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Home My WebLink AboutDIO 003 ) ) 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)1:0 OD3 Order File Identifier Organizing (done) D Two-sided 1III1II111111111111 o Rescan Needed 1111111111111111111 RESCAN DIGITAL DATA OVERSIZED (Scannable) D Maps: o Other Items Scannable by a Large Scanner o Color Items: o Greyscale Items: D Diskettes, No. D Other, No/Type: o Poor Quality Originals: o Other: OVERSIZED (Non-Scannable) ~9S of various kinds: NOTES: Scanning Preparation x 30 = + o Other:: I J Date: G' , 0'5: 151 ~ 1111111111111111111 \t\1~ = T0TAL PAGES 'i? c2. (Count cloe~ no': include cover sheet) l/1/l,D.' Date: ()I I ~ /5/ IV f 1111111111111111111 I Date?'? J (;ð- /5/ BY: Helen ~ Project Proofing BY: Helen~ BY: HeleC Maria J Production Scanning Stage 1 Page Count from Scanned File: C;S 3 (Count does include cover sheet) Stage 1 Page Count Matches Number in Scanning Preparation: Heier<': M'aria ) If NO in stage 1, page(s) discrepancies were found: I ./ Y~S Date: q J os- NO ~111112 /5/ r f , BY: YES NO BY: Helen Maria Date: /5/ 1111II1111111 Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Helen Maria Date: /5/ Comments about this file: Quality Checked 11111111111I1111111 8/24/2004 Orders File Cover Page.doc • Disposal Injection Order 3 Beluga River Gas Field 1. July 25, 1985 Chevron's withdraw ltr of application 2. July 25, 1985 Chevron's Application Package Submittal BRWD-1 Well 3. February 6, 1987 Arco Alaska's Application for Disposal Injection Order 4. February 23, 1987 Notice of Hearing and Affidavit of Publication 5. September 27, 2004 Public Notice to Amend Underground Injection Orders to Incorporate Consistent Language Addressing the Mechanical Integrity of Wells 6. August 15, 2005 ConocoPhillips (Alaska), Inc. Request for Administrative Approval for Disposal of Cement Rinsate and approved non-hazardous fluids in BRWD-1 7. September 8, 2406 Request for Administrative Approval DIO 3-002 8. June 10, 2008 ConocoPhillips Alaska, Inc. request for disposal of unused completion fluids 9. June 17, 2008 CPA memorandum re: Lightning 1800 usage 10. July 13, 2009 E-mail regarding unused completion fluids 11. June 3, 2010 E-mail re: Injection Question Disposal Injection Order 3 D. r .0. f:t ì R. ((\ - 'Gxh~{';f-r - -r / .)..,. tv' I i ~s - 'Bel ~ R..;" ,.". )..,....... l Ó+""~V"ff' ~) - "fy~;-"r Jf~'-"t;jk;.../(/ c. C(;tJI f ;ee-f-;."", ,- I E -l:;:' d_+,cI. .. M~ (&f?'f S to t W,U À (t' - (,1... (v"''"'' 'B RlJ ß ~~ 0... , ,f~.,. V \ (. (J r f"r\o-tt:""', ( d.. A:f-,., " f l{ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: THE REQUEST OF ARCO ) ALASKA, INC. to dispose) of non-hazardous gas ) field liquid wastes by ) underground injection ) in well BR WD-l, Beluga) River Gas Field ) Disposal Injection Order No. 3 Beluga River Gas Field Harch 11, 1987 IT APPEARING THAT: 1. ARCO Alaska, Inc. (ARCO) requested on February 6, 1987 the Alaska Oil and Gas Conservation Commission to authorize the continued use of BR WD-l as a disposal well in the Beluga River Gas Field. ARCO will inject non-hazardous waste fluids generated by normal drilling and production operations. 2. Notice of an opportunity for a public hearing on March 26, 1987 was published in the Anchorage Daily News on February 23, 1987. 3. No protest or request for a public hearing was timely filed. Accordingly, the Commission will, in its discretion, issue an order without a public hearing. FINDINGS: 1. ARCO, as operator of the Beluga River Gas Field, ! currently is authorized by EPA permit AK-2DOOOl-t, issued in conformance with the Safe Drinking Water Act as amended 42 USC 300f et ~, to utilize well BR WD-l for injection of non-hazaraous liquid wastes into the Sterling formation below the measured depth of 3060 feet. Disposal Injectil11 Order No. 3 March 11, 1987 Page 2 2. All aquifers below 3030 feet within a one-mile radius around the well bore of well BR WD-l Beluga River Gas Field, are exempted in E.P.A. Permit AK-2DOOOl-~for Class II injection activities. J 3. Permeable strata, that will accept injected fluids, are, present below 3060 feet in well BR WD-l. 4. A series of confining strata are present above 3060 feet in well BR WD-l that will prevent upward movement of the injected waste fluids into non-exempt aquifers. 5. The strata into which fluids are to be injected will accept fluids at injection pressures which are less than the fracture pressure of the injection strata and their confining formations. 6. To ensure that waste fluids are confined to injection strata, the mechanical integrity of BR WD-l will be demonstrated periodically and monitored routinely for disclosure of possible abnormalities in operating conditions. 7. BR WD-l is constructed and has been tested in con- formance with the requirements of 20 AAC 25.412. CONCLUSIONS: The geologic sequence present at the well site and maintenance of the mechanical integrity of well BR WD-l will prevent movement of injected waste fluids into non-exempt aquifers. NOW, THEREFORE, IT IS ORDERED THAT: Non-hazardous oil field waste fluids may be injected in conformance with Alaska Administrative Code Title 20, Chapter 25, for the purpose of disposal into the Sterling formation below the measured depth of 3060 feet in well BR WD-l, Sec. 13, TI3N, RI0W, S.M., Beluga River Gas Field. t Do 1 I ° 0 ~ 0 d N 3 ~sposa nJ ect1.01i r er o. March 11, 1987 Page 3 DONE at Anchorage, Alaska and dated March 11, 1987. cQl~ma~ Alaska Oil and Gas Conservation Commission /' rOO) ,.,...-/ r;.. 1,/" _ -....j L/i, /", £! 1~·Î-1.-~ '~/r<~~~Þl Lonnie C. Smith, Commissioner Alaska Oil and Gas Conservation Commission W.tI W. W. Barnwell, Commissioner Alaska Oil and Gas Conservation Commission ) r'-\ r~\,\ Ii L ~\ Lr"lJ ALASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRA TIVE APPROVAL NO. DIO 3.001 FRANK H. MURKOWSKI, GOVERNOR Re: Request for Disposal of Cement Rinsate and Approved Non-Hazardous Fluids in Beluga River Unit Well BRWD-1 Ms. Shannon Donnelly Environmental Coordinator ConocoPhillips Alaska Inc. P.O. Box 66 Kenai, AK 99611 Dear Ms. Donnelly: By letter dated August 15, 2005 ConocoPhillips Alaska Inc., ("ConocoPhillips") requested authorization to dispose of non-hazardous wastes, including wastes returned from downhole and small amounts of unused fluids directly associated with well operations into Beluga River Unit Well BRWD-l. The well is a dedicated Class II disposal well supporting production operations at the Beluga River gas field located on the west side of Cook Inlet. The fluids identified by ConocoPhillips would be generated during well maintenance and drilling activities include nonhazardous wastes that have not been down hole, and include excess cement slurry, cement rinsate, and small quantities of excess fluids associated with the proposed activities such as completions, well workover, testing and drilling. Provided with ConocoPhiIlips' request were test results of cement rinsate, and the Material Safety Data Sheet (MSDS) for each proposed fluid to be injected. Data provided by ConocoPhillips demonstrates that the fluids proposed for injection do not exhibit any hazardous characteristics as defined in 40 CFR 261. Additional correspondence dated August 22, 2005 notes that fluid wastes generated during well work will be minimized and fluids will be reused where possible. ConocoPhillips provided the results of feasibility reviews that indicate the cost of offsite management of fluids would be prohibitive and transport represents an additional risk that is unnecessary for environmental protection. The fluids noted in ConocoPhillips' August 15, 2005 request are generated in primary field operations intrinsic to development activities intended to improve the ultimate recovery of oil and natural gas from the reservoir, to repair well integrity, or properly abandon those development wells that have no future utility. These fluids are consistent in composition with materials already authorized under Disposal Injection Order No.3. The AOGCC also agrees with the assessment that underground injection into this Class II disposal well represents the environmentally preferable option for managing non-hazardous drilling and well service fluid at the Beluga River field. Our records indicate that Beluga River Well BR WD-I passed a Commission-witnessed mechanical integrity test on June 27, 2005, as required in 20 AAC 25.252(d). Evidence available to the Commission Ms. Shannon Donnelly August 23,2005 Page 2 of2 ') ) indicates well fluids are confined to the intended injection zone. The proposed fluids pose no additional risk of fluid movement into non-exempt aquifers.l The Commission has determined that the fluids, as represented in ConocoPhillips' request for administrative approval, namely excess cement slurry, cement rinsate, KCL water, CaCh brine, and excess water based mud are suitable for disposal in Beluga River BR WD-l as proposed. Approval applies only to this specific request and is not intended to provide for a blanket authorization to inject these or similar non-hazardous fluids down other Class II disposal wells. DAT , ayÇ:age, Alaska and dated August 23, ~05. ~!J - /~/ ~ Joht ~ ¿an Dani:;~::;~/ Cc~otmVfm:SS¿1.00neerrst~ \..9<ai~ Commissioner ~~~ BY ORDER OF THE COMMISSION I All aquifers below 3,030 feet within a one-mile radius around BRWD-I are exempted (EPA Permit AK-2DOOOI-l) for Class 2 injection activities )103.001 Beluga River Unit WeB BRWD-l ) ') Subject: DIO 3.001 Beluga River Unit Well BRWD-l From: Jody Colombie <jody_colombie@admin.state.ak.us> Date: Tue, 23 Aug 2005 08:49: 18 -0800 To: undisclosed-recipients:; >103.001 Beluga River Unit Well BRWD-l ) ) I, ,IIContent- Type: application/pdf DI03.1.pdf, ' , . , Content-EncodIng: base64 20f2 8/23/2005 8:49 AM Citgo Petroleum Corporation PO Box 3758 Tulsa, OK 74136 Mona Dickens Tesoro Refining and Marketing Co. Supply & Distribution 300 Concord Plaza Drive San Antonio, TX 78216 Jerry Hodgden Hodgden Oil Company 408 18th Street Golden, CO 80401-2433 Kay Munger Munger Oil Information Service, Inc PO Box 45738 Los Angeles, CA 90045-0738 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Ciri Land Department PO Box 93330 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Darwin Waldsmith PO Box 39309 Ninilchick, AK 99639 Penny Vadla 399 West Riverview Avenue Soldotna, AK 99669-7714 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 ) Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 Robert Gravely 7681 South Kit Carson Drive Littleton, CO 80122 Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 Samuel Van Vactor Economic Insight Inc. 3004 SW First Ave. Portland, OR 97201 Schlumberger Drilling and Measurements 2525 Gambell Street #400 Anchorage, AK 99503 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 James Gibbs PO Box 1597 Soldotna, AK 99669 Richard Wagner PO Box 60868 Fairbanks, AK 99706 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 ') David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 John Levorsen 200 North 3rd Street, #1202 Boise, ID 83702 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle, WA 98119-3960 David Cusato 200 West 34th PMB 411 Anchorage, AK 99503 Ivan Gillian 9649 Musket Bell Cr.#5 Anchorage, AK 99507 Jack Hakkila PO Box 190083 Anchorage, AK 99519 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 Cliff Burglin PO Box 70131 Fairbanks, AK 99707 North Slope Borough PO Box 69 Barrow, AK 99723 IJ1 t:?1 / ¿: c:?é- '( fR¡)5 . ~1f~1fŒ mJ~ ~~~~æ~ . AItASIiA OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL NO. DIO 3.002 Ms. Marta Czarnezki Environmental Coordinator ConocoPhillips P.O. Box 66 Kenai, Alaska 99611 Re: Disposal Injection of Canola Oil Beluga River Unit Dear Ms. Czarnezki: Disposal Injection Order ("DIO") 3 approved the injection of Class II waste fluids into Beluga River Unit Well BRWD-l. There has been one administrative approval granted since DIO 3 was issued clarifying fluids eligible for injection into this Class II disposal well. On September 8, 2006 you requested approval to dispose of canola oil and potentially small quantities of diesel in Well BR WD-l. Your request is approved. ConocoPhillips has scheduled a well cleanout for mid-September using concentric coil tubing ("CCT") technology. The equipment includes an inner coil tubing string connected to a down hole jet pump used to force fluid up through the CCT annulus to surface production equipment. Canola oil will be used as a lubricant to assist running the concentric coil tubing in the well, being applied to the coil tubing within a spill containment area. The addition of a small amount of diesel may be required to maintain a low level viscosity and prevent congealing of the canola oil during the cleanout. ConocoPhillips estimates I barrel of canola oil and up to 1 barrel of diesel will be required for the cleanout. Similar work was performed on the North Cook Inlet Tyonek Platform, and canola oil was authorized for injection in a Class II disposal well by DIO 17.005. Confinement of fluids to the intended injection zone in Well BRWD-l has been demonstrated by historical injection performance data available in Commission records. Well integrity has been demonstrated by successful mechanical integrity testing (most recent June 27, 2005) and monitoring the well's annular pressures. The disposal of canola oil (vegetable oil) and potentially up to 1 barrel of diesel will have no detrimental effect on the confinement of fluids. Well integrity, correlative rights, and waste will not occur from canola oil and diesel disposal into Well BR WD-l. Done at Anchorage, Alaska and dated September 11,2006. ~¿~ Commissioner Daniel T. Seamount Commissioner Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 John Levorsen 200 North 3rd Street, #1202 Boise, ID 83702 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Ciri Land Department PO Box 93330 Anchorage, AK 99503 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 James Gibbs PO Box 1597 Soldotna, AK 99669 Richard Wagner PO Box 60868 Fairbanks, AK 99706 North Slope Borough PO Box 69 Barrow, AK 99723 . David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 Jerry Hodgden Hodgden Oil Company 408 18th Street Golden, CO 80401-2433 Kay Munger Munger Oil Information Service, Inc PO Box 45738 Los Angeles, CA 90045-0738 Schlumberger Drilling and Measurements 2525 Gambell Street #400 Anchorage, AK 99503 Ivan Gillian 9649 Musket Bell Cr.#5 Anchorage, AK 99507 Jack Hakkila PO Box 190083 Anchorage, AK 99519 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 Cliff Burglin PO Box 70131 Fairbanks, AK 99707 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 . Mona Dickens Tesoro Refining and Marketing Co. Supply & Distribution 300 Concord Plaza Drive San Antonio, TX 78216 Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle, W A 98119-3960 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Darwin Waldsmith PO Box 39309 Ninilchick, AK 99639 Penny Vadla 399 West Riverview Avenue Soldotna, AK 99669-7714 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 ~~ ~¡~ I (rfo (j di03-2 (Beluga River), co 571,572,573 (near rew Mine) . Subject: di03-2 (Beluga River), co 571,572,573 (near red Dog Mine) From: Jody Colombie <jody_colombie@admin.state.ak.us> Date: Mon, 11 Sep 2006 17:02:18 -0800 To: undisclosed-recipients:; BCC: Cynthia B Mciver d <bren_mciver@admin.state.ak.us>, Robert E Mintz <robert_mintz@law.state.ak.us>, Christine Hansen <c.hans iogcc.state.okus>, Terrie Hubble <hubbletl@bp.com>, Sondra Stewman <Ste D@BP. >, stanekj <stanekj@unocal.com>, ecolaw <ecolaw@trustees.org>, trmjr 1 <trmjr l@aol.com>, jdarlington <jdarlington@forestoil.com>, nelson <knelson@petroleumnews.com>, cbo <c y@usibe om> ark Dalton <markdalton@hdrinc.com>, Shannon nn y <shannon. onnell onocophillips.com>, "Mark P. Worcester" <markp.worcester@conocophillips.com>, Bob <bob@inletkeeper.org>, wdv <wdv@dnr.state.ak.us>, tjr <tjr@dnr.state.ak.us>, bbritch <bbritch@alaska.net>, mjnelson <mjnelson@purvingertz.com>, Charles O'Donnell <charles.o'donnell@veco.com>, "Randy L. Skillern" <SkilleRL@BP.com>, "Deborah J. Jones" <JonesD6@BP.com>, "Steven R. Rossberg" <RossbeRS@BP.com>, Lois <lois@inletkeeper.org>, Dan Bross <kuacnews@kuac.org>, Gordon Pospisil <PospisG@BP.com>, "Francis S. Sommer" <SommerFS P.com>, Mikel Schultz <Mikel.Schultz@BP.com>, "Nick W. Glover" <GloverNW@BP.co , "Daryl J. Kleppin" <KleppiDE@BP.com>, "Janet D. Platt" <PlattJD@BP.com>, "Rosanne M. Jacobsen" <JacobsRM@BP.com>, ddonkel <ddonkel@cfl.rr.com>, mckay <mckay@gci.net>, Barbara F Fullmer <barbara.f.fullmer@conocophillips.com>, Charles Barker <barker@usgs.gov> , doug_schultze <doug_schultze@xtoenergy.com>, Hank Alford <hank.alford@exxonmobil.com>, Mark Kovac <yesnol@gci.net>, gspfoff <gspfoff@aurorapower.com>, Gregg Nady <gregg.nady@shell.com>, Fred Steece <fred. steece@state.sd.us>, rcrotty <rcrotty@ch2m.com>, jej ones <j ej ones@aurorapower.com>, dapa <dapa@alaska.net>,jroderick <jroderick@gci.net>, eyancy <eyancy@seal-tite.net>, "James M. Ruud" <james.m.ruud@conocophillips.com>, Brit Lively <mapalaska@ak.net>,jah <jah@dnr.state.ak.us>, buonoje <buonoje@bp.com>, Mark Hanley <mark_hanley@anadarko.com>, 10ren_Ieman <loren_Ieman@gov.state.ak,us>, Julie Houle <julie_houle@dnr.state.ak.us>, John W Katz <jwkatz@sso.org>, tablerk <tablerk@unocal.com>, Brady <brady@aoga.org>, Brian Havelock <beh@dnr.state.ak.us>, bpopp <bpopp@borough.kenai.akus>, Jim White <jimwhite@satx.rr.com>, "John S, Haworth" <john.s.haworth@exxonmobil.com>, marty <marty@rkindustrial.com>, ghammons <ghammons@aol.com>, rmclean <rmclean@pobox.alaska.net>, mkm7200 <mkm7200@aol.com>, Brian Gillespie <ifbmg@uaa.alaska.edu>, David L Boelens <dboelens@aurorapower.com>, Todd Durkee <TDURKEE@KMG.com>, Gary Schultz <gary_schultz@dnr.state.ak,us>, Wayne Rancier <RANCIER@petro-canada.ca>, Brandon Gagnon <bgagnon@brenalaw.com>, Paul Winslow <pmwinslow@forestoil.com>, Sharmaine Copeland <copelasv@bp.com>, Kristin Dirks <kristin_dirks@dnr.state.ak.us>, Kaynell Zeman <kjzeman@marathonoil.com>, John Tower <John.Tower@eia.doe.gov>, Bill Fowler <Bill_Fowler@anadarko.COM>, Scott Cranswick <scott.cranswick@mms.gov>, Brad McKim <mckimbs@BP.com>, Steve Lambe <lambes@unocal.com>,jack newell <jacknewell@acsalaska.net>, James Scherr <james.scherr@mms.gov>, nI617@conocophillips.com, Tim Lawlor <Tim_Lawlor@ak.blm.gov>, Lynnda Kahn <Lynnda _ Kahn@fws.gov>, Jerry Dethlefs <Jerry.C.Dethlefs@conocophillips.com>, crockett@aoga.org, Tamera Sheffield <sheffield@aoga.org>, Jon Goltz <Jon, Goltz@conocophillips.com>, Roger Belman <roger. belman@conocophillips.com>, Mindy Lewis <mlewis@brenalaw.com>, Kari Moriarty <moriarty@aoga.org>, Patty Alfaro <palfaro@yahoo.com>, Jeff <smetankaj@unocal.com>, Todd Kratz <ToddKratz@chevron.com>, Gary Rogers <gary Jogers@revenue.state.ak.us>, Arthur Copoulos <Arthur _ Copoulos@dnr.state.ak.us>, Ken <ken@secorp-inc.com>, Steve Lambert <salambert@unocal.com>, Joe Nicks <news@radiokenai.com>, Jerry McCutcheon <susitnahydronow@yahoo.com>, Bill Walker <bill-wwa@ak.net>, Iris Matthews lof2 9/11/20065:02 PM di03-2 (Beluga River), co 571,572,573 (near re.g Mine) . <Iris_Matthews@legis.state.ak.us>, Paul Decker <paul_decker@dnr.state.ak.us>, Rob Dragnich <rob.g.dragnich@exxonmobil.com>, Aleutians East Borough <admin@aleutianseast.org>, Marquerite kremer <marguerite_kremer@dnr.state.ak.us>, Alicia Konsor <alicia_konsor@dnr.state.ak.us>, Mike Mason <mike@kbbi.org>, Garland Robinson <gbrobinson@marathonoil.com>, Cammy Taylor <Camille_Taylor@law.state.ak.us>, Winton GAubert <winton_aubert@admin.state.ak.us>, Thomas E Maunder <tom_maunder@admin.state.ak.us>, Stephen F Davies <steve_davies@admin.state.ak.us>, Keith Wiles <kwiles@marathonoil.com>, Deanna Gamble <dgamble@kakivik.com>, James B Regg <jimJegg@admin.state.ak.us>, Cathenne P Foerster <cathy_foerster@admin.state.ak.us>, Bob <Bob@fairweather.com>, gregory micallef <micallef@c1earwire.net>, Laura Silliphant <laura _ silliphant@dnr.state.ak.us>, David Steingreaber <david.e.steingreaber@exxonmobil.com>, akpratts@acsalaska.net, Robert Campbell <Robert.Campbell@reuters.com>, Steve Moothart <steve _ moothart@dnr.state.ak.us>, Anna Raff <anna.raff@dowjones.com>, Cliff Posey <cliff@posey.org>, Paul Bloom <paul_bloom@ml.com>, Sonja Franklin <sfranklin6@blomberg.net> 20f2 9/11120065:02 PM • • ~~ 3~ 1 ~ ~ ~.,~ E ~ ~ ~ ~.:~ SARAH PALIN, GOVERNOR Ai~C~-7i>•A OIL ~ ~ 333 W. 7th AVENUE, SUITE 100 C01~5C' RQATIOAT COMI1'II551O1~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL NO. DIO 3.003 Ms. Mary Mae Aschoff Environmental Coordinator ConocoPhillips Alaska Inc. P.O. Box 66 Kenai, Alaska 99611 Re: Disposal Injection of Unused Completion Fluids Dear Ms. Aschoff: Disposal Injection Order ("DIO") 3 approved the injection of Class II waste fluids into Beluga River Unit Well BRWD-1. There have been three administrative approvals granted since DIO 3 was issued clarifying fluids eligible for injection into this Class II disposal well. On June 10 and clarified June 17, 2008 you requested approval to dispose of unused completion fluids in Well BRWD-1. Your request is APPROVED. The Beluga River Field is a remote gas production facility located on the west side of Cook Inlet. ConocoPhillips has scheduled well work and drilling operations for several Beluga wells during 2008. Hydraulic fracturing is necessary with an engineered fluid due to the insufficient capability of the completed formations to produce based on past production tests. ConocoPhillips Alaska Inc. (CPAI) has chosen a fluid designed with sufficient viscosity to carry and keep the fracture proppant in solution. CPAI notes in their request the 2008 drilling and completion programs are complex because of the uncertainty of fluid required for fracturing operations and the gross thickness to be completed. Planned operations call for fracturing multiple zones that may require separate fracture treatments due to pressure differences. CPAI states that while they have the ability to prepare the completion fluid at the location, there may be excess volumes that cannot be used downhole for cleaning out sand plugs placed in a well for isolating the zones that will be fractured. Disposal options are limited at Beluga and CPAI argues the most efficient and environmentally preferable option is to inject unused completion fluids into BRWD-1. DIO 3.003 ~ • June 19, 2008 Page 2 of 2 Confinement of fluids to the intended injection zone in Well BRWD-1 has been demonstrated by historical injection performance data provided by CPA. Well integrity has been demonstrated by successful mechanical integrity testing and monitoring the well's annular pressures. The disposal of unused completion fluids to be used during the 2008 drilling and completion program at Beluga will have no detrimental effect on the confinement of fluids. Well integrity, correlative rights, and waste will not occur from the disposal injection of unused completion fluid into Well BRWD-1. Approval applies only to this specific request and is not intended to provide for a blanket authorization to inject these or similar non-hazardous fluids down other Class II disposal wells. DONE at Anchorage, Alaska and dated June 19, 2008. j~ /~~- ~t'li Daniel T. Seamount, Jr Chair ~, Cathy . Foerster Co issioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within ]0-days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. • • Mary Jones David McCaleb Cindi Walker XTO Energy, Inc. IHS Energy Group Tesoro Refining and Marketing Co. Cartography GEPS Supply & Distribution 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 300 Concord Plaza Drive Ft. Worth, TX 76102-6298 Houston, TX 77056 San Antonio, TX 78216 George Vaught, Jr. Jerry Hodgden Richard Neahring PO Box 13557 Hodgden Oil Company NRG Associates Denver, CO 80201-3557 408 18th Street President Golden, CO 80401-2433 PO Box 1655 Colorado Springs, CO 80901 John Levorsen Mark Wedman Baker Oil Tools 200 North 3rd Street, #1202 Halliburton 4730 Business Park Blvd., #44 Boise, ID 83702 6900 Arctic Blvd. Anchorage, AK 99503 Anchorage, AK 99502 Schlumberger Ciri Ivan Gillian Drilling and Measurements Land Department 9649 Musket Bell Cr.#5 2525 Gambell Street #400 PO Box 93330 Anchorage, AK 99507 Anchorage, AK 99503 Anchorage, AK 99503 Jill Schneider Gordon Severson Jack Hakkila US Geological Survey 3201 Westmar Cr. PO Box 190083 4200 University Dr. Anchorage, AK 99508-4336 Anchorage, AK 99519 Anchorage, AK 99508 Darwin Waldsmith James Gibbs Kenai National Wildlife Refuge PO Box 39309 PO Box 1597 Refuge Manager Ninilchick, AK 99639 Soldotna, AK 99669 PO Box 2139 Soldotna, AK 99669-2139 Penny Vadla Richard Wagner Cliff Burglin 399 West Riverview Avenue PO Box 60868 PO Box 70131 Soldotna, AK 99669-7714 Fairbanks, AK 99706 Fairbanks, AK 99707 Bernie Karl North Slope Borough Williams Thomas K&K Recycling Inc. PO Box 69 Arctic Slope Regional Corporation PO Box 58055 Barrow, AK 99723 Land Department Fairbanks, AK 99711 PO Box 129 Barrow, AK 99723 /y)cr~/o/ (v/%9~fi • Page 1 of 1 Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Friday, June 20, 2008 9:41 AM Subject: FW: aio2B-033; dio3-003; dio17-006 Attachments: dio17-006.pdf; aio2b-33.pdf; dio3-003.pdf BCC:'Aleutians East Borough'; 'Anna Raff; Arion, Teri A (DNR); 'Arthur Copoulos'; 'Barbara F Fullmer'; 'bbritch'; 'Bill Walker'; 'Brad McKim'; 'Brandon Gagnon'; 'Brian Gillespie'; 'Brian Havelock'; 'Brit Lively'; 'Bruce Webb'; 'buonoje'; 'Cammy Taylor'; 'Cande.Brandow'; 'carol Smyth'; 'Cary Carrigan'; caunderwood@marathonoil.com; 'Charles O'Donnell'; 'Chris Gay'; 'Christian Gou-Leonhardt'; 'Cliff Posey'; 'Dan Bross'; 'dapa'; 'Daryl J. Kleppin'; 'David Brown'; 'David Hall'; David House; 'David L Boelens'; 'David Steingreaber'; 'ddonkel'; 'Deborah J. Jones'; 'doug_schultze'; 'Eric Lidji '; 'Evan Harness'; 'eyancy'; 'foms2@mtaonline.net'; 'Francis S. Sommer'; 'Fred Steece'; 'Garland Robinson'; 'Gary Laughlin'; 'Gary Rogers'; 'Gary Schultz'; 'ghammons'; 'Gordon Pospisil'; Gould, Greg M (DEC); 'Gregg Nady'; 'gregory micallef; 'gspfoff; 'Hank Alford'; 'Harry Engel'; 'jah'; 'James Scherr'; 'Janet D. Platt'; 'jejones'; 'Jerry McCutcheon'; 'Jim Arlington'; 'Jim White'; 'Jim Winegarner'; 'Joe Nicks'; 'John Garing'; 'John S. Haworth'; 'John Spain'; 'John Tower'; 'John W Katz'; johnny.aiken@north-slope.org; 'Jon Goltz'; 'Julie Houle'; 'Kari Moriarty'; 'Kaynell Zeman'; 'Keith Wiles'; knelson@petroleumnews.com; 'Krissell Crandall'; 'Kristin Dirks'; 'Laura Silliphant'; 'Lois'; 'Lynnda Kahn'; 'mail=akpratts@acsalaska.net'; 'mail=fours@mtaonline.net'; 'Marilyn Crockett'; 'Mark Dalton'; 'Mark Hanley'; 'Mark Kovac'; 'Mark P. Worcester'; 'Marguerite kremer'; 'marty'r 'Matt Rader'; 'Meghan Powell'; Melanie Brown; 'Mike Bill'; 'Mike Mason'; 'Mikel Schultz'; 'Mindy Lewis'; 'MJ Loveland'; 'mjnelson'; 'mkm7200'; 'Nick W. Glover'; NSK Problem Well Supv; NSU, ADW Well Integrity Engineer; 'Patty Alfaro'; 'Paul Decker'; 'Paul Winslow'; Pierce, Sandra M (DNR); 'Randall Kanady'; 'Randy L. Skillern'; 'rcrotty'; Rice, Cody J (DNR); 'rmclean'; 'Rob McWhorter '; rob.g.dragnich@exxonmobil.com; 'Robert Campbell'; 'Robert Fowler'; 'Robert Province'; 'Roger Belman'; 'Rudy Brueggeman'; 'Scott Cranswick'; 'Shannon Donnelly'; 'Sharmaine Copeland'; 'Sondra Stewman'; 'Sonja Frankllin'; 'Stan Porhola'; 'stanekj'; 'Steve Lambert'; 'Steve Moothart'; 'Steven R. Rossberg'; 'tablerk'; 'Tamera Sheffield'; 'Temple Davidson'; 'Terrie Hubble'; 'Tim Lawlor'; 'Todd Durkee'; Tony Hopfinger; 'trmjrl'; 'Walter Featherly'; 'Walter Quay'; 'Wayne Rancier' Attachments: dio 17-006.pdf;aio2b-33.pdf;dio3-003.pdf; From: Colombie, Jody J (DOA) Sent: Friday, June 20, 2008 9:35 AM Subject: aio2B-033; dio3-003; dio17-006 Jody Jaylene Colombie Special Assistant to the Commission Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 (907) 793-1221 Direct Line (907) 276-7542 Fax 6/20/2008 • Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Friday, June 20, 2008 9:35 AM Subject: aio26-033; dio3-003; dio17-006 Attachments: dio17-006.pdf; aio2b-33.pdf; dio3-003.pdf Page 1 of 1 BCC:'Dale Hoffman ; Fridiric Grenier; Joseph Longo; Maurizio Grandi; Tom Gennings; 'Willem Vollenbrock'; Birnbaum, Alan J (LAW); Crisp, John H (DOA); Davies, Stephen F (DOA); Fleckenstein, Robert J (DOA); Foerster, Catherine P (DOA); Grimaldi, Louis R (DOA); Johnson, Elaine M (DOA); Jones, Jeffery B (DOA); Laasch, Linda K (DOA); Mahnken, Christine R (DOA); Maunder, Thomas E (DOA); McIver, C (DOA); McMains, Stephen E (DOA); Noble, Robert C (DOA); Norman, John K (DOA); Okland, Howard D (DOA); Paladijczuk, Tracie L (DOA); Pasqual, Maria (DOA); Regg, James B (DOA); Roby, David S (DOA); Saltmarsh, Arthur C (DOA); Scheve, Charles M (DOA); Seamount, Dan T (DOA); Smith, Chasity R (DOA); Williamson, Mary J (DOA) Attachments: dio 17-006.pdf;aio2b-3 3 .pdf;dio3 -003 .pdf; Jody Jaylene Colombie Special Assistant to the Commission Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 (907) 793-1221 Direct Line (907) 276-7542 Fax 6/20/2008 x$11 C~ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, June 03, 2010 2:40 PM To: Czarnezki, Marta P. Subject: RE: Injection Que Marta, ~ ~~ _ ~ Page 1 of 2 Whether a well is producing or not is not a factor that is relevant. What matters is if the well is a development/producer (oil, gas or water supply) or service (EOR or Class 11 disposal) injection well. Wastes from such wells are E8~P exempt. Tom Maunder, PE AOGCC From: Czarnezki, Marta P. [mailto:Marta.P.Czarnezki@conocophillips.com] Sent: Thursday, June 03, 2010 2:35 PM To: Maunder, Thomas E (DOA) Subject: RE: Injection Question - DIO -3 Hi Tom - I did consult the "red book", but could not find any specific reference/differential regarding fluid disposal generated from anon-E&P exempt (non-producing) well...which is what prompted my call to AOGCC. I will route this accordingly and hopefully your interpretation will make it into the next "red book" revision. That is (in part) why I wanted something in writing from you. THANKS again!! -Marta Cz From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, June 03, 2010 11:11 AM To: Czarnezki, Marta P. Subject: RE: Injection Question - DIO -3 Hello Marta, Waste solids and fluids from production or Class II injection wells (EOR or disposal) are defined as Class 11. Some confusion is introduced when Class I wells enter the mix and EPA's position that wastes derived from a Class I well can only be disposed of in a Class I well. Since we spoke, it has occurred to me that the "Red Book" used on the slope by your colleagues might be a source of information that you can access. You might contact Wendy Mahan or Shelly Cosgrove(?) with questions. hope our call and this response answer your questions. Call or message anytime. Tom Maunder, PE AOGCC From: Czarnezki, Marta P. [mailto:Marta.P.Czarnezki@conocophillips.com] Sent: Wednesday, June 02, 2010 4:10 PM To: Maunder, Thomas E (DOA) Subject: Injection Question - DIO -3 Hi Tam, As discussed, I would like confirmation that it is acceptable to AOGCC to inject fluid used to workover BRWD-1 (a non-producing well} back into BRWD-1 for disposal. If you can paraphrase the logic you gave me, along with the differences in views between AOGCC & EPA that would be terrific. I will circulate this to my NS counterparts & field supervisors as well for education purposes. 6/16/2010 THANK YOU so much for your time and assistance! Marta Czarnezki Environmental Coordinator Cook Inlet Asset ConocoPhillips Company PO Box 66 48237 Kenai Spur Hwy Kenai AK 99611 Ph: 907-776-2092 Fx: 907-776-2095 Cell: 907-252-6794 email: manta.p.czarnezki@conocophillips.com Page 2 of 2 6/16/2010 ~10 Additional coverage under DIO 3,~03 ~ Page 1 of 1 ~ Regg, James B (DOA) From: Regg, James B(DOA) ~I~' ~g ?~~ f~~ Sent: Monday, July 20, 2009 2:55 PM ~ l To: 'Aschoff, Mary Mae' Subject: RE: Additional coverage under DIO 3.003 DIO 3.003 is written to cover the unused completion fluids associated with the ongoing Beluga River Unit drilling program. Work was initiated during 2008 and will recommence in August 2009. CPAI's request is aparoved. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Aschoff, Mary Mae [mailto:Mary.M.Aschoff@conocophillips.com] Sent: Monday, July 13, 2009 2:57 PM To: Regg, James B (DOA) Subject: Additional coverage under DIO 3.003 Hella Jim, Per our conversatian this afternoon CanocoPhillips Alaska TNC. (CPAI) is requesting that the unused completian fluids for the ZO09 Beluga River Unit's (BRU} Drilling progrnm be covered under the current bTC}3.003. CPAI anticipates these fluids far the 2009 BRU drilPing program will be the same type that was used last year. The 'final' completion fluid design is not complete at this time, and if there is any notable variation from fast year's, it will be submitted ta the AOGCC as we11. If there is any questians on this request, please contact me. Thanks so much. -MM 7/20/2009 n • ConocoPhillips Interoffice Communication To :Mary Mae Aschoff From :Brian R. Buck, Completion Engineer Date :June 17, 2008 Subject :Lightning 1800 Usage ConocoPhillips Alaska Inc. Drilling and Wells ATO 15`" Floor 700 G Street Anchorage, Alaska 99501 Phone: (907) 265-6346 Fax: (907) 265-1535 Ref No.: File Code: Purpose• Clarify reasons for using Lightning 1800 fluid in Cook Inlet. Briefly address complexities of Cook Inlet Drilling Program. Lightning 1800 Lightning 1800 is a BJ product used for the fracturing of formations. The fluid has an increased viscosity designed to carry proppant to the formation. A viscous fluid is needed so the job can be executed without proppant falling out of solution. The reason the formation needs to be fracture stimulated is because the permeability of the formation is likely insufficient to flow based on previous production tests. Due to platform space at Tyonek, the plan is to pre-mix the fracturing fluid at Tyonek. However, at Beluga because of the increased working area, there is enough room to add a hydration unit. This will limit the volume of Lightning 1800 fluid to 100 to 150 barrels at Beluga. In both locations, we will design our frac to limit the surface volume of Lightning 1800 wherever possible. There will likely always be some surface volume to deal with, but that volume will be minimized as operations permit. In both locations, the primary plan is to beneficially reuse left over Lightning 1800. One possible beneficial reuse is for cleaning out sand plugs with the viscosified fluid. Cook Inlet Program Complexity A large reason for the complexity of the Cook Inlet program is caused by the interval length being completed. Approximately 2700' of gross thickness will be completed. The sands will be perforated, leaving the coals and shales behind casing. The Cook Inlet program this year calls for fracturing of the some of the lower zones approximately 4 separate times using a sand plug to "isolate" the lower fractures from the upper ones. All of the sand plugs will be cleaned out and then the formation will be reperforated. Following reperforating, the formation will be gravel packed, because there is insufficient rock strength to maintain long term production (according to core tests and production data). After the lower interval of approximately 1200 feet is completed, the lower formations will be isolated and amulti-zone, single trip gravel pack will be performed on top of the lower conventional gravel pack. The nature of gravel packing operations is there is an increased need for clean fluids, because all of the production has to come through the gravel pack filled perforation tunnels. Hopefully this helps explain the complexity of the fluids handling for the Cook Inlet completions. Please feel free to contact me at 907-265-6346 if you have any questions. ~~ • ~ • ConocoPh~ll~ps Alaska, Inc. June 10, 2008 Mr. Jim Regg Alaska Oil & Gas Conservation Commission 333 W 7th Ave, Suite 100 Anchorage, Alaska 99501 Office: 907-793-1236 Fax: 907-276-7542 RE: Administrative Approval Request Disposal of `Unused' Completion Fluids NCIU A-12 (DIO 17.000) BRU BRWD-1 (DIO 003.000) Dear Mr. Regg: Mary Mae Aschoff Environmental Coordinator 700 G Street, ATO-1410 P.O. Box 100360 Anchorage, AK 99510 Phone 907.263.4618 Fax 907.265.1441 Mary.M.Aschoff@ConocoPhillips.com ConocoPhillips Alaska Inc. operates the Beluga River Gas Field, a remote gas production facility located on the west side of Cook Inlet, and the Tyonek Platform, a remote offshore gas production platform located within the North Cook Inlet Unit. There is a permitted Class II disposal well located at each of these facilities and each is regulated under the above referenced Injection Orders. Under normal operating conditions, the facilities are able to successfully manage most non-hazardous and/or exempt fluid wastes. Small quantities of Class I and hazardous wastes that cannot be managed locally are transported off-site for proper disposal. During periods of non-routine activity in the field, such as periods of intensive well work and drilling programs, the Class II-D disposal wells may be utilized more intensively to manage wastes returned from downhole. During such work, non-hazardous wastes directly associated with well maintenance and drilling activities that have not been down hole may be generated. Such waste streams include quantities of `unused' completion fluids. At the present time, management options for these types of wastes are not readily available at the Beluga River Field or on the Tyonek Platform, nor is it practical to containerize these fluids for off site disposal. Access to the Beluga River Unit (BRU) facility is limited to aircraft and supply barges during open water months. Access to the Tyonek facility is limited to helicopter or boat. The facilities are equipped with limited means for managing fluid wastes on-site. • • ConocoPhillips Alaska Inc., makes a concerted effort to minimize the quantities of Class wastes generated through proper planning and beneficial reuse programs. However, in evaluating waste management options in support of the 2008 Beluga River and Tyonek Platform drilling programs, the preferred option for managing `unused' completion fluids is via disposal in BRWD-1 for BRU and NCIU A-12 for Tyonek, when such wastes are generated. The purpose of this letter is to request AOGCC concurrence for this disposal request. ConocoPhillips Alaska Inc., respectfully requests approval from the Commission to utilize the permitted Class II disposal wells, BRWD-1 and NCIU A-12, for the disposal of designated `unused' completion fluids on a contingency basis, such as periods of well work or during drilling programs. Use of the Class II-D wells in this capacity would be restricted to an as-needed basis, and all disposal activities would be properly documented and reported. Provisional approval to use BRWD-1 and NCIU A-12 for disposal of `unused' completion fluids would significantly increase operational flexibility and minimize potential environmental exposure. Included for your review is a table of potential additives and possible variations in the completion fluid that will be used in the 2008 drilling programs. This is one completion fluid or variation of, which is used routinely in well work and work over applications. MSDS's and a detailed description of additives in this fluid are attached. Thank you very much for your consideration of this proposal. Please do not hesitate to contact me at (907) 263-4618 should you have any questions or additional information needs. Sincerely, ~r Mary Mae Asch ff Environmental Coordinator ConocoPhillips Alaska Inc -Cook Inlet Asset: Additives Table ~ ~ June 10, 2008 Below is the recipe for Lightning 1800 as originally designed. The product names in the below table should match up with the product descriptions in the attached MSDS file. Lightning 1800 frac fluid Function Name loading Units Potential Ranges Gellant : GLFC-5D 4.50 t Buffer : BF-7L 1.10 t 1.1-1.8 X-linker: XLW-32 0.80 t Breaker: Enz me G-I 1.00 t 1-1.5 Breaker 2 : BC-3 2.00 t 1-2.2 Other : Cla Master-5C 0.50 t Other : Flo-Back 30 0.50 t Clay stabilization KCI 6.00 * For the second option fluid possibility, the BC-3 from the "recipe" above would be deleted, and replaced with BC-6, GBW-5 and GBW-18. BC-6 0.5 - 1.5 gal/1000 gal GBW-5 0.5 - 2 Ib/1000 gal GBW-18 0.5 - 2 Ib/1000 gal • • Additives Table June 10, 2008 Below is the recipe for Lightning 1800 as originally designed. The product names in the below table should match up with the product descriptions in the attached MSDS file. Lightning 1800 frac fluid Function Name loading Units Potential Ranges Gellant : GLFC-5D 4.50 t Buffer : BF-7L 1.10 t 1.1-1.8 X-linker: XLW-32 0.80 t Breaker: Enz me G-I 1.00 t 1-1.5 Breaker (2): BC-3 2.00 ppt 1-2.2 Other : Cla Master-5C 0.50 pt Other : Flo-Back 30 0.50 pt Clay stabilization KCI 6.00 For the second option fluid possibility, the BC-3 from the "recipe" above would be deleted, and replaced with BC-6, GBW-5 and GBW-18. BC-6 0.5 - 1.5 gal/1000 gal GBW-5 0.5 - 2 Ib/1000 gal GBW-18 0.5 - 2 Ib/1000 gal • • EeIrME 6'"BREAKERS smUUnoH ' ~ • • Enzyme G is a patented, guar specific enzyme breaker custom-formulated to degrade guar polymer into non- damaging components. High Efficiency Enzyme complex attacks, or has an affinity toward, specific polymer linkages resulting in mono- and di-saccharides, which maximizes degradation efficiency. Customization Polymer-specific enzymes are custom-designed for any guar or derivatized guar polymer. Unique Chemistry Enzymes do not undergo chemical or structural changes during the reactions they initiate and do not produce undesirable side reactions. They have a unique property called "turn-over" number. Typical "turn-over" numbers are in excess of one million which means that more than one million linkages of polymer substrate can be cleaved per minute. A great many more can be cleaved over the "life span" of the enzyme unit. Temperature Stability Stable at temperatures up to 275°F (135°C). Recent advances in biotechnology allow for extreme temperature applications. pH Stability Effective in fluids that range in pH from 3 to 11. Recent advances in biotechnology also allow for broader pH applications. Non-Hazardous Produced from all natural processes. Compatibility Compatible with all types of formations, base waters, tubular goods and proppants (especially resin-coated proppants). Proppant pack testing has shown that retained conductivities approaching 100% are possible. Applicable to a broad range of downhole temperatures. Low and high pH stability of the enzymes permit use in all fracturing fluids, workover operations and remedial treatments. Environmentally friendly. Enzymes do not require any special handling or disposal. Cost effective. High retained conductivity and high regained permeability result in high productivity, which is a cost savings for the operator. Non-corrosive to any metals which may be encountered in the well. Highly compatible, with the only affinity toward specific linkages in the guar molecule; does not react with anything else. i ~ B/ SERV/CES COMPANY • ExirME G'" BREANEBS Product Information • Although prolonged contact and breathing can produce an irritation in sensitized people, there are no special storage, handling, toxicity or environmental precautions necessary. .- -.- GBW-9 and GBW-10; B-11 and B-11 L. ^~nu~r~~r•~~ti Suggested maximum temperature of 275°F (135°C). .- .. None. Confidential Mixing Instructions MSDS SPE 25214/25385 Remedial Treatment for Po/ymeric Damage Remova/Provides /mproved We//Productivity R. M. Tjon-Joe-Pin, H. D. Brannon and A. R. Rickards, BJ Services SWPSC 27 App/iedBiotechno%gica/Advances forthe Oi//ndustry R. M. Tjon-Joe-Pin, BJ Services SWPSC 1994 Increased We//Productivity Utilizing /mproved Fracturing F/aids and High pHEnzyme Breakers: A Case Study of San Andres Formation We//s in the Permian Basin R. M. Tjon-Joe-Pin and H.D. Brannon, BJ Services; Alex Martinez, Texaco E&P SWPSC 1994 High Temperature Blocking Ge/s for Temporary Workover Operations R. M. Tjon-Joe-Pin, B. Beall and A.R. Richards, BJ Services SPE 28513 Biotechno%gica/Breakthrough /mproves Performance ofModerate to High Temperature Fracturing App/ications H.D. Brannon and R. M. Tjon-Joe-Pin, BJ Services SPE 29446 /mproved Fracturing Techno%gies Provide for/ncreased We//Productivity.~A Case Study on Red Fork Formation We//s H.D. Brannon and R. M. Tjon-Joe-Pin, BJ Services; P. Handren, Oryx Energy Company SPE 29677/29822 App/ication ofDamage Remova/ Treatment Results in Mu/fifo/d We//Productivity /mprovement.~A Case Study H.D. Brannon and R. M. Tjon-Joe-Pin, BJ Services SPE 30492 Characterization ofBreakerE~ciencyBased Upon Size Distribution ofPo/ymeric Fragments R. M. Tjon-Joe-Pin and H.D. Brannon, BJ Services Patent #5,201,370 Enzyme Breaker for Galactomannan-Based Fracturing Fluids R. M. Tjon-Joe-Pin, BJ Services The above features and/or tlalaore supplied solely for informational purposes and BJ Services Company makes no guarantees orwarranties, either eapressetl pr implied, with respect to their accuracy or use. All product warranties and guarantees shall be governed by the BJ Services Company standard at the time of sale or tlelivery of service. Actual protlucl peAOrmance or availabiNty depentls on the liming antl location of the job, the type of job and the particular characteristics Of each job. This tlocument is conlrolletl by the reference tlate. To ensufe that this is the current version, please reference the Services section or the BJ Services Website (www.bjservices.com) or ask your BJ representative. 7/28/00 : ~ B/ SERVICES COMPANY • • POTASSIUM CHLORIDE s~~uu~oN Product Information ~~~ Potassium chloride's (KCI) primary applications are in the preparation of light brines for well completion operations and fracturing stimulation treatments. Potassium chloride is very effective at preventing reservoir clays from swelling and/or migrating and, therefore, protects the reservoir from permeability damage. Potassium chloride is also incorporated in solutions used for breaking emulsions or water blocks, for combating bacteria and for protecting production zones during work-over operation. Normally, a 1 to 3% KCI solutions (by weight of water) in fresh water provides an excellent fluid for each of these applications. The optimum concentration can easily be determined by laboratory testing. Potassium chloride can be prepared from fresh water up to a density of 9.7 ppg (1162.3 kg/m'), which is equivalent to 24% of KCI by weight of solution. Caustic Soda (NaOH), lime (Ca0) and magnesium oxide (Mg0) are commonly used to increase pH of KCI. Good Fluid Recovery Minimizes dispersion of swelling and non-swelling clays to maximize flow potenial. Easy to Use Potassium chloride is easily disolved in fresh water, readily available and inexpensive. Compatiabls Potassium chloride is compatible with most chemicals used in well stimulation fluids, such as friction reducers, gelling agents, fluid loss additives and surfactants. Usage Normally used in fresh water for water-based fracturing fluid (2% KCI) and completion brine (3% KCI) to prevent clay swelling. Inhibits hydration and swelling of formation clays. Potassium chloride is economical to prepare and apply. Can be used for treating most formations. Potassium chloride is easily dissolved in fresh water. Refer to Material Safety Data Sheet. B/ SERV/CES COMPANY POTASSIUM CNLORIUE Product Information . . Has to be stored in dry area. Some well conditions preclude the use of KCI for fracturing operations. For example, Potassium chloride should not be used in Hydrofluoric acid (acidizing treatments) systems. Check with your BJ Services representative for information that applies to an individual well. .- .~ Potassium Chloride, M-117, sodium chloride, Potassium formate, sodium formate Color: White Crystalline solid, no odor Specific Gravity: 1.988 Bulk Density: 76 Ib/cu.ft. (1217.4 kg/m3) (poured) 85 Ib/cu.ft. (1361.6 kg/m') (tapped) Molecular Weight: 74.56 Refractive Index: 1.490 Nature of Charge: Cationic Melting Point: 1421.6°F (772°C) Boiling Point: 2511.8°F (1411 °C) Sublimes: 2732.0°F (1500°C) Flash Point: Not combustible. pH of Solutions (water): 6.4 @ 1 % by weight 6.6 @ 2% by weight 7.1 @ 5% by weight 7.3 @ 10% by weight Solubility in Water: 25% @ 68°F Solubility in Oil: None Solubility in Alcohol: Slightly Price Book Reference Number: 100114 Confidential Mixing Instructions MSDS The above features and/w tlala are supDlietl solely for informational Durposes and BJ Services Company makes no guarantees or warranties, either expressed or implied, with respect to (heir accuracy or use. All protluct waranties antl guarantees shall be governed by the BJ Services Company standard al the lime of sale or delivery of service. Actual product performance or availability depends on the liming and location of Ihejob, the type ofjob and the particular characteristics of each job.ThTs document is conbolled 6y the reference dale. To ensure that This is the current version. please reference the Services section of the BJ Services Websila (www.bjservices.com) orask your BJ reoresentative. 10/30/00 ~ ~ B/ SERV/CES COMPANY • • Flo-BACN30" Sm~unoN 4nnliratic. Recovery of aqueous fracturing fluids can pose special problems, particularly in tight reservoirs with low bottomhole pressures. Flo-Back 30, a non-ionic liquid surfactant, relieves these problems by substantially increasing the fluid recovery rate for all aqueous fracturing fluids, including gelled and crosslinked systems, as well as matrix acidizing fluids. Flo-Back 30 is not absorbed on the formation; it stays in the stimulation fluid and it has some non-emulsifying properties to help prevent incompatibilities. Due to its non-ionic nature, the surfactant is compatible with other nonionic, cationic and anionic additives. Flexible Applicable in all aqueous fracturing, and matrix acidizing fluids, including foamed, gelled and crosslinked. Wettability The chemical structure of the water-liking part of the surfactant is designed to minimize absorption onto formation material. This behavior helps prevent the formation from becoming oil wet during and after treatment. The additive also reduces surface and interfacial tension to minimize water blocks during fluid recovery. High-Temperature Range Effective above 300°F (149°C) Mixing The additive is very dispersible in the various types of treating fluids. This dispersibility prevents the separation of the additive from the bulk fluid even after long periods without agitation. Compatibility The nonionic nature of the surfactant allows for mixing with other nonionic or ionic additives without fear of separations. The additive is also compatible with anti-sludge additives and mutual solvents. Faster payback from more rapid fluid recovery. Outperforms conventional surfactant systems at less cost. The chemical structure of the surfactants is designed to provide non-emulsifying capabilities. Conversion of a water-wet formation to oil-wet surfaces could be detrimental to hydrocarbon production. These surfactants were designed to prevent this wetting change and maximize hydrocarbon production. Certain materials used in making our products can have harmful effects if handled directly. Avoid contact with eyes, skin and clothing. Avoid prolonged breathing of mist or vapors. DO NO take internally. Do not use, store, spill or pour near heat, sparks or open flame. . . Proper pre-testing is mandatory to assure Flo-Back 30 can be used effectively for specific aqueous fracturing fluids. BJ SERVICES COMPANY FLO-BACK 30 Product Information Specific Gravity: 1.11 Density @ 77°F (25°C): 9.27 ppg (1.11 g/cm3) Freezing Point: <0°F (-18°C) Color: Pale Yellow Nature of Charge: Nonionic Solubility in water,acid, brine: Soluble .- .. SSO-21, F75N, J473. Material Safety Data Sheet 5/99 The above features andlor data are supplied solely for informational purposes and BJ Services Company makes no guarantees orwarranties, either express or implied, wiM respect to their accuracy or use. All product warranties and guarantees shall be governed by Me BJ Services Company standard at Me 6me of sale or delivery of service. Actual product performance or availability depends on the timing and location of the job, Me type of job and the particular characteristics of each job. This document is controlled by Me reference date. To insure that Mis is the current version, please reference the Services section of Me BJ Services Website (www.bjservices.com) or ask your BJ representative. ~ ~ BJ SERVICES COMPANY Region: MATERIAL SAFETY DATA SHEET usA 1 PRODUCT AND COMPANY IDENTIFICATION Product Name: BC-3 Item Number: 488187 Product Use: Breaker catalyst Supplier: BJ Services Company 5500 Northwest Central Dr Houston, TX 77092 (281)351-8131 IN CASE OF EMERGENCY CALL: (800) 424-9300 for CHEMTREC (703) 527-3887 for International HMIS HAZARD INDEX HEALTH: 1 FLAMMABILITY: 1 REACTIVITY: 0 PERSONAL PROTECTION: b 2 COMPOSITION/INFORMATION ON INGREDIENTS '..Ingredient Non-hazardous 100 3 HAZARDS IDENTIFICATION PRIMARY ROUTES OF EXPOSURE: ACUTE OVEREXPOSURE EFFECTS: Inhalation. Eye contact. Skin contact. INHALATION: May be harmful if inhaled. Exposure to high vapor/mist concentrations may cause respiratory tract irritation. • MSDS for BC-3 Page 1 INGESTION: Not a likely exposure route. EYE CONTACT: May cause mild eye irritation. SKIN CONTACT: May cause mild skin irritation. EXPOSURE LIMITS: 'Non-hazardous 4 FIRST AID MEASURES INHALATION: If inhaled, remove from area to fresh air. Get medical attention if respiratory irritation develops or if breathing becomes difficult INGESTION: Rinse mouth out with water. Drink plenty of water. If large quantities were ingested, seek medical advice. EYES: In case of contact, immediately flush eyes with plenty of water for at least 15 minutes and get medical attention if irritation persists. SKIN: Wash with water or soap and water. Remove contaminated clothing and launder before reuse. Get medical attention if irritation persists. 5 FIRE FIGHTING MEASURES FLASHPOINT (METHOD): 370°F (COC) LOWER EXPLOSION LIMIT (% v/v): Not applicable/available UPPER EXPLOSION LIMIT (% vlv): Not applicable/available AUTO-IGNITION TEMPERATURE: Not available/applicable SPECIAL HAZARDS: Product will burn in fire situation. • EXTINGUISHING MEDIA: Water fog, carbon dioxide, foam, dry chemical. SPECIAL FIREFIGHTING PROCEDURES: Fire-fighters should wear self-contained breathing apparatus and full protective clothing when fighting chemical fires. Cool exposed containers with water spray. HAZARDOUS COMBUSTION PRODUCTS: Oxides of carbon. 6 ACCIDENTAL RELEASE MEASURES MSDS for BC-3 Page 2 Wear specified protective equipment. Small spills -Cover spill with absorbent material. Scoop absorbed material into a suitable container for disposal. Large spills - Dike to contain. Prevent from entering sewers or waterways. Recover product to suitable containers or vessel for reuse, if possible, or for disposal. 7 HANDLING AND STORAGE HANDLING: Wear specified protective equipment Use only in a well ventilated area. STORAGE REQUIREMENTS: Keep container tightly closed, in a cool, well ventilated place. 8 EXPOSURE CONTROLS/PERSONAL PROTECTION SPECIFIC ENGINEERING CONTROLS: Use only in a well ventilated area. PERSONAL PROTECTIVE EQUIPMENT: Appropriate respiratory protection shall be worn when applied engineering controls are not adequate to protect against inhalation exposure. Chemical resistant goggles. Rubber gloves. Neoprene gloves. Coveralls. 9 PHYSICAL AND CHEMICAL PROPERTIES PHYSICAL STATE: COLOR: ODOR: ODOR THRESHOLD: SPECIFIC GRAVITY: VAPOR PRESSURE: VAPOR DENSITY (air = 1) EVAPORATION RATE: BOILING POINT: FREEZING POINT: pH: SOLUBILITY IN WATER: Liquid Clear Essentially None Not available/applicable 1.1 @ 25°C 1 mm Hg @ 132°C 11.1 < 1 (n-butyl acetate=1) 297°C -42°C Not available Negligible 10 STABILITY AND REACTIVITY STABILITY: Stable under normal conditions of use. INCOMPATIBILITY/CONDITIONS OF REACTIVITY: Strong oxidizers. HAZARDOUS THERMAL DECOMPOSITION PRODUCTS: • • MSDS for BC-3 Page 3 Carbon monoxide. Carbon dioxide. HAZARDOUS POLYMERIZATION: Will not occur. 11 TOXICOLOGICAL PROPERTIES CHRONIC EFFECTS: Not determined. SENSITIZATION: Not known. CARCINOGENICITY: None of the components of this product have been listed as carcinogenic by IARC, NTP or OSHA (IARC-International Agency for Research on Cancer) (NTP - National Toxicology Program) (OSHA -Occupational Safety & Health Administration (US)) MUTAGENICITY: Not known. REPRODUCTIVE TOXICITY: Not known. 12 ECOLOGICAL INFORMATION No specific information available 13 DISPOSAL CONSIDERATIONS WASTE DISPOSAL: Consult local waste authorities for direction and/or approvals prior to disposal. 14 TRANSPORT INFORMATION DOT Proper Shipping Name: NOT RESTRICTED MSDS for BC-3 Page 4 UN No.: NA AIR TRANSPORT (ICAO/IATA) Proper Shipping Name: NOT RESTRICTED UN/ID No.: NA MARINE TRANSPORT (IMDGlIMO) Proper Shipping Name: NOT RESTRICTED UN/ID No.: NA 15 REGULATORY INFORMATION SARA TITLE III: SECTION 302/304 This product does not contain substances listed in Appendix A and B as an Extremely Hazardous Substance. SECTION 311/312 Immediate SECTION 313 This product does not contain ingredients (at a level of 1% or greater) on the List of Toxic Chemicals. TSCA INVENTORY: The substances in this product are included on or exempted from the TSCA 8(b) Inventory (40 CFR 710) CALIFORNIA PROP 65: None of the chemicals on the current Proposition 65 list are known to be present in this product 16 OTHER INFORMATION ISSUE DATE: 10/21/2004 PREPARED BY: BJ SERVICES ENVIRONMENTAL GROUP REFERENCES: Suppliers' Literature. Dangerous Properties of Industrial Materials, 9th ed.; N. Irving Sax, 1996. CCINFOdisc (Core Collection), Canadian Centre for Occupational Health and Safety, 2004. International Marine Dangerous Goods Code, 2002 Edition ,International Maritime Organisation, 2002. Dangerous Goods Regulations, 45th ed., International Air Transport Association, 2004. TDG Clear Language Regulations, as published in the Canada Gazette Part II, August 2001. The information. contained herein is based on data considered accurate. However, no warranty is expressed or implied regarding the accuracy of these data or the results to be obtained from the use thereof. Vendor assumes no responsibility for injury to vendee or third persons proximately caused by the material i1 reasonable safety procedures are not adhered to as stipulated in the data sheet Additionally, vendor assumes no responsibility for injury to vendee or third persons proximately caused by abnormal use of the material even if reasonable safety procedures are followed Furthermore, vendee assumes the risk in his use of the material. MSDS for BC-3 Page 5 Revision: 1 Status: Approved & Released MSDS Revision History: Revision: Sec/Para Changed Change Made: Date 1 N/A Initial Issue of Document 10/21/99 2 I Telephone number 12/07/00 3 I Removed experimental designation 01/14/02 4 All Update to 16 pail format 10/21/04 • • MSDS for BC-3 Page 7 ~ ~ BJ SERVICES COMPANY Region: ~ MATERIAL SAFETY DATA SHEET usA SECTION I -GENERAL INFORMATION PRODUCT NAME: ITEM NUMBER CHEMICAL DESCRIPTION: PRODUCT USE: SUPPLIER: ADDRESS: EMERGENCY TELEPHONE NUMBER PREPARED BY: DATE PREPARED: BF-7L 488007, 425142, 411109 Potassium carbonate solution High pH Buffer BJ Services Company 5500 Northwest Central Dr Houston TX 77092 (800)424-9300 for CHEMTREC (703)527-3887 Alaska and International BJ Services Environmental Group (281)351-8131 September 25, 2003 Supersedes: August 4, 2000 HMIS HAZARD INDEX HEALTH: 2 FLAMMABILITY: 0 REACTIVITY: 0 PERSONAL PROTECTION: g • SECTION II -HAZARDOUS COMPONENTS HAZARDOUS COMPONENTS CAS # PERCENT HAZARD Potassium carbonate 584-08-7 40 - 50 Irritant N.E. =Not Established N.A. =Not Applicable MSDS for BF-7L...Page 1 SECTION III -FIRE AND EXPLOSION HAZARD DATA FLASHPOINT (METHOD): N.A. UPPER EXPLOSION LIMIT(% BY VOL): N.A. LOWER EXPLOSION LIMIT(% BY VOL): N.A. AUTO-IGNITION TEMPERATURE: N.A. EXTINGUISHING MEDIA: Material does not burn. Use appropriate media for surrounding fire SPECIAL FIRE FIGHTING PROCEDURES: Use aself-contained breathing apparatus with full facepiece operated in pressure-demand or other positive pressure mode. Cool fire-exposed containers using water spray. EXPLOSION DATA: None HAZARDOUS COMBUSTION PRODUCTS: N.A. SECTION IV -HEALTH HAZARD DATA PRIMARY ROUTES OF ENTRY: Skin and eye contact ACUTE OVEREXPOSURE EFFECTS: SKIN CONTACT: No irritation is likely after brief contact but may be irritating after prolonged contact. SKIN ABSORPTION: Not absorbed by skin. EYE CONTACT: Prolonged contact may damage the eyes. INHALATION: None currently known. INGESTION: Alkaline irritant to mouth, throat, esophagus, stomach. CHRONIC OVEREXPOSURE EFFECTS EXPOSURE LIMITS: No specific information available. HAZARDOUS COMPONENT ACGIH TLV OSHA PEL Potassium carbonate N.E. N.E. CARCINOGENICITY, REPRODUCTIVE EFFECTS: Not listed as carcinogen - IARC, NTP, or OSHA TERATOGENICITY, MUTAGENICITY: • • N.E. =Not Established N.A. =Not Applicable MSDS for BF-7L...Page 2 No effects listed. TOXICITY STUDIES: LD(50) 1870 mg/kg (oral rat) LC(50) N.E. SECTION V -FIRST AID PROCEDURES FOR EYES: Immediately flush eyes with lots of running water for 15 minutes, lifting the upper and lower eyelids occasionally. Get immediate medical attention. FOR SKIN: Immediately flush skin with running water for 15 minutes. Remove contaminated clothing and shoes; wash before wearing. Get medical attention. FOR INHALATION: Remove to fresh air. If breathing has stopped, give artificial respiration. Keep person warm, quiet and get medical attention. FOR INGESTION: Give plenty of water or fruit juice. DO NOT induce vomiting. Get medical attention. SECTION VI -PHYSICAL DATA APPEARANCE AND ODOR: SPECIFIC GRAVITY: VAPOR PRESSURE: VAPOR DENSITY (air=1): EVAPORATION RATE: BOILING POINT: FREEZING POINT: SOLUBILITY IN H2O: pH: Clear liquid, no odor 1.4 <15 ' N.E. Same as water 234°F N.E. Complete >13 SECTION VII -REACTIVITY DATA CHEMICAL STABILITY: Stable INCOMPATIBLE MATERIALS: Acids will cause formation of carbon dioxide HAZARDOUS POLYMERIZATION: Does not polymerize HAZARDOUS DECOMPOSITION PRODUCTS: Carbon dioxide SECTION VIII - SPECIAUPERSONAL PROTECTION N.E. =Not Established N.A. =Not Applicable MSDS for BF-7L...Page 3 VENTILATION: The use of mechanical ventilation is recommended whenever this product is used in a confined space. Where engineering controls are not feasible, assure use is in an area where there is natural air movement. RESPIRATORY PROTECTION: Not required PROTECTIVE GLOVES: Rubber or neoprene EYE PROTECTION: Goggles OTHER PROTECTIVE EQUIPMENT: Eyewash bottles or other rinsing equipment should be easily accessible. SECTION IX -HANDLING PRECAUTIONS LEAK AND SPILL PROCEDURES: Dike or contain spill to prevent material from entering waterways. Pump large spills into salvage containers. Soak up residue or small spills with absorbent pads, clay, or dirt and place in salvage containers. Residue may be neutralized with dilute acid before absorbent is used. WASTE DISPOSAL: If this product becomes a waste it does not meet the requirements of a RCRA hazardous waste. Always dispose of according to all local, state, and federal laws and regulations. HANDLING & SPECIAL EQUIPMENT: Do not get in eyes, on skin, or on clothing. STORAGE REQUIREMENTS: Store in a cool, dry, well-ventilated place. SECTION X -REGULATORY INFORMATION SHIPPING INFORMATION PROPER SHIPPING NAME: HAZARD CLASS: UN/NA NUMBER: PACKING GROUP W/ "PG": SUBSIDIARY RISK: REPORTABLE QUANTITY (RQ): EMERGENCY RESPONSE GUIDE #: ENVIRONMENTAL INFORMATION SARA TITLE III SECTION 302/304 SECTION 311/312 SECTION 313 Not DOT Regulated N.A. N.A. N.A. N.A. N.A. N.A. This product does not contain ingredients listed as an Extremely Hazardous Substance. Immediate This product does not contain ingredients (at a level of 1 % or greater) on the List of Toxic Chemicals. • N.E. =Not Established N.A. =Not Applicable MSDS for BF-7L...Page 4 OTHER REGULATORY INFORMATION TSCA INVENTORY: All of the components in this appear on the TSCA inventory. CALIFORNIA PROP 65: None of the chemicals on the current Proposition 65 list are known to be present in this product. The information contained herein is based on data considered accurate. However, no warranty is expressed or implied regarding the accuracy of these data or the results to be obtained from the use thereof. Vendor assumes no responsibility for injury to vendee or third persons proximately caused by the material if reasonable safety procedures are not adhered to as stipulated in the data sheet. Additionally, vendor assumes no responsibility for injury to vendee or third persons proximately caused by abnormal use of the material even if reasonable safety procedures are followed. Furthermore, vendee assumes the risk in his use of the material. Revision: 1 Status: Approved & Released MSDS Revision History: Revision: Sec/Para Changed Change Made: Date 1 NJA Initial Issue of Document Today 2 I Telephone number 08/04/00 3 VI pH 09-25-03 • t N.E. =Not Established N.A. =Not Applicable MSDS for BF-7L...Page 5 6LFC-5/-56/-5C/-5D Product Information SiIMUTAiION ' • s • GLFC-5, GLFC-5B, GLFC-5C, and GLFC-5D are Liquid Frac Concentrate slurried polymer suspensions used to prepare hydraulic fracturing fluid systems. They allow flexibility in job design and proppant staging to fit the customer's specific requirements. The nomenclature (5, 56, 5C, and 5D) denotes different buffer loadings used to optimize different hydraulic fracturing fluid systems. • The formulation includes ahighly-refined polymer and an exclusive suspension/hydration package that allow versatility in continuous-mix fracturing processes. GLFC-5 should be used in low- and high- temperature applications whereas GLFC-56 and GLFC-5C should be used in high-temperature applications. GLFC-5D can be used in all temperatures depending on water quality. • Fluid properties can be easily metered and monitored using automated systems. Maximum fluid quality is ensured as adjustments in fluid viscosity can be made while treatment is in progress (on-the-fly). • Very dispersible under low shear conditions. Rapidly develops viscosity, yielding clump-free polymer fluid. • Can prepare only fluid needed for treatment, thus eliminating unused "gelled" fluid disposal problems. • Creates on-the-job flexibility in fracture treatment design and proppant staging. • Reduces environmental concerns associated with surplus fluid disposal when used in the continuous-mix application as there is no pre-gelled fracturing fluid. Refer to Material Safety Data Sheet to determine appropriate handling of all chemicals used in XLFC formulations. Confidential Mixing instructions MSDS The above /eatures antl/or tlata are supplied solely (or inforntalional purposes antl BJ Services Company makes no guarantees or warranties, either expressed or implied, with respect to Iheir accuracy or use. All product warranties and guarantees snail Ue governed Uy the BJ Services Company standard at the time of sale or tlelivery ofservice. Actual protluct performance or availability depends on the timing and location of the job, the type of job and the padicular characteristics o/ each joD. 7nis document is controlled by the reference date. To ensure Thal This is the current version, please reference the Services section of the BJ Services ~Nebsife (www.Djservices.comj or ask your BJ representative. July 21, 2004 ~ BJ SERVICES COMPANY ~ ~ BJ SERVICES COMPANY Region: ~ MATERIAL SAFETY DATA SHEET usA SECTION I -GENERAL INFORMATION PRODUCT NAME: ITEM NUMBER CHEMICAL DESCRIPTION: PRODUCT USE: SUPPLIER: ADDRESS: EMERGENCY TELEPHONE NUMBER PREPARED BY: DATE PREPARED: Clay Master 5C 499808 Quaternary polyamines Clay control BJ Services Company 5500 Northwest Central Dr Houston TX 77092 (800)424-9300 for CHEMTREC (202)483-7616 Alaska and International BJ Services Environmental Group (281)351-8131 August 4, 2000 Supersedes:December 19, 1995 HMIS HAZARD INDEX HEALTH: 1 FLAMMABILITY: 1 REACTIVITY: 0 PERSONAL PROTECTION: d SECTION II -HAZARDOUS COMPONENTS HAZARDOUS COMPONENTS CAS # PERCENT HAZARD No hazardous ingredients N.A. N.A. N.A. SECTION III -FIRE AND EXPLOSION HAZARD DATA N.E. =Not Established N.A. =Not Applicable MSDS for Clay Master-5C...Page 1 FLASHPOINT (METHOD): >200°F (PMCC) UPPER EXPLOSION LIMIT(% BY VOL): N.E. LOWER EXPLOSION LIMIT(% BY VOL): N.E. AUTO-IGNITION TEMPERATURE: N.E. EXTINGUISHING MEDIA: Dry chemical, C02, water spray or regular foam SPECIAL FIRE FIGHTING PROCEDURES: This material may burn, but does not readily ignite. Move container from fire area if you can do so without risk. Apply cooling water to sides of containers that are exposed to flames until well after fire is out. Stay away from ends of containers. EXPLOSION DATA: None listed HAZARDOUS COMBUSTION PRODUCTS: May form oxides of carbon, nitrogen, and chlorine SECTION IV -HEALTH HAZARD DATA PRIMARY ROUTES OF ENTRY: Eye and skin contact, inhalation ACUTE OVEREXPOSURE EFFECTS: SKIN CONTACT: SKIN ABSORPTION EYE CONTACT: INHALATION: INGESTION: May cause mild irritation No effects listed May cause mild irritation May cause mild irritation May cause nausea CHRONIC OVEREXPOSURE EFFECTS: No effects listed EXPOSURE LIMITS: HAZARDOUS COMPONENT ACGIH TLV OSHA PEL No hazardous ingredients N.A. N.A. CARCINOGENICITY, REPRODUCTIVE EFFECTS: Not listed as carcinogenic - IARC, NTP, or OSHA TERATOGENICITY, MUTAGENICITY: N.E. =Not Established N.A. =Not Applicable MSDS for Clay Master-5C...Page 2 No effects listed TOXICITY STUDIES: LD(50) N.E. LC(50) N.E. SECTION V -FIRST AID PROCEDURES FOR EYES: Immediately flush with running water for at least 15 minutes. FOR SKIN: Wash with soap and water, removing clothing if contaminated FOR INHALATION: Remove to fresh air. If breathing is labored, give oxygen. If breathing has stopped, give artificial respiration. Keep person warm, quiet and get medical attention. FOR INGESTION: DO NOT INDUCE VOMITING. Give large amounts of water or milk to drink. Consult a physician for further instructions. SECTION VI -PHYSICAL DATA APPEARANCE AND ODOR: SPECIFIC GRAVITY: VAPOR PRESSURE: VAPOR DENSITY (air=1): EVAPORATION RATE: BOILING POINT: FREEZING POINT: SOLUBILITY IN H2O: pH: Clear amber liquid 1.144 N.E. N.E. N.E. N.E. N.E. Soluble 7 SECTION VII -REACTIVITY DATA CHEMICAL STABILITY: Stable INCOMPATIBLE MATERIALS: Strong oxidizers HAZARDOUS POLYMERIZATION: Does not polymerize HAZARDOUS DECOMPOSITION PRODUCTS: Oxides of carbon, nitrogen, and chlorine SECTION VIII - SPECIAL/PERSONAL PROTECTION VENTILATION: The use of mechanical ventilation is recommended whenever this product is used in a confined space. Where engineering controls are not feasible, assure use is in an area where there is natural air N.E. =Not Established N.A. =Not Applicable MSDS for Clay Master-5C...Page 3 movement. RESPIRATORY PROTECTION: None required under normal conditions. Use SCBA when entering tanks. PROTECTIVE GLOVES: Chemically resistant/non-slip EYE PROTECTION: Chemical safety goggles/safety glasses OTHER PROTECTIVE EQUIPMENT: Coveralls, splash aprons, eyewash bottles or other rinsing equipment should be easily accessible. SECTION IX -HANDLING PRECAUTIONS LEAK AND SPILL PROCEDURES: Stop leak if you can do it without risk. Take up with sand or other noncombustible absorbent material and place in DOT approved containers. WASTE DISPOSAL: If this product becomes a waste it does not meet the requirements of a RCRA hazardous waste. Always dispose of according to all local/state/and federal regulations. HANDLING & SPECIAL EQUIPMENT: Clean up spills promptly. Wash contaminated clothing. STORAGE REQUIREMENTS: No special recommendations. SECTION X -REGULATORY INFORMATION SHIPPING INFORMATION PROPER SHIPPING NAME: HAZARD CLASS: UN/NA NUMBER: PACKING GROUP W/ "PG": SUBSIDIARY RISK: REPORTABLE QUANTITY (RQ): EMERGENCY RESPONSE GUIDE #: Not DOT Regulated N.A. N.A. N.A. N.A. N.A. N.A. ENVIRONMENTAL INFORMATION SARA TITLE III SECTION 302/304 SECTION 311/312 SECTION 313 This product does not contain ingredients listed as an Extremely Hazardous Substance. Immediate This product does not contain ingredients (at a level of 1 % or greater) on the List of Toxic Chemicals. OTHER REGULATORY INFORMATION N.E. =Not Established N.A. =Not Applicable MSDS for Clay Master-SC...Page 4 TSCA INVENTORY: All of the components in this appear on the TSCA inventory. CALIFORNIA PROP 65: None of the chemicals on the current Proposition 65 list are known to be present in this product. The information contained herein is based on data considered accurate. However, no warranty is expressed or implied regarding the accuracy of these data or the results to be obtained from the use thereof. Vendor assumes no responsibility for injury to vendee or third persons proximately caused by the material if reasonable safety procedures are not adhered to as stipulated in the data sheet. Additionally, vendor assumes no responsibility for injury to vendee or third persons proximately caused by abnormal use of the material even if reasonable safety procedures are followed. Furthermore, vendee assumes the risk in his use of the material. Revision: 1 Status: Approved & Released MSDS Revision History: Revision: SeclPara Changed Change Made: Date 1 N/A Initial Issue of Document Today 2 I Telephone number 08/04!00 • • N.E. =Not Established N.A. =Not Applicable MSDS for Clay Master-SC...Page 5 E , BJ SERVICES COMPANY Region: MATERIAL SAFETY DATA SHEET usA 1 PRODUCT AND COMPANY IDENTIFICATION Product Name: GLFC-5D Item Number: 398373 Product Use: Gellant -Water Supplier: BJ Services Company 5500 Northwest Central Dr Houston, TX 77092 (281)351-8131 IN CASE OF EMERGENCY CALL: (800) 424-9300 for CHEMTREC (703) 527-3887 for International HMIS HAZARD INDEX HEALTH: 1 FLAMMABILITY: 1 REACTIVITY: 0 PERSONAL PROTECTION: h 2 COMPOSITION/INFORMATION ON INGREDIENTS Hazardous Component CAS# Percent Hazard Alkanes / Alkenes Multiple 45 - 50 Irritant Guar gum 009000-30-0 45 - 50 Irritant 3 HAZARDS IDENTIFICATION PRIMARY ROUTES OF EXPOSURE: Inhalation. Skin contact. Eye contact. ACUTE OVEREXPOSURE EFFECTS: • MSDS for GLFC-5D Page 1 INHALATION: May cause central nervous system depression. INGESTION: Product has a low order of acute oral toxicity, but minute amounts aspirated into the lungs during ingestion may cause severe pulmonary injury or death. EYE CONTACT: May cause mild eye irritation. SKIN CONTACT: May cause mild skin irritation. Prolonged contact may cause drying of skin. EXPOSURE LIMITS: HAZARDOUS COMPONENT ACGIH TLV OSHA PEL LC50 (inhalation) LD50 (oral) Alkanes / Alkenes 5 mg/m3 5 mg/m3 NA . ' NA ,Guar gum ' NA NA NA ' 6770 mg/kg rat 4 FIRST AID MEASURES INHALATION: If inhaled, remove to fresh air. If not breathing give artificial respiration, preferably mouth-to-mouth. If breathing is difficult give oxygen. Only trained personnel should administer oxygen. Get medical attention. INGESTION: DO NOT induce vomiting. Get medical attention! If vomiting occurs, keep head lower than hips to prevent aspiration. EYES: In case of contact, immediately flush eyes with plenty of water for at least 15 minutes and get medical attention. SKIN: Flush skin with water or soap and water, if available, for at least 15 minutes. Remove contaminated clothing and shoes. Seek medical attention if irritation persists. 5 FIRE FIGHTING MEASURES FLASHPOINT (METHOD): > 200°F (SPCC) LOWER EXPLOSION LIMIT (% v!v): Not applicable/available UPPER EXPLOSION LIMIT (% v/v): Not applicable/available AUTO-IGNITION TEMPERATURE: Not available/applicable SPECIAL HAZARDS: None. EXTINGUISHING MEDIA: On small fires, dry chemical, dry sand, or C02 may also be effective in large quantities. For large fire, water spray or fog. Foam. SPECIAL FIREFIGHTING PROCEDURES: MSDS for GLFC-5D Page 2 Cool exposed containers with water spray. Fire-fighters should wear self-contained breathing apparatus and full protective clothing when fighting chemical fires HAZARDOUS COMBUSTION PRODUCTS: Oxides of carbon. 6 ACCIDENTAL RELEASE MEASURES Dike to contain. Cover spill with absorbent material. Scoop absorbed material into a suitable container for disposal. 7 HANDLING AND STORAGE HANDLING: Avoid contact with skin and eyes. Do not inhale vapors. STORAGE REQUIREMENTS: Keep container closed when not in use. Keep away from ignition sources. 8 EXPOSURE CONTROLS/PERSONAL PROTECTION SPECIFIC ENGINEERING CONTROLS: Adequate ventilation should be provided to keep concentrations below acceptable exposure limit. PERSONAL PROTECTIVE EQUIPMENT: Appropriate respiratory protection shall be worn when applied engineering controls are not adequate to protect against inhalation exposure. Safety glasses. Neoprene gloves. Rubber gloves. 9 PHYSICAL AND CHEMICAL PROPERTIES PHYSICAL STATE: COLOR: ODOR: ODOR THRESHOLD: SPECIFIC GRAVITY: VAPOR PRESSURE: VAPOR DENSITY (air = 1): EVAPORATION RATE: BOILING POINT: FREEZING POINT: pH: VISCOSITY (F): SOLUBILITY IN WATER: Liquid light brown, Tan Mild Hydrocarbon Not available/applicable 1.00 - 1.01 Not available/applicable Not available/applicable Not available/applicable Not available/applicable Not available/applicable Not available/applicable Not available/applicable Insoluble 10 STABILITY AND REACTIVITY • MSDS for GLFC-5D Page 3 STABILITY: Stable. INCOMPATIBILITY/CONDITIONS OF REACTIVITY: Strong oxidizers. HAZARDOUS THERMAL DECOMPOSITION PRODUCTS: Carbon monoxide. Carbon dioxide. HAZARDOUS POLYMERIZATION: Will not occur. 11 TOXICOLOGICAL PROPERTIES i CHRONIC EFFECTS: None known. SENSITIZATION: Not known. CARCINOGENICITY: None of the components of this product have been listed as carcinogenic by IARC, NTP or OSHA (IARC- International Agency for Research on Cancer) (NTP - National Toxicology Program) (OSHA -Occupational Safety & Health Administration (US)) MUTAGENICITY: Not known. REPRODUCTIVE TOXICITY: • Not known. 12 ECOLOGICAL INFORMATION No specific information available 13 DISPOSAL CONSIDERATIONS WASTE DISPOSAL: MSDS for GLFC-5D Page 4 As local regulations may vary; all waste must be disposedlrecycled/reclaimed in accordance with federal, state, and local environmental control regulations. 14 TRANSPORT INFORMATION LAND TRANSPORT (DOT) Proper Shipping Name: NOT RESTRICTED UN No.: NA AIR TRANSPORT (ICAO/IATA) Proper Shipping Name: NOT RESTRICTED UN/ID No.: NA MARINE TRANSPORT (IMDG/IMO) Proper Shipping Name: NOT RESTRICTED UN/ID No.: NA 15 REGULATORY INFORMATION SARA TITLE III: SECTION 3021304 This product does not contain substances listed in Appendix A and B as an Extremely Hazardous Substance. SECTION 311/312 Immediate SECTION 313 This product does not contain ingredients (at a level of 1 % or greater) on the List of Toxic Chemicals. TSCA INVENTORY: The substances in this product are included on or exempted from the TSCA 8(b) Inventory (40 CFR 710) CALIFORNIA PROP 65: This product does not contain substances which require warning under California Proposition 65. 16 OTHER INFORMATION ISSUE DATE: 12/14/2004 PREPARED BY: BJ SERVICES ENVIRONMENTAL GROUP REFERENCES: Suppliers' Literature. Suspect Chemicals Sourcebook Guide to Occupational Exposure Values - 2004, American Conference of Governmental Industrial Hygienists, 2004. Dangerous Properties of Industrial Materials, 9th ed.; N. Irving Sax, 1996. The information contained herein is based on data considered accurate. However, no warranty is expressed or implied regarding the accuracy of these data or the results to be obtained from the use thereof. Vendor assumes no responsibility for injury to vendee or third persons proximately caused by the material i1 MSDS for GLFC-5D Page 5 reasonable safety procedures are not adhered to as stipulated in the data sheet Additionally, vendor assumes no responsibility for injury to vendee or third persons proximately caused by abnormal use of the material even if reasonable safety procedures are followed Furthermore, vendee assumes the risk in his use of the material. Revision: 1 Status: Approved & Released MSDS Revision History: Revision: Sec/Para Changed Change Made: Date 1 N/A Initial Issue of Document Today • • MSDS for GLFC-5D Page 6 ~ ~ BJ SERVICES COMPANY CANADA Region: MATERIAL SAFETY DATA SHEET Canada SECTION I -PRODUCT INFORMATION Product Name: Enzyme G Solutions Product Use: Frac gel breaker. Chemical Family: Enzyme solution. Supplier: BJ Services Company Canada 1300, 801 - 6th Avenue SW Calgary, Alberta, Canada T2P 4E1 Phone: (403)531-5151 IN CASE OF EMERGENCY CALL: (403) 531-5151 (24 hrs) SECTION II -HAZARDOUS INGREDIENTS In redient AS # % CGIH TWA: CGIH STEL: Non-hazardous 100 NA NA NA =Not available SECTION III -PHYSICAL AND CHEMICAL PROPERTIES PHYSICAL STATE: Liquid SPECIFIC GRAVITY: COLOR: Clear, colorless to pale yellow VAPOR PRESSURE: 1.0 Not available • MSDS for Enzyme G Solutions...Page 1 UNCONTROLLED COPY ODOR: None ODOR THRESHOLD: Not applicable FREEZING POINT: ~ 0°C SOLUBILITY IN WATER: Miscible. COEFFICIENT OF WATER/OIL DISTRIBUTION: > 1 VAPOR DENSITY (air=1) EVAPORATION RATE: BOILING POINT: pH: SECTION IV -FIRE AND EXPLOSION DATA NFPA-FLAMMABILITY CODE: 0 FLASHPOINT (METHOD): None LOWER EXPLOSION LIMIT (% v/v): Not applicable UPPER EXPLOSION LIMIT (% v/v): Not applicable AUTO-IGNITION TEMPERATURE: Not applicable SPECIAL HAZARDS: None. EXTINGUISHING MEDIA: Use appropriate media for surrounding fire. Not available Not available 100°C 7 SPECIAL FIREFIGHTING PROCEDURES: None required; however, when fighting chemical fires, self-contained breathing apparatus and protective clothing is recommended. HAZARDOUS COMBUSTION PRODUCTS: None. SENSITIVITY TO STATIC DISCHARGE: No SENSITIVITY TO MECHANICAL IMPACT: No SECTION V -STABILITY AND REACTIVITY STABILITY: Stable under normal conditions of use. INCOMPATIBILITY/CONDITIONS OF REACTIVITY: None known. MSDS for Enzyme G Solutions...Page 2 UNCONTROLLED COPY HAZARDOUS THERMAL DECOMPOSITION PRODUCTS: None known. HAZARDOUS POLYMERIZATION: Will not occur. SECTION VI -TOXICOLOGICAL PROPERTIES PRIMARY ROUTES OF EXPOSURE: Eye contact. Skin contact. ACUTE OVEREXPOSURE EFFECTS: INHALATION: Not a likely exposure route. INGESTION: Not a likely exposure route. Product has low oral toxicity. EYE CONTACT: May cause mild eye irritation. SKIN CONTACT: Prolonged contact may cause mild irritation. CHRONIC EFFECTS: None known. SENSITIZATION: Not known. CARCINOGENICITY: None of the components of this product have been listed as carcinogenic by IARC, NTP or OSHA. IARC-International Agency for Research on Cancer NTP -National Toxicology Program OSHA - Occupational Safety & Health Administration (US) • MUTAGENICITY: Not known. REPRODUCTIVE TOXICITY: Not known. SYNERGISTIC PRODUCTS: None known. SECTION VII -PREVENTATIVE MEASURES SPECIFIC ENGINEERING CONTROLS: Use only in well ventilated area. PERSONAL PROTECTIVE EQUIPMENT: Chemical resistant goggles. Rubber gloves. Coveralls. MSDS for Enzyme G Solutions...Page 3 UNCONTROLLED COPY HANDLING: Wear specified protective equipment. STORAGE REQUIREMENTS: Protect from freezing. ACTION TO BE TAKEN IF MATERIAL IS RELEASED OR SPILLED: Wear specified protective equipment. Small spills -Cover spill with absorbent material. Scoop absorbed material into a suitable container for disposal. Large spills -Dike to contain. Recover product to suitable containers or vessel for reuse, if possible, or for disposal. WASTE DISPOSAL: Consult local waste authorities for direction and/or approvals prior to disposal. SPECIAL SHIPPING INFORMATION: Comply with all local, federal and international transportation regulations. SECTION VIII -FIRST AID MEASURES INHALATION: If inhaled, remove from area to fresh air. Get medical attention if respiratory irritation develops or if breathing becomes difficult. INGESTION: Rinse mouth out with water. Drink plenty of water. If large quantities were ingested, seek medical advice. EYES: Flush eyes with plenty of water and get medical attention if irritation persists. SKIN: • Flush skin with water. Remove contaminated clothing and launder before reuse. SECTION IX -CLASSIFICATION SHIPPING NAME: NOT RESTRICTED UN NUMBER: NA MSDS for Enzyme G Solutions...Page 4 UNCONTROLLED COPY TDGR NA AIR-ICAO/IATA NA SEA-IMOIIMDG NA WHMIS Not controlled SECTION X -PREPARATION INFORMATION ISSUE DATE: 19/11/2003 SUPERSEDES: 02/11 /2000 REVISIONS: General review. PREPARED BY: Chemical Technology Centre REFERENCES: Suppliers' Literature. Dangerous Properties of Industrial Materials, 9th ed.; N. Irving Sax, 1996. CCINFOdisc (Core Collection), Canadian Centre for Occupational Health and Safety, 2001. International Marine Dangerous Goods Code, 2002 Edition, International Maritime Organisation, 2002. Dangerous Goods Regulations, 43rd ed., International Air Transport Association, 2002. TDG Clear Language Regulations, as published in the Canada Gazette Part II, August 2001. Revision: 2 Status: Approved 8~ Released MSDS • Revision History: Revision: Sec/Para Changed Change Made: Date 1 N/A Initial Issue of Document 02/11/00 2 N/A General review. 19/11/03 MSDS for Enzyme G Solutions...Page 5 UNCONTROLLED COPY MSDS for Enzyme G Solutions...Page 6 UNCONTROLLED COPY ~ ~ BJ SERVICES COMPANY Region: ~ MATERIAL SAFETY DATA SHEET usA SECTION I -GENERAL INFORMATION PRODUCT NAME: ITEM NUMBER: CHEMICAL DESCRIPTION: PRODUCT USE: SUPPLIER: ADDRESS: EMERGENCY TELEPHONE NUMBER PREPARED BY: DATE PREPARED: Flo-Back 30 • 488255, 488327 Surfactant Surface tension reducer, surfactant BJ Services Company 5500 Northwest Central Dr Houston TX 77092 (800)424-9300 for CHEMTREC (703)527-3887 Alaska and International BJ Services Environmental Group (281)351-8131 April 30, 2004 Supersedes: August 31, 2000 HMIS HAZARD INDEX HEALTH: 1 FLAMMABILITY: 0 REACTIVITY: 0 PERSONAL PROTECTION: b • SECTION II -HAZARDOUS COMPONENTS HAZARDOUS COMPONENTS CAS # PERCENT HAZARD No hazardous ingredients N.A. N.A. N.A. N.E. =Not Established N.A. =Not Applicable MSDS for Flo-Back 30...Page 1 SECTION III -FIRE AND EXPLOSION HAZARD DATA FLASHpOINT (METHOD): UPPER EXPLOSION LIMIT(% BY VOL): LOWER EXPLOSION LIMIT(% BY VOL) AUTO-IGNITION TEMPERATURE: EXTINGUISHING MEDIA: SPECIAL FIRE FIGHTING PROCEDURES EXPLOSION DATA: HAZARDOUS COMBUSTION PRODUCTS None N.E. N.E. N.E. This product is not expected to burn unless all the water is boiled away for surrounding fire. Use water to cool fire exposed containers. None Carbon monoxide during combustion SECTION IV -HEALTH HAZARD DATA PRIMARY ROUTES OF ENTRY: Skin and eye contact ACUTE OVEREXPOSURE EFFECTS: SKIN CONTACT: SKIN ABSORPTION EYE CONTACT: INHALATION: INGESTION: Use media appropriate Brief contact may cause mild irritation. Prolonged contact may cause severe irritation and dermatitis. Not absorbed by skin. May cause slight to moderate irritation. Not expected to pose an inhalation hazard. May cause irritation to the membranes of the mouth, cramps and diarrhea may occur. CHRONIC OVEREXPOSURE EFFECTS: None known EXPOSURE LIMITS: throat, and gastrointestional tract. Nausea, vomiting, HAZARDOUS COMPONENT ACGIH TLV OSHA PEL No hazardous ingredients N.E. N.E. • N.E. =Not Established N.A. =Not Applicable MSDS for Flo-Back 30...Page 2 CARCINOGENICITY, REPRODUCTIVE EFFECTS Not listed as carcinogenic - IARC, NTP, or OSHA TERATOGENICITY, MUTAGENICITY: No effects listed. TOXICITY STUDIES: LD(50) N.E. LC(50) N.E. SECTION V -FIRST AID PROCEDURES FOR EYES: Immediately flush with plenty of water for at least 15 minutes. If irritation persists, contact a physician. FOR SKIN: Flush skin with water or wash with mild soap and water if available. If irritation persists, contact a physician. FOR INHALATION: Remove to fresh air. If breathing has stopped, give artificial respiration. Keep person warm, quiet and get medical attention. FOR INGESTION: Do not induce vomiting. If vomiting occurs spontaneously, keep victim's head below hips to prevent aspiration into the lungs. Give large quantities of water to dilute. Never give anything by mouth to an unconscious or convulsing person. Seek immediate medical attention. SECTION VI -PHYSICAL DATA APPEARANCE AND ODOR: SPECIFIC GRAVITY: VAPOR PRESSURE: VAPOR DENSITY (air=1): EVAPORATION RATE: BOILING POINT: FREEZING POINT: SOLUBILITY IN H2O: pH: Pale yellow liquid with mild odor 1.16 N.E. N.E. N.E. Approx. 235°F < 0°F Complete N.E. SECTION VII -REACTIVITY DATA CHEMICAL STABILITY: Stable INCOMPATIBLE MATERIALS: Strong oxidizing agents HAZARDOUS POLYMERIZATION: Does not polymerize • • N.E. =Not Established N.A. =Not Applicable MSDS for Flo-Back 30...Page 3 HAZARDOUS DECOMPOSITION PRODUCTS: Carbon monoxide during combustion SECTION VIII - SPECIAL/PERSONAL PROTECTION VENTILATION: The use of mechanical ventilation is recommended whenever this product is used in a confined space. Where engineering controls are not feasible, assure use is in an area where there is natural air movement. RESPIRATORY PROTECTION: Not normally required under conditions of normal use. PROTECTIVE GLOVES: Rubber or neoprene EYE PROTECTION: Goggles OTHER PROTECTIVE EQUIPMENT: Eyewash bottles or other rinsing equipment should be easily accessible. SECTION IX -HANDLING PRECAUTIONS LEAK AND SPILL PROCEDURES: Dike or contain spill to prevent material from entering watenlvays. Pump large spills into salvage containers. Soak up residue or small spills with absorbent pads, clay, or dirt and place in salvage containers. WASTE DISPOSAL: If this product becomes a waste it does not meet the requirements of a RCRA hazardous waste. Always dispose of according to local/state/federal regulations. HANDLING & SPECIAL EQUIPMENT: Do not get in eyes, on skin or clothing. Do not take internally. STORAGE REQUIREMENTS: Keep container closed when not in use. Store drums with the bung up. Carefully vent container before removing bung. Wash thoroughly after handling. SECTION X -REGULATORY INFORMATION SHIPPING INFORMATION PROPER SHIPPING NAME: HAZARD CLASS: UN/NA NUMBER: PACKING GROUP W/ "PG": SUBSIDIARY RISK: REPORTABLE QUANTITY (RQ): EMERGENCY RESPONSE GUIDE #: Not DOT Regulated N.A. N.A. N.A. N.A. N.A. N.A. .7 • ENVIRONMENTAL INFORMATION N.E. =Not Established N.A. =Not Applicable MSDS for Flo-Back 30...Page 4 SARA TITLE III SECTION 302/304 This product does not contain ingredients listed as an Extremely Hazardous Substance. SECTION 311/312 N.A. SECTION 313 This product does not contain ingredients (at a level of 1% or greater) on the List of Toxic Chemicals. OTHER REGULATORY INFORMATION TSCA INVENTORY: All of the components in this appear on the TSCA inventory. CALIFORNIA PROP 65: None of the chemicals on the current Proposition 65 list are known to be present in this product. The information contained herein is based on data considered accurate. However, no warranty is expressed or implied regarding the accuracy of these data or the results to be obtained from the use thereof. Vendor assumes no responsibility for injury to vendee or third persons proximately caused by the material if reasonable safety procedures are not adhered to as stipulated in the data sheet. Additionally, vendor assumes no responsibility for injury to vendee or third persons proximately caused by abnormal use of the material even if reasonable safety procedures are followed. Furthermore, vendee assumes the risk in his use of the material. Revision: 1 Status: Approved & Released MSDS Revision History: Revision: SeclPara Changed Change Made: Date 1 N/A Initial Issue of Document Today 2 I Dropped experimental designation 11-13-98 3 I Telephoone number 08/31100 4 I Added item #, changed phone # for Int'I Chemtrec 04/30/04 • ~~ ~J N.E. =Not Established N.A. =Not Applicable MSDS for Flo-Back 30.:.Page 5 • • Operator: Well 1Vame: Date: PRODUCT DESCRIPTIONS AquaCon Concentrate Aquacon is a relative permeability modifier. Used to control water due to high perm streaks or early coning in oil and gas well. BC-3 BC-3 is a clear, colorless liquid that is designed to assist the degradation of alkaline pH fracturing fluids. Usage can be from 70 deg F to 300 deg F (21 deg C- 149 deg C) when proper testing is performed. It can be used with enzyme breakers to lower pH of the system and allow the enzymes to work more effectively without damaging the enzymes. BF-7L A liquid pH control agent used to adjust fracturing gels into the pH range of 8.5 to 10.5. This product was designed to retain its buffering capacity at high temperatures. Breaker AC-30% Breaker AC-30% is a hydrocarbon fluid that is used as a breaker in for surfactant fracturing systems. Clay Master-5C A concentrated low molecular weight polyamine used in water, brine or acids to protect the formation against damage due to clay swelling, sloughing and migration. Enzyme G-I A patented, polymer specific enzyme breaker custom formulated to degrade polymer into non-damaging components. FAC-1 W A surfactant gelling agent for HCI at low to moderate reservoir temperatures. The gellant provides a clean, solids free gel for HCI and the viscosity breaks as the acid is being spent on the reservoir. FAC-3W A surfactant gelling agent for low to moderate reservoir temperatures. The gellant provides a clean and solids free gel. Flo-Back 30 Recovery of aqueous fracturing fluids can pose special problems, particularly in tight reservoirs with low bottomhole pressures. Flo-Back 30, a non-ionic liquid surfactant, relieves those problems by substantially increasing the fluid recovery rate for all aqueous fracturing fluids, including foamed, gelled and crosslinked systems, as well as matrix acidizing fluids. Potassium Chloride A granular salt used to reduce clay swelling caused by water-base cementing fluids. Sand, White, 20/40 An excellent quality, well rounded quartz sand, commonly known as "Ottawa". Color variation, which has been construed as less than desirable, is common for these sands and has no apparent impact on their strength. It is used in low to moderate closure pressure situations. ~.~~,,,P,~„~P~o~ Au,~~,; zooa,229pM Page 15 ~,4~6~ STIMULATION .CEMENTING ,COMPLETION SERVICES ,SERVICE TOOLS < COILED TUBING PRODUCTION CHEMICALS .CASING AND TUBING RUNNING SERVICES ,PIPELINE SERVICES .WELL CONTROL .CHEMICAL SERVICES • Operator: Well Name: Date: i PRODUCT DESCRIPTIONS (Continued) GLFC-5 A high yield guar gum gelling agent blended with a buffering system, slurried in a Mineral oil. Used to prepare hydraulic fracturing fluid systems. XLW-32 A liquid Borate crosslinker (Boric Acid) used in gel systems. Xcide-207 A non-ionic isothiasolin bacteriacide in a convenient, solid granular form. It provides broad spectrum control of slime forming and sulfate-reducing bacteria in oilfield waters. FAC-2 A surfactant gelling agent for low to moderate reservoir temperatures. The gellant provides a clean and solids free gel. GW-21 GW-21 is ahigh-viscosity, derivatized cellulose polymer. This polymer can be used in virtually all types of gravelpack completions and workovers, as well as viscous hole sweeps in horizontal drilling, fluid loss control and rheology control Report PniiMd on' :~Fxi117. 20081229 PM Page 16 Gr4lo'3 STIMULATION , CEMENTING o COMPLETION SERVICES e SERVICE TOOLS e COILED TUBING PRODUCTION CHEMICALS .CASING AND TUBING RUNNING SERVICES o PIPELINE SERVICES a WELL CONTROL .CHEMICAL SERVICES i ~ ~ BJ SERVICES COMPANY Region: MATERIAL SAFETY DATA SHEET usA SECTION I -GENERAL INFORMATION PRODUCT NAME: ITEM NUMBER CHEMICAL DESCRIPTION: PRODUCT USE: SUPPLIER: ADDRESS: EMERGENCY TELEPHONE NUMBER PREPARED BY: DATE PREPARED: Potassium Chloride (KCI) • 100114, 85-000000013370 Potassium Chloride CAS # 7447-40-7 Salt BJ Services Company 5500 Northwest Central Dr Houston TX 77092 (800)424-9300 for CHEMTREC (703)527-3887 Alaska and International BJ Services Environmental Group (281)351-8131 October 28, 2003 Supersedes: November 9, 2000 HMIS HAZARD INDEX HEALTH: 0 FLAMMABILITY: 0 REACTIVITY: 0 PERSONAL PROTECTION: b • SECTION II -HAZARDOUS COMPONENTS HAZARDOUS COMPONENTS CAS # PERCENT HAZARD No hazardous ingredients N.A. N.A. N.A. N.E. =Nat Established N.A. =Not Applicable MSDS for Potassium Chloride (KCI)...Page 1 SECTION III -FIRE AND EXPLOSION HAZARD DATA FLASHPOINT (METHOD): UPPER EXPLOSION LIMIT(% BY VOL): LOWER EXPLOSION LIMIT(% BY VOL): AUTO-IGNITION TEMPERATURE: EXTINGUISHING MEDIA: SPECIAL FIRE FIGHTING PROCEDURES: EXPLOSION DATA: HAZARDOUS COMBUSTION PRODUCTS: N.A. N.A. N.A. N.A. Does not support combustion Non-Flammable N.A. N.A. SECTION IV -HEALTH HAZARD DATA PRIMAF2Y ROUTES OF ENTRY: Skin and eye contact, inhalation, ingestion ACUTE OVEREXPOSURE EFFECTS: SKIN CONTACT: Can cause irritation SKIN ABSORPTION: Not absorbed by skin. EYE CONTACT: Eye contact may cause irritation and redness. INHALATION: Inhalation of high levels of vapors or mists may cause unconsciousness. INGESTION: Ingestion can cause gastrointestinal irritation, nausea or vomiting. lightheadedness, dizziness, headaches or CHRONIC OVEREXPOSURE EFFECTS: Inhalation results in unpleasant deposits in nasal passages EXPOSURE LIMITS: HAZARDOUS COMPONENT ACGIH TLV OSHA PEL No hazardous ingredients 10 mg/m3 dust 15 mg/m3 dust CARCINOGENICITY, REPRODUCTIVE EFFECTS: Not listed as carcinogen - IARC, NTP, or OSHA • N.E. =Not Established N.A. =Not Applicable MSDS for Potassium Chloride (KCI)...Page 2 TERATOGENICITY, MUTAGENICITY: No effects known TOXICITY STUDIES: LD(50) 2430 mg/kg (oral rat) LC(50) N.E. SECTION V -FIRST AID PROCEDURES FOR EYES: Immediately flush with plenty of water for at least 15 minutes. If irritation persists, contact a physician. FOR SKIN: Flush skin with water or wash with mild soap and water if available. If irritation persists, contact a physician. FOR INHALATION: Remove to fresh air. If breathing has stopped, give artificial respiration. Keep person warm, quiet and get medical attention. FOR INGESTION: Give plenty of water. Induce vomiting! Never give anything to an unconscious person. Call a physician. SECTION VI -PHYSICAL DATA APPEARANCE AND ODOR: SPECIFIC GRAVITY: VAPOR PRESSURE: VAPOR DENSITY (air=1): EVAPORATION RATE: BOILING POINT: FREEZING POINT: SOLUBILITY IN H2O: pH: White, crystalline material, no odor 1.99 N.A. N.A. N.A. N.A. N.A. Complete 9.2 (1 % Solution) SECTION VII -REACTIVITY DATA CHEMICAL STABILITY: Stable INCOMPATIBLE MATERIALS: N.A. HAZARDOUS POLYMERIZATION: Does not polymerize HAZARDOUS DECOMPOSITION PRODUCTS: N.A. SECTION VIII - SPECIAL/PERSONAL PROTECTION • • N.E. =Not Established N.A. =Not Applicable MSDS for Potassium Chloride (KCI)...Page 3 VENTILATION: The use of mechanical ventilation is recommended whenever this product is used in a confined space. Where engineering controls are not feasible, assure use is in an area where there is natural air movement. RESPIRATORY PROTECTION: Dust mask if needed PROTECTIVE GLOVES: Neoprene EYE PFOTECTION: Glasses OTHER PROTECTIVE EQUIPMENT: None SECTION IX -HANDLING PRECAUTIONS LEAK AND SPILL PROCEDURES: Sweep up and place in suitable containers. WASTE DISPOSAL: If this product becomes a waste it does not meet the requirements of a RCRA hazardous waste. Always dispose of according to local/state/federal regulations. HANDLING & SPECIAL EQUIPMENT: None STORAGE REQUIREMENTS: None SECTION X -REGULATORY INFORMATION SHIPPING INFORMATION PROPER SHIPPING NAME: HAZARD CLASS: UN/NA NUMBER: PACKING GROUP W/ "PG": SUBSIDIARY RISK: REPORTABLE QUANTITY (RQ): EMERGENCY RESPONSE GUIDE #: ENVIRONMENTAL INFORMATION SARA TITLE III Not DOT Regulated N.A. N.A. N.A N.A. N.A. N.A. SECTION 302/304 This product does not contain ingredients listed as an Extremely Hazardous Substance. SECTION 311/312 Immediate SECTION 313 This product does not contain ingredients (at a level of 1 % or greater) on the List of Toxic Chemicals. OTHER REGULATORY INFORMATION • • N.E. =Not Established N.A. =Not Applicable MSDS for Potassium Chloride (KCI)...Page 4 TSCA INVENTORY: All of the components in this appear on the TSCA inventory. CALIFORNIA PROP 65: None of the chemicals on the current Proposition 65 list are known to be present in this product. The information contained herein is based on data considered accurate. However, no warranty is expressed or implied regarding the accuracy of these data or the results to be obtained from the use thereof. Vendor assumes no responsibility for injury to vendee or third persons proximately caused by the material if reasonable safety procedures are not adhered to as stipulated in the data sheet. Additionally, vendor assumes no responsibility for injury to vendee or third persons proximately caused by abnormal use of the material even if reasonable safety procedures are followed. Furthermore, vendee assumes the risk in his use of the material. Revision: 1 Status: Approved & Released MSDS Revision History: Revision: Sec/Para Changed Change Made: Date 1 N/A Initial Issue of Document Today 2 I Telephone number 11/9/00 3 t Chemtrec number, added item number 10/28/03 • N.E. =Not Established N.A. =Not Applicable MSDS for Potassium Chloride (KCI)...Page 5 ~ ~ BJ SERVICES COMPANY Region: ~ MATERIAL SAFETY DATA SHEET usA SECTION I -GENERAL INFORMATION PRODUCT NAME: ITEM NUMBER: CHEMICAL DESCRIPTION: PRODUCT USE: SUPPLIER: ADDRESS: EMERGENCY TELEPHONE NUMBER PREPARED BY: DATE PREPARED: XLW-32 a 499630, 499796 Boric oxide in methanol Crosslinker BJ Services Company 5500 Northwest Central Dr Houston TX 77092 (800)424-9300 for CHEMTREC (202)483-7616 Alaska and International BJ Services Environmental Group (281)351-8131 November 10, 2000 Supersedes: June 14, 1999 HMIS HAZARD INDEX HEALTH: 2 FLAMMABILITY: 3 REACTIVITY: 0 PERSONAL PROTECTION: b • SECTION II -HAZARDOUS COMPONENTS HAZARDOUS COMPONENTS CAS # PERCENT HAZARD Methanol Boric oxide 67-56-1 1303-86-2 < 90 < 20 Flammable Toxic N.E. =Not Established N.A. =Not Applicable MSDS for XLW-32...Page 1 SECTION III -FIRE AND EXPLOSION HAZARD DATA FLASHPOINT (METHOD): 68°F (TCC) UPPER EXPLOSION LIMIT(% BY VOL): N.E. LOWER EXPLOSION LIMIT(% BY VOL): N.E. AUTO-IGNITION TEMPERATURE: N.E. EXTINGUISHING MEDIA: C02, dry chemical, water spray/fog, or foam. Use water to keep containers cool. Isolate "fuel" supply from fire. Contain fire fighting liquids for proper disposal. SPECIAL FIRE FIGHTING PROCEDURES: Do not enter confined fire space without proper personal protective equipment including NIOSH approved self-contained breathing apparatus with full facepiece operated in the positive pressure demand mode. Do not inject a solid stream of water or foam into hot, burning pools; this may cause splattering and increase fire intensity. Evacuate personnel to a safe area. Keep unnecessary people away. EXPLOSION DATA: This material is volatile and readily gives off vapors that may travel along the ground or be moved by ventilation and ignited by pilot lights, other flames, sparks, heaters, smoking, electrical motors, static discharge, or other ignition sources at locations distant from material handling point. Never use welding or cutting torch on or near drum (even empty) because product (even just residue) can ignite explosively. Containers may explode from internal pressure if confined to fire. Keep containers cool. Keep unnecessary people away. HAZARDOUS COMBUSTION PRODUCTS: Smoke, carbon monoxide and carbon dioxide SECTION IV -HEALTH HAZARD DATA PRIMARY ROUTES OF ENTRY: Skin and eye contact, inhalation ACUTE OVEREXPOSURE EFFECTS: SKIN CONTACT: May produce skin irritation, redness, peeling, defatting and dermatitis. SKIN ABSORPTION: Exposure to this material can result in absorption through skin causing a health hazard. EYE CONTACT: May cause moderate irritation, including burning sensation, tearing, redness, swelling and blurred vision. INHALATION: Overexposure may cause coughing, shortness of breath, dizziness, intoxication and collapse. Can cause nasal and respiratory irritation, weakness, fatigue, headache, and possible unconsciousness and even death. INGESTION: Can cause gastrointestinal irritation, acidosis, nausea, vomiting, diarrhea, ocular toxicity ranging from diminished visual capacity to complete blindness, and death. CHRONIC OVEREXPOSURE EFFECTS: May cause liver abnormalities, kidney damage, eye damage, lung damage, brain damage and nervous system damage. EXPOSURE LIMITS: • N.E. =Not Established N.A. =Not Applicable MSDS for XLW-32...Page 2 HAZARDOUS COMPONENT ACGIH TLV OSHA PEL Methanol N.E. 200 mg/m3 Boric oxide N.E. 10 mg/m3 CARCINOGENICITY, REPRODUCTIVE EFFECTS: Not listed as carcinogenic - IARC, NTP, or OSHA TERATOGENICITY, MUTAGENICITY: No effects listed TOXICITY STUDIES: LD(50) N.E. LC(50) N.E. SECTION V -FIRST AID PROCEDURES FOR EYES: Flush eyes immediately with large amounts of water for at least 15 minutes. Lift lower and upper lids occasionally. Get medical attention. FOR SKIN: Wash with soap and water. Remove contaminated clothing and launder contaminated clothing before reuse. Get medical attention if redness or irritation develops. FOR INHALATION: Remove to fresh air. If breathing is labored, give oxygen. If breathing has stopped, give artificial respiration. Keep person warm, quiet and get medical attention. FOR INGESTION: Call a physician immediately. Give victim a glass of water. DO NOT induce vomiting unless instructed by a physician or poison control center. Never give anything by mouth to an unconscious person. SECTION VI -PHYSICAL DATA APPEARANCE AND ODOR: Clear, colorless liquid; alcohol odor SPECIFIC GRAVITY: 0.885 VAPOR PRESSURE: N.E. VAPOR DENSITY (air=1): N.E. EVAPORATION RATE: N.E. • • N.E. =Not Established N.A. =Not Applicable MSDS for XLW-32...Page 3 BOILING POINT: N.E. FREEZING POINT: N.E. SOLUBILITY IN H2O: Complete pH: N.A. SECTION VII -REACTIVITY DATA CHEMICAL STABILITY: Stable INCOMPATIBLE MATERIALS: Avoid contact with strong oxidizing agents, strong alkalies, and strong mineral acids. HAZARDOUS POLYMERIZATION: Does not polymerize HAZARDOUS DECOMPOSITION PRODUCTS: Thermal decomposition or combustion may produce smoke, carbon monoxide and carbon dioxide. SECTION VIII - SPECIAL/PERSONAL PROTECTION VENTILATION: The use of mechanical ventilation is recommended whenever this product is used in a confined space. Where engineering controls are not feasible, assure use is in an area where there is natural air movement. RESPIRATORY PROTECTION: If workplace exposure limits of product or any component is exceeded, an NIOSH/MSHA approved air supplied respirator is advised in absence of proper environmental control. OSHA regulations also permit other NIOSH/MSHA respirators (negative pressure organic vapor type) under specified conditions. Engineering or administrative controls should be implemented to reduce exposure. PROTECTIVE GLOVES: Neoprene, nitrite, polyvinyl alcohol (PVA), polyvinyl chloride (PVC) EYE PROTECTION: Chemical splash goggles or face shield in compliance with OSHA regulations is advised; however OSHA regulations also permits safety glasses under certain conditions. The use of contact lenses is not recommended. OTHER PROTECTIVE EQUIPMENT: Eyewash bottles or other rinsing equipment should be easily accessible. SECTION IX HANDLING PRECAUTIONS LEAK AND SPILL PROCEDURES WASTE DISPOSAL: HANDLING & SPECIAL EQUIPMENT: Eliminate sources of ignition. Persons not wearing suitable personal protective equipment should be excluded from area of spill until clean-up has been completed. Shut off source of spill if possible to do so without hazard. Prevent material from entering sewers or watercourses. Provide adequate ventilation. Contain spilled materials with sand or earth. Recover undamaged material for reuse or reclamation. Place all collected material and spill absorbents into DOT approved containers. If this material becomes a waste it does meet the requirements of a RCRA hazardous waste with the waste code D001. Always dispose of according to all local/state/and federal regulations. Avoid contact with eyes, skin, or clothing. Avoid breathing vapors or mist. Keep away from heat sparks, N.E. =Nat Established N.A. =Not Applicable MSDS for XLW-32...Page 4 and open flames and never use a cutting torch on or near container or explosion may result. Vapors may travel to areas away from the work site and ignite. Do not transfer to improperly marked container. Do not use pressure to empty container. Use with adequate ventilation. Wash thoroughly after handling. Containers should be grounded and bonded to receiving container when being emptied. STORAGE REQUIREMENTS: Keep container closed and away from heat, sparks, and open flames. SECTION X -REGULATORY INFORMATION SHIPPING INFORMATION PROPER SHIPPING NAME: Flammable liquids, n.o.s. (contains methanol) • HAZARD CLASS: 3 UN/NA NUMBER: UN1993 PACKING GROUP W/ "PG": PG II SUBSIDIARY RISK: N.A. REPORTABLE QUANTITY (RQ): N.A. EMERGENCY RESPONSE GUIDE #: 128 ENVIRONMENTAL INFORMATION SARA TITLE III SECTION 302/304 This product does not contain ingredients listed as an Extremely Hazardous Substance. SECTION 311/312 Immediate, Fire, Delayed SECTION 313 This product does contain ingredients (at a level of 1% or greater) on the List of Toxic Chemicals: Methanol 67-56-1 <90% • OTHER REGULATORY INFORMATION 1'SCA INVENTORY: All of the components in this appear on the TSCA inventory. CALIFORNIA PROP 65: None of the chemicals on the current Proposition 65 list are known to be present in this product. The information contained herein is based on data considered accurate. However, no warranty is expressed or implied regarding the accuracy of these data or the results to be obtained from the use thereof. Vendor assumes no responsibility for injury to vendee or third persons proximately caused by the material if reasonable safety procedures are not adhered to as stipulated in the data sheet. Additionally, vendor assumes no responsibility for injury to vendee or third persons proximately caused by abnormal use of the material even if reasonable safety procedures are followed. Furthermore, vendee assumes the risk in his use of the material N.E. =Not Established N.A. =Not Applicable MSDS for XLW-32...Page 5 Revision: 1 Status: Approved 8~ Released MSDS Revision History: Revision: Sec/Para Changed Change Made: Date 1 N!A Initial Issue of Document Today 2 X RQ is N.A. 6-14-99 3 I Telephone number 11/10/00 • N.E. =Not Established N.A. =Not Applicable MSDS for XLW-32...Page 6 • • CIAI' MASTEA•5C S~MUU~oN ~.. Water-sensitive formations, which contain swelling or sloughing-type clays such as smectite, some mixed layer clays and certain types of illite, can be protected. Clay Master-5C, a concentrated clay stabilizer, prevents the swelling and/or sloughing of such clay materials in the rock matrix-and extends protection beyond that offered by temporary solutions such as calcium, sodium or potassium salt solutions and liquid KCI (potassium chloride) substitutes. Versatile Stabilizer Applicable in any water, brine or acid-based stimulation treatment requiring control of migration and swelling of clay minerals in any workover or stimulation treatment. Stabilizes potentially mobile siliceous fines such as kaolinite, feldspars and fine quartz. Liquid Additive Can be added "on-the-fly" or batch mixed Temperature Stable Effective at formation temperatures as high as 300°F (149°C). Durable Not readily removed by subsequent treatments using brines or acid. Claymaster-5C leaves sand and silicates water-wet. Quick Effectiveness No shut-in period required to activate system. Compatible Works with mineral acids, brines and foamers for foam frac applications. Also effective in crosslinked gel systems and is compatible with most nonionic surfactants in the BJ product line. Provides long-lasting protection ofwater-sensitive formation clays during workover or stimulation treatments. Facilitates higher hydrocarbon production potential by maintaining water-wet condition in the formation. Effective in all types of wells and formations. Protective clothing, eye protection and face masks should always be worn when mixing chemicals. Should eye contact occur, flush the affected area immediately with water for 15 minutes. BJ SERVICES COMPANY CLAD MASTER-5C Product Information Clatrol-6. . . Claymaster-5C is not oil soluble, and thus should not be added to oil-based fluids. Clay Master-5C should not be used in conjuction with anionic materials unless testing has indicated that the materials are compatible. ~. Physical State: Liquid Color: Light amber Odor: Sugary Specific Gravity: 1.04 Pour Point: -25°F (-32°C) Ionic Character: Cationic Solubility in Water: Soluble •• .• L55 and L42; ClaSta FS and ClaSta XP; Clayset 3. Material Safety Data Sheet 5/96 The above features and/or date are supplied solely far informational purposes and BJ Services Company makes na guarantees orwarranties, either ezpress or implied. with respect to Meir accuracy or use. All product warranties and guarantees shall be governed by the BJ Services Company standard at the dme of sale or delivery o(service. AcNal product performance or availability depends on the timing and location of the job, the type of job and the particular characteristics of each job. This document is conbolled by the reference date. To insure that this is the current version, please reference the Services section of me BJ Services Website (www.bjservices.com) or ask your SJ representative. • • BG3 S~MUTA~UN Product Information ~.. BC-3 is a liquid catalyst that enhances fracturing fluid degradation at temperatures between 175°F (79°C) and 275°F (135°C). When coupled with GBW-23 or GBW-24 breakers, BC-3 slows early time fluid viscosity declines and then reacts to allow a more complete fluid break. The degree of fluid decomposition surpasses that typically observed from the breakers alone. It can be metered into the fracturing fluid as a batch mix operation or in a continuous mix operation. It can be used for both high and low pH systems and is very effective for shortening break times. Stable Early Viscosity Does not interfere with early viscosity development and stability. More Complete Fluid Break Faster and cleaner fluid break. High effeciency system offers shorter break times. Provides cost-effective break at low temperatures. Faster fluid break, thus enhancing post treatment production. Consult the Material Safety Data Sheet for proper handling instructions. .- .. None. Price Book Reference No. 488187 MSDS The above features and/or data are supplied solely for informational purposes and BJ Services Company makes no guarantees or warranties, either expressetl or implied, with respect to their accuracy or use. All product warranties and guarantees shall be governed by the BJ Services Company standard at the time of sale or delivery of service. Actual productpertormance oravailability depends on the timing and location of thejob, the type otjob and the particular characteristics ofeach jab. This document is controlled by [he reference date. Ta ensure that this is the currentversion, please reference the Services section of the BJ Services Website (www.bjservices.com) or ask your BJ representative. 4/5/01 ~ BJ SERVICES COMPANY BF•1L • S1IMUTAII~N Product Information ~.. BF-7L allows adjustments of pH levels in fracturing gels to the range of 8.5 to 9.75, preventing the fall in pH that occurs as fluid temperatures increase. Because BF-7L is a liquid, it is a convenient, easy-to-handle system that offers strong pH buffering capacity, and can be batch-mixed or mixed "on-the-fly". Compatible BF-7L has the appropriate pH range for crosslinking high pH systems (8 to 10), including Viking, Viking D and Spectra Frac G. It also is compatible with most common fracturing additives. Easier Handling As a liquid, BF-7L simplifies handling, particularly when mixed "on-the-fly". Clay Stabilizing Properties Buffer contains potassium ion and thus provides some clay stabilization. Stable BF-7L offers greater stability than conventional additives used to raise the pH of high pH fluids. High Efficiency As a concentrate, lower loadings are required to adjust pH levels. Makes the most of crosslinker performance. Provides excellent gel viscosity for sand transporting. Improves high temperature gel stability. BF-7L will cause caustic burns to skin and eyes. Consult the Material Safety Data Sheet for proper handling instructions. . . In most cases, sodium hydroxide is more efficient than BF-7L in neutralizing acid. Also, BF-7L is not efficient in lowering the pH of highly alkaline fluids. BJ SERVICES COMPANY • BF•ll Product Information • Color: Clear solution Odor: Odorless Solubility in Water, by Weight @ 32°F (0°C): 100% by Weight @ 219°F (104°C): 100% Solubility in Alcohol: Limited Specific Gravity: 1.477 .• .. M47; BJ-10, BA-20, BA-40, BA-40L, BA-50 and BA-120; NowpHix 6P. Confidential Mixing Instructions Material Safety Data Sheet 5/96 The above features andlar data are supplied solely for informational purposes and BJ Services Company makes no guarantees or warranties, either express or implied, with respect to their accuracy or use. All product warranties and guarantees shall 6e governed Dy the BJ Services Company standard at Ine Dme of sale ar delivery of service. Actual product per/ormance or availability depends on the timing and location of the job, the type of job and the particular characteristics of each job. This document is controlled by the reference date. To insure that this is the currentversion, please reference the Services section of the BJ Services Website (www.bjservices.com) orask your BJ representative. • xiyu-at Product Information SiIMUTAiION • .. XLW-32 is a borate-based crosslinker used to crosslink Viking TM and Lightning TM water-based fracturing fluid systems. Cross-linked polymers create high viscosity, which improves sand/proppant transport. Cross-linked fluid systems also provide for increased fracture width and better fluid efficiency, which allows for higher sand concentrations and longer fracture lengths. • Mono-borate crosslinker for use in high-pH fracturing fluid applications with BHST up to 200°F (93°C). • Rapid-on, non-delayed crosslink. • Compatible with most common fracturing additives. • Liquid additive is easy to handle, especially when mixed on-the-fly. • XLW-32 can be diluted with water if needed to maintain accurate metering capability at low rates. • Can be stored and used in temperatures as low as -30°F (-34°C). Color: Clear, colorless Odor: alcohol Specific Gravity @ 77°F (25°C}: 0.8 to 1.0 Solubility in Water: 100% Avoid contact with eyes, skin, or clothing. Avoid breathing vapors or mist. Keep away from heat, sparks, and open flames, and never use a cutting torch on or near container or explosion may result. Refer to MSDS for details. . . XLW-32 is for high-pH fracturing fluid applications and should not be used in low-pH crosslinked systems. BJ Technology Toolbox on PowerCenter Confidential Mixing Instructions MSDS The above features antllor tlata are supplied solely far informational purp°ses and BJ Services Company makes no guarantees or warranties, either expressed or Implietl, with respect to !heir accuracy or use. All product warranties anA guarantees shall be governed by the BJ Services Company standartl al the time of sale or delivery of service. A°Nal product performance or availability dapentls on the timing and location of the jpb, the type of job and Ine particular characteristics of each job. This tlocumenl 15 wntrolled by the reference tlale. To ensure Ihal Ihls i5 the cprrenl vefsion, please reference the Services section of the BJ Services Websile (www.blservices.com) or ask your BJ represetttaliva. March 14, 2007 ~ BJ SERVICES COMPANY C7 BJ SERVICES COMPANY MATERIAL SAFETY DATA SHEET SECT{ON I -GENERAL INFORMATION PRODUCT NAME: ITEM NUMBER: CHEMICAL DESCRIPTION: PRODUCT USE: SUPPLIER: ADDRESS: EMERGENCY TELEPHONE NUMBER PREPARED BY: DATE PREPARED: GBW-18 Region USA 488224 Sodium persulfate Breaker -Water BJ Services Company 11211 FM 2920 Tomball, TX 77375 (800)424-9300 for CHEMTREC (202)483-7616 Alaska and International BJ Services Environmental Group (281)351-8131 December 13, 2000 Supersedes: March 9, 1999 HMIS HAZARD INDEX HEALTH: 1 FLAMMABILITY: 1 REACTIVITY: 1 PERSONAL PROTECTION: h SECTION II -HAZARDOUS COMPONENTS HAZARDOUS COMPONENTS CAS # PERCENT HAZARD Sodium persulfate 7775-27-1 >99 Oxidizer SECTION III -FIRE AND EXPLOSION HAZARD DATA FLASHPOINT (METHOD): UPPER EXPLOSION LIMIT(% BY VOL): LOWER EXPLOSION LIMIT(% BY VOL): AUTO-IGNITION TEMPERATURE: EXTINGUISHING MEDIA: SPECIAL FIRE FIGHTING PROCEDURES EXPLOSION DATA: HAZARDOUS COMBUSTION PRODUCTS: Incombustible N.A. N.A. N.A. Water, dry powder, C02, and other inert materials Evacuate personnel to a safety area. If smoke and fumes can not be avoided, use proximity suits and self- contained breathing apparatus. N.E. Incombustible ~ • SECTION IV -HEALTH HAZARD DATA PRIMARY ROUTES OF ENTRY: Skin and eye contact, inhalation ACUTE OVEREXPOSURE EFFECTS: SKIN CONTACT: May cause irritation. SKIN ABSORPTION: Not absorbed by skin. EYE CONTACT: Airborne dust may irritate eyes. INHALATION: Inhalation of airborne dust at high levels may produce shortness of breath in allergic persons. INGESTION: Not an expected route of entry CHRONIC OVEREXPOSURE EFFECTS: Continuous contact may cause skin dermatitis. EXPOSURE LIMITS: HAZARDOUS COMPONENT ACGIH TLV OSHA PEL Sodium persulfate N.E. N.E. CARCINOGENICITY, REPRODUCTIVE EFFECTS: Not listed as carcinogenic - IARC, NTP, or OSHA TERATOGENICITY, MUTAGENICITY: No effects listed. TOXICITY STUDIES: LD(50) 895 mg/kg (oral rat) LC(50) N.E. SECTION V -FIRST AID PROCEDURES FOR EYES: Immediately flush with plenty of water for at least 15 minutes. If irritation persists, contact a physician. FOR SKIN: Wash thoroughly with water. If irritation occurs and persists, obtain medical attention. FOR INHALATION: Remove to fresh air. If breathing has stopped, give artificial respiration. Keep person warm, quiet and get medical attention. FOR INGESTION: Give plenty of water. Induce vomiting! Never give anything to an unconscious person. Call a physician. SECTION VI -PHYSICAL DATA APPEARANCE AND ODOR: SPECIFIC GRAVITY: VAPOR PRESSURE: VAPOR DENSITY (air=? ): EVAPORATION RATE: BOILING POINT: FREEZING POINT: White crystalline powder, odorless N.E. N.A. N.A. N.A. N.A. N.A. • SOLUBILITY IN H2O: pH: 70.2g/100g at 20°C N.A. SECTION VII -REACTIVITY DATA CHEMICAL STABILITY: INCOMPATIBLE MATERIALS: HAZARDOUS POLYMERIZATION: HAZARDOUS DECOMPOSITION PRODUCTS: • Stable Reacts with acids, alkalis, heavy metals and reductants to release oxygen. Does not polymerize Decomposes when stored under conditions of excessive heat and/or moisture, generating heat and causing the release of oxides of sulfuric acid and oxygen which supports combustion. SECTION VIII -SPECIAL/PERSONAL PROTECTION VENTILATION: The use of mechanical ventilation is recommended whenever this product is used in a confined space. Where engineering controls are not feasible, assure use is in an area where there is natural air movement. RESPIRATORY PROTECTION: Where there is inadequate ventilation, respirators with filters and/or sorbents are recommended. PROTECTIVE GLOVES: Rubber or neoprene EYE PROTECTION: Goggles OTHER PROTECTIVE EQUIPMENT: Eyewash bottles or other rinsing equipment should be easily accessible. SECTION IX -HANDLING PRECAUTIONS LEAK AND SPILL PROCEDURES: Sweep up and place in suitable containers for reuse or disposal. WASTE DISPOSAL: If this product becomes a waste it does not meet the requirements of a RCRA hazardous waste. Always dispose of according to local/state/federal regulations. HANDLING & SPECIAL EQUIPMENT: Avoid contact with combustible materials. STORAGE REQUIREMENTS: Store in a cool, dry, well-ventilated place away from incompatible materials. Keep bags or fiber drums dry at all times. SECTION X -REGULATORY INFORMATION SHIPPING INFORMATION PROPER SHIPPING NAME: Sodium persulfate HAZARD CLASS: 5.1 UNJNA NUMBER: UN1505 PACKING GROUP W/ "PG": PG III SUBSIDIARY RISK: N.A. REPORTABLE QUAN T i T Y (RQ): N.A. EMERGENCY RESPONSE GUIDE #: 140 • • ENVIRONMENTAL INFORMATION SARA TITLE III SECTION 302/304 This product does not contain ingredients listed as an Extremely Hazardous Substance. SECTION 311/312 Immediate SECTION 313 This product does not contain ingredients (at a level of 1 % or greater) on the List of Toxic Chemicals. OTHER REGULATORY INFORMATION TSCA INVENTORY: All of the components in this appear on the TSCA inventory. CALIFORNIA PROP 65: None of the chemicals on the current Proposition 65 list are known to be present in this product. The information contained herein is based on data considered accurate. However, no warranty is expressed or implied regarding the accuracy of these data or the results to be obtained from the use thereof. Vendor assumes no responsibility for injury to vendee or third persons proximately caused by the material if reasonable safety procedures are not adhered to as stipulated in the data sheet. Additionally, vendor assumes no responsibility for injury to vendee or third persons proximately caused by abnormal use of the material even if reasonable safety procedures are followed. Furthermore, vendee assumes the risk in his use of the material. Revision: 3 Status: Approved & Released MSDS Revision History Revision: Sec/Para Changed Change Made: Date 1 N/A Initial Issue of Document 3_g-99 2 I Telephone number, removed experimental dsignation 12/13/00 3 f Address Change 10/26/06 GBW5 Product Information • S1P~NR~IN ~.. GBW-5 is an oxidative breaker formulated to degrade polymers used in fracturing, workover and remedial treatments. Temperature Stability Can be utilized at temperatures to 200°F (93°C) Versatility Effective for all types of polymers. Convenience No special equipment required to mix or pump this additive. Low Concentrations Typical loadings range from 0.1 ppt to 10.0 ppt. Compatibility Compatible with most treatment additives. Operationally easy-to-use. Improved proppant pack permeability. Faster fluid cleanup, which minimizes workover time. Economical to use ~YiC~I\T - 1 • Protective clothing, eye protection and face mask should always be worn when mixing chemicals. Should eye contact occur, flush the eyes with water for 15 minutes. 11 . • A catalyst must be used at temperatures below 140°F (60°C) GBW-5 Engineering Bulletin Confidential Mixing Instructions 10/93 The above features and/or data are supplied solely for informational purposes and SJ Services Company makes no guarantees or warranties, either express orimplied, with respect to their accuracy or use. All product warranties and guarantees shall be governed by the BJ Services Company standard at the tlme of sale or delivery of service. Actual productperlormance or availability depends on the Hming and location of the job, the type of job and the particular characteristics of each joh. This document is controlled Dy the reference date. To insure that this is the current versicn, please reference the Services section of the BJ Services Website (www.hjservices.com) orask your BJ representative. BJ SERVICES COMPANY Product Name BC-6 Subject: Desc: Application Loading: Incompatibilities: Breaker catalyst Catalyst for oxidative breakers at temperatures below 120°F.. Can be used as a buffer in fracturing systems. PV Description: BC-6 is a clear, colorless liquid that is designed to assist the degradation of fracturing fluids. It can be used with breakers to allow the breakers to work more effectively. Specific Gravity: 1.13 pH: Color: water white Odor: mild ammonia Solubility: complete Particle Size: Viscosity: Bulk Weight: Bulk Density: 9.42 Harmonized Tariff: 2922.13.0000 (Schedule B) CAS Registry: 102-71-6 Shelf Life: 12 months Nature of Charge: Pour Point: -13°F Freeze Point: -22°F Crystallization Point: Flash Point: Melting Point: Boiling Point: Old BJ Name: BF-4 Old Western B-12 Name: OSCA Name: OSCA Item #: Hughes Name: M-13 Titan Name: LTB-1 • 407°F 635°F NOWSCO X- Triethanolamine REF: NOWSCO SAP 5626 #: FM X-REF Canada: FM # Canada: Smith Name: • • f~W-18 Product Information SiIMUTAiION .. GBW-18 is an oxidative breaker formulated to degrade polymers used in fracturing, workover and remedial treatments. • Can be utilized at temperatures up to 200°F (93'C). • Effective for all types of polymers. • No special equipment required to mix or pump this additive. • Typical loadings range from 0.1 to 10.0 pptg (0.012 to 1.2 kg/m3). • Compatible with most treatment additives. • Operationally easy-to-use. • Improved proppant pack permeability. • Faster fluid cleanup, which minimizes workover time. • Economical to use. Protective clothing, eye protection and face mask should always be worn when mixing chemicals. Should eye contact occur, flush the eyes with water for 15 minutes. A catalyst must be used at temperatures below 140°F (60`C). Confidential Mixing Instructions MSDS The above features antl/or tlala are supplied solely for in/ormational purposes antl 8J Services Company makes no guarantees or warranties, either expressetl or lmplled, with respect to their accuracy or use. All produce warranties ana guarantees sha41 be governed by the BJ Services Company standard at the time of sale or delivery o(service. Actual product performance or availability depentls on the timing antl location of the joU. the type of job and the particular cnaracterislics of each lob. This tlocumenl Is controlled by the reference tlate. To ensure Thal this Is the current version, please reference the Services section of the BJ Services Website (www.bjservices.comj or ask your BJ representative. November 14. 2006 ~ BJ SERVICES COMPANY • _. _ _ _ _ _ # ~ BJ SERVICES COMPANY MATERIAL SAFETY DATA SHEET __ Home > QHSE > Corporate HSE > Database > International MSDS MATERIAL SAFETY DATA SHEET Region USA 1 PRODUCT AND COMPANY IDENTIFICATION Product Name: B`i-6 Item Number: 424341 Product Use: Breaker catalyst Supplier: BJ Services Company 11211 FM 2920 Tomball, TX 77375 (281)351-8131 IN CASE OF EMERGENCY CALL: (800) 424-9300 for CHEMTREC (703) 527-3887 for International HMIS HAZARD INDEX HEALTH: 1 FLAMMABILITY: 1 REACTIVITY: 0 PERSONAL PROTECTION: b 2 COMPOSITION/INFORMATION ON INGREDIENTS ___ azardous Component __ ___ ___ CAS# __. Percent ' _ _._ azard Triethanolamine __ 000102-71-6 50 - 60 Irritant 3 HAZARDS IDENTIFICATION PRIMARY ROUTES OF EXPOSURE: Eye Contact. Skin Contact. ACUTE OVEREXPOSURE EFFECTS: • • INHALATION: This product has a very low vapor pressure and does not easily form a vapor at room temperature. Therefore, inhalation exposures are not expected unless the product is heated or misted. INGESTION: May cause nausea, vomiting and diarrhea. May cause stomach discomfort. May cause irritation or burns to the mouth, throat and stomach. EYE CONTACT: Causes irritation, redness, and pain. May cause corneal injury. SKIN CONTACT: May cause skin irritation. May cause redness and blistering of skin. EXPOSURE LIMITS: 'HAZARDOUS !ACGIH TLV :OSHA PEL LC50 LD50 (oral) COMPONENT (inhalation) Triethanolamine '5 mg/m3 NA NA :8000 mg/kg rat 4 FIRST AID MEASURES INHALATION: If inhaled, remove from area to fresh air. Get medical attention if respiratory irritation develops or if breathing becomes difficult. INGESTION: Do not induce vomiting. Give victim plenty of water. Obtain medical attention immediately. Never give anything by mouth to an unconscious person. EYES: Flush eyes immediately with large amounts of water for at least 15 minutes. Lift upper and lower lids occasionally. Get medical attention. SKIN: Flush skin with water or soap and water, if available, for at least 15 minutes. Remove contaminated clothing and launder before reuse. Seek medical attention. 5 FIRE FIGHTING MEASURES FLASHPOINT (METHOD): > 395°F (PMCC) LOWER EXPLOSION LIMIT (% v/v): Not applicable/available UPPER EXPLOSION LIMIT (% v!v): Not applicable/available AUTO-IGNITION TEMPERATURE: Not available/applicable SPECIAL HAZARDS: None. EXTINGUISHING MEDIA: Carbon dioxide, dry chemical, foam. Water or foam may cause frothing. SPECIAL FIREFIGHTING PROCEDURES: Fire-fighters should wear self-contained breathing apparatus and full protective clothing when fighting chemical fires. Use water spray to cool nearby containers and structures exposed to fire. ~ ~ HAZARDOUS COMBUSTION PRODUCTS: Oxides of carbon and nitrogen. 6 ACCIDENTAL RELEASE MEASURES Wear specified protective equipment. Dike to contain. Cover spill with absorbent material. Scoop absorbed material into a suitable container for disposal. 7 HANDLING AND STORAGE HANDLING: Avoid contact with skin and eyes. STORAGE REQUIREMENTS: Keep container closed when not in use. Keep container dry. Keep in a cool, well ventilated place. Protect from freezing. 8 EXPOSURE CONTROLS/PERSONAL PROTECTION SPECIFIC ENGINEERING CONTROLS: The use of mechanical ventilation is recommended whenever this product is used in a confined space. Where engineering controls are not feasible, assure use is in an area where there is natural air movement. PERSONAL PROTECTIVE EQUIPMENT: Chemical resistant goggles. Chemical resistant gloves. Appropriate respiratory protection shall be worn when applied engineering controls are not adequate to protect against inhalation exposure. 9 PHYSICAL AND CHEMICAL PROPERTIES PHYSICAL STATE: Liquid COLOR: Water-white ODOR: Mild Ammonia ODOR THRESHOLD: Not available/applicable SPECIFIC GRAVITY: 1.078 VAPOR PRESSURE: Not available/applicable VAPOR DENSITY (air = 1): Not available/applicable EVAPORATION RATE: Not available/applicable BOILING POINT: Not available/applicable FREEZING POINT: Not available/applicable pH: Not applicable/available SOLUBILITY IN WATER: Soluble 10 STABILITY AND REACTIVITY STABILITY: Stable. INCOMPATIBILITY/CONDITIONS OF REACTIVITY: Contact with acids. Contact with copper. Contact with iron. Contact with oxidizing agents. • • HAZARDOUS THERMAL DECOMPOSITION PRODUCTS: Carbon monoxide. Carbon dioxide. Oxides of nitrogen. HAZARDOUS POLYMERIZATION: Will not occur. 11 TOXICOLOGICAL PROPERTIES CHRONIC EFFECTS: May cause liver and kidney damage. SENSITIZATION: Not known. CARCINOGENICITY: None of the components of this product have been listed as carcinogenic by IARC, NTP or OSHA. (IARC- International Agency for Research on Cancer) (NTP -National Toxicology Program) (OSHA -Occupational Safety & Health Administration (US)) MUTAGENICITY: Not known. REPRODUCTIVE TOXICITY: Not known. 12 ECOLOGICAL INFORMATION No specific information available 13 DISPOSAL CONSIDERATIONS WASTE DISPOSAL: Disposal should be made in accordance with national and local regulations. 14 TRANSPORT INFORMATION LAND TRANSPORT (DOT) Proper Shipping Name: NOT RESTRICTED UN No.: NA AIR TRANSPORT (ICAO/IATA) Proper Shipping Name: NOT RESTRICTED UN/ID No.: NA • • MARINE TRANSPORT (IMDG/IMO) Proper Shipping Name: NOT RESTRICTED UN/ID No.: NA 15 REGULATORY INFORMATION SARA TITLE III: SECTION 302/304 This product does not contain substances listed in Appendix A and B as an Extremely Hazardous Substance. SECTION 311/312 Immediate SECTION 313 This product does not contain ingredients (at a level of 1 % or greater) on the List of Toxic Chemicals. TSCA INVENTORY: The substances in this product are included on or exempted from the TSCA 8(b) Inventory (40 CFR 710) CALIFORNIA PROP 65: This product does not contain substances which require warning under California Proposition 65. 16 OTHER INFORMATION ISSUE DATE: 09/19/2005 PREPARED BY: BJ SERVICES ENVIRONMENTAL GROUP REFERENCES: Suppliers' Literature. Suspect Chemicals Sourcebook SAX's Dangerous Properties of Industrial Materials The information contained herein is based on data considered accurate. However, no warranty is expressed or implied regarding the accuracy of these data or the results to be obtained from the use thereof. Vendor assumes no responsibility for injury to vendee or third persons proximately caused by the material if reasonable safety procedures are not adhered to as stipulated in the data sheet. Additionally, vendor assumes no responsibility for injury to vendee or third persons proximately caused by abnormal use of the material even if reasonable safety procedures are followed. Furthermore, vendee assumes the risk in his use of the material. Revision: 2 Status: Approved & Released MSDS Revision History: __ _ Revision: .Sec/Para Changed Change Made: ;Date 1 N/A Initial Issue of Document -09/19/0 r1 LJ BJ SERVICES COMPANY MATERIAL SAFETY DATA SHEET SECTION I -GENERAL INFORMATION PRODUCT NAME: ITEM NUMBER CHEMICAL DESCRIPTION: PRODUCT USE: SUPPLIER: ADDRESS: EMERGENCY TELEPHONE NUMBER PREPARED BY: DATE PREPARED: G BW-5 Region USA 100175 Ammonium persulfate Breaker -water BJ Services Company 11211 FM 2920 Tomball, TX 77375 (800)424-9300 for CHEMTREC (202)483-7616 Alaska and International BJ Services Environmental Group (281)351-8131 September 5, 2000 Supersedes: December 1992 HMIS HAZARD INDEX HEALTH: 1 FLAMMABILITY: 1 REACTIVITY: 1 PERSONAL PROTECTION: h SECTION II -HAZARDOUS COMPONENTS HAZARDOUS COMPONENTS CAS # PERCENT HAZARD Ammonium Persulfate 7727-54-0 >99 Oxidizer SECTION III -FIRE AND EXPLOSION HAZARD DATA FLASHPOINT (METHOD): UPPER EXPLOSION LIMIT(% BY VOL): LOWER EXPLOSION LIMIT(% BY VOL): AUTO-IGNITION TEMPERATURE: EXTINGUISHING MEDIA: SPECIAL FIRE FIGHTING PROCEDURES: EXPLOSION DATA: N.A. N.A. N.A. N.A. Water Use a self-contained breathing apparatus with full facepiece operated in pressure-demand or other positive pressure mode. Cool fire-exposed containers using water spray. Material will liberate oxygen, ammonia and fumes of sulfuric acid at 347°F. Oxygen gas, if confi~~ed, can increase the explosive limits or burning rate of flammable HAZARDOUS COMBUSTION PRODUCTS vapors. Oxygen, ammonia and fumes of sulfuric acid • • SECTION IV -HEALTH HAZARD DATA PRIMARY ROUTES OF ENTRY: Skin and eye contact, inhalation ACUTE OVEREXPOSURE EFFECTS: SKIN CONTACT: Powder is non-irritating. May be sensitizer to allergic persons. SKIN ABSORPTION: Not absorbed by skin. EYE CONTACT: Powder is minimally irritating to unwashed eyes, practically non- irritating to washed eyes. INHALATION: Dusts may be harmful and irritating. INGESTION: Swallowing may cause nausea and vomiting and irritation of mucous membranes. CHRONIC OVEREXPOSURE EFFECTS: May cause eczema and asthma in allergic persons. EXPOSURE LIMITS: HAZARDOUS COMPONENT ACGIH TLV Ammonium Persulfate 2 mg/m3 CARCINOGENICITY, REPRODUCTIVE EFFECTS: Not listed as carcinogen - IARC, NTP, or OSHA TERATOGENICITY, MUTAGENICITY: No effects listed. TOXICITY STUDIES: LD(50) 750 mg/kg (oral rat) LC(50) N.E. SECTION V -FIRST AID PROCEDURES OSHA PEL N.E. FOR EYES: Wash thoroughly with water. If irritation occurs and persists, see an ophthalmologist. FOR SKIN: Wash thoroughly with water. If irritation occurs and persists, obtain medical attention. FOR INHALATION: Remove to fresh air. If breathing has stopped, give artificial respiration. Keep person warm, quiet and get medical attention. FOR INGESTION: Drink plenty of water. Call a physician. NOTE TO PHYSICIAN: Aside from allergic reactions such as dermatitis and asthma, exposure problems are related to the oxidizing properties which cause problems resembling those caused by strong acids. However, attempts to neutralize with basic or halide-containing materials should be avoided because of possible exothermic reaction. Flooding of exposure areas with water is suggested. Gastric lavage or emesis induction for ingestions must consider the possible aggravation of esophageal injury and the expected absence of system effects. Demulcents may be helpful. Treatment otherwise is supportive and symptomatic. • • SECTION VI -PHYSICAL DATA APPEARANCE AND ODOR: SPECIFIC GRAVITY: VAPOR PRESSURE: VAPOR DENSITY (air=1): EVAPORATION RATE: BOILING POINT: FREEZING POINT: SOLUBILITY IN H2O: pH: White to light crystalline powder, odorless 1.9 N.A. N.A. N.A. N.A. N.A. 79% N.A. SECTION VII -REACTIVITY DATA CHEMICAL STABILITY: INCOMPATIBLE MATERIALS: HAZARDOUS POLYMERIZATION: HAZARDOUS DECOMPOSITION PRODUCTS Stable This material is a strong oxidizing agent: Avoid acids, alkalis, halides, reducing agents, combustible and organic materials, Metals such as iron and copper and their alloys and rust. Does not polymerize Will liberate flammable and corrosive fumes of oxygen, ozone, ammonia, and sulfuric acid. SECTION VIII -SPECIAL/PERSONAL PROTECTION VENTILATION: The use of mechanical ventilation is recommended whenever this product is used in a confined space. Where engineering controls are not feasible, assure use is in an area where there is natural air movement. RESPIRATORY PROTECTION: As necessary PROTECTIVE GLOVES: Rubber or neoprene EYE PROTECTION: Goggles OTHER PROTECTIVE EQUIPMENT: Eyewash bottles or other rinsing equipment should be easily accessible. SECTION IX -HANDLING PRECAUTIONS LEAK AND SPILL PROCEDURES: Sweep up and place in suitable containers for reuse or disposal. WASTE DISPOSAL: If this product becomes a waste it does not -meet the requirements of a RCRA hazardous waste. Always dispose of according to local/state/federal regulations. HANDLING & SPECIAL EQUIPMENT: Avoid contact with eyes, skin and clothing. STORAGE REQUIREMENTS: Store in a cool, dry, well-ventilated place away from incompatible materials. Keep bags or fiber drums dry at all times. • • SECTION X -REGULATORY INFORMATION SHIPPING INFORMATION PROPER SHIPPING NAME: HAZARD CLASS: UN/NA NUMBER: PACKING GROUP W/ "PG": SUBSIDIARY RISK: REPORTABLE QUANTITY (RQ): EMERGENCY RESPONSE GUIDE #: ENVIRONMENTAL INFORMATION SARA TITLE III Ammonium Persulfate 5.1 U N 1444 PG III N.A. N.A. 140 SECTION 302/304 This product does not contain ingredients listed as an Extremely Hazardous Substance. SECTION 311/312 Immediate, Fire SECTION 313 This product does not contain ingredients (at a level of 1 % or greater) on the List of Toxic Chemicals. OTHER REGULATORY INFORMATION TSCA INVENTORY: All of the components in this appear on the TSCA inventory. CALIFORNIA PROP 65: This product contains lead at a concentration equal to/less than 1 ppm. Lead is known to the State of California to cause reproductive toxicity. The information contained herein is based on data considered accurate. However, no warranty is expressed or implied regarding the accuracy of these data or the results to be obtained from the use thereof. Vendor assumes no responsibility for injury to vendee or third persons proximately caused by the material if reasonable safety procedures are not adhered to as stipulated in the data sheet. Additionally, vendor assumes no responsibility for injury to vendee or third persons proximately caused by abnormal use of the material even if reasonable safety procedures are followed. Furthermore, vendee assumes the risk in his use of the material. Revision: 3 Status: Approved & Released MSDS Revision History Revision: Sec/Para Changed Change Made: Date 1 N/A Initial Issue of Document Today 2 I Telephone number 09/05/00 3 I Address Change 10/26/06 *1 Disposal Injection Order Amendment Reques. Jim: ConocoPhillips Company is currently approved to dispose of Class II waste fluids into the Beluga River Unit (BRU) injection well BRWD-1 under DIO 3. CPAI seeks the Commission's approval to dispose of canola oil and potentially small quantities of diesel that are used in remedial wellwork operations. ConocoPhillips has scheduled a well cleanout for mid-September using concentric coiled tubing (CCT) technology. CCT consists of using an inner coiled tubing string to power a downhole jet pump which is used to force fluid up through a concentric coiled (steel) tubing annulus to surface production equipment. Canola oil will be used as a lubricant to assist running the coiled tubing into the wells, being applied to the coiled tubing within the spill containment area. As temperatures continue to decline, it may be necessary to cut the canola oil with diesel to maintain a low level of viscosity and prevent the oil from congealing. Approximately one barrel of canola oil and up to one barrel of diesel may require disposal upon job completion. ConocoPhillips believes that disposal of the fluids into BRWD-1 will not have detrimental effects on the confinement of disposed fluids and represents an environmentally preferable option to managing these fluids used during well operations. A similar request for disposal of canola oil was approved by the AOGCC under DID 017.005 for an identical project at the North Cook Inlet Unit (NCIU). I have attached MSDS copies for canola oil and diesel. CPAI appreciates the Commission's consideration of this request. Please feel free to contact me with any questions or if you would like additional information. «CanolaOil MSDS.pdf» «DF2 MSDS.pdf» Thank you, Marta Czarnezki Environmental Coordinator Cook Inlet Asset ConocoPhillips Alaska, Inc. PO Box 66 48237 Kenai Spur Hwy Kenai AK 99611 Ph: 907-776-2092 Fx: 907-776-2095 Cell: 907-252-6794 email: marta.p.czarnezki@conocophillips.com lof2 911112006 8:53 AM Disposal Injection Order Amendment Requese . Content-Description: CanolaOil MSDS.pdf CanolaOil MSDS.pdf Content-Type: application/octet-stream Content-Encoding: base64 DF2 20f2 Content-Description: DF2 MSDS.pdf Content-Type: application/octet-stream Content-Encoding: base64 911112006 8:53 AM . HALLIBURTON . MATERIAL SAFETY DATA SHEET Product Trade Name: CANOLA OIL Revision Date: 16-Feb-2004 11. CHEMICAL PRODUCT AND COMPANY IDENTIFICATION Product Trade Name: Synonyms: Chemical Family: Application: CANOLA OIL None Vegetable oil Carrier Fluid Manufacturer/Supplier Halliburton Energy Services P.O. Box 1431 Duncan, Oklahoma 73536-0431 Emergency Telephone: (800) 666-9260 or (713) 676-3000 Prepared By Chemical Compliance Telephone: 1-580-251-4335 12. COMPOSITIONIINFORMATION ON INGREDIENTS SUBSTANCE Canola oil CAS Number 1120962-03-0 PERCENT 160 -100% ACGIH TLV-TWA INot applicable OSHA PEL-TWA INot applicable þ. HAZARDS IDENTIFICATION Hazard Overview May cause eye and skin irritation. 14. FIRST AID MEASURES Inhalation If inhaled, remove from area to fresh air. Get medical attention if respiratory irritation develops or if breathing becomes difficult. Wash with soap and water. Get medical attention if irritation persists. In case of contact, immediately flush eyes with plenty of water for at least 15 minutes and get medical attention if irritation persists. Get medical attention! If vomiting occurs, keep head lower than hips to prevent aspiration. Skin Eyes Ingestion Notes to Physician Not Applicable CANOLA OIL Page 1 of 5 · . 15. FIRE FIGHTING MEASURES Flash Point/Range (F): Flash Point/Range (C): Flash Point Method: Autoignition Temperature (F): Autoignition Temperature (C): Flammability Limits in Air - Lower (%): Flammability Limits in Air - Upper (%): 418 214 COC Not Determined Not Determined Not Determined Not Determined Fire Extinguishing Media Special Exposure Hazards Water fog, carbon dioxide, foam, dry chemical. Decomposition in fire may produce toxic gases. Special Protective Equipment for Full protective clothing and approved self-contained breathing apparatus required for Fire-Fighters fire fighting personnel. NFPA Ratings: HMIS Ratings: Health 0, Flammability 1, Reactivity 0 Flammability 1, Reactivity 0, Health 0 16. ACCIDENTAL RELEASE MEASURES Personal Precautionary Measures Use appropriate protective equipment. Environmental Precautionary Measures None known. Procedure for Cleaning I Absorption Isolate spill and stop leak where safe. Contain spill with sand or other inert materials. Scoop up and remove. 17. HANDLING AND STORAGE Handling Precautions Storage Information Avoid contact with eyes, skin, or clothing. Store away from oxidizers. Store in a cool well ventilated area. Keep container closed when not in use. Product has a shelf life of 12 months. la. EXPOSURE CONTROLS/PERSONAL PROTECTION Engineering Controls Respiratory Protection Hand Protection Use in a well ventilated area. Skin Protection Not normally necessary. Normal work gloves. Normal work coveralls. Eye Protection Other Precautions Wear safety glasses or goggles to protect against exposure. None known. ~. PHYSICAL AND CHEMICAL PROPERTIES Physical State: Color: Odor: pH: Specific Gravity @ 20 C (Water=1): Density @ 20 C (Ibs.lgallon): Bulk Density @ 20 C (lbs/ft3): Liquid Brown Slight 7 0.889 7.40 Not Determined CANOLA OIL Page 2 of 5 . . Not DeterminedMin: > 598 Not DeterminedMin: > 314 -72 -58 Not Determined Not Determined Not Determined Not Determined Insoluble Not Determined Not Determined Not Determined Not Determined Not Determined Not Determined Boiling Point/Range (F): Boiling Point/Range (C): Freezing Point/Range (F): Freezing Point/Range (C): Vapor Pressure @ 20 C (mmHg): Vapor Density (Air=1): Percent Volatiles: Evaporation Rate (Butyl Acetate=1): Solubility in Water (g/100ml): Solubility in Solvents (g/100ml): VOCs (Ibs.lgallon): Viscosity, Dynamic @ 20 C (centipoise): Viscosity, Kinematic @ 20 C (centistrokes): Partition Coefficient/n-OctanollWater: Molecular Weight (g/mole): 110. STABILITY AND REACTIVITY Stability Data: Stable Hazardous Polymerization: Will Not Occur Conditions to Avoid None anticipated Incompatibility (Materials to Avoid) Strong oxidizers. Hazardous Decomposition Products Oxides of sulfur. Carbon monoxide and carbon dioxide. Additional Guidelines Not Applicable 111. TOXICOLOGICAL INFORMATION Principle Route of Exposure Eye or skin contact, inhalation. Inhalation May cause mild respiratory irritation. Skin Contact May cause mild skin irritation. Eye Contact May cause eye irritation. Ingestion Aspiration into the lungs may cause chemical pneumonitis including coughing, difficulty breathing, wheezing, coughing up blood and pneumonia, which can be fatal. Aggravated Medical Conditions None known. Chronic Effects/Carcinogenicity No data available to indicate product or components present at greater than 1 % are chronic health hazards. Other Information None known. Toxicity Tests Oral Toxicity: Not determined Dermal Toxicity: Inhalation Toxicity: Primary Irritation Effect: Not determined Not determined Not determined Carcinogenicity Not determined CANOLA OIL Page 3 of 5 . . Genotoxicity: Reproductive / Developmental Toxicity: Not determined Not determined 112. ECOLOGICAL INFORMATION Mobility (Water/Soil/Air) Not determined Persistence/Degradability Not determined Bio-accumulation Not Determined Ecotoxicologicallnformation Acute Fish Toxicity: Not determined Acute Crustaceans Toxicity: Not determined Acute Algae Toxicity: Not determined Chemical Fate Information Not determined Other Information Not applicable 113. DISPOSAL CONSIDERATIONS Disposal Method Disposal should be made in accordance with federal, state, and local regulations. If empty container retains product residues, all label precautions must be observed. Transport with all closures in place. Return for reuse or disposal according to national or local regulations. Contaminated Packaging 114. TRANSPORT INFORMATION land Transportation DOT Not restricted Canadian TDG Not restricted ADR Not restricted Air Transportation ICAOIIA T A Not restricted Sea Transportation IMDG Not restricted Other Shipping Information Labels: None CANOLA OIL Page 4 of 5 . 115. REGULATORY INFORMATION US Regulations US TSCA Inventory EPA SARA Title III Extremely Hazardous Substances . All components listed on inventory. Not applicable EPA SARA (313) Chemicals EPA SARA (311,312) Hazard Class None This product does not contain a toxic chemical for routine annual "Toxic Chemical Release Reporting" under Section 313 (40 CFR 372). EPA CERCLAlSuperfund Not applicable. Reportable Spill Quantity For This Product EPA RCRA Hazardous Waste Classification California Proposition 65 MA Right-to-Know Law NJ Right-to-Know Law PA Right-to-Know Law Canadian Regulations Canadian DSL Inventory WHMIS Hazard Class If product becomes a waste, it does NOT meet the criteria of a hazardous waste as defined by the US EPA. All components listed do not apply to the California Proposition 65 Regulation. Does not apply. Does not apply. Does not apply. All components listed on inventory. 116. OTHER INFORMATION Un-Controlled The following sections have been revised since the last issue of this MSDS Not applicable Additional Information Disclaimer Statement For additional information on the use of this product, contact your local Halliburton representative. For questions about the Material Safety Data Sheet for this or other Halliburton products, contact Chemical Compliance at 1-580-251-4335. This information is furnished without warranty, expressed or implied, as to accuracy or completeness. The information is obtained from various sources including the manufacturer and other third party sources. The information may not be valid under all conditions nor if this material is used in combination with other materials or in any process. Final determination of suitability of any material is the sole responsibility of the user. ***END OF MSDS*** CANOLA OIL Page 5 of 5 . . MATERIAL SAFETY DATA SHEET ......................................................·.....$çÇTJ(jN.·..l.~·f:'Fl()l)tJþT.ANtJ.·.¢QMpANY·!f:)liNTI¡:(C.AT(Q!tl............. . PRODUCT NAME: Diesel Fuel; SYNONYMS: Diesel Fuel #1 - LS Dyed; Diesel Fuel #2 - DSL2, Off-Road, On-Road, HS-Dyed, LS-Dyed, LS-U, ndyed LS Diesel; Winter Blend; Fuel Oil #2 - Diesel Fuel Oil, No.2 Diesel Fuel Oil, Non-Hwy Dyed; Diesel Fuel- Premium, Super, Supreme, Powerblend, Non-Taxed LS Dyed; Additized; Russian Summer; Arctic; -10 and -35 F pour point depressed diesel; Lago; Burner Oil; Aleyska Turbine Fuel; Distillate - Mid; No.2; Marine - Marine Gas Oil, MGO, DFM; Navy Fuel; F76; Marine Diesel Fuel (MDO); Intermediate Marine Fue11F-30 to IF-460; IMF; RR Diesel Fuel- No. 40, No. 35, RR Power Fuel HS Off-Road; CARB Diesel Fuel- On-Road, Off-Road, Tax Exempt Blends, TF3, 10%; EPA - LS Diesel Fuel Dyed, Undyed, Off- Road HS Dyed - Ultra Low Sulfur Diesel GENERAL USE: Fuel PRODUCT DESCRIPTION: Liquid. Color varies, clear, yellow (pale to straw), red, blue, blue-green color. Petroleum odor. MANUFACTURER'S NAME Tesoro Petroleum Com anies, Inc. ADDRESS (NUMBER, STREET, P.O. BOX) 300 Concord Plaza Drive (CITY, STATE AND ZIP CODE) San Antonio, TX 78216-6999 DISTRIBUTOR'S NAME Same ADDRESS (NUMBER, STREET, P.O. BOX) COUNTRY USA DATE PREPARED: September 16, 2004 SUPERSEDES: Ma 23, 2002 TELEPHONE NUMBER FOR INFORMATION Tesoro Call Center 877 783-7676 EMERGENCY TELEPHONE NUMBER Chemtrec 800 424-9300 Page 1 of 5 TELEPHONE NUMBER FOR INFORMATION (CITY, STATE AND ZIP CODE) COUNTRY EMERGENCY TELEPHONE NUMBER ....... ·:::::<}::.:<:S1tët'ON2';,;:i-IAZAR6ti()siNGflÉDiENfS>·<· . . . . . . . . . . . . - . . . . . . . . . . - . . . . - . . . . . . . . . . . . . . . - - . . . . . . . . . . . . . . . . . . . . . . . . . . . OSHA PEL HAZARDOUS COMPONENTS CAS # RQ LBS Contains or May Contain: ..... ...._............... .. .·_.._.__n._................ ..n..___" _........... . ......_...._.__..___m_n.__..__._....... Diesel Fuel #2 ................-...-......-........ ...__...n...n..'_____....._....._..___ . .....--............-..---......-....-- .n......................__....._.._ ..............-.................................--..-....-- . ,-------.-......-.---.- n" un.. ..n. ____.....___..._..__.__....__..__...._.............. ..........-..........---...-..... .... ......._."".................._.....-~_.._....- 68476-34-6 0 - 100 ------ 68476-30-2 0 - 100 . .............. ..._.__.,____........_.........__......___.._._...._~. ..~_ ... ...·............_....._..n.. ~~.__.._~__.._ .. _. ..... ...._....... ...._......~._.__.._" 64741-45-3 0-100 ------ 64741-56-6 0 -100 not established . ....... ....--..- -.... ,..-. ~......._.._. .... .................._............_-_....._-~.._~-~...._...._-_.__......_._....-..-..........-..--.-......... 64741-61-3 0-100 0.2 64741-59-9 0 - 100 not established .. _....._..__..._......__.__..n__..._.._.._........._....._......... ......_......~n~..__ .__...... .._.._............_..._......_ ...__....____..__.__~..~__.._~.._.._.__.__..__..__.._.._...._ ............ ...._._._.._.....__....._.._..__~_...._._....__ 64741-62-4 0 - 100 0.2 ----------~--- 1330-20-7 0 -1.1 100 435 100 .... ... .._..__. _.._...~_._u.._..__.._....____._~_..._...._._.._ ...... .... .. ...._.. ____.___..._.._.. ._........_..__.._.____.__...._n~_.._._._~_._ ..............._.._._.._..____._...._..__ 95-63-6 0 - 1.2 25 125 ----- 111-84-2 0 -1.1 200 1050 ..... .-....-.-....-.--.--..-....-.-...-..-.-.-..._.___._______.._....._.._._........__......._._...._._...____._~._....................._.._ ..... ...··_·....__..__·_...._..__M_.___~_._~.._..__.~ 7704-34-9 0 - 5.0 15 91-20-3 0 - 1 10 50 not established Fuel Oil #2 not established . ..--..---......---........-.-...............-. .. . ..._.._...___..__n_.._.. ---""--..-............-....- _M_..M...._____.____...__......___. Tower Residues, atmospheric ------- Residues (petroleum), Vacuum -...-.--......-..........-......-..-....-...- ..-.. .....-....-. - - ..-.....--................-.....---....,.. .......-..- Heavy catalytically cracked distillate (e,f,g) ------------- Light thermally cracked distillate (h) _._,,__.____....._..... .. .. _..__.. _... n' .. ._.._.........._..___n__.._...___.__.._........_._...__.._..____.._._.__....._._..__..__ Catalytically cracked clarified oil (e,g) ------- Xylene (mixed) (a,b,c) _.._ .. _n__.~.._,...._..........__...._... . ...., _n. .._.."............. .. __.___ . _._.. __...._........_..___.____._.____ Trimethylbenzene 1,2,4 (a) not established _.. ___,. _._..__...._..n..........__,_...~_ ..... .....~n_._..__............_.._ - ----_..~...._......__._...._.._.... 0.2 ...... ._.._...._._-..__......~._..__._... 0.2 Yes 1000 .........__............_........-..._..~-_....._._..- Yes ------------- ---- Nonane 200 ... ·.._.._.._..·_........·.._.........____h____.._ . ...........M......··_·__..·__.....·____..M'___..___...... .........-..-......-.--------.-.-..--.-..... Sulfur, precipitated ----------------- Naphthalene (a,b,c,d) ...._..·..·........__.._,__........_......................M_._.~.....__ .........._.....__......_n'____..__.........._..._____ , ~._._.._..__.._........_..___..._..~.__...._.._...._ Red Dye ------------~ (a,c) See Section 15 (b) Indicates that the Resource Conservation and Recovery Act (RCRA) has determined the waste for this chemical is listed as hazardous and must be handled according to regulations in 40 CFR 260-281. (d) Productfš-liStedõr def¡-ñecf;;S a marine pollutantin IMDG Code or 49 CFR 172.101 Appendix B, List of Marine Pollutants and must be classified as an Environmentally Hazardous Substance, Class 9, in addition to any other defined hazards for this product. --(ejCaÚfomjaPrõp65,Sa-feÖrinkingWaterarïdToxfcEniõ¡:cëïnentActof1986,chemicaïšknowrltõthe-štatetocausecanë:erorreprOduë:tiveiôïdci¡Y:-Ä-- person in the course of doing business must warn others who may consume, come into contact with, or otherwise be exposed to this chemical. -(f)IARC haš-determfned that resfdualfuels arepossibly-carcinogenictõ-hum-ans. Handling procedureš and safety precautiõrï-S¡ntïi-eMSDS-šïïõuld befollowed to minimize employee's exposure. u__(g) IARC has determined there isslJfficieni evideñcefor tiïec;arcinogenicity of catalyticallYcracked oils. ---. 10 Yes 100 ..--....-......-.-.....----..........--.....-. not specified Trace -~~~------ --..-......--.....-.......-....... (h) -kidney damage may result fôïlowing aspiraÜõn pneumõnitis.The results ôf animal tÏiô¡;Š-sayš- on middledistiïïatefueïš-show that prolonged dermal cõniact-U produces a weak to moderate carcinogenic activity. . . MATERIAL SAFETY DATA SHEET PRODUCT NAME: Diesel Fuel; SYNONYMS: Diesel Fuel #1 - LS Dyed; Diesel Fuel #2 - DSL2, Off-Road, On-Road, Page 2 of 5 HS-Dyed, LS-Dyed, LS-Undyed, LS Diesel; Winter Blend; Fuel Oil #2 - Diesel Fuel Oil, No.2 Diesel Fuel Oil, Non-Hwy Dyed; Diesel Fuel- Premium, Super, Supreme, Powerblend, Non-Taxed LS Dyed; Additized; Russian Summer; Arctic; -10 and -35 F pour point depressed diesel; Lago; Burner Oil; Aleyska Turbine Fuel; Distillate - Mid; No.2; Marine - Marine Gas Oil, MGO, DFM; Navy Fuel; F76; Marine Diesel Fuel (MDO); Intermediate Marine Fue11F-30 to IF-460; IMF; RR Diesel Fuel No. 40, No. 35, RR Power Fuel HS Off-Road; CARB Diesel Fuel- On-Road, Off-Road, Tax Exempt Blends, TF3, 10%; EPA LS Diesel Fuel Dyed, Undyed, Off-Road HS Dyed - Ultra Low Sulfur Diesel September 16,2004 ........................................................................................................................................................1$............................................................................ ... ·<»>«<>::::SECTlON3::.HAZARD :/DENTIFICATlON<' ....................._--............,,-...............--.........................., EMERGENCY OVERVIEW Various colored liquid, potentially hazardous vapors. Flammable as defined by DOT and TDG. May be classified by DOT as Combustible. Classified as Combustible by OSHA. Can cause eye and skin irritation upon contact. Inhalation of vapors can cause anesthetic effect leading to death in poorly ventilated areas. Hazard symbols for this product - Xn Risk Phrases - R10 20 36/38 POTENTIAL HEALTH EFFECTS INHALATION: High concentrations are irritating to the respiratory tract; may cause headache, dizziness, nausea, vomiting and malaise. SKIN: Brief contact may cause slight irritation; prolonged contact may cause moderate irritation or dermatitis. EYES: High vapor concentration or contact may cause irritation and discomfort. INGESTION: May result in vomiting; aspiration of vomitus into the lungs must be avoided; DO NOT induce vomiting. Minute amounts aspirated into the lungs can produce severe lung injury, chemical pneumonitis, pulmonary edema or death. CARCINOGENICITY NTP? No IARC MONOGRAPHS? No OSHA REGULATED? No This product contains a mixture of petroleum hydrocarbons called middle distillates. Because of this broad description, many products are considered middle distillates yet they are produced by a variety of different petroleum refining processes. Toxicology data developed on some middle distillates found that they caused positive responses in some mutagenicity tests and caused skin cancer when repeatedly applied to mice over their lifetime. . ·········::>.:.:.:.·.·>..>..:.:.>....>.......:·......5iEctlO/V..:4.:.;.FIRSfAID>MEASURlES»>.·.·:·:::: ..---.. -.-_..-.... ................... ..--........,.... ................ ................................................................................. INHALATION: Remove affected person to fresh air; provide oxygen if breathing is difficult; if affected person is not breathing, administer CPR and seek emergency medical attention. SKIN: Remove contaminated clothing; wash affected area with soap and water; launder contaminated clothing before reuse; if irritation persists, seek medical attention. EYES: Remove contact lenses. Flush eyes with clear running water for 15 minutes while holding eyelids open; if irritation persists, seek medical attention. INGESTION: DO NOT induce vomiting; if vomiting occurs spontaneously, keep head below hips to prevent aspiration of liquid into lungs; seek immediate medical attention. Vomiting may be induced only under the supervision of a physician. :.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:..:.:.:.:.:::.:.:.:..:·.·.·.·:·:·..:·.·:·:.::::.·:·.·.·.SEC.tio/V.:ð> FlRË·:FI GHtiNG...MEÄ$UREŠ....:·:....::·.·:·· . ...-.............-.............-......".................................-.... FLASH POINT (METHOD USED) I FLAMMABLE LIMITS LEL: 0.3% UEL: 10.0% 1000 - 1990 F (380 - 930 C) TCC I AUTOIGNITION TEMPERATURE: 3500 - 6250 F I NFPA CLASS: II GENERAL HAZARDS: Product is considered combustible. Products of combustion include compounds of carbon, hydrogen and oxygen, including carbon monoxide. EXTINGUISHING MEDIA Carbon dioxide, water fog, dry chemical, chemical foam FIRE FIGHTING PROCEDURES Firefighters must wear full facepiece self - contained breathing apparatus in positive pressure mode. Do not use solid stream of water since stream will scatter and spread fire. Fine water spray can be used to keep fire - exposed containers cool. UNUSUAL FIRE AND EXPLOSION HAZARDS Closed containers can explode due to buildup of pressure when exposed to extreme heat. Do not use direct stream of water on pool fires as product may reignite on water surface. Caution - Material is combustible! HAZARDOUS COMBUSTION PRODUCTS Smoke, fumes, oxides of carbon . . MA TERrAL SAFETY DATA SHEET PRODUCT NAME: Diesel Fuel; SYNONYMS: Diesel Fuel #1 - LS Dyed; Diesel Fuel #2 - DSL2, Off-Road, On-Road, HS-Dyed, LS-Dyed, LS-Undyed, LS Diesel; Winter Blend; Fuel Oil #2 - Diesel Fuel Oil, NO.2 Diesel Fuel Oil, Non-Hwy Dyed; Diesel Fuel- Premium, Super, Supreme, Powerblend, Non-Taxed LS Dyed; Additized; Russian Summer; Arctic; -10 and -35 F pour point depressed diesel; Lago; Burner Oil; Aleyska Turbine Fuel; Distillate - Mid; No.2; Marine - Marine Gas Oil, MGO, DFM; Navy Fuel; F76; Marine Diesel Fuel (MDO); Intermediate Marine Fue11F-30 to IF-460; IMF; RR Diesel Fuel No. 40, No. 35, RR Power Fuel HS Off-Road; CARB Diesel Fuel- On-Road, Off-Road, Tax Exempt Blends, TF3, 10%; EPA LS Diesel Fuel Dyed, Undyed, Off-Road HS Dyed - Ultra Low Sulfur Diesel September 16, 2004 Page 3 of 5 .......:...:...................:...:...........:....$£ÖtloN..i;.:ENtIIRONMENtAL··SElEAs/E.MEAStJRES......··· . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . "." ....... ........... STEPS TO BE TAKEN IN CASE MATERIAL IS RELEASED OR SPILLED: COMBUSTIBLE. Evacuate and ventilate area; confine and absorb into absorbent; place material into approved containers for disposal; for spills in excess of allowable limits (RQ) notify the National Response Center (800) 424 - 8802; refer to CERCLA40 CFR 302 and SARA Title III, Section 31340 CFR 372 for detailed instructions concerning reporting requirements. Do not discharge into lakes, ponds, streams or public waters. . ...........................:.............:...:.:..............···...·..:.··....·.SECT/Of\l.j)i1ANDLJNG.A.IVD:·.STOliAGE.·...·............ ............................................................................. .......................... .......................... ....................... ......................... .................... PRECAUTIONS TO BE TAKEN IN HANDLING AND STORAGE: This material is combustible. It should be stored in tightly closed containers in a cool, well ventilated area. Vapor may form explosive mixtures in air. All sources of ignition should be controlled. This material may be classified as COMBUSTIBLE by DOT unless transported by vessel or aircraft. Refer to 49 CFR 173.120. Keep this and other chemicals out of reach of children. Avoid inhaling concentrated fumes or vapors. .. ..... . . . .. . . .... . . ... .... . .···.···.·.·.·.·..:·................:...........SSCt/()N..8.;..EXP()SUBS.:CONTROLS/PER$()NAL...PROTECTION...·........:.:....... . ................................................................................................................................ ENGINEERING CONTROLS The use of local exhaust ventilation is recommended to control emissions near the source. Provide mechanical ventilation of confined spaces. Use explosion-proof ventilation equipment. See Section 2 for Component Exposure Guidelines. PERSONAL PROTECTION: RESPIRATORY PROTECTION (SPECIFY TYPE): None required while threshold limits (Section 2) are kept below maximum allowable concentrations; if TWA exceeds limits, NIOSH approved respirator must be worn. Refer to 29 CFR 1910.134 or European Standard EN 149 for complete regulations. PROTECTIVE GLOVES: Neoprene or rubber gloves with cuffs. EYE PROTECTION: Protective eyeglasses or chemical safety goggles. Refer to 29 CFR 1910.133 or European Standard EN166. OTHER PROTECTIVE CLOTHING OR EQUIPMENT: Safety eyebath nearby WORK I HYGIENIC PRACTICES: Practice safe workplace habits. Minimize body contact with this, as well as all chemicals in general. . . . .. »>««>.>«$Eþtl()ly!J)I:JldY$IÇALAN[)/C.f1~iti!lçAl..I:Jljþl?~RtIS$.>:>· VAPOR PRESSURE (PSIA) VAPOR DENSITY (AIR = 1) < 0.5 PSIA (â> 100° F > 1 SPECIFIC GRAVITY @ 60° F (WATER = 1) EVAPORATION RATE (WATER = 1) 0.78 - 0.955 < 1 SOLUBILITY IN WATER FREEZING POINT NeQIiQible, below 1.0% - 51° F (- 46° C) pH APPEARANCE AND ODOR Not determined Liquid, clear, yellow (pale to straw), red, blue, blue-Qreen, petroleum odor. BOILING RANGE PHYSICAL STATE 30 - 806° F (1.1 - 430° C) Liquid VISCOSITY VOLATILE ORGANIC COMPOUNDS (Total VOC's) 1.7 - 40.0 cS (â> 100°F . 6.75 Ibs I gallon . . . . ·»«$ECfl()NfO;~$rifø.ILlT'f:ìfNl?REÂcflfllTY.·»» . STABILITY UNSTABLE: STABLE: XXX INCOMPATIBILITY (MATERIALS TO AVOID): Strong oxidizers, strong acids CONDITIONS TO AVOID: Extreme temperatures, open flames HAZARDOUS DECOMPOSITION OR BYPRODUCTS: Decomposition will not occur if handled and stored properly. In case of a fire, oxides of carbon, hydrocarbons, fumes, and smoke may be produced. HAZARDOUS POLYMERIZATION MAY OCCUR: CONDITIONS TO AVOID: None WILL NOT OCCUR: XXX . . MATERIAL SAFETY DATA SHEET PRODUCT NAME: Diesel Fuel; SYNONYMS: Diesel Fuel #1 - LS Dyed; Diesel Fuel #2 - DSL2, Off-Road, On-Road, Page 4 of 5 HS-Dyed, LS-Dyed, LS-Undyed, LS Diesel; Winter Blend; Fuel Oil #2 - Diesel Fuel Oil, NO.2 Diesel Fuel Oil, Non-Hwy Dyed; Diesel Fuel- Premium, Super, Supreme, Powerblend, Non-Taxed LS Dyed; Additized; Russian Summer; Arctic; -10 and -35 F pour point depressed diesel; Lago; Burner Oil; Aleyska Turbine Fuel; Distillate - Mid; No.2; Marine - Marine Gas Oil, MGO, DFM; Navy Fuel; F76; Marine Diesel Fuel (MDO); Intermediate Marine Fue11F-30 to IF-460; IMF; RR Diesel Fuel- No. 40, No. 35, RR Power Fuel HS Off-Road; CARB Diesel Fuel - On-Road, Off-Road, Tax Exempt Blends, TF3, 10%; EPA LS Diesel Fuel Dyed, Undyed, Off-Road HS Dyed - Ultra Low Sulfur Diesel September 16, 2004 . .. ·················..··..····................·..·sl£ct/ÖN..n;toXICÖLOGICAlfNÞÖRMAt/o/v··......········ ..........-.............. ...... .............................. ........................... ........................ ............................................................................................ Hazardous Ingredients (All products may not be CAS # EINECS # LD50 of Ingredient LC50 of Ingredient listed if information is not available) (Species and Route) (Species) Contains or May Contain: Diesel Fuel #2 68476-34-6 270-676-1 Not established Not established Fuel Oil #2 68476-30-2 270-671-4 Not determined Not determined Tower Residues, atmospheric 64741-45-3 265-045-2 Not established Not established Residues (petroleum), Vacuum 64741-56-6 265-057-8 Not established Not established Heavy catalytically cracked distillate (e,f,g) 64741-61-3 265-063-0 Not established Not established Light thermally cracked distillate (h) 64741-59-9 265-060-4 Not established Not established Catalytically cracked clarified oil (e,g) 64741-62-4 265-064-6 Not established Not established Xylene (mixed) (a,b,c) 1330-20-7 215-535-7 4300 mg I kg 5000 ppm I 4H Oral - rat Inhalation - rat Trimethylbenzene 1,2,4 (a) 95-63-6 202-436-9 5 gm I kg 18gm/m3/4H Oral - mouse Inhalation - rat Nonane 111-84-2 203-913-4 218 mgl kg 3200 ppm I 4H Oral - mouse Inhalation - rat Sulfur, precipitated 7704-34-9 231-722-6 Not available Not available Naphthalene (a,b,c,d) 91-20-3 202-049-5 1780 mg I kg Not established Oral - rat Red Dye not specified not specified Not determined Not determined ........ ......................................................··.......·....·SECt/ON..·.,i;.15cdLOGICAt..·'N#okIfifA·t¡O/V.............. .............-.................. .............................. ........................... ........................... .................... ................................................................................ ................. No data are available on the adverse effects of this material on the environment. Neither COD nor BOD data are available. Release of this product should be prevented from contaminating soil and water and from entering drainage and sewer systems. U.S.A. regulations require reporting spills of this material that could reach any surface waters. The toll free number for the U.S. Coast Guard National Response Center is (800) 424-8802. Naphthalene (91-20-3) one of the ingredients in this mixture is classified as a Marine Pollutant. . -. -. - ., . . . . . . ............................................................:..···.·.:.:·$Et)tt()N··t3~·t)I$P(:)$A.L:·.C(:)N$ltJERAr.ION$·...>··......... . ..........................-.........................,..................-.--..... WASTE DISPOSAL METHOD: Dispose of in accordance with Local, State, and Federal Regulations. This product may produce hazardous vapors or fumes in a closed disposal container creating a dangerous environment. Refer to "40 CFR Protection of Environment Parts 260 - 299" for complete waste disposal regulations. Consult your local, state, or Federal Environmental Protection Agency before disposing of any chemicals. Do not flush to sanitary sewer or waterway. ........ ·SEcr/ON14rFt4N$poRtlNFORMArlØ.N . . . . . . . . . . . .........:-:-:-::::::::::..:...:.:. :::::.::.:..:::-.:_<:::::.::...::~::::.::.::.::.: :.:-_.:"::':::-'-::::::':::'::::::':':" .<.-:::..:..:......::-.::.::...-:::.:-.::::<..... PROPER SHIPPING NAME: Diesel Fuel DOT HAZARD CLASS I Pack Group: 3/111 lATA HAZARD CLASS I Pack Group: Not applicable REFERENCE: 49 CFR 173.150, .203, .242 IMDG HAZARD CLASS: Not applicable UN I NA IDENTIFICATION NUMBER: NA 1993 RID/ADR Dangerous Goods Code: Not applicable LABEL: Flammable UN TDG Class I Pack Group: Not applicable HAZARD SYMBOLS: F ····Note:-Yransporta1ior.-¡ñformaÜon-provideëfisforreference-orÏïy.-CI-ieñiTsl:,rgeëfio· consuïi-c-FR49partS1ÖO=-177~Trv'-DërIÄfÄ:-EC,ÜrÏ¡ied---- Nations TDG, and WHMIS (Canada) TDG information manuals for detailed regulations and exceptions covering specific container sizes, packaging materials and methods of shipping. . . MATERIAL SAFETY DATA SHEET PRODUCT NAME: Diesel Fuel; SYNONYMS: Diesel Fuel #1 - LS Dyed; Diesel Fuel #2 - DSL2, Off-Road, On-Road, Page 5 of 5 HS-Dyed, LS-Dyed, LS-Undyed, LS Diesel; Winter Blend; Fuel Oil #2 - Diesel Fuel Oil, NO.2 Diesel Fuel Oil, Non-Hwy Dyed; Diesel Fuel- Premium, Super, Supreme, Powerblend, Non-Taxed LS Dyed; Additized; Russian Summer; Arctic; -10 and -35 F pour point depressed diesel; Lago; Burner Oil; Aleyska Turbine Fuel; Distillate - Mid; No.2; Marine - Marine Gas Oil, MGO, DFM; Navy Fuel; F76; Marine Diesel Fuel (MDO); Intermediate Marine Fue11F-30 to IF-460; IMF; RR Diesel Fuel - No. 40, No. 35, RR Power Fuel HS Off-Road; CARB Diesel Fuel- On-Road, Off-Road, Tax Exempt Blends, TF3, 10%; EPA LS Diesel Fuel Dyed, Undyed, Off-Road HS Dyed - Ultra Low Sulfur Diesel Se tember 16, 2004 ..... ..... ............ . ·················..·····.·...····..··.·····..<.·...··..SlfctfCJN...1S·..;.BlfGUl.A.rt5iBV/NEÖRMAttOA/·......········ . ...............................................................,.................... TSCA (Toxic substance Control Act) All components of this product are listed on the U.S. Toxic Substances Control Act Chemical Inventory (TSCA Inventory) or are exempted from listing because a Low Volume Exemption has been granted in accordance with 40 CFR 723.50. SARA TITLE III (Superfund Amendments and Reauthorization Act) 311/312 Hazard Categories Acute health, flammable 313 Reportable Ingredients: (a) A "Yes" in the SARA TITLE III column in Section 2 indicates a toxic chemical subject to annual reporting requirements of Section 313 of the Emergency Planning and Community Right-To-Know Act of 1986 and of 40 CFR 372. CERCLA (Comprehensive Response Compensation and Liability Act) (c) The Comprehensive Environmental Response, Compensation, and Liability Act (CERCLA) has notification requirements for releases or spills to the environment of the Reportable Quantity (RQ for this mixture> 24,000 Ibs) or greater amounts, according to 40 CFR 302. CPR (Canadian Controlled Products Regulations) This product has been classified in accordance with the hazard criteria of the Controlled Products Regulations and the MSDS contains all the information required by the Controlled Products Regulations. IDL (Canadian Ingredient Disclosure List) Components of this product identified by CAS number are listed on the Canadian Ingredient Disclosure List are shown in Section 2. DSL 1 NDSL (Canadian Domestic Substances List 1 Non-Domestic Substances List) Components of this product identified by CAS number are listed on the DSL or NDSL and mayor may not be listed in Section 2 of this document. Only ingredients classified as "hazardous" are listed in Section 2 unless otherwise indicated. EINECS (European Inventory of Existing Commercial Chemical Substances) Components of this product identified by CAS numbers are on the European Inventory of Existing Commercial Chemical Substances. EC Risk Phrases SYMBOL(S) REQUIRED EC Safety Phrases R10 Flammable FOR LABEL S23 Do not breathe vapor R20 Harmful by inhalation S25 Avoid contact with eyes R36/38 Irritating to eyes and skin. Harmful S28 After contact with skin, wash immediately with R51 Toxic to aquatic organisms. plenty of soap and water. R65 Damaging to lungs when swallowed S29 Do not empty into drains S62 If swallowed, do not induce vomiting; seek medical advice immediately and show this label. ...... ·....»<SËcti(jN.f6~ÖtHËRtN¡::;ORMAt¡(:jN<..·......·· ...........................-...............................-.... Values do not reflect absolute minimums and maximums; these values are typical which may vary from time to time. HMIS HAZARD RATINGS HEALTH FLAMMABILITY PHYSICAL HAZARD PERSONAL PROTECTIVE EQUIPMENT 1 2 o B 0= INSIGNIFICANT 1 = SLIGHT 2 = MODERATE Safety Glasses, Gloves 3 = HIGH 4 = EXTREME REVISION SUMMARY: This MSDS has been revised in the following sections: Section 1, add name; Section 3, Hazard Symbols; Section 11, add EINECS #; Section 15, TSCA text, add symbol; Section 16, HMIS Text MSDS Prepared by: Chem-Tel, Inc. 1305 N. Florida Ave. Tampa, Florida USA 33602 (800) 255-3924 Outside USA (813) 248-0573 tl~r~~~Ël~~~~i~~~%:tt:t4NII~~~.ÆmMt~~R;~t~~c~JM~~e()~JW~1~~o~~rJK·.p$li€~m H~~¡jijng, ..~r¡¡g~¡ .u~¡)r.4Í!iP.q~1.qtih~~þQ~¡.ef~~· .pròdµ~· .i!f~YqiiØ. Qui- ~rjtrò·~ii¡i¡iiayo~µr.unq~i- ¢iiijdkÍ(jÌis ·.~~IC~· Væ..are .lfi¡fi¡Riiiiar. ..f:Q~ ·tHË$i; AND. .Q.THeR.· R~sòN$,.· W$ .D<:5. NOt .A$SUME. .R¡:SP<:5NSIEjIi,;ttY:.. AND. E)(pfies.sL Y.. DiSCLAiM.. tiNY.. IJA$ilJry· .FQ.R .bAMAi::¡S, ·iNJtJRY. ANt> .¢<:5S'r. .ARI$ING FBQMQF.tRaAt¡:;otQTHSù$eòF:tHSJ'>RòÞùöt~> . . . . . . . . . .. .. . . . . . . . . . . . .. ...................................................................... PRODUCT NUMBER (s). BHPP-1052, BHPP-1054, MSDS-1054, 2, 3, 27, 28, 29, 30, 31, 32, 33, 34, 35, 36, 37, 39, 46, 75, 88, 89, 90, 94, 97, 98, 99,100,101, 102,103,104,105,106,108,109,111,116, 117, 118,282,290,291,294,304,319,351,352, 1000, 1001, 1071,1076 4t-{P . . ~ ,---, :i~wj:r ~~\ II ',.! í,., j \0 W , r:J fi::ä ¡ '1 :j of i¡ J? '~.~ "(:1 "" :L.:::::! FRANK H. MURKOWSKI, GOVERNOR AI~SIiA OIL Alft) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 September 27, 2004 Proposals to Amend Underground Injection Orders to Incorporate Consistent Language Addressing the Mechanical Integrity of Wells The Alaska Oil and Gas Conservation Commission ("Commission"), on its own motion, proposes to amend the rules addressing mechanical integrity of wells in all existing area injection orders, storage injection orders, enhanced recovery injection orders, and disposal injection orders. There are numerous different versions of wording used for each of the rules that create confusion and inconsistent implementation of well integrity requirements for injection wells when pressure communication or leakage is indicated. In several injection orders, there are no rules addressing requirements for notification and well disposition when a well integrity failure is identified. Wording used for the administrative approval rule in injection orders is similarly inconsistent. The Commission proposes these three rules as replacements in all injection orders: Demonstration of Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before lllJection begins, at least once every four years thereafter (except at least once every two years in the case of a slurry injection well), and before returning a well to service following a workover affecting mechanical integrity. Unless an alternate means is approved by the Commission, mechanical integrity must be demonstrated by a tubing/casing annulus pressure test using a surface pressure of 1500 psi or 0.25 psi/ft multiplied by the vertical depth of the packer, whichever is greater, that shows stabilizing pressure and does not change more than 10 percent during a 30 minute period. The Commission must be notified at least 24 hours in advance to enable a representative to witness mechanical integrity tests. Well Integrity Failure and Confinement Whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, log, or other evidence, the operator shall immediately notify the Commission and submit a plan of corrective action on a Form 10-403 for Commission approval. The operator shall immediately shut in the well if continued operation would be unsafe or would threaten contamination of freshwater, or if so directed by the Commission. A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating well integrity failure or lack of injection zone isolation. . . Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. The following table identifies the specific rules affected by the rewrite. Affected Rules Injection Order "Demonstration of "Well Integrity "Administrative Mechanical Failure and Action" Integrity" Confinement" Area InJection Orders AIO 1 - Duck Island Unit 6 7 9 AIO 2B - Kuparuk River Unit; Kuparuk River, 6 7 9 Tabasco, Ugnu, West Sak Fields AIO 3 - Prudhoe Bay Unit; 6 7 9 Western Operating Area AIO 4C - Prudhoe Bay Unit; 6 7 9 Eastern Operating Area AIO 5 - Trading Bay Unit; 6 6 9 McArthur River Field AIO 6 - Granite Point Field; 6 7 9 Northern Portion AIO 7 - Middle Ground 6 7 9 Shoal; Northern Portion AIO 8 - Middle Ground 6 7 9 Shoal; Southern Portion AIO 9 - Middle Ground 6 7 9 Shoal; Central Portion AIO 10B - Milne Point Unit; Schrader Bluff, Sag River, 4 5 8 Kuparuk River Pools AIO 11 - Granite Point 5 6 8 Field; Southern Portion AIO 12 - Trading Bay Field; 5 6 8 Southern Portion AIO 13A - Swanson River 6 7 9 Unit AIO 14A - Prudhoe Bay 4 5 8 Unit; Niakuk Oil Pool AIO 15 - West McArthur 5 6 9 . . Affected Rules "Demonstration of "Well Integrity "Administrative Injection Order Mechanical Failure and Action" Integrity" Confinement" River Unit AIO 16 - Kuparuk River 6 7 10 Unit; Tam Oil Pool 6 8 AIO 17 Badami Unit 5 AIO 18A - Colville River 6 7 11 Unit; Alpine Oil Pool AIO 19 - Duck Island Unit; 5 6 9 Eider Oil Pool AIO 20 - Prudhoe Bay Unit; 5 6 9 Midnight Sun Oil Pool AIO 21 - Kuparuk River 4 No rule 6 Unit; Meltwater Oil Pool AIO 22C - Prudhoe Bay 5 No rule 8 Unit; Aurora Oil Pool 6 9 AIO 23 Northstar Unit 5 ArO 24 - Prudhoe Bay Unit; 5 No rule 9 Borealis Oil Pool AIO 25 - Prudhoe Bay Unit; 6 8 13 Polaris Oil Pool AIO 26 - Prudhoe Bay Unit; 6 No rule 13 Orion Oil Pool Disposal Injection Orders DIO 1 - Kenai Unit; KU No rule No rule No rule WD-1 DIO 2 - Kenai Unit; KU 14- No rule No rule No rule 4 DIO 3 - Beluga River Gas No rule No rule No rule Field; BR WD-l DIO 4 - Beaver Creek Unit; No rule No rule No rule BC-2 .. DIO 5 - Barrow Gas Field; No rule No rule No rule South Barrow #5 DIO 6 - Lewis River Gas No rule No rule 3 Field; WD-l DIO 7 - West McArthur 2 3 5 River Unit; WMRU D-I DIO 8 - Beaver Creek Unit; 2 3 5 BC-3 DIO 9 - Kenai Unit; KU 11- 2 3 4 17 DIO 10- Granite Point 2 3 5 Field; GP 44-11 . . Affected Rules "Demonstration of "Well Integrity "Administrative Injection Order Mechanical Failure and Action" Integrity" Confinement" DIO 11 - Kenai Unit; KU 2 3 4 24-7 DIO 12 -Badami Unit; WD- 2 3 5 1, WD-2 DIO 13 - North Trading Bay 2 3 6 Unit; S-4 DIO 14 - Houston Gas 2 3 5 Field; Well #3 DIO 15 - North Trading Bay 2 3 Rule not numbered Unit; 5-5 DIO 16 - West McArthur 2 3 5 River Unit; WMRU 4D DIO 17 - North Cook Inlet 2 3 6 Unit; NCIU A-12 DIO 19 - Granite Point 6 Field; W. Granite Point State 3 4 17587 #3 DIO 20 - Pioneer Unit; Well 3 4 6 1702-15DA WDW DIO 21 - Flaxman Island; 3 4 7 Alaska State A - 2 DIO 22 - Redoubt Unit; RU 3 No rule 6 Dl DIO 23 - Ivan River Unit; No rule No rule 6 IRU 14-31 DIO 24 - Nicolai Creek Order expired Unit; NCU #5 DIO 25 - Sterling Unit; SU 3 4 7 43-9 DIO 26 - Kustatan Field; 3 4 7 KFI Storage Injection Orders SIO 1 - Prudhoe Bay Unit, No rule No rule No rule Point Mcintyre Field #6 SIO 2A- Swanson River 2 No rule 6 Unit; KGSF #1 SIO 3 - Swanson River Unit; 2 No rule 7 KGSF #2 Enhanced Recovery In.iection Orders EIO 1 - Prudhoe Bay Unit; No rule 8 Prudhoe Bay Field, Schrader No rule Bluff Fonnation Well V-105 . . Affected Rules Injection Order "Demonstration of "Well Integrity "Administrative Mechanical Failure and Action" Integrity" Confinement" EI0 2 - Redoubt Unit; RU-6 5 8 9 · . ] I 02-902 (Rev. 3/94) Publisher/Original Copies: Department Fiscal, Department, Receiving AO,FRJ\1 STATE OF ALASKA ADVERTISING ORDER NOTICE TO PUBLISHER ADVERTISING ORDER NO. INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTIFIED AO-02514016 AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COpy OF ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE F R o M AOGCC 333 West ih Avenue, Suite 100 Anchorage, AK 99501 907-793-1221 AGENCY CONTACT DATE OF A.O. T o Journal of Commerce 301 Arctic Slope Ave #350 Anchorage, AK 99518 October 3, 2004 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: United states of America AFFIDAVIT OF PUBLICATION REMINDER State of ss INVOICE MUST BE IN TRIPLICATE AND MUST REFERENCE THE ADVERTISING ORDER NUMBER. A CERTIFIED COpy OF THIS AFFIDAVIT OF PUBLICATION MUST BE SUBMITTED WITH THE INVOICE. ATTACH PROOF OF PUBLICATION HERE. division. Before me, the undersigned, a notary public this day personally appeared who, being first duly sworn, according to law, says that helshe 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 Colombie <jody _ colombie@admin.state.ak.us> Date: Wed, 29 Sep 2004 13:01 :04 -0800 lof2 9/29/20041:10PM Public Notices . . 20f2 9/29/2004 1:10 PM Public Notice . . Subject: Public Notice From: Jody Colombie <jody _ colombie@admin.state;ak.us> Date: Wed, 29 Sep 2004 12:55:26 -0800 Please publish the attached Notice on October 3, 2004. Thank you. Jody Colombie Content-Type: applicationimsword Mechanical Integrity of Wells N otice.doc Content-Encoding: base64 Content-Type: applicationimsword Ad Order form. doc Content-Encoding: base64 1 of 1 9/29/2004 1: 10 PM Citgo Petroleum Corporation PO Box 3758 Tulsa, OK 74136 Kelly Valadez Tesoro Refining and Marketing Co. Supply & Distribution 300 Concord Plaza Drive San Antonio, TX 78216 Jerry Hodgden Hodgden Oil Company 408 18th Street Golden, CO 80401-2433 Kay Munger Munger Oil Information Service, Inc PO Box 45738 Los Angeles, CA 90045-0738 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 James Gibbs PO Box 1597 Soldotna, AK 99669 Richard Wagner PO Box 60868 Fairbanks, AK 99706 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 . Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 . /lJal"kd It'/~lj David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Housron, TX 77056 Robert Gravely 7681 South Kit Carson Drive Littleton, CO 80122 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 John Levorsen 200 North 3rd Street, #1202 Boise, ID 83702 Samuel Van Vactor Economic Insight Inc. 3004 SW First Ave. Portland. OR 97201 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle, WA 98119-3960 Schlumberger Drilling and Measurements 2525 Gambell Street #400 Anchorage, AK 99503 David Cusato 200 West 34th PMB 411 Anchorage. AK 99503 Ciri Land Department PO Box 93330 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Jack Hakkila PO Box 190083 Anchorage, AK 99519 Darwin Waldsmith PO Box 39309 Ninilchick, AK 99639 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 Penny Vadla 399 West Riverview Avenue Soldotna, AK 99669-7714 Cliff Burglin PO Box 70131 Fairbanks, AK 99707 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 North Slope Borough PO Box 69 Barrow, AK 99723 [Fwd: Re: Consistent Wording for Injection.s - Well Integrity ... . Subject: [.Fwd: Re: Co. nsistent.Wördingfor IIlJ~ction Orders-.Wellmt¢gritY{Reviseq)] F~om: John Norman<john_n0nfian@ait111in.state.ak.Us>··· .... ...... ...... . Date: Fri, 01· Oct 2004 11:09:26..0800 more -------- Original Message -------- Subject:Re: Consistent Wording for Injection Orders - Well Integrity (Revised) Date:Wed, 25 Aug 2004 16:49:40 -0800 From:Rob Mintz <robert mintz@law.state.ak.us> To:iim regg@admin.state.ak.us CC:dan seamount@admin.state.ak.us, john norman@admin.state.ak.us Jim, looks good, but I still think maybe it would be good to include the following sentence or something like it in the well integrity and confinement rule: "The operator shall shut in the well if so directed by the Commission." My thinking is that otherwise, an operator might argue that the Commission can only require the well to be shut in by going through an enforcement action, issuing an order after notice and opportunity for hearing, or meeting the strict requirements for an emergency order under the regulations. The proposed language makes clear that it is a condition of the authorization to inject, that the operator must shut in the well jf directed by the Commission after a notification of loss of integrity, etc. »> James Regg <¡im regg@¿,admin.state.ak.us> 8/25/2004 3:15:06 PM »> Rob - Thanks for the review; here's a redraft after considering your comments. I have accepted most of the suggested edits; also attached is response to questions you pose (responses are embedded in the comments, using brackets [JBR - ...] to set apart from your questions). Jim Regg Rob Mintz wrote: Jim, I have some questions about the draft language, which 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 <¡im regg@¿,admin.state.ak.us> 8/17/20044:33:52 PM »> Please delete previous version (email sent 8/9104); 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 TubinglCasing 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 lof2 10/2/20044:07 PM [Fwd: Re: Consistent Wording for Injectio.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", "USDW s"; "risk of fluid movement"; "fluid escape from disposal zone" Jim Regg John K. Norman <John Norman(GJadmin.state.us> Commissioner Alaska Oil & Gas Crnservation Commission 20f2 101212004 4:07 PM [Fwd: Re: Consistent Wording for Injection.s - Well Integrity... . Subject: [Fwd: Re:Consìstent W ordingfor Injection Orcfers "WellrnfegrityCR:evised)] F'r(}lR: John Norman <john__nqrman@âdmin.stâtê.ak.llS> Dåte: Fri, 01 Oct 2004 11:08:55 -0800 please print all and put in file for me to review just prior to hearing on these amendments. thanx -------- Original Message -------- Subject:Re: Consistent Wording for Injection Orders - Well Integrity (Revised) Date:Thu, 19 Aug 200415:46:31 -0800 From:Rob Mintz <robert mintz(Q?law.state.ak.us> To:dan seamount(Q?admin.state.ak.us, jim re.gg(Q?admin. state. ak.us, john norman(Q?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 reg,g@Jadmin.state.ak.us> 811 7/20044:33:52 PM »> Please delete previous version (email sent 8/9104); 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 TubinglCasing Annulus Mechanical Integrity" - "Well Integrity Failure" - "Administrative Actions". This proposal includes input from all Sr. staff (except Jack). If you agree with the approach, I'll work with Jody to prepare the public notice. Main points - Demonstration of Tubing/Casing Annulus Mechanical Integrity - standardizes the wording used for mechanical integrity demonstrations, and establishes abililty to grant alternate methods (e.g., temp survey, logging, pressure monitoring in lieu of pressure testing - specific to AIO 2C for Kuparuk, there is wording that is more appropriately included in Well Integrity Failure (i.e., more ti-equent MITs when communication demonstrated) - establishes more frequent MIT schedule for slurry injection wells (every 2 yrs) which is consistent with our current practice (but not addressed in regulations) Well Integrity Failure - retitles to "Well Integrity Failure and Confinement"; inserted language regarding injection zone integrity (see 010 25 and 26) - consistent language regardless of type of injection (disposal, EOR, storage); - eliminates requirement for immediate shut in and secure; allows continued injection until Commission requires shut in if there is no threat to ti-eshwater; - 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 lof2 10/2/20044:07 PM [Fwd: Re: Consistent Wording for Injectio.rs - Well Integrity ... . - adopts "Administrative Actions" title (earlier rules used "Administrative Relief'); - consistent language regardless of type of injection (disposal, EOR, storage); - uses "administratively waive or amend" in lieu 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~admin.state.us> Commissioner Alaska Oil & Gas Cæservation Commission Content-Type: applicationimsword Injection Order language - questions.doc Content-Encoding: base64 Injection Orders language Content-Type: applicationimsword Content-Encoding: base64 20f2 10/2/2004 4:07 PM . . Standardized Language for Injection Orders Date: August 17, 2004 Author: Jim Regg Demonstration of Tubing/Casing Annulus Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before injection begins, after a workover affecting mechanical integrity, and at least once every 4 years while actively injecting. For slurry injection wells, the tubing/casing annulus must be tested for mechanical integrity every 2 years. The MIT surface pressure must be 1500 psi or 0.25 psi/ft multiplied by the vertical depth, whichever is greater, must show stabilizing pressure and may not change more than 10% during a 30 minute period. Any alternate means of demonstrating mechanical integrity must be approved by the Commission. The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests. Well Integrity Failure and Confinement The tubing, casing and packer of an injection well must demonstrate integrity during operation. The operator must immediately notify the Commission and submit a plan of corrective action on Form 10-403 for Commission approval whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, or log. If there is no threat to freshwater, injection may continue until the Commission requires the well to be shut in or secured. A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating pressure communication or leakage. Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. . . Standardized Language for Injection Orders Date: August 17,2004 Author: Jim Regg Demonstration of Tubing/Casing Annulus Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before injection begins, at least once everv four years thereafter (except at least once everv two years in the case of a slurrv iniection well), and before returning a well to service foUO\ving- afæf a workover affecting mechanical integrity, and at least once every '1 yenr~; ':;hile actively injecting. For slurry injection wells, the tubing/casing ar.nulus must be tested for mechanical integrity every 2 years. Unless an alternate means is approved bv the Commission. mechanical integrity must be demonstrated by a tubing- pressure test using a +fle M±+-surface pressure of must be 1500 psi or 0.25 psi/ft multiplied by the vertical depth, whichever is greater, that ffl:t:tSf-show~ stabilizing pressure that doesand mí1)' not change more than 10%- percent during a 30 minute period. -Afl.y alternate means of demonstrating mechanical integrity must be approved by the Commission. The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests. Well Integrity Failure and Confinement Except as otherwise provided in this rule, +1he tubing, casing and packer of an injection well must demonstrate maintain integrity during operation. "Whenever any pressure communication. leakage or lack of iniection zone isolation is indicated by iniection rate. operating pressure observation. test, survey, log. or other evidence. t+he operator fffi!:Sf-shall immediately notify the Commission and submit a plan of corrective action on a Form 10-403 for Commission approval, "vhenevcr any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, or log. The operator shall shut in the well if so directed bv the Commission. The operator shall shut in the well without awaiting a response from the Commission if continued operation 'would be unsafe or would threaten contamination offreshwaterlfthere is no threat to fresh'v\'ater, injection may continue until the Commission requires the -;,:611 to be shut in or secured. Until corrective action is successfully completed. Aª monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating pressure communication or leakage. Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. . . [Fwd: Re: [Fwd: AOGCC Proposed WI Lanee for Injectors]] . Sµi)ject: [Fwd: Re: [Fwd: AOGCC Proposed WI Language for Injectors]] ~..om:WintohAubert <winton_aubert@admin.state.ak.us> Bate: Thu, 28 Qct2004.09:4~:53.-Q800 This is part of the record for the Nov. 4 hearing. WGA -------- Original Message -------- Subject: Re: [Fwd: AOGCC Proposed WI Language for Injectors] Date: Thu, 28 Oct 2004 09:41:55 -0800 From: James Regg <jim regg@admin.state.ak.us> Organization: State of Alaska To: Winton Aubert <winton aubert@admin.state.ak.us> References: <41812422.8080604@admin.state.ak.us> These should be provided to Jody as part of public review record Jim Winton Aubert wrote: FYI. -------- Original Message -------- AOGCC Proposed WI Language for Tue, 19 Oct 2004 13:49:33 -0800 Engel, Harry R <EngelHR@BP.com> winton aubert@admin.state.ak.us Injectors Subject: Date: From: To: Winton... Here are the comments we discussed. Harry *From: * NSU, ADW Well Integrity Engineer *Sent: * Friday, October 15, 2004 10:43 PM *To: * Rossberg, R Steven; Engel, Harry R; Cismoski, Doug A; NSU, ADW Well Operations Supervisor *Cc: * Mielke, Robert L.; Reeves, Donald F; Dube, Anna T; NSU, ADW Well Integrity Engineer *Subject: * AOGCC Proposed WI Language for Injectors Hi Guys. John McMullen sent this to us, it's an order proposed by the AOGCC to replace the well integrity related language in the current Area Injection Orders. Listed below are comments, not sure who is coordinating getting these in front of Winton/Jim. Overall, looks okay from an Operations perspective. We do have a few comments, but could live with the current proposed language. Note the proposed public hearing date is November 4. The following language does not reflect what the slope AOGCC inspectors are currently requiring us to do: "The mechanical integrity of an injection well must be demonstrated before injection begins, at least once every four years thereafter (except at least once every two years in the case of a slurry injection well), and * before*_** lof3 10/28/2004 11 :09 AM . , [Fwd: Re: [Fwd: AOGCC Proposed WI Lan. for Injectors]] . returni.ng a well to service following a workover affecting mechanical integrity." After a workover, the slope AOGCC inspectors want the well warmed up and on stable injection, then we conduct the AOGCC witnessed MITIA. This language requires the AOGCC witnessed MITIA before starting injection, which we are doing on the rig after the tubing is run. Just trying to keep language consistent with the field practice. If "after" was substituted for "before", it would reflect current AOGCC practices. It would be helpful if the following language required reporting by the "next working day" rather than "immediately", due to weekends, holidays, etc. We like to confer with the APE and get a plan finalized, this may prevent us from doing all the investigating we like to do before talking with the AOGCC. "Whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, log, or other evidence, the operator shall * immediately* ** notify the Commission" -- This section could use some help/wordsmithing: "A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating well integrity failure or lack of injection zone isolation." Report content requirements are clear, but it's a little unclear what triggers a well to be included on this monthly report. Is it wells that have been reported to the AOGCC, are currently on-line and are going through the Administrative Action process? A proposed re-write would be: "All active injection wells with well integrity failure or lack of injection zone isolation shall have the following information reported monthly to the Commission: daily tubing and casing annuli pressures, daily injection rates." Requirements for the period between when a well failure is reported and when an administrative action is approved are unclear. This document states "the operator shall immediately notify the Commission and submit a plan of corrective action on a Form 10-403". If we don't plan to do any corrective action, but to pursue an AA, does a 10-403 need to be submitted? The AOGCC has stated they don't consider an AA as "corrective action". Let me know if you have any questions. Joe -----Original Message----- From: Kleppin, Daryl J Sent: Wednesday, September 29, 2004 1:37 PM To: Townsend, Monte A¡ Digert, Scott A¡ Denis, John R (ANC) ¡ Miller, Mike E¡ McMullen, John C Subject: FW: Public Notices FYI -----Original Message----- From: Jody Colombie [ mailto:jody colombie@admin.state.ak.us Sent: Wednesday, September 29, 2004 1:01 PM Subject: Public Notices Please find the attached Notice and Attachment for the proposed amendment of underground injection orders and the Public Notice Happy Valley #10. Jody Colombie «Mechanical Integrity proposal. ZIP» «Mechanical Integrity of Wells Notice.doc» 2 of3 10/28/2004 11 :09 AM #5 ) ) ConocJPt.illips Shannon Donnelly Senior Environmental Coordinator Post Office Box 66 Kenai, AK 99611 Phone (907) 776-2092 Fax: (907) 776-2095 Email: Shannon.Donnelly@conocophillips.com RECEiVE,D AU G 1 ~1 '2.005 Alaska Oii & Gas Cons. CommissiQrt Anchmage August 15, 2005 Jim Regg Alaska Oil and Gas Conservation Commission 333 W. 7th Ave #100 Anchorage, Alaska, 99501-3539 Fax(907)276-7542 RE: Administrative Approval Request for Disposal of Cement Rinseate and Approved Non-Hazardous Fluids in BRWD-1 (DI0003) Dear Mr. Regg: The Beluga River Gas Field is a remote gas production facility located on the west side of Cook Inlet. Access is maintained primarily by helicopter support, the use of fixed wing aircraft, and by limited use of supply barges during the open water months. The facility is equipped with limited means for managing fluid wastes on-site. The primary disposal option for routine fluids such as produced water is the dedicated Class II Disposal Well (BRWD-1, Disposal Injection Order No. 3). Camp wastes are managed through a permitted septic system. Under normal operating conditions, the facility is able to successfully manage most non- hazardous and/or exempt fluid wastes. Small quantities of hazardous waste and other wastes that cannot be managed locally are stored temporarily prior to proper management off-site. During periods of non-routine activity in the field, such as periods of intensive well work and drilling programs, the Class II-D disposal well may be utilized more intensively to manage wastes returned from downhole. Periodically during such work, non-hazardous wastes directly associated with well maintenance and drilling activities that have not been down hole may be generated. Such waste streams include cement rinseate, small quantities of completion fluids and well workover or test fluids, and unused drilling mud. At the present time, management options for these types of wastes are not readily available in the Beluga River Field, nor is it practical to containerize these fluids for off site disposal. ConocoPhillips Alaska makes a concerted effort to minimize the quantities of Class I wastes generated through proper planning. However, in evaluating waste management options in support of the 2005 Beluga River work over program it has been determined that the preferred option for managing non-hazardous drilling and well service fluid is via disposal in BRWD-1 when such wastes are generated. The purpose of this letter is to request AOGCC concurrence for this disposal request. ) ) August 15, 2005 Page 2 ConocoPhillips Alaska respectfully requests approval from the Commission to utilize the permitted Class II disposal well, BRWD-1, for the disposal of designated non-hazardous fluids on a contingency basis, such as periods of well work or during drilling programs. Use of the Class 11-0 well in this capacity would be restricted to an as-needed basis, and all disposal activities would be properly documented and reported. Provisional approval to use BRWD-1 for disposal of cement rinseate, unused drilling mud, and other non-hazardous well service fluids would significantly increase operational flexibility and minimize potential environmental exposure. Included for your review are analytical results for a representative sample of cement rinseate, and an MSDS for commonly used cement product demonstrating the waste is non-hazardous. Excess KCI Water (1-3% KCI) and CaCI2 brine (-10 ppg) may also be generated and require disposal. These are completion fluids that are used routinely in well work and work over applications. MSDS's in support of the non- hazardous nature of these fluids are also attached. Thank you very much for your consideration of this proposal. Please do not hesitate to contact me (907) 776-2092 should you have any questions or additional information needs. Sincerely, -,"~í/j~/~ Shannon Donnelly 'C./ - ~ , Õ Environmental Coordinator ConocoPhillips Alaska- Cook Inlet Asset S:\CIA\ENVIRONMENTAL\wastc management\Disposal Rcquests\Disposal of drilling material in BRWD.doc 0'3,/27./2002 øg: 1.0 ~'~O¡;?Tf-Ir-l"¡ TEST LAB -7 9077766095 I) \' N J,I orC-J~erp\., r,10 . 226 [;)02 m Phillips Petroleum, Co,m,pany KsnID RBgion Test ~:a 35 I 8" 'Sf'N"' l-LJ~w"'1 ~o IJðtt-\~ t tÂ.K o/1C:,e:,c¡ CHAIN OP' CUSTODY RECORD ph. ;¿bZ -.J.!tf:,7/j "..I, '\~,t ' :,~ SAMPI..E LOCATION: T:tCJ rr,e k Þ I~ t..çðrHI~ I tùei/ '# ß-,<. ID# . DESCIÜÞTI:ON I LOCATION 8AMPLEP.8: (Printed) (Sir,n,~~I.Te) . /ÄVlkV\9~~ WI Tl'lESS; O?r.int(;lø.) Dl~,TE 'I'1MF. . (SiL"rH'¡rnre) SAMPJ~ TYPE # oF. CONT. ANA,LYSI8 REQ.UIDFJ) Q,AlQC REQUffiED : &meI1.! t''t1 ~.atk t/f-25 (~'r:.1I "ll. ß~ ~ 'tJ;o. h I . f II ~/íJ.7 . . - . - j Re1irlquitihed, by: (Prinr.e;:)) Dn,te l1'imð RooaiV'ed by:- œrin,~d) \,P:\ o.~'tØ-- Cø ~ i Daw ï T1rne , \ L.c.:o~ fA, {Sig.ri¡¡tura) ., ' . , (ßiffOa.tuYe)~ ~~~. _, _q~...q1--" R<liJ,qu;.hml by: (Prirted) Lci:\ .."1..... (å, \~tD.!IO I 'i'!me Rec.ived by;~""ted) é J1 rl;S Wor~t.u; I Time (,9ìR\1orore) ~ (' ~ q~~ ~ (Sigr¡oture) ~ I<J~ 1~-='~~, :R.<,hnq1..n~h~~;t~ted) ðrr~f' ~ å-k 1?,ì.)tI:Ct~ I TII11ß RecelV8d bf œ;~. œn~~' I~ ~ ~,.J;'\ Þf Do~~~ (Siß11ature) ~ß~ .. 9~~~!SIO .JSjgnature) f~ q-'lf.,.¿)"1.-- X RaJi!\quls~ by: (p-niltbd) Date 1 Time Rcç.eived by; rinted) .p~fi().. <." - ~ w.)_r-:J Datðl Time ~llturo) (s¡gnnrure)f.f!! ~_{, ') ~ ~4 7/fP V ,130 Reli,T.\quÜ~he.d by; <Print8d) Dote I Timo Rect\ívod by; œrintedJ .- () Date ( Timo . (Signowre) DifJpat£:hed by: (printed) (8ífÇ1~~ure) DatJ) I Ti.me R()(.øi\'ed. Qt I~e.bor~tory by: Date I Time (sìgnl¡,t~re) RchnQ.uiljhed, by (Prin.~) Dote I Tim., Received by: (1?r.inteii) Da.te/Time ~~tur9) Method of Sniprnemt: (Signpture) (! ..o!I~ .( C>..atA1."", Temp. Soá.}Ð Yð!.1 no Crr!. Pol......... ~.~ ¡ I r~~lJ..t:<,. rlt!--t r~~ Mlt ~ Commtmt.e: Good Fair Poor I:iw~ 1I)L~l'1ldt{Ì1II ?if'4<\{> €I Iè fA&h. If ip.rJ1~~.· dOM~f I ~ .@ ~.~ct:> . COW'- ~ a I ;$ð:. tt:\11 ~, !\('¡"'~~ Hi Ai. C:¡07- ï7(:,~ 7..ð'1Z. 1 70'- 2éJ ll~ r::~ .1!J 'to .R 6t1 i..!(!d " /2.S /tH Form PF-OOSJ 0'3./27.,·'2002 0'3: 10 ~,jORn-''-')j TEST LAB II + 90777660'35 ¡or ;. CLIENT: SAMPlE MARKED: SAMPLE POTNT: SAMPLE DA IE/T1MB: SAMPLED BY: SAMPLE RECEIVED: SAMPLE ANALYZED: SAMPLE NUMBER: \-- .~ .~_ ,..:_... _ _.I.Y' PARAMETER .... ...:.. .w___ "iII," :,x·--, ... pH ern ) es~ Phi11ips .PelToleu.m Company Tyonek Platform, Well B-2 Cement RinsE1;te 9/25/02 9/27/02 9/27/02 20022035-01 . ,.W':,....-.h ·'---~'A METHOD SM 4500H-t-B ...., Rev1ewedIReleased By: t ft ..J t'~-~ n r ~.~h·d a ~'·10 . 226 D01 RßSUL T UNIT AN'ALVS'T - ~-'- ~.... - -...-... . .' W.7 su P Crow]ey 3S\~(, ~PllR f:IWV SOl..DOTNA, AX 996(í!) (!)(I1) 26~tíJ.~ 1~1t1: (91)7) 26).....1:0777 An:.!1yrìclIl, Environrocnrllt, Gco/'cclI1lICQI, Canmuttlotl Mr.r,(;'f¡fI~ I(~t!ng ) ) Schlurnberger MATERIAL SAFETY DATA SHEET (Complies with USA OSHA 29 CFR 1910.1200 and ANSI Z 400.1) PRODUCT CODE: D907 Effective Date: 19-December-2001 1. IDENTIFICATION OF THE SUBSTANCE/PREPARATION AND OF THE COMPANY/UNDERTAKING Identification of the substance or preparation: CEMENT CLASS G D907 Company/undertaking identification: Schlumberger 110 Schlumberger Drive Sugar Land, Texas 77478, USA Corporate Emergency Phone: Corporate Non-Emergency Phone: USA 1-281-595-3518 USA 1-281-285-7873 2. COMPOSITION/INFORMATION ON INGREDIENTS PORTLAND CEMENT; CAS 65997-15-1; 60-100% 3. HAZARDS IDENTIFICATION Emergency Overview Form: Color: Odor: Main environmental hazards: None known. Main Physical Hazards Special Precautions: Physical Hazard: Main Health Hazards: HMIS RATING: Health 2 Flammability 0 Reactivity 0 May cause allergic reaction upon repeated skin exposure. May cause eye irritation. May cause respiratory tract irritation. Causes irritation if swallowed. May cause skin irritation. See Section 11 for a complete discussion of health hazards. Powder Gray Typical None. Dust 4. FIRST AID MEASURES Eye contact: Notes: Immediately flush eyes with water for 15 minutes while holding eyelids open. Seek medical attention. Remove contaminated clothes and shoes. Wash thoroughly with soap and water. Seek medical attention if irritation occurs. Remove to fresh air. Seek medical attention if irritation persists or you feel unwell. DO NOT induce vomiting. Give 2 glasses of milk (preferred) or water and seek medical attention at once. None. Skin contact: Inhalation: Swallowing: Page 1 of 4 Extinguishing media: Further Information: Flash point: Method: Flammability (explosion limits in air): Lower: Not applicable Autoflammability (auto-ignition temperature): Explosive properties (thermal decomposition temperature): NFPA Rating: Health 2 Flammability 0 Reactivity 0 Other: None Combustion products: see Section 10.. ) PRODUCT CODE: 0907 Effective Date: 5. FIRE FIGHTING MEASURES 19-December-2001 None needed None known. Not combustible. Not applicable Upper: Not applicable Not applicable Not determined 6. ACCIDENTAL RELEASE MEASURES After spillage/leakage: Scoop into containers. Flush residual with plenty of water. See Section 8 for protective equipment information. Se8 Section 13 'for disposal information. 7. HANDLING AND STORAGE Special Precautions: Packaging requirements: Ventilation: Keep material dry. Paper bag (minimum 3 ply), or other industrial container designed for powders and granulated materials. Provide ventilation to keep airborne concentrations below exposure limits. 8. EXPOSURE CONTROLS/PERSONAL PROTECTION Respiratory protection: Use NIOSH approved respirator with dust and mist protection (3M 8210). Chemical splash goggles. Impervious gloves made of: Rubber Clean, body-covering clothing. Eye protection: Hand protection: Skin protection: Exposure Limit Guidelines (mg/m3) No components have established exposure limits. Dust particles: total = 10 mg/m3, respirable fraction = 5 mg/m3. 9. PHYSICAL AND CHEMICAL PROPERTIES Form: Color: Odor: pH value: Boiling point: Pour point: Vapor pressure: Relative density (specific gravity): Bulk Density (solids): Powder Gray Typical in water 11-13 Not applicable Not applicable Not applicable Approximately 3.0 Not determined Page 2 of 4 ) PRODUCT CODE: D907 Solubility in water: Viscosity: Relative Vapor Density (air=1): % Volatile: Nature 10. STABILITY AND REACTIVITY Stability: Conditions to avoid: Materials to avoid: Hazardous Polymerization: Dust explosion hazard (solids): Special hazards: Hazardous decomposition products: 11. TOXICOLOGICAL INFORMATION Eye contact: Skin contact: Inhalation: Ingestion: Carcinogenicity: Mutagenicity: Teratogenicity: Target organs which may be affected: Sensitization: Other: 12. ECOLOGICAL INFORMATION Information on product as a whole: Main environmental hazards: Degradability: Fish Toxicity: 13. DISPOSAL CONSIDERATIONS Product: Container: USA EPA RCRA: ) Effective Date: 19-December-2001 Miscible with water Not applicable Not applicable <1 Alkaline Stable. None known Acids Will not occur. No. None. None. Irritant. May cause pain, redness, discomfort. Irritant; may cause pain, redness, dermatitis. Irritant; may cause pain and coughing. Irritant; may cause pain or discomfort to mouth, throat and stomach. Not listed by IARC, USA NTP, or USA OSHA. Not known to cause heritable genetic damage. Not known to cause birth defects. None known. May cause allergic reaction upon repeated skin exposure. None. None known. Not applicable Low toxicity to fish. Dispose of by sanitary landfilling or other acceptable method in accordance with local regulations. Send empty bags to sanitary landfill. Render other types of containers unuseable by puncturing or crushing and sanitary landfill unless prohibited by local regulations. None Page 3 of 4 , PRODUCT CODE: D907 Effective Date: 19-December-2001 14. TRANSPORT INFORMATION ICC Tariff Classification Cement ICC Item Number: 42130 ICC Class: CERCLA RQ: Not established. Department of Transportation (DOT) 50 LTL 35 TL Designation: Hazard Class: Shipping Name: DOT Label: Not Regulated Not Regulated Not Regulated Canadian Shipments Shipping Name: Label: Classification: Not Regulated Package Group: PIN: none 15. REGULATORY INFORMATION Notification/restrictions status: USA: All components of this material are on the USA TSCA inventory, or the components are exempt from inventory reporting. CANADA: All components of this material are on the Canada DSL, or the components are exempt from inventory reporting. This product contains no chemicals subject to the USEPA reporting requirements of SARA 313. The USEPA CERCLA Reportable Quantity (RQ) for this product as a whole is: Not established. Canadian WHMIS classification: D2B 16. OTHER INFORMATION Sections affected by last revision: IDENTIFICATION OF THE SUBSTANCE/PREPARATION AND OF THE COMPANY/UNDERTAKING *Mark of Schlumberger. The information herein is believed to be accurate and is presented in good faith; however, no warranties or representations are made by Schlumberger regarding the accuracy or completeness of the information. Page 4 of 4 Aug,20, 2002 3:55PM No,1935 p, 6 r'A - r J ' L ,C ' I X9.~39 . CALCIUM CHL01UQ§.J.:ALL GRADES) REVISION DATE: 07-~,:QQ ... SAFETY DATA SHEET CALCIUM CHLORIDE (ALL GRADES) 1. IDENT1FICATION OF THE SUBSTANCE/PREPARATION AND THE COMPANY: PRODUCT NAME: APPLICAT10NS~ EMERGENCY TELEPHONES: SUPPUER: CALCIUM CBLORIDE (ALL GMDF.$) Oil wcll completi.olJ fluid additivê. TELEPHONE: FAX: 001.1&1 5611600 (USA) M-I DrilLing Fluids UK Ltd, .E'OCIAt. Quay, rootd~. Aberdeen. A.B 11 SDQ 44 (0)1224 ~ 584336 44 (0)1224 ~ 576119 2. COMPOSITlONI1NFORMATION ON INGREDIENTS: INGREDIENT NAME: CALClU~ CHLORJDE CAS No.: 100.4.3-52-4 CONTENT HEALTH: Xi RISK: 36/38 COMPOSITlON COMMENTS; Thi/ï produce is dossified. as an Í1:ritaOt according to the EU Direcrivcg_ 3. HAZARDS IDENTIFICA rION: J.njCJting to eyes and skin. 4. FIRST AID MEASURES: INHALA T1ON: GeoCJJl1 fim ttid. rest, wmntb an.d tk:sh air. Get medical atœntioJ) íf any di.<¡comfort continues. INGESTION: Ri.n:Je mouth trnxoughly with ~œr. Vict:iJns wl10 are notuncotl.Sciö~ should drink la'Bc qUJUltitiC$ ófmilk or wtItcr, or &clf Î.Dd1lce vomir:ing (o.g. by :¡ticking own finger inro the throat). Get mediCo11 3I:œ.n!Ío.n. if any discomfon oonti:nuos. SKIN: ?rompt1y wttSh cont.1.InÏn.atoo. 8Ki.n ~!ith roap or mild detergenr 3M vr.uer. Promptly remove clotb.i.ng if6olÙc.c.d through IDld W\1Sh áS above. Get medical attention if irritatioo )«S.lstS afl:cr 'W11Shl.ng. EYES: Promptly ~b. eyes wirh. plemy of water while lifting tb.e. ¡ry-c lids. Con.t:Ì.nl1è to rinse fur at lea.f\t 1.5 rninu1r::rJ aod get ro.cd.ica.l <\t1entjoD.. 5. FIRE FIGHTING MEASURES: EXTINGUISHING MEDlk US(: QÍÌnb'ù.i:iliîng mOOia appropriate for 8UIroundi.c.g fire. SPECiAL FIRE FtGHTING PROCEDURES: NOTE! Uœ aiJ.'-5upplic:d r~pirators to protect sgain,st: gBSC'j\~. 1 i 4 J:~~~M ) No,1935 P,7 AUß· ¿U. ¿lJUL M-'f·L.C. [ ( )0539 ~ CALCIUM CHLOi.....0E (ALL GRADE~l_______~,____,,_~,,~,,___~,_~~~~,,__,..~, REVJ.S10N PAlE.: 07-06-00 HAZARDOUS COMBUSTION PRODUCTS: Fire Of high tðrnpö~ creare: Toxic gases/..."apoJ:Slfumçs of: Cbloric~. .---.............- 6, ACCIDENTAL RELEASE MEASURES: SPILL CLEANUP METHODS: A V'O.id genOJ.3ri.o,(\ and spreading of dust. CoUut and œ.claim or di!ipo!Jc in s.c:.a1cd cootUncr:r, in licensed Wi1!1tt:. Flush with plenty of wafer to crean spillage area.. - - __v',···"- . ....... __ 7. HANDLING AND STORAGE: USAGE PRECAUTIONS: Avoid spil~ skin a.ad ~ contact. Avoid bandling which kads to du£;t formJ1tÏon. STORAGE PRECAUTIONS: Keep i.n coo1.. dry, v0ml1atro m:or.age and c105t;d ooorniOCr.8. .Keep in, oAgiJJ.B1 containør. 8. EXPOSURE CONTROLS AND PER$ONAL PROTeCTION: INGREDIENT NAME: CALCIUM CHLORIDE CAS No.: 1 0043~52-4 STD: LT EXP. 8 HRS: No std. ST EXP.15 MIN: No std. INGREDIENT COMMENTS~ NUl = NWS9J)Ce.Dust. OE.$ TW A 4.rnglm.1 resp.iJ:3.bJe du.'>!t 10:mglm3 rotnl, dUR!. PROTECTIVE EQUIPMEHT: Oð~ VENTILATION: Provide mfficient ve.nti1a.tion fur opêr3tioC$ ~~.ing dwt fo.rmatio.11. RESPIRATORS: D, Dust ma~respirator. Dust flit".!:' ~2 (foX' fine dust). PROTECTIVE GLOVES: US<t1 suitahle prot~-nve gloves ¡frisk of slcin contact. Use protðCtÍ.ve glo'lies made of: lmpermeàbk materià.1. Rubber, nooprene or PVC. EYE PROTECTION: Wear dutt rx:.cist<mt safd)' gOB8'le& wbf:,r~ tbeJ.'C is danger of ØY''' contlCt.. OTHER PROTECTION: Wear. appropriate clothing to p.rev~n[ re}:X'ared or pNlo.nged skin contact.. Provide eyewa~ station. I 9. PHYSICAL AND CHEMICAL PROPERTIES: APPEARANCE: G.ranular. Crystals. Pellets. Flakes. Powder, dust. COLOUR: Whìte. to Grey. ODOURlTASTE: Odourless or .DO cl:I.u.rocteristic odoor. SOLUBILITY DESCRJPTION: v!::fy solub1c in 'WB.!er. SOLUBILITY VAlUE (g/100g H20 20°C): 7S MOL. WEIGHT: 1]J. BOILING POINT (OC, ¡maNal): >1600 PRESSURE; MELT JfREEZ. POINT (OC, interYiJt): 772 DENSITY/SPECifiC GRAVITY ÚJ/ml): 2.J. ·2.5 TEMPERATURE ("C); 20 BULK DENSITY: 800 ~m3 pH~VAlUE, DILUTED SOLUTION: 9 - 10.5 CONCENTRATlON (%)-i): 100 gI1 2/4 Aug,iU, iUUi M - ')L ' L ' C . ( .~~ÇI,YM-9l&hQ~~\?ß (~JJ...9RAQ.É~51_ REVISION DATE.: 07-ú6-OO 3:~5PM ) No,1935 P,8 10. STABILITY AND REACTIVITY: STABILITY: Nor.mally ~ble. CONDITIONS TO AVOID: Avo:îd contact ~th~, Hyg.t1)OCopjc. MATERIA.LS TO AVOID; BQSéiJ~iC8 (inorg¡mic). -""'~... 11. TOXICOLOGICAL INFORMATION: TOXIC DOSE - LD 50: 1000 mg/kg (oral-rot) INHALATION: Ms.y cau..'\e iIri,tarion to r.b.e. r.cspÚ'BIory sysrem. INGESTION: M.ay cauoo digco.mfort if swo.llowed.. t-..fay ~llie :rtö.l1JRch pain oc vomiting. SKIN: Powdèt may ÌIritaIc ilin.. Pro1onged 0( œ.pøattd exposure may C3.U&e sevC('Ð ir..r.í:tar\QJ.). EYEs: hritation of eyes and mucOU$ .m.embr1lnð:!i. I'brtidt::::s in IDe: C)·C~ Iruly ca'\JS.C iIrit9.tian B.lJd SJ'1:Ul[t:ÍD.g. .-. ·.....--·Y-· . ,. ....-. 12. ECOLOGICAlINFORMATION= .''-''~:,oÞ ~J-- ECOLOGICA1..INFORMATlON: CO.Dt8ct M~J's Environmenrol ~ Department fo.( ccologica.l ínfor::mntÍon. 13. DISPOSAL CONSIDERA TI ONS: DISPOSAL METHODS: Recover .lnd roclItim. or re<.:yc1~ if {J(actical. Dispose of in nœo.rdnnœ witb Local, Authority requirelne.ots. 14. TRANSPORT INFORMATION: ROAD TRANSPORT: ROAD TRANSPORT NOTES: RAIL TRANSPORT: RAIL TRANSPORT NOTES: SEA TRANSPORT: SEA TRANSPORT NOTES: .N ot Clas£.ifièd Not CJ.assi.fi.ed. Not Chtssi.5.cxl. AIR TRANSPORT: AIR TRANSPORT NOTES: Not ClßlJsìfied, -.,..-..,....~- 15. REGULATORY INFORMATION; 3/4 Aug, ~O' 2002 3:55PM M ~ ,L, C, ) No,1935 P, 9 ( .øl0539 - CALCIUM CHLORlDE (ALL GRADES) _"__.ß§':::'~~.JS~tJJ?8P~,: 07 ~06..oo LABEL FOR SUPPLY: )( !RSUIAur RISK PHRASES: R-36!38 Irri.wiug to eyas and !>kìn_ SA.FETY PHRASES: $-22 Do not breathe; dWlt. 5-24/25 Avoid contact -w:ith skin. and cye-s. $-36/37/39 Wc;a,J:' suit3.blc protective c1otbîng~ glove,; and e:yeJfitI:X prote'4i(),ß. It - ,- ...,,---.r\~- 16. OTHER INFORMATION: USER NOTES: HMlS Health· 1 HM.T.S F1.ammabiJity - 0 HMtS 1tcactivìty - 1 INFORMATION SOURCES: Sax's DangcrO'UJ1l'ropc:.rtié'8 oflndu.st::r'W Mntd.Ín1l, ~h ð<J,., Lewis, R.J. 51;'" (00.), VNR. New York., New YorIc, (1997). M.atx::.riJ:ù 5nfcty Data Sbcè't,. Ml~. ID:w.ut3ct11ters. REVISION C;OMPJII:Î'frS:- @@@~Ii~ by S:mh Glover@@@ ISSUED BY; REVISION DATE: Dt'. KiISty Walk.ß( 07 -06-00 THIS SDS IS PRODUCED WITH SAfECHEM fur WINDOWS .~~.- DiSCLAIMER.: MSDS furnish«! indopcndcm of prodUC1 snlc. While eveI)' «ffort M:'> been m."~ to <1CC1¡tt(l!:1.y dd:c:rjb,e thL~ prodUct, ~ of t1)e d8fà.ue ob~.oo. fÌ'OI.U SOtlIca; bcyo.cd om: ditect supc:rvir;ion. We C\'IIlßOt make any 2S~)~;\~ to it::; ~1!Jlbjl.(1y (¡.~ cömplctêl)~~~ ÙIß~f~e. ~J: tlUy .('(II)' on it only gt usa's risk. We have made: no ctrort to tetlWï or cöf.\tt:l11 \~leieJi('/\.1$ :(~pr¡JCt£ of (bl,~ pt,<XIuC't. SJ.occ we ca.n:not a.nricipJl1C Q(' control th~ conditions under which tb.is infonnat:o.n.,\M ¡:»:(JJu.::t ro;ty be ~e.d., Wé make DO BtlAr:aute1! thst the precantioll!!. we ha\'c mggc610d will be sdcquatc: for:ill individuals andior £ttlJ3tio.œ.. It ili tM obligation of ~h 1.1&e.r ()f'ÙlÎJi product 10 corop~' with the:: ~ of \lU IIppJicabJè: 1.'11115 T.cg<\rdjn¡¡: nse 8J:'d ~. of.thh product. Additional infoxmgtion will be fumisbc:d upo.n rcquc::ri to aJS$jst the U~; b~~r, no ~rr4tJt;y. e.itber ~~ed 01: ìxn¡,lie<l, nor lubillty of any M'tOre with ~pect to ihi~ tlrodt:Ict OÄ to'1hè cks.b .I:k.:~in i:s ~ 0" ÌJ:t~ he:tl!:ilt1der. 4/4 AUg.¿lJ. ¿lJU¿ J:~4~M M·')L.L,C. ( ) 04 99 - POTASSIUM CH'Lv.t.<..1DE ) No.1935 p, 2 ,_ ___..BEVISIO}{ DATE: 22~7~22 SAFETY DATA SHEET POTASSIUM CHLORIDE 1. IDENTIFICATION OF THE SUBSTANCE/PREPARATION AND THE COMPANY: pR,onUCT NAMJ:: APPLICATIONS: POTASSIUM CHLORIDE Oil well drlDlng fluid a.d(titive. Oil well com,þlet.ion fil1id addW,ve. EMERGENCY TELEPHONES: 001281 S611600 (USA) M-I DriI.Hng FWids. t.J't-ltd, Poc.ra Quay, Footdoo. A~.AßllSDQ 44 (0)1224 ·584336 44 (0)1224 ~ 576119 SUPPLIER: TELEPHONE: FAX: - _ - ....,.,--,--.-., 2. COMPOSlTIONJ1NFORMATION ON INGRE.DIENTS~ GROSS FOR,MULA: CAS No.: P otaß~LtIn Chlorid£l (KC I) 7447-40~7 COMPOSITION COMMENTS: Tb:Uì product fODI\ulatiùl:l g not eJíl,g,siflOO (\$ baurdous in acc.ordanœ witb tbe EU Diœctiv(:@. 3. HAZARDSIDENTlFICATION: Not regarded as a hð3Jth hmrd lIIldet C1trro1.1t kgÜ¡]ation. 4. FIRST AID MEASURES: INHALATION: M:ove tbt: exposed person to fu:sh air a.t once. Gd!:DCdlca1 a.tI.c:ntion ¡¡any ~órt Mntiaue:t. INGESTION: Ftt:St aid if; not Dor:nWly J:eqt1.Íred. Rinse mouth thoroughl)'.!>rink plenty ofwo.tcr. SKIN: WMh !kin thOföugbly with soop ¡~d wawr. RCU10\le COO'!3tnin.1tI.?d clOtb.iDg. Get mr:dic.eJ. artcntÌo.D, ¡fany disc.om.furt cODtbu~. EYES: Promptly wash eye:g with ple~l1y OfW3tet while: bfting the e~ HŒ. CO,nôoue to rinSG fOI" at ca.<1t 15 xnin!l'tcs. Get medical aH.ðnrioo ifan)' discomfort continues. 5. FIRE FIGHTING MEASURES: EXT1NGUISHING MEDIA: C3tbor.l dioxide (C02). Dry cbemica.1s... Foam. W.1~ sprny, fog or m:i!Jt. SPECIAL FIRE FIGHTING PROCEDURES: Use spccia.l protective clothing. Regular protection may not be We. Use ~ aJr mask if substance is Ïnvolvtd it) a fire. UNUSUAL FIRE & EXPLOSION HAZARDS: No unusual fire: ot explosion hazards DOted. 1/4 Aug,20, 2002 3:55PM M·')L,L,C, ) No.1935 p. 3 ( ·.L~2.:.J0TA5SIUM CB:U.JI;{JPE . _,ßrnSIONDATE: 22·7·99 HAZARDOUS COMBUSTION PRODUCTS: Fh:c or high tcm~re9 creatt:: ~"PhyxiaLing ~~vapol';;:,'fuúk.-s. Cbloridq¡:. 6. ACCIDENTAL RELEASE MEASURES: SPILL CLEANUP METHODS: Sbov~l m[{) dIy cootamern. Çover and move the CQDtIDners. Flush the area. with water. Måy be &liÞt'¢rY wben wet. We:ar. neœz;s.s.ry prOtecrive equiptOC1lt. 7. HANDUNG AND STORAGE: USAGE PRECAUTIONS: Avoid bancl1.Íf\g which 1~ to dust formatìon.. Pt-O'Vide good ventillrtion. STORAGE PRECAUTIONS: Store at moderate terI.1peratures in dry, wen vent:i1s:œd.&:J:ca.. .-~-""""'''---- - 8. EXPOSURE CONTROLS AND PERSONAL PROtECTION: INGREDIENT COMMENTS: Th~1 material is ronsick::r:cd a. nl.ÙsŒnc::c dust, OES TW A 4:mgfm3 Respirable DU5:t, 10 mg/mJ Tow, Dust. PROTECTIVE EQUIPMENT: 08~ VENTI LA 'ftON= fÞro"""¡de adequati! gdDeral and local ~.au$t V~)tiJat:io.n. RESPIRATORS: trventilation is ins.uffici.cr.lt" suit!sbk l'csp:iwöry ~iicn mù..~ be provided Du,st fitt£:r. P.2 (fO( fine dust). PROTECl1VE GLOVES: No spccifi<:: h!md protcotion notèd. but gkrves may still be advisable. For p(O)~ or Npeared E¡,kin contàct use suitable proterov<: glovOJ. Rubba or pläat:ìc. EYE PROTECTION: Wear d~ re~..ista:nt ~ gO,WeSi wb<::re there is dao,gcr of eye COOtMt. OTHER PROTECTION: Wear a~riaœ clothing to p.œvcnt r~ed or pro'long<::d skin cóntncl Providð eyewa.~ station. 9. PHYSICAL AND CHEMICAL PROPERTIES; APPEARANCE: COLOUR: ODOURlTASTE: SOLUBILITY DESCRJPTION: SOLUBILITY VALUE (g/1009 H20 20°C): BOILING POINT (GC, intervar): MELT JFREEZ. POrNT rC, lot.eml): DENSITYISPECIFIC GRAVITY (glml): pH-VALUE, DilUTED SOLUTiON: PARTITION COEFF. (log Pow): Powder, dust. \\I1ili.e.. Odourlcs5 or no chilnlctcri;-tic odour. So1ubk in wltttt. 37 Dublimcs @1500 733 1.93 -7 -3.0 PRESSURE: TEMPERATURE CC): 20 CONCENTRATION (%,M); 1 % 2/4 AUg,¿U. ¿UU¿ j:~~~M M )L . L ' C . ) No.1935 p. 4 ( ..]0499 -:.POTASSIUM CHLv¿(jDE ~IClli.Q.AJ£~}l:2:~, 10. STABILITY AND REACTIVITY: STABILITY: N onnally stable. CONDITIONS TO AVOID: Avoid wd. nn.d humid conditions. MATERIA1..S TO AVOiD: Strong o:Üdiring 3.gents. HAZARDOUS DECOMP. PRODUCTS: Fire 01' high temperatlln::s create: T o:cic g¡1!JCs/\'apòurtifumcs öf: Ch.1ori<k:s. . - - -- 11. TOXICOLOGICAL INFORMATION: TOXIC DOSE ~ LD 50: 2600 mg/kg (orol rat) INHALATION: Dust mlly mttltcrcgp:iratory s)'stem or lungs, INGESTION: SKIN: EYES: Mev èautv:; ~\!b:1c distr~, nausea. and vom.iti:ng if ingested. Powder may irritare skin. Particb: in tbe eyes lJ1,Qy C1I.LISO irriution and 8J1J33:'Qog. 12. ECOLOGICAL INFORMATION: ECOLOGICAL INFORMATION: Contact M·r~ EnvÌIöOInentàl Maim D<:partroc::z:¡t fo,: ~oþgicat lofo1'n)8.tiol),. r _.-....~ ..-'" 13. DISPOSAL CONSIDERATIONS: DISPOSAL METHODS: R.r::oova; t!Dd n:c1a.im or ICCYCk:. if prnctical Dispose of ~) site 1a:ndfitt area... Di~p0s0 of in ~œ with Local. Authority requiremcots. 14. TRANSPORT INFORMATION: RO,AD TRANSPORT: ROAD TRANSPORT NOTES: Not c~ificd for road tranlipOrt. RAIL TRANSPORT: RAIL TRANSPORT NOTES: SEA TRANSPORT: SEA TRANSPORT NOTES: AJR TRANSPORT: AIR TRANSPORT NOTES: N at c.Jß$sifiod for roil transport. Not cJ3ssi fled. for Sè9. tran S'XIrt. N 01: cl:¡s.c¡jfioo for 3.it 1J"3D8pOrt. 15. REGULATORY INFORMATION: RISK PHRASES: NQt c.lassific.d. 3/4 Aug.20. 2002 3:55PM M }, L, C, ) No.1935 P, 5 ( .10499 - ror A3Sn.H1.Çlli.AJ~\lDE REVISION DAtE: n· 7-99 ---_...~- . SAFETY PHRASES: Not c..\asgi£ed. STATUTORY INSTRUMENTS: Chcroico.ls (Haz:ard rtrfumunion and P3dœ.g:ing) R/!;gulaMf).~. ('..oJ)tr.ûl of Su~-tnn~ Hszardous to Hc:ahlI. GUIDANCE NOTES: OccuparioPal Expos\tN Limits EH40. 16. OTHER INFORMATION: USER NOTES: HMJS Health - IltM1S Pl3.n:n:nability - 0 HMJS Reactivity· 0 E· Safety ~~. Glove!), Dust 'R£5Pjmtor. Materi.9l Safety Pat:1 Sheet, Mise,. manl.J:fuctu:t:er.s. S,¡s¡';"$ D.u1gerou(S Propc:rtìcs of !Ddtmrial Mat.èria.t8, ~ ~.. U:wis, R.I. Sr., (ed.), VNR, New y~ New ,,{ùd-, (1991), The Merck Jn~ 11. edit.iop., 1989. Sigo:u-Alddcb Material Sa~ Data Sb.òim 00 CD-ROM. Cp)MtS: S\l.btænœ~ B'~.ardotIs to Health. INFORMATION SOURCeS: ISSUED BY: REVISION DATE: Dr.. Kix1It.y W~ 22--7·99 REV. No./REPL. SDS GENERATED: DISClAIMER; MSDS futni~hC'd iDdepc:ndent of product 88k:, WhiI€: r..'õ:ry dfat h3a ~~ Jl1,).de to ~.jely des.cribc tbl=: product, 5o.mlt of tbe da~ arc obmined from ~~ beyond. our dmd !U~on. WI! o.I1J:1ot rom ao)' ¡~tL~ IJ..~ to iP; rc:lißbili~' or corupJctcn.c.99; tb.:rwe. Wet t:rJ3'j röly on It only :a mm's Jig)::. We bIn'c .made no £ffurt 10 œnqor 01' eoüœ31 deletetk~ ~ts of ~ product SilJ.cc Ù¡C œ1].tJDt ilJ"l'tciplltc or control the CCll)c!1ricn~ u.ndc1' v/hich thi&. ÎnfQ,lJ.'l).Jtiot1. :\od product IDI1Y be used. we maJcc no guarantee thai the þtcomc.iona we hav~ aUf!:$€s:ted will ~ OOtqu.dè for. liD. ìodividu:tls ¡lJ.d'O( situ:1tioD", It ia the obligation of eacb. u.s.a of th1~ ~r:OOu(1lò eorop}y ~ìt.~ tbc reqo.irancD.i1; of all '1pplicabk lawe rcg&ding 1J.B¢ and disposal of ÙÙ8 pt'Odue:t. A&:I.it:6Ö~ ~1it:1Ð. wi.I1 be ñuui.med upon ~ucst ta Q9siat the: nea; ho~'(;t', 00 WaJ:rnnty, eÌth.(;.1' ex:p~:W&i or. im¡;Jlicd, ))ot JjJb¡lity of;\Qy ,1JlU\lrt with rcspccr: to thí:¡: ptOdüd o.~ tQ the œt1 bcfciD ¡,,; m:tdc or incurred her~dcr\ 4/4 #4 ì Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: The application of ARCO Alaska, Inc. for an order authoriz- ing the underground disposal by injection of non-hazardous oil field waste fluids in the Beluga River Gas Field. The Alaska Oil and Gas Conservation Commission has been requested by letter from ARCO Alaska, Inc. dated February 6, 1987 to issue an order authorizing the disposal of non-hazardous liquid waste by inj ection into the Sterling Formation through Beluga River Unit Well BRWD-1 of the Beluga River Gas Field, Alaska. A person, who may be harmed if the reques ted order is issued, may file a written protest prior to March 10, 1987 with the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska 99501 and request a hearing on this matter. If the protest is filed timely 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 9:00 AM on March 26, 1987, in conformance with 20 MC 25.540. If a hearing is to be held, interested parties may confirm this by calling the Commission's office, (907) 279-1433, after March 10, 1987. If no such protest is timely filed, the Commission will consider the issuance ot the order without a hearing. lilt! W. W. Barnwell Commissioner Alaska Oil & Gas Conservation Commission Published February 23, 1987 STATE OF ALASKA ADVERTISING .ORDER --:---- 'i¡i F R o M Anchorage Daily News P. O. Box 149001 Anchorage, Alaska 99514-9001 T o p U B L I S H E R .Alaska Oil & Gas Conservation Conmission 3001 Porcupine Drive Anchorage, Alaska 99501 ADVERTISING ORDER NO. t ,I AO- 08-5584 AGENCY CONTACT Gal yn Evans DATE OF A.a. February 19, 1987 PHONE 279-1433 (907) DATES ADVERTISEMENT REQUIRED: February 23, 1987 SPECIAL INSTRUCTIONS: AFFIDAVIT OF PUBLICATION UNITED STATES OF AMERICA STATEOFØ~ ~~. 88 DIVISION. BEFORE ME, THE UNDERSIGNED, A NOTARY PUBLIC THIS DAY PERSONALLY APPEARED ~~ WHO, BEING FIRST DULY SWORN, ACCORDING TO LAW, SAYS THAT HE/SHE IS THE ~ +- OF ~ ~ PUBLISHED AT ~ IN SAID DIVISION ~ AND STATE OF ~ -AND THAT THE ADVERTISEMENT, OF WHICH THE ANNEXED IS A TRUE COPY, WAS PUBLISHED IN SAID PUBLICATION ON THE ~ DAY OF ..ø~ 19.&'2, AND THEREAFTER FOR CJ CONSECUTIVE DAYS, THE LAST PUBLICATION APPEARING ON THE ,ftt-1AY OF a~ 198"J , AND THAT THE RATE CHARGED THEREON IS NOT IN EXCESS OF THE RATE CH~ED PRIVATE INDIVIDUALS. ~~~ SUBSCRIBED AND SWORN TO BEFORE ME THIS~DAY OF }~,\~~~~ 19____ C2"""ç¡ ",,~\j À ~ ~",......;--,~<;:".\"'C''''__ NOTARY PUBLlè--FOR STATE OF ^V- 2:> MY COMMISSION EXPIRES -II,('.Qm:roissionEx~i-:-esJnly3J1990 02-901 (Rev. 6-85) PUBLISHER REMINDER- INVOICE MUST BE IN TRIPLICATE AND MUST REFERENCE THE ADVERTISING ORDER NUMBER. A CERTIFIED COpy OF THIS AFFIDAVIT OF PUBLICATION MUST BE SU,BMITTED WITH THE INVOICE. ATTACH PROOF OF PUBLICATION HERE. , ,.-. ,', '",.,','..' I N~tlc!t øf pUbllc~ea~.I~~,": STATE OF'~LÁSK~::,:,',,:t AI~.ka·:OIII:a"G~~I~,,;~!~~I"',' , " Co"servatlqn CO",,,,ISSI~«;t " Re:, The ,apPII~a'lon"~f~O Aalska, "I"C~ for an:()t'~~I:".~\!",~;· rlzh1g thê undergroundl!âjs~s~1 by, '"Iactlon of:,1 noh.h.~ål',ClC?ks 011 flied wasteflUlds,lnBel~ga Rlver.Gas Field. "',, .i i;¡ The Alaska on ~"d GIS con~f¡~ . vatlon Commission hallbtte" requested by letterfr:om AR(¡() Alaska, 'Inc. datedFèbl'uary::,~¡ 1987 to Issueanorl;lerIUthor:!z~ Ing the dlsPosa,1 .()f nôn-Hllzar.~: ous liquid waste, by' InJection, Into the Sterlln'g Fo!:,matlon through Beluga Rlver,U~lt W~I BRWD-l' of the Beluga, River Gas- Field, Alaska. . A person, who may be harmed If the requested order Is Issued, may file I wrltte" protest pr1ct to March 10, 1987 .wIth the Alaska 011 and' Gas Conserva- tIon Commission, 3001,Porcu- pine Drive, Anchorage,' Aleskå 99501 end, request a, heerlng on this matter . ,'If the protest... fIItdtlm8lyand ,alses I sub- stlntlll Ind mlterlll Issue cru- clll to the Commission's deter- inlnltlon, I "h.lrlng'on th~ mltter Will be held It ,the lbove Iddress It 9: DO AM 011 Mlrch 26, 1987, In confol'mlnce with 20AAC 250540. It 'I hearing Is to be held, Interested Þartles may confirm this by calnng -the Commissioner's office, (907:) 279-1œ, after March 10, 1987. It no such protest Is tl~"y flied, the Commission will con, sider the Issulnce of the order wnhout I hN'lng~ W.W. Barnwell Commissioner Alaska 011 & Gas, Conservation Commission ~ub:February 23, 1987 AO-oa-558.4 #3 /' ~ r~vv ~~~ #L C{ø' ~:Y ~ C74? "..... '. .,M" '''_'~'. ARca Alaska, Inc. ) Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 265 6369 ) ; ad/~ ,- John C. Havard Engineering Manager Cook Inlet/New Ventures February 6, 1987 Mr. C. V. Chatterton Alaska Oi I and Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Beluga River Unit Application for Underground Injection Swanson River Field Area Injection Order Application Dear Commissioner Chatterton: Attached are the referenced permit applications. Please note that we have requested authorization on Iy for injection through well B RWD-1 in the Beluga River Field. This is the same well previously authorized for injection by the U. S. EPA. The EPA also exempted the aquifer extending in a 1 mile radius around this well bore. An area injection order is requested for the Swanson River Field. The aquifer there has been exempted below 1700 ft: Your help and patience during appreciated. If you have any Hoffman at 265-1345. the application preparation questions, please contact is Rod Sincerely, Æ Havard JCH: RWH: bp 0047 Enclosure cc: B. Wondzell, AOGCC I~ECEIVED FEB - 9 1987 A'a~ka Oil & Gas Cons. Comml~slon Anchorage ARca Alaska, Inc. Is II Subsidiary 01 AtlantlcRlchlleldCompany I ! / I "IvQÎ,. : S ~ f- tA./~ (( .(c,v- ) ~~ 'i"- t ( e--c.~d. ~ u ( C. ) C~ cv"""'" :I t< u -1>R w- f);f / (;I .¡:.. ~ (" I ""- fa",.. ~ ~ : '"' (/ f w-..:t..c.;"'-$. ~~.'...,~ ') ,) ,¡' PUBLIC NOTICE and STATEMENT OF BASIS CHEVRON U.S.A., INCORPORATED Produced Water Disposal Well and Aquifer Exemption UIe PERMIT NUMBER: AK-2D0001-I CONTACTS: Harold Scott u. S. Environmental Protection Agency Region 10, MIS 409 1200 Sixth Avenue Seattle, Washington 98101 Telephone: (206) 442-1846 or (FTS) 399-1846 DESCRIPTION OF FACILITY AND BACKGROUND INFORMATION: On February 1, 1985, Chevron U.S.A., Incorporated, Anchorage, Alaska, made application for an underground injection control permit for injection of produced waste brines into the Lower Sterling Formation. The BRWD-1 well is located adjacent to the Cook Inlet in the NE quarter of Section 13, Township 13N, Range lOW in Alaska. A maximum of 5,000 barrels of waste brines (produced waters, drilling muds, and completion fluids) will be injected each day through the BRWD-1 well to a depth of 3,540 feet below ground level. The aquifers deeper than 3,400 feet for a one mile radius around the well bore have been exempted. Chevron has submitted all required information and data necessary for permit issuance in accordance with 40 CFR Parts 124, 144, 146 and 147, and a final permit and aquifer exemption were issued on September 16, 1985, and effective October 21, 1985, unless review is granted under 40 CFR 124.19. The permit~as issued for the operating life of the injection well. therefore, no reapplication will be necessary unless the permit is terminated for reasonable cause (40 CFR 144.39. 144.40. and 144.41). However, the permit will be reviewed every five years. This Statement of Basis gives the derivation of the site specific permit conditions and reasons for them. The general permit conditions for which the content is mandatory and not subject to site specific differences (based on 40 CFR Parts 144, 146, and 147>. are not included in the following discussion. fJkt . ð ~ ~ Vv-t'l t her /C( ( ~~ { t" c!'" tv v-I6\ 1 I~~S' ~ ~fu ~ ß~~P~r ~c:.fc~ ~~. ) ) CHEVRON U.S.A., INCORPORATED Underground Injection Control Permit No. AK-2D0001~I and Aquifer Exemption Response to Comments Received During the Public Notice and Public Hearings 1 . A statement was made that the proposed project does not appear to affect the area of Tyonek. EPA concurs. 2. Request was made to delete continuous recording requirements under Part I.A. of the permit because of the intermittent injection schedule and 40 CFR 146.23 does not require. The Agency has reviewed this request and agrees to delete the. requirement for continuous recording devices. Instruments will be required, however, to monitor the injection pressure, flow rate, cumulative volumes and annular pressure. These measurements are required to be recorded monthly. 3. Concern was expressed that the Statement of Basis regarding the future use of ground waters in the area was not based on good judgement considering the proximity to Anchorage and that the Mat-Su Borough may, in the long-term future, sell 1,700 acres in the area for development. EPA agrees that it is difficult to predict the future growth and ground water needs. However, considering the depth of the injection zone and availability of surface and shallow ground water there should be adequate drinking water sources for future users. A correction to the Statement of Basis seems warranted since the community of Tyonek uses a lake (not ground water) for their drinking water. The Agency is unaware of any demographic data demonstrating the use of the exempted aquifer during the foreseeable future. 4. Concern that the area of review was limited to 1/4 of mile radius around the well instead of one mile. Under 40 CFR 146.6(b) the EPA accepts the 1/4 mile area of review. Therefore, the corrective action data Chevron provided for wells within 1/4 mile of the injection well in the application are still valid. 5. Concern was expressed that more information regarding the toxicity of drilling muds and the accidental contamination of the injection fluid needs to be determined. " ) :J 2 The permit is written to allow only Class II fluids to be injected. The operator is responsible for maintaining the integrity of the fluids being injected and injection of other than Class II fluids would be non-compliance and subject to enforcement actions. Under 40 CFR 261.4 drilling muds, produced waters and other wastes associated with the exploration, development, or production of crude oil or natural gas are not hazardous wastes. 6. Concern was expressed whether the application was critically reviewed by a hydrogeologist, seismologist, and oil and gas expert. ,A hydrogeologist and civil engineer reviewed the application. 7. Concern was expressed for the verification of where the wastes actually go since expert predictions are often wrong. The calculations which show the injection fluids will remain in the injection zone are based on current technical knowledge regarding the flow of fluids in porous media. Monitoring wells would provide limited verification at the expense of breaching the integrity of confining zones protecting underground sources of drinking water. EPA Changes to Permit The tubing and packer will be required to a depth of 3540 feet since the confining zone exists from 3510 and 3540 feet. The modifications to Part I.A.l. and 2. are commensurate with good engineering design and operation and standard industry practice. For mechanical integrity under 40 CFR 146.8 the following is required: 1. Pressure test the casing-tubing annulus to 1,000 psia for thirty minutes with a pressure loss not to exceed 100 psia to demonstrate there is no significant leak in the casing, tubing or packer; and 2. Submittal of adequate cementing records to demonstrate there is no significant fluid movement through vertical channels adjacent to the well bore. U.5. JNVIRONMENTAL PROTECTION At REGION 10 1200 SIXTH AVENUE SEATTLE, WASHINGTON 98101 ~Cy ~\"(ED sr"'l: ,,~ ~Qo ",' ~ ~ ~ -. % ¡¡œ~ o. "{ '\ ~ ~~ '\~ ~( PROi~v MAY 2 2 1986 REPLY TO ATTN OF: ~1/ S 409 Carl H. Harmon, Manager Environmental Services Chugach Electric Association, Inc. 5601 Minnesota Drive Anchorage, Alaska 99519-0300 RE: Modification of Class II Permit No. AK-2D0001-I, Aquifer Exemption Dear Mr. Harmon: This is in response to your April 21, 1986, letter to the Administrator of the U.S. Environmental Protection Agency and the concern for Beluga's water source. The penmit was modified on May 5, 1986, and differed from the proposed modification by limiting the aquifer exemption to below 3,030 feet (for a one mile radius around the well bore) and injection to below 3,060 feet instead of 1,860 feet and 2,028 feet, respectively. The permit is written to limit the extent of migration of the injected fluid to the exempted aquifer and does not allow migration into an underground source of drinking water. We believe these permit conditions will provide the assurance that your underground source of drinking water will not be contaminated from operation of this injection well. A copy of the permit, Statement of Basis and Response to Comments, are enclosed. If you need additional information, please contact Harold Scott of my staff at (206) 442-1846. Si ncerely, )tL~~1 Robert S. Burd Director, Water Division Enclosure cc: w/copy of incoming letter C. V. Chatterton Alaska Oil and Gas Conservation Commission RE'CE\VED MAY 2 7 1986 Alaska Oil & Gas Cons, Commlss\on Þ,nrll,-,r:Joe :to , } .. ) ~ ~ ELECTRIC ASSOCIATION. INC. ~ ~ ErF"\!EO ~ . 5601 MINNESOTA DRIVE-P.O. :BOX 19~0 - ANCHORAGE, ALASK'~ 99519-0300-PHONE 907-563-7494 I \ t'\Q~;' TELEX: CHUGACH AHG v ;) \~ ": (090) 25 265 April 21, 1986 0 M~'''' ----..-'-- "-.-.. .'~ rELECOPIEA' , ;907 ·564·0632 ., Administrator, MIS A-lOa , . EPI\-OWPB u. S. Environmental Protection Agency.. ' o' j 401 M Street, S.W. Washington, D.C. 20460 l£fil'£I , .-"'" Dear Sir or Madam: APR 2 5 1986 OFFICE OF REGIONAL ADMiNiStlAtOI ~ t. SUBJECT: Proposed modification of C~ass II Permit No. AD-2D0001-I, Aquifer exemption Under 40 CFR 124.19, Chugach Electric Association, Inc. (Chugach) has the following comments regarding the Chevron u. S. A., Inc.. (Chevron) permit application requesting a modification to Permit No. AD-2D0001-I, to exempt additional portions of the underground sources of drinking water ~n the. Beluga River field, and to change the point of inject~on and maximum injection pressure. Chugach wishes to make the permitting agency, the u.S. Environ- mental Protection Agency (EPA) aware of Chugach's Certificate of Appropriation of Water No. 743, granted May 4, 1971, and recorded in volume VI, page 743, Alaska Division of Lands 44664 Anchorage Recorders Office, General Index book (copy attached). This water is essential for Chugach to operate its Beluga Station, located within 4 1/2 miles of Chevron's injection site. Chugach is Alaska's largest electric utility, supplying power to more than half the state's population. Beluga Station is the largest electric generating facility in the state. Power from this facility serves consumers throughout Southcentral Alaska. Chugach is aware that Chevron's proposed injection will not have an immediate effect of ground water, but our concern is for the future. Chugach asks that assurance be given that Beluga's water source will not be aFrectëd b~i·-thisíñ.Jectfóri. '-.. - Should additional information be required, please call me at (907) 564-0739 or write me at the above address. Sincerely, " r' I: I :' J ~ \,' /: >1 f~J!L L·· v 1-\.;é;v-- '-,,'J.,'~ Carl H. Harmon Manager, Environmental Services ¡J f "\."\"'" !:;ÖO CHH/cb cc: Jim Topolski Larry Markley ~ EPA, Seattle Office RECEiVED MAY 2 7 1986 ~......~" ~ Alaska Center for ~ )e Environment Suite lA 411 West 4th Ave. Anchorage, Alaska 99501 274-3621 ) March 24, 1986 '....'..'."......'..".'..(}¡y."" ¡¡COh!,:¡','" '!i~:':',~'J! ,'" .'!----·-·-I..···~---: "" \,,,., .". . !,ll . ,I.. -- (Cr---\'{ ~'I , ' , I =rll ~' , I ,--",,!~ I i' '.,.""....", :"1.\2 !Wr',¡(:~!'\,' ,~I ! ~:)L<\\T ,:, (" ;:;:f:h1 !,:..::"\..:" " (.1 '!j/? ¡~ !.t~l~.:l~'2l~:'Q-j 6/: I Harold Scott MIs 409 EPA Region 10 1200 Sixth Avenue Seattle, WA 98101 RE: modification to class II permit No. AK-2D0001-I Dear' t1r. Scot t : We are opposed to the proposed permit modification and aquifer exemption. We prefer that the aquifer exemption be 1 imited to the area below approximately 3,050 feet and that injection occur between 3,050 and 3,500 feet. Chevron's Beluga River Field waste disposal well provides a clear example of how the Conservation of petroleum can confl iet with the protection of groundwater. The history of the regulatory action concerning the well also illustrate~. the obviolJs diff'er'encE' in prior'itie~, beil'leen EPA and tht'; Alaska Oil and Gas Conservation Commission CAOGCC). Allow me to briefl; recount the sequence of events, of which you are no doubt aware. In September, 1985, EPA issued a permit to Chevron, U.S.A., allowing them to inject 1 iquid wastes below 3,400 feet. AOGCC later denied Chevron a similar request, on the grounds that injection in the lower zones of the Sterling formation might jeopardize future recovery of gas. The low concentration ,of gas in these zones does not make reCovery economically feasible at this time. At AOGCC's suggestion, Chevron has now appl ied to EPA for a modification to its permit and aquifer exemption, allowing them {o pollute the aquifers from 1,860 to 3,400. In the Sterling formation of the Beluga Ri,,'er Field, ~oJater' qualit~/ diminishes as one moves to lower strata, while gas concentration decreases as one moves to higher formations. One cannot maximize the protection and minimize the waste of water, while also maximizing the protection and minimizing the waste of gas. It is undeniable that injecting at lower depths provides a greater margin of safety for the very valuable aquifers above the first major unconformity at about 1,860 feet. It is also undeniable that injecting at higher depths in the Sterling formation directly contaminates water of better qual ity. Parallel considerations apply in reverse from the standpoint of conserving natural gas. Greater safety and conservation of gas is provided by injecting higher above the unconformity, which 1 ies at about 3,521 ffet. ') ) , , Page 2 Harold Scot.t 3-24-86 One must. balance bet.ween conflict.ing goals, but. give priorit.y to the Conservation of water. For this reason, we bel ieve it is reasonable to confine the waste to the section between 3,050 and 3,500 feet. This pr"ovides Chevron with as much ar·ea in l.\lhich to inject waste as they proposed to use in applying for their original permit, i.e., all the aquifer exemption they need. We view the more extensive exemption as an unnecessary waste, and endangerment, of potentially useful water. The following considerations provide reasons for not exempting the aquifers up to 1,860 feet. 1) Insufficient da~a exists on the Qual ity of water near the top of the a Qui fer s p r' 0 p 0 sed for e >: e rn p t ion. E 1 e c i: r i c 1 () g s fro rn the n e i 9 h b () r' i n 9 I~I ell , 8RU 212-18 I suggest cloride concentrations of about 1,200 ppm at about 2,028 feet. Conceivably, water at 1,860 could be of even better Qual ity. It would almost certainly meet water qual ity standards for aQuacultural purposes (1,500 ppm TDS, under 18 AAC 70.020), and might meet water Quality standards for agricultural purposes (1,000 ppm TDS, under 18 AAC 70.020). Of course, with simple methods of treatment, this water could be purified of its chloride contents to meet the drinking water standards in that respect (500 ppm TDS, under 18 AAC 70.020). These methods are currently somewhat expensive to operate, but it is always possible that future technology would reduce the costs. It is worth noting the great difference in water qual ity between the water which EPA would allow Chevron to contaminate (less than 1,200 ppm chlorides) and water for which no aquifer exemption is required (above 10,000 ppm TOS) under the Safe Drinking Water Act. The Canadian standard is even more conservative at (we bel ieve) 20,000 ppm TOS. 2) The site of the injection well is less than 50 miles from Anchorage, residence for about half of the state's population. A Susitna Area Plan suggests that 1,700 acres of the 8,900 acres owned by the Mat-Su Borough could be sold for settlement. Native corporation land could also be sold for settlement. Population growth and land use is difficult to predict. part.icularly over such long periods as would mat.ch the 1 ife of t.hese wast.es underground. Faced with t.hese uncertainties, one should be especially conservative in prot.ect.ing ground wat.er suppl ies. 3) The toxicity of t.he waste has never been directly t.ested. While the expect.ed additives to the drilling muds are 1 isted in the permit, it. is not unCommon to find contaminants in drill ing muds which were not 3 n t. i c:::. i ~" a 1. '2 d . ;J (. cas ion all ~, , t ~. '2 L~ 2 S t e \ ~'r c- ¿..J ( €' d i;1 L~ a S ;-1 i ~-I 9 d C.I n r i rJ~: fin d -: h dn s ¿ ~ v E:-~, i n r E:- s E: r ve ¡:: i t.~; f 0 í' d r ill i n ç; mud s. Ai. t i m'2:::, s ç, E:- (. ¡ ale h e rill C a 1 ~: are added to thE:- mud system to solve particular problems encountered while drill ing. It is also worth noting that the annulus fluid planned t'or the disposal l'Jell will contain a corrosion inhibitor, a biocide, and diesel oil, all of L\lhich are toxic. ) Page 3 Harold Scott 3-24-86 EPA has replied to our Concerns by stating that the permit prohibits the injection of hazardous waste. This seems irrelevant to the question of actual toxicity, expecially given the blanket exemption to drill ing muds under section 3001 of RCRA. We do not bel ieve the permit application contains enough information to determine the toxicity of fluids which are finally injected down hole. We recommend that EPA require toxicity monitoring by bioassay and inorganic analysis. EPA should also limit injection to those muds whose only additives are 1 isted in the permit. 4) The permit appl ication fails to prove that no upward migration of the waste will occur during or after injection. There is a neighboring well ~ in j ec t i on we 11, liJh i c h m i g h t higher formations. BRU 212-18, 300 feet from the proposed provide vertical passage of the waste to The unconformity at 1,860 feet is composed of clay beds, permeability, fractul~e preSSlJr'e, and later'al extent have not specified in the permit appl ication. Lower strata provide several beds which can be correlated aCross well logs in the Beluga River region. lhlhose beerl shale Field A word on fracture pressure is in order. We are opposed to destructive testing, such as is typically used in measuring fracture pressure, when it is unnecessary. In this instance, it is not necessary because there is ample space for injection below 3,050 feet. The argument that the difference in sal ini~y above and below the unconformity at 1,860 feet attests to the confining capacity of that zone is as unconvincing as the argument that the OCCurrence of gas in the Sterling formation demonstrates the capacity of the unconformity to contain the waste. These zones have never experienced the injection of large volumes of waste at high pressure. The effect of injection could alter the natural confining properties of these beds. We appreciate this opportunity to comment. SinCerelY'A ~ a~L ~~v" Cl iff Landesman, Hazardous Waste Special ist ~fA ~~ Ursula Barril, Exesutive Director cc: Geral d Opatz, EPA JChat Chatterton, AOGCC Jul ie Howe, ADEC Bob Adler, Trustees for Alaska Chevron == <~ ) ) Chevron U.S.A. Inc. P.O. Box 107839, Anchorage, AK 99510 . Phone (907) 786-6600 October 18, 1985 J.L. Weaver Area Operations Superintenrlent Prcduc:ian Department Certified Mail Return Receipt Requested No. P460 104 301 UIC Permit (AK-2DOOI-O Modification Class ß Injection Well Beluga River Field - . - United States Environmental Protection Agency Region 10 1200 Sixth Avenue Seattle, Washington 98101 Attention: Mr. Harold M. Scott Gentlemen: Encl9sed find modified attachments (A, E, G, and S) to Chevron's DIC Permit Application dated February 1, 1985, which incorporates those changes needed to support, an aquifer exemption request to approximately 2,028' as discussed by the Alaska Oil and Gas Conservation Commission. Please call Mr. Norm Stone if you require any additional technical information, or Mr. J.D. Arlington if you have questions concerning the permit modification, both of this office (907)786-6600. Very truly yours, ¿ft. ,"I /ADlJJU~ J. L. Weaver '--) J CDC:mw Enclosures Modified Attachments A, E, G, & S Chevron Drawings 453194 and 401033-1 cc: C.V. Chatterton, Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive, Anchorage, AK 99501 :~, j.~ C t: . ~'.. ..., _I /~, ' ~. { .~. ;.~ ....:. i r'r'''; [: L: ,I ..' ,. ~c ;'~n\'~A.~.~ ,il 1v I.~-· ~ . :::~~~ ~, ,,1 f1 ~ :- .-1';'~~J . F f·l.! r; ;\ ~; S"~ ~_. ". Þi';~:?r'-r -fE,CH\- . C" ",.' ", "r '11' ¡:~ l''''.I_,\ ~,- ,;:) I !'\I "," J il.l\ i,':F'~~~~i~~:IL~:: J ) Attachment A AREA OF REVIBW Chevron U.S.A. proposes to drill a vertical disposal well, BRWD-1, to a bottomhole location approximately 300' north of BRU 212-18. The disposal well is scheduled to reach total depth (TD) within the Pliocene age Sterling Formation at 4,010' measured depth (MD) (-3918, vertical subsea, vss) as measured from Kelly bushing. Initial waste water disposal will be into Sterling Zones A, B, and C which are productive updip (south) of the proposed location. Sterling Zones A, B, and Care interpreted to be 'water productive' at the BRWD-1 location by electric log analysis of well BRU 212-18. The Sterling Formation is currently exempted at and below a depth of 3,400' MD (-3287' vss), for a one mile radius around the well bore by permit number AK-2D001-I. Chevron proposes to raise the aquifer exemption to a depth equivalent with 2,028' MD (-1931 vss) in well BRU 212-18, a depth coincident with the top of the "1st Disposal Sand" as depicted on Drawing #401033-1, enclosed for your review. The 1st disposal sand is easily identified on a field-wide basis. Hereafter, please refer to those sand aquifers present over field boundaries and correlative with the interval measured from 2,028' MD to 3,521' MD in BRU 212-18 as "subject 'aquifers." The area of review is proposed to be a circle around the disposal well having a fixed radius of one mile. As stated in Chevron's original permit application dated February 1, 1985, the amount of water forecast for injection over a 25 year well life yields a displacement radius of 722' if injected in equal proportions into Sterling Zones A, B, and C. Accordingly, any injection into subject aquifers would have the added benefit of reducing the displacement radius and containing the waste water within a smaller distance of the wellbore. Chevron does not propose a change in volume of wa ter to be injected. } ') Attachment E NAMES AND DEPTHS OF USDW's . There is little data concerning specific USDW's of the Beluga River Field area, but the 1980 USGS report on Water Resources of the Cook Inlet Basin, Alaska, by G.W. Freethey and D.R. Scully, indicates that fresh water-bearing rocks that underlie the area are mostly of proglacial lake and associated fluvial origins, that these unconsolidated sediments range in thickness from 1,000' to 1,500' across the area of the field and that the fresh-water/salt-water interface is more than 2,000' below sea level. These sediments are the youngest rocks of the Sterling formation, a unit which is Pliocene through Quaternary in age. The unconsolidated Quaternary rocks are described as being heterogeneous mixtures of silt, sand, anp gravel, interlayered with more homogeneous deposits of silt and clay (lake deposition) and sand and gravel (fluvial deposition). The 1980 USGS hydrologic report refers to the Beluga River Field area as having high potential groundwater yield because it includes large alluvial and outwash valleys containing highly permeable unconfined aquifers recharged from surface sources. It notes that large alluvial aquifers may also be confined beneath proglacial sediments. There are a total of 15 water wells completed in shallow aquifers of the Beluga River Field area (see Figure B-2) of which only 3 are used for drinking water. Most wells were drilled to depths of 100' to 200' but a. few are shallower and 3 are deeper, with the deepest penetration being 515'. Data from these shallow wells in the field area do not include determinations for total dissolved solids but 2 samples from springs in the Upper Capps Creek and Upper Chuitna River areas contained less than 50 mg/l TDS and 2 others from a shallow well in TI2N/Rll W contained 88 and 65 mg/l TDS. (See Hydrologic Reconnaissance of the Beluga, Peters Creek, and Healy Coal Areas, Alaska, USGS Water Resources Investigations 81-56, page 41). The dissolved iron concentrations in this well exceed EPA recommended domestic water supply standards and there are indications that in some wells in the field area, and immediately south of the field, the waters sampled sometimes exceed the standards for arsenic, iron, and manganese (see attached water analyses reports). Below the Qua ternary near surface aquifers in Beluga River Field area, electric logs and sample data show a stratigraphic section which is interpreted to be dominantly glacial sediments to depths of 1,700' - 1,900' (most electric logs start below 300'), and below that a series of interbedded sands and clays of Pliocene age which include the gas productive Sterling A, B, and C Zones. These Sterling Zones lie with slight disconformity on rocks of the Beluga formation of Miocene age. Water quality of the Zone proposed for injection waste water disposal (Sterling and below) is not well documented, but total dissolved solids in the. lowest Sterling sands appear to be about" 2,600 to 2,700 TDS from the few reliable samples available. The validity of this determination is confirmed to some extent by similar results obtained from a few samples of the deeper Beluga E and F Zone water (see attached water analyses reports Figures E-l through E-14). , ,,""' ~.--... ",.. " ~... ~ '., k_~~ ~~,~:..; I µ,~::lSk3 ':::1 t .,.......; ) ) Attachment G . . GEOLOGIC DATA ON INJECTION &: CONFINING ZONES . I· r" Initially, injection will be into partially depleted gas reservoirs of Sterling Zones A, B, and C. However, the Alaska Oil and Gas Conservation Commission (AOGCC), in a meeting held in their offices on August 6, 1985, recommended that Chevron apply for aquifer exemption up to the top of the Sterling Formation, an unconformity, and investigate the possibility of injection into a series of gas contaminated aquifers correlative with interval 3,291' - 3,521' in BRU 212-18. AOGCC prefers that no injection take place in Sterling Zone A, due to the potential damage of a currently producing updip well, BR U 224-23. While Chevron believes that downdip injection into the 'water leg' of the producing Sterling reservoirs could only remotely lead to a future production problem (possible watering out of updip producer BR U 224-23), we have taken AOGCC's suggestion under advisement and find it to be prudent procedure. Injection into a correlative series of Sterling aquifers is not without precedent in the Cook Inlet area. Union Oil Co. at Kenai Gas Field and Chevron U.S.A. at Swanson River Field currently inject waste waters into a similar stratigraphic section. Both operations have been performed successfully for a number of years. Over the Beluga Field area, the top of the Sterling Formation varies in depth from about 1,400' to 1,900' vss. Thickness from the top of the Sterling Formation to the top of Sterling Zone A is approximately 1,600', and thus the base of the subject aquifer zo~e varies in depth between 3,000' and 3,500'. The subject aquifers have porosities in excess of 30%. Individual sand units are commonly 10' to 70' in thickness and are interbedded with clay, silt, and coal beds throughout the formation. Gas at Beluga River Field is believed to be sourced from the many coal beds present throughout the Beluga and Sterling Formations. Geologically, dry gas (analogous to gas at Beluga River Field, 99.8% methane) is commonly associated with coal seams. The Sterling productive Zones A, B, and C have been contaminated by this coal sourced gas to a concentration capable of sustained. com mercial production. The remaining Sterling section (subject aquifers) have also been contaminated by gas from these numerous coal seams, rendering them undesirable sources of water for domestic consumption. Mudlogs from Beluga River Field show that concentrations of dry gas hydrocarbons from chromatograph readings are commonly in the 5,000 to 20,000 ppm range, and up to 200,000 ppm in BR U 241-34. Electric log analysis suggests that waters contained in subject aquifers contain 1,200 - 3,000 ppm chloride. While this chloride concentration places these aquifers into the USDW category by EP A definition, they exceed the approved chloride concentration for domestic consumption (less than 500 ppm CI-) and would require expensive treatment for future domestic use. Petrographically, the subject aquifers are fine to coarse grained, sub-angular to sub-round, with poor to moderate sorting. Microscopic analysis shows them to contain more than 50% rock fragments which are predominantly of volcanic origin. ) ) Other grains consist of quartz, chert, feldspar, and minor amounts of silt. The aquifers contain little discernible detrital or authigenic matrix. Confinement. of waste fluids will be achieved by the many clay beds in the Sterling Formation. The clay beds range in thickness from l' to 40' and are light to dark gray in color and firm to hard. At least 6 separate gas-water contacts, defined by wells on the northeast plunge, testify to the impermeable nature of the clay beds and their abili ty to seal. There have been no fracture pressure tests made of these clay beds, but the fact that there is a gas accumulation testifies to effective separation of the shallow aquifers from deeper zones. Perhaps the best confining zone at Beluga River Field is the unconformable surface which separates the glacial sediments from the Sterling Formation, depicted as a wiggly line on Drawing 401033-1. The Sterling Formation is unconformably overlain by glacial sediments of recent age. As shown on Drawing 401033-1, resistivities within the glacial aquifers are commonly 50+ ohm-meters. Mostly, these high resistivities reflect low chloride concentrations within the glacial zone's confined waters (less than 500 ppm). Sterling aquifer resistivities commonly range from 5 - 25 ohm-meters, representing more saline waters (1,200 - 3,000 ppm Cl-). Sterling Formation resistivities are lower because saline water is more conductive to electrical current than is fresh water. On a field-wide basis, the Sterling-Glacial unconformity is an easily recognizable anomaly from electric logs, and the field-wide zonation of fresh-saline waters testifies to the sealing capability of the unconformity. Finally, a structure contour map drawn on the unconformity, equivalent points from every well in Beluga River Field, shows that the anticline (an inverted bowl- like fold of the rocks at Beluga Field cpable of trapping hydrocarbons and waste water) is still present at a depth of 1,500'. Any fluid injected into the closed portion of the anticline (BRWD-1 is located within this closed portion) will not be sUbjected to regional underground flow processes and will stay in an area proximal to the wellbore. ) ) At~a~hment S AQUIFER EXEMPTION Exemption is requested for aquifers at and below an equivalent point to Sterling Formation depth 2,028' MD as measured from Kelly bushing in BRU 212-18. This depth is 168' below the Sterling-Glacial unconformity and is separated from fresh water glacial aquifers by three + clay bed confining zones and by the unconform- able surface itself. By UIC permit number AK-2D001-I, aquifers below 3400' MD are already exempt. By definition of 40 CFR Section 144.3, an aquifer can be a USDW if it contains a sufficient quantity of groundwater to supply a public water system and contains fewer than 10,000 mg/l total dissolved solids. The subject aquifers of the proposed injection zone are potential USDWs by this definition, but Chevron here proposes that these subject aquifers be exempted on the following grounds: 1. They are not currently sources of drinking water. 2. They cannot now, and will not in the future, serve as sources of drinking wa ter because: a) they are situated at depths (2,000' - 3,500'+/-) which make recovery of water for drinking purposes economically impractical, and b) I. the subject aquifers are hydrocarbon contaminated. Sterling Zones A, B, and C have produced some 161 BCF of gas as of January 1, 1984, and chromotograph readings indicate hydrocar- bon contamination of the remaining Sterling aquifers. U. S. E N V lJNMENTAL PROTECTION REGION X hENCY ~ëOMM ,()l .-..-...-., ....- 1.. ' _9q.~IA'~ ~:. COMM :1..,1'<\: " .,.. ìd\ F~E~ EN~=m' , c:.~ r_'1 "~-: I, (" ~'I ,--"nL._'I1_~ . .~ :8R E~G (I æ :ENG · 'SI=tGT~-ÖL '~ -ë"';:' -. ~I;';' t1' ,¡ ,,::>R G[:,JL 't , ' -:;.'¡ ..,.,1\ ..:- ~ . -. ~,; E 1\ G r\.),':' T 1: I :'r::,{:,-"Ì\ (> ~~r'·-'I'----:¡ L., t~] I,..Jt 1'"'\.'1....>..,..... ',J '0T"'j,;1"~'-i-':-C¡J ·I--,~ .''';:) J"\ i 1= n 1 fST A T TEGH,I]i' ; T=!LE·TJl C'---¡i" ~-"""""~""""""""'.~-"IiIII..................,_." 'I _\\"Ç\:,O sr-4 't:. ~" ~Ú' i ft ~ ~ ~ -z. :¡¡æ'.JJ o ' <.? ~ ; «'1-/:: "'~ -1( PRO"{~v 1200 SIXTH AVENUE SEATTLE, WASHINGTON 98101 SEP 1 G 1985 REPLY TO MIS 409 ATTN OF: J. L. Weaver Area Operations Superintendent Chevron U.S.A., Incorporated P.O. Box 107839 Anchorage, Alaska 99510 RE: Beluga River Field Class II Final Permit and Aquifer Exemption Dear Mr. Weaver: Enclosed is the Final Permit (AK-2D0001-I) for the Beluga River Field. The permit authorizes the aquifer exemption and construction of the Class II well. Also, enclosed are copies of the Statement of Basis and the Response to Comments. The permit remains in effect until either the State of Alaska is granted primary enforcement responsibility for the UIC program or the permit has been otherwise modified, revoked and reissued, or terminated in accordance with 40 CFR 144.39-144.41. Si ncere1y , ~F ~obert s. ~ ~~ Director, Water Division Enclosure cc: C. V. Chatterton, Alaska Oil and Gas Conservation Commission Rr.CE\\fED ~t-'P 2. 0 1961J "". ~~ ... ) m\Ss\Ofl ""ons con.1 . 0'\ & Gas v .' A\aSKa \ þ.\ìc\ìOíage <:"::~:=ïï=: i ~ \:-' I, j i: <'\ !! I L~ \\_)) i I ; ;-, --.~_,,/ \...J. ,___ c:--:= ¡ I i I '~ r-:= \ \ ' , ,¡ . 1--- ; ; /T, :3~';: : I j i.J \ "\\ : 1 IJ'\ \ n \ ~ t-=--= L \.J \.:::~./ ¡-o / I~ \ /i~\ u u BILL SHEFFIELD, GOVERNOR 27~~ (J!l ----......,' .. --K COMM I " --.,. ' , "'.--':7;' COMM 1',i«>' , ¡' 'RES ENd l.D; , ~r-1~NÖ_-=!4f. ~~.',_"..",.E.}~, G I H. ENG !PI sï=fëfEOL Jì SFf(.;tÖL J! -------~'- ".', ,- ~ ENG ASST I<1/', :~l~~~~~~;~:!~ !E~~~~g~11j FILE: '\ .1_-... , ----. l.~.,... .--J u DEPT. OF ENVIRONMENTAL CONSERVATION SOUTHCENTRAL REGIONAL OFFICE 437 E STREET, SUITE 200 ANCHORAGE, AK 99501 CERTIFIED MAIL RETURN RECEIPT REQUESTED September 24, 1985 Mr. J.L. Weaver Chevron U.S.A., Inc. P.O. Box 107839 Anchorage, Alaska 99510 Dear Mr. Weaver: RE: Waste Disposal Permit Application ADEC File No. 8523-DB017 The Department of Environmental Conservation has reviewed your Waste 13, i~ Disposal Permit Application for the injection of produced water and drilling and completion fluids. Based on our evaluation, Permit No. 8523-DB017 has been hereby granted. Please note the conditions in Appendices A and B. This permit expires January 1, 1990 and must be renewed by that date for continued operation of the facility. This permit is only for the injection of the wastewater and does not authorize the disposal of solid waste. The disposal of solid waste by a Departmental approved method, needs to be resolved immediately in order to begin operations. Department of Environmental Conservation regulations provide that any person who disagrees with any portion of this decision, may request an adjudicatory hearing in accordance with 18 AAC 15.200-310. The request should be mailed to the Commissioner of the Alaska Department of Environ- mental Conservation, Pouch 0, Juneau, Alaska 99811, or delivered to his office at 3220 Hospital Drive, Juneau. Failure to submit a hearing request within thirty (30) days of receipt of this letter shall con- stitute a waiver of that person's right to judicial review of this decision. Sincerely, B!Jt1<~:f[ay Regional Supervisor RECEIVED BHL :JH: lmc ENCLOSURES cc: (w/ENCLOSURES) Kenai District Office, ADEC Valerie Payne, EPA, Anchorage Jerry Opatz, EPA, Seattle ~~hat Chatterton, AOGCC Alaska Center for the Environment SEP 2 7 1985 , I' Alaska 011 & Gas Cons. Commission Anchorage ) STATE OF ALASKA DEPARTMENT OF ENVIRONMENTAL CONSERVATION SOUTHCENTRAL REGIONAL OFFICE 437 "E" Street, Suite 200 ANCHORAGE, ALASKA 99501 J.L. Weaver Chevron U.S.A., Inc. P.O. Box 107839 Anchorage, Alaska 99510 PERMIT NO. 8532-DB017 DATE ISSUED: September 23, 1985 This permit is issued to Chevron U.S.A., Inc., for the injection of a maximum of 42,000 gall day of produced water and drilling and completion fluids to a depth of 3540 feet or greater below the surface of the ground. This activity will be located atBRWD-1, Beluga River Field, T13N, R10W , Sec. 13 , S.M. This permit is subject to the conditions contained in Appendices A and B, which are incorporated herein by reference. This permi t is issued under provisions of Alaska Statutes 46.03, the Alaska Administrative Code as amended or revised, and other applicable State laws and regulations. This permit is effective on issuance and expires January 1, 1990, unless super seeded before that time by a state certified EPA perm! t. It may be terminated or modified in accordance with AS 46.03.120. 411f~!:Xf2ý Regional Supervisor RECEIVED SEP 2 7 1985 A\aska Oil & Gas Cons. Commission Anchortlq8 ) ) PERMIT NO. 8523-DB017 Page 1 of 4 APPENDIX A SPECIFIC CONDITIONS A. Application Compliance The Permittee shall comply with all parts of their permit applica- tion dated July 25, 1985, except as specified otherwise in this permit. B. Site Operation 1. The discharge shall be to a depth of at least 3540 feet below the surface of the ground, unless authorized by a permit modification issued by the Regional Supervisor of the Alaska Department of Environmental Conservation. 2. The waste must be contained within a 722 foot horizontal radius from the injection point. 3. The discharge shall not exceed 1,000 barrels per day (42,000 gal/day) and 365,000 barrels per year (15.33 million gal/year). 4. The maximum pressure at the surface is limi ted to 700 psi. 5. The discharge shall be limited to those wastes directly related to drilling activities. This includes produced water, drilling and completion fluids and dilution water. Other waste, including equipment washwater is not authorized to be discharged. 6. The injection of hazardous waste is prohibited. Hazardous wastes are defined according to Title 40, Part 251 of the Code of Federal Regulations. 7 . Should the montoring required in Section C of this permit indicate leaks in the casing, or the waste entering areas other than what is authorized by this permi t, the permittee shall cease injection immediately and take the necessary remedial steps to stop this violation. Injection will not begin until adequate repairs are complete and the Department authorizes start-up in writing. 8. The waste shall be collected and injected without loss or spillage onto the surface of the ground. 9. Permi ttee shall comply wi th the U. I. C. permi t issued by the u.S. Environmental Protection Agency. ) ) PERMIT NO. 8523-DB017 Page 2 of 4 C. Monitoring and Reporting 1. Hazardous Wastes The Permi ttee shall test all materials that are suspected of being hazardous and exclude them from injection under Sec. B.5. 2. Produced Water The permittee shall conduct a representative chemical analysis of produced water to be injected. The following chemical analysis are required: Sodium Potassium Magnesium Iron Calcium Chloride Carbonate Bicarbonate pH Sulfate Total Dssolved Solids This analysis shall be conducted annually and the results shall be submitted to the Department's Southcentral Regional Office and the Kenai District Office by January 31 of each year during the term of this permit. Following a review of two of these reports, the Department may modify this requirement. 3. Drilling Fluids The Permittee shall conduct a composite, representative chemical analysis of the drilling fluids to be injected from each new well and workover. The following chemical analysis are required: Sodium Potassium Magnesium Iron Calcium Chloride Carbonate Bicarbonate pH Sulfate Total Dissolved Solids Lead Arsenic Barium Cadmium Chromium Cyanide Nitrate This analysis shall be submitted to the Department's Southcentral Regional Office and the Kenai District Office within 30 days of sampling during the term of this permit. Following a review of two of these reports, the Department may modify this requirement. 4. The analysis required in Sec. 1., 2. and 3., shall be performed in accordance with Standard Mehtods for the Examination of Water and Wastewater. (American Public Health Assoc.) '; PERMIT NO. 8523-DB017 Page 3 of 4 5. Injection Log The Permittee shall maintain a log which will contain the date of- receipt and source of waste received, volume from each source, comp- osition of the waste, type of monitoring performed and the results. This log shall also include the dates of injection, the level of injection, surface pressures at the beginning and end of each injec- tion activity or daily, which ever occurs first, maintenance activi- ties, and any unusual complications. A copy of this log will be submitted to the Department's Southcentral Regional Office and the Kenai District Office on an annual basis. The log shall be submitted by January 31 of each year during the term of this permit. The log must be available for inspeciton at the site. 6. Well Integrity The integrity of the well must be tested upon completion of the well. A temperature or noise log may be used to satisfy this requirement. The results shall be submitted to the Southcentral Regional Office and the Kenai District Office within 15 days of completing the test. 7. Injection Level Any changes in injection levels other than as authorized in this permit, requires the written approval in the form of a permit modification from the Southcentral Regional Supervisor. 8. Noncompliance Notification If for any reason the Permittee does not comply with or will be unable to comply with any limitation specified in this appendix, the Permittee shall report the noncompliance to the Kenai District Office within 24 hours, by telephone, telegraph, or in the absence of both, by mail. This notification does not relieve the permittee of any civil or criminal penalties for noncompliance. For purposes of this permit, non-compliance is defined as: a. Discharging waste other than authorized. b. Operating the injection well with a leak in the casing, as identified by pressure monitoring. c. Causing discharges to surface waters and lands, and to fresh water aquifers. d. Injection into a formation and level other than as authorized in this permi t, or as may be amended by the Regional Supervisor. e. Violating any conditions of this permit. 9. D.I.C. Reporting All reports required in the D.I.C. Permit shall be submitted to this Department as well. ) '} PERMIT NO. 8523-DB017 Page 4 of 4 10. All reporting required in this section shall be submitted to: Alaska Department of Environmental Conservation Kenai District Office P.O. Box 1207 Soldotna, AK 99669 Phone (907) 262-5210 Alaska Department of Environmental Conservation Southcentral Regional Office 437 E Street, Suite 200 Anchorage, Alaska 99501 Phone (907) 274-2533 RECEIVED SEP 2 7 1985 Alaska Oil & Gas Cons. Commission Anchorage PERMIT NO. 8523-DB017 Page 1 of 2 APPE ND IX B GENERAL CONDITIONS A. Access and Inspection The Department's representatives shall be allowed access to the Permittee's facilities to conduct scheduled or unscheduled inspections or tests to determine compliance wi th this permi t and State laws and regulations. B. Availability of Records Except for information relating to secret processes or methods of manu- facture, all records and reports submitted in accordance with the terms ~f this permit shall be available for public inspection at the Southcentral Regional Office of the Alaska Department of Environmental Conservation at 437 "E" Street, Suite 200, Anchorage, Alaska. c. Civil and Criminal Liability Nothing in this permit shall be construed to relieve the Permittee from civil or criminal penalties for noncompliance, whether or not such noncom- pliance is due to factors beyond his control, including but not limited to accidents, equipment breakdowns, or labor disputes. D. Property Rights The issuance of this permit does not convey any property rights in either real or personal property, or any other privileges; nor does it authorize any damage to private property or any invasion of personal rights, nor any infringements of federal, State, or local laws and regulations. E. Severability The provisions of this permit are severable and, if any provision of this permit or the application of any provision of this permit to any circum- stances is held invalid, the application of such provision to other circumstances and the remainder of this permit shall not be affected thereby. Notwithstanding the above, in the event such invalidation materially alters the scope or conditions of this permit, the Department shall have the right, at its sole option, to terminate the permit. RECEIVED SEP 2 7 1985 Alaska DB & Gas COilS. Çqmm1ssion Anchoraof ) PERMIT NO. 8523-DB017 Page 2 of 2 F. State Laws Nothing in this permit shall be construed to preclude the institution of any legal action or relieve the Permittee from any responsibilities, liabilities, or penalties established pursuant to any applicabble State law or regulation. G. Adverse Impacts The Permittee shall take all necessary means to minimize any adverse impact to the receiving waters or lands resulting from noncompliance with any limitations specified in this permit, including such additional monitoring as necessary to determine the nature and impact of the noncomplying discharge. The Permi ttee is required to undertake cleanup activities in the event of any adverse impact resulting from noncom- pliance. H. Modifications or Changes Anticipated facility expansion, production increases or process modifi- cation resulting in changes to operation will be reported to the Depart- ment, at least 30 days prior to the implementation of such changes. I. Permit Availability The Permittee shall retain a copy of this permit at the disposal facility. J. Transfers Should operation of the facility be contracted or a change in contractors be made, the new contractor shall be notified of the existence of the permit and its conditions. A copy of the written notification shall be forwarded to the Regional Supervisor of the Department's Southcentral Regional Of fice, 437 "E" Street, Sui te 200, Anchorage, Alaska 99501 (274-2533). K. Renewal Application for a renewal of this permit will be treated in the same manner as the initial application, except that public notice or hearing will not be provided for applications for renewal. Application for renewal must be made no later than 30 days before the expiration of the permit. J. Cultural & Paleontological Resources Should cultural or paleontological resources be discovered as a result of this acti vi ty, work that would disturb such resources must be stopped. The Office of History and Archaeology, Division of Parks and Outdoor Recreation, Department of Natural Resources, shall be notified immediately (276-2653). ) ) Permit No. AK-2D0001-I AUTHORIZATION TO INJECT UNDER THE UNDERGROUND INJECTION CONTROL PROGRAM In compliance with prOV1Slons of the Safe Drinking Water Act, as amended, (42 U.S.C. 300f-300j-9, commonly known as SDWA) and attendant regulations incorporated by the U.S. Environmental Protection Agency under Title 40 of the Code of Federal Regulations, Chevron U.S.A. Incorporated P.O. Box 107839 Anchorage, Alaska 99510 is authorized to construct the Class II Well, BRWD-l, located in the NE quarter of Section 13, Township 13N, Range lOW in Alaska and to inject such production and drilling fluids into the Lower Sterling Formation, in accordance with conditions set forth herein. Issuance of this permit also constitutes an exemption for aquifers deeper than 3,400 feet and described by an area within a one mile radius of the injection well bore. The exemption applies to Class II wells only and is made under the authority of 40 CFR 144.7 and the criteria of 40 CFR 146.4. All conditions set forth herein refer to Title 40 Parts 124, 144, 146, and 147 of the Code of Federal Regulations and are regulations that are in effect on the date that this permit is effective. Attachments are referenced to the Underground Injection Control Permit Application (EPA Form 7520-6). This permit and the authorization to inject are issued for the operating life of the well but shall be reviewed at least every five years. This permit and aquifer exemption shall become effective on October 21, 1985, in accordance with 40 CFR 124.15. Signed this 16th day of September, 1985. Agency RECEIVED C' I::':' f) "2'·, 0 'Ía8\~ :::J L..c , eO,;) "" Alaska Oil & Gas Cons. COi~\m\S2,\Jrl Ancfloraqe TABLE OF CONTENTS AUTHORIZATION TO CONSTRUCT AND INJECT PART I. SPECIFIC PERMIT CONDITIONS WELL CONSTRUCTION CORRECTIVE ACTION WELL OPERATION Section A. Section B. Section C. Section D. Section E. Section F. 1. Prior to Commencing Injection 2. Mechanical Integrity 3. Injection Interval 4. Injection Pressure Limitation 5. Injection Rate Limitation 6. Injection Fluid Limitation 7. Annular Fluid Page 2 of 15 Permit No. AK-2D0001-I MONITORING, RECORDKEEPING, AND REPORTING OF RESULTS 1. Injection Well Monitoring Program 2. Monitoring Information 3. Recordkeeping 4. Reporting of Results PLUGGING AND ABANDONMENT 1. Notice of Plugging and Abandonment 2. Plugging and Abandonment Plan 3. Cessation of Injection Activities 4. Plugging and Abandonment Report FINANCIAL RESPONSIBILITY Section A. PART II. GENERAL PERMIT CONDITIONS Section B. Section C. Section D. EFFECT OF PERMIT PERMIT ACTIONS 1. Modification, Reissuance, or Termination 2. Transfers SEVERABILITY CONFIDENTIALITY Page 4 4 4 5 5 5 5 5 5 6 6 6 7 7 7 7 7 8 9 9 9 9 10 Section E. Page 3 of 15 Permit No. AK-2D0001-1 TABLE OF CONTENTS (continued) GENERAL DUTIES AND REQUIREMENTS 1. Duty to Comply 10 2. Penalties for Violations of Permit Conditions 10 3. Need to Halt or Reduce Activity not a Defense 10 4. Duty to Mitigate 10 5. Proper Operation and Maintenance 10 6. Duty to Provide Information 11 7. Inspection and Entry 11 8. Records of Permit Application 11 9. Signatory Requirements 11 10. Reporting of Noncompliance 11 Attachment L/M-2 (Construction Plan) 13 Attachment Q (Plugging and Abandonment Plan) Appendix A (Reporting Forms) 14 15 Page 4 of 15 Permit No. AK-2D0001-I PART I. SPECIFIC PERMIT CONDITIONS A. WELL CONSTRUCTION The proposed construction details submitted with the application are hereby incorporated into this permit as Attachment L/M-2t and shall be binding on the permittee except that the packer shall be set at 3t540 feet. Adequate amounts of cement shall be used to ensure a good cement bond between the casing and the well bore. The cement used in the construction of the well shall be designed for the life expectancy of the we 11 . The permittee shall give notice to the Regional Administrator as soon as possible of any planned physical alterations or additions to the permitted facility. In additiont the permittee shall provide all records of well workoverst logging, or other test data to EPA within 60 days of completion of the activity. Appendix A shows appropriate reporting forms. B. CORRECTIVE ACTION The operator is not required to take any corrective action on any well within the area of review. C. WELL OPERATION 1. Prior to Commencing Injection. Injection operations may not commence until: Rt(t\\Jt~ "'\ '\t\\1~ f' "ì") f} \.i~,'::Þ C'~.". S,-\~, t::~ " It Gas ,I' ~" 0\\ 0. . 'C"Ws t).,\asr-3 þ,,;\(~\V':¡ ,,"'1· b . a. Construction is complete and the permittee has submitted a well completion report (Form 7520-10), see Appendix A; and (i) The Regional Administrator has inspected or otherwise reviewed the new injection well and finds it is in compliance with the conditions of the permit; or (ii) The permittee has not received notice from the Regional Administrator of his or her intent to inspect or otherwise review the new injection well within thirteen (13) days of the date of the notice in paragraph (i) of this permit condition in which case prior inspection or review is waived and the permittee may commence injection. The operator demonstrates that the well has mechanical integrity in accordance with 40 CFR 146.8 and the permittee has received notice from the Regional Administrator that such a demonstration is satisfactory. The permittee shall notify EPA two weeks prior to conducting this test so that a representative may be present. Page 5 of 15 Permit No. AK-2D0001-I (i) In order to demonstrate there is no significant leak in the casing, tubing or packer, the tubing/casing annulus must be pressure tested to 1,000 pounds per square inch absolute (psia) for thirty minutes. Pressure loss may not exceed 100 psia at the end of the thirty minute test. (ii) In order to demonstrate there is no significant fluid movement through vertical channels adjacent to the injection well bore, records must show adequate cement to prevent such migration. 2. Mechanical Integrity. a. A demonstration of mechanical integrity in accordance with permit condition Part I.C.1.b.(i) shall be made every five (5) years from the effective date of this permit. The permittee shall notify the Regional Administrator of his intent to demonstrate mechanical integrity at least thirty (30) days prior to such demonstration. Results of the test shall be submitted to the Regional Administrator as soon as possible but no later than sixty (60) days after the demonstration. b. Loss of Mechanical Integrity. If the well fails to demonstrate mechanical integrity during a test, or a loss of mechanical integrity as defined by 40 CFR 146.8 becomes evident during operation, the permittee shall notify EPA in accordance with Permit Condition Part II, Section E.10. Operation shall not be resumed until the permittee has taken necessary actions to restore integrity to the well and EPA gives approval to recommence injection. c. Mechanical integrity tests shall be performed using noncorrosive fluids in the tubing/casing annulus, consisting of either a non-toxic liquid or the injection liquid. 3. Injection Interval. Injection shall be limited to the Lower Sterling Formations in the subsurface interval between 3540 ft. and 4009 ft. 4. Injection Pressure Limitation. Injection pressure, measured at the surface, shall not exceed 700 pounds per square inch absolute (psi a). 5. Injection Rate Limitation. The rate of wastes to be injected into the well will be limited to 5,000 barrels per day. 6. Injection Fluid Limitation. The permittee shall not inject any hazardous substances, per 40 CFR 261, at any time during the operation of the facility, and further, no substances other than those noted in the permit application shall be injected. 7. Annular Fluid. The annulus between the tubing and the casing shall be filled with a corrosion inhibited, sodium chloride solution or diesel fluid. Page 6 of 15 Permit No. AK-2D0001-I D. MONITORING, RECORDKEEPING, AND REPORTING OF RESULTS 1. Injection Well Monitoring Program. Samples and measurements shall be representative of the monitored activity. The permittee shall utilize the applicable analytical methods described in 40 CFR 144.52(a)(5). Monitoring shall consist of: a. Analysis of the injection fluids, performed: (i) quarterly for Total Dissolved Solids, pH, Specific Conductivity, and Specific Gravity: and, (ii) whenever there is a change in the source of injection fluids. A comprehensive water analysis shall be submitted to the Regional Administrator within thirty (30) days of any change in injection fluids. b. Weekly observations of injection pressure, annular pressure, flow rate and cumulative volume. At least one observation of injection pressure, annular pressure, flow rate, and cumulative volume shall be recorded at regular intervals no greater than thirty (30) days. 2. Monitoring Information. Records of any monitoring activity required under this permit shall include: a. The date, exact place, the time of sampling or field measurements; b. The name of the individual(s) who performed the sampling or measurements; c. The exact sampling method(s) used to take samples; d. The date(s) laboratory analyses were performed; e. The name of the individual(s) who performed the analyses; f. The analytical techniques or methods used by laboratory personnel; and g. The results of such analyses. 3. Recordkeeping. The permittee shall retain records concerning: a. The nature and composition of all injected fluids until three (3) years after the completion of plugging and abandonment. The permittee shall continue to retain the records after the three-year retention period unless he delivers the records to the Regional Administrator or obtains written approval from the Regional Administrator to discard the records. b. All monitoring information, including all calibration and maintenance records and all original strip chart recordings for monitoring instrumentation and copies of all reports required Page 7 of 15 Permit No. AK-2D0001-I by this permit for a period of at least five (5) years from the date of the sample, measurement or report during the operating life of the well. This period may be extended by request of the Regional Administrator at any time. 4. Reporting of Results. The permittee shall submit an annual report to the Regional Administrator summarizing the results of the monitoring required by Permit Condition Part I, Section 0.1 .(b). All monthly records on injected fluids, and any major changes in characteristics or sources of injected fluid shall be included in the annual report. The first annual report shall cover the period from the effective date of the permit through December 31. Subsequently, the annual report shall cover the period of January through December 31, and shall be submitted by February 15 of the following year. E. PLUGGING AND ABANDONMENT 1. Notice of Plugging and Ab~,donment. The permittee shall notify the Regional Administrator forty-five (45) days before conversion or abandonment of the well. 2. Plugging and Abandonment Plan. The permittee shall plug and abandon the well as provided in the Plugging and Abandonment Plan, Attachment Q. EPA reserves the right to change the manner in which the well will be plugged if the well is not proven to be made consistent with EPA requirements for construction and mechanical integrity. The ,Regional Administrator may ask the permittee to update the estimated plugging cost periodically. 3. Cessation of Injection Activities. After a cessation of operations of two years, the permittee shall plug and abandon the well in accordance with the Plugging & Abandonment Plan, unless he: a. provides notice to the Regional Administrator, b. demonstrates that the well will be used in the future, and c. describes actions or procedures, satisfactory to the Regional Administrator, that will be taken to ensure that the well will not endanger underground sources of drinking water during the period of temporary abandonment. 4. Plugging and Abandonment Report. Within sixty (60) days after plugging the well, the permittee shall submit a report to the Regional Administrator. The report shall be certified as accurate by the person who performed the plugging operation and the report shall consist of either: (1) a statement that the well was plugged in accordance with the plan, or (2) where actual plugging differed from the plan, specifying the different procedures followed. Page 8 of 15 Permit No. AK-2D0001-I F. FINANCIAL RESPONSIBILITY The permittee is required to maintain financial responsibility and resources to close, plug, and abandon the injection well as provided in the plugging and abandonment plan. The permittee shall submit information annually, as required by EPA, in order to demonstrate that the financial statement coverage continues to provide adequate coverage. If the financial statement coverage no longer meets the financial coverage criteria, the permittee must submit an alternative demonstration of financial responsibility acceptable to the Regional Administrator within 60 days. If a new financial instrument is required, it will be made part of this permit by permit modification. Failure to do so will be grounds for termination of this permit. The permittee may request a change in financial mechanisms. The new instrument must be approved by the Regional Administrator. Page 9 of 15 Permit No. AK-2D0001-I PART II. GENERAL PERMIT CONDITIONS A. EFFECT OF PERMIT The permittee is allowed to engage in underground injection in accordance with the conditions of this permit. The underground injection activity, otherwise authorized by this permit or rule, shall not allow the movement of fluid containing any contaminant into underground sources of drinking water, if the presence of that contaminant may cause a violation of any primary drinking water regulation under 40 CFR Part 141 or otherwise adversely affect the health of persons. Any underground injection activity not authorized in this permit or otherwise authorized by permit or rule is prohibited. Issuance of this permit does not convey property rights of any sort or any exclusive privilege; nor does it authorize any injury to persons or Jroperty, any invasion of other private rights, or any infringement of State or local law or regulations. Compliance with the terms of this permit does not constitute a defense to any enforcement action brought under Part C and the imminent and substantial endangerment provisions in Part D of the Safe Drinking Water Act (SDWA), or any other law for any imminent and substantial endangerment to human health or the environment, or for any breach of any other applicable legal duty. B. PERMIT ACTIONS 1. Modification, Reissuance, or Termination. This permit may be modified, revoked and reissued, or terminated for cause as specified in 40 CFR Sections 144.39, 144.40, and 144.41. The filing of a request for a permit modification, revocation and reissuance, or termination or the notification of planned changes or anticipated noncompliance on the part of the permittee does not stay the applicability or enforceability of any permit condition. This permit will be terminated when final EPA action has been taken on the permit application, or when the State of Alaska is granted primary enforcement responsibility for the underground injection control program pursuant to the Safe Drinking Water Act, applicable to the injection activity regulated by this permit, and the State has taken final action on the State permit application. 2. Transfers. This permit is not transferable to any person except after notice is sent to the Regional Administrator and the requirements of 40 CFR 144.38 are complied with. The Regional Administrator may require modification or revocation of the permit to change the name of the permittee and incorporate such other requirements as may be necessary under SDWA. C. SEVERABILITY The provisions of this permit are severable, and if any provlslon of this permit or the application of any provision of this permit to any circumstance, is held invalid, the application of such provision to other Page 10 of 15 Permit No. AK-2D0001-I circumstances, and the remainder of this permit shall not be affected thereby. D. CONFIDENTIALITY In accordance with 40 CFR Part 2, any information submitted to EPA pursuant to this Permit, may be claimed as confidential by the submitter. Any such claim must be asserted at the time of submission in the manner prescribed on the application form or instructions or, in the case of other submissions, by stamping the words "confidential business informationll on each page containing such information. If a claim of confidentiality is asserted, the information will be treated in accordance with the procedures in 40 CFR Part 2 (Public Information). If no claim is made at the time of submission, EPA may make the information available to the public without further notice. Claims of confidentiality for the following information will be denied: a. the name and address of the permit applicant or permittee, and b. information which deals with the existence, absence, or level of contaminants in drinking water. E. GENERAL DUTIES AND REQUIREMENTS 1. ~ to Comply. The permittee shall comply with all conditions of this permit, except to the extent and for the duration such noncompliance is authorized by an emergency permit. Any permit noncompliance constitutes a violation of SDWA and is grounds for enforcement action, permit termination, revocation and reissuance, modification, or for denial of a permit renewal application. 2. Penalties for Violations of Permit Conditions. Any person who violates a permit condition is subject to a civil penalty not to exceed $5,000 per day of such violation. Any person who willfully or negligently violates permit conditions is subject to a fine of not more than $10,000 per day of violation in lieu of the civil penalty previously stated. 3. Need to Halt or Reduce Activity not a Defense. It shall not be a defense for a permittee in an enforcement action that it would have been necessary to halt or reduce the permitted activity in order to maintain compliance with the conditions of this permit. 4. Duty to Mitigate. The permittee shall take all reasonable steps to minimize or correct any adverse impact on the environment resulting from noncompliance with this permit. 5. Proper Operation and Maintenance. The permittee shall at all times properly operate and maintain all facilities and systems of treatment and control (and related appurtenances) which are installed or used by the permittee to achieve compliance with the conditions of this permit. Proper operation and maintenance includes effective performance, adequate funding, adequate operator staffing and training, and adequate laboratory and process controls, including Page 11 of 15 Permit No. AK-2D0001-I appropriate quality assurance procedures. This provision requires the operation of back-up or auxiliary facilities or similar systems only when necessary to achieve compliance with the conditions of this permit. 6. Duty to Provide Information. The permittee shall furnish the Regional Administrator, within a time specified, any information which the Regional Administrator may request to determine whether cause exists for modifying, revoking and reissuing, or terminating this permit, or to determine compliance with this permit. The permittee shall also furnish to the Regional Administrator, upon request, copies of records required to be kept by this permit. 7. Inspection and Entry. The permittee shall allow the Regional Administrator, or an authorized representative, upon the presentation of credentials and other documents as may be required by law to: a. Enter upon the permittee1s premises where a regulated facility or activity is located or conducted, or where records are kept under the conditions of this permit; b. Have access to and copy, at reasonable times, any records that must be kept under the conditions of this permit; c. Inspect at reasonable times any facilities, equipment (including monitoring and control equipment), practices, or operations regulated or required under this permit; and d. Sample or monitor, at reasonable times, for the purposes of assuring permit compliance or as otherwise authorized by SDWA any substances or parameters at any location. 8. Records of Permit Application. The permittee shall maintain records of all data required to complete the permit application and any supplemental information submitted for a period of three (3) years from the effective date of this permit. This period may be extended by request of the Regional Administrator at any time. 9. Signatory Requirements. All reports or other information requested by the Regional Administrator shall be signed and certified according to 40 CFR 144.32. 10. Reporting of Noncompliance. a. ANTICIPATED NONCOMPLIANCE. The permittee shall give advance notice to the Regional Administrator of any planned changes in the permitted facility òr activity which may result in noncompliance with permit requirements. b. COMPLIANCE SCHEDULES. Reports of compliance or noncompliance with, or any progress reports on, interim and final requirements contained in any compliance schedule of this permit shall be submitted no later than thirty (30) days following each schedule date. Page 12 of 15 Permit No. AK-2D0001-1 c. TWENTY-FOUR HOUR REPORTING. (i) The permittee shall report to the Regional Administrator any noncompliance which may endanger health or the environment. Any information shall be provided orally within twenty-four (24) hours (Phone number: (206) 442-1846) from the time the permittee becomes aware of the circumstances. The following shall be included as information which must be reported orally within twenty-four (24) hours: (A) Any monitoring or other information which indicates that any contaminant may cause endangerment to an underground source of drinking water. (B) Any noncompliance with a permit condition or malfunction of the injection system which may cause fluid migration into or between underground sources of drinking water. (ii) A written submission shall also be provided within five (5) days of the time the permittee becomes aware of the circumstances. The written submission shall contain a description of the noncompliance and its cause; the period of noncompliance, including exact dates and times, and if the noncompliance has not been corrected, the anticipated time it is expected to continue; and steps taken or planned to reduce, eliminate, and prevent recurrence of the noncompliance. d. OTHER NONCOMPLIANCE. The permittee shall report all other instances of noncompliance not otherwise reported at the time monitoring reports are submitted. The reports shall contain the information listed in Permit Condition Part II, Section E.10.c.(i1). e. OTHER INFORMATION. Where the permittee becomes aware that he failed to submit any relevant facts in the permit application, or submitted incorrect information in a permit application or in any report to the Regional Administrator, the permittee shall submit such facts or information within 2 (two) weeks of the time such information became known to him. Da Nil'... eM. CIIlVI'an ,Da.,.. J &,( . ~ .,.... P'\ . ~ QIIII"a. DIJ'T. .....ov.C .. ....... ,*", SCALI NnN' DATI I_'A~ I. .0. I PROPOSED BRWD -I WASTE WATER/MUD DISPOSAL WELL ÞI 5 1/2" SLOTTED OR WIRE WRAPPED LINER a 390d . ~ ' I . . ~ j , ---- PACKER e 3300' ' . . POLISH BORE RECEPTACLE I ~ÿ i i\ J.-\ ~._ ~ 7 .. CASING e 3S70 I 5f,yt:, .' ~ :;h I' _"W~ , . . Je,rl.~ Q .. '_QWl · . · ,51/0 . . : .: .:?- GRAVEL PACK . 3 1/2 II FI BERGLASS TUSING .. 9 S/8 M CASING e I~OO' ~ 13 3/8 .. CASING e 120' Page 13 of 15 Permit ¡ro. AK-2D0001-I . lEV\<>! , .. · . . '" '41 (. . · . , , , · ' . · . . . , . · , ~ r:-: .. . ~ ~ ~ . Attachment L/M-2 Attachment Q ôEPA NAME AND ACDRUS OF FACIUTY BR WD-l Well P.O. Box 107839 Anchorage. Alaska 99510 LOCATE WILL AND OUTUNE UNIT ON SECTION P\.AT - &40 ACRES N I I I -I I ~- I I I I I I T- I I ~-I ~ø I I' I I I W I I I I I _.L...LI I I I I I I I -+-+-+- I I -t-- I I ..L_J..--LJ.._ I I I I I I S Page 14 of 15 Permit No. AK-2D0001-1 Fo,", APII'OYH. OMe No. 2ú40-otU2, AþlJfOtle/e1CfJ"el 9.30'!6 UNITED STATES ENV1RQNMENTAL PROTECTION AGENt" WASHINGTON. DC 20&80 PLUGGING AND ABANDONMENT PLAN NAME AND ADDRESS OF OWNER/OPERATOR Chevron U.S.A. Inc. P.O. Box 107839 Anchorage. AK 99510 5T A T£ COUftlT Alaska Kenai Peninsula Borough SURFACE LOCATION DESCRII'TION NE '4 OF SE '4 OF NE '4SECTlON 13 TOWNSHIP 13N ;\ANGE lOW LOCATE WELL IN 'tWO DIRECTIONS FROM NEAREST UNES O~QUARTER SECTION AND DRIWNG UNIT I PERMIT NUMBER I Surface 55" N Location L 'ft. from IN/S) _ Line of qua"_ Mction end..2.Q. ft. from IE/W)...!l. Une of QU'"" MCti~ TYPE OF AUTHORIZATION WELL ACTIVITY E «lndividu.1 Permit o Are. Permit OAul, Number of Wells -L. o CLASS I iXCl.ASS II l'XSrine OispoUI & Drilling/Completic n c:; Enhanced Recovery Fluids o Hydroclrbon Storage [J CLASS III CASING AND TUBING RECORD AFTER PLUGGING lease Name Located within ADL 58831 SIZE 13-3/&" .9-5/8" 7" WTILB/FT} 61 íg TO BE PUT IN well 1FT) TO BE LEFT IN well 1FT) 120 120 !~~8 !8~8 Size of 10401. or Pip. in WI'IICI'I Plug Will Be PI'ced (inche'l Oepth to Bonom of Tubing or Drill Pipe 1ft. I (# 1 retainer) Secks of Cement To Be Used leech plug) r Slurry Volume To Øe Pumped Icu. ft.1 Celculated Toø of Plug (ft,) Mee.ured Toø of Plug (if tlgged ft.1 Slurry Wt. ILb.lGII.) Type Cement or Other Meteriel (Cle.. III) UST ALL OPEN HOLE AND/OA PERFORATED INTERVALS AND INTERVALS WHERE CASING WILL BE VARIED (If en'!) To From Sf" 20 430 CEMENTING TO PLUG AND ABANDON DATA: From Slotted or wirewraPDed liner 3570' Estimated COlt to Plug Well. $200,000. Well Number B R WD-l METHOD OF EM~CEMENT OF CEMENT PlUGS [!! The alllnce Method # 2. 3, 4 o The Dump aliler Method o The Two-Plug Method [! Othe,. Squeeze # 1 430 HOLE SIZE Driven 12l" 8f" 6 t" PLUG .1 PlUG n 4.778 6.366 3500 3500 175 100 203 115 3500 2980 PLUG .7 PlUG n 6.366 1600 50 58 1337 PLUG .. R.835 500 190 218 o PLUG .15 PLUG ., 15.8 15.8 15.8 15.8 To 3900' CERTIFICATION RECEIVtO I certi'! un~er t~e penahy of law that I have personally examined and am f~mili~r with th,e ~e?P'.aJifJ' j B' . ' "' submItted In thIs document and all attachments and that. based on my inqUIry of those Indlviftua7s- ~85 immediately responsible for obtaining the information. I believe that the informaAlaslil tMe&B'lfJY'~e. and completll. lam aware that thllrsarll significant penahies for submitting false information. i'A.fi'¿f~/,rþIS. CornmlS ~jOfj the possibility of fine and imprisonment. (Ref. 40 CFR 744.32) I rage NAME ANQ_ OFFICIAL TITLE (Pl.... ryptI tw /Kint} J.t. Weaver , Area Operations Superintendent EPA Form 7120· 1" (3.84) s/f:J¿J~ èJr. . DATE SIGNED ~f -' ¡ -!:;- APPENDIX A (Reporting Forms) Page 15 of 15 Permit No. AK-2DOOOI-1 aEPA NAME AND ADDRESS OF EXISTING PERMITTEE LOCATE WELL AND OUTLINE UNIT ON SECTION PLAT - 640 ACRES N I I I I I I -+--+-+--+--+--+-- I I I I I I -T-'-T-T-rT- -+--+-+--+--+--+-- I I I I I I W I I I I I I E _1..-L.1.._...L-L...L_ I I I I I I -+-+-+-+-+-+- _l..-L.l.._...L-L..l_ I I I I I I S NAME(S) AND ADDRESS(ES) OF NEW OWNER(S) For4 Hoved. OMB No. 2000-0042. Approval expires 9-30-86 UNITED STATES ENVIRONMENTAL PROTECTION AGENCY WASHINGTÇ>N, DC 20460 APPLICATION TO TRANSFER PERMIT NAME AND ADDRESS OF SURFACE OWNER STATE COUNTY PERMIT NUMBER SURFACE LOCATION DESCRIPTION ',4 OF ',4 OF ',4 SECTION TOWNSHIP RANGE LOCATE WELL IN TWO DIRECTIONS FROM NEAREST LINES OF QUARTER SECTION AND DRILLING UNIT Surface Location _ ft. from (N/S) _ Line of quarter section and _ ft. from (E/W) _ Line of quarter section WELL ACTIVITY WELL STATUS o Class I 0 Operating o Class II 0 Modification/Conversion OBrine Disposal 0 Proposed o Enhanced Recovery o Hydrocarbon Storage o Class III o Other TYPE OF PERMIT o Individual o Area Number of Wells _ Lease Name Well Number NAME AND ADDRESS OF.NEW OPERATOR Attach to this application a written agreement between the existing and new permittee containing a specific date for transfer of permit responsibility, coverage, and liability between them. The new permittee must show evidence of financial responsibility by the submission of surety bond, or other adequate assurance, such as financial statements or other materials acceptable to the director. CERTIFICATION I certify under the penalty of law that I have personally examined and am familiar with the information submitt(¡]d in this document and all attachments and that, based on my inquiry of those individuals immediat~/y responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment. (Ref. 40 CFR 144.32) NAME AND OFFICIAL TitLE (Please type or print) EPA Form 7620-7 (2-~") SIGNATURE DATE SIGNED êEPA YEAR Injection Pressure (PSI) 1. Minimum 2. Average 3. Maximum Injection Rate (Gål/Min) 1. Minimum 2. Average 3. Maximum Annular Pressure (PSI) 1. Minimum 2. Average 3. Maximum . Injection Volume (Gal) 1. Monthly Total 2. Yearly Cumulative Temperature (FO) 1. Minimum 2. Average '. 3. Maximum pH 1. Minimum 2. Average 3. Maximum Other Name and Address of Permittee ) ) UNlTcLJ STATES ENVIRONMENTAL PROTECTION AGENCY WASHINGTON,' DC 20460 INJECTION WELL MONITORING REPORT MONTH MONTH Name and Official Title (Plee.e type or print) EPA Form 71520-8 (2-8.) Form Approved OMS No. 2000-0042 Approval expires 9-30-86 MONTH RECEIVED -~E-P (J """\ '·S . ...' I /C., V 11 .,.... ~ U;JJ .Alask~ (I.jJ & C '. ~ ð0 CUffS. Commission Anctorage Signature Permit Number Date Signed ) ) õEPA Ur.I. rED STATES ENVIRONMENTAL PROTECTION AGENCY WASHINGTON, DC 20460 COMPLETION REPORT FOR BRINE DISPOSAL, HYDROCARBON STORAGE, OR ENHANCED RECOVERY WEll Form Approved OMS No. 2040-0042 Approv81øxpires 9-30-86 Type of Injection Fluid (Chøck the appropriate block(s)) o Salt Water 0 Brackish Water 0 Fresh Water o Liquid Hydrocarbon 0 Other NAME AND ADDRESS OF EXISTING PERMITTEE LOCATE WELL AND OUTLINE UNIT ON SECTION P~T - 640 ACRES N I I I I I I -+--+-+---1--+--1-- I I I I I I -T-rT-T-'-T- -+--+-+---1--+-4-- I I I I I I W I I I ! I I E _1--L..L_..L-L1.._ I I I i I I -+-+-+-+-+-+- _1---'--..L_..L-L..L_ I I I I I I S Date Drilling Began NAME AND ADDRESS OF SURFACE OWNER STATE COUNTY PERMIT NUMBER SURFACE LOCATION DESCRIPTION 'A OF 1A OF 1A SECTION TOWNSHIP RANGE LOCATE WELL IN TWO DIRECTIONS FROM NEAREST LINES OF QUARTER SECTION A.ND DRILLING UNIT Surface Location _ ft. from (N/S) _ Line of quarter section and _ ft. from (E/W) _ Line of quarter section WELL ACTIVITY TYPE OF PERMIT o Brine Disposal 0 Individual o Enhanced Recovery 0 Area o Hydrocarbon Storage Number of Wells _ Anticipated Daily Injection Volume (Bbls) Injection Interval Average Maximum Feet Estimated Fracture Pressure of Injection Zone to Feet _ I Anticipated Daily Injection Pressure (PSI) Average Maximum Depth to Bottom of Lowermost Freshwater Formation (Feet) Lease Name Well Number Name of Injection Zone Date Well ComDleted Permeability of Injection Zone Date Drilling Completed OD Size CASING AND TUBING Wt/Ft - Gr~de - New 01' Used Porosity of Injection Zone CEMENT HOLE Depth Sacks Class Depth Bit Diameter Interval Treated INJECTION ZONE STIMULATION Materials and Amount Used WIRE LINE LOGS, LIST EACH TYPE Log Types Logged Intervals Complete Attachments A - E listed on the reverse. CERTIFICA TIQN I certify under the penalty of law that I have personally examined and am familiar with the information submitted in this document and a/l attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment. (Ref. 40 CFR 144.32). NAME AND OFFICIAL TITLE (PltllJ&tI typø or print) cp - FII' 'II' "'&"'1' 1n ''''' ,. , DATE SIGNED L õEPA \ Form ¡J \ved. OM8 No. 2000-0042. Approval expires 9-30-86 .I~ITED STATES ENVIRONMENTAL PROTECTION AGENCY } WASHINGTON, DC 20460 ANNUAL DISPOSAL/INJECTION WELL MONITORING REPORT NAME AND ADDRESS .OF EXISTING PERMITTEE LOCATE WELL AND OUTLINE, UNIT ON SECTION PLAT - 640 ACRES N ,I I I I I I --+---J-+'--+---l--+-- I I I I I I -T-'-T-T-'-T- --+--+--+---+---l--+-- I I I I I I W I I I I I I E _-L-L-L_..l-L..l_ I I I I I I -+-+-+- ,/ / +- _-L-L-L_..l-L...L_ I I I I I I S INJECTION PRESSURE MONTH YEAR AVERAGE PSIG NAME AND ADDRESS OF SURFACE OWNER STATE COUNTY PERMIT NUMBER SURFACE LOCATION DESCRIPTION '.1.4 OF '.1.4 OF '.1.4 SECTION TOWNSHIP RANGE LOCATE WELL IN TWO DIRECTIONS FROM NEAREST LINES OF QUARTER SECTION AND DRILLING UNIT Surface Location _ ft. from (N/S) _ Line of quarter section and _ ft. from (E/W) _ Line of quarter section WEll ACTIVITY TYPE OF PERMIT o Brine Disposal 0 Individual o Enhanced Recovery 0 Area o Hydrocarbon Storage Number of Wells _ lease Name Well Number TOTAL VOLUME INJECTED TUBING - CASING ANNULUS PRESSURE (OPTIONAL MONITORING) MAXIMUM PSIG MINIMUM PSIG MAXIMUM PSIG BBL MCF CERTIFICATION I certify under the penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment. (Ref. 40 CFR 144.32). NAME AND OFFICIAL TITLE (Please type or print) Fp Fnrm 71õ,?n." 1~-84) SIGNATURE DATE SIGNED õEPA NAME AND ADDRESS OF PERMITTEE LOCATE WELL AND OUTLINE UNIT ON SECTION PLAT - 640 ACRES N I I I I I I --+--+---+---+--+---+-- I I I I I I -T-rT-T-rT- -+--+---+---+--+--+-- I I I I I I W I I I I I E _.1.~_l.._.l-Ll.._ I I I I I I -+---+--t--+-+- _.1.~_1.._l..-Ll.._ I I I I I I S Casing Size Sacks Depth ) FormA. led. OMB No. 2000-0042. Approval expires 9-30-86 UNITED STATES ENVIRONMENTAL PROTECTION AGENCY WASHINGTON, DC 20460 WELL REWORK RECORD NAME AND ADDRESS OF CONTRACTOR STATE COUNTY PERMIT NUMBER SURFACE LOCATION DESCRIPTION '14 OF 1¡4 OF 1¡4 SECTION TOWNSHIP RANGE LOCATE WELL IN TWO DIRECTIONS FROM NEAREST LINES OF QUARTER SECTION AND DRILLING UNIT Surface Location _ ft. from (N/S) _ Line of quarter section and _ ft. from (E/W) _ Line of quarter section WELL ACTIVITY Total Depth Before Rework o Brine Disposal o Enhanced Recovery D Hydrocarbon Storage TYPE OF PERMIT D Individual D Area Number of Wells _ Total Depth After Rework Lease Name Date Rework Commenced Well Number Date Rework Completed WELL CASING RECORD - BEFORE REWORK Cement Perforations Acid or Fracture Treatment Record Type From To Casing WELL CASING RECORD - AFTER REWORK (Indicate Additions and Changes Only) Perforations Size Sacks Depth Cement Acid or Fracture Treatment Record Type From To DESCRIBE REWORK OPERATIONS IN DETAIL USE ADDITIONAL SHEETS IF NECESSARY WIRE LINE LOGS, LIST EACH TYPE Log Types Logged Intervals CERTIFICATION I certify under the penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment. (Ref. 40 CFR 144.32). NAME AND OFFICIAL TITLE (Please type or print) '-p - I=r·m "76~n 1 ~ ,,, a , SIGNATURE DATE SIGNED #2 Chevron === ) Chevron U.S.A. Inc. P.D. Box 107839, Anchorage, AK 99510 . Phone (907) 786-6600 J.L. Weav8r Area Operat:ons Superintendent Production Department July 25, 1985 Application Package Submittal BRWD-l Well Office of Ma gement & Budget 2600 Den . Street, Suite 700 Anchor e, Alaska 99503 Attention: Ms. Patty Bielawski Gentlemen: On April 30, 1985, Chevron U.S.A. Inc. (Chevron) submitted the above referenced application package. It is Chevron's understanding that until the Department of Environmental Conservation (DEC) deems the Solid Waste Disposal Permit Applica- tion complete, no action on the other applications within the package can proceed. Chevron is unable to resolve the surface use issue at this time, which DEC has indicated is necessary before it will deem the Solid Waste Disposal Permit application complete. Because of this unresolved issue, Chevron hereby withdraws the Solid Waste Disposal Permit application for BRWD-l. The reserve pit will only be used for temporary storage as all material will be removed for disposal at other approved disposal facilities and/or sites. We trust that the remaining applications can now be processed. This well is vital to the continued operation of the Beluga River Field. Any further delays in the drilling of this well will have serious negative impacts on Chevron's ability to satisfy its gas sale commitments as operator of the field. MRB:mw lJ;:J..yours, r L. wea~ cc: Department of Environmental Conservation, Attn: Bob Flint Alaska Oil & Gas Conservation Commission, Attn: Mr. Chat Chatterton / Division of Oil & Gas, Attn: Ms. Kay Brown Bureau of Land Management, Attn: Mr. Joe Dygas RECE\VED JUL 2 q 1985 Alaska Oil & Gas Cons. CommIssion Anchorage #1 Chevron III it ~~O'\^A~ ,I -.:g C ~:,' ,..; ..'J\ ,4. ,~.c_~~·":'':1 .J) ¡ i<~::,) ,"..-. 'I___! .,' 1. ::.' 1\'; r~ æ. i I r¡ r:":' -If ' ~I: :4:J',"'~ --, 7- ' : \! '_ì ~ ~---- : 1 (::·~-.:OL t'¡ 2!-::,!'C~ 'oj /' ~._. t I .~: ,~;.~ (~~¡I L Solid Waste Disposal Permit Application I .':':,:1 ï;':Cf ::r~~~~eation No. 8523-BA003 !~ST.",T ,":'" ~ r C()r~l~--- 'j ¡ fILF: Chevron U.SA. Inc. P.O. Box 107839, Anchorage, AK 99510 · Phone (907) 786-6600 J.L. Weaver Area Dperal!OnS Superintendent Production Department July 25, 1985 State of Alask Departmen Environmental Conservation Southce al Regional Office 437 treet, Suite 200 A orage, Alaska 99501 Attention: Mr. Robert C. Flint Gentlemen: Chevron hereby withdraws the application for the above referenced permit. We are currently unable to resolve the surface right issue with the Cook Inlet Region, Inc. (CIRI). Weare now in the process of preparing application packages for two new proposed wells (BRU 224-34 and BRU 211-3) which will be drilled from a common drill pad located on Kenai Peninsula Borough surface lands. The reserve pit at this site will be designed with a capacity to accommodate the drill cuttings and mud solids generated from the drilling of BRU 224-34, BRU 211-3, and from BRWD-1. This permit package should be ready for submittal to all appropriate agencies on or about August 15, 1985. A suitable drilling rig is being mobilized to obtain son profile information and depth to groundwater information, which your agency requires in the application. As no disposal will now take place in the BRWD-1 reserve pit and all drill cuttings and mud solids will be removed to the proposed BR U 224-34/211-3 reserve pit, Chevron therefore requests plan review approval for, the temporary storage of muds and cuttings in the BRWD-1 pit. The pit will still be constructed as indicated in the permit application No. 8523-BA003. Opera tions in the Beluga River Field have reached a critical point where any further delays in the development drilling schedule will result in serious gas contracted commitment shortages. Recent prohibitions and/or restrictions which we are encountering from both governmental agencies and certain land owners, have literally reached the point where Chevron is concerned if we will be able to RECE\VED JUL 2 í:j1985 :', ; ::.~ ~~'; ~,f ? ,''','' & Gas Cons Commission ,...dl . þ, nr.horage ...J.I .... Mr. Robert C. Flint July 25, 1985 Page 2 timely and economically meet the near future gas demands of the two affected utili ties. J. L. Weaver MRB:mw cc: Division of Governmental Coordination - Attn: Ms. Patty Bielawski Alaska Oil and Gas Conservation Commission - Attn: Mr. Chat Chatterton ~ Division of Oil and Gas - A ttn: Ms. Kay Brown Bureau of Land Management - Attn: Mr. Joe Dygas RECEIVED JUl2919·85 Alaska Oil & Gas Cons. Commission Anchorage -' .::1 ():¡ ,..-; . i : .~- ,. RE C E 1 V ED MAY 2 7 1986 Vol. .. y .~.................... .Page......? ~ .~....... ........ ALJL 44664 State Record of Water Right Certificates ~ d /.*'?/ L?p. . ~..~...r-::-:-./;...!......~.........:....... Acting Director, Division of Lands . day of.......... J'.~y......... .................................... .A.D. 19,7.1..... . . . . . . . ~ . . . . . . . . . . . . . . . . . . . . . . .. . . . . . . . . . . .. .......... of the Division of Lands pursuant to A. S. 46.15, as amended, this......4.th...... 3Jn mrøthnl1ny mqrrrof the State of Alaska has caused these presents to be executed by the Director ... to " ~ ._ and.........~.~l,~.:A:~...............heirs and assigns forever, subject to the provisions of A. S. 46.15.140-160. mo IrIanr nnit to lIolb the said water right with the appurtenances thereof unto the said Grantee HAY 26 I 32 fn '71 2:' : ~. ~é:17. l' · Q ___ _ .,X°..T..(.·.... . ~ 0 .". - :.' W. o~ ~ 5 'I . . Beneficial use of water began..........~.Ia.J'...~~66 ~.; c;; ·/f7!-~Üt>L. 9'j$OI .................. ........................... ............. ............... ....:.. ......:............. .... .............. ~ :"'\... -~ I .:J' 4 ~'I-: ¡,E.... f . -.-". . r . )II'\I~: c- ."..... . -~ 7/,0 ,. ~ q ? ~ \,i ... .... ~IOO . . ...... " : ' " :-- .---- _. . -- Parcel of property encompassing protracted NE 1/4 of SE 1/4 and SJ~ 1/4 of NE 1/4 of Sec. 27. T. 13N. R. lOW. Seward Meridian. follows: and the right to said water shall be appurtenant to that certain tract of real property described as the right to the use of...1.~4.t.qQ.q...g~JJ~.~~...P~.~...~~y .......................from the public waters of the State of Alaska for the purposes of. .~~.~~J.ng,. .º.(.p.º~.~;r;. ..P.J~.~~... ..~J~.C?. ..~.ª!.'J~.~ry.. ~.~ .º9~.~.~ ~Jç...µ.~.~~...~.~.. ....... .... power plant. The location of the water source to which the water right herein granted shall appertain is.J~9............... drilled wells in a parcel of property encompassing protracted NE 1/4 of SE 14/ and ~,~.. .~/~...~.f.. ~.~... ~.I..~...~. f....~ ~.~~....~ Z.....I ~.. .J~~".. .~.~...~.º~,... ~~~~:r;.~.. ~~~!~~J~~ ~............. ............ ................. ....... ....... and the rules and regulations promulgated thereunder, hereby grants to...ç.ñ.µga.çJl..E.t~.ç~.ri.ç.................~ ............. .A~.~.n.,..... In.<<; ~u... ~.9.~.. .~~J ~.,.. .AJ1çþ'ç?:~·.?g.ç A.. .Al~.~~.~.... .Q~.~Ql................. ..................................................... ..... ICnøw 1\11 iIIrn IIg œ~røf 'rrørntø that the State of Alaska, pursuant to A.S. 46.15, as amended Certificate No..... .743....... ....... ........ CERTIFICATE OF APPROPRIATION OF WATER I!!":, 5Ø1.~ of~· Z ~~l:~±~.~¿;~~,~y,-· q )~.. . ,.,.'..' ,.. ~ ...,., "'f_f,.~."4f: ",-..,.o;':~~J -~ ...