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Home My WebLink AboutAIO 007AREA INJECTION ORDER 7 Northern Portion of Middle Ground Shoal Field 1. July 15, 1986 Amoco’s AIO application 2. July 31, 1986 Notice of hearing, mailings 3. August 29, 1986 Supplemental data 4. September 30, 1986 Amoco’s letter to AOGCC 5. October 6, 1986 Amoco’s letter to AOGCC 6. November 4, 1986 EPA’s letter to Amoco: Termination of EPA Rule Authorization for Injection Wells 7. September 27, 2004 Public notice 8. December 21, 1994 AOGCC’s letter to Unocal: Use of Treated Effluent as EOR Fluid (Anna and Baker Platforms) 9. June 1, 2005 Unocal’s request for Baker wells 16 and 17 10. July 11, 2005 AOGCC’s response 11. May 10, 2007 Chevron’s AA request for Dillon Platform 12. -------------------- UIC Manager backup information 13. May 17, 2007 AOGCC’s decision that an AA is not necessary 14. August 24, 2010 Chevron’s AIO request (AIO 7.002) 15. October 25, 2010 Email: Baker Platform Fluids Suitable for Injection 16. May 3, 2013 Hilcorp’s AIO 7.002 cancellation request and request to have EOR injection operations governed by provisions of the underlying AIO 7.000 (AIO 7.002 Cancellation and AIO 007.003) 17. -------------------- Annual EOR reports 18. July 27, 2023 Hilcorp request for admin approval to inject class II waste from P&A activities (AIO 7.004) • R , M , ') l STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: THE REQUEST OF AMOCO ) PRODUCTION COMPANY for ) an Area Injection Order) for the portion of the ) Middle Ground Shoal Field) developed by Baker Platform) Area Injection Order No.7 Northern Portion of Middle Ground Shoal Field September 4, 1986 IT APPEARING THAT: 1 . 2 . 3 . FINDINGS: 1 . 2. Amoco Production Company requested the Alaska Oil and Gas Conservation Commission to issue an Area Injection Order permitting the underground injection of fluids within a portion of the Middle Ground Shoal Field for purposes of enhanced hydrocarbon recovery and fluid disposal. Notice of an opportunity for a public hearing on August 30, 1986, was published in the Anchorage Daily News on July 31, 1986. Neither a protest nor a request for a public hearing was timely filed. Accordingly the Commission will, in its discretion, issue an order without a public hear- ing. An order permitting the underground injection of fluids on an area basis, rather than for each injection well individually, provides for efficiencies in the adminis- tration and surveillance of underground fluid injection operations. 20 MC 25.460 provides the Commission with the authority to issue an order governing underground injection operations on an area basis. The portion of the Middle Ground Shoal Field developed by Amoco's platform Baker constitutes a compact "project area" which can readily be described by governmental subdivisions. Amoco is the sole operator of this Project Area. JUL 0 2 20D4 Area Injection òrler No. 7 Page 2 September 4, 1986 3. The Project Area encompasses approximately the nothern one-fourth (1/4) of the Middle Ground Shoal Field. The Project Area includes all existing injection wells and injection well sites planned for enhanced recovery of oil from this portion of theMGS A, B, C, D, E, F and G Oil Pools. The Project Area also includes all well sites planned for disposal by injection into shallower Tertiary strata of oil field waste fluids which may develop from the operation of this portion of the field. 4. The portion of aquifers beneath Cook Inlet described by a 1/4 mile area beyond and lying directly below the Middle Ground Shoal Field are exempted for Class II injection activities by 40 CFR 147.102(b)(2)(B) and 20 AAC 25.440(c). 5. Less stringent requirements for well construction, operation, monitoring, and reporting of injection operations may be more appropriate than would be required when injection occurs into, through or above portions of aquifers not exempted. 6. The vertical limits of injection strata and confining formations may be defined in the Pan American Petroleum Corporation State 17595 well No.4. 7. The strata into which fluids are to be injected will accept fluids at injection pressures which are less than the fracture pressure of the injection strata and their confining formations. 8. Statewide regulations and conservation orders govern field operations except as modified by this order. 9. To ensure that fluids injected are confined to in- jection strata, the mechanical integrity of injection wells should be demonstrated periodically and monitored routinely for disclosure of possible abnormalities in operating conditions. 10. Injection wells existing on the date of this order were constructed and completed in accordance with regu- lations which conform to the requirement of 20 AAC 25.412. SC;\NNED JUt 0 2 2004 ) Area Injection Order No. 7 Page 3 September 4, 1986 ) NOW, THEREFORE, IT IS ORDERED THAT the rules hereinafter set forth govern Class II underground injection operations in the following described area referred to in this order as the affect- ed area: SEWARD MERIDIAN T9N R12W Section 19: S ~. Section 30: all. Section 31 : all. Section 25: E ~. Section 36: E ~. T9N R13W Rule 1 Authorized Injection Strata for Enhanced Recovery Within the affected area, non-hazardous fluids may be injected for purposes of pressure maintenance and enhanced oil recovery into strata defined as those strata which correlate with the strata found in the Pan American Petroleum Corporation State 17595 well No.4 between the measured depths of 5,300 feet and 9,215 feet. Rule 2 Authorized Injection Strata for Disposal Within the affected area, non-hazardous oil field fluids may be injected for the purpose of fluid disposal into strata defined as those strata which correlate with the strata found in the Pan American Petroleum Corporation State 17595 well No.4 in the measured depth intervals of 2620 feet to 3090 feet and 4330 feet to 4955 feet. Rule 3 Fluid Injection Wells The underground injection of fluids must be: 1) through a new well that has been permitted for drilling as a service well for injection in conformance with 20 AAC 25.005; 2) through an existing well that has been approved for conversion to a service well for injection in conformance with 20 AAC 25.280; or 3) through a well that existed as a service well for injection purposes on the date of this order. '''''''C''\-N ~I """E 'f'\, \)i-. J. t) n 2 2004 ) Area Injection drder No. 7 Page 4 September 4, 1986 ') , Rule 4 Monitoring the Tubing/Casing Annulus Pressures The tubing/casing annulus pressure of each injection well must be checked weekly to ensure there is no leakage and that it does not exceed a pressure that will subject the casing to a hoop stress greater than 70% of the casing's minimum yield strength. Rule 5 Reporting the Tubing/Casing Annulus Pressure Variations Tubing/casing annulus pressure variations between consecutive observations need not be reported to the Commission. Rule 6 Demonstration of Tubing/Casing Annulus Mechanical Integrity A schedule must be developed and coordinated with the Commission which ensures that the tubing/casing annulus for each injection well is pressure tested prior to initiating injection and at least once every four years thereafter. A test surface pressure of 1500 psi or 0.25 psi/ft multiplied by the vertical depth of the packer, which ever is greater, but not to exceed a hoop stress greater than 70% of the casing's minimum yield strength, must be held for 30 minutes with no more than a 10 percent decline. The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests. Rule 7 Well Integrity Failure Whenever operating pressure observations or pressure tests indicate pressure communication or leakage of any casing, tubing or packer, the operator must immediately cease injection, notify the Commission, and obtain approval for corrective action. Rule 8 Plugging and Abandonment of Fluid Injection Wells An injection well located within the affected area must not be plugged or abandoned unless approved by the Commission in accor- dance with 20 AAC 25.105. êC-· /~¡Ml\~E' r·' Ii]'; r.Î 2 2004 ',,2' .ï~ð.E'" "'''' ~I\ "" . ) Area Injection Order No. 7 Page 5 September 4, 1986 ') Rule 9 Administrative Relief Upon request, the Commission may administratively amend any rule stated above as long as the operator demonstrates to the Com- mission's satisfaction that sound engineering practices are maintained and the amendment will not result in an increased risk of fluid movement into an underground source of drinking water. DONE at Anchorage, Alaska and dated September 4, 1986. Commission Lonnie C. Smi h, Alaska Oil & Gas Commission :7, '~ÎI~',,1':... SCANN~L, r¡ 21 ?DO¡~ Telecopy No. (907) 276-7542 October 28, 1986 ADM I N 1ST R AT I V E A P PRO V A L N O. 7.1 Re: Amend Rule 7 of Area Injection Order (AIO) No.7 11r.. W.. G. Smith District ~¡anager Amoco Production Company P. O. Box 100779 Anchorage, AK 99510-0779 Dear Mr. Smith: The Commission has determined that Rule 7 of AIO No. 7 as set forth is unclear as to the Comm.ission's intent. Therefore, Rule 7 is amended to read: Rule 7 Well Integrity Failure Whenever operating pressure observations or pressure tests indicate pressure communication or leakage of any casing, tubing or pa.cker, the operator must [IMMEDIATELY CEASE INJECTION,] notify the Commission on the first working day following the observation, [AND] obtain Commission approval [FOR CORRECTIVE ACTION] of a SIan for corrective action, and when an USDW is not endangered, 0 tain Commission approval to continue injection. ß-i-~. ,r~.. ~... .'. 1// ~...........,.1.t:} ( YJ..' "~4:/// \ 1:,/\ '/ ,>;Jj/ " y.- " f..,/~f ///7l>-;"7 '--,~._-- .; .....,·..---.1 ~".... .,.t.'. ~ - "f [.l,:,_' C. V. Chatterton Chairman jo/3.AA AIO 7.1 f» 2 2004, ME OT ALASKA SEAN PARNELL, GOVERNOR ALASKA OIL A" GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMIIIISSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 REVISED ADMINISTRATIVE APPROVAL AIO 7.2 Re: The application of Union Oil Company of California to increase the volume of approved wastes from the Baker Platform for the purpose of disposal into the stratigraphic interval authorized for enhanced recovery by Area Injection Order No. 7. Mr. Timothy Brandenburg Drilling Manager Union Oil Company of California. P. O. Box 196247 Anchorage, Ak 99519-6247 RE: Baker Platform (PTD 177-017 and PTD 185-217 Request for Administrative Approval Mr. Brandenburg: The Alaska Oil and Gas Conservation Commission (Commission or AOGCC) APPROVES Union Oil Company of California (UNOCAL)'s request to increase the allowed disposal volume in wells MGS State 17595 16 [Ba-16] and MGS State 17595 17 [Ba-17] to 100,000 barrels as requested in your letter of August 24, 2010. Prior to beginning disposal operations, please contact the AOGCC Inspectors so that witnessed MITs may be conducted. Production and injection operations were halted on Baker Platform in June 2003 and the platform surface equipment was purged/cleaned of hydrocarbons and most of the equipment removed from the platform. Waste liquids from the purging/cleaning operation were disposed of into the producing formations in Ba-16 and Ba-17 according to AIO 7.002. Slightly in excess of 10,000 barrels of waste was injected. In 2005, the productive intervals of 5 wells were plugged with cement and 7,000 additional barrels of waste was injected. A total disposal volume of 50,000 barrels was originally authorized. Unocal is now planning to place additional, shallower plugs in those 5 wells and deep and shallow plugs in the remaining 18 wells on the platform. Union requested that the total approved waste volume be increased to 100,000 barrels. The increase in volume allows for about 1,400 barrels of waste for each deep plug and 2,500 barrels of waste for each shallow plug. When the work is completed, all well drilled from Baker Platform should be plugged back proximate to the mud line in preparation for ultimate platform removal. The fluid is expected to be primarily comprised of unfiltered inlet water, produced water, produced oil, sludge, triethyleneglycol, paraffin, asphaltenes, deck drainage due to rainfall on the platform and waste liquids from the cementing process. Area Injection Order No. 7 authorizes injection in the Northern Portion of the Middle Ground Shoal Field. Administrative Approval Mr. Timothy Brandenburg AIO 7.2 (Revised) September 2, 2010 Page 2 of 2 AIO 7.002 authorized pumping waste liquids into the producing intervals of Ba-16 and Ba-17. Rule 9 of Area Injection Order No. 7 allows the Commission to administratively amend any rule in the order as long as the operator demonstrates to the Commission's satisfaction that sound engineering practices are maintained and the amendment will not result in an increased risk of fluid movement into an underground source of drinking water. Until the enhanced recovery operations were halted, Baker Platform wells Ba-16 and Ba-17 were operated in compliance with AIO 7 and 20 AAC 25.404 and 25.412. Both wells passed MITs in July 2005 in conjunction with the original deep plugging. The portion of aquifers beneath Cook Inlet described by a '/4 mile area beyond and lying directly below the middle Ground Shoal Field are exempted for Class II injection activities by 40 CFR 147.102(b)(2)(B) and 20 AAC 25.440(c). Disposal operations in these wells will not cause waste due to the limited volume of injectant and the swept condition of the underlying reservoirs that surround these wells. Unocal's correspondence demonstrates that the proposed injection wells have mechanical integrity, and that injection of non -hazardous Class II fluids into strata authorized for enhanced recovery injection by AIO No. 7 will not result in an increased risk of fluid movement into an underground source of drinking water. Pursuant to Rule 9 of Area Injection Order No. 7, the authorized total disposal volume for the well plugging project on Baker Platform is increased to—, 100,000 barrels. Witnessed MITs should be conducted prior to emplPMg tlw,,wells for dis*a DONE at Anchorage, Alaska and dated September 2, 2010. Daniel T. Se mount, Jr. Chair, Commissioner �4 K. N k �4an n' loner 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 reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. 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 Jerry Hodgden Richard Neahring Mark Wedman Hodgden Oil Company NRG Associates Halliburton 408 18th Street President 6900 Arctic Blvd. Golden, CO 80401-2433 P.O. Box 1655 Colorado Springs, CO 80901 Anchorage, AK 99502 Schlumberger CIRI Baker Oil Tools Drilling and Measurements Land Department 795 E. 94th Ct. 2525 Gambell St, #400 P.O. Box 93330 Anchorage, AK 99515-4295 Anchorage, AK 99503 Anchorage, AK 99503 Jill Schneider Ivan Gillian US Geological Survey Gordon Severson 9649 Musket Bell Cr. #5 3201 Westmar Circle Anchorage, AK 99507 4200 University Drive Anchorage, AK 99508-4336 Anchorage, AK 99508 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 Kenai National Wildlife Refuge Penny Vadla Cliff Burglin Refuge Manager 399 West Riverview Avenue 319 Charles Street P.O. Box 2139 Soldotna, AK 99669-7714 Fairbanks, AK 99701 Soldotna, AK 99669-2139 Richard Wagner Bernie Karl North Slope Borough P.O. Box 60868 K&K Recycling Inc. P.O. Box 69 Fairbanks AK 99706 P.O. Box 58055 Barrow AK 99723 ' Fairbanks, AK 99711 ' Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Tuesday, September 07, 2010 4:13 PM To: 'Aaron Gluzman'; Bettis, Patricia K (DNR); caunderwood@marathonoil.com; 'Dale Hoffman'; 'David Spann'; Fr6d6ric Grenier; 'Gary Orr'; 'Jason Bergerson'; Jerome Eggemeyer; 'Joe Longo'; Marc Kuck; 'Mary Aschoff; Maurizio Grandi; Ostrovsky, Larry Z (DNR); Richard Garrard; 'Sandra Lemke'; Talib Syed; 'Tiffany Stebbins'; 'Wayne Wooster'; 'Willem Vollenbrock'; 'William Van Dyke'; Woolf, Wendy C (DNR); (foms2@mtaonline.net);(michael.j.nelson@conocophillips.com); (Von. L. Hutchins@conocophillips.com); Alan Dennis; alaska@petrocalc.com; Anna Raff; Barbara F Fullmer; bbritch; Becky Bohrer; Bill Penrose; Bill Walker; Bowen Roberts; Brad McKim; Brady, Jerry L; Brandon Gagnon; Brandow, Cande (ASRC Energy Services); Brian Gillespie; Brian Havelock; Bruce Webb; carol smyth; Charles O'Donnell; Chris Gay; Cliff Posey; Crandall, Krissell; dapa; Daryl J. Kleppin; Dave Matthews; David Boelens; David House; 'David Spann'; David Steingreaber; 'ddonkel@cfl.rr.com'; Deborah J. Jones; Delbridge, Rena E (LAA); 'Dennis Steffy'; doug_schultze; Elowe, Kristin; Evan Harness; eyancy; Francis S. Sommer; Fred Steece; Garland Robinson; Gary Laughlin; Gary Rogers; Gary Schultz; ghammons; Gordon Pospisil; Gorney, David L.; Gregg Nady; gspfoff; Harry Engel; Jdarlington Qarlington@gmail.com); Jeff Jones; Jeffery B. Jones Qeff.jones@alaska.gov); Jerry McCutcheon; Jim White; Jim Winegarner; Joe Nicks; John Garing; John Katz (john.katz@alaska.gov); John S. Haworth; John Spain; John Tower; Jon Goltz; Judy Stanek; Julie Houle; Kari Moriarty; Kaynell Zeman; Keith Wiles; 'Kim Cunningham'; Larry Ostrovsky; Laura Silliphant; Marilyn Crockett; Mark Dalton; Mark Hanley (mark.hanley@anadarko.com); Mark Kovac; Mark P. Worcester; Marquerite kremer; 'Michael Dammeyer'; Michael Jacobs; Mike Bill; Mike Mason; Mikel Schultz; Mindy Lewis; MJ Loveland; mjnelson; mkm7200; nelson; Nick W. Glover; NSK Problem Well Supv; Patty Alfaro; Paul Decker (paul.decker@alaska.gov); PORHOLA, STAN T; Rader, Matthew W (DNR); Randall Kanady; Randy L. Skillern; rob.g.drag nich@exxonmobil.com; Robert A. Province (raprovince@marathonoil.com); 'Robert Brelsford'; Robert Campbell; Roberts, Susan M.; Rudy Brueggeman; Scott Cranswick; Scott, David (LAA); Shannon Donnelly; Sharmaine Copeland; Shellenbaum, Diane P (DNR); Slemons, Jonne D (DNR); Sondra Stewman; Steve Lambert; Steve Moothart; Steven R. Rossberg; Suzanne Gibson; tablerk; Tamera Sheffield; Taylor, Cammy O (DNR); Temple Davidson; Teresa Imm; Terrie Hubble; Thor Cutler; Tina Grovier; Todd Durkee; Tony Hopfinger; trmjrl; Vicki Irwin; Walter Featherly; Will Chinn; Williamson, Mary J (DNR); Winslow, Paul M; Yereth Rosen; Aubert, Winton G (DOA); Ballantine, Tab A (LAW); Brooks, Phoebe; Davies, Stephen F (DOA); Fisher, Samantha J (DOA); Foerster, Catherine P (DOA); Johnson, Elaine M (DOA); Laasch, Linda K (DOA); Maunder, Thomas E (DOA); McIver, Bren (DOA); McMains, Stephen E (DOA); Norman, John K (DOA); Okland, Howard D (DOA); Paladijczuk, Tracie L (DOA); Pasqual, Maria (DOA); Regg, James B (DOA); Roby, David S (DOA); Saltmarsh, Arthur C (DOA); Scheve, Charles M (DOA); Schwartz, Guy L (DOA); Seamount, Dan T (DOA); Shartzer, Christine R (DOA) Subject: Administrative Approvals cancelled or revised Attachments: aiol-8 cancel.pdf; aio4e-019 cancel.pdf; aio7-2 revised.pdf Jody J. Colombie Special Assistant Alaska Oil and Gas Conservation Commission 333 West 71h Avenue, Suite 100 Anchorage, AK 99501 (907)793-1221 (phone) (907)276-7542 (fax) • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 ) Area Injection Order No. 007.002 Re: THE APPLICATION OF HILCORP ) (Cancelled) ALASKA, LLC. for Administrative ) Approval to Cancel Administrative ) Middle Ground Shoal (MGS) Field Approval 7.002 which allows injection of ) Middle Ground Shoal A, B, C, D,E, F, G Oil a limited amount of non - hazardous waste ) Pools into wells MGS ST 17595 17 (aka Baker ) 17; PTD 1852170) and MGS ST 17595 16 ) May 28, 2013 (aka Baker 16; PTD 1770170). By letter dated May 3, 2013, Hilcorp Alaska, LLC (Hilcorp) requested approval to cancel Area Injection Order (AIO) 007.002 and have Enhanced Oil Recovery (EOR) injection operations governed by provisions of the underlying AIO 007.000. The Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS the Hilcorp request to cancel AIO 007.002. Administrative approval to allow the use of Middle Ground Shoal State 17595 Wells 16 and 17 (Baker 16; Baker 17) is addressed by separate correspondence dated May 28, 2013. Production and injection operations were halted on Baker Platform in June 2003 and the platform surface equipment was purged /cleaned of hydrocarbons and most of the equipment removed from the platform. AIO 7.002 authorized pumping waste liquids into the producing intervals of Baker 16 and Baker 17. Waste liquids from the purging /cleaning operation were disposed of into the producing formations in Baker 16 and Baker 17 in accordance with AIO 7.002. AOGCC records indicate that from 2003 the Baker 16 well had 10,400 bbls injected, and the Baker 17 well had 15,692 bbls injected into the peripheral areas of the production reservoir. The basis for approval of AIO 7.002 was the depleted nature of the producing intervals completed by Baker 16 and Baker 17. � t c,K �A OIL DONE at Anchorage, Alaska and dated May 28, 2013. ) / I .. r�? 8 Cathy P Foerster Jo Cr. ‘.. • • an��, • Chair, ommissioner Co - missioner "I l i 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 l0 -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) From: Colombie, Jody J (DOA) Sent: Tuesday, May 28, 2013 11:03 AM To: 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); McIver, Bren (DOA); Mumm, Joseph (DOA sponsored); Noble, Robert C (DOA); Norman, John K (DOA); Okland, Howard D (DOA); Paladijczuk, Tracie L (DOA); Pasqua!, 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); ( michael j .nelson @conocophillips.com); AKDCWelllntegrityCoordinator; 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 (jarlington @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; Mark Dalton; 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 Vanish; 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 0 (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; Lara Coates; 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 Subject: Hilcorp Administrative Approvals Middle Ground Shoal Attachments: AIO No 007 002 (Cancelled).pdf; AIO No 007 003.pdf 1 • • Jody J. Colombie Special Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 (907) 793 -1221 (907) 276 -7542 907 2 Easy Peel ®Labe {s 1 • 11 Bend along line to 1 t AVERI(® 5964Tm 1 Use Aver Template 5164® Feed Paper 1 expose Pop-up EdgeTM a • Reid Edwards i� � ( Reservoir Engineer –Cook Inlet Offshore Asset ■v1 C� Hilcorp Alaska, LLC �1 3800 Centerpoint Dr., Ste. 100 . S( r Z— e l 2 -0` Anchorage, AK 99503 ttiquettes fadles a paler ; Se de Repliez a la hachure afin de ; www averycom { Utilisez to aabarit AVERY®5160® r ti ft ,,. e ,„ e „+ reveler le rebord Pop -unTM ; 1- 800 -GO -AVERY ! Easy Peet® Labels i • ® Bend along line to 1 AVERY® 596flTM i Use Avery® Template 5160® . Feed Paper �� expose Pop EdgeTM CI 1 David McCaleb Penny Vadia INS 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 NRG Associates Hodgden Oil Company Halliburton 40818`" St. President 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 69 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 ( � 3 Etiquettes fadles a peter i Sen de Repliez a la hachure afin de i www avery com i Utilises le aabarit AVERY® 5160® ! reveler le rebord PonuDTM ! 14100-GO-AVERY ! • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 7. Re: THE APPLICATION OF ) Area Infection Order No. 007.003 HILCORP ALASKA, LLC. for ) Administrative Approval to re- ) Middle Ground Shoal (MGS) Field establish EOR Class II non - hazardous ) Middle Ground Shoal A, B, C, D,E, F, G fluid injection into wells MGS ST ) Oil Pools 17595 17 (aka Baker 17; PTD ) 1852170) and MGS ST 17595 16 (aka ) May 28, 2013 Baker 16; PTD 1770170). ) By letter dated May 3, 2013, Hilcorp Alaska, LLC (Hilcorp) requested approval to cancel Area Injection Order (AIO) 007.002 and have Enhanced Oil Recovery (EOR) injection operations governed by provisions of the underlying AIO 007.000. The Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS the Hilcorp request for administrative approval to allow the use of Middle Ground Shoal State 17595 Wells 16 and 17 (Baker 16; Baker 17). The request to cancel AIO 007.002 is addressed by separate correspondence dated May 28, 2013. An annual review of the performance of this injection project is required as outlined below and will be the basis for continuing approval of injection into Baker Wells 16 and 17 as currently configured. Production and injection operations were halted on Baker Platform in June 2003 and the platform surface equipment was purged /cleaned of hydrocarbons and most of the equipment removed from the platform. AIO 7.002 authorized pumping waste liquids into the producing intervals of Baker 16 and Baker 17. Waste liquids from the purging /cleaning operation were disposed of into the producing formations in Baker 16 and Baker 17 in accordance with AIO 7.002. AOGCC records indicate that from 2003 the Baker 16 well had 10,400 bbls injected, and the Baker 17 well had 15,692 bbls injected into the peripheral areas of the production reservoir. The basis for approval of AIO 7.002 was the depleted nature of the producing intervals completed by Baker 16 and Baker 17. The AOGCC finds the following regarding Hilcorp's application: 1. Hilcorp intends to utilize Baker 16 and Baker 17 for EOR injection which consists of pre- charging the reservoir for the planned return of oil production from the Baker platform. 2. Hilcorp's request for injection of Class II non - hazardous fluids specifically produced water from production operations and storm water from secondary containment areas on the Baker platform (deck drain fluids) is approved. AIO 007.003 • May 28, 2013 Page 2 of 3 3. Re- establishment of EOR injection and resulting production on the Baker platform does not compromise overall well integrity so as to threaten human safety or the environment. 4. Restoring production from Middle Ground Shoal Oil Pools will ensure greater ultimate recovery and is in the best interests of the State of Alaska. 5. Results of this EOR test are important to the design of Hilcorp's plans for redevelopment of the Middle Ground Shoal oil pools accessed by Baker Platform wells. AOGCC's approval to continue EOR injection is conditioned upon the following: 1. Hilcorp shall restrict injection to water only (no gas or miscible injectant); 2. Hilcorp shall perform a step rate test, baseline temperature survey, and mechanical integrity test of the inner annulus (MITIA) prior to commencing EOR injection; 3. Hilcorp shall monitor and record wellhead pressures and injection rate daily; 4. Hilcorp shall perform a MITIA every 4 years to the maximum anticipated surface pressure, or 1500 psi, or 0.25 psi /ft multiplied by the vertical depth of the packer, whichever is greater, but not to exceed a hoop stress greater than 70% of the casing's minimum yield strength. Refer to AOGCC Industry Guidance Bulletin 10 -002 for additional information about performing MITs; 5. Hilcorp shall submit to AOGCC an annual surveillance report evaluating the performance of the EOR injection by April 1 of each year covering injection operations during the previous calendar year. The report shall include data sufficient to characterize the injection operation, including among other information, the following: injection and annuli pressures (i.e. daily average, maximum, and minimum pressures); fluid volumes injected; injection rates; mechanical condition of the injection wells; and integrity of confining layers. An assessment of the applicability of the injection order findings, conclusions, and rules based on actual performance shall be included with the annual performance report. DONE at Anchorage, Alaska and dated May 28, 2013. Cathy P Foerster WK. Norman y' °' Chair, ommissioner Commissioner 9 ° c a p AIO 007.003 • May 28, 2013 Page 3 of 3 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), "[t]he questions reviewed on appeal are limited to the questions presented to the i ra' n AOGCC by the application for reco n s de ho . " 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: Colombie, Jody J (DOA) Sent: Tuesday, May 28, 2013 11:03 AM To: 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); McIver, Bren (DOA); Mumm, Joseph (DOA sponsored); Noble, Robert C (DOA); Norman, John K (DOA); Okland, Howard D (DOA); Paladijczuk, Tracie L (DOA); Pasqua!, 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); (michael.j.nelson@conocophillips.com); AKDCWelllntegrityCoordinator, 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 (jarlington @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; Mark Dalton; 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 Vanish; 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 0 (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; Lara Coates; 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 Subject: Hilcorp Administrative Approvals Middle Ground Shoal Attachments: AIO No 007 002 (Cancelled).pdf; AIO No 007 003.pdf 1 • • JodyJ. Colombie Special Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 (907) 793 -1221 (907) 276 -7542 2 Easy Pee1e Labels 1 ♦ allim Bend along tine to CA /l►y�(® 5960s�" ; Use Avery® Template 5164® 0 Feed Paper a expose Pop-up Edge"" 0 Reid Edwards /� 1 Reservoir Engineer - Cook Inlet Offshore Asset ‘ (�(l Hilcorp Alaska, LLC ` , 3800 Centerpoint Dr., Ste. 100 �/ ms ( Anchorage, AK 99503 (2- 1 -� Oi\C tctiquettes fadles a paler ; ♦ Repko: a is hachure atin de ; www.avery.com 1 1 I+lu:eeo to naiiv IJ rrt A DVe clan® ! Sens d e _. reveler le rehord Pon -uo*d ! 1 400-GO -AVERY ! Easy Peel® Labels i • 1 Bend along line to 1 CI AVERY® 5960TM ; Use Avery® Template 5160® i ll Feed Paper ■•••■ expose Pop - up EdgeTM 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 NRG Associates Hodgden Oil Company Halliburton 40818` St. President 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 69 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 2N4 2-423 CAC Etiquettes #aches peter ; Se de Repliez it la hachure afin del www.avery.com Utilisez le aabarit AVERY® 5160® reveler le rebord Pon -uoTM ! 1- SOO -GO -AVERY Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov ADMINISTRATIVE APPROVAL AREA INJECTION ORDER NO. 7.004 Mr. Aras Worthington Wells Integrity Manager, PE Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Docket Number: AIO-23-024 Request for Administrative Approval to Area Injection Order 7 Request to Inject Class II Waste from Baker Platform Well Plugging and Abandonment (P&A) Activities Wells MGS ST 17595 16 (PTD 1770170) and MGS ST 17595 17 (PTD 1852170) Dear Mr. Worthington: By letter dated July 27, 2023, Hilcorp Alaska, LLC (Hilcorp) requested administrative approval to inject Class II waste generated from well P&A operations on the Baker platform into the two service wells. In accordance with 20AAC 25.556(d), the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS Hilcorp’s request. AIO 7.002 was issued March 19, 2003, to authorize disposal of up to 50,000 bbls of Class II non- hazardous waste fluids into the depleted oil reservoir. This was revised September 2, 2010, to increase the total volume allowed to 100,000 bbls. It was ultimately cancelled May 28, 2013, when AIO 7.003 was issued that authorized the wells to revert back to enhanced oil recovery injection operations. The basis for the AIO 7.002 approval was the depleted nature of the hydrocarbon producing intervals accessed by the two wells. AOGCC issued Other Order 193 on May 19, 2022, requiring Hilcorp to P&A Baker wells in 2023. Hilcorp will perform a passing state-witnessed mechanical integrity test (MIT) of the inner annulus on each well prior to injection, and again within seven days of initiating injection. These tests will confirm at least two competent barriers to the release of well pressure and will give assurance that the disposal fluids are confined to the authorized injection zone. AOGCC authorizes disposal injection into these two wells up to a combined total of 100,000 bbls. AIO 7.004 August 9, 2023 Page 2 of 2 DONE at Anchorage, Alaska and dated August 9, 2023. Brett W. Huber, Sr Jessie L. Chmielowski Gregory C. Wilson 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. Gregory Wilson Digitally signed by Gregory Wilson Date: 2023.08.09 14:27:13 -08'00' Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.08.09 14:54:25 -08'00' Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.08.09 15:40:28 -08'00' From:Carlisle, Samantha J (OGC) To:AOGCC_Public_Notices Subject:[AOGCC_Public_Notices] Area Injection Order 7.004 (MGS) Date:Thursday, August 10, 2023 9:37:24 AM Attachments:aio7.004.pdf Docket Number: AIO-23-024 Request for Administrative Approval to Area Injection Order 7 Request to Inject Class II Waste from Baker Platform Well Plugging and Abandonment (P&A) Activities Wells MGS ST 17595 16 (PTD 1770170) and MGS ST 17595 17 (PTD 1852170) Samantha Carlisle 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 INDEXES 18 Hilcorp Alaska, LLC Aras Worthington Well Integrity Manager, PE Hilcorp Alaska LLC 3800 Centerpoint Dr., Suite 1400 Anchorage, Alaska 99503 July 27, 2023 Chairman Brett Huber, Sr. Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 VIA EMAIL AND CERTIFIED MAIL Subject: Cook Inlet (Baker Platform) Wells: MGS ST 17595 16 (PTD# 177-017) MGS ST 17595 17 (PTD# 185-217) Request for Administrative Approval to Inject Class II Waste from P&A Activities Dear Chairman Huber, Hilcorp requests an AA to inject Class II waste generated from well P&A operations on the Baker platform into these two service wells (Ba-16 and Ba-17). Approval for this activity had been previously approved via AA 7.002 but was later canceled due to a temporary waterflood project in 2013. The technical justification for using these service wells for disposal operations remains unchanged from the original request made in 2003. Per Docket OTH-022-005 (Public Hearing Notice), and Order 193 resulting from the hearing, Hilcorp was ordered to P&A the wells on the Dillon platform, Baker platform, and Spurr platform in 2022, 2023, and 2024 respectively. Hilcorp has completed the well P&As on the Dillon platform as of July 2023. We are currently moving our temporary camp and well P&A kit from the Dillon to the Baker platform to begin well P&As on the Baker platform. The injection of Class II fluids into Ba-16 and Ba-17 is the safest and lowest-risk option for Class II waste because it is the most efficient means of disposing of this waste. Returned wellbore fluids from the wells as a result of P&A activities can be collected into a return tank on the platform and then plumbed directly from the tank into a pump and into the wellbore and reservoirs of Ba-16 and Ba-17. This eliminates the risk of transferring fluids multiple times from return tanks to Iso-tanks, to a boat, off the boat, and to a Class II well elsewhere. The use of Ba-16 and Ba-17 as disposal wells is the best use of these wells. There are no other options for these wells currently being pursued by Hilcorp. Prior to injection an MITIA will be performed on both of these wells to ensure well integrity during the disposal injection. Within seven days of initiating disposal injection an AOGCC witnessed MITIA will be performed. The MITIAs will validate wellbore integrity as well as reservoir confinement. The wells were originally permitted for 50,000 bbls of total waste. In 2010 it was approved to increase the total volume to 100,000 bbls. Hilcorp requests this total volume be replicated in this AA. Fluids will be primarily comprised of filtered inlet water, produced water, produced oil, sludge, diesel, deck drainage due to rainfall on the platform and waste liquids from the cementing process. The use of the wellbores for disposal injection will not impact the future P&A of the wells adversely. Sincerely, Aras Worthington Well Integrity Manager, PE Hilcorp Alaska, LLC Attachments Technical Justifications Wellbore Schematics Digitally signed by Aras Worthington (4643) DN: cn=Aras Worthington (4643) Date: 2023.07.27 10:23:22 -08'00' Aras Worthington (4643) Technical Justification Well History and Status Well MGS ST 17595 16 was drilled and completed in 1977 as an oil producer. A number of workovers were performed including acidizing, plug-backs, adperfs, squeezes, and recompletes. The well was converted to a gas well in 1992 and then a water injector in 2000, and finally converted into a disposal well during P&A activities in 2005. Recent Well Events: 09/01/2007 SBHPS. 07/27/2005 AOGCC witnessed MIT-IA passed to 1650 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 1650 psi on 07/27/2005, which tests both barriers, demonstrates competent primary and secondary barrier systems. An MITIA will be performed before injection commences and within seven days after injection commences an AGOCC witnessed MITIA will be performed. Proposed Operating and Monitoring Plan 1. 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; 2. Limit the well’s inner annulus operating pressure to 2,000 psi. 3. Limit the well’s outer annulus operating pressure to 1,000 psi. 4. Record injection volumes, pressures, and type of injection fluid (brine, oil, FIW, etc.). 5. 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. Wellbore Schematic Well History and Status Well MGS ST 17595 17 was drilled and completed in 1985/1986 as an oil producer and then converted to an injector in 2000. A number of workovers were performed including acidizing, fracs, gravel packs, plug-backs, adperfs, squeezes, and recompletes. The well was converted to an injection well in 2000 and finally converted into a disposal well in 2005. Recent Well Events: 09/18/2013 AOGCC witnessed MIT-IA passed to 1570 psi 08/26/2007 SBHPS 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 1570 psi on 09/18/2013, which tests both barriers, demonstrates competent primary and secondary barrier systems. An MITIA will be performed before injection commences and within seven days after injection commences an AGOCC witnessed MITIA will be performed. Proposed Operating and Monitoring Plan 1. 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; 2. Limit the well’s inner annulus operating pressure to 2,000 psi. 3. Limit the well’s outer annulus operating pressure to 1,000 psi. 4. Record injection volumes, pressures, and type of injection fluid (brine, oil, FIW, etc.). 5. 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. Wellbore Schematic 17 Hilcorp Alaska, LLC March 27, 2017 E EIV'ED LIAR 312017 / OGk;u Cathy Foerster, Chairman Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Middle Ground Shoal 2016 FOR Report per AI07.003 Dear Commissioner Foerster: Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 In 2013 Hilcorp Alaska, LLC ("Hilcorp") as Operator of the Middle Ground Shoal field proposed a (class II) water injection project on the Baker platform wells 16 and 17. As a condition of AOGCC approval, a surveillance report covering injection operations was required by April 1 of each year. Since no injection activities have occurred, nor are any planned in the foreseeable future, it is requested that this approval be rescinded and reports ceased until further activity is proposed. Monitoring of the existing idle wells on the Baker will continue with no changes in that reporting scheme. Should you have questions, please contact Larry Greenstein at 777-8322. Reid Edwards I Reservoir Engineer 416 • • ) 62013 AOGCC Reid Edwards Reservoir Engineer — Cook Inlet Offshore Asset Hilcorp Alaska, LLC 3800 Centerpoint Drive - Suite 100 Anchorage, AK 99503 May 3, 2013 Chris Wallace Alaska Oil and Gas Conservation Commission 333 W 7`'' Ave #100 Anchorage, AK 99501 Dear Chris: Hilcorp Alaska, LLC requests an Administrative Approval to cancel AIO 007.002 and allow unlimited non - hazardous Class II fluids to be injected for enhanced oil recovery under the original AIO 007.000. Hilcorp Alaska, LLC plans to utilize well Ba -17 (PTD 185 -217, API # 50- 733 - 2038 -100) for FOR injection. This well was chosen as it currently is the only well completed for injection service with a valid MIT (as of 9/6/2011). Injection into well Ba -17 is intended to pre - charge the reservoir for the planned return of oil production from the Baker platform. Administrative Approval AIO 007.002 was approved March 19 2003 to allow for a limited volume of 50,000 bbls of approved non - hazardous Class II wastes generated from planned platform pre- abandonment activities to be injected into service wells Ba -16 (PTD 177 -017, API # 50- 733 - 2030 -000) and Ba -17. Wells Ba -16 and Ba -17 were previously operating under AIO 007.000 as water injectors since 2000. Platform operations were stopped in June 2003 where the surface equipment was cleaned of hydrocarbons and most of the equipment removed from the platform. Approximately 10,000 bbls of waster fluids generated during equipment removal was initially injected. An additional 7,000 bbls was injected in 2005 after cement plugging activities on 5 wells were completed. A revision was made to the Administrative Approval on Sept 2, 2010 after a request was made by Unocal to increase the volume to 100,000 bbls of approved waste fluid in order to handle further abandonment of the well stock. An approximate volume of 28,500 bbls has been injected from 2005 to 2011 during abandonment preparation activities run by Unocal / Chevron. ■ Chris Wallace 1 May 3, 2013 Page 2 It is requested the following Class II non - hazardous fluids be allowed for injection: 1. Produced water from production operations 2. Storm water from secondary containment areas on the Baker platform (deck drain fluids) A step rate injection test will be performed if the AOGCC deems necessary to prove injection capability. It is expected that the reservoir will be able to handle the specified fluids based on sustained injectivities seen when waste fluids were injected into the well. If the commission decides to cancel the current MO 007.002 and allow for injection into well Ba -17, a MIT will be run to prove well integrity before returning well to injection. Within one week of starting injection a witnessed MIT will then be performed. Hilcorp Alaska, LLC will then monitor injection rates and pressures on a daily basis in order to observe any pressure anomalies. Sincerely, // f Opr , ".--- - dwa s 415 0 0 Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, October 25, 2010 4:05 PM To: 'Quick, Mike [ASRC]' Cc: Kanyer, Christopher V; Bonnett, Nigel (Nigel.Bonnett); Kaufman, Kate [Hoefler] Subject: RE: Baker Platform PTD 177-017 and 185-217 Mike, et al, k � V You are correct that the fluids resulting from the cleaning of the surface equipment are suitable for injection into either Ba-17 or Ba-16. Call or message with any questions. Tom Maunder, PE AOGCC From: Quick, Mike [ASRC] [mai Ito: M Quick@chevron.com] Sent: Monday, October 25, 2010 3:48 PM To: Maunder, Thomas E (DOA) Cc: Kanyer, Christopher V; Bonnett, Nigel (Nigel.Bonnett); Kaufman, Kate [Hoefler] Subject: Baker Platform PTD 177-017 and 185-217 Tom — As we discussed on the phone, we are nearing the end of the current phase of work on the Baker Platform. We will be cleaning the flowback equipment that was used on site (separator, pressurized oil scrubbers, etc) with a soap and inlet water mixture, prior to removing the equipment from the platform. It is my understanding that this fluid meets criteria to be disposed of under the approved AIO 7.0 (and subsequent 7.2) into the permitted disposal wells Ba-17 (PTD 185-217) or Ba-16 (PTD 177-017). Best regards, Mike Mike Quick Project Manager / Drilling Engineer MidContinent/Alaska SBU Chevron North America Exploration and Production 3800 Centerpoint Drive, Suite 100 Anchorage, Alaska 99503 Direct 907-263-7900 Fax 1-866-480-5398 mquick chevron.com 10/25/2010 14 Chevron Timothy C Brandenburg Union Oil Company of California Drilling Manager P.O. Box Anchoragee,, AK AK 99519-6247 Ift1h.— —0.0 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com August 24, 2010 F rD Daniel T. Seamount, Jr. Chair ; _3 0 2010 Alaska Oil & Gas Conservation Commission 333 W. 7`h Avenue `., ` � of . rMmssion Anchorage, Alaska 99501 ioti° qp Re: Baker Platform : Area Injection Order Administrative approval 7.2 Dear Mr. Seamount, Union Oil are moving towards performing well P&A's on the Baker and Dillon installations. The Alaska Oil & Gas Conservation Commission authorized the injection of 50,000 barrels of Class II non -hazardous fluids on the Baker Platform, under Area Injection Order Administrative approval 7.2 (AIO 7.2), dated March 19, 2003. Currently, there has been 17,127 bbls (10,400 bbls in Ba- 16 and 6,727 bbls in Ba-17) injected, with 32,873 bbls remaining on AID 7.2. With planning for circulating well operations underway on the 25 wells on the Baker platform and operations expected to commence October 2010, Union Oil respectfully request that AID 7.2 be amended, to an increased disposal limit of 100,000 barrels. This will facilitate operational requirements for circulation and abandonment fluids during the Baker well P&A operations. If you have any questions or would like to discuss this matter, please do not hesitate to contact Nigel Bonnett at 263-7853 or myself at 263-7657. Sincerely, Timothy C. Branden g Drilling Manager TB: sk Cc: Darrell Hammons Larry Greenstein Union Oil Company of California / A Chevron Company 4*13 . . SARAH PALIN, GOVERNOR AllA~1iA OIL AND GAS CONSERVATION COMMISSION May 17,2007 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ms. Jean Bodeau Waste Specialist Chevron North America Exploration and Production PO Box 196247 Anchorage, AK 99519-6247 Re: Administrative Approval Request South Middle Ground Shoal; Baker Platform Dear Ms. Bodeau: The Chevron North America Exploration and Production ("Chevron") has requested authorization to inject up to 15,000 barrels of Class II non-hazardous fluids in Baker Platform wells 16 (PTD 177-017) and 17 (PTD 185-217) located within the Middle Ground Shoal Unit, Cook Inlet. The date of Chevron's request was May 10, 2007. The Alaska Oil and Gas Conservation Commission ("Commission") has already authorized the injection of up to 50,000 barrels of Class II non-hazardous fluids under Area Injection Order Administrative Approval 7.2 ("AIO 7.2") dated March 19, 2003. Additional clarification of fluids eligible for injection under AIO 7.2 was provided to Chevron in a letter dated July 11, 2005. Commission records indicate less than 11,000 barrels of Class II fluids have been injected into Baker 16 since AIO 7.2 was approved; Baker 17 has remained shut in. Chevron's request is a continuation of work initiated under AIO 7.2 requiring no further action by the Commission. A mechanical integrity test must be performed as outlined in AIO 7, Rule 6 prior to recommencing injection. Sincerely, ~~¡:J~ ~1. Foerster Commissioner ~12 TO: .- Jim Regg OK 'D/ & 71-Zp 0':: P.I. Supervisor rl tl J , State of Alaska ) . Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 27, 2005 SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA 16 MGS ST 1759516 . MEMORANDUM ) FROM: Chuck Scheve Petroleum Inspector 1..1/,rJ f7 \ '.' Src: Inspector Reviewed By: P.I. Suprv :JB,tL. Comm NON-CONFIDENTIAL Well Name: MGS ST 1759516 API Well Number: 50-733-20300-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS050722153429 Permit Number: 177-017-0 Inspection Date: 7/12/2005 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 16 Type Inj. N TVD 5067 IA 0 1650 1650 1650 P.T. 1770170 TypeTest SPT Test psi 1266,75 OA 50 120 120 120 Interval OTHER P/F p Tubing 750 750 750 750 Notes: Test performed in preparation for use in disposal of fluids during abandonment of wells on Baker Platform $ÇAN~EP AUG 0 9 2005 v'ednesday, July 27, 2005 Page I of I vs 800 700 600 500 o ($) Q ..,... ~ 16 MEMORANDUM ) TO: Jim Regg Q P.I. Supervisor 1)~1 7fz-.'tID5' . State of Alaska ) Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 27,2005 SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA 17 MGS ST 17595 17 . ,\1 {'...../~ . f '\ Cb'J . N . FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv~ Comm NON-CONFIDENTIAL Well Name: MGS ST 1759517 API Well Number: 50-733-20381-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS0507221 541 06 Permit Number: 185-217-0 Inspection Date: 7/1212005 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 17 Type Inj. N TVD 5280 IIA 250 1650 1630 1630 P.T. 1852170 TypeTest SPT Test psi 1320 lOA 0 0 0 0 Interval OTHER P/F p Tubing 750 750 750 í 750 Notes: Test performed in preparation for use in disposal of fluids during abandonment of wells on Baker Platfonn SCANNED AUG 0 92005 Nednesday, July 27,2005 Page I of I 17 vs 1000 (CJ o -. o o .. " " #11 ,.#If..""" . . Chevron === Jean Bodeau Waste Specialist Chevron North America Exploration and Production 909 West 9th Avenue P.O. Box 196247 Anchorage, AK 99519-6247 Tel 907 263 7803 Fax 907 263 7901 Cell 907 360 7929 Email BodeauJ@chevron.com RECEIVED MAY 1 1 2007 May 10, 2007 Mr. John K. Norman, Chairman Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 Alaska Oil & Gas Cons. Commission Anchorage RE: REQUEST FOR ADMINISTRATIVE APPROVAL TO AIO 7.2 FOR BAKER PLATFORM Dear Mr. Norman: Administrative Approval No. AIO 7.2, issued by AOGCC on March 19,2003, authorized Unocal to perform disposal injection of up to 50,000 barrels of Class II non-hazardous fluids into the upper portion of the Tyonek Formation in wells Ba-16 and Ba-17 on the Baker Platform. The approval was issued to enable disposal of fluids from cleaning of wellbores and surface equipment associated with the Baker Platform. The fluids approved under AIO 7.2 include unfiltered inlet water, produced water, produced oil, sludge, triethyleneglycol, paraffin, asphaltenes and deck drainage due to rainfall on the platform. In 2003, a total of approximately 10,271 barrels of Class II fluids were disposed in Ba-16, and Ba-17 was maintained as a backup. I am writing to request authorization to dispose of up to 15,000 barrels of Class II non- hazardous fluids in wells Ba-16 and/or Ba-17 during 2007. If this full volume were to be disposed, the total injected volume would still be well within the limit authorized in AIO 7.2. The fluids will be generated during cleaning operations on the fuel gas pipeline that runs from the XTO A Platform to the Baker Platform. Although that pipeline is still in use to provide fuel gas to the Baker Platform, its use supports abandonment activities because it provides fuel to keep the lights burning on the Baker Platform. The anticipated fluids include clean seawater, hydrocarbon residue, diesel, xylene, and soap. There may also be produced water, produced oil, sludge, triethyleneglycol, paraffin, asphaltenes and deck drainage due to rainfall on the platform. After receiving conceptual approval from AOGCC to inject the described fluids in these wells, mechanical integrity tests would be performed with AOGCC witnessing. Ba-17 passed its most recent mechanical integrity test which was performed on September 26, 2002 and witnessed by AOGCC inspector Lou Grimaldi. Ba-16 also demonstrated mechanical integrity in its last MIT which was performed on September 26, 2002 and witnessed by Lou Grimaldi. The wells are not currently in use and there are no plans to reactivate the Baker Platform for production. Midcontinent/ Alaska SBU/Chevron North America Exploration and Production http://www.chevron.com .. .,. .. . . We anticipate the project will take place no earlier than July 1 2007. Please contact me at (907) 263-7803 or by email atbodeaui@chevron.comif you require additional information. Thank you very much for your consideration and assistance. Best ~..' A n _ 9~~~ £:~Ipecialist #10 · .¡ ) ) UNOCAL8 :",'-Alaska Laura L. Hammond Waste Management Coordinator Unocal Alaska Tel 907.263.7898 Fax 907.263.7901 Cell 907.398.9900 E-maillhammond@unocal.com June 1,2005 Commissioner John Norman Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 ,RE JUN 0 ~~, 2005 l~Jask¡ Oil & Re: Description of Proposed Work On Baker Platform In 2005 and 2007 Dear Mr. Norman: The purpose of this document is to communicate to you the scope of work proposed by Unocal Alaska during 2005 and 2007 and the disposition of the associated waste streams. Attached please find "Description of Proposed Baker Platform Well and Pipeline Work and Related Waste Disposal." Mr. Tom Maunder recommended that this information be sent to you to secure your concurrence that the fluids associated with the gathering line cleaning and the well work may legally be injected into Baker Wells #16 and #17 under existing permitting and authorizations. Thank you very much for your consideration of these matters, and please contact me at (907) 263-7898 if you would like additional information about the proposed work. Best regards, /~/~ Laura L. Hammond Attachment: 2 pages Cc: Steve Lambe Bill Britt Bill Smith Tom Maunder, AOGCC OR\G\NAl Union Oil Company of California I Unocal Alaska 909 West 9th Avenue. Anchorage. Alaska 99501 http://www.unocal.com ) ) Description of Proposed Baker Platform Well and Pipeline Work and Related Waste Disposal Purpose Project Type and Planned Timeline Waste Streams by Project and Planned Disposition The purpose of this document is to provide an overview of the proposed Unocal Alaska Baker Platform work scope as requested by Mr. Tom Maunder. The following is a list of the prqject types and the planned timeline: Year Project 2005 P & A with cement up to 10 wells 2005 Clean and abandon Baker Pipelines 2007 P & A with cement remaining wells The following table delineates the expected waste streams and their planned disposition for each type of project: Project Type P & A with cement Waste Stream Fluids Clean and abandon Baker Fluids Pipelines Clean and abandon Baker Solids from Production Pipelines Test Separator and Shaker Clean Baker Gas Pipeline Residual Trapped Gas Both Oily Burnable Solids Both Greywater Both Both Blackwater/sewage Clean Trash o R 1 C¡ Il\~ f~\ L Disposition Inject in Well # 16 or # 17 Inject in Well # ,16 or # 17 OtIsite disposal at Commercial Disposal Vendor, likely G&I in Texas at Newpark, or contingent disposal if U nocal Alaska has a permitted Class II Disposal Well set up for G&I such as NNA #2 Vent maximum 3,900 cu ft (based on total pipeline volume) Incineration by Envirotech, Nikiski, AK NPDES Discharge or ISO Tank to Onshore Disposal by Envirotech OtIsite at Septic Vendor KPB Landfill Continued on next page ... .. ) ) Description of Proposed Baker Platform Well and Pipeline Work and Related Waste Disposal, Continued Background for Baker Pipeline Cleaning Project and Information Source Only Fluids To Be Injected The following section provides the background of the Baker Pipeline Cleaning Project and the source of the information: Source: Steve Simpson President Marine Project Management, Inc. 530 West Ojai Avenue #107 Ojai, CA 93023-2471 ph. 805-640-0799 fax 805-640-9955 steves @ mpmLcom www.mpmì.com Reportedly, the gas pipeline is filled with HzS gas, condensate, etc., and the oil line has hydrocarbon liquids and solids. A brief description of the suspension equipment setup / requirements on Baker to handle these products includes testing and pumping equipment, inlet water, pig launcher/receiver, production test separator, shaker, bins and tankage, and a PD pump to reinject fluids. Base procedures are anticipated as follows: 1) At XTO subsea manifold - Isolate pipelines from XTO A via divers closing valves. 2) From Baker - Fill the pipelines with inlet water (unfiltered), vent or flare gas, and perform a leak test. 3) At XTO A - Dive/hot tap both lines, flush pipelines from taps to Baker. Disconnect the pipelines at manifold and tie the two pipelines together creating a loop back to Baker. 4) At Baker - Utilize inlet water to pig the pipelines clean through a production test separator with solids and fluid to shaker/tankage and to dispose of the fluids into injection wells on Baker. Only fluids will be injected into Well # 16 and Well # 17; Unocal Alaska does not plan to mobilize Grind and Inject equipment; we plan to containerize solids captured in shakers and separators and ship them off of the Platform for approved disposal. #9 (f.:J 1'~r·. .. ,:ï;\ 1? fP ..~\' ,I .fl'~ '\ [I II I! iJ¡, '''~ ¡ :!,I'),\ '\ :,:1 ¡:;::; , '¡, 'I if;i.dj I ·1 'I I' n, j ::. );~\ i h !¡ ~ ~ '!,J,.. ~ :1'1.; "\ '¡I :11 :.......~ .~ ....'="~~ ~:,~ ,~ ( ',I<ñ. o~.:\ ,.il. i.:P , 'I 'Ii 1, , ! . , ~-=¡\ , :1 : ) 'i 7""'" ~ 'I ' 'I I 'I \~) L (" J ¡".~'"î1 ~ }ð~~\ /flj ¡1i I] 17·\ ,¡"Ii'\ ¡ ¡I lr \ :~\\~' ! : l ,fjl~ .J ' '. \' I II J" '\ \..... I II. I ,r,1 '\ , "J I ' ,~:~.~,...J, LrJ l..::J iJlj æJ u \~ :J~l 333 W. PH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 FRANK H. MURKOW5KI, GOVERNOR ATtASIiA. OILAlWD GAS CONSERVATION COMMISSION July 11 2005 Ms. Laura L. Hammond Waste Management Coordinator U nocal Alaska 909 West 9th Avenue Anchorage, AK 99501 Dear Ms. Hammond: Unocal Alaska ("Unocal") requested by letter dated June I, 2005 confirmation that liquid wastes developed from gas/oil gathering line cleaning and from well abandonment may be legally injected into service wells previously approved for limited disposal of Class II wastes on Middle Ground Shoal Baker ("Baker") Platform offshore Cook Inlet. Production operations ceased on Baker in June 2003 and Unocal "cleaned" the production equipment on board the platform. Prior to initiating the cleaning operations, Unocal sought administrative approval under Area Injection Order ("AIO") 7 to dispose of liquid wastes in either of three existing enhanced recovery ("EOR") wells on the platform. Injecting wastes into an EOR well are prohibited by Commission regulations, however the Commission determined that the liquids, mostly water and oil with some detergents would not be damaging to the reservoir. AIO 7.2 issued March 23, 2003 authorized disposal of up to 50,000 barrels of liquid wastes into either Ba-16 or Ba-17. The planned "cleaning" operations were performed during July and August 2003 with a total of 10,270 barrels of waste liquid injected into Ba-16. No waste fluid has been injected into Ba-17. At this time Unocal is proposing to conduct downhole plugging operations on about 8 wells on Baker and purge the subsea oil and gas gathering lines connecting Baker with XTO Platform A to the southwest. The anticipated wastes include fluids circulated from wells (filtered and unfiltered Inlet water, cement and small quantities of oil) and fluids circulated from the subsea gathering lines (unfiltered Inlet water and small quantities of oil and condensate). Some solid wastes may be generated by these operations, however Unocal is not seeking to dispose of solids on board Baker. Nor are they seeking approval to inject domestic sanitary wastes that may be generated by the crews performing the operations. The Alaska Oil and Gas Conservation Commission has completed its review of your request. Liquid wastes resulting from the described well plugging and flowline cleaning operations qualify as Class II fluids and may be injected into either Ba-16 or Ba-17 according to AIO 7 and Administrative Approval AIO 7.2. Prior to resuming injection operations, Unocal must .' ( f' ( ,It ,f2/~ ~ Daniel T. Seamount, Jr. Commissioner cc: Steve Lambe U nocal #8 MAR-19-2003 WED 12:48 PM .', .. ) FAX NO. ·~F~f ALASKA OIL A1\ID GAS CONSERVATION COMMISSION December 21, .1994 Alice Bullington Unocal Corporation P.O. Box 196247 Anchorage,AJaska 99519-6247 Re: UIC--Use of treated eft1uent as EOR fluid. Anna and Baker Platfonns Dear Ms. Bullington: ~ ,..--. ) P. 08 ;;:¡;' \? ~ TONY KNOWLES, GOVERNOR 3001 POI=tCUPINE DRIVE ANOHORAGE. ALASKA 00501-3192 PHONE: (907) 2,.9-1433 FAX: (9O?) 278-7542 A\a~ The Commission has reviewed your proposal to augment EOR fluid at Anna and Baker Platforms with sanitary eflluent. The treated effluent is chemically similar to seawater currently injected for enhanced recovery. The Commission concludes that the treated effiuent will function to enhance recovery and will not jeopardize well integrity. Accordingly, under the authority of AlO No.6 and AID No. 7~ the Commission approves the use of treated effluent to support EOR operations on' Anna Platform and Baker Platform. " ~I~ -. L-~ David W. Chairman ----,-. '. ~ ((- "'·:"Ir-'~"" JU'~ :) n 7.0n ~ .s !...; /\j\~ i '3 ,:: :~,,) "., ' . L, Ü t,1 . - ~ ~ I., #7 ) ) ~~ V· . . . -\.. --=~'f"': t....fU 1: /1'*"'1 .1 !.I <\. 1, ;' ;'.:\ .; 'I F ßD'<' ", ·U,I ,.>.oJ'". [ : ¡ , ;, ' " ,1 .r-\\ ,,! J: I"U '.' . ULi JJ ~ rPJ' '\ 'I! '¡_:1 '¡'.1:,I. .,...:J~ , ' , . ,¡ : : ' :, ,I " ; 'j' ¡ . 1,' . .: '':.,~ ',:.0...1 --, ',"W¡ :'~'1 -, /¡\\i¡ !¡l\rrd ) ,!J, '\ ,ii I fJ "\\".:~~>\ /¡'\ \ 1" I" d,--' 1 ) :W ..J:l...':::J LJ \.J '\'..:.::...... tT\ /lJ\ /FJ FRANK H. MURKOW5KI, GOVERNOR AI'.IASIi& OIL AlQ) GAS CONSERVATION COltDDSSION 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279·1433 FAX (907) 276-7542 September 27, 2004 Proposals to Amend Underground Injection Orders to Incorporate Consistent Language Addressing the Mechanical Integrity of Wells The Alaska Oil and Gas Conservation Commission ("Commission"), on its own motion, proposes to amend the rules addressing mechanical integrity of wells in all existing area injection orders, storage injection orders, enhanced recovery injection orders, and disposal injection orders. There are numerous different versions of wording used for each of the rules that create confusion and inconsistent implementation of well integrity requirements for injection wells when pressure communication or leakage is indicated. In several injection orders, there are no rules addressing requirements for notification and well disposition when a well integrity failure is identified. Wording used for the administrative approval rule in injection orders is similarly inconsistent. The Commission proposes these three rules as replacements in all injection orders: Demonstration of Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before injection begins, at least once every four years thereafter (except at least once every two years in the case of a slurry injection well), and before returning a well to service following a workover affecting mechanical integrity. Unless an alternate means is approved by the Commission, mechanical integrity must be demonstrated by a tubing/casing annulus pressure test using a surface pressure of 1500 psi or 0.25 psi/ft multiplied by the vertical depth of the packer, whichever is greater, that shows stabilizing pressure and does not change more than 10 percent during a 30 minute period. The Commission must be notified at least 24 hours in advance to enable a representative to witness mechanical integrity tests. Well Integrity Failure and Confinement Whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, log, or other evidence, the operator shall immediately notify the Commission and submit a plan of corrective action on a Form 10-403 for Commission approval. The operator shall immediately shut in the well if continued operation would be unsafe or would threaten contamination of freshwater, or if so directed by the Commission. A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating well integrity failure or lack of injection zone isolation. Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. The following table identifies the specifìc rules affected by the rewrite. Injection Order "Demonstration of Mechanical Integrity" Affected Rules "Well Integrity Failure and Confinement" "Administrati ve Action" Area Inj ection Orders AIO I - Duck Island Unit AIO 2B - Kuparuk River Unit; Kuparuk River, Tabasco, Ugnu, West Sak Fields AIO 3 - Prudhoe Bay Unit; Western Operating Area AIO 4C - Prudhoe Bay Unit; Eastern Operating Area AIO 5 - Trading Bay Unit; McArthur River Field AIO 6 - Granite Point Field; Northern Portion AIO 7 - Middle Ground Shoal; Northern Portion AIO 8 - Middle Ground Shoal; Southern Portion AIO 9 - Middle Ground Shoal; Central Portion AIO lOB - Milne Point Unit; Schrader Bluff, Sag River, Kuparuk River Pools AIO 11 - Granite Point Field; Southern Portion AIO 12 - Trading Bay Field; Southern Portion AIO 13A - Swanson River Unit AIO 14A - Prudhoe Bay Unit; Niakuk Oil Pool AlO 15 - West McArthur 6 7 9 6 7 9 6 7 9 6 7 9 6 6 9 6 7 9 6 7 9 6 7 9 6 7 9 4 5 8 5 6 8 5 6 8 6 7 9 4 5 8 5 6 9 ) ) Affected Rules "Demonstration of "Well Integrity "Administrative Injection Order Mechanical Failure and Action" Integrity" Confinement" River Unit AlO 16 - Kuparuk River 6 7 10 Unit; Tam Oil Pool 6 8 AIO 1 7 - Badami Unit 5 AIO 18A - Colville River 6 7 11 Unit; Alpine Oil Pool AIO 19 - Duck Island Unit; 5 6 9 Eider Oil Pool AIO 20 - Prudhoe Bay Unit; 5 6 9 Midnight Sun Oil Pool AIO 21 - Kuparuk River 4 No rule 6 Unit; Meltwater Oil Pool AIO 22C - Prudhoe Bay 5 No rule 8 U nit; Aurora Oil Pool 6 9 AIO 23 - Northstar Unit 5 AIO 24 - Prudhoe Bay Unit; 5 No rule 9 Borealis Oil Pool AlO 25 - Prudhoe Bay Unit; 6 8 13 Polaris Oil Pool AIO 26 - Prudhoe Bay Unit; 6 No rule 13 Orion Oil Pool Disposal Injection Orders DIO 1 - Kenai Unit; KU No rule No rule No rule WD-l DIO 2 - Kenai Unit; KU 14- No rule No rule No rule 4 DIO 3 - Beluga River Gas No rule No rule No rule Field; BR WD-l DIO 4 - Beaver Creek Unit; No rule No rule No rule BC-2 DIO 5 - Barrow Gas Field; No rule No rule No rule South Barrow #5 DIO 6 - Lewis River Gas No rule No rule 3 Field; WD-l DIO 7 - West McArthur 2 3 5 River Unit; WMRU D-l DIO 8 - Beaver Creek Unit; 2 3 5 BC-3 DIO 9 - Kenai Unit; KU 11- 2 3 4 17 DIO 10- Granite Point 2 3 5 Field; GP 44-11 Affected Rules "Demonstration of "Well Integrity "Administrative Injection Order Mechanical Failure and Action" Integrity" Confinement" DIO II - Kenai Unit;KU 2 3 4 24-7 010 12 - Badami Unit; WD- 2 3 5 1, WD- 2 010 13 - North Trading Bay 2 3 6 Unit; S-4 DIO 14 - Houston Gas 2 3 5 Field; Well #3 DIO 15 - North Trading Bay 2 3 Rule not numbered Unit; S-5 DIO 16 - West McArthur 2 3 5 River Unit; WMRU 4D DIO 17 - North Cook Inlet 2 3 6 Unit; NCill A-12 DIO 19 - Granite Point 6 Field; W. Granite Point State 3 4 17587 #3 01020 - Pioneer Unit; Well 3 4 6 1702-150A WDW 010 21 - Flaxman Island; 3 4 7 Alaska State A - 2 DIO 22 - Redoubt lJnit; RU 3 No rule 6 01 DIO 23 - Ivan River Unit; No rule No rule 6 IRU 14-31 DIO 24 - Nicolai Creek Order expired Unit; NCD #5 DIO 25 - Sterling Unit; SU 3 4 7 43-9 DIO 26 - Kustatan Field; 3 4 7 KFl Storage Injection Orders SIO 1 - Prudhoe Bay Unit, No rule No rule No rule Point Mcintyre Field #6 SIO 2A- Swanson River 2 No rule 6 Unit; KGSF #1 SIO 3 - Swanson River Unit; 2 No rule 7 KGSF #2 ,Enhanced Recovery Injection Orders EIO 1 - Prudhoe Bay Unit; No rule 8 Prudhoe Bay Field, Schrader No rule Bluff Fonnation Well V-IOS Injection Order EIO 2 - Redoubt Unit; RU-6 ) "Demonstration of Mechanical Integrity" 5 ) Affected Rules "Well Integrity Failure and Confinement" 8 "Administrative Action" 9 I 02-902 (Rev. 3/94) Publisher/Original Copies: Department Fiscal, Department, Receiving AO,FRM STATE OF ALASKA ADVERTISING ORDER NOTICE TO PUBLISHER ADVERTISING ORDER NO. INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO" CERTIFIED AO-02514016 AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COPY OF ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE F R o M AOGCC 333 West ih Avenue, Suite 100 Aü1chorage,AK 99501 907-793-1221 AGENCY CONTACT DATE OF A.O. loòy Colomhie September ?7, ?004 PHONE PCN (907) 793 -I ?~ 1 DATES ADVERTISEMENT REQUIRED: T o Journal of Commerce 301 Arctic Slope Ave #350 Anchorage, AK 99518 October 3, 2004 THE MA TERJAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE OATES SHOWN. SPECIAL INSTRUCTIONS: United states of America AFFIDAVIT OF PUBLICATION REMINDER State of SS INVOICE MUST BE IN TRIPLICATE AND MUST REFERENCE THE ADVERTISING ORDER NUMBER. A CERTIFIED COpy OF THIS AFFIDAVIT OF PUBLICATION MUST BE SUBMITTED WITH THE INVOICE. ATTACH PROOF OF PUBLICATION HERE. division. Before me, the undersigned, a notary public this day personally appeared who, being first duly sworn, according to law, says that he/she is the of Published at in said division and state of and that the advertisement, of which the annexed is a true copy, was published in said publication on the day of 2004, and thereafter for _ consecutive days, the last publication appearing on the _ day of , 2004, and that the rate charged thereon is not in excess of the rate charged private individuals. Subscribed and sworn to before me This _ day of 2004, Notary public for state of My commission expires 9/29/2004 1:10 PM 10f2 Subject: Public Notices From: Jody Colombie <jody_colombie@admin.state.ak.us> ~~1te: We~,2,9Sep2004 13:01 :04 ~0800 To: undisclosed.;;recil:'ients:; .' BÇC: Cynthia B Mciver <bren_mciver@admin.state.ak.us>, i\.ng'ela Webb' <aµgi¢ _webb@admìn.state.alcus>, Robert EMintz, <robert.:...mint?@la\\l.~tate.ak.us>; Christine . Hansen <c.hansen@iogcc.st~te.9k.u$>, Terde.Hubble <hubblètI@b¡J..com>,SQadra Stewman <StewmaSD@BP.com>, Scott & CammyTaylor <staylqr@alaska.net>,· staiJ.e~j· <stanekj.@unoCal..com>, ecolaw <ecolaw@trustees.org>, roset:;lgsdale <roseragsdale@gcLnet>, trmjr 1 <trinjr 1 @aol.colIl>"jbriddle'<jbrìddle@marathonoil.com>, rockhill. <rockhill@aoga.org>, shaneg <sb,ari,eg@evergreengas.c()m>, jdar1ington· <jdai1initon@forestojl.çQ¢>,,:n~lSon <kttelson@petroleumnews~c91tl> ,cboddy <cboddy@Usìbelli~co$>, Mark Dalton: ' . <mark.dalto1i@hdrinc~com>, Shannon Donnelly <shannon.doI1IlellY@conocophillips.com>~,"MarkP. .' ',' ", ,', , : " ,"'(¡, " I· . W örcester" <~arkp,.worc~s~er@conocophillips,.com,>, "Jerry ç. Dethlefs".. ' . . .': ~ ." <jerry.c.dethlefs@conocophillip~.com> ,Bob <bob@inletkeep~r.org:>, wdv. <wdv@dnr.state.ak.us>, tjr <~r@dnr.state.ak. us>,.bbritch <bbritch@alaska.net>, .mjnelson <(njnelson@'purv~p.gertz.c()m>, Charles O'Donnell <charles.o'donnell@veco.com>, "Randy.L. Skillern" <SkilleRL@BP.com>, "DeborahJ. Jones" <JonesD6@BP.com>, "PaulG. Hyatt!! <hyattpg@BP.com>, nSteven R.Rossberg" <It,ossbëRS@BP·.com> ,L¿is <lois@inletkeeper.otg>,D~ Bro$s·<kuacnews@kuac.org>,Gordon Pospisil <PospisG@BP~com>, "Francis :8. S0lÌ1ßi1er1f <S~œmerF$@BP~com>, Mikel S..chultz <Mike1.Schultz@BP.co1)1>, "NickW. Glover" <GloverN'W@BP.com>,,"Daryl J. K1eppin" <K1eppiDE@BP.com>, "JanetD. Platt" <PlattJD@BP.com>, "Rosånne M. Jacobsen" <JacobsRM@BP . coni> ,. ddonkel <ddörikel@cfl.rr.cotrl>,Collins· Mount <collins _ffiount@revenue.state.ak.us>, mckay <mcka.y@gcLnet>" B~baraF Fullmer <barbaraJ:,~lmer@c.oÍlocophillips.com>, bocastwf <bocastwf@bp.coni>, CharlesBark~r : <barker@usgs.gov>, doug~schultze <doug_schultze@xtoenergy.com>, Hank Alford ' <hank.alford@exxonmobìl.com>, Mark Kovac <yesno l@gci.net>, ·gspfoff··., <gspfoff@aurorapower.com>, Gregg N ady <gregg.nady@sheH.cbrn>,Fred. St~ece <fted~s~eece@state.sd. us>, rcrotty <rcrotty@ch2nl.com> ~ Jejones ..<jej9nes@aurorapower.com>, dapa <dapa@alaska.net> ,jroderick <jroderick@gci.net>, eyancy <:::eyancy@.seal-tìte~riet>, "James ·M. Rurid" <jatries~t11.ruud@conocophiÜips.com> ,Brit LiveÎy·<m~Þai.askå@*.n~t>,j,aþ . <j'ah@dtir.state.ak. us>,' Kurt E Olso~ <kurt _ olson@legis.state~ak.us>, buonoje <buonoje@blicom>, Mark Hanley <mark_ hanley@anadarko.com>, loren _lemån' <loren_Jeman@gov.state.ak.us>, Julie Houle <julie~houle@dttr.state.ak~us>,. John WKatz'<jwkatz@sso.org>, StizM J Hill . <suzan~hill@dec.state.ak.us>, tablerk <tablerk@unocal.com>, å-rady <bradY@~oga.org>, Brian Havelock. <beh@dnr.state.ak..us>, bpopp <bpopp@boro~gh.kenaLak.us>,. JirnWhite <jitnwhite@satx.rr.com>, "John S. Haworthtt. <john.s.haworth@exxomriobil.com>, marty <marty@rkindustrial.com>, gh~mons <ghammons@åól.com>, rr;ncle~ <nnclean@pobox.alaska.net>, mkm7200<mkm72Ó()@~o1.co~>" BrIan Gillespie <itbmg@ùa&alaska.edu>, Dávid L Bo~l~ns <dbgelens@~orapöwer.com.>, Todd Durkee <....T... ..D...·.........URIŒ......'......:. .... ..E.....@KM.. ...:....:........ ...G,...·....c.........o......m...·..,........>.. .'......:...G.:'.......ary:.......... S. C...:h...u. I..tz.. .....<.........g.... ary_schultZ@dhr~ståte.ak.Us>, Wa}a¡e,Rancier <. RANem~@pètt()-êåh~4~·:¿å:£,BÜfMinbr:<BiIl_ Mil1er@xtoalas~a.com>, Brandon Gagnon <bgagnon@brènalaw.~OIÌl>, Paul Winslow'::::pmwinslow@forestoiLcom>, Garry Catron <catrongr@bp.com>, Sharmaine Copeland <copelasv@bp.com>, Suzanne Allexan <saJlexan@helmei1ergy.com>,~,~~~~}1;)ir~~..<kristin _ clir~s@dnr.~ta.te'ak' us>'. Kaynell.,Zeman ~~'f;~jG~~;~~\1n'.;_t_~j'~~B~~~ ) ) Public Notices Public Notices <scott.cfartswick@ml11s.gpv>, Brad McKim <mckimbs@BP.com> ~¡,~ÇiS~fin.£i . tb.<= ...at.ta.ç:hed .'. N()ticeanqAttachRleIÎ~ . for ....~b.~. pr<?J?(')9~d ëÙnéñdment Óf '9:Ilderground injection orders and the Public. NoticeHapp¥VëtlJ.~Y #10. J(jd'y Colombie p.....,..."",'...."..", ".,'"....'"...............,..',.,.....""'.,,.,"-"..,.,..,' !...> .... ... . .. ... >¡,Col1tetJ.t-Type: applièätion/msword ¡':M:echanlcallntegrItyproposaLdoc¡. .............................. .... ............. .. ......... b·' 6.·.··.A..·.·.. .. ... ..... .. ... . .' ... ... : Contellt,:,Enco<ll]1,g:. ·.·ase ~ ...., ._~;..., ~~__:-,,,~,;," ,.,___.~....~_._..'.."._.,_.~.. '.,._...~,,~....,._. ,,~....m_'" .'~,~ '. '~"',.~._'~"_'_' ,.,......,.__........,_ . .... .. ... . ... ..... ....................................... ..... .. .......,.. ........... . .. ............ '.. ....~. ... ............... .i¿().~t~~t-t~~'~: applie ationJmsword MechaDlcallntegrlty of Wells NotIce~doc: .... . .... ....... .. .......i...... .... . .' ..... . t.. ..... £..... 4'. ... ! Content..;Encø<;ting: ·uaseu I Content-Type: applicatidIi/msword HappyVaUeytO _ HearingNotice.doc Content-El1cptµng: base(j4 , ' , , , , . .' ,. ..".'. .._. . ow, "_'"'' ."..'~ ~ "'_~.~'~·ø" ....~_."....;"~.., ......._".'... ..".~. ,~" ,__,,",,_,,~ ..~.~ .~."_" _,,'".. . . __.... _... ~,'"...... ... ._,_.. ""_' .._."....._ .... .......'_. _, .~"..' ~w.....:._....,'...--:.._....,~'... ._____".".,."._..:__......:..~.._._._. ,____"" , .'.._-~., ,,,....., ".... ~.-.._.'.....~ 20f2 9/29/2004 I: 10 PM Public Notice ) ) Subject: Public Notice From: Jody Colombie <jody _ colombie@admin.state.ak.us> Date: Wed, 29 Sep 2004 12:55:26 -0800 To: legal@alaskajouma1.com Please publish the attached Notice on October 3, 2004. Thank you. Jody Colombie Mechanical Integrity of Wells Content-Type: applicationlmsword Content-Encoding: base64 Content-Type: applicationlmsword :Ad Order form.doc Content-Encoding: base64 .·._.._...·..'.·,,·...'..n... 1 of 1 9/29/2004 1: 10 PM Citgo Petroleum Corporation PO Box 3758 Tulsa, OK 74136 Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 /fjalkd ItJ/¡tJ'J David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 Kelly Valadez Tesoro Refining and Marketing Co. Supply & Distribution 300 Concord Plaza Drive San Antonio, TX 78216 Robert Gravely 7681 South Kit Carson Drive Littleton, CO 80122 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 Jerry Hodgden Hodgden Oil Com pany 408 18th Street Golden, CO 80401-2433 Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 John Levorsen 200 North 3rd Street, #1202 Boise, ID 83702 Kay Munger Munger Oil Information Service, Inc PO Box 45738 Los Angeles, CA 90045-0738 Samuel Van Vactor Economic Insight Inc. 3004 SW First Ave. Portland, OR 97201 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle, WA 98119-3960 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Schlumberger Drilling and Measurements 2525 Gambell Street #400 Anchorage, AK 99503 David Cusato 200 West 34th PMB 411 Anchorage, AK 99503 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 Ciri Land Department PO Box 93330 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr, Anchorage, AK 99508 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 Jack Hakkila PO Box 1 90083 Anchorage, AK 99519 Darwin Waldsmith PO Box 39309 Ninilchick, AK 99639 James Gibbs PO Box 1597 Soldotna, AK 99669 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 Penny Vadla 399 West Riverview Avenue Soldotna, AK 99669-7714 Richard Wagner PO Box 60868 Fairbanks, AK 99706 Cliff Burglin PO Box 70131 Fairbanks, AK 99707 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 North Slope Borough PO Box 69 Barrow, AK 99723 ..[Fwd: Re: Consistent Wording for Injection \, ìrs - Well Integrity... ) S:ubject:...·[Fwd: .Re:. ··C:qRs.istent· .Wör~lìl1.~..·f?r 1rtj..~.9ti()Il.....9rd~t.~·.··· -····W¢ll...··w.t¢gri~y.·:..<~e(vis~q)]. Ffom:. John Norman<j0hn~~on:nan~a9mil1.state.*~u~?' Date: Fri, 01 Oct 200411:09:2ô+08QO T:9';,;,Jøø~,~¢Q~~fflb:i~::jfJ:,óiìy¿¢çlª~~i~@ª~i~:~r~t~f~¿'*,s~: more -------- Original Message -------- Subject:Re: Consistent Wording for Injection Orders - Well Integrity (Revised) Date:Wed, 25 Aug 2004 16:49:40 -0800 From:Rob Mintz <robert l11intz@law.state.ak.us> To:jim regg@admin.state.ak.us CC :dan seamount@admin.state.ak. us, john norman@admin.state.ak. us Jim, looks good, but I still think maybe it would be good to include the following sentence or something like it in the well integrity and confinement rule: "The operator shall shut in the well if so directed by the Commission." My thinking is that otherwise, an operator might argue that the Commission can only require the well to be shut in by going through an enforcement action, issuing an order after notice and opportunity for hearing, or meeting the strict requirements for an emergency order under the regulations. The proposed language makes clear that it is a condition of the authorization to inject, that the operator must shut in the well if directed by the Commission after a notification of loss of integrity, etc. »> James Regg <.iim regg@admin.state.akus> 8/25/2004 3: 15:06 PM »> Rob - Thanks for the review; here's a redraft after considering your comments. I have accepted most of the suggested edits; also attached is response to questions you pose (responses are embedded in the comments, using brackets [JBR - ...] to set apart from your questions). Jim Regg Rob Mintz wrote: Jim, I have some questions abQut the draft language, which are shown as comments on the first document attached. Based on my current guesses about what the answers will be to my questions, I also have some suggested edits, which are shown as redlines on the second document attached. »> James Regg <jim regg@admin.state.akus> 8/17/20044:33:52 PM »> Please delete previous version (email sent 8/9/04); I found another inconsistency in the injection orders regarding well integrity that I have integrated into the proposed fix. Attached is a proposal for consistent language in our injection orders addressing 3 rules related to well integrity: - "Demonstration of Tubing/Casing Annulus Mechanical Integrity" - "Well Integrity Failure" - "Administrative Actions". This proposal includes input from all Sr. staff (except Jack). If you agree with the approach, I'll work with Jody to prepare the public notice. Main points - Demonstration of Tubing/Casing Annulus Mechanical Integrity - standardizes the wording used for mechanical integrity demonstrations, and establishes abililty to grant alternate methods (e.g., temp survey, logging, pressure monitoring in lieu of pressure testing 10f2 10/2/20044:07 PM [Fwd: Re: Consistent Wording for Injection .ers - Well Integrity... - specific to AIO 2C for Kuparuk, there is wording that is more appropriately included in Well Integrity Failure (i.e., more frequent MITs when communication demonstrated) I - establishes more frequent MIT schedule for slurry injection wells (every 2 yrs) which is consistent with our current practice (but not addressed in regulations) Well Integrity Failure - retitles to "Well Integrity Failure and Confinement"; inserted language regarding injection zone integrity (see DIO 25 and 26) - consistent language regardless of type of injection (disposal, EOR, storage); - eliminates requirement for immediate shut in and secure; aIlows continued injection until Commission requires shut in if there is no threat to freshwater; - eliminates delay in notifying Commission after detect leakage or communication ("i.e., "immediately notify"); - removes language about notifying "other state and federal" agencies; - requires submittal of corrective action plan via 10-403; - requires monthly report of daily injection rate and pressures (tubing and all casing annuli); this is a requirement we currently impose when notified of leak or pressure communication; - notice and action not restricted to leaks above casing shoe as stated in several DIOs Administrative Actions - adopts "Administrative Actions" title (earlier rules used "Administrative Relief"); - consistent language regardless of type of injection (disposal, EOR, storage); - uses "administratively waive or amend" in lieu of terms like "revise", "reissue", etc.; - adds geoscience to "sound engineering principles"; - language is more generic regarding fluid movement out of zone; existing versions mention varying combinations of protecting "freshwater", "aquifers", "USDWs"; "risk of fluid movement"; "fluid escape from disposal zone" Jim Regg John K. Noonan <John Norrnan@?admin.state.us> Commissioner . Alaska Oil & Gas Conservation Commission 20f2 10/2/20044:07 PM jFwd: Re: Consistent Wording for Injection ( }s - Well Integrity... ') ~ùbject: [Fwd: Re:Consistent W ordin~for ItljectioriOnfer~ ~ WèllIþtëgrity{i{evis¢d)] ~r()l11: John N onnan <john_nprmatl@admin.state~ak.µs> Date: Fri, 01 Oct 2004 11:08:55...0800 't9i·,1eªy····j:~g~ø1±íØi,~~:d9,8~~j¢Q:~;gfîiWt~@~gîµ~~,~·~t*~.,~~µ~~;,'.'..'.:.".'..'...' ..... please print all and put in file for me to review just prior to hearing on these amendments. thanx -------- Original Message -------- Subject:Re: Consistent Wording for Injection Orders - Well Integrity (Revised) Date:Thu, 19 Aug 2004 15:46:31 -0800 From:Rob Mintz <robert mintz@law.state.ak.us> To:dan seamount@Jadmin.state.ak.us, jim regg@Jadmin.state.ak.us, john norman@admin.state.ak.us Jim, I have some questions about the draft language, which are shown as comments on the first document attached. Based on my current guesses about what the answers will be to my questions, I also have some suggested edits, which are shown as redlines on the second document attached. »> James Regg <jim regg@admin.state.ak.us> 8/17/20044:33:52 PM »> Please delete previous version (email sent 8/9/04); I found another inconsistency in the injection orders regarding well integrity that I have integrated into the proposed fix. Attached is a proposal for consistent language in our injection orders addressing 3 rules related to well integrity: - "Demonstration of Tubing/Casing Annulus Mechanical Integrity" - "Well Integrity Failure" - "Administrative Actions". This proposal includes input from all Sr. staff (except Jack). If you agree with the approach, I'll work with Jody to prepare the public notice. Main points - Demonstration of Tubing/Casing Annulus Mechanical Integrity - standardizes the wording used for mechanical integrity demonstrations, and establishes abililty to grant alternate methods (e.g., temp survey, logging, pressure monitoring in lieu of pressure testing - specific to AIO 2C for Kuparuk, there is wording that is more appropriately included in Well Integrity Failure (i.e., more frequent MITs when communication demonstrated) - establishes more frequent MIT schedule for slurry injection wells (every 2 yrs) which is consistent with our current practice (but not addressed in regulations) Well Integrity Failure - retitles to "Well Integrity Failure and Confinement"; inserted language regarding injection zone integrity (see DIO 25 and 26) - consistent language regardless of type of injection (disposal, EOR, storage); - eliminates requirement for immediate shut in and secure; allows continued injection until Commission requires shut in if there is no threat to freshwater; - eliminates delay in notifying Commission after detect leakage or communication ("i.e., "immediately notify"); - removes language about notifying "other state and federal" agencies; - requires submittal of corrective action plan via 10-403; - requires monthly report of daily injection rate and pressures (tubing and all casing annuli); this is a requirement we currently impose when notified of leak or pressure communication; - notice and action not restricted to leaks above casing shoe as stated in several DIOs Administrative Actions lof2 10/2/20044:07 PM [Fwd: Re: Consistent Wording for Injection :rs - Well Integrity ... - adopts "Administrative Actions" title (earlier rules used "Administrative Reliet""); - consistent language regardless of type of injection (disposal, EOR, storage); - uses "administratively waive or amend" in lieu of terms like "revise", "reissue", etc.; - adds geoscience to "sound engineering principles"; - language is more generic regarding fluid movement out of zone; existing versions mention varying combinations of protecting "freshwater", "aquifers", "USDWs"; "risk of fluid movement"; "fluid escape from disposal zone" Jim Regg ; John K.Norman <John Norman@admin.state.us> Commissioner Alaska Oil & Gas Conservation Commission Content-Type: applicationlmsword Injection Order language - questions.doc' Content-Encoding: base64 Content-Type: applicationlmsword Injection Orders language edits.doc Content-Encoding: base64 20f2 10/2/2004 4:07 PM ) ) Standardized Language for Injection Orders Date: August 17, 2004 Author: Jim Regg Demonstration of Tubing/Casing Annulus Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before injection begins, after a workover affecting mechanical integrity, and at least once every 4 years while actively injecting. For slurry injection wells, the tubing/casing annulus must be tested for mechanical integrity every 2 years. The MIT surface pressure must be 1500 psi or 0.25 psi/ft multiplied by the vertical depth, whichever is greater, must show stabilizing pressure and may not change more than 10% during a 30 minute period. Any alternate means of demonstrating mechanical integrity must be approved by the Commission. The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests. Well Integrity Failure and Confinement The tubing, casing and packer of an injection well must demonstrate integrity during operation. The operator must immediately notify the Commission and submit a plan of corrective action on Form 10-403 for Commission approval whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, or log. If there is no threat to freshwater, injection may continue until the Commission requires the well to be shut in or secured. A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating pressure communication or leakage. Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. Standardized Language for Injection Orders Date: August 17, 2004 Author: Jim Regg Demonstration of Tubing/Casing Annulus Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before injection begins, at least once every tour years thereafter (except at least once every two years in the case of a slurry injection well), and before returning a \vcIl to service fOOO\V1n,2: aft€.F a workover affecting mechanical integrity, and at least once every <1 yeac; while actively injecting. For ~;¡urry iRjection wells, the tubing/casing annulus lllUSt be tðsted f(ìr mechanical integrity every 2 years. Unless an alternate lTICanS is approved by the COlTI.D1Íssion. l11.cchanical integrity iTIUst be demonstrated by a tubin.2: pressure test using a =R:=t:e M++-surface pressure of must be 1500 psi or 0.25 psi/ft multiplied by the vertical depth, whichever is greater, that ffl-HSf-show3. stabilizing pressure that doesand lnay not change more than IOQ4r percent during a 30 minute period. -Afty alten1ate il1eans of dernonstrating tnechanical integrity must be approved by the Cotnn1ission. The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests. Well Integrity Failure and Confinement Except as otherwise prov·ided in this rule, +!he tubing, casing and packer of an injection well must demonstrate Inaintain integrity during operation. \Vhenever any pressure conlffiunication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, log. or other evidence. t+he operator fB:H:Sf-shall immediately notify the Commission and submit a plan of corrective action on a Form 10-403 for Commission approval;. \vhenever í1n)' pressure COlTIlnUnication7 lecl(age or lack of injection zone isolation is i.ndicated by injection fate. operating pressure observation, tèst, survey, Of log. The operator shall shut in the well if so directed bv the ComnlÌssion. The operator shall shut in the \vell \vithout awaitin.g a response from the Comlnission if continued operation would be unsafe or would threaten contamination of freshwaterIf there is no threat to freslnvater, injection Inay continue until the COl1unission requires the \x,,'eU to be shut in or ~~ecured. Until corrective action is successfully completed, Àª monthly report of daily tubing and casing armuli pressures and injection rates must be provided to the Commission for all injection wells indicating pressure communication or leakage. Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. .[F:d: Re: [Fwd: AOGCC Proposed WI Lang,..)e for Injectors]] ') $l.II;>,Iect: [Fwd: Re: [Fwd: AOGCCProposed WI Language for Injectors]] ~rºm:.VVit1ton·Aubert.·<wint()n _aubert@adrnin.state.al{;us> p~t~:'FJ:¡µ~ 28 Qct~004º9':.1&:?3... ,:O&QO Tø: Jody J Colombie <jody _coloinbie@adniin.state.ak.us> This is part of the record for the Nov. 4 hearing. WGA -------- Original Message -------- Subject: Re: [Fwd: AOGCC Proposed WI Language for Injectors] Date: Thu, 28 Oct 2004 09:41:55 -0800 From: James Regg <jim regg@admin.state.ak.us> Organization: State of Alaska To: Winton Aubert <winton aubert@adrnin.state.ak.us> References: <41812422.8080604@adrnin.state.ak.us> These should be provided to Jody as part of public review record Jim Winton Aubert wrote: FYI. -------- Original Message -------- AOGCC Proposed WI Language for Tue, 19 Oct 2004 13:49:33 -0800 Engel, Harry R <EngeIHR@BP.com> winton aubert@admin.state.ak.us Injectors Subject: Date: From: To: Winton... Here are the comments we discussed. Harry *From: * NSU, ADW Well Integrity Engineer *Sent: * Friday, October 15, 2004 10:43 PM *To: * Rossberg, R Steven; Engel, Harry Ri Cismoski, Doug Ai NSU, ADW Well Operations Supervisor *Cc: * Mielke, Robert L.; Reeves, Donald F¡ Dube, Anna T¡ NSU, ADW Well Integrity Engineer *Subject: * AOGCC Proposed WI Language for Injectors Hi Guys. John McMullen sent this to us, it's an order proposed by the AOGCC to replace the well integrity related language in the current Area Injection Orders. Listed below are comments, not sure who is coordinating getting these in front of Winton/Jim. Overall, looks okay from an Operations perspective. We do have a few ! comments, but could live with the current proposed language. Note the proposed public hearing date is November 4. The following language does not reflect what the slope AOGCC inspectors are currently requiring us to do: "The mechanical integrity of an injection well must be demonstrated before injection begins, at least once every four years thereafter (except at least once every two years in the case of a slurry injection well), and * before* ** 1 of 3 10/28/2004 11:09 AM [Fwd: Re: [Fwd: AOGCC Proposed WI LanL ~ for Inj ectors J] returnj.ng a well to service following a workover affecting mechanical integrity." After a workover, the slope AOGCC inspectors want the well warmed up and on stable injection, then we conduct the AOGCC witnessed MITIA. This language requires the AOGCC witnessed MITIA before starting injection, which we are doing on the rig after the tubing is run. Just trying to keep language consistent with the field practice. If "after" was substituted for "before", it would reflect current AOGCC practices. It would be helpful if the following language required reporting by the "next working day" rather than "immediately", due to weekends, holidays, etc. We like to confer with the APE and get a plan finalized, this may prevent us from doing all the investigating we like to do before talking with the AOGCC. "Whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, log, or other evidence, the operator shall * immediately* ** notify the Commission" - This section could use some help/wordsmithing: "A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating well integrity failure or lack of injection zone isolation." Report content requirements are clear, but it's a little unclear what triggers a well to be included on this monthly report. Is it wells that have been reported to the AOGCC, are currently on-line and are going through the Administrative Action process? A proposed re-write would be: "All active injection wells with well integrity failure or lack of injection zone isolation shall have the following information reported monthly to the Commission: daily tubing and casing annuli pressures, daily injection rates." Requirements for the period between when a well failure is reported and when an administrative action is approved are unclear. This document states "the operator shall immediately notify the Commission and submit a plan of corrective action on a Form 10-403". If we don't plan to do any corrective action, but to pursue an AA, does a 10-403 need to be submitted? The AOGCC has stated they don't consider an AA as "corrective action". Let me know if you have any questions. Joe -----Original Message----- From: Kleppin, Daryl J Sent: Wednesday, September 29, 2004 1:37 PM To: Townsend, Monte A¡ Digert, Scott Ai Denis, John R (ANC) ¡ Miller, Mike E¡ McMullen, John C Subject: FW: Public Notices FYI -----Original Message----- From: Jody Colombie [ mailto:jody colombie@admin.state.ak.us Sent: Wednesday, September 29, 2004 1:01 PM Subject: Public Notices Please find the attached Notice and Attachment for the proposed amendment of underground injection orders and the Public Notice Happy Valley #10. Jody Colombie «Mechanical Integrity proposal. ZIP» «Mechanical Integrity of Wells Notice.doc» 2 of3 10/28/2004 11 :09 AM #6 \~tO srJ4l': 0~ ~.s' ~ ft "G ~ % ~~~ o 'f \ ~ «'1- ' 4,.,0 '''4L PRO'~t:..(, U.S. ":~VIRONMENTAL PROTECTION ACC;~CY REGION 10 1200 SIXTH AVENUE SEATTLE. WASHINGTON 98101 HOV '1986 REPL Y TO A TTN OF MIS 409 w. G. Smith, District Manager Amoco Production Company P.O. Box 100779 Anchorage, Alaska 99510 RE: Termination of EPA Rule Authorization for Injection Wells Dear Mr. Smith: The Alaska Oil and Gas Conservation. Commission issued the Amoco Production Company Area Injection Orders No. 6 for the Northern Portion of Granite Point Field (Platfonns Anna and Bruce) and No.7 for the Northern Portion of Middle Ground Shoal Field (Platform Baker) and No.8 for the Southern Portion of Middle Ground Shoal Field (Platform Dillon) on September 4, 1986. Therefore, the EPA rule authorization under either 40 CFR 144.21 or 40 CFR 144.22 for existing injection wells is tenninated. Sincerely, ¡U;.J;~J Robert S. Burd Director, Water Division cc: C. V. Chatterton, AOGCC R~ :: c : : \i :: [j ", ..... -: c; c ::: ¡ ~ -" - ~...... --' .... ~iasK2 OL & G::; ::sns. Cor:~:71~ssi::. An:;;C::·6.n~~ JUL 0 2 200i~ #5 .---- , tf ,. ~T" AMOCO .,. ) ) ... V~\ ' ! I s .}~ A.~ ;¡(¡~; ,_~<1~tJ,. I.) j A!\\ f)!'?Î - WI f S.l (Ì\\~1 ~~, ~, ?_. ~~5. ~6~ ¡¿'fL.:'! ~~ 12¿~ / f ~. S:.C?~~rv1 . ~.., Amoco Production Company CqMM 11'èy Post Office Box 100779 C();\!~~1 ~ Anchorage, Alaska 99510 n~~~ ;:::i\,irs 907-272-8471 . --.,,- ,.:\¡~ ~_.") ,....,-~- .,'": :,... t.". ~:. , 11,."" '.. . t '., ¡, ., J ~.:; if E.~~(~ I ÍJ .~f',IG .'., *i ~q (·~:::("\L I " _~.~~ . u . ~< :"-.= L I,,...,,R .'-.r.,,', ,""ìl~ .::. l::JcOI.. I - --._-- n. --. ._ ~?'JG ASS! I r:~"3·--A·· 6~·T··-1 ..~-'.>'¡:-:_. "\>!_"~. ¡STATTECHW :~~~!?)\~fTECHI FILE: W. G. Smith District Manager October 6, 1986 File: FEW-251-986.511 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Aflchorage, Alaska 99501 Area Injection Order No.6, Northern Portion of Granite Point Field Area Injection Order No. 7~ Northern Portion of Middle Ground Shoal Field Area Injection Order No.8, Southern Portion of Middle Ground Shoal Field Referencing our letter of September 30, 1986, File: FEW-232-986.511 and telecon between M. T. Minder and J. C. Blagg on October 3, 1986, we are re-submitting our proposed schedule for testing the mechanical integrity of the tubing/casing annulus on our water injection wells. The primary difference in scheduling is that we will now test each well at this time in order to obtain "baseline" surveys rather than test each well individually when its previous test becomes four years old. As with our earlier proposed schedule, each well will then be retested at least once every four years. For ease of operation, retesting on a per platform basis by the following schedule is suggested: Year Platform 1987 Baker 1988 Anna 1989 Dillon 1990 Bruce Tests will be updated every fourth year thereafter. Attached is our proposed test procedure and a listing by platform all injection wells with their respective packer setting depth, required annulus test pressure, and relative comments. kECEIVED OCT 1 0 1986 Alaska Oil & Gas Cons, Commission Anchorage n n n ~ ?nnn C. V. Chatterton, Chairman FEW-251-986.511 October 6, 1986 Page 2 We will begin the annulus pressure tests as soon as possible following approval of our program. Please direct any questions to Jeff Blaggªt 562-2147. Very truly yours, IÍ//~ W. G. Sm; th District Manager cc: S. W. Souders M. E. Siekawitch JCB/jr 117/jcb1 kECEIVED OCT 1 0 1986 Alaska on & G3S, Cons. Commission A!1c':1~r~!1~ Ü 2 200,J· #4 ~ ~ ' .0?fVfM· GM-- ~ ,.41'-);"( I .¿;:s-CO~1M~ ( tHtfd pl~, calt jdf ~/~3 'COMM I~ Amoco Production Comparý1ES ENG-¡ Post Office Box 100779 SF! F~+3--r Anchorage. Alaska 99510 ("'If") ,...u,....,~ 907-272-8471 ",.) " CI'I\:.:1 I ~ FN'"\-~ v,~ "~('7 ¿:ll\~~"'~ .·,I,·,,(,·.·..r"L ...., "...' ';"'ø'\J r."' R- ' (' .~ ;"';~ .-_..o._ .~?~,..:;¡t::vL _~~'5~!\SSf/ 5!.'!~~,-"SSf-1 _~!~T!ECH, STATTËëRr FILE: /" ~f¡~Jt¿f/~ Á (! 5> ,. .-.T& AMOCO .I~ W. G. Smith District Manager September 30, 1986 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Conmission 3001 Porcupine Drive Anchorage, Alaska 99501 File: FEW-232-986.511 Area Injection Order No.6, Northern Portion of Granite Point Field Area Injection Order No.7, Northern Portion of Middle Ground Shoal Field Area Injection Order No.8, Southern Portion of Middle Ground Shoal Field Regarding Rule 6 of the captioned Area Injection Orders, Amoco Production Company is required to develop and còordinate with the Comnission a schedule for testing the mechanical integrity on each water injection well tubing/casing annulus. We presently have active four water injection wells with completions four years old or older, and we propose renewing the tubing/casing annulus pressure test on these wells by December 31, 1986. Our other water injection wells will be tested when the existing completion becomes four years old or following repair work, and every fourth year thereafter. Please see the attached Tables 1-4 which list by platform our water injection wells and the date of the next tubing/casing annulus pressure test. Also attached is our proposed tubing/casing annulus test procedure. Please direct any technical questions you might have to ,Jeff Blagg at 562-2147 · . ftl ~ Ù.. : Cß..J) )fO-"}t 'tf~9 Very truly yours, I j7 /¿LL t¿//~/ on /~~/#? ~iS~~i~~i~~r k~F/J4I#t:) /If! 'í pM,. t-ø Xrt lie I} / ik- I· .L: JCB/ dds ! /I1f;:tÇ-¡; W J ')1$ MA~¡lfj1i(~1fIT Attachments __f..B.~J:~_Á,4t¿1. ?~.()~.~"}fl.________.o. cc: S. W. ,1 ¡¡¿'lls 5Ât:tAIt<4 +O/t .J D : M. E. I wrl{ c..OMMf,ANiclft"~N -1i,'fYt'/'.14"/'Ct ~ I1t " 3 /) I' IN ;r,.:,.¡ t: '\INlþJJ w,·)Js LÞ.t~OKÞ"'''Ñ(1I: p~Î,s _--o~~._5~I.:,'~~..J~"^~.~ S !Æt:J/~_.~t . W,.¡liNj () H Fl,·/,j,~A{~ {' Co. A pp~;'T-'-- "HNþ¡:Jf"/:J c~ C.,I/",P6JC P \.J~ p~o~ i~ aN/:? ~i~A+ 'UIJI::S I. Abate ~:t~µ1 ;?k..lt/VIJ.': cA. ~ i i ,'~ be1'!~ Ii;.. e M I r D"" ~~ "-Y/~ t,~ ~. ~ b, H'1....'31 '-'/fr->¡( z.þ~ ~f w-tV, (, (-'¿~ "r...:.i/;,1 ~..,~~''t c . ::J F~ s <;. t"'1" 1 (ð')"' .d Þ ~ , z..ç ¿?:-:t o¥"' /5-'<"> ø (h...v.e ye 1.,~1iIl."" Y'v-I'!) 2, L..1.:~..J... -z-?'í'ü ...f /--¡1i!t--t;...'S(~~ Ih'" ') I wi 'I s ~ ~.).....L'\ r ~ w.e Lv ~ .r- ~ f,#h"~ ~v~"j .;"'~ (' I ð_ ': ""'"'" ðtl...U·· ~~.,. '. Anchorage ............... JUL 0 2 2004 #3 ) ,. ~T" AMOCO ~I~ w. G. Smith District Manager August 29, 1986 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 File: FEW-220-986.511 Supplemental Data on Waste Disposal Horizons Area Injection Order Applications Middle Ground Shoal and Granite Point Fields ') COMM ,'. Ó~, CO~J¡M ~~y 'cor ~~'''~. 11'> P d . C c:~!~ 1 Amoco ro uctlon om pan' !." I ,-." I 1 . I I ! \ _. L _E·'·;;;....; A, c;; '~T I '. ~ \~ \.:.1 If'" 1,~", '"",.7 ,EN-GASS;T..J_ 'STAT;f"ÉCHI 'STAr-TECH! I FILE: ~ " ( AI" #fX.'jr8 Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 'ENG In reference to our applications for Area Injection Orders, Platforms Baker and Ðillon at the Middle Ground Shoal Field, and Platforms Anna and Bruce at:the Granite Point Field, the attached supplemental data concern- ing horizons for waste disposal is submitted for your consideration. Please contact Mr. Jeff Blagg or Mr. Fred White at 562-2147 if you have questions or require additional information. Sincerely, ~ 7 þ/ ~~/ øß~' w. G. Smith District Manager JCB/dds Attachments 108/jcb1 -- ~f';~~· RECE\VED SEP 0 4 - comm\sston Mas\œ. on & Gas Cons. Anchorage r-..c' ',\\.!^¡iI....r", qU'ì if) C') ?OO,,~ ~'.l·th!n¡¡!:.J-> JI L 1j :~) I- ~j' ~ ') ') 14IÔ .j)t5- jAf/8 WASTE DISPOSAL HORIZON INFORMATION PLATFORMS BAKER AND DILLON MIDDLE GROUND SHOAL FIELD The horizons affected by injection for waste disposal are defined by the following depths in the Pan American Corporation State 17595 Well No.4: Horizon Name Measured Depth True Vertical Depth Kenai Group Tyonek "A" Sand 2,620 - 3,0901 2,534 - 3,004' Kenai Group Tyonek "c" Sand 4,330 - 4,955' 4,244 - 4,869' The Tyonek"AI1 sand is an argillaceous channel sandstone and conglomerate interbedded with siltstones, shales, and coals. The sandstone and con- glomerate is predominately quartz and chert with interspersed igneous and metamorphic rock grains. The Tyonek "Cn sand is composed of quartzitic, matrix supported conglomeratic sandstones, interbedded with siltstones, shales, and coals. The beds were deposited by braided streams migrating across the width of their flood plains. The confining zones between, above and below the disposal horizons are a series of tight, impermeable siltstones and shales, varying in thickness from 50 to 200 feet. RECE\\JED SEPO ~ - commission 0" &. Gas Cons. A\asKa \ þ.nchorage J 2 2.00i~ ~ ) ) WASTE DISPOSAL HORIZON INFORMATION PLATFORMS ANNA AND BRUCE GRANITE POINT FIELD The horizons affected by injection for waste disposal are defined by the following depths in the Mobil-Union Granite Point No.1 well: Horizons Name Measured Depth 5,941 - 6;4321 6,432 - 7,714' True Vertical Depth 5,920 - 6,411' 6,411 - 7,693' Kenai Group Tyonek IIAII Sand . Kena i Group Tyonek "B" Sand The Tyonek "A" and "B" sands are an argillaceous channel sandstone and conglomerate. interbedded with siltstones, shales, and coals. The sandstone and conglomerate is predominately quartz and chert with inter- spersed igneous and metamorphic rock grains. The confining zones between, above and below the disposal horizons are a series of tight, impermeable siltstones and shales, varying in thickness from 50 to 200 feet. RECE\VED SEPO l¡_ commission 0" &. Gas Cons. Alaska' Anchorage ') t'. DOli (~, ¿ " ,~¡ #2 STATE OF ALASKA ~ ADVERTISING ORDER F R o M Anchorage Daily News P.. O. Box 149001 Anchorage, Alaska 99514-9001 T o p U B L I S H E R Alaska Oil & Gas Conservation Cbnmission 3001 Porcupine Drive Anchorage"Alaska 99501 ADVERTISING ORDER NO. AO- 08-5566 AGENCY CONTACT Galyn Evans DATE OF A.O. July 29, 1986 PHONE (907)279-1433 DATES ADVERTISEMENT REQUIRED: July 31, 1986 SPECIAL INSTRUCTIONS: )('jt ~AFFIDAVIT OF PUBLICATION UNITED STATES OF AMERICA STATE OF~ qJ- 55 DIVISION. BEFORE ME, THE UNDERSIGNED, A NOTARY PUBLIC THIS DAY . PERSONALLY APPEARED#~rt.;~.'''f~ ... WHO, HE/SHE IS THE PUBLISHED AT ADVERTISEMENT, OF WHICH THE ANNEXED IS A TRUE COPY, WAS PUBLISHED IN SAID PUBLICATION ON THE ~-t- DAY OF M-- 198'L, AND THEREAFTER FOR () CONSECUTIVE DAYS, THE LAST PUBLICATION APPEARING ON THE .3I<1I;AY OF ~ 19jt, AND THAT THE RATE CHARGED THEREON IS NOT IN EXCESS OF THE RATE . C,1?'~RIVATE IN,DIVIDUA~ -- ..4 .,,~c~ v .¡ SUBSCRIBED AND SWORN TO BEFORE ME THISlLD~Y OF Au" Sl..l<':) T 19~ tlvt (clLQ ).. W P-)1~ 0 cl1t\LÀ . NOTARY PUBLIC FOR STATE OF MY COMMISSION EXPIRES . :rnmrssir¡r ~":'h, i\uverrJt:er ' 02-901 (Rev. 6-85) PUBLISHER REM I N DER- INVOICE MUST BE IN TRIPLlCATEAND MUST REFERENCE THE ADVERTISING ORDER NUMBER. A CERTIFIED COpy OF THIS AFFIDAVIT OF PUBLICATION MUST BE SUBMITTED WITH THE INVOICE. ATTACH PROOF OF PUBLICATION HERE. Notice Of ~ubllc,Hearlng , STATE ÓFÁ~SKA Alaska,Qllarid'G.s · .. ConservâtlOn"¢ðfflmlssrón' ". . ',.':~ ,," ,';:: :Y'" '¡~',~! ';,~w: ,: '" ' Re: The 'aÞP"catldñ:~Øt AMOCO PRODUCTlOM.cö~PANY,' for an. ,Area ,: In'~,oW~\' , .. ¡je;. 'for thorePØrtlcm$"'Ot:,t ;Mld~1e Ground$~I'"'Fte~: ,,' r~ by their' B~keî' a.n~\\1:>" " lon)~f" förm,s.I?:~'$~~~!¿,~:"",.r " The AlaSk. C),11'an" " , . . :c~nser- v.tlon 'Còrnmluf s '''n r8cuested~'b JIll' 15?'1986;fO~' der~ . ar_lnfeCt , övlde III" thOr'l~lon fOr'utRlf rigeXfStfll'i service Wèlls' pltl"nUfted'för'ln~ ledlO'f bythé' U'j$;,':l!nŸlr(Ìft" mecrtal ' Pròt,ct1Ør:i,'~V'a'd __vent '...-v.~;.~lsm· mlttedln' ~.WitÍl',,2Ò ÞlAC 25J105,orao~'Ç"25.28CffÖ Inlld flufdt ;~nd ,for .........,'qf.~".' ~jg'oil:re- from ... A!UcØI'" rOund =, POoIs''/i.¡8, 'Ci~';:e::'F end G . dêflne(fbY:~a' tIon 0rcIIn No. oU,·$ä.. 54 and for "'!t~1 of, non· hazardous .~ffètd 'flOtds, 1nto 1,~allow.rít~!~'~tJ;~~t""'N(¡:!)l;~" partleSWh()'~t~";I.O:~e granting ~ ,thê;;r'I..~ c:juestare'åliowèt'l f 'Y.·i ttle dafeQf)tll."'þ J~r, Whlchto,fl'~'."Wr lieï~' fOr a hé~rl"g:. 1: .'1$ filing Is the AI.skäi~its C,on, serv,.,tlcin"',,. ,com,',,' ", ,,' ',. ' Porcupl~. : Qr¡~: Alaska 9950,1." IV request 'tor 'lINt filed, . he.,lt:I'·. will be held .ti·...., dress.t ':OO.ANI,ðIII;" 1916, Incoftfór~~&:~' AAC25.540~ rf:a·~tm :'rbe',: held, Intereited:PlFf ,miy confirm this 'bf.dlllìîlJ . the CommIssion's off!C!': <I' ,!~279~ 143, after August' t~ì 1, ··,.Ifno,' sUCla prottjlf ......"" ' "M' Commlsll_*11I "~r1lNt: :: Issuance of .........~ .', ,! ....rlng.· . :,: , : Is/LonnIe C. smith " CommiSSioner.,',··.'.":: Alaska 011 and' Gas' conserva:- tion Commission :' . i' Ao.oø-5566 RECEIVED AUG 1 3 1986 Alaska ou & Gas Cons. Commission Anchorage ,JUl. 0 2 200iì 1 :1 Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: The application of AMOCO PRODUCTION COMPANY for Area In- , jection Orders for those portions of the Middle Ground Shoal Field developed by their Baker and Dillion platforms in the Cook Inlet. The Alaska Oil and Gas Conservation Commission has been requested, by letter dated July 15, 1986, to issue orders for area inj ection . to provide authorization for utilizing existing service wells permitted for injection by the U.S. Environmental Protection Agency and subsequent service wells permitted in accordance with 20 AAC 25.005 or 20 AAC 25.280 to inject fluids underground for purposes of enhancing oil recovery from the Middle Ground Shoal Pools A, B, C, D, E, F and G as defined by Conservation Orders No. 44, 53 and 54 and for the disposal of non-hazardous oil field fluids into shallower tertiary strata. Parties who wish to protest the granting of the referenced request are allowed 15 days from the date of this publication in which to file a written request for a hearing. The place of filing is the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska 99501. If a protest and request for hearing is timely filed, a hearing on the matter will be held at the above address at 9:00 AM on August 30, 1986, in conformance with 20 AAC 25.540. If a hearing is to be held, interested parties may confirm this by calling the Commission's office, (907) 279-1433, after August 15, 1986. If no such protest is timely filed, the Commission will consider the issu- ance of the order without a hearing. ke~ Commissioner Alaska Oil and Gas Conservation Commission Published July 31, 1986 f"\ q; 200'~ I! {~, - .". #1 Amoco Production Company Post Office Box 100779 Anchorage. Alaska 99510 907-272-8471 w. G. Smith District Manager July 15, 1986 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 File: FEW-170-986.511 Middle Ground Shoal Field Area Injection Order Application Attached is the Middle Ground Shoal Field, Platform Baker, area injection order application. Amoco Production Company as operator of the Middle Ground Shoal Field, Platform Baker, requests that an area injection order be issued for existing and future injection wells in the field. The injection wells will utilize Tertiary age formations and will be used for fluid disposal or enhanced recovery. This application is submitted in accordance with the regulations of the Alaska Administrative Code, Title 20 - Chapter 25, revised April 2, 1986. The transfer of authori ty from the EPA to the Commi s5i on affects both existing and future injection wells. Existing wells are authorized by pri or permi ts and it is Amoco IS understandi ng that those authori zati ons remain in place until an area injection order is issued. Attached are five (5) copies of the application for your use. Please con- tact Mr. Fred White (263-2206) or Mr. Jeff Blagg (263-2207) if you have questions or require additional information. Sincerely, ø:ÆL¿ W. G. Smith District Manager JCB/dds RECEIVED JUL 24 1986 AJa'ka 0/1 é( G as Cons C . A "'ch . ommlssiolJ ou oragQ , - Attachments n ¡ n~; 700:1 ') ') SECTION A AREA INJECTION ORDER 20 AAC 25.460 Amoco Production Company, as operator of the Middle Ground Shoal Field, Platform Baker, Lease ADL-17595, requests issuance of an Area Injection Order to authorize the use of service wells to inject fluids underground for purposes of enhancing oil recovery, and for disposal of non-hazardous waste fluids generated during normal drilling, workover, and production operations. The Area Injection Order will encompass all lands within the boundary of the Middle Ground Shoal Field (MGS), Platform Baker, Lease ADL-17595, as defined by Conservation Order No. 44. Conservation Order No. 44 is attached as Exhibit 1. The lease boundary and area operated by Amoco Production Company is shown in Figure A. RECE\\JED JUL24 \986 , comf\'\\Ss\on . \ & Gas Cons. þ.\asKa 0\ þ..nchorage l) C) ?OfL1 'J Ice! t.. 1..) ~t TABLE 3 PLATFORM BAKER Tubing/Casing Pressure Test Date Requi red Existing Packer Annulus Operating Completion Setting Test We 1 L No · Status Run Depth Pressure 4 Injecting 04/84 7,031 MD 1875 7,031 TVD BIB) Injecting 03/85 6,047 MD 1550 5,891 TVD 9HU2 Injecting 06/83 8,527 MD 2150 8,110 TVD 12 Injecting 03/85 7,050 MD 1600 6,040 TVD 18 Shut-In 02/82 8,844 MD 1900 7,157 TVD tJ) () ':Þ z ¿: iTI n L ....- ,~ ~ "" c:::> <:::) ~ Remarks /..~ .~ ~<'V ;,~,/ ~~~ r'_, .,c~J ':; . " ~ .;;.,..- g v ?) &:- ·t >" Ç) "Ç \.)~ <)...V > "y ~. ~ .,. .' ~c:J ~..:{j.S . ('oC;J '{"~ ~.. 'S.;.' ~~ ~ .../J! # ~t' ',..,~/ Well shut-in pending workover for tubing leak. This repair should commence during 1987. "~ - + ~ + +"-/ + FIGURE A T 23 2.4 ~ ŠIllIlI'Ì 1111I15 20 - - - - - - - - + + - - + lllllllll e: --- - - - - - - - I - - - - - 26 25 30 - ZCJ - - - - MIDDLE GR~~N+HOAL FIEL+~~ - - - - - + ----- - - - - - - - - - - - - 35 3b 31 - 32 - - - - ADL 17SQ5 - - - - - , \ RI3W - - R 12. \IV - - --=11111111 IIIIIIIIIIII~ II m ^ 2- 6 ~ + + + + 10 II 12- 7 ADL /8754 + + + + /5 14 13 T 18 B + + + N + 22 2..3 2.4 19 \' + + + + 27 26 25 &ECE\\JED I ADL 18756 JUL 211 1986 + + + Gk' ' comm\Ss\on . 0'\ &. G s Cons. ADL /67Lfh Alaska \ Anchorage . 3Lf 35 36 31 - - - - - 3 2- 6 + + + + 10 II IZ 7 + + + + T 7 /5 /'1 /3 N + + + Amoco Production Company SCANNED JUt () 2 2004 . - ) ') SECTION B PLAT 20 AAC 25.402 (c)(l) 20 AAC 25.252 (c)(l) Figure B is a plat showing the location of all wells that penetrate the uppermost injection zone within the MGS Lease ADL-17595 boundary. ~J.(t\\Jt\) 4 \Cj~lò ~\J '- '2. ';1\00 vv;>\\'-'\';;:> .~ 0. ;.:..;;:~ '. ß 1\\9.S"'& Q~ ~t\ct\O\~ o 2: 200i.P'l I I I I I I I I I ____L________ I ¡ I I I I I I I I I I I I I I I I I I I I I I I ------ I I I I 1 25 I · I I I 23 \ . I \ I I 8-1 \ A 2.0 II \ . . I I I 8 I + I I R I R 12 /3 I 12 Â WIW T9N ___ _ _ _ _ -1 ,-__ _ _ _ - _ - - - - - - - - - - - - - - - - - - - - - .,.- - I I I T8N I Û':: I ~CANNED JUL 0 2 20D4 : 't - ... , I :. 4 < 2.5 ---- 36 - _..- ..- . ~ ~ .- 19 FIGURE B 3 -+ - -------- -. '-:1 10 -.- 30 2.7 . : .'_0_- ._. 18 + . 9 + ---- --r- 17 \ü. Ct. \ \J t. ~ \f!J~G \ Ù \.. ~ be ~\$$\O~ .J co\,\,\" c,o\\s. & ß~$ e \Ia. Q\\ I\"cno~~g ~\a.$~ 1"'" I . \3 ~ . 4 6 A.- 15 . 16 . 1 31 I Amoco Production Company 7 . MIDDLE GROUND SHOAL FIELD ) ) SECTION C OPERATORS/SURFACE OWNERS 20 AAC 25.402 (c)(2) 20 AAC 25.252 (c)(2) The surface owners and operators within the area of this Area Injection Order and extending 1/4 mile beyond the boundary (excluding Amoco Produc- tion Company) are: * State of Alaska Department of Natural Resources 3601 C Street Anchorage, Alaska 99503 * Shell Western E and P, Inc. 601 West Fifth Avenue Suite 810 Anchorage, Alaska 99501 \t'tct.\\J't\) \9J~G \ \ \ \.. '2. ~ 'sc;v:::J~ oJ v \l~~~\ co"s. ~ \)as e \J~ 0\\ 1\ nc,'\\o"(ag ~a.s" ,...." ij ~,ì 2~ 20 L ) See attached affidavit. SECTION 0 AFFIDAVIT ). 20 AAC 25.402 (c)(3) 20 AAC 25.252 (c)(3) \ü.(t\\lt\) 4 \Cj~ß ~ U \.. '2. , . ~\,~$\Q~ \j\,)\\\\\\ ûaS conS. ~a.s\<.a. 0\\ &. ~\\cnQ~a.Qe o 2 2.00'1 ) ') AFFIDAVIT STATE OF ALASKA THIRD JUDICIAL DISTRICT Jeffrey C. Blagg, being first duly sworn on oath, deposes and says: That I am an employee of Amoco Production Company. That on the ~I day of July, 1986, I caused to be mailed a true and correct copy of this applica- tion to the following operators and surface owners listed in Section C: Mr. Jim Eason, Acting Director Division of Oil and Gas State of Alaska Department of Natural Resources P.O. Box 7034 Anchorage, Alaska 99510-0734 Mr. M. L. Woodson Shell Western E and P, Inc. 601 West Fifth Avenue Suite 810 Anchorage, Alaska 99501 Rt.C.t.\\Jt.~ \'?J'òtö ~ \) \.. ~ 1.\ .,~\\sc;\Of\ _ 'vv" ('I \\i~ .~ &. GaS .J'" e '~a.$~a. Q\ þ..t\c\\O~(),\ð JUt 0 2: 20D4 ) ) by placing a said copy in the United States Mail with postage prepaid and certified at Anchorage, Alaska. ç ~ (2, þÞ-<¡t'J 1frþ/. Blagg ! '")\ ~ SUBSCRIBED AND SWORN to before me this ~' day of July, 1986. r A-Á /Y\ -;J\-~_ K. ffi C- D ~YY"\ ~tt ;o~r~~;~bliC in and for Alaska I/IY Commission Expires: My commission expires tv1ay2,1987 O ",' ?on,f) ,'. ;:; I:.. -.;,,} ") ') SECTION E DESCRIPTION OF OPERATION 20 AAC 25.402(c)(4) Current and proposed injection operations at MGS Lease ADL-17595 are divided into two broad categories: enhanced recovery and fluid disposal. Enhanced recovery injection wells are used for the introduction of dis- placing fluids into the reservoir to increase the ultimate recovery of oil. Currently, water injection is the only method of enhanced recovery in use atMGS Lease 17595. The injection system utilizes Cook Inlet sea water passed through a network of filters, piping, injection pumps, and manifolding. Future injections may incorporate the injection of produced formation water or polymers. Existing water injection wells and future injection wells will continue to be designed, constructed, operated, and monitored to ensure the injection fluid is entering the oil reservoir. Enhanced oil recovery methods are/will be confined to Tertiary age for- mations. Presently, there are no disposal wells used for the disposal of produced water or other non-hazardous waste fluids generated during normal drill- ing, workover, or production operations. Future disposal wells for injecting these waste products will be designed, constructed, operated, and monitored to ensure the injected fluid is confined to the injection zone. Waste disposal will be confined to Tertiary age formations. f'\ ~ 2Ûfìlt 'tl/-" ~ ,th ) SECTION F POOL INFORMATION 20 AAC 25.402 (c)(5) ) The pools affected by injection for enhanced recovery and waste disposal are defi ned by Rul e 2 of Conservat ion Order No. 44 as the fo 11 owi ng measured depth intervals in the Pan American Corporation State 17595 No.4 Well: MGS Oi 1 Pool A - 53001 to 57201 MGS Oil Pool B - 57201 to 61001 MGS Oi 1 Pool C - 6100' to 6400' MG S 0 i 1 Pool o - 64001 to 67501 MGS Oi 1 Pool E - 67501 to 70501 MGS 0 il Pool F - 70501 to 73751 MGS 0 i 1 Pool G - 73751 to 92151 nu, ì tQ 9,' ?OCLí ~J L.';, t}"'~ L i ..., ') ) SECTION G GEOLOGIC INFORMATION 20 AAC 25.402 (c)(6) 20 AAC 25.252(c)(4) The Middle Ground Shoal anticline is a long, extremely narrow anticlinal feature which strikes north 10° east on the northern portion. The field is located at the crest of the anticline. The east flank dips from 33°E near the crest to 69°E at the extreme east flank in 17595 No.9. The west flank dips between 55-800W as implied by the 17595 No.8. Depositional patterns in Middle Ground Shoal indicate that the anticline did not exist during Oligocene to Miocene deposition. This is illustrated by the lack of thin or bald s.pots along the crest of the anticline in the depositional patterns. Although sand thickness within each Tyonek zone varies a great deal, pore thicknesses are very similar within each zone. Sands are generally thicker to the north and east but the best reservoir tends to be east and southeast. The Tyonek C and D sand members include units designated by the State of Alaska as Middle Ground Shoal (MGS) A through F as shown on Figure G. The A sand is an alluvial sandstone, coal, and flood-plain shale. The BCD is a fill channel deposit. The E and F are estuarine flood plain siltstones, shales and coals. The Miocene Tyonek C sands are composed of quartzitic, matrix supported conglomeratic sandstones, interbedded with siltstones, shales and coals. These beds were deposited by braided streams, migrating across the width of their flood plains. The E and F zones represent a transgressive phase with siltier sands. The best quality reservoir occurs to the northeast and southwest in the F zone. The best reservoir was deposited to the east and southeast during A through E time. Sands are thicker to the northeast only during the depo- sition of C and A sands. The A and BCD interval represents a regressive braided stream environment. The best quality sand was deposited on strike over the eastern flank of the field. The Oligocene Hemlock conglomerate is the main reservior of the Middle Ground Shoal Field. This alluvial conglomerate is composed of clast sup- ported conglomerate interbedded with siltstone, sandstone and clays. This conglomerate was deposited by braided stream channels of low to moderate gradient flowing from the north and west. The Hemlock is composed of sub- o 2004 ) rounded moderately sorted quartz, black chert pebbles and metamorphic rock fragments. This unit was deposted uncomformably over the West Foreland. The Hemlock and the overlying Tyonek section pinchout to the east on the Kenai Peninsula. The Hemlock G sands and conglomerates were deposited by braided streams shifting across their flood plain. These conglomerates have a good matrix porosity four to 15 percent and a permeability of only 2.1 md is needed for production. Extensive deposition occurred during G-3, G-4 and G-5 time. Depositional strike was north-south. During G-5 time highest sand deposition occurred along what is now the crest of the anticline. Deposition shifted north and eastward in G-4 time and the northern deposition shifted westward in G-3 time. These sands are very well developed to the north, south, and southeast of Platform Baker. the Middle Ground Shoal area was flooded at the end of G-3 time and a low energy environment existed north of the present location of the platform. The G-2 sand tends to be a tighter sand with average porosity only four to eight percent. The G-l represents a regressive environment of braided stream deposition. Though not as thick as the G-3, G-4 or G-5, this sand is very porous especially north, east and southeast of Baker platform. The A sand has an average net pay thickness of 113 feet, porosity of 19.4 percent, and permeability of 72.3 md. The BCD sand has an average net pay thickness of 199 feet, porosity of 17.8 percent, and permeability of 15.4 md. The EFG sand has an average net pay thickness of 561 feet, porosity of 10.9 percent, and permeability of 2.1 md. The confining zones between and above producing units are a series of tight, impermeable siltstones and shales, varying in thickness from 50 to 200 feet. "JU () 2~ '-' ~ FIGURE G COOK INLET TERTIARY NOMENCLATURE HEAVY AGE !JIIIEi.H PAL Y. SUITES PLEISTO- CENE Hu.. '. "..... PLIOCENE H T , er· stu. MIOCENE ~'v CJ<f., ~O V o EOCENE' PALEO- CENE UPPER CRET-' ACEOUS UP,PER JURASSIC " .,.. ~T"" :..AAAOC 0 "'LV "--,- ,-....--'-",-'-~, -~_...._....-"---"-.",-',....------.".,,, hit.tt 2 35 ~ Q 0:: ~ A233 313 E,i.ote G it ut 333 374 ROCK UNITS Glacial cover Bishop Creek mbr. Sterling Fm. . 'Cook Inlet sand m'br. ~6 ,,.,.,.,.., "~,,,,,,,--~,-~'-,'----.- '....... - -',' ',' . C ~ West Fork mbr..¡s;·· ~ Beluga Fm. 11IfI'-"_....-."..,.-." '*"""-'~__....-""""-_....- -- ..........,_~_~-_--..._-_- ..._~~ --_- ,- ~;.,_- 11 Chuitna mbr. HA" sand mbr. « ~ Tyonek F{'). "8" sand mbr. ~(~\~ "C" d b o ,\.. ~ sa n m r. ~ ,. \~~'u . e..ci\o~ . \) \.. '2. ~ \J")~~\~ ~ \})~~... 0" san d m b r . \:).'ð.~ ~'ð \)\\ ~ ~c"'o~~ ~'ò.~'(..'(). ~ Hemlock Conglomerate '6- STATE, ~ PRODUCING NOMENCLATURE. . MIDDLE G~OU~ SHOAL - "Á" "3" "C" - "0" 6. ,. E" ~ "F" lOG" 6 , '----,'----.......----'-'- ........-"--,-..--,, ---'," ....-,'-,- ....-_..:. - " &:.. ~ Tsadaka mbr. ':. ....-,-.""....-.---,.,..- --,.....- '-.-...--......-, -' -'----,', ..--.; -- -~ - - , 6UUl West Foreland Fm. W j 5 h bon e F m' . Chicka!con Fm. ... ~~-~-~_......,.,- -- .-.- -,--...,., - -~,,-----,--~_..........., .....-, ...............-;----~--........."'- ...,..,- --... M atanuska Fm. ',-- -"'-,' , ",,- ".. .--, ~.-"- -' - ....--',',- - .....-.,--,....-.".., ',....' ~.-.......... Naknek' Fm. , Fr.. fl. ~. l' w M CON N E L. L YAP R' r L . I 9 77 ._ ~ _..~'. .~\""'-__~,~...,~_ . ..:,.... a..", -,.:, _..-~~:~~~..~.-..'~_...._.. crJ\MMt=fi, Ii fit n? ?nn4 () C'¡ ')f\ n PI ~j t(, t.- U l)'"{ . GaS (~; ',,':-' \.<:1 Q\\ &. ."ù ·þ.\'ð.5"'" þ-\Ì~X\'Jr,',\'.;}"'" ~i"'''' Rt.(t.\\t.~ ~ Ù \... '2. 11 ~~'ò All open hole' logs from MGS Lease AOL-17595 are sent to the commission as the logs are completed. 20 AAC 25.402 (c)(7) 20 AAC 25.252 (c)(5) WELL LOGS SECTION H ') ,} ) SECTION I CASING INFORMATION 20 AAC 25.402(c)(8) 20 AAC 25.252(c)(6) Typical MGS Lease ADL-17595 injection wells are cased as shown in Figure 1. All newly completed injection wells will be cased, cemented, and tested in accordance with 20 AAC 25.252. Casing design will be submitted for approval as required under 20 AAC 25.005 (Form 10-401) on the drilling permit application. In wells converted to injection, the casing will be retested in accordance with 20 AAC 25.412(c), and the well will be completed in accordance with 20 AAC 25.412(d). o 2 200ll ~ 2 2004 S;CANNEC' L ::::::::.. 7" LlNE.~ @ BASE OF HEMLOCK "6" <1 '0/;" JNíEK.ME~\"TE CAS\NG @ ToP OF H£MLOc..k. 'I 6 ~- 3 ,,, /3 Vs 5uP..FA<ß.. CA'S/N(,- @ 2-000 ~ ~ 20// C.ONDUc..:rO~ é:! 000/ I 2.00 PILE @ // ~O ~ MUD LINE ~ SEA LEVEL WELLHEAD )., : ] L r ~ ~ I ~ :z X- L., ~ =0= =cx= I~={ FIGUR'E I L 1/ 3 ~ TußIN& o.N\CJ PA<"I<E~ TE..<¿. TED To 4000 PSI ¿ ~ ') ) SECTION J INJECTION FLUID COMPOSITION INJECTION RATE AND PRESSURE 20 AAC 25.402 (c)(9) & (10) 20 AAC 25. 252 (c ) ( 7) & (8) Enhanced Recovery Fluids The type of fluid injected into enhance recovery injection wells is fil- tered, treated Cook Inlet sea water. Water treatment additives include biocide, corrosion inhibitors, scale inhibitors, and oxygen scavengers. The maximum expected injection rate on a field wide basis is 15 MBWPD, and on a per well basis is 6 MBWPD. Water sensitivity tests on core samples showed no significant problems with formation plugging or clay swelling caused by injecting Cook Inlet sea water. The maximum wellhead injection pressure for enhanced recovery injection wells at MGS Lease ADL-17595 is 4000 psig. This pressure is the maximum discharge pressure of the injection equipment. The average injection pressure is estimated to be 3800 psig. Fluid Disposal The injection fluid for disposal is expected to be predominantly drilling, workover, and production related waste fluids. The injection stream could include drilling mud, reserve pit water, contaminated crude, diesel gel, glycol, domestic waste water and workover fluids. There are presently no waste disposal wells on MGS Lease 17595. The maximum expected injection rate on a per well basis is 6000 BPO. The maximum expected wellhead pressure for fluid disposal wells is 4000 psig. The average injection pressure will be determined at such time that a well is converted to waste disposal. I."uii. n? 20fM. t.) ~"'.<" \,;' i''1\:..' ' "o;;} g SECTION K FRACTURE INFORMATION 20 AAC 25.402(c)(11) 20 AAC 25.252(c)(9) The proposed maximum injection pressure for the enhanced recovery and fluid disposal wells will not initiate fractures in the confining strata which might enable the injection or formation fluid to enter freshwater strata. Enhanced Recovery The Hemlock State "G" Conglomerate has a fracture gradient of 0.9 to 1.1 psi/ft. A fracture gradient of 0.9 psi/ft corresponds to a bottom hole injection fracture pressure of 8280 psig. The surface injection pressure is estimated to average 3800 psig with a maximum projected pressure of 4000 psig. Since startup of waterflooding at MGS Lease ADL-17595, injection surveillance data has been collected. Such data has included injection profiles, temperature surveys, injectivity index monitoring, pressure fall off, and step rate tests. This information has verified that water injections have not extended into freshwater zones. Fluid Disposal Injection zones for fluid disposal may exhibit some hydraulic fracturing within the injection horizon around the wellbore because of the nature of the disposal fluids and the potential for high solids content. At such time that a well is converted to fluid disposal, step rate testing will be performed on the Tertiary injection interval to determine the fracture gradient. If the fracture gradient must be exceeded to inject fluids, then additional testing will be performed to ensure that injection or formation fluid will not enter nonexempt freshwater strata. SCANNEC, ~JUl 0 21 2004 ) SECTION L FORMATION FLUID 20 AAC 25.402(c)(12) 20 AAC 25.252(c)(10) A water analysis for the Tertiary State "All is presented as figure L-l. A water analysis for the Tertiary State IIBCDII is presented as Figure L-2. A water analysis for the Tertiary State "EFGII is presented as Figure L-3. n~u¡ f\.,¡ ') 200..~ ,,J 1_, U 4.3 - it (Ne -n..' ia eboft cr.8 1adU4S.8 N.. X. &ad 1.1) NOTE: Kc/l=WWi.cT&m8 pc Uter Xeqfl:: II~ equITa1euu pee U.. . '.'. So4Nm .-....~'~.. D.-" ".-...""'-' ,,-, SëÄNNEDJUl. ();2 ~a@~1 . . ',''''' . . .. '. ~ '. '.' ~;~.." '" --:-'..'" , . ,.. .,,~. r'.'" ,~ ~"~ ':~"~' ~...:.;".:~.,::. ~': .:;';;;~,~~t"::.:C' f f .~~. r', J -r '. ~ .t. :'- . 4 ' .~"... .>:,~ ~ . .. ) 'FIGURE L-l . CL1-12A (R~. 1°":) ~)~ I -'~~~~ ~~ ~~l" ".0. BOX 2127 . ANCHORAGE. ALASKA . CMEMICAL & GæOLOGICALLABORA TORIES ,Ät.lERICAN STRATIGRAPHIC COMPANY. ' . 0;-';1 WATER ANALYSIS REPORT OPERATO!? WI::LL l~O, FIELD COUNTY STATR Pan American Petroleum Corp. MGS Il-S 17595 Middle Ground Shoal DATR August 14, 1970 LOCATION.NE SE Sec. 35. FORMATION A Zone INTERVAl. SAUPLE FRO"" LAB NO.' A-630-1 T~8-N. R-13-W. SM. Alaska REMARKS lè CONCLUSIONS! Sample taken August 6, 1970. ~t!':m.S ~ m~/l AnIona mtr/l .!!!9L! SodIum - - - - - - 3382 147.10 Salfate - - - - - - 4 0.08 Po~um - - - - - 12 0.31 Chlorid. . - . - - - - - 3270 92.21 c.Icimn - - - - - - 7 0.35 Carbonate -. - - - - 396 13.19 U:a~ccium - - - - - 4 0.33 Bicarbona.te - - - - - 2598 42.61 Iron - - - - Hydroxide - - - - - C~,), Total Cationa, 148.09 Total Aniona 148.09 - - - - - - - - To~ ~lved ao1ids, mVl - - - - - 8355 Specific reåatance @ 68°F.: NaCl ~uiVõÙcnt. q/l - - - - - - - 7880 Oboerved - - - - 0.838 obm-meton Oboorvcd pH - - - - - - - - - - 8.3 c.JC1J'ntCld - - - - 0.83 ohm-ØMIt8'a WATER ANALYSIS PATTERN Scala MEQ per Unit Sample above described ('" 111\1\1\ 'j ¡ 11\11\ \1¡¡111111 '1 fit I I ' q I I. , d ~ I Ij I Ii I I I ¡ Nallllll, II 111¡(!i I~I! I III I, 1'1 I~ 1.1k Ca i dl,t IllÞ .'11 I " I ~ ¡II ! ¡I!¡III :/-1 Mg 1 t'l "!i¡ +¡;I~I ¡ 1\ ,i,II!¡I,J ," ! t. I) -I ¡ q ! I III~ I, I Fe q ¡ I 1\ \II,! . " ~t , I I,I! ¡ \1 ¡I, -ill.t J IL L! ,I III COa Cl Cl 50 Na BCO:s 5 Ca SO~ 5 Mg CO:s 5 Fe HCO:s SO" " , .'. I t,', . ~ : . L, V '" , ¡ .;' I:; t:( -1'..'r' I ' . -1'-' b ~. , I':: r; L f;';'.: Ì" ,. ¡ . [ , ,. í ~. ". ¡ ¡ , ,. " I'. t" . l.' . ~;F t: ,:.. r;;~: H: ti~,:' . l1; ,: . . t~.-, ¡l.' r.: :- F.,. j. . f ' ~. .. ff . - r: t" ~: r:',' ~ ", .. ~- . , ) FIGURE L-2 ) CLt.12A (R.1!V. 1-~ð.\) ~: .'. ..: .. : , , :~V. ~-, .~~~ ~;. .~~ ~.J P.O. BOX 2127 . "NCHORAG£. AL.AaKA . CHEMICAL & GÈ01~GICA.i. LABORATORIES AMERICAN stRATIGRAPH.IC COMPANY (::.) WATER ANALYSIS REPORT OP~RATO~ V''lELL ~ O. FIELD COUNTY STATR Pan American Petroleum Corp. MGS 11-1 17595 Middle Ground Shoal DATR August 14. 1970 LAB NO. A-631-2 LOCATION. NE SE Sec. 35. T-8-r{. R-13-W. SM. FORMATION B. C & D Zone INTERV A T~ SAMPLE FRO"" Alaska rot!1ARKS ð: CONCLUSIONS! . . Sample taken August 5. 1970. C¿ticna mf{/l ~ Aniona mg/l .æ!9l! Sodium - - - - - - 3348 145.61 Sulfato - - - - . - 18 0.. 37 Po~nm - - . - - 32 0.95 ChIorid. -. - - 3210 90.52 Cald1U:1 . - - - - - 13 0.65 Carbonate -. - - - - 396 13.19 Ha~um - - - - - 6 0.49 Bicarbonate - . - - 2660 43.62 . Ircn - - - - Hydroxide - . - - . C..,' 147.70 147.70 Tobl Cat1o:1a. - . . . Total Aniooa - - - - Totll di:301ved solida. mq/l - - - . - 8333 Specific: romtance @ 68.P.: NaCl oquiv~cn~ mvl - . - - - . - 7841 ObKrved - - - - 0.848 obm-meten O~cd pH - - - - - - - - - - 8.2 C-\cttt-t!'d - - - - 0.85 ohm-metera WATER ANALYSIS PATTERN Sale MEQ per Unit S~plc above described ( " -11\\1[1111 ¡ 11\ \ 1\\"\1\ \ (!\II! I ¡II'! ' : ! : I I j I f I Na ¡iil I ! ¡II f ~,I ..11111 jllli~ . ,1 c j, Ca 'II' \ \. ~;.. I I ¡. I' .1 1'1 . III II I, i~" -tttt.+ q !! L{Â Mg'! P. ¡ It I., tI '.. ¡ . :{~d I ': I II I It' Inl ~,I¡ ¡ I. 1\ Fe ¡PH,!:i,I!.,. 1 i ' IJ'I\ 11\1111 I 1 I It¡1 ,lijJltl! ¡ !' lit; . f: ~L!.. ! t 111 II . J co. - Cl Cl 50 Na', HC03 5 Ca SO.. 5 Mg C03. 5 Fe HC03 804 (If. _Ne'is ÜIOft anrpbs ÛlducS. Ifa. JC. u4 U) NOTE: JIIC/l=UIllicr- pet' litft' JI~I= )I~ 8qw.,.1ecu pc' Ii- ~hua chloride equi..a1eat=b7 D~ a H~- caJa¡1ado. fr_= I ,or u " I':.". ! l" .... ;; ! . ì ~,.: I ; ~. L;, t;;< I. ' t" t.I.' [): !,: I- ~ ::1: ;;{~ Li, . t"- I ~: Fi' r \~ f} ¡:,;" ~.- r ¡ ", 1.<:' f:' ! . :-~ f: f): !:t~: /;r:: f:...:.-.:;...:...". rI; ~.~? ti, .1;::. It ", .'-"- ~;; r . k ,. f : - . [t r. " H: ~f t<'. . :).i" . '.' '. ~. -:.. .~....~" .:H :0:""" "-:: -. r '."'~"~ '-i~ ~ ~... '.~- ",~,,,,,:,-.;.~,,,~.,,. .,~' .'= :~~:-"~~:.~~~ ' . . ì t-l 0: 2r 2Ö~O if!'~ ~:..,,:;~ ,'~: . ¡. '.' :~f~ I" L- .0 ,.: ,,~'::.. ,';. : ( ,.:~:. --,,"!,'-' ~-:.... ~'. ""'-:-..;;. ,.~- (. "<...'"- . ..; (' ,\ l-: ). CL 1-1 ZA rnl:.V. i~'ð4} ) FIGURE .L-3 fr'_. . CImI\'~(;ATJ « GEOI~O'CrCAL LÁ~Ôr\ÂTÔRi-F:§ ~ çq . 't\\"I')}"';~ í ~~!~ BH~i:H'H~&~~ §1'~AfS(Hì~APHiC COMPAfMY "'.0, 130;( 2,127 . ANCHOR""GE. AI..Af'i(A . VJllTER Jfilh.NALYSIS REPORT 0 P'!J.7J:.A7: OR PC', I: :. '-.:.2' "'l r ~-'p;-;,.t,1"'Ç',1 e.r~l1 C~Tr;.1~ ~1lI:LL ¡\¡O._--1~.s..ø3~~~!S (1) 7i?IRLD__- COUNTY. ~:~ ~"'.?}1:; t~~: _2?o1.rrt ~~ r, .'."''1,~1t, Q~J.1.A.;':;' ,t~J ~!::; L~ ~ Dp,.T1t .T'ìY1P 1 J e¡6c:¡ LAB NO. A-2:::;.h-2.. . h -:,.:~l" .~¡.:.' ..~_:. ~ ~. c' P , . c..: LOC.~TIO~'<l.-J.'."J ;-)~, ,.Jç¿'.;,ß. J::J, '1'::-- .-::J 1> ¡.:~-l"-":). ,.~î'. FORMAT!ON ~¡.::...) ¡!t; n. Cçr,H:1~œnf::.Ðt\~.~ INTERV AL SAUPLE FROM 10nf( ;3tJ:~pg - ~.~ c'.J:"' ~:. '::' J . ~ +, 'J S i::~ :~- s R..~!1A?'T{S &: COHCLUSIO:,W=-. è':,)(~r.y ';!~~";;'T'l' 81i.C-,ht,ì Y ('1011;,~r l'i-ght :T€:ì 1 Q~'I f41 j¡rA.Ìp.. f:5~ 81v () " -: 1~~ "t~~ ~": 1 (~. ,,:~?f}.nç1ß j.:1 ,~- .. ";'/"'1:'; - - -._"--\ C;":;tk,,,;,,,~ E2tr!.l. m~~ J ; ~ 'ø fi2 ~kÆo..":Q :::l:Y) "pot;.!ß.:1i'r'~ ,30.. -_9..;;,,1 '7- Ofl!,f() . - ~1;Stt.tn rj !~~2gn.~:£nr~ ---L- o~ ~)S !;'"'{Q. - - ;=ï ;'~I:~'~~~'~~~ -- ----- IIrc~ c¡je::.i.:g -3..3.6.,.~1L- O. -"'''''''';~_.-........,;. '. ~I- - Tc.:;zJ. (J~'Ohcd íKlZ1~:;¡. r,:-.:¡Il Hz:Cl <;"1UhT1:.,l~t. r::,;;/l ?.;P!, ..-.- - - - - t~~}(}jL- p ? - ~- L::fl",*ro- OW~'PJ~d pH ...--..- ~ .!!2,.'1/1 'J:I.r::.'>,"3./1 O..t;n 0o ') I~C :¿- "'_::.J ..J --L29 5JIIÎ.i.1 S-ql§;üt~ 2(~ 29hS 1/=. _._IW/\.J 1ì .H~ ~,..};- ..t,' Ch.ktrid~ ... - - - - woomt~ BitMb-cm::<.t~ HyÒi"O,...idc To~J Þ¡,:ci,fJ'i:JJ;J ] ":\6,,?), - ".~ -~~.. -'.; - .-_..... , . S~cific .r,;,~tc....t;;~ @ 63°P.: O~rv~d C;,;lcw....t"d 0..92 0/1192 oñ~~tä obm-l~~ lNATEJ::t.. A'NALYSIS PA"£TEIUi S;;1~¡P~C ~bov~ 4~5Crib{~d Nailrlllill.c¡ H.~-t-~.-'r-~. po. '-'-'-'.' -",:_-c-"'~.!..~]-.~'~1 +-'f..........,'-L!...1..rlt.t-~ 1-.. ~.J..fJ.-.,.....~;.4 :'r-""~~~-~~ -~., i' ~,+~~ ~ I,. .L.:<--.t,;-.f.,."'....~.i-t-r~;-!...J...w.J.T~4-7-t-l.J --1-::'-~_..J 4-~ì-'. "". Á-'- ¡,.,J....)ì..- r 7". -t-¡"'...~1;.Lf-1æ....~-t-!4..J._--'-"'; 'f-~~~~1~j~~i;t¡+4:t!i~+-;f.ü~j~:1 ~::~1ii¡~i:i~ ~r-,-,--~~~- J. 7; -~- - ,-,-,..L."'..-r-ì-'-'-'-J.~ "';1 -t-....~..J.hi1H He 0 Sai'3 MEQ ~!' Unit 50 5 HC03 5 304 ~ ./ Fe co;:, (H. 'tf'.tÎUA i~ .t-.:;r',". ~rb~h. iuchJJ" H"k. x... ué LLj 1'iOTE:: 1'.¡;;/1::-.;:ù.'l~li:;'('s;~.4 ;-:r1' tr~ }!óo<'!/:::; f.i.m4:nm (l<¡w,\,&l.7<t. pee lit.... !:!";'.II,,~ Ò~r:..i~ ~o.;lv..J..,«'{=b)' Pv~ . n(WtèOT- ~~~n hoar. ~ta . - _.. -.._. -- -_._. --.-- -.~.-._------.-.~_._,...- ~.... SC/\NNEC JUL 2 2004 . .--.- -.-..--..... ..-..', - . - - ... ~ ..- "_..-"'~.-"-- --._,-.------,-,.--,~ ) ) SECTION M Aquifer Exemption 20 AAC 25.402(c)(13) 20 AAC 25.252(c)(11) The portion of aquifers beneath Cook Inlet described by a '1/4 mile area beyond and lying directly below the Middle Ground Shoal Field are exempted aquifers for Class II injection. (Reference 40 CFR 147.102(b)(2) and 20 AAC 25.440(c).) SCÞ~NNE[' 0...' (1.." 2 0 \I !i \. 'j {., ., . ,.' ) SECTION N HYDROCARBON RECOVERY 20 AAC 25.402(c)(14} ) \ . Incremental hydrocarbon recovery from the Middle Ground Shoal Field, Plat- form Baker, resulting from enhanced recovery waterflood operations is 12.4 MMBO. SCANNELl, n n n? 20011 ) ) SECTION 0 MECHANICAL INTEGRITY 20 AAC 25.402(d) and (e) 20 AAC 25.252(d) and (e) In newly drilled Middle Ground Shoal injection wells, the casing is pres- sure tested in accordance with 20 AAC 25.030(g). If a producing well is converted to injection, the casing pressure test will be repeated in ac- cordance with 20 AAC 25.412 (c), prior to injection. Thereafter, casing-tubing annulus pressures will be monitored on a regular basis and reported monthly on Form 10-406 in accordance with 20 AAC 25.402(d). All injection wells will be constructed in compliance with mechanical integrity criteria as set forth in 20 AAC 25.252(d) and 20 AAC 25.402(d). 20 AAC 25.402(e) requires immediate notice to the Commission and correc- tive action if the casing-tubing annulus pressure subjects the casing to a hoop stress that exceeds 70 percent of the minimum yield strength of the casing, or if there is more than 200 psi change in the pressure between consecutive pressure readings. Amoco Production Company requests to use the 70 percent limit as the alarm for immediate notice and corrective action. By using the 70 percent yield pressure limit, the injection wells can be monitored to detect leaks and operated safely. . Tubing pressure changes and temperature effects during various workover, logging, or testing operations often yield casing-tubing annulus pressure changes greatly exceeding 200 psi. These operations are necessary and occur often during prudent operations. In addition, the annular pressure is sensitive to injection pressures and fluid temperature. Thermal effects and injection rate variation will be a significant controlling factor for casing pressure on water and waste disposal wells. 0 2 2004 ') ) SECTION P WELLS WITHIN AREA 20 AAC 25.402(h) 20 AAC 25.252(h) The wells within the Middle Ground Shoal Field, Platform Baker are shown on FigureB. To the best of Amoco Production Company's knowledge, the wells within the area were constructed, and where applicable, abandoned to prevent the movement of fluids into freshwater sources. SCANNEC, JUL 0 2. 2DO;~ ) ) SECTION Q GAS-OIL RATIOS 20 AAC 25.240 (b) & (c)(l) If this application for an Area Injection Order is approved, then a waiver is requested for 20 AAC 25.240(b) requiring no oil well to exceed 100 percent of the original solution gas-oil ratio. The requirement for an oil well to produce at below 100 percent of the original solution gas-oil ratio will not be necessary in accordance .wtih 25.240(c)(1) because the pool will have an approved additional recovery project in operation. n c;, 2lîD F¡ tJ ¡;, _u. '~'J. ( ) EXHIBIT 1 ( STATE OF ALASKA ùEP .-'L:Z'D{2~~ OF NATURAL ~SOæ.CES DIVISION OF MI::ŒS .AND ~ITNE?J.LS Alaska Oil a nd Gas Conservation Co!TI!Ilit t~e 3001 Porcupine Drive Anchorage, Alaska ?~: THE APPLICATION OF THE SHELL OIL COMP liNY ) ;~1) THE P;'1i ~1E~ICAN PETIOLEID1 CORPORATION, ) covering t~e developme~t or a prescribed area) of the ~iddle Ground Shoal Field for an except- ) ien to Section 2051.1 of t~e Alaska Oil and Gas) Conservation :legulations and !"equesting auth- ) orizaticnto initiate, expand and continue) pressure maintenance or secondary recovery ) operations purusant to the aut~ority granted) by Section 31.05.030 of the Alaska Statutes) Conservation Order #44 July 19, 1967 IT Þ2PE:~1ING ~\7: 1. T~e S~ell Oil Cowpâny a~d the P~n )nerican ~etrole~ Cor?oration submitted a petition dated June 9, 1957, requesting the refer:-ence¿ e:-:ce?tions. and authoriza- tions. , ! 2. Notice of the hearing was published in the Anc~orage Daily ~e~s.on July 3, 1967. Because of a t:ypegraphical error in the original publication .the no.tice of hearing -;.¡as repub lished July 8, 1967. , i , i J. A ~aíver of personal service was received fro~ each or the affected p~rties. ~ I 4. ~ public hearing ~as held in the City Counci~ Ch~be~s of t~e Z. J. Lþussac Library on July 19, 1967. 7esti=ony in support of the petition uas presented by ! Pan A~erican Pet=ole~ Corporation and Shell Oil Cowpany. "~m IT FUlTHE~ AP?EA~I~G that reservoir data presented at the hearing is adequate t~ dete~ine that an exce?tion to the acreage spacing requireme~ts of Section 2061.1 or the Alaska Oil and Gas Conservation ~egulations is necessa~y for the affected area hereinafter described. ~.'.C."!' !¡\~~~~\i'1 ,,;)J Q""~r\'J j ~ ~ \1..,~. C\ '10 fì /1 l L ~I..h I ; ) ) ( ( CONSE~VATION ORDEá #44 Page 2 July 19, 19ó7 .~~D IT F~Td2R ~~PEA1ING that the data on the reservoir perfo~ance as shown at the hearing indicates that tests to dete~ine the feasibility of pressure cain- tena~ce or secondary recovery operations by fluid injection should be ~nitiated and :~at Field luIes authorizing such testing ~~d initiation or pressùre maincen- ance or secondary recovery operations and a continuation and expansion of such operations if proven feasible should be adopced. fu~ IT FURTHEl )~?S~ING t~at certain changes should be ~ade to enlarge the affected area and ~odify rules listed in Conservation ;Jrder #31. Þ~D IT FURTHE~ AP?S~~ING that pool rules establishing requirements for bottom hole pressure surveys, gas-oil ratio surveys, and miniw~ casing and cementing require- ~ents should be adopted for the affected area. ~o~, THER~FORE, IT IS ORDE2ED that the area described as follows is affected by this order: T3N-?.13'"r-l, S. H. Section 1: Section 2: Section 11: Sectio!.1 12: Section 13: Section 14: All EI2 Si¡/~, E/2 S:J/4, ~¡/2 ~/2 All Section 22: Section 23: Section 24: Sect ion 25: Section 26: Section 27: S£/4 All w/2 :~/2 All E/2 T9N-:t 12:J, S. ~. Secticn 19: S/2 Section 30: :\11 Section 31: All T9N-113:.¡, S. M. Section 25: E/2 Section 36: E/2 The following special rules apply to the aforementioned area: 1ule 1, Spaci~g patt~r~ (~) Oil wells ~ay be cocpleted closer than 500 feet to the section lines or quarter secticn lines and aay be cocpleted closer than 1000 feet t~ any well drilling to or c3?ab1e of producing from the sace pool, except that no oil well shall be coopleted ar a distance of less than 500 feet from a lease line where ownership c~anges. ~c i"¡~\H,'t:~I~ \:.¿¡~h~ ~~ \ì~ 0 2. 200[: ( ( CONSERVATION ORDER #44 Page 3 July 19, 1967 (b) ~o more than two oil completions shall be alloved in any governmental quarter section or gover~ental lot corresponding thereto in any pool as designated in ~ule 2. lule 2, Pool designation The vertical producing intervals shall be divided into seven (7) pools which will be cor~elated with the following intervals in the Pan American Petrole~ Corporation State 17595 #4 well. ~~S Oil Pool A 5300' MGS Oil Pool B - 5720' ~GS Oil Pool C - 6100' XGS Oil Pool D - 6400' MGS Oil Pool E - 6750' MGS Oil Pool F - 7050' ~~s Oil Pool G - 7375' to 5720' to 6100' to 6400' to 6750' to 7050' to 7375' to 9215' Rule 3, ?e~issible co~inglin~ A well ~ay be completed in ar.d produced siaultaneously fros anyone or more, or from all or the above seven pools provided that the production fro~ the pools is adequately segregated in the ~ell bore and produced at the sur£ace so that the followi~g requiresents may be Det: (a) Production from XGS Oil Pool A, as defined in Rule 2, -------------. ~ust be segregated in the same well bore from production originating rro~ any other pool. (b) Prod~ction f~ow }~S Oil Pools B, C, and D, as defined in ~ule 2, Qay be co~ingled in the same well bore, but must be segre- gated froo production frc~ any other pool. (c) Production froc HGS Oil Pools E, F, and G, as defined in lule 2, cay be cOI:Dingled in the same vell bore, but must be segre- gated from production from any other pool. Rule 4, Fluid iniection The injection of fluid into any of the pools described in Rule 2, for ~'e purpose of pressure ~aintenance or secondary recovery or of conducti~g injecti- vity tests, is hereby pe~itted, subject to the following require~ents: SCÞ~r.H~EC I' C) ?Onß Î 1 1... ,.." \," , ) ) ( ( CO~iSERVATION ORD~I /144 Pa3e 4 July 19, 1967 (a) Fluid injected into MGS Pool A cust be segregated froe and injected separately in the well bore from fluid injection through the same well iûto any other pool. (b) Fluid to be injected into }1GS Pools B, C, and D, may be co~ingled in the well bore and injected simultaneously into all three pools, but ::1Ust be segregated from and injected separately in the well bore from fluid injection through the same well into any other pool. (c) ?luid to be i~jected into P£S Pools E, F, and G, cay be co~ingled ~n the well bore and injected simultaneously into all three pools, but ~st be segregated from and injected separately in the well bore fro!J. fluid injected through the Sa:J:le well into any other pool. (d) The same well may be used for both injection and producing purposes simultaneously provided that the requirements of Rule 3, and of Rule 4 (a), (b), and (c) above are met, and tàere is an adequate shut-off between that part of the 1;.¡ell used for injection purposes and that part used for ?roduction purposes. --. Rule 5, Lease line well r~e drilling of a well to be completed in the pools defined in Rule 2, at a locaticn as nearly as practic~ble upon the township line be~~een Township 8 North and ìO~JTIshi? 9 North and the boundary line separating Lease Þ~L 17595 fro~ Lease ADL 18754 is hereby ?eIT1itted, upon a showing being ~ade to the Co:Elittee that an appropriate agree~ent therefor has been entered into by all affected parties, including the State of Alaska as lessor. Said well may be cocpleted and produced as an oil well but shall not be considered as one of the two wells attributable to a quarter section for the purposes of Rule I as to either Lease AnL 17595 or Lease ADL 13754. Said well !:lay at any ti~e t~ereafter be converted to injection purposes. The Comôittee shall be n0tificd of the effective date of the change. lule 5, AdL1inistrative approval or changes in pressure maintenance or secondary recovery operations Tne Co~ittee cay upon a showing that the operators of each of the leases, as the representatives of all affected parties, concur in the request thereror and that appropriate and adequate casing, ce~enting, and testing has been, or ~ill be, carried out, aut~orize any of the following operations as an adcinistra- tive Datter and without notice or hearing: ~C;þ~\\~'N'EtJ 0 2 20\)4 .' ' ( ) -( OONSE~VATION ORDER #44 Page 5 July 19, 1967 (a) The conversion to injection purposes or any well initially co~leted either as a producer of oil or as a dry hole. (b) The drilling for injectioa purposes of a well or wells at any location. (c) The conversion from injection purposes to producing stat~s or any well or wells. (å) The drilling of additional wells, i.e. wells not otherwise authorized by these Field Rules, for producing purposes at any location. (e) The cODQingling in the well bore Œ fluid produced by a well froc ~~y pool defined by ~ule 2, with fluid produced by said well from any ocher pool or pools defined by Rule 2. (f) The cOrnflingling in the well bore of fluid injected through a well into any pool as defined by Rule 2 with fluid injected through said well into any other pool or pools as defined by Rule 2. ~ule 7, Casin£ and ceœentin~ reauire8ents Su~face c~sing ~ust be set and ceûented to a depth of at least 1600 feet. Sufficient ce=ent Dust be used to ci~cu12te to the sur:ace. The p~oduction string oust be ce8ented with a sufficient volU2e of cement to extend at least 500 feet above the shoe or a volume to cover the uppenwost pro- ducing zone encountered ia the well, whichever is greater. ~ule 8, Bcttom-hole pressure surveys An annual key well bottom hole press~re survey shall be Dade during the months of January and Febru~ry with the results to be reported to t~e Co~ittee by the end of ~rch eac~ year. The operators in the rield, with approval o~ the Co~ittee, wili dete~ine the datum, the wells to be included, the cetaod to be used and the t)~e or intorillation to be secured.- Bottom hole pressures obtained by a static build-up pressure survey, a 24 hour shut-i~ instantaneous test O~ a I:1uì.tiple flow rate test 'Ç,fill be acceptable for this pu;::-pose. Survey results 'Ç,fill be reported on Fo~ P-l2 or other appropriate means agreed to by the operators and the Coocittee. c- G) I) tj f\( -- .'-f~~. P \\ ~J (.) t:..ìJ w e:.:~ r. t N H t:J,,i ~,u ~- . i;1V, " . '''. ) ) " ( - ( CO~¡SERVATION 01DE3. #44 Page 6 July 19, 1967 Rule 9, Gas-oil ratio tests A gas-oil ratio test of 24 hours duration shall be made on each producing well annually. The test will be made during the months of January and. February and the results will be reported on Form P-9 by the end of March or each year. The requirements of this rule will be waived if monthly reported oil and gas production is based on a gas-oil ratio test made at least every sL~ months by the operator. !T IS FURTIiER 01D~RED that Conservation Orders #26 and #31 are superceded by COï.1servation Order ~f44. T:-1Ís Order is I!lade pursuant to Section 2061.3 of the Alaska Oil and Gas Conservation Regulations and the rules affecting well spacing shall continue in force for a period of not more than eighteen (18) months pro- vided, hm.¡ever, that wells which have been drilled and completed and are being produced in comp~iance with the provisions of this Order, or any other Order of the CoQffiittee, ~ay be produced in ca~liance with the terms or said Order not- withst2nding t~e fact that such Order may have expired or have been terminated, or that there may be ?ending a request that said Order be modified or terwinated, until such ti~e as t~e Co:::mittee shall, after notice and hearing, enter an Order establishing different rules, requireoents, or provisions. The Co~ittee on its o~vn 8otion, or at the request of any interested party, cay at any ti3e during the teopor2ry pe~iad set this matter for further hearing for the purpose of deter- oi:Üng >;.¡hether t:¡e preser1t Order should be ælenàeà or modified. T~e Co:3ilittee ~ill, in the absence o¡ a request of an interested p~rty for a hearing at an earlier date, set tilis Dâ.tter ror hearing Ear a date ,,,hieh s hall be not later than 30 days prior to the ¿ate or the expi~ation or this Order, for the pur?ose of deter3ini~g the proper spacing and field rules which should taen be applicable to t:.-tis field. , p n f¡ 2, LGDr;. SC/\NNEC <. tJ L . ) ( ( CONSE1VATIO~ OlDER #44 Page 7 July 19, 1967 DONE at Anc~orage and Juneau, Alaska, and dated July 19, 1967. vi. Æ 41{~. t . Thoaas ~. Marshall, Jr., Executive Secretary Alaska Oil and Gas Conservation Comcittee ßþ.. Oft ~ ~i[~~ .. :~ "A...... ~~J 1J'.'t1~~~~.';". .,~ 0 ~ ~Ÿt~ . \'.. ' ,- ~\~~~--~¡~Ø?'" ! ~~~.Jj ~..~ -""1'-lON Co~ Concurrence: Williams, Chairman Ala'ka Oil and Gas Conservation CoIIIQittee /;7 ~ .- / . . )/:--; /. . Æ-;:l-~~ Þ::.c.¿¿~.A-9~ Jale ~¡allingto:;" ~'fe::irer ~laska Oil anà Gas Conservation CoWDittee Ki{(:t::1~ Alaska Oil and Gas Conservation Co~ittee \Ü.Ct\\JtÐ !\ \Cð'ð6 ~ \.\ \.. Z m\SS\Qt\ CO~\" ~a.S conS. O'~ &. I;) ~ þ-\as\(a \ ~nc"ora.9 ''''. Î,) 20 D\ P L.j '. U "'r -,,) {.;;;.¡ ') (REV. 1DeA) i~"'.,...u.'.,...,......." : ..\ " ,~n;:'R:-~ .- ".~ '~::."..~~' ~...:,:~:;:.: ..,.r I L.l ~"" Ca.1.12A ~f) OPERATO~ WELL NO, FIELD CQUNTY STATJl ) FIGURE L-l 't,. CHEMICAL & GEOLOGICAL LA80RATORIES ÀAtERICAN STRA TIGRAPH.IC COMPANY ".0. BOX 2127 . ANCHORAGE. "'-AaKA . WATER ANALYSIS REPORT Pan American Petroleum Corp. MGS 11-817595 Middle Ground Shoal Alaska DAT"R August 14, 1970 LOCA TIOR . ME SR ..Sec. 35. PORMATION A Zone INTBRVAI. SAMPLE. PRO:-- LAB NO: A-630-1 T.-8-N, .R-13...W t SM. REMARKS ct CONCLUSIONS~ Sample taken August 6, 1970. ~ti.ons Sodium - - - - - - Po~um ... - . Calclmn - . . Magne:ium . - - . - -Iron . - - e". . - C:;;{f0' ~~ ,,~,~ ~".--, .,~~.....~..:I'.."- .!!:!!! 3382 12 7 4 mtq/l 147..10 . 0.31 0.35 0.33 . -, Total Catioaa: - - - - 148.09 Total di:Iolved ao1i4.. mzJ1 - - - - - NaCl oqwv.ùeG~ me/1 . - - - . - . . O~cd pH ... - . - . 8355 7880 8.3 Na 11 \ I ¡ Ca (-,~"".., Mg I .[ 1, Fe '~:¡. ¡ ,II . ¡ \ ~ II' JU.! L -" -. "' .~.- J.,. '.,.. ~, AnlO118 MK/l 4 3270 396 .2598 .!!!9L! 0~O8 92.21 13.19 42,61 Sulfate - . - - . - Ch1oriciè." .... . - - . Carbonate Bicarbonate Hydro:dde -. - . - . . - . . . . . . . . Total ADIoD8 148.09 . ., . . Specific I'8lIiatuce @ 68°1'.: Obaened -... c.J('""ttd .... 0.838 0.83 WATER ANALYSISPA'Ì'TERN Scale . MEQ per Unit Cl 50 Na . HC03 5 Ca . SO" 5 Mg . C03 5 Fe Sample above described I \ ' \1 '\ ~ -\ t \ ,~ I I 11'1~.'./. ¡ ! ¡ I~' , t I I' I:¡;~ 1 \ I I Cl HC03 ' SO.. CO. (Ha ...'" ÛO'I'8 IT" ladudel N.. x.... LI) NOTE: KlIl=KiUicrama per lit.. JltqJl= KiUl¡nm eqw..Ü8Dt8 per U- IodIwD chloride .c¡\iiva1nt=b7 D\U\1a¡¡Þ a: Hawtho.... caJcuJatIoa ft-: pc-- tit . ' , . ) (REV- IOS.\1 ~.....'...~........~.L: - J" .~.~~. ¡ I..~ ."h ~ ...,.. '..,... ""-"" ~.."'.r~ . '.~ y"'iï ~,"f, \ ~ ~~ CL1..12A (fi;) OPERATO~ WELL NO. FIELD COUNTY STAT'P.: FIGURE L-2 CHEMICAL. & GEOLOGICAL LABORATORIES AMERICAN STRATIGRAPHIC COMPANY ".0. BOX ala? . ANCHORAGE. AL.AalÇA . WATER ANALYSIS REPORT Pan American Petroleum Corp. MGS 11-1 17595 Middle Ground Shoal Alaska DAT1r. August 14, 1970, LAB NO. A-631-2 LOCATION. NE SE See. 35. T-8-N;. R-13-W. SM. FORMATION B. C ~. D . Zone INTKRV AT. SAMPLE PRO'. REMARKS 4:. CONCLUSIONS! . . Sample taken.Au~ust5. 1970. C:\t1ona m~/l 3348 32 13 6 m~/l 145.61 0.95 0.65 0.49 Sodlum .. - - - .. .. Po~um ......- C31cium --_-e. !bgncaium . . . - . Iron .----.- C...;,~ . ., Total Ca1iœa, . . - . 147.70 Total di:solved so1ida, mall ... - . - NaCl oquiva1eat, mall - . - .. . .. . Obcorved pH .... - .. - . . . 8333 7841 8.2 (. " . 1111 Na ,I~d I '! I, Ca I! . I! I I 11 ¡ Jig '\1, d . '\ ! I II ,1\ 11 Fe ¡ \ ¡III, j I ' ¡ - .JW~ Amona Sulfate ~........ Cb10ride .... . Carbonate... - . . Bicarbonate. .. . .. . Hydrozide -...- mgll 18 3210 396 2660 .!!!Sf! O_i'7 90.52 13.19 43.62 Total ADioDa 147.70 \ '\ Cl 50 Na Cl ~) HC03 5 Ca HC03 !~ I~ ,~.J SO.. 5 Mg S04 I \f( I" t n I \ r¡\ C03' 5 Fe CO. ! -, i \ 11 I I . . . . Specific relÍataDCe @ MOll.: ObeerYed ...- t'"C".I_ted ...- 0.848 0.85 obm-.... oJua....... WATER ANALYSIS PATTERN Scale MEQ per Unit Sample above described (Ha _hae' Ia allow crapbs 1adud81 H.. x.... U) NOTE: )I¡/l=UD1i¡rama per liter )(~1= JlW1cram eqw.a1euta I*' Ii- Sodhu:.a cbJorid. ecIulYaJeat::::1Þ7 Dura!8p . H..-tJaOf'110 cabJadoa IrCIIII !: I . ~ t8 . . ':;. , ,:..tf-!:,""'-.:i!:. :0::--'-' SCANNED ~,~:: (, \ Jc. C-.': Ct.1~~~A ('ffJ.ïE.V. 1'i\P~4) r , ,~ ), FIGURE L-3 éiIE1vnf:A l~ &. CEOiJ)CtCAt tABõñA'fœms 1 ì~! ~ ~ }-P"""'":~ a ~~ ' - rfilPn.TER AI\!ALYSIS REPORT IfAra.'íJ.WJ.mf.A~Jj IVIZA fIGf4žAPH Hl: COM'PANY 1".0, 60)( 2.127 'ÁNCK01llA(;Ió:, Al..AtiHU, . O"¡")?:/JJ:.A'TO"filt. - ,.- PQ p i' '"n8..Y'iJ::.D11. J~.t.J:ol?r}11 . .G.DXJ;:Lt.. '\Vr::LL è¡o_~l..l~~:SQ~ (L.) --- (~J~~ rtt iø,t2ì.._2a1 rr~~ DATL-.:ll~ 1 J 96Ci LAB NO 1\-2',)1,....2 LOÇATION' I\fg ~.~'?~~-'~:35,} _!t..B~N~ à"'13f1Íót. BH "!:I>"""'ð.our. IJ.'"I1'>YO'f:.'fI. ~ ,,'" f!t. n (;onz¡on"S:"1"Ðt,;~~ ICV.iCiJ.¡I"iIJLA"',4 ..¡<¡ ~ ;""A, ~.:J!- _J--"r.~ ~.'I".wij",JI., Ir-~ 1.11'!f!!.LD__- COUNTY~ '!f:/r¡~"r~ "-'1 """"-.,,-,,-,,, "....,.,. - -.- -- ,--...., -- - --- INTRRV AL SAKPLE FROM ~9ng E;.:t~DJlg , - - \-..-...". .*"--...,.... -..... .-;- - -.- --- _-is-; ~:t :~}~3 -~ ..-. T'~'lçlr.i:'i v:r~1"",;"~, ~.(U Gb.:t1.y~.rl.Dudy light yelJ0J1 .f4 -¡j~X:éÜ~"._,,-~ -<- :æ!J;,MAP.T:(fJ &: COHCLU$iOiHS' ,-.-'- ,. ...""'... .....~- ~"': ?~ ~':) ~§B',Qi'lri I :lJ'1 j;. r ~~-$ ,...f;5:Ð ]~~çiA ~S.~~J~"J-r~~:~]~2. +10 S...J 1jt:}:; TcUbl di~'Ol"ifl{!d ooUcJ.;',I. m¡¡ll .......... H :¡Cl ~.t¡Uh71s,l~t¡ 1tß:fi,ll .. .., ," ... O~~1.Í pH .. .. .. .. FtP+.~L+-~~:~~~4,~r+.l:i+~r¡~r.;:p:rçr-!}:H~-R:} f....++......ttR+;-"'¡"'.¡~J.""-' -''''''''+'''-'-"''.''T¡-'''r",,-'''''''I-~-4:f-¡~'''''H-i Nal.S..tf~JJJc¡ r,w"nh""'._.""'H'~"W~- '--h." ~!!!f1. ~00j~"n Y?~'t'l::1l..'!J:M:mn Ccldwn ..t/;'ar¡;r¡.;!::¡¡f¡,u.~ :h~ .. .. ... .. - l. .,........ .o"".L v., ","''''.--''- _.D!'-.t:- I!.:"I"I'-~"','-"";""-.-...a.". MMi.;,/!"::/fI.-""-""'.""',_..JfItf'I;:::......'....,. .... !Et:!.l ~ SuU~t~ Cè'Jorld@ Cu-ooWAte Bicm'oo!mte Hydro:ridê .'!E/!!11 2ß ?;1T è;' .. "W.~ ..-:i! jJ, ) ----3[;: .-. .~ 1.1 lr~ M -~''':''._'''-';' ~.JJ. ~) tú!i<) . 8.1, ()~ 1,,20 ~1"ì.i.l '1 '..... ti.-- :i1l!7::J//l ~¡~ . 13),¡ II ß?--- ~ ~ ,~ ~~Q.I!. c~5 "3,1 cn .. ... ----3.CL.- - .. ... ... ---1-- - t~ 1-) ~~, f~ ~.~:t - .. .. .. - '#P._-- - --_... "---',,- ------.... '~.". ~ --- "ro~ Ci4tkm'lt ~...116,d...L- ~l1- W.' .. T~ Jœ;!¡,fJfI:JJ! _IØ ItØ1lolØ",04~_' ",,~.._..:.;.o..._._""'.I'..-...c...;. -; ¿,",""X-I>.. 11" ...-- #'.,-- .~..:..&..1'iiL ..J .-..- '-~._'.- , - ~- .....u.ro..~,.Q--""_f¡II;_. 7heJi h()9k g,,2 S~cific r~W:./;.@ @ 6~01J.: O~~d C6ù"åted o. 92 t;:;'!:J.ïJ:¡,.r:cdmttf1fZGJ, ,fh9..2- ~~ .. IIIN .. ... - VJJ:'8.TEJ::r.. Al.IALYSIS PATTEYit.Ji S~iß MEQ ~t Unit ;~;;1mple ~bOV;2 d¡Z¡i1crlh¡:~d Cl r.J,-, Na ;)v 5 5 ~ Fe .,; HC03 S04 CQ:' (Nit ~i~ }'¡J wÍ;>ar\"" :;ra¡.;hll ¡1i;:~u,j~ N~ x.. uð U) NOTE:: :r..f.!l=Mil1)¡;u.J:¡',!! ;;-""1: ¡'¡t~ ;M;I/<lIl= Jiilil~~m ~1.Ú'Ul*7\ta pel; l1h'4' ill.;!.Hu~ d~r..,~ll ~>dk"¡¡J.¡¡i'¡.;::::Qy Du~ " Na~oreMt ~~ti..nL ftl:Jl:11¡ ~Ut 2 2004 . 4 "',.~,-..-,'_._'.-'_.'--'--' ---.-_.-._--~....~ -.."'.- .....>. -.,. . . - . .''''' '.- ~........ -. .--.-......-,-..-......-....".,-..-........ _..-. . .. -.- _. ..". -'-'" -"-'.~'._..... "'-" -" .... -.,'-" ....-.....,-.-.--.-.--..-.".. '-'~.-....- ') SECTION M Aquifer Exemption 20 AAC 25.402(c)(13) 20 AAC 25.252(c)(11) ) The portion of aquifers beneath Cook Inlet described by a '1/4 mile area beyond and lying directly below the Middle Ground Shoal Field are exempted aquifers for Class II injection. (Reference 40 CfR 147.102(b)(2) and 20 AAC 25.440(c).) JUL 0 2 2004 ) SECTION N HYDROCARBON RECOVERY 20 AAC 25.402(c)(14) ) \ Incremental hydrocarbon recovery from the Middle Ground Shoal Field, Plat- form Baker, resulting from enhanced recovery waterflood operations is 12.4 MMBO. S(;~\NNED ~jUL (1 2 2004 ) ) SECTION 0 MECHANICAL INTEGRITY 20 AAC 25.402(d) and (e) 20 AAC 25.252(d) and (e) In newly drilled Middle Ground Shoal injection wells, the casing is pres- sure tested in accordance with 20 AAC 25.030(g). If a producing well is converted to injection, the casing pressure test will be repeated in ac- cordance with 20 AAC 25.412 (c), prior to injection. Thereafter, casing-tubing annulus pressures will be monitored on a regular basis and reported monthly on Form 10-406 in accordance with 20 AAC 25.402(d). All injection wells will be constructed in compliance with mechanical integrity criteria as set forth in 20 AAC 25.252(d) and 20 AAC 25.402(d). 20 AAC 25.402(e) requires immediate notice to the Commission and correc- tive action if the casing-tubing annulus pressure subjects the casing to a hoop stress that exceeds 70 percent of the minimum yield strength of the casing, or if there is more than 200 psi change in the pressure between consecutive pressure readings. Amoco Production Company requests to use the 70 percent limit as the alarm for immediate notice and corrective action. By using the 70 percent yield pressure limit, the injection wells can be monitored to detect leaks and operated safely. Tubing pressure changes and temperature effects during various workover, logging, or testing operations often yield casing-tubing annulus pressure changes greatly exceeding 200 psi. These operations are necessary and occur often during prudent operations. In addition, the annular pressure is sensitive to injection pressures and fluid temperature. Thermal effects and injection rate variation will be a significant controlling factor for casing pressure on water and waste disposal wells. SCANNED JUL €I 2 20Ci! ) ) SECTION P WELLS WITHIN AREA 20 AAC 25.402(h) 20 AAC 25.252(h) The wells within the Middle Ground Shoal Field, Platform Baker are shown on Figure B. To the best of Amoco Production Company's knowledge, the wells within the area were constructed, and where applicable, abandoned to prevent the movement of fluids into freshwater sources. JUl t[J 2 20D4 ) ) SECTION Q GAS-OIL RATIOS 20 AAC 25.240 (b) & (c)(l) If this application for an Area Injection Order is approved, then a waiver is requested for 20 AAC 25.240(b) requiring no oil well to exceed 100 percent of the original solution gas-oil ratio. The requirement for an oil well to produce at below 100 percent of the original solution gas-oil ratio will not be necessary in accordance .wtih 25.240(c)(1) because the pool will have an approved additional recovery project in operation. SCANNED JUl 0 2 2004 EXHIBIT 1 STATE OF ALASKA DEP.~~TME~~ OF NATURAL RESOURCES DIVISION OF MI¡æS AND ~lIlœ?J.~S Alaska Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska ?-.E: THE APPLICÞ..TION OF THZ SHELL OIL COMPANY) A~1) THE P Þ1i ~1ERIC.~N PETIOLEID1 CORPORATION, ) covering t~e deve¡opment or a prescribed area) of the Middle Ground Shoal Field for an except- ) ion to Section 2061.1 of the Alaska Oil and Gas) Conservation Regulations and requesting auth- ) orization to initiate, expand and continue ) pressure maintenance or secondary recovery ) operations purusant to the authority granted) by Section 31.05.030 of the Alaska Statutes) Conservation Order #44 July 19, 1967 IT Þ2PE~~ING TIL\T: 1. The Shell Oil Coopany and the P~n Þnerican ~etroleUQ Cor?oration submitted a petition dated June 9, 1967, requesting the referenced excep tions' and authoriza- tions. \ I 2. Notice of the hearing was published in the Anchorage Daily News.on July 3, 1967. Because of a t~"'pographica1 error in the original publication 'the no.t:i.ce of hearing ~was repub lished July 8, 1967. \ i . \ f 3. A ~aiver of personal service was received from each or the affected p~rties. , I 4. A public hearing ~as held in the City Council Ch~bers or t~e z. J. Lþussac Library on July 19, 1967. Testi=ony in support of the petition was presepted by Pan l~~erican Petrole~ Corporation and Shell Oil Cowpany. ' .~m IT F~THEl APPE.~~ING that reservoir data presented at the hearing is adequate t~ detercine that an exception to the acreage spacing requireme~ts of Section 2061.1 or the Alaska Oil and Gas Conservation ~egulations is necessary for the affected area hereinafter described. 0 2; 20DLJ. I '" I ) \. CONSE1VATION ORDE1 #44 Page 2 July 19, 1967 la'ID IT FU1THER APPEARING that the data on the reservoir performance as shown at the hearing indicates that tests to determine the feasibility of pressure main- tena~ce or secondary recovery operations by fluid injection should be ~nitiated and :hat Field lules authorizing such testing ~~d initiation of pressúre mainten- ance or secondary recovery operations and a continuation and expansion of such operations if proven feasible should be adopted. AND IT FURTHER. Þ..P?~~ING that certain changes should be made to enlarge the affected area and :Jodify rules listed in Conservation 'Jrder ii31. Þ~D IT FURTdER APP~}l~ING that pool rules establishing requirements for bottom hole prassuresurveys, gas-oil ratio surveys, and minÍJ:lUm casing and cementing require- ~ents should be adopted for the affected area. NOW, THEREFORE, IT IS ORDE~D that the area described as follows is affected by this order: T3N-113W, S. H. Section 1: Sect ion 2: Section 11: Section 12: Section 13: Section 14: All "2/2 S'\I/4, E/2 S \J / 4 , N /2 W/2 All Section 22: Section 23: Section 24: Section 25: Section 26: Section 27: S£/4 All W/2 ~{/2 All E/2 T9N-~12~'¡, S. M. Section 19: 5/2 Section 30: All Section 31: All T9N-113~'¡, S. M. Section 25: E/2 Section 36: E/2 The following special rules apply to the aforementioned area: 1ule 1, Spacing patt~rn (a) Oil wells ~ay be co~leted closer than 500 feet to the section lines or quarter secticn lines and Qay be completed closer than 1000 feet to any well drilling to or capable of producing from the sace pool, except that no oil well shall be co~leted at a distance of less than 500 feet from a lease li~e where ownership changes. tr Ph\. í eN''''' ~'- 8V$~r~ ~~JEU t':;'j 20. D ,.~ ¿'\";~ ,,",' d~''':1 ) ) \ CONSR..~VATION ORDER :{f44 Page 3 July 19, 1967 (b) ~~o more than two oil comp letions shall be allowed in any governmental quarter section or governmental lot corresponding thereto in any pool as designated in Rule 2. Rule 2, Pool designation The vertical producing intervals shall be divided into seven (7) pools which will be correlated with the following intervals in the Pan American Petroleum Corporation State 17595 114 well. HGS Oil Pool A 5300' MGS Oil Pool B - 5720' ~GS Oil Pool C - 6100' MGS Oil Pool D - 6400' MGS Oil Pool E - 6750' MGS Oil Pool F - 7050' HGS Oil Pool G - 7375' to 5720' to 6100' to 6400' to 6750' to 7050' to 7375' to 9215' Rule 3, Pe~issible cOQffiingling A well ~ay be completed in and produced simultaneously from anyone or more, or from all or the above seven pools provided that the production fro~ the pools is adequately segregated in the ~¡ell bore and produced at the surface so that the followi~g requireQents may be met: "- (a) Production from XGS Oil Pool A, as defined in Rule 2, ---------~---- ~ust be segregated in the same well bore from production originating frc~ any other pool. (b) Production frow }fGS Oil Pools B, C, and D, as defined in Rule 2, may be co~ingled in the same well bore, but must be segre- gated frem production from any ether pool. (c) Production rrom ~fGS Oil Pools E, F, and G, as defined in :{u1e 2, may be cODClingled in the same well bore, but must be segre- gated fro~ production from any other pool. Rule 4, Fluid iniection The injection of fluid into any of the pools described in Rule 2, for ~~e purpose of pressure ~aintenance or secondary recovery or or conducting injecti- vity tests, is hereby pe~itted, subject to the following require~ents: {) :2 2ÛUL1 . . '.. ) \ CONSERVATION OR.D:::l /144 Page 4 July 19, 1967 (a) Fluid injected into MGS Pool A must be segregated from and injected separately in the well bore from fluid injection through the same well into any other pool. (b) Fluid to be injected into HGS Pools B, C, and D, may be comcingled in the well bore and injected simultaneously into all three pools, but ::lUst be segregated from and injected separately in the well bore from fluid injection through the same well into any other pool. (c) Fluid to be i~jected into P~S Pools E, F, and G, may be conningled in the well bore and injected simultaneously into all three pools, but :lUst be segregated from and injected separately in the well bore fro~ fluid injected through the s~e well into any other pool. (d) The same well may be used for both injection and producing purposes simultaneously provided that the requirements of Rule 3, and of Rule 4 (a), (b), and (c) above are met, and tàere is an adequate shut-off between that part of the well used for injection purposes and that part used for production purposes. -.....-. . Rule 5, Lease line well The drilling or a well to be completed in the pools derined in Rule 2, at a location as nearly as practic~ble upon the township line be~~een Township 8 North and TO\Ÿ&1ship 9 North and the boundary line separating Lease ~~L 17595 fro~ Lease )~L 18754 is hereby permitted, upon a showing being made to the Co~ittee that an appropriate agree~ent thereror has been entered into by all affected parties, including the State of Alaska as lessor. Said well may be completed and produced as an oil well but shall not be considered as one of the two wells attributable to a quarter section for the purposes of Rule 1 as to either Lease AnL 17595 or Lease ADL 18754. Said well may at any ti=e thereafter be converted to injection purposes. The Comnittee shall be natified of the effective date of the change. lule 6, Administrative approval or changes in pressure maintenance or secondary recovery operations Tne Cocmittee cay upon a showing that the operators of each of the leases, as the representatives of all affected parties, concur in the request therefor and that appropriate and adequate casing, cementing, and testing has been, o~ ~ill be, carried out, authorize any of the following operations as an adcinistra- tive Datter and without notice or hearing: .HJ"~.. 0 ~~ 2rr, ~H t L K .- ,~ ".... , " .' ') \ CONSE~VATION ORDER #44 Page 5 July 19, 1967 (a) The conversion to injection purposes of any well initially comp leted either as a producer of oil or as a dry hole. (b) The drilling for injection purposes of a well or wells at any location. (c) The conversion from injection purposes to pr9ducing stat~s or any well or wells. (d) The drillin3 of additional wells, i.e. wells not otherwise authorized by these Field Rules, for producing purposes at any location. (e) The comcingling in the well bore Œ fluid produced by a well fro~ ~âY pool defined by ~ule 2, with fluid produced by said well from any other pool or pools defined by Rule 2. (f) The cotnI!lingling in the well bore of fluid injected through a well into any pool as defined by Rule 2 with fluid injected through said well into any other pool or pools as defined by Rule 2. 1ule 7, Casin2: and cementing require~ents Surface casing must be set and cenented to a depth or at least lóOO feet. Sufficient ce=ent must be used to circulate to the surface. The p~oduction string must be cenented with a sufficient vol~e of cement to extend at least 500 feet above the shoe or a volume to cover the uppercost pro- ducing zone encountered in the well, whichever is greater. ~ule 3, Bcttom.hole pressure surveys An annual key well bottom hole pressure survey shall be wade during the months of January and February ~Jith the results to be reported to the Co~ittee by the end of ~rch each year. The operators in the field, with approval oz the Cowoittee, will dete~ine the datum, the wells to be included, the cethod to be used and the t}~e or inforillation to be secured. Bottom hole pressures obtained by a static build-up pressure survey, a 24 hour shut-i~ instantaneous test or a I:lUltiple flow rate test will be acceptable for this purpose. Survey results will be reported on Form P-12 or other appropriate means agreed to by the operators and the Coarnittee. "rt~'~w\L':'f"" HU~ {~«1; SGJ'"'Ìe~I,~~L"""~.I Ì- \} k . . c '. . ',. t , ) ) \ CO~¡SERVATION 01DE3. #44 Page 6 July 19, 1967 Rule 9, Gas-oil ratio tests A gas-oil ratio test of 24 hours duration shall be made on each producing well annually. The test will be made during the months of January and. February and the results will be reported on Form P-9 by the end of March of each year. The requirements of this rule will be waived if monthly reported oil and gas production is based on a gas-oil ratio test made at least every six months by the operator. IT IS FURTIiER 01DERED that Conservation Orders #26 and #31 are superceded by Conservation Order #44. Lìis Order is made pursuant to Section 2061.3 of the Alaska Oil and Gas Conservation Regulations and the rules affecting well spacing shall continue in force for a period of not more than eighteen (18) months pro- vided, however, that wells which have been drilled and completed and are being produced in comp~iance with the provisions of this Order, or any other Order of the Committee, nay be produced in co~liance with the terms of said Order not- withstanding the ract that such Order may have expired or have been terminated, or that there may be ?ending a request that said Order be modified or terminated, until such ti;:¡e as the Co:!!mittee shall, after notice and hearing, enter an Order establishing different rules, requirements, or provisions. The Co~ittee on its o~vn motion, or at the request or any interested party, cay at any tioe during the teopor::.ry period set this matter for further hearing for the purpose 0 E deter- mi:ling \.¡hether the present Order should be a!:lended or modified. T~;e Co~ittee will, in the absence oE a request of an interested party for a hearing at a~ earlier date, set this aatter for hearing Ear a date '\.¡hich s hall be not later than 30 days prior to the date of the expiration of this Order, for the pur?ose oz determining the proper spacing and field rules which should then be applicable to this field. ") .f'!, 'lJ'ì .~ .::, J ~ .'- . , ' .> t' ) J \ CONSE1VATIO~ OWER 1144 Page 7 July 19, 1967 DONE at ..-mchorage and Juneau, Alaska, and dated July 19, 1967. t/!.!( I/{¡~.t, Thomas R. Marshall, Jr., Executive Secretary Alaska Oil and Gas Conservation Committee Concurrence: ~~ Williams, Chairman A1a~ka Oil and Gas Conservation Committee . /l ~¿/l -/ /Liu~ ¿//::'C-- ~c-9/~ Jale \lallingto:l, Ne.....-ili-er Alaska Oil and Gas Conservation Cowcittee dfí:¿~~ Alaska Oil and Gas Conservation Co~ittee SCANNED 2004