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Home My WebLink AboutSIO 010 INDEX STORAGE INJECTION ORDER NO. 10 1. February 9, 2010 Unocal Application for Injection Order for Gas Storage for Ivan River with attachments 2. February 16, 2010 Notice of Public Hearing, Affidavit of publication, e-mail Distribution list, Copy of bulk mailing List 3. February 25, 2010 E -mail correspondence AOGCC and Conoco re: Ivan River Application 4. March 1, 2010 E -mail correspondence with AOGCC and DNR re: Ivan River Public Notice 5. March 17, 2010 E -mail correspondence with AOGCC and Thor Cutler re: EPA regulations 6. March 19, 2010 DNR questions re: Ivan River Storage Order 7. --------------- - - - - -- DNR's question's submitted for hearing 8. March 23, 2010 Public Hearing record 9. March 23, 2010 E -mail correspondence re: Chevron's withdrawal of application for Ivan River Storage Order Storage Injection Order No. 10 ~ 9 Page 1 of 1 Aubert, Winton G (DOA) C From: Walsh, Chantal [Petrotechnical Resources of Alaska (PRA)] [WaIshCLdichevron.com] Sent: Tuesday, March 23, 2010 8:18 AM To: Aubert, Winton G (DOA) Cc: Wright, Stephen (SStNR}; Zager, John P; Whitacre, Dave S Subject: Withdrawal of Chevron application for Ivan River Storage Order Winton, Chevron has encountered a number of obstacles in progressing the Ivan River Gas Storage project. In trying to work through them we have run out of time to effectively implement this project. We respectfully ask the commission to withdraw our application for a Storage Order for Ivan River Gas Storage Sincerely, Chantal Walsh. Chantal Walsh PRA Petroleum Engineer, P.E. ~.y,~ , ~ ~.ti t~_ Anchorage, AK~ Chevron North America Exploration and Production Midcontinent/Alaska SBU 909 W. 9th Avenue Anchorage, AK 99501-3322 Tel 907 263 7627 Fax 1 907 263 7884 Mobile 907 227 0952 Mail Confidential Footer Privileged/Confidential information maybe contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy this message after notifying me immediately by replying to the message or contacting me at (907) 263- 7892. 3/23/2010 ~$ 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 • ALASKA OIL AND GAS CONSERVATION COMMISSION Before Commissioners: Daniel T. Seamount, Chair Cathy Foerster John K. Norman In the Matter of Union Oil Company) of California Requesting an order ) authorizing Underground Natural ) gas Storage in the undefined Gas ) Pool of the Ivan River Unit, well ) 1RU 44-36, in Conformance with ) 20 AAC 25.252 and 20 AAC 25.412 ) ALASKA OIL and GAS CONSERVATION COMMISSION Anchorage, Alaska March 23, 2010 9:00 o'clock a.m. VOLUME I PUBLIC HEARING BEFORE: Daniel T. Seamount, Chair Cathy Foerster, Commissioner John K. Norman, Commissioner R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 1 TABLE OF CONTENTS 2 Opening remarks by Chair Seamount 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 03 • ~ 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18' 19 20 21 22 23 24 25 P R O C E E D I N G S (On record - 9:00 a.m.) CHAIR SEAMOUNT: On the record. Good morning. Today is March 23rd, 2010. It's 9:00 o'clock in the morning. We're located at 333 West Seventh Avenue, Suite 100, Anchorage, Alaska. Those are the offices of the Alaska Oil & Gas Conservation Commission. I'm Dan Seamount, Chair of the Alaska Oil & Gas Conservation Commission. Also present are Commissioner Foerster and Commissioner Norman. We're on record at the time for the public hearing on Docket number SIO-10-02, the Application of Union Oil Company of California for an Order Authorizing Underground Natural Gas Storage in the Undefined Gas Pool of the Ivan River Unit Well 44-36. Notice of this hearing was published on February 12th, 2010 in the Anchorage Daily News as well as the State of Alaska online notices and the AOGCC website. However, today on March 23rd, 2010, the Commission received an e-mail from the applicant which I will read and then move that we put it into the record. This is from Chantel Walsh of Chevron -- oh, Petrotechnical Resources of Alaska working for Chevron. Is that correct, Mr. -- Dr. Aubert? DR. WINTON: (Nods in the affirmative) CHAIR SEAMOUNT: Okay. Subject: Withdrawal of Chevron Applicant, for Ivan River Storage Order. Winton. It was R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 3 1 addressed to Dr. Winton. Winton: Chevron has encountered a 2 number of obstacles in progressing the Ivan River Gas Storage 3 project. In trying to work through them we have run out of 4 time to effectively implement this project. We respectfully 5 ask the Commission to withdraw our application for a storage 6 order for the Ivan River gas storage. Sincerely, Chantel 7 Walsh. 8 And I move that we put this in the record. 9 COMMISSIONER NORMAN: No objection. 10 CHAIR SEAMOUNT: Any objections? Okay. This goes into 11 the record. As a result of this withdrawal the -- of the 12 application the public hearing is vacated. I'm sorry that you 13 all had to go to the effort to attend, get all dressed up and 14 show up, but you probably knew this was going to happen, so t 15 his matter is, therefore, adjourned. 16 (Recessed - 9:05 a.m.) 17 18 19 20 21 22 23' 24 25 R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 4 1 C E R T I F I C A T E 2 UNITED STATES OF AMERICA ) )ss. 3 STATE OF ALASKA ) 4 I, Rebecca Nelms, Notary Public in and for the State of Alaska, residing at Anchorage, Alaska, and Reporter for R & R 5 Court Reporters, Inc., do hereby certify: 6 THAT the annexed and foregoing Public Hearing held on March 23rd, 2010 was taken by Suzan Olson commencing at the 7 hour of 9:00 o'clock a.m, at the Alaska Oil and Gas Conservation Commission of Alaska in Anchorage, Alaska; 8 THAT this Public Hearing, as heretofore annexed, is a true 9 and correct transcription of the proceedings taken by Suzan Olson and transcribed by myself. 10 IN WITNESS WHEREOF, I have hereunto set my hand and 11 affixed my seal this 24th day of March 2010. 12 13 Notary Public in and for Alaska My Commission Expires:l0/10/10 14 15 16 17 18 19 20 21 22 23 24 25 R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 Page 1 of 1 1 I Aubert, Winton G (DOA) From: Walsh, Chantal [Petrotechnical Resources of Alaska (PRA)] [V1/a1shC@chevron.com] Sent: Tuesday, March 23, 2010 8:18 AM To: Aubert, Winton G (DOA) Cc: Wright, Stephen (SSWR); Zager, John P; Whitacre, Dave S Subject: Withdrawal of Chevron application for Ivan River Storage Order Winton, Chevron has encountered a number of obstacles in progressing the Ivan River Gas Storage project. In trying to work through them we have run out of time to effectively implement this project. We respectfully ask the commission to withdraw our application for a Storage Order for Ivan River Gas Storage Sincerely, Chantal Walsh. Chantal Walsh PRA Petroleum Engineer, P.E. ~~ n Anchorage, AK Chevron North America Exploration and Production Midcontinent/Alaska SBU 909 W. 9th Avenue Anchorage, AK 99501-3322 Tel 907 263 7627 Fax 1 907 263 7884 Mobile 907 227 0952 Mail Confidential Footer Privileged/Confidential information may be contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy this message after notifying me immediately by replying to the message or contacting me at (907) 263- 7892. 3/23/2010 • • STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Ivan River Unit, well IRU 44-36 Storage Injection Order March 23, 2010 at 9:00 am NAME ~~~tt~i 1~t nn ~ s AFFILIATION ~~~ ID~(z PHONE # ~-8~~ TESTIFY (Yes or No) /~ ~ w~a ~ ~~~~ DUGr ~~ ~ 77`~ ~'~ ~~~ ~ ~ ~~.. 1~0~~ Z~~ - ~a S ~ ~ ~7 r~ • DNR's Questions Submitted for Hearing SIO 9: Ivan River Unit 44-36 DNR Question Pa a Answer g 1. Does Union plan to perforate the 71-3 3, 5 Initially, IRU 44-36 will be used as the sole well sand in other wells? If so, which wells? for storage operations. Union may decide later to drill a new well or, redrill or workover an existing well to this same sand in the future to increase deliverability from the storage facility. 2. What well work is planned prior to Attach. Misc. Workover Notes: starting the storage operation? 8 1. Abandon lower zones with 20 bbls LXT cement squeezed below retainer. 2. Steps to abandon & isolate sands 58-4 & 59-6: a. Squeeze zones with LXT cmt b. Test squeeze to 1500 psi c. Run gravel pack completion across 71-3 sand d. Run upper SC-2A isolation packer and tubing 3. Run completion tubing with sliding sleeve 4. Circulate diesel as packer fluid and freeze protection. 3. How does Union plan to complete or re- 7 & The sand was produced commingled with two complete IRU 44-36 to avoid or prevent Prod underlying sands from 1993 to Jan 1996, when water production in the future? history water breakthrough occurred. Well was shut in until workover in latter 2001. Sand 71-3 was produced in isolation until May 2005, when reservoir pressure dropped to 615 psia and well wasn't able to flow into compressor station. Production stats for that period: 1.707 BCF, 459 bbls water over 680 producing days (an average of 2.5 MMCFD with 0.68 bbls water per day) 4. Maximum capacity of storage reservoir? 7 OGIP = 3.9 BCF; cumulative production = 3.1 BCF (79.5%) 5. Maximum amount of gas withdrawn is a Not given. given year? What is working volume of 9 Maximum injected gas will be 20 MMCFD. gas storage facility? 6. Cushion gas volume of storage facility? Not given. • DNR Question Pa a g Answer 7. What is the plan for monitoring 7, 8 Monitor daily injection rates and pressure and reservoir performance as it is being filled notify AOGCC next working day if and depleted? communication or leakage is suspected. Monitor material balance plot (P/Z vs Cum. Production). 8. Type and frequency of surveillance? 8 Rate and pressure data reported to AOGCC on monthly basis. Commission order will have a Rule specifying regular and annual reporting requirements. ~~6 • SEAN PARNELL, GOVERNOR D Q ~ ~ ~ DEPARTMENT OF NATURAL RESOURCES 550 WEST 7T" AVENUE, SUITE 1100 ANCHORAGE, ALASKA 99501-3560 DIVISION OF OIL & GAS PHONE: (907) 269-8800 FAX.• (907) 269-8938 March 19, 2010 Via Email & Hand Delivered Commissioner Daniel T. Seamount, Jr., Chair ~~~~~~~ Alaska Oil and Gas Conservation Commission 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501 MAR. I y Zfltfl ONB~~Co~a+'ssron Re: Underground Natural Gas Storage in the Ivan River Unit well IRU 44-36 qe Dear Commissioner Seamount; The Division of Oil and Gas (Division) has several questions regarding Union Oil Company of California's (Union) proposed underground natural gas storage in the Undefined Gas Pool of the Ivan River Unit, well IlZU 44-36. • Does Union plan to perforate the 71-3 sand in other wells? If so, which wells? • What well work is planned prior to starting the storage operation? • How does Union plan to complete or re-complete IRU 44-36 to avoid or prevent water production in the future? • What is the maximum capacity of the proposed storage reservoir? • What is the maximum amount of gas that can be withdrawn in a given year, or what is the working volume for the gas storage facility? • What is the volume of cushion gas required to operate the gas storage facility? • What is the plan for monitoring the reservoir performance as it is being filled and depleted? • What type of surveillance and frequency of measurements are anticipated? Thank you for the opportunity to ask questions, and we look forward to attending the hearing on Tuesday March 23, 2010. Sincerely, G~-~ Wendy olf Petroleum Land Manager cc: Kevin Banks, DNR Cammy Taylor, DNR Alan Dennis, DNR Ivan River Gas Storage Team "Develop, Conserve, and Enhance Natural Resources for Present and Future Alaskans. " • • Colombie, Jody J (DOA) From: Woolf, Wendy C (DNR) Sent: Friday, March 19, 2010 11:23 AM To: Colombie, Jody J (DOA) Cc: Banks, Kevin R (DNR); Taylor, Cammy O (DNR); Dennis, Alan R (DNR); Silliphant, Laura J (DNR); Helmold, Kenneth P (DNR); Anderson, Paul C (DNR); Peterson, Shaun (DNR); Houle, Julie (DNR); Kevin Tabler Subject: Public Hearing Comments -Ivan River Unit well IRU 44-36 Attachments: 20100319 IRU Underground Natural Gas Storage Well IRU 44-36.pdf Jody, Attached are the Dept. of Natural Resources, Division of Oil and Gas comments for the upcoming hearing on Union Oil Company of California's application for underground natural gas storage in the Undefined Gas Pool of the Ivan River Unit, well IRU 44-36. Regards, Wendy Woolf Petroleum Land Manager ADNR, Division of Oil & Gas, Units Section Voice: (907) 269-8779 Fax: (907) 269-6587 Email: wendy.woolf@alaska.gov • • Colombie, Jody J (DOA From: ferry mccutcheon [susitnahydronow@yahoo.com] Sent: Tuesday, March 02, 2010 1:36 PM To: Colombie, Jody J (DOA) Subject: Re: Public Notice Ivan River Unit Well 44-36 SIO To the AOGCC, Alaska Oil and Gas Conservation Commission, March 2, 2010 This is an objection to the consideration of gas storage in the undefined Gas Pool of the Ivan River unit, well IRU 44- 36. There has been no showing of the need for a Cook Inlet Gas storage facility. There has been no showing that a gas storage facility is in the public interest when in fact gas storage is not. The AOGCC would foist on the Cook Inlet gas consumers an unnecessary gas storage scam if the permit were granted. The gas storage permit by a State agency which is responsible for the oversight of the production of Cook Inlet oil and gas would lead the public to believe that gas storage was in the public interest when in fact gas storage is not in the public interest. Allowing gas storage would be to compound the continued the fleecing of the Cook Inlet gas consumers by Conoco/ Marathon/ Chevron /Enstar. As former Governor Murkowski's Attorney General pointed out the charges for Cook Inlet gas were and are "excessive", "unjustified" and "unwarranted". Those problems have not been addressed and remain unresolved. The AOGCC, through the years, has not acted in the public interest. The AOGCC has acted contrary to the requirements of Alaska's Constitution. The AOGCC has acted as hand maiden of and rubber stamp to the major Cook Inlet producers. The AOGCC by allowing the Cook Inlet producers to sell off and flare the associated gas as the gas was produced with the oil, it rendered one or more barrels of oil unrecoverable for every barrel produced. More than billion barrels of oil has been rendered unrecoverable because the AOGCC failed to carry out the AOGCC's statutory and Constitutional responsibilities. Now the AOGCC is poised to allow another fraud to be perpetrated on Alaskans by permitting Union Oil (Chevron) to develop and foist on the Cook Inlet gas consumer, a gas storage facility with all of its attendant excessive costs, which the Cook Inlet gas Consumer will have to unnecessarily bear. The AOGCC knows that the solution to reservoir pressure problems is infill and horizontal drilling. The AOGCC also knows that infill and horizontal drilling will be required in the long term. The AOGCC has chosen to remain silent in furtherance of previous `no gas' scam ,which became `not enough gas pressure' scam and this new scam the Cook Inlet gas storage scam to solve the lack of pressure scam. The AOGCC was and is well aware that there is ample gas, 7 tcf to 13 tcf, in Cook Inlet, much of the gas is under lease and is required to be developed under Alaska's Constitution which has not been enforced. Within the last month a legislator ask the AOGCC Chairman Seamount, during a legislative committee hearing if the AOGCC had done any studies on North Slope and Prudhoe Bay gas availability , Seamount responded in the negative. That was not truthful response. The AOGCC in fact hired an unlicensed reservoir engineer, who with the AOGCC's Kathy Foerster, another unlicensed reservoir engineer, who holds the Commissions' reservoir engineer's position ,spent hundreds of thousands of dollars falsifying Prudhoe Bay reservoir production simulations trying to show that Prudhoe Bay gas would be available before Prudhoe Bay's gas would actually be available without the loss of billions of barrels of oil. They got caught. AOGCC Chairman Seamount~d to the legislator and the legislative c~imittee and covered up for them and the fact that hundreds of thousands of dollars of State funds were fraudulently spent in furtherance of a gas scam. Was Chairman Seamount aware of the fact that the results Prudhoe Bay reservoir production simulation were being falsified? Chairman Seamount certainly knew that were Prudhoe Bay reservoir production simulations because Seamount was there when the Prudhoe Bay production simulations were presented, with great fanfare, to the AOGCC and the public, then abruptly withdrawn and made confidential to keep from disclosing the fraud. Jerry McCutcheon susitnahydronow@yahoo.com Draft 03/02/10 Cc. FBI --- On Fri, 2/12/10, Colombie, Jody J (DOA) <jody.colombie@alaska.gov> wrote: From: Colombie, Jody J (DOA) <jody.colombie@alaska.gov> Subject: Public Notice Ivan River Unit We1144-36 SIO To: "Aaron Gluzman" <aaron.gluzman@gmaiLcom>, caunderwood@marathonoil.com, "Dale Hoffman" <dale.hoffman@pxd.com>, "Frederic Grenier" <mastiq@sympatico.ca>, "Gary Orr" <ORRGA@chevron.com>, "Jerome Eggemeyer" <jerome.c.eggemeyer@conocophillips.com>, "Joe Longo" <joe.longo@enipetroleum.com>, "Lamont Frazer" <Lamont.C.Frazer@conocophillips.com>, "Marc Kuck" <Marc.kuck@enipetroleum.com>, "Mary Aschoff' <Mary.M.Aschoff@conocophillips.com>, "Maurizio Grandi" <maurizio.grandi@enipetroleum.com>, "Ostrovsky, Larry Z (DNR)" <larry.ostrovsky@alaska.gov>, "P Bates" <pbates@ciri.com>, "Richard Garrard" <rgarrard@talisman-energy.com>, "Sandra Lemke" <Sandra.D.Lemke@conocophillips.com>, "Scott Nash" <snas@chevron.com>, "Talib Syed" <talibs@ecentral.com>, "Tiffany Stebbins" <tastebbins@marathonoil.com>, "Wayne Wooster" <wwooster@asrcenergy.com>, "Willem Vollenbrock" <WVOLLEN@kockw.com>, "William Van Dyke" <bvandyke@petroak.com>, "Woolf, Wendy C (DNR)" <wendy.woolf@alaska.gov>, foms2@mtaonline.net, michael.j.nelson@conocophillips.com, Von.L.Hutchins@conocophillips.com, alaska@petrocalc.com, "Anna Raff' <anna.raff@dowjones.com>, "Barbara F Fullmer" <barbara.£fullmer@conocophillips.com>, "bbritch" <bbritch@alaska.net>, "Becky Bohrer" <bbohrer@ap.org>, "Bill Walker" <bill-wwa@ak.net>, "Bowen Roberts" <Bowen.E.Roberts@conocophillips.com>, "Brad McKim" <mckimbs@BP.com>, "Brady, Jerry L" <Jerry.Brady@bp.com>, "Brandon Gagnon" <bgagnon@brenalaw.com>, "Brandow, Cande (ASRC Energy Services)" <Cande.Brandow@bp.com>, "Brian Gillespie" <ifbmg@uaa.alaska.edu>, "Brian Havelock" <brian.havelock@alaska.gov>, "Bruce Webb" <bwebb@aurorapower.com>, "carol Smyth" <carol.smyth@shell.com>, "Charles O'Donnell" <charles.o'donnell@veco.com>, "Chris Gay" <CGay@ciri.com>, "Cliff Posey" <cliff@posey.org>, "Crandall, Krissell" <Krissell.Crandall@bp.com>, "Dan Bross" <kuacnews@kuac.org>, "dapa" <dapa@alaska.net>, "Daryl J. Kleppin" <KleppiDE@BP.com>, "David Boelens" <dboelens@aurorapower.com>, "David House" <dhouse@usgs.gov>, "David Steingreaber" <david.e.steingreaber@exxonmobil.com>, ddonkel@cfl.rr.com, "Deborah J. Jones" <JonesD6@BP.com>, "doug_schultze" <doug_schultze@xtoenergy.com>, "Elowe, Kristin" <Kristin.Elowe@mms.gov>, "Evan Harness" <eharness@chevron.com>, "eyancy" <eyancy@seal- tite.net>, "Francis S. Sommer" <SommerFS@BP.com>, "Fred Steece" <fred.steece@state.sd.us>, "Garland Robinson" <gbrobinson@marathonoil.com>, "Gary Laughlin" <galaughlin@marathonoil.com>, "Gary Rogers" <gary.rogers@alaska.gov>, "Gary Schultz" <gary.schultz@alaska.gov>, "ghammons" <ghammons@aol.com>, "Gordon Pospisil" <PospisG@BP.com>, "Gorney, David L." <dgorney@marathonoil.com>, "Gregg Nady" <gregg.nady@shell.com>, "gspfoff' <gspfoff@aurorapower.com>, "Hank Alford" <hank.alford@exxonmobil.com>, "Harry Engel" <engelhr@bp.com>, jarlington@gmaiLcom, "Jeff Jones" <jef£jones@alaskajournal.com>, jef£jones@alaska.gov, "Jerry McCutcheon" <susitnahydronow@yahoo.com>, "Jim White" <jimwhite@satx.rr.com>, "Jim Winegarner" <jwinegarner@brpcak.com>, "Joe Nicks" <news@radiokenai.com>, "John Garing" <garingJD@bp.com>, "John S. Haworth" <john.s.haworth@exxonmobil.com>, "John Spain" <jps@stateside.com>, "John Tower" <John.Tower@eia.doe.gov>, "John W Katz" <jwkatz@alaskadc.org>, "Jon Goltz" <Jon.Goltz@conocophillips.com>, "Joseph Darrigo" <jd@nativeamericanenergy.com>, "Julie Houle" <julie.houle(a),alaska.gov>, "Kari Mor~y" <moriarty(c~aoga.org>, "Kaynell Zeeman" <kjzeman@marathonoil.com>, "Keith Wiles" <kwiles@marathonoil.com>, "Larry Ostrovsky" <larry.ostrovsky@alaska.gov>, "Laura Silliphant" <laura.silliphant@alaska.gov>, "Marilyn Crockett" <crockett@aoga.org>, "Mark Dalton" <mark.dalton@hdrinc.com>, mark.hanley@anadarko.com, "Mark Kovac" <yesnol@gci.net>, "Mark P. Worcester" <mark.p.worcester@conocophillips.com>, "Marquerite kremer" <meg.kremer@alaska.gov>, "Michael Jacobs" <Michael.W.Jacobs@conocophillips.com>, "Mike Bill" <Michael.Bill@bp.com>, "Mike Mason" <mike@kbbi.org>, "Mikel Schultz" <Mikel.Schultz@BP.com>, "Mindy Lewis" <mlewis@brenalaw.com>, "MJ Loveland" <N1878@conocophillips.com>, "mjnelson" <mjnelson@purvingertz.com>, "mkm7200" <mkm7200@aol.com>, "nelson" <knelson@petroleumnews.com>, "Nick W. Glover" <GloverNW@BP.com>, "NSK Problem Well Supv" <n1617@conocophillips.com>, "Patty Alfaro" <palfaro@yahoo.com>, paul.decker@alaska.gov, "PORHOLA, STAN T" <stan.porhola@chevron.com>, "Rader, Matthew W (DNR)" <matt.rader@alaska.gov>, "Raj Nanvaan" <raj@nativeamericanenergy.com>, "Randall Kanady" <Randall.B.Kanady@conocophillips.com>, "Randy L. Skillern" <Ski11eRL@BP.com>, "Rob McWhorter" <rnmassociates@gci.net>, rob.g.dragnich@exxonmobil.com, raprovince@marathonoil.com, "Robert Campbell" <Robert.Campbell@reuters.com>, "Roberts, Susan M." <smroberts@marathonoil.com>, "Rudy Brueggeman" <rudy.brueggemann@international.gc.ca>, "Scott Cranswick" <scott.cranswick@mms.gov>, "Shannon Donnelly" <shannon.donnelly@conocophillips.com>, "Sharmaine Copeland" <copelasv@bp.com>, "Shellenbaum, Diane P (DNR)" <diane.shellenbaum@alaska.gov>, "Slemons, Jonne D (DNR)" <jonne.slemons@alaska.gov>, "Sondra Stewman" <StewmaSD@BP.com>, "Steve Lambert" <salambert@unocal.com>, "Steve Moothart" <steve.moothart@alaska.gov>, "Steven R. Rossberg" <RossbeRS@BP.com>, "Suzanne Gibson" <sgibson@ciri.com>, "tablerk" <tablerk@unocal.com>, "Tamera Sheffield" <sheffield@aoga.org>, "Taylor, Cammy O (DNR)" <cammy.taylor@alaska.gov>, "Ted Rockwell" <rockwell.theodore@epa.gov>, "Temple Davidson" <temple.davidson@alaska.gov>, "Teresa Imm" <timm@asrc.com>, "Terrie Hubble" <hubbletl@bp.com>, "Thor Cutler" <Cutler.Thor@epamail.epa.gov>, "Todd Durkee" <todd.durkee@anadarko.com>, "Tony Hopfinger" <thopfinger@gci.net>, "trmjrl" <trmjrl@aol.com>, "Walter Featherly" <WFeatherly@PattonBoggs.com>, "Williamson, Mary J (DNR)" <jane.williamson@alaska.gov>, "Winslow, Paul M" <PWinslow@chevron.com>, "Aubert, Winton G (DOA)" <winton.aubert@alaska.gov>, "Ballantine, Tab A (LAW)" <tab.ballantine@alaska.gov>, "Brooks, Phoebe" <phoebe.brooks@alaska.gov>, "Crisp, John H (DOA)" <john.crisp@alaska.gov>, "Darlene Ramirez" <darlene.ramirez@alaska.gov>, "Davies, Stephen F (DOA)" <steve.davies@alaska.gov>, "Foerster, Catherine P (DOA)" <cathy.foerster@alaska.gov>, "Grimaldi, Louis R (DOA)" <lou.grimaldi@alaska.gov>, "Johnson, Elaine M (DOA)" <elaine.johnson@alaska.gov>, "Jones, Jeffery B (DOA)" <jef£jones@alaska.gov>, "Laasch, Linda K (DOA)" <linda.laasch@alaska.gov>, "Mahnken, Christine R (DOA)" <christine.mahnken@alaska.gov>, "Maunder, Thomas E (DOA)" <tom.maunder@alaska.gov>, "McIver, Bren (DOA)" <bren.mciver@alaska.gov>, "McMains, Stephen E (DOA)" <steve.mcmains@alaska.gov>, "Noble, Robert C (DOA)" <bob.noble@alaska.gov>, "Norman, John K (DOA)" <john.norman@alaska.gov>, "Okland, Howard D (DOA)" <howard.okland@alaska.gov>, "Paladijczuk, Tracie L (DOA)" <tracie.paladijczuk@alaska.gov>, "Pasqual, Maria (DOA)" <maria.pasqual@alaska.gov>, "Regg, James B (DOA)" <jim.regg@alaska.gov>, "Roby, David S (DOA)" <dave.roby@alaska.gov>, "Saltmarsh, Arthur C (DOA)" <art.saltmarsh@alaska.gov>, "Scheve, Charles M (DOA)" <chuck.scheve@alaska.gov>, "Schwartz, Guy L (DOA)" <guy.schwartz@alaska.gov>, "Seamount, Dan T (DOA)" <dan.seamount@alaska.gov> Date: Friday, February 12, 2010, 3:59 PM Jody J. Colornbie Special Assistant .Alaska Oil and Gas Conservation Co~mnission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 (907)793-1221 (phone) • (907)276-7542 (fax) m ., • Colombie, Jody J (DOA) From: Aubert, Winton G (DOA) Sent: Wednesday, March 17, 2010 2:24 PM To: Colombie, Jody J (DOA) Subject: FW: Gas storage purposes is exempt from UIC regulation pursuant to 40 CFR 144.1(g)(2)(iv) -----Original Message----- From: Regg, James B (DOA) Sent: Wednesday, March 17, 2010 9:00 AM To: Aubert, Winton G (DOA); Maunder, Thomas E (DOA); (DOA); Norman, John K (DOA); Ballantine, Tab A (LAW) Subject: FW: Gas storage purposes is exempt from UIC Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 Foerster, Catherine P (DOA); Seamount, Dan T regulation pursuant to 40 CFR 144.1(g)(2)(iv) -----Original Message----- From: Cutler.Thor@epamail.epa.gov [mailto:Cutler.Thor@epamail.epa.gov] Sent: Wednesday, March 17, 2010 8:03 AM To: Regg, James B (DOA) Cc: Thor Cutler; Contreras.peter@epa.gov Subject: Gas storage purposes is exempt from UIC regulation pursuant to 40 CFR 144.1(g)(2)(iv) ]ames Regg, Last week, you asked about gas storage wells and the role of Federal aquifer exemptions. I hope I answered your question and I defer to you regarding any state regulations, that said... Short answer, no, the state does not need an aquifer exemption from the UIC program as injection of natural gas for purposes of storage is clearly exempted from UIC program regulation but if the state is going to use their own process to exempt the aquifer to allow for storage, it would be nice if the state shared the information with the EPA Region-10 prior to issuing the exemption. However, the state is not obligated to do this. EPA regulations that discuss aquifer exemptions include but not limited to 40 CFR 144.7, 40 CFR 144.12 and 40 CFR 146.4. See 40 CFR 144.1(g) (2) (iv) regarding gas storage. This matter was not articulated in the preamble to the UIC framework regulation in the 1980s. Aquifer exemptions are usually associated with permits. Specifically, if the gas being stored is a gas at standard temp. and pressure and is of "pipeline quality", then yes the injection of the gas for storage purposes is exempt from UIC regulation pursuant to 40 CFR 144.1(g)(2)(iv). This is the key specific regulation, in my review. A lawyer may always have another view. 1 • • The purpose of aquifer exemptions is to allow injection that would otherwise violate 40 CFR 144.12 into an injection zone that meets the definition of an underground source of drinking water. Since the injection activity (pursuant to 40 CFR 144.1(g)(2)(iv)) is beyond the scope of the UIC program, there appears to be no need or requirement pursuant to Federal UIC regulations to exempt the injection zone for gas storage purposes. That having been said, what the state does, or is required to do, is dependent on the state program(s) and state regulations. Most primacy states incorporated their UIC programs into their existing NPDES ground water protection programs (as you know, the NPDES program is in the process of being delegated to Alaska, which may take years) so the state jurisdiction and requirements for ground water protection may (are likely to) extend beyond just UIC. So it's possible that your state may have extended their regulatory aquifer exemption requirements, or some similar ground water protection requirements, beyond just UIC-regulated activities. Therefore the state may have some sort of requirements for injecting gas (Based on our past discussions over the years, I am sure you are familiar with them), or any contaminant, into a zone that meets the definition of a "waters of the state" and also has the potential to serve as a drinking water source (assuming the prospective zone has that potential to serve as a USDW). So long as the state meets their regulatory requirements in making your permitting decision, establishing appropriate permit restrictions, etc., the state is not required to comply with the Federal UIC aquifer exemption criteria or process (unless the state regulations require the state to do so for gas storage facilities. I am not aware of such requirements in state regulations in Alaska). The EPA would not have to concur for an aquifer exemption for underground injection that is not within the scope of the applicable State UIC program. If the state were to exempt an aquifer for gas storage operations, the exempted zone (as EPA would apply it) would be limited to an area associated with the injection zone. If a gas storage well is drilled through the USDW, it does not mean the gas storage operation may contaminate the USDW. It should still be protected by state regulations. I hope this is helpful. Please call if I can be of further assistance. Sincerely, Thor Cutler 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 z ~t Colombie, Jody J (DOA) From: Woolf, Wendy C (DNR) Sent: Monday, March 01, 2010 4:26 PM To: Colombie, Jody J (DOA) Cc: Taylor, Cammy O (DNR); Dennis, Alan R (DNR); Davidson, Temple (DNR); Ostrovsky, Larry Z (DNR) Subject: RE: Public Notice Ivan River Unit Well 44-36 SIO '1 he DNR, Division of Oil. anti Gas requests the AOGCC schedule a hearing nn Union. Oil Company of California"s application fc~r underground natural gas storage in the Undefined Gas Pool of the Ivan River Unit, ~~~el] IR1J 44-36. Thank you. Regards, G1 enc~v YT'oolf Petroleum Land Manager ADNR, Division of Oil & Gas, Units Section Voice: (907} 269-8779 Fax: (907) 269-6587 Email: wendy.woolf@alaska.gov From: Colombie, Jody J (DOA) Sent: Friday, February 12, 2010 3:59 PM To: Subject: Public Notice Ivan River Unit Well 44-36 SIO .todv J. Colombie Special Assistant Alc~aska Oil and Uas Consen~ation Commission 333 West 7th Avenue. Suite 100 Ancho~•age, AK 99501 (907)793-1221 (phone) (97)276-7542 (fax) ~3 • • Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Thursday, February 25, 2010 11:05 AM To: 'Hutchins, Von L' Subject: RE: Ivan River Underground Gas Storage Application Attachments: S45C-210022510590. pdf Von- As I indicated Attachment C not includes (too large). From: Hutchins, Von L [mailto:Von.L.Hutchins@conocophillips.com] Sent: Thursday, February 25, 2010 10:37 AM To: Colombie, Jody J (DOA) Subject: Ivan River Underground Gas Storage Application Importance: High Jody, Please send to me electronically the submitted information that you have on the above referenced application (except for the map which is too large to scan). Thank you, Von L. 3futchins Director of Gas Supply and Marketing Cook Inlet Gas Assets ConocoPhillips Alaska, Inc. 700 G. St. Anchorage, AK 99510 (907) 265-1605 (w) (907) 632-7476 (c) (918) 662-6889 (fax) ~2 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 /~ 0_03014023 I"~ SEE BOTTOM FOR INVOICE ADDRESS F R A~GCC Ste 100 333 W 7th Ave AGENCY CONTACT Jod Colombie DATE OF A.O. February 12, 2010 ° M , Anchorage, AK 99501 907-793-1238 PHONE - PCN DATES ADVERTISEMENT REQUIRED: o Anchorage Daily News PO Box 149001 Arichora e AK 99514 g , February 16, 2010 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 i OF 2 PAGES TOTAL OF ALL PAGES$ REF TYPE NUMBER AMOUNT DATE COMMENTS 7 VEN z AR1~ 02910 FIN AMOUNT SY CC PGM LC ACCT FY NMR DIST LIQ ~ 10 02140100 73451 2 REQUISITIONED BY: DIVISION APPROVAL: U 02-902 (Rev. 3/94) Publisher/Original Copies: Department Fiscal, Department, Receiving AO.FRM ~ • Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: The application of Union Oil Company of California for an order authorizing underground natural gas storage in the Undefined Gas Pool of the Ivan River Unit, well IRU 44-36, in conformance with 20 AAC 25.252 and 20 AAC 25.412. Surface location: 742' FSL, 777' FEL, S1 T13N, R9W SM. Bottom hole location: 298' FSL, 932' FEL, S36 T14N, R9W SM. The Commission has tentatively scheduled a public hearing on this matter for March 23, 2010 at 9:00 am. To request that the hearing be held, a written request must be filed by 4:30 p.m. on March 8, 2010. If a request is not timely filed, the Commission may consider the issuance of an order without a hearing. To learn if the Commission will hold a hearing, call 907-793-1221 after March 18, 2010. Written comments regarding the application may be submitted to the Commission, at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. Comments must be received no later than 4:30 p.m. on March 19, 2010, except that, if a hearing is held, comments must be received no later than the conclusion of the hearing. If, because of a disability, special accommodations may be needed to comment or attend the hearing, ca11907-793-1221 by March 15, 2010. Daniel T. Seamount, Jr. Chair • ;ali/zolo Anchorage Daily News Affidavit of Publication 1001 Northway Drive, Anchorage, AK 99508 PRICE OTHER OTHER OTHER GRAND AD # DATE PO ACCOUNT PER DAY CHARGES CHARGES #2 CHARGES #3 TOTAL 739541 02/16/2010 AO-03014 STOF0330 $146.08 $146.08 $0.00 $0.00 $0.00 $146.08 STATE OF ALASKA THIRD JUDICIAL DISTRICT Shane Drew, being first duly sworn on oath deposes and says that he 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 o£ 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 ~ o Subscribed and sworn to me before this date: c v ~ v Notary Public in and for the State of Alaska. Third Division. Anchorage, Alaska MY COMMISSION EXPIRES: ~ `~`ttclfr~r~(r~i `~y~~tPtA q. ~~ ... ^~ ~JJJffI~ 1)l)1)l~l~`1 ~.~~.~. Notice of Pu6Nc Bearing STA1B OP ALASKA Alaeka 0iI end Gas Coneervatton aa• rnw anollcation of~Union Oii'COmpany lof 20 AAC25252'and 20 AAC 25.412 Surface location: 742' FSL, 777' FEL, S1 T13N, R9W SM. Bottom hole location: 298' FSL, 932' FEL, S36 T141d, R9W SM. , The Commission has tentatively scheduled a putoiic hearing on this matter for March 23, 2010 at 9;04 am. To request that the hearing be held, a written request must be filed by 4:~ P•m. on March 8, 2010: If a request is not tameiq tiled tfte corrallissron may hold a heanrtg, can'. 10. - --..... conclusion of the hearing. ff, because ~ a disability, special accommodations ma be needed to comment or attend d1e hearing, calf 907-793-7221 by March 15, 2010: Daniel T. Seamount, N'.: Chair AO-030'44023' Pubiistled: February 16, 2010 • • STATE OF ALASKA ADVERTISING ORDER SEE BOTTOM FOR INVOICE A NOTICE TO PUBLISHER I ADVERTISING ORDER NO. INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTIFIED /~ 0_03014023 AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COPY OF /1 ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE F AOGCC R 333 West 7th Avenue. Suite 100 Anch~rage_ AK 99501 M 907-793-1238 o Anchorage Daily News PO Box 149001 Anchorage, AK 99514 AGENCY CONTACT ~ DATE OF A.O. PHONE IPCN 1 7\/ / 1 / 7J ~ 1 LL 1 DATES ADVERTISEMENT REQUIRED: February 16, 2010 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: Account # STOF0330 United states of America State of AFFIDAVIT OF PUBLICATION REMINDER 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 2010, and thereafter for consecutive days, the last publication appearing on the day of , 2010, 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 2010, Notary public for state of My commission expires _ • • Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Friday, February 12, 2010 3:59 PM To: 'Aaron Gluzman'; caunderwood@marathonoil.com; 'Dale Hoffman'; Frederic Grenier; 'Gary Orr'; Jerome Eggemeyer; 'Joe Longo'; 'Lamont Frazer'; Marc Kuck; 'Mary Aschoff; Maurizio Grandi; Ostrovsky, Larry Z (DNR); P Bates; Richard Garrard; 'Sandra Lemke'; 'Scott Nash'; Talib Syed; 'Tiffany Stebbins'; 'Wayne Wooster'; 'Willem Vollenbrock'; 'William Van Dyke'; Woolf, Wendy C (DNR); (foms2@mtaonline.net); (michael.j.nelson@conocophillips.com); (Von.L.Hutchins@conocophillips.com); alaska@petrocalc.com; Anna Raff; Barbara F Fullmer; bbritch; Becky Bohrer; Bill Walker; Bowen Roberts; Brad McKim; Brady, Jerry L; Brandon Gagnon; Brandow, Cande (ASRC Energy Services); Brian Gillespie; Brian Havelock; Bruce Webb; carol smyth; Charles O'Donnell; Chris Gay; Cliff Posey; Crandall, Krissell; Dan Bross; dapa; Daryl J. Kleppin; David Boelens; David House; David Steingreaber; 'ddonkel@cfl.rr.com'; Deborah J. Jones; doug_schultze; Elowe, Kristin; Evan Harness; eyancy; Francis S. Sommer; Fred Steece; Garland Robinson; Gary Laughlin; Gary Rogers; Gary Schultz; ghammons; Gordon Pospisil; Gorney, David L.; Gregg Nady; gspfoff; Hank Alford; Harry Engel; Jdarlington Qarlington@gmail.com); Jeff Jones; Jeffery B. Jones Qeff.jones@alaska.gov); Jerry McCutcheon; Jim White; Jim Winegarner; Joe Nicks; John Garing; John S. Haworth; John Spain; John Tower; John W Katz; Jon Goltz; Joseph Darrigo; Julie Houle; Kari Moriarty; Kaynell Zeman; Keith Wiles; Larry Ostrovsky; Laura Silliphant; Marilyn Crockett; Mark Dalton; Mark Hanley (mark.hanley@anadarko.com); Mark Kovac; Mark P. Worcester; Marguerite kremer; Michael Jacobs; Mike Bill; Mike Mason; Mikel Schultz; Mindy Lewis; MJ Loveland; mjnelson; mkm7200; nelson; Nick W. Glover; NSK Problem Well Supv; Patty Alfaro; Paul Decker (paul.decker@alaska.gov); PORHOLA, STAN T; Rader, Matthew W (DNR); Raj Nanvaan; Randall Kanady; Randy L. Skillern; Rob McWhorter; rob.g.dragnich@exxonmobil.com; Robert A. Province (raprovince@marathonoil.com); Robert Campbell; Roberts, Susan M.; Rudy Brueggeman; Scott Cranswick; Shannon Donnelly; Sharmaine Copeland; Shellenbaum, Diane P (DNR); Slemons, Jonne D (DNR); Sondra Stewman; Steve Lambert; Steve Moothart; Steven R. Rossberg; Suzanne Gibson; tablerk; Tamera Sheffield; Taylor, Cammy O (DNR); Ted Rockwell; Temple Davidson; Teresa Imm; Terrie Hubble; Thor Cutler; Todd Durkee; Tony Hopfinger; trmjr1; Walter Featherly; Williamson, Mary J (DNR); Winslow, Paul M; Aubert, Winton G (DOA); Ballantine, Tab A (LAW); Brooks, Phoebe; Crisp, John H (DOA); Darlene Ramirez; Davies, Stephen F (DOA); Foerster, Catherine P (DOA); Grimaldi, Louis R (DOA); Johnson, Elaine M (DOA); Jones, Jeffery B (DOA); Laasch, Linda K (DOA); Mahnken, Christine R (DOA); Maunder, Thomas E (DOA); McIver, Bren (DOA); McMains, Stephen E (DOA); Noble, Robert C (DOA); Norman, John K (DOA); Okland, Howard D (DOA); Paladijczuk, Tracie L (DOA); Pasqual, Maria (DOA); Regg, James B (DOA); Roby, David S (DOA); Saltmarsh, Arthur C (DOA); Scheve, Charles M (DOA); Schwartz, Guy L (DOA); Seamount, Dan T (DOA) Subject: Public Notice Ivan River Unit Well 44-36 SIO Attachments: Ivan River Unit 44-36Public Notice.pdf Jody J. Colombie Spectral Assistant Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ('907)793-1221 (phone) (907)276-7542 (fax) 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 ~ ~~,,, ~ ~~~ J PO Box 69 //! Barrow, AK 99723 /~ I q ~ ~, r~~~~ ~, ,/` I ~, ~p ~n ~(~ ~~ • Chevron February 09, 2010 Ms. Cathy Foerster Mr. Dan Seamount Mr. John Norman Alaska Oil and Gas Conservation Commission 333 W. 7t" Avenue, Suite 100 Anchorage, AK 99501-3539 Re: APPLICATION FOR STORAGE ORDER FOR IVAN RIVER GAS STORAGE FACILITY Dear Commissioners: RECEIVED ~~i~ 1 1 2010 ~I®~ku Oil F+ Gas Cans. Can An~hera~e Attached for your review are two copies of the Application for Injection Order for Gas Storage for the Ivan River Gas Storage Facility. The application is submitted by Union Oil Company of Cali- fornia (Union), as Operator. Upon your approval of this application and pending approval of gas storage with the Alaska Department of Natural Resources Division of Oil and Gas, Union plans to commence injection of gas into the IRU 44-36 Well this summer. Please contact me at 263-7627 if you have any questions regarding this application. Sincerely, Chantal R. Walsh Petroleum Engineer, P.E. • Chantal R. Walsh Union Oil Company of California Petroleum Engineer, P.E. 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tel 907 263 7627 Fax 907 263 7828 Email walshc@chevron.com Union Oil Company of California vvww.chevron.com • ~ -,~ .- p~ tom/ -~.~ ~ ,,-: ; ~ .~",~C __ _. __ ~t _ L `~,2 4 ~5~1~~'~` ~ 1 r ~ . • • APPLICATION FOR INJECTION ORDER FOR GAS STORAGE IVAN RIVER GAS STORAGE FACILITY TABLE OF CONTENTS Section/Regulatory Citation Subject Paae A. 20 AAC 25.252(c)(1) Plat information 3 B. 20 AAC 25.252(c)(2) Operators/Surface Owners 3 C. 20 AAC 25.252(c)(3) Affidavit 4 D. 20 AAC 25.252(c)(4) Description of Operation 5 E. 20 AAC 25.252(c)(4) Storage Zones 5 F. 20 AAC 25.252(c)(4) Geologic Information 5 G. 20.AAC 25.252(c)(4) Production History 6 H. 20 AAC 25.252(c)(5) Well Logs 7 I. 20 AAC 25.252(c)(6) Mechanical Integrity 7 J. 20 AAC 25.252(c)(6) Casing Information 8 K. 20 AAC 25.252(c)(7) Injection Fluid 9 L. 20 AAC 25.252(c)(8) Injection Pressure 9 M. 20 AAC 25.252(c)(9) Fracture Information 9 N. 20 AAC 25.252(c)(10) Formation Fluid 10 O. 20 AAC 25.252(c)(11) Aquifer Exemption 10 P. 20 AAC 25.252(c)(12) Wells Within Area 10 1 • • IVAN RIVER UNIT APPLICATION FOR INJECTION ORDER FOR GAS STORAGE IVAN RIVER GAS STORAGE FACILITY LIST OF ATTACHMENTS Number Description 1 Regional Cook Inlet Location Map 2 IRU 44-36 Location Map, 71-3 Sand 3 IRU 44-36 Well Log Section Showing 71-3 Sand 4 IRU 44-36 Production Chart -Gas and Water Rates 5 Material Balance Plot: P/Z vs Cumulative Gas 6 Current Wellbore Schematic for IRU 44-36 7 Completion Report and Directional Survey 8 Proposed Wellbore Schematic for IRU 44-36 9 Sample Gas Analysis from Ivan River Unit 10 Sample Gas Analysis from IRU 44-36 11 Ivan River Water Analysis 12 Wellbore Schematic for IRU 14-31 13 Wellbore Schematic for IRU 13-31 14 Wellbore Schematic for IRU 11-06 2 • • IVAN RIVER UNIT IVAN RIVER GAS STORAGE FACILITY APPLICATION FOR STORAGE INJECTION ORDER February 01, 2010 Introduction Union Oil Company of California (Union), as operator of the Ivan River Unit, requests a storage injection order for a gas storage project within the boundaries of the Ivan River Unit. Union specifically requests permission for storage injection operations into the Beluga 71-3 sand, which is present in the IRU 44-36 well. After obtaining all necessary approvals, IRU 44-36 would be converted to gas storage service. Additional wells would possibly be drilled, redrilled or worked over to this same sand in the future to increase deliverability from the storage facility. Section A -Plat Attachment 1 is a regional map showing the location of the Ivan River Unit relative to other Units in the Cook Inlet area. Attachment 2 is a plat showing the location of the proposed gas storage reservoir in IRU 44-36: Beluga 71-3 and the surrounding wells in the Ivan River Unit. Section B -Operators/Surface Owners The surface owners and operators within the area of this injection order and extending one-quarter mile beyond the boundary are: • Union Oil Company of California • State of Alaska Department of Fish and Game 3 • • • Section C -Affidavit Affidavit of Shannon W. Martin STATE OF ALASKA THIRD JUDICIAL DISTRICT I, Shannon W. Martin, declare and affirm as follows: 1. I am over 19 years of age. I am employed by Union Oil Company of California as a Land Representative. I have personal knowledge of the matters set forth in this affidavit. 2. On '~'~~ ~ cl f , 2010, the surface owners/operators listed in section B were provided a copy o/f,this permit application. DATED at Anchorage, Alaska this ~%~ ~i day of ~i~.`~^- ~~,y 2+° ~1 , 2010.. __..~ ~~ ~ L Shannon W. Martin Subscribed and affirmed before me at Anchorage, Alaska on ~~ -~ 4; ~~~, 2010. . ~ /6,. ~ , STATE OF ALASKA ,.v~ NOTARY PUBLIC Zelma M. Clarke My Commission E~iras Nav ~o, 202 Notary Public in and for the State of Alaska My commission expires: ~~f /~' ~~- 4 • • Section D -Description of Operation Union proposes injecting gas into the nearly depleted Beluga 71-3 sand for gas storage purposes. Initially, the IRU 44-36 well will be used as the sole well for gas storage operations (both production and injection). Union may later decide to redrill or work over an existing Ivan River well or drill a new well for storage operations into this reservoir. The storage gas will be injected during periods of excess supply and produced back during periods of increased demand to help balance gas deliverability requirements. Section E -Storage Zone The Beluga 71-3 sand is the proposed zone of injection. This zone comprises a stratigraphic interval, the top of which correlates to depths defined in the following Ivan River Unit wells: Well 71-3 Sand Top (MD) 71-3 Sand (TVDSS) IRU 44-36 6829' -5237' IRU 13-31 7137' -5236' IRU 14-31 6240' -5238' IRU 11-06 6514' _ -5247' IRU 41-01 5854' ~ Sand Not Present -5275' IRU 44-01 5363' ~ -5317' IRU 23-12 6506' -5376' Section F -Geologic Information Gas production from the Ivan River Unit has come from the Lower Sterling, Beluga and Tyonek Formations. The gas sands of Lower Sterling Formation are the shallowest, extending from a depth of approximately -4850 feet SSTVD to the top Beluga, approximately -5175 feet SSTVD. The Lower Sterling is comprised of interbedded sandstone, siltstone, mudstone, and coal. The Sterling Formation was most likely deposited in ahigher-energy meandering to braided stream environment. The Lower Sterling section is approximately 320 feet TVD thick at Ivan River Unit. 5 • • Underlying the Sterling is the Beluga Formation. The Beluga sands were deposited in a thinner, lower energy meandering stream system and are likely to be laterally discontinuous. These low-energy Beluga sands are inter-layered with abundant siltstones, mudstones and coals. The Beluga low-energy section is approximately 2750 feet TVD thick at Ivan River Unit. Currently all Beluga gas production has been from the upper 350 feet TVD of the Beluga section. Although gas production continues in the Tyonek sands at Ivan River Unit, the Tyonek section was not reached in the IRU 44-36. The Tyonek is currently producing from gas sands in the IRU 44-01 and the IRU 11-06. The Tyonek Formation is comprised of meander belt and anastomosing stream sandstones, often stacked into thicker sandstone sections interbedded with siltstones, mudstones and thick coals and is approximately 4850 feet thick at Ivan River Unit. Currently all Tyonek gas production has been from the upper 200 feet TVD of the Tyonek Formation. Beluga 71-3 Sand The 71-3 sand is a Beluga channel sand that is highly depleted from earlier production in the IRU 44-36 well. The sand was not completed and produced in any other well. The sand appears to transition to overbank siltstone and silty mudstone to the south in the IRU 41-01, suggesting that the 71-3 channel sands at the north end of the unit are isolated from the channel sands at the south end of the unit. The attached log section for IRU 44-36 (Attachment 3) shows the 71-3 sand at depths from 6829' to 6856 feet measured depth (MD). The 71-3 sand is topped by a section of interbedded siltstone, clay-rich siltstone and mudstone, which is topped by a 5 TVD feet of coal (PC4 Coal pick). Above the PC4 Coal there is a thick, approximately 50 foot section of siltstone and mudstone creating an impermeable barrier above; there are no permeable gas sands identified immediately above the 71-3 sand. The sand is underlain by 20 TVD feet of interbedded siltstone and mudstone. Below the first 20 feet there are some laterally discontinuous sands interbedded with clay rich siltstones, mudstones and laterally continuous 4 to 6 foot coals. The PC4, PC5 and PC6 Coals are laterally extensive and easily picked in other wells across the Unit. These sections above and below the 71-3 sand will act as a seal. Section G -Production History The IRU 44-36 Well was drilled and completed in March 1993. Three sands were perforated: the Sterling 58-4, the Sterling 59-6, and the Beluga 71-3 sand. A single 2- 7/8" completion was run with the production packer set above all zones. Attachment 4 shows the production history of the IRU 44-36 well. The well was first produced with all three sands open and commingled. Peak gas production from the well occurred in September 1993 at 10.731 MMCFD. In January 1995 water 6 • • breakthrough occurred. Attempts to chemically plug off the water production were made without success. The well loaded up and was unable to produce after September of 1995. In September 2001, a rig workover was performed on the well. Three deeper sands were opened, and the previous Sterling and Beluga intervals were reperForated. The 2- 7/8" single string completion was run with packers and sliding sleeves to enable isolated production intervals. Initial attempts were unsuccessful at bringing the new deeper zones on due to water, sand and coal production. An isolation plug was set below the Beluga 71-3 sand and the sliding sleeve was opened. Peak, stand alone, gas production from this interval was in January 2002 at 6.6 MMCFD at 1235 psig flowing tubing pressure. The 71-3 sand continued to produce with very little associated water (attachment 4) until March 2004. With a reservoir pressure of 615 psia the well was unable to flow into the compressor at the Ivan facility. The 71-3 sand was isolated as unsuccessful attempts were made to bring on the shallower Sterling sand intervals. These intervals brought water and sand into the well bore and the well has not been returned to production since. Estimates for original gas in place for the Beluga 71-3 sand were determined by analyzing the material balance plot (Attachment 5) for the post September 2001 period when the zone produced 1.7 bcf in isolation from the other Beluga intervals. Note that the P/Z vs. cumulative gas produced plot for this time period is a straight line, indicating volumetric type depletion or a weak aquifer at most. By extrapolating this straight line back to the original reservoir pressure for the sand, we constructed a theoretical plot for the zone had it produced in isolation over the entire depletion period. Using this approach, it is estimated that the original gas in place for this zone is 3.9 bcf. As of June 2005, cumulative production from the IRU 44-36 well is 3.1 bcf of gas and 460 bbl water, the gas production representing 79.5% of OGIP. It is desired to convert the well to gas storage service at this time. Section H -Well Loas All open hole logs from wells in the Ivan River Unit were sent to the Commission once the logs were completed. Attachment 3 shows the log section for the proposed injection interval in well IRU 44-36. Section I -Mechanical Integrity The IRU 44-36 well will be tested for mechanical integrity using the standard 30 minute annulus test per 20 AAC 25.412(c). To confirm continued mechanical integrity, Union Oil Company of California will monitor daily injection rates and pressure and notify the AOGCC the next working day if the rates and pressure indicate pressure 7 • • communication or leakage in any casing, tubing or packer. The rate and pressure data will also be reported to the Commission on a monthly basis. Mechanical integrity will also be monitored by observing the Material Balance Plot of P/Z versus Cumulative Gas Produced or Injected during gas storage operations. Monitoring of pressures and volumes in a gas storage reservoir is a secondary check upon mechanical integrity. The data from the original depletion can be compared with subsequent injection and production cycles. Although some hysteresis has been known to occur even in volumetric reservoirs, any problems that result in a loss of mechanical integrity will likely be evident in this data. Section J -Casing Information Well IRU 44-36 was directionally drilled from a surface location 742 feet from the south line (FSL) and 777 feet from the east line (FEL) in Section 1, Township 13 North, Range 9 West, Seward Meridian to a total depth of 8,308 feet MD (6,438 feet TVD) with a bottom hole location of 156 feet west and 4,836 feet north of the surface location. The top of the gas storage interval at 6,836 feet MD (-5,245 feet TVDSS) is 65 feet west and 3914 feet north of the surface location. A schematic of the well as currently completed is shown in Attachment 6. Original Construction: The 13 3/$ surface casing was set at 908 feet MD with cement returns to the surface. A 12 '/4 hole was drilled and the 9 5/$ casing run to 3,449 feet MD and cemented with 491 sacks of 12.9 ppg lead and 440 sacks of 15.8 ppg tail cement with cement to surface. A leakoff test was run to 19.5 ppg EMW at 2,941' TVD shoe depth. The 7-inch casing was set at 8,308 feet MD and cemented in place with 550 sacks of 13.2 ppg cement. A cement bond log was run and found the top of cement at 4,400 feet MD (3,591 feet TVD). Attachment 7 includes the State Completion Report with construction events detailing the casing, cementing, and tubing-packer equipment status. A directional survey is also included in Attachment 7. The 7-inch casing to 7,789' MD is 29# N-80 with an unsupported burst pressure of 8,160 psi. The new tubing will be 4'/2-inch 12.6# L-80 (attachment 8). The unsupported burst pressure is 8,430 psi. This exceeds the maximum bottom hole injection pressure by more than 25% as required by the Alaska Administrative Code 20 AAC 25.412(b). A waiver request will be submitted to allow a variance to 20 AAC 25.412(b) to allow more than 200 feet MD between the packer and perforations. This waiver is being requested to allow a 2"d packer above the gas storage zone to ensure long-term isolation of the 58-4 and 59-6 zones in addition to the squeeze cementing that will be 8 • • performed on those intervals. If this packer is not run, pressure cycling during future MITs may break down the squeeze perforations, creating a mechanical condition that would not allow use of the well until a workover could be performed. Considering the challenging logistics of this wells location, it could be several months before a workover could be performed, leaving the well unavailable during that time period. Section K -Iniection Fluid The type of fluid for proposed injection is dry natural gas, which is predominantly methane. It is intended to use the Ivan River Storage Facility for the injection of excess gas owned by Union. Attachments 9 and 10 are representative gas analyses for gas produced from the Ivan River Unit and from IRU 44-36. The compositions of these samples are typical of gas from Cook Inlet Units. Since all expected sources of gas are predominantly methane and are very similar to the original gas in the reservoir, no fluid compatibility problems are expected. The estimated maximum amount of gas to be injected daily is 20 mmcfd. Section L -Iniection Pressure Compression will be used for gas injection and production operations. The maximum injection pressure will be 3450 psig. Wellhead injection pressures will be maintained such that a gradient of 0.65 psi/ft at the target midpoint of perforations depth of 5,300' TVD (71-3 sand) is not exceeded. This corresponds to wellhead pressures of approximately 2800psig with the well shut in and 3450 psig at a 20 mmcfd injection rate. Section M -Fracture Information The proposed maximum injection pressures for the gas storage operation will not initiate fractures in the confining strata which might enable the injection or formation fluid to enter freshwater strata. The proposed maximum injection pressure for IRU 44-36 in the Beluga 71-3 sand, as previously mentioned, will not exceed a gradient of 0.65 psi/ft at the sandface. As stated in Section I of this document, leak off tests conducted while drilling IRU 44-36 in February, 1993 show the fracture gradient at 918' TVD and 2950' TVD to be 1.35 psi/ft and 1.014 psi/ft, respectively. The offset well IRU 11-06 conducted a deeper FIT in December of 2009. This test was done at a depth of 4930' ND establishing a pressure gradient of .71 psi/ft was withstood by the formation. Original reservoir pressure in the Beluga 71-3 sand in IRU 44-36 is estimated at 2894 psi based on normal pressure gradient in offset wells on the West side. 9 • • Section N -Formation Fluid Attachment 11 are produced water samples collected from IRU on 08/01/90 and 5/11 /05. Section O -Aquifer Exemption ~ The proposed gas injection will be at depths of approximately 6,836' - 6,852' MD 1 ~~~c (5,293' - 5,305' TVD). As per 40 CFR 147.102(b) the aquifers in the Ivan River Unit are ~° exempted in accordance with 40 CFR 144.7(b) and 40 CFR 146.4. ~ Section P -Wells Within Area The'/4 mile area of review around the top of the proposed gas storage zone in IRU 44- 36 is shown on Attachment 2. This perimeter encompasses three wells: IRU 14-31, IRU 13-31 and IRU 11-06. These wells are cased and cemented so as to not provide a conduit for injected gas to escape the injection Zone. No correction action plans are required. Detailed information on these wells has been provided to the State. Additional copies can be provided if requested. Well IRU 14-31: Attachment 12 includes the well schematic. The 10 3/ inch surface casing is set at 2,037 feet MD (1,960 feet TVD). Cement was recorded to the surface and bond logging shows good bonding. The 7-inch casing was set at 7,018 feet MD (5,829 feet TVD) and cemented to 4,197 feet TVD, which is above the top of the proposed gas storage zone. Second stage cement was placed from 3,646 feet to 625 feet TVD. This well is an active Class II disposal well. Well IRU 13-31: Attachment 13 includes the well schematic. The 9 5/$ inch surface casing is set at 3,460 feet MD (2,938 feet TVD). Cement was recorded at the surface. The 7-inch production casing is set at 10,350 feet MD (7,349 feet TVD) and cemented. A cement bond log run on December 2, 2008 showed a cement top at 3,453 feet MD (2,932 feet TVD), which is above the top of the proposed gas storage zone. This well is an active Class II disposal well. Well IRU 11-06: Attachment 14 includes the well schematic. The 9 %8 inch surface casing is set at 6,015 feet MD (4,920 feet TVD) and cemented in two stages. The 1Sc stage top is estimated at 4,100 feet MD (3,597 feet TVD) and the 2"d stage from 3,487 feet MD (3,175 feet TVD) to 900 feet MD (900 feet TVD). The 7-inch production casing is set at 10,020 feet MD (8,237 feet TVD) and cemented. A cement bond log run on February 8, 2009 showed a cement top at 6,118 feet MD (4,992 feet TVD), which is above the top of the proposed gas storage zone. This well is an active gas producer. 10 • • Regional Cook Inlet Location Map I I I I ~ - I I I I t ~ , 1 I -----t----- -~-----------~--- ~---------- --~--------- - -------~---- I I 1 ~ I , I I ~ i I 1 I I I ~ I ~ t 1 I I , I ~ 1 ~ I I I I 1 1 I I I I I I I I ~ PREm ~ ~ 1 I I I 1 1 I I ~ ' ~ I I 1 I I I -''--I I I 1 I 1 , +-----------~-----------a-----------i---------- --- ---- - s>u~P- I I I I I I I I I LAKE 1 I I I , rvAN II .~ II 1 I ~ I Po11ER~ I I 1 m ~y~a Po~ . , I I I O[luun I ' I I I I I ~ ' I r_________i_r_ Y_________1~____ I I I ~ Ivan River I I I 1 I I ; I I I I I I ~ Unit ~ I ~ I 1 ~ YOOUANKIE ~ ~ ' ! I ~ 1 I _ _ 7-------~--~--~ ~ I 1 -------~ UNOCU ----------~ -------- ---NbRTR"-----------'-----------r-- 1 ' ' II ' auNlrE POINr I COOK N.ET I I PROD. 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I I I 1 I~ 1 ATTACHMENT 1 Application for Injection Order for Gas Storage IRU • ~ 0 0 0 v m N O O O N N O O O O N O O O W a N O O O N O O N O O O N N ATTACHMENT 2 Application for Injection Order IVAN RIVER UNIT 2010 356000 ::5_~~ 308000 ~59fl00 3u00::+- 361000 362000 ';3(700 363000 365000 ~ (~(~CU ~ N~ ~ ~~~I scats®n f®r I n sects®~ Order [p~ Date: 8-February-2010 Wells I ~ /! N R ~ ~ U Flt StC1tUS Dperator: UNION D1L CO OF CRLIFORNI Completed: 1993-03-07 00:00:00 -----------Location Data----------- Xs 359630.0 7: 2646434.0 States RLRSKR Elevation: 51.0 FEET K8 UWI: 502832008900 Total Oepths 8308.0 FEET MD 39 38 38 ~~ DT ~~ -- ------ - -50 wrn rn ~ ~e _ __ _ _ 25e - - - - - - 15,E ILD RHOBFDC DSMTF~Ce~F~ ~ DO 1 .65 Production ZW~115 Tes~LGS I0D ~-ac V SS Track Tr 300 • ~~w B __ _~ _~ ~ ~ j ~' i __ -__ ----_ o ,,, ~ ~ , ® ~ ~ ~~ - - - ___ _. _- -- - __ > ~ , ~ ~~._ ,~ --- - 0 = o ,~ _ _, --- --___ __ 4 C®a l __ _ ~ - ~. -_- - . ._ _ .. _. ~_ ._ :~ .. , .:. .. .:- :' .. .. .:, . _ _ .. .. _ - - - •.. .- I .---.~; :1.= ~~ ~ 1 .. .= • .::' ,• .,, •.. . . ,{ .':' . _ . ..,. - ., .. ... .' •- .. :- •. •. .. - ~~~~ - ~ ~~ 1 ~ :_. ~~` ,~ ~ i f I s ! -~--t ---.._ r... ,`---}- r ., I i t i O f I I__ _ L _ o ~ M _--. _ _ _ - -- _ ~ j ~ ~ ~ ! ~. _ __ --~ -r-- _ _ _ _ _ _- I 9 ; I , I • • -- _ __. y ..._. _ __._ f - f . I U ~~~36 Wel I L®g Sh®w i ~g 7~ ~3 Sand NPHIS 0.6 0 GRSON GRSON 50 GR1 502832008900:BELUG-STER Cumulative Oil Prod : 0 Mbbl Cumulative Gas Prod :9826 MMcf Cumulative Water Prod : 12 Mbbl Cum Water Inj :0.000 bbl Monthly Monthly Monthly Monthly Oil Water Gas Water Oil Water Gas Water Rate Rate Rate Inj Rate Prod Prod Prod Inj (CD} (CD) (CD) (CD) Date -------- bbl --------- - bbl ---------- Mcf ---------- bbl --------- - - bbl/d ------- -- bbl/d -------- -- Mcf/d ---------- bbl/d --------- - 1993-Mar 0 0 4959 * 0 0 160 1993-Apr 0 5 172507 * 0 0 5750 1993-May 0 7 101003 * 0 0 3258 1993-Jun * * * * * * * * 1993-Jul 0 5 55899 * 0 0 1803 1993-Aug 0 7 42830 * 0 0 1382 1993-Sep 0 26 218693 * 0 1 7290 1993-Oct 0 31 332659 * 0 1 10731 1993-Nov 0 31 300896 * 0 1 10030 1993-Dec 0 30 --- 322107 ---------- --------- * - -------- 0 -- -------- 1 -- 10391 ---------- --------- - --------- - 0 ------- 142 1551553 0 0 1994-Jan 0 18 315979 * 0 1994-Feb 0 26 277935 * 0 1994-Mar 0 26 307388 * 0 1994-Apr 0 25 303888 * 0 1994-May 0 9 302625 * 0 1994-Jun 0 0 291492 * 0 1994-Jul 0 0 282222 * 0 1994-Aug 0 0 292725 * 0 1994-Sep 0 0 276251 * 0 1994-Oct 0 0 275016 * 0 1994-Nov 0 1 261693. * 0 1994-Dec 0 0 260066 -------- ---- * ------ ---- 0 ------ ---- ------ --- 0 ------- - 105 - 3447280 0 0 1995-Jan 0 0 251944 0 0 1995-Feb 0 0 205145 0 0 1995-Mar 0 0 232499 0 0 1995-Apr 0 0 219293 0 0 1995-May 0 0 222957 0 0 1995-Jun 0 0 208635 0 0 Attachment 4 0 5079 1 10193 1 9926 1 9916 1 10130 0 9762 0 9716 0 9104 0 9443 0 9208 0 8871 0 8723 0 8389 0 9448 Sum 0 Average * * * * * * * * * * * * Sum 0 Average 0 8127 0 0 7327 0 0 7500 0 0 7310 0 0 7192 0 0 6955 0 D-,nn , :] • 502832008900:BELUG-STER Cumulative Oil Prod : 0 Mbbl Cumulative Gas Prod :9826 MMcf Cumulative Water Prod : 12 Mbbl Cum Water Inj :0.000 bbl Monthly Monthly Monthly Monthly Oil Water Gas Water OiI Water Gas Water Rate Rate Rate Inj Rate Prod Prod Prod Inj (CD) (CD) (CD} (CD) Date -------- bbl --------- - bbl --------- - Mcf ---------- bbl --------- - bbl/d -------- -- bbl/d -------- -- Mcf/d ----------. bbl/d --------- - 1995-Jul 0 0 175707 0 0 0 5668 0 1995-Aug 0 0 192282 0 0 0 6203 0 1995-Sep 0 0 152084 0 0 0 5069 0 1995-Oct 0 0 167007 0 0 0 5387 0 1995-Nov 0 0 184546 0 0 0 6152 0 1995-Dec - 0 - 1 174321 --------- 0 - -------- 0 -- -------- 0 -- 5623 ---------- --------- 0 - ------- -- 0 ---- ---- - 1 ---------- 2386420 0 Sum 0 0 6543 0 Average 1996-Jan 0 335 151413 0 0 it 4884 0 1996-Feb 0 601 145054 0 0 21 5002 0 1996-Mar 0 723 128793 0 0 23 4155 0 1996-Apr 0 898 86374 0 0 30 2879 0 1996-May * * * * * * * * 1996-Jun * * * 0 * * * 0 1996-Jul * * * * * * * * 1996-Aug * * * * * * * * 1996-Sep * * * * * * * * 1996-Oct * * * 0 * * * 0 1996-Nov * * * * * * * * 1996-Dec * * * * ------ ---- * ------ --- * ------- -- * -------- ---- * ------ ---- ------ --- 0 ------- - 2557 --------- ---- 511634 0 Sum 0 7 1410 0 Average 1997-Jan * * * * * * * * 1997-Feb * * * * * * * * 1997-Mar * * * * * * * * 1997-Apr * * * * * * * * 1997-May * * * * * * * * 1997-Jun * * * * * * * * 1997-Jul * * * * * * * * 1997-Aug * * * * * * * * 1997-Sep * * * * * * * * 1997-Oct * * * * * * * * ~~ •I Attachment 4 D~no ~ 502832008900:BELUG-STER Cumulative Oil Prod : 0 Mbbl Cumulative Gas Prod :9826 MMcf Cumulative Water Prod : i2 Mbbl Cum Water Inj :0.000 bbl Monthly Monthly Monthly Monthly Oil Water Gas Water Oil Water Gas Water Rate Rate Rate Inj Rate Prod Prod Prod Inj (CD) (CD) (CD) (CD) Date bbl bbl Mcf bbl bbl/d bbl/d Mcf/d bbl/d 1997-Nov * * * * * * * * 1997-Dec * * * * * * * * 0 0 0 0 Sum 0 0 0 0 .Average 1998-Jan * * * * * * * * 1998-Feb * * * * * * * * 1998-Mar * * * * * * * * 1998-Apr * * * * * * * * 1998-May * * * * * * * * 1998-Jun * * * * * * * * 1998-Jul * * * * * * * * 1998-Aug * * * * * * * * 1998-Sep * * * * * * * * ~ 1998-Oct * * * * * * * * 1998-Nov * * * * * * * * 1998-Dec * * * * * * * * 0 0 0 0 Sum 0 0 0 0 Average 1999-Jan * * * * * * * * 1999-Feb * * * * * * * * 1999-Mar * * * * * * * * 1999-Apr * * * * * * * * 1999-May * * * * * * * * 1999-Jun * * * * * * * * 1999-Jul * * * * * * * * 1999-Aug * * * * * * * * 1999-Sep * * * * * * * * 1999-Oct * * * * * * * * 1999-Nov * * * * * * * * 1999-Dec * * * * * * * * 0 0 0 0 Sum AF4~nhment d *~----- ~ 502832008900:BELUG-STER Cumulative Oil Prod : 0 Mbbl Cumulative Gas Prod :9826 MMcf Cumulative Water Prod : 12 Mbbl Cum Water Inj :0.000 bbl Monthly Monthly Monthly Monthly Oil Water Gas Water Oil Water Gas Water Rate Rate Rate Inj Rate Prod Prod Prod Inj (CD) (CD) (CD) (CD) Date bbl -------- ---------- bbl ---------- Mcf ---------- bbl ---------- bbl/d ---------- - bbl/d --------- Mcf/d -------- ,bbl/d -- ---------- 0 0 0 0 Average 2000-Jan * * * 2000-Feb * * * 2000-Mar * * * 2000-Apr * * * 2000-May * * * 2000-Jun 0 143 4711 2000-Jul * * * 2000-Aug * * * 2000-Sep 0 0 479 2000-Oct * * * 2000-Nov * * * 2000-Dec * * ------ --- ------- ---- ------ --- 0 - 143 5190 * * * * * * * * * * * 0 * * * * * * * * * * * * * * * * * * * * 0 5 157 * * * * * * * * 0 0 16 * * * * * * * * * * * * Sum 0 0 14 0 Average 2001-Jan * * * * * * 2001-Feb * * * * * * 2001-Mar * * * * * * 2001-Apr * * * * * * 2001-May * * * * * * 2001-Jun * * * * * * 2001-Jul * * * * * * 2001-Aug * * * * * * 2001-Sep * * * * * * 2001-Oct * * * * * * 2001-Nov 0 19 49453 * 0 l 2001-Dec 0 34 177111 * 0 1 0 53 226564 0 0 0 2002-Jan 0 30 153845 * 0 1 n+f.,,.ti.,~.e.,+ ~ * * * * * * * * * * * * * * * * * * * * 1648 5713 ----- ---- ------ Sum 613 0 Average 4 9 63 ~>,.a a :~ • 502832008900:BELUG-STER Cumulative Oil Prod : 0 Mbbl Cumulative Gas Prod :9826 MMcf Cumulative Water Prod : 12 Mbbl Cum Water Inj :0.000 bbl Monthly Monthly Monthly Monthly Oil Water Gas Water Oil Water Gas Water Rate Rate Rate Inj Rate Prod Prod Prod Inj (CD) (CD) (CD) (CD) Date -------- bbl --------- - bbl ---------- Mcf ---------- bbl --------- - bbl/d -------- -- - bbI/d ------- -- Mcf/d ---------- bbl/d ---------- 2002-Feb 0 14 145732 * 0 1 5205 2002-Mar 0 15 142333 * 0 0 4591 2002-Apr 0 11 68838 * 0 0 2295 2002-May * * * * * * * * 2002-Jun 0 0 661 * 0 0 22 2002-Jul * * * * * * * * 2002-Aug * * * * * * * * 2002-Sep 0 5 47661 * 0 0 1589 2002-Oct 0 15 129797 * 0 0 4187 2002-Nov 0 30 102343 * 0 1 3411 2002-Dec 0 31 84538 -------- * - -------- 0 -- -------- 1 -- 2727 ---------- ---------- -------- -- 0 ---------- 151 ---------- 875748 - 0 Sum 0 0 2416 0 Average 2003-Jan 0 31 54095 * 0 1 1745 2003-Feb 0 28 61559 * 0 1 2199 2003-Mar 0 17 64041 * 0 1 2066 2003-Apr 0 19 44559 * 0 1 1485 2003-May 0 62 66196 * 0 2 2135 2003-Jun 0 48 26316 * 0 2 877 2003-Jul 0 0 0 * 0 0 0 2003-Aug 0 17 10647 * 0 1 343 2003-Sep 0 0 43803 * 0 0 1460 2003-Oct 0 1 50483 * 0 0 1628 2003-Nov 0 7 54742 * 0 0 1825 2003-Dec 0 8 48988 ---- ---- * ------ ---- 0 ------ ---- 0 ------ -- 1580 -------- ---- ------ ---- ------ --- 0 ------- - 238 ----- 525429 0 Sum 0 1 1445 0 Average 2004-Jan 0 8 28129 * 0 0 907 2004-Feb 0 7 17943 * 0 0 619 2004-Mar 0 2 9370 * 0 0 302 2004-Apr 0 0 2749 * 0 0 92 2004-May 0 0 4038 * 0 0 130 ~~i •i 502832008900:BELUG-STER Cumulative Oil Prod : 0 Mbbl Cumulative Gas Prod :9826 MMcf Cumulative Water Prod : 12 Mbbl Cum Water Inj :0.000 bbl Monthly Monthly Monthly Monthly Oil Water Gas Water Oil Water Gas Water Rate Rate Rate Inj Rate Prod Prod Prod Inj (CD) (CD) (CD} (CD) Date -------- bbl --------- - bbl -------- -- Mcf ---------- bbl --------- - bbl/d -------- -- bbl/d -------- -- Mcf/d ------- --- bbl/d --------- - 2004-Jun 0 0 1132 * 0 0 38 2004-Jul 0 0 0 * 0 0 0 2004-Aug 0 0 0 * 0 0 0 2004-Sep 0 0 0 * 0 0 0 2004-Oct 0 0 0 * 0 0 0 2004-Nov 0 0 0 * 0 0 0 2004-Dec 0 0 0 ---------- --------- * - -------- 0 -- -------- 0 -- ------- 0 --- --------- - --------- - 0 -------- -- 17 63361 0 0 0 174 0 2005-Jan 0 0 11114 * 0 0 359 2005-Feb 0 0 3902 * 0 0 139 2005-Mar 0 0 0 * ~ 0 0 0 2005-Apr 0 0 0 * 0 0 0 2005-May 0 0 695 * 0 0 22 2005-Jun 0 0 0 * 0 0 0 2005-Jul 0 0 0 * 0 0 0 2005-Aug 0 0 0 * 0 0 0 2005-Sep 0 0 0 * 0 0 0 2005-Oct 0 0 0 * 0 0 0 2005-Nov 0 0 0 * 0 0 0 2005-Dec 0 0 0 ------- ---- * ------ ---- 0 ------ ---- 0 ------ --- 0 ------- ---- ------ ---- ------ ---- 0 ------ -- 0 - 15711 0 0 0 43 0 2006-Jan 0 0 0 * 0 0 0 2006-Feb 0 0 0 * 0 0 0 2006-Mar 0 0 0 * 0 0 0 2006-Apr 0 0 0 * 0 0 0 2006-May 0 0 0 * 0 0 0 2006-Jun 0 0 0 * 0 0 0 2006-Jul 0 0 0 * 0 C 0 2006-Aug 0 0 0 * -0 0 0 2006-Sep 0 0 0 * 0 0 0 Sum Average Sum Average • • ~#~rhmnr-t d n,,.,, G 502832008900:BELUG-STER Cumulative Oil Prod : 0 Mbbl Cumulative Gas Prod :9826 MMcf Cumulative Water Prod : 12 Mbbl Cum Water Inj :0.000 bbl Monthly Monthly Monthly Monthly Oil Water Gas Water OiI Water Gas Water Rate Rate Rate Inj Rate Prod Prod Prod Inj (CD) (CD) (CD) (CD) Date -------- bbl --------- - bbl --------- - Mcf --------- - bbl ---------- - bbl/d ------- -- bbl/d -------- -- - Mcf/d ------- -- bbl/d ---------- 2006-Oct * * * * * * * * 2006-Nov 0 0 0 * 0 0 0 2006-Dec 0 0 0 * 0 0 0 0 0 0 0 0 0 0 0 2007-Jan * * * * * 2007-Feb * * * * * * 2007-Mar * * * * * * 2007-Apr 0 0 0 * 0 0 2007-May 0 0 0 * 0 0 2007-Jun 0 0 0 * 0 0 2007-Jul 0 0 0 * 0 0 2007-Aug 0 0 0 * 0 0 2007-Sep 0 552 43787 * 0 18 2007-Oct 0 744 53979 * 0 24 2007-Nov 0 582 31246 * 0 19 2007-Dec 0 741 -- -- 17685 -------- ---- * ------ ---- 0 ------ ---- 24 ------ ---- ------ -- 0 ------ 2619 146697 0 * * * * * * 0 0 0 0 0 1460 1741 1042 570 ------ ---- ------ 0 7 401 Sum Average Sum 0 Average 2008-Jan 0 744 0 * 0 24 0 2008-Feb 0 696 1490 * 0 24 51 *. 2008-Mar 0 744 0 * 0 24 0 2008-Apr 0 720 0 * 0 24 0 2008-May 0 744 0 * 0 24 0 2008-Jun 0 720 803 * 0 24 27 2008-Jul 0 744 29184 * 0 24 941 2008-Aug 0 560 22118 * 0 18 713 2008-Sep 0 444 16805 * C 15 560 2008-Oct 0 0 0 * 0 0 0 2008-Nov 0 0 0 * 0 0 0 2008-Dec ---- 0 ------ --- 0 ------- -- 0 -------- ---- * ------ ---- 0 ------ --- 0 ------- --- 0 ------- ---- ------ • • D+t~rh„..,..a w s 502832008900:BELUG-STER Cumulative Oil Prod : 0 Mbbl Cumulative Gas Prod :9826 MMcf Cumulative Water Prod : 12 Mbbl Cum Water Inj :0.000 bbl Monthly Monthly Monthly Monthly Oil Water Gas Water Oil Water Gas Water Rate Rate Rate Inj Rate Prod Prod Prod Inj (CD} (CD) (CD) (CD) Date bbl -------- ---------- bbl ---------- Mcf ---------- bbl ---------- bbl/d ---------- bbl/d ---------- Mcf/d ---------- bbl/d ---------- 0 6116 70400 0 Sum 0 17 191 0 Average ~ I 2009-Jan 0 0 0 * 0 0 0 * 2009-Feb 0 0 0 * 0 0 0 * I 2009-Mar 0 0 0 * 0 0 0 * ', 2009-Apr 0 0 0 * 0 0 0 * i 2009-May 0 0 0 * 0 0 0 2009-Jun 0 0 0 * 0 0 0 * I 2009-Jul 0 0 0 * 0 0 0 2009-Aug 0 0 0 * 0 0 0 2009-Sep 0 0 0 * 0 0 0 2009-Oct 0 0 0 * 0 0 0 * ', 2009-Nov 0 0 0 *. 0 0 0 * I 2.009-Dec 0 0 0 * ------ ---- 0 ------ ---- 0 ------ ---- 0 ------ ---- ------ ---- ------ ---- 0 ------ ---- 0 ------ ---- 0 0 Sum 0 0 0 0 Average • Ivan 44-36 -- Beluga 71-3 P/Z vs Cum Production Plot 4000 3500 3000 2soo .~ °' 2000 N A. 1500 1000 500 0 0 • 5 Cum Gas Produced, bcf •i OGIP = 3.9 bcf nearly depleted 10 y = -884.89x + 9188.2 RZ = 0.9978 15 Att~oh.rnont 5 - IVlaterial ~~lanoe Plot 20" (d 84' 17.016" ~ 906' 9.516" ~ a.419' CBL TOC: 4,100' Tagged fdYgue @T,ets't9lTrotl i • Casing and Tubing Detail Size Type yVU Grads Top Btm CONN I ID Cement I Other 20" Structural 94#, - Surtace 94' Driven 13-3/8" Surface 68#, K-55 Surtace 908' BTC / 12.415" 115 bbl ! Cmt to Surtace 9518" Surface 47#, N-80 Surface 3,449' BTC 18.681" 270 bbl / Cmt to Surface ' 29#, N-80 Surface 7, 789' BTC ! 6.184° 1 t 5 bbl ! Cmt to 4 420' 7 Production 29#, P-110 7,789' 8,308' BTC / 6.184° , Tubing 2-718" Production 6.4#, L-80 Surtace 7,735' IBT SCC / 2.441" Cpig OD = 3.220" 2318" Heater 4.6#, L-80 Surface 2,990' IBT SCC / 1.995" Fluid: Propylene Glywl Production S'trin Jewel Detail # Depth (RKB) Length ID OD Item 1 22' 0.30' 2.441 _ Dual Tubing Hanger, 2-718' x 2-3l8" 10° 5M Vetco Gray (2-718" 8 2-318" IBT lift threads) 2 3,071' 3.86' 2.313 3.750 Sliding Sleeve, Baker, CMD, 2-718" CLOSED 3 3,117 6.40' 2.441 5.980 Packer, FH Retrievable (30K Shear) 4 6,384' 3.85' 2.313 3750 Sliding Sleeve, Baker, CMD, 2-718" [CLOSED 5 6,525' 4.71' 2.347 5.970 Packer, Baker SC-2 Ret. (Min ID thru 5-22 latch) 6 6548' 3.8T 2.313 3.750 Slidi Sleeve Baker CMD 2-718° LEAKING 7 6,660' 0.18' - 2 200 Fish, 113 of Pinning Proted'wn Sleeve from 2.5° GR adapter (22" OD, %" thick), (lost 2114/06) 8 6,753' 4.69' 2.347 5.970 Packer, Baker SC-2 Ret. Min ID 8wu 5-22 latch) 9 6,805' - G-Stop (set 9/5!04) 10 6,806' Packoff (set 915!04) 11 6,807' - Separation Tool wl Side Door Choke (set 11!14!01) 12 6,807 3.8T 2.313 3.750 Slidi Sleeve, Baker, CMD, 2-7/8° IBT OPEN) 13 7,068' 1.14' 2.313 3.500 X Nipple, 2.313" ID, 14 7 10T 4.T 2.347 5.810 Packer Baker SC-1 Ret. Min ID ihru 5-22 latch 15 7,122' 76.0' 4.480 5.500 Meshrite sand screen ass . 2 at 38' each 16 7,242' 3.91' 2.347 5.673 Packer, Baker Model D Perm. 17 7,701' 1.06' 2.313 3-500 X Nipple, 2.313" ID, (PX Plug set 70124!01) 18 7 735' 0.75' 2.441 3.250 W ireline En Guide 19 7,815' 438' 4.500 4-V2" TCP Gun, 12 spf (Leff in 17o1e 317!93) fill ~ 6,721' Tag 2121109 Perforation Data Zone Top Btm Amt apf Comments 58-0 6,431' 6,440' 9' 12,12 4-112' TCP (9/4101), (317193) 595 6,557 6,568' 11' 12,12 4-112" TCP (9!4101), (317193) 713 6,836' 6,852' 16' 72.12 4-112° TCP (9141011, (377193) 74~ 7,11 T 7,150' 33' 12 Mestxite Screen, TCP Pert (317193) 753 7,163' 7,184' 21' 12 Meshrde Screen; TCP Pert (317193) 82-7 7 760' 7 772' 12' 12 Isolated below tubi TCP Pert 3!7193 7" Cement Boud Log 3ISi93) 4.400' - 4.600' - Poor x.600' - 4.740' - Fair 4,740' - 8.250' - Good r 8'6.766' I)irnctional Darn: TD ~,~08' PBTD = 872' 77/a]r holc ample =48.3'° at 9.?.'S' TID IR114436 Actual Wet Schematic 2-21-09 door Dpdated tty STP 1-29-10 Attachment 6 -Current IRU 44-36 Well Schematic RKB: 51' KB f CL: 26.5' pMSI KB•TKf: 24' KB ._ • • Attachment 7 -Well IRU 44-36 State Completion Report and Directional Survey State Completion Report Well Drilling History: "IRU 44-36; API 50-283-20089-00; PTD: "193-022" 2/10/93: Spud Well: Grace #154 Rig, • Spud Ivan River Unit 44-36 @ 2000 hours, February 10, 1993 w/ 17-1/2" hole. 2/10/93: Drilling Surface Hole: (20" @ 94') • 20" Conductor Driven prior to rig arrival • Drilled 17-1 /2" hole to 916' RKB on 2/12/93. 2/13/93: Run/Cement Surface Casing (20" @ 94') • Ran 908' 13-3/8" 68# K55 BTC casing. Cement to surface 80 bbl lead / 35 bbl tail. 2/14/93: Drilling Intermediate Hole: (20" @ 94', 13-3/8" @ 908') • Test casing to 1,500 psi - OK. • Drill out float shoe and open hole t/922' -LOT 26.0 PPG EMW • Directionally drill 12-1/4" hole t/ 3453' on 2/18/93. 2/20/93: Run/Cement 9-5/8" Intermediate Casing (20" @ 94', 13-3/8" @ 908') • Ran 3,449' 9-5/8" 47# N80 BTC casing. Cement to surface 180 bbl lead / 90 bbl tail. 10/07/93: Drilling 8-1/2" Production Hole: (20" @ 94', 13-3/8" @ 908', 9-5/8" @ 3,449') • Test casing to 1,500 psi - OK. Drill out float shoe and open hole t/3464' -LOT 19.5 PPG EMW I• Directionally drill 8-1/2" hole t/ 8,120' on 2/27/93. • Ran casing caliper inside 9-5/8" from 0-3,202'. Minimal wall loss. Test to 4,100 psi - OK. • Ran bond log from 0'-3,420'. • Directionally drill 8-1/2" hole t/ 8,308' TD on 3/01/93. 3/03/93: Run/Cement 7" Production Casing (20" @ 94', 13-3/8" @ 908', 9-5/8" @ 3,449') • Ran 8,308' 7" 29# N80 BTC and 7" 29# P-110 BTC casing. Cement to 4,400' MD 129 bbl lead. r. • r • Test casing to 1,500 psi - OK. • Tag PBTD at 8,272'. Ran bond log from 3,500'-8,250'. • Ran TCP guns on 2-7/8" tubing w/ 2-3/8" heater string. • Perforate Tyonek zones 6,836'-6,852', 6,557'-6,568' and 6,431'-6,440'. • Dispose of brine down 7" x 9-5/8" annulus (495 bbl total, 2,300 psi @ 4.8 bpm). • TD = 8,308' MD, 6,438' TVD. • PBTD = 8,272' MD, 6,408' TVD. • Release rig 18:00 hrs 3/09/93. 8/23/01: Workover (20" @ 94', 13-3/8" @ 908', 9-5/8" @ 3,449', 7" @ 8,308') • Pull existing completion. • Perforate Tyonek zones 7,760'-7,772', 7,163'-7,184', 7,117'-7,150' and re- perforated 6,836'-6,852', 6,557'-6,568' and 6,431'-6,440'. • Run new completion with multiple packers and sliding sleeves. • Release rig 06:00 hrs 9/13/01. Directional Survey Directional Survey: "Full Survey to TD" MD ft TVD ft TVDSS ft FNUFSL FWUFEL Inc de Azi de 0 0.00 51.00 0.00 N 0.00E 0 0 97 97.00 -46.00 0.31 S 0.28 W 0.5 222 191 190.99 -139.99 1.23 S 1.11 W 1 222 284 283.98 -232.98 2.12 S 1.51 W 0.4 154 376 375.97 -324.97 1.13 S 1.45 W 1.6 356 465 464.89 -413.89 2.67 N 1.71 W 3.3 356 555 554.67 -503.67 8.94 N 1.89 W 4.7 360 645 644.26 -593.26 17.42 N 2.70 W 6.2 351 733 731.60 -680.60 28.06 N 4.04 W 7.8 355 825 822.70 -771.70 40.91 N 4.82 W 8.3 358 859 856.30 -805.30 46.04 N 5.12 W 9.1 355 952 947.90 -896.90 62.07 N 6.30 W 10.8 356 1,044 1,037.92 -986.92 81.00 N 7.54 W 13 356 1,135 1,126.19 -1,075.19 103.02 N 9.27 W 15.1 355 1,227 1,214.49 -1,163.49 128.71 N 11.83 W 17.5 354 1,319 1,301.68 -1,250.68 157.90 N 14.81 W 19.7 354 1,411 1,387.65 -1,336.65 190.41 N 18.69 W 22 352 1,502 1,471.38 -1,420.38 225.76 N 23.08 W 24.1 354 1,594 1,554.79 -1,503.79 264.35 N 27.16 W 25.8 354 Attachment 7 • w 1,686 1,636.72 -1,585.72 306.03 N 30.78 W 28.3 356 1,778 1,716.55 -1,665.55 351.65 N 33.63 W 31.3 357 1,867 1,791.77 -1,740.77 399.17 N 35.27 W 33.3 359 1,960 1,86$.37 -1,817.37 451.91 N 35.80 W 35.8 360 2,052 1,941.30 -1,890.30 507.97 N 35.55 W 39.3 1 2,144 2,010.61 -1,959.61 568.43 N 34.69 W 42.9 1 2,236 2,077.79 -2,026.79 631.28 N 33.60 W 43.3 1 2,329 2,146.02 -2,095.02 694.44 N 31.73 W 42.3 2 2,420 2,212.74 -2,161.74 756.27 N 29.14 W 43.4 2 2,513 2,280.48 -2,229.48 819.94 N 26.64 W 43.1 2 2,605 2,347.38 -2,296.38 883.05 N 24.32 W 43.6 2 2,696 2,412.72 -2,361.72 946.34 N 22.22 W 44.6 2 2,791 2,479.78 -2,428.78 1013.62 N 20.64 W 45.6 1 2,883 2,543.81 -2,492.81 1079.68 N 19.90 W 46.2 0 2,973 2,607.00 -2,556.00 1143.76 N 19.39 W 44.6 1 3,065 2,672.67 -2,621.67 1208.18 N 18.72 W 44.3 1 3,158 2,738.89 -2,687.89 1273.48 N 18.04 W 44.9 1 3,250 2,803.49 -2,752.49 1338.98 N 18.16 W 45.9 359 3,340 2,865.44 -2,814.44 1404.26 N 18.67 W 47.1 360 3,400 2,906.67 -2,855.67 1447.85 N 18.86 W 46.1 360 3,490 2,968.90 -2,917.90 1512.86 N 18.51 W 46.4 1 3,581 3,031.26 -2,980.26 1579.14 N 18.17 W 47.1 360 3,672 3,092.91 -3,041.91 1646.07 N 18.46 W 47.6 360 3,764 3,155.36 -3,104.36 1713.62 N 19.17 W 46.9 359 3,857 3,219.26 -3,168.26 1781.18 N 20.05 W 46.3 360 3,949 3,282.82 -3,231.82 1847.70 N 20.52 W 46.3 360 4,041 3,346.32 -3,295.32 1914.26 N 21.39 W 46.4 359 4,134 3,410.40 -3,359.40 1981.64 N 23.09 W 46.5 358 4,225 3,472.87 -3,421.87 2047.78 N 25.17 W 48.8 358 4,316 3,535.10 -3,484.10 2114.13 N 27.49 W 46.9 358 4,407 3,597.28 -3,546.28 2180.51 N 30.45 W 46.9 357 4,498 3,659.11 -3,608.11 2247.20 N 33.59 W 47.5 358 4,591 3,721.28 -3,670.28 2316.29 N 36.85 W 48.6 357 4,684 3,783.15 -3,732.15 2385.66 N 39.94 W 48 358 4,776 3,844.94 -3,793.94 2453.76 N 42.56 W 47.6 358 4,868 3,906.50 -3,855.50 2522.09 N 44.94 W 48.4 358 4,959 3,967.40 -3,916.40 2589.67 N 47.30 W 47.6 358 5,052 4,031.00 -3,980.00 2657.48 N 49.50 W 46.1 359 5,144 4,095.20 -4,044.20 2723.37 N 50.59 W 45.4 360 5,235 4,159.26 -4,108.26 2788.00 N 50.88 W 45.1 360 5,324 4,221.92 -4,170.92 2851.20 N 50.76 W 45.4 0 5,417 4,286.81 -4,235.81 2917.82 N 50.42 W 46.1 0 5,509 4,350.72 -4,299.72 2984.00 N 50.30 W 45.9 360 5,603 4,416.25 -4,365.25 3051.39 N 50.01 W 45.7 1 5,696 4,481.26 -4,430.26 3117.88 N 49.31 W 45.6 1 5,785 4,543.26 -4,492.26 3181.74 N 48.81 W 46.1 0 Attachment 7 u 5,878 4,607.92 -4,556.92 3248.58 N 48.05 W 45.8 1 5,971 4,673.10 -4,622.10 3314.90 N 46.89 W 45.2 1 6,064 4,738.63 -4,687.63 3380.88 N 45.51 W 45.2 1 6,158 4,804.99 -4,753.99 3447.44 N 44.12 W 45 1 6,251 4,871.04 -4,820.04 3512.91 N 44.00 W 44.5 359 6,345 4,938.02 -4,887.02 3578.85 N 45.09 W 44.6. 359 6,439 5,004.90 -4,953.90 3644.89 N 46.76 W 44.7 358 6,532 5,071.96 -5,020.96 3709.24 N 49.78 W 43 356 6,626 5,141.05 -5,090.05 3772.83 N 54.17 W 42.4 356 6,719 5,209.56 -5,158.56 3835.54 N 58.89 W 42.7 356 6,811 5,277.50 -5,226.50 3897.39 N 63.70 W 42.1 355 6,903 5,345.54 -5,294.54 3959.11 N 68.67 W 42.5 355 6,995 5,413.37 -5,362.37 4021.04 N 73.87 W 42.5 355 7,089 5,482.79 -5,431.79 4084.19 N 79.39 W 42.3 355 7,182 5,551.90 -5,500.90 4146.14 N 85.19 W 41.7 354 7,275 5,621.66 -5,570.66 4207.34 N 91.30 W 41.1 354 7,369 .5,692.76 -5,641.76 4268.52 N 97.41 W 40.6 354 7,460 5,762.16 -5,711.16 4327.09 N 103.25 W 40 354 7,553 5,833.77 -5,782.77 4386.12 N 109.30 W 39.3 354 7,647 5,906.77 -5,855.77 4445.05 N 115.13 W 38.8 355 7,738 5,977.94 -5,926.94 4501.49 N 120.71 W 38.3 354 .7,830 6,050.53 -5,999.53 4557.71 N 126.47 W 37.5 354 7,926 6,126.90 -6,075.90 4615.58 N 132.40 W 37.1 354 8,020 6,202.17 -6,151.17 4671.58 N 138.29 W 36.5 354 8,085 6,254.72 -6,203.72 4709.62 N 142.29 W 35.6 354 8,114 6,278.34 -6,227.34 4726.35 N 144.04 W 35.3 354 8,206 6,353.66 -6,302.66 4778.89 N 149.57 W 34.8 354 8,273 6,408.84 -6,357.84 4816.68 N 153.54 W 34.3 354 8,308 6,437.76 -6,386.76 4836.30 N 155.60 W 34.3 354 Attachment 7 s • Recompletion Workover Program: Surface Location: Longitude: -150.7968086° Latitude: 61.24108419° 742' FSL & 777' FEL Sec. 1, T13N R9W SM Total Depth: 8,308' MD (6,437.76' TVD; -6,386.76' TVDSS) Bottom Hole Location: 4,836.30 feet N; 155.60 feet W Top of Gas Storage Zone: 6,836 feet MD (-5,245 feet TVDSS) 3,914 feet N, 65 feet W from Surface location Wellbore azimuth: 0.17° Kelly bushing elevation: 51 feet above mean sea level Item and Depth Subsea TVD (RKB) MD (RKB) 20" -43' 94' 94' 13-3/8" -857' 908' 908' 9-5/8" -2,890' 2,941' 3,449' 7" -6,387' 6,438' 8,308' Top Gas Storage Zone -5,245' 5,296' 6,836' Base Gas Storage Zone -5,257' 5,308' 6,852' Attachment 7 • IVdll RI`JCI Vllll IRU 44-3G `~~Nell IftU 44-3n PROPOSED SCHEMATIC Pr°p°Sed ""'~o '~, 25" R4 94' 78318" ~ ~S' 5a5° a,44a' CBL Top: 4,420' ~49Yb ~'9~ Casing and Tubing Detail 31ze Type WU Grade Top Btm CONN I ID Cement /Other 20" Structural 94#, - Surtece 94' - Driven 13-318' Surtace 68#, K-55 Surface 908' BTC ! 12.415" 115 bbl 1 Cmt to Surface 9-518" Surface 47#, N-80 Surface 3,449' BTC 18.681" 270 bbl 1 Cmt to Surtace " 29#, N-80 Surface 7,789' BTC / 6.184" 420' 115 bbl 1 Cmt to 4 7 Production 29#, P-110 7,789' 8,308' BTC 16.184" , Tubing 4-112" Production 12.6#, L-80 Surtace 6,900' TC-II 13.958" Cplg OD = 4.932" Production Strin Jla wel Detail # Depth (RKB) Length ID OD Item 1 24' 1.0' 3.958 4.500 Tubing Hanger, 4-112" Vetco Gray 10" SM 2 6,352' 3.5' 3.813 5.000 Sliding Sleeve, X-profile, 3.813" ID, 4-112" TC-II 3 6,400' S.0' 3.875 6.000 Packer, Baker SC-2A (Min ID thru seals) 4 6,753' 5.0' 3.875 6.000 Packer, Baker SC-2A (Min ID thru seals) 5 6,827' 37.0' 3.548 4.800 4" Excluder Screen 1 jt (Gravel Packed) 6 6,865' 2.0' 4.000 5.875 Sump Packer, Baker Model FS 7 6,900' 1.0' 3.950 4.950 WirelineEntryGuide 8 7,050' 2.0' - - Cement Retainer, Halliburton EZSVB 9 7,107 4.T 2.347 5.810 Packer, Baker SC-1 Ret. (Min ID thru S-221atchj 10 7,122' 76.0' 4.480 5.500 Meshrite sand screen ass . 2 is at 38' each 11 7,242' 3.91' 2.347 5.673 Packer, Baker Model D Perm. 12 7 701' 1.06' 2.313 3.500 X Ni le 2.313" ID PX PI set 10/23!01 _ 13 7,735' 0.75' 2.441 3.250 Wiroline Entry Guide 14 7,815' 438' - 4.500 4-1 /2" TCP Gun, 12 s f (Left b hole 3/7193) Perforation Data Zone Top Btm Amt spf Comments 58~ 6,431' 6,440' 9' 12,12 To be squeezed, TCP Perf (9/4/D1), (317193) 59-6 6,557' 6,568' 11' 12,12 To be squeezed. TCP Perf (914!01), (3!/!93) 71-3 6,836' 6852' 16' 12,12 TCP Perf (9/4!01), (317193) 74~ 7,17T 7,150' 33' 12 To be squeezed, TCP Pert (3!7/93) 75-3 7,163' 7,184' 21' 12 To be squeezed. TCP Perf (3!7193) 82-7 7 760' 7777 12' 12 Isolated bebw tuts lu TCP Pert 3!7193 7" Cement ]3oud Lo$ (3!5!93) 4,420' - 4.600' - Poor 4,600' - 4.740' - Fair 4,740' - 8,308' - Good ~Iisc R'orko~er \oites • R'orko~-er fluid to be 9°o IiCL Brnte i S.3 pp.j. • Abandon lower zones R'i 20 bbl LYT content squeezed belo~t' retauter. • Steps to abzutdon and isolate SS-4 and 59-6: Squeeze zones ~+~% 40 bb) LXT cement and drill out cement and plus. Test squeeze to 1.500 psi for 30 nun. Run grai•el pack completion across 71-3. _ Run upper SC'-2A isolation packer and htbing to isolate SS-4 and ~9-6. • Kuu coupletion htbing with sliding slee~-e. • Cuc diesel as packer fluid and fieeze protection. v T'~8.315' .. ~.• ~ Directional: TD =8.308' PBTD = 8.2?2' t»ax hole angle =48.8° at 4 '25' MD IRU 44-36 Proposed Web Sct>arnafK 1-11-10 door liy~~y STP t-11-10 Attachment 8 - Proplosed Gas Storage Well Schematic RKB: 51' KB ! CL: 28.5' AMSL KB•THf: 24' KB iF~~sr'~1e ®v~rti R~sv~r Fi~IG9 rig-.it~~~-~>~ Unocal Gas Analysis Report Facility: WS IR Meter Number: 7 Date: 4/25/96 l3tu/C f: 1,010.63 Relative Dens: O.S6 C02: 0.27 H2S: 0.00 N2: 0.22 Methane: 99.40 [ahane: 0.09 Pronanc: 0.02 E3utanc: 0.00 NButanc: 0.00 NeoPentane: 0.00 (Pentane: 0.00 N Pentane: 0.00 C6: 0.0 I UnnormTotal: 103.10 <J Attachment 9 EG&G Ch andler Engineering Model 292 BTU Analyzer t time: Jan.30 02 16:35 Calibration #: 1 14at #:2 Location No. :2 04b Standard/Dry Analysis Saturated/Wet Analysis Molex BTU* R.Den.* GPM** Molex BTU* R.Den.* Methane 99.304 1005.32 0.5501 -- 97.576 987.83 0.5405 Ethane 0.077 1.36 0.0048 0.0205 0.075 1.33 0.0008 Moisture 0.000 0.00 0.0000 -- 1.740 0.88 0.0108 Nitrogen 0.263 0.00 0.0025 -- 0.259 0.00 0.0025 C02 } 0.356 0.00 0.0054 -- 0.350 0.00 0.0053 Total 100.00 1006.7 0.5588 0.0205 100.00 990.0 0.5599 * Uncorrected for compressibility at 6D.OF & 14.730PSIA. **: Liquid Volume reported at 60.OF. Standard/Dry Analysis Saturated/Wet Analysis Molar Mass = 16.185 16.217 Relative Density = 0.5597 0.5609 Compressibility Factor = 0.9980 0.9979 Heating Valuue = 23549. Btu/1b 23114. Btu/1b Heating Value = 1008.7 Btu/CF 992.1 Btu/CF :absolute Gas Density = 42.8333 lbm/1000CF 42.9220 lbm/1000CF wobbe Index = 132b.11 LTnnormalized Total 93.535 Last Calibrated with Calgas of 1057.3 Btu/CF May 05 00 12:26 r~+ Last Update: GPA 2261-90. C6+ BTU/CF 5065.8, C6+ lbm/Gal 5.64250, and C6+ Mo1.Wt. 92.00. ~~~~~ ~~/~ ct.~e.P.P~ Attachment 10 Ivan River Water Analysis Anions Cations TDS Density CO2 H2S pH Chloride Bicarbonate Sulfate Na Mg Ca Sr Ba Fe K Facility Location Zone Date mg/I g/cm^3 ppm ppm mg/I mg/I mg/I mg/I mg/I mg/1 mg/I mg/I mg/I mg/I Wastside IRU 44-36 5/11/2005 7,286 1.0070 7.47 2,854 1,655 7 1,653 62 99 1 4.0 137.00 814 Wastside IRU 44-36 5/11/2005 7,076 1.0060 8.13 2,323 2,216 38 1,826 61 89 1 3.5 40.00 479 Wastside Iv an RNer Field 8/1/1990 5.40 10,000 Scaling Index and Am ount of Scale in Ib/1000661 CaCO3 CaSO4.2H2O Facility Location Zone Date 80 100 120 140 I A I A I A I A 80 100 120 140 I A I A I A I A Wastside IRU 44-36 5/11/2005 Wastside IRU 44-36 5/11/2005 Wastside Ivan River Field 8/1/1990 0.82 54.63 0.92 60.55 1.03 65.77 1.14 70.64 1.51 68.22 1.54 69.96 1.57 71.35 1.61 72.74 -3.16 -3.18 -3.18 -3.19 -2.48 -2.50 -2.51 -2.51 Ca5O4 SrSO4 80 100 120 140 80 100 120 140 Facility Location Zone Date I A I A I A I A I A I A I A I A Wastside IRU 44.36 5/11/2005 -3.23 -3.18 -3.11 -3.02 -3.39 -3.37 -3.35 -3.31 Wastside IRU 44.36 5/11/2005 -2.55 -2.50 -2.43 -2.34 -2.65 -2.64 -2.61 -2.57 Wastside Ivan River Field 8/1/1990 Scaling Index and Amount of Scale in 16/1000661 Ba5O4 CO2 pressure Resistivity 80 100 120 140 80.00 100.00 120.00 140.00 @ 70 F Facility Location Zone Date I A I A 1 A I A ohm/cm Comment Wastside IRU 44-36 Wastside IRU 44-36 Wastside Ivan River Field 5/11/2005 0.31 1.04 0.17 0.70 0.04 0.00 -0.05 0.68 0.91 1.20 1.54 sample 1 5/11/2005 1.00 1.74 0.85 1.74 0.73 1.74 0.64 1.74 0.21 0.33 0.50 0.75 sample 2 •i u Attachment 11 • • Ivan River Field M/ell ~4-3i SPUD 5~iJ75 SU3P 8118/75 ~" 94# @421 812,98' For 7" CSG 1014" 40.5# K-5t @ 203T 1050 SX! TTC @ 51' Based o~ Hole Sire @ 1316 Bssed an Equalizatb~ Thru Fbeuj Shoi Stage CA)!er @ 42&I Ei88 Sx: Annulus 7TC Bstweei 4845' and 405E {CBL Not Conclusive 7" 23, 2Ei d~ 29# N-EM ® 7018' 500 SXI b 1/2" Liner ®10,00! I ~ ~ . _ •7/8' 6.4# N-!~D Butt Tubing alter 3-H Packer at 2903' Profile at 2948' (2.312 ID) sleet WL Reentry Guide at 2982' ;ement Retainer at 3225' :ement Plug 3360' -3508' $62' -6882' Sgz'd 200 SX ` ~ish #1 BHA Total Length 228' probably on Bottom at 10,064' ~lsh #2 2206' of 2 718° Q.P. 'op @ 7495' Bottom ®9701' :~ #3 W.O. Assy & D.C.'s Length 380" 'op @7345' Bottom @7725' ~ish #4 2876' 2-2/3' TBG &3200' 3 i/2' D,P. 'op @3510' Bottom @8686' ;ement Plug 7600' -9927' ;ement Plug 10,100' -10,350' Cement Plug 10,650' -10,900' TD =10,958' Attachment 12: IRU 14-31 Well Schematic 0' 2~ rt C7 rt W N C W W C~ G n ~_ n ~~ D H R '~ a ~ ~ ~ $ ~R ~~~ ~~~ w~a a ~' ~ ~ ~s~ ~s~ ~~~ o~$~ ®D© ooo®o S ~ T m o n m D o '~ ~' ~ < 1~ ~ ~~ m m P~ c m~~ 5 K O y n ~~v~L~L~~ ~a4y~iS+~°~R~'~g8H 9 ~~ $ ~~~ ~~~~~n ~ ' o Ki ~ {y y ~ .-. Q $~~~~~~~ ~ R~~ ~e~~ ~~~' ~oae8~ y, F ~~ ~ '~° N~ ~g ~~ ~ s $~4 ~„ ~ r, ~+.«I m p o S u ° y o~ .A7 ~ c, ~// ~~i~~, --= - - _ _-_ _.. I I ~ Y o ~~ 3 ~ u ~_ y ~ ~ c~i n `~ ~ ~~~~ .. 7 ~ ~ ~ ~ ~ N N ~ > ° ~gS ~ ~ F ~ y _ ~ - 4 $ ~ ~ ~8~ O ~ ~ ~ m g ~ 4 s o 4 o o o ~ ~ ~ a o ~ ^ g ~ N - , ~ u Q ~ m ~ ~~ ~~ ~ ° s ~ a i ~ ~i -+ 3- 5 n ~ .9C ~' ~~ • Chevron IRU 11-081van River Unit I ,sv- PermIt100tlIIM: 208-0H LNS! d SlrIaIP: ADL-002900 FIeW: Iv;ul River Unit APIe. 50-283-20130-00 ORIGINAL RIG Surixe Lowlron Wen ClasslncatoB Deveblznent Gas Wea ELEVATIONS 585' FSL 8 630' FEL ToGll De m'. 10,060' Set 1 T13N R9W,SM PBTD: 9,926' R103-GL X: ASP4 359.785 Tubing: 3-'/.". 9.2N, LAO, IBT-M0o T 16.60' v' ASP4 2,646,275 TuM 2-Y.", 4 6#, LAO, IBT(SCC) R103-MSL Well Stable: Shul-kl Pm0 Pkrs' (1) 7" Baker MoOel "SC-2' MetltanlUl Set Pkr 46 90' ~I ~ Operalof: UOCC Ownership: Draon OI Canparry of t:allfamla 100% OL-MSL' 30.00' Spuo Da te: 1222N8 2:00 PM 17 '.' r;u RX&MSL- 46.80' Otna: Sputa Dec 2008; Rig Release Feb 2009: Coi Tubkg Mar 2008, Top Job BHP' 3698 i ~ 1006 0' MD SNCkline Apr 2008 15.B ppq t5l,•. BHT'. 134' 10,060 'MD Pralwry Cmt 130ppq 552 sx Dlscnpaan WeIgM Grace Conn b Length Top Btln TOC 1e. 1,016' Csg Strutlufal 20" 129.00 X-56 Wep 19.124" 771' 0' 171' DMen 16.5 hrs Cml above DV - Surtace 133/8' 68.0! LAO BTC 12415" 1,076' 0' 1,016' Surf 91.0 hrs 900'3487' I Intemleoiate 95/8' 40.0! L-80 BTC 3.681" 6015' 0' 6,015' 900' 163.5Irs 125 ppg 642 sx II Proouckm T 26.0! L-80 BTC-Moo 6276" 6,195' 5,825' 10,020' 8,118' DO hrs OV Cdlar 3,4BT MD Cmt bebw DV '~ 4,100b,120' :~ Tubrp 31/2' 92e L-80 IBT~M00' 7992' 9,495' 0' 9,495' 12 0 ppg 397 sx 2 3/8' 4ba L-80 IBT 1.995" 3,501' 0' 3,501' • - scc s lal cleara nce ) tl > A . D! on De n u to to oD 1 Tubin Ma , 3-trz' NSCO UnlleaC 11" 5M, 3' Type H BPV iT 0 49 7000" 11.000' 2 HaIIWINton 'H' ES DV Cdlar (CkzseO 1/16N9 3,687' 780' 8.601' 10 625' ' e 3 9-5/8"Baker ZXP packer (set 7/4/09) 5,825' 1853' 6285' 8.310' 4 • 9-5/8'Y7' BaKa Flex-Lack III liner tN (set 774/09) 5,844' 9 69' 6.275" 8.310' . 5 Baker MoOel °SC-2' Retrievable Packer (se17110/09) 5,915' 5.45' 4000 " 5960' ~ ' 7 6 Bakes Moael 80.40 Seatoere w/ GBH-22 Seal Assemdy 5920' 9 07 4000 " 5.000' 6,015' Csg 7 MalNburton OuraSleeve Skakg Sleeve (Ck>seo 4/3~D9) 5,970' 454' 2.813 " 4500' 8 Halkburtdt PoneO SW wl Glass Disk 9,at8' 069 7992 " 4.187' 9 MaIGWZ'bn WLEG w/7CP AUto-Release 9,483' 12.07 2.997 4.250' TOC (USR Log) 10 tl8atable BP (taggeA 36' deeper Iran setlag oep01 7/15A9) 9,666' 13.1' 6,718' MD 11 Haltiburton 4-513' TCP Assem (Pert 4/4/09. T 4f6109) 9,716' 204 00' - 4.625' 4,997 TVD 12 PBTD - Top d T Fbal equyzrenl (Tagged 7/6N9) 9.926' - 12 0 ppg 432 Sx oee 4k1 Fbat Str ) a MWeshoecuon - z-3B-tutxg 3.sor ZOIN Top Bull AOti Outs Stu EPF Phae Siaba Dab A T 9.545 9,576' 31' 4-510' 6 60 O 414A9 5/10A9 A Tyonek 9.537 9,609 2T 4-5/8" 6 60 Open 4/4A9 Repot 5110109 B 9.618' 9,698' 59 4-578' 6 60 Open 4141091so1a(etl?? - t0 t t 4 12 1D.073 Csg -- ~ ___ 10;367 TLD - , :...'::•.....'~.. MUD 10.1 ppg CvruK aelB fcllanatlc f44~OB Pfep30D B5" C117G Kenya Attachment 14: IRU 11-06 Well Schematic