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Home My WebLink AboutAIO 006 INDEX AREA INJECTION ORDER NO. 6 INDEX AREA INJECTION ORDER NO. 6 Granite Point Field Middle Kenai Oil Pool 1. July 15, 1986 Amoco’s application for injection order for Granite Pointe Field, Platforms Anna and Bruce 2. July 31, 1986 Notice of Public Hearing and Affidavit of Publication 3. August 29, 1986 Amoco’s supplemental data on waste disposal horizons 4. September 30, 1986 Amoco’s testing schedule for mechanical integrity 5. October 6, 1986 Amoco’s testing schedule for mechanical integrity 6. November 4, 1986 US EPA’s letter re: termination of EPA rule authorization for injection wells 7. January 11, 1990 Letter from Amoco re: amendment to Rule 3 of AIO 6 (AIO 6.002) 8. September 2003 Unocal’s injection report compliance 9. September 27, 2004 Proposals to amend underground injection orders to incorporate consistent language addressing the mechanical integrity of wells 10. January 14, 2005 Unocal’s request for administrative approval conversion to injector Anna Platform well No 5 (AIO 6.003) 11. February 9, 2005 Unocal’s request for administrative approval conversion to injector Anna Platform well No 25 (AIO 6.004) 12. February 17, 2005 Unocal’s request for administrative approval conversion to injector Anna Platform well No 37 (AIO 6.005) 13. February 16, 2005 Unocal’s request for administrative approval conversion to injector Anna Platform well No 32RD (AIO 6.006) 14. February 17, 2005 Unocal’s request for administrative approval conversion to injector Anna Platform well No 38 (AIO 6.007) 15. February 25, 2005 Unocal’s request for administrative approval conversion to injector Anna Platform well No 19 (AIO 6.008) 16. February 25, 2005 Unocal’s request for administrative approval conversion to injector Anna Platform well No 21 (AIO 6.009) 17. March 20, 2007 Email from AOGCC to Chevron re: Anna well No. 5 MIT 18. August 9, 2007 Memo and subsequent email re: fluid injection for EOR 19. December 26, 2007 Email re: well with questions on determining the anniversary dates for compliance temp surveys 20. January 30, 2008 Chevron’s request to cancel AIO 6.6 21. February 7, 2008 Email re: Anna well No 5 administrative approval AIO 6.003 clarification 22. March 24, 2009 Chevron’s request for revised anniversary date for injector temperature surveys (AIO 6.003 Revised, AIO 6.004 Revised, AIO 6.007 Revised, AIO 6.008 Revised, and AIO 6.009 Revised) 23. October 19, 2009 Email re: Anna Platform MUCI-3 integrity failure and plan forward 24. November 5, 2009 Unocal’s request to continue injecting non-hazardous Class II fluids into Granite Point State 18742 well MUCI-3 (AIO 6.010) 25. January 14, 2010 Unocal’s submittal of temperature overlays for AIO 6.003 and AIO 6.008 26. March 1, 2012 Hilcorp’s request to permanently amend compliance anniversary date (AIO 6.007 Amended) 27. January 18, 2013 Hilcorp’s request for administrative approval to allow produced water injection into well Br-5RD-86 (AIO 6.011) 28. -------------------- Emails 29. September 20, 2013 Administrative approval to add sanitary waste to the EOR fluids at McArthur River field (AIO 6.012) 30. October 1, 2013 Email re: sanitary waste to Cook Inlet platforms 31. January 29, 2014 Hilcorp’s request to cancel AIO 6.011 (AIO 6.011 Cancellation) 32. -------------------- Emails between Hilcorp and AOGCC re: request for administrative approval to allow Granite Point State 18742 13RD to be online in water only injection service with a known tubing by inner annulus communication (AIO 6.013) 33. -------------------- Emails between Hilcorp and AOGCC re: request to amend the administrative approval to allow Granite Point State 18742 13RD to be online in water only injection service with a known tubing by inner annulus communication (AIO 6.013 Amended) 34. October 17, 2018 AA Granite Point ST 18742 (Amended and Second Amended AIO 6.013) 35. December 19, 2023 Hilcorp request removal of commitment (AIO 6.013 amended) ORDERS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: THE REQUEST OF AMOCO ) Area Injection Order No. 6 PRODUCTION COMPANY for an ) Area Injection Order for ) Nothern Portion of the portion of the Granite ) Granite Point Field Point Field developed by ) Anna and Bruce Platforms ) September 4, 1986 IT APPEARING THAT: 1. Amoco Production Company requested the Alaska Oil and Gas Conservation Commission to issue an Area Injection Order permitting the underground injection of fluids within a portion of the Granite Point Field for pur- poses of enhanced hydrocarbon recovery and fluid disposal. 2. Notice of an opportunity for a public hearing on August 30, 1986, was published in the Anchorage Daily News on July 31, 1986. 3. Neither a protest nor a request for a public hearing was timely filed. Accordingly the Commission will, in its discretion, issue an order without a public hear- ing. FINDINGS: 1. An order permitting the underground injection of fluids on an area basis, rather than for each injection well individually, provides for efficiencies in the adminis- tration and surveillance of underground fluid injection operations. 20 AAC 25.460 provides the Commission with the authority to issue an order governing underground injection operations on an area basis. 2. The portion of the Granite Point Field developed by Amoco's platforms Anna and Bruce constitutes a compact "project area" which can readily be described by governmental subdivisions. Amoco is the sole operator of this Project Area. l 40 Area Injection Order No. 6 Page 2 September 4, 1986 3. The Project Area encompasses approximately the northern two-thirds (2/3) of the Granite Point Field, Middle Kenai Oil Pool. The Project Area includes all existing injection wells and injection well sites planned for enhanced recovery of oil from this portion of the Middle Kenai Oil Pool. The Project Area also includes all well sites planned for disposal by injection into shallower Tertiary strata of oil field waste fluids which may develop from the operation of this portion of the field. 4. The portion of aquifers beneath Cook Inlet described by a 1/4 mile area beyond and lying directly below the Granite Point Field are exempted for Class II injection activities by 40 CFR 147.102(b)(2)(B) and 20 AAC 25.440(c). 5. Less stringent requirements for well construction, operation, monitoring, and reporting of injection operations may be more appropriate than would be required when injection occurs into, through or above portions of aquifers not exempted. 6. The vertical limits of injection strata and confining formations may be defined in the Mobil Granite Point well No. 1. 7. The strata into which fluids are to be injected will accept fluids at injection pressures which are less than the fracture pressure of the injection strata and their confining formations. 8. Statewide regulations and conservation orders govern field operations except as modified by this order. 9. To ensure that fluids injected are confined to in- jection strata, the mechanical integrity of injection wells should be demonstrated periodically and monitored routinely for disclosure of possible abnormalities in operating conditions. 10. Injection wells existing on the date of this order were constructed and completed in accordance with regu- lations which conform to the requirement of 20 AAC 25.412. w r,p�,,, 46 Area ti n In a Per � c o No. 6 Page 3 September 4, 1986 NOW, THEREFORE, IT IS ORDERED THAT the rules hereinafter set forth govern Class II underground injection operations in the following described area referred to in this order as the affect- ed area: SEWARD MERIDIAN T10N R11W Sections 5, 6, 7, and 8. T10N R12W Sections 1 and 12. T11N R11W Sections 29, 30, 31 and 32. T11N R12W E 2 NE 4, SE ,, of Section 25, E 2 of Section 35, and all of Section 36. Rule 1 Authorized Injection Strata for Enhanced Recovery Within the affected area, non -hazardous fluids may be injected for purposes of pressure maintenance and enhanced oil recovery into strata defined as those strata which correlate with the strata found in the Mobil Granite Point well No. 1 between the measured depths of 7,725 feet and 10,800 feet. Rule 2 Authorized Injection Strata for Disposal Within the affected area, non -hazardous oil field fluids may be injected for the purpose of fluid disposal into strata defined as those strata which correlate with the strata found in the Mobil Granite Point well No. 1 between the measured depths of 5941 feet and 6220 feet. Rule 3 Fluid Injection Wells The underground injection of fluids must be: 1) through a new well that has been permitted for drilling as a service well for injection in conformance with 20 AAC 25.005; 2) through an existing well that has been approved for conversion to a service well for injection in conformance with 20 AAC 25.280; or 3) through a well that existed as a service well for injection purposes on the date of this order. Area n ecti In'0r Injection de No. 6 Page 4 September 4, 1986 Rule 4 Monitoring the Tubing/Casing Annulus Pressures The tubing/casing annulus pressure of each injection well must be checked weekly to ensure there is no leakage and that it does not exceed a pressure that will subject the casing to a hoop stress greater than 70% of the casing's minimum yield strength. Rule 5 Reporting the Tubing/Casing Annulus Pressure Variations Tubing/casing annulus pressure variations between consecutive observations need not be reported to the Commission. Rule 6 Demonstration of Tubing/Casing Annulus Mechanical Integrity A schedule must be developed and coordinated with the Commission which ensures that the tubing/casing annulus for each injection well is pressure tested prior to initiating injection and at least once every four years thereafter. A test surface pressure of 1500 psi or 0.25 psi/ft multiplied by the vertical depth of the packer, which ever is greater, but not to exceed a hoop stress greater than 70% of the casing's minimum yield strength, must be held for 30 minutes with no more than a 10 percent decline. The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests. Rule 7 Well Integrity Failure Whenever operating pressure observations or pressure tests indicate pressure communication or leakage of any casing, tubing or packer, the operator must immediately cease injection, notify the Commission, and obtain approval for corrective action. Rule 8 Plugging and Abandonment of Fluid Injection Wells An injection well located within the affected area must not be plugged or abandoned unless approved by the Commission in accor- dance with 20 AAC 25.105. Area Injection *Order No. 6 41 Page 5 September 4, 1986 Rule 9 Administrative Relief Upon request, the Commission may administratively amend any rule stated above as long as the operator demonstrates to the Com- mission's satisfaction that sound engineering practices are maintained and the amendment will not result in an increased risk of fluid movement into an underground source of drinking water. DONE at Anchorage, Alaska and dated September 4, 1986. Alaska Oil & Ga )# iu saau Conservation Commission p, ®I L Lonnie C. Smith, Commissioner Alaska Oil & Gas Conservation Commission r1oN co IN, I� W. V. Barnwell, Commissioner Alaska Oil & Gas Conservation Commission Telecopg No. (907) 276•-7542 October 28, 1986 ADMEN I S T R A T I V E APPROVAL N0. 6.1 Re: Amend Rule 7 of Area Injection Order (AIO) No. 6 Mr. W. G . Smith District Manager Amoco Production Company P. 0. Box 100779 Anchorage, AK 99510-0779 Dear Mr. Smith: The Commission has determined that Rule 7 of AIO No. 6 as set forth is unclear as to the C ission's` intent. Therefore, Rule 7 is amended to read. - Rule 7 Well Integrity Failure . Whenever operating pressure observations or pressure tests indicate pressure communication or leakage of any casing', tubing or packer, the operator must [IMMEDIATELY CEASE INJECTION,] notify the Commission on the first working day follo : the -observation, [AND] obtain Commission approval [FOR CORRECTIVE ACTION] of a glan for corrective action and vhen an USDW is not endangered,obtain ommiss n approval to continue n eet on rel , i C. V. Chatter/ton' Chairman jo13,AA AIO 6.1 SCANNEF JUL 022004 Tolecopy No. (907) 2 6-75s2 January 17, 1990 A D M I N 1 STRAT'IVL APPR0VA'L A 1 d RQ, 6,2 f Re: Amend Rule 1 and 3 of Area Injection Order {AI4} ire. 6 Mr. W. D. Ford' Regional Production Amoco Production Company P. ©. Box -800 `Denver, CO ` 80201 Dear Mr'. Ford; Due to conditions at Drift River resulting from volcanic activity at Mt, Redoubt, Cook Inlet Pipe, Line Comps y {CIPL) has.sbutdown its oil pipeline and marine terminal which handlesall crude ail produced to the western shore of Cook Inlet. The Cnivission has reviewed Area Injection Order (ATO) No. 6 and determined that it does not allow for an emergency situation such as this for Cork Inlet producers.' Pursuant to your written request of January 11, 1990 and your earlier verbal, request for amendment of AIO No.. 6 to ppr vide-- emargesncy store a of produced crude oil by injection baek into the reservoir through an existing production well, Rule 1 and are amended to .read: Rule 1 Authorised In action Strata for Enhanced RecoverZ and toraage i Within the affected area, non -hazardous fluid a may be injected, for purposes of pressure maintenance, enhanced ail recovery and storage into strata defined as those strata which corrolaate t e strata : found in the mobil Granite Point well No. 1 between` the measured depth* of 7,725 feet and 10,800 feet. SCANNED JUL 0 2 2004 t .,iMr. W. U. Ford - '2 - January 17, 1990 .. Amoco Production Company Rule 3 Fluid- Infection Wells The underground injection of fluids must be: 1? through a new well that has been permitted for drilling as a service well for injection in conformance with 20 AAC 25.0051 2) through an existing well that has been approved for conversion to a service well for injection in conformance with 20 AAC 25.2801 3) through a well that existed as a service well for inj ection .. purposes on the date of this order or; 4) on an emerenc basis thryh an existing roduction well for PMUOSOS or storms crude oil groduction from otrier ore s 'from e.sa oo Production wel.5 used for en!SMcy storage mal not neceesaril meet Me re U r®m rots of 20 AAC 25.412. SirkeArely, C. V. Chat a on ' Chairman 4 dlf/3.AA, ATO 6.2 i i i SCANNEL, JUL 0 2 20D4 • 0 ME ALASKA FRANK H. MURKOWSKI, GOVERNOR L1•iIASKA OIL AND (GAS 333 W. T" AVENUE, SUITE 100 CONSERVATION COMbIISSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL AIO 6.003 Mr. Hal Martin Reservoir Engineer Unocal Alaska P.O. Box 196247 Anchorage, AK 99519-6247 RE: Granite Point State 18742 #5 [aka Anna #5] (PTD 167-014) Request for Administrative Approval AIO 6 Dear Mr. Martin: Per Rule 9 of Area Injection Order ("AIO") 006, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants Unocal Alaska. ("Unocal")'s request for administrative approval for water injection in the subject well. AOGCC finds the following: 1. The subject well is not completed with a packer and there is no plan to workover the well to install a packer. 2. Several similarly equipped wells on Anna Platform were previously converted to service wells beginning in 2000 according to a procedure developed by Unocal and approved by the Commission. 3. In support of this application, Unocal has submitted the results of temperature logs obtained prior to initiating injection and approximately 10 weeks later. These operations were conducted according to Sundry permit 04-318. They have also submitted a graphical maximum operating pressure determination. 4. Based upon analysis of the submitted logging information, there are no tempera- ture anomalies indicated. 5. Unocal has also begun reporting injection rate and pressure information on the well. The pressure information indicates that the reservoir pressure in Anna 5 is low and insufficient to support a fluid column to surface. The successive pressure information gathered with the temperature surveys indicates that the bottomhole pressure in the vicinity of the well is increasing. 6. Examination of the well file and production history indicates that as best can be determined the well structure is sound and that 2 competent casing barriers exist to prevent the release of pressure or fluids. Mr. Hal Martin • March 29, 2005 Page 2 of 2 7. An aquifer exemption is in effect below Cook Inlet for Granite Point Field [40 CFR 147.102(b)(2)(i).] Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety. AOGCC's administrative approval to continue water injection in Granite Point State 18742 #5 [aka Anna #5] is conditioned upon the following: 1. The effect date for conversion from producer to injector is the date injection commenced according to Sundry permit 304-318, October 24, 2004. Unocal shall file form 10-404 noting the changed status of the well. 2. Injection is limited to WATER ONLY; 3. Unocal shall monitor and record wellhead pressures [T/I/O] (tubing/inner annu- lus/outer annulus) and injection rates daily; 4. Unocal shall submit to the AOGCC a monthly report of well pressures and injec- tion rates; 5. Unocal shall perform a temperature log every two years to demonstrate continued production casing integrity; 6. Unocal shall immediately shut in the well and notify the AOGCC upon any meas- urable change in well outer annulus pressure or any change in the rate/pressure re- lationship for the tubing/IA; and 7. After well shut in, AOGCC approval shall be required to restart injection. As provided in AS 31.05.080, within 20 days after written notice of this 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 rehearing. A request for rehearing is consid- ered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next workin day if the 23rd day falls on a holiday or weekend. A person may not appeal a Comm' si n decision to Superior Court unless rehearing has been requested. Alaska and dated March 29, 2005. J n I . rman �g� Off' A Daniel . Seamount, Jr. Chairman f ommissioner 91a! s, q`,, c " Citgo Petroleum Corporation Mary Jones David McCaleb PO Box 3758 XTO Energy, Inc. IHS Energy Group Tulsa, OK 74136 Cartography GEPS 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 Ft. Worth, TX 76102-6298 Houston, TX 77056 Mona Dickens Robert Gravely George Vaught, Jr. Tesoro Refining and Marketing Co. 7681 South Kit Carson Drive PO Box 13557 Supply & Distribution Littleton, CO 80122 Denver, CO 80201-3557 300 Concord Plaza Drive San Antonio, TX 78216 Jerry Hodgden Richard Neahring John Levorsen Hodgden Oil Company NRG Associates 200 North 3rd Street, #1202 408 18th Street President Boise, ID 83702 Golden, CO 80401-2433 PO Box 1655 Colorado Springs, CO 80901 Kay Munger Samuel Van Vactor Michael Parks Munger Oil Information Service, Inc Economic Insight Inc. Marple's Business Newsletter PO Box 45738 3004 SW First Ave. 117 West Mercer St, Ste 200 Los Angeles, CA 90045-0738 Portland, OR 97201 Seattle, WA 98119-3960 Mark Wedman Schlumberger David Cusato Halliburton Drilling and Measurements 200 West 34th PMB 411 6900 Arctic Blvd. 2525 Gambell Street #400 Anchorage, AK 99503 Anchorage, AK 99502 Anchorage, AK 99503 Ciri Baker Oil Tools Ivan Gillian Land Department 4730 Business Park Blvd., #44 9649 Musket Bell Cr.#5 PO Box 93330 Anchorage, AK 99503 Anchorage, AK 99507 Anchorage, AK 99503 Jill Schneider Gordon Severson Jack Hakkila US Geological Survey 3201 Westmar Cr. PO Box 190083 4200 University Dr. Anchorage, AK 99508-4336 Anchorage, AK 99519 Anchorage, AK 99508 Darwin Waldsmith James Gibbs Kenai National Wildlife Refuge PO Box 39309 PO Box 1597 Refuge Manager Ninilchick, AK 99639 Soldotna, AK 99669 PO Box 2139 Soldotna, AK 99669-2139 Penny Vadla Richard Wagner Cliff Burglin 399 West Riverview Avenue PO Box 60868 PO Box 70131 Soldotna, AK 99669-7714 Fairbanks, AK 99706 Fairbanks, AK 99707 Bernie Karl Williams Thomas North Slope Borough K&K Recycling Inc. Arctic Slope Regional Corporation PO Box 69 PO Box 58055 Land Department Barrow, AK 99723 Fairbanks, AK 99711 PO Box 129 Barrow, AK 99723 Various Administrative Approvals Subject: Various Administrative Approvals From: Jody Colombie <jody_colombie@admin.state.ak.us> Date: Wed, 30 Mar 2005 13:25:04 -0900 To: undisclosed -recipients:; BCC: Cynthia B Mciver<bren_mciver@admin.state. ak.us>, Robert E Mintz <robert_mintz@law. state.ak.us>, Christine Hansen <c.hansen@iogcc. state. ok.us>, Terrie Hubble <hubbletl@bp.com>, Sondra Stewman <StewmaSD@BP.com>, Scott & Cammy Taylor <staylor@alaska.net>, stanekj <stanekj@unocal.com>, ecolaw <ecolaw@trustees.org>, roseragsdale <roseragsdale@gci.net>, trmjrl <trmjrl@aol.com>, jbriddle <jbriddle@marathonoil.com>, shaneg <shaneg@evergreengas.com>, jdarlington <jdarlington@forestoil.com>, nelson <knelson@petroleumnews.com>, cboddy <cboddy@usibelli.com>, Mark Dalton <mark. dalton@hdrinc. com>, Shannon Donnelly <shannon.donnelly@conocophillips.com>, "Mark P. Worcester" <mark.p.worcester@conocophillips.com>, Bob <bob@inletkeeper.org>, wdv <wdv@dnc.state. ak.us>, tjr <tj r@dnr. state. ak.us>, bbritch <bbritch@alaska.net>, mjnelson <mjnelson@purvingertz.com>, Charles O'Donnell <charles.o'donnell@veco.com>, "Randy L. Skillern" <SkilleRL@BP.com>, "Deborah J. Jones" <JonesD6@BP.com>, "Paul G. Hyatt" <hyattpg@BP.com>, "Steven R. Rossberg" <RossbeRS@BP.com>, Lois <lois@inletkeeper.org>, Dan Bross <kuacnews@kuac.org>, Gordon Pospisil <PospisG@BP.com>, "Francis S. Sommer" <SommerFS@BP.com>, Mikel Schultz <Mikel.Schultz@BP.com>, "Nick W. Glover" <GloverNW@BP.com>, "Daryl J. Kleppin" <KleppiDE@BP.com>, "Janet D. Platt" <PlattJD@BP.com>, "Rosanne M. Jacobsen" <JacobsRM@BP.com>, ddonkel <ddonkel@cfl.rr.com>, Collins Mount <collins_mount@revenue. state.ak.us>, mckay <mckay@gci.net>, Barbara F Fullmer <barbara.£fullmer@conocophillips.com>, bocastwf <bocastwf@bp.com>, Charles Barker <barker@usgs.gov>, doug_schultze <doug_schultze@xtoenergy.com>, Hank Alford <hank.alford@exxonmobil.com>, Mark Kovac <yesno 1 @gci.net>, gspfoff <gspfoff@aurorapower.com>, Gregg Nady <gregg.nady@shell.com>, Fred Steece <fred.steece@state.sd.us>, rcrotty <rcrotty@ch2m.com>, jejones <jejones@aurorapower.com>, dapa <dapa@alaska.net>, jroderick <jroderick@gci.net>, eyancy <eyancy@seal-tite.net>, "James M. Ruud" <james.m.ruud@conocophillips.com>, Brit Lively <mapalaska@ak.net>, jah <j ah@dnr. state. ak.us>, Kurt E Olson <kurt_olson@legis.state.ak.us>, buonoje <buonoje@bp.com>, Mark Hanley <mark_hanley@anadarko.com>, loren_leman <loren_leman@gov.state. ak.us>, Julie Houle <julie_houle@dnr.state. ak.us>, John W Katz <jwkatz@sso.org>, Suzan J Hill <suzan_hill@dec.state.ak.us>, tablerk <tablerk@unocal.com>, Brady <brady@aoga.org>, Brian Havelock <beh@dnr.state.ak.us>, bpopp <bpopp@borough.kenai.ak.us>, Jim White <jimwhite@satx.rr.com>, "John S. Haworth" <john.s.haworth@exxonmobil.com>, marty <marty@rkindustrial.com>, ghammons <ghammons@aol.com>, rmclean <rmclean@pobox.alaska.net>, mkm7200 <mkm7200@aol.com>, Brian Gillespie <ifbmg@uaa.alaska.edu>, David L Boelens <dboelens@aurorapower.com>, Todd Durkee <TDURKEE@KMG.com>, Gary Schultz <gary_schultz@dec.state. ak.us>, Wayne Rancier <RANCIER@petro-canada.ca>, Bill Miller <Bill_Miller@xtoalaska.com>, Brandon Gagnon <bgagnon@brenalaw.com>, Paul Winslow <pmwinslow@forestoil.com>, Garry Catron <catrongr@bp.com>, Sharmaine Copeland <copelasv@bp.com>, Kristin Dirks<kristin_dirks@dnr.state. ak.us>, Kaynell Zeman <kjzeman@marathonoil.com>, John Tower <John.Tower@eia.doe. gov>, Bill Fowler <Bill_Fowler@anadarko.COM>, Vaughn Swartz <vaughn.swartz@rbccm.com>, Scott Cranswick <scott.cranswick@mms.gov>, Brad McKim <mckimbs@BP.com>, Steve Lambe 1 of 3 3/30/2005 3:10 PM IVarious Administrative Approvals <lambes@unocal.com>, jack newell <jack.newell@acsalaska.net>, James Scherr <James.Scherr@mms.gov>, david roby <David. Roby@mms. gov>, Tim Lawlor <Tim_Lawlor@ak.blm.gov>, Lynnda Kahn <Lynnda_Kahn@fws.gov>, Jerry Dethlefs <Jerry. C.Dethlefs@conocophillips. com>, Jerry Dethlefs <nl617@conocophillips.com>, crockett@aoga.org, Tamera Sheffield <sheffield@aoga.org>, Jon Goltz <Jon. Goltz@conocophillips. com>, Roger Belman <roger.belman@conocophillips.com>, Mindy Lewis <mlewis@brenalaw.com>, Harry Lampert <harry. lampert@honeywell. com> AIO5.002.pdf Content -Type: application/pdf Content -Encoding: base64 AIO6.009.pdf Content -Type: application/pdf Content -Encoding: base64 AIO6.006.pdf Content -Type: application/pdf Content -Encoding: base64 AIO6.008.pdf Content -Type: application/pdf Content -Encoding: base64 AIO6.005.pdf Content -Type: application/pdf Content -Encoding: base64 AIO 6.004.pdf Content -Type: application/pdf Content -Encoding: base64 AIO6.007.pdf Content -Type: application/pdf Content -Encoding: base64 2 of 3 3/30/2005 3:10 PM Various Administrative Approvals . . . . ! 0 AIO5.003.pdf Content -Type: application/pdf Content -Encoding: base64 AIOl 1.003.pdf Content -Type: application/pdf Content -Encoding: base64 AIO2B.03.pdf Content -Type: application/pdf Content -Encoding: base64 3 of 3/30/2005 3:10 PM _AIASKA OIL AND GAS S:;3VV 7til1WENUL, SUITE 100 ANCI-InF AOF, ALA5K4; 99501-3539 P110NE. (907) 279-1433 FAX (907) 276-7542 ADIi'IimsTRATIVE APPROVAL AI0 6,003 (Revised ADMINISTRATIVE APPROVAL AI0 6.004 (Revised) ADMINISTRATIVE APPROVAL AIO 6.007 (Revised) ADMINISTRATIVE APPROVAL AIO 6.008 (Revised) ADMINISTRATIVE APPROVAL AIO 6.009 (Revised) Mr. J. Hal Martin Optimization Engineer Union Oil Company of California PO Box 196247 Anchorage, Alaska 99519-6247 RE: Request for Administrative Approval Revision Dear Mr. Martin: Union Oil Company of California (Union) requests a permanent revision to the anniversary date for temperature surveys for water injection wells located on the Anna Platform (Granite Point Field). The Alaska Oil and Gas Conservation Commission (Commission) approves Union's request to change the anniversary date for temperature surveys in the following wells from March 29 to May 20: - Granite Pt. State 18742 Well No. 5; PTD 1670140; AIO 6.003; - Granite Pt. State 18742 Well No. 19; PTD 1680060; AIO 6.008; - Granite Pt. State 18742 Well No. 21; PTD 1760490; AIO 6.009; - Granite Pt. State 18742 Well No. 25; PTD 1680360; AIO 6.004; - Granite Pt. State 18742 Well No. 38; PTD 1880340; AIO 6.007. The Commission granted administrative approvals to Union allowing temperature surveys every 2 years in lieu of pressure tests of the tubing -casing annulus. Temperature surveys are intended to demonstrate that injected fluids are exiting the wellbore and remaining confined as required by Area Injection Order 6.000. Union argues that performing temperature surveys in May will allow warmer weather conditions to improve the slickline operations on these water injection wells. Dailly qireillance of wellhead pressures and injection rates with monthly reporting to the Commission — mandated by the administrative approvals — provide for early detection and action regarding any deterioration of well integrity that might occur during the 2-year interval between ~ • • March J I ., 2009 telxlptirature R.oarveys, Administrativc: approvals also rc(,11.1i_rt Cinior) to irrinlediately shill irl the well and notify the Commission if there is any measurable change in the wells mechanical Integrity, The Commission finds that moving the anniversary date for ter_rlperatrure surveys frol�I March 29 to May 20 will not compromise overall well integrity so as to threaten the environment or human safety; DONE at Anchorage, Alaska and dated March 31, 2009, 9/4: �-- a Z4 � � !ram Daniel T. Seamount, Jr. Cathy . Foerster Chair Commissioner RECONSIDERATION AND APPEAL NOTICE Commissioner As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the 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 tiled within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[tlhe questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Page 1 of 1 Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Thursday, April 02, 2009 9:07 AM Subject: Revised AIO 6-003; AIO 6-004, AIO 6-007; A10 6-008; AIO 6-009 (all combined on one admin approval) Attachments: aio6 revised admin approval.pdf BCC:'Aaron Gluzman'; caunderwood@marathonoil.com; 'Dale Hoffman'; Fridiric Grenier; 'Gary Orr'; 'Joe Longo'; 'Lamont Frazer'; Marc Kuck; 'Mary Aschoff ; Maurizio Grandi; P Bates; Richard Garrard; 'Sandra Lemke'; 'Scott Nash'; 'Steve Virant'; Tom Gennings;'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'; 'Cary Carrigan'; 'Charles O'Donnell'; 'Chris Gay'; 'Cliff Posey'; 'Cody Rice'; 'Dan Bross'; 'dapa'; 'Daryl J. Kleppin'; 'David Brown'; 'David Gorney'; 'David Hall'; David House; 'David L Boelens'; 'David Steingreaber'; 'ddonkel'; Deborah Jones; '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'; 'James Scherr'; 'Janet D. Platt'; 'jejones'; 'Jerry McCutcheon'; 'Jim Arlington'; 'Jim White'; 'Jim Winegarner'; 'Joe Nicks'; 'John Garing'; 'John S. Haworth'; 'John Spain'; 'John Tower'; 'John W Katz'; johnny.aiken@north-slope.org; 'Jon Goltz'; 'Julie Houle'; 'Kari Moriarty'; 'Kaynell Zeman'; 'Keith Wiles'; knelson@petroleumnews.com; 'Krissell Crandall'; 'Kristin Dirks'; 'Laura Silliphant'; 'Lynnda Kahn'; 'mail=akpratts@acsalaska.net'; 'mail=foms@mtaonline.net'; 'Marilyn Crockett'; 'Mark Dalton'; 'Mark Hanley'; 'Mark Kovac'; 'Mark P. Worcester'; 'Marguerite kremer'; 'Matt Rader'; Melanie Brown; '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 Decker'; 'Paul Winslow'; Pierce, Sandra M (DNR); 'Randall Kanady'; 'Randy L. Skillern'; 'rcrotty'; 'rmclean'; 'Rob McWhorter '; rob.g.dragnich@exxomnobil.com; 'Robert Campbell'; 'Robert Province'; 'Roger Belman'; 'Rudy Brueggeman'; 'Scott Cranswick'; 'Shannon Donnelly'; 'Sharmaine Copeland'; 'Sondra Stewman'; 'Sonja Frankllin'; 'Stan Porhola'; 'stanekj'; 'Steve Lambert'; 'Steve Moothart'; 'Steven R. Rossberg'; 'tablerk'; 'Tamera Sheffield'; 'Temple Davidson'; 'Terrie Hubble'; Thompson, Nan G (DNR); 'Tim Lawlor'; 'Todd Durkee'; Tony Hopfmger; 'trmjrl'; Von Gemmingen, Scott E (DOR); 'Walter Featherly'; 'Walter Quay'; 'Wayne Rancier'; Birnbaum, Alan J (LAW); Crisp, John H (DOA); Davies, Stephen F (DOA); Fleckenstein, Robert J (DOA); Foerster, Catherine P (DOA); Grimaldi, Louis R (DOA); Johnson, Elaine M (DOA); Jones, Jeffery B (DOA); Laasch, Linda K (DOA); Mahnken, Christine R (DOA); Maunder, Thomas E (DOA); McIver, 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); Seamount, Dan T (DOA); Smith, Chasity R (DOA); Williamson, Mary J (DOA) Attachments: aio6 revised admin approval.pdf, fy i Jody J. Colombie Special Assistant Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 (907)793-1221 (phone) (907)276-7542 (fax) 4/2/2009 Mary Jones David McCaleb Cindi Walker XTO Energy, Inc. IHS Energy Group Tesoro Refining and Marketing Co. Cartography GEPS Supply & Distribution 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 300 Concord Plaza Drive Ft. Worth, TX 76102-6298 Houston, TX 77056 San Antonio, TX 78216 George Vaught, Jr. Jerry Hodgden Richard Neahring PO Box 13557 Hodgden Oil Company NRG Associates Denver, CO 80201-3557 408 18th Street President Golden, CO 80401-2433 PO Box 1655 Colorado Springs, CO 80901 Mark Wedman Schlumberger Ciri Halliburton Drilling and Measurements Land Department 6900 Arctic Blvd. 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 Darwin 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 0 a ALASKA FRANK H. MURKOWSKI, GOVERNOR !>•i/A KA OIL AND GAS 333 W. 7- AVENUE, SUITE 100 CONSERVATION COMDIISSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL AIO 6.004 Mr. Larry Greenstein Production Technician Unocal Alaska P.O. Box 196247 Anchorage, AK 99519-6247 RE: Granite Point State 18742 #25 [aka Anna #25] (PTD 168-036) Request for Administrative Approval AIO 6 Dear Mr. Greenstein: Per Rule 9 of Area Injection Order ("AIO") 006, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants Unocal Alaska. ("Unocal")'s request for administrative approval for water injection in the subject well. AOGCC finds the following: 1. The subject well is not completed with a packer and there is no plan to workover the well to install a packer. 2. Several similarly equipped wells on Anna Platform were previously converted to service wells beginning in 2000 according to a procedure developed by Unocal and approved by the Commission. 3. Unocal was authorized to convert Anna 25 from producer to injector via Sundry permit 300-215 approved September 28, 2000. 4. As required by the conversion Sundry permit, Unocal has been recording daily in- jection rates and well pressures and has been reporting this information to the Commission monthly. In support of this application, Unocal has submitted the re- sults of temperature logs obtained in compliance with conversion sundry and a graphical maximum operating pressure determination. 5. Based upon analysis of the submitted logging information, there are no tempera- ture anomalies indicated. The monthly rate/pressure information has not indi- cated any pressure integrity loss. 6. The original analysis performed for the conversion in September 2000 is still valid. 7. An aquifer exemption is in effect below Cook Inlet for Granite Point Field [40 CFR 147.102(b)(2)(i).] Mr. Larry Greenstein March 29, 2005 Page 2 of 2 Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety. AOGCC's administrative approval to continue water injection in Granite Point State 18742 #25 [aka Anna #25] is conditioned upon the following: 1. Injection is limited to WATER ONLY; 2. Unocal shall monitor and record wellhead pressures [T/I/O] (tubing/inner annu- lus/outer annulus) and injection rate daily and submit this information to the Commission monthly; 3. Unocal shall perform a temperature log every two years to demonstrate continued production casing integrity; 4. Unocal shall immediately shut in the well and notify the AOGCC upon any meas- urable change in well outer annulus pressure or any change in the rate/pressure re- lationship for the tubing/IA; and 5. After well shut in, AOGCC approval shall be required to restart injection. As provided in AS 31.05.080, within 20 days after written notice of this 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 rehearing. A request for rehearing is consid- ered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Alaska and dated March 29, 2005. Daniel T. amount, Jr. Commissioner Citgo Petroleum Corporation Mary Jones David McCaleb PO Box 3758 XTO Energy, Inc. IHS Energy Group Tulsa, OK 74136 Cartography GEPS 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 Ft. Worth, TX 76102-6298 Houston, TX 77056 Mona Dickens Robert Gravely George Vaught, Jr. Tesoro Refining and Marketing Co. 7681 South Kit Carson Drive PO Box 13557 Supply & Distribution Littleton, CO 80122 Denver, CO 80201-3557 300 Concord Plaza Drive San Antonio, TX 78216 Jerry Hodgden Richard Neahring John Levorsen Hodgden Oil Company NRG Associates 200 North 3rd Street, #1202 408 18th Street President Boise, ID 83702 Golden, CO 80401-2433 PO Box 1655 Colorado Springs, CO 80901 Kay Munger Samuel Van Vactor Michael Parks Munger Oil Information Service, Inc Economic Insight Inc. Marple's Business Newsletter PO Box 45738 3004 SW First Ave. 117 West Mercer St, Ste 200 Los Angeles, CA 90045-0738 Portland, OR 97201 Seattle, WA 98119-3960 Mark Wedman Schlumberger David Cusato Halliburton Drilling and Measurements 200 West 34th PMB 411 6900 Arctic Blvd. 2525 Gambell Street #400 Anchorage, AK 99503 Anchorage, AK 99502 Anchorage, AK 99503 Ciri Baker Oil Tools Ivan Gillian Land Department 4730 Business Park Blvd., #44 9649 Musket Bell Cr.#5 PO Box 93330 Anchorage, AK 99503 Anchorage, AK 99507 Anchorage, AK 99503 Jill Schneider Gordon Severson Jack Hakkila US Geological Survey 3201 Westmar Cr. PO Box 190083 4200 University Dr. Anchorage, AK 99508-4336 Anchorage, AK 99519 Anchorage, AK 99508 Darwin Waldsmith James Gibbs Kenai National Wildlife Refuge PO Box 39309 PO Box 1597 Refuge Manager Ninilchick, AK 99639 Soldotna, AK 99669 PO Box 2139 Soldotna, AK 99669-2139 Penny Vadla Richard Wagner Cliff Burglin 399 West Riverview Avenue PO Box 60868 PO Box 70131 Soldotna, AK 99669-7714 Fairbanks, AK 99706 Fairbanks, AK 99707 Bernie Karl Williams Thomas North Slope Borough K&K Recycling Inc. Arctic Slope Regional Corporation PO Box 69 PO Box 58055 Land Department Barrow, AK 99723 Fairbanks, AK 99711 PO Box 129 Barrow, AK 99723 Various Administrative Approvals Subject: Various Administrative Approvals From: Jody Colombie <Jody_colombie@admin.state. ak.us> Date: Wed, 30 Mar 2005 13:25:04 -0900 To: undisclosed -recipients:; BCC: Cynthia B Mciver <bren mciver@admin.state.ak.us>, Robert E Mintz <robert_mintz@law. state.ak.us>, Christine Hansen <c.hansen@iogcc. state. ok.us>, Terrie Hubble <hubbletl@bp.com>, Sondra Stewman <StewmaSD@BP.com>, Scott & Cammy Taylor <staylor@alaska.net>, stanekj <stanekj@unocal.com>, ecolaw <ecolaw@trustees.org>, roseragsdale <roseragsdale@gci.net>, trmjrl <trmjrl@aol.com>, jbriddle <jbriddle@marathonoil.com>, shaneg <shaneg@evergreengas.com>, jdarlington <jdarlington@forestoil.com>, nelson <knelson@petroleumnews.com>, cboddy <cboddy@usibelli.com>, Mark Dalton <mark.dalton@hdrinc.com>, Shannon Donnelly <shannon.donnelly@conocophillips.com>, "Mark P. Worcester" <mark.p.worcester@conocophillips.com>, Bob <bob@inletkeeper.org>, wdv <wdv@dnr. state. ak.us>, tjr <tj r@dnr. state. ak.us>, bbritch <bbritch@alaska.net>, mjnelson <mjnelson@purvingertz.com>, Charles O'Donnell <charles.o'donnell@veco.com>, "Randy L. Skillern" <SkilleRL@BP.com>, "Deborah J. Jones" <JonesD6@BP.com>, "Paul G. Hyatt" <hyattpg@BP.com>, "Steven R. Rossberg" <RossbeRS@BP.com>, Lois <lois@inletkeeper.org>, Dan Bross <kuacnews@kuac.org>, Gordon Pospisil <PospisG@BP.com>, "Francis S. Sommer" <SommerFS@BP.com>, Mikel Schultz <Mikel.Schultz@BP.com>, "Nick W. Glover" <GloverNW@BP.com>, "Daryl J. Kleppin" <KleppiDE@BP.com>, "Janet D. Platt" <PlattJD@BP.com>, "Rosanne M. Jacobsen" <JacobsRM@BP.com>, ddonkel <ddonkel@cfl.rr.com>, Collins Mount <collins_mount@revenue. state.ak.us>, mckay <mckay@gci.net>, Barbara F Fullmer <barbara.f.fullmer@conocophillips.com>, bocastwf <bocastwf@bp.com>, Charles Barker <barker@usgs.gov>, doug_schultze <doug_schultze@xtoenergy.com>, Hank Alford <hank. alford@exxonmobil. com>, Mark Kovac <yesnol@gci.net>, gspfoff <gspfoff@aurorapower.com>, Gregg Nady <gregg.nady@shell.com>, Fred Steece <fred.steece@state.sd.us>, rcrotty <rcrotty@ch2m.com>, jejones <jejones@aurorapower.com>, dapa <dapa@alaska.net>, jroderick <jroderick@gci.net>, eyancy <eyancy@seal-tite.net>, "James M. Ruud" <james.m.ruud@conocophillips.com>, Brit Lively <mapalaska@ak.net>, jah <jah@dnr.state.ak.us>, Kurt E Olson <kurt_olson@legis.state. ak.us>, buonoje <buonoje@bp.com>, Mark Hanley <mark_hanley@anadarko.com>, loren_leman <loren_leman@gov.state. ak.us>, Julie Houle <julie_houle@dnr.state. ak.us>, John W Katz <jwkatz@sso.org>, Suzan J Hill <suzan_hill@dec.state. ak.us>, tablerk <tablerk@unocal.com>, Brady <brady@aoga.org>, Brian Havelock <beh@dnr. state. ak.us>, bpopp <bpopp@borough.kenai.ak.us>, Jim White <jimwhite@satx.rr.com>, "John S. Haworth" <john.s.haworth@exxonmobil.com>, marty <marty@rkindustrial.com>, ghammons <ghammons@aol.com>, rmclean <rmclean@pobox.alaska.net>, mkm7200 <mkm7200@aol.com>, Brian Gillespie <ifbmg@uaa.alaska.edu>, David L Boelens <dboelens@aurorapower.com>, Todd Durkee <TDURKEE@KMG.com>, Gary Schultz <gary_schultz@dnr. state. ak.us>, Wayne Rancier <RANCIER@petro-canada.ca>, Bill Miller <Bill_Miller@xtoalaska.com>, Brandon Gagnon <bgagnon@brenalaw.com>, Paul Winslow <pmwinslow@forestoil.com>, Garry Catron <catrongr@bp.com>, Sharmaine Copeland <copelasv@bp.com>, Kristin Dirks <kistin_dirks@dnr.state. ak.us>, Kaynell Zeman <kjzeman@marathonoil.com>, John Tower <John.Tower@eia.doe. gov>, Bill Fowler <Bill_Fowler@anadarko.COM>, Vaughn Swartz <vaughn.swartz@rbccm.com>, Scott Cranswick <scott.cranswick@mms.gov>, Brad McKim <mckimbs@BP.com>, Steve Lambe 1 of 3 3/30/2005 3:10 PM Various Administrative Approvals • <lambes@unocal.com>, jack newell <jack.newell@acsalaska.net>, James Scherr <James.Scherr@mms.gov>, david roby <David. Roby@mms. gov>, Tim Lawlor <Tim_Lawlor@ak.blm.gov>, Lynnda Kahn <Lynnda_Kahn@fws.gov>, Jerry Dethlefs <Jerry. C.Dethlefs@conocophillips. com>, Jerry Dethlefs <nl617@conocophillips.com>, crockett@aoga.org, Tamera Sheffield <sheffield@aoga.org>, Jon Goltz <Jon.Goltz@conocophillips.com>, Roger Belman <roger.belman@conocophillips.com>, Mindy Lewis <mlewis@brenalaw.com>, Harry Lampert <harry. lampert@honeywell. com> AIO5.002.pdfContent-Type: application/pdf ' Content -Encoding: base64 AIO6.009.pdf Content -Type: application/pdf Content -Encoding: base64 AIO6.006.pdf Content -Type: application/pdf Content -Encoding: base64 AIO6.008.pdf Content -Type: application/pdf Content -Encoding: base64 Content -Type: application/pdf AI06.005.pdf' Content -Encoding: base64 Content -Type: application/pdf AIO 6.004.pdf Content -Encoding: base64 AIO6.007.pdf Content -Type: application/pdf Content -Encoding: base64 2 of 3 3/30/2005 3:10 PM Various Administrative Approvals • 0 AIO5.003.pdf Content -Type: application/pdf Content -Encoding: base64 AIO11.003.pdf Content -Type: application/pdf Content -Encoding: base64 AIO2B.03.pdf Content -Type: application/pdf Content -Encoding: base64 3 of 3 3/30/2005 3:10 PM • _AJASKA OIL AND GAS CONSERVATION COMMSSION AMCi-ORAr�E,ALASKA 99501-3539 nl I0HE (907) 2.79-1433 !'AX (907) 276-7542 ADMINISTRATIVE APPROVAL A10 6,00LReyisd ADMINISTRATIVE APPROVAL AI® 6.004 (Revised) ADMINISTRATIVE APPROVAL AIO 6.007 (Revised) ADMINISTRATIVE APPROVAL AI0 6.008 (Revised) ADMINISTRATIVE APPROVAL AIO 6.009 (Revised) Mr. J, Hal Martin Optimization Engineer Union Oil Company of California PO Box 196247 Anchorage, Alaska 99519-6247 RE: Request for Administrative Approval Revision Dear Mr. Martin: Union Oil Company of California (Union) requests a permanent revision to the anniversary date for temperature surveys for water injection wells located on the Anna Platform (Granite Point Field). The Alaska Oil and Gas Conservation Commission (Commission) approves Union's request to change the anniversary date for temperature surveys in the following wells from March 29 to May 20: - Granite Pt. State 18742 Well No. 5; PTD 1670140; AIO 6.003; - Granite Pt. State 18742 Well No. 19; PTD 1680060; AIO 6.008; - Granite Pt. State 18742 Well No. 21; PTD 1760490; AIO 6.009; - Granite Pt. State 18742 Well No. 25; PTD 1680360; AIO 6.004; - Granite Pt. State 18742 Well No. 38; PTD 1880340; AIO 6.007. The Commission granted administrative approvals to Union allowing temperature surveys every 2 years in lieu of pressure tests of the tubing -casing annulus. Temperature surveys are intended to demonstrate that injected fluids are exiting the wellbore and remaining confined as required by Area Injection Order 6.000. Union argues that performing temperature surveys in May will allow warmer weather conditions to improve the slickline operations on these water injection wells. Daily surveillance of wellhead pressures and injection rates with monthly reporting to the Commission — mandated by the administrative approvals — provide for early detection and action regarding any deterioration of well integrity that might occur during the 2-year interval between vlr, l,IgI 1Vl�11 11 li • 0 Marc.'h. 1, )009 Pagic) ot' ) tempc,ro(u e surveys, Adrninistrative approvals also refill rc ►Jnioll to irnrrled ately shut in tbc; well and notify the Commission if there is any measurable change in the well's mechanical integrity, The Commission finds that moving the anniversary date for temperature surveys Front March 29 to May 20 will not compromise overall well integrity so as to threaten the environment or human safety. DONE at Anchorage, Alaska and dated March 31, 2009, Daniel T. Seamount, Jr. Cathy . Foerster Chair Commissioner RECONSIDERATION AND APPEAL NOTICE Commissioner As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the 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 tiled 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 tiled within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[tlhe questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5.00 p.m. on the next day that does not fall on a weekend or state holiday. 9 • Page 1 of 1 Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Thursday, April 02, 2009 9:07 AM Subject: Revised AIO 6-003; AIO 6-004, AIO 6-007; AIO 6-008; AIO 6-009 (all combined on one admin approval) Attachments: aio6 revised admin approval.pdf BCC:'Aaron Gluzman'; caunderwood@marathonoil.com; 'Dale Hoffman'; Fridiric Grenier; 'Gary Orr'; 'Joe Longo'; 'Lamont Frazer'; Marc Kuck; 'Mary Aschoff; Maurizio Grandi; P Bates; Richard Garrard; 'Sandra Lemke'; 'Scott Nash'; 'Steve Virant'; Tom Gennings;'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'; 'Cary Carrigan'; 'Charles O'Donnell'; 'Chris Gay'; 'Cliff Posey'; 'Cody Rice'; 'Dan Bross'; 'dapa'; 'Daryl J. Kleppin'; 'David Brown'; 'David Gomey'; 'David Hall'; David House; 'David L Boelens'; 'David Steingreaber'; 'ddonkel'; Deborah Jones; 'doug_schultze'; 'Eric Lidji '; 'Evan Harness'; 'eyancy'; 'f6ms2@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'; 'James Scherr'; 'Janet D. Platt'; 'jejones'; 'Jerry McCutcheon'; 'Jim Arlington'; 'Jim White'; 'Jim Winegarner'; 'Joe Nicks'; 'John Garing'; 'John S. Haworth'; 'John Spain'; 'John Tower'; 'John W Katz'; johnny.aiken@north-slope.org; 'Jon Goltz'; 'Julie Houle'; 'Kari Moriarty'; 'Kaynell Zeman'; 'Keith Wiles'; knelson@petroleumnews.com; 'Krissell Crandall'; 'Kristin Dirks'; 'Laura Silliphant'; 'Lynnda Kahn'; 'mail=akpratts@acsalaska.net'; 'mail=foms@mtaonline.net'; 'Marilyn Crockett'; 'Mark Dalton'; 'Mark Hanley'; 'Mark Kovac'; 'Mark P. Worcester'; 'Marguerite kremer'; 'Matt Rader'; Melanie Brown; '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 Decker'; 'Paul Winslow'; Pierce, Sandra M (DNR); 'Randall Kanady'; 'Randy L. Skillern'; 'rcrotty'; 'rmclean'; 'Rob McWhorter'; rob. g.dragnich@exxonmobil.com; 'Robert Campbell'; 'Robert Province'; 'Roger Belman'; 'Rudy Brueggeman'; 'Scott Cranswick'; 'Shannon Donnelly'; 'Sharmaine Copeland'; 'Sondra Stewman'; 'Sonja Frankllin'; 'Stan Porhola'; 'stanekj'; 'Steve Lambert'; 'Steve Moothart'; 'Steven R. Rossberg'; 'tablerk'; 'Tamera Sheffield'; 'Temple Davidson'; 'Terrie Hubble'; Thompson, Nan G (DNR); 'Tim Lawlor'; 'Todd Durkee'; Tony Hopfinger; 'trmjrl'; Von Gemmingen, Scott E (DOR); 'Walter Featherly'; 'Walter Quay'; 'Wayne Rancier'; Birnbaum, Alan J (LAW); Crisp, John H (DOA); Davies, Stephen F (DOA); Fleckenstein, Robert J (DOA); Foerster, Catherine P (DOA); Grimaldi, Louis R (DOA); Johnson, Elaine M (DOA); Jones, Jeffery B (DOA); Laasch, Linda K (DOA); Mahnken, Christine R (DOA); Maunder, Thomas E (DOA); McIver, 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); Seamount, Dan T (DOA); Smith, Chasity R (DOA); Williamson, Mary J (DOA) Attachments: aio6 revised admin approval.pdf; fyi Jody J. Colombie Special Assistant Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 (907)793-1221 (phone) (907)276-7542 (fax) 4/2/2009 Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth. TX 76102-6298 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 James Gibbs PO Box 1597 Soldotna, AK 99669 Richard Wagner PO Box 60868 Fairbanks, AK 99706 North Slope Borough PO Box 69 Barrow, AK 99723 David McCaleb Cindi Walker IHS Energy Group Tesoro Refining and Marketing Co. GEPS Supply & Distribution 5333 Westheimer, Ste 100 300 Concord Plaza Drive Houston, TX 77056 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 Schlumberger Ciri Drilling and Measurements Land Department 2525 Gambell Street #400 PO Box 93330 Anchorage, AK 99503 Anchorage, AK 99503 Ivan Gillian Jill Schneider 9649 Musket Bell Cr.#5 US Geological Survey Anchorage, AK 99507 4200 University Dr. Anchorage, AK 99508 Jack Hakkila Darwin Waldsmith PO Box 190083 PO Box 39309 Anchorage, AK 99519 Ninilchick, AK 99639 Kenai National Wildlife Refuge Penny Vadla Refuge Manager 399 West Riverview Avenue PO Box 2139 Soldotna, AK 99669-7714 Soldotna, AK 99669-2139 Cliff Burglin Bernie Karl PO Box 70131 K&K Recycling Inc. Fairbanks, AK 99707 PO Box 58055 Fairbanks, AK 99711 0 C� WE ALASKA FRANK H. MURKOWSKI, GOVERNOR di ASKAL OIL AND GALS 333 W. 7' AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL AIO 6.005 Mr. Larry Greenstein Production Technician Unocal Alaska P.O. Box 196247 Anchorage, AK 99519-6247 RE: Granite Point State 18742 #37 [aka Anna #37] (PTD 187-109) Request for Administrative Approval AIO 6 Dear Mr. Greenstein: Per Rule 9 of Area Injection Order ("AIO") 006, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants Unocal Alaska. ("Unocal")'s request for administrative approval for water injection in the subject well. AOGCC finds the following: 1. The subject well is not completed with a packer and there is no plan to workover the well to install a packer. 2. Several similarly equipped wells on Anna Platform were previously converted to service wells beginning in 2000 according to a procedure developed by Unocal and approved by the Commission. 3. Unocal was authorized to convert Anna 37 from producer to injector via Sundry permit 300-218 approved October 25, 2000. 4. As required by the conversion Sundry permit, Unocal has been recording daily in- jection rates and well pressures and has been reporting this information to the Commission monthly. In support of this application, Unocal has submitted the re- sults of temperature logs obtained in compliance with the conversion Sundry permit and a graphical maximum operating pressure determination. 5. Based upon analysis of the submitted logging information, there are no tempera- ture anomalies indicated. The monthly rate/pressure information has not indi- cated any pressure integrity loss. 6. The pressure information gathered with the temperature survey indicates that the bottomhole pressure in the vicinity of Anna 37 is low and insufficient to support a fluid column to surface. According to the injection report, there has not been any Mr. Larry Greenstein • • March 29, 2005 Page 2 of 2 injection since May 2002. A similar low reservoir pressure was shown on Anna 5. 7. The original analysis performed for the conversion in October 2000 is still valid. 8. An aquifer exemption is in effect below Cook Inlet for Granite Point Field [40 CFR 147.102(b)(2)(i).] Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety. AOGCC's administrative approval to continue water injection in Granite Point State 18742 #37 [aka Anna #37] is conditioned upon the following: 1. Injection is limited to WATER ONLY; 2. Unocal shall monitor and record wellhead pressures [T/I/O] (tubing/inner annu- lus/outer annulus) and injection rate daily and submit this information to the Commission monthly; 3. Unocal shall perform a temperature log every two years to demonstrate continued production casing integrity; 4. Unocal shall immediately shut in the well and notify the AOGCC upon any meas- urable change in well outer annulus pressure or any change in the rate/pressure re- lationship for the tubing/IA; and 5. After well shut in, AOGCC approval shall be required to restart injection. As provided in AS 31.05.080, within 20 days after written notice of this 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 rehearing. A request for rehearing is consid- ered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. LN Alaska and dated March 29, 2005. Daniel T. Seamount, Jr. Commissioner Citgo Petroleum Corporation Mary Jones David McCaleb PO Box 3758 XTO Energy, Inc. IHS Energy Group Tulsa, OK 74136 Cartography GEPS 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 Ft. Worth, TX 76102-6298 Houston, TX 77056 Mona Dickens Robert Gravely George Vaught, Jr. Tesoro Refining and Marketing Co. 7681 South Kit Carson Drive PO Box 13557 Supply & Distribution Littleton, CO 80122 Denver, CO 80201-3557 300 Concord Plaza Drive San Antonio, TX 78216 Jerry Hodgden Richard Neahring John Levorsen Hodgden Oil Company NRG Associates 200 North 3rd Street, #1202 408 18th Street President Boise, ID 83702 Golden, CO 80401-2433 PO Box 1655 Colorado Springs, CO 80901 Kay Munger Samuel Van Vactor Michael Parks Munger Oil Information Service, Inc Economic Insight Inc. Marple's Business Newsletter PO Box 45738 3004 SW First Ave. 117 West Mercer St, Ste 200 Los Angeles, CA 90045-0738 Portland, OR 97201 Seattle, WA 98119-3960 Mark Wedman Schlumberger David Cusato Halliburton Drilling and Measurements 200 West 34th PMB 411 6900 Arctic Blvd. 2525 Gambell Street #400 Anchorage, AK 99503 Anchorage, AK 99502 Anchorage, AK 99503 Ciri Baker Oil Tools Ivan Gillian Land Department 4730 Business Park Blvd., #44 9649 Musket Bell Cr.#5 PO Box 93330 Anchorage, AK 99503 Anchorage, AK 99507 Anchorage, AK 99503 Jill Schneider Gordon Severson Jack Hakkila US Geological Survey 3201 Westmar Cr. PO Box 190083 4200 University Dr. Anchorage, AK 99508-4336 Anchorage, AK 99519 Anchorage, AK 99508 Darwin Waldsmith James Gibbs Kenai National Wildlife Refuge PO Box 39309 PO Box 1597 Refuge Manager Ninilchick, AK 99639 Soldotna, AK 99669 PO Box 2139 Soldotna, AK 99669-2139 Penny Vadla Richard Wagner Cliff Burglin 399 West Riverview Avenue PO Box 60868 PO Box 70131 Soldotna, AK 99669-7714 Fairbanks, AK 99706 Fairbanks, AK 99707 Bernie Karl Williams Thomas North Slope Borough K&K Recycling Inc. Arctic Slope Regional Corporation PO Box 69 PO Box 58055 Land Department Barrow, AK 99723 Fairbanks, AK 99711 PO Box 129 Barrow, AK 99723 Various Administrative Approvals 0 0 Subject: Various Administrative Approvals From: Jody Colombie<j ody_colombie@admin. state. ak.us> Date: Wed, 30 Mar 2005 13:25:04 -0900 To: undisclosed -recipients:; BCC: Cynthia B Mciver<bren_mciver@admin.state. ak.us>, Robert E Mintz <robert_mintz@law. state.ak.us>, Christine Hansen <c.hansen@iogcc. state. ok.us>, Terrie Hubble <hubbletl@bp.com>, Sondra Stewman <StewmaSD@BP.com>, Scott & Cammy Taylor <staylor@alaska.net>, stanekj <stanekj@unocal.com>, ecolaw <ecolaw@trustees.org>, roseragsdale <ro seragsdale@gci. net>, trmjrl <trmjrl@aol.com>, jbriddle <jbriddle@marathonoil.com>, shaneg <shaneg@evergreengas.com>, jdarlington <jdarlington@forestoil.com>, nelson <knelson@petroleumnews.com>, cboddy <cboddy@usibelli.com>, Mark Dalton <mark. dalton@hdrinc. com>, Shannon Donnelly <shannon.donnelly@conocophillips.com>, "Mark P. Worcester" <mark.p.worcester@conocophillips.com>, Bob <bob@inletkeeper.org>, wdv <wdv@dnr. state. ak.us>, tjr <tj r@dnr. state. ak.us>, bbritch <bbritch@alaska.net>, mjnelson <mjnelson@purvingertz.com>, Charles O'Donnell <charles.o'donnell@veco.com>, "Randy L. Skillern" <SkilleRL@BP.com>, "Deborah J. Jones" <JonesD6@BP.com>, "Paul G. Hyatt" <hyattpg@BP.com>, "Steven R. Rossberg" <RossbeRS@BP.com>, Lois <lois@inletkeeper.org>, Dan Bross <kuacnews@kuac.org>, Gordon Pospisil <PospisG@BP.com>, "Francis S. Sommer" <SommerFS@BP.com>, Mikel Schultz <Mikel.Schultz@BP.com>, "Nick W. Glover" <GloverNW@BP.com>, "Daryl J. Kleppin" <KleppiDE@BP.com>, "Janet D. Platt" <P1attJD@BP.com>, "Rosanne M. Jacobsen" <JacobsRM@BP.com>, ddonkel <ddonkel@cfl.rr.com>, Collins Mount <collins_mount@revenue. state.ak.us>, mckay <mckay@gci.net>, Barbara F Fullmer <barbara.f.fullmer@conocophillips.com>, bocastwf <bocastwf@bp.com>, Charles Barker <barker@usgs.gov>, doug_schultze <doug_schultze@xtoenergy.com>, Hank Alford <hank.alford@exxonmobil.com>, Mark Kovac <yesno I @gci.net>, gspfoff <gspfoff@aurorapower.com>, Gregg Nady <gregg.nady@shell.com>, Fred Steece <fred.steece@state.sd.us>, rcrotty <rcrotty@ch2m.com>, jejones <jejones@aurorapower.com>, dapa <dapa@alaska.net>, jroderick <jroderick@gci.net>, eyancy <eyancy@seal-tite.net>, "James M. Ruud" <james.m.ruud@conocophillips.com>, Brit Lively <mapalaska@ak.net>, jah <j ah@dnr. state. ak.us>, Kurt E Olson <kurt_olson@legis.state. ak.us>, buonoje <buonoje@bp.com>, Mark Hanley <mark_hanley@anadarko.com>, loren_leman <loren_leman@gov.state. ak.us>, Julie Houle <julie_houle@dnr.state. ak.us>, John W Katz <jwkatz@sso.org>, Suzan J Hill <suzan_hill@dec. state. ak.us>, tablerk <tablerk@unocal.com>, Brady <brady@aoga.org>, Brian Havelock <beh@dnr. state. ak.us>, bpopp <bpopp@borough.kenai.ak.us>, Jim White <jimwhite@satx.rr.com>, "John S. Haworth" <john.s.haworth@exxonmobil.com>, marty <marty@rkindustrial.com>, ghammons <ghammons@aol.com>, rmclean <rmclean@pobox.alaska.net>, mkm7200 <mkm7200@aol.com>, Brian Gillespie <ifbmg@uaa.alaska.edu>, David L Boelens <dboelens@aurorapower.com>, Todd Durkee <TDURKEE@KMG.com>, Gary Schultz <gary_schultz@dnr. state. ak. us>, Wayne Rancier <RANCIER@petro-canada.ca>, Bill Miller <Bill_Miller@xtoalaska.com>, Brandon Gagnon <bgagnon@brenalaw.com>, Paul Winslow <pmwinslow@forestoil.com>, Garry Catron <catrongr@bp.com>, Sharmaine Copeland <copelasv@bp.com>, Kristin Dirks<kristin_dirks@dnr.state. ak.us>, Kaynell Zeman <kjzeman@marathonoil.com>, John Tower <John.Tower@eia.doe. gov>, Bill Fowler <Bill_Fowler@anadarko.COM>, Vaughn Swartz <vaughn.swartz@rbccm.com>, Scott Cranswick <scott.cranswick@mms.gov>, Brad McKim <mckimbs@BP.com>, Steve Lambe 1 of 3 3/30/2005 3:10 PM Various Administrative Approvals 0 0 <lambes@unocal.com>, jack newell <jack.newell@acsalaska.net>, James Scherr <James.Scherr@mms.gov>, david roby <David.Roby@mms.gov>, Tim Lawlor <Tim_Lawlor@ak.blm.gov>, Lynnda Kahn <Lynnda_Kahn@fws.gov>, Jerry Dethlefs <Jerry. C. Dethlefs@conocophillips. com>, Jerry Dethlefs <nl617@conocophillips.com>, crockett@aoga.org, Tamera Sheffield <sheffield@aoga.org>, Jon Goltz <Jon. Goltz@conocophillips. com>, Roger Belman <roger.belman@conocophillips.com>, Mindy Lewis <mlewis@brenalaw.com>, Harry Lampert <harry.lampert@honeywell.com> AIO5.002.pdf Content -Type: application/pdf Content -Encoding: base64 AIO6.009.pdf Content -Type: application/pdf Content -Encoding: base64 AIO6.006.pdf Content -Type: application/pdf Content -Encoding: base64 AIO6.008.pdf Content -Type: application/pdf Content -Encoding: base64 AIO6.005.pdf Content -Type: application/pdf Content -Encoding: base64 Content -Type: application/pdf AIO 6.004.pdf Content -Encoding: base64 AIO6.007.pdf Content -Type: application/pdf Content -Encoding: base64 2 of 3 3/30/2005 3:10 PM Various Administrative Approvals AIO5.003.pdf Content -Type: application/pdf Content -Encoding: base64 Content -Type: application/pdf AIOI 1.003.pdf Content -Encoding: base64 AIO2B.03.pdf Content -Type: application/pdf Content -Encoding: base64 3 of 3 3/30/2005 3:10 PM u l I 0 ALASKA FRANK H. MURKOWSKI, GOVERNOR Aiat1•►7KA OIL AND GAS 333 W. 7' AVENUE, SUITE 100 CONSERQAUON CODil►USSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL AIO 6.006 Mr. Larry Greenstein Production Technician Unocal Alaska P.O. Box 196247 Anchorage, AK 99519-6247 RE: Granite Point State 18742 #32RD [aka Anna #32RD] (PTD 187-063) Request for Administrative Approval AIO 6 Dear Mr. Greenstein: Per Rule 9 of Area Injection Order ("AIO") 006, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants Unocal Alaska. ("Unocal")'s request for administrative approval for water injection in the subject well. AOGCC finds the following: 1. The subject well is not completed with a packer and there is no plan to workover the well to install a packer. 2. Several similarly equipped wells on Anna Platform were previously converted to service wells beginning in 2000 according to a procedure developed by Unocal and approved by the Commission. 3. Unocal was authorized to convert Anna 32RD from producer to injector via Sun- dry permit 300-217 approved October 25, 2000. 4. As required by the conversion Sundry permit, Unocal has been recording daily in- jection rates and well pressures and has been reporting this information to the Commission monthly. In support of this application, Unocal has submitted the re- sults of temperature logs obtained in compliance with conversion Sundry permit and a graphical maximum operating pressure determination. 5. Based upon analysis of the submitted logging information, there are no tempera- ture anomalies indicated. The monthly rate/pressure information has not indi- cated any pressure integrity loss. 6. The original analysis performed for the conversion in October 2000 is still valid. 7. An aquifer exemption is in effect below Cook Inlet for Granite Point Field [40 CFR 147.102(b)(2)(i).] Mr. Larry Greenstein • March 29, 2005 Page 2 of 2 Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety. AOGCC's administrative approval to continue water injection in Granite Point State 18742 #32RD [aka Anna 932RD] is conditioned upon the following: 1. Injection is limited to WATER ONLY; 2. Unocal shall monitor and record wellhead pressures [T/I/O] (tubing/inner annu- lus/outer annulus) and injection rate daily and submit this information to the Commission monthly; 3. Unocal shall perform a temperature log every two years to demonstrate continued production casing integrity; 4. Unocal shall immediately shut in the well and notify the AOGCC upon any meas- urable change in well outer annulus pressure or any change in the rate/pressure re- lationship for the tubing/IA; and 5. After well shut in, AOGCC approval shall be required to restart injection. As provided in AS 31.05.080, within 20 days after written notice of this 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 rehearing. A request for rehearing is consid- ered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commis' n decision to Superior Court unless rehearing has been requested. D E at A2ce, Alaska and dated March 29, 2005. oe J h an Daniel T. Seamount, Jr. W Chairman Commissioner Citgo Petroleum Corporation Mary Jones David McCaleb PO Box 3758 XTO Energy, Inc. IHS Energy Group Tulsa, OK 74136 Cartography GEPS 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 Ft. Worth, TX 76102-6298 Houston, TX 77056 Mona Dickens Robert Gravely George Vaught, Jr. Tesoro Refining and Marketing Co. 7681 South Kit Carson Drive PO Box 13557 Supply & Distribution Littleton, CO 80122 Denver, CO 80201-3557 300 Concord Plaza Drive San Antonio, TX 78216 Jerry Hodgden Richard Neahring John Levorsen Hodgden Oil Company NRG Associates 200 North 3rd Street, #1202 408 18th Street President Boise, ID 83702 Golden, CO 80401-2433 PO Box 1655 Colorado Springs, CO 80901 Kay Munger Samuel Van Vactor Michael Parks Munger Oil Information Service, Inc Economic Insight Inc. Marple's Business Newsletter PO Box 45738 3004 SW First Ave. 117 West Mercer St, Ste 200 Los Angeles, CA 90045-0738 Portland, OR 97201 Seattle, WA 98119-3960 Mark Wedman Schlumberger David Cusato Halliburton Drilling and Measurements 200 West 34th PMB 411 6900 Arctic Blvd. 2525 Gambell Street #400 Anchorage, AK 99503 Anchorage, AK 99502 Anchorage, AK 99503 Ciri Baker Oil Tools Ivan Gillian Land Department 4730 Business Park Blvd., #44 9649 Musket Bell Cr.#5 PO Box 93330 Anchorage, AK 99503 Anchorage, AK 99507 Anchorage, AK 99503 Jill Schneider Gordon Severson Jack Hakkila US Geological Survey 3201 Westmar Cr. PO Box 190083 4200 University Dr. Anchorage, AK 99508-4336 Anchorage, AK 99519 Anchorage, AK 99508 Darwin Waldsmith James Gibbs Kenai National Wildlife Refuge PO Box 39309 PO Box 1597 Refuge Manager Ninilchick, AK 99639 Soldotna, AK 99669 PO Box 2139 Soldotna, AK 99669-2139 Penny Vadla Richard Wagner Cliff Burglin 399 West Riverview Avenue PO Box 60868 PO Box 70131 Soldotna, AK 99669-7714 Fairbanks, AK 99706 Fairbanks, AK 99707 Bernie Karl Williams Thomas North Slope Borough K&K Recycling Inc. Arctic Slope Regional Corporation PO Box 69 PO Box 58055 Land Department Barrow, AK 99723 Fairbanks, AK 99711 PO Box 129 Barrow, AK 99723 Various Administrative Approvals Subject: Various Administrative Approvals From: Jody Colombie <jody_colombie@admin.state.ak.us> Date: Wed, 30 Mar 2005 13:25:04 -0900 To: undisclosed -recipients:; BCC: Cynthia B Mciver<bren_mciver@admin.state. ak.us>, Robert E Mintz <robert_mintz@law. state.ak.us>, Christine Hansen <c.hansen@iogcc.state.ok.us>, Terrie Hubble <hubbletl@bp.com>, Sondra Stewman <StewmaSD@BP.com>, Scott & Cammy Taylor <staylor@alaska.net>, stanekj <stanekj@unocal.com>, ecolaw <ecolaw@trustees.org>, roseragsdale <roseragsdale@gci.net>, trmjrl <trmjrl@aol.com>, jbriddle <jbriddle@marathonoil.com>, shaneg <shaneg@evergreengas.com>, jdarlington <jdarlington@forestoil.com>, nelson <knelson@petroleumnews.com>, cboddy <cboddy@usibelli.com>, Mark Dalton <mark.dalton@hdrinc.com>, Shannon Donnelly <shannon.donnelly@conocophillips.com>, "Mark P. Worcester" <mark.p.worcester@conocophillips.com>, Bob <bob@inletkeeper.org>, wdv <wdv@dnr. state. ak.us>, tjr <tj r@dnr. state. ak.us>, bbritch <bbritch@alaska.net>, mjnelson <mjnelson@purvingertz.com>, Charles O'Donnell <charles.o'donnell@veco.com>, "Randy L. Skillern" <SkilleRL@BP.com>, "Deborah J. Jones" <JonesD6@BP.com>, "Paul G. Hyatt" <hyattpg@BP.com>, "Steven R. Rossberg" <RossbeRS@BP.com>, Lois <lois@inletkeeper.org>, Dan Bross <kuacnews@kuac.org>, Gordon Pospisil <PospisG@BP.com>, "Francis S. Sommer" <SommerFS@BP.com>, Mikel Schultz <Mikel.Schultz@BP.com>, "Nick W. Glover" <GloverNW@BP.com>, "Daryl J. Kleppin" <KleppiDE@BP.com>, "Janet D. Platt" <P1attJD@BP.com>, "Rosanne M. Jacobsen" <JacobsRM@BP.com>, ddonkel <ddonkel@cfl.rr.com>, Collins Mount <collins_mount@revenue. state.ak.us>, mckay <mckay@gci.net>, Barbara F Fullmer <barbara.£fullmer@conocophillips.com>, bocastwf <bocastwf@bp.com>, Charles Barker <barker@usgs.gov>, doug_schultze <doug_schultze@xtoenergy.com>, Hank Alford <hank. alford@exxonmobil. com>, Mark Kovac <yesno I @gci.net>, gspfoff <gspfoff@aurorapower.com>, Gregg Nady <gregg.nady@shell.com>, Fred Steece <fred.steece@state.sd.us>, rcrotty <rcrotty@ch2m.com>, jejones <jejones@aurorapower.com>, dapa <dapa@alaska.net>, jroderick <jroderick@gci.net>, eyancy <eyancy@seal-tite.net>, "James M. Ruud" <james.m.ruud@conocophillips.com>, Brit Lively <mapalaska@ak.net>, jah <j ah@dnr. state. ak.us>, Kurt E Olson <kurt_olson@legis.state. ak.us>, buonoje <buonoje@bp.com>, Mark Hanley <mark_hanley@anadarko.com>, loren_leman <loren_leman@gov.state.ak.us>, Julie Houle <julie_houle@dnr.state. ak.us>, John W Katz <jwkatz@sso.org>, Suzan J Hill <Suzan_hill@dec.state. ak.us>, tablerk <tablerk@unocal.com>, Brady <brady@aoga.org>, Brian Havelock <beh@dnr. state. ak.us>, bpopp <bpopp@borough.kenai.ak.us>, Jim White <jimwhite@satx.rr.com>, "John S. Haworth" <john.s.haworth@exxonmobil.com>, marty <marty@rkindustrial.com>, ghammons <ghammons@aol.com>, rmclean <rmclean@pobox.alaska.net>, mkm7200 <mkm7200@aol.com>, Brian Gillespie <ifbmg@uaa.alaska.edu>, David L Boelens <dboelens@aurorapower.com>, Todd Durkee <TDURKEE@KMG.com>, Gary Schultz <gary_schultz@dnr. state. ak.us>, Wayne Rancier <RANCIER@petro-canada.ca>, Bill Miller <Bill_Miller@xtoalaska.com>, Brandon Gagnon <bgagnon@brenalaw.com>, Paul Winslow <pmwinslow@forestoil.com>, Garry Catron <catrongr@bp.com>, Sharmaine Copeland <copelasv@bp.com>, Kristin Dirks<kristin_dirks@dnr.state. ak.us>, Kaynell Zeman <kjzeman@marathonoil.com>, John Tower <John.Tower@eia.doe. gov>, Bill Fowler <Bill_Fowler@anadarko.COM>, Vaughn Swartz <vaughn.swartz@rbccm.com>, Scott Cranswick <scott.cranswick@mms.gov>, Brad McKim <mckimbs@BP.com>, Steve Lambe 1 of 3 3/30/2005 3:10 PM Various Administrative Approvals • • <lambes@unocal.com>, jack newell <jack.newell@acsalaska.net>, James Scherr <James.Scherr@mms.gov>, david roby <David.Roby@mms.gov>, Tim Lawlor <Tim_Lawlor@ak.blm.gov>, Lynnda Kahn <Lynnda_Kahn@fws.gov>, Jerry Dethlefs <Jerry. C. Dethlefs@conocophillips. com>, Jerry Dethlefs <n1617@conocophillips.com>, crockett@aoga.org, Tamera Sheffield <sheffield@aoga.org>, Jon Goltz <Jon.Goltz@conocophillips.com>, Roger Belman <roger.belman@conocophillips.com>, Mindy Lewis <mlewis@brenalaw.com>, Harry Lampert <harry. lampert@honeywell. com> AIO5.002.pdf Content -Type: application/pdf Content -Encoding: base64 Content -Type: application/pdf AIO6.009.pdf Content -Encoding: base64 AIO6.006.pdf Content -Type: application/pdf Content -Encoding: base64 AIO6.008.pdf Content -Type: application/pdf Content -Encoding: base64 Content -Type: application/pdf AI06.005.pdf' Content -Encoding: base64 AIO 6.004.pdf Content -Type: application/pdf Content -Encoding: base64 AIO6.007.pdf Content -Type: application/pdf Content -Encoding: base64 2 of 3 3/30/2005 3:10 PM Various Administrative Approvals 0 AIO5.003.pdf Content -Type: application/pdf Content -Encoding: base64 AIO11.003.pdf Content -Type: application/pdf Content -Encoding: base64 AIO2B.03.pdf Content -Type: application/pdf Content -Encoding: base64 3 of 3 3/30/2005 3:10 PM o o 0 0 SARAH PALIN, GOVERNOR �T ALASKA OIL AND + GAS 333 W 7thAVENUE, SUITE 100 CONSERVATION COMUSSIO ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 CANCELLATION ADMINISTRATIVE APPROVAL NO. AIO 6.006 Mr. J. Hal Martin Optimization Engineer Chevron North America Exploration and Production P.O. Box 196247 Anchorage, AK 99519-6247 RE: Cancellation of Administrative Approval AIO 6.006 Dear Mr. Martin: Pursuant to Chevron's request dated January 30, 2008 Alaska Oil and Gas Conservation Commission ("AOGCC") hereby cancels Administrative Approval AIO 6.006, which allows continued water injection in Granite Point State 18742 Well 32RD located on the Anna Platform, Granite Point Field, offshore Cook Inlet. This well was completed as a production well without a packer and later converted to injection. Chevron did not at the time propose repairing the well to install a packer to eliminate tubing by inner annulus communication. The Commission determined that water injection could safely continue in the well, but subject to a number of restrictive conditions set out in the administrative approval. Chevron has since shut in Well 32RD and has no plans to place back on injection. Instead, Chevron plans to plug and abandon the existing wellbore in preparation for a redrill and completion as an oil producer. Consequently, Administrative Approval AIO 6.006 no longer applies to operation of this well. DONE at Anchorage, Alaska and dated February 6, 2008. IR Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 John Levorsen 200 North 3rd Street, #1202 Boise, ID 83702 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 Ivan Gillian 9649 Musket Bell Cr.#5 Anchorage, AK 99507 Jack Hakkila PO Box 190083 Anchorage, AK 99519 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 Cliff Burglin PO Box 70131 Fairbanks, AK 99707 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 David McCaleb Cindi Walker IHS Energy Group Tesoro Refining and Marketing Co. GEPS Supply & Distribution 5333 Westheimer, Ste 100 300 Concord Plaza Drive Houston, TX 77056 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 Michael Parks Mark Wedman Marple's Business Newsletter Halliburton 117 West Mercer St, Ste 200 6900 Arctic Blvd. Seattle, WA 98119-3960 Anchorage, AK 99502 Schlumberger Ciri Drilling and Measurements Land Department 2525 Gambell Street #400 PO Box 93330 Anchorage, AK 99503 Anchorage, AK 99503 Jill Schneider Gordon Severson US Geological Survey 3201 Westmar Cr. 4200 University Dr. Anchorage, AK 99508-4336 Anchorage, AK 99508 Darwin Waldsmith James Gibbs PO Box 39309 PO Box 1597 Ninilchick, AK 99639 Soldotna, AK 99669 Penny Vadla Richard Wagner 399 West Riverview Avenue PO Box 60868 Soldotna. AK 99669-7714 Fairbanks, AK 99706 Bernie Karl North Slope Borough K&K Recycling Inc. PO Box 69 PO Box 58055 Barrow, AK 99723 Fairbanks, AK 99711 Ile Page 1 of 1 a Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Wednesday, February 06, 2008 3:51 PM Subject: Cancelled Administrative Approval AlO 6-6 Granite Point Attachments: aio6-6 cancelled.pdf BCC:Cynthia B Mciver (bren.mciver@alaska.gov);'Alan Birnbaum <""Alan J Birnbaum "> (alan.bimbaum@alaska.gov)'; 'Aleutians East Borough'; 'Anna Raff ; Arion, Teri A (DNR); 'Arthur C Saltmarsh'; 'Arthur Copoulos'; 'Barbara F Fullmer'; 'bbritch'; 'Bill Walker'; 'Brad McKim'; 'Brandon Gagnon'; 'Brian Gillespie'; 'Brian Havelock'; 'Brit Lively'; 'Bruce Webb'; 'buonoje'; 'Cammy Taylor'; 'Cande.Brandow'; 'carol smyth'; 'Cary Carrigan'; caunderwood@marathonoil.com; 'Charles O'Donnell'; 'Chris Gay'; 'Christian Gou-Leonhardt'; 'Cliff Posey'; 'Dan Bross'; 'dapa'; 'Daryl J. Kleppin'; 'David Brown'; 'David Hall'; 'David L Boelens'; 'David Steingreaber'; 'ddonkel'; 'Deanna Gamble'; 'Deborah J. Jones'; 'doug_schultze'; 'Evan Harness'; 'eyancy'; Toms2@mtaonline.net'; 'Francis S. Sommer'; 'Fred Steece'; 'Garland Robinson'; 'Gary Laughlin'; 'Gary Rogers'; 'Gary Schultz'; 'ghammons'; 'Gordon Pospisil'; 'Gregg Nady'; 'gregory micallef ; 'gspfoff ; 'Hank Alford'; 'Harry Engel'; Jah'; 'James B Regg'; 'James M. Ruud'; 'James Scherr'; 'Janet D. Platt'; Jdarlington'; 'jejones'; 'Jerry McCutcheon'; 'Jim White'; 'Jim Winegamer'; 'Joe Nicks'; 'John Garing'; 'John S. Haworth'; 'John Spain'; 'John Tower'; 'John W Katz'; johnny.aiken@north-slope.org; 'Jon Goltz'; 'Julie Houle'; 'Kari Moriarty'; 'Kaynell Zeman'; 'Keith Wiles'; ,knelson@petroleumnews.com; 'Kristin Dirks'; 'Laura Silliphant'; 'Lois'; 'Lynnda Kahn'; 'mail=akpratts@acsalaska.net'; 'mail=crockett@aoga.org'; 'mail=foms@mtaonline.net'; 'Mark Dalton'; 'Mark Hanley'; 'Mark Kovac'; 'Mark P. Worcester'; 'Marguerite kremer'; 'marty'; 'Matt Rader'; 'mckay'; 'Meghan Powell'; 'Mike Bill'; 'Mike Mason'; 'Mikel Schultz'; 'Mindy Lewis'; 'MJ Loveland'; 'mjnelson'; 'mkm7200'; 'Nick W. Glover'; NSK Problem Well Supv; NSU, ADW Well Integrity Engineer; 'Patty Alfaro'; 'Paul Decker'; Pierce, Sandra M (DNR); 'Randall Kanady'; 'Randy L. Skillern'; 'rcrotty'; Rice, Cody J (DNR); 'rmclean'; rob.g.dragnich@exxonmobil.com; 'Robert Campbell'; 'Robert Fowler'; 'Robert Province'; 'Roger Belman'; 'Rudy Brueggeman'; 'Scott Cranswick'; 'Shannon Donnelly'; 'Sharmaine Copeland'; 'Sondra Stewman'; 'Sonja Frankllin'; 'Stan Porhola'; 'stanekj'; 'Stephen F Davies'; 'Steve Lambert'; 'Steve Moothart'; 'Steven R. Rossberg'; 'tablerk'; 'Tamers Sheffield'; 'Temple Davidson'; 'Terrie Hubble'; 'Tim Lawlor'; 'Todd Durkee'; 'trmjrl'; 'Walter Featherly'; 'Walter Quay'; 'Wayne Rancier' Attachments: aio6-6 cancelled.pdf; Jody Colombie Special Assistant Alaska Oil & Gas Conservation Commission Direct: 907-793-1221 Fax: 907-276-7542 *Note new email address 2/7/2008 • i o ALASKA FRANK H. MURKOWSKI, GOVERNOR ALA KA OIL AND GAS 333 W. 7T AVENUE, SUITE 100 CONSERVATION COMNIISSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL AIO 6.007 Mr. Larry Greenstein Production Technician Unocal Alaska P.O. Box 196247 Anchorage, AK 99519-6247 RE: Granite Point State 18742 #38 [aka Anna #38] (PTD 188-034) Request for Administrative Approval AIO 6 Dear Mr. Greenstein: Per Rule 9 of Area Injection Order ("AIO") 006, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants Unocal Alaska. ("Unocal")'s request for administrative approval for water injection in the subject well. AOGCC finds the following: 1. The subject well is not completed with a packer and there is no plan to workover the well to install a packer. 2. Several similarly equipped wells on Anna Platform were previously converted to service wells beginning in 2000 according to a procedure developed by Unocal and approved by the Commission. 3. Unocal was authorized to convert Anna 38 from producer to injector via Sundry permit 300-219 approved October 25, 2000. 4. As required by the conversion Sundry permit, Unocal has been recording daily in- jection rates and well pressures and has been reporting this information to the Commission monthly. In support of this application, Unocal has submitted the re- sults of temperature logs obtained in compliance with conversion sundry and a graphical maximum operating pressure determination. 5. Based upon analysis of the submitted logging information, there are no tempera- ture anomalies indicated. The monthly rate/pressure information has not indi- cated any pressure integrity loss. 6. The original analysis performed for the conversion in October 2000 is still valid. 7. An aquifer exemption is in effect below Cook Inlet for Granite Point Field [40 CFR 147.102(b)(2)(i).] Mr. Larry Greenstein • March 29, 2005 Page 2 of 2 Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety. AOGCC's administrative approval to continue water injection in Granite Point State 18742 #38 [aka Anna #38] is conditioned upon the following: 1. Injection is limited to WATER ONLY; 2. Unocal shall monitor and record wellhead pressures [T/I/O] (tubing/inner annu- lus/outer annulus) and injection rate daily and submit this information to the Commission monthly; 3. Unocal shall perform a temperature log every two years to demonstrate continued production casing integrity; 4. Unocal shall immediately shut in the well and notify the AOGCC upon any meas- urable change in well outer annulus pressure or any change in the rate/pressure re- lationship for the tubing/IA; and 5. After well shut in, AOGCC approval shall be required to restart injection. As provided in AS 31.05.080, within 20 days after written notice of this 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 rehearing. A request for rehearing is consid- ered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Chairman Alaska and dated March 29, 2005. \_ Daniel T. Seamount, Jr. Commissioner Vp Citgo Petroleum Corporation Mary Jones David McCaleb PO Box 3758 XTO Energy, Inc. IHS Energy Group Tulsa, OK 74136 Cartography GEPS 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 Ft. Worth, TX 76102-6298 Houston, TX 77056 Mona Dickens Robert Gravely George Vaught, Jr. Tesoro Refining and Marketing Co. 7681 South Kit Carson Drive PO Box 13557 Supply & Distribution Littleton, CO 80122 Denver, CO 80201-3557 300 Concord Plaza Drive San Antonio, TX 78216 Jerry Hodgden Richard Neahring John Levorsen Hodgden Oil Company NRG Associates 200 North 3rd Street, #1202 408 18th Street President Boise, ID 83702 Golden, CO 80401-2433 PO Box 1655 Colorado Springs, CO 80901 Kay Munger Samuel Van Vactor Michael Parks Munger Oil Information Service, Inc Economic Insight Inc. Marple's Business Newsletter PO Box 45738 3004 SW First Ave. 117 West Mercer St, Ste 200 Los Angeles, CA 90045-0738 Portland, OR 97201 Seattle, WA 98119-3960 Mark Wedman Schlumberger David Cusato Halliburton Drilling and Measurements 200 West 34th PMB 411 6900 Arctic Blvd. 2525 Gambell Street #400 Anchorage, AK 99503 Anchorage, AK 99502 Anchorage, AK 99503 Ciri Baker Oil Tools Ivan Gillian Land Department 4730 Business Park Blvd., #44 9649 Musket Bell Cr.#5 PO Box 93330 Anchorage, AK 99503 Anchorage, AK 99507 Anchorage, AK 99503 Jill Schneider Gordon Severson Jack Hakkila US Geological Survey 3201 Westmar Cr. PO Box 190083 4200 University Dr. Anchorage, AK 99508-4336 Anchorage, AK 99519 Anchorage, AK 99508 Darwin Waldsmith James Gibbs Kenai National Wildlife Refuge PO Box 39309 PO Box 1597 Refuge Manager Ninilchick, AK 99639 Soldotna, AK 99669 PO Box 2139 Soldotna, AK 99669-2139 Penny Vadla Richard Wagner Cliff Burglin 399 West Riverview Avenue PO Box 60868 PO Box 70131 Soldotna, AK 99669-7714 Fairbanks, AK 99706 Fairbanks, AK 99707 Bernie Karl Williams Thomas North Slope Borough K&K Recycling Inc. Arctic Slope Regional Corporation PO Box 69 PO Box 58055 Land Department Barrow, AK 99723 Fairbanks, AK 99711 PO Box 129 Barrow. AK 99723 Various Administrative Approvals Subject: Various Administrative Approvals From: Jody Colombie <Jody_colombie@admin.state. ak.us> Date: Wed, 30 Mar 2005 13:25:04 -0900 To: undisclosed -recipients:; BCC: Cynthia B Mciver<bren_mciver@admin.state. ak.us>, Robert E Mintz <robert mintz@law. state.ak.us>, Christine Hansen <c.hansen@iogcc. state. ok.us>, Terrie Hubble <hubbletl@bp.com>, Sondra Stewman <StewmaSD@BP.com>, Scott & Cammy Taylor <staylor@alaska.net>, stanekj <stanekj@unocal.com>, ecolaw <ecolaw@trustees.org>, roseragsdale <roseragsdale@gci.net>, trmjrl <trmjrl@aol.com>, jbriddle <jbriddle@marathonoil.com>, shaneg <shaneg@evergreengas.com>, jdarlington <jdarlington@forestoil.com>, nelson <knelson@petroleumnews.com>, cboddy <cboddy@usibelli.com>, Mark Dalton <mark. dalton@hdrinc. com>, Shannon Donnelly <shannon.donnelly@conocophillips.com>, "Mark P. Worcester" <mark.p.worcester@conocophillips.com>, Bob <bob@inletkeeper.org>, wdv <wdv@dnr. state. ak.us>, tjr <tj r@dnr. state. ak.us>, bbritch <bbritch@alaska.net>, mjnelson <mjnelson@purvingertz.com>, Charles O'Donnell <charles.o'donnell@veco.com>, "Randy L. Skillern" <SkilleRL@BP.com>, "Deborah J. Jones" <JonesD6@BP.com>, "Paul G. Hyatt" <hyattpg@BP.com>, "Steven R. Rossberg" <RossbeRS@BP.com>, Lois <lois@inletkeeper.org>, Dan Bross <kuacnews@kuac.org>, Gordon Pospisil <PospisG@BP.com>, "Francis S. Sommer" <SommerFS@BP.com>, Mikel Schultz <Mikel.Schultz@BP.com>, "Nick W. Glover" <GloverNW@BP.com>, "Daryl J. Kleppin" <KleppiDE@BP.com>, "Janet D. Platt" <PlattJD@BP.com>, "Rosanne M. Jacobsen" <JacobsRM@BP.com>, ddonkel <ddonkel@cfl.rr.com>, Collins Mount <collins_mount@revenue. state.ak.us>, mckay <mckay@gci.net>, Barbara F Fullmer <barbara.f.fullmer@conocophillips.com>, bocastwf <bocastwf@bp.com>, Charles Barker <barker@usgs.gov>, doug_schultze <doug_schultze@xtoenergy.com>, Hank Alford <hank. alford@exxonmobil. com>, Mark Kovac <yesnoI @gci.net>, gspfoff <gspfoff@aurorapower.com>, Gregg Nady <gregg.nady@shell.com>, Fred Steece <fred.steece@state.sd.us>, rcrotty <rcrotty@ch2m.com>, jejones <jejones@aurorapower.com>, dapa <dapa@alaska.net>, jroderick <jroderick@gci.net>, eyancy <eyancy@seal-tite.net>, "James M. Ruud" <james.m.ruud@conocophillips.com>, Brit Lively <mapalaska@ak.net>, jah <j ah@dnr. state. ak.us>, Kurt E Olson <kurt_olson@legis.state.ak.us>, buonoje <buonoje@bp.com>, Mark Hanley <mark_hanley@anadarko.com>, loren_leman <loren_leman@gov.state. ak.us>, Julie Houle <julie_houle@dnr.state. ak.us>, John W Katz <jwkatz@sso.org>, Suzan J Hill <Suzan_hill@dec.state. ak.us>, tablerk <tablerk@unocal.com>, Brady <brady@aoga.org>, Brian Havelock <beh@dnr.state.ak.us>, bpopp <bpopp@borough.kenai.ak.us>, Jim White <jimwhite@satx.rr.com>, "John S. Haworth" <john.s.haworth@exxonmobil.com>, marty <marty@rkindustrial.com>, ghammons <ghammons@aol.com>, rmclean <rmclean@pobox.alaska.net>, mkm7200 <mkm7200@aol.com>, Brian Gillespie <ifbmg@uaa.alaska.edu>, David L Boelens <dboelens@aurorapower.com>, Todd Durkee <TDURKEE@KMG.com>, Gary Schultz <gary_schultz@dnr. state. ak.us>, Wayne Rancier <RANCIER@petro-canada.ca>, Bill Miller <Bill_Miller@xtoalaska.com>, Brandon Gagnon <bgagnon@brenalaw.com>, Paul Winslow <pmwinslow@forestoil.com>, Garry Catron <catrongr@bp.com>, Sharmaine Copeland <copelasv@bp.com>, Kristin Dirks<kristin_dirks@dnr.state. ak.us>, Kaynell Zeman <kjzeman@marathonoil.com>, John Tower <John.Tower@eia.doe. gov>, Bill Fowler <Bill_Fowler@anadarko.COM>, Vaughn Swartz <vaughn.swartz@rbccm.com>, Scott Cranswick <scott.cranswick@mms.gov>, Brad McKim <mckimbs@BP.com>, Steve Lambe 1 of 3 3/30/2005 3:10 PM IVarious Administrative Approvals . 0 <lambes@unocal.com>, jack newell <jack.newell@acsalaska.net>, James Scherr <James.Scherr@mms.gov>, david roby <David. Roby@mms. gov>, Tim Lawlor <Tim_Lawlor@ak.blm.gov>, Lynnda Kahn <Lynnda_Kahn@fws.gov>, Jerry Dethlefs <Jerry. C. Dethlefs@conocophillips. com>, Jerry Dethlefs <n1617@conocophillips.com>, crockett@aoga.org, Tamera Sheffield <sheffield@aoga.org>, Jon Goltz <Jon.Goltz@conocophillips.com>, Roger Belman <roger.belman@conocophillips.com>, Mindy Lewis <mlewis@brenalaw.com>, Harry Lampert <harry. lampert@honeywell. com> AIO5.002.pdf Content -Type: application/pdf Content -Encoding: base64 Content -Type: application/pdf AIO6.009.pdf Content -Encoding: base64 AIO6.006.pdf Content -Type: application/pdf Content -Encoding: base64 AIO6.008.pdf Content -Type: application/pdf Content -Encoding: base64 AIO6.005.pdf Content -Type: application/pdf Content -Encoding: base64 Content -Type: application/pdf AIO 6.004.pdf Content -Encoding: base64 AIO6.007.pdf Content -Type: application/pdf Content -Encoding: base64 2 of 3 3/30/2005 3:10 PM Various Administrative Approvals AIO5.003.pdf Content -Type: application/pdf Content -Encoding: base64 Content -Type: application/pdf AIO11.003.pdf Content -Encoding: base64 AIO2B.03.pdf Content -Type: application/pH Content-Encoding: base64 3 of 3 3/30/2005 3:10 PM • ALASKA ®IL AND GAS CO NSL+"RVA9CION C®MMSSI®N SARAH PALIN, GOVFRNOR 333 VV 7th AVENUE, surrE 100 ANCI-10RAGE,ALASKA 99501-3539 N110NE (907) 279-1433 rAX (907) 276-7542 ADMINISTRATIVE APPROVAL AIO 6.003 (Revised) ADMINISTRATIVE APPROVAL AIO 6.004 (Revised) ADMINISTRATIVE APPROVAL AIO 6.007 (Revised) ADMINISTRATIVE APPROVAL AIO 6.008 (Revised) ADMINISTRATIVE APPROVAL AIO 6.009 (Revised) Mr. J. Hal Martin Optimization Engineer Union Oil Company of California PO Box 196247 Anchorage, Alaska 99519-6247 RE: Request for Administrative Approval Revision Dear Mr. Martin: Union Oil Company of California (Union) requests a permanent revision to the anniversary date for temperature surveys for water injection wells located on the Anna Platform (Granite Point Field). The Alaska Oil and Gas Conservation Commission (Commission) approves Union's request to change the anniversary date for temperature surveys in the following wells from March 29 to May 20: - Granite Pt. State 18742 Well No. 5; PTD 1670140; AIO 6.003; - Granite Pt. State 18742 Well No. 19; PTD 1680060; AIO 6.008; - Granite Pt. State 18742 Well No. 21; PTD 1760490; AIO 6.009; - Granite Pt. State 18742 Well No. 25; PTD 1680360; AIO 6.004; - Granite Pt. State 18742 Well No. 38; PTD 1880340; AIO 6.007. The Commission granted administrative approvals to Union allowing temperature surveys every 2 years in lieu of pressure tests of the tubing -casing annulus. Temperature surveys are intended to demonstrate that injected fluids are exiting the wellbore and remaining confined as required by Area Injection Order 6.000. Union argues that performing temperature surveys in May will allow warmer weather conditions to improve the slickline operations on these water injection wells. Daily Surveillance of wellhead pressures and injection rates with monthly reporting to the Commission — mandated by the administrative approvals — provide for early detection and action regarding any deterioration of well integrity that might occur during the 2-year interval between fir, .i-ial [Martin • • M arch ; 1 , 2009 1j rise 01 terriperat>tre surveys, Ad-ministrative approvals also require Union to immediately shul. in the well and notify the Commission if there is any mcasurahh°, change in the well's mechanical integrity. The Commission finds that moving the anniversary date for ter_riperattlre surveys from March 29 to May 20 will not compromise overall well integrity so as to threaten the environment or human safety. DONE at Anchorage, Alaska and dated March 31, 2009. 91-:�55 94, /!�� Daniel T. Seamount, Jr. Cathy . Foerster Chair Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[tlhe questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Page 1 of 1 Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Thursday, April 02, 2009 9:07 AM Subject: Revised AIO 6-003; AIO 6-004, AIO 6-007; AIO 6-008; AIO 6-009 (all combined on one admin approval) Attachments: aio6 revised admin approval.pdf BCC:'Aaron Gluzman'; caunderwood@marathonoil.com; 'Dale Hoffman'; Fridiric Grenier; 'Gary Orr'; 'Joe Longo'; 'Lamont Frazer'; Marc Kuck; 'Mary Aschoff; Maurizio Grandi; P Bates; Richard Garrard; 'Sandra Lemke'; 'Scott Nash'; 'Steve Virant'; Tom Gennings;'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'; 'Cary Carrigan'; 'Charles O'Donnell'; 'Chris Gay'; 'Cliff Posey'; 'Cody Rice'; 'Dan Bross'; 'dapa'; 'Daryl J. Kleppin'; 'David Brown'; 'David Gorney'; 'David Hall'; David House; 'David L Boelens'; 'David Steingreaber'; 'ddonkel'; Deborah Jones; 'doug_schultze'; 'Eric Lidji 'Evan Harness'; 'eyancy'; Toms2@mtaonline.net'; 'Francis S. Sommer'; 'Fred Steece'; 'Garland Robinson'; 'Gary Laughlin'; 'Gary Rogers'; 'Gary Schultz'; 'ghammons'; 'Gordon Pospisil'; 'Gregg Nady'; 'gspfoff ; 'Hank Alford'; 'Harry Engel'; 'jah'; 'James Scherr'; 'Janet D. Platt'; 'jejones'; 'Jerry McCutcheon'; 'Jim Arlington'; 'Jim White'; 'Jim Winegarner'; 'Joe Nicks'; 'John Garing'; 'John S. Haworth'; 'John Spain'; 'John Tower'; 'John W Katz'; johnny.aiken@north-slope.org; 'Jon Goltz'; 'Julie Houle'; 'Kari Moriarty'; 'Kaynell Zeman'; 'Keith Wiles'; knelson@petroleumnews.com; 'Krissell Crandall'; 'Kristin Dirks'; 'Laura Silliphant'; 'Lynnda Kahn'; 'mail=akpratts@acsalaska.net'; 'mail=foms@mtaonline.net'; 'Marilyn Crockett'; 'Mark Dalton'; 'Mark Hanley'; 'Mark Kovac'; 'Mark P. Worcester'; 'Marquerite kremer'; 'Matt Rader'; Melanie Brown; '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 Decker'; 'Paul Winslow'; Pierce, Sandra M (DNR); 'Randall Kanady'; 'Randy L. Skillern'; 'rcrotty'; 'rmclean'; 'Rob McWhorter'; rob.g.dragnich@exxonmobil.com; 'Robert Campbell'; 'Robert Province'; 'Roger Belman'; 'Rudy Brueggeman'; 'Scott Cranswick'; 'Shannon Donnelly'; 'Sharmaine Copeland'; 'Sondra Stewman'; 'Sonja Frankllin'; 'Stan Porhola'; 'stanekj'; 'Steve Lambert'; 'Steve Moothart'; 'Steven R. Rossberg'; 'tablerk'; 'Tamera Sheffield'; 'Temple Davidson'; 'Terrie Hubble'; Thompson, Nan G (DNR); 'Tim Lawlor'; 'Todd Durkee'; Tony Hopfinger; 'trmjrl'; Von Gemmingen, Scott E (DOR); 'Walter Featherly'; 'Walter Quay'; 'Wayne Rancier'; Birnbaum, Alan J (LAW); Crisp, John H (DOA); Davies, Stephen F (DOA); Fleckenstein, Robert J (DOA); Foerster, Catherine P (DOA); Grimaldi, Louis R (DOA); Johnson, Elaine M (DOA); Jones, Jeffery B (DOA); Laasch, Linda K (DOA); Mahnken, Christine R (DOA); Maunder, Thomas E (DOA); McIver, 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); Seamount, Dan T (DOA); Smith, Chasity R (DOA); Williamson, Mary J (DOA) Attachments: aio6 revised admin approval.pdf, fyi Jody J. Colombie Special Assistant Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 (907)793-1221 (phone) (907)276-7542 (fax) 4/2/2009 Mary Jones David McCaleb Cindi Walker XTO Energy, Inc. IHS Energy Group Tesoro Refining and Marketing Co. Cartography GEPS Supply & Distribution 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 300 Concord Plaza Drive Ft. Worth, TX 76102-6298 Houston, TX 77056 San Antonio, TX 78216 George Vaught, Jr. Jerry Hodgden Richard Neahring PO Box 13557 Hodgden Oil Company NRG Associates Denver, CO 80201-3557 408 18th Street President Golden, CO 80401-2433 PO Box 1655 Colorado Springs, CO 80901 Mark Wedman Schlumberger Ciri Halliburton Drilling and Measurements Land Department 6900 Arctic Blvd. 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 Darwin 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 0 0 2 ME O ALASKA SEAN PARNELL, GOVERNOR ALASFA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERQATION C011"IISSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL AREA INJECTION ORDER 6.007 AMENDED Mr. Larry Greenstein Regulatory Compliance Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: Request for Administrative Approval Amendment Granite Point State 18742 Well 38 (PTD 1880340) Granite Point, Middle Kenai Oil Pool Dear Mr. Greenstein: Hilcorp Alaska, LLC (Hilcorp) requests a permanent revision to the anniversary date for temperature surveys for water injection wells located on the Anna Platform (Granite Point Field). The Alaska Oil and Gas Conservation Commission (AOGCC) approves Hilcorp's request to change the anniversary date for wellbore temperature surveys in Granite Point State 18742 Well 38 (Anna 38) from May 20 of odd numbered years to August of even numbered years. The next temperature survey for Anna 38 is due August 25, 2012. Administrative Approval AIO 6.007 authorized continued water injection into Anna 38 subject to wellbore temperature surveys at a 2-year interval in lieu of pressure testing the tubing -casing annulus. Anna 38 is one of several packerless wells on the Granite Point State "Anna" platform converted from production to injection. The style of completion prevents performing a conventional mechanical integrity pressure test. Temperature surveys are intended to demonstrate that injected fluids are exiting the wellbore and remaining confined as required by Area Injection Order 6.000. Amended Administrative Approval AIO 6.007 dated March 31, 2009 established a new schedule for Anna 38, allowing the wireline survey work to be conducted in May instead of March to take advantage of warmer weather. Temperature surveys performed on April 5, 2007 and August 25, 2010, and pressure monitoring data indicate injected fluids continue to be confined to the injection zone. Administrative Approval 6.007 as amended requires Anna 38 to be immediately shut in if there is any measurable change in the well's mechanical integrity. Daily surveillance of wellhead pressures and injection rates with monthly reporting to the AOGCC — mandated by the administrative approval — provide for early detection and action 1 Water flood injection has been shut down on Anna platform since January 2008 due to surface facility issues; consequently Anna 38 has been shut in until the water flood injection can be restored. 0 AIO 6.007 Amended March 5, 2012 Page 2 of 2 regarding any deterioration of well integrity that might occur during the 2-year interval between temperature surveys. The AOGCC finds that moving the anniversary date for temperature surveys to August of even numbered years will not compromise overall well integrity so as to threaten the environment or human safety. DONE at Anchorage, Alaska and dated March 5, 2012. Cathy P. Foerster Chair, Commissioner 11� Daniel T. Seamount, Jr. Commissioner RECONSIDERATION AND APPEAL As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. • Mary Jones David McCaleb XTO Energy, Inc. IHS Energy Group George Vaught, Jr. Cartography GEPS P.O. Box 13557 810 Houston Street, Ste 200 5333 Westheimer, Suite 100 Denver, CO 80201-3557 Ft. Worth, TX 76102-6298 Houston, TX 77056 Jerry Hodgden Richard Neahring Mark Wedman Hodgden Oil Company NRG Associates Halliburton 408 18th Street President 6900 Arctic Blvd. Golden, CO 80401-2433 P.O. Box 1655 Anchorage, AK 99502 Colorado Springs, CO 80901 Bernie Karl CIRI K&K Recycling Inc. Land Department 795 Baker Oil hoofs P.O. Box 58055 P.O. Box 93330 E. 94 Ct. Anchorage, Fairbanks, AK 99711 Anchorage, AK 99503 Anchorage, AK 99515-4295 North Slope Borough Richard Wagner Gordon Severson Planning Department P.O. Box 60868 3201 Westmar Circle P.O. Box 69 Fairbanks, AK 99706 Anchorage, AK 99508-4336 Barrow, AK 99723 Jack Hakkila Darwin Waldsmith James Gibbs P.O. Box 190083 P.O. Box 39309 P.O. Box 1597 Anchorage, AK 99519 Ninilchick, AK 99639 Soldotna, AK 99669 Penny Vadla 399 West Riverview Avenue Soldotna, AK 99669-7714 Cliff Burglin 319 Charles Street Fairbanks, AK 99701 0 i Fisher, Samantha J (DOA) From: Fisher, Samantha J (DOA) Sent: Tuesday, March 06, 2012 4:03 PM To: 'Aaron Gluzman'; 'Ben Greene'; 'Bruce Williams'; Bruno, Jeff J (DNR); 'CA Underwood'; 'Casey Sullivan'; 'Dale Hoffman'; 'David Lenig'; 'Donna Vukich'; 'Eric Lidji'; Franger, James M (DNR); 'Gary Orr'; 'Graham Smith'; 'Greg Mattson'; Heusser, Heather A (DNR); 'Jason Bergerson'; 'Jennifer Starck'; 'Jill McLeod'; 'Joe Longo'; 'Kim Cunningham'; King, Kathleen J (DNR); 'Lara Coates', 'Lois Epstein'; 'Marc Kuck'; 'Marie Steele'; 'Mary Aschoff; 'Matt Gill'; 'Maurizio Grandi'; Ostrovsky, Larry Z (DNR); 'Patricia Bettis'; Perrin, Don J (DNR); 'Peter Contreras'; Pexton, Scott R (DEC); 'Richard Garrard'; 'Ryan Daniel'; 'Sandra Lemke'; 'Talib Syed'; 'Ted Rockwell'; 'Wayne Wooster'; 'Wendy Wollf; 'William Hutto'; 'William Van Dyke'; '(michael.j.nelson@conocophillips.com)'; '(Von.L.Hutchins@conocophillips.com)'; 'AKDCWelllntegrityCoordinator'; 'Alan Dennis'; 'alas ka@petrocalc. com'; 'Anna Raff; 'Barbara F Fullmer'; 'bbritch'; 'Becky Bohrer'; 'Bill Penrose'; 'Bill Walker'; 'Bowen Roberts'; 'Brandon Gagnon'; 'Brandow, Cande (ASRC Energy Services)'; 'Brian Havelock'; 'Bruce Webb'; 'Chris Gay'; 'Claire Caldes'; 'Cliff Posey'; 'Crandall, Krissell'; 'D Lawrence'; 'dapa'; 'Daryl J. Kleppin'; 'Dave Harbour'; 'Dave Matthews'; 'David Boelens'; 'David House'; 'David Scott'; 'David Steingreaber'; 'ddonkel@cfl.rr.com'; 'Dennis Steffy'; 'Elowe, Kristin'; 'Erika Denman'; 'Francis S. Sommer'; 'Fred Steece'; 'Garland Robinson'; 'Gary Laughlin'; 'Gary Schultz (gary.schultz@alaska.gov)'; 'ghammons'; 'Gordon Pospisil'; 'Gorney, David L.'; 'Greg Duggin'; 'Gregg Nady'; 'Gregory Geddes'; 'gspfoff; 'Jdarlington Qarlington@gmail.com)'; 'Jeanne McPherren'; 'Jeff Jones'; 'Jeffery B. Jones (jeff.jones@alaska.gov)'; 'Jerry McCutcheon'; 'Jill Womack'; 'Jim White'; 'Jim Winegarner'; 'Joe Nicks'; 'John Easton'; 'John Garing'; 'John Katz (john.katz@alaska.gov)'; 'John S. Haworth'; 'John Spain'; 'Jon Goltz'; Jones, Jeffrey L (GOV); 'Judy Stanek'; 'Julie Houle'; 'Kari Moriarty'; 'Kaynell Zeman'; 'Keith Wiles'; 'Kelly Sperback'; 'Kim Cunningham'; 'Larry Ostrovsky'; 'Laura Silliphant (laura.gregersen@alaska.gov)'; 'Marc Kovak'; 'Mark Dalton'; 'Mark Hanley (mark.hanley@anadarko.com)'; 'Mark P. Worcester'; 'Marquerite kremer (meg.kremer@alaska.gov)'; 'Michael Dammeyer'; 'Michael Jacobs'; 'Mike Bill'; 'Mike Mason'; 'Mike Morgan'; 'Mike) Schultz'; 'Mindy Lewis'; 'MJ Loveland'; 'mjnelson'; 'mkm7200'; 'nelson'; 'Nick W. Glover'; 'NSK Problem Well Supv'; 'Patty Alfaro'; 'Paul Decker (paul.decker@alaska.gov)'; 'Paul Figel'; 'Randall Kanady'; 'Randy L. Skillern'; 'Rena Delbridge'; 'Renan Yanish';'rob.g.drag nich@exxonmobil. com'; 'Robert Brelsford'; 'Robert Campbell'; 'Ryan Tunseth'; 'Scott Cranswick'; 'Scott Griffith'; 'Shannon Donnelly'; 'Sharmaine Copeland'; Shellenbaum, Diane P (DNR); Slemons, Jonne D (DNR); 'Sondra Stewman'; 'Steve Lambert'; 'Steve Moothart (steve.moothart@alaska.gov)'; 'Steven R. Rossberg'; 'Suzanne Gibson'; 'tablerk'; 'Tamers Sheffield'; Taylor, Cammy O (DNR); 'Temple Davidson'; 'Teresa Imm'; 'Terrie Hubble'; 'Thor Cutler'; 'Tim Mayers'; 'Tina Grovier'; 'Todd Durkee'; 'Tony Hopfinger'; 'trmjr1'; 'Vicki Irwin'; 'Walter Featherly'; 'Will Chinn'; Williamson, Mary J (DNR); 'Yereth Rosen'; Ballantine, Tab A (LAW); Bender, Makana K (DOA); 'Brooks, Phoebe L (DOA) (phoebe.brooks@alaska.gov)'; 'Colombie, Jody J (DOA) Qody.colombie@alaska.gov)'; 'Crisp, John H (DOA) (john.crisp@alaska.gov)'; 'Davies, Stephen F (DOA) (steve.davies@alaska.gov)'; 'Foerster, Catherine P (DOA) (cathy.foe rster@alaska.gov)'; 'Grimaldi, Louis R (DOA) (lou.grimaldi@alaska.gov)'; Herrera, Matt F (DOA); 'Johnson, Elaine M (DOA) (elaine.johnson@alaska.gov)'; 'Laasch, Linda K (DOA) (linda.laasch@alaska.gov)'; 'McIver, Bren (DOA) (bren.mciver@alaska.gov)'; 'McMains, Stephen E (DOA) (steve.mcmains@alaska.gov)'; Mumm, Joseph (DOA sponsored); 'Noble, Robert C (DOA) (bob.noble@alaska.gov)'; 'Norman, John K (DOA) (john.norman@alaska.gov)'; 'Okland, Howard D (DOA) (howard.okland@alaska.gov)'; 'Paladijczuk, Tracie L (DOA) (tracie.paladijczuk@alaska.gov)'; 'Pasqual, Maria (DOA) (maria.pasqual@alaska.gov)'; 'Regg, James B (DOA) Qim.regg@alaska.gov)'; 'Roby, David S (DOA) (dave.roby@alaska.gov)'; 'Saltmarsh, Arthur C (DOA) (art. saltmarsh@alaska. gov)'; 'Scheve, Charles M (DOA) (chuck.scheve@alaska.gov)'; 'Schwartz, Guy L (DOA) (guy.schwartz@alaska.gov)'; 'Seamount, Dan T (DOA) (dan.seamount@alaska.gov)' Subject: aio 6-007 amended Granite Point Field Attachments: aio 6-007 amended.pdf • 1-n-1 a D ALASKA FRANK H. MURKOWSKI, GOVERNOR AILA►7KA OIL AND �17 333 W. 7'" AVENUE, SUITE 100 CONSERVATION COMMSSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 ADMINISTRATIVE APPROVAL AIO 6.008 FAX (907) 276-7542 Mr. Larry Greenstein Production Technician Unocal Alaska P.O. Box 196247 Anchorage, AK 99519-6247 RE: Granite Point State 18742 #19 [aka Anna #19] (PTD 168-006) Request for Administrative Approval AIO 6 Dear Mr. Greenstein: Per Rule 9 of Area Injection Order ("AIO") 006, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants Unocal Alaska. ("Unocal")'s request for administrative approval for water injection in the subject well. AOGCC finds the following: 1. The subject well is a "standard" tubing/packer completion. 2. The well was converted to injection service late 1998. From the record, it appears pressure communication has been present since the well was converted. 3. Since conversion, Unocal has been recording daily injection rates and well pres- sures and has been reporting this information to the Commission monthly. In support of this application, Unocal has submitted the results of temperature logs obtained in compliance with the conversions Sundry permit and a graphical maximum operating pressure determination. Prior to this action, Unocal was au- thorized to keep Anna 19 in service via sundry 303-043 approved April 15, 2003. 4. Based upon analysis of the submitted log information, there are no temperature anomalies indicated. The monthly rate/pressure information has not indicated any further pressure integrity loss. 5. At this time, Unocal is not proposing to repair the well to restore full integrity. 6. An aquifer exemption is in effect below Cook Inlet for Granite Point Field [40 CFR 147.102(b)(2)(i).] Based on analysis of the submitted information, the Commission concludes that Anna 19 exhibits two competent barriers to release of well pressure. Accordingly, the Commis- sion believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety. Mr. Larry Greenstein • March 29, 2005 Page 2 of 2 AOGCC's administrative approval to continue water injection in Granite Point State 18742 #19 [aka Anna #19] is conditioned upon the following: 1. Injection is limited to WATER ONLY; 2. Unocal shall monitor and record wellhead pressures [T/I/O] (tubing/inner annu- lus/outer annulus) and injection rate daily and submit this information to the Commission monthly; 3. Unocal shall perform a temperature log every two years to demonstrate continued production casing integrity; 4. Unocal shall immediately shut in the well and notify the AOGCC upon any meas- urable change in well outer annulus pressure or any change in the rate/pressure re- lationship for the tubing/IA; and 5. After well shut in, AOGCC approval shall be required to restart injection. As provided in AS 31.05.080, within 20 days after written notice of this 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 rehearing. A request for rehearing is consid- ered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. at o�ge, Alaska and dated March 29, 2005. A o Np. rman Daniel T. Seamount, Jr. Chairman Commissioner Citgo Petroleum Corporation Mary Jones David McCaleb PO Box 3758 XTO Energy, Inc. IHS Energy Group Tulsa, OK 74136 Cartography GEPS 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 Ft. Worth, TX 76102-6298 Houston, TX 77056 Mona Dickens Robert Gravely George Vaught, Jr. Tesoro Refining and Marketing Co. 7681 South Kit Carson Drive PO Box 13557 Supply & Distribution Littleton, CO 80122 Denver, CO 80201-3557 300 Concord Plaza Drive San Antonio, TX 78216 Jerry Hodgden Richard Neahring John Levorsen Hodgden Oil Company NRG Associates 200 North 3rd Street, #1202 408 18th Street President Boise, ID 83702 Golden, CO 80401-2433 PO Box 1655 Colorado Springs, CO 80901 Kay Munger Samuel Van Vactor Michael Parks Munger Oil Information Service, Inc Economic Insight Inc. Marple's Business Newsletter PO Box 45738 3004 SW First Ave. 117 West Mercer St, Ste 200 Los Angeles, CA 90045-0738 Portland, OR 97201 Seattle, WA 98119-3960 Mark Wedman Schlumberger David Cusato Halliburton Drilling and Measurements 200 West 34th PMB 411 6900 Arctic Blvd. 2525 Gambell Street #400 Anchorage, AK 99503 Anchorage, AK 99502 Anchorage, AK 99503 Ciri Baker Oil Tools Ivan Gillian Land Department 4730 Business Park Blvd., #44 9649 Musket Bell Cr.#5 PO Box 93330 Anchorage, AK 99503 Anchorage, AK 99507 Anchorage, AK 99503 Jill Schneider Gordon Severson Jack Hakkila US Geological Survey 3201 Westmar Cr. PO Box 190083 4200 University Dr. Anchorage, AK 99508-4336 Anchorage, AK 99519 Anchorage, AK 99508 Darwin Waldsmith James Gibbs Kenai National Wildlife Refuge PO Box 39309 PO Box 1597 Refuge Manager Ninilchick, AK 99639 Soldotna, AK 99669 PO Box 2139 Soldotna, AK 99669-2139 Penny Vadla Richard Wagner Cliff Burglin 399 West Riverview Avenue PO Box 60868 PO Box 70131 Soldotna, AK 99669-7714 Fairbanks, AK 99706 Fairbanks, AK 99707 Bernie Karl Williams Thomas North Slope Borough K&K Recycling Inc. Arctic Slope Regional Corporation PO Box 69 PO Box 58055 Land Department Barrow, AK 99723 Fairbanks, AK 99711 PO Box 129 Barrow, AK 99723 Various Administrative Approvals Subject: Various Administrative Approvals From: Jody Colombie <jody_colombie@admin.state.ak.us> Date: Wed, 30 Mar 2005 13:25:04 -0900 To: undisclosed -recipients:; BCC: Cynthia B Mciver<bren_mciver@admin.state. ak.us>, Robert E Mintz <robert_mintz@law. state.ak.us>, Christine Hansen <c.hansen@iogcc. state. ok.us>, Terrie Hubble <hubbletl@bp.com>, Sondra Stewman <StewmaSD@BP.com>, Scott & Cammy Taylor <staylor@alaska.net>, stanekj <stanekj@unocal.com>, ecolaw <ecolaw@trustees.org>, roseragsdale <roseragsdale@gci.net>, trmjrl <trmjrl@aol.com>, jbriddle <jbriddle@marathonoil.com>, shaneg <shaneg@evergreengas.com>, jdarlington <jdarlington@forestoil.com>, nelson <knelson@petroleumnews.com>, cboddy <cboddy@usibelli.com>, Mark Dalton <mark.dalton@hdrinc.com>, Shannon Donnelly <shannon.donnelly@conocophillips.com>, "Mark P. Worcester" <mark.p.worcester@conocophillips.com>, Bob <bob@inletkeeper.org>, wdv <wdv@dnr. state. ak.us>, tjr <tjr@dnr.state.ak.us>, bbritch <bbritch@alaska.net>, mjnelson <mjnelson@purvingertz.com>, Charles O'Donnell <charles.o'donnell@veco.com>, "Randy L. Skillern" <SkilleRL@BP.com>, "Deborah J. Jones" <JonesD6@BP.com>, "Paul G. Hyatt" <hyattpg@BP.com>, "Steven R. Rossberg" <RossbeRS@BP.com>, Lois <lois@inletkeeper.org>, Dan Bross <kuacnews@kuac.org>, Gordon Pospisil <PospisG@BP.com>, "Francis S. Sommer" <SommerFS@BP.com>, Mikel Schultz <Mikel.Schultz@BP.com>, "Nick W. Glover" <GloverNW@BP.com>, "Daryl J. Kleppin" <KleppiDE@BP.com>, "Janet D. Platt" <PlattJD@BP.com>, "Rosanne M. Jacobsen" <JacobsRM@BP.com>, ddonkel <ddonkel@cfl.rr.com>, Collins Mount <collins_mount@revenue. state. ak. us>, mckay <mckay@gci.net>, Barbara F Fullmer <barbara.£fullmer@conocophillips.com>, bocastwf <bocastwf@bp.com>, Charles Barker <barker@usgs.gov>, doug_schultze <doug_schultze@xtoenergy.com>, Hank Alford <hank. alford@exxonmobil. com>, Mark Kovac <yesnol@gci.net>, gspfoff <gspfoff@aurorapower.com>, Gregg Nady <gregg.nady@shell.com>, Fred Steece <fred.steece@state. sd.us>, rcrotty <rcrotty@ch2m.com>, jejones <jejones@aurorapower.com>, dapa <dapa@alaska.net>, jroderick <jroderick@gci.net>, eyancy <eyancy@seal-tite.net>, "James M. Ruud" <james.m.ruud@conocophillips.com>, Brit Lively <mapalaska@ak.net>, jah <jah@dnr.state.ak.us>, Kurt E Olson <kurt_olson@legis.state. ak.us>, buonoje <buonoje@bp.com>, Mark Hanley <mark_hanley@anadarko.com>, loren_leman <loren_leman@gov.state. ak.us>, Julie Houle <julie_houle@dnr.state.ak.us>, John W Katz <jwkatz@sso.org>, Suzan J Hill <suzan_hill@der.state. ak.us>, tablerk <tablerk@unocal.com>, Brady <brady@aoga.org>, Brian Havelock <beh@dnr. state. ak.us>, bpopp <bpopp@borough.kenai.ak.us>, Jim White <jimwhite@satx.rr.com>, "John S. Haworth" <john.s.haworth@exxonmobil.com>, marty <marty@rkindustrial.com>, ghammons <ghammons@aol.com>, rmclean <rmclean@pobox.alaska.net>, mkm7200 <mkm7200@aol.com>, Brian Gillespie <ifbmg@uaa.alaska.edu>, David L Boelens <dboelens@aurorapower.com>, Todd Durkee <TDURKEE@KMG.com>, Gary Schultz <gary_schultz@dnr. state. ak.us>, Wayne Rancier <RANCIER@petro-canada.ca>, Bill Miller <Bill_Miller@xtoalaska.com>, Brandon Gagnon <bgagnon@brenalaw.com>, Paul Winslow <pmwinslow@forestoil.com>, Garry Catron <catrongr@bp.com>, Sharmaine Copeland <copelasv@bp.com>, Kristin Dirks<kristin_dirks@dnr.state. ak.us>, Kaynell Zeman <kjzeman@marathonoil.com>, John Tower <John.Tower@eia.doe. gov>, Bill Fowler <Bill_Fowler@anadarko.COM>, Vaughn Swartz <vaughn.swartz@rbccm.com>, Scott Cranswick <scott.cranswick@mms.gov>, Brad McKim <mckimbs@BP.com>, Steve Lambe 1 of 3 3/30/2005 3:10 PM Various Administrative Approvals <lambes@unocal.com>, jack newell <jack.newell@acsalaska.net>, James Scherr <James.Scherr@mms.gov>, david roby <David.Roby@mms.gov>, Tim Lawlor <Tim_Lawlor@ak.blm.gov>, Lynnda Kahn <Lynnda_Kahn@fws.gov>, Jerry Dethlefs <Jerry.C.Dethlefs@conocophillips.com>, Jerry Dethlefs <n1617@conocophillips.com>, crockett@aoga.org, Tamera Sheffield <sheffield@aoga.org>, Jon Goltz <Jon. Goltz@conocophillips. com>, Roger Belman <roger.belman@conocophillips.com>, Mindy Lewis <mlewis@brenalaw.com>, Harry Lampert <harry. lampert@honeywell. com> AIO5.002.pdf Content -Type: application/pdf Content -Encoding: base64 AIO6.009.pdf Content -Type: application/pdf Content -Encoding: base64 AIO6.006.pdf Content -Type: application/pdf Content -Encoding: base64 AIO6.008.pdf Content -Type: application/pdf Content -Encoding: base64 AIO6.005.pdf Content -Type: application/pdf Content -Encoding: base64 AIO 6.004.pdf Content -Type: application/pdf Content -Encoding: base64 AIO6.007.pdf Content -Type: application/pdf Content -Encoding: base64 2 of 3 3/30/2005 3:10 PM Various Administrative Approvals r. • Content -Type: application/pdf AI05.003.pdf' Content -Encoding: base64 AIO11.003.pdf Content -Type: application/pdf Content -Encoding: base64 AIO2B.03.pdf Content -Type: application/pH Content-Encoding: base64 3 of 3 3/30/2005 3:10 PM C • O OT a ASKA SARAH PALIN, GOVERNOR ALAS KA 011L AND GALS 333 W 7thAVENUE, SUITE 100 CONSERVATION COI -ID ISSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL AIO 6.003 (Revised ADMINISTRATIVE APPROVAL AIO 6.004 (Revised) ADMINISTRATIVE APPROVAL AIO 6.007 (Revised) ADMINISTRATIVE APPROVAL AIO 6.008 (Revised) ADMINISTRATIVE APPROVAL AIO 6.009 (Revised) Mr. J. Hal Martin Optimization Engineer Union Oil Company of California PO Box 196247 Anchorage, Alaska 99519-6247 RE: Request for Administrative Approval Revision Dear Mr. Martin: Union Oil Company of California (Union) requests a permanent revision to the anniversary date for temperature surveys for water injection wells located on the Anna Platform (Granite Point Field). The Alaska Oil and Gas Conservation Commission (Commission) approves Union's request to change the anniversary date for temperature surveys in the following wells from March 29 to May 20: - Granite Pt. State 18742 Well No. 5; PTD 1670140; AIO 6.003; - Granite Pt. State 18742 Well No. 19; PTD 1680060; AIO 6.008; - Granite Pt. State 18742 Well No. 21; PTD 1760490; AIO 6.009; - Granite Pt. State 18742 Well No. 25; PTD 1680360; AIO 6.004; - Granite Pt. State 18742 Well No. 38; PTD 1880340; AIO 6.007. The Commission granted administrative approvals to Union allowing temperature surveys every 2 years in lieu of pressure tests of the tubing -casing annulus. Temperature surveys are intended to demonstrate that injected fluids are exiting the wellbore and remaining confined as required by Area Injection Order 6.000. Union argues that performing temperature surveys in May will allow warmer weather conditions to improve the slickline operations on these water injection wells. Daily surveillance of wellhead pressures and injection rates with monthly reporting to the Commission — mandated by the administrative approvals — provide for early detection and action regarding any deterioration of well integrity that might occur during the 2-year interval between Mr. Hal Martin • • March 31, 2009 Page 2 of 2 temperature surveys. Administrative approvals also require Union to immediately shut in the well and notify the Commission if there is any measurable change in the well's mechanical integrity. The Commission finds that moving the anniversary date for temperature surveys from March 29 to May 20 will not compromise overall well integrity so as to threaten the environment or human safety. DONE at Anchorage, Alaska and dated March 31, 2009. 6� 9 4 — Daniel T. Seamount, Jr. Cathy . Foerster Chair Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[tlhe questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5.00 p.m. on the next day that does not fall on a weekend or state holiday. 1 y r Page I of I Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Thursday, April 02, 2009 9:07 AM Subject: Revised AIO 6-003; AIO 6-004, AIO 6-007; AIO 6-008; A10 6-009 (all combined on one admin approval) Attachments: aio6 revised admin approval.pdf BCC:'Aaron Gluzman'; caunderwood@marathonoil.com; 'Dale Hoffman'; Fridiric Grenier; 'Gary Orr'; 'Joe Longo'; 'Lamont Frazer'; Marc Kuck; 'Mary Aschoff ; Maurizio Grandi; P Bates; Richard Garrard; 'Sandra Lemke'; 'Scott Nash'; 'Steve Virant'; Tom Gennings;'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'; 'Cary Carrigan'; 'Charles O'Donnell'; 'Chris Gay'; 'Cliff Posey'; 'Cody Rice'; 'Dan Bross'; 'dapa'; 'Daryl J. Kleppin'; 'David Brown'; 'David Gomey'; 'David Hall'; David House; 'David L Boelens'; 'David Steingreaber'; 'ddonkel'; Deborah Jones; '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'; 'James Scherr'; 'Janet D. Platt'; Jejones'; 'Jerry McCutcheon'; 'Jim Arlington'; 'Jim White'; 'Jim Winegarner'; 'Joe Nicks'; 'John Garing'; 'John S. Haworth'; 'John Spain'; 'John Tower'; 'John W Katz'; johnny.aiken@north-slope.org; 'Jon Goltz'; 'Julie Houle'; 'Kari Moriarty'; 'Kaynell Zeman'; 'Keith Wiles'; knelson@petroleumnews.com; 'Krissell Crandall'; 'Kristin Dirks'; 'Laura Silliphant'; 'Lynnda Kahn'; 'mail=akpratts@acsalaska.net'; 'mail=foms@mtaonline.net'; 'Marilyn Crockett'; 'Mark Dalton'; 'Mark Hanley'; 'Mark Kovac'; 'Mark P. Worcester'; 'Marquerite kremer'; 'Matt Rader'; Melanie Brown; '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 Decker'; 'Paul Winslow'; Pierce, Sandra M (DNR); 'Randall Kanady'; 'Randy L. Skillern'; 'rcrotty'; 'rmclean'; 'Rob McWhorter'; rob.g.dragnich@exxonmobil.com; 'Robert Campbell'; 'Robert Province'; 'Roger Belman'; 'Rudy Brueggeman'; 'Scott Cranswick'; 'Shannon Donnelly'; 'Sharmaine Copeland'; 'Sondra Stewman'; 'Sonja Frankllin'; 'Stan Porhola'; 'stanekj'; 'Steve Lambert'; 'Steve Moothart'; 'Steven R. Rossberg'; 'tablerk'; 'Tamera Sheffield'; 'Temple Davidson'; 'Terrie Hubble'; Thompson, Nan G (DNR); 'Tim Lawlor'; 'Todd Durkee'; Tony Hopfinger; 'trmjrl'; Von Gemmingen, Scott E (DOR); 'Walter Featherly'; 'Walter Quay'; 'Wayne Ranier'; Birnbaum, Alan J (LAW); Crisp, John H (DOA); Davies, Stephen F (DOA); Fleckenstein, Robert J (DOA); Foerster, Catherine P (DOA); Grimaldi, Louis R (DOA); Johnson, Elaine M (DOA); Jones, Jeffery B (DOA); Laasch, Linda K (DOA); Mahnken, Christine R (DOA); Maunder, Thomas E (DOA); McIver, 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); Seamount, Dan T (DOA); Smith, Chasity R (DOA); Williamson, Mary J (DOA) Attachments: aio6 revised admin approval.pdf; fyi Jody J. Colombie Special Assistant Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 (907)793-1221 (phone) (907)276-7542 (fax) 4/2/2009 Mary Jones David McCaleb Cindi Walker XTO Energy, Inc. IHS Energy Group Tesoro Refining and Marketing Co. Cartography GEPS Supply & Distribution 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 300 Concord Plaza Drive Ft. Worth, TX 76102-6298 Houston, TX 77056 San Antonio, TX 78216 George Vaught, Jr. Jerry Hodgden Richard Neahring PO Box 13557 Hodgden Oil Company NRG Associates Denver, CO 80201-3557 408 18th Street President Golden, CO 80401-2433 PO Box 1655 Colorado Springs, CO 80901 Mark Wedman Schlumberger Ciri Halliburton Drilling and Measurements Land Department 6900 Arctic Blvd. 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 Darwin 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 6 0 29OFALASKA FRANK H. MURKOWSKI, GOVERNOR ALA KA 01% AND GASS 333 W. 7`" AVENUE, SUITE 100 CONSERVATION COMMSSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL AIO 6.009 Mr. Larry Greenstein Production Technician Unocal Alaska P.O. Box 196247 Anchorage, AK 99519-6247 RE: Granite Point State 18742 #21 [aka Anna #21 ] (PTD 176-049) Request for Administrative Approval AIO 6 Dear Mr. Greenstein: Per Rule 9 of Area Injection Order ("AIO") 006, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants Unocal Alaska. ("Unocal")'s request for administrative approval for water injection in the subject well. AOGCC finds the following: 1. The subject well is not completed with a packer and there is no plan to workover the well to install a packer. 2. Several similarly equipped wells on Anna Platform were previously converted to service wells beginning in 2000 according to a procedure developed by Unocal and approved by the Commission. 3. Unocal was authorized to convert Anna 32RD from producer to injector via Sun- dry permit 300-214 approved September 28, 2000. 4. As required by the conversion Sundry permit, Unocal has been recording daily in- jection rates and well pressures and has been reporting this information to the Commission monthly. In support of this application, Unocal has submitted the re- sults of temperature logs obtained in compliance with conversion sundry and a graphical maximum operating pressure determination. 5. Based upon analysis of the submitted logging information, there are no tempera- ture anomalies indicated. The monthly rate/pressure information has not indi- cated any pressure integrity loss. 6. The original analysis performed for the conversion in September 2000 is still valid. 7. An aquifer exemption is in effect below Cook Inlet for Granite Point Field [40 CFR 147.102(b)(2)(i).] Mr. Larry Greenstein March 29, 2005 Page 2 of 2 Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety. AOGCC's administrative approval to continue water injection in Granite Point State 18742 #21 [aka Anna #21] is conditioned upon the following: 1. Injection is limited to WATER ONLY; 2. Unocal shall monitor and record wellhead pressures [T/I/O] (tubing/inner annu- lus/outer annulus) and injection rate daily and submit this information to the Commission monthly; 3. Unocal shall perform a temperature log every two years to demonstrate continued production casing integrity; 4. Unocal shall immediately shut in the well and notify the AOGCC upon any meas- urable change in well outer annulus pressure or any change in the rate/pressure re- lationship for the tubing/IA; and 5. After well shut in, AOGCC approval shall be required to restart injection. As provided in AS 31.05.080, within 20 days after written notice of this 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 rehearing. A request for rehearing is consid- ered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DONE at Alaska and dated March 29, 2005. Daniel T. Seamount, Jr. Commissioner • Citgo Petroleum Corporation Mary Jones David McCaleb PO Box 3758 XTO Energy, Inc. IHS Energy Group Tulsa, OK 74136 Cartography GEPS 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 Ft. Worth, TX 76102-6298 Houston, TX 77056 Mona Dickens Robert Gravely George Vaught, Jr. Tesoro Refining and Marketing Co. 7681 South Kit Carson Drive PO Box 13557 Supply & Distribution Littleton, CO 80122 Denver, CO 80201-3557 300 Concord Plaza Drive San Antonio, TX 78216 Jerry Hodgden Richard Neahring John Levorsen Hodgden Oil Company NRG Associates 200 North 3rd Street, #1202 408 18th Street President Boise, ID 83702 Golden, CO 80401-2433 PO Box 1655 Colorado Springs, CO 80901 Kay Munger Samuel Van Vactor Michael Parks Munger Oil Information Service, Inc Economic Insight Inc. Marple's Business Newsletter PO Box 45738 3004 SW First Ave. 117 West Mercer St, Ste 200 Los Angeles, CA 90045-0738 Portland, OR 97201 Seattle, WA 98119-3960 Mark Wedman Schlumberger David C:usato Halliburton Drilling and Measurements 200 West 34th PMB 411 6900 Arctic Blvd. 2525 Gambell Street #400 Anchorage, AK 99503 Anchorage, AK 99502 Anchorage, AK 99503 Ciri Baker Oil Tools Ivan Gillian Land Department 4730 Business Park Blvd., #44 9649 Musket Bell Cr.#5 PO Box 93330 Anchorage, AK 99503 Anchorage, AK 99507 Anchorage, AK 99503 Jill Schneider Gordon Severson Jack Hakkila US Geological Survey 3201 Westmar Cr. PO Box 190083 4200 University Dr. Anchorage, AK 99508-4336 Anchorage, AK 99519 Anchorage, AK 99508 Darwin Waldsmith James Gibbs Kenai National Wildlife Refuge PO Box 39309 PO Box 1597 Refuge Manager Ninilchick, AK 99639 Soldotna, AK 99669 PO Box 2139 Soldotna, AK 99669-2139 Penny Vadla Richard Wagner Cliff Burglin 399 West Riverview Avenue PO Box 60868 PO Box 70131 Soldotna. AK 99669-7714 Fairbanks, AK 99706 Fairbanks, AK 99707 Bernie Karl Williams Thomas North Slope Borough K&K Recycling Inc. Arctic Slope Regional Corporation PO Box 69 PO Box 58055 Land Department Barrow, AK 99723 Fairbanks, AK 99711 PO Box 129 Barrow, AK 99723 Various Administrative Approvals Subject: Various Administrative Approvals From: Jody Colombie<j ody_colombie@admin. state. ak.us> Date: Wed, 30 Mar 2005 13:25:04 -0900 To: undisclosed -recipients:; BCC: Cynthia B Mciver<bren_mciver@admin.state. ak.us>, Robert E Mintz <robert_mintz@law. state.ak.us>, Christine Hansen <c.hansen@iogcc.state. ok.us>, Terrie Hubble <hubbletl@bp.com>, Sondra Stewman <StewmaSD@BP.com>, Scott & Cammy Taylor <staylor@alaska.net>, stanekj <stanekj@unocal.com>, ecolaw <ecolaw@trustees.org>, roseragsdale <roseragsdale@gci.net>, trmjrl <trmjrl@aol.com>, jbriddle <jbriddle@marathonoil.com>, shaneg <shaneg@evergreengas.com>, jdarlington <jdarlington@forestoil.com>, nelson <knelson@petroleumnews.com>, cboddy <cboddy@usibelli.com>, Mark Dalton <mark. dalton@hdrinc. com>, Shannon Donnelly <shannon.donnelly@conocophillips.com>, "Mark P. Worcester" <mark.p.worcester@conocophillips.com>, Bob <bob@inletkeeper.org>, wdv <wdv@dnr. state. ak.us>, tjr <tj r@dnr. state. ak.us>, bbritch <bbritch@alaska.net>, mjnelson <mjnelson@purvingertz.com>, Charles O'Donnell <charles.o'donnell@veco.com>, "Randy L. Skillern" <SkilleRL@BP.com>, "Deborah J. Jones" <JonesD6@BP.com>, "Paul G. Hyatt" <hyattpg@BP.com>, "Steven R. Rossberg" <RossbeRS@BP.com>, Lois <lois@inletkeeper.org>, Dan Bross <kuacnews@kuac.org>, Gordon Pospisil <PospisG@BP.com>, "Francis S. Sommer" <SommerFS@BP.com>, Mikel Schultz <Mikel.Schultz@BP.com>, "Nick W. Glover" <GloverNW@BP.com>, "Daryl J. Kleppin" <KleppiDE@BP.com>, "Janet D. Platt" <P1attJD@BP.com>, "Rosanne M. Jacobsen" <JacobsRM@BP.com>, ddonkel <ddonkel@cfl.rr.com>, Collins Mount <collins_mount@revenue. state.ak.us>, mckay <mckay@gci.net>, Barbara F Fullmer <barbara.£fullmer@conocophillips.com>, bocastwf <bocastwf@bp.com>, Charles Barker <barker@usgs.gov>, doug_schultze <doug_schultze@xtoenergy.com>, Hank Alford <hank, alford@exxonmobil. com>, Mark Kovac <yesno I @gci.net>, gspfoff <gspfoff@aurorapower.com>, Gregg Nady <gregg.nady@shell.com>, Fred Steece <fred.steece@state.sd.us>, rcrotty <rcrotty@ch2m.com>, jejones <jejones@aurorapower.com>, dapa <dapa@alaska.net>, jroderick <jroderick@gci.net>, eyancy <eyancy@seal-tite.net>, "James M. Ruud" <james.m.ruud@conocophillips.com>, Brit Lively <mapalaska@ak.net>, jah <jah@dec.state. ak.us>, Kurt E Olson <kurt_olson@legis.state. ak.us>, buonoje <buonoje@bp.com>, Mark Hanley <mark_hanley@anadarko.com>, loren_leman <loren_leman@gov.state.ak.us>, Julie Houle <julie_houle@der.state. ak.us>, John W Katz <jwkatz@sso.org>, Suzan J Hill <Suzan_hill@dec.state.ak.us>, tablerk <tablerk@unocal.com>, Brady <brady@aoga.org>, Brian Havelock <beh@dnr.state.ak.us>, bpopp <bpopp@borough.kenai.ak.us>, Jim White <jimwhite@satx.rr.com>, "John S. Haworth" <john.s.haworth@exxonmobil.com>, marty <marty@rkindustrial.com>, ghammons <ghammons@aol.com>, rmclean <rmclean@pobox. alaska. net>, mkm7200 <mkm7200@aol.com>, Brian Gillespie <ifbmg@uaa.alaska.edu>, David L Boelens <dboelens@aurorapower.com>, Todd Durkee <TDURKEE@KMG.com>, Gary Schultz <gary_schultz@dec.state. ak.us>, Wayne Rancier <RANCIER@petro-canada.ca>, Bill Miller <Bill_Miller@xtoalaska.com>, Brandon Gagnon <bgagnon@brenalaw.com>, Paul Winslow <pmwinslow@forestoil.com>, Garry Catron <catrongr@bp.com>, Sharmaine Copeland <copelasv@bp.com>, Kristin Dirks<kristin_dirks@dec.state. ak.us>, Kaynell Zeman <kjzeman@marathonoil.com>, John Tower <John.Tower@eia.doe. gov>, Bill Fowler <Bill_Fowler@anadarko.COM>, Vaughn Swartz <vaughn.swartz@rbccm.com>, Scott Cranswick <scott.cranswick@mms.gov>, Brad McKim <mckimbs@BP.com>, Steve Lambe 1 of 3 3/30/2005 3:10 PM Various Administrative Approvals <lambes@unocal.com>, jack newell <jack.newell@acsalaska.net>, James Scherr <James.Scherr@mms.gov>, david roby <David.Roby@mms.gov>, Tim Lawlor <Tim_Lawlor@ak.blm.gov>, Lynnda Kahn <Lynnda_Kahn@fws.gov>, Jerry Dethlefs <Jerry. C. Dethlefs@conocophillips. com>, Jerry Dethlefs <n1617@conocophillips.com>, crockett@aoga.org, Tamera Sheffield <sheffield@aoga.org>, Jon Goltz <Jon.Goltz@conocophillips.com>, Roger Belman <roger.belman@conocophillips.com>, Mindy Lewis <mlewis@brenalaw.com>, Harry Lampert <harry.lampert@honeywell.com> AIO5.002.pdf Content -Type: application/pdf Content -Encoding: base64 AIO6.009.pdf Content -Type: application/pdf Content -Encoding: base64 AIO6.006.pdf Content -Type: application/pdf Content -Encoding: base64 AIO6.008.pdf Content -Type: application/pdf Content -Encoding: base64 AIO6.005.pdf Content -Type: application/pdf Content -Encoding: base64 AIO 6.004.pdf Content -Type: application/pdf Content -Encoding: base64 AIO6.007.pdf Content -Type: application/pdf Content -Encoding: base64 2 of 3 3/30/2005 3:10 PM Various Administrative Approvals 0 AIO5.003.pdf Content -Type: application/pdf Content -Encoding: base64 AI011.003.pdf Content -Type: application/pdf Content -Encoding: base64 Content -Type: application/pdf AIO2B.03.pdf Content -Encoding: base64 3 of 3 3/30/2005 3:10 PM ALASKA OIL AND GAS CONSERVATION COMOSSION K53 VV Itli AV r, NUr-, SUITI_ 100 ig4CI-10RAOr,AI_/-SKA 9950-1-3539 iC)HE (907) 279-1433 AX (907) 216-7542 ADMINIST'RATIVE_APPRQVV_AL AI® 6e003 (Reviled ADMINIST'RAT'IVE APPROVAL AIO 6.004 (Revised) ADMINISTRATIVE APPROVAL AIO 6.007 (Revised) ADMINIS'TRA'TIVE APPROVAL. AIO 6.008 (Revised) ADMINIS'TRAT'IVE APPROVAL, AIO 6.009 (Revised) Mr. J, Hal Martin Optimization Engineer Union Oil Company of California PO Box 196247 Anchorage, Alaska 99519-6247 RE: Request for Administrative Approval Revision Dear Mr. Martin: Union Oil Company of California (Union) requests a permanent revision to the anniversary date for temperature surveys for water injection wells located on the Anna Platform (Granite Point Field). The Alaska Oil and Gas Conservation Commission (Commission) approves Union's request to change the anniversary date for temperature surveys in the following wells from March 29 to May 20: - Granite Pt. State 18742 Well No. 5; PTD 1670140; AIO 6.003; - Granite Pt. State 18742 Well No. 19; PTD 1680060; AIO 6.008; - Granite Pt. State 18742 Well No. 21; PTD 1760490; AIO 6.009; - Granite Pt. State 18742 Well No. 25; PTD 1680360; AIO 6.004; - Granite Pt. State 18742 Well No. 38; PTD 1880340; AIO 6.007. The Commission granted administrative approvals to Union allowing temperature surveys every 2 years in lieu of pressure tests of the tubing -casing annulus. Temperature surveys are intended to demonstrate that injected fluids are exiting the wellbore and remaining confined as required by Area Injection Order 6.000. Union argues that performing temperature surveys in May will allow warmer weather conditions to improve the slickline operations on these water injection wells. Dail- y c,"rvedlance of wellhead pressures and injection rates with monthly reporting to the Commission - mandated by the administrative approvals - provide for early detection and action regarding any deterioration of well integrity that might occur during the 2-year interval between Mr, 1"JA I'VlJrtlrt • March 1 1., )009 I1ctt,c +)I�: ternpVrattrre Surveys, Administrative approvals also require Union to irn nedi.ately shul; it) the well and notify the Corm-nission if there is any rneasurahle change in the well's mechanical integrity, The Commission finds that moving the anniversary date for ternperature surveys from March 29 to May 20 will not compromise overall well integrity so as to threaten the environment or human safety. DONE at Anchorage., Alaska and dated March 31, 2009. Daniel T. Seamount, Jr. Cathy . Foerster Chair Commissioner RECONSIDERATION AND APPEAL NOTICE Commissioner As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[tlhe questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5.00 p.m. on the next day that does not fall on a weekend or state holiday. 0 Page 1 of 1 Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Thursday, April 02, 2009 9:07 AM Subject: Revised AIO 6-003; AIO 6-004, AIO 6-007; AIO 6-008; AIO 6-009 (all combined on one admin approval) Attachments: aio6 revised admin approval.pdf BCC:'Aaron Gluzman'; caunderwood@marathonoil.com; 'Dale Hoffman'; Fridiric Grenier; 'Gary Orr'; 'Joe Longo'; 'Lamont Frazer'; Marc Kuck; 'Mary Aschoff ; Maurizio Grandi; P Bates; Richard Garrard; 'Sandra Lemke'; 'Scott Nash'; 'Steve Virant'; Tom Gennings; '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'; 'Cary Carrigan'; 'Charles O'Donnell'; 'Chris Gay'; 'Cliff Posey'; 'Cody Rice'; 'Dan Bross'; 'dapa'; 'Daryl J. Kleppin'; 'David Brown'; 'David Gomey'; 'David Hall'; David House; 'David L Boelens'; 'David Steingreaber'; 'ddonkel'; Deborah Jones; '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'; 'James Scherr'; 'Janet D. Platt'; 'jejones'; 'Jerry McCutcheon'; 'Jim Arlington'; 'Jim White'; 'Jim Winegarner'; 'Joe Nicks'; 'John Garing'; 'John S. Haworth'; 'John Spain'; 'John Tower'; 'John W Katz'; johnny.aiken@north-slope.org; 'Jon Goltz'; 'Julie Houle'; 'Kari Moriarty'; 'Kaynell Zeman'; 'Keith Wiles'; knelson@petroleumnews.com; 'Krissell Crandall'; 'Kristin Dirks'; 'Laura Silliphant'; 'Lynnda Kahn'; 'mail=akpratts@acsalaska.net'; 'mail=foms@mtaonline.net'; 'Marilyn Crockett'; 'Mark Dalton'; 'Mark Hanley'; 'Mark Kovac'; 'Mark P. Worcester'; 'Marguerite kremer'; 'Matt Rader'; Melanie Brown; '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 Decker'; 'Paul Winslow'; Pierce, Sandra M (DNR); 'Randall Kanady'; 'Randy L. Skillern'; 'rcrotty'; 'rmclean'; 'Rob McWhorter '; rob.g.dragnich@exxomnobil.com; 'Robert Campbell'; 'Robert Province'; 'Roger Belman'; 'Rudy Brueggeman'; 'Scott Cranswick'; 'Shannon Donnelly'; 'Sharmaine Copeland'; 'Sondra Stewman'; 'Sonja Frankllin'; 'Stan Porhola'; 'stanekj'; 'Steve Lambert'; 'Steve Moothart'; 'Steven R. Rossberg'; 'tablerk'; 'Tamera Sheffield'; 'Temple Davidson'; 'Terrie Hubble'; Thompson, Nan G (DNR); 'Tim Lawlor'; 'Todd Durkee'; Tony Hopfinger; 'trmjrl'; Von Gemmingen, Scott E (DOR); 'Walter Featherly'; 'Walter Quay'; 'Wayne Rancier'; Birnbaum, Alan J (LAW); Crisp, John H (DOA); Davies, Stephen F (DOA); Fleckenstein, Robert J (DOA); Foerster, Catherine P (DOA); Grimaldi, Louis R (DOA); Johnson, Elaine M (DOA); Jones, Jeffery B (DOA); Laasch, Linda K (DOA); Mahnken, Christine R (DOA); Maunder, Thomas E (DOA); McIver, 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); Seamount, Dan T (DOA); Smith, Chasity R (DOA); Williamson, Mary J (DOA) Attachments: aio6 revised admin approval.pdf, fyi Jody J. Colombie Special Assistant Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 (907)793-1221 (phone) (907)276-7542 (fax) 4/2/2009 Mary Jones David McCaleb Cindi Walker XTO Energy, Inc. IHS Energy Group Tesoro Refining and Marketing Co. Cartography GEPS Supply & Distribution 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 300 Concord Plaza Drive Ft. Worth, TX 76102-6298 Houston, TX 77056 San Antonio, TX 78216 George Vaught, Jr. Jerry Hodgden Richard Neahring PO Box 13557 Hodgden Oil Company NRG Associates Denver, CO 80201-3557 408 18th Street President Golden, CO 80401-2433 PO Box 1655 Colorado Springs, CO 80901 Mark Wedman Schlumberger Ciri Halliburton Drilling and Measurements Land Department 6900 Arctic Blvd. 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 Darwin 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 0 ALASKA SEAN PARNELL, GOVERNOR ALASSA OIL A" GAS 333 W. 7thAVENUE, SUITE 100 CONSERVATION CODIMUSSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL AIO 6.010 Mr. Hal Martin Optimization Engineer Unocal Alaska P.O. Box 196247 Anchorage, AK 99519-6247 RE: Granite Point State 18742 MUCI-3 (PTD 178-019) Request for Administrative Approval Dear Mr. Martin: Per Rule 9 of Area Injection Order 6, the Alaska Oil and Gas Conservation Commission (AOGCC or Commission) hereby GRANTS Unocal Alaska (Unocal)'s November 5, 2009 request for administrative approval to inject water in Granite Point State 18742 MUCI-3 (MUCI-3). Unocal notified the Commission on October 14, 2009 that MUCI-3 exhibits tubing by casing pressure communication. Although pressure communication to the casing annulus was indicated by provided pressure monitoring information, analysis of the data indicated that the casing remained competent. Approval to continue injection for the purpose of performing well integrity diagnostics was granted and Unocal performed a temperature survey on October 16, 2009. Unocal has elected to perform no corrective action at this time on MUCI-3. Temperature surveys performed as part of the diagnostic testing confirm the injected fluids are exiting the well at the perforations and monitoring has shown that pressures are contained within the wellbore. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety. The Commission's administrative approval to inject in MUCI-3 is conditioned upon the following: 1. Injection is limited to WATER ONLY; 2. Unocal shall monitor and record tubing, inner annulus, and outer annulus pressures and injection rate daily; Mr. Hal Martin November 18, 2009 Page 2 of 2 3. Unocal shall submit to the Commission a monthly report of well pressures and injection rates; 4. Unocal shall perform a temperature survey every 2 years in lieu of the mechanical integrity test as outlined in Rule 6 of A10 6 to demonstrate continued production casing integrity; 5. Unocal shall immediately shut in the well and notify the Commission if there is any change in the well's mechanical condition; and 6. After well shut in due to a change in the well's mechanical condition, Commission approval shall be required to restart injection. 7. The next temperature survey is due May 20, 2011 and at 2-year intervals thereafter. As provided in AS 31.05.080, within 20 days after written notice of this 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 rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DONE at Anchorage, Alaska and dated November 18, 2009. Daniel T. Seamount, Jr. Cathy . Foerster Chair Commissioner Mary Jones David McCaleb Cindi Walker XTO Energy, Inc. IHS Energy Group Tesoro Refining and Marketing Co. Cartography GEPS Supply & Distribution 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 300 Concord Plaza Drive Ft. Worth. TX 76102-6298 Houston, TX 77056 San Antonio, TX 78216 George Vaught, Jr. Jerry Hodgden Richard Neahring PO Box 13557 Hodgden Oil Company NRG Associates Denver, CO 80201-3557 408 18th Street President Golden, CO 80401-2433 PO Box 1655 Colorado Springs, CO 80901 Mark Wedman Schlumberger Ciri Halliburton Drilling and Measurements Land Department 6900 Arctic Blvd. 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 Darwin 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 led • Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Wednesday, November 18, 2009 121 PM To: (foms2@mtaonline. net);(michael.j.nelson@conocophillips.com); (Von.L.Hutchins@conocophillips.com); alaska@petrocalc.com; Anna Raff; Barbara F Fullmer, bbritch; Bill Walker; Bowen Roberts, Brad McKim; Brady, Jerry L; Brandon Gagnon; Brandow, Cande (ASRC Energy Services); Brian Gillespie; Brian Havelock; Bruce Webb; carol smyth; caunderwood; Charles O'Donnell; Chris Gay; Cliff Posey; Crandall, Krissell; Dan Bross; dapa; Daryl J. Kleppin; David Boelens; David House; David Steingreaber; 'ddonkel@cfl.rr.com'; Deborah J. Jones; doug_schultze; Elowe, Kristin; Evan Harness; eyancy; Francis S. Sommer; Fred Steece; Garland Robinson; Gary Laughlin; Gary Rogers; Gary Schultz; ghammons; Gordon Pospisil; Gorney, David L.; Gregg Nady; gspfoff; Hank Alford; Harry Engel; Jdarlington (jarlington@gmail.com); Jeff Jones; Jeffery B. Jones (jeff.jones@alaska.gov); Jerry McCutcheon; 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; Laura Silliphant; Marilyn Crockett; Mark Dalton; Mark Hanley (mark.hanley@anadarko.com); Mark Kovac; Mark P. Worcester; Marquerite kremer; Melanie Brown; Michael Jacobs; Mike Bill; Mike Colombie; Mike Mason; Mikel Schultz; Mindy Lewis; MJ Loveland; mjnelson; mkm7200; nelson; Nick W. Glover; NSK Offtake Coord; NSK Problem Well Supv; Patty Alfaro; Paul Decker (paul.decker@alaska.gov); PORHOLA, STAN T; Rader, Matthew W (DNR); Raj Nanvaan; Randall Kanady; Randy L. Skillern; Rob McWhorter; rob.g.dragnich@exxonmobil.com- Robert A. Province (raprovince@marathonoil.com); Robert Campbell; Roberts, Susan M.; Rudy Brueggeman; Sandra Pierce; Scott Cranswick; Shannon Donnelly; Sharmaine Copeland; Shellenbaum, Diane P (DNR); Slemons, Jonne D (DNR); Sondra Stewman; Sonja Frankllin; Steve Lambert; Steve Moothart; Steven R. Rossberg; Suzanne Gibson; tablerk; Tamera Sheffield; Taylor, Cammy O (DNR); Ted Rockwell; Temple Davidson; Teresa Imm; Terrie Hubble; Thor Cutler; Todd Durkee; Tony Hopfinger; trmjrl; Walter Featherly; Williamson, Mary J (DNR); Winslow, Paul M; 'Aaron Gluzman'; 'Dale Hoffman'; Frederic 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); Aubert, Winton G (DOA); Ballantine, Tab A (LAW); Brooks, Phoebe; Crisp, John H (DOA); Darlene Ramirez; Davies, Stephen F (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) Subject: aio 3-021 (corrected cancellation) and PBU and aio 6-010 Granite Point Attachments: aio6-010.pdf; aio3-021 corrected cancellation. pdf Jody J. Colombie Special Assistant Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 9.9501 (907)793-1221 (phone) (907)276-7542 (fax) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 71h Avenue, Suite 100 Anchorage, Alaska 99501 Re: THE APPLICATION OF ) Area Injection Order No. 6.011 HILCORP ALASKA LLC. for ) Administrative Approval allowing ) Granite Point Field well Bruce 5RD-86 (PTD 1790050) ) Middle Kenai Oil Pool (aka Granite Point State 17586 5RD) ) to be online in water only injection ) January 29, 2013 service with a suspected tubing x inner ) annulus communication. ) By letter dated January 18, 2013, Hilcorp Alaska LLC. (Hilcorp) requested administrative approval to continue water only injection in the subject well. In accordance with Rule 9 of Area Injection Order (AIO) 6.000, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS Hilcorp's request for administrative approval to continue water only injection in the subject well. Hilcorp reported to AOGCC on May 1, 2012 that the well showed signs of tubing x inner annulus (TxIA) communication and was shut in after being on produced water disposal. Hilcorp performed a MIT -IA on May 6, 2012 which failed. Hilcorp requested on September 13, 2012 approval to perform a baseline temperature survey, perform a 30 day injection test, then run a follow up temperature survey to determine fluid entry. AOGCC granted that request November 14, 2012 and the survey, 30 day test, and survey were completed December 31, 2012. Testing indicates fluid entry is below the packer and to the existing perforations. The AOGCC finds that Hilcorp does intend to perform repairs in Q3 2013 with a new completion, and operation of this well is critical to continued field production at this time. Accordingly, the AOGCC believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's approval to continue water infection only in Bruce 5RD-86 is conditioned upon the following: 1. Hilcorp shall record wellhead pressures and injection rate daily; 2. Hilcorp shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli. Bleeds to be flagged on the report; 3. Hilcorp shall install, maintain and operate automatic well shut-in equipment linked to the well's inner annulus (IA) and outer annulus (OA) pressure. The actuation pressure shall not exceed 3,250 psi for the inner annulus. The actuation pressure shall not exceed 750 psi for the outer annulus. Testing of the shut in equipment shut -down valve and mechanical or electrical pressure devices shall be performed upon install, and every 6 months thereafter, ideally in conjunction with production well pilots and safety valves. Hilcorp shall provide to the commission AIO 6.011 January 29, 2013 Page 2 of 2 commission the testing procedure that will be used to verify integrity of the well shut-in equipment linked to the inner and outer annulus pressures; 4. Hilcorp shall limit the wells IA operating pressure to 3,250 psi; 5. Hilcorp shall limit the wells OA operating pressure to 750 psi; 6. Hilcorp shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 7. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 8. This administrative approval shall expire 12 months after the effective date shown below. DONE at Anchorage, Alaska and dated January 29, 2013. Cathy P oerster Daniel T—Seamount, Jr. Chair, Commissioner Commissioner TION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[tlhe questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration" In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. C� 0 Singh, Angela K (DOA) From: Colombie, Jody 1 (DOA) Sent: Wednesday, January 30, 2013 11:48 AM To: Singh, Angela K (DOA); Ballantine, Tab A (LAW); Bettis, Patricia K (DOA); Brooks, Phoebe L (DOA); Colombie, Jody J (DOA); Crisp, John H (DOA); Davies, Stephen F (DOA); Ferguson, Victoria L (DOA); Fisher, Samantha J (DOA); Foerster, Catherine P (DOA); Grimaldi, Louis R (DOA); Johnson, Elaine M (DOA); Jones, Jeffery B (DOA); Laasch, Linda K (DOA); Bender, Makana K (DOA); McIver, Bren (DOA); McMains, Stephen E (DOA); Mumm, Joseph (DOA sponsored); Noble, Robert C (DOA); Norman, John K (DOA); Okland, Howard D (DOA); Paladijczuk, Tracie L (DOA); Pasqual, Maria (DOA); Regg, James B (DOA); Roby, David S (DOA); Scheve, Charles M (DOA); Schwartz, Guy L (DOA); Seamount, Dan T (DOA); Wallace, Chris D (DOA); Aaron Gluzman; Aaron Sorrell; Bruce Williams; Bruno, Jeff J (DNR); caunderwood@marathonoil.com; Casey Sullivan; Dale Hoffman; David Lenig; Donna Vukich; Eric Lidji; Erik Opstad; Franger, James M (DNR); Gary Orr, Smith, Graham 0 (PCO); Greg Mattson; Heusser, Heather A (DNR); James Rodgers; Jason Bergerson; Jennifer Starck; jill.a.mcleod@conocophillips.com; Jim Magill; Joe Longo; King, Kathleen J (DNR); Lara Coates; Lois Epstein; Louisiana Cutler; Marc Kuck; Steele, Marie C (DNR); Matt Gill; Ostrovsky, Larry (DNR sponsored); Bettis, Patricia K (DOA); Perrin, Don J (DNR); Peter Contreras; Pexton, Scott R (DNR); Pollard, Susan R (LAW); Pollet, Jolie; Richard Garrard; Ryan Daniel; Sandra Lemke; Talib Syed; Wayne Wooster; Woolf, Wendy C (DNR); William Hutto; William Van Dyke; (michael j.nelson@conocophillips.com); Abbie Jossie; AKDCWeIIIntegrityCoordinator; alaska@petrocalc.com; Alexander Bridge; Andrew VanderJack; Anna Raff; Barbara F Fullmer; bbritch; bbohrer@ap.org; Bill Penrose; Bill Walker; Bowen Roberts; Brian Havelock; Bruce Webb; Burdick, John D (DNR); Cliff Posey, Crandall, Krissell; D Lawrence; Daryl J. Kleppin; Dave Harbour; Dave Matthews; David Boelens; David Duffy; David House; David Scott; David Steingreaber; Davide Simeone; ddonkel@cfl.rr.com; Donna Ambruz; Dowdy, Alicia G (DNR); Dudley Platt; Elowe, Kristin; Evans, John R (LDZX); Francis S. Sommer; Gary Laughlin; Schultz, gary (DNR sponsored); ghammons; Gordon Pospisil; Gorney, David L.; Greg Duggin; Gregg Nady; Gregory Geddes; gspfoff, Jdarlington oarlington@gmail.com); Jeanne McPherren; Jones, Jeffery B (DOA); Jerry McCutcheon; Jill Womack; Jim White; Jim Winegarner; Joe Lastufka; news@radiokenai.com; Easton, John R (DNR); John Garing; John Spain; Jon Goltz; Jones, Jeffrey L (GOV); Juanita Lovett; Judy Stanek; Houle, Julie (DNR); Julie Little; Kari Moriarty; Kaynell Zeman; Keith Wiles; Kelly Sperback; Gregersen, Laura S (DNR); Luke Keller; Marc Kovak; Mark Dalton; Mark Hanley (mark.hanley@anadarko.com); Mark P. Worcester; Kremer, Marguerite C (DNR); Michael Jacobs; Mike Bill; mike@kbbi.org; Mike Morgan; Mikel Schultz; Mindy Lewis; MJ Loveland; mjnelson; mkm7200; knelson@petroleumnews.com; Nick W. Glover, Nikki Martin; NSK Problem Well Supv; Patty Alfaro; Decker, Paul L (DNR); Paul Mazzolini; Pike, Kevin W (DNR); Randall Kanady; Randy L. Skillern; Randy Redmond; Rena Delbridge; Renan Yanish; Robert Brelsford; Robert Campbell; Ryan Tunseth; Sandra Haggard; Sara Leverette; Scott Cranswick; Scott Griffith; Shannon Donnelly; Sharmaine Copeland; Sharon Yarawsky; Shellenbaum, Diane P (DNR); Slemons, Jonne D (DNR); Smith, Kyle S (DNR); Sondra Stewman; Stephanie Klemmer; Stephen Miller; Moothart, Steve R (DNR); Steven R. Rossberg; Suzanne Gibson; sheffield@aoga.org; Taylor, Cammy 0 (DNR); Ted Kramer; Davidson, Temple (DNR); Teresa Imm; Thor Cutler; Tim Mayers; Tina Grovier; Todd Durkee; Tony Hopfinger; trmjrl; Vicki Irwin; Walter Featherly; yjrosen@ak.net Subject: AOGCC Orders Attachments: co456a.pdf, aio6.011.pdf; aio2la.pdf 0 Aio21a Area Injection Order Kuparuk River Field, Meltwater Oil Pool C0456A Denial Kuparuk River Field, Meltwater Oil Pool NO 6-11 Granite Point Field, Middle Kenai Oil Pool, Bruce 5RD-86 (Administrative Approval) Easy Peel® Labels Use Avery® Template 5160® ♦ Bend along line to Q AVERY@ 5960TM Feed Paper expose Pop-up EdgeTM Reid Edwards Reservoir Engineer — Cook Inlet Offshore Asset Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 100 Anchorage, AK 99503 ttiquettes faciles a peter I A Repliez a la hachure afin de ; www.averycom i i+mrIe k, * evoov® run® i Sens de I— .,.I. -A D__ ..—Mc ! 1-800-GO-AVERY I Easy Peel® Labels Use Avery® Template 51600 Penny Vadla 399 W. Riverview Ave. Soldotna, AK 99669-7714 Jerry Hodgden Hodgden Oil Company 40818`h St. Golden, CO 80401-2433 Bernie Karl K&K Recycling Inc. Post Office Box 58055 Fairbanks, AK 99711 North Slope Borough Planning Department Post Office Box 69 Barrow, AK 99723 Jack Hakkila Post Office Box 190083 Anchorage, AK 99519 AL® Bend along line to 10 Feed Paper expose Pop-up EdgeT" David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste. 100 Houston, TX 77056 Richard Neahring NRG Associates President P.O. Box 1655 Colorado Springs, CO 80901 CIRI Land Department Post Office Box 93330 Anchorage, AK 99503 Richard Wagner Post Office Box 60868 Fairbanks, AK 99706 Darwin Waldsmith Post Office Box 39309 Ninilchik, AK 99639 O AVERY® 5960TM t George Vaught, Jr. Post Office Box 13557 Denver, CO 80201-3557 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Baker Oil Tools 795 E. 94"' Ct. Anchorage, AK 99515-4295 Gordon Severson 3201 Westmar Cir. Anchorage, AK 99508-4336 James Gibbs Post Office Box 1597 Soldotna, AK 99669 Etiquettes faciles a peter ; A Repliez A la hachure afin de ; www.averycom Sens de .. 4_4nn_An_AVCov STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: THE APPLICATION OF ) Area Injection Order No. 6.011 HILCORP ALASKA LLC. for ) Cancellation cancellation of Administrative ) Approval 6.011 for well Bruce 5RD- ) Granite Point Field 86 (PTD 1790050) (aka Granite Point ) Middle Kenai Oil Pool State 17586 5RD). ) February 13, 2014 By email dated January 30, 2014, Hilcorp Alaska LLC. (Hilcorp) requested cancellation of administrative approval (AA) Area Injection Order (AIO) 6.011. In accordance with Rule 9 of AIO 6.000, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS Hilcorp's request to cancel the AA. Bruce 5RD-86 exhibited suspected tubing x inner annulus communication. However, the AOGCC determined that water injection could safely continue if Hilcorp complied with the restrictive conditions set out in AA AIO 6.011. The AOGCC set a condition for AA AIO 6.011 to expire on January 29, 2014 (12 months). Hilcorp has determined not to use this well for injection in its present condition and the well is currently shut in. AA AIO 6.011 is no longer necessary to the operation of this well and is hereby CANCELLED. Injection into Bruce 5RD- 86 will be governed by provisions of AIO No. 6.000. DONE at Anchorage, Alaska and dated February 13, 2014. (Ad Cathy . Foerster Chair, Commissioner Daniel T. Seam unt, Jr. Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. • • Singh, Angela K (DOA) From: Carlisle, Samantha J (DOA) Sent: Friday, February 14, 2014 11:20 AM To: Ballantine, Tab A (LAW); Bender, Makana K (DOA); Bettis, Patricia K (DOA); Brooks, Phoebe L (DOA); Carlisle, Samantha J (DOA); Colombie, Jody J (DOA); Crisp, John H (DOA); Davies, Stephen F (DOA); Eaton, Loraine E (DOA); Ferguson, Victoria L (DOA); Foerster, Catherine P (DOA); Frystacky, Michal (DOA); Grimaldi, Louis R (DOA); Hunt, Jennifer L (DOA); Johnson, Elaine M (DOA); Jones, Jeffery B (DOA); Mumm, Joseph (DOA sponsored); Noble, Robert C (DOA); Paladijczuk, Tracie L (DOA); Pasqual, Maria (DOA); Regg, James B (DOA); Roby, David S (DOA); Scheve, Charles M (DOA); Schwartz, Guy L (DOA); Seamount, Dan T (DOA); Singh, Angela K (DOA); Turkington, Jeff A (DOA); Wallace, Chris D (DOA); (michaelj.nelson@conocophillips.com); AKDCWellIntegrityCoordinator; Alexander Bridge; Andrew VanderJack; Anna Raff; Barbara F Fullmer; bbritch; bbohrer@ap.org; Barron, William C (DNR); Bill Penrose; Bill Walker, Bob Shavelson; Brian Havelock; Burdick, John D (DNR); Cliff Posey; Colleen Miller; Crandall, Krissell; D Lawrence; Daryl J. Kleppin; Dave Harbour; Dave Matthews; David Boelens; David Duffy; David Goade; David House; David McCaleb; David Scott; David Steingreaber; Davide Simeone; ddonkel@cfl.rr.com; Donna Ambruz; Dowdy, Alicia G (DNR); Dudley Platt; Elowe, Kristin; Evans, John R (LDZX); Francis S. Sommer, Frank Molli; schultz, gary (DNR sponsored); ghammons; Gordon Pospisil; Gorney, David L.; Greg Duggin; Gregg Nady; gspfoff, Jacki Rose; Jdarlington oarlington@gmail.com); Jeanne McPherren; Jerry McCutcheon; Jim White; Jim Winegarner; Joe Lastufka; news@radiokenai.com; Easton, John R (DNR); John Garing; Jon Goltz; Jones, Jeffrey L (GOV); Juanita Lovett; Judy Stanek; Houle, Julie (DNR); Julie Little; Kari Moriarty; Keith Wiles; Kelly Sperback; Klippmann; Gregersen, Laura S (DNR); Leslie Smith; Lisa Parker; Louisiana Cutler; Luke Keller; Marc Kovak; Dalton, Mark (DOT sponsored); Mark Hanley (mark.hanley@anadarko.com); Mark P. Worcester; Mark Wedman; Kremer, Marguerite C (DNR); Michael Jacobs; Mike Bill; mike@kbbi.org; Mikel Schultz; Mindy Lewis; MJ Loveland; mjnelson; mkm7200; knelson@petroleumnews.com; Nick W. Glover; Nikki Martin; NSK Problem Well Supv; Patty Alfaro; Decker, Paul L (DNR); Paul Mazzolini; Pike, Kevin W (DNR); Randall Kanady; Randy L. Skillern; Randy Redmond; Rena Delbridge; Renan Yanish; Robert Brelsford; Ryan Tunseth; Sandra Haggard; Sara Leverette; Scott Griffith; Shannon Donnelly; Sharmaine Copeland; Sharon Yarawsky; Shellenbaum, Diane P (DNR); Slemons, Jonne D (DNR); Smart Energy Universe; Smith, Kyle S (DNR); Sondra Stewman; Stephanie Klemmer; Steve Kiorpes; Moothart, Steve R (DNR); Steven R. Rossberg; Suzanne Gibson; sheffield@aoga.org; Tania Ramos; Ted Kramer; Davidson, Temple (DNR); Terence Dalton; Teresa Imm; Thor Cutler; Tim Mayers; Tina Grovier; Todd Durkee; Tony Hopfinger; trmjrl; Tyler Senden; Vicki Irwin; Vinnie Catalano; Walter Featherly; yjrosen@ak.net; Aaron Gluzman; Aaron Sorrell; Ajibola Adeyeye; Alan Dennis; Andrew Cater; Anne Hillman; Bruce Williams; Bruno, Jeff J (DNR); Casey Sullivan; David Lenig; David Tetta; Perrin, Don J (DNR); Donna Vukich; Eric Lidji; Erik Opstad; Gary Orr; Smith, Graham O (PCO); Greg Mattson; Hans Schlegel; Heusser, Heather A (DNR); Holly Pearen; James Rodgers; Jason Bergerson; Jennifer Starck; jill.a.mcleod@conocophillips.com; Jim Magill; Joe Longo; Josh Kindred; Kenneth Luckey; King, Kathleen J (DNR); Laney Vazquez; Lois Epstein; Longan, Sara W (DNR); Marc Kuck; Marcia Hobson; Steele, Marie C (DNR); Matt Armstrong; Matt Gill; Franger, James M (DNR); Morgan, Kirk A (DNR); Pat Galvin; Bettis, Patricia K (DOA); Peter Contreras; Pollet, Jolie; Richard Garrard; Richard Nehring; Ryan Daniel; Sandra Lemke; Pexton, Scott R (DNR); Peterson, Shaun (DNR); Pollard, Susan R (LAW); Talib Syed; Terence Dalton; Todd, Richard J (LAW); Tostevin, Breck C (LAW); Wayne Wooster; Woolf, Wendy C (DNR); William Hutto; William Van Dyke Subject: A119o11 cancellation Granite Point Field • Attachments: aio6-011 cancellation.pdf Samantha Carlisle Executive Secretary IT ACaska Oil and -Gas Conservation Commission 333 West 711 .Avenue, Suite wo .Anchorage, ABC 99501 (907) 793-1223 (yhone) (907) 276-7542 (fax) 0 • Larry Greenstein Hilcorp Alaska, LLC Post Office Box 244027 Anchorage, AK 99524-4027 • Penny Vadla George Vaught, Jr. 399 W. Riverview Ave. Post Office Box 13557 Soldotna, AK 99669-7714 Denver, CO 80201-3557 Bernie Karl CIRI K&K Recycling Inc. Land Department Post Office Box 58055 Post Office Box 93330 Fairbanks, AK 99711 Anchorage, AK 99503 Richard Wagner Gordon Severson Post Office Box 60868 3201 Westmar Cir. Fairbanks, AK 99706 Anchorage, AK 99508-4336 Darwin Waldsmith James Gibbs Post Office Box 39309 Post Office Box 1597 Ninilchik, AK 99639 Soldotna, AK 99669 Jerry Hodgden Hodgden Oil Company 40818' St. Golden, CO 80401-2433 North Slope Borough Planning Department Post Office Box 69 Barrow, AK 99723 Jack Hakkila Post Office Box 190083 Anchorage, AK 99519 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 71h Avenue, Suite 100 Anchorage, Alaska 99501 Re: THE APPLICATION OF HILCORP ALASKA, LLC. for Administrative Approval to add treated sanitary waste to the enhanced oil recovery fluids at North Granite Point field. Area Injection Order No. 006.012 Anna Platform Bruce Platform North Granite Point Field Middle Kenai Oil Pool December 18, 2013 By letter dated September 20, 2013 Hilcorp Alaska, LLC (Hilcorp) applied for approval to add treated sanitary waste (treated effluent or TSW) to the Enhanced Oil Recovery (EOR) injection operations governed by provisions of the underlying AIO 006.000. The Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS the Hilcorp request for administrative approval. Hilcorp's application provided water sample chemical compatibility analysis and mixing ratio data for TSW being mixed with Anna platform produced water and Bruce platform produced water. AOGCC has reviewed the analysis of the TSW provided in the application and concurs that the TSW is appropriate to augment the current FOR fluid for the Anna platform and Bruce platform. Rule 9 of AIO 6.000 allows the AOGCC to administratively amend any rule stated as long as the operator demonstrates to the AOGCC's satisfaction that sound engineering practices are maintained and the amendment will not result in an increased risk of fluid movement into an underground source of drinking water. Finding 4 of AIO 6.000 states that the portion of aquifers beneath the Cook Inlet described by a 1/4 mile area beyond and lying directly below the Granite Point Field are exempted for Class II injection activities by 40 CFR 147.102(b)(2)(B) and 20 AAC 25.440(c). AIO 006.012 December 18, 2013 Page 2 of 2 DONE at Anchorage, Alaska and dated Decem Q � �' Daniel T. Seamount, Jr. Commissioner RECONSIDERATION AND APPEAL As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rasher, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on aweekend or state holiday. Singh, Angela K (DOA) From: Colombie, Jody J (DOA) Sent: Thursday, December 19, 2013 10:2S AM To: (michae[j.nelson@conocophillips.com); AKDCWellIntegrityCoordinator; Alexander Bridge; Andrew Vanderlack; Anna Raff; Barbara F Fullmer, bbritch; bbohrer@ap.org; Barron, William C (DNR); Bill Penrose; Bill Walker; Brian Havelock; Burdick, John D (DNR); Cliff Posey; Colleen Miller; Crandall, Krissell; D Lawrence; Daryl J. Kleppin; Dave Harbour, Dave Matthews; David Boelens; David Duffy; David Goade; David House; David Scott; David Steingreaber; Davide Simeone; ddonkel@cfl.rr.com; Donna Ambruz; Dowdy, Alicia G (DNR); Dudley Platt; Elowe, Kristin; Evans, John R (LDZX); Francis S. Sommer, Frank Molli; schultz, gary (DNR sponsored); ghammons; Gordon Pospisil; Gorney, David L.; Greg Duggin; Gregg Nady; gspfoff; Jacki Rose; Jdarlington Oarlington@gmail.com); Jeanne McPherren; Jones, Jeffery B (DOA); Jerry McCutcheon; Jim White; Jim Winegarner; Joe Lastufka; news@radiokenai.com; Easton, John R (DNR); John Garing; Jon Goltz; Jones, Jeffrey L (GOV); Juanita Lovett; Judy Stanek; Houle, Julie (DNR); Julie Little; Kari Moriarty; Keith Wiles; Kelly Sperback; Kiorpes, Steve T; Klippmann; Gregersen, Laura S (DNR); Leslie Smith; Lisa Parker; Louisiana Cutler; Luke Keller; Marc Kovak; Dalton, Mark (DOT sponsored); Mark Hanley (mark.hanley@anadarko.com); Mark P. Worcester; Kremer, Marguerite C (DNR); Michael Jacobs; Mike Bill; mike@kbbi.org; Mikel Schultz; Mindy Lewis; MJ Loveland; mjnelson; mkm7200; knelson@petroleumnews.com; Nick W. Glover; Nikki Martin; NSK Problem Well Supv; Patty Alfaro; Decker, Paul L (DNR); Paul Mazzolini; Pike, Kevin W (DNR); Randall Kanady; Randy L. Skillern; Randy Redmond; Rena Delbridge; Renan Yanish; Robert Brelsford; Ryan Tunseth; Sandra Haggard; Sara Leverette; Scott Griffith; Shannon Donnelly; Sharmaine Copeland; Sharon Yarawsky; Shellenbaum, Diane P (DNR); Slemons, Jonne D (DNR); Smart Energy Universe; Smith, Kyle S (DNR); Sondra Stewman; Stephanie Klemmer; Moothart, Steve R (DNR); Steven R. Rossberg; Suzanne Gibson; sheffield@aoga.org; Tania Ramos; Ted Kramer; Davidson, Temple (DNR); Terence Dalton; Teresa Imm; Thor Cutler; Tim Mayers; Tina Grovier (tmgrovier@stoel.com); Todd Durkee; Tony Hopfinger; trmjrl; Vicki Irwin; Vinnie Catalano; Walter Featherly; yjrosen@ak.net; Aaron Gluzman; Aaron Sorrell; Ajibola Adeyeye; Alan Dennis; Andrew Cater; Anne Hillman; Bruce Williams; Bruno, Jeff J (DNR); Casey Sullivan; David Lenig; Perrin, Don J (DNR); Donna Vukich; Eric Lidji; Erik Opstad; Gary Orr; Smith, Graham O (PCO); Greg Mattson; Hans Schlegel (hans.schlegel@ge.com); Heusser, Heather A (DNR); Holly Pearen; James Rodgers; Jason Bergerson; Jennifer Starck; jill.a.mcleod@conocophillips.com; Jim Magill; Joe Longo; Josh Kindred; King, Kathleen J (DNR); Laney Vazquez, Lois Epstein; Longan, Sara W (DNR); Marc Kuck; Marcia Hobson; Steele, Marie C (DNR); Matt Armstrong; Matt Gill; Franger, James M (DNR); Morgan, Kirk A (DNR); Pat Galvin; Bettis, Patricia K (DOA); Peter Contreras; Pollet, Jolie; Richard Garrard; Ryan Daniel; Sandra Lemke; Pexton, Scott R (DNR); Peterson, Shaun (DNR); Pollard, Susan R (LAW); Talib Syed; Todd, Richard 1 (LAW); Tostevin, Breck C (LAW); Wayne Wooster; Woolf, Wendy C (DNR); William Hutto; William Van Dyke; Singh, Angela K (DOA); Ballantine, Tab A (LAW); Bettis, Patricia K (DOA); Brooks, Phoebe L (DOA); Colombie, Jody J (DOA); Crisp, John H (DOA); Davies, Stephen F (DOA); Ferguson, Victoria L (DOA); Carlisle, Samantha 1 (DOA); Foerster, Catherine P (DOA); Frystacky, Michal (DOA); Grimaldi, Louis R (DOA); Hunt, Jennifer L (DOA); Johnson, Elaine M (DOA); Jones, Jeffery B (DOA); Eaton, Loraine E (DOA); Bender, Makana K (DOA); Mumm, Joseph (DOA sponsored); Noble, Robert C (DOA); Norman, John K (DOA); Paladijczuk, Tracie L (DOA); Pasqua[, Maria (DOA); Regg, James B (DOA); Roby, David S (DOA); Scheve, Charles M (DOA); Schwartz, Guy L (DOA); Seamount, Dan T (DOA); Turkington, Jeff A (DOA); Wallace, Chris D (DOA) Subject: Administrative Approval Anna and Bruce Platform Attachments: aio006 012.pdf Jody J Colombie AOGCC Special Staff Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 'o� dy.cc)lombieWaska.gov Office: (907) 793-1221 Fax: (907) 276-7542 Easy PeelO Labels i A Bend along line to i AVERY@ 51600 ; Use Avery Template 5160® Feed Paper ��' expose Pop-up Edger"" Larry Greenstein Regulatory Compliance Hilcorp Alaska, LLC Post Office Box 244027 Anchorage, AK 99524-4027 Etiquettes faciles a peler Repliez a la hachure afin de i www.avery.com Sens de reveler le rebord Pop-up1-800-GO-AVERY T"' i David McCaleb Penny Vadla IHS Energy Group 399 W. Riverview Ave. GEPS Soldotna, AK 99669-7714 5333 Westheimer, Ste. 100 Houston, TX 77056 Jerry Hodgden Richard Neahring Hodgden Oil Company NRG Associates m 408 18 St. President Golden, CO 80401-2433 Post Office Box 1655 Colorado Springs, CO 80901 Bernie Karl CIRI K&K Recycling Inc. Land Department Post Office Box 58055 Post Office Box 93330 Fairbanks, AK 99711 Anchorage, AK 99503 North Slope Borough Richard Wagner Planning Department Post Office Box 60868 Post Office Box 69 Fairbanks, AK 99706 Barrow, AK 99723 Jack Hakkila Darwin Waldsmith Post Office Box 190083 Post Office Box 39309 Anchorage, AK 99519 Ninilchik, AK 99639 George Vaught, Jr. Post Office Box 13557 Denver. CO 80201-3557 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Baker Oil Tools 795 E. 941n Ct. Anchorage, AK 99515-4295 Gordon Severson 3201 Westmar Cir. Anchorage, AK 99508-4336 James Gibbs Post Office Box 1597 Soldotna, AK 99669 �ortiy�nl \� �2e �3 �C THE STATE °fALASKA GOVERNOR SEAN PARNELL Alaska Oil and Gas Conservation Commission ADMINISTRATIVE APPROVAL AREA INJECTION ORDER NO.6.013 Mr. Daniel Taylor Operations Engineer Hilcorp Alaska, LLC. P.O. Box 244027 Anchorage, AK 99524-4027 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Re: Docket Number: AIO-14-039 Request for administrative approval to allow Granite Point State 18742 13RD (PTD 1870440) to be online in water only injection service with a known tubing by inner annulus communication Granite PT ST 18742 13RD (aka An-13RD) (PTD 1870440) Granite Point Field Middle Kenai Oil Pool Dear Mr. Taylor: By email dated September 4, 2014, Hilcorp Alaska, LLC (Hilcorp) requested administrative approval to continue water only injection in the subject well. In accordance with Rule 9 of Area Injection Order (AIO) 06.000, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS Hilcorp's request for administrative approval to continue water only injection in the subject well. This well has been shut in since January 2008. It has communication between the tubing and 9 5/8" casing that was not resolved by a tubing patch intervention performed in August 2014. Hilcorp requested on September 4, 2014 approval to perform a baseline temperature survey, perform a 30 day injection test, then run a follow up temperature survey to determine fluid entry. AOGCC granted that request and these were completed October 18, 2014. Testing indicates fluid entry is below the packer and to the existing perforations. The AOGCC finds that Hilcorp does intend to perform repairs before Q4 2016 with a new completion, and operation of this well is critical to continued field production at this time. Accordingly, the AOGCC believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AIO 6.013 October 24, 2014 Page 2 of 2 AOGCC's approval to continue water injection only in Granite Point State 18742 13RD is conditioned upon the following: 1. Hilcorp shall record wellhead pressures and injection rate daily; 2. Hilcorp shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli with any bleeds flagged on the report; 3. Hilcorp shall install, maintain and operate automatic well shut-in equipment linked to the well's inner annulus (IA) and outer annulus (OA) pressure. The actuation pressure shall not exceed 2,150 psi for the inner annulus. The actuation pressure shall not exceed 750 psi for the outer annulus. Testing of the shut in equipment shut -down valve and 4. 5. 6. 7. mechanical or electrical pressure devices shall be performed upon install, and every 6 months thereafter, ideally in conjunction with production well pilots and safety valves. Hilcorp shall provide to the commission the testing procedure that will be used to verify integrity of the well shut-in equipment linked to the inner and outer annulus pressures; Hilcorp shall limit the well's IA operating pressure to 2,150 psi; Hilcorp shall limit the well's OA operating pressure to 750 psi; Hilcorp shall perform a temperature survey every two years; Hilcorp shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and This administrative approval shall expire on December 31, 2016. !li DONE at Anchorage, Alaska and dated October 24, 2014. Cathy P Foerster Chair, Commissioner avid yberr Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grantor refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial Of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and maybe appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Singh, Angela K (DOA) From: Carlisle, Samantha J (DOA) Sent: Friday, October 24, 2014 1:09 PM To: (michaelj.nelson@conocophillips.com); AKDCWellIntegrityCoordinator, Alexander Bridge; Allen Huckabay; Andrew VanderJack; Anna Raff; Barbara F Fullmer; bbritch; bbohrer@ap.org; Barron, William C (DNR); Bill Penrose; Bill Walker; Bob Shavelson; Brian Havelock; Burdick, John D (DNR); Carrie Wong; Cliff Posey; Colleen Miller; Corey Cruse; Crandall, Krissell; D Lawrence; Dave Harbour; David Boelens; David Duffy; David Goade; David House; David McCaleb; David Scott; David Steingreaber; David Tetta; Davide Simeone; ddonkel@cfl.rr.com; Dean Gallegos; Delbridge, Rena E (LAA); Donna Ambruz; Ed Jones; Elowe, Kristin; Evans, John R (LDZX); Francis S. Sommer; Frank Molli; Gary Oskolkosf, George Pollock; ghammons; Gordon Pospisil; Greg Duggin; Gregg Nady; gspfoff; Jacki Rose; Jdarlington rjarlington@gmail.com); Jeanne McPherren; Jones, Jeffery B (DOA); Williams, Jennifer L (LAW); Jerry Hodgden; Jerry McCutcheon; Solnick, Jessica D (LAW); Jim Watt; Jim White; Joe Lastufka; news@radiokenai.com; John Adams; Easton, John R (DNR); John Garing; Jon Goltz; Jones, Jeffrey L (GOV); Juanita Lovett; Judy Stanek; Houle, Julie (DNR); Julie Little; Kari Moriarty; Keith Wiles; Kelly Sperback; Klippmann; Gregersen, Laura S (DNR); Leslie Smith; Lisa Parker; Louisiana Cutler; Luke Keller; Marc Kovak; Dalton, Mark (DOT sponsored); Mark Hanley (mark.hanley@anadarko.com); Mark Landt; Mark Wedman; Kremer, Marguerite C (DNR); Michael Jacobs; Michael Moora; Mike Bill; mike@kbbi.org; Mikel Schultz; MJ Loveland; mjnelson; mkm7200; Morones, Mark P (DNR); knelson@petroleumnews.com; Nichole Saunders; Nick W. Glover, Nikki Martin; NSK Problem Well Supv; Oliver Sternicki; Patty Alfaro; Paul Craig; Decker, Paul L (DNR); Paul Mazzolini; Pike, Kevin W (DNR); Randall Kanady; Randy L. Skillern; Randy Redmond; Renan Yanish; Robert Brelsford; Ryan Tunseth; Sara Leverette; Scott Griffith; Shannon Donnelly; Sharmaine Copeland; Sharon Yarawsky; Shellenbaum, Diane P (DNR); Slemons, Jonne D (DNR); Smart Energy Universe; Smith, Kyle S (DNR); Sondra Stewman; Stephanie Klemmer; Steve Kiorpes; Moothart, Steve R (DNR); Suzanne Gibson; sheffield@aoga.org; Tania Ramos; Ted Kramer; Davidson, Temple (DNR); Terence Dalton; Teresa Imm; Thor Cutler; Tim Mayers; Tina Grovier; Todd Durkee; Tony Hopfinger; trmjrl; Tyler Senden; Vicki Irwin; Vinnie Catalano; Walter Featherly; yjrosen@ak.net; Aaron Gluzman; Aaron Sorrell; Ajibola Adeyeye; Alan Dennis; Andrew Cater; Anne Hillman; Bruce Williams; Bruno, Jeff J (DNR); Casey Sullivan; David Lenig; Diane Richmond; Donna Vukich; Eric Lidji; Erik Opstad; Gary Orr; Smith, Graham O (PCO); Greg Mattson; Hans Schlegel; Heusser, Heather A (DNR); Holly Pearen; James Rodgers; Jason Bergerson; Jennifer Starck; jill.a.mcleod@conocophillips.com; Jim Magill; Joe Longo; John Martineck; Josh Kindred; Kenneth Luckey; King, Kathleen J (DNR); Laney Vazquez; Lois Epstein; Longan, Sara W (DNR); Marc Kuck; Marcia Hobson; Steele, Marie C (DNR); Matt Armstrong; Matt Gill; Franger, James M (DNR); Morgan, Kirk A (DNR); Pat Galvin; Bettis, Patricia K (DOA); Peter Contreras; Richard Garrard; Robert Province; Ryan Daniel; Sandra Lemke; Pexton, Scott R (DNR); Peterson, Shaun (DNR); Pollard, Susan R (LAW); Talib Syed; Terence Dalton; Todd, Richard J (LAW); Tostevin, Breck C (LAW); Wayne Wooster; William Hutto; William Van Dyke; Ballantine, Tab A (LAW); Bender, Makana K (DOA); Brooks, Phoebe L (DOA); Carlisle, Samantha J (DOA); Colombie, Jody J (DOA); Crisp, John H (DOA); Davies, Stephen F (DOA); Eaton, Loraine E (DOA); Foerster, Catherine P (DOA); Frystacky, Michal (DOA); Grimaldi, Louis R (DOA); Guhl, Meredith D (DOA); Herrera, Matthew F (DOA); Hill, Johnnie W (DOA); Hunt, Jennifer L (DOA); Kair, Michael N (DOA); Konkler, Stacey L (DOA); Loepp, Victoria T (DOA); Mayberry, David J (DOA); Mumm, Joseph (DOA sponsored); Noble, Robert C (DOA); Paladijczuk, Tracie L (DOA); Pasqual, Maria (DOA); Regg, James B (DOA); Roby, David S (DOA); Scheve, Charles M (DOA); Schwartz, Guy L (DOA); Seamount, Dan T To: (DOA); Singh, Angela K (DOA); Skutca, Joseph E (DOA); Wallace, Chris D (DOA) Subject: Area Injection Order 6.013 (Granite Point Field) Attachments: aio6-013.pdf Samantha Carlisle Executive Secretary II Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 (907) 793-1223 (phone) (907) 276-7542 (fax) CONFIDENTIALITY NOTICE. This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Samantha Carlisle at (907) 793-1223 or Samantha.Carlisle@alaska.gov. James Gibbs Jack Hakkila Bernie Karl Post Office Box 1597 Post Office Box 190083 K&K Recycling Inc. Soldotna, AK 99669 Anchorage, AK 99519 Post Office Box 58055 Fairbanks, AK 99711 Gordon Severson Penny Vadla George Vaught, Jr. 3201 Westmar Cir. 399 W. Riverview Ave. Post Office Box 13557 Anchorage, AK 99508-4336 Soldotna, AK 99669-7714 Denver, CO 80201-3557 Mr. Daniel Taylor Richard Wagner Darwin Waldsmith Operations Engineer Post Office Box 60868 Post Office Box 39309 Hilcorp Alaska, LLC Fairbanks, AK 99706 Ninilchik, AK 99639 Post Office Box 244027 Anchorage, AK 99524-4027 Angela K. Singh THE STATE °fALASKA GOVERNOR BILL WALKER Alaska Oil and Gas Conservation Commission ADMINISTRATIVE APPROVAL AREA INJECTION ORDER NO. 6.013 AMENDED Mr. Larry Greenstein Regulatory Compliance Manager Hilcorp Alaska, LLC. P.O. Box 244027 Anchorage, AK 99524-4027 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Re: Docket Number: AIO-16-044 Request for administrative approval to amend the expiration date to allow Granite Point State 18742 13RD (PTD 1870440) to continue to be online in water only injection service with a known tubing by inner annulus communication Granite PT ST 18742 13RD (aka An-13RD) (PTD 1870440) Granite Point Field Middle Kenai Oil Pool Dear Mr. Greenstein: By email dated November 8, 2016, Hilcorp Alaska, LLC (Hilcorp) requested administrative approval to amend the expiration date to continue water only injection in the subject well. In accordance with Rule 9 of Area Injection Order (AIO) 06.000, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS the Hilcorp request for administrative approval to continue water only injection in the subject well. This well has communication between the tubing and 9 5/8" casing that was not resolved by a tubing patch intervention performed in August 2014. Hilcorp requested on September 4, 2014 approval to perform a baseline temperature survey, perform a 30 day injection test, then run a follow up temperature survey to determine fluid entry. AOGCC granted that request and these were completed October 18, 2014. Hilcorp has also performed a temperature survey on October 30, 2016, which continues to indicate fluid entry is below the packer and to the existing perforations. Hilcorp requested on November 8, 2016 approval to extend the expiration date from December 31, 2016 to December 31, 2018. In 2014, Hilcorp committed to complete a repair of this well before Q4, 2016 with a new completion. Hilcorp now asserts the standalone well repair is not justified in this current price environment. Accordingly, the AOGCC believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AIO 6.013 Amended November 29, 2016 Page 2 of 2 AOGCC's approval to continue water injection only in Granite Point State 18742 13RD is conditioned upon the following: 1. Hilcorp shall record wellhead pressures and injection rate daily; 2. Hilcorp shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli with any bleeds flagged on the report; 3. Hilcorp shall install, maintain and operate automatic well shut-in equipment linked to the well's inner annulus (IA) and outer annulus (OA) pressure. The actuation pressure shall not exceed 2,150 psi for the inner annulus. The actuation pressure shall not exceed 750 psi for the outer annulus. Testing of the shut in equipment shut -down valve and mechanical or electrical pressure devices shall be performed upon install, and every 6 months 4. 5. 6. 7. 91 7 thereafter, ideally in conjunction with production well pilots and safety valves. Hilcorp shall provide to the commission the testing procedure that will be used to verify integrity of the well shut-in equipment linked to the inner and outer annulus pressures; Hilcorp shall limit the well's IA operating pressure to 2,150 psi; Hilcorp shall limit the well's OA operating pressure to 750 psi; Hilcorp shall perform a temperature survey every two years; Hilcorp shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and This administrative approval shall expire on December 31, 2018. DONE at Anchorage, Alaska and dated November 29, 2016. Cathy/P. Foerster Dani�Sount,Jr. Chair, Commissioner Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. TlII` S"I'A'1'1: A L A S K--A- BII_I �%'AI.I:FI4. Alaska Oil and Gas Conservation Commission ADMINISTRATIVE APPROVAL AREA INJECTION ORDER NO. 6.013 AMENDED Mr. Larry Greenstein Regulatory Compliance Manager Hilcorp Alaska, LLC. P.O. Box 244027 Anchorage, AK 99524-4027 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 aogcc.alaska.gov Re: Docket Number: AIO-16-044 Request for administrative approval to amend the expiration date to allow Granite Point State 18742 13RD (PTD 1870440) to continue to be online in water only injection service with a known tubing by inner annulus communication Granite PT ST 18742 13RD (aka An-13RD) (PTD 1870440) Granite Point Field Middle Kenai Oil Pool Dear Mr. Greenstein: By email dated November 8, 2016, Hilcorp Alaska, LLC (Hilcorp) requested administrative approval to amend the expiration date to continue water only injection in the subject well. In accordance with Rule 9 of Area Injection Order (AIO) 06.000, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS the Hilcorp request for administrative approval to continue water only injection in the subject well. This well has communication between the tubing and 9 5/8" casing that was not resolved by a tubing patch intervention performed in August 2014. Hilcorp requested on September 4, 2014 approval to perform a baseline temperature survey, perform a 30 day injection test, then run a follow up temperature survey to determine fluid entry. AOGCC granted that request and these were completed October 18, 2014. Hilcorp has also performed a temperature survey on October 30, 2016, which continues to indicate fluid entry is below the packer and to the existing perforations. Hilcorp requested on November 8, 2016 approval to extend the expiration date from December 31, 2016 to December 31, 2018. In 2014, Hilcorp committed to complete a repair of this well before Q4, 2016 with a new completion. Hilcorp now asserts the standalone well repair is not justified in this current price environment. Accordingly, the AOGCC believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. A10 6.013 Amended November 29, 2016 Page 2 of 2 AOGCC's approval to continue water injection only in Granite Point State 18742 13RD is conditioned upon the following: 1. Hilcorp shall record wellhead pressures and injection rate daily; 2. Hilcorp shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli with any bleeds flagged on the report; 3. Hilcorp shall install, maintain and operate automatic well shut-in equipment linked to the well's inner annulus (IA) and outer annulus (OA) pressure. The actuation pressure shall not exceed 2,150 psi for the inner annulus. The actuation pressure shall not exceed 750 psi for the outer annulus. Testing of the shut in equipment shut -down valve and mechanical or electrical pressure devices shall be performed upon install, and every 6 months thereafter, ideally in conjunction with production well pilots and safety valves. Hilcorp shall provide to the commission the testing procedure that will be used to verify integrity of the well shut-in equipment linked to the inner and outer annulus pressures; 4. Hilcorp shall limit the well's IA operating pressure to 2,150 psi; 5. Hilcorp shall limit the well's OA operating pressure to 750 psi; 6. Hilcorp shall perform a temperature survey every two years; 7. Hilcorp shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 8. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 9. This administrative approval shall expire on December 31, 2018. DONE at Anchorage, Alaska and dated November 29, 2016. //signature on file// Cathy P. Foerster Chair, Commissioner //signature on file// Daniel T. Seamount, Jr. Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Thursday, December 01, 2016 2:45 PM To: aogcc.inspectors@alaska.gov, 'Bender, Makana K (DOA) (makana.bender@alaska.gov)'; 'Bettis, Patricia K (DOA) (patricia.bettis@alaska.gov)'; 'Brooks, Phoebe L (DOA) (phoebe.brooks@alaska.gov)'; Carlisle, Samantha J (DOA); 'Colombie, Jody J (DOA) Oody.colombie@alaska.gov)'; 'Davies, Stephen F (DOA) (steve.davies@alaska.gov)'; Eaton, Loraine E (DOA); 'Foerster, Catherine P (DOA) (cathy.foerster@alaska.gov)'; 'French, Hollis (DOA)'; 'Frystacky, Michal (michal.frystacky@alaska.gov)'; 'Guhl, Meredith (DOA sponsored) (meredith.guhl@alaska.gov)'; Kair, Michael N (DOA); 'Link, Liz M (DOA)'; Loepp, Victoria T (DOA); 'Mumm, Joseph (DOA sponsored) Ooseph.mumm@alaska.gov)'; 'Paladijczuk, Tracie L (DOA) (tracie. pa lad ijczu k@a laska.gov)'; 'Pasqual, Maria (DOA) (maria.pasqual@alaska.gov)'; 'Quick, Michael (DOA sponsored)'; 'Regg, James B (DOA) Oim.regg@alaska.gov)'; 'Roby, David S (DOA) (dave.roby@alaska.gov)'; 'Schwartz, Guy L (DOA) (guy.schwartz@alaska.gov)'; 'Seamount, Dan T (DOA) (dan.seamount@alaska.gov)'; Singh, Angela K (DOA); 'Wallace, Chris D (DOA) (chris.wallace@alaska.gov)' Subject: aio 6-013 (Hilcorp) Attachments: aio6.013 amended.pdf Re: Docket Number: AIO-16-044 Request for administrative approval to amend the expiration date to allow Granite Point State 18742 13RD (PTD 1870440) to continue to be online in water only injection service with a known tubing by inner annulus communication Granite PT ST 18742 13RD (aka An-13RD) (PTD 1870440) Granite Point Field Middle Kenai Oil Pool Jody .J. Cotom6ie .AO(�'CC Special Assistant .Ataska Oitanct-Oas conservation Commission 333 West 7"' .Avenue .Anchorage, A(aska 995��1 Ofti('e: (g)07) 7,()3-1221 j_ax: (�) 07) 276-754 2 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jody Colombie at 907.793.1221 or iodv.colombie@alaska.gov. Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Thursday, December 01, 2016 10:04 AM To: AOGCC Cust Svc (DOA sponsored); 'AK, GWO Projects Well Integrity'; 'AKDCWellIntegrityCoordinator'; 'Alan Bailey'; 'Alex Demarban'; 'Alexander Bridge'; 'Allen Huckabay'; 'Andrew VanderJack'; 'Ann Danielson'; 'Anna Raff'; 'Barbara F Fullmer'; 'bbritch'; 'Becky Bohrer'; 'Ben Boettger'; 'Bill Bredar'; 'Bob'; 'Brandon Viator'; 'Brian Havelock'; 'Bruce Webb'; 'Caleb Conrad'; 'Candi English'; 'Cocklan-Vendl, Mary E'; 'Colleen Miller'; 'Crandall, Krissell'; 'D Lawrence'; 'Dale Hoffman'; 'Dave Harbour'; 'David Boelens'; 'David Duffy'; 'David House'; 'David McCaleb'; 'David McCraine'; 'David Tetta'; 'ddonkel@cfl.rr.com'; 'DNROG Units'; 'Donna Ambruz'; 'Ed Jones'; 'Elizabeth Harball'; 'Elowe, Kristin'; 'Evan Osborne'; 'Evans, John R (LDZX)'; 'Gary Oskolkosf'; 'George Pollock'; 'Gordon Pospisil'; Greeley, Destin M (DOR); 'Gretchen Stoddard'; 'gspfoff'; Hyun, James J (DNR); 'Jacki Rose'; 'Jdarlington Oarlington@gmail.com)'; 'Jeanne McPherren'; 'Jerry Hodgden'; 'Jim Watt'; 'Jim White'; 'Joe Lastufka'; 'Joe Nicks'; 'John Burdick'; 'John Easton'; 'John Stuart'; 'Jon Goltz'; 'Juanita Lovett'; 'Judy Stanek'; 'Julie Little'; 'Kari Moriarty'; 'Kasper Kowalewski'; 'Kazeem Adegbola'; 'Keith Torrance'; 'Keith Wiles'; 'Kelly Sperback'; 'Kevin Frank'; Kruse, Rebecca D (DNR); 'Laura Silliphant (laura.gregersen@alaska.gov)'; 'Leslie Smith'; 'Lori Nelson'; 'Louisiana Cutler'; 'Luke Keller'; 'Marc Kovak'; 'Mark Dalton'; 'Mark Hanley (mark.hanley@anadarko.com)'; 'Mark Landt'; 'Mark Wedman'; 'Mealear Tauch'; 'Michael Bill'; 'Michael Calkins'; 'Michael Moora'; 'MJ Loveland'; 'mkm7200'; Munisteri, Islin W M (DNR); 'nelson'; 'Nichole Saunders'; 'Nikki Martin'; 'NSK Problem Well Supv'; 'Patty Alfaro'; 'Paul Craig'; 'Paul Decker (paul.decker@alaska.gov)'; 'Paul Mazzolini'; Pike, Kevin W (DNR); 'Randall Kanady'; 'Rena Del bridge'; 'Renan Yanish'; 'Richard Cool'; 'Robert Brelsford'; 'Ryan Tunseth'; 'Sara Leverette'; 'Scott Griffith'; 'Shannon Donnelly'; 'Sharmaine Copeland'; 'Sharon Yarawsky'; Shellenbaum, Diane P (DNR); Skutca, Joseph E (DNR); 'Smart Energy Universe'; Smith, Kyle S (DNR); 'Stephanie Klemmer'; 'Stephen Hennigan'; 'Sternicki, Oliver R'; 'Steve Moothart (steve.moothart@alaska.gov)'; 'Steve Quinn'; 'Suzanne Gibson'; 'Tamera Sheffield'; 'Ted Kramer'; 'Temple Davidson'; 'Teresa Imm'; 'Thor Cutler'; Tim Jones; 'Tim Mayers'; Todd Durkee; trmjrl; 'Tyler Senden'; Umekwe, Maduabuchi P (DNR); Vinnie Catalano; Weston Nash; Whitney Pettus; 'Aaron Gluzman'; 'Aaron Sorrell'; Ajibola Adeyeye; Alan Dennis; Assmann, Aaron A; Bajsarowicz, Caroline J; 'Bruce Williams'; Bruno, Jeff J (DNR); Casey Sullivan; Catie Quinn; 'Don Shaw'; Eric Lidji; Garrett Haag; 'Graham Smith'; Hak Dickenson; Heusser, Heather A (DNR); Holly Pearen; Jamie M. Long; 'Jason Bergerson'; 'Jim Magill'; Joe Longo; John Martineck; Josh Kindred; Laney Vazquez; Lois Epstein; Longan, Sara W (DNR); Marc Kuck; Marcia Hobson; 'Marie Steele'; Matt Armstrong; 'Mike Franger'; Morgan, Kirk A (DNR); Pascal Umekwe; Pat Galvin; 'Patricia Bettis'; 'Pete Dickinson'; Peter Contreras; Richard Garrard; Richmond, Diane M; Robert Province; 'Ryan Daniel'; 'Sandra Lemke'; 'Susan Pollard'; Talib Syed; Tina Grovier (tmgrovier@stoel.com); Tostevin, Breck C (LAW); 'Wayne Wooster'; 'William Van Dyke' Subject: aio 6-013 (Hilcorp) Attachments: aio6.013 amended.pdf Re: Docket Number: AIO-16-044 Request for administrative approval to amend the expiration date to allow Granite Point State 18742 13RD (PTD 1870440) to continue to be online in water only injection service with a known tubing by inner annulus communication Granite PT ST 18742 13RD (aka An-13RD) (PTD 1870440) Granite Point Field Middle Kenai Oil Pool )odd J. Cotolribie .A00'CC speciat .Assistant Ataska Oit and Cjas COnse1'Vatloll Coil 1I'll ission 333 West 7"' .Avenue Anchorage, _Alaska �gsc)1 Office: r�o717�3-1221 ;fax: (c)u7) 276-742 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jody Colombie at 907.793.1221 or iody.colombie@alaska.gov. 2 Jack Hakkila Bernie KarlK&K Recycling Inc. Gordon Severson P.O. Box 190083 POBox 58055 3201 Westmar Cir. .. Anchorage, AK 99519 Anchorage, AK 99508-4336 Fairbanks, AK 99711 Penny Vadla 399 W. Riverview Ave. Soldotna, AK 99669-7714 Richard Wagner P.O. Box 60868 Fairbanks, AK 99706 George Vaught, Jr. P.O. Box 13557 Denver, CO 80201-3557 Darwin Waldsmith P.O. Box 39309 Ninilchik, AK 99639 THE STATE 01ALASKA GOVERNOR BILL WALKER Ms. Holly Tipton Regulatory Technician Hilcorp Alaska, LLC. 3800 Centerpoint Drive Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission SECOND AMENDED ADMINISTRATIVE APPROVAL AREA INJECTION ORDER NO. 6.013 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.claska.gov Re: Docket Number: AIO-18-016 Request for administrative approval to eliminate the expiration date to allow Granite Point State 18742 13RD (PTD 1870440) to continue to be online in water only injection service with a known tubing by inner annulus communication Granite PT ST 18742 13RD (aka An-13RD) (PTD 1870440) Granite Point Field Middle Kenai Oil Pool Dear Ms. Tipton: By letter received April 16, 2018 and an email request dated October 17, 2018, Hilcorp Alaska, LLC (Hilcorp) requested administrative approval to eliminate the expiration date and continue water only injection in the subject well. In accordance with Rule 9 of Area Injection Order (AIO) 06.000, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS the Hilcorp request for administrative approval to eliminate the expiration date and continue water only injection in the subject well. This well has communication between the tubing and 9 5/8" casing that was not resolved by a tubing patch intervention performed in August 2014. Hilcorp has committed to repair this well should a workover rig get deployed to the Anna platform. Hilcorp has performed a temperature survey on October 15, 2018 which shows good correlation with the other temperature surveys completed October 18, 2014 and October 30, 2016 and continues to indicate fluid entry is below the packer and to the existing perforations. Accordingly, the AOGCC believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AIO 6.013 Second Amended October 22, 2018 Page 2 of 2 AOGCC's approval to continue water iniection only in Granite Point State 18742 13RD is conditioned upon the following: 1. Hilcorp shall record wellhead pressures and injection rate daily; 2. Hilcorp shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli with any bleeds flagged on the report; 3. Hilcorp shall install, maintain and operate automatic well shut-in equipment linked to the well's inner annulus (IA) and outer annulus (OA) pressure. The actuation pressure shall not exceed 2,150 psi for the inner annulus. The actuation pressure shall not exceed 750 psi for the outer annulus. Testing of the shut in equipment shut -down valve and mechanical or electrical pressure devices shall be performed upon install, and every 6 months thereafter, ideally in conjunction with production well pilots and safety valves. Hilcorp shall provide to the commission the testing procedure that will be used to verify integrity of the well shut-in equipment linked to the inner and outer annulus pressures; 4. Hilcorp shall limit the well's IA operating pressure to 2,150 psi; 5. Hilcorp shall limit the well's OA operating pressure to 750 psi; 6. Hilcorp shall perform a temperature survey every two years; 7. Hilcorp shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 8. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and DONE at Anchorage, Alaska and dated October 22, 2018. Hollis S. French Chair, Commissioner Cat P. Poerster Daniel T. Sean Commissioner Commissioner RECONSIDERATION AND As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or stale holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. THE STATE °fALASKA (.1(1VERNOR 8111. WALKER SECOND AMENDED ADMINISTRATIVE APPROVAL AREA INJECTION ORDER NO. 6.013 Ms. Holly Tipton Regulatory Technician Hilcorp Alaska, LLC. 3800 Centerpoint Drive Anchorage, AK 99503 Re: Docket Number: AIO-18-016 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 aogcc.olaska.gov Request for administrative approval to eliminate the expiration date to allow Granite Point State 18742 13RD (PTD 1870440) to continue to be online in water only injection service with a known tubing by inner annulus communication Granite PT ST 18742 13RD (aka An-13RD) (PTD 1870440) Granite Point Field Middle Kenai Oil Pool Dear Ms. Tipton: By letter received April 16, 2018 and an email request dated October 17, 2018, Hilcorp Alaska, LLC (Hilcorp) requested administrative approval to eliminate the expiration date and continue water only injection in the subject well. In accordance with Rule 9 of Area Injection Order (AIO) 06.000, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS the Hilcorp request for administrative approval to eliminate the expiration date and continue water only injection in the subject well. This well has communication between the tubing and 9 5/8" casing that was not resolved by a tubing patch intervention performed in August 2014. Hilcorp has committed to repair this well should a workover rig get deployed to the Anna platform. Hilcorp has performed a temperature survey on October 15, 2018 which shows good correlation with the other temperature surveys completed October 18, 2014 and October 30, 2016 and continues to indicate fluid entry is below the packer and to the existing perforations. Accordingly, the AOGCC believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. Bernie Karl K&K Recycling Inc. P.O. Box 58055 Fairbanks, AK 99711 George Vaught, Jr. P.O. Box 13557 Denver, CO 80201-3557 Gordon Severson 3201 Westmar Cir. Anchorage, AK 99508-4336 Darwin Waldsmith P.O. Box 39309 Ninilchik, AK 99639 Penny Vadla 399 W. Riverview Ave. Soldotna, AK 99669-7714 Richard Wagner P.O. Box 60868 Fairbanks, AK 99706 THE STATE °fALASKA GOVERNOR BILL WALKER Alaska Oil and Gas Conservation Commission ADMINISTRATIVE APPROVAL AREA INJECTION ORDER NO. 6.013 AMENDED Mr. Larry Greenstein Regulatory Compliance Manager Hilcorp Alaska, LLC. P.O. Box 244027 Anchorage, AK 99524-4027 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 aogcc.alaska.gov Re: Docket Number: AIO-16-044 Request for administrative approval to amend the expiration date to allow Granite Point State 18742 13RD (PTD 1870440) to continue to be online in water only injection service with a known tubing by inner annulus communication Granite PT ST 18742 13RD (aka An-13RD) (PTD 1870440) Granite Point Field Middle Kenai Oil Pool Dear Mr. Greenstein: By email dated November 8, 2016, Hilcorp Alaska, LLC (Hilcorp) requested administrative approval to amend the expiration date to continue water only injection in the subject well. In accordance with Rule 9 of Area Injection Order (AIO) 06.000, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS the Hilcorp request for administrative approval to continue water only injection in the subject well. This well has communication between the tubing and 9 5/8" casing that was not resolved by a tubing patch intervention performed in August 2014. Hilcorp requested on September 4, 2014 approval to perform a baseline temperature survey, perform a 30 day injection test, then run a follow up temperature survey to determine fluid entry. AOGCC granted that request and these were completed October 18, 2014. Hilcorp has also performed a temperature survey on October 30, 2016, which continues to indicate fluid entry is below the packer and to the existing perforations. Hilcorp requested on November 8, 2016 approval to extend the expiration date from December 31, 2016 to December 31, 2018. In 2014, Hilcorp committed to complete a repair of this well before Q4, 2016 with a new completion. Hilcorp now asserts the standalone well repair is not justified in this current price environment. Accordingly, the AOGCC believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AIO 6.013 Amended November 29, 2016 Page 2 of 2 AOGCC's approval to continue water injection only in Granite Point State 18742 13RD is conditioned upon the following: 1. Hilcorp shall record wellhead pressures and injection rate daily; 2. Hilcorp shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli with any bleeds flagged on the report; 3. Hilcorp shall install, maintain and operate automatic well shut-in equipment linked to the well's inner annulus (IA) and outer annulus (OA) pressure. The actuation pressure shall not exceed 2,150 psi for the inner annulus. The actuation pressure shall not exceed 750 psi for the outer annulus. Testing of the shut in equipment shut -down valve and mechanical or electrical pressure devices shall be performed upon install, and every 6 months thereafter, ideally in conjunction with production well pilots and safety valves. Hilcorp shall provide to the commission the testing procedure that will be used to verify integrity of the well shut-in equipment linked to the inner and outer annulus pressures; 4. Hilcorp shall limit the well's IA operating pressure to 2,150 psi; 5. Hilcorp shall limit the well's OA operating pressure to 750 psi; 6. Hilcorp shall perform a temperature survey every two years; 7. Hilcorp shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 8. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 9. This administrative approval shall expire on December 31, 2018. DONE at Anchorage, Alaska and dated November 29, 2016. //signature on file// Cathy P. Foerster Chair, Commissioner //signature on file// Daniel T. Seamount, Jr Commissioner a As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days isa denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov ADMINISTRATIVE APPROVAL AREA INJECTION ORDER 6.013 AMENDED Mr. Ryan Rupert CIO Operations Engineer Hilcorp Alaska, LLC. 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 Re: Docket Number: AIO-24-006 Request to Amend Area Injection Order 6.013, Water Only Injection Granite PT ST 18742 13RD (aka An-13RD) (PTD 1870440), Middle Kenai Oil Pool Dear Mr. Rupert: By emailed letter dated December 19, 2023, Hilcorp North Alaska, LLC (Hilcorp) requested administrative approval to amend Area Injection Order (AIO) 6.013 to remove the commitment to repair the well should a workover rig get deployed to the Anna platform and continue water only injection with a known tubing by inner annulus (TxIA) pressure communication. In accordance with 20AAC 25.556(d), the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS, subject to conditions, Hilcorp’s request to amend the administrative approval to remove the rig workover requirement and continue water only injection in the subject well. This well has communication between the tubing and 9 5/8” casing that was not resolved by a tubing patch intervention performed in August 2014. Hilcorp had previously committed to repair this well should a workover rig get deployed to the Anna platform. Hilcorp has now reneged on that workover commitment and plans to repair other wells on the platform. Hilcorp has performed multiple temperature surveys on a two-year schedule with the latest on October 7, 2022. This temperature survey continues to show good correlation with the other temperature surveys completed since 2014 and continues to indicate fluid entry is below the packer and to the existing perforations. AOGCC is implementing a four-year combination MIT of the tubing and inner annulus – in addition to the two- year temperature survey requirement. Accordingly, the AOGCC believes that the well’s condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC’s approval to continue water only injection in Granite Point State 18742 13RD is conditioned upon the following: 1) Hilcorp shall record wellhead pressures and injection rate daily; 2) Hilcorp shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli. Bleeds to be flagged on the report; AIO 6.013 Amended February 26, 2024 Page 2 of 2 3) Hilcorp shall install, maintain and operate automatic well shut-in equipment linked to the well’s inner annulus (IA) and outer annulus (OA) pressure. The actuation pressure shall not exceed 2,150 psi for the inner annulus. The actuation pressure shall not exceed 750 psi for the outer annulus. Testing of the shut in equipment shut-down valve and mechanical or electrical pressure devices shall be performed upon install, and every 6 months thereafter, ideally in conjunction with production well pilots and safety valves. Hilcorp shall provide to the commission the testing procedure that will be used to verify integrity of the well shut-in equipment linked to the inner and outer annulus pressures; 4) Hilcorp shall limit the well’s inner annulus operating pressure to 2,150 psi; 5) Hilcorp shall limit the well’s outer annulus operating pressure to 750 psi; 6) Hilcorp shall perform a temperature survey every two years; 7) Hilcorp shall perform a combination MIT of the tubing and inner annulus every four years to the greater of the maximum anticipated injection pressure or 0.25 x packer TVD, but not less than 1500 psi; 8) Hilcorp shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; and 9) After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection. 10) The next required combination MIT shall be completed before or during the month of October 2024. AOGCC must be provided the opportunity to witness the MIT for a test to establish a new test due date. DONE at Anchorage, Alaska and dated February 26, 2024. Brett W. Huber, Sr. Jessie L. Chmielowski Gregory C. Wilson Chair, Commissioner Commissioner Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.02.26 10:58:02 -09'00' Gregory Wilson Digitally signed by Gregory Wilson Date: 2024.02.26 13:48:14 -09'00' Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.02.26 14:35:04 -09'00' From:Coldiron, Samantha J (OGC) To:AOGCC_Public_Notices Subject:[AOGCC_Public_Notices] Area Injection Order 6.013 amended (Hilcorp) Date:Monday, February 26, 2024 2:50:10 PM Attachments:aio6.013 amended 022624.pdf Docket Number: AIO-24-006 Request to Amend Area Injection Order 6.013, Water Only Injection Granite PT ST 18742 13RD (aka An-13RD) (PTD 1870440), Middle Kenai Oil Pool Samantha Coldiron Special Assistant Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 (907) 793-1223 __________________________________ List Name: AOGCC_Public_Notices@list.state.ak.us You subscribed as: samantha.coldiron@alaska.gov Unsubscribe at: https://list.state.ak.us/mailman/options/aogcc_public_notices/samantha.coldiron%40alaska.go v INDEXES 35 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Ryan Rupert To:McLellan, Bryan J (OGC) Cc:Wallace, Chris D (OGC); Juanita Lovett; Dan Marlowe; Jamie Wilson; Casey Morse; Ryan Rupert Subject:Granite Point State 18742 #13RD (PTD#187-044) Modification Request to AIO 6.013 Date:Tuesday, December 19, 2023 4:29:57 PM Attachments:An-25 Admin Approval 6.004 March05.pdf An-25 Schematic 12-2-86.pdf MUCI-3_AOGCC_AdminApproval_Nov09.pdf MUCI-3 Schematic 7-23-07.pdf AIO 6-013 second amended 10-22-18.pdf An-13RD Schematic 2014-11-10.pdf Bryan- Hilcorp requests administrative approval to modify the second amendment of AIO 6.013 dated 10/22/18. Specifically, Hilcorp requests removal of the commitment to “Repair this well should a workover rig get deployed to the Anna platform. The existing conditions of approval would not need to be modified. The limited rates of EOR injection achievable in Anna injectors require the use of all 3 active injectors (Anna-13RD, Anna-25, and MUCI-3) to comfortably handle the produced water from the platform. This is especially true each winter as the water outfall line at Granite Point Tank Farm freezes up, and all produced water must be injected on the Anna platform. Below is a brief review of the 3 active injection wells. Associated schematics attached. Anna- 25 (Granite Point State 18742 #25) PTD #168-036 Dual string Jet Pump completion with no packer AA of AIO 6.004 for packer-less injector approved 3/29/05 Performed a temp log every 2 years since 2001. No anomalies MUCI-3 (Granite Point State 18742 MUCI-3) PTD #178-019 Traditional injector completion 1987 completion developed TxIA communication in 2009 AA of AIO 6.010 for TxIA communication approved 11/18/09 Performed a temp log every 2 years since 2009. No anomalies Anna-13RD (Granite Point State 18742 #13RD) PTD #187-044 Traditional injector completion 1987 completion developed TxIA in 2008 August 2014: Tubing patch set, still won’t pass an MIT-IA SL troubleshooting / leak hunting. No success Passed CMIT-TxIA to 2150psi against a TTP set at 8293’ MD AA of AIO 6.013 for TxIA communication approved 10/24/14 Performed a temp log every 2 years since 2014. No anomalies Given the following, Hilcorp believes that the current condition of the well does not compromise overall well integrity so as to threaten human safety or the environment. 1. Passing casing MIT in 2014 2. Repeat temp surveys in 2014, 2016, 2018, 2020, and 2022 showing no out of zone injection 3. Meets or exceeds the annular isolation of the other 2 active injectors on the platform Thank you for your consideration, Ryan Rupert CIO Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 aogcc.alaska.gov SECOND AMENDED ADMINISTRATIVE APPROVAL AREA INJECTION ORDER NO. 6.013 Ms. Holly Tipton Regulatory Technician Hilcorp Alaska, LLC. 3800 Centerpoint Drive Anchorage, AK 99503 Re: Docket Number: AIO-18-016 Request for administrative approval to eliminate the expiration date to allow Granite Point State 18742 13RD (PTD 1870440) to continue to be online in water only injection service with a known tubing by inner annulus communication Granite PT ST 18742 13RD (aka An-13RD) (PTD 1870440) Granite Point Field Middle Kenai Oil Pool Dear Ms. Tipton: By letter received April 16, 2018 and an email request dated October 17, 2018, Hilcorp Alaska, LLC (Hilcorp) requested administrative approval to eliminate the expiration date and continue water only injection in the subject well. In accordance with Rule 9 of Area Injection Order (AIO) 06.000, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS the Hilcorp request for administrative approval to eliminate the expiration date and continue water only injection in the subject well. This well has communication between the tubing and 9 5/8” casing that was not resolved by a tubing patch intervention performed in August 2014. Hilcorp has committed to repair this well should a workover rig get deployed to the Anna platform. Hilcorp has performed a temperature survey on October 15, 2018 which shows good correlation with the other temperature surveys completed October 18, 2014 and October 30, 2016 and continues to indicate fluid entry is below the packer and to the existing perforations. Accordingly, the AOGCC believes that the well’s condition does not compromise overall well integrity so as to threaten human safety or the environment. AIO 6.013 Second Amended October 22, 2018 Page 2 of 2 AOGCC’s approval to continue water injection only in Granite Point State 18742 13RD is conditioned upon the following: 1.Hilcorp shall record wellhead pressures and injection rate daily; 2.Hilcorp shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli with any bleeds flagged on the report; 3.Hilcorp shall install, maintain and operate automatic well shut-in equipment linked to the well’s inner annulus (IA) and outer annulus (OA) pressure. The actuation pressure shall not exceed 2,150 psi for the inner annulus. The actuation pressure shall not exceed 750 psi for the outer annulus. Testing of the shut in equipment shut-down valve and mechanical or electrical pressure devices shall be performed upon install, and every 6 months thereafter, ideally in conjunction with production well pilots and safety valves. Hilcorp shall provide to the commission the testing procedure that will be used to verify integrity of the well shut-in equipment linked to the inner and outer annulus pressures; 4.Hilcorp shall limit the well’s IA operating pressure to 2,150 psi; 5.Hilcorp shall limit the well’s OA operating pressure to 750 psi; 6.Hilcorp shall perform a temperature survey every two years; 7. Hilcorp shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 8.After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and DONE at Anchorage, Alaska and dated October 22, 2018. //signature on file// //signature on file// //signature on file// Hollis S. French Cathy P. Foerster Daniel T. Seamount, Jr. Chair, Commissioner Commissioner Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7lhAVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501-3539 PHONE (S07) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL AIO 6.010 Mr. Hal Martin Optimization Engineer Unocal Alaska P.O. Box 196247 Anchorage, AK 99519-6247 RE: Granite Point State 18742 MUCI-3 (PTD 178-019) Request for Administrative Approval Dear Mr. Martin: Per Rule 9 of Area Injection Order 6, the Alaska Oil and Gas Conservation Commission (AOGCC or Commission) hereby GRANTS Unocal Alaska (Unoca1)'s November 5, 2009 request for administrative approval to inject water in Granite Point State 18742 MUCI-3 (MUCI-3). Unocal notified the Commission on October 14, 2009 that MUCI-3 exhibits tubing by casing pressure communication. Although pressure communication to the casing annulus was indicated by provided pressure monitoring information, analysis of the data indicated that the casing remained competent. Approval to continue injection for the purpose of performing well integrity diagnostics was granted and Unoca1 performed a temperature survey on October 16,2009. Unocal has elected to perform no corrective action at this time on MUCI-3. Temperature surveys performed as part of the diagnostic testing confirm the injected fluids are exiting the well at the perforations and monitoring has shown that pressures are contained within the wellbore. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety_ The Commission's administrative approval to inject in MUCI-3 is conditioned upon the following: I. Injection is limited to WATER ONLY; 2. Unocal shall monitor and record tubing, 1I1ner annulus, and outer alUlUlus pressures and injection rate daily; Mr. Hal Martin November 18, 2009 Page 2 of2 3. Uno cal shall submit to the Commission a monthly report of well pressures and injection rates; 4. Uno cal shall perform a temperature survey every 2 years in lieu of the mechanical integrity test as outlined in Rule 6 of AIO 6 to demonstrate continued production casing integrity; 5. Unocal shall immediately shut in the well and notify the Commission if there is any change in the well's mechanical condition; and 6. After well shut in due to a change in the well's mechanical condition, Commission approval shall be required to restart injection. 7. The next temperature survey is due May 20, 2011 and at 2-year intervals thereafter. As provided in AS 31.05.080, within 20 days after written notice of this 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 rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DONE at Anchorage, Alaska and dated November 18,2009. Daniel T. Seamount, Jr. Chair REVISED: 11/10/14 DRAWN BY: JLL Granite Point Field Well: An-13RD As Completed: 6/87 SCHEMATIC API: 50-733-20055-01 RKB to TBG Hngr = 33ft KB ELEV: 105ft 3 1 C-5 Top MD: 8,551ft 2 C-8 Btm MD: 9,645ft C-7 5 XN PBTD: 10,214ft TD: 10,302ft 4 7in MD: 7,719ft Bkr F-1 Pkr MD: 8,304ft C-3 C-5A No.Depth (ft)ID (in)Item 33 Cameron Tbg Hanger 1 34 2.992 XO 3.5in BTC X 3.5in DSS-HTCH 2 8,303 2.992 Locator Joint 3 8,304 2.992 Seals 4 8,304 Baker F-1 Packer 5 8,315 2.992 Muleshoe JEWELRY DETAIL CSG Wt (lb/ft)Grade ID (in)Top (ft)Btm (ft) 20in 94 H-40 19.124 Surf 627 13-3/8in 54.5 J-55 12.615 Surf 2,002 9-5/8in 40 N-80 8.835 Surf 5,284 9-5/8in 40 S-95 8.835 5,284 7,343 9-5/8in 43.5 S-95 8.755 7,343 8,964 7in 35 N-80 6.004 7,719 10,295 Tubing: 3.5in 9.3 N-80 2.992 Surf 8,316 Casing and Tubing PERFORATION DATA Zone Top (ft) Btm (ft) Amt SPF Date Present Comments C-3 8,384' 8,417' 33' 6 10/9/2014 Open C-5A 8,526' 8,550' 24' 6 10/9/2014 Open C-5 8,551 8,581 30 4 7/87 Open Vann TCP C-5 8,606 8,648 42 4 7/87 Open Vann TCP C-7 9,188 9,192 4 4 7/87 Open Vann TCP C-7 9,012 9,042 30 4 7/87 Open Vann TCP C-7 9,064 9,088 24 4 7/87 Open Vann TCP C-7 9,102 9,112 10 4 7/87 Open Vann TCP C-7 9,133 9,182 49 4 7/87 Open Vann TCP C-7 9,217 9,223 6 4 7/87 Open Vann TCP C-7 9,228 9,258 30 4 7/87 Open Vann TCP C-7 9,284 9,360 76 4 7/87 Open Vann TCP C-8 9,582 9,645 63 4 7/87 Open Vann TCP Anna Platform Well No. MUCI-3 Work Over 4/14/87 O:\NAU\MCBU\Alaska\Depts\CI_Oil_Ops\Fields\GPF\Anna\Wells\Injectors\MUCI-3Inj\Schematics\MUCI-3 Schematic 7-23-07.doc DATE: 7/23/07 by BMB Updated: 10/23/09 by JHM 1 2 PBTD = 10,998’ TD = 11,065’ MAX. HOLE ANGLE = 17.5  KB Elev – 105’ C-7 3 4 5 C-8 C-2 6 C-5 C-6 2 A CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20 91.4 5LX-42 19.125 Surf 610’ 13-3/8” 61/68 S-80/K-55 12.415 Surf 3495’ 9-5/8” 47 S-95 8.681 Surf 173’ 9-5/8” 40 N-80 8.835 173’ 950’ 9-5/8” 47 SMN-80 8.681 950’ 3617’ 9-5/8” 43.5 S-95 8.755 3617’ 3661’ 9-5/8” 47 S-95 8.681 3661’ 9553’ 7” 35 N-80 6.004 9318’ 11050’ Tubing: 3-1/2” 9.3 N-80 DSS-HTC 2.992 Surf 9638’ JEWELRY DETAIL NO. Depth ID Item 1 33’ Hanger CIW Tbg Hanger 2 35’ Crossover 3-1/2 Btc. X 3-1/2” DSS-HTC 3 9626’ Seal locator 4 9625’ Baker F-1 Packer W/ 15000# set on it 5 9627’ Seal Assembly 6 9638’ Mule Shoe A. Ran 1.75” GR to 10674’ and tagged up 10/16/09 PERFORATION DATA Zone Top Btm Amt Accum SPF Perf Date C-2 9718 9734 16 6 April 78, Jan 80 Sqz 9825 9827 2 3 Apr-78 C-5 9954 9964 10 6 April 78, Jan 80 10004 10094 90 6 April 78, Jan 80 C6 10186 10206 20 6 April 78, Jan 80 10252 10262 10 6 April 78, Jan 80 10334 10350 16 6 April 78, Jan 80 C7 10436 10454 18 6 April 78, Jan 80 10474 10490 16 6 April 78, Jan 80 10520 10544 24 6 April 78, Jan 80 10576 10600 24 6 April 78, Jan 80 C8 10820 10830 10 6 April 78, Jan 80 10880 10890 10 6 April 78, Jan 81 10926 10950 24 6 April 78, Jan 82 *I Docl� 4io ( -c,3 Wallace, Chris D (DOA) /-�tO 15-01( P TD /T -70J --9-C;) From: Holly Tipton <hotipton@hilcorp.com> Sent: Wednesday, October 17, 2018 2:39 PM To: Wallace, Chris D (DOA) Subject: Granite Point State 18742 #13RD Temp Survey Attachments: An-13RD AIO 6.013 Request for Expiration Elimination 3-19-18.pdf, AN 13RD Temp Survey 10-15-18 vs 10-30-16.xis Hi Chris, On 10/15/18, a compliance temp survey was completed on Granite Point State 18742 #13RD (aka Anna Well No. 13RD — PTD 1870440), per condition #6 of AIO 6.013. The attached temperature survey plot, overlaying An-13RD temp surveys on 10/15/2018, 10/30/16, and 10/18/14, indicates downhole containment of the injection fluids with no significant temperature anomalies. No visible anomalies demonstrate that downhole fluid containment is being maintained. The three temp surveys run every two years overlay each other, which continues to be a good indication that nothing has changed in regards to casing integrity and that the injected fluids are exiting the casing at the perfs. With the monthly plots being submitted to the State showing expected rates and pressures, and this most recent temp survey indicating that injected water remains contained in the targeted EOR interval, we'd like to uphold our request to remove the sunset expiration from AIO 6.013. A copy of the official request originally submitted in March 2018 to remove this expiration in AIO 6.013 is also attached. Thank you and please feel free to call with any questions, Holly Tipton Hilcorp Alaska, LLC 907-777-8330 0 �U1. TC'��,✓l, c,w,� Larry Greenstein APR 16 2018 From: Larry Greenstein AOU` V V Sent: Monday, March 19, 2018 7:39 AM To: Chris Wallace @ AOGCC Subject: Granite Point State 18742 #13RD (aka An-13RD PTD #1870440) AIO 6.013 - Request for Expiration Elimination Attachments: AIO 6-013 amended 11-29-16.pdf Hi Chris As AIO 6.013 is one of the only Administrative Approvals (AA) to have an expiration date, our request is that the expiration date be eliminated from this AA as it serves no useful purpose. The prove up of injected fluid containment outweighs the artificial deadline (two years) first proposed by Hilcorp and then extended by the amended AIO 6.013 attached. As noted in the highlighted paragraph from the Nov 2016 request below, not only was a WO rig not deployed to the Anna platform in 2016 or 2017, but it appears from this year's approved budget line items that there will not be a WO rig sent to the Anna in 2018 either. The commitment of a WO to fix the well still stands but remains uneconomic as a standalone project. The limited EOR rates achievable in the Anna reservoirs require the use of all three of the existing injections wells to comfortably handle the produced water being processed out of the oil. This is most critical during the winter months when the outfall line at GPTF freezes off and all of the water production from Anna, Bruce and Granite Point platforms has to be injected on each platform as the water can no longer be sent to the tank farm. Assuming the monthly plots for this well, being sent to the State, continue to display expected rates and pressures and this October's two year compliance temp survey again indicates that the injected water remains contained in the EOR intervals targeted by the perts in the An-13RD well, we are requesting permission to extend AIO 6.013 indefinitely. This would align the 'lifetime' of this AA with nearly every other AA currently in force. The AA for An-13RD would still remain different due to the commitment to fix this well should a WO rig get deployed to Anna for other well work. So, rather than wait until the compliance temp survey is completed this October to request an extension to this AIO and contingent upon the success of this upcoming survey in proving full injection containment, we wanted to propose this change ahead of time now that our 2018 budget is in place. Thank you and please c II with ny questions Larryep,� 777-8322 From: Larry Greenstein Sent: Tuesday, November 08, 2016 3:10 PM To:'Chris Wallace @ AOGCC' <chris.wallace@alaska.gov> Subject: Granite Point State 18742 #13RD (aka An-13RD) AIO 6.013 Compliance Temp Survey 10-30-16 Hi Chris, On 10/30/16, a compliance temp survey was completed on Granite Point State 18742 #13RD (aka Anna Well No. 13RD — PTD 1870440), per condition #6 of AIO 6.013. The attached temperature survey plot, overlaying An-13RD temp surveys on 10/30/16 and 10/18/14, indicates downhole containment of the injection fluids with no significant temperature anomalies. No visible anomalies demonstrate that downhole fluid containment is being maintained. Also notable is that the two temp surveys run two years apart nearly overlay one another — another good indicator that nothing has changed regarding casing integrity and all injected fluids are still exiting the casing at the perts. Per condition #9 of AIO 6.013, the expiration date of this AA is 12/31/16. The attached e-mail resulted in this deadline by referencing (in 2014) the certainty of repairs being completed on this well before the end of this year (2016)... such is not the case. Due to re -verifying the injected fluid containment, as proven by the overlaid temp surveys, and the challenging price environment to justify a standalone costly well repair, Hilcorp is requesting an extension of this AA for two more years (ie 12/31/18). Should an occasion arise to get a WO rig on the platform prior to this new deadline, the opportunity to repair the integrity in this well will be taken. Thank you Please call me if you have any questions. Larry 777-8322 THE STATE °fALASKA GOVERNOR BILL WALKER Alaska Oil and Gas Conservation Commission ADMINISTRATIVE APPROVAL AREA INJECTION ORDER NO. 6.013 AMENDED Mr. Larry Greenstein Regulatory Compliance Manager Hilcorp Alaska, LLC. P.O. Box 244027 Anchorage, AK 99524-4027 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 aogcc.alaska.gov Re: Docket Number: AlO-16-044 Request for administrative approval to amend the expiration date to allow Granite Point State 18742 13RD (PTD 1870440) to continue to be online in water only injection service with a known tubing by inner annulus communication Granite PT ST 18742 13RD (aka An-13RD) (PTD 1870440) Granite Point Field Middle Kenai Oil Pool Dear Mr. Greenstein: By email dated November 8, 2016, Hilcorp Alaska, LLC (Hilcorp) requested administrative approval to amend the expiration date to continue water only injection in the subject well. In accordance with Rule 9 of Area Injection Order (AIO) 06.000, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS the Hilcorp request for administrative approval to continue water only injection in the subject well. This well has communication between the tubing and 9 5/8" casing that was not resolved by a tubing patch intervention performed in August 2014. Hilcorp requested on September 4, 2014 approval to perform a baseline temperature survey, perform a 30 day injection test, then run a follow up temperature survey to determine fluid entry. AOGCC granted that request and these were completed October 18, 2014. Hilcorp has also performed a temperature survey on October 30, 2016, which continues to indicate fluid entry is below the packer and to the existing perforations. Hilcorp requested on November 8, 2016 approval to extend the expiration date from December 31, 2016 to December 31, 2018. In 2014, Hilcorp committed to complete a repair of this well before Q4, 2016 with a new completion. Hilcorp now asserts the standalone well repair is notjustified in this current price environment. Accordingly, the AOGCC believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. ATO 6.013 Amended November 29, 2016 Page 2 of 2 AOGCC's approval to continue water injection only in Granite Point State 18742 13RD is conditioned upon the following: 1. Hilcorp shall record wellhead pressures and injection rate daily; 2. Hilcorp shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli with any bleeds flagged on the report; 3. Hilcorp shall install, maintain and operate automatic well shut-in equipment linked to the well's inner annulus (IA) and outer annulus (OA) pressure. The actuation pressure shall not exceed 2,150 psi for the inner annulus. The actuation pressure shall not exceed 750 psi for the outer annulus. Testing of the shut in equipment shut -down valve and mechanical or electrical pressure devices shall be performed upon install, and every 6 months thereafter, ideally in conjunction with production well pilots and safety valves. Hilcorp shall provide to the commission the testing procedure that will be used to verify integrity of the well shut-in equipment linked to the inner and outer annulus pressures; 4. Hilcorp shall limit the well's IA operating pressure to 2,150 psi; 5. Hilcorp shall limit the well's OA operating pressure to 750 psi; 6. Hilcorp shall perform a temperature survey every two years; 7. Hilcorp shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 8. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 9. This administrative approval shall expire on December 31, 2018. DONE at Anchorage, Alaska and dated November 29, 2016. //signature on file// Cathy P. Foerster Chair, Commissioner //signature on file// Daniel T. Seamount, Jr Commissioner As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to ran 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. Larry Greenstein Sent: Monday, March 19, 2018 7:26 AM To: Chris Wallace @ AOGCC Subject: Granite Point State 18742 #13RD (aka An-13RD PTD #1870440) AIO 6.013 - Request for Expiration Elimination Attachments: AIO 6-013 amended 11-29-16.pdf Hi Chris As AIO 6.013 is one of the only Administrative Approvals (AA) to have an expiration date, our request is that the expiration date be eliminated from this AA as it serves no useful purpose. The prove up of injected fluid containment outweighs the artificial deadline (two years) first proposed by Hilcorp and then extended by the amended AIO 6.013 attached. As noted in the highlighted paragraph from the Nov 2016 request below, not only was a WO rig not deployed to the Anna platform in 2016 or 2017, but it appears from this year's approved budget line items that there will not be a WO rig sent to the Anna in 2018 either. The commitment of a WO to fix the well still stands but remains uneconomic as a standalone project. The limited EOR rates achievable in the Anna reservoirs require the use of all three of the existing injections wells to comfortably handle the produced water being processed out of the oil. This is most critical during the winter months when the outfall line at GPTF freezes off and all of the water production from Anna, Bruce and Granite Point platforms has to be injected on each platform as the water can no longer be sent to the tank farm. Assuming the monthly plots for this well, being sent to the State, continue to display expected rates and pressures and this October's two year compliance temp survey again indicates that the injected water remains contained in the EOR intervals targeted by the perfs in the An-13RD well, we are requesting permission to extend AIO 6.013 indefinitely. This would align the 'lifetime' of this AA with nearly every other AA currently in force. The AA for An-13RD would still remain different due to the commitment to fix this well should a WO rig get deployed to Anna for other well work. So, rather than wait until the compliance temp survey is completed this October to request an extension to this AIO and contingent upon the success of this upcoming survey in proving full injection containment, we wanted to propose this change ahead of time now that our 2018 budget is in place. Thank you and please call with any questions Larry 777-8322 RECEIVE® MAR 19 2018 From: Larry Greenstein AO �� Sent: Tuesday, November 08, 2016 3:10 PM To: 'Chris Wallace @ AOGCC' <chris.wallace@alaska.gov> Subject: Granite Point State 18742 #13RD (aka An-13RD) AIO 6.013 Compliance Temp Survey 10-30-16 Hi Chris, On 10/30/16, a compliance temp survey was completed on Granite Point State 18742 #13RD (aka Anna Well No. 13RD — PTD 1870440), per condition #6 of AIO 6.013. The attached temperature survey plot, overlaying An-13RD temp surveys on 10/30/16 and 10/18/14, indicates downhole containment of the injection fluids with no significant temperature anomalies. No visible anomalies demonstrate that downhole fluid containment is being maintained. Also notable is that the two temp surveys run two years apart nearly overlay one another — another good indicator that nothing has changed regarding casing integrity and all injected fluids are still exiting the casing at the perfs. Per condition #9 of AIO 6.013, the expiration date of this AA is 12/31/16. The attached e-mail resulted in this deadline by referencing (in 2014) the certainty of repairs being completed on this well before the end of this year (2016)... such is not the case. Due to re -verifying the injected fluid containment, as proven by the overlaid temp surveys, and the challenging price environment to justify a standalone costly well repair, Hilcorp is requesting an extension of this AA for two more years (ie 12/31/18). Should an occasion arise to get a WO rig on the platform prior to this new deadline, the opportunity to repair the integrity in this well will be taken. Thank you Please call me if you have any questions. Larry 777-8322 33 Wallace, Chris D (DOA) From: Larry Greenstein <Ireenstein@hilcorp.com> Sent: Tuesday, November 08, 2016 3:10 PM To: Wallace, Chris D (DOA) Subject: Granite Point State 18742 #13RD (aka An-13RD) AIO 6.013 Compliance Temp Survey 10-30-16 Attachments: AN 13RD Temp Survey 10-30-16 vs 10-18-14.xls; RE: An-13RD AA (PTD: 187-044) 10-23-14 Hi Chris, On 10/30/16, a compliance temp survey was completed on Granite Point State 18742 #13RD (aka Anna Well No. 13RD — PTD 1870440), per condition #6 of AIO 6.013. The attached temperature survey plot, overlaying An-13RD temp surveys on 10/30/16 and 10/18/14, indicates downhole containment of the injection fluids with no significant temperature anomalies. No visible anomalies demonstrate that downhole fluid containment is being maintained. Also notable is that the two temp surveys run two years apart nearly overlay one another — another good indicator that nothing has changed regarding casing integrity and all injected fluids are still exiting the casing at the perfs. Per condition #9 of AIO 6.013, the expiration date of this AA is 12/31/16. The attached e-mail resulted in this deadline by referencing (in 2014) the certainty of repairs being completed on this well before the end of this year (2016)... such is not the case. Due to re -verifying the injected fluid containment, as proven by the overlaid temp surveys, and the challenging price environment to justify a standalone costly well repair, Hilcorp is requesting an extension of this AA for two more years (ie 12/31/18). Should an occasion arise to get a WO rig on the platform prior to this new deadline, the opportunity to repair the integrity in this well will be taken. Thank you Please call me if you have any questions. Larry 777-8322 AN__I__ 1 1 / %A/_11. I A\1 J A^MM Ir:_IJ_ A____- -1. 1 m Y w 500C 4) a 600C sZ 4) a vressure (psia) 1000 1500 2000 2500 3000 3500 4000 4500 Pressure -Temperature Profile 1. RIH Overlay 10/18/14 - 10/30/16 11000 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 —10-30-16 Pressure — Perfs —9 5/8" 7" 20" 13 3/8" 10-30-16 Temp 10-18-14 Temp Report date: 11/23/2016 Wallace, Chris D (DOA) From: Daniel Taylor <dtaylor@hilcorp.com> Sent: Thursday, October 23, 2014 3:12 PM To: Wallace, Chris D (DOA) Subject: RE: An-13RD AA (PTD: 187-044) 10-23-14 Attachments: An-13RD 6month Pressure.xlsx Chris, Please see the attached tubing and casing pressures for the An-13RD. As I mentioned on the phone. The injection pressures are sporadic because we are not continuously injecting. These pressures are entered manually. The previously recorded 13-3/8in pressure was reading 200psi due to the gauge being positioned on the other side of a header block valve. The valves have since been oriented appropriately and the 13-3/8in casing is reading zero. Please give me a call if you have any further questions. Thank you. Regards, Daniel Taylor Operations Engineer Hilcorp Alaska, LLC. O: 907-777-8319 C: 907-947-8051 From: Daniel Taylor Sent: Monday, October 20, 2014 11:11 AM To: 'Wallace, Chris D (DOA)' Subject: RE: An-13RD AA (PTD: 187-044) Chris, Please see the attached overlay of the two temperature surveys (9/17 and 10/18). They overlay well and show no exit other than to the perforations. I have also attached the previous jug test of casing indicating we have casing integrity. At this time we do not have An-13RD on the schedule for work over. However, we plan on being on the Anna platform with a pulling unit within the next +/-2years with 100% certainty. There is a 50% chance that we will be on this well in 2015. Do we have permission to continue injecting into An-13RD knowing that we will be working over the well by December 2016? Thank you Chris. Regards, Daniel Taylor Operations Engineer Hilcorp Alaska, LLC. O: 907-777-8319 C: 907-947-8051 From: Daniel Taylor Sent: Friday, October 17, 2014 2:06 PM To: 'Wallace, Chris D (DOA)' Subject: RE: An-13RD AA (PTD: 187-044) Chris, We have completed our one month injection test into this well and are currently rigging up to get the temperature survey tonight or tomorrow. We will be following up with you shortly. Thank you. Regards, Daniel Taylor Operations Engineer Hilcorp Alaska, LLC. 0: 907-777-8319 C: 907-947-8051 From: Wallace, Chris D (DOA)[mailto:chris.wallace@alaska.govl Sent: Tuesday, September 16, 2014 2:45 PM To: Daniel Taylor Subject: RE: An-13RD AA (PTD: 187-044) Daniel, Thank you for the phone call this afternoon and the explanation of the plan. We approve your request for 30 days water injection for diagnostic testing and monitoring with TxIA communication. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 71h Avenue Anchorage, AK 99501 (907) 793-1250 (phone) (907) 276-7542 (fax) chris.wallace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Daniel Taylor [mailto:dtaylor@hilcorp.com] Sent: Thursday, September 04, 2014 1:20 AM To: Wallace, Chris D (DOA) Subject: An-13RD AA (PTD: 187-044) Mr. Wallace, We are pursuing an AA for the An-13RD to return to injection. Well Granite Point State 18742 No. An-13RD has been shut in since January of 2008. It is an injector that has communication between tubing and the 9-5/8in casing. Last month (8/14) we ran diagnostics to locate and isolate the compromised section of tubing without success. We performed a jug test with a tubing plug set at 8,293ft for 1 hr at 2,150psi confirming that we have casing integrity to the top of packer set at 8,304ft (please see attached). We are requesting permission for temporary injection for 1 month. Within that time we will run a temperature survey to help evaluate the mechanical integrity of the well. After this we will shut in the well and wait until you have had time to evaluate the jug test and temperature survey. Do we have your permission to move forward with this plan of action? Thank you sir. Regards, Daniel Taylor Operations Engineer Hilcorp Alaska, LLC. O: 907-777-8319 C: 907-947-8051 32 Wallace, Chris D (DOA) From: Daniel Taylor <dtaylor@hilcorp.com> Sent: Monday, October 20, 2014 11:11 AM To: Wallace, Chris D (DOA) Subject: RE: An-13RD AA (PTD: 187-044) Attachments: An-13RD Csg.Testl.pdf; AN-13RD Temp Survey 9-17-14 vs 10-18-14.pdf Chris, Please see the attached overlay of the two temperature surveys (9/17 and 10/18). They overlay well and show no exit other than to the perforations. I have also attached the previous jug test of casing indicating we have casing integrity. At this time we do not have An-13RD on the schedule for work over. However, we plan on being on the Anna platform with a pulling unit within the next +/-2years with 100% certainty. There is a 50% chance that we will be on this well in 2015. Do we have permission to continue injecting into An-13RD knowing that we will be working over the well by December 2016? Thank you Chris. Regards, Daniel Taylor Operations Engineer Hilcorp Alaska, LLC. O: 907-777-8319 C: 907-947-8051 From: Daniel Taylor Sent: Friday, October 17, 2014 2:06 PM To: 'Wallace, Chris D (DOA)' Subject: RE: An-131RD AA (PTD: 187-044) Chris, We have completed our one month injection test into this well and are currently rigging up to get the temperature survey tonight or tomorrow. We will be following up with you shortly. Thank you. Regards, Daniel Taylor Operations Engineer Hilcorp Alaska, LLC. O: 907-777-8319 C: 907-947-8051 From: Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent: Tuesday, September 16, 2014 2:45 PM To: Daniel Taylor Subject: RE: An-13RD AA (PTD: 187-044) Daniel, Thank you for the phone call this afternoon and the explanation of the plan. We approve your request for 30 days water injection for diagnostic testing and monitoring with TxlA communication. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 (907) 793-1250 (phone) (907) 276-7542 (fax) chris.wallace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Daniel Taylor [mailto:dtaylor@hilcorp.com] Sent: Thursday, September 04, 2014 1:20 AM To: Wallace, Chris D (DOA) Subject: An-13RD AA (PTD: 187-044) Mr. Wallace, We are pursuing an AA for the An-13RD to return to injection. Well Granite Point State 18742 No. An-13RD has been shut in since January of 2008. It is an injector that has communication between tubing and the 9-5/8in casing. Last month (8/14) we ran diagnostics to locate and isolate the compromised section of tubing without success. We performed a jug test with a tubing plug set at 8,293ft for 1 hr at 2,150psi confirming that we have casing integrity to the top of packer set at 8,304ft (please see attached). We are requesting permission for temporary injection for 1 month. Within that time we will run a temperature survey to help evaluate the mechanical integrity of the well. After this we will shut in the well and wait until you have had time to evaluate the jug test and temperature survey. Do we have your permission to move forward with this plan of action? Thank you sir. Regards, Daniel Taylor Operations Engineer Hilcorp Alaska, LLC. O: 907-777-8319 C: 907-947-8051 SCHEMATIC Granite Point Field Well: An-13RD ti��P-aia,kA,t.Lc As Completed: 6/87 API: 50-733-20055-01 RKB to TBG Hngr = 33ft KB ELEV: 105ft 4: w l5fl PBTD: 10,214ft TD: 10,302ft Casing and Tubing CSG Wt (lb/ft) Grade ID (in) Top (ft) Btm (ft) 20in 94 H-40 19.124 Surf 627 13-3/8in 54.5 J-55 12.615 Surf 2,002 9-5/8in 40 N-80 8,835 Surf 5,284 9-5/8in 40 S-95 8.835 5,284 7,343 9-5/8in 43.5 S-95 8.755 7,343 8,964 7in 35 N-80 1 6.0041 7,7191 10,295 Tubing: 3.5in 9.3 1 N-80 1 2.992 Surf 8,316 1 EW ELRY DETAII No. Depth (ft) ID (in) Item 33 Cameron Tbg Hanger 1 34 2.992 XO 3.5in BTC X 3.5in DSS-HTCH 2 8,303 2.992 Locator Joint 3 8,304 2.992 Seals 4 8,304 Baker F-1 Packer 5 8,315 2.992 Muleshoe PERFORATION DATA Zone Top (ft) Btm (ft) Amt SPF Date Present Comments C-5 8,551 8,581 30 4 7/87 Open Vann TCP C-5 8,606 8,648 42 4 7/87 Open Vann TCP C-7 9,188 9,192 4 1 4 7/87 Open Vann TCP C-7 9,012 9,042 30 4 7/87 Open IVann TCP C-7 9,064 9,088 24 4 7/87 Open Vann TCP C-7 9,102 9,112 10 4 7/87 Open Vann TCP C-7 9,133 9,182 49 4 7/87 Open Vann TCP C-7 9,217 9,223 6 4 7/87 Open Vann TCP C-7 9,228 9,258 30 4 7/87 Open Vann TCP C-7 9,284 9,360 76 4 7/87 Open Vann TCP C-8 9,582 91645 63 4 7/87 Open Vann TCP REVISED: 8-12-14 DRAWN BY: DRT 6 AM N i:2 T Wd 9 Hilcorp I Well: AN-13RD I Field: jAnna Pit. 10/18/2014 1 1 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 Temperature (Deg. F) 10-18-14 Pressure — Perfs x PKR 20" 13 3/8" 9 5/8" _„w 7" 3 1/2" 10-18-14 Temp —9-17-14 Terr Report date: 10/20/2014 431 • C] Wallace, Chris D (DOA) From: Larry Greenstein [Ireenstein@hilcorp.com] Sent: Thursday, January 30, 2014 7:57 AM To: Wallace, Chris D (DOA) Cc: Reid Edwards Subject: RE: AIO 6.011 expires today for Bruce 5RD-86 (PTD 1790050) Attachments: Injection well BR 5RD-86 Thank you for the note, Chris. We were aware of the 1 yr limitation of the AA for this well. As we had recently shut-in the well, we swung blinds and labeled the well with placards to ensure that the well will not inadvertently be returned to injection (see attached e-mail from 1/10/14). It is Hilcorp's intention to not use this well for injection in its present condition. I will add this well to my LTSI (long term shut-in) list for quarterly monitoring and as such, the AIO 6.011 Administrative Approval can be cancelled. If you have any question, please call. Larry From: Wallace, Chris D (DOA)[mailto:chris.wallace(�i)alaska.gov] Sent: Wednesday, January 29, 2014 9:12 AM To: Larry Greenstein Subject: AIO 6.011 expires today for Bruce 5RD-86 (PTD 1790050) Larry, Our records indicate NO 6.011 will expire today. Please confirm it is Hilcorp's intention for me to cancel the AA. Thanks and have a great day. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 (907) 793-1250 (phone) (907) 276-7542 (fax) chris.wallace@alaska.gov • • Wallace, Chris D (DOA) From: Aaron Douget [adouget@hilcorp.com] Sent: Friday, January 10, 2014 1:06 PM To: Larry Greenstein Cc: Chester Holt; Stuart Allison; Glen Payment Subject: Injection well BR 5RD-86 Attachments: photo 1.JPG; photo 2.JPG; photo 3.JPG Larry, Attached are some pictures of 5-86. Right now it has the spec blind rolled and two signs stating that it is not to be injected to. Let me know if there is anything else I need to do. Thanks, Aaron Douget Bruce Platform r�„� �� ~. �� #30 Wallace, Chris D (DOA) From: Larry Greenstein [Ireenstein@hilcorp.com] Sent: Tuesday, October 01, 2013 5:41 PM To: Wallace, Chris D (DOA) Subject: RE: Sanitary Waste to Cook Inlet platforms Thank you for the quick request for info, Chris. I appreciate you attempting to get this cleared up as soon as possible. I tried to get the compatibility testing done for the specific FOR fluids by platform intentionally. AIO 6 for NGP field has Anna and Bruce platforms only putting produced water into the ground. As there is only one oil pool at this time getting FOR (Tyonek), any injection well on either platform would be putting water into that one pool. The Granite Point platform isn't doing any FOR injection and none is planned at this time. That is a little different than Dolly and Steelhead where there are three oil pools getting FOR fluids (West Foreland, Hemlock and G-Zone) using only filtered inlet water (FIW) now. Which is why the compatibility testing was done using that particular fluid for these platforms. As the King, Grayling and even Monopod already have permission to enhance their FIW FOR fluids with sanitary waste, I was just trying to extend that to all the platforms in AID 5 with the compatibility testing on the Dolly and Steelhead. Even if we were to convert other wells to FOR injection on these platforms, they would only be going to the existing oil pools within their respective AIOs. As I didn't see anything specific to the oil pools on the other approvals, I didn't get specific with my request. Perhaps I don't completely understand what review you are looking to get from me. I will be back on Monday and I'll call you if the info above isn't what you were needing to complete the AA process. Larry From: Wallace, Chris D (DOA) [chris.wallace@alaska.gov] Sent: Monday, September 30, 2013 10:34 AM To: Larry Greenstein Subject: Sanitary Waste to Cook Inlet platforms Larry, We have received the water compatibility analysis for Anna, Bruce, Dolly, and Steelhead and your request for administrative approval. Your request references AIO 5 McArthur River and AIO 6 North Granite Point. As these are platform specific water compatibility, it makes sense to ensure all wells utilizing these streams be covered. Please review your wells on each platform, review which injection oil pool each well is allocated, and confirm which AIO's are affected. Our aim is to complete an administrative approval for each AID, referencing the platform (s) included in the water compatibility analysis. 1 Call if questions. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 (907) 793-1250 (phone) (907) 276-7542 (fax) chris.wallace(@alaska.gov<mailto:chris.wallacepalaska.gov> #29 .7 0 n G %* F, A V" W SEP 2 0 2013 Hilcorp Alaska, LLC September 20, 2013 Chris Wallace Alaska Oil and Gas Conservation Commission 333 West 71h Avenue, Suite 100 Anchorage, Alaska 99501 AULitL Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 100 Anchorage, AK 99503 Phone:907/777-8322 RE: Request for Administrative Approval to add Sanitary Waste to the Enhanced Oil Recovery (EOR) fluids at McArthur River (AIO #5) and Granite Point (AIO #6) fields. Dear Mr. Wallace: Per our previous discussions, Hilcorp Alaska, LLC (Hilcorp) is requesting Administrative Approvals for the use of Sanitary Waste (treated effluent) to be used as an enhancement to the FOR fluids in the McArthur River and North Granite Point fields. These fluids have already been authorized for use on certain platforms in Cook Inlet (King Salmon — 12-4-92 letter, Grayling — AIO #5 6-7-94 letter and Monopod — AIO #12 6-7-94 letter). We are requesting to extend those approvals to other platforms based on the compatibility tests that have been completed (attached) which indicate that no problems with overall injectivity would occur with the addition of these fluids to the FOR fluids. The tests confirm that the mixture of treated effluent and either produced water (Anna & Bruce) or seawater (Dolly & SHP) wouldn't cause any incompatibilities or precipitants that would impact the FOR projects in these fields. With consideration of the successful compatibility testing and the proven benign nature of previously approved treated effluent additions to the FOR fluid streams, Hilcorp requests that the treated effluent fluids be approved as appropriate additions to the FOR fluids in the McArthur River (AIO #5) and North Granite Point (AIO #6) fields. Sincerel , /�'La rry Green ein, Regulatory Compliance Hilcorp Alaska, LLC IN[ Hilcorp Alaska, LLC August 18, 2013 Larry Greenstein Hilcorp Alaska Cook Inlet Kenai, Alaska Executive Summary FrAA a a BAKER NUGNES 14704 Kenai Spur Hwy Kenai, AK 99611 Tel: 907-283-4634 Fax: 907-283-9619 Todd Stone Senior Advisor Kenai Peninsula Enhanced FOR Study • Fluid Compatibility Testing • • Treated sanitary waste water is to be injected as a component of enhanced waterflood. • Testing was done to verify the compatibility of the sanitary waste water with other water components in the injection system. • Waters were collected and analyzed by Baker Hughes for the Anna, Bruce, Dolly Varden, and Steelhead Platforms. • These analyses were used to determine scaling scaling tendencies using ScaleSoftPitzer TM Scale Program. • Ratios for mixing were supplied by Hilcorp Alaska. Collection &Testing The identified waters were collected and pH and soluble gases (HCO3, CO2) were run prior to sending into lab for analyses. The analytical data was used to run scaling tendencies using ScaleSoftPitzer TM Scale Program from Rice University. Samples of these same waters were used for mixing at predetermined ratios for observation of precipitants. Results The results of the testing are provided in reports for each platform following this cover letter. Please review these reports and contact me in the Kenai office (907-283-4634) if you have any questions. Disclaimer of Liability: Baker Petrolite Corporation and its affiliates (BPC) disclaim all warranties or representations express or implied, including any implied warranties of merchantability or fitness for aparticular purpose or to the accuracy, correctness or completeness of such information herein or that reliance on such information will accomplish any particular result. All such information is furnished "as is" and by using such information the user is assuming all liabilities for the use or reliance on such information. BPC SHALL NOT BE LIABLE FOR ANY INDIRECT, SPECIAL, PUNITIVE, EXEMPLARY OR CONSEQUENTIAL DAMAGES OR LOSSES FROM ANY CAUSE WHATSOEVER INCLUDING BUT NOT LIMITED TO ITS NEGLIGENCE. Regards, 9 • Todd Stone I Senior Advisor Baker Hughes I Upstream Chemical & Capillary Services Office: 907-283-4634 1 Cell 907-398-8426 todd.stoneCaD-bakerhughes.com http://www.bakerhughes.com I Advancing Reservoir Performance Cc Mike Ping — Hilcorp Dan Marlowe — Hilcorp Disclaimer of Liability Baker Petrolite Corporation and its affiliates (BPC) disclaim all warranties or representations express or implied, including any implied warranties of merchantability or fitness for a particular purpose or to the accuracy, correctness or completeness of such information herein or that reliance on such information will accomplish any particular result. All such information is furnished "as is" and by using such information the user is assuming all liabilities for the use or reliance on such information. BPC SHALL NOT BE LIABLE FOR ANY INDIRECT, SPECIAL, PUNITIVE, EXEMPLARY OR CONSEQUENTIAL DAMAGES OR LOSSES FROM ANY CAUSE WHATSOEVER INCLUDING BUT NOT LIMITED TO ITS NEGLIGENCE. Anna Platform Water Analyses & Mixing Data The sanitary fluids on the Anna Platform are mixed with FIW and, as needed, a salt brine for processing. The amount of daily sanitary fluid treated is 250 bbls. When injected for FOR it would be mixed with 180 bbis clean produced water. Parameters for calculating scaling indices are Ttopside= 1000F, Ptopslde=100 psi, BHT=1600F, and a water mix of 180.250. The water analyses and scaling tendencies for both waters and the mixed brine are attached. The Anna PW alone has a no scaling tendency for calcite in the temperature range of discussion. The barite scaling tendency is moderate. The Anna produced water is treated with a scale inhibitor for scale prevention. The Anna sanitary water has no scaling tendencies. When mixed together, the brine scaling tendency remains at zero for calcite and is reduced for barite. I would expect no scale precitpitation/deposition related to mixing the two waters. Anna Scale Data. pdf Bruce Platform Water Analyses & Mixing Data The sanitary fluids on the Bruce Platform are nomally not mixed with additional water for processing. Ocasionally drill water is added to aid in processing. The amount of daily sanitary fluid treated is 25-100 bbis, depending on the number of people on board. When injected for FOR it would be mixed with 75-100 bbis clean produced water. Parameters for calculating scaling indices are Ttopside= 70°F, Ptopside=3200 psi, BHT=1600F, and a water mix of 100.100. The water analyses and scaling tendencies for both waters and the mixed brine are attached. The Bruce PW alone has a slight scaling tendency for calcite and barite. The Bruce sanitary water has no scaling tendencies. When mixed together, the brine scaling tendency is reduced to zero for calcite and greatly reduced for barite. I would expect no scale precitpitation/deposition related to mixing the two waters. Bruce Sole Data. pdf Disclaimer of Liability Baker Petrolite Corporation and its affiliates (BPC) disclaim all warranties or representations express or implied, including any implied warranties of merchantability or fitness for aparticular purpose or to the accuracy, correctness or completeness of such information herein or that reliance on such information will accomplish any particular result. All such information is furnished "as is" and by using such information the user is assuming all liabilities for the use or reliance on such information. BPC SHALL NOT BE LIABLE FOR ANY INDIRECT, SPECIAL, PUNITIVE, EXEMPLARY OR CONSEQUENTIAL DAMAGES OR LOSSES FROM ANY CAUSE WHATSOEVER INCLUDING BUT NOT LIMITED TO ITS NEGLIGENCE. Dolly Varden Platform Water Analyses & Mixing Data The sanitary fluids on the Dolly Varden Platform are mixed with filtered seawater for processing. The amount of daily sanitary fluid treated is estimated at 419 bbls. When injected for FOR it would be mixed with 20,000 bbls FIW. Parameters for calculating scaling indices are Ttopside= 80°F, Ptopside=3450 psi, BHT=1600F, and a water mix of 20,000:419. The water analyses and scaling tendencies for both waters and the mixed brine are attached. Because the makeup water for the sanitary system is FIW, the chemistry for both waters are very similar. Niether have scaling tendencies for calcite and barite within the temperature range of discussion. When mixed, the scaling tendencies remain zero. I would expect no scale precitpitation/deposition related to mixing the two waters. Dolly Varden Scale Data.pdf Steelhead Platform Water Analyses & Mixing Data The sanitary fluids on the Steelhead Platform are mixed with filtered seawater for processing. The amount of daily sanitary fluid treated is estimated at 379 bbls. When injected for FOR it would be mixed with 16,000 bbis FIW. Parameters for calculating scaling indices are Ttopside= 800F, Ptopside=3200 psi, BHT=1600F, and awater mix of 16,000.379. The water analyses and scaling tendencies for both waters and the mixed brine are attached. Because the makeup water for the sanitary system is FIW, the chemistry for both waters are very similar. The Steelhead FIW has a slight scaling tendency for calcite and nothing for barite within the temperature range of discussion. The sanitary water has no scaling tendencies for either scale. When mixed the scaling tendencies drop to zero for all scales. I would expect no scale precitpitation/deposition related to mixing the two waters. Steelhead Scale Data.pdf Disclaimer of Liability Baker Petrolite Corporation and its affiliates (BPC) disclaim all warranties or representations express or implied including any implied warranties of merchantability or fitness for a particular purpose or to the accuracy, correctness or completeness of such information herein or that reliance on such information will accomplish any particular result. All such information is furnished "as is" and by using such information the user is assuming all liabilities for the use or reliance on such information. BPC SHALL NOT BE LIABLE FOR ANY INDIRECT, SPECIAL, PUNITIVE, EXEMPLARY OR CONSEQUENTIAL DAMAGES OR LOSSES FROM ANY CAUSE WHATSOEVER INCLUDING BUT NOT LIMITED TO ITS NEGLIGENCE. • • Water Compatability Studies All Platforms The above waters were mixed, placed in a water bath at 160OF for a period of 24 hours. They were observed for visual signs of precipitation. The rsults are shown in the table. Water Com atibilit Water Mix Observations Anna PW + Sanitary Water No precipitant observed Bruce PW + Sanitary Water No precipitant observed Dolly Varden FIW + Sanitary Water No precipitant observed Steelhead FIW + Sanitary Water No precipitant observed Disclaimer of Liability. Baker Petrolite Corporation and its affiliates (BPC) disclaim all warranties or representations express or implied, including any implied warranties of merchantability or fitness for aparticular purpose or to the accuracy, correctness or completeness of such information herein or that reliance on such information will accomplish any particular result. All such information is famished "as is" and by using such information the user is assuming all liabilities for the use or reliance on such information. BPC SHALL NOT BE LIABLE FOR ANY INDIRECT, SPECIAL, PUNITIVE, EXEMPLARY OR CONSEQUENTIAL DAMAGES OR LOSSES FROM ANY CAUSE WHATSOEVER INCLUDING BUT NOT LIMITED TO ITS NEGLIGENCE. E 0 Water Analysis Report HILCORP ALASKA ANNA PLATFORM TK#7 BAKER MUGUE5 Baker Pctrolilr Account Manager A.WAKEMAN Summary of Entered Data Sample 17405HIL @ 75°F Sampling Date 21 Marl Anions mg_11 meq/1 Cations mg/I __ meg11 Analysis Date 4Apr13 Chloride 5,011 141 Sodium 3,767 164 Analyst IRENE LOPEZ ! JIALOR CHEUNG Bicarbonate 470 7.70 Magnesium 22.8 1.88 Garbonate NIA ";tA Calcium 53.1 2.65 TDS (mgll or g/ma) 9,491 Sulfate 43.1 0.90 Strontium 10.9 0.25 Density (g/cm' or tonnelma) 1.0062 f,I Nr'A Barium 7.93 0.12 Anion/Cation Ratio 0.88 P, Iron 5.66 0.20 Silica 42.4 0.00 Potassium 56.5 1.45 Carbon Dioxide 160 illli; - Hydrogen Sulfide 0.5 Chromium Col)[wr ZINC 0.02 MGIL pH at time of sampling 6.88 1 „.ld P (TOTAL) 2.00 MG/L pH at time of analysis Manganese 0.20 0.01 H used in Calculations 6.88 " , Specific ion interactions calculated for ions in bold faced type. other ions contribute to ionic strength. Conditions Values Calculated at the Given Conditions - Amounts of Scale in Ib/1000bbl Temp. Gauge Calcite Gypsum Anhydrite Celestite Barite Press. CaCO3 CaSO 4.2H 7 O CaSO 4 SrSO 4 BaSO 4 OF psi Index Amount Index Amount Index Amount Index Amount Index Amount 80 0.0 1.32 4.44 100 0.0 1.17 4-33 120 0.0 1.04 4.22 140 0.0 0.94 4.09 160 0.0 0.86 3.97 180 0.0 0.08 3.8 0.80 3.86 200 0.0 0.24 10.8 1 0.75 3.77 220 2.5 0.40 17.5 0.72 3.71 240 10.3 0.55 23.6 0.71 3.67 260 20.8 0.71 28.9 0.70 3.66 280 34.5 0.87 33.4 0.71 3.68 300 52.3 1.03 37.0 0.73 3.72 Precipitation of each scale is considered separately: total scale will be less than the sum of the amounts of the five scales The amount of scale indicates the severity of the problem: the index (equivalent to Stiff Davis SI) indicates how difficult it is to control the problem Disclaimer of Lfabflfty: Baker Petrolite Corporation an<I its affiliates (BPt') disclaim all warranties or reprcxnlations express or implied, including any implied wananlics of merchantability or fitness for it particular purpose or to the accuracy, cotrcomess or completeness of such information herein or that reliance on such information will accomplish any panicular result. All such inthmmation is lim ushcd "as is" and by using such information the user is assuming all liabilities for the use or reliance on such information. BPC SHALI. No BE LIABLE FOR ANY INDIRECT, SPECIAI_ Pt1NfrIVE, EXEMPLARY OR CONSEQUF.N'FIAL DAMAGES OR LOSSES FROM ANY CAUSE WHA"rSOF.VF:R INCLUDING BU'r NOT LIMITUD'TO ITS NEGLIGF:NCP.. Scale Calculations from Baker Petrolite using Program WASEQ Page 1 0 • Water Analysis Report HILCORP ALASKA ANNA PLATFORM SAWWASTE PUMP DISCH 110111 Imm Baker Petrolite Account Manager A.WAKEMAN Summary of Entered Data Sample 17404HIL @ 75'F Sampling Date 21Mar13 Anions mg/1 meq/I Cations -mg/1 meg11 Analysis Date 4Apr13 _ Chloride 15,908 449 Sodium 7,338 319 Analyst IRENE LOPEZ / JIALOR CHEUNG (Bicarbonate 126 2.07 Magnesium 831 68.4 N/A Calcium 296 14.8 TDS (mg/I or glma) 27,186 Sulfate 2,322 48.4 Strontium 4.92 0.11 Density (glcm' or tonnelma) 1.0177 ' f : Barium 0.02 0.00 Anion/Cation Ratio 1.21 Iron 0.66 0.02 Silica 7.47 0.00 Potassium 351 8.97 `h11711l1i1:1I . ;hromium :.opphr i ZINC 0.80 MG/L 1aH at time of sampling 6.43 Lead 0.01 0.00 P (TOTAL) 3.40 MG/L IDH at time of analysis Manganese 0.02 0.00 H used in Calculations 6.43 1 !, . Specific ion interactions calculated for ions in bold faced type: other ions contribute to ionic strength Conditions Values Calculated at the Given Conditions - Amounts of Scale in Ib11000bb1 Temp. Gauge Calcite Gypsum Anhydrite Celestite Barite Press. CaCO J CaSO 4 -2H z 0 CaSO 4 SrSO 4 BaSO 4 'F psi Index Amount Index Amount Index Amount Index Amount Index Amount 80 0.0 -(;.7:> 0.03 0.00 100 0.0 -1).10 r, 1, 120 0.0 0.63 140 0.0 it bd 160 0.0 180 0.0 200 0.0 220 2.5 240 10.3 0.02 0.7 0.14 81 260 20.8 0.19 5.5 0.30 153 280 34.5 0.36 10.1 0.47 209 300 52.3 0.53 14.3 0.64 250 Precipitation of each scale is considered separately; total scale will be less than the sum of the amounts of the five scales. The amount of scale indicates the severity of the problem; the index (equivalent to Stiff Davis SI) indicates how difficult it is to control the proolem. Disclaimer of Hability: Raker Petrolite Corporation and its affiliates, t Bl'C) disclaim all warranties Or representations express or implied, including any implied warranties of merchantability or fitness for a particular purpose or to the accuracy, correctness or completeness of such inibrmmion herein or that reliance on such intormation will accomplish any particular result. All such information is furnished "as is" and by using :uch mfimnation the user is assuming all liabilities for the use or reliance on such information. BM' SI IALI. NOT BE LIABLE. FOR ANY INDIRECT. SPECIAL., PUNrrlvii. EXEMPI ARY OR CONSFI i IFN IIAI. DAMAGES OR LOSSFS FROM ANY CAIISF WIIA fSOFVER INCLUDING RI IT NOT LIMITED TO ITS NP.GLI iENCE. Scale Calculations from Baker Petrolite using Program WASEQ Page 1 • • Rice Anna Input 081813.xls BCC 3rin M _ _..-._.-. _ Parameters - Units I --1 Input 2 Input 3 Input 4 Input 5 Input Mixed brine: Click here to 1. Adjust the value of a parameter; to 2. A specific value by 3. Adjusting some well parameter. For example: Vary SH SI to 0.00 by adjusting P-CO . Click here to run SSP 6.0 the same as is done on the Run sheet. +e ect t e r nes Sample ID )ate - .___. )�erator Well Name _ __- Location --- Field - Select Well by checking the boxes on Row 3. Select'r, P the button n Row 34. ' ' Li Li Cell H28 is STP talc. PH 17405111L /21/2013 174041111. 3/2U2013 - --- - -- _ - - Cell H28 Is talc. BH T. -- Hilcorp PW _ Anna - --- Hiicorp Sanitary Aorta Cells H3638 are used in calculations. - - - - Va K'(if not known =0) - - lfgt' - - Carl Fee. --- zn= CI _ Total Alkalituty _.- Carhoxvlic acids - -- TUS (Measured) Catc Density(STPI - - CO, Gas (STP) H=S Gas (STP) Total H2Saq (STP) memured(STP) pH measured at STP to calculate S17 (mg/1)' 3,767 56.50 7,38E 351.00 831.00 296.00 4.92 0.02 - 0." 0.80 5,878 223.19 493.97 I93.5 _-, 7A1 332 2.75 0.47 BHT & P JWHT&P Saturation Index values (mg/1) - (mgll) (nii (mgA) (mgjl) - (mg/1) (mg/1) pngll) (ing/1) ("'PI "UO3) 0! HAc ) 2280 53.10 10.90 7.93 5.66 - - 0.02 5,011 43.10 -470:00 _ _ Calcite -0.64 -0.16 Barite 1.19 1 1.51 Halite -3.11 -3.03 15,90E 2.322.00 -- -- _---_ 11.364 G um 1,371.66 -1.15 -0.92 _ -- - - - Ydrate HAsh 126.00 _ .. _ 27,1 1.017 2S __- _ -- - - - 269 -1.70 1.45 - - - _- 0-� 19,813 drlte (mgA) ( mI !n_ _ I%) (%) (mgH2S/l) pH 1-Yes.0-No - - -- - 9,491 1.006 - - 4.2E 0.00 0.110 6.8E t'`ray6�dt:`� I -1.11 .0.55 - ---- 1.013 - 3.2- 0. Celestite --- 0.93 0.64 Iron Sulfide +6.43 f3 i r - - - :'`..,. 3%. -- 0.00pill 668 r ` u"t� 0 -5.32 -5.13 : %'ss>,•>;.:`�%r�; Sul zinc tideUse 1.24 1.53 CalciumflaorldeC:as/Day ,.NVater/Day (103SC'n U(1iI/Dev0 IRO 0 430 Iron Carbonate 0.59 •0.13 _0.(STB) For mixed brines the B-H Temp in H34 is calculated from the C 's & Temps for individual wells. Other T&P's must be entered Inhibitor needed (m L) B-H Temp_ W-H Temp 13-H Pres (°F) - 1°i) (pia) (psi") 160 - 100 100 -100 160 _ --8 100 _ 100 160 150 7. Calcite DTPMP 0.00^ 0.00 Barite DTPMP 0. ' 0.00 &52 6.61 Use 30011 & 0.6gas- (o colic. P It If No, then Oil gray. _ ,and Gas Sp Crav: McOH/Day - 1-Yes.0-No API r�ay. I 0.(NI ti.f10 - 0 1 0.00 0.00 -- 1 -30.00 0• Sp Gray. -STB Well Depth _ _... . _ _ Perforation formation Rock Type -- Porosity_ _ Permesbllitr alcite_ _.. clays (11) - - - -- -- __.0.) I%) - --- -- QC Checks ECations= EAnions uivAiter-0.15 equivJlitcrF9.448.01 0.17 0.41 1.23 -1.22 1.07 -1.07 0.01 -0.011, -0.50 Differ - mg�litcr 6.38 -9.37 27,228.40 0.43 0.02 62,776.30 0.33aIcTDS 451.15 71,639.32 love ScaleSo tritzer sick inhtbkor for you? If No. inhibitor N b: If you select Mixed, I" inhibitor 0Is: _..._ ---- %of 1` inhibitor is.• 2""inhibitor Xis: _ 0 4 i - -- 2 1-Yes;0-No q -- - -- ---- # % 0 2 3 BHPMP PAA -C m m' MPS 200 100 1110 "t fe STB J" _629 _ 4 DTPMP 5 PPCA 10 _ t00 10,000 W. 1,600 - psis du - STB _ STB 1,131 1�1 i6 v - .. 12 i _- 6 ---- 7 _ 8 9 SPA -- -- ... HEDP Bar - --... Torr Gal 1 HDTMP Averaagc Nsplay act. cods. 0 1-Yes 0 No 10 Mixed _- 'Concentrations are in mg/l. ofbrine (except methanol. which is in uni is of barrels per day, the same as the water and oil). input 11 • Water Analysis Report HILCORP ALASKA BRUCE TK#7 DISCHARGF g��Rd it 1N16HES Raker Petrolite Account Manager A.WAKEMAN Summary of Entered Data Sample 17406HIL @ 750F Sampling Date 21 Marl Anions mg/I me_gli Cations mg1I meg1I Analysis Date 4Aprl3 _ hl Coride 8,125 229 Sodium 4,642 202 Analyst IRENE LOPEZ / JIALOR CHEUNG Bicarbonate 1,074 17.6 Magnesium 114 9.37 hate NIA Calcium 350 17.5 TDS (mg/I or g/m') 14,840 Sulfate 72.6 1.51 Strontium 20.3 0.46 Density (glcm' or tonnelm') 1.0097 ^ Barium 17.3 0.25 Anion/Cation Ratio 1.03 A Iron 214 7.66 Silica 44.9 0.00 Potassium 160 4.08 Carbon Dioxide 400 limill Hydrogen Sulfide 2 hrornium ., tpper ZINC 0.49 MG/ L pH at time of sampling 6.30 i r! P (TOTAL) 1.43 MGIL pH at time of analysis Manganese 5.89 0.21 )H used in Calculations 6.30 Specific ion interactions calculated for ions in bold faced type, other ions contribute to ionic strength. Conditions Values Calculated at the Given Conditions - Amounts of Scale in W1000bbl Temp. Gauge Calcite Gypsum Anhydrite Celestite Barite Press. CaCO 3 CaSO , -,2H 1 O CaSO 4 SrSO 4 BaSO 4 °F psi Index Amount Index Amount Index Amount Index Amount Index Amount 80 0.0 1.70 9.95 100 0.0 1.54 9.85 120 0.0 0.11 2.1 1.41 9.73 140 0.0 0.25 47 1.31 9.60 160 0.0 0.39 72 1.22 9.47 180 0.0 0.55 97 1.15 9.35 200 0.0 0.71 121 t . S 1.10 9.25 220 2.5 0.87 143 ..112 1.07 9.17 240 10.3 1.04 164 ..f a 1.05 9.13 260 20.8 1.21 183 1.04 9.11 280 34.5 1.38 200 1.04 9.12 300 52.3 1.56 215 1.06 9.15 Precipitation of each scale is considered separately, total scale will be less than the sum of the amounts o the five scales. The amount of scale indicates the severity of the problem; the index (equivalent to Stiff Davis SI) indicates how difficult it is to control the problem. Disclaimer of Liability: Baker Petrolite Corporation and its affiliates flit"C) disclaim all warranties or representations express or implied, including any implied warranties of merchantability or fitness for a particular purpose or to the accuracy, con-Loness or completeness of such information herein or that reliance on such inlixmation will accomplish am particular result. All such information is lumished "as is" and by using such information the user is assuming all liabilities fix the use or reliance on such inlixmation. BK' SHAI.I . NOT 13E LIABLE FOR ANY INDIRECT. SPECIAL PUNITIVE, EXEMPIARY OR CONSEQUENTIAL DAMAGES OR LOSSES FROM ANY CAUSE WHATSOEVER INCLUDING BUT NOT HMI TED"101'IS NEGLIGENCE. Scale Calculations from Baker Petrolite using Program WASEQ Page 1 Water Analysis Report HILCORP ALASKA BRUCE SEWAGE EFFLUENT /C Ill, r �s Baker Petrolite Account Manager A.WAKEMAN Summary of Entered Data Sample 17407HIL 75°F Sampling Date 21 Marl Anions mg1i Cations mg/1 meq/1 Analysis Date 4Aprl3 Chloride 137 _meq/1 3.87 Sodium 26.4 1.15 Analyst IRENE LOPEZ / JIALOR CHEUNG Bicarbonate 92.0 1.51 Magnesium 9.33 0.77 NIA N/A Calcium 41.9 2. 99 TDS (mg/I or glma) 382 Sulfate 21.3 0." Strontium 0.15 0.00 Density (g/cma or tonne/m3) 1.0003 Barium 0.04 0.00 Anion/Cation Ratio 1.31 Iron 0.96 0.03 Silica 36 G 0.00 Potassium 15.8 0.40 ZINC 0.14 MG/L pH at time of sampling Lead 0.03 0.00 P (TOTAL) 3.55 MG/L pH at time of analysis 6.18 Manganese 0.09 0.00 H used in Calculations 6.18 Specific ion interactions calculated for ions in bold faced type: other ions contribute to ionic strength. Conditions Values Calculatedat the Given Conditions - Amounts of Scale in W1000bbl Temp. Gauge Calcite Gypsum Anhydrite Celestite Barite Press. CaCO J CaSO, •2H 1 O CaSO 4 SrSO 4 BaSO 4 °F psi Index Amount Index Amount Index Amount index Amount Index Amount 80 0.0 100 0.0 120 0.0 140 0.0 160 0.0 180 0.0 200 0.0 220 2.5 240 10.3 260 20.8 280 34.5 0.19 3.81 300 52.3 0.40 7.62 Precipitation of each scale is considered separately; total scale Grill be less than the sumo the amounts of the five scales The amount of scale indicates the severity of the problem; the index (equivalent to Stiff Davis Sly indicates how difficult it s to control the problem. Disclaimer of Liability: Baker I'drohic Corporation and its alliliatcs (BP0 disclaim all warn, rides or representations express or implied, including any implied warranties of merchantability or Illness for it particular purpose or to the accuracy, correctness or completeness ol'such inlormalion herein or that reliance on such information Hill accomplish any particular result. All such information is furnished "as is" and by using such information the user is assuming all liabilities for the use or reliance on such information. BPC SHALL NOTBE LIABLE FOR ANY INDIRECT. SPECIAL.. 1'UNI FIVE, EXEMPLARY OR CONSEC)tIENTTAL DAMAGES OR I OSSES FROM ANY CAUSE WIIA'ISOI?VER INCLUDING BUT NOT LIMITED TO ITS NEGLIGENCE Scale Calculations from Baker Petrolite using Program WASEQ Page 1 Rice Bruce Input 081813.xls Brine N 1_ In t 2 In nt 3 In ut 4 5 In ut Mixed brine: Click here to 1, Adjust the value of a parameter; to 2. A specific value by 3. Adjusting some well parameter. For example: Vary BH SI to 0.00 by adjusting P-0O2. Parameters Units In t ect t e brines Select Well bycheck ine the boxes on Row 3. Select T, P the button on Row 34.t ° ' Cell 1128 is STP talc. pH Sample ID ---------- - Date Aerator _ _ _ _ Well Nome 174061111. /21/2013 1Iilcorp PW Bruce 17407111L 3/2112013 Hikor p Cell H28 Is ealc. BH T. Sanitary Bruce Cells H36-38 are used in lculations. Location - Field No* k' pf not known =0) (mgp)• (mg/1) 4,642 160.00 114.00 350.00 26 - 2,34o 99.09 61.80 192.35 10.25 BH T & P WH T & P 15.80 9.33 41.90 -- 0.15 0.04 0.% 0.14 137 21.30 _ 92.00 -- - - 392 - Saturation Index values (to •) (ml;A) (mgFl) (mSA) (_mglll fl) (mg lq Calcite - Bat' Fe".___. 7n t' - -- Cl' SO,` -0 50 -0.02 Bar ke - 20.30 17.30 _ 214.00 AA9 -- - 8.69 ---- -- 0.54 0.88 107.7 _ 0.32 Halke _ _--- -3.87 3.79 (mg/1) (m1'n) (rnii tma9HCO3) (m 10 HAc) 8,125 72.60 4,142 47.02 0.00 Gypsum -2.25 -2.01 F TotalAlkallaity 1,074.00 Herat h #rate - - - - - - - - -- -- -" 584 -2.81 -2.54 Carbox He acids 1•DS (Measured) - . 0 7,582 _1.00 Anhydrite -2.21 -1.95 (mgJp 14,940 1.009 - 36.81 0.00 ak Density(S•TP) - Ot Gan (STP) 112S_Gas (SCP) Tohtl H2Saq (STP) - pill, measured S'r - t%) (.o) (mg}i,SII) 11 1-Ymi(I-No 1.000 -- 5.94 - Celestite -1.88 -1.58 21.07 11.00 11.011 - 6.18 t' f - -- _ nr .J ^• - --- - 0.00 0. 6.32 ?' 0 IronSulfide .4.35 -4.16 - __0.66 - --6.30 ?' 1 ---- " �" Zinc Sulfide 0.46 0.78 Use pH measured of STP to calculate SI? Calcium Buorkle _..---_-_-- Gas/Day OiUDay -- - Water/Da__ (103SCF) VS"fB) - iST13) 0 -- 100 0 ---too 0 - 0 2 Iron Carbonate 1.24 1.71 For mixed brines the B-H Temp in H34 is calculated from the C 's & Temps for individual wells. Other T&P's must be entered inhibitor needed It- I Temp ---- - _ _-- _ W-H Temp Il-H Pres _ W-H Pres (dH ._ _ (°F] - 160 70 3 200 - 3,200 160 70 3 200 3.200 - 160 IS 7,MIII 500 Calcite -_- _ -_ DTPMP 0.00 0.00 (psis) ( in) Barite DTPMP _ 0.0010. Use 3M)II&(.6apH to talc. P It Ok�_.-_ It No,then Oil gray. and Gas Sp Grav McOlf/Dav I -Yes t)-No AP] ray I 0.00 1 0 00 0.00 _... 6 -- -.... -- ---- - -_ I _ 6.60 0 &is 6.25 Sp Cm.._ STB 0.00 _-. _._ U _ . ---- - - Perforation Formation Rock T� cam- - Portuity _ Permeability Calcite Clays ---- _. - ---_ - ._��•1 _ _(mD) {") - 9ej _ - _-- --. QC Checks ECations EAnions __cquivlliter 0.24 0.00 -0.01 ...... 1.23 -1.22 . _. 1.07 -1.07 0.01 -0.01 equivAiter •0.25 b'o IN filer- Laic TDS- _ Ex . IDS• mblliter Moiler -1.44 14.789.69 14.840.00 -13.2 345.02 382,00 0.43 0.02 62,776.30 62776.30 0.33 451.15 465.00 71,639.32 70000.(10 ;o Difli�r 0.17 5.09 1.16 0,00 L51 Inhibitor Selection Input Unit N Inhibitor Unit Converter (From metric to Ent kh) Protection Time aveScaleSortPitw pick Inhibitor for yonM If No, inhibitor Nis: If you select Mixed, 1" Inhibitor N in: - ibitor -.. % of I" inhibitor is: 2'° inhibitor N h: 0 4 - - 1 - - - 2 min _ 1-Yen;O No q t1 - - -. % N I _-__ 2 3 4 - 5 6 . _. - 7 8 Q 10 NTMP From Unit Value To Unit Value BHPMP °C m3 _ _ _ . . m3 - Militia Bar 200 I" ---__ Joe 10 100 -._ - 10,000_A °F _- _- ._ ff' STB Pcla _ pan _yids - 350 3,531 PAA DTPMP PPCA 629 1.451 - SPA 1450 - It" --- HEDP Tarr -- HDTMP T - Average Mixed Cal 500 - 1.000 Fro B STB 12 Display sot_coofs"_ 0 1-)Lc :. No - 1 • Concentrations are in mir/I, of brine (extent methanol- which is in unite of harrek nrr clav- the same as the water and oil). BCC Click here to run SSP 6.0 the same as Is done on the Run sheet. Input 0 Water Analysis Report HILCORP ALASKA DOLLY VARDEN FIW MOM Boom Baker Petrolite Account Manager D.BARKMAN Summary of Entered Data Sample 17403HIL @ 75°F Sampling Date 21 Marl Anions m_ g/I m_ e_q/I Cations mg/1 _ _ meg11 Analysis Date 4Aprl3 Chloride 15,982 451 Sodium 8,076 351 Analyst IRENE LOPEZ / JIALOR CHEUNG Bicarbonate 90.0 1.48 Magnesium 1,025 84.3 arbonate NiA WA Calcium 345 17.2 TDS (mg/1 or gam') 28,370 Sulfate 2,417 50.3 Strontium 6.03 0.14 Density (glcm' or tonne/m') 1.0184 ,, . ;.! ,, ^ Barium 0.01 0.00 Anion/Cation Ratio 1.08 ;.ill J: ^, Iron 0.23 0.01 Silica 2.74 0.00 Potassium 426 10.9 Carbon Dioxide 48.luminu�n Chromium (;upper ZINC 0.03 MG/L pH at time of sampling 7.35 1 • ,.l P (TOTAL) 0.35 MG/L pH at time of analysis Manganese 0.02 0.00 H used in Calculations 7.35' Specific ion interactions calculated for ions in bold faced type, other ions contribute to ionic strength Conditions Values Calculated at the Given Conditions - Amounts of Scale in 1b/1000bb1 Temp. Gauge Calcite Gypsum Anhydrite Celestite Barite Press. CaCO 9 CaSO 4.2H 2 0 CaSO, SrSO 4 BaSO 4 of psi Index Amount Index Amount Index Amount Index Amount Index Amount 80 0.0 100 0.0 120 0.0 140 0.0 160 0.0 180 0.0 0.08 1.1 200 0.0 0.18 2.6 220 2.5 0.28 4.4 0.04 30 240 10.3 0.39 6.5 0.20 126 260 20.8 0.50 8.7 0.36 202 280 34.5 0.61 10.9 0.53 259 300 52.3 0.73 13.1 0.70 302 Precipitation of each scale is considered separately. total scale will be less than the sum of the amounts of the five scales. The amount of scale indicates the severity of the problem; the index (equivalent to Stiff Davis SI) indicates how difficult it is to control the problern Disclaimer of Liability: Raker Petrolite Corporation and its affiliates (I31,C) disclaim all wamntics or representations express or implied. including any implied warranties of merchantability of fitness for a particular purpose or to the accuracy, correctness or completeness ofsueh information herein or that reliance on such information will accomplish any particular rlwult. All such information is fumished "as is" and by using such information the user is assuming all liabilities for the use or reliance on such int'onnation. BPC SHALL NOT 131E LIABLE FOR ANY INDIRECT. SPECIAL. I'IINIIIVL. LXEMPIARY OR CONSLQUFN HAL DAMM&S OR LOSSES MOM ANY CAOSE' WHATSOEVER IN( I UDING Hl I I' NOI' LIMITED TO ITS NEGLIGENCE Scale Calculations from Baker Petrolite using Program WASEQ Page 1 • • Water Analysis Report HILCORP ALASKA DOLLY VARDEN SNITARY WASTE MUG g MES [faker Petrolite Account Manager D.BARKMAN Summary of Entered Data Sample 17401H/L @ 75°F Sampling Date 21 Mar13 Anions mg/l mIl l Cations mg/1 meq/! Analysis Date 4Aprl3 Chloride 10,183 287 Sodium 5,175 225 Analyst IRENE LOPEZ / JIALOR CHEUNG Bicarbonate 152 2.49 Magnesium 656 54.0 G. ;nate NIA N/A Calcium 240 12.0 TDS (mg/I or g/m') 18,276 Sulfate 1,583 33.0 Strontium 3.87 0.09 Density (g/cm' or tonne/m') 1.0119 Barium 0.03 0.00 Anion/Cation Ratio 1.08 : - if : A Iron 1.00 0.04 Silica 14.2 0.00 Potassium 267 6.84 r',!lJfi iiiillll i Chromium ( upper id:l ZINC 0.07 MG/L pH at time of sampling 1, ' P (TOTAL) 1.68 MG/L pH at time of analysis 6.31 Manganese 0.03 0.00 H used in Calculations 6.31 : , Specific ion interactions calculated for ions in bold faced type, other ions contribute to ionic strength Conditions Values Calculated at the Given Conditions - Amounts of Scale in W1000bbl Ternp' Gauge Calcite Gypsum Anhydrite Celestite Barite Press. CaCO s CaSO a •2H 2 O CaSO 4 SrSO 4 BaSO < °F psi Index Amount index Amount Index Amount Index Amount Index Amount 80 0.0 0.15 0.01 100 0.0 J1,,, 120 0.0 140 0.0 160 0.0 180 0.0 - 200 0.0 220 2.5 240 10.3 0.02 0.7 0.04 20 260 20.8 0.20 7.0 0.21 90 280 34.5 0.38 12.8 0.38 144 300 52.31 0.56 18.0 0.55 184 r,eupaauon or each scale is considered separately, total scale will be less than the sum of the amounts of the five scales. The amount of scale indicates the severity of the problem; the index (equivalent to Stiff Davis SI) indicates how difficult it is to control the problem. Disclaimer of Liability: Raker Petrolite C'orpomtion and its affiliates (liPC) disclaim all warranties or representations express or implied, including any implied warranties of merchantability or filness for a particular purpose or to the accuracy, correctness or completeness of such information herein or that reliance on such information will accomplish any particular result, All such infirmtation is famished "as is"and by using such infcmnation the user is assuming all liabilities for the use or reliance on such information. BPC SHALL NOT BE LIABLE I -OR ANY INDIRFCr, SPFC'IAI_ PUNITIVE, [:XFMPI ARY OR CONSEQUFNTIAI. DAMAGES OR I OSSGS FROM ANY CAUSE WIIATSOFVFR INCH (DING BUT NOTI IMITFD TO ITS NEGLIGENCE. Scale Calculations from Baker Petrolite using Program WASEQ Page 1 Rice Dolly Varden Input 081813.xis Brine N Parameters Units I In of 2 In ut 3 4 5 In w Mixed brine: Click here to 1. Adjust the value of a parameter; to 2. A specific value by 3. Adjusting some well parameter. For example: Vary BH SI to 0.00 by adjusting P-0O2. In ut In of ,Sekct the brines S a4PIT Date Aerator Well Name -_ Location Field Select Well by checking the boxes on Row 3. Sdect'f P the button on Row 34. + - -- -- Cell 1128 is STP talc. PH 17403111L /21/2013 Hlkorp - FIW Dolly Varden 174011111, 3121i2013 Hilcorp Sanitary- Cell H28 Is catc. BH T. Cells H36-38 are used in calculations. Dolly Varden Na le (if not known =0-) a Ba Few - - --1 - --- - a F - - Total Alkalinity Carbox)Ikacids DS(Measured) Cak. Density (STP) -- 02 Gas (STP) H2S Gas (STP) otaf HiSatt (STP) - H, measured (STP) ftfl)• (mg/1) (mg/1) (mgA) Img11) � 8,076 5.175 267.00 _ _ 656.00 240.00 _ - - -- _ 8,017 422.75 1,017.4 342.33 BHT & P WH T & P 426.00 1,025.00 345.00 Saturation Index values aktte 4Al 0.06 6.03 0.01 0.23 0.03 15,932 2,417.00 9U.00 3.87 0.03 LOO 0.07 10,183 1,583 5.99 0.01 0.2 _ 0.03 15,83 Barite -1.26 -0.94 (mgA (mg/) Halite -2.85 •2.77 Gypsam -0.82 -0.61 (mgA) (ml;A) Ing/ltICO}) 2,399.95 0.00Hemih 41:27 0.00 28,I6 IAIx 0.3 0. 152.011 I8,Z76 drate --_ ----- - - _ 1.38 •1.13 {mg(II1Ac) (mgfq ml) _ {40) (4,) (mgII2si) 28,370 -- 1.019 - 0.21 0.00 -- 0.011 f yr <fl:Nic1 1 Anhydrite •0.79 -0.54 _ 1.012 - -- 4A4 0.00 - --- 0.00 611 si :; .. �2 ..... ..�+f Celestite - 0.95 0.67 - - , r: f x',::jfi'*'GI/.'F. Iron Sulfide -3.34 -3.14 -- 0. PH7.35 uY :xNx- y,, -.X YF.•rl.�SC .✓..%/.F.:-:�U.:{'Q. r ycc 711 :•r,`•� i ;; :ftx✓nd F Zinc Sulfide_ 3A6 3.36 Use pH measured at STP to calculate Sl? - _ 1-Yes;O-Np 01 Calcium fluoride Gas/Day N ay Water/Day (103SCF) ISTI3) (S173)- 0 0 - 20,000 0 11 419 - 0-� 0 20,41 Iron Carbonate -1.69 -1.23 For mixed brines the B-H Temp in H34 is calculated from the C 's & Temps for individual wells. Other T&P's must be entered Inhibitor needed B H Temp -H Tcmp H Pres -41 Pres (^E) {eta (Asia) (SIR) 160 80 3A-" 3,4% 160 8U 3,450 3,450 - I611 Calcite DTPMP - -150 0.00' 0.00 7,000 500 Barite . DTPMP 0.0 0. Use 300i1 & bgas to ealc. P b !t No, then Oil gran. - _ aad Cas Sp.Gray.: McOH/Da -- I-Yes;O-No API 6 av_ Sp.Gray. -STB I 000 0.011 U u dr):::•s:: d: :;„,;:.y 1 0.00 0.00 - 0 . _--_----:.__ _ Y: ,�•.w, I 30.00 -- 0.60 0 7.04 7.14 _ _. - - - - - ell Depth -- Perforation -.._____ _._.__. Formation Rock Typ Porosity. Permeability -- -- la alcitcQC (It) - _._ (R) -_-_--- -- --- -- - - _-- -(mD) Checks 2 Cations -- - -- 'Anions euivAiter - uivAiter .. �� - ... 0.46 -0.50 ,;.. ..LSc'"n2> :�� -- 0.30 -0.32 :y. - - 1.23 -1.22 yr. • a g . 1.07 - - - .1.07 :: ;r.<>;3;- .. 0.01 - -0.01 vi: .,... o Differ alc TDS tia TDS= mg/ lita m iter -4.01 28,367.30 28 370.00 -198 18.260 97 0.43 71,639.32 0.02 62,776.30 62 776.30 0.33 451.15 465.00 18 276.00 70 000.00 n Differ= 0.00 0.04 1.1 0.110 1.51 Inhibitor Selection Input Unit N lobibitor Unit Converter (From metric to Ent lish) Protection Time iiiave ScaleSaftPiker pkk lah "cT for you. If No, Inhibitor N is: f you select Mixed, 1" inhibitor N is: _. Ne of 1" inhibtor is: 2ie Inhibitor p is: 0 4 I 2 min 1-Yes;U•No N # __-_----_ % N I 2 3 4 NTMP BIIPMP From Unit Value To Unit Value eC ata _ of, 200 100 100 10 °F ft' STB psia 3 i1 629 PAA DTPMP PPCA 5 1 I 6 __ J_ -8 9 ---g_ 10 SPA ---HE-DP HEDP NDTM P Avcm e . Mixed -Mrs Bar ---- TtMr___ 100 -- . _ _ .. 0,000 Asia l a 113 Cal t __ STB 12 may u. t wets? 0 1-Y 0.No L:."9 STB 6 -_- • Concentrations are in mc/I, ofbrine (extent methanol. which is in units of baffels per day. the same as the water and oil). BCC Click here to run SSP 6.0 the same as is done on the Run sheet. Input Water Analysis Report HILCORP ALASKA STEELHEAD FIW MAIN BAKER HUGMES Baker Petrolite Account Manager D.BARKMAN SumT.ga of Entered Data Sample 17412HIL @ 75°F Sampling Date 21 Marl 3 Anions mg11 Mai Cations mg/l meg// Analysis Date 4Aprl3 Chloride 15,675 442 _ Sodium 7,859 342 Analyst IRENE LOPEZ / JIALOR CHEUNG Bicarbonate 100 1.64 Magnesium 989 81.4 Carbonate Calcium 343 17.1 TDS (mg/I or g/m') 27,878 Sulfate 2,483 51.7 Strontium 5.85 0.13 Density (g/cm' or tonne/m') 1.0181 i ' 1--;)hnrut,:. Barium 0.02 0.00 Anion/Cation Ratio 1.10 - Iron 0.14 0.01 Silica 2.34 0.00 Potassium 422 10.8 Carbon Dioxide 96 P,iuminunt NiA .hromium P!?A i',opper N-,' ZINC 0.01 MG/L pH at time of sampling 7.80 P (TOTAL) 0.39 MG/L pH at time of analysis Manganese 0.01 0.00 H used in Calculations 7.80 Conditions Temp. Gauge Press. °F__psi 80 0.0 100 0.0 120 0.0 140 0.0 160 0.0 180 0.0 200 0.0 220 2.5 240 10.3 260 20.8 280 34.5 300 52.3 Specific ion interactions calculated for ions in bold faced type: other ions contribute to ionic strength. Values Calculated at the Given Conditions - Amounts of Scale in lb/1000bbl Calcite Gypsum Anhydrite Celestite Barite CaCO J CaSO 4.2H 2 O CaSO 4 SrSO 4 BaSO 4 Index Amount Index Amount Index Amount Index Amount Index Amount 0.09 0.5 0.03 0.00 0.11 0.8 0.14 1.2 0.19 1.8 0.24 2.7 , 0.30 3.9 0.37 5.5 0.45 7.4 0.06 41 0.53 9.5 0.22 135 0.63 11.8 0.38 208 0.73 14.1 0.54 264 0.84 16.3 0.71 305 rrecrpnauon of each scale is considered separately: total scale will be less than the sum of the amounts of the five scales. The amount of scale indicates the severity of the problem; the index (equivalent to Stiff Davis SI) indicates how difficult it is to control the problem. Disclaimer of Liability: Baker Petrolite Corporation and its alliliales (BIV) disclaim all warranties or representations express or implied, including any implied warranties of merchantability or fitness for a particular purpose or to the accuracy, correctness or completeness of such inturrnation herein or that reliance on such information will accomplish any particular result. All such information is fumishcd "as is" and by using such information the user is assuming all liabilities for the use or reliance on such inl'orrnation. BPC SHALT NOT BE L.IABLF. FOR ANY INI)IRE("I'. SPEC'IAl_ PUNITIVE. IiXFMPIARY OR CONSEQUEN'IIAt. DAMAGES Olt LOSSI-S PROM ANY CAtISF WIIA'I:SOT?Vf{R I NCIA I DI N(i Bur NO I LIMITED "1'0 ITS N E(iLIGEN(' I!. Scale Calculations from Baker Petrolite using Program WASEQ Page 1 • • Water Analysis Report HILCORP ALASKA STEELHEAD SANITARY INJECTION FBI A6 mom Baker Petroiite Account Manager D.BARKMAN Summary of Entered Data Sample 17493H1L @ 75°F Sampling Date 21 Marl Anions mg/1 Cations_ mg11 meq/l Analysis Date 4Aprl3 Chloride 16,782 _megll 473 Sodium 8,020 349 Analyst IRENE LOPEZ / JIALOR CHEUNG Bicarbonate 153 2.51 Magnesium 995 81.8 a:arbonate Nlj NIA Calcium 342 17.0 TDS (mg/I or g/m') 29,307 Sulfate 2,580 53.7 Strontium 5.91 0.13 Density (glcm' or tonne/m') 1.0191 N ;^, f l'' Barium 0.01 0.00 Anion/Cation Ratio 1.15 Iron 0.27 0.01 Silica 3.00 0.00 Potassium 426 10.9 2"1(11111t11111) _h nniitn% N A ZINC 0.02 MG/L pH at time of sampling Lead 0.02 0.00 P (TOTAL) 0.48 MGIL pH at time of analysis 6.26 i f H used in Calculations 6.26 Specific ion interactions calculated for ions in bold faced type; other ions contribute to ionic strength Conditions Values Calculated at the Given Conditions - Amounts of Scale in W1000bb1 Temp.Gauge Calcite Gypsum Anhydrite Celestite Barite Press. CaCO, CaSO 4.2H 2 0 CaSO 4 SrSO 4 BaSO 4 °Fpsi Index Amount Index Amount Index Amount Index Amount Index Amount 80 0.0 100 0.0 120 0.0 140 0.0 160 0.0 180 0.0 200 0.0 220 2.5 0.05 38 240 10.3 0.00 0.0 0.21 132 260 20.8 0.18 6.4 0.37 205 280 34.5 0.35 12.3 0.54 261 3001 52.3 0.53 17.61 1 0.71 302 -ec,pitatton or each scale is considered separately, total scale will be less than the sum of the amounts of the five scales. The amount of scale indicates the severity of the problem; the index (equivalent to Stiff Davis SI) indicates how difficult it is to control the probiern. Disclaimer of Liability: Baker Petrolite Corporation and its atlihatts (HPl') disclaim all warranties or representations express or implied, including any implied warranties of merchantability or fitness for a particular purpose or 10 the accuracy, correctness or completeness of such intiumalion herein or that reliance on such information will accomplish any paricular result. All such information is furnished "as is" and by using such Information the user is assuming all liabilities for the use or reliance on such infomralion, UPC SHALL. NOT HE LIABLE FOR ANY INDIRE.(" r, SPEC[AL.. PUN111VL', EXEMPLARY OR CONSEQIIEN HAL DAMA6FS OR LOSSES FROM ANY CAUSF WHATSOIiVE.R INCLUDING H1l'1 NOT I]MI rED 101I'S NEGLIGENCE. Scale Calculations from Baker Petrolite using Program WASEQ Page 1 • Rice Sleelhead Input 081813.xis Brine 11 Parameters Units 1 In uI 2 - In t 3 -- - In t- 4 Input 5 In ut Mixed brine: Click here to 1. Adjust the value of a parameter; to 2. A specific value by 3. Adjusting some well parameter. For example: Vary BH SI to 0.00 by adjusting P-0O2. Sefect the brines Sample ID Date Operator Well Name Location Field ^ Select Well by checking the boxes on Row 3. Select T, P the button on Row 34. Cell 1128 is STP talc. pH 17412HIL 1/2013 Hileorp FiW Steelbead -- 17413111E 3/2V2013 Hlleor _ Sanitary Steelhead -- _ --------- -- _ _ _ Cell H28 Is eale. SH T. Cells H36-38 are used In calculations. Na K' (if not known -0) + SrZ' Ila" I, - - ZA CI' so". (mwl)• (mg/I) 7,959 422.00 989.00 343.00 5.95 0.02 - 0.14 0.01 15,675 2,4E3.00 -- -- .. ._ 100.00 27.87_3 1.018 0.0E 0.00 0.00 8,020 426.00 995.00 342.00 5.91 0.01 0.27 0.02 16,782 7,963 422.09 989.14 342.40 5.85 0.02 0.14 BH T & P I WH T & P Saturation Index values (MO - (mg/1) (m 118) (mg/1) Img/) (mgn) (mg/1) (mg/) - - ---- Calcite - - --- - -- --- --- -0.11 0.36 Barite -0.% -0.64 Haute 0.01 -2.86 -2.78 15,701 C um 2,580.00 - 153.00 ---- 29,307 2,4E5.25 -0A0 -0.152 - --- - 0.00 101.23 0.011 - 27,909 -- 1.018 0.18 Hem_ lib _- - �d_rate 1.36 - 4.11 Total Alkalinity Y-. -- Carbox lie acids TDS (Measured) imb•I ftc0a) (bn- j. m � HAc (rng/1) ml) (°o) (°o) Anhydrite - Y -0.76 -0.52 Cak.Densi STP COr Gas (STP) 11ZS Gas (STP) TotalH2Sa ST q (• P) -------- pH, measured (STP) Use pH measured at STP to calculate SI? 1.019 Celestite -- - - - - -- -0.94 -0.08 - - 4.50 0.00 - 0.00 6.26 a, , a 1 -..... ,; ,>, , ; .w`.4`�.t,�d��i NI. ,1 _ ,y...r; , ..;:. %%b:.a•:• .�'!.•`f':ast'v?c:w: 0.00 0. 7.4 f <nr•>..1,.% r...r�'%�' 0 Iron Sulfide - ._. (a -- S11) -- --- H 1-Yes;O-No .87 -3.06 2E7 7.80 a �;�z..!!!J�•, 1 Zinc Sulfide 3.10` 3.39 Calcium fluoride GWDay Water/Da (t03SCF) (S'f8) 0 0 _.. 0 379 --- - -- -- 0- 16,37 Iron Carbonate _ - -1.63 •1.17 16,000 For mixed brines the B-H Temp in H34 is calculated from the C 's & Temps for individual wells. Other T&P's must be entered Inhibitor needed m L B-H Temp -- W-}I Temp K-H Pecs w-H Pres (°F) (°Fj -_ (psia) a 160 t10 3,200 3,200 160 80 3,200 3,200 - _ - - 161 Calcite DTPMP ---- - --- 0.00'' 0.00 --- ---- 1_ 7,000 -- Barite DTPMP 0.00 0.00 -- - Use 30011 & 0.6gas to talc. P b If No, tben Oilgray. and Gas SpGrav If/Day I-Yes;O-No API hraiay. - Sp.Gray. STB f'; c7'' 1 0.00 0.00 - - - 1 - 0.00 000 -- 0 -- _ - - - SOMM-W_ 1 - 30.00 _0.60 7.30 7.30 Well Depth_ Perforation Formation Rock Type Porosityakite--- Clays --- (tt) _ L - - (ya QC Checks £Cations EAnions=equivAiter ccyuivAiter 0.45 -0.5 0.46 1.23 i.22 1.07 -1.01 0.01 .0.01 -0.53 o Differ - cak TDS - - '- F s . IDS mg6ler iter _ 4.6 27.877.02 -7.16 29 304 21 0.43 -71,639.32 0.02 62.776.30 62.776.30 0.33 451.15 465.00 27.878.00 29 307.00 70 00D. 1. Di ITcr - 0.00 0.00 1,16 0.00 1.51 Inhibitor Selection War! I Unit N Inhibitor Usk Converter From metric to Cal fish) Protection Time - - HaveScale.SoaPitur ek Inhibitor for vou? If No, inhibitor k is: If you select Mixed, 1" inhibitor # is: %01 1; inhibitor is: 2'd inhibitor N is: -- 0 4 min 1-Yes;O-No ft - # % k i 2 3 4 5 6 7 - 8 9 --... 'O-- N fMP BHPMP- PAA DTPMP PPCA SPA _ HEDP HDTMP-L-±-- Average From Unit Value To Unit Valise •C m' ms MPa Bar 200 ISO •F fe STB psla. psla STB STB 3" 3 1 ISO 10 t00 1 810 -� 629 1 2 1451 1,451 I" - - -- 1,000 - _ 12 BPIay act. wets? 0 --- 1-Yes.-0-No - --- 6 �--_. Mixed • Concentrations are in m1dL ofbrine (except methanol• which is in units of barrels Der day, the same as the water and oil}. BCC Click hereto run SSP 6.0 the same as is done on the Run Sheet. Input #28 • • Wallace, Chris D (DOA) From: Reid Edwards [reedwards @hilcorp.com] a S Sent: Monday, January 28, 2013 4:16 PM 3 Z J S To: Wallace, Chris D (DOA) Subject: Response regarding questions on AA for Br- 5RD -86 ,iA You OA 7s0 Chris, Addressed are your questions from the message you left last week. 3 1. Why did we not run MIT- TXIA on Br- 5RD -86? • See email response below from previous conversations 2. Are we going to perform MIT -TXIA on Br -6 -42? • We are not planning on it due to same reasons listed for Br- 5RD -86. We would like to pursue integrity diagnostics using temp surveys 3. Are we planning on using a fail safe system (i.e. pilot valve on IA and / or OA) with limits of 3000 psi for IA and 750 psi for OA • After talking with Larry, he agreed we would need pilot valves on an unmanned platform or an area that wasn't checked daily. But, this is a manned platform and the wells are checked daily for pressure variations we don't feeLt eed to install pressure pilots for the wells. Also in all the time we have been operating without pilots there has been no history of problems. • I would like to propose a do not exceed limit of 4 000 psi for the IA (the burst rating is 7510 psi so we are well below the 70% safety factor). The well currently injects at 2800 -3000 psi to put away the produced water that the platform produces so it would be nice to have some cushion there. Please let me know if you have any more questions or need clarification on anything. Thanks M (c . ce.ra iap Reid Edwards — Reservoir Engineer Hilcorp Alaska LLC " 1Ll tNI Office: 907-777-8421 6�se� Cell: 907-250-5081 ©Q net V.SL. t• e tcA64. r , From: Reid Edwards Sent: Tuesday, September 18, 2012 9:33 AM To: 'Wallace, Chris D (DOA)' Subject: RE: Permission to Inject - Br- 5RD -86 PTD 1790050 Chris, The intent for this well is primarily to dispose of our produced water but is also used for waterflood pressure support. We will be injecting our produced water during the temp survey and for the foreseeable future if the well is approved for continued injection. We have not attempted to obtain a combo MIT as we feel there is high risk involved with this process. As this is a produced water injection well there is tendency for solids to build up on the tubing walls. These solids will tend to "sluff' as work is done on the well either by re -entry or pressure testing. If we are in fact able to set a plug in the well there is a good chance that we will not be able to pull it out after the test. A few weeks ago we tried to enter the well to • get the baseline temp survey and stuck the tools in some sludge. We are planning to clean the well out with coil tubing but am still hesitant on trying to set a plug. We feel that there are a few issues with the CMIT due to the fact that if it fails you cannot determine the exact source of the failure. Several factors could lead to a failed test besides casing (well head packoff leaks, plug not set correctly, packer leak). We would like to prove casing integrity with the temp survey as this will give us proof that the casing above the packer has not been compromised. Please let me know if we need to take any further steps or you need any more information. Thanks Reid Edwards — Reservoir Engineer Hilcorp Alaska LLC Office: 907 - 777 -8421 Cell: 907 - 250 -5081 From: Wallace, Chris D (DOA) [ mailto :chris.wallace(aalaska.gov) Sent: Friday, September 14, 2012 12:25 PM To: Reid Edwards Subject: RE: Permission to Inject - Br- 5RD -86 PTD 1790050 Reid, Thank you for the request. What is the intent for this well? Produced water disposal, EOR, combination? Please detail all fluids planned to be injected with the temperature survey and then for the life of the well going forward. The current AIO 6 is not as specific as our current Area Injection Orders (AIO) and Disposal Injection Orders (D10) and so may need to be updated to allow your planned or future activity. Why was there not an attempt to establish a combination MIT to verify the integrity of the 9 5/8" casing? We need to hear the decision process and reasons that make a temperature survey your decision prior to us authorizing injection into any well that has failed mechanical integrity. As I look through our files for Permit # 1790050 Granite Pt ST 17586 5RD I see: Area Injection Order AIO 006.0 applies (September 1986). 9. To ensure that fluids injected are confined to injection strata, the mechanical integrity of injection wells should be demonstrated periodically and monitored routinely for disclosure of possible abnormalities in operating conditions Rule 1 Authorized Injection Strata for Enhanced Recovery Within the affected area, non - hazardous fluids may be injected for purposes of pressure maintenance and enhanced oil recovery into strata defined as those strata which correlate with the strata found in the Mobil Granite Point well No. 1 between the measured depths of 7,725 feet and 10,800 feet. Rule 2 Authorized Injection Strata for Disposal Within the affected area, non - hazardous oil field fluids may be injected for the purpose of fluid disposal into strata defined as those strata which correlate with the strata found in the Mobil Granite Point well No. 1 between the measured depths of 5941 feet and 6220 feet. Rule 7 Well Integrity Failure 2 Whenever operating pressure observations or pressure tests indicate pressure comm unication or leakage of any casing, tubing or packer, the operator must immediately cease injection, notify the Commission, and obtain approval for corrective action. Well was advised as shut in May 1 2012 due to tubing x IA communication. Last injection was month of November 2011. Failed internal MITIA 6- May -2012. Pass AOGCC witnessed MITIA to 1950 psi 5- Aug -2010, 4 yr cycle Well is identified as 1WINJ which as an FOR Class II, not identified as a disposal well as such. Well Br 3 -87 (PTD 1660520) is classified as a WDSP2 waste disposal Class II. Conservation order 351a applies to this well and exempts the well from sundry request approval for some identified well operations. Perforations are detailed as 8530 to 9446 ft MD (18- March -1979) and confirmed with Sundry report November 6, 2006 with an injectivity test with intent to designate as produced water injector for waterfiood operations along with Br 6 -42 (Letter November 3, 2006 Ted Kramer, Chevron). Graph indicates water injection to perforations from 8750 to 8850 ft MD. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, AK 99501 (907) 793 -1250 (phone) (907) 276 -7542 (fax) chris.wallace(aalaska.gov From: Reid Edwards jmailto:reedwards(ahilcoro.coml Sent: Friday, September 14, 2012 8 :26 AM To: Wallace, Chris D (DOA) Subject: Permission to Inject - Br- 5RD -86 Chris, Attached is a request to obtain permission to temporarily inject into well Br- 5RD -86 to establish a thermal profile. This test will be used to prove / disprove casing integrity above the packer. If the test proves we have integrity we will then apply for an Administrative Approval to continue injection. Please let me know if you have any questions. Thanks Reid Edwards — Reservoir Engineer Hilcorp Alaska LLC Office: 907 - 777 -8421 Cell: 907 - 250 -5081 3 • 1 Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Wednesday, November 14, 2012 2:52 PM To: 'Reid Edwards' Cc: Larry Greenstein; Regg, James B (DOA) Subject: RE: Permission to Inject - Br- 5RD-86 PTD 1790050 Reid, As per your proposed procedure for bringing Br- 5RD -86 back on injection detailed in the letter dated September 13, 2012, you have approval to inject for up to 30 days to establish the thermal profile prior to completing a post injection temperature survey. Let us know the results as soon as they are available, and we can discuss appropriate steps at that time. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 (907) 793-1250 (phone) (907) 276 -7542 (fax) chris.wallace @alaska.gov From: Reid Edwards [mailto:reedwards @hilcorp.com] Sent: Tuesday, November 13, 2012 2:51 PM To: Wallace, Chris D (DOA) Cc: Larry Greenstein; Regg, James B (DOA) Subject: RE: Permission to Inject - Br- 5RD -86 PTD 1790050 Chris, We have successfully fished out the stuck tools in this well and have run a base line temperature survey. We would like to obtain permission for a 30 day injection test in order to establish a thermal profile. A temperature survey will then be run after the injection test to analyze fluid entry which will help prove up casing integrity. Please call if you have any questions / concerns. Thanks Reid Edwards — Reservoir Engineer Hilcorp Alaska LLC Office: 907 - 777 -8421 Cell: 907 - 250 -5081 From: Reid Edwards Sent: Tuesday, September 18, 2012 9:33 AM To: 'Wallace, Chris D (DOA)' Subject: RE: Permission to Inject - Br- 5RD -86 PTD 1790050 Chris, The intent for this well is primarily to dispose of our produced water but is also used for waterflood pressure support. We will be injecting our produced water during the temp survey and for the foreseeable future if the well is approved for continued injection. 1 • • We have not attempted to obtain a combo MIT as we feel there is high risk involved with this process. As this is a produced water injection well there is tendency for solids to build up on the tubing walls. These solids will tend to "sluff" as work is done on the well either by re -entry or pressure testing. If we are in fact able to set a plug in the well there is a good chance that we will not be able to pull it out after the test. A few weeks ago we tried to enter the well to get the baseline temp survey and stuck the tools in some sludge. We are planning to clean the well out with coil tubing but am still hesitant on trying to set a plug. We feel that there are a few issues with the CMIT due to the fact that if it fails you cannot determine the exact source of the failure. Several factors could lead to a failed test besides casing (well head packoff leaks, plug not set correctly, packer leak). We would like to prove casing integrity with the temp survey as this will give us proof that the casing above the packer has not been compromised. Please let me know if we need to take any further steps or you need any more information. Thanks Reid Edwards — Reservoir Engineer Hilcorp Alaska LLC Office: 907 - 777 -8421 Cell: 907- 250 -5081 From: Wallace, Chris D (DOA) f mailto:chris.wallace@ alaska.gov] Sent: Friday, September 14, 2012 12 :25 PM To: Reid Edwards Subject: RE: Permission to Inject - Br- 5RD -86 PTD 1790050 Reid, Thank you for the request. What is the intent for this well? Produced water disposal, EOR, combination? Please detail all fluids planned to be injected with the temperature survey and then for the life of the well going forward. The current AI0 6 is not as specific as our current Area Injection Orders (AIO) and Disposal Injection Orders (D10) and so may need to be updated to allow your planned or future activity. Why was there not an attempt to establish a combination MIT to verify the integrity of the 9 5/8" casing? We need to hear the decision process and reasons that make a temperature survey your decision prior to us authorizing injection into any well that has failed mechanical integrity. As I look through our files for Permit # 1790050 Granite Pt ST 17586 5RD I see: Area Injection Order AI0 006.0 applies (September 1986). 9. To ensure that fluids injected are confined to injection strata, the mechanical integrity of injection wells should be demonstrated periodically and monitored routinely for disclosure of possible abnormalities in operating conditions Rule 1 Authorized Injection Strata for Enhanced Recovery Within the affected area, non - hazardous fluids may be injected for purposes of pressure maintenance and enhanced oil recovery into strata defined as those strata which correlate with the strata found in the Mobil Granite Point well No. 1 between the measured depths of 7,725 feet and 10,800 feet. Rule 2 Authorized Injection Strata for Disposal Within the affected area, non - hazardous oil field fluids may be injected for the purpose of fluid disposal into strata defined as those strata which correlate with the strata found in the Mobil Granite Point well No. 1 between the measured depths of 5941 feet and 6220 feet. 2 Rule 7 Well Integrity Failure Whenever operating pressure observations or pressure tests indicate pressure communication or leakage of any casing, tubing or packer, the operator must immediately cease injection, notify the Commission, and obtain approval for corrective action. Well was advised as shut in May 1 2012 due to tubing x IA communication. Last injection was month of November 2011. Failed internal MITIA 6- May -2012. Pass AOGCC witnessed MITIA to 1950 psi 5- Aug -2010, 4 yr cycle Well is identified as 1WINJ which as an FOR Class II, not identified as a disposal well as such. Well Br 3 -87 (PTD 1660520) is classified as a WDSP2 waste disposal Class II. Conservation order 351a applies to this well and exempts the well from sundry request approval for some identified well operations. Perforations are detailed as 8530 to 9446 ft MD (18- March -1979) and confirmed with Sundry report November 6, 2006 with an injectivity test with intent to designate as produced water injector for waterflood operations along with Br 6 -42 (Letter November 3, 2006 Ted Kramer, Chevron). Graph indicates water injection to perforations from 8750 to 8850 ft MD. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, AK 99501 (907) 793-1250 (phone) (907) 276 -7542 (fax) chris.wallace @alaska.gov From: Reid Edwards fmailto:reedwardsOhilcorp.coml Sent: Friday, September 14, 2012 8:26 AM To: Wallace, Chris D (DOA) Subject: Permission to Inject - Br- 5RD -86 Chris, Attached is a request to obtain permission to temporarily inject into well Br- 5RD -86 to establish a thermal profile. This test will be used to prove / disprove casing integrity above the packer. If the test proves we have integrity we will then apply for an Administrative Approval to continue injection. Please let me know if you have any questions. Thanks Reid Edwards — Reservoir Engineer Hilcorp Alaska LLC Office: 907 - 777 -8421 Cell: 907 -250 -5081 3 • • Reid Edwards Reservoir Engineer — Kenai Asset Hilcorp Alaska, LLC 3800 Centerpoint Drive - Suite 100 Anchorage, AK 99503 Tb 1 00 ,50 September 13, 2012 Chris Wallace Alaska Oil and Gas Conservation Commission 333 W 7 Ave #100 Anchorage, AK 99501 Dear Chris: Hilcorp requests approval to perform a 30 day injection test on well Br- 5RD -86. This test is proposed as the first step to return this well to long term produced water disposal service. This well is suspected to have tubing by casing communication. Well Br- 5RD -86 is a produced water disposal well which was SI 5/01/2012 due to suspected tubing by casing communication. The last measured rate was 109 bwpd with 1940 psi tubing pressure and 300 psi casing pressure measured on 5/01/2012. The well has been continually monitored since that time and is reported on the monthly Waivered Injection Well Report Following is the proposed procedure for bringing this well back on injection. 1. Run a baseline temperature survey 2. Obtain permission to inject 3. Inject into the well until downhole thermal profile is established (Limit the length of the test to 30 days) 4. Run follow -up temperature survey and analyze fluid entry. 5. Request an Administrative Approval to continue injection depending on results of the survey • i [Recipient Name] September 14, 2012 Page 2 If the well is returned to long term injection it will be monitored daily with temperature surveys run every two years. Sincerely, Reid Edwards 427 • • Reid Edwards Reservoir Engineer — Cook Inlet Offshore Asset Hilcorp Alaska, LLC 3800 Centerpoint Drive - Suite 100 Anchorage, AK 99503 January 18, 2013 Chris Wallace Alaska Oil and Gas Conservation Commission 333 W 7 Ave #100 Anchorage, AK 99501 Dear Chris: Hilcorp requests an Administrative Approval to allow produced water injection into well Br- 5RD -86 (API# 50- 733 -2011 -801, PTD #1790050). A follow up temperature survey was run on December 31, 2012 after the approved 30 day injection test period was finished. An overlay of the pre and post injection test temperature surveys indicates that there is no injection occurring above the packer and all fluid is entering the existing perforations. Well Br- 5RD -86 is a produced water disposal well which was SI 5/01/2012 due to suspected tubing by casing communication. The last measured rate before SI was 109 bwpd with 1940 psi tubing pressure and 300 psi casing pressure measured on 5/01/2012. The well had been continually monitored since that time and is reported on the monthly Waivered Injection Well Report. A request was made September 13, 2012 to the state to perform an injection test in order to establish a thermal profile from which the location of fluid exit could be determined. Approval was given November 14, 2012 and the 30 day injection test commenced December 1, 2012 with a follow up temperature survey on December 31, 2012. There are currently plans to work the well over in Q3 of 2013 in order to repair the tubing by annulus communication by installing a new completion. Until that time the well pressures and rates will be monitored and recorded daily. Operating pressures are estimated to be between 2500 and 3500 psi, which is below the 70% yield pressure of the 9 5/8" casing at 5257 psi. If our current plan changes and the well is not repaired with a work over then a temperature survey will be run every two years to confirm casing integrity. IOW • • [Recipient Name] January 16, 20133 Page 2 As of 1/16/2013, well Br -6 -42 (API# 50- 733 - 2001 -500, PTD # 1670190) is SI due to apparent tubing by casing pressure communication. Br -6 -42 and Br- 5RD -86 are the only produced water disposal wells on the Bruce platform. Production is still currently online as wet oil can be sent to the Granite Point production facility and disposed through the outfall line. It is possible, and is usually the case during the winter months, that the out fall line will freeze and water must be disposed of on platform. It is requested that this approval be handled in a time conscious manner to avoid possible SI of production. Attached are the following • Wellbore schematic • Temperature survey overlay of pre and post injection • Rate and TIO pressure plot The well Sincerely, Reid Edwards J Granite Point X7586 Well Ao. 5RD Wellbore Diagram (as run 3- 18 -79) Casing Record Depth 13 -3/8" 54.57 (12.615 ID) 1590' - �'i® 9 -5/8" . 43.5= S -95 (8.75 ID) 6290' 7" 32# S -95 (6.094 ID) 5966 -9600' Completion Record - 1) 3 Butt. Tbg w /AB Couplings 94' 2) Otis X- Nipple 2.75 I.D. 96' 3) 31/2" Butt. Tbg err /AB Couplings 8163' 4) Otis X- ,Nipple 2.75 I.D. 8165' ®4 5) 3 Butt. Tbg w /AB Couplings 8199' 6) Seal Locator 8199' 7) Baker Model 'F -1' Packer 8210' 7n) 11 8) Seal Assembly 3.00 I.D. 8213' 9 Muleshoe • 8214' Perforations y jo TVD top of Pay = 8067' r � C - 3: 8530 - 8607' C 7:(CONT) 9280 - 9284' C -5: 8752 -8816' 9338 -9354' 8823 -8848' • : 9366 -9399' C -7: 9148 -9179' 9431 -9446' 9194 -9255' Fill @ 9527' 4 -80 PBD 9538' • ` e - • • I Hilcorp Alaska LLC I WeII:IBR #5RD I FieId:IBruce 112 -31 -2012 I Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 p I a I Pressure - Temperature Profile 1000 1. RIH 11 - - vs 12 -31 -12 Overlay 2. Well Shut - _ - -- - „V 2000 1 1 3000 O • 4000 Ci \\IS\ , 2 +r+ 5000 Q 6000 N hliS so 7000 8000 N. N ... .... IMM MINN 9000 i i i i i I I I I 1 50 60 70 80 90 100 110 120 130 140 150 160 Temperature (Deg. F) - 12 - 31 - 12 Pressure 3 1/2 TBG" 13 3/8" 9 5/8" — 7" – Perfs 12 - 31 - 12 Temp 11 -11 -12 Temp BR 5 -86 Rate & Pressure Plot 4,000 — 1,000 3,200 1 01 800 2,400 600 • 1,600 400 800 I 200 0 ( \. - mu I 0 1 5 10 15 20 25 1 5 10 15 20 25 1 5 10 15 20 25 1 5 10 15 20 25 1 5 10 15 20 25 1 5 10 15 20 25 1 Jul 2012 Aug 2012 Sep 2012 Oct 2012 Nov 2012 Dec 2012 Jan 2013 7" — 9 5/8' 13 3/8" — Water Injection — Tubing Pressure • • I ii N O) ' • . Hilcorp Alaska, LLC - , Post Office Box 244027 Anchorage, AK 99524 -4027 1 Cd VC 3800 Centerpoint Drive 1 Suite 100 f Anchorage, AK 99503 ■ ¢ ' 1 Phone: 907/777 -8322 s Fax: 907/777 -8310 March 1, 2012 ` ;ask t,, E n, r Igreenstein @hilcorp.com v r.,4 ti Mr. Jim Regg Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501 -3509 II Re: Granite Point State 18742 #38 (AIO 6.007) Compliance Anniversary Change Dear Mr. Regg: Hilcorp Alaska, LLC ( "Hilcorp ") is requesting to permanently amend the anniversary date of the compliance temp survey for the Granite Point State 18742 #38 (aka An -38 PTD #1880340) on the Anna platform from May 20 of the odd numbered years to August 25 of the even numbered years (two year cycle). Due to physical space restrictions on the platform related to rig equipment covering up the slickline access in the past (per the attached e- mail), the last compliance temp survey on An -38 was completed on 8- 25 -10. Hilcorp is requesting this date become the new anniversary date for the bi- annual temp survey required for compliance with Admin Approval # 6.007. Please contact Larry Greenstein at 777 -8322 if there are any questions. Sincerely, HILCORP ALASKA, LLC 1 i Larry Gre stein Regulatory Compliance Attachment cc: Chet Starkel, Hilcorp • • Larry Greenstein From: Martin, J. Hal Sent: Wednesday, September 08, 2010 1:54 PM To: Tom Maunder (AOGCC) Cc: Greenstein, Larry P Subject: Granite Point State 18742 #38 (aka Anna #38) AIO 6.007 Compliance Temp Survey Attachments: Anna 38 Temp Survey 8 -25 -10 vs 4- 05- 07.zip Tom, A compliance temp survey was conducted on Granite Point State 18742 #38 (a.k.a. Anna Well No. 38), AIO 6.007 (PTD 188 -034) water injector on 8/25/10. The previous compliance temp survey was conducted on 4/5/07. The attached temp plots (MD and TVD) overlaying Anna Well No. 38 temp surveys on 8/25/10 and 4/5/07 indicate downhole containment of the injection fluids with no significant temperature anomalies. A compliance temp survey was due for this well by 5/20/09. As mentioned in e-mail correspondence over the past year, access to Anna Well No. 38 has been prevented due to slickline access issues related to rig position and rig equipment. The rig sits over Leg #2 in which this well resides. The rig was moved to a different position over Leg #2 in late 2009 to give the best overall chance to access to most of the wells in Leg #2. However, other rig equipment obstacles remained and even after these obstacles were removed to access Anna Well No. 38, an evaluation to creatively and safely determine how and then the effort to rig up slickline underneath the rig substructure finally resulted in a temp survey being run. As you recall, our waterflood injection has been down on the Anna Platform since January 2008 due to surface facility issues. However, previous communication with the AOGCC indicated a desire and acceptance of a compliance temp survey for Anna Well No. 38 even though the well has not been on injection for a period immediately prior to running the temp survey. Since access to the well delayed the temp survey by 15 months and since the well is still shut - in, is it possible to have the due date for the temp survey reset so that the next survey is due in 2 years (August 2012)? Please call me if you have any questions. Thanx, Hal Martin Optimization Engineer MidContinent /Alaska Business Unit Chevron North America Exploration and Production 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tel 907 263 7675 Fax 907 263 7847 hal.martin chevron.com • 1 • • Regg, James B (DOA) From: Regg, James B (DOA) Sent: Monday, February 27, 2012 3:48 PM ((i l To: 'Larry Greenstein' Subject: RE: Granite Point State 18742 #38 (PTD #1880340) An -38 temp survey question A formal request from Hilcorp would make this much cleaner. Does't have to be real elaborate, just make the request to amend permanently the temp survey anniversary date and include reason for request. It's a bit messy extrapolating a request from Chevron /Union to Hilcorp. I've started on the admin approval, amending AIO 6.007 Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 Original Message From: Larry Greenstein [ mailto:lgreensteinPhilcorp.com] Sent: Thursday, February 02, 2012 3:55 PM To: Regg, James B (DOA) Subject: RE: Granite Point State 18742 #38 (PTD #1880340) An -38 temp survey question Thanks Jim. We can perform the TS in May of this year, but that would be the 'off cycle' year based on the original March 2005 approval and subsequently revised to May in 2009. If it wasn't for that darn rig out there, we would have been able to keep this on schedule and avoid all of this. Let me know what works best for you and we will get it done. Larry Original Message From: Regg, James B (DOA) [mailto:iim.regaalaska.gov] Sent: Thursday, February 02, 2012 3:41 PM To: Larry Greenstein Subject: RE: Granite Point State 18742 #38 (PTD #1880340) An -38 temp survey question I think this is going to require an Admin Approval since precedent was set by AIO 6.001, and to document reasons for not doing temp survey in May 2011 as required. I'll work on this based on info provided and see if Commissioners agree with delaying until August. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 1 • 907 - 793 -1236 Original Message From: Larry Greenstein [ mailto:lgreensteinOhilcorp.com] Sent: Thursday, February 02, 2012 1:51 PM To: Regg, James B (DOA) Subject: RE: Granite Point State 18742 #38 (PTD #1880340) An -38 temp survey question Yes, that is true, Jim. Shifting from March to May was a big help, if we would have been able to stay on that schedule. When it turned out we couldn't get the temp survey done until August of 2010 due to the reasons explained in Hal's e-mail (physical obstacle), Hal thought it seemed premature to then go back to the May 2011 due date (9 months later) for the next compliance temp survey to be due. He requested two years from the August 2010 survey to sort of reset the due date to August 2012. That's as much as I know about it, Jim. Hopefully this explains why we didn't do a temp survey in May of 2011 and planned on doing the survey in 2012. We could do this in May 2012 if this would help keep your records straight. Larry Original Message From: Regg, James B (DOA) [mailto:jim.reggOalaska.gov] Sent: Thursday, February 02, 2012 12:41 PM To: Larry Greenstein Subject: RE: Granite Point State 18742 #38 (PTD #1880340) An -38 temp survey question We previously approved the shift from March to May to take advantage of the warmer months and resulting improvements to slick line ops; it is not clear to me the reasons for delaying the required temp survey from May to August. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 Original Message From: Larry Greenstein [ mailto:lgreensteinOhilcorp.com] Sent: Thursday, February 02, 2012 9:37 AM To: Regg, James B (DOA) Subject: Granite Point State 18742 #38 (PTD #1880340) An -38 temp survey question Hi Jim, I found this old e-mail from Hal to Tom about a delayed MIT compliance temp survey on An -38 in 2010. In the last paragraph, Hal asked for approval to modify the anniversary date to two years from the 8/25/10 temp survey. 2 • • After contacting Hal (who's now down in Houston with Chevron), it appears he never got a response from Tom about the request for a change to the anniversary date. The well is currently shut -in and we were planning on doing our compliance temp survey this summer (before 8/25/12), but the current AA anniversary date is in May (per Hal's e- mail). Do you have any issue with us modifying the anniversary date for the An -38 well to the August timeframe ?? Call me if you would like to discuss this, Jim. Thanks Larry 777 -8322 3 • • >> A n , //\\ /1\K' SARAH PALIN, GOVERNOR ALASKA 0 1[, AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276.7542 ADMINISTRATIVE APPROVAL AIO 6.003 (Revised) ADMINISTRATIVE APPROVAL AIO 6.004 (Revised) ADMINISTRATIVE APPROVAL AIO 6.007 (Revised) ADMINISTRATIVE APPROVAL AIO 6.008 (Revised) ADMINISTRATIVE APPROVAL AIO 6.009 (Revised) Mr. J. Hal Martin Optimization Engineer Union Oil Company of California PO Box 196247 Anchorage, Alaska 99519 -6247 RE: Request for Administrative Approval Revision Dear Mr. Martin: Union Oil Company of California (Union) requests a permanent revision to the anniversary date for temperature surveys for water injection wells located on the Anna Platform (Granite Point Field). The Alaska Oil and Gas Conservation Commission (Commission) approves Union's request to change the anniversary date for temperature surveys in the following wells from March 29 to May 20: - Granite Pt. State 18742 Well No. 5; PTD 1670140; AIO 6.003; - Granite Pt. State 18742 Well No. 19; PTD 1680060; AIO 6.008; - Granite Pt. State 18742 Well No. 21; PTD 1760490; AIO 6.009; - Granite Pt. State 18742 Well No. 25; PTD 1680360; AIO 6.004; �J - Granite Pt. State 18742 Well No. 38; PTD 1880340; AIO 6.007. The Commission granted administrative approvals to Union allowing temperature surveys every 2 years in lieu of pressure tests of the tubing- casing annulus. Temperature surveys are intended to demonstrate that injected fluids are exiting the wellbore and remaining confined as required by Area Injection Order 6.000. Union argues that performing temperature surveys in May will allow warmer weather conditions to improve the slickline operations on these water injection wells. Daily surveillance of wellhead pressures and injection rates with monthly reporting to the Commission — mandated by the administrative approvals — provide for early detection and action regarding any deterioration of well integrity that might occur during the 2 -year interval between • • Mr. Hal Martin March 31, 2009 Page 2 of 2 temperature surveys. Administrative approvals also require Union to immediately shut in the well and notify the Commission if there is any measurable change in the well's mechanical integrity. The Commission finds that moving the anniversary date for temperature surveys from March 29 to May 20 will not compromise overall well integrity so as to threaten the environment or human safety. DONE at Anchorage, Alaska and dated March 31, 2009. / 4, 0,9 0 . / 4 i i i . a v o A r NI iii 4 ....... Daniel T. Seamount, Jr. Cathy ' . Foerster IF . • man Chair Commissioner Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[tlhe questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the 1 period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. 4A. 1111k • i,e41 /fiY 14 • • • Colombie, Jody J (DOA) From: Regg, James B (DOA) Sent: Thursday, February 02, 2012 3:43 PM To: Colombie, Jody J (DOA) Subject: FW: Granite Point State 18742 #38 (PTD #1880340) An -38 temp survey question Please assign docket number to this (may already be one since they previously discussed with Maunder...or maybe not). Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 Original Message From: Regg, James B (DOA) Sent: Thursday, February 02, 2012 3:41 PM To: 'Larry Greenstein' Subject: RE: Granite Point State 18742 #38 (PTD #1880340) An -38 temp survey question I think this is going to require an Admin Approval since precedent was set by AIO 6.001, and to document reasons for not doing temp survey in May 2011 as required. I'll work on this based on info provided and see if Commissioners agree with delaying until August. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 Original Message From: Larry Greenstein ( mailto :lgreenstein(ahilcorp.coml Sent: Thursday, February 02, 2012 1:51 PM To: Regg, James B (DOA) Subject: RE: Granite Point State 18742 #38 (PTD #1880340) An -38 temp survey question Yes, that is true, Jim. Shifting from March to May was a big help, if we would have been able to stay on that schedule. When it turned out we couldn't get the temp survey done until August of 2010 due to the reasons explained in Hal's e-mail (physical obstacle), Hal thought it seemed premature to then go back to the May 2011 due date (9 months later) for the next compliance temp survey to be due. He requested two years from the August 2010 survey to sort of reset the due date to August 2012. That's as much as I know about it, Jim. Hopefully this explains why we didn't do a temp survey in May of 2011 and planned on doing the survey in 2012. We could do this in May 2012 if this would help keep your records straight. Larry 1 • Original Message From: Regg, James B (DOA) [mailto:iim.regaalaska.govl Sent: Thursday, February 02, 2012 12:41 PM To: Larry Greenstein Subject: RE: Granite Point State 18742 #38 (PTD #1880340) An -38 temp survey question We previously approved the shift from March to May to take advantage of the warmer months and resulting improvements to slick line ops; it is not clear to me the reasons for delaying the required temp survey from May to August. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 Original Message From: Larry Greenstein [ mailto:lgreensteinOhilcorp.coml Sent: Thursday, February 02, 2012 9:37 AM To: Regg, James B (DOA) Subject: Granite Point State 18742 #38 (PTD #1880340) An -38 temp survey question Hi Jim, I found this old e-mail from Hal to Tom about a delayed MIT compliance temp survey on An -38 in 2010. In the last paragraph, Hal asked for approval to modify the anniversary date to two years from the 8/25/10 temp survey. After contacting Hal (who's now down in Houston with Chevron), it appears he never got a response from Tom about the request for a change to the anniversary date. The well is currently shut -in and we were planning on doing our compliance temp survey this summer (before 8/25/12), but the current AA anniversary date is in May (per Hal's e- mail). Do you have any issue with us modifying the anniversary date for the An -38 well to the August timeframe ?? Call me if you would like to discuss this, Jim. Thanks Larry 777 -8322 2 X25 • • Page 1 of 4 Maunder, Thomas E (DOA) ._ _ __ From: Maunder, Thomas E (DOA) '~v--. ~t-c3 ~ Jc~'~ ~ `Zri ~ ~~~~ '~~.~ ~CC~~~ r-~~ Sent: Friday, January 15, 2010 1:03 PM ~\r.~~ «~~,~~ ~,~~ ~PC~~.~'~vt-~ To: Martin, J. Hal; 'Greenstein, Larry P' t~ Cc: Regg, James B (DOA) Subject: RE: Granite Point State 18742 #5 (aka Anna #5) AIO 6.003 Compliance Temp Survey ~~'~j~, t~ls - Hal and Larry, 1 ~~- ~ r ~` ~ 11 I concur that the temperature survey comparison indicates that fluid is confined to the intended interval. Tom Maunder, PE AOGCC From: Regg, James B (DOA) Sent: Friday, January 15, 2010 8:39 AM To: Maunder, Thomas E (DOA) Subject: FW: Granite Point State 18742 #5 (aka Anna #5) AIO 6.003 Compliance Temp Survey Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Martin, J. Hal [mailto:Hal.Martin@chevron.com] Sent: Thursday, January 14, 2010 5:53 PM To: Regg, .James B (DOA) Cc: Greenstein, Larry P Subject: Granite Point State 18742 #5 (aka Anna #5) AIO 6.003 Compliance Temp Survey Jim, A compliance temp survey was conducted on Granite Point State 18742 #5 (a.k.a. Anna Well No. 5), AIO 6.003 (PTD 167-014) produced water injector on 1/7/10. The previous compliance temp survey was conducted on 4/7/07. The attached temp plots (MD and TVD) overlaying Anna Well No. 5 temp surveys on 1/7/10 and 4/7/07 indicate downhole containment of the injection fluids with no significant temperature anomalies. As you can see on the plots, an effort was made to run the 1/7/ 10 temp survey below the top perforation depth (9072'). The tools reached 9039' (33' from top perf) before tagging up. Nothing definite exists at that point (possibly slickline tools lost in 8/00), but we were unable to work the tools deeper.. For reference, the temp survey in 4/07 was run to 8796' (end of the tubing). A compliance temp survey was due for this well by 5/20/09. As mentioned below in our correspondence, access to Anna Well No. 5 was prevented until mid-December 2009 because of a rig-use building set on the deck covering the slot. Please call me if you have any questions. Thanx, Hal 1/15/2010 • • Page 2 of 4 From: Martin, J. Hal Sent: Friday, December 18, 2009 2:56 PM To: 'Regg, James B (DOA)' Cc: Greenstein, Larry P Subject: RE: Anna Platform Remaining Waterflood Injector Compliance Temp Surveys -- An-5, An-19, and An-38 Jim, Status Update. The rig-use building was removed from the Anna this week. It was delayed alittle -- most recently due to the fog which essentially shut down travel for a week or two. We still have a Utility Module and a Rig to skid in to a position that would allow access to most, if not all of the wells on the Anna. Because of the holidays, the skidding of this equipment is currently planned for sometime in January. An-5 and An-19 were under the building that was removed and we'll work toward getting an MIT on those wells after the holidays as well. An-38 needs the rig to be skidded before it becomes accessible. Thanx, Hal From: Martin, J. Hal Sent: Thursday, October O1, 2009 2:42 PM To: 'Regg, James B (DOA)' Cc: Greenstein, Larry P; Rust, Wayne; Brandenburg, Tim C Subject: RE: Anna Platform Remaining Waterflood Injector Compliance Temp Surveys -- An-5, An-19, and An-38 Tim, I spoke with Wayne Rust about moving the buildings on the Anna. The current plan is to remove one of the buildings and skid the other sometime before December. Once this is done, then we should be able to access and work toward getting the temp surveys on the An-5, An-19, and An-38 wells. Thanx, Hal From: Martin, J. Hal Sent: Tuesday, September 22, 2009 1:45 PM To: 'Regg, James B (DOA)' Cc: Greenstein, Larry P; Rust, Wayne; Brandenburg, Tim C Subject: RE: Anna Platform Remaining Waterflood Injector Compliance Temp Surveys -- An-5, An-19, and An-38 Jim, The person responsible for figuring out the removal of the Anna rig-use buildings is currently out of the office. I made the comment below to respond to you now before I knew that he was out. I should be able to get an idea next week some time after he returns. Thanx, 1/15/2010 • • Page 3 of 4 Hal From: Martin, J. Hal Sent: Wednesday, September 16, 2009 11:07 AM To: 'Regg, James B (DOA)' Cc: Greenstein, Larry P; Moultrie, Dan R; Baker, Robert R; Dorman, Allen; Moultrie, Dan R; Agler, Brit G; Schwartz, Guy L (DOA); Aubert, Winton G (DOA); Freeman, Justin T Subject: RE: Anna Platform Remaining Waterflood Injector Compliance Temp Surveys -- An-5, An-19, and An-38 Tim, The short answer is: 1. Drilling is supposed to be working the plan to remove the rig-use buildings that covering the An-5 and An-19 slots and the rig is on the leg that An-38 is on, but out of position to get over it. Once the building and utility module are removed, access to all the wells will be available on An-5 and An-19 and my understanding is that then skidding the rig can be planned. 2. The waterflood will be down for a while and it is not a given that it will be restored at this point. The sand filters were recently inspected internally and uncovered a failure of the grating that kept the various sizes of sand media stable and properly layered. As you recall, we were hoping it was a butterfly control valve issue, which would have been an easier fix. We are in the process of evaluating whether to proceed with repairs given the significant cost impact coupled with budget constraints. I am guessing that we should be close to an answer on this by mid November. I'll get back to you on this either tomorrow or Monday afternoon with more info on the current timing guesstimate from our drilling guys on the rig-use building removal. Let me know if you have any other questions. Thanx, Hal From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, September 16, 2009 9:00 AM To: Martin, J. Hal Cc: Greenstein, Larry P; Moultrie, Dan R; Baker, Robert R; Dorman, Allen; Moultrie, Dan R; Agler, Brit G; Schwartz, Guy L (DOA); Aubert, Winton G (DOA) Subject: RE: Anna Platform Remaining Waterflood Injector Compliance Temp Surveys -- An-5, An-19, and An-38 Would appreciate an update on schedule for completing temp survey in Anna 5. Same for Anna wells 19 and 38 if they are back on injection; otherwise, we would appreciate an update on status of water flood on Anna platform. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Martin, J. Hal [mailto:Hal.Martin@chevron.com] Sent: Thursday, May 21, 2009 5:58 PM 1/15/2010 • Page 4 of 4 To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Greenstein, Larry P; Moultrie, Dan R; Baker, Robert R; Dorman, Allen; Moultrie, Dan R; Agler, Brit G Subject: Anna PlatForm Remaining Waterflood Injector Compliance Temp Surveys -- An-5, An-19, and An-38 ]im and Tom, FYI and reminder. I just sent you the compliance temp surveys for An-21 and An-25. We were able to access those wells. We have yet to do the compliance temp surveys for An-5, An-19, and An-38, which were also due on May 20th as well. The reason, as we've discussed before, is that the wells are currently not accessible with slickline due to rig equipment covering the wells and supply boat support issues. We will run temp surveys on the three wells above when we regain access to the well bores. All of the Anna waterflood injectors have been shut in since ]anuary 2008 due to ongoing surface facility issues compounded with heavy drilling rig activity during much of 2008. An-5, a produced water injector, is still on injection, averaging about 60 BWPD. As we've discussed, as a result of the unusual shut-in circumstances brought on by the Redoubt volcano, this is because we are still producing some wells on the platform, separating out the produced fluids, and injecting the produced water down An-5. The oil is being injected in to four producers. This is a temporary situation that we are monitoring during this period of downtime for oil shipments. Let me know if you have any questions. Hal Martin Optimization Engineer MidContinent/Alaska Business Unit Chevron North America Exploration and Production 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tel 907 263 7675 Fax 907 263 7847 hal.martin@chevron.com 1/15/2010 Chevron Well: Anna # 5 Field: Anna 01-07-2010 Pressure (psia) 0 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 0 Pressure-Temperature Profile 1. Going in hole to 9039' RKB 2 Shut-In 1000 2000 3000 4000 ~. 5000 .C .r Q d ~ 6000 7000 8000 9000 10000 40 50 60 70 80 90 100 110 120 130 140 150 160 Temperature (Deg. F) 1-7-10 Pressure - Perfs 13 318" 9 5/8" 7" TBG 1-7-10 Temp 4-7-07 Temp Report date: 1/15/2010 Chevron Well: Anna # 5 Field: Anna 01-07-2010 Pressure (psia) 0 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 0 1000 2000 3000 Pressure-Temperature Profile 1 RIH Hole TVD 2. Shut-In y 4000 ... i r fl. 5000 6000 9000 7000 8000 1-7-10 Pressure - Perfs 13 3/8" 9 5/8" 7" TBG 1-7-10 Temp 4-7-07 Temp 40 50 60 70 80 90 100 110 120 130 140 150 160 Temperature (Deg. F) • • Page 1 of 4 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) ~ C ~ Sent: Friday, January 15, 2010 1:01 PM To: Martin, J. Hal; 'Greenstein, Larry P' Cc: Regg, James B (DOA) J Subject: RE: Granite Point State 18742 #19 (aka Anna #19) AIO 6.008 Compliance Temp Survey ~- Hal and Larry, t~4~s--~,~~ ~<<s'"~ I concur that the temperature survey comparison indicates that fluid is confined to the intended interval. Tom Maunder, PE AOGCC From: Regg, James B (DOA) Sent: Friday, January 15, 2010 8:39 AM To: Maunder, Thomas E (DOA) Subject: FW: Granite Point State 18742 #19 (aka Anna #19) AIO 6.008 Compliance Temp Survey i Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Martin, ]. Hal [mailto:Hal.Martin@chevron.com] Sent: Thursday, January 14, 2010 6:26 PM To: Regg, James B (DOA) Cc: Greenstein, Larry P Subject: Granite Point State 18742 #19 (aka Anna #19) AIO 6.008 Compliance Temp Survey Tim, A compliance temp survey was conducted on Granite Point State 18742 #19 (a.k.a. Anna Well No. 19), AIO 6.008 (PTD 1680060) produced water injector on 1/8/10. The previous compliance temp survey was conducted on 10/3/06. The attached temp plots (MD and TVD) overlaying Anna Well No. 19 temp surveys on 1/8/10 and 10/3/06 indicate downhole containment of the injection fluids with no significant temperature anomalies. A compliance. temp survey was due for this well by 5/20/09. As mentioned below in our correspondence, access to Anna Well No. 19 was prevented until mid-December 2009 because of a rig-use building set on the deck covering the slot. As you recall, our waterflood injection has been down on the Anna since 7anuary 2008 due to surface facility issues. However, previous communication with you indicated your desire and acceptance of a compliance temp survey for Anna Well No. 19 even though the well has not been on injection for a period immediately prior to running a temp survey. On another related issue, the compliance temp survey for Anna Well No. 38 is still 1/15/2010 • • Page 2 of 4 outstanding due to similar reasons as mentioned below. The rig has been skidded but there are still some miscellaneous obstacles preventing access to the well. It is expected that these obstacles will be removed from the platform shortly and a compliance temp survey completed within the next 30 days. Please call me if you have any questions. Thanx, Hal From: Martin, J. Hal Sent: Friday, December 18, 2009 2:56 PM To: 'Regg, James B (DOA)' Cc: Greenstein, Larry P Subject: RE: Anna Platform Remaining Waterflood Injector Compliance Temp Surveys -- An-5, An-19, and An-38 Jim, Status Update. The rig-use building was removed from the Anna this week. It was delayed alittle -- most recently due to the fog which essentially shut down travel for a week or two. We still have a Utility Module and a Rig to skid in to a position that would allow access to most, if not all of the wells on the Anna. Because of the holidays, the skidding of this equipment is currently planned for sometime in 7anuary. An-5 and An-19 were under the building that was removed and we'll work toward getting an MIT on those wells after the holidays as well. An-38 needs the rig to be skidded before it becomes accessible. Thanx, Hal From: Martin, J. Hal Sent: Thursday, October 01, 2009 2:42 PM To: 'Regg, James B (DOA)' Cc: Greenstein, Larry P; Rust, Wayne; Brandenburg, Tim C Subject: RE: Anna Platform Remaining Waterflood Injector Compliance Temp Surveys -- An-5, An-19, and An-38 .7im, I spoke with Wayne Rust about moving the buildings on the Anna. The current plan is to remove one of the buildings and skid the other sometime before December. Once this is done, then we should be able to access and work toward getting the temp surveys on the An-5, An-19, and An-38 wells. Thanx, Hal From: Martin, J. Hal Sent: Tuesday, September 22, 2009 1:45 PM To: 'Regg, James B (DOA)' Cc: Greenstein, Larry P; Rust, Wayne; Brandenburg, Tim C Subject: RE: Anna Platform Remaining Waterflood Injector Compliance Temp Surveys -- An-5, An-19, and An-38 1/15/2010 • • Page 3 of 4 )im, The person responsible for figuring out the removal of the Anna rig-use buildings is currently out of the office. I made the comment below to respond to you now before I knew that he was out. I should be able to get an idea next week some time after he returns. Thanx, Hal From: Martin, J. Hal Sent: Wednesday, September 16, 2009 11:07 AM To: 'Regg, James B (DOA)' Cc: Greenstein, Larry P; Moultrie, Dan R; Baker, Robert R; Dorman, Allen; Moultrie, Dan R; Agler, Brit G; Schwartz, Guy L (DOA); Aubert, Winton G (DOA); Freeman, Justin T Subject: RE: Anna Platfiorm Remaining Waterflood Injector Compliance Temp Surveys -- An-5, An-19, and An-38 Tim, The short answer is: 1. Drilling is supposed to be working the plan to remove the rig-use buildings that covering the An-5 and An-19 slots and the rig is on the leg that An-38 is on, but out of position to get over it. Once the building and utility module are removed, access to all the wells will be available on An-5 and An-19 and my understanding is that then skidding the rig can be planned. 2. The waterflood will be down for a while and it is not a given that it will be restored at this point. The sand filters were recently inspected internally and uncovered a failure of the grating that kept the various sizes of sand media stable and properly layered. As you recall, we were hoping it was a butterfly control valve issue, which would have been an easier fix. We are in the process of evaluating whether to proceed with repairs given the significant cost impact coupled with budget constraints. I am guessing that we should be close to an answer on this by mid November. I'll get back to you on this either tomorrow or Monday afternoon with more info on the current timing guesstimate from our drilling guys on the rig-use building removal. Let me know if you have any other questions. Thanx, Hal From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, September 16, 2009 9:00 AM To: Martin, J. Hal Cc: Greenstein, Larry P; Moultrie, Dan R; Baker, Robert R; Dorman, Allen; Moultrie, Dan R; Agler, Brit G; Schwartz, Guy L (DOA); Aubert, Winton G (DOA) Subject: RE: Anna Platform Remaining Waterflood Injector Compliance Temp Surveys -- An-5, An-19, and An-38 Would appreciate an update on schedule for completing temp survey in Anna 5. Same for Anna wells 19 and 38 if they are back on injection; otherwise, we would appreciate an update on status of water flood on Anna platform. Jim Regg 1/15/2010 • Page 4 of 4 AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Martin, J. Hal [mailto:Hal.Martin@chevron.com] Sent: Thursday, May 21, 2009 5:58 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Greenstein, Larry P; Moultrie, Dan R; Baker, Robert R; Dorman, Allen; Moultrie, Dan R; Agler, Brit G Subject: Anna Platform Remaining Waterflood Injector Compliance Temp Surveys -- An-5, An-19, and An-38 )im and Tom, FYI and reminder. I just sent you the compliance temp surveys for An-21 and An-25. We were able to access those wells. We have yet to do the compliance temp surveys for An-5, An-19, and An-38, which were also due on May 20th as well. The reason, as we've discussed before, is that the wells are currently not accessible with slickline due to rig equipment covering the wells and supply boat support issues. We will run temp surveys on the three wells above when we regain access to the well bores. All of the Anna waterflood injectors have been shut in since January 2008 due to ongoing surface facility issues compounded with heavy drilling rig activity during much of 2008. An-5, a produced water injector, is still on injection, averaging about 60 BWPD. As we've discussed, as a result of the unusual shut-in circumstances brought on by the Redoubt volcano, this is because we are still producing some wells on the platform, separating out the produced fluids, and injecting the produced water down An-5. The oil is being injected in to four producers. This is a temporary situation that we are monitoring during this period of downtime for oil shipments. Let me know if you have any questions. Hal Martin Optimization Engineer MidContinent/Alaska Business Unit Chevron North America Exploration and Production 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tel 907 263 7675 Fax 907 263 7847 hal. martin@chevron.com 1/15/2010 Chevron Well: Anna # 19-42 Field: Anna 01-08-10 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 0 Pressure-Temperature Profile 1 . Going in hole to 9500' RKB 2. Shut-In 1000 2000 3000 4000 ..r ~ 5000 t a m 0 sooo 7000 sooo sooo 10000 40 50 60 70 80 90 100 110 120 130 140 150 160 170 Temperature (Deg. F) 1-8-10 Pressure - Perfs 13 3/8" 9 5/8" 7" TBG 1-8-10Temp 10-3-06 Temp Chevron Well: Anna # 19-42 Field: Anna 01-08-10 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 0 1000 2000 Pressure-Temperature Profile 1 RIH Hole TVD 2 Shut-In 3000 4000 r d «.. ... D ~ 5000 H t r C. ~ 6000 7000 8000 9000 10000 40 50 60 70 80 90 100 110 120 130 140 150 160 170 Temperature (Deg. F) -1-8-10 Pressure - Perfs 13 3/8" 9 5/8" -7" TBG 1-8-10 Temp 10-3-06 Ter 24 Chevron J. Hal Martin Chevron North America %.1 Optimization Engineer Exploration and Production MidContinent/Alaska P.O. Box 196247 Anchorage, 99519-6247 Tel el 907 7 7 263 7675 Fax 907 263 7847 Email Hal.Martin @chevron.com November 5, 2009 RECEIVED NOV 0 5 2009 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission Alaska Oil Gas Cons. Commission 333 W 7th Ave 100 Anchorage Anchorage, Alaska 99501 -3509 REQUEST FOR ADMINISTRATIVE APPROVAL UNDER AREA INJECTION ORDER 6 CONTINUATION OF INJECTION GRANITE POINT STATE 18742 WELL NO. MUCI -3 ANNA PLATFORM GRANITE POINT FIELD Dear Chair Seamount: Union Oil Company of California (Union Oil) requests administrative approval under Area Injection Order 6 for the continuation of injection of non hazardous Class II fluids for Granite Point State 18742 Well No. MUCI -3 (Permit 1780190), Anna Platform, Granite Point Field. To support this request, Unocal submits the following information and documentation: 1. Schematic (attached). 2. MD and TVD plot of temperature survey (attached). 3. TIO plot (attached). 4. Maximum allowable injection pressure calculation in graphical form (attached). 5. Brief /relevant well history (below). The Granite Point State 18742 Well No. MUCI -3 was drilled and completed in 4/78 as a single string injector in the Tyonek Formation C -2, 5, 6, 7, and 8 Sands. A workover in 1/80 attempted to apply mechanical injection conformance control to the completion. The last workover in 4/87 was performed to repair tubing -to- casing communication. Until recently, the well injector operated under a standard MIT with 2500 psi applied to the annulus to keep seals in the packer and maintain integrity. Waterflood injection on the Anna Platform has been down since late 2007 due to surface waterflood system issues. However, Well No. MUCI -3 continued on effluent injection at approximately 250 BFPD as part of an enhancement to waterflood. In late 3/09, the 2500 psi applied to the annulus was lost and effluent injection continued until the oversight was discovered in 10/09. The AOGCC was notified by meeting on October 14, 2009. A temperature survey was run on October 16, 2009 and the AOGCC agreed with Union Oil that injected fluids are only entering the completion interval below the packer as intended. The AOGCC has given interim approval to continue effluent injection in to Well No. MUCI -3 while this administrative approval application is being prepared and processed. MidContinent /Alaska Chevron North America Exploration and Production www.chevron.com Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission November 5, 2009 Page 2 Union Oil will monitor and record daily injection rates and tubing and casing pressures on the well and provide a report to the AOGCC on a monthly basis. Surface injection pressures will be kept below 3400 psi to maintain casing integrity. A temperature survey will be run every two years to insure the injected water is contained within the completion interval. Please call me at (907)263 -7675 if you have any questions. Sincerely, 7g Hal Martin JHM:jII Attachments Chevron North America Exploration Alaska loration and Production www.chevron.com p 1 mikettinati Anna Platform Well No. MUCI -3 UNOCAL 76 Work Over 4/14/87 CASING AND TUBING DETAIL KBEIev -105' SIZE WT GRADE CONN ID TOP BTM. 20 91.4 5LX-42 19.125 Surf 610' 2 13 -3/8" 61/68 S- 80/K -55 12.415 Surf 3495' 9 -5/8" 47 S -95 8.681 Surf 173' 9 -5/8" 40 N -80 8.835 173' 950' 9 -5/8" 47 SMN -80 8.681 950' 3617' L 9 -5/8" 43.5 S -95 8.755 3617' 3661' 9 -5/8" 47 S -95 8.681 3661' 9553' 7" 35 N -80 6.004 9318' 11050' Z. Tubing: 3 -1/2" 9.3 N -80 DSS -HTC 2.992 Surf 9638' JEWELRY DETAIL NO. Depth ID Item 1 33' Hanger CIW Tbg Hanger 2 35' Crossover 3 -1/2 Btc. X 3 -1/2" DSS -HTC 3 9626' Seal locator Z S 4 9625' Baker F -1 Packer W/ 15000# set on it 5 9627' Seal Assembly 6 9638' Mule Shoe Tagged at 10200' 1/28/95 3 PERFORATION DATA i 1 4 Pccum Zcne Top Btm Ant SPF Perf Date 5 C -2 9718 9734 16 6 April 78, Jan 80 Scg 9825 9827 2 3 Ap -78 6 C -5 9954 9964 10 6 April 78, Jan 80 10004 10094 90 6 April 78, Jan 80 C 2 C6 10186 10206 20 6 April 78, Jan 80 10252 10262 10 6 April 78, Jan 80 C 5 10334 10350 16 6 April 78, Jan 80 C7 10436 10454 18 6 Apil 78, Jan 80 EE 10474 10490 16 6 April 78, Jan 80 C 10520 10544 24 6 April 78, Jan 80 10576 10600 24 6 April 78, Jan 80 C8 10820 10830 10 6 April 78, Jan 80 C 10880 10890 10 6 April 78, Jan 81 10826 10950 24 6 April 78, Jan 82 C-8 PBTD 10,998' TD 11,065' MAX. HOLE ANGLE 17.5° MUCI -3 Schematic 7- 23- 07.doc DATE: 7/23/07 by BMB Updated: 10/23/09 by JHM Chevron Well: MUCI -3 Field: ANNA Date 10 -16 -2009 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 0 20° Pressure Temperature Profile 1. Going in hole 1000 2. Well Static 2000 13 -3/8" r 3000 4000 cD TBG 5000 Q 6000 cD 7000 8000 9000 10000 IF 11000 50 60 70 80 90 100 110 120 130 140 Temperature (Deg. F) 10-16-09 Pressure 13-3/8 9 -5/8 7" 20" 1/2 TBG Pkr Perfs 10 -16 -09 Temp -8 -89 Temp 'Chevron I Well:IMUCI -3 I Field: ANNA Date 10 -16 -2009 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 0 20" Pressure Temperature Profile 1. Going in hole TVD 2. Well Static 1000 I 113 -3/8" r 2000 3000 TBG 4000 VIM .4 5000 O. 6000 7000 Lnr 8000 y. 9000 50 60 70 80 90 100 110 120 130 140 Temperature (Deg. F) Pressure 13 -3/8 9 -5/8 7" 20" 3 1/2 TBG Pkr Perfs —Temperature Plot Pressure Rate vs Time Well An -I -03 400 2500 350 9 5/8" 11\11Th 13 3/8" 20" Tubing 300 2000 Vol 4I 250 i 1500 3 N cn 200 m cu m L a 150 1000 L i 100 500 I I 1 1 T i 111. 50 I 4 ;1 I tiI 1I i' 1W �I I I .r r ill 0 rr..,r r.., I l_>r iA., 10 0 0 CO CO rn o) rn o a o rn 0 o) w 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 co 0 co 0 0 Xr) 0 0 •0 0 0 0 0 0 0 0 0 0 0 a 0 0 0 0 0 0 0 0 CO 0 0 0 0 MUCI -3 Maximum Allowable Operating Pressure Graph Pressure (PSI) 0 1,000 2,000 3,000 4,000 5,000 6,000 7,000 8,000 9,000 10,000 0 Cak,uIalivii ate 1 0/20/2 0 09 Safe operating pressures (surf ace gauge) Production 4025 p si. 70% nominal casing yield Intermediate 894 psi. limited by fracture pressure at shoe Surface 163 psi limited by fracture pressure at shoe 1,000 Current Pressure readings TBGPRESS 37 CSGPRESS2 550 CSGPRESS3 380 CSGPRESS5 50 Casin Details 2,000 Casi Size Weight Grade Yield MD Top MD Bottom Protio 9 -578" 47 S -95 8150 34 173 Production 9 -5/8" 40 N -80 5750 173 950 Production 9 5/8" 47 SMN 80 6870 950 3617 Production 9 -5/8" 43.5 S-95 7510 3617 3661 Production -5/8" 47 S-95 8150 3661 9553 Surface 1 3/8" 68 S-80 5020 37 188 Surface 13 ./8" 61 K-55 3090 188 1193 3,000 Surtace 20 68 2321 Surface 13- 68 S 5380 2321 3495 Conductor 94 X 42 39 612 ...■11 a 4,000 Casing Param titers Assumptions Production casing yield 70% of nominal with flu weight of 0.433 #/ft Intermediate casin< yield 45% of nominal with fl 'd weight of 0.433 #/ft Surface casing yied 45% of nominal with fluid w• ght of 0.433 #/ft Fracture gradient 0.7 #/ft API 507332031 00 Permit 1780190 5,000 Workbook MUCI- `MASOP_19Oct09.xls t 6,000 Q CD 0 7,000 Variable Definitions 8,000 RP Reservoir Pressure CYP Casing Yield Pressure SF Safety Factor (70% for working annulus; 45% for o er annuli) HP Internal Fluid Hydraulic Pressure MASP Maximum allowable surface working pressure Graphical calculation method Inside pressure potential Outside pressure containment 9,000 Therefore HP MASP RP (CYP SF) Rearranging MASP RP (CYP SF) HP 10,000 Internal Fluid Hydraulic Pressure Formation facture pressure 0.7 #/ft -MASP (production casing) Intermediate CYP 45% Outside Containment for Intermediate casing 11,000 MASP (Intermediate casin Production CYP 70% Outside Containment for Prod Casing Disclaimers (fine print) Casing yield values taken from published sources where specifications are known. If specifications are unknown then values are the lowest value of probable materials. 12,000 TVD interpolated from Openworks directional surveys. Values should be 25 ft 10,000 ft. MD Graphical Casing Pressure Analysis ver 22x.xls *23 Page 1 of 4 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, October 20, 2009 8:47 AM To: 'Martin, J. Hal' Cc: Cole, David A; Agler, Brit G; Greenstein, Larry P; Dorman, Allen; Moultrie, Dan R; Baker, Robert R; Freeman, Justin T; Ross, Gary D; Myers, Chris S Subject: RE: Anna Platform MUCI -3 (178 -019) Integrity Failure and Plan Forward Hal, et al, Thanks to all for moving expeditiously to acquire the temperature log data. I concur with your assessment that there is no temperature anomaly evident above the packer and that injected fluids are entering the perforated intervals as intended. It is ACCEPTABLE to keep MUCI -3 in service. It is appropriate to submit an application for administrative approval. Call or message with any questions. Tom Maunder, PE I w r AOGCC From: Martin, J. Hal [mailto:Hal.Martin @chevron.com] Sent: Monday, October 19, 2009 10:49 AM To: Maunder, Thomas E (DOA) Cc: Cole, David A; Agler, Brit G; Greenstein, Larry P; Dorman, Allen; Moultrie, Dan R; Baker, Robert R; Freeman, Justin T; Ross, Gary D; Myers, Chris S Subject: RE: Anna Platform MUCI -3 Integrity Failure and Plan Forward Tom, Attached is the temp survey for MUCI -3 performed last Friday afternoon. Note that a short segment from a temperature log run in March 1989 (only comparative data available from the well) is also included in the graph and indicates a consistency over the interval just above and below the packer. Our interpretation of the survey is that there is no temperature anomaly above the packer and all injected fluids are entering the perforated intervals below the packer. I will call you mid this afternoon after you have had time to look at the survey as well and we can discuss any concerns you may have and the AOGCC interpretation of the survey. The well was returned to injection following the survey based on my interpretation of the survey Friday evening. If the survey results are satisfactory to the AOGCC, I would like to request that injection in to MUCI -3 be allowed to continue while the application for Administrative Approval on this well is prepared for submission to you within the next week or two. Thanx, Hal From: Martin, J. Hal Sent: Thursday, October 15, 2009 11:10 AM 10/20/2009 Page 2 of 4 To: 'Maunder, Thomas E (DOA)' Cc: Cole, David A; Agler, Brit G; Greenstein, Larry P; Dorman, Allen; Moultrie, Dan R; Baker, Robert R; Freeman, Justin T; Ross, Gary D; Myers, Chris S Subject: RE: Anna Platform MUCI -3 Integrity Failure and Plan Forward Tom, With regard to timing of the temp survey, here is what I know at the moment. The slickline unit needs to be moved by boat from the Granite Point Platform to the Anna. Boat and helicopter work has been hammered this week due to the weather, consequently things are backed up a bit. The Steelhead M -20 grass roots gas well and King K -1RD2 CT deployed ESP work is starting. We have been working the issue since before yesterday. I just spoke with John Hammelman down in Nikiski and he will work to see if we can get the slickline unit moved tonight or early tomorrow. 9 Y I will update you this afternoon (or earlier) if I hear of a more definite schedule. Thanx, Hal From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Thursday, October 15, 2009 10:46 AM To: Martin, J. Hal Cc: Cole, David A; Agler, Brit G; Greenstein, Larry P; Dorman, Allen; Moultrie, Dan R; Baker, Robert R; Freeman, Justin T; Ross, Gary D; Myers, Chris S Subject: RE: Anna Platform MUCI -3 Integrity Failure and Plan Forward Hal, Larry, al y, al, I acknowledge our meeting yesterday and your delivery of the documents you attached to your message. In our meeting you indicated that arrangements were being made to conduct the temperature survey(s) mentioned in paragraph 3 of your Plan Forward section. Do you have information as to when that operation may be accomplished? The TIO pressure plot does indicate that the 13 -3/8" x 9 -5/8" annulus pressure has not shown a step change in pressure that could indicate communication from the 9 -5/8" casing at least at shallow depths. There is an aquifer exemption in effect for Granite Point Field as granted by EPA at 40 CFR 147.102 (b)(2)(i) so contamination of fresh water is not an issue. For the short term, it is acceptable to keep the well in operation however continued operation pending an Administrative Approval is contingent on the temperature survey demonstrating that injection is into the perforations. As an interim measure, it is appropriate to include this well in the monthly monitoring report. Please be aware that the Commission reserves the right to pursue an enforcement action in this matter. I look forward to your reply. Tom Maunder, PE AOGCC From: Martin, J. Hal [mailto:Hal.Martin @chevron.com] Sent: Thursday, October 15, 2009 10:07 AM To: Maunder, Thomas E (DOA) Cc: Cole, David A; Agler, Brit G; Greenstein, Larry P; Dorman, Allen; Moultrie, Dan R; Baker, Robert R; Freeman, Justin T; Ross, Gary D; Myers, Chris S Subject: Anna Platform MUCI -3 Integrity Failure and Plan Forward 10/20/2009 Page 3 of 4 Tom, As a follow up to our meeting on 10/14/09 at your office, this e-mail concerns the integrity failure and plan forward for the Granite Point State 18742 Well No. MUCI -3 (MUCI -3, Permit #1780190), a waterflood injector on the Anna Platform. FYI, attached is a schematic of the MUCI -3 and a TIO plot covering the period in question. The topics we discussed were: 1. The integrity failure of the tubing /packer resulting in tubing -to- casing communication. 2. The plan forward in working toward an Administrative Approval for continued injection on the well. Integrity Failure Background: Historically, the MUCI -3 has been a high rate waterflood injector on the Anna Platform, relative to other waterflood injector rates. At least since 1999 (and possibly earlier), the injector has had 2500 psi pressure applied to the 9 -5/8" casing to keep the tubing seals in the packer. The well has passed 4 -yr Standard MITs in 2001 and 2005 operating in this fashion. In late 2007, the Anna waterflood was shut down due to surface waterflood system issues and has remained shut -in since that time. Recently it was determined that the sand filters will require more extensive repair than was originally anticipated. The decision to repair the waterflood system is currently under evaluation. Even though this part of waterflood was down, the effluent from the waste system, which is part of our enhancement to waterflood, continued to be injected into MUCI -3 in an intermittent pumping fashion at about 250 BPD with a max injection pressure of about 1000 psi. Integrity_ Failure: Around March 24, 2009, the annular pressure applied to the 9 -5/8" casing was lost. Since waterflood was not in operation the loss of annular pressure was inadvertently overlooked because, although waterflood was down, relatively low pressure, low volume intermittent effluent injection continued. Daily calculated effluent volume reporting had been accidentally overlooked as well and reporting these volumes was initiated in early May. Nevertheless the compliance failure associated with the loss of tubing /packer integrity in MUCI -3 and injection continued until recognized recently and then quickly reported to you in our recent meeting. Plan Forward Operationally, the MUCI -3 is an important injector, not only for waterflood, but also because it is the best waterflood injector to handle the effluent generated from the platform and used to enhance waterflood recovery. The reason for this is because the effluent generated is 90% seawater, making it compatible with waterflood injection water and the volumes generated are easily injected into the well. Therefore, Chevron would like to work toward an Administrative Approval of this well to continue injection. Using an alternate well such as the produced water injection Well An -5, which continues to operate as well on a daily basis, is not preferred because of the various incompatibility issues generated from mixing produced water and seawater such as H2S, BaSO4, bacteria, corrosion, etc. The use of other 10/20/2009 Page 4 of 4 waterflood injection wells on the platform is not recommended because of the generally low injection rates observed in these wells. The plan that we agreed to pursue in our meeting is to run a temp survey ASAP and have the analysis demonstrate to the AOGCC that no abnormal cooling is taking place above the packer. If the completion intervals are reachable, the temp survey should also show the expected cooling is occurring from injected fluids going into approved intervals. In the unlikely event that the temperature survey strongly indicates injection may be occurring at some point above the packer, the well will be shut -in immediately. If the temp survey results are as expected, Chevron would like to continue injecting into MUCI -3 while preparing the necessary documentation for an Admin Approval request. Let me know if you have any questions or need additional information. Thanx, Hal Martin Optimization Engineer MidContinent /Alaska Business Unit Chevron North America Exploration and Production 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tel 907 263 7675 Fax 907 263 7847 hal.martin@chevron.com 10/20/2009 0 Chevron I WeII:IMUCI -3 I Field:IANNA I Date1l0 -16 -2009 I Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 III 1 20" i oft. as Pressure- Temperature Profile EE 1000 1 Going in hole •N ■=......M1 2. Well Static 1 -111 �Z_B a C 2000 L 13 318" 3000 ii. ss lin :oil E mon‘ 4000 M I ill LI T BG E: 1 15 i CD O 5000 1E o i t a s000 EE a) in I. 7000 iME i 8000 9000 'E E l0000 MN 11000 I I I I 50 60 70 80 90 100 110 120 130 140 Temperature (Deg. F) 10 -16 -09 Pressure 13 -3/8 9 -5/8 7" 20" 3 1/2 TBG _1 Pkr Perfs —10-16-09 Temp 3 -8 -89 Temp ~ 22 i 1 • • Chevron y ,~'.w 7. Hal Martin Optimization Engineer MidContinent/Alaska Chevron North America Exploration and Production P.O. Box 196247 Anchorage, AK 99519-6247 Tel 907 263 7675 Fax 907 263 7847 Email Ha1.Martin@chevron.com 9 14 March 24, 2009 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 W 7th Ave, Suite 100 Anchorage, Alaska 99501-3539 REQUEST FOR REVISED ANNIVERSARY DATE FOR INJECTOR TEMPERATURE SURVEYS ANNA PLATFORM GRANITE POINT FIELD Dear Mr. Seamount: .~las~a Oii ~ Gas L'nris. Cainmissi~r+ Anchorage Union Oil Company of California (Union Oil) requests a permanent revision to the anniversary date for temperature surveys for water injection wells on the Anna Platform with Administrative Approval requiring temperature surveys every two years. The specific wells for which the revised date is requested are: a. Granite Point State 18742 Well No. 19 (An-19, Permit #1680060) waterflood injector -Administrative Approval AIO 6.008 ~% b. Granite Point State 187421Ne11 No. 21 (An-21, Permit #1760490) waterflood injector -Administrative Approval AIO 6.009 c. Granite Point State 18742 Well No. 25 (An-25, Permit #1680360) waterflood injector - Administrative Approval AIO 6.004 d. Granite Point State 18742 Well No. 38 (An-38, Permit #1880340) waterflood injector - Administrative Approval AIO 6.007 e. Granite Point State 18742 VNell No 5 (An-5, Permit #1670140) produced water injector -Administrative Approval AIO 6.003 ~ The current anniversary date for temperature surveys on the above wells is March 29, and all are due in 2009. Union Oil requests that the anniversary date be permanently moved to May 20 for all of the above wells. ____aThe reason for the request is to allow warmer weather conditions to improve slickline operations on water wells. MidContinent/Alaska Chevron North America Exploration and Production www.chevron.com • Commission Chair Dan Seamount Alaska Oil and Gas Conservation Commission March 24, 2009 Page 2 Thank you for your consideration and if you have any questions regarding this, please contact me at 263-7675. Sincerely, i~ Hal Martin cc: Jim Regg, AOGCC MidContinent/Alaska Chevron North America Exploration and Production www.chevron.com ~# 21 Page 1 of 2 • Maunder, Thomas E (DOA) From: Martin, J. Hal [Hal.Martin@chevron.com] Sent: Wednesday, February 13, 2008 10:16 AM To: Maunder, Thomas E {DOA) Cc: Greenstein, Larry P; Flynn, Tim [ASRC]; Cole, David A Subject: RE: Anna Well No. 5 Admin Approva~~ 3 Clarification Thanks, Tom! From: Maunder, Thomas E {DOA) [mailtoaom.maunder@alaska.gov] Sent: Wednesday, February 13, 2008 9:58 AM To: Martin, ). Hal Cc: Greenstein, Larry P; Flynn, Tim [ASRC]; Cole, David A Subject: RE: Anna Well No. 5 Admin Approval AIO 6.003 Clarification Hal, et al, Jim and I reviewed your request and stated operating plans. We do not see any issue here. Water only is approved and water is what you are proposing to pump. Although the process prior to arriving at the wellhead is different, the fluid is approved for use in the enhanced recovery project. Sorry I am a little late in getting this back to you. I will place a copy of this message in the AIO 6 file. Call or message with any questions. Tom Maunder, PE AOGCC From: Martin, ). Hal [mailto:HaLMartin@chevron.com] Sent: Thursday, February 07, 2008 1:59 PM To: Maunder, Thomas E (DOA) Cc: Greenstein, Larry P; Flynn, Tim [ASRC]; Cole, David A Subject: Anna Well No. 5 Admin Approval AIO 6.003 Clarification Tom, As we discussed yesterday, I am sending you this a-mail to help us understand and appropriately apply a condition on an Admin Approval. Granite Point State 18742 #5 [aka Anna #5] (PTD 167-014) had an administrative approval (AIOI 6.003) granted to it March 29, 2005. Condition #2 of the Admin Approval says that injection is limited to WATER ONLY. The question is: Is the proposed use we have for An-5 with regard to supplemental waterflood injection due to well work operations on other platform wells in the near future acceptable to the AOGCC? Background Info -- An-5 currently has primarily produced water being injected in to it. -- Rig work is scheduled to begin shortly on Anna. However, the supplemental injection of water from the first well in to An-5 will not take place until about March 1. -- Because the waterflood system is currently down on Anna with sand filter and pump 2!13/2008 Page 2 of 2 issues, the current plan is to supplement the injection in to An-5 with primarily a mixture of raw inlet and produced water displaced from the wells being worked on. Currently, there are three wells (An-24, An-32RD, and An-17) scheduled for the first phase of rig work that would have water sent to An-5. -- The general process as I understand it is as follows: 1. The well will be filled as needed with raw inlet water (no circulating planned). 2, The completion pulled and hole kept full with raw inlet water. 3. A cement retainer set with E-line. 4. TIH with DP and equalize cement plug on top of cement retainer (cement plug slurry volume of raw inlet water will go into pits (approx. 30 Bbls) -potentially included in OBM mud makeup). 5. POOH with DP, keeping hole full with raw inlet water. 6. TIH with whipstock for sidetrack. 7. Displace hole with spacer and OBM (+/- 600 Bbls per well). Raw and produced water mix returns go to pit thru fine shaker (max 50 micron screen size) to be treated for oxygen, corrosion, etc. When spacer returns, fluid will be diverted to a different pit. 8. Raw and produced water mix will be pumped from the pit and into the produced water tanks and then in to An-5. Chevron believes that the introduction of this water will not adversely affect the completion and in a limited fashion the supplemental injection of this water will benefit the waterflood. Let me know if this fits within the bounds of ~~WATER ONLY" as it applies to An-5 AIO 6,003. Thanx, Hal Martin Optimization Engineer MidContinent/Alaska Business Unit Chevron North America Exploration and Production 909 West 9th Avenue Anchorage, AK 99501-3322 Tel 907 263 7675 Fax 907 263 7847 hal.martin@chevron.com 2/13/2008 ~ 2Q • Chevron ). Hal Martin Optimization Engineer MidContinent/Alaska • Chevron North America Exploration and Production P.O. Box 196247 Anchorage, AK 99519-6247 Tel 907 263 7675 Fax 907 263 7847 Email Hal.Martin@chevron.com ~' ~' ,~ ~ ~:~ January 30, 2008 Commission Chair John K. Norman Alaska Oil and Gas Conservation Commission 333 W 7th Ave, Suite 100 Anchorage, Alaska 99501-3539 r> ~~~~~,~ ~~ ~r~ .~; ,~ ~ - _:; ... ~~nr ~ ~' REQUEST FOR CANCELLATION OF ADMINISTRATIVE APPROVAL AIO 6.006 GRANITE POINT STATE 18742 WELL NO. 32RD ANNA PLATFORM GRANITE POINT FIELD Dear Mr. Norman: Union Oil Company of California (Union Oil) requests that the Administrative Approval AIO 6.006 for Granite Point State 18742 Well No. 32RD (PTD #187-063), Anna Platform, Granite Point Field, be cancelled. The reason for the cancellation is because the subject well (a.k.a. An-32RD) is planned for P&A in February 2008 in preparation for redrill as an oil producer. Thank you for your consideration and if you have any questions regarding this, please contact me at 263-7675. Sincerely, ~~ f~Z~~ Hal Martin cc: Tom Maunder, AOGCC Well File MIT Book MidContinent/Alaska Chevron North America Exploration and Production www.chevron.com X19 • • Regg, James B (DOA) From: Regg, James B (DOA) <''? ~~ ~, ~,, /~; ~ Sent: Wednesday, December 26, 2007 5:23 PM To: 'Greenstein, Larry P' Cc: Maunder, Thomas E (DOA) Subject: RE: Well with Questions on Determining the Anniversary Dates for Compliance Temp Surveys Larry -Each of the (fisted admin approvals did not establish a formal anniversary date for determining when to perform compliance temperature surveys. There has been some confusion that has resulted. Based on what I have read below and our conversation earlier today, I believe using the effective date (signature date) of the administrative approvals is consistent with your request for nearly all wells accomplishes what you are after (efficiency). The veils you reference below are (with a due date for the next temp survey}: Granite Pt State (Anna} 19 - AIO 6.008 (3/29/2005); next temp survey due 3/29/2009 Granite Pt State (Anna) 21 - AIO 6.009 (3/29/2005); next temp survey due 3/29/2009 TBU G-11 - Al0 5.009 (12/15/05); next temp survey due 12!15/2009 (yo€~ suggested 9;2009} TBU G-22 - Al0 5.006 {9/14/2005); next temp survey due 9/1 412 0 0 9 TBU G-23RD - AIO 5.004 (6/30/2005}; next temp survey due 6/30/2009 (you suggested 3.12009) TBU G-27 - AIO 5.003 {3/2912005}; next temp survey due 3129/2009 TBU G-29RD - AIO 5.007 (9/2312005); next temp survey due 9!23/2009 TBU G-40 - AIO 5.002 {3/2912005}; next temp survey due 3/29/2009 TBU K-11 - AIO 5.011 {2/6/06}; next temp survey due 2/6/2010 TBU K-24RD2 - AIO 5.010 (2/6/06); next temp survey due 2/6/2010 There is nothing preventing Chevron from testing earlier (as you have proposed for 2 of these wells}. This does not affect any admin approvals that have anniversary dates specifically fisted in the conditions. Jim Regg ROGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: Greenstein, Larry P [mailto:Greensteinlp@chevron.com] Sent: Wednesday, December 26, 2007 10:45 AM To: Regg, James B (DOA) Subject: Well with Questions on Determining the Anniversary Dates for Compliance Temp Surveys Thanks for the conversation on this anniversary date topic Jim. It gets real confusing for me to keep the different basis for the anniversary dates separate for each well. The wells in question are: An-19 - AA signed 3/29/C5 -fast compliance temp survey 1013!06. ~lVauld like to slide 10108 temp survey to 3109 to get on AA anniversa~~y date cycle. An-21 - AA signed 3129x`05 -last compliance temp survey 10/4/06. Would like to slide 10!08 temp sunray to 3109 for the AA date reason. K-11 - AA signed 216106 -last compliance temp survey 12/11/07 (ust sent to you). Would like to sEide 12;09 temp surrey to 2110 for the AA date reason. 12/26/2007 ~ ~_ -°-a-- ~-- i<-24RD2 - AA signed 2/6106 -last c~iiance temp survey 12i21f07 (will send t soon}. Would like to slide 12f09 temp survey to 2110 for the AA date reason. The Grayling wells have some other things going on. We have wells with AA anniversary dates in every quarter.. I sure would like to get the number of logging visits down to just twice a year instead of four times a year. Maybe slide G-23RD forward from June to March and G-11 forward from December to September. This way only two wells get off the AA anniversary date cycle and we'll have three wells due for temp surveys each visit. G-11 - AA signed 12f15/05 -last compliance temp survey 6;25107. Would like to slide to 6109 temp survey to 09f09 for efficiency, G-22 - AA signed 9/14/05 -last cornpiiance temp survey 4f26107. Would like to slide 4f09 temp survey to 9f09 for the AA date reason. G-23RD - AA signed 6130105 -last compliance temp survey 4/19/07. Would Tike to slide 4109 temp survey to 3109 for efficiency. G-27 - AA signed 3!29;05 -last compliance temp survey 9/21;06. Would like to slide 9r"08 temp survey to 3/09 for the AA date reason. G-29RD - AA signed 9;23105 -last compliance temp survey 6/24!07. Would like to slide 6109 temp survey to 9109 for AA date reason. G-40 - AA signed 3!29f05 -last compliance temp survey 9/21f06. Would like to slide 9108 temp survey to 3109 for AA date reason. I hope there aren't any more hiding out there. Surely next year I'll find one or two, but for now this list looks like all of them. Thanks again for your consideration Jim. Call me if you want to discuss some more. Larry 263-7661 12/26/2007 --, 2-Year Temperature Survey Timing Requirements Granite Point Field and Trading Bay Unit Administrative Approvals for these wells did not include specific anniversary dates for determining when to perform compliance temperature surveys (alternate mechanical Background Info: integrity determinations in lieu of MITs). Clarification was requested by Chevron (L. Greenstein; 907-263-7661) on 12/26/2007. The following table summarizes admin approval info, anniversary date options, and the Commission's decision. Well PTD AA Anniversary Date AA Date Last Surve GP State An-19 168-006 6.008 3/29/2005 10/3/2006 GP State An-21 176-049 6.009 3/29/2005 10/4/2006 TBU G-11 168-043 5.009 12/15/2005 6/25/2007 TBU G-22 175-016 5.006 9/14/2005 4/26/2007 TBU G-23RD 179-014 5.004 6/30/2005 4/19/2007 TBU G-27 178-070 5.003 3/29/2005 9/21/2006 TBU G-29RD 192-052 5.007 9/23/2005 6/24/2007 TBU G-40 190-003 5.002 3/29/2005 9/20/2006 TBU K-11 168-083 5.011 2/6/2006 12/11/2007 TBU K-24RD2 201-141 5.010 2/6/2006 12/21/2007 GP State An Granite Point Field, Anna Platform TBU G Trading Bay Unit, Grayling Platform TBU K Trading Bay Unit, King Salmon Platform AA Administrative Approval (AIO 5 and AIO 6, Rule 9) Options Next Temp Survey Due, Based on AA Date1 AA Date2 Last Survey 3/29/2007 3/29/2009 10/3/2008 3/29/2007 3/29/2009 10/4/2008 12/15/2007 12/15/2009 6!25/2009 9/14/2007 9/14/2009 4/26/2009 6/30/2007 6/30/2009 4/19/2009 3/29/2007 3/29/2009 9/21 /2008 9/23/2007 9/23/2009 6/24/2009 3/29/2007 3/29/2009 9/20/2008 2/6/2008 2/6/2010 12/11/2009 2/6/2008 2/6/2010 12/21/2009 last update: 12/26/2007 Next Survey Due (Chevron Proposed) NexfSurvey Due (AOGCC) Which Option? 3/29/2009 3/29/2009 AA Date 3/29/2009 3129/2009. AA Date 9/30/2009 12/45/2009 AA Date 9/30/2009 9/14/2009 AA Date 3/30/2009 6/30/2009 AA Date 3/30/2009 3/29/2009 AA Date 9/30/2009 9123!2009 AA Date 3/30/2009 3/28/2009 AA Date 2/28/2010 2!6!2010 AA Date 2/28/2010 216/2010 AA Date • • ~18 . . AOGCC Memorandum Date: August 9, 2007 To: AI06 tß( 1 (07 From: Jim Regg, Petroleum Engineer 'K&f! Subject: Fluid Injection for EOR Chevron notified the Commission by email dated August 8, 2007 of recently completed testing ofthe C-pipeline connected to Dillon Platform. Testing generated 50 barrels of used Cook Inlet seawater with minor amounts of residual fluids from the pipeline. Chevron's notice requested concurrence that the resultant nonhazardous fluid could be injected for EOR purposes at the Granite Point field Anna Platform under Area Injection Order No.6. Attached concurrence was sent to Chevron (Jean Bodeau and Jeff Smith). Supporting this decision are the following: pipeline is non-transportation; fluids could be injected at Dillon platform under previously approved AIO 8.2; an insufficient volume was generated to justify a mechanical integrity test prior to reinitiating injection at Dillon platform; resulting fluids are non-hazardous; AIO 6 allows the injection of non-hazardous fluids for enhanced recovery operations. Attachment Request for confirmation of injectio.temination - Anna . Page I of2 Regg, James B (DOA) From: Sent: To: Cc: Regg, James B (DOA) Thursday, August 09, 2007 10:52 AM 'Bodeau, Jean' SMITH, JEFFREY A 'Kè'11 q;{q(?£ifl Subject: RE: Request for confirmation of injection detemination - Anna This is within the scope of the fluids authorized for EOR injection under AIO 6. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: Bodeau, Jean [mailto:BodeauJ@chevron.com] Sent: Wednesday, August 08,20074:50 PM To: Regg, James B (DDA) Cc: SMITH, JEFFREY A Subject: Request for confirmation of injection detemination - Anna Dear Mr. Regg, A recent pressure test of the C-Pipeline which is connected to the Dillon Platform resulted in approximately 50 barrels of essentially clean Cook Inlet seawater - a Class /I non-hazardous fluid. We would like to take this water to the Anna Platform to utilize in the EOR system by injection into in one of the Class /I wells authorized under AIO #6. Both our reservoir engineer, Hal Martin, and myself believe that this fluid is clearly compatible with the reservoir and that therefore it is acceptable for injection. However, I did want to contact you and confirm that determination with AOGCC. I spoke with you a couple of months ago about disposing fluids in the approved disposal wells on the Dillon Platform. However, less fluid was produced than was originally anticipated, as the scope of this summer's project was down-sized. Hence, it was impractical to perform an MIT on the Dillon Platform to accommodate this small volume. The fluid is contained in 3 water-tight tanks, and will be transferred utilizing Union Oil Company of California's standard transportation systems, which include our spill prevention and response protocols. Thank you in advance for your attention and response to this issue. Please email me or call me at the numbers below if you have any questions or concerns. Regards, Jean Jean M. Bodeau. CPG Hydrogeologist Waste Specialist 8/9/2007 Request for confirmation of injectio.temination - Anna Chevron North America . Page 2 of2 Exploration and Production P.O. Box 196247 Anchorage, AK 99519-6247 Tel. (907) 263-7308 Fax (907) 263-7321 Mobile (907) 360-7929 ßººªª~¡J@Çt!e\lTºn.çºm 8/9/2007 I i iEW17 xe: Anna well No..) MI t 410 tv [ No. 5 MIT i_regg ad in.state.ak.us> 13:30.-52 -0800 Based on a review of TIO pressure data for Anna 5 provided monthly, and the findings noted in Administrative Approval 6.003 dated March 29, 2005, the well continues to demonstrate acceptable mechanical integrity. We agree that delaying the temperature survey as requested does not represent an increased risk of loss of mechanical integrity nor does it introduce an increased risk of fluid movement. Your request to delay the temp survey (required every 2 years) on Anna 5 until May 2007 is acceptable. Jim Regg AOGCC Martin, J. Hal wrote: Jim, Larry informed me that you and he noted that Anna Well No. 5 is due for it's biennial MIT (temp survey) this month (March). In an effort to consolidate our annual MIT work requirements on the Anna Platform, I'd like to request that Chevron be allowed to move the temp survey date required for Anna Well No. 5 this year to May to coincide with all the other MITs to be done on Anna this year. Chevron currently has plans to begin moving a rig on to the Anna beginning sometime in June for drilling work scheduled late this year. Therefore, our plan is to move the MITs up to May. We would like to do Anna Well No. 5 at the same time. Anna Well No. 5 will continued to be monitored and does not indicate any anomalous behavior. Chevron does not believe that delaying this temp survey approximately 2 months introduces significant risk in our expectation that the welibore is containing fluids as required. I will be out of the office until 3/26. Please contact Larry Greenstein if you have any questions or let him know if this is acceptable to the AOGCC. Thanx, Yfa[Wartin Optimization Engr Chevron 909 W. 9th Avenue Anchorage, AK 99501 Tel 907 263 7675 (4 2- b (A, -- 3/20/2007 1:32 PM Larry P. Greenstein Prodction Technician Unocal Alaska Union Oil Company of California 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7661; Fax (907) 263-7847 UNOCAL19 Date: February 25, 2005 Commission Chair John Norman Alaska Oil and Gas Conservation Commission 333 W. 7 th Ave., Suite #100 Anchorage, AK 99501-3539 Attn: Tom Maunder Administrative Approval Request Well No. An-21 Injector Anna Platform Granite Point Field Dear Chair Norman, Unocal requests administrative approval under Area Injection Order 6, Rule 9 for the continuation of injection of non -hazardous Class 11 fluids for the Anna Platform Well No. An-21 Injector (Permit # 176-049) in Granite Point Field. To support this request, Unocal submits the following information and documentation: 1. Schematic (attached). 2. Temperature survey comparison plot (attached). 3. Maximum allowable injection pressure calculation in graphical form (attached). 4. Brief/relevant well history (below and attached). This well was drilled and completed as a producer in September of 1976. Per the attached well history, it was converted to a waterflood injector and has been injecting with a variance since June of 2001. Injection was authorized after a review of the well's construction and demonstration of integrity via temperature logs and step rate injection tests according to a procedure titled "Procedures to Obtain Variances on Packerless Wells (Version 4) dated February 9, 2000". This procedure was cooperatively developed by Unocal and the Commission in accord with 20 ACC 25.450(a), that allows the Commission to authorize less stringent well operating and construction requirements where injection does not occur into, through or above fresh water. In addition, please note that Granite Point Field has an auquifer exemption per EPA 40 CFR 147.102 (b)(2)(i). The temperature survey run on 6/12/2004 matches the last survey run on 11/25/2001 in character showing no cooling anomalies above the packer. This indicates that injection is occurring only 0 into the Tyonek C-Sands. Also, the plotted daily monitoring, which is reported monthly, hasn't shown any unexplainable rate or pressure responses from this well. Unocal will continue to monitor and record daily injection rates and tubing and casing pressures on the well and provide a report to the AOGCC on a monthly basis. A temperature survey will be run every two years to insure the injected water is contained within the completion interval. Thank you for your consideration and if you have any questions regarding this, please contact me at 263-7661 or Hal Martin at 263-7675. Sincerely, Larry P. Grtenstein cc: MIT book Well File • • • Anna Well No. 21 Actual Coil Tubing Jet Pump Completion as Run 2/16/99 UNOCA� 76 CASING AND TUBING DETAIL RKB to TBG Head = 33' SIZE WT GRADE CONN 1D TOP BTM. 20" 94 Surface 610' 13-3/8" 54.5/68 J-55 12.615 Surface 2,979' j 9-5/8" 40 /47 N-80 & S-95 8.5" restr ID a 8972'- Surface 10573' 9005' 2 Packer �!! Tubing • • Holes • 8757• 8757'- m e n Tubing Jet Cut @ 8829' Live Perf gun left at 9070' Fill tagged @ 9,560' 4/ 1 /96 4 5 6 7 8 Jt 9 Tubing: LS 3-1/2" 9.2 L-80 BTC SC 2.992 Surface 9569' SS 3-1/2" 9.2 L-80 BTC SC 2.992 Surface 8785' SS 2-3/8" 4.6 1.995 8785' 8796' 109" wall HS-KO Coil Tbg 1,782` Sui!a'�e 8h98, O. Deuth ID OD JEWELRY DETAIL Item 1 35' Dual Tubing Hanger 2 8799' 2.992 3.5 3-1/2" BTC tbg 3 8799' 2.687 3.865 Kobe 3" Cavity, Type B S/N L-236 4 8824' 2.992 3.5 3-1/2" BTC tbg 5 8979' Blast Joints, 8979'-9067' 6 Live perf gun fish left in hole 7 3-1/2" BTC tubing 8 9569' 3-1/2" Muleshoe 9 9600' Baker DB packer Short String B 8785' 2.992 3.5 3-1/2" BTC tubing bottom C 8785' 1.995 2.375 2-3/8" pup with XO to 3-1/2" in top of cavity D 8688' 1.300 2.75" Baker seal bore extension with 10' seal assy 8697' 1.440 2.20" Baker K-22 anchor E 8698' 1.375 2.765 Baker "FA -I" packer with 10' seal bore extension on top Tops Actual 2" Coil Tubing (.109" wall) in Long String F 8732' 1.625 2.27" 1-1/2" jet pump cavity with standing valve 8737' 1.300 2.75" Baker seal bore extension with 10' seal assy 8747' 1.440 2.20" Baker K-22 anchor G 8747' 1.375 2.765 Baker -FA- I" packer with 10' seal bore extension on top E-line set packer at 8739' ELM PERFORATION HISTORY Interval Accum. Date Zone Top Btm Amt spf Comments 5/24/78 8,862' 8,865' 3' 3 Squeezed 9/76,6/96 C-5 8,932' 8,995' 63' 8-12 9/76,6/96 C-4 9,005' 9,085' 80' 12-18 4/2/96 C-7 9,348' 9,374' 26, 14 4/2/96 C-7 9,430' 9,486' 56' 18 9/76,4/96 C-7 9,534' 9,560' 26' 6-14 PBTD = 9735' TD = 10,575' MAX HOLE ANGLE = 25° 9800' Anna 21 2-16-99 final dwg.doc 02/17/05 r #n-21 Temperature Survee 11 /25/01 vs 6/12/04 Pressure (psia) 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 0 1000 2000 3000 r d 4000 t p. 5000 6000 7000 8000 9000 50 Pressure -Temperature Profile 1. Going in hole 2. Shut -In 60 70 80 90 100 110 120 130 140 150 160 Temperature (Deg. F) —6-12-04 Pressure — Perfs 13 3/8" 9 5/8" —TBG 6-12-04 Temp 11-25-01 Temp 0:\OOE\OOEFields\GPF\Anna\Wells\An-21\Surveys\Temperature\An-21 Temp Survey 11-25-01 & 6-12-04.x1s NOTE TO FILE In Re. Anna 21 (18742 #21)...PTD (176-049) Unocal has applied to convert this production well to an injector. Since the well does not have a packer in it, MI demonstration must be by other means, The well was drilled in summer 1976. There is no information in the well file regarding the cementing operation, on the 9-5/8" production casing. According to the well history, the 9-518" casing was run and landed on July 26 —27, 1978. The completion was run and the well perforated. Unfortunately all the well would make was water and the initial completion was puffed on August 20. A DST was attempted followed by a series of squeezes. It is noted that circulation could be established via the perforations in the well. On September 1, 1976 the wellbore was tested above a BP at 9575' to 1500 psi. Subsequent higher -pressure tests bled off to 1700 psi. Using an RTTS (or equivalent), the annulus from 8700' to surface was successfully tested to 2050 psi. On September 3 a CBL was run from 10277-7200. This CBL is not available in our files. The report notes "good bond across the squeezed perforations. The well was then perforated in 5 intervals and put on production pumping 448 bopd, 570 bwpd. The well was worked over in May 1978 to shut off water production. Following a series of DSTs, squeeze perforations were shot about 65' above the upper production zone. 2 75 ex squeezes were performed May 23 —24, 1978. Little information is in the file on these operations, although the noted production rate before the squeezes was 174 bopd with 522 bwpd and the rate after was 362 bopd and 34 bwpd. Following the squeeze, a CBL was run, The CBL is riot available in AOGCC files. The well was worked over again in May 1985 to replace the pump BHA. No other work was done at that time. The latest work on the well was done in January 1999. At that time a coiled tubing jet pump was run in the long string and the well place back on production. Unocal has provided Xerox copies of the both logs mentioned above. In the 1976 log, low amplitude response begins at about 8930' or at the top of the perforations. The response of the 1978 log is improved with low amplitude response beginning at about 8800'. M1 is indicated. Subject to Unocal complying with the requirements of the attached "Procedures to Obtain Variances on Packerfess dells (version 4) February 9 2000", l recommend ap royal to convert Anna 21 (176-049) as proposed, Tom Maunder Petroleum Engineer �-� O a 1,000 2,000 3,000 111 5,000 7,000 111 10,000 11,000 An-21 Maximum Allowable Operating Pressure Graph Pressure (PSI) 0 1,000 2,000 3,000 4,000 5,000 6,000 7,000 8,000 9,000 10,000 Run da e : 2/23/2005 10:04:23 AM Safe operating pressures (surface gauge) Production = 4021 psi. @ 70% nominal casing yield Intermediate = 784 psi. limited by fracture pressure at shoe Surface = 162 psi. limited by fracture pressure at shoe Current Pressure readings CSGPRESS2 = 2750 CSGPRESS3 = 356 'atilliq Lou ails Production Se ment = 9.625" 43.5#, S-95 internal yield = 7510 psi from 10400' to 10573' MD' Production SeVent = 9.625" 40#, N-80 internal yield = 5745 psi from 9376' to 10573' MD' Production Segill = 9.625" 40#, S-95 internal yield = 6822 psi from 6035' to 10573' MD' Production Seg nt = 9.625" 43.5#, S-95 internal yield = 7510 psi from 7222' to 10573' MD' Pr duction Se m nt = 9.625" 47# S-95 internal yield_= 8150 psi from 9296' to 10573' MID'_ _ Pr duction Shoe 9.625" #, internal yield = N/A psi from 10572' to 10573' MD' Int rmediate Segm nt = 13.375" 68#, K-55 internal yield = 3450 psi from 2900' to 2979' MD' Intermediate Segm t = 13.375" 54.5#, K-55 internal yield = 2730 psi from 1546' to 2979' MD' Intermediate Segme t = 13.375" 61#, K-55 internal yield = 3090 psi from 1949' to 2979' MD' Intermediate Segmen = 13.375" 68.5#, J-55 internal yield = 3450 psi from 2578' to 2979' MD' Intermediate Shoe = 1 .375" #, internal yield = N/A psi from 2978' to 2979' MD' Surface Casing = 20" #, H-40 internal yield = 1530 psi from 41' to 610' MD' Surface Shoe = 20" #, i ternal yield = N/A psi from 609' to 610' MD' sing Parameter s\5% ssumpttons Pr duction casing yield @% of nominal with fluid weight of 0.433 #/ft In rmediate casing yield of nominal with fluid weight of 0.433 #/ft Su ace casing yield @ 4f nominal with fluid weight of 0.433 #/ft Fn cture gradient = 0.7 #/ 507332029100 1760490 An-21 Casing Pressurk Analysis @70 percent 20050223.xls Variable Definitions RP = Reservoir Pressure CYP = Casing Yield Pressure SF = Safety Factor (70% for working annulus, 45° for outer annuli) HP = Internal Fluid Hydraulic Pressure MASP = Maximum allowable surface working pressure Graphical calculation method Inside pressure potential == Outside pressure containment Therefore HP + MASP = RP + (CYP * SF) Rearranging MASP = RP + (CYP * SF) - HP Internal Fluid Hydraulic Pressure Formation facture pressure @ 0.7 #/ft Production CYP @ 70% Outside Containment for Production casing MASP (production casing) Intermediate CYP @ 45% Outside Containment for Intermediate casing MASP (Intermediate casing) Surface CYP @ 45% Outside Containment for Surface casing MASP (Surface casing) ♦ Current Pressure Readings Disclaimers (fine print) Casing yield values taken rom published sources where specifications are known. If specifications are unknown then values are the lowest value of probable materials. TVD interpolated from Openworks directional surveys. Values should be +/- 25 ft @ 10,000 ft. MD Graphical Casing Pressure Analysis ver 22x.xls #15 Unocal Alaska Union Oil Company of California 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7661; Fax (907) 263-7847 UNOCAL18 Larry P. Greenstein Proddion Technician Date: February 25, 2005 Commission Chair John Norman Alaska Oil and Gas Conservation Commission 333 W. 7 th Ave., Suite #100 Anchorage, AK 99501-3539 Attn: Tom Maunder Administrative Approval Request Well No. An-19 Injector Anna Platform Granite Point Field Dear Chair Norman, Unocal requests administrative approval under Area Injection Order 6, Rule 9 for the continuation of injection of non -hazardous Class 11 fluids for the Anna Platform Well No. An-1 9 Injector (Permit # 168-006) in Granite Point Field. To support this request, Unocal submits the following information and documentation: 1. Schematic (attached). 2. Temperature survey comparison plot (attached). 3. Maximum allowable injection pressure calculation in graphical form (attached). 4. Brief/relevant well history (below and attached). This well was drilled and completed as a producer in April of 1968. Per the attached well history, it was converted to a waterflood injector in October of 1971 and has been injecting with a variance since October of 1998. Injection was authorized after a review of the well's construction and demonstration of integrity via temperature logs and step rate injection tests according to a procedure titled "Procedures to Obtain Variances on Packerless Wells (Version 4) dated February 9, 2000". This procedure was cooperatively developed by Unocal and the Commission in accord with 20 ACC 25.450(a), that allows the Commission to authorize less stringent well operating and construction requirements where injection does not occur into, through or above fresh water. In addition, please note that Granite Point Field has an auquifer exemption per EPA 40 CFR 147.102 (b)(2)(i). The temperature survey run on 6/13/2004 matches the last survey run on 11/24/2002 in character showing no cooling anomalies above the packer. This indicates that injection is occurring only into the Tyonek C-Sands. Also, the plotted daily monitoring, which is reported monthly, hasn't shown any unexplainable rate or pressure responses from this well. Unocal will continue to monitor and record daily injection rates and tubing and casing pressures on the well and provide a report to the AOGCC on a monthly basis. A temperature survey will be run every two years to insure the injected water is contained within the completion interval. Thank you for your consideration and if you have any questions regarding this, please contact me at 263-7661 or Hal Martin at 263-7675. Sincerely, Larry P. G enstein cc: MIT book Well File I GRANITE POINT ADL 18742 WELL NO. '19 MIDDLE KENAI SANDS PLATFORM ANNA 4 E91hant Date-, Spw Date: 01/27/88 Surface Location: L" 3, got I Platform Anne 534@ M 67V FVL� 5" 12. TIM RIZV. SAO. Subsurf000 Locatlon., toir m 93w im, Sec. mnolt m2w, Sm. sevation: 105, K"SL M. 100W Tw. POD: 982W rvv: toor Castnip W'. 03 end 94f Coming met at 604'ift 12M sx. ownent 13 Wr. 34.3f Coming met at 1341- with 1100 m ownent 9 Wr, 40 and 43.5f "3 and N-90 Coming set at 8324' *M 473 wL ownert 7-, 32f P—I 10 Lkw set at @=-1111 8V UM 280 mg. ownent 7". 350 S-93 Uner sot at 8183-999W wM 450 sm. consent PaIrforallorw C-4.1 2370-939W C—L, 9440-94700 81593-86131 2310-934W C-3: 8093-871W C-9: 2070-08W $780-891W U30-88OW C-7: 900-1113W 9183-0243' 92&5-931W kad potenvol: 2006 MM at 4322 pal Initlol Stinvuladonj None ltawv* Dats, Cored h AN Von: Hona wk"We and Reaultst me" Log Inweefty. IM OFUL and 1340-03111 IM M and 8325-1000(r an to 993W am 1500-0930, Completion Record Z'"" 1. Cameron IW Singfe Tubing Hanipw 33* 2. 3 1/2!' NO and 3 IIV Buttress XO W 3. 3 Vr Suttre s TuMng WAB Collary $273' 4. 3 1/r Butt= and 2 7/11" Buttress XO 827f 3. 11"1 Loader 8273' 0. Soul Asserntity 15259, 7. Muleshoe $29(r (As run 12/17/54) I I - , 85 & 94f CSA $04' 13 W, 34.31 3 CSA 1341' top of 7- 32 Lber at 6301- :ported Coming Top of 7', 350 Lbw at Sias* Taggail FIN 0 ........ 91W 12/19A4 P&M 9820' 41; TD I 000cr L9 i�r. 4o at 4Uf CSA WaV 957& 1111131 0 eflow w 0 0r 1000 2000 3000 4000 d d 5000 t Q 01 cl 6000 7000 8000 9000 10000 1.- 40 0I-19 Temperature Surveo 11 /24/02 vs 6/13/04 Pressure (psia) 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 Pressure -Temperature Profile . Going in Node 2. Shut -In 50 60 70 80 90 100 110 120 130 140 150 160 170 Temperature (Deg. F) 6-13-04 Pressure — Perfs — 13 3/8" 9 5/8" 7" TBG 6-13-04 Temperature 11-24-02 Temperature O:\OOE\OOEFields\GPFWnna\Wells\An-191nj\Surveys\Temperature\AN-19 Temp Survey 11-24-02 & 6-13-04.xls 0 0 NOTE TO FILE WMNED APR 2 3 2003 Granite Point Field Anna 19 (19-42) PTID 168-006 303-043 Unocal has submitted a temperature survey to demonstrate mechanical integrity for this Injection well and has requested to keep the well in service with known tubing x annulus (T x IA) communication. This note evaluates Unocal's request and recommends approval of it. This well has been in service since late 1998. The well had been shut In since mid 1995 prior to being reactivated. The well has communication between the tubing and IA. Unocal has been providing rate and pressure infbirmation since the well was returned to service. Examination of the information shows the tubing and casing pressures tracking as expected. There is no spike in the !njoe-tion rate that would indicate development of an external leak. There Is a record In the MIT binder that Blair examined the bond log an 12130186 and concluded that MI was indicated. In August 1998, Unocal performed a baseline temperature survey. They have performed subsequent surveys in October 2000 and in November 2002. The subsequent profiles are cooler than the baseline, which would be expected Injecting cold Inlet water. It is interesting to note that the most recent temperature pass Is warmer than the one in 2000 at the some time of year. This difference is due to the relative volume that was Injected between surveys. Between October 1998 and October 2000 nearly 190,000 bble, of water were injected. In the following 25 months, only 84,000 bbls has been Injected. A now temperature equilibrium has been established relative to the reduced Injecilon rate. There are no thermal anomalies noted In the presentation. Area Injection Order 6 allows Injection into the Northern Portion of Granite Point Field, developed by the Anna and Bruce Platforms. The OHL of well An-26 Is located In the covered area. The portion of aquifers beneath Cook Inlet described by a 1/4 mile area beyond and lying directly below the Middle Ground Shoal Field are exempted for Class 11 injection activities by 40 CFR 147.102(b)(2)(1) and 20 AAC 25.440(c). Granting Unocal's request will not endanger any fresh water. I recommend acceptance of the submitted temperature irdormation. A fbllow up survey should be required in 2 years and the monthly pressure and rate information should oont1nue to be submitted. Tom Maunder, PE Sr. Petroleum Engineer April 11, 2003 MALTIC File Roviews\030411-GP-19-42.doc An-19 Maximum Allowable Operating PresSUre Graph 1❑ 1,000 2,000 3,000 111 t� H 5,000 CL m, 0 7,000 111 10,000 Pressure (PSI) 0 1,000 2,000 3,000 4,000 5,000 6,000 7,000 8,000 9,000 10,000 Run date : 2V23/2005 9:42:28 AM Safe operatin ressures (surface gauge) Production = 4021 s @ 70% nominal casing yield Intermediate = 40 si limited by fracture pressure at shoe Surface = 161 psi. Nit d by fracture pressure at shoe Current Pressf re r%adings TBGPRESS = 456 CSGPRESS3 = 10 CSGPRESS5 = 0 asing Details ner Segment = 7" 32#, P-110 internal yield = 11640 psi from 8117'to 9996' MD' L er Hanger = 7" #, internal yield = N/A psi from 9973' to 9996' MD' Li er Segment = 7" 35#, S-95 internal yield = 11210 psi from 9077' to 9996' MD' Lin r Joint = 7" 35#, S-95 internal yield = 11210 psi from 9954' to 9996' MD' Lin Segment = 7" 35#, S-95 internal yield = 11210 psi from 9221' to 9996' MD' Line FJcollar = �" #, intarnal_yield = N/A psi from 9995' to 9996' Mn' Liner egment = 7" 35#, S-95 internal yield = 11210 psi from 9948' to 9996' MD' Liner loatshoe = 7" #, internal yield = N/A psi from 9994' to 9996' MD' Produ ion Segment = 9.625" 47#, S-95 internal yield = 8150 psi from 7589' to 8526' MD' Produc on Travel Joint = 9.625" #, internal yield = N/A psi from 8520' to 8526' MD' Product n Segment = 9.625" 40#, N-80 internal yield = 5745 psi from 4906' to 8526' MD' Producti n Segment = 9.625" 40#, S-95 internal yield = 6822 psi from 6510' to 8526' MD' Productio Segment = 9.625" 43.5#, S-95 internal yield = 7510 psi from 7865' to 8526' MD' Hole = 9. 5" #, internal yield = N/A psi from 8525' to 8526' MD' Production egment = 9.625" 43.5#, S-95 internal yield = 7510 psi from 7275' to 8526' MD' Production hoe = 9.625" #, internal yield = N/A psi from 8524' to 8526' MD' Intermediat casing = 13.375" 54.5#, J-55 internal yield = 2734 psi from 40' to 1542' MD' Intermediate hoe = 13.375" #, internal yield = N/A psi from 1541' to 1542' MD' Surface Casi = 20" 94#, H-40 internal yield = 1530 psi from 42' to 608' MD' Surface Shoe 20" #, internal yield = N/A psi from 607' to 608' MD' Casing Para eters / Assumptions Production casin yield @ 70% of nominal with fluid weight of 0.433 #/ft Intermediate cask yield @ 45% of nominal with fluid weight of 0.433 #/ft Surface casing yieXJ @ 45% of nominal with fluid weight of 0.433 #/ft Fracture gradient = .7 #/ft API :5073320081 Permit : 1680060 An-19 CasiM7f4rTTmr-Valysis @70 percent 20050223.xls Variable Definitions RP = Reservoir Pressure CYP = Casing Yield Pressure SF = Safety Factor (70% for working annulus; 45% for outer annuli) HP = Internal Fluid Hydraulic Pressure MASP = Maximum allowable surface working pressure Graphical calculation method Inside pressure potential == Outside pressure containment Therefore HP + MASP = RP + (CYP * SF) Rearranging MASP = RP + (CYP * SF) - HP Internal Fluid Hydraulic Pressure Formation facture pressure @ 0.7 #/ft Production CYP @ 70% Outside Containment for Production casing MASP (production casing) Intermediate CYP @ 45% Outside Containment for Intermediate casing MASP (Intermediate casing) Surface CYP @ 45% Outside Containment for Surface casing MASP (Surface casing) Current Pressure Readings Disclaimers (fine print) Casing yield values taken from published sources where specifications are known. If specifications are unknown then values are the lowest value of probable materials. TVD interpolated from Openworks directional surveys. Values should be +/- 25 ft @ 10,000 ft. MD Graphical Casing Pressure Analysis ver 22x.xls #14 Larry P. Greenstein Prodction Technician Unocal Alaska 0 Union Oil Company of California 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7661; Fax (907) 263-7847 UNOCAL9 Date: February 17, 2005 Commission Chair John Norman Alaska Oil and Gas Conservation Commission 333 W. 7t'Ave., Suite #100 Anchorage, AK 99501-3539 Attn: Tom Maunder Administrative Approval Request Well No. An-38 Injector Anna Platform Granite Point Field Dear Chair Norman, Unocal requests administrative approval under Area Injection Order 6, Rule 9 for the continuation of injection of non -hazardous Class 11 fluids for the Anna Platform Well No. An-38 Injector (Permit # 188-034) in Granite Point Field. To support this request, Unocal submits the following information and documentation: 1. Schematic (attached). 2. Temperature survey comparison plot (attached). 3. Maximum allowable injection pressure calculation in graphical form (attached). 4. Brief/relevant well history (below and attached). This well was drilled as a producer in June of 1988. Per the attached well history, it was converted to a waterflood injector and has been injecting with a variance since June of 2001. Injection was authorized after a review of the well's construction and demonstration of integrity via temperature logs and step rate injection tests according to a procedure titled "Procedures to Obtain Variances on Packerless Wells (Version 4) dated February 9, 2000". This procedure was cooperatively developed by Unocal and the Commission in accord with 20 ACC 25.450(a), that allows the Commission to authorize less stringent well operating and construction requirements where injection does not occur into, through or above fresh water. In addition, please note that Granite Point Field has an auquifer exemption per EPA 40 CFR 147.102 (b)(2)(i). The temperature survey run on 5/30/2003 matches the last survey run on 11/24/2001 in character showing no cooling anomalies above the packer. This indicates that injection is occurring only into the Tyonek C-Sands. Also, the plotted daily monitoring, which is reported monthly, hasn't shown any unexplainable rate or pressure responses from this well. Unocal will continue to monitor and record daily injection rates and tubing and casing pressures on the well and provide a report to the AOGCC on a monthly basis. A temperature survey will be run every two years to insure the injected water is contained within the completion interval. Thank you for your consideration and if you have any questions regarding this, please contact me at 263-7661 or Hal Martin at 263-7675. Sincerely, ilu Larry P. enstein cc: Dave Cole Hal Martin MIT book Well File *w Ddw swlvoa Leadmm t lod Aabwallab kisd somukam Owed tie�,rar t Lot MaMreda 11t742-= GRANITE POINT FIELD GP ADL 18742 Well No. 38 LOWER KENAI SANDS PLATFORM ANNA 04--24- U Lp 2 SW 6, 0 NWam Anw 10l1' 10!-Ms� 114M 114W 20- 133#. Mt vt aw RAM so M* m .viM oi�M srt at 30W 2480 SO Gnat a-M I � -11 G-6t 10663-IOVV C-71 1010 -109W 11013-11031' C -St 11224--112W 11273-112M e-14- M "3 BVD x 84 NM x 340 MCFD NONE NONIE NOW "m _ 0i-04--0 � Ohm* 0"--10' 2:14-a m -7Ct .ma!C w CWL FEW�-sm Cs--13-418 AM 113s0-1000a' 06-13-48 a d -6q 1 f 73-97W 06--13--ed 0^ »Jwhoe Le" !Ubw to -mv x 2 7 0V IRA! %pawwwwwww�41q* Shwt A. 3 ur WD soft 0.z# A sL X* 2 rV e>+D x 3 vz C. pm. 2 aver aNa 4. saear (po nen0-itF-es� T Top of Lkw • sat 0 11144.31, pi f 47?1�0 1097-0400 00483--10 ier 0133--1 i 1• 12Z4-112W 1273-1126.f' • C 40 50 60 70 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 11000 11500 Anna Platform AN 38 Temp Survey 5/30/03 MIT vs 11/24/01 MIT TEMPERATURE(DEG. F) 80 90 100 110 120 130 140 150 160 170 A 4. f!' `y CCL 5/30/03 TEMP RIH, SI=12HRS 11/24/01 Temp RIH 5/30/03 PRES RIH, SI=12HRS j; I. jF. t I> ; PKR @ 9707' PERFORATIONS C-5 10397-10459 C-5 10483-10578 C-6 10663-10675 C-7 10918-10962 C-7 11013-11031 C-8 11224-11262 C-8 11275-11295 PBTD=11400' BHP=4912.4 PSIG 12000 - -1000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 PRESSURE(PSIG) 0 0 NOTE TO FILE In Ro: Anna 3B (18742#38)...PTa (188-034) Unocal has applied to convert this production well to an injector. Since the well does not have a packer in it, MI demonstration must be by other means. The well was drilled beginning in late April, 1988 and completed in late June, 1988 There is very little information available in the AOGCC well file. It does not appear that any of the original perforations have been altered since the 'original completion. A note in the file does indicate that Unocal employed a snubbing unit on the well in 1997 No information on that work is in the file. Unocal has provided a copy of the CBI run June 14, 1988. A copy of the log is not available in the AOGCC well files. The quality of the provided copy is not great. Two passes are presented one at 0 psi and the other with 1000 psi. A cement top is shown at about 10310' in each presentation, approximately 90' above the top perforation. The nonpressured:pass indicates the presence of a microannufus. The initial wave arrivals are pretty consistent throughout the log run. When pressure is applied, there is improvement in the attenuation. The available information indicates there is cement present beginning about 90' above the top perforation. MI is indicated. The MIT demonstration methods and subsequent monitoring program will identify any deficiencies in isolation. Subject to Unocal complying with the requirements of the attached "Procedures to Obtain Variances on Packerless Wells (version 4) February 9 2000 1 recommend approval to convert Anna 38 (188-034) as proposed, t.0" wcx�-� Tom Maunder kO Petroleum Engineer It oz J } 1' lee r , W 1,000 2,000 3,000 111 5,000 7,000 111 10,000 11,000 12,000 An-38 Maximum Allowable Operating Pressure Graph Pressure (PSI) 0 1,000 2,000 3,000 4,000 5,000 6,000 7,000 8,000 9,000 10,000 R date : 2/16/2005 10:56:54 AM S operating pressures (surface gauge) Pr u ion = 4809 psi. @ 70% nominal casing yield Int m iate = 887 psi. limited by fracture pressure at shoe Rid 164 psi. limited by fracture pressure at shoe C ren ressure readincis TB 7PRES = 2289 CS PRES = 2300 CS PRESS = 375 CS PRESS 160 C ing Det 'Is Liner Hanger = #, internal yield = N/A psi from 11450' to 11453' MD' Liner Reentry Joi = 7" #, internal yield = N/A psi from 11446' to 11453' MD' _-- — Gner Casio #, S-95-internal yield 11 —11453'-MD'— — 9 — y psi rom 9874' to Liner Flcollar = 7" internal yield = N/A psi from 11451' to 11453' MD' Liner Casing = 7" 3 S-95 internal yield = 11210 psi from 11414' to 11453' MD' Liner Floatshoe = 7" internal yield = N/A psi from 11451' to 11453' MD' Production Segment 9.625" 53.5#, N-80 internal yield = 7927 psi from 10057' to 10068' MD' Production Segment = .625" 47#, N-80 internal yield = 6870 psi from 3594' to 10068' MD' Production Segment = 625" 53.5#, N-80 internal yield = 7927 psi from 6520' to 10068' MD' Sh le = 9.625" #, intern yield = N/A psi from 10066' to 10068' MD' Int mediate Casing = 13. 75" 61# K-55 internal yield = 3090 Dsi from 38' to 3535' MD' IntIlmnediate Shoe = 13.3 " #, internal yield = N/A psi from 3534' to 3535' MD' Surface Casing = 20" 133#, -52 internal yield = 2840 psi from 42' to 620' MD' Surface Shoe = 20" #, inter I yield = N/A psi from 617' to 620' MD' Casing Parameters / A sumptions Production casing yield @ 700 of nominal with fluid weight of 0.433 #/ft Int mediate casing yield @ 45 of nominal with fluid weight of 0.433 #/ft Su ace casing yield @ 45% of n minal with fluid weight of 0.433 #/ft AP:507332039800 Per it : 1880340 An-38 Casing Pressure Anklysis @70 percent 20050216.xls Variable Definitions —RP —= Reservoir Pressure— CYP = Casing Yield Pressure SF = Safety Factor (70% for working annulus, 45% for outer annuli) HP = Internal Fluid Hydraulic Pressure 1 MASP = Maximum allowable surface working pressure Graphical calculation method Inside pressure potential == Outside pressure containment Therefore HP + MASP = RP + (CYP * SF) Rearranging MASP = RP + (CYP * SF) - HP Internal Fluid Hydraulic Pressure Formation facture pressure @ 0.7 #/ft Production CYP @ 70% Outside Containment for Production casing MASP (production casing) .1 11 Intermediate CYP @ 45% Outside Containment for Intermediate casing MASP (Intermediate casing) Surface CYP @ 45% Outside Containment for Surface casing MASP (Surface casing) ♦ Current Pressure Readings Disclaimers (fine sprint) Casing yield values taken rom published sources where specifications are known. If specifications are unknown then values are the lowest value of probable materials. TVD interpolated from Openworks directional surveys. Values should be +/- 25 ft @ 10,000 ft. MD Graphical Casing Pressure Analysis ver 22x.xls #13 Unocal Alaska 0 Union Oil Company of California 909 West 9h Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7661; Fax (907) 263-7847 UNOCALO Larry P. Greenstein Prociction Technician Date: February 16, 2005 Commission Chair John Norman Alaska Oil and Gas Conservation Commission 333 W. 7 th Ave., Suite #100 Anchorage, AK 99501-3539 Attn: Tom Maunder Administrative Approval Request Well No. An-32RD Injector Anna Platform Granite Point Field Dear Chair Norman, Unocal requests administrative approval under Area Injection Order 6, Rule 9 for the continuation of injection of non -hazardous Class If fluids for the Anna Platform Well No. An-32RD Injector (Permit # 187-063) in Granite Point Field. To support this request, Unocal submits the following information and documentation: 1 - Schematic (attached). 2. Temperature survey comparison plot (attached). 3. Maximum allowable injection pressure calculation in graphical form (attached). 4. Brief/relevant well history (below and attached). This well was redrilled as a producer in June of 1987. Per the attached well history, it was converted to a waterflood injector and has been injecting with a variance since November of 2001. Injection was authorized after a review of the well's construction and demonstration of integrity via temperature logs and step rate injection tests according to a procedure titled "Procedures to Obtain Variances on Packerless Wells (Version 4) dated February 9, 2000". This procedure was cooperatively developed by Unocal and the Commission in accord with 20 ACC 25.450(a), that allows the Commission to authorize less stringent well operating and construction requirements where injection does not occur into, through or above fresh water. In addition, please note that Granite Point Field has an auquifer exemption per EPA 40 CFR 147.102 (b)(2)(i). The temperature survey run on 5/30/2003 matches the last survey run on 2/14/2001 in character showing no cooling anomalies above the packer. This indicates that injection is occurring only 0 into the Tyonek C-Sands. Also, the plotted daily monitoring, which is reported monthly, hasn't shown any unexplainable rate or pressure responses from this well. Unocal will continue to monitor and record daily injection rates and tubing and casing pressures on the well and provide a report to the AOGCC on a monthly basis. A temperature survey will be run every two years to insure the injected water is contained within the completion interval. Thank you for your consideration and if you have any questions regarding this, please contact me at 263-7661 or Hal Martin at 263-7675. Sincerely, IkAA L v arry P. GIrenstein cc: Dave Cole Hal Martin MIT book Well File GRANITE POINT FIELD GP ADL 18742 Well No. 32RD LOWER KENAI SANDS PLATFORM ANNA sw Oda 9wf4mo OR mom toogam m- for xs-yx MW 1i1E110300' PeD: 11Ns' cubv ad .t am wAa so omt 13 3V.01. 00 ■ W 72 f. oubg so xt MV V 1d30as Qst an CMt caft me at � go bw 0940-1 r AW1wu.-W +Vam re 17, LkW 10I-1:ti00!' W300 So Okt pwfb1 V 0-21 10471-1o01Nt' C-�a tONp-101'7e' 0-71 11313-11360• 114000 11'.fOs-•1 Imy b 6d Psdntlo� bd 96mAeGm > 0w9d btrvda � now t� r,waeewyi 08- 30-w eoc FIALL 0-20 -07 CNL-= 13742- = Cwe, now Lw4 9bbv vqm s� 3' W Ile? as' a 0. %qx-o �. x�" x.-o 1 Pat rq* odw low shmt 1R:! Q 33 IM x zZ »" p�ltt r-0 E 2 . �a#x4 d1D�O (At nm&2W" cow Nab t"m 10-z)-w Ca. mo we VIM am l337' u7r+.rave % 30 # 0940--10770' 1 CIA 10143 OW 64' 10471,104M � °# i 1 j }l--12001P Anna Platform An-32RD Temp Survey 5/30/03 MIT vs 2/14/01 MIT TEMPERATURE(DEG F) 25 35 45 55 65 75 85 95 105 115 125 135 145 155 165 0 L _ 500 - -- -- - --�.._ 1000 - --- - 1500 -- 2000 - -- -- -5/30/03 TEMP RIH, SI=12HRS 2500 —2l14/01 Temp RIH 3000—5/30/03 PRES RIH, SI=I2HRS 3500 — CCL 4000 -- -- -- - - - — - - - - 4500 - ---- ---- - -- - - ---- 5000 -- ------ - -- - - 5500 - - 6000 - ----- - 6500 - - - — 7000 - ------------------ -- ---------- ------------- -... ---- _ -- - . . 7500 - - -- -- ------- ---- --------------- -- ...------------------------------- ---- - 8000 -- --- -- 8500 _ -- --- 9000 - PK @ 9865' 9500 ----- -- -- --- --- - -- -- -- 10000 PERFORATIONS -- --- - -- -- -- -- C-2 10471-10488 10500 C-5 10860-10978 11000 C-7 11315-11350 BHP= 4729 PSI C-7 11435-11480 11500 PBTD= 11915' C 7 11505-11575 12000 0 2000 3000 4000 5000 PRESSURE(PSIG) NOTE TO FILE In Re: Anna 32rd (18742 #32rd)...PTD (187-063) �-SC3U - -1�1 Unocal has applied to convert this production well to an injector. Since the well does not have a packer in it MI demonstration must be by other means. The original well (176-087) was completed in early May, 1977. In June, 1987 much of the original welibore was abandoned in preparation for a redrill. Essentially, the only portion of the original wellbore salvaged was to the surface casing shoe at 402W md, 3977' tvd. Sidetrack operations commenced following the abandonment and the well was completed in late October. A kick was taken at 10478'. Mud weight was increased from 8.7 to 13.0. Drilling resumed to 10778' where the 7-518" liner was set. No cement was drilled at the liner top, although It Is noted that contaminated mud was circulated. No pressure test of the well was performed prior to drill out and leak off test. A LOT of 16.5 EMW is noted with 150 psi surface pressure', A CBL was run over the 7-518" liner. The comments note that the top of good cement was 10240' and that the remainder of the cement was poor per the log. Amoco then conducted an inflow test on the well with the RTTS set at'964W EMW at the 9-5180 shoe was 7.8. A slight, steady ,bubbling is noted. After much difficulty, the next liner was set in mid October. No cement was found on top of the "liner. An inflow test was conducted above the liner top with no bubbles noted. A 3000 psi surface pressure test was conducted against the liner top with 50 psi lost -in 30 minutes. Whentheliner was drilled out, cement was encountered high at 11746. 2 bond log passes were made in the 5" liner at 0 and 1500 psi. A "Good Bond, comment is made. The well produced intermittently until March, 1988 when a workover was conducted. Following that workover the well was returned to production making about 180 bo and 18 bw. The Pie does not Indicate any other work since. Unocal has provided copies of the CBLs run In the 7-5f8" liner on September 2, 1987 and 5" liner on October 22 1987. Neither log copy is available in the AOGCC well files, Some cement can be seen at 10940' In the 5. liner. Very good cement begins at 10980'. From the 7-518" , shoe at 10778' to 10940', bond quality Is poor, The drilling record indicates that Amoco took a kick In this interval. There is one perforated zone in this interval. The VDL presentation shows that there is likely a mlcroannulus in the poorly bonded interval. Some Improvement is noted in the poor bond interval on the pressure pass. Below 10880', no real changes seen. Bond Interpretation In :the liner lap from 107781 —10578' is not possible due to the 2 strings of pipe present. Above the -5" liner top, the 5' pressure pass, the 7-518" liner is well bonded. The bond log run when the 7- 6/8" liner was set shows there could be cement as high as 10000', although the quality does not get really good until about 10250'. Bonding remains good throughout the run interval, There Is one perforated interval in ,the liner lap. The 7-518" run indicates wall bonded pipe. MI Is Indicated. Subject to Unocal complying with the requirements of the attached 'Procedures to Obtain Variances on Packerless Wells (version 4) February 9 2000", I recommend approval to convert Anna 32rd (187-063) as proposed. � 61? Tom Maunder tot i DC Petroleum Engineer a 1,000 2,000 111 5,000 0 H s 6,000 CL m 0 7,000 111 10,000 11,000 12,000 An-32RD Maximum Allowable Operating Pressure Graph Pressure (PSI) 0 1,000 2,000 3,000 4,000 5,000 6,000 7,000 8,000 9,000 10,000 ® date : 2/16/2005 9:40:51 AM e operating pressures (surface gauge) \Run uction = 4428 psi. @ 70% nominal casing yield mediate = 1059 psi. limited by fracture pressure at shoe ce = no data available _C C rent Pressure readings TB RESS = 2292 CSGJ : SS2 = 2100 CSGi � SS3 = 397 CSG! ' SS5 = 20 Casin Details Liner Han er = 5" #, internal yield = N/A psi from 11995' to 12005' MD' Liner Casi = 5" 18#, N-80 internal yield = 10140 psi from 10590' to 12005' MD' Liner oa s oe = , Internal yie = Nei from 12006 to 120D5' MU Liner Hang_ = 7.625" #, internal yield = N/A psi from 10762' to 10778' MD' Liner Casing 7.625" 39#, N-80 internal yield = 9180 psi from 9958' to 10778' MD' Liner Shoe = 625" #, internal yield = N/A psi from 10776' to 10778' MD' Production cas g = 9.625" 43#, N-80 internal yield = 6327 psi from 34' to 10164' MD' Production Sho = 9.625" #, internal yield = N/A psi from 101 62'to 10164' MD' Intermediate cas g segm = 13.375" 72#, N-80 internal yield = 5380 psi from 3913' to 4020' M Intermediate casi segm = 13.375" 61#, K-55 internal yield = 3090 psi from 3473' to 4020' M St collar = 13.375" internal yield = N/A psi from 4016' to 4020' MD' Intermediate casing egm = 13.375" 61#, K-55 internal yield = 3090 psi from 2131' to 4020' M Intermediate casing egm = 13.375" 68#, K-55 internal yield = 3450 psi from 2964' to 4020' M Intermediate casings gm = 13.375" 72#, N-80 internal yield = 5380 psi from 3641' to 4020' M Intermediate Shoe = 1 .375" #, internal yield = N/A psi from 4018' to 4020' MD' Surface Casing = 20" 9 .4#, X-52 internal yield = psi from 41' to 600' MD' Surface Shoe = 20" #, i ternal yield = N/A psi from 599' to 600' MD' - Casing Parameters Assumptions ro uction caking yi - o of nominalwith w weight- - Intermediate casing yield @ 5% of nominal with fluid weight of 0.433 #/ft Surface = no data available Fracture gradient = 0.7 #/ft API :507332029801 Permit : 1870630 Workbook : An-32RD Casing Pres re Analysis @70 percent 20050216.xls Variable Definitions P =Reservoir Pressure - - - CYP = Casing Yield Pressure SF = Safety Factor (70% for working annulus; 45% for ter annuli) HP = Internal Fluid Hydraulic Pressure MASP = Maximum allowable surface working pressure Graphical calculation method Inside pressure potential == Outside pressure containment Therefore - - HP + MASP = RP + (CYP' SF) Rearranging MASP = RP + (CYP ' SF) - HP ---Internal Fluid Hydraulic Pressure Formation facture pressure @ 0.7 #/ft -Production CYP @ 70% Outside Containment for Production casing MASP (production casing) Intermediate CYP @ 45% Outside Containment for Intermediate casing MASP (Intermediate casing) r Current Pressure Readings Disclaimers (fine print) Casing yield values taken from published sources where specifications are known. If specifications are unknown then values are the lowest value of probable materials. TVD interpolated from Openworks directional surveys. Values should be +/- 25 ft @ 10,000 ft. MD Graphical Casing Pressure Analysis Ver 22x.xls #12 Unocal Alaska Union Oil Company of California 909 West 91h Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7661; Fax (907) 263-7847 UNOCALID Larry P. Greenstein Prodction Technician Date: February 17, 2005 Commission Chair John Norman Alaska Oil and Gas Conservation Commission 333 W. 7 th Ave., Suite #100 Anchorage, AK 99501-3539 Attn: Tom Maunder Administrative Approval Request Well No. An-37 Injector Anna Platform Granite Point Field Dear Chair Norman, Unocal requests administrative approval under Area Injection Order 6, Rule 9 for the continuation of injection of non -hazardous Class 11 fluids for the Anna Platform Well No. An-37 Injector (Permit # 187-109) in Granite Point Field. To support this request, Unocal submits the following information and documentation: 1. Schematic (attached). 2. Temperature survey comparison plot (attached). 3. Maximum allowable injection pressure calculation in graphical form (attached). 4. Brief/relevant well history (below and attached). This well was drilled as a producer in December of 1987. Per the attached well history, it was converted to a waterflood injector and has been injecting with a variance since June of 2001. The well has been shut-in since July of 2004. Injection was authorized after a review of the well's construction and demonstration of integrity via temperature logs and step rate injection tests according to a procedure titled "Procedures to Obtain Variances on Packerless Wells (Version 4) dated February 9, 2000". This procedure was cooperatively developed by Unocal and the Commission in accord with 20 ACC 25.450(a), that allows the Commission to authorize less stringent well operating and construction requirements where injection does not occur into, through or above fresh water. In addition, please note that Granite Point Field has an auquifer exemption per EPA 40 CFR 147.102 (b)(2)(i). The temperature survey run on 5/31/2003 matches the last survey run on 11/23/2001 in character showing no cooling anomalies above the packer. This indicates that injection is occurring only 0 0 into the Tyonek C-Sands. Also, the plotted daily monitoring, which is reported monthly, hasn't shown any unexplainable rate or pressure responses from this well. Unocal will continue to monitor and record daily injection rates and tubing and casing pressures on the well and provide a report to the AOGCC on a monthly basis. A temperature survey will be run every two years to insure the injected water is contained within the completion interval. Thank you for your consideration and if you have any questions regarding this, please contact me at 263-7661 or Hal Martin at 263-7675. Sincerely, Larry P. Gr re nstein cc: Dave Cole Hal Martin MIT book Well File GRANITE POINT FIELD GP ADL 18742 Well No. 37 LOWER KENAI SANDS PLATFORM ANNA bdbftma Camd ft ft mid 3ptd belle 11--01- W tam VA0 b"ft our 91aelrao. teeall�a 3 �1v. '. -not P. A.attnn pmw 1. Oud� D 3f• 3gbm*l�eor teootlau 7-1'M ��1J' Fly. * 3` M��" Dal.' "' W. 7L1 11741' WD 10Z' rM t 7/IN" x 2 / x-a 10dle' pm 1157V Who � 1 «t � •1� 30d :Aa oft13 %V o« «t .t ae r�r wr�aoo on OR* shot swbr .rt 1olw rnbo o„c i °°'�� ss�louer wean sr. apt Oro, t a% 11wr Nt 10446-11 W W?W go Cot � � 1�/7C' x If x_0 "m 0-& I071 d--» 6 ; Ji b -17 113lIEEti`11i4ircT'I KIV $:1fL �/ Z Z 5 �► bm Pawm* 1-45- S 223 WM x 74 VM x " UM WIN SgxPA VM Hl oee.a r�e.rwrr iiaa. Us lam % y 11-1b-d7 /at 1! 17-*D7 -14-M 02-27-0 AR Q}-0 vim :n4► 3af° IN-tbTLj'9eu, RTWf'Y C-51b, 7 1 CIA 411V 13 W. . «i. C3A Mr ". 39f 1s low 11 1144 7 Ir 1 1" Mw U • 30 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 11000 11500 12000 -1000 Anna Platform An 37 Temp Survey 5/31/03 MIT vs 11/23/01 MIT TEMPERATURE(DEG F) 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 -500 0 500 1000 1500 2000 2500 PRESSURE(PSIG) 0 0 NOTE TO FILE In Re: Anna 37 (18742 #37)... PTD (187-109) mo '- .;k � %') Unocal has applied to convert this production well to an injector. Since the well does not have a packer in it, MI demonstration must be by other means. The well was drilled beginning in late 1987 and was completed in March, 1988. There is very little information available in the At9GCC well file. Like wells -38 and -36, it does not appear that any of the original perforations have been altered since the original completion. Some of the original zones have been re-perfed and additional perforations have been added, but all are below the top of the original perfs. Unocal has provided a copy of the CBL run March 6, 1988. A copy of the log .is not available in the AQGCC well files. Passes for the 7-518" liner and 5" liner are presented. A clear cement top is shown at 10940' in the a" liner. Bond quality looks very good from 10940' to TD. From the 7-5f8" shoe at 10687' to 10940', bond quality is very poor, The drilling record indicates that Amoco became stuck twice in that interval and lost BHA$ each time. There are two perforated zones in this interval. The VDL presentation shows that there Is likely a microannulus (at best) in this interval. Bond interpretation In the liner lap from 10687'-10440' is not possible due to the 2 strings of pipe present. Above the 5" liner top, both tool runs indicate the 7-518" liner is well bonded. Given the excellent signal above the 5" liner top, it is likely that the lower portions of the 7-5/8" liner are bonded as well. MI is indicated. Subject to Unocal complying with the requirements of the attached "Procedures to Obtain Variances on Packerless Wells (version 4) February 9 2000", I recommend approval to convert Anna 37 (187-109) as proposed. lee Tom Maunder Petroleum Engineer �' W 1,000 2,000 3,000 111 5,000 7,000 111 10,000 11,000 12,000 An-37 Maximum Allowable Operating Pressure Graph Pressure (PSI) 0 1,000 2,000 3,000 4,000 5,000 6,000 7,000 8,000 9,000 10,000 Run date I12/16/2005 10:23:44 AM Safe operati g ressures (surface gauge) Production = 55 8 p i. @ 70% nominal casing yield Intermediate = 3 pk. limited by fracture pressure at shoe Surface = 163 1. lim d by fracture pressure at shoe Current Pre sure k.adings CSGPRESS2 = CSGPRESS3 = 50 CSGPRESS5= Casing Details Liner Hanger = " #, internal field = N/A psi from 11641' to 11644' MD' Liner Reentry Jc nt = 5" #, int nal yield = N/A psi from 11637' to 11644' MD' - miner asing = 18#_,V=80 int nal yield = 10140-psi-from 10566' to 1T644 MDR Liner Flcollar = ' #, internal yie = N/A psi from 11642' to 11644' MD' Liner Casing = E' 18#, N-80 inter I yield = 10140 psi from 11560' to 11644' MD' Liner Floatshoe = 5" #, internal yi d = N/A psi from 11642' to 11644' MD' Liner = 7.625" 39#, S-95 internal yi Id = 10900 psi from 9897' to 10687' MD' Production Casing = 9.625" 53.5#, 80 internal yield = 7927 psi from 6470' to 10150' MD' Production Stgcollar = 9.625" #, in al yield = N/A psi from 101 47'to 10150' MD' Production Casi g = 9.625" 53.5#, N- 0 internal yield = 7927 psi from 3718' to 10150' MD' Production Sho = 9.625" # internal Id = N/A si from 10148' to 10150' MD' Intermediate Ca ing = 13.375" 68#, N- internal yield = 5020 psi from 40' to 3522' MD' Intermediate Shoe = 13.375" #, internal ield = N/A psi from 3520' to 3522' MD' Surface Casing `-- 20" 133#, X-56 internal ield = 2125 psi from 42' to 615' MD' Surface Shoe = 0" #, internal yield = N/A si from 613' to 615' MD' Casing Parameters / Assumption Production casing yield @ 70% of nominal w h fluid weight of 0.433 #/ft Intermediate ca ing yield @ 45% of nominal th fluid weight of 0.433 #/ft —Surface cas;; g o of nominaa with fl weig o — Fracture gradie = 0.7 #/ft API :507332OP9400 Permit:187109 Workbook : An-17 Casing Pressure Analysis @70 Variable Definitions --RP = Reservoir Pressure CYP = Casing Yield Pressure SF = Safety Factor (70% for working annulus: 45% for outer annuli) HP = Internal Fluid Hydraulic Pressure MASP = Maximum allowable surface working pressure Graphical calculation method Inside pressure potential == Outside pressure containment Therefore HP + MASP = RP + (CYP ' SF) Rearranging MASP = RP + (CYP ' SF) - HP Internal Fluid Hydraulic Pressure Formation facture pressure @ 0.7 #/ft Production CYP @ 70% Outside Containment for Production casing MASP (production casing) Intermediate CYP @ 45% Outside Containment for Intermediate casing MASP (Intermediate casing) Surface CYP @ 45% Outside Containment for Surface casing MASP (Surface casing) Disclaimers (fine print) Casing yield values taken from published sources where specifications are known. If specifications are unknown then values are the lowest value of probable materials. TVD interpolated from Openworks directional surveys. Values should be +/- 25 ft @ 10,000 ft. MD 20050216.xls Graphical Casing Pressure Analysis ver 22x.xls #11 þ ~ e Unocal Alaska Union Oil Company of California 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7661; Fax (907) 263-7847 e UNOCAL. R c [:-~ FnE B .1 ;, IOOh _ ~j,-'J Larry P. Greenstein Prodction Technician Date: February 9, 2005 Commission Chair John Norman Alaska Oil and Gas Conservation Commission 333 W. ¡th Ave., Suite #100 Anchorage, AK 99501-3539 Attn: Tom Maunder Administrative Approval Request Well No. An-25 Injector Anna Platform Granite Point Field Dear Chair Norman, Unocal requests administrative approval under Area Injection Order 6, Rule 9 for the continuation of injection of non-hazardous Class II fluids for the Anna Platform Well No. An-25 Injector (Permit # 168-036) in Granite Point Field. To support this request, Unocal submits the following information and documentation: 1. Schematic (attached). 2. Temperature survey comparison plot (attached). 3. Maximum allowable injection pressure calculation in graphical form (attached). 4. Brief/relevant well history (below and attached). This well was drilled as a producer in August of 1968. Per the attached well history, it was converted to a waterflood injector and has been injecting with a variance since June of 2001. Injection was authorized after a review of the well's construction and demonstration of integrity via temperature logs and step rate injection tests according to a procedure titled "Procedures to Obtain Variances on Packerless Wells (Version 4) dated February 9,2000". This procedure was cooperatively developed by Unocal and the Commission in accord with 20 ACC 25.450(a), that allows the Commission to authorize less stringent well operating and construction requirements where injection does not occur into, through or above fresh water. In addition, please note that Granite Point Field has an auquifer exemption per EPA 40 CFR 147.102 (b)(2)(i). The temperature survey run on 5/31/2003 matches the last survey run on 11/24/2001 in character showing no cooling anomalies above the packer. This indicates that injection is occurring only into the Tyonek C-Sands. Also, the plotted daily monitoring, which is reported monthly, hasn't shown any unexplainable rate or pressure responses from this well. e e Unocal will continue to monitor and record daily injection rates and tubing and casing pressures on the well and provide a report to the AOGCC on a monthly basis. A temperature survey will be run every two years to insure the injected water is contained within the completion interval. Thank you for your consideration and if you have any questions regarding this, please contact me at 263-7661 or Hal Martin at 263-7675. Sincerely, /! ~nstein cc: Dave Cole Hal Martin MIT book Well File ~ ~ II C A ,: 311". 54.Sf e CSA n07' e CRANITE POINT ADL 18742 WELL NO. 25 MIDDLE fŒHþJ SANDS PLATroRW ANNA '0'1" 10300' . I Cempl.øon Lon, Sbint: Depth t. ocr Dual ...... 3S" 2. " '/2- suttrul lubin, 8230" 3. 3 t.fr ...... M 123" 4. 3 1/2" lAD and " 111" IIult:Nn XO I23T 5. 3 '11" IRD pup ~ L 3" I<obI. . '8' 1lih-L224 7. 3 1/2· ~ oncI :v). Ntra. 1(0 . 2 7/r ""'1 tu....,' '0113" 27/11' MuI.... 1IfIIIn. 10114" Short ... A. 3 1.fr ..... pup 31' II. 3 112" Buttn.. and 2 7/11I" ...... )CO 3t' Co t 71r IIuttreM tuWntI 8ur D. 2 7/1f' ButtN.. and f 311" IRD XO 1231' IE. :2 3JI'" 8RD 1M.- 8241" eM rvn 12111I1) P8D 10 Aeaont ~ Date ""'I Dote: &It QIII Sc.fooe lAcaØon: IAct 4, Sot OJI. Platform Mne Ttr1' FNt.. j . m.. ... '2. nON, 'tt2W, I.'" SubIuIfooe LooatIOIU 11) - 421" .2401' FIlL. Sea. '2. nON, Inn, EIevotfon: '05' ...... TO: t03OO" I: "'" ps): 10'1I')S .... CnIftt: '3 ~," , CaInJI Nt at t70r with U'70 .. ~ . 5.JI", 40 I ~ N-IO aM 1-15 CoIfnt -' . 1500' with .~ In IInIIIt 7", ÐI S- u.- let.. 8281-10240' wIIh .go... oement 'erfcwatlonl: C-3: 11 U 1125'. C-1t 1020-IOIO'- "44 IUO·. .,20-I1:s5'- c-4: "IC œl00- '1I50-ItI5'. I2t1 1250"- .,75-lurcr. C-,: 834C ,405· 1220-1280'. "'1 I~Ucr 1380-'~ C-I: '570-1110" C-t: 1870-1155" C-10: 10030-10110' ____ f«aØoM Inftlal ~aIt Ca02 IIOPë ~ IWPD, 354 UCPD, OOR 214 .:....-.. .-..----- lnItIaf Stlmufdon: ~ ft.--lr Data: Coßd tnterwa.: tton. DST InteMIII and RuuftI: None !At IftVIriory: a 8500-1.,0, GRS 1500-7500, 10 GRS II COm 8a01S-.eoI. 10, CAS oil CDU 1100-10141, CSL to 10111. S.M. ~ Anna Platform An 25 temp Survey 5/31/03 MaT vs 11/24101 MIT 8115-8125 814Q-8160 C-4 8190-8210 8220-8250 C-5 8340-8405 8416-8510 9020-9090 9120-9135 9150·9165 9175·9180 9220-9280 9380-9430 9570-9610 C-10 10030·10110 RIH, 11/24/01 Temp RIH ~~ CCl , 1;. ( e ( e NOTE TO FILE In Re: Anna 25 (18742 #25)...PTD (168·036) Unocal has applied to convert this production well to an Injector. Since the well does not have a packer in it, MI demonstration must be by other means. The well was drilled in summer 1918. There Is tittle information In the well file regarding the cementing operation on the 9·5/8or production casing or T' liner, in the sparse comments it is noted that no cement was found above the liner top. Perforations were shot at 8030' and a squeeze attempted through IiII retainer. They were unable to inject at 3500 psi. The well was cleaned out, the completion run and the well was perforated and put on productIon. No casing or liner pressure test is noted. No mention is made of running a CSl, although Unocal has provided a Xerox copy of a log run July 23, 1968. A copy of the eSl is in the AOGCC well file. The 407 filed on initial completion reports the well we. flowing 1202 bOpd with 10 bwpd. A workover to clean-out the well and change to pump BHA was performed in June 1982. In June 1984 another workover was necessary due to pump problems. In April 1985, a workover was performed to shut off increasing water production. The summarized work included squeezes and reprerforatlng the well. Little infonnation on this work 1$ available in the AOGCC well file. As noted, a copy of the CBL run in July 1968 fa available in the AOGCC files and Unocal has provided Xerox copies of the log. Log response shows the TOC to be about 7420'. Cement quality is variable from TOe to about 8020'. Quality improves to <5% free by 8060' and varies from 5 to 10% free to 8220 where excellent bond is indicated to 8300', No new information is available following the squeeze work in April 1985. The completion drawing and perforation record report that a number of Interval. were squeezed includIng 4 Intervals above the Kobe BHA. Based on the response of the original bond log, the inability to inject through perforations at 8030' and the 1985 squeeze work, I conclude that the 4 squeezed intervals are isolated and should not take injected water. MI is indicated. Subject to Unocal complying with the requirements of the attached ·'Procedures to Obtain Variances on Packerless Wells (version 4) February 9 2000", I recommend ~ ~n. 25 (168-036) as prapaeed. ~~~~::~~gineer ~/~· ei::) / 1.000 2,000 3,000 4,000 5,000 - c ~ - .c ..... Q. (þ c 6,000 7,000 8,000 9,000 10,000 11 ,000 An-25 Maximum Allowable Operating Pressure Graph o Pressure (PSI) 4,000 5,000 6,000 9,000 1,000 2,000 3,000 7,000 8,000 o Run date: 2/8/2005 3: 11 :32 PM n9 Details 7" 23#, 6-95 internal yield::: 5330 psi from 8288' to 10240' MD' P duction::: 9.625" 40#, N-80 internal yieid ::: 5745 psi from 0' to 8500' MD' In! rmedia!e::: 13.375" 54.5#, K-55 internai yield::: 2730 psi from 0' to 1707' MD' ~m.ete.rs I Assumptions 0% of nominal with fluid weight of 0.433 #lft casing yield @ 45% of nominal with fluid weight of 0.433 #lft ::: no data available ur gradient::: 0.7 #lft : n-25 Casing Pressure Analysis @70 percent 20050208.xls Internal Fluid Hydraulic Pressure Formation facture pressure @ 0.7 #lft -Production CYP @ 70% - Outside Containment for Production casing -MASP (production casing) Intermediate CYP @ 45% - Outside Containment for Intermediate casing Disclaimers (fine Drint) Casing yield values taken trorn published sources where specifications are known. If specifications are unknown then values are the lowest value of probable materials. ND interpolated from Openworks directional surveys. Values should be +1- 25 ft @ 10,000 ft. MD " . ' 10,000 #10 It Unocal Alaska . Union Oil Company of Ca nia 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCALE'é1 Hal Martin Reservoir Engineer January 14, 2005 JAN [ ..~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 REQUEST FOR ADMINISTRATIVE APPROVAL UNDER AREA INJECTION ORDER 6 CONVERSION TO INJECTOR ANNA PLATFORM WELL NO.5 GRANITE POINT FIELD Dear Tom: Unocal requests administrative approval under Area Injection Order 6, Rule 9 for the conversion to an injector of non-hazardous Class II fluids for Anna Platform Well NO.5 (Permit # 1670140) in Granite Point Field. To support this request, Unocal submits the following information and documentation: 1. Schematic (attached). 2. MD and TVD plot of pre-injection/baseline and post-injection period temperature surveys (attached). 3. Maximum allowable injection pressure calculation in graphical form (attached). 4. Brief/relevant well history (below). The Anna Well NO.5 was drilled and completed as a producer in 9/67 in the Tyonek Formation with C-2, 5,6,7,8, and 9 Sand perforations spread out between 9074' and 10613'. A cement bond log run in the 9-5/8" casing on 7/3/67 indicated that bond exists from the shoe at 8965' to approximately 8620'.~ Indications are that the 9-5/8" casing was tested to 2000 psi on 8/14/67. No information was found for a test on the 7" Iiner.tlConverted to a hydraulic lift completion in 6/74, the Anna Well No.5 produced until 2/96 when it developed tubing integrity issues. A coiled tubing jet pump completion was run in 7/96 and production continued until problems developed in 4/97. A hydraulic workover in 9/97 repaired the well with dual strings of 3-1/2" tubing and hydraulic pump completion. The well developed holes in the short string in 12/02 and was shut-in. Efforts to remedially repair in 3/03 were unsuccessful. In 10/04, Unocal received permission to begin the process of converting the well to a Tyonek C-2, 5, 6, 7, 8, and 9 injector of non-hazardous Class II fluids. A baseline temperature survey was run on 10/6/04, then beginning on 10/24/04 waterflood water was injected into the well under conditions averaging about 150-200 BWPD with 100 psi. On 1/9/05, a follow up temperature survey was run and confirmed that .;;;- water was not moving uphole. C:\Documents and Settings\ambrudm\Local Settings\Temporary Internet Files\OLK7\An-5 Admin Relief Request Jan05.doc Tom Maunder January 14, 2005 Page 2 e e As an injector, Anna Well No.5 will support AN- 23Rd and 33 which currently produce at combined test rates of about 180 SOPD and 90 SWPD (33.3% WC). Anna Well No.5 is not the first completion without a packer to be converted to an injector on the Anna Platform. Anna Well Nos. 21, 25, 32RD, and 38 have also been converted to injection and are currently operating as injectors. Unocal will monitor and record daily injection rates and tubing and casing pressures on the well and provide a report to the AOGCC on a monthly basis. A temperature survey will be run every two years to insure the injected water is contained within the completion interval. Please note also that Granite Point Field has an aquifer exemption per EPA 40CFR147.102b2i. Please call me at (907)263-7675 if you have any questions. ¡¡;'/Ja:zL - Hal Martin JHM:dma Attachments RKB to TBG Head = 30' 13-3/8" 54.5 J-55 8 RD ST & C 12.165 Surtàce 2,050' 1 A 9-5/8" 43.5 S-95/N-80 8 RD/BUTT. 8.755 Surface 8,965' T' 26 S-95 8 RD ST & C 6.276 8,754' 10,797' Tubing Long String 3-1/2" 9.2 L-80 BTC SC 2.992 8,618' Short String 3-1/2" 9.2 L-80 BTC SC 2.992 8,608' 2 30' 2.99 11 CIW 3-1/2" DCB Tubing Hanger Half 2 8,618' 3.00 3.86 Crossover, 3-l/2" Buttress Box x 3-l/2" EUE 8 rd Pin 3 8,619' 2.68 6.5 Kobe, 3", Type "B", Pump Cavity 4 8,642' 3.00 4.5 Crossover, 3-l/2" EUE 8 rd Pin x 3-l/2" Buttress Box 5 8,796' 3.00 5.25 Wireline re-entry guide, 3-1/2" Buttress Box 0 Short String A 30' 2.99 11 CIW 3-1/2" DCB Tubing Hanger Half B 8,608' 2.00 3.86 Crossover, 3-1/2" Buttress Box x 2-3/8" EUE 8 rd Pin C 8,609' 2.00 2.37 Pup, 2-3/8", 4.6#, L-80, EUE 8 rd Fish: 1,198' Tail Pipe, 2-7/8", 6.4#, N-80, Buttress @ 9,348' DPM 9-5/8" CS2 Breakdown: 0' 4466': 40# N-80 4466' 6452': 40#,8-95 6452' 8965': 43.5#,8-95 PERFORATION mSTORY = == Interval Accum. Date Zone Top Btm Amt sof Present Condition C-2 9,072' 9,087' 15' Initial then re perfed C-5 9,323' 9,440' 117' C-6 9,523' 9,580' 57' C-7 9,755' 9,995' 240' C-8 10,170' 10,411' 241' C-9 10,583' 10,613' 30' Partially coverd by fill l~erfOration Data Sheet for more Detail 3 4 PBTD == 10,784' TD == 13,821' MAX HOLE ANGLE == 33° @ 1,850' 0: \00 E\OOEF ie1ds\GPF\Anna \ W ells\An-05\Schematics\A- 5Schm9-19-97 .doc DRAWN BY: tcb REVISED: 9119/97 MD Temperature SUN 10-6-04 vs 1-9-05 Pressure (psia) 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 600D 7000 BODO 9DOO 10000 40 50 100 110 120 130 140 150 160 60 70 80 90 Temperature (Deg. F) 13 3/8" -TBG 0-6-04 Temp -1-9-05 Temp O:\OOE\OOEFields\GPF\Anna\Wells\An-05\Surveys\Temp\An-5 Temp Survey 10-6-04 & 1-9-05.xls A TVD Temperature Su 10-6-04 vs 1-9-05 Pressure (psia) o 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 (I 1000 3000 - 4000 .... CI) .! - '" C ~ 5000 I .c .... Q,. CI) C 6000 7000 sooo 9000 10000 40 50 60 70 80 90 100 110 Temperature (Deg. F) 10-6-04 Pressure Perfs 9 5/8" -7" 1-9-05 Pressure -10-6-04 Temp 120 130 150 160 140 13 3/8" -TBG -1-9-05 Temp O:\OOE\OOEFields\GPF\Anna\Wells\An-05\Surveys\Temp\An-5 Temp Survey 10-6-04 & 1-9-05.xls 1.000 2,000 3,000 4,000 An ...5 aximum Allowable perating Pressure Graph o 3,000 Pressure (PSI) 4,000 5,000 6,000 1,000 2,000 o Run date: 1/14/2005 10:15:59 AM 7,000 8,000 9,000 10,000 rameters I Assum tions sing yield @ 70% of nominal with fluid weight of 0.433 45% of nominal with fluid weight of 0.433 #/ft yield @ 45% of nominal with fluid weight of 0.433 #/ft t:: 0.7 #/ft Workbook: An- Casing Pressure Analysis @70 percent 20050114.xls 5,000 - C ~ - .c: ..... Q. 'W c 6,000 ._~- 7,000 8,000 9,000 10,000 .. 11 ,000 -~"~-_.._-- ._._.~ Fluid Hydraulic Pressure Formation facture pressure @ 0.7 #/ft -Production CYP @ 70% -Outside Pressure Containment -MASP (production casing) ' Intermediate CYP @ 45% -Outside Containment for Intermediate casing ... MASP (Intermediate casing) . Current Pressure Readings Disclaimers (fine "nt) Casing yield values taken ublished sources where specifications are known. If specifications are unknown then values are the lowest value of probable rnaterials. WD interpolated from Openworks directional surveys. Values should be +1- 25 ft @ 10,000 ft. MD #9 . J . . ti1) ~ \,!~ jl ',:\ ¡ j M1' l' ~i LJ liF!t 11 j:r Ui1::::J FRANK H. MURKOWSKI, GOVERNOR A."tA.~1iA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 September 27, 2004 Proposals to Amend Underground Injection Orders to Incorporate Consistent Language Addressing the Mechanical Integrity of Wells The Alaska Oil and Gas Conservation Commission ("Commission"), on its own motion, proposes to amend the rules addressing mechanical integrity of wells in all existing area injection orders, storage injection orders, enhanced recovery injection orders, and disposal injection orders. There are numerous different versions of wording used for each of the rules that create confusion and inconsistent implementation of well integrity requirements for injection wells when pressure communication or leakage is indicated. In several injection orders, there are no rules addressing requirements for notification and well disposition when a well integrity failure is identified. Wording used for the administrative approval rule in injection orders is similarly inconsistent. The Commission proposes these three rules as replacements in all injection orders: Demonstration of Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before injection begins, at least once every four years thereafter (except at least once every two years in the case of a slurry injection well), and before returning a well to service following a workover affecting mechanical integrity. Unless an alternate means is approved by the Commission, mechanical integrity must be demonstrated by a tubing/casing annulus pressure test using a surface pressure of 1500 psi or 0.25 psi/ft multiplied by the vertical depth of the packer, whichever is greater, that shows stabilizing pressure and does not change more than 10 percent during a 30 minute period. The Commission must be notified at least 24 hours in advance to enable a representative to witness mechanical integrity tests. Well Integrity Failure and Confinement Whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, log, or other evidence, the operator shall immediately notify the Commission and submit a plan of corrective action on a Form 10-403 for Commission approval. The operator shall immediately shut in the well if continued operation would be unsafe or would threaten contamination of freshwater, or if so directed by the Commission. A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating well integrity failure or lack of injection zone isolation. . . 4~ , 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 Injection Order "Demonstration of "Well Integrity "Administrati ve Mechanical Failure and Action" Integrity" Confinement" Area Injection Orders AIO 1 - Duck Island Unit 6 7 9 AlO 2B - Kuparuk River Unit; Kuparuk River, 6 7 9 Tabasco, U gnu, West Sak Fields AlO 3 - Prudhoe Bay Unit; 6 7 9 Western Operating Area AIO 4C - Prudhoe Bay Unit; 6 7 9 Eastern Operating Area AlO 5 - Trading Bay Unit; 6 6 9 McArthur River Field AlO 6 - Granite Point Field; 6 7 9 Northern Portion AlO 7 - Middle Ground 6 7 9 Shoal; Northern Portion AIO 8 - Middle Ground 6 7 9 Shoal; Southern Portion AIO 9 - Middle Ground 6 7 9 Shoal; Central Portion AIO I DB - Milne Point Unit; Schrader Bluff, Sag River, 4 5 8 Kuparuk River Pools AlO 11 - Granite Point 5 6 8 Field; Southern Portion AIO 12 - Trading Bay Fielçl; 5 6 8 Southern Portion AIO 13A - Swanson River 6 7 9 Unit AIO 14A - Prudhoe Bay 4 5 8 Unit; Niakuk Oil Pool AlO 15 - West McArthur 5 6 9 . . Affected Rules "Demonstration of "Well Integrity "Administrative Injection Order Mechanical Failure and Action" Integrity" Confinement" River Unit AIO 16 - Kuparuk River 6 7 10 Unit; Tam Oil Pool 6 8 AIO 17 Badami Unit 5 AIO 18A - Colville River 6 7 11 Unit; Alpine Oil Pool AIO 19 - Duck Island Unit; 5 6 9 Eider Oil Pool AIO 20 - Prudhoe Bay Unit; 5 6 9 Midnight Sun Oil Pool AIO 21 - Kuparuk River 4 No rule 6 Unit· Meltwater Oil Pool , AIO 22C - Prudhoe Bay 5 No rule 8 Unit; Aurora Oil Pool 6 9 AIO 23 . Northstar Unit 5 AIO 24 - Prudhoe Bay Unit; 5 No rule 9 Borealis Oil Pool AIO 25 - Prudhoe Bay Unit; 6 8 13 Polaris Oil Pool AIO 26 - Prudhoe Bay Unit; 6 No rule 13 Orion Oil Pool Disposal In.iection Orders DIO I - Kenai Unit; KU No rule No rule No rule WD-I DIO 2 - Kenai Unit; KU 14- No rule No rule No rule 4 DIO 3 - Beluga River Gas No rule No rule No rule Field; BR WD-I DIO 4 - Beaver Creek Unit; No rule No rule No rule BC-2 DIO 5 - Barrow Gas Field; No rule No rule No rule South Barrow #5 DIO 6 - Lewis River Gas No rule No rule 3 Field; WD-l DIO 7 - West McArthur 2 3 5 River Unit; WMRU D-I DIO 8 - Beaver Creek Unit; 2 3 5 BC-3 DIO 9 - Kenai Unit; KU 11- 2 3 4 17 DIO 10 - Granite Point 2 3 5 Field; GP 44-11 e . Affected Rules "Demonstration of "Well Integrity "Administrative Injection Order Mechanical Failure and Action" Integrity" Confinement" DIO 11 - Kenai Unit; KU 2 3 4 24-7 DIO 12 - Badami Unit; WD- 2 3 5 1, WD-2 010 13 - North Trading Bay 2 3 6 Unit; S-4 DIO 14 - Houston Gas 2 3 5 Field; Well #3 DIO 15 - North Trading Bay 2 3 Rule not numbered Unit; S-5 DIO 16 - West McArthur 2 3 5 River Unit; WMRU 4D DIO 17 - North Cook Inlet 2 3 6 Unit; NCill A-12 DIO 19 - Granite Point 6 Field; W. Granite Point State 3 4 17587 #3 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 I Storage Injection Orders SIO 1 - Prudhoe Bay Unit, No rule No rule No rule Point McIntyre Field #6 SIO 2A- Swanson River 2 No rule 6 Unit; KGSF #1 SIO 3 - Swanson River Unit; 2 No rule 7 KGSF #2 Enhanced Recovery InJection Orders EIO 1 - Prudhoe Bay Unit; No rule 8 Prudhoe Bay Field, Schrader No rule BluffFonnation Well V-I05 . . Affected Rules Injection Order "Demonstration of "Well Integrity "Administrative Mechanical Failure and Action" Integrity" Confmement" EIO 2 - Redoubt Unit; RU-6 5 8 9 · . 'I I 02-902 (Rev. 3/94) Publisher/Original Copies: Department Fiscal, Department, Receiving AO.FRM STATE OF ALASKA ADVERTISING ORDER NOTICE TO PUBLISHER ADVERTISING ORDER NO. INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO, CERTIFIED AO-02514016 AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COPY OF ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE F AGENCY CONTACT DATE OF A.O. AOGCC 333 West ih Avenue, Suite 100 o Anchorage,AJ( 99501 M 907-793-1221 R T o Journal of Commerce 301 Arctic Slope Ave #350 Anchorage, AJ( 99518 October 3,2004 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: United states of America AFFIDAVIT OF PUBLICATION REMINDER State of ss INVOICE MUST BE IN TRIPLICATE AND MUST REFERENCE THE ADVERTISING ORDER NUMBER. A CERTIFIED COpy OF THIS AFFIDAVIT OF PUBLICATION MUST BE SUBMITTED WITH THE INVOICE. ATTACH PROOF OF PUBLICATION HERE. division. Before me, the undersigned, a notary public this day personally appeared who, being first duly sworn, according to law, says that he/she is the of Published at in said division and state of and that the advertisement. of which the annexed is a true copy, was published in said publication on the day of 2004, and thereafter for _ consecutive days, the last publication appearing on the _ day of , 2004, and that the rate charged thereon is not in excess of the rate charged private individuals. Subscribed and sworn to before me This _ day of 2004, Notary public for state of My commission expires Public Notices . . Subject: Public Notices From: J ody Colombie <jody _ colombie@admin.state.alcus> Date: Wed, 29 Sep2004 13:01:04 -0800 10f2 9/29/2004 1: 10 PM Public Notices . . 20f2 9/29/2004 1: 10 PM Public Notice . . Subject: Public Notice From: Jody Colombie <jody_ colombie@admin.state.ak.us> Date: 29 2004 12:55:26 -0800 Please publish the attached Notice on October 3, 2004. Thank you. Jody Colombie Content- Type: applicationlmsword Mechanical Integrity of Wells Notice.doc Content-Encoding: base64 Content- Type: applicationlmsword Ad Order form.doc Content-Encoding: base64 I of 1 9/29/20041:10 PM Citgo Petroleum Corporation PO Box 3758 Tulsa, OK 74136 Kelly Valadez Tesoro Refining and Marketing Co. Supply & Distribution 300 Concord Plaza Drive San Antonio, TX 78216 Jerry Hodgden Hodgden Oil Company 408 18th Street Golden, CO 80401-2433 Kay Munger Munger Oil Information Service, 'nc PO Box 45738 Los Angeles, CA 90045-0738 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 James Gibbs PO Box 1597 Soldotna. AK 99669 Richard Wagner PO Box 60868 Fairbanks, AK 99706 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 . . Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 Robert Gravely 7681 South Kit Carson Drive Littleton, CO 80122 Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 Samuel Van Vactor Economic Insight Inc. 3004 SW First Ave. Portland, OR 97201 Schlumberger Drilling and Measurements 2525 Gambell Street #400 Anchorage, AK 99503 Ciri Land Department PO Box 93330 Anchorage, AK 99503 Jack Hakkila PO Box 190083 Anchorage, AK 99519 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 Cliff Burglin PO Box 70131 Fairbanks, AK 99707 North Slope Borough PO Box 69 Barrow, AK 99723 /ljalkd ItJ/¡{tt; 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, 10 83702 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle, WA 98119-3960 David Cusato 200 West 34th PMB 411 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 · [F:d: Re: Consistent Wording for Injection ers - Well Integrity ... . Subject:. [Fwd: Re:.· Consistent W otdìn~fotlt1j~ction Order~"Wélllr1t¢gritYi{R.~vise4)J F~om: John Nonnan<john=nonnan@agmin.state.ak.us> Date: Fri, 01 Oct 200411:09:26;-0800 more -------- Original Message -------- Subject:Re: Consistent Wording for Injection Orders - Well Integrity {Revised) Date:Wed, 25 Aug 2004 16:49:40 -0800 From:Rob Mintz <robert mintz@}law.state.ak.us> To:jim regg@}admin.state.ak.us CC:dan seamount@}admin.state.ak.us, john nonnan@}admin.state.ak.us Jim, looks good, but I still think maybe it would be good to include the following sentence or something like it in the well integrity and confinement rule: "The operator shall shut in the well if so directed by the Commission." My thinking is that otherwise, an operator might argue that the Commission can only require the well to be shut in by going through an enforcement action, issuing an order after notice and opportunity for hearing, or meeting the strict requirements for an emergency order under the regulations. The proposed language makes clear that it is a condition of the authorization to inject, that the operator must shut in the well if directed by the Commission after a notification of loss of integrity, etc. »> James Regg <iim regg@admin.state.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 - ...J 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 <iim regg@admin.state.ak.us> 8/17/20044:33:52 PM »> Please delete previous version (email sent 8/9/04); I found another inconsistency in the injection orders regarding well integrity that I have integrated into the proposed fix. Attached is a proposal for consistent language in our injection orders addressing 3 rules related to well integrity: - "Demonstration of Tubing/Casing Annulus Mechanical Integrity" - "Well Integrity Failure" - "Administrative Actions". This proposal includes input from all Sr. staff (except Jack). If you agree with the approach, I'll work with Jody to prepare the public notice. Main points - Demonstration of Tubing/Casing Annulus Mechanical Integrity - standardizes the wording used for mechanical integrity demonstrations, and establishes abililty to grant alternate methods (e.g., temp survey, logging, pressure monitoring in lieu of pressure testing 10f2 10/2/2004 4:07 PM [Fwd: Re: Consistent Wording for InjectiOleers - Well Integrity ... . - specific to Ala 2C for Kuparuk, there is wording that is more appropriately included in Well Integrity Failure (i.e., more frequent MITs when communication demonstrated) - establishes more frequent MIT schedule for slurry injection wells (every 2 yrs) which is consistent with our current practice (but not addressed in regulations) Well Integrity Failure - retitles to "Well Integrity Failure and Confinement"; inserted language regarding injection zone integrity (see DIO 25 and 26) - consistent language regardless of type of injection (disposal, EaR, 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, EaR, storage); - uses "administratively waive or amend" in lieu oftenns like "revise", "reissue", etc.; - adds geoscience to "sound engineering principles"; - language is more generic regarding fluid movement out of zone; existing versions mention varying combinations of protecting "freshwater", "aquifers", "USDWs"; "risk of fluid movement"; "fluid escape from disposal zone" Jim Regg John K. Norman <John Norman~admin.state.us> Commissioner Alaska Oil & Gas Conservation Commission 20f2 10/2/20044:07 PM JF~d: Re: Consistent Wording for Injection.s - Well Integrity... . Subject: [Fwd: Re: Consistent Wording for Injection Orciers-. Well Irttegrity (Revised)] Fr()Dl: John Nonnan <john__nonnan@admin.state.ak.µs> Date: Fri, 01 Oct 2004 11:08:55 -0800 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 200415:46:31 -0800 From:Rob Mintz <robert mintz~law.state.ak.us> To:dan seamount~admin.state.ak.us, ¡im regg~admín.state.ak.us, john nonnan~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 red lines on the second document attached. »> James Regg <jim regg@admin.state.ak.us> 8117/20044:33:52 PM »> Please delete previous version (email sent 8/9/04); I found another inconsistency in the injection orders regarding well integrity that I have integrated into the proposed fix. Attached is a proposal for consistent language in our injection orders addressing 3 rules related to well integrity: - "Demonstration of Tubing/Casing Annulus Mechanical Integrity" - "Well Integrity Failure" - "Administrative Actions". This proposal includes input from all Sr. staff (except Jack). If you agree with the approach, I'll work with Jody to prepare the public notice. Main points- Demonstration of Tubing/Casing Annulus Mechanical Integrity - standardizes the wording used for mechanical integrity demonstrations, and establishes abililty to grant alternate methods (e.g., temp survey, logging, pressure monitoring in lieu of pressure testing - specific to AIO 2C for Kuparuk, there is wording that is more appropriately included in Well Integrity Failure (i.e., more frequent MITs when communication demonstrated) - establishes more frequent MIT schedule for slurry injection wells (every 2 yrs) which is consistent with our current practice (but not addressed in regulations) Well Integrity Failure - retitles to "Well Integrity Failure and Confinement"; inserted language regarding injection zone integrity (see 010 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 10f2 10/2/2004 4:07 PM [Fwd: Re: Consistent Wording for Injectio.rs - Well 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 ofterrns 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", "USDW sIt; "risk of fluid movement"; "fluid escape from disposal zone" Jim Regg John K. Norman <John Norman(a¿admin.state.us> Commissioner Alaska Oil & Gas Cmservation Commission Content-Type: application/msword Injection Order language - questions.doc Content-Encoding: base64 Content-Type: application/msword Orders language edits. doc Content-Encoding: base64 20f2 10/2/2004 4:07 PM . . Standardized Language for Injection Orders Date: August 17, 2004 Author: Jim Regg Demonstration of Tubing/Casing Annulus Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before injection begins, after a workover affecting mechanical integrity, and at least once every 4 years while actively injecting. For slurry injection wells, the tubing/casing annulus must be tested for mechanical integrity every 2 years. The MIT surface pressure must be 1500 psi or 0.25 psi/ft multiplied by the vertical depth, whichever is greater, must show stabilizing pressure and may not change more than 10% during a 30 minute period. Any alternate means of demonstrating mechanical integrity must be approved by the Commission. The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests. Well Integrity Failure and Confinement The tubing, casing and packer of an injection well must demonstrate integrity during operation. The operator must immediately notify the Commission and submit a plan of corrective action on Form 10-403 for Commission approval whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, or log. If there is no threat to freshwater, injection may continue until the Commission requires the well to be shut in or secured. A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating pressure communication or leakage. Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. . . Standardized Language for Injection Orders Date: August 17,2004 Author: Jim Regg Demonstration of Tubing/Casing Annulus Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before injection begins, at least once every four years thereafter (except at least once every two years in the case of a slurry iniection well), and before returning a well to service follo\ving aftef a workover affecting mechanical integrity, and at leœ;t once every /1 years v;hiIe actively injecting. For slurry injection wells, the tubing/casing ar..nulus must be tested for mechanical integrity every 2 years. Unless an alternate means is approved bv the Commission. mechanical integrity must be demonstrarcd by a tubing pressure test using a +lte M-I+-surface pressure of must be 1500 psi or 0.25 psi/ft multiplied by the vertical depth, whichever is greater, that ffil:tSt-show~ stabilizing pressure that doesand may not change more than 10%- percent during a 30 minute period. -:Â:fty altemate means of demonstrating mechanical integrity mœt be approved by tho 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 Except as otherwise provided in this rule, +!he tubing, casing and packer of an injection well must demonstrate maintain integrity during operation. 'Whenever any pressure communication, leakage or lack of iniection zone isolation is indicated by iniection rate. operating pressure observation, test, survey, log. or other evidence. t+he operator fFH:tSi-shall immediately notify the Commission and submit a plan of corrective action on a Form 10-403 for Commission approval" '1;hene\'er an)' pressure communication, leakage or lock of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey. or log. The operator shall shut in the well if so directed bv the Commission. The operator shall shut in the well without awaiting a response from the Commission if continued operation would be unsafe or would threaten contamination of freshwaterIf there is no threat to fresh'l;ater, injection may continue until the Commission require::; the '.\"ell to be shut in or secured. 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. ·[F;d: Re: [Fwd: AOGCC Proposed WI Lana for Injectors]] . SubJect: [Fwd: Re: [Fwd: AOGCCProposed WI Language for Injectors]] ~..om:Winton Aubert <winton__aubert@admin.state.ak.us> Date:Tu, 28 Qct 200409:48.:53-()800 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 -------- AOGCC Proposed WI Language for Tue, 19 Oct 2004 13:49:33 -0800 Engel, Harry R <EngeIHR@BP.com> winton aubert@admin.state.ak.us Injectors Subject: Date: From: To: Winton... Here are the comments we discussed. Harry *From: * NSU, ADW Well Integrity Engineer *Sent: * Friday, October 15, 2004 10:43 PM *To: * Rossberg, R Steven; Engel, Harry 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* ** 10f3 10/28/200411:09 AM [Fwd: Re: [Fwd: AOGCC Proposed WI Laee for Injectors]] . returni.ng a well to service following a workover affecting mechanical integrity." After a workover, the slope AOGCC inspectors want the well warmed up and on stable injection, then we conduct the AOGCC witnessed MITIA. This language requires the AOGCC witnessed MITIA before starting injection, which we are doing on the rig after the tubing is run. Just trying to keep language consistent with the field practice. If "after" was substituted for "before", it would reflect current AOGCC practices. It would be helpful if the following language required reporting by the "next working day" rather than "immediately", due to weekends, holidays, etc. We like to confer with the APE and get a plan finalized, this may prevent us from doing all the investigating we like to do before talking with the AOGCC. "Whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, log, or other evidence, the operator shall * immediately* ** notify the Commission" - This section could use some help/wordsmithing: "A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating well integrity failure or lack of injection zone isolation." Report content requirements are clear, but it's a little unclear what triggers a well to be included on this monthly report. Is it wells that have been reported to the AOGCC, are currently on-line and are going through the Administrative Action process? A proposed re-write would be: "All active injection wells with well integrity failure or lack of injection zone isolation shall have the following information reported monthly to the Commission: daily tubing and casing annuli pressures, daily injection rates." Requirements for the period between when a well failure is reported and when an administrative action is approved are unclear. This document states "the operator shall immediately notify the Commission and submit a plan of corrective action on a Form 10-403". If we don't plan to do any corrective action, but to pursue an AA, does a 10-403 need to be submitted? The AOGCC has stated they don't consider an AA as "corrective action". Let me know if you have any questions. Joe -----Original Message----- From: Kleppin, Daryl J Sent: Wednesday, September 29, 2004 1:37 PM To: Townsend, Monte A¡ Digert, Scott A¡ Denis, John R (ANC) ¡ Miller, Mike E¡ McMullen, John C Subject: FW: Public Notices FYI -----Original Message----- From: Jody colombie [ mailto:jody colombie@admin.state.ak.us Sent: Wednesday, September 29, 2004 1:01 PM Subject: Public Notices Please find the attached Notice and Attachment for the proposed amendment of underground injection orders and the Public Notice Happy Valley #10. Jody Colombie «Mechanical Integrity proposal. ZIP» «Mechanical Integrity of Wells Notice.doc» 2 of3 10/28/2004 11 :09 AM :::t: 00 ~ OCT. 1.2003 1:46PM UNOCAL Alaska Resources ANNA Platform Fax Cover Sheet To~ Name: ..,,,Torn Depatbnent: From; Name: De(\t1 Ls ; - PC_v-Je. ~- \ . Department: I - -~I Remarks: - " . \"-' NO.616 P.l ¥~ UNOCAL Oil & Gas Divi~ìon P.O. 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Date lira On Valu"" Injected TBG ,,~re.s 9.625 CS~ "Press 13~~75 C~'J Press ,,) Co",",snts 9/1/200S 0 - 0 0 0 .. 22C .." 9/2/2003 '" 0 0 0 '" q .--. 22C - - 9/3/;2.003 0 0 -. 0 0 22C "91412003 0 0 0 Q 22C '" 9/5/2003 0 22C 0 0 0 9/612003 Q '" '0 0 0 22& 917/;2.00'3 0 0 0 .,. 0 220 "'9/8/2003 0 0 0 0 0 ~{9/2ÕÒ3 0 ,- 0 0 0 22C1 9/1012003 0 0 ,0 0 0 9/11/2003 0 Ö 0 (f 220 :- 9/121200~ Q .." 0 ~ 22Ø 9/1312003 0 0 0 220 ,~ 9/14J20p3 u- 0" (f 0 --" 220 -- -9/15/2003 0 0 0 220 9/161?D03 0 °, 0 220 9/1712003 0 -'" 0 0 220 9/18i2003 0 0 0 22) 9/1912003 0 0 0 22) 9/20/2003 0 0 0 22) 9J21}2003 0 0 0 0 9/2212003 0 0 0 -. , 22) '" 9/23/2003 if 0 0 - .221.1 9/24Ï20_03 0 0 0 223 9/2512003 0 0 0 221') 9/26/2003 0 Ö 0" 22J 9127/20Õ3 0 0 0 223 9!2å12003 0 0 0 2!iÖ 9/29/2003 ... 0 0 0 0 ~V 9Ï30/2003 0 0 0 22~ C. ¡('A~ ~'i\, ~ ìi\U:: t ' ,..,?;v ,~,\\,; \)¡¡..,t-- 0 2 2004. OCT. 1.2003 1:47PM NO.616 P.7 1 Re.po'ô Name .. I Tb-g Strinv I' ' Montl:a-.- -' I I API No .n J Platfortn I bäte Crsatød I Year Monthly Injector Va_ñance AN29~ Sep 2003 50733203100-0... , ANNA pu, TFORM 10"12003 Date .1:'.i$ On Volume I"njected r.Bß press 9.625 CSG Press 13,.~75 Css Press Commeñts 9/~/~90'3 0 0 0 0 '0 .." ,.. 91212003 tJ 0 ..ow 0 0 0 9l3(tO'03 '0 -- 0 0 0 .~ 9/412003 0 0 -. 0 0 0 9/5/2003 0 () 0 .j)" 0 -9-'6J20Q~ 0 '0 0 0 - , 0 . Jtn/20D3 0 0 ..,-- 0 0 0 9/8/2003 0 0 0 0 "" 0 .-. 91912003""' 0 0 ,0 0 "'0 9/1012003 Õ' 0 0 0 0 9/1112003 .. 0 Ö' 0 0 ". 0 9/12120D:$ 0 0 0 0 0 9/13/2003 0 0 0 0 0 9/1412003 0 ". , 0 0 .0 -, 0 911512003 0 0 0 0 0 -..., Q. 0 0 0 Q .._9/1612003 9/1112003 0 å 0 0 0 9/18/2003 0 0 0 0 'ò --911 W?P03 0 0 0 0 --.. ( 912012003 0 0 0 0 ë 9/2112003 O . - "."'0 0 0 C ". ØL22I20D3 () 0 ._" 0 0 C 9/23/2003 0 0 0 0 C 912412003 0 0 b ... 0 è 9/2512003 0 Q 0 0 C '.. ~1?612003 0 0 Ö ".., 0 Ó 9/2712003 0 ö." 0 0 0 912812003 0 ... 0 '0 0 0 9/29/2003 0 0 0 - 0 C~ , 9/3012003 .. 0 0 0 0 ~ 0 2 2004 OCT. 1.2003 1:48PM NO.616 P.8 l Report Name ~ Tbg String J Month 1'- .~::; ' APIN9 I PI8LtO om I Date Creatëd I Monthly Inject~r Variance .' , , AN 32-42 Sep 507332029801 ANNA PLATFORM __10/112003" Date Hrs On V"I"ume'lnJected TBG Pr~sri 9.625 CSG Press ---13.375 c,sg Pres~ -- Comments 9/; 12003 24 188 2435 2400 - 365 9/212003 22 180 ,2358 2~50 33jl J1i3/2003 24 193 2436 ,- 2436 34' 9/4/200~ 24 191 -2445 2445 -. , 342 Q/S'f2003 21 179 2445 .' 2445 5 9f6~903 8 82 2155 2155 39' J~f7/2003 24 195 2353 235! 39" 9/8/2003 24 192 . ?392 24~O 356 9/912003 24 190 2414 2400 358 ~(1 012003 "18 142 1~g2 ". 1500 333 9/11/200~ 0 0 480 500 ---. 383 Ø!, 212003 0 -", 0" 283 ~QO saj 9/1312003 11 134 2458 2420 377 9f14120C3 24 23"6 2455 ' , 2400 - " 347 '- ., - 9/15120.03 24 223 2531 2531 34ß 9/16/2003 24 221 -"2563 2563 -'351J 9/1712003 24 - 222 2677 2577 352 9/'812003 24 220 " , 2594 2600 352 "9/19g003 24 .. 219 '~5_97 2600 35~2 "" 9,~O/2003 24 218 ._2548 2550 ,35:3 9/2112003 16 156 2548 2550 35~ 9/2212003 24 20~ 2470 - 24t5~. 385- .. 9/23/2003 23 214 2530 -"2500 385 9/2412003 " ..?4 222 2570 2550 385 9125/20Q~ 24 221 .. 259Q 2600 385 9[2612003 24 ?17 2600 " 2600 Sß5, 9/2712003,- 24 217 2505 ", 2600 385 "-912812003 - 24 2;6 ..2615" 2600 ~85 9129/2003 24 212 21322 - 2800 384 9/3012003 2'" 209 ", 2397 2397 383 ." 0 2 20D4 OCT. 1.2003 1:48PM NO.616 P.9 I Report Name -, l Tbg String' F Mont~ .-- I API Ña l Platfo l'n' t Date Created I Y&ar Monthly Inje~~~r Variance _AN 37-42 .. Sep 20Ø3 5073,~2039400n - ÃNNA PLÄTFORM 101112003 Date Hrs On Volume Injected TBG Press 9.~ZS CSçtPress 13.375 CS3 Pre. Comments 9ïÙ2003 0 (L 0 0 378 91212003 9 0 -.. 0 0 37: ...- 913/2003 .. a 0 0 0 37 . . 0 38$ 9/4/2003 0 .Q. 0 ~/51?OO:Ç 0 0 "" q 0 -. .3~. ' 9~I2Q03 ~- 0 0 - 0 917/2003 0 0 0 0 ".~~f 9/8/2p03 0 0 0 0 91912003 0 '0 0 0 - ~;t .. 9/1 O!2Ò03 9 ---. 0 0 0 9111/2003 0 0 0" 0 381" 9/1212Õ03 .. 0 " 0 0 0 381 ,. ,~m 312003 0 .. 0 0 0 381 ." 9/1412003 -. 0 0 0 0 377 ,. 9/15/2QD~ õ' 0 0 0 371 9/16[2003 0 - a 0 0 ~i7' -,. 9/1712003 0 0 0 Õ 377 9/191200-3 0 0 0 0 373 . 9/19/2003 0 0-" I) 0 375 91201200S 0, 0 .., 0 0 372 ....~/2112003 0 ._0 0 0 an 9/2212003 " 0 0 ( 0 375 9~3/2003 Ö 0 0 0 375 9/2412003 0 Q 0 0 - ~75 9!2512003 .. 0 0 0 0 375 -. 375 9/2612003 0 0 0 0 9127~OÕ3- 0 0 0 0 375 1" -- - 912812003 0 0 0 0 37~. 9/2912003 0 0 0 0 ~?5 9130/2003 0 0 0 0 375 SC!~NNED JUL 0 2 2004. ') \ NO.616 P.10 OCT. 1.2003 1:48PM I Report Name 1 TbV String I Month r ""Ÿear I API No I Pla~rm ""., 1 Date Croai:ø~" I Monthly Injector Va~i~t)~ë"-- ÄN 3B-42 Sap 2003 507~32ö3gBOO ANNA P~TF~RM 10/112Ø03 Data Hrs On . Vo~~.me Injected. ..JBG prëS$ 9.625 CSG Press ~~75 Csg "~~~S- Comments 911/2003 24- 0 2445 .2~50 37') , 912/2003 22 0 -2370 2400 394 9/3/2003 24 .__n." 11 2448 2450 394 24'--- - ..--- 2461 39) 9/412003 0 2461 91512003 21 0 2461 2461 16J ~/S~P03 e 10 2170 2200 _~83 9/7/2003 24 6 2367 _2361'''''' 383 g/8I200~ u 24'" 0 2406 2400 388 91912003 ".2~ 0 2428 24ÕO -. 384 9/1q129P3 -- , 18 0 11403 1450 381 9/11/2003 0 0 0 0 392 9/1212003 0 0 .-.--- 0 0 381 9/1312003 11 43 2461 ..- -. 2400 ~8( .." 9/1412003 - 24 34 2461 2450 386 -." 91151200~- 24 '2S 2542 2.542 381 ---.- 9f1612003 24 27 2570 -. 2570 381 9/17/2003 24 .- 27 2592 2592 381 9/18/.2003 24 28 -~~~B 2600 -- 381 ~/:!.~12003 211t. "_...~ 2608 2600 378 912012003 24 31 2553 2553 -..-,',.". 37¡-'- ~l~1120-03 16 . -. 30 2553' 2553 377 9/2212003 24- - . 39 2470 2500 360" 9/2312003 23 -"34 2530 2550 3ecl. -. 9/2412003 . - 24 31 2580 2600 3EC 9/25/2003 24- 30 2600 2600 3~0 .. . 2610 ~eoo 9/2612003 24 29 ......... 350 .- -912712003 24 ,". ,2~ 2605 26QQ "..,. -'r' 3S-0 9/2812003 24 29 2625 ,. 2600 35-Cf" 9/2912003 24 28 2636'"'' \ 2639 3£9 ,. -. 9/3012003 24 28 2414 2414 3£9 .- r'. ,\ h""'Y'. n ¡ç" n $)?í'ilÌå' OCT. 1.2003 1:48PM ) NO.616 P.ll I TO' °Year ¡ ., Report Name I Tbg String. 0 . MOJ;l~". - API No I Platform I Date Created I Monthly Inlactor Variance AN .6..2 Ssp 2003 507332035500 ANNA P~T¡:ORM 101112003 Date HršÖö' ... ~oIU~e '~J~~*,d TBG Press 9.625 eSG Press 13.375 Csg Press .. Com",_a)lts --.-. 9/112003 0 0 0 1280 '--340 912/2003 0 0 0 . _J 280 340 9/312003 0 "'õ. 0 1280 330 9/412003 0 0 0 1280 -3~0 9/512003 0 0 Q 1280 70 '" 9ï612003" 0 0 0 .1?80 330 9/712003 0 0 0 1280 3!,O. 91ãi2(få3' 0 0 . --.<1 1280 330 9/912003 0 ..". 0 0 1280 3~(f 9/1 O~2qO? - ..- ." "-" 0 0 0 1280 330 9/11/2003 0 0 0 1280 33(1 ..,. 9/1212003 0_._- 0 128Q..' 3~O 9/1312003 ., --- - .- 0 0 0 1280 ~O 9/1412003 0 0 1260 3~O 911512003 0 0 .~~6Õ' -.. ,,~. 3~O ". 9/16i2Q9.3 0 0 1260 3Z0 9/1712003 0 0 " 1260 3~O 9'/18I2.o.qa 0 0 1260 ~SO 9/1912003 0 .._- 0 1259._- -- 3~0 9/201200~. -..-.-......" 0 0 1240 330 9/21/2003 0 0 1240 3;)0 9/2212003 0 0 1230 3S0 . ~12312003 0 0 1230 350 9/24/2003 0 mo 0 1220 330 9/25/2003 0 0 1220 3~O . .,-.- -'\ -- 0 0 1220 3~Ò- 9/26/2003 9/27/2003 a õ'" 1210 . . 3~O ,.. 9/2812003 0 0 1210 330 9/2912003 0 0 0 1210 3~0 9/30120Q3 0 0 l.~OO 330 SCANNED JUL \} 2 20ü4 ::t:t: -....J ) ') " .T~ AMOCO ~I~ Amoco Production Company Denver Region 1670 Broadway P.O. Box 800 Denver. Colorado 80201 303-830-4040 January 11, 1990 A A Ai {) f:.. L 1..C"~.1\,..r,I\-..~.,"-f¿. ~V. U 7';:;:~;~~! : ' ,/ ""l I..J ¡V! ¡A , 7 ,hf I ~~\f¡~~i3 ~ / O.I',.'.-.'.-".'.."'-...-...?.. :'.-..."'.-..:.',.;,-..---.'-~-.,. I'.>~~:d. \~,.:\.;~ ì-l ~-'t~ -- -- -;-" . '., I.: ,..,.",~.¡.;-.;".'-.,'.'\."...'.'.' .~l\-~I ..' 1(~~;-7/~~~:..L.- ~:,,'il j',,:::;?T I ,s.'r'¡';''''O'~i--,''.'..'. '.".' .',"F".'.' " (\, ~rr/.¿?'ø I~\l~('" ~~."'-'L.~:-.Ö".I...,' i.\,C'...:ë.".TI . c:: ~~I~~.~~!.,.r,i..~.i _~~rfE-CFf1- FlU::: AiO~/I--' ---:-:LL:~~~£..,~>r_~ W. D. Ford Regional Production Manager Alaska oil & Gas Conservation commission Porcupine Drive Anchorage, Alaska Attn: C.L. Chatterton File: JLh-60-400.1-LF Amendment to Rule 3 of Area Application Order No.6 Granite Point Field, Cook Inlet, Alaska Pursuant to Rule 3 Fluid Injection Wells of Order NO.6, and in reference to the January 9, 1990 telephone conversation between Amoco's C.L. Wiggs and C.V. Chatterton of the A.O.G.C.C., Amoco requests Rule 3 be amended to include item 4 as follows: '''On an emergency basis, through an existing producing well for purposes of storing crude oil production for enhanced recovery, even though the producing well is not necessarily equipped with tubing and packer." We request this amendment be put in place to allow for immediate action. Please advise B.L. Bren-Carley at (303) 830-4542 of your acceptance of this amendment, or Of your need for additional information, as applicable. Thank you for your prompt attention to this matter. oJ. J1 ~#I BLBC/slj Attachment cc: RECEIVED C.L. Wiggs K.J. Overcash G.J. Elledge JLH60400.1LF.8 .JAN 16 Jg~¡" Dil & Gas Cons Cor" ',,, Q 'IHJ~¿w', lmchorélý3 '. " , 0 2 20D4 :tt: 0\ ,,,£.O 8r-41': ..::,~ ~IS' ~. ~ ~ ~ -- -z. ~œ-~ 0 ~ "\ ~ ~1- ",-,0 ,..",,1.. PRO",~S.J . I,~ U.S. ....JVIRONMENTAL PROTECTION AGL.)CY REGION 10 1200 SIXTH AVENUE SEATTLE, WASHINGTON 98101 NÐV (..1986 REPLY TO A TTN OF: MIS 409 w. G. Smith, District Manager Amoco Production Company P.O. Box 100779 Anchorage, Alaska 99510 RE: Termination of EPA Rule Authorization for Injection Wells Dear Mr. Smith: The Alaska Oil and Gas Conservation COß111ission issued the Amoco Production Company Area Injection Orders No.6 for the Northern Portion of Grani te Poi nt Fi el d (Pl atforms Anna and Bruce)\ and No. '-'for the Northern Portion of Middle Ground Shoal Field (Platform Bakerr"ã:nâ-m>:-"'-S-for the Southern Portion of Middle Ground Shoal Field (Platform Dillon) on September 4, 1986. Therefore, the EPA rule authorization under either 40 CFR 144.21 or 40 CFR 144.22 for existing injection wells is terminated. Sincerely, ~~J Robert S. Burd Director, Water Division cc: C. V. Chatterton, AOGCC Alaska on & ~C/J~NNEC: ~JUL 0 2 200~l . . =+I:: Ut ~ ) I . ~. ~:~~f1{c~fþj=i!! Amoco Production Company! {:::())\~jV~ '7~/ Post Office Box 100779 I.. CC);\/..f./J,............ ~" Anchorage, Alaska 99510 ¡ é;;';U;;';' 907-272-8471 I --:-":'J Il¡jfi~; . "c' h. ,',», ~ I~+~H~~~ u::~ H:.E: . ,. "T~ AMOCO .I~ w. G. Smith District Manager October 6, 1986 File: FEW-251-986.511 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Area Injection Order No.6, Northern Portion of Granite Point Field Area Injection Order No.7, Northern Portion of Middle Ground Shoal Field Area Injection Order No.8, Southern Portion of Middle Ground Shoal Field Referencing our letter of September 30, 1986, File: FEW-232-986.511 and telecon between M. T. Minder and J. C. Blagg on October 3, 1986, we are re-submitting our proposed schedule for testing the mechanical integrity of the tubing/casing annulus on our water injection wells. The primary difference in scheduling is that we will now test each well at this time in order to obtain "baseline" surveys rather than test each well individually when its previous test becomes four years old. As with our earlier proposed schedule, each well will then be retested at least once every four years. For ease of operation, retesting on a per platform basis by the following schedule is suggested: Year Platform 1987 Baker 1988 Anna 1989 Dillon 1990 Bruce Tests will be updated every fourth year thereafter. Attached is our proposed test procedure and a listing by platform all injection wells with their respective packer setting depth, required annulus test pressure$ and relative comments. ktCEIVtD 1 0 1986 Alaska Oil & GJS Cons. c. V. Chatterton, Chairman FEW-251-986.511 October 6, 1986 Page 2 We will begin the annulus pressure tests as soon as possible following approval of our program. Please direct any questions to Jeff Blagg at 562-2147 . ..-------- Very truly yours, ø. /' 1'. ~~.//'" .... ..://¡>'" .. (/'/ ~. "'/ ' .~ ",,/..., w. G. Smith District Manager cc: S. W. Souders M. E. Siekawitch JCB/ j r 117/jcb1 'iD 1 0 1986 ;. 2' 20fìi1 \}, . ,G':j ) TUBING/CASING PRESSURE TEST 1. Give the AOGCC (279-1433) 24-hour notice that an injection well annulus pressure test will begin. 2. Install a chart pressure recorder on the tubing. The recorder should have a 24-hour clock and a pressure range exceeding the injection pressure. 3. Install a chart pressure recorder on the tubing/casing annulus. The recorder should have a 24-hour clock and a 0-5000 psi pressure range. 4. When the AOGCC witness arrives, begin the injection well annulus pressure test as follows: A. Examine chart recorders to ensure that they are properly working. . B. Pressure the tubing/casing annulus to 1500 psi or (.715-packer fluid gradient) x TVD of packer, whichever is greater. C. Shut in the tubing/casing annulus and monitor for 30 minutes. This pressure must not change more than 10 percent for the well to pass the test. D. If the well passes the test, it may remain active. If the well fails the test, it must be shut-in until corrective action is taken. 5. Remove chart pressure recorders and send charts to the Anchorage office. The packer fluid gradient for the Amoco operated water injection wells is approximately 0.45 psi/foot. The fluid is filtered Cook Inlet water containing corrosion inhibitors and pH controllers. 02WW Date Existing Operating Completion Well No. Status Run 7RD Injecting 02/85 13 Shut-In 05/84 17 Injecting 01/84 Injecting 12/84 Injecting 04/83 Shut-In 06/80 19 27RD 28 f!.J'j (""I '''''"' <"y :z f~,~ (.~ rn r 29 Injecting 01/84 Injecting 12/84 Injecting 01/80 ..~ 46 t'~ rv c::;j :F2 MUC-I-3 TABLE 1 PLATFORM ANNA '~~) (.Jœ! t.J.:-~{~ Tubing/Casing Pressure Test Packe r Setting Depth 9,154 MD 8,706 TVD 8,233 MD 7,709 TVD 9,590 MD 8,956 TVD 8,273 MD 8,173 TVD 8,065 MD 7,569 TVD 8,096 MD 7,508 TVD 9,117 MD 8,871 TVD 8,200 MD 7,921 TVD 9,589 MD 7,989 TVD Required Annulus Test Pressure 2300 2050 2375 2175 2000 2000 2350 2100 2125 ~--> i' ''""i t~~ Remarks Well 5.1. because of collapsed casing above pay horizons. The well is currently being evaluated for redri 11 . Well 5.1. pending workover for injection conformance. These repairs should commence during 1987. {eL) Ç(:J C:J) , 4?''''''~i fJ') ¡:;~ ;C~ 8 <""".1 OJ? C';~ C!5 c<:i E £j 1i:¡ ~Æ ~ ~' , . TABLE 2 PLATFORM BRUCE .~ .-,93 Tubing/Casing Pressure Test ~~ 'i..'JY '"f' {'$þ' (i', Date Required r.,'?~~~t1;tt v~,J 't7 " Existing Packer Annulus Ç)~ Operating Completion Setting Test ~ Gf;" Well No. Status Run Depth Pressure Remarks ~ 5RD-86 Shut-In 02/79 8,210 MD 2050 Well shut-in pending workover for injection '--" 7,750 TVD conformance. These repairs should commence during 1987. 3-87 Injecti ng 05/84 7,810 MD 1875 7,093 TVD 6 Shut-In 05/84 8,250 MD 2150 Well shut-in pending workover for injection 8,146 TVD conformance. These repairs should commence during 1987. 10 Injecting 05/86 8,600 MD 2150 8,086 TVD 12RD Shut-In 09/79 8,700 MD 2275 Well shut-in pending workover for injection 8,595 TVD conformance. These repairs should commence during 1987. 14 Injecting 09/85 9,150 MD 2250 8,515 TVD 16 Injecting 09/77 8,955 MD 2075 7,810 TVD C) 31 (¡:;~ Shut-In 06/84 9,340 MD 2300 Well shut-in pending workover for injection ~ 8,665 TVD conformance. These repairs should commence c:J c::> ~ during 1987. -. TABLE 3 PLATFORM BAKER Tubing/Casing Pressure Test Date Requi red Existing Packer Annulus Operating Completion Setting Test Well No. Status Run Depth Pressure Remarks '- -- 4 Injecting 04/84 7,031 MD 1875 7,031 TVD 8RD Injecting 03/85 6,047 MD 1550 5,891 TVD 9RD2 Injecting 06/83 8,527 MD 2150 8,110 TVD 12 Injecti ng 03/85 7,050 MD 1600 6,040 TVD 18 Shut-In 02/82 8,844 MD 1900 Well shut-in pending workover for tubing 7,157 TVD leak. This repair should commence during 1987. '~ ~ f'>-.,) c:) <::.:::;, ~ TABLE 4 PLATFORM DILLON TubinfJ/Casing Pressure Test Date Required Existing Packer Annulus Operating Complete Setting Test Well No. Status Run Depth Pressure Remarks 8RD Injecting 09/85 9,750 MD 2400 8,997 TVD 9RD2 Injecting 06/85 10,200 MD 2500 9,464 TVD 11 Injecting 01/81 9,320 MD 2400 9,002 TVD 12 Injecting 06/81 10,051 MD 2300 8,627 TVD ~n ç! ¿; ~~ ¿. n=, c; c~ C:.: 1-." c:;, t~) t'0 t::) t:::::2> ..{~ ~ :::t: ~ ,4f¡;' J6ü/ --þ: ) Á e.$ ~ ~ ..... .,92}~~~--- ¥ ~ . .1./ .. 1 "":~".~"C 0 r.;,.Ai r' II .1....£! ,''1 Úf1 ~, ~~ki~,;,,:;''''._''~' .. '. -, ~ \¡¡ i ~V:J, pi tJì,,-~ C()M~' J l Amoco Production Comp;rV:Œ;f~" i=';:,K~- I .. Post Office Box 100779 SF¡ E>r:.~ "-/ . Anchorage. Alaska 99510 '(q ",,~--------:-J 907-272-8471 ¡ c,N:':'!J II œ~jfi~~ .. 1=. ~. P\l r':.:t . '." f"...'."..". ..^r. "-I'~. ¡ ':'~ ~--~'":~~- ~..."\ .,~~ v ~~!.!~t_~r~911r ISTArTEC~ FILE: ') ( ~ , W. G. Smith District Manager September 30, 1986 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Conmission 3001 Porcupine Drive Anchorage~ Alaska 99501 File: FEW-232-986.511 Area Injection Order No.6, Northern Portion of Granite Point Field Area Injection Order No.7, Northern Portion of Middle Ground Shoal Field Area Injection Order No.8, Southern Portion of Middle Ground Shoal Field Regarding Rule 6 of the captioned Area Injection Orders, Amoco Production Company is required to develop and coordinate with the Commission a schedule for testing the mechanical integrity on each water injection well tubing/casing annulus. We presently have active four water injection wells with completions four years old or older, and we propose renewing the tubing/casing annulus pressure test on these wells by December 31, 1986. Our other water injection wells will be tested when the existing completion becomes four years old or following repair work, and every fourth year thereafter. Please see the attached Tables 1-4 which list by platform our water injection wells and the date of the next tubing/casing annulus pressure test. Also attached is our proposed tubing/casing annulus test procedure. Please direct any technical questions you might have to Jeff Blagg at 562-2147. Very truly yours, 1tJ~L4x W. G. Smi th Di stri ct ~1anager JCB/dds Attachments RECEI'IED cc: S. W. Souders M. E. Siekawitch i} ÍJ 3 1986 Alaska Oil &. Gas {'~~1~~" UU¡¡.)II'Ss'on r'ln~b¡-.,",-,.,,.., . j l''\...¡''u\.j¡ d~Jc {.~lt-.......v¡ UL ) TUBING/CASING PRESSURE TEST 1. Give the AOGCC (279-1433) 24-hour notice that an injection well annulus pressure test will begin. 2. Install a chart pressure recorder on the tubing. The recorder should have a 24-hour clock and a pressure range exceeding the injection pressure. 3. Install a chart pressure recorder on the tubing/casing annulus. The recorder should have a 24-hour clock and a 0-5000 psi pressure range. 4. When the AOGCC witness arrives, begin the injection well annulus pressure test as follows: A. Exami ne chart recorders to ensure that they are properly working. B. Pressure the tubing/casing annulus to 1500 psi or 0.25 psi/ft x TVD of packer, whichever is greater. C. Shut in the tubing/casing annulus and monitor for 30 minutes. This pressure must not change more than 10 percent for the well to pass the test. D. If the well passes the test, it may remain active. If the well fails the test, it must be shut-in until corrective action is taken. 5. Remove chart pressure recorders and send charts to the Anchorage office. RECEIVED ;-- '.' 0 3 1qR6 AJaska Oil & G;~ ~ n 2 » .;æi TABLE 1 !t? ;:« ~ c. c:.~ -- :~ PLATFORM ANNA (:::.) ~ .. m ~~ ~ J m Tubing/Casing Pressure Test ~;.' -"-' .- -< :.D n¡¡ C)O en 0 Date Next Date Annulus Required Existing Pressure Packer Annulus Operating Completion Test Setting Test /~ll No. Status Run Required Depth Pressure Rema rks 7RD Injecting 02/85 02/89 9,154 MD 2175 8,706 TVD 0) Shut-In 05/84 05/88 8,233 fvtD 1925 ./ ",,",",.IY 7,709 TVD 17 Injecting 01/84 01/88 9,590 MD 2250 8,956 TVD 19 Injecting 12/84 12/88 8,273 r~D 2050 8,173 TVD 27RD Injecting 04/83 04/87 8,065 MD 1900 7,569 TVD ~' l Shut-In 06/80 See 8,096 MD 1875 Well S.I. pending workover. Annulus will be Remarks 7,508 TVD pressure tested following workover. 29 Injecting 01/84 01/88 9,117 MD 2225 8,871 TVD 46 Injecti ng 12/84 12/88 8,200 MD 1975 7,921 TVD MUC-I-3 Injecting 01/80 See 9,589 MD 2000 Annulus will be pressure tested prior to 12/81/86. Rema rks 7,989 TVD ~ ~ ~ ~ (¡'-;, 1: ~ <- .~ :..~<\ ....-,t> (f1 ~ ¿ ~ <::) TABLE 2 PLATFORN BRUCE ~'Þ Ò c:::J C'4 ~~ '" 0 ~ Tubing/Casing Pressure Test G~ Date Next Date Annulus Required Existing Pressure Packer Annulus Operating Completion Test Setting Test /-'(ell No. Status Run Required Depth Pressure Remarks 5RD-86 Shut-In 02/79 See 8,210 MD 1950 Well shut-in pending workover. Annulus will be Remarks 7,750 TVD pressure tested following workover. 3-87 Injecting 05/84 05/88 7,810 MD 1775 7,093 TVD 6 Shut-In 05/84 05/88 8,250 MD 2025 8,146 TVD 10 Injecting 05/86 05/90 8,600 MD 2025 8,086 TVD 12RD Shut-In 09/79 See 8,700 MD 2150 Well shut-in pending workover. Annulus will be Remarks 8,595 TVD pressure tested following workover. .-- ~. "4 I njecti ng 09/85 09/89 9,150 MD 2125 8,515 TVD 16 Injecting 09/77 See 8,955 MD 1950 Annulus will be pressure tested prior to 12/31/86 Remarks 7,810 TVD 31 Shut-In 06/84 06/88 9,340 MD 2175 8,665 TVD TABLE 3 t":~}~ '":::::J c:::J PLATFORM BAKER ('.J (i~ 0 Tubing/Casing Pressure Test ~...J :::J --) Date Next Date Annulus Required Existing Pressure Packer Annulus Operating Completion Test Setting Test ~:ll No. Status Run Required Depth Pressure Remarks .~. 4 Injecting 04/84 04/88 7,031 MD 1750 7,031 TVD 8RD Injecting 03/85 03/89 6,047 MD 1500 5,891 TVD 9RD2 Injecti ng 06/83 06/87 8,527 MD 2025 8,110 TVD 12 Injecti ng 03/85 03/89 7,050 MD 1500 6,040 TVD 18 Shut-In 02/82 See 8,844 MD 1800 Remarks 7,157 TVD ~"- Well shut-in pending workover. Annulus will be pressure tested following workover. .-.., TABLE 4 PLATFORM DILLON Tubing/Casing Pressure Test c;;~-~~;=, c;:.') C=> {'...! (;<:1; Ç,) Date Next Date Annulus Requi red Existing Pressure Packer Annulus Operating Completion Test Setting Test ;-.~ 11 No. Status Run Required Depth Pressure 8RD Injecting 09/85 09/89 9,750 MD 2250 8,997 TVD 9RD2 Injecting 06/85 06/89 10,200 MD 2375 9,464 TVD 11 Injecting 01/81 See 9,320 f4D 2250 Annulus will be pressure tested prior to 12/31/86. Remarks 9,002 TVD 12 Injecting 06/81 See 10,051 MD 2150 Annulus will be pressure tested prior to 12/31/86. Remarks 8,627 TVD ¡.;.~~ r.;.~ ~.2J .¡; Remarks , -, ill '7P ~~. t;,) ~ ~" ~.", ::tI:: l;J .:I ) August 29, 1986 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 COMM -, 'I' CÒfvA.M I cor.,;1M I Amoco Production Com pan' pES ENG I ç~n c1¡\ln I Post Office Box 100779 '-.J ó' ,. . ''''. Anchorage, Alaska 99510 SR EN3 I 907-272-8471 "END . I "J -SR GEOL I SR GEOt I eNëfÄsst, ENG-ÁSST I STATTECH 'STAT-TECH! .FILE: ~ "'T~ AMOCO .I~ w. G. Smith District Manager File: FEW-220-986.511 f( () f& Supplemental Data on Waste Disposal Horizons Area Injection Order Applic~.ti~~s~~;},'./"i'~~~ ~ Mi ddl e Ground Shoa 1 an(G¡íll¡lj¡~è"','::I~¡\1¡!rï:e';:;P'irÎ11';él'sr / ~ In reference to our applications for Area Injection Orders, Platforms Baker and .Di 11 on at the Mi dd1 e Ground Shoal Fi e 1 d, and Platforl11sAnna and Bruce at.the Granite Point Field, the attached supplemental data concern- ing horizons for waste disposal is submitted for your consideration. Please contact Mr. Jeff Blagg or Mr. Fred White at 562-2147 if you have questions or require additional information. .' ,.:~::~.:~ " -~.,.,.~~:;:~. Sincerely, øß~ .' ~;rif;:.: w. G. Smith District Manager JCB/dds Attachments lOB/jcbl .", RECE\VED SEP 0 4 - Comm\sston 01 & Gas Cons. A'aska' Anchorage , 'J: ~" . f} '.-r':1 ~~( ./~~ '~~:., ) WASTE DISPOSAL HORIZON INFORMATION PLATFORMS ANNA AND BRUCE ,GRANITE POINT FIELD The horizons affected by injection for waste disposal are defined by the following depths in the Mobil-Union Granite Point No.1 well: Horizons Name Measured Depth 5,941 - 6;432' 6,432 - 7,714' True Vertical Depth 5,920 -6,411' 6,411 - 7,693' Kenai Group Tyonek "A" Sand .Kenai Group Tyonek "Bit Sand The Tyonek "A" and "B" sands are an argillaceous channel sandstone and conglomerate. interbedded with siltstones, shales, and coals. The sandstone and conglomerate is predominately quartz and chert with inter- spersed igneous and metamorphic rock grains. The confining zones between, above and below the disposal horizons are a series of tight, impermeable siltstones and shales, varying in thickness from 50 to 200 feet. RECE\VED SEPOl4- ~nmm\ss\on 0'\ & Gas Cons. \IV A.\aska \ AnchoJage 02 ') WASTE DISPOSAL HORIZON INFORMATION PLATFORMS BAKER AND DILLON MIDDLE GROUND SHOAL FIELD The horizons affected by injection for waste disposal are defined by the following depths in the Pan American Corporation State 17595 Well No.4: Horizon Name Measured Depth 2,620 - 3,090' 4,330 - 4,955' True Vertical Depth 2,534 - 3,004' 4,244 - 4,869' Kenai Group Tyonek "A" Sand Kenai Group Tyonek "C" Sand The Tyonek "A" sand is an argillaceous channel sandstone and conglomerate interbedded with siltstones, shales, and coals. The sandstone and con- glomerate is predominately quartz and chert with interspersed igneous and metamorphic rock grains. " The Tyonek "c" sand is composed of quartzitic, matrix supported conglomeratic sandstones, interbedded with siltstones, shales, and coals. The beds were deposited by braided streams migrating across the width of their flood plains. The confining zones between, above and below the disposal horizons are a series of tight, impermeable siltstones and shales, varying in thickness from 50 to 200 feet. RECE\VED SEP041Ø c mm\Ss\on 0\\ & Gas Cons. 0 /1.\aska /1.nchorage C... " ') ? n [',1 i I.., ..." ..', '--'''-.----''':',",'"""\ ,.,:11!1'! =+1:: N ') Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: The application of AMOCO PRODUCTION COMPANY for an Area Injection Order for the portion of the Granite Point Field developed by their Anna and Bruce platforms in the Cook In let. The Alaska Oil and Gas Conservation Commission has been requested, by letter dated July 15, 1986, to issue an order for area inj ection to provide authorization for utilizing existing service wells permitted for injection by the U.S. Environmental Protection Agency and subsequent service wells permitted in accordance with 20 AAC 25.005 or 20 AAC 25.280 to inject fluids underground for purposes of enhancing oil recovery from the Granite Point Middle Kenai Oil Pool, as defined by Conservation Order No. 76 and for the disposal of non-hazardous oil field fluids into shallower tertiary strata. Parties who wish to protest the granting of the referenced request are allowed 15 days from the date of this publication in which to file a written request for a hearing. The place of filing is the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska 99501. If a protest and request for hearing is timely filed, a hearing on the matter will be held at the above address at 9: 00 AM on August 30, 1986, in conformance with 20 AAC 25.540. If a hearing is to be held, interested parties may confirm this by calling the Commission's office, (907) 279-1433, after August 15, 1986. If no such ~rotest is timely filed, the Commission will consider the 1ssuance of the order without a hearing. Lp Lonnie C. Smith Commissioner Alaska Oil and Gas Conservation Commission Published July 31, 1986 JUL () 2 2004 STATE OF ALASKA ADVERTISING ORDER ') F R 0 M Anchorage Daily News P. O. Box 149001 Anchoragef Alaska 99514-9001 T 0 p U B L I S H E R Alask.a. Oil & Gas Conservation Cœmission 3001 Porcupine Drive Anchorage, Alaska 99501 ~ -_.- ..~QYERTISING ORDER NO. AO. AGENCY CONTACT Galyn Evans PHONE (907) 279-1433 DATES ADVERTISEMENT REQUIRED: July 31, 1986 SPECIAL INSTRUCTIONS: AFFIDAVIT OF PUBLICATION INVOICE MUST BE IN TRIPLICATE AND MUST REFERENCE THE ADVERTISING ORDER NUMBER. . A CERTIFIED COPY OFI.HIS AFFIDAVIT OF PUBLICATION MUST BE SUBMIITEQWITH THE INVOICE. Notlce.C# P,u~"cH~.a~'ln¡¡-- STt.,'r .' 'Aa::~$KA ATTAC '. CA. ,.. '.~rW~ ,i:'ATION HERE. ~,: ,Th¿';'~if'!\;'ii";~;;;"i . . f ~.RODUC .:M an Area J"J . ''Ør.d portion. of' Jh~. <~rjti FIeld. deve'~'þ.YI" . and. BruCetpIØtòr'. "I C~k Inl,t. '.'., j ....::'!:'~)i{!;;/J.:'~~Ìt; , . ~ UNITED STATES OF AMERICA STATE OF aL Pi~~ - S8 ~ DIVISION. BEFORE ME, THE UNDERSIGNED, A NOTARY PUBLIC TtilS DAY PERSONALLY APPEARED~.- ~ WHO, BEING FIRST DULY SWORN, ACCORDING TO LAW, SAYS THAT HE/SHEISTHE~ +O~^ J PUBLISHED AT~~ J1 -' IlAID DIVISION '""},, L AND STATE OFfT ~ND THAT THE ADVERTISEMENT, OF WHICH THE ANNEXED IS A TRUE COPY, WAS PUBLISHED IN SAID PUBLICATION ON THE ~+ DAY OF ~ 19&, AND THEREAFTER FOR (') f{oNsluTIVE DAYS, THE LAST PUBLICATION APPEARING ON THE ~AY °rt- 1~, AND THAT THE RATE CHARGED THEREON IS NOT IN EXCESS OF THE RATE ~ED PRIVA~IVIDU~ . ~.,..,."...... ~ .... ~ SUBSCRIBED AND $'WORN TO BEFORE ME THIS -Ll DAY OF. A1-^-.&. O..OT 19¡ f\v\lCWU :Px()(~/~ NOTARY PUBLIC FOR STATE OF MY COMMISSION EXPIRES My Commission E)(r f res: November 8J J 989 ..--- 02-901 (Rev. 6-85) PU BLISH ER REM I N DER- 08-5567 DATE OFAO. July. 29, 1986 ~~ >æ - N'\ LU ..... U C.!J LU=> æ~ 0 2 200,:~ II::; S CJ) CJ) 'š E 0 0 en CD CO) 0 C'J 00 CI).s:::. .." (.) ~~ oð ë5 œ .:a::: ~ <11 ~ ::tt: ÞO--I> ) ) ,. "T~ AMOCO ~I. Amoco Production Company Post Office Box 100779 Anchorage. Alaska 99510 907-272-8471 W. G. Smith District Manager July 15, 1986 Mr. C. V. Ch~tterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 File: FEW-174-986.511 Granite Point Field Area Injection Order Application Attached is the Granite Point Field, Platforms Anna and Bruce, Area Injection Order Application. Amoco Production Company, as operator of the Granite Point Field, requests that an area injection order be issued for existing and future injection wells in the field. The injection wells will utilize Tertiary age formations and will be used for fluid disposal or enhanced recovery. This application is submitted in accordance with the regulations of the Alaska Administrative Code, Title 20 - Chapter 25, revised April' 2, 1986. The transfer of authority from the EPA to the Commission affects both existing and future injection wells. Existing wells are authorized by prior permits and it is Amoco's understanding that those authorizations remain in place until an area injection order is issued. . Attached are five (5) copies of the application for your use. Please con- tact Mr. Fred White (263-2206) or Mr. Jeff Blagg (263-2207) if you have questions or require additional information. Sincerely, /(Jf~ W. G. Smith District Manager JCB/dds RECEIVED JUL 241986 Attachments Alaska Oil & Gas Cons. Commission . Anchorage '~NNED JUL Ð 2 2DDlJ ') ') SECTION A AREA INJECTION ORDER 20 AAC 25.460 Amoco Production Company, as operator of the Granite Point Field, Platforms Anna and Bruce, requests issuance of an Area Injection Order to authorize the use of service wells to inject fluids underground for purposes of enhanci ng oi 1 recovery, and for di sposa 1 of non-hazardous waste fluids generated during normal drilling, workover, and production operations. The Area Injection Order will encompass all lands within the boundary of the Granite Point Field (GP) as defined by Conservation Order No. 76. Conservation Order No. 76 is attached as Exhibit 1. The lease boundary and area operated by Amoco Production Company is shown in Figure A. RECEIVED JUL 2 q 1986 Alaska Oil & Gas Cons. Commission Anchorage 0 2 ZDD4 . I '-' ~ , . I RECEIVED JUL 2 4 1986 Alaska Oil & Gas ~ons. Commission Anchdrage I Ztf ¡q ZO. Z I ::11111111111111111 U I~III' II um III I II W - ,- - - - - 'Mlllê 30¿C¡ ~.2B - - - - - - ¡:tll UI II II IllmUJJ II ê_- ' ><-,-~ -.. "" . -Ëê --- - - - - - - - - - - - - 34 æ 35 3(0 3( 32J æ 33 - - ,- - - - - - -- ~ 11111111111 II nl f.-'"'''''''-''' 1._...__-.-- --~...,.- ',--- m---..ê '''-- '.'" .... - = = .... - ... - ¿:: I b 5:: 4 --- -- ,-----~ ----- - --- ,---~ ------ ------ § ~ II § J2- 7 8 § 9 , ~" .1 .'.. ~ --, -.-. ---'=lnllllnnnllllllllnllllllllll~nIlIlIIlIlITl1T(= "-- ,.'-~ ¡ , ~-~-1 I I .! - -"-"..--.. \ ........--"----- . 22 23 I I 27 2b 3 10 15: 1'-1 13 IS 17 . R 11 w-. .~ "'-,~..-. --A.., R1~W ----,...._- -- !...-....-.............-.... ." -'-- -- 2.Z -"""-"------ ~. 'II T , 11 :¿7 IN ¡ "--r- 34 3 --.... 'T 10 10 N /0 /5 .._-~-..,.,...-.....~-- _.'''.-~ I . u- - - . - Amoco Production Company GRANITE POINT FIELD FIGURE A .... ~'f'Atr*i~'\ ¡~ ~V: Ü')ìr-'tÍ'.~ I ~. H. ~ j; ::~ Ii r- *~, 1i II ¡¡ II /':'1. C"fJ f) n n Ii. ) f. SECTION B PLAT 20 AAC 25.402 (c) (1) 20 AAC 25.252 (c) (1) Figure B is a plat showing the location of all wells that penetrate the uppermost injection zone within the Amoco Granite Point Field boundary. ) ) =I~IIIIIIÎII ·IIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIII·I~ III i 1IIIIIIIIIIInlllll~IIIII.IIIIIIIIIIIII~ - . Ë- -:- . . , ~ - -Iæ- - - - - - - - - - - - - - - - - - - - - - - Z~IJIIIIII~ Zg ~ - 5 30 _ = 0 ~2 æ lid ~~ I 11111111111111111111111111111111111111111111111111111111111111= 6- - Ë- =1 14 ,æ - - - - - - - - :: 60 T :: = 4 = § -^- °34 20 II Ë = y 0 N = æ 31 :32:: ~ 35 36 -Il' 6 ~lR~ æ = ^ 6 Ylz - =} ~ :: = 5RD = - - - - - 3 30 - ~I BO 1-<:>- ° °fr °'6 ~ æ RI2w R' II W = - iiilllllllllllllllllllllllllllllllllllll= - - -{;>-4002.46Ib ¿' 610 :31 5 II 2 1 03¿ t) _ 2.7 RD ¿56 #-9ï T .~ 27 4767RD 10 :: N ~= 03C¡ ~? 30 04 015 036 1- 46 ,q 6 {), ¿q 7 8- 12 {), = z~ _ ~I 033 Z3~D 0.1.1 ¿7 ~ =1 Os 0 . = = ~ = - ffi 111111111111111111 611 ""'Iï ~ 1IIIIIIIIIIItllllllllllllllllllllllllllllllllllllllllllllllllllllllllllllllllllllliñiiiiïlllllIII (11f- f MUC-l, 6/ Muc-l l .T& AMOCO .. .r~ 26 35 13 o 6 II 14 13 18 . ~ __....w. "_ ______ Âmoco Production Company GRANITE POINT FIELD FIGURE B ') SECTION C OPERATORS/SURFACE OWNERS 20 AAC 25.402 (c)(2) 20 AAC 25.252 (c)(2) The surface owners and operators within the area of this Area Injection Order and extending 1/4 mile beyond the boundary (excluding Amoco Produc- tion Company) are: * State of Alaska Department of Natural Resources 3601 C Street Anchorage, Alaska 99503 * Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 ) See attached affidavit ') SECTION D AFFIDAVIT 20 AAC 25.402 (c)(3) 20 AAC 25.252 (c)(3) ) ') AFFIDAVIT STATE OF ALASKA THIRD JUDICIAL DISTRICT Jeffrey C. Blagg, being first duly sworn on oath, deposes and says: That I am an employee of Amoco Production Company. That on the~' day of July, 1986, I caused to be mailed a true and correct copy of this applica- tion to the following operators and surface owners listed in Section C: Mr. Jim Eason, Acting Director Division of Oil and Gas State of Alaska Department of Natural Resources P.O. Box 7034 Anchorage, Alaska 99510-0734 Mr. G. A. Graham Unocal P.O. Box 190247 Anchorage, Alaska 99519-0247 by placing a said copy in the United States Mailwith'postage prepaid and certified at Anchorage, Alaska. ') ') ,~jt f ~ ê1'f~. Bla~g ( SUBSCRIBED AND SWORN to before me this OJ i ~ ::?\. , day of July, 1986. ~ I *),;^_ K 0 ''f\c.'~~o--ti: Nota· Public in and for Alaska o 0 0 ~'/v Comi1ì;ssion Expire~ My comml ss 1 on expl res . '/-y?, 1987 __ ) ') . . SECTION E DESCRIPTION OF OPERATION 20 AAC 25.402(c)(4) Current and proposed injection operations at Amoco Granite Point Field are divided into two broad categories: enhanced recovery and fluid disposal. Enhanced recovery injection wells are used for the introduction of dis- placing fluids into the reservoir to increase the ultimate recovery of oil. Currently, water injection is the only method of enhanced recovery in use at Amoco Granite Point Field. The injection system utilizes Cook Inlet sea water passed through a network of filters, piping, injection pumps, and manifolding. Future injections may incorporate the injection of produced formation water or polymers. Existing water injection wells and future injection wells will continue to be designed, constructed, operated, and monitored to ensure the injection fluid is entering the oil reservoir. Enhanced oil recovery methods are/will be confined to Tertiary age formations. Presently, there are no disposal wells used for the disposal of produced water or other non-hazardous waste fluids generated during normal drill- ing, workover, or production operations. Future disposal wells for in- jecting these waste products will be designed, constructed, operated, and monitored to ensure the injected fluid is confined to the injection zone. Waste disposal will be confined to Tertiary age formations. ) ) SECTION F POOL INFORMATION 20 AAC 25.402 (c)(5) The pools affected by injection for enhanced recovery and waste disposal are defined by Rule 1 of Conservation Order No. 76 as the Mobil-Union Granite Point No.1 well between 7,725 feet and 10,800 feet. ) ) SECTION G GEOLOGIC INFORMATION 20 AAC 25.402 (c)(6) 20 AAC 25.252 (c)(4) The Granite Point Field produces from the Oligocene- Miocene Tyonek Forma- tion which consists of conglomerate, sandstone, siltstone, and coal. The trap is a northeast-southwest trending asymmetric anticline. The Tyonek is informally divided into the upper Chuitna and lower Middle Ground Shoal members (See Figure G). Four zones within the Middle Ground Shoal member are recognized by Amoco at Granite Point. The upper A and B zones are largely fine-grained sandstone siltstone, claystone, and coal. The C zones consists of pebble conglomerate, pebbly sandstone, coarse-to fine-grained sandstone, siltstone and coal. Fine grained sandstone, siltstone, claystone, and minor coal comprise the basal D zone. The C zone is the primary reservoir at Granite Point. Reservoir rocks of the Tyonek Formation at Granite Point were deposited by south to southwesterly flowing fluvial systems on a low-lying alluvial plain. A nonmarine setting is indicated by numerous coals and well-preserved deciduous leaf fossils and an absence of marine fossils or trace fossils. Both local and distant terrains are sources of sediment in the Tyonek C zone. Altered silicic volocanic rock fragments may have been derived from the now-eroded cupolas of Tertiary-age batholiths exposed in the Alaska Range. Seven different lithofaces are present in cores from the Tyonek C zone at Granite Point Field. Lithofaces are physically distinctive rock units, distinguishable by lithology, grain size, sorting, and sedimentary struc- tures. Lithofaces are intergradational and recognition is in some cases subjective. Lithofaces No.1 is a pebble conglomerate with clasts of pale white to dark grey or black chert and altered silicic volcanic rock frag- ments. X-ray diffraction analysis of the matrix indicates that clays are predominantly kaolinite, with lesser amounts of chlorite and illite. Carbonate cement is irregularly distributed and makes up a small percent- age of the rock. Lithofaces No. 2 is a pebbly sandstone. Authigenic kaolinite is the most abundant clay mi nera 1, wi th mi nor amounts of ch 1 ori te and ill i te. Carbonate cement is locally abundant and is dominately siderite or ankerite. Lithofaces No.3 is a medium-to-coarse grained sandstone and is the most abundant lithofaces at the Granite Point Field. It is predominately a chert/silicic volcanic litharenite. Chert, altered silicic volcanic rock fragments and monocrystalline quartz are the most abundant rock types. ') ) Field spar makes up 2-5 percent of the rock and Authigenic Kaolinite is abundant, comprising up to 18 percent of the rock. Illite and chlorite are present in lesser amounts. Lithofaces No.4 is a fine-grained, cross-bedded sandstone. Grains are predominantly chert, altered silicic volcanic rock fragments and noncrys- talline quartz. Siderite is fairly common along bedding planes. Illite and kaolinite are the primary clay minerals, comprising up to 14 percent of the rock. Lithofaces No.5 is an interbedded fine-grained sandstone and siltstone. Monocrystalline quartz is the primary constituent, followed by chert and 1 esser amounts of Fe 1 dspa rand mi cas. III i te is the predomi nant clay mineral. Lithofaces No.6 is a massive siltstone containing plant debris and occa- sional well preserved fossil leaves. Root mottling is also present. Minor amounts of fine-grained and very fine-grained sand occur in thin laminae. Clays, dominantly illite, represent up to 30 percent of the rock. Lithofaces No.7 is a carbonaceous siltstone and coal. The coals are silty and fissile. Very thin wisps of fine-grained sand are occasionally present. The average net pay thickness of the middle Kenai C sands at the Granite Point Field is 401 feet. The average porosity is 13 percent and the aver- age permeability to air is 11 md. The confining zones above the producing unit is a series of tight, impermeable siltstones and shales, varying in thickness from 50 to 200 feet. SCANNED Jut {) 2, 2.0D4 ._ ~. ........ .\\~.......~,~....,.~",.. ...:-" A__~' ";-I_._.-~-_4_!þ"""ç~..""""",.oN--··"'. F r aD Fl t ~. 7 , W M CON N E I.. I.. '( A P R I L . I 9 7 7 Naknek Fm. 1::_-..... ,_--.,...-,_-_-....."......- . _,_ ........-.-_-__-__......-__-~.......-.-_ -~- ~.......---- - -_._-..............-,..-.,--..-~ .....-_- -~1 Matanuska Fm. ~ _-......--,.......,._...........~_ _-_~_-_-._, -......~.............-_.........,..,..,_-__......-_- -_-_...-.__ .,~4J1I'...............-___,-4IfI' -~. Chickaloon Fm. W ish bon e F m' . ~ Tsadaka mbr. ,,-. - ".. -...... - -....-........ .....-- - ...-,....-- ...._-. - --...-. . . . -.- ...-. ....-...~ - ~ - -.- "".- -. '-.. West Foreland Fm, .6 I - __ -."", _ ~ _ - __~ -.... .,,- _...... -...... -:-, ~... -............. ,- __ ~.........._ - ~ ,-_....- _~...,.".., _ - - ......,.._ -~- __ - _" - __-.... "G" Hemlock Conglomerate 6 "F" Chuitna mbr. '6 "A" sand mbr. S-T ATE ~ PRODUCING NOMENCLATURE, "8" sand mbr. MIDDLE GROU* SHOAL - "C" sand mbr. "Á" 6- "ä" "C" "0" sand mbr. - "0" . If r' ~ 333 37J 3 13 2 35 ~ Q c: A233 ~ <: :z: ~ Tyonek Fm. .., ., - -~ ,_~~ ~_~, - ~ ~ - - _.... .....-_.....-~ -._ - _, _.....'_n-".... -~._ ...~._. _ - _ --.,..., .5;> West Fork mbr. .¿s; ~ Beluga Fm. , 'C oak I n let san d ml b r , ~ 6 " !._"-""..~,----.-- -~.-..... ._-_...._....-.---_.".._-._~._.,_._-, "" - . 6" Bishop Creex mbr. I Sterling Fm. UPP~R C R ET - ' ACEOUS U PIPE R JURASSIC GU1t PALEO- CENE EOCENE I E,i40lt GUIfI . ,Iv , <v~ 'C" ~O: ., Q~ M 1 O,C ENE hi.,I, HE! VY AGE ~IUiÁL PUY. SUITES \ PLEISTO- GENE Her.. , ii, d e PLIOCENE H " er- S t... .... ----- .-...........~-"..,..........,~""........ '" --- -"",~---~,. .'---~-----"-""'" --...........-.~,,-,~_..... -- -- ROCK UNITS Glacial cover f/e. IrtIÍÍÍ/J; T Jh. :.,A.Moc 0 ..tV TERTIARY NOMENCLATURE ---" FIGURE G COOK INLET .,./ ) SECTION H WELL LOGS 20 AAC 25.402 (c)(7) 20 AAC 25.252 (c)(5) ) All open hole logs from the Amoco Granite Point Field are sent to the com- mission as the logs are completed. RECE\\JED JUl2 4 \~ß6 ...J":'>\V~ " 'þ.\a.s\(8. 0:' .c' fl,\\\.ji ,'..J i \.'\~..fC,1 o 2 200/'1· ') SECTION I CASING INFORMATION 20 AAC 25.402(c)(8) 20 AAC 25.252(c)(6} Typical Granite Point Field injection wells are cased as shown in Figure I. All newly completed injection wells will be cased, cemented, and tested in accordance with 20 AAC 25.252. Casing design will be sub- mitted for approval as required under 20 AAC 25.005 (Form 10-401) on the drilling permit application. In wells converted to injection, the casing will be retested in accordance with 20 AAC 25.412(c), and the well will be completed in accordance with 20 AAC 25.412(d}. n c; 20fìl1 t,,' ¡,"" \ _.~ ...,,'. ~''''i\ ) ) FIGURE I ~.- 3 ,~ Tvßf 1Je,- (t^~<J Pi4CKEfZ TE.STED Tù 4000 PSI =0= L. L ¡ i ¡ ! ¡ ~ ì , )¡.! i ! ¡ \ þ3: ¡ I ~ ¿ LI IRI t I ¡ ¡ ¡ ¡ i ì W I X ~ =0= WELLHEAD ~ SEA LEVEL MUD LINE ~ // I 40 PILE @ 200 ~ ~ ; 20 CONDVC-TOfl, @ bOO ~ /33/8" SUR..FAGI~. CA'5/N& @ ZOOO / q 613" INí£KME1)IATE. CASING @. To P . Of: " C. - /_.. L ~ 7'/ UNË~ @ BASE OF //C-IO" o 2 20D4 ) ) SECTION J INJECTION FLUID COMPOSITION INJECTION RATE AND PRESSURE 20 AAC 25.402 (c)(9) & (10) 20 AAC 25.252(c)(7) & (8) Enhanced Recovery Fluids The type of fluid injected into enhance recovery injection wells is fil- tered, treated Cook Inlet sea water. Water treatment additives include biocide, corrosion inhibitors, scale inhibitors, and oxygen scavengers. The maximum expected injection rate on a field wide basis is 30 MBWPD, and on a per well basis is 6 MBWPD. Water sensitivity tests on core samples showed no significant problems with formation plugging or clay swelling caused by injecting Cook Inlet sea water. The maximum wellhead injection pressure for enhanced recovery injection wells at the Amoco Granite Point Field is 5,600 psig. This pressure is the maximum discharge pressure of the injection equipment. The average injection pressure is estimated to be 4500 psig. Fluid Disposal The injection fluid for disposal is expected to be predominantly drilling, workover, and production related waste fluids. The injection stream could include drilling mud, reserve pit water, contaminated crude, diesel gel, glycol, domestic waste water and workover fluids. There are presently no waste disposal wells on at the Amoco Granite Point Field. The maximum expected injection rate on a per well basis is 6000 BPD. The maximum expected wellhead pressure for fluid disposal wells is 5,600 psig. The average injection pressure will be determined at such time that a well is converted to waste disposal. o ') 2'onQ ,} t",J "it '"",~ IJ ) SECTION K FRACTURE INFORMATION 20 AAC 25.402(c)(11) 20 AAC 25.252(c)(9) The injection pressure for enhanced recovery and fluid disposal wells will be maintained below the fracture pressure of the confining strata in order to prevent injection or formation water from entering freshwater strata. Enhanced Recovery The Tyonek C has a fracture gradient of 0.9 to 1.1 psi/ft. A fracture gradient of 0.9 psi/ft corresponds to a bottom hole injection fracture pressure of 7902 psig. The surface injection pressure is estimated to average 4500 psig with a maximum projected pressure of 5,600 psig. Since startup of waterflooding at the Amoco Granite Point Field, injection surveillance data has been collected. Such data has included injection profiles, temperature surveys"injectivity index monitoring, pressure fall off, and step rate tests. This information has verified that water injections have not extended into freshwater zones. Fluid Disposal Injection zones for fluid disposal may exhibit some hydraulic fracturing within the injection horizon around the wellbore because of the nature of the disposal fluids and the potential for high solids content. At such time that a well is converted to fluid disposal, step rate testing will be performed on the Tertiary injection interval to determine the fracture gradient. If the fracture gradient must be exceeded to inject fluids, then additional testing will be performed to ensure that injection or for- mation fluid will not enter nonexempt freshwater strata. o 2 2004 " } SECTION L . FORMATION FLUID 20 AAC 25.402(c)(12) 20 AAC 25.252(c)(10) ) A water analysis for the Tyonek C is presented as Figure L. o 2 2004 o 2 2DD4 ___h____"._____.__ ___. --,-_.._- ------- ----...-,-- \ Fe ~~~_~:__-.~ ~~: __..~_~_=_=..:- _~. ~~~..~_~~:: C03 '.-. - -.--.. '·0· ,--.-n--.H..l.-.--~' ..._-.._, ~~~g~~~~~~~~p~~ s Fe ~=~~~:~~;~i~~~~;·~~~:j~~;~~:~~~~~î CO. ...,._......~'_..._~_._- ._--_..----;._..~.__._.. --~.-_. _..~ ----- _._____.. ___..,..~___o...-..¡,..-.....~__ .....---..-., ""_.... ... ...-....._~--...-.. ==-=..==:::~:î-::::=-==-:=_=:~~~:- ~~:~:~~:=...::= --------- ..---.---- . . - Mg 5 Na ~_~.~~:.:.:j~~~~- . ~-.~Cl .- ,..-"-- ,- ~I.:.:~ ,_ _, ·1 C. ::..: -; ~:-::-;-.: ::~::-. :-. I i~~__~~:_ -- ".~ ~ HCO» . - r' . I Mg ~~·~~~:~;0' ~3~::\-~.-01S0. ~. -. ..... . .. - - -...- - " . ..... . --... --- -- ..-. .-.... . ..~ -... ...-.. '-- .. - ..- -_. -- -...... ..-.. - - - .... .. . . -- -. .. - .... . -~... . -.. -- -- .- _. - .... - . ~ _-~ SO.. "-' ... . - -- ...~- - ...... ..... . ~ -.- . 00: , . , , Na =~:-:~~~,~:.' --_-~~~--'-~ ~~.~ Cl Ca ~<~-~',~ - ~ ~ ~~-'~- ~.~~~:~ ~~~~~:~ 13 HC03 5 50 ~., - .._~ ..J --. ~ ~.. -- -.. . . -- :. ..... -". ~ ~ ..--..'--- .......... --- - - ~~ - . -- .. -- . ...... ~ - ~ - .... - ~.. - . --< - - - ~ - -.- .._~..~...-._.- - "'--"" . ~ r ~ ...- ..- - - . ... - . - - . . --... r ' --------- --....... --+----.----..... ~_._----._. ~-_._---_.__.- ...-....----..---- -------- ~-_... ~... .. ----- - - . -- -... ~~ .. . - . .. ... ..... -.. - _-----.- Scale MEQ per Unit Sample above described WATER ANALYSIS PATTERN , Note: PPM=Milligrams per liter (1 PPM is equivalent to 0.0001% by weight). MEQ=Milliequivalents per liter. MEQ%=MilliequivaIent8 per liter in percent. AlJ[':1Jst 10, 19ón Resistivity @ 68DF. 1 12 7 · 9 ohm-meters . 5421 Calculated Rw 1.lS Sampled at YIP.,.llheé1n (Bottom samp1p.) Observed pH NaC1 Eq. Remarks CONSTITUENTS. PPM MEQ. .MEQ..% TOTAL SOLIDS IN PARTS PER MILLION: Sodium - - - - 2h71 107 . }19 .11i.Jlß By evaporation A,SJ? Calcium - - - - hI 2.0S, 0.91 After ignition A,Oln Magnesium - - - 5 O.LI ~ Calculated Ã, 1 J1R Sulfate - - - - 53 1.10 ~1 Chloride - 2020 56.96 25.89 ~ Carbonate - - - 0 - - - Bicarbonate - - 31bl¡ 51.89 23 .60 Hydroxide - - - 0 - - - Analyzed by... .......A.f... ............................................................. Date,. . August,. .1lt.,.. ,19. .68.,. ...' Lab. No.,. 1.\::-115::-.'hT::-.2.. . .................................... ................ ............ .... ......... .............................. ............ ............... .................... ...... .... ...... .................... ............... ... ... ..... .......... Fie1d....Qr.a. :n.tt.~... r9~XLt.,.. .A+' ~.~ !';,~ .... '..,.'....',..,...,........ ...W ell NQ... .4.. ,G..J'...... ..18 7.1J2 ........ ....................... ................ Operator, ..... ,:P~n.. .~~.f.~.ç: ~,~... p'~,t rq JG.t.JJ1:I. ...çqr.P..!.,.. _..Loçation. ...$ ~.ç ,..,.1,. ..T-:-:l.Q~.N .,... R7:12.~ ~.!. ,... .s.ri r... ..... ..... H ow sampled...... _....,.,.. '" ...... .... ............ ......... ....... ........ ........ ..Date. ......... .~.~ c.~~ ~.~,.J 9. ,... .~.~~.f_"........., .._._......... ............'. ... Formation... ,~.~~.~~,., ,'.I.g.'.'_...,. ~pp~ r...?a. y...... ..................' .Depths".... .$.~ ~ ~~þ_t.ng., .~.:t... ß_ ~J.Q.. .~,.. 6 3SJ..,..... ... .... ..... '" Other pertinen t data......., r1 ~gq Y. .:w~ .t~.r -'... ç.~~. fLr. ..li.gh.t. .YfÜl Ok{. .filtr a.t e. A.......... ........................................ WATER ANALYSIS REPORT P. O. Box 279 Casper. Wyoming ÞJiLJU C^;~ 0TRATIGl1APttl C cor·jP^ [~y Anchorage, Alaska CHEMICAL & GEOLOGICAL LABORATORIES CLl-t2A "..,.,, .".u..... c..--',... ~. þure L ) ') SECTION M Aquifer Exemption 20 AAC 25.402(c)(13) 20 AAC 25.252(c)(11) The portion of aquifers beneath Cook Inlet described by a 1/4 mile area beyond and lying directly below the Granite Point Field are exempted aqu i fers for C1 ass I I i nj ect ion. (Reference 40' CFR 147 .102 (b) (2) and 20 AAC 25.440(c).) Rr.Cr.\\Jr.Q UL'2 q \9ß6 . J ..n\SS\On Com", . & Ga.s conS. A\aS~a 0\\ þ.nc"ota.~e n 2 200t1 SECTION N HYDROCARBON RECOVERY 20 AAC 25.402(c)(14) Incremental hydrocarbon recovery from the Amoco Granite Point Field, resulting from enhanced recovery waterflood operations is 49.9 MMBO. 2 2D ) SECTION 0 MECHANICAL INTEGRITY 20 AAC 25.402(d) and (e) 20 AAC 25.252(d) and (e) In newly drilled Amoco Granite Point injection wells, the casing is pres- sure tested in accordance with 20 AAC 25.030(g). If a producing well is converted to injection, the casing pressure test will be repeated in ac- cordance with 20 AAC 25.412 (c), prior to injection. Thereafter, casing-tubing annulus pressures will be monitored on a regular basis and reported monthly on Form 10-406 in accordance with 20AAC 25.402(d). All injection wells requests to be constructed in compliance with mechan- ical integrity criteria as set forth in 20 AAC 25.252(d) and 20 AAC 25.402(d) . 20 AAC 25.402(e} requires immediate notice to the Commission and correc- tive action if the casing-tubing annulus pressure subjects the casing to a hoop stress that exceeds 70 percent of the minimum yield strength of the casing, or if there is more than 200 psi change in the pressure between consecutive pressure readings. Amoco Production Company requests to use the 70 percent limit as the alarm for immediate notice and corrective action. By using the 70 percent yield pressure limit, the injection wells can be monitored to detect leaks and operated safely. Tubing pressure changes and temperature effects during various workover, logging, or testing operations often yield casing-tubing annulus pressure changes greatly exceeding 200 psi. These operations are necessary and occur often during prudent operations. In addition, the annular pressure is sensitive to injection pressures and fluid temperature. Thermal effects and injection rate variation will be a significant controlling factor for casing pressure on water and waste disposal wells. J"~ì ,"¡ '~'1 ~ - " . >"i SECTION P WELLS WITHIN AREA 20 AAC 25.402(h) 20 AAC 25.252(h) ) The wells within the Amoco Granite Point Field are shown on Figure B. To the best of Amoco Production Company's knowledge, the wells within the a rea were constructed, and where app 1 i cab 1 e, abandoned to prevent the movement of fluids into freshwater sources. f).. ? ?orVì Ii· {·e b ...';;.¡ ) ) SECTION Q GAS-OIL RATIOS 20 AAC 25.240 (b) & (c) (1) If this application for an Area Injection Order is approved, then a waiver is requested for 20 AAC 25.240(b) requiring no oil well to exceed 100 percent of the original solution gas-oil ratio. The requirement for an oil well to produce at below 100 percent of the original solution gas-oil ratio will not be necessary in accordance with 25.240(c)(1) because the pool will have an approved additional recovery project in operation. ¢ìJ. £)0 01 fj I..; c:.. ·...4· ) ~. ... t.. ') (. Exhibit 1 STATE OF ALASKA DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL ~~ GAS Alaska Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 Re: The motion of the Alaska ) Oil and Gas Conservation Com- ) mittee to determine if waste ) is occurring, to hear testi- ) mony on the initiation of a ) pressure maintenance project, ) the beneficial use of gas and ) other relevant matters; and ) the application of Mobil Oil ) Corporation and Pan American ) Petroleum Corporation for an ) order authorizing water in- ) jection for pressure mainten- ) ance or secondary recovery ) purposes and for the consoli- ) dation and revision of Con- ) servation Orders No. 59 and ) No. 60; Granite Point Field. ) IT APPEARING THAT: Conservation Order No. 76 Granite Point Field: Pressure Maintenance Project, Field Rules and Beneficial Use of Gas Granite Point Middle Kenai Oil Pool September 12, 1969 1. The Alaska Oil and Gas Conservation Committee moved to hold a public hearing to hear testimony by the operators of the Granite Point Field to determine if waste is occurring as a result of producing the Middle Kenai Pool and to hear testimony on the initiation of a pressure maintenance project for the 1-liddle Kenai Pool, the beneficial use of gas produced as the result of crude oil production and any other matters relevant to the proper development and operation of this pool. 2. Notice of the hearing was published in the Anchorage Daily News on July 17, 1969. 3. Mobil Oil Corporation and Pan American Petroleum Corporation, as operators of the Granite Point Field, by application received July 22, 1969, petitioned the Committee for an order authorizing water injection for pres- sure maintenance or secondary recovery purposes in the Granite Point Field and for the consolidation and revision of Conservation Orders No. 59 and No. 60. 4. A public hearing was held in the City Council Chambers of the Z. J. . Loussac Library, Anchorage, Alaska, on August 15, 1969. ·Tëstimony was pres- ented in response to the motion and in support of the petition, and affected and interested parties were heard. i ! \ , î ~ l 2 ?OO¿ï· \ .{ ) , COKSE~VATION ORDER NO. 76 Page 2 September 12, 1969 AND IT FURTHER APPEARING THAT: 1. The Middle Kenai Pool should be re-named the Granite Point Middle Kenai Oil Pool. 2. Development of the Granite Point Middle Kenai Oil Pool is essentially complete and the pool limits have been reasonably well defined. 3. The reservoir fluids are undersaturated and maximum recovery of oil will not be achieved unless some additional recovery method is used. 4. Water injectivity tests indicate the feasibility of injecting fluids into the Granite Point Middle Kenai Oil Pool to supplement the natural reservoir energy and thereby achieve increased oil recovery. 5. There is a substantial variance in permeability between crestal wells and do-wndip or flank wells and more than one injection pattern may be advisable. 6. Lease line injection wells should confine reservoir fluids to each operator's leases and thereby protect correlative rights. 7. The value of the additional recovery from a fluid injection project will exceed the cost of such a project. 8. The operators have increased their use of produced gas but some gas is being flared. 9. Negotiations with potential purchasers of produced gas indicate there is no market for the flared gas and the findings of Conservation Order No. 61 with respect to the Granite Fcint Field have not materially changed. 10. Conservation Orders No. 59 and No. 60 should be revised and consoli- dated herein. (; ~ {)nOf} \. f ~I::. Lv t L f " ) , CONSERVATION ORDER NO. 76 . Page 3 September 12, 1969 NOW, THEREFORE, IT IS ORDERED that the rules herein set forth apply to the following described area: Township 10 North, RanRe 11 West, S. M. Sections 5, 6, 7, 8, 18 and 19: All Township 10 North, Range 12 West, S. M. Sections 1, 2, 11, 12, 13, 14, 23 and 24: All Sectiòn 15: E 1/2 SE 1/4 Section 22: NE 1/4 NE 1/4, S 1/2 NE 1/4, SE 1/4, SE 1/4 SW 1/4 Township 11 North, Range 11 West, S. M. Sections 29, 30, 31 Bnd 32: All Township 11 North, Range 12 West, S. M. Section 25: E 1/2 NE 1/4, SE 1/4 Section 35: E 1/2 Section 36: All Rule 1. Definition of Pool. The Granite Point Middle Kenai Oil Pool is defined as the accumulation of oil common to and yhich correlates with the accumulation found in the Mobil-Union Granite Point No.1 well between the drilled depths of 7,725 feet and 10,800 feet. Rule 2. Spacing. (a) Not more than two completed wells shall be allowed in any govern- mental quarter section. (b) No pay opened to the well bore shall be nearer than 500 feet to any property line nor nearer than 1,000 feet to any well drilling to or capable of producing from the same pool. Rule 3. Casing and Cementing Reouirements. Surface casing must be set and cemented to a depth of at least 1600 feet. Sufficient cement must be used to circulate to the surface. The production string must be cemented with a sufficient volume of cement to extend at least 500 feet above the shoe or a volume sufficient to cover 100 feet above the top of the uppermost producing zone encountered in the well, whichever is greater. Rule 4. Bottom Hole Pressure Surveys. A key well bottom hole pressure survey shall be made upon Committee request; provided, however, such surveys shall not be required more often than twice in any calendar year. The time and length of survey, number and location of wells, datum and other details will be determined by the Committee upon consultation with the operators. () 2 2D04 , < ) t ) CONSERVATION ORDER NO. 76 Page 4 September 12, 1969 Rule 5. Gas-Oil Ratio Tests. A gas-oil ratio test of 24 hours duration shall be made annually on each producing well. The tests will be made during the months of June and July and the results will be reported on Committee Form P-9 prior. to September of each year. The requirements of this rule will be waived if monthly reported oil and gas production is based on a gas-oil ratio test made at least every six months in each producing well. Rule 6. Pressure Maintenance Pro;ect. The injection of water for the purpose of pressure maintenance, secondary recovery or of conducting injectivity te~ts is hereby permitted in the Granite Point Middle Kenai Oil Pool. A semi-annual progress report detailing project operations and results shall be submitted to the Committee in January and July of each year. Rule 7. Administrative Approval. Upon request of the applicants and a showing that the affected parties have been notified of such request, the Committee may authorize the conver- sion or drilling of any well at any location, the termination or suspension of the project, or any operation reasonably designed to further the purposes of the project. Rule 8. Other Conservation Orders. Conservation Orders No. S9 and No. 60 are hereby revoked. Conservation Orders affecting the Granite Point Middle Kenai remain in full force and effect, except as modified hereby. All other OilRrè EWE D ~ ~ ~>~ i":-, "'L~rtl~: - {. ~:~ -.,,;~ v". .:/ '\._; " ~ . ~{, :.;. '::·:..~V..£ ,~. \ . ~r---- .(~~:~::.~~~~,~.::~::1 ~~ ~~. Ii q r: '.' . . '.. . .... \ (4 k:rìf~~~\~~:~;: ~~(J.:=: i 0.1 ~::=- l' '.,.:"..'~'; - I 7-- - ~ ':...- '" ,":- I ¡ ...~~/ ~ -:--'- ; '¡:¡ ,:i / :-ì ~"'i'v.. <>,J~,w~:. };;./~:,. ~ 1~1 ~,., .( o~ c:.·,r dated Sept~mber 12, 1969. JUL 241986 --1-1. '¿:t /;/ Alaska Oil &AS Cons. Commission ( /~. Jr. IUf ~,A :~orage Thomas R. Marshall, Jr., Executiv. Secretary Alaska Oil and Gas Conservation Committee DONE at Anchorage, Alaska, and Concurrence: ~¿$~ Homer L. Burrell, Chai~an Alaska Oil and Gas Conservation Committee otR~~~:,{¡2:/' Alaska Oil and Gas Conse~ation Committee th 9 ClnfL' \} t<J c..u..,'1