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Home My WebLink AboutAEO 006 A• INDEX AQUIFER EXEMPTION ORDER NO. 6A 1. July 15, 2008 Unocal's application for depth exemption of AEO 6 for Ivan River 13-31 2. July 22, 2008 Notice of Hearing-Anchorage Daily News and July 24, 2008 Peninsula Clarion affidavit of publications and mailing lists 3. ---------------- Revised tables 4. ---------------- Various E-mails 5. November 26, 2008 Letter, proposed Order and attachments sent to US EPA for review and approval 6. December 4, 2008 Letter from US EPA concurring with AOGCC findings and Order AQUIFER EXEMPTION ORDER NO. 6A • ~ FILE CHECKED FOR CONFIDENTIALITY MATERIALS 12/5/2008 ~. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7`h Avenue, Suite 100 Anchorage, Alaska 99501 Re: THE APPLICATION of Union Oil ) Aquifer Exemption Order No. 6A Company of California for a depth extension of ) Aquifer Exemption Order No.6, which relates to ) Sterling and Beluga Formations portions of the Ivan River Unit within the ) Ivan River Unit Matanuska-Susitna Borough, Alaska. ) December 5, 2008 NOTICE CLOSING DOCKET BY THE COMMISSION: The Commission has the closed the Docket in the above captioned matter. ENTERED AND EFFECTIVE at Anchorage, Alaska and this 5th day of December, 2008. BY DIRECTION OF THE COMMISSION Ui Col Inbi~ As i~ta to the Commission • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: THE APPLICATION of Union ) Oil Company of California for a depth ) extension of Aquifer Exemption Order ) No.6, which relates to portions of the ) Ivan River Unit within the Matanuska- ) Susitna Borough, Alaska. ) Aquifer Exemption Order No. 6A Sterling and Beluga Formations Ivan River Unit December 5, 2008 IT APPEARING THAT: 1. Union Oil Company of California (Union), a wholly owned indirect subsidiary of Chevron Corporation, submitted an application for a depth extension of Aquifer Exemption Order (AEO) No. 6. Union's application dated July 15, 2008 was received by the Alaska Oil and Gas Conservation Commission (Commission) on July 17, 2008. 2. AEO 6 exempts those portions of freshwater aquifers lying between 2500 feet and 3420 feet measured depth in, and within %2-mile radius of, the Ivan River Unit (IRU) Well 14-31 for purposes of Class II underground injection activities.i 3. The surface location of IRU Well 14-31 is located within Section 1, Township 13N, Range 9W, Seward Meridian. 4. Union's application requests a depth extension from 3420 feet to 6195 feet. 5. The Commission's jurisdiction in this matter is under AS 31.05.030(h) and 40 CFR 147, Subpart C -Alaska, and relates to 20 AAC 25.440. 6. The Commission published a public hearing notice, with a tentative hearing date of September 4, 2008, on the Commission's Web site on July 21, 2008, on the State of Alaska Online Notices on July 21, 2008, in the ANCHORAGE DAILY NEWS on July 22, 2008, and in the PENINSULA CLARION on July 24, 2008. 7. The Commission submitted a copy of Union's aquifer exemption application and related documents to the U.S. Environmental Protection Agency, Region 10 (EPA Region 10), on July 22, 2008. 8. The Commission received no comments, protests, or requests for a hearing. The public hearing was vacated on September 2, 2008. 9. Union submitted a disposal injection order (DIO) application on September 8, 2008, proposing the conversion of IRU 13-31 from gas production to Class II waste disposal service. IRU 13-31 penetrates the proposed disposal zone within the '/2-mile exemption radius established by AEO 6. 1 All depths presented herein are measured depths within IRU 14-31 unless otherwise noted. Aquifer Exemption Order 6A• Ivan River Unit December 5, 2008 • Page 2 10. On October 20, 2008, the Commission requested additional information from Union regarding water quality within the affected geologic strata. 11. On November 7, 2008, Union submitted a revised request for a depth extension of AEO 6. This revision changes the interval of the requested depth extension to the following: 3420 feet to 5435 feet in IRU 14-31. 12. On November 8, 2008, Union submitted the water quality information the Commission requested on October 20, 2008. 13. On November 14, 2008, the Commission requested further information from Union regarding water quality. Union responded with the requested information on that same day. 14. The information submitted by Union and public well history and well log records are the basis for this order. 15. On November 25, 2008 and in accordance with the memorandum of agreement between EPA and the Commission, a draft of this aquifer exemption order was sent to EPA Region 10. Information that supports the Commission's findings and conclusions were provided to EPA Region 10 on November 25 and November 26, 2008. 16. In correspondence dated December 4, 2008, EPA Region 10 concurred with the proposed depth extension of AEO 6 to 5435 feet in IRU 14-31. FINDINGS: Extent of Aquifer Exemption Area. The IRU is on the west side of Cook Inlet within the Matanuska-Susitna Borough, approximately 45 miles due west of Anchorage. This gas field has been in production since July 1990. There are six wells within the IRU: one plugged and abandoned well, four gas production wells, and one disposal well (IRU 14-31) used for underground injection of Class II oilfield wastes. Union plans to convert shut-in gas producer IRU 13- 31 to disposal injection service; the well was shut-in December 2007. AEO 6 exempts aquifers within a '/2-mile radius of, and between 2500 feet and 3420 feet in, IRU 14-31. Union requests a depth extension to allow for the deeper injection of Class II oilfield wastes into IRU 13-31. No change to the lateral extent of the exempted area is requested since IRU 13-31 is within the '/2-mile exemption in AEO 6. 2. Formation Water Total Dissolved Solids. Union calculated the total dissolved solids (TDS) concentrations in the affected aquifers within IRU 13-31 utilizing well log data and techniques that conform with EPA guidance document "Survey of Methods to Determine Total Dissolved Solids Concentrations," (KEDA Project No. 30-956). Union's analysis indicate that aquifers within IRU 13-31 that correlate to the interval between 3420 feet and 5156 feet within IRU 14-31 contain Aquifer Exemption Order 6A• Ivan River Unit December 5, 2008 • Page 3 TDS concentrations greater than 3,000 parts per million (ppm). Union's analysis also indicates aquifers within IRU 13-31 that correlate to the depth below 5156 feet in IRU 14-31 contain TDS concentrations of approximately 2,500 ppm.2 The Commission verified Union's analysis using EPA-recommended techniques and well log data from IRU Wells 14-31, 13-31, and 44-36. The results of the Union and Commission analyses are consistent. The Commission determined that aquifers equivalent to the interval from 3420 feet to 5163 feet in IRU 14-31 contain TDS concentrations exceeding 3,000 ppm. The Commission also found that aquifers below the equivalent of 5163 feet in IRU 14-31 contain TDS concentrations between about 2,000 ppm and 3,000 ppm. 3. Suitability of IRU Sediments Below 2500 Feet as Drinking Water Aquifers. 20 AAC 25.440(a)(1)(B) provides that the Commission may grant a freshwater aquifer exemption regardless of total dissolved solids content if the aquifer does not and cannot now, and will not in the future, serve as a source of drinking water because it "is situated at a depth or location that makes recovery of water for drinking water purposes economically or technologically impractical." AEO 6 concludes that the portions of aquifers between 2500 feet and 3420 feet in IRU 14-31 are not reasonably expected to serve as underground sources of drinking water based on depth and water quality. The TDS data indicates a trend reversal toward less TDS as the well gets deeper. Extending the aquifer exemption depth to the equivalent of 5435 feet in IRU 14-31 is unlikely to affect potential drinking water supplies since increased lifting costs are associated with deeper zones, and suitable sources of drinking water are available on the surface and within the shallow subsurface. CONCLUSIONS: 1. The findings and conclusions of AEO 6 remain valid. AEO 6 properly exempts for purposes of Class II underground injection activities the portions of freshwater aquifers between 2500 feet and 3420 feet and within a '/2-mile radius of IRU 14- 31; 2. All known and foreseeable ground water consumption from the IRU vicinity is consistent with usable ground water resources above 200 feet; 3. The TDS content of the water within a %2-mile radius and within strata equivalent to those between 3420 feet and 5163 feet in IRU 14-31 is greater than 3,000 ppm. Strata equivalent to those below 5163 feet in IRU 14-31 contain TDS concentrations between about 2,000 ppm and 3,000 ppm; 4. Those portions of aquifers at an interval equivalent to between 3420 feet and 5435 feet within IRU 14-31 are at depths that make recovery of the water for drinking water purposes economically impractical now or in the future; 2 To minimize confusion, affected aquifers and strata in nearby wells are specified as equivalent depths within IRU 14-31, which is the reference well for AEO 6. Aquifer Exemption Order 6A• • Page 4 Ivan River Unit December 5, 2008 5. Those portions of aquifers within a %2-mile radius around the IRU 14-31 wellbore and below 2,500 feet qualify as exempt freshwater aquifers under 20 AAC 25.440(a)(1)(B) or 20 AAC 25.440(a)(2) or both; and 6. The stratigraphic sequence and maintenance of the mechanical integrity of the wells within a '/2-mile radius of IRU 14-31 will prevent the movement of fluids into underground sources of drinking water. NOW, THEREFORE, IT IS ORDERED THAT the aquifers or portions of aquifers between 2500 feet and 5435 feet in, and within a t/2-mile radius of, IRU Well 14-31 are exempt for purposes of Class II underground injection activities. ENTERED at Anchorage, Alaska, and dated December 5, 0 . Daniel T. Seamount, Jr. Jo K. Orman Chair ommissioner 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 tiled 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), "[tJhe 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: Monday, December 08, 2008 9:59 AM Subject: AE06A Ivan River Attachments: aeo6a.pdf BCC:'Aaron Gluzman'; caunderwood@marathonoil.com; 'Dale Hoffman'; Fridiric Grenier; '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); 'Aleutians East Borough'; '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'; 'Dan Bross'; 'dapa'; 'Daryl J. Kleppin'; 'David Brown'; 'David Hall'; David House; 'David L Boelens'; 'David Steingreaber'; 'ddonkel'; 'Deborah J. Jones'; 'doug_schultze'; 'Eric Lidj i '; 'Evan Harness'; 'eyancy'; 'foms2@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 Scherr'; 'Janet D. Platt'; 'jejones'; 'Jerry McCutcheon'; 'Jim Arlington'; 'Jim White'; 'Jim Winegarner'; 'Joe Nicks'; 'John Garing'; 'John S. Haworth'; 'John Spain'; 'John Tower'; 'John W Katz'; johnny.aiken@north-slope.org; 'Jon Goltz'; 'Julie Houle'; 'Kari Moriarty'; 'Kaynell Zeman'; 'Keith Wiles'; knelson@petroleumnews.com; 'Krissell Crandall'; 'Kristin Dirks'; 'Laura Silliphant'; 'Lois'; 'Lynnda Kahn'; 'mail=akpratts@acsalaska.net'; 'mail=fours@mtaonline.net'; 'Marilyn Crockett'; 'Mark Dalton'; 'Mark Hanley'; 'Mark Kovac'; 'Mark P. Worcester'; 'Marguerite kremer'; 'Matt Rader'; Melanie Brown; 'Mike Bill'; 'Mike Mason'; 'Mikel Schultz'; 'Mindy Lewis'; 'MJ Loveland'; 'mjnelson'; 'mkm7200'; 'Nick W. Glover'; NSK Problem Well Supv; NSU, ADW Well Integrity Engineer; 'Patty Alfaro'; 'Paul Decker'; 'Paul Winslow'; Pierce, Sandra M (DNR); 'Randall Kanady'; 'Randy L. Skillern'; 'rcrotty'; Rice, Cody J (DNR); 'rmclean'; 'Rob McWhorter '; rob.g.dragnich@exxonmobil.com; 'Robert Campbell'; 'Robert Fowler'; 'Robert Province'; 'Roger Belman'; 'Rudy Brueggeman'; 'Scott Cranswick'; 'Shannon Donnelly'; 'Sharmaine Copeland'; 'Sondra Stewman'; 'Sonja Frankllin'; 'Stan Porhola'; 'stanekj'; 'Steve Lambert'; 'Steve Moothart'; 'Steven R. Rossberg'; 'tablerk'; 'Tamera Sheffield'; 'Temple Davidson'; 'Terrie Hubble'; 'Tim Lawlor'; 'Todd Durkee'; Tony Hopfinger; 'trmjrl'; 'Walter Featherly'; 'Walter Quay'; 'Wayne Rancier'; Birnbaum, Alan J (LAW); Crisp, John H (DOA); Davies, Stephen F (DOA); Fleckenstein, Robert J (DOA); Foerster, Catherine P (DOA); Grimaldi, Louis R (DOA); Johnson, Elaine M (DOA); Jones, Jeffery B (DOA); Laasch, Linda K (DOA); Mahnken, Christine R (DOA); Maunder, Thomas E (DOA); McIver, C (DOA); McMains, Stephen E (DOA); Noble, Robert C (DOA); Norman, John K (DOA); Okland, Howard D (DOA); Paladijczuk, Tracie L (DOA); Pasqual, Maria (DOA); Regg, James B (DOA); Roby, David S (DOA); Saltmarsh, Arthur C (DOA); Scheve, Charles M (DOA); Seamount, Dan T (DOA); Smith, Chasity R (DOA); Williamson, Mary J (DOA) Attachments: aeo6a.pdf; Jody J. Colombie Special Assistant to the Commission Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 (907) 793-1221 Direct Line (907) 276-7542 Fax 12/9/2008 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 ~~ o~aEDSTaTFS UNITED~TES ENVIRONMENTAL PROTECTION AGE. ~m A y2 REGION 10 9 ~ 1200 Sixth Avenue, Suite 900 2~ _ Seattle, Washington 981 01-31 40 0 c$yT'q< PROZti~'~\ DEC - 4 ~~~" Reply To: OCE-127 ~ ~ - Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission - 333 West Seventh Avenue, Suite 100 Anchorage, Alaska 99501 Re: Aquifer Exemption Order Number 6A -- Ivan River Unit Cook Inlet, Alaska, Class-II Program Dear Commissioner Seamount: The U.S. Environmental Protection Agency (EPA) Region 10, Office of Compliance and Enforcement, has received an email request dated November 25, 2008, from the Alaska Oil and Gas Conservation Commission's (AOGCC) regarding Aquifer Exemption Order No. 6A (AEO No. 6A). The Commission's Order documents AOGCC's determination that the aquifers or portions of aquifers between 2500 feet and 5435 feet measured depth (MD) in, and within one-half ('h) mile radius of, Ivan River Unit (IRU) Well 14-31 are exempt for purposes of Class II injection activities and qualify for aquifer exemption under 40 CFR§ 146.4. The email requests EPA's concurrence with that determination. AOGCC, with the concurrence of EPA, previously granted an aquifer exemption for those portions of fresh water aquifers occurring within one-half (%2) mile radius between 2500 feet and 3420 feet MD in the IIZU 13-31 well under Aquifer Exemption Order No. 6, dated July 23, 2001. Union Oil Company of California, a wholly owned indirect subsidiary of Chevron Corporation, has now requested a depth extension for the aquifer exemption from 3420 feet to 5435 feet MD. EPA staff members have reviewed the material submitted by AOGCC on July 22, 2008, November 25, 2008, and November 26, 2008, which supports AEO No. 6A. Based on the information provided, EPA concurs with AOGCC's findings that the portions of the IRU aquifer identified in AEO No. 6A are at a depth or location that makes recovery of water for drinking water purposes economically or technologically impractical. EPA concurs with the AOGCC in their decision to grant AEO No. 6A' for Class II injection activities for aquifers in depth interval between 2500 and 5435 feet MD within the Ivan River Unit, Matanuska-Susitna Borough, Alaska. If you have any questions or need clarification, please contact Mr. Thor Cutler of my staff at (206) 553-1673. S' re , /// G 1~~J Michael A. Bussell, Director Office of Compliance and Enforcement cc: Shawn Stokes, ADEC, Anchorage, AK Jim Regg, AOGCC, Anchorage, AK Talib Syed, EPA Consultant, Denver, CO Printed on Recycled Paper ~5 November 26, 2008 Certified Mail -Return Receipt Requested Mr. Thor Cutler Ground Water Protection Unit US EPA Region 10 1200 Sixtll Avenue, OW-137 Seattle, WA 981.01 Dear Mr. Cutler: .... N~~ .~,.,.,.,.,...~...,M. ~...~.., .~~,~.~.u.~a_~.,~.....~._.~~...~...._.. ~t C r5~-z ` ~~ .. ~ ..F _ ._~_4'vUv~ .. _rr~._ 4~ ~._....- ~ ..-,., _-_ .. J ~'kkf' Ct~t.~ ~ Fr t ~'2 ~,~ 2c; ._._ I e~le-- .,. ~,~ ... ~ . ~,;,o,,,_... ,.... . ~'!:.~~~' ;, ,.~,,~_M ~~~:.~ ~c ice....,. ..._-.,~~....~..~.............~_..,,._....1~S.r......r...n...~.~..,.,,._..~,,,.__ µ~~q.,...~....,..~ The Alaska Oil and Gas Conservation Commission (Commission) received from Union Oil Company of California (Union) a request for an amendment to the Ivan River Unit (1RU) aquifer exemption. Union's specific request is a depth extension (deeper) of the exempted interval in Aquifer Exemption Order 6 that was issued in 2001 for Class II waste disposal injection lasing IRU Well 14-31. The draft aquifer exemption order amendment that has been prepared by the Commission is provided for EPA action as outlined in Section 14 of our Underground Injection Control (UIC) Memorandtun of Agreement. The Commission would. appreciate an expedited review with CPA concurrence by December 5, 2008 if possible. We apologize for the short response time being requested. The following documents are attached to facilitate EPA's review: • Application for aquifer exemption, as originally submitted by Union, dated July 15, 2008, and provided to EPA on July 22, 2008; • Public notice of the aquifer exemption request; • Revised application dated November 7, 2008; • Supplemental information provided by Union addressing questions posed by the COIl11niSSlo11; • Commission log analysis summary sheets and interpreted cross section; • Aquifer Cxe.mption Order 6 (July 23, 2001); • Proposed Aquifer Exemption Order 6A granting a depth extension. The Commission performed a comprehensive review of die forulation wafers for total dissolved solids. Despite total dissolved solids decreasing below 3000 parts per million at a depth near the base of the proposed injection zone, aquifers in the IRU area are so deep, sore~mote, and surface water is so plentiful that these aquifers will never serve as economic sources of drinking water. The IRU is a remote gas production f eld operated by Union and located on the west side of Cook Tnlet. In September 2008 the Commission received an application for a disposal injection Mr. Thor Cutler ~ • November 26, 2008 Page 2 of 2 order (DIO) for IRU Well 13-31 (a second Class II disposal well). That application has been reviewed in accordance with regulations at 20 AAC 25.252, and the final order awaits action on the aquifer exemption amendment. Union is currently performing a rig workover to convert IRU Well 13-31 from gas producer to Class II disposal injector. The Sterling Formation between 4272 feet and 4681 feet true vertical depth (5544 feet to 6183 feet measured depth) would be authorized for disposal injection upon approval of the DIO. IRU Well 13-31 penetrates the proposed injection zone within the %Z-mile radius used for the aquifer exemption in AEO 6. Thank you in advance for the prompt attention to this proposed aquifer exemption. Please contact me by phone (907-793-1236) or email (jim.re~g,~~~alaska.gov) should you have any questions about the attached information. Sincerely, James B. Regg UIC Program Manager AOGCC Attachments . ~ Page 1 of 1 Regg, James B (DOA) From: Scheve, Charles M (DOA) Sent: Wednesday, November 26, 2008 10:25 AM To: Regg, James B (DOA) Cc: Noble, Robert C (DOA); Jones, Jeffery B (DOA); Crisp, John H (DOA) Subject: weekly report /changeout 11/19/08 Travel to PBU and changeout with JJ. 11/20/08 MIT PBU W-11 & 4-28, took most of the day both tested good. Traveled to Nabors 19AC on Oogoruk ODSN-37 started testing BOP 11/21/08 Finished 19AC BOP test @ 4am returned to office around 9. The managed pressure drilling stuff is rigged up above the hydrill so I didn't do any pressure testing on this equipment. It didn't look like to bad a rig up but adds potential for screw ups with halliburton running this equipment. Attempted to get a nap, the phone and pager woudn't allow this to happen. BOP test Nordic 1 on Z-01 B, same old crap having to grease valves on tree and stack to get a test. 11/22/08 Misc SVS PBU Flow 3 (4 wells) Pilot on 15-20 tripped low retested good. 245 called with 24 notice at 2100. 11/23/08 Misc SVS PBU FIow1 (5 wells) all passed. waiting on 245. 11/24/08 MITs PBU PSI-05 passed, went to 3-33B, took about 3 hours to move and rig up start pumping, 5 gland nuts were leaking aborted test. Moved to 12-30 another 3 hours, in addition to 3 leaking gland nuts the stem packing on the annulus valve and the packing port were leaking aborted this test also. Had all could stand for the day 10 hours 1 MIT completed. Still waiting on 245. 11/25/08 SVS PBU J Pad (15 Wells) no failures. Headed out to 245 got there at 22:00 they were getting test pump rigged up. 7ES on H pad didn't get cement to surface and couldn't pump through Tam collar. Missed top job as 245 took priority, let them test choke manifold while gathering stuff for top job. 11/26/08 At 4:00 they had tightened up all the nipple up leaks and were ready to start testing. Got a test on the upper pipe rams, kill HCR and outside 3 valves on manifold. tried to open HCR kill and it woudn't work and was leaking oil around acuator. I went down to look at it and found oil leaking from ram body on lower pipe rams, it looked like it had been welded in the past but now had a pin hole leak. Told them to change out single gate or get written aproval from Hydrill to repair. Other items needing attention include, position indicator, pressure gauge, and continuous running pump on choke panel. Hammer union where Kill line comes off mud manifold. Don't know what else will pop up, I didn't check PVT system or gas detectors but all appeared to be operable. Going in, 7ES should call for BOP test (choke already tested) when they get finished cementing, and of course 245 when they repaired. No other irons in the fire. Chuck 11 /26/2008 Notice of Public Hearing • State of Alaska Alaska Oil and Gas Conservation Commission Re: Request for Depth Extension, Aquifer Exemption Order No. 6 Ivan River Unit, Well 14-31 Section 1, T13N, R9W, Seward Meridian, Westside Cook Inlet, Alaska Chevron North America Exploration and Production ("Chevron"), by letter dated July 15, 2008, has applied for a depth extension of the exempted aquifers of Ivan River Unit. Aquifer Exemption Order ("AEO"} No.6 was issued by the Alaska Oil and Gas Conservation Commission (Commission) in accordance with 20 AAC 25.440 on July 23, 2001 for a %Z-mile radius around Well I4-31 and between the depths of 2500 and 3420 feet measuxed depth for the purpose of Class II underground injection. Chevron is planning a second Ivan River Unit disposal injection well within that t/Z-mile radius and with a deeper injection interval. Disposal injection from this second well requires additional permitting in addition to the requested extension of AEO No.6. Chevron's applicatian may be reviewed at the offices of the Commission, 333 West 7th Avenue, Suite 100, Anchorage, Alaska, or a copy may be obtained by phoning the Commission at (907) 793-1221. The Commission has tentatively scheduled a public hearing on this application for September 4, 2008 at 9:00 am at the offices of the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchoxage, Alaska 99501. A person may request that the tentatively scheduled hearing be held by filing a written request with the Commission na later than 4:30 pm on August 15, 200$. If a request fox a hearing is not timely filed, the Commission may consider the issuance of an order without a hearing. To learn if the Commission will hold the public hearing, please call 793-1221 after August 22, 2x08. In addition, a person may submit a written protest or written comments regarding this application and proposal to the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. Protests and comments must be received no later than 4:30 pm on August 28, 2008 except that if the Commission decides to hold a public hearing, protests or comments must be received no later than the conclusion of the September 4, 2008 hearing. If you are a person with a disability who may need special accommodations in order to comment or to attend the public hearing, please ntact the Commission's Special Assistant Jody Colombie at 793-1221. Daniel T. Seamount, Jr. Chair • Chevron Sharon T. Sullivan Chevron North America HES Planning and Exploration and Production Permitting Specialist P.O. Box 196247 MidContinent/Alaska SBU Anchorage, AK 99519-6247 Te! 907 263 7839 Fax 907 263 7901 Cell 907 830 1821 Email SuliivanS@Chevron.com July 15, 2oas ,~~~. ~ ;zoos Daniel T. Seamount, Jr., Commissioner Alaska Oil and Gas Conservation Commission Alaska ~„~ $~ Gas Cons. Comn?siran 333 West 7th Avenue; Suite 700 _. Anchorage Anchorage, Alaska 99507 Re: REQUEST FOR DEPTH EXTENSION OF AQUIFER EXEMPTION ORDER N0.6 IVAN RIVER UNIT WELL 14-31, SECTION 1, T13N, R9W, S.M. WESTSIDE COOK INLET, ALASKA Dear Mr. Seamount: The Alaska Oil and Gas Conservation Commission (AOGCC) issued Aquifer Exemption Order No. 6 to Union Oit Company of California {UOCC), a wholly-owned indirect subsidiary of Chevron Corporation, on July 23, 2001. This order currently exempts those portions of freshwater aquifers lying between 2,500 feet and 3,420 feet measured depth (MD) and within aone-half mile radius of UOCC's Ivan River Unit (IRU) Well 14-31 for the purposes of Class II underground injection activities. The one-half mile radius was granted to allow for the possible permitting of a second disposal welt near the IRU Well 14-31 injection zone. UOCC respectfully reques#s that the AOGCC grant an extension of this freshwater aquifer exemption from 3,420 feet MD down to 6,195 feet MD. This would include the base of the injection zone of the planned second disposal well, IRU Well 13-31 which lies well within the'/ mile radius of the injection zone in welt 74-31. The attached Table 1 shows the salinity values in sands within the proposed injection zone in IRU Well 13-31, which correlate with the lower portion of the requested exemption depth in IRU Well 14-31. Thank you for considering this request. An application for a Disposal Injection Order for IRU Well 13-31 will follow shortly. If you have any questions or require addi#ional information, please contact me at 907.263.7839. Sincerely, ~~~~vz*m'~~d',~~~' Sharon T. Sullivan Planning and Permitting Specialist • ~ Table 1. Salini#y Values wi#hin Proposed Injection Zone Sands in iRU Well 13-31 Sand Depth Porosity Rt Rwa TFM Salinity (Degree MD SSTVD (%) (~hmm) (Ohmm) F) (ppm} 5, 585 -4, 235 24 2.96 0.1916 84 23, 300 5,695 -4,318 27 3.86 0.4182 84 13,800 5,730 -4,340 23 4.95 0.3651 84 16,000 5,845 -4,414 22 17.9 1.223 84 4,400 6,020 -4,526 25 95.7 1.453 86 3,600 6,150 -4,609 25 16.5 1.609 87 3, 300 1750080 KB 46.4 'MSL GL 26.9 'MSL METHODS Permafrost Present? No Lithology SS Shaley Formation? Yes Vshl Method: Steibner Porosity Method: Sonic-Empirical Sw Method: Mod_Simandoux HC Effect Applied? No Ivan River Unit 14-31 Unocal Summary Zone 4 5082' to 5284' MD Temp = (X 3"MD^3) + (X 2*MD^2) + (X 1*MD) + b X_3 0 X_2 0 X_1 0.007983 b 70.34736 PARAMETERS TDS = (X 2*NaCI^2) + (X 1*NaCI) + b Gamma Ray Clean 62 DT fluid 189 Gamma Ray Shale 91 DT matrix 55.5 X 2 -5.3E-06 Shale Density Poro 0.33 DT shale 138 X 1 1.251665 * Shale Neutron Poro 0.51 Rw 0.45 b 207.469 a 0.62 m 2.15 'Source: 081117 Unocals_Saliniry_and 7DS_Data_USGS aleska_rw xls n 2 Filtered to indude only wells in Southern Alaska with 7DS <35,000 ppm DEPTH TDS Sw INPUT OFFSET WELLS Measured TVDSS AOGCC AOGCC OPERATOR OFFSET Archie Mod Sim Fm GR Vsh RT Sonic-Empirical Rwa Measured De the 1-Pt 3-Pt Min 44-36 Tem Porosi 13-31 44-36 51UZ 3,y44.L 7,tiUU /,GUU - 4,4UU U.tS7b U./U4 IUZ.Ub /3 U.l by b.3 U.Zif4 V.b/b D/8Z DOlB 5156 3,978.6 4,200 4,200 4,250 4,900 0.603 0.482 102.32 75 0.212 12.9 0.269 1.238 5845 5675 5179 3,993.2 3,000 3,000 - 2,600 0.512 0.439 102.44 72 0.160 12.6 0.317 1.717 5877 5714 5259 4,044.2 2,200 2,200 - 2,600 0.432 0.399 102.85 68 0.079 17.1 0.322 2.406 5973 5784 ~~~ ~~ . 11/1 W2008 AOGCC 081119 1750080_IRU 14-31 Zone 4_TDS_5084-5284MD.xls 20,000 18,000 16,000 14,000 E a 12,000 0 ~- 10,000 ~a d R ~ 8,000 U 6,000 4,000 3000 ppm 2,000 AOGCC Ivan River Unit 14-31 TDS vs Measured Depth 3643 to 5470' MD 11/19/2008 081119_1750080_1 RU_14-31_Zones_0_5_TDS_3643-5470 M D.xls 3,600 3,800 4,000 4,200 4,400 4,600 4,800 5,000 5,200 5,400 5,600 5,800 6,000 Measured Depth (ft) 1920880 KB 51 'MSL GL 26 'MSL METHODS Permafrost Present? No Lithology SS Shaley Formation? Yes Vshl Method: Steibner Porosity Method: Sonio-Empirical Sw Method: Mod_Simandoux HC Effect Applied? No Ivan River Unit 13-31 Unocal Summary Zone 4 5745' to 5995' MD Temp = (X 3*MD"3) + (X 2*MD^2) + (X 1*MD) + b X_3 0 X_2 0 X_1 0.007983 b 70.34736 PARAMETERS TDS = (X_2*NaCi"2) + (X 1*NaCI) + b Gamma Ray Clean 62 DT fluid 189 Gamma Ray Shale 91 DT matrix 55 X 2 -5.3E-06 Shale Density Poro 0.32 DT shale 131 X 1 1.251665 * Shale Neutron Poro 0.6 Rw 0.75 b 207.469 a 0.62 m 2.15 ' Sour: 081117_Unocafs_Salinily_and TDS Data_USGS alaska_rw.xls n 2 Filtered to indude only wells in Southern Alaska with 7DS <35,000 ppm TDS Sw INPUT OFFSET WELLS Measured TVDSS AOGCC AOGCC OPERATOR OFFSET Archie Mod Sim Fm GR Vsh RT Sonic-Empirical Rwa Measured De th 1-Pt 3-Pt Min 44-36 Tem Porosi 14-31 44-36 578'L 4,373.8 6,5UU d,5UU - 4,4UU U.yyU U.8/5 1U5.4/ /L U.154 5.`J U.31U U./btl D1 UL 5blif 5845 4,414.1 3,600 2,800 4,250 4,900 0.737 0.585 105.79 75 0.225 14.8 0.265 1.381 5156 5675 5877 4,434.6 3,200 3,100 - 2,600 0.689 0.537 105.96 76 0.248 15.1 0.280 1.578 5179 5714 5973 4,496.1 2,500 2,000 - 2,600 0.612 0.536 106.45 71 0.135 16.4 0.301 2.004 5259 5784 • 11 /19!2008 AOGCC 081119 1920880 IRU 13-31 Zone 4 TDS 5745-5995MD.xls Ivan River Unit 13-31 TDS vs Measured Depth 3952 to 6184' MD 20,000 ___,_ . ___.,__ __,"_, _~__ _. ___ _ ___.__ _ ~._~_u_~_.__ ______._ . _-.__.__.__. • AOGCC TDS 18,000 - - - - - ^- ~', ^ Operator TDS 16,000 _ - - - 14,000 - - - - - - - E a 12,000 -- - 0 ~ 10,000 .: A ~ • ~~ ~ 8,000 ~ I . ~' ca ~.• • • ~. 6,000 ~ • •~~ • ~• • • • • t • ~ • ~• ~ • ~• 4,000 • •t • • ' ^ 3000 • ppm • • • .• ^ 2,000 • ~ • t ~•ir 3,900 4,100 4,300 4,500 4,700 4,900 5,100 5,300 5,500 5,700 5,900 6,100 6,300 Measured Depth (ft) 1 v1 si2oo8 081119 1920880 IRU 13-31 Zones 0 5 TDS 3952-6184MD.xls • AOGCC 1930220 KB 51 'MSL GL 26 'MSL METHODS Permafrost Present? No Lithology SS Shaley Formation? Yes Vshl Method: Steibner Porosity Method: Neu-Den_Avg Sw Method: Mod_Simandoux HC Effect Applied? No Ivan River Unit 44-36 Unocal Summary Zone 4 5586' to 5813' MD Temp = (X 3*MD^3) + (X 2*MD"2) + (X 1*MD) + b X_3 0 X_2 0 ~1 0.007983 b 70.34736 PARAMETERS TDS = (X 2*NaCI^2) + (X 1*NaCI) + b Gamma Ray Clean 62 DT fluid 189 Gamma Ray Shale 91 DT matrix 55.5 X_2 -5.3E-06 Shale Density Poro 0.32 DT shale 127.5 X 1 1.251665 Shale Neutron Poro 0.59 Rw 0.70 b 207.469 a 0.62 m 2.15 "Sourrs: 081117_Unocals Salinity and TDS Data USGS aaska rw.xls n 2 Filtered to indude only wells in Southern Alaska with TDS <35,000 ppm DEPTH TDS Sw INPUT OFFSET WELLS Measured TVDSS AOGCC AOGCC OPERATOR OFFSET Archie Mod Sim Fm GR Vsh RT Neu-Den_Avg Rwa Measured De th 1-Pt 3-Pt Mln 14-31 Tem Porosi 14-31 44-36 bti1S 4,"LtiS./ 4,4UU 4,4UU - /,6UU U.//tS U./3Z 1U4.63 673 U.UiS3 5.b V.3tSD I."ID8 D1UZ 5/tfZ 5675 4,305.2 4,900 4,900 4,250 4,200 104.92 77 0.276 13.8 0.239 1.025 5156 5845 5714 4,330.1 2,700 2,600 - 3,000 0.609 0.527 105.12 72 0.154 14.1 0.314 1.886 5179 5877 5784 4,375.1 2,700 2,600 - 2,200 0.611 0.523 105.48 71 0.137 20.5 0.263 1.877 5259 5973 • • t vtsnooe AOGCC 081119 1930220 IRU 4436 Zone 4 TDS 5586.5813MD.xls Ivan River Unit 44-36 TDS vs Measured Depth 3892 to 5989' MD 20,000 ___..._ _... _ ___ __ _- _.__. ___ _.______ ___ __ _____ _._ _ _._ _ _ - r • AOGCC TDS ~ 18,000 - - -- ~ Operator TDS -- 16,000 - - -- - • 14,000 E a 12,000 • v~ p • i • • ~ 10,000 ~ tai • v ~ 8,000 .: ~t~~ ~ • s ~ • • _ 6,000 ; • •. jw- ~ _ •~ ~' • •: 4,000 • . ~ ~ ~ "7 . . = i ~•; L~ • ~• ~ • 3000 ppm 2,000 { : • • • ~ f . • +1 I 3,900 4,100 4,300 4,500 4,700 4,900 5,100 5,300 5,500 5,700 5,900 Measured Depth (ft) • ~ cam. ~~' ~~ ~~~ ~~s~~ Revised Table 1 Salinity Values within Proposed Injection Zone Sands in IRU i 3-s~ 11 /14/2008 ~®GCC NaCI Equiv. Calc Sand Depth Porosity Rt Rwa TFM Salinity TDS" MD SSTVD % (Ohmm) (Ohmm) (Deg. F) (ppm) 5,565 -4235 27 2.88 0.267 103.9 16,300 20,049 5,695 -4318 26 3.96 0.225 104.5 19,550 24,047 5,730 -4340 24 3.47 0.29 104.7 14,780 18,179 5,845 -4414 24 14.4 1.125 105.3 3,450 4,244 6,020 -4526 25 16.8 1.562 106.2 2,420 2,977 6,150 -4609 24 22.3 1.839 106.5 2,030 2,497 * Based on spreadsheet provided by Unocal via email 11/14/2008, that is saved as G:\common\West Team\OrdersWquifer ExemptionslAEO_6A IRU_13-31\ 081114_Unocals Salinity_and_TDS_Data_USGS alaska_rvv.csv Per email from T. Hillegeist, Chevron to J. Regg, AOGCC, dated 11/14/2008, the conversion from NaCI equivalent to TDS is TDS (ppm) = 1.23 X NaCI equivalent (ppm) AOGCC 11/17/2008 using data from USGS provded by Unocal 081114 UNocals Salinity_Values_Aquifer Exemption IRU 13-31 Revised Table 1 .xts • • Revised Table 1 Salinity Values within Proposed Injection Zone Sands in IRU 13-31 11 /14/2008 NaCI Equiv. Sand Depth Porosity Rt Rwa TFM Salinity MD SSTVD 5,565 -4235 5,695 -4318 5,730 -4340 5,845 -4414 6,020 -4526 6,150 -4609 (Ohmm) (Ohmm) (Deg. F} (ppm) 27 2.88 0.267 103.9 16, 300 26 3.96 0.225 104.5 19,550 24 3.47 0.29 104.7 14,780 24 14.4 1.125 105.3 3,450 25 16.8 1.562 106.2 2,420 24 22.3 1.839 106.5 2,030 • • ®avies, Stephen F (®®~,) From: Hillegeist, Tony [Hi11eTK@chevron.com] Sent: Friday, November 14, 2008 6:43 PM To: Davies, Stephen F (DOA) Cc: Regg, James B (DOA); Sullivan, Sharon T; Whitacre, Dave S; Orr, Gary A. Subject: FW: AEO 6 Depth Extension Importance: High Attachments: USGS alaska_rw.csv; Aquifer Exemption IRU 13-31 Revised Table 1 .xls Steve, Here is the revised "Table 1"for the IRU 13-31 well aquifer exemption. Revised Table 1 Salinity Values within Proposed Injection Zone Sands in IRU 13-31 11 /14/2008 NaCI Equiv. Sand Depth Porosity Rt Rwa TFM Salinity MD SSTVD 5565 -4235 5695 -4318 5730 -4340 5845 -4414 6020 -4526 6150 -4609 (Ohmm) (Ohmm) (Deg. F) (ppm) 27 2.88 0.267 103.9 16300 26 3.96 0.225 104.5 19550 24 3.47 0.29 104.7 14780 24 14.4 1.125 105.3 3450 25 16.8 1.562 106.2 2420 24 22.3 1.839 106.5 2030 In reference to your second question on NaCI Equiv to TDS. Using the USGS Alaska data that we have available to us at this time. I am inclosing this table. TDS = 1.23 x NaCI Equivalent. (based on average of 60 samples) Please let me know if you have any questions. Thanks your attention to this issue. Tony Hi//egeist Staff Geologist Chevron North America Exploration and Production Mid-Continent/ Alaska Business Unit 909 West 9th Avenue, Anchorage AK 99501-3322 Tel 907 263 7877 hilletk@chevron.com From: Regg, James B (DOA) To: Sullivan, Sharon T ra~~i~a~, 11/17/2008 Cc: Davies, Stephen F (DOA) Sent: Fri Nov 14 15:39:48 2008 Subject: AEO 6 Depth Extension per our phone call, below is the assessment from Steve Davies and his request: - Please have Chevron's geologist / petrophysicist update the TDS values in Table 1 of their most recent submittal; The values in that table don't reflect the revised temperature estimates for the injection zone (in their original submittal it was ~85 deg F, but has been revised to 105 deg). - Near the bottom of page 6 of their most recent formation evaluation submittal (Ivan River Unit Aquifer Exemption Questions Followup.pdf), they state that the Rw for the lower injection zones equates to 2700 ppm NaCI equivalent. What does this say about the TDS content of the connate waters in those zones? If you can get us the info today, Steve has indicated he will continue reviewing over the weekend. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 11/17/2008 rage ~ Qa ~ ®~~ies9 ~t~phen F ~~~11) From: Regg, James B {DOA) Sent: Wednesday, November 12, 2008 9:21 Aid To: Davies, Stephen F (DOA) Subject: FW: Ivan River Unit Aquifer Exemption Extension -Additional Information Needed Attachments: AOGCC AEO Extension Letter Request rev1.pdf; IRU_44-36 mudlog_section.pdf; IRU_13- 31 mudlog_InjectionZone.pdf; IRU_14-31 mudlog_InjectionZone.pdf; IRU_41- 01 mudlog_seciion.pdf; Temperuature_Pressure IRU44-01.pdf; Ivan River Unit Aquifer Exemption Questions Followup.pdf; DIO Permit App IRU 13-31_rev2.pdf Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Sullivan, Sharon T [mailto:SullivanS@chevron.com] Sent: Saturday, November 08, 2008 5:48 PM To: Regg, James B (DOA) Cc: don.andrews@asrcenergy.com Subject: RE: Ivan River Unit Aquifer Exemption Extension -Additional Information Needed Hi Jim, I have attached the following files in response to Steve Davies request for information in your a-mail below: • The Ivan River Unit Aquifer Exemption Questions Followup document with a Temperature and Pressure file and mudlog excerpts from IRU wells 13-31, 14-31, 41-01, and 44-36, • The Revised AEO No. 6 Depth Extension Request Letter that clarifies the requested end depth for Well IRU 14-31, and • The Disposal Injection Order Application (Revision 2) for Well IRU 13-31 that also clarifies the requested end depth for Well IRU 14-31 in the aquifer exemption section of the document. You have now received our responses to both your and Steve Davies's request for information (the a-mail sent to you on November 3, 2008 responded to your request for information/clarification). If you have more questions or require additional information regarding this submittal, please let me know as soon as possible. Once you deem the information you received to be satisfactory, I will send you the final hardcopy versions. If there is anything you can do to help expedite the issuance of the revised or amended AEO No. 6 for IRU 14-31 and the new DIO for IRU 13-31, 1 would really appreciate it since we are now on a very time-critical path with the drill rig arriving at Ivan River Pad this coming week. Thank you very much! Sharon T. Sullivan Planning & Permitting Specialist, HES Group Chevron North America Exploration and Production Company MidContinent/Alaska Business Unit 11/12/2008 • • 300 Cer~ierpc~inz I;r-i,;e; .'l~vh~ra~e, >>~ 9'~S0 Office 90?.263.1839 Cell 907.~3~~.1821 Fay ~66.~U1.Sl°4 Email SulliaanS~~.Chevr~n.cc~r;i From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov) Sent: Monday, October 20, 2008 5:44 PM To: Sullivan, Sharon T Subject: FW: Ivan River Unit Aquifer Exemption Extension -Additional Information Needed Listed below are questions/requests posed by our Sr. Geologist that are needed before we can complete the amendment to AEO 6. These are equally important for us to complete the DIO application for IRU 13-31. In addition to the questions/requests for the AEO 6 amendment, please address the following specific to IRU 13-31: 1) there needs to be a more detailed discussion of the upper confinement and why Chevron believes it will confine the injected fluid stream; 2) there is a mix of depths used throughout the application (MD and TVD); the datum (MD, TVD, TVDss) is not referenced on several of the exhibits (e.g., Exhibits 2,5,6,7) -please clarify; 3) Exhibit 8 indicates a top of cement (TOC) at 6250 ft that appers to represent the well's plug back depth; header for the well schematic references plug back depth (PBTD) as 7400 feet -please clarify; 4) Exhibits 10 and 11show proposed injection perfs as Beluga formation; the remainder of the application references proposed disposal injection perfs in the Sterling formation -please clarify; 5) Exhibit 11 indicates TOC for 7" csg is 5600 feet; other well schematics far IRU 13-31 show it at 5000 feet -please clarify 6) Exhibit 11 indicates a USIT was used to establish TOC in IRU 13-31-only bond lag information in Commission files are sepia copies of segmented bond logs for portions of 7" (surface to 2800 ft) and 9-5/8" casing (1470 to 3400 ft); provide USIT log data Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 su I live ns ~cheyro n_co m From: Davies, Stephen F (DOA) Sent: Monday, October 20, 2008 10:13 AM To: Regg, James B (DOA) Cc: Roby, David S (DOA); Maunder, Thomas E (DOA) Subject: Ivan River Unit Aquifer Exemption Extension - Addfional Information Needed Jim, Since you are coordinating this AEO extension, I thought it best to relay these questions and requests for the operator through you. The structure at the level of the proposed injection zone in Ivan River Unit 13-31 is relatively flat, the stratigraphy is not complicated, there are several nearby wells, and mud logs from those wells suggest that gas may be present within the downward expansion of the aquifer exempted by Aquifer Exemption Order No. 6. In order to ensure that water-quality standards are met and that natural gas resources will not be wasted, additional information is needed. Formation temperature calculations 11/12/2008 • A Q~6+ J ail J Please discuss derivation of the temperature gradient from surface through the proposed injection interval, incorporating maximum temperature readings recorded in wells 41-01, 44-36, 14-31 and 13-3 i. Is any additional temperature information available? If so, please provide copies to the Commission. _ _ _ _. - - . . Lithology - Please provide a detailed lithologic description of the proposed injection zone and the proposed expanded exemption _ _- zone. How do the lithologic components affect gamma ray, SP, sonic, density and neutron measurements throughout the expanded exemption zone? For log analysis purposes, would the sand beds within the proposed injection zone be considered clean_or shaly? Please explain. Are additional data, such as core or sidewall core descriptions available? If so, please provide copies to the Commission. ~ -- - - Porosity Please describe techniques used to calculate porosities provided in the application to expand the aquifer exemption. Justify their use over other techniques in this instance. Mud logs from nearby wells 44-01, 41-01 and 44-36 suggest that methane gas is present throughout the proposed expanded aquifer exemption interval. Please explain and demonstrate how wireline porosity measurements were corrected to compensate for any affect of any gas present. Were shale corrections utilized in your calculations? If so, please describe the techniques and demonstrate their validity. Total Dissolved Solids Since the stratigraphy is relatively uncomplicated and there are several closely spaced wells, TDS calculations within a given interval in well 13-31 should be replicated in stratigraphically equivalent beds logged in nearby wells 44-36 and 14- 31. Please provide confirming TDS calculations in representative beds for well 13-31 and these nearby wells. Were environmental corrections made to any of the well log measurements? If so, describe what was done and demonstrate validity of the corrections. Were any waters recovered from any of the Ivan River Unit wells analyzed for TDS content? If so, please provide copies to the Commission. Natural Gas Content Please explain why the proposed injection activities will not result in waste of natural gas resources. Provide water saturation analyses and test or production information from representative sand beds within the proposed expanded exemption zone demonstrating whether or not commercial quantities of gas aze present. Explain and justify the choice of technique(s) and critical parameters such as Rw. Please describe and demonstrate how these parameters were obtained. Thanks, Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission Telephone: (907) 793-1224 ~' Fax: (907) 276-7542 New Email Address: steve.davies~alaska.gov_ 11/12/2008 • • Revised Table 1 Salinity Values within Proposed Injection Zone Sands in IRU 13-31 11/14/2008 AOGCC NaCI Equiv. Calc Sand Depth Porosity Rt Rwa TFM Salinity TDS IVID SSTVD % (Ohmm) (Ohmm) (Deg. 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Lc~catian: IV,~N RIVER Field & pool..; Production inter•,tal.: t?€ci point 'uerf : 79{3fl ~lel l status : SMUT IN Test t^Tpe: STATIC CRAT)TENT Elevations KB: C~'; ~3ate of test: 97/fl2/2~ Shut in date: Tubing pressure cefore: 1755 Tubing pressure alter: 1755 Casing pressure before: Casing pressure after: Tubing diameter: Z-7~8 Casing diameter: 7~-5/8„ Probe serial ~: 20f3t~8 I;FI+IAI ~K, ~2eadiaags and Calcu3.atzons Fc3r Static Gradient depth Time Stop Te~oerature _ Pressure Gradient Stops ~ ~' ) ( PSIA ) PSI~~`F ~ Sur>ace 2fla~1 _ 2D:55 69.1 176297 C3.Oflt3 ?40.(3 2fl:29 _ ?C3.35 86.9 1788.5 t~.t3~'7 1445, fl 2(3: Zfl - 20:26 BS a 8 I8~?~. 3. 13.341 240,0 2£3:1,1 - 2fl:17 8$.3 1866.1 f3. (342 3445.fl 2f3:fl2 -- 2(?:fl8 98.2 19{38.3 ~.~342 =~~~c~.G 19:52 - 19:68 1.{31. i 1951.9 t~.t34~ 5446. fl 19.42 ~- 19 ; a8 ifl8.9 3.995. ~ fl o fl43 6446. u 19:26 - 1.9:32 115, 1 2fl38.6 C3. fl43 b94o.{3 19:18 - 19:24 17, 1' 1. ~?. 1. 2 t~D }~ ~.~ 3 ,. .3~1i 19iti ._ ~7.. i~ y ~.L~s.~1 9 ~ L~CJZ~ q n ~,.. V'2~ ~ • .. ~ _ -~y t# ~. 't w ~ ~, . .. .._ ~ Vii. ~~ _ .c ... ~~:_,~~ < z Y~..:.t~~ .w. .~s. ;^# x m LA ~LS~~ a'~.~r.XwL.i 6:~ ~.~w4 ~'W~~ L~..~,e A' Y.~s AL ~< ~. • • Formation Evaluation of the Proposed Injection Lone in IRU 13-31, Addressing AOGCC questions on the "Application for Disposal Injection Order Ivan River Unit Development Project, September 2008" 07 November 2008 Formation temperature: The graph below summarizes the temperature data currently available to us: - bottom-hole temperature (BHT) recorded at logging in wells Ivan River Unit ([RU) 13-31, 14-31, 23-12, 44-01 and 4l-Ol, plotted as a function of the time since last circulation (TSLC) for these wells - a complete temperature survey after 3-day shut-in for IRU 44-01 The temperature profile is given by the equation FTEMP = 70 - 0.008 TVDSS, where temperatures are in degF and TVDSS in ft. ~' ~ r ~` -' i ,, ~F; , ~~ _ -; ~~~' `~ ~ ~ ~,T ,i "' 0 50 \ 100 150 200 250 -2000 X-~ --- -4000 ' -6000 '~ -~ ~ - - -- ~ -8000 _- ~`O~- o a -10000 ~ X IRU BHT record (TSLC< ___ - - -- -- - 6 hrs) O IRU BHT record (6 hrs < -12000 I TSLC < 10 hrs) _ _ _-_ -- - - ^ IRU BHT record(TSLC >10 hrs) ~ -14000 - ---;- IRU 44-01 temperature - - - - log after 3-day shut-in ~ - Trend for IRU field -16000 - - -- - - - - -- - -18000 Measured BHT (degF) [See attached. pdf file: Temperature_Pressure [RU 44-01 ] • • Lithol®gy: The proposed injection zone is described from offset mudlogs (cuttings description records) as a mix of coals, unconsolidated sands or conglomerates (for the zones with lower Gamma-Ray readings) and sands with some clay and abundant tuffs and volcanic materials (zones with higher GR readings). Please see attached mudlogs for wells IRU 13-31, IRU 44-36, IRU 14-31 and IRU 41-01 in the equivalent section, representing the injection zone. (See the four attached .pdf mudlog section files for detail) No core is available for this part of the section. Mudlog description: The section can be divided into three major zones. The upper most being a low resistivity sands 5544'-5746 MD, and two higher resistivity zones in the lower section from 5746'- 6183' MD in the IRU 13-31. The following mudlog description summarizes the section and is taken from the mudlogs of IRU 13-31, 44-36, and 41-01. At the top of the injection zone and just above is a tuffaceous claystone that appears to be 20' to 30' (TVD) in thickness. The upper low resistivity sand is described generally as a massive fine to coarse grained pebbly sandstone with only minor amounts of finer material. The upper sand appears to be cleaner than the lower sands, but still contains some lithics of metavolcanic and igneous grains. Locally the quartz content as high as 80 percent (IRU44-36). This sand sits on a possible disconformity within the Sterling section. The lower section is topped by about 100' (TVD) of thin interbedded tuffaceous claystone, claystone, sandstone, coal and mudstones. The sands are described as being very tuffaceous with quartz as low as 15 percent in some samples. Below this section is a more massive sand made up primarily of a tuffaceous matrix. The sand is poorly sorted with very fine to granular grains, predominantly fine to course. Quartz ranges from 15 to 40 percent. At the base of the sand is a thin tuffaceous mudstone made up of approximately 75 percent clay and 25 percent silt. The lowest lobe is made up of a conglomeratic tuffaceous sand. This sand is poorly consolidated, fine to very coarse with interbedded stringers of conglomerate, and grain supported. The section is very low in quartz, ranging from 10 to 40 percent. The remainder of the sands are made up of metamorphics, chert and igneous lithics, with minor amounts of feldspar. Below the base of injection zone is a thin section of coal and claystone. 2 ~ • Petrophysical: Given these descriptions and an established knowledge that GR can be adversely influenced by volcanic materials in parts of the Cook Inlet, the neutron-density separation was used to calculate shale index. The SP log is better suited to identify the sands insofar as there is resistive contrast between formation brine and mud filtrate. Gas identification is provided by the sonic log, which is in that region more sensitive to gas presence than the density log regardless of shaliness. The Appendix Attachment-1 shows a typical gas response, within this section, of that formation in a nearby field (North Cook Inlet Unit). In IRU 13-31, no such behavior of the sonic log is observed; this supports the absence of gas pay in the proposed injection zone. [n the absence of obvious gas effects, the neutron and density responses reflect lithology and shaliness. In the zone of interest, there is mark of a 30'-thick shale around 6000' MD, while the neutron-density separation remains consistent above and below that shale regardless of the GR log, likely affected by laminae of volcanic deposits. However, neutron and density logs are not available in IRU 13-31 in the obviously clean low- resistivity zone above 5750' MD (-4353' TVDSS), so to compare these zones we consider the offset well IRU 14-31. This offset shows that the neutron-density separation remains consistent across all the sands of the zone of interest, regardless of GR and resistivity. For log analysis purposes, we can therefore consider these sands as clean. Coals are characterized by local peaks of high porosity, low GR and high resistivity. In IRU 13-31 and 14-31, a simple flag using a porosity cutoff of 0.35 correctly captures all the coals. In IRU 44-36, crossovers of density porosity (DPHI) and sonic porosity (SPHI) indicate the cause for the porosity increases: coal are characterized by DPHI>SPHI while gas sands are flagged by SPHI>DPHI. • • _ j, v/~ ~r~ P ro { ;..7 y,. i Cr ~A~ ~S { lid {~f~~ l~)~r~~~~ ~~±~,~;m; F} (~ 5,565 -4,235 24 2.96 0.1910 84 23,300 ~,~95 -4,318 2? 3.86 0.4132 84 13,800 5,730 -4,344 23 4.95 0.3661 84 16,000 5,845 -4,414 22 17,0 1.?23 84 4,400 6,020 -4,526 25 15.7 1,453 $6 3,600 6,150 -4,609 25 16.5 1.609 87 3,300 • • Porosity9 salinity and gas content: As shown in the previously shown logs of wells 13-31 and 14-31, there is excellent correlation in the zone of interest between density porosity (with a default value of 2.65 g/cc grain density, curve DPHI) and a Wylie sonic porosity (curve SPHI) using a compaction coefficient c SPHI = (DT - SS) / (c * (189-55) ), where DT is in ,us/ft c needs to be zoned, but in the proposed injection zone is it 1.8 for well 13-31, 1.9 for 14- 31,and 1.7 for 44-36. The mudlog of IRU 13-31 shows gas in a coal and mudstone zone above the zone of interest around 4500' MD (-3553' TVDSS), in coals (5045' MD/ 3903' TVDSS; series of coals between 5750' MD/-4353' TVDSS and 5854' MD/-4420' TVDSS; 6195' MD/- 4638' TVDSS). Likewise, in IRU 14-31 mudlog there is an increase background gas in a zone at 4125' MD (-3586' TVDSS) which is above the injection zone. The low, constant background gas continues over most zones of interest. The is a substantial gas show increase in the coals below the zones of interest (around 5700' MD/-4844' TVDSS), and is just above the know productive gas sands in the well. In IRU 44-36, there is no gas show across the zone of interest (5200' to 6000' MD or roughly -4080 to 4640' SSTVD) Overall, none of these wells presents evidence of gas seeping from the sands of the . proposed zone of injection. Finally, the apparent formation water resistivity (Rw) was computed both from an inverse Archie relation (assuming a=1 and m=1.8 which is appropriate in poorly consolidated sands) .and from SP, using the temperature trend determined earlier and the following measured values of mud filtrate resistivity: Rmf = 1.56 Ohm.m @ 64 degF for IRU 13-31 2.34 64 14-31 1.04 64 44-36 Rw computed from the maximum SP deflection in a sand (RWA_SP) usually gives the lower-end of a possible Rw range in that sand. Apparent Rw from Archie (RWA) represents the value of Rw that this sand would have if it were wet. RWA increases if the sand is not wet and/or if the actual value of Rw increases. A quality index is here given by the separation between RWA_SP and RWA. As shown in the following displays, Rw can be very reliably determined in both the low- and high-resistive zones by agreement between RWA and RWA_SP: • in the top zone Rw = 0.3 Ohm.m @ 105 degF or 14,000 ppm NaCI equivalent ((Schlumberger chartbook) • in the bottom zones Rw = 1.5 Ohm.m @ 105 degF or 2,700 ppm NaCI equivalent , f The value in the top zone remains compatible with both IRU 13-31 and 44-36, but in the IRU 13-31 lower zones RWA increases and with a minor amount of gas -not enough to justify an increase in sonic porosity, but sufficient to reduce the neutron-density separation and impact resistivity. An Archie saturation with a=1, m=1.8 and n=2 yields 6 • • Sw = 0.8 in the sand lobe 5900'-5760' YID and Sw = 09 in the lobe 6030'-6150', everything else being wet in the proposed injection zone. Given the approximations on the SP baselining and Archie's coefficients, we conclude there is some irreducible residual gas in these to parts of the lower zones of IRU 13-31 injection section. These levels of gas are not high enough to be commercially economic. y Similar calculations in IRU 44-36 yield Sw = 0.8 in the high-resistive sand lobes 5718'- 5782' MD and 5850'-6136' and the same conclusion applies. See following five well log displays. This petrophysical formation evaluation was conducted independent of earlier work and was completed by Emmanuel Toumelin -Chevron Petrophysicist and Tony Hillegeist - Chevron Geologist 7 • ~~o~~ ~~L v~~~[ L~~.t_. l :x-~ L t~ ~~r~ ~oFl., ~L ~S~-v~pc7~d ~Eti~ertrar~ Y [ C` SPHI_ 1 PT1~ ~ I b1riRE.ILM_i _ _ .~_._. ~.o. ,~..v~ e m®ma« -.s®~~mo ®® -o )~~ ®~.o . ~, ~d~ ~®moe ®~®®~ rs~-' ~(.~~ ® v~~~ ~ o® ~s ~F.,~ tw ~~ ®wo. o~~wo :~~ ..~ ~® . ® ~x ~ ~~ ~eeo ~~m T_~ -a" ~~~ il~(j ~~ ~~ ..... ~ a® ~ . .... mom... -Sa® ~® y. i ~ O~ ®® reae s~mmnr ~®va. ~ oo® } 4 '... ~~ 4 ~ • Logs of well IRU l ~-31 in the zone equivalent to the proposed injection wne ti•om IRU Ii-31: fvD~S I GEPTF FEET FEET _.. ._. - 4900 5Q00 -4300 5100 -4400 5200 -4500 5300 -4600 5400 • • i~FU ~.r-.y ~ at~~~i:~y SS t.~Ei' ; t 3 PEc~ 560!> OG 57oG 58GG 70 s~oG ~o soot h~oo ~o • IKU l ~-31 display: • [E71~ 44-3h ciisp(ay CJ 10 • Residual gas saturation in IRU 13-3 r~os> c~EFrr fFtf FEET 5600 -4300 5700 5800 -4400 5900 -4500 6000 6100 -4600 • • C~U~i~u~.C g~~ ~:tu!u~!.G.rc~b~ ire E~~ ~~-~.s~ • Y2 • .Appendix: Attachment-1 Log of North Cook [nlet [Jnit A-12 well ___ cali____i 1h'IRE.ILD_1 SF'HI_1 6 w 2a 1 oHn~al 1ao ~ v! o _.__...~__.._ . __._ ...__ TVDS,~ tF~f GEPI-N FEET ilm DPHI_1 1 OHld R4 100 .6 V!V G WIRE.GR_1 ••~~•• ••"•" sfl _ . 5 GAPI 75 1 Oflf.ll;i 100 . ---- .,---___.__~. ~ ~~ "t -.3 X00 ,,... ~. ' ~~ , -r~ ~ " .r ~ •, •- ~ ~ ~y ~ i j ~, r- I 3 ~3 " 1` ~~ yAy ~, - ~~,~` ~ -3600 - -- - ~ ."~• f ~• •- •t. c ~ -.` { ~; ~ ."' -~r-~ --- ----- °-- e.s . t"^, - . . '`~ "- - - ti r = ~ ~ ~-- --- ~ 3aoo -- - ~ ~ - ~~:~ ~i -3?00 - ---- - ----- .. ..~.., ,w~.. ~~t~" ` ..r ,' ~ .~ ~ 4 " ~ .. : The sand between 3642' and 3779' (MD) is fractioned by a known gas-water contact at 3714' MD; with water below this depth, and gas, above. The top (gay pay) exhibits a strong sonic porosity (SPHI) crossover, while the density (DPHI) is only moderately affected by gas. The wet zone below exhibits a good match between sonic and density porosities. l3 ~ 4 • Regg, James B (DOA) From: Talib Syed [talibs@ecentral.com) Sent: Wednesday, November 26, 2008 12:37 PM To: Regg, James B (DOA) Cc: cutler.thor@epa.gov Subject: Re: Draft Aquifer Exemption Order -Ivan River Unit Jim, Thank you for the additional information received. Talib ----- Original Message ----- From: "Regg, James B (DOA)" <jim.regg@alaska.gov> o: "Talib Syed" <talibsC~ecentral.com>; <cutler.thor@epa.gov> S t: Wednesday, November 26, 2008 2:14 PM Su 'ect: RE: Draft Aquifer Exemption Order - Ivan River Unit > Some a ditional information and clarification to assist your review - > 1) Cross ection provided to you this morning is AOGCC interpretation > based on 1 information provided by Union; same regarding the log > analysis su ary sheets (also AOGCC interpretation); > 2) Salinities reported by Union (their calculations from log analysis)in > July 15 applic tion were revised and provided to AOGCC on November 7 > (forgot to incl e that in my initial email) - revised table is > attached; > 3) IRU 14-31 mecha ical integrity assessment is attached. > Thank you again for pediting this review. Call if you have any > questions. I will be 'n the office Friday. > Jim Regg > AOGCC > 333 W.7th Avenue, Suite 100 > Anchorage, AK 99501 > 907-793-1236 > -----Original Message----- > From: Talib Syed [mailto:talibs@e entral.com] > Sent: Wednesday, November 26, 2008 :54 AM > To: Regg, James B (DOA) > Cc: cutler.thor@epa.gov > Subject: Re: Draft Aquifer Exemption O der - Ivan River Unit > Jim, > Received the cross-section. > Thanks, > Talib > ----- Original Message ----- > From: "Regg, James B (DOA)" <jim.regg@alaska.g v> > To: <Cutler.Thor@epamail.epa.gov> > Cc: <talibs@ecentral.com> > Sent: Wednesday, November 26, 2008 10:35 AM > Subject: RE: Draft Aquifer Exemption Order - Ivan R ver Unit » Thor and Talib - » Here is the cross section I referenced. 1 • • Regg, James B (DOA) From: Regg, James B (DOA) Sent: Wednesday, November 26, 2008 12:14 PM To: 'Talib Syed ; cutler.thor@epa.gov ~~~ ~, ~~2>~ Subject: RE: Draft Aquifer Exemption Order -Ivan River Unit Attachments: aeo6_depth_extension_request_rev_2008-1107.pdf; IRU_14-31_mech_integrity_ 2008-1126.pdf L~ l-J aeo6_depth_exten IRU_14-31_mech_i sion_request_r... ntegrity_2008-... Some additional information and clarification to assist your review - 1) Cross section provided to you this morning is AOGCC interpretation based on log information provided by Union; same regarding the log analysis summary sheets (also AOGCC interpretation); 2) Salinities reported by Union (their calculations from log analysis)in July 15 application were revised and provided to AOGCC on November 7 (forgot to include that in my initial email) - revised table is attached; 3) IRU 14-31 mechanical integrity assessment is attached. Thank you again for expediting this review the office Friday. Call if you have any questions. I will be in Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 -----Original Message----- From: Talib Syed [mailto:talibs@ecentral.com] Sent: Wednesday, November 26, 2008 9:54 AM To: Regg, James B (DOA) Cc: cutler.thor@epa.gov Subject: Re: Draft Aquifer Exemption Order - Ivan River Unit Jim, Received the cross-section. Thanks, Talib ----- Original Message ----- From: "Regg, James B (DOA)" <jim.regg@alaska.gov> To: <Cutler.Thor@epamail.epa.gov> Cc: <talibs@ecentral.com> Sent: Wednesday, November 26, 2008 10:35 AM Subject: RE: Draft Aquifer Exemption Order - Ivan River Unit > Thor and Talib - > Here is the cross section I referenced. > Jim Regg > AOGCC > 333 W.7th Avenue, Suite 100 1 Anchorage, AK 99501 • 907-793-1236 -----Original Message----- From: Cutler.ThorCepamail.epa.gov [mailto:Cutler.Thor@epamail.epa.gov] Sent: Wednesday, November 26, 2008 6:24 AM To: Regg, James B (DOA) Cc: talibsc~ecentral.com Subject: Re: Draft Aquifer Exemption Order - Ivan River Unit Jim, I called this morning and Left a voice message returning your cal from yesterday so that we can talk at your convenience ... I have read the email you sent last night and, You offered the additional information that Steve Davies has (5 mb in size). To expedite our decision, Please go ahead and forward it (the details that you referenced) to me and to Talib Syed at the same time. We will be able to accept it. (if a probelm with data transfer occurs,I will let you know) Thanks Thor Please note new fax floor, and mailstop: Thor Cutler, LEG, LHG, LG, CPG EPA (mailstop: OCE-127) (12th floor) 1200 Sixth Avenue Seattle Wa 98101 Phone: 206-553-1673 Fax 206-553-8509 Email cutler.thor @epa.gov "Regg, James B (DOA) " <jim.regg@alaska To .gov> Thor Cutler/R10/USEPA/US@EPA CC 11/25/2008 04:28 "Colombie, Jody J (DOA)" PM <jody.colombie@alaska.gov> > Subject > Draft Aquifer Exemption Order - > Ivan River Unit > As per Section 14 of our UIC Memorandum of Agreement, attached is a > draft amendment for Aquifer Exemption Order 6 (Ivan River Unit) - file > is "aeo6A draft.pdf". The purpose for this amendment is a depth > extension (deeper zone). I have also attached a copy of the current > Aquifer Exemption Order 6 issued in 2001 (AEO-6.pdf) so you readily > have the findings and conclusions leading to that order . > On July 22, 2008, EPA Region 10 was provided copies of the application > from Union and the Commission's public notice. We received no > comments, protests or requests for a hearing in response to the public notice. > The public hearing was vacated. > Steve Davies (AOGCC Sr. Geologist) performed a comprehensive > assessment and provides the following overview for you:. > The varying salinity of the formation waters forced me to > segregate the interval of interest into six zones. I separately > analyzed each zone for wells IRU 14-31, 13-31 and 44-36 because I > wanted to ensure that there was no potentially commercial gas that 2 > might be wasted. I found ~ only minor amounts of gas ar~resent. > More importantly, I found that a thin coal at 5163' in IRU 14-31 > (within my log analysis Zone 4) forms a prominent barrier in this > area: above it the TDS of the formation waters is above 3000 ppm; > below it the formation waters are less than 3000 ppm. Even though the > TDS values drop below 3000 ppm, the aquifers in the Ivan River Unit > area are so deep, so remote, and surface water is so plentiful that > these aquifers will never serve as economic sources of drinking water. > Log analysis summary sheets developed by Steve Davies are attached in > support of his review. We can also provide a cross section if needed > - electronic file size is 5MB (don't know what your limit for email > file size is). > The MOA provides EPA with up to 30 days to act; we would appreciate > EPA's expedited review and concurrance with the Commission's order. > Union Oil Company of California (applicant) is currently performing > well work (rig intervention) that will be completed soon. The > approved aquifer exemption amendment is required prior to initiating injection. > Call if you have any questions. Thank you in advance! > Jim Regg > AOGCC > 333 W.7th Avenue, Suite 100 > Anchorage, AK 99501 > 907-793-1236 > (See attached file: aeo6A_draft.pdf)(See attached file: AEO-6.pdf)(See > attached file: > 081119_1920880_IRU_13-31_Zones_0_5'TDS_3952-6184MD_Summary.pdf)(See > attached file: > 081119_1750080_IRU_14-31_Zones_0_5_TDS_3643-5470MD_Summary.pdf)(See > attached file: > 081119_1930220_IRU 44-36_Zones_0_5_TDS_3892-5989MD_Summary.pdf) 3 • • Ivan River Unit 14-31 PTD 175-008 Mechanical Integrity Assessment J. Regg, AOGCC; 11/26/2008 Ivan River Unit (IRU) Well 14-31 has injected over 46,000 barrels of drilling waste since commencing Class II injection in 2001. The well is constructed with casing and cement across the injection and confining layers, preventing the migration of injected fluids. Confinement of fluids to the intended injection zone in IRU 14-31 has been shown from historical injection performance data provided by Union. The 2008 Annual Disposal Injection report for IRU 14-31 is attached -includes recorded pressures for tubing, inner annulus and outer annulus, and a current well schematic. Well integrity has been demonstrated by successful mechanical integrity testing and monitoring the well's annular pressures. A passing mechanical integrity test on IRU 14-31 was witnessed by a Commission inspector on October 26, 2008 (copy attached). Previous MIT was performed 12/5/2006; passing test witnessed by AOGCC (copy attached). 3 Attachments • Chevron September 8, 2008 Gary A. Orr Reservoir Engineer Mr. Jim Regg Alaska Oil & Gas Conservation Commission (AOGCC) 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Re: Disposal Report for the 14-31 Well in the Ivan River Unit Dear Mr. Regg: Union Oil Company of California P.O. Box 196247 Anchorage, AK 99519-6247 Tel 907 263 7800 Fax 907 263 7828 Email orrga@chevron.com SEP 0 9 2008 Alaska tail & Cas Cons. Commission Anct~,crage This is the 2007 Annual Report for UIC Class II disposal operations in the IRU 14-31 wellbore. These disposal operations are governed by AOGCC Disposal Injection Order #23 issued 08/09/01. The attached plot shows that the injection pressures and low rates are relatively predictable and stable and do not indicate any reservoir or mechanical concerns. Specific items to note for this reporting period: • In 2007 the fluids injected into the IRU 14-31 well were essentially produced water from the Ivan River, Pretty Creek and Lewis River fields. Please contact me if I can be of further assistance at 907-263-7800. Best regards, ~d .,~ ~ ~, Gary Orr cc: Dave Whitacre Jean Bodeau Larry Greenstein Well File Union Oil Company of California / A Chevron Company http://www.chevron.com ~ 1 € ~_ _ ~ i } - _,„w~ .. ~.-r ~ 1 2 _. ~. 0'l'',. { ~ -. - 4 - ~.~ _ ~ ,. y ' _ d -~' 3Ai4a ~-~ 'L~_r=a P'~ _ F V, _ __~-~_ _-_ ~ Mr. T t 'Y3 ~-_ ~ ~ - fir.. (,. ~ ~. L. P .- _- 1 ~ __ __. t ~* F ~ ~ ', --_ _ ,. _ ~ l ~a ~- _. . ww ..._,. _.. ..._. j ^) i _ _ _.~_ G'i <r a7 ~ ~ . ... :,~ t~ _,~ ~ ,., ~ ,. r ~j ~ ~ _ _.. .. _ t)/ L 0 l' ~, ~, 1 i~~n F~i~e~r Fi~i~ ~I I 1 ~~ ~~ ~'!' ~ ~' ~ rte` ~~ ~• . 1 D-~4" +I{~0.5~ lC~56 ~~'1 TTY ~ by' 8ea+ed on ~ti~d Qn Equalisa~on 1'hru Flt~tt Shoe ~ ~allar ~ ~4#' ,Amnului TTY Bet+ ~ +~45' and #05~' ~ ~~BL Nit ncl~st+nl~} 7" ~, ~ ~ !' N 80 +~' 74'i~' Is4t~ [~ d 2~T1~• ~.~ 1~0 t Tublta~ suss ~r, ~~ Bar 3-H Paf 8t ~$CM~` 'P Frofll~ aR ' {~,~1~ 1~~ t3e~8r V~L F~entry ~ttlde at 2~2' Pert 3'189' - 3209' 12 SPF B-8-07 ,~~~ntian~ Rlt~~ 9S5gr - 3508' ' - ~988~' sgz'd F`~sh ~t1 BHA Total I..an~tfit 22~ ~~ ~n E~+~ttam at 4,084' Fish #~ 246` ~f 2 ~!~' D. P. Top ~ ~4' f~-t#Qrrt +~ ~~'~1' Flsh #3 YV.~ ~ [}.~.'a Length 3~,Y Tap ~ 7M.3+46' B~ttam ~ T12~' Flat ~8'F'B' ~~f3' TBf~ & 3,2t?LY 31' D_P. T~ ~ ~ ~ a awn ~ a~$~ ~amenrt ~~ ~~cr 5 i~2' ~,inar ~ 1~~l4D` 1 ~ lament plug 10,y0Qr - ta'35+~' ~~~~~ ----t moment Plug 14.850' -1 ~~0' ~ 1.r ~ 1 ~.~~F r MEMORANDUM To: Jim Regg P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, November 26, 2008 SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA 14-31 IVAN RIVER UNIT 14-31 Src: Inspector NON-CONFIDENTIAL Well Name: NAN RNER UNIT 14-31 Insp Num: mitcso612o6092206 Rel Insp Num: MITOP000001525 API Well Number: 50-283-20045-00-00 Permit Number: t~s-oo8-o Inspector Name: Chuck Scheve Inspection Date: 12isi2oo6 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well la-sl Type Inj. N TVD 2903 IA o ls8o ls8o ls8o P.T.D 175°°8° TypeTest SPT Test psi 725.75 OA o 0 0 0 Interval Other (descnbe in P~F Pass Tubing 170 170 170 170 11(~ PC Notes: Two year MIT cycle Wednesday, November 26, 2008 Page 1 of 1 • MEMORANDUM To~ Jim Regg P.I. Supervisor FROM: $Ob NOble Petroleum Inspector L State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, November 26, 2008 SUBJECT: Mechanical Integrity Tests IINION OIL CO OF CALIFORNIA 14-31 IVAN RIVER UNIT 14-31 Src: Inspector NON-CONFIDENTIAL Well Name: NAN RNER UNIT 14-31 Insp Num: mitRCN081027064703 Rel Insp Num: Mrrorooooo2390 API Well Number: 50-283-2004s-00-00 Permit Number: l~s-oo8-o Inspector Name: Bob Noble Inspection Date: 1oi26i2oos Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1a-31 Type Inj. N TVD 2682 IA ~s Is6o ls6o ls6o P.T.D 1750080 TypeTest SPT Test psi ls6o Op o 0 0 0 Interval Other (descnbe in p~F Pass TUb1Ug 20 20 20 20 nn ec NOteS: Well is a disposal injector that is on a 2 year cycle. Wednesday, November 26, 2008 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: November 21, 2008 P.I. Supervisor SUBJECT: Blowout Preventer Test Nordic Rig #1 BPX, PBU,Z-01 B FROM: Chuck Scheve PTD# 2081080 Petroleum Inspector NON- CONFIDENTIAL Operator Rep.: Bordes Op. phone: 659-4433 Op. E-Mail: Contractor Rep.: VanRav Rig phone: 659-4421 Rig E-Mail: Test Pressures Rams: 250/3500 Annular: 250/2500 Choke: 250/3500 P/F P/F Quantity P/F Location Gen.: P Well Sign P Upper Kelly N/A N/A Housekeeping: P Drl. Rig P Lower Kelly N/A N/A PTD On Location P Hazard Sec. P Ball Type 2 P Standing Order Posted P Inside BOP N/A N/A BOP STACK: Quantity Size/Type P/F MUD SYSTEM: Visual Alarm Stripper Trip Tank N/A N/A Annular Preventer 1 7 1/16 P Pit Level Indicators P P #1 Rams 1 Blind Shear P Flow Indicator N/A N/A #2 Rams 1 2 3/8 combi P Meth Gas Detector P P #3 Rams 1 2 3/8 X 3 1/2 P H2S Gas Detector P P #4 Rams 1 2 3/8 combi P #5 Rams Quantity P/F Choke Ln. Valves 1 3 1/8 P Inside Reel valves Not Nitnessed HCR Valves 1 3 1/8 P Kill Line Valves 2 2 1/6 F/P ACCUMULATOR SYSTEM: Check Valve 1 2 1/16 P Time/ Pressure P/F System Pressure 2900 P CHOKE MANIF OLD: Pressure After Closure 2000 P Quantity P/F 200 psi Attained 15 P No. Valves 15 p Full Pressure Attained 100 P Manual Chokes 1 p Blind Switch Covers: All P Hydraulic Chokes 1 p Nitgn. Bottles (avg): 31900 psi The inside Kill Line valve failed on initial test, this valve was serviced and retested OK. Total Test Time: 6 Number of failures: 0 BOP Nordic 1 11-21-08 CS.xls 11/26/2008 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Tuesday, November 25, 2008 6:00 PM To: Birnbaum, Alan J (LAW) Cc: Colombie, Jody J (DOA) Subject: DIO for Ivan River Unit 13-31 Attachments: dio35 IRU 13-31 draft.doc Page 1 of 1 Attached is draft DIO 35 for Ivan River Unit 13-31 for your review. This is the reason for the aquifer exemption you just reviewed. I have tried to keep up with edits you suggested on previous orders but there's no guarantee I have done a good job of it. I really appreciate the effort you put into making these read clear. We have at least aweek -until December 5 -assuming EPA bites on my request for an expedited concurrence of the aquifer exemption. So, if I could get comments back from by the same date (December 5) it would be appreciated. Thank you and have a Happy Thanksgiving (don't take any work home with you!) Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 11/25/2008 Page 1 of 1 Colombie, Jody J (DOA) From: Regg, James B (DOA) Sent: Tuesday, November 25, 2008 5:19 PM To: sullivans@chevron.com Cc: Colombie, Jody J (DOA) Subject: IRU AEO Depth Extension and Disposal Injection Order Proposed AEO 6A was sent by electronic mail to EPA today; I will follow with a letter to EPA tomorrow. As you requested, I have petitioned EPA for expedited review and concurrence. The DIO for IRU 13-31 is undergoing final editing and will be issued once we receive EPA concurrence on AEO 6A. Regarding the DIO application, Exhibit 2 is labeled incorrectly: - T13N R9W should be T14N R8W - T14N R8W should be T13N R8W Any other graphics in your application that reference Section-Township-Range should also be checked and adjusted as necessary; revised copies should be provided to the Commission. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 11/26/2008 Page 1 of 1 Colombie, Jody J (DOA) From: Regg, James B (DOA) Sent: Tuesday, November 25, 2008 3:28 PM To: Cutler.Thor@epamail.epa.gov Cc: Colombie, Jody J (DOA) Subject: Draft Aquifer Exemption Order -Ivan River Unit Follow Up Flag: Follow up Flag Status: Yellow Attachments: aeo6A_draft.pdf; AEO-6.pdf; 081119_1920880_IRU_13-31_Zones_0_5_TDS_3952-6184MD Summary.pdf; 081119_1750080 1RU 14-31_Zones_0_5_TDS_3643-5470MD_Summary.pdf; 081119_1930220_IRU_44- 36_Zones_0_5_TDS_3892-5989MD_Summary.pdf As per Section 14 of our UIC Memorandum of Agreement, attached is a draft amendment for Aquifer Exemption Order 6 (Ivan River Unit) -file is "aeo6A draft.pdf'. The purpose for this amendment is a depth extension (deeper zone). I have also attached a copy of the current Aquifer Exemption Order 6 issued in 2001 (AEO-6.pdf) so you readily have the findings and conclusions leading to that order . On July 22, 2008, EPA Region 10 was provided copies of the application from Union and the Commission's public notice. We received no comments, protests or requests for a hearing in response to the public notice. The public hearing was vacated. Steve Davies (AOGCC Sr. Geologist) performed a comprehensive assessment and provides the following overview for you: The varying salinity of the formation waters forced me to segregate the interval of interest into six zones. I separately analyzed each zone for wells IRU 14-31, 13-31 and 44-36 because I wanted to ensure that there was no potentially commercial gas that might be wasted. I found that only minor amounts of gas are present. More importantly, I found that a thin coal at 5163' in IRU 14-31 (within my log analysis Zone 4) forms a prominent barrier in this area: above it the TDS of the formation waters is above 3000 ppm; below it the formation waters are less than 3000 ppm. Even though the TDS values drop below 3000 ppm, the aquifers in the Ivan River Unit area are so deep, so remote, and surface water is so plentiful that these aquifers will never serve as economic sources of drinking water. Log analysis summary sheets developed by Steve Davies are attached in support of his review. We can also provide a cross section if needed -electronic file size is 5M6 (don't know what your limit for email file size is). The MOA provides EPA with up to 30 days to act; we would appreciate EPA's expedited review and concurrence with the Commission's order. Union Oil Company of California (applicant) is currently performing well work (rig intervention) that will be completed soon. The approved aquifer exemption amendment is required prior to initiating injection. Call if you have any questions. Thank you in advance! Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 11/26/2008 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: THE APPLICATION of Union ) Aquifer Exemption Order No. 6A Oil Company of California for a depth } extension of Aquifer Exemption Order ) Sterling and Beluga Formations No.6, which relates to portions of the ) Ivan River Unit Ivan River Unit within the Matanuska- ) Susitna Borough, Alaska. ) --, 2008 IT APPEARING THAT: 1. Union Oil Company of California (Union), a wholly owned indirect subsidiary of Chevron Corporation, submitted an application for a depth extension of Aquifer Exemption Order (AEO) No. 6. Union's application dated July 15, 2008 was received by the Alaska Oil and Gas Conservation Commission (Commission) on July 17, 2008. 2. AEO 6 exempts those portions of freshwater aquifers lying between 2500 feet and 3420 feet measured depth in, and within '/z-mile radius of, the Ivan River Unit (IRU) Well 14-31 for purposes of Class II underground injection activities. ~ 3. The surface location of IRU Well 14-31 is located within Section 1, Township 13N, Range 9W, Seward Meridian. 4. Union's application requests a depth extension from 3420 feet to 6195 feet. 5. The Commission's jurisdiction in this matter is under AS 31.05.030(h) and 40 CFR 147, Subpart C -Alaska, and relates to 20 AAC 25.440. 6. The Commission published a public hearing notice, with a tentative hearing date of September 4, 2008, on the Commission's Web site on July 21, 2008, on the State of Alaska Online Notices on July 21, 2008, in the ANCHORAGE DAILY NEws on July 22, 2008, and in the PENINSULA CLARION on July 24, 2008. 7. The Commission submitted a copy of Union's aquifer exemption application and related documents to the U.S. Environmental Protection Agency, Region 10 (EPA Region 10), on July 22, 2008. 8. The Commission received no comments, protests, or requests for a hearing. The public hearing was vacated on September 2, 2008. 9. Union submitted a disposal injection order (DIO) application on September 8, 2008, proposing the conversion of IRU 13-31 from gas production to Class II waste disposal service. IRU 13-31 penetrates the proposed disposal zone within the '/2-mile exemption radius established by AEO 6. 'All depths presented herein are measured depths within IRU 14-31 unless otherwise noted. Aquifer Exemption Order 6A Page 2 Ivan River Unit --, 2008 10. On October 20, 2008, the Commission requested additional information from Union regarding water quality within the affected geologic strata. 11. On November 7, 2008, Union submitted a revised request for a depth extension of AEO 6. This revision changes the interval of the requested depth extension to the following: 3420 feet to 5435 feet in IRU 14-31. 12. On November 8, 2008, Union submitted the water quality information the Commission requested on October 20, 2008. 13. On November 14, 2008, the Commission requested further information from Union regarding water quality. Union responded with the requested information on that same day. 14. The information submitted by Union and public well history and well log records are the basis for this order. 15. A draft of this aquifer exemption order was sent to EPA Region 10 on ---, 2008. 16. In correspondence dated --, 2008, EPA Region 10 concurred with the proposed depth extension of AEO 6 to 5435 feet in IRU 14-31. FINDINGS: Extent of Aquifer Exemption Area. The IRU is on the west side of Cook Inlet within the Matanuska-Susitna Borough, approximately 45 miles due west of Anchorage. This gas field has been in production since July 1990. There are six wells within the IRU: one plugged and abandoned well, four gas production wells, and one disposal well (IRU 14-31) used for underground injection of Class II oilfield wastes. Union plans to convert shut-in gas producer IRU 13- 31 to disposal injection service; the well was shut-in December 2007. AEO 6 exempts aquifers within a 1/z-mile radius of, and between 2500 feet and 3420 feet in, IRU 14-31. Union requests a depth extension to allow for the deeper injection of Class II oilfield wastes into IRU 13-31. No change to the lateral extent of the exempted area is requested since IRU 13-31 is within the %z-mile exemption in AEO 6. 2. Formation Water Total Dissolved Solids. Union calculated the total dissolved solids (TDS) concentrations in the affected aquifers within IRU 13-31 utilizing well log data and techniques that conform with EPA guidance document "Survey of Methods to Determine Total Dissolved Solids Concentrations," (KEDA Project No. 30-956). Union's analysis indicate that aquifers within IRU 13-31 that correlate to the interval between 3420 feet and 5156 feet within IRU 14-31 contain TDS concentrations greater than 3,000 parts per million (ppm). Union's analysis also Aquifer Exemption Order 6A Page 3 Ivan River Unit --, 2008 indicates aquifers within IRU 13-31 that correlate to the depth below 5156 feet in IRU 14-31 contain TDS concentrations of approximately 2,500 ppm.2 The Commission verified Union's analysis using EPA-recommended techniques and well log data from IRU Wells 14-31, 13-31, and 44-36. The results of the Union and Commission analyses are consistent. The Commission determined that aquifers equivalent to the interval from 3420 feet to 5163 feet in IRU 14-31 contain TDS concentrations exceeding 3,000 ppm. The Commission also found that aquifers below the equivalent of 5163 feet- in IRU 14-31 contain TDS concentrations between about 2,000 ppm and 3,000 ppm. 3. Suitability of IRU Sediments Below 2500 Feet as Drinking Water Aquifers. 20 AAC 25.440(a)(1)(B) provides that the Commission may grant a freshwater aquifer exemption regardless of total dissolved solids content if the aquifer does not and cannot now, and will not in the future, serve as a source of drinking water because it "is situated at a depth or location that makes recovery of water for drinking water purposes economically or technologically impractical." AEO 6 concludes that the portions of aquifers between 2500 feet and 3420 feet in IRU 14-31 are not reasonably expected to serve as underground sources of drinking water based on depth and water quality. The TDS data indicates a trend reversal toward less TDS as the well gets deeper. Extending the aquifer exemption depth to the equivalent of 5435 feet in IRU 14-31 is unlikely to affect potential drinking water supplies since increased lifting costs are associated with deeper zones, and suitable sources of drinking water are available on the surface and within the shallow subsurface. CONCLUSIONS: 1. The findings and conclusions of AEO 6 remain valid. AEO 6 properly exempts for purposes of Class II underground injection activities the portions of freshwater aquifers between 2500 feet and 3420 feet and within a %2-mile radius of IRU 14- 31; 2. All known and foreseeable ground water consumption from the IRU vicinity is consistent with usable ground water resources above 200 feet; 3. The TDS content of the water within a 'h-mile radius and within strata equivalent to those between 3420 feet and 5163 feet in IRU 14-31 is greater than 3,000 ppm. Strata equivalent to those below 5163 feet in IRU 14-31 contain TDS concentrations between about 2,000 ppm and 3,000 ppm 4. Those portions of aquifers at an interval equivalent to between 3420 feet and 5435 feet within IRU 14-31 are at depths that make recovery of the water for drinking water purposes economically impractical now or in the future; 2 To minimize confusion, affected aquifers and strata in nearby wells are specified as equivalent depths within IRU 14-31, which is the reference well for AEO 6. Aquifer Exemption Order 6A Page 4 Ivan River Unit --, 2008 Those portions of aquifers within a %-mile radius around the IRU 14-31 wellbore and below 2,500 feet qualify as exempt freshwater aquifers under 20 AAC 25.440(a)(1)(B) or 20 AAC 25.440(a)(2) or both; and The stratigraphic sequence and maintenance of the mechanical integrity of the wells within a %2-mile radius of IRU 14-31 will prevent the movement of fluids into underground sources of drinking water. NOW, THEREFORE, IT IS ORDERED THAT the aquifers or portions of aquifers between 2500 feet and 5435 feet in, and within a 'h-mile radius of, IRU Well 14-31 are exempt for purposes of Class II underground injection activities. ENTERED at Anchorage, Alaska, and dated ---, 2008. Daniel T. Seamount, Jr. Cathy P. Foerster John K. Norman 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 ]0-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(6), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday • ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7`h Avenue, Suite 100 Anchorage Alaska 99501 Re: THE APPLICATION OF UNOCAL Corporation for a Freshwater Aquifer Exemption Order to allow disposal of Class II oil field wastes by underground injection into Glacial and Upper Sterling Formations, Ivan River Unit Well IRU 14-31, Section 1, T13N, R9W, Seward Meridian IT APPEARING THAT: Aquifer Exemption Order No. 6 Ivan River Field Upper Sterling Formation July 23, 2001 } 1. Unocal Corporation ("Unocal") submitted an application, dated April 26, 2001, requesting that the Alaska Oil and Gas Conservation Commission ("Commission") issue a freshwater aquifer exemption for purposes of Class II disposal in the Ivan River IRU 14-31 well. 2. Additional information supporting the request for the freshwater aquifer exemption and Class II disposal in Well IRU 14-31 was received by correspondence dated June 22, 2001 and by sundry notice and reports dated June 13, 2001. 3. Notice of opportunity for public hearing was published in the Anchorage Daily News and Peninsula Clarion on May 14, 2001 in accordance with 20 AAC 25.540. 4. The Commission has jurisdiction in this matter under AS 31.05.030(h}, 20 AAC25.440, and 40 CFR 147, Subpart C -Alaska. 5. The Commission did not receive any protest or a request for a public hearing. 6. The Commission submitted a copy of Unocal's aquifer exemption application to the U.S. Environmental Protection Agency Region 10 ("EPA Region 10") on May 10, 2001 and a copy of the proposed order on July 17, 2001, in accordance with Section 14 of the November 22, 1991 Memorandum of Agreement between EPA Region 10 and the Commission. Aquifer Exemption Order No. 6 July 23, 2001 Page 2 of 4 EPA Region 10 did not object to the Aquifer Exemption Order for the Ivan River IRU 14-31 well. FINDINGS: 1. By correspondence dated May 16, 2001 Unocal requested authorization from the Commission to dispose of Class II oil field waste fluids by underground injection into Upper Sterling Formation sandstones and conglomerates in well IRU 14-31, located in the Ivan River Field, Matanuska-Susitna Borough, Alaska. 2. Unocal is the operator of the Ivan River Field. 't'here are no other operators within a %2 mile radius of the proposed disposal injection well. 3. Unocal proposes to conduct disposal operations in the Well IRU 14-3I between 3145' and 3420' measured depth (MD). 4. In order to accommodate the proposed Ivan River Field disposal injection operations Unocal has requested exemption of all fresh water aquifers within a mile radius and below 2500' MD in well IRU 14-31. 5. Wireline log analytical techniques, which comply with EPA recommended methods as described in "Survey of Methods to Determine Total Dissolved Solids Concentrations", (KEDA Project No. 30-956), were used to characterize formation water total dissolved solids content in the IRU 14-31 well. 6. Wireline log analysis of the IRU 14-31 well demonstrates that the water total dissolved solids content in the aquifers requested for exemption by Unocal are all greater than 4,000 parts per million from 2500' to 3420' MD. 7. Ivan River Unit is located in the Susitna Flats State Game Refuge where there are no permanent residences. With the present completion in IRU 14-31, a cement retainer and cement plug restricts access to depths deeper than 3225'MD. Current perforations for planned disposal are between 3189' and 3209' MD. Should additional perforated intervals become necessary, Unocal will seek additional authorizations from the Commission. Unocal requests an exemption for %z mi. radius surrounding the 1RU 14-31 wellbore. Unocal requests a % mile radius to allow for the possible permitting of a second disposal well near the IRU 14-31 surface location. 10. IRU 14-31 was drilled to a depth of 10,958' MD. IRU 14-31 includes ZO" casing to 401' MD, 10 %" casing to 2018' MD, and 7" casing to 7018' MD. The well Page 2 of 4 Aquifer Exemption Order No. 6 July 23, 2001 Page 3 of 4 was suspended on August 18, 1975 as 7" casing and drill string was cemented in place with cement extending from 3510' to 9937' MD. A cement plug was placed from 3350-3508' MD with a retainer set at 3225' MD. In 1993 Unocal received Commission approval to run 2 7/8" tubing to 2982' MD with an isolation packer at 2903' MD. 11. The nearest drinking water wells are two freshwater wells completed at approximately 200' MD on the Ivan River production pad. 12. A segmented cement bond log was run in the 7" of IRU 14-31 on Jan 31, 1993. This log shows adequate cement to prevent movement of fluids above the proposed injection intervals. 13. The wells within % mile perimeter were reviewed for mechanical integrity. Unocal submitted records of cementing and mechanical details for these wells. All wells appear to be sufficiently cased/cemented, although IRU 13-31 will require additional monitoring due to its close proximity to the proposed injector. 14. Operations will be manned during injection into IRU 14-31. All annulus pressures of wells within the % mile radius will be checked and recorded prior to and after each injection cycle. The existing IRU 13-31 Glycol High Level Alarm will also alarm at the injection pump so that the injection pump operator can immediately shut down the pump in the event that communication developed to IRU 13-31. In that event, injection would not be re-initiated until it was determined that safe operations could continue and with Commission approval. 15. The Commission's authority to act in this matter is embodied in 40 CFR 147 Subpart C, the Alaska Oil and Gas Conservation Act (A5 31.05}, and the Alaska Administrative Code (20 AAC 25.005 through 20 AAC 25.990). 16. Aquifer exemptions exist at similar depths in the Lewis River Unit to the north and at Beluga River Unit and North Cook Inlet Units to the south. Freshwater used at Beluga River also comes from shallow wells completed at depths of approximately 200' MD. CONCLUSIONS: 1. Those portions of freshwater aquifers occurring within a '/z mile radius and between 2500' and 3420' MD in the IRU 14-31 well do not currently serve as a source of drinking water. 2. Sources of drinking water exist at shallow intervals in the area. Page 3 of 4 • s Aquifer Exemption Order No. 6 7uly 23, 2001 Page 4 of 4 3. The total dissolved solids content of the water occurring within a '/2 mile radius and between 2500' and 3420' MD in the IRU 14-31 well is greater than 3000 parts per million and is not reasonably expected to supply a public water system. 4. Those portions of freshwater aquifers occurring within a %Z mile radius and between 2500' and 3420' MD in the IRU 14-31 well is not reasonably expected to serve as an underground source of drinking water. 5. Those freshwater aquifers occurring within a '/2 mile radius and between 2500' and 3420' MD in the IRU 14-31 well qualify for designation as exempt freshwater aquifers under 20 AAC 25.440. 6. The stratigraphic sequence present in Ivan River and maintenance of mechanical integrity of the IRU 14-31 well will prevent movement of fluids into underground sources of drinking water. NOW, THEREFORE, IT IS ORDERED THAT the portions of freshwater aquifers lying between 2500' and 3420' MD in Unocal's Ivan River well IRU 14-31 and within a one-half (%) mile radius of the well are exempt for purposes of Class II underground injection activities. DOME at Anchorage, Alaska and dated July 23, 2001. Cammy O hsli Taylor, C it Julie M. Heusser, Commissioner AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an application for reheating. A request for rehearing must be received by 4:30 PM on the 23rd day following the date of the older, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can t~efuse an application by not acting on it within the 10-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an or•der• upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30-day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e. IOth day after the application for rehearing was bled). 1 certify that an ! ' ~ ~ ~ ~p'Y of the above was faaxt~d/ al esCt~ of the ~ilowing at their addresses of record: u//~~'a ~- Gc'~7d~Q ~ ~~ . Page 4 of 4 1920880 KB 51 'MSL GL 26 'MSL METHODS Permafrost Present? No Lithology SS Shaley Formation? Yes Vshl Method: Steibner Porosity Method: Sonic-Empirical Sw Method: Mod_Simandoux HC Effect Applied? No Ivan River Unit 13-31 Unocal Summary Zone 4 5745' to 5995' MD Temp = (X 3*MD^3) + (X 2*MD^2) + (X_1*MD) + b X_3 0 X_2 0 X_1 0.007983 b 70.34736 PARAMETERS TDS = (X 2*NaCI^2) + (X_1*NaCI) + b Gamma Ray Clean 62 DT fluid 189 Gamma Ray Shale 91 DT matrix 55 X 2 -5.3E-06 Shale Density Poro 0.32 DT shale 131 X 1 1.251665 Shale Neutron Poro 0.6 Rw 0.75 b 207.469 a 0.62 m 2,15 'Source: 081117_Unocals_Salinity_and TDS_Data_USGS alaska_rw.xls n 2 Filtered to include only wells in Southern Alaska with TDS <35,000 ppm TDS Sw INPUT OFFSET WELLS. Measured TVDSS AOGCC AOGCC OPERATOR OFFSET Archie Mod Sim Fm GR Vsh RT Sonic-Empirical Rwa Measured De th 1-Pt 3-Pt Min 44-36 Tem Porosi 14-31 44-36 5 /tSZ 4,3/3.15 6,bUU tl,bUU - 4,4UU U.`J`JV U.6/D IUD.4/ rc u.lo4 a.~ v.~iv v.rw oivc vu io 5845 4,414.1 3,600 2,800 4,250 4,900 0.737 0.585 105.79 75 0.225 14.8 0.265 1.381 5156 5675 5877 4,434.6 3,200 3,100 - 2,600 0.689 0.537 105.96 76 0.248 15.1 0.280 1.578 5179 5714 5973 4,496.1 2,500 2,000 - 2,600 0.612 0.536 106.45 71 0.135 16.4 0.301 2.004 5259 5784 L' 11 /19/2006 AOGCC 081119_1920880_IRU_13-31_Zone_4_TDS_5745-5995MD.xls Ivan River Unit 13-31 TDS vs Measured Depth 3952 to 6184' MD 20,000 18,000 16,000 14,000 E a 12,000 rn O ~ 10,000 m r R ~ 8,000 U 6,000 4,000 2,000 11 /19/2008 081119 1920880 IRU 13-31 Zones 0 5 TDS 3952-6184MD.xls • AOGCC 3,900 4,100 4,300 4,500 4,700 4,900 5,100 5,300 5,500 5,700 5,900 6,100 6,300 Measured Depth (ft) 1750080 KB 46.4 'MSL GL 26.9 'MSL METHODS Permafrost Present? No Lithology SS Shaley Formation? Yes Vshl Method: Steibner Porosity Method: Sonic-Empirical Sw Method: Mod_Simandoux HC Effect Applied? No Ivan River Unit 14-31 Summary Zone 4 5082' to 5284' MD PARAMETERS Gamma Ray Clean 62 Gamma Ray Shale 91 Shale Density Poro 0.33 Shale Neutron Poro 0.51 a 0.62 m 2.15 n 2 DT fluid 189 DT matrix 55.5 DT shale 138 Rw 0.45 Unocal Temp = (X 3*MD^3) + (X_2*MD"2) + (X 1*MD) + b X_3 0 X_2 0 X_1 0.007983 b 70.34736 TDS = (X 2*NaCI^2) + (X_1*NaCI) + b X_2 -5.3E-06 X_1 1.251665 b 207.469 `Source: 081117_Unowls_Saliniry_and_TDS Data_USGS alaska_rw.xls Filtered to include only wells in Southern Alaska with TDS <35,000 ppm DEPTH TDS Sw INPUT OFFSET WELLS Measured TVDSS AOGCC AOGCC OPERATOR OFFSET Archie Mod Sim Fm GR Vsh RT Sonic-Empirical Rwa Measured De the 1-Pt 3-Pt Min 44-36 Tem Porosi 13-31 44-36 51 U2 3,944.2 7,6UU /,tiUU - 4,4UU U.Sl6 u. N4 luz.uo /s u.-Ina o.s 5156 3,978.6 4,200 4,200 4,250 4,900 0.603 0.482 102.32 75 0.212 12.9 5179 3,993.2 3,000 3,000 - 2,600 0.512 0.439 102.44 72 0.160 12.6 5259 4,044.2 2,200 2,200 - 2,600 0.432 0.399 102.85 68 0.079 17.1 U.L04 V.O/V O/OL UO 10 0.269 1.238 5845 5675 0.317 1.717 5877 5714 0.322 2.406 5973 5784 • 1 v1 s/zoos AOGCC 081119 1750080 IRU 14-31 Zone 4 TDS 5084-5284MD.xls Ivan River Unit 14-31 TDS vs Measured Depth 3643 to 5470' MD 20,000 18,000 16,000 14,000 E a 12,000 F' 10,000 ro ~ 8,000 U 6,000 4,000 ~~ 2,000 AOGCC 3,600 3,800 4,000 4,200 4,400 4,600 4,800 5,000 5,200 5,400 5,600 5,800 6,000 Measured Depth (ft) _~ • AOGCC TDS Operator TDS .• • • • : • 2. • ., ~. • • . • • .. • S t • • .• ;Z N • • •, • • • • I 1lnsizoo6 OS 1119_1750080_1 R U_14-31 _Zones_0_5_TD S_3643-5470 M D.xls • C] 1930220 KB 51 'MSL GL 26 'MSL METHODS Permafrost Present? No Lithology SS Shaley Formation? Yes Vshl Method: Steibner Porosity Method: Neu-Den_Avg Sw Method: Mod_Simandoux HC Effect Applied? No Ivan River Unit 44-36 Summary Zone 4 5586' to 5813' MD PARAMETERS Gamma Ray Clean 62 DT fluid 189 Gamma Ray Shale 91 DT matrix 55.5 Shale Density Poro 0.32 DT shale 127.5 Shale Neutron Poro 0.59 Rw 0.70 a 0.62 m 2.15 n 2 Unocal Temp = (X_3*MD^3) + (X 2*MD"2) + (X_1*MD) + b X_3 0 X_2 0 X_1 0.007983 b 70.34736 TDS = (X 2*NaC I^2) + (X_1*NaCI) + b X_2 -5.3E-06 X_1 1.251665 * b 207.469 ' Source: 081117_Unocals_Salinity_and T DS_Data_USGS aaska rw.xls FiRered to include only wells in Southern Alaska with TDS <35,000 ppm DEPTH TDS Sw INPUT OFFSET WELLS °' Measured TVDSS AOGCC AOGCC OPERATOR OFFSET Archie Mod Sim Fm GR Vsh RT Neu-Den_Avg Rwa Measured De th 1-Pt 3-Pt Min 14-31 Tem Porosi 14-31 44-36 5618 4,268.7 4,400 4,4UU - /,tiUU U.//a U./sZ lU4.b3 ea u.uas a.n u.saa l.loa olvc al OL 5675 4,305.2 4,900 4,900 4,250 4,200 104.92 77 0.276 13.8 0.239 1.025 5156 5845 5714 4,330.1 2,700 2,600 - 3,000 0.609 0.527 105.12 72 0.154 14.1 0.314 1.886 5179 5877 5784 4,375.1 2,700 2,600 - 2,200 0.611 0.523 105.48 71 0.137 20.5 0.263 1.877 5259 5973 • 1 111 912 00 8 AOGCC D81119 1930220 IRU 44-36 Zone 4 TDS 5566-5813MD.xls Ivan River Unit 44-36 TDS vs Measured Depth 3892 to 5989' MD 20,000 18,000 16, 000 14,000 E a 12,000 0 ~ 10,000 R ~ 8,000 U 6,000 4,000 2,000 • AOGCC TDS Operator TDS • s • •. !~~ •• • . _ • • , j ~_~•• • s . • ~ ~~ • •• • : ~, ~ • • ~ • s i • • • _ ~ • • fit 3,800 4,000 4,200 4,400 4,600 4,800 5,000 5,200 5,400 5,600 5,800 6,000 Measured Depth (ft) a • 11 /19/2008 AO G C C 081119_1930220_1 RU_44-36_Zo nes_0_5_TDS_3892-5989 M D.xls • Regg, James B (DOA) From: Regg, James B (DOA) Sent: Wednesday, November 26, 2008 8:36 AM To: 'Cutler.Thor@epamail.epa.gov' Cc: talibs@ecentral.com Subject: RE: Draft Aquifer Exemption Order -Ivan River Unit Attachments: 081119 XSec_Ivan_River Wells_Crop.pdf 081119_XSec_Ivan River WeIIs C... Thor and Talib - Here is the cross section I referenced. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 -----Original Message----- From: Cutler.Thor@epamail.epa.gov [mailto:Cutler.Thor@epamail.epa.gov] Sent: Wednesday, November 26, 2008 6:24 AM To: Regg, James B (DOA) Cc: talibs@ecentral.com Subject: Re: Draft Aquifer Exemption Order - Ivan River Unit Jim, I called this morning and left a voice message returning your cal from yesterday so that we can talk at your convenience ... I have read the email you sent last night and, You offered the additional information that Steve Davies has (5 mb in size). To expedite our decision, Please go ahead and forward it (the details that you referenced) to me and to Talib Syed at the same time. We will be able to accept it. (if a probelm with data transfer occurs,I will let you know) Thanks Thor Please note new fax floor, and mailstop: Thor Cutler, LEG, LHG, LG, CPG EPA (mailstop: OCE-127) (12th floor) 1200 Sixth Avenue Seattle Wa 98101 Phone: 206-553-1673 Fax 206-553-8509 Email cutler.thor ~epa.gov "Regg, James B (DOA) " <jim.regg@alaska To .gov> Thor Cutler/R10/USEPA/US@EPA cc 11/25/2008 04:28 "Colombie, Jody J (DOA)" PM <jody.colombieCalaska.gov> Subject Draft Aquifer Exemption Order - Ivan River Unit 1 As per Section 14 of our UIC Memorandum of Agreement, attached is a draft amendment for Aquifer Exemption Order 6 (Ivan River Unit) - file is "aeo6A draft.pdf". The purpose for this amendment. is a depth extension (deeper zone). I have also attached a copy of the current Aquifer Exemption Order 6 issued in 2001 (AEO-6.pdf) so you readily have the findings and conclusions leading to that order . On July 22, 2008, EPA Region 10 was provided copies of the application from Union and the Commission's public notice. We received no comments, protests or requests for a hearing in response to the public notice. The public hearing was vacated. Steve Davies (AOGCC Sr. Geologist) performed a comprehensive assessment and provides the following overview for you:. The varying salinity of the formation waters forced me to segregate the interval of interest into six zones. I separately analyzed each zone for wells IRU 14-31, 13-31 and 44-36 because I wanted to ensure that there was no potentially commercial gas that might be wasted. I found that only minor amounts of gas are present. More importantly, I found that a thin coal at 5163' in IRU 14-31 (within my log analysis Zone 4) forms a prominent barrier in this area: above it the TDS of the formation waters is above 3000 ppm; below it the formation waters are less than 3000 ppm. Even though the TDS values drop below 3000 ppm, the aquifers in the Ivan River Unit area are so deep, so remote, and surface water is so plentiful that these aquifers will never serve as economic sources of drinking water. Log analysis summary sheets developed by Steve Davies are attached in support of his review. We can also provide a cross section if needed - electronic file size is 5MB (don't know what your limit for email file size is). The MOA provides EPA with up to 30 days to act; we would appreciate EPA's expedited review and concurrance with the Commission's order. Union Oil Company of California (applicant) is currently performing well work (rig intervention) that will be completed soon. The approved aquifer exemption amendment is required prior to initiating injection. Call if you have any questions. Thank you in advance! Jim Regg AOGCC 333 W.7th Avenue, Suite I00 Anchorage, AK 99501 907-793-1236 (See attached file: aeo6A_draft.pdf)(See attached file: AEO-6.pdf)(See attached file: 081119_1920880_IRU_13-31_Zones_0_5_TDS_3952-6184MD_Summary.pdf)(See attached file: 081119_1750080_IRU_14-31_Zones_0_5_TDS_3643-5470MD_Summary.pdf)(See attached file: 081119_1930220_IRU_44-36_Zones_0_5_TDS_3892-5989MD_Summary.pdf) 2 • • Regg, James B (DOA) From: Regg, James B (DOA) Sent: Friday, November 14, 2008 12:40 PM ~ /~ //~ 14'~ ~a:~ To: 'sullivans@chevron.com' ~ j Cc: Davies, Stephen F (DOA) Subject: AEO 6 Depth Extension per our phone call, below is the assessment from Steve Davies and his request: Page 1 of 1 - Please have Chevron's geologist / petrophysicist update the TDS values in Table 1 of their most recent submittal; The values in that table don't reflect the revised temperature estimates for the injection zone (in their origins( submittal it was -85 deg F, but has been revised to -105 deg). - Near the bottom of page 6 of their most recent formation evaluation submittal (Ivan River Unit Aquifer Exemption Questions Followup.pdf), they state that the Rw for the lower injection zones equates to 2700 ppm NaCI equivalent. What does this say about the TDS content of the connate wafers in those zones? If you can get us the info today, Steve has indicated he will continue reviewing over the weekend. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 11/14/2008 r ~c Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Tuesday, July 22, 2008 11:49 AM To: Cutler Thor Subject: Chevron's AEO Request Ivan River 14-31 Attachments: D00080722-002.pdf; D00080722-001.pdf Thor, Page 1 of 1 Attached is a request from Chevron to amend Aquifer Exemption 6. AOGCC publicly noticed their request today. If you have any questions, please call Jim Regg. Jody Jody Jaylene Colombie Special Assistant to the Commission Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 (907) 793-1221 Direct Line (907) 276-7542 Fax 7/22/2008 ~3 Page 1 of 2 • Davies, Stephen F (DOA) • From: Hillegeist, Tony [HiIIeTK@chevron.com] Sent: Friday, November 14, 2008 6:43 PM To: Davies, Stephen F (DOA) Cc: Regg, James B (DOA); Sullivan, Sharon T; Whitacre, Dave S; Orr, Gary A. Subject: FW: AEO 6 Depth Extension Importance: High Attachments: USGS alaska_rw.csv; Aquifer Exemption IRU 13-31 Revised Table 1 .xls Steve, Here is the revised "Table 1"for the IRU 13-31 well aquifer exemption. Revised Table 1 Salinity Values within Proposed Injection Zone Sands in IRU 13-31 11/14/2008 NaCI Equiv. Sand Depth Porosity Rt Rwa TFM Salinity MD SSTVD % (Ohmm) (Ohmm) (Deg. F) (ppm) 5565 -4235 27 2.88 0.267 103.9 16300 5695 -4318 26 3.96 0.225 104.5 19550 5730 -4340 24 3.47 0.29 104.7 14780 5845 -4414 24 14.4 1.125 105.3 3450 6020 -4526 25 16.8 1.562 106.2 2420 6150 -4609 24 22.3 1.839 106.5 2030 In reference to your second question on NaCI Equiv to TDS. Using the USGS Alaska data that we have available to us at this time. I am inclosing this table. TDS = 1.23 x NaCI Equivalent. (based on average of 60 samples) Please let me know if you have any questions. Thanks your attention to this issue. Tony Hillegeist Staff Geologist Chevron North America Exploration and Production Mid-Continent! Alaska Business Unit 909 West 9th Avenue, Anchorage AK 99501-3322 Tel 907 263 7877 hilletk@chevron.com From: Regg, James B (DOA) To: Sullivan, Sharon T 11/17f2008 Page 2 of 2 Cc: Davies, Stephen F (DOA) • Sent: Fri Nov 14 15:39:48 2008 Subject: AEO 6 Depth Extension per our phone call, below is the assessment from Steve Davies and his request: - Please have Chevron's geologist / petrophysicist update the TDS values in Table 1 of their most recent submittal; The values in that table don't reflect the revised temperature estimates for the injection zone (in their original submittal it was ~85 deg F, but has been revised to 105 deg). - Near the bottom of page 6 of their most recent formation evaluation submittal (Ivan River Unit Aquifer Exemption Questions Followup.pdf), they state that the Rw for the lower injection zones equates to 2700 ppm NaCI equivalent. What does this say about the TDS content of the connate waters in those zones? If you can get us the info today, Steve has indicated he will continue reviewing over the weekend. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 11/17/2008 • • Revised Table 1 Salinity Values within Proposed Injection Zone Sands in IRU 13-31 11 /14/2008 AOGCC NaCI Equiv. Calc Sand Depth Porosity Rt Rwa TFM Salinity TDS* MD SSTVD % (Ohmm) (Ohmm) (Deg. F) (ppm) 5,565 -4235 27 2.88 0.267 103.9 16,300 20,049 5,695 -4318 26 3.96 0.225 104.5 19,550 24,047 5,730 -4340 24 3.47 0.29 104.7 14,780 18,179 5,845 -4414 24 14.4 1.125 105.3 3,450 4,244 6,020 -4526 25 16.8 1.562 106.2 2,420 2,977 6,150 -4609 24 22.3 1.839 106.5 2,030 2,497 * Based on spreadsheet provided by Unocal via email 11/14/2008, that is saved as G:\common\West Team\OrdersWquifer Exemptions\AEO_6A_IRU_13-31\ 081114_Unocals_Salinity_and_TDS_Data_USGS alaska_rw.csv Per email from T. Hillegeist, Chevron to J. Regg, AOGCC, dated 11/14/2008, the conversion from NaCI equivalent to TDS is TDS (ppm) = 1.23 X NaCI equivalent (ppm) AOGCC 11~17l2008 using data from USGS provded by Unocal 081114 UNocals Salinity_Values Aquifer Exemption IRU 13-31 Revised Table 1 .xls C7 Revised Table 1 Salinity Values within Proposed Injection Zone Sands in IRU 13-31 11!14/2008 NaGI Equiv. Sand Depth Porosity Rt Rwa TFM Salinity MD SSTVD °lo 5,565 -4235 5,695 -4318 5,730 -4340 5,845 -4414 6,020 -4526 6,150 -4609 (Ohmm) (Ohmm) (Deg. F) (ppm) 27 2.88 0.267 103.9 16,300 26 3.96 0.225 104.5 19,550 24 3.47 0.29 104.7 14,780 24 14.4 1.125 105.3 3,450 25 16.8 1.562 106.2 2,420 24 22.3 1.839 106.5 2,030 Page 1 of 3 .7 Davies, Stephen F (DOA) L' From: Regg, James B (DOA) Sent: Wednesday, November 12, 2008 9:21 AM To: Davies, Stephen F (DOA) Subject: FW: Ivan River Unit Aquifer Exemption Extension -Additional Information Needed Attachments: AOGCC AEO Extension Letter Request revl.pdf; IRU_44-36_mudlog_section.pdf; IRU_13- 31 mudlog_InjectionZone.pdf; IRU_14-31 mudlog_InjectionZone.pdf; IRU_41- 01 mudlog_section.pdf; Temperuature_Pressure IRU44-01.pdf; Ivan River Unit Aquifer Exemption Questions Followup.pdf; DIO Perrrrit App_IRU 13-31_rev2.pdf Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorege, AK 99501 907-793-1236 From: Sullivan, Sharon T [mailto:SullivanS@chevron.comJ Sent: Saturday, November 08, 2008 5:48 PM To: Regg, James B (DOA) Cc: don.andrews@asrcenergy.com Subject: RE: Ivan River Unit Aquifer Exemption Extension -Additional Information Needed Hi Jim, I have attached the following files in response to Steve Davies request for information in your a-mail below: • The Ivan River Unit Aquifer Exemption Questions Followup document with a Temperature and Pressure file and mudlog excerpts from IRU wells 13-31, 14-31, 41-01, and 44-36, • The Revised AEO No. 6 Depth Extension Request Letter that clarifies the requested end depth for Well IRU 14-31, and • The Disposal Injection Order Application (Revision 2) for Well IRU 13-31 that also clarifies the requested end depth for Well IRU 14-31 in the aquifer exemption section of the document. You have now received our responses to both your and Steve Davies's request for information (the a-mail sent to you on November 3, 2008 responded to your request for informationlclarification). If you have more questions or require additional information regarding this submittal, please let me know as soon as possible. Once you deem the information you received to be satisfactory, I will send you the final hardcopy versions. If there is anything you can do to help expedite the issuance of the revised or amended AEO No. 6 for IRU 14-31 and the new DIO far IRU 13-31, I would really appreciate it since we are now on a very time-critical path with the drill rig arriving at Ivan River Pad this coming week. Thank you very much! Sharon T. Sullivan Planning & Permitting Specialist, I-lES Group Chevron North America Exploration and Production Company MidContinentfAlaska Business Unit 11/12/2008 Page 2 of 3 3800 Centerpoint Drive, Anchorage, AK ~3 • Office 907.263.7839 Cell 907.830.1821 Fax 866.801.5194 Email SullivanS@,Chevron.com From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, (ktober 20, 2008 5:44 PM To: Sullivan, Sharon T Subject: FW: Ivan River Unit Aquifer Exemption Extension -Additional Information Needed Listed below are questions/requests posed by our Sr. Geologist that are needed before we can complete the amendment to AEO 6. These are equally important for us to complete the DIO application for IRU 13-31. In addition to the questionslrequests for the AEO 6 amendment, please address the following speafic to IRU 13-31: 1}there needs to be a more detailed discussion of the upper confinement and why Chevron believes it will confine the injected fluid stream; 2) there is a mix of depths used throughout the application (MD and TVD); the datum (MD, TVD, TVDss) is not referenced on several of the exhibits (e.g., Exhibits 2,5,6,7) -please clarify; 3) Exhibit 8 indicates a top of cement (TOC) at 6250 ft that appers to represent the well's plug back depth; header for the well schematic references plug back depth (PBTD) as 7400 feet -please clarify; 4) Exhibits 10 and 11show proposed injection perfs as Beluga formation; the remainder of the application references proposed disposal injection perfs in the Sterling formation -please clarify; 5) Exhibit 11 indicates TOC for 7" csg is 5600 feet; other well schematics for IRU 13-31 show it at 5000 feet -please clarify 6) Exhibit 11 indicates a USIT was used to establish TOC in IRU 13-31-only bond log information in Commission files are sepia copies of segmented bond logs for portions of 7" (surface to 2800 ft) and 9-5/8" casing (1470 to 3400 ft); provide USIT log data Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorege, AK 99501 907-793-1236 sulliva ns~chevron.com From: Davies, Stephen F (DOA) Sent: Monday, Oc~ber 20, 2008 10:13 AM To: Regg, James B (DOA) Cc: Roby, David S (DOA); Maunder, Thomas E (DOA) Subject: Ivan River Unit Aquifer Exemption Extension -Additional Information Needed Jim, Since you aze coordinating this AEO extension, I thought it best to relay these questions and requests for the operator through you. The structure at the level of the proposed injection zone in Ivan River Unit 13-31 is relatively flat, the stratigraphy is not complicated, there aze several neazby wells, and mud logs from those wells suggest that gas may be present within the downward expansion of the aquifer exempted by Aquifer Exemption Order No. 6. In order to ensure that water-quality standards are met and that natural gas resources will not be wasted, additional information is needed. Formation temperature calculations 11/12/2008 Page 3 of 3 Please discuss derivation of the temper'~re gradient from surface through the propo ed injection interval, incorporating maximum temperature readings recorded in wells 41-01, 44-36, 14-31 and 13-31. Is any. additional temperaturg information available? If so, please provide copies to the Commission. ~,-, ~-,~ 1~~ ~'~a- ~~~-~'/~~ ~~`~-~ ~/dv8 ~~' Lithology ,/'~ rc ~ ~ ~~ f e.ti..~~c..-r ~u ~- ~r-~~ ~~.~ Please provide a detailed lithologic description of the proposed injection zone and the proposed expanded exemption ~~"~~ ~ zone. How do the lithologic components affect gamma ray, SP, sonic, density and neutron measurements throughout the expanded exemption zone? For log analysis purposes, would the sand beds within the proposed injection zone be considered clean or shalt'? Please explain. Are additional data, such as core or sidewall core descriptions available? If so, please provide copies to the Commission. ~lc~- ~~e~-.~~' Porosity Please describe techniques used to calculate porosities provided in the application to expand the aquifer exemption. Justify their use over other techniques in this instance. Mud logs from nearby wells 44-01, 41-Oi and 44-3b suggest that methane gas is present throughout the proposed expanded aquifer exemption interval. Please explain and demonstrate how wireline porosity measurements were corrected to compensate for any affect of any gas present. Were shale corrections utilized in your calculations? If so, please describe the techniques and demonstrate their validity. Total Dissolved Solids Since the stratigraphy is relatively uncomplicated and there are several closely spaced wells, TDS calculations within a given interval in well 13-31 should be replicated in stratigraphically equivalent beds logged in nearby wells 44-36 and 14- 31. Please provide confirming TDS calculations in representative beds for well 13-31 and these nearby wells. Were environmental corrections made to any of the well log measurements? If so, describe what was done and demonstrate validity of the corrections. Were any waters recovered from any of the Ivan River Unit wells analyzed for TDS content? If so, please provide copies to the Commission. Natural Gas Content Please explain why the proposed injection activities will not result in waste of natural gas resources. Provide water saturation analyses and test or production information from representative sand beds within the proposed expanded exemption zone demonstrating whether or not commercial quantities of gas are present. Explain and justify the choice of technique(s) and critical parameters such as Rw. Please describe and demonstrate how these parameters were obtained. Thanks, Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission Telephone: (907) ?93-1224 ~' Fax: (907) 276-7542 New Email Address: steve.daviesnalaska.gov 11/12/2008 • • Revised Table 1 Salinity Values within Proposed Injection Zone Sands in IRU 13-31 11/14/2008 AOGCC NaCI Equiv. Calc Sand Depth Porosity Rt Rwa TFM Salinity TDS MD SSTVD % (Ohmm) (Ohmm) (Deg. F) (ppm} 5,565 -4235 27 2.88 0.267 103.9 16,300 20,049 5,695 -4318 26 3.96 0.225 104.5 19,550 24,047 5,730 -4340 24 3.47 0.29 104.7 14,780 18,179 5,845 -4414 24 14.4 1.125 105.3 3,450 4,244 6,020 -4526 25 16.8 1.562 106.2 2,420 2,977 6,150 -4609 24 22.3 1.839 106.5 2,030 2,497 WELL LOGGING, INC. LOfi MITERVAi DIFPTH6: 3453' TO ~' owTES: 4Y1-z~-93 To oa-oi-ss scALF~ x=~oo• ~ ..~ .~ ® foama5cn log VuPMr, G- I>~1 ~ 7708 (~ DrilEit+g Qy^am;cs Log - Praaawro Ewtuation log A6eAawg6, AK (907) 561.244 =~ `+ Cfiromampraphy Ratio Lop CAiNO DATA 4bAfPAMY.~ t1MOCl1L 95.8' AT 3649' I4vEt1: NU 4490 AT i ftf LO: IYAN N1fE'R AT REG JQAP: UPPER COOK M9lET AT COORCO6 ATEi: 76TF84, 777'FEL ~~ - umyens In +,c+P T«w Tll .rr eGr - . - ; _ s sA . sr.u . cPr ... q aE r m. t+~ a.-o«, .snow rn.. r,em ' r<L TJ Vi6 S` V J$1 M ' ' V~CM'/OiC . , l `43;: 9~n...Me. COM . Y'S Y9 Wr1rMY 4_. 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IvAh R;YER !4-Jl _ .___. __ GOi:NTY _ __....~fAT31 ._ STATE ALASKA ELEVATIGN 3Q~Gf7g SCZlL9..it3tL SPUD DA'E .. S!~/T3 ___ F:NA~ DATE_ 7/'y!7_S _ TOTAL DEP' ~~ _. _10,43fl~ DRILLING CG _.1iENALOf3LS..S4. f~,Sr,ERT,g)l~g-HQWgI.!`}yR1Gli~_ REMARKS Pl1MP ,y~j EMSCD D-jQQQ_~~$jg'j((~_ru2~11NF$ PUMP_jYQ,_Z GD G_Y R___~~STROKE-31/x+ INfR p$jLL PIPE ~ DIA 19.30 WT . I^ HOC. E. ~> _'c: ~ ~ ~.,AS,N~ RECORD ... .. 13n7 r.. ~ _ ~ ~ 0 _~.. {, ( .. . r~~~~ ~. . ` •r+ . .. ~ .4. ..... .. :. :.. RPN FY ~y°y °>..~E- ~ .. - . .. ~ .~.. - -.... .1. ..._._ .. .... .. .... ..: :I::-.. ._. _ ~ .~.: _.._ ._...::f:.. .~ :: :..::_ ~_:_:. .: i:. .::. ~. -... I .: 41 _ ..». i~.~~ -- -- ~ ._ " ~ _ ~f::: .._i .... ~ .._...~ ~ ._ ~::~ .-... r ... .. i ,~_y .. .. ...... _...... .... ~... ... 1. _. r ~ -_. ~ ..-... _.. ..-....-I .t .. ... .~ .. _.._.. .. 'c" .. .. . ~ .. .. ~ r. Zfi :. .. c _ , . . '~~ ~ O . _._.~ ..__._ $~ . _ ... 49 ~. _. 1 E~. .~C r... 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DATE BEGUN 3/Tljg_ _ -~ uE;.EASED _ Il3LZ~__~ INTERVAL LGGGEU 435T-1!?.93$.- FoCTAGE_.14w523 __~ SERVtGES PERFCRME(' ..t+m!!L_LQGGL"1G W/CHRO~AIOS~I3AFti _~Q..~YFI BHT, 1F~MA RATy~ ~$(STlV17Y IN B _,_, 0UT• +A=OcneanmenY SHALE DENSITY NITRATE A88REVfAT~ONS NB NEW B.7 CG U?NNECTION GAS N i,B NEW CORE 81T ::OR CORRECTED DEPTH NR NO RETUPNS WT MUO WEIGHT GO CIRCULATE QUT VIS VISCOSITY DST ORiLLSTEMTEST WL WATERLO55 PR POOk RETURNS CI PPM CHLORIDE TG TP.iP GAS NoG~ SOD. CHLORIDE .aT LC~.GEUAFTEk 7P,IF Rm MUD RESISTIVi7Y t ~ wf-Cf. mwM KOI W->y .. _.. ..4...__. .... .. .... irse L d wn bm gray-sw ~.. ... _ .. _.. ~ . _ .a.........» .~ .... .........~. .::-:::- naerof sac ISOcc l.- ._..„ 1j1- /~v y cq1 ac gp _. }.~.... ..... .~..... _ ~O f1' ...... ........~~ I '~~ ..:.:. ~ m~oe ~~ maw wq j ~ .+oad +r.. ma. - - -fit . tow D+ n.nd ry ~'y 'nwf yr r.^r~.ur .nm .. ~ .... }~rU ~Ils~ypr InM.11 pq .. 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AMD FElOSPAR, fiAJADM,T DDAL ARD GRa SiMIC. 5Linf.' ~ .B1S'• 32W Of.,:. aasso AZi TvT• as,e.sr, ,3Da.arN. n.u•E _..__ `+A',D - YETy DAMY TO O[c DRY: UIKUNS: GEN [ME TO NEOMI CRMMS: AMCtAM W SaR!L*G Act Y[ti ~RRD: CU/ NATRDt AND GRAN s:ED; MosTLr oN caDRrD META Ati6 r~`-a."+G S V~57M.'S M?M M t4 6!1?' RTZ: 7+E4S; tINtCEDO[IY AND RNSOLTJ4E i3RR: AF~Nv++aT TVfi*.a0U5 SfAMCNIS ~,cf - usM aY cR. ro a.FCe+ der• s~ ':J [9Rkp GENERALLY S~OOTN TExiIYIE: Y !~,sd" - GR'CN6N FRAY 10 1t:11T/RKF ~A!'f- _ aFra:tB..4L~UE: CCNTAD[5 MAF,C MtC ~I t]ilt5 .c}:, v . REYt1AVT 3/tlDS: Y SR: GENERAV,fY a ~lwcrnELr awe arsr. AMA li+_~°-.=h 5?+i,Yftwel E$:: QYEf-WT1E-A57F[ 'L~. SPAfi'.lY-bAl ISTR Kia PRp9 4 v 5iy R. l se t• a, e[ ~ lo, , s,.eD Dec. c.:o A<, rsi, +xro.t,•, ,~axzrq aD.a~rT ~, :~[ - ORE[MPSN DRAY ro L1c++r aarc ~tA` t£C VKa• ORNY F71Y TO 1FOD Mtt e • ; . : v N:(Y L45TCR: RE?IENAM !nA#ai: 'P^`r i, SKTY TCxNIlE_ F~ANOARI.E ATt!h YF!n2VNTEP. ASHY AFPe/t1Y,CE. - bl.h DPOwN TO 91LY: ORAMAl~R - cJ7Y: 4NKY Ni HARE: SYOOiN m 9LTi -E XTL~RE: GIMAAtLY we-em~wx,~ sowE ~ >.- t.Wn:sE tx D,erni rVCw. ~~ z ,.,,. TD .Nn TIAY: LODGE eoNSCL '~ v*M.Cw3.; nNF G,WN l.'A01 M YEN[ G5i Rti`4:G ICMR; S,AK1t'JJa/R TO ~"aPFiY,t[~ED •_ ~5 C'hJd+Ill SVNCR. MOD SRiD: LDtIL1Y f•c Ft,~,Yg[w'E AFA';,RI}[[KEWS Ma7Gfd: $E~0.T E* i:AfF: GRJdN alim(lATED: COYR G[' APRROY .u 151E ;3T7 ki6 9rJu{YiT META, ~PJtLS• f}fiT, ahD eaTx?R [ELDSRAP, SCN l/G HV,CS. GN«;:DMEAU[/sxa - GEN Y NCMIXQ7EDikS. .r ~D ti Dr-YEO Q. Gr w/ li1MS*, n4C GtC <;P<ttl:P dAf plNbn 7'-CRNBN G;; RJtGES S ~tEl. SR;r~ M Y IPPEF f..If+AER S>Y ~ 4t' E: t+G-FU-Y.API M R^ j7~R'r V .#~ Rr wMtY rnAr.. GE f n[u DEV ~u ~~ Ab{A• C YR ARiT GRAINS SMERY,.K AND p~ ~tzeLx~Y.[(iK, ALMCh'i TOTKIr ,AU~R 1E4 N,f f1AV WTMh TrµT F VERY ~:L:raE ANO La•. To rHE L+aurt: YceD. Via:. a[0 GRY m FFi5+1 DAnwN: 50[T T?t ~E~QL'~I~CE F E~'ET~ I~A~ RISER SELL #~ ~~-i ~~~ ~ /~~ to 2~~~197 .'_.;'21197 0830 ~i~ up nn ~•ell. Pressure test Lubricator. 0930 RAH ~~-~ 1.5" GR. ~a~ tiil at X09?' r~°lm, P3H dwell flt~v~rin~ ~ 456 Mart bomb ? 0808 1057 Start bomb ?t3$09 ~ 105 Open swab ~~ai~=e ~~t 1 ~ minute ~Iowin~ sura~e pr~~sur~ i I20 R1H ~~~~dual electronic pressure recorders l 143 ~eaci~ 7'946' w1tn. l 700 Smut ~t~in~ ~tal ate, start buildup. '.'?4197 I841 Start client steps, make stops at 7$46, 7746, 7646, 7546, `~~, 6346, f~~-4~i. ~~14~i. >=146. X46. 346, ?446, 144b, 446, and 0. _' 100 Bleed dov~rn (ubrcaeor, check infc~rrnation., rid dawn. • • POLLARD WIRELINE Subsurface Pressure Measurements Company: UNOCAL Address: CAVIAR STREET, Well, name: 44-1 Location: IVAN RIVER Field & pool. Production inter val: Mid point gerf; 7900 Well status: SHUT IN Test type: STATIC GRADIENT Elevations KB: CF: Date of test: 97/02/24 Shut in date: Tubing pressure before: 1755 Tubing pressure after. 1755 Casing pressure before: Casing pressure after: Tubing diameter: 2-7/8 Casing diameter: 7-5/$" Probe serial #: 20$0$ KEI+TAI AK. Readings and Calculations For Static Gradient depth Time Ston Temperature Pressure Gradient Stops (F} (PSIA} (PSIA/F) Surface 20:41 - 20:56 59.1 1762,7 0..000 446,0 20;2 9 - 20:35 86.9 1783.5 0..047 1446..0 20:20 - 20:26 85.8 1824.1 0.041 2446.0 20:11 - 20:17 88,3 1855.1 0.042 3446.0 20:02 - 2010$ 93.2 1$08.3 0.042 4446.0 19;52 - 19:5$ 101.7 1951.9 0.044 5446.0 19:42 - 19:48 108.9 1.99.5.4 .0..043 6446.0 19:25 - 3.9:32 115.1 2038.5 0.043 6946..0 19:18 - 13:24 I1?.7 2060.1 0.043 ^`4b,(3 19:10 - 19:16 119.5 2082,9 0.04E ~~~rs try; ;~'~~,~~ {P~#'~~ 7?45.~ 1~~4~ - 18~~~ ~.23,£s ~433~.~ 0~{~~~ ?846. I~r~~ - x.:48 I~S.~ 4 ~.~ ~ ~B.t2 ~ rP Q`~~.~ i.~:~v ~ iv:ww ~~~a t ~ p L~€~~a~ g ~s~i3~ +.~4i ~L.i41~ ~.7Y! a~~4`4/.iAir ~~i~r~ ~~cC37C'd@~ ~CE$t38 ~~Q'PkI • • Formation Evaluation of the Proposed Injection Zone in IRU 13-31, Addressing AOGCC questions on the "Application for Disposal Injection Order Ivan River Unit Development Project, September 2008" 07 November 2008 Formation temperature: The graph below summarizes the temperature data currently available to us: - bottom-hole temperature (BHT) recorded at logging in wells Ivan River Unit (IRU) 13-31, 14-31, 23-12, 44-01 and 41-01, plotted as a function of the time since last circulation (TSLC) for these wells - a complete temperature survey after 3-day shut-in for IRU 44-01 The temperature profile is given by the equation FTEMP = 70 - 0.008 TVDSS, where temperatures are in degF and TVDSS in ft. ~~~r'~~~~' ` --- ---- -L - - __ 0 50 100 150 200 -2000 ~ X .: w 0 -4000 -6000 -8000 -10000 X IRU BHT record (TSLC< 6 hrs) O IRU BHT record (6 hrs < -12000 TSLC < 10 hrs) i ^ IRU BHT record(TSLC I >10 hrs) -14000 ~ -~- IRU 44-01 temperature log after 3-day shut-in - Trend for IRU field -16000 i -18000 1 -_ ___ ___ _ -_ ___ __- -_ Measured BHT (degF) ,C~e{~. ~ s 33 S F ~L, v 8 O 250 [See attached. pdf file: Temperature_Pressure IRU 44-01 ] • • Lithology: The proposed injection zone is described from offset mudlogs (cuttings description records) as a mix of coals, unconsolidated sands or conglomerates (for the zones with lower Gamma-Ray readings) and sands with some clay and abundant tuffs and volcanic materials (zones with higher GR readings). Please see attached mudlogs for wells IRU 13-31, IRU 44-36, IRU 14-31 and IRU 41-01 in the equivalent section, representing the injection zone. (See the four attached .pdf mudlog section files for detail) No core is available for this part of the section. Mudlog description: The section can be divided into three major zones. The upper most being a low resistivity sands 5544'-5746 MD, and two higher resistivity zones in the lower section from 5746'- 6183' MD in the IRU 13-31. The following mudlog description summarizes the section and is taken from the mudlogs of IRU 13-31, 44-36, and 41-01. At the top of the injection zone and just above is a tuffaceous claystone that appears to be 20' to 30' (TVD) in thickness. The upper low resistivity sand is described generally as a massive fine to coarse grained pebbly sandstone with only minor amounts of finer material. The upper sand appears to be cleaner than the lower sands, but still contains some lithics of metavolcanic and igneous grains. Locally the quartz content as high as 80 percent (IRU44-36). This sand sits on a possible disconformity within the Sterling section. The lower section is topped by about 100' (TVD) of thin interbedded tuffaceous claystone, claystone, sandstone, coal and mudstones. The sands are described as being very tuffaceous with quartz as low as 15 percent in some samples. Below this section is a more massive sand made up primarily of a tuffaceous matrix. The sand is poorly sorted with very fine to granular grains, predominantly fine to course. Quartz ranges from 15 to 40 percent. At the base of the sand is a thin tuffaceous mudstone made up of approximately 75 percent clay and 25 percent silt. The lowest lobe is made up of a conglomeratic tuffaceous sand. This sand is poorly consolidated, fine to very coarse with interbedded stringers of conglomerate, and grain supported. The section is very low in quartz, ranging from 10 to 40 percent. The remainder of the sands are made up of metamorphics, chert and igneous lithics, with minor amounts of feldspar. Below the base of injection zone is a thin section of coal and claystone. 2 • • Petrophysical: Given these descriptions and an established knowledge that GR can be adversely influenced by volcanic materials in parts of the Cook Inlet, the neutron-density separation was used to calculate shale index. The SP log is better suited to identify the sands insofar as there is resistive contrast between formation brine and mud filtrate. Gas identification is provided by the sonic log, which is in that region more sensitive to gas presence than the density log regardless of shaliness. The Appendix Attachment-1 shows a typical gas response, within this section, of that formation in a nearby field (North Cook Inlet Unit). In IRU 13-31, no such behavior of the sonic log is observed; this supports the absence of gas pay in the proposed injection zone. In the absence of obvious gas effects, the neutron and density responses reflect lithology and shaliness. In the zone of interest, there is mark of a 30'-thick shale around 6000' MD, while the neutron-density separation remains consistent above and below that shale regardless of the GR log, likely affected by laminae of volcanic deposits. However, neutron and density logs are not available in IRU 13-31 in the obviously clean low- resistivity zone above 5750' MD (-4353' TVDSS), so to compare these zones we consider the offset well IRU 14-31. This offset shows that the neutron-density separation remains consistent across all the sands of the zone of interest, regardless of GR and resistivity. For log analysis purposes, we can therefore consider these sands as clean. Coals are characterized by local peaks of high porosity, low GR and high resistivity. In IRU 13-31 and 14-31, a simple flag using a porosity cutoff of 0.35 correctly captures all the coals. In IRU 44-36, crossovers of density porosity (DPHI) and sonic porosity (SPHI) indicate the cause for the porosity increases: coal are characterized by DPHI>SPHI while gas sands are flagged by SPHI>DPHI. • Table l . Salinity Values within Proposed Injection Zone Sands in 1RU VVel1 13-31 Sand Depth Porosity Rt Rwa TFM Salinity (Degree MD SSND (%) (Ohmm) (Ohmm) ~} (ppm) 5,565 -4,235 24 2..98 4.1916 84 23,300 5,695 -4,318 27 3.86 0,4182 84 13,800 5,730 -4,340 23 4.95 0.3851 84 16,000 5,845 -4,414 22 17,9 1.223 84 .4,:,400 6,020 -4,526 25 15.7 1.453 86 3,600 6,150 -4,609 25 1fi,5 1.609 87 3,300 • ~ Porosity, salinity. and gas content: As shown in the previously shown logs of wells 13-31 and 14-31, there is excellent correlation in the zone of interest between density porosity (with a default value of 2.65 g/cc grain density, curve DPHI) and a Wylie sonic porosity (curve SPHI) using a compaction coefficient c SPHI = (DT - 55) / (c * (189-55) ), where DT is in ,us/ft c needs to be zoned, but in the proposed injection zone is it 1.8 for well 13-31, 1.9 for 14- 31, and 1.7 for 44-36. The mudlog of IRU 13-31 shows gas in a coal and mudstone zone above the zone of interest around 4500' MD (-3553' TVDSS), in coals (5045' MD/ 3903' TVDSS; series of coals between 5750' MD/-4353' TVDSS and 5854' MD/-4420' TVDSS; 6195' MD/- '' 4638' TVDSS). Likewise, in IRU 14-31 mudlog there is an increase background gas in a zone at 4125' MD (-3586' TVDSS) which is above the injection zone. The low, constant background gas continues over most zones of interest. The is a substantial gas show increase in the coals below the zones of interest (around 5700' MD/-4844' TVDSS), and is just above the know productive gas sands in the well. In IRU 44-36, there is no gas show across the zone of interest (5200' to 6000' MD or roughly -4080 to 4640' SSTVD) Overall, none of these wells presents evidence of gas seeping from the sands of the proposed zone of injection. Finally, the apparent formation water resistivity (Rw) was computed both from an inverse Archie relation (assuming a=1 and m=1.8 which is appropriate in poorly consolidated sands) and from SP, using the temperature trend determined earlier and the following measured values of mud filtrate resistivity: Rmf = 1.56 Ohm.m @ 64 degF for IRU 13-31 2.34 64 14-31 1.04 64 44-36 Rw computed from the maximum SP deflection in a sand (RWA SP) usually gives the lower-end of a possible Rw range in that sand. Apparent Rw from Archie (RWA) represents the value of Rw that this sand would have if it were wet. RWA increases if the sand is not wet and/or if the actual value of Rw increases. A quality index is here given by the separation between RWA SP and RWA. As shown in the following displays, Rw can be very reliably determined in both the low- and high-resistive zones by agreement between RWA and RWA_SP: • in the top zone Rw = 0.3 Ohm.m @ 105 degF or 14,000 ppm NaCI equivalent ((Schlumberger chartbook) • in the bottom zones Rw = 1.5 Ohm.m @ 105 degF or 2,700 ppm NaCI equivalent / The value in the top zone remains compatible with both IRU 13-31 and 44-36, but in the IRU 13-31 lower zones RWA increases and with a minor amount of gas -not enough to justify an increase in sonic porosity, but sufficient to reduce the neutron-density separation and impact resistivity. An Archie saturation with a=1, m=1.8 and n=2 yields 6 • • Sw = 0.8 in the sand lobe 5900'-5760' MD and Sw = 0.9 in the lobe 6030'-6150', everything else being wet in the proposed injection zone. Given the approximations on the SP baselining and Archie's coefficients, we conclude there is some irreducible residual gas in these to parts of the lower zones of IRU 13-31 injection section. These levels of gas are not high enough to be commercially economic. ~ Similar calculations in IRU 44-36 yield Sw = 0.8 in the high-resistive sand lobes 5718'- 5782' MD and 5850'-6136' and the same conclusion applies. See following five well log displays. This petrophysical formation evaluation was conducted independent of earlier work and was completed by Emmanuel Toumelin -Chevron Petrophysicist and Tony Hillegeist - Chevron Geologist 7 • Logs of well [RU 13-31 in the zone of proposed injection: NDSS FEET DEPTF FEET 5600 -4300 5700 5800 -440D 5900 -4500 6000 6100 -4600 • 4 • • Logs of well IRU 14-31 in the zone equivalent to the proposed injection zone from IRU 13-31: NDSS DEPTH FEET FEET -420D 4900 50DD -4300 5100 -4400 520D -4500 5300 -4600 5400 IRU 13-31 display ~WIRE.TLGS_1 ~ NONE 3.fi94 'ORE.= " ~h'IRE.RMF_1 - -- NDSS DEPTH iu~ ~ - ' ~Nwi ~ ~ IRE.~:ALJ_~ fgr FeEr .;~. ~P'~1_t *`d `'=-E,_'' r4'IRE.IL.M__1 R1h'.R4d'fL2 DPHI_1 ,. ;,~,,:. 1 OHp,iM 100 .7 OHkN 10 L' ~3 ti ,~ i?_1 ,. i' ~ ~i ~i.,ry .~ cF, I ~~• - I ~ -~~.- --- ssoa --- I -- - ----- ---- --- .-;f~ ~'~ °°- ~ - ----- ---- ,~ ---- ~ ,o --- I--- ~ J .t- I y ~ ~ ---- 500 - --- .. -----. ~~ ~.-- ~5~. I ~ t X800 I - ~- - ~' ----- -- -- ------ -44i1i~ I - - y _<, • {~.~ -- ' 5900 ----. 4 ~--- ~-- ---.. -- -!F-~ ~~ , .r ` -•i-'-- ----• -- A -- ---•• --- •-r ~ _ _~~ ~ $ ~( _ ~ .~~ s~---- ----• ---- --- ---•• . --~ --- ~: -{---- 6100 ----- ---- - --_.. -- ---- ~ ~ ,~ ^ -4h00 ~ 1 ~.--- ---- ----... ----... ~---a... ---.... ---~ ,--- IRl1 14-31 display: • • IRU 44-36 display: ~hlIRE.TLGS_1 is NONE 49.05 ,IPE.FTEP:IP_ ~ Y11RE.RMF_1 NDSS DEPTH : oec~ Ts i - oHMni _1J _._ coli h ... FEET FEET -:~., WIftE.ILD_1 SPH!_ ~ ~4 1 N 1 I . ~ ~. rr ~~~ c v, =`N.`F!~ ~' WIRE.RILMi_1 RN+.RW.~2 DPHI_1 ~- E.1'- P OFWM 1G`C~ .1 ONk1M 10 .B Y:~'v 6'~'IREGR_1 ' `~ ~cr ~ 1 3------c:~i ....y3 ~'~~~~~~ 5300 ___... __~~... ..,.. ~_.... _~_ ~.~~ .~~ ~ I " ___~ 5400 ~... ~ __~... a. . ~ _.... __ .~~~_ ~ ~ r ~ .~~ ~ ~ ' ..5~, ~ ~ ' 2 ' _.y.. ~, : -4;00 i '- ~ ~~ 9 ~ ~ _____ __--° 1 3 ._a.. .~'~~ I ~ ___ 5600 ____ ~~`_ j ___ __~. __ ~.. _ . ..~ ,~ti -+.:~ -- -4400 700 ____. ----- + _~. ~ ___ ____ .. ~.... __ ' ___ .,,~ << ~ . __ - 4500 5800 J ~ ~ _ ___ ~~.- .__•• - ____... __~... I _ . .. I _.... __ _ +i. , ,: e~~ '° 1 10 • • Residual gas saturation in IRU 13-31 NTH :er X00 00 100 X00 100 00 • Residual gas saturation in IRU 44-36 NONE 4~.G5 W'IRE.RMF_1 i ~ un-ri --3 tv0 S€GF T^D ~ _ ~ ' Vy9RE.ILD_i RW.R4^IA_2 SFHI_Z I M 1 -4 8 V•i W1RE.RILM_1 WIRE.SW~IRCH_1 DPHI_1 OF#1M tQG 1 Y 4 .6 V, + ~~ ~, °E.B~~~C_1 F= ~ ~- ~ - -, I; i 1 ---- ___ ----- .__°. --i.. -_ _.~- ___.. --~~ __ ~~ i ~ ----- ~----- ---7 ~ __~. ___ ___ i ~ r ____. ____ .i. 1 ___. __ __~ 1 t ' s i t I - -- ~L - t I. - - - ____. }~ ~.__---• i --i.. __..._ __~ 12 • Appendix: Attachment-1 Log of North Cook Inlet Unit A-12 well k ` WIRE.ILD_1 SPHI_1 1 OHM AA 100 4 6 V J 0 ilm DPHL1 1 OHfAA4 10G 0.6 V sfl r~,t_,i_h_i 1 GHt,l~a 1'%0 __ _ 4.6 _ ., . ~=' `~ / i f t } i~ _S ". f s' ~~~~~ ~~~ } ~; J ~' The sand between 3642' and 3779' (MD) is fractioned by a known gas-water contact at 3714' MD; with water below this depth, and gas, above. The top (gay pay) exhibits a strong sonic porosity (SPHI) crossover, while the density (DPHI) is only moderately affected by gas. The wet zone below exhibits a good match between sonic and density porosities. 13 �J n s STATE OF ALASKA '- NOTICE TO PUBLISHER ADVERTISING ORDER NO. ADVERTISING ORDER INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTIFIED AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COPY OF ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE A 0-02914003 /'1 SEE BOTTOM FOR INVOICE ADDRESS F R AOGCC 333 W 7th Ave, Ste 100 AGENCY CONTACT Jod Colombie DATE OF A.O. Jul 21 2008 ° M Anchorage, AK 99501 907-793-1238 PHONE PCN DATES ADVERTISEMENT REQUIRED: o Anchorage Daily News PO Box 149001 Anchora e AK 99514 g ~ July 22, 2008 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: Advertisement to be published was e-mailed Type of Advertisement Legal® ^ Display Classif ied ^Other (Specify) SEE ATTACHED SEND INVOICE IN TRIPLICATE TO AOGCC, 333 W. 7th Ave., Suite 100 Anchora e AK 99501 PAGE t OF 2 PAGES TOTAL OF ALL PAGES$ REF TYPE NUMBER AMOUNT DATE COMMENTS 1 VEN z ARD 0291 0 FIN AMOUNT SY CC PGM LC ACCT FY NMR DIST LIQ ~ 08 02140100 73451 EQUISI ON D 1 DIVISION APPROVAL: 3/94) Publisher/Original Copies: Department Fiscal, Department, Receiving AO.FRM :J Notice of Public Hearing • State of Alaska Alaska Oil and Gas Conservation Commission Re: Request for Depth Extension, Aquifer Exemption Order No. 6 Ivan River Unit, Well 14-31 Section 1, T13N, R9W, Seward Meridian, Westside Cook Inlet, Alaska Chevron North America Exploration and Production ("Chevron"), by letter dated July 15, 2008, has applied for a depth extension of the exempted aquifers of Ivan River Unit. Aquifer Exemption Order ("AEO") No.6 was issued by the Alaska Oil and Gas Conservation Commission (Commission) in accordance with 20 AAC 25.440 on July 23, 2001 fora '/2-mile radius around Well 14-31 and between the depths of 2500 and 3420 feet measured depth for the purpose of Class II underground injection. Chevron is planning a second Ivan River Unit disposal injection well within that 1/z-mile radius and with a deeper injection interval. Disposal injection from this second well requires additional permitting in addition to the requested extension of AEO No.6. Chevron's application may be reviewed at the offices of the Commission, 333 West 7th Avenue, Suite 100, Anchorage, Alaska, or a copy may be obtained by phoning the Commission at (907) 793-1221. The Commission has tentatively scheduled a public hearing on this application for September 4, 2008 at 9:00 am at the offices of the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. A person may request that the tentatively scheduled hearing be held by filing a written request with the Commission no later than 4:30 pm on August 15, 2008. If a request for a hearing is not timely filed, the Commission may consider the issuance of an order without a hearing. To learn if the Commission will hold the public hearing, please ca11793-1221 after August 22, 2008. In addition, a person may submit a written protest or written comments regarding this application and proposal to the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. Protests and comments must be received no later than 4:30 pm on August 28, 2008 except that if the Commission decides to hold a public hearing, protests or comments must be received no later than the conclusion of the September 4, 2008 hearing. If you are a person with a disability who may need special accommodations in order to comment or to attend the public hearing, please ntact the Commission's Special Assistant Jody Colombie at 793-1221. Daniel T. Seamount, Jr. Chair Anchorage Daily News Affidavit of Publication 1001 Northway Drive, Anchorage, AK 99508 . d'R~GE OTHER AD # DATE ~ PO ACCOUNT PER DAY .CHARGES 525206 07/22/2008 02914003 STOF0330 $239.04., $239.04 $0.00 STATE OF ALASKA THIRD JUDICIAL DISTRICT Christine Clark, being first duly sworn on oath deposes and says that she is an advertising representative of the Anchorage Daily News, a daily newspaper. That said newspaper has been approved by the Third Judicial Court, Anchorage, Alaska, and it now and has been published in the English language continually as a daily newspaper in Anchorage, Alaska, and it is now and during all said time was printed in an office maintained at the aforesaid place of publication of said newspaper. That the annexed is a copy of an advertisement as it was published in regular issues (and not in supplemental form) of said newspaper on the above dates and that such newspaper was regularly distributed to its subscribers during all of said period. That the full amount of the fee charged for the foregoing publication is not in excess of the rate charged private individuals. Signed Subscribed and sworn to me before this date: Notary Public in and for the State of Alaska. Third Division. Anchorage, Alaska MY COM SIGN EXPI ~:' ~`~O~'4~E •• ' !4F~i~~ ~;•~pTAI~ '~' .. --- • ... .. .. " ~UBL1G ~ --- '~ .. JJJ J 'a~~ A~~,~y ___ lll"~~~ _~ 1 /~~ J j~ ~.~~'ip~S',~.~ ~/~iza~s OTHER OTHER OTHER OTHER GRAND CHARGES #Z CHARGES #3 CHARGES #4 CHARGES #5 TOTAL $0.00 $0.00 $0.00 $0.00 No[ice of Public Heating State of Alaska Alaska Oil and Gas Conservation Commission Re: Request for Depth Extension, Aquifer Exemption Order No. b NanRiverUnit; Wel(14-31, Sectibn 1, T13N, R9W, Seward Meridian, Westside Cook Inlet, Alaska Chevron North America Exploiation anii Production. ("Chevron"), by letter dated July 15, 2008,'has applied for a depth extension o the exempted aquifers of Ivan-Rroer Unit. Aquifer Exemption prder ("AEO") No.b was issued by the Alaska oil and Gas Conservation Commission (Commission) in accordance with 20 AAC 25.440 or( July 23, 2001 for a/-mile radius around Well 14-31 and. between the depths of 2590 and 3420 feet measured depth for the purpose of Class Il underground injection. Chevron is_planning a second Ivan River Unit disposal injection weq wit in that/-mile radius. and with a deeper injection interval: Disporal injection frdm this second well: requires additional permitting in addition to the ' requested extension of AE0 No.b. Chevron's application may be reviewed at the offices of the Commission, 333 West 7th Avenue; Suite 100, Anchgrage, Alaska, or a cgi5v may Ise dbrained by phoning thhe Commission at ( 7) 793-1221. The. Commission has tentatively scheduled a public hearing on this application forSeptember 4, 2008 Bt 9:00 am at the offices of the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. A persdn may request.that the tentatively scheduled hearing be held by filingg a written request with the Commission no later than 4:30 pm OnAUgust 15, -2008. If a request for a hearing is not timely filed, the Commission may consider the issuance of an order without a hearing. To learn if the Commission will hold thepublic hearing, please call 793-1221 after August 22, 2008. in addition, a person may submit a written protest or written comments regarding this. application and proposal tq the Alaska Oil and.Gas: Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. Protests antl comments must be received no iatecthan 4:30 pm on August 28; 2008 except that if the Commission decides to hold a pupLic,hearinS, protests or comments must be received no later than the, .conclusion of thy September d; 2008 nearing. If you are a person with a disability who may. needspecial accommodations in order to comment or to attend the public hearing, please contact the Commission's Special Assistant Jody Colompe'at 793-1221. Daniel T. Seamount, 9r: Chair AO-02914003 Published: July 22, 2008 $239.04 E 1 ADVERTISING INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTIFIED /t, O_02914003 ORDER AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COPY OF /'1 ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE SEE BOTTOM FOR INVOICE ADDRESS F AOGCC AGENCY CONTACT DATE OF A.O. R 333 West 7th Avenue. Suite 100 ° Anchnra~e_ AK 99561 PHONE PCN M 907-793-1238 - DATES ADVERTISEMENT REQUIRED: o Anchorage Daily News July 22 2008 , PO Box 149001 Anchora e AK 99514 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN g ~ ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: Account # STOF0330 AFFIDAVIT OF PUBLICATION United states of America REMINDER State of ss INVOICE MUST BE IN TRIPLICATE AND MUST REFERENCE THE ADVERTISING ORDER NUMBER. division. A CERTIFIED COPY OF THIS AFFIDAVIT OF PUBLICATION MUST BE SUBMITTED WITH THE INVOICE. Before me, the undersigned, a notary public this day personally appeared ATTACH PROOF OF PUBLICATION HERE. who, being first duly sworn, according to law, says that he/she is the of Published at in said division and state of and that the advertisement, of which the annexed is a true copy, was published in said publication on the day of 2008, and thereafter for consecutive days, the last publication appearing on the day of , 2008, 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 2008, Notary public for state of My commission expires !, STATE OF ALASKA ~ NOTICE TO PUBLISHER ~ ADVERTISING ORDER NO. ADVERTISING ORDER INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTIFIED AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COPY OF ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE A 0-02914004 /`1 SEE BOTTOM FOR INVOICE ADDRESS F R A~GCC 333 W 7th Ave, Ste 100 AGENCY CONTACT Jod Colombie DATE OF A.O. Jul 21 2008 ° M Anchorage, AK 99501 907-793-1238 PHONE PCN DATES ADVERTISEMENT REQUIRED: ASAP o Peninsula Clarion P.O. Box 3009 Kenai AK 9961 I ~ THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: Advertisement to be published was e-mailed Type of Advertisement Legal® ^ Display Classif ied ^Other (Specify) SEE ATTACHED SEND INVOICE IN TRIPLICATE TO AOGCC, 333 W. 7th Ave., Suite 100 Anchora e AK 99501 PAGE 1 OF 2 PAGES TOTAL OF ALL PAGES$ REF TYPE NUMBER AMOUNT DATE COMMENTS 1 VEN ~ A~ 02910 3 4 FIN AMOUNT SY CC PGM LC ACCT FY NMR DIST LID ~ 08 02140100 73451 2 3 4 QUISI I Y DIVISION APPROVAL: Notice of Public Hearing State of Alaska Alaska Oil and Gas Conservation Commission Re: Request for Depth Extension, Aquifer Exemption Order No. 6 Ivan River Unit, Well 14-31 Section 1, T13N, R9W, Seward Meridian, Westside Cook Inlet, Alaska Chevron North America Exploration and Production ("Chevron"), by letter dated July 15, 2008, has applied for a depth extension of the exempted aquifers of Ivan River Unit. Aquifer Exemption Order ("AEO") No.6 was issued by the Alaska Oil and Gas Conservation Commission (Commission) in accordance with 20 AAC 25.440 on July 23, 2001 fora '/2-mile radius around Well 14-31 and between the depths of 2500 and 3420 feet measured depth for the purpose of Class II underground injection. Chevron is planning a second Ivan River Unit disposal injection well within that %2-mile radius and with a deeper injection interval. Disposal injection from this second well requires additional permitting in addition to the requested extension of AEO No.6. Chevron's application may be reviewed at the offices of the Commission, 333 West 7th Avenue, Suite 100, Anchorage, Alaska, or a copy may be obtained by phoning the Commission at (907) 793-1221. The Commission has tentatively scheduled a public hearing on this application for September 4, 2008 at 9:00 am at the offices of the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. A person may request that the tentatively scheduled hearing be held by filing a written request with the Commission no later than 4:30 pm on August 15, 2008. If a request for a hearing is not timely filed, the Commission may consider the issuance of an order without a hearing. To learn if the Commission will hold the public hearing, please ca11793-1221 after August 22, 2008. In addition, a person may submit a written protest or written comments regarding this application and proposal to the Alaska Oil and Gas Conservation Commission at 333 West 7tn Avenue, Suite 100, Anchorage, Alaska 99501. Protests and comments must be received no later than 4:30 pm on August 28, 2008 except that if the Commission decides to hold a public hearing, protests or comments must be received no later than the conclusion of the September 4, 2008 hearing. If you are a person with a disability who may need special accommodations in order to comment or to attend the public hearing, please ntact the Commission's Special Assistant Jody Colombie at 793-1221. Daniel T. Seamount, Jr. Chair r ~ ~ PUBLISHER' S AFFIDAVIT UNITED STATES OF AMERICA, STATE OF ALASKA ss: Denise Reece being first duly sworn, on oath deposes and says: That I am and was at all times here in this affidavit mentions, Supervisor of Legals of the Peninsula Clarion, a news- paper of general circulation and published at Kenai, Alaska, that the Public Hearin AO-02914004 a printed copy of which is hereto annexed was published in said paper one each and every dad for one successive and consecutive day in the issues on the following dates: July 24, 2008 X ~.C/1.~, ~Q~~'1~ SUBSCRIBED AND SWORN to me before t 's 1st of Au ust 2008 NOTARY PUBLIC in favor for the State of Alaska. My Commission expires 26-Aug-08 ,•`P~~S Russ ~'t.16L\G /pm.._ OF _....~~~ ' Notion of PubNc Hearing Stag of Alaska I Alaska Oil and Gas Conservation Commission I Re: Request for Depth Extension, Aquifer' Exemption Order No. 6 ' Ivan River Unit, Well 14-31 ' Section i, T13N, R9W, Seward Meridian,' Westside Cook Inlet, Alaska ' Chevron North America , fxploration and' I Production ("Chevron"), by letter dated July 15, 2008,' has applied for a depth extension of the exempted aquifers of Ivan River Unitr Aquifer Exemption Order ' ("AEO") No.6 was issued by the Alaska Oil and Gas'. Conservation Commission (Commission): in 'accordance with 20 AAC 25.440 on July 23, 2001 for. a' 1/2 mile radius around Well 14-3t and between the depths of 2500-and 3420 feet measured depth for the purpose of Class ll underground injection. Chevron is' planning a second Ivan River Unit disposal. injection well within that 1/2 mile, radius and. wi#h a deepen ' injection interval -Disposal injection from this second 'well requires additional permitting'in addition to the requested extension of AEO No.6. Chevron's' application may be reviewed at the offices of the I Commission, .333 West 7th Avenue, Suite 100,' Anchorage, Alaska, or a copy may be obtained by (phoning the Commission at (907) 793-1221. The Commission has tentatively. scheduled a public hearing on this application for September 4, 2008 at 1 9:00. am at the :offices of the Alaska Oil and Gas 1 Conservation Commission-at 333,~Vest 7th Avenue, I Suite 100, Anchorage, Alaska 99501 A person may request that the tentatively scheduled hearing be'held' by filing a written requestwith the Commission no 'later than. 4:30 pm on August 15, 2008._ If a request for a hearing is not timely filed, the ' Commission may consider, the issuance of an order without a hearing. To Learn if the Commission will hold the public hearing, please call 793-1221 after August' 122, 2008. In addition, a person may submit a written protest' or written comments regarding this application .and proposal to the Alaska Oil and Gas Conservation Commission at 333 .West 7th Avenue, Suite 100, Anchorage, Alaska 99501. Protests and comments' must be received no later than 4:30 pm on August 28, ' 2008 except that if the Commission decides to hold a' public hearing, protests' or comments must be Yeceived no dater than the conclusion of the I. September 4, 2008 hearing.. If you.are a person with a disability who may need' 'special accommodations in order to comment or to' attend the .public hearing, please contact. the Commission's Special .Assistant Jody . Colombie at 793-1221, ' '.Daniel T. Seamount, Jr. ' ' Chair . `PUBUSH~l2i20~ ~ ~ ~ ~ ~7~P0~ ~ 02-902 (Rev. 3/94) Publisher~inal Copies: Department Fiscal, Departme~ceiving AO.FRM STATE OF ALASKA NOTICE TO PUBLISHER ADVERTISING ORDER NO. ADVERTISING INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTIFIED /~ 0-02914004 ORDER AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COPY OF F1 ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE SEE' BOTTOMfOR`INVOICE ADDRESS F AOGCC AGENCY CONTACT DATE OF A.O. R 333 West 7th Avenue. Suite 100 ° Anchorage. AK 995(11 PHONE PCN M 907-793-1238 - DATES ADVERTISEMENT REQUIRED: ASAP T PenlnSUla ClarlOn O PO Box 3009 K n i AK 99611 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN e a ~ ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: AFFIDAVIT OF PUBLICATION United states ofAmerica REMINDER State of ss INVOICE MUST BE IN TRIPLICATE AND MUST REFERENCE THE ADVERTISING ORDER NUMBER. division. A CERTIFIED COPY OF THIS AFFIDAVIT OF PUBLICATION MUST BE SUBMITTED WITH THE INVOICE. Before me, the undersigned, a notary public this day personally appeared ATTACH PROOF OF PUBLICATION HERE. who, being first duly sworn, according to law, says that he/she is the of Published at in said division and state of and that the advertisement, of which the annexed is a true copy, was published in said publication on the day of 2007, and thereafter for consecutive days, the last publication appearing on the day of , 2007, and that the rate charged thereon is not in excess of the rate charged private individuals. Subscribed and sworn to before me This _ day of 2007, Notary public for state of My commission expires Page 1 of 1 Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Monday, July 21, 2008 4:02 PM Subject: Public Notice Ivan River 14-31 Attachments: Ivan River 14-31.pdf BCC:'Dale Hoffman'; Fridiric Grenier; Joseph Longo; 'Lamont Frazer'; 'Mary Aschoff; Maurizio Grandi; 'Scott Nash'; Tom Gennings; 'Willem Vollenbrock'; 'Aleutians East Borough'; 'Anna Raff; Arion, Teri A (DNR); 'Arthur Copoulos'; 'Barbara F Fullmer'; 'bbritch'; 'Bill Walker'; 'Brad McKim'; 'Brandon Gagnon'; 'Brian Gillespie'; 'Brian Havelock'; 'Brit Lively'; 'Bruce Webb'; 'buonoje'; 'Cammy Taylor'; 'Cande.Brandow'; 'carol smyth'; 'Cary Carrigan'; caunderwood@marathonoil.com; 'Charles O'Donnell'; 'Chris Gay'; 'Christian Gou-Leonhardt'; 'Cliff Posey'; 'Dan Bross'; 'dapa'; 'Daryl J. Kleppin'; 'David Brown'; 'David Hall'; David House; 'David L Boelens'; 'David Steingreaber'; 'ddonkel'; 'Deborah J. Jones'; 'doug_schultze'; 'Eric Lidji '; 'Evan Harness'; 'eyancy'; 'foms2@mtaonline.net'; 'Francis S. Sommer'; 'Fred Steece'; 'Garland Robinson'; 'Gary Laughlin'; 'Gary Rogers'; 'Gary Schultz'; 'ghammons'; 'Gordon Pospisil'; Gould, Greg M (DEC); 'Gregg Nady'; 'gregory micallef ; 'gspfoff ; 'Hank Alford'; 'Harry Engel'; 'jah;'James Scherr'; 'Janet D. Platt'; 'jejones'; 'Jerry McCutcheon'; 'Jim Arlington'; 'Jim White'; 'Jim Winegarner'; 'Joe Nicks'; 'John Garing'; 'John S. Haworth'; 'John Spain'; 'John Tower'; 'John W Katz'; johnny.aiken@north-slope.org; 'Jon Goltz'; 'Julie Houle'; 'Kari Moriarty'; 'Kaynell Zeman'; 'Keith Wiles'; knelson@petroleumnews.com; 'Krissell Crandall'; 'Kristin Dirks'; 'Laura Silliphant'; 'Lois'; 'Lynnda Kahn'; 'mail=akpratts@acsalaska.net'; 'mail=fours@mtaonline.net'; 'Marilyn Crockett'; 'Mark Dalton'; 'Mark Hanley'; 'Mark Kovac'; 'Mark P. Worcester'; 'Marguerite kremer'; 'marty'r 'Matt Rader'; 'Meghan Powell'; Melanie Brown; 'Mike Bill'; 'Mike Mason'; 'Mikel Schultz'; 'Mindy Lewis'; 'MJ Loveland'; 'mjnelson'; 'mkm7200'; 'Nick W. Glover'; NSK Problem Well Supv; NSU, ADW Well Integrity Engineer; 'Patty Alfaro'; 'Paul Decker'; 'Paul Winslow'; Pierce, Sandra M (DNR); 'Randall Kanady'; 'Randy L. Skillern'; 'rcrotty'; Rice, Cody J (DNR); 'rmclean'; 'Rob McWhorter '; rob.g.dragnich@exxonmobil.com; 'Robert Campbell'; 'Robert Fowler'; 'Robert Province'; 'Roger Belman'; 'Rudy Brueggeman'; 'Scott Cranswick'; 'Shannon Donnelly'; 'Sharmaine Copeland'; 'Sondra Stewman'; 'Sonja Frankllin'; 'Stan Porhola'; 'stanekj'; 'Steve Lambert'; 'Steve Moothart'; 'Steven R. Rossberg'; 'tablerk'; 'Tamera Sheffield'; 'Temple Davidson'; 'Terrie Hubble'; 'Tim Lawlor'; 'Todd Durkee'; Tony Hopfinger; 'trmjrl'; 'Walter Featherly'; 'Walter Quay'; 'Wayne Rancier'; Birnbaum, Alan J (LAW); Crisp, John H (DOA); Davies, Stephen F (DOA); Fleckenstein, Robert J (DOA); Foerster, Catherine P (DOA); Grimaldi, Louis R (DOA); Johnson, Elaine M (DOA); Jones, Jeffery B (DOA); Laasch, Linda K (DOA); Mahnken, Christine R (DOA); Maunder, Thomas E (DOA); McIver, C (DOA); McMains, Stephen E (DOA); Noble, Robert C (DOA); Norman, John K (DOA); Okland, Howard D (DOA); Paladijczuk, Tracie L (DOA); Pasqual, Maria (DOA); Regg, James B (DOA); Roby, David S (DOA); Saltmarsh, Arthur C (DOA); Scheve, Charles M (DOA); Seamount, Dan T (DOA); Smith, Chasity R (DOA); Williamson, Mary J (DOA) Attachments:Ivan River 14-31.pdf; Jody Jaylene Colombie Special Assistant to the Commission Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 (907) 793-1221 Direct Line (907) 276-7542 Fax 7/21 /2008 • Mary Jones David McCaleb Cindi Walker XTO Energy, Inc. IHS Energy Group Tesoro Refining and Marketing Co. Cartography GEPS Supply & Distribution 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 300 Concord Plaza Drive Ft. Worth, TX 76102-6298 Houston, TX 77056 San Antonio, TX 78216 George Vaught, Jr. Jerry Hodgden Richard Neahring PO Box 13557 Hodgden Oil Company NRG Associates Denver, CO 80201-3557 408 18th Street President Golden, CO 80401-2433 PO Box 1655 Colorado Springs, CO 80901 John Levorsen Mark Wedman Baker Oil Tools 200 North 3rd Street, #1202 Halliburton 4730 Business Park Blvd., #44 Boise, ID 83702 6900 Arctic Blvd. Anchorage, AK 99503 Anchorage, AK 99502 Schlumberger Ciri Ivan Gillian Drilling and Measurements Land Department 9649 Musket Bell Cr.#5 2525 Gambell Street #400 PO Box 93330 Anchorage, AK 99507 Anchorage, AK 99503 Anchorage, AK 99503 Jill Schneider Gordon Severson Jack Hakkila US Geological Survey 3201 Westmar Cr. PO Box 190083 4200 University Dr. Anchorage, AK 99508-4336 Anchorage, AK 99519 Anchorage, AK 99508 Darwin Waldsmith James Gibbs Kenai National Wildlife Refuge PO Box 39309 PO Box 1597 Refuge Manager Ninilchick, AK 99639 Soldotna, AK 99669 PO Box 2139 Soldotna, AK 99669-2139 Penny Vadla Richard Wagner Cliff Burglin 399 West Riverview Avenue PO Box 60868 PO Box 70131 Soldotna, AK 99669-7714 Fairbanks, AK 99706 Fairbanks, AK 99707 Bernie Karl North Slope Borough Williams Thomas K&K Recycling Inc. PO Box 69 Arctic Slope Regional Corporation PO Box 58055 Barrow, AK 99723 Land Department Fairbanks, AK 99711 PO Box 129 Barrow, AK 99723 ~~ CI1@VI"O11 Sharon T. Sullivan Chevron North America HES Planning and Exploration and Production Permitting Specialist P.O. Box 196247 MidContinent/Alaska SBU Anchorage, AK 99519-6247 Tel 907 263 7839 Fax 907 263 7901 Cell 907 830 1821 Email SullivanS@Chevron.com ~- ~~~~ July 15, 2008 E"J~. ~ `~~' 2008 Daniel T. Seamount, Jr., Commissioner Alaska Oil and Gas Conservation Commission Ai` ~' ~ ',,~' ~ S~ ~ ~'~ ~'-, 333 West 7th Avenue; Suite 100. ~~oi ~~~~~:~ Anchorage, Alaska 99501 Re: REQUEST FOR DEPTH EXTENSION OF AQUIFER EXEMPTION ORDER NO. 6 IVAN RIVER UNIT WELL 14-31, SECTION 1, T13N, R9W, S.M. WESTSIDE COOK INLET, ALASKA Dear Mr. Seamount: The Alaska Oil and Gas Conservation Commission (AOGCC) issued Aquifer Exemption Order No. 6 to Union Oil Company of California (UOCC), a wholly-owned indirect subsidiary of Chevron Corporation, on July 23, 2001. This order currently exempts those portions of freshwater aquifers lying between 2,500 feet and 3,420 feet measured depth (MD) and within aone-half mile radius of UOCC's Ivan River Unit (IRU) Well 14-31 for the purposes of Class II underground injection activities. The one-half mile radius was granted to allow for the possible permitting of a second disposal well near the IRU Well 14-31 injection zone. UOCC respectfully requests that the AOGCC grant an extension of this freshwater aquifer exemption from 3,420 feet MD down to 6,195 feet MD. This would include the base of the injection zone of the planned second disposal well, IRU Well 13-31 which lies well within the'/ mile radius of the injection zone in well 14-31. The attached Table 1 shows the salinity values in sands within the proposed injection zone in IRU Well 13-31, which correlate with the lower portion of the requested exemption depth in IRU Well 14-31. Thank you for considering this request. An application for a Disposal Injection Order for IRU Well 13-31 will follow shortly. If you have any questions or require additional information, please contact me at 907.263.7839. Sincerely, Sharon T. Sullivan Planning and Permitting Specialist • ~ Table 1. Salinity Values within Proposed Injection Zone Sands in IRU Well 13-31 Sand Depth Porosity Rt Rwa TFM Salinity (Degree MD SSTVD (%) (Ohmm) (Ohmm) F) (ppm) 5,565 -4,235 24 2.96 0.1916 84 23,300 5, 695 -4, 318 27 3.86 0.4182 84 13, 800 5,730 -4,340 23 4.95 0.3651 84 16,000 5,845 -4,414 22 17.9 1.223 84 4,400 6,020 -4,526 25 15.7 1.453 86 3,600 6,150 -4,609 25 16.5 1.609 87 3,300