The URL can be used to link to this page

Home My WebLink AboutDIO 020Image Project Order File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. I ~ ~0 Order File Identifiier Organizing (done> RE CAN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: BY: Maria ..~ Project Proofing BY: Ml aria 1 .wo,aea iiiimmmuui DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type: Date: ~/ Date: Scanning Preparation x 30 BY: Maria Date: Production Scanning ~e,~,~eedee iuumiiiiiuii OVERSIZED (Scannable) Maps: her Items Scannable by a Large Scanner l,,.p Q~ OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: /s/ _ + =TOTAL PAGES ~~ /~ ~ (Count does not include cover sheet) IIIIIIIIIIIIIIIIIII D /s/ D /s/ IIIIIiIIIIIIII IIIII Stage 7 Page Count from Scanned File: ~~~q (Count does include cover heet) Page Count Matches Number in Scannin Preparation: ___~ES NO BY: Maria Date: ~ ~/ /~ /s/ (/V' I Y ~ Y Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III IIIII IIIII II III ReScanned III II'II) I I III I I III BY: Maria _ Date: Comments about this file: /s/ a a„~~e~~.d imummimiii 10/6/2005 Orders File Cover Page.doc DISPOSAL INJECTION ORDER #20 GRANITE POINT FIELD 1. May 14, 1999 2. June 9, 1999 3. June 24, 1999 4. July 16, 1999 5. Apri124, 2000 6. September 19, 2002 7. October 30, 2002 8. October 31, 2002 9. September 27, 2004 Unocal's AEO Application, Confidential portion located in confidential room Unocal's submittal of Amendment to Application Ocean Energy Affidavit of Mailing Notice of Hearing, Affidavit of Publication and bulk mailing list Compliance information filed by Ocean Energy Evergreen's request for Administrative Approval Evergreen's Analytical Results of Support for Administrative Approval to inject cement rinsate in the Pioneer Unit Injection Order No #20 1702-15DA WDW Well UIC File Review Proposal to amend underground injection order DISPOSAL INJECTION ORDER #20 • ' _ l y~ ~ ,,~ ~ 1{,'~a~ ~ ~ i ~ ; I~ i j ~ ~~ '' ~ a ~ 1 a ~ f ~+ ~ ;~ FRANK H. MURKOWSKI, GOVERNOR ~`: :. ,. ,... ~ .•.:..d :~.~ ~~~ 'sue' ~~~~ ~~~~++ ~1~ ~~~+ a ~+ ~A-7~ OIL A1QD t7rs'aa7 ?I{ 333 W. 7"' AVENUE, SUITE 100 COIQ9ER~ATIOI~T COMirIISSIOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 27&7542 September 27, 2004 Proposals to Amend Underground Injection Orders to Incorporate Consistent Language Addressing the Mechanical Integrity of Wells The Alaska Oil and Gas Conservation Commission ("Commission"), on its own motion, proposes to amend the rules addressing mechanical integrity of wells in all existing area injection orders, storage injection orders, enhanced recovery injection orders, and disposal injection orders. There are numerous different versions of wording used for each of the rules that create confusion and inconsistent implementation of well integrity requirements for injection wells when pressure communication or leakage is indicated. In several injection orders, there are no rules addressing requirements for notification and well disposition when a well integrity failure is identified. Wording used for the administrative approval rule in injection orders is similarly inconsistent. The Commission proposes these three rules as replacements in all injection orders: Demonstration of Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before injection begins, at least once every four years thereafter (except at least once every two years in the case of a slurry injection well), and before returning a well to service following a workover affecting mechanical integrity. Unless an alternate means is approved by the Commission, mechanical integrity must be demonstrated by a tubing/casing annulus pressure test using a surface pressure of 1500 psi or 0.25 psi/ft multiplied by the vertical depth of the packer, whichever is greater, that shows stabilizing pressure and does not change more than 10 percent during a 30 minute period. The Commission must be notified at least 24 hours in advance to enable a representative to witness mechanical integrity tests. Well Integrity Failure and Confinement Whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, log, or other evidence, the operator shall immediately notify the Commission and submit a plan of corrective action on a Form 10-403 for Commission approval. The operator shall immediately shut in the well if continued operation would be unsafe or would threaten contamination of freshwater, or if so directed by the Commission. A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating well integrity failure or lack of injection zone isolation. Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. The following table identifies the specific rules affected by the rewrite. Affected Rules Injection Order "Demonstration of "Well Integrity "Administrative Mechanical Failure and Action" Integrity" Confinement" Area In'ection Orders AIO 1 -Duck Island Unit 6 7 9 AIO 2B - Kuparuk River Unit; Kuparuk River, Tabasco, Ugnu, West Sak 6 ~ 9 Fields AIO 3 -Prudhoe Bay Unit; Western Operating Area 6 ~ 9 AIO 4C -Prudhoe Bay Unit; Eastern Operating Area 6 ~ 9 AIO 5 -Trading Say Unit; McArthur River Field 6 6 9 AIO 6 -Granite Point Field; Northern Portion 6 ~ 9 AIO 7 -Middle Ground Shoal; Northern Portion 6 ~ 9 AIO 8 -Middle Ground Shoal; Southern Portion 6 ~ 9 AIO 9 -Middle Ground Shoal; Central Portion 6 ~ 9 AIO 1 OS -Milne Point Unit; Schrader Bluff, Sag River, 4 5 g Kuparuk River Pools AIO 11 -Granite Point Field; Southern Portion 5 6 8 AIO 12 -Trading Bay Field; Southern Portion 5 6 8 AIO 13A -Swanson River Unit 6 ~ 9 AIO 14A -Prudhoe Bay Unit; Niakuk Oil Pool 4 5 8 AIO 15 -West McArthur 5 6 9 Affected Rules Injection Order "Demonstration of "Well Integrity "Administrative Mechanical Failure and Action" Integrit " Confinement" River Unit AIO 16 - Kuparuk River Unit; Tarn Oil Pool 6 7 10 AIO 17 - Badami Unit 5 6 8 AIO 18A -Colville River Unit; Alpine Oil Pool 6 7 11 AIO 19 -Duck Island Unit; Eider Oil Pool 5 6 9 AIO 20 -Prudhoe Bay Unit; Midnight Sun Oil Pool 5 6 9 AIO 21 - Kuparuk River Unit; Meltwater Oil Pool 4 No rule 6 AIO 22C -Prudhoe Bay Unit; Aurora Oil Pool 5 No rule 8 AIO 23 - Northstar Unit 5 6 9 AIO 24 -Prudhoe Bay Unit; Borealis Oil Pool 5 No rule 9 AIO 25 -Prudhoe Bay Unit; Polaris Oil Pool 6 g 13 AIO 26 -Prudhoe Bay Unit; Orion Oil Pool 6 No rule 13 Dis osal Injection Orders DIO 1 -Kenai Unit; KU WD-1 No rule No rule No rule DIO 2 -Kenai Unit; KU 14- 4 No rule No rule No rule DIO 3 -Beluga River Gas Field; BR WD-1 No rule No rule No rule DIO 4 -Beaver Creek Unit; BC-2 No rule No rule No rule DIO 5 -Barrow Gas Field; South Barrow #5 No rule No rule No rule DIO 6 -Lewis River Gas Field; WD-1 No rule No rule 3 DIO 7 -West McArthur River Unit; WMRU D-1 2 3 5 DIO 8 -Beaver Creek Unit; SC-3 2 3 5 DIO 9 -Kenai Unit; KU 11- 17 2 3 4 DIO 10 -Granite Point Field; GP 44-11 2 3 5 Affected Rules Injection Order "Demonstration of Mechanical Integrity" "Well Integrity Failure and Confinement" "Administrative Action" DIO 11 K i - ena Unit; KU 24-7 2 3 4 DIO 12 B d - a ami Unit; WD- 1, WD-2 2 3 5 DIO 13 N - orth Trading Bay Unit; S-4 2 3 6 DIO 14 H - ouston Gas Field; Well #3 2 3 5 DIO 15 N - orth Trading Bay Unit; S-5 2 3 Rule not numbered DIO 16 W - est McArthur River Unit; WMRU 4D 2 3 5 DIO 17 N - orth Cook Inlet Unit; NCIU A-12 2 3 6 DIO 19 -Granite Point Field; W. Granite Point State 17587 #3 3 4 6 DIO 20 -Pioneer Unit; Well 1702-15DA WDW 3 4 6 DIO 21 - Flaxman Island; Alaska State A-2 3 4 7 DIO 22 -Redoubt Unit; RU D T 3 No rule 6 DIO 23 -Ivan River Unit; IRU 14-31 No rule No rule 6 DIO 24 - Nicolai Creek Unit; NCU #5 Order expired DIO 25 -Sterling Unit; SU 43-9 3 4 7 DIO 26 - Kustatan Field; KF 1 3 4 7 Storage Injection Orders SIO 1 -Prudhoe Bay Unit, Point McIntyre Field #6 No rule No rule No rule SIO 2A- Swanson River Unit; KGSF #1 2 No rule 6 SIO 3 -Swanson River Unit; KGSF #2 2 No rule 7 Enhanced Recove In'ection Orders EIO 1 -Prudhoe Bay Unit; Prudhoe Bay Field, Schrader Bluff Formation Well V-105 No rule No rule g C~ Injection Order "Demonstration of Mechanical • Affected Rules "Well Integrity Failure and Confinement" "Administrative Action" ~ EIO 2-Redoubt Unit; RU-6 ~ 5 g 9 02-902 (Rev. 3/94) Publisher/Original Copies: Department Fiscal, Department, Receiving AO.FRM STATE OF ALASKA NOTICE TO PUBLISHER ADVERTISING ORDER NO. ADVERTISING INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTIFIED /~ ORDER AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COPY OF AO-02 5'14016 ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE SEE BOTTOM FOR ENVOICE ADDRESS F AOGCC R 333 West 7th Avenue, Suite 100 ° Anchorage, AK 99501 M 907-793-1221 AGENCY CONTACT DATE OF A.O. ~_~ - ADVERT[SEMENT REQUIRED: T Journal of Commerce 0 301 Arctic Slope Ave #350 Anchorage, AK 99518 October 3, 2004 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPEC[ALINSTRCCTIONS: ~ AFFIDAVIT OF PUBLICATION ~ United states of America State of ss • division. Before me, the undersigned, a notary public this day personally appeared who, being first duly sworn, according to law, says that he/she is the Published at state of of in said division and and that the advertisement, of which the annexed is a true copy, was published in said publication on the day of 2004, and thereafter for consecutive days, the last publication appearing on the day of .2004, and that the rate charged thereon is not in excess of the rate charged pl7vate individuals. Subscribed and sworn to before me This -day of 2004, REMINDER INVOICE MUST BE IN TRIPLICATE AND MUST REFERENCE THE ADVERTISING ORDER NUMBER. A CERTIFIED COPY OF THIS AFFIDAVIT OF PUBLICATION MUST BE SUBMITTED WITH THE INVOICE. ATTACH PROOF OF PUBLICATION HERE Notary public for state of My commission expires _ Public Notices Subject: Public Notices From: Jody Colombe <jody_colombie@admin.state.ak.us> Date: Wed, 29 Sep-2004 13:01:04-0800 To: undisclosed-recipients:; BCC: Cynthia B ~tci<<er ~.bren_mcver@admin.state.ak.us>, Angela `Webb <ange_~~-ebbl~iadmin.state.ak.us> Robert E Mintz <robert_mintz~a?law.state_ak.us>, Christine Hansen <c.hansen@<iogec.state.ok.us>, Terrie Hubble <hubbletl(ubp.com>, Sondra Stewman <Ste~vmaSD@BP.com>, Scott & Carr~my ~Etylor <staylor(~~.ataska.net>, stanekj <stanekj(~unocal.com~, ecalaw <eeolaw@trustees.org>, roseragsdale ~roseragsdale~a`,gci.net>, trmj;rl <trmjri a~aol.co~>, jbrddle <jbriddle@marathc~noit.com~ rockhill -~rockllill@~aoga.org>, shaneg <shaneg@evergreengas.cam>, jdarlington <jdarlington(g!forestoil.com>, nelson <knelson@petroleumr~ews.com>, ebo~€dv <cboddy@,usibelli.com>, Mask Dalton <mark.dalton@hdrinc.com=~, Sharulon Donnelly zshannon.donnelly(~i~conocophillips.com>, "iVlark P. Worcester"`<rnark.p.Worcester«~?ccinocophillil~s.com>, "Jem' C'. Dethlefs" <j~rly.c.dethl.efs@conocophillips.cor~>, Bole <bob~cuinletkeeper.org>, wdv <wd~~ ci;;dnr.state.ak.us>, tjr <tjrC~z dnr:~tate.alc.us>, bbritch <bbritch@laska.net>, mjnelson <mjnelson(~zpurvingertz.corn>, Charles Q'Donnell <charles_o'donnell@veco.com>, "Randy L. Skillern" ~Ski11eRL~uBP.com> "Deborah J. Jonest' <JonesDfi@BP.eom>, "Paul C. Hyatt" <hyattp~;@BP.com>. "Steven-R. Rossberg" <RossbeRS@BP.EQxn= , Lais <lois@nletke~per.org>, Dan Bross ~~k-tiacnews@kuac.org>, Gordon Pospisil <PospisG~a BP.com>, "Francis S. Sommer" <Somn~erP'S@;BP.com>, Mikel Schulte. <MikeLSchultz@BF.com>, "Nick tiV. Clover" ~GloverN~V~`BP.com>, "Daryl J. K~eppin" <KleppiDE@$P.coni ~; ' ;lanet D. Play" <PlattJD~~i.!BP.com>, "Rosanne ~ti2. 3acobsen" <JacobsRNS ciiBP.com%, ddonkel ~ddonkel@cfl.rr.eom=. Collins tilount eollins_mount(u;rev~eriue.state_ak.us>, mekay <tnckay(u,gci.net>, Barbara F Fullmer <Barbara.f:fullmer@conoeophillips.com>, bocastwf <bocastE~~f~~i?bp.com>, Charles Barker . <barker@tsgs.gr~v>, doug_schtltze <c1ouR'' schuttze(u)xtoenergy_com>, Hank Alfi~rd hank.alford@e:~.xanrnobiLcom>,?~IarkKovae~<yesnol@gci.net>, gspfoff <gsgfaff@atu-orapc~wer.com>, Gregg Nady <gregg.nady@ shell.com>, Fred Steece <fred.steeee cz statesd.u~ ~, rcrotty <rcrotty(cch2m.com>, jejones < jejon~sfa)aurorapo~ver.eom>, dapa <dapa~%alaska.net>, jroderick <jroderi~k~c~;gci.net=-, eyancy <eyancy@..seal-tite.net>, "James Inf. kuud" ~james.m.ntud~ci~conocophillips.com>, Brit Lively <mapalaska@,ak.net>, jah <jah(adnr.state.ak.us=>, Kurt FOlson -'k~rt_olson@legis.state.ak.us=~, buonoje ~~buonoje'a bp.cc>m>, Mark Hanley <~ark_hanley@~anadirko.com>, loren_leman <Loren_leman(ajgo~r.state.ak.us>. Juiie Houle'<Julie_houle(~.dnr.stat~.~k.us>, John W Katz <jwkatz~~i~sso.org>, Suzan J Hill <suzan hill@dec.state.ak.us>, tablerk ~ tablerk~;unocal.com>, Brady ~brady(aaoga.orQ ~, Brian Havelock ~6eh~cL~~.dnr.state.ak.us>. bpopp <bpopp(~%~boraugh.kenai.ak.us>, Jim White <jimw~lite(~satx.rr.com>, "John S. Haworth" <john.s.haworth(ci~,eY~onmobil.com>, marty <marty(arkindustriaLcom>, ghammons <ghammons@aol.com>, rmclean <rmclean(tipobox.alaska.net>, mkm720t) <m1:m72C-0(g~aol.com>, Brian Gillespie <ilbmg(ciuaa.alaska.edu>, David L Boelens <dboelens(a;!aurorapower.com>, Todd Durkee <TDURKEE(aKMG.com>, Gary Schultz <gary schultz(~~,dnr.state.ak.us>, Wayne Rancier <RAN~I~R~a~petro-canada.ca>, Bitl Miller <Bi11_Miller@-xtoalaska.com>. Brandon Gagnon <bgagrfon@brenalaw.com>, Paul Winslow <pmwinslow@~.forestoil.com>, Garry' Catron <catrongr@;bp.com>, Sharmaine Copeland <copelasv@bp.com>, Suzanne Allegan <salLe~an~a?helmenergy.com>, Kristin Dirks <kristin_dirks@dnr.state.ak.us>, Kavnell Zeman. <kjzeman@~,marathonoil.eom>, John Tower ~John.To~wer@eia.doe.gov>, Bill Fowler <Bi1i_Fowler@anadarko.COl~i>, Vaughn Swartz ~vaughn.swartzrirbccm.com--~, Scott C'ranswick 1 of 2 9/29/2004 1:10 PM Public Notices • <scott.cranswick@mms.gov>,-Brad McKim <mckimbs@BP.corn> Please find the at ached Notice and Attachment for the proposed amendment of underground injection orders and the Public Notice Happy Valley #10. .Jody Colombie Content-Type: appicatian;'msword 'Mechanical Integrity proposal.dac Content-Encoding:-base64 ..Mechanical Integrity of Wells Notice.dac' Content=Type: applcatiorvmsword Content-Encoding: base6=i Content-Type: apptcatior~'msword IlappyValleyl0_HearingNatice.doc Content-Encoding: base64 2 of 2 9/29!2004 1:10 PM Public Notice Subject: Public Notice From: Jody Colombie <jody_colombie@admin.state.ak.us> Date: Wed, 29 Sep 2004 12:55:26 -0800 T a: legal @alaskaj ournal. com Please publish the attached Notice on October 3, 2004. Thank you. Jody Colombie i Content-Type: application/msword 'Mechanical Integrity of Wells Notice.doc i Content-Encoding: base64 __ ____ .Content-Type: application/msword Ad Order form.doc Content-Encoding: base64 I 1 of 1 9/29/2004 1:10 PM Cit o Petroleum C ti g orpora on Mary Jones David McCaleb PO Box 3758 XTO Energy, Inc. IHS Energy Group Tulsa, OK 74136 Cartography GEPS 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 Ft. Worth, TX 76102-6298 Houston, TX 77056 Kelly Valadez Robert Gravely George Vaught, Jr. Tesoro Refining and Marketing Co. 7681 South Kit Carson Drive PO Box 13557 Supply & Distribution Littleton, CO 80122 Denver, CO 80201-3557 300 Concord Plaza Drive San Antonio, TX 78216 I~ Jerry Hodgden Richard Neahrin 9 John Levorsen i Hodgden Oil Company NRG Associates 200 North 3rd Street, #1202 408 18th Street President Boise, ID 83702 Golden, CO 80401-2433 PO Box 1655 Colorado Springs, CO 80901 Kay Munger Samuel Van Vactor Michael Parks Munger Oil Information Service, Inc Economic Insight Inc. Marple's Business Newsletter PO Box 45738 3004 SW First Ave. 117 West Mercer St, Ste 200 Los Angeles, CA 90045-0738 Portland, OR 97201 Seattle, WA 98119-3960 Mark Wedman Schlumberger David Cusato Halliburton Drilling and Measurements 200 West 34th PMB 411 6900 Arctic Blvd. 2525 Gambell Street #400 Anchorage, AK 99503 Anchorage, AK 99502 Anchorage, AK 99503 Baker Oil Tools Ciri Jill Schneider 4730 Business Park Blvd., #44 Land Department US Geological Survey Anchorage, AK 99503 PO Box 93330 4200 University Dr. Anchorage, AK 99503 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 Williams Thomas North Slope Borough Arctic Slope Regional Corporation PO Box 69 Land Department Barrow, AK 99723 PO Box 129 Barrow, AK 99723 r [Fwd: Re: Consistent Wording for Injection ~rs -Well Integrity ... Subject: [Fwd: Re: Consistent Wording for Injection Orders - From: John Norman <john_norman@admin.state.ak.us> Date: Fri, 01 Oct 2004 11:09:26 -0800 To: Jody) CoIombie <jody colombie@adrnin.state.ak.us> more Well Integrity (Revised)] ------- Original Message -------- Subject:Re: Consistent Wording for Injection Orders -Well Integrity (Revised) Date:Wed, ZS Aug 2004 16:49:40 -0800 From:Rob Mintz <robert mintzna,law.state.ak.us> To:jim regg(a~admin.state.ak.us CC:dan seamount ~r,admin.state.ak.us, john norman(c~,admin.state.ak.us Jim, looks good, but I still think maybe it would be good to include the following sentence or something like it in the well integrity and confinement rule: "The operator shall shut in the well if so directed by the Commission." My thinking is that otherwise, an operator might argue that the Commission can only require the well to be shut in by going through an enforcement action, issuing an order after notice and opportunity for hearing, or meeting the strict requirements for an emergency order under the regulations. The proposed language makes clear that it is a condition of the authorization to inject, that the operator must shut in the well if directed by the Commission after a notification of loss of integrity, etc. »> James Regg <iim regg~~admin.state.ak.us> 8/25/2004 3:15:06 PM »> Rob -Thanks for the review; here's a redraft after considering your comments. I have accepted most of the suggested edits; also attached is response to questions you pose (responses are embedded in the comments, using brackets [JBR - ...] to set apart from your questions). Jim Regg Rob Mintz wrote: Jim, I have some questions about the draft language, which aze shown as comments on the first document attached. Based on my current guesses about what the answers will be to my questions, I also have some suggested edits, which are shown as redlines on the second document attached. »> James Regg <jim reQh(~admin.state.ak.us> 8/17/2004 4:33:52 PM »> Please delete previous version (email sent 8/9/04); I found another inconsistency in the injection orders regarding well integrity that I have integrated into the proposed fix. Attached is a proposal for consistent language in our injection orders addressing 3 rules related to well integrity: - "Demonstration of Tubing/Casing Annulus Mechanical Integrity" - "Well Integrity Failure" - "Administrative Actions". This proposal includes input from all Sr. staff (except Jack). If you agree with the approach, I'll work with Jody to prepare the public notice. Main points - Demonstration of Tubing/Casing Annulus Mechanical Integrity - standardizes the wording used for mechanical integrity demonstrations, and establishes abililty to grant alternate methods (e.g., temp survey, logging, pressure monitoring in lieu of pressure testing 1 of 2 10/2/2004 4:07 PM [Fwd: Re: Consistent Wording for Injection~rs -Well Integrity ... • - specific to AIO 2C for Kuparuk, there is wording that is more appropriately included in Well Integrity Failure (i.e., more frequent MITs when communication demonstrated) - establishes more frequent MIT schedule for slurry injection wells (every 2 yrs) which is consistent with our current practice (but not addressed in regulations) Well Integrity Failure - retitles to "Well Integrity Failure and Confinement"; inserted language regarding injection zone integrity (see DIO 25 and 26) - consistent language regardless of type of injection (disposal, EOR, storage); - eliminates requirement for immediate shut in and secure; allows continued injection until Commission requires shut in if there is no threat to freshwater; - eliminates delay in notifying Commission after detect leakage or communication ("i.e., "immediately notify"); - removes language about notifying "other state and federal" agencies; - requires submittal of corrective action plan via 10-403; - requires monthly report of daily injection rate and pressures (tubing and all casing annuli); this is a requirement we currently impose when notified of leak or pressure communication; - notice and action not restricted to leaks above casing shoe as stated in several DIOs Administrative Actions - adopts "Administrative Actions" title (earlier rules used "Administrative Relief'); -consistent language regardless of type of injection (disposal, EOR, storage); - uses "administratively waive or amend" in lieu of terms like "revise", "reissue", etc.; - adds geoscience to "sound engineering principles"; - language is more generic regarding fluid movement out of zone; existing versions mention varying combinations of protecting "freshwater", "aquifers", "USDWs"; "risk of fluid movement"; "fluid escape from disposal zone" Jim Regg ._......._..._........._...__..___...... '! John K. Norman <John Norman(u~admin.state.us> Commissioner Alaska Oil & Gas Conservation Commission _.._ ___ _ _ _ _ 2 of 2 10/2/2004 4:07 PM .[Fwd: Re: Consistent Wording for Injection ~s -Well Integrity ... Subject: -[Fwd: Re: Consistent Wording for Injection Orders -Well Integrity (Revised)] From: John lVorrnan <john_nortnan@admin.state.ak.us>' Date: Fri, Ol Oct 2004 11:08:55 -0800 To: 3ody J Calornbie <jolly_colombe@admin.state.akus> please print all and put in file for me to review just prior to hearing on these amendments. thanx ------- Original Message -------- Subject:Re: Consistent Wording for Injection Orders -Well Integrity (Revised) Date:Thu, 19 Aug 2004 15:46:31 -0800 From:Rob Mintz <robert mintz~law.state.ak.us> To:dan seamount(a~admin.state.ak.us, jim re~g(a,admin.state.ak.us, john norman(c~admin.state.ak.us Jim, I have some questions about the draft language, which are shown as comments on the first document attached. Based on my current guesses about what the answers will be to my questions, I also have some suggested edits, which are shown as redlines on the second document attached. »> James Regg <jim re~g~admin.state.ak.us> 8/17/2004 4:33:52 PM »> Please delete previous version (email sent 8/9/04); I found another inconsistency in the injection orders regarding well integrity that I have integrated into the proposed fix. Attached is a proposal for consistent language in our injection orders addressing 3 rules related to well integrity: - "Demonstration of Tubing/Casing Annulus Mechanical Integrity" - "Well Integrity Failure" - "Administrative Actions". This proposal includes input from all Sr. staff (except Jack). If you agree with the approach, I'll work with Jody to prepare the public notice. Main points - Demonstration of Tubing/Casing Annulus iVlechanical Integrity - standardizes the wording used for mechanical integrity demonstrations, and establishes abililry to grant alternate methods (e.g., temp survey, logging, pressure monitoring in lieu of pressure testing - specific to AIO 2C for Kuparuk, there is wording that is more appropriately included in Well Integrity Failure (i.e., more frequent MITs when communication demonstrated) - establishes more frequent MIT schedule for slurry injection wells (every 2 yrs) which is consistent with our current practice (but not addressed in regulations) Well Integrity Failure - retitles to "Welt Integrity Failure and Confinement"; inserted language regarding injection zone integrity (see DIO 25 and 26) - consistent language regardless of type of injection (disposal, EOR, storage); - eliminates requirement for immediate shut in and secure; allows continued injection until Commission requires shut in if there is no threat to freshwater; - eliminates delay in notifying Commission after detect leakage or communication ("i.e., "immediately notify"); - removes language about notifying "other state and federal" agencies; - requires submittal of corrective action plan via 10-403; - requires monthly report of daily injection rate and pressures (tubing and all casing annuli); this is a requirement we currently impose when notified of leak or pressure communication; - notice and action not restricted to leaks above casing shoe as stated in several DIOs Administrative Actions 1 of 2 10/2/2004 4:07 PM [Fwd: Re: Consistent Wording for Injection~rs -Well Integrity ... • . - adopts "Administrative Actions" title (earlier rules used "Administrative Relief'); - consistent language regardless of type of injection (disposal, EOR, storage); - uses "administratively waive or amend" in lieu of terms like "revise", "reissue", etc.; - adds geoscience to "sound engineering principles"; - language is more generic regarding fluid movement out of zone; existing versions mention varying combinations of protecting "freshwater", "aquifers", "USDWs"; "risk of fluid movement"; "fluid escape from disposal zone" Jim Regg John K. Norman <John Norman(a~admin.state.us> Commissioner Alaska Oil & Gas Conservation Commission ___ _ _. _ _ ....._ Content-Type: application/msword :Injection Order language - questions.doc Content-Encoding: base64 _ _. _. Content-Type: application/msword ;Injection Orders language edits.doc Content-Encoding: base64 2 of 2 10/2/2004 4:07 PM • • Standardized Language for Injection Orders Date: August 17, 2004 Author: Jim Regg Demonstration of Tubin /g Casing Annulus Mechanical Inte rity The mechanical integrity of an injection well must be demonstrated before injection begins, after a workover affecting mechanical integrity, and at least once every 4 years while actively injecting. For slurry injection wells, the tubing/casing annulus must be tested for mechanical integrity every 2 years. The MIT surface pressure must be 1500 psi or 0.25 psi/ft multiplied by the vertical depth, whichever is greater, must show stabilizing pressure and may not change more than 10% during a 30 minute period. Any alternate means of demonstrating mechanical integrity must be approved by the Commission. The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests. Well Integrity Failure and Confinement The tubing, casing and packer of an injection well must demonstrate integrity during operation. The operator must immediately notify the Commission and submit a plan of corrective action on Form 10-403 for Commission approval whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, or log. If there is no threat to freshwater, injection may continue until the Commission requires the well to be shut in or secured. A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating pressure communication or leakage. Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. Standardized Language for Injection Orders Date: August 17, 2004 Author: Jim Regg Demonstration of Tubing/Casing Annulus Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before injection begins, at least once every four years thereafter (except at least ones every two years in the case of a slurry injection well) and before returning a well to sen•ice folla~vin~ r a workover affecting mechanical integrity ~~' •~* 1, °•* ~~ •~"~~~ ~*~ ~ ~ ~ .+~ ~,,,. ~.,rr=. ~•~ •L1~ 111, Litilll V. t7nless an alternate means is approved by the Coi~lission mechanical integrity must be dei~nonstaated by a tubing pressure tc5t using a ~ ?-~~surface pressure ~f:s~-1~ 1500 psi or 0.25 psi/ft multiplied by the vertical depth, whichever is greater, t11at m~~-shows stabilizing pressure that doesand-may not change more than 10°=8- percent during a 30 minute period. -may ~, .. - . The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests. Well Inte~y Failure and Confinement Except as otherwise provided in this rule Tthe tubing, casing and packer of an injection well must ' * • * .maintain integrity during operation. ~~Thenever any pressure communication leakage c?r lack of infection zone isolation is indicated by injection rate operating pressure observation, test, survey log or other evidence the operator shall immediately notify the Commission and submit a plan of corrective action on a Form 10-403 for Commission approval, • ~ ,~ .` , ,', .The operator shall shut in the well if so directed by the Commission The operator shall shut in the well without a~vaitin~ a response li-om the Commission if continued operation would be unsafe or would threaten contamination of freshwaterT~'*"°r° ~ ~ * *„ ~ ~~.~_ ~* . +~ t• ~~~ ~r... Llv ~ „v lu euc ~Z V 111 tai GL"CiI"Cd. C" "°' " ~' " ~ ' '~ * ' Until corrective action is successfully com le~ted, ,4a monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating pressure communication or leakage. Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. r ,[Fwd: Re: [Fwd: AOGCC Proposed WI Lan for Injectors]] Subiect: [Fwd: Re: [Fwd: AOGCC Proposed WI Language for Injectors]] From: Winton Hubert <winton aubert@adxnin.state.ak.us> Date: Thu, Z8 Oct 2004 09:48:53 -0800 To: Jody J Colombe <jody_calombie@adrr~in.state.ak.us> This is part of the record for the Nov. 4 hearing. WGA -------- Original Message -------- Subject: Re: [Fwd: AOGCC Proposed WI Language for Injectors] Date: Thu, 28 Oct 2004 09:41:55 -0800 From: James Regg <jim regg@admin.state.ak.us> Organization: State of Alaska To: Winton Hubert <winton aubert@admin.state.ak.us> References: <41812422.8080604@admin.state.ak.us> These should be provided to Jody as part of public review record Jim Winton Hubert wrote: FYI. -------- Original Message -------- Subject: AOGCC Proposed WI Language for Injectors Date: Tue, 19 Oct 2004 13:49:33 -0800 From: Engel, Harry R <Enge1HR@BP.com> To: winton aubert@admin.state.ak.us Winton... Here are the comments we discussed. Harry *From: * NSU, ADW Well Integrity Engineer *Sent: * Friday, October 15,.2004 10:43 PM *To: * Rossberg, R Steven; Engel, Harry R; Cismoski, Doug A; NSU, ADW Well Operations Supervisor *Cc: * Mielke, Robert L.; Reeves, Donald F; Dube, Anna T; NSU, ADW Well Integrity Engineer *Subject: * AOGCC Proposed WI Language for Injectors Hi Guys. John McMullen sent this to us, it's an order proposed by the AOGCC to replace the well integrity related language in the current Area Injection Orders. Listed below are comments, not sure who is coordinating getting these in front of Winton/Jim. Overall, looks okay from an Operations perspective. We do have a few comments, but could live with the current proposed language. Note the proposed public hearing date is November 4. The following language does not reflect what the slope AOGCC inspectors are currently requiring us to do: "The mechanical integrity of an injection well must be demonstrated before injection begins, at least once every four years thereafter (except at least once every two years in the case of a slurry injection well), and * before*_** 1 of 3 10/28/2004 11:09 AM [Fwd: Re: [Fwd: AOGCC Proposed WI Lane for Injectors]] return'.ng a well to service following a workover affecting mechanical integrity." After a workover, the slope AOGCC inspectors want the well warmed up and on stable injection, then we conduct the AOGCC witnessed MITIA. This language requires the AOGCC witnessed MITIA before starting injection, which we are doing on the rig after the tubing is run. Just trying to keep language consistent with the field practice. If "after" was substituted for "before", it would reflect current AOGCC practices. It would be helpful if the following language required reporting by the "next working day" rather than "immediately", due to weekends, holidays, etc. We like to confer with the APE and get a plan finalized, this may prevent us from doing all the investigating we like to do before talking with the AOGCC. "Whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, log, or other evidence, the operator shall* immediately*_** notify the Commission" This section could use some help/wordsmithing: "A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating well integrity failure or lack of injection zone isolation." Report content requirements are clear, but it's a little unclear what triggers a well to be included on this monthly report. Is it wells that have been reported to the AOGCC, are currently on-line and are going through the Administrative Action process? A proposed re-write would be: "All active injection wells with well integrity failure or lack of injection zone isolation shall have the following information reported monthly to the Commission: daily tubing and casing annuli pressures, daily injection rates." Requirements for the period between when a well failure is reported and when an administrative action is approved are unclear. This document states "the operator shall immediately notify the Commission and submit a plan of corrective action on a Form 10-403". If we don't plan to do any corrective action, but to pursue an AA, does a 10-403 need to be submitted? The AOGCC has stated they don't consider an AA as "corrective action". Let me know if you have any questions. Joe -----Original Message----- From: Kleppin, Daryl J Sent: Wednesday, September 29, 2004 1:37 PM To: Townsend, Monte A; Digert, Scott A; Denis, John R (ANC); Miller, Mike E; McMullen, John C Subject: FW: Public Notices FYI -----Original Message----- From: Jody Colombie [ mailto:j Sent: Wednesday, September 29, Subject: Public Notices dy_colombieQadmin.state.ak.us ] 2004 1:01 PM Please find the attached Notice and Attachment for the proposed amendment of underground injection orders and the Public Notice Happy Valley #10. Jody Colombie «Mechanical Integrity proposal.ZIP » «Mechanical Integrity of Wells Notice.doc » 4 2 of 3 10/28/2004 11:09 AM J~ t STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: THE APPLICATION OF OCEAN ENERGY RESOURCES, INC. ("Ocean Energy") for disposal of Class II oil field wastes by underground injection in the Pioneer Unit #1702-15DA WDW well. Disposal Injection Order No. 20 Well #1702-15DA WDW Pioneer Unit August 11, .1999 IT APPEARING THAT: 1. By correspondence dated June 28, 1999, Ocean Energy requested authorization from the Alaska Oil and Gas Conservation Commission ("Commission") to dispose of Class II oil field waste fluids by underground injection into the Pioneer Unit #1702-15DA WDW well, located in Section 15, Township 17 North, Range 2 West, Seward Meridian. 2. The Commission published notice of opportunity for public hearing in the Anchorage Daily News on July 2, 1999. A second notice of opportunity for public hearing was published in the Anchorage Daily News and the Frontiersman on July 16, 1999. 3. The Commission did not receive any protest or a request for a public hearing. 4. The proposed disposal project requires an aquifer exemption under 20 AAC 25.440 The Commission issued Aquifer Exemption Order #5 on June 29, 1999, after receiving no objection from the U.S. Environmental Protection Agency. FINDINGS: 1. Ocean Energy is the operator of the Pioneer Unit. There are no other operators within aone-quarter mile radius of the proposed disposal injection well. Ocean Energy has notified the surface owners by certified mail of the proposed disposal project. 2. Aquifer Exemption Order #5 exempts those portions of aquifers underlying the Pioneer Unit in Sections 14, 15, 22 and 23, Township 17 North, Range 2 West, which are common to and correlate with the interval below 2,790 feet in the BLT No. 1 well. Disposal Injection Order. 20 ~ Page 2 August 11, 1999 3. Ocean Energy proposes to conduct disposal injection within the proposed Pioneer Unit 1702-15DA WDW well in strata of the Tyonek Formation, which are common to' and correlate-with the interval below 2,790' in the BLT No. 1 well. 4. .The proposed disposal zone in the BLT #1 well is confined by over 700 feet of shale between the top of the disposal interval and the base of freshwater known to be used in the area. Similar confinement is anticipated at the proposed Pioneer Unit 1702-15DA WDW well location. 5. There are currently no other wells within one-quarter mile radius of the proposed Pioneer Unit 1702-15DA WDW well that penetrate the injection zone. 6. Specific injection intervals will be identified after the Pioneer Unit 1702-15DA WDW well is drilled and logged. Ocean Energy will analyze produced water samples following completion of the well to confirm that the aquifers meet the requirements for exemption specified in 20 AAC 25.440. Copies of the water analysis will need to be submitted to the Commission for concurrence. 7. A cement bond log will be run and cement records evaluated to ensure that the #1702-15DA WDW well is cemented adequately to isolate the proposed disposal interval. 8. The well will be completed with 133/s inch conductor set at 35 feet MD, 95/s inch surface casing set at 700 feet MD and cemented to surface, and 7 inch production casing set at 4,100 feet MD and cemented back into the surface casing. 9. The well will be equipped with 2'/s inch tubing string and packer set 50 feet above the top of the perforations or the uppermost disposal interval, whichever is shallowest. 10. Ocean Energy intends to utilize the Pioneer Unit 1702-15DA WDW well to dispose of fluids and drilling wastes from the coalbed methane test wells described in the "Pioneer Unit Plan of Operations" and the "Pioneer Unit-Vine Extension Plan of Operations." 11. The waste stream will consist of produced formation water, drilling, completion and workover fluids, rig wash, drilling mud slurries, and other Class II fluids generated from drilling, production, workover and completion operations. Although initially predominantly produced water, constituent volumes may vary depending on drilling, workover, stimulation and maintenance activity. 12. Ocean Energy estimates that the maximum daily volume to be injected will be 2,000 barrels per day. 13. Ocean Energy estimates the average and maximum injection pressure will not exceed 900 psi. 14. Ocean Energy will conduct periodic surveillance of disposal operations through temperature surveys, pressure transient tests, step rate tests, thermal decay time Disposal Injection Order. 20 ~ Page 3 August 11, 1999 logs, disposal rate and pressure monitoring, mechanical integrity tests and tagging effective depth to determine fill buildup. 15. _ Reservoir surveillance techniques will also be used for tracking near wellbore fluid movement, estimating dimensions of disposal fracture or disposal storage volume and detecting changes in disposal zone characteristics. 16. Evaluation of operational performance data and reservoir surveillance data will aid in preventing fracturing of the confining zones. CONCLUSIONS: The requirements of 20 AAC 25.252(c) have been met. 2. Those portions of aquifers underlying the Pioneer Unit in Sections 14, 15, 22 and 23, Township 17 North, Range 2 West, which are common to and correlate with the interval below 2,790 feet in the BLT No. 1 well, are exempt for Class II injection activities. 3. Waste fluids that are authorized for disposal in the Pioneer Unit 1702-15DA WDW well will consist exclusively of Class II waste generated from drilling, completion, workover and production operations. 4. Permeable strata, which are common to and correlate with the portion of the Tyonek Formation below 2,790 feet in the BLT No. 1, are likely to be present in the Pioneer Unit 1702-15DA WDW well. These strata can reasonably be expected to contain the total volume of disposal fluids anticipated for this project. 5. Waste fluids will be contained within appropriate receiving intervals by confining lithologies, cement isolation of the wellbore and operating conditions. 6. Disposal injection operations in the Pioneer Unit 1702-15DA WDW well will be conducted at rates and pressures below those required to fracture the confining zones. 7. Periodic surveillance of disposal material placement, daily monitoring of operating parameters when in operation, and demonstration of mechanical integrity at least every two years will ensure the waste fluids are contained within the disposal interval. Changes in baseline data may be an indication that fluid is escaping beyond the designated confining zone. 8. The mechanical integrity of the tubing, packer and production casing in the Pioneer Unit 1702-15DA WDW well must be demonstrated in accordance with 20 AAC 25.412 prior to commencing injection operations. 9. Disposal injection operations in the Pioneer Unit 1702-15DA WDW well will not cause waste, jeopardize correlative rights, or impair ultimate recovery. Disposal Injection Order~vo. 20 August 11, 1999 NOW, THEREFORE, IT IS ORDERED THAT: Rule 1 Authorized Injection Strata for Disposal. Page 4 Class II oil field fluids maybe injected in conformance with Alaska Administrative Code Title 20, Chapter 25, for disposal into Tyonek Formation strata that are common to and correlate with the interval below 2,790 feet in the BLT No. 1 well in the #1702-15DA WDW well. Rule 2 Authorized Fluids This authorization is limited only to Class II fluids. The Commission must be notified immediately if any non-Class II fluids are injected into the well. Rule 3 Demonstration of Tubing/Casing Annulus Mechanical Integrity A schedule must be developed and coordinated with the Commission that ensures the tubing-casing annulus is pressure tested prior to initiating disposal and at least once every two years thereafter. The casing must be tested at a surface pressure of 1500 psi or 0.25 psi/ft multiplied by the true vertical depth of the packer, whichever is greater. The test pressure must show stabilizing pressure and may not decline more than 10 percent within 30 minutes. The Commission must be notified at least twenty-four (24) hours in advance to enable a representative to witness pressure tests. Rule 4 Well Integrity Failure Whenever disposal rates and/or operating pressure observations or pressure tests indicate pressure communication or leakage of any casing, tubing or packer, the operator must notify the Commission on the first working day following the observation, obtain Commission approval of a plan for corrective action and obtain Commission approval to continue injection. Rule 5 Surveillance Operating parameters including disposal rate, disposal pressure, annulus pressures and volume of fluids and solids pumped must be monitored and reported according to requirements of 20 AAC 25.432. An annual report evaluating the performance of the disposal operation and summary of surveillance activity and results must be submitted by July 1 of each year. Rule 6 Administrative Action Upon request, the Commission may administratively revise and reissue this order or any of its rules upon proper showing that the change is based on sound engineering practices, will not allow waste fluids to escape from the disposal zone, and will not cause waste. Disposal Injection Order'To. 20 ~ Page 5 August 11, 1999 DONE at Anchorage, Alaska and dated August 11, 1999. A 01~ 9~ :'~,d Robert N. istenson, P.E., Chairman .. c~u1 ..~ o ___ ~~ ~ o o~ . `j'•~~._ David W, Johnston\Commissioner H~ ~ i.v~.~a~ proviaes tnat wnnm zu days aver receipt of wntten notice oT the entry of an order, a person affected by rt may hle with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23rd day following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the 10-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30-day period for appeal to Superior Court mns from the date on which the request is deemed denied (i.e., 10th day after the application for rehearing was filed). R ~ • ` i , DRI / MCGRAW HILL PIRA ENERGY GROUP RANDALL NOTTINGHAM LIBRARY 24 HARTWELL 3 PARK AVENUE (34TH & PARK) LEXINGTON MA 02173 NEW YORK NY 10016 '~~ OVERSEAS SHIPHOLDING GRP ECON DEPT 1114 AV OF THE AMERICAS NEW YORK NY 1003 6 ALASKA OFC OF THE GOVERNOR JOHN KATZ STE 518 444 N CAPITOL NW WASHINGTON DC 20001 ARENT FOX KINTNER PLOTKIN KAHN LIBRARY WASHINGTON SQ BLDG. 1050 CONNECTICUT AV NW WASHINGTON DC 20036-5339 LIBRARY OF CONGRESS STATE DOCUMENT SECTION EXCH & GIFT DIV 10 FIRST ST SE WASHINGTON DC 20540 NY PUBLIC LIBRARY DIV E GRAND CENTRAL STATION P O BOX 2221 NEW YORK NY 10163-2221 OIL DAILY CAMP WALSH 1401 NEW YORK AV NW STE 500 WASHINGTON DC 20005 US MIN MGMT SERV CHIEF OCS STATS & INFO 381 ELDEN ST MS 4022 HERNDON VA 20170-4817 U S DEPT OF ENERGY PHYLLIS MARTIN MS E2823 1000 INDEPENDENCE SW WASHINGTON DC 20585 r ~ TECHSYS CORP US GEOL SURV BRANDY KERNS LIBRARY PO BOX 8485 NATIONAL CTR MS 950 GATHERSBURG MD 20898 RESTON VA 22092 DPC SD DEPT OF ENV & NATRL RESOURCES DANIEL DONKEL OIL & GAS PROGRAM 1420 NORTH ATLANTIC AVE, STE 204 2050 W MAIN STE #1 DAYTON BEACH FL 32118 RAPID CITY SD 57702 AMOCO CORP 2002A ILLINOIS STATE GEOL SURV LIBRARY/INFO CTR LIBRARY P 0 BOX 87703 469 NATURAL RESOURCES BLDG CHICAGO IL 60680-0703 615 E PEABODY DR CHAMPAIGN IL 61820 LINDA HALL LIBRARY ALFRED JAMES III SERIALS DEPT 107 N MARKET STE 1000 5109 CHERRY ST WICHITA KS 67202-1811 KANSAS CITY MO 64110-2498 MURPHY E&P CO UNIV OF ARKANSAS ROBERT F SAWYER SERIALS DEPT P O BOX 61780 UNIV LIBRARIES NEW ORLEANS LA 70161 FAYETTEVILLE AR 72701 • CROSS TIMBERS OPERATIONS DWIGHTS ENERGYDATA INC SUSAN LILLY JERLENE A BRIGHT DIRECTOR 210 PARK AVE STE 2350 PO BOX 26304 OKLAHOMA CITY OK 73102-5605 OKLAHOMA CITY OK 73126 IOGCC R E MCMILLEN CONSULT GEOL P O BOX 53127 202 E 16TH ST OKLAHOMA CITY OK 73152-3127 ~ OWASSO OK 74055-4905 OIL & GAS JOURNAL CH2M HILL LAURA BELL J DANIEL ARTHUR PE PROJ MGR P O BOX 1260 502 S MAIN 4TH FLR TULSA OK 74101 TULSA OK 74103-4425 BAPI RAJU MARK S MALINOWSKY 335 PINYON LN 15973 VALLEY VW COPPELL TX 75019 FORNEY TX 75126-5852 US DEPT OF ENERGY DEGOLYER & MACNAUGHTON ENERGY INFORMATION ADMINISTRATION MIDCONTINENT DIVISION MIR YOUSUFUDDIN ONE ENERGY SQ, STE 400 1999 BRYAN STREET STE 1110 4925 GREENVILLE AVE DALLAS TX .75201-6801 DALLAS TX 75206-4083 1 MOBIL OIL CORP GAFFNEY, CLINE & ASSOC., INC. MORRIS CRIM ENERGY ADVISORS P O BOX 290 MARGARET ALLEN DALLAS TX 75221 16775 ADDISON RD, STE 400 DALLAS TX 75248 GCA ENERGY ADV MOBIL OIL RICHARD N FLETCHER JAMES YOREK 16775 ADDISON RD STE 400 P O BOX 650232 DALLAS TX 75248 DALLAS TX 75265-0232 JERRY SCHMIDT STANDARD AMERICAN OIL CO 4010 SILVERWOOD DR AL GRIFFITH TYLER TX 75701-9339 P O BOX 370 GRANBURY TX 76048 CROSS TIMBERS OIL COMPANY PRITCHARD & ABBOTT MARY JONES BOYCE B BOLTON PE RPA 810 HOUSTON ST STE 2000 4521 S. HULEN STE 100 FORT WORTH TX 76102-6298 FT WORTH TX 76109-4948 SHELL WESTERN E&P INC ENERGY GRAPHICS K M ETZEL MARTY LINGNER P O BOX 576 1600 SMITH ST, STE 4900 HOUSTON TX 77001-0574 HOUSTON TX 77002 ~.J H J GRUY PURVIN & GERTZ INC ATTN: ROBERT RASOR LIBRARY 1200 SMITH STREET STE 3040 2150 TEXAS COMMERCE TWR HOUSTON TX 77002 600 TRAVIS ST HOUSTON TX 77002-2979 RAY TYSON 1617 FANNIN ST APT 2015 HOUSTON TX 77002-7639 BONNER & MOORE LIBRARY H2O 2727 ALLEN PKWY STE 1200 HOUSTON TX 77019 PETRAL CONSULTING CO DANIEL L LIPPE 9800 RICHMOND STE 505 HOUSTON TX 77042 MARK ALEXANDER 7502 ALCOMITA HOUSTON TX 77083 CHEVRON PAUL WALKER 1301 MCKINNEY RM 1750 HOUSTON TX 77010 u OIL & GAS JOURNAL BOB WILLIAMS 1700 W LOOP SOUTH STE 1000 HOUSTON TX 77027 MOBIL OIL N H SMITH 12450 GREENSPOINT DR HOUSTON TX 77060-1991 MARATHON OIL CO GEORGE ROTHSCHILD JR RM 2537 P O BOX 4813 HOUSTON TX 77210 ~OC~ EXXON EXPLOR CO REVENUE ACCOUNTING. LAND/REGULATORY AFFAIRS RM 301 P O BOX 4531 P O BOX 4778 HOUSTON TX 77210-4531 HOUSTON TX 77210-4778 EXXON EXPLORATION CO. CHEVRON USA INC. T E ALFORD ALASKA DIVISION P O BOX 4778 ATTN: CORRY WOOLINGTON HOUSTON TX 77210-4778 P O BOX 1635 HOUSTON TX 77251 PETR INFO PHILLIPS PETR CO DAVID PHILLIPS ALASKA LAND MGR P O BOX 1702 P O BOX 1967 HOUSTON TX 77251-1702 HOUSTON TX 77251-1967 PHILLIPS PETROLEUM COMPANY WORLD OIL W ALLEN HUCKABAY MARK TEEL ENGR ED PO BOX 1967 P 0 BOX 2608 HOUSTON TX 77251-1967 HOUSTON TX 77252 EXXON CO USA EXXON CO USA RESERVES COORD RM 1967 J W KIKER ROOM 2086 P 0 BOX 2180 P O BOX 2180 HOUSTON TX 77252-2180 HOUSTON TX 77252-2180 • • EXXON CO USA EXXON CO USA GARY M ROBERTS RM 3039 M W ALBERS RM 1943 P 0 BOX 2180 P O BOX 2180 HOUSTON TX 77252-218.0 HOUSTON TX 77252-2180 PENNZOIL E&P CHEVRON CHEM CO WILL D MCCROCKLIN LIBRARY & INFO CTR P O BOX 2967 P O BOX 2100 HOUSTON TX 77252-2967 HOUSTON TX 77252-9987 MARATHON ACE PETROLEUM COMPANY MS. NORMA L. CALVERT ANDREW C CLIFFORD P O BOX 3128, STE 3915 PO BOX 79593 HOUSTON TX 77253-3128 HOUSTON TX 77279-9593 PHILLIPS PETR CO PHILLIPS PETR CO ERICH R. RAMP JOE VOELKER 6330 W LOOP SOUTH 6330 W LP S RM 492 BELLAIRE TX 77401 BELLAIRE TX 77401 PHILLIPS PETR CO TEXACO INC PARTNERSHIP OPRNS R EWING CLEMONS JERRY MERONEK P O BOX 430 6330 W LOOP S RM 1132 BELLAIRE TX 77402-0430 BELLAIRE TX 77401 WATTY STRICKLAND 2803 SANCTUARY CV KATY TX 77450-8510 INTL OIL SCOUTS MASON MAP SERV INC. P O BOX 338 AUSTIN TX 78767 DIANE SUCHOMEL 10507D W MAPLEWOOD'DR LITTLETON CO 80127 AMOCO PROD CO LIBRARY RM 1770 JILL MALLY 1670 BROADWAY DENVER CO 80202 JERRY HODGDEN GEOL 408 18TH ST GOLDEN CO 80401 w TESORO PETR CORP LOTS DOWNS 8700 TESORO DR SAN ANTONIO TX 78217 ROBERT G GRAVELY 7681 S KIT CARSON DR LITTLETON CO 80122 GEORGE G NAUGHT JR P O BOX 13557 DENVER CO 80201 C & R INDUSTRIES, INC. KURT SALTSGAVER 1801 BROADWAY STE 1205 DENVER CO 80202 NRG ASSOC RICHARD NEHRING P O BOX 1655 COLORADO SPRINGS CO 80901-1655 RUBICON PETROLEUM, LLC BRUCE I CLARDY SIX PINE ROAD COLORADO SPRINGS CO 80906 RUI ANALYTICAL JERRY BERGOSH P O BOX 58861 SALT LAKE CITY UT 84158-0861 HUNGER OIL 2NFOR SERV INC P O BOX 45738 LOS ANGELES CA 90045-0738 US OIL & REFINERY CO TOM TREICHEL 2121 ROSECRANS AVE #2360 ES SEGUNCO CA 90245-4709 ANTONIO MADRID P O BOX 94625 PASADENA CA 9110 9 JOHN A LEVORSEN 200 N 3RD ST #1202 BOISE ID 83702 TAHOMA RESOURCES GARY PLAYER 1671 WEST 546 S CEDER CITY UT 84720 LA PUBLIC LIBRARY SERIALS DIV 630 W 5TH ST LOS ANGELES CA 90071 BABSON & SHEPPARD JOHN F BERGQUIST P O BOX 8279 VIKING STN LONG BEACH CA 90808-0279 ORO NEGRO, INC. 9321 MELVIN AVE NORTHRIDGE CA 91324-2410 PACIFIC WEST OIL DATA 76 PRODUCTS COMPANY ROBERT E COLEBERD ~ CHARLES BURRUSS RM 11-767 15314 DEVONSHIRE ST STE D 555 ANTON MISSION HILLS CA 91345-2746 COSTA MESA CA 92626 SANTA FE ENERGY RESOURCES INC TEXACO INC EXPLOR DEPT PORTFOLIO TEAM MANAGER 5201 TRUXTUN AV STE 100 R W HILL BAKERSFIELD CA 9330 9 P O BOX 5197X BAKERSFIELD CA 93388 US GEOL SURV SHIELDS LIBRARY KEN BIRD GOVT DOCS DEPT 345 MIDDLEFIELD RD MS 999 UNIV OF CALIF MENLO PARK CA 94025 DAVIS CA 95616 H L WANGENHEIM ECONOMIC INSIGHT INC 5430 SAWMILL RD SP 11 SAM VAN VACTOR PARADISE CA 95969-5969 P O BOX 683 PORTLAND OR 97207 US EPA REGION 10 MARPLES BUSINESS NEWSLETTER LAURIE MANN OW-130 MICHAEL J PARKS 1200 SIXTH AVE 117 W MERCER ST STE 200 SEATTLE WA 98101 SEATTLE WA 98119-3960 PATTI SAUNDERS 1233 W 11TH AV ANCHORAGE AK 99501 DEPT OF REVENUE BEVERLY MARQUART 550 W 7TH AV STE 570 ANCHORAGE AK 99501 FAIRWEATHER E&P SERV INC JESSE MOHRBACHER 715 L ST #4 ANCHORAGE AK 99501 STATE PIPELINE OFFICE LIBRARY KATE MUNSON 411 W 4TH AVE, STE 2 ANCHORAGE AK 99501 FORCENERGY INC. JIM ARLINGTON 310 K STREET STE 700 ANCHORAGE AK 99501 DUSTY RHODES 229 WHITNEY RD ANCHORAGE AK 99501 DEPT OF REVENUE OIL & GAS AUDIT DENISE HAWES 550 W 7TH AV STE 570 ANCHORAGE AK 99501 GUESS & RUDD GEORGE LYLE 510 L ST, STE 700 ANCHORAGE AK 99501 TRUSTEES FOR ALASKA 725 CHRISTENSEN DR STE 4 ANCHORAGE AK 99501 YUKON PACIFIC CORP JOHN HORN VICE CHM 1049 W 5TH AV ANCHORAGE AK 99501-1930 PRESTON GATES ELLIS LLP ALASKA DEPT OF LAW LIBRARY ROBERT E MINTZ ASST ATTY GEN 420 L ST STE 400 1031 W 4TH AV STE 200 ANCHORAGE AK 99501-1937 ANCHORAGE AK 99501-1994 GAFO DEPT OF NATURAL RESOURCES GREENPEACE DIV OF OIL & GAS PAMELA MILLER TIM RYHERD 125 CHRISTENSEN DR. #2 550 W 7TH AVE STE 800 ANCHORAGE AK 99501-2101 ANCHORAGE AK 99501-3510 DEPT OF REVENUE BAKER OIL TOOLS OIL & GAS AUDIT ALASKA AREA MGR FRANK PARR 4710 BUS PK BLVD STE 36 550 W 7TH AVE STE 570 ANCHORAGE AK 99503 ANCHORAGE AK 99501-3540 HDR ALASKA INC KOREAN CONSULATE MARK DALTON OCK JOO KIM CONSUL 2525 C ST STE 305 101 BENSON STE 304 ANCHORAGE AK 99503 ANCHORAGE AK 99503 N-I TUBULARS INC ANADARKO 3301 C STREET STE 209 MARK HANLEY ANCHORAGE AK 99503 3201 C STREET STE 603 ANCHORAGE AK 99503 :~ ALASKA OIL & GAS ASSOC JUDY BRADY 121 W FIREWEED LN STE 207 ANCHORAGE AK 99503-2035 DEPT OF NATURAL RESOURCES DIV OF OIL & GAS BRUCE WEBB 3601 C ST STE 1380 ANCHORAGE AK 99503-5948 DEPT OF NATURAL RESOURCES DIV OF OIL & GAS JULIE HOULE 3601 C ST STE 1380 ANCHORAGE AK 99503-5948 DEPT OF NATURAL RESOURCES PUBLIC INFORMATION CTR 3601 C STREET STE 200 ANCHORAGE AK 99503-5948 FINK ENVIRONMENTAL CONSULTING, INC. THOMAS FINK, PHD 6359 COLGATE DR. ANCHORAGE AK 99504-3305 • AK JOURNAL OF COMMERCE OIL & INDUSTRY NEWS ROSE RAGSDALE 4220 B STREET STE #210 ANCHORAGE AK 99503-5911 DEPT OF NATURAL RESOURCES DIV OIL & GAS WILLIAM VAN DYKE 3601 C ST STE 1380 ANCHORAGE AK 99503-5948 DEPT OF NATURAL RESOURCES DIV OF OIL & GAS JAMES B HAYNES NATURAL RESRCE MGR 3601 C ST STE 1380 ANCHORAGE AK 99503-5948 DEPT OF NATURAL RESOURCES DIV OF OIL & GAS JIM STOUFFER 3601 C STREET STE 1380 ANCHORAGE AK 99503-5948 ARLEN EHM GEOL CONSLTNT 2420 FOXHALL DR ANCHORAGE AK 99504-3342 ' ~ • JAMES E EASON RUSSELL DOUGLASS 8611 LEEPER CIRCLE 6750 TESHLAR DR ANCHORAGE AK 99504-4209 ANCHORAGE AK 99507 STU HIRSH US BUREAU OF LAND MNGMNT 9630 BASHER DR. ANCHORAGE DIST OFC ANCHORAGE AK 99507 DICK FOLAND 6881 ABBOTT LOOP RD ANCHORAGE AK 99507 US BLM AK DIST OFC THOMAS R MARSHALL JR RESOURCE EVAL GRP 1569 BIRCHWOOD ST ART BONET ANCHORAGE AK 99508 6881 ABBOTT LOOP RD ANCHORAGE AK 99507-2899 CASS ARIEY UNIVERSITY OF ALASKA ANCHORAGE 3108 WENTWORTH ST INST OF SOCIAL & ECON RESEARCH ANCHORAGE AK 99508 TERESA HULL 3211 PROVIDENCE DR ANCHORAGE AK 99508 TRADING BAY ENERGY CORP US MIN MGMT SERV PAUL CRAIG RICHARD PRENTKI 5432 NORTHERN LIGHTS BLVD 949 E 36TH AV ANCHORAGE AK 99508 ANCHORAGE AK 99508-4302 US MIN MGMT SERV AK OCS REGIONAL DIR 949 E 36TH AV RM 110 ANCHORAGE AK 99508-4302 REGIONAL SUPRVISOR, FIELD OPERATNS MINERALS MANAGEMENT SERVICE ALASKA OCS REGION 949 E 36TH AV STE 308 ANCHORAGE AK 99508-4363 US MIN MGMT SERV RESOURCE EVAL JIM SCHERR 949E 36TH AV RM 603 ANCHORAGE AK 99508-4363 JOHN MILLER 3445 FORDHAM DR ANCHORAGE AK 99508-4555 CIRI LAND DEPT P 0 BOX 93330 ANCHORAGE AK 99509-3330 US MIN MGMT SERV RESOURCE STUDIES AK OCS REGN KIRK W SHERWOOD 949 E 36TH AV RM 603 ANCHORAGE AK 99508-4302 US MIN MGMT SERV LIBRARY 949 E 36TH AV RM 603 ANCHORAGE AK 99508-4363 US MIN MGMT SERV FRANK MILLER 949 E 36TH AV STE 603 ANCHORAGE AK 99508-4363 USGS - ALASKA SECTION LIBRARY 4200 UNIVERSITY DR ANCHORAGE AK 99508-4667 ANCHORAGE TIMES BERT TARRANT P O BOX 100040 ANCHORAGE AK 99510-0040 BRISTOL ENVIR SERVICES ARCO ALASKA INC JIM HUNTER JOANN GRUBER ATO 712 P O BOX 100320 _ P O BOX 100360 ANCHORAGE AK 99510-0320 ANCHORAGE AK 99510-0360 ARCO ALASKA INC ARCO ALASKA INC LEGAL DEPT STEVE BENZLER ATO 1404 MARK P WORCESTER P O BOX 100360 P O BOX 100360 ~ ANCHORAGE AK 99510-0360 ANCHORAGE AK 99510-0360 ARCO ALASKA INC ARCO ALASKA INC LIBRARY MARK MAJOR ATO 1968 P 0 BOX 100360 P O BOX 100360 ANCHORAGE AK 99510-0360 ANCHORAGE AK 99510-0360 ARCO ALASKA INC ARCO ALASKA INC LAND DEPT SAM DENNIS ATO 1388 JAMES WINEGARNER _ P O BOX 100360 P O BOX 10036 ANCHORAGE AK 99510-0360 ANCHORAGE AK 99510-0360 ARCO ALASKA INC PETROLEUM INFO CORP SHELIA ANDREWS ATO 1130 KRISTEN NELSON PO BOX 100360 P 0 BOX 102278 ANCHORAGE AK 99510-0360 ~ ANCHORAGE AK 99510-2278 U ARCO ALASKA INC ALYESKA PIPELINE SERV CO KUP CENTRAL WELLS ST TSTNG PERRY A MARKLEY WELL ENG TECH NSK 69 1835 S BRAGAW - MS 575 P O BOX 196105 ANCHORAGE AK 99512 ANCHORAGE AK 99510-6105 ALYESKA PIPELINE SERV CO _ ALYESKA PIPELINE SERV CO CHUCK O'DONNELL LEGAL DEPT 1835 S BRAGAW - MS 530B 1835 S BRAGAW ANCHORAGE AK 99512 ANCHORAGE AK 99512-0099 US BUREAU OF LAND MGMT ANCHORAGE DAILY NEWS OIL & GAS OPRNS (984) EDITORIAL PG EDTR J A DYGAS MICHAEL CAREY 222 W 7TH AV #13 P O BOX 149001 ANCHORAGE AK 99513-7599 ANCHORAGE AK 99514 JWL ENGINEERING NORTHERN CONSULTING GROUP JEFF LIPSCOMB ROBERT BRITCH, P.E. 9921 MAIN TREE DR. 2454 TELEQUANA DR. ANCHORAGE AK 99516-6510 ANCHORAGE AK 99517 GERALD GANOPOLE CONSULT GEOL DAVID CUSATO 2536 ARLINGTON ~ 600 W 76TH AV #508 ANCHORAGE AK 99517-1303 ANCHORAGE AK 99518 • ASRC SCHLUMBERGER CONRAD BAGNE DARREN AKLESTAD 301 ARCTIC SLOPE AV STE 300 1111 E 80TH AV ANCHORAGE AK 99518 ANCHORAGE AK 99518 ARMAND SPIELMAN HALLIBURTON ENERGY SERV 651 HILANDER CIRCLE MARK WEDMAN ANCHORAGE AK 99518 6900 ARCTIC BLVD ANCHORAGE AK 99518-2146 OPSTAD & ASSOC JACK O HAKKILA ERIK A OPSTAD PROF GEOL P 0 BOX 190083 P O BOX 190754 ANCHORAGE AK 99519-0083 ANCHORAGE AK 99519 ENSTAR NATURAL GAS CO MARATHON OIL CO RICHARD F BARNES PRES OPERATIONS SUPT P O BOX 190288 P 0 BOX 196168 ANCHORAGE AK 99519-0288 ANCHORAGE AK 99519-6168 MARATHON OIL CO UNOCAL BRAD PENN P O BOX 196247 P 0 BOX 196168 ANCHORAGE AK 99519-6247 ANCHORAGE AK 99519-6168 UNOCAL KEVIN TABLER P O BOX 196247 ANCHORAGE AK 99519-6247 BP EXPLORATION (ALASKA) INC MR: DAVIS, ESQ P O BOX 196612 MB 13-5 ANCHORAGE AK 99519-6612 BP EXPLORATION (ALASKA) INC INFO RESOURCE CTR MB 3-2 P O BOX 196612 ANCHORAGE AK 99519-6612 BP EXPLORATION (ALASKA) INC SUE MILLER P 0 BOX 196612 M/S LR2-3 ANCHORAGE AK 99519-6612 AMERICA/CANADIAN STRATIGRPH CO RON BROCKWAY P O BOX 242781 ANCHORAGE AK 99524-2781 • EXXON COMPANY USA MARK P EVANS PO BOX 196601 ANCHORAGE AK 99519-6601 BP EXPLORATION (ALASKA) INC BOB WILKS MB 5-3 P 0 BOX 196612 ANCHORAGE AK 99519-6612 BP EXPLORATION (ALASKA) INC PETE ZSELECZKY LAND MGR P O BOX 196612 ANCHORAGE AK 99519-6612 BP EXPLORATION (ALASKA), INC. MARK BERLINGER MB 8-1 PO BOX 196612 ANCHORAGE AK 99519-6612 AMSI/VALLEE CO INC WILLIAM O VALLEE PRES PO BOX 243086 ANCHORAGE AR 99524-3086 L G POST O&G LAND MGMT CONSULT DIANA FLECK 10510 CONSTITUTION CIRCLE 18112 MEADOW CRK DR EAGLE RIVER AK 99577 EAGLE RIVER AK 99577 D A PLATT & ASSOC PINNACLE 9852 LITTLE DIOMEDE CIR STEVE TYLER EAGLE RIVER AK 99577 20231 REVERE CIRCLE EAGLE RIVER AK 99577 DEPT OF NATURAL RESOURCES COOK INLET VIGIL DGGS JAMES RODERICK JOHN REEDER P O BOX 916 P O BOX 772805 HOMER AK 99603 EAGLE RIVER AK 99577-2805 COOK INLET KEEPER RON DOLCHOK BOB SHAVELSON P O BOX 83 PO BOX 3269 KENAI AK 99611 HOMER AK 99603 • DOCUMENT SERVICE CO PHILLIPS PETR JOHN PARKER ALASKA OPERATIONS MANAGER P 0 BOX 1137 J W KONST KENAI AK 99611 P O DRAWER 66 KENAI AK 99611 .~ - .• KENAI PENINSULA BOROUGH PENNY VADLA ECONOMIC DEVEL DISTR P 0 BOX 467 STAN STEADMAN NINILCHIK AK 99639 P O BOX 3029 KENAI AK 99611-3029 BELOWICH COAL CONSULTING JAMES GIBBS MICHAEL A BELOWICH P O BOX 1597 HC31 BOX 5157 SOLDOTNA AK 99669 WASILLA AK 99654 PACE KENAI NATL WILDLIFE REFUGE SHEILA DICKSON REFUGE MGR P O BOX 2018 P O BOX 2139 SOLDOTNA AK 99669 SOLDOTNA AK 99669-2139 ALYESKA PIPELINE SERVICE CO VALDEZ PIONEER VALDEZ CORP AFFAIRS P O BOX 367 SANDY MCCLINTOCK VALDEZ AK 99686 P O BOX 300 MS/701 VALDEZ AK 99686 VALDEZ VANGUARD UNIV OF ALASKA FAIRBANKS EDITOR PETR DEVEL LAB P 0 BOX 98 DR V A KAMATH VALDEZ AK 99686-0098 427 DUCKERING FAIRBANKS AK 99701 NICK STEPOVICH 543 2ND AVE FAIRBANKS AK 99701 JACK HAKKILA P O BOX 61604 FAIRBANKS AK 99706-1604 FAIRBANKS DAILY NEWS-MINER KATE RIPLEY P O BOX 70710 FAIRBANKS AK 99707 DEPT OF NATURAL RESOURCES DIV OF LAND REG MGR NORTHERN REGION 3700 AIRPORT WAY FAIRBANKS AK 99709-4699 ASRC BILL THOMAS P O BOX 129 BARROW AK 99723 r RICK WAGNER P O BOX 60868 FAIRBANKS AK 99706 C BURGLIN P O BOX 131 FAIRBANKS AK 99707 FRED PRATT P O BOX 72981 FAIRBANKS AK 99707-2981 K&K RECYCL INC P 0 BOX 58055 FAIRBANKS AK 99711 RICHARD FINEBERG P O BOX 416 ESTER AK 99725 i C: UNIV OF ALASKA FBX PETR DEVEL LAB SHIRISH PATIL 437 DICKERING FAIRBANKS AK 99775 SENATOR LOREN LEMAN STATE CAPITOL RM 113 JUNEAU AK 99801-1182 SNEA(P) DISTR FRANCE/EUROPE DU SUD/AMERIQUE TOUR ELF CEDEX 45 992078 PARIS LA DEFE FRANCE UNIVERSITY OF ALASKA FBKS PETR DEVEL LAB DR AKANNI LAWAL P O BOX 755880 FAIRBANKS AK 99775-5880 DEPT OF ENVIRON CONSERV SPAR CHRIS PACE 410 WILLOUGHBY AV STE 105 JUNEAU AK 99801-1795 0 a ~ a TONY KNOWLES, GOVERNOR ~~ OIIJ ~ ~ 333 W. 7T" AVENUE, SUITE 100 C011TSIiRQATI011T COM1~i15SIO1~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 27&7542 ADMINISTRATIVE APPROVAL NO. DIO 20.001 Mr. John Tanigawa Alaska Projects Manager Evergreen Resources (Alaska) Corp. PO Box 871845 Wasilla AK 99587 Re: Request for Disposal of Cement Rnnsate in Pioneer Unit Well #1702-15DA Dear Mr. Tanigawa: By letter dated September- 19, 2002, Evergreen Resources (Alaska) Corporation requested authorization to dispose of cement rinsate into the pre-existing Pioneer Unit Well #1702-15DA, permitted as an Underground Injection Control Program Class II disposal well. The Pioneer Unit. is a pilot coalbed methane development located within the Matanuska Valley, near the city. of Wasilla, Alaska. The project involves as many as 12 wells drilled to test the viability of coalbed methane production in Alaska. On October 30, 2002, Evergreen provided laboratory analysis of a representative sample of cement rinsate from Baranoff #4 well that is currently being drilled at the Pioneer Coalbed Methane Project location. Data provided by Evergreen demonstrates that the cement rinsate proposed for disposal does not exhibit any hazardous characteristics as defined in 40 CFR 261. The letter forwarding the analytical results of the cement rinsate indicates that Evergreen will, upon approval by the AOGCC, "place the rinsate into the cuttings pit for later disposal" into Well #1702-15DA. The cement rinsate noted in Evergreen's request is generated in primary field operations intrinsic to the drilling of exploration and production wells at the Pioneer Unit. Cement rinsate is consistent in composition with materials already authorized for injection under Disposal Injection Order No. 20 and pose no risk of fluid movement into a USDW. Underground injection into this Class II disposal well represents the environmentally preferable option for managing the cement rinsate generated in conjunction with the drilling of Evergreen's coalbed methane development wells when compared to surface discharge, the only other viable option. The AOGCC has determined that the cement rinsate, as represented in Evergreen's request for administrative approval, is suitable for disposal in Pioneer Unit Well #1702-15DA as proposed. No injection into this well may occur until Evergreen has performed a mechanical integrity test as required in 20 AAC 25.252(d). Approval applies only to this specific request and is not DIO 20.001 November 1, 2002 Page 2 of 2 intended to provide for a blanket authorization to inject these or similar non-hazardous fluids down other Class II disposal wells. DONE at Anchorage, Alaska and dated November 1, 2002. Cammy( echsli Tay r Chair BY ORDER O Daniel T. Seamount Commissioner SIGN Michael L. Bill, PE Commissioner ~ C~~L" a a a ~ TONY KNOWLES, GOVERNOR 0 l1iJA17R~ OIL ~D GAS 333 W. 7"' AVENUE, SUITE 100 COI~TSERVA~'IO1~T COMI-IIS3IOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 278-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL NO. DIO 20.001 Mr. John Tanigawa Alaska Projects Manager Evergreen Resources (Alaska) Corp. PO Box 871845 Wasilla AK 99587 Re: Request for Disposal of Cement Rinsate in Pioneer Unit Well #1702-15DA Dear Mr. Tanigawa: By letter dated September 19, 2002, Evergreen Resources (Alaska) Corporation requested authorization to dispose of cement rinsate into the pre-existing Pioneer Unit Well #1702-15DA, permitted as an Underground Injection Control Program Class II disposal well. The Pioneer Unit is a pilot coalbed methane development located within the Matanuska Valley, near the city of Wasilla, Alaska. The project involves as many as 12 wells drilled to test the viability of coalbed methane production in Alaska. On October 30, 2002, Evergreen provided laboratory analysis of a representative sample of cement rinsate from Baranoff #4 well that is currently being drilled at the Pioneer Coalbed Methane Project location. Data provided by Evergreen demonstrates that the cement rinsate proposed for disposal does not exhibit any hazardous characteristics as defined in 40 CFR 261. The letter forwarding the analytical results of the cement rinsate indicates that Evergreen will, upon approval by the AOGCC, "place the rinsate into the cuttings pit for later disposal" into Well #1702-15DA. The cement rinsate noted in Evergreen's request is generated in primary field operations intrinsic to the drilling of exploration and production wells at the Pioneer Unit. Cement rinsate is consistent in composition with materials already authorized for injection under Disposal Injection Order No. 20 and pose no risk of fluid movement into a USDW. Underground injection into this Class II disposal well represents the environmentally preferable option for managing the cement rinsate generated in conjunction with the drilling of Evergreen's coalbed methane development wells when compared to surface discharge, the only other viable option. The AOGCC has determined that the cement rinsate, as represented in Evergreen's request for administrative approval, is suitable for disposal in Pioneer Unit Well #1702-15DA as proposed. No injection into this well may occur until Evergreen has performed a mechanical integrity test as required in 20 AAC 25.252(d). Approval applies only to this specific request and is not • • 0 ~ ~ ~ FRANK H. MURKOWSKI GOVERNOR ~i/A-7~~ OI~ t>•1`il ~ 333 W. 7"' AVENUE, SUITE 100 CO1~T5ERQA'1'IOI1T COriDIISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 2767542 ADMINISTRATIVE APPROVAL NO. DIO 20.002 Mr. John Tanigawa Alaska Projects Manager Evergreen Resources (Alaska) Corp. PO Box 871845 Wasilla AK 99587 Re: Request to complete Pioneer Unit Well 1702-14CC as a water injection well. Dear Mr. Tanigawa: By letter dated May 15, 2003 Evergreen Resources (Alaska) Corporation requested authorization to perforate, stimulate, and complete as a water injector Pioneer Unit Well 1702-14CC. The Pioneer Unit is a pilot coal bed methane development located near Wasilla, Alaska. AOGCC Aquifer Exemption Order No. 5 authorizes injection into subsurface strata that correlate with the interval below 2790 feet in Pioneer Unit Well BLT No. 1. Disposal Injection Order No. 20 permitted Pioneer Unit Well 1702-15DA as a Class II waste disposal well. Well 1702-14CC is located approximately 1157 feet east of well 1702-15DA. AOGCC has determined that injection in Tyonek Formation strata via wells 1702-15DA and 1702-14CC is based on sound engineering practices, will not allow waste fluids to escape from the injection zone, and will not cause waste. Subsequently, Class II oil field fluids may be injected in Pioneer Unit Well 1702-15DA, and produced water is hereby authorized for injection in Pioneer Unit Well 1702-14CC. DONE at Anchorage, Alaska and dated May 27, 2003. .~ V~.~.,. Sar . Palin ~ I Daniel T. Seamount Chair v Commissioner BY ORDER OF THE COMMISSION Randy Ruedrich ,r.:,_.Commissioner ,~ 1~ItG-I2..IN RESOURCES {AtASKAI CORP. ~ g~i'.wdaN o~ E~!orne^..7eso,rces. lam. May 15, 2003 Ms. Sarah Palin Dr. Randy Ruederich Mr. Daniel Seamount Commissioner Alaska Oil and Gas Conservation Commission 333 W. 7th Ave #100 Anchorage, Alaska, 99501-3539 • RE: .Injection Order No 20 Request to change order under Rule 6 -Administrative Action Sundry 10-403 for the Pioneer Unit 1702-14CC -perforate & frac as injector Dear Commissioners Palin, Ruederich and Seamount, Evergreen Resources (Alaska) Corp requests that the commission make changes to Injection Order 20 under au#hority given by Rule 6 -Administrative Action. In 2002, Evergreen drilled eight coal bed methane (CBM}wells within the Pioneer Unit ', and in 2003, we plan to drill an additional 4 wells. To determine the economic viability of coal bed methane production within the Pioneer Uni#, these wells must be placed on 'along-term production test to ascertain the producibility of the Tyonek coals. As a part ', of the production test, water is produced and must be safely disposed. Having a reliable way to dispose of our produced water is vital to the success of this project. ~~~! In summary, Evergreen requests that the 1702-14CC well ~~~'4,,, „"'' '1°" ...~~~~ be added to the list of injector wells, ~~~ Originally, only the 1702-15DA well was authorized for water disposal. '; Along with this request, Evergreen submits a 10-403 Sundry Notices to perforate and '' then fracture stimulate the 1702-14CC as a water injection well. Evergreen hopes to move onto the 1702-14CC well on May 20, 2003. At this time, we do not foresee completing the 15DD well as an injector, but request the commission allow us to inject into it, if needed. Please contact me if you have questions or comments. My e-mail address is JohnT(a~EvergreenGas.com and my cell phone is 907-841-0000. On behalf of Evergreen, I commend your staff for their assistance regarding this matter. Their help has been invaluable. Thank you. Strut 1075 (~edc Street, Sulfa 202 Wastla, AK 99854 Mating: P.O. Bmc 87,845 Warta AK 998 r~s9E,so~-e34o MAY ~ 5 X003 Alaska Oil & Gas Cons. Commission Anchorage i Sincerely, Evergreen Resou es (Alaska) Corp Jo n J. Taniga a '. Alaska. Projects Manager Attachments • RE~Et V r~aY 1 5 2003 Alaska Oil ~ Gas Cons C~r~~ission Anchorage Summary of Request Rule 6 Administrative Action -Injection Order 20 -Pioneer Unit Background Information: In fall 2002, Evergreen drilled eight coal bed methane wells and plans to drill four more wells in 2003. Evergreen would now like to production test these wells to determine if the Tertiary aged Tyonek Coals are capable of economic gas production. A necessary part of the production testing process is having a reliable and safe place to dispose of produced water. The previous operators, Ocean Energy and Unocal, determined that underground injection is the most feasible water disposal method during the initial phase of this project. To that end, Unocal applied for and then received authority to inject Class II wastes under Injection Order 20 dated August 11, 1999. A group of three wells -two producers and one injector were drilled and partially completed in 1999 and 2000. These wells are within 1,500 feet of each other. Evergreen purchased a 100% working interest in the Pioneer Unit in March 2001. Evergreen continued completing the 1702-15DA WDW injection well and finished construction of the surface facilities beginning in the summer of 2002. To date, Evergreen has broken down the perforations using a weak acid (August 2002), performed injection tests (August 2002 to May 2003), and hydraulically fracture treated the well (February 2003). We are able to inject water into the Tyonek, however, due to suspect casing conditions as verified by a downhole video (May 2002), we have only recently been successful in maintaining isolation between the tubing and the annulus. We are currently testing the Infectivity of this zone. Rationale Having a reliable well to inject water cannot be understated. To begin a productian test and then prematurely stop the test because of water disposal problems provide inconclusive and therefore unacceptable results. We believe that sound engineering principles require redundancy in our water disposal options. Evergreen Request As a part of Injection Order 20, Rule 6 Administrative Action, Evergreen requests that the commission revise the current order. Our request ensures that "sound engineering practices, will not allow waste fluids to escape from the disposal zone, and will not cause waste" is still maintained as a result of these changes. Outlined below are the three requests. 1. Add the 1702-14CC well to the list of available injector wells and give Evergreen authority to complete the 1702-14CC well as a water injector. This well is located 1,157 feet to the east of the current injector well and there already exists a water .pipeline connecting the well to the injector pump. We submit a 10-403 to complete this well as an injector. This 403 includes perforating sandstones and then stimulating them via hydraulic fracture. We plan to perform this work an May 20, 2003. • • - ;~~~ 'Additional Information: !, Evergreen believes that neither the 14CC nor the 15DD wells are capable of ', commercial CBM production. As evidence by the by the production testing by the ', previous operator. Thus, utilization of these well bores as injectors prevents waste since the wells will be utilized and not abandoned. Cement Evaluation Logs (Baker Atlas Segmented Bond Tool), on file with the ', commission, show sufficient quality cement isolating the fresh water zone (e.g., gravels) from the injection zone. Water wells producing in the area are from the Quaternary gravels located within a few hundred feet of surface. All of the proposed and existing perforations are within the Order's guidelines of being below 2,790 ft KB in the BLT No. 1. Presented in the table below is information on how the BLT depth limitation correlates to the 1702 pilot area. As the table illustrates, the uppermost interval that can be injected for the 14CC well is 2,672 feet KB for the 15DA is 2,682 ft KB and for the 15DD it is 2,564 ft KB. Table showing Top of Injection Zone based on BLT No 1 Well Name Top Injection Interval KB Surfaces : Elevation ~ KB ft. 3 Top Tyonek Formation KB Tap = Tyonek Fm. Subsea ft. Tap Injection Interval Subsea ft. 1702-14CC 2672 - 281 ~ 480 -199 -2391 1702-15DA 2682 276 490 -214 -2406 1702-15DD 2564 264 372 -108 -2300 BLT #1 2790 205 598 -393 -2585 After analyzing relevant electric and mud log data, it is evident that correlating individual sands, coals, and shales is not possible between the the BLT No 1 and the 1702 area where over eight miles of separation exists. This is primarily due to the lucustrine environment that generated these coals. However, estimating an equivalent depth between the two areas is possible. Here is how. From the BLT No 1, we know that injections must remain below 2,790 feet. In -BLT, this occurs after 598 feet of gravel and 2,192 feet of Tyonek is encountered. In the 1702 area, we define the injection interval as those rocks 2,192 feet below the top of Tyonek. By making this assumption, over one thousand feet of impermeable shales and clay- filled sandstones exist. These zones will provide a barrier between the injection zone and the intervals of domestic water production. ~ ~ Location of the 14CC and the 15DD wells are close to the 15DA WDW water disposal well. These wells are within the sections authorized for injection under Injection Order 20. Shown on the next page is the plat showing the well locations of all three wells. The remaining portion of this document contain two 10-403 Sundry Notices. T~;z ~~~ . The other is a sundry notice to complete via hydraulic fracture and perforating, the 14CC well as an alternate water injector. t ~ ~-'\1 `y '. ~ , ~~ Y ~~ ~ O ~ ~ ~ ~ ~U ~ ;., W~ - ~ z n hE '~ s~5 s14 - -~- Oce:In F.rlergy V` /.~ l SCCT~ON 15 +6~; 5~ 5 y~ ~6'~ ~lrnnd.ny 5t» 7d(i0 \~~ ' Z NVY 1 /4 `JW 1 /4 Uenv.r. ~;; 9~YC2 Ti7N, R2W, S.M., AK i 1cg SECTON 14 ~ ~ " - ~- ~a PFz(~POSED F IO~iEFI-~ [-\ I'I' W I ~ v.z T17N, R2W, S.M., AK s ~ ` ~:( G.~S G_1'i'HE:KI~ Cr ~Y~'i' 1;11 o ; Parcel C-oL ON 1 DA Paaa (3)-4" ~IAk! 2,~ il`~~IL[.:~, aI.45K:1 PIPELIN~~ r"'f ~ I)('t~ll 30~ R/~' (~ _ -- - _._._._ _~_- r ~ ~' _ _ __.- _~- ._.._ 50~--~Kesa ReaC j `s5' ~ W -- - 35' J 90' Bend ~, ~ Jr. 90' Sena 4 ~ 90' ;land Q 8 PIPELINE LENGTHS: ~ ~+I ` 0- PIONEER 14CC to 150ti 14~c" LL ? ~~ r ' _ ~ al °~ ~g o ~~ ~ g3 ~ ~ PIONEER 150D to TSDA- ~~~i L~ - ~~`~- ~ - S N ul C d a¢ I ~ .' a ~ I Q ~ n L R! ~ I ~ - a~ ~ d - _._ 90 G'". Road Bores-~- `~ 5 r' ~ ° Pad I R 4 T,. _ ~ c 9.,. E,... ~ , 4 ()IAM. G'i INE ~ ~+ ~ Lin-~ '_ '. c~ ~ ~ 1 h6 Lined __ K/W ~ ~~ ~ _.. P` e. s' W' a 3G' R/'h' ~.~ ~ i Z ~ R %~'- x ~ -~ t 5~ a r+- Z I t p I I --~ ~ , > 5' ` ~ ` 35' t s' w 90' 9er: d _A ~~ s3' secnoa u~ ~ L)P.t.i3ll ` Z f J (Scale: ~ 50' ~`' sw 1 /a sw 1 /4 SECTION 14 Ti7N, R2W, S.M., AK ~- •S' PorcSSi C-5 ~ t aietinq Ensfm «h. -- ~-- ~ 3~ 3q' Patl Exlsting Grovai Plt 4 ~ 0! AIAT-SU ~egin PFpeline ~' fiend - I SrS+fa 1 a' ~ S22 523 /I ~ - _ s636-S ~ ,a' '~~ -t; .f- 54' :. r ~41eLANE CONSULTING GROUP Professional Engineers. Surrryorv & Plannerv IO DOX ~ 8fri-OOTMA. AK 9MeY C9W) 111.42 FAX {9071 aR~1~E6 DRAWN er, x•~: 200' 1' ``~\`l\~I11 ~ rnsm = - -- `=A~!! t%0 ` ` " B/19/99 - ~ ~ ~ Y I ~* 49~"GV ~S ORAYi111G R0. 993050 PRO,.EC7 rq.: BR n~ 993060 99~ •'7 ~ $ ~ ~ u SGT' ~ ~.n' 3 . ~¢ ~ a]R S '!j ' _ _ ___ __ ~ ! \~ !!' ~ DF 1 SHEET 1j1~\\~\ • ~$ UIC File Review Date: October 31, 2002 • Subject: Injection of Cement Rinsate Evergreen Pioneer Unit Well 1702-15DA (Class II UIC Well) PTD #: 199-064 Orders: AEO 5 DIO 20 ~~~~,~~~~ Reviewers: Jim Regg, Petroleum Engineer C~ . `~ Initiating Action: Administrative Approval Request to DIO 20 Review Summary 1. Pioneer Unit is a coalbed methane project located near Wasilla, Alaska. 2. Evergreen requested Administrative Approval for Disposal of Cement Rinsate in Pioneer Unit Well 1702-15DA, a Class II water disposal well (9/19/02) 3. Evergreen request includes data demonstrating fluid proposed for injection is non-hazardous a. Laboratory testing of cement rinsate (10/30/02) i. Does not exhibit hazardous characteristics as defined in 40 CFR 261. 4. Chronological Review of files revealed: a. Permit to Drill (PTD) for Well 1702-15DA (approved 7/28/99) i. Ocean Energy Resources was operator of record b. Well drilled August 1999 by Ocean Energy as dedicated water disposal well i. Perforations were unable to be cleaned up ii. Operations suspended.... c. Aquifer Exemption Order (AEO) (issued 6/5/99) i. Portion of those aquifers underlying Pioneer Unit field common to and correlating with the interval below 2,790 feet in the Pioneer BLT No. 1 well (PTD # 199-068) ii. No objection by EPA to the AEO d. DIO 20 (issued 8/11/99) i. Dispose Class II oil field wastes by underground injection into the Tyonek Formation common to and correlate with the interval below 2,790' (MD) in the BLT No. 1 well ii. Rule 6 provides AOGCC with ability to "administratively revise and reissue this order or any of its rules upon proper showing that the change is based on sound engineering practices, will not allow waste fluids to escape from the disposal zone, and will not cause waste." • e. Evergreen' requests Sundry Approval to stimulate Well 1702-15DA (approved 8/27/02) i. Stimulation was unsuccessful (verbal -Winton Aubert, AOGCC); Water Disposal Well 1702-15DA remains unable to inject sufficient volume of water; additional well work may be necessary. f. AOGCC records indicate well has not commenced injection. Technical Evaluation 1. Well integrity has yet to be confirmed with required MIT. There has been no injection into the well to date. 2. Cement rinsate sample from Baranoff Well #4 (Evergreen Pilot Well #2) isnon-hazardous - pH=12.0 (<12.5 and >2.0 defines boundaries for non-hazardous characteristics) a. Testing performed by Northern Testing Laboratories, Inc. (10/29/02) 3. EPA has historically opposed disposal into Class II-D wells of fluids such as cement rinsate. AOGCC has made no official determination in the past regarding the applicability of disposing these fluids in Class II-D wells. EPA opposition appears to be based on how they define "uniquely associated" and "intrinsically derived from the primary field operations". a. By EPA interpretation, cement rinsate in Evergreen request for Pioneer Well #1702- 15DA is not RCRA exempt since they have not come from downhole. b. The phrase "intrinsically derived from the primary field operations" was intended to differentiate exploration/development/production operations from transportation"2, not limit injection based on whether or not it was used. i. Class II waste streams should be inclusive of any fluids that are generated in ~r~mary field operations intrinsic (necessary) to exploration, development, or production; designation should recognize. the composition of the fluid, and the intent for use; primary field operations should recognize all activities that occur (human and industrial) as part of the proposed action. c. EPA's interpretations appear to contradict the performance provisions and environmental objectives intended for the UIC program. i. Adverse effects to human health resulting from waste injection is expected to be negligible; the greatest potential for adverse impact is from the discharge to and seepage from surface placement of wastes3 ii. Questions posed by injection practice must be interpreted in relation to a complex and long established background of existing regulations4; it appears this was intended to account for regulatory requirements established by states iii. "Prudent waste management decisions, even for non-hazardous wastes, should be based on the inherent nature of the waste"5 iv. The definition of Class II fluids was intended to establish be flexible to recognize unique circumstances to the geologic and hydrologic conditions peculiar to certain areas of the country6 ' Evergreen purchased unit acreage and Well #1702-15DA (water disposal well) in Apri12001 from Ocean Energy 2 Congressional Record: House Report, October 1, 1980. s EPA Report to Congress: Management of Wastes from Exploration, Development, and Production ... a EPA Report to Congress: Management of Wastes from Exploration, Development, and Production ... s "Exemption of Oii & Gzs Exploration and Production Wastes from Federal Hazardous Waste Regulations"; EPA530- K-O1-004, January 2002 6 Preamble to UIC Regulations; 47 FR 4995, February 3, 1982. • v. It is highly unlikely that any promulgation of regulations such as RCRA could recognize every E&P waste fluid eligible for exemption; the minimum standards and intent was appropriately established in the RCRA exemption but the list of exempt fluids was not intended to be comprehensive. 4. EPA has recognized that non-hazardous characteristic of cement rinsate (and for that matter, anything that can satisfy the testing established by 40 CFR 261) and has agreed that underground injection is the environmentally preferred option for these fluids; ConocoPhillips reiterates the environmental preference; AOGCC concurs. 5. Wastes streams are minimized through proper planning and controlling batch sizes a. There is a practical limit to waste minimization; design, engineering and implementation for proper well construction must account for uncertainties in well conditions; this is accomplished with safety factors that equate to excess volumes of fluids (e.g., well control, proper annulus cementing for zonal isolation and structural support, etc.). Recommendation - This File Review indicates Evergreen compliance with AOGCC regulations, permitting conditions, and DIO 20. - The composition of cement rinsate proposed for disposal under this administrative approval of DIO 20 is no different than the fluids already authorized as Class II-D fluids; the only difference is the fact that the proposed fluid has not been used downhole. - Underground injection represents the environmentally preferable option for managing cement rinsate at Pioneer project location. - Approval of Evergreen's request for an Administrative Approval to DIO 20 is recommended. - Evergreen should be reminded of requirements for: a. Conducting and reporting the results of a standard Mechanical Integrity Test (MIT) prior to initiating disposal into Well #1702-15DA b. Annual Performance Report per DIO 20 Rule 5. Aquifer Exempion 5 http://www.state.ak.us/local/akpages/ADMIN/ogc/oindex/aeo/aeo5.htm • STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3192 The REQUEST OF UNION OIL COMPANY OF CALIFORNIA ("Unocal") ) Ptquifer Exemption 0Y for an Aquifer Exemption Order fora disposal well located ) in the Pioneer Unit in the Matanuska-Sustina Valley in ) Pioneer Unit Southcentral Alaska. ) Pioneer Coalbed Meth June 29, 1999 IT APPEARING THAT: 1. Union Oil Company of California ("Unocal") applied to the Alaska Oil and Gas Conservation Commission ("Commission") on May 14, 1999 for an aquifer exemption for purposes of Class II disposal in the Pioneer Unit 1702-15DA WDW well ("WDW well"). Additional information requested by the Commission was received on June 9, 1999. 2. The Commission publish notice of an opportunity for public hearing in the Anchorage Daily News on May 18, 1999. 3. The Commission did not receive any protest or request for a public hearing. 4. The Commission has jurisdiction in this matter under AS 31.05.030(h), 20 AAC 25.440, and 40 CFR 147, Subpart C -Alaska. 5. The Commission submitted a copy of Unocal's aquifer exemption application to the U.S. Environmental Protection Agency Region 10 ("EPA Region 10") on May 20, 1999, .and a copy of the proposed order on June 14, 1999, in accordance with Section 14 of the November 22, 1991 Memorandum of Agreement between EPA Region 10 and the Commission. 6. EPA Region 10 did not object to the requested Aquifer Exemption Order for the Pioneer Unit 1702-15DA WDW well. FINDINGS: 1. Unocal plans to test the Coalbed methane potential of the Pioneer Unit, which is located north of Knik Arm, in the Wasilla to Big Lake vicinity of the Matanuska-Susitna Valley. The Parks Highway run east to west through the center of the unit. 2. Unocal seeks authorization to inject Class II waste fluids into permeable sands and conglomerates of the Tyonek Formation, at depths below 2500 feet in its proposed Pioneer Unit 1702-15DA WDW well (June 9, 1999 letter). 3. The WDW' well is proposed to be drilled approximately 1500 feet from the south line, 515 feet from the east line of Section 15, T17N, R2W, Seward Meridian. The well location is in the southern portion of the unit, approximately centered east to west, in an area of the valley with relatively low. population. 4. There are many water wells and a few oil wells in the Matauska-Susitna Valley. 1 of 3 10/3l /2002 2:08 PM Aquifer Exempion 5+ ~ http://www.state.ak.us/local/akpages/ADMIN/ogc/oindex/aeo/aeo5.htm • 5. To determine the total dissolved solids ("TDS") content in formation waters at the proposed WDW well location, Unocal analyzed wireline log data, well cuttings descriptions and produced water analysis reports from 31 oil and gas exploratory wells within a 48 township (1,728 square mile) study area surrounding the Pioneer Unit; records from water wells within four miles of the Pioneer Unit boundary; and published data on the surficial geology and distribution of fresh water in the area. 6. Unocal utilized a method for calculating TDS content from wireline log data endorsed in EPA publication "Survey of Methods to Determine Total Dissolved Solids Concentration"(KEDA Project No. 30-956). Unocal refined the technique by calibrating log calculations with produced water samples in order to insure conservative estimates of TDS content. 7. The ARCO Big Lake Test ("BLT") No. 1 well was drilled 6.8 miles due west of the proposed WDW well location. 8. The BLT No. 1 well encountered Pleistocene glacial deposits to a depth of 535 feet measured depth ("MD") and Oligocene to Miocene-aged Tyonek Formation sediments to a depth of 5,745 feet MD. The BLT well appears to provide the most reliable control for estimating stratigraphic conditions at the WDW well location. 9. Salinity data from the BLT No. 1 well shows an abrupt change in TDS content at about 535 feet MD from less than 500 ppm to greater than 3,000 ppm, and salinity ranging from between 3,000 ppm to 13,000 ppm TDS between 1,500 feet to 4,000 feet MD. 10.The abrupt change in TDS content appears to correspond to the unconformable contact between Pleistocene-aged glacial deposits and the much older underlying Tyonek Formation. 11.The Tyonek Formation in the northern portion of the Cook Inlet Basin is composed of fluvial deposits that have a high degree of lateral lithologic variability. 12.Subsurface mapping throughout the Cook Inlet Basin has demonstrated that lithologic sequences dominated. by fine-grained deposits and coals are generally more laterally continuous than coarse-grained intervals. 13.Over 700 feet of confining zone lithologies are present in the BLT No. 1 well between 535 feet and 2,790 feet MD, with the thickest confining zone being a predominantly shale interval between 2,520 feet and 2,790 feet MD. 14.The proposed WDW well disposal zone will be within that portion of the Tyonek Formation that is confined by the stratigraphic equivalents of 2520 feet and 2790 feet MD interval in the BLT No. 1 well. 15.The TDS content of formation waters in the proposed WDW well disposal zone is expected to be greater than 6,000 ppm. 16.Unocal proposes to verify actual TDS content of disposal zone in the proposed WDW well by obtaining uncontaminated water samples following the wells completion and prior to disposal operations. 17.Records from the Division of Mining and Water Management, Department of Natural 2 of 3 10/31/2002 2:08 PM Aquifer Exempion 5 • http://www.state.ak.us/local/akpages/ADMIN/ogc/oindex/aeo/aeo5.htm ~ • Resources, show that most water wells in study area are less than 300 feet deep, and that within four miles of the unit boundary only 10 water wells exist with a depth greater than 400 feet, with the deepest at 605 feet. 18.Five water wells are present within ahalf-mile radius of the proposed WDW well, the deepest of which is 140 feet. 19.Unocal intends to obtain baseline chemical analyses of water chemistry from the adjacent water wells prior to initiating disposal operations in the WDW well. 20.The Commission's authority to act in this matter is embodied in 40 CFR 147 Subpart C, the Alaska Oil and Gas Conservation Act (AS 31.05), and the Alaska Administrative Code (20 AAC 25.005 through 20 AAC 25.570). CONCLUSIONS: 1. Drinking water with TDS content less than 500 ppm is present to a depth of approximately 535 feet in the vicinity of the proposed WDW well. 2. The portion of the aquifer proposed for disposal operations in the WDW well will likely have a TDS content greater than 3,000 ppm but less than 10,0000 ppm. 3. The portion of the aquifer proposed for disposal operations in the WDW well does not now serve as a source of drinking water, and cannot reasonably be expected to supply a public water system because it is situated at a depth that makes recovery for drinking water purposes economically impractical and because better quality water exists abundantly at a much shallower depth. 4. In the vicinity of the proposed WDW well, those portions of aquifers common to and which correlate with the interval below 2790 feet in the BLT No. 1 well qualify as exempt freshwater aquifers under 20 AAC 25.440(a)(2). NOW, THEREFORE, IT IS ORDERED THAT those portions of aquifers common to and which correlate with the interval below 2,790 feet MD in the BLT No. 1 well in the following tracts of land are exempt under 20 AAC 25.440. Seward Meridian T17N R2W Sections: 14, 15, 22 and 23. DONE at Anchorage, Alaska and dated June 29, 1999. Robert N. Christenson, P.E., Chairman David W. Johnston, Commissioner Camille Oechsli, Commissioner Aquifer Exemption Order Index 3 of 3 10/31/2002 2:08 PM DIO http://www.state.ak.us/local/akpages/ADMIN/ogc/oindex/dio/dio20.htm • STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: The APPLICATION OF Ocean Energy Resources, Inc. ) Disposal"Injection Order PTo ("Ocean Energy") for disposal of Class II oil field ) wastes by underground injection in the Pioneer Unit ) Well #1702-15DA WDW #1702-15DA WDW well. ) Pioneer Unit August 11, 1999 IT APPEARING THAT: 1. By correspondence dated June 28, 1999, Ocean Energy requested authorization from the Alaska Oil and Gas Conservation Commission ("Commission") to dispose of Class II oil field waste fluids by underground injection into the Pioneer Unit #1702-15DA WDW well, located in Section 15, Township 17 North, Range 2 West, Seward Meridian. 2. The Commission published notice of opportunity for public hearing in the Anchorage Daily News on July 2, 1999. A second notice of opportunity for public hearing was published in the Anchorage Daily News and the Frontiersman on July 16, 1999. 3. The Commission did not receive any protest or a request for a public hearing 4. The proposed disposal project requires an aquifer exemption under 20 AAC 25.440. The Commission issued Aquifer Exemption Order #5 on June 29, 1999, after receiving no objection from the U.S. Environmental Protection Agency. FINDINGS: 1. Ocean Energy is the operator of the Pioneer Unit. There are no other operators within a one-quarter mile radius of the proposed disposal injection well. Ocean Energy has notified the surface owners by certified mail of the proposed disposal project. 2. Aquifer Exemption Order #5 exempts those portions of aquifers underlying the Pioneer Unit in Sections 14, 15, 22 and 23, Township 17 North, Range 2 West, which are common to and correlate with the interval below 2,790 feet in the BLT No. 1 well. 3.Ocean Energy proposes to conduct disposal injection within the proposed Pioneer Unit 1702-15DA WDW well in strata of the Tyonek Formation, which are common to and correlate with the interval below 2,790' in the BLT No. 1 well. 4. The proposed disposal zone in the BLT #1 well is confined by over 700 feet of shale between the top of the disposal interval and the base of freshwater known to be used in the area. Similar confinement is anticipated at the proposed Pioneer Unit 1702-15DA WDW well location. 5. There are currently no other wells within one-quarter mile radius of the proposed Pioneer Unit 1702-15DA WDW well that penetrate the injection zone. 1 of 4 10/3 I /2002 2:07 PM DIO http://www.state.ak.us/local/akpages/ADMIN/ogc/oindex/dio/dio20.htm • • 6. Specific injection intervals will be identified after the Pioneer Unit 1702-15DA WDW well is drilled and logged. Ocean Energy will analyze produced water samples following completion of the well to confirm that the aquifers meet the requirements for exemption specified in 20 AAC 25.440. Copies of the water analysis will need to be submitted to the Commission for concurrence. 7. A cement bond log will be run and cement records evaluated to ensure that the #1702-15DA WDW well is cemented adequately to isolate the proposed disposal interval. 8. The well will be completed with 133/s inch conductor set at 35 feet MD, 95/s inch surface casing set at 700 feet MD and cemented to surface, and 7 inch production casing set at 4,100 feet MD and cemented back into the surface casing. 9. The well will be equipped with 27/s inch tubing string and packer set 50 feet above the top of the perforations or the uppermost disposal interval, whichever is shallowest. 10.Ocean Energy intends to utilize the Pioneer Unit 1702-15DA WDW well to dispose of fluids and drilling wastes from the coalbed methane test wells described in the "Pioneer Unit Plan of Operations" and the "Pioneer Unit-Vine Extension Plan of Operations." 11.The waste stream will consist of produced formation water, drilling, completion and workover fluids, rig wash, drilling mud slurries, and other Class II fluids generated from drilling, production, workover and completion operations. Although initially predominantly produced water, constituent volumes may vary depending on drilling, workover, stimulation and maintenance activity. 12.Ocean Energy estimates that the maximum daily volume to be injected will be 2,000 barrels per day. 13.Ocean Energy estimates the average and maximum injection pressure will not exceed 900 psi. 14.Ocean Energy will conduct periodic surveillance of disposal operations through temperature surveys, pressure transient tests, step rate tests, thermal decay time logs, disposal rate and pressure monitoring, mechanical integrity tests and tagging effective depth to determine fill buildup. 15.Reservoir surveillance techniques will also be used for tracking near wellbore fluid movement, estimating dimensions of disposal fracture or disposal storage volume and detecting changes in disposal zone characteristics. 16.Evaluation of operational performance data and reservoir surveillance data will aid in preventing fracturing of the confining zones. CONCLUSIONS: 1. The requirements of 20 AAC 25.252(c) have been met. 2. Those portions of aquifers underlying the Pioneer Unit in Sections 14, 15, 22 and 23, Township 17 North, Range 2 West, which are common to and correlate with the interval below 2 of 4 10/31 /2002 2:07 PM DIO http://wwwstate.ak.us/local/akpages/ADMIN/ogc/oindex/dio/dio20.htrn • • 2,790 feet in the BLT No. 1 well, are exempt for Class II injection activities. 3. Waste fluids that are authorized for disposal in the Pioneer Unit 1702=15DA WDW well will consist exclusively of Class II waste generated from drilling, completion, workover and production operations. 4. Permeable strata, which are common to and correlate with the portion of the Tyonek Formation below 2,790 feet in the BLT No. 1, are likely to be present in the Pioneer Unit 1702-15DA WDW well. These strata can reasonably be expected to contain the total volume of disposal fluids anticipated for this project. 5. Waste fluids will be contained within appropriate receiving intervals by confining lithologies, cement isolation of the wellbore and operating conditions. 6. Disposal injection operations in the Pioneer Unit 1702-15DA WDW well will be conducted at rates and pressures below those required to fracture the confining zones. 7. Periodic surveillance of disposal material placement, .daily monitoring of operating parameters when in operation, and demonstration of mechanical integrity at least every two years will ensure the waste fluids are contained within the disposal interval. Changes in baseline data may be an indication that fluid is escaping beyond the designated confining zone. 8. The mechanical. integrity of the tubing, packer and production casing in the Pioneer Unit 1702-15DA WDW well must be demonstrated in accordance with 20 AAC 25.412 prior to commencing injection operations. 9. Disposal injection operations in the Pioneer Unit 1702-15DA WDW well will not cause waste, jeopardize correlative rights, or impair ultimate recovery. NOW, THEREFORE, IT IS ORDERED THAT: Rule 1 Authorized Infection Strata for Disposal. Class II oil field fluids may be injected in conformance with Alaska Administrative Code Title 20, Chapter 25, for disposal into Tyonek Formation strata that are common to and correlate with the interval below 2,790 feet in the BLT No. 1 well in the #1702-15DA WDW well. Rule 2 Authorized Fluids This authorization is limited only to Class II fluids. The Commission must be notified immediately if any non-Class II fluids are injected into the well. Rule 3 Demonstration of Tubing/Casing Annulus Mechanical Integrity A schedule must be developed and coordinated with the Commission that ensures the tubing-casing annulus is pressure tested prior to initiating disposal and at least once every two years thereafter. The casing must be tested at a surface pressure of 1500 psi or 0.25 psi/ft multiplied by the true vertical depth of the packer, whichever is greater. The test pressure must show stabilizing pressure and may not decline more than 10 percent within 30 minutes. The Commission must be notified at least twenty-four (24) hours in advance to enable a 3 of 4 10/31 /2002 2:07 PM .DIO . http://www.state.ak~ cal/akpages/ADMIN/ogc/oindex/dio/dio20.htm representative to witness pressure tests. Rule 4 Well Integrity Failure Whenever disposal rates and/or operating pressure observations or pressure tests indicate pressure corrlmunication or leakage of any casing, tubing or packer, the operator must notify the Commission on the first working day following the observation, obtain Commission approval of a plan for corrective action and obtain Commission approval to continue injection. Rule 5 Surveillance Operating parameters including disposal rate, disposal pressure, annulus pressures and volume of fluids and solids pumped must be monitored and reported according to requirements of 20 AAC 25.432. An annual report evaluating the performance of the disposal operation and summary of surveillance activity and results must be submitted by July 1 of each year. Rule 6 Administrative Action Upon request, the Commission may administratively revise and reissue this order or any of its rules upon proper showing that the change is based on sound engineering practices, will not allow waste fluids to escape from the disposal zone, and will not cause waste. DONE at Anchorage, Alaska and dated August 11, 1999. Robert N. Christenson, P.E., Chairman David W. Johnston, Commissioner Disposal Infection Order Index 4 of 4 10/31 /2002 2:07 PM "f7~ \~=IBC-I~.=1~ RESOURCES (ALASKA) CORP~ A Subsidiary of Evergreen Resources, Inc. October 30, 2002 Ms. Cammi Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission (AOGCC) 333 West 7th Ave, #100 Anchorage, Alaska 995501-3539 RE: Analytical Results to Support a Request for Administrative Approval to inject cement rinsate in the Pioneer Unit Injection Order No. 20, 1702-15DA WDW Well, Pioneer Unit, Matanuska-Susitna Borough Dear Commissioner Taylor: Evergreen Resources Alaska Corp submitted a letter requesting an administrative approval per Rule 6 (Administration Action) to the Injection Order No. 20 to inject cement rinsate into the Pioneer Project Class II Well referenced above to AOGCC on September 19, 2002. Evergreen commenced drilling activities on October 28, 2002. A representative sample of the cement rinsate was collected per Alaska Department of Environmental Conservation (ADEC) protocol and was delivered to Northern Testing Laboratories in Anchorage on October 29, 2002. The analytical result for the cement rinsate sample was 12.0 and determined to be non-hazardous per 40 Code of Federal Regulations, Part 261. A waste becomes hazardous for corrosivity if the pH is less than or equal to 2.0, or greater than or equal to 12.5 the under the Resource Conservation Recovery Act (RCRA). The analytical result for the cement rinsate sample is attached. Upon approval, Evergreen will place the rinsate into the cuttings pit for later disposal in the subject well. Subsequent cement jobs will include field screening to ensure pH levels are acceptable. On behalf of Evergreen, we sincerely appreciate you assistance in this project. Sincerely, Evergreen Resources (Alaska) Corp • John Tanigawa Alaska Projects Manager Cc: Dan Seamont, Jim Rigg, Winton Aubert, AOGCC Lynx Enterprises, Inc. (file) RECEIVER acT 30 ~ao2 ~taslta QiF&~Gas ~b~ngeComm9ssion P.O. Box 871845 Wasilla, AK 99687 TEL 907.357.8130 FAX 907357.8340 ul, I ~b ' NG b (~ G6HI'1 NIL HI~ICHORRGE ~d0a?HERN TESTING LABORATORIES, INC. P.1 3530 I~OU$TE11AL AVENUE FAIREANKs^^, ALASKA 99701 (907) ,A56-3118 • FAX 456-3125 ~a7~t'I 51LVERADl7 WAY; UNIT N .ANCHORAGE, ALASKA 99516 (907) 349-1000 ~ FAX 949••1016 Y+QIJCH 340043 ?RUpH4E BAY, ALASKA 99734 (907) 859.2145 • FAX 655-2146 naaersxr.um.•a•+e..vrµ+..-.•.......~..~~rrm.rc. e..srwam z Lynx Enterpriscs/Evergreen 1029 West 3rd Ave, Suite 400 Anchorage, AK 99501 Attn: Julie Noftke PhonE: (907)277-4b11 FAX: (907) 277-4717 NTL Lab#: A304645 Client Sample ID: 102902 Rinsate O1 & 02 Co Location: Comp. Of Units 402 & 461 Client Project: COC#: 31147 Sample Matrix; Liquid PWS #: Comments: Evergreen Pilot #2 Baranoff #4 Report Date: 10/30/02 Date Arrived: 10/29/02 Sample Date: 10/29/02 Sample 'I~ae: 13:15 Collected By: JC F'la6 DeSr-Stions MRL ° Method RcpottZevel MCL =Max. Contaminant Level H =Present in Method Stank H .. Above Regulatory Maximum M = Mntrix inoerferencc = gstimsted Value Below MRL D - Lost to Dilution 8 = Es6maoed Val~c Anatysitt Method Itesolt Flag MRL MCL Units ~ PreP Prep Analysts Parameter Method Date - D9te TPA 150.1 pH 12.0 Unit 1029/02 Reported By: Wendy Mitchell Anchozage Laboratory Manager ~~ C uI~CR.cIN RESOUNCES {ALASKA)COHP. 5.~~.`s;rar c~c'~a~~rec~Aedwrres. !n. September 19, 2002 Ms. Cammile Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission (AOGCC) 333 West 7th Ave, #100 Anchorage, Alaska 995501-3539 • RE: Request for Administrative Approval to inject cement rinsate in the Pioneer Unit Injection order No. 20, 1702-15DA WDW Well, Pioneer Unit, Matanuska-Susitna Borough Dear Ms. Taylor: Evergreen Resources Alaska Corp requests an administrative approval per Rule 6 (Administration Action) to the Injection Order No. 20 to inject cement rinsate into the Pioneer Project Class 11 Well referenced above. Background: API Class G cement or equivalent will be used to cement our well casings. The cement itself is similar to those used in the construction industry and contain additives that make it more amenable for the unique requirements of down hole environments. These additives include calcium chloride, silica flour, gilsonite and others. Immediately after the well is cemented, water is used to clean the pumps, tanks and lines that connect the cementing equipment to the well. The water used to clean up the equipment is called °rinsate". Samaling and Proposed Aaaroval Process: Evergreen discussed the proper sampling method with the ADEC. We will sample the cement rinsate to verify that its contents are Resource Conservation Recovery Act (RCRA) non-hazardous per 40 Code of Federal Regulations, Part 261. Based on the RCRA hazardous waste characteristics (ignitability, corrosivity, reactivitiy, and toxicity) only corrosivity is a concern for the cement rinsate. A waste becomes hazardous for corrosivity if the pH is less than or equal to 2.0, or greater than or equal to 12.5. The rinsate will be representatively sampled per ADEC protocol and sent to an Anchorage analytical laboratory for analysis of corrosivity (pH) by SW9040. These results will then be shared with the AOGCC. Until we receive approval from the commission, the subject rinsate will be containerized on site. Upon approval, Evergreen will place the rinsate into the cuttings pit for later disposal in the subject well. Subsequent cement jobs will include field screening ensuring pH levels are acceptable. Dates: We plan to spud a well in Pilot 2 on September 25, 2002. Rnnsate from the first cement job will be available for your review late on September 25th or early on September 26th. We request that Evergreen be advised on this request as soon as feasible. On behalf of Evergreen, we sincerely appreciate your help and assistance in this project. Sincerely, Evergreen Reso rtes {Alaska) Corp John Tanigawa Alaska Projects Manager Cc: Dan Seamont, Jim Rigg, Winton Aubert, AOGCC Lynx Enterprises, Inc. (file) P. O. Box 871805 Wesilla, Alaska 99587 Te1;9W-357-8730 Fax;907.35T-$340 www.EvetgreanGas.com -- I RESOURCES(ALASKA)CORP. 4 .Si~hciAury nt F r~mnn Awwrtrox, it September 19, 2002 Ms. Cammile Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission (AOGCC) 333 West 7th Ave, #100 Anchorage, Alaska 995501-3539 RE: Request for Administrative Approval to inject cement rinsate in the Pioneer Unit Injection order No. 20,1702-15DA WDW Well, Pioneer Unit, Matanuska-Susitna Borough Dear Ms. Taylor: Evergreen Resources Alaska Corp requests an administrative approval per Rule 6 (Administration Action) to the Injection Order No. 20 to inject cement rinsate into the Pioneer Project Class II Well referenced above. Background: API Class G cement or equivalent will be used #o cement our well casings. The cement itself is similar to those used in the construction industry and contain additives that make it more amenable for the unique requirements of down hole environments. These additives include calcium chloride, silica flour, gilsonite and others. Immediately after the well is cemented, water is used to clean the pumps, tanks and lines that connect the cementing equipment to the well. The water used to clean up the equipment is called "rinsate". Sampling and Proposed Approval Process: Evergreen discussed the proper sampling method with the ADEC. We will sample the cement rinsate to verify that its contents are Resource Conservation Recovery Act (RCRA) non-hazardous per 40 Code of Federal Regulations, Part 261. Based on the RCRA hazardous waste characteristics (ignitability, corrosivity, reactivitiy, and toxicity) only corrosivity is a concern for the cement rinsate. A waste becomes hazardous for corrosivity if the pH is less than or equal to 2.0, or greater than or equal to 12.5. The rinsate will be representatively sampled per ADEC protocol and sent to an Anchorage analytical laboratory for analysis of corrosivity (pH) by SW9040. These results will then be shared with the AOGCC. Until we receive approval from the commission, the subject rinsate will be containerized on site. Upon approval, Evergreen will place the rinsate into the cuttings pit for later disposal in the subject well. Subsequent cement jobs will include field screening ensuring pH levels are acceptable. Dates: We plan to spud a well in Pilot 2 on September 25, 2002. Rinsate from the first cement job will be available for your review late on September 25th or early on September 26th. We request that Evergreen be advised on this request as soon as feasible. On behalf of Evergreen, we sincerely appreciate your help and assistance in this project. Sincerely, Evergreen Reso rces (Alaska) Corp • John Tanigawa Alaska Projects Manager Cc: Dan Seamont, Jim Rigg, Winton Aubert, AOGCC Lynx Enterprises, Inc. (file) P. O. Box 871843 YYasi~, Alaska 09557 T~:907.'i57-8130 Fax907-357-8340 www.EVerpreeM~as.can Cement Ru-sate • s Subject: Cement Rinsate Date: Tue, 17 Sep 2002 15:42:31 -0600 From: Jerry Jacob <JerryJ@EvergreenGas.com> To: cammy_taylor@admin.state.ak.us CC: John Tanigawa <JohnT@EvergreenGas.com> Thanks for the opportunity to talk with you yesterday about the disposal of rinsate associated with coalbed methane well cementing. As we discussed, I briefly looked into the issue of products and processes uniquely associated with oil and gas exploration and development. In brief: * Oil and gas well cement is specially formulated to address unique conditions associated with oil and gas wellbores. I'm faxing on manufacturer's "lay person" explanation of this issue. * Oil and gas well cement is graded according to specific standards (American Petroleum Institute) that are unique to the industry. Also see the fax information. * Special chemicals are often added to oil and gas well cement to address problems encountered during pumping of cement, downhole conditions and other situations unique to oil and gas. I've faxed but one example of the types of products and additives that may be employed in oil and gas well cement. * In the case of coalbed methane wells, additives and the special cement add up to a tailor-made mix that is adjusted to address unique downhole conditions. Materials that may be added to the cement for a coalbed methane well may include disunite, bentonite, calcium chloride, silica flour., among others. * In short, oil and gas well cement mixtures are unique to the industry, as is the equipment used to pump such mixtures downhole. * The task of cementing casing for a coalbed methane well requires running a mixture of produced water through the mixer and cement pump to clear the pump and equipment. In short, this is standard practice and critical to protect the equipment from damage. * The cement left behind in the mixing and pumping equipment is not the equivalent of "unused" drilling or frac fluid. The cement mixture caught in the equipment has been used up (i.e., it cannot be recovered or used again) as part of the cementing operation. It's impossible to cement the casing in a well without this occurring and without generating some of this waste. The material trapped in the equipment used to cement the casing for a well is associated with operations to locate or remove oil and gas from the ground. This operation is a pre-requisite for such activity and the waste is an unavoidable aspect of that operation. The waste material is an integral part of the process used to pump the identical material downhole. The materials and equipment used in this process are uniquely associated with oil and gas exploration, development and production. Finally, none of the waste is generated by transportation or manufacturing activities. 1 of 1 9/20/2002 7:48 AM 4 09/17/2002 11:03 FAg 303 298 7 EVERGREEN RESOURCES ~I 001 ~f~ ~~ ~l ,.<,_,.~ _.., l~i, fY- .. .. ~. ~ _ ~~F31?~i~i't'*i~' To: Camille Taylor From: Gerald Jacob Fax: (9d7}_276-7542 P~~ (including 8 cover sheet): Pf:one: Catm 9N 7/02 ~~ CC: ^ Urgent ^ For Review ^ Please Comment ^ Please Reply ^ Please Recyde • Comments: R there is a:ry problem in receiving this fau, please ca11303-288.8700. 1401 17"' Street, Suite 1200 Denver, Colorado 80202 Tel 303-298-8100 Fax 303-298-7800 !~ Dil-well ce+rnerlts For more information, please contact Serae Schmidt. ~ ;: i~ ~ "~ ~.,~, ::. 1~.~ ~ ~~~ ~~11 ~,,.~ a ....1 f 1. Cements for oil-wells 2. Five grades of oil-well cement 3, International service Click here to read the press release: CCB: 1 DD tonnes of cement in the middle of the sea. 1. Cements for oil-wells CCB is one of the oldest producers of cements for oil wells. Launched on the European market in 1954, CEMOIL won the certificate of the American Petroleum Institute (API) four years later. CCB is the first European cement manufacturer to belong to this type of institution. Since that time, several million tonnes of CEMOIL have been used around the world, notably by drilling and cementing companies. The professionalism of CCB in this domain is well established. 2. Five grades of oil-well cement Cementing an oil-well is a difficult and delicate operation. The mixture has to set at a depth of 6000 m or more, where the temperature can exceed 220°C and the pressure is 1500 times greater than at sea level. In these difficult conditions, the setting time of the cement is of vital importance. Whatever the nature of the terrain, the conditions onshore or offshore, climates varying from storms in the North Sea to the burning sands of the desert, the range of CEMOIL cements has been developed to suit the most extreme requirements.. http://www.ccb.be/products/pfor en.htm 9/17/2002 09/17/2002 16:03 FA% 303 298 7 EVERGREEN RESOURCES I~j003 CCB -Products and applicatioil-well cements ~ Page Z of 3 - CEMOIL has five grades of oii-well cements conforming to the standards of the API Classes CEMOIL grades {APi standards) API CLASS • Used below the surface down to 6000 feet A: (1830 m) • When no particular characteristics are required. • Available as an ordinary grade APi CLA55 . Used below the surface down to 6000 feet B: (1830 m) when the conditions,demand a moderate resistance to sulphates. . This grade is also available with a high resistance to sulphates. API CLASS . Used below the surface down to 6000 feet C: {1830 m) when the conditions require a high initial resistance. • This grade is also available with a high resistance to sulphates. API CLASS . Used as a base cement from the surface G: down to 8000 feet (2440m}, as it is or with accelerators or retarders to cover a wide range of depths and temperatures. . This grade is also available with a high resistance to sulphates. API CLASS • Similar to Class G but with a higher mixture H: density. . This grade is also available with a high resistance to sulphates. i:ach one of these grades has characteristics required by oil drilling operators 1 Pumpability time corresponding to requirements 2 Elevated speed of hardening 3 High mechanical resistance 4 Resistance to aggressive Fluids and to sulphate corrosion 5 Volumetric stability and adequate rheological properties Other major advantages of CEMOIL: http://www.ccb.be/products/pfor en.htm 9/17/2002 09/17/2002 16:04 FA% 303 298 7 EVERGREEN RESOURCES f~j004 CCB -Products and applicatio~il-well cements ~ Page 3 of 3 The product reacts well with additives. This characteristic, associated with a manufacturing technique that is both rigorous and regular, contributes to making CEMOIL one of the best performing oil-well cements on the market. In addition to cements with the API label, CCB also offers special cements for use with advanced oil-well drilling techniques. These cements have high-performance physico-chemical characteristics. The whole range of oil-well cements is covered in a technical document available on demand from CCB. 3. International Service At the crossroads of Europe, beside a river, and just an hour from one of the largest ports in the world (Antwerp), CCB is ideally situated to ensure the delivery of CHEMOIL In the best conditions. Delivery can be arranged in bulk, in sacks on pallets, in in barrels or in large bags of 1500 kg -CCB is well equipped to offer the most suitable solutions for the needs of its clients. CCB has been involved in international markets for many years and can, therefore, offer specific competence in the reliability, rapidity and price of transport. Finally, CCB has a finance and insurance service that is able to arrange financing programmes and the coverage of risks.. As well as advice on the choice of the cement best suited to the application, CCB is also able to offer the services of its laboratory.. © CCB 1999-2001. Updated: February 19, 2001 To Contact the Webmaster or consult our FA http://www,ccb.be/products/pfor en.htm 9/17/2002 09/17/2002 16:04 FAg 303 298 7 EVERGREEN RESOURCES f~j005 t;learwater, lnc. - (;ementmg ~cals ~ Page 1 of 2 ~ R&D ~ Manufacturing ~• About Us : News For more information, click on a product below Por Technical Data "'• Sheet. ~~r •• . Must have Adobe Acrobat Reader to view these files. AMICO-109 Annular Gas Migration Control CD-110 Cement Dispersant and Friction Reducer CD-12 Cement Dispersant and Friction Reducer CEX-100 Cement Extender CEX-209 Cement Extender/Gas Migration Control CFL-110 Cement FIuId Loss Additive CFL-117 Cement Fluid Loss Additive CFL-12 Cement Fluid Loss CFL-150 Cement Fluid Loss CFL-6E Cement Fluid Loss/Gas Migration Control CLC-101 Lost Circulation Control for Cementing Clear-Air 100 Liquid Cement Defoamer Clear-Air 100P Powered Cement Defoamer Clear-Air 200 Liquid Cement Defoamer Clear-Air 207 Uquld Cement Defoamer Clear-Air 300 Liquid Cement Defoamer Clear-Block 10 Temporary Piuggin Agent Clear-Block 10 Temporary Gel Diverting Ptll Clear-Block 10 Gel Data Clear-Flush 1A Powdered Mud Flush Additive CR-220 Cement Retarder CR-221 Cement Retarder CR-223 Cement Retarder CR-230 Cement Retarder CR-231 Intensifier for Cement Retarder CR-233 Hydroxycarboxylic Cement Retarder CR-240 Cement Retarder CWS-280 Spacer for Cementing Fl.X-Bubbles Bridging Agent http://www.cwichem.com/cemeniing.htm 9/I 7/2002 09/17/2002 16:04 FAX 303 298 78 Clearwater, Inc. -Cementing ~cals EVERGREEN RESOURCES CFL-tSOD Cement Fluid Loss with Defoamer CFL-151 Cement Fluid Loss CFL-203 Low Temperature Cement Fluid Loss CFL-205 Latex Type Cement Fluid Loss Additive CFL-3000 Cement Fluid Loss. Control CFL-6 Cement Fluid Loss/Gas Migration Control • Clear-Block 8 Temporary Pluggin Agent Clear-Block 8 Temporary Gel Diverting Pili Clear-Block 8 Gel Data Clear-Chek P 6ctender/Lost Circulation Control Additive Clear-Chek Extender/Lost CPrculation Control Additive C~ 006 Page 2 of 2 Latex-10L Proprietary Additive for Fluid Loss LCP-100 Cement Fluid Loss Additive LCP-101 Cement Fluid Loss Additive MudCleair 48 Mud Removal Surfactant http://www.cwichem.com/cementing.htm 9/17/2002 09/17/2002 16:04 FAX 303 298 7~ EVERGREEN RESOURCES ~ [~j007 ISO 9001 Cet7ffled CLEwtWATER, INC. t P C ~ ~ ~ C 8 i d 8 t i Engineered Chemistry Headquarters 5665 srarw Avem~e • Pdlsb~spA, PA 15zz5 usa • ~ x12294.1616 • Phox:412~t~9089 • www.cwkrrem.com DESCRIPTION Cement is a mixture of water and cement parti- cles. Excessive water loss can damage forma- tions and in severe cases dehydrate the cement to the point of preventing the cement from being placed properly. LCP-100 is a dual purpose ce- ment additive that prevents fluid in the cement from being forced into the permeable formation while it also prevents gas or water flow from ~- teringthe wellbore. USAGE Use 0.5-2.0 percent LCP-100 by weight of ce- mentand is effective up to 210°F (99°C). The wa- ter requirement is adjusted to obtain the desired slurry viscosity. LCP-100 should not be used in cements containing greater than 10% NaCI by weight of water or with borax or boric acid. ADVANTAGES • Greatly reduces fluid loss • Prevents flow after cementing • Chemical resistant • Stable from thermal shock • Increases shear bond • Reduces sedimentation • Reduces free water LCP-'I 00 Cement Fluid Loss Additive LCP-900 AND CEMENT LCP-100 is extremely effective as a fluid loss con- trol additive even at low concentration levels. This makes LCP-100 ideal for primary cement jobs where fluid loss control is required. By minimizing the fluid loss, LCP-100 helps to maintain an adequate pressure differential be- tween the annulus and the formation. This pres- sure differential prevents water and gas flow through the setting .cement. LCP-100 contains a temperature stable, medium molecular weight polymer which causes a slight viscosity increase in the cement slurry, reducing free water. LCP-100 does not retard or accelerate the ce- ment slurry and is compatible with most cement- ing additives, including retarders, accelerators, extenders and weighting agents. PHYSICAL PROPERTIES Appearance ................................. White Powder Solubility in Water ...............................Complete This material is supplied solely for informational purposes and Clearwater, Inc.. makes no guarantees or warranties, either ex- pressed or implied, with respect to the accuracy and the use of this data. All product warranties and guarantees shall be gov- erred by the Standard Terms of Sale. 99/03 09/17/2002 16:05 FA% 303 298 7~ EVERGREEN RESOURCES ~ f~j008 ISO 9007 Certified CLEARWATER, INC. t e ~ h ~ ~ C a ~ d 8 1 8 Engineered Chemis~y H~uwrers: 5eo5 cxand Avemro • Pitlsb~uph, PA 15228 USA • Fac 412(2841618 • Pha~:472/16&8383 • wwwcwxsern.can DESCRIPTION Cement is a mixture of water and cement parti- cles. Excessive water loss can damage forma- tions and in severe cases dehydrate the cement to the point of preventing the cement from being placed properly. LCP-101 is a dual purpose ce- ment additive that prevents fluid in the cement from being forced into the permeable formation while it also prevents gas or water flow from en- tering the wellbore. USAGE Use 0.5-2.0 percent LCP-101 by weight of ce- ment and. Is effective up to 210°F (99°C). The wa- ter requirement is adjusted to obtain the desired slurry viscosity. LCP-101 should not be used in cements containing greater than 10% NaCI by weight of water or with borax or boric acid. ADVANTAGES • Greatly reduces fluid loss • Prevents flow after cementing • Chemical resistant • Stable from thermal shock • Increases shear bond • Reduces sedimentation • Reduces free water LCP-101 Cement Fluid Loss Additive LCP-109 AND CEMENT LCP-101 is extremely effective as a fluid loss con- trol additive even at low concentration levels. This makes LCP-101 ideal for primary cement jobs where fluid loss control is required. By minimizing the fluid loss, LCP-101 helps to maintain an adequate pressure differential be- tween the annulus and the formation. This pres- sure differential prevents water and gas flow through the setting cement, LCP-101 contains a temperature stable, medium molecular weight polymer which causes a slight viscosity increase in the cement slurry, reducing free water. LCP-101 does not retard or accelerate the ce- ment slurry and is compatible with most cement- ing additives, including retarders, accelerators, extenders and weighting agents. PHYSICAL PROPERTIES Appearance ................................. White Powder Specific Gravity .......................................1.8-1.9 Solubility in Water......... ..................... Partial This material is supplied sdely for informational purposes and Glearwater, Inc. makes no guarantees or warranties, either ex- pressed or implied, with respect to the accuracy and the use of this data. All product warranties and guarantees shall be gov- erned by the Standard Terms of Sale, 9g/p3 45 2 b 2Q0 Kaska t~l ~ has forts. ~olnmissi~rl c~or Mr. Blair Wondzell State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Blair: Apri124, 2000 -~. ~, _~ - ~ , _. Following several conversations and correspondence we have completed the majority of the State of Alaska's request for regulatory information on the Pioneer Unit. Please find enclosed the following items. Pioneer Unit 15DA WDW (Permit to Drill #99-064): 1. Completion Report (Form 10-407) with geologic market 2. Daily Completion Summary Report 3. Daily Completion Reports 4. Daily Drilling Reports 5. Digital data from logs run on diskette 6. Copies of logs 7. Copy of Fluid Sample Analysis 8. Monthly Injection Report (Form 10-406) for water dispc No additional samples or testing were done on this well. Pioneer Unit 14CC (Permit to Drill #99-065): 1. Daily Completion Reports 2. Digital data from logs run on diskette No additional samples or testing were done on this well Pioneer Unit 15DD (Permit to Drill #99-066) 1. Completion Report (Form 10-407) with geologic market 2. Daily Completion Summary Report 3. Daily Completion Reports 4. Daily Drilling Reports 5. Digital data from logs run on diskette 6. Copy of Fluid Sample Analysis 7. Copy of cementing tickets No additional samples or testing were done on this well Pioneer Unit BLT #1 (Permit to Drill #99-068) 1. Completion Report (Form 10-407) with geologic marke 2. Daily Completion Summary Report 3. Daily Completion Reports 4. Drilling Summary 5. Daily Drilling Reports 6. Copy of logs 7. Copy of Fluid Sample Analysis 8. Copy of Well Bore Diagram No additional samples or testing were done on this well. Our D~ that lagging companies do not produce Sepia copies anymore. ~~/~ ~~Ook~ GcJi/~I ~t.J~sr1~ VQ~ M ~ sd,~ !r 7/3 ~ /" ~ 0 wGJ/s, . - Co~~ ~'6s~~~ ~~ vhf liarG ~L°SC/r~'t'~n fx ~`~ ° ~ z ~~lS ~ ~ ~~~~~s Ocean Energy, Inc. #7 Cantrel Drive P.O. Box 549 Newcastle, Wyoming 82701 (307) 746-4052 Fax: (307) 746-4045 f t I trust you will see that Steve Davies and Robert Crandall will receive copies of this information. If you have any further questions on any of the attached please feel free to contact me at 307-746-4052. Sincerely, Loretta Mu h rP Y Production Analyst Attachment ~~~l..~ ~~~~~ 2 6 2000 r~aska C~~ ~ Gas Cons. Commission Anchorage MAY 26 '00 14 22 FR OCEAN ENERGY • 7132658852 TO 919072767542 P.01~02 • Ocean Energy aA,->r~ ~ 1 z6 ~~ -- ~_. .. _ T0: t7 r~ .-.c~c~l ~ FAX• ~t~ -'~7(~-75 Z. COMPANY: ~ O (~- Gam. FROM: e, S ,.,, c~ _t TELEPHONE: "7 ~ - 2, ~ 5- 67$ RE: PACES includin cover awe : z- CC: [ X J Urgent [ ]For Review [ ]Please Comment [ ] Pleasc Repty [ j Please Approve Comments: OGCaIn Energy, tn~, 1001 F~nn~n, Suite 1600 Haust~n, Tcxas 77002 -G79G X713) Z65.60QU MAY 26 '00 1422 FP, OCEAN ENERGY 7132658852 TO 919072767542 P.02i02 ~~~$r _ ~A ~ Z 6 zooo ~~tas~~ ~ A~~~a ilaska Oil and Gas ~ irslon May 26, 2000 3001 Poreli ve ¢'~~ Anchorage, Alasl~a 99501 Robert P. Crandall Senior Petroleum Geologist Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Mr. Crandall: Ocean Energy We received your letter of May 3, 2000 advising Ocean Energy of additional requirements for our Pioneer Prospect welts. We are working to get Sepias of log data. Please understand that this is difficult due to the fact that the logs are computer generated through a dry print process and Sepia is not routinely created in well logging anymore. However, we have provided digital data to our logging company and they are in file process of creating the Sepia. Our core analysis program is still in progress and we will forward those reports as soon as results arc available. Descriptive core data has been compiled and is being forwarded to your office. Regards, SA~...~.e~/~-~- Br~ y~fi Saunders Senior Reservoir Engineer Daean Energy, Inc. 1001 Fannin, Suite 1600 Houston, Texav 77002-6794 (713) 265-6000 ** TOTAL PAGE.02 ** 1~; ~ .Q r , '; ~LA5>~ OIL A1QD t~~S COIQSLRQ~TIOIQ COMDIIS5IO11t T+DNY KNOWt.ES, Cs01/ERNOR 3001 PORCUPINE DRNE ANCHORAGE. ALASKA 99501-3192 PHONE:. (907) 279-1433 FAX: (907) 276-7542 May 3, 2000 Loretta Murphy Productiorp Analyst Ocean Energy, Inc. P.O. Box $49 Newcastlep Wy. 82701 Dear Ms. llvlurphy: We received your most recent submittal of information from the Pioneer Prospect coalbed methane v~ells in the Matanuska Valley, Alaska on April 26, 2000. This submittal does not bring Ocean Energy into compliance with the requirements of 20 AAC 25.071. A list of materials still outstanding follows: Pioneer Upit well 15DD, Permit Number 99-66, API Number 50-009-2001.7 1) Sepias; of the open hole logs and the segmented bond tool (cement bond log). czdl/cnl/hdil, hdil/ac, sbt 2) Wholei core description (lithology, porosity,fractures, cleats ect) 3} Wholei. core chips, as described in 20 AAC 25.071 (b) (4) 4) Wholei core analysis, as described in 20 AAC 25.071 (b) (8) (C). In the context of a coalbed reservoir these analysis include methane desorbtion measurements. Pioneer Unlit well 15DA-WDW, Permit Number 99-64, API Number 50-009-20015 1) Sepias and paper copies of all logs run in the well. (hdil/dallgr/cal, ldl/cn/gr/cal, sbt) Fioneer Unit well 14CC, Permit Number 99-65, API Number 50-009-2001.6 1) Sepias and paper copies of all logs run in the well (hdil/dal/gr/cal, zdl/cnl/gr/cal, sidewalk, sbt) 2) Digital sbt data 3) Whop, core description (lithology, porosity,fractures, cleats etc) 4) Whoh core chips, as described in 20 AAC 25.071 (b) (4) 5) Wholei core analysis, as described in 20 AAC 25.071 (b) (8) {C). In the context of a coalbed reservpir these analysis include methane desorbtion measurements, 5) Sidew~.ll core analysis and descriptions i ~.;.. Loretta M1~rphy ~ 2 ~ May 3, 2000 Production Analyst Ocean Energy, Inc. Pioneer Unit well BLT #1 RE, Permit Number 99-68, API Number 50-009-20006-90 1) Digitau sbt data 2) Sbt sepia We note ypu have made a significant effort to comply with the .reporting requirements of 20 AAC 2.071, however all of this information is long overdue and is considered very important ko this developing play. If we have not been advised in writing by May 26, 2000 as to the disposition of these materials, I will recommend the Commission undertake an enforcement action as described in ' 20 AAC 2.535. Notwithstanding, AOGCC recognizes the importance and potential benefit of OE's coalbed methane pjrogram to the State of Alaska. We look forward to your continued success. as well as a good working relationship with the Commission. Please give me a call at (907)-793-1230 if you'd like to discuss this matter. Sincerely i ~ `~ i~`> % ,~ .G{~ Robert P. Crandall Senior Petroleum Geologist cc: Rabert Christenson Cajmmy Oechsli-Taylor Dan Seamount APR-06-00 01:37 PM 3©~~ • t ~^~ ~~-~ ~ ~' ~ ~ 7~~ G~~~1 - L6 r~`~`~ ~ v +^n~C y Loretta Murphy v' ° / J' f ~OG ~!t'! C~~c~ dv~ CfL d GG(. G~ J` G ~ ~ h I~tt ~ ~C < , -TstL , ~ n / ~ ~ Eqc ~j o h ~ n ~-o zc.i ~ ~ - /j .t, C- e- , ~'\. I~y-~'^-~-~ "->, J'-•~x- ~ d"~l 1 ~ w lal t,L~ ~~ ~~ Z- ~ IYi ~U ~~ U i2 4~i~ ~ S April X000 ! ~ J G G% ~~ ~U ~ Et ~ Cam- h~ o ~~-; ~.~~ ~~•o tit. Mr. Itubu,l P ~ d7L ~-~1, C.~ 6 ~ J . Crandall °~' I Senior Petrul~unt Geolubist 3UU I l'urcuphte Drive Anchorage, Alnska 99501.319 Uuur Mr, Crnndull: am in receipt of your letter dated April 4, ?UUU. 1 ant cun~etrily working un your requests. Thy unc thing I -vauld like to clarify is that Ofa has not eonnn~rtced injection operations into well ISpA WDW. All of the wells m~ntioncd in >~ou letter arc currently shut in until sometirne in the sprins when we will commence eunthletiun operations. I have been in contact with Chuck Wilson our Drilling Supervisor to cullrct the adilitiunal data That you are requesting. A large portion of t)te data Hurst carne !'tom our geolobical department and will come out of Houston. Chock is currently in the process of contracting them to help us gather this information. I have made it clear to Mr. Wilson that the State of Alaska is growing impatient and that we tirr overdue in our requirements. He wilt relay this to Noustuu and ask them to forward the requested items to thu Newcas otlicc so wr con make every effort to see that you receive all items that you have requested. 1 have in our files the daily drilling ttnd operations history. I will copy and forward these items innncdiateh' aS well as the two lacking complrtian reports And the labs on the DLT !; I and I SC WUW. 1:rpola~!iie Ior all ol'thc confusion and thank you for you cooperation. Sirtccrely, pPt : ~ ~ 2"v0u i r. "' • ~~~a C} ~. J6j ;;ins. sj~nmt~t~' P. 01 .. i ~~ F ,. .~<< ~~ ~~ i~ Larry Curtis Ne,+•castle Area Foreman ocean Ener+~y, toe. ,r~ c',,,tr,t ttrh•r P,et, IA,x Say Nrwc.+«u~, Wynminti s27tn cilt71746.4052 I~,.: t.~tn>74h•4tt45 J ti , , + L~1 ~LASS~ OIL ~D GAS COIQ5ERQATIOIQ COMM15SIO1Q April 24, 2000 Mr. Chuck Wilson, Drilling Supervisor Ocean Energy, Inc. 1001 Fannin Street, Suite 1600 Houston, Texas 77002-6714 TONY KNOWLE S, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 9950 1-31 92 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re: Pioneer Unit, Alaska: Request for Compliance with Alaska Oil and Gas Conservation Commission Reporting Regulations Dear Mr. Wilson: During 1999, Ocean Energy, Inc. (OE) received permits to drill the 15DA WDW, 14CC, and 15DD wells within the Pioneer Unit near Wasilla, Alaska. OE also received a permit to re-drill and recomplete the ARCO BLT # 1 well within this same unit. It is the Alaska Oil and Gas Conservation Commission's (AOGCC's) understanding that operations were conducted in each of these wells. Alaska Administrative Codes 20 AAC 25.070 and 20 AAC 25.071 require OE to submit reports, records, geologic data and well logs for each of these wells within 30 days after completion, abandonment, or suspension. According to our records, OE has not complied with these regulations, having only submitted incomplete information on two wells. On April 4, 2000, Mr. Robert Crandall sent the attached letter detailing the required Pioneer Unit information to Ms. Loretta Murphy, a Production Analyst in your Newcastle, Wyoming office. On April 6, 2000, AOGCC received the attached letter from Ms. Murphy indicating efforts were being made to comply with our request. To date, no additional information has been received from OE. Your prompt attention to this problem is requested. Continued lack of compliance will result in further commission action. A copy of the AOGCC's regulations is attached for your review. If you have any questions, please contact Robert Crandall or Steve Davies at (907) 279-1433. Notwithstanding, AOGCC recognizes the importance and potential benefit of OE's coalbed methane program to t}ie State of Alaska. We look forward to your continued success as well as a good working relationship with the Commission. Sincerely, Robert N. Christenson, P.E. Chair cc: Mr. Kevin Tabler. Land and Governmental Affairs Manager. UNOCAL (w/attaclu~ients) Attacluncuts: "Pioneer Unit, Alaska: Compliance with Alaska Oil and Gas Conservation Commission Reporting Regulations.~~ letter from Robert Crandall to Ocean Energy, dated April 4. 2000. Ocean Energy response letter to Robert Crandall, dated April h, 2000. Alaska Oil and Gas Conservation Commission Regulations. November 7. (999 APR-06-00 01:37 PM Mr, lZubvrt I'. Crandall Senior I'l'.tt'C11CUlt1 Geologist 3(IU I I'urcupine Urive Anchorage, Ahtska 99501.319: L7eur Mr, C"rnndall; April G, 2000 P. 01 & ~+. „ ~r pay ~ "'r ~y, I am in receipt of your letter dated April 4, ?UOU. I Fan currently Working ur) your requests. 'Chu one thing I would like to clarify is that p131 has not eonuncttced injection operatiuns into well t S[)A WDW, All o('the wells mentioned in you letter ore currently shut in until sometime in the spring when we will comtrencr; cunthletiun operatiuns. 1 have been in contact with Chuck Wilson our [)rifling Supervisor to collect the additional data That you are requesting. A Ittrge portion of t}te data must come front our gcolobical depat'tment and will come out uf` liuuston. Chuck is currently in the process of contacting them to help us gnthur this in('ormation. I hove made it clear lu Mr, Wiltion that tllc 5lale ol'Alaska is growing impatient attd that WG nt'e overdue in our requirements. FIN W1II 1'e lily thiti tU NOUStUtt Find risk lheltl lU fUPWard the rrrquested items to the Newcastle o1'(ice so Wr tsut make every efiiirt to see that you receive all items that you have reduasted. 1 have in our files the daily drilling sand operatiuns history, I will copy and forward then items innncdiatell~ as well as thr two lacking cc)ntplrtian reports and the logs ort the DLT l~ 1 and I51:)A W'C>W. apologixu }br all ol'the confusion and thank you for you cooperation. 5incercly, ~.T i~ ~ ~ 2V~~ ~a~~~ ~[ ~ An~vrag~~ntmi~~ ~~ _..,~, Loretta Murphy Pri)duction Analyst i ~) v Li~rry Curtis Newcastle Arcr3 I'Ore171:1n Ocean wwner9y, InC. F7('antrcll)riva P.t), E~~s 549 NCwca«tla, Wyumtnk 62701 falt7) 74b-4052 {+,~~ (,107)7hb.41145 199-065-0 PIONEER i1NIT 1702 14CC 50- 009-20016-00 MD 04050 TVD 03980 Completion Date: 9/23/99 Com pleted Status: 1-GAS Current: T Name Interval Sent Received T/C/D L CZDL/CNL/HDIL 1 LGR 676-4039 OH 2/5 12/28/99 1/21/00 '~~,i„ L HRDIP/DIR SRVY 1 LGR 675-3512 OH 5 12/28/99 1/21/00 ~j~pR L MUD PASON BL(C) 0-4051 OH 1 12/28/99 1/21/00 ~'~ ~~L SBT 1 LGR 0-3925 9/20/99 CH 5 12/28/99 1/21/00 R DIR SRVY OE 628-3506. OH 12/28/99 1/21/00 199-066-0 PIONEER UNIT 1702 __ _ 15DD _ __ 50- 009-20017-00 MD 04228 TVD 04228 Completion Date: 12/12/99 Com pleted Status: 1-GAS Current: T Name Interval Sent Received T/C/D L CZDL/CNL/HDIL FINAL BL 680-4212 OH 2/5 3/15/00 L HDIL/AC FINAL BL 0-4203 OH 2/5 3/15/00 L SBT FINAL BL 0-4217 10/2/99 CH 5 3/15/00 Friday, Apri128, 2000 Page 1 of 1 i ~ ~ March 24, 2000 ~cean Energy l~es~urces, Inc. #7 ~antrel )!rive Newcastle, Wyoming 82711 Attention: Ms. Loretta Murphy, Production Analyst Pioneer Unit, Alaska: Compliance with Alaska Oil and Gas Conservation Commission Reporting Regulations , ~~~ Dear Ms. Murphy: ~~~„'~-[-~/ ~ ~~~ s During 1999, Ocean Energ Resources, Ina (OER) received permits to drill the 15DA WDW, 14CC, and 15DD wells within the Pioneer Unit near Wasilla, Alaska. OER also received a permit to re-drill and recomplete the ARCO BLT # 1 well within this same unit. It is the Alaska Oil and Gas Conservation Commission's (AOGCC's) understanding that operations were conducted in each of these wells. Alaska Administrative Codes 20 AAC 25.070 and 20 AAC 25.071 re uire OER to submit reports, records, geologic data and well logs for each of these wells within 30 days after completion, abandonment, or suspension. Additionally, fluids injected into wells must be reported according to 20 AAC 25.420 and 20 AAC 25.432. We have received. reports that OER has commenced injection operations into well 15DA WDW. According to our records, OER has not complied with these regulations, having only submitted incomplete information on two wells. Your cooperation is requested to bring OER into compliance wit Alaska regulation ~C~i~ O~Q ~,~,Q,c, t~'-~ ' ~ .~2sa~ ~,.ic~ ~ a~ ~~- ~1 ~ ~~ ~~....,, GV~ Information la ing on each of OER's Pioneer Unit wells includes, but is not limited to, the ~.Ut~~ following: a,~,.Q kY~ ioneer Unit 15DA WDW (Permit to Drill Number 99-064): 1. Completion Report (Form 10-407) 2. Geologic markers encountered (name, measured depth and true vertical depth of each marker) ~~I_,, 3. Daily drilling and operations history p ~~c~ ~ L, I V'~ 4. Sepia and reproduced copies of all logs run ~n~G~C ~~~~' •-~! 5. Digital data and verification listings for all logs run (on diskette or tape) ~''~ 6. Data and reports for production tests, drill stem tests or other formation tests (if conducted) 7. Samples and laboratory analytical results from conventional and sidewall cores (if obtained) g y ~ p ( ) s the well was used for disposal purposes. , Pioneer Unit 14CC (Permit to Drill Number 99-065): _ A.. a ~-,~,,~ Q'`~~ ~~ 1. Daily drilling and operations history ~ ~`,,, ~ C _ ~ , -_t~ NQ 2. Sepia copies of all logs run ~~'X~~.'. ~'''"~~ G~ Ri~ Gt~f~t., ^((~3. Digital data and verification listings for all logs run (on diskette or tape) 1 ~~ ~ ~~ ~~ ~( 8. Geochemical and formation fluid analyses (if obtained) Month! Injection Re ort Form 10-406 for the month ~ • ~~ 4. Data and reports for production tests, drill stem tests or other formation tests (if conducted) NHS. Samples and laboratory analytical results from conventional and sidewall cores (if obtained) • ~-`.P ~6. Geochemical and formation fluid analyses (if obtained) 1~ O t-~``~ W G~~ ioneer Unit 15DD (Permit to Drill Number 99-066): Geologic markers encountered (name, measured depth and true vertical depth of each marker) `r 2. Daily drilling and operations history IvQ3. Sepia copies of all logs run '~.t4. Digital data and verification listings for all logs run (on diskette or tape) ''~.f 5. Data and reports for production tests, drill stem tests or other formation tests (if conducted) 6. Samples and laboratory analytical results from conventional and sidewall cores (if obtained) ,/ 7. Geochemical and formation fluid analyses (if obtained) j~~,a-f~l ~~C3 ~-e- c.~ Re. 'oneer Unit BLT #1 (Permit to Drill Number 99-068): Completion Report (Form 10-407) Geologic markers encountered (name, measured depth and true vertical depth of each marker) Daily drilling and operations history 4. Sepia and reproduced copies of all logs run 5. Digital data and verification listings for all logs run (on diskette or tape) 6. Data and reports for production tests, drill stem tests or other formation tests (if conducted) ~. Geochemical and formation fluid analyses (if obtained) A copy of the AOGCC's regulations is attached for your review. If you have any questions, please contac~ '' _* r '' " ~~ T--=,.o~ --* `nn~~ ~-~n , e.~ ~j Sincerely, -~'kaarr Attachment: Alaska Oil and Gas Conservation Commission Regulations, November 7, 1999 ~ ~~~~ ~c,n ~.. ~ ~ls-,~.5' ~ 4 SUPPLEMENTAL Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: Pioneer Unit Disposal Injection Order Ocean Energy Resources, Inc. by letter dated June 28, 1999, has requested an order allowing the disposal of Class II fluids in the Pioneer Unit in the Matanuska- Susitna Valley in Southcentral Alaska. The requested order would allow disposal of oilfield wastes in the Pioneer Unit #1702-15DA WDW well located in Section 15, Township 17 North, Range 2 West, Seward Meridian. A person who may be harmed if the requested order is issued may file a written protest prior to 4:00 PM, August 2, 1999 with the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska 99501, and request a hearing on this matter. If a protest is timely filed a hearing on the matter will be held at the above address at 9:00 AM on August 17, 1999, in conformance with 20 AAC 25.540. If no protest is filed, the Commission will consider the issuance of the order without a hearing. Copies of the application for disposal injection are available for inspection at the AOGCC office at the above address. This notice supersedes the notice published July 2, 1999 that would have provided an opportunity for public hearing on August 3, 1999. The August 3 date is withdrawn. If you re a person with a disability who may need a special modification in order to comment or to attend the public hearing, please contact Diana Fleck at 793-1221 before August 11, 1999. Published July l6, 1999 Frontiersman AO# 02U 14003 Robert N. Christenson, P.E. Chairman • • F_rontier~ anlVallev~n ~~~~ers Alaska's Best Small Tawn Newspaper 5751 East Mayflower Court (907) 376-5225 UNITED STATES OF AMERICA STATE OF ALASKA THIRD DIVISION. Wasilla, AK 99654 (907) 694-6318 (907} 352-2277 Fax AFFIDAVIT OF PUBLICATION BEFORE ME, THE UNDERSIGNED, A NOTARY PUBLIC THIS DAY PERSONALLY APPEARED TRACY RESSLER WHO, BEING FIRST DULY SWORN, ACCORDING TO LAW, SAYS THAT SHE IS THE BUSINESS MANAGER OF THE FRONTIERSMAN NEWSPAPER PUBLISHED A WASILLA IN SAID DIVISION THREE AND STATE OF ALASKA AND THAT THE ADVERTISEMENT, OF WHICH THE ANEXED IS A TRUE COPY, WAS PUBLISHED ON THE FOLLOWING DAYS: JULY 16, 1999 AND THAT THE RATE CHARGED THEREIN IS NOT IN EXCESS OF THE RATE CHARGED PRIVATE INDIVIDUALS. SUBSC~ED AND ; THIS 16TH DAY OF NOTARY PUBLIC FOR FR 7921 AO-02014003 IItN TO BEFORE ME Y 1999. ~ ~ ` T.'~ ~V J. CA~LSGN j ~ i _ t ~~ ;~~• ~ `~.. a~A . L. C ,z. [r,. Es ,~-C C2 ~ -su-~~rr~t. lVOtice of PupFic ttearit-~ STATE OF AIASICA Alaska tlil end G8S Conservation Commission Re: Pioneer Unit Risposat Injection Order Clean Energy Resources, Irtc. by letter dated June 28, 1999, haS requ2ste~d att;brd~r ailo6ving the dispessaJ pt Class 11 fluids in the Picineer-Unit ict the tvlatanuska-Susi~ta t}al-. ley in Sauthoehtral l~laska. The requested order would flow disposal of oiIcLwast,~: in the Pioneer Unit #1702- "lSDA WDW well located In Sectron 15, Ttlwn~hip 47 ; Range2 Wesf, SewardMeriii, ian. A who may be t~m~ec1- if t~rsquested order is issued may file a written ~rntest pri- orto 4A0 PM, August2,1889 with ate Alaska Oit anal Gas G®nsCruation Commission, 3001 Poralpine brivt3, Anchpr- age,Alaska 89501, aril request a`hearing on this matter. t£ a ~ protest is timely filed a'hearitig on the matter will be held at the above address at 9;00 AM ~t August 17, ;1999, in conior- manse with 20 AP~G'..~,540. If no protest is'et tl'ie t~Rt- mission wilA c« 'tsideP the issuance of ttte;prd0r stdut a hearing. ~s of the appticatlbn ~ des- posal injection pare avaHalNe tot inspection atthe AOGCC catttce at the above address. This. notice supersedes nati~apubfished-July 2; 11399 ttret would have provided ~ oppoiiunity for pubNc haarran5. mAugust3, t8951.Tf'~eAt~}uat. 3 date is wtttldrawn. tFyou ace's person wiitt a dis~ ebil~y who may reed a~peciat modification in order to edrp- ment sir to strand the public hearing, please contact Oiaria ~Fieck at783-1~t t~efpre August 11, 1999: Rok~+t N. Christenson, P.E. Chaimtan , Publish: July 16, 1998 ~R7521 ' ~ 1 • ~ ~ ~ l • • ~ DRI / MCGRAW HILL PIRA ENERGY GROUP RANDALL NOTTINGHAM LIBRARY 24 HARTWELL 3 PARK AVENUE (34TH & PARK) LEXINGTON MA 02173 NEW YORK NY 10016 a OVERSEAS SHIPHOLDING GRP NY PUBLIC LIBRARY DIV E ECON DEPT GRAND CENTRAL STATION 1114 AV OF THE AMERICAS P 0 BOX 2221 NEW YORK NY 10036 NEW YORK NY 10163-2221 ALASKA OFC OF THE GOVERNOR OIL DAILY JOHN KATZ STE 518 CAMP WALSH 444 N CAPITOL NW 1401 NEW YORK AV NW STE 500 WASHINGTON DC 20001 WASHINGTON DC 20005 ARENT FOX KINTNER FLOTKIN KAHN US MIN MGMT SERV LIBRARY CHIEF OCS STATS & INFO WASHINGTON SQ BLDG 381 ELDEN ST MS 4022 1050 CONNECTICUT AV NW HERNDON VA 20170-4817 WASHINGTON DC 20036-5339 LIBRARY OF CONGRESS U S DEPT OF ENERGY STATE DOCUMENT SECTION PHYLLIS MARTIN MS EI823 EXCH & GIFT DIV 1000 INDEPENDENCE SW 10 FIRST ST SE WASHINGTON DC 20585 WASHINGTON DC 20540 "'r`t-~ ~r- s r r TECHSYS CORP BRANDY KERNS PO BOX 8485 GATHERSBURG MD 20898 DPC DANIEL DONKEL 1420 NORTH ATLANTIC AVE, STE 204 DAYTON BEACH FL 32118 AMOCO CORP 2002A LIBRARY/INFO CTR P O BOX 87703 CHICAGO IL 60680-0.703 LINDA HALL LIBRARY SERIALS DEPT 5109 CHERRY ST KANSAS CITY MO 64110-2498 MURPHY E&P CO ROBERT F SAWYER P O BOX 61780 NEW ORLEANS LA 70161 US GEOL SURV LIBRARY NATIONAL CTR MS 950 RESTON VA 22092 SD DEPT OF ENV & NATRL RESOURCES OIL & GAS PROGRAM 2050 W MAIN STE #1 RAPID CITY SD 57702 ILLINOIS STATE GEOL SURV LIBRARY 469 NATURAL RESOURCES BLDG 615 E PEABODY DR CHAMPAIGN IL 61820 ALFRED JAMES III 107 N MARKET STE 1000 WICHITA KS 67202-1811 UNIV OF ARKANSAS SERIALS DEPT UNIV LIBRARIES FAYETTEVILLE AR 72701 .~ . ~ • s CROSS TIMBERS OPERATIONS DWIGHTS ENERGYDATA INC SUSAN LILLY JERLENE A BRIGHT DIRECTOR 210 PARK AVE STE 2350 PO BOX 26304 OKLAHOMA CITY OK 73102-5605 OKLAHOMA CITY OK 73126 IOGCC R E MCMILLEN CONSULT GEOL P O BOX 53127 202 E 16TH ST OKLAHOMA CITY OK 73152-3127 OWASSO OK 74055-4905 OIL & GAS JOURNAL CH2M HILL LAURA BELL J DANIEL ARTHUR PE PROJ MGR P O BOX 1260 502 S MAIN 4TH FLR TULSA OK 74101 TULSA OK 74103-4425 BAPI RAJU MARK S MALINOWSKY 335 PINYON LN 15973 VALLEY VW COPPELL TX 75019 FORNEY TX 75126-5852 US DEPT OF ENERGY DEGOLYER & MACNAUGHTON ENERGY INFORMATION .ADMINISTRATION MIDCONTINENT DIVISION MIR YOUSUFUDDIN ONE ENERGY SQ, STE 400 1999 BRYAN STREET STE 1110 4925 GREENVILLE AVE DALLAS TX 75201-6801 DALLAS TX 75206-4083 a MOBIL OIL CORP GAFFNEY, CLINE & ASSOC., INC. MORRIS CRIM ENERGY ADVISORS P O BOX 290 MARGARET ALLEN DALLAS TX 75221 16775 ADDISON RD, STE 400 DALLAS TX 75248 GCA ENERGY ADV MOBIL OIL RICHARD N FLETCHER JAMES YOREK 16775 ADDISON RD STE 400 _ P O BOX 650232 DALLAS TX 75248 DALLAS TX 75265-0232 JERRY SCHMIDT STANDARD AMERICAN OIL CO 4010 SILVERWOOD DR AL GRIFFITH TYLER TX 75701-9339 P O BOX 370 GRANBURY TX 76048 CROSS TIMBERS OIL COMPANY PRITCHARD & ABBOTT MARY JONES BOYCE B BOLTON PE RPA 810 HOUSTON ST STE 2000 4521 S. HULEN STE 100 FORT WORTH TX 76102-6298 FT WORTH TX 76109-4948 SHELL WESTERN E&P INC ENERGY GRAPHICS K M ETZEL MARTY LINGNER P O BOX 576 1600 SMITH ST, STE 4900 HOUSTON TX 77001-0574 ~ HOUSTON TX 77002 H J GRUY PURVIN & GERTZ INC ATTN: ROBERT RASOR LIBRARY 1200 SMITH STREET STE 3040 2150 TEXAS COMMERCE TWR HOUSTON TX 77002 600 TRAVIS ST HOUSTON TX 77002-2979 RAY TYSON 1617 FANNIN ST APT 2015 HOUSTON TX 77002-7639 BONNER & MOORE LIBRARY H2O 2727 ALLEN PKWY STE 1200 HOUSTON TX 77019 PETRAL CONSULTING CO DANIEL L LIPPE 9800 RICHMOND STE 505 HOUSTON TX 77042 MARK ALEXANDER 7502 ALCOMITA HOUSTON TX 77083 CHEVRON PAUL WALKER 1301 MCKINNEY RM 1750 HOUSTON TX 77010 OIL & GAS JOURNAL BOB WILLIAMS 1700 W LOOP SOUTH STE 1000 HOUSTON TX 77027 MOBIL OIL N H SMITH 12450 GREENSPOINT DR HOUSTON TX 77060-1991 MARATHON OIL CO GEORGE ROTHSCHILD JR RM 2537 P O BOX 4813 HOUSTON TX 77210 UNOCAL EXXON EXPLOR CO REVENUE ACCOUNTING LAND/REGULATORY AFFAIRS RM 301 P O BOX 4531 P O BOX 4778 HOUSTON TX 77210-4531 HOUSTON TX 77210-4778 EXXON EXPLORATION CO. CHEVRON USA INC. T E ALFORD ALASKA DIVISION P O BOX 4778 ATTN: CORRY WOOLINGTON HOUSTON TX 77210-4778 P 0 BOX 1635 HOUSTON TX 77251 PETR INFO PHILLIPS PETR CO DAVID PHILLIPS ALASKA LAND MGR P O BOX 1702 P O BOX 1967 HOUSTON TX 77251-1702 HOUSTON TX 772.51-1967 PHILLIPS PETROLEUM .COMPANY WORLD OIL W ALLEN HUCKABAY MARK TEEL ENGR ED PO BOX 1967 P O BOX 2608 HOUSTON TX 77251-1967 HOUSTON TX 77252 EXXON CO USA EXXON CO USA RESERVES COORD RM 1967 G T THERIOT RM 3052 P O BOX 2180 P 0 BOX 2180 HOUSTON TX 77252-2180 HOUSTON TX 77252-2180 EXXON CO USA PENNZOIL E&P GARY M ROBERTS RM 3039 WILL D MCCROCKLIN P O BOX 2180 P O BOX 2967 HOUSTON TX 77252-2180 HOUSTON TX 77252-2967 CHEVRON CHEM CO MARATHON LIBRARY & INFO CTR MS. NORMA L. CALVERT P O BOX 2100 P O BOX 3128, STE 3915 HOUSTON TX 77252-9987 HOUSTON TX 77253-3128 ACE PETROLEUM COMPANY PHILLIPS PETR CO ANDREW C CLIFFORD ERICH R. RAMP PO BOX 79593 6330 W LOOP SOUTH HOUSTON TX 77279-9593 BELLAIRE TX 77401 PHILLIPS PETR CO PHILLIPS PETR CO JOE VOELKER PARTNERSHIP OPRNS 6330 W LP S RM 492 JERRY MERONEK BELLAIRE TX 77401 6330 W LOOP S RM 1132 BELLAIRE TX 77401 TEXACO INC WATTY STRICKLAND R EWING CLEMONS 2803 SANCTUARY CV P O BOX 430 KATY TX 77450-8510 BELLAIRE TX 77402-0430 TESORO PETR CORP LOTS DOWNS 8700 TESORO DR SAN ANTONIO TX 78217 INTL OIL SCOUTS MASON MAP SERV INC P O BOX 338 AUSTIN TX 78767 ROBERT G GRAVELY 7681 S KIT CARSON DR LITTLETON CO 80122 GEORGE G NAUGHT JR P O BOX 13557 DENVER CO 80201 C & R INDUSTRIES, INC. KURT SALTSGAVER 1801 BROADWAY STE 1205 DENVER CO 80202 DIANE SUCHOMEL 10507D W MAPLEWOOD DR LITTLETON CO 80127 AMOCO PROD CO LIBRARY RM 1770 JILL MALLY 1670 BROADWAY DENVER CO 80202 JERRY HODGDEN GEOL 408 18TH ST GOLDEN CO 80401 NRG ASSOC RUBICON PETROLEUM, RICHARD NEHRING BRUCE I CLARDY P 0 BOX 1655 SIX PINE ROAD COLORADO SPRINGS CO 80901-1655 COLORADO SPRINGS CO LLC 80906 JOHN A LEVORSEN RUI ANALYTICAL 200 N 3RD ST #1202 JERRY BERGOSH BOISE ID 83702 P O BOX 58861 SALT LAKE CITY UT 84158-0861 TAHOMA RESOURCES HUNGER OIL INFOR SERV INC GARY PLAYER P O BOX 45738 1671 WEST 546 S LOS ANGELES CA 90045-0738 CEDER CITY UT 84720 LA PUBLIC LIBRARY US OIL & REFINERY CO SERIALS DIV TOM TREICHEL 630 W 5TH ST 2121 ROSECRANS AVE #2360 LOS ANGELES CA 90071 ES SEGUNCO CA 90245-4709 BABSON & SHEPPARD ANTONIO MADRID JOHN F BERGQUIST P O BOX 94625 P O BOX 8279 VIKING STN PASADENA CA 91109 LONG BEACH CA 90808-0279 ORO NEGRO, INC. PACIFIC WEST OIL DATA 9321 MELVIN AVE ROBERT E COLEBERD NORTHRIDGE CA 91324-2410 15314 DEVONSHIRE ST STE D MISSION HILLS CA 91345-2746 76 PRODUCTS COMPANY SANTA FE ENERGY RESOURCES INC CHARLES BURRUSS RM 11-767 _ EXPLOR DEPT 555 ANTON 5201 TRUXTUN AV STE 100 COSTA MESA CA 92626 BAKERSFIELD CA 93309 TEXACO INC US GEOL SURV PORTFOLIO TEAM MANAGER KEN BIRD R W HILL 345 MIDDLEFIELD RD MS 999 P O BOX 5197X MENLO PARK CA 94025 BAKERSFIELD CA 93388 SHIELDS LIBRARY H L WANGENHEIM GOVT DOCS DEPT 5430 SAWMILL RD SP 11 UNIV OF CALIF PARADISE CA 95969-5969 DAVIS CA 95616 ECONOMIC INSIGHT INC US EPA REGION 10 SAM VAN VACTOR LAURIE MANN OW-130 P O BOX 683 1200 SIXTH AVE PORTLAND OR 97207 SEATTLE WA 98101 MARPLES BUSINESS NEWSLETTER PATTI SAUNDERS MICHAEL J PARKS 1233 W 11TH AV 117 W MERCER ST STE 200 ~ ANCHORAGE AK 99501 SEATTLE WA 98119-3960 DUSTY RHODES 229 WHITNEY RD ANCHORAGE AK 99501 DEPT OF REVENUE OIL & GAS AUDIT DENISE HAWES 550 W 7TH AV STE 570 ANCHORAGE AK 99501 GUESS & RUDD GEORGE LYLE 510 L ST, STE 700 ANCHORAGE AK 99501 TRUSTEES FOR ALASKA 725 CHRISTENSEN DR STE 4 ANCHORAGE AK 99501 YUKON PACIFIC CORP JOHN HORN VICE CHM 1049 W 5TH AV ANCHORAGE AK 99501-1930 DEPT OF REVENUE BEVERLY MARQUART 550 W 7TH AV STE 570 ANCHORAGE AK 99501 FAIRWEATHER E&P SERV INC JESSE MOHRBACHER 715 L ST #4 ANCHORAGE AK 99501 STATE PIPELINE OFFICE LIBRARY KATE MUNSON 411 W 4TH AVE, STE 2 ANCHORAGE AK 99501 FORCENERGY INC. JIM ARLINGTON 310 K STREET STE 700 ANCHORAGE AK 99501 PRESTON GATES ELLIS LLP LIBRARY 420 L ST STE 400 ANCHORAGE AK 99501-1937 ALASKA DEPT OF LAW GAFO ROBERT E MINTZ ASST ATTY GEN GREENPEACE 1031 W 4TH AV STE 200 PAMELA MILLER ANCHORAGE AK 99501-1994 125 CHRISTENSEN DR. #2 ANCHORAGE AK 99501-2101 DEPT OF REVENUE BAKER OIL TOOLS OIL & GAS AUDIT ALASKA AREA MGR FRANK PARR 4710 BUS PK BLVD STE 36 550 W 7TH AVE STE 570 ANCHORAGE AK 99503 ANCHORAGE AK 99501-3540 HDR ALASKA INC KOREAN CONSULATE MARK DALTON OCK JOO KIM CONSUL 2525 C ST STE 305 101 BENSON STE 304 ANCHORAGE AK 99503 ANCHORAGE AK 99503 N-I TUBULARS INC ANADARKO 3301 C STREET STE 209 MARK HANLEY ANCHORAGE AK 99503 3201 C STREET STE 603 ANCHORAGE AK 99503 ALASKA OIL & GAS ASSOC AK JOURNAL OF COMMERCE JUDY BRADY OIL & INDUSTRY NEWS 121 W FIREWEED LN STE 207 ROSE RAGSDALE ANCHORAGE AK 99503-2035 4220 B STREET STE #210 ANCHORAGE AK 99503-5911 ~ ~ DEPT OF NATURAL RESOURCES DEPT OF NATURAL RESOURCES DIV OF OIL & GAS DIV OIL & GAS BRUCE WEBB WILLIAM VAN DYKE 3601 C ST STE 1380 3601 C ST STE 1380 ANCHORAGE AK 99503-5948 ANCHORAGE AK 99503-5948 DEPT OF NATURAL RESOURCES DEPT OF NATURAL RESOURCES DIV OF OIL & GAS DIV OF OIL & GAS JULIE HOULE JAMES B HAYNES NATURAL RESRCE MGR 3601 C ST STE 1380 3601 C ST STE 1380 ANCHORAGE AK 99503-5948 ANCHORAGE AK 99503-5948 DEPT OF NATURAL RESOURCES DEPT OF NATURAL RESOURCES DIV OF OIL & GAS PUBLIC INFORMATION CTR TIM RYHERD 3601 C STREET STE 200 3601 C ST STE 1380 ANCHORAGE AK 99503-5948 ANCHORAGE AK 99503-5948 DEPT OF NATURAL RESOURCES FINK ENVIRONMENTAL CONSULTING, INC. DIV OF OIL & GAS THOMAS FINK, PHD JIM STOUFFER 6359 COLGATE DR. 3601 C STREET STE 1380 ANCHORAGE AK 99504-3305 ANCHORAGE AK 99503-5948 ARLEN EHM GEOL CONSLTNT RUSSELL DOUGLASS 2420 FOXHALL DR 6750 TESHLAR DR ANCHORAGE AK 99504-3342 ANCHORAGE AK 99507 STU HIRSH US BUREAU OF LAND MNGMNT 9630 BASHER DR. ANCHORAGE DIST OFC ANCHORAGE AK 99507 DICK FOLAND 6881 ABBOTT LOOP RD ANCHORAGE AK 99507 US BLM AK DIST OFC THOMAS R MARSHALL JR RESOURCE EVAL GRP 1569 BIRCHWOOD ST ART BONET ANCHORAGE AK 99508 6881 ABBOTT LOOP RD ANCHORAGE AK 99507-2899 LASS ARIEY UNIVERSITY OF ALASKA ANCHORAGE 3108 WENTWORTH ST INST OF SOCIAL & ECON RESEARCH ANCHORAGE AK 99508 TERESA HULL 3211 PROVIDENCE DR ANCHORAGE AK 99508 TRADING BAY ENERGY CORP US MIN MGMT SERV PAUL CRAIG RICHARD PRENTKI 5432 NORTHERN LIGHTS BLVD 949 E 36TH AV ANCHORAGE AK 99508 ANCHORAGE AK 99508-4302 US MIN MGMT SERV US MIN MGMT SERV AK OCS REGIONAL DIR RESOURCE STUDIES AK OCS REGN 949 E 36TH AV RM 110 KIRK W SHERWOOD ANCHORAGE AK 99508-4302 949 E 36TH AV RM 603 ANCHORAGE AK 99508-4302 REGIONAL SUPRVISOR, FIELD OPERATNS US MIN MGMT SERV MINERALS MANAGEMENT SERVICE LIBRARY ALASKA OCS REGION 949 E 36TH AV RM 603 949 E 36TH AV STE 308 ANCHORAGE AK 99508-4363 ANCHORAGE AK 99508-4363 US MIN MGMT SERV US MIN MGMT SERV RESOURCE EVAL FRANK MILLER JIM SCHERR 949 E 36TH AV STE 603 949 E 36TH AV RM 603 ANCHORAGE AK 99508-4363 ANCHORAGE AK 99508-4363 JOHN MILLER USGS - ALASKA SECTION 3445 FORDHAM DR LIBRARY ANCHORAGE AK 99508-4555 4200 UNIVERSITY DR ANCHORAGE AK 99508-4667 CIRI ANCHORAGE TIMES LAND DEPT BERT TARRANT P 0 BOX 93330 P O BOX 100040 ANCHORAGE AK 99509-3330 ANCHORAGE AK 99510-0040 BRISTOL ENVIR SERVICES ARCO ALASKA INC JIM HUNTER JOANN GRUBER ATO 712 P O BOX 100320 P O BOX 100360 ANCHORAGE AK 99510-0320 ANCHORAGE AK 99510-0360 ARCO ALASKA INC ARCO ALASKA INC LEGAL DEPT STEVE BENZLER ATO 1404 MARK P WORCESTER P O BOX 100360 P O BOX 100360 ANCHORAGE AK 99510-0360 ANCHORAGE AK 99510-0360 ARCO ALASKA INC ARCO ALASKA INC LIBRARY MARK MAJOR ATO 1968 P O BOX 100360 P O BOX 100360 ANCHORAGE AK 99510-0360 ANCHORAGE AK 99510-0360 ARCO ALASKA INC ARCO ALASKA INC LAND DEPT SAM DENNIS ATO 1388 JAMES WINEGARNER P O BOX 100360 P O BOX 10036 ANCHORAGE AK 99510-0360 ANCHORAGE AK 99510-0360 ARCO ALASKA INC PETROLEUM INFO CORP SHELIA ANDREWS ATO 1130 KRISTEN NELSON PO BOX 100360 _ P O BOX 102278 ANCHORAGE AK 99510-0360 ANCHORAGE AK 99510-2278 ARCO ALASKA INC ALYESKA PIPELINE SERV CO KUP CENTRAL WELLS ST TSTNG PERRY A MARKLEY WELL ENG TECH NSK 69 1835 S BRAGAW - MS 575 P O BOX 196105 - ANCHORAGE AK 99512 ANCHORAGE AK 99510-6105 ALYESKA PIPELINE SERV CO _ ALYESKA PIPELINE SERV CO CHUCK O'DONNELL LEGAL DEPT 1835 S BRAGAW - MS 530E 1835 S BRAGAW ANCHORAGE AK 99512 ANCHORAGE AK 99512-0099 US BUREAU OF LAND MGMT ANCHORAGE DAILY NEWS OIL & GAS OPRNS (984) ~ EDITORIAL PG EDTR J A DYGAS MICHAEL CAREY 222 W 7TH AV #13 P O BOX 149001 ANCHORAGE AK 99513-7599 ANCHORAGE AK 99514 JWL ENGINEERING NORTHERN CONSULTING GROUP JEFF LIPSCOMB ROBERT BRITCH, P.E. 9921 MAIN TREE DR. 2454 TELEQUANA DR. ANCHORAGE AK 99516.-6510 ANCHORAGE AK 99517 GERALD GANOPOLE CONSULT GEOL DAVID CUSATO 2536 ARLINGTON ~ 600 W 76TH AV #508 ANCHORAGE AK 99517-1303 ANCHORAGE AK 99518 ASRC SCHLUMBERGER CONRAD BAGNE ~ DARREN AKLESTAD 301 ARCTIC SLOPE AV STE 300 1111 E 80TH AV ANCHORAGE AK 99518 ANCHORAGE AK 99518 ARMAND SPIELMAN ~ HALLIBURTON ENERGY SERV 651 HILANDER CIRCLE MARK WEDMAN ANCHORAGE AK 99518 6900 ARCTIC BLVD ANCHORAGE AK 99518-2146 OPSTAD & ASSOC - JACK O HAKKILA ERIK A OPSTAD PROF GEOL P O BOX 190083 P O BOX 190754 ANCHORAGE AK 99519-0083 ANCHORAGE AK 99519 ENSTAR NATURAL GAS CO MARATHON OIL CO RICHARD F BARNES PRES OPERATIONS SUPT P O BOX 190288 P O BOX 196168 ANCHORAGE AK 99519-0288 ANCHORAGE AK 99519-6168 MARATHON OIL CO UNOCAL BRAD PENN P O BOX 196247 P O BOX 196168 ANCHORAGE AK 99519-6247 ANCHORAGE AK 99519-6168 UNOCAL _ EXXON COMPANY USA KEVIN TABLER MARK P EVANS P O BOX 196247 PO BOX 196601 ANCHORAGE AK 99519-6247 ANCHORAGE AK 99519-6601 BP EXPLORATION (ALASKA) INC MR. DAVIS, ESQ P O BOX. 196612 MB 13-5 ANCHORAGE AK 99519-6612 BP EXPLORATION (ALASKA) INC INFO RESOURCE CTR MB 3-2 P O BOX 196612 ANCHORAGE AK 99519-6612 BP EXPLORATION (ALASKA) INC SUE MILLER P O BOX 196612 M/S LR2-3 ANCHORAGE AK 99519-6612 AMERICA/CANADIAN STRATIGRPH CO RON BROCKWAY P O BOX 242781 ANCHORAGE AK 99524-2781 L G POST O&G LAND MGMT CONSULT 10510 CONSTITUTION CIRCLE EAGLE RIVER AK 99577 • BP EXPLORATION (ALASKA) INC BOB WILKS MB 5-3 P O BOX 196612 ANCHORAGE AK 99519-6612 BP EXPLORATION (ALASKA) INC PETE ZSELECZKY LAND MGR P O BOX 196612 ANCHORAGE AK 99519-6612 BP EXPLORATION (ALASKA), INC. MARK BERLINGER MB 8-1 PO BOX 196612 ANCHORAGE AK 99519-6612 AMSI/VALLEE CO INC WILLIAM O VALLEE PRES PO BOX 243086 ANCHORAGE AK 99524-3086 DIANA FLECK 18112 MEADOW CRK DR EAGLE RIVER AK 99577 ~ . D A PLATT & ASSOC PINNACLE 9852 LITTLE DIOMEDE CIR STEVE TYLER EAGLE RIVER AK 99577 20231 REVERE CIRCLE EAGLE RIVER AK 99577 DEPT OF NATURAL RESOURCES COOK INLET VIGIL DGGS JAMES RODERICK JOHN REEDER P O BOX 916 P O BOX 772805 HOMER AK 99603 EAGLE RIVER AK 99577-2805 COOK INLET KEEPER RON DOLCHOK BOB SHAVELSON P O BOX 83 PO BOX 3269 KENAI AK 99611 HOMER AK 99603 DOCUMENT SERVICE CO PHILLIPS PETR JOHN PARKER ALASKA OPERATIONS MANAGER P O BOX 1137 J W KONST KENAI AK 99611 P O DRAWER 66 KENAI AK 99611 KENAI PENINSULA BOROUGH PENNY VADLA ECONOMIC DEVEL DISTR P O BOX 467 STAN STEADMAN NINILCHIK AK 99639 P O BOX 3029 KENAI AK 99611-3029 • • BELOWICH COAL CONSULTING JAMES GIBBS MICHAEL A BELOWICH P O BOX 1597 HC31 BOX 5157 SOLDOTNA AK 99669 WASILLA AK 99654 PACE KENAI NATL WILDLIFE REFUGE SHEILA DICKSON REFUGE MGR P O BOX 2018 P O BOX 2139 SOLDOTNA AK 99669 SOLDOTNA AK 99669-2139 ALYESKA PIPELINE SERVICE CO VALDEZ PIONEER VALDEZ CORP AFFAIRS P O BOX 367 SANDY MCCLINTOCK VALDEZ AK 99686 P 0 BOX 300 MS/701 VALDEZ AK 99686 VALDEZ VANGUARD UNIV OF ALASKA FAIRBANKS EDITOR PETR DEVEL LAB P 0 BOX 98 DR V A KAMATH VALDEZ AK 99686-0098 427 DUCKERING FAIRBANKS AK 99701 NICK STEPOVICH RICK WAGNER 543 2ND AVE P O BOX 60868 FAIRBANKS AK 99701 FAIRBANKS AK 99706 .' JACK HAKKILA P O BOX 61604 FAIRBANKS AK 99706-1604 FAIRBANKS DAILY NEWS-MINER KATE RIPLEY P O BOX 70710 FAIRBANKS AK 99707 DEPT OF NATURAL RESOURCES DIV OF LAND REG MGR NORTHERN REGION 3700 AIRPORT WAY FAIRBANKS AK 99709-4699 ASRC BILL THOMAS P O BOX 129 BARROW AK 99723 UNIV OF ALASKA FBX PETR DEVEL LAB SHIRISH PATIL 437 DICKERING FAIRBANKS AK 99775 C BURGLIN P O BOX 131 FAIRBANKS AK 99707 FRED PRATT P O BOX 72981 FAIRBANKS AK 99707-2981 K&K RECYCL INC P O BOX 58055 FAIRBANKS AK 99711 RICHARD FINEBERG P O BOX 416 ESTER AK 99725 UNIVERSITY OF ALASKA FBKS PETR DEVEL LAB DR AKANNI LAWAL P O BOX 755880 FAIRBANKS AK 99775-5880 SENATOR LOREN LEMAN DEPT OF ENVIRON CONSERV SPAR STATE CAPITOL RM 113 CHRIS PACE JUNEAU AK 99801-1182 410 WILLOUGHBY AV STE 105 JUNEAU AK 99801-1795 SNEA (P ) DISTR FRANCE/EUROPE TOUR ELF CEDEX 45 992078 PARIS LA DEFE DU SUD/AMERIQUE FRANCE Affidavit Ad # Run Dates ED Po # 120479 07/16/99 DN 02014004 STATE OF ALASKA of Publication Price per Account d~ $93.75 STOF0330 STOF0330 $93.75 THIRD JUDICIAL DISTRICT Eva Kaufmann, being first duly sworn on oath deposes and says that she is an advertising representative of the Anchorage Daily News, a daily newspaper. That said newspaper has been approved by the Third Judicial Court, Anchorage, Alaska, and it now and has been published in the English language continually as a daily newspaper in Anchorage, Alaska, and it is now and during all said time. was printed in an office maintained at the aforesaid place of publication of said newspaper. That the annexed is a copy of an advertisement as it was published in regular issues (and not in supplemental form) of said newspaper on the above dates and that such newspaper was regularly distributed- to its subscribers during all of said period. That the full amount of the fee charged for the foregoing publication is not in excess of the rate charged private individuals. Legal Clerk~~-~~ _ _ 1'~ Subscribed and sworn to me be this date: ---7~-~0>1 ~4g-- Notary Public in and for the State of Alaska. Third Division. Anchorage, Alaska MY COMMISSION EXPIRES: ~/ ~ a9Jc~ `~`~`~~~Yr 1 ~~~ ~r~f ~ ~ ~ . 6-'. -. 1J11f~~#!J 1l )111>>>1 S4RPlEMENTAL NaticP of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: Pioneer Unii Disposal Infection Order Ocean Energy Resources, Inc. by letter-dated June 28, 7999, gas. requested an order allowing The d15PO5al of Clasa H fluids in the Pio- neer U.nitTn tfie Matanus- ka-Susffttp-ValfeY in South- ceniral Alaska. The requested order would allow disposal of oilfletd wastes in the Pioneer Unii 711702-15DA WDW well located in Section 15, Town- ship 17 North, Range ~2 West, Seward Meridian, A person who may be harmed if The requested order is issued maV file a written protest prior to 4:00 PM, August 2, 1999. wfig fife Alaska Oil and Gds Conner-: valion Commission, 3b01 Porcupine Orive, Anchor- age, Alaska 99501, and reque4f a hearing on this t1'latter. If a protest is ffinely filed a hearing on Qhe molter will beheltl at 'the above address at 9:00 AM on August TT, 1999, in Con#or~nance with 20 A:4C 2.540. If no protest is filed, the Commission will con- aiderthe issuance of the order without a hearing. Copies of the application for disposal inieGtion dre a+(bilable far iRSpectiMl at tge : AOGCC ~~Ofiicavai The above tlddress• T.ifis'notiCe suparsed#2~'the rrotice publFShetl - J WY..' 2, 1499. i+hat would hCrte pro- vid~ ~.an ! oppartuniTY for public gearing on AalgusT 3, 1494: The Piu9ust 3 date is withdrawn. If.XOU:are gperson with a disability who-.may need a special modification in' order fo commenT or tb attend the public hearing, pl¢~ase contact Diana Fleck of 793-1221 tiefbre August' 1 L 1994. /slRot>ert N: Cnrtstensary P.€.. Chairman . AO-O1~t114004 Pub.: 3WV T6, 1999 - DRI / MCGRAW HILL PIRA ENERGY GROUP RANDALL NOTTINGHAM LIBRARY 24 HARTWELL 3 PARK AVENUE (34TH & PARK) LEXINGTON MA 02173 NEW YORK NY 10016 OVERSEAS SHIPHOLDING GRP NY PUBLIC LIBRARY DIV E ECON DEPT GRAND CENTRAL STATION 1114 AV OF THE AMERICAS P 0 BOX 2221 NEW YORK NY 10036 NEW YORK NY 10163-2221 ALASKA OFC OF THE GOVERNOR OIL DAILY JOHN KATZ STE 518 CAMP WALSH 444 N CAPITOL NW 1401 NEW YORK AV NW STE 500 WASHINGTON DC 20001 WASHINGTON DC 20005 ARENT FOX KINTNER PLOTKIN KAHN US MIN MGMT SERV LIBRARY CHIEF OCS STATS & INFO WASHINGTON SQ BLDG 381 ELDEN ST MS 4022 1050 CONNECTICUT AV NW HERNDON VA 20170-4817 WASHINGTON DC 20036-5339 LIBRARY OF CONGRESS U S DEPT OF ENERGY STATE DOCUMENT SECTION PHYLLIS MARTIN MS E2823 EXCH & GIFT DIV 1000 INDEPENDENCE SW 10 FIRST ST SE WASHINGTON DC 20585 WASHINGTON DC 20540 ~r- * ~ TECHSYS CORP US GEOL SURV BRANDY KERNS LIBRARY PO BOX 8485 NATIONAL CTR MS 950 GATHERSBURG MD 20898 RESTON VA 22092 DPC SD DEPT OF ENV & NATRL RESOURCES DANIEL DONKEL OIL & GAS PROGRAM 1420 NORTH ATLANTIC AVE, STE 2.04 2050 W MAIN STE #1 DAYTON BEACH FL 32118 RAPID CITY SD 57702 AMOCO CORP 2002A ILLINOIS STATE GEOL SURV LIBRARY/INFO CTR LIBRARY P 0 BOX 87703 469 NATURAL RESOURCES BLDG CHICAGO IL 60680-0703 615 E PEABODY DR CHAMPAIGN IL 61820 LINDA HALL LIBRARY ALFRED JAMES III SERIALS DEPT 107 N MARKET STE 1000 5109 CHERRY ST WICHITA KS 67202-1811 KANSAS CITY MO 64110-2498 MURPHY E&P CO UNIV OF ARKANSAS ROBERT F SAWYER SERIALS DEPT P O BOX 61780 UNIV LIBRARIES NEW ORLEANS LA 70161 FAYETTEVILLE AR 72701 CROSS TIMBERS OPERATIONS DWIGHTS ENERGYDATA INC SUSAN LILLY JERLENE A BRIGHT DIRECTOR 210 PARK AVE STE 2350 PO BOX 26304 OKLAHOMA CITY OK 73102-5605 OKLAHOMA CITY OK 73126 IOGCC R E MCMILLEN CONSULT GEOL P 0 BOX 53127 202 E 16TH ST OKLAHOMA CITY OK 73152-3127 OWASSO OK 74055-4905 OIL & GAS JOURNAL CH2M HILL LAURA BELL J DANIEL ARTHUR PE PROJ MGR P O BOX 1260 502 S MAIN 4TH FLR TULSA OK 74101 TULSA OK 74103-4425 BAPI RAJU MARK S MALINOWSKY 335 PINYON LN 15973 VALLEY VW COPPELL TX 75019 FORNEY TX 75126-5852 US DEPT OF ENERGY DEGOLYER & MACNAUGHTON ENERGY INFORMATION ADMINISTRATION MIDCONTINENT DIVISION MIR YOUSUFUDDIN ONE ENERGY SQ, STE 400 1999 BRYAN STREET STE 1110 4925 GREENVILLE AVE DALLAS TX 75201-6801 DALLAS TX 75206-4083 MOBIL OIL CORP GAFFNEY, CLINE & ASSOC., INC. MORRIS GRIM ENERGY ADVISORS P O BOX 290 MARGARET ALLEN DALLAS TX 75221 16775 ADDISON RD, STE 400 DALLAS TX 75248 GCA ENERGY ADV MOBIL OIL RICHARD N FLETCHER JAMES YOREK 16775 ADDISON RD STE 400 P 0 BOX 650232 DALLAS TX 75248 DALLAS TX 75265-0232 JERRY SCHMIDT STANDARD AMERICAN OIL CO 4010 SILVERWOOD DR AL GRIFFITH TYLER TX 75701-9339 P 0 BOX 370 GRANBURY TX 76048 CROSS TIMBERS OIL COMPANY PRITCHARD & ABBOTT MARY JONES BOYCE B BOLTON PE RPA 810 HOUSTON ST STE 2000 4521 S. HULEN STE 100 FORT WORTH TX 76102-6298 FT WORTH TX 76109-4948 SHELL WESTERN E&P INC ENERGY GRAPHICS K M ETZEL MARTY LINGNER P O BOX 576 1600 SMITH ST, STE 4900 HOUSTON TX 77001-0574 HOUSTON TX 77002 H J GRUY PURVIN & GERTZ INC ATTN: ROBERT RASOR LIBRARY 1200 SMITH STREET STE 3040 2150 TEXAS COMMERCE TWR HOUSTON TX 77002 600 TRAVIS ST HOUSTON TX 77002-2979 RAY TYSON 1617 FANNIN ST APT 2015 HOUSTON TX 77002-7639 BONNER & MOORE LIBRARY H2O 2727 ALLEN PKWY STE 1200 HOUSTON TX 77019 PETRAL CONSULTING CO DANIEL L LIPPE 9800 RICHMOND STE 505 HOUSTON TX 77042 MARK ALEXANDER 7502 ALCOMITA HOUSTON TX 77083 CHEVRON PAUL WALKER 1301 MCKINNEY RM 1750 HOUSTON TX 77010 ~J OIL & GAS JOURNAL BOB WILLIAMS 1700 W LOOP SOUTH STE 1000 HOUSTON TX 77027 MOBIL OIL N H SMITH 12450 GREENSPOINT DR HOUSTON TX 77060-1991 MARATHON OIL CO GEORGE ROTHSCHILD JR RM 2537 P 0 BOX 4813 HOUSTON TX 77210 FOCAL EXXON EXPLOR CO REVENUE ACCOUNTING LAND/REGULATORY AFFAIRS RM 301 P 0 BOX 4531 P O BOX 4778 HOUSTON TX 77210-4531 HOUSTON TX 77210-4778 EXXON EXPLORATION CO. CHEVRON USA INC. T E ALFORD ALASKA DIVISION P 0 BOX 4778 ATTN: LORRY WOOLINGTON HOUSTON TX 77210-4778 P O BOX 1635 HOUSTON TX 77251 PETR INFO PHILLIPS PETR CO DAVID PHILLIPS ALASKA LAND MGR P 0 BOX 1702 P O BOX 1967 HOUSTON TX 77251-1702 HOUSTON TX 77251-1967 PHILLIPS PETROLEUM COMPANY WORLD OIL W ALLEN HUCKABAY MARK TEEL ENGR ED PO BOX 1967 P O BOX 2608 HOUSTON TX 77251-1967 HOUSTON TX 77252 EXXON CO USA EXXON CO USA RESERVES COORD RM 1967 J W KIKER ROOM 2086 P O BOX 2180 P O BOX 2180 HOUSTON TX 77252-2180 HOUSTON TX 77252-2180 EXXON CO USA GARY M ROBERTS RM 3039 P O BOX 2180 HOUSTON TX 77252-2180 PENNZOIL E&P WILL D MCCROCKLIN P 0 BOX 2967 HOUSTON TX 77252-2967 MARATHON MS. NORMA L. CALVERT P O BOX 3128, STE 3915 HOUSTON TX 77253-3128 PHILLIPS PETR CO ERICH R. RAMP 6330 W LOOP SOUTH BELLAIRE TX 77401 PHILLIPS PETR CO PARTNERSHIP OPRNS JERRY MERONEK 6330 W LOOP S RM 1132 BELLAIRE TX 77401 EXXON CO USA M W ALBERS RM 1943 P O BOX 2180 HOUSTON TX 77252-2180 CHEVRON CHEM CO LIBRARY & INFO CTR P O BOX 2100 HOUSTON TX 77252-9987 ACE PETROLEUM COMPANY ANDREW C CLIFFORD PO BOX 79593 HOUSTON TX 77279-9593 PHILLIPS PETR CO JOE VOELKER 6330 W LP S RM 492 BELLAIRE TX 77401 TEXACO INC R EWING CLEMONS P O BOX 430 BELLAIRE TX 77402-0430 • WATTY STRICKLAND TESORO PETR CORP 2803 SANCTUARY CV LOIS DOWNS KATY TX 77450-8510 8700 TESORO DR SAN ANTONIO TX 78217 INTL OIL SCOUTS ROBERT G GRAVELY MASON MAP SERV INC 7681 S KIT CARSON DR P O BOX 338 LITTLETON CO 80122 AUSTIN TX 78767 DIANE SUCHOMEL GEORGE G NAUGHT JR 10507D W MAPLEWOOD DR P O BOX 13557 LITTLETON CO 80127 DENVER CO 80201 AMOCO PROD CO C & R INDUSTRIES, INC. LIBRARY RM 1770 KURT SALTSGAVER JILL MALLY 1801 BROADWAY STE 1205 1670 BROADWAY DENVER CO 80202 DENVER CO 80202 JERRY HODGDEN GEOL NRG ASSOC 408 18TH ST RICHARD NEHRING GOLDEN CO 80401 P 0 BOX 1655 COLORADO SPRINGS CO 80901-1655 ~ i RUBICON PETROLEUM, LLC JOHN A LEVORSEN BRUCE I CLARDY 200 N 3RD ST #1202 SIX PINE ROAD BOISE ID 83702 COLORADO SPRINGS CO 80906 RUI ANALYTICAL TAHOMA RESOURCES JERRY BERGOSH GARY PLAYER P O BOX 58861 1671 WEST 546 S SALT LAKE CITY UT 84158-0861 CEDER CITY UT 84720 HUNGER OIL INFOR SERV INC P O BOX 45738 LOS ANGELES CA 90045-0738 US OIL & REFINERY CO TOM TREICHEL 2121 ROSECRANS AVE #2360 ES SEGUNCO CA 90245-4709 ANTONIO MADRID P O BOX 94625 PASADENA CA 91109 LA PUBLIC LIBRARY SERIALS DIV 630 W 5TH ST LOS ANGELES CA 90071 BABSON & SHEPPARD JOHN F BERGQUIST P O BOX 8279 VIKING STN LONG BEACH CA 90808-0279 ORO NEGRO, INC. 9321 MELVIN AVE NORTHRIDGE CA 91324-2410 • s PACIFIC WEST OIL DATA 76 PRODUCTS COMPANY ROBERT E COLEBERD CHARLES BURRUSS RM 11-767 15314 DEVONSHIRE ST STE D 555 ANTON MISSION HILLS CA 91345-2746 COSTA MESA CA 92626 SANTA FE ENERGY RESOURCES INC TEXACO INC EXPLOR DEPT PORTFOLIO TEAM MANAGER 5201 TRUXTUN AV STE 100 R W HILL BAKERSFIELD CA 93309 P O BOX 5197X BAKERSFIELD CA 93388 US GEOL SURV SHIELDS LIBRARY KEN BIRD GOVT DOGS DEPT 345 MIDDLEFIELD RD MS 999 UNIV OF CALIF MENLO PARK CA 94025 DAVIS CA 95616 H L WANGENHEIM ECONOMIC INSIGHT INC 5430 SAWMILL RD SP 11 SAM VAN VACTOR PARADISE CA 95969-5969 P O BOX 683 PORTLAND OR 97207 US EPA REGION 10 MARPLES BUSINESS NEWSLETTER LAURIE MANN OW-130 MICHAEL J PARKS 1200 SIXTH AVE 117 W MERCER ST STE 200 SEATTLE WA 98101 SEATTLE WA 98119-3960 PATTI SAUNDERS DUSTY RHODES 1233 W 11TH AV 229 WHITNEY RD ANCHORAGE AK 99501 ANCHORAGE AK 99501 DEPT OF REVENUE DEPT OF REVENUE BEVERLY MARQUART OIL & GAS AUDIT 550 W 7TH AV STE 570 DENISE HAWES ANCHORAGE AK 99501 550 W 7TH AV STE 570 ANCHORAGE AK 99501 FAIRWEATHER E&P SERV INC GUESS & RUDD JESSE MOHRBACHER GEORGE LYLE 715 L ST #4 510 L ST, STE 700 ANCHORAGE AK 99501 ANCHORAGE AK 99501 STATE PIPELINE OFFICE TRUSTEES FOR ALASKA LIBRARY 725 CHRISTENSEN DR STE 4 KATE MUNSON ANCHORAGE AK 99501 411 W 4TH AVE, STE 2 ANCHORAGE AK 99501 FORCENERGY INC. YUKON PACIFIC CORP JIM ARLINGTON JOHN HORN VICE CHM 310 K STREET STE 700 1049 W 5TH AV ANCHORAGE AK 99501 ANCHORAGE AK 99501-1930 • PRESTON GATES ELLIS LLP ALASKA DEPT OF LAW LIBRARY ROBERT E MINTZ ASST ATTY GEN 420 L ST STE 400 1031 W 4TH AV STE 200 ANCHORAGE AK 99501-1937 ANCHORAGE AK 99501-1994 GAFO DEPT OF NATURAL RESOURCES GREENPEACE DIV OF OIL & GAS PAMELA MILLER TIM RYHERD 125 CHRISTENSEN DR. #2 550 W 7TH AVE STE 800 ANCHORAGE AK 99501-2101 ANCHORAGE AK 99501-3510 DEPT OF REVENUE BAKER OIL TOOLS OIL & GAS AUDIT ALASKA AREA MGR FRANK PARR 4710 BUS PK BLVD STE 36 550 W 7TH AVE STE 570 ANCHORAGE AK 99503 ANCHORAGE AK 99501-3540 HDR ALASKA INC KOREAN CONSULATE MARK DALTON OCK JOO KIM CONSUL 2525 C ST STE 305 101 BENSON STE 304 ANCHORAGE AK 99503 ANCHORAGE AK 99503 N-I TUBULARS INC ANADARKO 3301 C STREET STE 209 MARK HANLEY ANCHORAGE AK 99503 3201 C STREET STE 603 ANCHORAGE AK 99503 ALASKA OIL & GAS ASSOC JUDY BRADY 121 W FIREWEED LN STE 207 ANCHORAGE AK 99503-2035 AK JOURNAL OF COMMERCE OIL & INDUSTRY NEWS ROSE RAGSDALE 4220 B STREET STE #210 ANCHORAGE AK 99503-5911 DEPT OF NATURAL RESOURCES DIV OF OIL & GAS BRUCE WEBB 3601 C ST STE 1380 ANCHORAGE AK 99503-5948 DEPT OF NATURAL RESOURCES DIV OF OIL & GAS JULIE HOULE 3601 C ST STE 1380 ANCHORAGE AK 99503-5948 DEPT OF NATURAL RESOURCES PUBLIC INFORMATION CTR 3601 C STREET STE 200 ANCHORAGE AK 99503-5948 FINK ENVIRONMENTAL CONSULTING, INC. THOMAS FINK, PHD 6359 COLGATE DR. ANCHORAGE AK 99504-3305 DEPT OF NATURAL RESOURCES DIV OIL & GAS WILLIAM VAN DYKE 3601 C ST STE 1380 ANCHORAGE AK 99503-5948 DEPT OF NATURAL RESOURCES DIV OF OIL & GAS JAMES B HAYNES NATURAL RESRCE MGR 3601 C ST STE 1380 ANCHORAGE AK 99503-5948 DEPT OF NATURAL RESOURCES DIV OF OIL & GAS JIM STOUFFER 3601 C STREET STE 1380 ANCHORAGE AK 99503-5948 ARLEN EHM GEOL CONSLTNT 2420 FOXHALL DR ANCHORAGE AK 99504-3342 • JAMES E EASON RUSSELL DOUGLASS 8611 LEEPER CIRCLE 6750 TESHLAR DR ANCHORAGE AK 99504-4209 ANCHORAGE AK 99507 STU HIRSH US BUREAU OF LAND MNGMNT 9630 BASHER DR. ANCHORAGE DIST OFC ANCHORAGE AK 99507 DICK FOLAND 6881 ABBOTT LOOP RD ANCHORAGE AK 99507 US BLM AK DIST OFC THOMAS R MARSHALL JR RESOURCE EVAL GRP 1569 BIRCHWOOD ST ART BONET ANCHORAGE AK 99508 6881 ABBOTT LOOP RD ANCHORAGE AK 99507-2899 LASS ARIEY UNIVERSITY OF ALASKA ANCHORAGE 3108 WENTWORTH ST INST OF SOCIAL & ECON RESEARCH ANCHORAGE AK 99508 TERESA HULL 3211 PROVIDENCE DR ANCHORAGE AK 99508 TRADING BAY ENERGY CORP US MIN MGMT SERV PAUL CRAIG RICHARD PRENTKI 5432 NORTHERN LIGHTS BLVD 949 E 36TH AV ANCHORAGE AK 99508 ANCHORAGE AK 99508-4302 • US MIN MGMT SERV US MIN MGMT SERV AK OCS REGIONAL DIR RESOURCE STUDIES AK OCS REGN 949 E 36TH AV RM 110 KIRK W SHERWOOD ANCHORAGE AK 99508-4302 949 E 36TH AV RM 603 ANCHORAGE AK 99508-4302 REGIONAL SUPRVISOR, FIELD OPERATNS US MIN MGMT SERV MINERALS MANAGEMENT SERVICE LIBRARY ALASKA OCS REGION 949 E 36TH AV RM 603 949 E 36TH AV STE 308 ANCHORAGE AK 99508-4363 ANCHORAGE AK 99508-4363 US MIN MGMT SERV US MIN MGMT SERV RESOURCE EVAL FRANK MILLER JIM SCHERR 949 E 36TH AV STE 603 949 E 36TH AV RM 603 ANCHORAGE AK 99508-4363 ANCHORAGE AK 99508-4363 JOHN MILLER USGS - ALASKA SECTION 3445 FORDHAM DR LIBRARY ANCHORAGE AK 99508-4555 4200 UNIVERSITY DR ANCHORAGE AK 99508-4667 CIRI ANCHORAGE TIMES LAND DEPT BERT TARRANT P 0 BOX 93330 P 0 BOX 100040 ANCHORAGE AK 99509-3330 ANCHORAGE AK 99510-0040 • , BRISTOL ENVIR SERVICES ARCO ALASKA INC JIM HUNTER JOANN GRUBER ATO 712 P 0 BOX 100320 P O BOX 100360 ANCHORAGE AK 99510-0320 ANCHORAGE AK 99510-0360 ARCO ALASKA INC ARCO ALASKA INC LEGAL DEPT - STEVE BENZLER ATO 1404 MARK P WORCESTER P O BOX 100360 P O BOX 100360 ANCHORAGE AK 99510-0360 ANCHORAGE AK 99510-0360 ARCO ALASKA INC ARCO ALASKA INC LIBRARY MARK MAJOR ATO 1968 P O BOX 100360 P O BOX 100360 ANCHORAGE AK 99510-0360 ANCHORAGE AK 99510-0360 ARCO ALASKA INC ARCO ALASKA INC LAND DEPT SAM DENNIS ATO 1388 JAMES WINEGARNER P 0 BOX 100360 P 0 BOX 10036 ANCHORAGE AK 99510-0360 ANCHORAGE AK 99510-0360 ARCO ALASKA INC PETROLEUM INFO CORP SHELIA ANDREWS ATO 1130 KRISTEN NELSON PO BOX 100360 P O BOX 102278 ANCHORAGE AK 99510-0360 ANCHORAGE AK 99510-2278 • ARCO ALASKA INC ALYESKA PIPELINE SERV CO KUP CENTRAL WELLS ST TSTNG PERRY A MARKLEY WELL ENG TECH NSK 69 1835 S BRAGAW - MS 575 P O BOX 196105 ANCHORAGE AK 99512 ANCHORAGE AK 99510-6105 ALYESKA PIPELINE SERV CO ALYESKA PIPELINE SERV CO CHUCK O'DONNELL LEGAL DEPT 1835 S BRAGAW - MS 5308 1835 S BRAGAW ANCHORAGE AK 99512 ANCHORAGE AK 99512-0099 US BUREAU OF LAND MGMT ANCHORAGE DAILY NEWS OIL & GAS OPRNS (984) EDITORIAL PG EDTR J A DYGAS MICHAEL CAREY 222 W 7TH AV #13 P O BOX 149001 ANCHORAGE AK 99513-7599 ANCHORAGE AK 99514 JWL ENGINEERING NORTHERN CONSULTING GROUP JEFF LIPSCOMB ROBERT BRITCH, P.E. 9921 MAIN TREE DR. 2454 TELEQUANA DR. ANCHORAGE AK 99516-6510 ANCHORAGE AK 99517 GERALD GANOPOLE CONSULT GEOL DAVID CUSATO 2536 ARLINGTON 600 W 76TH AV #508 ANCHORAGE AK 99517-1303 ANCHORAGE AK 99518 • ASRC SCHLUMBERGER CONRAD BAGNE DARREN AKLESTAD 301 ARCTIC SLOPE AV STE 300 1111 E 80TH AV ANCHORAGE AK 99518 ANCHORAGE AK 99518 ARMAND SPIELMAN HALLIBURTON ENERGY SERV 651 HILANDER CIRCLE MARK WEDMAN ANCHORAGE AK 99518 6900 ARCTIC BLVD ANCHORAGE AK 99518-2146 OPSTAD & ASSOC JACK O HAKKILA ERIK A OPSTAD PROF GEOL P O BOX 190083 P O BOX 190754 ANCHORAGE AK 99519-0083 ANCHORAGE AK 99519 ENSTAR NATURAL GAS CO MARATHON OIL CO RICHARD F BARNES PRES OPERATIONS SUPT P O BOX 190288 P O BOX 196168 ANCHORAGE AK 99519-0288 ANCHORAGE AK 99519-6168 MARATHON OIL CO UNOCAL BRAD PENN P O BOX 196247 P O BOX 196168 ANCHORAGE AK 99519-6247 ANCHORAGE AK 99519-6168 ~~ UNOCAL KEVIN TABLER P O BOX 196247 ANCHORAGE AK 99519-6247 BP EXPLORATION (ALASKA) INC MR. DAVIS, ESQ P O BOX 196612 MB 13-5 ANCHORAGE AK 99519-6612 BP EXPLORATION (ALASKA) INC INFO RESOURCE CTR MB 3-2 P 0 BOX 196612 ANCHORAGE AK 99519-6612 BP EXPLORATION (ALASKA) INC SUE MILLER P O BOX 196612 M/S LR2-3 ANCHORAGE AK 99519-6612 AMERICA/CANADIAN STRATIGRPH CO RON BROCKWAY P 0 BOX 242781 ANCHORAGE AK 99524-2781 5~ EXXON COMPANY USA MARK P EVANS PO BOX 196601 ANCHORAGE AK 99519-6601 BP EXPLORATION (ALASKA) INC BOB WILKS MB 5-3 P O BOX 196612 ANCHORAGE AK 99519-6612 BP EXPLORATION (ALASKA) INC PETE ZSELECZKY LAND MGR P O BOX 196612 ANCHORAGE AK 99519-6612 BP EXPLORATION (ALASKA), INC. MARK BERLINGER MB 8-1 PO BOX 196612 ANCHORAGE AK 99519-6612 AMSI/VALLEE CO INC WILLIAM O VALLEE PRES PO BOX 243086 ANCHORAGE AK 99524-3086 • L G POST O&G LAND MGMT CONSULT DIANA FLECK 10510 CONSTITUTION CIRCLE 18112 MEADOW CRK DR EAGLE RIVER AK 99577 EAGLE RIVER AK 99577 D A PLATT & ASSOC PINNACLE 9852 LITTLE DIOMEDE CIR STEVE TYLER EAGLE RIVER AK 99577 20231 REVERE CIRCLE EAGLE RIVER AK 99577 DEPT OF NATURAL RESOURCES COOK INLET VIGIL DGGS JAMES RODERICK JOHN REEDER P O BOX 916 P O BOX 772805 HOMER AK 99603 EAGLE RIVER AK 99577-2805 COOK INLET KEEPER RON DOLCHOK BOB SHAVELSON P 0 BOX 83 PO BOX 3269 KENAI AK 99611 HOMER AK 99603 DOCUMENT SERVICE CO PHILLIPS PETR JOHN PARKER ALASKA OPERATIONS P O BOX 1137 J W KONST KENAI AK 99611 P O DRAWER 66 KENAI AK 99611 MANAGER KENAI PENINSULA BOROUGH ECONOMIC DEVEL DISTR STAN STEADMAN P O BOX 3029 KENAI AK 99611-3029 BELOWICH COAL CONSULTING MICHAEL A BELOWICH HC31 BOX 5157 WASILLA AK 99654 PACE SHEILA DICKSON P O BOX 2018 SOLDOTNA AK 99669 ALYESKA PIPELINE SERVICE CO VALDEZ CORP AFFAIRS SANDY MCCLINTOCK P O BOX 300 MS/701 VALDEZ AK 99686 VALDEZ VANGUARD EDITOR P O BOX 98 VALDEZ AK 99686-0098 PENNY VADLA P O BOX 467 NINILCHIK AK 99639 JAMES GIBBS P O BOX 1597 SOLDOTNA AK 99669 KENAI NATL WILDLIFE REFUGE REFUGE MGR P 0 BOX 2139 SOLDOTNA AK 99669-2139 VALDEZ PIONEER P O BOX 367 VALDEZ AK 99686 UNIV OF ALASKA FAIRBANKS PETR DEVEL LAB DR V A KAMATH 427 DUCKERING FAIRBANKS AK 99701 • • NICK STEPOVICH RICK WAGNER 543 2ND AVE P O BOX 60868 FAIRBANKS AK 99701 FAIRBANKS AK 99706 JACK HAKKILA C BURGLIN P O BOX 61604 P O BOX 131 FAIRBANKS AK 99706-1604 FAIRBANKS AK 99707 FAIRBANKS DAILY NEWS-MINER FRED PRATT KATE RIPLEY P O BOX 72981 P 0 BOX 70710 FAIRBANKS AK 99707-2981 FAIRBANKS AK 99707 DEPT OF NATURAL RESOURCES K&K RECYCL INC DIV OF LAND P O BOX 58055 REG MGR NORTHERN REGION FAIRBANKS AK 99711 3700 AIRPORT WAY FAIRBANKS AK 99709-4699 ASRC RICHARD FINEBERG BILL THOMAS P O BOX 416 P O BOX 129 ESTER AK 99725 BARROW AK 99723 • ~ UNIV OF ALASKA FBX PETR DEVEL LAB SHIRISH PATIL 437 DICKERING FAIRBANKS AK 99775 SENATOR LOREN LEMAN STATE CAPITOL RM 113 JUNEAU AK 99801-1182 SNEA(P) DISTR FRANCE/EUROPE TOUR ELF CEDEX 45 992078 PARIS LA DEFE DU SUD/AMERIQUE FRANCE UNIVERSITY OF ALASKA FBKS PETR DEVEL LAB DR AKANNI LAWAL P O BOX 755880 FAIRBANKS AK 99775-5880 DEPT OF ENVIRON CONSERV CHRIS PACE 410 WILLOUGHBY AV STE JUNEAU AK 99801-1795 SPAR 105 Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: Pioneer Unit Disposal Injection Order Ocean Energy Resources, Inc. by letter dated June 28, 1999, has requested an order allowing the disposal of Class II fluids in the Pioneer Unit in the Matanuska- Susitna Valley in Southcentral Alaska. The requested order would allow disposal of oilfield wastes in the Pioneer Unit #1702-15DA WDW well located in Section 15, Township 17 North, Range 2 West, Seward Meridian. A person who may be harmed if the requested order is issued may file a written protest prior to 4:00 PM, July 19, 1999 with the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska 99501, and request a hearing on this matter. If the protest is timely filed and raises a substantial and material issue crucial to the Commission's determination, a hearing on the matter will beheld at the above address at 9:00 AM on August 3, 1999, in conformance with 20 AAC 25.540. If no protest is filed, the Commission will consider the issuance of the order without a hearing. If you re a person with a disability who may need a special modification in order to comment or to attend the public hearing, please contact Diana fleck at 793-1221 before July 28, 1999. . Robert N. Christenson, P.E. Chairman Published' July 2, 1999 ADN AO# 02014001 Affidavit Ad # Run Dates ED Po # of Publication Price per Account 110218 07/02/99 DN 02014001 $81.25 $81 .25 STATE OF ALASKA THIRD JUDICIAL DISTRICT Eva Kaufmann, being first duly sworn on oath deposes and says that she is an advertising representative of the Anchorage Daily News, a daily newspaper. That said newspaper has been approved by the Third Judicial Court, Anchorage, Alaska, and it now and has been published in the English language continually as a daily newspaper in Anchorage, Alaska, and it is now and during all said time was printed in an office maintained at the aforesaid place of publication of said newspaper. That the annexed is a copy of an advertisement as it was published in regular issues (and not in supplemental form) of said newspaper on the above dates and that such newspaper was regularly distributed to its subscribers during all of said period. That the full amount of the fee charged for the foregoing publication is not in excess of the rate charged private individuals. Legal Clerk~`_'~~~~ ~--' Subscribed and sworn to me befo is date: ~1~L~q Notary Public in and for the State of Alaska. Third Division. Anchorage, Alaska MY COMMISSION EXPIRES: ~a~a ~~ -~y4?-n Q ~P ``,~~`~~, fP;. CRO~~P~~ `' '~p-RY'~ ~' ~•.. ~; ~`. V . ~'~ r : PUBO- "~ J~1J111 )31,~ STOF0330 STOF0330 Nottceoi~ Public Hearing STATE OF ALASKA Alaska Oil aM Oqs - Conservation Commission j Re: Pioneer Unit Disposal lniection Qrder ~ Oc®an Energy Re3ources, Ittc. by letfer da}gd June . 29r 1999, hps r~qu~6tBd gn aRMeass~/ fludshn~heip~. Weer Unit in the Matapus- ka-Susitna Valley in SoutYi- cgntral_ Alaska.,.. Tbe. requested order would 'oliow distx+3al._.of, pd~9kl wdstes in the Pioneer Untt #1702-15DA WpW~.well located in Secitoh 15; Town- ShiP t7 North, r<`nnge_ 2 ,'~T, Seward Meridian. j A Gerson who mpg (~ harllied if .the reque~tep order is issued may file p written prot'la3t prior to a:00 PM, July 19,1999 with the Alaska Oil and Gas C,onser- VatFan +CpmmiSSi~re,-~ 3(1Q1 Porcupine Drive, Anchor- age, Alaska 99501, and. t'e9Uest a hearing on'ttiis r}Yatt~r. If the profes#- is ilmely fjled pnd raises a substantial and material issue crucial to the Corrl- rnis~tan's deterlni» `~~~ " ~~~ pe held qt the db3ve address at 9:00' AM °~ Ol1 August 3,i999,trr cpnform- ance with ?p AAC 25.540, if no protest is filed, -flip Com- mission wil! consider the ~8suance of the orderwfth- oui p hdafing. If you are a Uersan with a df3pb7tltr wfw mey new. o special madificatkln in order tp cornmegt ,QM" 'ta attentl the public heprklg, at ~9~12?tt befot'e Juh RB', 1999. /s/Roberi N. Chrlafensbri; P.E. Chairrrwn Ap-0?914007 ` ! Pi~b3r',(uly?,)999 ,~ ~3 t • AFFIDAVIT OF MAILING Pioneer Unit # 1702-15DA WDW Operator List ~v~~~ ~,. n/ ... ; # Ocean Energy Resources Inc., is the only operator with-in a'/a mile radius of the proposed well. Surface Owners See .Attached Table 1 On June 24,1999, the persons listed on tre attached ""Table 1"were notified by ce1-tifieJ mail of an application for disposal in the Pioneer Urut #1'102-1SDA. Si nod: ~ `°°~ C i Jate: June 24 1999 ~ - - ---- - Scctt M. Webb, Zegulatoly Coo~d.;nator State of Colorado Cot:rlty of Denser Signed and sworn before me this 24th day of June, 1999, ~~, Debl,~ J~,Dlack, Notary Public My Commission Expires: July 30, 2001 ~ ~~ ~. ~. r ~~,: a w° 4 ~ 4~ " *` a y( lbi~+t ~at`~ t t; ,. ~`.~~~1 ~~C~~,'t~ ('4t1 ~ ~,~~tt0'(`t~~~" Ocean Energy Resource, Inc. Amorn Building 1670 Broadway, Suite 2800 Denver, Colorado 80202 (303) 308-8500 Fax: (303) 308-8510 • a TABLE 1 Matthew V. Kiviaho 17006 Calle Del Flores Fountain Hills, AZ 85268 Surface Owners Paul, Wm A. & AJ Daniel 1/a Mile Radius 6034 SE Alderhill Lp Milwaukie, OR 97267 Douglas N. Hotes Thomas Grace 1800 W Hoteco Ave P.O. Box 61508 Anchorage, AK 99502 Vancouver, WA 98666 Dallas & Caren M. Smith John F. & Sara K. Wiber P.O. Box 671 P.O. Box 878804 Palmer, AK 99645 Wasilla, AK 99687 Jim Contreras Miguel Nazario-Acosta P.O. Box 672068 P.O. Box 875284 Chugiak, AK 99567 Wasilla, AK 99687 Ralph T. Berg Linda L. Medieros 3750 Grey Wolf Dr P.O. Box 872912 Wasilla, AK 99564 Wasilla, AK 99687 Mark A. & Sharon A. Jackson J. C. Page P.O. Box 878317 P.O. Box 872573 Wasilla, AK 99687 Wasilla, AK 99687 Robert B. Pace 3510 Evergreen St Anchorage, AK 99504 Craig A. & Shirley Thompson 3957 Pinyon St Springfield, OR 97478 Charles L. Mowrer P.O. Box 770647 Eagle River, AK 99577 Jake Marquez P.O. Box 874526 Wasilla, AK 99687 Joan I. Markle 3575 N. Brookside Ln Boise, ID 83703 ,~ ~ ~ ~ „~, _ ~ ~~ ,x ~,}i~1~~K l.:.,.. ~~,K • ~ SENDER: V y ^ Complete items t an or additional services. ry Complete items 3, 4a, 4b. ^ Print your name and address on the reverse of this form so that we can return this ~ card to you. ^ Attach this form to the front of the mailpiece, or on the back if space does not y permit. ^ Write "Return Receipt Requested' on the mailpiece below the article number. ~ ^ The Return Receipt will show to whom the article was delivered and the date ~ n delivered. '~ 3. Article Addressed to: 4a. Article Number '~ d~o7- 4~8/- ~~l a E 4b. Service Type Ralph T. Berg ^ Registered ertified ~ 3750 Grey Wolf Dr ^ Express Mail ^ Insured w ~ Wasilla AK 99564 , ^ Return Receipt for Merchandise ^ COD 0 a 7. Date of Delivery z ~ 5. Received By: (Print Name) 8. Addressee's Address (Only if requested and w fee is paid) c 6. Signature (Addressee or Agent) a PS Form 3811, December 1994 tozsss-se-a-o223 Domestic Return Receipt m SENDER: I also wish to receive the follow- .o 'w ^ Complete items tand/or 2 for additional services. ing services (for an extra fee): m Complete items 3, aa, and 4b. O Print your name and address on the reverse of this form so that we can return this 1 ' ~ card to you. s Address • ^ Addressee m ^ Attach this forth to the front of the mailpiece, or on the back if space does not 2• ^ Restricted Delivery ~, r permit. p Write "Return Receipt Requested" on the mailpiece below the article number. ~ ^ The Return Receipt will show to whom the artice was delivered and the date p delivered. '~ 3. Article Addressed to: 4a. Article Number r, ~"" 772 "' ~ ~ d t3 ~~ Z ~ Douglas N. Rotes 4b. Service Type ^ Registered ertified y 1800 W Hoteco Ave ^ Express Mail ^ Insured ~ Anchorage, AK 99SO2 ^ Return Receipt for Merchandise ^ COD C ~ 7. Date of Delivery a z ~ 5. Received By: (Print Name) 8. Addressee's Address (Only if requested and fee is paid) a 6. Signature (Addressee or Agent) a PS Form 3811, December 1994 102595-99-B-0223 Domestic Return Hecelpt d -- SENDER: I also wish to receive the follow- .o 'y ^ complete items t andlor 2 for additional services. ing services (for an extra fee): d Complete items 3, 4a, and 4b. ~ ^ Print your name and address on the reverse of this farm so that we can return this 1 ~ ^ Addressee's Address card to you. ^ Attach this form to the front of the mailpiece, or on the back if space does not 2• ^ Restricted Delivery ~, .c pem,it. ^ Write 'Aetum Receipt Aequested' on the mailpiece below the article number. ~ ^ The Return Receipt will show to whom the article was delivered and the date o delivered. 'a ~ a 3. Article Addressed to: 4a.Z icle'~u ~ ~ _ Z ~` ~ r _ ~ 73 7 r E Joan I. Markle 4b. Service Type 3575 N. Brookside Ln ^ Registered ^ Certified N Boise, ID 83703 ^ Express Mail ^ Insured w ^ Return Receipt for Merchandise ^ COD 0 7. Date of Delivery a z ~ 5. Received By: (Print Name) 8. Addressee's Address fee is paid) I also to receive the follow- ing s s (for an extra fee): 1 ^ Addressee's Address 2. ^ Restricted Delivery ai v .~ a`~ N a U a~ m m c N `o 0 T Y c m r ai `m ar G .~ U G7 tr c 3 rn c .N `o 0 T Y C A I- requested and ai d G .~ v m c d rn .N `o 0 a Y c m r t- ~ 6. Signature (Addressee or Agent) 0 N PS Form 3811, December 1994 102595-99-B-o223 Domestic Return Receipt SENDER: ^ Complete items 1 and/or 2 for additil~rvices I also wish to rec he follow- ing services (for ~ra fee): , Complete items 3, 4a, and 4b. ^ Print your name and address on the reverse of this form so that we can return this card to you.. 1. ^ Addressee's Address ^ Attach this form to the front of the mailpiece, or on the back if space does not i d D li t t 2 ^ R permit. r c e very es e • ^ Write 'Return Receipt Requested'on the mailpiece below the article number. ^ The Return Receipt will show to wham the article was delivered and the date delivered. to: Linda L. Medieros P.O. Box 872912 Wasilla, AK 99687 5 6. Signature (Addressee or 4a. Article Number /L 4b. Service Type ^ Registered ~rtified ^ Express Mail ^ Insured ^ Return Receipt for Merchandise ^ COD 7. Date of Delivery 8. Addressee's Address (Only if requested and fee is paid) d to Q .~ U Q c m c N 3 `o 0 a Y c m r PS Form 3811, December 1994 102595-99-8-0223 Domestic Return Receipt d .a SENDER: I also wish to receive the follow- ~v1 ^ Complete items 1 and/or 2 for additional services- ing S@rVIC@S (for an extra fee): H Complete items 3, 4a, and 4b. ^ Print your name and address on the reverse of this form so that we can return this ai ~ card to you. 1. ^ Addressee's Address d ^ Attach this form to the front of the mailpiece, or on the back if space does not ermit 2• ^ Restricted Delivery p . ^ W rite 'Return Receipt Requested' on the mailpiece below the article number. ~ D The Return Receipt will show to whom the artice was deli vered and the date a • p delivered. d v ~ 3. Article Addressed to: 4a. Article Number ~ - ~} 07 - ~ gI- 7g 7 ~ E Thomas Grace 4b. Service Type ~~ ~~ ,~', ~ P.O. Box 61508 ^ Registered L~'Certified ~ cn w Vancouver WA 98666 ^ Express Mail ^ Insured .N , ^ Return Receipt for Merchandise ^ COD , ~ a 7. Date of Delivery 3 z o T ~ 5. Received By: (Print Name) 8. Addressee's Address (Only if requested and ~ fee is paid) F 3 6. Signature (Addressee or Agent) 0 N PS Form 3811, December 1994 to2sss-ss-e-0223 Domestic Return Receipt d .~ SENDER: I also wish to recei}~ie follow- m ^ Complete items 1 and/or 2 for additio~ices. ing services (fora a fee): N, Complete items 3, 4a, and ab. ^ Print your name and address on the reverse of this form so that we can return this ai card to you. 1. ^ Addressee's Address ~ d ^ Attach this form to the front of the mailpiece, or on the back if space does not 2• ^ Restricted Delivery ermit ;? ~, t p . ^ Write 'Return Receipt Requested' on the mailpiece below the anicle number. ~ ^ The Return Receipi will show to whom the article was del ivered and the date a ~ o delivered. ~ U ~ 3. Article Addressed to: 4a. Article Number - efg/- 783 ~ Z o7 E Paul, Wm A. & AJ Daniel 4b. Service Type 6034 SE Alderhill l.p ^ Registered C9'Gertified ~ ~' Milwaukie, OR 97267 ^ Express Mail ^ Insured rn y w ~ ^ Return Receipt for Merchandise ^ COD ~ d a 7. Date of Delivery w = 0 a ~ 5. Received By: (Print Name) 8. Addressee's Address (Only if requested and c fee is paid) F ~ 6. Signature (Addressee or Agent) 0 a N PS Form 3811, December 1994 to25ss-ss-B-0223 Domestic Return Receipt a SENDER: I also wish to receive the follow- •w ^ Complete items 1 and/or 2 for additional services. ing S2rviC@S (for an extra fee): N Camplete items 3, 4a, and 4b. ^ Print your name and address on the reverse of this form so that we can return this ai ~ card to you. 1 ~ ^ Addressee's Address ° ... - m ^ Attach this form to the front of the mailpiece, or on the back if space does not 2. ^ Restricted Delivery ;t ;' ° perrn . ^ Write 'Return Receipt Requested' on the mailpiece below the anicle number. to ~ ^ The Return Receipt will show to whom the article was delivered and the date o- ° delivered. d U D 3. Article Addressed to: 4a. Article Number Z_~{o7-~81- 7~~ ° Q E o Jake Marquez 4b. Service Type ifi ^ R i d d ;, ~ ° eg stere ert e ~ w P.O. Box 874526 ^ Express Mail ^ Insured ~ ° . ~ Wasilla, AK 99687 ^ Return Receipt for Merchandise ^ COD 3 a 7. Date of Delivery ~ z ~ ° T ~ 5. Received By: (Print Name) 8. Addressee's Address (Only if requested and ¢ fee is paid) F ~ 6. Signature (Addressee or Agent) 0 T N PS Form 3811, December 1994 102595-99-B-0223 Domestic Return Receipt m~ ~ SENDER: I also wish to receive the follow- .y ^ Complete items 1 and/or 2 for additional services. ing S@NICBS (for an extra fee): H Complete items 3, 4a, and 4b. ^ Print your name and address on the reverse of this form so that we can return this ai card to you. 1. ^ Addressee's Address m ^ Attach this form to the front of the mailpiece, or on the back if space does not 2• ^ Restricted Delivery it m perm . ^ Write "Return Receipt Requested' on the mailpiece below the anicle number. ~ ~ ~ The Return Receipt will show to whom the article was delivered and the date °- ° delivered. ~ U ~ 3. Article Addressed to: 4a. Article Number -7 e d a E L 4b. Service Type 3 ;, v Robert B. Pace ^ Registered ertified ~ ~ 35.10 Evergreen St ^ Express Mail ^ Insured ~ w Anchorage, AK 99504- ^ Return Receipt for Merchandise ^ COD `o a 7. Date of Delivery ~ Z o ~ 5. Received By: (Print Name) 8. Addressee's Address (Only if requested and ¢ fee is paid) ~ ~ 6. Signature (Addressee or Agent) 0 a N PS Form 3811, December 1994 102595-99-B-0223 Domestic Return Receipt ~ w SENDER: ~ ^ Com lete items tand/or diti l ices I also wi~eceive the follow- In SefVl Or an extra fee): ` N p ona serv . Complete items 3, aa, and g ^ Print your name and address on the reverse of this farm so that we can return this ai card to you. 1. ^ Addressee's Address m ^ Attach this form to the front of the mailpiece, or on the back if space does not Z• ^ Restricted Delivery ermit n ~, p , ^ Write 'Return Aeceipt Requested' on the mailpiece below the article number. r c ^ The Return Receipt will show to whom the article was del ivered and the date a o delivered. m U -~ ~ 3. Article Addressed to: 4a. Article Number ~ f -7 g U ~ ~ d ~^~C~7 '7 ~~- ! c a o John F. & Sara K Wiber 4b. Service Type ~ N . P.O Box 878804 ^ Registered CKertified ~ m w . Wasilla AK 99687 ^ Express Mail ^ Insured ~ 'N I7C , ^ Return Receipt for Merchandise ^ COD ~ O a 7. Date of Delivery z ¢ o ~' r 5. Received By: (Pent Name) 8. Addressee's Address (Only if requested and c ~ fee is paid) ~ 6. Signature (Addressee orAgenf) 0 T N PS Farm 3811, December 1994 tozsss-ss-a-oz23 Domestic Return Receipt m .~ SENDER: I also wish to receive the follow- .N ^ Complete items tand/or 2 for additional services. ing S@fVIC2S (for an extra fee): w Complete items 3, 4a, and 4b. ^ Print your name and address on the reverse of this forth so that we can return this .: .... ai ;•-::.: ;'; ~ care to you. 1. ^ Addressee's Address ::. ... :: -- d ^ Attach this form to the front of the mailpiece, or on the back if space does not 2• ^ Restricted Delivery erms ~, L p . ^ Write "Rearm Receipt Requested' on the mailpiece below the article number. ~ ^ The Return Receipt will show to whom the artice was del ivered and the date n. • o delivered. ~ ~ m 3. Article Addressed to: 4a. Article Number --7~/ [~~ ~ _ ~~~_ o ° Mark A. 3z Sharon A. Jackson E 4b. Service Type P.O. Box 878317 ~~ ^ Registered Istienified ~ w Wasilla, AK 99687 ^ Express Mail ^ Insured er y ~ ^ Return Receipt far Merchandise ^ COD ` ~ a 7: Date of Delivery w 3 _ ~ ~ 5. Received By: (Print Name) 8. Addressee's Address (Only if requested and 0 T w fee is paid) r r ~ 6. Signature (Addressee or Agent) 0 N PS Form 3811, December 1994 tozsss-ss-e-ozzs Domestic Return Receipt d SENDER: I also wish to receive the follow- D .y ^ Complete items tand/or z for additional services. ing services (for an extra fee): y Complete items 3, 4a, and 4b. ^ Print your name and address on the reverse of this form so that we can return this card to you. 1 • ^ Addressee's Address ` ^ Attach this form to the front of the mailpiece, or on the back if space does not it z• ^ Restricted Delivery perm . ^ Write 'Return Receipt Requested' on the mailpiece below the article number. ~ ^ The Return Receipt will show to whom the article was delivered and the date o delivered. ~ 7. Date of Delivery a Z ~ 5. Received By: (Print Name) 8. Addressee's Address (Only if requested and w fee is paid) v 3. Article Addressed to: 4a. Article Number -z- cfto7~ fb'~ 78z o. a Jim Contreras 4b. Service Type ~.,~ ~ P.O. Fox 672068 ^ Registered Lsc:ertified w Chu~iak, AK 99567 ^ Express Mail ^ Insured 0 ^ Return Receipt for Merchandise ^ COD ~ 6. Signature (Addressee or Agent) 0 a - - PS Form 3811, December 1994 tozsss-ss-a-ozzs Domestic Return Receipt ai U .j d N a .~ U m a~ rn c .N 7 `o 3 0 a Y c m L r v 'y SENDER: ^ Complete items 1 and/or 2 f~onal services. I also wish~eive the follow- ing service an extra fee): m Complete items 3, 4a, and 4b. ^ Print your name and address on the reverse of this form so that we can return this ai ~ card to you. 1. ^ Addressee's Address m ^ Attach this form to the front of the mailpiece, or on the back it space does not ermit 2• ^ Restricted Delivery c, Y p . ^ Write "Return Receipt Requested' on the mailpiece below the article number. ~ ^ The Return Receipt will show to whom the artide was delivered and the date fl- • p delivered. ~ ~ m 3. Article Addressed to: 4a. Article Number ~j / ~ -~{0 7 - SDI - X77 m a 0 Miguel Nazat7o-Acosta 4b. Service Type ^ Registered L~1'tTertified ~ ~' in P.O. Box 875284 ^ Express Mail ^ Insured ~' Wasilla, AK 99687 ^ Return Receipt for Merchandise ^ COD Q 0 0 a 7. Date of Delivery i ~ 5. Received By: (Print Name) 8. Addressee's Address w fee is paid) c 6. Signature (Addressee or Agent) T N 0 ~+ requested and c ~a t F PS Farm 3811, December 1994 102595-99-8-0223 Domestic Return Recei d .o SENDER: I also wish to receive the follow- 'vr ^ Complete items 1 and/or 2 for additional services, ing SeNICeS (for an extra fee): N Complete items 3, 4a, and 4b. ^ Print your name and address on the reverse of this form so that we can return t his ai ~ card to you. 1. ^ Addressee's Address ~ d ^ Attach this form to the front of the mailpiece, or on the back if space does not 2• ^ Restricted Delivery ~, permit. N Y ^ Write 'Return Receipt Requested' on the mailpiece below the article number. c ^ The Return Receipt will show to whom the artide was delivered and the date O- p delivered. ~ ~ 3. Article Addressed to: 4a. Article Number ~ °' Z -- ~r n ~7 ~ ~ 7 ~ 7 tJ/ ~ / 78 c 4b. Service Type Craig A. & Shirley Thompson ^ Registered ~ertified ~ 3957 Pinyon St ^ Express Mail ^ Insured c ~ Springfield, OR 97478 ^ Return Receipt for Merchandise ^ COD ~ ` 7. Date of Delivery o ~ __ ` :.., o a 5. Received By: (Pont Name) 8. Addressee's Address (Only if requested and c w I fee is paid) F ~ 1 ~ 6. Signature (Addressee or Agent) 0 ~, N PS Form 3811, December 1994 to2sss-ss-a-o223 Domestic Return Receipt ~ 0 SENDER: I also wish to receive the foilow- rn ^ complete items 1 and/or 2 for additional services. ing services (for an extra fee): H Complete items 3, 4a, and 4b. ^ Print your name and address on the reverse of this form so that we can return this ai card to you. 1. ^ Addressee's Address °- ` ^ Attach this form to the front of the mailpiece, or on the back if space does not 2• ^ Restricted Delivery it ~, perm . ^ Write "Return Receipt Requested' on the mailpiece below the articl e number. in ~ ^ The Return Receipt will show to whom the artide was delivered and the date o- o delivered. m U ~ ~ 3. Article Addressed to: 4a. Article Number _Gfp~.- ~~/-77q ~ c E ~ J. C. Page 4b. Service Type ~ ^ R rtifi d i d 0 C ~ e e eg stere n P.O. Box 872573 ^ Express Mail ^ Insured °' c ~' Wasilla, AK 99687 ^ Return Receipt for Merchandise ^ COD o ~ ~ 7. Date of Delivery o ~ 0 T ~ 5. Received By: (Print Name) 8. Addressee's Address (Only if requested and n fee is paid) ~ 3 6. Signature (Addressee or Agent) 0 a N PS Form 3811, December 1994 102595-99-8-0223 Domestic Return Receipt d SENDER: v rd ^ Complete items 1 and/or 2 f oval services. N Complete items 3. 4a, and 4b. p Print your name and address on the reverse of this form so that we can return this j card to you. ~ ^ Attach this form to the front of the mailpiece, or on the back if space does not y permit. t ^ Write 'Aetum Receipt Requested' on the mailpiece below the article number. ~ ^-The Return Receipt will show to whom the article was delivered and the date ° delivered. PS Form 3811, December 1994 102595-99-8-0223 Domestic Return Receipt 2 ° a ~ 5. Received By: (Print Name) 8. Addressee's Address (Only if requested and c w fee is paid) r ~ 6. Signature (Addressee or Agent) a ~+ N N n. .~ U d 77~ c E ~ r 4b. Service Type ~, Dallas & Caren ./.. Sl;tith ^ Registered mortified ~ u P.O. Box 671 rn ^ Express Mail ^ Insured ~ u Palmer, AK 99645 ~; C ^ Return Receipt for Merchandise ^ COD C ~ 7. Date of Delivery a 3. Article Addressed to: 4a. Article Number d a SENDER: I also wish to receive the follow- 'N ^ complete items t anrl/or z for additional services. ing services (for an extra fee): H Complete items 3, 4a, and 4b. ^ Pdnt your name and address on the reverse of this form so that we can return this ai ~ card to you. 1. ^ Addressee's Address ^ Attach this form to the front of the mailpiece, or on the back if space does not it 2• ^ Restricted Delivery n ~, t perm . ^ Wnte 'Return Receipt Requested' on the mailpiece below the article number. r ~ ^ The Return Receipt will show to whom the artide was del ivered and the date ° delivered. d U '° ~ 3. Article Addressed to: 4a. Article N~lumber /~ r ~7 -7 Z ~ ~? ~ `C ~/ -/ t ~ ~ 2 a 7 3 E 4b. Service Type ~, ° ° Matthew V. Kiviaho ^ Registered C]t,ertified ~ ai 17006 Calle Del Flores ^ Express Mail ^ Insured ° ~ Fountain Hills, AZ 85268 ^ Return Receipt for Merchandise ^ COD Q D a 7. Date of Delivery w 3 Z - o a ~ 5. Received By: (Print Name) 8. Addressee's Address (Only if requested and w fee is paid) F ~ 6. Signature (Addressee or Agent) 0 N PS Form 3811, December 1994 102595-99-8-0223 Domestic Return Receipt ~ 7. Date of Del a r 5. Received By: (Print Name) 8. Addressee' w fee is paid) ~ 6. Signature (Addressee or Agent) 0 T ~ 3. Article Addressed to: 4a. Article Number ~ _~r~~-~fe~- 776 a E 4b. Service Type ~~~~ ~ Charles L. Mowrer ^ Registered L7C;ertified P.O. Box 770647 ^ Express Mail ^ Insured ~ Eagle River, AK 99577 ^ Return Receipt for Merchandise ^ COD ai SENDER: I also wish to receive the follow- .o w ^ Complete items 1 and/or 2 for additional services. ing S@NiC2S (for an extra fee): m Complete items 3, 4a, and 4b. ^ Print your name and address on the reverse of this form so that we can return this ~' card to you. 1 ~ ^ Addressee's Address ^ Attach this form to the front of the mailpiece, or on the back if space does not 2. ^ Restricted Delivery m L permit ^ Write 'Return Receipt Requested' on the mailpiece below the article number. c ^ The Return Receipt will show to whom the article was delivered and the date p delivered. I also wish~eive the follow- ing service n extra fee): a> .~ 1 • ^ Addressee's Address ° 2• ^ Restricted Delivery d (Only if requested ~ ,. U .~ a`~ rn a .~ v d d m c 'N `o 0 a Y c m L I- PS Form 3811, December 1994 to2sss-se-a-az23 Domestic Return y ,~ •i • • LETTER OF APPLICATION FOR AN UNDERGROUND INJECTION ORDER PIONEER PROJECT WELL # 1702-15DA WDW OCEAN ENERGY RESOURCES, INC. ~, ,. b ~;r~~ ~. ~~ :; ,~ ~ .. ~ ~~, ~~rS~s ~ ~~~~~~~'{~ pn~~,~~a~4 .e • • APPLICATION FOR AN UNDERGROUND INJECTION ORDER PIONEER PROJECT WELL # 1702- 15DA WDW (The attached application for aquifer exemption titled "PIONEER PROJECT, Request for Aquifer Exemption, Proposed Class II Waste Disposal, Well #1702 15AD WDW, Tyonek Formation, May 14 1999" be referenced as "the attached report" to minimize verbiage in this application.) 20 AAC 25.252. UNDERGROUND DISPOSAL OF WATER AND OTHER OIL FIELD WASTE FLUIDS AND UNDERGROUND STORAGE OF LIQUID HYDROCARBONS. 20 AAC 25.252 (c) (1) Figure 1 shows the location of the proposed disposal and production wells. Presently, no abandoned wells, production wells, dry holes, or any other wells that penetrate the injection zone exist within one-quarter mile of the proposed disposal or storage well. 20 AAC 25.252 (c) (2) No other operators exist within '/, mile of the proposed well. Table 1 is a list of surface owners within a 1/4 mile radius of the proposed disposal well. 20 AAC 25.252 (c) (3) Appendix "A" contains an affidavit and certified mail receipts showing that the operators and surface owners within a one-quarter mile radius have been provided a copy of the application for disposal or storage; 20 AAC 25.252 (c) (4) Appendix " 2" ("PIONEER PROJECT, Request for Aquifer Exemption, Proposed Class II Waste Disposal, Well #1702 15AD WDW, Tyonek Formation, May 14 1999") contains geologic information pertaining to this application. It has been used to apply for the fresh water exemption under regulation 20 AAC 25.400. It discusses the name, description, depth, and thickness of the formation into which fluids are to be injected and container appropriate geological data on the injection zone and confining zones, including lithologic description and geologic name. 20 AAC 25.252 (c) (5) As discussed in the introduction section of ("PIONEER PROJECT, Request for Aquifer Exemption, Proposed Class II Waste Disposal, Well #1702 15AD WDW, Tyonek Formation, May 14 1999"), logs will be provided to the state after the disposal well (#1702 15AD WDW) is drilled. 20 AAC 25.252 (c) (6) (1) A description of the casing of the disposal or storage wells, or the proposed casing program and the proposed method for testing casing before use of the disposal or storage wells; See Attachment 1 "Drilling Program". 20 AAC 25.252 (c) (7) The primary purpose of the disposal well is injection of produced formation water with total dissolved solids expected to range from 3000ppm to 25000ppm. The fluids will be very similar in composition to those of the injection zones (Figure 8 in Appendix " 2"). Maximum rates would be 2000 BWPD/well. Other fluids which may be injected in minor volumes include drilling and completion fluids, workover fluids, equipment washdown, and drilling mud slurries. • • • 20 AAC 25.252 (c) (8) The estimated average and maximum injection pressure will not exceed 900 psi surface pressure. 20 AAC 25.252 (c) (9) Evidence and data to support a commission finding that the proposed disposal or storage well will not initiate or propagate fractures through the confming zones which might enable the injection fluid or formation fluid to enter any freshwater strata; The maximum surface casing pressure will not exceed 900 PSI. Based on a fracture gradient of .7 and a hydraulic gradient of .433 and amid-perforation range of 3500', then: (.7 - .443) 3500 = 935 PSI 20 AAC 25.252 (cl (10 Actual analyses of the formation water from the potential injection zones is not available yet. However, produced Tyonek Formation water analyses from wells in the area and log analyses is included in Appendix " 2". Produced samples will be collected and analysed by a standard laboratory water analysis determination, or by an analytical method acceptable to the commission after drilling and completing the well. 20 AAC 25.252 (c) (11) Application for fresh water Exemption for the well location (in accordance with 20 AAC 25.440) was made on 5/14/99 and amended per EPA and AOGCC requests on 6/9/99, letter attached. 20 AAC 25.252 (d) (d) Mechanical integrity for disposal or storage wells drilled or converted to disposal or storage wells after the effective date of approval of the commission's program under 42 U.S.C. 300h-4 must be demonstrated according to 20 AAC 25.412 before operation. Mechanical integrity for all disposal or storage wells must be demonstrated by the operator by monitoring the pressure in the casing-tubing annulus during actual injection. The monitored annulus pressure must be reported monthly on the Monthly Injection Report (Form 10-406). Initial mechnical integrity tests will be performed in the following manner: Well will be pressured up to 1000 PSI for a minimum of 30 minutes. Monthly pressure monitoring of the injection wells will be reported on Form 10- 406. 20 AAC 25.252 (e) (e) If the casing-tubing annulus pressure subjects the casing to a hoop stress that exceeds 70 percent of the minimum yield strength of the casing, or if there is more than a 200 psi change in pressure between consecutive pressure readings, the commission must be immediately notified and commission-approved corrective action taken. Ocean Energy Resources will notify the AOGCC in the event that a 200 PSI change in pressure occurs. See Attachment "1" Drilling Program fo casing burst point and ratings. 20 AAC 25.252 (f) (f) The commission will, in its discretion, require additional mechanical integrity tests. 20 AAC 25.252 (g) (g) Modifications of existing or pending disposal or storage operations will be approved by the commission, in its discretion, under 20 AAC 25.507, upon application containing sufficient detail to evaluate the proposed modification. No modification will be approved unless the applicant proves to the commission that the modification will not allow the movement of fluids into sources of freshwater. `~ ~~", • i 20 AAC 25.252 (h) No wells within '/< mile will have penetrated potential injection zones at the time the well is drilled. However, the Pioneer wells #1702-15DD and 1702-14CC will be permitted and drilled'/o mile (40 acre offset) from the injector (Figure 1). The operator will provide a report on the mechanical conditions of the wells in the normal reporting proceedures of drilling and completing new wells. The anticipated well bore mechanics is depicted in the APD Attachment "1" Drilling Program. The well will be completed so as to prevent the movement of fluids into sources of freshwater (which are estimated to exist above 500' MD). 20 AAC 25.412. CASING, CEMENTING AND TUBING OF INJECTION WELLS FOR ENHANCED RECOVERY, DISPOSAL AND STORAGE. (a) Wells that inject fluids for enhanced recovery of oil or gas, for disposal ofnon-hazardous oil field waste fluids, or for storage of liquid hydrocarbons, must be cased with safe and appropriate casing and be tubed to prevent leakage, and must be cemented to protect oil, gas, and freshwater sources. (b) A new well drilled for the injection of fluids must be cased, cemented, and pressure tested in conformance with 20 AAC 25.030. (c) An existing well newly converted for injection of fluids may not be operated before pressure testing the casing immediately exterior to the injection tubing string. The casing must be tested at a surface pressure of 1,500 psig or 0.25 psi/ft multiplied by the true vertical depth of the casing shoe whichever is greater, but must not subject the casing to a hoop stress that will exceed 70 percent of the minimum yield strength of the casing. If the pressure declines more than 10 percent within 30 minutes, corrective measures must be taken until a satisfactory pressure test is achieved. (d) Fluid injection wells must be equipped with tubing and packer, or other equipment which isolates pressure to the injection interval. The minimum burst pressure of the tubing must exceed the maximum surface injection pressure by at least 25 percent. (e) Sufficient notice of pressure tests required by (c) must be given so that a representative of the commission may witness the test. (Eff. 4/2/86, Register 97) Authority: AS 31.05.030 ~, ~. ~~ -~ ' ) w~ . ' w ~ , ~`~y,~' ~,~C QC Pioneer Unit #17~15DA WDW Proposed Water Disposal Well NE SE Section 15-T17N-R2W Matanuska-Susitna Borough, AK GL: 265' C Well Detail/Casing Detail 1) Conductor: 13-3/8"/ 68# / K-55 /Welded @ 35' / 17-1/2" hole. Cemented with 35 sx. 2) Surface: 9-5/8" / 36# / J-55 / STC @ 700' / 12-1/4" hole. Cemented with 400 sx "G". 3) Production: 7" / 23# / WC-50 / LTC @ 4,100' / 8-3/4" hole. Cemented with 455 sx .,G,. 4) Tubing:2-7/8"/ 6.5# / J-55 / EUE 8rd @ 50' above top perfs. 5) Packer @ 50' above top perts. 6) Perforations Between 2,500' and 4,000' (estimated). 7) TD: 4,100' ,. .., ,. r „r,~ . , . .. ~ ....~ a.. ... •-----------------~-------------.; ~~, ~ 1~b I Narlwra ~. Niggan _ ],~ ,..,~,e f ~ ~ ~ .. 11 II.11 ~ ' -- - _ ,. ` - to ell ,, ~ j .., ~~ ~ ~ Locations " ~ 1/2 Mile -,a, . a,rrer 11 ~ M ~ Jaan,.Mar4ie '' #1702- 15WDW • - wen #102- Proposed Class II ' 15llA-WUW Alaxka,5Wleof,UNN @ Injection well ® _ ~ - - ~~_ ~> Jate Maryura. ~~ ~" ~ - - I Proposed CBM Test Wells ~, ~^^^ • Ala~4a. Stale o4 UNN I , ~UIID I .o ..i - , /~-- 23 i ~ .. -. _. } - _ .. l '~ Jury ,~. m UeLorah bl ~. P'ruxl Q 46 Water Wells from 125' to 1-°'~""- - ~ ~~ 305' deep in the SE 1/4 of ,., , 'i~' " bb Section 22 ~ y~ ~ ~~ 0 ! ~ ~~~ 0 _ - ~~ Q ~ ~.: ~~' I. 80 , ~ . ' Q 4 \\ ~ _ D. ~ ~~L:. ., I ~„ ~ ~ ~ 0 , , per, ~'~ - ~' 9.. ~ ~ ' ~ ~ ~'~! I ~ _ 1, ~/ ~ l b ~r - v ~. ~ ~24b~ ~ 0 Q D ~ ~ ~ ,. ~7 _ J ` - ~ Q W ~ O _0 .. ~ - r - - 0 ~,~ ~~ -- - _ --_ -„- -=~-. 1 - - - - 21 fi . Proposed Access Route • • - ,~.. ~~~, June 28, 1999 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Pioneer Unit ~ 1702- I SDA `VD~V Section IS-TI7N-R2W Matanuska-Susitna Borough Injection Disposal Application Dear Madam or Sir; Enclosed for the subject well is the application for in action for produced water disposal. 1 have included a copy of the request for an aquifer exemption with the application. If you have any questions cr need additional i,ifcrmaiieu, 1 can be reached in ?~enver at X03) X08-88 s. Thank you for your time in this nicer. Sincerely, ,~'°' ~ i° ~~/ , S;,ott }V1. t'lebb Fcegulatory Coordir.•ator ~,_ ~~ . ,h ~~;a ,, Alaska l;i~ Gas Cons. ~i3niCt~~:~~si, Anchorage Ocean Energy Resources, Inc. Amoco Building 1670 Broadway, Suite 2800 Denver, Colorado 50202 (303) 30&8500 Fax: (303) 308-8510 • • LETTER OF APPLICATION FOR AN UNDERGROUND INJECTION ORDER PIONEER PROJECT WELL # 1702- 15DA WDW OCEAN ENERGY RESOURCES, INC. >x,; ~..; } ` ~~ • APPLICATION FOR AN UNDERGROUND INJECTION ORDER PIONEER PROJECT WELL # 1702- 15DA WDW (The attached application for aquifer exemption titled "PIONEER PROJECT, Request for Aquifer Exemption, Proposed Class II Waste Disposal, Well #1702 15AD WDW, Tyonek Formation, May 14 1999" be referenced as "the attached report" to minimize verbiage in this application.) 20 AAC 25.252. UNDERGROUND DISPOSAL OF WATER AND OTHER OIL FIELD WASTE FLUIDS AND UNDERGROUND STORAGE OF LIQUID HYDROCARBONS. 20 AAC 25.252 (c) (1) Figure 1 shows the location of the proposed disposal and production wells. Presently, no abandoned wells, production wells, dry holes, or any other wells that penetrate the injection zone exist within one-quarter mile of the proposed disposal or storage well. 20 AAC 25.252 (c) (2) No other operators exist within'/< mile of the proposed well. Table 1 is a list of surface owners within a 1/4 mile radius of the proposed disposal well. 20 AAC 25.252 (c) (3) Appendix "A" contains an affidavit and certified mail receipts showing that the operators and surface owners within a one-quarter mile radius have been provided a copy of the application for disposal or storage; 20 AAC 25.252 (c) (4) Appendix " 2" ("PIONEER PROJECT, Request for Aquifer Exemption, Proposed Class II Waste Disposal, Well #1702 15AD WDW, Tyonek Formation, May 14 1999") contains geologic information pertaining to this application. It has been used to apply for the fresh water exemption under regulation 20 AAC 25.400. It discusses the name, description, depth, and thickness of the formation into which fluids are to be injected and container appropriate geological data on the injection zone and confining zones, including lithologic description and geologic name. 20 AAC 25.252 (c) (5) As discussed in the introduction section of ("PIONEER PROJECT, Request for Aquifer Exemption, Proposed Class II Waste Disposal, Well #1702 15AD WDW, Tyonek Formation, May 14 1999"), logs will be provided to the state after the disposal well (#1702 15AD WDW) is drilled. 20 AAC 25.252 (c) (6) (1) A description of the casing of the disposal or storage wells, or the proposed casing program and the proposed method for testing casing before use of the disposal or storage wells; See Attachment 1 "Drilling Program". 20 AAC 25.252 (c) (7) The primary purpose of the disposal well is injection of produced formation water with total dissolved solids expected to range from 3000ppm to 25000ppm. The fluids will be very similar in composition to those of the injection zones (Figure 8 in Appendix " 2"). Maximum rates would be 2000 BWPD/well. Other fluids which may be injected in minor volumes include drilling and completion fluids, workover fluids, equipment washdown, and drilling mud slurries. • • 20 AAC 25.252 (c) (8) The estimated average and maximum injection pressure will not exceed 900 psi surface pressure. 20 AAC 25.252 (c) (9) Evidence and data to support a commission finding that the proposed disposal or storage well will not initiate or propagate fractures through the confining zones which might enable the injection fluid or formation fluid to enter any freshwater strata; The maximum surface casing pressure will not exceed 900 PSI. Based on a fracture gradient of .7 and a hydraulic gradient of .433 and amid-perforation range of 3500', then: (.7 - .443) 3500 = 935 PSI 20 AAC 25.252 (c) (10) Actual analyses of the formation water from the potential injection zones is not available yet. However, produced Tyonek Formation water analyses from wells in the area and log analyses is included in Appendix " 2". Produced samples will be collected and analysed by a standard laboratory water analysis determination, or by an analytical method acceptable to the commission after drilling and completing the well. 20 AAC 25.252 (c) (11) Application for fresh water Exemption for the well location (in accordance with 20 AAC 25.440) was made on 5/14/99 and amended per EPA and AOGCC requests on 619/49, letter attached. 20 AAC 25.252 (d) (d) Mechanical integrity for disposal or storage wells drilled or converted to disposal or storage wells after the effective date of approval of the commission's program under 42 U.S.C. 300h-4 must be demonstrated according to 20 AAC 25.412 before operation. Mechanical integrity for all disposal or storage wells must be demonstrated by the operator by monitoring the pressure in the casing-tubing annulus during actual injection. The monitored annulus pressure must be reported monthly on the Monthly Injection Report (Form 10-406). Initial mechnical integrity tests will be performed in the following manner: "Well will be pressured up to 1000 PSI for a minimum of 30 minutes. Monthly pressure monitoring of the injection wells will be reported on Form 10- 406. 20 AAC 25.252 (e) (e) If the casing-tubing annulus pressure subjects the casing to a hoop stress that exceeds 70 percent of the minimum yield. strength of the casing, or if there is more than a 200 psi change in pressure between consecutive pressure readings, the commission must be immediately notified and commission-approved corrective action taken. Ocean Energy Resources will notify the AOGCC in the event that a 200 PSI change in pressure occurs. See Attachment "1" Drilling Program fo casing burst point and ratings. 20 AAC 25.252 (f) (f) The commission will, in its discretion, require additional mechanical integrity tests. 20 AAC 25.252 (g) (g) Modifications of existing or pending disposal or storage operations will be approved by the commission, in its discretion, under 20 AAC 25.507, upon application containing sufficient detail to evaluate the proposed modification. No modification will be approved unless the applicant proves to the commission that the modification will not allow the movement of fluids into sources of freshwater. • 20 AAC 25.252 (h) • No wells within '/< mile will have penetrated potential injection zones at the time the well is drilled. However, the Pioneer wells #1702-15DD and 1702-14CC will be permitted and drilled''/4 mile (40 acre offset) from the injector (Figure 1). The operator will provide a report on the mechanical conditions of the wells in the normal reporting proceedures of drilling and completing new wells. The anticipated well bore mechanics is depicted in the APD Attachment "1" Drilling Program. The well will be completed so as to prevent the movement of fluids into sources of freshwater (which are estimated to exist above 500' MD). 20 AAC 25.412. CASING, CEMENTING AND TUBING OF INJECTION WELLS FOR ENHANCED RECOVERY, DISPOSAL AND STORAGE. (a) Wells that inject fluids for enhanced recovery of oil or gas, for disposal of non-hazardous oil field waste fluids, or for storage. of liquid hydrocarbons, must be cased with safe and appropriate casing and be tubed to prevent leakage, and must be cemented to protect oil, gas, and freshwater sources. (b) A new well drilled for the injection of fluids must be cased, cemented, and pressure tested in conformance with 20 AAC 25.030. (c) An existing well newly converted for injection of fluids may not be operated before pressure testing. the casing immediately exterior to the injection tubing string. The casing must be tested at a surface pressure of 1,500 psig or 0.25 psi/ft multiplied by the true vertical depth of the casing shoe whichever is greater, but must not subject the casing to a hoop stress that will exceed 70 percent of the minimum yield strength of the casing. If the pressure declines more than 10 percent within 30 minutes, corrective measures must be taken until a satisfactory pressure test is achieved. (d) Fluid injection wells must be equipped with tubing and packer, or other equipment which isolates pressure to the injection interval. The minimum burst pressure of the tubing must exceed the maximum surface injection pressure by at least 25 percent. (e) Sufficient notice of pressure tests required by (c) must be given so that a representative of the commission may witness the test. (Eff. 4/2/86, Register 97) Authority: AS 31.05.030 • • f^l -, ~J ~ -~ r ~~ AFFIDAVIT OF MAILING Pioneer Unit # 1702-15DA WDW Operator List Ocean Energy Resources Inc., is the only operator with-in a '/4 mile radius of the proposed well. Surface Owners See Attached Table 1 On June 24, 1999, the persons listed on tre attached "Table 1"were notified by certified mail of an application for disposal in the Pioneer Unit #l 702-1.5DA. Si ned: -"-~ v~~ ~%~ = Date: June 24 1999 l; Scott M. Webb, Regulatory Coordinator State of Colorado County of Denver Signed and sworn before me this 24th day of June, 1999, ~, Deb J~ Tack, Notary Public My Commission Expires: July 30, 2001 ~: - -f r•?" ~$ =~ t1G ~'~ Ocean Energy Resources, InC. Amour Building 1670 Broadway, Suite 2800 Denver, Colorado 80202 (303) 308-8500 Fax: (303) 308-8510 • TABLE 1 Surface Owners 1/4 Mile Radius Thomas Grace P.O. Box 61508 Vancouver, WA 98666 John F. & Sara K. Wiber P.O. Box 878804 Wasilla, AK 99687 Miguel Nazazio-Acosta P.O. Box 875284 Wasilla, AK 99687 Linda L. Medieros P.O. Box 872912 Wasilla, AK 99687 J. C. Page P.O. Box 872573 Wasilla, AK 99687 Robert B. Pace 3510 Evergreen St Anchorage, AK 99504 Craig A. & Shirley Thompson 3957 Pinyon St Springfield, OR 97478 Chazles L. Mowrer P.O. Box 770647 Eagle River, AK 99577 Jake Mazquez P.O. Box 874526 Wasilla, AK 99687 Joan I. Mazkle 3575 N. Brookside Ln Boise, ID 83703 Matthew V. Kiviaho 17006 Calle Del Flores Fountain Hills, AZ 85268 Paul, Wm A. & AJ Daniel 6034 SE Alderhill Lp Milwaukie, OR 97267 Douglas N. Hotes 1800 W Hoteco Ave Anchorage, AK 99502 Dallas & Caren M. Smith P.O. Box 671 Palmer, AK 99645 Jim Contreras P.O. Box 672068 Chugiak, AK 99567 Ralph T. Berg 3750 Grey Wolf Dr Wasilla, AK 99564 Mark A. & Sharon A. Jackson P.O. Box 878317 Wasilla, AK 99687 SENDER: I also wish to receiv. the follow- N ^ Complete items tand/or 2 far additi~rvices. ing services (for a~a fee): y Complete items 3, aa, and ab. ^ Print your name and address on the reverse of this form so that we can return this ~ card to you. 1 ^ Addressee's Address ~ ^ Attach this form to the front of the mailpiece, or on the back if space does not ~, permit. 2• ^ Restricted Delivery ^ Write 'Return Receipt Requested' on the mailpiece below the article number. ~ ^ The Return Receipt will show to whom the article was delivered and the date a delivered. ~ 3. Article Addressed to: 4a. Article Number o /L /' Z ~ TD7- ~8/- 7~p . o U Linda L. Nledieros 4b. service Type ,,~,, ~~ ^ R i ' P.O. BOX 872912 eg stered I~ C:ertified ~ w Wasilla, AK 99687 ^ Express Mail ^ Insured ~ C ^ Return Receipt far Merchandise ^ COD a 7. Date of Delivery z ~ 5. Received By: (Print Name) 8. Addressee's Address (Only if requested and w lee is paid) 0 6. Signature (Addressee orAgenq a N ~._ PS Form 3811, December 1994 tazsss-ss-a-a2zs Domestic Return Receipt ai U .~ cn a .~ U c c~ c N `o 0 T Y c m L m -o SENDER: I also wish to receive the follow- - - 'N ^ Complete items tand/or 2 for additional services. ing services (for an extra fee): y Complete items 3, 4a, and ab. ^ Print your name and address on the reverse of'his form so that we can return this ai ~ card to you. 1 . ^ Addressee's Address " ~ ^ Attach this form to the front of the mailpiece, or on the back if space does not permit. '• ^ Restricted Delivery ;? ~, ^ Write 'Return Receipt Requested' on the mailpiece below the article number. rn ' The Return Receipt will show to whom the article was delivered and the date a ~ p delivered. v ~ 3. Article Addressed to: 4a. Article Number ~ Z- yon- CBI- 787 ,z E o ~ Thomas Grace 4b. Service Type ~/ , ~ u, P.O. Box 61508 ^ Registered L4'Gartified ~ w Vancouver, WA 98666 ^ Express Mail ^ Insured .N ^Return Receipt for Merchandise ^ COD ~ a 7. Date of Delivery 0 ¢ ~' ~ 5. Received By: (Print Name) 8. Addressee's Address (Only if requested and c w fee is paid) ~ r c 6. Signature (Addressee orAgenr) a y PS Form 3811, December 1994 102595-99-8-0223 Domestic Return Receipt `~~ ~ SENDER: I also wish to receive the follow- 'N m ~ ^ Complete items tand/or 2 for additio ices. Complete items 3, 4a, and ab. ing services (for ar~ fee): ^ Print your name and address on the re ,e of this form so that w e can return this ~ card to you. 1 ~ ^ Addressee's Address ~ ' v ^ Attach this lorm to the front of the mailpiece, or on the back if space does not ~ permit. 2• ^ Restricted Delivery m Y p Write 'Return Receipt Requested' on the mailpiece below the article number. u) ~ ^ The Return Receipt will show to whom the article was celivered and the date t1 a delivered. '~, ~ 3. Article Addressed to: 4a. Article Number -7 07- ~~~ /~3 Z c a ~ . 7 E Paul, Wm A. & AJ Daniel 4b. Service Type 6034 SE Alderhill i,p ^ Registered La'G~rtified ~ w Milwaukee, OR 97267 ^ Express Mail ^ Insured , ~ ~ ^ Return Receipt for Merchandise ^ COD N ~ a 7. Date of Delivery ~ z o T ~ 5. Received By: (Print Name) S. Addressee's Address (Only if requested and c fee is paid) r r ~ 6. Signature (Addressee or Agent) 0 a i w ~ PS Form 3811, December 1994 to2sss-ss-a-o2zs Domestic Return Receipt z a 7. Date of Delivery e d Q 3. Article Addressed to: , 4a. Article Number Z-~{o7- ~gl- 7~~ E o Jake Marquez ~ 4b. Service Type ^ Registered ertified ~ P.O. BOx 874526 ^ Express Mail ^ Insured w Wasilla, AK 99687 ^ Return Receipt for Merchandise ^ COD C ' ~• .~ SENDER: I also wish to receive the fotlow- 'uf ^ Complete items 1 and/or 2 for additional services. ing S@NICBS (for an eXtra fee): w Complete items 3, 4a, and ab. ^ Print your name and address on the reverse of this form so that we can return this card to you. 1 ~ ^ Addressee's Address m ^ Attach this form to the front of the mailpiece, or on the back if space does not ~, pem,it. 2- ^ Restricted Delivery - ^ Write 'Aetum Receipt Aequested' on the mailpiece below the article number. ~ ^ The Return Receipt will show to whom the article was celivered and the date o delivered ~~ 5. Received By: (Print Name) 8. Addressee's Address (Only if requested and w fee is paid) o 6. Signature (Addressee or Agent) T 71 - _ PS Form 3811, December 1994 102595-99-8-0223 Domestic Return U .; to a .~ U `m c N `o 0 T Y R SENDER: I also wish to receive the follow- ^ Complete items 1 and/or 2 for additional services. ing S8NIC8S (for an extra fee): Complete items 3, 4a, and 4b. ^ Print your name and address on the reverse of this form so that we can return this card to you. 1. ^ Addressee's Address ^ Attach this form to the front of the mailpiece, or on the back if space does not permit. 2• ^ Restricted Delivery ^ Write 'Return Receipt Aequested' an the mailpiece below the article number. ^ The Return Receipt will show to whom the article was delivered and the date delivered. 3. Article Addressed to: 4a. Article Number Z - ~0 7 - ~~~ ' 7 BS --_ -- 4b. Service Type Robert B. Pace ^ Registered ertified 3610 Evergreen St ^ Express Mail ^ Insured Anchorage, AK 99504_ ^ Return Receipt for Merchandise ^ COD 7. Date of Delivery 5. Received By: (Print Name) 8. Addressee's Address (Only if requested and fee is paid) 6. Signature (Addressee or Agent) PS Form 3811, December 1994 to2sss-ss-a-a223 Domestic Return Receipt ai N a .~ U m at c N `o 0 ~. s m F= SENDER: ^ Complete items 1 and/or ~ditional services I also wis receive the follow- in servi~r an extr f . Complete items 3. 4a, and g a ee): ^ Print your name and address on the reverse of this form so that we can return this ~ card to you. 1 • ^ Addressee's Address `-' ^ Attach this form to the front of the maitpiece, or on the back if space does not permit. z• ^ Restricted Delivery ~ n ^ Write -Return Receipt Requested' on the madpiece Celow the article number. c ^ The Return Receipt will show to whom the article was delivered a nd the date a delivered. '~ 3. Article Addressed to: 4a. Article Number ~ -~--~'o ~ -- y ~/- 78 ~ John F. & Sara K. Wiber ab. Service Type P.O. Box 878804 ^ Registered certified ~ Wasilla, AK 99687 ^ Express Mail ^ Insured m y `_ ^ Return Receipt for Merchandise ^ COD 7. Date of Delivery ~ - c ~. 5. Received By: (Print Name) 8. Addressee's Address (Only if requested and c fee is paid) L 6. Signature (Addressee or Agent) PS Form 3811, December 1994 10259s-99-B-0223 Domestic Return Receipt SENDER: .also wish to receive the follow- ~w ^ Complete items tand/or 2 for additional sernces. ing S@NiC@S (fof an extra feel: N Complete items 3, 4a, and 4b. ^ Print your name and address on the reverse of this form so that we can return this y ~ card to you. 1 ^ Addressee's Address `? d ^ Attach this form to the front of the mailpiece. or on the back if space does not permit. 2. ^ Restricted Delivery ~, ^ Write 'Rerom Receipt Requested' on the mailpiece below the article number ~ ~ ^ The Retum Receipt will show to whom the article was delivered and the date Q ' o delivered. y '~ 3. Article Addressed to: 4a. Article Number ~ ~ Mark A. do Sharon A. Jackson 4b. Service Type ~ P.O. BOX 878317 ^ Registered C'M'G rtified ~ w Wasilla, AK 99687 ^ Express Mail ^ Insured 0 ^ Retum Receipt for Merchandise ^ COD a 7. Date of Delivery 0 = tr 0 ~ 5. Received By: (Print Name) 8. Addressee's Address (Only if requested and c w fee is paid) m F- o 6. Signature (Addressee or Agent) T y PS Form 38l 1, December 1994 102595-99-8-0223 Domestic Return Recaipt m .o SENDER: I also wish to receive the follow- N O complete Gems 1 and/or 2 for additional services. ing services (for an extra fee): m Complete items 3, 4a, and ab. ^ Print your name and address on the reverse of this form so that we can retum this ~ card to you. 1. ^ Addressee's Address ~ ^ Attach this form to the front of the mailpiece, or on the back if space does not permit. 2• ^ Restricted Delivery ~, ^ Write "Retum Receipt Requested' on the mailpiece below the article number. C ^ The Retum Receipt will show to whom the artide was delivered and the date o delivered. 'D 3. Article Addressed to: 4a. Article Number a a Jin1 Contreras 4b. Service Type ~, P.O. BOX 672068 ^ Registered ~rtified f° Chu~iak, AK 99567 ^ Express Mail ^ Insured ^ Retum Receipt for Merchandise ^ COD ~ a 7. Date of Delivery !r F 5. Received By: (Print Name) 8. Addressee's Address (Only if requested and ~ fee is paid) ~ 6. Signature (Addressee or Agent) 0 a N ai m` fl. .~ U m m rn c ._ `o 0 T Y c L P5 Form 3811, December 1994 to2sss-ss-a-o223 Domestic Return Receipt SENDER: I also wish to eive the follow- ^ Complete items tand/or 2 fo~nal sernces. ing services ~n extra fee): Complete items 3, 4a, and 4b. ^ Print your name and address on the reverse of this form so that we can return this card to you. 1. ^ Addressee's Address O Attach this form to the Iront of the mailpiece, cr on the back if space does not 2 perma. . ^ Restricted Delivery ^ Write 'Return Receipt ReOUested'on the maJciece below the article number. ^ The Return Receipl will show to whom the article was delivered and the date delivered. 3. Article Addressed to: Nli~uel Nazario-Acosta P.O. Box 875284 Wasilla, AK 99687 4a. Article Numb-e7r ~/ ~j z -~0 / ~ YIJrI- 777 4b. 5ervlce I ype ^ Registered C~1'Cartified ^ Express Mail ^ Insured ^ Return Receipt for Merchandise ^ COD cJ Name) 6. Signature (Addressee or Agent) 7. Date of Delivery 8. Addressee's Address (Only ii requested and fee is paid) PS Form 3811, December 1994 tozsss-ss-a-ozz3 Domestic Return Receipt SENDER: ~m ^ Complete items 1 and/or 2 for additional services. N Complete items 3, Ja, and 4b. ^ Print your name and address on the reverse of this form so that we can return this ~ card to you. ~ ^ Attach this form to the front of the mailpiece. cr on the back if space does not y permit. ^ Wnte 'Return Receipt Requested' on the ma,lpiece below the article number. ~ ^ The Return Receipt will show to whom the artice was delivered and the date o delivered. ~ 3. Article Addressed to: 4a. Article Number Cram A. & Shirley Thompson 3957 Pinyon St Springfield, OR 97478 2. 5. Received By: (Print Name) F- w ~ 6. Signature (Addressee or Agent) 0 N n. .~ U m 7 7g 4b. Service hype ^ Registered ~ertified ;, ~ ^ Express Mail ^ Insured . ~ ^ Return Receipt for Merchandise ^ COD N 3 ` 7. Date of Delivery o ~ 0 a 8. Addressee's Address (Only if requested and fee is paid) t t- PS Form 3811, December 1994 tozsss-ss-a-oz23 Domestic Return Receipt SENDER: I also wish to receive the fotlow- ^ Complete items 1 and/or 2 for additional services. ing S2fvIC8S (fof an extra fee): Complete items 3, 4a, and 4b. ^ Print your name and address on the reverse of this form so that we can return this card to you. 1. ^ Addressee's Address ^ Attach this form to the front of the mailpiece, cr cn the bade if space does not it 2• ^ Restricted Delivery perm . ^ Write 'Return Receipt Requested' on the mailpiece below the article number. ^ The Return Receipt will show to whom the arttde was delivered and the date delivered. IO: J. C. Pale P.O. Box 872573 Wasilla, AK 99687 4a. ArtIC1e Number Z_~fo7-- rfg/-77~ 4b. Service Type / ' ^ Registered p Certified ^ Express Mail ^ Insured ^ Return Receipt for Merchandise ^ COD 7. Date of Oeliverv 5. Received By: (Print Name) 8. Addressee's Address (Only if requested and fee is paid) 6. Signature (Addressee or Agent) ai U V) a .~ U m c m c .N `o 0 a Y c m L H I also wish to receive the follow- ing services (for an extra fee): ti .~ 1 • ^ Addressee's Address ~ 2. ^ Restricted Delivery d ai U •~ a .~ U d a~ rn .y `a 0 Y c m L H PS Form 3811, December 1994 102595-99-8-0223 Domestic Return Receipt d `~~ SENDER: , D w ^ Complete items 1 and/or 2 fo nal services. N Complete items 3, 4a, and ab. ^ Print your name and address on the reverse of this form so that we can return this j card to you. ~ p Attach this form to the front of the mailpiece, or on the back if space does not y permit. Y ^ Write 'Return Receipt Aequested' on the mailpiece below the article number. _ ^ The Return Receipt will show to whom the artice was delivered and the date p delivered. ~ 3. Article Addressed to: 4a. Article Number u) Q .~ / ~ U 7 7 '7 c <Dallas & Caren `~;. Sl;tith < 4b. Service type i d mo ifi ^ R ~, u P.O. Box 671 stere rt ed eg ~ o u Palmer, A?{ 9,64:, ^ Express Mail ^ Insured .N ~ ^ Return Receipt for Merchandise ^ COO J C ~ 7. Date of Delivery ~ 2 a a ~ 5. Received By: (Print Name) 8. Addressee's Address (Only if requested and c u.l fee is paid) r t- 0 6. Signature (Addressee or Agent) PS Form 3811, December 1994 tozsss-9s-e-ozz3 Domestic Return Receipt SENDER: .y ^ Complete items tand/or 2 for additional services. v Complete items 3, 4a, and 4b. ^ Print your name and address on the reverse of this form so that we can return this ....... ~ card to you. ` ^ Attach this form to the front of the mailpiece, or on the back if space does not y permit. ^ Write 'Return Receipt Aequested' on the mailpiece below the article number. ~ ^ The Return Receipt will show to whom the article was delivered and the date o delivered. ~ 3. Article Addressed to: 4a. Article N Z-4 c a 7. Date of Delivery z ~ 5. Received By: (Print Name) 8. Addressee's Address (Only if requested and w fee is paid) I also wish to eive the follow- ing services~n extra fee): ai ~ ~ ^ Addressee's Address ~ .~ 2• ^ Restricted Delivery m` I also wish to receive the follow- ing services (for an extra fee): 1 • ^ Addressee's Address 2~ ^ Restricted Delivery ,tuber 07_~~~-77s E 4b. Service i ype ° Matthew V. KiViaho ^ Registered Ca'Gzrtified vi 17006 Celle Del Flores ^ Express Mail ^ Insured Fountain Hills, AZ 35268 ^ Return Receipt for Merchandise ^ COD ~ 6. Signature (Addressee or Agent) 0 m ___. __.. __ _. ___- - PS Form 381 l , December 1994 102595-99-B-0223 Domestic Return Receipt r SENDER: H ^ Complete items tand/or 2 for additional services. m Complete items 3, 4a, and 4b. - - ~ ^ Print your name and address on the reverse of this form so that we can return this ~ card to you. ;u ^ Attach this form to the front of the mailpiece, or on the back if space does not ~ permit. ^ Write 'Return Receipt Aequested' on the mailpiece below the article number. ~ ^ The Return Receipt will show to whom the artrcle was delivered and the date o delivered. ~ 7. Date of Delivery z ~ 5. Received By: (Print Name) 8. Addressee's Address (Only if w fee is paid) ~ 6. Signature (Addressee or Agent) 0 a I also wish to receive the follow- ing services (for an extra fee): 1 • ^ Addressee's Address 2. ^ Restricted Delivery '~ °' 3. Article Addressed to: 4a. Article Number -het- 776 -~{v~ z a E Charles L. Mowrer 4b. Service Type ~~ ~~ ^ Registered I_7C;ertified P.O. Box 770647 ^ Express Mail ^ Insured Q Eagle River, AK 99577 ^ Return Receipt for Merchandise ^ COD and ai U .~ d Q .~ U d a~ tt m c N `a 0 Y c m I- PS Form 3811, December 1994 102595-99-(3.0223 Domestic Return Receipt `~~ SENDER: a fn ^ Complete items 1 and~r additional services. ar Complete items 3, aa, b. ^ Print your name and address on the reverse of this form so that we can return this ~ card to you. d ^ Attach this form to the front of the mailpiece, or on the back if spaco does not ~ permit. ^ Write 'Return Recaipt Requested' on the mailpiece below the anicle number. ~ ^ The Return Receipt will show to whom .he artide was delivered and the date o delivered. 8. Addressee's Address (Only if requested fee is paid) SENDER: .y ^ Cpmplete items 1 andlor 2 far additional services. m Complete items 3, aa. and 4b. ;n ^ Print your name and address on the reverse of this form so that we can return this _ ~ card to you. ' d ^ Attach this form to the front of the maiipiece, or on the back if space does not m permit. p Write 'Return Aecaipt Aequested'on the mailpiece below the article number. ~ ^ The Return Receipt will show to whom ;he artide was delivered and the date o delivered. ~ 3. Article Addressed to: a E Ralph T. Berg ~ 3750 Grey Wolf Dr ~ Wasilla, AK 9956a O a Z ~ 5. Received By: (Print Name) w ~ 6. Signature (Addressee or Agent) 0 ~+ PS Form 3811, December 1994 4a. Article Number ~ ~{O7- 4'y`'/- 77~ 4b. Service Type ^ Registered ertified ^ Express Mail ^ Insured ^ Return Receipt for Merchandise ^ COD 7. Date of uehvery Addressee's Address (C1nly tt requested and fee is paid) 1o2sss-ss-B-o223 Domestic Return Receipt ~ 3. Article Addressed to: c c Douglas N. Hotes 1800 W Hoteco Ave ~ Anchorage, AK 9950? C C Q 2 ~ 5. Received By: (Punt Nam w lozsss-ss-B-o223 Domestic Return Receipt 6. Signature (Addressee orAgenl 0 ~+ PS Form 3811, December 1994 ai `m n. .~ U m N `o 0 T Y c m L t- ai U •~ fl. .~ U d c m c N `o 0 a Y c L r 4 SENDER: I also wish to receive the follow- .y ^ Complete items 1 and/or 2 for additional services. ing services (for an extra fee): m Complete items 3, aa, and 4b. ^ Print your name and address on the reverse of this form so that we can return this ~' card to you. 1 • ^ Addressee's Address ^ Ariach this forth to the front of the matiptece, or on the bade if space does not 2- ^ Restricted Delivery ~, .e permit. ^ Write 'Return Receipt Requested' on the mailpiece below the article number. e ^ The Return Receipt will show to wham the artide was delivered and the date o ~ vere . e 3. Article Addressed ta: E Joan I. Markle 3575 N. Brookside Ln Boise, LD 83703 w Q Z ~ 5. Received ey: (Print Name) w 0 6. Signature (Addressee or Agent) a N li d d PS Form 3811, December 1994 4a. Article Number Z -tfa7 - ~f~r'-77~ 4b. Service Type ^ Registered ^ Certified ^ Express Mail ^ Insured ^ Return Receipt for Merchandise ^ COD I also w to receive the follow- ing s (for an extra fee): 1 ^ Addressee's Address 2. ^ Restricted Delivery I also wish to receive the follow- ing services (for an extra fee): 1 ~ ^ Addressee's Address 2• ^ Restricted Delivery 8. Addressee's Address (Only if requested and fee is paid) 4a. Artide Number ^ ~ ~ ~ ~ ~ry~ '~ 7 7Z 4b. Service Type ^ Registered ertified ^ Express Mail ^ Insured ^ Return Receipt for Merchandise ^ COD 102595-99-8-0223 Return Receipt ai U ., `m Q. .~ u d d rn c ._ `o 0 T Y c s • 0111®CAL~6 D. T. Seamount Senior Advising Geologist Business Ventures June 9, 1999 Robert P. Crandall Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Amendment to Application for Freshwater Aquifer Exemption Pioneer Coal Bed Methane Project Proposed Class II Waste Disposal Well #1702 15AD WDW Mat-Su Borough, AK Dear Mr. Crandall, In response to your recommendations regarding Unocal's Application for Freshwater Aquifer Exemption for the proposed Class II Waste Disposal Well #1702 15AD WDW May 12, 1999), the following modifications and additional information are: The location of the proposed Class II injector well is in the NESS section 15- T17N R2W (Attached map). Locations of nearby water wells and the proposed test wells are shown on the attached map. A baseline study of water wells surrounding the in immediate area (>1/2 mile radius) will be performed by a third party geo-technical firm. The proposed injection interval is changed from "1500' to 4000" to "below 2500". This will result in an additional 1000' of separation between the base of the fresh water aquifers at approximately 500' and the proposed injection zones (Attached cross-section B-B'). The injection zones will be confined by a 270' thick shaley interval present from 2520' to 2790' in the ARCO BLT #1 (Figure 8 in original application dated may 12, 1999) • Produced water samples from the potential injection zones will be analyzed for Total dissolved solids concentrations after the injection well is drilled, logged, cased, and perforated Very truly yours, D. T. Seamount Senior Advising Geologist • Submitted by UNOCAL ~4~ PIONEER PROJECT Request for Aquifer Exemption Proposed Class II Waste Disposal Well #1702 15AD WDW Tyonek Formation May 14 1999 Tim Brandenburg- Drilling Dan Seamount- Geology Faye Sullivan- Environmental ~ ~ UNOCAL 76 D. T. Seamount Senior Advising Geologist Business Ventures May 14, 1999 Robert P. Crandall Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Application for Freshwater Aquifer Exemption Pioneer Coal Bed Methane Project Proposed Class II Waste Disposal Well #1702 15AD WDW Mat-Su Borough, AK Dear Mr. Crandall, Unocal, in accordance with the requirements of 20 AAC 25.440, herein submits an "Application for aquifer Exemption" for a single class II waste disposal well, Pioneer #1702-15DA WDW on State oil and gas Lease ADL 374117 within the Pioneer Unit. The surface Owner is Joan I. Markle. The approximate location is 1500' FSL & 515' FEL of Section 15, T17N, R2W. It is anticipated that well drilling will be initiated around July 15, 1999 in order to comply with unit obligations. The injection zones exist as permeable sands and conglomerates at depths between 1500' and 4000' within the Tyonek Formation. The zones correlate with those at similar depths in the ARCO BLT #1 (located approximately 6 3/4 miles to the west) which range in salinity from 3000ppm to 10000ppm. The specific injection intervals will be identified after the well has been drilled and log analyses indicate that the aquifers meet the criteria for exemption as specified in both the State and Federal regulations (CFR 40 146.4 and 20 AAC 25.440). Unocal respectfully requests that aquifer exemptions be granted for the Pioneer Unit Well #1702-15DA-WDW. An application for underground injection (regulation 20 AAC 25.252) will soon follow. Very truly yours, D. T. Seamount • ,Senior Advising Geologist • i Geologic Data For Freshwater Aquifer Exemption Tyonek Formation Pioneer Unit Well #1702 15AD WDW I. Introduction Union Oil Company of California, d.b.a. Unocal, plans to test the coal bed methane potential (CBM) of the Pioneer Unit in northern Cook Inlet (Figure 1). The project will target numerous coal seams in the Tertiary Tyonek Formation (Figure 2). The subsurface geology and coal bed methane (CBM) potential of the unit is described in Seamount et al. (1997). The entire three year exploratory phase of the project is described in the "Pioneer Unit Plan of Operations" (1999) and the "Pioneer Unit -Vine Extension Plan of Operations" (1999). Since CBM wells commonly produce large initial quantities of water (up to 500BWPD anticipated) ,safe methods of disposal must be planned. Pioneer well #1702-15DA- WDW is planned to be drilled this summer as a class II Waste disposal well to handle fluids and drilling wates from test wells to be drilled nearby (Figure 3). Operations are expected to begin on approximately July 15, 1999. Testing of the first few wells may continue for up to 18 months. It is of utmost importance to identify the entire stratigraphic section containing all of the potential fresh water acquifers. Then, they can be protected through safe cementing and casing designs of both producers and disposal wells. State of Alaska regulation "20 AAC 25.440." requires that application for a fresh water aquifer exemption is required if the potential disposal zones contain fluids between 3000ppm and 10,000ppm TDS. Through exploration well tests and log analyses, it will be shown that: • Zones within the Tyonek section between 1500' and 4000' contain fluids within those limits. • The base of the potable water section (<500ppm) is at depths above 1000'. • Adequate confining layers exist between the potable water section and any potential disposal zones below 1500'. • The salinities of the injected fluid will be similar to the salinities of the fluid in the injected zone. Confirmation of the suitability of any potential injection zones will be made after drilling and logging the disposal wells. The following information is intended to show that for Pioneer well #1702 15AD WDW, permeable zones within the Tyonek Formation below 1500' qualify for a Freshwater Aquifer Exemption in accordance with 20 ACC 25.440. • FIGURES Figure 1- Pioneer Unit Location Map Figure 2- Stratigraphic Chart of Cook Inlet Figure 3- Pioneer Unit Geography and Well Locations Figure 4- Water Table Contour Map, Pioneer 1702-15DA WDW Area Figure 5- Water Well Location Map- Well # 1702-15DA WDW Area Figure 6- Log Curves and TDS Analyses of DST'd zone- Horseshoe Lake State #1 Figure 7- Log Curves and TDS Analyses of Kick Zone- American Quasar Big Lake #1 Figure 8- Wireline Log and Salinity Curves of BLT #1 (in pocket) Figure 9- Map of B/ Glacial/fresh water Includes deep water wells (Large copy in pocket) Figure 10- Cross-Section A-A' (in pocket) Figure 11-Cross-Section B-B' TABLES Table 1-Pioneer Proposed Wells Table 2- Deep Water Well List Table 3- Exploration Well List Table 4- Exploration Well Tests Table 5- -Log Curves and TDS Analyses of DST'd zone- Horseshoe Lake State #1 Table 6- -Log Curves and TDS Analyses of Kick zone- American Quasar Big Lake #1 Appendix 1- Pioneer #1702-15DA WDW Area Water Wells Appendix 2- Geochemical Analyses & Test Data From the Horseshoe Lake State #1 & American Quasar Big Lake #1 Appendix 3- EPA Log Analyses Method to Determine Total Dissolved Solids Concentrations • COOK INLET L-3ASIN COAL BED METHANE POTENTIAL ,~. • .; 1 ~laC~:(JSTC"7N ~ t ~ ~~ nsrit.n I ~ ~` / i ~T~LLEY ~ ~ ,~~ j ! ~ ~' ~ ' .: • • ~ i~'' ,~ ~', ~' ~ ~ -~ ~ ~~~~€ f ~:. ~ ' a ~; ~.r' •; Hl714.SR R C~'e~~ ~a t' 1-ii~laesC 4~ E~2 w 4~~1i~ t~ i~h Co<~l 1~aT~k C4T~Ti~o1 Area of Highest Potential Figure 1- The Pioneer Project is located in the northern Cook Inlet `s Matanuska Valley. r~ u T AGE LITHOLOGIC ,~„ TYPE PRODUCING ZONES ~N . M. SYSTEN SERIES UNITS "°"~ LOG O0.&ASSOCIATED GAS FIELDS MIASSOCW7FD GAS FIELDS T.A.I. I I ~ i '~ Glacial 0-4500' ~~ ~ I , Q ~ aECENr EISfOCENE ` SECjliIlBflt.S ':' ~ ~ ~ ~ ~~ i ~ ~ ~ ~i I zl~i~ x Qj wlfrestt H2O ~ ~ 3 ~ "I~ ~ ~ ~ ~a Es Is ~ ~ 15 ~ F ~ > I _ ~ t ~~1s <I tt l~ ~ i.. ~ ~ my E I I~~ ~, ~ 0-6300' '~ I ~ Ii I s PLIOCENE ~~ ~ ~ ',, ', ~ i I ~ ~' II ~ '.. '. i ' STERLING ~ ~ ~~ ~ ~ ~ ~ I I I FM ~ ~ ~ ~ I ~ ~ ~ I ~_ ~~ L ~ ~ I I ~ T ~~,q~~ _ ~ ', ~ I ~ Srndskne ,~istma Tin Cod ~~.y - 'i I '. i I ~ ~ ' ~ ' E ~ I ~ i ~ I I R ~ 0-4900' - ~ ~ I i~l ~ BELUGA ~ ~ ~ ~ ~ ~ MCCENE UI FM I i I ~ Z "FAN I i w FACIES" ' I Y 000-, 0,00 ~~~ ~ I I I~ ,; ' ' ~ I ` A ! I ~ ~.- ~ ~ m I , ~ ( ~_ TYONEK - i I ~ ~ - D ' .~ i ~ I ~ Y FM " I ~ .. ~: I ~ .I I ~ ~I j ~ I se,v~,a ~; I ~ c«I~«„~ ~ j ~ I Sandslme. Sitstona .j ~ I I I '. Cod .~ I j ' ~ f I I ]RS J .~ . I I II( J ~ . . a } ~ ~ ! ~ I ~ ~~ ~ OLIGOCENE a , _~ .. i o-a o' b ~ ~ 1 1 I i ~ I i [ HENLCCK CGI, ~ f ~ ~~ , ~~ I 1 ~ ~ HENLOCK SHALE 3 <j ~ ~ ~ I ~ I , I ~ i I ~ I I _- a 0_6~, 5a i ~ I I ' I I i I EOCENE WEST Fg2ElAN0 FN ~ i i. I it i I i I I, x PALEOCENE CHICK4LOON FN 0-2000' 'I ' II ICI ~~~ ~c UNDIFFERENMTED ru '~ NNRWE SEDINENTS AND vacANlcs I Figure 2: Stratigraphic Chart of Cook Inlet a r-y z -~ z ".~ a z c a r r ;-y ^'C • Location of Proposed Well and Proximity to Well Control The Pioneer Unit outline and the well location for the .Class II Disposal Well- Pioneer #1702-15DA WDW and the proposed test Wells are shown in Figure 3. Houston, Alaska is located on the western edge of the unit and Wasilia is located on the southeast edge. Residential use of the area is sporadic. Elevation of the well .location is approximately 300' above sea level. The topography is somewhat irregular due to past glacial events. The disposal well specifics are as follows: Pioneer # 1702-15DA WDW State Lease ADL 374117 Surface Owner: Joan I. Markle Land: Approx. 1500' FSL, 515' FEL of Section 15, T17N, R2W Proposed Total Depth 4,000' ~, ~~ . r~. Surface Hydrology and Fresh Groundwater Water wells in the unit area typically tap the water table; they do not drill through the water column. Figure 4 is a portion of regional water table maps (Montgomery, 1990) of the Palmer to Big Lake area which pertain to the proposed wells in the project. They indicate that the depth to the aquifer is very shallow throughout the unit area and basically follows the topography ranging from sea level to 800'+ from SW to NE. They also show that ground water flow is generally to the SW. Most of the lake surfaces define the top of the water table. The estimated elevation and depth to fresh water for the proposed disposal well are 300' and 35 feet respectively. The depth to fresh waterwas estimated from regional mapping (Figure 4 from Montgomery, 1990) and local water well drilling depths (Table • Appendix 1 and Figure 5). The regional maps often show that the main water table at the locations are deeper than some water well total depths. The shallower depths to fresh water are possibly indicative of wells which tapped confined or semi-confined aquifers. The Division of Mining and Water Management identified 10 water wells with depths greater than 400 ft (Table 2) that were located within four miles of the unit boundary. The deepest total depth for a fresh water well is 605 ft. While water well data can be used to estimate the depth to the top of the aquifer, no water wells were identified which drilled completely through the fresh water column. Therefore, the fresh waterlbrackish (3000ppm to 10,000ppm TDS) water transition zone cannot be determined by examining only water well information. Salinity Evaluation/Depth to Base of the Fresh Water Section Wireline and mudlog data from 31 deep oil and gas exploratory wells (Table 3) and produced water analyses from two wells (Appendix 2) within a 48 township study area were analyzed to help determine the depth to the base of the fresh water. Rwa Method In the absence of reliable laboratory water analysis data, electric logs provide the means to discriminate between freshwater sands and those that contain saltwater. Because the total dissolved solids (TDS) content (salinity) of fresh water is relatively low, it is a poor electrolyte that exhibits high resistivity. Conversely, if the water is more saline, it conducts electricity better and its resistivity is lower. Within permeable rocks, resistivity is a function of temperature, porosity, and water salinity. The "Rwa" method (Appendix 3) described in EPA publication "Survey of Methods to Determine Total Dissolved Solids Concentrations" relates formation water salinity to those parameters. The method generally underestimates the actual salinity of formation fluid and, therefore, helps to insure that potential disposal zones are in compliance with regulation "20 AAC 25.440". Fluid Recovery from Deep Wells Very few of the deep exploration wells were tested. The locations of the wells are shown in Figure 3. Fluid was recovered from only 15 tested zones in five wells and one zone in a well which kicked (flowed into the well bore) while drilling (Table 4). Furthermore, chemical analyses of the fluid exist for only three of the zones. Most of the other fluid recoveries were described as "salt water". Of the three analyzed zones, fluid recovered from the Horseshoe State #1 Well from 4246' to 4310' was probably not formation fluid, but was fresher mud filtrate used in the drilling operations. The recovery was described as "354' of water cut • drilling mud". The other two analyzed fluids were probably true formation fluids, which were contaminated (diluted), somewhat by the fresher drilling muds. The probable result was in measured salinity being lower than true formation salinity. The two zones were from 1870'to 1930' where a "kick" occurred in the American Quasar Well Big Lake #1 and from 2950' to 3084' in the Great Plains Horseshoe Lake State #1 Well. The "Rwa" method was used to calculate TDS salinity of the two zones (Figures 6 & 7) using porosities derived from three different curves- density, density/neutron crossplots, and sonic travel time. The .results were compared with the actual measured salinity (Tables 5 & 6). It was found that using the sonic derived porosity gave the best match with the measured data. Higher salinity was calculated using density and density/neutron derived porosities. Most likely, the density/neutron-derived salinity. is the most accurate and the lower measured salinity is due to fresh drilling mud contamination. However, the sonic derived salinity was used in the area evaluation to remove any doubt about a potential disposal zone's regulatory compliance. Salinity Evaluation of the Section to be Drilled A salinity curve was generated for the ARCO BLT #1 well (Figure 8) using the "Rwa/sonic" method. The analysis indicates that the base of the fresh water can be identified at 534' were there is a marked decrease in ILD resistivity of permeable zones from >50 ohm-m to <20 ohm-m. At this depth '`Rwa/sonic" calculated TDS salinity changes abruptly from <500ppm TDS to >3000ppm TDS. The mud log indicates that the lithologic section changes from massive Quaternary gravel of glacial origin to the interbedded claystones, siltstones, sandstones, conglomerates, and coals of the fluvially deposited Tertiary Tyonek Formation. Resistivity values >20 ohm-m in deeper permeable zones are mostly dine to gas effect and result in erroneously low calculated salinities. The erroneous calculations can be identified where zones have high total gas readings on the mudlog and/or production testing resulted in gas recovery with no water (Table 4). Specifically, gas effect was apparent from 2250' to 2500' and was very common below 3800' (Figure 8). "Rwa/Sonic" calculated salinity generally range between 3000ppm and 13000ppm TDS from 1500' to 4000'. Obviously, well control in the area is sparse. Therefore, after drilling a disposal well, the wireline logs will be analyzed using the "Rwa/sonic" method in order to identify specific injection zones. Base of the Fresh Water Resistivity curves from the rest of the deep tests in the area were used to estimate the depth to the base of the fresh water for each well. The base of fresh water structure map (Figure 9) incorporated all of the 31 deep exploratory wells and the 10 deep water • • wells (Although none of the water wells were drilled to the base of the fresh water, their total depths were used to determine minimum depths). The Base of the fresh water sediments ranges from above sea level in the NE to very deep and thick (> 4000') to the SW (Figure 9 & 10). The Castle Mountain and Cottonwood Creek Faults seem to act as impermeable seals to deeper fresh water flow from the NW and east. The thickening and extreme depth of the fresh water section to the southwest corresponds to the area where the Susitna River crosses the fault. The huge volume of water flowing in the Susitna River combined with continued regional rapid subsidence of Cook Inlet Basin and high vertical permeability of the glacial section is probably the reason for the anomalous thickness. Within the Unit, the base of the fresh water ranges from -500' to above sea level. The structure rising to the NE combined with the coincidental rise in topography results in fairly consistent drilling depths to the base of the fresh water throughout the unit of between 400' and 700' (Table 1). Therefore, surface casings of all unit wells are proposed to be set deeper than 800'. Inspection of resistivity and mud log data indicates that most of the fresh water aquifers are well sorted sands and gravels within glacial drift (including deeper unproduced reservoirs). The exception is where the glacial sediments are thin in the NE corner of the unit. Here, the upper few hundred feet of the Tyonek Formation contains some fresh water above sea level (Figure 9). Injection zones It is recommended that the Tyonek section between 1500' and 4000' be covered by the fresh water aquifer exemption. All potential disposal zones are permeable zones within the Tyonek Formation. Experience has shown us that the Tyonek is a sand rich system and it is anticipated that there will be no problem in identifying suitable injection zone between 1500' and 4000'. And, the Tyonek Formation exists and is thick at the well location (Figure 11). Examinations of wireline logs from the exploratory deep wells within the Unit, the Pittman #1 and the BLT #1 indicate that there are a number of specific potential disposal zones within the Unit (Figure 8 & 10). However, because the Tyonek sands and conglomerates are lenticular and discontinuous, it is uncertain that specific potential disposal zones in those wells will exist at the proposed location 6 3/4. miles to the east. Therefore, disposal zones and overlying confining zones in the well will be identified from wireline and mud logs after drilling the well. Confining Layers As in the BLT #1 well, the high resistivity/low resistivity transition is very abrupt in every well where it was logged. The difference between these two dramatically different salinity environments leaves no doubt that the intervening layer of • • siltstone and coal is a very effective permeability barrier. The transition occurs above 1000' throughout the Pioneer Unit. Also, numerous confining layers between the base of the fresh water and 1500' (and specific confining layers containing individual potential disposal zones) can be identified in every well drilled in the area. Figures 8 & 10 demontrate this in the BLT #1 and Pittman #1 wells. There are 29 impermeable claystones and siltstones (net of 614') in the BLT #1 between the base of the fresh water at 534' and 1500' depth. At the proposed well location, the thick 500'+ section containing numerous confining layers (will be obvious from the well logs) would prevent upward migration of wastes into any fresh water aquifers (Figure 11). Injection Zone Salinity The target coal reservoirs seams are interspersed within the section between 1000' and 4000'. .Although, formation fluids within the seams have never been analyzed it is probable that their compositions are similar to those of any potential injection zones. In fact, produced fluids from the shallower seams (1000' to 1500') would probably be fresher than fluids within the injection zones. References EPA publication "Survey of Methods to Determine Total Dissolved Solids Concentrations" . Fuelner, A. J., 1971, Water Resources Reconnaissance of a Part of Matanuska-Susitna Borough, U. S. Geological Survey, Hydrologic Investigations Atlas HA-364. Jokela, J.B., Munter, J.A., and Evans, J.G., 1991, Report of Investigations 90-4 Ground-Water Resources of the Palmer-Big Lake Area, Alaska: A conceptual Model; State of Alaska DNR, Div. Of Geol. & Geophysical Surveys, 3 maps or Montgomery, James M., Consulting Engineers Inc., 1990, Conceptual Model of Groundwater Resources from Big Lake to Palmer-Final Report. Seamount, D.T., Cross, R., & Buck, G., 1997, Geologic And Engineering Report To Accompany Application For Approval For Unitization Of The Pioneer Unit, State Of Alaska, December 10, 1997 Unocal, 1999, Pioneer Plan of Operations", March 8, 1999 Unocal, 1999, Pioneer Unit -Vine Extension Plan of Operations", May 11, 1999 • Additional References Kartstrom, T. N. V., 1964, Quaternary Geology of the Kenai Lowland and Glacial History of the Cook Inlet Region, Alaska, U. S. Geological Survey Professional Paper 443. Reger, R. D., 1981 a, Geological and Materials Maps of the Anchorage C-8 Southeast. Quadrangle, Alaska, Department of Geological and Geophysical Surveys, Department of Natural Resources, State of Alaska, Geologic Report 65. Reger, R. D., 1981 b, Geological and Materials Maps of the Anchorage C-8 Southwest Quadrangle, Alaska, Department of Geological and Geophysical Surveys, Department of Natural Resources, State of Alaska, Geologic Report 68. Reger, R. D., and R. G. Updike, 1983, Upper Cook Inlet Region and the Matanuska Valley, in Guidebook to Permafrost and Quaternary Geology along the Richardson and Parks Highways between Fairbanks and Anchorage, Alaska, ed. by Pewe, T. L. and R. D. Reger, 1983. Fourth International Conference on Permafrost, Division of Geological and Geophysical Surveys, Department of Natural Resources, State of Alaska. APPENDIX 1 • TDS Calculation From Well Logs Thermal Gradient Formula: TG = (Tmax -MST) / (Depth Subsea / 100) Tmax =Maximum recorded temperature from log header MST =Mean Surface Temperature for Cook Inlet (= 35 deg. F Depth Subsea =Meas. depth of~Tmax converted to subsea depth Formation Factor F = 0.81/ (porosity*porosity) {average of the density and neutron log porosity) (Tixier Formula) Resistivity of 100% Water Saturated Formation: Ro = Rt (deep induction R value through analyzed zone assumed to be 100% water). Resistivity of Formation Water Rw=Ro/F Formation Temperature: Tf = (Depth subsea 1100) x TG Resistivity of Formation Water at 750 F: Rw@75degF = Rw {(Tf + 6.77) / 81.77) Salinity. (ppm): x Salinity= 10 ~f= 3.562 -log (RW@75DegF - 0.0123) .955 A procedure to generate the salinity curve using the method has been developed for WDS. APPENDIX 2 • APPENDIX 3 FIGURES Pioneer Unit #170~5DA WDW Proposed Water Disposal Well NE SE Section 15-T17N-R2W Matanuska-Susitna Borough, AK GL: 265' Well Detail/Casing Detail 1) Conductor: 13-3/8"/ 68# / K-55 /Welded @ 35' / 17-1/2" hole. Cemented with 35 sx. 2) Surface: 9-5/8" / 36# / J-55 / STC @ 700' / 12-1/4" hole. Cemented with 400 sx "G". 3) Production: 7" / 23# / WC-50 / LTC @ 4,100' / 8-3/4" hole. Cemented with 455 sx ,.G., 4) Tubing:2-7/8"/ 6.5# / J-55 / EUE 8rd @ 50' above top perts. 5) Packer @ 50' above top perts. 6) Perforations Between 2,500' and 4,000' (estimated). 7) TD: 4,100' • • Found survey NE 1 /4 SE 1 /4 monument MAT-SU SECTION 1 5 S,5 S,4 T17N, R2W, S.M., AK + 4636-5 1994 GL 265' PIONEER 15D~ GRID N: 2762483.04; GRID E: 569295.57 LATITUDE: 61'33'37.043 LONGITUDE: 149'36'09.349 ASP ZONE 4 NAD2- South Line Section 15 `~~~~~~~111 -°P-~E ~F A~gS~41 _~ ~~, =~ 49Id.~ ~~~i NORTF- i _ __ i M. SCOTT McLANE. o i .. ~ s~~, 4928-S ~~ ~. ~~ SCALE ~~~ ~F cy4a ~~ .~ 1 = 200 ~ pR ~ ~P ~ 1) Basis of Horizontal Coordinates State of Alaska DOT&PF Georeferencing Project GPS Control Stations BigL & G40. 527' ;cess gad Found survey monumen{ MAT-SU S15 S14 S22+S23 4636-S 1994 _ ~~ II II I I I~ ~~ ~I~ III Q III Ilz I I' III CIII W O ~ NI I ;~ CI I O ~I v WI I III II III OCEAN ENERGY, INC. PIONEER UNIT X17®2-15DA SURFACE LOCATION 527' FEL and 1354' FSL - --------------------------------------------- SECTION 15, T17N, R2W, 5.M., AK Prepared For: Ocean Energy Inc. 1670 Broadway Suite 2800 Denver, CO 80202 Surve ed b McLANE CONSULTING GROUP Y Y Engineers, Surveyors and Planners P.O. box A68 Soldotna, AK 99669 993060 99-20 June 19, 1999 Job No: _______ rleld Book No.________ Date: ___________ Proposed Surface Facilities Pad 1354' • -- ~ `n . ~ ~ _ ~ ~ ~ ,,;,,: ~ z ~, •SD li .. ~: , .~ Imo', ,~ ~ ~ ,~ ::: ~ ~ Barbara E. R~ggan ' 14 ~ ~ l G r E ~ 80 ® i lU~l ' ,.,~~ ~. ~, ~ ~ cr'a ~ i ~ _, a rn 1 _- __ - ,. - ~ ~~ - ,,--~o ----------------------------- ~- Water Welf N~ ~ ,~ ~ • ~ .a Locations r I ~~: do " ~ ~, ~.,~, ~ ®o ~ _ ~, ~_~'~ i 1/2 Mile 1 ~ ~ CImsL.Mowrer JoanLMarkle ~ ' #1702- 15WDW ~'°~ ~ weu #1702- i~ Proposed Class II lsvn-wnw ® Alaaka,Slaleat,DNR t Injection well _ _ ~~_ ~ - ~ Jake Marquez ~ i -' oo - I Proposed CBM Test Wells • usb' Alrvka, Smte o4 DNR n. i a ~S - - - - - • ~_ - 22 _ _` , ' 23 ni.xlen wet~De sl~~ri ~ ~ 14111~~ ~~ ~ ~ ~ ~ ~ Proposed Access Route ~ ~ ,. ..~ I. .~. } - Dick Lawmm~ Jerry A. & Deborah ~ 01 Frost • g 46 Water Wells from 125' to ~~ ; - - ' 218' 305' deep in the SE 1/4 of ~ • Section 22 1j ~ '196" ~)0 _ _ -200 _ -- -1~, _ OS ' 197 ~ 37_ ~ ,~ -240 ,. .~ ~ 196 ~~~~;,, ~~,~~t_ ~~= i ~ - = 200 uu;,<" ~ U - '= •~ e, ~, - ~ ® J~240~ • • ®~ N • -- ~~ a. ~ 21 ~,, : • a.' ~ _ ~7 _ _ - ,~ ~I • ~ Found survey NE 1 /4 SE 1 /4 monument MAT- 5U SECTION 15 S,5 S14 T17N, R2W, S.M., AK + 4636-5 1994 UL 265' PIONEER 15Di GRID N: 2762483.04 GRID E: 569295.57 LATITUDE: 61'33'37.043 LONGITUDE: 149'36'09.349 ASP ZONE 4 NA02 Proposed f Pad South Line Section 15 =~P~~ of q~~s~~°i ~ ~- ~ ~~ 49~~ ~*~i NORTI- ~. _ _ _ _ / i ~~~~~ ~ M. SCOTT McLANE ,o i ~ ~ ~~~ sTF~ G 492e-s ~J~ .. 1., scA 200' s ~~\\\\~~ 1) Basis of Horizontal Coordinates State of Alaska DOT&PF Georeferencing Project GPS Control Stations BigL & G40. Surface Facilities _ ~ 527' ~cess gad Found survey monument MAT-SU S15 S14 S22+S23 4636-S 1994 . ~~ II II I I~ I~ II~ III Q III Ilz I I' III ~ N plll O NI I f- r7 C) I ~ ~I I O wl III II OCEAN ENERGY, INC. PIONEER UNIT x'1702-15DA SURFACE LOCATION 527' FEL_ and_ 1354_' FSL _ _SECTION 15, T17N, R2W, S.M., AK_________ ------------- ------------------ AAATAAII ICllA-CI ICITnl4 R(1R(11I(:4-1 Prepared For: Ocean Energy Inc. 1670 Broadway Suite 2800 Denver, CO 80202 McLANE CONSULTING GROUP Surveyed by. Engineers, Surveyors and Planners P.D. Box 46B Soldotno, AK 99669 993060 99-20 June 19, 1999 Job No: ____-__ Fleld gook No.________ Dale: ___________ 1354' ~ ~ ~ ~ r • uMU~~• s, ~ ~ s J~ ~~ Rar~ra ~ Rlggan d 14 E ~ SO ®i ~ lO~l ~ ~ I,. ~, ; III r i ~.. ~._. .. ~ 1 -. ., ____...._. -~ I~I I ,,,.~,_,.,.. ~,~ ® 0 4. - ~ ~ ~ or ' 1/2 Mile - i Chas L. Mowrer '. Joan t. Markle Well #1702- 15DA-WUW ® Alaska, Slate af, DNR !~ ..,, ~ ~ - - Jake Manfuee ~ ', ~ LIAh' • Alaska, Stale of, DNR i ~~ ~a to - - .._ - e- sc- ~~„ ~ ~ ~. ~., ~~, - _ ..e 22 laaP~ ~ 23 - ~ICRILV ~VEI~UE 5161;1AG KO0 U: ~ ~ , '~ ~ AUU ND , Water Well Locations #1702- 15WDW Proposed Class II Injection well Proposed CBM Test Wells • . ~. Dsk Lawman _ Jerry A. & Deborah Ql Frost 1 ~ 46 Water Wells from 125' to d 21s 305' deep in the SE 1/4 of ~~; ,1~, , no Section 22 _ -: r - 200 `~ I ~,~:~.~ ~ 80 240 ~ O ~ ~ ~ ® .a ,~ ~ ~ ~r.,._, ,~ ~__ ~.. 196. .. ~ ~ ~ _~ 9'~ ~ ! ~ ~, - _= 200 wu. g ~ - ®~ f d~ - - O ~ ~ 240.: v ® ~ ~ ~ 21 ~ . i~'°` ~. ~~: - - - - - ~-.~_i ®~~ 31'7-. .. _ '~ Proposed Access Route Pioneer Unit #170~5DA WDW Proposed Water Disposal Well NE SE Section 15-T17N-R2W Matanuska-Susitna Borough, AK G L: 265' Well Detail/Casing Detail 1) Conductor: 13-3/8"/ 68# / K-55 /Welded @ 35' / 17-1/2" hole. Cemented with 35 sx. 2) Surface: 9-5/8" / 36# / J-55 / STC @ 700' / 12-1/4" hole. Cemented with 400 sx "G". 3) Production: 7" / 23# / WC-50 / LTC @ 4,100' / 8-3/4" hole. Cemented with 455 sx ..G.. 4) Tubing:2-7/8"/ 6.5# / J-55 / EUE 8rd @ 50' above top perfs. 5) Packer @ 50' above top perts. 6) Pertorations Between 2,500' and 4,000' (estimated). 7) TD: 4,100' Chas L. Mowrer I ~ n esroN I ~ ~(~ li ~.v M~~ I I I ~ - ~ 1.53/) I I ~ I w cRLE smcF oR .. an 1. Markle - Motes -,7L ~ ~ i r_1 ~ ''- 1/q Mile Well #1702- (n 15DA-WDW I I I i - „3L _. Jake Marquez .... Alaska, State oP, UV R I Well #1702- • 1~1~, ~. I i Well #1702- ~~, 15DD • ` I I ~ I „~ ., ~ ~ ~~ _~ t: W JOLI CIRCLE iszsa) ~, ~I ~ ~ ~~ _ _ _ A/ N ~L.~ -.. GGd~.~kdE1. Figure 1 #1702- 15WDW Proposed Class II Injection well • Proposed CBM Test Wells 0 v ~ a • L LETTER OF APPLICATION FOR AN UNDERGROUND INJECTION ORDER PIONEER PROJECT WELL # 1702-15DA WDW OCEAN ENERGY RESOURCES, INC. • • APPLICATION FOR AN UNDERGROUND INJECTION ORDER PIONEER PROJECT WELL # 1702- 15DA WDW (The attached application for aquifer exemption titled "PIONEER PROJECT, Request for Aquifer Exemption, Proposed-Class II Waste Disposal, Well #1702 15AD WDW, Tyonek Formation, May 14 1999" be referenced as "the attached report" to minimize verbiage in this application.) 20 AAC 25.252. UNDERGROUND DISPOSAL OF WATER AND OTHER OIL FIELD WASTE FLUIDS AND UNDERGROUND STORAGE OF LIQUID HYDROCARBONS. 20 AAC 25.252 (c) (1) Figure 1 shows the location of the proposed disposal and production wells. Presently, no abandoned wells, production wells, dry holes, or any other wells that penetrate the injection zone exist within one-quarter mile of the proposed disposal. or storage well. 20 AAC 25.252 (c) (2) No other operators exist within '/. mile of the proposed well. Table 1 is a list of surface owners within a 1/4 mile radius of the proposed disposal well. 20 AAC 25.252 (c) (3) Appendix "A" contains an affidavit and certified mail receipts showing that the operators and surface owners within a one-quarter mile radius have been provided a copy of the application for disposal or storage; 20 AAC 25.252 (c) (4) Appendix " 2" ("PIONEER PROJECT, Request for Aquifer Exemption, Proposed Class II Waste Disposal, Well #1702 15AD WDW, Tyonek Formation, May 14 1999") contains geologic information pertaining to this application. It has been used to apply for the fresh water exemption under regulation 20 AAC 25.400. It discusses the name, description, depth, and thickness of the formation into which fluids are to be injected and container appropriate geological data on the injection zone and confining zones, including lithologic description and geologic name. 20 AAC 25.252 (c) (5) As discussed in the introduction section of ("PIONEER PROJECT, Request for Aquifer Exemption, Proposed Class II Waste Disposal, Well #1702 15AD WDW, Tyonek Formation, May 14 1999"), logs will be provided to the state after the disposal well (#1702 15AD WDW) is drilled. 20 AAC 25.252 (c) (6) (1) A description of the casing of the disposal or storage wells, or the proposed casing program and the proposed method for testing casing before use of the disposal or storage wells; See Attachment 1 "Drilling Program". 20 AAC 25.252 (c) (7) The primary purpose of the disposal well is injection of produced formation water with total dissolved solids expected to range from 3000ppm to 25000ppm. The fluids will be very similar in composition to those of the injection zones (Figure 8 in Appendix " 2"). Maximum rates would be 2000 BWPD/well. Other fluids which may be injected in minor volumes include drilling and completion fluids, workover fluids, equipment washdown, and drilling mud slurries. • • 20 AAC 25.252 (c) (8) The estimated average and maximum injection pressure will not exceed 900 psi surface pressure. 20 AAC 25.252 (c) (9) Evidence and data to support a commission finding that the proposed disposal or storage well will not initiate or propagate fractures through the confining zones which might enable the injection fluid or formation fluid to enter any freshwater strata; The maximum surface casing pressure will not exceed 900 PSI. Based on a fracture gradient of .7 and a hydraulic gradient of .433 and amid-perforation range of 3500', then: (.7 - .443) 3500 = 935 PSI 20 AAC 25.252 (c) (10) Actual analyses of the formation water from the potential injection zones is not available yet. However, produced Tyonek Formation water analyses from wells in the area and log analyses is included in Appendix " 2". Produced samples will be collected and analysed by a standard laboratory water analysis determination, or by an analytical method acceptable to the commission after drilling and completing the well. 20 AAC 25.252 (c) (11) Application for fresh water Exemption for the well location (in accordance with 20 AAC 25.440) was made on 5/14/99 and amended per EPA and AOGCC requests on 6/9/99, letter attached. 20 AAC 25.252 (d) (d) Mechanical integrity for disposal or storage wells drilled or converted to disposal or storage wells after the effective date of approval of the commission's program under 42 U.S.C. 300h-4 must be demonstrated according to 20 AAC 25.412 before operation. Mechanical integrity for all disposal or storage wells must be demonstrated by the operator by monitoring the pressure in the casing-tubing annulus during actual injection. The monitored annulus pressure must be reported monthly on the Monthly Injection Report (Form 10-406). Initial mechnical integrity tests will be performed in the following manner: Well will be pressured up to 1000 PSI for a minimum of 30 minutes. Monthly pressure monitoring of the injection wells will be reported on Form 10- 406. 20 AAC 25.252 (e) (e) If the casing-tubing annulus pressure subjects the casing to a hoop stress that exceeds 70 percent of the minimum yield strength of the casing, or if there is more than a 200 psi change in pressure between consecutive pressure readings, the commission must be immediately notified and commission-approved corrective action taken. Ocean Energy Resources will notify the AOGCC in the event that a 200 PSI change in pressure occurs. See Attachment "1" Drilling Program fo casing burst point and ratings. 20 AAC 25.252 (f) (f) The commission will, in its discretion, require additional mechanical integrity tests. 20 AAC 25.252 (g) (g) Modifications of existing or pending disposal or storage operations will be approved by the commission, in its discretion, under 20 AAC 25.507, upon application containing sufficient detail to .evaluate the proposed modification. No modification will be approved unless the applicant proves to the commission that the modification will not allow the movement of fluids into sources of freshwater. • • 20 AAC 25.252 (h) No wells within '/4 mile will have penetrated potential injection zones at the time the well is drilled. However, the Pioneer wells #1702-15DD and 1702-14CC will be permitted and drilled'/< mile (40 acre offset) from the injector (Figure 1). The operator will provide a report on the mechanical conditions of the wells in the normal reporting proceedures of drilling and completing new wells. The anticipated well bore mechanics is depicted in the APD Attachment "1" Drilling Program. The well will be completed so as to prevent the movement of fluids into sources of freshwater (which are estimated to exist above 500' MD). 20 AAC 25.412. CASING, CEMENTING AND TUBING OF INJECTION WELLS FOR ENHANCED RECOVERY, DISPOSAL AND STORAGE. (a) Wells that inject fluids for enhanced recovery of oil or gas, for disposal of non-hazardous oil field waste fluids, or for storage of liquid hydrocarbons, must be cased with safe and appropriate casing and be tubed to prevent leakage, and must be cemented to protect oil, gas, and freshwater sources. (b) A new well drilled for the injection of fluids must be cased, cemented, and pressure tested in conformance with 20 AAC 25.030. (c) An existing well newly converted for injection of fluids may not be operated before pressure testing the casing immediately exterior to the injection tubing string. The casing must be tested at a surface pressure of 1,500 psig or 0.25 psi/ft multiplied by the true vertical depth of the casing shoe whichever is greater, but must not subject the casing to a hoop stress that will exceed 70 percent of the minimum yield strength of the casing. If the pressure declines more than 10 percent within 30 minutes, corrective measures must be taken until a satisfactory pressure test is achieved. (d) Fluid injection wells must be equipped with tubing and packer, or other equipment which isolates pressure to the injection interval. The minimum burst pressure of the tubing must exceed the maximum surface injection pressure by at least 25 percent. (e) Sufficient notice of pressure tests required by (c) must be given so that a representative of the commission may witness the test. (Eff. 4/2/86, Register 97) Authority: AS 31.05.030 • AFFIDAVIT OF MAILING Pioneer Unit # 1702-15DA WDW Operator List T,~ Ocean Energy Resources Inc., is the only operator with-in a'/4 mile radius of the proposed well. Surface Owners See Attached Table 1 On June 24, 1999, the persons Listed on tre attached "Table 1" were notified by cel-tified mail of an application for disposal in the Pioneer Unit #1702-1SDA. Si ned: -"'- ~~~ ~% I = Date: June 24 1999 Scott M. Webb, Regulatoly° Coordinator State of Colorado County of Denver Signed and sworn before me this 24th day of June, 1999, b~ ~ ,_ Deb J~ Tack, Notary Public ~ .. ~` My Commission Expires: July 30, 2001 _. Ocean Energy Resources, Inc. Amorn Building 1670 Broadway, Suite 2800 Denver, Colorado 80202 (303) 308-8500 Fax: (303) 308-8510 • TABLE 1 Surface Owners '/4 Mile Radius Thomas Grace P.O. Box 61508 Vancouver, WA 98666 John F. & Sara K. Wiber P.O. Box 878804 Wasilla, AK 99687 Miguel Nazario-Acosta P.O. Box 875284 Wasilla, AK 99687 Linda L. Medieros P.O. Box 872912 Wasilla, AK 99687 J. C. Page P.O. Box 872573 Wasilla, AK 99687 Robert B. Pace 3510 Evergreen St Anchorage, AK 99504 Craig A. & Shirley Thompson 3957 Pinyon St Springfield, OR 97478 Charles L. Mowrer P.O. Box 770647 Eagle River, AK 99577 Jake Marquez P.O. Box 874526 Wasilla, AK 99687 Joan I. Markle 3575 N. Brookside Ln Boise, ID 83703 • Matthew V. Kiviaho 17006 Calle Del Flores Fountain Hills, AZ 85268 Paul, Wm A. & AJ Daniel 6034 SE Alderhill Lp Milwaukie, OR 97267 Douglas N. Hotes 1800 W Hoteco Ave Anchorage, AK 99502 Dallas & Caren M. Smith P.O. Box 671 Palmer, AK 99645 Jim Contreras P.O. Box 672068 Chugiak, AK 99567 Ralph T. Berg 3750 Grey Wolf Dr Wasilla, AK 99564 Mark A. & Sharon A. Jackson P.O. Box 878317 Wasilla, AK 99687 SENDER: I also wish to receiv the follow- 'w y ^ Complete items 1 and/or 2 for additio~ices. ing services (for a~a fee): y Complete items 3, aa, and ab. ^ Print your name and address on the reverse of this farm so that we can return this card to you.. 1. ^ Addressee's Address d ^ Attach this form to the Iront of the mailpiece, or on the back if space does not R i d D li 2 ~, permit. estr cte e very • ^ t ^ Wrile 'Return Receipt Requested'on the mailpiece below the article number. ~ ^ The Return Receipt wdl show to whom the article was delivered and the date o delivered. ~ 3. Article Addressed to: 4a. Article Number Z -- 407- ~B/- 7~6 a ~ Linda L. Nledieros 4b. Service Type ,~.,,,, ~~ rtifi ^ R i d P.O. BOx 372912 eg stered t~;e e cq w Wasilla, AK 99687 ^ Express Mail ^ Insured ~ ^ Return Receipt for Merchandise ^ COD a 7. Date of Delivery Z tr ~ 5. Received By: (Print Name) 8. Addressee's Address (Only if requested and w fee is paid) ~ 6. Signature (Addressee or Agent) 0 a PS Form 3811, December 1994 102595-99-8-0223 Domestic Return Receipt d SENDER: I also wish to receive the follow- ~ 'y ^ Complete items 1 and/or 2 for additional services. ing Services (for an extra fee): y Complete items 3, aa, and ab. ^ Print your name and address on the reverse of this form so that we can return this ai ~ card to you. 1. ^ Addressee's Address .~ ~ ^ Attach this form to the front of the mailpiece, or on the back if space does not 2• ^ Restricted Delivery ~, permit. ^ Write 'Return Receipt Requested' on the mailpiece below the article number. ~ ^ The Return Receipt will show to whom the artcle was delivered and the date t1 p delivered. 3 6. Signature (Addressee or Agent) 0 a y ai U .~ in o. .~ U cn c `o 0 ~, Y c m r i- ~ 3. Article Addressed to: 4a. Article Number z-yon-~s~-~~~ ~ ~ E ~ Thomas Grace 4b. Service Type ~~ /~ ifi d R ,~~, ~ v, P.O. Box 6108 ^ egistered L.~Cart e rn w Vancouver WA 98666 ^ Express Mail ^ Insured .N , ^ Return Receipt for Merchandise ^ COD o C e 7. Date of Delivery w = 0 a 5. Received By: (Pont Name) 8. Addressee's Address (Only if requested and fee is paid) ~ PS Form 3811, December 1994 102595-99-B-0223 rn Receipt SENDER: I also wish to recero he follow- 'w ^ Complete items 1 and/or 2 far additior>~ices. ing services (for a~ fee): ~ Complete items 3, 4a, and 4b. ^ Print'your name and address on the reverse of this form so that we can retum this ~ card to you. 1. ^ Addressee's Address m ^ Attach this form to the front of the mailpiece, or on the back if space does not permit. z• ^ Restricted Delivery r ^ Write 'Return Aeceipt Requested' on the mailpiece below the amcle number. ~ ^ The Return Receipt will show to whom the article was celivered and the date p delivered. D 3. Article Addressed to: a ~ sta. Article Number Z- L~o7- ~~~ X83 E Paul, Wm A. & AJ Daniel ' 4b. service Type ~ 6034 SE Alderhill i,p ^ Registered mortified w Milwaukie, OR 972b7 i ^ Express Mail ^ Insured C i ^ Return Receipt for Merchandise ^ COD a 7. Date of Delivery 5. Received 8y: (Print Name) 8. Addressee's Address (Only if requested and fee is paid) ~ 6. Signature (Addressee or Agent) 0 a PS Form 3811, December 1994 to2595-99-8-0223 Domestic Return Receipt U .~ rn a .~ U m m N `o 0 a c m t a 3. Artlcte Addressed to: ~ ~ 4a. Arttcle Number ~-~{0~-~81- 78~f Q Jake Marquez 4b. Service Type ^ Registered 2rtifiied ~ w P.O. Box 874526 ^ Express Mail ^ Insured Wasilla, AK 99687 ^ Retum Receipt for Merchandise ^ COD a 7. Date of Delivery z ?„ 5. Received. By: (Print Name) 8. Addressee's Address (Only if requested and ~ fee is paid) 0 6. Signature (Addressee or Agent) T y ____. _ ___.___ ~• ~ er SENDER: I also wish to receive the follow- ~w ^ Complete items 1 and/or 2 far additional services. ing services (for an extra fee): m Complete items 3, 4a, and 4b. ^ Print your name and address on the reverse of this forth so that we can return this card to you. 1. ^ Addressee's Address m p Attach this form to the front of the mailpiece, or on the back if space does not ermit 2• ^ Restricted Delivery p . ^ Write 'Aetum Aeceipt Aequesred' on the mailpiece beww the article number. ^ The Retum Receipt will show to wham the article was celivered and the date p delivered. PS Form 3811, December 1994 102595-99-i3-0223 Receipt SENDER: I also wish to receive the follow- ^ complete Gems ~ and/or 2 for additional services. ing services (for an extra fee): Complete items 3, 4a, and 4b. ^ Print your name and address on the reverse of this form so that we can retum this card to you. 1 • ^ Addressee's Address ^ Attach this form to the front of the mailpiece, or on the back if space does not i 2• ^ Restricted Delivery pem, t. ^ W rite 'Aetum Receipt Aequesred' on the mailpiece below the article number. ^ The Retum Receipt will show to whom the article was delivered and the date delivered. 3. Article Addressed to: 4a. Article Number Robert B. Pace 3.510 Evergreen St Anchorage, AK 99504 5. Received By: (Print Name) 6. or Agent) Z -- ~{0 7 - ~~~ 1 7 8S 4b. Service Type ^ Registered ertified ^ Express Mail ^ Insured ^ Return Receipt for Merchandise ^ COD 7. Date of Delivery 8. Addressee's Address (Only it requested aria lee is paid) PS Form 3811, December 1994 to2595-99-B-0223 Domestic Return Receipt U .~ `m N a .~ U 41 tx rn c N `o 0 Y c m f- w SENDER: ^ Complete items 1 and/or ~ditional services. I also wis eceive the follow- ing servit~r an extra fee): ' N Complete items 3, 4a, and ^ Print your name and address on the reverse of this form so that we can return this ~ ~ card to you. 1. ^ Addressee's Address = ^ Attach this form to the hunt of the madpiece, or on the back if space does not permit 2• ^ Restricted Delivery ;' ~, . ^ Write 'Return Receipt Requested' on the madpiece below the article number. ~ e ^ The Return Receipt will show to whom the article was delivered and the date a . o delivered. ~ ~ 3. Article Addressed to: 4a. Article Number ~ a o John F. & Sara K Wiber 4b. Service Type ~, ~ . P O BoX 878804 ^ Registered (~'>'ertified ~ w . . Wasilla, AK 99687 ^ Express Mail ^ Insured S .N ~ ^ Return Receipt for Merchandise ^ COD J ~ a 7. Date of Delivery z - c ~ T ~ 5. Received By: (Punt Name) 8. Addressee's Address (Onty if requested and c w fee is paid) t t... ~ 6. Signature (Addressee or Agent) 0 a rn PS Form 3811, December 1994 to2sss-ss-a-oz2s Domestic Return Receipt d .Q SENDER: I also wish to receive the follow- 'N ^ Complete items 1 and/or z for additional servces. ing services (for an extra feej: y Complete items 3, aa, and 4b. _ ^ Prim your name and address on the reverse of this form so that we can return this 4j - - ~ card to you. 1. ^ Addressee's Address -° .. .. d ^ Attach this form to the front of the mailpiece, or on the back if space does not 2• ^ Restricted Delivery ermit ~ ~, p . ^ W rite "Aetam Receipt Requested' on the ma,lpiece below the article number. to ~ ^ The Return Receipt will show to whom the article was delivered and the date a . o delivered. ~ ~ 3. Article Addressed to: 4a. Article Number ~ / ~ Mark A. dz Sharon A. Jackson 4b. Service Type y P .O. Box 878317 ^ Registered G'fiLe ified ~ w Wasilla, AK 99687 ^ Express Mail ^ Insured ~ ^ Return Receipt for Merchandise ^ COD ~ a 7. Date of Delivery 0 ¢ ~' ~ 5. Received By: (Print Name) 8. Addressee's Address (Only if requested and c w lea is paid) t ~ 6. Signature (Addressee or Agent) 0 a N PS Form 3811, December 1994 ta2sss-ss-e-o223 Domestic Return Receipt a Jim Contreras 4b. Service Type ,._.~ rtifi d ^ R ~, P.O. Eox 672068 e egistered I~;e w Chu~iak, AK 99567 ^ Express Mail ^ Insured ^ Return Receipt for Merchandise ^ COD ~ a 7. Date of Delivery ~ 5. Received By: (Print Name) 8. Addressee's Address (Only if requested and w fee is paid) ~ SENDER: I also wish to receive the follow- 'y ^ complete items tand/or 2 for additional services. ing services (for an extra fee): y Complete items 3, 4a, and ab. ^ Print your name and address on the reverse of this form so that we can return this card to you. 1. ^ Addressee's Address d ^ Attach this form to the front of the mailpiece, or an the back if space does not ~, pem,a. 2• ^ Restricted Delivery t ^ Write 'Return Receipt Aequesred' on the mailpiece below the aside number. ~ ^ The Return Receipt will show to whom the artide was delivered and the date a delivered. a 3. Article Addressed to: 4a. Article Number a ~ 6. Signature (Addressee or Agent) 0 a PS Form 3811, December 1994 tozsss-ss-a-oz2a Domestic Return Receipt ai U .; a .~ U N c m m c .~ o` 0 T Y c L H d II ~ SENDERr I also wish to r ceive the follow- N ^ Complete items tand/or 2 for nal sernces. Ing SeNIC@S n extra fee): N Complete items 3, aa, and ab.• ^ Print your name and address on the reverse of this farm so that we can return this ~ card to you. t . ^ Addressee's Address m p Attach this form to the Iront of the mailpiece, or on the back if space does not permit. 2• ^ Restricted Delivery O Write 'Return Receipt Requested' on the mailpiece below the article number. e ^ The Return Receipt will show to whom the art~de was delivered and the date p delivered. a °' 3. Article Addressed to: 4a. Article Numb-e7r /~ Z'~0 ! ~ Yr~~ - 777 a E 4b. Service Type Miguel Nazario-Acosta ^ Registered C~!'Cartified ~ P.O. Box 875234 ^ Express Mail ^ Insured ~ WaSilla, AK 99687 ^ Return Receipt for Merchandise ^ COD n a 7. Date of Delivery Z 6. Received By: (Print Name) 8. Addressee's Address (Only if requested and w fee is paid) ~ 6. Signature (Addressee or Agent) 0 a PS Form 3811, December t 994 tozsss-ss-a-ozz3 Domestic Return Receipt a SENDER: ~in ^ Complete items tand/or 2 for additional services. N Complete items 3, aa, and 4b. p Print your name and address on the reverse of this form so that we can return this ~ card to you. ~ ^ Attach this form to the front of the mailpiece, cr on the back if space does not y permit. ^ W rite 'Return Receipt Requested' on the mailpiece below the article number. ~ ^ The Return Receipt will show to whom the amde was delivered and the date o delivered a. .~ U 7g ¢ '~ 3. Article Addressed to: 4a. Article Number z - ~0 7- 4~8/- Craig A. & Shirley Thompson 3957 Pinyon St Springfield, OR 97478 7. Date of Delivery ~ 5. Received By: (Print Name) t- w ~I ~ 6. Signature (Addressee or Agent) 0 a 0 requested and m L H PS Form 3811, December 1994 tozsss-ss-a-ozz3 Domestic Return Receipt m SENDER: I also wish to receive the follow- a w ^ Complete items tand/or 2 for additional services. ing ServiC@S (for art extra fee): m Complete items 3, 4a, and 4b. ^ Print your name and address on the reverse of this form so that we can return this °' care to you. t • ^ Addressee's Address ^ Attach this form to the front of the mailpiece, or an the back if space does not 2• ^ Restricted Delivery t permit. ^ Write 'Return Receipt Requested' on the mailptece below the article number. ~ ^ The Return Receipt will show to whom the article was delivered and the date a delivered. '~ 3. Artiefe Addressed to: 4a. Article Number Z_~ot_ ~~/-~7q a E e Pa C J 4b. Service Type g . . ^ Registered Certified ~ P.O. BoX 872573 ^ Express Mail ^ Insured ~ Wasilla, AK 99687 ^ Return Receipt for Me rchandise ^ COD n n a 7. Date of Delivery Z 5. Received By: (Print Name) 8. Addressee's Address (Only if requested and. fee is paid) ~ 6. Signature (Addressee or Agent) a T N PS Form 3811, December 1994 702595-99-8-0223 Domestic Return Receipt 4b. Service Type ~ ^ Registered ~ertified ~ ^ Express Mail ^ Insured ~ N ^ Return Receipt for Merchandise ^ COD `o 8. Addressee's Address tee is paid) ai to o. .~ U m c rn c N `o 0 T Y c m I- I also wish to receive the follow- ing services (for an extra fee): ai 1. ^ Addressee's Address 2. ^ Restricted Delivery d ai U .j d a .~ U d IL m tr rn c .y `o 0 T Y c m L I- SENDER: 'y ^ Complete items 1 and/or 2 fo~onal services I also wish t eive the follow- ing services~n extra fee): N . Complete items 3, Sa, and 4b. ^ Print your name and address on the reverse of this form so That we can return this ai ~ card to you. 1. ^ Addressee's Address ~ ` ^ Attach this form to the front of the mailpiece, or on the back it space does not it 2. ^ Restricted Delivery ~, perm . ~ ~ Write 'Return Aecerpt Requested' on the mailpiece below the article number. ~ ^ The Return Receipt will show to whom the aniGe was delivered and the date ea p delivered. ~ U ~ 6. Signature (Addressee or Agent) a ~r 3. Article Addressed to: 4a. Articl ~iui~ e~ - / y ~ ~ ' ~ 7 ~ ~ ~ Z '7 '7 ~ f ~ t 4b. Service Type ~ Dallas & Caren .r,. St;tith ^ Registered mortified ~ uP.O. BOJC 671 ^ Express Mail ^ Insured u Palmer, ATE 996~+~ .N ~ ^ Return Receipt for Merchandise ^ COD C ~ 7. Date of Delivery ~ a ~, ~ 5. Received By: (Print Name) 8. Addressee's Address (Only if requested and c w fee is paid) L H - - __ PS Form 3811, December 1994 to2595-49-8-0223 Domestic Return Receipt PS Form 3811, December 1994 702595-99-8-0223 Domestic Return Receipt m .o SENDER: I also wish to receive the follow- 'H ^ complete items ~ and/or z for additional services. ing services (for an extra fee): ~ Complete items 3, sa, and ab. ;n ^ Print your name and address on the reverse of this form so that we can return this ai ~' card ro you. 1 • ^ Addressee's Address °- m ^ Attach this form to the front of the mailpiece. or on the back if space does not i 2• ^ Restricted Delivery :, ~, t perm t. ^ Write 'Return Receipt Requested' on the mailpiece below the article number. ~ ~ ^ The Return Receipt will show to whom the artiGe was del ivered and the date Q. p delivered. d U m 3. Article Addressed to: 4a-.7Article Number / ~ / ~7 L~ ~ ~~7 t'f"e~! -/ ~~ °' 2 a E 4b. Service Type 'r ~, ~ Matthew V. KiViaho ^ Registered ~rtified ~ ran 17006 Celle Del Flores ^ Express Mail ^ Insured °1 ~ ~ Fountain Hills, AZ 35268 ^ Return Receipt for Merchandise ^ COD = C p ~ 7. Date of Delivery z ,, ~ 5. Received By: (Print Name) 8. Addressee's Address (Only if requested and ~ w lee is paid) m = 1 ~ 6. Signature (Addressee or Agent) 0 T N SENDER: y ^ Complete items 1 andtor 2 for additional services. a~ Complete items 3, da, and 4b. ;n ^ Print your name and address on the reverse of this farm so that we can return this ~ card to you. ` ^ Attach this form to the front of the mailpiece, or on the back if space does not ~ permit. Y ^ Write 'Return Receipr Requested' on the mailpiece below the article number. ~ ^ The Return Receipt will show to whom the article was delivered and the date p delivered. a 7. Date of Delivery Z ~ 5. Received By: (Print Name) 8. Addressee's Adt w fee is paid) 0 6. Signature (Addressee or Agent) ~. I also wish to receive the follow- ing services (for an extra fee): 1 • ^ Addressee's Address 2. ^ Restricted Delivery ~ 3. Article Addressed to: 4a. Article Number ~ - rev ~ - ~F~ ~- 7 ~6 a E 4b. Service Type ~~ Charles L. Mowrer ^ Registered L!fGertified P.O. Box 770617 ^ Express Mail ^ Insured Q Eagle River, AK 99577 ^ Return Receipt for Merchandise ^ COD if requested and PS Form 3811, December 1994 102595-99-8-0223 Domestic Return Recetp ai U i a`~ a. .~ U Ol ix c N 3 `o 0 T Y c m f- ~. v SENDER: I also h to receive the follow- N p Complete items 1 an~or additionaf services. ing s~s (for an extra fee): d Complete items 3, aa, ab. y ^ Print your name and address on the reverse of this form so that we can return this ~ card to you. 1 ^ Addressee's Address d ^ Attach this form to the front of the mailpiece, or on the back if space does not ^ Restricted Delivery 2 ~ permit. • L ^ Write 'Return Receipt Aequasted' on ;he mailpiece below the article number. c ^ The Return Receipt will show to whom the article was delivered and the date o delivered. '~ 3. Article Addressed to: 4a. Article Number ~ 107- ~ ~/ - 7 7/ a E 4b. Service Type Ralph T. Berg ^ Registered artified ~ 3750 Grey Wolf Dr ^ Express Mail ^ Insured ~ Wasilla, AK 99564 ^ Return Receipt far Merchandise ^ COD D n a 7. Date of Delivery Z ~ 5. Received By: (Print Name) 8. Addressee's Address ("Only if requested and w fee is paid) ~ 6. Signature (Addressee or Agent) 0 ~+ N PS Form 3811, December 1994 102595-99-8-0223 Domestic Return Receipt ~ ~ 3. Article Addressed to: 4a. Article ,Number z -- Zf~7 `' ~ ~r.3~'" 7 7Z C ~ Douglas N. Hotel 4b. Service Type ^ Registered ~ertified 1800 W HOteCO AVe ^ Express Mail ^ Insured w ~ Anchora e AK 9950? ~ , ^ Re[um Receipt for M erchandise ^ COD C C C 7. Date of Delivery Z ~ 5. Received By: (Print Name) 8. Addressee's Address (Only if requested and w fee is paid) 6. Signature (Addressee or Agent) 0 a m PS Form 3811, December 1994 102595-99-8-0223 Domestic Return ReceiF a SENDER: I also wish to receive the fouow- 'N ^ complete Gems tand/or z for additional serv;ces. ing services (for an extra fee): m Complete items 3, aa. and 4b. w ^ Print your name and address on the reverse of this form so that we can return this ~' card to you. 1 ^ Addressee's Address ^ Attach this form to the front of the maiipiece, or on the back if space does not 2• ^ Restricted Delivery ~, permit. ^ Wdte 'Return Receipt Aequasted' on the mailpiece below the article number. C ^ The Return Receipt will show to whom the article was delivered and the date a delivered. ai rn n. .~ U m c .N `o 0 T Y c m r F- ai `m N C .~ U tr c 3 cn c .y `o 0 T Y c L F-' a SENDER: I also wish to receive the foltow- .y ^ Complete items 1 and/or z for additional services. ing services (far an extra fee): d Complete items 3, aa, and 4b. ~ p Print your name and address on the reverse of this form so That we can return this ~ card to you. 1 • ^ Addressee's Address m p Attach this forth to the front of the mailpiece, or on the bade if space does not 2• ^ Restricted Delivery ~, t permit. ^ Write 'Rerum Receipt Aequested' on the mailpiece below the article number. ~ ^ The Rerum Receipt will show to whom ;he article was delivered and the date p delivered. a ~ v 3. Article Addressed to: 4a.Z icle Nu ~ ~ _ Gf ~ ~ ~ _ ~ 73 a E loan I. Markle 4b. Service Type ~ 3575 N. Brookside Ln ^ Registered ^ Certified N BOtse, ID 53703 ^ Express Mail ^ Insured w ^ Return Receipt for Merchandise ^ COD 0 7. Date of Delivery Q Z 5. Received By: (Print Name) 8. Addressee's w fee is paid) ~ 6. Signature (Addressee or Agent) 0 T PS Form 3811, December 1994 to2sse-ss-e-oz23 (Only if requested and ai U .j m rn a U d c d tt rn c .~ a vt, ~. 3 D Y C ~ m L f- ` rte r ~..~ . „~,5z • 1I11~OC~1~.76 D. T. Seamount Senior Advising Geologist Business Ventures June 9, 1999 Robert P. Crandall Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Amendment to Application for Freshwater Aquifer Exemption Pioneer Coal Bed Methane Project Proposed Class it Waste Disposal Well #1702 15AD WDW Mat-Su Borough, AK Dear Mr. Crandall, In response to your recommendations regarding Unocal's Application for Freshwater Aquifer Exemption for the proposed Class II Waste Disposal Well #1702 15AD WDW May 12, 1999), the following modifications and additional information are: • The location of the proposed Class II injector well is in the NESE section 15- T17N R2W (Attached map). • Locations of nearby water wells and the proposed test wells are shown on the attached map. A baseline study of water wells surrounding the in immediate area (>1/2 mile radius) will be performed by a third party geo-technical firm. • The proposed injection interval is changed from "1500' to 4000" to "below 2500". This will result in an additional 1000' of separation between the base of the fresh water aquifers at approximately 500' and the proposed injection zones (Attached cross-section B-B'). The injection zones will be confined by a 270' thick shaley interval present from 2520' to 2790' in the ARCO BLT #1 (Figure 8 in original application dated may 12, 1999) • Produced water samples from the potential injection zones will be analyzed for Total dissolved solids concentrations after the injection well is drilled, logged, cased, and perforated Very truly yours, • • D. T. S'eamount Senior Advising Geologist • Submitted by • UNOCAL za! PIONEER PROJECT Request for Aquifer Exemption Proposed Class II Waste Disposal Well #1702 15AD WDW Tyonek Formation May 14 1999 Tim Brandenburg- Drilling Dan Seamount- Geology Faye Sullivan- Environmental ~1iCl~AL: 76 D. T. Seamount Senior Advising Geologist Business Ventures May 14, 1999 Robert P. Crandall Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Application for Freshwater Aquifer Exemption Pioneer Coal Bed Methane Project Proposed Class II Waste Disposal Well #1702 15AD WDW Mat-Su Borough, AK Dear Mr. Crandall, Unocal, in accordance with the requirements of 20 AAC 25.440, herein submits an "Application for aquifer Exemption" for a single class 11 waste disposal well, Pioneer #1702-15DA WDW on State oil and gas Lease ADL 374117 within the Pioneer Unit. The surface Owner is Joan I. Markle. The approximate location is 1500' FSL & 515' FEL of Section 15, T17N, R2W. It is anticipated that well drilling will be initiated around July 15, 1999 in order to comply with unit obligations. The injection zones exist as permeable sands and conglomerates at depths between 1500' and 4000' within the Tyonek Formation. The zones correlate with those at similar depths in the ARCO BLT #1 (located approximately 6 3/4 miles to the west) which range in salinity from 3000ppm to 10000ppm. The specific injection intervals will be identified after the well has been drilled and log analyses indicate that the aquifers meet the criteria for exemption as specified in both the State and Federal regulations (CFR 40 146.4 and 20 AAC 25.440). Unocal respectfully requests that aquifer exemptions be granted for the Pioneer Unit Well #1702-15DA-WDW. An application for underground injection (regulation 20 AAC 25.252) will soon follow. Very truly yours, D. T. Seamount Senior Advising Geologist • • Geologic Data For Freshwater Aquifer Exemption Tyonek Formation Pioneer Unit Well #1702 15AD WDW I. Introduction Union Oil Company of California, d.b.a. Unocal, plans to test the coal bed methane potential (CBM) of the Pioneer Unit in northern Cook Inlet (Figure 1). The project will target numerous coal seams in the Tertiary Tyonek Formation (Figure 2). The subsurface geology and coal bed methane (CBM) potential of the unit is described in Seamount et al. (1997). The entire three year exploratory phase of the project is described in the "Pioneer Unit Plan of Operations" (1999) and the "Pioneer Unit -Vine Extension Plan of Operations" (1999). Since CBM wells commonly produce large initial quantities of water (up to 500BWPD anticipated) ,safe methods of disposal must be planned. Pioneer well #1702-15DA- WDW is planned to be drilled this summer as a class II Waste disposal well to handle fluids and drilling wates from test wells to be drilled nearby (Figure 3). Operations are expected to begin on approximately July 15, 1999. Testing of the first few wells may continue for up to 18 months. It is of utmost importance to identify the entire stratigraphic section containing all of the potential fresh water acquifers. Then, they can be protected through safe cementing and casing designs of both producers and disposal wells. State of Alaska regulation "20 AAC 25.440." requires that application for a fresh water aquifer exemption is required if the potential disposal zones contain fluids between 3000ppm and 10,000ppm TDS. Through exploration well tests and log analyses, it will be shown that: • Zones within the Tyonek section between 1500' and 4000' contain fluids within those limits. • The base of the potable water section (<500ppm) is at depths above 1000'. • Adequate confining layers exist between the potable water section and any potential disposal zones below 1500'. • The salinities of the injected fluid will be similar to the salinities of the fluid in the injected zone. Confirmation of the suitability of any potential injection zones will be made after drilling and logging the disposal wells. The following information is intended to show that for Pioneer well #1702 15AD WDW, permeable zones within the Tyonek Formation below 1500' qualify for a Freshwater Aquifer Exemption in accordance with 20 ACC 25.440. • • FIGURES Figure 1-Pioneer Unit Location Map Figure 2- Stratigraphic Chart of Cook Inlet Figure 3- Pioneer Unit Geography and Well Locations Figure 4- Water Table Contour Map, Pioneer 1702-15DA WDW Area Figure 5- Water Well Location Map- Well # 1702-15DA WDW Area Figure 6- Log Curves and TDS Analyses of DST'd zone- Horseshoe Lake State #1 Figure 7- Log Curves and TDS Analyses of Kick Zone- American Quasar Big Lake #1 Figure 8- Wireline Log and Salinity Curves of BLT #1 (in pocket) Figure 9- Map of B/ Glacial/fresh water Includes deep water wells (Large copy in pocket) Figure 10- Cross-Section A-A' (in pocket) Figure 11-Cross-Section B-B' TABLES Table 1- Pioneer Proposed Wells Table 2- Deep Water Well List Table 3- Exploration Well List Table 4- Exploration Well Tests Table 5- -Log Curves and TDS Analyses of DST'd zone- Horseshoe Lake State #1 Table 6- -Log Curves and TDS Analyses of Kick zone- American Quasar Big Lake #1 Appendix 1- Pioneer #1702-15DA WDW Area Water Wells Appendix 2- Geochemical Analyses & Test Data From the Horseshoe Lake State #1 & American Quasar Big Lake #1 • Appendix 3- EPA Log Analyses Method to Determine Total Dissolved Solids Concentrations C4~K INLET BASIN ~~a~~~~ ~~c~~~~~~r CO~.L BED METHANE POTENTIAL /, rrea.nt l~<~t~ii Sti.id~• t 1, / ."` --..~. ~ t-T t~ 41 S"t`C")N ~ 1 ~ t ~sJLLn ~ .~'`~ i ~ ~ ,,~ ~i~~TAl~T.T~~ ~ ~: ,~ ; V:~LLEY ': ~ ~ ~ ~ ~ ;:,;~ rf~c~-- ~ ~~ ~~ . • • ~~``' s ~y l -; ~ ,, i ~F,?dtt E 1"11 r ~ 'qq~yy ~r.c.-~". *J +~ PENSULA ~~ t~~L~s ~4tx i r'~~e~ts ot'I-~igliest ~'~ _. j • ti~eli~ «itla Coal [~as~k Co1~t~~ol 1 t~~_rtc~"o~ S~z7~plc.:s ~s-it.h G'T. Area of ifighest Potential ~„ Ht-l kiF. R Figure 1- The Pioneer Project is located in the northern Cook Inlet `s Matanuska Valley. • AGE LITHOLOGIC TYPE PRODUCING ZONES MT. ,~„ "CQi T A I SYSIEN SERIES UNITS """~ LOG 09AASSOCWTED GAS f1ELD5 Ut`WSSOCWiED GAS FIELDS . . . Q 7 ? ~{aciat ~l 0-4500' i i I ~ I i I ~ i ~ ' ~ I RECEM ~ 1 t :4 S f ~ ~ ` ~~ ~ ~~ ~ ~ j EISfOCENE EC if7tGrl S g K , P z ~i's f 0-6300' ~- l i 5 PLIOCENE ~ ', ' i ~ ', Li I ' i l i STERLING ~ - _ ; I FM Y _" T ~~q~~ Sondsime z _ ~ I I ~ ' i~ ttii.~t~~ i I ,.., - I I I ~~~ E I R a ~ ~ 4 0 900 BELUGA ~ z I ~ Ii I ~ ~ I j MOCENE Uf FM ~ I ~',. ~. ! ~ T Q -. I ~ ~, ~ I I I . z .'FAN I I w FACIES" ~ I I ' ' i Y 1000-10,00 ~T i I < S ~~ R ~ ~ 'I ~I I ~~ ', ~ I ~ i TYONEK _ a ~ ~, ' i Y FM ~ ~ ' I' ~ I~ ,~ Sondefaie. ~ I ~ I Concjanerob '7'^: , 1 SmdStme. 1 9 9islona ', Shde ~ j i Cod ~ ~ 1]5 ~ ~ ii ..:~ ~ I I I I I I I I fll r OLIGOCENE ~ II -. ', I I '~ o-vo0' a" ~ ? ~~ ~ ~ i l C HEM.OC1(CGI. t t. 7 y~ HEM.OCIC SHALE 3 ?I ? ~ (, I ~ I ~.. - ~ ~ I ~ ~ - ]5 EOCENE 0-600' WEST FCREIANO FN ~ a ( ~ ~ ~~ ... ~ ~ j ~ ~~ ~l i ~ 1 ~ ~ ~ i I I ', PALEOCENE 0-2000' CHICKALCON FN ~ I ~ i I ' ' I ';,. i, I m ~~ roim n w UNDIFfERENMTED . e ~ NWiME SEDIM:NTS AND vacaN~cs Figure 2: Stratigraphic Chart of Cook Inlet r~ z ~"' Z '~ z c C r r i-7 ^'C • i Location of Proposed Well and Proximity to Well Control The Pioneer Unit outline and the well location for the Class II Disposal Well- Pioneer #1702-15DA WDW and the proposed test Wells are shown in Figure 3. Houston, Alaska is located on the western edge of the unit and Wasilla is located on the southeast edge. Residential use of the area is sporadic. Elevation of the well location is approximately 300' above sea level. The topography is somewhat irregular due to past glacial events. The disposal well specifics are as follows: Pioneer # 1702-15DA WDW State Lease ADL 374117 Surface Owner: Joan I. Markle Land: Approx. 1500' FSL, 515' FEL of Section 15, T17N, R2W Proposed Total Depth 4,000' r,~_ *,~ ~ ~ ~~~.~ Surface Hydrology and Fresh Groundwater Water wells in the unit area typically tap the water table; they do not drill through the water column. Figure 4 is a portion of regional water table maps (Montgomery, 1990) of the Palmer to Big Lake area which pertain to the proposed wells in the project. They indicate that the depth to the aquifer is very shallow throughout the unit area and basically follows the topography ranging from sea level to 800'+ from SW to NE. They also show that ground water flow is generally to the SW. Most of the lake surfaces define the top of the water table. The estimated elevation and depth to fresh water for the proposed disposal well are 300' and 35 feet respectively. The depth to fresh waterwas estimated from regional mapping (Figure 4 from Montgomery, 1990) and local water well drilling depths (Table ~'~ i~f ~. x '"iJ, ~ ~ Appendix 1 and Figure 5). The regional maps often show that the main water table at the locations are deeper than some water well total depths. The shallower depths to fresh water are possibly indicative of wells which tapped confined or semi-confined aquifers. The Division of Mining and Water Management identified 10 water wells with depths greater than 400 ft (Table 2) that were located within four miles of the unit boundary. The deepest total depth for a fresh water well is 605 ft. While water well data can be used to estimate the depth to the top of the aquifer, no water wells were identified which drilled completely through the fresh water column. Therefore, the fresh water/brackish (3000ppm to 10,000ppm TDS) water transition zone cannot be determined by examining only water well information. Salinity Evaluation/Depth to Base of the Fresh Water Section Wireline and mudlog data from 31 deep oil and gas exploratory wells (Table 3) and produced water analyses from two wells (Appendix 2) within a 48 township study area were analyzed to help determine the depth to the base of the fresh water. Rwa Method In the absence of reliable laboratory water analysis data, electric logs provide the means to discriminate between freshwater sands and those that contain saltwater. Because the total dissolved solids (TDS) content (salinity) of fresh water is relatively low, it is a poor electrolyte that exhibits high resistivity. Conversely, if the water is more saline, it conducts electricity better and its resistivity is lower. Within permeable rocks, resistivity is a function of temperature, porosity, and water salinity. The "Rwa" method (Appendix 3) described in EPA publication "Survey of Methods to Determine Total Dissolved Solids Concentrations" relates formation water salinity to those parameters. The method generally underestimates the actual salinity of formation fluid and, therefore, helps to insure that potential disposal zones are in compliance with regulation "20 AAC 25.440". Fluid Recovery from Deep Wells Very few of the deep exploration wells were tested. The locations of the wells are shown in Figure 3. Fluid was recovered from only 15 tested zones in five wells and one zone in a well which kicked (flowed into the well bore) while drilling (Table 4). Furthermore, chemical analyses of the fluid exist for only three of the zones. Most of the other fluid recoveries were described as "salt water". Of the three analyzed zones, fluid recovered from the Horseshoe State #1 Well from 4246' to 4310' was probably not formation fluid, but was fresher mud filtrate used in the drilling operations. The recovery was described as "354' of water cut • • drilling mud". The other two analyzed fluids were probably true formation fluids, which were contaminated (diluted), somewhat by the fresher drilling muds. The probable result was in measured salinity being lower than true formation salinity. The two zones were from 1870' to 1930' where a "kick" occurred in the American Quasar Well Big Lake #1 and from 2950' to 3084' in the Great Plains Horseshoe Lake State #1 Well. The "Rwa" method was used to calculate TDS salinity of the two zones (Figures 6 & 7) using porosities derived from three different curves- density, density/neutron crossplots, and sonic travel time. The results were compared with the actual measured salinity (Tables 5 & 6). It was found that using the sonic derived porosity gave the best match with the measured data. Higher salinity was calculated using density and density/neutron derived porosities. Most likely, the density/neutron-derived salinity is the most accurate and the lower measured salinity is due to fresh drilling mud contamination. However, the sonic derived salinity was used in the area evaluation to remove any doubt about a potential disposal zone's regulatory compliance. Salinity Evaluation of the Section to be Drilled A salinity curve was generated for the ARCO BLT #1 well (Figure 8) using the "Rwa/sonic" method. The analysis indicates that the base of the fresh water can be identified at 534' were there is a marked decrease in ILD resistivity of permeable zones from >50 ohm-m to <20 ohm-m. At this depth "Rwa/sonic" calculated TDS salinity changes abruptly from <500ppm TDS to >3000ppm TDS. The mud log indicates that the lithologic section changes from massive Quaternary gravel of glacial origin to the interbedded claystones, siltstones, sandstones, conglomerates, and coals of the fluvially deposited Tertiary Tyonek Formation. Resistivity values >20 ohm-m in deeper permeable zones are mostly due to gas effect and result in erroneously low calculated salinities. The erroneous calculations can be identified where zones have high total gas readings on the mudlog .and/or production testing resulted in gas recovery with no water (Table 4). Specifically, gas effect was apparent from 2250' to 2500' and was very common below 3800' (Figure 8). "Rwa/Sonic" calculated salinity generally range between 3000ppm and 13000ppm TDS from 1500' to 4000'. Obviously, well control in the area is sparse. Therefore, after drilling a disposal well, the wireline logs will be analyzed using the "Rwa/sonic" method in order to identify specific injection zones. Base of the Fresh Water Resistivity curves from the rest of the deep tests in the area were used to estimate the depth to the base of the fresh water for each well. The base of fresh water structure map (Figure 9) incorporated all of the 31 deep exploratory wells and the 10 deep water • • wells (Although none of the water wells were drilled to the base of the fresh water, their tots{ depths were used to determine minimum depths). The Base of the fresh water sediments ranges from above sea level in the NE to very deep and thick (> 4000') to the SW (Figure 9 & 10). The Castle Mountain and Cottonwood Creek Faults seem to act as impermeable seals to deeper fresh water flow from the NW and east. The thickening and extreme depth of the fresh water section to the southwest corresponds to the area where the Susitna River crosses the fault. The huge volume of water flowing in the Susitna River combined with continued regional rapid subsidence of Cook Inlet Basin and high vertical permeability of the glacial section is probably the reason for the anomalous thickness. Within the Unit, the base of the fresh water ranges from -500' to above sea level. The structure rising to the NE combined with the coincidental rise in topography results in fairly consistent drilling depths to the base of the fresh water throughout the unit of between 400' and 700' (Table 1). Therefore, surface casings of all unit wells are proposed to be set deeper than 800'. Inspection of resistivity and mud log data indicates that most of the fresh water aquifers are well sorted sands and gravels within glacial drift (including deeper unproduced reservoirs). The exception is where the glacial sediments are thin in the NE corner of the unit. Here, the upper few hundred feet of the Tyonek Formation contains some fresh water above sea level (Figure 9). Injection zones It is recommended that the Tyonek section between 1500' and 4000' be covered by the fresh water aquifer exemption. All potential disposal zones are permeable zones within the Tyonek Formation. Experience has shown us that the Tyonek is a sand rich system and it is anticipated that there will be no problem in identifying suitable injection zone between 1500' and 4000'. And, the Tyonek Formation exists and is thick at the well location (Figure 11). Examinations of wireline logs from the exploratory .deep wells within the Unit, the Pittman #1 and the BLT #1 indicate that there are a number of specific potential disposal zones within the Unit (Figure 8 & 10). However, because the Tyonek sands and conglomerates are lenticular and discontinuous, it is uncertain that specific potential disposal zones in those wells will exist at the proposed location 6 3/4 miles to the east. Therefore, disposal zones and overlying confining zones in the well will be identified from wireline and mud logs after drilling the well. Confining Layers As in the BLT #1 well, the high resistivity/low resistivity transition is very abrupt in every well where it was logged. The difference between these two dramatically different salinity environments leaves no doubt that the intervening layer of • • siltstone and coal is a very effective permeability barrier. The transition occurs above 1000' throughout the Pioneer Unit. Also, numerous confining layers between the base of the fresh water and 1500' (and specific confining layers containing individual potential disposal zones) can be identified in every well drilled in the area. Figures 8 & 10 demontrate this in the BLT #1 and Pittman #1 wells. There are 29 impermeable claystones and siltstones (net of 614') in the BLT #1 between the base of the fresh water at 534' and 1500' depth. At the proposed well location, the thick 500'+ section containing numerous confining layers (will be obvious. from the well logs) would prevent upward migration of wastes into any fresh water aquifers (Figure 11). Injection Zone Salinity The target coal reservoirs seams are interspersed within the section between 1000' and 4000'. Although, formation fluids within the seams have never been analyzed it is probable that their compositions are similar to those of any potential injection zones. In fact, produced fluids from the shallower seams (1000' to 1500') would probably be fresher than fluids within the injection zones. References EPA publication "Survey of Methods to Determine Total Dissolved Solids Concentrations" . Fuelner, A. J., 1971, Water Resources Reconnaissance of a Part of Matanuska-Susitna Borough, U. S. Geological Survey, Hydrologic Investigations Atlas HA-364. Jokela, J.B., Munter, J.A., and Evans, J.G., 1991, Report of Investigations 90-4 Ground-Water Resources of the Palmer-Big Lake Area, Alaska: A conceptual Model; State of Alaska DNR, Div. Of Geol. & Geophysical Surveys, 3 maps or Montgomery, James M., Consulting Engineers Inc., 1990, Conceptual Model of Groundwater Resources from Big Lake to Palmer-Final Report. Seamount, D.T., Cross, R., & Buck, G., 1997, Geologic And Engineering Report To Accompany Application For Approval For Unitization Of The Pioneer Unit, State Of Alaska, December 10, 1997 Unocal, 1999, Pioneer Plan of Operations", March 8, 1999 Unocal, 1999, Pioneer Unit -Vine Extension Plan of Operations", May 11, .1999 • • Additional References Karlstrom, T. N. V., 1964, Quaternary Geology of the Kenai Lowland and Glacial History of the Cook Inlet Region, Alaska, U. S. Geological Survey Professional Paper 443. Reger, R. D., 1981 a, Geological and Materials Maps of the Anchorage C-8 Southeast Quadrangle, Alaska, Department of Geological and Geophysical Surveys, Department of Natural Resources, State of Alaska, Geologic Report 65. Reger, R. D., 1981 b, Geological and Materials Maps of the Anchorage C-8 Southwest Quadrangle, Alaska, Department of Geological and Geophysical Surveys, Department of Natural Resources, State of Alaska, Geologic Report 68. Reger, R. D., and R. G. Updike, 1983, Upper Cook Inlet Region and the Matanuska Valley, in Guidebook to Permafrost and Quaternary Geology along the Richardson and Parks Highways between Fairbanks and Anchorage, Alaska, ed. by Pewe, T. L. and R. D. Reger, 1983. Fourth International Conference on Permafrost, Division of Geological and Geophysical Surveys, Department of Natural Resources, State of Alaska. • APPENDIX 1 • TDS Calculation From Wel/ Logs Thermal Gradient Formula: TG = (Tmax -MST) / (Depth Subsea / 100) Tmax =Maximum recorded temperature from log header MST =Mean Surface Temperature for Cook Inlet (= 35 deg. F Depth Subsea =Meas. depth of Tmax converted to subsea depth Formation Factor F = 0.81/ (porosity*porosity) (average of the density and neutron log porosity) (Tixier Formula) Resistivity of 100% Water Saturated Formation: Ro = Rt (deep induction R value through analyzed zone assumed to be 100% water). Resistivity of Formation Water Rw=RoIF Formation Temperature: Tf = (Depth subsea / 100) x TG Resistivity of Formation Water at 750 F: Rw@75degF = Rw ((Tf + 6.77) / 81.77) Salinity (ppm): x Salinity= 10 ~= 3.562 -log (RW@75DegF - 0.0123) .955 A procedure to generate the salinity curve using the method has been developed for WDS. • • APPENDIX 2 APPENDIX 3 FIGURES .fin JUN-09-99 WED 03 13 Phl UNOCAL-AK BUSINESS VNTRS FAX N0, 907 263 7828 P, 01/01 *r ~ , y . ~1111Q~A~. Q.'r. S~mourt Senior AdVlglflg Geologist B~einags MentYres RobeK P. Crandall Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 June 9, 1999 Amendment to Application for Freshwater Aquifer Exemption Pioneer Coal Bed Methane Project Proposed Class II Waste Disposal WeII #1702 15AD WpW Mat-Su Borough, AK Dear Mr. Crandall, In response to your recommendations regarding Unocal's Application for Freshwater Aquifer Exemption for the proposed Class II Waste Disposal Well #1702 15AD WDW May 12, 1999), the following modifications and additional information are: + The location of the proposed Class Il injector well is in the NESS section 15- T17N R2W (Attached map). • Locations of nearby water wells and the proposed test wells are shown on the attached map. A baseline study of water wells surrounding the in immediate area (>1/2 mile radius) will be performed by a third party geo-technical firm. • The proposed injection interval is changed from "1500' to 4000" to "below 2500". This will result in an additional 1000' of separation between the base of the fresh water aquifers at approximately 500' and the proposed injection zones (Attached crass-section 6-B'). The injection zones will be confined by a 270' thick shaley interval present from 2520' to 2790' in the ARCO BLT #1 (Figure 8 in original application dated may 12, 1999) + Produced water samples from the potential injection zones will be analyzed for Total dissolved solids concentrations after the injection well is drilled, logged, cased, and perforated e trul ours . T. Seamount Senior Advising Geologist ('rt U~sU' ~ ' : ~ r ° ~ ._ _ ,_~~~ narh.n R. Ragan -_ ~ A D.. i ~ ~ ~ 1' _ -- - TS 3 of ~. ~ , ~ - . ~ . ,.~'t~•i p:' .{ ,. 1. ~ _._ E~ '.- _ _ FSPA[KS--:: : ~ - h ~ ~ ~ - _ _ HyRIE HBI a . ~~\' :~ 1> _ _ - rx~s6 ci •.. b b ~e "~' Figure 5 S _.u, Nerxr °ue_ ~ lo~~ .'__-~1 -: -I frtuJ t ~r~ Miir i' ?" ~ #1702- ISWI}W Proposed GMO -._. _..- :~ E SS ~- ...__I Chat E. MoRrx 7uwe l.Ahrklc ro _ _ - 1 ~, i -..: ~ ~-'"._. ! Class II It~jeetiott well ~ ~._._ .........- - - wear #i~oz. ~ '. ,~~ ° --" ° ----- 15t?A-WDW ~ Ala~aa~Eraa°I,OKR - - ~.. ._ "'~ i ;~ ~ - " - ~ ~ ~-- - i Pr posed CBM Test'Wel~s o ~ - ___ -~--------- ---- f--- - ;r,a ;r - ~, --- ~ o /~ lafu: Naapun ~i.,r = ~ ! Boa Water Well & Qepth C.c. i ++~' ~ I I nlulca,sMlror,l):f2 ~~ ~~ ~ TfEBRA V1;AB6: S1gCIKC a'ODDS ~ ' CI2 € ADL RD l stop '.' :~ i ~~Y . w ~,yee, .•'~ ` ~ : - `' ~. '-"~ Pro seal Access Route ~ 77~ ~ '--- ~ Dld Lrn mrc ' ~ ~-~ l _~ ~ - ~ - 1 - erosJ lent n. &ikboaah ~ - .-~ j_'_ - : - ' n ~- ~ > ~'. x ;-- ., ~ __ _!` - _ _- 46 ~Yater Wells from l?,S' to ;: ._ II~~ 23 "= - '- ~-_.. - I ' :. ` ;,ai,<D ~1°'riFC l• i .~. - _ 3U5' deep io tie SE 1/4 of ~- ~roo»9f`,•^ (3ir.;~ 9s, '19 - Section 22 €ru~ 197 ~ a+ '- , -t, _...~ _ - _ ..... ~_ ? .i ~ ~> i : :.. ' -. 51ftC7KG CODS ' _ ~`~ ` _ - - - _ ~ _ a.. " -% _ _ %~ ° .~ . M Y ~ADB HC f1s4r1 _ I~ _ .. ;c° , 196 \ _ . ° ~ `: - - TFKfttt-~LV~ _/~ -`1 >.i~ _~' ~ 1 N I GB I ' ~t -- - • [soli '~ f~ -~__ .•-' r ...~~ pj ~ __~.~ Z s: r? - - ,,tom: - ~ _ '~'~~>,I ~, ~~ : i. I , . ;N ~ ~_ ARCO ~ B1.T #1 Pioneer #1702-1SAD WDw ~ ~ ,_-~..,~ "'"~"' Deepest Water~Velt Average Water Weil ~ 30S' Deep 154' Deep 3S9 ~ ~ _. 5.. w - _ -W .. - $ 6 ,- - ~ High ltesistii~i6y Ih W~tier- . ~ ~ ~' - ~ - -. - .. 3 ~ ,. ; ._ -. - - ~ ,_ - ° ~ _~ - - z .-. :. . . ~ ~~ : . _ ~ . .Sri i` _ _ ! O = ~ ' a w46 ~vb -1000 = ~_ .. - : ~~ ~ ~~ N % x Y ~ - ` F~ > _ s ~ '# ~> ~ 1000 _~ :. ~ _ 1vu ~ - -2000 ` ; ~ `: r ~f : ._. .. .. . - =x; n ' _ v~ -2000 : :: •s ~ . ~ ~ ~~'" .. .. .. ~ ~ 2500' T'VD ~ O ``~1 ~ 3007 T'l] . G.'cS ~ Q ~ ~. -3800 ~ a ~ ~-,. -3@88 ~ ~ ~ - H ~ M 4fl00' TVD -40~e ~ -~e~e ~ 6.8 Miles ~ ~,; Figure 11-Cross-section showing correlation of zones fra~n BLT` #1 and Class II Waste Disposal V{~e111742-35AD WDW P,ors~ un,rr #117oz-ISDA WD~ Dlo A~~,uv~o~.~ ~ONf DE~~ 71A~ )N ~O , U ~Z . ~~ ~~ oz ©~ ~~ ~~ ~~ ~; ~~ T~ L Ci 0 f~ UNOCAL D. T. Seamount Senior Advising Geologist Business Ventures Robert P. Crandall Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 May 14, 1999 Application for Freshwater Aquifer Exemption Pioneer Coal Bed Methane Project Proposed Class II Waste Disposal Well #1702 15AD WDW Mat-Su Borough, AK Dear Mr. Crandall, Unocal, in accordance with the requirements of 20 AAC 25.440, herein submits . an "Application for aquifer Exemption" for a single class II waste disposal well, Pioneer #1702-15DA WDW on State oil and gas Lease ADL 374117 within the Pioneer Unit. The surface Owner is Joan I. Markle. The approximate location is 1500' FSL & 515' FEL of Section 15, T17N, R2W. It is anticipated that well drilling will be initiated around July 15, 1999 in order to comply with unit obligations. The injection zones exist as permeable sands and conglomerates at depths between 1500' and 4000' within the Tyonek Formation. The zones correlate with those at similar depths in the ARCO BLT #1 (located approximately 6 3/4 miles to the west) which range in salinity from 3000ppm to 10000ppm. The specific injection intervals will be identified after the well has been drilled and log analyses indicate that the aquifers meet the criteria for exemption as specified in both the State and Federal regulations (CFR 40 146.4 and 20 AAC 25.440). Unocal respectfully requests that aquifer exemptions be granted for the Pioneer Unit Well #1702-15DA-WDW. An application for underground injection (regulation 20 AAC 25.252) will soon follow. Very trul yo , . T. Seamount Senior Advising Geologist ,~ _, Submitted by UNOCAL PIONEER PROJECT Request for Aquifer Exemption Proposed Class II Waste Disposal Well #170215AD WDW Tyonek Formation May 141999 • Tim Brandenburg- Drilling Dan Seamount- Geology Faye Sullivan- Environmental • Geologic Data For Freshwater Aquifer Exemption Tyonek Formation Pioneer Unit Well #1702 15AD WDW I. Introduction Union Oil Company of California, d.b.a. Unocal, plans to test the coal bed methane potential (CBM) of the Pioneer Unit in northern Cook Inlet (Figure 1). The project will target numerous coal seams in the Tertiary Tyonek Formation (Figure 2). The subsurface geology and coal bed methane (CBM) potential of the unit is described in Seamount et al. (1997). The entire three year exploratory phase of the project is described in the "Pioneer Unit Plan of Operations" (1999) and the "Pioneer Unit -Vine Extension Plan of Operations" (1999). Since CBM wells commonly produce large initial quantities of water (up to 500BWPD anticipated) ,safe methods of disposal must be planned. Pioneer well #1702-15DA- WDW is planned to be drilled this summer as a class II Waste disposal well to handle fluids and drilling wates from test wells to be drilled nearby (Figure 3). Operations are expected to begin on approximately July 15, 1999. Testing of the first few wells may continue for up to 18 months. It is of utmost importance to identify the entire stratigraphic section containing all of the potential fresh water acquifers. Then, they can be protected through safe cementing and casing designs of both producers and disposal wells. State of Alaska regulation "20 AAC 25.440." requires that application for a fresh water aquifer exemption is required if the potential disposal zones contain fluids between 3000ppm and 10,OOOppm TDS. Through exploration well tests and log analyses, it will be shown that: • Zones within the Tyonek section between 1500' and 4000' contain fluids within those limits. • The base of the potable water section (<500ppm) is at depths above 1000'. • Adequate confining layers exist between the potable water section and any potential disposal zones below 1500'. • The salinities of the injected fluid will be similar to the salinities of the fluid in the injected zone. Confirmation of the suitability of any potential injection zones will be made after drilling and logging the disposal wells. The following information is intended to show that for Pioneer well #1702 15AD WDW, permeable zones within the Tyonek Formation below 1500' qualify for a Freshwater Aquifer Exemption in accordance with 20 ACC 25.440. • • FIGURES Figure 1-Pioneer Unit Location Map Figure 2- Stratigraphic Chart of Cook Inlet Figure 3- Pioneer Unit Geography and Well Locations Figure 4- Water Table Contour Map, Pioneer 1702-15DA WDW Area Figure 5- Water Well Location Map- Well # 1702-15DA WDW Area Figure 6- Log Curves and TDS Analyses of DST'd zone- Horseshoe Lake State #1 Figure 7- Log Curves and TDS Analyses of Kick Zone- American Quasar Big Lake #1 Figure 8- Wireline Log and Salinity Curves of BLT #1 (in pocket) Figure 9- Map of B/Glacial/fresh water Includes deep water wells (Large copy in pocket) Figure 10- Cross-Section A-A' (in pocket) Figure 11-Cross-Section B-B' TABLES Table 1-Pioneer Proposed Wells Table 2- Deep Water Well List Table 3- Exploration Well List Table 4- Exploration Well Tests Table 5- -Log Curves and TDS Analyses of DST'd zone- Horseshoe Lake State #1 Table 6- -Log Curves and TDS Analyses of Kick zone- American Quasar Big Lake #1 Appendix 1-Pioneer #1702-15DA WDW Area Water Wells • Appendix 2- Geochemical Analyses & Test Data From the Horseshoe Lake State #1 & American Quasar Big Lake #1 • Appendix 3- EPA Log Analyses Method to Determine Total Dissolved Solids Concentrations FIAIIT~ER ~"~~Q~~''EC ~` ~"1s'~,;~~.sr$ fa+a,.is~ car ~;~, ~ -,.. ~ i --` t~sx ro,.:rz; ~•ia ~ ~, t ~ • ~ „~ ,I ~' S i r i . t; ~~ ,k ~ ~ ~~ i ... ... ... r..~...r... ,` / • i i ~`` ~ i ~'/ i~ ~ " i ;; ~ j r, i • • I / I i t • PL~~~~~JI.~A 2~ n~r~.~s i r AeMc*.f~~~ c~t'F~i.iglit~s~i: ~i~ i Area of Highest Potential II Hr7'A+lR" F2 Figure 1- The Pioneer Project is located in the northern Cook Inlet `s Matanuska • Valley. • • • • Mi AGE LITHOLOGIC ~x,. TYPE PRODUCING ZONES ,~m,,_~ S15fEN SERIES U~•J~TS av F LOG OIL&P.SSOC f AiFD lG{4 WTED GAS F T.A., Q Glacial 0-4500' RECEM ~ ~ ~ ~ FsTOCENE Sediments y, ~ ~ ~ a ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ y ~ ~ ~ ~ w/freshH2O ~; `~ ~ 3 Y ~~ z u ~ ~ ! ~uu ~ 8 € ~ 2 b ~ S Y Y ~ o ~ ~ ~ ~ z o y_~ i ~ ~ Y PUOCEPIE i STERLING FM ~ `' Y (z ~ ' T ~~,~~g~ Z r i sue . al~~ mm coa ~ E a ~ 0-4900 R ~ BELUGA -~ nuocEraE ~ FM - T Q Z "FAN w FACIES" y 1000-10,00 A -, ~.- '4 R ~ _ c TYONEK ~ ~ ~ ~-- ~ Y FM `~ ~ ~ " ' w t ~ k - ~ P'k ; ~ , ' Z ~ ~ • ' 1 Smd ' r a^~ I ~a Ccn~ ale S d l l m x ma `Jt3rna ~ ~ , ;. Slide ~ . Cad 1 } ~y ~ `. 1 tr "T 7 r sas _ J y ,~ . * ~ oucocENE ~ a - 1 ~ 0-600' I-' HENLOCK CGL, 6 . s 5 HFNLOCIC SW1LE 3 ~-, 0 600 EOCENE WEST FOREUV~ID FN ~ ~ PAIEOCEIJE 0-200 ' CHICK,4LOON FN w UNDIFFERENTWTED ~,na~ M4RINE SEDReENiS AND ' `JO~CMJICS Figure 2: Stratigraphic Chart of Cook Inlet tz~ H y c Y yyC t~ r • Location of Proaosed Well and Proximity to Well Control The Pioneer Unit outline and the well location for the Class II Disposal Well- Pioneer #1702-15DA WDW and the proposed test Wells are shown in Figure 3. Houston, Alaska is located on the western edge of the unit and Wasilla is located on the southeast edge. Residential use of the area is sporadic. Elevation of the well location is approximately 300' above sea level. The topography is somewhat irregular due to past glacial events. The disposal well specifics are as follows: Pioneer # 1702-15DA WDW State Lease ADL 374117 Surface Owner: Joan I. Markle Land: Approx. 1500' FSL, 515' FEL of Section 15, T17N, R2W Proposed Total Depth 4,000' S Surface Hvdrologv and Fresh Groundwater Water wells in the unit area typically tap the water table; they do not drill through the water column. Figure 4 is a portion of regional water table maps (Montgomery, 1990) of the Palmer to Big Lake area which pertain to the proposed wells in the project. They indicate that the depth to the aquifer is very shallow throughout the unit area and basically follows the topography ranging from sea level to 800'+ from SW to NE. They also show that ground water flow is generally to the SW. Most of the lake surfaces define the top of the water table. The estimated elevation and depth to fresh water for the proposed disposal well are • 300' and 35 feet respectively. The depth to fresh waterwas estimated from regional mapping (Figure 4 from Montgomery, 1990) and local water well drilling depths (Table ~ ~ the locations are deeper than some water well total depths. The shallower depths to fresh water are possibly indicative of wells which tapped confined or semi-confined aquifers. The Division of Mining and Water Management identified 10 water wells with depths greater than 400 ft (Table 2) that were located within four miles of the unit boundary. The deepest total depth for a fresh water well is 605 ft. While water well data can be used to estimate the depth to the top of the aquifer, no water wells were identified which drilled completely through the fresh water column. Therefore, the fresh water/brackish (3000ppm to 10,000ppm TDS) water transition zone cannot be determined by examining only water well information. Salinity Evaluation/Depth to Base of the Fresh Water Section Wireline and mudlog data from 31 deep oil and gas exploratory wells (Table 3) and produced water analyses from two wells (Appendix 2) within a 48 township study area were analyzed to help determine the depth to the base of the fresh water. Rwa Method In the absence of reliable laboratory water analysis data, electric logs provide the means to discriminate between freshwater sands and those that contain saltwater. Because the total dissolved solids (TDS) content (salinity) of fresh water is relatively low, it is a poor electrolyte that exhibits high resistivity. Conversely, if the water is more saline, it conducts electricity better and its resistivity is lower. Within permeable rocks, resistivity is a function of temperature, porosity, and water salinity. The "Rwa" method (Appendix 3) described in EPA publication "Surrey of Methods to Determine Total Dissolved Solids Concentrations" relates formation water salinity to those parameters. The method generally underestimates the actual salinity of formation fluid and, therefore, helps to insure that potential disposal zones are in compliance with regulation "20 AAC 25.440". Fluid Recovery from Deep Wells Very few of the deep exploration wells were tested. The locations of the wells are shown in Figure 3. Fluid was recovered from only 15 tested zones in five wells and one zone in a well which kicked (flowed into the well bore) while drilling (Table 4). Furthermore, chemical analyses of the fluid exist for only three of the 'zones. Most of the other fluid recoveries were described as "salt water". Of the three analyzed zones, fluid recovered from the Horseshoe State #1 Well from 4246' to 4310' was probably not formation fluid, but was fresher mud filtrate used in the drilling operations. The recovery was described as "354' of water cut drilling mud". The other two analyzed fluids were probably true formation fluids, which were contaminated (diluted), somewhat by the fresher drilling muds. The probable result was in measured salinity being lower than true formation salinity. The two zones were from 1870' to 1930' where a "kick" occurred in the American Quasar Well Big Lake #1 and from 2950' to 3084' in the Great Plains Horseshoe Lake State #1 Well. The "Rwa" method was used to calculate TDS salinity of the two zones (Figures 6 & 7) using porosities derived from three different curves- density, density/neutron crossplots, and sonic travel time. The results were compared with the actual measured salinity (Tables 5 & 6). It was found that using the sonic derived porosity gave the best match with the measured data. Higher salinity was calculated using density and density/neutron derived porosities. Most likely, the density/neutron-derived salinity is the most accurate and the lower measured salinity is due to fresh drilling mud contamination. However, the sonic derived salinity was used in the area evaluation to remove any doubt about a potential disposal zone's regulatory compliance. Salinity Evaluation of the Section to be Drilled A salinity curve was generated for the ARCO BLT #1 well (Figure 8) using the "Rwa/sonic" method. The analysis indicates that the base of the fresh water can be identified at 534' were there is a marked decrease in ILD resistivity of permeable zones from >50 ohm-m to <20 ohm-m. At this depth "Rwa/sonic" calculated TDS salinity changes abruptly from <500ppm TDS to >3000ppm TDS. The mud log indicates that the lithologic section changes from massive Quaternary gravel of glacial origin to the interbedded claystones, siltstones, sandstones, conglomerates, and coals of the fluvially deposited Tertiary Tyonek Formation. Resistivity values >20 ohm-m in deeper permeable zones are mostly due to gas effect and result in erroneously low calculated salinities. The erroneous calculations can be identified where zones have high total gas readings on the mudlog and/or production testing resulted in gas recovery with no water (Table 4). Specifically, gas effect was apparent from 2250' to 2500' and was very common below 3800' (Figure 8). "Rwa/Sonic" calculated salinity generally range between 3000ppm and 13000ppm TDS from 1500' to 4000'. Obviously, well control in the area is sparse. Therefore, after drilling a disposal well, the wireline logs will be analyzed using the "Rwa/sonic" method in order to identify specific injection zones. Base of the Fresh Water Resistivity curves from the rest of the deep tests in the area were used to estimate the depth to the base of the fresh water for each well. The base of fresh water structure map (Figure 9) incorporated all of the 31 deep exploratory wells and the 10 deep water wells (Although none of the water wells were drilled to the base of the fresh water, their total depths were used to determine minimum depths). • The Base of the fresh water sediments ranges from above sea level in the NE to very deep and thick (> 4000') to the SW (Figure 9 & 10). The Castle Mountain and Cottonwood Creek Faults seem to act as impermeable seals to deeper fresh water flow from the NW and east. The thickening and extreme depth of the fresh water section to the southwest corresponds to the area where the Susitna River crosses the fault. The huge volume of water flowing in the Susitna River combined with continued regional rapid subsidence of Cook Inlet Basin and high vertical permeability of the glacial section is probably the reason for the anomalous thickness. Within the Unit, the base of the fresh water ranges from -500' to above sea level. The structure rising to the NE combined with the coincidental rise in topography results in fairly consistent drilling depths to the base of the fresh water throughout the unit of between 400' and 700' (Table 1). Therefore, surface casings of all unit wells are proposed to be set deeper than 800'. Inspection of resistivity and mud log data indicates that most of the fresh water aquifers are well sorted sands and gravels within glacial drift (including deeper unproduced reservoirs). The exception is where the glacial sediments are thin in the NE corner of the unit. Here, the upper few hundred feet of the Tyonek Formation contains some fresh water above sea level (Figure 9). Infection zones • It is recommended that the Tyonek section between 1500' and 4000' be covered by the fresh water aquifer exemption. All potential disposal zones are permeable zones within the Tyonek Formation. Experience has shown us that the Tyonek is a sand rich system and it is anticipated that there will be no problem in identifying suitable injection zone between 1500' and 4000'. And, the Tyonek Formation exists and is thick at the well location (Figure 11). Examinations of wireline logs from the exploratory deep wells within the Unit, the Pittman #1 and the BLT #1 indicate that there are a number of specific potential disposal zones within the Unit (Figure 8 & 10). However, because the Tyonek sands and conglomerates are lenticular and discontinuous, it is uncertain that specific potential disposal zones in those wells will exist at the proposed location 6 3/a miles to the east. Therefore, disposal zones and overlying confining zones in the well will be identified from wireline and mud logs after drilling the well. Confining Lavers As in the BLT.#1 well, the high resistivity/low resistivity transition is very abrupt in every well where it was logged. The difference between these two dramatically different salinity environments leaves no doubt that the intervening layer of siltstone and coal is a very effective permeability barrier. The transition occurs above 1000' throughout the Pioneer Unit. Also, numerous confining layers between the base of the fresh water and 1500' (and specific confining layers containing individual potential disposal zones) can be identified in every well drilled in the area. Figures 8 & 10 demontrate this in the BLT #1 and Pittman #1 wells. There are 29 impermeable claystones and siltstones (net of 614') in the BLT #1 between the base of the fresh water at 534' and 1500' depth. At the proposed well location, the thick 500'+ section containing numerous confining layers (will be obvious from the well logs) would prevent upward migration of wastes into any fresh water aquifers (Figure 11). Infection Zone Salinity The target coal reservoirs seams are interspersed within the section between 1000' and 4000'. Although, formation fluids within the seams have never been analyzed it is probable that their compositions are similar to those of any potential injection zones. In fact, produced fluids from the shallower seams (1000' to 1500') would probably be fresher than fluids within the injection zones. References EPA publication "Survey of Methods to Determine Total Dissolved Solids Concentrations" . Fuelner, A. J., 1971, Water Resources Reconnaissance of a Part of Matanuska-Susitna Borough, U. S. Geological Survey, Hydrologic Investigations Atlas HA-364. • Jokela, J.B., Munter, J.A., and Evans, J.G., 1991, Report of Investigations 90-4 Ground-Water Resources of the Palmer-Big Lake Area, Alaska: A conceptual Model; State of Alaska DNR, Div. Of Geol. & Geophysical Surveys, 3 maps or Montgomery, James M., Consulting Engineers Inc., 1990, Conceptual Model of Groundwater Resources from Big Lake to Palmer-Final Report. Seamount, D.T., Cross, R., & Buck, G., 1997, Geologic And Engineering Report To Accompany Application For Approval For Unitization Of The Pioneer Unit, State Of Alaska, December 10, 1997 Unocal, 1999, Pioneer Plan of Operations", March 8, 1999 Unocal, 1999, Pioneer Unit -Vine Extension Plan of Operations", May 11, 1999 Additional References Karlstrom, T. N. V., 1964, Quaternary Geology of the Kenai Lowland and Glacial History of the Cook Inlet Region, Alaska, U. S. Geological Survey Professional Paper 443. Reger, R. D., 1981 a, Geological and Materials Maps of the Anchorage C-8 Southeast Quadrangle, Alaska, Department of Geological and Geophysical Surveys, Department of Natural Resources, State of Alaska, Geologic Report 65. Reger, R. D., 1981 b, Geological and Materials Maps of the Anchorage C-8 Southwest Quadrangle, Alaska, Department of Geological and Geophysical Surveys, Department of Natural Resources, State of Alaska, Geologic Report 68. Reger, R. D., and R. G. Updike, 1983, Upper Cook Inlet Region and the Matanuska Valley, in Guidebook to Permafrost and Quaternary Geology along the Richardson and Parks Highways between Fairbanks and Anchorage, Alaska, ed. by Pewe, T. L. and R. D. Reger, 1983. Fourth International Conference on Permafrost, Division of Geological and Geophysical Surveys, Department of Natural Resources, State of Alaska. • ~ ~ • FIGURES J • • •• M -~~ ~ _` t~. __ ~~ _,, Horseshoe La 1 mile to west !~~: ~~ ~J f Lzte7i Lade; . - , ;y, ~,- _.,, -W= D > ~ ~~ tats • Figure 3: Geography Well Locations • CBM test Well Location • Class II Waste Disposal ~'4'ell Location • Exploration Wells discussed in Report 0 M Scale • Figure 4- Water Table Contour Map, Vine Extension Pilot Area- Arrows show flow direction of ground water in acquifers less than 150' deep. Contours in meters (from Montgomery, 1990) • •~ M •• M • a 1 ~ ~ : ~ ~ ; ,,o• 0 ~~~! --_- L~~~/1..~1 ~ ,•,;- :~ -.: It DIY - 6 ~ go. , s, (~,+%: Barbara E Ri an e ail etx e. --- - ei] as - 14 ~~ . p,S ~ ~ 1 ~ _ - 80 -- ~ ~. 5 ; n. 11 . t:I.:F Ili.:t ~ 1 ~I .11 ~ - ~ .....~..~~~~~...~. Fi 5 _ . ; - ,© ^~ ~a s ~~^I 1010 ., ~ .. 00 °°'~~ ~~ • gure #1702- 15WDW , ---- _- 84 WATER WELL I, - .,_, „~ ~: ~ ` - - ~ U~ 1/2 Mile '~ ~""' - - Joan 1. Markle ~. C ~:. Ch s L. Mowrcr 2 LOCATIONS ~ Wei. #170 _ .,:, 15DA-WDW Alaska, sW1e ar, DNR _ , I' a ~' a Mar uez Proposed CBM Test Wells ~ y 50 ~ Water Well & Depth IAA ~ Alaska, Smle of, UNR I I l6 ~ i I:, ~ 14 I la 1! 15 -_. 4 i _.._. ___. -__- ~ ea YI YY - -.. _ --- i E 22 2 1.,..I,IIiF 14~ 23 e. _ ~ ~ ~ TIEBRA VEl DE SINGING MODDS ADD N0 ' ~ (sss~Y ~ Proposed Access Route rs: •,. ' 4 . . ' -- ''~. Dick L awman & Deborah Jerr A t - ' - ---_. - ~ ~ 1 - ,.so ~; .,~. - -.-. _._-- y . Frost - _ _ - ~.. ~- ~ ~1 _ 46 Water Wells from 125' to • ~ • ++~~~ ~ I ~~~~~ 305' deep in the SE 1/4 of -~~ - Hibflf 4 ! --. _ ~ "D01s r 200 19G 196 0 ,, Section 22 • ® Ys• OS _ - .._.. _ r:ar.~ ~a- 197 ~ I " 2 220 ~ ,. i ~ ~ ~ L ~. ~ ~ ,,. . 1 ..- ~~ - ~,9 __- oa 9 . ADD No I 196 . , .•:. --~- •- ~ ` ~•I. \ItIDGE- 3 E --- . • tzsou :TFtIRTY-GOVT 159 ~ \\ - TIERRA VERDE ~ '.. 2OO REVERI:1' i~. ~_ ~ ~ •: ~.. a -_ ~ HILLS ~ . ~., ea .P n L Vl 8 r --- .9 38 2 ~ ~ n~z~ - 1 ®1 H.~ ~I I~1~4~ 217_. - ul~_~>IUD,E' --- II r-~1 1~° -l - I., Ya •. h • uNOca~~6 Horseshoe Lake St #1 ~?1 NPHtOH G t00 ., . 0.6 0 Total Depth 8226 Temp at TD 132 Temp C~ Surface 35 Temp Gradient 1.18 Matrix Density 2.67 Matrix TT 53 Sonic Compaction Factor 1 a 0.62 m 2.15 Calculated TDS (Sonic) 3273ppm Average Depth Rild Sonic Porosity TDS (Sonic) • 2932 7.7 0.35 4364 2936 7.8 0.35 4346 i 2940 7.6 0.37 4032 2944 7.9 0.36 4022 2948 10.3 0.34 3488 2952 9.3 0.29 5666 2956 8.1 0.35 4251 2960 10.0 0.34 3567 2964 8.9 0.38 3205 2968 9.6 0.35 3474 2972 7.8 0.38 3622 2982 6.8 0.35 5052 j 2986 9.1 0.34 3931 ~ 3024 11.9 0.33 3083 3028 12.8 0.40 1940 3032 13.0 0.40 1876 • 3036 12.6 0.40 1957 3040 11.1 0.39 2333 3044 12.8 0.36 2378 3054 11.0 0.38 2443 3066 10.1 0.34 3433 ~ 3070 11.2 0.34 3146 ~ 3074 12.6 0.34 2797 3078 15.4 0.32 2590 3082 12.7 0.37 2242 3086 13.8 0.39 1777 3090 12.8 0.39 1930 Figure 6 •• ~ • UNOCAL 76 Rmf 3.05 Temp Rmf 91 Big Lake # 1 (A m Quasar) Total Depth 6095 Temp at TD 118 Temp ~ Surface 35 Temp Gradient 1.36 Matrix Density 2.67 w Matrix TT 53 ~ Compaction Factor 1 ~ ~ ~;,~~ Apparent !)ip r~ ;" ; .~.,. a osz ~.r.~ ._»... ~.. .~~.. ._... r. ... _... ~ __ _.._.. _~- ._ 1 b 2.15 Plot t0 Avg ; 65 RH06 "~ Neighting - " E 4 FE ETU 3 ~ I fi DT Calculated Ave. TDS (ppm) from Sonic 3154 • F ~D OT~~~S ".2 _~- 21100 150 _: ,~ - - , »_ ? ~ z. Pro 9 e ~ ~ C '"' ~.. O _ - a ~ _t ~ -- - o c~ ; -- - ~ . H+ ~ A ~~ J ~ ~ ~.+ ~ ~ ; ~ -1700 ~ ~ C ~3 ~ ~ C ~ ` ~ ,~ 9 t sy a 1900 ~ , ,, ~ ~' '$ `- -. Depth Rt Sonic Porosity TDSson(ppm) 1906 13 6 0 33 3183 ~ ~ . . '"3 ~ ~ 1906 14.8 0.34 2706 t ~ f"~ _ 1910 15.5 0.35 2474 1917 11.6 0.35 3233 ° S~ " ~ ~T - 1919 13.7 0.35 2658 ,~ O• _ t _ 1924 10.0 0.33 4349 ~- - - -- 1926 10 7 0 35 3526 ~ - i . . - I 1928 10.5 0.39 2841 1930 9.2 0.42 2802 a ,,~ Figure 7 I I I ,~_~ • C • .-. O U ~ ~ a ~ T ~ ~ M W ~, .., ~: .., { A, • - - - - - - - - - - - - - - - - - - - - - - - 1 L - - - - - - - - - - - - - - - - - - - - - - - - - - - - - r ~ ~r • c 4, - f ~~ ~ ~. 3 .--; ~ ~~ - . r' , 1H ~ f -~ ~ ~_ ~ i ` ~ • Z~ tt i ; ' I ... .^ ~ - ; ``"~-'` I '>111Ax'RR SD S+ ~ ,t ^':-~ , ° ,~' .4 T-'~f [ .t .. aq~F' ~ ` ~{F~ = t PAL ~ . ~ i , . , S .- ~, ~ : y2.. - t~ . `~. i~ c++.,m #(, '_ •.r<.. - ~t _'r a ~ ~~ ~ ~~ . t ,: _ -t:! ~__ _~ ~. -~ ti ~ A : I . a . , s ,. 3r a ~ +e<_ . _. ~~ ~ ~~ ~~ . r k _ ~ I .: ,~ i ' '" ` rue dk . ~ : awa.s I z . •~ _ a ~ ~_ r ~ YsF '""_. ~ y _ da`-= ~, B Nth, .t .. - i5 ~ t1M sY ~ .~ i ' rti Y ) t B ,,..,,•__ •4~ .... ; ° ' ... 1 j ~ '~ y . v ~ _ I_`E •, vISF,I \Il tisION ~ - r," FY jCt I II,(r1 I R()JF(T ~3 ~\ ' f } f f ~~{ ~.. . ~ • '~1ifLC Als tlNtlt ~i ~. '., ~ ~ f ~~ ^ •a.>~R~W `'~„~,1...,'~'~of ~~~ ~ - t" -~" d ~ ~ t ~ d ~" ~°' _ ~ ~ .: ... ~ ~ .~ ~j r e . v .. .,- _- ~ ~ .1 .. • ~ ,.: 1 _ 1 ~ r - :. +., .:. , ~. _ - _ t ~ Rw( ~ ~ ' ~ ~ { .. i .;, ~ •.~ n 6>•K1 g,S? -»a9 nx M1 ~ 1 j'- 1f W tM ~.Yt rY :/ 1 1~ ~Y N . ~ x ~ ~ N ~ rye} a1 ;~ -~ ti-.J j{~ ! r li 1~,~ `: , j ~•~ a ,., ; _ I Y ~.._1 e n. - ~ i~'' '~ ' t ~ ~`, j ~ ~ o- ~ _~ ~ 1 ~~ _. _ i i ~ F i _ ___ }~y [~ '!s ue . "R . 1 O 2 4 ~~_ ', rY ,. I ~a .. ~, .. ~ :w a i Ir st w ~ I ~-; ¢ ~.. •rn rs ~ ~. _ = ~. Figure 9 ._-~ t ~ i €._,,.,.~ _ ~ ~ ~. ~ - ~t~ 4a Q 1M~ 1$:. mss kiRSDaea E1PkOPa~^AC 192i - R{,LT~J ._ ~._- y°`° v" i , ~ eYlr R ~.. _a Gsxx; 'IC611 ~..r. sr~w ~ Ruk~3a PEi![~ - - __._-.-- .:~ ti~ r _ # E ~ s rafm w ~yrsk K- St~L'CA;Rf IaIiSF - 4 ~ i xx.~s,E ~u.~Y rr zw a5rrnc ...r R$~!^RESh WAl~.ii EBB ~ Rt95f rtY; • • •• M • A A, PIONEER UNIT ~ .~oo~ ~ ~ ~~ ~ . ~ ~J ~II ,.~_ PIONEER PIONEER PIONEER PIONEER 1000 si ., wow si n2 it ~ / .. ,~,. ~ ^ - _ ,., _. n3 _ '~ .. I 1000 I ,Y ,... wT „„ ... / ~ . _ o i i HIGH RESISTIVITY . ~ L I 1 0 FRESH - 1 ~. ~ WATER GLACIAL -1000 _ DEPOSITS LOW RESISTIVITY ± -1000 ~ POTENTIAL '~, - DISPOSAL I 1 ZONES SALINE T ~ TYONEK -2000 ~ -2000 ~ vao 1 t v ro ~ ~. T 2500' / ! / ~ -3000 ~ I + -3000 i i, PROPOSED Prep ro xx~n' rsoao' azoaa } TEST ~ } ZONES HORIZONTAL SCALE -4000 t j / -4000 uROCAL® I Y t ~ // r ~ COOKINLETMm~~ 9 vaovro va vro ~ R ~ PIONEER PROJECT i, Y ~ `~~~ CROSS SECTION + r ~ AA ~ -5000 ~ ~~ ,a Figure 10 •• ti • B 350 f 0 1000 -2000 -3000 -40001 ;M„ ARCO Pioneer #1702-15AD BLT #1 WDW B ~ ...~.... Yj~~ ~~ ~- High Resistivity Fresh Water Water Aquifer t n m 0 7 '~ C m 9 x r IINNI' TVD ~ e3e m ~. 1500' TVD ... c _ __- 20fN1' TVD ..,. ~ .,. ~ .__..,~,_ 3000' TVD 6.8 Miles 4000' TVD b ~.. '~ ~. o a ~ '~ o ~ ' ~ ~ M 350 0 F-1e001 ~ -20001 ~-30001 ~ -4000 1 Figure 11-Cross-section showing correlation of zones from BLT #1 and Class II Waste Disposal Well 1702-15AD WDW ~ ~ ~1 L__J l • TABLES • •• M • Table 1 Pioneer Project Proposed Class II Injection Well & Test Wells Well Township Range Section Location Est KB Elev. T/Fresh Water T/Fresh Water B/Fresh Water B/Fresh Water Total Depth Datum SL@ Drilled D tl11 Datum - SL Drilled D it #1702-15DA- 17N 2W 15 1500' FSL 300 265 35 -235 535 4000 WDW 515'FEL #1702-15A8 17N 2W 15 1015' FNL 325 295 30 -225 550 4000 2130'FEL #1702-15CD 17N 2W 15 837'FSL 300 265 35 -250 550 4000 1931'FEL #1702-15DD 17N 2W 15 772' FSL 300 265 35 -255 555 4000 798'FEL #1702-14CC 17N 2W 14 743' FSL 300 270 30 -245 545 4000 660'FWL #1702-22A6 17N 2W 22 660' FNL 300 265 35 -265 565 4000 1675'FEL #1702-22AD 17N 2W 22 1870' FNL 420 270 150 -275 695 4000 Table 2: PIONEER UNIT AREA DEEP WATER WELLS The letters in lhe'Loca6on' column represent tl~e four quarters of the section and its divisions, from largest to smallest, taken counter dodcwise, also as below. CDAB (reversed and translated to the standard convention) m eans NW 1/4("8") of NE 1/4 ("A') of SE 1/4("D") of SW 1/4("C') KEY OWNER D h Townehi Ran a Section Location Drllle SubDivlelor Drill Dat[ 6695 WALDAL, MEL 405 17 NORTH 1 EAST 9 - DCBC7-12 PENN JERSEY DRILLI WILDERNESS E L12 87 7/1/77 420 MADCO 423 17 NORTH 1 WEST 10 BBBA1-42 PENNJERSEY THOMAS L7,9,861081&2 6/16/77 6940 J&J CONST 465 17 NORTH 1 WEST 29 DADA1-3 A R L DRILLING BLUFF VIEW ACRES LS 83 6/20/78 8939 MAT-SU BORO 518 17 NORTH 1 WEST 29 CCAAt-1 M-W DRILLING SNOWSHOE ELEM SCHOOL WELL 6/13!79 8932 WILLOW BARK INV 605 17 NORTH 1 WEST 24 DADAt-5 PENN JERSEV DRILLI SOURDOUGH WLDRNS TR-A B1 8/1!77 16657 MELNEDT, ROGER 400 18 NORTH 1 WEST 15 DDDC1-3 PENN JERSEV DRILLI SEC 15 L-DS 1/14/85 4243 TOWNER, WYATT 405 18 NORTH 1 EAST 3 ADCA1-5 MOORE DRILLING GOLD RUSH EST 3 L36 84 4/10/84 14750 UNITED BANK OF AK 405 18 NORTH 1 EAST 19 ACCD3-23 WHEATON WATER WELL FISHHOOK W L4 B2 WEL#2 7/28/87 13956 DOLLARHIDE, FLOYD 460 18 NORTH 1 EAST 19 ACDC1-25 BIG DIPPER DRILLIN FISHHOOK W L3A B3 / / 14865 FIRST NATL BANKAK 545 18 NORTH 1 EAST 8 CDDA1-7 WHEATON WATER WELL MCDOWELL TR-E 10/9/87 STATE OF ALASKA DEPARTMENT OF NATURAL RESOURCES DIVISION OF MINING & WATER MG MT. HYDROLOGIC SURVEY 3601 C STREET, SUITE 800 ANCHORAGE, ALASKA, 99503-5935 MAIN PHONE: (907)269-8624 ROY IRELAND: (907)269-6639 • •• M • Table 3: PIONEER UNIT AR EA DEEP EXPLORATORY W ELLS WEEEhJAME OPERATOR SECT TWP RNG STATUS COMPLETED MCA KNIKARM ST 1 UNION 1 14N UU4W P&A 8/31/63 6,106 LORRAINE ST 1 ARCO 21 14N 004W P&A 2/25/66 8,010 BIG LAKE USA 1 PAN AM 1 15N 004W P8cA 10/21 /68 6,026 SUSITNA ST UNIT 1 HUMBLE 18 15N 004W P&A 3/12/64 12,550 MIDDLE LK UNIT 1 GULF 22 15N 005W P&A 4/3/69 9,742 FIGURE EIGHT UNIT 1 UNION 15 15N 006W P8cA 3/15/76 10,660 BELL ISLAND UNIT #1 1 BRIT AMER 12 15N 007W P8cA 5/31 /62 11,364 ISLA GRANDE 1 AMAREX 36 15N 008W P8cA 4/9/75 11,801 KNIKARM 2 UNION 5 16N 003W P8cA 10/22/60 3,215 FISH CK UNIT 12-8 UNION 8 16N 003W P8cA 10/2/61 6,418 KNIKARM 1 UNION 2 16N 004W P8cA 10/8/60 3,013 NEEDHAM 1 7 17N 001E P&A 5/7/66 6,004 WALLACE-KNUTSON 1-A AGOD 23 17N 001 W P&A 4/30/66 6,146 WASILLA ST 1 BP 33 17N 001 W P&A 2/25/63 4,849 BIG LAKE BLT-Ol ARCO 22 17N 003W P&A 3/24/92 6,200 AM 9UASAR BIG LK 1 AM C~UASAR 22 17N 003W P&A 1/6/72 6,307 HORSESHOE LK ST 1 GREAT PLAINS 1 17N 004W P8cA 5/15/73 8,230 FISH CK 1 INLET OIL 13 17N 006W P8cA 3/29/69 2,035 FISHHOOK 1 HILL 3 18N 001E P8cA 5/7/69 2,384 ALASKA 94 CBM 1 AK DNR 31 18N 001 W P8cA 5/24/94 1,245 PITTMAN 1 UNION 33 18N 002W P8cA 5/27/62 6,136 HOUSTON 1 18 18N 003W P8cA 10/00/55 2,135 HOUSTON CORE HOLE 3 18 18N 003W P&A 1 /00/51 386 HOUSTON CORE HOLE 1 20 18N 003W P&A 11 /00/51 482 HOUSTON CORE HOLE 2 20 18N 003W P8cA 1/00/51 1,142 ROSETTA 1 AGOD 20 18N 003W P&A 6/30/59 4,260 ROSETTA 2 X 20 18N 003W P8cA 5/21/56 1,100 ROSETTA 4-A AGOD 21 18N 003W P&A 9/24/62 2,407 ROSETTA 4 AGOD 21 18N 003W SUSP 10/7/61 1,627 ROSETTA 3 AGOD 21 18N 003W SUSP 8/1/59 6,109 BEAVER LAKES ST 1 LOVELY 32 18N 003W P&A 9/18/75 8,474 RED SHIRT LK 1 HILL 27 18N 005W P8cA 12/14/68 2,074 C~ LJ •• M • Table 4: WATER RECOVERY FROM PION EER UNIT AREA DEEP EXPLORATORY WELLS WELL NAME OPERATOR SECT TWP RNG INTERVAL RECOVE(?Y BIG LAKE BLT-O1 ARCO 22 17N 003W 3 tests from 4800' to 6100 no water, sm amounts of as AM QUASAR BIG LK 1 AM QUASAR 22 17N 003W ell kicked from 1870'-193 Two samples of mud/reservoir fluid mixture collected during kick; TDS of 3049ppm and 1709ppm, mud filtrate HORSESHOE LK ST 1 GREAT PLAINS 1 17N 004W 2950'-3084' 680' of mudd salt water- TDS= 3850 4246'-4310' 354' of water cut drillin mud TDS= 3300 PITTMAN 1 UNION 33 18N 002W 1103'-1158' Gas to surface in 3 minutes, water to surface in 40 minutes at 1206/d rate. No TDS measurement 2709'-2747' Flowed 100bb1s of "salt water"/d rate, No TDS measurement 3577'-3595 1030' of "salt water" in i s 3577'-3595' 65' of "salt water" in i e ROSETTA 4 AGOD 21 18N 003W 1589'-1624' Flowed "salt water & gas", No TDS or rates measured 1609'-1620' Flowed "salt water & gas", No TDS or rates measured 1533'-1564' Flowed "salt water & gas", No TDS or rates measured ROSETTA 3 AGOD 21 18N 003W 2103'-2193' Flowed "salt water & gas", No TDS or rates measured BEAVER LAKES ST 1 LOVELY 32 18N 003W 1846'-1856' 20' of "salt water" in i e 2874'-2886' 75' of "salt water" in i e 3164'-3174' 240' of "salt water" in i s 3120'-3136' 20' of "salt water" in i e 3956'-3971' 30' of "salt water" in i e U • S • • Table 5 Comparison of Measured TDS of produced fluid with Calculated TDS of Tested Zone in Horseshoe Lake State #1 Rmf 0.53 Temp Rmf BO Total Depth 8226 Temp of Rw Measurement 60 Temp at TD 132 Temp @ Surtace 35 Temp Gradient 1.1 791 8 7941 Matrix Density 2.67 Matrix TT 53 Compaction Factor 1 a 0.62 m 2.15 TDS (DenMeut) Average 6751 ppm TDS (Sonic) Average 3273 ppm Actual measured TDS of produced fluid 3850 ppm Depth Rild Density Porosity Neutron Porosity Sonic Porosity TDS (Den/Neut) TDS (Sonic) 2932 7.7 0.17 0.34 0.35 8998 4364 2934 7.8 0.18 0.32 0.35 9480 4358 2936 7.8 0.18 0.34 0.35 8601 4346 2938 7.7 0.18 0.34 0.36 8778 4240 2940 7.6 0.19 0.34 0.37 8386 4032 2942 7.7 0.20 0.35 0.37 7577 3981 2944 7.9 0.19 0.34 0.36 8064 4022 2946 B.7 0.20 0.33 0.35 7248 3988 2948 10.3 0.20 0.34 0.34 5788 3488 2950 11.2 0.20 0.33 0.30 5517 4337 2952 9.3 0.20 0.32 0.29 7212 5666 2954 7.9 0.17 0.3 0.30 10809 6194 2956 8.1 0.21 0.32 0.35 7958 4251 2958 9.1 0.19 0.34 0.35 6921 3698 2960 10.0 0.20 0.31 0.34 6808 3567 2962 9.0 0.19 0.35 0.36 6722 3458 2964 8.9 0.20 0.34 0.38 6925 3205 2966 9.4 0.19 0.35 0.36 6399 3287 2968 9.6 0.19 0.31 0.35 7689 3474 2970 8.1 0.15 0.29 0.35 12052 4261 2972 7.8 0.20 0.34 0.38 7764 3622 2980 7.2 0.19 0.35 0.36 8648 4367 2982 6.8 0.19 0.34 0.35 9669 5052 2984 7.5 0.20 0.36 0.34 7591 4675 2986 9.1 0.19 0.34 0.34 7087 3931 2988 8.8 0.16 0.29 0.34 10724 4205 3024 11.9 0.16 0.29 0.33 7472 3083 3026 12.4 0.20 0.31 0.36 5350 2544 3028 12.8 0.19 0.31 0.40 5448 1940 3030 13.0 0.20 0.32 0.40 4867 1873 3032 13.0 0.22 0.32 0.40 4610 1876 3034 13.1 0.22 0.32 0.40 4457 1871 3036 12.6 0.21 0.32 0.40 4881 1957 3038 11.7 0.22 0.33 0.39 4955 2168 3040 11.1 0.20 0.33 0.39 5479 2333 3042 10.8 0.21 0.32 0.39 5719 2387 3044 12.8 0.18 0.3 0.36 6003 2378 3052 11.2 0.12 0.27 0.34 11114 3116 3054 11.0 0.19 0.31 0.38 6570 2443 3056 11.5 0.20 0.32 0.37 5521 2532 3066 10.1 0.19 0.43 0.34 4358 3433 3068 11.1 0.11 0.39 0.33 6243 3342 3070 11.2 0.12 0.39 0.34 6000 3146 3072 11.2 0.13 0.39 0.34 5862 3099 3074 12.6 0.13 0.35 0.34 6000 2797 3076 15.5 0.11 0.31 0.33 6481 2450 3078 15.4 0.16 0.3 0.32 5351 2590 3080 12.9 0.16 0.37 0.36 4811 2407 3082 12.7 0.20 0.36 0.37 4157 2242 3084 13.6 0.21 0.32 0.40 4481 1787 3086 13.8 0.20 0.34 0.39 4237 1777 3088 13.2 0.22 0.33 0.39 4307 1895 3090 12.8 0.23 0.36 0.39 3666 1930 • • • • • Table 6 Comparison of Measured TDS of produced fluid with Calculated TDS of Kick Zone in American Quasar Big Lake #1 Rmf 3.05 Temp Rmf 91 Total Depth 6095 Temp at TD 118 Temp ~ Surface 35 Temp Gradient 1.361771944 Matrix Density 2.67 Matrix TT 53 Compaction Factor 1 a 0.62 m 2.15 TDS (Den/Neut) Average 7881 ppm TDS (Sonic) Average 3154 ppm Actual measured TDS of produced fluid 3049 ppm 1709 ppm Depth Rt Density porosity Sonic Porosity TDSden(ppm) TDSson(ppm) 1905 13.0 0.26 0.32 5559 3518 1906 13.6 0.30 0.33 3979 3183 1907 14.2 0.21 0.33 8099 2928 1908 14.8 0.18 0.34 11727 2706 1909 15.3 0.19 0.34 9611 2557 1910 15.5 0.22 0.35 7206 2474 1916 11.9 0.23 0.37 8092 2757 1917 11.6 0.25 0.35 7208 3233 1918 12.1 0.24 0.35 7581 3092 1919 13.7 0.22 0.35 8231 2658 1923 11.3 0.19 0.31 13291 4334 1924 10.0 0.24 0.33 9399 4349 1925 10.3 0.23 0.34 9769 3931 1926 10.7 0.22 0.35 10448 3526 1927 11.0 0.25 0.37 7556 3087 1928 10.5 0.26 0.39 7264 2841 1929 9.8 0.33 0.40 4455 2792 1930 9.2 0.45 0.42 2383 2802 • C APPENDIX 1 • • • Water Welis Located on Nine Sections Surrounding Pioneer Class II Waste Disposal Well #1702-15DA-WDW The one to tour letters under'Spot Location" represent the four quarters, from largest to smallest, taken counter clockwise. For example: CDAB (reversed and translated to the standard convention) means NW 1/4("B") of NE 1/4("A') of SE 1/4("D'~ d SW 1/4("C") KEY Owner Total Township Range Seetion Spot Location Drilling Company Sub-Division Drill Date De th North West 16754 DUBEAU, AL ANDY 0 17 2 9 BCDA7-9 AQUA DRILLING END OF RAINBOW L28 B2 / / 15586 PATTERSON, WILLIS 33 17 2 9 BCDD1-6 DAVIS WELL DRILLIN END OF RAINBOW L27 B2 / ! 16465 WADE, BRUCE VALDA 41 17 2 9 CBDD1-8 MCKAV WELL DRILLIN END OF THE RAINBOW L487 11/20/76 8957 BOZINOFF, KENNETH K 46 17 2 9 DB8B2-1 VALLEY DRILLING THE SAVANNAH L7 B7 1/1176 10017 WIDMER, KENNETH 46 77 2 9 BCAAt-5 MOON DRILLING - END OF THE RAINBOW L587 6/21/77 17994 WILSON, JOHN/MARY 49 17 2 9 BCCA UNKNOWN END OF THE RAINROW L7 B2 4/7/77 1884 POOLE, BOB 50 17 2 9 BDD81-4 MOON DRILLING END OF RAINBOW L5 B4 7/8/82 12793 NORTHERN INTERIORS 50 17 2 9 DURBIN DRILLING THE SAVANNAH L4 81 7/31/85 22031 CEDERBORG, CYRIL 59 17 2 9 CBBB MCKAY WELL DRILLIN END OF THE RAINBOW L1 62 9/1/90 9798 SANDAVILLE, CINDY 61 17 2 9 GIELAROWSKI JOE DR 7/5185 15715 NAIL, CLYDE 63 17 2 9 AACB7-7 FRIESEN DRILLING SEC 9 L-A10 7/28/83 7565 88J 101 17 2 9 AA WHEATON WATER WELL RAINBOW PROPERTY WELL 1 8r24/08 7566 B$J 101 17 2 9 AA WHEATON WATER WELL RAINBOW PROPERTY WELL 2 7/19/84 8958 81RDWELL, TERRY 51 17 2 10 BBCA MOFFITT DRILLING RAINBOW LAKE LODGE 4/24/70 4268 GARRISON, CARL 110 17 2 10 DCCC DAVIS DRILLING AIRPLANE ACRES L01 B1 7/6/84 23475 49'ER HOMEOWNERS ASS 118 17 2 10 BCCC 49'ER L02 TR B / / 21108 ALDRIDGE, BILL 41 17 2 11 JOE GIELAROWSKI DR MOOSE CREEK AREA LOT D3 7/31/91 12340 LAUVER, KEVIN 58 17 2 11 CBBBt-5 DURBIN DRILLING KRANBERRY HILLS L7 B7 8/29/85 3710 BAGLEY,JIM 60 17 2 11 CBBDt-4 WHEATON WATER WELL KRANBERRY HILLS L3 B2 12/31/82 7527 BALES, CINDY 68 17 2 11 CCBAt-6 B $ B DRILLING KRANBERRY HILLS TR-A 64 9/883 4264 JOHNSON, R C 73 17 2 11 DAVIS DRILLING KRANBERRY HILL L7 B2 5/4/84 8959 HAGGENBURGER, CLAUS 88 17 2 11 DACC7-3 VALLEY DRILLING LAKE WALLACE L72 2/17/77 8074 PAGE, JAMES/LINDA 84 17 2 14 BCDCi-2 BEAR DRILLING EYRIE HEIGHTS I L6 B7 7/23/85 5856 RAYMOND, MICHAEL 100 17 2 14 BCBC7-1 MCKAY WELL DRILLIN EYRIE HEIGHTS II L5 B2 5/21/83 12663 CARNEY BLDRS 80 17 2 15 DURBIN DRILLING BRUNS L09 63 10/28/84 17986 DRAKE, ROBERT 80 17 2 15 BBAA McKAY WELL DRILLIN BRUNS L09 61 7/72/84 2672 MAY, JOSEPH/CINDY 90 17 2 15 ADAB7-1 HDA DRILLING BROOKRIDGE EST L02 B4 3/31/78 12564 DYER, SKIPPER/CHERYL 100 17 2 15 ADBA ADA DRILLING BROOKRIDGE EST LOt B4 4/Sr78 21096 KEVAN, MICHAEL A. 101 17 2 t5 JOE GIELAROWSKI DR BROOKRIDGE EST LOt 81 5/11/91 21101 GANZE, DAVID 101 17 2 15 JOE GIELAROWSKI DR BROOKRIDGE EST L04 B4 5/17/91 16684 STAENGEL, JAMES 123 17 2 15 BBAD ARCTIC DRILLING BRUNS L10 B3 5/24185 13970 MATSU BORO 38 17 2 22 DCDC7-9 UNKNOWN BIG LAKE LANDFILL MW-3 / / 8963 PIERCE, WALT 196 17 2 22 CBDDt-2 M-W DRILLING TIERRA VERDE L07 81 6/30176 8964 JACKSON, KENNETH 197 17 2 22 DAAA7-1 FOSS DRILLING WASILLA AREA 9/i 0/74 23529 VAN HOUT, M 200 417 2 22 DC HOOD $ SONS L-De 8/6/96 22734 GALLEAR, ELDON 278 17 2 22 DDDB HOOD 8 SON'S BEVERLY HILLS L3 Bt 5125/95 16741 HARGETT, DAVID 125 17 2 23 DDDD UNKNOWN HOLLANRIDGE L09 BS / / 12354 LONNIE ROBINSON CONS 138 17 2 23 D DURBIN DRILLING HOLLANRIDGE L15 B4 3/30/84 12356 LONNIE ROBINSON CONS 136 17 2 23 D DURBIN DRILLING HOLLANRIDGE LOS BS 3/10/84 3440 LORICH INC 140 17 2 23 D M-W DRILLING HOLLANRIDGE L17 B4 11/19/83 3509 LORICH, INC 140 17 2 23 DCAD M-W DRILLING HOLLANRIDGE L03 B6 W#1 10/15/83 23665 KENYON, T 140 17 2 23 B HOOD 8 SONS MONTCLAIR L02 B7 8/18/96 3350 LOGUE, RUTH 141 17 2 23 DDCC7-7 WHEATON WATER WELL HOLLANRIDGE L03 B5 8/31/83 14650 LORICH INC 141 17 2 23 DCDA WHEATON WATER WELL HOLLANRIDGE LO7 Bfi &6/83 15719 MAXWELL, HAROLD 143 17 2 23 DCAD1-9 FRIESEN DRILLING HOLLANRIDGE L04 86 9/21/83 3508 LORICH, INC 149 17 2 23 D M-W DRILLING HOLLANRIDGE L04 B7 W#2 10/71/83 3443 LORICH INC 153 17 2 23 D M-W DRILLING HOLLANRIDGE L24 B4 11/18183 14829 ANDERSON. ROBERT C 156 17 2 23 CCCC7-6 MARTINS WATER WELL BIRCH HILLS EST L01 62 11/26/86 15203 ANDERSON, ROBERT C 156 17 2 23 CCCC MARTINS WATER WELL BIRCH HILLS EST L01 82 11/26/86 12357 ROFFS CONST 157 17 2 23 DCDA DURBIN DRILLING HOLLANRIDGE L02 B6 10/25/83 12353 ROFFS CONST 158 17 2 23 D DURBIN DRILLING HOLLANRIDGE L04 84 3/29/84 12355 LONNIE ROBINSON CONS 158 17 2 23 D DURBIN DRILLING HOLLANRIDGE L22 64 4/5/84 12361 LONNIE ROBINSON CONS 158 17 2 23 D DURBIN DRILLING HOLLANRIDGE L05 B7 1/10/84 3439 LORICH INC 159 17 2 23 D M-W DRILLING HOLLANRIDGE L20 84 11/20/83 5403 BUNDTROCK, TERRY 159 17 2 23 CACA M-W DRILLING BIRCH HILLS EST L44 B7 2116/84 3442 LORICH INC 160 17 2 23 D M-W DRILLING HOLLANRIDGE L12 B3 11/21/83 3511 NOVO INVESTMENTS 160 17 2 23 D M-W DRILLING HOLLANRIDGE L09 B6 10/17/83 4300 ROBINSON CONST, LONN 160 17 2 23 DBCD DURBIN DRILLING HOLLANRIDGE L02 B4 4/1/84 12360 ROFFS CONST 160 17 2 23 DBDD DURBIN DRILLING HOLLANRIDGE LO7 87 10/26/83 14333 CHINOOK PLG 8 HT 161 17 2 23 D WHEATON WATER WELL HOLLANRIDGE L07 66 10/21/83 14856 LORICH INC 161 17 2 23 D WHEATON WATER WELL HOLLANRIDGE L21 B4 4/4/84 14914 LORICH INC 161 17 2 23 D WHEATON WATER WELL HOLLANRIDGE LO6 B4 9/27/84 15379 SCHEEL, ROBERT 161 17 2 23 DBDD MOON DRILLING HOLLANRIDGE LOZ B7 9/28r83 14792 SCHEEL, ROBERT 163 17 2 23 DBDD MOON DRILLING HOLLANRIDGE L02 87 / / 12358 LONNIE ROBINSON CONS 166 17 2 23 D DURBIN DRILLING HOLLANRIDGE L72 B6 5/21/84 12362 CASEY/BERNALDO 166 17 2 23 DDBA7-11 DURBIN DRILLING HOLLANRIDGE L07 67 313/84 12359 LONNIE ROBINSON CONS 168 17 2 23 D DURBIN DRILLING HOLLANRIDGE L13 B6 5/21/84 12352 ROFFS CONST 178 17 2 23 D DURBIN DRILLING HOLLANRIDGE L10 B3 10/28/83 4048 LORICH, INC 179 17 2 23 D M-W DRILLING HOLLANRIDGE L14 B3 10/24/83 2834 ANDERSON, IRENE 180 17 2 23 CBBCt-4 H 8 H DRILLING BIRCH HILLS EST L01 BS 7/15/82 4298 ROBINSON CONST, LONN 180 17 2 23 D DURBIN DRILLING HOLLANRIDGE L73 81 3/31/84 1677 CHINOOK PLUMBING 181 17 2 23 DBBC1-13 WHEATON WATER WELL HOLLANRIDGE L04 B7 4/20/84 • (continued): Water Wells Located on Nine Sections Surrounding Pioneer Class II Waste Disposal Well #1702-15DA-WDW The one to tour letters uMer'Spot Location" represent the four quarters, from largest to smallest, taken counter clockwise. For example: CDAB (reversed and translated to the standard convention) means NW 1/4("B'~ of NE 1/4("A") of SE 1/4("D") of SW 1/4("C") KEV Owner Total Township Range Section Spot Location Drilling Company Sub-Division Drill Data Depth North West 12351 LONNIE ROBINSON CONS 186 17 2 23 D DURBIN DRILLING HOLLANRIDGE L09 B3 11/15/84 9740 BITTEROOT CONST 190 17 2 23 B PIONEER DRILLING MONTCLAIR L13 BS 7/24/85 22732 PALMOUIST, MIKE 192 17 2 23 B HOOD 8 SON'S MONTCLAIR L13 B7 5/28/95 9741 MARTIN, JAMES/CINDI 193 17 2 23 BDDCt-5 PIONEER DRILLING MONTCLAIR 2 L15 BS 7/22/85 12342 LONNIE ROBINSON CONS 196 17 2 23 D DURBIN DRILLING HOLLANRIDGE L08 B/ 11/20/84 23713 GRAHAM, L 196 17 2 23 B HOOD & SONS MONTCLAIR i LOS 83 5/21/97 8251 STURE, DIRK 200 17 2 23 CCAB7-10 JERRY'S DRILLING BIRCH HILLS EST L21 82 8/10182 9743 BITTEROOT CONST 200 17 2 23 B PIONEER DRILLING MONTCLAIR L76 BS 5121/85 15899 THOMPSON, MYRL 200 17 2 23 CCAB HOOD & SON'S DRILL BIRCH HILLS EST L22 82 9/16/91 23881 MOHN, JUDY BALDWIN 200 17 2 23 BCCC HOOD 8 SONS DRL MONTCLAIR 1 L72 B3 8114797 24108 TRIPLET7, BOB 201 17 2 23 BDBA JAY WILLIAMS MONTCLAIRE 2 L74 B6 6/17/94 9742 BIT7ER00T CONST 205 17 2 23 B PIONEER DRILLING MONTCLAIR L17 B6 5/25/85 12341 LONNIE R081NSON CONS 208 17 2 23 DBBB DURBIN DRILLING HOLLANRIDGE L02 Bi 9/17/84 12350 LONNIE ROBINSON CONS 208 17 2 23 D DURBIN DRILLING HOLLANRIDGE L04 83 9/15/84 12344 BENNETT, ROBERT JR 211 17 2 23 DBBA7-12 DURBIN DRILLING HOLLANRIDGE L01 62 3/3/84 12349 LONNIE ROBINSON CONS 213 17 2 23 DBAC DURBIN DRILLING HOLLANRIDGE L03 B3 11/7/84 18079 RHODUS, MURRAY/NONA 214 17 2 23 DBAD7-14 MOON DRILLING HOLLANRIDGE L01 B3 4/27/84 23785 HABITAT FOR HUMANITY - 214 17 2 23 BDBC M-W DRL MONTCLAIRE L04 87 6/10/97 2628 GOURLEY, JOHN 217 17 2 23 CDDC1-3 VALLEY DRILLING BIRCH HILLS EST L17 B3 3/18/82 12343 ROFFS CONST 217 17 2 23 D DURBIN DRILLING HOLLANRIDGE L09 B7 11/14/83 15609 CASH, KENNETH 217 17 2 23 CDDC7-3 VALLEY DRILLING BIRCH HILLS EST L17 B3 &18/82 1771 MCMAHEN, TIM 218 17 2 23 CDCA VALLEY DRILLING BIRCH HILLS EST L39 B3 3/24/82 12345 LONNIE ROBINSON CONS 218 17 2 23 DBBA DURBIN DRILLING HOLLANRIDGE L02 82 7/24/84 12347 LONNIE ROBINSON CONS 218 17 2 23 D DURBIN DRILLING HOLLANRIDGE LOS B2 4/11/84 24140 BELLISTON, HARRY 218 17 2 23 BDDB PIONEER DRILLING MONTCLAIRE 2 L10 BS 8/9/86 8965 CRUMP, CHARLES 220 17 2 23 CCD61-1 M-W DRILLING BIRCH HILLS EST L15.17 10/3/78 23748 STUTHARD, D 8 M 220 17 2 23 CBAD DENALI DRILLING BIRCH HILLS EST Lit B8 7/8/95 24145 SUTHERLAND, TIM 220 17 2 23 B HOOD & SONS MONTCLAIRE LOS 87 9/30/97 4153 RUDDELL, ERNEST 221 17 2 23 CBAD M-W DRILLING BIRCH HILLS EST L12 BB 5/9/84 10877 EARTHLIGHT HOMES 222 17 2 23 D WHEATON WATER WELL HOLLANRIDGE L70 B6 7/22/83 14913 LORICH INC 222 17 2 23 D WHEATON WATER WELL HOLLANRIDGE L06 83 8/14/84 11678 ANKROM, CHRIS/GAIL 227 17 2 23 DBA61-8 MOON DRILLING HOLLANRIDGEL04 B2 9/6/63 1255 SISK, KACEVDORIS 228 17 2 23 CCAC7-2 H & H DRILLING BIRCH HILLS EST L07,8 B2 6725/79 12348 LONNIE ROBINSON CONS 232 17 2 23 D DURBIN DRILLING HOLLANRIDGE L07 B2 4/14784 22712 OLSEN, KEN 237 17 2 23 CBAC HOOD & SON'S BIRCH HILLS EST L09 88 8/4/94 12660 BAAS, RON 240 17 2 23 CDAD DURBIN DRILLING BIRCH HILLS EST L30 B3 3/17/84 17931 DAY, DAVID 240 17 2 23 CBDB JOE GIELAROWSKI DR BIRCH HILLS EST L57 B7 3/16/89 12346 SERENCHA, CARVPATTY 305 17 2 23 DBAA DURBIN DRILLING HOLLANRIDGE LOS 82 1/6/83 STATE OF ALASKA DEPARTMENT OF NATURAL RESOURCES DIVISION OF MINING & WATER MGMT. HYDROLOGIC SURVEY 3601 C STREET. SUITE 800 ANCHORAGE, ALASKA, 99503-5935 MAIN PHONE: (907)269-8624 ROY IRELAND: (907)269-8639 • • APPENDIX 2 • CI-IEMICAL ~ GI•;OLOGI~,A~AT3ORATORII~S I.TD. _ 'g a ~ ~ 11~ 1 ~ WOw4TM1(J Date Reported: June 5,1973 Laboratory Report Number: C73-16-1 GREAT PLAINS DEVELOPMENT COMPANY OF CANADA LTD. C73-16-2: 354' above tool. Resistivity determined on a dark brown filtrate recovered from watery mud. RESISTIVITY: 0.480 OHM meters at 68°F. C73-16-3: 266' above tool. Sample description same as above. RESISTIVITY: 0.475 OHM meters at 68°F. C73-16-4:178' Above tool. Sample description same as above. RESISTIVITY: 0.492.OHM meters at 68°F. C73-16-5: 90' above tool. Resistivity determined on a dark brown filtrate recovered from muddy water. RESISTIVITY: 0.553 OHM meters at 68°F. C73-16-6: Above tool. Sample description same as -5. RESISTIVITY: 0.586 OHM meters at 68°F. • • ~.,/ lJ !~ i I LJ L I W 1 11'1 i~ . '' ~ CN~~NdIC'' . C~OLOG~CAL L~aS01'~A" ---, ~S Ll"D. t`1-`=. ~ • ~'i''-'' E~NTON - FORT 6T. JOHN - CALOAn~ [DNTAINTR IDENTITY - - WATER ANALYSIS - .. ,_ . 1_ I- ~',`:`~~ ;:;_~- ,s•.' LAeoRATOaY NuI+eER C73-17-1 - OPERATOR NAME AND ADDRESS _ GREAT PLAINS DEVELOPMENT COMPANY OP' CANADA LTD. 736 - 8 Ave. S.W. Calgary , _. .... _.. - . - CLEvATIONS . . SAMPLE LOCATION wEll OR SAMPLE LOCATION NAME Ke GAD. ,_ _ ._.__.. .._-- -- --._. r. ~_1-17N-4[1-SM i GP Noel etal Horse Shoe Lake State ~I1 ~ i 205.5' 191.6' ilELO OR AREA POOL OR LONE NAME Of SAMPLER COMPANY _ Cook Inlet _.. .i I . -.C Sands _. _ . _ . , J . Yelnik _ _.~ ~_ Lynes_ United _ ..: TEST TYPE G NO. TEST RECOVERY ~. D.S.T. ! _4 . I _.--450'-.drilling mud,. 680' .salt_-water,-.watery mud. TEST INTERVAL OR PERFS POINT OF SAMPLE AMT, (. TYPE Of CUSHION MUD RESISTIVITY ~ .. _ i _ ._ ... ....._. _._. __. _._ ._... .... 1.. .._.. _._ : i ~..._ .Top... ---. .. _.. ... .._..- - - ---. ..__ ~ .-- ---- - --._; I_. __ _ _. _ o . _.. 'f ~ 2950' - 3085' i I .. - I _ _TYPE OF PRODUCTION --- I - _ -- - ;PUMPING ~ ;FLOWING I !GAS LIFT i ;SWAB j .._ .. ._ _. ....__ ~. .. ... .._._ .... __ ..._ I ! ,~ - -~~ ~ - PRODUCTION RATES ~ - - - _ ... _. I :WATER sell/0 'OIL BBLS/D. 'GAS MCf/D ~_ ,.. _....___.. -. _....--- .. _. ._.. ___.-1 1....-------_.._..---- --..___. l_.._. - --- PRESSURES - PSIG - CONTAINER WHEN WHEN SEPARATOR TREATER RESERVOIR SAMPLED RECEIVED I. I._..._. .-.. - _ . 1 . , I - . I 1 1 i . I . GATE SAMPLED 10/M/YI DATE RECEIVED 10/M/Y1 DATE ANALYZED 10/M/Y1 L__ 12/5/73 _J _.25/5/73----_ J 1,.__1/6/73----- ~-~ ~ f ~ r -,---._ .._.__.. ~._..._ ._ . _., _.._.. - , ! ION ! MG/L I MG% ~ MEO/L I I ION i MG/L ; MG% I MEO/L l Na i 5297 ~ 36.90 i 230.41 ' ! cl i 5510 138.38 I 155.38 j I ~ i-. _____ .._.__-I ~._ _._ _ __ _~.' ' ..~ I K j ~ I i t Br I I i l I ! j._ {-- -~-----, I , - , , { ce I 52 I 0.36 ~. 2.59 { i ' I------ ----i _. ..._I I {... .....I__~ .- - I MQ { 2 ~ 0.01 i 0.16 ~ ~ "col, 1775 { 12.36 I 29.11 ~_.-- ~------~ -i-------~ {-. _. _--1--- ._. - ~--- i ' eo ~ { ~ j l so, 683 4.76 1 14.21 I __ ' I I i ~ L_. ' ~ sr { I j co,' 1035 7.21 34.46 1 { i I.._ I F. I present ~ { I °H . NIL I ~ I . : l ~ 1 I .. ~ .... .. __.. ..-~-- 1 r----i . ' ' I ! ~ ' t . ,NS• NIL i . ~ I i I , LOGARITHMIC PATTERN MEQ PER LITER -I~1 ~~1 i'I{i 11-1~,;1ji ~ l~~jm~Tl';{~ ij 1-~~ I'll I ~'! 1 I Ilj , II~::.1 111.,1,.!1 :;I ~ 1~ I l IIiII il. iI I ~ ; : I .; i i , I , . I ll•~ I I ' ,: I I I : IIIj , ~. I ~;~ I!.I I , , ~ : I Iti i. ; ,~: ; i i ;ll': I : ~ I 'I I I I ~ I i., Na uia~:" ';:,;;:; , ~,.I, I! I,:ll,: :.I~I:I) I, .;ll„t :,;,I,I 1 ,II,I I ~ I ii~ i;~illl'I...ii;li I••.Iili y~lijll illlllll i I ;,1111 I IIII Illi. II I'~II I'; I; I{ I l;l, i it I ~! i {i , ~1i1: I;; I i~ l !, i~ i l~ j{il t I ':~ i , ,Iij { ~ l I l; 'i i I I i ~~{I III Ijil ~ I~ I i( ~ i II'i ' i l l ill'{ ;'1111111 I{~ 11:1'111 ~ IIII III' 411,1 I;':i~{,i li Iill Ca LL,,. ~._~ll„1111 ,, ; :l II ,. I.IL. 1,;;, ~;1~1 i ,;,~iIII~ ~!;II;I . ' ;,I~~ ~.~ ~ ~lil,i,; i ;;t1;i :,, ~~ `.1~,~ ; i~ II ,~ l I 1 i '{I {~ I ~ ~ I'll's ~~ ~ ~{! ~i~ i i~ I I I lip ~ i i I lil I I I I ijli ~~: I{ I ~ i ~' iIi ; ~ {, I~jl ;:., ,; ;',Ili' ~ I :,,; I I i•u' ' ~ ~ I I ~ !Ill I { i M ,...,... ..{_., i..1~ - i{~ '•-- ~ 'I I•-tjj~I1 is _{ I .I{ i ~ I ~~ ~I- ` ~,) ~~I; ~~~ ,, ~j~;~r4i ~-,,I{{Ir ~ -I;,;~{l ~I 111 1 r I ~ I ~I II Iilli I +I 1 I~I ii 11111;1.1 ~ ~ji;ll I !~! {i i' ~'il~ll ~ ; 111 ii ll j ~,I I II~- . ; .l l li ;ill II 111111 I 1111 1111111 I II ll l it I;;;ili i,il~( diIlIl{II ,' ~ ;il 1 1 I ~ I I l i IIII I .:.' ,~~ ~i~i~~l l _I!l~~ll _ -Ii~lill_I~.l-1_i~ I_l__ J..l _ I~ __ I I __l I IlL . llli~ j t )I j ~ s - t e: - c i ~~ TEMPERATURES ('F) CONiA{NER WHEN WHEN SEPARATOR TREATER SAMPLED RECEIVED ANALYST REMARKS LE._Neubauer.-_J jSlight trace of oil on last ; sample salinity 3850 ppm. TOTAL SOIIDS MG/l _ 8Y EVAPO/~R ATION eY EVAPORATION I _17,11\/Ce !'0°C~ t, (e IBO"C AT IGNITION CAI [UL ATEO 1_..13,170__.._._! . ~. 14,354 Organic matter -Very Much _ SPECIE IC GRAVITY- REf RACTWE IN OEK ~__1.. 014. ------ °.b~°F ~ i _ 1.3360 ~ IS°C: OBSERVED PN RESISTIVITY -IO~In /n.,t tr al 1__.9.7_ _._... ~ 81 °i+. i. 0.464 - ~ ZS°[: Remarks and Conclusions Analysis determined on a dark brown filtrate recovered from watery mud. I I lil CI Ii I~~ ~ i HCO, I{ I~~ ~:i . i.i.l SO ~I,I 111 1 I ~ co, -11 ill >< y f M -~ I' ~i~ :~.~ C OH TAI NlR IOEN TITY L_ ~~ _. i.,., CHEN~fC~ GEOLOGICAL LARORA' IFS LTD. ))_ ~!~ ~~ ONTON - FORT ST. JOHN - CALOJIR~ `r~' - WATER ANALYSIS - LABORATORY NUMBER j C73-14 ' OPERATOR NAME ANO ADDRESS GREAT PLAINS DEVELOPMENT COMPANY OF CANADA, LTD. 736 - 8 Ave._S-.W.._-__Calgary SAMPLE IOCAT10N W ELEveTIONi .__ ,____ Ell OR SAMPLE LOCATION NAM[ KB GRD. 1-17N-4W-SM -! l GP Noel etal Horse..Shoe Lake State ~fl ._~ x_.205.5' 191.6' - FIELD OR AREA POOL OR 20NE NAME OF SAMPLER COMPANY Cook Inlet _, { - D Sands _ _ _.____-_. ._.._ _ ~ J. Yelenik ____ _ -_._ I_-Lynes United TEST TYPE G N0. .. TEST RECOVERY .. D. S.T. ~ 1 I { _ . .- 90.'_ drilling mud. - TEST INTERVAL OR PERFS POINT OF SAMPLE AMT. L TYPE OF CUSHION MUO RESISTIVITY '' Tool . I I I __ ---• ~ 6800' - 6910' I -TYPE OF PRODUCTION - - _ _ _. .. _... .. - I (PUMPING ~ .FLOWING __ _ 7 I (GAS LIFT 7 ;SWAB , ...._.. I - - PR ' ODUCTION RATES ~ -- ~ - - ~ - - _ .... _ .__..... ___ .__ I .. . ;WATER ._...-_ . ..-- - __.. ._-...... .. _ __._. .. _ BBLS/D~ (OIL ... _.. ... I L--- - _.. ---_ ..---- .. - --- BBLS/0{ GAS - .__... _.__. _~._ .., ...._. _ .. _.....-_ MCF/D• _.. - - PRESSURES - PSIG - - - - - - - ~- TEMPERAT URES (°FI CONTAINER CONTAINER W NEN WHEN WHEN WHEN SEPARATOR TREATER RESERVOIR S AMPLED RECEIVED SEPARATOR TREATER SAMPLED RECf INFO i I' i - ii 11 , . . i DATE SAMPLED lD/M/Y1 DATE RECEIVED ID/M/Y) DA TE ANALYZED ID/M/YI ANALYST REMARKS 10/5/73 25/5/73 j__ _ 1/6/73 ___ _J ti E. _ Neubaue~__1 ____ _ _,-.. -_,_-_. .._ ...---- ---I---- ----------._ -- -----....- .--, ION j MG/L ~ MG% ~ MEO/L I I ION I MG/L I MG % I MEO/L I ' I t { i I I - _. ~ I . .., ! NB ~ 6002 I 35.98 l 261.10 ~ ~ cl i 6270 i 37.59 ~ 176.81 ~ I ' I --'-' - . I i K I I !~ B` I ~- I . ;__. _I ~- --,--......--- -- --~------- . __j ~ ...__---- ---- ---i.__......._ ~ j c°~ 60 1-_0.36 ~ 2.9.9 I~ -L ~ I ---- I My ~ 7 j 0.04 I 0.58 ~ I Hco,i 2750^!! 16.49' 45.10 ~ '---I i ------- ---~---_._. ~_- - ----. L_...... -- _. -l. I ~ I I-. ..,.._._ I I ~ g° ! ~ ~ j ~ SO• ( 815 ~ 4.89 ~ 16.95 j I , s. ~ ~.------~ cos 775 ~ 4.65 ~ 25.81`( F. ~ PRESENT ~ off ! j NIL , I I •, . . I ~ _; I _~ I I i i ' I i HZS ~ NIL I LOGARITHMIC PATTERN MEO PER LITER 's,t E ~ iii 4 ii~ _+I T:'c C_• c cc--- ll~l i' l l i~ Ili i I I f~ l I~~!; i ~ ~ l i 1~~j II I I i I Il~j l i I I~ I I~ ~ ~ ~ (III ~ 'I ~ t ll!I ' ~ I t ;';III I I. I!!! !' ~ I! Iii!`' I j li"III I I i!,,I (;;•jI! 111''!(. I•~, ~i ,, j~,,,i, ~ ~,! ~~,!~ I. !;ij.!u!~ Na !.:. , 'fit. ~ ~ i jl'+i !Ij~ 'j,~ll!!I "~,!Ijl i,iii~li~' ~,I~l! .j' j'I' ji!I Iljl Ijl!j ;," ~I~~ I''' ~~ Iljllii it ',~ 'jl .~ Jii~ ',.~,j,i '~Il~ill Ijliil'i r;.!!~I ! ~,IIII~~i ~ I~IIII~ ,ii ' i l~ 1:~1ii i i II , I I I ii,.'' 1 1 ~.I,,. I I , .,i' C ~IJ .:... ~ ;:I ~.. III. l .; l L . , ~ , i. I II ,I,~I i ! { I. jil it rl;~'I ~ ''~'jl ~I 1 {i,l{I,~ ;I!I1 ~!~11~}1 11i1 I, III ,;~il , ~,!i: ~~, i ~;j~,!li 1f~ d i l l; !I;i l i~ j i jI ~;II I~ j I I III I I I 1 jj.~ i j l I i I ill j;~. ~.:•:; ~i.....!li_l.~l_I4;,:j_~..~.li,•I11 I .;',, ~ ' Ll l~~li!11 I j i !Iijil~ I I•jil I I ~;ii~ ~ l i! j iil;!i~ ' ; ~ ~ ~ii i; I I ~ j ~ij' ~ 1 ! ~ Iijl I ~ j ~ ' ( i ~' ~ ~l I i i lip' ~1 j I!I I' ~ ~ ! !I~t,l I Fe ..... _ ;, ';. _aj:lll~t.~.l_ il,i~ ! .jl 'll I ' 'lilii~ i'li!'I iii(iI.I-' Ili. ~ ~j I I i jj j;' , I' ~ 1 1 II , j ~ ~) 1 ;I I (III I~~ ~ I I 'I _ ~ 141) ~ ~ I ~; i 1,..1 l;!~! _. I 11, r c ~ i ~ ~ TOTAL SOIIDS Mp/l BY EVAPORATION _BY EVAPORATION AT IGNITION _ _ CAl CULATEO r~.15, 304.__- __~ I-...16, 679. Organic matter -Very Much SPECIFIC GRAVITY REFRACTrvE INDEX 1-1...018- ---Dec°FJ x_1.3365 _ez~°c; OBSERVED PH _ RES13TiVITY .{DAM/I°.1er.1 {____ t___ .9_..S__®.80 "F ~.. 0.418. ~ a°[ Remarks and Conclusions Analysis determined on a dark brown filtrate recove-red from mud. CI Hco, SO, COa ' r 114... CL: ~f~~ --' ©~ ; ^r ; .; C~~; `' ~~~P y~ ' ~':' :=~ ~ jf ' ' ' • .; ~ d~ C . F ..,.. .. . . .. . .. c , ~ ~ . :_ . ~ y4 • _ NTON - FOTT 5T. JOHN - CAt.G... , - ' CONTAINFR IDENTITY WATER ANALYSIS ~- LADORATORr NUMOER , C7 3-15 OPERATOR NAME ANO ADDRESS GREAT PLAINS DEVELOPMENT C OMPANY OF CANADA, LTD. Calgary ELEVATIONS. SAMPLE LOCATION WELL OR SAMPLE LOCATION NAME - KB GRD 1-17N-4jd-SM ~ GP Noel etal Horse Shoe Lake State ~I1 205.5' 191.6' FIELD OR AREA POOL OR 20HE NAME OF SAMPLER COMPANY Cook Inlet _ D Sands J. Yelnik Lynes United 7EST TYPE G N0. TEST RECOVERY D.S.T. 2 500' water cushion 90' drilling mud TEST INTERVAL OR PERFS POINT OF SAMPLE A MT. L TYPE OF CUSHION MUD RESIS71VIlY ' Above tool o •F 6772' - 6392' I TYPE .OF PRODUCTION ;PUMPING :FLOWING GAS LIFT SWAB PRODUCTION RATES ~ ~~ ~ ~ ~ ' ~~ __ -, _.. _., WATER BBLS/D~ ,OIL BBLS/0 GAS MCF/D PRESSURES - PSIG TEMPERATURES ('F1 CONTAINER CONTAINER ' WHEN WNEN WHEN WNEN SEPARATOR TREATER RESERVOIR SAMPLED RECEIVED SEPARATOR TREATER SAMPLED RECEIVED DATE SAMPLED lD/M/Y) GATE RECEIVED ID/M/Y ) DATE ANALYZED IO/N/Yl ANALYST R EMARKS 10/5/73 •25/5/73 .. ;.; 1/6/73 E. Neubauer . , ION MG/L I MG% MEO/L ~. ~ ION i MG/L MG% MEO/L I ' , TOTAL S OLIDS Mq/L 1 Nc ~ 5144 ~, 36.94 223.78 ... _. - - -.. I ~ cl 5680 '. 40.79 .160.18 ! . 6Y EVAPORATION e 21,576 ~ IID ~ BY EVAPORATION - .~ IBD t . K ~ Br i ~ I ; ' 4T IGNITION ~ f.Al fUL 4TE0 , ' i ; 1 2 2,99 1 24 3,9 ca ; 44 0.32 i 2.20 • i I 1 `• ~ ~ ' Organic mat ter -Very Much My ;TRACE i ~ I HCO~~ 1800 12.93 ~ 29.52 I SPECIFIC GRAVITY REFRACTIVE INDEX I i 1.017 06~°F ° 1.3365 ~ z$°~ so ~ so, 444 3.19 ' 9.24 ' $r COQ' 812 5.03 27..04 OBSE RYEO PH RESISTIVITY .IOXIP/mrlerd , 9.8 el g0 °F. 0.435 ~ ~$^~ P~ PRESENT ~ ~ ~ off NIL . ' HZs NIL , . _ _._ ._ .. Remarks and Conclusions LOGARITHMIC PATTERN MEO PER LITER _ Analysis determined on a '~$;.Q 0 )la,b 6,is, aas a ,P•. P_ ~ L 6 E8 ~ @ ~b)>, ~ ~,~~• ' ll'~ ?~ IT~I ~ l II I' ~ r II'I:~ ' !I I~ I 'li I I ' !'I I { dark brown filtrate i ! I I I!!~! I I:I,iI li IIIiI ill Illill!I I IIII !IIII I II III II I it lill!I'I!I IIII I!I tl I; I , , I~ ,. . I . i l. l~ l l !+ l ~ I L I I I , I l li,! (, 1 11 1 I I I I I l l Lill I III ,I recovered from mud . '~ I, i; I l i' j I l i I I I III ~ I! t I ~ I' I III I I! I I IIII , ~ I- ~ I i l 1 I I 'il I '~ I I I I ~' I i I I Na I .... II , ; • CI I i II 1 I. I I I I '; i I, , I I I I I'! I I l i, ~ i I , I! I. , I I I' , I! I I I .I~ I! I I ~ ~ ~, I ' I I, :Ili I.I I' i I I I I I I i I I I I ', I I I I I I I .! I I.I I 1 t I I Ili I I ,,I! , I, I I I li I I I •', i I, III I I I i ,, I I L1 Ca I I I '~ ~ i ; I,f III I ;I I ~,. ai I~ .'I _l I '~ i HCO~ ~' i II I ~I:I~ I' .I !I '~I ~~I III ..ICI -lil iII iII' I !! I I i. III I , I ! I ~ III. I I I.. • ' I I I I I I I I 1 1 1 1' - I I ! I l i I ~ I !! I I t I l I,II I I III -.I ! I I! • M t.. I I I I ii Ilii I~ I it jll I I, I ,I ,I I '1 . i ilt I ~ I , ~ 1, Ii S~~ i, i ,,il !I, IIII' I.I ~~lil IIII II I~Ii ICI li.i I I I;illl - ! ..III. I I I I li I~ ~ I ~ I~ I I I~ I! i l '! I ~~ !! I ;i I ,, I , I I ! I ~., I I ~ ! . I I I I l i i i i l l I il' I I I I III I~i !~ ! I II~, Fe •• ~ i ' l l l i• '' I I _' '• i '~ I I I I I I I i I I I IIII,' I I Iil CO, I I ~ I I i I I ~• I i l: I I i i , I I ~~ I I I i! I i I~ I I I I I i! i I l! I! !III' I I ~ I III (I ili I I I III I I I .....1,11 .L'I!LII! IIII~I!iI~ ui!.i;) .II~IIIiI.~.,_ILI'Illlil..l ~!!~I!I I~liII111! IIII~LII~I I.li~ll,l.~ ~, ~ ~ ~ i;' ~ t..s L I v 1117 ~. ~ CHEMICr ti` GEOLOGICAL LAE30RA"~"^~ES LTD. ,~a~ ` • ' NTON - FORT BT. JOHN - CAIOAgT ~' ' „ ,~ CpN TAIN[R IDENTITY _ - WATER ANALYSIS - LABOR AT DRY MUMOER _ ~ ~ C t 73-16-1 . OPERATOR NAME AND ADDRESS _ GREAT PLAINS DEVELOPMENT_ COMPANY OF CANADA, LTD. 736 - 8 Ave. S.W._ __ __Calgar y _ SAMPLE IOC ATION _ _ _ _ ~ WEII OR SAr~PIE LOCATION NAME ~ EL vAT10N5 R! 4RD. ~ _ 1-17N-4Td-SM I GP Noel etal Horse Shoe Lake State 4I1 _-_~ (205.5' 191.6' FIELD OR AREA POOL OR TONE NAME OF SAMPLER COM-ANY ~ _ - ~ Cook Inlet .._..- .. _~ ~ C Sands ~ J Yelnik ; ... - t L}rnes United - _- _ _ _ _ - --- _ _ . _ . _ _ . _- -__~ ,-_ _, , TEST TYPE G N0. --_. TESY RECOVERY , ~ D.S.T. I ;_ 3 _ 120'.- drilling fluid, 35.4'._watE~ry_.drilling.mud._. - ___ ____.__ ._.- -_.-. _TESY INTERVAL OR -ERFS POINT Oi SAMPLE AMT. L TYP[ OF CUS NION MUD RESISTIVITY --- 4.74'.. above._ tool...---------- ------ --- .. ! I-.. ----- ----- ----~ _ 1-- -- ° •F ~ 4265' - 4310' I - - - TYPE Oi PRODUCTION _ - -- _ _ - _ - I I I - - - t PUMPING - ~ (FLOWING- ! I GAS UFT . - - ~ { SWAR - - ~ ..____ _..-.. !-_-_ ~ o III _ - ~ I ~ - - ~ ~ - - ~~ ~ ~ ~ ~ -- PRODUCTION RATES ~ - ~ --~ _ _ ~ ~ ~ _ _. . _ ` (WATER ffBLS/D OIL ffBlS/D. (GAS MCF/p; -~ ~- - ~~- PRESSURES - PSIG - - ~ ~--- -•- --- -- ~~ TEMPERAT URES ('FI CONTAINER CONTAINER W NEN WHEN SEPARATOR TREATER RESERVOIR SAMPLED RECEIVED SEPARATOR TREATER WNEN WHEN SAMPLED RECEIVED I -- - - DA TE SAMPLED ID/N/YI DATE RECEIVED l0/M/YI DATE ANALYZED (D/M/YI ANALYST REMARKS - 11/5/73---• •-.25/5/73 ~ ~l/6/73. ------~ L_E.__Neubauer_J I__.-- - - ~ --- -- -..--- _- -- .- I -~ -- --- - --- ----.._.. __ I ION ~ i MG/L MG% i MEO/L tON I MG/L I MG% I MEO/L . "° I .._.. - _ 4693 i I 37.72 ~ 204.13 ~ _ , c' ~ 5075 ~ 40.79 . 1143.12. j . 1 ..--_.._ __.__ _-. .- . -- . _i.-..__-.__ ... _. ~ __ _ I _. ~--. ' _ I K ` I I I i Br I I c° ' 40 I 0.32 ! 2.00 I I i I I ` • I -- --._ ~-- ~_.__ ._... ~ - ._ .... . _ ~ _I... -- -- , -_~ ...- _~ . ~ ~ (Mp 10 0.08 i 0.82 I I Hco,! 1150 ~ 9.24 18.86 I , _ ----- a° I I t ~ so, ! 329 2.64 6.84 ~ ._. .. .. ._- ...~ --_ __. ... _ ..t. --~ ' sr ~_...- I ~--~ --_.-- ( - -- I___. I co,I 1145 ._.. I_. - 1 ~ 9.20 ..._ ~ 38.13 . . I F. , TRACE i I 1 , ~ I I --- ~ o" ~ NIL ; --r----- . ~ I j c j ; I I ~ I ... _ j "zs ;NIL L_ ~ _ , j LOGARITHMIC PATTERN MEO PER LITER #i' 1 it E Il~~; II ,1 Ill -1 III II; (I i ii I I;; ,~~~ i;~ j Na r;';~i, I 1i11"~ I .IIII l l I,I III I I I~I.I,I I ';!IIII' I~I!II I III ~~ 'j' I'I ~(IIII ~ I I III~ILI ~,~Iilli~i ~~'!I I'e '!I1Ily I I IIiI I'' I i+l;~1 ~' I' L~ I ~~1~~ ~ 1. j 1 i i -- •5..:i.. ~ l l ;Illy l~_,~~,i~~.r~ ~1~;~, I .I III I ;I.! IIII I • ,, II:~;I; I i:~l'l l I III II I ~ I T _I~ I I ~ II z C--.- ., ~I,~,I ~ ~ I II I, I I~ !!i. i I _ I 11 .~;~~. II I 11!!j ~ i 5 >s,II III I I III 8 I , . I ,I ~ ;, I I~IiII ;~ IIII I I ~ ; l l i, ~i; Il I ~ I I 'II I~~ I I ~ I j I _I ~ ''~ , IIIIII :~Ii~ ';~I,Ii l '' ' i , i ll ,., i l UPI , I ~ I III~~ I~IIIII _~I;~II I ;;ilfl,; r ,I;~, I' 'll III I I~. I I !III I l ~~ , I I I ,. I I I 1 ~II ~ ~ , I ~ ~ I~ IIi ~, IL ' ~ i Ii_ I~ I I I . ! I ,~ II I I I!I !~ ~I~ I I I~~ I ~ II, ~~ `I`I I , iI ~ 11 ~ I .I i . I I I i ii . I ~; I I l i I l i l j ! i l i I ±I C ' II' I ~ ~ I~ I I I II I II i I' I ~ I1 I I -- I II ill I I I I Ii I ; I ~I I ~ jljl I I I I I ,j~l i I I I I I II II I I I, II iI ' I i I l j I, I I I I ( 'iII I I I I ;.~, I I ! _I,,;,,, ; I I,I i I_ . I ~ I ~ I I j l , ~ I . I LE . I ~ I i li ._ ' ' ' I,, I ,~ i1 ' i I ' ~ f'~ , , _ I ) 1 I ICI ~I~ . I l I - I- I I 1 I _ _ _I I 1... ~ ii ~ ~ _ I __ . I. L I. t • s - • L L G - : fi ~ I~I ' l I, iII I I lull ~~111 1, f.1 ~~ II~ tl -~ III i TOTAL SOUOS Mp/L BY EVAPORATION OY EVAPORATION t...17,870~e_I~o°~~ 1_.. .1° 19D"~~ AT IGNI iION_ _ CAI CUL ATEO 11,530_._._._ ~ I .12,442 Organic matter -Very Much SPECIFIC GRAVITY REFRACTIVE INOEK I-_l. 014._..-__06~^F~ 1_ 1.3360 zs°c; OBSERVED PH RESISTIVITY -10~•~/..el t~rl L -.9..8 ._._®...80.`F !.. .0.462 ..~ zs^E! Remarks and Conclusions Analysis determined on a dark brown filtrate recovered from watery mul CI HCO, 504 coa ~ .__.- .~ ._..g - ~ LYNES UNITED SERVICES LTD. _ ~~ TES? DATA Test No. 4 ynes Test 4 GENERAL INFORMAL ' Formation C, Sands T.D. Ft. Company r e~$ l o i n s D e v e l o p m f3 n t Interval Tested 2 9 5 0 Ft• '° 3 0 8 4 Ft. Address W Interval Teste.l 34 Ft. Net Pay Tested ft. peofTest ab e Straddle 1- - ushion Amount Ft. Well Nome Started in Hole at Hrs. Tool Open at 4 ~ 3 Q Hrs. Well Number Pre-Flow Min:. Initial Shut-in Mins. K.B. Elevation Sub-Sea Elevation 2nd Flow Mins. Second Shut•in Mins. Area COO k I n I et Province A I a s ka final Flow Mins. Final Shut-in Q Mins. Company Rep. G , L i n d h o me Remarks: Tester ,1 Y e l e n i k contractor R B Montgomery Rits No. Blew: ' t i a l p f f Good Ticket No. 6 O 1 7 oare May 1 2 7 3 Service Reports To: out the test. ll -complete II -pictures. GAS BLOW MEASUREMENTS Meosured with MUO AND HOLE DATA Mud Type Gel C h e m Time Surface Choke Reading Cubic Feet/Day Weight 12 Viscosity Water Loss Inches Filter Coke 2 3 2 Bottom Hole Temperature Orill Pipe Size 4 I 2 F H Weight Drill Collars 4 I 2 H 9 0 I.D. feet 'Run Main Hole or Casing Size 8 I 2 tt Rathole or Liner Size No. of Fees • Bottom Hole Choke Size I tt Surface Choke Size I I 4 tt Pocker Rubber Size 7 5 8 X 6 6 x REMARKS Shut-in pressures sugges avers e ermeabillty wl In the interval tested. RECOVERY TOTAL FLUID RECOVERED I 13 Q Ft. Consisting of: 450 Ft.af dri I 1 in mud 680 Ft. of sa I t water mud Ft. of Ft. of Tesf wos/was not Reverse Circulated W a S n o t Oil Recovery A.P.I. Water Specific Gravity salinity 3 8 5 0 P P M PRESSURE READINGS Inside Outside X Recorder No. 8 0 2 capacity 6 2 0 0 Depth 2 9 2 5 Inside Outside X Recorder No. 8 6 8 2 capacity 6 2 0 0 Depth 2 9 5 4 Inside Outside Recorder No. 8 6 8 0 capa~;,y 6 0 0 0 Depth 2 9 5 4 Inside Outside X Recorder No. 5 6 2 9 capacity 4 0- 3 5 6 Depth 2 9 5 4 NUMBER KEY: - INITIAL HYDROSTATIC 1 9 1 2 1 9 4 0 1 9 2 0 - PRE-FLOW 194 230 225 68 3-INITIAL SHUT•IN 1 2 9 9 1 3 1 9 1 3 1 3 4a - 2nd INITIAL FLOW 46 - 2nd FINAL FLOW 4c - 2nd SHUT-IN li s- 3rd INITIAL FLOw~ 2 4 3 2 7 8 2 7 7 6 FINAL FLOW 6 2 5 6 3 5 6 3 2 - 7 -FINAL SHUT-IN 1 2 8 1 1 2 9 0 1 2 8 3 FINAL HYDROSTATIC 8 1 9 0 4 1 9 1 7 1 9 1 0 - • L Y f' `~:.'~ P.J 8 `~ 1 1 ~: 4.! J 6 : i4 ~ Y ~ ' ~3 ~. 0 6/ . ~•lELL NAME - GP NOEL ETAL HORSESHOE LAKE STATEI;l LOCAT J ON - ] -] 7N-11~iJ SM DST NUMBER - 1{ INTERVAL TESTED - 2Q50 TO 30811 RECORDER N0. - 8682 ~DEPTti - 2451{ INITIAL StiUT IN PRESSURE • • TIME(MIN~ T + PSIG ~ m 0 0.0000 230 5 2.0000 ]]27 ]0 ].5000 1218 ] 5 ] .3333 1251- 20 1.2500 ]272 25 ].2000. ]~~~ 30 ].]667 ]2Q5 35 ] . ] 1{ 2~ ] 307 1{0 ] . 7 250 ] 306 1{5 ].]]]] ]308 50 ].]000 ].373 55 ].ogoQ ]376 60 ].0833 737Q EXTRAPOLA710N OF INITIAL SHUT-IN = ]3!{6.68 LAC ;~ U~I~~e~ ~~~~1~ ~ ~.T'®. ~_ ~' ~ 1~JELL NAME - GP NOEL ETAL HUP.SESfiOE LAKE STATE#] LOCATION - ] -] 7N-111~J SM DST NUMBER - 11 INTERVAL TESTED - 2950 ~fO 30811 RECORDER N0. - 8682 DEPTH - 2954 SECOND StiUT 1N PRcSSURE -------------------------- TIME(MIN) T + ~ PSIG - ~ ------- m ------- ------- 0 ~ 0.0000 635 4 8.2222 1]]11 ]8 11.6]]] ]]84 27 3.40711 ] 27 8 36 2.8056 1236 45 2.44114 12511 511 ?..2n37 ] 2F? . 63 2.03]7 ]272 ' 72 ].4028 ]277 ., 8] ] .8025 ] 285 90 ].7222 7240 EQU. FITTED LJNE IS LOG((TO+~~/~~_ -0.00349 PSIG.+ 5.38625 EXTRAPOLATION OF SECOND St1UT-IN = ].3114.13 M= 250.118 • • To+~ 50 ~ I I I 2 0 -{- i ,o +. i ~1 r 2 -~ 1 -}- -1000 DST NO. 4 REC. NO. 8E82 UEPTH 2c~5!{ ,~ • -f ' r , i }- '1 .~ M +. ~~ -500 0 500 loo0 1500 PSIG(OIL OR 1•lATEP.) PRESSUP.E EXTRAPOLATION PLOT 200o i • f • • LYNES UNITED SERVICES LTD._ ' r ~ ~ 1 1 Tt:'ST DATA Test No. 3 lynes Tcst 3 GENERAL INFORMA Formotion T.D. 8 2 3 0 ft. Company G r e P l a i n s D e v e l o men t Intervol Tested 4 2 4 6 Ft. to Ft. Address Interval Tested 64 Ft. Net Pay Tested Ft. Type of Test Inflatable Straddle Great Plains Noet et al Horse Cushion Amount Ft. Well Name Shoe Lake State # I Started in Hole at I ~ O O Hrs. Tool Open at 0 Hrs. Well Number - 7 N - 4 W - S M Pre-flow Mins. Initial Shut-in Mins. K.B. Elevation Sub-Seo Elevation 2nd Flow ~ Mins. Second Shur-in Mins. Area COO k Inlet P`°~'"Ce Alaska final Flow 6 O Mins. Final Shut-in 2 O Mins. Company Rep. (j L i n d h o m e Remark:: Tester J Ye I en i k contract°` RB Mont omer Rio "°• 6 Blow: Weak i n i t i a l u f f Mai f Ticket Na. 6 0 6 Date M a 1 7 3 weak d e e a i n a n Service Reports To: 45 minutes. II com lete I ictures GAS BLOW MEASUREMENTS Meatured with FI j I MUD AND HOLE DATA Mud Type Gel C h e m Time Surface Choke Reading Cubic feet/Day Weight 12 ~ L~ Viscosity 6 O Water Lost Inches Filter Coke 2 3 2 tt Bottom Hole Temperature Drill Pipe Sire 4 1 2 tt F H Weight Drill collars 4 I 2 H 9 O I.D. Feet 'Run 2 3 Main Hole or Casing Size 8 I 2 tt Rathole or Liner Size No. of Fee• Bottom Hole Choke Size tt Surface Choke Sire I I ~ !~ tt Packer Rubber Size 8 6 6 6 REMARKS Shut-in ressures su est ow e meabi it with'n h i t to RECOVERY TOTAL FLUID RECOVERED Ft. Consisting of: Ft. of Ft. of ft. of Ft. of Test was/was not Reverse Circulated Oil Recovery A.P.I. Wafer SpeciFic Gravity Salinity PRESSURE READINGS Inside Oy(t}~dptiX Recorder No. `J' tS U capacity 6 2 0 0 Depth 4 2 1 8 Inside Outside Recorder No. $ 6 8 2 capacity ~ 6 2 0 0 Depth 4 2 5 0 Inside Outside x Recorder No. $ 6 8 O capacity 6 0 0 0 Depth 4 2 5 0 Inside Outside x Recorder No. 5 6 2 9 Capacity 4 0- 3 5 6 Depth 4 2 5 0 NUMBER KEY: 1 •INITIAI HYDROSTATIC 2 7 4 6 ~ 2 7 6 6 2 7 5 4 I ~' 2 -PRE-FLOW 1 8 8 1 9 1 1 8 5 8 2 3-INITIAI SHUT-IN 2.3 7 0 2 3 8 3 2 3 7 4 4a - 2nd INITIAL fIOW 46 - 2nd FINAL FLOW 4c - 2nd SHUT-IN 5- 3rd INITIAL FLOW 2 3 2 2 5 5 2 5 6 b fINAI FLOW 2 9 5 3II 3 I I 7 -FINAL SHUT-IN 2 3 0 6 2 3 2 4 2 3 1 2 8 -FINAL HYDROSTATIC 2 6 9 4 2 7 0 9 2 6 9 8 • l • • ~~ WELL NAME - GP NOEL ETAL HORSESHOE LAKE STATE#1 LOCAT T ON - 7 -] 7N-tIW SM DST NUMBER - 3 I NTERVAL TESTED - 112146 TO 113] 0 RECORDER N0. - 8682 DEPTH - 11250 INTTIAL SHUT IN PRESSURE TJME(MIN~ T + PSIG ~ ~ ------- ------- ------- 0 0.0000 ]Q7 5 3.0000 7 7 8t~ ]0 2.0000 1668 ]5 ].6667 7go2 20 ] .5000 2otlt~ 25 ] , t~ooo 2] tlo 30 1.3333 2203 35 1.2857 22tIc~ 110 ].2500 2~~~ 115 ] .2222 287 8 50 ] .2000 23t~5 55 ] .7 87 8 2366 60 ].]667 2383 EXTRAPOLATJON OF INITIAL Sf1UT-rN = 25Q3.56 ~~ 4~ELL NAME - GP NOEL ETAL t10R5ESti0E LAKE STATE#1 LOCAT I (1N - ] -] 7N-llh! SN' DST NUMBER - 3 INTERVAL TESTED - 112116 TO 113] 0 RECORDER N0. - 8682 DEPTH - 11250 SECOND SHUT IN PRESSURE l • • TIME(MIN) T + PSIS ~ ------- ~ ------- ------- 0 0.0000 3]] ] 0 8.0000 ] ] 1{5 20 11.5000 ] 5Q] 30 3.3333 ] 8211 1{0 2.7>00 l X66 50 2.11000 2057 60 2. ] 667 2] 211 70 2.0000 2]76 80 1.8750 221h Q~ 1.777$ 2251 ]00 ].7ono 2280 ] ] o ] .63611 2303 120 ] .5833 2321{ EQU. FITTED LINE IS LOG(CTO+~)/~)_ -0.0006 PSIG + ].78573 EXTRAPOLATION OF SECOND SHUT-IN = 2611{.57 M= ]1155.Q~ I. • TO+~ 50 ~ I 2 0 -~ 10 5 z } I I I 1 -- ~ ^~`, • ' ~ • 1 • • • • .T • . .} '~- 1; • 1 ~ ~ Tf - " • 1• ~~ . ~~' -2000 -1000 0 1000 2000 PS IG(OI L OR blATER~ PRESSURE .EXTRAPOLATION PLOT 3000 -~ 4000 ~; , ~' ~ ~ ''. ~~ ~ ~ liiil r~ ~ ~ fl'i't= i ~~ ~ ~ 4,. ? ~ ~~I"k ~~ ,t~!, ~~ lid;! ~--~--tee.-' 4 I'.~ t .~?r` 57 F Tr ~~ ~ ~~~ +' ~~. ~~ '. ~~ > p 1 i _ }~ ~ b~ 9 f 0. ~T y r S~: ~~ t -, YdF C~ n S !~ ~ }Fx 1 ~ ? 4 ~'H`' fd 3 :z ~ ~' •_ ' ~ ~ ~r ~x yrRr~,A' sp t ~. ~ '' ~ kg ~.h a ~c 4 ~ ~ ~ .S~t 5' 6 F°, ~t~r ~~; a 5 r ~,zu ~ .n,-~ ~ ~. ., ~ ~ ~r a 't n~ ~ z r , ~ga~g,x't~.1 ~{ h~k 'r~ ~#t r f 4~r i ii ~ ~ ,~> ~ y' , a, '~ ~ ~~' ~. ~r~` , g ~ t x ~ t sn T r I~;yY'~ h ~ ~.1. t ' y VT S G ~ Y~+~~ x ~ ~~i S l ~ t ~ ~ , h r ~ ~ 1 p, ~~ j~1R ~ ~l ~ ; ~,x i -,E r '~-v-~ fl ~,F L ~ t ~' ,,~~, ~}r~*, ~„~su.. `eti; '' ~~ Xr Y~~ r~.+s ' P ~ i 7 1 ~, w ti al+ d `~ I l`'' ' 1 v y. - ~ ~ Fe ~ C 3 ~~pp 1 `, 'sf" ~SYn~ ~~~w ky~ !~'s` ~iS ~ "H,if M ~ K ~~' r~ ;~t •f t,r ~;,F' ~. I ~. ~ ~4 ~ ,. Y 1 r a :; x t ~i,.. n '*d Nk ST ~ ~ e rhU ' ~{{~ i ~ a ~ .f ilk? t`p~~h }.t~ -`t ~ n{T. L R ~ '~l ~,~ r ~7 . lam. ._ -_- __ __ a r {' , fYT tai; 's~. FI' 4~ F 4?~ 4 N ~ , ~ ~, 7 `.' '~ .I. ~f~'~ r ' w ~ r ~ ~~~~z a j7, i 3~ . +t ~ ~ d ~~~. ~ ~ ~ ~ ~~.~Y~dS' ~, ,,~. < ~ `. ka,~ 11: v '~ II ~ d ~z, ~ , i .• 2 { Nr, ~ } .~ ~~ , ~~ f r i,qi U. t~ R .r ~` Y ~' ..,~ .=W z' r,N ,1 ~ A F ~ r l,:Rl .~y ~, 1 l ~'~ J r' 1` 33 ~v ~`~~ ~ ~ ~ si,,~ ~ ,u' ~~,''~ { s ti ,~ ~ t a ~~" ~i~ .t'a~~ rte ?l ,~ 1 T a. {( ~ lg ~ _ M1 tf ~i 1 k~ '~ t b ,~ 3 1 ~ ~ I j ~ ~ ,a~,+~+aL'~ ~ r p t F ~ , r „ ~ ~~ ~`3t 1 f ~~ f r" 4 ~ i ° ~ ~ l~. IY- llt ~ P L"I 1 ~ '+ ~a~ ~~'~$ rFfr s ~'" `~~PS ~~~ ` iii ~ a ,%_:~, ~ ;. ~ i cicPriG\E (907) 274-<Ol~ ~ ~ F'.O. ':',Oi:.~ - i 276 ~ i '~' ' i 2503 ~~cCF:C':51V D l ~ ..:~~ fiN~;-:.^.:2%Gc, ::CAS~CA 99509 • G?~='.I:idY' A':.,r.n = fib?-tn,r~~;"~.C-~~~ ~ _'~.~ I;eCe^~b~r 15, 7.9~I ',E;.. :.. 0036-2 ~~ O -- ~..,, O '~L .JJ Lei ~i~ Lake No. 1 d f_ 'd L Va 1 Boa i,~., jr11C~Ca'i. I'v-ZT'Ir_•:?psi f. ~..«rn[Y ~.J Vag- } )) [~ '` i.4 :?^.7 1 I.- / ~i J ~ v1 f ,`5V h1 a~`A ,;r,,~ .,t ::.:.._ ~._~~ a Cd~~LL'~_O:~'S• day w~ cr - ~ ~. A ~trate- c ~ e~" ~ ma~yC? Io:v i1 ' Samn? e ta'_:e:~ :C~. ~a_Z or_ ~ ~ antic .iun. ~:t~ - - - - 1~~? '-`-..w-=r=te - -~ - - ~. ~ ~~~/1 ~r.:rn~ ~, mfr/1 ~ >:~~~/: 53..:19 Sr:_~Co - - - - ,n ' . n4 ~%• ~" Cs:.:..~:c - ?0~ 6.79 yci:o:icc 9nr? 5:3. ~? . 6 9.50 Tct...I Aajor~ __ F a_ 5 n ="o~1 d:;;ovco :a:i;:a, r..r/1 - - - - ';0~~ .°.~c::~c rc~c~co Q W' °~ ~. ~~aCl c _t:it~:'c '~ ~;/1 - - - -• - Ob.:eracd - n. 87~ ~ o:s:s..~•:.~s vc.~'_e S ~~?e a'aovE ~esc~bea "~G a:: °v'~i~ • •~T., w .a Ca n r,,, May . c CI . 50 . ~a SO.e 5 .rib C0 3 ~ 5 ..,'. ;I ~~ ' , ,. i ~. C1 1 r?CO~ SOS ' I 1 CO, I ' ~ !.~ ~~. ; ~ ~~ i ~; i (?:a valor !a .^.'axv rr:7~n tac;vCn tic, ~, cad U) ! ~ ; YO?'i:.: ;;/:_._.. ,;rc_. 9~ ..;r. .:c:,/:c ~_.~l;run cquivd:aa pcz litvc ' ~:I .glum c'~.!anEar ~u~.. :oct_.:;;• ~ ~ ~' - i ,,.: ~ 7v.~q.Z: ~:acrti~on:a c:L'uatSon trcm cc:r-^~sta i ' Y ~'~ ''~ Ft -- ~\ ~ ~ ~::?~?~~Or~'c 1907}~79-riG]~. i i.i:.•. .:~.~ w i'`Tii i ~. ~ ~6Gs~ :,~Cii~; B:VC• -- ~ - II i ; i ~ ~ ' • .. •~ ,-~ :{:~CSO~~C~, ALASKA 99509 ~ ~~ •. • - . ~ ~V l~~s 1 ~3 1\~t+~ei ~\ '~ ~~V~ ~ ~ . ' . . .. . e ~ c Ate. r. r. d~ ..E~1 miry 1i: ~.3~.. w.v. ~-v'.n !~^~ ~ . .c~i'r. ii~.V ~ICVJJU` _' V!~~~V~`.''i~=•'.~~7 ^~~^'~';r?(!~?tTt~?~+ ~ S ~ Q~71 ~y ~` ~~i3G~3 f-- r~'.T.. ~\ ~- '~_f* 1~2~i(' ?~r0. 1 TiCi'l .. t ~Ci~~ O~ rA TT d`~ / ~ i- -,,,, ..,.-.,, v ~~~...r:•..u.~ G.: CO. iCLCJ SCJ ?;it~cdy r•;w per, s? :.~:~ ~~ y clo~~dy ~iztxa ~e :I':s~ ~ f_ z . ~ ? c:r:: _ _ 652 25.3 Crir~.._. _ . _ _ _ ~! 0. ?.0 `~, r1`r? ce 10".~~ C~...C^.0 - - 29.80 o~' 4:~A:DCf: soli; s, ~~1= - - - - - 1709 Spxi c r~s~.co QQ 63°S.: O...:.::Y'VO:i ?:: - - .. _ ~ s J ~ •C...:CLL~Liid d _ `Z. 0.'•SL'r~3 w~~ S :~~:e ooove cescribe;,' IZi ~ ~cr Ja.t Ci ~ zo ~ ~~ F-iC©a ~ Ca COs ~ zi~~ "c i ~ . ; ~ I• -~~~~~ ' Z .Ca :? J a C u r~---; ' ~,..^ I ~ f~~ i t ~ r -~^---^ ~ ~r i I11 Fr t-"'. QTY. .. +. ~..T'rT1~.. .. _~•-~ * ~-r.-T ~ _~~ . Y rJ•""T"..'Y'1.~T. :~f...yT, ~. -r-~~-r'.: T ~~ -t'~-~ _~ ~' err --,-; "` ' ' ^.~1y.t~ ~ ~~ Ski ~~:. .~ .. - -r .~_.-.-._. '4`Qyzl ~ Rfrvnn 7Q _ ~>'ri (?:a r.:'.na fa sSocro L'"•y`z Iaeuu6,- 1'n, ~, tnd Id) 40T::: ~/:=.-=~L~~ ~a ,-~,x ilzc: '^cQ/1= ::illl~ra~ cquivul~or~ par llmr ' «cwlu~n c}'wnCa c:'u:':a!_>at~~j )~L:s`.~... }::c+tSora uL-u!ation ftun car„~~ti s~cco ~ - - - ~ 95 ~ . nr .`.. t,..w... o - • - - ~~n - - F . ~n C~::..^,~~tc 180 5.99 ~:crr:;o~^ta 830 ]. ~, F,i C1 HCO, .S~{ 1 ~ j: ~~ !. ;~ i ,. I~ `i '' ' .I ~ • • • • APPENDIX 3 • Y ~_ TDS Calculation From Well Logs ~ Thermal Gradient Formula: TG = (Tmax -MST) / (Depth Subsea / 100) Tmax =Maximum recorded temperature from log header MST =Mean Surface Temperature for Cook Inlet (= 35 deg. F Depth Subsea =Meas. depth of Tmax converted to subsea depth Formation Factor F = 0.81/ (porosity*porosity) (average of the density and neutron log porosity) (Tixier Formula) Resistivity of 100% Water Saturated Formation: Ro = Rt (deep induction R value through analyzed zone assumed to be 100% water). Resistivity of Formation Water Rw=Ro/F Formation Temperature: Tf = (Depth subsea / 100) x TG Resistivity of Formation Water at 750 F: Rw@75degF = Rw ((Tf + 6.77) / 81.77) Salinity (ppm): x Salinity= 10 X= 3.562 - log (RW@75DegF - 0.0123) .955 A procedure to generate the salinity curve using the method has been developed for WDS. i