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Home My WebLink AboutERIO 002• • INDEX Enhanced Recovery Injection Order #2 Redoubt#6 1. June 14, 2004 Forest Oils Application for Redoubt Unit Enhanced Recovery Pilot Project 2. June 25, 2004 Notice of Hearing, Affidavit of publication, e-mail Distribution list, bulk mailing 3. June 29, 2004 Forest Oils follow up information for the Enhanced Recovery Pilot Project Confidential 4. May 6, 2005 Forest Oil's request for authorization to inject alternative fluids into Redoubt 6 enhanced recovery well and information of fluid compatibility and missing ratios (background information for the ERO2.001) 5. November 5, 2005 Request to inject non-hazardous fluids for Class II enhanced oil recovery in the Redoubt Unit (ERO 2.001) 6. June 20, 2005 Forest Oil Corporation's request to include deck drainage in Administrative Approval ERO2.001 (ERO 2.OOlA) 7. August 24, 2005 Memo to File re: Sampling Requirements per ERO 2.001 A 8. June 30, 2006 Forest Oil's Annual Injection report 2005-2006 9. September 26, 2006 Ltr to Forest re: Annual Report for Pilot Enhanced Recovery Injection (Annual Report located in Field Files) 10. January 25, 2007 Request from Forest Oil to include West Foreland produced water in well 11. September 21, 2007 Forest Oil's request for 30 day extension of ERIO 2, which expires on September 30, 2007 12. March 9, 2009 Pacific Energy Resources, Ltd. Filing of Chapter 11 Restructuring Enhanced Recovery Injection Order #2 . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: THE APPLICATION OF FOREST ) Enhanced Recovery Injection Order No.2 OIL CORPORATION for an order ) authorizing a pilot waterflood pro- ) Redoubt Unit ject designed to test the potential for ) Hemlock Formation enhanced oil recovery in the Hem- ) Well RU-6 lock Formation, Redoubt Unit, Cook ) Inlet, Alaska ) August 26, 2004 IT APPEARING THAT: 1. By letter and application dated June 14th, 2004, Forest Oil Corporation, ("Forest"), Operator of the Redoubt Unit ("RU") requested an order from the Alaska Oil and Gas Conservation Commission ("Commission") to authorize pilot water injection into Well RU-6 for enhanced oil recovery under 20 AAC 25.402. 2. Pilot projects for enhanced recovery may also be administered under 20 AAC 25.450(b) where feasibility of a process has not been proved. 3. Notice of a public hearing was published in the Anchorage Daily News on June 25, 2004. 4. No comments, protests or request for public hearing were received during the protest period. 5. The Commission determined it had sufficient information as a basis for ruling, and a tentative public hearing was canceled. FINDINGS: 1. Operator: Forest Oil Corporation ("Forest") operates the Redoubt Shoal Undefmed Oil Pool in the Redoubt Unit, Cook Inlet, Alaska. 2. Proiect Location The surface location of Redoubt Unit Well No.6 ("RU-6") is 1,909 feet from the south line and 318 feet from the east line of Section 14, T7N, R14Wof the Seward Meridian. The bottomhole location is 1,137 feet from the north line and 1,518 feet from the east line of Section 19, T7N, and R13W of the Seward Meridian. The sur- face location of the well is located on Osprey Platform, which is approximately 1.5 miles southeast of West Foreland, offshore Cook Inlet. 3. Operators/Surface Owners Notification: Forest provided operators and surface owners within one-quarter mile of the proposed area with a copy of the application for injection. The only affected operator is Forest. Enhanced Recovery InjectiO.der No.2 August 26, 2004 e Page 2 The State of Alaska, Department of Natural Resources is the only affected surface owner. 4. Description of Operation: Current development of the field consists of five production wells in the Hemlock Formation. The Redoubt Unit ("RU") waterflood pilot project plan includes a single injector, Well RU-6. RU-6 is an oil producer that has cumulative production of 177,497 barrels of oil through May 2004. A pilot project of about 36 months duration is proposed with the following objectives: o Determine the injectivity into the Hemlock Formation. o Confirm that geological barriers will contain the injection fluid when injected at injection pressures above fracture gradient. o Evaluate injection influence on offset producers. Data gathered will include: o Injectivity in well RU-6. o Production and injection rates and pressure. o Rate and pressure response to injection in various wells. o Confmement of injected fluids. 5. Geologic Information: a. Injection will occur within RU-6 in the Hemlock Formation. The pool is being devel- oped under statewide regulations and has not been defined in vertical or regional space. b. The Hemlock Formation resulted from fluvial deposition in meandering, coalescing stream channels. It consists of interbedded fine to medium-grained sand and gravels, pebble conglomerates, dense silts and occasional thin coal beds. Core from RU-2 indi- cated a distal low energy depositional environment. There are six identified lithofacies within the Hemlock based on conventional core analysis in Well RU-2. Porosity is in- tergranular with well-cemented and competent rock. Clay volume ranges from 9-20% of rock volume and appears to be dispersed. Reservoir facies consist of pebble con- glomerate (porosity 7-13%), pebble-gravel sandstone (porosity 10-16%), medium to coarse grain sandstone (porosity 10-16%) and fine-grained sandstone (porosity 12- 14%). Permeability ranges from 0.1 to several hundred millidarcies throughout the reservoir facies. c. Non-reservoir facies consist of very fine-grained siltstone (porosity 1-4%) and gener- ally impermeable carbonaceous claystone and coals. d. The injection interval is will be from 15,130 to 15,890 feet measured depth in RU-6, the same intervals that produced oil. 6. Well Logs: The initial formation logs obtained while drilling RU-6 are on file with the Commis- SlOn. Enhanced Recovery InjectiO.der No.2 August 26, 2004 e Page 3 7. Mechanical Integrity and Well Design ofInjection Wells: Well RU-6 was permitted, drilled and then completed in accordance with statewide regulations. A cement bond log was run on well RU-6 that demonstrates good cement integrity between the Hemlock Formation and overlying Tyonek Formation. 8. Injection Rates. Pressures. Fracture Propagation The initial injection rate will be 2,500 to 3,000 barrels water per day ("BWPD") and may vary according to production from RU wells. The operator anticipates the injec- tion will exceed the withdrawals from the area of influence offsetting the injector. Pressure support is anticipated at RU-l, -7 and possibly -2. The injection pumps will be located at the onshore Kustatan Production Facility. To account for friction loss, the maximum injection pressure planned for the RU-6 pilot water flood is approximately 4800 psi. Forest plans to verify pressure loss when RU-6 is recompleted. The pilot water flood will be operated to prevent fracture of the confming zone or the Hemlock Formation. Regulation 20AAC 25.402 (b)(11) requires operation of the injection well at pressures less than that required to initiate or propa- gate fractures through confining zones. 9. Type of Fluid / Source Water Analvsis: Fluids requested for injection are filtered, produced Hemlock Formation water from RU wells 1,2, SA and 7. The produced water source is the Hemlock Formation; there- fore compatibility is not an issue. 10. Freshwater Exemption: Hemlock formation water analyses submitted with Forest's application averaged 11,060 mgll TDS for 6 separate samples. The Hemlock Formation is hydrocarbon bearing in the area of RU and produced water contaminated with oil and total dis- solved solids (TDS) has no potential as a source of drinking water. Both ofthese char- acteristics disqualify the Hemlock Formation at RU as a source of drinking water. No aquifer exemption is necessary. 11. Expected Increase in Hvdrocarbon Recovery Forest estimates primary recovery of oil would be about 6% of original oil in place or about 3 million barrels to the reservoir pressure bubble point of 1,490 psi, without any pressure maintenance process. The crude gravity is 26.5 degrees API and is under- saturated with a solution gas-oil ratio of 250 scf/STB oil. Preliminary studies indicate waterftood will increase recovery to greater than 20% assuming full field develop- ment. Data acquisition on injection response and recovery benefits is an objective of the pilot project. 12. Mechanical Condition of Adjacent Wells: Well RU-7 and exploration well Redoubt State 29690 #1 are within ~ mile of RU-6. Both wells were cemented satisfactorily to isolate hydrocarbons within the Hemlock and in the case of Redoubt State 29690 # 1, isolation plugs were satisfactorily placed to permanently confine any hydrocarbons to the Hemlock and abandon the well. Enhanced Recovery InjectiO.der No.2 August 26, 2004 e Page 4 CONCLUSIONS: 1. The application requirements of20 AAC 25.402 have been met. 2. 20 AAC 25.450 allows the Commission to approve pilot projects for enhanced recov- ery if the project will not result in an increased risk of fluid movement into freshwater sources. 3. Mechanical integrity of the well was demonstrated at completion and conformed to Commission regulations at that time. 4. Water injection is anticipated to significantly increase recovery. 5. Freshwater aquifer exemption for the Hemlock formation is not necessary. 6. Sufficient information has been provided to authorize pilot water injection into the Hemlock Formation to evaluate pressure maintenance and the enhanced oil recovery process, and to provide data to evaluate full field waterflood development. 7. Injection pressure will be less than fracture gradient of the confining zone. Forest in- tends to establish injection operation limits during the pilot project. 8. Reservoir and well surveillance coupled with regularly scheduled mechanical integ- rity tests will demonstrate appropriate performance of the enhanced oil recovery pro- ject and disclose anomalous performance. 9. An annual report will keep the Commission apprised of the pilot project's progress. NOW, THEREFORE, IT IS ORDERED THAT: The underground injection of fluids for evaluation of enhanced oil recovery is authorized, subject to the following rules and the statewide requirements under 20 AAC Chapter 25 to the extent not superseded by these rules. Rule 1 EXDiration Date This Order shall expire September 30, 2007 unless the Operator applies to extend the test, expand the pilot area up to a full field project, or abandon the pilot. Rule 2 Authorized Iniection Strata Strata common to the Hemlock Formation between 15,130 to 15,890 feet measured depth are authorized for injection for pressure support and enhanced oil recovery injection. Rule 3 Fluid Iniection Well Well RU-6 is the only well authorized for fluid injection during this pilot project. Well RU-6 bottomhole location is in Section 19, T7N, and R13W ofthe Seward Meridian. Rule 4 Authorized Fluids for Enhanced Recovery Produced water from the Hemlock Formation is the only authorized injection fluid. Enhanced Recovery Injectio.der No.2 August 26, 2004 e Page 5 Rule 5 Demonstration of Tubinw'Casine: Annulus Mechanical Intee:ritv The mechanical integrity of an injection well must be demonstrated before injection be- gins, 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 work- over affecting mechanical integrity. Unless an alternate means is approved by the Com- mission, 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. Rule 6 Pilot Proiect Surveillance Prior to initiating injection, a baseline temperature survey within RU-6 is required from above the Hemlock Formation to total depth of the well. Within 60 days after injection begins, a step rate test is required. The need for subsequent temperature or step rate tests shall depend on injection performance or notable performance anomalies. Information gathered from the pilot, including daily wellhead injection pressures and rates, results of injection surveys, shall be monitored and provided monthly to the Commission until the maximum surface pressure is determined by a step-rate test. In addition to reporting requirements of 20 AAC 25.432 (1) an annual progress report of pilot operations shall be submitted within 90 days of the project startup anniversary and annually thereafter. The progress report shall contain information regarding project pa- rameters including but not limited to: a. Reservoir V oidage balance within the project area. b. Analysis of pressure response and production response. c. Analysis of injection performance. d. Analysis of fluid containment surveys, step-rate tests or MIT's that would demonstrate confinement of injected fluids. e. Review of any specialized tests performed to gauge performance and results of the pi- lot project. Rule 7 Notification of Improper Class II Iniection Injection of fluids other than produced water from the Hemlock formation is considered improper Class II injection. Upon discovery of such an event, the operator must immedi- ately suspend injection, notify the Commission, and provide details of the operation. Ad- ditional notification requirements of any other State or Federal agency remain the opera- tor's responsibility. Rule 8 Well Intee:ritv Failure and Confinement Whenever any pressure communication, leakage or lack of injection zone isolation is indi- cated 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 ac- tion 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 Enhanced Recovery InjectiO.der No.2 August 26, 2004 e Page 6 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 in- jection wells indicating well integrity failure or lack of injection zone isolation. The Commission may suspend, revoke, or modify this authorization if injected fluids fail to be confined within the designated injection strata. Rule 9 Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administra- tively 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. DONE at Anchorage, Alaska and dated August 26, 2 Jo orman, Chairm 0kA Oil and Gas Conservation Commission ~mmiSSioner Alaska Oil and Gas Conservation Commission AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it Month file with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23rd day following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the lO-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by non- action of the Commission, the 30-day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., lOth day after the application for rehearing was filed). ERIO #2 . e Subject: ERIO #2 From: Jody Colombie <jodY__colornbie@adrrtin.state.ak.us> Date: Mon, 30 Aug 2004 14:39:52 -0800 To: undisclo'sed,..rcpipients:; " '., " " .BÇÇ:,'J~.obert EMìhtz <r()bert _ min~@law .state.ak. us>, Christine Hansen ."^ ""/:<::>.:; ,- ~.... .. .. ./. . .. <c.hanšen@iogcc.state.ok.us>, Terrie Hubble <hubbletI@bp.com>, SondraStewmaJi <Stewrp~D@BP.com>, Scott & Cammyiaylor <staylor@alaska.net>~ stänekj, <starie~··'.' ocal.com>, ecolaw <ecolaw@trustees.org>, roseragsdalê<'foserags4ale@gci.~et>, trmjr1 <trmjr "l.com>, jbriddle <jbriddle@marathonoil.com>, rockhill <ròckhill@aöga.org>j shaneg , , , <shailt~g@ey~rgreengas.'9om>, jd~lington <jdarlington@fòrestoitcom>, nelson' ' , , ,.. . y ~^"'<. .. ..,., :<:. . . ..". ~lson@petï:Ql~~news~com> ,cboddy <cboddy@usibelli.com>, Mark Dalt~m <mark.da1tòn@hclrinC:.éÓm>, Sh8.11l10n Donnelly <shannon.donn'eHy@con()çophillips:com>, "Mark P. Worcest~!ç::'<mark.p;wôrcester@conocophillips.com>, "Jerry C.,Dethlefs~t:: ",;,:' ,,: <jerry.Q~êthlefs@coriocophillips.com>, Bob <bob@inletkeeper.org>, wdy :<wdv@dnr,state.aJ.cµs>, tjr <tJÌ'@d.nr.state.ak.us>, bbritch <bbritch@alàska.net>, mjnelson <m jnelsôÌ1@purvihgêrtz.corrt;~ Charles O'Donnell <charles.o'donnell@veco.com>, "Randy L. Skillern" <SkilleRL@BP.com>, ¡'Jeanne Fi.Dickey"<DickeyJH@BP.com>, "Deborah J. Jones" <JonesD6@BP.com>, "Paul G. Hyatt" <hyattpg@BP;com>, "Steven R. Rossberg" <RossbeRS@BP.com>, Lois <lois@iríletkeeper.org>, "JosephF. Kirchner" <KirchnJF@BP.com>, Gordon Pospisil :spospìsG@BP.com>, "Francis S. Sommer" <SommerFS@BP.com>, Mikel Schultz <Mik¢I.Schultz@BP.com>, "NickW. Glover" <GloverNW@BP.com>, "Daryl J. Kleppin" <KleppiDE@BP.com>, "Janet D.Platt" <PlattJD@BP.com>, "Rosanne M. Jacobsen" ?~åêøbsRM@BP.com>, ddonkel <ddonkel@cfl.rr.com>, Collins Mount 5~óUins _mount@revenue.state.ak.us>,mckay <mckay@gci.net>, Barbara F Fullmer <barbar~tf;fullmer@coh()cophillips.com>, bocastwf <bocastwf@bp.com>, Charles Barker <barker@usgs.gov> , doug_schultze <doug_schultze@xtoenergy.com>, Hank Alf()rd ,.ç~:aJ..ford@exxonmobil.com>,Mark Kovac <yesnol@gci.net>, gsptòff <g~p:fo:ff@aurorapower.c011l>, Gregg Nady <gregg.nady@shell.com>, Fred Steece <fred:steece~state.sd;us>, rcrotty <rcrotty@ch2m.com>,jejones<jejones@aurorapower.com>, dapa <dapa@alaská.net>, jroderick <jroderick@gci.net>, eyancy <eyancy@seal-tite.net>, "James M. . Ruud" <james.m.ruud@conocophìl1ips.com>, Brit Lively <mapalaska@ak.net>,jah ',. ^'"y", ... ... ~4nr.state.ak.us>, KurtE Olson <kurt_olson@legis.state.ak.us>, buonoje <buönoje@bp:com>, Mark Hanley <mark _ hanley@anadarko.com>, loren Jeman <loren_leman@gov.state.ak.us>, Julie Houle <julie;;-.ll()ule@dnr.state.ak.us>, John W Katz <jwkatz@sso.org>, Suzan J Hill <suzan _ hill@dec:state.ak.us>, tablerk <tablerk@unoca1.com>, ,Brady <brady@aoga.org>, Brian aavelock<beh@dnr.st~,te.ak. us>,hpopp <bpopp@borough.kenai.ak.us>, Jim 'White <jimwhîté"@satx.n.e6ÏriS>,;,'John S. Haworth"·<john,s.haworth@exxonmobiLcom>, marty·····'·· <marty@rkihdustljaJ...com>, ghammons <ghammons@aoLcom>, rmclean . .. <nnclean@pobõx'.ålaska.net>, James Scherr <james.scherr@mms.gov>, mkm7200 <mþn7200@aoI.com>, Brian Gillespie <ifbmg@uaa.alaska.edu>, David L Boelens ~4,bpelens@aurorapower.com>, Todd Durkee <TDURKEE@KMG.com>, Gary Schultz <gary_schultz@dnr.state.ak.us>, Wayne Rancier <RANCIER@petro-canada.ca>, Bill Miller <Bill_Miller@xtoalaska.com>, Brandon Gagnon <bgagnon@brenalaw.com>, Paul Winslow <pmwinslow@,forestoiLcom>, Garry Catron <catrongr@bp.com>, Sharmaine Copeland <copelasv@bp.co~>, Suzanne Allexan <salIexan@helmenergy.com>, Kristin Dirks <kristin_dir~s~dnr.state.ak.us>, Kaynell Zeman <kjzeman@marathonOi1.com>, John Tower <John.Towër@eia.doe.gov>, Bill Fowler <Bill.Jowler@anadarko.COM>, Cynthia B Mciver lof2 8/30/2004 2:40 PM ERIO #2 . .. <:bren Jnciver@admin.state.ak.us> ~.,. h:. e Content-Type: application/msword ERI02.doc. Content-Encoding: base64 .., . . ". ,..... ."x"·:"· :/..::-:::. ...., ,'. 20f2 8/30/20042:40 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 e 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 3940 Arctic Blvd., Ste 300 Anchorage. AK 99503 Ciri Land Department PO Box 93330 Anchorage. AK 99503 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 . 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 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 1ki/ecL fir /of e ~1f~1fŒ (ID~ ~~~~[K(~ e ALASKA. 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 ERO 2.001A Re: The application from Forest Oil Corporation to inject non-hazardous fluids for Class II enhanced oil recovery in the Redoubt Unit, Redoubt Shoal Undefined Oil Pool, Cook Inlet, Alaska. Mr. Bob Elder HSE Manager Forest Oil Corporation 310 K Street Anchorage, AK 99501 Dear Mr. Elder: Forest Oil Corporation ("Forest") requested by letter dated November 5, 2004 authorization to inject non-hazardous fluids from several sources into Class II enhanced oil recovery ("EOR") wells in the Redoubt Shoal Undefined Oil Pool. The Commission may authorize the injection of fluid for EOR purposes if it is appropriate for enhanced recovery. The non-hazardous fluid sources are: treated sanitary waste, treated gray water from camp or platform facilities, produced water from the West McArthur River Unit, and storm water collected in secondary containment areas at the Kustatan and West McArthur River Unit Production Facilities. Forest contends addition of these fluids to EOR injection streams will provide beneficial use for oil recovery. Additional information regarding fluids compatibility and potential mixing ratios was requested by the Commission and provided by Forest by letter dated May 6,2005. An Administrative Approval, Enhanced Recovery Injection Order ("ERO") 2.001 was issued to Forest on June 13, 2005. By supplemental letter dated June 20, 2005 Forest also requested inclusion of deck drainage from the Osprey platform in the list of non- hazardous fluid sources eligible for EOR injection in the Redoubt Shoal Oil Pool. These fluids would normally be injected into the Class II disposal well (RU D-l). However, the option to mix waste fluids with produced water will not be possible because produced water will be injected as EOR fluid, there is only one injection manifold, and the relatively small volumes of waste that are generated by the sanitary waste treatment and storm water collection systems do not justify a separate manifold. ERO No.2 authorized injection of produced water from the Hemlock Formation into the Redoubt Shoal Undefined Oil Pool. Forest conducted tests that mixed proportional amounts of produced indigenous Redoubt Unit Hemlock produced water and the proposed wastewater streams (including deck drainage from the Osprey platform). ADMINISTRATIVE APPROV&RO 2.001 A July 14,2005 Page 2 of2 . Results showed no adverse precipitation occurred with either individual mixtures or a composite of all waters mixed together. The fluid streams will be blended with Redoubt Unit Hemlock Formation water and injected in proportions ranging from approximately 0.2% to 1% (0.002 - 0.01) of the expected total injection volume. The estimated maximum volume of the non-hazardous fluids injected per month would be approximately 4,650 barrels (195,000 gallons) assuming peak seasonal volumes. Forest provided the results of fluid compatibility studies that demonstrate the proposed fluid/ seawater mix would not be detrimental to fluids within the Redoubt Shoal Undefined Oil Pool. Treated waste used as a beneficial EaR fluid will reduce logistical problems of handling and disposing waste at the remote facilities operated by Forest. The Commission agrees with Forest's analysis and assessment that blending the small volumes of treated camp gray water, treated sewage waste water, storm water runoff, deck drainage and other Hemlock Formation waters prior to injection is unlikely to impact the EaR efficiency negatively. The Commission further fmds that the blended EOR fluids will not promote waste, will not jeopardize correlative rights, and will not contribute to the potential for fluid movement outside of the injection zone. Therefore, in accordance with the provisions of ERO No.2, Rule 9, the Commission approves the injection of the following non-hazardous fluids by blending with produced water from the Redoubt Shoal Undefined Oil Pool (Hemlock formation): 1) treated sanitary waste, 2) treated gray water from platform and camp living facilities, 3) produced Hemlock Formation water from the West McArthur River Oil Pool, 4) storm water from secondary containment areas at the Kustatan and West McArthur Production Facilities, and 5) deck drainage from the Osprey platform. As a condition of this approval, Forest must continue to collect and analyze representative samples of the mixed fluid stream at Redoubt Unit injection manifold to demonstrate its non-hazardous characteristics and its continued suitability for EaR injection. Analytical results shall be retained according to the provisions of 20 AAC 25.310. Volumes shall be incorporated into the monthly (Form 10-406) and annual (Form 10-413) injection reports. s and replaces the original administrative approval ERa 2.001 005. ommlssloner Cathy P Foerster Commissioner 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 Reqycling Inc. PO Box 58055 Fairbanks, AK 99711 e 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 e 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, 10 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 ERO 2.001A Redoubt Unit (Cook Inlet) e e Subject: ERO 2..Q01A Redoubt Unit (Cook Inlet) From: Jody Colombie <jody_colombie@admin.state.akus> Date: Thu, 14Ju12005 15:29:16-0800 To: undisclosed-recipients:; BCC: Cynthia B Mciver <bren_mciver@admin.state.ak.us>, Robert E Mintz <robert_mintz@law.state.ak.us>, Christine Hansen <c.hansen@iogcc.state.okus>, Terrie Hubble <hubbletl@bp.com>, Sondra Stewman <StewmaSD@BP.com>, Scott & Cammy Taylor <staylor@alaska.net>, stanekj <stanekj@unocal.com>, ecolaw <ecolaw@trustees.org>, roseragsdale <roseragsdale@gcLnet>, trmjr 1 <trmjr l@aol.com>, jbriddle <jbriddle@marathonoil.com>, shaneg <shaneg@evergreengas.com>, j darlington <j darlington@forestoil.com>, nelson <knelson@petroleumnews.com>, cboddy <cboddy@usibelli.com>, Mark Dalton <markdalton@hdrinc.com>, Shannon Donnelly <shannon.donnelly@conocophillips.com>, "Mark P. Worcester" <mark.p.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@BP.com>, Mikel Schultz <Mikel.Schultz@BP.com>, "Nick W. Glover" <GloverNW@BP.com>, "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>, bocastwf <bocastwf@bp.com>, Charles Barker <barker@usgs.gov>, doug_schultze <doug_schultze@xtoenergy.com>, Hank Alford <hank.alford@exxonmobil.com>, Mark Kovac <yesno l@gci.net>, gspfoff <gspfoff@aurorapower.com>, Gregg Nady <gregg.nady@shell.com>, Fred Steece <fred.steece@state.sd.us>, rcrotty <rcrotty@ch2m.com>, j ej 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>, Kurt E Olson <kurt_olson@legis.state.ak.us>, buonoje <buonoje@bp.com>, Mark Hanley <IÌ:1ark_hanley@anadarko.com>, loren_leman <lorenJeman@gov.state.ak.us>, Julie Houle <julie_houle@dnr.state.ak.us>, John W Katz <j~katz@sso.org>, Suzan J Hill <suzan _ hill@dec.state.ak.us>, tablerk <tablerk@unocal.com>, Brady <brady@aoga.org>, Brian Havelock <beh@dnr.state.ak.us>, bpopp <bpopp@borough.kenaLakus>, 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>, Bill Miller <Bill_ Miller@xtoalaska.com>, Brandon Gagnon <bgagnon@brenalaw.com>, Paul Winslow <pmwinslow@forestoil.com>, Garry Catron <catrongr@bp.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>, Vaughn Swartz <vaughn.swartz@rbccm.com>, Scott Cranswick <scott.cranswick@mms.gov>, Brad McKim <mckimbs@BP.com>, Steve Lambe <lambes@unocal.com>,jack newell <jack.newell@acsalaska.net>, James Scherr lof2 7/14/20053:29 PM ERG 2.001A Redoubt Unit (Cook Inlet) e . <james_scherr@yahoo.com>, david roby <David.Roby@mms.gov>, Tim Lawlor <Tim_Lawlor@ak.blm.gov>, Lynnda Kahn <Lynnda_Kahn@fws.gov>, Jerry Dethlefs <Jerry.C.Dethlefs@conocophillips.com>, Jerry Dethlefs <n1617@conocophillips.com>, crockett@aoga.org, Tamera Sheffield <sheffield@aoga.org>, Jon Goltz <Jon.Goltz@conocophillips.com>, Roger Belman <roger.belman@conocophillips.com>, Mindy <mlewis@brenalaw.com>, Harry Lampert <harry.lampert@honeywell.com>, Kari Moriarty <moriarty@aoga.org>, Patty Alfaro <palfaro@yahoo.com>, Jeff <smetankaj@unocal.com>, Todd Kratz <ToddKratz@chevron.com> . Content-Type: application/pdf . ER02.001A.pdf Content-Encoding: base64 20f2 7/l4/2005 3:29 PM . ~1f~1fæ (ID~ ~~~~[K(~ . AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. P" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROV AL ERO 2.001 Re: The application from Forest Oil Corporation to inject non-hazardous fluids for Class II enhanced oil recovery in the Redoubt Unit, Redoubt Shoal Undefined Oil Pool, Cook Inlet, Alaska. Mr. Bob Elder HSE Manager Forest Oil Corporation 310 K Street Anchorage, AK 99501 Dear Mr. Elder: Forest Oil Corporation ("Forest") has requested by letter dated November 5, 2004 authorization to inject non-hazardous fluids from several sources into Class II enhanced oil recovery ("EaR") wells in the Redoubt Shoal Undefined Oil Pool. The non-hazardous fluid sources are: treated sanitary waste, gray water from camp or platform facilities, produced water from the West McArthur River Unit, and storm water collected in secondary containment areas at the Kustatan and West McArthur River Unit Production Facilities. Forest contends addition of these fluids to EaR injection streams will provide beneficial use for oil recovery. These fluids would normally be injected into the Class II disposal well (RU D-1), however, the option to mix waste fluids with produced water will not be possible because produced water will be injected as EaR fluid, there is only one injection manifold, and the relatively small volumes of waste that are generated by the sanitary waste treatment and storm water collection systems do not justify a separate manifold. The Commission may authorize the injection of fluid for EaR purposes if it is appropriate for enhanced recovery. Additional information regarding fluids compatibility and potential mixing ratios was requested by the Commission and provided by Forest by letter dated May 6, 2005. Enhanced Recovery Order No. 2 authorized injection of produced water from the Hemlock Formation into the Redoubt Shoal Undefined Oil Pool. Forest conducted tests that mixed proportional amounts of produced indigenous Redoubt Unit Hemlock produced water and the proposed wastewater steams. Results showed no adverse precipitation occurred either with individual mixtures or a composite of all waters mixed together. The fluid streams will be blended with Redoubt Unit Hemlock Formation water and injected in proportions ranging from approximately 0.2% to 1 % (0.002 - 0.01) of the expected total injection volume. The estimated ADMINISTRATIVE APPRO. ERa 2.001 June 13,2005 Page 2 of2 e maximum volume of the non-hazardous fluids injected per month would be approximately 4,650 barrels (195,000 gallons) assuming peak seasonal volumes. Forest provided the results of fluid compatibility studies that demonstrate the proposed fluid/seawater mix would not be detrimental to fluids within the Redoubt Shoal Undefined Oil Pool. Treated waste used as a beneficial EaR fluid will reduce logistical problems of handling and disposing waste at the remote facilities operated by Forest. The Commission agrees with Forest's analysis and assessment that blending the small volumes of treated camp gray water, treated sewage waste water, storm water runoff, and other Hemlock Formation waters prior to injection is unlikely to impact the EaR efficiency negatively. The Commission further finds that the blended EaR fluids will not promote waste, jeopardize correlative rights, and will not contribute to the potential for fluid movement outside of the injection zone. Therefore, in accordance with the provisions of Enhanced Recovery Order No.2, Rule 4, the Commission approves the injection of the following non-hazardous fluids by blending with existing Class II fluids used for EaR: treated sanitary waste (formerly approved for Class II disposal), treated gray water from platform and camp living facilities, produced Hemlock Formation water from the West McArthur River Oil Pool, and storm water from secondary containment areas at Kustatan and from the West McArthur Production Facility in addition to the fluids approved by ERO No.2. As a condition of this approval, Forest must continue to collect and analyze representative samples of the mixed fluid stream at Redoubt Unit injection manifold to demonstrate its nonhazardous characteristics and its continued suitability for EaR injection. Analytical results shall be retained according to the provisions of 20 AAC 25.310. Volumes shall be incorporated into the monthly (Form 10-406) and annual (Form 10-413) injection reports. o ge, Alaska and dated June 13,2005. Daniel T. Seamount Commissioner ~~ athy . Foerster Commissioner 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 e 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 e 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 Amended Orders Cook Inlet and Admin Approval Redoubt e e Subject: Amended Orders Cook Inlet and Admin Approval Redoubt From: Jody Colombie <jody_colombie@adrnin.state.ak.us> Date: Wed, 15 Jun 2005 11 :30:50 -0800 TÔ:Ûhdisêlosed2recipìènts: ; BCC: Robert E Mintz <robert_mintz@law.state. <c.hansen@iogcc.state.ok.us>, Terrie Hubble <hubbletl@bp.com>, Sondra Stewman <StewmaSD@BP.com>, Scott & Cammy Taylor <staylor@alaska.net>, stanekj <stanekj@unocal.com>, ecolaw <ecolaw@trustees.org>, roseragsdale <roseragsdale@gci.net>, trmjr1 <trmjr1@aol.com>, jbriddle <jbriddle@marathonoil.com>, shaneg <shaneg@evergreengas.com>, jdarlington <jdarlington@forestoil.com>, nelson <knelson@petroleumnews.com>, cboddy <cboddy@usibelli.com>, Mark Dalton <mark.dalton@hdrinc.com>, Shannon Donnelly <shannon.donnelly@conocophillips.com>, "Mark P . Worcester" <mark.p.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>, "Debo.t'~J.Jo~~~"<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@BP.com>, Mikel Schultz <Mikel.Schultz@BP.com>, "Nick W. Glover" <GloverNW@BP.com>, "Daryl J. Kleppin" <KleppiDE@BP.com>, "Janet D. Platt" <Plått~D@BP.com>, "Rosanne M. Jacobsen" <JacobsRM@BP.com>, ddonkel <ddonkel@cfl.rr.com>, µ1ckét.Y<mckay@gci.net>, Barbara F Fullmer <barbara.f.fullmer@conocophillips.com>, bocastwf <bocåstwf@bp.com>, Charles Barker <barker@usgs.gov>, doug_schultze <doug_schultze@xtoenergy.com>, Hank Alford <hank.alford@exxonmobil.com>, Mark Kovac <yesno 1 @gci.net>, gspfoff <gspfoff@aurorapower.com>, Gregg Nady <gregg.nady@shell.com>, Freq Steece <fred.steece@state.sd.us>, rcrotty <rcrotty@ch2m.com>, jejones <jejones@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>, Kurt E Olson <kurt_olson@legis.state.ak.us>, buonoje <buonoje@bp.com>, Mark Hanley <mark_hanley@anadarko.com>, loren_leman <loren_leman@gov.state.ak.us>, Julie Houle <julie_houle@dnr.state.ak.us>, John W Katz <jwkatz@sso.org>, Suzan J Hill <suzan _ hill@dec.state.ak.us>, tablerk <tablerk@unocal.com>, Brady <brady@aoga.org>, Brian Havelock <beh@dnr.state.ak.us>, bpopp <bpopp@borough.kenai.ak.us>, 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 <itbmg@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>, Bill Miller <Bill_Miller@xtoalaska.com>, Brandon Gagnon <bgagnon@brenalaw.com>, Paul Winslow <pmwinslow@forestoil.com>, Garry Catron <catrongr@bp.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> , Vaughn Swartz <vaughn.swartz@rbccm.com>, Scott Cranswick <scott.cranswick@mms.gov>, Brad McKim <mckimbs@BP.com>, Steve Lambe <lambes@unocal.com>,jack newell <jack.newell@acsalaska.net>, James Scherr <james_scherr@yahoo.com>, david roby <David.Roby@mms.gov>, Tim Lawlor lof2 6/15/200511:31 AM Amended Orders Cook Inlet and Admin Approval Redoubt e e <Tim_Lawlor@ák.blm.gov>, Lynnda Kahn <Lynnda__Kahñ@fws:gov>,JerryDetHlefs <Jerry.C.Dethlefs@conocophillips.com>, Jerry Dethlefs <n1617@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>, Harry Lampert <harry.lampert@honeywell.com>, Kari Moriarty <moriarty@aoga.org>, Patty Alfaro <palfaro@yahoo.com>, Cynthia B Mciver <bren _ mciver@admin.state.ak.us> Content-Type: application/pdf ER02.001.pdf Content-Encoding: base64 Content-Type: application/pdf DI030A.pdf Content-Encoding: base64 Content-Type: application/pdf DI028A.pdf Content-Encoding: base64 20f2 6/15/2005 11 :31 AM . ~1f~1fŒ (ID~ ~~~~[K(~ . AltASIiA. OIL AND GAS CONSERVATION COMMISSION SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL ERO 2.002 Re: The application from Forest Oil Corporation to inject non-hazardous fluids for Class II enhanced oil recovery in the Redoubt Unit, Redoubt Shoal Undefmed Oil Pool, Cook Inlet, Alaska. Mr. Paul M. Winslow Reservoir Engineer Forest Oil Corporation 310 K Street, Suite 700 Anchorage, AK 99501 Dear Mr. Winslow: Forest Oil Corporation ("Forest") requested by letter dated January 25, 2007 approval to commingle West Foreland produced water with non-hazardous fluids currently authorized for injection into the Hemlock formation of the Redoubt Shoal Undefined Oil Pool. Enhanced Recovery Injection Order ("ERa") 2.001A authorizes a pilot waterflood involving injection well Redoubt Unit 6A and lists the fluids currently permitted for injection. Produced water from Redoubt Unit and West MacArthur River Unit ("WMRU") development wells is currently authorized for waterflood injection in Redoubt Unit 6A. West Foreland produced water is currently not listed in ERa 2.001A. Forest's request to include produced water from the West Foreland field is approved. The Commission reviewed results of a fluid compatibility study attached to Forest's request. The study results included analyzing mixed samples of the produced water streams to be injected into the Hemlock formation for total suspended solids and turbidity. Results indicate that addition of the small volume of West Foreland produced water is insufficient to adversely impact the Hemlock reservoir. Forest indicates oil production from the Redoubt Unit has been enhanced because of the pilot waterflood. However, recent mechanical problems in one Redoubt Unit production well have significantly reduced the volume of produced water available for injection. Completion of a 4- inch transmission line from the WMRU in October 2006 has made it possible to transfer produced water to the Redoubt Unit to sustain the waterflood. To date WMRU produced water has been diverted to Class II disposal well WMRU #4D because produced water from the WMRU and West Foreland fields are commingled before injection. ADMINISTRATIVE APPR.L ERO 2.002 January 30, 2007 Page 2 of2 . The Commission finds that the addition of West Foreland produced water to the currently authorized EaR injection fluids in Redoubt Unit Well 6A will not promote waste, will not jeopardize correlative rights, and will not contribute to the potential for fluid movement outside of the injection zone. Therefore, in accordance with the provisions of ERO No.2, Rule 9, the Commission approves the injection of the following non-hazardous fluids by blending with produced water from the Redoubt Shoal Undefined Oil Pool (Hemlock formation): 1) treated sanitary waste, 2) treated gray water from platform and camp living facilities, 3) produced Hemlock Formation water from the West McArthur River Oil Pool, 4) produced water from gas wells at the West Foreland field, 5) storm water from secondary containment areas at the Kustatan and West McArthur Production Facilities, and 6) deck drainage from the Osprey platform. As a condition of this approval, Forest must continue to collect and analyze representative samples of the mixed fluid stream at Redoubt Unit injection manifold to demonstrate its non-hazardous characteristics and its continued suitability for EaR injection. Analytical results shall be retained according to the provisions of 20 AAC 25.310. Volumes shall be incorporated into the monthly (Form 10-406) and annual (Form 10-413) injection reports. This approval amends and replaces the original administrative approval ERa 2.001A dated July 14,2005. age, Alaska and dated January 30, 2007. Various Administrative Approvals . . Subject: Various Administrative Approvals From: Jody Colombie <jody_colombie@admin.state.ak.us> Date: Wed, 31 Jan 2007 10:05:32 -0900 To: undisclosed-recipients:; BCC: Christine Hansen <c.hansen@iogcc.state.okus>, Terrie Hubble <hubbletl@bp.com>, Sondra Stewman <StewmaSD@BP.com>, stanekj <stanekj@unocal.com>, ecolaw <ecolaw@trustees.org>, trmjr 1 <trmjr 1 @aol.com>, jdarlington <jdarlington@forestoil.com>, nelson <knelson@petroleumnews.com>, cboddy <cboddy@usibelli.com>, Mark Dalton <markdalton@hdrinc.com>, Shannon Donnelly <shannon.donnelly@conocophillips.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@BP.com>, Mikel Schultz <Mikel.Schultz@BP.com>, "Nick W. Glover" <GloverNW@BP.com>, "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 <yesn01@gci.net>, gspfoff <gspfoff@aurorapower.com>, Gregg Nady <gregg.nady@shell.com>, Fred Steece <fred.steece@state.sd.us>, rcrotty <rcrotty@ch2m.com>, jejones <jejones@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>, Julie Houle <julie_houle@dnr.state.ak.us>, John W Katz <jwkatz@alaskadc.org>, tablerk <tablerk@unocal.com>, Brady <brady@aoga.org>, Brian Havelock <beh@dnr.state.ak.us>, bpopp <bpopp@borough.kenai.ak.us>, 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>, jack newell <jacknewell@acsalaska.net>, James Scherr <james.scherr@mms.gov>, n1617@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>, Gary Rogers <gary_rogers@revenue.state.ak.us>, Arthur Copoulos <Arthur_Copoulos@dnr.state.ak.us>, Ken <krlyons@suddenlink.net>, Steve Lambert <salambert@unocal.com>, Joe Nicks <news@radiokenai.com>, Jerry McCutcheon <susitnahydronow@yahoo.com>, Bill Walker <bill-wwa@ak.net>, Iris Matthews <Iris_Matthews@legis.state.ak.us>, Paul Decker <paul_decker@dnr.state.ak.us>, Aleutians East Borough <admin@aleutianseast.org>, Marquerite kremer 100 1/31/2007 10:06 AM Various Administrative Approvals . . <marguerite_kremer@dnr.state.ak.us>, Mike Mason <mike@kbbi.org>, Garland Robinson <gbrobinson@marathonoil.com>, Cammy Taylor <Camîlle_Taylor@law.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 <jim _regg@admin.state.ak.us>, Catherine P Foerster <cathy _foerster@admin.state.ak.us>, Bob <Bob@fairweather.com>, gregory micallef <micallef@clearwire.net>, Laura Silliphant <laura _ silliphant@dnr.state.ak.us>, David Steingreaber <david.e.steingreaber@exxonmobi1.com>, akpratts@acsalaska.net, Robert Campbell <Robert.Campbell@reuters.com>, Steve Moothart <steve _ moothart@dnr.state.ak.us>, Anna Rat! <anna.raff@dowjones.com>, Cliff Posey <c1iff@posey.org>, Paul Bloom <paul_ bloom@ml.com>, Meghan Powell <Meghan.Powell@asrcenergy.com>, Temple Davidson <temple_davidson@dnr.state.ak.us>, Walter Featherly <WFeatherly@PattonBoggs.com>, Tricia Waggoner <twaggoner@nrginc.com>, Mike Stockinger <Mike.Stockinger@anadarko.com>, John Spain <jps@stateside.com>, Cody Rice <Cody _ Rice@legis.state.ak.us>, John Garing <garingJD@bp.com>, Harry Engel <engelhr@bp.com>, Jim Winegamer <jimwinegamer@brooksrangepetro.com>, Matt Rader <matt_rader@dnr.state.ak.us>, David Risser <dmrisser@marathonoi1.com>, carol smyth <carol.smyth@shell.com>, Arthur C Saltmarsh <art_saltmarsh@admin.state.ak.us>, Cynthia B Mciver <bren_mciver@admin.state.ak.us> Jody Colombie <iody colombie(a¿admin.state.ak.us> Special Staff Assistant Alaska Oil and Gas Conservation Commission Department of Administration Content-Type: application/pdf aio3-14.pdf Content-Encoding: base64 Content-Type: application/pdf aio4e-14.pdf Content-Encoding: base64 Content-Type: application/pdf aio4e-13.pdf Content-Encoding: base64 Content-Type: application/pdf aio4e-12.pdf Content-Encoding: base64 Content-Type: application/pdf aiol-2 cancelled.pdf Content-Encoding: base64 200 1/31/200710:06 AM Various Administrative Approvals 30f3 . . . Content-Type: application/pdf eno2-2.pdf . Content-Encodmg: base64 Content-Type: application/pdf aio4e-15.pdf . Content-Encodmg: base64 1/31/2007 10:06 AM . 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, WA 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 Bemie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 ,\ ~ \ . ~1r~1rŒ (ffi~ ~~~~æ/A\ . AI1ASIiA. OIL AND GAS CONSERVA.TION COMMISSION 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL ERlO 2.003 SARAH PALIN, GOVERNOR Mr. Paul M. Winslow Reservoir Engineer Forest Oil Corporation 310 K Street, Suite 700 Anchorage, AK 99501 RE: Temporary Extension to Enhanced Recovery Injection Order 2 Dear Mr. Winslow: In accordance with Rule 9 of Enhanced Recovery Injection Order ("ERIO") 2, the Alaska Oil and Gas Conservation Commission ("Commission") hereby grants Forest Oil Corporation ("Forest") a temporary extension to the expiration date of this order from September 30, 2007, to October 31,2007. On July 30, 2007, Forest applied to the Commission to convert ERIO 2 into a full-field area injection order or, alternatively, to extend the expiration date ofERIO 2 for 12 months. On August 6 and 7, 2007, the Commission asked Forest to provide additional information. The additional information was provided on August 22, 2007. On September 12, 2007, the Commission asked for further information regarding well integrity. This information was provided by Forest on September 14, 2007. The Commission is continuing its review of Forest's July 30, 2007, application and the supplemental information. The Commission anticipates completing this review prior to the September 30, 2007, expiration date in Rule 1 of ERIO 2. Nonetheless, to ensure there are no disruptions in the ongoing injection operations authorized under ERIO 2 (i.e., should the review not be completed in time), the Commission is granting the 31-day extension to the expiration date of ERIO 2. Forest must continue to comply with all the other provisions of ERIO 2 and the subsequent administrative approvals. As provided in AS 31.05.080, within 20 days after written notice of this 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. A request for reconsideration is timely if it is received by 4:30 p.m. on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a state holiday or weekend. A person may not appeal this decision to Superior Court unless reconsideration has been requested. . . Page 1 of 1 Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Friday, September 21, 2007 10:27 AM Subject: erior2-003 Cook Inlet Attachments: erio2-003.pdf BCC:'Alan Birnbaum <""Alan J Birnbaum "> (alan.birnbaum@alaska.gov)'; 'Aleutians East Borough'; 'Anna Raff; 'Arthur C Saltmarsh'; 'Arthur Copoulos'; 'Barbara F Fullmer'; 'bbritch'; 'Bill Fowler'; 'Bill Walker'; 'Brad McKim'; 'Brandon Gagnon'; 'Brian Gillespie'; 'Brian Havelock'; 'Brit Lively'; 'Bruce Webb'; 'buonoje'; 'Cammy Taylor'; 'carol smyth'; 'Cary Carrigan'; 'Catherine P Foerster'; 'Charles O'Donnell'; 'Chris Brecht'; 'Chris Gay'; 'Christian Gou-Leonhardt'; 'Christine Hansen'; 'Cliff Posey'; 'Cody Rice'; 'Dan Bross'; 'dapa'; 'Daryl 1. Kleppin'; 'David L Boelens'; 'David Steingreaber'; 'ddonkel'; 'Deanna Gamble'; 'Deborah 1. Jones'; 'doug_schultze'; 'Evan Harness'; 'eyancy'; 'Francis S. Sommer'; 'Fred Steece'; 'Garland Robinson'; 'Gary Laughlin'; 'Gary Rogers'; 'Gary Schultz'; 'ghammons'; 'Gordon Pospisil'; 'Gregg Nady'; 'gregory micallef; 'gspfoff; 'Hank Alford'; 'Harry Engel'; 'jah'; 'James B Regg'; 'James M. Ruud'; 'James Scherr'; 'Janet D. Platt'; 'jdarlington'; 'jejones'; 'Jerry McCutcheon'; 'Jim White'; 'Jim Winegarner'; 'Joe Nicks'; 'John Garing'; 'John S. Haworth'; 'John Spain'; 'John Tower'; 'John W Katz'; 'Jon Goltz'; 'Julie Houle'; 'Kari Moriarty'; 'Kaynell Zeman'; 'Keith Wiles'; knelson@petroleumnews.com; 'Kristin Dirks'; 'Laura Silliphant'; 'Lois'; 'Lynnda Kahn'; 'mail=akpratts@acsalaska.net'; 'mail=crockett@aoga.org'; 'mail=foms@mtaonline.net'; 'Mark Dalton'; 'Mark Hanley'; 'Mark Kovac'; 'Mark P. Worcester'; 'Marquerite kremer'; 'marty'; 'Matt Rader'; 'mckay'; 'Meghan Powell'; 'Mike Bill'; 'Mike Mason'; 'Mikel Schultz'; 'Mindy Lewis'; 'MJ Loveland'; 'mjnelson'; 'mkm7200'; 'Nick W. Glover'; 'Patty Alfaro'; 'Paul Decker'; 'Paul Winslow'; 'Randall Kanady'; 'Randy L. Skillern'; 'rcrotty'; 'rmc1ean'; 'Robert Campbell'; 'Roger Belman'; 'Rosanne M. Jacobsen'; 'Rudy Brueggeman'; 'Scott Cranswick'; 'Shannon Donnelly'; 'Sharmaine Copeland'; 'Sondra Stewman'; 'Sonja Frankllin'; 'stanekj'; 'Stephen F Davies'; 'Steve Lambert'; 'Steve Moothart'; 'Steven R. Rossberg'; 'tablerk'; 'Tamera Sheffield'; 'Temple Davidson'; 'Terrie Hubble'; 'Thomas E Maunder'; 'Tim Lawlor'; 'Todd Durkee'; 'Tricia Waggoner'; 'trmjrl'; 'Walter Featherly'; 'Walter Quay'; 'Wayne Rancier' Attachments: eri02-003. pdf; 9/21/2007 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 Baker Oil Tools 4730 Business Park Blvd., #44 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 . . David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 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 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, WA 98119-3960 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Schlumberger Drilling and Measurements 2525 Gambell Street #400 Anchorage, AK 99503 Ciri Land Department PO Box 93330 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 Darwin Waldsmith PO Box 39309 Ninilchick, AK 99639 James Gibbs PO Box 1597 Soldotna, AK 99669 Penny Vadla 399 West Riverview Avenue Soldotna, AK 99669-7714 Richard Wagner PO Box 60868 Fairbanks, AK 99706 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 North Slope Borough PO Box 69 Barrow, AK 99723 \ lei/ \01 :~~ q J\ • d 0 ~ ~ d SARAH PALIN, GOVERNOR t~Lt'•a7~ OIL ~ ~ 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQATI011T COMr-II55IO1~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL ERIO 2.004 Mr. Paul M. Winslow Reservoir Engineer Forest Oil Corporation 310 K Street, Suite 700 Anchorage, AK 99501 RE: Temporary Extension to Enhanced Recovery Injection Order 2 Dear Mr. Winslow: In accordance with Rule 9 of Enhanced Recovery Injection Order ("ERIO") 2, the Alaska Oil and Gas Conservation Commission ("Commission") hereby grants Forest Oil Corporation ("Forest") a temporary extension to the expiration date of this order from October 31, 2007, to November 30, 2007. On July 30, 2007, Forest applied to the Commission to convert ERIO 2 into a full-field area injection order or, alternatively, to extend the expiration date of ERIO 2 for 12 months. On August 6 and 7, 2007, the Commission asked Forest to provide additional information. The additional information was provided on August 22, 2007. On September 12, 2007, the Commission asked for further information regarding well integrity. This information was provided by Forest on September 14, 2007. The Commission is continuing its review of Forest's July 30, 2007, application and the supplemental information. The .Commission anticipates completing this review prior to the October 31, 2007, expiration date established by administrative approval ERIO 2.003. Nonetheless, to ensure there are no disruptions in the ongoing injection operations authorized under ERIO 2 (i. e., should the review not be completed in time), the Commission is granting a 30-day extension to the expiration date of ERIO 2. Forest must continue to comply with all the other provisions of ERIO 2 and the subsequent administrative approvals. As provided in AS 31.05.080, within 20 days after written notice of this 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. A request for reconsideration is timely if it is received by 4:30 p.m. on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a state holiday or weekend. A person may not appeal this decision to Superior Court unless reconsideration has been requested.. and dated October 31, 2007. c Cathy P. oerster Commissioner ,~ • Page 1 of 1 Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Wednesday, October 31, 2007 11:26 AM Subject: ERIO 2-004 Redoubt Unit Attachments: erio2-004.pdf BCC:McIver, C (DOA); 'Alan Birnbaum <""Alan J Birnbaum "> (alan.birnbaum@alaska.gov)'; 'Aleutians East Borough'; 'Anna Raff; Arion, Teri A (DNR); 'Arthur C Saltmarsh'; 'Arthur Copoulos ; 'Barbara F Fullmer'; 'bbritch'; 'Bill Fowler'; 'Bill Walker'; 'Brad McKim'; 'Brandon Gagnon'; 'Brian Gillespie'; 'Brian- Havelock'; 'Brit Lively'; 'Bruce Webb'; 'buonoje'; 'Cammy Taylor'; 'carol smyth'; 'Cary Carrigan'; 'Catherine P Foerster'; 'Charles O'Donnell'; 'Chris Brecht'; 'Chris Gay'; 'Christian Gou- Leonhardt'; 'Cliff Posey'; 'Cody Rice'; 'Dan Bross'; 'dapa ; 'Daryl J. Kleppin'; 'David L Boelens'; 'David Steingreaber'; 'ddonkel ; 'Deanna Gamble'; 'Deborah J. Jones'; 'doug_schultze'; 'Evan Harness'; 'eyancy'; 'Francis S. Sommer'; 'Fred Steece'; 'Garland Robinson'; 'Gary Laughlin'; 'Gary Rogers'; 'Gary Schultz'; 'ghammons'; 'Gordon Pospisil'; 'Gregg Nady'; 'gregory micallef ; 'gspfoff; 'Hank Alford'; 'Harry Engel'; 'jah'; 'James B Regg'; 'James M. Ruud'; 'James Scherr'; 'Janet D. Platt'; 'jdarlington'; 'jejones'; 'Jerry McCutcheon ; '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; 'Kristin Dirks'; 'Laura Silliphant'; 'Lois'; 'Lynnda Kahn'; 'mail=akpratts@acsalaska.net'; 'mail=Crockett@aoga.org'; 'mail=fours@mtaonline.net'; 'Mark Dalton'; 'Mark Hanley'; 'Mark Kovac'; 'Mark P. Worcester'; 'Marguerite kremer'; 'marty'r 'Matt Rader'; 'mckay'; 'Meghan Powell'; 'Mike Bill'; 'Mike Mason'; 'Mikel Schultz'; 'Mindy Lewis'; 'MJ Loveland'; 'mjnelson'; 'mkm7200'; 'Nick W. Glover'; 'Patty Alfaro'; 'Paul Decker'; 'Paul Winslow'; Pierce, Sandra M (DNR); 'Randall Kanady'; 'Randy L. Skillern'; 'rcrotty'; 'rmclean'; 'Robert Campbell'; 'Robert Province'; 'Roger Belman'; 'Rudy Brueggeman'; 'Scott Cranswick'; 'Shannon Donnelly'; 'Sharmaine Copeland'; 'Sondra Stewman'; 'Sonja Frankllin'; 'stanekj'; 'Stephen F Davies'; 'Steve Lambert'; 'Steve Moothart'; 'Steven R. Rossberg'; 'tablerk'; 'Tamera Sheffield'; 'Temple Davidson'; 'Terrie Hubble'; 'Thomas E Maunder'; 'Tim Lawlor'; 'Todd Durkee'; 'Tricia Waggoner'; 'trmjrl'; 'Walter Featherly'; 'Walter Quay'; 'Wayne Rancier' Attachments :erio2-004.pdf; 10/31 /2007 • Mary Jones David McCaleb Mona Dickens 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 Michael Parks Mark Wedman 200 North 3rd Street, #1202 Marple's Business Newsletter Halliburton Boise, ID 83702 117 West Mercer St, Ste 200 6900 Arctic Blvd. Seattle, WA 98119-3960 Anchorage, AK 99502 Baker Oil Tools Schlumberger Ciri 4730 Business Park Blvd., #44 Drilling and Measurements Land Department Anchorage, AK 99503 2525 Gambell Street #400 PO Box 93330 Anchorage, AK 99503 Anchorage, AK 99503 Ivan Gillian Jill Schneider Gordon Severson 9649 Musket Bell Cr.#5 US Geological Survey 3201 Westmar Cr. Anchorage, AK 99507 4200 University Dr. Anchorage, AK 99508-4336 Anchorage, AK 99508 Jack Hakkila Darwin Waldsmith James Gibbs PO Box 190083 PO Box 39309 PO Box 1597 Anchorage, AK 99519 Ninilchick, AK 99639 Soldotna, AK 99669 Kenai National Wildlife Refuge Penny Vadla Richard Wagner Refuge Manager 399 West Riverview Avenue PO Box 60868 PO Box 2139 Soldotna, AK 99669-7714 Fairbanks, AK 99706 Soldotna, AK 99669-2139 Cliff Burglin Bernie Karl North Slope Borough PO Box 70131 K&K Recycling Inc. PO Box 69 Fairbanks, AK 99707 PO Box 58055 Barrow, AK 99723 Fairbanks, AK 99711 Williams Thomas Arctic Slope Regional Corporation Land Department ///~~~ PO Box 129 Barrow, AK 99723 ~` • • 0 ~ ~ ~ SARAH PALIN, GOVERNOR ~IL>•-7~ OIIJ tal`il IZAS 333 W. 7th AVENUE, SUITE 100 C01~5ERQA7`IOi~T CO1~II~II55IOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL ERIO 2.005 Mr. Paul M. Winslow Reservoir Engineer Forest Oil Corporation 310 K Street, Suite 700 Anchorage, AK 99501 RE: Temporary Extension to Enhanced Recovery Injection Order 2 Dear Mr. Winslow: In accordance with Rule 9 of Enhanced Recovery Injection Order ("ERIO") 2, the Alaska Oil and Gas Conservation Commission ("Commission") hereby grants Forest Oil Corporation ("Forest") a temporary extension to the expiration date of this order from November 30, 2007, to December 31, 2007. On July 30, 2007, Forest applied to the Commission to convert ERIO 2 into a full-field area injection order or, alternatively, to extend the expiration date of ERIO 2 for 12 months. On August 6 and 7, 2007, the Commission asked Forest to provide additional information. The additional information was provided on August 22, 2007. On September 12, 2007, the Commission asked for further information regarding well integrity. This information was provided by Forest on September 14, 2007. The Commission is continuing its review of Forest's July 30, 2007, application and the supplemental information. The Commission anticipates completing this review prior to the November 30, 2007, expiration date established by administrative approval ERIO 2.004. Nonetheless, to ensure there are no disruptions in the ongoing injection operations authorized under ERIO 2 (i. e., should the review not be completed in time), the Commission is granting a 31-day extension to the expiration date of ERIO 2. Forest must continue to comply with all the other provisions of ERIO 2 and the subsequent administrative approvals. As provided in AS 31.05.080, within 20 days after written notice of this 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. A request for reconsideration is timely if it is received by 4:30 p.m. on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a state holiday or weekend. A person may not appeal this decision to Superior Court unless reconsideration has been requested. ka, and dated November 30, 2007. ~; ~,,SK~1 Old, ~ ~~ _ Cathy P. Foerster r X ' ~a';'~^~; Commtssioner ~. ~~ • Mary Jones David McCaleb Mona Dickens 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 Michael Parks Mark Wedman 200 North 3rd Street, #1202 Marple's Business Newsletter Halliburton Boise, ID 83702 117 West Mercer St, Ste 200 6900 Arctic Blvd. Seattle, WA 98119-3960 Anchorage, AK 99502 Baker Oil Tools Schlumberger Ciri 4730 Business Park Blvd., #44 Drilling and Measurements Land Department Anchorage, AK 99503 2525 Gambell Street #400 PO Box 93330 Anchorage, AK 99503 Anchorage, AK 99503 Ivan Gillian Jill Schneider Gordon Severson 9649 Musket Bell Cr.#5 US Geological Survey 3201 Westmar Cr. Anchorage, AK 99507 4200 University Dr. Anchorage, AK 99508-4336 Anchorage, AK 99508 Jack Hakkila Darwin Waldsmith James Gibbs PO Box 190083 PO Box 39309 PO Box 1597 Anchorage, AK 99519 Ninilchick, AK 99639 Soldotna, AK 99669 Kenai National Wildlife Refuge Penny Vadla Richard Wagner Refuge Manager 399 West Riverview Avenue PO Box 60868 PO Box 2139 Soldotna, AK 99669-7714 Fairbanks, AK 99706 Soldotna, AK 99669-2139 Cliff Burglin Bernie Karl North Slope Borough PO Box 70131 K&K Recycling Inc. PO Box 69 Fairbanks, AK 99707 PO Box 58055 Barrow, AK 99723 Fairbanks, AK 99711 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 UL~ • • Page 1 of 1 Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Friday, November 30, 2007 10:25 AM Subject: Corrected Admin Approvals and ERIO 2-005 Attachments: Corrected Various Administrative Approvals.pdf; erio2-005.pdf BCC:McIver, C (DOA); 'Alan Birnbaum <""Alan J Birnbaum "> (alan.birnbaum@alaska.gov)'; 'Aleutians East Borough'; 'Anna Raff; Arion, Teri A (DNR); 'Arthur C Saltmarsh'; 'Arthur Copoulos'; 'Barbara F Fullmer'; 'bbritch'; 'Bill Walker'; 'Brad McKim'; 'Brandon Gagnon'; 'Brian Gillespie'; 'Brian Havelock'; 'Brit Lively'; 'Bruce Webb'; 'buonoje'; 'Cammy Taylor'; 'carol Smyth ; 'Cary Carrigan'; 'Catherine P Foerster'; caunderwood@marathonoil.com; 'Charles O'Donnell'; 'Chris Gay'; 'Christian Gou-Leonhardt'; 'Cliff Posey'; 'Dan Bross'; 'dapa'; 'Daryl J. Kleppin'; 'David L Boelens'; 'David Steingreaber'; 'ddonkel ; 'Deanna Gamble'; 'Deborah J. Jones'; 'doug_schultze'; 'Evan Harness'; 'eyancy'; 'foms2@mtaonline.net'; 'Francis S. Sommer'; 'Fred Steece'; 'Garland Robinson'; 'Gary Laughlin'; 'Gary Rogers'; 'Gary Schultz'; 'ghammons'; 'Gordon Pospisil'; 'Gregg Nady'; 'gregory micallef; 'gspfoff; 'Hank Alford'; 'Harry Engel'; 'jah'; 'James B Regg'; 'James M. Ruud'; 'James Scherr'; 'Janet D. Platt'; 'jdarlington'; 'jejones'; 'Jerry McCutcheon'; '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; 'Kristin Dirks'; 'Laura Silliphant'; 'Lois'; 'Lynnda Kahn'; 'mail=akpratts@acsalaska.net'; 'mail=Crockett@aoga.org'; 'mail=fours@mtaonline.net'; 'Mark Dalton'; 'Mark Hanley'; 'Mark Kovac'; 'Mark P. Worcester'; 'Marguerite kremer'; 'marty'r 'Matt Rader'; 'mckay ; 'Meghan Powell'; 'Mike Bill'; 'Mike Mason'; 'Mikel Schultz'; 'Mindy Lewis'; 'MJ Loveland'; 'mjnelson'; 'mkm7200'; 'Nick W. Glover'; 'Patty Alfaro'; 'Paul Decker'; 'Paul Winslow'; Pierce, Sandra M (DNR); 'Randall Kanady'; 'Randy L. Skillern'; 'rcrotty'; Rice, Cody J (DNR); 'rmclean'; 'Robert Campbell'; 'Robert Province'; 'Roger Belman ; 'Rudy Brueggeman'; 'Scott Cranswick ; 'Shannon Donnelly'; 'Sharmaine Copeland'; 'Sondra Stewman'; 'Sonja Frankllin'; 'stanekj'; 'Stephen F Davies'; 'Steve Lambert'; 'Steve Moothart'; 'Steven R. Rossberg'; 'tablerk'; 'Tamera Sheffield'; 'Temple Davidson'; 'Terrie Hubble'; 'Thomas E Maunder'; 'Tim Lawlor'; 'Todd Durkee'; 'trmjrl'; 'Walter Featherly'; 'Walter Quay'; 'Wayne Rancier' Attachments:Corrected Various Administrative Approvals.pdf;erio2-OOS.pdf; 11/30/2007 • • d D ~ 6 ~ SARAH PALIN, GOVERNOR ALASSA. OII. AI~TD GA5 333 W 7th AVENUE, SUITE 100 COI~TSER~ATIOI~T CO1~II55IOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL ERIO 2.006 Mr. Paul M. Winslow Reservoir Engineer Forest Oil Corporation 310 K Street, Suite 700 Anchorage, AK 99501 RE: Temporary Extension to Enhanced Recovery Injection Order 2 Dear Mr. Winslow: In accordance with Rule 9 of Enhanced Recovery Injection Order ("ERIO") 2, the Alaska Oil and Gas Conservation Commission ("Commission") hereby grants Forest Oil Corporation ("Forest") a temporary extension to the expiration date of this order from December 31, 2007, to January 31, 2008. On July 30, 2007, Forest applied to the Commission to convert ERIO 2 into a full-field area injection order or, alternatively, to extend the expiration date of ERIO 2 for 12 months. On August 6 and 7, 2007, the Commission asked Forest to provide additional information. The additional information was provided on August 22, 2007. On September 12, 2007, the Commission asked for further information regarding well integrity. This information was provided by Forest on September 14, 2007. The Commission is continuing its review of Forest's July 30, 2007, application and the supplemental information. The Commission anticipates completing this review prior to the January 31, 2008, expiration date established by administrative approval ERIO 2.005. Therefore, to ensure there are no disruptions in the ongoing injection operations authorized under ERIO 2 (i. e., should the review not be completed in time), the Commission is granting a 31-day extension to the expiration date of ERIO 2. Forest must continue to comply with all the other provisions of ERIO 2 and the subsequent administrative approvals. As provided in AS 31.05.080, within 20 days after written notice of this 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. A request for reconsideration is timely if it is received by 4:30 p.m. on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a state holiday or weekend. A person may not appeal this decision to Superior Court unless reconsideration has been requested. ska, and dated December 28, 2007. i . • Page 1 of 1 Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Friday, December 28, 2007 2:56 PM Subject: Public Notice Pt. McIntyre P2-456 and erio2-006 Redoubt Unit Attachments: Pt McIntyre P2-456 Public Notice.pdf; erio2-006.pdf BCC:McIver, C (DOA); 'Alan Birnbaum <""Alan J Birnbaum "> (alan.birnbaum@alaska.gov)'; 'Aleutians East Borough'; 'Anna Raff ; Arion, Teri A (DNR); 'Arthur C Saltmarsh'; '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'; 'Catherine P Foerster'; caunderwood@marathonoil.com; 'Charles O'Donnell'; 'Chris Gay'; 'Christian Gou-Leonhardt ; 'Cliff Posey'; 'Dan Bross'; 'dapa'; 'Daryl J. Kleppin'; 'David L Boelens'; 'David Steingreaber'; 'ddonkel'; 'Deanna Gamble'; 'Deborah J. Jones'; 'doug_schultze'; 'Evan Harness'; 'eyancy'; 'foms2@mtaonline.net'; 'Francis S. Sommer'; 'Fred Steece'; 'Garland Robinson'; 'Gary Laughlin'; 'Gary Rogers'; 'Gary Schultz'; 'ghammons'; 'Gordon Pospisil'; 'Gregg Nady'; 'gregory micallef; 'gspfoff; 'Hank Alford'; 'Harry Engel'; 'jah'; 'James B Regg'; 'James M. Ruud'; 'James Scherr'; 'Janet D. Platt'; 'jdarlington'; 'jejones'; 'Jerry McCutcheon'; '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'; keelson@petroleumnews.com; 'Kristin Dirks'; 'Laura Silliphant'; 'Lois'; 'Lynnda Kahn'; 'mail=akpratts@acsalaska.net'; 'mail=Crockett@aoga.org'; 'mail=fours@mtaonline.net'; 'Mark Dalton'; 'Mark Hanley'; 'Mark Kovac'; 'Mark P. Worcester'; 'Marguerite kremer'; 'many'; 'Matt Rader'; 'mckay'; 'Meghan Powell'; 'Mike Bill'; 'Mike Mason'; 'Mikel Schultz'; 'Mindy Lewis'; 'MJ Loveland'; 'mjnelson'; 'mkin7200'; 'Nick W. Glover'; 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.g.dragnich@exxonmobil.com; 'Robert Campbell'; 'Robert Province'; 'Roger Belman'; 'Rudy Brueggeman'; 'Scott Cranswick'; 'Shannon Donnelly'; 'Sharmaine Copeland'; 'Sondra Stewman'; 'Sonja Frankllin'; 'stanekj'; 'Stephen F Davies'; 'Steve Lambert'; 'Steve Moothart'; 'Steven R. Rossberg'; 'tablerk'; 'Tamera Sheffield'; 'Temple Davidson'; 'Terrie Hubble'; 'Thomas E Maunder'; 'Tim Lawlor'; 'Todd Durkee'; 'trmjrl'; 'Walter Featherly'; 'Walter Quay'; 'Wayne Rancier' Attachments:Pt McIntyre P2-45B Public Notice.pdf;erio2-006.pdf; 12/28/2007 ! • 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 Michael Parks Mark Wedman 200 North 3rd Street, #1202 Marple's Business Newsletter Halliburton Boise, ID 83702 117 West Mercer St, Ste 200 6900 Arctic Blvd. Seattle, WA 98119-3960 Anchorage, AK 99502 Baker Oil Tools Schlumberger Ciri 4730 Business Park Blvd., #44 Drilling and Measurements Land Department Anchorage, AK 99503 2525 Gambell Street #400 PO Box 93330 Anchorage, AK 99503 Anchorage, AK 99503 Ivan Gillian Jill Schneider Gordon Severson 9649 Musket Bell Cr.#5 US Geological Survey 3201 Westmar Cr. Anchorage, AK 99507 4200 University Dr. Anchorage, AK 99508-4336 Anchorage, AK 99508 Jack Hakkila Darwin Waldsmith James Gibbs PO Box 190083 PO Box 39309 PO Box 1597 Anchorage, AK 99519 Ninilchick, AK 99639 Soldotna, AK 99669 Kenai National Wildlife Refuge Penny Vadla Richard Wagner Refuge Manager 399 West Riverview Avenue PO Box 60868 PO Box 2139 Soldotna, AK 99669-7714 Fairbanks, AK 99706 Soldotna, AK 99669-2139 Cliff Burglin Bernie Karl North Slope Borough PO Box 70131 K&K Recycling Inc. PO Box 69 Fairbanks, AK 99707 PO Box 58055 Barrow, AK 99723 Fairbanks, AK 99711 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 y ~ ,. ~~ ` - V t ~` l ~~~~ e~~ '.~12 • • From: Saltmarsh, Arthur C (DOA) Sent: Monday, March 09, 2009 11:08 AM Subject: FW: Pacific Energy files chapter-11, it's official!!! FYI. PACIFIC ENERGY RESOURCES LTD. ~~~~a 111 West Ocean Btvd., Suite 1240 Long Beach, California 90802 Telephone: (562) 628-1526; Fax: (562) 628-1536 Files for Chapter ii to Facilitate a Restructuring LONG BEACH, CALIFORNIA, Monday, March 9, 2009 - -Pacific Energy Resources Ltd. (the "Company")(TSX:PFE) announces today that it and its wholly owned subsidiaries have filed voluntary petitions for reorganization under Chapter 11 of the U.S. Bankruptcy Code in the U.S. Bankruptcy Court for the District of Delaware. The filing was precipitated by the dramatic decrease in the market price of oil over the past flue months. Combined with the Company's pre-existing level of debt related to past acquisitions and poor capital market conditions, the Company's liquidity and cash flow is insufficient to operate its business and invest in its oil producing assets to increase production. Faced with these constraints, the Company and its subsidiaries filed petitions for reorganization under chapter 11 to facilitate access to an immediate source of liquidity as it works to restructure its debt. In connection with the filing, the Company is seeking customary authority from the Bankruptcy Court that will enable it to continue operating its business in the ordinary course of business. The requested approvals include requests for the authority to make wage and salary payments and continue various benefits for employees. In addition, the Company has negotiated a commitment for $40 million in debtor-in-possession ("DIP")financing. The DIP facility wraps and replaces two of the Company's three asset-based credit facilities and is being provided by the lenders of the two credit facilities that are being replaced. Upon Court approval, the DIP financing combined with the Company's operating revenue will provide sufficient liquidity to fund working capital, meet ongoing obligations and ensure that normal operations continue without interruption during its restructuring. About Pacific Energy Resources Pacific Energy Resources Ltd. is an oil and gas exploration and production company based in Long Beach, California, U.S.A. Additional information relating to the Company may be found on SEDAR at www.sedar.com. The Company's web site is www.PacEnergy.com. ON BEHALF OF THE BOARD OF DIRECTORS PACIFIC ENERGY RESOURCES LTD. ~~ Pacific Ener~t~ Resources Ltd. 310 K. Street, Suite 700 Anchorage, AK 99507 Office: 907-258-8600 Fax: 907-258-8601 ~~ ~a~~~d Ha~1 Alaska ®perations Manager Main: 907-868-2133 Cell: 907-317-8239 dmhal Ur`i,nacener6v.com ww~_.pacenerav.com #11 . . Page 1 of 1 Colombie, Jody J (DOA) From: Roby, David S (DOA) Sent: Friday, September 21,20072:34 PM To: Colombie, Jody J (DOA) Subject: ERIO 2-003 Jody, On Wednesday September 19th I received a call from Paul Winslow regarding the review of their application to convert ERIO 2 into a full-field AIO. He reminded me that ERIO 2 expires on September 30th and stated that if an AIO was not issued by that time or alternatively ERIO 2 extended that they would need to shut down the injection operations at RU #6. In order to accomplish this in a controlled manor they would need several days notice so that other arrangements could be made to handle the fluids normally injected into this well. I fully expect that the Commission will be able to complete its review and take action on the AIO request in a timely manner but because of Forest's logistical concerns and Commission staff workload and Commissioner availability over the coming week I thought it best to issue a temporary extension to ERIO 2 just in case the September 30th expiration date could not be met. Therefore, on the Commission's own initiative I prepared the administrative approval to extend the expiration date of ERIO 2 by one month. Dave Roby Reservoir Engineer Alaska Oil and Gas Conservation Commission Phone: 907-793-1232 Fax: 907-276-7542 email: dave.roby@alaska.gov 9/21/2007 #10 . . ~ FOREST OIL CORPORATION _0'/' J:J:' .. _0 510 GV1/ C!/teJrpÆt . CYude 700 QQhU:hÆÞN£1f6' Q9iIr£ðÆ:a .9.9,1)01 (907) 258-86'00 · (907) 25(5'-8ôOf (9'ßæc) January 25,2007 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Request to Include West Foreland Produced Water in Administrative Approval ERa 2.001A Dear Commissioner Norman: On July 14,2006 Forest Oil Corporation (Forest Oil) received Administrative Approval ERa 2.001A from AOGCC granting approval for the injection ofthe following non- hazardous fluids into the RU #6 Class II enhanced oil recovery (EaR) well in the Redoubt Shoal Undefined Oil Pool: 1. treated sanitary waste 2. gray water from camp or platform facilities 3. produced water from the West McArthur River Unit (WMRU) 4. storm water collected in secondary containment areas at the Kustatan Production Facility 5. storm water collected in secondary containment areas at the WMRU Production Facility 6. storm water from secondary containment areas on the Osprey Platform (deck drain fluids) In October of 2006 Forest Oil completed construction of a 4" produced water transmission pipeline which now makes it physically possible to send produced water from WMRU to the Osprey Platform for injection into EaR wells. However, WMRU's produced water (~2,000 bbls/day) is commingled with a small amount (~1,000 gallons/day) of produced water from the gas wells at the West Foreland (WF) Field. Since produced water from WF is not currently authorized for injection at Redoubt Unit, the entire commingled produced water stream currently must be injected into the Class II disposal well at WMRU (WMRU #4D). . . In order to obtain administrative approval from the Alaska Oil and Gas Conservation Commission to inject WF produced water into the Hemlock formation at Redoubt Unit (RU), Forest Oil has conducted a fluid compatibility study ofthe produced WF Tyonek water with the produced water from both RU and WMRU. This compatibility study consisted of analyzing the three produced water samples, then filtering and mixing them proportionally to the maximum expected rates/volumes produced and finally letting the mixtures stand at 180 of for 48 hours. The mixed samples were then analyzed for total suspended solids (TSS) and for turbidity. The expected volumes of produced water from RU, WMRU, and WF at peak production rates are shown in Table 1. Table 2 summarizes the results of the compatibility analyses performed by SGS Environmental Services, Inc. Table 1 Relative Volumes of Produced Water to be Injected for EOR at Peak Production Water Source Est-peak BPD % of total WF 47 0.78% RU 3,000 49.61 % WMRU 3,000 49.61 % Total 6,047 100.00% Table 2 Results of Compatibility Study Sample Vol WF Vol RU VolWMRU Turbidity TSS pH ID H2O H2O H2O (NTU) (ppm) WF 500 mL - - 452 148 7.30 RU - 500 mL - 136 56.2 7.00 WMRU - - 500 mL 7.50 9.6 7.30 Mix 1 8mL 492 mL - 2.00 29.0 - Mix 2 8mL - 492 mL 0.38 40.0 - Mix 3 4mL 248 mL 248 mL 1.22 25.5 - Once filtered and mixed (and let stand at reservoir temperature for 48 hours) the three mixtures showed very minor increases in turbidity, 0.38 to 2.00 NTU (Nephelometric Turbidity Units). Filtering of the water sources removes the suspended solids from the waters, thus allowing the mixture to truly reflect the interaction ofthe water sources. Similarly, the mixed samples showed relatively low concentrations of total suspended solids (TSS), 25.5 to 40.0 ppm, after they were allowed to stand at 180 of temperature for 48 hours. In Forest Oil's opinion, neither the observed increase in turbidity nor TSS was of sufficient magnitude to adversely affect the Hemlock reservoir at Redoubt Unit. ·/ / . Allowing the produced water ftom WMRU and WF to be added to the enhanced oil recovery pilot waterflood being conducted at Redoubt Unit will have a very beneficial impact on the oil recovery at RU. The current pilot waterflood operation at RU has already shown a significant enhancement to oil production. Once initiated, the water injection into RU #6 has resulted in a significant decrease in the production decline rate of the nearby producing wells. Note that the majority of the produced RU water that has been re-injected into the Hemlock formation has come from the RU #5A well. The electrical submersible pump (ESP) in RU #5A failed on January 7,2007 and the well has been shut-in ever since. Thus the water injection into RU #6 has dropped ftom nearly 1,000 bwpd to approximately 250 bwpd. Having the ability to augment the water injection volume by using WMRU produced water (with minor amounts ofWF water) will help sustain the waterflood enhancement project at Redoubt Unit. In order to maintain the pilot waterflood operation, Forest Oil Corporation respectfully requests an expedited review and approval by the Commission to allow WF produced water to be injected into the Hemlock formation at Redoubt Unit. Thank you for your continued assistance. Please contact me at 868-2131 if you have questions or need additional information. Sincerely, (('£11 ÙL Paul M. Winslow Reservoir Engineer cc: Jim Regg Attachment . . Laboratory Analysis Report 200 W. Potter Drive Anchorage, AK 99518-1605 Tel: (907) 562-2343 Fax: (907) 561-5301 Web: http://www.us.sgs.com Paul Winslow Forest Oil Corporation 310 K Street Suite 700 Anchorage, AK 99501 Work Order: Client: Report Date: 1070105 Redoubt Fluid Com pat Study P2A Forest Oil Corporation January 23,2007 Released by: ..f¡.J..,.i&" d IJaf1 SGS Barbara Hager 2007.01,23 15:22: 16 - 09'00' BubarallaBe:r A1aslaDiYis!on~Manager Enclosed are the analytical results associated with the above workorder. As required by the state of Alaska and the USEP A, a fonnal Quality Assurance/Quality Control Program is maintained by SGS. A copy of our Quality Assurance Plan (QAP), which outlines this program, is available at your request. The laboratory certification numbers are AK971-05 (DW), UST-005 (CS) and AK00971 (Micro) for ADEC and 001582 for NELAP (RCRA methods: 1010/1020, 1311,6000/7000,9040/9045,9056,9060,9065, 8015B, 8021B, 8081A/8082, 8260B, 8270C). Except as specifically noted, all statements and data in this report are in conformance to the provisions set forth by the SGS QAP, the National Environmental Laboratory Accreditation Program and, when applicable, other regulatory authorities, If you have any questions regarding this report or if we can be of any other assistance, please contact your SGS Project Manager at 907-562-2343. The following descriptors may be found on your report which will serve to further qualifY the data. * Practical Quantitation Limit (reporting limit), Indicates the analyte was analyzed for but not detected. Indicates value that is greater than or equal to the MDL The quantitation is an estimation. Indicates the analyte is not detected. Indicates the analyte is found in a blank. associated with the sample, The analyte has exceeded allowable regulatory or control limits, Greater Than The analyte concentration is the result of a dilution. Less Than Surrogate out of control limits. QC parameter out of acceptance range. A matrix effect was present. The analyte was positively identified, but the quantitation is a low estimation. The analyte result is above the calibrated range, PQL U F J ND B GT D LT ! Q M JL E Note: Soil samples are reported on a dry weight basis unless otherwise specified. SGS Environmental Services Inc. _1200 W Potter Dr Anchoraae AK 99518-1605 t (907) 562-2343 f(907) 561-5301 wwwus sgs com . . SGS Ref.# Client Name Project Name/# Client Sample ID Matrix 1070105001 Forest Oil Corporation Redoubt Fluid Compat Study P2A West Foreland Produced Tyonek Other Liquids All Dateslfimes are Alaska Standard Time Printed Datelfime 01/23/2007 13:52 Collected Datelfime Received Datelfime Technical Director 01/04/2007 16:23 Stephen C. Ede Sample Remarks: 6010B - Elevated PQL for Fe due to matrix. Allowable Prep Analysis Parameter Results PQL Units Method Container ID Limits Date Date Init Silicon 14300 ug/L SW6020 A 01116/07 01117/07 TK Routine Oilfield Water Analysis Alkalinity 5640 10,0 mg/L SM20 2320B A 01112/07 PLW Chloride 2610 10,0 mg/L EPA 300.0 A 01109/07 01109/07 IDS C03 Alkalinity ND 10.0 mg/L SM20 2320B A 01112/07 PLW HC03 Alkalinity 5640 10.0 mg/L SM20 2320B A 01112/07 PLW OH Alkalinity ND 10.0 mg/L SM20 2320B A 01112/07 PLW pH 7.30 0.100 pH units EPA 150,1 A 01112/07 KP Resistivity 0.570 0.0100 ohm-m SM192510A A 01115/07 PLW Sulfate 190 10.0 mg/L EPA 300.0 A 01109/07 01109/07 IDS Metals Department Barium 16,7 0.500 mg/L SW6010B A 01116/07 01117/07 DSH Calcium 61.1 25.0 mg/L SW6010B A 01116/07 01117/07 DSH Iron ND 10.0 mg/L SW6010B A 01116/07 01117/07 DSH Sodium 4930 250 mg/L SW6010B A 01116/07 01/17/07 DSH Strontium 12,3 0.250 mg/L SW6010B A 01/16/07 01/17/07 DSH Magnesium 16.2 5.00 mg/L SW6010B A 01/16/07 01/17/07 DSH Dissolved Metals Potassium 58300 ug/L SW6020 A 01/16/07 01/17/07 TK Waters Department Total Suspended Solids 148 1.67 mg/L EPA 160.2 A 01/22/07 KP Total Dissolved Solids 16700 160 mg/L SM20 2540C A 01116/07 ACF Turbidity 452 0.100 NTU SM202130B A 01115/07 AZS . . SGS Ref.# Client Name Project Name/# Client Sample ID Matrix 1070105002 Forest Oil Corporation Redoubt Fluid Compat Study P2A RU Produced Water Other Liquids All Dateslfimes are Alaska Standard Time Printed Dateffime 01/23/2007 13:52 Collected Datelfime Received Date/Time Technical Director 01/04/2007 16:23 Stephen C. Ede Sample Remarks: 6010B - Elevated PQL for Fe due to matrix. Allowable Prep Analysis Parameter Results PQL Units Method Container ID Limits Date Date Init Silicon 20800 ug/L SW6020 A 01/16/07 01/17/07 TK Routine Oilfield Water Analysis Alkalinity 605 10.0 mg/L SM20 2320B A 01/12/07 PLW Chloride 7430 100 mg/L EPA 300.0 A 01/09/07 01/10/07 IDS C03 Alkalinity ND 10,0 mg/L SM20 2320B A 01/12/07 PLW HC03 Alkalinity 605 10,0 mg/L SM202320B A 01/12/07 PLW OH Alkalinity ND 10,0 mg/L SM20 2320B A 01/12/07 PLW pH 7,00 0.100 pH units EPA 150.1 A 01/12/07 KP Resistivity 0.230 0.0100 ohm-m SMI92510A A 01/15/07 PLW Sulfate 17.5 10.0 mg/L EPA 300,0 A 01/09/07 01/09/07 IDS Metals Department Barium 4.45 0.500 mg/L SW60lOB A 01/16/07 01/17/07 DSH Calcium 1300 25.0 mg/L SW60lOB A 01/16/07 01/17/07 DSH Iron ND 10.0 mg/L SW60lOB A 01/16/07 01/17/07 DSH Sodium 3050 250 mg/L SW60lOB A 01/16/07 01/17/07 DSH Strontium 25.2 0.250 mg/L SW60lOB A 01/16/07 01/17/07 DSH Magnesium 12,0 5.00 mg/L SW60lOB A 01/16/07 01/17/07 DSH Dissolved Metals Potassium 65100 ug/L SW6020 A 01/16/07 01/17/07 TK Waters Department Total Suspended Solids 56.2 1.00 mg/L EPA 160.2 A 01/22/07 KP Total Dissolved Solids 13200 160 mg/L SM20 2540C A 01/16/07 ACF Turbidity 136 0.100 NTU SM202130B A 01/15/07 AZS . . SGS Ref.# Client Name Project Name/# Client Sample ID Matrix 1070105003 Forest Oil Corporation Redoubt Fluid Compat Study P2A WMRU Produced Water Other Liquids All Datesffimes are Alaska Standard Time Printed Dateffime 01/23/2007 13:52 Collected Dateffime Received DatelTime Technical Director o l/04/2007 16:23 Stephen C. Ede Sample Remarks: 6010B - Elevated PQL for Fe due to matrix. Allowable Prep Analysis Parameter Results PQL Units Method Container ID Limits Date Date Init Silicon 17700 ugIL SW6020 A 01/16/07 01/17/07 TK Routine Oilfield Water Analysis Alkalinity 335 10.0 mgIL SM20 2320B A 01/12/07 PLW Chloride 20300 100 mgIL EPA 300,0 A 01/09/07 01/10/07 IDS cm Alkalinity ND 10.0 mgIL SM20 2320B A 01/12/07 PLW HCm Alkalinity 335 10,0 mgIL SM20 2320B A 01/12/07 PLW OH Alkalinity ND 10.0 mgIL SM20 2320B A 01/12/07 PLW pH 7,30 0,100 pH units EPA 150.1 A 01/12/07 KP Resistivity 0.500 0,0100 ohm-m SM192510A A 01/15/07 PLW Sulfate 94.3 10.0 mgIL EPA 300.0 A 01/09/07 01/09/07 IDS Metals Department Barium 9,63 0.500 mgIL SW6010B A 01/16/07 01/17/07 DSH Calcium 4850 25.0 mgIL SW6010B A 01/16/07 01/17/07 DSH Iron ND 10,0 mgIL SW6010B A 01/16/07 01/17/07 DSH Sodium 4710 250 mgIL SW6010B A 01/16/07 01/17/07 DSH Strontium 79.3 0.250 mgIL SW6010B A 01/16/07 01/17/07 DSH Magnesium 33,0 5,00 mgIL SW6010B A 01/16/07 01/17/07 DSH Dissolved Metals Potassium 81000 ugIL SW6020 A 01/16/07 01/17/07 TK Waters Department Total Suspended Solids 9,60 1.00 mgIL EPA 160.2 A 01/22/07 KP Total Dissolved Solids 32500 160 mgIL SM20 2540C A 01/16/07 ACF Turbidity 7.50 0.100 NTU SM202130B A 01/15/07 AZS . . SGS Ref.# Client Name Project Name/# Client Sample ID Matrix 1070105004 Forest Oil Corporation Redoubt Fluid Com pat Study P2A Mix 1 WF Tyonek RU Prod Wtr Other Liquids All Datesffimes are Alaska Standard Time Printed Dateffime 01/23/2007 13:52 Collected Dateffime Received Date/Time Technical Director 01/04/2007 16:23 Stephen C. Ede Sample Remarks: SM20 2130B - Turbidity analyzed on sample composites after heating over the weekend at 180 degrees F. EP A 160.2 - TSS analyzed on sample composites after heating over the weekend at 180 degrees F. Parameter Method Results Allowable Prep Container ID Limits Date Analysis Date Init Units PQL Waters Department Total Suspended Solids Turbidity 29,0 2.00 01/22/07 KP 01/22/07 PL W 5,00 0.100 EPA 160.2 SM20 2130B A A mg/L NTU . . SGS Ref.# Client Name Project Name/# Client Sample ID Matrix 1070105005 Forest Oil Corporation Redoubt Fluid Compat Study P2A Mix 2 WF Tyonek WMRU Prod Other Liquids All Datesffimes are Alaska Standard Time Printed Dateffime 01/23/2007 13:52 Collected Dateffime Received Date/Time Technical Director 01/04/2007 16:23 Stephen C. Ede Sample Remarks: SM20 2130B - Turbidity analyzed on sample composites after heating over the weekend at 180 degrees F. EP A 160.2 - TSS analyzed on sample composites after heating over the weekend at 180 degrees F. Parameter Method Waters Department Total Suspended Solids Turbidity Results Allowable Prep Container ID Limits Date Analysis Date Init Units PQL 40,0 0.380 EPA 160.2 SM202130B 01/22/07 KP 01/22/07 PL W 4,35 0.100 mg/L NTU A A . . SGS Ref.# Client Name Project Name/# Client Sample ID Matrix 1070105006 Forest Oil Corporation Redoubt Fluid Com pat Study P2A Mix 3 WF Tyonek Wtr/RUIWMRU Other Liquids All Datesrrimes are Alaska Standard Time Printed Datelfime 01/23/2007 13:52 Collected Dateffime Received Dateffime Technical Director 01/04/2007 16:23 Stephen C. Ede Sample Remarks: SM20 2130B - Turbidity analyzed on sample composites after heating over the weekend at 180 degrees F. EP A 160.2 - TSS analyzed on sample composites after heating over the weekend at 180 degrees F. Parameter PQL Method Waters Department Total Suspended Solids Turbidity Results Units Allowable Prep Container ID Limits Date Analysis Date Init 25.5 L22 4.55 0.100 mgIL NTU EPA 160.2 SM202130B A A 01/22/07 KP 01/22/07 PLW 4fq . . FRANK H. MURKOWSKI, GOVERNOR ALASKA. OIL AM) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAJ< (907) 276-7542 September 26, 2006 Mr. Paul M. Winslow Reservoir Engineer Forest Oil Corporation 310 K Street, Suite 700 Anchorage, AK 99501 Re: Annual Report for Pilot Enhanced Recovery Injection Redoubt Unit #6 Dear Mr. Winslow: The Alaska Oil and Gas Conservation Commission has reviewed your annual report for the pilot enhanced recovery injection operations in Redoubt Unit, Well 6. That report is dated June 30, 2006 covering the period March 7,2005 through May 31, 2006. The performance data provided in the report meets the intent of the Commission's Enhanced Recovery Injection Order 2, Rule 6. All injected fluids appear to be confined to the intended injection zone. The next annual report is due July 1,2007. In that report, Forest should describe plans for expanding the pilot area to full field, extend the pilot test (with justification), or abandonment of the pilot injection project. Sincerely, Ã ,~.~ ~¿wa.j b . ~ ey¡ James B. Regg ~ , Sr. Petroleum Engineer ~8 @ . . Forest Oil Corporation 310 K Street, Suite 700 Anchorage, Alaska 99501 (907) 258-8600 Fax: (907) 258-8601 O-RrG'NAl June 30,2006 REce\VED JUN 3 0 2006 . C CQO"llTlission Alaska OIl & Gas on5. Anchorage Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501 Attn: Mr. Tom Maunder Re: Redoubt Unit #6 - Annual Injection Report 2005 - 2006 Dear Mr. Maunder, This report is in response to the requirements for annual surveillance reporting on the Redoubt Unit #6 (RU #6) enhanced recovery injection well. Enhanced Recovery Injection Order NO.2 (ERI02) specifies that the reporting requirements of 20 MC 25.432 (1) shall be submitted within 90 days of the project startup anniversary and annually thereafter. This first annual injection report (2005 - 2006 Annual Injection Report) will cover the period March 7, 2005 through May 31, 2006. Subsequent reports will cover the injection period from June 1st through May 31st, and will be submitted by July 1st of the respective year. First injection into RU #6 occurred on March 7th 2005, with continuous injection commencing April 25th 2005. During the period of this first annual injection report, 550 Mbbls of water were injected back into the Hemlock formation via the RU #6 well bore. Over the course of this period, RU #6 has been operating within what we consider normal parameters and has shown no sign of integrity problems. If there are any questions, please contact me at 907-868-2131. Sincerely, v~n.u~ Paul M. Winslow Reservoir Engineer Forest Oil Corporation , . Redoubt Unit #6 2005 - 2006 Annual Injection Analysis Report covering: (March 7, 2005 - May 31, 2005) . . @< . . @J : Redoubt Unit #6 -Injection Histo~ · RU #6 converted from a Hemlock production well to a Hemlock . injection well, in February/March 2005 · First injection (into Hemlock Reservoir) 3/7/05 · Continuous injection commenced 4/25/05 · Cumulative injection volume from March 7th, 2005 - May 31st, 2006 = 550 M STB of water . - njection History #6 Redoubt íi ¡ii ..9: () ... :;: fII fII () ... Cl. oð - C Cl. ~ ¡:: o :;::¡ (.) () ...... ¡:: ... S ~ ;::., ¡¡:j c 'f:>~ 'f:>~ 'f:>~ 'f:>~ 'f:>~ 'f:>~ 'f:>~ 'f:>~ 'f:>~ 'f:>~ 'f:>f{:¡ 'f:>f{:¡ 'f:>f{:¡ 'f:>f{:¡ 'f:>f{:¡ 'f:>f{:¡ "'J~ b<\1>.,. ~\I>.,. f{:¡~ "\~ 'ò~ oþ \)~ I>.,.~ 11>.,. I>.,.~ 11>.,. "'J~ ~I>.,. ~I>.,. f{:¡~ 1\ I>.,. I>.,. Date Hemlock Reservoir Voidage to date: . Cumulative Hemlock Production to date (5/31/06) = 4.31 MM STB (4.70 MM RB) 1.95 MM STBO - 2.36 MM STBW (2.29 MM RB of oil) (2.41 MM RB of water) Hemlock Production prior to RU #6 injection = 3.22 MM STB (3.53 MM RB) · 1.57 MM 8TBO · 1.65 MM 8TBW (1.85 MM RB of oil) (1.68 MM RB of water) Hemlock Production after start RU #6 injection = 1.09 MM STB (1.17 MM RB) · 0.37 MM 8TBO · 0.72 MM 8TBW (0.44 MM RB of oil) (0.73 MM RB of water) ~ ~ . . Hemlock Reservoir Voidage to date (cont.t · Cumulative Hemlock Production to date (5/31/06) = 4.31 MM STB (4.70 MM RB) · RU #6 Injection Volume to date (5/31/06) = 0.55 MM STBW (0.56 MM RB) · Hemlock Voidage to date (5/31/06) = 4.14 MM RB of fluid Note: Voidage Assumes average Bo = 1.175 RB/STB & Bw = 1.02 RB/STB I~J' . . Hemlock Voida~(3/7/05 - 5/31/06t · Cumulative Hemlock Production (3/7/05 - 5/31/06) = 1.09 MM STB (1.17MMRB) - 0.37 MM STBO (0.44 MM RB of oil) - 0.72 MM STBW (0.73 MM RB of water) · Cumulative Hemlock Injection to date (3/7/05 - 5/31/06) = 0.40 MM STBW (0.41 MM RB) · 2005 Hemlock Voidage = 0.76 MM RB of fluid - (350/0 volumetric replacement) ~ . . Date - Redoubt Unit Daily Fluid -Redoubt Unit Daily Water RU #6 Water Injection 00 V ~ ~ ~ ~ ~ ~ ¢ ¢ ¢ ¢ ¢ ¢ ~ ~ ~ ~ ~ ~ ~ ~ ~ $~~~~$$~~~~$$~~~~$$~~~ ! Production Unit - Redoubt 0,000 000 - C Il. ~ ¡:: o :¡:¡ (.) .!!:!, ¡:: ..... ¡:: <:) :¡:¡ (.) :;: "C o i- ll. :>. ïii C Redoubt Unit - Production !Injection History ...........Redoubt Unit Daily Fluìd ...........Redoubt Unit Daily Water RU #6 - Daily Water 00 ~~ ~~ ~~ ~~ ~~ ~~ ~~ ~~ ~~ ~fò ~fò ~fò ~fò ~fò ~fò ~, ~t- <J.' '\t- qj.' o}' ~t- ,t- ,rp.' ,\' rp.' o;;¡t- ~, ~t- fòt- , , Date 0,000 ,000 - C 11. ~ ¡:: o :;::¡ (.) .S!!.. ¡:: - ¡:: o ~ (.) :;: "t:I o ... 11. >- ïii c . Prior to water injection into RU #6, the total Redoubt Unit Hemlock oil production exhibited a very steep decline rate (see plot on next page). 1 . rate has The Redoubt Unit Hemlock oil production decline been relatively flat since commencement of water injection into RU #6. 2. J . o ~ ....J m m ~ w !- « ?;: (D o + ;J ~ - f=f R ==t= April 25, 2005 - Initiate Continuous Water Injection I I 3: f--- Flatter Production Decline ~ -r I -- I " II § , t"'-, . "". ""-"'""". I'" die 95 96 97 98 99 00 01 02 03 04 05 06 YEAR 07 08 09 10 11 12 13 14 f>.PTI=C: M"j¡.¡,-:;."...h - rPMIM P"¡"o_Tim,,, C:",mil ",., r M";,,. = I ¡...k...",.,...11 .. Forest Oil Corporation Osprey Platform Yearly Injection Report - Production Water June 1,2005 to May 31,2006 Disposal Well RU 6 Injected Produced from Produced Water Rain Water Effluent Water Gray Water RU#3 Total Injected 6/30/2005 40,981 40,981 7/31/2005 42,547 490 3 43,040 8/31/2005 37,543 118 110 72 37,843 9/30/2005 41 ,790 1014 10 42,814 10/31/2005 37,284 306 16 47 37,653 11/30/2005 53,640 78 11 51 53,780 12/31/2005 35,578 499 27 96 36,200 1/31/2006 26,014 58 19 83 26,174 2/28/2006 26,034 169 18 87 26,308 3/31/2006 33,059 151 15 77 33,302 4/30/2006 34,644 180 17 69 34,910 5/31/2006 31,713 80 79 411 32,283 Total 440,827 3,143 325 921 72 445,288 . . :æ: Cl. ŒI ~ 0.80 () .... ~ D:: RU 6 June 2005 Rate and Pressure 1.60 1.40 1.20 1.00 0.60 0.40 0.20 0.00 5/28/2005 6/212005 6/7/2005 6/12/2005 6/17/2005 6/22/2005 6/27/2005 Time 4,500 4,000 3,500 3,000 fñ 2,500 ~ I Rate, BPM I ~ I-+- Wellhead Pressure I 2,000 ~ L ~ Annulus Pressure i Cl. 1,500 1,000 500 o 7/2/2005 :E 0.80 Cl. m <i ..... 11:1 Ct: 0.60 RU 6 July 2005 Rate and Pressure 1.40 1.20 1.00 0.40 0.20 0.00 6/27/2005 7/2/2005 o 7/7/2005 7/12/2005 7/17/2005 7/22/2005 7/27/2005 8/1/2005 8/6/2005 Time 4,500 4,000 3,500 3,000 ëñ 2,500 Cl. <i ... :;: fII 2,000 Ë Cl. 1,500 1,000 500 Rate, BPM i -+-Wellhead Pressure I -+- Annulus Pressure I ~ 2.50 ¡:J ti .... ~ 2.00 RU 6 August 2005 Rate and Pressure 4.50 4.00 3.50 3.00 1.50 1.00 0.50 0.00 7/27/2005 8/1/2005 ° 8/6/2005 8/11/2005 8/16/2005 8/21/2005 8/26/2005 8/31/2005 9/5/2005 Time 4,500 4,000 3,500 3,000 ëñ 2,500 Cl. ti ... :;: fII fII 2,000 ~ Cl. 1,500 1,000 500 I ...... Rate, BPM ;~ 1"""'- Wellhead Pressure 1-- Annulus Pressure ~ 0.80 Cl. !:IJ a) .... I'C 0::: 0.60 RU 6 September 2005 Rate and Pressure 1.40 1.20 1.00 0.40 0.20 0.00 8/26/2005 8/31/2005 9/5/2005 o 9/10/2005 9/15/2005 9/20/2005 9/25/2005 9/30/2005 10/5/2005 Time 4,500 4,000 3,500 3,000 fI'j 2,500 Cl. a) ... :;: II) fII 2,000 ~ Cl. 1,500 1,000 500 Rate, BPM ---è-- Wellhead Pressure Pressure ::¡¡: 2.50 Cl. m 0,; ...- ~ 2.00 RU 6 October 2005 Rate and Pressure 4.50 4.00 3.50 3.00 1.50 1.00 0.50 0.00 0 9/25/2005 9/30/2005 10/5/2005 10/10/2005 10/15/2005 10/20/2005 10/25/2005 10/30/2005 11/4/2005 Time 4,500 4,000 3,500 3,000 CI'J 2,500 Cl. € :;: !II 2,000 ~ ~ Annulus Pressure Cl. 1,500 1,000 500 :¡: Cl. co ~ 1.00 <Þ .... ca œ: RU 6 November 2005 Rate and Pressure 2.00 1.80 1.60 1040 1.20 0.80 0.60 0040 0.20 0.00 10/30/2005 11/4/2005 o 11/9/2005 11/14/2005 11/19/2005 11/24/2005 11/29/2005 12/4/2005 Time 6,000 5,000 4,000 ëi5 Cl. c¡) 3,000 3 () () () ... Cl. 2,000 1,000 '1-- Rate, BPM I .......... Wellhead Pressure I I Annulus Pressure i 2.50 2.00 1.50 IL m 1.00 0.50 0.00 11 /29/2005 RU 6 December 2005 Rate and Pressure 12/4/2005 12/9/2005 12/14/2005 12/19/2005 12/24/2005 12/29/2005 Time 5,000 4,500 4,000 3,500 3,000 _ a' Rate, BPM ai 2,500 Wellhead Pressure H —*—Annulus Pressure L 2,000 a 1,500 1,000 500 0 1 /3/2006 CJ RU 6 January 2006 Rate and Pressure 5.00 4.50 4.00 3.50 2 IL M 2.50 2.00 1.50 1.00 0.50 4,500 4,000 3,500 3,000 cn 2,500 a Rate, BPM ti 3 —Wellhead Pressure 2,000 L +Annulus Pressure IL 1,500 1,000 500 12/29/2005 1 /3/2006 1 /8/2006 1 /13/2006 1 /18/2006 1 /23/2006 1 /28/2006 2/2/2006 Time • L_J 5.00 4.50 4.00 3.50 3.00 a m 2.50 d w 2.00 1.50 1.00 0.50 0.00 1 /28/06 RU 6 February 2006 Rate and Pressure 2/2/06 2/7/06 2/12/06 2/17/06 2/22/06 2/27/06 Time 4,000 3,500 3,000 2,500 Fn a Rate, BPM ai 2,000 3 -Wellhead Pressure H -9—Annulus Pressure L a 1,500 1,000 500 0 3/4/06 r� J • 5.00 4.50 4.00 3.50 3.00 2.00 1.50 1.00 0.50 0.00 2/27/2006 3/4/2006 3/9/2006 RU 6 March 2006 Rate and Pressure 4,000 3,500 3,000 2,500 F5 a Rate, BPM m 2,000 +Wellhead Pressure —*--Annulus Pressure L a 1,500 1,000 500 0 3/14/2006 3/19/2006 3/24/2006 3/29/2006 4/3/2006 Time • a 5.00 4.50 4.00 3.50 2.00 1.50 1.00 0.50 0.00 3/29/2006 4/3/2006 RU 6 April 2006 Rate and Pressure 4,500 4,000 3,500 2,500 a Rate, BPM a� —�—Wellhead Pressure 2,000 m --or—Annulus Pressure L a 1,500 1,000 500 0 4/8/2006 4/13/2006 4/18/2006 4/23/2006 4/28/2006 5/3/2006 Time • L_J 4.00 3.50 3.00 2.50 a m 2.00 m co 1.50 1.00 0.50 0.00 4/28/2006 RU 6 May 2006 Rate and Pressure 5/3/2006 5/8/2006 5/13/2006 5/18/2006 5/23/2006 5/28/2006 Time 4,000 3,500 3,000 2,500 rn a Rate, BPM ai 2,000 3 4 Wellhead Pressure Annulus Pressure m IL 1,500 1,000 0 6/2/2006 • #7 e e Memo to File Date: August 24, 2005 To: ERO 2 Jim Regg, Petroleum Engineer 1;"11 '31Z4'j05 From: Subject: Sampling Requirements per ERO 2.001A Enhanced Recovery Order ("ERO") 2 addresses the injection of produced water into the Redoubt Shoal Undefined Oil Pool. On July 14, 2005 the Commission issued an administrative approval (ERO 2.001A) allowing the addition of several nonhazardous fluid streams and exempt produced water from other Forest locations by blending with produced water from the Redoubt Shoal Undefined Oil Pool (Hemlock formation), namely treated sanitary waste, treated gray water from Osprey platform and camp living facilities, produced Hemlock Formation water from the West McArthur River (WMR) Oil Pool, storm water from secondary containment areas at Kustatan and WMR production facilities, and deck drainage from Osprey. Mr. Bob Elder (Forest; 907-898-2139) called August 16,2005 requesting clarification about the required sampling program addressed in ERO 2.001A. The stated purpose of the mixed fluid stream sampling requirement is to "demonstrate its non-hazardous characteristics and its continued suitability for EaR injection". The sampling point referenced in ERa 2.001A is the Redoubt Unit injection manifold. Mr. Elder's specific request was to clarify that the sampling program could be prior to commingling with produced water. His concern was even though produced water is an exempt fluid it could exhibit hazardous characteristics as noted in 40 CFR 261 (namely toxicity) and could therefore render the entire mixture hazardous. The following was considered in reviewing Mr. Elder's concerns: The Commission's intent of requiring sampling (to ensure the additional fluid streams do not exhibit hazardous characteristics); EPA 530-K-01-004, "Exemption of Oil and Gas Exploration and Production Wastes from Federal Hazardous Waste Regulations" (provides some guidance regarding mixtures- "mixing a non-hazardous waste (exempt or non-exempt) with an exempt waste results in a mixture that is also exempt"). Mr. Elder responded to my inquiries about the disposition of produced water from the WMR Oil Pool on August 24,2005. He stated that none ofthis produced water has been injected to date. In the future, WMR produced water would be transported to the Kustatan production facility and introduced into the produced water flow line that goes to the Osprey Platform. This effectively segregates all produced water from the other fluids approved by ERO 2.001A. Commingling would be downstream of the sampling point, just prior to inj ection into Well RU-6. Sampling Requirements P&RO 2.00lA August 24, 2005 e Because produced water is exempt from hazardous waste regulation under RCRA, the proper test is to determine if the blended stream of additional fluids (other than produced water) are nonhazardous. It is my interpretation that the sampling point for fluid analysis should be representative of the blended fluid stream prior to commingling with the produced water. Mr. Elder was provided clarification on August 24, 2005 by email (copy attached). 2 Clarification - EOR 2.001A e e Subject: Clarification - EOR 2.001A From: James. Regg <jimJegg@admin.state.ak.us> Date: Wed, 24Aug 2005 15:09:01 -0800 TofIBogderDe}¡:l~'iMorestoil.com> --) 01u' J{)( .. \",eft·· )( .: ., Mr. Elder - ERa 2.001A authorizes the injection of nonhazardous fluid streams in addition to produced water from the Redoubt Shoal Undefined Oil Pool. The additional fluids authorized are treated sanitary waste, treated gray water from Osprey platform and camp living facilities, produced Hemlock Formation water from the West McArthur River (WMR) Oil Pool, storm water from secondary containment areas at Kustatan and WMR production facilities, and deck drainage from Osprey. You requested clarification about the Commission's stipulated sampling of the commingled fluid stream being injected for EaR into Redoubt Shoal Undefined Oil Pool. The purpose of mixed fluid stream sampling and analysis is to demonstrate its non-hazardous characteristics and its continued suitability for EOR injection. You specifically asked about the sampling point, and suggested the proper sample point should be before commingling the other fluids with the produced water. The following were considered in reviewing your concerns: 1) The Commission's intent of requiring sampling (to ensure the additional fluid streams do not exhibit hazardous characteristics); 2) EPA 530-K-OI-004, "Exemption of Oil and Gas Exploration and Production Wastes from Federal Hazardous Waste Regulations" (provides some guidance regarding mixtures; i.e., "mixing a non-hazardous waste (exempt or non-exempt) with an exempt waste results in a mixture that is also exempt") 3) Additional details about the disposition of produced Hemlock formation waters from the WMR Oil Pool (commingled with produced water from Redoubt Undefined Oil Pool, thus segregated from the other fluids). Because produced water is exempt from hazardous waste regulation under RCRA, the proper test is to determine if the blended stream of additional fluids (other than produced water) are nonhazardous. The sampling point for fluid analysis should be representative of the blended fluid stream prior to commingling with the produced water to be consistent with the intent of the Commission-required sampling and the provisions of the RCRA exemption. Jim Regg AOGCC I of I 8/24/20053:09 PM #6 ~ e FOREST OIL e CORPORATION .J 1 0 dYC D%C(X'Æ. dj';~{:te 700 OyínchÆJrU¡¡ø, OQi'laðka .9.9/¡ 01 (907) 2.5'8-86'00 · (907) 2.5'8-86'01 (Q'Øcrr) June 20, 2005 Mr. Jim Regg Alaska Oil and Gas Conservation Commission 333 West 7tll Avenue, Suite 100 Anchorage, AK 99501 Re: Request to Include Deck Drainage in Administrative Approval ERO 2.001 Dear Mr. Regg: Forest Oil Corporation (Forest) has received Administrative Approval ERO 2.001 from AOGCC. As you are aware, that approval is for the injection of non-hazardous fluids into Class II enhanced oil recovery (EOR)wells in the Redoubt Shoal Undefined Oil Pool from five sources: 1. treated sanitary waste 2. gray water from camp or platform facilities 3. produced water from the West McArthur River Unit 4. storm water collected in secondary containment areas at the Kustatan Production Facility 5. storm water collected in secondary containment areas at the West McArthur River Unit Production Facility Originally, Forest requested approval to inject fluids from six sources: 1. treated sanitary waste 2. gray water 3. produced water from WMRU 4. produced water from the Tyonek Formation generated at KPF and West Forelands 5. storm water from secondary containment areas at KPF 6. storm water from secondary containment areas at WMRU . . Since the original request (November 5, 2004), Forest' decided that it would be. beneficial to inject another non-hazardous fluid (deck drain fluids from the Osprey Plàtform) that was not included on the original list. Currently, deck drainage is being disposed in Redoubt Unit #D1 on the Osprey under authorization of Disposal Injection Order (DIO) e . No. 22.001, issued June 19,2002. Forest also decided that it did not need to inject produced water from the Tyonek Formation generated at KPF and West Forelands. At the request of AOGCC, Forest conducted a fluid compatibility study ofthe fluids intended to be injected. The results ofthe study were submitted to AOGCC by Forest on May 6, 2005. Deck drainage was analyzed during the study, in addition to five other sources originally requested. The cover letter on the May 6 submittal referred to deck drainage as one of six sources that Forest wished include for injection into EaR. These are: 1. treated sanitary waste 2. gray water 3. produced water from WMRU 4. storm water from secondary containment areas at KPF 5. storm water from secondary containment areas at WMRU 6. storm water from secondary containment areas on the Osprey Platform (deck drain fluids) Forest appreciates AOGCC's assistance in issuing the above approval but requests that deck drain fluids be added to the approval. We apologize for the confusion created by changing the original list to include this source. Thank you for your continued assistance. Please contact me if you have questions or need additional information. Sincerely, ø~Ä 13~bElder . HSE Manager 907-868-2139 rgelder@forestoil.com #5 - , \.¡"'\ 10:42 AM Admin Approval 11/1212004 for EI02 - alternate fluids -- ~ 'ti \--- 1>J' \~ ~ ... ....¿ ~ ~ ~~~ - ::s 10:50 AM '-r\ c::::. - ...... " -. ~ ~ x ~ \.~ .\- ~ 2~ ciL ~ \;- ",.) ~ y ~ ~ ~~ - ~~ Bob Elder ~ -:---. .'\..$'\ 'l'" 'Ç; '~ ~ Forest 907 -868-2139 .,. '\. roe!dertZHoreswi1.com I left msg for him regarding Forest's admln approval request under EIO 2 (Redoubt RU-6 water flood well) and asked for return call; Forest's request to inject other than proudced water; advised we need additional justirication before can approve request - fluid compatibility with produced water and formation; volumes (estimates) of other fluid streams He returned my call; reiterated need for estimated volumes of other fluid streams and analysis of fluid compatibility with existing water flood approved in EIO 2 and compatibility with fomaUon and formation water, he will get with Forest tech staff to discuss @ . FOREST . OIL CORPORATION November 5, 2004 510 d/CQ%(+'Æt. ç~¿tè 700 QZtnchÆM(flfle, QQÝlajk<~ c9.9/i01 (907) 2,§8-86'OO · (907) 2.§8-/16'M (Q'#a.r) Commissioner John Norman Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 Re: Request for Authorization to Inject Alternative Fluids into Redoubt RU-6 Enhanced Recovery Well Dear Commissioner Norman: Forest Oil Corporation (Forest) operates the Osprey Platform in Cook Inlet. AOGCC issued Enhanced Recovery Injection Order No.2 to Forest Oil August 26, 2004. The order authorizes the injection of produced water from the Hemlock Formation into well Redoubt Unit #6 (RU-6) for enhanced oil recovery (EOR). Forest intends to begin EOR operations using RU-6 before the end of2004. Currently, produced water is being disposed in Redoubt Unit #D 1 on the Osprey under authorization of Disposal Injection Order (DIO) No. 22, issued August 9, 20001. Subsequent to the issuance ofDIO No. 22, two administrative approvals to disposal of other fluids in RUD #1 were issued by AOGCC: 1) DIO No. 22.001, issued on June 19,2002 allows the disposal of storm water collected on the Osprey deck to be injected into RUD #1, and 2) DIO No. 22.002, issued on February 3, 2004, allows treated sanitary waste to be commingled with produced water and injected into RUD #1. By this letter, Forest is requesting the Commission's authorization to inject other waters, in addition to produced water from the Hemlock Formation into RU-6 to assist in the EOR project. The other waters that Forest is seeking an administrative approval to use in EOR in RU-6 include the following: 1) Treated sanitary waste already approved for iniection into RUD #1. This is a non- exempt, non-hazardous waste that would be more beneficially used in EOR than discharged as a waste. Because all of the produced water from the Redoubt Unit will be injected into EOR, sanitary waste will become operationally difficult to inject into RUD #1 because ofthe relatively small volumes produced and the existence of only one injection line manifold. Finally, DIO No. 22.002 requires this waste stream to be commingled with produced water before it is injected into RUD #1. This will not be possible once EOR operations begin. . . 2) Gray water. Gray water from showers, laundry, and sinks is a permitted discharge under the Osprey's NPDES discharge permit. This, like sanitary waste, is a non- exempt, non-hazardous waste that could be more beneficially used in EOR than discharged as a waste. Before injection into RU-6 the waste stream will be treated for solids removal by filtration through strainers. 3) Produced water from West McArthur River Unit (WMRU). Forest Oil does not have an immediate need for additional water from WMRU for EOR but we would like to have prior authorization to inject this into RU-6 as a beneficial use of an exempt waste stream should the need arise in the future. 4) Produced water from the Tyonek Formation generated at Kustatan Production Facility (KPF) and West Forelands. Beneficial use of this exempt fluid could be made as a water source for EOR injection at RU-6. 5) Storm water from secondary containment areas around the tank farm at the KPF. This would constitute a beneficial use of collected storm water that may, at times, be commingled with small amounts of exempt fluids from the crude oil and produced water tanks at Kustatan. 6) Storm water from secondary containment areas around the tank farm at WMRU. This would constitute a beneficial use of collected storm water that may be commingled with small amounts of exempt fluids from the crude oil and produced water tanks at WMRU. Forest respectfully requests the Commission's approval to inject the above fluids into RU-6 as make-up water for the EOR project authorized under Enhanced Recovery Injection Order No.2. Please contact me if you have questions or need additional information. Sincerely, /~¿}~¿:p~ Bob Elder HSE Manager 907-868-2139 rgelder@forestoi1.com #4 " k' @ e e Forest Oil Corporation 310 K Street, Suite 700 Anchorage, Alaska 99501 (907) 258-8600 Fax: (907) 258-8601 May 6, 2005 MAY 0 9 p I.:'~ Commissioner John Norman Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Request for Authorization to Inject Alternative Fluids into Redoubt RU-6 Enhanced Recovery Well Dear Commissioner Norman: In a letter dated November 5, 2004, Forest Oil Corporation (Forest) requested the Commission's approval to inject six (6) alternate fluid sources (listed below) into Redoubt Unit #6 (RU-6) as make-up water for the EOR project authorized under Enhanced Recovery Injection Order No. 22. As a follow-up to that letter and to subsequent verbal correspondence with AOGCC staff, Forest has undertaken a fluid compatibility study ofthese various fluids. The first phase of this study was to perform a complete water analysis on each fluid type (including Redoubt produced Hemlock water). The second phase was to test the compatibility of each alternate fluid type with the produced Redoubt Hemlock water to check for precipitation. The fluids included in this study were: 1) Treated sanitary waste already approved for iniection into RUD #1. This is a non- exempt, non-hazardous waste that would be more beneficially used in EOR than discharged as a waste. Because all of the produced water from the Redoubt Unit will be injected into EOR, sanitary waste will become operationally difficult to inject into RUD #1 because ofthe relatively small volumes produced and the existence of only one injection line manifold. Finally, DIO No. 22.002 requires this waste stream to be commingled with produced water before it is injected into RUD #1. This will not be possible once EOR operations begin. 2) Gray water. Gray water from showers, laundry, and sinks is a permitted discharge under the Osprey's NPDES discharge permit. This, like sanitary waste, is a non-exempt, non- hazardous waste that could be more beneficially used in EOR than discharged as a waste. Before injection into RU-6 the waste stream will be treated for solids removal by filtration through strainers. 3) Produced water from West McArthur River Unit (WMRU). Forest Oil does not have an immediate need for additional water from WMRU for EOR but we would like to have prior authorization to inject this into RU-6 as a beneficial use of an exempt waste stream should the need arise in the future. Date Prepared: 3/12/04 AOGCC Request for EOR Fluids 5-6-05.doc '" 4) Storm water from secondary containment areas around the tank farm at the KPF. This would constitute a beneficial use of collected storm water that may, at times, be commingled with small amounts of exempt fluids from the crude oil and produced water tanks at Kustatan. 5) Storm water from secondary containment areas around the tank farm at WMRU. This would constitute a beneficial use of collected storm water that may be commingled with small amounts of exempt fluids from the crude oil and produced water tanks at WMRU. 6) Storm water from secondary containment areas on the Osprey Platform (Deck Drain fluids). This would constitute a beneficial use of collected storm and deck drain water that may be commingled with small amounts of exempt fluids from the crude oil and produced water on the Osprey Platform. Beneficial use of this exempt fluid could be made as a water source for EOR injection at RU-6. The first phase of the fluid compatibility study was to have a routine water analyses performed on each fluid source. Attached to this letter is a report from BJ Services Company showing the water analyses for the fluid sources listed above. For the second phase of the fluid compatibility study, each of the six fluid sources was mixed (proportionally to estimated monthly volumes) with produced Redoubt Hemlock water and let stand for 48 hours at a temperature of 180 degrees Fahrenheit. The mixtures were observed to see if any precipitate formed. Finally, a seventh mixture was observed, in which all six sources were mixed with Redoubt produced water. Once again this mixture was observed at 180 degrees for 48 hours. The following table shows the estimated monthly volumes of each source and the volumes that were tested the seven tests. Redoubt Fluid Compatibility Study Phase 2 - Mixing with produced Redoubt Hemlock Water Mix 1 Mix 2 Mix 3 Mix4 Mix 5 Mix6 11.0 0.18% 25.8 0.42% 30.1 0.49% 28.2 0.46% Combine the seven (7) mixtures listed in the table above and: 1) Let stand at 1800 F for 48 hours 2) ObselVe and document any precipitation fallout In all seven mixtures, no precipitates were observed when let stand at reservoir temperature (180° F) for 48 hours. Attached to this letter is BJ Services Company's report on the phase 2 fluid compatibility testing. e e Based upon the fluid compatibility testing, Forest does not believe that injection ofthese alternative water sources into the Hemlock reservoir at Redoubt Unit will create a problem, thus altering the waterflood response. Forest is thus requesting the Commission's authorization to inject other waters, in addition to produced water from the Hemlock Formation into RU-6 to assist in the EOR project. Forest respectfully requests the Commission's approval to inject the above fluids into RU-6 as make-up water for the EOR project authorized under Enhanced Recovery Injection Order No. 22. Please contact me if you have questions or need additional information. Sincerely, C?J'J11 ÙJ~ Paul M. Winslow Reservoir Engineer 907 -868-2131 pmwins10w@forestoi1.com - e e ~ BJ SERVICES COMPANY PACIFIC REGION TECHNOLOGY CENTER LABORATORY REPORT NO. STM050419A FOREST OIL REDOUBT FLUID COM PAT ABILITY STUDY REPORT PREPARED FOR: PAUL WINSLOW FOREST OIL COPR. ALASKA APRIL 21, 2005 .. e . . BJ SERVICES LABORATORY REPORT #STM050419A APRIL 21, 2005 e PAGE 2 r..:¿j SCOPE AND PURPOSE Seven different water samples from various locations were submitted for analysis to determine if there would be any precipitation when various mixtures of the waters were made. The project was initiated in order to comply with state regulations for an upcoming injection program. The samples were submitted by Paul Winslow of Forest Oil and assigned BJ Services laboratory sample number STM050419A. The results are documented below and on the page that follows. Compatibility Study Results 1. The mixtures presented below were made using water samples that were received in February 2005. 2. The samples were mixed and placed in a 180°F water bath for a period of 48 hours. Water Mix Results 9.5ml Osprey Gray water/490.5 ml RU No Precipitation Detected Produced Water 1.8 ml Osprey sewer fluid/498.2 ml RU No Precipitation Detected Produced Water 4.3 ml Osprey Deck Fluid/495.7 ml RU No Precipitation Detected Produced Water 5.0 ml KPF berm fluid/495 ml RU Produced No Precipitation Detected Water 4.7 ml WMRU berm fluid/495.3 ml RU No Precipitation Detected Produced Fluid 250 ml WMRU Produced Water/250 ml RU No Precipitation Detected Produced Water 0.94%Gray Water/0.18% Sewage No Precipitation Detected Water/0.42% Deck Water/0.49% KPF berm/0.46% WMRU berm/48.76% WMRU Produced Water/48.76% RU Produced Water Laboratory Report No.: STM050419A Reported by: Matthew Kedzierski Requested by: Location: Analyzed by: Data Integration: Distribution: Jay Garner Anchorage, Alaska Matthew Kedzierski Matthew Kedzierski Jay Garner, Region file, Lab copies e e "I( . _. r ;!~ BJ SERVICES COMPANY PACIFIC REGION TECHNOLOGY CENTER LABORATORY REPORT NO. STM050228A FORES RP. WATER ANALYSIS FOR INJECTION PROGRAM REPORT PREPARED FOR: PAUL WINSLOW FOREST OIL COPR. ALASKA MARCH 1, 2005 e · BJ SEiRVICES LABORATORY REPORT #STM050228A MARCH 1, 2005 e PAGE 2 [.:¿J SCOPE AND PURPOSE Seven different water samples from various locations were submitted for analysis to determine their compositions. The project was initiated in order to comply with state regulations for an upcoming injection program. The samples were submitted by Paul Winslow of Forest Oil and assigned BJ Services laboratory sample number STM050228A. The results are documented below and on the page that follows. Water Analysis Results Water analysis results from the water are attached at the end of this report. The samples will be retained for further testing for incompatibilities when mixed at different ratios. Laboratory Report No.: STM050228A Reported by: Matthew Kedzierski Requested by: Jay Garner Location: Alaska Analyzed by: Matthew Kedzierski, Chris Jamison Data Integration: Matthew Kedzierski Distribution: Jay Garner, Region file, Lab copies The above data is supplied solely for informational purposes and BJ Services Company makes no guarantees or warranties, either expressed or implied, with respect to the accuracy or use of this data. All product warranties and guarantees shall be governed by the standard contract terms at the time of sale. .. e e PAGE 3 ~ BJ SERVICES LABORATORY REPORT #STM050419A APRIL 21,2005 The above data is supplied solely for informational purposes and BJ Services Company makes no guarantees or warranties, either expressed or implied, with respect to the accuracy or use of this data. All product warranties and guarantees shall be governed by the standard contract terms at the time of sale. e BJ SERVICES LABORATORY REPORT #STM050228A MARCH 1, 2005 e PAGE 3 ~ B J Services Water Analysis m Date: 3/1/05 Company: Forest Oil Lease: State: Alaska Analyst: C. Jamison pH: Specific Gravity: 6.21 1.0010 CATIONS mg/I Sodium (calc.) Calcium Magnesium Barium Potassium Iron 712 16.84 11.7 < 25 59.4 < .5 ANIONS Chloride Sulfate Carbonate Bicarbonate 1183.2 < 20 < 1 63.4 Total Dissolved Solids(calc.) 2047 Total Hardness as CaC03 90.1 Resistivity (ohm-meters--calc.) 2.423938 Scale Index: CaC03 SI = -2.54 CaS04 %KCI (based on potassium) 0.0 Stiff Plot 05 04 03 02 01 00 01 Na&K Ca Mg , -:-:~L:l~t . ·1 CI HC03 . S04 ! [~:..-.- Sample #: Well#: County: Date: H20 type: STM050217A Osprey Deck Drains Temp (F): 68 mell ppm 31.0 711 0.8 16.83 1.0 11.7 1.5 59.3 33.4 1182.0 1.0 63.4 2045 1.8 90.0 SI = #VALUEI 02 03 04 05 .. ! e BJ SERVICES LABORATORY REPORT #STM050228A MARCH 1, 2005 e PAGE 4 ~ B J Services Water Analysis Ii] Date: 3/1/05 Company: Forest Oil Lease: State: Alaska Analyst: C. Jamison Sample #: Well#: County: Date: H20 type: STM050217A Osprey 9-Feb Gray Water pH: Specific Gravity: 6.32 1.0000 Temp (F): 68 CATIONS mg/I mell ppm -215 -9.3 -215 24.86 1.2 24.86 19.9 1.6 19.9 32 0.5 32 461.1 11.8 461.1 1.4 0.0 1.4 Sodium (calc.) Calcium Magnesium Barium Potassium Iron ANIONS Chloride Sulfate Carbonate Bicarbonate 61.2 15 < 1 229.4 1.7 0.3 61.2 15 3.8 229.4 Total Dissolved Solids(calc.) 630 630 Total Hardness as CaC03 144.1 2.9 144.1 Resistivity (ohm-meters--calc.) #NUM! Scale Index: CaC03 SI=-1.43 CaS04 SI = -3.46 %KCI (based on potassium) 0.1 Stiff Plot 05 04 03 02 01 00 01 02 03 04 05 Na&K Ca , i ...-. ..--.-+-----.-- I I .. -.. ---·-T- .. .-.-.--.!--....-. --.. . ! ! ! ..._.1.... ___j_____... .1 CI HC03 S04 Mg =-~ n~~ ~-_+ e BJ SERVICES LABORATORY REPORT #STM050228A MARCH 1, 2005 e PAGE 5 r ;!Á B J Services Water Analysis m Date: 3/1/05 Company: Forest Oil Lease: State: Alaska Analyst: C. Jamison pH: Specific Gravity: 7.40 1.0020 CATIONS mgll Sodium (calc.) Calcium Magnesium Barium Potassium Iron 457 60.15 32.1 <25 65.6 <.5 ANIONS Chloride Sulfate Carbonate Bicarbonate 316.2 74 < 1 1024.8 Total Dissolved Solids( calc.) 2030 Total Hardness as CaC03 282.3 Resistivity (ohm-meters--calc.) 3.854787 Scale Index: CaC03 SI = 0.58 CaS04 %KCI (based on potassium) 0.0 Stiff Plot 05 01 04 03 02 01 00 Sample #: Well#: County: Date: H20 type: STM050217A Osprey Treated Sanitation Temp (F): 68 mell ppm 19.9 456 3.0 60.03 2.6 32.0 1.7 65.4 8.9 1.5 315.6 74 16.8 1022.8 2025 5.6 281.7 SI = -2.46 02 03 04 05 ",'I"~ Na & K ;______.n ..-- ___1 - I i CI Ca t····m --, - ..__m____-+ . . HC03 Mg l___~~~ __:::.:L 'm:_ I ',' _ ___ ! 804 e BJ SERVICES LABORATORY REPORT #STM050228A 'MARCH 1, 2005 e PAGE 6 r.:¿J B J Services Water Analysis m Date: Com pany: Lease: State: Analyst: 3/1/05 Forest Oil Alaska M. Kedzierski pH: Specific Gravity: 5.96 1.0015 CATIONS Sodium (calc.) Calcium Magnesium Barium Potassium Iron ANIONS Chloride Sulfate Carbonate Bicarbonate Total Dissolved Solids( calc.) Total Hardness as CaC03 Resistivity (ohm-meters--calc.) Scale Index: CaC03 SI = #VALUEI CaS04 %KCI (based on potassium) Stiff Plot 05 04 03 02 01 00 ------+-.-.--.. --...--- !------+----: - --t-- Mg l==1_.__.1.._.........-L. Na&K Ca 18.73702 #VALUEI 01 ...-;........----- Sample #: Well#: County: Date: H20 type: STM050228A KPF 9-Feb KPF Secondary Containment Temp (F): 68 mgll mell ppm 18 0.8 18 < .5 < .5 < 25 <10 < .5 10.2 <20 < 1 29.3 0.3 10.2 0.5 29.2 57 57 0.0 0.0 0.0 SI = #VALUE! 02 03 04 05 I .,L_.. ........ i i i .r _'~._._:J.. . . ---1 CI -------j HC03 I ¡ 804 ¡ ; e BJ SERVICES LABORATORY REPORT #STM050228A MARCH 1, 2005 e PAGE 7 [.:¿J B J Services Water Analysis m Date: Company: Lease: State: Analyst: 3/1/05 Forest Oil Alaska M. Kedzierski pH: Specific Gravity: 6.50 1.0090 CATIONS mgll Sodium (calc.) Calcium Magnesium Barium Potassium Iron 3500 1379.44 34.0 < 25 53.5 2.0 ANIONS Chloride Sulfate Carbonate Bicarbonate 7344.0 35 < 1 1098.0 Total Dissolved Solids( calc.) 13446 Total Hardness as CaC03 3584.9 Resistivity (ohm-meters--calc.) 0.508522 Scale Index: CaC03 SI = 0.47 CaS04 %KCI (based on potassium) 0.0 Stiff Plot Sample #: Well#: County: Depth: H20 type: STM050228A RU-5 Produced from Redoubt Hemlock Temp (F): 69 mell ppm 152.2 3468 68.8 1367.14 2.8 33.7 1.4 53.1 0.1 2.0 207.2 0.7 7278.5 35 18.0 1088.2 13326 71.6 3552.9 SI=-1.82 10 09 08 07 06 05 04 03 02 01 00 01 02 03 04 05 Na&K Ca It _. _,..__ ---+-______ ¡ ... .~ -- _. .. -- -.. l' Mg t----t... ·----1,-- -- ;: --1- - 1-- L_..o...-._____. _~...o __..__--..L... .J... ......._~L..._..l.... _......_.:.. ~~~ ~-- --' CI I HC03 -1___--1 504 _.1."..1 '" " e BJ SERVICES LABORATORY REPORT #STM050228A 'MARCH 1, 2005 e PAGE 8 [.:¡j B J Services Water Analysis Ii] pH: Specific Gravity: 5.96 1.0020 Sample #: STM050228A Well #: WMRU County: Depth: H20 type: WMRU Secondary Containment Temp (F): 68 Date: 3/1/05 Company: Forest Oil Lease: State: Alaska Analyst M. Kedzierski CATIONS mgll mell ppm 14 0.6 14 < .5 <.5 < 25 < 10 <.5 Sodium (calc.) Calcium Magnesium Barium Potassium Iron ANIONS Chloride Sulfate Carbonate Bicarbonate 10.2 < 20 < 1 19.5 0.3 10.2 0.3 19.5 Total Dissolved Solids(calc.) 44 44 Total Hardness as CaC03 0.0 0.0 0.0 Resistivity (ohm-meters--calc.) 20.14507 Scale Index: CaC03 SI = #VALUE! CaS04 SI = #VALUEI %KCI (based on potassium) #VALUEI Stiff Plot 05 04 03 02 01 00 01 02 03 04 05 I i t· . -:. CI -=_t_-="_~Jj-j ~~~3 Na&K Ca t----t-- . 0" -- __u_ I ¡ ¡ ----r---~~:-~-=-t---r--· Mg Co_L_____L...._L. .....1. .. e BJ S'ERVICES LABORATORY REPORT #STM05022BA ·MARCH 1, 2005 e PAGE 9 [:¿j B J Services Water Analysis m Date: 3/1/05 Company: Forest Oil Lease: State: Alaska Analyst: M. Kedzierski Sample #: STM050228A Well #: WMRU County: Depth: H20 type: WMRU Produced pH: 6.98 Temp (F): 68 Specific Gravity: 1.0205 CATIONS mg/l mell ppm Sodium (calc.) 4409 191.8 4321 Calcium 4812.00 240.1 4715.34 Magnesium 364.5 30.0 357.2 Barium < 25 Potassium 69.9 1.8 68.4 Iron <.5 ANIONS Chloride 15963.0 450.3 15642.3 Sulfate 36 0.8 35 Carbonate < 1 Bicarbonate 817.4 13.4 801.0 Total Dissolved Solids(calc.) 26472 25940 Total Hardness as CaC03 13517.5 270.1 13246.0 Resistivity (ohm-meters--calc.) 0.254269 Scale Index: CaC03 SI = 1.08 CaS04 SI = -1.45 %KCI (based on potassium) 0.0 Stiff Plot 05 04 03 02 01 00 01 02 03 04 05 Na&K Ca Mg ~""'4"r1;~; ',,~\,.!.~.7~·0?~'· I !dd'J,.,¿~ . -- .,..,...... .',.,. .-...... - . u' ."-. ..... "'1 I~"'''''' 'CI =--~--~---i -+ +_! ~.. :~.~ HCO' ·.___L.___..L .._.~_._=.;._._~-- h._~~-j .~-=t.--j:.__...t_..... 804 #3 . . CONFIDENTIAL INFORMATION LOCATED IN CONFIDENTIAL ROOM #2 STATE OF ALASKA . NOTICE TO PUBLISHER . ADVERTISING ORDER NO. ADVERTISING INVOICE' T BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., _ ;TIFIED AO-02414045 ORDER AFFIDAVIT OF PUBLICATION (PART2 OF THIS FORM) WITH ATTACHED COPY OF ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE SEE BOTTOM FOR INVOICE ADDRESS F AOGCC '\(;I'::\C," C{)Vr.\CT ) \...1 OF \.0. R 333 W 7th Ave, Ste 100 Jodv Colombie June 24 2004 0 Anchorage,AJ( 99501 PHONE PCN M - I (907) 793 -1221 DATES ADVERTISEMENT REQUIRED: T Anchorage Daily News June 25, 2004 0 POBox 149001 Anchorage, AJ( 99514 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: STOF0330 Advertisement to be published was e-mailed Type of Advertisement X Legal D Display D Classified DOther (Specify) SEE ATTACHED SEND INVOICE IN TRIPLICATE I AOGCC. 333 \\'. 7th A\·c.. Suitc 100 PAGE 1 OF TOTAL OF ~I TO Anchoragc. AK 9950 I 2 PAGES ALL PAGES$ REF TYPE NUMBER AMOUNT DATE COMMENTS 1 VEN 2 ARD 02910 3 4 FIN AMOUNT SY CC PGM LC ACCT FY NMR DIST LID 1 04 02140100 73540 2 3 4 REQUISITIONED BY,;. .. J. (7 ;:r' ¡ 1M ¿ IDIVISION APPROVAL: ( ¡ , ./'~~ ,-/' ./ . ( /,¡. - 02-902 (Rev. 3/94) Publisher/Original Copies: Department Fiscal, Department, Receiving AO.FRM · e Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: The application of Forest Oil Corporation ("Forest") for an order to allow produced water to be reinjected for enhanced recovery purposes into the Hemlock Formation of the Redoubt Shoal undefined oil pool. Forest Oil Corporation by letter dated June 14, 2004 has applied for an enhanced recovery order under 20 AAC 25.402 to allow pilot produced water injection at approximately 3800 to 4300 psi into Redoubt Unit No.6 at depths betweenl5130 and 15890 feet MD in the Hemlock Formation. The surface location of the well is 1909 feet from the south line and 318 feet from the east line of Section 14, T7N, R14W, SM. The bottomhole location is 113 7 feet from the north line and 1518 feet from the east line of Section 19, T7S, R13W, SM. The Commission has scheduled a tentative public hearing on this application for August 10, 2004 at 1:00 pm at the Alaska Oil and Gas Conservation Commission, 333 West ih Avenue, Suite 100, Anchorage, Alaska 99501. A person may request that the scheduled tentative hearing be held by filing a written request with the Commission no later than 4:30 pm on July lih, 2004. If a request for a hearing is not timely filed, the Commission will consider the issuance of an order without a hearing. To learn if the Commission will hold the public hearing, please call 793-1221. In addition, a person may submit written comments regarding this application to the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. Written comments must be received no later than 4:30 pm on July 28, 2004 except that if the Commission decides to hold a public hearing, written protest or comments must be received no later than the conclusion of the August 10, 2004 hearing. If you are a person with a disability who may need a special modification in order to comment or to attend the p . he , lease contact Jody Colombie at 793-1221 before August 5, 2004. Published Date: June 25, 2004 ADN AO# 02414045 . . Anchorage Dally News Affidavit of Publication 1001 Northway Drive, Anchorage, AK 99508 . PRICE OTHER OTHER OTHER OTHER OTHER GRAND AD# DATE PO ACCOUNT PER DAY CHARGES CHARGES #2 CHARGES #3 CHARGES #4 CHARGES #5 TOTAL 208462 06/25/2004 02414045 STOF0330 $169.36 $169.36 $0.00 $0.00 $0.00 $0.00 $0.00 $169.36 STATE OF ALASKA THIRD JUDICIAL DISTRICT Teresita Peralta, being first duly sworn on oath deposes and says that she is an advertising representative of the Anchorage Daily News, a daily newspaper. That said newspaper has been approved by the Third Judicial Court, Anchorage, Alaska, and it now and has been published in the English language continually as a daily newspaper in Anchorage, Alaska, and it is now and during all said time was printed in an office maintained at the aforesaid place of publication of said newspaper. That the annexed is a copy of an advertisement as it was published in regular issues (and not in supplemental form) of said newspaper on the above dates and that such newspaper was regularly distributed to its subscribers during all of said period. That the full amount of the fee charged for the foregoing publication is not in excess of the rate charged private individuals. Signed eJryMdfaJ Subscribed and sworn to me before this date: Iii'" " I ;". /1 ,..-- 1 ;ry) ,) ,~_,.f_,,'i,' ( ,~'l,,,,¡ Notary Public in and for the State of Alaska. Third Division. Anchorage, Alaska , I i MY COMMISSION EXPIRES: (Vi /! ) / ,Ç/YY7 )) ¡ ,1 c' l;:¡ ;' J /~ß.r~l /) /( J) 1 f'\ If. ¡:( ;,1,(" L / I /,,\ v(iHfi V .. . I' I / r/ /- f / J~ L./ \\\1(( \.\\ ,\. . . $:';:;" '" ~,,« .... ...::: .... ... Notice of. Put¡lic Heoring STATE OF ALASKA Alasko Oil and Gas Conservation Commission Re: The application of Forest Oil Con>oråtlon ("Forest") for an order to Ollow produced W(lter to be reiniected for enhanted recovery purposes Into the H.emlock Formotion of the Redoubt Shoal undefined oil pool. Fores/Oil Corpøration bY letter dated June 14 2004 has appl ied for an enhanced recovery order' !,,!der.20 AAC 25.402 to alloW pilot produced water Inlectlon at approximatelY 3800 to 4300 psi into Re- doubt Unit No.6 at depths between15130 and 15890 feet IyID in the Hemlock Formation. The surfåce location of the well Is 1909 feet from the south line and 318 feet from the east line Of 5ectionI4, T7N, RI4W, SM. The" d. ... .. .. .]feet from t~e north. . east line of Section 19, T... "'0'" ~.... The Commission ho~ scheduled 0 tentative pUb. lie heoring .on this application for August 10, 2004 at 1 :00 pmot the Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Suite 100, An- chorage, Alasko 99501. A person may reqUest that th~ scheduled tentative hearing be held bYfiiin9 a written request with the Commission. no la. ter than 4:30 pm on July 12th, 2004. I . If a reqUest for a hearing is not timely filed the C~mmisslon w!" consider the issuance. of ån .órder wIthout a hearing; To learn i!the Commission will hold the public hearing, please call 793-1221. ~~~~::~~¡r.:, ~':~~~r5,~t~.:::?J;::;·~~:Z;~··~;7~1~ Avenue, Suite 100, Anchorage, Alo$ka 99501. writ- ten comments must be received no later thon 4:30 PM.on JUly 28, 2004 except that If the Commission decides to hold a public hearing, written protest or ' comments must be recE!Îved no later than the Con. clusion of the August 10, 2004 hearing. l/You area person with a disability who may need a special modification in order to tomment or to attend the PUblic hearing, please contact JodY Colombie at 793-1221 before August 5,2004. John K. Norman, Chair Com'missioner ADN AO# 02414045 Publish: June 25, 2004 {!<"ì .... RE: Notice . . Subject: RE: Notice From: legalads <legalads@adn.com> Date: Thu, 24 Jun 2004 14:42:55 -0800 T(): ¡ódy Colombie <jody~co1oWº~e@aðtninJ3tate.ak.us> Hi Jody: Following is the confirmation information on your legal notice. Please let me know if you have any questions or need additional information. Account Number: STOF 0330 Legal Ad Number: 208462 Publication Date(s): June 25,2004 Your Reference or PO#: 02414045 Cost of Legal Notice: $169.36 Additional Charges Web link: E-Mail Link: Bolding: Total Cost to Place Legal Notice: $169.36 Ad Will Appear on the web, www.adn.com: XXXX Ad Will Not Appear on the web, www.adn.com: Thank You, Kim Kirby Anchorage Daily News Legal Classified Representative E-Mail: lega1ads@adn.com Phone: (907) 257-4296 Fax: (907) 279-8170 ---------- From: Jody Colombie Sent: Thursday, June 24,200412:31 PM To: legalads Subject: Notice «File: Ad Order form.doc»«File: Forest Pilot Proiect.doc» Please publish 6/25/04. Jody lofl 6/24/20043:38 PM STATE OF ALASKA ADVERTISING ORDER' SEE BOTTOM FOR INVOICE ADDRESS . NOTICE TO PUBLISHER" ADVERTISING ORDER NO. INVOICE , ST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO~TIFIED AO 02414045 AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COpy OF . ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE F AGENCY CONTACT Toc!v ~, ,. PHONE (Q07) 7Q1 -1')') 1 DATES ADVERTISEMENT REQUIRED: DATE OF A.O. AOGCC R 333 West 7th Avenue, Suite 100 o Anchorage, AK 99501 M 907-793-1221 Tnnf': ')4 ')004 PCN T o Anchorage Daily News POBox 149001 Anchorage, AK 99514 June 25, 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 02-901 (Rev. 3/94) Page 2 AO.FRM PUBLISHER Public Notice e . From: Jody Colombie <jody _ colombie@admin.state.ak.us> Date: Thu, 24 Jun 2004 12:40:32 -0800 To:,un4i~losed;'recipÌ<ID.ts¿;"'" ......, ." .. .':>,~;i::.. BCCiRoQert E Mintz <:robërt mintz@law.state.ak.us>, Christine Ham¡êiì:;;~ ):C,,~_en@iogcc.S~~~î$~;: Terrief.Illbble <hl;\bbletl@bltcortt>, Sondt~::Ste~man ~~SD@BP.cOXlt>;Scott& Cammy Taylor <staylor@alaska.net>, stanek] <$tånë i', "0 ... >, ecolaw<ecolaw@trustees.org>, toseragsdale <roseragsdale@gci.net>, trmjrl <trmjr( '/~~;>:,;. ." , jbriddle <jbti.ddle@marathonoi1.com>, rockhill<rockhill@aoga.org>, shaneg <shaneg@êvergreengas.com:>, jdarJ~on..<jdarlington@forestøi1.com>,inelson <netson@gci.net>,.. cboeJd . ;~ddY@usibelli.com>, Mark Da.Ìton <mark;d~tö\1@hQ¡inc;~",ShàtJndrt~~lly.. ~¡dOl>l1~ll~:::;::~;~::;:~:¡j::,~'c;, " <jerry.c.d ;-,:. onoc0J>hillips~oom:>, Bob <bob@it¥etk~pe1;~rg> ,V\'9:¥,,~wdv@dnr;~.'ak:us>, tjr <tjr@4m"~~t¢;åk.llS>, :bbritch <bbXi~ch@~a$£a.neq; mjrielson <mjnélson@purvingertz,,~'t2~t.. . Ch~l~s OÐonnell <charles;o'donnell@yecöicom?, "Rándy L Skil,lern" <Skt!leRL@BP.com>,'/·>·· ~šxme:H. Dickey" <:DickeyJH;@BP.có'rh>,"Debörah J.¡()nè'~1 <j9~esD6@BP.com>, "Paul G. H:yaW' <!thyattpg@llJ>.com>, "Stè'Vtm R. R()ssbergi' 5RossbeRSt@BP;'com>, Lois. .,..«i!,<'>:'" <lois@þílrtKêêpéEörg>, "JosepbF. Kirchner" <KirchrµF@BP:com>,GórdonPospisil' .... <pospîsG@BP.com>,'(.f1JØéis S. Sonuner"<SommerFS@BP.com>, MikelSchultz $Mi.ke1.Schultz@B~wm>, "Nick W. ~lov~r" <GloverNW@BP.:~om>,'i]jâryl J. Kleppin" <:KleppipE@BP.com>; "Janet.::p. PlattUkPlattJD@BP.ê:om>;'·"Rosanne M. J,acobsen" <Jacob$RM@în~:9;~pl>, ddonk~I <ddonkj(:l@cfl.rr;Óom> t Co,lµns~ount .' ".0'. <collins _Ií1oul1~venue.state.*'Ps>, mckay <mckay@gcLrtet>,Barbara F Fullmer·/ . .. . .....~ :..... . . v<" " "," ... . . . <barbara.f:ful~'f@conocophil~Ws;com>, bocastwf <bo~astwf@bp.com>, . Charles Barker.. <barker@'ijSgS',goÿ>, doug_ schüJtze <doug_ schult,ze@xtoenergy.com>, H~ Alford <hahk.£Ùford@eX?'~nniobil.com>; MarkI<.ovac <yesnol@gct.net?;:, gspfoft: .....",:'.. '. ~~,¥,f~auf(~tapower.com>, gr~gg Nady <gre~;l)ady@shell.com>, Fred,:Steece ,.., ~frêiJ';$e.~'tàte.sd.us>, rcro~Y;,<:rcrotty@ch2m'£öm>, jej9nes<jejones@aurorapowe9~om>, dapa . ..' ~ ~r-0 . . . ..' . . .. . . . ..... . "$:.:; . <dapa@alm;káf~~, jroderick ~d~rick@gcLne~>, ~y~cy 1eya#cy@seal-tite.net>,,!lJ~·M. Ruud" <james:~d@ConocöPhilhps;cþm>, Bnt LIvely <qï.apaJ,aska@ak.net>,jah';\:>;0;;', <jah@dnfstatê:;}(;Ì1s>, Kurt E Olson <krirt _ Ólson@legis.state.aldus>, b1J~nojë<buoIlöjë@bp.com>,.· Mark Hanley <m~, hanley@anadarko.êom>, IQren _leman<lot~n _lert:1Ø,r1@gov.state.ak.us>, Julie ..' Houle ~l1li~~..þouŒ@dnr,st~te.*:us>, John W K~tz <jWkatz@sso.org>;'S'Üzan},ßJll,/.:.:-: <suzan l~iU@dec.st~!~~,,~ij~j(,tablerk <tablerk@Unoqll.com>,.J3rady,<brady@àol~â;'þ~g>, 'Brian ff~y~19c~ <beh@dnf:sfåt~:àk:us>, bß<Jpp <þpoþp@borou~.kena.Lak..Us>; Jim"W~~~,;,,;::: '" ~jiiW}1Ïte@satx,J1"COm>, "Jòhn ,S:.;a.aworth",ç:john2&:hawõrth@exxö:riïnobil.¿oin>~ marty ~~~:~t.Jt~'~~c#r1:~~~~~~~~7+9IIài'.. <mkm720()@aph99m>,Bnan QîlfespIe <:ltbnig@uaa.alaska.edu>,DavId L Bt>elens ·:;':0>' <dboelþ$@åûtórà{jower.com>, eJd D19'Jcee:-<TI):T1RK~f@iMQ:,com>, Gary Schultz . :i¿:tt::~~~~Ë~S~?~~t~~f~: .,:" .~ . Forest_Pilot_prOject.doc Content-Type: . ..-.......-.-....--...¡ i applicationtmsword ·1 ¡ lof2 6/24/2004 12:41 PM Notice e e Subject: Notice From: Jody Colombie <jody _ colombie@admin.state.ak.us> Date: Thu, 24 Jun 2004 12:39:20 -0800 To:'ùndisclosed-recip,~~~~, ' ,,<,'<, """, BCC:~Angela Webb',~~~' webb@adniin.state.ak.us>, Cynthia B Mciver <br~íìLmciver@å&ìríili;š#it~;'tJs> "',.' ",., ., '," Please publish on the web site. Jody ........... .......... ............. ............. :r Content-Type: applicationlmsword 11 I Forest_Pilot_Project.doc i Content-Encoding: base64 I .........._.............__.......___._...._....___ ..................mm..mmm...............mmm............mmm.............................. mon........................................_... ..........mmm..........mmm.............mmm.........mmm_ :::':.::::::'::::::'.~'J 1 of 1 /:"; 6/24/2004 12:41 PM Notice e e Subject: Notice From: lody Colombie <jody _ colombie@admin.state.ak.us> Date: Thu, 24 100 2004 12:31:18 -0800 ~~:te,Ø':}\d~bhorage Daily Ne~~:~legålads@adn,com~,:,: .\-: Please publish 6/25/04. Jody . ...... ........ Content- T\'pc: appl ication.'msword ¡Ad Order form.docl ~! ¡Content-Encoding: base64 i ,'1,__ i 1--· ~---_.._------------------ Cont~~~=T;~~: -------~~~iï~~~i~~~~;'~;d'-I I. Forest_Pilot_Project.doc ' Content-Encoding: base64 i ......................-......... ....................---...............--. ...................................... ;.;;;..;;;.....;;.....;..........:.1 1 of 1 6/24/2004 12:41 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 e Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 .. David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 Robert Gravely 7681 South Kit Carson Drive Littfeton, 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 3940 Arctic Blvd., Ste 300 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 lI/æi!Jf{j / #1 @) June 14,2004 e . Forest Oil Corporation 310 K Street, Suite 700 Anchorage, Alaska 99501 (907) 258-8600 Fax: (907) 258-8601 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Application for Enhanced Recovery Pilot Proiect Redoubt Unit Gentlemen: Enclosed is Forest Oil Corporation's Application for an Enhanced Recovery Pilot Project for Redoubt Unit. The application conforms to regulations specified under the Alaska Administrative Code, Title 20 - Chapter 25, Article 05. More specifically the application conforms to the Enhanced Recovery Operations regulations specified by 20 AAC 25.402(c). If there are any questions, please contact me at 868-2131. Sincerely, C?ir¡;1~ Paul M. Winslow Reservoir Engineer Forest Oil Corporation cc: Leonard C. Gurule, Senior V.P. - Forest Oil Corporation e e Redoubt Unit Enhanced Recovery Operations Pilot Project Application Forest Oil Corporation June 14, 2004 There are two (2) wells with Hemlock penetrations within a 'l4 mile radius of the proposed injection interval in RU #6. The top Hemlock penetration point for RU #7 is approximately 1,310 ft ftom the top penetration point in RU #6. The bottom hole locations for these two wells are approximately 835 ft apart. Similarly, the top Hemlock penetration point for RU #6 is approximately 940 ft ftom the top penetration point for the abandoned Redoubt Shoal State 29690 #2 wellbore. The bottom hole locations are roughly 1,390 ft separated. RU #6 is currently a Hemlock oil producing well, which will be converted to an injection well most likely in June or July, 2004. The conversion is likely to coincide (directly proceeding) with an electrical submersible pump (ESP) change-out on RU #2. This enhanced recovery application is being submitted in order to obtain approval for injection into RU #6 shortly after its conversion of servIce. Note that all of the Redoubt Unit wells have been drilled directionally ftom the Osprey Platform, which is located approximately 1.5 miles west-northwest of the crest of the Redoubt Shoal Structure. Redoubt Unit #6 (RU #6), located in the "Central Fault Block" of the Redoubt Shoal Structure, is the proposed injection well for the Enhanced Recovery Pilot Project. This is the only injection well proposed at this time. ill addition to the nine (9) Forest/Forcenergy Hemlock penetrations, there were three (3) more wells drilled directly on the Redoubt Shoal structure in 1967, 1968, and 1976 (Redoubt Shoal State 29690 #1, Redoubt Shoal State 29690 #2, and Redoubt Bay Unit #1, respectively) and two (2) additional wells drilled on the southwest flank or panhandle in 1967 (Redoubt Shoal State 22064 #1 and Tenneco State 36465 #1). All five (5) of these wells were plugged and abandoned, prior to drilling by F orest/Forcenergy. Attached are two plats showing the location of all of the wells currently drilled on the Redoubt Shoal structure. Eight (8) wells have been drilled by Forest Oil Corporation (Forest) and/or Forcenegy illc., of which five (5) are currently producing ftom the Hemlock reservoir (RU #1, RU #2, RU #5A, RU #6 and RU #7). ill addition to the five producing wells, there is one (1) disposal well (D-1), one (1) shut-in G-zero gas well (RU #3, which was re-comp1eted up hole ftom the Hemlock), and one (1) suspended wellbore (RU #4A). Two (2) of the wells (RU #5A and RU #4A) are sidetrack locations, thus the total number of Hemlock penetrations by Forest/Forcenergy is nine (9) wellbores. 1) Location Plat 20 AAC 25.402(c) Enhanced Recovery Application e e ¡ 5 5 24 1 31 :24000 FEET STATUTE ~OO I 7 íJj ; ø z cc " 33 St 36465 34 '.):c:; 36 32 33 34 e' R 8 28 27 22 RS 26 23 25 RU 3 30 29 28 27 22 1 RB , O~prey 8 ø 7 35 ø 36 23'i:BØØ S McArth U o Riv A 12302 216000 - -- --- 32 4 33 220Ø øø 34 0' 5 200 000 205 000 210 000 21 5 000 OJ 0 0 -Þ R14W L (".J f::¿1 , t 12 7 to..) 8 -Þ (Jl (Jl 0 0 0 Unit nd L 1203 T7~~ OJ 0 0 -Þ to..) to..) 13 , -Þ 17 (Jl 0 0 0 0 to..) OJ -Þ 0 -Þ 20 0 (Jl -Þ 0 ~ , 0 0 L 7400 to..) -Þ -Þ FOREST OIL CORPORATION 0 30 0 Alaska Business Unit 29 0 1 :31680 OJ 0 0 Redoubt Unit FEET 0 5000 FEET 0 I -Þ 0 STATUTE MILES 0 .5 1.0 , Well Locations STATUTE MI S mu 1 N 2640~ -- NAD27. ASP ZONE 4 -151040/ -151°3W -151 °36/ e e 2) Offset Surface Owners and Operators The only surface owner within a one-quarter mile radius of either the Osprey Platform, which is the surface location of the RU #6 well, or the bottom hole location of the RU #6 well is the State of Alaska. The surface owner's lands are managed by the Department of Natural Resources, Division of Mining, Land & Water. Forest is the only operator of any wells within a one-quarter mile radius of either the Osprey Platform or the bottom hole location of the RU #6 well, into which the water injection will occur. 3) Affidavit Showing Notification of Other Operators and Surface Owners The following affidavit it provided to verify that a copy of this application has been sent to the State of Alaska, the Department of Natural Resources, Division of Mining, Land & Water, being the manager for the State of Alaska. e e TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Alaska Oil and Gas Conservation Commission In the Matter of the Application of Forest Oil Corporation for Injection For Enhanced Recovery Operations Subject to the provisions of 20 AAC 25.402 VERIFICATION OF FACTS AND AFFIDAVIT OF JIM ARLINGTON Jim Arlington, being first duly sworn, upon oath, deposes and states as follows: 1. My name is JIM ARLINGTON. I am over 19 years old and have personal knowledge of the matters set forth herein. 2. I am the Land Manager for the well operator, Forest Oil Corporation (FOREST). 3. I am acquainted with the facts associated with the application of Forest Oil Corporation for an application for injection for enhanced recovery operations pursuant to the provisions of 20 AAC 25.402 as they pertain to the proposed enhanced recovery operation involving water injection in the Redoubt Unit #6 well. 4. The only surface owner within a one-quarter mile radius of either the Osprey Platform, which is the surface location of the RU #6 well, or the bottom hole location of the RU #6 well is the State of Alaska. The surface owner's lands are managed by the Department of Natural Resources, Division of Mining, Land & Water. 5. Forest is the only operator of any wells within a one-quarter mile radius of either the Osprey Platform, which is the surface location of the RU #6 well, or the bottom hole location of the RU #6 well. 6. On June 14,2004, pursuant to 20 AAC 25.402 (c), FOREST sent a copy of its application for injection by United States mail to the State of Alaska, the Department of Natural Resources, Division of Mining, Land & Water at 550 W. 7th Avenue, Suite 1070, Anchorage, Alaska 99501. Subscribed and sworn to on June d, 2004. STATE OF ALASKA ) ) ss. THIRD JUDICIAL DISTRICT ) ., :;:..1 On this ~ day of June 2004, before me, the undersigned, a Notary Public duly commissioned and sworn, appeared Jim Arlington, personally known to me, to be the person whose name is subscribed to within the Verification of Facts and Affidavit. ,,\\\ ,\ \1111I '1/// '\\' Eo. Tit '~ ::e,Y. · · .Oì~ , yo. ... ....-: ~ . ~~. 0 "'(",Ijt .,:1eP"ª ~~."!IÞ ,'" · := :: .~ fI/IIIJ. CJ. = ;:;:.$.. ~UB\. ~ ·s::::: ~. "" . ,."Jio' :::: ~. ., ~~ ~ ~ · · · · -:!V....'5:f:. ~ ~'1'£ Of ~~~ 1111/lIIn\\\\\\: The Hemlock formation is the only formation currently producing oil at Redoubt Unit and is the proposed formation for this enhanced recovery operation. The description, depth, and thickness of the Hemlock formation at Redoubt Unit and the appropriate geologic data including lithologic descriptions and geologic names have been previously submitted to AOGCC as a part of the "Redoubt 6) Injection Formations The Redoubt Unit Hemlock oil pool is the only pool which will be effected by this proposed enhanced recovery project. Injection into RU #6 is expected to support pressure and enhance the recovery from RU #1, RU #7, and possibly from RU #2. The nearest producing well to the proposed RU #6 injection well, is RU #7 which is completed in the Hemlock formation from 11,633' - 12,168' SSTVD. RU #1 is completed in the Hemlock formation from 11,680' - 12,292' SSTVD. RU #6 is currently completed and producing from the Hemlock formation over the interval 11,696' - 12,304' SSTVD. 5) Pools to be Affected This application is requesting approval to initiate an enhanced recovery pilot project to inject produced Redoubt water into the RU #6 well. Currently the produced water at Redoubt is disposed of in the Redoubt Unit D-1 disposal well, located on the Osprey Platform. RU D-1 is a 8,611' (TD) vertical well with an approved disposal zone in the Tyonek formation at 8,216' - 8,450' ft SSTVD. This injection well will remain operational as a back- up for produced water disposal should RU #6 have mechanical problems. Just prior to the electrical submersible pump (ESP) going down in RU #2, the water produced rate from RU #1, RU #2, RU #5A, and RU #7) at Redoubt Unit was approximately 2,700 bwpd. The total fluid production rate for RU #1, RU #2, and RU #7 (the three wells likely to be effected by injection in RU #6) was approximately 2,400 bfpd. Thus it is expected that injecting the produced water at Redoubt Unit will equal or exceed the total fluid off-take from the surrounding three wells. Due to the relatively small number of Hemlock wells at Redoubt Unit, it would be uneconomical to develop a more thorough injection pattern at this time. Depending upon the success of this Pilot Project, more injection and production wells will be drilled in the future. The Redoubt Unit field presently consists of five (5) producing wells completed in the Hemlock formation. It is being proposed to convert one of these wells (RU #6) from a Hemlock producer to a Hemlock Injection well. RU #6 is located in the "Central" fault block of the Redoubt Shoal structure, Southeast and Northeast of RU #1 and RU #7, respectively. Water injection into the Hemlock formation in RU #6 will primarily influence the hydrocarbon recovery in RU #1 and RU #7, but may also help support the pressure and hydrocarbon recovery in RU #2 as welL RU #2 is located South of RU #1 and RU #7, in the northern part ofthe "Southern" fault block. 4) Description of Operation for which Approval is being Requested e e e e Unit Hemlock Participating Area" (RUHP A) application. Excerpts fÌom the RUHP A application as well as a brieflithofacies description follows: Deposition and Stratigraphy of the Hemlock The Hemlock conglomerate unconformably overlies the West Foreland Fm. and was deposited in a much higher energy depositional environment. The Hemlock consists of interbedded fine to coarse grained sands and gravels, pebble to cobble conglomerates, dense silts and occasional thin coals. Although there is some disagreement as to the exact depositional environment of the Hemlock, it is still essentially fluvial in nature. As to whether it was deposited in conglomerate fans shedding off of structural highs, or was deposited in a wide band of anastomosing braided stream systems, is still open to interpretation. In fact, the truth probably lies in a mix of the two interpretations depending on where you are geographically in the Inlet. The Hemlock is the primary oil producing reservoir in the Inlet, having yielded over a billion barrels of oil since it's discovery. It is also the primary target reservoir in the Redoubt structure. The Hemlock conglomerates display porosities and permeabilities equivalent to those in the West Foreland Fm. At Redoubt, 520 ft. of conventional core was cut and recovered fÌom the RU _ 2 welL This core displayed a much finer grain size than was expected and than what is found at McArthur River. Overall, there are no boulder- or cobble-sized conglomerates found in the core fÌom RU-2. The grain size of the sandstones is fine to medium and the largest pebble found in the core was approximately 2 inches x 1 inch x % inches. The depositional environment appears to be more distal fÌom the source and have a great deal less energy than the fan-glomerates at McArthur River. The Hemlock appears more uniform in its grain size distribution. Overlying the Hemlock conglomerates is the Tyonek Formation. This section is characterized by decreasing energy within the depositional environment and more uniform lithologies than were found in the Hemlock. The Tyonek can be divided into two separate sections based on affinity for oil or gas. The lower section, the G-zone, consists of interbedded sands, gravels and pebble conglomerates, with some minor coal and silt interbeds present. The G-zone is an oil prone section on the west side of the Inlet and in the Redoubt area. The upper Tyonek section is the Grayling Gas Sands equivalent (McArthur River Field). This section consists of a series of stacked packages bounded by thick coals. These packages consist of fine to coarse grained sands, and gravels with some interbedded silts and coals. The coals within the major packages are thinner and discontinuous, with a great deal of lateral variation. The upper Tyonek section was deposited in an anastomosing stream channels system, with the typical overbank deposits and swampy areas associated with this type of system. The Tyonek section displays porosities ranging fÌom 12-23% and permeabilities fÌom 50md to several hundred millidarcies. With less of a variation in the lithologies, the reservoirs act more continuous in terms of hydrocarbon flow. Hemlock Lithofacies There are approximately 6 identified lithofacies present in the Hemlock Formation at Redoubt Unit. This was determined fÌom the conventional core recovered fÌom the Redoubt Unit #2 welL Porosity within the Hemlock is intergranular and the rocks are well cemented and competent. Each of the lithofacies displays dispersed clays ranging fÌom 9% to as much as 20% of the rock volume. This has e e a direct effect on the fluid flow within the reservoir. The lithofacies, from coarsest to finest are as follows: Reservoir Facies 1) Pebble conglomerate - These conglomerates range from clast supported to very sandy and matrix supported. Pebbles in this facies are well rounded, and moderately sorted, indicating a considerable transport distance from their source. Porosities are relatively uniform, ranging from 7- 13%. 2) Pebble / gravel sandstone - This lithofacies is more uniform in grain size and is entirely matrix supported. Porosities range from 10-16%. 3) Medium to coarse grained sandstone - Facies is moderately well sorted and is matrix supported. Porosities range from 10-16%. 4) Fine grained sandstones - Facies is well sorted. Porosities range from 12-14%. Non-Reservoir Facies 5) Siltstones - Facies is very fine grained, dense and generally non-permeable. Porosities are very low ranging from 1-4%. 6) Carbonaceous Claystones / Coals - Facies is non-permeable generally have low porosities. Cuttings within the claystones resemble coals, while log response does not. Actually coals give a characteristic coal response on logs and in cutting. Hemlock Reservoir Characterization The Hemlock Reservoir at Redoubt is very heterogeneous both vertically and horizontally as seen in the core form RU #2 and from wireline analysis. The Hemlock was deposited in a fluvial depositional setting, comprised of meandering and coalescing fluvial stream channels. The channels sands can anastomoze and stack, and are interbedded with the gravel sands, pebble conglomerates and overbank deposits represented by the claystones, siltstones and coals. The source of sediments for the Hemlock was from the west and north-west, with a depositional flow direction south and south-east. Porosities in the sandstone facies of the Hemlock are between 12-18% , with some small sands displaying higher averages. This includes the medium and coarse sandstone and pebble conglomerate facies. Permeabi1ities in these same facies range from 0.1 to several hundred millidarcies. The siltstone and very fine grained sandstone display lower porosities and permeabilities. This contrast in porosities and permeabi1ities between the different reservoir facies can affect fluid flow within the Hemlock reservoir. e e 7) Logs of the Injection Well Logs are already on file at AOGCC for all producing wells at Redoubt Unit, including the proposed injection well, RU #6. ill addition to all of the Redoubt Unit wells, the Commission also has on file logs ITom the original Redoubt Shoal wells (Redoubt Shoal State 29690 #1, Redoubt Shoal State 29690 #2, and Redoubt Bay Unit #1). 8) Casing Program and Mechanical Integrity Testing Attached are the current well completion schematics for RU #6 and RU #7. Both wells are completed in, and are currently producing ITom the Hemlock Formation. Once approval has been granted, RU #6 will be re-comp1eted to allow injection into the Hemlock formation. The current completion intervals in RU #6 will be the same intervals injected into for the enhanced recovery pilot project. Note that the completion schematic for RU #7 has been included in this application due to its proximity of just under y,¡ mile ITom the proposed injection welL Wellbore surveys suggest that the top Hemlock penetration point for RU #7 is approximately 1,310 :ft ITom the top penetration point in RU #6. The bottom hole locations for these two wells are approximately 835 :ft apart. ill addition to the completion schematics, the cementing programs for both RU #6 and RU #7 are provided in the following pages. RU #6 currently has 3-1/2" P-11O and L-80 (47 and 418 joints, respectively) tubing in the hole. The injection string being proposed is a 3-112" coated 9.3# TSHP-CR tubing string. Note that prior to injection into RU #6, a mechanical integrity test of the casing and tubing will be performed. Sufficient notice will be given to the AOGCC so that a witness may be present for this pressure test. Perforations: 15,130 - 15,164' MD 15,192 - 15,226' 15,252 - 15,302' 15,316 - 15,336' 15,418 15,444' 15,458 - 15,480' 15,542 - 15,630' 15,680 - 15,760' 15,788 - 15,812' 15,856 - 15,890' Redoubt Unit TOl @ 14779 MD ompletion - April 2003 30" 150 # A-36 Welded 133/8" 68# 3 1/2" P-110 Pup 47 jts 3 1/2" P-11 0 Tubing 418 jts 3 1/2" l-80 Tubing Centrilift ESP Assembly @ 14675 MD (bottom) 95/8" 47# llC-3 Valve set in Baker Model FA Packer @ 15030 MD Perforations EZ Drill @ 15990 MD 75/8" 297# l-80 Hydril 521 200 TVD 200 MD l-80 BTC 2975 TVD 3480 MD l-80 11748TVD BTC 15085 MD 12570 TVD 16100 MD Perforations: 14,350' - 14,424' 14,442' - 14,505' 14,535' - 14,580' 14,610' - 14,635' 14,745' - 14,785' 14,840' - 14,955' 15,100' - 15,123' 15,340' - 15,383' 15,590' - 15,667' 3-3/8" guns, 6 SPF Redoubt it #7 Completion March, 2004 36", 150#, A-36, Welded Conductor @ 215' MD /2 15'TVD 13-3/8", 68#, L-80, BTC @ 3,528' MD / 3,088' TVD 431 jts 3-1/2", RTS, PH-6 Tubing Centrilift ESP assembly @ 13,445'MD LLC valve set in Baker Retrieva SC-1 packer @ 13,630' MD Top of 7" liner @ 13,708' MD / 11,262' TVD 9-5/8",47#, L-80, BTC @ 14,049' MD / 11,528' TVD 7", 32#, P-11O, Hydril521 @ 15,950' MD / 12,332' TVD e e 9) Type of Fluid to be Injected Filtered produced water ftom RU #1, RU #2, RU #5A, and RU #7 will be injected into the Hemlock formation in RU #6. Since the water's source is the same Hemlock formation as the injection destination, compatibility is not an issue. It is not known at this time what the maximum daily rate that can be injected into the Hemlock formation at RU #6. Initial injection rates are expected to be between 2,500 and 3,000 bwpd, which is the total produced water ftom the remaining four producing wells. This injection rate will match or exceed the total production rate for the wells likely to be effected by the water flood. 10) Injection Pressure The Hemlock ftacture gradient is not currently known at Redoubt Unit. It is suspected that the ftacture gradient is between 0.75 and 1.2 psi/ft, as demonstrated by other Cook Inlet Hemlock reservoirs. Assuming a ftacture gradient of 0.75 psi/ft and an average reservoir injection depth of 12,090' TVD, the maximum allowable surface injection pressure to avoid ftacturing the Hemlock formation is approximately 3,800 psi (0.75 psi/ft x 12,090' - 0.436 psi/ft Hemlock water hydrostatic gradient x 12,090'). This maximum allowable surface injection pressure does not take into account tubing fiction pressure loss. It is estimated that tubing fiction pressure loss for an injection rate of 2,500 bwpd, will be on the order of 500 psi, thus raising the maximum surface injection pressure to 4,300 psi. Actual fiction loss and maximum allowable injection pressure will be determined once the injection string has been finalized. Note that the pumps currently installed at Kustatan Production Facility, which will be used to inject water into RU #6, discharge at 5,000 psi. Taking into a 200 psi pressure drop ftom Kustatan to the Osprey Platform, the maximum possible surface injection pressure will be 4,800 psi. This pump pressure will be choked back such that it does not exceed the ftacture gradient of the Hemlock formation. 11) Protection of Freshwater Strata The casing and cementing program practiced at Redoubt Unit ensures that no injected water will be able to migrate above the Hemlock formation to contact any fteshwater strata near the surface. All Redoubt Unit wells, including RU #6 (which is the proposed injection well), have intermediate casing set at or just above the top of the Hemlock Formation. This intermediate casing is cemented to isolate any upward movement of fluids on the back-side of the casing. Prior to drilling out the plug and drilling through the Hemlock formation, the cement is pressure tested. Once the Hemlock formation has been drilled through, a casing liner is hung and cemented across the entire Hemlock formation. Cement bond logs have been run in all wells and copies have been sent previously to AOGCC. Schlumberger's "Cement Evaluation" (attached) of the cement job in the RU #6 wellbore (across the Hemlock formation) shows cement across the entire Hemlock interval, with better cement bond at the top of the formation. Likewise, the cement bond interpretation in Redoubt #7, shows good to excellent bond across the Middle and Upper Hemlock (with poorer bond in the e Forest Oil Corporation Field: Redoubt Shoal Oil Field I 9 I 16645-16670 I Good cement. Figure 5 displays the transition from well cemented to free pipe signal around 15800 ft. Job Number 23237 'ment Evaluation Logs Redoubt Unit 6 Redoubt Unit 6 was logged with USIT and CBT tools on 05-APR-2003. These were logged over the in combination over the interval 14700 ft to 16000 ft. Three centralizers were employed on the CST tool and 2 on the USIT tool. The logs were recorded inside 7.625 in. 29.7 Iblft casing cemented inside an 8.5 in. borehole. A swivel was included in the tool string to minimize tool rotation while logging. The cement bond in this well in general improves towards the top of the logged interval. Above 15225 ft most of the casing is cemented. Below that depth there are sections with little to no cement mixed with sections with good cement. Isolation of individual perforated intervals in described in Table 4. Table 4 Perforation Interval Isolation Redoubt Unit 6 Zone Perforation Interval Description 1 15130-15164 The cement across this interval appears very good. A short section at the bottom (15162 ft to 15175 ft) contains poor cement but is isolated by good bond above and below. This zone appears to be well isolated above and below. 2 15192-15226 Most of this interval appears to be well bonded with a channel located below. The channel runs from 15225 ft to 15324 ft with a possible small barrier located at 15265 ft. This connects Zone 2, Zone 3, and Zone 4. 3 15252 - 15302 A channel appears to cover this perforated zone as noted above. 4 15316-15336 This interval is connected at the top to the channel described above. A channel exists below this zone to 15410 ft. 5 15418-15444 The top of this zone is well cemented but a channel extends below to 15466 ft. This channel connects Zone 5 and Zone 6 6 15458- 15480 A channel is located both above and below this zone but cement at 15520 to 15525 ft separates this zone from Zone 7 7 15542-15630 This interval is characterized by poor cement across the interval. The poor cement extends down to 15686 ft, lNhich connects Zone 7 and Zone 8. 8 15680-15760 Zone 8 is well bonded at the t~ With some un-bonded intervals towards the bottom. This zone is isolated below by good cement at 15765 ft. 9 15788-15812 Zone 9 is poorly bonded across the perforations but isolated above and below by good cement. 10 15856-15890 This bottom-perforated interval crosses a channel that extends from 15820 ft to 15920 ft. Spotty cement can be seen below 15920 ft. en (') ::T c: 3 e- It) .... (,Q It) .... "tJ c: e- o Figure 6 identifies a channel located from 15225 ft to 15324 ft. DRAFT e e Lower Hemlock). The cement quality in both of these wells coupled with the intermediate casing set just above the Hemlock formation will ensure that the shallow rreshwater strata will be protected. 12) Water Analysis Water analyses of the produced water rrom RU #2, RU #5A, RU #6, and RU #7 are attached to this application. The following table summarizes the analyses that have been conducted on the produced water at Redoubt. Redoubt Unit Produced Water Analyses Sample Water Na K Ca Mg Ba Sr Fe CI HC03 S04 TOS TOS Well Date Point Cut (mg/I) (mg/I) (mg/I) (mg/I) (mg/I) (mg/I) (mg/I) (mg/I) (mg/I) (mg/I) Calc. Obs. RU#2 24-Mar-03 Separator 13% 2,590 87.2 712 5.85 3.42 16.3 --- 5,100 300 52.6 9,730 RU #SA 19-Feb-03 Well Head 71% 2,817 78 1402 12 4 30.0 4 6,836 122 74 11,379 RU #SA 9-Aug-03 Well Head 79% 3,120 --- 1360 9.94 4.38 26.8 5.7 7,260 490 64.6 12,220 15,800 RU #fj MDT 28-Mar -03 MDT Tool 2,510 60.9 577 3.83 3.52 12.7 --- 4,700 583 48.2 8,187 8,250 RU #fj 9-Aug-03 Well Head 62% 2,540 --- 616 6.39 3.57 13.4 10.6 4,860 560 46.8 8,363 10,100 RU#7 15-Apr-04 Well Head 95% 2,970 183 735 7.02 2.96 15.0 --- 5,520 605 75.7 9,854 11,100 Average: 2,758 102 900 7.51 3.64 19.0 6.8 5,713 443 60.3 9,656 11,060 Temp Resistivity Well Densitv ph (F) (ohms) RU#2 1.0068 7.25 RU #SA 1.01· 7.02 75 RU #SA 1.0095 7.4 68 0.45 RU #fj MDT 8.09 68 RU #fj 1.0064 7.2 68 0.67 RU#7 1.0063 6.6 68 0.556 Average: 1.0073 7.3 0.56 4- 3-0.3; 4: 50PM; e .907 5615301 # 2/ 3 SGS Ref.# 1031591001 AU DateslTirnes are Alaska Standard Time Client N arne Forest Oil COIporation Printed DateITlme 04/0312003 15:31 Project Namel# Redoubt Unit #2 CoUected DatelTJme 03/24/2003 0:00 Client Sample ID Redoubt Unit #7 Received DateITlme 03/26/2003 8:30 Matrix Water (Surface, Eft'., Ground) Tecbnical Director StePh~ Released By 5J~ C' Sample Remarks: EP 150.1 Sample was received after holding time had expired. SM2540 - Holding time expired 3-31-03. Samples set up on 3-31-03. Allowable Prep Analysis Parameter Results PQL Units Method Limits Date Date ¡nit % Difference 0.39 % SM20 1030E 04/01/03 KAW So~i.ds Total Suspended Solids ]0.5 1.00 mgIL EPA 160.2 03/28103 KAP Routine Oi~fie1d Water Ana~ysis Alkalinity 300 50.0 mg/L SM20 2320B 03/28103 KC C03 Alkalinity SO.OU 50,0 mglL SM202320B 03/28103 KC Hcm Alkalinity 300 50.0 mg/L SM2023208 03/28/03 KC OH Alkalinity 50.0U 50.0 mg/L SM20 23208 03/28/03 KC pH 7.25 0.100 pH units EPA 150.1 03/26/03 KC Resistivity 0.625 0.0100 ohm-m SMI92SIOA 03/26/03 KC Meta1s Department: Barium 3.42 1.00 mg/L EPA 200.7 Dissolved 03/24/03 04/01/03 MTG Calcium 712 20.0 mg/L EPA 200.7 Dissolved 03/24/03 04/01/03 MTG Iron 3.15 0.400 mgIL EPA 200.7 Dissolved 03124103 04101103 MTG Sodium 2590 200 mglL EPA 200.7 Dissolved 03124/03 04/01/03 MTG Strontium 16.3 1.00 mgfL EPA 200.7 Dissolved 03/24/03 04/01/03 MTG Magnesium 5.85 2.00 mg/L EPA 200.7 Dissolved 03/24103 04/01/03 MTG Meta~s by rcp /MS Potassium 87200 500 ug/L EPA 200.8 Dissolved 03/24/03 03/31/03 KGF Waters Department: Chloride 5100 500 mglL SM174500CL-B 03/26/03 KC Sulfate 52.6 5.00 mgIL EPA 375.4 03131/03 JWD 4- 3-03: 4:50PM: e e;907 5615301 # 3/ 3 SGS Ref.# Client Name Project Name/# Client Sample ID Matrix 1031591001 Forest Oil Corpo~ation Redoubt Unit #2 Redoubt Unit #7 Water (Surface, Eff., Ground) All DateslTimes are Alaska Standard Time Printed DateITlme 04/0312003 15:31 Collected DatelTime 03/24/2003 0:00 Received DateITlme 03/2612003 8:30 Technical Director Stepben C. Ede Allowable: Prep Analysis Parameter Results PQL Units Method Limits Date Date Init Waters Department Total Dissolved Solids 9730 100 mgIL SM202540C 03131103 KC Oi1a Laboratory Density 1.006& ASTM D-287 04/01103 JWD ÜS-22-03 04:42PM FROM-CT&E ENVIRONMENTAL SRV e ~__S_G$___ SGS Ref.# Client Name Project Name/# Client Sample JD Matrix 1035079001 Forest Oil Corporation RU #5N6 RU #5A Water (Surface, Efr., Ground) Sample Remarks: 150.1 -Sample was received after holding time had expired. 9075615301 T-750 P.02/05 F-645 ", 1'" ",: I, :l ¡¡:~ ,'. ¡ Ii ¡,. ';'1' ~.r :'," 'Îg' "~ !:~ ¡'~ ;'i !',!I n ~¡~ .... e All Datesffimes are Alaska Standard Time Printed Date/Time 08/22/2003 ]4:09 Collected Daternme 08/09/2003 0:00 Received Date/Tlme 08/13/2003 16:10 Techniaal Director Stephen C. Ede Released By ~ C ~ íiL--- Parameter " ~ I : Units l' 'Method Allowable Prep Anlllysìs Container ID Limits Date Date Init 08/22/03 KA W % Difference Qualifiers Results 0.96 Routine Oilfield Water Analysis AJka1inity Chloride cm Alkalinity HC03 Alkalinity DH Alkalinity pH Resistivity Sulfate Metals Deparblent Barium Calcium Iron Sodium Snontium Magnesium Metals by ICP/MS Potassium Waters Deparblent Toml Dissolved SoMs Oils Laborato:ry Density 490 7260 lOOU 490 lOOU 7.40 0.450 64.6 4.38 1360 0,400 U 3120 26.8 9.94 200000 U 15800 1.0095 PQL 100 20.0 100 100 100 0.100 0.0100 10.0 0.100 2.00 0.400 200 0.100 2.00 200000 800 % !'iISM20 1030E J ;.!I !;j ~ ;11 mgIL ;~ SM20 2320B mgIL i:¡ EPA 300.0 mg/L1,i¡, SM202320B mg/L ! SM202320B mg/L !j¡ SM20 2320B pH unitsa EPA 150.1 ohm-m;~ SM192510A o, mglL ¡,i¡ EPA 300.0 j;I~' r!f ;~! mg/L ¡~ EP200.7 Dissolved A mgIL !~ EP200.7 Dissolved A mg/L ;~ EP200.7 Dissolved A mglL :~ EP200.7 Dissolved A 'I mglL ¡¡ EP200.7 Dissolved A mglL ¡'ï EP200.7 Dissolved A n UgIL j'~ EP2oo.8 Dissolved A !:!¡: 'I ¡I: !: í! mglL L' SM202540C P A A 08/14/03 KC 08121/03 JIB A 08/14/03 KC A 08114/03 KC A 08114/03 KC A 08114/03 KC A 08/14/03 KC A 08/21/03 Jm 08/09/03 08/18/03 BAG 08109103 08/18/03 BA<ì 08109/03 08118/03 BA<ì 08109103 08/18/03 BAG 08/09/03 08/18103 BA<ì 08/09/03 08/18/03 BAG 08/09/03 08/19103 SCL 08/15/03 J8 A I;': I:' I ASTM D-287 H f' !i I'! -i' 1[' A 08/14/03 GD) 9075615301 ¡I' ¡~ L~ 1'\ Routine Oil Field wate1tnalYSiS Report Date I;. I.· Chem- b Ref. Number Approv( By L.ocatiorl; ,.. Samplei,.rom !I ¡: ¡.¡ r f -f I.i~ Anions i:!1 ¡.¡¡Sulfate . . . . . . . . . . . . 64.6 I;!! Chloride. . . . . . . . . .. 7260 1:: Carbonate. . . . . - . . . . . . . . . P Bicarbonate. . . . . . . . 490 j: . Hydroxide. . . . . . . . . . 0 J'!. -- ii' b.:' ~;r; L¡. ï; mglL Specifi~~Resistance @ 68° F.: mg/L ~served . . . . . . . . . . . . 0.45 ohm-meters ç~ICulated . . . . . . . . . . .. 0.58 ohm-meters ..11- 2i:~~ ~~t II 5.700 mg/L :! !'~ Water Analysis ~attern Scale: Milligram equjval~nts per Unit .:» W /~ Ð , lø ., ~ 0 41.., ,. t 1, 1'/ I~ II dol) . (}8-22-03 04:43PM FROM-CT&E ENVIRONMENTAL SRV -- Operator Well Number Field County State Remarks and conclusions: T-750 P.04/05 F-645 - . "'-0# ..... 1035079001 ~ I e¡.}.()./B Cations ID9lb mg/L Meq./L 1.34 204.73 0.00 8.04 0.0 3334 --~ 1248 11 5.7 Sodium. . . . . . . . . . . . . . . . . Potassium. . . . . . . . . . . . . . Calcium. . . . . . . . . . . . . . . . Magnesium. . . . . . . . . . . . . Iron............. ....... -.- Total Cations. . . . . . . - . . . . . 210.00 Total dissolved solids. . _. . .__ 12220 NaCI equivalent (chloride) _ 12028 Observed pH . . . . . . . . . . . . 7.4 Barium. . . . . . . . . . . . . . . . . Strontium. . . . . . . . . . . . . . . Total Iron . . . . . . . . . . . . . . . ~ 145.03 1.58 62.28 0:90 0.21 Total Anions. . . . . . ., 214.112 '-!-'is Na & I~ ~ Caú I~) tL..'-D. Mgb,) D~ Fe (A I) /J '" , ~ ,. I ., .- I- , , , - J I i ~,oo) CI..;}....os (}I'jHC03 ~o4 (1).') 504~'¡ (Xt) C03 ~Q,?' (N. ",... " _. graph' ¡no"''' slam. Pet_Jam and L 1) NOTE: mg/L ;: Milligrams per liter, Meq./L$ Milligram equivalent per liter. Soldium Chloride equivalent.. by Dunlap & HaVlj~ome calculation from components. ;"1/" l!j i! ,'. ,¡ !:L (!I in q ,oa-n-03 04:42PM FROM-CT&E ENVIRONMENTAL SRV e _~_s. SGS Ref.# Client Name Projeef Namel# CUent Sample JD Matrix 1035079002 Forest Oil Corporation RU #5N6 RU t/6 Water (Surface, EfT., Ground) Sample Remarks: 150.1 - Sample was received after bolding time had expired. Parameter Qualifiers Results I'QL % Difference 1.9 Routine Oi~field Water Analysis Alkalinity 560 lOO Chloride 4860 10.0 cm Alkalinity l00U 100 HC03 Alkalinity 560 100 OH Alkalinily lOOD 100 pH 7.20 0.100 Resistivity 0.670 0.0100 SuJfate 46.8 10.0 Meta~s Department Barium 3.57 0.100 Calcium 616 2.00 Iron 0.400 U 0.400 Strontium 13.4 0.100 Magnesium 6.39 2.00 Metals by ICP/MS Potassium 200000 U 200000 Sodium 2540000 200000 Waters Department Total Dissolved Solids 10100 800 Oils Laboratory Density 1.0064 PI ï ¡:¡ 1··:1; I'·· Hi hi. 1:11 ;'IL I:~ ;:~ J ¡.~ 1-" ¡:~ , ~ .~ , ~ !~ .,' H! Units iil Method II % ¡" SM20 1030E !:~ :~ mglL II SM20 2320B mglL :,1 ErA 300.0 mgIL ¡~ SM20 2320B ::01 mgIL !~~. SM20 2320B mglL ¡:. SM202320B " pH units.!.!,. EPA 150.1 obm-m 1'1 SM192510A il mgIL 'I, EPA 300.0 !i, ,·;1 'U ¡:~ mg/L J mgIL F mg/L ;' mglL jr mgIL r.. fl' r¡ !} I, UglL!, EP200.8 Dissolved A UglL.II:.I. EP200.8 Dissolved A q !,,' t: '] mglIJ! SM20 2540C ;·:1 :r¡ ii¡ ;, ¡~ ¡ill' ASTM D-287 I, ¡i,II.. ri 9075615301 T-750 P.03/05 F-645 e All DatesJTimes are Alaska Standard Time Printed Daterrime 08/22/2003 14:09 Conected DateJTime 08109/2003 0:00 Received DateJTime 08/13/2003 16:10 Tec:bnjeal Djre~wtePben C. Ede Released By./'VU'( C'" ~ Container ID A)lowllble Limits Prep Analysis Date Date Init 08/22/03 KA W A A A A A A A A A 08/14/03 KC 08121/03 JJB 08/]4/03 KC 08/14/03 KC 08/14/03 KC 08/14/03 KC 08114103 KC 08121103 JJB EP200.7 Dissolved A EP200.7 Dissolved A EP200.7 Dissolved A EP200.7 Dissolved A EP200.7Dissolved A 08109/03 08/18103 BAG 08109/03 08118/03 BAG 08/09/03 08/18/03 BAG 08/09103 08/18/03 BAG 08/09103 08/18/03 BAG 08/09/03 08/19103 SCl 08/09/03 08/19/03 SCl A 08115/03 J! A 08/14/03 GD' ,'08-22-03 04:43PM FROM-CT&E ENVIRONMENTAL SRV e e 9075615301 Ilil !, ¡., Routine Oil Field Waterl~nalYSiS Report Date i'~ Chem~L~ Ref. Number Approv~ By Locatio~,!1 Sample ~rom l~. ¡~[ rf i'" ili Anions ID9l.b , . r ¡: Sulfate. . . . . . . . . . .. 46.8 r.~Ch'Oride . . . . . . . . . .. 4861 1:1 -- 'I¡ Carbonate. . . . . . . . . . . . . . . I:~ Bicarb~nate . . . . . . . . --s6O !~ HydroxIde. . . . . . . . . . 0 ~:; Hi . It Total Anions. . . . . . " 147.238 :!. ). 'I mg/L speCifi'.,...Resistance@680F.: mg/L . seIVed............ 0.67 ohm-meters . Iculated............ 0.84 ohm-meters ," i;!f 3.72 mg/L I:~ _ 13.50 mg/L iN 10.600 mg/L ;::1 ¡:ì ,r, Water Analysis~attem S I Mll' . t'f t u 't Opel'Eltor Well Number Field County State T-750 P.05/05 F-645 1035079002 ~ '¡¡ f.I.o Remarks and conclusions: Cations Sodium. . . . . . . . . . . . . . . . . Potassium. . . . . . . . . . . . . . Calcium. . . . . . . . . . . . . . . . Magnesium. . . . . .. . . .. . . Iron.. . . . . . .. . . ., " . . . .. mQ/L Meq.lL ~ 0.97 137.08 0.00 9.18 0.0 2545 50.3 577 7.56 10.6 110.71 1.29 28.79 0.62 0.38 Total Cations. . . . . . . . . . . . . 141.79 Total dissolved solids. . . . . . NaCI equivalent (chloride) Observed pH . . . . . . . . . . . . Barium. . . . . . . . . . . . . . . . . Strontium. . . . . . . . . . . , . . . T otallron . . . . . . . . . . . . . . . .hll Na(1.I~ c:i,U Ca (XIO) (hIM Mg ('tl) ð.3ß' Fe ('J.f) 8363 8194 7.2 ca e: I Igram eqUlva. n s per nt o I'I'I,"'¡ J). 16 r " ., .1 0':' 0( " , lOll. 1'/ " " '. .,. ., .. I " . ( ~; ..J ..20 ('l/6U) C?1-L:J7 Juo)HC03A'iI, (x,) S04~,? Kf) C03.1JLðb .'11" ¡:~ (Na value in above graphs includes ~~dium, Potassium and L 1) NOTE: mglL:= Milligrams per liter. Meq./4JF Mílligram equivalent per liter. Soklium Chloride equivalent'" by Dl.lßlap & HajtlOme calCI.Ilation from components. !:~. F h Lñ if .;;:>_·-V~ pt. . . . .........,,,,, e e 'P~ WÙA-~\ow \+0.;\& CO p 1 -to -ÇonDW. ~ .......... ~ ;S Ref.# ient Name ·oject Namel# ient Sample ID atrix 1041806001 Forest Oil Corporation Redoubt Unit #7 RU#7 Other Liquids All DatesITimes are Alaska Standard Time Printed Dateffime 05/03/2004 11:08 Collected Dateffime 04/15/2004 7:00 Received DatelTime 04/16/2004 13:30 Technical Director Stephen C. Ede Released By mple Remarks: EP150.1 - Sample was received after holding time had expired. EP 300.0 - Detectable amount of chloride in the method blank; concentration of chloride in the sample is lOX greater. 5/3/04 Revised report: Density - unrounded result is 1.0063 Results PQL Units Method Container ID Allowable Prep Analysis 'ameter Limits Date Date Init % Difference 1.2 % SM20 1030E A 04/28/04 KA W ~tine Oilfield Water Analysis Alkalinity 605 50.0 mgIL SM202320B A 04/20/04 JMP Chloride 5520 25.0 mgIL EPA 300.0 A 04/20/04 JJB C03 Alkalinity 50.0U 50.0 mgIL SM202320B A 04/20/04 JMP HC03 Alkalinity 605 50.0 mgIL SM202320B A 04/20/04 JMP OH Alkalinity 50.0U 50.0 mgIL SM202320B A 04/20/04 JMP pH 6.60 0.100 pH units EPA 150.1 A 04/19/04 KC Resistivity 0.556 0.0100 ohm-m SM192510A A 04/19/04 KC Sulfate 75.7 1.00 mgIL EPA 300.0 A 04/20/04 JJB ,tals Department Barium 2.96 0.100 mglL EP200.7 Dissolved A 04/22/04 04/28/04 BAG Calcium 735 2.00 mgIL EP200.7 Dissolved A 04/22/04 04/28/04 BAG Iron 0.0400 U 0.0400 mgIL EP200.7 Dissolved A 04/22/04 04/28/04 BAG Sodium 2970 200 mgIL EP200.7 Dissolved A 04/22/04 04/28/04 BAG Strontium 15.0 0.100 mgIL EP200.7 Dissolved A 04/22/04 04/28/04 BAG Magnesium 7.02 2.00 mgIL EP200.7 Dissolved A 04/22/04 04/28104 BAG ,tals by ICP /MS Potassium 183000 50000 ugIL EP200.8 Dissolved A 04/22/04 04/22/04 W A W tars Department rotal Dissolved Solids 11100 80.0 mgIL SM20 2540C A 04/19/04 KC 5- 3-04;11:11AM; e e ;S Ref.# ient Name ·oject Name/# ¡ent Sample ID atrix 1041806001 Forest Oil Corporation Redoubt Unit #7 RU#7 Other Liquids All Datesffimes are Alaska Standard Time Printed DatelTime 05/03/2004 11 :08 Collected Date/rime 04/15/2004 7:00 Received DatelTime 04/16/2004 13:30 Technical Director . Stephen C. Ede Results Units Method Container OJ Allowable Prep Analysis rameter PQL Limits Date Date Init L~s Laborato.ry Density 1.01 ASTM D-287 A 04121/04 BJA e . 13) Freshwater Exemptions Currently Forest has an Aquifer Exemption Order (AEO 7) for RU D-1, which exempts injection below 3949' MD for a one-half mile radius around D-1. This AEO will need to be updated to include the proposed pilot project area (most likely expanded to encompass the Redoubt Unit Hemlock Participating Area). The Hemlock formation itself is not a rreshwater strata, so the exemption should not be an issue. 14) Expected Incremental Increase in Ultimate Hydrocarbon Recovery The crude oil being produced at Redoubt Unit has an API gravity of 26.5 degrees, a gas-oil-ratio (GOR) of 250 scf/STB, and a bubble point pressure of 1,490 psia. Initial reservoir pressure at Redoubt Unit was approximately 5,340 psia at a datum depth of 12,000' SSTVD. Recovery under primary depletion of this relatively dead oil, is estimated to be about 6% of the original oil-in-place (OOIP), rrom initial pressure down to the bubble point. The latest estimates for OOIP in Redoubt Unit are about 50 MMbb1s of oiL Assuming a 6% recovery down to bubble point, the primary recovery is expected to be approximately 3.0 MMbb1s. Other Hemlock reservoirs in the Cook Inlet which mature water floods have achieved recoveries of as much as 42% of the OOIP. Preliminary reservoir modeling shows that the Hemlock reservoir at Redoubt Unit may be capable of 20+% recovery, given a sufficient injection pattern. The pilot project of converting RU #6 to an injection well is being proposed to start gathering data on the responsiveness of the Hemlock formation at Redoubt, to water flood. 15) Well Status (Mechanical) There are two wells that have penetrated the Hemlock formation within If4 mile of the proposed injection well (RU #6). One of these wells, RU #7, is currently producing rrom the Hemlock formation and the other well, Redoubt Shoal State 29690 #2, has been plugged and abandoned. The casing profile and cement program for RU #7 has been discussed previously in this application, so will not be addressed again. As for the Redoubt Shoal State 29690 #2, it was plugged and abandoned in September 1968. Records show that the abandonment of the well consisted of; 1) setting a 5" BP at 13,106' with 25 sacks of cement above, 2) setting a 7" BP at 11,525' with 25 sacks of cement above, 3) setting a 9-5/8" BP at 7,825' with 50 sacks of cement above, 4) setting a 9-5/8" BP at 2,037' with 50 sacks of cement above, and finally 5) setting a 80 sack cement plug at 180-400'. It is assumed that a surface plug was also set to abandon the well, but our records can not verify this. In a letter dated 7- 26-91, rrom Amoco Production Co. to AOGCC, Amoco made the same conclusion as to the status of this Redoubt Shoal well.