North process, stimulation fluids Prudhoe Bay, Lisburne and Niakuk produced water separated through the Lisburne Production Center ("LPC'), with the majority coming from Pt. McIntyre. Seawater has been injected as well. SEM, XRD and ERD analyses conducted on Niakuk core indicate very low clay content in reservoir intervals. As a result no significant problems with formation plugging or clay swelling due to fluid incompatibilities is expected. Produced water may contain trace amounts of scale inhibitor, corrosion inhibitor, emulsion breakers, and other products used in the production process. 20 1 Midnight fluids appropriate for A1020 Finding 21: Geochemical model results Sun enhanced recovery; indicate that a combined Tertiary water and AIO 20.001 filtered and connate water is likely to form calcium carbonate chemically treated lake and barium sulfate scale. Similar scale water used for hydrotesting precipitation is anticipated for produced water. replacement pipeline Scale will be controlled with commonly available segments inhibitors. • Alaska Oil and Gas Conservation Commission April 30, 2012 Page 5 22E 10 Aurora produced water, Prince Creek source water*, enriched hydrocarbon gas*, immiscible hydrocarbon gas*, tracer survey fluid, non -hazardous filtered water from pads and cellars *conditions for authorization are included in the current order A10226, Finding 9: The compositions of injection water and AOP connate water were provided in Exhibit IV -4 of the original AIO application. Water analysis from the nearby Milne Point Prince Creek Formation was provided in the April 28, 2003 application for rehearing 24B 2 Borealis produced water, non- A1024A, Finding 9: As previously approved by hazardous filtered water the Commission, produced water from GC -2 is from pads and cellars, used as the primary water source for Borealis tracer survey fluid, treated injection. Injection performance, core, log and seawater, enriched pressure -buildup analyses indicate no significant hydrocarbon gas*, Prince problems with clay swelling or compatibility with Creek source water; in-situ fluids. BPXA analysis of cores from the AIO 24A.001 filtered and BOP wells indicates relatively low clay content. chemically treated lake Petrographic analysis indicates that clay volumes water used for hydrotesting in the better quality sand sections (>20 md) are in replacement pipeline the range of 3 - 6%. Clay volumes increase to segments approximately 6 - 12% in rock with permeabilities in the range of 10 - 20 md. Below 10 md, clay volumes increase to a range of 12 - 20%. Most of the identified clay is present as intergranular matrix, having been intermixed with the sand through burrowing. The overall clay composition is a mixture of roughly equal amounts of kaolinite, illite and mixed layer illite/smectite. No chlorite was reported during petrographic analysis. The presence of iron -bearing minerals suggests that *conditions for authorization the use of strong acids should be avoided in are included in the current breakdown treatments, spacers, etc. Water from order the seawater treatment plant has been successfully used for injection within the Kuparuk of the Pt. McIntyre Oil Pool. Geochemical modeling indicates that a combination of GC -2 produced water and connate water is likely to form calcium carbonate and barium sulfate scale in the production wells and downstream production equipment. Scale precipitation will be controlled using scale inhibition methods similar to those used at Kuparuk River Unit and Milne Point Unit. Miscible gas is a hydrocarbon with similar composition to reservoir fluids in the BOP therefore no compatibility issues are anticipated with the formation or confining zones. The composition of injection water from the Prince Creek aquifer is expected to fall within the range of Well W-400 and MPF -02 produced water 0 • Alaska Oil and Gas Conservation Commission April 30, 2012 Page 6 compositions, less than 10,000 -ppm total dissolved solids. Milne Point Unit F -Pad Prince Creek source water has been injected since 1996 into the Milne Point Kuparuk Reservoir, lithologically similar to the BOP, with no apparent formation damage. A single well chemical tracer test in BOP well L-122 conducted using 640 barrels of Prince Creek Source water did not detect any formation damage. 25A 3 Polaris produced water, tracer AIO 25A, Finding 11: The enriched gas proposed survey fluid, enriched for injection is a hydrocarbon with similar hydrocarbon gas, treated composition to reservoir fluids in the Polaris Oil seawater, non -hazardous Pool and therefore no compatibility issues are filtered water from pads and anticipated. cellars, enriched AIO 25, Finding 12: BPXA provided laboratory hydrocarbon gas; analysis of the injection and produced waters. No AIO 25A.001 filtered and significant compatibility problems are evident chemically treated lake from these analyses. Disposal of PBU produced water used for hydrotesting water within the Ugnu sands has successfully replacement pipeline occurred in other parts of the field. segments 26B 3 Orion enriched gas, produced AIO 26A, Finding 11: The enriched gas proposed water, tracer survey fluid, for injection is a hydrocarbon with similar treated seawater, Prince composition to reservoir fluids in the Orion Oil Creek source water, non- Pool and therefore no compatibility issues are hazardous filtered water anticipated. from pads and cellars, non- AIO 26, Finding 11: The composition of produced hazardous filtered lake water will be a mixture of connate water and water employed for injection water, and will change over time hydrotesting pipeline depending on the rate and composition of segments injection water. Based on analyses of Polaris water samples, no significant compatibility problems are expected between connate water and injection water. 31 3 Raven produced water, tracer AIO 31, Finding 14: Water compatibility problems survey fluid, stimulation are not expected because of the successful fluids, source water from history of both sea water and produced water STP, and non -hazardous injection into the Prudhoe Bay Reservoir. No clay water collected from well swelling problems have been seen in the Ivishak house cellars and standing Formation in the Ivishak Participating Area of the ponds. PBU (IPA) with either source water injection or produced water injection. When present, scaling in the Ivishak Formation in the IPA has been limited to calcium carbonate deposition, which has been eliminated with acid treatments and controlled with the use of inhibitors. Minimal problems with formation plugging or clay swelling due to fluid incompatibilities are anticipated. • • Alaska Oil and Gas Conservation Commission April 30, 2012 Page 7 Attachment B Proposed Standardized List of Fluids Authorized for Injection in Prudhoe Bay Field Pools Fluids authorized for injection include: • Produced water and gas; • Enriched hydrocarbon gas • Non -Hazardous Water and water based fluids — (includes seawater, source water, freshwater, domestic wastewater, equipment washwater, sump fluids, hydrotest fluids, firewater, and water with trace chemicals, and other water based fluids with a pH greater than or equal to 2 or less than or equal to 12.5 and flashpoint greater than 140 degrees F) • Fluids introduced to production facilities for the purpose of oil production, plant operations, plant/piping integrity or well maintenance that become entrained in the produced water stream after oil, gas and water separation in the facility. Includes but not limited to: • Freeze protection fluids; • Fluids in mixtures of oil sent for hydrocarbon recycle • Corrosion/Scale inhibitor fluids • Anti-foams/emulsion breakers • Glycols Non -hazardous glycols and glycol mixtures Fluids that are used for their intended purpose within the oil production process. Includes: • Scavengers; • Biocides • Fluids to monitor or enhance reservoir performance. Includes: • Tracer survey fluids; • Well stimulation fluids • Reservoir profile modification fluids • a Alaska Oil and Gas Conservation Commission April 30, 2012 Page 8 Attachment C Historical Fluids Injected for EOR and Pressure Maintenance: these fluids were authorized and injected under the general descriptions of authorized fluids: AIO 4, 4A, and 4B: Class II fluids; AIO 4C: authorized fluids; AIO 3: non -hazardous fluids Treated Seawater supplied from PBU STP. Contains small amounts of chemicals: coagulant, anti -foam, scale inhibitor, biocide, oxygen scavenger and other process chemicals. Produced water from PB field producing formations. Contains small amounts of entrained produced oil and gas, and chemicals: scale inhibitor, corrosion inhibitor, emulsion breaker, and other production process chemicals. Natural Gas (including natural gas liquids) from PB field producing formations. Miscible Injectant from PBU Central Gas Facility. Reserve Pit water from pit dewatering operations. Consists of precipitation and small amounts of drilling wastes and chemicals (oxygen scavenger and biocide). Source water from shallow formations. Contains small amount of production chemicals (scale inhibitor). ML • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 September 9, 2008 • Mr. Daniel Seamount, Chairman SEP 16 2008 Alaska Oil and Gas Conservation Commission Alaska Of! & Glos Oansw Commission 333 West 7th Avenue Anhora Anchorage, Alaska 99501 Subject: Prudhoe Bay Unit well L-111 (PTD #2020300) Request for Administrative Approval: Continued Water Injection Operations Dear Mr. Seamount, BP Exploration (Alaska) Inc. requests approval for continued water injection operations into Prudhoe Bay well L-111. Well L-111 exhibits inner annulus re -pressurization of 245 psi/day when on MI injection and minimal re -pressurization when on water injection. However, a pressure test of the inner annulus passed to 4000 psi, indicating the tubing and production casing are competent. Based upon sound engineering practice, two barriers have been established and the well can be safely operated. Consequently, no repairs are planned at this time. In summary, BPXA believes Prudhoe Bay well L-111 is safe to operate as stated above and requests administrative approval for continued water injection operations. If you require any additional information, please contact me at 564-5637 or Anna Dube / Andrea Hughes at 659-5102. Sincerely, R. Steve Rossberg BPXA, Wells Manager Attachments: Technical Justification TIO Plot Injection Plot Wellbore Schematic Cc: Bixby/Olsen Dube/Hughes West Area Manager Ray Oakley Harry Engel Janice Vosika • 0 • Prudhoe Bay Oil Pool well L-111 Technical Justification for Administrative Approval Request September 9, 2008 Well History and Status Prudhoe Bay well L-111 (PTD #2020300) exhibits inner annulus repressurization indicated by wellhead pressure trends on a TIO plot. An MIT -IA to 4000 psi passed on 08/08/08 indicating competent tubing and production casing. Recent Well Events: > 04/10/08: Notify AOGCC of TAA while on MI; swap to water injection > 07/14/08: DGLVs with extended packing; MIT -IA Passed to 4000 psi > 08/08/08: AOGCC MIT -IA Passed to 4000 psi > 08/17/08: Swap to MI > 09/04/08: IA re -pressurization - 245 psi / day Barrier Evaluation The primary and secondary barrier systems consist of tubing and production casing and associated hardware. A pressure test of the inner annulus passed to 4000 psi, demonstrating competent primary and secondary barrier systems. Proposed Operating and Monitoring Plan 1. Record wellhead pressures and injection rate daily. 2. Submit a report monthly of well pressures and injection rates to the AOGCC. 3. Perform a 4 -year MIT -IA to 1.2 times maximum anticipated injection pressure. 4. The well will be shut-in and the AOGCC notified if there is any change in the wells mechanical condition. 4,000 3,000 ?,000 1,000 0 L-111 TIO Plot 09114107 10115107 11115107 12/16/07 M59 021169 09/18108 04/18108 05119108 061190 07!001'08 08120!08 3,5m 3,000 2,500 i 2,000 ' 1,500 Writ L-111 Injection Plot 09114107 10115107 11/15/07 12/16107 01116M 02/16108 0180 04118108 01191 06119108 07120108 181201 14,000 12,000 CO 10,000 � 000 ° 6,000 n 4,000 ° 2,000 TREE= 4-1/16" CM/ WELLsHEAD = FMC ACTUATOR = NA KB. ELEV =� 76.4' BF. R EV = 52.02' KbP = 800' Max Angle = 40'@ 1595' Datum MD = 7075' Datum TVD = 6600' SS 9-5/8" CSG, 40#, L-80, ID = 8.835" F-{ 2922' Minimum ID = 2.813" @ 6768' 3-112" HES X NIPPLE 4-1 /2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 4375' PERFORATION SUMMARY REF LOG: TCP PERF ANGLE AT TOP PERF: 9' @ 4546' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4-5/8" 5 4546-4586 O 03/04/02 4-5/8" 5 4616-4636 O 03/04/02 4-5/8" 5 4660-4673 O 03/04/02 4-5/8" 5 4719-4729 O 03/04/02 4-5/8" 5 4768-4805 O 03/04/02 4-5/8" 5 4832-4852 O 03/04/02 2-1/2" 6 7014-7038 O 03/22/02 2-1/2" 6 7047-7052 O 03/22/02 2-1/2" 6 7070-7078 O 03/22/02 3-1/2" TBG, 9.2#, L-80 TCII, .0087 bpf, ID = 2.992" i-� 6838' PBTD - 7505- 7" CSG, 26#, L-80-0383 bpf, ID = 6.276" 7589' L-1 11 974'-19-5/8" TAM PORT COLLAR 22� 4-1/2" HES X NIP. ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH I PORT I DATE 4 3 3842 4199 3541 3896 4 8 KBG-2 KBG-2 "DMY -DMY BK -5 BK -5 1 0 0 07/14/08 07/14/08 Si A # 3 & # 4 = UMY'S HAV L LX I LNULU F'KG F --43-08-'--]—F4-1/2" HES X NIP, ID = 3.813" I DEVI 4319' 7" X 4-1/2" BKR PREM PKR, ID = 3.910" 4377' 4-1 /2" X 3-112" XO, ID = 2.992" I DATE WATFRFLOOD MANDRELS ST MD I TVD I DEVI TYPE I VLV I LATCH I PORT I DATE 2 1 4418 4478 4113 4172 8 7 MMG-W 1 MMG-W I RKED I RKED RKP RKP 0 0 03/03/02 103/03/02 5243' 7" TAM PORT COLLAR —F -6-7-68-'--]-F3 1/2" HES X NIP, ID = Z813- -67-78-'--]-F3 1/2' .813"6778' 3-1/2" —X4-1/2- XO, ID = 2.950" 6780' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 6786'4-1 /2" X 3-1 /2" XO, ID = 2.950" 6806' 3-112" HES X NIP, ID = 2.813" 6826' 3-1/2" HES X NIP, ID = 2.813" 6838' 3-1/2" WLEG, ID = 2.905" ELMD TT NOT LOGGED 6892' PUP JT W/RA TAG DATE REV BY COMMENTS DATE REV BY COMMENTS 03/06/02 ORIGINAL COMPLETION 07/18/08 JLJ/JMD GLV C/O (07/14/08) 03/12/02 CH/TP CORRECTIONS 07/25/08 PJC GLV CORRECTIONS 03/16/02 MH/tlh GLV UPDATE 03/22/02 CWS/KK ADPERFS 06/06/02 RL/tlh I GLV UPDATE 104/08/031 DRS/TP I TVD/MD CORRECTIONS PUP JT w / RA TAG BOREALIS UNR WELL: L-111 PERMIT No: 2020300 API No: 50-029-23069-00 SEC 34, T1 2N, R11 E 2339' NSL & 3873' WEL BP Exploration (Alaska) -3 • BP Exploration (Alaska) Inc. Attn: Well Integrity Engineer, PRB 20 Post Office Box 196612 Anchorage, Alaska 99519-6612 July 15, 2008 • *ss JUL 7 2008 Alas,a oil �^ (6 & ion .,r Mr. Daniel Seamount, Chairman Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay well V-112 (PTD #2060200) Application for Cancellation of Administrative Approval 2413.001 Dear Mr. Seamount, BP Exploration (Alaska) Inc. requests cancellation of Administrative Approval number 2413.001 dated April 21, 2008. The administrative approval was for continued water injection with slow inner annulus repressurization. A slickline intervention was performed on May 25, 2008 to replace the dummy gas lift valves with new valves with extended packing in an attempt to eliminate the IA repressurization. Monitoring of wellhead pressures since the intervention confirms the IA pressure remains stable when on MI injection. A plot of wellhead pressures has been included for reference. If you require any additional information, please contact me at 564-5637 or Anna Dube / Andrea Hughes at 659-5102. Sinqteen SRossberg Wells Manager, BPXA Attachments: TIO Plots Injection Plot Cc: • Bixby/Olsen Dube/Hughes West Area Manager Ray Oakley Harry Engel Janice Vosika 40 3,000 2,000 m 0 41152008 41302008 5/16!2008 5f302008 61142008 6292008 7116200$ 7f30J2008 -4- Tbg -■- IA -*- OA -o- OOA OOOA 4,000 0 3,000 2,000 1,000 dL 711512007 V-112 TIO Piot 9!14!2007 11 /W2007 111412008 M 5Q008 5A 5/2008 7115,2008 �- Tbg f A OA w OOA -E OOOA I iPC:) Q o p CO LL u 2 O o 0 'r co CD i CD t3 C + Tr CL 0 C {y 711612007 V-112 Daily Allocated Injection Plot 911612007 1111612007 111612008 311612008 6i16i2008 711612008 CD I— CO WHIR O S CO C:' CD — RVVI+DVA CL �i o� o ( —MGI CD I GAS 0 RECEIVED BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 April 9, 2008 APR 1 6 2008 by Alaska Oil & Gas Cons, Commission Anchorage 0 Mr. Daniel Seamount, Chairman Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay well V-112 (PTD #2060200) Request for Administrative Approval: Continued Water Injection Operations Dear Mr. Seamount, BP Exploration (Alaska) Inc. requests approval for continued water injection operations into Prudhoe Bay well V-112. Well V-112 exhibits inner annulus re -pressurization when on miscible gas injection. The well was swapped to produced water injection and subsequently passed a pressure test of the inner annulus to 3000 psi, indicating the tubing and production casing are competent. Based upon sound engineering practice, two barriers have been established and the well can be safely operated. The well will remain on water injection and, consequently, no repairs are planned at this time. In summary, BPXA believes Prudhoe Bay well V-112 is safe to operate as stated above and requests administrative approval for continued water injection operations. If you require any additional information, please contact me at 564-5637 or Anna Dube / Andrea Hughes at 659-5102. Sincerely, R. Steven Rossberg Wells Manager, BPXA Attachments: Technical Justification TIO Plot Injection Plot Wellbore Schematic Cc: Bixby/Olsen Dube/Hughes West Area Manager Ray Oakley Harry Engel Janice Vosika • Prudhoe Bay Oil • Pool well V-112 Technical Justification for Administrative Approval Request April 9, 2008 Well History and Status Prudhoe Bay well V-112 (PTD #2060200) exhibited inner annulus repressurization when on miscible gas injection indicated by wellhead pressure trends on a TIO plot. The well was swapped to water injection and a MIT -IA to 3000 psi passed on 03/16/08 indicating competent tubing and production casing. Recent Well Events: > 07/13/06: AOGCC MITIA Passed to 2200 psi > 02/20/08: Notified AOGCC of TAA Comm > 03/11/08: MIT -IA Passed to 3000 psi > 03/16/08: AOGCC MIT -IA Passed to 3000 psi Barrier Evaluation The primary and secondary barrier systems consist of tubing and production casing and associated hardware. A pressure test of the inner annulus passed to 3000 psi, demonstrating competent primary and secondary barrier systems. Proposed Operating and Monitoring Plan 1. Record wellhead pressures and injection rate daily. 2. Submit a report monthly of well pressures and injection rates to the AOGCC. 3. Perform a 4 -year MIT -IA to 1.2 times maximum anticipated injection pressure. 4. The well will be shut-in and the AOGCC notified if there is any change in the wells mechanical condition. V 4J6)2007 6/6/2007 MAW 1QS12007 1218)2007 2/7)2008 4P82008 + Tbg f IA -t OA OOA OOOA 8 0 0-112 Daily Allocated Injection Plot • 8 — WHIP 0 0 0 N 8 O O 419f2007 6r9f2007 SIMON TREE = TBD WELLHEAD = FMC GEN 5 ACTUATOR = INTERVAL KB. R EV = 82.30' BF. ELEV = 55.90' KOP = 400 Max Angle = 100 @ 8858' Datum MD = 7818' Datum TVD = 6600' SS • V-1 12 20" CONDUCTOR 1-1 101 9-5/8" CSG, 40#, L-80 BTC, ID = 8.835" 3003' 7" CSG, 26#, L-80 TCII, ID = 6.276" H 4153' Minimum ID = 2.813" @ 7520' BAKER CMD SLIDING SLEEVE 1 4-1/2" TBG, 12.6#, L-80 TCII, .0152 bpf, ID = 3.958" 13-1/2" TBG, 9.2#, L-80 TCII, .0087 bpf, ID = 2.992" 7" CSG, 26#, L-80 BTC -M, ID = 6.276" PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 74@7550' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 5 7550-7620 O 03/04/06 2-7/8" 5 7632- 7660 O 03/04/06 2-7/8" 5 7680- 7706 O 03/04/06 2-7/8" 5 7745-7770 O 03/04/06 4-1/2" 6 9140-9190 O 03/04/06 4-1/2" 6 9250-9290 O 03/04/06 4-1/2" 6 9320-9375 O 03/04/06 4-1/2" 6 9410-9438 O 03/04/06 LNR, 12.6#, L-80 IBT-M, .0152 bpf, ID = 3.958" SW NOTES: 70° @ 7365' 2220' H4-1/2" HES X NIP, ID = 3.813- L GAS LIFT MANDRELS iT MD I TVD I DEVI TYPE I VLV I LATCHI PORTI DATE 4 3196 3020 24 1 KBG-2 DMY BK 0 06/16/06 3 4843 4515 25 KBG-2 DMY BK 0 06/16/06 WATER IN1FrTION MANDRELS ST MD I TVD I DEVI TYPE I VLV I LATCHI PORTI DATE 2 1 7430 1 7491 6570 6587 73 74 M M G -W 1 M M G -W I DMY DMY I RK RK 1 0 0 1 03/05/06 5219' N HES ES CEMENTER STAGE TOOL 7308' 7" MARKER JOINT w /RA TAG 7359' H 4-1/2" HES X NIP, ID = 3.813" 7380' 7" X 4-1/2" BKR PRM PROD PKR, ID = 3.875" 7408' 4-1/2" HES X NIP, ID = 3.813" 7419' 4-1/2" X 3-1/2" XO, ID = 2.992" 7520' BKR CMD SLIDING SLV, ID = 2.813" 06/16/06 RCT/PJC GLV C/O 3-1/2" HES X NIP, ID = 2.813" 8011' 8042' 7" X 5" BKR ZXP LNR TOP PKR, FLEX-LOK LNR HNGR & TIEBACK SLV, ID = 4.400 8056' H LOCATOR & BKR SPACER TUBE, ID = 3.00" 8069' 4-112" BKR SEAL BORE EXT, ID = 4.00" 8077' HBKR BONDED SEAL ASSY, ID - 3.00" 8426;—, RA TAG DATE REV BY COMMENTS DATE REV BY COMMENTS 03/07/06 N9ES ORIGINAL COMPLETION 03/18/06 GLMITLH DRLG DRAFT CORRECTIONS 04/20/06 DAV/PJC GLV C/O 06/16/06 RCT/PJC GLV C/O BOREALIS UNIT WELL: V-112 PERMIT No: 82060200 API No: 50-029-23300-00 SEC 11, T11 N, R1IE, 4627' FSL, 1876' FEL BP Exploration (Alaska) 0 Notice of Public Hearing State of Alaska Alaska Oil and Gas Conservation Commission Re: Amendment of underground injection orders to incorporate consistent language addressing the mechanical integrity of wells for the Prudhoe Bay Field, Aurora and Borealis Pools. The Alaska Oil and Gas Conservation Commission ("Commission"), on its own motion, proposes to amend the existing rules of area injection orders for the Aurora and Borealis Pools. The proposed amendments will add a requirement addressing injection well mechanical integrity failures, and clarify requirements for mechanical integrity demonstrations. The purpose of these amendments is to establish rules with uniform language that promote consistent implementation of well integrity requirements for injection wells when pressure communication or leakage is indicated. The proposed amendments may be reviewed at the offices of the Commission, 333 West 7th Avenue, Suite 100, Anchorage, Alaska, or on the Commission's website at http://www.aogcc.alaska.gov, or a copy may be obtained by phoning the Commission at (907) 793-1221. The Commission has tentatively set a consolidated public hearing on the amendments proposed for January 31, 2008 at 9:00 am at the offices of the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. A person may request that the tentatively scheduled hearing be held by filing a written request with the Commission no later than 4:30 pm on January 8, 2008. If a request for a hearing is not timely filed, the Commission may consider the issuance of an order without a hearing. To learn if the Commission will hold the public hearing, please call 793-1221 after January 15, 2008. In addition, a person may submit a written protest or written comments regarding this application and proposal to the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. Protests and comments must be received no later than 4:30 pm on January 23, 2008 except that if the Commission decides to hold a public hearing, protests or comments must be received no later than the conclusion of the January 31, 2008 hearing. If you are a person with a disability who may need special accommodations in order to comment or to attend the public e ing, please contact the Commission's Special Assistant Jody Colombie a �= V1 STATE OF ALASKA 0 NOTICE TO PUBLISHER 0 ADVERTISING ORDER NO. ADVERTISING INVOICE AFFIDAVIT OF OF PUBLICATION (UST BE IAPART 2OOFINTH S ORMTE SHWG SIW THO ATTACHED OPY RDER NO., CERTIFIED AO-02814035 ORDER ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE SEE BOTTOM FOR INVOICE ADDRESS F AOGCC AGENCY CONTACT DATE OF A.O. R 333 W 7th Ave, Ste 100 Jody Colombie December 19 2007 ° Anchorage, AK 99501 PHONE PCN M Q07-7()'1-1?';9 — 1221 T Anchorage Daily News PO Box 149001 Anchorage, AK 99514 Type of Advertisement TO REF ITYPE 1 VEN 2 ARD FIN AMOUNT 2 REQUISITION BY: DATES ADVERTISEMENT REQUIRED: December 20, 2007 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: IAdvertisement to be published was e-mailed Display Classified ❑Other (Specify) SEE ATTACHED AOGCC, 333 W. 7th Ave., Suite 100 Anchorage, AK 99501 )MBER AMOUNT 2910 SY CC PGM 08 02140100 PAGE 1 OF `TOTAL OF 2 PAGES I ALL PAGES LC ACCT FY NMR DIST 73451 DIVISION APPROVAL: 02-902 (Rev. 3/94) , j Publisher/Original Copies: Department Fiscal, Department, Receiving AOTRM *Anchorage Daily News • 12/2°', Affidavit of Publication 1001 Northway Drive, Anchorage, AK 99508 PRICE OTHER OTHER OTHER OTHER OTHER GRAND AD # DATE PO ACCOUNT PER DAY CHARGES CHARGES #2 CHARGES #3 CHARGES #4 CHARGES #5 TOTAL 399876 12/20/2007 02814035 STOF0330 $229.08 $229.08 $0.00 $0.00 $0.00 $0.00 $0.00 $229.08 STATE OF ALASKA THIRD JUDICIAL DISTRICT Angelina Benjamin, being first duly sworn on oath deposes and says that she is an advertising representative of the Anchorage Daily News, a daily newspaper. That said newspaper has been approved by the Third Judicial Court, Anchorage, Alaska, and it now and has been published in the English language continually as a daily newspaper in Anchorage, Alaska, and it is now and during all said time was printed in an office maintained at the aforesaid place of publication of said newspaper. That the annexed is a copy of an advertisement as it was published in regular issues (and not in supplemental form) of said newspaper on the above dates and that such newspaper was regularly distributed to its subscribers during all of said period. That the full amount of the fee charged for the foregoing publication is not in excess of the rate charged private individuals. Signed Subscribed and sworn t me b fore this date: ��i� o 7 Notary Public in and for the State of Alaska. Third Division. Anchorage, Alaska '..' / MY n Notice of Public Hearing State ofAlaska Alaska Oil and Gas Conservation commission Re: Amendment of underground injection orders to incorporate consistent language addressing the mechanical integriWty of wells for the Prudhoe. Bay Field, Aurora and Borealis Pools: The Alaska oil and cac w av pin -on January 25;:2008 .If a request for a hearing is not timely filed the Commission may consider the issuance of an order without a hearing. To learn if the Commission will hold the public hearing, please call 793-1221 after January 15, 2008.. In addition, a person maysdbmit a written protest or written comments regarding this application and proposal to the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue; Suite 100, Anchorage, Alaska 99501. Protests and comments must be received no later than 4 an nm ne = puv„� uca�m pt VLCSrs or comments must_be received no ater than the conclusion of the January 31, 2008 hearing. If you are a person with a disability who may need special accommodations in order to comment or LAO-028144035, cial Assistant JodyC0lombie at John K. Norman Chairman. er 20, 2007 Ah Aft ADVERTISING ORDER INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTIFIED AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COPY OF ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE /(►O_02814035 M SEE BOTTOM FOR INVOICE ADDRESS F AOGCC AGENCY CONTACT DATE OF A.O. R o 333 West 7h Avenue. Suite 100 Anchorage_ AK 99501 Jody Colombie Decemba 19- 2007 PHONE PCN M 907-793-1238 -1221 ADVERTISEMENT REQUIRED: December 20, 2007 T Anchorage Daily News PO Box 149001 Anchorage, AK 99514 THE MATERIAL BETWEEN THE ITS ENTIRETY ON THE DATES SHOWN.DOUBLE LINES MUST BE PRINTED IN SPECIAL INSTRUCTIONS: Account # STOF0330 AFFIDAVIT OF PUBLICATION United states of America REMINDER State of ss INVOICE MUST BE IN TRIPLICATE AND MUST REFERENCE THE ADVERTISING ORDER NUMBER. division. A CERTIFIED COPY OF THIS AFFIDAVIT OF PUBLICATION MUST BE SUBMITTED WITH THE INVOICE. Before me, the undersigned, a notary public this day personally appeared ATTACH PROOF OF PUBLICATION HERE. 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 2007, and thereafter for consecutive days, the last publication appearing on the day of 2007, 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 2007, Notary public for state of My commission expires • Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Wednesday, December 19, 2007 9:51 AM 0 Subject: Amendments to PBU Borealis and Aurora Pools (Public Notice) Attachments: Amendment Borealis Aurora Pools.pdf BCC:McIver, C (DOA); 'Alan Birnbaum <""Alan J Birnbaum "> (alan.birnbaum@alaska.gov) ; 'Aleutians East Borough'; 'Anna Raff ; Arion, Teri A (DNR); 'Arthur C Saltmarsh'; 'Arthur Copoulos'; 'Barbara F Fullmer'; 'bbritch'; 'Bill Walker'; 'Brad McKim'; 'Brandon Gagnon'; 'Brian Gillespie'; 'Brian Havelock'; 'Brit Lively'; 'Bruce Webb'; 'buonoje'; 'Cammy Taylor'; 'carol smyth'; 'Cary Carrigan'; 'Catherine P Foerster'; caunderwood@marathonoil.com; 'Charles O'Donnell'; 'Chris Gay'; 'Christian Gou-Leonhardt'; 'Cliff Posey'; 'Dan Bross'; 'dapa'; 'Daryl J. Kleppin'; 'David L Boelens'; 'David Steingreaber'; 'ddonkel'; 'Deanna Gamble'; 'Deborah J. Jones'; 'doug_schultze'; 'Evan Harness'; 'eyancy'; 'f6ms2@mtaonline.net'; 'Francis S. Sommer'; 'Fred Steece'; 'Garland Robinson'; 'Gary Laughlin'; 'Gary Rogers'; 'Gary Schultz'; 'ghammons'; 'Gordon Pospisil'; 'Gregg Nady'; 'gregory micallef; 'gspfoff ; 'Hank Alford'; 'Harry Engel'; Jah'; 'James B Regg'; 'James M. Ruud'; 'James Scherr'; 'Janet D. Platt'; Jdarlington'; Jejones'; 'Jerry McCutcheon'; 'Jim White'; 'Jim Winegarner'; 'Joe Nicks'; 'John Garing'; 'John S. Haworth'; 'John Spain'; 'John Tower'; 'John W Katz'; johnny.aiken@north-slope.org; 'Jon Goltz'; 'Julie Houle'; 'Kari Moriarty'; 'Kaynell Zeman'; 'Keith Wiles'; knelson@petroleumnews.com; 'Kristin Dirks'; 'Laura Silliphant'; 'Lois'; 'Lynnda Kahn'; 'mail=akpratts@acsalaska.net'; 'mail=crockett@aoga.org'; 'mail=foms@mtaonline.net'; 'Mark Dalton'; 'Mark Hanley'; 'Mark Kovac'; 'Mark P. Worcester'; 'Marquerite kremer'; 'marry'; 'Matt Rader'; 'mckay'; 'Meghan Powell'; 'Mike Bill'; 'Mike Mason'; 'Mikel Schultz'; 'Mindy Lewis'; 'MJ Loveland'; 'mjnelson'; 'mkm7200'; 'Nick W. Glover'; NSU, ADW Well Integrity Engineer; 'Patty Alfaro'; 'Paul Decker'; 'Paul Winslow'; Pierce, Sandra M (DNR); 'Randall Kanady'; 'Randy L. Skillern'; 'rcrotty'; Rice, Cody J (DNR); 'rmclean'; rob.g.dragnich@exxonmobil.com; 'Robert Campbell'; 'Robert Province'; 'Roger Belman'; 'Rudy Brueggeman'; 'Scott Cranswick'; 'Shannon Donnelly'; 'Sharmaine Copeland'; 'Sondra Stewman'; 'Sonja Frankllin'; 'stanekj'; 'Stephen F Davies'; 'Steve Lambert'; 'Steve Moothart'; 'Steven R. Rossberg'; 'tablerk'; 'Tamera Sheffield'; 'Temple Davidson'; 'Terrie Hubble'; 'Thomas E Maunder'; 'Tim Lawlor'; 'Todd Durkee'; 'trmjrl ; 'Walter Featherly'; 'Walter Quay'; 'Wayne Rancier' Attachments: Amendment Borealis Aurora Pools.pdf, 12/19/2007 Kenai National Wildlife Refuge Penny Vadla Richard Wagner Refuge Manager 399 West Riverview Avenue PO Box 60868 PO Box 2139 Soldotna, AK 99669-7714 Fairbanks, AK 99706 Soldotna, AK 99669-2139 Cliff Burglin Bernie Karl North Slope Borough PO Box 70131 K&K Recycling Inc. PO Box 69 Fairbanks, AK 99707 PO Box 58055 Barrow, AK 99723 Fairbanks, AK 99711 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 O Barrow, AK 99723 Ul � l • Mary Jones David McCaleb Cindi Walker XTO Energy, Inc. IHS Energy Group Tesoro Refining and Marketing Co. Cartography GEPS Supply & Distribution 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 300 Concord Plaza Drive Ft, Worth, TX 76102-6298 Houston, TX 77056 San Antonio, TX 78216 George Vaught, Jr. Jerry Hodgden Richard Neahring PO Box 13557 Hodgden Oil Company NRG Associates Denver, CO 80201-3557 408 18th Street President Golden, CO 80401-2433 PO Box 1655 Colorado Springs, CO 80901 John Levorsen Michael Parks Mark Wedman 200 North 3rd Street, #1202 Marple's Business Newsletter Halliburton Boise, ID 83702 117 West Mercer St, Ste 200 6900 Arctic Blvd. Seattle, WA 98119-3960 Anchorage, AK 99502 Baker Oil Tools Schlumberger Cid 4730 Business Park Blvd., #44 Drilling and Measurements Land Department Anchorage, AK 99503 2525 Gambell Street #400 PO Box 93330 Anchorage, AK 99503 Anchorage, AK 99503 Ivan Gillian Jill Schneider Gordon Severson 9649 Musket Bell Cr.#5 US Geological Survey 3201 Westmar Cr. Anchorage, AK 99507 4200 University Dr. Anchorage, AK 99508-4336 Anchorage, AK 99508 Jack Hakkila Darwin Waldsmith James Gibbs PO Box 190083 PO Box 39309 PO Box 1597 Anchorage, AK 99519 Ninilchick, AK 99639 Soldotna, AK 99669 Kenai National Wildlife Refuge Penny Vadla Richard Wagner Refuge Manager 399 West Riverview Avenue PO Box 60868 PO Box 2139 Soldotna, AK 99669-7714 Fairbanks, AK 99706 Soldotna, AK 99669-2139 Cliff Burglin Bernie Karl North Slope Borough PO Box 70131 K&K Recycling Inc. PO Box 69 Fairbanks, AK 99707 PO Box 58055 Barrow, AK 99723 Fairbanks, AK 99711 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 O Barrow, AK 99723 Ul � l