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Home My WebLink AboutDIO 006• • Image 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. 1© QO ~j Order File Identifier Organizing (done> RESCAN Color Items: ^ Greyscale Items: ^ Poor Quality Originals ^ Other: ,wa=ded iuumiiiiiuim DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type: ke,~a~~ee~ea uiumimiuiui OVERSIZED (Scannable) O M ps: Other Items Scannable by a Large Scanner ~,o~S OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: BY: Maria Project Proofing BY: Maria Scanning Preparation BY: Maria Date: Date: ~/o 0 o~.e, ~IIIIIIIIIIIII VIII ~P ~ao~lo _ ~ WII~ + =TOTAL PAGES oZ O (Count does not include cover sheet) ~~ /s/ x30= Date: r ~/~ Production Scanning Illililllllllllllll~-T Stage ? Page Count from Scanned File: ~S~ _l._ (Count does include covers eet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~~~ ~O /s/ ~~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II'III I IIII I I III ReScanned BY: Maria Date: /s/ Comments about this file: a , ~e«e~ uuiuiuiiiimu 10/6/2005 Orders File Cover Page.doc s December 7, 1988 2. August 29, 1989 3. December 14, 1988 4. December 28, 1988 5. January 13, 1989 6. January 13, 1989 7. May 11, 1989 8. September 27, 2004 r~ Disposal Injection Order 6 Lewis River Unit Well D-1 Unocal's Application for Underground Injection Lewis River Unit Well D-1 Step Rate Test #1 Lewis River Unit D-1 Notice of Hearing Ltr from Trustees of Alaska written protest Sign in sheet for Public Hearing Transcript Request from UNOCAL to dispose Proposal to amend underground injection order Disposal Injection Order 6 ~~ { ~~~ ~j ~ ~ ~ ~ I r~ 1 :`~ { ~, 1 sJ j ti 7 ~ ~~ ~ '- FRANK N ; i ~' _' MURKOWSKI ~ ~ ~ ,~ ; > ,~ , ~ , ~; a . >; , . , GOVERNOR ~ ~~ OII. ~ ~ ', W '" 333 . 7 AVENUE, SUITE 100 COI~TSERQAZ'IO1~T CO1~IIfIISSIOIQ 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" Inte 'ty" Confinement" Area Injection 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 O erating Area 6 ~ 9 AIO 5 -Trading Bay 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 l OB -Milne Point Unit; Schrader Bluff, Sag River, 4 5 g Ku aruk 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" Inte rity" 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; Al ine Oil Pool 6 7 11 AIO 19 -Duck Island Unit; Eider Oil Pool 5 6 9 AIO 20 -Prudhoe Bay Unit; Midni ht Sun Oil Pool 5 6 9 AIO 21 - Kuparuk River Unit; Meltwater Oil Pool 4 No rule 6 AIO 22C -Prudhoe Bay Unit; Aurora Oil Pool 5 No rule 8 AIO 23 - Northstar Unit 5 6 9 AIO 24 -Prudhoe Bay Unit; Borealis Oil Pool 5 No rule 9 AIO 25 -Prudhoe Bay Unit; Polaris Oil Pool 6 g 13 AIO 26 -Prudhoe Bay Unit; Orion Oil Pool 6 No rule 13 Dis osal In'ection Orders DIO 1 -Kenai Unit; KU WD-1 No rule No rule No rule DIO 2 -Kenai Unit; KU 14- 4 No rule No rule No rule DIO 3 -Beluga River Gas Field; BR WD-1 No rule No rule No rule DIO 4 -Beaver Creek Unit; BC-2 No rule No rule No rule DIO 5 -Barrow Gas Field; 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; BC-3 2 3 5 DIO 9 -Kenai Unit; KU 11- 17 2 3 4 DIO 10 -Granite Point Field; GP 44-11 2 3 5 • Affected Rules Injection Order "Demonstration of "Well Integrity "Administrative Mechanical Failure and Action" Integrity" Confinement" DIO 11 -Kenai Unit; KU 24-7 2 3 4 DIO 12 - Badami Unit; WD- 1, WD-2 2 3 5 DIO 13 -North Trading Bay Unit; S-4 2 3 6 DIO 14 -Houston Gas Field; Well #3 2 3 5 DIO 15 -North Trading Bay Unit; S-5 2 3 Rule not numbered DIO 16 -West McArthur River Unit; WMRU 4D 2 3 5 DIO 17 -North Cook Inlet Unit; NCIU A-12 2 3 6 DIO 19 -Granite Point Field; W. Granite Point State 3 4 6 17587 #3 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 D1 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; KF1 3 4 7 Stora a 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 No rule No rule 8 Bluff Formation Well V-105 • Affected Rules Injection Order "Demonstration of "Well Integrity "Administrative Mechanical Failure and Action" Inte 'ty" Confinement" EIO 2 -Redoubt Unit; RU-6 5 g 9 02-902 (Rev. 3/94) Publisher/Original Copies: Department Fiscal, Department, Receiving AO.FRIVI STATE OF ALASKA NOTICE TO PUBLISHER ADVERTISING ORDER NO. ADVERTISING INVOICE MUST BE IN TRIPLICATE SHOWING ADVEj TISING ORDER NO., CERTIFIED A 0.02514016 ORDER AFFIDAVIT OF PUBLICATION PART 2 OF THIS FORM WITH ATTACHED COPY OF A ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE SEE BQTTOM FOR INVOICEADORESS F AOGCC AGENCY CONTACT DATE OF A.O. R 333 West 7`h Avenue, Suite 100 ° Anchorage, AK 99501 PHONE pC "I 907-793-1221 DATES ADVERTISEMENT REQUIRED: o Journal of Commerce October 3, 2004 301 Arctic Slope Ave #350 Anchorage, AK 99518 THE ;MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRL`CTIONS: AFFIDAVIT OF PUBLICATION United states of America REMINDER State of ss INVOICE MUST BE IN TRIPLICATE AND MUST REFERENCE THE ADVERTISING ORDER NUMBER. division. A CERTIFIED COPY OF THIS AFFIDAVIT OF PUBLICATION MUST BE SUBMITTED WITH THE INVOICE. Before me, the undersigned, a notary public this day personally appeared ATTACH PROOF OF PUBLICATION HERE. who, being first duly sworn, according to law, says that he/she is the of Published at in said division and state of and that the advertisement, of which the annexed is a true copy, was published in said publication on the day of 2004, and thereafter for consecutive days, the last publication appearing on the day of .2004, and that the rate charged thereon is not in excess of the rate charged private individuals. Subscribed and sworn to before me This _ day of 2004, Notary public for state of My commission expires Public Notices • Subject: Public Notices From: Jody Colombe <jody colombie@admin.state.ak.us> Date: Wed, 29 Sep 2004 13:01:04 -0800 To: undisctased-recipients:; BCC:; Cynthia B ~lciver ~bren_rncver@admin.state.ak.us>, Angela ~~"ebb <artgie vc!ebb~~iadmin.state.ak.us>, Robert E Mints 'robert mintz~la«-.state.ak.us~=, Christine Hansen <c.hansen(u'iogec.state.ok:us>, Terrie Hubble <hubbletl(~bp.com>, Sondra Stewman <StewmaSD@$P.com>, Scotty, C~~nmy'f'aylor ~~staylar(~;alaska.net>, stanekj <stanekj@unocal.com>, ecolaw <ecolaw@trustees.org>, roseragsdale <roseragsdale("ci;gci.net?, trrnjrl <trmjxl@a€~1_com>, jbriddle <jbriddle@rnarathonail.com>, rockhill <rockhill a;aoga.org>, shaneg <shaneg@evergreengas.cUm>, jdarlington <jdarli@on@forestoil.com>, nelson <knelso@petroleumnzw-s.COm>, Cboddy <cboddy@usibelli.com>,1~-lark Dalton <mark.dalton@hdrinc.cu~n>, Sharman Donnelly <Shannon.donnelly~ci;cunocophillips.com>, "Mark P. Worcester" mark'p.worcester@corocophillips:cotn~, "Jerry C'. Dethlefs" <jenny.c.dethlef@condcophillips.eorrt>, Bolri fbo~Z@inl~tk~eper.or~'>, ~cdv <-wd~~~ridnr.state.alc.us>, tjr <tj@dnr.state.ak.us>, bbriteh <bbritCh@aiaska.net>, mjnelson <'mjnelson(a!purvingertz.cQm>, Charles O`Donnell <Charles.o'donnell~a?veco:com>, "Randy L. Skllern" ~ Ski11eRL@BP.corn> "Deborah J. Jones" <JonesD6@BP.cam>, "Paul G. Hyatt" <hyattpg@BP.com~, "Steven R. Rassberg" <RossbeRS~a BP.com>, Zois dais@inletkeeper.org>, Dan Bross ~ ~kuacnews@;kuac.org>, Gardam Pospisil <PospisG@BP.COm> "Francis S. Sommer" <SammerFS(~~BP.com=, 1~~iikel Schultz <Mikel.Sch~ftz@BP.eom>,' "Nick W. Glover" <Glover~rW~cBP.com>, "Daryl J. hleppir" <KleppiDE;a),BP.com=, "Janet D. Platt" <PIattJD@ BP.Cam-y, "Rosanne 'ul. Jacobsen" <JacobsRV1@BP.cc~m>, ddonkel <ddonkel@cfl.n-.com= ,Collins Mount <Collins_mourt@revenue.stateak.us>, mckay <mcka}@gci.net =, Barbara F Fullmer <barbs.ffullmex@conocophiilips.com> bocastwf <bocastwf(dtbp.com=,Charles Barker <barker@u5gs.gc~~~=>, dou~_schultz~; <doug~schultze@xtoenerg}~.c~~m%, Hank Alford <hank.alford@exxenmobil.conv. 1'~'fark Kovac ~ yesnol (cigci.net%, gspfoff <gspfufl@aurarapbw~Cr.com>. Gregg Nady <gregg.t~ady(~UShelLcom>, Fred Steece <fred.steece@state.sd.us=>, rcrotty <rcrotty!a uh~m:com-°, jejones ~ jejont~ic?aurorapower.com=>, dapa ~dapa(@laska.net>, jroderick <jroderickFu~~gci.ret= ~, eyancy <eyancy~c"%seal-tite.net==, "James M. >Z.t~ud" <Wines.m.ruud@conocophillips.ca~n>, Brit Lively ~mapalaska(u-ak.net=r, @~ <jah@dnr.st~te.ak.us>, hurt E Olson <kurt_olso@legis.state.ak.us>, buonoje ~buonojc;@bp.ann?, Mark Hanley<~nark_hanleti-(~i~anadarko.eom>, loren leman <loren_lemanlu~gav.state.ak.us~; .Julie Houle'<julie_haule@drr.statC.ak.us>, Johm ~V" K atz <jvvkatz~i?sso.org%, Suzan J Hill <suzan hih@dec.state.ak.us>, tabler~<tahlerk~c%~unocal.com>, Brady <brad@aoga.org?, Brian Havel©Ck <beh~cidnr.state.ak.us>, bpopp <bpop@~~borough.kenai.ak.tu%. Jim White <jimvvhite~a;satx.rr.com>, "John S. Haworth" <john.s.haworth~~,exxonmobil.com ~, many <marty@ rkindustrial.com= , ghammons <@ammons(u aol.com>, rmclean <rm~lean~iz:pobox.alaska.net>, mkm7200 <mkm7?UO@aol.com~, Bran Gillespie <ilbrrrg@uaa.alaska.edu?, David L Boelens ~dboelens~aurorapower.eom>, Todd Durkee <TDURKEE@KMG.com>, Gary Schultz <gary schultz~i~dnr.state.ak.us>, Wame Rancier <RANC'IERrcLpetro-canada.ca>, Bill Millar <Bill_Mille@xtoalaska.com%, Brandon Gagnon <bgagnon~ribrenalaw.com>, Paul Winslow @nlwinslow@:forestoil.com>, Garry Catron <Catrongr~r@p.com>, Sharmainz Copeland <cc~pelasv@bp.com>, Suzanne Allexan <salle~@~a~,h~lmenergy.com>, Kristin Dirks <kristisi_dirks a~dnr.state.ak.us>, Ka}Hell Zeman <k@eman@.marathonoil.com>, John Tower <John.Tower@ia.doe.gov>, Bill Fowler <Bill Fowler-anadarko.COM>. Vaughn Swartz <vau~hn.swartz@rbccm.com>, Scott Cranswick_ 1 of 2 9/29/2004 1:10 PM Public Notices . • <scott.cranswick@rn~n .gov>, Brad Mci{im <mckimbs~aB~.com> ...Please find the attached Notice and Attachment for the proposed amendment of underground injection orders and the Pu]~lic Notice Happy Valley #10. .Jody Colombie Content-Type: applicatian/msward IVTechanical Integrity proposal.doe Content-Encoding: base64 Content-Type: apglicationlmsword ..Mechanical Integrity of Wells Natice.doc Content-Encoding: base64 Content-Type: applicatiorv'msword HappyValleyl0_HearingNotice.doc Content-Encoding: base64 Public Notice . . Subject: Public Notice From: Jody Colombie <jody Colombie@admin.state.ak.us> Date: Wed, 29 Sep 2004 12:55:26 -0800 To: -.legal@alaskajournal.com Please publish the attached Notice on October 3, 2004. Thank you. Jody Colombie Content-Type: application/msword Mechanical Integrity of Wells Notice.doc Content-Encoding: base64 _ _.. _ _ . Content-Type: application/msword Ad Order form.doc Content-Encoding: base64 __ 1 of 1 9/29/2004 1:10 PM Citgo Petroleum Corporation Mary Jones David McCaleb PO Box 3758 XTO Energy, Inc. IHS Energy Group Tulsa, OK 74136 Cartography GEPS 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 Ft. Worth, TX 76102-6298 Houston, TX 77056 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 Jerry Hodgden Richard Neahring John Levorsen Hodgden Oil Company NRG Associates 200 North 3rd Street, #1202 408 18th Street President Boise, ID 83702 ', Golden, CO 80401-2433 PO Box 1655 Colorado Springs, CO 80901 ~I Kay Munger Samuel Van Vactor Michael Parks Munger Oil Information Service, Inc Economic Insight Inc. Marple's Business Newsletter PO Bax 45738 3004 SW First Ave. 117 West Mercer St, Ste 200 Los Angeles, CA 90045-0738 Pdrtland, 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 [Fwd: Re: Consistent Wording for Injection ~rs -Well Integrity Subject: [Fwd: Re: Consistent Wording for Injection Orders - From: John Norrnari <john_norrnan@admin.state.ak.us> Date: Fri, 01 Oct 2004 11:09:26 -0800 To: Jody J Colombie <jody eolombe@dmn:state.ak.us> more • Well Integrity (Revised)] ------- Original Message -------- Subject:Re: Consistent Wording for Injection Orders -Well Integrity (Revised) Date:Wed, 25 Aug 2004 16:49:40 -0800 From:Rob Mintz <robert mintz(a~law.state.ak.us> To:jim re~g~aadmin.state.ak.us CC:dan seamount(u~admin.state.ak.us, john normannaadmin.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 <jim regg(aadmin.state.ak.us> 8/25/2004 3:15:06 PM »> Rob -Thanks for the review; here's a redraft after considering your comments. I have accepted most of the suggested edits; also attached is response to questions you pose (responses are embedded in the comments, using brackets [JBR - ...] to set apart from your questions). Jim Regg Rob Mintz wrote: Jim, I have some questions about the draft language, which are shown as comments on the first document attached. Based on my current guesses about what the answers will be to my questions, I also have some suggested edits, which are shown as redlines on the second document attached. »> James Regg dim reag(i%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(a~admin.state.us> '! Commissioner Alaska Oil & Gas Conservation Commission 2 of 2 10/2/2004 4:07 PM ,[Fwd: Re: Consistent Wording for Injection ~rs -Well Integrity ... Subject: [Fwd: Re: Consistent Wording for Injection Orders- Well Integrity (Revised)) From: John. Norman <john_norman@admirratate.ak.us> Date: Fri, O1 Oct 200411:08:55 -0800 To: Jody J Calombe <jody_colombie@admin.state.ak.us> please print all and put in file for me to review just prior to hearing on these amendments. thanx ------- Original Message -------- Subject:Re: Consistent Wording for Injection Orders -Well Integrity (Revised) Date:Thu, 19 Aug 2004 15:46:31 -0800 From:Rob Mintz <robert mintz~law.state.ak.us> To:dan seamount~admin.state.ak.us, jim reggnaadmin.state.ak.us, john norman(a~admin.state.ak.us Jim, I have some questions about the draft language, which are shown as comments on the first document attached. Based on my current guesses about what the answers will be to my questions, I also have some suggested edits, which are shown as redlines on the second document attached. »> James Regg <jim regg~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 abililty to grant alternate methods (e.g., temp survey, logging, pressure monitoring in lieu of pressure testing - specific to AIO 2C for Kuparuk, there is wording that is more appropriately included in Well Integrity Failure (i.e., more frequent MITs when communication demonstrated) - establishes more frequent MIT schedule for slurry injection wells (every 2 yrs) which is consistent with our current practice (but not addressed in regulations) Wetl Integrity Failure - retitles to "Well Integrity Failure and Confinement"; inserted language regarding injection zone integrity (see DIO 25 and 26) - consistent language regardless of type of injection (disposal, EOR, storage); - eliminates requirement for immediate shut in and secure; allows continued injection until Commission requires shut in if there is no threat to freshwater; - eliminates delay in notifying Commission after detect leakage or communication ("i.e., "immediately notify"); - removes language about notifying "other state and federal" agencies; - requires submittal of corrective action plan via 10-403; - requires monthly report of daily injection rate and pressures (tubing and all casing annuli); this is a requirement we currently impose when notified of leak or pressure communication; - notice and action not restricted to leaks above casing shoe as stated in several DIOs Administrative Actions 1 of 2 10/2/2004 4:07 PM [Fwd: Re: Consistent Wording for Injection ~rs -Well Integrity ... i - 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 ___ i Content-Type: application/msword .'Injection Orders language edits.doc Content-Encoding: base64 .........._ ............................. _.. ___ 2 of 2 10/2/2004 4:07 PM • i Standardized Language for Injection Orders Date: August 17, 2004 Author: Jim Regg Demonstration of Tubing/Casing Annulus Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before injection begins, after a workover affecting mechanical integrity, and at least once every 4 years while actively injecting. For slurry injection wells, the tubing/casing annulus must be tested for mechanical integrity every 2 years. The MIT surface pressure must be 1500 psi or 0.25 psi/ft multiplied by the vertical depth, whichever is greater, must show stabilizing pressure and may not change more than 10% during a 30 minute period. Any alternate means of demonstrating mechanical integrity must be approved by the Commission. The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests. Well Irate rite 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 (eYCept at least once every two years in the case of a slumT injection «•ell), and before returnin~a well to sen-rice, folio~vin~ a-fte-~ a workover affecting mechanical integrity, ~~~u c.t l,c.:~* „~,~~ : ~:,r~, ,:=jam ~` .f,: ~, ,.*~ ~ *~ / ~;r-;~ Unless an alternate means is approved by the Commission mechanical integrity must be demonstrated. by a tubing pressure test using a ~ -~ surface pressure ofn~ 1500 psi or 0.25 psi/ft multiplied by the vertical depth, whichever is greater, t11at ~-shows stabilizing pressure that does^„ not change more than 10°=~ percent during a 30 minute period. ~-y - . The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests. Well Integrity Failure and Confinement EYCept as other«:•ise 1rovided in this rule Tthe tubing, casing and packer of an injection well must d~o°~~rte-maintain integrity during operation. Whenever any pressure communication, leaka€~e or lack of injection zone isolations indicated by injection rate, operatin6 pressure obscrvati.on, test, survey 106 or otl~cr evidence tThe operator must-shall immediately notify the Commission and submit a plan of corrective action on a Form 10-403 for Commission approval: ., ` ` ) ` °"~'"" ""t ° ~~nn "''° • *• ~ -' The operator shall shut in the "J ~'Y 5 Yre° , , wel.I if so directed by the Commission Tl~e operator shall shut in the well «:-ithout a«•aiting a response from the Comtnissicm if continued operation i-vould he unsafe or would threaten contamination of freshwater t .Until corrective action is successfully completed, f4a monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating pressure communication or leakage. Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. -[Fwd: Re: [Fwd: AOGCC Proposed WI Lan for Injectors]] Subiect: [Fwd: Re: [Fwd: AOCrCC Proposed WILanguage for Injectors]] From: Winton Aubert <winton aubert@admin.state.ak.us> Date: Thu, 28 Ocf 2004 09:4$:53 -0800 To: Jady J Colo~nbie <jody_colornbe@admin.state.ak.us> This is part of the record for the Nov. 4 hearing. WGA -------- Original Message -------- Subject: Re: [Fwd: AOGCC Proposed WI Language for Injectors] Date: Thu, 28 Oct 2004 09:41:55 -0800 From: James Regg <jim regg@admin.state.ak.us> Organization: State of Alaska To: Winton Aubert <winton aubert@admin.state.ak.us> References: <41812422.8080604@admin.state.ak.us> These should be provided to Jody as part of public review record Jim Winton Aubert wrote: FYI. -------- Original Message -------- Subject: AOGCC Proposed WI Language for Injectors Date: Tue, 19 Oct 2004 13:49:33 -0800 From: Engel, Harry R <Enge1HR@BP.com> To: winton aubert@admin.state.ak.us Winton... Here are the comments we discussed. Harry *From: * NSU, ADW Well Integrity Engineer *Sent: * Friday, October 15, 2004 10:43 PM *To: * Rossberg, R Steven; Engel, Harry R; Cismoski, Doug A; NSU, ADW Well Operations Supervisor *Cc: * Mielke, Robert L.; Reeves, Donald F; Dube, Anna. T; NSU, ADW Well Integrity Engineer *Subject: * AOGCC Proposed WI Language for Injectors Hi Guys. John McMullen sent this to us, it's an order proposed by the AOGCC to replace the well integrity related language in the current Area Injection Orders. Listed below are comments, not sure who is coordinating getting these in front of Winton/Jim. Overall, looks okay from an Operations perspective. We do have a few comments, but could live with the current proposed language. Note the proposed public hearing date is November 4. The following language does not reflect what the slope AOGCC inspectors are currently requiring us to do: "The mechanical integrity of an injection well must be demonstrated before injection begins, at least once every four years thereafter (except at least once every two years in the case of a slurry injection well), and * before*_** 1 of 3 10/28/2004 11:09 AM [Fwd: Re: [Fwd: AOGCC Proposed WI Lan 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:jody colombie@admin.state.ak.us ] Sent: Wednesday, September 29, 2004 1:01 PM Subject: Public Notices Please find the attached Notice and Attachment for the proposed amendment of underground injection orders and the Public Notice Happy Valley #10. Jody Colombie «Mechanical Integrity proposal.ZIP» «Mechanical Integrity of Wells Notice.doc » 2 of 3 10/28/2004 11:09 AM ~ 7 • ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3912 Re: THE REQUEST OF UNION OIL ) Disposal Injection Order No. 6 COMPANY OF CALIFORNIA to ) dispose of non-hazardous ) Lewis River Well D-1 oil field waste fluids ) Lewis River Gas Field by underground injection ) in Lewis River Well D-1 ) May 11, 1989 IT APPEARING THAT: 1. By letter dated December 7, 1988, Union Oil Company of California (Unocal) submitted an application requesting the Alaska Oil and Gas Conservation Commission (the Commission) to issue an order authorizing the disposal of non-hazardous oil waste fluids by injection into Lewis River Well D-1. 2. Notice of an opportunity for a public hearing on January 13, 1989 was published by the Commission in the Anchorage Daily News on December 14, 1988. 3. By letter dated December 28, 1988 Trustees for Alaska and the Alaska Center for the Environment protested issuance of subject disposal order and requested a hearing for Unocal's application. 4. On January 13, 1989, at 11:00 AM AST in the conference room of the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska, a hearing was held on Unocal's application to dispose of non-hazardous oil field waste fluids by underground injection in .Lewis River Well D-1. 5. The hearing record remained open for ten working days follow- ing notification, to all parties attending the hearing, of the U. S. Environmental Protection Agency's (EPA's) action under 40 CFR 144.7(b)(3)(ii) with respect to Unocal's aquifer exemption application. EPA approved the aquifer exemption by letter dated March 28, 1989. Trustees for Alaska and the Alaska Center for the Environment both testified against the application. Trustees for Alaska submitted a written opposi- tion dated January 13, 1989. The hearing record closed at 4:30 PM, April 11, 1989, without any further opposition to the application being filed. 6. The Commission issued Aquifer Exemption Order No. 3 on March 30, 1989, exempting aquifers lying below a depth of 2300 feet in Unocal's Lewis River Well D-1 and within a circle of one-quarter (4) mile radius around the well. The exemption is for the purpose of Class II underground injection activities only. ~'' • ~ Disposal Injection Order No. 6 May 11, 1989 Page 2 FINDINGS: 1. Trustees for Alaska and the Alaska Center for the Environment have raised questions regarding: 1) requirement for a waste water disposal permit from Alaska Department of Environmental Conservation (ADEC); 2) consistency of activity with the Alaska Coastal Management Program (RCMP) and notification of those agencies with ACMP responsibility; 3) Commission authority to approve activity outside an existing oil and gas unit; 4) D-1 well's integrity and subsequent ability to confine injected fluids to proposed disposal zones; 5) characterization of fluids proposed for disposal; 6) com- patibility of injected fluids with formation and formation waters; 7) extent of radial invasion of injected fluids; 8) processing of fluids proposed for disposal; 9) solid waste disposal; 10) filing of EPA Form 4 (EPA Form 7520-6); 11) applicable procedures for processing UIC permits; and 12) public notice requirements. 2. No ADEC permit is required because AS 46.03.100(d) exempts from ADEC permitting requirements injection projects per- mitted by the Commission under AS 31.05.030(h). 3. Unocal received a conclusive ACMP consistency determination for its surface operations from the Division of Governmental Coordination March 22, 1989. The Commission's regulations provide for control of the proposed subsurface operations, which should ensure that surface impacts will not occur, other than those resulting from the above ground activities which have been permitted by other agencies and which already have been found to be consistent with the ACMP. 4. AS 31.05.030 grants the Commission jurisdiction and authority over all persons and property subject to the state's police powers, regardless of whether the property is "unitized". 5. Unocal's Lewis River Well D-1, an abandoned well, will be entered and completed as an underground injection well. 20 AAC 25.005(b) requires submission of an application for Permit to Drill. Enforcement of 20 AAC 25.412 requires that Lewis River Well D-1 be constructed, and the mechanical integrity demonstrated in a manner that will insure that injected fluids are confined to projected disposal strata. The well must be tested and monitored thereafter for dis- closure of possible abnormalities in operating conditions that may lead to the endangerment of underground sources of drinking water. 6. The Commission finds the fluids proposed for injection under Unocal's December 7, 1988 application are acceptable for disposal into Class II injection wells. • ~ Disposal Injection Order No. 6 May 11, 1989 Page 3 7. Commission regulations do not require that oil field waste fluids injected for disposal be compatible with the formation or formation waters. 8. The Commission finds the proposed volume of injected fluids over the life of the disposal project will not extend beyond a one-quarter (4) mile radius from the well. 9. Enforcement by the Commission of the regulations will insure the requirements of 20 AAC 25.432, requiring regular reporting of injection activities, are met. 10. Disposal of waste solids has no bearing on issuance of an order providing for disposal of oil field waste fluids. 11. The Commission does not require the filing of EPA Form 4 (EPA Form 7526-6) as part of an application for issuance of an order providing for disposal of non-hazardous oil field waste fluids . 12. 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). 13. The Commission's procedures in matters involving handling of the subject application and posting of public notice fully conforms to the Alaska Oil and Gas Conservation Act, AS 31.05; the Commission's regulations, 20 AAC 25; and 40 CFR 147 Subpart C (which is in consort with those sections of 40 CFR Part 124 that apply to state UIC programs awarded in conformance with Section 1425 of the Safe Drinking Water Act of 1974 as amended). 14. Permeable strata that will accept injected fluids are present below 2300 feet in Lewis River Well D-1. 15. A series of confining strata are present above 2300 feet in Lewis River Well D-1 that will prevent upward movement of injected fluids through the strata into underground sources of drinking water. 16. The strata into which fluids are to be injected should accept fluids at injection pressures which are less than the fracture pressure of the confining strata. CONCLUSION: The stratigraphic sequence present at the well site and mainten- ance of the mechanical integrity of Lewis River Well D-1 will prevent movement of injected fluids into underground sources of drinking water. • r Disposal Injection Order No. 6 May 11, 1989 Page 4 NOW, THEREFORE, IT IS ORDERED THAT: Rule l Non-hazardous oil-field waste fluids may be injected in conform- ance with AAC Title 20, Chapter 25 for the purpose of disposal into the Beluga Formation below the measured depth of 2300 feet in Lewis River Well D-1. Rule 2 Tubing/casing annulus pressure variations between consecutive observations need not be reported to the Commission. Rule 3 Upon request, the Commission may amend any rule stated above so long as the operator demonstrates to the Commission's satisfaction that sound engineering practices are maintained, and the amend- ment(s) will not result in an increased risk of fluid movement into an underground source of drinking water. DONE at Anchorage, Alaska, and dated May 11, 1989. '4•~~A ®gL .'fir ~~ ~ ,~ ~' :~ , ~ ~N~ , `~,• y~0 ~?'jaN Co~~,~ .. C V Chatterton, Ch Alaska Oil and Gas Conservation Commission Bonnie L 5mit Cissioner Alaska Oil an Gas Conservation Commission llavicl W Johns~or~; C;o~iniissioner Alaska Oil an Gas Conservation Commission ~6 1 STATE OF ALASKA 2 ALASKA OIL AND GAS COMMISSION 3 PUBLIC HEARING 4 REGARDING UNOCAL's APPLICATION FOR AN UNDERGROUND INJECTION CONTROL PERMIT 5 LEWIS RIVER WELL D-1 6 COMMISSIONERS PRESENT: 7 Chat Chatterton, Chairman 8 Lonnie Smith, member 9 Steven R. Porter, Assistant Attorney General 10 January 13, 1989 11 11:00 p.m. 3001 Porcupine Drive 12 Anchorage, Alaska 13 14 15 16 17 18 19 ~~VEC~ 20 ~~~.. , 21 Alaska Oil .& Gas Cans. Commission 22 `,~`'-' AfIChO('a~@' 23 24 25 R & R COURT REPORTERS 810N STREET, SUITE 101 509 W.3RD AVENUE 1007 W.3RD AVENUE 277-0572 - 277-0573 277-8543 272-751 5 ANCHORAGE, ALASKA 99501 1 • • 2 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 r~ U P R O C E E D I N G S MR. CHATTERTON: Ladies and gentlemen, if we could come to order, please? The time is approximately 11:02 a.m. on ~i~he 13th of January, 1989, and the location is at 3001 Porcupine Drive in the conference room of the Alaska Oil and Gas Conservation Commission. I am Chat Chatterton with the Commission and will be presiding over the meeting here, the hearing. To my extreme left, your right, is Meredith Downing with R & R Court Reporters who will be taking down the proceedings, and immediately to my left is Lonnie -- Commissioner Lonnie Smith, and to my right is Steve Porter from the Attorney General's Office, and acting in .the capacity as the attorney for the Commission. Commissioner Smith, would you be willing to read into the record the purpose of this meeting? MR. SMITH: Thank you. The purpose of this 'hearing was call by the notice published in the Anchorage Daily jNews December the 14th, 1988, and I will read it in its entirety. "The State of Alaska, Oil and Gas Conservation ,Commission, reference, the application of Unocal for an order lauthorizing the underground disposal by an injection. of 'nonhazardous oil waste fluids at the Lewis River. Field. The Alaska Oil and Gas Conservation Commission has been 'requested by letter from Unocal dated December the 7th, 1988, to tissue an order in conformance with 20 AAC 25.252. The order R & R COURT REPORTERS 810N STREET, SUITE 101 509 W.3RD AVENUE 1007 W.3RD AVEN UE 277-0572 - 277-0573 277-8543 272-751 5 ANCHORAGE, ALASKA 99501 1 2 3 4 5 6 7 8 9 I 10 11 12 • 13 14 15 16 17 18 19 20 21 22 23 24 25 r~ • • 3 would authorize the disposal of nonhazardous liquid waste by injection into. Lewis River Well D-1. .This well would be converted to an injector and used for disposal of nonhazardous oil field waste fluids by injection into the upper half of the Beluga formation at the Lewis River Field, Mat-Su Borough, Alaska. "A person who may be harmed if the requested order is issued may file a written protest prior to December the 29th of 1988 with the Alaska Oil and Gas Gonservation Commission, 3001 Porcupine Drive, Anchorage, Alaska .99501, and request a hearing on thee 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 be held at the above address at 11:00 a.m. on January the 13th, 1989. In conformance with 20 AAC 25.540. If a hearing is to be held, interested parties may confirm this by calling the Commission's office at 279-1433 after December the 29th, 1988. If no proper protest is filed, the Commission will consider the issuance of the order without a hearing. Lonnie Smith, Commissioner, Alaska Oil and Gas Conservation Commission." MR. CHATTERTON: Thank you, Lonnie. The -- this hearing, the procedure to be followed in this hearing is -- will be followed according to our regulation, which is 20 AAC 25.540. We have just completed a hearing and as I look around on another matter which is basically an aquifer exemption request, R & R COURT REPORTERS 810NSTREET, SUITE 101 509 W.3RD AVENUE 1007 W.3RD AVENUE 277-0572-277-0573 277-8543 272-7515 ANCHORAGE, ALASKA 99501 • 4 1 and as I looked around the room, I see virtually no one new here. 2 that was not present at that earlier time when I briefly set 3 forth the procedures that 540 calls for in conducting this 4 hearing, so I will not belabor the point by repeating that. 5 I do have to make a statement that I think is 6 appropriate, and that is the resolution of the matter we have at ~ this hearing before us now obviously cannot be reached until such g time as action is taken upon -- one .way or the other upon the 9 aquifer exemption by another agency, a federal agency, and so we 10 '- we cannot -- we will discuss this as we get on down through 11 the matter as far as keeping the hearing record open for further 12 action. . 13 I do believe that it's appropriate, and lacking any 14 Protest, why to make the testimony that was offered by all 15 parties in the previous public hearing held earlier this morning 16 on the application by Union for a fresh water aquifer exemption, 1~ that that testimony be made a part of the record of this hearing, lg and we will -- lacking any objection, we -- we will proceed to 19 make that Exhibit A of the current hearing. Is there -- I'll 20 give you a moment to think about it, but is there any objection? 21 Off the record. 22 (Off record) 23 (On record) 24 MR. CHATTERTON: During the break, why we 25 ascertained that there was no objection to that proceedure, so '' R & R COURT REPORTERS 810N STREET, SUITE 101 509 W.3RD AVENUE 1007 W.3RD AVENUE '. 277-0572 - 277-0573 277-8543 272-751 5 '. ANCHORAGE, ALASKA 99501 • 1 2 3 4 5 6 7 8 9 10 11 12 . 13 14 15 16 17 18 19 20 21 22 23 24 25 ~~ U 5 very formally the testimony from the previous hearing held this morning on Union of California's request for an aquifer exemption, that testimony becomes part of the record for the hearing on the underground disposal by injection, application by Union Oil Company, and we will designate that as Exhibit A of this hearing. Again why I'll ask the question of who -- whom would -- if the people wish- -- wishing to testify, would -- would indicate their presence and step forward, why we'll have. Commissioner Smith swear you in. All those wishing to testimy, why please step forward. (All potential witnesses sworn under oath by Mr. Smith) MR. CHATTERTON: Just as an aside, why while several of you have been sworn in, it's not mandatory that you testify, so it's your choice as we proceed. Well, that brings us to the first step in -- in this procedure, and that is for the applicant, Union Oil Company of California, to present their case? MR. ROBERTS: Thank you. My name is Roy Roberts. I'm Unocal's environmental engineer for the Alaska District. Unocal in a similar manner to the previous hearing for the aquifer -- aquifer exemption, would request that the permit application be considered part of the hearing.. The per- -- excuse me, the permit application for Lewis River D-1 well be considered part of this hearing. R & R COURT REPORTERS SIONSTREET, SUITE 101 509 W.3RD AVENUE 1007 W.3RD AVENUE 277-0572-277-0573 277-8543 272-7515 ANCHORAGE, ALASKA 99501 C7 • 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 • MR. SMITH: Okay 'Exhibit B. 6 And I will make .that MR. ROBERTS: Unocal ..... MR. CHATTERTON: Mr. Roberts, go ahead. MR. ROBERTS: Unocal would also like to request that the -- as I'm sure that will be considered that we hold this comment period or the -- the formal written comment period open for an additional two weeks similar to the previous aquifer exemption hearing so that we may prepare and submit our comments which we do not have at this time. MR. CHATTERTON: Thank you. We will address the -- keeping the hearing record open as we proceed and get closer. to finalization of our morning hearing. MR. ROBERTS: Thank you. That's all the comments I have. MR. CHATTERTON: All right. Are there any other things to be brought before us? Yes, sir? MR. WEINER: I'd like the opportunity to testify here? MR. CHATTERTON: Please do, Mr. Weiner. MR. WEINER: Thank you, Commissioner. It's my understanding that Exhibit A includes all of the testimony produced in the previous hearing on an aquifer exemptions -- aquifer exemptions, and I would propose that my prior testimony be incorporated with modifications. R & R COURT REPORTERS BfONSTREET, SUITE101 509 W.3RD AVENUE 1007 W.3RD AVENUE 277-0572 - 277-0573 277-8543 272-751 5 ANCHORAGE, ALASKA 99501 • • • 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 r 1 U 7 First, that any reference made to aquifer exemptions where appropriate should refer to this underground injection permit. And -- and secondly, I have two additional comments to make relating specifically to the UIC permit application. First is that Unocal apparently has not submitted evidence of a surety bond or a financial statement verifying the resources necessary for plugging and abandoning the -- the D-1 well. The bond normally posted with this Commission applies to ail and gas wells or strategraphic test wells, not injection wells. Modification of -- of the form 10-402 may be required or a -- or a separate form developed. Finally, this Commission -- this Commission's systems programs for -- for permit transfers appear to require a modification -for injection wells as well. The -- the application for sundry approval, form 10-403, designation of operator for 20 AAC 25.020, and -- and notice of change of -- of ownership .should all be part of that modification process. And -- and finally, if I could at this junction point out ~~ that I understand that with -- oh, may I see that, please -- ''~ relating to aquifer exemptions, this Commission is -- is not a permitting body, but to use your terminology in a prior hearing, is a clearing house for the EPA, and as such the requirements -- the regulations set forth pursuant to the Safe Drinking Water Act, Section 14.25, are probably not applicable, and the R & R COURT REPORTERS 810N STREET, SUITE 101 509 W.3RD AVENUE 1007 W.3RD AVENUE 277-0572 - 277-0573 277-8543 272-751 5 ANCHORAGE, ALASKA 99501 • • 1 2 3 4 5 6 7 8 9 10 11 12 • 13 14 15 16 17 18 19 20 21 22 23 24 25 U 8 regulations promulgated pursuant to 14.21 and 14.22 of the safe - - safe drinking water act, are probably. more applicable, and. those regulations to -- require -- necessitate all sorts of -- of procedural requirements, one of which. is a 30-day notice period as opposed to a 15-day notice period. And although this is the UIC portion of these series of hearings, it may be appropriate for the Commission to take a hard look at -- at whether it should grant 30-day periods for underground injection -- excuse me, for aquifer exemption notices as opposed to -- to 15 days. And with that I conclude my formal testimony. MR. CHATTERTON: Thank you very much. Is there anyone else that would chose to make any statements, .... MR. DISOTELL: Yes. MR. CHATTERTON: ..... direct any questions through the chair? MR. SMITH: He said yes. MR. CHATTERTON: Yeah. MR. DISOTELL: I thought you were asking for testimony, I'm sorry. MR. CHATTERTON: Oh, okay. Did -- do you want to .....? MR. DISOTELL: I do wish to testify, yes. MR. CHATTERTON: You bet. Go ahead, Bob. MR. DISOTELL: Thanks. MR. CHATTERTON: Okay. R & R COURT REPORTERS BfONSTREET, SUITE 101 509 W.3RD AVENUE 1007 W.3RD AVENUE 277-0572 - 277-0573 277-8543 272-751 5 ANCHORAGE, ALASKA 99501 • • 1 2 3 4 5 6 7 8 9 10 11 12 '~~ 13 14 15 16 17 18 19 20 21 22 23 24 25 ~J 9 MR. DISOTELL: My name is Robert Disotell. I am employed by Trustees for Alaska as a technical advisor.. I have some comments' here, and I think they'll be relatively brief, I'll read '.quickly through them. These are 'comments on the UIC permit application technical grounds. One, Unocal has not described those -- those surface facilities necessary for the'' processing of the fluids to be injected into well D-1. Unocal's application should be revised to describe these facilities. 'This will be required for obtained an ADEC waste water permit. Number two, the fluids proposed for injection are not adequately characterized. For example, workover fluids, such as acids and bases are not characterized. Number Three, Unocal has not described the manifesting system which will be employed to trace these fluids from the point of origin to the point of disposal. Four, Unocal has not described any contingency plans or emergency plans for controlling well problems or surfact facility problems such as spills. Five, it appears tat this well will have a substantial capability for backflowing. A surface safety valve will be required at a minimum.. A subsurface safety valve may be required to protect the drinking water formations from a backflow of injected fluids and hydrocarbons from the injection -- from the injection zones in the event of well damage between the surface R & R COURT REPORTERS 81 O N STREET, SUITE 101 509 W. 3R D..AVENUE 1007 W. 3RD AVENUE 277-0572 - 277-0573 277-8543 272-751 5 ANCHORAGE, ALASKA 99501 • • 10 1 2 3 4 5 6 7 8 9 10 11 12 • 13 14 15 16 17 18 19 20 21 22 23 24 25 r ~ L...J and the injection intervals. Six, Unocal has not described its plan for conducting mechanical integrity testing on this well. Seven, Unocal has not presented any information concerning the current condition of the well. After seven years, this well may not be worth attempting reentry on. Eight, Unocal has not described its stimulation plan for this well. Nine, Unocal has failed to demonstrate that the fluids proposed for injection will be compatible with the receiving formation fluids and the -- and the lithology of the receiving zone. Ten, Unocal's calculation. of the extent of radial invasion is inadequate. The calculation addresses only one interval whereas Unocal is proposing injection into one or more of seven different intervals, some of which are thinner than the interval that was -- this was calculated for. Eleven, Unocal has not addressed in sufficient detail the following items, among others, .pertaining to the processing of fluids proposed for disposal: A. Transport of the fluids; B. A thorough description of the sources of the fluids; C. On site storage and processing of the; D. Metering of the fluids; and E. Record keeping requirements for these fluids. R & R COURT REPORTERS 810NSTREET, SUITE 101 509 W.3RD AVENUE 1007 W.3RD AVENUE 277-0572 - 277-0573 277-8543 272-751 5 ANCHORAGE, ALASKA 99501 • 11 1 Twelve, Unocal has not addressed in sufficient detail the 2 following items, among others, pertaining to the physical 3 appurtenances of the injection well and to its ..physical 4 integrity: 5 A. Well head safety systems; 6 B. Subsurface safety systems; ~ C. Annulus monitoring and vacuum/pressure safety .devices 8 and alarms; 9 D. Tubing pressure monitoring nad vacuum/pressure safety 10 devices and alarms; and 11 E. Workover plans to ensure the physical integrigy of 12 the well. 13 Thirteen, Trustees taks specific issue with Unocal's 14 request for a waiver of the requirements of 20 AAC 25.25(e) -- 15 252(e). This well has been suspended/abandoned for seven years 16 and may have serious structural integrity problems. The present 17 condition of the casing, tubing, and cement related to this well 18 is unknown and waivers of those requirements designed to ensure 19 the integrity of the well are inappropriate. 20 The small thermal gradients that would be experienced by 21 this well should result in minimal thermally. induced pressure 22 effects in the annulus. A pressure rise of 200 PSI in the 23 annulus of this well would be indicative of a potentially serious 24 problem. 25 Fourteen, Unocal's application does not address a water i R & R COURT REPORTERS 810NSTREET, SUITE 101 509 W.3RD AVENUE 1007 W.3RD AVENUE 277-0572-277-0573 277-8543 272-7515 ANCHORAGE, ALASKA 99501 • ! 12 1 well which is at the edge of the Lewis River D-i well pad. It is 2 unknown if this well penetrates the proposed injection zone. We 3 have very little information on this particular well, just simply 4 a picture of it. 5 Fifteen, Unocal has not addressed the disposal of solids 6 that may be filtered out or settle in tanks at the well head. 7 This would normally be addressed by a separte solid waste 8 disposal permit application to the ADEC. 9 Unocal -- sixteen, Unocal's application for an 10 underground injection control permit does not appear to have been 11 certified by a true and correct -- to be true and correct by a 12 responsible corporate officer. • 13 Seventeen, Unocal has not submitted a plugging and 14 abandonment plan for well D-1. 15 Eighteen, Unocal -- that one has already been covered by 16 Mr. Weiner. 17 That's the end of my testimony. 18 MR. CHATTERTON: Thank you very much, Bob. 19 Is there anyone else that wishes to present something for 20 the record or have any questions that they might like to direct 21 through the chair? 22 Well, that brings us down to the matter of keeping the 23 record open for this hearing, and why don't we go off the record 24 and -- and just start exploring it? 25 (Off record] R & R COURT REPORTERS 810N STREET, SUITE 101 509 W.3RD AVENUE 1007 W.3RD AVENUE 277-0572 - 277-0573 277-8543 272-751 5 ANCHORAGE, ALASKA 99501 • . 13 1 (On record) 2 MR. CHATTERTON: While we were at ease, .why we 3 explored the procedure that would be most equitable and -- and 4 simplest to follow from here on out. Obviously as we've 5 previously said, why any action on the part of the current 6 application before -- subject of this hearing by the Commission ~ becomes moot if the -- unless the aquifer is exempt by EPA. And 8 accordingly what we see would be appropriate is to keep the 9 hearing record open until two weeks, ten working days, following 10 receipt -- following notification to all parties in this hearing 11 of -- of EPA's action with respect to the aquifer exemption 12 request which was the subject of the previous hearing held here 13 this morning. 14 There is one further question which I forgot to ask while 15 we were at ease, and so I'll -- I'll put it on the table right 16 now . 17 The Commission would request that the December 28th, 18 1988, letter to Commission Lonnie Smith from Trustees of Alaska 19 be made a part of this record, and lacking any objection, why we 20 will so designate it as Exhibit ....? 21 MR. SMITH: C. 22 MR. CHATTERTON: C as in Charlie. 23 MR. WEINER: Trustees for Alaska assents. 24 MR. CHATTERTON: Thank you very much. 25 Is there anything else to -- to become -- to come before ~, R & R COURT REPORTERS i 810N STREET, SUITE 101 509 W.3RD AVENUE 1007 W.3RD AVENUE 277-0572 - 277-0573 277-8543 272-751 5 ANCHORAGE, ALASKA 99501 • • • C7 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 14 us in this hearing? If not, why the hearing record will be held open until fourteen days, ten days -- ten working days after notification of all parties to this hearing is received as to what EPA's decision is regarding the exemption of the- aquifer in the Lewis River area, which was the subject of the previous ~~hearing held this morning -- earlier this morning on January 13th, 1989. That's it. Off the record. (END OF PROCEEDINGS) R & R COURT REPORTERS 810 N STREET, SUITE 101 509 W. 3RD AVENUE 1007 W. 3RD AVENUE 277-0572-277-0573 277-8543 272-7515 ANCHORAGE, ALASKA 99501 • • 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 r 1 U 15 C E R T I F I C A T E UNITED STATES OF AMERICA ) ss. STATE OF ALASKA ) I, Meredith L. Downing, Notary Public in and for the State of Alaska, residing at Anchorage, Alaska, and Electronic Reporter for R & R Court Reporters, Inc., do hereby certify: That the annexed and foregoing public hearing before .the Alaska Oil and Gas Conservation Commission was taken before me on the 13th day of December, 1988, commencing at the hour of 11:00 o'clock a.m., at the offices of the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska, pursuant to Notice. That all witnesses, before examination, were duly sworn to testify to the truth, the whole truth, and nothing but the truth; That this transcript, as heretofore annexed, is a true and correct transcription of the testimony given at said Public Hearing, taken by me and thereafter transcribed by me. That the original of the transcript has been lodged as required with the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska. That I am not a relative, employee or attorney of any of the parties, nor am I financially interested in this action. IN WITNESS WHEREOF, I have hereunto set my hand and affixed my seal this 30th day of January, 1989. S E A L Notary Public in and for Alaska My Commission Expires: 5/3/90 R & R COURT REPORTERS 810NSTREET, SUITE 101 509 W.3RD AVENUE 1007 W.3RD AVENUE 277-0572-277-0573 277-8543 272-7515 ANCHORAGE, ALASKA 99501 ~5 ' ~ ~ . I ~~ ~a ~a~ ~ Ll~lDGAL ~y ~~~-~ ,~ .~ ~~ ~, vwo~d ~-, ~~/ i ~ C ' ~ ,~- o--r.~. U., _e _ ~. - _ _ ___ ~~Qir ~~ Wc~ril.dL~'~l /'_t ~ ~9 CG ,~ ~~. ~ ~o ~~ ,~ O G C C M' Min~dc: I ~ k c: R. ~ 4 • q December 28, 1988 Commissioner Lonnie C . Smith Alaska Oil and Gas Conservation Commission DEC 2 S1°~3 3001 Porcupine Drive Anchorage , Alaska 99501 Alaska Oll Sc Gas Cons. CO[nm1SS1G Subject: UNOCAL Lewis River Well D-1 Injection Application UNOCAL Lewis River Well D-1 Aquifer Exemption Application Request for public hearing Dear Commissioner Smith: Trustees for Alaska and the Alaska Center for the Environment hereby file a written protest to, and request a hearing on, the. above applications. Our request is predicated, in part, on the need for a thorough discussion and review of-the following-material _. issues, which, we believe, are crucial. to your determination on whether to grant these applications: 1. UNOCAL apparently has not applied for a-waste water dis- - posal permit from the Alaska Department of Environmental Conserva- tion (ADEC) for these activities. A waste water disposal permit is required pursuant to 18 AAC.72.210, et seq.. - 2. Section 307(c)(3) of the Coastal Zone Management Act of 1972, as amended by 16 USC 1456(c)(3), requires. the applicant to certify that activity affecting land .or water uses in the Coastal - Zone complies with the Alaska Coastal~Management Program. A deter- mination of consistency with the Matanuska - Susitna Borough Coastal -- - Management Program is also required pursuant to AS 46.40. 010. - UNOCAL apparently has not notified the Matanuska-Susitna Borough or the Office of Management and Budget, Division of Govern- mental Coordination of the proposed injection well activity and has not applied for a coastal zone management act certification. The proposed activity is within the Mat-Su coastal zone as shown on Tyonek Map #89 of the Alaskan Coastal Zone Boundaries. 3. UNOCAL apparently has not notified the Office of Management. and Budget, Department of Governmental Coordination of this applica- tion as required by AS 44.19.145(x)(11) .whenever an application includes two or more government agencies. _ 725 Christensen Drive, Suite 4 Anchorage, Alaska 99501 (907) 276-4244 4. The proposed injection well is outside the boundaries of the Lewis River Unit. The legality of injecting unit fluids from production oil and gas wells into an aquifer that lies outside of an existing oil and gas unit is questionable. The Alaska Oil and Gas Commission (AOGCC) may not have the legal authority to approve of such an activity. 5. The requested aquifer exemption is for a well outside the boundaries of the Lewis River Unit. AOGCC does. not appear to have the authority to exempt aquifers outside the boundaries of existing oil and ,gas units. 6. UNOCAL has not addressed the issue of casing cementing as required by 20 AAC 25.252 (b). The integrity of the cementing of this well is particularly critical between 1190 feet and 1270 feet of measured depth. UNOCAL has not demonstrated that the drilling affected zone is sealed in a manner that will prevent the vertical migration of the injected fluids. 7. UNOCAL has not demonstrated that vertical migration of fluids will not occur between any of the various zones whether they are injection zones, hydrocarbon zones, or fresh water zones.. If this well is dependant upon the use of drilling mud for zone seal- ing, then vertical migration will likely occur.. 8. UNOCAL has stated that the maximum surface injection pressure will be 1500 PSI.. This appears to be extremely high considering the nature and depth of the receiving formations as well as the relatively low injection volumes. Injection pressures this high would tend to indicate a tight formation and would result in high pressures adjacent to the well bore. This would promote vertical migration through the drilling affected zone adjacent to 'the wellbore. 9. UNOCAL has not adequately characterized the fluids proposed for disposal. For example, workover fluids such as acids .and bases are not characterized. 10. Some of the fluids listed by UNOCAL pursuant to 20 AAC 25.252(c)(7) for disposal are not eligible for disposal into Class II wells. EPA has provided specific guidance on the fluids eligible for disposal into Class II wells and such fluids as equipment washwaterare not included. 11. UNOCAL has failed to demonstrate for injection will be compatible with the formations, required by 40 CFR 146. 12. UNOCAL has failed to demonstrate for injection will be compatible with the required by 40 CFR 146. 2 that the fluids proposed fluids in the receiving that the fluids proposed receiving formations, as RECEIVED DEC 2 8 1°r:~s Alaska :Oii & Gas Cons. Commission ` ' +' AnCi10~a~'° C: 13. UNOCAL's calculation of the extent of radial invasion is inadequate. The calculation addresses only one interval whereas UNOCAL is proposing injection into one or more of 7 different intervals. 14. UNOCAL has not addressed in sufficient detail the following items, among others, pertaining to the processing of the fluids proposed for disposal: ~a. Transport of the fluids; b. A thorough description of the sources of the fluids; c.~ On site storage and processing of the fluids; d. Metering of the fluids; and e. Record keeping requirements for these fluids. 15. UNOCAL has not addressed in sufficient detail the follow- ing items, among others, pertaining to the physical appurtenances of the injection well and to its physical integrity: a. Well head safety systems; b. Subsurface safety systems; c. Annulus monitoring and vacuum/pressure safety devices and alarms; d. Tubing pressure monitoring and vacuum/pressure safety devices and alarms; and e. Workover plans to ensure the physical integrity of the well. 16. Trustee's takes specific issue with UNOCAL's request for a waiver of the requirement of 20.AAC 25.252 te) . This well has been suspended/abandoned for 7 years and may have serious structural integrity problems. The present condition of the casing, tubing., and cement related to this well is unknown and waivers of those requirements designed to ensure the integrity of the arell are inappropriate. 17. UNOCAL's application does not address a is at the edge of the Lewis River D-1 well pad. this well penetrates the proposed injection zone. water well which It is unknown if 18. UNOCAL's methodology for calculating salinity does not appear to adequately substitute for the laboratory analysis for total dissolved solids, as required by 40 CFR 136. 19. UNOCAL has not addressed .the disposal of solids that may be filtered out or settle in tanks at the well head. This would normally be addressed by a separate solid waste disposal permit application to the ADEC. 20. UNOCAL's application for a Underground Injection Control permit has not been certified to be true. and correct by a respon- sible corporate officer. R E C E 1~ E G 3 DES 2 ~ l~c~ Alasla Oil & Gas Cons. Commission anchorage • • 21. UNOCAL apparently has not submitted to AOGCC a filled out EPA Form 4 (EPA Form 7520-6) which is required for all UIC applica- tions at the beginning of the administrative process. This over- sight has led to several other apparent deficiencies in UNOCAL's application including: a. UNOCAL has not submitted a topographic map as required by Form 4; ~b. UNOCAL has not submitted sufficient geologic data on the confining zones as required by Form 4; c. UNOCAL has not submitted sufficient operating data to meet the requirements of Form 4, instruction H; d. UNOCAL has not submitted sufficient data on formation testing to meet the requirements of Form 4, instruction I; e. UNOCAL has not submitted a plugging and abandonment plan; f. UNOCAL has not .submitted a contingency plan for well failures; g. UNOCAL has not outlined a stimulation plan; h. UNOCAL has not described injection procedures; and i. UNOCAL has not submitted evidence of a surety bond or a financial statement verifying the resources necessary for plugging and abandoning the well. 22. AOGCC is not processing UNOCAL's application in accordance with those procedures for UIC permits issued by states as set forth in 40 CFR 124, Subpart A. 23. The public notice published by AOGCC does not conform to the public notice requirement of 40 CFR, Part 124, which provides that any interested member of the public may comment on a proposed permit within the full 30 day notice period. A member of the public may.. also request a hearing at any time during the 30 day period. However, AOGCC limits the eligibility to protest and request a public hearing to those persons "who may be harmed if the requested RECEI,JEG _ 4 DEC 2 ~ lc;; ; J~lasica Oil & Gas Cons. Commission "~' -~ : Anchorage . ' .. ~ order is issued," and AOGCC's allows only 15 days to make this request. We thank you for your consideration of these comments. Very truly yours: TRUSTEES FOR ALASKA by Randall M. Weiner Executive Director ALASKA CENTER FOR THE ENVIRONMENT ~~ ~.t~~ .-- by Kristine A. Benson Hazardous Waste Specialist cc: W. Lamoreaux, ADEC, Anchorage W. Ashton, ADEC, Juneau J. Eason, ADNR, Anchorage G. Graham, UNOCAL, Anchorage S. Planchon, CIRI, Anchorage W. Rodgers, OXY USA INC., Bakersfield, CA C. Oxford, Mat-Su Borough, Palmer P. Bielawski, OMB/DGC, Anchorage D. Thiel, EPA, Seattle, WA ` _ R~CEIV~G 5 DEC 2 ~ 1~~'J Alaska Oil & Gas Ccns. Commissicn '+. Anchorage ~3 • • Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: The application of UNOCAL for an order authorizing the underground disposal by injection of non-hazardous oil field waste fluids at the Lewis River Field. The Alaska Oil and Gas Conservation Commission has been requested by letter from UNOCAL dated December 7, 1988 to issue an order in conformance with 20 AAC 25.252. The order would authorize the disposal of non-hazardous liquid waste by injection into Lewis River Well No. D-1. This well would be converted to an injector, and used for disposal of non-hazardous oil field waste fluids by injection into the" upper half of the Beluga Formation at the Lewis River Field, Mat-Su Borough, Alaska. A person who may be harmed if the requested order is issued may file a written protest prior to December 29, 1988 with the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska 99501, and. request a hearing on the 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 be held at the above address at 11:00 a.m, on January 13, 1989 in conformance with 20 AAC 25.540. If a hearing is to be held, interested parties may confirm this by calling the Commission's office, (907) 279-1433, after December 29, 1988. If no proper protest is filed, the Commission will consider the issuance of the order without a hearing. ~ ~~ ~-- Lonnie C. Smith Commissioner Alaska Oil & Gas Conservation Commission Published December. 14,.1988 -.LLj% 7WAd u- t { ~ ~ Navin Sharma August 29, 1989 STEP RATE TEST #1 LEWIS RIVER UNIT D-1 A step rate test was conducted on the following perforations in Lewis River Unit D-1: 3,714' - 3,768' 3,873' - 3,893' 3,907' - 3,918' Fluid used was filtered 2% KCL with Nacl, weighted up to 70.5 pcf (0.49 psi/ft). Initial pumping rate was 0.25 BPM and final pumping rate was 3.5 _BPM. Formation fracture occurred at 2,825 psi at 3 BPM. .After the step rate test the well was shut-in and the tubing pressure stabilized at 2,250 psi. Data gathered from the test is tabulated below. Graphical representation of this data is attached. INJECTION RATE SURFACE INJ COMM VOLUME BPM PSI BBLS 0.25 1,975 2 (Unstable) 0.50 2,000 5-1/2 0.50 2,300 7-1/2 0.50 2,325 9 0.50 2,350 10-1/2 0.50 2,350 11-1/2 0.50 2,350 12-1/2 0.75 2,400 13 0.75 2,400 13-1/2 0.75 2,425 14 0.75 2,425 14-1/2 0.75 2,425 15 0.75 2,425 16 1.0 2,475 16-1/2 1.0 2,475 17-1/2 1.0 2,475 18-1/2 1.25 2,500 19 1.25 2,500 19-1/2 1.25 2,500 22 1.25 2,500 23 1.5 2,550 24 1.5 2,550 25 1.5 2,550 28 1.5 2,550 29 1.5 2,550 31 1.75 2,675 33 1.75 2,675 40 i • STEP RATE TEST #1 LEWIS RIVER IINIT D-1 Continued INJECTION RATE BPM 1.75 1.75 2.0 2.0 2.0 2.0 2.0 2.25 2.5 2.5 2.5 2.5 3.0 3.0 3.25 3.5 3.5 SURFACE INJ PSI 2,675 2,675 2,720 2,725 2,725 2,725 2,725 2,750 2,800 2,800 2,800 2,800 2,825 2,825 2,825 2,825 2,825 COMM VOLUME BBLS 42 44 52 55 56 58 60 62 63 68 70 78 82 (Frac Pressure) 94 96 98 112 END OF TEST NKS:trf 0372r-53/54 .. __ LEWIS RIVER WELL D-1 STEP RATE TEST #1 377 4' - 39 78' MD/VD SURFACE PSI 3000 2900 2800 ~ 2700 2600 2500 2400 2300 ~ 2200 ~ ~ 1 2100 ! , 2000 ~:. 1900 ~'' i 1800 i 1700( 1600 ~~ 1500 500 450 • FIL4CTURE PRESSURE O 2825 PSiG FRACTURE GR4D/ENT• 1.234 PSl/fT 400 350 ~ M 300 B L 250 S N 200 E c T 150 p 100 50 0 0.5 1 1.5 2 2.5 INJECTION RATE. BPM .0 3 3.5 4 ~ PSI ~- CUM INJ., BBLS t~KS s/a9 STEP RATE TEST #2 LEWIS RIVER IINIT D-1 Navin Sharma August 29, 1989 A second step rate test was performed on the following sands- using the same fluid as in Test #1. 2, 562' - 2, 596'- 2, 850' - 2, 900' 2, 950' - 2, 960' 3, 020' - 3, 046' Fracture pressure was unattainable due to limits of pumping equipment at hand. Final injection pressure achieved was 2,500 psig at 8 BPM. Data below represents this step rate test. Information is also plotted and the graph attached for review. INJECTION RATE SURFACE INJ COMM VOLUME BPM PSI BBLS 0.25 950 1 0.25 1,200 2 0.25 1,200 3 0.25 1,200 4 0.5 1,250 5 0.5 1,250 6 0. 5 1, 250 7. 0.75 1,250 8 0.75 1,250 9 0.75 1,250 10 1.00 1,300 11 1.00 1,300 12 1.00 1,300 13 1.125_ 1,350 14 1.125 1,350 15 1.25 1,350 16 1.25 1,350 17 1.25 1,350 18 1.5 1,400 19 1.5 1,400 20 1.5 1,400 21 1.5 1,350 22 l.5 1,350 23 2.0 1,400 25 2.0 1,400 27 2.0 1,400 29 2.25 1,450 31 2.25 1,450 33 2.25 1,450 35 STEP RATE TEST #2 LEWIS RIVER UNIT D-1 Continued INJECTION RATE SURFACE INJ COMM VOLUME BPM PSI BBLS 2.50 1,450 37 2.50 1,450 39 2.50 1,450 41 2.50 1,450 43 2.50 1,450 45 2.50 1,450 47 3.00 1,500 49 3.00 1,500 51 3.00 1,550 55 3.00 1,550 57 3.00 1,550 59 3.25 1,600 61 3.25 1,600 63 3.25 1,600 65 3.50 1,650 69 3.50 1,650 71 3.50 1,650 73 4.0 1,700 75 4.0 1,700 77 4.0 1,700 79 4.0 1,700 83 4.0 1,700 85 4.25 1,750 89 4.25 1,750 91 4.25 1,750 93 4.25 1,750 100 5.0 1,950 108 5.0 1,950 110 5.0 1,950 124 6.0 2,000 133 6.0 2,000 140 6.0 2,000 148 6.0 2,000 162 6.25 2,050 170 6.25 2,050 188 6.25 2,050 194 6.25 2,050 205 6.25 2,050 210 6.25 2,050 218 Shut-down to increase pump intake capacity. B.J. Suction maxed out due to intake line size. Resumed test within 10 minutes. • STEP RATE TEST #2 LEWIS RIVER IINIT D-1 Continued INJECTION RATE SURFACE INJ COMM VOLUME BPM PSI BBLS 1,250 Shut-Down 6.5 2,200 240 6.5 2,200 250 7.0 2,300 260 7.0 2,300 270 8.0 2,500 280 8.0 2,500 290 8.0 2,500 300 8.0 2,500 310 8.0 2,500 320 Shut-down. Test terminated. Maxed out on pump strokes (@ 8 BPM - BJ) Frac Pressure Unreachable NKS•trf 0372r-55/57 - - LEWIS RIVER WELL D-1 STEP RATE TEST #2 2562' - 3046' MD/VD SURFACE PSI 3000 250 200 150 1000 0 1 NKS 8/89 0 2 3 4 5 6 7 8 9 10 INJECTION RATE, SPM ~ PSI -e- CUM INJ., BBLS 00 00 00 c 00 M S 00 B s 00 N J E 00 T E D 00 00 TUBING DETAIL 30" DRNEN 33' 2335' ~ 68#L 4-1/2", 12.6~E, N-80 TBG. 1) X -Nipple ®28T 2) "VST" Pocker ®2302' 3) XA -Sliding Sleeve ~ 2512' 4) XA -Sliding Sleeve d9 3000' 5) "BWD" Packer a1 3503' 6) X -Nipple ®3554' 7) Wireline Re-entry guide m 3584' ~ 2395' - 2397` Sgz'd w/ 300 sx 2562' ~g~` ~~ 2850' ifi r ~, +~ 2950' ~v~ ,~,~° 2967' . ~. 3020' ~'~~ 3070' 2596' 2900' 2960' 2972' Sgz'd 3046' 3072' Sgz'd w/ 100 sx 3451' - 3464' Sgz'd w/ 450 sx 3 7iU` 3 Tb0 ~~o~ _ z683~ Sgz'd w/ 150 sx ~~~ ~~ ~'` ~ ~~ ~ o ~~~ t' .,.5 3873' - 3893' 3894' - 3897' Sgz'd 0 3907' - 3918' ~ ti ~ Top of cement ~ 3945 EZSV ~ 394T 3956' - 3970' Sgz'd w/ 100 sx EZSV ®4020' 4034' -- 4054' 4062' - 4068' Sgz'd w/ 200 sx 4077` - 4094' ' ' - 4126 4122 Junk EZSV ®4144' Top of cement ~ 4154' EZSV ~ 4220' 9-5/8" CAD 5135` r LEWIS RNER D-1 INJECTOR DRAWN: ~ GRB CURRENT COMPLETION SCALE: NONE UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) `DATE: 8-31-89 r- I J _ `iC Ov -__ Let+~is River D-1 Mechanical Integrity Test Water Injection Well API # 50-283-?0068 Date: 8-30-89 Time: 1500 hrs Procedure: Pumped into the 9-5/8" casing - 4-1; ?" tubing annulus with bo KC1 brine until a pressure of 1500 psi was reached. The pumps were then shut off and the pressure was observed resulting in the above chart. Note: Witness of this initial test was waived by Blair Wondzell of the AOGCC. Another test will be run with a witness from the AOGCC present in the near future. *' 1 Unocal Oi- & Gas Divis~ Unocal Corporatior; PO. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 ~~ G. A. Graham District Operations Manager Alaska District December 7, 1988 Mr. C.V. Chatterton, Chairman Alaska Oil and Gas Conservation Comm. 3001 Porcupine Give Anchorage, Ak. 99501 Dear Mr. Chatterton: INJECTION APPLICAT1OtJ LEWIS RIVER UNIT - itiELL D-1 MAT-SU BOROUGH, ALASKA Union Oil Company of California, DBA UNOCAL, as operator of the Lewis River Unit, requests that an injection order be issued to authorize conversion of Lewis River Well No. D-1 from a plugged and abandoned gas well to a Cass TT disposal well. This well will be used to inject non-hazardous .;ash-V fluids generated during normal drilling, workover and production operations. Currently, Unocal operated gas wells in the Lewis River area are not. being produced at their full potential due to the lack cf water disposal .facilities. Approval of Unocal's application will remove a major impediment to producing idle gas wells and increasing gas ^roducticn from active wells. The attached application will demons :rate to the Commission that the proposed disposal operation will not allow the movement of injected fluids ir;to sources o` freshwater. Should you have any questions regarding this application; you may contact Roy Roberts or Candace Lockwood at Unocal's Anchorage office. flank you for your consideration of Unocal's application. Very truly yours, - ~ C- ~~~'/lam '-'-=f /~ a'~~ -~ G.A. Graha„i District Operc~~ons Manager ~ ~ • LEWIS RIVER UNIT APPLICATION TO THE AO~CC FOR UNDERGROUND INJECTION UNION OIL COMPANY OF CALIFORNIA • J ~ ~ LEWIS RIVER UNIT INJECTION APPLICATION 20 AAC 25.252(c)(1) Exhibit No. 1 is a plat showing the Levris River Unit, wells within the unit and 1/4 mile radius around the proposed disposal well, D-1. Although the proposed injection well is outside of the Lewis River Unit boundaries, the D-1 lease is held by the Lewis River Unit. 20 AAC 25.252(c)(2 Union Oil Company of California, dba Unocal, CIRI and OXY USA, INC. are co-owner's in the Lewis River Unit. Unocal is operator of the Unit and the State of Alaska is the surface owner. Exhibit No. 2 lists the operators and surface owner within 1/4 mile radius of the proposed well. 20 AAC 25.252(c)(3) Exhibit No. 3 is an affidavit s-iowing that the operators and surface owner have been provided with a copy of this application. 20 AAC 25.252(c)(4) Exhibit No. 4 contains geological information for the Lewis River Unit. 20 AAC 25.252(c)(5) Logs for Well C-1 have previously been submitted to the AOGCC. Tne electric log has been included in this permit request and is discussed and referred to in Exhibit 4. (Geological Support Information). 20 AAC 25.252(c)(5) Exhibit No. 5 shows present casing detail and wellbore condition of Well D-1. A new schematic showing current and proposed condition will be sent to the Commission at a later date to replace Exhibit No. 5. Testing of casing integrity will be in accordance with 20 AAC 25.030(8). 20 AAC 25.252(c)(7) Unocal will be injecting non-hazardous fluids associated with drilling, production and workover projects. Such fluids may include, but are not limited to: 1) Produced Water 2) Drilling/Completion Fluids 3) Equipment Washwater Exhibit No. 6 is an analysis of a representative sam le of roduced water from P P Lewis River and Exhibit 6a is an analysis of produced water from Pretty Creep. Fluids will be transporter by vacuum truck from various locations to the injection facilities at Lewis River. Exhibit No. 7 snows the composition of the typical completion fluid proposed for .use during workover uperat~ions. • Lewis River Unit Injection Application Page 2 The maximum daily injection should not exceed 500 BWPD, based on operational limitations of the surface equipment proposed for installa}ion. The average daily injection rate is estimated at 75 BWPD, based on the anticipated water production rates of the producing wells. 20 ANC 25.252(c)(8) & (9) DST tests (Exhibit 4~9) show that the' formation pressure gradient of the proposed injection zones (2562'-3918'h1D) range from 0.52 - 0.54 ,~~si/ft. in comparison to the fracture gradient of 0.822 psi/f t, as determined from a cement squeeze at a depth of 3070' VD. The anticipated maximum surface injection pressure will be approximately 1500 psi. Prior to injection " operations a step rate test will be performed to confirm the fracture gradient and establish a maximum injection pressure. Based on a average daily injection rate of 75 BWPD, for fifteen years,. the extent of radial invasion is estimated at 275'. Exhibit No. 8 is a calculation showing extent of invasion. 20 AAC 25.252(c)(lU) Exhibit No. 4 contains information regarding formation fluids. 20 AAC 25.252(c)(11) Under separate cover, Unocal is submitting an application for aquifer exemption for aquifers contained below 2300' in the Lewis River D-1 well. 20 AAC 25.252(d) Disposal Well D-1 will be monitored during injection, in accordance with existing regulations of the Alaska Oii and Gas Conservation Commission. Disposal rates and tubing/casing pressures 4ri11 be recorded daily. Unocal, as operator, will submit reports as required under this section. A mechanical integrity test will be performed as required by 20 AAC 25.412 prior to injection. 20 AAC 25.252(e) Unocal requests a waiver of both requirements under this section. Limitations of the disposal equipment will not allow pressures to exceed 7090 of the minimum yield strength of the casing-tubing and changes of L;;O psi between readings occur on a frequent basis due to injection practices, thus making reporting impractical and a burden to both parties. 20 AAC 25.252(h) Tnere ar: no wells within the Lewis River D-1 Area of .Review. The newest well is approximately 3,000' away. m x W z 0 L~WrIS RNER'~UNIT INDEX MAP i° =zooo• 27 28 29 X1/4 MII.E RADNS % \ E ~ WIS R. I ( ~ I D-1 34 Tn eoz5~ 36 ~ ~ ~~~ ~ ~ ' z R. Ci f ~ iD S 7 ~ T15N-R9W o i~ T14N-R9W IN W J ~ ~ LEWI5 R. # 1 L TD 9480' ' 3 ~ 2 I 1 r- ! L_ ~JLEWIS R. 13-2 TD 11,625' LEW IS R. B-1 EXHIBIT 1 TD 10,319 LOCATION MAP .~ O ~ • ANCHORAGE 2 -- -- M GY m x W z O L ~ ~ ~x~~~~T r~o.~ 20 AAC 25.402(2) Listed below are the operators and surface owner within one-quarter mile radius o` the proposed disposal well: UNOCAL Mr. Jim Eason, Director Division of Oil and Gas State of Alaska P.0. Box 107034 Anchorage, Alaska 9°510-7034 CIRI 2525 C Street P.0. Box 93330 Anchorage, Ak. 9°509-3:30 Attn: Steve Planchon OXY USA, INC. P.0. Box 12011 Bakersfield, Ca. 93359 Attn: i~'ayne Rodges s m w z 0 W EXH[B~~' t~lO. 3 • STATE OF ALASKA ) )ss fiird Judicial District) ArFiDAVIT Candace W. Lockwood, being first ouiy sworn on oatn, deposes and says: That I am an employee of Union Oii Company of California (UNOCAL). Tnat on the ~ day of Decemoer, 1908, I caused to oe mailed a true and correct copy of this app_ication to the follovring operators and surface owners: Mr. Jim Eason, Director Division of Oil and Gas State of Alaska P.O. Box :107034 Anchorage, Alaska 99510-7034 OXY USA, INC. P.O. Box 12011 3akersfieid, Ca. 93389 Attn: V,'ayne Rodges CIRI 2525 C Street P.O. Box 9:330 Anchorage, Ak. 9y509-3330 Attn: Steve Planchon by placing said copy in the United States Nail with postage pTepa:id ana certified at Anchorage, Alaska. r; ~ i ' l ~; ~.~. ~. ~c~ l.anGa:;B Vi . LockWO ~~ SU°SCRI3ED AND SY~ORIJ to before me this ~ day of December, 1988 Notary~~Public in and for Alaska ; My Commission Expires: ,/ /~1%, rn x z 0 Geologic Support Information for Lewis River D-1 Injection Permit Application ' Prepared by y Roger B. Stickney (December 6, 1988). The following discussion presents geologic evidence to show that utilizing multiple sands in the Lewis River D-1 well for water disposal will NOT cause contamination of freshwater aquifers. The relative positions of wells in Lewis River Field are shown on the accompanying index map (Exhibit 1). D-1 is the northernmost well and is located approximately 3,000' northeast of the nearest other well (C-1). Lewis River D-1 is an excellent candidate to use for water disposal because testing has shown that it does not contain commercial gas .and there are several sands suitable for injection which are well-isolated from freshwater aquifers. 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 the shallowest logged interval at Lewis River Field, high resistivity values recorded on the electric logs indicate that these sands contain fresh water. Focusing attention on Lewis River D-1 (Exhibit 4.1 -- see pocket), the base of this zone (characterized by resistivities well over 100 ohm-m) occurs at a depth of 1,192' MD where it is underlain by a layer of interbedded siltstone and coal over 70' thick. Below 1,270' MD, resistivities in the porous sands generally do not exceed 25 ohm-m, a stark contrast to the interval mentioned above. 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. Using standard log analysis techniques, the equivalent salinity of formation water (in ppm NaCl) can be estimated in two ways. One is the Rwa method and the other is the SP method. Both techniques were utilized here and the results are detailed and explained under Methodology (Exhibit 4.3). These methods generally underestimate the actual salinity of formation fluid. Of the two, it is felt that the Rwa method yields the more reliable results because the SP method requires some assumptions that do not strictly apply to the Beluga Formation. Even with these imperfect assumptions,. the salinity values determined with both methods do corroborate each other in showing that the sands below 1,270' MD contain very salty water (cf. Tables 1 and 2). ~ ~ The results of the .Rwa method are presented in Table 1 and also on the log (Exhibit 4.1 -- see pocket). They show that. the equivalent salinities are generally between 4,600 and 11,000 ppm NaCl. Because the Rwa method often tends to underestimate salinity, the true values are probably higher yet. The key point is that this salinity range is several times greater than the 500 ppm limit for potability under 18 ACC 70,020 which effectively rules out these sands as being reasonably expected to supply a public water system. As explained earlier (it is also evident from the accompanying log - Exhibit 4.1 -- in pocket), a freshwater aquifer over 1,000' thick lies immediately beneath the surface in the Lewis River Field area. Numerous lakes and ponds there show that the water table remains at or near the surface all year long. Although Lewis River Field is currently remote from even small population centers, fresh water in this aquifer could be easily tapped by shallow wells should the need ever arise. With continuous recharge from precipitation and snow-melt runoff, this supply of fresh water is virtually limitless. Thus, it would be economically impractical to attempt recovery of drinking water from the underlying saltwater sands. Their depth and the high cost of desalinization would render such an operation economically unfeasible. Water disposal into the deeper saltwater sands would have no affect on potable water quality available at Lewis River Field. Using the mudlog, together with available electric logs and core data, the confining layers were identified are depicted in Exhibit 4.1 (the D-1 log -- in pocket) by shading in and they , the depth track. The main sands targeted for injection in this well occur within the upper half of the Beluga Formation. They are isolated, not only from each other, but the shallowest injectable zone (at 2,562' MD) is isolated from the near-surface freshwater aquifer by over 1,000 cumulative vertical feet of impermeable strata. The specific zones recommended for injection, are indicated below: Planned Injection Zones (MD) Footage Comments 2,562 - 2,596' 34' Correl. sd 300' deeper in C- 2,850' - 2,900' S0' Correl. zone absent in C-1. 2,950' - 2,960' 10' Tested wet in D-1 & absent in C-l. 3,020' - 3,046' 26' Correl. zone very slty in C-l. 3,714' - 3,768' 54' Tested very subcommercial in C-1. 3,873' - 3,893' 20' Tested wet in D-1 & no gas in C-l. 3,907' - 3,918' 11' Tested wet in D-1 & no gas in C-l. Total: 205' A correlation section (Exhibit 4.2 -- in pocket) shows the stratigraphic relationship between Lewis River D-1 and C-1, the nearest well, located 3,000' to the southwest. The top of the Beluga is represented as a horizontal datum and the vertical scale is in hundreds of feet subsea (SS). Proposed injection zones in D-1 are plotted along the left side of the depth track. Test data for both wells is also shown. 2. • • .The generalized dipmeter data, which appears on the cross section, attests to significant structural complexity between the two wells. The opposing dips are consistent with the presence of a structural axis between them. Indications are also strong that each well is cut by a different fault. Although the quality available seismic data is not good, our- latest interpretation shows that Lewis River C-1 and D-1 are situated in separate fault blocks. With these observations in mind, there are two key points: First, the geologic structure between these wells appears to be much more complicated than the simplistic stratigraphic correlation section (Exhibit 4.2 -- in pocket) portrays. Secondly, the zones targeted for injection in D-1 are not in fluid communication with sands in C-1 that are capable of commercial gas production. There is good evidence to show that the various fine-grained facies within the Beluga Formation are impermeable, even when they are of limited thickness. DSTs were conducted on several sands between 2,868 and 4,980' NSD. Although none were found to contain commercial gas, sands that did test some gas are as little as 40 feet deeper than others that tested no gas. These results demonstrate that in this area, the sand-deficient, mixed lithologies between the tested zones do act as effective confining layers. STRATIGRAPHY Glacial: The glacial veneer is characterized by a very poorly sorted mixture of • pebbles, cobbles, sand and interstitial clay. Plant debris in various stages of coalification is also prevalent. At shallow depths, these diverse lithologies tend to be extremely unconsolidated and clay layers are generally discontinuous over large areas. This allows fresh surface runoff to percolate downward unobstructed. As a result, the. electric log signatures normally ascribed to the glacial cover include very high resistivity and a featureless spontaneous potential curve. Very slow acoustic travel time is also typical of such noncompacted sediments. In Lewis River D-1, .the thickness of glacial veneer is uncertain. The Sterling Formation that often underlies the Glacial is so similar as to be indistinguishable from it. Sterling Fm' The lithologic description of the Glacial can also apply to parts of the Sterling Formation. These two units may even be transitional in .places, although a fluvial origin for the Sterling Formation is well-documented (Hayes, 1976). The resulting deposits generally include fining-upward sequences of bedload conglomerates overlain by thick and blocky quartz-rich sands which are often capped by point-bar siltstones and mudstones. Coals are common and represent the vegetative cover of abandoned meanders. Lateral continuity of these lithologies can be quite good in places. These fluvial sediments have been subjected to effective winnowing and abrasion processes that are together responsible for excellent porosity development. 3. In the.. Sterling ~mation, the resistivity cure often shows a blocky character due to the contrast between the generally resistive sandstone beds .and the more conductive, finer-grained interbeds. These lithologies are similarly reflected on the. spontaneous potential and acoustic curves which often makes bed boundaries very distinctive. Unfortunately, in the Lewis River D-1 well, this is not the case. Here, noncompaction limits log resolution such that the contact between the Glacial and the Sterling Formation, if logged, is masked. Under these conditions, fresh connate water can easily. saturate the extremely porous, shallow strata (above 1,192' MD) creating the high resistivity response and a lack of usable character on the spontaneous potential curve. Although proprietary seismic indicates that the Sterling Formation is represented in the Lewis River D-1 well, a clear-cut contact .with the overlying Glacial is not recognizable from available logs. Quite possibly it was penetrated above the logged interval. Whether or not this is true, their cumulative thickness is approximately 1,910' and both units undoubtedly contain freshwater sands to a depth of 1,192' MD. A preoccupation with relative thicknesses of Glacial and Sterling Formation is of little importance. The overriding concern is that the shallow, freshwater zone(s), however subdivided, will remain uncontaminated by the proposed injection program and the above evidence clearly shows this to be true. Beluga Fm• Within the Beluga Formation, sands are thinner and more lenticular than in the overlying units. They tend to be encased in low-permeability siltstones and mudstones as well as being associated with coals of varying thickness. These are the typical interchannel deposits of braided streams from which the Beluga Formation is interpreted to have originated (Hayes, 1976). Thin, low-porosity stringers occur throughout the section which are probably artifacts of diagenetic cementation. At the higher energy levels which are characteristic of braided streams, finer particles do .not have the opportunity to settle out of suspension. Consequently, the resulting sediments tend to be poorly sorted. The "dirty" nature of the Beluga Formation, coupled with the occurrence of hard streaks and coals makes the proposed zones an especially favorable target for injection because permeability should be very low in the finer-grained facies. In Lewis River Field, there is also a coarser conglomeratic facies within the Beluga Formation. These beds have lower porosity than the finer-grained interbeds. The degree to which they are cemented controls their effectiveness as .permeability barriers. Compared to the overlying Sterling Formation, log responses are usually quite dissimilar. The alternation between thin sandstones, mudstone, hard streaks and coal creates an irregular resistivity response. With the predominance of finer-grained facies, the spontaneous potential is also "ragged" and is frequently of little help in delineating bed boundaries. A "ratty" acoustic log response is usually very characteristic of the Beluga Formation. This effect is blurred in the Lewis River D-1 well, presumably by a combination of noncompaction and possibly transitional lithology at the contact with the Sterling Formation. 4. The entire Beluga Formation is approximately 4,086~hick. All of the sands that will be utilized for injection (except as a last resort) are within its upper half. Below 3,950' MD, within the lower half of the Beluga Formation, multiple sands were tested and some even produced subcommercial gas. However, test rates and especially pressures are well below what could ever be considered commercial even under the most optimistic market conditions. Log analysis indicates that other sands below those that were tested also have very minor gas saturation. Since it would be possible to safely utilize any of these sands for water disposal without jeopardizing potential gas recovery, it may be prudent to do so in some cases. This would help ensure the availability of sufficient cumulative injection interval in the event that some of the proposed target sands fail to take fluid as well as we hope. At the low rates and pressures we intend to use for water disposal, even under the most pessimistic conditions, the radius of injection around the D-1 wellbore will be very shallow, even after 15 years, as substantiated by the engineering calculations in Exhibit 8. Tyonek Fm: Although the Tyonek Formation was penetrated by the Lewis River D-I well, it is considerably deeper than any of the proposed injection targets. Thus, its description is not relevant to this application. References• Hayes, J. B., et al., 1976 Contrasts Between Braided and Meandering Stream Deposits, Beluga and Sterling Formations (Tertiary), Cook Inlet, Alaska: in Alaska Geological Society Symposium Proceedings, p. Jl-J27. Hilchie, D. W., 1978, Applied Openhole Log Interpretation: Douglas W. Hilchie, Inc., Golden, CO. Merkel, R. H.,~Well Log Formation Evaluation: AAPG Continuing Education Course Note Series ~~14, 82 p. Regulations, Jan 83, Alaska Administrative Code, Register 84, Title 18, Chapter 70, p. 16.5. Regulations, Apr 86, Alaska Administrative Code, Register 97, Title 20, Chapter 25, p. 31. Schlumberger, 1978, Log Interpretation Charts: Schlumberger Ltd., 83 p. 1988, Log Interpretation Principles/Applications, 2nd Edition, Sch umberger Educational Services, 198 p. 1988, Log Interpretation Charts: Schlumberger Educational Services, 150 p. 1989, Log Interpretation Charts: Schlumberger Educational Services, 150 p. RBS/pg 2664D 5. a EXHIBIT 4.1 Electric Log for Lewis River D-1 Well (in pocket) • r: EXHIBIT 4.2 Correlation Section (in pocket) • EXHIBIT 4.3 Methodology for Calculating Salinity from Log Data Rwa Method• This technique is based on the following-relationships: Rwa = Rt/F, where F = 0.62/2.15 (Humble formula) Rwa Apparent formation fluid resistivity Rt True formation fluid resistivity F Formation resistivity factor Porosity For a given sand, if porosity, formation temperature (Tfm) and apparent fluid resistivity are known, it is possible to estimate equivalent salinity (in ppm NaCl). It is assumed that NaCl is the dominant salt where specific knowledge of the actual fluid chemistry is unavailable. Resistivity, read from the deep induction curve (Rill), is assumed to be the best approximation of true resistivity of the formation beyond the zone that was invaded by drilling fluids at the time of logging. The formation resistivity factor eliminates the effect of the rock itself from the resistivity measurement so that the resulting value (Rwa) represents only the contained fluid. Rwa values, when corrected to formation temperature, can be used to estimate salinity with a standard nomograph (Exhibit 4.4; Schlumberger, 1978). A straight line through any value for Rwa ton the right stem). and the corresponding formation temperature (on the left stem) will intersect the equivalent salinity (on the middle stem). Since determination of salinity this way involves an exponential of porosity (see Humble formula above), a small error in porosity is reflected as a much larger error in the calculated salinity. Tn Lewis River D-1, an acoustic log provides the only available formation porosity data above 2,395' MD. In shallow sediments that have never been deeply buried, there is only minimal compaction due to normal overburden stress. Under such conditions, acoustic logs grossly overestimate porosity. Adjustment of these abnormally high porosity values for n~compaction is done empirically and is, at best, rather subjective. Hence, the results must be utilized with utmost caution. Lacking confidence in the porosity data for the zones shallower than 2,395' MD in the D-1 well, it was felt that calculated salinities would not be valid and are not shown here. • EXHIBIT 4.3 (continued) • Below 2,395' MD, a neutron-density log was run which provides more reliable porosity data since noncompaction effects are much less dramatic with this tool compared to the acoustic device. Therefore, density porosity (lip) was used in the Humble equation. Because salinity is also a .function of temperature, Rwa must be first be corrected to formation temperature (Tfm) in order to obtain the corresponding salinity. Formation temperatures were determined as shown below and they are represented on the log (Exhibit 4.1) at the appropriate depths. Estimated Mean Surface Temp (MST): 35° F (for Cook Inlet area) Maximum Recorded Temp (Tmax) from FDC: 135° F C~ 8,025' TMD (-7889), i.e., 7,989' BGL where BGL = Below Ground Level Thermal Gradient (TG): TG = (Tmax - MST)/(Depth BGL/100) _ (135° F - 35° F)/(7,989'/100) 1.252° F/100' It is felt that salinity estimation with this method is most valid, so this technique was used for selected sands below 2,500' MD. The results appear on the log (Exhibit 4.1 -- see pocket) and also in Table 1 along with the parameters from which they were calculated. Some sands in this well contain small amounts of gas, yet test results show that even the most prospective ones are subcommercial. The presence of even minor gas is emphasized because it causes Rwa to apoear abnormally high. This must not be ignored because it will result in salinity estimates that are artifically low. SP Methnd: This is a well-known approach which involves calculation of formation fluid resistivity (Rw) using the spontaneous potential (SP) curve from the electric log. In general terms, in a given sand having even a small amount of permeability, the character of the SP curve will reflect the degree of salinity contrast between the drilling mud and the fluid in the formation. n U EXHIBIT 4.3 (continued) Under ideal conditions, using the SP curve to determine Rw (and the corresponding salinity} can work quite well. Most often, however, it must be utilized very cautiously because several factors can suppress SP development. To get reliable results, a sand. within the zone of interest should meet the following criteria: 1) It needs to be sufficiently thick to allow the SP curve to respond to its fullest extent. This maximum excursion of the SP is called static SP or SSP. The minimum thickness required for this to occur is approximately 30 feet. 2) It should also be "clean", i.e., devoid of mudstone or shale because these lithologies interspersed with sand limit SP development. 3) The sand should be 100% water-wet since hydrocarbons can also suppress the SP curve to an unpredictable extent. According to the mudlog and the electric log suite, sands of the Beluga Formation in Lewis River D-1 (between 1,934' and 6,020' MD), contain significant amounts of mudstone. This most certainly limits SP response. Referring to the depths shown in Table 1, most, if not all of those sands fall short of the ideal criteria listed above. Therefore, others with better SP character were chosen for analysis. As was pointed out above, certain sands do have minor, stdcommercial gas saturation which also likely contributes to +~ an SP which is less than the ideal SSP. Several references describe how Rw can be calculated from the SP curve and there are often minor disparities between the various recommended techniques. Usually these differences can be ascribed to the way a particular log analyst chooses to correct for less than ideal conditions in the formation he is analyzing. The service company charts used in this analysis are included herewith as Exhibits 3 through 6. The Schlumberger charts were chosen because they allow the user to make some corrections that are frequently ignored by other general purpose charts. They also circumvent other inappropriate assumptions. Table 2 details the raw data and the values used from each chart. RESISTIVITY HOMOGRAPH FQR NaCI .7CILUTIONS •i R (ohm-m) -r-.01 a N °F °C 50 ~-- l0 60 20 70 80 30 90 100 40 50 60 150 Conversion. approximated by: TI+ 6.TT ° R2=RI~Tx+s.77~tArpa)' F Of T I + 21.5 ° R2= R~ ~ TY+21.5 ~' C kppm g/g 80 200 100 250 120 140 300 160 180 400 200 220 240 500 260 Exhibit 4.4 ~a 75°F 300 17500 200 13000 10000 100 80 5000 60 4000 3000 40 30 2000. 20 1000 10 8 S00 400 6 300 4 200 3 2 100 I 50 .8 40 '6 30 '4 20 .3 .2 © Schlumberger L O a .02 .03 .04 .05 ,O6 .OS t3.. 0.1 t1 .2 .3 ~ x tY .4 .5 c .6 ~ .8 1.0 .r _~ 2 ~ 3 Wo 4 5 6 8 3 10 ~ 20 x -- «; Gen-9 5 SPONTANEOUS POTENTIAL 1 ;~ ~'_ _y 1 5 • J y t~ q a M~ i SP Correction Charts tFOR REPRESENTATIVE CASES) ~. 4~~ ~ J: ~. ... :. :~ l ~.yu ~ ~ ~ ~ ~ ~ 6 .~ ~N r G1 fie. 1L ~ /d d sion .I L' ~t'~.V .J1. JF '~„. r ~ ~ -- No Invasion `.. ~ h ; , nva -- . ' . = .. 4 _ : _ - ~ ~ ~. _ ~ -:: R,~ . = Rt _. 0.2 Rc . `' R"° R~ ~ 5 Fic .; I . t;' • 1.0 . 0.8 "s... _ 0.8 ~m , o.a 0. t .2 .5 1 ~ ~ _ 2 5 ~ \ t0 _ -- _ ~_\ ~ 50~ ~ I R.dR~ 2 100 -- - s ~ 10 7s s > „; :: _ ,ry sv• ,r.= :h .~ ,~~ . ,~ .+ h/d„ _ a _ 1.0 . o.e ' 0.6 0.4 ,.1 - 0. _ s. _ .2 -~ - .s I +.: 1 -- 2 I _ _ IS ~ 10 120 '- t ~1 50 R.,/RT 2 ~ 200 i.~ 5 I ,: ~~2 o.e - _i 9 .t .0.6 - 20 +0.4 ~ ' I 100 - 0.2 _ I 200 R,dR~, _ soo 5 5 •>~ ~I~ 40 30 20 15 ~_W 75 5 40 30 20 /5. 10 7 . M ,} h' ~ . 3 - :: 4' t"t ~ } . , } r '\^ F' -.r SR -'- h/mil . ,..., I ' 3 ..~ .~ ,,t ~ - ~ . : _ ~: .. ' 2 . ~ F~~. Q l ~ l . F , } ~ o e 2 o.e 10 o.e - . . .;;~.: _ - 5 20 6 _ 0 6 c ` < 0.6 0. . oo - - `, i0 .c _ ~ ` ~~ ~ .O.i 100 - ,,, 0.4 . 20 0.4 ~ - _y 100 200 - ~ ~~~ r .0.2 ~ 02 .~ - 200 100 ~^ 200 500 R ~ 1000 R.dRm R.dRT 1000 . 4 0 30 2 0 15 ',: t 0 7.5~,, 6 40 3 0 20 15,,:10 7.5 , 5 ` 40 30 2 0 15 10 75 5 =`. , ,~ ... _ .. _ ; ... o .~ ~ Select row of charts for most appropriate value of Rs/Rm ~ ~ ~~-~ ~ 1 ~~t ;- ~., . . .. Selectchart for No Invasion or for Invasion of d,/dh =:: 5, whichever is appropriate ~- _.~. .. ~; 2 ~; - . -~ ..t Enter abscissa with~value of h/dh (ratio of bed thickness to hole diameter). , . '- `~` -° ~ ' -~ 3 - . . . _. .. 4. Go vertically up to curve for appropriate R1/Rm (for no invasion) or R,~/R~, (for invaded cases) :;_~ ,t Y, _ , interpolating ,..,, _ , , ~- -~" _., _ ' - '~ ~ ;' - . between curves if necessary .=:: --~ ~ Y , _ , ). (FsP ~s SP from log) ,~ .~5. Read F,sP/F.sp~. ui ordinate scale. Calculate F~P~ . ,ESP/(Esr~sr~ - _ ' ~ For moire detail on SP corrections see References 4 and 33 a ' . ~ - .~ - ~ ~ ~ ,~ +_ +- r~~ ~3 SP-3 ~- • - it Exhibit 4.5 .; .. ,_~. CYC)1TA~rOI'S F'OTE\1 R~;,eq Determination from ESSP (CLEAN FORMATIONS) This chart and nomograph calculate the equivalent formation Water resistivity, RN.~, from the static spontaneous _. potential, EssP, measurement in clean formations.. - _ Enter the namograph`with Essr iri mV turning through the reservoir temperature in °F or °C to define the Rmrey~Rwcq ratio. From this value, pass through the Rmr°y value to define R„~. ,. ~_ ...... :. as follows: _ ~ R For predominantt~ NaCI muds determine R,,,r~q - _ weq a. If Rmr at 75°F (24°C) is greater than 0,1 S2•m, correct Rmr to formation temperature S2•m using Chart Gen 9, and use Rmrro = 0.85 Rmr '001 . ,. b. If R .. mr at 7S F (24 C) is ,less than 0.1 SI m, use Chart SP-2 to derive a value _ _ ~ - of Rm~~q~a[ formation temperature. .,' , - .-: , : _ EXA'~1PLE SSP is 100 mV at 2S0°F. ~ " EssP=-K~log Rmkq '. ... :Rmr:= 0 7012•m Q 100°F or 0.3312•m Q 250°F. :. _ _ ~ :_ R,,,~ - ~ °~ _ >-:: ... - 0.85 x 0.33 - 0.28 f2•m Q 250°F. ~ _ Therefore, Rmrro - - _- Kc = 61 + 0.133 T•F T ~ - ~> R,.°~ = 0.025 S2•m (c~ 250° F. ` - , .. , . _ Kc = 65`+ 0.24 T•~ .. .. : .005. .3 .. . 2 CC E 3 4 O E co E 3 co F 1C 2( 30 40 50 .-~ - 7-. .._.. .-.- - .. _. ~.. -- .~ 7 .... ...»- -...._ , ..... _ ._.~ -' . ~. _ ... ~. ~ s ~ i ._~_~'.. iw 2 ' .' i - -.' / j - _ 3 - i -~ -~---- is-- _._::s 1~. - -.i i.:_ i t. ,. .. ~, i 1 , ! ~ .. ~ -~ I .- ' _~ _'.. _ .. - , ~___ - ._ . a ~ ._. ~--- _ ` _ ~ _ ~a ._ .. i- _;__ _ .~ _ .- . ~ __ . _ -_ . ._,._.._..~..~y.1 ` __ _ . . -;- - - • - -.._ _ ~ - _ • -- 1 -' -3 - , _ -- :\ 1 ~ _ ~ `~~ : __ = - ._.. . t l= \ -1 - ~ -._ _- ~- t. ~ . , . -~ _ ~ , _ _ ;._ .~. .l ~ ~ .. .: i~ ~ _ ~ . ~:. -_ .. _ _ , . ._ _' ~_ ;^<<~ ~ ~ \--~-\~~ `moo --- ° ~_ _- ~ `_ ~ __ r ~ - ~ ~.~~ _ s C~ ~---~errtperature-----= ~ . ~4. ,<.:: ~ :: `~° . _' 10 \ : .a . -~~ ~ ~o .- -4° - ., _ `. ~ - - - - ~ ~ \ - + 50 0 - 50 -100 150 EssP, Static Spontaneous Potential (mV) .. ... SP-1 .3 .4 .O6 2 .1 .2 4 -4 .6 6 1 8 2 ,10 4 6 '20 ,o 20 -;- 40 40 - 200 .. 60 100 °Schlumberger .05 1 0.2 0.5 1.0 Exhibit x ! ~r ~~ - -i ~ ~ itr ,tr i+~- ~~- ~L' I ic1 ~~I ~_I l:I I.:I iat 1=,~~- ~~, ~~! :_~ ~tJ i~:l 1~1 ICJ ICJ L~. Ly, 1:~: ~l ,,$ a E k~ 6y'~t~4 ~}~.~ R~'fi. N~Y'~'C'l ~a~ ii ~~ +1 TTT444"' ;~'~E~4~~~ Y~ f 1 ~;1~ M13 ~ 1r> ~..~Y'4` ~ ~ ,i e~,y'is i~ y~•:~3nit~~ i~~~''.~p~0 t rA ~ ~~ ~ -~ -i ~~ "4~ ~ ~(~p ~NDy ~L ~ } }{ C ~ r r ~~i''J' tip ~! ~.~_ 53 ~~~ ~~1p1 .y ~ I r 4~bl~ G A(?{ ~5~1~ 5~ .~~fO O R ~14 3 ~i~ta;~~ ,. • ;v N - - --. ~~ p'~~. t.r. re ~~,~ 'S. a;•~ re. p, w~.~; '~' y . /r i ~ [~ ~ '~ I i~ ~ v ~ ~ k~{{j}1'i~~~ .'~~ 'yQ,". y i x ~ ~' r _~ s• _il~~~ ~'t'S W ` ~•} ~ . ~ 'ti a'~ ~ 3 - ~ ~p -. ~~~~~t ~~ ~. ~ ,, ~~~~L#y~,r~ ~ i k~i i~ 4~!! ^ O ~, n 0~^y{ i~0,`J r{ --`' ~r N ;y ~ ~ ~~ ~ t~ ( C ;~: ~ ~ ~ N O ~~~f~~ ~, ~'ti n ; y~pa ~t = o ,: i .-. i I ~~ ,w. ~~ At r, r. °i, ~r ., ~!. d Z c6s~, a•~ xAj 0;~~! f ~ 't rpl ~ ~ O ~ y~-~N i= t ~',ti s ~' S ' fyr O g fw dNC - r it'~~ CSC _, r~ • ~~ J ~S ~ ~ j~'}~~ ` O' w ,~ ~ ., til t416 {pt'~ 'F.n'~ tY~- '~ ! dw .~~~y ~. ~i: .~y~ .+.s k. i r i - e~ ' ~r'~ i4 'yF;~¢:~$~~~+~ •V ~ is ~ru+'~~S ,1.~' 'r•.~'yE.~ ~r>i~ ..i~birye. '.'~i s~i i~ ~F~ ~'~f~y a ^~je`r:-°ir'tf;pi i ,•~ ~'"~ J tv 'j>~~Uf ~.~t,r,r. `'r'1 ~'' ~ _ i~j~ ~ !'~ ,~^N ~~tf-;c2(.~1~~~, f7T '`~%~~ ~~~~i• ~ .`r~i+vJ.. a ~;{,.~ r t ~s.~ ~ , ~ LAS l,vfi. ..~ ~~ Rweq mfeq ,~~ ~ ~. r~'' y _ x ~ ,~ ~. ~ 4: t`«'~.'~~~M~ ,~~ v ~`~~` ~d~rs~~p.{',f}-a_~~`ryyi~.td'~~~~~ ~ ~"i ~ ~ ~;Y~ ~ `''i •t+'~1.-rs1F44~r 4 q _~i ~' ~~. ~.p 7?! { .~';i ~ SP 'y ~S^.x .C. a. , .Zi .e~,~,~~'.Rla`.-t .'~x~ ~.~~'~fil~ •,3i l_~ .fN . s,r, ti ~ tn~ ~rw.~:: ~f a F--~~: tti~. `, yi t , ~.,.r(;.. ,;~t'~-~°;~,. ta~:~1.i-.i ~..i7{, i£~+;fi-' b ;"S~ 1 _f. .i ~"~r.~~Yt b~ ~,~ d pt.. o ~ 7 ~ t ~J ~ ~ '!'Y~ ~" ~ ~4~ i.-~a~~ :°,a ,.,. . s'iiY~- r E~.~ fs a .~~~k~^~~ 4'.:Gia~ ~~'°. a .~rss;?,~- 'r ~~~;ti y; r ~.r# ~k; * ~1;~ _ ;; s, i.~. ~. ;.y :+'ar, ,~~t~ 31 O ,tCrit!•7°,',¢,~~;p0 ~., .,,~f~.,yOt }~~y" p 't~-6 t~'0 a~i :7•i.~ t. g. ,~'-~t~ gaa<~.r Q n~~r~~} '"~i r. `C'ogs p-' '~ 5,~ ,".71~ ..1~',t ty'R..:.. #~'-~.~V ~.. ~ t7! ~. '~. Y;~ r., V '~RC.`~~.~., --r-~- r • ...- • ~ . II -/ . I ~ `5 r ~~~nir ~~ { i i ~ ~~ ~ i ~ ~ ~ ~ O t t}~ ~ ~ ~ ~ ~ ~ ( 1 ~ _ 1 1 ~ I OA p l v ~ ._~ #i 8 ; ~ ~ ~ ~ ~ O ~ F ,a~~~ j N i I ~ ' f ~ f I f t f -, _ :S. J / O _ t ~ . i o .~$ ._ : ~ - _. _ I I t~. • ~ ,~ _ r a T ~'. _ ~ f i ` ~. ~~~aa > .~~•c - f p .,~~~ ~;~ I -a . /; / .~ r ,;Y • I/ / ~ ' ! ~.. 2 h~ ~4 t. Oi O O atW ~~~0 /O ~O O /O ` O ~ / ~ ~ ~~ ~~' ~o ~~ t ~ ~~ ~..//_ ~ / . ~ __ _4.,'...i../ ~= I# ~-tip } / ' ~ry ~vyt ~~ • _t~~y {[ +~t,Y 6'.~' C4_~~iR . .mafyu y~ ' .~..~y. l f ~.~ y~~ j 1(r~ E. .T~,,S s . y~M~'k7 ~~"~~° 7~^*•~i!: ~ R?" t~`w T~~~; r?r~ - t •(.v' 1 ..r A"N ". ~Mlt*ji - ~'I lTrn+'e~-F+~'.;I ~~~ V v '~.I' ~ia R~. E4,. ~'iB ;~r rs~~F ~t."°11J c# s.~. _.,.a. i~ ~"+~':(K_.~. }. Jt... ~'~~.~., j~~H ;. :- ~ G. k`-~ Y_ !,'t~ t , . 1s.;AV ~, ve'. s.~. ,~,f ..fi i LY° ~:~ 1 ~ ~ a`~' 4 a , l ~:~~'r. ;, r ~~ \V .B - ~+ O O N O Z D z rn O r ti m -1 D fr) t ~ s a°~ s • Table 1 r~ -.J Depth Dens. Equivalent MD SS BGL Tfm Poros. Rt .Rwa Salinity (ft) (ft) (ft) (Deg F) (~) (ohm-m) (ohm-m) (ppm NaCl) 2576 2451 2551 66.9 25 12 0.98 6,500 2590 2465 2565 67.1 24 13 0.98 6,500 2853 2728 2828 70.4 20 16 0.81 7,500 2878 2753 2853 70.7 18 14 0.57 11,000 2892 2767 2867 70.9 19 17 0.77 8,000 2955 2830 2930 71.7 22 20 1.24 4,600 3024 2899 2999 72.5 16 25 0.78 7,500 3038 2913 3013 72.7 14 25 0.59 10,050 3482. 3356 3456 78.3 17 20 0.71 7,800 3717 3591 3691 81.2 15 21 0.57 9,43 3740 3614 3714 81.4 17 18 0,64 8,500 3758 3632 3732 81.7 19 17 0.77 7,000 3885 3759 3859 83.3 15 25 0.68 7,600 3912 : 3786 3886 83.6 16 28 0..88 5,800 MD Measured Depth SS Subsea Depth BGL Below Ground Level Tfm Formation Temperature Rt True Resistivity Rwa Apparent Formation Fluid Salinity RBS/pg 2663D TABLE 2 Parameters from R~ 3 Equiv Meas Rm Rmf Hole Rmfeq Rweq Rweq Rw NaCl Depth Tfm ® Tfm ~ Tfm h SP Diam SP/ SSP Rmfeq/ ®Tfm ~ Tfm ~ 75°F ® 75°F @ 75°F (ft) °F °C (ohm-m) (ohm-m) (ft) (mv) Rs/Rm (in) h/dh Rxo/Rm SPcorr (mv) Rwfeq (ohm-m) (ohm-m) (ohm-m) (ohm-m) (ppm) 2590 67 19 2.10 l.ll 24 -10 4.76 14 1.71 4,76 0.58 -17 1.65 0.94 0.55 0.50 0.50 11,800 2895 71 22 1.99 1.06 30 -10 6.03 16+ 1.88 6.03 0.56 -18 1.75 0.90 0.51 0.49 0.49 12,000 3100 74 23 1.91 1.02 35 -12 21.47 13 2.69 21.47 0.43 -28 2.41 0.87 0.35 0.35 0.35 17,000 3365 77 25 1.85 0.98 38 -10 26.49 12.5 3.04 26.49 0.45 -22 2.00 0..83 0.41 0,42 0.42 14,000 4455 91 33 1.58 0.84 32 -10 9.49 13 2.46 9.49 0.41 -24 2.20 0.71 0.31 0,37 0.37 16,000 Tfm Formation temperature (see log) Rm Mud resistivity (see log header) Rmf Mud filtrate resistivity (see log header) h Bed thickness SP Spontaneous potential Rs Shallow formation resistivity Dh Hole diameter Rxo Resistivity of flushed zone (lacking a microlog it is assumed that Rs = Rxo) SPcorr SP correction (see Exhibit 4.5) SSP Static SP (see Exhibit 4.5) Rmfeq Equivalent mud filtrate resistivity where NaCl is the dominant salt (Rmfeq = 0.85 Rmf since Rmf ~ 75° F 0.1 ohm-m; Schlumberger, 1987) Rweq Equivalent formation water resistivity where NaCl is the dominant salt (see Exhibit 4.6) Rw Resistivity of virgin formation fluid (see Exhibit 4.7) u RBS/pg 2668D EXHIBIT ~t9 LEh'IS RIVER D-1 DP~N HOLE TEST DATA • . ~_ f 1 Sell t;~me: :.e~is Fiver D-1 Date o: Test: `-?/12/E1 Fer~s @: 5970'-49BC' Type o~ guns used: 2-1/16" thru tag. Tool set @: 490C' T~~oe of tocl used: r,T':S: Nycro Sprint Tool run on; Drill pipe t~;~ter cushion: r of feet: 4'_~0' t•~oe fiuic: ='resh mater _i:~e :.col was cpe.^.ec- Gas to sur_°acec lvo lL'+u t0 SL`I'dZCe: Igo. <~ DST ~ la SPF: 8 SurraCE _re~sure; o psi ~ lLre: 1\0 Chlcrides: 1:/~ ChlOrideS C. CO'~p• =1L'1C: j':/n __-e tool ras c_cs.c. -..-_-al _ ~~~~a~-~. _ __ss•~.e. . -.l~l C-yCG~ -• _ -e~SL..re. • ~~ Paoe 2 ,. Well Name: Lewis River D-1 Date of Test: 9/13/81 Perfs @: 4970'-9980' T}~pe of Guns used: 2-1/16" thru tbg. Tool set @: 4894' Type of tool used: RTTS: Y.ydro Spring Tool run on: Drill pipe Wader cushion: € o: feet: 700' tvice fluid: Fresh water Time tool was opened:i1:29 a.m. Gas to surface: No Fluid to surface: No l~ DS:# lb~ SPF: 8 Surface pressure: 0 psi Flare: No Chlorides : N/F. Chlorides of comp. fluid: N/A mime tool was clcsed: 1:30 p.m. Initial nVGrCStat~o oressure: 2696.2 Initial ric:.:ing _ -'°-ssurec 323. 3 irai f~o~»inc _ressure: 431.1 Final clcsec in pressure: -'- Second initial fio~ing press-.:re: --' ^i ~~~ ros~at_c pressure: 266.2 _ :,al '.. J....1 ~.. i....-::. .... • • rr^aae 3 ~~ i c~ DST' ~`..2=` t~'ell 1:ame: :.ewis River D-1 Date o: Test: °/14/81 • SPF: 8 Perfs @: 4675'-470.4' Type of guns used: 2-1/16" thru tbg. Tool set @: 4579' Type of tool used: RTTS: Hydro Spring Tool run on: Drill pipe t;ater cushion: n of feet: 1000' tyae fluid: fresh water Time Surface pressure: 0 psi tool was opened: 5:00 p.m. Flare: 6' (12' rya.}:) 5:15 am flare lit Gas to surface: yes Chlorites: N/A Fluid to surface- very little Chlorites of comp. fluid: N/i. _ime tool was closet: 3:45 a.m. Initial hvtrostatic pressure: 2502..2 r :lowing p~essure: 456.6 itial I ^ . . _ _.-.al _'_owing- pressure: 500.0 Fuel close in aressure: 761.4 Seconr -n~~_al Fio•»ing pressure: 478.3 . 1 ::^.ycrestatic '°ssure: 2373.4 --na _- ~...-a Qr,.s: H:-__~ L_ 1.20 a.-~. 0 psi 1:30 a..... 17 p_=i _ :45 a.... , 42 psi -:00 ~..... 67 psi :15 a..... c4 ~s~ -: JO a.l... +2O ~ 51 2.45 a..,.. _55 ps= 2.00 a.-.. i60 psi • _.15 a..... 2C•. psi c. L..+v S. ~:30 .... ""'~ p ~:45 a..,.. 260 ps= •- L~ • •~ Page 4 \ _ .. . Well Name: Lewis River D-1 Date of Test: °/15/B1 Perfs @: 4444'-4476' T~~pe of guns used: 4" csg. Tool set @: 3666' Type of tool used: RTTS: Yydro spring Tool run on: Drill pipe Slater cushion: No. of feet: tyae fluid: Time tool was oaened: 5:30 a.m. Gas to surface: No Fluid to surface: No _C~ DST~`'`~ 3" SPF: 4 Surface pressure: 0 psi Flare: Lone Chlorides: 1:/A Chlorides o_` coma. fluid: N/A Time tool was closed: t ~-ycrestatic ore sure: 2036.4 _ni ial ., - 64.7 Initia'_ fio•»inc ress•,.re: F;nal ~1Cwin^ D"O_SSUre: ~~•2 Final clcsea in pressure: 1°-4.2 Second in ~ '_lcw_^g _ressure: itia~ `o `_ossure: 2027.8 _ _nzl ''^.~~dres ~a ~ _ - Co;-~e:as Su_ld uo yes ~. S- ~ 8.30 a.m. 0 ^=i ~0 a.m. 3 : si • ~~ pace 5 i ,: DST 4 Well 1:ame: Lewis River D-1 ' Date of Test: 9/i6/81 Perfs @: 432. 4347 4..90 4300 43L 4327 • Type of guns used: 4" csg. Total set @: 4229' Type of tool used: RTTS: Hycro sp=ing Tool run on: Drill pipe Water cus;:ion: No of feet: t~'ae fluid: . Sur`ace pressure: 0 psi Time tool wcs opened: 5:10 a.m. Fare- None Gas to surface: Very smell Chlorides: I`/A Fluid to surface: None G1 Chlorides of comp. ~ uid: A ~ .ire tool was c lcsed: it~al hyarostati ~essure: 2160.3 ~r itial fic~ing `'"=ss:.=e: 64.7 In r~:nc -esS'~-e~ 60.3 r :,nal ~ o•~ _ _ _~nal closet X11`_ -ess,:re: 215.6 SeCGn in:...~al _1GM'_:~Cj :-°_55L~°_: --- al h; c_GSta~ic -essure: '%160.3 in - Co^~~:~s: E'~~lc uc test . E:15 a..... 0 psi 4:15 a..... 2 psi • / 1 . . __ - ~ Page b - "-- ` .~ ...° . _. _ ...... .. .~ hell ?:ame: Lekis Fiver D-1 Date of Test: 9/17/61 _ _ . -__ s per_°s C~:3°Oy'-3916'; 3892'-3897' T}•pe of guns used: ~" csg. Tool set C~: 3E20' Type c= tool used: FTTS: Hydro spring Tool run on: Drill pipe t;ater cushion: 240 r cf .eet: t,~e fluid: Time tool was opened: 2:35 a•~'- G~s to surface: 130 `ace : 240 -laid to sur i• DST~r ,._` S SPF: 4 Sur_ace pressure: 0 psi Flare: 230 Chlorides: ~'/~ Chlorides of ccmp• fluic: 1~/~ _i:^e tool »as closed. ~r.itial ~ycrestatie p~essu'-"°-: 20°1.9 }_ng «..,- 43.2 Initial :lc» : =e_-~_e: .final ~~o•~_ng ~ress•~re: 4~•2 ^inal closet in =~essure: 64.7 eccna n~~~a ~ v.- 2G79 i . -~G1 ra~•Qr~.~..^..a~y~. _ re.^-.SUrec ~~i~--fir l.r-'.: -.~o a.It.. 0 ~=-_ i• _ Nell 1~ame: Lewis River D-1 DST 6a Date of .Test: 9/19/81 • 4122'-4126'; 4077'-4094'; 4062'-9068' Perfs @: ~_ ,, o ,_ , SPF: 8 4034 4054 ~ 56 3970 Type of guns usea: 4.. cs~. Tool set @: 3855, Type of tool used: FTTS: Hydro spring Tool run on: Drill pipe c•,~ter cushion: n of reet: 500' ' type fluid: fresh water 0 wsi Time tool was oaened: 8:30 a.n. Surface pressure: _ Gas `o surface: yes Flare: ti'erY small(2') 10:15 a.m. :laid to surface: no Chlorides: ~'/A Chlorides o= coup . fluid: 1Q/Ty __;,.e tocl kas clcsea. 10:4:, a.:n. •-~ ~ ressure. 2013 0 _ni a al hycrestat__ _.._ ~_al f_cwing _ ressure. 304 •4 *- =~ o•.._ng _ ress~~re: 326•'- Finallclesed _n pressure: 736.1 Second ini~ial flowing pressure: --- _ _:,al ^ycreste sic pressure: 2073.0 Cc...,._.. ~s . • DST~r bb Well T one: Lewis River D-1 Date of Test: y/20/81 Perfs @: Same as 6a . ;~~pe o= guns used: 1QO1 J Jet e• _3 ~~ .ype of tool usec: RT'='S: Hycro spring Tool run cn: Drill pipe S~;ater cushicn: 2:0 € of feet: . t~•pe fluid: Time tool uas opened: 8:00 p .... Gas to surrace: 1'e5 ~ see attached _lui d to sur_ace: yes • Time tcol uas ,.icsed: 10: C5 SPF: 8 0 psi Surface pressure: Flare: see a;.tachments Chlorides• see attac::ments ^ Chlorides. of comp- ..°luic:277,000 pp:. _al ^.v;..CS- --e~SL'~e. t07°.1 _ :tia_ ~' _ _ _na= flo•.:_. ~ _ ressure: 2S°.7 :final c_cse~^_n r=ensure: ~°-~-7 Seconc init_al __o'~_n: press's=°-: 230.2 . ~~ , -e_=su=e. c_oc e~;p_re~ _ _nal ^yc_c _at_.. _ _ '_~al ._c» _ =ess.:r°_: 383 Cc.;..~~Ga`.s i• Page 9 C Test ~6.B i _.. _... _ Tool open 8:00 p.m. - 0 psi 10:45 p.m. - small flare (1 to 2 feet) • 4:00 a.m. - 6' flare (0 psi) Shut in well 4:00 a.m. -Build L'a 4:00 a.m.- 0 psi 4:10 a.m.- l0 psi 4.20 a.m.- 35 psi 4:30 a.m.- 47 Fsi .:_,.,.,~.__ _. _- ... - .. - 6:00 a.m.- 180 psi Cpe n tool 6:00 a.m. - 40' flare 6:05 a.m. - B psi F:'. -15' flare 6:30 a.m. - 0 psi F~'P 4:30 p.m. - 0 psi FmP 6:e11 }sicked fluid -built to 10 psi at o:00 p.m. 6:10 p. m. - 0 psi i,P Well };ic3:ed fluid -built to 30 psi at 7:52 p.m. 8:05 a.m. - 2 psi E:30 a..... to 2:00 a.m. - 0 a~i rTP 2:00 a.m. - pressure builc_^c " 2:30 a.m. - 20 psi .TP 4.00 a...~. - 2 asi _ .P Well shut 00 a.m. = build up in - 4 . 4.30 a.m. 165 asi 5:00 a..... - 300 ^si 0:00 ~..... - 5 B O _^~i `` ~ r % : V V G i:l. - G.J V ~C~ Caen well 7.25 a...,. w/920 ps_ - _erce __~re 8:00 a..::. - 5 aSi set 10/04" C:1: 8._0 a..... _.:Cw rate 'i E:45 a..^... - 5`S _as= C ~~ C..... - .JAG ..... ,~~ - C~ S1 1"1.5 c..... - ..__ ....._.~~ - 57 a_=~ s:-:~t ~, we ll 1_ . c~ a..... - ~..__.: ~~ __ ~G G..... - - ~, _~ _ '__.G~ a.-.. - 450 '_ 1.00 _ .... - 720 ^s~ Oxen well ...00 _ ..... «/c30 ps_ (C 7C0 ~+-_ wF11 becan to unloa^. wager - _5 =C1 c.,^~ _ _ 52t 10/04 " C;.}; 2 . ~5 _ . r... - 45 psi _.0^v _ .-,. - ~_2 .._~/C C:71_.. well 1i7 ...3G a .... - D:__.:C L'a 4.OD _ ..... - 3~~1 _^~_ . 00 _ ..... - cc~ - 0:00 ..... - 940 ^~_ . Open •~~e'_1 .... (~ 5~., : ~~ r.+e11 beca:: to ...._cac »ate_1 - set ./8,' c:-~.}; c:_5 _ O. 1J _ .... - .7 51 _ _? Set 0/04" c?~J: 0:30 _ ..... - 02 _ _0:00 _ .... - 11~ .'•:_='/J s0 ?___ ~ __ ~~. tom.. _,,...~...... r1 U l Y\ - ~- S~ =tom. ,,:,/; : -=~ __ ~+ _ :;~ ,.: ago - .. ~,'~' a cs /:~ - ~ i C : _ T-a:a ~_ ~:~ -sue r _? _- - .. CC _ -mac CG%'- _ CC 5 -~c i np ;.- -- .. CO _ i.~G (jCj - ,.. .. CiG l '-~~ zr C~, z1) Lov ~t~:o ..9/S /•~ 'te'e ST o T.a.h ,:acp Esc CSo - W 00 0 Lac X07 - -'z 00 3 tsc S; ~ - -.' e GO ~ L Esc o3 - C/..C:d CZ~ - - CE S ( ~+ ? sue QZ3 - =t4c ~9/S /~'' '~'E ST 5 TTa.h ~acC _ _ - ._. do l- 'Ci J - "~'? Cv E T Ta,-t c:- ~.^.43 (~~t .~. CCG' 9LT ?'"STS : a,o~:) C/.i ::~i gEE - Tsd oo - ~-' e S`~ i.T =trio ,. `?/9l =a; (,a.e.~ ~eo<<~a o~ c25a4 TTa,h ts~ COS ~) =t4c ..3/S /•`~ '~'' C~~ZT TTa,~ uac~ -sd CC3 - 'te'e CE ET tsd OCS - '1'~ CENT tsd 99 - '~'~ CE C; _ _ ~~.w ~ .~'.'Y`.i:I1 •..v~ .-`Q` .. ...~i:'.. `~... ... _.+V\: :<. . _ r. ..._... .....s. .r_ - _ ... ~ r _. ... ~~fe:- -.. ..._r'~. ..~ .a • .t~'G.: '. . Page " - - ~ ~- ~ - ._ . ~° ~ ti',ell 1~~.'te: :,euis Fiver D-1 DST 6c :,ate c: Test: 9/25/31 Perfs ~: Same as ba Spp: 8 '`,;pe of tuns used: Tool set C: 3Q41 Tv~e of tool Used: F.'TS: Hydro spring Tool run on: '-7/8" t~g• hater c::shion: too r cf eet: t~'~e f1U1d: . ime tool ,:as opened: ..: 40 a..... Gas ~o surface: `-'eS =_.:id to surface: 1'es SL'rfaCe pressure: Aare: 3:50 a.m. (very small) Chlorides : 2v/P. Chlorides of corp. fluid: 2:/h r~ __me tC; 1 Was C1CSec. initial rycrost~ti c ~-ess~re: '~ 64.6 =n~ti al flc..~ing pressure. _33.7 ^i;:al _°iowine pressure. 474.2 __nal ciesed in pressure: 1630.4 Seco:;~ _.._=_al flo•~_n: _r°°s:-r°: 4°5.7 ^~ -•a' ^y -_cs~at~c _ ress•~re, 21'_3. 2 _ -... _ ~lo~; . 6G~ . 1 Inc .._os~d 1n: _801.3 Co..~:,er=-= ~~~.. _.. ",cl - ve=~' shore test • ~y„i:~w~,y. ..a . .. JU."'~-~;'~.~ -. ... ~ _ ~..- ~.~'.-... _..:.(~,.. _ ~., w,. q.`:l~T ~". a2,..J.__.... • =~..'f~'-ham _ ~... ~...i-._.. ~ ~-. w-~.~.~ Paoe 12 i Fell 1:ame: :,ewis River D-1 Date of Test: °/~B/61 DST 6D. Perfs C~: same as r6A Spr; 6 - ~._ Type of guns used: Tool se :. @ : 3560' Tvae of tool uses: Tool run on: Drill pipe 4;ater cushion: Igo r cf feet: tvice fluid: Time tool was openec: S:?2 p.m. Gas to sure ace : ~ es Auld t0 SllrfaCe: n0 Time tool was closec: Sur=ace pressure: 'lire: ves i~T?-? psi) 1~:3B _ .... Chlorides: ~`/" C~:oriQeS Gf CO^.~~. f1L'1C: 1~/~ Inyt_al nvGrCS~at1C D«°_SL're: ~;)?~.~ _r.itial :lcuinq _ ress~.:re: _3.6 _ _nal _'lo•~'~. _ _ -essu_e. 5.! .5 _ anal clcsec _n y.•ress•~.e. 61.5 SecGnc ini~_al __cwin~ _-_ss'~.e: --- C~-~sr.` B~.:i_.. '~. ...?~ a..... - c~ 5 . ~0 a...,. - -1 os_ • "~_` ~I: w- •.' . ,.~. - ...c......:«IS.~i~~a.ri•• .. r. ~ ~ .~T~w.n.s __ _.-: -. ~..._~. ut.~. _..u.J.....~. ... _.~~ ~:^.v-•w >. a'te'... '~...-.1 ... ~. ... .~ . ,. -~•...y.-. - ~- Page 13 Y~ ~~.. _ 3,'ell Tame: LeM•is Fiver D-1 Date of Test:.. 9/30/61 Perfs C~: 3451'-3469' _ _ Type of guns used: 2-1/16" thru F,.bg. ~?50' Tool set @: Type of tool used: RTTS: Hydro spring Tool run on: 2-7/8" :fig. t,ater cushion: f of feet: 500' type fluid: fresh kater Time tool kas cpened: 7:30 a.m. Gas to surface: No :laid to s~.:rface: too DST' ~ SPF: B Surface pressure: 0 psi r lire: Chlorices. °~~~^ `lLid-O.8 pp, i1S , ~~i0- ., 000 Chlorides.of cc:r~p. ~I::id: 3°0, __ '.'1^:e tCCl t+a5 C1CSeG: ~ i~l r Ir.it_ol .ycrostatic p~ess•~re: - ~nitizl flc»in~ _-ess~re: 478 final flo~in~ _ -ess:.re: 651. _ -:.al closed in press•..~e. ?'~47 `'e:. ter.-- 1 _1o•M_n^. •„-ess~re_ --- ... v..._ _LaC ~ _~ l ~.vcrosta~-c ~essure: _i~3 --~~ - -' Cc.-:ants. 5•r.r...~_ - f_. ~ =-~~,. _ '_ _„ ' .;. .. - -_. _ _. i} t,'ell 1:ame: LeMis River D-1 Date o: Test: 10/2/81 DST -- 8 ;. Perfs @:28G8'-2°00'; 2°55'-2Q5°'; 2967'-72' Type of guns used: 4" csg. Tool set C: 2E25' T}•pe e~ tool used : RTTS : r?}~dro spring Tool run on: 2-7/8" tbg ~:ater cushion: No r of .feet: tvoe fluid: _i:~e too'_ was opened: x:40 a.:~. Gas to surface: ?~o =laid to surface: swa~~ed 10.3 ppg SPF: 8 Sur: ace _ressure:0 psi Flare: No Chlorides:3~0,000 CfllOr~deS Cf CC:;.p. f1L'ld: 70~~00 :i-,o toil was closed: ~nlt~cl ~:VG_CStat_C DreSS'.=re: _-_3 _ _r;~l ~_v~2nG`p'-°_SSUre: 53^ __nal closed _n aress•ure: --- - --;~= ; cr~_ta ~_c _ ~~°sure:_~13 .- - • - = -.~~'~ 10 _.: __~~ v. .__'JS~_ _n ~~ _~. _'~G ~-va', S"v.~~e'u v:e__. ~. 'n -. r •. ~__.~ na--.-~sr"" . .. ._ -.~' (~ .. .. ., ._.. _ ,..c. ... ..4....- -. ...-.. ... .ate (~ ~ ~- ~ -r.. ~ ~.~ ~.... _:. ... + _. _ . ~. .. _ .. rage 15 Fepeat Fozmation Tests Formation Tested Fluid Fecoverv 7240 2~one 6545 Ivone 6552 Ivone 6302 -- _; __ - None _ . :. 6310 Ncne 4 05 5 None 4 09 9 2vone 4068 None rres~ure Buildup (^si) 4002 1C5 283 118 50 65 240 °6 i RI X __ O c~, EXE°~t~[T NO. 5 n ~~ ! ! ~~ ~ , !~e~~-~ ~~;-er iela ,dell D-1 PRESENT CONDITION CASII~~ DETAIL !. Kelm Dunning ~ 123' Il. 30" Driven to 33' Ili, 20", 94~, N-40 Casing @ 359' f1~. ~ 3-3/8", 68~, K-55 Cosing ®2395' V. 4-5/8", 47r-', N-80 Casing ~ 5135' AI~AI~DO[~~~~EI~T RECORD • {~` ., ~. ~I nr f~ tT ~~ J ~Y t~ `i "'~~i~}iT ~i ~~', C=1~~NT ,; I i .% i ~' v~ i, 50' S:~rfcce Cement Plug 2. T.O.C. ~ 2745' 3. Cement Retainer ~ 2805' 4. T.O.C. ® 3317' 5. Cement Retainer ~ 3374' 6. T.v.G. g' 3192` ?. Cement Retainer ® 3849' 8. Cement Plucs From 5135' to 7235' I?EI~E~ A. 2868` 2955' ~ 2967` T I 3G70` v `` B. „451 ` I ~ ~. x882: ~ 39G4' ~~eATl01~I .ECOI~D - ~900F ~ . 2059` 1 - 2972° UPPcR BELUGA - 3072` - .~4u4' ~ - 3887' } F~!!DpLF gBLUGA ~h~ ~ f - ~~ 16~ _~ ~``~~~ ~ ~ ;TFt`;f L~J Ili.?~o~ I~IIQC•ll±^i!p^l~ IJ~ i ~ j or ~qz'c~ ~~rioratiors cnd Cemer ~luQ I f -j-rr+*irJ-, 'ma'n+~r i~[pC~~ ii i, of i 1.11, I i ~~,v t v~.. ~ ,• m x _~ z O °, t lr. !"111 t31 _i tr1 V . D _ - - "-~. CHEh1IC,4L & GEOLOGIC~4L L.4BOR~'~RIES OF AL4SI~.q, I.~'C. -.- '- 5633 B STREET AN:,HORAGE, ALASKA 9951& TELEPHONE (907) 862-2343 FEDERAL 7AX ID # 92-0040440 X804.10 o.E~ ANALISIS REPOP,' EI SAMPLE foz Bork Ozdez ~ 7194 Gate Repozt Pzinted: JU6 27 88 ! 10:42 Client Sample ID:LEi+:S RIVER PWS1G :UA Collected ! hze. Received JUN 10 88 ! 13:00 hrs. fzesezved vlth :NONE Client Fare UNOCI,L Client lcct DNOCI,LP JUf~! 2 :' X988 P.O.i NONE REC D Req t C. fi't'. LOCH:«'pOD Ozdezed By C1,NDI LOCb~+'OOD knalysis Completed :JUN 21 88 Send Repeats to: Labczatozy Supe:visoz :S?EPHEN C. EDE 1)UFOCkL heieased 6y ~~ G ~~~ 1 2) -_ . Special V ins t:uct: Chemlab kef #: 1373 Lab Snpl ID: 1 Matzix: Fatez Fazametez vested Result/Units Method EP 20XICIiI'INDRG?,NICS RF.SENIC n/a n/a kD(0.01) mg/1 EP SW846 EPSW846 E}.RiUlf 0.14 mg/1 EPSW646 C3DY.IUI! ND(0.01) mg/1 EPSW846 CP~O~UM ND(O.GS) me/i EPSW846 LE1D ND(0.05) mg/1 EPSW846 lr'F.CURI ND(0.001) ~/1 EPSW84b SELE};IUM xD(0.01) m~/1 EPSW84b SiLvtR h'D(0.05) m~/1 EPSW846 pH, CDRRDSIVI'I 8.3 units EPSW84b ce;zees £,°L1~?D+.kBILITI G'200 deczees F EPSW84b F.EfC"IVI:I FOh RE?C:'l+t EPSk84b iC?-25 ELEY.F,hi SCAN nJa n%a ICP i:LU!t'h'II?: 0.81 my/1 ICP ~,RSEFiC ND(0.05) ~/1 ICP E~EiUM 0.22 m~/1 ~ ICP bOwOF 0.21 mg/1 ICP CbLCiU?! 8.1 m9/1 ICP C1,D}r~;sy ND(0.01) m~/1 ICP C~OM:UX ND(0.05) m~/1 ICP CO?PER ND(0.05) ~/1 ICP IRDN 5.5 zog/1 ICP LEAD kD(D.05) m; '1 ICP ?'.LGh~'SIU1~! 3.4 m9/1 ICP M~+GLh'ESE O.Ob mg/1 ICP Y?F.:U.I fiD(0.05) m9/1 ICP NiCErTL h'D(0.05) me/1 ICP PHDSPEOP,OUS RD(0.05) m~/1 PG:lSSIU1~! 8.G mc,/1 ICP SELENIU1r HD(0.05) my/1 ICP SILICON 5.2 m~/1 ICP SiLVEF, h'D(0.05) m;/1 ICP bllovable Limits -------------------- 5.0 a.:yimura 100.0 maxim 1.0 maxim•,im 5.0 maxim•~n 5.G maximua 0.2 m:xim~.un 1.0 mx:a.uL 5.0 maY.imum 2.5 - 12.5 mix.. 150 de '~ >'::~;~:_ CHE.'tslC4l, ~ GEOLOGIC-4L L.~4BOR47'ORIES OF:4I~ASI~.~, L'~' ~~~c - ~ I~~~~'i: ' 5633 E STREET ANCHC)RACE, ALASKA 99518 TELEPHONE ;907) 562-2343 ~~ y O 1' /=' FEDERAL 1~,X ID k 92.0040a40 J~ `~ ~Ot~.a el(i a.F~ ~ ~~ ___ ..J~ -~ Client Sanple ID:LEh'IS AIVEf; PWSID :UA Collected E hrs. Received JUN 10 86 E 13:00 hra. Preserved With :NONE Clzent Nane UNOCAL Client Acct UNDCALP P .0. # NONE REC D Req # Ordered Ey CANDI LOCfWODD Analysis Completed :JUN 21 BB Send Repozta to: Labozator}• Supe~~z~via~r STEPHEN C. EDE 1)UNOCAi Released Iy JCu(6~-'-~ `i- vu~ 2) Special Instruct: Chemlab Ref #: 1373 Lab Szcpl iD: 1 Matrix: Water Fazametez Tested SODIUM S~ROhiiUM TIN VANADIUt! ZINC -IRCOiiIUM P,OUTiHE WATEP, ANALISIS CPW ORI DE SULrATE RESIDLIE:(TDS) PILTERAELE F.Ls.DFESS (as CaCC3) A:,T:ALINiTI (CaCC3) coaDIICTIVITI p5 f;exult/Units --------------------------------------- b45 zoo/1 e.sl m~/1 ND(G.05) mg/i fiD(0.05) my/i ND;0.05) m3/1 hli(0.05) mgh n/e n/a 550 mqJ'_ ND(1.0) mg/1 1730 mT/1 35 mg/1 640 m3/1 :°00 ur~os/cm B.1 units Sas~le t, err: }:S Allowable Method Liryits ICP ICP ICP Irp TCP ICF 4b Tests Fezformed See Special Instructions Above UA-Unavailable hT~- None Detected See Sa^zle Remarks Above Nt.- hct Anel}-zed LT-Less Titan, GT-~reatez Than ANALISIS REPORS BI SAMIPLE for Wozk Ozdez # 7194 Late Report Printed: JDN 27 86 t 10:92 -, EXHIBIT IrrIO. 6 ~ ~~ ~\ ,~BO'+a 1(14~E~ CHE.'~11~-4L &TGEOLOGoR ~ALA~OR47Y~RI os ~0 56~~~~. I~;C. 5 3„6S ( 1 ~ rEDERAL TAX ID ar 92.0040a40 ANALISIS REPORT BI SAMDLE foz Wozk Grdez ~ 7111 Late Report Printed: JUN 15 SE ! 12:51 C'_:ent Sanple ID:PRETTI CP,EER - PRODUCED WATER Client Name UNOCAL PFS;D Client Acct UNOCALP Collected JUN 6 68 E tus. P.O.fi ~'EP,BAL heceived JUN 8 88 E 09:45 hzs. Req i Pzeserved with :AONE Ozdezed By PRED DUTHWEILEP, knelysis Colpleted :JUN 14 68 Send Repczte to: LaDC:atozy Supezvisez :STEPHEN C. EDE 1)UNOCAL he;eased By : ~~-G~--' C • '~ 2)PP.ED DU'iHh~ILEE'UNDCAL-PRODUC?ION f' Special ALTEP~NATE CONTACT: JOHN BEITLA 2b3-7672. i^rtzuct: Chemlab Ref ~: 1323 Lab Smpl ID: 1 Pa:ametez Tested ---- -------------------------------- EP TOZICITI'INORGANICS ARSENIC BAF,I~u CADY.IU!! C:-~ 0?rU11 LEAD 1n'RCU::Y SELEhUH SiLPiR pE, COR.A,OSIPITI decrees F,PLA>•'-~!~BILITI REkC_:GII Sa-~'se Matzix: Watez Allovabie P,esult/Units }Sethod Limits n/a n/a EP SWE96 0.013 zog/1 EPSWE46 5.0 maximum 1.3 m~/1 EPSW846 100.6 rzxim R'D(0.05) mg/1 EPSWE4o 1.0 massmw~e ND(0.05) mT/1 EPSWEa_6 5.0 nazirsim ND(0.05) mg/1 EPSWE46 5.0 maxizcuc h'D(O.D02) m~/1 EPSWE46 0.2 maxirruo ND(0.01) rn.7/1 EPSWE46 2.0 7rza::V:m ND(0.05) mOJl EPSWE4o E.0 m=x.nzm 4.6 units EPSWe46 2.5 - __.5 GT200 dea:eea E EPSWc46 nin. 140 ae NON REACTIGE EPSitiE46 i2 Tests Performed See Special Instzuctions Abcr•e UA-Unavailable ND- Ncne Detec.ed See Sanale Remazks Above NA- Nct Analy~ed LT-Less Than, GT-G:eater Than CHEh1ICAL 8 GEOLOGIC-4L LABORATORIES OF AL.~4SI:A, I.'~'C. 5633 B STREET ANCHORAu=, ALASKA 99516 TELEPHONE (907) 562-2343 ~ FEDERAL Tf,X ID k 92-0040«0 ANALIS:S REPORT BI SA10'LE for Mork Oz de: # 7111 Date Repozt Punted: JUN 15 88 E 12:52 Client Sample ID:PRETTI CREEF. - PRODUCED hATER Client Name UNOCAL PkSID Client Acct UNOCAIP Collected JUN 6 88 E hrs. P.O.# VERBAL Received JUN 6 BB E 04:45 hzs. F,eG # Yzesezved with :NONE Ordered By :FRED DL'THh'EILER knalysis Completed :JUN 14 BB Send Reports to: Laboznto:y Supe:~•isor •STEPHEN C. EDE 1)UNOCAL keleased F7 S~~ ~i- Z~ 2)FRED D'JTHWEILEE'UNO~AL-PRODUCTION /" Special ALTERNATE COAiACT: JOHN fiEITiA 263-7672. Instzuct: Chemisb Ref #: 1323 Lab Smpl ID: 2 Hatzlx: Fatez Allowable Fazametez Tested Result/Units Method limits - --------------(U j------------------------- RESIDUE: ~S NON-FILTERAELE ------------~---------------------------------------------------- 1307 /1 ROUTINE SCALE ANALISIS-SOLIDS n~a n/a IGNITION LOSS E 550 deyzees C 43.0 ~ by ugt ACID INSOLUBLE liATERIkL ND(0.1) ~ by u.t I F2'JN AS FE 3 C4 b 5, 0 MAGNESIUM 0.5t S[L1CON 0,49 SOD I UM1! 0 , 4 1 ALUMINUM 0,08 SORON 0,07 ZINC 0.06 Sar~ie ne~z ks rests Pe:fozmed See Special i2 tzucticns kbovE UA-Unazailable ND- Fene Detected See Sa.~ole Rezxzks Above NA- Not Anel}zed L-Less Than, GT-Gzeatez Than _l ~ _~ /' -_~~=-~ CHE1t1ICAL & GEOLOGIG-4L L4BOR4TORIES OF ALASILA, I~~1'C. ' 5633 6 STREET ANCHORAGE, ALASKA 89518 TELEPHONE (907) 562.23<3 FEDERAL 7h ); ID ~ 92-00400<0 u eoa•ro'art5 AxALISIS REPORT EI SA1l'LE foz Mozk Gzdez # 7':11 Date Repozt Punted: JU1~ 15 6E ! 12:53 Client Saapls ID:PRETTI CREEK - PRODUCED WATER Client Kane UNOCAL PWSID Client Acct UNOCALP Collected JUK 6 BB ! hza. P.O.# VEP.BAL Received JUK 8 88 ! 09:45 hza. Rsq # Pzeaezved vith :xDKE Ozdezed By £AED DUTHWEILER Anelysia Colplcted :JUN 14 88 Send Repozta to: Labozatozy SupezYipo STEPHE' C. EDE 1)UNOCAL Reieaeed Ey ~~z ~_ v`t~it/ 2)FEED DUTHWEILEF,'UNOCAL-PRODUCTION Special ALTERNATE CONTACT: JOHN EEITIA 263-7672. Instruct: Chezdab Ref #: 1323 Lab Smpl ID: 3 Fazametez Tested ICP-25 ELE}n'h'T SCAN kLUlr? RUK 3RSENIC E?•P,IUM fiDROx CALCiUH CADYSUY. C~O1+.IU1± COPPER IRDx LEAD Y.k~h~ SI'JN. KAxGAh'ESE 20.'BCURI h1..F.EL PHOSPHOROCS POTASSIUM SELExiUM SILICON SILPEA SODT.UF! sTP,oh1IUM x _: ~Ax~DiUM i1NC 2IP,COh'LUM RDUTiNE WATER AKALISIS C~.ORIDE S ~F~"E FrSIDTt:(TDS) FILTE::AELE HAP.DNESS (as CsC03) ALEALINiTI (CaCO3) Kaizis: Watez hesult/Units ---------------------------------- n/a z~la 1.3 mg/1 b.3 m3/1 120 mq/1 0.12 mg/1 xD(0.05) zo:il O. i0 my/1 470 ~/1 0.12 s.~!1 ~° m;/1 3.. ma/1 xD(0.05) myil C.51 a~/1 C.56 r~/1 73 mg/i 15 mall xD(0.05) my/1 1940 mg/1 D.4s x0.;'1 7.G m;/' 0.72 my/l xD(0.05) myll nfa r~/s 2120 ~!1 5.0 mr: l 5220 m-/'_ 542 mc,'1 145 D rr;,' l Allovable Hethod Limits ICP ICP ICP ICP ICP ICP ICP L%P ICP ICP ICP ICP ICP ~. iCP ICP ~D ICP ICP iCP ICD i~P ICP ,Cp 1 ICP ~, ~} • - ~' J _ ~ `~ CHEHI C4L ~ GEOLOGICAL L.4.BORA7'ORIES OF AL.4SK~, I.~'C. '' 5533 B STREET ANCHORAGE. ALASKA 99516 TELEPHONE (907) 562-2343 I~BORilORgp i=EDERAL TAX ID ~ 92-OOapa40 ANALISIS REPORT BI SAMPLE for tiork Order } 7111 Late Report Printed: JIIN 15 BB ! 12:54 Client Sample ID:PRETTI CP,EEb - PRODUCED HATER Client Nacre llNOCAL PKSID : Client Acct UNOCALP Collected JUN 6 86 E h:s. F.O.i VEREAL ReceiYed JUN 8 88 E D4:45 hrs. Req } Preserved with :NONE Ordered By FP,ED DUTHWEILEP, ,rn~ ': ,. Analysis Colpeeted :JUN 14 S8 Send Reports to: Laboratory Superv sor :STEPHEN CEDE 1)UNOCAL heleased By ~~ !!~~ 2)FRED DUTHh'EILEE'IINOCAL-PP,ODUCTION Spatial ALTERNATE CONTACT:--JOHN BEITIA 263-7672. Instzuct: Chemlab Ref $: 1323 Lab Smpl ID: 3 Hatziz: Hater Parameter Tested Result/Units ---------------------------------------------------------------- CONDUCTIVITI 7690 umhos/ca pfl 4.6 units Alloxable Method Lirlts Ser.:le i,en~:ks: 34 Tests Performed ; See Special la tructions Above UA-unavailable HD- None Detected - See Sample Remarks Above HA- Not A:Llyzed Li-Less Than, GT-Greater Than m X 2 -i Z O i ~ COMPLETION FLUID EXHtBLT h[O. 7 Percent Pounds Pounds t.~aterial by Weight Per Barrel Per Gallon Fresh ~•,ater 80.8 339 8.07 Potassium Cnloricie (KL'L) 6.0 25 .00 Sooium Chloride (Ivacl) 12.9 55 1.31 X~ Polymer .3 1 0.02 (Xanthum~um biopolymer) Total 100.0 420 10.00 a m X 2 • . EXHBIT NO. 8 • Unocal performed a detailed analysis of injectable sands in well D-1 and their correlations to the nearest gas producer, well C-1. Based on that analysis, Unocal requests permission to use the following intervals for injection. Zone ~F Depth ~~~D and VD Footage 1 3, y07' - 3, 918' 11' 2 3,873' - 3,893' 20' 3 3,714' - 3,768' S4' 4 3,020' - 3.,046' 26' 5 2,950' - x,960' 10' 6 2,850' - 2,900' 50' 7 2,562' - 2,596' 34' Justifications for each zone are as fellows: Zones l & 2 3,907' - 3,918' / 3,873' - 3,893' Both these zones have impervious s~,ale barriers above them. Tne lower zone is sealed off on the bottom by multiple coals and low-porosity interbeds. Zone 3,907' - 3,918' was perforated for a DST during the initial .drilling phase. Tne zone was shot without a cushion, and no gas or water ever reached surfac=. During the test, surface pressure was 0 psi and showed no buildup. Tne final prognosis concluded this zone is not gas productive. Zone 3,873' - 3,893' was never perforated and does not appear to correlate to a gas Zone in the nearby C-1 well. Zone ~~3 3,714' - 3, 7::8' This zone teas confining lagers at _east 80' thicK above and Bel ow ~t. _.. was not tested during the cry ~ final cri_li ng of the D-1 well but it appears to be correlative to a sang that tested noncommercial in the nearby well C-l. It must be noted that the correlative sand in 0-1 (DST ~~7) flowed only 300 h+CFPD of wet gas through a 3/8" choke ~t 85 psi tubing pressure. These numbers represent an extremely wet gas reservoir with a very limited accumu~ati on and therefore, the sand was squeezed off v;ith 150 sac~;s of cement. • LEWIS RIVER FIELD WELL D-1 • PROPOSED 30" Driven to 33' ' 94# H-40 Casing O 359 245' 2805' 13-3/8" 68# K-55 Csg ®23! Pkr O 24 2562-2; 2850-25 2950-25 331;' X374' 3792' 3849' ~ y 3904'-3:. ? 6' -,- Cmt Pluas E+35-723 Pkr ®29 3020-3s 3714-~ '. 3873-a 3907-3 BP/RTNR ®39 3856-~4-' QSV ~ 42: 9-5f 8" 47fi N-80 C~•g O 51: NOTE: For additional. psrf info Below 4220' see History 1 /19/88. Chi . By: NKS P~:~S~I~dT COAST~ZONE BOUNDARIES OF ALASKA ~A ~ ~ t s ~ ,I~ ~~~ ~ ~ w l ~~` a } ~~ 9 ~Al ~ t C :. A. ,.J ~ . , ~. `r ~ _ ~ r r `% , ,."~"", ~, ,j~. ~T• ). w 'AIL' .. :ES a !. 1 ter '" ~! + r . 1 k b td! .1` 4 1 1y - __.~.y~ ~, 1 0 it 't!~ ' w~ T"e • ~ y, 4~ ~j' 4•. r b~ ~ 1; .. I . , I ,, ti ,~ ~ 7 s ~ ,tt q v i '~(.1 t.. ~ 4 f ( ~ I$ ~ ~. ec P A , ~ ~ ~` ~Ma a~ska ~`~ , s, ~ E .;. .. ~ ~' '1 T' > A ~ "f f - .: J ~ ~3-~ ~ r+l~~,,~ 'Z~ g~g •+a : Y '- t~ ~ 1 - i r ~ ;ri a 4 ~ ~~. ~k ~ ,~ ~,' ,' , C, ~ . _ ~~~~ ~~ R ~' '~-! "rte'- ;:..r .''. a..- ~ "! 'ate'/ j ~a:'. ~ ~ ~ ~ yr 9 '~~~ -- ,~ ,. .! ~ _,~r, '' l,tl' "(ki ,"i r trtzf Y J i~ ?`~=~~4F 1~ rir.'rC~. ,~ -' ? ?;~ - ~ it J ek `~' i ~' r r ~S Cr ~" ~ " J P ~,P ~.1 -'---- - . : ~. ~: ~~~~~ - ~. ' i •. 'y.,_ ~~ _ ~. \_ _ _ - r 4 I a • - ~~ ~ ~ , r; ~ ~ , . ~- , ' - f ;~' r.- ,]j:~- r r- r4~YU s.,, ~ . Z ?: ~ ~.,-~ S f, EJ ~` - 1 ~-. S r - -~~ N ~' ~ 1 G~. ~T ~~ 1 ~ T1. - per' 91^x` t L ~ 1_- ~ ) vY~ &~ ~ ~ z ,r '•-`--•--'~. ; t~, S - I-_ 'i, t e 1 ljy I, _7 3 y _ r-R- --`-- Yj~am.. t I- .~ r n~ t ill ~ -. 1 ~. L.r'1r~ C",t7 ~ ~ 'R r t I , .' >.. ~. ~ ~* J ~~ ~ T .es ..• ~ -. v ~ $ .off e- ~,~'~A, ~ ~f - ~ ~ & F ~ F ~ ,,~ '1 , ~. ~~. ~ `. rE - „A..7 ~ ~ r: ~bx J C' 7 ~'~ , F ~~ r7" *.._ I _ L'-"+ -~ 1 7-i~-- y ~_~- >w - '...~'. ^F,~ e .J +ae ~ ° T I ~+J ) - , i - s~ "-J` i ~ ~ r ' I"L~ ~ P :r 1, y, - F T~ a R h± t y c^.'- ty !"..t' 4 ~~ xl ~ ~ y ~ a # "t,,,~ +_ I, ~`~ 1%: ~` : ' sr ~; 9 _ x ~; d tt a -a ~~ -yZ -': +- { ~1 ~ r ~ ~ 6 ~. : Ih`-'r rri..a ~ '~..~ d e i ''" -3--'' ~"` j. r•,.~ f ~E' .~ r I -- r T., a `~ ~' Fe, ti~ l~r ~:~ d fir,', P ~` 1' ~ ~ ,^ 1 i~ ~; r;. ~ P - TYONEK #89 In ~- i 11 ' ~ ~ ~,..m.. .,, ~ ~'. u ` ~ ,~ 1001T10N INDE[ .~ -...D Inland Boundary 5eatward Boundary --- District Boundary ~.~.~.~ . ~y e.t ~a" ~ 6 y'.~. ~` 'y, ~ .. rM~ ~. ! ,)3a1a~3:' n. t .,~ 6 t r ~'!b - -~ ~F ~ ~ .*. }~ . y ~;~.:-?a` .,Cf "~~ .r ,:~i .>.i'.. ~ 1 r J u 1 A ~;a.\ C~ -.kj E ~ - c ,r "` Of Y'k v k t t.pa,• . § u' ~ "' er,u,µ} t } - v,„,' 1 ti r ;.~, ++^ BOUNDARY DESCRIPTION ~y ~ + w r: 5^~1~, ~i....• ~Peikx!.E 1 ~,} ~ ~n 71Y w t_ _ s,. x: ..~ r f ~-' 'ul N --{' ~ ~"'s"2,`.~..Y•y '~' ,Fy,~W, { .~~ i _ ry .._G f ~, may, - _ r. t ,: ~~ wt~=~ -T - ~~`":`~~ „~~ ;-r Federal (ands: Excluded from Alaska's coastal zone c "` ~ T:_""` ~''"~-~'-`~ :'y 3. "~ ,- ~•-' - - - ` ~ ~- 'v}'f' ~, _ boundaries are "those lands omed, leased, beld in "7 v r. ` ~ ~~; ('`' ~ •- ~~! 'v. T ~ _.F "' 1. ~J~•.-`~~ ~ . fa 4 ~~~ -I- ^ test or whose use is othervise by law euhject ,Y <':• `b 1..;, lll~~~. 1, ~ ', i - ~' G F ,~ 1 4, ..~ ~. _ , ~ Y t e tl ,'~y - t! ~ ~ Y ` + ~',e *., 9r, X ~ '~Y, ,' C~ ~, , ~; solely to the discretion at file Federal Government, °+^-;y~ ." ~% ~. '{ ~ ?s, ~- 1 - rY 1`., t - +{ ip, Yy.'. + -r,.Y~ .~~~ ~' ~r t - its officers or ay-ents ." (15 CFR 527.33). ,' , :. . i~Y -~~~t~~- `r ,lk; \ ~ 'i'!t , { d` '~ ~~`} ~ „r. )r.-. ~ ~;+, rr ~`. ) ,~, ~: ~ t ~ -"•~~ r ,+~" ~ °` '. Activities on these lands are subject to the ,~ ,. .. ~,, ., „ y ~, et ,li. .f R..• .`.; ,. _. ~~•: - tip.. .v~ ,~ ~•~- '~~ 'r~ ~'ti ~;.9 ,.~(]~ . -._ ~"_' 't° ,- ,F - consistency provisions of Section 307 of the Coastal g;'i:~{ .tOE~.~ ; .., ~_ ~p.°~ f ,~ 4v- ~.. y ~'"yr. ,'v.. T~ ~~ ~"N _• f 4; -{. ly.+ Eone Management Act of 15'1, as amended. 2 Y ~~ `t :.i~ IF.- „~,:.`'_ -,_r~ ;. 4 t~:-. _ .. f y r ,.~ ;~ •, t, ..~ *ai~ .~ ~~.P 4.d-~--. ~~?{)~~ ,, '~ / ~., ~~' ~tr ~ X:- j:_^l'Y ~ h'~~~~1~~-~ ; . ~r0',. .~~.. -"h ~ I ~ ~ _ - ,`. c _.-y~ ~:y~_"- nTrrY,.. T-~. t'~^~"i'~;'~ .id• ~.'. Seaward Boundary: The seaward coastal zone tcndary ;` ~^'~` _ -°--i'==-'~-'1-~-`~ - --1- °-_-~~"-'~ `7-F ~ ~ "" ` ~~~ ~"~: ~~^ is the "outer limit of CLe United States ter_torial ~. 2 rt _ ~ '=~ & ,i~ -~ - ,,[ ~v I. ,~. sea" (15 CFR 92 J. )2}, which is the "*_h:ee a' ~v ~._ ' x :7` ~.* ,.,'~y ~ , '•~~ v -:~. ~ 4.-Y ~,r,~' Y„,., - ~r a,,. i. ~ ~ s - geographical mile line" (47 CFR 3701.,). All ,6a. ~~'~,*t. .~: l'~~SV `j °'"` j.}, Sti '~ - ` ~ ,, •" , ~ 7 i` ~.~ 'Va Q - Yrr- f ~, ~ ~~' offshore waters on this map are within the coastal ' ~ ` ! ~, ~ y ~~ ~`_ ~~ ~<~ ~ _ ~ •.., r - .p, I v.T',;:{' . r. -.\ F - ~~ ci'~~ d: ~~ 4 r ~~ '{S"' zone. r • - - _ x q., yi" ': `, . , ~~\ ,. ' y`~. ~, . ~~ r . ~ e 1 _ :-~- ~. .. - _,_ 1~. _..-~, ^ ,~ :f ~ tf(; r x- ~.. k ,, - Aenai Peninsula &;roug; : The inland coas'a' zone ' {,.v¢~?~G",_ ' ~.*~} ~ ~ k 'v; ~ U ""5f: j \a- ~~~ - - - - ~ '.! _ ~ q~ -'~ ~ i~ ~~«~ ~l+l c, boundary in the Kenai Peninsula Borovgh is [he 'Q`'"~~, A „ • ^~,.. ~~ ~-.~ '~ ~. ~ - ~'.•, ~ lit r --. ~'- ~ -_: -• -_ `~• L,, ~ ~-. ;_ ~ ~1 s; f .~;, ~.: - ~~e ~ i '~-- '*--+'-."'-"'- interim coastal zonz bou.Aary. The inland boundary _t. __,~,~ ,~~"`r ~~'~_;~ .`._.~ ~ !,.= '.-~ - _ --'a~~r-' ~,_~ 'r`- - vest of Cook Inle: in ttis portion of t:e Kenai _ _ „ _-~ -~.;- v <' ~_= r+;,., ,.,:. ',. a -`' a .-r :.' _ „~. ~. - .. .: } ,, ~ ., i ~,. y ~ ~ xp ,' ~~ t1.i ,_ . ~ _ •~ Pemrsula Borough inclines the lands an? eaters ~1 99~ rFip q-' ,'-^ -~ .'~'. y' ~} _ ~ l~~ '` ~•!-- vith:n: (1) the 1000-foot elevation conta~ south ,L v~ ~ r''" ~~. ~ ~ -„ ,-~~• ,~,:~ `~ ~~~ f 4, .-- f 1 -:° of the Chuitna River, 2 the 400-foot e.evation 3 ~ " ~ ;f--~ v~ ,r " - I ~ ~~C ~ x y t .- ,~ , ~,Irz ' J~'". t. ~.• . ~ ~ *~; { '~.,. ` contour north of the Chcitna River, and (3, other ~~ ~ 0 ~.~at'+' ~\4 ~ ~`' ~ ,. r •,~ ~ .l ., -~ 1 .~ ~;-'t areas as delinea`,xd or, this map. The inland ~ ., - -e.- - 1:I,,tl d~ .~. - I p-. ^~^ }~.-~' - _ ~J ~' boundary on ethesRenai Peninsulaline thisl portion aof • -,.. _ - ., r'..j ,, .~ t+ -. ~ ~ ... ~ ~ ;' ~~ - ~ ,,id ~ f .r '•~~~ the Y,enai P inn ula Borough inc ud s al axis nd s ::.; t -i ,.. ~ J~.. _ r ~ _ ~~«+~d r ~a -_t a eaters. _,~ ~ S~,#gr,~{pg~ngU~a ~~q~9ry ~. '. +' .bJw,:`,- r i - Matanuska-SUSitna 6orouot: The inland coas'_a: zone "q~ -, ... ., ~;a " ~ ~ '~ R,;, ~ ~ s r f )• _ r° ~ " .r~,~ ~'v, !-a _ boundary in this portion of the Matanuska-Susitna x ;:; - ~ *~.4 ,-,: *y....:. .' i.: v~La, - - _{ .ri~ to n~ ~ r .•{- t4 ~ f ..~?l ;:'i + ~ /~ '. Borough includes a?1 islands and the lards and + ~^; , waters within: jt$ r ,_ ~F ~;7 - ,, _:., ,. -. ~ -_.-q .._ _ ,J -rn~. q- 1 ~ •y, ~¢~' i ~ (1; the f00-foot elevatics contour ~5' [,.,x ~- #,~.:.~, • e .: ~ _.- ~ _. ~^ - •. ~-i~ ~.' ~ ..,, - „T. '•` - !. r,'_d' A ~'` %,;j•~'-;r ~ ° ~ ~` ~~ ";b,. near Beluga Lake: i2) the 100-foot elevatior acntour , 1,.~~ I ~ 'IE f"y'~ + `~. ~.~.. J _ _ ~ 1 - i• " ~ ~^,1s1 y(~ vt -r-~:i east of the Parks Highway: (3) the Skwentru and - ~. .F.- "'' ,. i~- - ! :+ ~' `` ~ y`.rr''-~ T ~ `"~~ - - - d:7' F ~- 1~' `~j~~.' ~ir'~~ $~ ~F-*' Rashvitna rivers and Talachulitna, Sheep, Little y ~ 'a' .l ~, ~! . -t .t,^.• ;, ,,,. : ~a .y _°_ ~,~"~ - _ ,,. ..: `~ - _, ~ ~ ~ ~ - 1. ,.. ' 4 F~(n t; ~. ,,•~.:• '~,,.~~~~~.. _"_ ~;'-? Nillov, and Willow creeks upstream to the 1~0-foot ~r-..,~-.-~- ~ ~', _ • ~- ~-,-~ ..r .~ ,y_ ~ elevation contour, inclining all lands and eaters ~. - ,. .? f : ~ e . ,., `, - ;` ~ ~ ~ ~ ~ •:~ -~ ~~4 " ;,~ y4 within the loo year floodplain or 20C feet on each '.., _ fi ., " k y~ - ¢ '.eJ''^'.-;nry'~ ~.+CIEH~ ~~ ~ ~ .~:' X.'`. ,.... .... y-, _--~ ,. ~', .---. ~ ~•~-+'.r~ ~~ ~~ ..~.i)- ~.-?t. _~_ ~' ~ .~.1 -. ;a side as measured frog. the ordinary high vatic mark, . • r~ ~~ ~ ~~ ~ -. !. ~ - x ~ z ~ .fir; 1F ~~M" ~r~ •- whichever is reate: includes all lands en~.m ssed _ ~ ~; .' ~....rr -. '{v..- ,= ~ -----c+' .~ `.. ~-' ~ . M. -: r. ... 'x,- ;.~i' - ~ - r JI a.~- "Y ~ )•. ;tc 5 a" . g (~ Fa 2„fiJ; , >y+` , ~ r ~,-. t~' ~ _ - ` ,, ~ ~- ??,` ~ *~ i •' 4 8 _ ~~•~- kn ~: by the extended Wundarv_ such as islands in a rl l _ L. q `~ ~;~ ~'1 ~ "'~`~, -- -~' ~,.d - ~ ~~`~" rte? ~>°.apd~p k'a 'h ~ "'~ - ~ ~ *'~-_1;: braided stream or river, even though they may be ~'k~ 1 ~,t~'T ~. ; -.,- ~ r'v~_` vi ~''~ 'v ~!. ~ .'' N '-"'A"'. __ ,.','>a^i ~ `~ '= ~"~'':;..rr r y;.--,'-5C Righe: in elevation than the 100-year flo>d-lair,) r i~ T, ,. _ ~~~, ~ c r~ a ~ ~ ! -' ~'' ~ .T- ~ ~ 4~~ "'~~,,, '~ ~ "{ -Tt _d.9r and (4) other areas vitA.in the borough h:.:ndary, °~ 1^';. '~' • ~` l l ~ ;t~C gp bU h"~ r vA, ~ `°w 2`_y = township lines, o: vest of the Parks Hiy`_raj, as ,~ ,1 .:} ~;'' ~ : ~'.., ~' ~ ~. ~B+BM 8k SCI~~~~~ -,~ - - - delineated on this map. Reference to 1:67,750 USGS __ - ~"-'~"~~"'"`' ' .' ~ - - ~~ r ~ ',. ~ ~r "~ ~ ~[j a ~~ ~~ '--- topographic maps, Federal Ea~ergency 14aragement . _ >~ < ~ -'$ ~'.. ^ j~ ~~~ ~ ~ : ^~ ~' ~CO. ~.y' ~ ,. 1 ~ 'r AM"R~~ Agency Flood Irs~rance Aate naps, cr other y F `-x °- .'. ? u~M .',~ :,~,. .# r r.. ` infornation vhicF. defines the 100-year f:codplain '~ ,... ~ .,.L,- ` ~. ,: _'d. ~ i~~"yf i'' ,..~j~J ~~:+: y y -iteria . mz be necessar tc determine if the above c. Y~~' ~ ~ - -. ~ • •' • ` ~t `•~ , 9` ap ly and whether the use or activity will lie `~ ~~ ~ ~ ? ++ ' within the coastal zone. ,; , - y~;qN ^,q ~ mj , 1•.. p F"`~.. `~~ a ~ •' <. ~y 1 h` ~ - `$~~ v, J ~ ~` Municiaality of A-.aaraoe: The inland coas'_' zone ~- «~ i?-Y` ¢, `.:_~, ". ~''~. ,. .. i ". ~': _ .r~ ~ '- ~r Y":~,~ v - " ~ ~$ -. s ~ „i ~ boundary in this portion of the Municipz'ay of ~r~-d~- -- , ~~".T ~ ~,. - ~~ ~ ~H Anchorage includes Fire Island and the lz .ds and `..1~; +~. '. ,.~~ °~~ .. ~ ~ ~ ^:.' .- ~ :,, `.... - ,... ,. - D+ 4 ~.-"1 ~~~ `~-_ _a're"~9j `4 ~`4 ~ inland, vmeasured barizontanly ezfromlthe lel _ent eof ,N ~ ',~ .t d ~~x ~'. <, - ~• J y:««~•' ' ,r..a; ~ /"/ 'eAj` •'~ ~• ~gt~ . ?~~ P • =..~f p •~ .... the 100-year coastal flood; (21 the ;~,-year 1 _ } fy,F_ . ~,+ 9p K i~~ : -p~$~.' I` floodplain or 200 feet from the center (vhich_ver is j} - -; ~ t ~ _ z, •- G~ 1 -- - _ ~~7~=' ` ~ - greater) of each ricer aM streams intersectei by the r '~ ~,; t ti.- .•,« -.- :`i. ,d~ %~~ 9e ~,:~ i--, ~•.~~ ~ 1,720-foot zone rr tc the 1000-foot elevation j~ r - e ~~~ -. -~;" y , ~ ". fryt s" p~~ ~ @~ ~~~r~,$:~x contour; and (3) tither areas as del ineated on this ~~ ~ ~ - r r _ - -~_ ~- ~ ~ ma Reference to 1:25,000 L'SGS to rapL,c mzps, ~~ ~.-._-T '_- ~ .. _. ~ ___+s.a.,,(1~:~, ~ .,,~ ,T-r-,-..ti- A,r., ,, F r ~ - ~Q(OUQh Federal Emergency Management Agency Flood Isirance 7 LS -~ .i ~ ~ ~~ . ~ _ I- ~ > ~ ~~~~ M+ ~ ~~,,~ ~ 11 4 ~+~ Rate maps, or L*s Mc^,azage Coastal lL~.agement 'r •'' ~ 1 "" -~ - f' = a-r r ` ~~ '+, ~ ~ ~ ~~ ~' r' ,- ( ~~ ~~~ '{~ ~ Pro ram ma be necessa to determine if Le above 5 ~ .+. j .l 9 Y ry ~`,.~iv - a4-- ~-f R r~ _ ~'~ - ~i~ 1 w t ~_ z '~4 K. J.T. / ~ ,~ /_" -~,~.,-~,, -~ r"/ ^q ,~ ~ y { a L -Y.~. FY' `'( ` ,~'"~,~f. ~.fY~ -h 3 y, '~ -t~ +^jt-`l ~ t.x -T1 ust '~'. Xeioa..~ °~~~1lEN#fENWSV[!.~/~ , .wl.. ' ~ \ ,W ..-~ ~.,__.~., ~_~.-- ~ - x:1'11 -.. - -. _.. . . I /_s ~-_ ---- JUNE 1988 6 0 6 1G 15 ZO ;5 MILES 6 0 5 10 15 EO YS KII OMETfmS Beaed on a USBB map Universal Trenarerea Mercet or Prolectlon ;' ~`.f,~ ~•~-_ criteria apply and whether the use or activity will _ ` :ie within the coastal zone. looN" bN r ~~. -'-~. . r~ .:,. r ..- i:. ,, _; .TG ~. ..~ ,:.~' ~ ?m,,rr a ~ y ..1 a swg ~~9Ygo- 3g i - - zL c°`ypr'°fa.~n.. .n _.r s y` I '. ~ *y ~ T ~# At ~ § 33ft.3 CfR Ch. f (T•1-8T Edition) Environa~entc TABLE 18-L(ST OF gppgp y ED INORGANIC TEST PROCEDURES--~pn~jnued _ T~Et pardmet~, I . artd rrtetltod Reference (method No. or pary~;. EPA 1979 me ~ ASTAI 11SG5 ~ ?'ammeter, W~ ~; 1 SL Tow •, rtg/L Dtgastion , 1 Ott,.er J AA deed aspration or : ~ 70. Ttm~m--Tote{ ~ ......... , ................ 255.1-... AA tt+rtace :......... 303A......._.......... foBoved by. ..._............ ....., r 2552 St p,'~syum-total a> tnp/L Dpeshpn I .... ._. ..............:.... _-..........-~....... .......... 304.......-:~__ ._....-........:. AA direct aspiratd ''~ r. faicwed. by. i AA direct as e p atior ......:......................_~ 25a 1 a zt. T-e.-Tow .... men, a-same........_ ............. .......... .......~.............. .......: t_ss3a-$4 ---::: 33 03 ~ , aa~d oy ' r- ._.......: ~ Pteotometriq or : _ . . . .........................: I __ ... .......... .. Cictorirt+etric (CObalhnitrete)..-_ . .......... 3228........ ~ Di42$-82 A _.. 200 7 • AA.tRrect aspra~ ~, AA htmace : - .. _-. 53. ResitAee-Total. mg/L• Gr avimeVic, 1~ 3 1t~-105°C ................_ °. 209A f ......--..-..... 3176.+6 - _ ..-~_. 72. Titanium-Tote! °. . 54. Residue--fdterabk - 13750-$d_ .. tolb.?~ py: , /L G m9 ravrtne- tB0 1 . trC, t10'C ........ 2098.... AA erect aspraA . 55. Rpnfig~~ (TSS), rttg/L• 602 ..... ..-.r ........: 1 1750-01.--.:....: AA furnace._-.. 73. Turbidity. NTU: Nl 7 G+avsnetric, 103-105'C Post rrasltirtp . ..':... ~....._---. ..-.....: 1-3765-84 74. Vanadium. Total a ~ ar 56. R,endue-settleable m /L V .__-_: fotto,red by: AA d .. g ottanet- , 160 5 no. (tsrdtoff Done) or 9ravimetric. .. ' ....... 209E...:....._ y : aect asPn6c AA firrrrtace S7. Resdue-VolaSte. rtg/L: Gravime. ~ i60.4 ....... Inc. 550°C .....____. ....... 2~9D . -..-._. 1Mttivefy cocyl8 . . ~ -Total a, rng/L: pigea~n ~ ~ ......_ .....-... ..:...:. 1~753..g1 _._.... Cobdmetric iCstlli 75. Zcsc-Total', mga totlo~ed by:. AA d"vect as irati bored ~, p on, or ................ ..._: 265 1 ... ~ Aartac ._... 303A . AA bract aspi.atx e ........... ......... .. .................:i 2$52........ 59. Po=~enenr4-Total', Reg/L Dyes- tior' b b ...,... .._ ........ ... _.._._..,. .:.... 304...........v: ................................. -......._-_...:-.( AA turnace.. -__ l wed by AA ' ~ ~ lndcrctivefy COt.tpfq d cect aspration, or ................ .: 267.1- ' 303A Cobrimetnc fUtlxi - 1 ....... M arraoe ...:........... .. ...... .........-. ~ ... incon).. _.. ..._.. ~ „~ ................. .~ 267-2......... 60. Sedermim-Total s, mg/L Digestion a I ..... 304 ............._F --- ..) .... ..:' : ; n f OtK+reG py; i .... ~ _. _.., j ..~ ttwds to A. Aa Asr+ace...... ............. !2702 j Geologecat Survey, z " ~~ t ......... 'Y=~'ey coupled Plasma, or.... I ..... 304...........°-t-................ ................ ..... Otficiat MethcrLds or deter > AA gaseous hydride .............._ ~ --~ -- ........... ....... :270.3 .......... 67. -Dissolved. mg/L 0.45 moron ~ i .._. .. 7 ..................._:...---s-....:........... .........._.- .. 200 .... 303E.........-.-~ D3659-84(A)...... I-3667-84 • sotubikze wspended' t - dtra=x totbwed by. Ca~:metric, Manual or . . 1 ._..... j I t i less ous cauLO~e~+ that thts :~ . ......... ._. 370 t.......... Aut~^ated Mo ~ ( tybdosdecate ._. 425C..........._f D859-80(8) 1 17 employed, K es ~ o , r.. l~t"r~Y coupled plasm I ......... - 00-6a..---~-_.! I situat,ec<, the com l a.......... 62. Sower-TOtaIY• mg/L: Degestior a I - ... ........... -2 ....700-84 _.° .... .. 200 7 nmg ar leehn~.~e rnd~trvBFy toliawe;! M; ...._...... . . m rcury se rn m, '„ AA CveM as era P lion ..................... ~ 272 1 ~ e spec ~ ertstructeon _ . . .......... ~+ mace .. .................... I ?.722........... Cca~v,rnetnc(Diihizorte) or ... 303 A or B I {- 3720-64 .... Ogg s P .. 304 ....... ~ 33. 37.° ........i :_ _-.-._... NOTE I} the be used. _... i y , .........._ Ir~,vety coupled plasma.......... I - ............ 63. Sayur,-Total ~, mg/L' Digesteon a i --• ........... follower p ... ...... .._............_..._ _...._.__. s 2008 ee ....... • .......... .. .. - b D pq~ y. ~ e O ';, AA dnect aspiration ............. I ........... 273.1 ........... Inoztivel ~ .. 303A the following Criiena'. y coupled plasma, or... _. I Fia:-e PhotomeMc - .-._ ..:.:................... 1-3735-64 07 s .. , 33.1 c~ a M .................. ....... .._ ............. 64. Sperihc conductance. micromhos/ 120 t ............. cm as 25'C. Wheatstone brid e I .. .7.• 3256 (200 .~ 205............... 07125-62{A) I 7 ~ ess d d. isbk one Ipuid. g 65. SuMa' fas SO,), mglL: ......I -S 80 84 .. : ? 33.002. • The tedl tetct e• Autorated colorimetric, ~ (banum 375 1 I ' Anayss of Wa?ar and;, s Manuai distd?aizon . ........... Csu aniiate) ....... i ~ - ... ..................... Yhis preertswrsa ds ~ ..... G a .eMC. or ........... ' .... ! 375 ........ ..' A o' mm nee, Aut ,..-....... TW-..+-etric. ........... .......... 375 4 6 .i 426 A or B ~ Q576-62(A)......L......... 3 ~ ~ 3 1 ~ uto na~ II T h . ..-......... ti. Sut ~ .as S) mglL T2_ Etc (iodine ; or . 24. ...... ' !?St6-82(6)......... _ I .....' 426C.Y9 ~ droved Sedime s' , USGS " i i ....._._ ............. 376 t -............ Cot~vic (methylene blue) ...... 3762 ~ 427D _._......._. .............i t-3840 64 ao American Na? NY i *$,. New S ;, ........ ............ 67. Suter (as SO,), mg/L Trtremetric i 377 7 ._... (iodvee~a,e>. ...... 2 26A ~ 427C I ~ .... .............................. 426A . D1339-84(C) •: ~ e~ tetl A _ the ~sbo°-e ~ (metwte.~ blue). tnglL: Colonmetnc j 425.1.--....... . i ............ .. 5126 .E 02330-82(A) ~ he uuse o Carbenacecau .,t " - 69. Tempeaa:re 'C : Th ~' I ...... . ..... ~ ota BOD. The , . emrometric....... 770.1_.......... 212 Parameter. A d . Note 3t. ---- .................................. -- procedure for r report data. using thB I ~, 256 - ~_~_ } } ) k ~~ Y ~. 11 '~ ~- ~ J. '~:, . v t"~~ y "~"" .~., t Y~,:'~ .,~, i f .~. -, ::+,; ' 'i`;~a ~l ~, ' ~~ ~ ~.~ "- ^-z ik ~ , R`. ,, , .;. , .,T ~` ' ~ # ~~ .' ~-.~~, (,,, ~' ~~ . § 146.4 SD WA means the Safe Drinking Water Act (Pub. L. 95-523, as amended by Pub. L. 95-190, 42 U.S.C. 300(f) et seq. ). Site means the land or water area where any facility or activity is phys- ically located or conducted, including adjacent land used in connection with the facility or activity. Sole or princip¢I source ¢cquifer means an aquifer which has been des- ignated by the Administrator pursuant to section 1424 (a) or (e) of the SDWA. .State Director means the chief ad- ministratfve officer of any State or interstate agency operating an ap- proved program, or the delegated rep- resentative of the State Director. If re- sponsibility is divided among two or more State or interstate agencies, "State Director" means the chief ad- niinistrative officer of the State or interstate agency authorized to per- form the particular procedure or func- tion to v~-hich reference is made. Stratum (.plural strata) means a .single sedimentary bed or layer, re- gardless of thickness, that consists of generally the same kind of rock mate- rial. Subsidence means the lowering of the natural land surface in response to: Earth movements; lowering of fluid pressure; removal of underlying sup- porting material by mining or solution of .solids, either artificially or .from natural causes; compaction due to wet- ting <Hydrocompaction); oxidation of organic matter ir. soils; or added load on the land surface. Surface casing means the first string of well casing to be installed in the well. Tot¢Z dissolved solids ("TDS") means the total dissolved (filterable) solids as determined by .use of the method specified in 40 CFR Part 136. UIC means the Underground Injec- tion Control program under Part C of the Safe Drinking Water Act, includ- ing an "approved program." Underground injection means a "well injection." Underground source of drinking water (USDW) means an aquifer or its portion: (1)(i) Which supplies any public water system; or 40 CFR Ch. { (T-i-87 Edition; ~~- ! ~mrironmeM (ii) Which contains a sufficien~ ` (1) It is m' quantity of ground `water to supp;~ ct dermal ene public wa+_er system; and i ~rnonstrate' (A) Currently supplies drinking part of a pC water fer human eonsumptior,; or yi or III opt <B) Contains fewer than 10,000 mg; l ~r hydrocazl~ total dissolved solids; and quantity an~< t2) Which is not an exempted aqua. be commerci; ' fer. (2) It is si ~ USDW means "underground source tion Which of drinking water." for drinking. Well means a bored, drilled or driver. 'ra.lly or Lech (3) It is .shaft, or a dug hole, whose .depth is 'pould be greater than the largest surface ai. cally'impr ' mension. fit for h Well injection means the subsurface (4} It is 1 emplacement of fluids through a minim are bored, .drilled or driven well; or Gatastrophi through a dug well, where the depth (~} The to of the dug well is greater than the of the gro largest surface dimension. wad less. th Well plug means a' watertight and reasonably gastight seal installed In a borehole or water syste well to prevent movement of fluids. Well stimul¢tion means several proc- tClean water Clean .Air esses used to clean the well bore, en• ~ ~ Recovery Ac large channels, and increase pore gg27, 6974) Space in the interval to be injected ! E45FR 4250(! thus making it possible for a•astetivatcr i 47 b'R, 4998. to move more readily irto the forma- ~ 1,19837 tion, and includes (1) surging, (Z) jet- ting, t3) blasting, (4) acidizing, (5) h~~ ~ ~ IA6.5 Cias s draulic fracturing. ~ Injection I ~ Welt monitoring meartc the measure lows: ~ meat, by on-site instruments or labo i~ (a) Class I ~ ratory methods, of the quality o:` ¢ tors of has ' water in a well. ~ operators o meat facil (Clean Water Act, Sa.'e Dr::kng A'ater Act waste ben Clean Air Act, Resource CGnservation ar"~ tlon COnta .Recovery Act: 42 L.S.C. &905, 6912, 6P25 (`%a) IT)ile O 6927, 6974) £ ' ground sots [45 FR 42500, June 24, 1980, as amended a~ <2) Othe 46 FR 43161, Aug. 27, 1981; 47 FR 9998, Ft~b ~ disposal w 3, 1982; 48 FR 14293, Apr. i, 19837 neath the § 146.4 Criteria for exempted aquifers. ~ {{ twining, wi ] Fell bore,. An aquifer or a portion thereof k . drinking w which meets the criteria for an "un ' ~ (b> C1as derground source of drinking water f luids: in § 146.3 may be determined under 4'~~ t ( CFR 144.8 to be an "e~:empted aq~.:} in connect fer" if it meets the follo~x:ng criteria: ~ natural g (a) It does not currently serve as a commingle source of drinking water; and gas plants (b> It cannot now and will not in the of product future serve as a source of drinking waters ar water because: waste at t 662 { 1 92 PHYSICAL EXAMINATION (200) RosEN, A.A.,1970. Report of research committee STAHL, R'.H., ed. 1973. Compilation of Odor and on tastes and odors. 1. Amer. Water Works Taste Threshold i'siues Data. Amer.. Soc. Aas 62:59. Testing ~ Materials Data Ser. DS 48, Phi1_ Sv~ET, I.H. & S. SEGwLL. 1971. Detecting taste adelphia, Pa. and odor in drinking water. J. Amer. Water A~xtCAly SOCIETY POt TESTnvG why MwTE- Workr Ass. 63:605. Itlwls. 1473. Aaatal Book of ASTM Stand- GELDw1tD, F.A. 1972. The Httmaa Senses. John ards_ Fart 23. D-1292-65, ASTM, Wiley & Sons, New York, N.Y. Philadelphia, Pa. 208 OXYGEN TRANSFER* 'A standard for the measurement of oxygen transfer in clean water has been adoptcd by the American Society of Civil Engineers, 345 East 47th Street, New Yorlt, N.Y. 209 SQLIDS* The terms "solids," "suspended," and "dissolved," as used herein, replace the terms "residue," "nonfiltrable," and "fil- trable" of the previous edition. Solids refer to matter suspended or dissolved in water or wastewater. Solids may affect water or effiuent quality adversely in a number of ways. Waters with high dissolved solids generally are of inferior palatability and may induce an unfavorable physiological reaction in the transient consumer. For these reasons, a limit of 500 mg dissolved solids/L is desirable for drinking waters. Highly mineralized waters also are unsuit- able for many industrial applications. Waters high in suspended solids. may be esthetically unsatisfactory for such pur- poses as bathing. Solids analyses are im- portant in the control of biological and physical wastewater treatment processes and for assessing compliance with regula- tory agency wastewater e$iuent limitations. 1. Definitions "Total solids" is the term applied to the material residue left in the vessel after evap- 'Approved by Standard Methods Committee, 1985. .oration of a :sample and its .subsequent drying in an oven at a defined temperature. Total solids includes "total suspended sol- ids," the portion of umtal solids retained by a filter, and "total dissolved solids," the portion that .passes through the filter. .The type of filter holder, the pore size, porosity, area, and thickness of the filter and the physical nature, particle size, and amount of material deposited on the filter are the principal factors affecting separa- tion of suspended. fznm dissolved solids. "Fixed solids" is the term applied to the residue of total, stis~ended, or dissolved solids after ignition for a specified time at a specified temperature. The weight loss on ignition is called "volatile solids." Deter- minations of fined and volatile solids do not distinguish precisely between inorganic and organic matter because the loss on ig- nition is not confined to organic matter. It includes losses due to decomposition or volatilization of sotae mineral salts. Better characterization of e>rganic matter can be made by such tests as total organic carbon (Section 505), BOD :(Section 50~, and COD (Section 508). "Settleable solids" its the term applied to the material settling out of suspension SOLIDS/Total within a defined period, It may include Eoahng material, depending on the tech- nique (209E.3b). 2. Sources of Error and Variability The temperature at which the residue is deed has an important bearing on results, because weight losses due to volatilization of organic matter, mechanically occluded Rater, water of crystallization, and gases from heat-induced .chemical decomposi- bon, as well as weight gains due to oxi- dation, depend on temperature and time of heating. Residues dried at 103 to 105°C may re- tain not only .water of crystallization but >uso some mechanically occluded water. Loss of COz will result in conversion of carbonate to carbonate. Loss of organic matter by volatilization usually will be very fit. Because removal of occluded water a Il1at'ginal at this temperature, attainment ~ constant weight may be very slow. Residues dried at 180 t 2°C will lose +~most all mechanically occluded water. Mme water of crystallization may remain, ~~Y if sulfates are present. Organic fitter maY be lost by volatilization, but e0t completely destroyed. boss of COZ re- s+ilts from conversion of bicarbonates to donates and carbonates maybe decom- ~ partially to oxides or basic salts. Mme chloride and nitrate salts may be lost. ~ Beneral, evaporating and drying water ~P1es at 180°C yields values for dissolved buds closer ~ those obtained through 93 summation of individually determined mineral species than the dissolved solids values secured through drying at the tower temperature. Results for residues high in oil ar grease may be questionable because of the diffi- culty of drying to constant weight in a rea- sonable time. Analyses performed for some special purposes may demand deviation from the stated procedures to include an unusual constituent with the measured solids. Whenever such variations of technique are introduced,. record and present them with the results. 3. Sample Handling and Preservation Use resistant-glass or plastic bottles, pro- vided that the material in suspension does not adhere to container walls, Begs an~_ ysis as soon as possible because of the im- practicality of preserving the sample. Refrigerate sample at 4°C up to analysis to minimize microbiological decomposition of solids. 4. Selection of Method Methods A through E are suitable for the determination of solids in potable, sur- face, and saline waters, as well as domestic and industrial wastewaters in the range up to 20 000 mg/L. Method F is suitable for the determi- nation of solids in sediments,. as well as solid and semisolid materials produced during water and wastewater treatment. 209 A. Totat Solids Dried at 103-105°C ~ t• ~enerai Discussion 4 P-tinciple.• A well-mixed sample is ~+Porated in a weighed dish and dried to constant weight in an oven at 103 to IOSC. The increase in weight over that of the empty dish represents the total solids. The results may not represent the weight of ' r ,-j iii ~; . 1 ~+ t ~ ~ i f P 1 ((~~ ~' I {F ' ~ a i. ~ i E, ~. 'r ~ ! !t t t ~ !; 'i11 ~ ~ I i; ~~ ii '~ ~, ;. 1~ ~ '; i ,; 3 ~~ ~~ i Ii , ` i ?t i I~ :~ `J '~ ~' ii '~ ._ , SOLIDS /Total Dissolved 95 209 B. Total Disso!:~ed Solids Dried at 180°C 1. General Discussion a Principte: A well-mixed sample is fil- tered through a standazd glass fiber filter, and the filtrate is evaporated to dryness in a weighed dish and dried to constant weight at i 80°C. The increase u- dish weight represenu the total dissolved solids. The results may not agree with the the- oretical value for solids calculated from chemical analysis of sample (see above). Approximate methods for correlating chemical analysis with dissolved solids are available.' The filtrate from the total sus- pended solids determination (Section 209C) may be used for determination of total dissolved solids. b. Interjerenres Highly mineralized waters with a considerable calcium, mag- nesium, chloride, and/or sulfate content may be hygroscopic and wire prolonged ~Ying> proper desiccation, and rapid weighing, Samples high in bicarbonate re- quire careful and possibly prolonged drying at 180°C to insure complete conversion of bicarbonate to carbonate. Because exces- sive residue in the dish mad form awater- uapping crust, limit sample to ao more than 200 mg residue. 2• Apparatus Apparatus listed in 2O9A.2a-d is re- 9u~red, and in addition: a Glass-fiber frlter disks' without or- >~nic binder. b. Filtration apparatus C-ne of the fol- lo~ng, suitable for filter disk selected: 1) Membrane filter fanner: °~~° Brsde 934AH; Gelman npe A/E; M~1lipore ~ ~~; or equivalrnt. Available in diametea of 2.2 ~ b 4.7 Mp. 2) Gooch crucible, 2S-mL to 40-mL ca- pacity, with Gooch crucible adapter. 3) Filtration apparatus with reservoir and coarse (40- to 60-µm) fritted disk as filter support. c. Suction (task, of sufficient capacity for sample size selected. d. Drying oven, for operation at 180 ± 2°C. 3. Procedure a. Preparation of glass fiber filter disk.• Insert disk with wrinkled side up into fil- tration apparatus. Apple vacuum and wash disk with three successive 20-mL volumes of distilled water. Continue suction to re- move all traces of water. Discard washings. b. Preparation of evaporating dish: If vol- atile solids are to be measured, ignite cleaned evaporating dish at SSO ± SO°C for 1 h in a muffle furnace. If only total dissolved solids are to be measured, heat clean dish to 180 ± 2°C for 1 h in an oven. Store in desiccator until needed. Weigh im- mediately before use. c. Selection of filter and sample sizes: Choose sample volume to yield between 2.5 and 200 mg dried residue. If more than 10 min are required to complete filtration, in- crease filter size or decrease sample volume but do not produce less than 2.5 mg resi- due. d. Sample analysis• Filter measured vol- ume of well-mixed sample through glass- fiber filter, wash azth three successive 10- mL volumes of distilled water, allowing complete drainage between washings, and continue suction for about 3 min after fil- tration is complete. Transfer filtrate to a weighed evaporating dish and evaporate to dryness on a steam bath. If filtrate volume exceeds dish capacity add successive por- ~:, I ~~ ~' l~ ` is f' ~` g !l 1~ i j ~~ i ~ ~; ; iI ~' ~ t. ~~ {, i ~ i a i f` `• ;~ ~f>` ,,' ~~ ;: ~~! ~l; S`~ s ss tions to the same dish after evaporation. Dry for at least 1 h in an oven at 180 2°C> cool in a desiccator to balance tem- perature, and weigh. Repeat drying cycle of drying, cooling, desiccating, and weigh- ~B until a constant weight is obtained or until weight loss is less than 4% of previous weight or 0.5 mg, whichever is less. 4. Calculation mg tots! dissolved solids/L _ (a - a) x loon sample volume, mL PHYSICAL EXAMINATION (2p~} where: a .! =weight of dried residue + dish, mg, and c` B =weight of dish, mg. ~, 5. Precision and Accuracy Single-laboratory analyses of 77 samples of a known of 293 mg/L prepared; as ~, lution B (Section 1048) were made.. with a standard deviation of differences of 21.20 mg/L. 209 C. Total Suspended Solids Dried at 103-~ 05°C 1. General Discussion a P-'inciple.• A well-mixed sample is fil- tered through a weighed standard glass- fiber filter and the residue retained on the filter is dried to a constant weight at 103 to 105°C. The increase in weight of the filter represents the total suspended solids. If the suspended material clogs the filter and pro- longs filtration, the difference between the total solids and the total dissolved solids may provide an estimate of the total sus- pended solids. b. Interferences: Exclude large floating particles or submerged agglomerates of nonhomogeneous materials from the sam- ple if it is determined that their inclusion is not desired in the fins] result.- Because excessive residue on the filter may form a water-entrapping crust, limit the sample size to that yielding no more than 200 mg residue. For samples high in dissolved sol- ids thoroughly wash the filter to ensure removal of the dissolved material. Pro- longed filtration times resulting from filter clogging may produce high results owing to excessive solids capture on the clogged filter. 2; Apparatus Apparatus listed in Sections 209A.2 and 2098.2 is required, except for evaporating dishes, steam bath, and 180°C drying oven, In addition: Planchet, • aluminum or stainless steel, 65-mm diam. 3. Procedure a Preparation of glass-fiber frlter disk' Insert disk with wrinkled side up in filtra- tion apparatus. Apply vacuum and wash disk with three successive 20-mL portions of distilled water. Continue suction to re- move all traces of water, and discard wash- ings. Remove filter from filtration apparatus and transfer to an aluminum or stainless steel planchet as a su ~ ternatively remove crucible and filptoertcom- bination if a Gooch crucible is used. Dry )' in an oven at 103 to 105°C for 1 h. If volatile solids are to be measured, ignite at SSO ± 50°C for 1S min in a mu®e furnace. Cool in desiccator to balance temperature and 'Available from New England Nuclear, Boston, Mass., or equivalent. rTl X 2 Z O cfl By log analysis the porosity of this sand nas been determined to be 18~. Based on injecting 75 ~iwPD into t^is G-i sand equivalent, over a period of 15 years of continuous daily injection, at the 75 bwpo rate, the radius of invasion of the injected fi.:io ~~ili be on~y 275'. CA±CULATON - RADIUS 0~ INVASION: R = Rabius of = Volume injected, bbls inv invasion (5.141 j '~ H * porosity where: H = injection interval, ft R = 410.525 * 5.515 inv (3.i41i (54) (G.lc~) R = 275 `t. in 15 years ~ 75 BW°D. inv Zone f4 3,020' - 3,046' Tnis zone has a series of impervious siltstcnes and coals aowe and oeiow it. It was not tested in the c=igina_ C-1 well and it does not correlate to any gas productive sands in well C-1. Zone ~`5 & ,:5 2,950' - 2.950' i 2,850' - 2,900' A portion of both these zones ~~.:ere tested in C-1 ariti~ no cas or water to surface. Curing the test the h~e=_ ~~~as _r.-?r:~ic~'~aily swabbed i-,ahout resUlting in any gas flow. Meitner of tnese sands ,nave co~,~~nercial gas potential in we.~1 C-1. Zone ~~7 2,502' - 2,596' Tnis zone was not shot in the ~=i_~_nal testi~o of .this well.. a nas duet 100' of isolating siltstones and coa_ direct_•:~ above and below. No correlative sands bearing gas have oeen .cund_n well ~-_.