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Home My WebLink AboutDIO 015Imag`~ Project Order File Cover f~'~ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspecti~opn~--o~f the file. ~--e ® ~ IJ Order File Identifier Orgafl%z%ng (done) RESCAN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: „~.,d~, uuimiim;,iuu DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type: „~,~~eea~ iuui!iiiiuiiiii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ ~~ j /s/ Projecf Proofing III I III IIIII II III BY: Maria Date: ~ j ~ ~ /s/ Scanning Preparation x 30 = + =TOTAL PAGES ,..... (Count does not include cover sheet) BY: Mari Date: ~ ®~ /s/ __ ~, Production Scanning III II III IIIII II III ___- Stage 1 Page Count from Scanned File: ~ (count does include cove heet) Page Count Matches Number in Scannin Pre aration: t/ YES NO BY: /I aria Date: Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II IIII III II I I III ReScanned II ~ II II I I I I III I I II I BY: Maria Date: /s/ Comments about this file: o~a ~,~~e~~ea mimmiuiiui 10/6!2005 Orders File Cover Page.doc • i DISPOSAL INJECTION ORDER #15 SPARK PLATFORM WELL S-5 L June 12, 1998 2. --------------- 3. May 26, 1998 4. June 9, 1998 5. June 26, 1998 6. June 23, 2003 7. September 27, 2004 8. --------------------- 9. August 19, 2009 Notice of Hearing, Affidavit of Publication and Bulk Mailing Address MIT Test Individual Well Production Marathon's Application for AO Spark Platform S-5 Marathon's documentation of inechanical integrity test performed on Well S-5 UIC File Review Proposals to Amend Underground Injection Orders to Incorporate Consistent Language Addressing the Mechanical Integrity of Wells Annual Report of Disposal Injection Operations Marathons request to dispose of Class II fluids utilizing North Trading Bay Unit S-OS without passing a MIT-I1 or MIT-T Disposal Injection Order #15 ~: STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: THE APPLICATION OF ) Disposal Injection Order No. 15 MARATHON OIL COMPANY ) ("Marathon") for an order allowing the ) North Trading Bay Unit S-5 well underground disposal of Class II fluids in ) North Trading Bay Unit the North Trading Bay Unit S-5 well. ) August 31, 1998 IT APPEARING THAT: By letter dated June 9, 1998, Marathon requested authorization from the Alaska Oil and Gas Conservation Commission to dispose of Class II oil field waste fluids by underground injection into the North Trading Bay Unit S-5 well, located on the Spark Platform. 2. The Commission published notice of an opportunity for public hearing in the Anchorage Daily News on June 12, 1998. 3. The Commission did not receive protest or a request for a public hearing. FINDINGS: 1. Marathon is the operator of the North Trading Bay Unit ("NTBU"). There are no other operators within aone-quarter mile radius of the proposed disposal injection project. The State of Alaska is the surface owner. 2. Marathon and Unocal are the only working interest owners within the NTBU. 3.. The U. S. Environmental Protection Agency has exempted portions of aquifers beneath the Cook Inlet described by aone-quarter mile area beyond and lying directly below the Trading Bay Field. C.F.R. § 147.102(b)(2)(iv). 4. The NTBU is within the geographical area known as the Trading Bay Field. 5. Fluids proposed for disposal will consist of Class II oil field waste fluids associated with the production of natural gas from the NTBU, and primarily will be produced water and associated natural gas condensate from the NTBU S-2rd well. The NTBU S-2rd well is currently producing less than 200 barrels of water per day. 6. The NTBU S-5 well was originally drilled as a Hemlock and "G" oil producer in 1969. The well was converted to a waterflood injector in 1974. Over 13 million barrels of water were injected into the well between December 1974 and March 1981. 7. Marathon suspended NTBU Hemlock and "G" zone oil production in 1992. At the time of shut in, the cumulative oil recovery exceeded 40% of the original oil Disposal Injection Orde'~'o. `"~°' '~~ Page 2 North Trading Bay Unit S-5 well August 31, 1998 in place. Combined with the high water cut of wells, Marathon concluded that the Hemlock and "G" zones had been fully swept and no longer had economic potential. 8. The Hemlock and "G" zones in the NTBU are common to and correlate with the 10,070' - 10,635' measured depth ("MD") interval in the Texaco-Superior TS No. 1 well as defined by Conservation Order 69. 9. The proposed waste disposal will occur in the depleted Hemlock and "G" zones through existing perforations located between 10,826'-11,397` MD in the NTBU S-5 well. 10. The depleted Hemlock and "G" zones are separated from the overlying gas productive sands of the "basal F" and "upper G" formations by an aggregate thickness of over 200' of shale and coal seams. 11. The NTBU S-2rd well was recompleted in 1996 to develop gas reserves from the "basal F" and "upper G" formations. 12. Produced water from the NTBU S-2rd well is currently being disposed of down the annulus of the NTBU S-4 well under the authority of Disposal Injection Order #13, however, produced water rates continue to increase and injection pressures are approaching the pressure limitations of the S-4 well. 13. The requested maximum injection rate for the NTBU S-5 well is 1000 barrels of fluid per day. The anticipated maximum and average surface injection pressures are 3000 psi and 1000 psi, respectively. 14. Model studies indicate that fracture growth out of the proposed disposal zone will not occur under the estimated injection pressures and rates. 15. The NTBU S-5 well was constructed with 13 3/8", 61 lb./ft, K-55 surface casing set at 2,245' MD and cemented to surface, and 9 5/8", 47 lb./ft BTC, N-80 and P- 110 production casing set at 11, 527' MD and cemented to 7998' MD (calculated). The well is equipped with tubing and packer. 16. The NTBU S-5 well passed a mechanical integrity test of the casing-tubing annulus on June 12, 1998. CONCLUSIONS: The requirements of 20 AAC 25.252 for authorization to dispose of Class II fluids in the NTBU S-5 well have been met. 2. Waste fluids authorized for disposal under this order will consist exclusively of Class II wastes generated from the production of natural gas from the NTBU. 3. Movement of waste fluids will be confined within appropriate receiving intervals by confining lithology, cement isolation of the perforated intervals, and operating parameters. Disposal Injection Order~'o. ~"`' ``-~ Page 3 North Trading Bay Unit S-5 well August 31, 1998 4. Monitoring of disposal rates and pressures will help ensure fluids are contained within the disposal interval. Abnormalities in operating conditions may be an indication that fluid is escaping beyond the authorized disposal interval. 5. Disposal injection into the NTBU S-5 well will not occur into, through, or above a non-exempt freshwater aquifer, and will not result in an increased risk of movement of fluids into a freshwater saurce. 6. The mechanical integrity of this well has been demonstrated in accordance with 20 AAC 25.412. 7. Disposal injection operations in the NTBU S-5 well will not cause waste nor jeopardize correlative rights, and will result in greater ultimate recovery from the NTBU. NOW, THEREFORE, IT IS ORDERED THAT: Rule 1 Authorized Iniection Strata for Disposal Class II oil field fluids may be injected into the NTBU S-5 well in conformance with 20 AAC 25 for the purpose of disposal into strata that is common to and correlates with the 10,070' - 10,635' MD interval in the Texaco-Superior TS No. 1 well. Rule 2 Demonstration of Tubin Casing Annulus Mechanical Integrity The tubing/casing annulus must be tested for mechanical integrity in accordance with 20 AAC 25.412 prior to initiating injection and at least once every four years. A test surface pressure of 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 minimum yield strength of the casing is to be used. The test pressure must show stabilizing pressure and a decline of less than 10% in athirty-minute period. The Commission must be notified at least twenty-four (24) hours in advance to enable a representative to witness pressure tests. Rule 3 Well Integrity Failure Whenever disposal rates and/or operating pressure observations or pressure tests indicate pressure communication or leakage of any casing, tubing or packer, the operator must notify the Commission on the first working day following the observation, obtain Commission approval of a plan for corrective action and obtain Commission approval to continue injection. Rule 4 Operational Criteria Maximum disposal rates shall not exceed 1000 bbls/day. Maximum surface disposal pressure shall not exceed 3000 psi. Disposal Injection Order'°ivo.:~~ `°'°'~ ` Page 4 North Trading Bay Unit S-5 well August 31, 1998 Surveillance Operating parameters including disposal rate, disposal pressure, annulus pressure and fluid volume must be monitored and reported according to the requirements of 20 AAC 25.432. An annual report evaluating the performance of the disposal operation must be submitted on or about July 1 of each year. Administrative Action Upon request, the Commission may administratively revise and reissue this order upon proper showing that any changes are based on sound engineering practices and will not allow waste fluids to escape from the disposal zone. DONE at Anchorage, Alaska and dated August 31, 1998. ~~~ ~ ~~~h ~~ E~'3 ~ `~~1P~-_ ~~~ n'a y ~~ '^ ~ ,` 33 ~' 9 '~ ~n'8. W.1 gym' ~`~~ ~n } ~' Jf~l~ ~~~~~ ~d~~~~ David W~Johnston, Robert Commissioner ~ ~ lf~..~E~4iV.1-Cn. Camille Oechsli, Commissioner ___ AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission au application for rehearing. A request for rehearing must be received by 4:30 PM on the 23rd day following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the 10-day period. A,i affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30-day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e. 10th day after the application for rehearing was filed). • ~ a a ~ ~ SEAN PARNELL, GOVERNOR 0 ~-7~~ ~I~ ~D Vrn47 333 W. 7th AVENUE, SUITE 100 COI~TSERQATIOI~T COrIl-IISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL NO. DIO 15.001 Ms. Tiffany Stebbins Regulatory Compliance Representative Marathon Alaska Production, LLC P.O. Box 196168 Anchorage, AK 99519-6168 Re: The application from Marathon Alaska Production, LLC to authorize disposal of Class II fluids utilizing North Trading Bay Unit (NTBU) S-OS without a passing MIT-IA or MIT-T. Dear Ms. Stebbins: Marathon Alaska Production, LLC (Marathon) requested by letter dated August 19, 2009 approval to inject Class II fluids into NTBU well S-OS in support of the ongoing P& A activities associated with dismantling the Spark Platform. S-OS recently failed MIT's on both tubing and inner annulus but follow- up diagnostic testing indicates injected fluid is being contained in the desired strata. Marathon's request to inject Class II fluids as described in the~application is GRANTED. In the application Marathon describes the sequence of events and pressure testing history of well NTBU S-OS as follows: 5/12/09: Initial baseline temperature pass was run. 6/25/09: The initial testing on June 25, 2009 where a WRP (retrievable plug) was set at 10800' just above the top packer in the tubing. The well failed the MIT-T and the IA pressured up to the same pressure as the tubing (the OA did not see any pressure response). 6/26/09: On June 26, 2009 the CMIT pressure left on the well overnight had slowly bled to 0 psi. This indicated a tubing leak as well as a possible 9 5/8" leak or a packer leak. 6/27/09: Pertnission was granted to use alternate NTBU S-04 for disposal of Class II wastes. 7/27/09: After about 1000 bbls of fluid were pumped into S-04 it locked up. Re-perforating the injection zones in S-04 did little to improve injectivity. Marathon requested use of S-OS for disposal. 8/13/09: Performed a temperature/pressure survey after pumping 200 bbls of cold fluid down well NTBU S-O5. The temperature overlay with the baseline log done on 5/12/09 indicates fluid is being injected below the upper packer at 10796' md. There is a major cooling temperature shift seen at the top of the upper packer. No indication of fluid moving upward from the top packer or out of the target intervals is evident. 8/17/09: A charted 15 minute passing pressure test of the OA was done on NTBU S-O5. In summary, Marathon supplies sufficient evidence to justify a short term period of injection into NTBU S-O5. The anticipated minor amount of waste fluid (approx. 2000 bbls) is additional argument to justify DIO 15.001 ~ • Page 2 of 2 August 21, 2009 injection into the onsite DIO well instead of mare costly and potentially hazardous shipping of waste fluids to an onshore site for disposal. The Commission agrees with Marathon's assessment that there is no reason to believe injecting the requested fluids will result in fluid movement out of zone. The Commission further finds that injecting the subject fluids will not promote waste or jeopardize correlative rights, and will not contribute to the potential for fluid movement outside of the authorized injection zone. The following stipulations will apply to this Administrative Approval (DIO 15.001) 1) There must be continuous manning of the well during injection. Tubing, IA and OA pressures to be recorded every 30 minutes. 2) If any indications of OA pressure or communication are seen, immediate shut-down of operations and notification of AOGCC must occur. 3) A weekly summary of injection to include TIO plot, volume pressure plot, total volume injected and any anomalous conditions or pressure bleeds. 4) Fluids permitted under this AA are restricted to associated P& A activities on the Spark platform anr) are limiterl tn a tntal vnlnmA nf 75M hhlc DONE at Anchorage, Alaska and dated August 21, 2009. Daniel T. Seamount, Jr. Chair RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this arder 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 afrer 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." Cat y P. oers er \ Com ssioner 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 Cindi Walker XTO Energy, Inc. IHS Energy Group Tesoro Refining and Marketing Co. Cartography GEPS Supply & Distribution 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 300 Concord Plaza Drive Ft. Worth, TX 76102-6298 Houston, TX 77056 San Antonio, TX 78216 George Vaught, Jr. Jerry Hodgden Richard Neahring PO Box 13557 Hodgden Oil Company NRG Associates Denver, GO 80201-3557 408 18th Street President Golden, CO 80401-2433 PO Box 1655 Colorado Springs, CO 80901 Mark Wedman Schlumberger Ciri Halliburton Drilling and Measurements Land Department 6900 Arctic Bivd. 2525 Gambell Street #400 PO Box 93330 Anchorage, AK 99502 Anchorage, AK 99503 Anchorage, AK 99503 Baker Oil Tools Ivan Gillian Jill Schneider 4730 Business Park Blvd., #44 9649 Musket Bell Cr.#5 US Geological Survey Anchorage, AK 99503 Anchorage, AK 99507 4200 University Dr. Anchorage, AK 99508 Gordon Severson Jack Hakkila Darvuin Waldsmith 3201 Westmar Cr. PO Box 190083 PO Box 39309 Anchorage, AK 99508-4336 Anchorage, AK 99519 Ninilchick, AK 99639 James Gibbs Kenai National Wildlife Refuge Penny Vadla PO Box 1597 Refuge Manager 399 West Riverview Avenue Soldotna, AK 99669 PO Box 2139 Soldotna, AK 99669-7714 Soldotna, AK 99669-2139 Richard Wagner Cliff Burglin Bernie Karl PO Box 60868 PO Box 70131 K&K Recycling Inc. Fairbanks, AK 99706 Fairbanks, AK 99707 PO Box 58055 Fairbanks, AK 99711 North Slope Borough PO Box 69 Barrow, AK 99723 r ~ a~ ~~ ~~/ o ~ ~ • Page 1 of 1 Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Friday, August 21, 2009 1:31 PM Subject: DI015-009 Attachments: dio15-001.pdf BCC:'Aaron Gluzman'; caunderwood@marathonoil.com; 'Dale Hoffman'; Fridiric Grenier; 'Gary Orr'; Jerome Eggemeyer; 'Joe Longo'; 'Lamont Frazer'; Marc Kuck; 'Mary Aschoff ; Maurizio Grandi; P Bates; Richard Garrard; 'Sandra Lemke'; 'Scott Nash'; 'Steve Virant'; 'Wayne Wooster'; 'Willem Vollenbrock'; 'William Van Dyke'; Woolf, Wendy C(DNR); 'Anna Raff ;'Barbara F Fullmer'; 'bbritch'; 'Bill Walker'; 'Brad McKim'; 'Brandon Gagnon'; 'Brian Gillespie'; Brian Havelock'; 'Brit Lively'; 'Bruce Webb'; 'buonoje'; 'Cammy Taylor'; 'Cande.Brandow'; 'carol smyth'; 'Charles O'Donnell'; Chris Gay; 'Cliff Posey'; 'Dan Bross'; 'dapa'; 'Daryl J. Kleppin'; 'David Brown'; 'David Gorney'; David House; 'David L Boelens'; 'David Steingreaber'; 'ddonkel'; Deborah Jones; Decker, Paul L(DNR); 'doug_schultze'; 'Eric Lidji '; 'Evan Harness'; 'eyancy'; 'foms2@mtaonline.net'; 'Francis S. Sommer'; 'Fred Steece'; 'Garland Robinson'; 'Gary Laughlin'; 'Gary Rogers'; 'Gary Schultz'; 'ghammons'; 'Gordon Pospisil'; 'Gregg Nady'; 'gspfoff; 'Hank Alford'; 'Harry Engel'; 'jah'; 'Janet D. Platt'; 'jejones'; 'Jerry Brady'; 'Jerry McCutcheon'; 'Jim Arlington'; 'Jim White'; 'Jim Winegarner'; 'Joe Nicks'; 'John Garing'; 'John S. Haworth'; 'John Spain'; 'John Tower'; 'John W Katz'; 'Jon Goltz'; Joseph Darrigo; 'Julie Houle'; 'Kari Moriarty'; 'Kaynell Zeman'; 'Keith Wiles'; knelson@petroleumnews.com; 'Krissell Crandall'; 'Kristin Elowe'; 'Laura Silliphant'; 'mail=akpratts@acsalaska.net'; 'mail=foms@mtaonline.net'; 'Marilyn Crockett'; 'Mark Dalton'; 'Mark Hanley'; 'Mark Kovac'; 'Mark P. Worcester'; 'Marquerite kremer'; Melanie Brown; 'Michael Nelson'; 'Mike Bill'; 'Mike Jacobs'; 'Mike Mason'; 'Mikel Schultz'; 'Mindy Lewis'; 'MJ Loveland'; 'mjnelson'; 'mkm7200'; 'Nick W. Glover'; NSK Problem Well Supv; NSU, ADW Well Integrity Engineer; 'Patty Alfaro'; 'Paul Winslow'; Rader, Matthew W(DNR); Raj Nanvaan; 'Randall Kanady'; 'Randy L. Skillern'; 'Rob McWhorter '; rob.g.dragnich@exxonmobil.com; 'Robert Campbell'; 'Robert Province'; 'Rudy Brueggeman'; 'Sandra Pierce'; 'Scott Cranswick'; 'Shannon Donnelly'; 'Sharmaine Copeland'; Slemons, Jonne; 'Sondra Stewman'; 'Sonja Frankllin'; 'Stan Porhola'; 'stanekj'; 'Steve Lambert'; 'Steve Moothart'; 'Steven R. Rossberg'; 'tablerk'; 'Tamera Sheffield'; 'Temple Davidson'; Teresa Imm; 'Terrie Hubble'; Thompson, Nan G(DNR); 'Tim Lawlor'; 'Todd Durkee ; Tony Hopfinger; 'trmjrl'; 'Walter Featherly'; Walter Quay; Aubert, Winton G(DOA); Birnbaum, Alan J (LAW); Crisp, John H(DOA); Darlene Ramirez; Davies, Stephen F(DOA); Fleckenstein, Robert J(DOA); Foerster, Catherine P(DOA); Grimaldi, Louis R(DOA); Johnson, Elaine M(DOA); Jones, Jeffery B(DOA); Laasch, Linda K (DOA); Mahnken, Christine R(DOA); Maunder, Thomas E(DOA); McIver, Bren (DOA); McMains, Stephen E (DOA); Noble, Robert C(DOA); Norman, John K(DOA); Okland, Howard D(DOA); Paladijczuk, Tracie L(DOA); Pasqual, Maria (DOA); Regg, James B(DOA); Roby, David S(DOA); Saltmarsh, Arthur C(DOA); Scheve, Charles M(DOA); Schwartz, Guy L(DOA); Seamount, Dan T(DOA) Attachments: dio 15-00 l .pdf; Jody J. Colombie Special Assistant ,Alaska Dil and Gas Conservation Comrnission 333 West 7th Avenue, Suite 100 Ancho~•a~e, ,4K y9501 (907)793-1221 (phone) (907)27b-7542 (fcrx) 8/21 /2009 ~ ~ ~ Marathon MApM ~ Alaska Production LLC Alaska Ass~f Team P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/565-3076 August 19, 2009 Mr. Guy Schwartz Alaska Oil and Gas Conservation Commission 333 West 7`" Ave, Suite 100 Anchorage, AK 99501 j ~-`~° ~°~'~~~~"~ "~ ~ ~.,_ ~. ~,.: Re: Disposal Injection Order No. 15 North Trading Bay Unit Spark Platform Well No. S-5 Dear Mr. Schwartz: ~ .~~~~3,a~,za~~~ Marathon Alaska Production, LLC (Marathon) would like administrative approval to begin disposal of Class II fluids down Spark well no. S-5. S-5 is currently authorized for disposal under Disposal Injection Order No. 15, but the well failed an MIT on 6/25/09. Diagnostics were run on S-5 June 25-26 and discussed with AOGCC. Summary is as follows: • On June 25, 2009 the well S-05 (DIO #15) had a WRP set at 10,800', well was filled with fluid and both the tubing string and IA were pressured up to 1650 psi. The OA gauge was at 0. During the pressuring up of the tubing and IA the OA pressure remained static. Throughout the entire process, 13-3/8" outer annulus pressure remained unaffected. • On June 26, 2009 personnel reported both the tubing and IA had bled down to 0 psi. After further diagnostics, it was determined there is communication between the 3-1/2" tubing and 9-5/8" casing and possibly a packer leak. • Shared results with AOGCC on June 26. It was our understanding that we could not use S-05 until further diagnostics have been performed. It was also our understanding we were permitted to use the S-4 but after approximately 200 bbls had been injected; we were required to run a PT survey. Results of the survey were good and permission was granted to continue using S-4. After approximately 948 bbls injected into S-4 the perfs plugged up. We requested approval to reperf G2 zone from 4594-4624' and 4654-4684'. We had no success with the reperf. The well would no longer take fluids. On 8/11/09 we requested AOGCC approval to use S-5. Approval was granted on 8/12/09 to run a PT survey on S-5 after pumping 200 bbls of cold fresh water down the tubing. A PT survey was completed 8/13/09. Ken Walsh, Sr. Production Engineer for Marathon, has reviewed the data and plot overlay of the static pressure-temperature surveys recorded 5/12/09 and 8/13/09, and has interpreted them as follows: "The survey on 5/12/09 was taken after a long shut in period. The survey taken on 8/13/09 was recorded shortly after pumping 200 bbls of cold water down the tubing. The character and trend of the two pressure and temperature surveys track each other very well with the exception of the temperature signature that shows a sharp cooling trend from about 10,500' # !- Marathon Alaska Production, LLC Disposal Injection Order No. i5 North Trading Bay Unit no. S-5 to the tag depth of 10,776' MD. It is interesting to note that there is a gas lift mandrel placed at 10,502' MD. It would be incorrect to assert that the fluid pumped on 8/13/09 exited this mandrel as there is no indication of the expected temperature profile bend back to normal gradient above this mandrel. Therefore, it is my interpretation that al! of the injected water exited into the perforated intervals below the packer located at 10,796' MD. This is consistent with the cooling trend exhibited at the bottom of the log." With casing integrity verified, injection fluids entering into the perforated zones, and no upward migration of fluids behind cement, Marathon would like administrative approval to begin disposing of Class II fluids under the following guidelines: 1) We will follow the stipulations of DIO No. 15. 2) We have a documented pressure test on the 13-3/8" outer annulus of 530 psi on August 17, 2009. 3) We will man the well 100% of the time during injection operations. If there is any evidence of communication with the 13-3/8" outer annulus, operations will be shut down immediately and notification will be made to the AOGCC. 4) We anticipate injecting approximately 2000 bbls of Class II fluid in support of ongoing P&A operations on the Spark Platform. 5) Monitor operating parameters including tubing pressure, annular pressure and record fluid volume. 6) We will plug and abandon S-5 at the end of our P&A efforts. 7) We anticipate abandonment operations to be complete by October 7, 2009. If you have any questions, please contact me at 907-565-3043 or by email at tastebbins @ marathonoil.com. Sincerely, Tiffany Stebbins Regulatory Compliance Representative cc: L.Ibele G. Laughlin T. Paxton K. Walsh Page 2 of 2 ~$ ,,- • Alaska AsseRTeam Marathon MAM ®Alaska Production LLC May 28, 2010 Daniel T. 5eamount, Jr., Commission Chair Alaska Oil & Gas Conservation Commission Attn: Jim Regg 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 P.O. Boz 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/565-3076 RE~ElVEC~ ~11~1l~1 €~ ~ ~~~~ Alaska Oil ~ has Ceps. Cammissi~r~ Anchorage ~~~~~ Reference: Report on Disposal Injection Operations Well S-5, Spark Platform, North Trading Bay Unit ~~ ~ ~ ~ Well S-5 on the Spark platform of the North Trading Bay Unit is governed by Disposal Injection Order (DIO) No. 15, approved August 31, 1998. This report covers the final disposal injection operations for S-5 from January 1, 2009 until September 20, 2009, when the well was plugged and abandoned. S-5 has been shut-in for most of the reporting period. The only injection during 2009 was in August and September for a total of 1433 barrels, injected at a maximum pressure of 2250 psi. Attached please find an injection monitoring report and charts showing volume injected, maximum tubing injection pressure, inner annulus injection pressure and outer annulus injection pressure. Please contact me with any questions at 907-565-3043. Sincerely, t ~~~ . Tiffany Stebbins Compliance Representative cc: M. D. Dammeyer Well file Houston file (T N N W W O (J7 O (77 O U~ O O O O O O O O 1/1/2009 '----, - --- i 1/11/2009 1/21/2009 ~ ~ i ( ~ 1/31/2009 I ~ j 2/10/2009 ~ ~ ~ ' 2/20/2009 3/2/2009 3/12/2009 ! ' 3/22/2009 ~ ~ ! 4/1/2009 i 4/11/2009 !, 4/21/2009 ~I ~ ~ 5/1/2009 i ~ 5/11/2009 ~ . ~ I m a 5/21 /2009 ~- - 'i } ~ i $ 5/31 /2009 0 ~ i 6/10/2009 ~ 6/20/2009 m i ! 6/30/2009 _ a ~ ', ! ~ 7/10/2009 .~ ~ ~I ~ ~ I ', ! I 7/20/2009 7/30/2009 i ', I ' 8/9/2009 I I ~ ' 8/19/2009 I ~ ~ ! ' 8/29/2009 i I ', 9/8/2009 ' ~ ' i 9/18/2009 i ~1 rn O O 3 ... ~~ ~ ~ ~ ~ ~ .-r ~ o o D 3 ~ ~ m ~ ~ Q ~~ n ~ O- ~ • r r C~ • v cQ (D N 0 w U7 O N N CJ7 O (T O O O O O O 1/1/2009 -- 1/11/2009 1/21/2009 ' ', 1/31/2009 2/10/2009 2/20/2009 ~ 3/2/2009 ' 3/12/2009 ' 3/22/2009 . 1 1 ~ 4/1/2009 : ~ I + s 4/11/2009 'm 4/21/2009 . ~ D C 5/1 /2009 N i 5/11/2009 ~ s I n 0 ~ 5/21/2009 ~~ ~ ~ ~ 5/31/2009 = I- _ m ~ m 6/10/2009 ~ ~ T ~~. ~ - - ~ ~~~ I 6/20/2009 ; ~ o -~ ~~~~i'll i~~ D = ~~~~,~ ~ 6/30/2009 ,~~~t ~ 7Ni~~,~~1i~~u~ ~ F~~ VV ~ ~fF~~ 7/10/2009 r ~~ ~~ ~ 'II m ?, , - ~~.i .. I i , "I ~ hd~91 7/20/2009 I ~ i 7/30/2009 ICI ~~I't~~ fi~ $ ~ ~ ' i 8/9/2009 IIr a~P'~ ~ ~ ~ ~ ~ ~ 8/19/2009 ~~ ;III --r--- ~ - 8/29/2009 ~ i~ - _~ ~ 9/8/2009 ~ ,, 9/18/2009 CT O Ui O O O O 1 /1 /2009 1/11/2009 1/21/2009 I 1/31/2009 ~ ' 2/10/2009 2/20/2009 II 3/2/2009 3/12/2009 ', ' 3/22/2009 4/1/2009 4/11/2009 4/21 /2009 5/1/2009 i 5/11/2009 ~! 5/21/2009 ~'', 5/31/2009 ~ ~ I 6/10/2009 ~ ~i i 6/20/2009 ~ 6/30/2009 I ~ ~i ~~ 7/10/2009 ~ , 7/20/2009 ~ ~ 7/30/2009 ~ 8/9/2009 ~ 8/19/2009 _ -,--~ ~__ T 8/29/2009 ---- 9/8/2009 - I - I ~~__ 9/18/2009 c 0 c~ ~~ ~ ~ ~ ~ ~ .-r ~ O o D ~ ~ ~ ~ m ~ ~ O Q ~~ ~ O~ ~~ r r C7 cQ m W O W • M Marathon MARATHON Oil Company April 16, 2009 ~K- ~aPR ~ ~ z~a~ Daniel T. Seamount, Jr., Commission Chair. Alaska Oil & Gas Conservation Commission Attn: Jim Regg 333 W. 7t" Avenue, Suite 100 Anchorage, AK 99501 ~lasl<.a Cil Cas Cons. GotTlrnisSlor= Anchorage Reference: Report on Disposal Injection Operations Well S-5, Spark Platform, North Trading Bay Unit This well is governed by Disposal Injection Order (DIO) No. 15, approved August 31, 1998. This report covers disposal injection operations for the period of January 1, 2007 through December 31, 2008 for well S-5 on the Spark platform of the Norfh Trading Bay Unit: S-5 has been shut-in for most of the reporting period. The only disposed volume was in June 2007; 48 barrels was disposed down the well. S-2RD is the only producing gas well on the Spark platform and it has been shut-in due to liquid loading. Marathon is currently in the process of preparing procedures for abandonment of all wells on the Spark Platform. Abandonment is planned in 2009. Please contact me with any questions at 907-565-3043 or tastebbinsC«~ marathonoil.com. Sincerely, ~~~ ~~~ Tiffany Stebbins Compliance Representative Alaska Asset Team P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/565-3076 cc: B. Schoffmann Well file Houston file • ',,~', Math®1'9 MARATHON O'' ~t11~1t1~ August 4, 2008 (Revision to June 23, 2008) Tom Maunder AOGCC 333 West 7th Ave, Suite 100 Anchorage, AK 99501 • Alaska Asset Team PO BOX 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/565-3076 Reference: Report on Disposal Injection Operations 2007 Well S-4 and S-5, Spark Platform, North Trading Bay Unit Dear Mr. Maunder: This annual report of disposal operations covers the period of January 1, 2007 through December 31, 2007 forwells S-4 and S-5 on the Spark platform of the North Trading Bay Unit. Disposal via well S-4 is governed by Disposal Injection Order (DIO) No. 13 for the North Trading Bay Unit (approved September 17, 1997), and disposal well S-5 is governed by DIO No. 15 approved August 31, 1998. Attached are three plots showing injection volume, injection pressure and casing pressure for Well S-5 in the calendar year 2007. The last mechanical integrity test for S-5 was conducted on July 13~' 2004. The next such test is expected to be performed within two months, with appropriate notice provided to the AOGCC. In the interim, no disposal/injection activities will be performed. S-4 is a Class II injection well with a completion variance and mechanical integrity is determined by monitoring of injection rates and pressures only. For the report period, there were no fluids injected into either well; thus all injection rates and tubing pressures for both wells were zero. Spark production has been shut in since 2005 due to liquids loading in the sole gas producing well, S-2rd. A minor anomaly was noted in the recorded data for the S-5 casing pressure (see attached graph), however since the pressure is very low and there was no injection activity during this period, no action was deemed necessary. Sincerely, ~r G~ A. B. Schoffmann Operations Manager Marathon Oil Company Enclosures Q:\Spark\Wells\Regulatory\2007 Annual Injection Report for S-4 and S-5\Spark #4 and #5 Annual Inj Rept - 080408 revision.doc ~~ a~ a~ E ~ ~ ~ 0 0 > > c c 0 0 w w U U m a~ 'c 'c ~~ *k *k Y ~C N N fl. fl. ~~ ~ ++ ~ ~C O m V ~ N _ .~ ~ ~ ``L 1 r N L C O R Z N ~ N L . ~O N ~ ~a ~~ ~ L O ~ a aN c 12/27/2007 11 /27/2007 i 10/28/2007 I 19/28/2007 8/29/2007 17/30/2007 .dr 6/30/2007 p a 5/31 /2007 5/1 /2007 .,' 4/1/2007 y' 3/2/2007 1 /31 /2007 ;.~ ~~ 1/1/2007 0 Q:\Spark\Wells\Regulatory\2007 Annual Injection Report for S-4 and S-5\Spark #4 and #5 Annual Inj Rept - 080408 revision.doc °o °o °o °o °o °o °o °o ~ ~ ~ adMB `awnjon uo~;oafu~ `~ • • a~ ~ L L ~ ~ i I 12/27/2007 ~ ~~ i a a i i 0 0 ~`! a~i a~i ~ I ~ ~~~~~' 11/27/2007 'c 'c I i ~ ~ L L ~ ~ 10/28/2007 • ~ i ~ ~ ; X28/2007 ~ L I I~ ~ i ' ~ .w ~ ', ~, ',~ ~ ~ ~~, 8/29/2007 ~ C N d ~ j I ~'i ~ I '' ~ ~ ~ ~ L , I ~ ~ ;I = m I ~ _ ~ ' ~ I .~ s -' 7/30/2007 _~ V C ~ i . R ~ ~ ` C L ~ ~~~i { ~ ~ ~ t is ~ d { i ~ j:J w - ~ ~ 'i ~~ ~ ~ ~ ~ { ~~ 6/30/2007 p ~ ~ C i ~ I ; i ~ Z ~ I - ,r~' I ~ L G i 1 /2007 s- ~~ 5/3 .~ ~ ~'~ to ~ d ~~ ~ ~ ~: ~ a ~ I ;; ' ea ~ O ~ ~ ~ j I ~~ i , . ~., `!, '~ 5/1/2007 Q. N N ~' 'I i ~ ~ O I I i I i I ~ ~ ~ ~ ; 4/1/2007 3/2/2007 I~~1 1 /31 /2007 ~ ' '~ ' ~~r- ~-~ 1/1/2007 o °o °o °o °o °o °o °0 0 0 ° O 00 CO V' N O 00 C4 d' N `~ ~ ~ ~ Bisd aanssa~d uoi;oafu~ Q:\Spark\Wells\Regulatory\2007 Annual Injection Report for S-4 and S-5\Spark #4 and #5 Annual Inj Rept - 080408 revision.doc .r • • ~ m L L ~ ~ ~ ~ a~ a~ L L a a rn +~ c c .~ .N U U ~r ~n ~~ Y1 L L •^Q 'Q^- vJv~~~^^{I{ 12/27/2007 11 /27/2007 ~ 0/28/2007 x/28/2007 L N ~ ~ ~ L a ~ a, m C ~ '~ C V R ~ ~ N ~ 'C ~ ~ Z y L ~_ ~ ~a ~a ~ N L Q 3/29/2007 '/30/2007 i/30/2007 G i/31 /2007 i ~: 5/1/2007 t: `" 4/1/2007 ='13/2/2007 i 1 /31 /2007 ~ I j I, ,T-~ ~- ~ ~ ~ ~ ~ -- 1 /1 /2007 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o ~n o~ o~ o~ o~ o ~n o n o ~n o n o ~n O~ O O O ti ti O CO In to '~ d' M M N N ~ ~ r B~sd `amssa~d 6uise~ Q:\Spark\W ells\Regulatory\2007 Annual Injection Report for S-4 and S-5\Spark #4 and #5 Annual Inj Rept - 080408 revision.doc ~.l ~I i¢''I q `~ ~ ~~ ~~ ~~ I ~, ~~ i I Aiaska A~ei Team tJ.S. Production Operations ~ ~ Ma!'alt~'1011 ~ ''~ . maxarxox i' Ci0111a11~/ . ~ _i i`~,! ~~ _ 200f June 23, 2008 Tom Maunder AOGCC 333 West 7t" Ave, Suite 100 Anchorage, AK 99501 P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/565-3076 Reference: Report on Disposal Injection Operations 2007 Well S-4 and S-5, Spark Platform, North Trading Bay Unit Dear Mr. Maunder: This annual report of disposal operations covers the period of January 1, 2007 through December 31, 2007 for welts S-4 and S-5 on the Spark platform of the North Trading Bay Unit. Disposal via well S- 4 is governed by Disposal Injection Order (DIO) No. 13 for the North Trading Bay Unit (approved September 17, 1997), and disposal well S-5 is governed by DIO No. 15 approved August 31, 1998. Attached are three plots showing injection volume, injection pressure and casing pressure for this well in the calendar year 2007. The last mechanical integrity test for S-5 was conducted on July 13tH 2004 and the next such test is due by July 13tH 2008. (S-4 is completed as an annular injector and mechanical integrity is determined by monitoring of injection rates and pressures only.) For the report period, there were no fluids injected into either well; thus all injection rates and tubing pressures for both wells were zero. Spark production has been shut in since 2005 due to liquids loading in the sole gas producing well, S-2rd. A minor anomaly was noted in the recorded data for the S-5 casing pressure (see attached graph), however since the pressure is very low and there was no injection activity during this period, no action was deemed necessary. Sincerely, A. B. Schoffmann ~~~~ Operations Manager Marathon Oil Company L:\Spark\Wells\Regulatory\Spark #4 and #5 Annual Inj Rept - 05-2007 final.doc Enclosures • • ~ a~ E E ~ ~ 0 0 > > c ~ 0 0 :~ U U a~ a~ .~ .~ ~ ~ ~ ~ ~ ~ c~ c~ a. a ~~ • ^ +.• ~ ~C A O m V ~ ~ ~ .~ .~ C ~ LLL 1 r ~ t C O ca Z N ~ N ` _ O d ~ a c~ ~ N L O ~ ~ fl- N N 12/27/2007 11 /27/2007 10/28/2007 9/28/2007 8/29/2007 7/30/2007 d 6/30/2007 p 5/31 /2007 5/1 /2007 4/1 /2007 3/2/2007 1 !31 /2007 1 /1 /2007 0 °o °o °o °o °o °o o °o ~ r ~ adMB `aua jon uoi~~a(u~ N Disposal Wells S-4 and S-5 Injection Pressure Spark Platform -North Trading Bay Unit • Spark #4 Injection Pressure ^ Spark #5 Injection Pressure 2000 __-.._.. _.._ _.------- _-..__ - - - - ---- -_ 11300 1600 1 x(00 - _ -- -- -- _ -~- ----- -=----- -- --.~______~ _ -__,.~~~- =---- --_ - - -------- -- --- _.. _.__ _-._ _ _ --- __ ~ N i ~ a . - _ ~ 1 ?00 d --- - - ---- -- - - --- - - - - -- -- ---- - - __ L1000 _ _-.._. ...- _ a c o v 800 as -t= - _ •_ 600 --- -~- -- ------ ---- -=- -- - - X00 .__-._.. _ ~_._ .e.__~__ __ _..:_~__~.._ ._.~. ___:_ .. ..__.._. ---- ~_..--,-.----- ---------- •--- --__ _ .._ ....._.,_ .---- - - - = __._ ___ _ . - ---- --_---__.. ?00 ----- ---- --- -- i 0 1 ~ w .~ j ~ rn ~ w N c\o j j 1 N \ N 1 ~ N ~ I~ N ~ 1 N ~ O N W O N W O N ~ N N W N ~ N ~ ~ N ~ N ~ O O N O O O O O O O O O O O N N N V O V ^J V J O V O V O V O V O V O O O O O O J J ~I Date ~ m~~ ~i ~ ~ ~ ~~ ~ ~' ~ ~ i ~ ~ ~ ~ U U; I~ ~I IY YI c~ c~ c~ cn i • ^ N 3 N ~ ~ ~ L a ~ a, m C p~ ~~ C co U ~ LLL 1 r N L ~ ~ C O ~Z N ~ fA ` O . ~ ~ *' a ~~ O ~ fl. N N D 12/27/2007 11 /27/2007 10/28/2007 9/28/2007 8/29/2007 7/30/2007 r 6/30/2007 p 5/31 /2007 5/1 /2007 4/1 /2007 3/2/2007 1 /31 /2007 ~-i r ~ r-~r ~ i ~--~-~~ iT-~ ~ ~ F .~ 1 /1 /2007 O O O O O O O O O O O O O O O O O O O O O O~ O~ O u") O~ O~ O to O H O tc) O~ O~ O O O M M ~ ~ O O to ~ ~ ~ M M N N ~ •- 6isd `aanssaad 6uise~ • • Alaska Asse Team o PO BOX 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/565-3076 June 28, 2007 Tom Maunder RECEIVED AOGCC JUL 4 6 2007 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Alaska Oil & Gas Cons. Commission Anchorage Reference: 2006 Annual Report of Disposal Injection Operations Well S-4 and S-5, Spark Platform, North Trading Bay Unit Dear Mr. Maunder: This annual report of disposal operations covers the period of January 1, 2006 through December 31, 2006 for wells S-4 and S-5 on the Spark platform of the North Trading Bay Unit. Disposal via well S-4 is governed by Disposal Injection Order (DIO) No. 13 for the North Trading Bay Unit (approved September 17, 1997), and disposal well S-5 is governed by DIO No. 15 approved August 31, 1998. During the report period, there were no production activities on the Spark platform. The only producing gas well, S-2rd, was shut-in for the entire period due to liquid loading. Therefore, there were no fluids produced or injected during the report period. All rates and pressures for the two Spark injection disposal wells were "zero" as indicated on the attached plots for calendar year 2006. The last mechanical integrity test for S-5 was conducted on July 13t" 2004 and the next such test is due by July 13`" 2008. Well S-4 is not equipped with a serviceable tubing or packer, and therefore mechanical integrity is established by alternative means as set forth in D10-13. Sincerely, ~ .S . B. Schoffmann Operations Superintendent Marathon Oil Company Enclosures r Y Spark Platform -North Trading Bay Unit - • Spark #4 Casing Pressure 2000 1800 1600 1400 200 1000 d 800 U 600 400 200 0 N 0001 fffJ33~ ~ ~ ~ o 01 ~J1 f3 ~ Q (~/ Sfslll~ fQ3 fy~ ,5~2j ~~ NN 1 p S $ `~ OO 3 N p ' OI JJ Ol S~ O~ ~~ Disposal Well S-5 Casing Pressure Spark Platform -North Trading Bay Unit ~ 9 ^ S ark #5 Casin Pressure 2000 1800 1600 1400 200 1000 6 800 V 600 400 200 0 Q+ Q~+ 5~+~ f5~~ ~ Q~ 13 ~ gN 1g3 $N 8'i M M ~ Q ~ 3~ 01 3~ o.ee ~ ~ • + ^isposa~WeFF6-4lnjeetion-Vela Spark Platform -North Trading Bay Unit - j•Spark #4 Injection Volume 800 700 600 200 100 0 O 6 '=500 t0 E O~ >C O 300 c J !v ~ £+ ~ f QQ 3 J ~ 13 Q pp Qi o N ~ 183 W 8N 01 ~ ?? ~ 8~ 1 8~ 01 Npp~ Ol oN O v ~ of C1 T O OWi 01 Date Disposal Well S-5 Injection Volume Spark Platform -North Trading Bay Unit ^ Spark #5 Injection Volume 000 700 000 O ;500 m$¢ 0400 300 e 200 100 0 1. r y iS - .. - ' >j, s; ' ~ ;._ - - " .. ~- .d ' ~ - "'-' .. - - ... - - --- T _ - _ - - -~ OI ~ Ol Ol 01 ~ W ~ m ~ v O OI Dots • t ~ •• ~ ~ ' ~SptySal'iNllt'S~'1f ~8Ct10Ti~f@S3~Y Spark Platform -North Trading Bay Unit - •Spark #4 Injection Pressure 2000 1800 1600 1400 2 g ~1zoo plooo a 800 e 600 400 200 0 $~ ?~ ~ ~ ~ 8i Q~Q b'i Q~Q ~i ~ ~ ~`~y 3 ~~{i ~i Q~ ?li Q~ X 2 ~ JJ ~F ~ Date Disposal Well S-5 Injection Pressure Spark Platform -North Trading Bay Unit ^Sp ark #5 Injection Pressure "-- ----- - 2000 x. -yp ,~ .~r'~. i - ', ~ +-~ ^ .3.. S ~ ~ v '' t AF ~. 1800 - ~ i .i ~ ° '~..-~iL. ~' ' '~.~--- --~-r' - ..~ 1600 ~ ;> ~ 1 e - :~; ~ ~ ' - - ~ ~=, ` , T > a, 1400 ;fir - _:.,~ _. - 1200 ;~~- -<- ~ "~~§ s ~,U ' :ti ~ ~ _.. j'x 1L j ~ .rt; t ~ x rys ,ham 1000 p 4 r~ r ~ _ _ - -- ~ _ ~~' 3 _ ~ ~~;~N = . - a r`T. 800 ---yr. -_ ~, ,- iii . --' -- - 800 ~ z= ~. .. .ti` -- , 400 -_, ._. ---._- ._T=. _ _ _°- -----. .._ __._. _ .-_.. _ ..-_._.._.~_. ..- _-___`. ._. ~a: 200 ,". • .. --.~_- --`------- - _ -- ___. _- __ ..; 0 ~ 1 ~ ~ ~ ~ ~ ~ ~ ~ ! 3 ~ f3 N ~ ~ _ f3 N ~_VV f3 ~ 8 8 ~ N8 S~ S ~ o f3 13 d ~ 0~ O1 O~ O1 p GI Date ~,. y;1 } i~t , i. j ~ ,~ ~ i„a ~ ~~ ,/ I ` r ~'+ t ~~ FRANK H. MURKOWSKI, GOVERNOR ~-7IfiA OII~ A1~TD ~ir`AS !j 333 W. T" AVENUE, SUITE 100 CO1QSFiRVA'1`IOP~T COMnII5SI01~ 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 welt 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 Intep~ity The mechanical integrity of an injection well must be demonstrated before injection begins, at least once every four years thereafter (except at least once every two years in the case of a slurry injection well}, and before returning a well to service following a workover affecting mechanical integrity. Unless an alternate means is approved by the Commission, mechanical integrity must be demonstrated by a tubing/casing annulus pressure test using a surface pressure of 1500 psi or 0.25 psi/ft multiplied by the vertical depth of the packer, whichever is greater, that shows stabilizing pressure and does not change more than 10 percent during a 30 minute period. The Commission must be notified at least 24 hours in advance to enable a representative to witness mechanical integrity tests. Well Integrity Failure and Confinement Whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, log, or other evidence, the operator shall immediately notify the Commission and submit a plan of corrective action on a Form 10-403 for Commission approval. The operator shall immediately shut in the well if continued operation would be unsafe or would threaten contamination of freshwater, or if so directed by the Commission. A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating well integrity failure or lack of injection zone isolation. Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. The following table identifies the specific rules affected by the rewrite. Affected Rules "Demonstration of "Well Integrity "Administrative Injection Order Mechanical Failure and Action" Integrity" Confinement" Area Injection Orders AIO 1 -Duck Island Unit 6 7 9 AIO 2B - Kuparuk River Unit; Kuparuk River, 6 ~ 9 Tabasco, Ugnu, West Sak Fields AIO 3 -Prudhoe Bay Unit; 6 ~ 9 Western Operating Area AIO 4C -Prudhoe Bay Unit; 6 ~ 9 Eastern Operating Area AIO 5 -Trading Bay Unit; 6 6 9 McArthur River Field AIO 6 -Granite Point Field; 6 7 9 Northern Portion AIO 7 -Middle Ground 6 ~ 9 Shoal; Northern Portion AIO 8 -Middle Ground 6 ~ 9 Shoal; Southern Portion AIO 9 -Middle Ground 6 ~ 9 Shoal; Central Portion AIO l OB -Milne Point Unit; Schrader Bluff, Sag River, 4 5 8 Ku aruk River Pools AIO 11 -Granite Point 5 6 8 Field; Southern Portion AIO 12 -Trading Bay Field; 5 6 S Southern Portion AIO 13A -Swanson River 6 7 g Unit AIO 14A -Prudhoe Bay 4 5 S Unit; Niakuk Oil Pool AIO 15 -West McArthur 5 6 9 Affected Rules Injection Order "Demonstration of "Well Integrity "Administrative Mechanical Failure and Action" Integrity" Confinement" River Unit AIO 16 - Kuparuk River Unit; Tarn Oil Pool 6 ~ 10 AIO 17 - Badami Unit 5 6 8 AIO 18A -Colville River Unit; Al ine Oil Pool 6 7 11 AIO 19 -Duck Island Unit; Eider Oil Pool 5 6 9 AIO 20 -Prudhoe Bay Unit; Midni ht Sun Oil Pool 5 6 9 AIO 21 - Kuparuk River Unit; Meltwater Oil Pool 4 No rule 6 AIO 22C -Prudhoe Bay Unit; Aurora Oil Pool 5 No rule 8 AIO 23 - Northstar Unit 5 6 9 AIO 24 -Prudhoe Bay Unit; Borealis Oil Pool 5 No rule 9 AIO 25 -Prudhoe Bay Unit; Polaris Oil Pool 6 g 13 AIO 26 -Prudhoe Bay Unit; Orion Oil Pool 6 No rule 13 Dis osal In'ection Orders DIO 1 -Kenai Unit; KU WD-1 No rule No rule No rule DIO 2 -Kenai Unit; KU 14- 4 No rule No rule No rule DIO 3 -Beluga River Gas Field; BR WD-1 No rule No rule No rule DIO 4 -Beaver Creek Unit; BC-2 No rule No rule No rule DIO 5 -Barrow Gas Field; No rule No rule No rule South Barrow #5 DIO 6 -Lewis River Gas Field; WD-1 No rule No rule 3 DIO 7 -West McArthur River Unit; WMRU D-1 2 3 5 DIO 8 -Beaver Creek Unit; BC-3 2 3 5 DIO 9 -Kenai Unit; KU 11- 17 2 3 4 DIO 10 -Granite Point Field; GP 44-11 2 3 5 Affected Rules Injection Order "Demonstration of "Well Integrity "Administrative Mechanical Failure and Action Integrity" Confinement" DIO l I -Kenai Unit; KU 2 3 4 24-7 DIO 12 - Badami Unit; WD- 2 3 5 1, WD-2 DIO 13 -North Trading Bay 6 Unit; S-4 2 3 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; NCIU A-12 DIO 19 -Granite Point Field; W. Granite Point State 3 4 6 17587 #3 ~ DIO 20 -Pioneer Unit; Well 3 4 6 1702-15DA WDW DIO 21 - Flaxman Island; 3 4 ~ 7 Alaska State A-2 DIO 22 -Redoubt Unit; RU 3 No rule 6 D1 DIO 23 -Ivan River Unit; No rule No rule 6 IRU 14-31 DIO 24 - Nicolai Creek Order expired Unit; NCU #5 DIO 25 -Sterling Unit; SU 3 4 7 43-9 DIO 26 - Kustatan Field; 3 4 7 KF1 Stora a 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 Recover In'ection Orders EIO 1 -Prudhoe Bay Unit; Prudhoe Bay Field, Schrader No rule No rule 8 Bluff Formation Well V-105 ,~' Affected Rules "Demonstration of "Well Integrity "Administrative Injection Order Mechanical Failure and Action" Integrity" Confinement" EIO 2 -Redoubt Unit; RU-6 5 8 9 02-902 (Rev. 3/94) Publisher/Original Copies: Department Fiscal, Department, Receiving AO.FRR4 STATE OE ALASKA NOTICE TO PUBLISHER ADVERTISING ORDER NO. ADVERTISING INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTIFIED AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COPY OF AO.O2514016 ORDER ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE SEE BOTTOM FOR INVpICE ADt3R~55 F AOGCC AGENCY CONTACT DATE OF A.O. R Suite 100 333 West 7th Avenue ° , Anchorage, AK 99501 PHONE Pc "` 907-793-1221 - DATES ADVERTISEMENT REQU[RED: o Journal of Commerce October 3, 2004 301 Arctic Slope Ave #350 AK 99518 Anchora e S SHOW OUBLE LINES MUST BE PRINTED IN ITS g , ENTIRETY ON THE DATE SPECIAL INSTRUCTIONS: AFFIDAVIT OF PUBLICATION United states of America REMINDER State of ss INVOICE MUST BE IN TRIPLICATE AND MUST REFERENCE THE ADVERTISING ORDER NUMBER. division. A CERTIFIED COPY OF THIS AFFIDAVIT OF PUBLICATION MUST BE SUBMITTED WITH THE INVOICE. Before me, the undersigned, a notary public this day personally appeared ATTACH PROOF OF PUBLICATION HERE. who, being first duly sworn, according to law, says that he/she is the of Published at in said division and state of and that the advertisement, of which the annexed is a true copy, was published in said publication on the day of 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 Public Notices ~, Subject: Public Notices From: Jody Colombie <Jody_colombie@admin.state.ak,us> Date: Wed, 29 Sep 2004 13:01:04 -0800 To: undisclosed-recipients:; BCC: Cynthia B Mciver <brenmciver@admin.state.ak.us -, Angela ~~~ebh <angie_webb@admin.state.ak.ds>, _RobcrC E ;~~lintz -rubert mintz,c~;law.state.ak.us=, Christina Hansen <c.hansen@,io~cc.state.ak.us%, Terrie Hubble ~ hubhlet(~u-bp.con%->, Sondra Ste~E man <StewmaSD@BP.coixi--~, Scott 8c C~tmmv Taylor ~stavlor~u:alaska.net%, statlekj <stanekj@unocal.com>, ecolaw <ecola~~Jr~ trustcts.org:%, rosera~sdale ~ roseragsdalc~~i `7~i.n~t >. trmjrl ctrmjrl~aaol.com> jbriddle <jbriddle[<i~.marathonoil.coni>, rockhill <roekhili~~caogaor~=. shanag <shaneg@evergreengas.com>, jdarlingtun - jdarlington(a torestctiLconi>, nalson <knelson@etroleumnews.com>, eboddy'~~ choddy~a,usilielli.com; -, I~~lark Dalton <mark.daltoh@hdrinc.com>, Shannon Dotulelly ~shannon.donn~lly~ci;conocophillips.com>. "~~tark P. Worcester" <inark.~.worcester@conocophill ips.com>. "Jerry C. Dethlets" <jetty.e.dethlefs@eonocophillips.com>. Bob 'bob ~.inletkeeper.ora'°, ~.~d~: <~~d~ ~~i;dnr.statc.ak.u, -. tjr <tjr@dr~.state.ak.us>, bbritch <bbrit~h u alaska.net~=~, mjnelson <:mjn~lson!~i:pur~°in~ertz.c<~m>, Charles O'Donnell <charles.o'doi7ne11@aeco.com=>. "Rand~~ I_. Skillern" ~~~Skill~Rl.~«.BP.com=-, "Deborah J. Jonas" ~JonesD6@BP.corn?, "Paul G. Hyatt" <~hyattpg!aBP.com ~, "Steven. R. [~ossberg" <RossbeRS@BP.com>, Lais <loi@inletkccper.or~:-, Dan Bross kuacne«-s(ci;kuac.org>, Gurdcrn Pospisl <PospisG@$P.com>, "Francis S. Sommer" <SommerFS~uBP.com=~. lt~likcl Schultz <Mike],Schultz@BP.com>, "Nick W. CJlo~er" <Gloverti~~"~~iBP.com~-, "Daryl J. kleppin" <1CleppiDE@BP.eorn>, ".Tanet D. Platt" 'PlattJD~a;'BP.com>_ "Rosanne !~1. Jacobsen." ~JacobsRM@BP.com>, ddonkel'<ddoi~kcl~u cfil.rr.com =. Collins ti-fount <collns monn@revenue. tate.ak.us>,`mckav ~~~nlckay(~%:gct.net>. Barbara F Fullmer <Barbara.£fullmer@conocophillps.com =. bo~astl~f bc>cast~~f~c~bp.c~>m==. C:harl~s Barker <barker@usgs.gov>, doug__schull;ze <dou~_sehultz~iu xtoencr~r<.cum~~, Hank Alfiin~d hank.afford@exxonmobil.com = Ltark Kova~ 'vesnola'gci.net==. ~spfoff <gspfoff@aurorapower.conl= . Gre`T~T tiael~ ~7r~gg.n td~ «%sh~ILcum=>, Fred Steed- <fred.steece@state.sd.us>'reri~tty <rcrott} ~~ ch?m.com>- J~Jones ~~-jejones(uaurorapo~~er.eom==, dapa <dap@alaska.net>; jroderick ~jroderiek ci;gci.net>. eyancy ~ ~evan~~ 4i-weal-tite.net~=-, "Jams lit. Ruud" <fames.m.ruud@corrocophil(ips.c;om>, Brit Lip ~1~~ <mapalasku(a<al:.net=~. fah <jah@dnx.state.ak.us>, Kurt E Olson ~~'kurt_ol5on;u lei=is.state.ak.u~~-~, buonoje ~:buono7~ ubp.c~~m~~. Mark I-3anley'~mark_hanley@a~~adarkuc~~m~->. Loren I~man <luren_leman~c~gov.state.ak.us=~. Julie Houle <julie_houle@dnr.state.ak.us>, John ~'~' Kate j~~ katz'u;sso.or~=~, Suzan J Elill <suzan hilt cr dec.State.ak.us>, tablerk <~tabl~rk~u::unocaLcom>, Srady° ~=:bradv~u ao~a.or~==. Brian Havelock <beh~adnr.state.ak.us>~ bpopp ~'~bpopp~«;borough.kenai.ak.us==, Jim ~~hite <jimwh~ite~asatx.rr.com>, "John ~S. Ha«rorth" <john.s.ha~~-orth~a:exYOnmobii.com=>, marty <marty@,rkindustrial.com>, ghammons <ghammons;~i?aoLcom=-. t-tnclean <rmelean@po~iox.alaska.n~t-, mkm7?l10 ~~mkm?2[IU ~r'aol.com%, Brian Gillespie <ifbmg atuaa.alaska.edu=•, David L 13oelens <:dbo~lensc~i>.aurorapo« er.com=>. Todd Durkee <TDC112KEE@KN1G.eom ~, G~~~ Schultz, ~~ ~ra~-~-~_schultr(~~dnr.state_ak.us=>, ~y"a~~~e Rancier <RANCIER@petro-cani~da.ca==~, 13111 ~Iiller~ Bill_~1iil~r~a;~toalaska.com->_ Brandon Ga~m~~n <1?gagnon@brenalaw.com?, Paul ~y'`inslo~~~~ <pm«~inslow!r~~Torestoil.com>, Garry Catron <catrongr@bp:com> Sharmaine Copeland 'ccrpelasvc~~bp.com=>. SUZalltl~ Allegan <sallexan@helmenergy coni%, Kristin Dirks ° kristin dirks~u~dnr.state.ak us= , Kaynell Leman <kjzeman@marathonoiLc;~m =, John To~~er 'Jotut.To~~~tr'~i~eia.doc.~oti-?, Bill Fo~wl~r @ill_Fowler@anadarko.CC~J1 -, ~'aublui Slvartz ., ~ auglu~.;s~vartz@rbt:ctn.com >, Scutt C:rans«~i~.k 1 of 2 9/29/2004 1:10 PM Public Notices <scott.cranswick@mms.gov>, Brad IVIcKirn <mckimbs~BP.eorn> Please £nd the attached Notice and Attachment for `the proposed amendment of_ .underground injection orders and the Public Notice Happy Va11ey ##l0. Jody Colombie Content-Type: application/msword Mechanical »ntegrity praposal.doe Content-Encoding: base64 Content-Type: application/msword Mechanical Integrity of Wells Notice,dac I Content-Encoding: base64 Content-Type: application~`msword HappyV alleyl0 I~earingNatice.doc Content-Encoding: base64 2 of 2 9%29!2004 1:10 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@alaskajoarnal.com Please publish the attached Notice on October 3, 2004. Thank you. Jody Colombie Content-Type: application/msword 'Mechanical Integrity of Wells Notice.doc Content-Encoding: base64 __ _ __ _ Content-Type: appiication/msword Ad Order form.doc Content-Encoding: base64 __ _ __ __ 1 of 1 9/29/2004 1:10 PM Citgo Petroleum Corporation Mary Jones PO Box 3758 XTO Energy, Inc. Tulsa, OK 74136 Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 Kelly Valadez Robert Gravely Tesoro Refining and Marketing Co. 7681 South Kit Carson Drive Supply & Distribution Littleton, CO 80122 300 Concord Plaza Drive San Antonio, TX 78216 Jerry Hodgden Richard Neahring Hodgden Oil Company NRG Associates 408 18th Street President Golden, CO 80401-2433 PO Box 1655 Colorado Springs, CO 80901 Kay Munger Samuel Van Vactor Munger Oil Information Service, Inc Economic Insight Inc. PO Box 45738 3004 SW First Ave. Los Angeles, CA 90045-0738 Portland, OR 97201 Mark Wedman Schlumberger Halliburton Drilling and Measurements 6900 Arctic Blvd. 2525 Gambell Street #400 Anchorage, AK 99502 Anchorage, AK 99503 Baker Oil Tools Ciri 4730 Business Park Blvd., #44 Land Department Anchorage, AK 99503 PO Box 93330 Anchorage, AK 99503 Gordon Severson Jack Hakkila 3201 Westmar Cr. PO Box 190083 Anchorage, AK 99508-4336 Anchorage, AK 99519 James Gibbs Kenai National Wildlife Refuge PO Box 1597 Refuge Manager Soldotna, AK 99669 PO Box 2139 Soldotna, AK 99669-2139 Richard Wagner Cliff Burglin PO Box 60868 PO Box 70131 Fairbanks, AK 99706 Fairbanks, AK 99707 Williams Thomas North Slope Borough Arctic Slope Regional Corporation PO Box 69 Land Department Barrow, AK 99723 PO Box 129 Barrow, AK 99723 ~~~~~ ~~ David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 John Levorsen 200 North 3rd Street, #1202 Boise, ID 83702 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle, WA 98119-3960 David Cusato 200 West 34th PMB 41 1 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Darwin Waldsmith PO Box 39309 Ninilchick, AK 99639 Penny Vadla 399 West Riverview Avenue Soldotna, AK 99669-7714 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 [Fwd: Re: Consistent Wording for Injection ,, ;rs -Well Integrity Subject: [Fwd: Re: Consistent Wording for Injection Orders - From; John Norman <john_norrnanC'.admin.state.ak.us> Date: Fri, O1 Act 2004 11:09:26 -0800 To: Jody J Colombie <jolly_cohmbie(d,~admn.state.ak.us> more ;~,1 WeII Integrity {Revised)] ------- 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 mintz(a~law.state.ak.us> To:jim re~g c(r~,admin.state.ak.us CC:dan seamount a,admin.state.ak.us, john norman(c~,admin.state.ak.us Jim, looks good, buC 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 ]ass of integrity, etc. »> James Regg <Iim regg c~admin.state.ak.us> 8/25/2004 3:15:06 PM »> Rob -Thanks for the review; here's a redraft after considering your comments. I have accepted most of the suggested edits; also attached is response to questions you pose (responses are embedded in the comments, using brackets [JBR - ...] to set apart from your questions). Jim Regg Rob Mintz wrote: Jim, I have some questions about the draft language, which are shown as comments on the first document attached. Based on my current guesses about what the answers will be to my questions, I also have some suggested edits, which are shown as redlines on the second document attached. ` »> James Regg <jirn regti(aadminstate.ak.us> 8117!2004 4:33:52 PM »> Please delete previous version (email sent 8!9/04); 1 found another inconsistency in the injection orders regarding well j 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 1 of 2 10/2/2004 4:07 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) - establishes more frequent MIT schedule for slurry injection wells (every 2 yrs) which is consistent with our current practice (but not addressed in regulations) Welt Integrity Failure - retitles to "Well Integrity Failure and Confinement"; inserted language regarding injection zone integrity (see DIO 25 and 26) - consistent language regardless of type of injection (disposal, EOR, storage); - eliminates requirement for immediate shut in and secure; allows continued injection until Commission requires shut in if there is no threat to freshwater; - eliminates delay in notifying Commission after detect leakage or communication ("i.e., "immediately notify"); - removes language about notifying "other state and federal" agencies; - requires submittal of corrective action plan via 10-403; - requires monthly report of daily injection rate and pressures (tubing and all casing annuli); this is a requirement we currently impose when notified of leak or pressure communication; - notice and action not restricted to leaks above casing shoe as stated in several DIOs Administrative Actions - adopts "Administrative Actions" title (earlier rules used "Administrative Relief'); - consistent language regardless of type of injection (disposal, EOR, storage); - uses "administratively waive or amend" in lieu of terms like "revise", "reissue", etc.; - adds geoscience to "sound engineering principles"; - language is more generic regarding fluid movement out of zone; existing versions mention varying combinations of protecting "freshwater", "aquifers", "USDWs"; "risk of fluid movement"; "fluid escape from disposal zone" Jim Regg John K. Norman <John Notman(a~admin.state.us> i Commissioner Alaska Oil & Gas Conservation Commission 2 of 2 10/2/2004 4:07 PM ,EFwd: Re<: Consistent Wording for Injection ~;rs -Well Integrity ... ;~: Subject: [Fwd: Re: Consistent, Wording for Injection Orders - We11 Integrity (Revised)]. From: John Norman <john_norman@admin.state.ak.us> Date: Fri, O1 Oct 2004 11:08:55 -0800 To: Jody J Colotnbie <jody_colombie aadmn.state.ak.us> 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(a~law.state.ak.us> To:dan seamount(a?,admin.state.ak.us, jim regg(a~admin.state.ak.us, john normanna,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(aJ,admin.state.ak.us> 8/17/2004 4:33:52 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) We(I 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 1 of 2 10/2/2004 4:07 PM [Fwd: Re: Consistent W"ording for Injection ;rs -Welt Integrity -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. Norman <John Norman(a~admin.state.us> Commissioner Alaska Oil & Gas Conservation Commission _. _._ _ _ Content-Type: application/msword Injection Order language - questions.doc Content-Encoding: base64 __ __ _.. _ __ Content-Type: application/msword Injection Orders language edits.doc Content-Encoding: base64 2 of 2 10/2/2004 4:07 PM 4 Standardized Language for Injection Orders Date: August 17, 2004 Author: Jirn Regg Demonstration of Tubin /Casing Annulus Mechanical Inte rite 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 ofTubing/Casing Annulus Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before injection begins, at least once every four years thereafter (e~ccept at least once every two years in the case of a slurry injection well), and. before returning a well to ser`~ice fo}lo`vina ~Til"`1' a workover affecting mechanical integrity, zzn~,a „t ~,,,..~ , . ,, . ,.f,:~., ,.*:..:,~.. ; ~:.~:.,~. ~ ~~~1zRT~ ~~ a~~ ~ .. unless az~ alternate moans is approved by the Commission, znecl~anical integrity must be demonstrated. by a tubinz; pressure test using_a T4~ ?vI-I-surface pressure ofnb~ 1500 psi or 0.25 psi/ft multiplied by the vertical depth, whichever is greater, t11at m~-shows stabilizing pressure that does~d-x not change more than 10-°-s- percent during a 30 minute period. --4n-y - - The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests. Well Inte rity Failure and Confinement Except as otherwise provided in this rule, Tthe tubing, casing and packer of an injection well must ~'°m^^~~*••^*° maintain integrity during operation. t~rhenever any pressure communication, leakage or lack of injection zone isolation is indicated liv injection rate. operatingpressure obsezti~ation test sur<-rev, loa. or other evidence, tThe operator r~shall immediately notify the Commission and submit a plan of corrective action on a Form 10-403 for Commission approval. .. , , ~ ~ . , ~~, .The operator shall shut in the well if so directed by the Commission. The operator shall shut in the well without aEVaitin~ a response from the Corntnissic>n if continued operation ~~~ould be unsafe or would threaten contamination of freshwater .Until corrective action is successfully completed, Aa monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating pressure communication or Leakage. Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. Fwd: Re: [Fwd: AOGCC Proposed WI Lane for Injectors]] Subject: [Fwd: Re: [Fwd: AOGCC Proposed WI Language for Injectors] Fro-n: Winton Aubert <winton aubert~admin.state.ak.us> Date: Thu, 28 Oct 2004.09:48:53 -0800 Toc Jody J Colo~rlbe <jody calombie@admin.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@admin.state.ak.us> References: <41812422.8080604@admin.state.ak.us> These should be provided to Jody as part of public review record Jim Winton Aubert wrote: FYI. -------- Original Message -------- Subject: AOGCC Proposed WI Language for Injectors Date: Tue, 19 Oct 2004 13:49:33 -0800 From: Engel, Harry R <Enge1HR@BP.com> To: winton aubert@admin.state.ak.us Winton... Here are the comments we discussed. Harry *From: * NSU, ADW Well Integrity Engineer *Sent: * Friday, October 15, 2004 10:43 PM *To: * Rossberg, R Steven; Engel, Harry R; Cismoski, Doug A; NSU, ADW Well Operations Supervisor *Cc: * Mielke, Robert L.; Reeves, Donald F; Dube, Anna T; NSU, ADW Well Integrity Engineer *Subject: * AOGCC Proposed WI Language for Injectors Hi Guys. John McMullen sent this to us, it's an order proposed by the AOGCC to replace the well integrity related language in the current Area Injection Orders. Listed below are comments, not sure who is coordinating getting these in front of Winton/Jim. Overall, looks okay from an Operations perspective. We do have a few comments, but could live with the current proposed language. Note the proposed public hearing date is November 4. The following language does not reflect what the slope AOGCC inspectors are currently requiring us to do: "The mechanical integrity of an injection well must be demonstrated before injection begins, at least once every four years thereafter (except at least once every two years in the case of a slurry injection well), and * before*_** 1 of 3 10/28/2004 11:09 AM [Fwd: Re: [Fwd: AOGCC Proposed WI Lan, e for Injectors]] return'.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". I Let me know if you have any questions. Joe -----Original Message----- From: Kleppin, Daryl J I, Sent: Wednesday, September 29, 2004 1:37 PM To: Townsend, Monte A; Digert, Scott A; Denis, John R (ANC); Miller, Mike E; McMullen, John C Subject: FW: Public Notices FYI -----Original Message----- From: Jody Colombie [ mailto:j Sent: Wednesday, September 29, Subject: Public Notices dy colombie@admin.state.ak.us 2004 1:01 PM 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 of 3 10/28/2004 11:09 AM a @ `,~ ,, UIC File Review Date: June 23, 2003 Subject: Unocal N. Trading Bay Unit (NTBU) Spark Platform Well S-OS (Waste Disposal) PTD #: 169-039 ,~~ Orders: CO 69, 74, 108 (pressure maintenance-11/18/71) and 225 DIO 15 Reviewers: Tom Maunder, P.E. Initiating Action: Intent to perform MIT Review Summary-Well File 1. This well was drilled in May 1969. 13-3/8" @ 2245', w/ 1090 sx Class G w/10% gel followed by 400 sx Class G tail 9-5/8" @ 11527', 1000 sx Class G. Ran CBL with determined TOC at 8400'. 2. Rig was released 6/1/69 with the well completed as an oil producer.. 3. ARCO converted the well to an injector in December 1974. Injection into the well ceased in March 1981 according to RBDMS. 4. Conversion of the well from producer to injector was according to CO 108, issued 11/18/71, which authorized a pressure maintenance project. It appears that no Area Injection Order was issued to compliment CO 108. It is uncertain if issuing an AIO to compliment the CO was the practice in 1971. 5. The platform was "sold" to Marathon prior to the end of 1991 when Marathon proposed to SI the well. The well was SI long term effective February 25, 1992. 6. On June 9, 1998, Marathon submitted an application for underground disposal into S-O5. Disposal was planned into the original production/injection perforations and a statement is made in the application (from the application for NTBU Suspension of Operations) that "This high recovery factor (>40% OOIP) and the high watercut of wells when they were shut in indicates that NTBU (Hemlock and G) has been swept and has no economic potential." 7. The well was converted to disposal service in September 1998. 8. Marathon submitted an operations report for S-OS in early October 2001. Due to an internal oversight error, this was the hrst report submitted for the disposal project. Review Summary-DIO 15 On June 9, 1998, Marathon submitted an application for a Disposal Injection Order (DIO) to allow disposal of the produced water from 5-02 into S-O5. Marathon erroneously applied for a Class II authorization. On July 17, 1998, a hearing notice was published. DIO 15 was issued August 31, 1998. The ordered specified in Rule 4 that the average daily disposal rate could not exceed 1000 bbUday with the maximum disposal pressure not to exceed 3000 psi. M:\UIC File Reviews\030623-ntbuS-S-file-review.doc ^'vy~ / . ~ 4. In the course of their application, Marathon demonstrated mechanical integrity in June .1998. 5. According to the available records, it does not appear that there has been an MIT since the original test in June 1998. Since the Marathon has not injected any fluids since June 2000, this is not a serious deficiency. Conclusion 1. NTBU S-OS appears to be in compliance with the applicable conservation orders and disposal injection order 15. Recommendation 1. A standard MIT should be conducted to demonstrate mechanical integrity, as proposed by Marathon. 2. Pending successful passing of the MIT, no further action is recommended or needed at this time. Tom Maunder, PE Sr. Petroleum Engineer M:\UIC File Reviews\030623-ntbuS-S-file-review.doc #5 ) Alas~~gion Dome:::(jc Production 'M.') Marathon ',MARATHON Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 June 26,1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Mr. Blair Wondzell RE: MIT for Well S-5 NTBU, Spark Platform Dear Mr. Wondzell: Attached please find documentation of a mechanical integrity test performed on the casing-tubing annulus of Well 8-5 on June 12, 1998. A request for an injection permit for Well 8-5 is currently pending before the AOGCC. In the interim, a mechanical integrety test was performed by Marathon Oil Company employee, Wayne E. Cissell, in accordance with the requirements of 20 MC 25.412. The test was conducted by applying 2550 psi to the casing-tubing annulus through a wellhead valve. The valve was then closed and the downstream pressure relieved. The pressure on the annulus was monitored for 45 minutes, and the results recorded on a chart recorder (original chart attached). No leak-off occurred during the test. The test chart is signed by Mr. Cissell, attesting to its authenticity. We believe that you will find that this test meets the requirements for proving mechanical integrety for an injection well. Because the Spark Platform is an unmanned facility with no regularly scheduled helicopter flights, we request that you accept these test results to avoid unnecessary expenditures and delay in injection permitting. However, we are willing to repeat the test on our next trip to the platform for maintenancelinspection, providing 24-hour notice to AOGCC if you wish the opportunity to witness the procedures. S.. in....c. erE~.IY'~. ' P / I /--:__....>- ' .I .~ , , , . ,<> ,.. V Lyndon C. Ibele ~1ì """, .¡,." ~~' ~ "\ ,~ ~- f"'¡... t·.t ~"" ~ ~..., ~ '} \"" 1 t Ò \" I:.~ "'-.. ~~, ~ \1 t" ~~..r I, \,.. v' r-<,' '1 q q Q .(~. ,I"" '. \." "~yo (") r, r'l"'Î" """rr'I\'\i~;s\or: AJaSK3l\!\ (J' u3S '...;l:¡'~. \.)\1.II.,,,~· . Attachment cc: DR Erwin JG Eller we Barron 55 well file A subsidiary of USX Corporation Environmentally aware for the long run. #4 , I' .. ..~ ) Alas¡ )eg¡on Domestic Production 'M.) Marathon '.MARATHON Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 June 9, 1998 ORIGINtL Attn: Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE: Application for Underground Injection, Spark Platform Well S-5 Cook Inlet, Alaska RECEIVED J Ui·¡ 1 0 1998 Dear Mr. Wondzell: Alaska Oil & Gas Cons. commission Anchorage Marathon Oil Company, as Operator of the Spark Platform and gas production from the North Trading Bay Unit (NTBU), respectfully requests approval for an Underground Injection Permit for Spark Platform Well S-5. The injection permit is required for disposal of produced liquids associated with natural gas production from the North Trading Bay Unit. A reliable, high capacity disposal well is necessary in order to assure continued recovery of gas reserves from NTBU. Well S-5, the proposed disposal well, is a shut-in waterflood injection well completed in the Hemlock and G formation of the North Trading Bay Unit. Injection into Well S-5 was discontinued in 1981 when the NTBU waterflood was terminated due to poor economics. The NTBU Hemlock and G oil production was terminated in 1992. Well S-5 was originally drilled and completed by ARCOas a Hemlock and G oil producer in 1969. In 1974, ARCO recompleted the well as a waterflood injector into the Hemlock and G formations with 356 feet of perforations in the gross interval from 10,826-11,397 feet MD, 9,626-10,116 feet 1VD (see wellbore diagram in attachments). Cumulative injection in Well S-5 was 13.7 MMSTBW. Marathon received permission from the State of Alaska Department of Natural Resources to suspend Hemlock and G oil production from the North Trading Bay Unit in 1992. Cumulative oil recovery at NTBU exceeded 40% of original oil in place (OOIP) at the time of shut-in. Marathon's May 22, 1992 application for NTBU Suspension of Operations states: "This high recovery factor and the high watercut of wells when they were shut-in indicates that NTBU (Hemlock and G) has been swept and has no economic potentiaL" A subsidiary of USX Corporation Environmentally aware for the long run. 1 I ,) Application for Underground Injection, Spark Platform Well S-5 June 9, 1998 Page 2 ') Spark Well S-2rd was recompleted to develop NTBU gas reserves and continuous gas production was established in December 1996 upon installation of gas handling facilities on the Spark Platform. NTBU gas production is from the Basal F and Upper G formations at depths of 9,580-10,090 feet MD (8,722-9,087 feet TVD). Recent gas production has been accompanied by increased volumes of produced water. Remedial activities to shut-off the source of water production exhibit poor economics and have high risk of failure. Meanwhile, the injection pressure into the existing permitted disposal well (S-4) is climbing and approaching the limit of the available injection pressure. Thus, an injection permit is requested for Well S-5 to provide a second wellbore for water disposal and allow for continued recovery of NTBU gas reserves. Attached are a Request for Underground Disposal (Sundry Application, Form 10-403), and required information per 20 AAC 25.252( c). It is understood that approval of Well S-5 for injection service is contingent upon passage of a mechanical integrity test (MIT) per requirements of 20 AAC 25.412. Sincerely, MARATHON OIL COMPANY If rØt!t I: C 'pIleI' Gary Eller Production Engineer JGE/LCl/kz:O:\ELLER\SPARK\DISPOSAL.WPD Attachments cc: W. C. Barron L. C. Ibele CEF Spark Well S-5 , . I .) MARATHON OIL COMPANY NORTH TRADING BAY UNIT SPARK PLATFORM, WELL S-5 Request for Underground Disposal Applicant: Marathon Oil Company Attn: Gary Eller P.O. Box 196168 Anchorage, AK 99519-6168 Telephone: (907)581-5311 Facsimile: (907)564-6489 Date: June 9, 1998 Required Information as per 20 AAC 25.252(c): (1) Well Vicinity Plat - There are five we II bores within a one-quarter mile radius of Well S-5 at the depth of the proposed injection interval: S-2, S-2rd, S-7, S-7rd, and TS-8 (see attached map). The S-2 wellbore was plugged back with cement and replaced by S-2rd. The S2rd wellbore was plugged back with cement across the Hemlock and G and is presently an active gas producer in the Upper G and Basal F sands. The S-7 wellbore was plugged back with cement and replaced by S-7rd. The S-7rd wellbore was shut-in and secured in 1976 by filling the wellbore with kill-weight mud. Well TS-8 (Spurr Platform, operated by Marathon) was plugged back with cement to a depth above the Hemlock and G formations when the Spurr Platform was shut in 1992. (2) List of Operators & Surface Owners - Marathon Oil Company is the only operator in the vicinity of well S-5. There are no other operators within one-quarter mile of the Spark platform or the bottomhole location of the S-5 well injection interval. Marathon's mailing address is given above. The Spark platform is located within waters of the Cook Inlet owned by the State of Alaska (surface owner). There are no other surface owners within a one-quarter mile radius. (3) Affidavit - No affidavit is necessary since there are no adjacent operators or surface owners within one-quarter mile of the Spark Platform or the bottomhole location of Well S-5. (4) Geologic Data - The North Trading Bay Field was discovered in 1967 as a result of drilling the ARCO Trading Bay State #1. The trap for the hydrocarbons in the field is a slightly, westerly asymmetric anticline. Oil was produced from Hemlock and lower "G" formation (S-5: 10,800-11,425' MD). Gas is produced from upper "G" sandstones above the oil (S-5: 9,800-10,400' MD) in the S-2rd wellbore. The oil interval and the gas interval are separated by 400 feet of sandstone, shale and coal (S-5: 10,400-10,800' MD). Communication between the oil and gas intervals -1- , ) NORTH TRADING BAY UNIT SPARK PLATFORM, WELL 5-5 Request for Underground Disposal does not occur and is not expected to occur as a result of water injection (see cement bond log and fracture propagation analysis). Beneath the Hemlock lie coals, shales and sandstones of the West Foreland formation (S-5: 1,425'-TD MD). The oil interval is characterized by Hemlock sandstones that have few interbedded shale and coal beds. The Hemlock is in excess of 350 feet thick. The Hemlock sandstones are most likely in communication across the field, based on the common original oil/ water contact. The lower "G," oil bearing sandstones are each separated by shale and coal layers. Their communication is probably more complicated, however, the water flood of these reservoirs effectively swept the individual sandstones. The "G" oil interval is 200 feet thick in total. These sandstones may each have a different oil/ water contact. In both cases, the Hemlock and G oil recovery using water flood was sufficient to recover over 40°/Ó (20.5 MMBO) of the original oil in place. The Hemlock and G formation is sufficiently depleted to accept large water volumes for disposal purposes. The proposed injection interval is the existing perforated interval in the Hemlock and G formation between the depths of 1 0,826-11,397' M D (9,626-1 0, 116' TVD ) in the S-5 wellbore. (5) Logs - A copy of the cement bond log for well S-5 dated 5/30/69 is attached. Also attached is a spinner/temperature injection profile dated 12/16/74. (6) Casing Program - The following casing is set in well S-5: a) 13-3/8",61 ppf, K-55 from 0' to 2,245', cemented with 1,090 sacks b) 9-5/8, 47 ppf, BTC, N-80 & P-110 from 0' to 11,527', cemented with 1,000 sacks. The 9-5/8", N-80 casing is rated to a burst of 6,870 psi. (7) Fluid Description - The fluids to be injected in well S-5 are primarily produced water and associated natural gas condensates from well S-2rd, which is currently producing less than 200 BPD total liquids. The requested maximum permitted injection rate into Well S-5 is 1,000 BPD. Condensate production is not economic to recover at any time in the foreseeable future. The facility is unmanned, and is equipped only with two-phase separation, and has no active liquids pipeline to shore. (8) Injection Pressure - The last recorded injection test on well S-5 was in April 1976, when 10,380 BWPD was injected down the tubing with 1800 psig injection pressure. The average anticipated injection pressure is less than 1,000 psig. The requested maximum permitted injection pressure is 3,000 psig. The current shut-in tubing pressure is "zero." - -2- , . " NORTH TRADING SAY UNIT SPARK PLATFORM, WELL 8-5 Request for Underground Disposal (9) Fracture Propagation - A fracture propagation analysis was performed at the conditions of 1000 BPD at 1000 psi surface injection pressure. Results indicate that though a fracture may be initiated under these conditions, there would be little or no growth due to fluid leakoff. A similar analysis performed in support of the injection permit application for Well S-4 indicates that with injection rates as high as 28,000 BPD at 1000 psi, upward growth of the fra,cture would be limited to about 300'. Under the planned injection conditions, fracture growth would be impossible to achieve. (See attached letters.) (10) Water Analysis - The most recent available analysis for the produced water from well S-2rd is attached. Our lab is currently analyzing a water sample from well S-2rd that was gathered on June 2, 1998, and Marathon will provide this analysis to AOGCC immediately upon availability. (11) Freshwater Exemption - Freshwater aquifers in the Trading Bay Field have been exempted by the EPA as per 40 CFR 147.102(b)(2)(iv). -3- \) O:\EXCEL\SUNDRY\AOGCC\AOGCC01.XLS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 11562 feet Plugs (measured) 1 0259 feet 11439 feet Junk (measured) 11429' Baker "D" packer 1 0152 feet Size Cemented Measured Depth True Vertical Depth 13-3/8" 1 090 sx 2245 2073 9-5/8" 1000sx 11527 10127 measured 10826' - 876',10926' - 946',10974' - 998', 11026' - 056',11064' - 074',11082' -136',11150' -180',11210' - 240',11255' - 305',11329' - 349',11357' - 397' true vertical 9626' - 668', 9711' - 728', 9752' - 772', 9796' - 837', 9829' - 837', 9844' - 891', 9903' - 928', 9954' - 980', 9993' - 1 0036', 1 0057' - 074', 1 0081' - 116' Tubing (size, grade, and measured depth) 4-1/2",12.6#, N-80, buttress @ 11337' Packers and SSSV (type and measured depth) Baker "F" perm. packers @ 10796' & 11069' Cameo TRB-6 SCSSV @ 261' Description Summary of Proposal 1. Type of Request: Abandon Alter Casing Change Approved Program 2. Name of Operator MARATHON Oil COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 2608' FSl, 2488' FEL, See 26-10N-13W, S.M. At top of Productive Interval 1514' FSl, 786' FWL, See 35-10N-13W, S.M. At Effective Depth Suspend Repair Well Pull Tubing 5. Type of Well: Development Exploratory Stratigraphic Service X Operation Shutdown Plugging Variance I Request for Underground Disposal At Total Depth 1839' FSL, 598' FWL, See 35-1 ON-13W, S.M. 12. Present Well Condition Summary Total Depth: measured true vertical Effective Depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: Length 2245 11527 13. Attachments Detailed Operations Program 14. Estimated Date for Commencing Operation 6/21/98 16. If Proposal was Verbally Approved 15. Status of Well Classification as: Oil Gas Suspended water injection well Suspended L Name of Approver Date Approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Production Engineer FOR COMMISSION USE ONLY Conditions of Approval: Notify Commission so representative may witness Plug Integrity BOP Test Location Clearance Mechanical Integrity Test Subsequent Form Required 10- Approved by Order of the Commission Form 10-403 Rev. 06/15/88 Re-enter Suspended Well Time Extension Stimulate Perforate Other X 6. Datum Elevation (DF or KB) 115' KB above MSl 7. Unit or Property Name North Trading Bay Unit 8. Well Number S-5 9. Permit Number ~ '~ ~C¡- S1 . 10. API Number 50- 133-20186 11. Field/Pool Hemlock & G-zone feet BOP Sketch Date 2-Jun-98 Approval No. Commissioner Date Submit in Triplicate ~'.~ VJ.....\\ c..()......9\~~Ñ .~~~~~~ S~...~I ~~.~.\). ;:( "'t..~\' ~-, .... ~.'2. ~-1 Cër-4- ~S \\- \ \\-1. \-\-3 "n-lr ~"'-... ~ \.. 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L~ "'\ 't:) \ \ S "'~ · ,Jun, 4, ,1998 3:37PM U!'WCAL CORP, ~ÖI1Í1eld~ sJlcëi .. . 500 W, Interna110nal Airport Road Anchorage~ Alalka 99518·1199 Phone: (907)-561-1324 Fax: (Ð07)·562-39Oe Marathon Oil Company 3201 "C· Street AnchorageAK 99S19~1eB ~~o,7809 p. ) 4 June~ 199·8 Attention: Mr. Gary Eller, AdvanCed Production Engineer Mr. Lyndon Ibele, Reservoir Engineer Re: Sp.rk Platform, Well S",S; Fracture Propagation Dam Dear Sirs, The results from our evalultion on Well S...5 are dÎscul..d below. Well Infq,rmation: BHSP Mid-Perf Depth Anticip.ted Maximum Injection Rate Anticipated Maximum I njection Pressure Casing 3000 psi 10.912 ft 11 t212 ft 100.0 bpd (0.69 bpm) 1000 psi 4 %", 12.8 IbJft~ N·80 With the data given, worst case, even though a fracture may be initiated Bit a surface injection pressure above 858 pe¡. the low injection rete would ceu.. the fluid to be almo.t immediately lost to leakoff through the fracture face, and any fracture created would close with little or no growth. Attached, please find a copy of a letter regarding a similar situation concerning Well S-4 that was prepared for Mr. Mike Olson last year. Unfortunately, we do not have a copy of the referenced plot in our files. This welt was also deemed to create no hazard of fracture propagation or growth upward to the surface. Should you require any further information, or have any questions or commentst please do not helitate to contact the undersigned at 263-7800. " ~L,~t( J Rob MontgoMery OFS Salea Engineer, AI.aka -....-....---,..-..-.......,... . Jun, 4,,1998 3:38DM . U~WCAL CORP, ) 11)0,7809 P.2 ) Ju~y 10, 1997 To: Mike Olson MAAA THON 011 Comþs.ny From: Fred Peters Schlumberger Dowell Ref: Potentl.1 of Hydtaullc Ft'acturing vi. Brine Disposal Opetatlon$ in Well 8..4, North 'Tr.dlng Bay FI81d DoweWs hydraulic fracturing simulation software. FracCADEtm ~ was used to evaluate the potential of fracturing to surface via disposal operations in 'live I I 5..4· of North Trading Bay Field. To assume worst-case conditions, streSS$S were cons¡dered to be normal from surface to the bottom of the 13 3/8" surface casing, I.e. the shallowest possible point of injection Into the open hole formations If the surface càslng 's adequately cemented" Coals and shale above the surface casing were included, since both types of formation are good fracture barriers. Actual stresses used can be seen on the attached plot Under anticipated Injection c·ondltlons of 300 barrels of brine per day and 1000 psi surface Injection pressure, FnlcCADEtm Indicates no hy'draullc fracture can be established. While adequate downhole pressure may be reached to Initiate a fracture, the low injection rate would almost immediatety be lost to leekoff through the fracture 'faces, and the fracture would ctose with little or no areal growth. Given the tong Interval of formation open behind production casing and below surface casing, it is impossible to determine with any accuracy how much brine could be Injected before any hydraulic fracture created would be sustained end experience even minimal growth. To further evaluate the worst-case scenario, a conventional fracturing procedure was simulated using the normal stresses discussed above. The results are defined on the attached plot. Even at an injectìon rate nearly 100 time$ greeter than that planned for disposal (20 BF'M~ or 28,800 barrels per day), the upward growth of the fracture Is lImited to about 300 feet above the surface casing shoe by the first thick shale found there. Under planned injection conditions, even this moderate upward growth wouid be impossible to achieve. Based on these studi$$, it is t::onfirmed that the planned dlsposat operations create no hazard of fracturing upward to the surface, assuming the surface casing shoe's properly cemented. Fred Peters Area engineer, A1aska ....,""'~~".\I!\".'f':';'l"':-:ro;.,'...,~....".. ·,M\41I"".,'n"......,-_ ..,. ..,....., ,....."'"...,~.____..~.." "'"'.'-'~"."'---'-""'''''''''' "".....,".. -..."...." · ). ) ... .. CT&E Environmental Services Inc. ,....,....,..I..,..III..,..IIIIIIIIIIIIIIII~ CT&E Ref.# Client Name Project N ame/ # Client Sample ID Matrix Ordered By PWSID 970500001 Marathon Oil Co AK Region Routine Oilfield H20 Analysis S-2rd Produced Water Sample Other Liquids Client PO# Printed Date/Time 02/12/97 15: 17 Collected Date/Time 02/03/97 00:00 Received Date/Time 02/05/97 16:30 Technical Director: Stephen C. Ede Released BY"~~" ~ _..,.¡I' ...--- ~-...-,- r ~",,~ Sample Remarks: Sample was analyzed undigested for potassium. Allowable Prep Analysis Parameter Results PQL Uni ts Method Limits Date Date Init Potassium 294 50.0 mg/L SW846-7610 02/12/97 02/12/97 BJS Barium 1.59 0.200 mg/L EPA 200.7 02/11/97 EMM Calcium 5.27 2.00 mg/L EPA 200.7 02/11/97 EMM Iron 5.45 0.500 mg/L EPA 200.7 02/11/97 EMM Magnesium 3.35 2.00 mg/L EPA 200.7 02/11/97 EMM sodium 108 5.00 mg/L EPA 200.7 02/11/97 EMM Strontium 1.09 0.300 mg/L EPA 200.7 02/ 11 /97 EMM Aluminum 1 . 00 U 1.00 mg/L EPA 200.7 02/11/97 EMM Manganese 0.200 U 0.200 mg/L EPA 200.7 02/11/97 EMM pH 8.38 pH units EPA 150.1 02/06/97 EMB Alkalinity as CaC03 124 1. 00 mg/L SM18 2320B 02/07/97 EMB Bicarbonate Alkalinity 105 1.00 mg/L SM18 2320B 02/07/97 EMB Carbonate Alkalinity 19.0 1.00 mg/L SM18 2320B 02/07/97 EMB Conductivity 702 0.100 rrmhos/cm SM 2510B 02/06/97 EMB 14.2 ohm-meters Chloride 240 2.00 mg/L EPA 300.0 02/ 11/97 SPM sulfate 2.8 0.200 mg/L EPA 300.0 02/11/97 SPM #3 ALASKA INDIVIDUAL WELL PRODUCTION AS OF OS/26/98 WELL-NAME: N TRADING BAY UNIT S-05 API: 733-20186-00 LEASE: ADLOO18776 OPERATOR: MARATHON OIL CO FIELD/POOL: TRADING BAY, G-NE/HEMLOCK-NE SALES CD - 82 ACCT GRP - 004 FINAL STATUS: DEV 1-0IL CURRENT STATUS: SER SI ** OIL PRODUCTION ** 1969 JAR FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT DAYS 30 16 23 30 31 30 31 OIL 32,799 8,191 57,280 91,804 95,294 74,056 76,562 WTR 34,666 12,222 664 452 325 668 1,057 GAS 7,217 2,747 13,516 22,181 22,680 18,169 17,036 1969 TOTALS OIL 435,986 WATER 50,054 GAS 103,546 CUM OIL 435,986 CUM WATER 50,054 CUM GAS 103,546 1970 JAN FEB MAR APR MAY JUN. JUL AUG SEP OCT NOV DEC '-'" METH GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT DAYS 31 28 31 30 31 30 31 31 30 31 30 31 OIL 71,662 61,440 55,915 55,938 50,730 44,993 37,542 33,072 35,052 33,124 26,457 23,100 _F WTR 1,656 3,714 8,727 6,255 8,955 11,528 13,634 13,114 13,920 16,117 21,776 26,342 GAS 19,669 17,137 15,217 11,124 10,972 10,741 10,639 8,855 7,957 6,214 4,242 4,366 1970 TOTALS OIL 529,025 WATER 145,738 GAS 127,133 CUM OIL 965,011 CUM WATER 195,792 CUM GAS 230,679 1971 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT DAYS 31 28 30 30 31 21 31 31 30 31 30 31 OIL 24,532 22,216 15,404 9,815 14,051 5,325 6,323 11,880 10,240 10,011 7,696 7,970 WTR 21,668 22,394 27,148 30,744 21,077 15,395 26,511 27,340 20,630 20,017 16,474 17,263 GAS 2,989 2,537 1,877 902 1,541 637 614 1,347 899 905 670 734 1971 TOTALS OIL 145,463 WATER 266,661 GAS 15,652 CUM OIL 1,110,474 CUM WATER 462,453 CUM GAS 246,331 1972 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT DAYS 31 29 31 30 31 30 31 31 30 31 30 31 OIL 8,163 9,415 12,361 13,641 20,991 23,055 24,693 27,679 26,531 25,264 21,919 21,033 WTR 27,584 26,528 28,037 27,812 33,409 29,025 29,912 32,527 29;787 29,108 29,350 31,395 GAS 721 785 1,073 1,767 3,750 4,131 4,661 5,720 5,129 5,011 5,001 5,050 1972 TOTALS OIL 234,745 WATER 354,474 GAS 42,799 CUM OIL 1,345,219 CUM WATER 816,927 CUM GAS 289,130 -" 1973 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT - DAYS 31 28 31 30 30 25 29 31 30 31 30 31 OIL 22,660 19,661 19,221 18,462 18,163 8,703 18,928 18,602 16,014 15,514 15,148 14,121 WTR 32,779 29,447 34,238 35,750 31,943 25,195 39,608 43,550 39,400 43,726 45,678 49,884 GAS 6,445 5,373 5,569 5,651 4,990 2,607 4,997 5,070 4,177 3,984 3,659 3,128 1973 TOTALS OIL 205,197 WATER 451,198 GAS 55,650 CUM OIL 1,550,416 CUM WATER 1,268,125 CUM GAS 344,780 1974 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT DAYS 31 28 31 30 31 30 31 31 30 31 30 10 OIL 14,128 12,417 13,560 11,743 10,591 9,777 9,238 7,842 6,564 6,654 5,889 1,529 WTR 51,379 44,027 52,754 46,917 52,802 49,765 57,038 47,540 40,875 41,025 41,870 13,800 GAS 2,985 2,622 2,842 2,440 2,243 2,181 2,030 1,950 1,675 1,580 1,500 400 1974 TOTALS OIL 109,932 WATER 539,792 GAS 24,448 CUM OIL 1,660,348 CUM WATER 1,807,917 CUM GAS 369,228 FIELD/POOL: TRADING BAY, G-NE/HEMLOCK-NE SALES CD - 82 ACCT GRP - 004 FINAL STATUS: DEV 1-0IL CURRENT STATUS: SER SI ** ENHANCED RECOVERY ** ALASKA INDIVIDUAL WELL PRODUCTION AS OF OS/26/98 1974 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH WTR INJT DAYS 6 OIL WTR 52,026 GAS 1974 TOTALS OIL WATER 52,026 GAS CUM OIL CUM WATER 52,026 CUM GAS 1975 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT DAYS 30 28 13 28 31 30 30 31 30 31 27 15 OIL WTR 292,757 258,903 118,847 271,480 313,805 350,298 311,994 341,650 315,178 342,742 278,792 150,881 GAS - 1975 TOTALS OIL WATER 3,347,327 GAS CUM OIL CUM WATER 3,399,353 CUM GAS 1976 JAN FEB. MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT DAYS 31 29 31 12 31 29 31 31 30 30 30 31 OIL WTR 314,453 309,073 318,666 98,535 189,130 187,639 196,160 194,182 173,552 180,326 177,034 188,153 GAS 1976 TOTALS OIL WATER 2,526,903 GAS CUM OIL CUM WATER 5,926,256 CUM GAS 1977 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT DAYS 31 26 31 30 21 23 16 10 10 29 30 6 OIL WTR 186,805 152,990 182,810 147,350 77,004 116,580 79,341 41,709 53,620 175,881 182,299 19,640 GAS 1977 TOTALS OIL WATER 1,416,029 GAS CUM OIL CUM WATER 7,342,285 CUM GAS 1978 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT DAYS 13 28 31 29 31 30 31 27 28 31 30 31 OIL -~- WTR 86,690 178,970 207,230 175,330 200,230 189,340 191,380 159,280 169,810 191,910 189,420 200,052 GAS 1978 TOTALS OIL WATER 2,139,642 GAS CUM OIL CUM WATER 9,481,927 CUM GAS -' 1979 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT DAYS 31 28 30 30 31 30 31 31 30 30 30 30 OIL WTR 207,580 185,320 196,590 200,140 211,020 194,950 199,530 198,880 199,490 207,760 212,440 221,510 GAS 1979 TOTALS OIL WATER 2,435,210 GAS CUM OIL CUM WATER 11,917,137 CUM GAS 1980 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT DAYS 28 3 9 9 19 30 31 31 30 29 30 31 OIL WTR 170,790 12,406 42,740 54,590 127,370 211,570 192,130 194,920 197,780 200,750 119,280 102,420 GAS 1980 TOTALS OIL WATER 1,626,746 GAS CUM OIL CUM WATER 13,543,883 CUM GAS ALASKA INDIVIDUAL WELL PRODUCTION AS OF OS/26/98 1981 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH WTR INJT WTR INJT WTR INJT SHUT- IN SHUT - IN SHUT-IN SHUT - IN SHUT- IN SHUT-IN SHUT- IN SHUT-IN SHUT- IN DAYS 31 21 8 OIL WTR 88,949 68,975 22,720 GAS 1981 TOTALS OIL WATER 180,644 GAS CUM OIL CUM WATER 13,724,527 CUM GAS 1982 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH SHUT - IN SHUT-IN SHUT-IN SHUT- IN SHUT- IN SHUT-IN DAYS OIL W'FR GAS '"-', 1982 TOTALS OIL WATER GAS CUM OIL CUM WATER 13,724,527 CUM GAS '- - ALASKA OIL AND GAS CONSERVATION COMMISSION PETROLEUM WELL RECORD - Commission use only - OS/26/98 +------------------------------------------------------------------------+ PERMIT API WELL WELL LEASE CONFID NUMBER NUMBER NAME I NUMBER ISRT NUMBER CODE ~~=~~~~=~ ;~~;~~~~~~ ~-;~~~;-~~~-~~;-- ~=~~---- ~~~ ~~~~~~;;~ ~;;~~- +------------------------------------------------------------------------+ -~~~;-I----------::~;;~:~------------- ~~~~i-,::~~~::-------l:f~~;;l~ 129000 MARATHON OIL CO 820 COOK INLET BASIN OFF 0 +--------------------------------------------------------------------------+ FLDPOL FIELD AND POOL MULTIPLE POOLS -~~~~-/-------------~~~---------------I~~~:~~I~~~:~~/~~~:~~I~~~:~~I~~~:~~ 800158 TRADING BAY, G-NE/HEMLOCK-NE 000000 000000 000000 000000 000000 +--------------------------------------------------------------------------+ UNIT UNIT ELEVATIONS DEPTHS LSE :~~~-I-------------~~~--------------- ~~~~I~~~:I~~~~I~~~: -~~--I~~- :~~ 11456 NORTH TRADING BAY KB 115 00 11562 10259 17A +--------------------------------------------------------------------------+ SURFACE LOCATION BOTTOM HOLE LOCATION ~~~:I~~~I~~~:I~~~I~~:I:~:I-~~I~~~ ~~~:I~~~I~~~:I~~~I~~:I:~:I-~~I~~~ 2608 S 2488 E 26 10N 013W S 1839 N 0598 W 35 10N 013W S +----------------------------------------~-------------------------------+ LATITUDE LONGITUDE FOOTAGE DRILLED PERM SSSV ~~~I~~~I-~~:- ~~~I~~~I-~~:- =~I~~~:-I=~~I~~~:-I=~I~~~:- :~~:~ ~~::~ 60 55 42.00 151 31 49.00 69 11562 +------------------------------------------------------------------------+ INITIAL FINAL CURRENT REQUIREMENTS FRM SALES ~~~~I~:~:~~ ~~~~I~:~:~~ ~~~I~:~:~~ ~~:~I-~-I-~~-I~:~~~ :~: ~~~:~ DEV 1-0IL DEV 1-0IL SER SI 82004 +------------------------------------------------------------------------+ PERMIT PERMIT DATE DATE STATUS RECORD APPROVED ISSUED SPUDDED COMP, ETC DATE LAST UPD ~ ._~ ._/ .- ---------- ---------- ---------- ---------- ---------- ---------- 04/21/69 04/21/69 04/22/69 06/01/69 02/25/92 01/28/93 +-----------------------------------------------------------------+ #2 ') 't ') f'.2Tðu ~ - 5 ') l;b~ .. t)~~ MECHANICAL INTEGRITY REPORT' "-- 3 P U D D ATE: ' : 4l ë...z.i .b ~ RIG R E LEA S E: . obI' ~ (.... ~ OPER & FIELD tv'\A~1 r\OIÙ t\)ï ~ Ù "'TELL NUMB ER b~ .. o~9 . WELL DATA ,TD:, IlSb2. .MD.. IQ'2.5"'9 J ~*:)-ç- Cas ing : r!:>3/ß b\·' Shoe: ZZ45" MD ~~ ~ ~~ðo Liner : o..~/,^ 4.,- Shoe: HÇ2:i MD .c.~ ' . I \ z.~ _~o )Ol~~ ~ Tubl!1g: ~ /7~ P acker \\Ob~ . HD \81' ana' I., '/4" Hole Size ~ TVD; PBTD: H-4 ~~ MD JOI~2.. TVD TVD; DV: MD ·TVD TVTI j 'l'OP: HD TVD TVD Set a t \\~~i ,', I Perfs )'OßZIo to \\~91 HECRÞ.J~ICAL INTEGRITY - PART /1 Annulus Press Test: IF ; 15 min 3 0 min Comments: / MECHÞJ.'1ICÞ.~ INTEGRITY - PART 42 Cement Volumes:' Þ...mt4 Liner \00(:) S-J. Csg t40¡04)'j DV Cillt vol to cover perfs . A :.~51~ 30.-, 2..-1'.~ l~::¡'b I'f:, -4=1 - (,,~¡;:¡ -" 4 5C\ J~':~sr~ l' (wS'~z. - H'S2."1 jX'-b~C}Ç" + (US"2=1 - Joß"z'-"))(. "2b1~ -, ZA 3 sy. ~ to ..bC\qS"" Theoretical Toe 2.82..ß - . JO~z.t, -[IJOQO - 7A3J~···2b-=lb ~ 'f."J Cement Bond Log (Yes or No) ~t6 In AOGCC CBL Evaluation, zone above perfs J 19~8 -rf:.MP 5\1Q..~i File '-^L f ~ ' l'ò'" \ z' 1.4 <. 2.101 b ~"1l-r AocQ\J-A't-l:., (M-r -?\ f\O"-E:. :PE:.~~ Production Log: Type 1 Evaluation CONCLUSIONS: Part f 1 : Part : 2: M \ \ ~ ) C\JDI c...t\ ël=-J') WM 1116 (9l) ('1"-''''''('''-' ,.., n'1n #1 ,~ ) Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: North Trading Bay Unit Disposal Injection Marathon Oil Company by letter ·dated. June 9, 1998 petitioned the Commission under 20 AAC 25.252 for aninjection orderfor the underground disposal of fluids in well S-5 on the, Spark Platform, located in the North Trading Bay Unit, offshore in the Cook, Inlet basin. ' A person who may be harmed if the requested order is issued may file a written protest prior to 4:00 PM June 29, 1998, with the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska 99501, and.reque~t a hearing on the matter. If the protest is timely filed and raises a substantial 'and rriáterial iSsue crucial to the Commission's determination, a hearing on the matter will be held at. the above address at 9:00 AM on July 14, 1998, 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 June 29, 1998. If no' protest is filed, the Commission will consider the issuance of the order withòut a hearing. ' If you are a person with a disability who may need a special modification in order to comment or to attend the public hearing, please contact Diana Fleck at 279-1433 no later than July 7, 1998. ~,-----" Published June 12, 1998 AND AO 02814054 1113873 STOF0330 AO-02814954 $62.01 -) ) AFFIDAVIT OF PUBLICATION June 12, 1998 ~ '.. N,ol~i~~t~~bitf:;1~.~'):t:N· ~, O\lanCf'~~ con~'~:¡¡~·"::: .... .. .~~~I'hIS~W':"I': ;",:;\;o;í~':~1 1,'1:, I .,~,., I~ "~ 1\ \.~ '7"11 :~j:'/I'I~,I'~~1'~~~~~'~~Î',lll Re: . No~th, ::rrQdl'ri~,' 'øOy',:,'l:Init DiSPOS~I·hl.~,~ction, ':;¡'I~'i'.H<.':iJ¡. ·ÎJ;' . Marat on" 011 ~om'Po"')f: U}I letter date~ June' ,9. 1998 ·.I>etl-l tiMed the Commission,. under I 20 <AAC .2~.2'2·· for an ·,II)'.~,~tlo" order for the· '",ndergröurîddls· posol of. fluids II'! well 5-5. on I the Spark· Plqtform. located In ~';:.h~r'::~ ·;hZ~~~~~",~~~~r" ,Un It, Basin. I.;., ,:: 'c" ',,1.",,1;· \., A.' øêr!iOh'·Wñq: 'n'IoY'll;iiii '·'borm. ed ,If· :the 'rec:/I!ested\orøt!"·; Is IS$ued mdll flle·a·wrltten;·prò· test PFlort04:QO. RM Jùrie 29. 1998..· with' thlil Alaska ':Qi'land Gas Conservation Com'mlsslon, 3001 'Porcuplne, Drive, i +(I~~or. age, Alaska 99501, and rè~ïuestl a. hearlDg. on the. matter;.,I{ ;the I protest"ls, timely . flied ,;·;.·ond. raises d .Su..bsta. ntlalan~"~mpte; rial ISsuer.'PIIClol. JC! J.th~·,;SiP~ mission's ',detèr·mfnat1ðìl',·I,. a . hear!nll 6n flîê'(11ottè~ wl~'~ heltl' (It the abo"radêh'ë~, ;~r~ ~~~~o~~n~~ :J~J~h 1~'2019¡~~~~ 25;540; If 0 hearing IS to 'be' held, . InrereSTea parTies mav conflrrn tnlS bv tOiling Tne Conirr'lls,>,on S altite. (907, ~~. ~;;te~~lersJ f~reed}~fh~:~?~~~~ mission.· wll . eonslderlSsijaneé of the. order without 0. heCl~ln$if.':'· : 'If yOU .Clre a person '''YJltha dlsåbl.llty whC) may,. rlee,d" a. s¡:)eçlq I. mod Ifleatlon )n ·,griiter to c!)n:lm.entor' to· attenð,Jbe public nearing; . pläase , contact Diana fleck at· 279-1433,.: no later thah July 7, 199B:,' '~ .:, Is/David W. Johnston. , Chairman . .', ..1 '.,. I~' AO 0281405.4 ." ii " ,I ~ub.:Jun.12,'J~B·I: · STATE OF ALASKA, THIRD JUDICIAL DISTRICT. . . . E 1l a. . .t1... . Ka ufmann.. .. .. .. .. .. being first duly sworn on oath deposes and says that he/she is an advertising representative of the Anchorage Daily News, a daily newspaper. That said newspaper has been approved by the Third Judicial Court, Anchorage, Alaska, and it now and has been published in the English language continually as a daily newspaper in Anchorage, Alaska, and it is now and during all said time was printed in an office maintained at the aforesaid place of publication of said newspaper. That the annexed is a copy of an advertisement as it was published in regular issues (and not in supplemental form) of said newspaper on and that such newspaper was regu larly distributed to its subscribers during all of said period. That the full amount of the fee charged for the foregoing publication is not in excess of the rate charged private individuals. ~m Subscribed and sworn t bore me this .1.7 day Ofq.~ 99 19...... ~ /'£'rv i£ A . .. .. .. ..... '~'otar .~~ '~J the State of Alaska. Third Division. Anchorage. Alaska MY COMMISSION EXPIRES ............ ..Æ.!J..... .'?....... .)4.. ~d ð b LIBRARY OF CONGRESS STATE DOCUMENT SECTION EXCH & GIFT DIV 10 FIRST ST SE WASHINGTON DC 20540 ARENT FOX KINTNER PLOTKIN KAHN LIBRARY WASHINGTON SQ BLDG 1050 CONNECTICUT AV NW WASHINGTON DC 20036-5339 AMERICAN PETR INST STAT SECT JEFF OBERMILLER 1220 L ST NW WASHINGTON DC 20005 NY PUBLIC LIBRARY DIV E GRAND CENTRAL STATION POBOX 2221 NEW YORK NY 10163-2221 PlRA ENERGY GROUP LIBRARY 3 PARK AVENUE (34TH & PARK) NEW YORK NY 10016 ) US MIN MGMT SERV CHIEF oes STATS & INFO 381 ELDEN ST MS 4022 HERNDON VA 20170-4817 OIL DAILY CAMP WALSH 1401 NEW YORK AV NW STE 500 WASHINGTON DC 20005 ALASKA OFC OF THE GOVERNOR JOHN KATZ STE 518 444 N CAPITOL NW WASHINGTON DC 20001 OVERSEAS SHIPHOLDING GRP ECON DEPT 1114 AV OF THE AMERICAS NEW YORK NY 10036 DRI / MCGRAW HILL RANDALL NOTTINGHAM 24 HARTWELL LEXINGTON MA 02173 ) U S DEPT OF ENERGY PHYLLIS MARTIN MS EI823 1000 INDEPENDENCE SW WASHINGTON DC 20585 US GEOL SURV LIBRARY NATIONAL CTR MS 950 RESTON VA 22092 AMOCO CORP 2002A LIBRARY/INFO CTR POBOX 87703 CHICAGO IL 60680-0703 LINDA HALL LIBRARY SERIALS DEPT 5109 CHERRY ST KANSAS CITY MO 64110-2498 MURPHY E&P CO ROBERT F SAWYER POBOX 61780 NEW ORLEANS LA 70161 ) ') TECHSYS CORP BRANDY KERNS PO BOX 8485 GATHERSBURG MD 20898 SD DEPT OF ENV & NATRL RESOURCES OIL & GAS PROGRAM 2050 W MAIN STE #1 RAPID CITY SD 57702 ILLINOIS STATE GEOL SURV LIBRARY 469 NATURAL RESOURCES BLDG 615 E PEABODY DR CHAMPAIGN IL 61820 ALFRED JAMES III 107 N MARKET STE 1000 WICHITA KS 67202-1811 UNIV OF ARKANSAS SERIALS DEPT UNIV LIBRARIES FAYETTEVILLE AR 72701 ) CROSS TIMBERS OPERATIONS SUSAN LILLY 210 PARK AVE STE 2350 OKLAHOMA CITY OK 73102-5605 IOGCC POBOX 53127 OKLAHOMA CITY OK 73152-3127 CH2M HILL J DANIEL ARTHUR PE PROJ MGR 502 S MAIN 4TH FLR TULSA OK 74103-4425 BAPI RAJU 335 PINYON LN COPPELL TX 75019 US DEPT OF ENERGY ENERGY INFORMATION ADMINISTRATION MIR YOUSUFUDDIN 1999 BRYAN STREET STE 1110 DALLAS TX 75201-6801 ) DWIGHTS ENERGYDATA INC JERLENE A BRIGHT DIRECTOR PO BOX 26304 OKLAHOMA CITY OK 73126 OIL & GAS JOURNAL LAURA BELL POBOX 1260 TULSA OK 74101 R E MCMILLEN CONSULT GEOL 205 E 29TH ST TULSA OK 74114-3902 MARK S MALINOWSKY 15973 VALLEY VW FORNEY TX 75126-5852 PURVIN & GERTZ LIBRARY 1201 MAIN ST STE 2600 DALLAS TX 75202 ) DEGOLYER & MACNAUGHTON MIDCONTINENT DIVISION ONE ENERGY SQ, STE 400 4925 GREENVILLE AVE DALLAS TX 75206-4083 MOBIL OIL CORP MORRIS CRIM POBOX 290 DALLAS TX 75221 GAFFNEY, CLINE & ASSOC., INC. ENERGY ADVISORS MARGARET ALLEN 16775 ADDISON RD, STE 400 DALLAS TX 75248 GCA ENERGY ADV RICHARD N FLETCHER 16775 ADDISON RD STE 400 DALLAS TX 75248 MOBIL OIL JAMES YOREK POBOX 650232 DALLAS TX 75265-0232 JERRY SCHMIDT 4010 SILVERWOOD DR TYLER TX 75701-9339 STANDARD AMERICAN OIL CO AL GRIFFITH POBOX 370 GRANBURY TX 76048 PRITCHARD & ABBOTT BOYCE B BOLTON PE RPA 4521 S. HULEN STE 100 FT WORTH TX 76109-4948 SHELL OIL CO J F CORDARO POBOX 2463 HOUSTON TX 77001 SHELL WESTERN E&P INC K M ETZEL POBOX 576 HOUSTON TX 77001-0574 ENERGY GRAPHICS MARTY LINGNER 1600 SMITH ST, STE 4900 HOUSTON TX 77002 PURVIN & GERTZ INC LIBRARY 2150 TEXAS COMMERCE TWR 600 TRAVIS ST HOUSTON TX 77002-2979 CHEVRON PAUL WALKER 1301 MCKINNEY RM 1750 HOUSTON TX 77010 OIL & GAS JOURNAL BOB WILLIAMS 1700 W LOOP SOUTH STE 1000 HOUSTON TX 77027 MOBIL OIL N H SMITH 12450 GREENSPOINT DR HOUSTON TX 77060-1991 ) ') H J GRUY ATTN: ROBERT RASOR 1200 SMITH STREET STE 3040 HOUSTON TX 77002 RAY TYSON 1617 FANNIN ST APT 2015 HOUSTON TX 77002-7639 BONNER & MOORE LIBRARY H20 2727 ALLEN PKWY STE 1200 HOUSTON TX 77019 PETRAL CONSULTING CO DANIEL L LIPPE 9800 RICHMOND STE 505 HOUSTON TX 77042 MARK ALEXANDER 7502 ALCOMITA HOUSTON TX 77083 ) MARATHON OIL CO GEORGE ROTHSCHILD JR RM 2537 POBOX 4813 HOUSTON TX 77210 UNOCAL REVENUE ACCOUNTING POBOX 4531 HOUSTON TX 77210-4531 EXXON EXPLOR CO LAND/REGULATORY AFFAIRS RM 301 POBOX 4778 HOUSTON TX 77210-4778 EXXON EXPLORATION CO. T E ALFORD POBOX 4778 HOUSTON TX 77210-4778 CHEVRON USA PROD CO ALASKA DIVISION ATTN: CORRY WOOLINGTON POBOX 1635 HOUSTON TX 77251 PETR INFO DAVID PHILLIPS POBOX 1702 HOUSTON TX 77251-1702 PHILLIPS PETR CO ALASKA LAND MGR POBOX 1967 HOUSTON TX 77251-1967 UNION TEXAS PETR ALASKA W ALLEN HUCKABAY POBOX 2120 HOUSTON TX 77252 WORLD OIL MARK TEEL ENGR ED POBOX 2608 HOUSTON TX 77252 UNION TEXAS PETR ALASKA CORP MANAGER-WORLDWIDE BUSINESS DEVELOP. STEVEN R FLY POBOX 2120 HOUSTON TX 77252-2120 UNION TEXAS PETROLEUM TECHNICAL SERVICES JIM E. STEPINSKI, MANAGER POBOX 2120 HOUSTON TX 77252-2120 EXXON CO USA G T THERIOT RM 3052 POBOX 2180 HOUSTON TX 77252-2180 PENNZOIL E&P WILL D MCCROCKLIN POBOX 2967 HOUSTON TX 77252-2967 MARATHON MS. NORMA L. 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