The URL can be used to link to this page

Home My WebLink AboutDIO 022 -) ) Image Project Order File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. <p.t(J D~~ Order File Identifier Organizing (done) o Two-sided 1111111111111111111 o Rescan Needed 1111111111111111111 RESCAN DIGITAL DATA OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Color Items: o Diskettes, No. o Greyscale Items: 0 Other, No/Type: ~or Quality Originals: I p~ o Other: NOTES: OVERSIZED (Non-Scannable) ~s of various kinds: o Other:: BY: ~ Date: I d- G fO~ /s/ wr~ 1111111111111111111 mP Project Proofing BY: cMaria) 1 Date: 1 ~ (þ (j,S /s/ Scanning Preparation BY: ~ x 30 = + Date: {é!J.- / (; /05 = TOTAL PAGES ~~ j (Count does not include cover sheet) AM if) /5/ f r I r Production Scanning 1111111111111111111 Stage 1 Page Count from Scanned File: ::..3 d.. :L (Count does include cover sheet) VYES NO MP Stage 1 BY: pa9.e Count Matches Number in scanni7 Preparation: ~ Maria) Date: fa- biDS- If NO in stage 1, page(s) discrepancies were found: /s/ BY: YES NO Maria Date: /s/ 1111I111I1111111111 Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Orders File Cover Page. doc • • INDEX DISPOSAL INJECTION ORDER #22 REDOUBT UNIT WELL REDOUBT UNIT D1 1. Apri124, 2001 Fracture simulations for Redoubt Unit #1 Well 2. May 14, 2001 Notice of Hearing, ad order and mailing list 3. June 1, 2001 AOGCC letter to Forest w/questions regarding Application 4. June 5, 2001 Forest answers to questions 5. June 20, 2001 AOGCC's questions 6. June 20, 2001 Forest answers to questions 7. July 25, 2001 Sign In Sheet for meeting w/Forest Oil 8. July 27, 2001 Forest revised application for underground injection of oil field wastes and an Aquifer Exemption 9. August 3, 2001 Forest Oil's submittal of RU DI Casing Schematic 10. August 9, 2001 Ltr from AOGCC to operator re: disposal considerations 11. October 4, 2001 Operators submittal of well fracture model 12. June 17, 2002 Forest request to use the Class II disposal well for the disposal of storm water collected in the platform's deck drain system 13. June 17, 2002 Joint Stipulation to stay proceedings on amended notice of appeal 14. June 20, 2002 EPA Ltr re: coverage under the Cook Inlet NPDES General Permit 15. November 20, 2003 e-mail to operator from AOGCC 16. June 30, 2004 Forest Oil's Annual Report 17. November 19, 2004 Forest Oil's request for authorization to inject gray water into redoubt Unit #D1 Class II Disposal Well 18. October 7, 2005 Forest Oil's request to inject alternate fluids into Redoubt Unit #D1 Class II Disposal Well 19. June 30, 2006 Forest Oil's Annual Injection Report 2005-2006 20. February O1, 2007 Forest Oil Corp Notification of Conversion of Class II Disposal Wells to Class I Wells 21. April 5, 2007 Forest Oil's request for Administrative Approval (DIO 22- 00.5) 22. July 19, 2007 Forest Oil's 2007 Annual Injection Report 23. July 24, 2007 Forest Oil's RU D1 2007 Injection Analysis 24. July 24, 2007 Memo to File 25. May 7, 2008 Pacific Energy Resources request to rescind Order 26. March 9, 2009 Pacific Energy Resources, Ltd. Filing of Chapter 11 Restructuring DISPOSAL INJECTION ORDER #22 Some Annual reports are located in the Field Files ~ ~( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: THE REQUEST OF FOREST OIL CORPORATION for a Disposal Injection Order for the Redoubt Unit #D 1 well, Sec.14, T7N, RI4W, Seward Meridian, offshore Cook Inlet. ) Disposal Injection Order No. 22 ) ) Upper Tyonek Formation ) Redoubt Unit ) Well Redoubt Unit #Dl ) August 9, 2001 IT APPEARING THAT: 1. Forest Oil Corporation ("Forest") submitted an application, dated May 9, 2001, requesting that the Alaska Oil and Gas Conservation Commission issue a disposal injection order to allow Class II disposal in the Redoubt Unit #D 1 well. Additional information requested by the Commission was received on June 5, June 22 and July 5, 2001. Subsequent to numerous changes, a revised application for disposal injection and aquifer exemption orders was submitted on July 27,2001. 2. The Commission published notice of an opportunity for a public hearing in the Anchorage Daily News and Peninsula Clarion on May 14, 2001. 3. The Commission submitted a copy of Forests' Aquifer Exemption application to the U.S. Environmental Protection Agency, Region 10, ("EP A Region 1 0") on May 1 0, 2001, in accordance with Section 14 of the November 22, 1991 Memorandum of Agreement between EP A Region 10 and the Commission. A copy of the revised application was submitted to EPA Region 10 on July 27,2001. The Commission also submitted a copy of a proposed aquifer exemption order to EP A Region lOon July 31, 2001. 4. The Commission did not receive any protest or request for a public hearing. FINDINGS: 1. In correspondence dated May 8, 2001 Forest requested an order authorizing Class II disposal into the Tyonek Formation in the Redoubt Unit #D 1 well. Subsequent to numerous plan changes and data correction efforts, a revised application was submitted on July 27,2001. 2. The Redoubt Unit ("RU") is located offshore in Cook Inlet, approximately 2 miles east the West Forelands area, and is being developed from the Osprey platform. 3. The RU #Dl well is located approximately 1915' from the south line and 322' from the east line of Section 14, Township 7 North, Range 14 West, Seward Meridian. Forest Oil Corporation (Forest) is the only operator within one-half mile radius of the proposed disposal operation. SCANNED JUN 2. 3 2004 ...-.. Disposal Injection Order #22 Redoubt Unit August 9, 2001 Page 2 of5 4. Forest has provided an affidavit showing that they provided a copy of the application for disposal to the State of Alaska, Department of Natural Resources, the only surface owner within a one-quarter mile radius of the proposed disposal project. 5. Wire1ine log analytical techniques, which are compliant with EP A recommended methods as described in "Survey of Methods to Determine Total Dissolved Solids Concentrations", (KEDA Project No. 30-956), were used to characterize formation water salinities in the Redoubt Unit. 6. Wireline log analysis from the RU #Dl well show the proposed Class II disposal injection zone contains freshwater with a total dissolved solids (TDS) concentration generally between 3,000 and 10,000 mg/I. 7. Current perforations in the RU #Dl well are between 8216' and 8450' measured depth (MD), within sandstones of the Upper Tyonek Formation. Forest intends to also perforate and inject into another sand interval between 7650' and 7900' MD. 8. In the Redoubt Unit area the Upper Tyonek Formation sandstones are anastomozing fluvial deposits, which tend to be laterally continuous over several miles. Porosities typically range from 20%-30% and permeabilities range to the 100's ofmillidarcies. 9. The Upper Tyonek Formation contains numerous laterally continuous claystones, siltstones and coals that have been shown to be effective confining zones. In the interval 300 feet above the proposed disposal operations in RU #D-l these rock types represent approximately 30% of all lithologies. Similar percentages of confming lithologies are present in the underlying Tyonek Formation. 10. In the Redoubt Unit the Upper Tyonek Formation is overlain by approximately 1700 feet of Beluga Formation. The Beluga Formation is composed of approximately 50% confming lithologies. 11. At the top of the proposed disposal zone in the RU #D 1 well, the nearest well will be the planned RU #3 well, at a distance of over 3000' away. 12. Forest has requested and received an Aquifer Exemption Order (AEO) for all aquifers below 3749' MD (3650' true vertical depth subsea) and within one-half mile radius of the RU #D 1 well, to prepare for the possibility of a need for Class II disposal into intervals at shallower depths than originally anticipated. 13. The proposed disposal interval is overlain and confmed by siltstones, coals and shales within the Tyonek and Beluga Formations which will prevent vertical migration of Class II wastes into formation waters with TDS content less than 3000 mg/l. 14. A cement bond log and cement records were reviewed to confirm that the RU #D 1 well is cemented adequately to isolate the currently accessible disposal interval. 15. The well is current completed with 36" conductor set at 200' MD, 9 5/8" casing to 2517'MD, and 7 5/8" casing at 8600' MD. A 3 1/2" tubing string and packer were set at 7620' MD. 16. The well passed the initial mechanical integrity test on July 22, 2001. SC/-\N~\JEL JUN ~. ;3 2004 ,.--. Disposal Injection Order #22 Redoubt Unit August 9, 2001 Page 3 of5 17. The waste stream will consist of produced water, drilling, completion and workover fluids, rig wash, drilling mud slurries, NORM scale, tank bottoms, and other fluids brought to the surface in connection with oil and gas development activity on the Osprey platform. 18. Forest estimates that the average volume of fluids to be disposed will be approximately 600 barrels per day, with a maximum volume of 1000 barrels per day. The average and maximum density of injected fluids will be 10.0 pounds per gallon (ppg) and 11.5 ppg, respectfully. 19. Forest estimates the surface injection pressure will not exceed 4000 psi at an injection rate of 5 barrels per minute (bpm). Average anticipated surface injection pressure is 3600 psi. 20. Forest provided fracture modeling simulations assuming 23,810 barrels of 10.5 ppg fluid system transporting 5 ppg 100 mesh sand at a rate of 5 bpm. The resulting simulator output data showed the injected fluids to be fully contained within the intervals modeled (at 3784' MD and at 5477' MD). It is reasonable to assume that fluids injected at deeper intervals will also be contained within their respective receiving intervals. 21. Fracture propagation within the disposal interval is an integral part of the process of placing waste slurries into the disposal interval. Fractures will be created as disposal zone porosity and permeability is occluded by the deposition of solids in pore spaces. Fractures provide pathways to transport waste fluids to unfilled areas within the disposal zone. 22. Forest will perform a step rate test to establish optimum injection rates and pressures. The step rate will be incrementally increased to pump rates 100% in excess of the maximum anticipated injection rates for waste disposal. Pressure falloff data will be collected at the end of the step rate test. 23. Reservoir surveillance techniques including but not limited to, step rate injection tests, monitoring operation parameters, and temperature logging will be used for tracking near wellbore fluid movement, estimating dimensions of disposal fracture or disposal storage volume and detecting changes in disposal zone characteristics. CONCLUSIONS: 1. The application requirements of20 AAC 25.252 have been met. 2. Those portions of aquifers below 3749' MD (3650' true vertical depth subsea) and within one-half mile radius of the RU #D 1 well have been exempted from consideration as freshwater to allow for Class II disposal in the RU #D 1 well. 3. Waste fluids authorized for disposal under this order will consist exclusively of the following Class II fluids: produced water, drilling, completion and workover fluids, rig wash, drilling mud slurries, NORM scale, tank bottoms;anduther fluids brought 'to the surface in connection with oil and gas development activity on the Osprey platform. SCþ,~\!~\jEr JUN?' 3 200¿} .-. Disposal Injection Order #22 Redoubt Unit August 9, 2001 Page 4 of 5 4. Permeable strata, which can reasonably be expected to contain the total volume of disposal fluid anticipated for this project are present in the Tyonek Formation. 5. Waste fluids will be contained within appropriate receiving intervals by confining lithologies, cement isolation of the wellbore and operating conditions. 6. Disposal injection operations in the RU #Dl well will be conducted at rates and pressures below those estimated to fracture the confming zones. 7. Evaluation of operational performance data and reservoir surveillance data will aid in preventing fracturing of the confming zones. 8. Surveillance of disposal material placement, daily monitoring of operational parameters, and demonstration of mechanical integrity prior to injection and every two years thereafter will reasonably assure the waste fluids are contained within the disposal intervaL 9. Disposal injection operations in the RU #Dl well will not cause waste, jeopardize correlative rights, or impair ultimate recovery. NOW, THEREFORE, IT IS ORDERED Rule 1 Authorized Injection Strata for Disposal Class II oil field waste fluids may be injected in conformance with Alaska Administrative Code Title 20, Chapter 25, for disposal into the Upper Tyonek Formation, between the depths of 7650' and 8450' MD in the RU #Dl well. Rule 2 Authorized Fluids This authorization is limited to Class II waste fluids as follows: produced water, drilling, completion and workover fluids, rig wash, drilling mud slurries, NORM scale, tank bottoms, and other fluids brought to the surface in connection with oil and gas development activity on the Osprey platform. Rule 3 Demonstration of Tubing/Casing Annulus Mechanical Integrity The tubing/casing annulus must be tested every two years for mechanical integrity. Rule 4 Surveillance A baseline temperature survey from surface to total depth, initial step rate test to pressures equal or exceeding maximum injection pressure and pressure falloff are required prior to sustained disposal injection. Regular fill depth tags are required at least once annually or as warranted following consultation with the Commission. Operating parameters including disposal rate, disposal pressure, annulus pressures and volume of slurry pumped must be monitored and reported according to the requirements of20 AAC 25.432. An annual performance report will be required including rate and pressure performance, surveillance logging, fill depth, survey results, and volumetric analysis of the disposal storage volume, estimate of-fracture growth, if any, and updates of operational plans. Report submission must be on or before July 1. Q ~o-, 1'\ . 'I !r-- r-" "I [\' &} I<) 2 f) Of1 -_;.Cl-':·h:~1\;r:f~ ...Itd'j /; Q) .Uu f """ Disposal Injection Order #2L. Redoubt Unit August 9, 2001 Rule 5 Notification ''''-'''' Page 5 of5 The operator must immediately notify the Commission if it learns of any improper Class II injection. Additionally, notification requirements of any other State or Federal agency remain the operators' responsibility. Rule 6 Administrative Action Upon request or its own volition, the Commission may administratively revise and reissue this order or any of its rules upon proper showing that the change is based on sound engineering practices, will not allow waste fluids to escape from the disposal zone, and win not cause waste. Rule 7 Statewide Requirements Except where a rule stated above substitutes for a statewide requirement, statewide requirements under 20 AAC 25 apply in addition to the above rules. DONE at Anchorage, Alaska, and dated August 9, 2001. Daniel T. Se ount, Jr., Commissioner Alaska Oil and Gas Conservation Commission Ju.Lw ¡tt.. 1=4e.¿(./~/¡/ Julie M. Heusser, Commissioner 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 may file with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23rd day foJlowing the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the 10-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the [mal order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30-day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., 10th day after the application for rehearing was filed). SCÞ"NNEC JUN 2 3 20D4 ) ~1f ~1JŒ mJ~ !Æ~!Æ~rg!Æ ) I ALASK& OIL AM) GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 FRANK H. MURKOWSK', GOVERNOR ADMINISTRATIVE APPROVAL DIO 22.004 Re: The application of Forest Oil Corporation to Inject Fluids from Alternate Sources into Redoubt Unit Disposal Well RU D-l, Redoubt Unit, Redoubt Shoal Undefined Waste Disposal Pool, Cook Inlet Area, 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 October 7, 2005 authorization to inject non-hazardous fluids into Redoubt Unit Well D-l ("RU Dl") that are generated at other Forest operated facilities on the west side of Cook Inlet in addition to the Osprey platform. Well RU DI was authorized as Class II waste disposal by Disposal Injection Order ("DIO 22"; August 9,2001) but injection was limited to Class II fluids generated in conjunction with the Osprey platform operation. Administrative approvals since the issuance ofDIO 22 have expanded the types of fluids authorized for waste injection but have not authorized sources outside of Osprey Platform-generated Class II wastes. As provided by DIO 22, Rule 6 - "Administrative Action", the Commission hereby approves Forest's request for authorization to dispose of commingled waste streams as identified herein from the West McArthur River Unit, Kustatan Production Facility and permitted exploration wells into Redoubt Unit Well D-I. In its letter, Forest identified the need to inject wastes from alternate sources (from outside the Redoubt Unit) into RU Dl, including Class II wastes from the West McArthur River Production Facility, Kustatan Production Facility and various exploration wells to be drilled on the west side of Cook Inlet in the foreseeable future. Forest has operated two other Class II disposal wells in the Cook Inlet area: Kustatan Field Well #1 ("KF 1") authorized by DIO No. 26 (at the Kustatan Production Facility), and West McArthur River Unit Well4D ("WMRU 4D") authorized by DIO No. 16 (at the West Mc Arthur River Production Facility). Forest converted KF #1 to a gas producer in October 2005 and it is no longer available for waste disposal. WMRU 4D is permitted for all Class II wastes, regardless of type and origin but is scheduled for a work-over ) ADMINISTRATIVE APPROVAL DIO 22.004 November 8, 2005 Page 2 of2 ) beginning mid-November 2005. There are no alternate sites, at this time, to dispose of wastes while WMRU 4D is out of service. The Commission may authorize the injection of appropriate Class II oilfield wastes into an approved and permitted disposal well. Waste produced water from the WMRU is from the same geologic formation as that developed at Redoubt Unit. Other Class II waste streams from WMRU are similar to waste generated from Redoubt Unit. Waste streams from Kustatan Production Facility are a result of production operations at Redoubt Unit's Osprey Platform (Redoubt Shoal Field). Well RU D 1 can provide necessary optional disposal capacity in support afForest's operations on the west side of Cook Inlet. RU D 1 has demonstrated mechanical integrity based on pressure surveillance and testing as required by DIO 22. All injected fluids have been confined to the intended injection zone. Commingling alternate sources of wastes that are similar to the disposal waste stream already being injected into RU Dl will have no impact on the mechanical integrity and will not promote waste, jeopardize correlative rights, or contribute to the potential for fluid movement outside of the injection zone. For the reasons stated above Forest's request is approved. ora e, Alaska and dated November 8, 2005. (}Jtj f lø~N~ Cathy ~. Foerster Commissioner DIO 22.3, 22.4 Redoubt #1 and CO 341E Prudhoe Bay lof2 ,( ( 11/9/2005 11 :08 AM 20f2 11/9/2005 11 :08 AM ( ( " ", \ ' ,1"1",': ','" ,",:" 'DI()äóo3.pdt:C~~!~Dt:J,)P~:. applicati()n¡Pdf¡"'~; ~,..................jE?..~~Dt~;E9CIl~i..g: base64 I i'\.i ¡"..' . ,.....,...'....., .~. . . .~;;¡,- ,..F"';'~=c'-'~;¡:';¡;" '.,."" . . DIO 22.3, 22.4 Redoubt #1 and CO 341E Prudhoe Bay 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 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 James Gibbs PO Box 1597 SOldotna, AK 99669 Richard Wagner PO Box 60868 Fairbanks, AK 99706 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 ) Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 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 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 ) 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 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Darwin Waldsmith PO Box 39309 Ninilchick, AK 99639 Penny Vadla 399 West Riverview Avenue SOldotna, AK 99669-7714 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 · ~~'iJ ~ ~~ ~,'~ ni~ [C.~J',i· 1íù !~,' ", , t,~ æd, TÙ j lb ') [,',n ~ ~, K\ I1 .® \,~ Yllj), 11 J LrÙ ~ Ifû ® ~\ lJi1 ) ALASKA. OIL AND GAS CONSERVATION COMMISSION / y I / / FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE ACTION NO. DIO 22.003 Mr. Bob Elder HSE Manager Forest Oil Corporation 310 K Street Anchorage, AK 99501 Re: Denial of Forest Oil Corporation's application to inject non-hazardous fluid into Class II Disposal Well RU D-1, Redoubt Unit, Redoubt Shoal Undefined Oil Pool, Cook Inlet, Alaska. Dear Mr. Elder: Forest Oil Corporation ("Forest") has requested by letter dated November 19, 2004 authorization to inject non-hazardous gray water into RU Well D-l. The gray water originates from platform living and camp facilities located on the Osprey Platform in the Cook Inlet. Other sources of non-hazardous gray water are camp facilities from the West McArthur River Unit and Kustatan Production Facilities. Forest identified problems with meeting overboard discharge permit limits as the primary reason for the request and that transportation to shore has been studied and determined economically non-feasible. Forest prefers to reduce discharges under its NPDES permit to near zero to reduce risk of exceeding discharge limits. The Commission may authorize the injection of appropriate Class II oilfield wastes into an approved and permitted disposal well. Disposal Injection Order 22 was approved August 9,2001 for disposal of Class II fluids: produced water, drilling, completion and workover fluids, rig wash, drilling mud slurries, NORM scale, tank bottoms, and other fluids brought to the surface in connection with oil and gas development activity on the Osprey platform. RU D 1 has demonstrated mechanical integrity based on pressure surveillance and testing as required by DIO 22. All injected fluids have been confined to the intended injection zone. The Commission has determined that the gray water from the Osprey Platform and other Forest operated sources is not included in the array of approved and appropriate Class II fluids that are generally "fluids brought to the surface" as a result of oil and gas operations. While it can be argued that gray water is associated with oil and gas operations it has not been brought to the ) Administrative Approval DIO 2L..û03 November 8, 2005 Page 2 of2 surface. Non-hazardous non-exempt oil and gas operations waste is best disposed into a Class I disposal according to the UIC regulations as administered by EP A. ) Therefore, the Commission denies Forest's request for authorization to dispose gray water in Redoubt Unit Well D-l. (f(;tA ¿~orrnan Chairman rage, Alaska and dated November 8, 2005. æLIJw~/ Cathy/t'o 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 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 James Gibbs PO Box 1597 SOldotna, AK 99669 Richard Wagner PO Box 60868 Fairbanks, AK 99706 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 ) Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 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 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 ) 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 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Darwin Waldsmith PO Box 39309 Ninilchick, AK 99639 Penny Vadla 399 West Riverview Avenue Soldotna, AK 99669-7714 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 ~( § fJ\' \) '{ ~ )1022.3,22.4 Redoubt #1 and CO 341E Prudhoe Bay ) ) lof2 11/9/2005 11 :08 AM 11/9/2005 11 :08 AM 20f2 ) )1022.3,22.4 Redoubt #1 and CO 341E Prudhoe Bay ) , ,,' , ~T'i~ '~"\\,' <l'~"r \'\ II ' J \rÜ ~ I,'. ~'¡,~: ' \,--) ,~, ~_\, rIDŒ ) r·' r", r~\,' ".~)..' [11' r,7, n'\,' ,p l' I~\~) I ~( lþ\ t\Jl1 "~::J U L Q.:!..., L~ \~\ 1.1 lU ) FRANK H. MURKOWSKI, GOVERNOR AlASIiA. OIL AND GAS CONSERVATION COMMISSION ADMINISTRATIVE APPROVAL NO. DIO 22.002 Re: Disposal Injection of Treated Sanitary Waste and Produced Water Mr. John Amundsen HSE Manager Forest Oil Corporation 310 K Street, Suite 700 J\nchorage,AJe 99501 Dear Mr. Amundsen: 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 By letter dated January 15, 2004, Forest Oil Corporation ("Forest") requested authorization to inject into Redoubt Unit #Dl a mixture of "non-hazardous treated sanitary waste with produced water." Well Dl is a Class II disposal well supporting operations at the Osprey platfonn located in the Cook Inlet. Disposal Injection Order (DIO) 22 does not list treated sanitary waste as eligible for injection into a Class II disposal well. Administrative Approval DIO 22.001 dated June 19, 2002, grants approval to Forest for the injection of storm water collected in the Osprey Platform deck drain system into Well #Dl. Forest identifies problems with meeting overboard discharge permit limits as the primary reason for the request; transportation to shore has been studied and detennined economically infeasible. . ',p Confinement of fluids to the intended injection zone in Well DI has been demonstrated by injection performance data provided by Forest. Injection of a commingled produced water and treated sanitary waste stream will have no detrimental effect on the confinement of fluids or well integrity. Exploration and production wastes associated with oil and gas development are exempt from the requirements of Section 300 I (b )(2) of the Resource Conservation and Recovery Act (RCRA). The exemption provides for mixing a non-hazardous waste with an exempt waste; the resulting commingled stream is considered exempt. Forest's proposed action to mix treated sanitary waste (non-hazardous, non- exempt) with the Osprey produced water waste stream (exempt) is consistent with the provisions of the RCRA exemption. Injection of the commingled stream into Well DI is the preferred alternative and is approved by the Commission. DONE at Anchorage, Alask The A1rÜ an ---- Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION c ((", Þ) IT",~ ~. '..11 F If ., "j ~ 'j \\" ',} ~~,. ,I f1 jî t ~;J' ~,:¡[¡- '\\ìl 'U . '- ~". l J ) ) ~ FOREST OIL CORPORATION .'J 1 () O/(è-Wlr(?(11 . o'/¡~(/(> 7 (}() OÇr;,chOlr{'~7~1, OC;;xf(a.1ka .9.9.5(}/ (907) ,:!!/;,S'-Sú'O() · (907) 2:SS-cS'úYN (C'J-Þa.,) January 15, 2004 Ms. Sarah Palin, Chair Alaska Oil and Gas Conservation Commission 333 W. ih Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Redoubt Unit #D 1 Class II Disposal Well Dear Ms. Palin: Forest Oil Corporation (Forest) is requesting approval to mix non-hazardous treated sanitary waste with produced water, (an exempt waste under Section 300 1 (b)(2) of the Resource Conservation and Recovery Act (RCRA); for injection into a Class II disposal well on the Osprey Platform, Cook Inlet. Forest is requesting permission to mix and inject the sanitary waste from the living quarters on the Osprey Platform due to its remote location and problems getting the sanitary treatment package to perform to meet discharge permit limitations. The facility currently discharges approximately 1600 gallons of treated sanitary waste per day. The facility currently disposes of (injects) approxÜllately 1500 barrels (63,000 gals) of produced water each day. Therefore the volume of sanitary waste would be approximately 2 per cent of the total volume injected. To allow the mixing of non hazardous treated sanitary waste with produced water, would be consistent with the USEPA's document "Exemption of Oil and Gas Exploration and Production Wastes from Federal Hazardous Waste Regulations" (EPA530-K-OI-0004). That document states: "Mixing a non-hazardous waste (exempt or non-exempt) with an exempt waste results in a mixture that is also exempt." Other oil producing states, i.e. Louisiana, have addressed the same issue and recognize that the mixing of "treated non-hazardous sanitary waste with produced water", is acceptable in a Class II disposal well. (See attached letter dated Deccn~ber 22, 2003). Forest has been working with our sanitary treatment system to meet permit conditions for over five years. We are still not able to maintain compliance with our permit conditions, even after having completely replaced the package plant at a considerable expense. We have looked at constructing holding tanks and hauling the sanitary wastes to shore for disposal, but that approach is not economically feasible. We ask that you give a favorable response to our request to mix the treated non-hazardous sanitary waste with produced water and dispose of this exempt mixture down Redoubt Unit #D 1. If you have any questions, please feel free to call me at 907-868-2139. P:\HSE\AOGCC RUD#l injection I 1-16-04,doc 0) ") 0 [\ ¡'~ f' 'I ¡ j t\,!\ ") .1: .' i ,J~;. 11...': I'"" ß\ ti\.~. M c: I, ' ^ ~ r. ¡ ;,y, :" ,~ .. ~,;JA../ll! ,~110 ¡i'<:j lC" " RECEIVED JAN 2 0 2004 Alaska Oil & Gas Cons. Commission Anchorage ) ) ~' '1(( ,""'...",', ~\t Ø,:i ~Ø,f."".',J:u,' ::is'll¡ . o{ U V, ; ~¿"',', ,". ~".. ~"~'"1'. q ~ ".':£ (¡r¡ ~, '¡1. . . JACK C. CALI)\\'ELL SECRETARY M.J. "MIKE" FOSTER, JR. GOVERNOR DEPARTMENT OF NATURAL RESOURCES (nrFICE ()F C()NSERVATl()N .JAMES H. WELSH COMMISSIONER OF CONSERV..!\nON Decenlber 22, 2003 Mr. L.E. Fontenot Forest Oil Corporation (1814) 4023 Alnbassador Caffery Parkway, Suite 200 Lafayette, LA 70503 Re: Sanitary Waste Injection Into Class II Disposal \\lells Yount Lee Oil Con1pany S\\lD No. 86, SN 973159 Sweet Lake Field, Cameron Parish, LA Dear Mr. Fontenot: In reply to your letter of Decenlber 8, 2003, regarding the above, please be advised that your proposal to mix treated nonhazardous sanitary \vaste with produced \vater (an exempt \vaste under Section 300] (b)(2) of RCRA), \vould result in a mixture that is also RCRA exempt. This determination is consistent \\lith USEP A's May 1995 document titled "Crude Oil and Natural Gas Exploration and Production Wastes from RCRA Subtitle C Regulation" (EP A530-K-95-003) and USEPA guidance provided in a letter to this Office dated April 20, 1993. Therefore, such exempt waste is eiigiblt: for injection into a Class II disposal well. Based on the above, the subject request is hereby granted. Contact Teresa Rougon at (225) 342- 5584 ¡fyou have questions. Yours truly, JanlCS H. \Velsh Comlnissioner of Conservation ./",.... /' seph S. Ball, Jr., Director Injection and Mining Division SC.t-\N1~EI':. ~JUN 2 3 2DDLJ. JH\V:JSB:thr F'l,SlRS,'!<.,,,,WCOMI'ASY UTn:RS,fORFS [' 01 I.'-S "'" IT A.RY w.A.sn' ISJlTIlO"P1 \" "I>J P. O. BOX 94275 . BATON ROUGE. LC>lnSIAt'\A 70:-\04··1)~75 . 61 ì NORTH THIRD STREET . B.-\TON ROllGE. LOUISIAt'\/\ 7mW2 ) ) ("1), ~j-~::!~' ¡¡:-"'? ~~ I VI 1~ .,'1 !' ~ j~ æ ~J ,.1 'u¡ TONY KNOWLES, GOVERNOR ALASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL NO. DIO 22.001 Re: Injection of storm water gathered on the deck of the Osprey Platform, Redoubt Unit. Gary E. Carlson Senior Vice President Forest Oil Corporation 310 K Street, Suite 700 Anchorage, Alaska 99501 Dear Mr. Carlson: By letter dated June 17, 2002, Forest Oil Corporation ("Forest") requested authorization to dispose of storm water collected in the deck drain system of the Osprey platform in the Redoubt Unit #D 1 disposal well. The estimated annual volume of storm water is approximately 3500 barrels, which represents the annual precipitation over the area of the platform. The Commission has determined that the storm water collected in the drain system of the Osprey Platform is suitable for disposal in the RU #Dl well and is the preferred alternative to discharge overboard from the platform. Therefore, as provided by Rule 6- Administrative Action, the Commission approves Forest's request for authorization to dispose of storm water collected in the deck drain system of the Osprey Platform in the Redoubt Unit #D 1 disposal well. DATED at Anchorage, Alaska and dated June 19,2002. c0~~~~y~'~ ~, OIL~~ Chair ~\ IT ~o'" ~ \ ~, / I) ~ ii:\~~\p " l- ........ t ~m, , ',~~~'f;)~~~~-~, A]~ '~~¡:,r:^J~,.,~,..A t:/ ~ ~~.....".",- . '. ""''''f'Q'' . 00 ' . J, t,'I', ~;,~_,I,' ..;' '-., ' ,~t·I'J".' =-%~ ~. r .~! "~ ~~~~~~;" ~ ~~ rJkl~l ¡....~~"L. 1'~ '"' \.~ of.! ,¡:....'JP... ..;~",..~ ~. ~ ~' .v1,. ').·¡;'.~,l~~,,~$í!! S(;/\\\JNfJ' 410N c§t1/' '-, ..., '-"." Daniel T. Seamount Commissioner \1 \~ TI \1\'1 (¡,'tI C1! f)nÍl f! ..,: ~Jr'',1 /. c.P (:..ßJl:'ò· OFFICE OF THE GOVERNOR, JOHN KATZ STE 518 444 N CAPITOL NW WASHINGTON, DC 20001 LIBRARY OF CONGRESS, STATE DOCUMENT SECTION EXCH & GI FT DIV 10 FIRST ST SE WASHINGTON, DC 20540 US GEOLOGICAL SURVEY, LIBRARY NATIONAL CTR MS 950 RESTON, VA ?2092 AMOCO CORP 2002A, LIBRARY/INFO CTR POBOX 87703 CHICAGO, IL 60680-0703 ALFRED JAMES III 107 N MARKET STE 1000 WICHITA, KS 67202-1811 XTO ENERGY, SUSAN LILLY 210 PARK AVE STE 2350 OKLAHOMA CITY, OK 73102-5605 OIL & GAS JOURNAL, LAURA BELL POBOX 1260 TULSA, OK 74101 US DEPT OF ENERGY, ENERGY INFORMATION ADMINISTRATION MIR YOUSUFUDDIN 1999 BRYAN STREET STE 1110 DALLAS, TX 75201-6801 XTO ENERGY, MARY JONES 810 HOUSTON ST STE 2000 FORT WORTH, TX 76102-6298 ') PIRA ENERGY GROUP, LIBRARY 3 PARK AVENUE (34th & PARK) NEW YORK, NY 10016 ARENT FOX KINTNER PLOTKIN KAHN, LIBRARY WASHINGTON SO BLDG 1050 CONNECTICUT AV NW WASHINGTON, DC 20036-5339 U S DEPT OF ENERGY, PHYLLIS MARTIN MS EI823 1000 INDEPENDENCE SW WASHINGTON, DC 20585 DPC, DANIEL DONKEL 1420 NORTH ATLANTIC AVE, STE 204 DAYTON BEACH, FL 32118 ILLINOIS STATE GEOL SURV, LIBRARY 469NATURALRESOURCESBLDG 615 E PEABODY DR CHAMPAIGN, IL 61820 MURPHY E&P CO, ROBERT F SAWYER POBOX 61780 NEW ORLEANS, LA 70161 IOGCC, POBOX 53127 OKLAHOMA CITY, OK 73152-3127 GAFFNEY, CLINE & ASSOC., INC., LIBRARY 16775 ADDISON RD, STE 400 ADDISON, TX 75001 DEGOL YER & MACNAUGHTON, MIDCONTINENT DIVISION ONE ENERGY SO, STE 400 4925 GREENVILLE AVE DALLAS, TX 75206-4083 SHELL WESTERN E&P INC, G.S. NADY POBOX 576 HOUSTON, TX 77001-0574 ) NY PUBLIC LIBRARY DIV E, GRAND CENTRAL STATION POBOX 2221 NEW YORK, NY 10163-2221 US MIN MGMT SERV, CHIEF OCS STATS & INFO 381 ELDEN ST MS 4022 HERNDON, VA 20170-4817 TECHSYS CORP, BRANDY KERNS PO BOX 8485 GATHERSBURG, MD 20898 SD DEPT OF ENV & NATRL RESOURCES, OIL & GAS PROGRAM 2050 W MAIN STE #1 RAPID CITY, SD 57702 LINDA HALL LIBRARY, SERIALS DEPT 5109 CHERRY ST KANSAS CITY, MO 64110-2498 UNIV OF ARKANSAS, SERIALS DEPT UNIV LIBRARIES FAYETTEVILLE, AR 72701 R E MCMILLEN CONSULT GEOL 202 E 16TH ST OWASSO, OK 74055-4905 BAPIRAJU 335 PINYON LN COPPELL, TX 75019 STANDARD AMERICAN OIL CO, AL GRIFFITH POBOX 370 GRANBURY, TX 76048 H J GRUY, A TIN: ROBERT RASOR 1200 SMITH STREET STE 3040 HOUSTON, TX 77002 ¡ í\~ 1."0 6) 1flli,P' "-~.r:,/\!t\H\~FJ_" Hi!1 t., '.I» ¿UU-} PURVIN & GERTZ INC, LIBRARY 2150 TEXAS COMMERCE TWR 600 TRAVIS ST HOUSTON, TX 77002-2979 OIL & GAS JOURNAL, BOB WILLIAMS 1700 W LOOP SOUTH STE 1000 HOUSTON, TX 77027 MARATHON OIL CO, GEORGE ROTHSCHILD JR RM 2537 POBOX 4813 HOUSTON, TX 77210 EXXON EXPLORATION CO., T E ALFORD POBOX 4778 HOUSTON, TX 77210-4778 PHILLIPS PETROLEUM COMPANY, W ALLEN HUCKABAY PO BOX 1967 HOUSTON, TX 77251-1967 EXXONMOBIL PRODUCTION COMPANY, J W KIKER ROOM 2086 POBOX 2180 HOUSTON, TX 77252-2180 MARATHON, Ms. Norma L. Calvert POBOX 3128, Ste 3915 HOUSTON, TX 77253-3128 TEXACO INC, R Ewing Clemons PO BOX 430 BELLAIRE, TX 77402-0430 INTL OIL SCOUTS, MASON MAP SERV INC POBOX 338 AUSTIN, TX 78767 DIANE SUCHOMEL 10507D W MAPLEWOOD DR LITTLETON, CO 80127 ) RAY TYSON 2016 MAIN #1415 HOUSTON, TX 77002-8844 PETRAL CONSULTING CO, DANIEL L LIPPE 9800 RICHMOND STE 505 HOUSTON, TX 77042 UNOCAL, REVENUE ACCOUNTING POBOX 4531 HOUSTON, TX 77210-4531 CHEVRON USA INC., ALASKA DIVISION ATTN: CORRY WOOLlNGTON POBOX 1635 HOUSTON, TX 77251 WORLD OIL, DONNA WILLIAMS POBOX 2608 HOUSTON, TX 77252 PENNZOIL E&P, WI LL D MCCROCKLI N POBOX 2967 HOUSTON, TX 77252-2967 ACE PETROLEUM COMPANY, ANDREW C CLIFFORD PO BOX 79593 HOUSTON, TX 77279-9593 WATTY STRICKLAND 2803 SANCTUARY CV KATY, TX 77450-8510 BABCOCK & BROWN ENERGY, INC., 350 INTERLOCKEN BLVD STE 290 BROOMFIELD, CO 80021 GEORGE G VAUGHT JR POBOX 13557 DENVER, CO 80201 ) CHEVRON, PAUL WALKER 1301 MCKINNEY RM 1750 HOUSTON, TX 77010 MARK ALEXANDER 7502 ALCOMITA HOUSTON, TX 77083 EXXON EXPLOR CO, LAND/REGULATORY AFFAIRS RM 301 POBOX 4778 HOUSTON, TX 77210-4778 PETR INFO, DAVID PHILLIPS POBOX 1702 HOUSTON, TX 77251-1702 EXXONMOBIL PRODUCTION COMPANY, GARY M ROBERTS RM 3039 POBOX 2180 HOUSTON, TX 77252-2180 CHEVRON CHEM CO, LIBRARY & INFO CTR POBOX 2100 HOUSTON, TX 77252-9987 PHILLIPS PETR CO, PARTNERSHIP OPRNS JIM JOHNSON 6330 W LOOP S RM 1132 BELLAIRE, TX 77401 TESORO PETR CORP, LOIS DOWNS 300 CONCORD PLAZA DRIVE SAN ANTONIO, TX 78216-6999 ROBERT G GRAVELY 7681 S KIT CARSON DR LITTLETON, CO 80122 US GEOLOGICAL SURVEY, LIBRARY BOX 25046 MS 914 DENVER, CO 80225-0046 S(J\li\~\Ì\~F\¡'" ,I,!\¡N 2 2 20ü~ C & R INDUSTRIES, INC." KURT SAL TSGA VER 7500 W MISSISSIPPI AVE STE C4 LAKEWOOD, CO 80226-4541 RUBICON PETROLEUM, LLC, BRUCE I CLARDY SIX PINE ROAD COLORADO SPRINGS, CO 80906 US GEOLOGICAL SURVEY, LIBRARY 2255 N GEMINI DR FLAGSTAFF, AZ 86001-1698 BABSON & SHEPPARD, JOHN F BERGQUIST POBOX 8279 VIKING STN LONG BEACH, CA 90808-0279 TEXACO INC, Portfolio Team Manager R W HILL POBOX 5197x Bakersfield, CA 93388 H L WANGENHEIM 5430 SAWMILL RD SP 11 PARADISE, CA 95969-5969 MARPLES BUSINESS NEWSLETTER, MICHAEL J PARKS 117 W MERCER ST STE 200 SEATTLE, WA 98119-3960 TRUSTEES FOR ALASKA, 1026 W. 4th Ave, Ste 201 ANCHORAGE, AK 99501 GUESS & RUDD, GEORGE LYLE 510 L ST, STE 700 ANCHORAGE, AK 99501 STATE PIPELINE OFFICE, LIBRARY KATE MUNSON 411 W 4TH AVE, STE 2 ANCHORAGE, AK 99501 ) JERRY HODGDEN GEOL 408 18TH ST GOLDEN, CO 80401 JOHN A LEVORSEN 200 N 3RD ST #1202 BOISE, ID 83702 MUNGER OIL INFOR SERV INC, POBOX 45738 LOS ANGELES, CA 90045-0738 ANTONIO MADRID POBOX 94625 PASADENA, CA 91109 US GEOLOGICAL SURVEY, KEN BIRD 345 MIDDLEFIELD RD MS 999 MENLO PARK, CA 94025 ECONOMIC INSIGHT INC, SAM VAN V ACTOR POBOX 683 PORTLAND, OR 97207 FAIRWEATHER E&P SERV INC, JESSE MOHRBACHER 7151 ST #4 ANCHORAGE, AK 99501 DEPT OF ENVIRON CONSERVATION, DIV OF ENVIRONMENTAL HEALTH JANICE ADAIR 555 CORDOVA STREET ANCHORAGE, AK 99501 DEPT OF REVENUE, OIL & GAS AUDIT DENISE HAWES 550 W 7TH A V STE 570 ANCHORAGE, AK 99501 FOREST OIL, JIM ARLINGTON 310 K STREET STE 700 ANCHORAGE, AK 99501 ) NRG ASSOC, RICHARD NEHRING POBOX 1655 COLORADO SPRINGS, CO 80901- 1655 TAHOMA RESOURCES, GARY PLAYER 1671 WEST 546 S CEDER CITY, UT 84720 LA PUBLIC LIBRARY, SERIALS DIV 630 W 5TH ST LOS ANGELES, CA 90071 ORO NEGRO, INC., 9321 MELVIN AVE NORTHRIDGE, CA 91324-2410 SHIELDS LIBRARY, GOVT DOCS DEPT UNIV OF CALIF DAVIS, CA 95616 US EPA REGION 10, THOR CUTLER OW-137 1200 SIXTH AVE SEATTLE, WA 98101 DEPT OF ENVIRON CONSERVATION, DIV OF AIR & WATER QUALITY TOM CHAPPLE 555 CORDOVA STREET ANCHORAGE, AK 99501 DUSTY RHODES 229 WHITNEY RD ANCHORAGE, AK 99501 DEPT OF REVENUE, BEVERLY MARQUART 550 W 7TH A V STE 570 ANCHORAGE, AK 99501 DEPT OF REVENUE, CHUCK LOGSTON 550 W 7TH AVE, SUITE 500 ANCHORAGE, AK 99501 '.",' ,¡\~.H\1.E,L) ~JUN 2- 3 2004. DEPT OF REVENUE, DAN DICKINSON, DIRECTOR 550 W 7TH AVE, SUITE 500 ANCHORAGE, AK 99501 ALASKA DEPT OF LAW, ROBERT E MINTZ ASST ATTY GEN 1031 W 4TH AV STE 200 ANCHORAGE, AK 99501-1994 DEPT OF REVENUE, OIL & GAS AUDIT FRANK PARR 550 W 7TH AVE STE 570 ANCHORAGE, AK 99501-3540 AK JOURNAL OF COMMERCE, OIL & INDUSTRY NEWS ROSE RAGSDALE 4220 B Street Ste #210 ANCHORAGE, AK 99501-3560 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS JULIE HOULE 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 N-I TUBULARS INC, 3301 C Street Ste 209 ANCHORAGE, AK 99503 ANADARKO, MARK HANLEY 3201 C STREET STE 603 ANCHORAGE, AK 99503 FINK ENVIRONMENTAL CONSULTING, INC., THOMAS FINK, PHD 6359 COLGATE DR. ANCHORAGE, AK 99504-3305 US BUREAU OF LAND MNGMNT, ANCHORAGE DIST OFC DICK FOLAND 6881 ABBOTT LOOP RD ANCHORAGE, AK 99507 UOA/ ANCHORAGE, INST OF SOCIAL & ECON RESEARCH TERESA HULL 3211 PROVIDENCE DR ANCHORAGE, AK 99508 ) ) YUKON PACIFIC CORP, JOHN HORN VICE CHM 1049 W 5TH AV ANCHORAGE, AK 99501-1930 PRESTON GATES ELLIS LLP, LIBRARY 420 L ST STE 400 ANCHORAGE, AK 99501-1937 GAFO,GREENPEACE PAMELA MILLER 125 CHRISTENSEN DR. #2 ANCHORAGE, AK 99501-2101 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS TIM RYHERD 550 W 7th AVE STE 800 ANCHORAGE, AK 99501-3510 DNR, DIV OF OIL & GAS JAMES B HAYNES NATURAL RESRCE MGR 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 DEPT OF NATURAL RESOURCES, PUBLIC INFORMATION CTR 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS BRUCE WEBB 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS JIM STOUFFER 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 DEPT OF NATURAL RESOURCES, DIV OIL & GAS WILLIAM VAN DYKE 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 BRISTOL ENVIR SERVICES, JIM MUNTER 2000 W. INT'L AIRPORT RD #C-1 ANCHORAGE, AK 99502-1116 BAKER OIL TOOLS, ALASKA AREA MGR 4710 BUS PK BLVD STE 36 ANCHORAGE, AK 99503 HDR ALASKA INC, MARK DALTON 2525 C ST STE 305 ANCHORAGE, AK 99503 ALASKA OIL & GAS ASSOC, JUDY BRADY 121 W FIREWEED LN STE 207 ANCHORAGE, AK 99503-2035 ANADRI LL-SCH LU MBERGER, 3940 ARCTIC BLVD #300 ANCHORAGE, AK 99503-5711 ARLEN EHM GEOL CONSL TNT 2420 FOXHALL DR ANCHORAGE, AK 99504-3342 JAMES E EASON 8611 LEEPER CIRCLE ANCHORAGE, AK 99504-4209 US BUREAU OF LAND MNGMNT, ANCHORAGE DIST OFC PETER J DITTON 6881 ABBOTT LOOP ROAD ANCHORAGE, AK 99507 AMERICA/CANADIAN STRA TIGRPH CO, RON BROCKWAY 4800 KUPREANOF ANCHORAGE, AK 99507 US BLM AK DIST OFC, GEOLOGIST ARTHUR BANET 949 EAST 36TH AVE STE 308 ANCHORAGE, AK 99508 THOMAS R MARSHALL JR 1569 BIRCHWOOD ST ANCHORAGE, AK 99508 SCf\NNEJ \ ,'iUN ? '3 {"oaf} VECO ALASKA INC., CHUCK O'DONNELL 949 EAST 36TH AVENUE ANCHORAGE, AK 99508 US MIN MGMT SERV, RESOURCE STUDIES AK OCS REGN KIRK W SHERWOOD 949 E 36TH A V RM 603 ANCHORAGE, AK 99508-4302 US MIN MGMT SERV, FRANK MILLER 949 E 36TH A V STE 603 ANCHORAGE, AK 99508-4363 US MIN MGMT SERV, RESOURCE EVAL JIM SCHERR 949 E 36TH A V RM 603 ANCHORAGE, AK 99508-4363 CIRI, LAND DEPT POBOX 93330 ANCHORAGE, AK 99509-3330 PHILLIPS ALASKA, JOANN GRUBER ATO 712 POBOX 100360 ANCHORAGE, AK 99510-0360 PHILLIPS ALASKA, LEGAL DEPT MARK P WORCESTER POBOX 100360 ANCHORAGE, AK 99510-0360 PHILLIPS ALASKA, KUP CENTRAL WELLS ST TSTNG WELL ENG TECH NSK 69 POBOX 196105 ANCHORAGE, AK 99510-6105 US BUREAU OF LAND MGMT, OIL & GAS OPRNS (984) J A DYGAS 222 W 7TH AV #13 ANCHORAGE, AK 99513-7599 JODY COLOMBIE 6811 ROUND TREE DRIVE ANCHORAGE, AK 99516 ) TRADING BAY ENERGY CORP, PAUL CRAIG 5432 NORTHERN LIGHTS BLVD ANCHORAGE, AK 99508 US MIN MGMT SERV, RICHARD PRENTKI 949 E 36TH AV ANCHORAGE, AK 99508-4302 REGIONAL SUPRVISOR, FIELD OPERATNS, MMS ALASKA OCS REGION 949 E 36TH A V STE 308 ANCHORAGE, AK 99508-4363 JOHN MILLER 3445 FORDHAM DR ANCHORAGE, AK 99508-4555 PHILLIPS ALASKA, LAND MANAGER JIM RUUD P.O. BOX 100360 ANCHORAGE, AK 99510 PHILLIPS ALASKA, LAND DEPT JAMES WINEGARNER POBOX 10036 ANCHORAGE, AK 99510-0360 PHILLIPS ALASKA, STEVE BENZLER ATO 1404 POBOX 100360 ANCHORAGE, AK 99510-0360 AL YESKA PIPELINE SERV CO, PERRY A MARKLEY 1835 S BRAGAW - MS 575 ANCHORAGE, AK 99512 ANCHORAGE DAILY NEWS, EDITORIAL PG EDTR MICHAEL CAREY POBOX 149001 ANCHORAGE, AK 99514 JWL ENGINEERING, JEFF LIPSCOMB 9921 MAIN TREE DR. ANCHORAGE, AK 99516-6510 ) US MIN MGMT SERV, AK OCS REGIONAL DIR 949 E 36TH AV RM 110 ANCHORAGE, AK 99508-4302 GORDON J. SEVERSON 3201 WESTMAR CIR ANCHORAGE, AK 99508-4336 US MIN MGMT SERV, LIBRARY 949 E 36TH A V RM 603 ANCHORAGE, AK 99508-4363 USGS - ALASKA SECTION, LIBRARY 4200 UNIVERSITY DR ANCHORAGE, AK 99508-4667 ANCHORAGE TIMES, BERT TARRANT POBOX 100040 ANCHORAGE, AK 99510-0040 PHILLIPS ALASKA, MARK MAJOR A TO 1968 POBOX 100360 ANCHORAGE, AK 99510-0360 PETROLEUM INFO CORP, KRISTEN NELSON POBOX 102278 ANCHORAGE, AK 99510-2278 AL YESKA PIPELINE SERV CO, LEGAL DEPT 1835 S BRAGAW ANCHORAGE, AK 99512-0099 DAVID W. JOHNSTON 320 MARINER DR. ANCHORAGE, AK 99515 NORTHERN CONSULTING GROUP, ROBERT BRITCH, P.E. 2454 TELEQUANA DR. ANCHORAGE, AK 99517 Ii ¡ "1 ß1 6)) '1fit"'i A ,J~.J N t.~ r:¡þ LUll'" ~ GERALD GANOPOLE CONSULT GEOL 2536 ARLINGTON ANCHORAGE, AK 99517-1303 ARMAND SPIELMAN 651 HILANDER CIRCLE ANCHORAGE, AK 99518 JACK 0 HAKKILA POBOX 190083 ANCHORAGE, AK 99519-0083 MARATHON OIL CO, LAND BROCK RIDDLE POBOX 196168 ANCHORAGE, AK 99519-6168 EXXONMOBIL PRODUCTION COMPANY, MARK P EVANS PO BOX 196601 ANCHORAGE, AK 99519-6601 BP EXPLORATION (ALASKA) INC, PETE ZSELECZKY LAND MGR POBOX 196612 ANCHORAGE, AK 99519-6612 AMSINALLEE CO INC, WILLIAM 0 VALLEE PRES PO BOX 243086 ANCHORAGE, AK 99524-3086 DA PLATT & ASSOC, 9852 LITTLE DIOMEDE CIR EAGLE RIVER, AK 99577 COOK INLET KEEPER, BOB SHA VELSON PO BOX 3269 HOMER. AK 99603 DOCUMENT SERVICE CO, JOHN PARKER POBOX 1468 KENAI, AK 99611-1468 ) DAVID CUSATO 600 W 76TH A V #508 ANCHORAGE, AK 99518 HALLIBURTON ENERGY SERV, MARK WEDMAN 6900 ARCTIC BLVD ANCHORAGE, AK 99518-2146 ENSTAR NATURAL GAS CO, PRESIDENT TONY IZZO POBOX 190288 ANCHORAGE, AK 99519-0288 UNOCAL, POBOX 196247 ANCHORAGE, AK 99519-6247 BP EXPLORATION (ALASKA), INC., MARK BERLINGER MB 8-1 PO BOX 196612 ANCHORAGE, AK 99519-6612 BP EXPLORATION (ALASKA) INC, INFO RESOURCE CTR MB 3-2 POBOX 196612 ANCHORAGE, AK 99519-6612 L G POST O&G LAND MGMT CONSULT 10510 Constitution Circle EAGLE RIVER, AK 99577 JAMES RODERICK PO BOX 770471 EAGLE RIVER, AK 99577-0471 RON DOLCHOK PO BOX 83 KENAI, AK 99611 KENAI PENINSULA BOROUGH, ECONOMIC DEVEL DISTR STAN STEADMAN POBOX 3029 KENAI, AK 99611-3029 ) ASRC, CONRAD BAGNE 301 ARCTIC SLOPE A V STE 300 ANCHORAGE, AK 99518 OPST AD & ASSOC, ERIK A OPSTAD PROF GEOL POBOX 190754 ANCHORAGE, AK 99519 MARATHON OIL CO, OPERATIONS SUPT W.C. BARRON POBOX 196168 ANCHORAGE, AK 99519-6168 UNOCAL, KEVIN TABLER POBOX 196247 ANCHORAGE, AK 99519-6247 BP EXPLORATION (ALASKA) INC, SUE MILLER POBOX 196612 MIS LR2-3 ANCHORAGE, AK 99519-6612 BP EXPLORATION (ALASKA) INC, MR. DAVIS, ESQ POBOX 196612 MB 13-5 ANCHORAGE, AK 99519-6612 PINNACLE, STEVE TYLER 20231 REVERE CIRCLE EAGLE RIVER, AK 99577 DEPT OF NATURAL RESOURCES, DGGS JOHN REEDER POBOX 772805 EAGLE RIVER, AK 99577-2805 PHILLIPS PETROLEUM CO, ALASKA OPERATIONS MANAGER J W KONST PO DRAWER 66 KENAI, AK 99611 NANCY LORD PO BOX 558 HOMER, AK 99623 'I"J \ JUN 2 320D!1 PENNY VADLA POBOX 467 NINILCHIK, AK 99639 PACE, SHEILA DICKSON POBOX 2018 SOLDOTNA, AK 99669 AL YESKA PIPELINE SERVICE CO, VALDEZ CORP AFFAIRS SANDY MCCLINTOCK POBOX 300 MS/701 VALDEZ, AK 99686 UNIV OF ALASKA FAIRBANKS, PETR DEVEL LAB DR V A KAMATH 427 DUCKERING FAIRBANKS, AK 99701 C BURGLlN POBOX 131 FAIRBANKS, AK 99707 K&K RECYCL INC, POBOX 58055 FAIRBANKS, AK 99711 UNIV OF ALASKA FBX, PETR DEVEL LAB SHIRISH PATIL 437 DICKERING FAIRBANKS, AK 99775 DEPT OF ENVIRON CONSERV SPAR, CHRIS PACE 410 WILLOUGHBY AV STE 105 JUNEAU, AK 99801-1795 ) ') BELOWICH, MICHAEL A BELOWICH 1125 SNOW HILL AVE WASILLA, AK 99654-5751 JAMES GIBBS POBOX 1597 SOLDOTNA, AK 99669 KENAI NATL WILDLIFE REFUGE, REFUGE MGR POBOX 2139 SOLDOTNA, AK 99669-2139 VALDEZ PIONEER, POBOX 367 VALDEZ,AK 99686 VALDEZ VANGUARD, EDITOR POBOX 98 VALDEZ, AK 99686-0098 NICK STEPOVICH 543 2ND AVE FAIRBANKS, AK 99701 RICK WAGNER POBOX 60868 FAIRBANKS, AK 99706 FAIRBANKS DAILY NEWS-MINER, KATE RIPLEY POBOX 70710 FAIRBANKS, AK 99707 FRED PRATT POBOX 72981 FAIRBANKS, AK 99707-2981 DEPT OF NATURAL RESOURCES, DIV OF LAND REG MGR NORTHERN REGION 3700 AIRPORT WAY FAIRBANKS, AK 99709-4699 ASRC, BILL THOMAS POBOX 129 BARROW, AK 99723 RICHARD FINEBERG POBOX 416 ESTER, AK 99725 UNIVERSITY OF ALASKA FBKS, PETR DEVELLAB DR AKANNI LAWAL POBOX 755880 FAIRBANKS, AK 99775-5880 SENATOR LOREN LEMAN STATE CAPITOL RM 113 JUNEAU,AK 99801-1182 '~~:J\~~¡\~EC JUN ~ 3 2.00t( NY PUBLIC LIBRARY DIV E, GRAND CENTRAL STATION POBOX 2221 NEW YORK, NY 10163-2221 US MIN MGMT SERV, CHIEF OCS STATS & INFO 381 ELDEN ST MS 4022 HERNDON, VA 20170-4817 TECHSYS CORP, BRANDY KERNS PO BOX 8485 GATHERSBURG, MD 20898 SD DEPT OF ENV & NATRL RESOURCES, OIL & GAS PROGRAM 2050 W MAIN STE #1 RAPID CITY, SD 57702 LINDA HALL LIBRARY, SERIALS DEPT 5109 CHERRY ST KANSAS CITY, MO 64110-2498 10GCC, POBOX 53127 OKLAHOMA CITY, OK 73152-3127 BAPIRAJU 335 PINYON LN COPPELL, TX 75019 STANDARD AMERICAN OIL CO, AL GRIFFITH POBOX 370 GRANBURY, TX 76048 H J GRUY, ROBERT RASOR 333 CLAY STREET SUITE 3850 HOUSTON, TX 77002 CHEVRON, PAUL WALKER 1301 MCKI NNEY RM 1750 HOUSTON, TX 77010 ) ) OFFICE OF THE GOVERNOR, JOHN KATZ STE 518 444 N CAPITOL NW WASHINGTON, DC 20001 ARENT FOX KINTNER PLOTKIN KAHN, LIBRARY WASHINGTON SQ BLDG 1050 CONNECTICUT A V NW WASHINGTON, DC 20036-5339 LIBRARY OF CONGRESS, STATE DOCUMENT SECTION EXCH & GIFT DIV 10 FIRST ST SE WASHINGTON, DC 20540 U S DEPT OF ENERGY, PHYLLIS MARTIN MS EI823 1000 INDEPENDENCE SW WASHINGTON, DC 20585 US GEOLOGICAL SURVEY, LIBRARY NATIONAL CTR MS 950 RESTON, VA 22092 DPC, DANIEL DONKEL 2121 NORTH BA YSHORE DR #616 MIAMI, FL 33137 BP EXPLORATION (ALASKA), INC., LIBRARY/INFO CTR POBOX 87703 CHICAGO, IL 60680-0703 ILLINOIS STATE GEOL SURV, LIBRARY 469 NATURAL RESOURCES BLDG 615 E PEABODY DR CHAMPAIGN, IL 61820 ALFRED JAMES III 107 N MARKET STE 1000 WICHITA, KS 67202-1811 UNIV OF ARKANSAS, SERIALS DEPT UNIV LIBRARIES FAYETTEVILLE, AR 72701 R E MCMILLEN CONSULT GEOL 202 E 16TH ST OWASSO, OK 74055-4905 OIL & GAS JOURNAL, LAURA BELL POBOX 1260 TULSA, OK 74101 US DEPT OF ENERGY, ENERGY INFORMATION ADMINISTRATION MIR YOUSUFUDDIN 1999 BRYAN STREET STE 1110 DALLAS, TX 75201-6801 DEGOL YER & MACNAUGHTON, MIDCONTINENT DIVISION ONE ENERGY SQ, STE 400 4925 GREENVILLE AVE DALLAS, TX 75206-4083 XTO ENERGY, MARY JONES 810 HOUSTON ST STE 2000 FORT WORTH, TX 76102-6298 SHELL WESTERN E&P INC, G.S. NADY POBOX 576 HOUSTON, TX 77001-0574 PURVIN & GERTZ INC, LIBRARY 2150 TEXAS COMMERCE TWR 600 TRAVIS ST HOUSTON, TX 77002-2979 RAY TYSON 2016 MAIN #1415 HOUSTON, TX 77002-8844 OIL & GAS JOURNAL, BOB WILLIAMS 1700 W LOOP SOUTH STE 1000 HOUSTON, TX 77027 PETRAL CONSULTING CO, DANIEL L LIPPE 9800 RICHMOND STE 505 HOUSTON, TX 77042 '::,(,¡,'::,r~~~EC: JUN 2~ $ 2.004 AURORA GAS, G. SCOTT PFOFF 10333 RICHMOND AVENUE, STE 710 HOUSTON, TX 77042 MARK ALEXANDER 7502 ALCOMIT A HOUSTON, TX 77083 EXXON EXPLOR CO, LAND/REGULATORY AFFAIRS RM 301 POBOX 4778 HOUSTON, TX 77210-4778 PETR INFO, DAVID PHILLIPS POBOX 1702 HOUSTON, TX 77251-1702 EXXONMOBIL PRODUCTION COMPANY, J W KIKER ROOM 2086 POBOX 2180 HOUSTON, TX 77252-2180 MARATHON OIL COMPANY, NORMA L. CALVERT POBOX 3128, Ste 3915 HOUSTON, TX 77253-3128 TESORO PETR CORP, LOIS DOWNS 300 CONCORD PLAZA DRIVE SAN ANTONIO, TX 78216-6999 XTO ENERGY, DOUG SCHULTZE 3000 N GARFIELD SUITE 175 MIDLAND, TX 79705 DIANE SUCHOMEL 10507D W MAPLEWOOD DR LITTLETON, CO 80127 C & R INDUSTRIES, INC." KURT SAL TSGA VER 7500 W MISSISSIPPI AVE STE C4 LAKEWOOD, CO 80226-4541 ) ') GAFFNEY, CLINE & ASSOC., INC., LIBRARY 1360 POST OAK BLVD., STE 2500 HOUSTON, TX 77056 MARATHON OIL COMPANY, WILLIAM R HOLTON, JR. 5555 SAN FELIPE STREET SUITE 2511 HOUSTON, TX 77056-2799 UNOCAL, REVENUE ACCOUNTING POBOX 4531 HOUSTON, TX 77210-4531 EXXON EXPLORATION CO., T E ALFORD POBOX 4778 HOUSTON, TX 77210-4778 TEXACO EXPLORATION & PRODUCTION INC, CORRY WOOLlNGTON PO BOX 36366 HOUSTON, TX 77236 CHEVRON USA INC., ALASKA DIVISION ATTN: CORRY WOOLlNGTON POBOX 1635 HOUSTON, TX 77251 PHILLIPS PETROLEUM COMPANY, W ALLEN HUCKABAY PO BOX 1967 HOUSTON, TX 77251-1967 WORLD OIL, DONNA WILLIAMS POBOX 2608 HOUSTON, TX 77252 PENNZOIL E&P, WILL 0 MCCROCKLIN POBOX 2967 HOUSTON, TX 77252-2967 CHEVRON CHEM CO, LIBRARY & INFO CTR POBOX 2100 HOUSTON, TX 77252-9987 ACE PETROLEUM COMPANY, ANDREW C CLIFFORD PO BOX 79593 HOUSTON, TX 77279-9593 WATTY STRICKLAND 2803 SANCTUARY CV KATY, TX 77450-8510 JIM WHITE 4614 BOHILL SAN ANTONIO, TX 78217 INTL OIL SCOUTS, MASON MAP SERV INC POBOX 338 AUSTIN, TX 78767 BABCOCK & BROWN ENERGY, INC., 350 INTERLOCKEN BLVD STE 290 BROOMFIELD, CO 80021 ROBERT G GRAVELY 7681 S KIT CARSON DR LITTLETON, CO 80122 GEORGE G VAUGHT JR POBOX 13557 DENVER, CO 80201 US GEOLOGICAL SURVEY, LIBRARY BOX 25046 MS 914 DENVER, CO 80225-0046 -:(" 1"',111-,:'- liU' :I~" ~~ 0} 'JOflf; ~" ~ ~"r-"} '~ iI'<~, C. 1 j ~J ! 'Ii {¿ I.J t.. ~ W i.,J. JERRY HODGDEN GEOL 408 18TH ST GOLDEN, CO 80401 NRG ASSOC, RICHARD NEHRING POBOX 1655 COLORADO SPRINGS, CO 80901- 1655 RUBICON PETROLEUM, LLC, BRUCE I CLARDY SIX PINE ROAD COLORADO SPRINGS, CO 80906 US GEOLOGICAL SURVEY, LIBRARY 2255 N GEMINI DR FLAGSTAFF, AZ 86001-1698 ANTONIO MADRID POBOX 94625 PASADENA, CA 91109 SHIELDS LIBRARY, GOVT DOCS DEPT UNIV OF CALIF DAVIS, CA 95616 US EPA REGION 10, THOR CUTLER OW-137 1200 SIXTH AVE SEATTLE, WA 98101 TRUSTEES FOR ALASKA, 1026 W. 4th Ave, Ste 201 ANCHORAGE, AK 99501 FOREST OIL, JIM ARLINGTON 310 K STREET STE 700 ANCHORAGE, AK 99501 AURORA GAS, J. EDWARD JONES 1029 W 3RD AVE, STE 220 ANCHORAGE, AK 99501 DEPT OF REVENUE, OIL & GAS AUDIT DENISE HAWES 550 W 7TH A V STE 570 ANCHORAGE, AK 99501 PRESTON GATES ELLIS LLP, LIBRARY 420 L ST STE 400 ANCHORAGE, AK 99501-1937 ) JOHN A LEVORSEN 200 N 3RD ST #1202 BOISE,ID 83702 MUNGER OIL INFOR SERV INC, POBOX 45738 LOS ANGELES, CA 90045-0738 ORO NEGRO, INC., 9321 MELVIN AVE NORTHRIDGE, CA 91324-2410 H L WANGENHEIM 5430 SAWMILL RD SP 11 PARADISE, CA 95969-5969 MARPLES BUSINESS NEWSLETTER, MICHAEL J PARKS 117 W MERCER ST STE 200 SEATTLE, WA 98119-3960 DUSTY RHODES 229 WHITNEY RD ANCHORAGE, AK 99501 DEPT OF ENVIRON CONSERVATION, DIV OF AIR & WATER QUALITY TOM CHAPPLE 555 CORDOVA STREET ANCHORAGE, AK 99501 DEPT OF REVENUE, CHUCK LOGSTON 550 W 7TH AVE, SUITE 500 ANCHORAGE, AK 99501 STATE PIPELINE OFFICE, LIBRARY KATE MUNSON 411 W 4TH AVE, STE 2 ANCHORAGE, AK 99501 ALASKA DEPT OF LAW, ROBERT E MINTZ ASST ATTY GEN 1031 W 4TH AV STE 200 ANCHORAGE, AK 99501-1994 ) PLAYER GAS CO., GARY PLAYER 1671 WEST 546 S CEDER CITY, UT 84720 BABSON & SHEPPARD, JOHN F BERGQUIST POBOX 8279 VIKING STN LONG BEACH, CA 90808-0279 US GEOLOGICAL SURVEY, KEN BIRD 345 MIDDLEFIELD RD MS 999 MENLO PARK, CA 94025 ECONOMIC INSIGHT INC, SAM VAN V ACTOR POBOX 683 PORTLAND, OR 97207 DEPT OF REVENUE, DAN DICKINSON, DIRECTOR 550 W 7TH AVE, SUITE 500 ANCHORAGE, AK 99501 DEPT OF REVENUE, BEVERLY MARQUART 550 W 7TH A V STE 570 ANCHORAGE, AK 99501 DEPT OF ENVIRON CONSERVATION, DIV OF ENVIRONMENTAL HEALTH JANICE ADAIR 555 CORDOVA STREET ANCHORAGE, AK 99501 FAIRWEATHER, DUANE VAAGEN 715 L STREET STE 7 ANCHORAGE, AK 99501 GUESS & RUDD, GEORGE LYLE 510 L ST, STE 700 ANCHORAGE, AK 99501 ~,.' 'i' ~~'~n - "~lhhJ1'<j¡C,r':, n ~~¡ I.) 6'ì 20n (¡ ~"., ,,~ I;.,q \j t'(. o;¡) fJg. GAFO,GREENPEACE PAMELA MILLER 125 CHRISTENSEN DR. #2 ANCHORAGE, AK 99501-2101 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS TIM RYHERD 550 W 7th AVE STE 800 ANCHORAGE, AK 99501-3510 DEPT OF NATURAL RESOURCES, DIV OIL & GAS WILLIAM VAN DYKE 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS JULIE HOULE 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 BRISTOL ENVIR AND ENG SERVICE, MIKE TORPY 2000 W. INT'L AIRPORT RD #C-1 ANCHORAGE, AK 99502-1116 YUKON PACIFIC CORP, 1400 W BENSON BLVD STE 525 ANCHORAGE, AK 99503 ALASKA 01 L & GAS ASSOC, JUDY BRADY 121 W FIREWEED LN STE 207 ANCHORAGE, AK 99503-2035 ARLEN EHM GEOL CONSL TNT 2420 FOXHALL DR ANCHORAGE, AK 99504-3342 US BUREAU OF LAND MNGMNT, ANCHORAGE DIST OFC DICK FOLAND 6881 ABBOTT LOOP RD ANCHORAGE, AK 99507 ROSE RAGSDALE 3320 EAST 41ST AVENUE ANCHORAGE, AK 99508 UOAJ ANCHORAGE, INST OF SOCIAL.: & ECON RESEARCH TERESA HULL 3211 PROVIDENCE DR ANCHORAGE, AK 99508 ) ) DEPT OF REVENUE, OIL & GAS AUDIT FRANK PARR 550 W 7TH AVE STE 570 ANCHORAGE, AK 99501-3540 DNR, DIV OF OIL & GAS JAMES B HAYNES NATURAL RESRCE MGR 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS JIM STOUFFER 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS BRUCE WEBB 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 ALASKA JOURNAL OF COMMERCE, ED BENNETT 2000 INTL AIRPORT W #A10 ANCHORAGE, AK 99502 AK JOURNAL OF COMMERCE, OIL & INDUSTRY NEWS ROSE RAGSDALE 2000 INTL AIRPORT RD W #A10 ANCHORAGE, AK 99502 HDR ALASKA INC, MARK DALTON 2525 C ST STE 305 ANCHORAGE, AK 99503 BAKER OIL TOOLS, ALASKA AREA MGR 4710 BUS PK BLVD STE 36 ANCHORAGE, AK 99503 N-I TUBULARS INC, 3301 C Street Ste 209 ANCHORAGE, AK 99503 ANADARKO, MARK HANLEY 3201 C STREET STE 603 ANCHORAGE, AK 99503 ANADRI LL -SCH LU MBERGER, 3940 ARCTIC BLVD #300 ANCHORAGE, AK 99503-5711 FINK ENVIRONMENTAL CONSULTING, INC., THOMAS FINK, PHD 6359 COLGATE DR. ANCHORAGE, AK 99504-3305 JAMES E EASON 8611 LEEPER CIRCLE ANCHORAGE, AK 99504-4209 AMERICA/CANADIAN STRATIGRPH CO, RON BROCKWAY 4800 KUPREANOF ANCHORAGE, AK 99507 BUREAU OF LAND MANAGEMENT, GREG NOBLE 6881 ABBOTT LOOP ROAD ANCHORAGE, AK 99507 US BUREAU OF LAND MNGMNT, ANCHORAGE DIST OFC PETER J DITTON 6881 ABBOTT LOOP ROAD ANCHORAGE, AK 99507 VECO ALASKA INC., CHUCK O'DONNELL 949 EAST 36TH AVENUE ANCHORAGE, AK 99508 TRADING BAY ENERGY CORP, PAUL CRAIG 5432 NORTHERN LIGHTS BLVD ANCHORAGE, AK 99508 US BLM AK DIST OFC, GEOLOGI~T,__ 'I"~ :'.,\.>'::'~' ìnN f!~ 3 2.ÛGl~. ARTHUR BANET ~"\'do-"d~r'(L...cc..- v THOMAS R MARSHALL JR 949 EAST 36TH AVE STE 308 1569 BIRCHWOOD ST ANCHORAGE, AK 99508 ANCHORAGE, AK 99508 US MIN MGMT SERV, RICHARD PRENTKI 949 E 36TH AV ANCHORAGE, AK 99508-4302 GORDONJ.SEVERSON 3201 WESTMAR CIR ANCHORAGE, AK 99508-4336 US MIN MGMT SERV, RESOURCE EVAL JIM SCHERR 949 E 36TH A V RM 603 ANCHORAGE, AK 99508-4363 USGS - ALASKA SECTION, LIBRARY 4200 UNIVERSITY DR ANCHORAGE, AK 99508-4667 PHILLIPS ALASKA INC., JOANN GRUBER ATO 712 POBOX 100360 ANCHORAGE, AK 99510-0360 PHILLIPS ALASKA INC., MARK MAJ OR A TO 1968 POBOX 100360 ANCHORAGE, AK 99510-0360 PHILLIPS ALASKA INC., KUP CENTRAL WELLS ST TSTNG WELL ENG TECH NSK 69 POBOX 196105 ANCHORAGE, AK 99510-6105 ANCHORAGE DAILY NEWS, EDITORIAL PG EDTR MICHAEL CAREY POBOX 149001 ANCHORAGE, AK 99514 NORTHERN CONSULTING GROUP, ROBERT BRITCH, P.E. 2454 TELEQUANA DR. ANCHORAGE, AK 99517 ASRC, CONRAD SAGNE 301 ARCTIC SLOPE AV STE 300 ANCHORAGE, AK 99518 ) US MIN MGMT SERV, AK OCS REGIONAL DIR 949 E 36TH AV RM 110 ANCHORAGE, AK 99508-4302 US MIN MGMT SERV, FRANK MILLER 949 E 36TH A V STE 603 ANCHORAGE, AK 99508-4363 US MIN MGMT SERV, LIBRARY 949 E 36TH A V RM 603 ANCHORAGE, AK 99508-4363 CIRI, LAND DEPT POBOX 93330 ANCHORAGE, AK 99509-3330 PHILLIPS ALASKA INC., LEGAL DEPT MARK P WORCESTER POBOX 100360 ANCHORAGE, AK 99510-0360 PHILLIPS ALASKA INC., LAND DEPT JAMES WINEGARNER POBOX 10036 ANCHORAGE, AK 99510-0360 AL YESKA PIPELINE SERV CO, PERRY A MARKLEY 1835 S BRAGAW - MS 575 ANCHORAGE, AK 99512 DAVID W. JOHNSTON 320 MARINER DR. ANCHORAGE, AK 99515 GERALD GANOPOLE CONSULT GEOL 2536 ARLINGTON ANCHORAGE, AK 99517-1303 ARMAND SPIELMAN 651 HILANDER CIRCLE ANCHORAGE, AK 99518 ) US MIN MGMT SERV, RESOURCE STUDIES AK OCS REGN KIRK W SHERWOOD 949 E 36TH A V RM 603 ANCHORAGE, AK 99508-4302 REGIONAL SUPRVISOR, FIELD OPERATION, MMS ALASKA OCS REGION 949 E 36TH A V STE 308 ANCHORAGE, AK 99508-4363 JOHN MILLER 3445 FORDHAM DR ANCHORAGE, AK 99508-4555 PHILLIPS ALASKA INC., LAND MANAGER JIM RUUD P.O. BOX 100360 ANCHORAGE, AK 99510 PHILLIPS ALASKA INC., STEVE BENZLER ATO 1404 POBOX 100360 ANCHORAGE, AK 99510-0360 PETROLEUM INFO CORP, KRISTEN NELSON POBOX 102278 ANCHORAGE, AK 99510-2278 AL YESKA PIPELINE SERV CO, LEGAL DEPT 1835 S BRAGAW ANCHORAGE, AK 99512-0099 JWL ENGINEERING, JEFF LIPSCOMB 9921 MAIN TREE DR. ANCHORAGE, AK 99516-6510 DAVID CUSATO 600 W 76TH A V #508 ANCHORAGE, AK 99518 HALLIBURTON ENERGY SERV, MARK WEDMAN 6900 ARCTIC BLVD ANCHORAGE, AK 99518-2146 ~~ û) 00n rJ \;\,i( (, OlD l. t.J¿ll· TESORO ALASKA COMPANY, PO BOX 196272 ANCHORAGE, AK 99519 ENSTAR NATURAL GAS CO, PRESIDENT TONY IZZO POBOX 190288 ANCHORAGE, AK 99519-0288 UNOCAL, POBOX 196247 ANCHORAGE, AK 99519-6247 BP EXPLORATION (ALASKA) INC, MR. DAVIS, ESQ POBOX 196612 MB 13-5 ANCHORAGE, AK 99519-6612 BP EXPLORATION (ALASKA) INC, SUE MILLER POBOX 196612 MIS LR2-3 ANCHORAGE, AK 99519-6612 PINNACLE, STEVE TYLER 20231 REVERE CIRCLE EAGLE RIVER, AK 99577 JAMES RODERICK PO BOX 770471 EAGLE RIVER, AK 99577-0471 PHILLIPS PETROLEUM CO, ALASKA OPERATIONS MANAGER J W KONST P 0 DRAWER 66 KENAI, AK 99611 KENAI PENINSULA BOROUGH, ECONOMIC DEVEL DISTR STAN STEADMAN POBOX 3029 KENAI, AK 99611-3029 BELOWICH, MICHAEL A BELOWICH 1125 SNOW HILL AVE WASILLA, AK 99654-5751 ) ) OPSTAD & ASSOC, ERIK A OPSTAD PROF GEOL POBOX 190754 ANCHORAGE, AK 99519 JACK 0 HAKKILA POBOX 190083 ANCHORAGE, AK 99519-0083 MARATHON OIL COMPANY, OPERATIONS SUPT W.C. BARRON POBOX 196168 ANCHORAGE, AK 99519-6168 MARATHON OIL COMPANY, LAND BROCK RIDDLE POBOX 196168 ANCHORAGE, AK 99519-6168 UNOCAL, KEVIN TABLER POBOX 196247 ANCHORAGE, AK 99519-6247 EXXONMOBIL PRODUCTION COMPANY, MARK P EVANS PO BOX 196601 ANCHORAGE, AK 99519-6601 BP EXPLORATION (ALASKA) INC, INFO RESOURCE CTR MB 3-2 POBOX 196612 ANCHORAGE, AK 99519-6612 BP EXPLORATION (ALASKA) INC, PETE ZSELECZKY LAND MGR POBOX 196612 ANCHORAGE, AK 99519-6612 BP EXPLORATION (ALASKA), INC., MARK BERLINGER MB 8-1 PO BOX 196612 ANCHORAGE, AK 99519-6612 AMSINALLEE CO INC, WILLIAM 0 VALLEE PRES PO BOX 243086 ANCHORAGE, AK 99524-3086 L G POST O&G LAND MGMT CONSULT 10510 Constitution Circle EAGLE RIVER, AK 99577 o A PLATT & ASSOC, 9852 LITTLE DIOMEDE CIR EAGLE RIVER, AK 99577 DEPT OF NATURAL RESOURCES, DGGS JOHN REEDER POBOX 772805 EAGLE RIVER, AK 99577-2805 COOK INLET KEEPER, BOB SHAVELSON PO BOX 3269 HOMER, AK 99603 RON DOLCHOK POBOX 83 KENAI, AK 99611 DOCUMENT SERVICE CO, JOHN PARKER POBOX 1468 KENAI, AK 99611-1468 NANCY LORD PO BOX 558 HOMER, AK 99623 PENNY VADLA PO BOX 467 NINILCHIK, AK 99639 JAMES GIBBS POBOX 1597 SOLDOTNA, AK 99669 . ,,-.~- ¡It TIP ~ Q, 20fìUl ,:S (;1'..;.1'5 N \tJJ ",d..J L\~ l., '<I '4 PACE, SHEILA DICKSON POBOX 2018 SOLDOTNA, AK 99669 KENAI NATL WILDLIFE REFUGE, REFUGE MGR POBOX 2139 SOLDOTNA, AK 99669-2139 VALDEZ VANGUARD, EDITOR POBOX 98 VALDEZ, AK 99686-0098 UNIV OF ALASKA FAIRBANKS, PETR DEVELLAB DR V A KAMATH 427 DUCKERING FAIRBANKS, AK 99701 FAIRBANKS DAILY NEWS-MINER, KATE RIPLEY POBOX 70710 FAIRBANKS, AK 99707 K&K RECYCL INC, POBOX 58055 FAIRBANKS, AK 99711 UNIV OF ALASKA FBX, PETR DEVEL LAB SHIRISH PATIL 437 DICKERING FAIRBANKS, AK 99775 DEPT OF ENVIRON CONSERV SPAR, CHRIS PACE 410 WILLOUGHBY AV STE 105 JUNEAU, AK 99801-1795 ') VALDEZ PIONEER, PO BOX 367 VALDEZ, AK 99686 EVERGREEN WELL SERVICE CO., JOHN TANIGAWA PO BOX 871845 WASILLA, AK 99687 COOK AND HAUGEBERG, JAMES DIERINGER, JR. 119 NORTH CUSHMAN, STE 300 FAIRBANKS, AK 99701 C BURGLlN POBOX 131 FAIRBANKS, AK 99707 ASRC, BILL THOMAS POBOX 129 BARROW, AK 99723 UNIVERSITY OF ALASKA FBKS, PETR DEVEL LAB DR AKANNI LAWAL POBOX 755880 FAIRBANKS, AK 99775-5880 ") AL YESKA PIPELINE SERVICE CO, VALDEZ CORP AFFAIRS SANDY MCCLINTOCK POBOX 300 MS/701 VALDEZ, AK 99686 NICK STEPOVICH 543 2ND AVE FAIRBANKS, AK 99701 RICK WAGNER POBOX 60868 FAIRBANKS, AK 99706 DEPT OF NATURAL RESOURCES, DIV OF LAND REG MGR NORTHERN REGION 3700 AIRPORT WAY FAIRBANKS, AK 99709-4699 RICHARD FINEBERG PO BOX416 ESTER, AK 99725 SENATOR LOREN LEMAN STATE CAPITOL RM 113 JUNEAU, AK 99801-1182 2 3 2004 . ~1r~1rŒ (ID~ ~~~~[{~ . AI4ASIiA. OIL AlO) 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 DIO 22.005 Re: The application of Forest Oil Corporation to Inject Fluids ITom Alternate Sources into Redoubt Unit Disposal Well RU D-l, Redoubt Unit, Redoubt Shoal Undefined Waste Disposal Pool, Cook Inlet Area, 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 April 5, 2007 an amendment to Disposal Injection Order 22 Administrative Approval No.4 ("DIO 22.004"). Specifically, Forest requests authorization to inject produced water ITom the West Foreland gas field into disposal well Redoubt Unit Well D-l ("RU D 1 "). As provided by DIO 22, Rule 6 - "Administrative Action", the Commission hereby approves Forest's request. Well RU Dl was authorized for Class II waste disposal by DIO 22 (August 9, 2001) but injection was limited to Class II fluids generated in conjunction with the Osprey platform operation. Administrative approvals since the issuance of DIO 22 expanded the types of fluids authorized for waste injection but had not authorized sources outside of Osprey Platform-generated Class II wastes. Administrative Approval DIO 22.004 expanded the fluid sources by authorizing the disposal injection of appropriate Class II oilfield wastes ITom West McArthur River Unit ("WMRU"), Kustatan Production Facility ("KPF"), and permitted exploration wells. Produced water ITom the West Foreland gas field is currently commingled with produced water ITom WMRU and transported to RU 6 (located on Osprey platform) as part of the pilot injection project authorized by Enhanced Recovery Order 2 ("ERO 2") and as administratively amended by ERO 2.002. Forest reports that injection pressure limitations at RU 6 prevent the entire commingled WMRU and West Foreland produced water stream ITom being injected for enhanced recovery, requiring . ADMINISTRA TIVE APPROVAL DlO 22.005 April 16, 2007 Page 2 of2 . excess water to be stored at KPF. Forest previously has indicated RU Dl can provide necessary optional disposal capacity in support of Forest's operations on the west side of Cook Inlet. The Commission agrees with Forest's assessment that injecting excess produced water into RU 6 will simplify the handling of Class II-eligible wastes ITom the Forest operated fields on the west side of Cook Inlet and will provide additional flexibility in operating these fields. Further, the inclusion of West Foreland produced water does not affect the Class II disposal status of RU D 1. RU D 1 has demonstrated mechanical integrity based on pressure surveillance and testing as required by DIO 22. All injected fluids have been confmed to the intended injection zone. Commingling alternate sources of wastes that are similar to the disposal waste stream already being injected into RU D 1 will have no impact on the mechanical integrity and will not promote waste, jeopardize correlative rights, or contribute to the potential for fluid movement outside of the injection zone. This administrative approval amends and replaces DIO 22.004, authorizing Forest to dispose of commingled Class II waste streams from the WMRU, KPF, West Foreland gas field, and permitted exploration wells into Redoubt Unit Well D-l. DONE at An 0 ge, Alaska and dated April 16, 2007. ~~ Cathy P Foers er Commissioner Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 John Levorsen 200 North 3rd Street, #1202 Boise,lD 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 . Jerry Hodgden Hodgden Oil Company 408 18th Street Golden, CO 80401-2433 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle, WA 98119-3960 Schlumberger Drilling and Measurements 2525 Gambell Street #400 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Darwin Waldsmíth 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 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 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 . ~,\ dio 22-005 Redoubt Unit D-l . . Subject: dio 22-005 Redoubt Unit D-l From: Jody Colombie <jody _ colombie@admin.state.ak.us> Date: Tue, 17 Apr 2007 09:07:26 -0800 To: undisclosed-recipients:; BCC: Cynthia B Mciver <bren_mciver@admin.state.ak.us>, Christine Hansen <c.hansen@iogcc.state.okus>, Terrie Hubble <hubbletl@bp.com>, Sondra Stewman <StewmaSD@BP.com>, stanekj <stanekj@unoca1.com>, trmjrl <trmjrl@ao1.com>,jdarlington <jdarlington@forestoi1.com>, nelson <knelson@petroleumnews.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>, "RandyL. 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 <Mike1.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>, doug_schultze <doug_schultze@xtoenergy.com>, Hank Alford <hank.alford@exxonmobi1.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>,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 <bl@mapalaska.com>, 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@exxonmobi1.com>, marty <marty@rkindustrial.com.>, ghammons <ghammons@ao1.com>, rmclean <rmclean@pobox.alaska.net>, mkm7200 <mkm7200@ao1.com>, Brian Gillespie <ifbmg@uaa.alaska.edu>, David L Boelens <dboelens@aurorapower.com>, Todd Durkee <fDURKEE@KMG.com>, Gary Schultz <gary_schultz@dnr.state.ak.us>, Wayne Rancier <RANCIER@petro-canada.ca>, Brandon Gagnon <bgagnon@brenalaw.com>, Paul Winslow <pmwinslow@forestoi1.com>, Sharmaine Copeland <copelasv@bp.com>, Kristin Dirks <kristin_dirks@dnr.state.ak.us>, Kaynell Zeman <kjzeman@marathonoi1.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>, James Scherr <james.scherr@mms.gov>, Tim Lawlor <fim_Lawlor@ak.blm.gov>, LynndaKahn <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 Jogers@revenue.state.ak.us>, Arthur Copoulos <Arthur _ Copoulos@dnr.state.ak.us>, Ken <klyons@otsint1.com>, Steve Lambert <salambert@unocal.com>, Joe Nicks <news@radiokenai.com>, Jerry McCutcheon <susitnahydronow@yahoo.com>, Bill Walker <bill-wwa@ak.net>, Paul Decker <paul_decker@dnr.state.ak.us>, Aleutians East Borough <admin@aleutianseast.org>, Marquerite kremer <marguerite_kremer@dnr.state.ak.us>, Mike Mason <mike@kbbi.org>, Garland Robinson <gbrobinson@marathonoi1.com>, Cammy Taylor <cammy _ taylor@dnr.state.ak.us>, Thomas E Maunder lof2 4/17/20079:15 AM dio 22-005 Redoubt Unit D-I <tom _ maunder@adminostateo!US>. Stephen F Davies <steve _ davieAinostateoakous>. Keith Wiles <kwiles@marathonoiI.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@c1earwire.net>, Laura Silliphant <laura _ silliphant@dnr.state.ak.us>, David Steingreaber <david.e.steingreaber@exxonmobiI.com>, akpratts@acsalaska.net, Robert Campbell <Robert.Campbell@reuters.com>, Steve Moothart <steve_moothart@dnr.state.ak.us>, Anna Raff <anna.raff@do\\jones.com>, Cliff Posey <cliff@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>, 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>, carol smyth <caroI.smyth@shell.com>, Arthur C Saltmarsh <art_saltmarsh@admin.state.ak.us>, Chris Gay <cdgay@marathonoiI.com>, foms@mtaonline.net, Rudy Brueggeman <rudy.brueggemann@international.gc.ca>, Cary Carrigan <cary@kfqd.com>, Sonja Frankllin <sftanklin6@bloomberg.net>, Mike Bill <MichaeI.Bill@bp.com>, Walter Quay <WQuay@chevron.com>, "Alan Birnbaum <\"\"Alan J Birnbaum \">" <alan _ birnbaum\"@law.state.ak.us>, Randall Kanady <Randall.B.Kanady@conocophillips.com>, MJ Loveland <N1878@conocophillips.com> Jody Colombie <iody colombie~admin.state.ak.us> Special Staff Assistant Alaska Oil and Gas Conservation Commission Department of Administration Content-Type: application/pdf dio22-005.pdf . Content-Encodmg: base64 20f2 4/17/20079:15 AM . . AOGCC Memorandum Date: April 12, 2007 To: DIO 22 '?-'114Itv1Dí From: Jim Regg, Petroleum Engineer Subject: Administrative Approval Request - Forest Oil Corporation Inject West Foreland Produced Water into Redoubt Dl Forest applied for administrative approval under DIO 22 to allow the inclusion of produced water from West Foreland into Redoubt Dl (Class II disposal well). At issue is the excess produced water from the West McArthur River Unit and West Foreland fields; volume in excess of what can be injected into Redoubt 6 as part of the pilot water flood [see Enhanced Recovery Injection Order 2]. Also at issue is the fact that ERO 2 includes West Foreland produced water; DIO 22 does not include West Foreland produced water as an authorized fluid. I called Paul Winslow (Reservoir Engineer) at Forest for clarification. Discussion summary: Q - What is the limitation? A - Not sure if it is frac pressure or pump limitation [injection pumps are at onshore Kustatan Production Facility and are injecting at rates and pressures approaching frac pressure]. Regardless, fluids pile up at Kustatan Production Facility due to restricted ability to inject; limited storage capacity at Kustatan. Only disposal option from Kustatan is Redoubt D 1 unless shut down production and reverse pipeline to transport back to WMRU 4D disposal well. Q - Performance of water flood to date? A - At fluid rates Forest has been able to pump, water injection into RU 6 has been effective in flattening out the oil production decline. Forest will be either be applying for an extension in September or converting to area injection order; currently evaluating options. Q - Why not send excess produced water from WMRU and West Foreland to start up the WMRU 2A pilot water flood? A - Have not been able to commence WMRU 2A pilot water flood project; well has mechanical integrity problems and may require mobilizing a rig to pull, rerun tubing. Currently investigating patch options. Also, West Foreland is midway between WMRU to Kustatan (tie-in point into line from WMRU to Kustatan); it is not possible to divert West Foreland water to WMRU without operating pipeline in a batch flow mode. Q - Any additional work planned for Redoubt, West Foreland, or WMRU? A - In addition to evaluation ofWMRU 2A well integrity (may require mobilizing rig that will have to wait for Cook Inlet to clear of ice), Forest may drill several sidetracks in Redoubt (Osprey Platform). That could eliminate need for make up water from other fields for Redoubt water flood. Thoughts on Forest's Redoubt Shoal request. . Hi Jim, Here are some quick thoughts on Forest's request to dispose of the excess produced water from WMRU and West Foreland at Redoubt. 1) Ideally they would inject this water in the WMRU2A pilot EOR well, but as you said the well currently has mechanical integrity issues and therefore can not be used for injection purposes so that is out of the question. 2) Since they are at their injection pressure limit for the Redoubt pilot EOR well it is not possible for them to inject more produced water into that well to try to improve the performance of the EOR pilot. 3) Since they can not put more water away into the Redoubt pilot EOR well injecting the water in their disposal well at Redoubt will not adversely affect the performance of the Pilot EOR project. Therefore, there is not a conservation of resources issue with this request as they are already doing as much for EOR as they are currently physically capable of. As an aside, the Redoubt pilot EOR project expires this September. They should come in during the next few months to brief us on how the project worked and whether or not they wish to extend or expand the pilot and/or make the pilot a permanent project. At that time they may consider increasing their EOR injection capabilities by either adding an additional injector or possibly stimulating the existing well in an attempt to improve injectivity. Dave Roby R.eservoi.r Ala,ska Oil and Gas COl1ser"\ration C()rnn1issJ.cn 90'"! m 793 ....1232 I of I 4/12/2007 I :47 PM • ~~Q~[~ Old aC~~~~{Q / s...M.µao~,~ Ai~C~-7i1L~ OIIJ ~ ~ 333 W. 7th AVENUE, SUITE 100 CO1~T5~RQATIOI~T C011II~IISSIOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 CANCELLATION DISPOSAL INJECTION ORDER NO. 16 DISPOSAL INJECTION ORDER N0.22 Mr. David Hall Alaska Operations Manager Pacific Energy Resources Ltd. 310 K Street, Suite 700 Anchorage, AK 99501 RE: Cancellation of Disposal Injection Orders Dear Mr. Hall: Pursuant to Pacific Energy Resources Ltd ("Pacific")'s request dated May 7, 2008 AOGCC hereby cancels Disposal Injection Order 16 (West McArthur River Unit We114) and Disposal Injection Order 22 (Redoubt Unit Well D1). Both orders authorize the injection of Class II waste fluids. On July 20, 2007 the Environmental Protection Agency approved Pacific's request to authorize both wells as Class Inon-hazardous waste injectors. The status of obligations under DIO 16 and DIO 22 have been reviewed. Finding no outstanding items, the Commission cancels Disposal Injection Orders 16 and 22. DONE at Anchorage, Alaska and dated May 16, 2008. The Alaska Oil and Gas Conservation Daniel . Seamount, Jr. Cathy~P. Foerster Commissioner • Colombie, Jody J (DOA) Page 1 of 1 • From: Colombie, Jody J (DOA) Sent: Monday, May 19, 2008 11:24 AM Subject: Cancellation DIO 16 (West McArthur River); Cancellation DIO 22 (Redoubt Unit); A102B-031 (Kuparuk) Attachments: dio22.pdf; aio2b-031.pdf BCC:'Aleutians East Borough'; 'Anna Raff ; Arion, Teri A (DNR); 'Arthur Copoulos'; 'Barbara F Fullmer'; 'bbritch'; 'Bill Walker'; 'Brad McKim'; 'Brandon Gagnon'; 'Brian Gillespie'; 'Brian Havelock'; 'Brit Lively'; 'Bruce Webb'; 'buonoje'; 'Cammy Taylor'; 'Cande.Brandow'; 'carol smyth'; 'Cary Carrigan'; caunderwood@marathonoil.com; 'Charles O'Donnell'; 'Chris Gay'; 'Christian Gou-Leonhardt'; 'Cliff Posey'; 'Dan Bross'; 'dapa'; 'Daryl J. Kleppin'; 'David Brown'; 'David Hall'; David House; 'David L Boelens'; 'David Steingreaber'; 'ddonkel'; 'Deanna Gamble'; 'Deborah J. Jones'; 'doug_schultze'; 'Eric Lidji '; 'Evan Harness'; 'eyancy'; 'foms2@mtaonline.net'; 'Francis S. Sommer'; 'Fred Steece'; 'Garland Robinson'; 'Gary Laughlin'; 'Gary Rogers'; 'Gary Schultz'; 'ghammons'; 'Gordon Pospisil'; Gould, Greg M (DEC); 'Gregg Nady'; 'gregory micallef; 'gspfoff; 'Hank Alford'; 'Harry Engel'; 'jah'; 'James Scherr'; 'Janet D. Platt'; 'jejones'; 'Jerry McCutcheon'; 'Jim Arlington'; 'Jim White'; 'Jim Winegarner'; 'Joe Nicks'; 'John Garing'; 'John S. Haworth'; 'John Spain'; 'John Tower'; 'John W Katz'; johnny.aiken@north- slope.org; 'Jon Goltz'; 'Julie Houle'; 'Kari Moriarty'; 'Kaynell Zeman'; 'Keith Wiles'; knelson@petroleumnews.com; 'Krissell Crandall'; 'Kristin Dirks'; 'Laura Silliphant'; 'Lois'; 'Lynnda Kahn'; 'mail=akpratts@acsalaska.net'; 'mail=fours@mtaonline.net'; 'Marilyn Crockett'; 'Mark Dalton'; 'Mark Hanley'; 'Mark Kovac'; 'Mark P. Worcester'; 'Marguerite kremer'; 'marty'r 'Matt Rader'; 'Meghan Powell'; 'Mike Bill'; 'Mike Mason'; 'Mikel Schultz'; 'Mindy Lewis'; 'MJ Loveland'; 'mjnelson'; 'mkm7200'; 'Nick W. Glover'; NSK Problem Well Supv; NSU, ADW Well Integrity Engineer; 'Patty Alfaro'; 'Paul Decker'; 'Paul Winslow'; Pierce, Sandra M (DNR); 'Randall Kanady'; 'Randy L. Skillern'; 'rcrotty'; Rice, Cody J (DNR); 'rmclean ; 'Rob McWhorter '; rob.g.dragnich@exxonmobil.com; 'Robert Campbell'; 'Robert Fowler'; 'Robert Province'; 'Roger Belman'; 'Rudy Brueggeman'; 'Scott Cranswick'; 'Shannon Donnelly'; 'Sharmaine Copeland'; 'Sondra Stewman'; 'Sonja Frankllin'; 'Stan Porhola'; 'stanekj'; 'Steve Lambert'; 'Steve Moothart'; 'Steven R. Rossberg'; 'tablerk'; 'Tamera Sheffield'; 'Temple Davidson'; 'Terrie Hubble'; 'Tim Lawlor'; 'Todd Durkee'; Tony Hopfinger; 'trmjrl'; 'Walter Featherly'; 'Walter Quay'; 'Wayne Rancier'; 'Dale Hoffman'; Fridiric Grenier; Joseph Longo; Maurizio Grandi; Tom Gennings; Birnbaum, Alan J (LAW); Crisp, John H (DOA); Davies, Stephen F (DOA); Fleckenstein, Robert J (DOA); Foerster, Catherine P (DOA); Grimaldi, Louis R (DOA); Johnson, Elaine M (DOA); Jones, Jeffery B (DOA); Laasch, Linda K (DOA); Mahnken, Christine R (DOA); Maunder, Thomas E (DOA); McIver, C (DOA); McMains, Stephen E (DOA); Noble, Robert C (DOA); Norman, John K (DOA); Okland, Howard D (DOA); Paladijczuk, Tracie L (DOA); Pasqual, Maria (DOA); Regg, James B (DOA); Roby, David S (DOA); Saltmarsh, Arthur C (DOA); Scheve, Charles M (DOA); Seamount, Dan T (DOA); Smith, Chasity R (DOA); Williamson, Mary J (DOA) Attachments: dio22.pdf;aio2b-031.pdf; Cancellation of DIO 16 and DIO 22 are on same Administrative Order. 5/19/2008 • • 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 Jiil 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 ~ ~ ` ~~~~ ~ 26 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. 111 West Ocean Blvd. Suite 1240 ~ ~O Long Beach, California 90802 Telephone: (562) 628-1526; Fax: (562) 628-1536 Files for Chapter 11 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 five 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 Bankruptty 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. Paci is Ener~Y Resources Ltd. 310 K. Street, Suite 700 A.nchora~e, .AK 99507 Office: 907-258-8600 Fax: 907-Z58-8601 I~av~d Hall Alask~r Operations ~blancrger' Main: 907-868-2133 Cell: 907-317-8239 d mh a] l.`a-pace nerav. com www_pacener_w.com -~25 • C] PACIFIC ENERGY RESOURCES, LTD. 310 KStreet, Suite 700 Anchorage, AK 99501 Phone: (907) 258-8600 • Fax: (907) 258-8601 May 7, 2008 ~ -' ~, ~-- -~- Mr. Dan Seamount, Chair Alaska Oil and Gas Conservation Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 ,~~t~~ Re: Disposal Iniection Orders No. 16 and 22 Dear Commissioner Seamount: Pacific Energy operates a disposal well at both its West McArthur River Unit (WMRU 4D) and its Osprey Platform (RU D1). It has come to my attention that Disposal Injection Order Nos. 16 and 22 covering WMRU 4D and RUD1 are still in effect, despite the conversion of these wells to Class Inon-hazardous wells July 20, 2007 under EPA permit 2005DB0001. Mr. Jim Regg indicated that disposal orders remain in effect until it is requested that they be rescinded. Pacific Energy desires to rescind these injection orders, and I would respectfully request that the Commission do so. If the Commission requires any further information, please contact me at 868-2137. Sincerely, ;' ~:~' David Hall Alaska Operations Manager Pack Energy Resources Ltd. Pacific Energy Resources Ltd., 111 West Ocean Blvd. ,Suite 1240, Long Beach, CA 90802 Ph: 562-628-1526 Fax:562-628-1536 ::tf24 . . AOGCC Memorandum Date: July 24, 2007 To: DIO 22 From: Jim Regg, Petroleum Engineer fZ.Cf1 7/m/oJ Subject: Annual Disposal Inj ection Performance Report Forest Oil Corporation ("Forest") submitted the 2006 Redoubt Unit ("RU") Annual Disposal Injection Performance Report on July 19, 2007 as required by Disposal Injection Order ("DIO") 22, Rule 4 and 20 AAC 25.432. The report covers disposal operations from Jun 1,2006 through May 31, 2007 in RU Well D 1. Supplemental information - namely the estimate of facture growth and a volumetric analysis of the cumulative disposal storage volume - was provided on July 24,2007 at the Commission's request. I have completed a review of the disposal injection performance report and find it to be complete. The cumulative volume of Class II fluids injected as of May 31,2007 is approaching 1.42 million barrels, consisting mostly of produced water. Injection during the report period was intermittent and infrequent ( 5 days total) primarily due to start up of the pilot water flood injection in RU Well 6 (Enhanced Recovery Injection Order 2). Based on the performance data provided, I concur with the findings of Forest that there is no indication of any reservoir or mechanical concerns with the ongoing disposal injection operations in RU Well D 1. I have attached a volumetric analysis of the stored disposal volume that agrees well with the findings provided by Forest Forest has completed work to convert RU Well D1 to UIC Class I and is awaiting final approval from EP A. Monitoring of disposal operations should continue as directed in DIO 22 despite the pending conversion to Class I since Class II fluids will make up a significant (majority) ofthe injected fluids in RU Well D1. Attachment . . x~q 7(~31D? Radius of Influence Calculation Redoubt Unit D1 Disposal July 23, 2007 Notes 1 RU D1 (PTD 201-085) is located within the Redoubt Unit, drilled from Osprey Platform 2 Well was approved for Class II-D injection in support of drilling/production at RU, WMRU, and W Foreland 3 Injection is governed by DlO 22 4 Aquifers exempted below 3650 ft MDITVD 5 Approved injection zone between 7650 and 8450 ft MDITVD 6 Confinement provided by siltstones and other lithogies, discrete layers comprising 50% of overlying 1700 ft 7 Range of porosity values based on log analysis 20-30 percent 8 1,416,848 bbls cumulative injected as of May 31, 2007 9 Perfs 8216 - 8450 ft MDITVD (per Well Completion Rpt dated 8/22/2001); packer at 7620 ft MDITVD 10 Fill depth tag 5/10/07 indicated top of fill @ 8062 ft MDITVD (2007 annual rpt) 11 Receiving interval? (radial type disposal domain around RU D1 likely with batch/intermittent injection) Radius of Influence Calculation V=(h*p)[(PI)*R]^2 V is volume of fluid pumped (barrels) p is porosity of receiving zone (expressed as decimal) h is thickness of receiving zone (feet) PI is 3.1416 5.615 cubic feetlbarrel (cf/bbl) R is radius (ft) thickess (h) of receiving zone R=SQRT[V*5.615/«PI)*h*p )] Possible V (bbl) h (ft) R (ft) Receiving Zone p 0.20 650 8230-8360 ft 1,416,848 0.25 30 581 0.30 530 8230-8260 ft; 0.20 441 1,416,848 0.25 65 395 8280-8315 ft 0.30 360 0.20 386 8230-8315 ft 1,416,848 0.25 85 345 0.30 315 0.20 233 8216-8450 ft 1,416,848 0.25 234 208 0.30 190 #23 . . ~g, James B CDOA) From: Sent: To: Subject: Paul Winslow [PMWinslow@forestoil.com] Tuesday, July 24, 2007 1 :54 PM Regg, James B (DOA) RU 01 Injection Analysis Attachments: RU 01 2007 Injection Analysis.ppt CJ. 1\1A\ol \ ~M(~ RU D1 2007 Injection Analysis.... Jim, Here is the injection/fracture analysis that you requested supporting Forest's RU D1 2007 Annual Injection Report. If you require any further information, please give me a call. Regards, Paul Paul Winslow Sr. Reservoir Engineer Forest Oil Corporation 310 K Street, Suite 700 Anchorage, AK 99501 Work: (907) 868-2131 Cell: (907) 317-8193 Fax: (907) 258-8601 pmwinslow@forestoil.com Redoubt Unit D1 . Injection Volume Analysis Data supplementing the AOGCC 2007 Annual Injection Report . (July 24th, 2007) IIð 1 1 - Cumulative 1 11IIII 11IIII III III III III III III III III III :11I III Month ID .,., m 11::: ,III III III # ....... I 111I III III III III III III III · Cumulative "2007" (6/1/06 - 5/31/07) Injection Volume = 47.7 Mbbls . · Cumulative Injection Volume (as of 5/31/07) = 1.42 MMbbls · RU 01 Perforations: 8,216' - 8,450' MO (straight hole) · Permeable sand thickness = -195 ft · Average porosity = -21 % · Irreducible water saturation = -30% . · Cumulative Injection Radius = ~300 ft · Assuming homogeneous, radial injection volume · Cumulative Injection Volume (as of 5/31/07) = 1.42 MMbbls · Maximum Injection Pressure = 4,735 psi · Maximum "2007" Injection Pressure = 4,274 psi . · 2007 Temperature Survey did not show any fluid movement above the perforated zones · Minimum Fracture Gradient = 1.01 psi/ft · Using a maximum injection pressure of 4,735 psi · Using a water gradient of 0.436 psi/ft . (Redoubt Hemlock average water density = 1.006) · Assumes that no fracture has been generated as a result of the injection history :#-22 . ~ . . Forest Oil Corporation 310 K Street, Suite 700 Anchorage, Alaska 99501 (907) 258-8600 Fax: (907) 258-8601 RECEIVED JUL 2 3 7007 July 19, 2007 Alaska Oil & Gas Com:;. COOìmissÎon Anchoragf:1 James Regg Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Redoubt Unit #D1 - 2007 Annual Injection Report Dear Mr. Regg, Rule #4 of Disposal Injection Order #22 requires an annual surveillance report be submitted by Forest Oil Corporation (Forest) for the Redoubt Unit #D1 (RU #D1) Class II disposal well. This report covers the period from June 1,2006 through May 31,2007. . During this period, RU #D1 has been used for periodic disposal of Class II fluids generated from the operations at Redoubt Unit, West McArthur River Unit, and from the West Foreland gas wells. Inclusion of produced water from Forest's two West Foreland gas wells into the Class II disposal stream was granted by the Alaska Oil and Gas Conservation Commission (AOGCC) on April 16th, 2007 (DIO 22.005). Most of the Class II fluids generated at Redoubt Unit (supplemented with fluids from WMRU and WF) have been injected back into the Hemlock formation, since the initiation of a Redoubt Unit Hemlock pilot waterflood which began in March 2005. Consequently RU #D1 has been used sporadically for disposal of Class II fluids. During the course of this 2007 reporting period (June 1,2006 through May 31,2007), Forest applied for a reclassification of the RU #D1 well, from a Class II to a Class I disposal well. It is anticipated that the Environmental Protection Agency (EPA) will grant the Class I status within the next couple of months. In meeting the EPA requirements for Class I status, Forest conducted a mechanical integrity test (MIT) and a temperature survey on the RU D1 well bore. Both tests passed to the satisfaction of the EPA. . MIT criteria as per AOGCC requirements, requires that the casing be tested at a surface pressure of 1,500 psig or at a pressure equal to 0.25 psi/ft multiplied by the true vertical depth (TVD) of the casing shoe/packer, whichever is greater, but not exceeding 70% of the minimum yield strength of the casing. Note that the packer in RU #D1 is set at 7,600', so 0.25 psi/ft multiplied by the packer depth is equal to 1,900 psi. A satisfactory test is defined as one in which the surface pressure stabilizes and does not decline more than 10% within 30 minutes. . . . . ..:te ~ Æ-oGcc. M:Pï HïK <¡:; ÏUw '> 2ps~ (07~ oÇ f~3~LA,~ C).¿V'IJ 'æ> }Ill/\. .M.:P1 ay\ 61'O~J'Z.tb7 0 1I(~1 During the MIT (conducted on May 10, 2007) the tubing-casing annulus was pressured up 7/z3/D7 to 2,053 psia and then shut in. Over the next 40 minutes the casing pressure bled off only~ psi, to 2,047 psia. This 6 psi pressure drop amounts to 0.3% of the test pressure and is well below the AOGCC requirement of 10% within 30 minutes. / A temperature survey of well RU #01 was also conducted on May 9,2007. The survey was conducted from the surface down to a tagged fill depth of 8,062' MD. Note that the survey / did not extend all the way down to the perforations, which are at 8,216' - 8,450' MD. Nevertheless, the survey does show that no injected fluids are migrating up the casing annulus, nor are the injected fluids entering the Tyonek formation above the perforated intervals. If either of these scenarios were occurring, the temperature profile would show a distinct reduction of temperature above the packer (set at 7,600'), and/or below the packer but above the perforations, neither of which occurred. L.'":;:> 7bZOl (ílcC¿)rt~.tv 10407 Throughout the course of this 2007 reporting period, RU #01 has been operating within what we consider normal parameters and has shown no sign of integrity problems. c/ If there are any questions, please contact me at 907-868-2131. Sincerely, (]~rl Q~ Paul M. Winslow Reservoir Engineer RU #01 - Annual Report 2007.doc RedoubtL njection History 7000 - - - - - - RU D1 Water 6000 RU D1 Wellhead Pressure ~ - - - ... - Ii) c.. - () ... ~ 5000 - Ii) () ... 0.. !:: 0 +:; 4000 u () ï: ~ oð - "&. 3000 .Q - !:: 0 +:; u .!. 2000 - !:: \ 1000 - ..... .... 0 .. .. "<t "<t "<t "<t "<t "<t I.{) I.{) I.{) I.{) I.{) I.{) (!) (!) (!) (!) (!) (!) t- t- t- o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 -. -. -. -. -. -. -. -. -. -. -. -. -. -. -. -. -. -. -. -. -. ..... ..... ..... ..... ..... ..... ..... ..... ..... ..... ..... ..... ..... ..... ..... ..... ..... ..... ..... ..... ..... -. -. -. -. -. -. -. -. -. -. -. -. -. -. -. -. -. -. -. -. -. ..... ('I) I.{) t- O") ..... ..... ('I) I.{) t- O") ..... ..... ('I) I.{) t- O") ..... ..... ('I) I.{) ..... ..... ..... Date . . . Forest Oil Corporation Osprey Platform Yearly Injection Report - Production Water June 1,2006 to May 31,2007 Disposal Well RU 0#1 Injected Injected Produced WMRU Rain Effluent Circulated Well bores Gray Produced from Total Water DWMA Water Water RU#2,RU#5A,RU#6 Water RU#3 Injected 6/30/2006 3,509 3,509 7/31/2006 4,948 4,948 8/31/2006 - - 9/30/2006 - - 10/31/2006 - - 11/30/2006 - - 12/31/2006 - - 1/31/2007 - - 2/28/2007 - - 3/31/2007 - - 4/30/2007 13,307 13,307 5/31/2007 25,113 25,113 Total 46,877 - - - - - - 46,877 . . D#1 June 2006 Rate and Pressure 4.00 4,000 3.50 3,500 3.00 3,000 2.50 2,500 :E en !l. Rate, BPM !l. m 2,000 ---+-Wellhead Psi - 2.00 ~ .... m 11::: 1.50 1,500 1.00 1,000 500 0.50 0.00 6/1 /2006 o 7/1/2006 6/21/2006 6/26/2006 6/6/2006 6/11/2006 6/16/2006 Time ::æ: Il. m ~ 2.50 - ID .... m 11::: RU July 2006 Rate and Pressure 5.00 4.50 4.00 3.50 3.00 2.00 1.50 1.00 0.50 0.00 7/1/2006 o 7/31/2006 7/21 /2006 7/26/2006 7/6/2006 7/11/2006 7/16/2006 Time 4,000 3,500 3,000 2,500 VJ Il. ,¡ 2,000 5 IJ) IJ) <!.) .... Il. 1,500 1,000 500 ::¡: a. !:!J ~ 2.50 (I - ('IS 11::: RU D#1 August 2006 Rate Pressure 5.00 4.50 4.00 3.50 3.00 2.00 1.50 1.00 0.50 0.00 8/1 /2006 o 8/31/2006 8/16/2006 8/21/2006 8/26/2006 8/6/2006 8/11/2006 Time 3,500 3,000 2,500 2,000 æ ø .... ;::$ IJ' IJ' (I 1,500 è: 1,000 500 ~ Il. a:1 ~ 2.50 ID ..... "' 11::: D#1 September 2006 and Pressure 5.00 4.50 4.00 3.50 3.00 2.00 1.50 1.00 0.50 0.00 9/1/06 9/6/06 9/11/06 9/16/06 9/21/06 9/26/06 Time 1,800 1,600 1 ,400 1,200 æ 1,000 Il. W ... :::s Ii 800 ~ l- ll. 600 400 200 o 10/1/06 ~ !l. m ~ 2.50 w ...- lIS 11::: RU October 2006 Rate and 5.00 4.50 4.00 3.50 3.00 2.00 1.50 1.00 0.50 0.00 10/1/2006 ° 10/31/2006 10/6/2006 10/11/2006 10/16/2006 1 0/21/2006 10/26/2006 Time 1 ,400 1,200 1,000 800 ëñ !l. ci" .... .......- Wellhead :;j IJ IJ -.~ Annulus 600 ~ !l. 400 200 RU November 2006 Rate and Pressure 0.9 0.8 0.7 0.6 :¡¡: Il. ID 0.5 W - !"II 11::: 0.4 0.3 0.2 0.1 ° 11/1/2006 11/11/2006 11/16/2006 11/21/2006 11/26/2006 o 12/1/2006 11/6/2006 Time 5,000 4,500 4,000 3,500 3,000 _ en Il. Q 2,500 5 III III Q ... 2,000 Il. 1,500 1,000 500 Rate, BPM """'-Wellhead Psi Annulus Psi 2006 Pressure 0.9 0.8 0.7 0.6 :::¡¡: a- m 0.5 QÎ .... ('( 11::: 0.4 0.3 0.2 0.1 0 12/1/2006 12/21/2006 12/26/2006 o 12/31 /2006 12/11/2006 12/16/2006 12/6/2006 Time Rate, BPM 4.5 4 3.5 3 :::E 2.5 a. 00 2 RU 2007 Rate and Pressure 1.5 0.5 o 1/1/2007 o 1/31/2007 1/16/2007 1/21/2007 1/26/2007 1/6/2007 1/11/2007 Time 900 800 700 600 00 500 a. 400 300 200 100 Rate, RU February Rate and Pressure 3,000 0.9 2,500 0.8 0.7 2,000 0.6 :¡¡: VJ Il. Il. ø m 0.5 ... ø :::::¡ ...., !II CIS !II 11::: ID ... 0.4 Il. 1,000 0.3 0.2 500 0.1 0 0 2/1/2007 2/6/2007 2/11/2007 2/16/2007 2/21/2007 2/26/2007 Time RU D#1 and Pressure 4.5 800 4 700 3.5 600 3 500 ~ 2.5 en Il. ID 400 Wellhead Psi oi ..... iii 2 11::: 300 1.5 200 0.5 o 3/1/2007 o 3/31/2007 3/16/2007 3/21/2007 3/26/2007 3/6/2007 3/11/2007 Time 100 - 1.2 :::æ: Il.. m ri .... m 0.8 11::: 0.6 0.4 0.2 0 4/1/2007 RU D#1 Rate Pressure 1.8 1.6 1.4 en Il.. 4/6/2007 4/11/2007 4/16/2007 4/21/2007 4/26/2007 Time Rate, BPM Wellhead Psi :!2 0.80 Q. In 1J) .... m 11::: 0.60 RU D#1 May 2007 and Pressure 1.40 1.20 1.00 en Q. 1J) .... :::! III III 2,000 ~ Q. 0.40 0.20 0.00 5/1/2007 5/6/2007 5/11/2007 5/16/2007 5/21/2007 5/26/2007 Time · . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;BobJleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERA TOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Forest Oil Reboubt Unit 05/10/07 Mike Murray Witness Waived by Jim Regg Packer Depth Pretest Initial 15 Min. 30 Min. WeIlIRUD-1 I Type Inj. I N TVD I 7620' Tubing 3,630 3,627 3,627 3.627 Interval I 0 P.T.D.1201-085 I Type test I P Test psil 2,049 Casing 11 2,049 2,047 2,047 P/FI P OA 0 0 0 0 Notes: Witnessed by T. Cutler and Talib Syed with the EPA. Weill I Type Inj. I TVD I Tubing Interval! P.TD. I Type test I I Test psil Casing P/FI Notes: OA Weill I Type Inj.1 I TVD I Tubing Interval P.TD.I I Type test I I Test psil Casing P/FI Notes: OA Weill I Type Inj.1 I TVD I Tubing Interval! P.T.D.I I Type test I I Testpsil Casing P/FI Notes: OA Weill I Type Inj.1 TVD I Tubing Interval! P.TD.I I Type test I Test psil Casing P/FI Notes: OA · TYPE INJ Codes o = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water · MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Mon~oring P = Standard Pressure Test R = Intemal Radioactive Tracer Survey A = Temperature Anomaly Survey 0= Differential Temperature Test INTERVAL Codes I = In~ial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT RU 0-1 05-10-07.xls 4000 3500 3000 2500 ..- .!2'I II) c.. - () 2000 ... ~ II) II) () ... Il. 1500 Redoubt Unit D-1 Mechanical Integrity (5/10107) 1000 500 o ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ ~ ~ ~ :b ~ Q¡ Q, b ~ " ~ ~ 9> ¡¡,. á) fò " Þ< (\ ~ ~ <0 fò ~_" ~~;:... 50 :b <0 2> ~ Ý) ç5~ ~~ 0;ry ~V;; r:;5ry ::e-<? <¿fþ co';5 çS';; cs~ 0;~ ç)~ çS'If- CS'Y ~:J ~l[; ,,? ':}';; ro? c:¿~ ,,~ ~~ ro":' Fò:J "Y r:s:J fÔr::> ç¡? "r::> t$.';5 ro~ Oj~ ror::> rofþ ro'? rofþ ro~ ro~ ro~ ro~ ro<? roV;; ro<? roV? ,,':3 ,,? ,,';5 ,,';J ,,~ ,,~ ,,~ ,,":' "ry "Y "ry/ ,,'ÿ "fþ "fþ "r::> ,,'? ,,~ ,,~ ,,~ ,,'If- Time Well: Field: 8000 120 7000 110 100 6000 90 - 5000 IJ.. - en .! (!) ø 80 C Q. - - (!) ~ 4000 !I.. :::I :::I - ø CU 70 !I.. ø (!) (!) Q. !I.. Il. E 3000 (!) I- 60 2000 50 1000 40 o 15 16 17 18 19 20 21 30 22 Time (hrs) I-Pressure -Temperature I Report date: 7/18/07 II) 3500 ~ 0::: 'Z" 4000 () ~ - J: 4500 .... C. () Q 5000 4000 4500 Pressure (psia) 5000 5500 6000 6500 7000 7500 2500 3000 -------.------------- 5500 50 60 70 80 90 100 110 120 Temperature (Deg. F) 3500 4000 0 500 1000 1500 2000 2500 3000 m 3500 ~ a=: Z' 4000 (,) ~ - J: 4500 ... c.. (,) C 5000 5500 6000 6500 7000 4500 Pressure (psia) 5000 5500 6000 6500 7000 7500 8000 8500 30 40 50 60 70 80 90 100 110 120 Temperature (Deg. F) Report date: 1/18/01 #21 @) . . Forest Oil Corporation 310 K Street, Suite 700 Anchorage, Alaska 99501 (907) 258-8600 Fax: (907) 258-8601 ~I2CI2II1. APR O.j-, ~10'/2D 4JiJSk;¡h .. 20D? t.l1I~G 8, C. A Dill C... "'f1lc.1. . . On-: 'tOr", ""'''81;QII April 5, 2007 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 Re: Request to Include West Foreland Produced Water in Disposal Injection Order DIO 022 Dear Commissioner Norman: , On November 8, 2005 Forest Oil Corporation (Forest) received Administrative Approval DIO 022.004 ftom the Alaska Oil and Gas Conservation Commission (AOGCC) authorizing disposal of commingled waste streams ftom West McArthur River Unit (WMRU), Kustatan Production Facility (KPF), and permitted exploration wells, into the Redoubt Unit D-l well. Forest is requesting that the produced water ftom the West Foreland (WF) gas field be added to the disposal injection order (DIO) No. 022. Currently the small amount of water that is being produced rrom the West Foreland gas field (--25 bwpd) is commingled with the produced water ftom WMRU (~2,000 bwpd) and is being injected into the Hemlock formation at Redoubt Unit (RU), via the RU #6 wellbore. Due to injection pressure limitations, Forest is not quite able to inject all of the produced water ftom RU, WMRU, and WF, into RU #6. The excess WMRU/WF water that has been shipped to KPF is stored in tanks (at KPF) until it can be injected down RU #6 in subsequent days. In order to feed this tanked water into the injection stream going into RU #6, the volume of water shipped ftom WMRU is decreased and the excess WMRU water is disposed of down the WMRU #4D Class II disposal well. Amending DIO 022 to include WF produced water will allow the entire produced water stream ftom WMRU and WF to be shipped to Kustatan Production Facility for injection into RU #6, with the excess being disposed of into RU D-l. This will greatly simplify operations at both WMRU and KPF, and allow for more flexibility in operating both fields. As always, Forest appreciates your consideration of this matter. If you have any questions or need any further information, please feel ftee to contact myself (868-2131) or Bob Elder (868- 2139) at your earliest convenience. , Sincerely, DJrJ.ù~ Paul M. Winslow Sr. Reservoir Engineer cc: Jim Regg AOGCC Request fOT WF Fluids 4-4-07.doc . . :\\::- ~ 0 . . FOREST OIL ,CORPOR¡!\T o N '. _y/' c,,· .J/OQ./1 C'J/7rOC/- D 70(} ,9,950/ (907) 2.sá'-S600 () (.907) 2:5'8-860/ (cÞcu) February 1,2007 Mr. John Norman Commissioner Alaska Oil and Gas Conservation Commission 333 W, ih Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Notification of Conversion of Class II Disposal Wells to Class I Wells Dear Commissioner Norman: Forest Oil Corporation (Forest Oil) operates the West McArthur River Unit Production Facility (WMRU) on the West Foreland of Cook Inlet. A Class II disposal well, WMRU 4D, is permitted by the Alaska Oil and Gas Conservation Commission (AOGCC) by Disposal Injection Order No. 16 issued on September 3, 1998 and has been in operation at WMRU since. Forest Oil desires to expand the number of available on-site waste disposal options at WMRU. Accordingly, Forest Oil is working with EP A Region X to convert WMRU 4D to a Class I non-hazardous waste disposal well. An application was submitted to EPA on August 25,2006. A Class I pennit (AK-1I007-A) was issued on October 12, 2006 but has not yet been activated. AOGCC was included in the distribution of that transmittal. A representative ofEP A is presently on-site at WMRU witnessing the well tests (step-rate, mechanical integrity, temperature, and caliper) required by the Class I permit. Once the tests have been satisfactorily completed and the financial assurance certificate issued the well will be activated as a Class I non-hazardous waste disposal well. Concurrently, Forest Oil has also proceeded with permitting the conversion of Redoubt Unit #Dl from a Class II disposal well to a Class I non-hazardous waste disposal well. That conversion was permitted by the same permit issued by EP A for WMRU 4D. Redoubt Unit #D 1 is expected to be activated as a Class I well in the spring of 2007 after the required well tests have been completed. Forest Oil is not requesting any action on the part of AOGCC for these conversions. The conversions are part of Forest Oil's ongoing effort to improve waste management plans under the UIC program. Please feel free to contact me at 868-2139 or rgelder@forestoil.com with any questions or concerns. Sincerely, ¡P~&Ø¡ Bob Elder HSE Manager -U=lQ @ . . Forest Oil Corporation 310 K Street, Suite 700 Anchorage, Alaska 99501 (907) 258-8600 Fax: (907) 258-8601 0 R , G , N A l June 30, 2006 Attn: Mr. Tom Maunder Re: Redoubt Unit #01 - Annual Injection Report 2005 - 2006 RECE\VED jUN 3 0 2006 r A.....ftssion n'! o. Gas COf\$.\,r\n,..·.. Naska u\t CL . Anchorage Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501 Dear Mr. Maunder, This report is in response to the requirements for annual surveillance reporting on the Redoubt Unit #01 (RU #01) Class 1/ disposal well. Rule #4 of the Disposal Injection Order #22 requires this surveillance. This report covers the period from June 1, 2005 through May 31,2006. During this period, RU #01 has been used for periodic disposal of Class II fluids generated from the operations at Redoubt Unit. With the initiation of a pilot waterflood, which began in March 2005, the quantity of Class 1/ fluid disposed of in the RU #01 well has been reduce significantly. Most of the produced water from Redoubt Unit is now being injected back into the Hemlock reservoir via the RU #6 wellbore. Over the course of this reporting period, RU #01 has been operating within what we consider normal parameters and has shown no sign of integrity problems. A slick line tag performed on April 11 , 2006 encountered fill at 8,035' KB. If there are any questions, please contact me at 907-868-2131 . Sincerely, \?Jrt U~ Paul M. Winslow Reservoir Engineer Forest Oil Corporation >'_. ~ 0 "'" "'" "'" "'" "'" "'" "'" "'" "'" "'" "'" "'" I[) I[) I[) I[) I[) I[) I[) I[) I[) I[) I[) I[) ID ID ID ID ID ID 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 -.. -.. -.. -.. -.. -.. -.. -.. -.. -.. -.. -.. -.. -.. -.. -.. -.. -- -.. -.. -.. -.. -.. -.. -.. -.. -.. -.. -.. -.. .... .... .... .... .... .... .... .... ...... ...... .... .... .... .... .... ...... ...... ...... .... ...... ...... ...... .... .... .... .... ...... ...... ...... .... -.. -.. -.. -.. -.. -.. -.. -- -.. -.. -- -.. -- -.. -.. -- -.. -- -.. -.. -.. -.. -- -.. -.. -.. -.. -.. -.. -.. ..- N M "'" I[) ID f'-. CO Q) 0 .... N .... N M "'" I[) <0 f'-. CO Q) 0 ...... N .... N M "'" I[) <0 .... .... .... ...... .... .... Date 7000 _ 6000 .!! III Q. - CI> ... ; 5000 III ~ Q. c o ~ 4000 CI> ,- C oð ~ 3000 s: a:¡ - c o ~ 2000 ,- c ~ «S C 1 000 Water njection Redoubt #D1 njection History Forest Oil Corporation Osprey Platform Yearly Injection Report - Production Water June 1,2005 to May 31,2006 Disposal Well RU D#1 Injected Injected Produced WMRU Rain Effluent Circulated Wellbores Gray Produced from Total Water DWMA Water Water RU#2,RU#5A,RU#6 Water RU#3 Injected 6/30/2005 - - 7/31/2005 - - 8/31/2005 - - 9/30/2005 53 53 1 0/31 /2005 - - 11/30/2005 60,522 60,522 12/31/2005 19,841 19,841 1/31/2006 6,508 6,508 2/28/2006 4,920 4,920 3/31/2006 1,726 1,726 4/30/2006 1,771 1,771 5/31/2006 3,223 3,223 Total 78,723 - - - 19,841 - - 98,564 . . . :5 Q. a:¡ - 0.50 CI> .... «S e::: RU D#1 June 2005 Rate and Pressure 1.00 0.90 0.80 0.70 0.60 0.40 0.30 0.20 0.10 0.00 5/28/2005 6/27/2005 o 7/2/2005 6/2/2005 6/7/2005 6/12/2005 6/17/2005 6/22/2005 Time æ Q. oS 1 :; fj fj CI> ... o Q. o o o -+-Wellhead ~ Annulus Pressure :5 Q. a:¡ - 0.5 CI> .... «S e::: RU D#1 July 2005 Rate and Pressure 0.9 0.8 0.7 0.6 0.4 0.3 0.2 0.1 o 6/27/2005 7/2/2005 7/7/2005 7/12/2005 7/17/2005 7/22/2005 7/27/2005 8/1/2005 o 8/6/2005 Time æ Q. oS ... :::s fj fj CI> ... o Q. o o o I Rate, BPM -+-Wellhead Pressure ~ Annulus Pressure :5 2.5 Q. a:¡ CI> - f}, 2 RU D#1 August 2005 Rate and Pressure 4.5 4 3.5 3 1.5 0.5 o 7/27/2005 8/1/2005 o 8/6/2005 8/11/2005 8/16/2005 8/21/2005 8/26/2005 8/31/2005 9/5/2005 Time æ Q. oS ... :::s fj fj CI> ... o Q. o o o Rate, BP~ -+-Wellhead Pressure I I ~ Annulus Pressure I :5 Q. a:¡ - 0.5 CI> .... «S e::: RU D#1 September 2005 Rate and Pressure 0.9 0.8 0.7 0.6 0.4 0.3 0.2 0.1 o 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 3,000 2,500 2,000 æ Q. oS 1,500 :; fj fj CI> ... Q. 1,000 500 , .---' i Rate, BPM I I I-+- Wellhead Pressure I I ~ Annulus Pressure :5 2.5 Q. a:¡ oS ... f}, 2 RU D#1 October 2005 Rate and Pressure 4.5 4 3.5 3 1.5 0.5 o 9/25/2005 9/30/2005 -0 10/5/2005 10/10/2005 10/15/2005 10/20/2005 10/25/2005 10/30/2005 11/4/2005 Time W Q. oS ... :::s fj fj ~ o Q. -+-Wellhead Pressure Annulus Pressure o o o RU D#1 November 2005 Rate and Pressure 3 6,000 3.5 5,000 2.5 4,000 :5 2 æ Q. Rate, BPM Q. oS a:¡ 3,000 ... -+-Wellhead Psi oS :::s .... fj «S fj ~ Annulus Psi e::: 1.5 CI> ... Q. 2,000 0.5 1,000 o 10/30/2005 11/4/2005 11/9/2005 11/14/2005 11/19/2005 11/24/2005 11/29/2005 o 12/4/2005 Time 4.5 4 3.5 3 :5 2.5 Q. a:¡ oS ... «S 2 e::: 1.5 RU D#1 December 2005 Rate and Pressure 0.5 o 11/29/2005 12/9/2005 12/14/2005 12/19/2005 12/24/2005 12/29/2005 12/4/2005 Time 5,000 4,500 4,000 3,500 3,000 _ W Q. oS 2,500 :; fj fj CI> ... 2,000 Q. 1,500 1,000 500 o 1 /3/2006 I Rate, BPM I-+-Wellhead Psi I Annulus Psi :5 Q. a:¡ - 2.50 CI> - «S e::: RU D#1 January 2006 Rate and Pressure 5.00 4.50 4.00 3.50 3.00 2.00 1.50 1.00 0.50 0.00 12/29/2005 1 /8/2006 1/13/2006 1/18/2006 1/23/2006 1/28/2006 1 /3/2006 Time 3,500 3,000 2,500 2,000 æ oS ... :::s fj fj 1,500 £ 1,000 500 , 0 2/2/2006 I Rate, BPM I -+-Wellhead Psi I I Annulus Psi I RU D#1 February 2006 Rate and Pressure 5.00 4.50 4.00 3.50 3.00 :5 Q. 00 ~ 2.50 CI> .... «S e::: 2.00 1.50 1.00 0.50 0.00 1/28/06 2/2/06 2/22/06 2/27/06 2/12/06 2/17/06 2/7/06 Time 4,000 3,500 3,000 2,500 æ Q. oS 2,000 :; fj fj ~ Q. 1,500 1,000 500 o 3/4/06 --~ I Rate, BPM I I--+- Wellhead Psi ~ Annulus Psi I :5 Q. a:¡ - 2.50 CI> ... «S e::: RU D#1 March 2006 Rate and Pressure 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 3/14/2006 3/19/2006 3/24/2006 3/29/2006 Time 4,000 3,500 3,000 2,500 W Q. oS 2,000 :; III fj CI> ... Q. 1,500 1,000 500 .- 0 4/3/2006 -+- Wellhead Psi ~ Annulus Psi :5 Q. a:¡ - 2.50 CI> ... «S e::: RU D#1 April 2006 Rate and Pressure 5.00 4.50 4.00 3.50 3.00 2.00 1.50 1.00 0.50 0.00 3/29/2006 o 5/3/2006 4/23/2006 4/28/2006 4/8/2006 4/13/2006 4/18/2006 4/3/2006 Time 3,000 2,500 2,000 æ Q. oS 1,500 :; fj III CI> ... Q. 1,000 500 Rate, BPMI -+-Wellhead Psi I ~ Annulus Psi I RU D#1 May 2006 Rate and Pressure 3 4,000 4 3.5 3,500 3,000 2.5 2,500 :5 æ Q. Rate, BPM c. oS a:I 2 2,000 ... -+-Wellhead Psi oS ::::¡ ... 1/1 «S III ~ Annulus Psi e::: CI> ... Q. 1.5 1,500 0.5 1,000 500 o 4/28/2006 5/3/2006 5/8/2006 5/13/2006 5/18/2006 5/23/2006 5/28/2006 o 6/2/2006 Time _ FOREST OIL W"ELL SERVICE REPOfr Date: 4/11/2006 Well Number: RU #D1 Wireline Company: Pollard Wireline Inc. Location: Osprey Work Being Done: Tag fill AFE# I Charge Code: Present Operations: Wireline Crew: WhitakerlWolfe Supervisor: David Hall Total Wireline Miles: 4 Wireline Unit Number: Power Pack Max Depth (KB): 8035' Zero Wireline at: Tubing Hanger Well KB: 55.6' Minimum Tubing ID: 2.31" Max Tool OD: 2.25" Time ODeration Details Inspect Unit MIT 07:15 Arrive @ XTO Heliport 08:00 Arrive @ Osprey. Meet wi foreman - Hold safety meeting 09:30 RlU 11 :00 Pressure test W IL valve & lubricator to 3000 psi - Good 11 :30 RIH wi 2.25" Gauge ring to 8035' KB, tag fill. POOH - slowly due to lock @ Stuffing box 14:30 RID, clean up, make report 15:30 Stand by for chopper Tool Cost: 2.25" Gauge ring $ 60.00 Work String Detail: 1 1/2" - RS, KJ, 10' stem, KJ, OJ, SJ, 2' stem Description of any NONE tools or debris left in the hole: Brief Summary of Tag fill @ 8035' wi 2.25" Gauge ring Total Work Completed: I Total Hours Worked 12 Total Tool Cost $60.00 Total Hour Cost $2,075.00 Ticket # : I P-361 I Day # :1 1 Daily Cost: I $2,135.00 I Cumulative Cost: I $ 2,135.00 Well Downtime Hr. nla H2S PPM nla Wire Test 21, 21 Approved by: David Hall Code: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test E-Mail to;Tom_Maunder@admin.state.ak.usandBob_Fleckenstein@admin.state.ak.us OPERATOR: Forest Oil FIELD I UNIT I PAD: Redoubt Unit DATE: October 4, 2005 PTD: 2022280 Well #: RU#6 COMMENTS: PTD: Well #: COMMENTS: PTD: Well #: COMMENTS: PTD: Well #: COMMENTS: PTD: Well #: COMMENTS: TBG. INJ. FLUID CODES F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING TEST TYPE: M = ANNULUS MONITORING P = STD ANNULUS PRESSURE TEST R = INTERNAL RAD. TRACER SURVEY A = TEMPERATURE ANOMALY TEST D = DIFFERENTIAL TEMPERATURE TEST ANNULAR FLUID: DIESEL GL YCOL SALT WATER DRILLING MUD OTHER P.P.G. Grad. WELL TEST: Initial X 4 - Year Workover Other 1.01 0.05 Distribution: orig - Well File OPERATOR REP SIGNATURE: c - Operator c - Datatsffèet revised by L.G. 8/6/00 c - Trip Rpt File c - Inspector Doug Young , AOGCC REP SIGNATURE: Chuck Scheve RU #6 MIT RU-6 10405 6/20/2006 , ~ Redoubt Unit #WF6 DATE 3/7/05 Injection Log FOREST OIL CO. Step-Rate Test Flow Time start/stop Well Head Information Meter InjRate Start Stop Wen Head Flow Line WH Temp, FL Temp. CSP Comments Time (BPM) Time Time (PSI) (PSI) (Deg.F) (Deg.F) (PSI) 0100 0200 0300 0400 4:40 0 0500 0.34 19 41 0 1,295 BBls on totalizer fm start 0600 0.34 586 36 0 0700 0.32 875 33 0 0800 0.33 1003 32 0 0900 0.32 1096 31 0 1000 0.32 1109 31 0 1100 0.35 1166 31 0 1200 0.32 1150 31 0 1300 0.35 1141 30 0 1400 0.36 1067 30 0 1500 0.35 1063 31 800 1600 0.35 1060 31 850 1700 0.35 1086 31 1040 17:00 HRs Started bleedina ann.1040# 1800 0.34 1061 31 965 1900 0.37 1041 31 920 2000 0.35 1041 30 920 22:40 Opened bleed valve more 2100 0.34 1029 30 900 2200 0.34 1019 30 840 2300 0.36 1016 30 820 2400 0.36 1019 30 820 23:59 Shut in annulas bleed off. Comments SCROLL DOWN FOR DAILY AVERAGES . . Daily Injection Rate Total Amount From HMI Average Wellhead PSI Average Flowline PSI Average Casing PSI Average Flowline Temp 0,34 413.00 982.35 i'OlVlOl 443.75 31.55 #18 ) ) ~ FOREST OIL CORPORATION ,'fI() Q7{'Ó/);¡r(~(!1 . DX~dl'! 700 QÇY/;'('h(!,)(a~r¡r!, QW/adka ,9,9/}(}1 (907) 25S-S6,{)() · (907) 2,')S-S6'O/ RECE IVE 0 OCT 11 2005 October 7, 2005 Alaska Oil & Gas Cons. Commission AnchOfage Commissioner John Norman Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 Re: Request for Authorization to Inject Alternate Fluids into Redoubt Unit #D1 Class II Disposal Well (DIO No. 22) Dear Commissioner Norman: Forest Oil Corporation (Forest) received approval on August 9, 2001 to inject Class II fluids into the Upper Tyonek Formation according to the conditions of Disposal Injection Order (DIO) No. 22. That Order authorizes injection of "produced water; drilling, completion, and workover fluids; rig wash, drilling mud slurries, NORM scale, tank bottoms, and other fluids brought to the surface in connection with oil and gas development activity on the Osprey Platform" into RU #D1. Two subsequent administrative approvals (DIO 22.001 and DIO 22.002) authorized the injection of treated sanitary waste and storm water. Forest is requesting an administrative approval from the Commission to allow for the injection into RU #D 1 of Class II fluids that are generated at other Forest operated facilities in Alaska in addition to the Osprey platform. The request is for the following reasons: · In addition to RU #D1, Forest operates two other Class II disposal wells, KF #1 (DIG No. 26) at the Kustatan Facility, and WMRU 4D (DIG No. ló) at the West Mc Arthur River Unit. Of the three wells, only WMRU 4D is permitted for all Class II wastes, regardless of type and origin. RU #D 1 is restricted to the class II fluids mentioned above and generated only from the Osprey Platform. KF #1 is restricted to produced water from the Redoubt Shoal Oil Field. . KF #1 is scheduled for re-entry in October 2005 for conversion to gas production. It will no longer be available as a disposal well. . WMRU 4D is scheduled for a work-over later this year, after which it will placed back into operation for disposal. During that work-over Forest will have no other disposal wells available to accept produced water from WMRU. ) ) . Forest is undertaking a long-term exploration program in Cook Inlet area. Drilling wastes from that program can currently be injected only into WMRU 4D but Forest now relies heavily on WMRU-4D for disposal of class II fluids from production operations. . Forest requires additional injection capacity at RU #D1 because of the increasing capacity demands at WMRU-4D and the need for an alternate disposal well during periods when WMRU-4D is not operational. Forest requests from the Commission approval to inject into RU #D 1 all Class II fluids generated at its Alaska facilities, including the Osprey platform. Please contact me if you have questions or need additional information. Sincerely, ßW~ Bob Elder HSE Manager 907-868-2139 rgelder@forestoil.com #17 ) ) \ ~ FOREST OIL CORPORATION ,'fI() Ó)'{OYÎI(N!! . c:Vt~lle 7()() OÇ~I('h()'J((~r¡(!, oçflaJka .9.95() 1 (f)07) 258-å'6,{)() · (907) 258-86'0/ (d-),;;'./) Commissioner John Norman Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, .A.K. 99501 RECEIVED :') If 23?~'4 Aia_a Oil & Gas Con' 'A... S. CommÌ8ÐÍfi ~.ch~,vn November 19, 2004 Re: Request for Authorization to Inject Gray Water into Redoubt Unit #D1 Class II Disposal Well Dear Commissioner Norman: Forest Oil Corporation (Forest) subrnitted a request to AOGCC on November 5, 2004 for approval to inject several types of fluids into Redoubt Unit #6 (RU-6) on the Osprey Platform for enhanced oil recovery under Enhanced Recovery Injection Order No.2, issued to Forest on August 26,2004. One specific fluid is gray water from sinks and showers on the platform. Gray water is perrrlitted to be discharged under the terms of Osprey Platform's NPDES permit. However, Forest prefers to operate the Osprey as close as possible to a zero surface discharge facility to reduce the risk of exceeding NPDES discharge limitations. To accomplish this objective Forest continues to seek a favorable response from the Commission on our August 26, 2004 request to use gray water and other alternate fluids for EOR operations in RU-6. This letter is to request, in addition, approval to inject gray water into the Redoubt Unit #D1 Class II disposal well as a backup to using gray water in EOR. This request is for the same reasons cited in DIO No. 22.001, issued on June 19, 2002 allowing the disposal of storm water collected on the Osprey deck to be injected into RUD #1, and in DIO No. 22.002, issued on February 3, 2004, allowing treated sanitary waste to be commingled with produced water and injected into RUD #1. .ì ') Gray water from the Osprey Platform is filtered through strainers for solids removal and would be commingled with treated sanitary waste before injection into RUD #1. Approximately 4000 gallons per day or less is produced. The pH of the water ranges from 6.0 to 8.5. Forest respectfully requests the Commission's approval to inject this fluid 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, ;i3¿}f-~ Bob Elder HSE 11anager 907-868-2139 rgelder@forestoil.com #16 ) ) )@ FOREST OIL CORPORATION .'fi(} º?(cf1;j((~q/. cY;'~(Ir~ 7()() ()Ç4n(:,hof(UU!., C'C{kr.Jka .9.9,j(ij (:I ((¡OJ) ;¡..),S'-Sú'(i(r e (10J) ,!';S-S6'()j (r;~f0,,) June 30, 2004 Alaska Oil and Gas Conservation Commission 333 W. ih Avenue, Suite 100 Anchorage, Alaska 99501 Attn: Mr. Tom Maunder Re: Redoubt Unit #01 - Annual Report Dear Mr. Maunder, This report is in response to the requirements for annual surveillance reporting on the Redoubt Unit #01 Class II disposal well. Rule #4 of the Disposal Injection Order #22 requires this surveillance. ) This well has been used for disposal of Class II drilling wastes generated from the drilling of all Redoubt Unit wells after Redoubt Unit #2. In addition to the drilling waste, produced water was introduced into RU 0#1 in July 2003. The well has been operating within what we consider normal parameters and has shown no sign of integrity problems. A slick line tag performed on June 29, 04 encountered fill at 7,714' MD. If there are any questions, please contact me at 907-868-2137. Sincerely, ~~~~ Ted E. Kramer Production Manager Forest Oil Corporation RECEIVED SEP 2 2 2004 ORIG\NAL Alaska Oil & Gas Cons. Commission Anchorage J" " SCANNED OCT 1 0 2804 ) Corrected 0#1 Pro 6/30/2003 7/31/2003 8/31/2003 9/30/2003 10/31/2003 11/30/2003 12/31/2003 1/31/2004 2/29/2004 3/31/2004 4/30/2004 5/31/2004 ) ) 3,315 71 ,949 43,210 44,399 38,651 36,386 54,188 76,101 86,546 89,977 80,283 ) ) Forest Oil Corporation Osprey Platform Yearly Injection Report - Production Water June 1,2003 to May 31, 2004 Disposal Well RU 0#1 Corrected 0#1 drill 4,168 9,611 1,983 18,305 7,777 7,752 7,981 3,893 1,985 4,868 SCANNED OCT 1 0 2Q04 Effluent reported Effluent correct 586 168 14 '. ) ) Forest Oil Corporation Osprey Platform ) Yearly Injection Report SWACO Pump June 1, 2003 to May 31, 2004 Disposal Well RU 0#1 Produced Rain/Effl. Date Injection # Seawater Slurry Water Water 6/3/2003 175 190 625 0 0 6/8/2003 176 160 680 0 0 6/12/2003 177 170 804 0 0 6/21/2003 178 143 810 0 0 6/30/2003 179 174 412 0 0 June Total 837 3331 0 0 7/6/2003 180 158 1051 0 0 7/8/2003 181 180 755 0 0 7/9/2003 182 140 968 0 0 7/10/2003 183 0 1855 0 0 7/10/2003 184 140 1684 0 0 7/14/2003 185 161 327 0 0 7/16/2003 186 158 553 0 0 7/20/2003 187 20 10 0 0 7/22/2003 188 182 592 0 0 7/27/2003 189 160 517 0 0 7/31/2003 P1 0 0 3315 0 7/31/2003 P2 0 0 6194 0 ) July Total 1299 8312 9509 0 8/2/2003 P3 0 0 948 0 8/3/2003 P4 0 0 3987 0 8/4/2003 P5 0 0 4245 0 8/5/2003 P6 0 0 4697 0 8/6/2003 P7 0 0 2674 0 8/7/2003 P8 0 0 5207 0 8/8/2003 P9 0 0 5410 0 8/9/2003 P10 0 0 4523 0 8/10/2003 190 141 1325 0 0 8/11/2003 191 153 126 0 0 8/13/2003 192 0 238 0 0 August Total 294 1689 31691 0 9/7/2003 193 0 0 0 643 9/7/2003 194 165 218 0 0 9/8/2003 195 165 1359 0 0 9/9/2003 196 176 1827 0 0 9/11/2003 197 164 210 0 0 9/11/2003 198 34 449 0 0 9/12/2003 199 200 901 0 0 9/14/2003 200 189 720 0 0 9/16/2003 201 21 302 0 0 9/16/2003 202 141 943 0 0 ) 9/17/2003 203 162 1246 0 0 9/18/2003 204 181 1246 0 0 9/18/2003 205 140 1100 0 0 9/20/2003 206 181 930 0 0 9/22/2003 207 175 1148 0 0 9/24/2003 208 190 808 Jage ~ of 3 0 SCANNED OCT 1 0 2004 ) ) Forest Oil Corporation Osprey Platform ) Yearly Injection Report SWACO Pump June 1, 2003 to May 31, 2004 Disposal Well RU D#1 Produced Rain/Eftl. Date Injection # Seawater Slurry Water Water 9/25/2003 209 178 857 0 0 9/27/2003 210 167 769 0 0 September Total 2629 15033 0 643 10/1/2003 211 276 723 0 0 10/3/2003 212 229 760 0 0 10/6/2003 213 160 923 0 0 10/10/2003 214 140 723 0 0 10/17/2003 215 154 949 0 0 10/20/2003 216 20 417 0 0 10/20/2003 217 157 449 0 0 10/24/2003 218 160 836 0 0 10/28/2003 219 161 540 0 0 October Total 1457 6320 0 0 11/2/2003 220 160 1387 0 0 11/7/2003 221 160 867 0 0 11/9/2003 222 169 662 0 0 11/13/2003 223 132 486 0 0 ) 11/15/2003 224 157 572 0 0 11/17/2003 225 0 172 0 0 11/18/2003 226 0 1054 0 0 11/19/2003 227 0 539 0 0 11/22/2003 228 121 350 0 0 11/26/2003 229 125 639 0 0 November Total 1024 6728 0 0 12/1/2003 230 124 630 0 0 12/5/2003 231 126 418 0 0 12/8/2003 232 126 240 0 0 12/12/2003 233 119 340 0 0 12/15/2003 234 120 316 0 0 12/17/2003 235 160 274 0 0 12/18/2003 236 131 168 0 0 12/19/2003 237 100 331 0 0 12/20/2003 238 1018 1018 0 0 12/21/2003 239 126 423 0 0 12/25/2003 240 20 526 0 0 12/26/2003 241 20 607 0 0 12/30/2003 242 0 500 0 0 December Total 2190 5791 0 0 7981 1/7/2004 243 125 672 0 0 1/9/2004 244 106 187 0 0 ) 1/13/2004 245 137 152 0 0 1/25/2004 246 0 190 0 0 1/26/2004 247 160 665 0 0 1/27/2004 248 160 794 0 0 1/29/2004 249 0 400 0 0 ".ß-\NNED OCT 1 0 2004- 1/31/2004 250 20 125 :>age ~ of 3 0 ') ) Forest Oil Corporation Osprey Platform Yearly Injection Report SWACO Pump ) June 1, 2003 to May 31 2004 Disposal Well RU 0#1 Produced Rain/Eftl. Date Injection # Seawater Slurry Water Water January Total 708 3185 0 0 2/3/2004 251 20 143 0 0 2/7/2004 252 124 742 0 0 2/12/2004 253 21 255 0 0 2/23/2004 254 140 540 0 0 February Total 305 1680 0 0 3/2/2004 255 125 409 0 0 3/5/2004 256 121 641 0 0 3/12/2004 257 23 1242 0 0 3/14/2004 258 125 361 0 0 3/22/2004 259 219 501 0 0 3/25/2004 260 20 710 0 0 3/30/2004 261 227 144 0 0 March Total 860 4008 0 0 I Yearly Total 11603 56077 41200 643 ) ) SCANNED OCT ,1 0 2~04 Page 3 of 3 (J') c' :Þ z z m o C) CJ -t I--" <=> f'-' C) C) ~ ~- Ch",_.-~ INJECTION WELL: RU-D1 RU-4A INJECTION #180 JULY 6, 2003 609Ð.·--:-·---~~~~-·~---·_" ¡ , w c:= ::J tJ) tJ) w c:= Q. -' INJECTION BY SWACO NO ANNULUS PRESSURE , ,,' .". ~:-.7~-·---'·---·~-·--:-:-·---:-:---:-:·"-·-··--:---·--"~··~-~"-·~._.__._...---._....--~..---:'~:-.-:~~.-:,..-'_._-_.---:~-:---._-~--~7~7~ 4.5 "'~~.A'· ~r~heS~ R:::rd,:d:eS:~re -.:032 psi ~ . . ... ..~ 4 3.5 '- ""''''N'L -.~'\,.,........"AV~~' ~'v_ '. .... I, " Seawater Volume: Cumulative Seawater: 1 58 bbls 29350 bbls ì I ¡ 50~O ¡ i I ¡ ¡ 40$0,.' ! . ' ; i I ¡ . 1 ", . 30œC, I :.... ¡: I, L i 20CÞ() ¡ 10~ i ~ í !, i~: I . II' I: I" 'I ': I'; I, 1-- . . i º> ~ !J., ~j., ~ ~ ~ ~ ~ K> .... b ...~ IL<O º> ~_br. ~ b ~ <ò ('If'¡., ~ !>. º> ILl>. ~S;j <.8:> ~ ~ ~ ~<o ~ ('I~ s;:) ~~ ~tf- ~<rþ ~'C? r:j9 ryjç;5 r:;~ Oj~ r:)~ ~ry r:j~ '.:6'? rj~ rs't ~~ :-j~.J t-;.r;;s ..;.':5 ..;.~ t-;.~ tX·v ..;.ry t-;.~ ..;.~ ~r t-;.Y t-;.:.J ~~ X)' X)' fJry ~.v r6~ r'.~ r'.~ r-:,.f} r-:,.,? c-.:~ r::5~ ~~ ~~ ~ry ~'? ~~ t\.~ ('I'~ ('I'~ ('I''} ('I',? ('I'~ ('I'~ oj';) oj~ ojY oj~ oj~ oj~ ~';) ~~ ~ry ~'? ~~ ~'? <t5':5 <t5~ <t5'P ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~v ~v ~v ~v ~v ~v ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ TIME Slurry Volume: Cumulative Slurry Volume: 1051 bbls 152200 bbls Slurry Wt: 10.0 ppg Slurry Vis: 50 Retort: 14% Solids 14% Oil 72% Oil I ~ump Pres -BPM I Page 1 ._-;~,,-';.' - --- 3 2.5 ~ Q. m 1.5 1 0.5 ---- 0 c ~'-~~þ07~ !> '~ (f' (j );- z z m F'i '00--" 6C{)~-- I 5~OO .·.1 4 w Q: :J (fJ 3~ (fJ UJ j a:: 0- 2 , 1 ~O() I ! Il Chc...~ INJECTION WELL: RU-D1 RU-4A INJECTION #181 JULY 8, 2003 ,.-..---.--------->~-.-~--.. .. 'm__~" .-.-'-~____:__-.,- 4.5 INJECTION BY SWACO NO ANNULAR PRESSURE , - ,..1. -'~~- :~- - ~ ,,, ~~-4 '-'~r ' ;,'.-:,5 Start Post-Flush @ 17:55 ,-, - - - ' Start Slurry @ 14:45 Seawater Volume: Cumulative Seawater Volume: Highest Recorded Pressure - 5559 psi :,-:- 2.5 .. _ :E 0- m 180 bbls 29530 bbls ;. -:- 2 ,- . ,- .. Slurry Volume Cumulative Slurry Volume: 755 bbls 152955 bbls -, Slurry Wt. 11.5 Retort: Solids - 18% Water - 58% Oil - 26% Slurry Vis 62 ',- 1 - - 0.5 , ,. , ' '1 0 I" I ' I . o <.J -t ¡....¿ 0- r--..:> C) <=> .þ. ~~rv ~~~ ~~<t:> ')j'P~ 9!:J~ co~rv ~~ ~{y~ 9!J~ ')jOÇJ<t:> ~~~ co~Cò rò~"':> gj~OJ g?0J fiJ~~ ~~ CfJP pjrf> r;f;'?Ý) 9.Jf ~~Cò ~~ r:i.J~OJ .Ç:j"':> .Ç:jCò ~f} ~'? ~~ ~<? ~'l> ~~ ~ry ~~ i¢~ ~?? iò'l> cö~ <ôry iò~ cö~ cö<? ~r;;s ~~ ¿,:,'ý ~'? N~ N<? ~ç;s a:..~ a:.,?<::J' n:.~~' ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~v ~v ~v TIME I-pump Pres -BPM I '<{to·-r- Page 1 -.~ ---- "-~/ 1.5 ---- v '- '~ RU-4AST Injection #182 July 9, 2003 NO ANNULAR PRESSURE '''-~'-·-'C-~-'''''---''----:---'''7~---'·-''"·-~:·-O':-·-''''·:-7'~77''''''.:,. ..: .'7::-7:"':,,',::::"./,','--- 6 Injection Well RU-D1 600 0 '-"'-'~'--'---:--:--""-''''''-::---~'''---'--'''T,''~; .<\ ~.'., o ,II '! I' I" il I Î' I .~., ~ ~ (_~ t-.Có ~ R> ~ '?> (\Có ~ ~ ~ ~ t-.~ s::> R> ~ '?> ~ ~ ~ ~ s:) (£0 ('V R> :1-- CD ~ ~ ~ 0J~ fJ~ f>~.J <&.J röç;J (]5':J íÓ~ fÖ~ !ô,v C{j'? ró'? (]5~ íÓtf- rò~.J C\'? ~r;;s (\~ (:\~ ~ry ~'? C\~ A\~ (\<? (:\y 9:J~ 93':5 9:)~ <O~ ~cy ~? 9:J~ ~~ ç:S<? ,,';5 ,,~ ,,'Y ,,~ ,,~ ,,~ (\.';5 (\.':' (\.r; (\'~ (\'~ (\'~ ~~ nj~ ~cy ~'? ~~ ~<t;> ~~ ~~ ~cy t-,;.'? ~~ ~<? 0J~ 0J~ 0J'Y (~~ 0J~ ~ ~ ~ , ~ ~ ~ ~ ~v ~v ~v ~v ~v ~v ~ , ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Time 5000 4000 ~ ~ t/) t/) ~ 3000 Il. Q. E ::;, Il. 2000 (f; C~· )::0- Z. Z m o o (""') --l ¡.-.t o "'"' CJ CJ ..þ 1000 '---:-.....,--...:-..__...-.-.~.->.....------,.-~........~----.....~.-._"'-'-.-.--~~...--.............~.~,.-..~-.."":..._.. .-:::---;"-"'. ._ _ "_uo_ __., _ _. _ ._ d. . f.--_-,'-__'.;<_- :.__'~-:.: ,'. ',. ..15635, psi- HighestRecorded pres~urel i No Pre-Flush pumped - injected liquid was~ash water I -" "- ~. ~ -'. .' ~ " . ... , . O'" . ~ '- ¡Start Post-Flush at 1·4:56~. . :. -;- _; ~ ~._.:- c-' '. .-.;c.-:.,....-.-.. - .; --.--. . " ,. ". : .--.-. -:. . :.::".,' - '. '-: ..0:' '_ '..-"~"_ . -.-.--.....-...,.-.--... '.-.' .. - -- --..- --- -.' .. ., . _..' ~ .. ,. . .-: - :'- -, . . .J_, .__..-.. .'_·cc' . .., " ..' '.. .~..- ...- - . ..--: - .- ...-. .'. -.-. '.: ::~:~.~.-.: ::,:. ; 1"..' ' .' :J.,::-'.:' , '...'.. ....."'. . ....',-..:- .'--.: .- -__'-'.._'" ,c_,_ .-. ,... . . . -." .-.-. .... . .':'.'-.':'--. .-,,-...." . - ..- .- ,-'f .~~;.. "!:~;I_ .- ~ . '~ . - . . - - ~. i*¡ti~jji;i' Seawater Volume: 140 bbls .' Cumulative Seawater Volume: 29670 bbls n :,,, t:~:'~ . -. . - --- ..'..-.-- '-. -.". ~~ ~,~--./(~-:~.'~ Slurry Volume: 968 bbls '. Cumulative Slurry Volume: 153923 bbls '-, '·t" - ~:;,':'J...,', : ,.';, "."., : . i ~".,.- ". '... -.-.. . ,"..-- ,,-:"-, .,' r>: ' , " !:' " -.. - ~ - - I -: -' :... . ." I·' Slurry: Wash water from pit cleaning Slurry Weight: 8.5 ppg \-~,:. '-- 1·:>-··· I-pump Pressure -BPM l ~·~-.~~ir;~· -' ,.-." 5 , / -' 4 3 g: en 2 1 ---' o '~i# -,-, .---- .~ Injection Well: RU-D1 RU-4AST Injection #183 July 10, 2003 NO ANNULAR PRESSURE 6000 ..-'~-- .".-..-.--,."...,....,.,..........-....,...."..,..·......-..--~~_·,'~·=,~~...".....,.7- . ., ",.., ,..".,..""""".,:"_~."""~,~2~,,,.~,.~,,,!,,,,, 6 5000 5 _/ 4000 ~ ~ ~ en en ~ 3000 I; 0- 0. E ~ 0- 2000 I 1 000 -- 1.,,1_1 ''''_.' ~ ~" ~_.. .~,' , u~_ _." - ~ _. VIII' A1 ,.y ,,- - .- _¿ _ _ _ ._"., . - _, v'., VtfIhI. ~ 4 Î No Pre-Flush or Post-Flush pumped - injected fluid was seawater used to displace OBM from well I - - " 3 ~ co '. Seawater Volume: 0 bbls Cumulative Seawater Volume: 29670 bbls 2 Slurry Volume: 1855 bbls Cumulative Slurry Volume: 15578 bbls (j¡ () » :z z rn o o CJ --4 ~ o f'..,) C) C) -Þ:> Slurry: Seawater displaced from well Slurry Weight: 8.5 ppg 1 ----- o I I r I I I ! I I' I I I I I I I f I I I II I I I' III I i I I I I I I I I I I I I I 'i 1'1' ~ ~ ~_~ r.:> :¡" ~ ~ 9.> º> ~~ b ~ ~ ~ ~ :¡, º> C (\ ~ " ~ ~ ~ ~£t, " (\ ~ ~ Ç) ~ ~ ~';3 ~~ ~~.) ~';J ró~ to:..'Y gSf)} ~'? rótf- ~~J ~~ a:.~ ~~ C(,ry ~'þ a:.~ ~tf- t:!JC:;S gj';J ~~ cof} rfJr-y ~'? ~~ CO~J _~';J 9J';J _~~ ~ry _~';3 9Jn;; ~~ r,,;,~ r,,;,r;3 r,,;,~ n!J';J n!J ~ nj '? nj ~ ~ ';J ~ ~ ~ '? ~ ~ <6 ';J <6 ~ <6 '? <6 ~ (()~ (() ~ (() 'þ (() t?- A\.~ '\ ~ /\. '? A\. ~ rò~ qj ~ ~.~. Cb ~ Ój"if - Ój ~ ~ ::r Ój ~ "r::5';) Time o l-Pump Pressure -BPM I ~ìfii :C. ..' '.::2 ~ (JJ (') :Þ z z m L) o n --I /-=l o f'.,;) c=> CJ -+:- 6000 5000 4000 ~ ;:, en en e 3000 Q. Q. E ::J a.. 2000 1000 -'- Injection Well: RU-D1 '-' RU-4AST Injection #184 July 10, 2003 NO ANNULAR PRESSURE Seawater Volume: 140 bbls Cumulative Seawater Volume: 29810 bbls . Slurry Volume: 1684 bbls Cumulative Slurry Volume: 157462 bbls Slurry: Seawater displaced from well Slurry Weight: 8.5 ppg o <-:> ~ ~ ~ ~ .....<:> ,j:) a, ~ ~ (\ ~ bo. ~ ~ ~ " ~ ~ ~ ~ (.!O ~ ~ " º> (f).. ~ ~ " ~ 2> <¿~ ~ry <¿~ çS~ ~n¡3 ~~ n;? 1j)9 ?s':' Rj'Y ~ry Ij)~ ?s~ f6YJ - t¡;.~ Ç6t;. t;.ry riJr-p t;.~ Ç6~ t;.:J çS\;> f6t;. ç5f} t;.~ ~:J ~9 ~~ ~f} RSrv ~n¡> (..:~ rò~ (".:..~ rò~ rò<9 ~9 ~'} ~'? ~?;J qj<::¡) qj'Y qj'? qj<t;J ~<::¡) ~ry ~~ ()j~ ~t;5 ~ry ~~ ~~ ~':' ~ry ~~ n'~ n'~ n''? n'~ n:.9 rs'Y rj'? ~ ~ ~ ~ ~ " " " " ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~- 0/ 0/ 0/ 0/ 0/ ~ ~ Time , . I-Pump Pressure -BPM I '-" 6 5 ------ 4 3 ~ ca 2 1 ~' o \~ (J) (') » z z m o o CJ ~ ~ 00 '" c:> c:> .þ 'c__ "-' -'-' RU..4AST Injection #185 July 14, 20Ò3 NO ANNULAR PRESSURE --------. -., - .. ,~--~, ~ 6 Post-Flush at 17:3S~PSi - Highe:tR~CO~:dP;~u~~J~ 5 Injection Well: RU-D1 6000 7ë,>~: -", '~, -,' '--:;.,:",-',,", -'.", -!"'; :~:,lstart Slurry at 16:13 5000 4000 ~ ~ en en ~ 3000 0- Co E ~ 0- 2000 1000 -. -/ '. '",_.,. - . .' -~ , " , .' . ,',. .", . '.: .~ 4 Seawater Volume: 161 bbls Cumulative Seawater Volume: 29971 bbls 3 ~ ca 2 Slurry Volume: 327 bbls Cumulative Slurry Volume: 157789 bbls Slurry Wt: 11.0 ppg Slurry Visco: 51 sec/qt Slurry Retort: 11 % Oil 82% Water 7% Solids 1 -' o I . I I' I I I Þ ¡. I . I '1 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ b ~ ~ ro '? X5~ c-¿c;J ro ~ c-¿ ~ c-¿ ":' vfÞ c-¿ ry X5 ~ ro ~ X5 ~ X5 tf. r.l? ro <f> (\ '? A .~ (\ ':- Ä' ':' Ä'cy ¿.:, ry A'';5 ¿.:, ~ ¿.:, ~ Ä'tf. A':..1 Ä':..1 n:.';3 n:.~ n:. ':- n:. ':' ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~v ~ ~ ~\ ~ ~\ ~\ ~ ~\ ~ ~ ~\ ~\ ~ ~v ~v ~v ~v Time o I-Pump Pressure -BPM I en (") )::. z z m o C) CJ --I J-A o "" C=> CJ .þo ~-~ , "-~ . '- Injection Well: RU-D1 6000 ~.~--:-~~.,., ~~~~-"""'~.",.-""_"--::~""'" RU-4AST Injection #186 July 16, 2003 NO ANNULAR PRESSURE ,'~.,.,m-'-^-C-~-'~-~-·'é-"""':···""-·---:~-·--:-"~--'···-'----·-~··^--'··-,·.----..,.,......--"7"7~~'-...-·~---:---,-..,ë·-"--·....,.,...-~-~.........,...~'""~_=.:7~ 6 5000 4000 e ::;, V> V> e 3000 0. Q. E ::J 0. 2000 '. ' ~~:. .-,::;-. n_ ; ";- -., ~~;-;.~~'.'-:~~ ";',: ~ - , " "_»:::'::,-;.-:-->--::.-~-' ,'. ", ," ':-. :.,·_-ô_· ",-,". '. -,:,}'")..:.":". .... ,",.,- ". .- J' --.". - " .... - - -".. ..'" ,. ' : - - ._-. -; .- - -. ~. ......~_c. "' Seawater Volume: 158 bbls Cumulative Seawater Volume: 30129 bbls Slurry Volume: 553 bbls Cumulative Slurry Volume: 158342 bbls 1 000 ~- Slurry Wt: 8.7 ppg Slurry Visco: 28 sec/qt ':'-,", .-..---:-',-:'-':- -, '-.-.--::.- .' - - - -::~ - - '--- -" - -" : -. . . .. _:-'".,:., ,'-- ." -:;:-- -. - . ... -"'-,--..::--. .- -' _: -." -.----' ..-....-.: :-:'- - -. -.-_.- -' .. -. -. -.-" - - -- ---. ';'--- --- -..--..----..--. -------:--.,':. ....··.~;;;,i;~.·&:: .- c"/~.'""-: -..:u_··'_-".':':C-_..--·;' --.~ _. - - - . :--....---:-'"--'-:'--'--"'--.'-.--::::.:. . . : - - - - - -- = -- -- -: - ~ . - ~ '...:..,..-:_----- -.- 5 -- 4 3 ~ en 2 '. 1 / -- o I' "'1 I 'Î .! 0 .<:><:> .~O:> .s-. .~n" .~ .0/ .~ .~~ .~O:> .~ .<:>~ .~ .~ .~r-v .,,<ò ".'1;.~ JP.R> ".n".~ J~.9:> ".~.~ ".~.<:Ò ".<r.;.~ ft:>0:> ~ïo Q)' ~. ~. R;)' S-)' s:)' s:). ~. ~. ~. ~. Sy ". ~. ~. " ., ., ., ., ., ., ",. ~. ~~ ~~ ~~ ~~ ~~ ~~ ~~ ~~ ~~ ~~ ~~ ~~ ~~ ~~ ~~ ~~ ~~ ~~ ~~ ,,~ ,,~ ,,~ ,,~ "'~ ~ ~ ~ ~ ~ ~ " ~ ~ ~ ~ Time I-Pump Pressure -BPM I ,,<*;y¡--;." \~ en (") » z z m D <::) CJ -- J-=l o í'V C) C) ..þ RU..4AST Injection #189 July 27 2003 NO ANNULAR PRESSURE --.--~-_..-"----.-------"-.------- ---.--_.-- --,----' ---.--. ---- --- --'.-'.-'.-' -..-.---------.---'.---.-~ 4 .. . .. ..-J 5457 psi - Highest Recorded Pressure I . . .... ~., yt~~ -I .. - .,¡;-'~I Start Slurry at07:23 ,,~.J -~.... r I Start Post-Flush at 09:50 I -- Injection Well: RU-D1 6000 -, ._- --..-------:------ - 5000 4000 ~ = () .. () ~ e 3000 0.. Q, E :::J 0.. 2000 \ 1000 ~'.--' , , Seawater Volume: 160 bbls Cumulative Seawater Volume: 30491 bbls Slurry Volume: 517 bbls Cumulative Slurry Volume: 159461 bbls Slurry Wt: 8.6 ppg Slurry Visco: 34 sec/qt Slurry Retort: 3.5% Oil 95% Water 1,5% Solids o ~ -- I' t- I - : I ~~~ ~~~ R5~0; s:5o/ ç51- ~'?' ~~ r;:j~ R5~ ç5~rv ç5~0; t-;.~~ t-;.t;-' ,,~ ,,1" ,1' ,,'?~ r-;.'?f1... ,,'?~ ,,1 ,,~'" "tþ ,,~' A\~ '\ ~ A\'Y A\ ~ A\ ~ A\ V} C'Ö~ C'Ö ~ C'Ö 'Y C'Ö ~ C'Ö ~ C'Ö <tþ cb~ cb t;- cb f} OJ'? OJ ~ OJ <tþ ,Ç5~ ,Ç5 t;- ,\:5 ry .....Ç5 '? ,\:5 ~ Time .~ I-Pump Pressure -BP~ I '~ë - '- 3.5 - 3 "_/ 2.5 2 :IE 0- m 1.5 1 - 0.5 -- o ·L.., "~ll.,,·) ~ ..........7' - NJECTION BY SWACO NO ANNULAR PRESSURE . -',. 4 .~ ~ - 3.5 ~\:~:'C ; 3 Ch~-~-~ NJECTION P1 JULY 30-31. 2003 RU-D1 NJECTION WELL ....~.¿ " '·r ..... ti,iJI~!6t~, , .l,;;~.,~,_', ~~-~t~~~ - . . :";.', '~,{~Ô.~~' . 600) ¡.;' I. ~ .'"-- ~F~Ft~;f~7 ~ ~ : :: .. ". 500 .~ :æ: Q. m 2.5 1.5 0.5 2 1 ~ ~ I < -, .... . :.. f. 3315 BBLS 162,766 BBLS Slurry Vis: 26 Slurry Volume: Cumulative Slurry Volume: Retort: : Solids - 2% Water - 98% Oi 0% 5312 PSI J.... :.>. " <'" ':::~ï~'t*~~{ :~ - ".1. ,. - . " . ...- '. ',,' ~lI~~~.,.,.:"¡.j;'~:""~';'~{4f' L '''.~~~''~.;.. ..' . .. ':"P-~1ib ~..~'f;\.~ ,... ~' ':;-. .;,~¥~}~" -~ . <,,~,~~:~$~~. ~~l~~~~~'~.' '. - , . , . \·N~{'... jI. -. - _ -', J!.1¥i¡-#;l..y!>!¡1~ ~ ' " ~ . ., :~~~;~~~ :~:"'~:: ,~'''.'''~ ~~~£~~~~;t::r..;~ : 300 I i -" . . .....3"Øtt1~,,,,, ...- '. '. . ", . . ..~r%ffl~:~;c;};;:<'r:";'-:' [::~.Ù2;~;:\~ :;:':"'I~M4~~ ' "" .... ,Þi..~;.r,~"4' ,", .- ..,....!;. 7 >,~~:;r'$..>-... fJ '(:' ;~ ". ~r~':>'ì~'" ,'-: (L 1"1" ,..','.' r', I I 8.4 Slurry Wt. Highest 400 w 0:: ::J en en w 0:: 0. ~7·~!~;- ;.--~ . I o .' ';< ~~~~~~g~~~~~~~~~~~~~~~~~~~~~g9~~~~9~~~~~~~~~~~~~ çS ~~ ~ssY"~,, ':'"Y" '?"y~~f);,':'a:.~f);,~f);,~a:.Y~~~~~~~~~~~Y~ ~~ tp~~~ ~~~~~~~~~'?~~Q:;SJ~ ~sotpQ:; ~~ ~/(~'\ 0.:~/( ~,\~~~g;~~<o'?g;~<O~9~9ry <,:, ~<,:, ~<ó <9Q:; ~Q:; '?Q:;<9.A\ ~ ~/(<?<O ~o:. '?o:.<?r-:. \::6 '?r-:.<?,ç;j ~çS '?r-:.<?"~,, '?,,~n·~·~n·~n: ':'n: '?n:~ç;j ':'çS '?ç;j~" ~~~" ~n'~\/~n'~n: ':'n:. '?n: ~~;.>t-;. ~t-;.~<':' ~I~<,:, ~(",:, ~("J?("..: ~ ~~~~~~~~~~~~~~~~~~~~~o/o/o/o/o/o/ vvv~~~ ~~~vvv TIME Page ~ BPM Pump Pres 1 (/) () » z z m o o CJ -{ ¡..-.\ o '" C) C) .þ - INJECTION BY SWACO NO ANNULUS PRESSURE C ~ ."-'" NJECTION P2 JULY 31. 2003 INJECTION WELL: RU-D1 ~. -..-' 4.5 '.~ 3.5 :E c.. m 3 ;- 2.5 -2 ~4 - , .~' J _." .' 'I'" , . ~·ø - .' - -. .... . -' - .~. , . . . - . .,~~~.~ "~hj~~-:~~'-;::'>i ..... ~ -.: . . _ '-i:_ '...:-:- :.",: . -"':-,-- (:/:-.:: .:: "a·· ..; :: ..;: ';:~ _ .r; : , - :~": . I.~~ . . :.i;'" II ,,' ',. - j.... . ~ .: - i 1- '.~- " i ~. .r.r..-., __ .:. .~. :1...; :'l""":~" ~ ;...; ":''':;E~'; r ~ '0(''': ;..'~.. .-" r _ .... .::" ~~ . .". -.. '. r" ,'.... ",_ ...--r-;·· . .' .":;. ~. ':""- 5126 psi .:",~..¡~~~ - Recorded Pressure -·.:i:t~~ :&~~~;!' 6C'(~.o:~, " , " ~=r~~~ &F·:~ :" -f;~1X ,,\ ~.. ~.r: 5C .J~ :";~.- 'f; " ,.... ~ ~:- .~ I ... '.. ~ . - ..-...... ' ......... .... i 6194 bbls 168.960 bbls Slurry Volume: Cumulative Slurry Volume " ~ " '. ,- w 0::: ::> en en w 0::: c.. 5 1 1 - 0.5 Slurry Vis: 26 sec/qt 8,4 Retort: Solids - 2% Water - 98% Oi 0% Slurry Wt: o 2C .- '", .{ ~.I ;- ' ~~, , I " L . ~! 1(-0 j .1 o o r I~ ~ ~ ~ ~ rv R> ~ a.. ~ Ç;:) I.Ý:) ~ ~ ~ l.fb ~ ~ ~ " C?> c\ I,Ý.) \:) ~ 9 1£0 \:) r.s:.) \5':3 \5f} \5~ \5<t¡J ~~ ~ry ~~ tJ,9 tJ,f"þ tJ,~ tJ,:.) n¿,~ n¿,'? n¿,~ n¿,:.) t» t:;.'? t:;.~ <t5~ <t5~ <t5'? <t5:.) 6~ 6f} 6~ 6:'; ~~ .\:) {').'" .po,,: .'" n'po,,: ." ...:" I':"" r.:.." A·PI... 0:.." ." r\.PI... ." n'" .PI... r\.'" Þo.'''' n'''' n:..t.;. ....:t.;. I':"t..;. r.:..t.;. A'po,,: o:..po,,: (').'" r\.'" .PI... <Ò. -oJ' ,,~. "". ""V· ,,~. "",,' ".). "V' ",' "V' "C!)' t'),'V' t'),~' t'),v' rÇ:>' 'V. "'·V·-.J· ",,' ~.). v', -,' v' -oJ' ,,'V' ,,~. TIME Page BPM Pump Pres 1 (J) (') » z z m o o (J -f ~ c::::> I"V CJ C) ..þ. '-..,...' CL<~_, INJECTION P3 INJECTION BY SWACO NO ANNULUS PRESSURE INJECTION WELL: RU-D1 AUGUST 2, 2003 6000 - -------...- - 5000 ,. - ,. ~,--~VI. /~~ 5170 PSI - Highest Recorded Pressure I' 40?0 , w i 0::: ¡ . ::J tn 3060 tn w 0::: 0. 2000 Slurry Volume: Cumulative Slurry Volume: 948 bbls 169,908 bbls , Slurry Wt: 8.4 Slurry Vis: 26 sec/qt Retort: Solids - 2% Water - 98% '" () ):-. Z z m C? a n --f 1000 o ¡ I I I I I I I I I I I I I I I I I I I I I I .~~~#$ß##"~~-~~$""'~#~~~~#$ ~q!;~~q!;~ ~d;c:;3 ~cl'!- ~d;ry; ~d;0) ~d;~ t...d;~ ~c:;3 ~~ ~')ì ~O) ~~<~~ r-v~c:;3 r-v~~ r-v~')ì r-v~0) r-v~~ r-v~<? r-vrc,~ r-vrc,~ r-vrc,ry r-vrc,n¡5 r-vrc,~ r-vrc,<? cÇ5~ cÇ5~ TIME I-Pump Pres -BPM I r~ o f'..) c:::') c::> .þ. Page 1 -~_.7 4.5 -4 - 3.5 --' 3 - 2.5 :E 0. m -2 1.5 - 1 - 0.5 - 0 en (') » z z m C1 o n -I f....1 .0 '" C) c::J ..þb -,- w 0::: ::) tJ) tJ) W 0::: c.. Ct.-_" INJECTION WELL: RU-D1 INJECTION P4 AUGUST 3, 2003 INJECTION BY SWACO NO ANNULUS PRESSURE 6¡GGG 5~ - - ~ - - - - I A _ _ , - , ~ - t _ _ _I _ "u ~,-- -,-, - 1--- _ Ia'_ '-Ar_ .A-, - _ -'A__ _I'" A-:\ ,,_ 3 ~ 00 , J \CO i I I I ~OO I I I i ¡ 1.J00 Slurry Volume: Cumulative Slurry Volume: 3987 bbls 173,895 bbls - 1.5 Slurry Wt: 8.4 ppg Slurry Vis: 26 Retort: Solids - 2% Water - 98% - 1 . - 0.5 o I I I I I I I I I r-..~ n\::> n..'ò ~~ t\,,'>:> n\o ......'>:> G..\o t\,,'>:> nCb ",t'1" ~~ t\,,'>:> nCb . ......'>:> r>. r-...~ r>. ".'ò n..~ ~ r-..~ n t\" n..\o ~.a., n:.~ n;..v n;..~ röy ~. ~.v ~~ ~:J ",. ",.v "'~ ",:J R)' R)'v R>~ ._~'-J ,-J ~:-' ~. <;5~ <;5'v <;5.~ <;5:J ~~9~~~~~~~~~~~~~~~~~~~~ TIME I-Pump Pres -BPM I Page 1 -- 3.5 2.5 '-- 2 :E c.. m .-- o Ct.~~ INJECTION P5 AUGUST 4, 2003 ....~ :" '. . - - 4026 1-·- -'. - ,. ,",. . .'.#1 ~' INJECTION BYM SWACO NO ANNULUS PRESSURE INJECTION WELL: RU-D1 "-.,- '-~'" :2 Q. ca 3.5 2.5 2 1.5 3 - :~' :~~~~r:~~) -~. ~~~{~-!~;?;~-~::. ~~;f;? ::-}-:,::'~~: '- - ";". h _ "..- .. ";"', " \. . ,- . '-~."'" ~ ~~,::'~~14 ~i ~ r;.~ ~:-~ ~ '.. ~ -". =". ~ --. ~ .' . ~:- :"" \~ .. ,-' " - , .~: -~~ -'- ? ,"' .".r ';",' "." .,:. " . ¡: l' ~ -~ '. .c:':~~?:..:::'- , ~~:;., ~:v3·.·:' "'"'-~~~~}. - ~:¡; ., 1 -I -. ;, Slurry Volume: Cumulative Slurry Volume - ,I.", ·.::~.7~;r ¡:-....... . '!,- ~", ~. '...... 4 5.00 " _ :, '. " .. /} :.á' H~?~est ReCO~ded Pressure 4 ·I'~ ~ßt::'~~¡;-~~~';:;i{\ ~~-,.' "- ~i' '·!.J,."r~~~'!:tJ"..·:--. . '¡"-:._;~,:-,,"~ ·~~t..!~\:~ . ,. '-- ~-tf" :t. -'~ -f~""~" \: "?:'1t'1¡~*.'J~':~' .: - 1- '. 2~JÖ; 2J,J0 w ct: ::> en en w ct: a. .- 4245 bbls 140 bbls : 78 15JO 1 J~O, 1 .. - , Slurry Vis: 26 sec/qt 8.4 ppg Retort: Solids - 2% Water - 98% Slurry Wt: . , '1 .-- 0.5 o r ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ r;5<? ~~ ~y ~~ ~<? ~<? [Ò~ [Òf} [Òfþ [Ò<t? (\'!J (\f} (\~ (\~ ~~ ~~ ~~ ~<? ~~ ~~ ~~ çj~ çjf} çj'}) ~~~~~#~~~~~~~~~~~~~~~~~¿ v ~ ~ ~v ~ ~ ~ ~ ~ ~ ~ ~ ~ ~v ~~ BPM TIME Pump Pres 1 Page :- ..- :r,' ~."~:. ' :;i:;%~,:,~ I I (j) () )? Z z m o o c-:> -f ¡-.L <:> '" c::> C) -ÞO> :'>. ~ .. " {7~: 5JO o ,~/ INJECTION BY SWACO NO ANNULUS PRESSURE Cl.,~ NJECTION P6 AUGUST 5, 2003 - ~t~.:. .-~.i .....,: -~'.I.:;.,; -. ~:'{:;-.,~ : - ~. .;. ~-:'.' . . ~-- -- _ 1 . ~. .' 1-", - .., . . , '.::':'> ':: ':'~(';,>:L' ~: y..:" ~. ;";". :.- '. -- . .~. "~:.- ~;..~",:.:_>'_~-:' '-:"; .>c::~' Slurry Volume: " ,~" ,': {:.- Cumulative Slurry Volume 4 3.5 3 INJECTION WELL: RU-D1 f^1~s~;]}~1~: . - ~ . . . . - ~ -:,,". ; .';~.: - :- -,"' . ".: ~:.¡.::..: '. ",-, ~ ...: l '" . ,-. - .. "'i . 0"' ........ "_,, ,or , .::_~~':)t¡·<2· '.: . '.' J~' ,:... . 3708 psi ;. ~I . ~~'.f"~-'_'~~j~~~?:~'~~~j Recorded Pressure .-L. -~.~ ~~ ,~::~ ~..;;:~: : . ........ . ~:'. ~ '. '. -' ,,-" . '1.... 4~~i !~~ighest 3 ;!Ù!~: --- :e Q. a:I 2.5 2 {:.... -\ 4697 bbls 82.837 bbls '- "; ; -' , , ";J ......._ 2 ;:;>p~:; 2 ::>0:: w 0::: :) en en w 0::: Q. 1.5 1 Slurry Vis: 26 sec/qt ). - J:' Slurry Wt: 8.4 ppg Retort: Solids: 2% Water: 98% ,-. . .::~ ....; . " ' :X":~- r ;:)0 '. ~O; 1 0.5 : ::0Q. -" o ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ (~ ~ ~ ~ ~ ~ ~~ ~~ ~ry ~~ ~<{3 ~ry ~~ ròç;s rò~ ròfþ ròtf- (!\~ ~~ ~fþ ~~ ~:? R)ry R)~ R)Y ~l~ pjry pj~ ç5ç;s ç5~ ~~~~~#~~#~~~~~~~~~~#~~~$ Page BPM TIME Pump Pres 1 o fJ'J () :Þ Z z m t? o tJ --I ¡.....\ <:> N <::) c::J ..¡::.. -- INJECTION BY SWACO NO ANNULUS PRESSURE CI.,~ NJECTION P7 August 6, 2003 NJECTION WELL: RU-D1 -' :æ Q. OJ ~ ;:~~:. :~:J-~~:.? . '. - ~.. ,-. . .~.~:~ii? .I'~-~ _-: \'_>\~:<1' -;-.1 '.' ~~:f:>:~__ '. .. .: , -,:- :;'; ~~.~:~..:, ,-~, -~.,:. '-;~"'..:'-~ . .. - ---.-ç' . :,-.-' ;:-'~~ _..- ,'.- . - . .. . .:.~ . I' -." , I'~~: :'>:',\" . ~ - :- .\~' ~';:~~ ~ 2.5 . ,..... . - .~. ~...... . . . 4 ~, j- -~.. . " . .. ...;.........." .. - . ....":.. ;:~ ~.. ?'3.:;'i.". _..~~~·:-:\~:·;~~~-~.~'.~t-~4:~·~ Recorded Pressure est Irry VolumE mulative S 3.5 3 2 ; ; ~ - . 2674 bbls bbls , . . 0 I~' :-'. -,- -, ~ 'A ~. - ~ .. .'V~:::'_ -..: ~ '. - .£' . ,:,,\;0,:,59°0 :~<[;: ' ~.:.','.:'.'.;".~.',~.:t.~.'Fl~50~,~.. \:'?~5! _. 4", }'. :..~.>;:- " i;J~-9' .0'-:': ~;!;t '., J :, f/li ~OO},: ~. - .~ ~ . ' ~j,;:!i ". . " ':.'\;000, ~.:r:' , ::'X~500 ~- ~'-'.j . ~..': : w a:: ~ en en w a:: Q. ",1' 185,511 olume: i;~090 , 1.5 ~ Work on Pump 26 sec/qt Slurry Vis: 8.4 ppg 2% 98% Solids: Water: Slurry Wt: Retort: 4, :- -' 1 ~ 0.5 o 3:01:12 4:01:25 5:04:52 6:05:06 7:05:26 8:05:42 9:06:01 10:06:21 11:06:38 12:06:58 13:07:19 14:07:37 TIME Pump Pres BPM Page 1 . ._~.; :..~ - ¡ ;~:;§,: ,~. 1,:. "f . .~ . L ~.:-..;- ~::-.~. . ~ ~1~[~~j;: : 500 0.00 500 : : ., :::~/, ~-J : ;, :~:T~;~;.~~1JL -, :.. ~.-: ~I :, ' ",;~~:';~. o 0:00:26 1 :00:43 2:00:59 w (j :Þ Z z m a o CJ --J, ~ o ~ C) ..þt .~ INJECTION BY SWACO NO ANNULUS PRESSURE CI.~ NJECTION P8 AUGUST 7, 2003 ~ :E 0- m 4.5 3.5 3 2.5 2 4 ,----' -. " ., ~..-~., .:.~";._\.;. . - :-'.~ .. -; -0. ~:;.: ~ - ... r ~_". . .1'. "I .,.- '~. :<~~:,,:.:}:'~,.: :(. ~'- '~:c-/,,\iY!';;-~'- . _"", '::-~~~!(~':r:? ;.(-(~~j::(~~~~: ~ ~-' f7-~:~)~~~:' "; ·._r..-..~.,.._ - -=. ;--' ;,'~-' .:~. . I -: . .\. ~ '. 1.: -.- _ ~. :~,~·¿·;::f}:::· -';"". ~ ::~~ ~ '.';:..~~: ~:~, --.- .'---:~:; .'.- ~~.,; :;: - -.....!, .-. ,'.' -: ;~~~.:.t' .~- . .. - :- :-, . ....;-..~~= '-<' .':,:,,' "~.: '~:.::' , ~~~~- ~~.t{~·: .:: J. . -. - ,... .11' ..~._. '.-. . . . .- -'= ':·-I~~~~~-..· , ~L. .. . "I' ~.~""- .-.....:-.-.. '" - . 5207 bbls 90,718 bbls Slurry Vis: 26 sec/qt INJECTION WELL: RU-D1 Recorded Pressure - ~O~1 p~i 1:" ::~>,:_:: ~ tll~~~~~~~ :i-f~lt2';;!~:~'-' ,: '.:~-2-;'~it_~>,:: ¡.- -':,:-;.:~?; Slurry Volume: - ::~,;,-~ Cumulative Slurry Volume: " ,. 2~O.~ w 0:: ::> tn tn W 0:: 0- 5 1 1 i .~: Slurry Wt: 8.4 ppg ~" Retort: Solids - 2% Water - 98% Ä)O 1 :"00 ~ 0.5 o ~ 0 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ b ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~~~~~~~~~~~~~~~~~###~~~ ~~~~~~~~~~~~~~~#~~~~~~~~ ~ ~ ~ ~. ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ TIME Pump Pres BPM Page 1 ;'00 fJ) (') » z z m ....... t__,-.-:A- o C'? -{ ~ o N C) o ~ 00 (j :Þ Z Z m t? o (J ~ ~ o N c:J C) ~ '- C~I·.__ INJECTION BY SWACO NO ANNULUS PRESSURE 5410 bbls 196,128 bbls Slurry Vis: 26 sec/qt I I I I I I I I a" ~ Q" ~ ~ ~_~ 9.::> ~ ~ 6. ~ :\ ~ ~ ~ a" ~ \X Q> ~ ~j:) \:) s:5~ s:5~ ~\Ç) ~'Y ~~ ~.:y Q,':5 Q,'Y Q,~ Q,:J c.:s~ c.:sl} c.:stf- t;;.':5 t;;.~ t;;.~ t;;.tf- f>r.:;J f>~ Ý.5~ f>:J 9:)~ ç;j':5 t.;,':5 rr,\Ç) ns~ t>.~ Vj<? ",<? q;<? oj<? ~ç;j<? ~~<t;> ~rr,<t;>. ~ns<t;> ~t>.<r} ~<ò<r} ~Vj<r} ~<r} ~q;<? ~oj<? rt><? rvt.;,<? r¡,rr,<? INJECTION WELL: RU-D1 INJECTION P9 AUGUST 8, 2003 LOOO Highest Recorded Pressure - 3769 psi ~;~r_ --- 4.5 - -~!.l~It~~.'-»""'-~~.M:':&- , ~-;çri.\.-~^"I1......, v....'v~rJ.\:~- 4 .~r~ ..,,~ ~"...J~.. "~,.",,,\t'" -, ... 30e:> w 0::: ::J en en w 0::: 0- 45U> I ~OCO I I Slurry Volume: Cumulative Slurry Volume: , 5(,,0 Slurry Wt: 8.4 ppg 'OC 0 Slurry Retort: Solids - 2% Water - 98% 5(,¡0 I I ~ i TIME I-Pump Pres -BPM I Page 1 - 3.5 -' -3 - 2.5 :E 0- m -2 - 1.5 - 1 - 0.5 "-' o ~~'-. "1.... ~;...~ .. .I'p, . ~ , ~I'i~'~ ' " -;-(~~\ t~·:,·- ::~~ ~ -. ;:.~ : ~. . ..' -- ...~-;-:: :.: ., . ", -~ . .':. '. ' 2 ~ O(r-l ; ',\_. . : )7::,'::~:~:~;::.~ 2 00;, ;'.~:{;;}~;:: . :,,'\~'~'. - . 'r' . 1- '.. -~ -.~ INJECTION BY SWACO NO ANNULUS PRESSURE Ct, _.-' NJECTION P10 AUGUST 9, 2003 - ~ 4.5 3.5 4 3 \ -- -.;- . _:., - ~. -< 2·:\~~ . '. ~. .. -.'- , ~ ".J'. . ., ~ " .... -.:- '_: ".;" ..:..:. ..... I'. ',"_ - - . . . -";;"'1 -w·' . , ~ ..~...',~ :-~¿<-'- ~ .,~'-~::~,'~ ...... =', . -:--- '.. ..\ ....- ~~'~i~~y^, .: ~ .:. ,...··-r.....~I.~:.. .-.~I_ -'. . , , .-'" . --. .' - ~ NJECTION WELL: RU-D1 :i Q.. In 2.5 2 .5 .- 4523 bbls 200,651 bbls Slurry Vis: 26 sec/qt . ~~ ';~;~ ..~.~.~'; ;': '.~ ~ . .:!,If. ~'.._. " - Slurry Volume Cumulative Slurry Volume . Slurry Wt: 8.4 ppg Retort: Solids - 2% Water - 98% .~ 1 0.5 o ; ~ ~ , ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ , 2> ~ ~ ~ ~~ ~ ~ ~ ~ ~ A~ A~ A~ A~ ~ ^ ~ ~~ ~ ~ ~ ~ ~ ~" :,' :," ~" ~" ~" ~" ;.\" _\. _\" ;.\" ;;v' ~. ;;v' ;;v" 2>' ::"J" ::"J" ::"J" N" ~ n~ ~ ~ ~ ~ ~ # ~ ~ ~ n~ ~ ~ ~ ~ A~ ~ ~ ~ v ~ , ~v ~ ~ ~ ~ ,\ ~ ~ ~ -¡- :-." !,", ~;~:...~.:~- :~·,::~;;j:~\~'~1;:~·;~ I': ,:..:, -'-: '-:1 ,.- '~~~~f{) }T~f~;·;. '\, ;;;¡1~i':~' ,~~i' ,;}!¡í~i,~n ""1' - I .:.... ~~:;. .J. . , :t-öo ¡ ~OQ w a:: :J en en w a:: Q.. ;ii{i~~\:~:' -;, ' " ~O,O: o BPM TIME Pump Pres 1 Page (J') (j ~ z m a o CJ ~ ~ o '" ~ C) .þ. ~~J INJECTION BY SWACO NO ANNULUS PRESSURE C\ '-' RU-4A INJECTION #190 AUGUST 10, 2003 INJECTION WELL: RU-D1 ~' :æ Q. CD 4.5 3.5 2.5 2 1.5 4 3 1 :~~... __:.:,-'_. :: - ~ ,- .' I- 4213 I"~ ~ .' Start Post-Flush @ 23:00 J , . '. _~ _ ¿t v"'"; Recorded Pressure 141 bbls 30,632 bbls 1325 bbls 201,976 bbls Slurry Vis: 35 Water 88% Highest psi Volume: , ::.,:;,:::~,;,y'l..~'o:?~: ~B~~l',; , ,~,.,. ..-' ,..,'~'~.~~ "'12~- ...... . , i::~~~:~:t{, "¿' ~~~-'r:"" "!;ft'~''''L,,;~\i , ::>J~~~;,~~:'-;!;::~>:~~-~' , . _', ::,;~~;,~r~;_>.~, :;>, L." ., '~.¿.:i¡~ ,: <, S~awater Volume: _:'~)::~~':..'.o ',~ Cumulative Seawater ,':1, '..,'- - ~ .... (' .-" .;.. . : , .. '",~~1 ~~".:~~~, . ,-:"-:-;::(t~{~·~·· Slurry Volume: .·.:1Jf~~ :1:~~I::e :.I~r~ Volume: Retort: , , ;~,·~::~-t-~~, .:.\-:. 1.: . "'~':" '.~ :~-'. \~ -:: ~ ~F : ·.··;~~1·j;;~<f'/~ · ,f~"'; - , ø.'- ~ -J I ;;~ dfi ~ ~ " '. " :·'1'-" I.... . , . - ~. :' I.J~ _..-':.... : ... 450) 350 J. 3004: 100J 400J 200) 250J 150-) w 0:: ::J en en w a::: Q. ~ 0.5 ) I 0 ~~~9~~~~~~~~~~~~~~~~~~~~~9~~~~~~~~~~~B~ ~'? f!!Jn¡3 ~'? tyjOþ (6~ njt?- ~~ f!!J. ~. tyj. (6. nj. ~''nf.~ t:;.~ t;;.r;;5 t;;.~ t:;.~ t:;.~ t;;.rp t:;.f).; t;;.rp t;;.'? t:;.'? t:;.'? t:;.Oþ t:;.~ t;;.tr- t:),.~ t:;.. t:;.~ t:;.. t:;.. t:),.. ~~ ~':J ~r;;5 ~':5 f>t;- ~f).; ~'? ~~ ~~ qj~ qj~ qjf).; qj'? qj~ qj~ cfJ~ cfJt;- ~f).; cfJ· ~tr- cfJ<,¡3 ~':J ~~ ~y ~n¡3 ~tr- ~<r) ~':J ~~ ~y ~n¡3 ~tr- ~<r) r(,':J r(,~ r(,Y r(,n¡3 r(,tr- ~<r) ~ç;s ~~ ~'Y ~Oþ rst?- ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ TIME Pump Pres BPM Page 1 10% Oi Solids 2% 50J YJ () :;> Z z m t'J C> CJ -1 J.-.,\ '0 ,....., C) ~ ..þ. INJECTION BY SWACO NO ANNULUS PRESSURE Ct.~ RU-4A INJECTION #191 AUGUST 11. 2003 INJECTION WELL: RU-D1 ~ .~ . I , -. }-;"I-:' _ ...: ',,;- -," - - . -= ,~. ....:- >'~~.,;.-.~ ,,' - ."' 3 5 -.: ,:~lr- !::'.' - . _:;: -'~"j' . ". _.1., :. .: . ,'. -~.......: ~ . :. y- .,.. r~:"" .-. .'~~. ;:>: l~: :~:~ 3 :71 ;:~ t?:': '~~.' ::;\ 4 . ~ -.- I:'C- 2.5 ¡-ro,'":""=".- ...;;;:,;- ~I !:~:::':' ._- !~. ~ -':":'1 ...._ _:', ~ -š:;-' - (. '0;.;. '.- . ,........ ..' .'~:~: -'}·;.f:"~~;.~ ~,.- ';'.:.:- ~,~;.:,,¡~~~. " :: .. l.....:.! ;: :_:"T~;-~>~. .::.~ .-~ ". . ~ .!:. ";. .," ,:+?'~' - ~~:~~~~¿f:~ , _: ','1; - , ; '\..:-:.. ..~." .. <-., '~";r-" t. - r 3889 psi r' t Recorded Pressure 12:05 , - ~ . :', ot;". -~.. ~1~;~: --, , ':}¡~: y)é-:¿;*¥.~i';~:;.: ... ·..·~·"'~·;·Î'·· "'".- Highest ::E 0- m ~2 1.5 - ;, -" ., -' -, 153 bbls 30,785 bbls 126 bbls 202,102 bbls Slurry Vis: 33 Volume: :::¡~~/",~-;:~:: Cumulative Seawater ~ ~-"::!;.~~~~::~ ~:_~-}~f.1.~~~ Slurry Volume: ,,(:-~-_~. ~_ Cumulative Slurry Volume: :;:;;'!SIUrry WI: 8.5 " Retort: Solids 2% .....\, -~J_ :.f ;;·::.:;~~:~;;:~{~:,~i:: ,:," '.' ,. ":-;~,'L:.i""'" ,\-.!I"'>'" ",( .. - - ~J.r.-~-~";¡" , E>,{r;~i¡t~lr}j': ¡'" ·:;.;}ft,~tr;:; '·...1 . - - "';.; ;._;:J~;t{;;c- ~.~ .' ><:·U;:~!/,~,:~;~ : , L . I . ! ;':~:_. t:Y: .,,45GO. , ~:'?::; ;:'" - ;;- );)/:- ,:>, 1.~ ~~ '~9~O;~ ...:'.... . . ~ I . _ -. J ' .' ". -õ ~. ,,. .' ~. . t~:35ho':;~ .~99q . I' ," 2500';-" r. ".r,: . I I 209°, 1,500 w 0:: => (/) (/) w 0:: 0- ~ 1 0.5 o 12:47:28 12:37:26 12:27:22 12:17:20 11 :57:14 12:07:16 TIME 11 :47:11 0 11:17:05 11 :27:06 11 :37:09 BPM 1 Pump Pres Page rJ. (""\ ~ Z Z ~ C) n --{ ~~ <: f-...;) c:J c:J .þ, 96% Water 2% Oi ~ ,- ,,~'~'''.'~~:. '" - 'I , \:"- ;~t5:i: ~, ,';',- ~ ~'i< ~ .,". , 1000. ,500 4000 3500 3000 2500 (1) ~ :J 0 2000 0 (1) ~ 0.. 1500 (J) (') :Þ z z m C) o n --{ ~ o r" c:> c::> .þ >--~ ,~ Injection #192 Injection Well: RU-D1 8-13-03 Injection by Swaco No Annulus Pressure ':.. .,~;-.-¡-- :-.. -~ .:'--~":.:..,~,: ~.~~",::-;;';\:;,;,:::~"--:' ;'._:. ~"--'-;:.~---~ --.' '.c 3.5 , . ',' ::Jjigt:¡est pressure~~1()O,:p.Si, .' . . ~ .' . .. '. ....;;';;,'f7?/·'···· .. - . . . - . . . - 2.5 500 Seawater Vol: 0 bbls Cumulative: 30785 bbls , - 1.5 Slurry Vol: 238 bbls Cumulative: 202340 bbls 1000 Vis: 51 o I I· I 'I I I ···1 -I I r I· fl I I f 0 8:028:038:048:058:068:078:108:158:208:258:308:35 8:40 8:45 8:50 8:55 9:00 9:05 9:10 9:15 9:20 9:25 9:30 9:35 9:40 9:45 Time I-Pressure -BPM I -. 3 '~ 2 :E 0.. OJ ---- 4000 3500 3000 2500 ~ ::s UJ UJ Q) - 2000 Q. Co E ::s Q. 1500 1000 (j) o :Þ z z m o C) CJ -I J-.l o r"-' c:> c:> aþ. 500 "'~ Injection Well: RU-D1 '" / ~' Injection #193 September 7 I 2003 NO ANNULAR PRESSURE - ...... 13764 psi - Highest Recorded Pressure I / Injection #193 was rain water only. No Pre-Flush or Post-Flush was required Rain Water Volume: 643 bbls Cumulative Rain Water Volume: 643 bbls Rain Water Weight: 8.4 ppg Rain Water Viscosity: 27 sec/qt Cumulative Seawater Volume: 30,785 bbls Cumulative Slurry Volume: 202,983 bbls o I I I I I I I r,.t?~ r':'~ ró<t¡J~ ~\¡)~ ~~~ ~f> ~fþ~ ~f ~<t¡J~ 'Ò\¡)~ 'Ò~~ 'Òf> 'Òfþ~ 'Ò~~ 'Ò<t¡J~ d;\¡)\::) r;.~~ d;f> d;fþ~ d;~~ d;<t¡J~ ~\¡)~ ~~~ ~çf ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Time I-Pump Pressure -BPM I 4 3.5 3 - 2.5 2 :E Q. co 1.5 1 0.5 .---- o 4500 4000 l .1:.;. Z Z m C1 a C? -I f-4 ~ f'-' C=> c:::::> ~ 3500 3000 ~ ;j 2500 In In (1) ~ Q. C. E 2000 ;j Q. 1500 1000 500 - <~' Injection Well: RU-D1 Injection #194 September 7, 2003 .' ,.' .'", ~ I ... 0'0" ~··;}:'~';#;!:fi~j.i1[f~1~~~1\~t§:~,~..··',:: ',:~·~J.;C:·~'f'+~~';;t¡;:;'::~'·' . ,." ',~,)}.~\:~~}/,':;."'. ,.~:, ''lSta~..~~~t~FIUSh at22:56 '.. . ~ " .-, . ," '. . I' I, . . ~ .., ..... '. - 'I" ,.. ' '.' . . :r; . '. '. ;. I . ., , - -.' - ,'.. '. '.". . " " . ,.. .::: <':,':)~~~f~;;:: , ..' ~; ": , . . , :'1'" ~ . ~~ '~o >:~n:1~~;::};::>:"?,,"o - '. -.-.:"~' -.' ~~_::;~"-...-.':>'-' -.". -.' , , . _. ..... 0' 'i f:' . ,.W o , ,o,:::~ ' ° ~:.._,:: :", ", ,,~.., ....., ; . " ~ I NO ANNULAR PRESSURE NOTED 14125 psi ~ Highest 'Recorded ° Pressure I~<"':; 3.5 No Pre-Flush was required for Injection #194, Injection #194 was started 1-1/2 hrs after Injection #193. Injection #193 was rain water only o Seawater Volume: 165 bbls Cumulative Seawater Volume: 30,950 bbls Slurry Volume: 218 bbls Cumulative Slurry Volume: 203,201 bbls Slurry Weight: 10.1 ppg Slurry Viscosity: 55 sec/qt ° I 21 :40 21 :50 22:00 22:10 22:20 22:30 22:40 22:50 22:56 Time I ° I 23:00 23:10 23:20 23:30 23:40 23:50 I-Pump Pressure -BPM I '-..- ' 4.5 4 -- 3 2.5 :i Q. al 2 1.5 1 .-- 0.5 o (j) (J » z z m o o CJ -I I-' ~ ......, c::J c::> .þR, 4500 ~- ~' Injection Well: RU-D1 Injection #195 September 8, 2003 NO ANNULAR PRESSURE Start Slurry 4000 _ at 10:30 - ' 14090 PSI - Highest Recorded Pressure ~ 3500 3000 (1) .. ~ 2500 t/) (1) ... 0.. Q, E 2000 :J 0.. 1500 1000 I -~ ~ Start Post-Flush I at 17:40 Seawater Volume: 165 bbls Cumulative Seawater Volume: 31,115 bbls Slurry Volume: 1359 bbls Cumulative Slurry Volume: 204,560 bbls 500 Slurry Weight: 9.8 ppg Slurry Viscosity: 55 sec/qt o I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 10:20 11:10 12:00 12:25 12:50 13:30 14:20 15:10 16:00 16:50 17:30 17:55 Time I-Pump Pressure--SPM I --~/ 4.5 4 3.5 ~ 3 2.5 :E 0.. OJ 2 1.5 1 ---- 0.5 o --/ 2.5 :æ 0- m '~ ~- I-Pump Pressure -BPM I Time o 21:33 I I I II I I II 20: 10 20:50 r I I I I I I 17:40 18:30 16:00 15:10 14:20 o " f'j I I I i 12:40 13:30 0.5 Slurry Weight: 10.0 ppg Slurry Viscosity: 50 sec/qt 1 Slurry Volume: 1827 bbls Cumulative Slurry Volume: 206,387 bbls 1.5 Seawater Volume: 176 bbls Cumulative Seawater Volume: 31,291 bbls 2 j¿;,n~{:;:~:~:_f!~[,'~;(43);,;'~;?~>:;'~;:~;i~:'d.: . . ..,.'. I Start po~t-FI~~h at 20:47l.' '.' .:.', 3.5 . ~ ~ \ _ 3 NO ANNULAR PRESSURE Injection #196 September 9, 2003 Injection Well: RU-D1 ~' 4500 4000 3500 3000 (1) .. ~ 2500 (/) ~ 0- C. E 2000 ::s 0- 1500 1000 500 en (") » z z m a o n -( J-d- o ~ C) c::> .pa. ---- 2.5 :æ 0.. m .~ I-Pump Pressure -BPM I o 011 4:52 5:00 5:10 5:12 5:15 5:20 5:30 5:40 5:50 6:00 6:08 6:10 6:20 6:30 6:40 6:50 7:00 Time 2 0.5 Slurry Weight: 10.4+ ppg Slurry Viscosity: 48 sec/qt 1 Slurry Volume: 210 bbls Cumulative Slurry Volume: 206,597 bbls 1.5 Seawater Volume: 164 bbls Cumulative Seawater Volume: 31,455 bbls , , 3 71'~""--,:,:, >-" . ". .. ~. . . '. -" . ".', -.... . - . -" . . . -. .;:i~;!lfS(·;~:!;';i::;!m~;rY'·' ~".;,. .. ..' . ,>' ""-''''x_ '>-'--.'.'~.,,, "-,,,, - ,'- ,,' ""I Start Post-Flush at 6 081 ,:':,,\\~t'h~7-~Y/'~;,;:<;')~:,::'~ / ,:)i:" , . 4190 psi Highest Recorded Pressure ~ 3.5 , " /'_., , . . .. . . . . '. .,. :' , 4 ....'. .-.... .;-: -;." "-~" " 4.5 . . NO ANNULAR PRESSURE Injection #197 September 11, 2003 Injection Well: RU-D1 ----- --~ 4500 4000 3500 3000 ~ ~ 2500 en ~ 0.. C. E 2000 :j 0.. 1500 1000 500 .'-' \.... £ z z m CJ o C") --I ~ ~ ,......" c:::> c:::> ~ :..1 ' c » z z m o o c:> -( ~ ~ r~ c=> C:) ~, '- "--" Injection #198 September 11, 2003 4500 Injection W~I.,I: RU-~1 ~"I~~~' I ~ I\.' " -' . 4000 3500 :,' 3000 (1) '- ; 2500 tn (1) '- c.. E 2000 ~ c.. - _I·"....··'. ;,'q 3850~,~1 ~ ~,i~he~~Recorded Pressure '.: 0" ~...I.:_.~_A~.. .<'~i>-~;:~::;...:-..: '~;:, -::: ~1."";' ~ , . ,.....', -0. . ..~:,.~......~.;. ~ ~.,'..-- ~ .' . ~~';"";,,;.' :. . . ','''l /Jr:;.:.~.. ~~ " :: . " ",', "', ' -".",",~. -:',;) , . .'t....~'.~ . ..-. . "";,-:,\:",:,,<,.',,,,::<,"',' I . ~ " ~....... ~ - NO ANNULAR PRESSURE 4.5 o "II I '" I I I I' I"" .....<:> ~Ç) "Ç) ('\Ç) n..Ç) .....Ç) ~S:> ~Ç) "Ç) ,,<:> ('\Ç) ('\<:> ~.~.~ ......Ç) ~.~~oS:) ~.;..No$:) ~.;..~oÇ) ~.;..('\'.R:> ~.;..~.~ ~.;..t0oÇ) ~.;..~~.S:) r..;,oN.$:) Ç) ('\Ç) "rt~ "njY "oj 0 "njoV ,,~.;.1 "nj~ "oj:.) ~Y ,,~. ,,~. ,,~.v ,,~ov ".;.;.1 ~~ "..;.....) ...;..)'-J...;..) "';'..1 v "';'..1;.1 "';'..1V' ...;.~"..1 "....;'-J "VS~ "VS'v Time I S,tart Slurry at 14: 15 . - II: ........ ·,~(·~t~:t-"?' . ',:.", . . . .." - '.~ ~ <-:" . ,- FOC - KPC (Kustatan Production Facility) pumped the Post-Flush for Injection #198. KPC injects produced water into RU-D1 . _ >. _~... . _:. r. 1500 Seawater Volume: 34 bbls Cumulative Seawater Volume: 31,489 bbls 1000 Slurry Volume: 449 bbls Cumulative Slurry Volume: 207,046 bbls 500 Slurry Weight: 10.4+ ppg Slurry Viscosity: 50 sec/qt I-Pump Pressure -BPM I '-"' 4 - 3.5 '-- 3 2.5 :æ c.. OJ 2 1.5 1 0.5 -/ o (f) () :Þ Z z m o o c-.> --{ ~ o r-..:> C::J C) c.þ. - ,-,' Injection #199 September 12,2003 Injection Well: RU-D1 4000 3500 3000 2500 (1) - ::s C/) C/) £ 2000 Q. E ::s Q. 1500 1000 I Start Slurry at 13:30 /- ý" ~ ... NO ANNULAR PRESSURE I 3405 psi - Highest Recorded Pressure ¡ 3.5 .,/ 3 ~sært :OSt-FIUSh at 18:10 I o I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I (::) R) ~ ~ ~£) C ~ R) ~ s:::> ¿,.~ c ~ R) ~ s:::> ~£) c ~ R) ~ ~ ~£) C ~ R) ~ Ç) <-.~ C (::) R) ~ s:::> ~£) C .~ .rç .~ .~ ."J t..:<::5 t..:~ t..:rç t..:~ t..:~ t..:.J ~.:..<::5 ~.:..~ ~.:..rç ~.:..~ ~.:..~ ~.:...J r.:..<::5 r':"t>;;. r.:..rç r':"~ r':"~ r.:..·J Â·<::5 A'~ Â·rç A'~ A'~ ""..J 0:..<::5 o:..~ o:..rç o:..~ o:..~ o:...J ,..;.<::5 ~'~'~'~'~'~'~'~'~'~'~'~'~'~'~'~'~'~'~'~'~'~'~'~\'~'~\'~\.~.~\.~.~.~.~.~.~.~. Time " .. "- Seawater Volume: 200 bbls Cumulative Seawater Volume: 31,689 bbls Slurry Volume: 901 bbls Cumulative Slurry Volume: 207,947 bbls 500 Slurry Weight: 9.7 ppg Slurry Viscosity: 67 sec/qt I-Pump Pressure -BPM I "-" 4 -" 2.5 2 :i Q. en 1.5 1 0.5 ~ o '-- ---- - Injection Well: RU-D1 Injection #200 September 14, 2003 NO ANNULAR PRESSURE 4000 3500 4 3510 psi - Highest Recorded Pressure 3.5 UJ (j :Þ Z z m tJ o c-> -( -! C) r-> c:> c::J ..þ. 3000 -7 1 3 -' " , ' 2500 2.5 Q) ~ ::I ," - . ':0;- .,_~_:.:: 5.:"' ..- "' ,..' f/) f/) :E Q) -. ~ 2000 Q. Q. C. m E Seawater Volume: 189 bbls ::I Q. Cumulative Seawater Volume: 31,878 bbls 1500 1.5 Slurry Volume: 720 bbls 1000 Cumulative Slurry Volume: 208,667 bbls 1 - Slurry Weight: 9.7 ppg Slurry Viscosity: 65 sec/qt 500 0.5 ~ o 1" I I I , I I I I I I· I I I I I I , :,' I I' .,' 0 ~~ð~6~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ <tjY <tj:J <tj:J <tj:J <tj:J <tj:J <tjY <tjY <tjY ro':3 ro~ rory ro~ rot?- roY A\.':> A\.~ A\.ry A\.~ A\.t?- A\.Y C(j':3 C(j~ C(jry C(j~ C(jt?- C(jY C6':3 C6~ C6ry C6~ C6t?- C6~ C6Y ~,5?~çS~~çSry~çS~ Time I-Pump Pressure -BPM I 4000 3500 "=o~~ ---- Injection Well: RU-D1 Injection #201 September 16, 2003 -',' '''1:;;' oS':'" .:~.:.__.- '- 't~~·::~·\o~ . ~ -, --:-;-:It¿~Kf;: ..-.:. .-.... : ., -' .", .... .". -' _.~ u . 1'.- ~".. '.' .... . " ' w'" :.. ',Ph :, ' Ó '~'" .-. - -', .. ::'~v ""}':',,';. .,.. .' ">'<~::}~:rj:;'~;',·;':" ' Sta~SIU;~ at 10:~5::e1,:~r.? .... 3000 ~ 2500 C1) ... ::J tJ tJ C1) ... 2000 a. a. E ::J a. 1500 (j) o :Þ Z :z m o C') r:J --I J--.\ ~~ ~ c::> c:> .þ. 1000 . . .,. ",. -' I': FOC - KPC (Kustatan Production Facility) pumped the Post-Flush for Injection #198. KPC injects produced water into RU-D1 Seawater Volume: 21 bbls Cumulative Seawater Volume: 31,899 bbls 500 Slurry Volume: 302 bbls Cumulative Slurry Volume: 208,969 bbls Slurry Weight: 10.3 ppg Vi~r.n~itv· fi? ~pr.lnt . . o 'I; , 11:15 11:25 Time I 11:35 11:45 I 10:40 10:45 I 10:30 10:35 10:55 11:05 I-Pump Pressure -BPM I NO ANNULAR PRESSURE - 1 '- 0.5 11:55 12:05 12:15 12:25 12:35 -' 3.5 3 2.5 -- :E a. r;a 1.5 --- o (/) c: » z z m CJ o C-) -c -Þ- ~ "-' c:::J c::> .þ> -- ~--; RU-7 INJECTION #202 INJECTION BY SWACO NO ANNULUS PRESSURE INJECTION WELL: RU-D1 September 16, 2003 400 ),} ....~~i0'i~Ìfg~?[¡~~;,"",:,-':, ~i~h~~.~;~~d~~:P·~~.~~~;e~366ò psi 350J, ~ - -.'~..~ "........;.,'..;: , ' , .' .. .: .\.,.. ~ :..:.. '. - . - ;. '~.:.""'. . 300J ,~ '. t', ~.' ~. "',; '~.:.'. . . þ ,~~ ::):~_~~,.~.t<~:·,Þ:,,:þ'~~::-~~·'::·"~·~~~}'~:~'./.!.~~;~~ø;.~...~:~ -.~:.~' ~:-~",~r'<""~ . ','" . ... L ~:'."~~;:~ >. II~;~)"~ . - . OIL..;.. . '. ',j." "::. .'~·:·"-.~·~~·.:~.}.:_·~I;~~I ~~. ',:. ." ,," ~ . -': ;~, '..,Y,','¡..! '. :,.. .., .. . . ','," ,"-, . , . '. , ..~. " . , . 250) ;," ,...., " ....- ,\ . .". ..' .." '.: ~''; '" . ,"" : - ....: .. ~ . ,. ",- ,- . i. -, .. .1'.. ~ J, I w a::: ::) U) 200) U) w a::: Q. " ~.' . 1 . ." ':. ".". . ~. . , , - .' ".' - . ~ . ..; . . , ' " , Seawater Volume Cumulative Seawater Volume 141 bbls 32,040 bbls Slurry Volume Cumulative Slurry Volume 943 bbls 209,912 bbls Slurry Wt: 10.3 ppg Slurry Vis: 51 sec/qt ) I I II I I I I $~~fi~~fißßß~$A~A~~~~~~~~~~fl~~ ,,"J I\."J ,,"J "", "'" "", ~J ~J ~J ,,'V ,,'V .....'V ", ......' ~. .....CÒ· "Cö· .....CÒ· ,,~. ,,~. "Q). ~. rps. ",'-1 1');,' ",". TIME l- Pressure - BPM I "-" 3.5 3 .~ 2.5 :E Q. OJ --- o (f) () » z z m o <:) CJ --1 J-..1 o f"...:1 c:J C) ..þ. ç-~ 400Q 3500 3000 2500 w 0::: ~ ~ 2000 w 0::: a.. 1500 1000 500 ,----' INJECTION WELL: RU-D1 RU-7 INJECTION #203 SEPTEMBER 17, 2003 INJECTION BY SWACO NO ANNULUS PRESSURE ~\\/- I Hi~hest Recorded Pressure - 3720 ~ n~1 1/ -~~ ~ t I Start Post-Flush @ 12:00 / Start Slurry @ 05:25 / Seawater Volume: Cumulative Seawater Volume: 162 bbls 32,202 bbls Slurry Volume: Cumulative Slurry Volume: 1246 bbls 211,158 bbls Slurry Wt: 10.3 I Slurry Vis: 50 o I I I I I I I I I I I I I I I I ~ ~ ~ ~ ~ ~S;) ~ ~ ~S;) ~ ~ ~S;) ~ ~ ~S;) ~ ~ ~S;) ~ ~ ~ ~ ~ ~£) ~ ~ Ç) ~ ~ ~ <ó~ <ó~ <ó~ <ó'Y <ó~ <ó:.J ((j~ ((j~ ((jY ,,~ ,,~ "y q¡,~ q¡,~ q¡,Y oJ~ oJ~ oJY "çS~ "çS~ "çS<? "",~ "",~ "",:.J ,,~~ ,,~ry ,,~~ "rs~ "rsry "rs~ TIME 1- Pressure - BPM I ~.~ 4 3.5 3 ~ 2.5 2 :E a.. cc 1.5 1 0.5 ~ o ;'£: ( , þ z z m a o c:> --I ~ C;:1 ~ c::> c:::> ..þ> '-.--/ RU-7 INJECTION #204 INJECTION BY SWACO NO ANNULUS PRESSURE INJECTION WELL: RU-D1 SEPTEMBER 18, 2003 450Q\: -:.::_~-: ;~':. ~._:_ ::,. ~:,,;:~.,- ':1 ~.~ ~:.-.-:.;'~.."'''~-'-~-=:7<-'~~''' ," £~<;.;:._~-,,,, :-~"~~';'¡ ::":.:::--_.~:-,,:_.:,::--..~:,~??!1,:-: - _:_""i"..-;-t."_:'..., -:....;-~ '.'.-~:;.' :;:.;." >; .:.:.! -.--.::;':'::. 3500 ""'}\:~?<-:;,:, 3865 psi - Highest Recorded Pressure ,:~ ~':~::~'.':'.', >:£~"Î"~;? .. ;~.;' ',' ~ ,.~:;. ....'.. , ";:,:',:~:,,:,:,:,:,, ,.'.." c;.,", ",:'.', ".,~">:~"'::::f;';:"',·::,~:<;':,·:,~;~ '·-:-"'-·-'-·0·- 4000::'·', :' "'~ 3.5 , - 3000 ".. '.- '. ,./. :,;:,,~ ',/". - 2.5 -3 ~ 250Q'". :J tn tn W a::: c.. Seawater Volume: . " Cumulative Seawater Volume: 181 bbls 32,383 bbls Slurry Volume: Cumulative Slurry Volume: 1246 bbls 212.404 bbls Viscosity: 50 Water:76% Solids:14% - 0.5 500: 01'1 I I I I I I .~Ç) .f>;)Ç) .bÞ .<:><:> ."Ç) .f>;)Ç) .<:>\:) .~\:) .f>;)\:) .<:>\:) .~\:) .f>;)\:) .<:>\:) .~\:) .f>;)\:) .<:>\:) n'''''\:) n'':>'S::> n'<:>'S::> o:.."'.\:) rv~' rv'" rv~' rv'" rv~' rv~' rv~' rV' rV' rV' Ç)' Ç)' Ç)' ". ". ". v v v oJ TIME I I I I I I' 0 s::> <,S:) \:) R) Ç) ~ R) <,S:) \:) s::> oj~ oj:J ~~ ~ry ~~ <¿';5 <¿ry <¿:J ((j~ ((j~ I-pressure -BPM I -" 4 -- 2 ::E c.. aJ ---' 2500 '. ' ( w a:: :::J CJ) 2000 CJ) w a:: c.. 1500 4000 3500 3000 1000 F~ ~ " J" Z Z IT! a o CJ --i 4-':- ~ (--j t:::) c:::> ~ '--- '-" RU-7 INJECTION #205 INJECTION BY SWACO NO ANNULUS PRESSURE INJECTION WELL: RU-D1 SEPTEMBER 18, 2003 3550 psi - Highest Recorded Pressure ._," . .... , , ~,. .' , .', . ".". "1"-" , _~. ,- . ~ - -.." _I' ." .' r -'t-.·· . '., ~ "'. L . ?,~,->}f0~~;":~r<::~:," '... ,", ",:;-~;~,~~,":'" " ,: ;', , , .': ,'.. ",,', :_j'¡;¡~, .'.,.'0,/"."'...,"",.'., - . - .-. .~, I .J s.tart Post-Flush @04:_~~..1 ; .-,;;-..--... , , Seawater Volume: Cumulative Seawater Volume: 140 bbls 32,523 bbls ·"4'-' .' ~;_:~I_;'~ _~'~_-'_-. - . ., ...." '" '. :. . . ~~ . . ' ~' N~,~r~~y~n,:~Q~~iS i~j~C~!9,ri, . ;... . . ' "':, " r... , ~ . . ,-": _'; .~ ~'. .' '.~:"..-: . 500 Solids: 15% Slurry Volume: Cumulative Slurry Volume: 1,100 bbls 213,504 bbls Slurry Vis: 52 Water: 74% o I (1;(111 . 1111 II I I II II I I I I I I ~ ~ ~ R> ~ ~~S) S;:),,~ ~ ~ ~~S) S;:),,~ ~ ~ ~~S) S;:) ~ ~ ~ ~~S) S;:) ~ ~ ~ ~~S) &),,~ ~ ~ ~ ~~S) S;:),,~ ~ ~ ~~S)~J;, S;:) ~,,~ ~ rj~~~~~~~~~~~YçS~çS. çSCYçS~çS~çS:J~~~. ~CY~~~~~:+\·~t'f,~CYt'f,~t'f,~(1;?~~~~CY~~~~~Y~~b(. ~cy~~~iþ~~~Y<:)~<:). ~CY<:)~<:)~<:)Y<:)Y6~6~6· ro~ 1;1; iV1; iV 1;1; v TIME 1- Pressure - BPM I - 4 3.5 3 ~ 2.5 2 :E c.. aJ 1.5 1 0.5 --- o , ' .;r-_ þ z z m o o o -I ~, Ö' f'-..:J c::> c:::Þ .þL 400) 350) 300f' ' 250) w ~ :J ~o) W 0::: a.. 150) , ' 100) 50) c__ "-- INJECTION WELL: RU-D1 RU-7 INJECTION #206 SEPTEMBER 20, 2003 INJECTION BY SWACO NO ANNULUS PRESSURE 3.5 > . ...- -- -- . ." "'. , . . . .., . ~.:.._ ." I ..J ~.. . ..... ...., .. , ·,,·;:;,tT~;<~: ':':;·d·'_~··, . ,-",... .' . ." 13450 psi - Highest Recorded Pressure l , \. -3 '- "",. ~.'- . . .' r' '. ~ -:. '. -:: :-'. ". , . ,'.... ',', . 0,"'- . - -. - .. '-. -" ." -.' ".' "...-- -." - -.. - . . - - . . . -' - . -. . . . - " '.- - -. " - -........'...- ;.- - --,' '.'.:.",' -.- ", - - . -' - - -. . - . - ". -."', .".-".- ." -'.-," ~c: :.-' . ;-" .-." ."... -; ..'. '.- -". ~ ..... ..... " ,.. ...,..... ........... ". . --'-.. - 2.5 .. , j .' . ",'... ~ . ..:' '. . . I " - - - ,I _~ ;" I Start Post-Flush @ 16:00 , ~, Seawater Volume: Cumulative Seawater Volume: Slurry Volume: Cumulative Slurry Volume: 930 bbls 214,434 bbls Slurry Vis: 52 Water: 74% Solids:15% J ... )/ ,,<:.) ~ rt:' ~ ~ ~ ~'1; ....~Ý;) ,,<S' ,,<S' ,,<S' "'" "'" t.\' , I I " I I I I I ' I ' I I I ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ <:.) ~ ~ ~ <:.) ,.;,,'Y ,.;,,~ ('I'» ('I'Y ('I'~ n:.';S n:.'Y nj~ ..;.';S ..;.'Y ..;.~, (.:.';S (.:.'Y (.:.~ ,..:.';3 ,..:.~ ,..:.r;3 ,..:.Y "".';3 "".':' " " "V "V "V ~~ ~ " ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~\ ~\ TIME I-Pressure -BPM I -- --- :æ a.. al 1 0.5 '~ o ---- 2 ~ en ~' --- ) I I I I I '1 ('T""II I I I I I I I' I I I I I I I I 0 ~ ~ ~ a, ...~ ~ s::> ...~ ~ s::> ¿..~ ~ s::> ...~ ~ s::> ...~ ~ s::> ...~ S:) ~ Ç) S:) ~ Ç) r.;.<? çS~ çSf)) çS'? çS:.J t\.~ ,,']3 t\.Y n-t.' n-n¡; n-:.J o:.~ OS']3 0:.:.J t:;.~ t;;.']3 t:;.:.J ....:.~ ....:.']3 ....:.:.J fÔ';3 rot"'þ fÔ'tf- ~';3 A't"'þ ~'tf- ~ ~ ~ ~ ~ ~ ~ ~ ~v ~v ~v ~~ ~ ~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~\ ~ TIME I-Pressure -BPM I fI r-, ~ Z z m o o C"') -( -do o ~ ~ c::> .þ.. 0.5 Water:75% Solids:14% 1 Slurry Vis: 51 1001-, 1.5 1,148 bbls 215,582 bbls : Slurry Volume: Cumulative Slurry Volume: 150r ' 175 bbls 32,879 bbls w 0:: :J CI) , CI) 200 l", w 0:: a. Seawater Volume: Cumulative Seawater Volume: , . 2.5 250 3 - I'''.. I. ~ 3.5 '".," 350 r~: : - , \.:..' :~. : .: 4 400 1;~; )~;,':'/ :'::: : :" :~:.\ ,:':, :.: ' INJECTION BY SWACO NO ANNULUS PRESSURE SEPTEMBER 22, 2003 INJECTION WELL: RU-D1 RU-7 INJECTION #207 '~ '---' 1- Pressure - BPM I F O~ (-",j c=- c::;> ~ 01 I :1 1 I I - I I 1 -'-f I ~ r "11-' I 1 "'T I -, -" I I I 1 I I - I I I I I I >-1 I 0 ~b~~6~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ <ô?3 <ô~ <ôtt- <ô~ <ô:.) ~~ ~~ ~~ ~ry~?3 ~tt- ~:.) q5~ q5~ q5ry q5?3 q5tt- q5:.) C6~ C6~ C6ry C6?3 C6tt- C6<? r:s~ r:s~ r:sry r:s?3 r:stt- r:s<? r:s<? ~~ ~~ ~ry~?3 ~tt- ~~ ~y ~<? ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ TIME 1 c:.' o -{ :r. z :z m o '--' 500 -, ,. -, 0.5 2 ~ aJ .-- '." " ".-- ""P"''-' , . "'.' "~:~'~;'.':~':" ,:"-,':' -',- '.-', ':,-. ',~", ,;' :-,,": ,~~:~;_/ >?,".' .....:~. .'. _:,'.:". - -. -. .0_,.;'- , - . . .~ ." . ,. f. - :. . . . . '. . '.':~:'.'" 11.'::. "., "'>,~: I: ' Post-Flush @ 20:50 r ' 1.5 2.5 ..'. . " 3 3.5 4 INJECTION BY SWACO NO ANNULUS PRESSURE - Solids: 15% Water: 74% Slurry Vis: 50 10.4 808 bbls 216,368 bbls Slurry Volume: Cumulative Slurry Volume: 190 bbls 33,069 bbls Seawater Volume: Cumulative Seawater Volume: -. ' " .;::L,~lt:;il¡~¡~~·'::';,,:· :"~'I~~:~!!~~?'iii~@~lî¡ii0~é;",:,;' ..... RU-7 INJECTION #208 SEPTEMBER 24, 2003 INJECTION WELL: RU-D1 ,~ 1000 2500 w a:: ::> ~ 2000 w a:: c. 1500 3000 3500 4000 ~ - RU-7 INJECTION #209 INJECTION BY SWACO NO ANNULUS PRESSURE INJECTION WELL: RU-D1 4000 3500 3000 (j') (") » z z m o o D -{ ~. t:::) "" c:> c:> ~ 2500 w a::: ::> en 2000 en w 0:: 0- 1500 1000 f 500 SEPTEMBER 25, 2003 4.5 13535 psi - Highest Recorded Pressure I ~ -4 /\ " ~ Start Slurry @ 18:40 I ,,-"j ~ - 3.5 I l Start Post-Flush @ 22:20 -3 - 2.5 :E 0- m Seawater Volume: Cumulative Seawater Volume: 178 bbls 33,247 bbls -2 Slurry Volume: Cumulative Slurry Volume 857 bbls 216,368 bbls \ - 1.5 Slurry Wt. Slurry Vis: 45 - 1 10.1 Retort: Oil: 11 % Water: 74% Solids: 15% - 0.5 .~ o I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 0 ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ ~.~.~~.~~~~~~~~~~y~.~.~~~~~~~~y~.~.~~~~~~~~y~~.~~.~~~~~~~~~~~y~~.~~.~~.~~~~~~~~~~y~.~.~.v~~ TIME 1- Pressure - BPM I -~- 4000 3500 3000 2500 w e::: ::) en 2000 en w e::: a. 1500 1000 CD (: þ' Z z m r-¡ '~J 500 o C? -~ ~ .0 r...:> c::::J c=> ~ --" INJECTION WELL: RU-D1 RU-7 Injection #210 SEPTEMBER 27, 2003 INJECTION BY SWACO NO ANNULUS PRESSURE 13603 psi - Highest Recorded Pressure l /\ \,,--/ \ Start Slurry @ 13: 1 0 / I / Start Post-Flush @ 16:20 Seawater Volume: Cumulative Seawater Volume: 167 bbls 33,414 bbls Slurry Volume: Cumulative Slurry Volume: 769 bbls 217,994 bbls \ Slurry Wt: 10.3 Slurry Vis: 44 Retort: Oil: 15% Water:70% Solids: 15% I If I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ~ 5-;) ~ ~ ~ ~ ~ ~ s::> Ç:)~S;) ~ ~ ~ s::> ~~S) ~ ~ ~ s::> ~ ~ ~ ~ ~ ~ s::> Ç:)~S;) ~ ~ ~ s::> Ç:) n'~ n'~ n·<tJ n'~ n:.';3 n:.~ n:.~ n:.ry n:.~ n:.~ n:.:.J t:;.';3 t:;."!- t:;.ry t:;.~ t:;.~ t:;.:.J ~';3 <~~ <6ry <.:.~ <6~ <~<tJ ro';3 ro~ rory rory ro~ ro~ ro:.J ~? ':\~ ,:\ry ':\~ ':\~ ~V~V~V~V~J ~J ~J ~ ~ ~ ~J ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ o TIME 1- Pressure - BPM I -..-'/ 4.5 -4 - 3.5 -' -3 - 2.5 :i: a. m -2 - 1.5 - 1 _/ - 0.5 o (I (' }-; Z ¿ fiì ¡-'1 ,"-ð c C? --f ~ ~ t~ C=> c::> .-Þ 4000 3500 3000 2500 w ct: :J (J) 2000 (J) w ct: 0.. 1500 1000 -~ ,_/ RU 7 INJECTION # 211 NO ANNULAR PRESSURE INJECTION WELL RU-D1 10..01-03 . -~1'_'·"-"· :."~~';''''.t...~.....:~..'.-'- ".~.....~~~ -.. ",_. . ,. ' ":. - _. . ,.,¡ I . '.' ,-. , . . ~ .. I. .\ ". ' ..L..~..~~ ~ .~~ . . .,". :,' .>~.,,: - , . . ,'...:;':;::~',:~:',::..'~.~"':;~:/«:,,~~,:'.. '-7:: ";:-:' .',_ " . .- .,. , ....~I. ~.~ ... ,'... .~i', :'. ~: .', ;.'~ . . . ;.'. . ~." _.' r .01' ' , ,. . ...r ....': '.~,: '. :;:.~' , .... ..,. .,. I . ., "... . ~ ',. , .. .;~~'~ .: t , (:;": ~ " ,. ... .'. ,.':-::,::<::':<' '.' ',,:, '.~ >,.' ...,.. ·····:Jhighest recorded pressure 3790 psi I ,'r ~'. . ~ ..~. _I. , , . ~ :~ '" . , "'" ',- , .-.... "''";''''~;;i'J';; .~J:'" '. i start slurry at 11: 12 '_ ., I. , ~'.:., ...... :~~~~~~ ", þ' .., .. ... ~ 500 ,........',..\......,...,:.................'.........,... . ·:"0, ."-.-. :'. - ,-;...-. seawater volume 276 bbls cumualtive seawater volume: 33690 bbls slurry volume 723 bbls cumulative slurry volume 218717 bbls slurry wt. 9.7 ppg slurry retort 9% oil slurry vis. 42 10% solids 81 % water o I I I I ,," ,il 'I' I"' I I .\:)\:) . ,,\:) .~ .O;J\:) . b? .<t:>\:) .\:)\:) . ,,\:) .,,~ .~ .O;J\:) . b? .<t:>\:) .\:)\:) . ,,\:) .~ .O;J\:) . ~\:) .<t:>\:) .\:)\:) . ,,\:) .~ .O;J\:) . b? .<t:>\:) .\:)\:) . ,,\:) ~ ~ n:,\:) . b? ~\:) Ç)\:) ,,\:) ,,<t:> .~ ~.~.~.~.~.~.~.~.~.~.~.~.~.~.~.,,~~.,,~~.~.~.~.~.~.~.~.~.~.~.~.~.~.~.~.~.~. TIME I-pressure -bbl/min I -' 4.5 4 3.5 ----' 3 - 2.5 :æ 0.. CD :- 2 - 1.5 .-:- 1 '~ -'- 0.5 o (J) () :Þ Z Z m c o '"" -..{ 1--.1. C:::) N C) <:::) ..þo 4000 3500 3000 2500 Cñ 2000 a.. 1500 1000 ~..,-~ '~ [WEll # RU-D1 RU-7 INJECTION # 212 10 3-03 '- NO ANNULAR 4.5 500 .,d··-'·'·~ - '.... .. . .' ',..>"-' , -. -." ......",~."..~. . '. -. ~ ,'.. . ,~ - . ~... I', .' .: -' -4 ";', /' ' . '~ , -'. .' :.: " ' .. ~~ -... .' '. , " ," '....·..1.' - 3.5 _/ -3 JSTART POST FLUSH @ 15:10 I, SLURRY WT.10.1 PPG SLURRY VIS 44 SEC. '., , SLURRY RETORT 8% Oil 12% SOLIDS 80 % WATER I I" ì 1'1 'T-2r;~r"'-'r' r':-I'I' I 1"1 Il-:I I I I I - I ' I 'II I I' r I I I ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ ..:,~..:,~..:,'Y..:,'..:,~ ..:,:-' n~~ n~~ n''Y n~' n'~ n~:-' n:.~ n:.~ n:.'Y n:.',.;~ n:.:-' t;.~ t;.~ t;.'Y.;.' t;.~ .;.:-' ¿:~ ¿:~ ~~ ¿:'Y~' ~~ ~:-' rö~ ~~ ~~ ~~ ~ ~ ~ ~ ~ ~ ~Y~Y~Y~Y~Y~Y~J~~~J~J~ ~J~ ~ ~ ~ ~ ~ ~-'~-'~ ~-'~ ~ ~ ~ SEAWATER VOLUME 229 BBlS CUMULATIVE 33919 BBlS SLURRY VOLUME 760 BBlS CUMULATIVE 219447 BBlS o ~ ~ ~ TIME -Series2 -Series1 - 2.5 :E a.. m -2 , " :~:~<;:':;':I;"" .': --."'-". -..-' i:: ..... -:- 1.5 ," .~ 1 - 0.5 '- o ,~/ -,/ I-psi -bpm I o 1000 J. ' ,,-', Seawater volume - 160 bbls. Cumulative - 34079 bbl . Slurry volume - 923 bbls. Cumulative - 220370 500 . , , "',1,..:: . bbl :,~, Slurry wt. 9.85 Slurry Vis. 40 sec. )·,S,I,~,~ry..~et().rt; Oil.6.%~Wat~r.80%, ~olids 14% o I r Î I I I r I 1"'('·(..··1 'I' r I: ;;r;< d":"C", r Ir:'):~r:"'I:'I'\¡"lr'I";<:;~""{;I":"I", I' ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ A'~""~ A\~ A'Y <ó~ o:.~ <óry <ó~ o:.~o:.<? r"Ó.~ C'/)~ C'/)ryr"Ó.~ C'/)~(".¡y çS~ çS~ çSryçS~ çS~ç;S<? t-;.~ t-;.~ t-;.ry t-;.~ t-;.~ t-;.~ ~~ n·ç¡5 n'~ n·ryn·~ n·tt-c5~ c5~ c5~ \ \\ V V V ~ ~ ~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~v~v~v~v~v time E Co .c 4000 2 Highest recorded pressure @ , pos~ flush, 3623 psi 1500 '[ 2000 2.5 : s.J"" .. ", - . I.... .' . . L .-. . ' .-.. r "- '.. " ,.. . ~.. . ;. . . . 2500 3000 3.5 3500 4 ,~*¡i,~'gIf~¡l~~~~~~:~"';,~,';,~;-~J{l:~:'.,-- ", ,.,-- I 4.5 injection # 213 graph ru-7 'I 10-6-03 1 I No Annular Pressure I well # RD-D1 '~ "-- U) (l ~ Z Z m o o CJ -t ~, ~ ~ c::> c:::> ..þ> 4500 4000 3500 3000 2500 'ëi) c. 2000 1500 1000 500 " "'" 0 ; þ 'Z Z 11 .:J =' ;") --t ¡.....\ ~ rv c:::> <::::) eþ ~ Cti..-->' WELL #RD-D1 10-10-03 Injection #214 I NO ANNULAR PSI - . -,:'. "f... :. 'I':~ .'.. - ."Sf 'r- :J "./.- ,:, ,". .'. - ., , ' '. .. - - . '.. . , ,I '. ~~;, ',: . .;!' r , - :.~ :·':',i..- ";' '. t, ;..' Highest Psi .4005 ,,' . ~ . . " Slurry Volume: 723 bbls bbls. Cumulative Slurry Vol: 221093 Slurry WT. 9.7 ppg. Slurry VIS 48 sec. Slurry Retort OilDfc. 25; Water'/o 61; Solids% 14 ~ ~ ~ ~~~~~~~~~~~~~~~~~~~~~~~,~~~~,~~~~~~~~~~~~~~-~~~~,~~~ ~~~,~~ ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ time I-PSI -BPM I '--, 4.5 4 3.5 3 2.5 E c. .c 2 1.5 1 0.5 0 ~ '-- 4500 4000 3500 3000 2500 - ëñ a.. 2000 ~ 1500 - 1000 ~,' en 500 - () :Þ Z Z 0 m c ~ ~ 0 C"? --1 ~ 0 ~ C) oþ ~.~...../ ~/ Well # RU-D1 Injection # 215 Graph 10-17-03 ., .', .,.' <::~ 5if"~: :'~'. ';[i~,,;· .J ":.", ..,. :.; .....: ,.-",:., " - .. ~. .. -. ,-' ,., .. ". .. ,':.".' ., . " ~. ~'''., ." . "._ ~ ..;.J . ~ J~ '. . , ,,');',< ''"''- . ,- ... Start Post Flush @ 17:06 - Seawater volume 154 bbls. Cumulative 34373 bbls . Slurry volume 949 bbls. Cumulative 222043 bbls Slurry Wt 10.4 Slurry Vis 54 see Slurry Retort Oil %23; Water %60; Solids % 17 -' r No Annular Pressure 4.5 4 3.5 -__oJ ..:..... 2.5 :E 0- m - 1.5 ~- 0.5 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I: 0 ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ n:.Çj n:.'Þn:.~ n:.":- n:.~ n:.'Yn:.~n:.t?- n:.:J t;.~ t;.~ t;.'Y t;.~ t;.t?- t;.Y ~~~ ~~~'Y~.:.~ ~t?- ~.:.<9 6~ 6~ cotp 6~ r.:.t?- 6<9 A .~~~ ~~~~ A\.~ A' t?- ~:J ç;j~ ç;j~ç;j~ç;j~ ç;j~ ~J~J~J~J~J~J~J~J~J~ ~ ~ ~ ~ ~ ~J~ ~ ~J~J~J~ ~ ~ ~ ~v~ ~\~ ~ ~ ~ ~\~ Time I-Pressure -BPM I -~ INJECTION BY SWACO NO ANNULAR PRESSURE 4.5 4 --P :E ~ £Xl 3.5 2.5 2 3 . .., "." __,:j:lf~: :::} <: L~~;~?t};~~, . . . -' _.~.~~. -.~. _ ," "~ S ~~~_~~ i . "-:- ~. .'. ~',.,.,>.."'..:"'. --". . : .: . - - : . . . --- ,:>j;~. "\"{ ::.,'>~::,' . - -' .~.! '. :-., :. I,'·'"' .-. ''':". :; .' !¡''l .- :-' .-;... .',~'. :~: :..:I/. ~~~', ·"::'~·t~.; , . ' -. - .' -. ." ...... . 'or .,y::.",::..,.," ",; .:."r ~ ~. -".- . . - ~ . .'. . " . ".' 1 :". . ...:. - " "'- - :" , ;"~~~i~L i~f}J~~:S; I,;' :,,- . . -~~~.. .' ~. .'J ...:. . r. - l - : ~ , '. NJECTION WELL: RU-D1 ::i!~~~%~<\-:·.· .ê·._ . ;:;~,}:-_·;,~~..i:~{~f§2- ;' ,.- . -, '.~ '-' .. 4500 4000 : ." , , - ";:; ;t¡;r;:~," - . -'.~'-~..' :-:; - .-.~" .:' ',. ::~::«'" " . _. .-.... r.''- -.'.- Production Finished Flush ., Power - ~-. "-L '. 'J' .¿'- Rig Lost ,: 14:05 : ~=' Start Slurry @ '::;~/~:,~;r : ..::.... , . -" ': ~-: '. , ~ -, "',' ~ I.' : I 3500 3000 2500 UJ 0:: ::) tJ) tJ) w 0:: Q. 1.5 ."~ 1 , 20 bbls 34393 bbls Wt: 10.6 ppg Vis: 49 417 bbls 222460 bbls 64 % water Seawater Volume Cumulative Seawater - RU-7 INJECTION #216 October 20, 2003 ',">.' : .: ~. ...1.=" .._.;;. :";~'~.'. -:.¿' ---.". Recorded Pressure - 4035 psi 2000 1500 Volume Slurry Volume: Cumulative Slurry Volume I 000 0.5 18% solids 8%0 Retort: 0 0 13:54 13:55 13:56 13:57 14:01 14:05 14:15 14:25 14:35 14:45 14:55 15:05 15:15 15:25 15:35 15:45 15:47 TIME Pressure BPM (j":, ;=r-\ .., / :Þ Z Z m o o C? --t ~ o f'J c:::> CJ .þ : " 500 4500 4000 3500 (f) o ;:þ, z z m a o c-.J --{ 3000 w 2500 a::: - , ::J en en w a::: 2000 0.. 1500 1000 500 ~ o t'--J c::> c:> 4» --- -~ INJECTION WELL: RU-D1 RU-7 INJECTION #217 INJECTION BY SWACO NO ANNULUS PRESSURE OCTOBER 20, 2003 o ,- ',\' . . ....., '.. ; . " r' '. ..~ - . .. ~ ". _~~ :-- -~ '\" ~ t _' ."~ ':;', > ,<, ~_:. ":;~ .;':,,-: . It. :r . . ~ '.' . . r.";~' . :';.' ",' . , ,?:' ;';; No Pre-Flush Production Just Pumped Production Water Seawater Volume: Cumulative Seawater Volume: Slurry Volume Cumulative Slurry Volume 449 bbls 222909 bbls Wt: 10.7 Vis: 51 Retort: 18% Oil 19% Water 63% Solids I ,.,:,;: I -, I -II r-,.<;::) r-,.~ ~~ ~ ~n;, b-. ~ n~ b ~ ,~ ~ ~~ n~ ~ ~ ,~ ~ <;::) ~ n<;::) n<O ~ n...~ .....<;::) ~ ,S) ,~ r-,.<;::) ~d;":J ~d;":J ~d;' ~d;~ ~d;' ~d;~ ~d;' ~d;.v ~d;Oþ ~d;'!" ~d;Y ~'Þ ~. ~.v ~?:5 ~'!" ~Y f),,~'Þ f),,":"~ f),,":"~ f),,~.v f),,~.v f),,~f>} f),,~';.) f),,":"'!" f),,":"'!" f)",,:,,:J ~~y f)"r(,":J TIME I-Pressure -BPM I -' 4.5 4 3.5 ~ 3 2.5 :æ 0.. en 2 1.5 1 0.5 --. 0 en (") » z z m a o C"? -f ~ "~ ~ Cj c:> ~ -~~ 500G" . 45cJO:. ' 35c)q~ :; 30 w 0::: :J en 25 en w 0::: 0- 20 15 10~ 590 ~/ INJECTION WELL: RU-D1 RU-7 INJECTION #218 OCTOBER 24, 2003 NO ANNULAR PRESSURE INJECTION BY SWACO ~", . __-..-.._--....·.0_·.;:··.-_._·. --_-_-~.;....... , . ',- ,. ......:'..:.:~ ~.i:~~t.::.~o~~ed ..~res::. -.43~~ ,~Sl . ~ . '.' ~.:.: - ~ ::'~.~~~.J ;.~~. '. .' -.:' ... ".. .' " . - , -',' "''';')- " ~" ~ , . . .~. .- -8 I I I ~ ~ ~ g ~ ~ ~ ~ B ~ ~ ~ ~ ~ ~ ~ ~ ~ b ~ ~ ~ ~ 9 ~ ~ ~ g PJ<? 9J<? ~<,;3 Ç6<? çjS> ~S> r;5~ r;5S> r;j9 rs~ çj~ ~~ r;5'Y çjl} r;jtp rs'Y çj~ ~~ s:s~ çj~ r;j~ rs~ çj~ ~~ s:s:.) çj:.) r;j<? ~<? n:.'P ."5 n:.b' n:.<¿ ~'" ~t'1) .~ .b\ .~ ~.:..'3 ~.:..'" ~.:..t'1) ~.:..~ ~..:.b\ ~.:..~ .'3 .~ r':"'Y r":'~ r':"~ r..:.<? A'<;S A'~ A''Y A'~ A'~ A'<? ~ t\,.;,)' ~~. ~/ t\,.;,)' "",' "",' ~b" ~b" ~b" ".). ".). ".). ".). ".). ".). ~co· "CO· ~'V ~'V ~'V ~'V ~\ ~\ ~\ ~\ ,,\ ~\ '.; . ,-=.:-,:",: '; ~.,.: ..- ~ ~ - -~. ~ ','. :',~ _ ~ Start Slurry @ 13:45 ...,,': "-'00 ,,_. _'.,~~,. "~:.""" ~",,',"'~' . ~~~ -. ' . .... .. ~ ",' .:,.".> s;art Post-Flush @ 17:20 ( ", ~ . .~:.~: Seawater Volume: Cumulative Seawater Volume 160 bbls 34710 bbls ,- . . -" ~.." .;. :,.-.:. . ...,;.. . . . _<:" .~', I ,- ...'. ';. ,. -'~I' - . '-, ,. . - .; -, . ~~ J ~ C I" j, I . ":.""-> '.;' ';.", ,I'ø ..- . ." :- ;. , Slurry Volume: Cumulative Slurry Volume: 836 bbls 223744 bbls Mud Wt: 10,9 Vis: 49 sec/qt ....... ", . , ~ . " , Change out pop-off Retort: Oil - 12% Water - 68% Solids - 20% . . .-...._~-: TIME I-pump Pres -BPM I .~ 4.5 -4 ,- - 3.5 , , -'- - 3 ,- - 2.5 :E 0- m - 2 - 1.5 - 1 - 0.5 '-' " .; 0 (j) (j :Þ Z Z m CJ o CJ ~ ~ C~ ,....., C) ~ ~ ~~ 5100 4500 4)00 3500 3)00 ~ = th 2500 th e 0.. 2)00 1500 1 )00 ''-'"'' ---- INJECTION WELL: RU-D1 RU-7 Injection # 219 OCTOBER 28, 2003 NO ANNULAR PRESSURE INJECTION BY SWACO 4.5 I Highest recorded pressure - 4411 psi '- -..-" -4 - 3.5 -,~ --! '-- -- / I Start post flush @ 12:20 -3 \start slurry at 10:10 I - 2.5 :æ: c.. m Seawater volume: Cumulative Seawater volume 161 bbls. 34871 bbls. -2 Slurry volume: Cumulative slurry volume 540 bbls. 224284 bbls. - 1.5 Mud weight 10.7 Vis: 48 - sec/qt - 1 Retort: Oi112% Solids 18% Water 70% - 0.5 -" o I I I I I I 0 ~ ~ ~ ~ ~ ~.~ ~ ~ ~ ~ ~ ~ ~ & ~ ~ ~ ~ ~ ~ ~ .~~~ ~~ ~~ ~. ~. ., ~y ~~ ~~ 6~ ~~ ~~ ~~ ~~ ~~ 6~ ~~ ~~ ~~ ~~ ~~ Q)' ~\5~ ~\5~ ~\5ry ~\5'? ~\5~ ~\5~ ~\5~ ~,.;,,';3 ~,.;,,~ ~,.;,,'Y ~,.;"r;> ~,.;,,~ ~,.;,,~ ~~';3 ~~~ ~~'Y ~~'? ~~~ ~~~ ~oj~ Time I-Pump Pres -BPM I (J) () ~ z z m CJ o CJ -..f f-r-A ~ f'~J ~ c::::; ~ '-' '-' RU-7 INJECTION #220 NO ANNULAR PRESSURE INJECTION BY SWACO INJECTION WELL: RU-D1 NOVEMBER 2, 2003 4-5~O:, '.',: :.,.:. .':':,/> ": Co", :,~::::: :~'~~~:f}~1~;,it;::-': .': , , .' )". ;'. . . . .._ ,;.';.;.-7."' 4 .' ~': ::<;,.::gl~<~'· ..~~,/ ';:,~;[,'" 35.Q~~~ ~.~t~!i &~> .._)":_':'.,~,.', 3)O~{ ;'Hr';,:,:;?; ;» ,/,." - ',.' ',-' "..,' ...t Hi~hest recorded pressure - 4085 - ,,~-- ~ , - Start post flush - - 3 @ 14:50 w 0:: :;) en en w 0:: c.. . ':' .:. . ." '. . .r. . ~R ,...:J'~ ,I ,.. ... .. . - Start slurry at 09:00 I 25Ga . ~ . ;..: .....' Seawater volume: Cumulative Seawater volume: Slurry volume: Cumulative slurry volume: 1387 bbls. 225671 bbls. 10.3 ppg Vis: 43 sec/qt. Oil 9% Solids: 140/0 water 70% () . I II I' I . ~ ~ ~ ~ ~ ~ 8 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~. ?). ~.v ~.v !!j.v ~~ ~~ ?):J t:;.'i> t:j,.~ t:j,..v t:;.~ t:j,.~ t:j,.:J ~'i> [¿~ 0>f} <õ~ [¿~ 0>:J q¡,,'i> ~~ ~~~~~~~~~~~~~~~~~$~~~~ TIME I-Pump Pres -BPM I ~ 4.5 4 3.5 ~ 2.5 :E c.. Q] 2 1.5 1 0.5 ~ o ....~~ '~ '-" RU-7 INJECTION # 221 5000 4500 4000 3500 3000 -' w et:: :J tJ) 2500 tJ) w et:: c.. 2000 1500 1000 INJECTION WELL: RU-D1 NOVEMBER 7, 2003 NO ANNULAR PRESSURE INJECTION BY SWACO 4.5 (fJ () )'.:0 Z z m C1 500 . -0 __'. - = _ _ .'::;:'~.. ~~ - -- - ~;;'-··_·".··Y:--:-';-·_:I~:~.:~~-'··--'-~ . "'~-,,,_ iÄ:~¡Lt~\,:-_ ,..' , ";"::--':':"'~>~" . 'JV:.:i~I~:.~~<: .. ,.~,.,;. . . .. 4 3.5 ---- 3 2.5 :IE c.. CQ 1.5 - 0.5 ~. o C") --( ~ o I""..:Þ c:> c::> OÞ'> 0 I j' I I PJ .~ rstfY ~ " ~ .~OJ ~ "Ç) ~ ,,<õ ~ R> þ.. ~ r:;tp ~. r:;~ r!3<9 rs<? ~. ~ç;s ~. ~~ ~. ~ry ~ry ~"? t>.'? "rs ry oj~ ~9 ~ry ~~ <ó9 ,,<Q ry ,,<Q~ ro~ ro'Y ro~ ~~ ~'Y ~~ "qj~ " ~ '" ~ ~ ~ '" '" " " TIME o -PRESSURE -BPM I (f) (') :r> z z rn o c:> (J .--f ~ c::J f"..,) CJ c::> ..þ> 5eee 4500 4COO 3500 3COO w 0:: => r.n 2eoo UJ w 0:: Q. 2GOO 1600 1000--· Ch~ RU-7 INJECTION #222 INJECTION WELL: RU-D1 INJECTION BY SWACO NO ANNULAR PRESSURE 4.5 NOVEMBER 9, 2003 ...-.. , Highest Recorded Pressure - 4315 psi \ -4 )-. - - "",, ~Start Slurry @ 13:20 -, I~\/ / Start Post-Flush @ 15:55 I '""" - 3.5 I -3 1-2,5 :E Q. En Seawater Volume: Cumulative Seawater Volume: 169 bbls 35360 bbls '-- -2 Slurry Volume: Cumulative Slurry Volume 662 bbls 227 ,160 bbls - 1.5 Slurry Weight: 10.3 Slurry Vis: 45 - 1 Retort: Oil: 10% Solids: 10% Water: 80% 500 - 0.5 o I I I I I I I I I I I 0 ~ ~ ~ ~ ~ ~ ~ ~ ~ b ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ b'?'- ~'?- 0>~ r6"f- ~Y f>:'; bY ro~ r¿':> rö'? 9!J':> ~~ g¿,~ ro~ r¿~ röf} 9!JY ~'Y g¿,'Y ror:D r¿'? rötp 9!J~ ~';> ~~~~~~~~~~~~~~~~~~~,~,~~ TIME I-Pump Pres -BPM I --/ -~ '-- (/'.; r"""" \, .- p z z m a C) t-:> -I ~ o ~ c:::Jr c::> ..þD ';..,~ 500e 450C 400C 350C 300C w a::: ::> CJ) 250C CJ) w a::: Q. 200C 150C 100C 50C '---' RU-7 INJECTION # 223 No Annular pressure Injection by SWACO ~ - - 4.5 -4 - 3.5 '--" -3 - 2.5 :æ Q. aJ -2 - 1.5 - 1 - 0.5 ---- RU - D1 November 13 2003 C I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ~ 0 ~~~~~~~~~~~~~~~&ð~~~~~~~~~~~'~~~~~'~~~~~'~~ t..;,~ A\.'Y rj'Y PJ~f>'? t..;,'?~~'!j~ 9S~~~ *'.~ ~~rj~PJ~ f>~ t\.:.)~:.)'!j:.) 9S:.)~~ *'.:.) Clj~ t;.~ çj';j g;j~ fj,,~ qj~ ~~ ~t;. ròt;. ~~> Clj~ t;.t;. çj~ g;jl}fj,,~ qjY ~ry ~ry rò'Y ~'? Clj'? t;.n¡5 t;.t;. t;.t;. t;.~t;.'Y t;.n¡5 t;. ~ t;.~ t;.<? t;.~ <¡j~ <¡jt;. ,.:.t;.<¡jf},.:.'Y <¡jn¡5¿:,~ ,.:.~ ,.:.<? ,.:.~ V::? r.:.t;. rö~ x;Y x;~ rö~ r':'~ röt:; r.:.<9 A'~ ~~ A .t;.~~~y. A\. ~ A'~ A' ~ A' ~ A·<9 o:.~ o:.~ o:.t;. Clj~o:.Y ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~.)~ ~.)~ ~.)~.)~.)~.)~ ~v~ ~ ~ ~ ~v~ ~V~\~ ~~ ~ , ~\~\,\~\,V~V,V~ ~v I Highest recorded pressure 4396 psi I "" "" - ~ , '~ -....., , -- '\. .,. - ~ Start slurry at 15:40 ( I start post flush at Wash and rain water from production used for pre flush. Production shut down injection. Seawater volume: - Cumulative seawater volume: 132 bbls 35492 bbls Slurry volume: bbls Cumulative slurry volume: 486 227,916 bbls Slurry weight: 9.9 ppg Slurry Vis: 50 Retort oil: 10% Solids: 6% Water: 84% TIME I-Pump Pres -BPM I vj (") :Þ Z Z m a o c:; ~ ~ c:5) r---' c::> ~ .,ç- '- .~ RU-INJECTION # 224 RU-D1 5000,;, . NOVEMBER 15, 2003 NO ANNULAR PRESSURE INJECTION BY SWACO .- 4500 . . ...' .~ .' 4000 ..' ··'·1[;[~~1·~~~i" .~... . :~~ ......_~~..~.'ír...; ',"'::'f::~-'.'- , -...,", '. .", ~-..' ." ...... ' . ". , ,::,:,.'~",;." -,"".' , ,:.;:"'_.~ ~ .: .... .< - /~~i; ,: ~;~ ~~:- .' . .':' . , -;,:} ?;'~ ,'- 'I ~ta~post flush at .. to' ..' '-1 3500< ""~: ~ .' ": ;;,:"> ¡Seawater pump not <}\¿tì;2~;S~" ,"' , . "; '.... . '-:,' ;"::}~f.~~ ,:\i',-~~~' "' : .,:~':../:~' ,', '.·f "~ , , 3000, .. ~.' . .' :: '. ... I .' -,... -. ~. '.: o. '.' ~ '.- . . w 0::: ~ en en w 0::: a.. " 2500 .-' . _ ':: i".' I Seawater pump working Seawater volume: Cumulative seawater volume: 2000,> i; .. ' 1500> ' Slurry volume: Cumulative slurry volume: 572 bbls 228488 bbls Slurry weight: 9.6 ppg Slurry vis: 49 -t- - 0.5 8% Solids: 8% Water: 84% I i I I I I I I ~ ' I I I I I ,', I I I I I I I I I ":' 0 ~~~~~~~~~ð~~~~~~~~~~~~~~~~~~~~~~~~~~ ~~ ,,~ ~~ r¡,tt- r:iJt:!- ~t:!- ,,~ ~:.J ~y 9S:.J ~y "Y ~<? ~t;;¡) çjt;;¡) rö~ ~\¡J ~\¡J tJ.,t;;¡) r:j';) rö~ :¡:,':' q;~ ~~ çj':' rö'Y !J,'Y ~f} tJ.,<"'f; r:j'Y röY :¡:,n¡3 q;~ ~~ çj~ rön¡3 .\:S .~ .~ .1); .f',; n:..Oj .~ .~ n:.<i:> n:.~ ...:\:S ...:~ ...:~ ...:CV ...:'=> ...:'=> ...:~ ...:~ ì..:~ ~.:.(j ¿;,,<::;j ¿;,,~ ¿;"t-...:. ~.:.CV ~I'3 ~.:.'=> ¿;,,~ ~.:.~ ~.:.~ r.:.\:S r.:.<::;j r':'~ r':'t-...:. r':'CV r.:.'=> r.:.'=> ~.~'~'~.~'~.~'~.~~'~J~.~.~.~'~'~'~.~.~.~'~'~'~'~'~.~'~.J.~.~.~'~.~'~'~.~'~. TIME I-Pressure -BPM I .~ 4.5 4 3.5 ~ 3 2.5 :E a.. m 2 1.5 1 -- ~ "~' INJECTION # 225 4500 RU-D1 4000 3500 3000 w 2500 0::: :J (J) (J) w 0::: 2000 a.. 1500 1000 NOVEMBER 17, 2003 NO ANNULAR PRESSURE INJECTION BY SWACO (\Hi9hest pressure recorded 4290 lEnd pumping slurry at I Pumped only slurry. No seawater flushes. I Seawater volume: Cumulative seawater volume: o 35649 bbls Slurry volume: Cumulative slurry volume: 172 bbls 228660 bbls Slurry weight: 8.5 ppg Slurry Vis: 30 Retort oil: 0 Solids: 1.2% Water: 98.8% (p c: ::Þ Z z m CJ o C"') ~ !-' C) ,......, t:::) c:::) OÞ> 500 , /I Start slurry at 15:30 I o I~IIIIIII I11III111 II .~~ .~~ .~I'), .<t> ."br. .,,~ .,,~ .,,~ .,,<0 .,,<0 .,,<0 .~ .~'ò .,,'ò ."OJ .~OJ .1'),(.) .I'),~ .I'),~ .1')," .1'),1'), .0/ .0/ .I'),c:, .~ .~ .~ n'~ ....:~ ~. Ç)' a;,. b" Çò' ~. Ç:)' ~. ~. ~. ~. Ç)' !),. b" ~. ~. ~. ~. b" !O' R>' Ç)' ~. ~. «). <ò. ~. IV' V" ,,<6Y ,,<6'?3 ,,<6fþ ,,<6~ ,,<6'?3 ,,<6~ ~<6'f- ,,<6~ ~<6' ,,<6tf- ,,<6t?- ~<? ,,<6<? ,,<6<,¡3 ~<6<t? ,,<6<? ~ró':S "ró~ "róc:;J "ró':S ~róç;; "ró~ "ró~ "ró~ "ró~ "ró~ "ró'Y ~róY ~róY TIME I-Pump Pres -BPM I -~ 4.5 4 3.5 ---' 3 2.5 :! a.. m 2 1.5 1 0.5 '-'" o ----- '~ c_ INJECTION #226 GRAPH NO ANNULAR PRESSURE 6 5 18 2003 17 + NOVEMBER WELL # RU-D1 i , 50e9-, 45(9\ ~ ~. '-:-' .-: :~.~ , ',T,;' 40(~ --' 4 35CO'. ~,-., , , Q:-;, :E 0- m o bbls 35694 bbls 1 054 bbls 229714 bbls Slurry vis: 30 Water: 98.8% Seawater volume: Cumulative seawater volume: ~ .' - :. ',- -;r.'~'''-,'~'.',' , ,'~_ ..-:,.-. "¿,.,:,:;,:~.;;,.:, ,'., , - '. ... I '''I':i-·.· ~. -, ~. '.". Þ'~t1' ';(.,"~'. ~'''~ "r~I~"'.c.· .... .... ...\ . .. "'~ j.t';:.~',:~;ti'H,~~ :~;"~'6~' " " '. , ,;::; :; ~,·'jS.;::I~j!?~'·>;· .... ... '., /. f:-':; ~. ~.~~;-.: ~ "õ- " if."':' SHUT DOWN ~.-:\ ;-..... - ....."o!.,. - -. :I;Ú TO CLEAN Seawater disp of well, production did post flush 30( 25C~ 2000.--, w a:: :J en en w a:: Q. Slurry volume: Cumulative slurry volume: Slurry weight 8.5 Retort oil: 0 Solids: 1.2% -' 15(0 Ð- 5(:11 10( o y ~ ð ~ ~ ~ b ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 9 ~ ~ ~ O;Y r:i;:,) <;6:,) ~c:;> ~c:;> \5~ ~c:;; ç:5~ ç:)~ ~~ ~~ \5~ ~ry ç:5Y ç:)r; ssrv ~'? \5~ ~'? ç:5r;> ç:)~ ~~ ~tf- r::S~ ~~ Ç5<? çS<? SS<? ~c:;> ~c:;; ~c:;; ~~~~~~~~~~~~~~~~~~#~#~~~ð~~~~~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ O/~ ~ ~ ~ ~ ~ ~ ~ ~ ~ TIME BPM Pump Pres (j) c> ): z z m o o C"') --{ ~ o t'-J c:=> c:::J ..þ (j) () ::þ' z z m a o n --f ~ <:::) ~ CJ c::J ~ '~ '-----' WELL # RU-D1 INJECTION # 227 GRAPH NOVEMBER 19, 2003 '~'~j[ii~~1~1 ~tart seawate:po~tfIUSh .~,~' , " NO ANNULAR PRESSURE INJECTION BY SWACO 450C '." ", ù,; .:~ ~: ·;.:f.'::;"'-;¡{{:.{_~;~'~l~..~¡¿~~ .'''' "', !"~' . ",-"; . ,-', . . : .~.;: -:;~\:?,~-~:../.-~. '. ~~:;~~:ft;~~~~~·-~-':--~-:·-~-.. - ':':'Ä.., ~ 400C Rig wash + well disposal seawater. , , , - . .''; , - .. " . " I Highest pressure 4268 , ...- 350G I 30od. w 250G 0:: ::> U> U> , , w 0::: 200<::) Q. ._'. -f"":Ú~f', , ,.... ",. t", _I ~. ~ . .... . ",_1 ',' r ....~ , ",' . '.~-'- ' .:¡".. - . . ., . '.- - .~. - o bbls 35649 bbls Seawater volume: Cumulative seawater volume: Slurry volume: Cumulative slurry volume: 539 bbls 230253 bbls Slurry weight: 9.3 ppg Slurry Vis: 47 100 Solids: 6.5 % Water: 89 % c '., ,~;, I I I I I I ,"" I I I " I 'I I i I I ~ ~ B \) \)~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 9 t;;.~ qj';J ~<::;5 ròto;' ~~~. gj~ ~~ ~~ çjto;' t$> ~~ 0;.':' röf} çjY t;;.f} qjY ~C} ròry ~~_~fþ ~fþ:r,O) ~~ çj~ t>.fþ ~O) a;,~ rö~ çj~ t;;.~ qj~ n:.~ r<:jt;. ~t;. t>.~ gjt:¡. çj~ ('\.~ çjY çjry ('\.~ ci.~ çjO) çj~ çj~ çj<? çj<t;J çj<? ..;.~ ..;.':3 ..;.to;' ..;.~ ..;.~ ..;.i)I..;.ry ..;.~ ~.~ ,,0) ..;.~ ,,~ ..;.<? ..;.<t;J ..;.~ 0·9 0'':3 o'~ o'~ o'~ o·f} o·ry o'~ 0·0) o·r;> ~ ~~ ~ ~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~v~v~v~v~v~v~v~v~v~v TIME I-Pump Pres -BPM I "- 4.5 4 3.5 -~..,,>,: 3 2.5 ::i Q. en 2 1.5 1 0.5 - o iJ> (') ~þ z z m a o C"') --f \-l c:::t N c::::J c:::;:) ..þ --- '--- INJECTION WELL: RU-D1 RU-7 INJECTION #228 NOVEMBER 22. 2003 w 0:: ;:) rJ) rJ) w 0:: a.. 500C . .' ~I... ~ .)1 ~-f' ~J' þ . ·-···~~:'~·~·~'-.;,:·~,''':-:7'~~'\t'T.'''::-'' ,~ -, '.,'~,"~.':':','.~,'.,.~_:~..,',..-'~"~.;,;::~.,~.'~~'~.~;_'_'~.~..~_'.~,~~','~,'-;.'_:,'~,~.~._.,~.~.-.'".~,'._~.~.~~:.:_".:.~.:,:r".~~.~.o~~':_.,,"..~,.' d 4500 ;"~;:":~;h:¡¡,r '. {:;' :~;. , . , ,-.~,,?: . 400~· . .;:;;::,flJ·~'· '. '.. '~':~Î:;~~'~:'~,:':~" , 350C .: '.-J:' JIf.· .. . .:.I~t¿;}-;:',· ..:;:; . ,;+ Start Slurry @ 12:551::~: . INJECTION BY SWACO NO ANNULUS PRESSURE ·c··_". ..-.".,__;__,,,.:-.. "-.-. '-, ..:----."'-__.::~._.::.- .~- '-"--~-:.~'--'-'--~-'"' '~ "Highest Recorded Pressure - 4455 psi . . ~.....,~ j" Start Post-Flush @ 14:25 300G -, -... ,"/& .- .'.~ ....-.-<i..··r~;··. .. ~:. 250C . ~ .~....~..... '~"j'~ ..,;,. . ,';~,:;)\:tJ~" '.,'.,:::, Seawater Volume: . _ ,~,'::,~('.~:;,:~~~. - ;, Cumulative Seawater Volume: 121 bbls 35770 bbls '..':' 200C 92% Water 50C., 0.5 '-'" 150C:;.' Slurry Volume: Cumulative Slurry Volume: 350 bbls 230603 bbls 9.1 ppg Slurry Vis: 49 1 OOG. ~ 6% solids 2% Oil '- 4.5 4 3.5 ~ 3 2.5 :i a.. co 2 1.5 1 - ' C ,-'I I· 1 r I I , I I I I I I '>1" 1 0 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 9 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 9 9 ~ ~ ~t¡. ~~ totP 0>'Y 9JY ~Y (\l) t.;.Y ~ry ~ry r.>'Y (\'Y ~~ ~~ ~l? ~'? ~'? ~~ f>~ 9J'? ~~ (\~ t\.~ ~~ ~~ r.>~ (\~ ~~ f>~ riJ'f- ~'f- ~~ ~~ f>~ 9J<9 ~~ ~~~~~~~~~¢~~~~~~~##~~~~~~~~~~~~~~~~~~~ ~v~v~v~v~v~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ TIME I-Pump Pres -BPM I / -- Injection by Swaco No annular pressure -- RU-7 INJECTION #229 November 26, 2003 '~~_r ....-- 4.5 4 3.5 - 3 2.5 :E a.. -, OJ , 2 -1.5 1 --- Pressure 4495 psi Start Post Flush @14:50 , . Î. I Highest I " /i- '. ~i~-':{-~; ~j:Ú<~'~?::f:1 m~ ~~s t-}::';::; f:::::~, ~ ::::~ .~: >.- .... I'· ;." . .'~I.. '. .- - -. - \~'~f~:" : ' - '-,~ ~'- "'-; : ~~. .~ ~;: ;:::, . .......-,..\.,., . ..". , .-.'.:: . _ . ., .1' . ;-,::,:-~~.':.: '-~-' :'/-;, , -.. - . . .~ . .-" - - Seawater Volume 125 bbls. , ' njection Well RU-D1 {}f*~~~i; ;, rt Pumping rry @12:20 ,- f.; 50~ca.:;: ; -.. ti" 45QO¿r...,,· ,.,:' .... . "1- ,-..... . ">" , ,": F;: '~, :;:!.~ 40P9,,~., ;-. _1'-;- .11I17~ .¡.. ;.~! 35,òci~t~~r 8,; '". .,.....,..L'. nO... ..>\{j~ ~/ . . t).: 3000 ' - :."-: - "\'. (;.'..:, 25,00. 200,0;, w " ~ tJJ tJJ W 0::: a.. Cumulative 35895 bbls ~ " 150.0 Cumulative 231242 bbls. Slurry Volume 639 bbls. 100P " Slurry Vis. 50 see ppg Slurry weight 10.1 Water 91% 0 ; 0 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ A ~ ~ ~ ~ ~ ~ 9 ~ ~ !:!> ~ r!J <tþ n!J <r) t$.';> ~ 9 ~';> t;;.\;> t;;. ~ t$. ~ t$. ~ 'fi.. ry t$. 'ÿ t;;. 'Y t;;. n¡3 t$. ~ t$. ~ t$. ~ t$. ~ t;;. ~ 'fi.. ~ t$. . t$. . ~~~~~#~~~~~#~~~~~#~#~# ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ TIME Pump Pres BPM Solids 7% Oil 2% Slurry Retort: 500 (j) () ~ Z z m ~ \..-1 o CJ -J, ~ <::) r-v ~ ~ ..þ. fj; (J ;:Þ. Z Z m o o Ç) --f þ.t o r-0 C) C) ..þ. ~. 5000 4500 4000 3500 3000 () ... ::J tn 2500 tn () ... a. "-' RU-7 Injection #230 Injection Well RU-D1 Injection by Swaco No annular pressure December 01, 2003 . ::~~ç'-'~"~~;a~.~U:Pi~~11~~!~~'·· . ',.' ..~~":::':~.::~'~.:."..,..,. -, :,:,>~.~;,~::.':!~.~>->~:' ~~. .. .\(~"~ r?·~:~Ji;,'~:'-~,\:-, ''''':,::.;;-~'~ _':- ~.~~~;,~,'-' .." : :,c~:'}h;~':/''',::>_ ' . ,,' ~'-:::-',.<:~:.';; , ,,' - , ~: .: Or: t .'':. . '>:. ~ . "'. ..4'": .J-": ...;;. . ~ . ... I'. . - _ -:.:. ~~_-~.:; - ". :. ". ~.- {-":i:~-' .'- .~ '-'.: : ~".<.:-.::..:.(.~; ~:..~f~~i-~-_:"_:.:;':--·_- '..~-' :';":C':"-;; . -::;.... .='"....;::": ~;~ ::~"""':"';"l~~ ..'.' ''-:'-'''''"'"c·. i"."> .".; Highas! Pœssur.~3g1 ~i' R~~~~ ~ ~ ~, ¡ . ~ '-~~' ", :... L.rL, :. . . ~"~I";~r~ '~...:' }t\..· : . I~'~~ ,....:_.~ .: .::. i l>': <:'-;'':, . .' . p. ~. ~:: )<;~:...:~:::' . '~- ::'," , ...~.>;,i.:-..,~.,":,-. - I .. '~'.'- ..... :....~. . ..;. . . ~ . \ .r ,', '.. '",; , .....' ,. . ,.,r,:~' ~, ~ Start Post Flush @1,3: 1 0 ,,: ¡' ., ~.. ,'; "~/'~ ' , ; :\~,) ~;~~'~~ ';'-~ .' - ,.,'":",:, , '.' -....,.:: ::.:.; :-.,.. - .: -~: . - , ' ~ f)o- ~ 2000 " 1500 --1., 1000 500 '. ~~.<~:~:~r~., :.' .....-.. -'..;. . - ' .. ..' - .-: . ~, -. '::'>~'~<"- ;:.:; Seawater Volume 124bbls. Cumulative -.- .'- 36019bbls. . r , 'i"" , ~_. r ~~' , ",' . t '. -. ....- Slurry Volume 630bbls. 231872bbls. Cumulative , , ". . .i~ ',",-"-" .'" '- ,~'-. '-. '.. . -,"~ Slurry weight 11.4 ppg Slurry Vis 50 sec/qt ~;. , .; . ,. . . - '.~ ......r... ~. ..';: :}~~;Y~\~~f?/'L~~,-}.'-·· . '. ._ o : ;:·:".~~::T:·:"(:=(I"-:l·-·'Î:'Ff:·ìl-í·:IIII-f··f -'I'Î--llllî-lll'-¡"-¡ III r-î II rllll-l-II-Î-Ilî-'-I j-'lî I-III--r~--II'-I (~'-"I+t ~~~~~~~~9~~~~~9~~~~~&~~~~b~~C)~~~~~n~ ~ry r:i;f) ~y ..;,'? ~'? ~~ ~'? ~~ ,,'? ~~ ~tr- r:i;tr- ~~ ,,~~~ ti>:.J ~:.J ~:.J ,,:.J ~:.J ~:.J r:i;:.J rò~ ~f.? '1)';) ~';5 ';5? gj';5 a:,':' ~~ ~~ ~':' rò~ a;::' '1),v ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~#~~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~v~v~v~v~v~v~v~v~v~v~ ~ ~ ~ ~ ~ ~ Time I-Pump Pres -SPM 11 ~.~ 250 200 --- 150 :E Q. en 100 50 ~ o (fJ () » z z m o o CJ --t ~ ;0 f'.) C) C) -,þ -~ 5000 4500 ... , , , , 4000 3500 3000 Q) ~ ::s fA 2500 fA Q) ~ a- 2000 1500 1000 ..~_/ RU-7 Injection #231 Injection Well RU- December 05 2003 . . ····.·::T:;·~~ç~Æ~~~~.~:::}*?~BÆl:~fP'· ... . .... ···~···i·.········· . ·I,è·~·' . . Injection by Swaco No Annular Pressure . - . ," ·'·~r _ .#'-,-".-.-' - Highe~t pres'sure- .;': 1..- 3.5 r-3 I .', .." . . ,". . .. ,." ". - .' . . . ..4·ry.....~' ~~?·~i~·· . . or:' Start- Post- Flush "';>i..' '-',>;:,-::~-~", "". . ..' '. . "'7:~..... ~ :- .~:::. ~ >. . -, . -~ .....;~ .. . I .'. - '." ._" . _. .r".-. .~'.~ ."., ~ .;..~ . . .. ., -. .....~.., :' .' , " . -. a ,")' .::_ I .' ~ . .' . :;.:.'~ . , , , , . .'"-" .' . . J'~ ',~'.... a ~ '';,'':"" . _ ~"." . - ~ , '. .OJ· _. _~..:... '., . , " "': ..' ~ . .. Seawater Volume 126 bbls Cumulative 36271 bbls Slurry Volume 418 bbls Cumulative 232530 bbls ,- I ,- 50: i:?J~;IIII'1 111"1 I I I ;;;~:~;I;I;~~ r I ~~;~~ IV;;t~~ ~~~o I I I I I I 1 I III I I II II lid: : ~ ~ "'- ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ "'- ~ ~ ~ ~ ~ & ~ ð ð ~ ~ ~ ."'- .'-' I':'''' .'1.; Nt'); n.:'V 0:'1t 1.:.03 ....~ ",.~ n.:Oj o:Oj ,.:.~ ....~ ",.~ n.:b-. o:~ ,.:.~ .~ ",.tx n.:".) 0:".) ,.:....) .......) "'....) n.:".) 0:".) r;. ~. :!.). ",-. ....,. -"'J' ~J' ò!')' .,' :,' ¡'J' ¡vJ' :!.). .,' ~,,' -"'J' ~J' ò!')' ",-. :,' ¡'J' ,"",J' :!.). .,' .,,' -"'J' ~J' ~~~~~~~~~~~~~~~~~~~~~~~~~...~...~...~...~ "'-V "'-v "'-v "'-v "'-v ~v "'-V ~'J "'- ",-'J ",-'J "'- "'- "'- "'- "'- ~'J '" '" '" '" '" '" ., ., ., ., Time [-Pressure -SPM ! I 4.5 -4 '~ - 2.5 :E a- CD -2 1.5 1 0.5 '-- 0 -- 3.5 '~ ':...... 3 2.5 :E 0. m 2 1.5 1 0.5 ---' 0 4.5 "- I-Pressure -SPM 11 o r 11I,- ' f ;'1 -- 'r ,- 'r'"~~';;F><1 ' - T~"l"'l- II I ,"cll I I II II I I I ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~^~~~A^~~~~A^^~~^A^^~~^A^^~~^A^^~^ .v· ;v' "'YJ' ,"".J' '-.J' \,' .,' ;:!J' ~,J' :,-.J' ;"",' ". :!J' ::'..1' ~. ....,. ~. ,YJ' ,""..1' ~. \,' ~. ;:!J' ~.J' ~. ;_,. ". :!J' ~. ""~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ "V "V "V "V "V "V "V "V ~V "V "V "V "V" " " " " " " " " " " " " " ~ Time 500 100(" 150(';, 2000;, 300e,,;:, C1) , ... ::::J ~ 250~ ~ 0. . _ . ..... ..,~>.¡j,..,.:..:;~~~~;<~~~9he~t.p,r~~û;~.. ,'~'~ _,;tart'PQst,\flu' 'hf<!;i;,~., . -:~_,:~ ":r..< ',',"i ';:,:'- ~:~-:.---' ',"'., "" ": -' . '.~ . . - - . - ~ .. ..' -,- -: 500Q Injection by Swaco No annular pressure Decembèr 8, 2003 Injection Well RU-D1 RU-7 Injection #232 -' --' 1./) o :Þ Z Z m a o ("') ~ ~ c::J r-J C::J c:::) ..þ --- , ':- 2.5 :E Q. m ~ o I I 'I '¡"~I ,1:1>IT'''T''r~r~'T''r,:''rll'I<ITII'-II'''f-l,l'l '(I II 111'1 I II 11-11:1 Illfl 11(11111 I ~ð~6~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ a;? (j,):.J çSY .:.J tfJY a:,Y ~r:;s ~~ ~~ SiJC::S ~~ ¿.:Ç5 "Ç5 ro~ P>~ ~~ C\~ ,,~ 0J~ 9J~ ~ry ~ry ~y ~f); SiJY n,;'Y ¿.:ry to;,~ ro'J3 P>~ ~~ ~~ to;,~ 0J~ I() ~ I() ~ rot:¡. I() tf I() t?- I() <i¡> I() ~ ;..;.~ ;..;.r:;; ;..;.Ç5 ;..;. ~ ;..;. ~ ;..;. ry ;..;. 'Y ;..;. ry ;..;. ~ ;..;. ~ ;..;. ~ ;..;. ~ ;..;. ~ ;..;. <? ;..;. ~ 'Ô ~ 'Ôr:;; 'Ô Ç5 'Ô ~ 'Ô ~ 'Ô ry 'Ô 'Y 'Ô ry 'Ô ~ 'Ô ~ 'Ô t:¿-. 'Ô ~ I-Pump Pres -BPM I Time o Slurry vis 50 - 1 0.5 Retort: Solids 22% Oi14% Water 74% Cumulative 232870 bbls Slurry Volume 340 bbls - 1.5 Cumulative 36390 bbls , Seawater Volume 119 bbls I .'~ . ;.~~ .:~ ~_:'~- i~: "'¡~ ~ ~ :':' ~,~-~-. ~~: r:- .' ". .'~'" '; ", "J , . '~2 ,. '., ,~ 3 " .-:.",.,,' '- 3.5 - 4.5 .'.0...:-. I njection by Swaco No annular pressure December 12, 2003 RU-7 Injection #233 -- "-' . ",. ~ .:.:.~ .ij:::\;;~r .. I: -, , "<~',-, , ... ;j;iLL~,:~¡;;¡:;, '-- .~..: ~¡ ." . ' ' .. .' .......:. , ' ~ <,\:;)-,'~~ '". ::. !..:_../.~ . ..:\.;~;"~":::'. ~:;'.~:'': :';'~'., Injection Well RU-D1 500 !'J) r, ); Z z m o (:) CJ -4 Þ" o "" ~ <:::) ..pa, 5000 4500 4000 3500 3000 2:! :s ~ 2500 CD ... Q. 2000 1500 1000 c...-..............._ .....~-- .~ 300C , Seawater volume: 120 bbls. Cumulative seawater volume: 36510 bbls. ¡start post flush I w £X: ::> Slurry volume: 316 bbls. CJ) 200C CJ) Cumulative slurry volume: 233186 bbls. w a::: a.. Slurry weight: 10.2 Slurry Vis: 47 1000 Retort oil: 4% Solids: 10% Water: 86°J'o en o ~ z m CJ o n =-t ¡-.." ~ N C) C) -Þ> RU-7 INJECTION # 234 ~ 500e· Injection Well RU-D1 Injection by SWACO No annu,lar pressure 4.5 I Highest pressure 4671 psi I December 15, 2003 400C " ---/ - ~ .., C ; ~ I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ~ ~ ~ ~ ~ B ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ PJ':> t:f>~ ~'i'..;.':> ~ç;s ~l~ ~~ ~~ ~~ ~~ fib~ ~~ ~~ ..;.~ (tj'Y PJ'Y ði} ~<J; ..;.<J; ~ry ~'ÿ ~'Y ~'Y ~'ÿ ~ry fib'? ~'? ~.,? ..;.~ (tj~ PJO} ð~ ñi.'? ð~~~ð~~~~~~~~~~~~~~~~~~~~~~~h~~~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~v ~v~v~v~v~v~v ~v~v~v -100C -...~----- TIME I-Pump Pres -BPM I -4 - 3.5 .~ 3 - 2.5 :E a.. CD -2 1.5 - 1 -' - 0.5 o (J': -. , " ":Þ Z Z m CJ o CJ --I ¡-.!> o '" c;::) c:::> ..þ>- 'c~J ..,-" - RU-7 INJECTION # 235 Injection by SAWCO No annular pressure Injection Well RU-D1 5003 450:> - 400:> - 350) - - 300:> - w 0:: ;:) en 250:> - en w 0:: 0.. 200) - 150) - , 1 00) - I 50) - December 17, 2003 4.5 I Highest pressure 4596 psi ~ -4 ~~ IV Y , - 3.5 .--- -3 - 2.5 ::E -Pump Pres 0.. -BPM co -2 - 1.5 - 1 .~ - 0.5 Pump shut down at 9:50 Seawater volume: Cumulative seawater volume: 160 bbls. 36670 bbls. Slurry volume: Cumulative slurry volume: 274 bbls. 233460 bbls. Slurry weight: 9.6 Slurry Vis: 53 Retort oil: 4% Solids: 6% Water: 90% I I 1 I I I I I I I I I I I I I I I I I I I I I ~- 0 PJ~Co f>~Co ,~'ò ~~~ þ.~n;, ~~<o g5~Co ~~Oj Cb~Ç) ~~~ çS~n;, (jj~ ~~ ~~: ~~Oj ~ry~ g5P ~rp Cb~ ~~ çS'þÇ) (jj'þ~ ~,., ~'þCo ~'þ'ò ~'þOj g5~Ç) ~~~ c:fJf'ý OJ'~ c:fJ~ c:fJ'rf- c:fJ~ c::5~ c::5~ c::5~ c::5~ c::5"Y c::5']3 c::5']3 ~~ c::5'f- c::5v¡J,~ ,.;,,~ ~~ ,~ ,.;"Y ,']3 ~']3 ,~ ,'f- ,~ n'~ n'~ n'~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~v ~v ~v TIME ~ ~/ o ; ; ;~<" "'1""1' 1 'I~;": '1'("'1 "I' I (I I I I I I I I I " ; : ; 0 ~ - tx b ~ i'!1t a, i'!1t i'!!:J i'!!:J i'_~ þ.. i'Ý:> i'Ý:> i'~ i'~ i'~ i'!ò 1'.9 ~ ~ ~ " a, r:, r:, r:, þr. þr. b ro ro (\ t;.'? i·~' ~'? ~'}3 ç6Y t\.<? ~'".J ~'".J ~'".J ~'".J t\.<r) r:!3Y ~'".J ~'".J 9J'".J ~'".J rj'".J ~'".J Rj";) ç;j";) ~";) ~~ \Ö~ '6~ R5~ ~~ ~\;) rô\;) fÒ<;5, çS";) ~";) t;.~ ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ " " " " " " " " " " " " " " " " " TIME I-Pump Pres -BPM I '~ 0.5 . : ~ ." , . -::~. . Water: 92% Solids: 40/0 Slurry weight: 9.3 Retort oil: 40/0 Slurry Vis: 52 - 1.5 168 bbls. 233628 bbls. '.. -2 :E a.. en 131 bbls. 36801 bbls. ... - 2.5 , , , . ," ,'", - 3 : ~ 3.5 '~ 4 ~.,_. " - ." " . ;.", -". . .": ~ '. ~- . ,"';: ~',; . .. .,," p' o ~ .. . - .:: ;.:. " . . " ~ ," ~-. ."...... ." .. ".,' . ..' t,~t;:¿;;>;;§¡< ::, ., ,., 4.5 , , .. ~. . ·i2.,. /.:.", ." ~·~~;.r~·~~.·~t~·~: ': Injection by SWACO No annular pressure December 18, 2003 Injection Well RU-D1 RU-7 INJECTION # 236 "-' "'-" -, 5000 4500 4000 3500 3000 w a::: ::> ~ 2500 w a::: a.. 2000 1500 1000 500 ,',' ".', ~2·· ·r '-'''þ ",'" j':;'., '-- (jj (j » z z m o <:) C'"') ~ I-=-' e1 J'..> c:::> ~ ~ (f' "'! P Z Z rn o o C"") ==-1 }=J ~ ~ c:Þ ~ "~ RU-7 INJECTION # 237 Decernber19,2003 w 0:: :J CJ) CJ) w 0:: c.. Injection Well RU-D1 4 >Q~ : " , ,',~':.;,:',~,y . I ~- . ::r:0:;::~r:,:. ..'- ~'~;:~~;1;~~~~c.~ .~"~ ~':.~ ',';':,: ~:~ ~ a,~?t:1Start slurry, no pre-flush -":',: ' <.':: 3)QP~~~ 1 ;],.:... '. . ,"C:~·~¡ltf·,,· . 2 500~:]~ ~e:' . '. ~~:~~~i~~o~~:~ter volume: 2, JOO, -:: ~~ Slurry volume: , Cumulative slurry volume: 100 bbls. 36901 bbls. 331 bbls, 233959 bbls. 1 )Q~':~ ¡ 9.8 Slurry Vis: 51 Solids: 7% Water: 89% Injection by SWACO No annular pressure 4.5 3.5 'f 3 .:- 2.5 :i c.. m I ~f> ,,'?~ PJ'?~ ~1" f6~ ?j'?OJ ,,~t... rr,,<t;J rj9 rjr:::s rj~ rjf} rj'? rj~ ~ ~ ~ ~ ~ ~ ~ 'I I ~~~ ~~ 6~ nj~ ,,<t;J~ ~l~ rj tf rj <t;J ç;S'? ç;S ~ ç;S '} ç;S ry ~ ~ TIME I ~ ~ ~ 2> (!\<? 0>~ 'f><? ,,<9 ç;S '? ç;S ~ ç;S ~ "r:::> o ,,-' ~' -Pressure -BPM .~ -~ '~ RU-7 INJECTION # 238 December 20, 2003 ~- ~ Pump Pres BPM 2 1.5 1 ~ 0 0 (f) ~ :z 2 m , tJ .;,'" ~ ~\~E;: ~ ~::~:\.< o ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 9 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ g~~~~~~~~~~~~~#~~#~~~~~~~~~~~~# ~~~~~~~~~~~~~~~~~~~~h~~~~~~~~ ~ ~ ~ ~ ~ ~ ~v ~v ~v ~J ~J ~J ~ ~ ~ ~J ~ TIME 1018 bbls. 234977 bbls. 52 Slurry Vis Injection by SWACO No annular pressure >,..'.;' :',~" "__ :'", ,',' ' ':~',,-: 4.5 . - . - ~ . - - .. "-" , - .'-. -:;~ ~-:...-; }}:.<->:-<' . ......". .,-,; . .-'- . .~. . - . ",' "': --"'~ . ,'.;. __.~.~_:~--,. i,'_-.-'-:. ". :'__)'''~;~~__':''_'< . - '.' c· . "_",-~l~1t,,::'::\ ~j;r 4 :. - -. '---::' ".~.. ~ .. . '. : ,:-. ~ ....._,. - .. ,-~, Injection W "~;' Start s y no need for :;::',' .J", ,; "1 ,. " pre fIU...;~_!:-:::~;~SI~W down injection ; > "', :,-_.:;,' waiting on rig pump Highest Seawater volume: Cumulative seawater volume: Slurry volume: Cumulative slurry volume: 9.7 : " ~I J" r·':'-" -, -'. :: ",:.,ì ,.- :¡p". o. '.' :;: . - , ," ::ltJ': :. "~:~:'~i~ ~'. .' -. -: ) - ~ I 40JI~ 35 ~rl~~p:_ 30r t' 25 ~.:II~ 20JI;~ 15 ~~;.-- w 0::: ~ UJ UJ w 0::: Q. 89% Water: 7% Solids: 4% (fJ ("') » z ;z m tJ o ("") ~ ~ o ~ c::> C) ..þ. "- ',,-, Injection Well RU-D1 RU-7 INJECTION # 239 December 21, 2003 50('0,~ . ');5"::1 ';i~;:-'''-i·_:t~,~.;~~~~~[ir-;: ." Pump aired up bleed thru SPM choke, . ."-'.:'~~.'~~'~~. :~'."".:~~ Injection by SWACO No annular pressure . -, ~ ',~ ". I Highest pressure 4385 psi. ". ....... ;',.. , , 45CO;, " .~.:>~.,~. . <':. ~..:, - 40CO, ~ '. 35CO,' , . , w c::: ::) en en w c::: 0- ",' ~ , , " .~. ;.. . . ...··r·.. . . - - :-:;- t,.;':;.·}:-'·' . " .. ~..: ~~ . . Seawater volume: :, Cumulative seawater volume: 126 bbls. 39063 bbls. 25C O.·,)·,~ -, 20C O,~/ :t;:~' .'. '. '".'_~ Slurry volume: , ' Cumulative slurry volume: 423 bbls. 235400 bbls. ;, ..... .'J ~~"?:~ :'."."'" '--'~'.' .'.. ~ . 15C . -.-. ~ . . ;"':':'~' , J ~... '~... ; ..... ;", ': '"':'" . .:. ,.:." ~. .. " . , .'~ -:: ". 10C .; i .,r.. ., .... "1 Slurry weight: 9.2 Slurry Vis: 49 :', :~ ~ ¿.,'. , , ~¡:~;~t~;:~1~~~:- Jfetort oil: 3% Solids 5% ~'( I "I I I I 1 I ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 9 ~ ~ ~ ~ 9 ~ ~ ~ t-;.'ÿ ~ry R5f)1 ~'ÿ ~~ . ~fþ S$fþ g)~ ~fþ ~~ t-;.Oj ~~ R5~ a;.!>' ~t¡. t-;.~ S$Y g):.) ~y A.:. ~ A.:. ry A\ ry A.:. fþ A.:. ~ A.:. ~ - A.:. <9 A.:. <9 cfJ~ cfJÇ) cfJ ~ cfJ ry cfJ cy CO'? CO ~ cfJ ~ cfJ <9 qj <9 o.? TIME 5C Water: 92% ....." ..::.::J,.~::~'~.~',.;.; i' -]",.- .' Start post flush - I 1 I ~ ~ ~ ~ 9 ~ a, ~ ~<tþ t;.<9 ~~ R5~ ~<9 9~ ~~ ,.;.r:;:3 ojÇ) oj ~ oj ry oj cy oj'? oj OJ oj 'f; oj<? I-Pump Pres -SPM I ',,-,' 7 ., -6 ---- :- 5 -4 :E 0- m 3 2 t ~ 1 .~ o ~ 2 ~ r:n '~ I-Pressure -BPM I 0, 'I ;- I "I II 1'11"'1">"'1"1"'1' I 1'1"lflllll; I ; lid;; I 'I 111-"- I [f>o[';'; 0 ~~~~~~~~~~~6~~~~~~~~~~~~~~~~~~~~~~~~~~b~~~~~ ~c');,~~c');,~c');,~~c');,~ c');,~~c');,~~c');,: ~ c');,: ~ c');,: ~ c');,:~ c');,:~ 'î? ~~ ~~ ~ ~ ~ ry t\. ~ ~ ~ ~ y c');,~ c');, ~ c');,ry c');,~ c');,~ c');,Y of>~ of> ~ of> ry of> ~ of> ~ of> y t>.~ t>. ~ t>. ry t>. cy t>. ~ t>. ~ t>. ~ <ò \;5 <ò ~ <ò ry <ò cy <ò ~ <ò ~ Time 0.5 1 Slurry Wt 8.7 Slurry Volume Cummulative Slurry Vol Slurry Vis 29 1.5 526 bbls 235926 bbls 2.5 " ......, . 3 "\'.' , .' "'-. . ,'-. ",,',-',", '.'-:,",',' ,-: . . . . . , ,L_ ", , , , ", 3.5 4 I njection By Swaco No Annulus Pressure Injection #240 December 25 2003 Injection Well RU-D1 '~ '-/ "I. . 4500 4000 3500 3000 ~ 2500 ~ ø ø (1) ò: 2000 1500 1000 500 '- o ~ c=J ~ "þ. j-J en (j > Z z m o o Ç) --{ f.j) (j » z z m tJ o ('"') --f -.! e;, '" c:::J c::J .þn '- ~ '~ Injection #241 Injection Well RU-D1 4500 4000 3500 3000 Q) 2500 ... ::J In In e 2000 Q. 1500 1000 500 December 26 2003 I njection By Swaco No Annulus Pressure . . - -. 4 ~ - 3.5 -3 ~~ ~tart Slurry No Post Flush - 2.5 Seawater Volume 20 bbls :i Cummulative Seawater Vol 39103 bbls -2 Q. en Slurry Volume 607 bbls Cummulative Slurry Vol 236533 bbls - 1.5 Slurry Wt 8.7 Slurry Vis 29 - 1 '-" - 0.5 o III I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ~'i' ~~ ~~ ~~~ ~~ ~ ,.;.~f1.., ~~O;) ~~ ,.;.~<o ~~co ,.;.0/ ,.;.~'ò r¡,9\;:) r¡,~~ r¡,f> r¡,fþ\;:) r¡,~\;:) r¡,<r;>~ 0!>9~ O!>~\;:) O!>f> O!>fþ\;:) O!>~\;:) O!>~~ tr;.9~ t:;.~\;:) tr;.rf t:;.fþ\;:) tr;.~\;:) tr;.~\;:) tr;.~0;) tr;.~CO tr;.~Oj <rj9f1.., Time o I-Pressure -BPM I f./'; (') » z z m o a <J --{ ~ c;::, "" c::> C) ~ .~ "~ ~' RU-7 INJECTION # 242 INJECTION BY SWACO NO ANNULUS PRESSURE INJECTION WELL: RU-D1 December 30 2003 4500 . 4 4000 ....... ..:... 3.5 3500 -3 --~ 3000 - 2.5 w 2500 0:: ::> :E en -2 0.. en en w 0:: 2000 c.. Seawater Volume: Obbls Cumulative Seawater Volume: 39,103bbls - 1.5 1500 Slurry Volume: 500bbls Cummulative Slurry Volume: 237,033bbls - 1 1000 Slurry Wt:8.6pp Slurry Vis:28sec/qt Started pumping - 500 slurry - 0.5 o o I I I I I I I I I I rorß> cörfr cö'þ\:::1 ro'þ~ cö'?0" ro'þO;) ro~ cö'?<O ro~ cö~<O ~~<o ~~<o ~p ~'?<o ~~ ~~<o 'b~<O 'b~<O 'b1' qj'þ<O qj~ 'b~<O C6~~ C6~<O ~Çj~\:::1 TIME I-pressure -BPM I "-' '-' ~/ :E 0. aJ 4.5 ~ 3.5 -3 ~ 2.5 ~4 Injection By Swaco No Annular Pressure '. " ~.", . -' -2 1.5 0.5 1 " NJECTION # 243 January 7 2004 ':~ .~' '" '. -High~~~; "'.1 .'rr.~ ~~~¡r}~ . - . . , '. . '" ., - '., " "'" ""'.. :'t"". ;..~'p'~. ost .',' ". 'c,'., , ;., _""." ' ,,'-- . ". ',." ' , ,,'.....' ï>~:,: .;... , -~ 1 '¡ .~..~-n~ njection Well RU-D1 ~~r¡\/!!~/',,:, ," ,:d;,;~::'~','" :;P':·:"'~i";OJ.~~5t;~~ , ;-.:'; :>~,~ '~. ':', ",,~'.-: ~::~:"::'.'~,<>~¿.~:<;:, ','" <~::.- '-<~ ' , , -' :::. ~}<~~,;:;" . .'"1"("- . :.>~' Seawater voluume: 125 bbls ,".::'.' Cumulative seawater volume: \. ,~ I. '- 5000 4500 4000 3500 3000 2500 w ~ :;:) en en w ~ 0. 39228 bbls Slurry volume: 672 bbls Cumulative slurry volume: 237477 bbls Slurry vis: 34 8.5 2000 500 500 000 0 0 ~ ~ ~ ~ ~~ ~<o ~ ~c;:) ~ ~ ~ ~c;:) ~ c;:) ~ ~ ~ ~c;:) ~ c;:) ~ ~ ~ ~c;:) ~ ~c;:) ,,~ ~ ~ ~ 5-::> ~ ~ ~ ~ \S~ \S~ \S~ \S. \S. \S. t.;.\¡) t.;.. t.;.'Y t.;.~ ...:~...:. 1.? ~':' ~'Y ~~ ~~~. rs~ rs':' oj'Y oj~ oj~ oj. ~~~. ~. ~'Y ~ry t;.~ ~'? ~~ \S~ \S~ \S~ ~ ~ ~ ~ ~ " ~ " " ~ ~ ~ ~ ~ " ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ TIME Pressure BPM 00 (j :Þ Z 2 m a <=> Ç') ~--! ~ o r'--' c::J '=' ~ ~ Injection by Swaco No annular pressure ~ njection #244 "~~ -- ::i Q. m 4 3.5 ,.;- 2.5 1.5 1 2 ,...... ., Highest :p:ressLir~ -:'- .-,. '. / ';f:~~sl.~~ '. '-~'~.'·:':,:'"V:-' -, .~ o. r .' Seawater Volume: 106 bbls Seawater Cumulative: 39334 bbls Surry Volume: 187 bbls Slurry Cumulative: 195353 bbls Slurry wt: 8.5 Slurry vis: 34 January 9 2004 ~.\";.. ~. ; . _:~.. ~:~~,:.:~ '.:.~:-:"-,~~;..:: .,.. ..:,.,;".. " -.' ~.~. . ~: I" .~ .,:-...;.-. _ '-. ",1 " . ~ .: ~ J -- "- -' -r;"; "'.-. .:t~~: .'~;' """1 ,~ -, ~~,~ ; . .,; .,- . njection well RU-D1 · : ", ·'.··"::;~r~t~ø~~~'. No..post':::~,iE' ';c:',,: ~ .' ~ .' ;.~:.,. .!:~. ..,:..\~.¡.~.:~.'"; " 5000 4500 3000 1500 Q) ~ :J ~ 2500 Q) ~ Q. 2000 4000 3500 '~ 0.5 I...",~. -,-' , 1000 500 0 0 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ b ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ \!J':> \!J':> \!J':> ~~ ~':> ~~ ~~ ~- ~- ~ry ~«y ~n;3 ~n¡; ~~ ~~ ~- ~. oj':> oj~ oj. oj- oj'Y oj«Y ojn;3 \!J':> \!J':> \!J':> Time Pressure BPM fJ) () p z :z m a o Ç) --I ~ ~ f',) c::> c::J ..þ. C: , ~- -- Injection Well RU-D1 Injection # 245 January 13 2004 5000 4500 Highest Pressure 4360 pg¡ en () ::Þ Z Z m o o CJ -f I--' ~ N c:> CJ .,po. 4000 3500 3000 ~ ::s tn 2500 tn C1) "" a- 2000 1500 1000 500 0 Start Slurry >. / J7" / Start Post Flush " Seawater Volume: 137 bbls Cummulative Seawater Volume: 39471 bbls Slurry Volume: 152 bbls Cummulative Slurry Volume: 237816 bbls Slurry Wt: 8.8 Slurry Vis: 54 Injection By Swaco No Annulus Pressure ~ ;'1 I I I I I I I I I I I I I I ~ r-..Ç) r-..Ç) ....~ ....<0 ..'\ 1'S) l'~ l'~ ~ r-..~ Ç) ,,~ R) ("\~ ~ ~ ~ Ç) ~ ¿.Ç) l'~ ~ S:> Ç) ~ ~ ~ \:S~ \:S"¡J \:S"¡J ""r ""r ""r ",,:J ",,:J "t>\.Y ,,1,~ ,,1,Y ,,1,~ ,,1,' ,,1,'Y ,,1,'v ,,1,n¡3 ,,1,'? ,,1,fþ ,,1,~ ,,1,~ ,,1,:J ,,1,Y ,,~~ ,,~ÇÇ5 ,,~~ \:S~ \:S~ \:S~ Time I-Pressure -BPM I Page 1 --- - 4 . - 3.5 -3 ..--- - 2.5 2 :E a- m - 1.5 - 1 - 0.5 ~/ o (J) () :Þ Z z m '0 o C"') -I J-l «:::) ......., C) c:> ..þ. Page 1 Pressure BPM Time ~ ~ ~ b ~ ~ ~ ~ ~ b ~ ~ ~ ~ ~ b ~ ~ ~ \:5':3 \:5':3 \:5':3 ..;.ç;5 ..;.~ ..;.~ ..;.'Y ..;.ry ..;."ß ..;.?:5 ..;.~ ..;.þt ..;.:.; ..;.:.; 0'':3 n·ç;5 \:5':3 \:5':3 \:5':3 , , , , , , , , , , , ,v ,v o 500 1500 Q) ~ :J ~ 2000 ~ 0. 3500 2500 3000 000 .;t,:~:i . ~ . .; ~ .~!. ~. : ; [{:" {; - .¡i. :'~:: --? ,'~f; -; ,."-f ;;<>-~ - . . -:'.: ~: :~= ~- .. -:" o. ..::>.~.:-. .1" . :, . . .or .- .~.. . ' . '. -~ . . - . .' ..' I . "~" ~ .' . .~ _N_O~ p~;t:ft~~h.:·_~_:-/ -- -. ~. . . -... ~ ," .,'- ':.'. '~.a--~ , ~J_; 'h . ..-~~:'- :ft- . '~..r" ,- .~::t·~·:-·~~ - ~.:;.~~:- - j,,' , '. ~c~ -. ,-.' . ~~I,'~ ~".- Slurry wt: 8.4 Surry Volume: 190 bbls Slurry Cumulative: 238006 bbls Seawater Seawater ,'( r ..~. ',ti.:"..--t'-· ".,,';--" - ,:-:" ~'~:~'?/ -::~' .-~:>''; .~~ , , I , '.;.~ "S. Volume: 0 bbls Cumulative: 39471 }!:E'~tf~~~it~~J~~f~t ';-, ';':' e}:1ëtti¡¡! . . -" . - :...,,-.! . /.~ . . :w,,;':" bbls Slurry vis: 26 o 2 3.5 0.5 2.5 3 1 1.5 ::æ 0. m ~ '--- 4000 '....- njection well RU-D1 G 1 --- njection #246 January 25 2004 Injection by Swaco No annular pressure 4 ~. ~-' Ct·>-~· Injection #247 Injection well RU-D1 January 26 2004 Highest pressure(461 0) Injection by Swaco No annular pressure 5000 4500 ..... ""- Start Post-Flush / 4000 (j) () :Þ z z m (] o ç") ~ J--\ c:;I '" c:> c::> ..þ. 3500 3000 Q) ... ::s t/) 2500 t/) Q) " ... c.. 2000 Start Pre-Flush 1500 1000 500 Slurry wt: 10.2 Slurry vis:250 Start slurry flush Seawater Volume: 160 bbls Seawater Cumulative: 39631 bbls \ . Surry Volume: 665 bbls Slurry Cumulative: 238671 bbls o I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~b~~b~~b~~ ~ ~~ cy~ cy~ i}~ cy~ 'Y~ \) ~<;$ ~çS ~~ Y"<;s,,~,,~,,~,, ~,,~·h·55(\· ~.CY(\.?3(\.~(\. :"h.:<;Sn:.~ ~n:. ~n:. ~n:. ~.)~<;s~ ~~ ~~ ~~ ~~~G.:<;S(...:~...: ':\J}~...:~...: '?(...: ~(...:~+...:ç;5r"': ':\....: 'Yr...: '?r...: ~r"':~.) -J -J -J -J -J -J~'V", "" "" ~'V~ ~ ~ ~ ~ ~ ~V""'V~V~V~V~V~J""'J~J""'J""'J""'J"" ~ "" "" "" "" ~.)~.)~.)~.)~.)~.)~.)~.)~'V~'V~'V~'V~'V~'V Time I-Pressure -BPM I Page 1 .~ 4 '- 3.5 -3 .---- - 2.5 2 :e c.. co - 1.5 - 1 - 0.5 --/ o ~ G,-.--, '---' njection #248 _/ :E Q. aJ Injection by Swaco No annular pressure - 4.5 . ...-:' ',-;':",,--' ,;':,--.: - ~"?~I.- . ..:,~::{~,:: 4 : : ::~'~'~~;I' ¥(:.¡i-{ ~ -\_~\..~._, ,. .('~':~-:'::;~: '~~.~:;, /::'~ 3.5 ~.~.J .--- 1 ,- 0.5 Slurry vis:250 10.2 Slurry wt: .',.." ' RU-D1 .,"'-:' . :,:":Lt!d. ,.". c' ~,' ,,''''' ~...··.-?~ti~¡;f:::~~: . 3,·:~tX? ' . .,' ,r" ,~, .,~,'-" " : ,?~ ..' .,·':~~ttV;f-,-' . :: "" ," ..,.,,- . 5 ., ; .,:f~~~~f~:- J~(t slurry flush"'; ~. -"'< ~- ., ;: ::: H . . ".;:;{:~~,~" : ")-A(:"'; -;¡~_. " _~ ~"-'.JJf ": ~ . . t·... .~~ . . . ~. ~ - .... - I 'J-J!irr'¡' I 1'1 I" I - 2.5 ~2 1.5 3 -, , " , '-. -~_ P . I, _ ._:.~;;.:'~ L~_"".~~~,.,<:::;_:,_,:,~,.: ~, H ig,h,~~~~pre~sui.e.(~~qQt ~,~"~~:~'. ,::", ..: ...... ...., ....\",. ;,:,:,:)-< ~f~·;:~Zé':·,:::~:',:·.~~ - ". -. ... I':: - .: .-..~ ~. ... ", ·:át~:~,~P-Þ;t;~ju'~h'¡ ; ....~:~~. ,~:':: ,":;, ~ I,''''' -:,. - ," .'~_.~_~:::' : ._. P", .: - . II ~ - -. . January 27 2004 . \ Volume: 160 bbls Cumulative: 39791 ;:~~i:~¡¡'~¡r: ...: ." '. . '~:i;)I;:~:f;~;;XX,}~ " . :'~~·t:::~};~;~i~¡f':.: 1.-".... . Seawater Seawater ! ¡;, :····-r - ~~~-~ t.:.-.~.- _ L;; r·.:'~ ~~ njection wel .' ·.L~~ .'.~ ......!" ~(~f. . 4000 11II ~ :::s ~ 3000 ~ Q. 2000 -. 6000 5000 bbls Surry Volume: 794 bbls Slurry Cumulative: 239465 bbls o f ~~~~~'\~~~~~~~~~~~~~~ Time Pressure BPM Page ~' , ~:ta~:pre-F.I~Sn ..:.>:.:-.-.:..... ..... ,<~ ~:;~~::.Ù.·l~· '., ." -;....., . 000 o (J) (') » z z m o o o --t ~ <:::) ,....., c:::J c:> -Þ '-; I njection by Swaco No annular pressure CI.,~/ njection #249 January 29 2004 --- '~~~~~if~ :.5 'i~ "'-~'~~Š~1<~~;:\ '> >~: ':':!~~:'~~'" :.:".:--. . -.: '.'~ '. ~__:. :.r..¡ .~. '7 - - - '-.~' - '.... 1-1 ...',; '1', .' 4.5 :~~~~?;.~,~:'~,:'~;-r ' , ,: ; ',' '~:,,-i:~f~~ }; ~ - " ., ,~.--.. ~ ; - .- - ".. ~_., Æ'·..':·'··,' , -. . , ,.....,... . . .", ,- RU-D1 ...~.-::-/" ~. ,. ,. ..' .'" :~." .' .:..~ ,~,' ,,:;F~ ':;;;~~, , '~\'~, ,~ ~., .~. ,".., ç r . t".i , ;.. ~ ~. . T ".\.. \:....... .r.,' njection wel r~~}.I..':? ~: . 1"'... ~~. :.: .:';\'~ '~~~'. .~ . :~:;."!:.,: . . ~ ~ .. . , ·i~··"rl. I.i. .(.... . .' . . ..~ ...~. ....... ;, ~.~~~. \. .~ 3950 3900 --- :E a- m -3 " - 2.5 -2 1.5 < ' ';,", ...J.-- . " 7'.·· ,., --. . , , :> '_~';:, -:;:: -;:~\.~~ ~.\... ~'r .:~:'!:~~:~)T ,'. .~ ~ . :-:.~- '\ .'"< " , :"-1 :,:~·_.~~~f:·.·: ." ):{ £i :!~_~ ~ -L~': ~....~. ¡_- to. .-~~;-{:~. ·r';". . i. > '.I' ;,:; :~.~ t.·.· ~!>::'~': I .. ....... :,' :: -r I .; ,~.. ;;.. .¡\ ...- 3850 3800 (1) ... ::J :z 3750 ~ a- 3700 Volume: 0 Cumulative: 39791 Seawater Seawater 1 bbls ; ,'" 3650 '-- - 0.5 ,-, ;} : . ~ Surry Volume: 400 bbls Slurry Cumulative: 239865 bbls 3600 o " ~ n'b' "V' Ç) n'~ "V· ~ n'':) "V· n'~ "V· Slurry vis:Water 3550 ~ .~~ ,,~ ~ .O;)~ Ç) .~~ S) ~ (:j<? ". ~. ~ry ". ~~ ". "rr.,ç;3 "rr.,~ '" " " " " " " Time Pressure BPM I Page Slurry wt: 8.5 CJ'J () :Þ Z ;2 m o o CJ -{ J-=1 o ,......., <:::) c:::> ..þ. <:....~/ Injection by Swaco No annular pressure Ci'_'¡ njection #250 January 31 2004 -- -- :æ a.. OJ 3.5 1.5 1 - 2.5 :~ 3 ,.-2 .1···· - .,. ~~I , ~-....::"':: , ' o .., 0 - .-'? _I':~. .' L : - .-. .-'..1' ": ,''A'~_~.o ' ~ - '.- , -. ;. Seawater Volume: 20 bbls Seawater Cumulative: 39811 bbls Surry Volume: 125 bbls Slurry Cumulative: 239990 bbls .\-; - , " ,-,: '~ ~~o~ ~)t~. Start Slurry, -... , ", f :' ~ b. .i:....!f~:.-:.J:,;\~~i~¿-;tl~'"(:· ,=_ :'1., '_..:..' _ - , $.'I.h\ o~l;iq:'":_~~:~.~·f 0 '~, ": ~;~'J~~;~~W~~j9bèst: Pr:Ðs~Yr:e(42-20}, :.:~lJf~~7 , '·.~ai~,;~~¡~iI .: '~.: ',I; :r'. .:' :',;:;(~}< ¡,::,- . ~:;~!- .:~~~ ;~' --::1-:'.-- ".0: ' _ ...\. :, -, r·o . l -'_":~ :.:-'-~ .._-,._~~~.,.." .' ..... ._< .", ~ " njection well RU-D1 I : ,<1 ' ¿_~tartPre-FI~s,h 4300 4200 4100 4000 3900 3800 3700 3600 <1> -. :2 fn fn <1> -. a.. ----- - 0.5 Slurry vis:Water Slurry wt: 8,5 .~ ,,?~(~> ...-...... .' 3500 o I ~ r.:5 ~'ò r.:5 ~O; ~ "- .<::>'), .<::>0;; .~ . ,,<::> .~ .0;;<::> . b-,<::> ~~'ò r.:5~ ~';3 ~~ ". ". ". ". ". ". ". '" ~ '" " " " " " " "- "- " " Time Pressure BPM I Page 1 . . 3400 (f¡ () ~ z rn a C> C? --1 i-" o '" c::;:) C) ..þ .~ :E 2 a.. en --' I-Pressure -BPM I Time r-:. <oO;J ~,-,' r-:. <o~ ~,-,' Ç) r-:.~ ~,-,' ~ r-:.t-.\. ~",' ~ I\.~ I\.~ro /""\.rf' ~,-,' S:) r-:.Oj ~,-,' ~ 1\.':> I\. ~O;J I I\. ~"v " I\.~ ~ I\.~ o Slurry vis:Water I , ~. Seawater Volume: 20 bbls Seawater Cumulative: 39831 bbls Surry Volume: 143 bbls Slurry Cumulative: 240133 bbls 0.5 1 1.5 " ' , , ' ~ 3.5 . -". . .- ::'..' ~'" /,:-' . -' . . ~ "'. .~ .; .. :. .";'. - ~ -. '.".. . . - .,<~;,:<,::\>'-'., .. ,:",;;:),: :" - ", '. - '" ;-. -. - ",,' --"\ " " "". "".... ' /". ""':': C.'.' :.: -." " "''':''~'' .', '. '".':'." ·':.'Y¥5<1i,·. . ' '. .' ,', . ,',' "i~:',~,~,,--,;,~:,<,¿~~:~.t~rfslurry':F!~'Sh' - , .·;_~i' r.:.-'~~"~ - , - ~'-r:'''!: .' " 4 February 3 2004 Injection by Swaco No annular pressure Injection #251 -~. '$t~ri{Rr;~~;~f¥;f:~\7;( , , .:::·.:'~t~'i~!~~~ï;j" ".' ,:;;.;i,.¡;. ;ij;';¡: '.': . Injection well RU-D1 s;:) 1\.9 3300 3400 3500 4300 4200 4100 4000 3900 (1) .. ::s ~ 3800 e a.. 3700 3600 -' Ch o » z z m o o C"') -I ~ o "" c:::> c:::> -þ " / '- -~- Injection #252 ~ 4.5 3.5 2.5 4 3 I njection By Swaco No Annulus Pressure 2-7 -04 ~, njection Well RU-D1 6000 '." '~~!1ßlur.ri;:~i~1<:~ ~\?"'. :~:.- , f. . Jir(fl'~-;/.:. ,.. ' ' 5000 :.;£. ','~::-:::;:JY" ~t~';~~:'i~' ';1I0-..~:.j~:~~r~:~/,.:' "':"";t<~~~i;;c... _' I.. 'fi. "' - .' ':::.~, '.' ,;r ;,,; '~:.,':,' , .~.'" . .».~~~. . ~ ;...~~.. . , . "'J"" . j--:~, . '. " . 4000 e = U) U) G> ~ c.. :! 0- m 5 2 124 bbls. Slurry vol 742 bbls. Cumulative 240875 bbls Slurry Wt 8.5 Slurry Vis 34 Retort: Oil 70% Water 29% Solids 1 % vol Seawater : ~ ~ 3000 2000 '---' 1 0.5 o - o I .., I I ~.. ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~N~V~Ø~ ~ ~ ~ ~ ~. ~. ~. ~. ~. ~. ~. ~ ~. ~ ~. ~ ~. ~. ~ ~. ~. ~. ~. ~. ~. ~. ~. ~. ~. ~. ~. ~. ~. ~. ~. Time Pump Pres BPM 1000 - -,.~ ~. .. "" I.:, ~ . ...~..::? ;::.~~ :~:< í~ :: . ~{ {f; (') ~ Z iT1 a o n -t 1-4 o N c::> c:::> ..þ 5000 Injection Well RU-D1 4500 4000 3500 3000 ~ :J f/) 2500 f/) ~ a.. 2000 1500 1000 500 ~--- (j) (") :Þ z z m o o CJ ....-t J-I' c:::t '" c:> C:) .þ -- -~ Injection #253 2-12-04 Injection By Swaco No Annulus Pressure 4.5 -.. ..-.. / Highest pressure 4440 psi Shut down to check inj line ,. -4 Start good 50 vis slurry ~ - 3.5 - Production Flushed Well -3 Seawater vol: 21 bbls Cumulative: 39976 - 2.5 :æ: a.. m Slurry vol: 255 bbls Cumulative: 241130 -2 Slurry Wt: 9.0 Slurry Vis: 56 - 1.5 Retort: Oil 9% Water 89% Solids 2% - 1 - 0.5 '-" o I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ; ; I I 0 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~~~.~~~~~#~~~~#~~~~~~~~~ ~.:.~ ~.:.~ ~.:.~ ~J? ~.:.~- ~.:.<? r.:.\¡) r.:.\¡) r':'~ \Ö~ \ö":' Qjf); r.:.r'} \ö~ \Ör;; Qj?5 Qj~ \ö~ \ö~ Qj<? \ö<? ~\¡) ~\¡) ~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Time I-Pump Pres -BPM I --' ~' 'L3.5 4 3 Injection By Swaco No Annulus Pressure ¡ '. -.---;. ~ ~ , '"--' njection #254 2-23-04 ..;r.:" ~,t)Htq~~t:1.'to r~p:~9~1~~ction valv~ _ _ Bleed off air ' - fe··.. ~ ~.,~fitifi~:,;~"~~~'::·'>;:~'~:'::: /,/.; . \~ '---, J0;Y~:::~, S~tt~IJ~Î¥ ,'" "\', · : " '; ':. -:'~j9~este~~~;42~O psi '.' 'start.sea Water ]; .:S,~~~í'~ate~:~·"';I:'."; .' '12.',';' Po"t-FIi,,,h .. : ~~:~J;f~~~~ ~,; r ;?b~~'~ ;,~ _,h Well RU-D1 :''';;}~~:~~;:;.:·'·.:'-~};~í~ ":.I,., _, ., ,,' ',......,¡, '.,í!..._ t;,~]<~:';',,",. <~:~~;,#tf:~ Ht~~~¡:~~~m~ njection ',---- 3000 4000 3500 4500 :æ 0.. CD 2.5 2 ~ 140 bbls .: ' ..a'-, Seawater vol <t.\:.. ~;.~'( 1~',-' 'f:): -, ' ';"-. - -.. ~ ,. ·':-:.;-··t.. '- . ~\~;, iLl ~~ .:. - ~:~'r"'~I,' 1.. . l .,..: . y"" -, i,....- r. . ~ - .-.. . :1 . ._.~...~ 2500 2000 ~ :J o o ~ 0.. -----. 1.5 ::,0.5 1 \.: - .. " Cumulative: 241670 Slurry vol: 540 bbls : .: Slurry Wt: 8.5 Slurry Vis: 50 ';, Retort: Oil 9% Water 90% Solids 1 % 1 -=t:....,.,..',.. ", -'.. . " I . . ~ . . ';!'-.-;,. , . :-- . :. 1500 1000 500 o o ~ ~ <0 <ò Q) f1, ~ (\ ~ " ~ ~ ~ Q> ~ ~ ~ ~SJ ~_" !), ~_~ â:) ~.9.>~.9.> ~ ~ b (\ ~ " ~ <:> ~.:.." .~ .~ '~.A,I\: ~I\) ,f); '~r;,r'Ç .A'~ ~.:..~ n:.0;} '~r;,'5 .A'~ ~.:..~ n:.~ ",:"J r;,"J .A'<:> ~.:.."J n:."J ",:"J r;,"J 0:.'5 r.:..Ç) ",:Ç) f'\.Ç) r-:.'5 0:." r':"~ ...:" ,"J' ~' ~. ~. ...,' '!J' ~' ~, ¡-J' ,-,' ;:!J' ;"'J' ~, ~J' :,' ."J' :"J' ..,' ~J' ...,' ,!J' ~J' .,' ¡-J' "'-" ~' .",,' ,V''J' ,v' ,,,,' .",,' "Y "fþ ,,~ ,,~ ,,~ qj'? qj~ qjf} qjf)) qjfþ qjt:!- qj<? C6~ C6'? C6~ C6Y C6fþ C6~ C6~ C6~ "çS'? "çS~ "çSf} "çSf)) "çS~ "çStf "çS~ ",,~ ",,~ ",,~ ",,'Y ",,~ BPM Time Pump Pres ~ (f; () » :z z m o o CJ ~ J--.\ c::> J'..,) C) C) -Þ> ".--- Injection Well RU-D1 5000 4500 4000 3500 (fj ("J » z z m o o Ç) ~ }-J- o N c::> c::> cþ> 3000 <1> ... :s In 2500 In <1> ... 0- 2000 1500 1000 Start dirty water - ~ CIO pop off .~ Injection #255 Injection by Swaco No Annulus Pressure 3-2-04 '" ... '- - Highest pressure 4570 psi r,- ...... Start post flush / J Seawater Vol: 125 bbls Cumulative: 40241 bbls Slurry Vol: 409 bbls Cumulative: 242079 bbls Slurry Wt: 8.4 Slurry Vis: 32 Retort: Oil 1 % Water 98 % Solids 1 % 5000 j I I I I I I I I ~,?ro ~f ~,?'ò <ç6,?Q) f>~~ ~~ C\~ ~~ C6~ro ft5~ t.:.t>~ ~~rv ~~O;) <ç6<t! f>~ro ~~Q) C\t>Q) t:;.':>" ~,:>O;) rò,:>O;) ~~ ~,:>ÝJ t:;.,:>ro çS':>'ò g.j~~ ~~" &)~O;) t:;.~ ~~~¿~~~~~~~~~~~~~~ðð~~~~~~~~ v v v v v ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ " " " Time I-Pump Pres -BPM I .~~ 4.5 -4 - 3.5 ~' -3 - 2.5 :i 0- m -2 - 1.5 - 1 - 0.5 ~ o .-'(', ';', :,~. , I I' I II I II + ~~~&~~~b~~~~~~~~~~~~~~~~~~~~g~~~~~99~~~ ~:.J ~y ç:j:.J g,;:.J tiJç;s ç¡,':::> ~r;:;; ~~ ~':::> r3~ f.6~ f!5~ ~~ ~~ tiJ~ ç¡,~ ~~ ...:.,~ ~~ r3f} f.6'Y f!5lJ;...:.,<'Y ~'Y tiJ'J3 ç¡,fþ ~~ ...:.,fþ ~n¡> r3~ f.6~ f!5~ ...:.,~ ~~ tiJ"f- ç¡,~ ~<? ~<? ~~ .I\.rp .I\'Oj ;\"t$. .1\' t¡y. ;\"<ö .I\'~ 0:..'5 0:.. ~ 0:.. ~ 0:..'1; 0:..f"'Ç 0:.. OJ 0:..tJ.. 0:.. ~ 0:..<Ö o:..~ r-;.'5 r-;. ~ r-;. ~ r-;.'1; r-;. rp r-;. OJ r-;. ~ r-;. ~ r-;.<Ö r-;.~ ,'5 . ~ r-;, ~ .~ .f"'Ç ,OJ ,~ ,~ ,<Ö ,~ .'5 . ~ ,~ ,',',',',' " V· V· v' v' v' v' v' v' V· V'~'~'~·~'~'~·~'~'~' ~'~.~'~'~.~.~'~.~.~'~.~.~.~' Time "-- <n o :Þ .z :z m o o C-) -f f.-\ o ......, C> c:::::> .þ. 5000 4500 4000 3500 3000 Q) ~ :::s fA 2500 fA Q) ~ Q. 2000 1500 1000 500 .~ '~ Injection #256 Injection Well RU-D1 Injection by Swaco No Annulus 4 . ~ 3 -' 3-5-04 f~W: dl¢¡wa,ter..:,,~. ,", ." '~" -,,- " '; .,,};~;~, ,,", ' - ':'7-~:::?>;.·' :', ' , , , " ~tart POS~fluSh I . . . .' .. ~'.' _".' I .' ~ .: I . .... . ~. 4 : _ ~" ' ". ' . .' \'.:r.;< - . . ',', . .~ . . '. ',", , . " ~, '. '. ~ 2.5 2 :E Q. cc 1.5 . -I .. . . - ~ - ~ .. Slurry Vol: 641 bbls Cumulative: 242720 bbls Slurry Vis: 32 1 . , , " Retort: Oil 1 % Water 98% Solids 1 % 0.5 --- o I-pump Pres -BPM I -' -' -' 4 2 :e 0.. en 1.5 -- 1 '- 0.5 0 ,¡~JtOWd~S;for~~i~~rfl~~~rgep~JO,~_ _ 3.5 ~ - . -< - - - ~-- '.::-- .: ;~::_:, -_.:-:;..::~-'..'--'.' .:-;~ _ ::{ . _ ... ~~;_~.;-','__.~?:T~-.~;_ ,::,:_ _.: . ~. . _" -.. _~ :>:i ", , - ';"':'"';¡'-Á- - ~ - . - 'Ç_ ~ .. S".:~~.I --,J"". , ~.J.' .' - , ~ co:, ' --~l,~~;~;;~:i:;}}n - :' -~ : , - - 3 , ,- " Prod,Jj~li_Øn:¡finished post.:flush ~Ftci;í!t·~~'VJ.e h~~ ~ 1'505-con~ 'necf.ig:b{!ê~,king . - '.:- 2.5 Injection by Swaco No annular pressure -~ njection #257 .~~~ ~ ..._.~,,~(#.~~.. ~ - . : :;~ ¡:r~~:~}: . Or; : . ~',..:' ..: .. ~; _... ~~~~ -, .... -: .: _ :~~s ':: ~~þ~C;~, Seawater VOl: ;¿;;s DO IS L;umulative: 40385 bbls , ':'o~; " ;',"1:;:r:' >~- -:+ ~ r:1~:~2~;;c Slurry Vol: 1242 bbls Cumulative: 243962 bbls . -:: :.., ." ..:.- :. - ,.,,:::~:~~, Slurry Wt: 8.4 Slurry Vis: 30 ,', Retort: njection ,NAII RU-D1 .. -, ",. - ,.' .: . ~ \'{cl 6000 4000 3000 5000 (1) ... ::s tn tn (1) ... 0.. Solids 2% o Ç:) ~ ~ ~ ~ s:::> a, ~ <;:) !'), ~ Ç:) R) f1, K> (\ ~ ~ ~ 9 ~ ~ ~ ,S;) ,i)" i-.<:> ,2:> s:::> ~ (\ 2> ~ ~ ~ Q> " ~ K> r¿~ fÓ~ rò~ ro~ rô<t;> ~t:;S ~';J ~c:;s ~~ ~~ (\;.~ ~~ ~'Y ~ry ~'Y ~f) (\;.'? ~~ ~'? ~n¡5 ~~ ~~ (\;.~ ~:J ~y ~y ~y 'bt:;S ffJ';J 9,j';J gSC:;S <jj~ ~~ 'b~ ffJ~ 9,ji} gS'Y <jj'Y r":~ r..:<.? Á-t:;S N':' Á-'Y Á''? Á-~ ~<t;> 'b';J o:.~ 'bf} 'b'? 'b~ o:.<t;> n.';J n.~ ~f} ~'? ~~ n.<t;> r:s';J r:s~ r:sf} r:s'? r:s~ r:s<t;> ..:..';J t..:,~ t..:,y t..:,~ t..:,~ t..:,<? ("\.';) ("\-~ ("\.y ("\'~ ("\'~ ("\-<? ~~~, ",~, ~\ ~ ~ ~ ~~ ~ ~ ~~~~ ~ ~ ~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~v~v~v~v~v~v Time Pump Pres BPM 97% I Water 1% Oi ,- ; :~ - ~ ' '\;: _:~ j[ 2000 1000 (j) () p Z Z ,,, o o C"J -t ~ C) '" C::J C) .þ o ,- 0 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~~#~~~~~~~~~~~~~~~~ð~~~~~ #~~~~~~~~~~~~~~~~~~,~~~~~~ Time (}) o » z z rn '0 o CJ -I ~ c:;¡ N c:> CJ ..p-, 5000 4500 4000 3500 3000 ~ ::J rn 2500 rn Q) ... Q. 2000 1500 1000 500 ----- ----~ Injection Well RU-D1 Injection #258 03-14-04 Injection By Swaco No annular pressure 4 ~ -,:~;: ..... .'., '..>-:-:r~::·~·,':~-':,,·i"\::\~t:~..?i \d'r'f~~,;-":.':'-~~:~·.~"-~ . 0 ~,- . - . -' "StàC-td'rtý f): 'd" O^.·~! .; ..-, .' '.: . ~",: " ",,' , ,""\'~~'.~'~;:f).I~~,. ~.' ,~::_~~-.~::~~~~< _.,' _~_,~"r, ':>. ,. , ~. ~..." ,". ...;ø .."--~ ~'- . .' ~.~-. -I>'~' . '., ..- - ,:.:', ,'. ,~~:'~:~.;--~\':::'~ ,·-·:~"'~~.:¡rj:.,,:::~:~~::·:t~..~ " :-'>"'~,:,' ;~ ,: :" < " , i ,; ;,". ,;:". ,,~- : ':. ~-' . )~_ ; ~ .;:,. ~- J~ _: _ <._~.: ;' . , . :1. ~.' '. ~. :.:Hi~ipe~rPfessure 4660~psi _., ,'- ' . ". ,:.. ;'Wo"·-· - . 'j:'-: S_tart ~ost'~- , , - . '". ... ... - 3.5 -3 " ,0 . '. .',' :.. . . I ~.. . . .,1 ~ _ .. __" : t'. I ~. .';,... , -. , ' r.', ~ ' ~. .~~::: .". :'.. . " " . - . ", .' , <i': -..,:~ '" . .: r _ . . I .., ~ .' i· '.J I .,' - 2.5 -¡.... .' . ".',~.:. . ;- . ' . . . ~ ,.' .. '-; Seawater Vol: 125 bbls Cumulative: 40510 bbls ....-. ~ ,""'. i', .' - .. '- T.: ......:.. .... :~, Slurry Vol: 361 bbls Cumulative: 244323 bbls ," ·.1.(..... ·1;' . . .~.,.". '. " , , < . <,.~ ,:'.i~Ù::::>,{,:':-_:~::,t: Slurry Wt: 8.3+ Slurry Vis: 29 Oil 1 % Water 98% Solids 1 % ~ 0.5 I-Pump Pres -BPM I '-"- -.-' 2 :! Q. to 1.5 -~ (f) () :Þ Z z m o o CJ --f ~ o 1'0 C=> c:::> .þ, -~ 5000 4500 4000 3500 3000 f ::s en 2500 en Q) .. Q. 2000 1500 1000 500 ~' --' Injection #259 Injection Well RU-D1 /;wa;hwater + brine r ,- Injection By Swaco No Annu!ar Press~re 4 Highest pressure 4700 psi____ ... 03-22-04 , '- - 3.5 - - -3 J --- - 2.5 2 ::i Q. a3 - 1.5 ~ , :r /" Start post - Seawater Vol: 219 bbls Cumulative: 40825 bbls Slurry Vol: 501 bbls Cumulative: 244824 bbls Slurry Wt: 9.4 Slurry Vis: 38 Retort: Oil 1 % Water 97% Solids 2% - 1 - 0.5 ---- o - I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ¡ 0 ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~9~~~~~~~~~~~~ ~~~~~~~~~~~~~~9~~~~~~~~~~~~~~~~Y~Y9~~~~~~~~~~~~~~~~~~~9~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ r>.~r>.~r>.~ r>.Yr;.~r>.~ r>.~ r;.~ r;.<? r::5~r::5~r::5~r{~r::5Yr::5~ r::5~ r::5~r::5~r::5<? ~~ ~~ ~~ ~~ ..;.Y~~ ~~ ~~ ~~ ~<? ("~n'~n'~n'~ n·Yn·~n'~n·~n·~n·~ ~~ ~~~~~ry ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~ ~ ~~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~v~v~v~v~v~v~v~v~v~v~ ~ ~ ~ Time I-Pump Pres -BPM I --- ~' 3.5 4 3 .~ tr,,; I Injection By Swaco No Annular Pressure .( Highe5tpre~Sf8 4600 p~ '- ~ ~ njection #260 4 Injection Well RU-D1 . ~/: ::,;' eawater Vol ,.; ~~, urry Vol .,~- 5000 4000 4500 2.5 20 bbls 3500 Cumulative: 245534 bbls 710 bbls 3000 (,) ... ::s tJ tJ (,) ... Q. :æ Q. In 2 Slurry Vis: 51 9.5 Slurry Wt: 2500 --' 1.5 0.5 o 1 Solids 2% o ~~~~~~~~~~~~~~~~~~9~~~~~~~~~~~~~~~~~b~~ ~~ t:;.~ r:s~ rô~ !j,':' ~fy t;.Y ~ry rõy (f,<J; ~ey .¡,.'Y r:srp rô~ !j,n;> ~~ t;.~ ~~ rõ'? (f,~ ~~ .¡,.~ r:s~ rô~ !j,~ ~~ t:;.:.J ~y rõ:.J (f,~ ~<9 t:;.Y r:sY ~9 r.b9 9J';3 ~'? ...;.9 ¿;,';3 ,,';) ,,':' "ry "ey "n;> ,,~ ,,~ ,,<9 ,,~ q;~ q;';) q; ':' q; ry q;ey q; fþ q;~ q; ~ q;<9 q;<9 ÔJ~ ÔJ';) ÔJ ':' ÔJ ry ÔJ ey oj n;> oj ~ ÔJ ~ oj <.;3 oj ~ ~<:s9 ~<:s';3 ~<:s ~ <:sf)) ,,<:s CY~<:s n;> ~<:s '? ~<:s Þ' ,,<:s ~ ~<:s ~ Pump Pres BPM Water 97% Time 1% - o Retort: I ¡' ~f~. ( ...... ~~:} ;.-:;r:1 ;'!i 2000 1500 1000 500 (j) () ~ z m a o n ~ )-t <= ~ d .þ ',--- ('J'> «.J ~ :z m tJ C> CJ --t ~ c::; '" c:> c:> ..þ., 5000 4500 4000 3500 3000 Q) ~ ::I f/ 2500 f/ ~ c.. 2000 1500 1000 500 ", '.' .... . ·,~::~·,~t:f:~;·(: :':". ..' ?):"~þ':~~r:!iu~,~ : ;::.":~~~' ,···,:.:!,¡,~:~f.'_:,..,l.'~,·,;;,:.;_:.".,'_:",:~,:~,:;,-~;:':SH·,tlag'. rth:','e.~.:t.,:S,'pt:rfel..Us, .Ss.hu_. ':r"e·.· 4' 60' ,0 ·p"'s·.· .17, /~ .,":,-',>,".':;~ ,': ~,.?~~~~:~:-::~"",'" - ~, ,£ :; ",. . " .,- '," ,',' ,;~?: ~! !\~.'.;'~-~> :::;;::~:.~;~:~>.:':.' ····:".:f~~(f~¡..·.~ ¡\ i> . :.~. :~' . ~.~? -~\ . .. .' '.Of :, .' .> .",; .:...~~ . L" . . " -' '. . -.~ Injection # 261 Injection Well RU-D1 3-30-2004 I njection by Swaco No Annular Pressure :.;..."..- <_·.~__~_n.__:!.~:': -:.-..,,,' . .~:"'.: ':'.,~:,,':::':; - 3.5 :.... , " . "'··-.1· ..... . ~ '. , , -3 - 2.5 . "- 0.5 o ; ~' ,- I I I ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ b b ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~ tfJ<? ¿.:.<? t.{? f><t? r;S<t? t:¡,.':3 qj':3 rr.,'? rò'? ~'? ~'? ~';5 ~';5 g.;'? ~~ ~';J ~~ a> [.Õ~ ç;S~ t:¡,.~ qj~ rr.,~ rò~ ~~ t;;.ry ~ry ~~ g.;~ ~y I'(Y '\':.) <t5 <9 <t5 <r;> ro'? ro';J ro';J ro ~ ro ~ ro ry ro rp ro" ro ~ ro 'J:' ro ~ ro tf. ro ~ ro <r) ro <? I'(~ 1'(':3 I'( ~ I'( ~ I'( ~ I'( ~ I'( ry 1'(" I'( ~ I'( ~ I'( ~ I'( tf. I'( ~ Time " . ,; .' '.. ~ , '. .:' : ;'. :' :-.:~;:;: Saewater Vol: 227 bbls Cumulative: 41072 bbls :~~~..._ ";·.õ:J ~ :{~.;~__ -. ,: ': "'~-'. r"· , .~ :,_.,',~:~,:.>,; Slurry Vol: 144 bbls Cumulative: 245678 bbls . >d . .n -,,"~~~.>, Slurry Wt: 8.7 Slurry Vis: 52 . ~". -'. .. .,: : ~ ~"!. , , ._,:);',!~~.:::- Retort: Oil1 % Water 95% Solids 4% : . .: .". -' ~.. - '..:,.. " . - ", . . . I ~ I-Pump Pres -BPM I ..~ 4 .---- 2 :æ 0- m 1 ..~ o #15 Ke: Kedoubt Unit U#1 Injection Well ) ) ~\O d \ 1/ .:J-." Subject: Re: Redoubt Unit D#1 Injection Well Date: Thu, 20 Nov 2003 12:16:26 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Roy Smith <RLSmith@forestoil.com> CC: John D Hartz <jack_hartz@admin.state.ak.us>, Jim Regg <jim_regg@admin.state.ak.us>, Steve Davies <steve_davies@admin.state.ak.us> dO \ - 0 <6 S Roy, My colleagues and I have reviewed your request. DIO 22 does not contain any conclusion or rule that would limit the disposal to 1000 bId and the frac modeling provided was done at 5 bbllmin or 7200 bbl/day. Based on the prior performance you reference, it would appear that continuously injecting the clean produced water could improve the injectivity. In order to assess the injectivity improvement, we request that Forest supply "batch" pressure plots similar to what was submitted in the annual report. Please provide the reports for injections thus far in November. We also request that pressure graphs for the next 3 weeks (through December 12) be provided when they are available. Please call me at 793-1250 if you have any questions. Tom Maunder, PE AOGCC Roy Smith wrote: > Tom > As a follow up to our conversation this afternoon, Forest Oil is requesting > to increase the injection volume of fluid (most produced formation water) > into the Redoubt Unit D # 1 injection well to assist in cleaning out the > perforations of fines/solids, which should reduce the injection pressure at > the surface. In the original permit it was stated that the estimated > volume of fluid injected would not exceed 1000 barrels per day, but was only > an estimate. > > Back in July of 2003, prior to the rig move from one leg-to-another, the > injection tubing pressures had increased to the upper 4,000 psi range. > During the rig moving injection of produced formation water continued, > flushing the perforations of fines and reducing the injection pressure to > 3,200 psi. > > Slurry injection was restarted in early September with the drilling of the > RU # 7 well. Since then the injection pressure has increased to a range of > 4,100 to 4,600 psi tubing pressure. Currently the slurry is being flushed > with seawater from the Cook Inlet, which as you know is not clean or > filtered which also introduced fines into the perforations along with the > slurry solids. > > In reviewing the success of reducing the injection pressure by flushing the > perforations with produced water during the rig move Forest Oil is > requesting approval to increase the volume of injection fluid. The > additional volume would total 2-2,500 barrels per day and would be produced > formation from the beach to assist in flushing the perforations of fines. > The increase in volume would allow a constant injection of clean water and > prevent having to shutdown the injection operations from the beach and > reduce the chance of freezing of the water pipeline coming from the beach > with the colder temperatures. !:\/þ c::¡:. ...,0011 ,c, [ . ';'1' 1 of 2 11/20/2003 12:17 PM ~e: [Fwd: Redoubt Unit 0#1 Injection Well] ) ) Subject: Re: [Fwd: Redoubt Unit D#1 Injection Well] Date: Thu, 20 Nov 2003 08:51 :58 -0900 From: Jim Regg <jim_regg@admin.state.ak.us> Organization: AOGCC To: Jack Hartz <jack_hartz@admin.state.ak.us> CC: Tom Maunder <tom_maunder@admin.state.ak.us>, Steve Davies <steve_davies@admin.state.ak.us> b \ ad-:)~ d--,O (- 0 ~-ç.' I agree with Jack - no AA and get some performance data with well operating in a more continuous mode. Jim Jack Hartz wrote: > You 3 (or You All), > I looked at 010 22 and there are no conclusions or rules that suggest the well > should be limited to 1000 Bid of slurry or water. The frac modeling assumed 5 bpm > (7200 Bid). The pressure increases are likely caused by fines and solids plugging > the perfs and near wellbore area. The problems evident after operating the well > are much more realistic that those envisioned prior to gaining injection > experience. > > It may be good to get some of the rate pressure data before and after rate > increases to see if they are successful in clearing some of the solids and > cleaning up a bit. > > I don't believe an AA is required. I appreciate the fact they proposed this and > since there are no rules about rate, they really don't need approval. The > following is the surveillance rule for 010 22. I looked over the notes Tom and I > wrote after looking at their annual disposal report. The intermittent nature of > injection is not the best for the well and more continous operation is probably > better in the long run. > > I recommend we acknowledge the change in plan and ask for some followup data for > performance comparisons and interest. > > Jack > »»»»»»»»»»»»»»»»».»»»»»»»»»>»»»»»»»»»»»»»> > Rule 4 Surveillance > A baseline temperature survey from surface to total depth, initial step rate test > to pressures equal or exceeding maximum injection pressure and pressure falloff > are required prior to sustained disposal injection. Regular fill depth tags are > required at least once annually or as warranted following consultation with the > Commission. Operating parameters including disposal rate, disposal pressure, > annulus pressures and volume of slurry pumped must be monitored and reported > according to the requirements of 20 AAC 25.432. An annual performance report will > be required including rate and pressure performance, surveillance logging, fill > depth, survey results, and volumetric analysis of the disposal storage volume, > estimate of fracture growth, if any, and updates of operational plans. Report > submission must be on or before July 1. > > Tom Maunder wrote: > > > All, > > Attached is a note from the new drilling manager at Forest. Based on > > recent happenings, he is likely the only drilling guy over there. > > Please have a look at his proposal. As far as the decrease in pressure > > seen earlier, I do remember some of the plots in their annual report > > showing the surface pressure decreasing over the long term while PÐf\r¡ Cj¡ ~ 2nnt! ~, ~J", (.:1 (!J, l\1 t:.fJ' 1 of 3 11/20/2003 12 ~e: [Fwd: Redoubt Unit D#1lnjection Well] t ,,' > > injecting produced water. I think that the batching they are doing > > likely only moves the wastes minimally away from the wellbore. The > > extended injection periods using clean produced water likely establishes > > communication with portions of the disposal interval more distant from > > the wellbore. Alternately one could view the decrease in injection > > pressure as evidence of extending frac height, however I believe the > > performance once slurry injection resumed would argue against this. > > I do not believe that allowing Forest to exceed the "estimated daily > > volume" provided in the application would increase the risk of getting > > waste into fresh water. The present injection zone is well below the > > 3000 ppm depth. Given the cooler temperatures, keeping the fluid moving > > in their pipeline is necessary to avoid potential freeze up. > > Please let me have your opinions. Is this something that would need an > > AA?? My thought is no, but I am interested in your thoughts. > > If possible, we should try to reach some determination before week's > > end. > > Thanks, > > Tom » > > ------------------------------------------------------------------------ » > > Subject: Redoubt Unit 0#1 Injection Well > > Date: Tue, 18 Nov 2003 16:28:45 -0700 > > From: Roy Smith <RLSmith@forestoil.com> > > To: "'tom_maunder@ADMIN.state.ak.us'" <tom_maunder@ADMIN.state.ak.us> » > > Tom > > As a follow up to our conversation this afternoon, Forest Oil is requesting > > to increase the injection volume of fluid (most produced formation water) >'> into the Redoubt Unit 0 # 1 injection well to assist in cleaning out the > > perforations of fines/solids, which should reduce the injection pressure at > > the surface. In the original permit it was stated that the estimated > > volume of fluid injected would not exceed 1000 barrels per day, but was only > > an estimate. » > > Back in July of 2003, prior to the rig move from one leg-to-another, the > > injection tubing pressures had increased to the upper 4,000 psi range. > > During the rig moving injection of produced formation water continued, > > flushing the perforations of fines and reducing the injection pressure to > > 3,200 psi. » > > Slurry injection was restarted in early September with the drilling of the > > RU # 7 well. Since then the injection pressure has increased to a range of > > 4,100 to 4,600 psi tubing pressure. Currently the slurry is being flushed > > with seawater from the Cook Inlet, which as you know is not clean or > > filtered which also introduced fines into the perforations along with the > > slurry solids. » > > In reviewing the success of reducing the injection pressure by flushing the > > perforations with produced water during the rig move Forest Oil is > > requesting approval to increase the volume of injection fluid. The > > additional volume would total 2-2,500 barrels per day and would be produced > > formation from the beach to assist in flushing the perforations of fines. > > The increase in volume would allow a constant injection of clean water and > > prevent having to shutdown the injection operations from the beach and > > reduce the chance of freezing of the water pipeline coming from the beach > > with the colder temperatures. » > > ------------------------------------------------------------------------ » > > Tom Maunder <tom_maunder@admin.state.ak.us> > > Sr. Petroleum Engineer 2 of 3 ) , nJ:¡\~ 2' ~ 011.P,:1 \;~,: ~ '~\¡ . çJJ c.u -.v ~ 11/20/200312:17 p~ #14 06/20/2002 11: 44 FAX 907 258 8f<\-) FOREST OIL ALASKA I4I 001 ) @ FOREST OIL CORPORATION 310 K Street, suite 700 Anchorage, Alaska 99501 (907) 258-8600 - Office (907) 258-8601 - Fax FAX NUMBER: bimll11L tJ¿CJI/SLI ~1" - 7.05'1-' (, - ~- 02.... . · ~ 1-1 u IÎm U,Ä) /).$ &4U . ¿J6<f--¡¿131 I~,' ~ TO: DATE: FROM: , . PHONE NUMBER: TIME: Total Number of Pages Including Cover Sheet: COMMENTS: I t.J R:J¡2.M I'1r 10 JJ ?£4>U¿SZ . . hI¡ffT ~ V RECE1\IED JUN 20 2002 AJask~ Oil & Gas Cons. Gommlsslol Anchorage SC~\IN\\t\~lF.r) \nn\~ &), ~ ?.GD~1 06/20/2002 11:45 FAX 907 258 8~t:)l ) FOREST OIL ALASKA I4I 002 ~', .,fJ) sr..~ t"~ê_'~ \~~ '\ ~~ ~( PRO,t.C, ) UNITED STATES ENVIRONMENTALPROTECTION. .._ëNCY REGION 10 1200 Sixth Avenue Seattle, WA 98101 I .¡.IJI :L~'" 563 -1.J.dO Reply To Attn Of: QW-130 HAV'! 4 _ CERTIFIED MAIL· RETURN RECEIPT REQUESTED John Am~dsen Safety, Health and Environment Manager Forcenergy Inc. 310 K Street, ISuite 700 Anchorage,.A:K 99501 ttlf"" 1') fj "','r'1;f'{1 ,-j.""! .) :,,1 ¡~~.J .,...':"Re: Coverage under the Cook Inlet NPDES General Permit (No. AKG285000) for Redoubt Shoal Dear Mr. Amundsen: We have revi.ewed your February 29, 2000, request for coverage and authorization to discharge from exploratory drilling operations under the general Cook Inlet National Pollutant Discharge Elimination System (NPDES) permit. Listed below is the permit number assigned to the site and the information identifying the site in our records. Future correspondence and Discharge Monitoring RepOrts should reference this permit number. NPDES Permit No.: Site Name: Latitude: Longitude: Water Depth: AKG285024 Redoubt Shoal 60°40'46" 151 040'101' 41 feet below mean lower low watèr (MLlW) Note that you must provide the exact coordinates (latitude and longitude) and water depth of the discharge site, as well as provide written certification that a Best Management Practices Plan (Part 11.1.1) is completed and on site when you notify this office of the commencement of discharges (Part 1.A.3). Any questions may be addressed to Kristine Koch at (206)553-6705. Sincerely, /1 /-) "'J'~ . ?1':(¡<i+. ,-:~<~ ~. . ,:9'\·~·~C.c~/l Robert R. Robichaud, Manager NPDES Permits Unit Enclosure cc: Judy Kitigawa. Alaska Department of Environmental Conservation - Valdez G" 1\}U4 .. \' \\~ ?: j \'~e~) ..,u SG~\~f, o P"",ed on RM:yCIÐd Paper 06/20/2002 11:45 FAX 907 258 86f1.l ") :;.'1' FOREST OIL ALASKA 141 003 , , ) Page 41 of 45 Permit No. AKG285000 Cook Inlet measurement. the "daily discharge" is calculated as the average measurement of the pollutant over the day. 21. "Deck drainage" means all waste resulting from platform washings, deck washings, spillage, rainwater, and runoff from curbs, gutters, and drains including drip pans and wash areas within facilities subject to this permit. 22. IIDesalination unit wastes" means wastewater associated with the process of creating freshwater from seawater. 23. "Development" operations are those operations that are engaged in the drilling and completion of production wells. These operations may occur prior to or simultaneously with production operations. 24. "Diesel oil" means the grade of distillate fuel, as specified in the American Society for Testing and Materials Standard Specifications 0975-81, that is typically used as the continuous phase in conventional oil~based drilling fluids, which contains a number of toxic pollutants. For the purpose of this permit, IIdiesel oil" includes the fuel oil present at the facility. 25. "Director" means the Regional Administrator or delegated authority for administration of the NPDES program in EPA, Region 10. 26. "Domestic wastes" means materials discharged from showers, sinks, safety showers, eye-wash stations. hand~wa5h stations, fish-cleaning stations, galleys and laundries. 27. "Drill cuttings" means particles generated by drilling into subsurface geological formations and carried to the suriace with the drilling fluid. 28. "Drilling Fluid" refers to the circulating fluid (mud) used in the rotary drilling of wells to clean and condition the hole and to counterbalance formation pressure. The four classes of drilling fluids are: (a) A water~based drilling fluid has water as its continuous phase and the suspending medium for solids, whether or not oil is present. (b) An oil-based drilling fluid has diesel oil, mineral oil, or some other oil. but neither a synthetic material nor enhanced mineral oil, as its continuous phase with water as the dispersed phase. (c) An enhanced mineral oil-based drilling fluid has an enhanced mineral oil as its continuous phase with water as the dispersed phase. (d) A synthetic-based drilling fluid has a synthetic material as its continuous phase with water as the dispersed phase. 29. "Drilling Fluids Toxicity Test" means a toxicity test conducted and reported In accordance the following approved toxicity test methodology: "Drilling Fluids Toxicity Test," as defined in Appendix 2 to Subpart A of 40 CFR 435, or other methods approved in advance by Region 10 that produce results which will assure equivalent protection levels. 30. IIEnhanced Mineral Oil" as applied to enhanced mineral oil-based drilling fluid means a petroleum distillate which has been highly purified and is distinguished from diesel oil and conventional mineral oil in having a lower polycyclic aromatic hydrocarbon (PAH) content. Typically. conventional mineral oils have a P AH content on the order of 0.35 weight percent expressed as phenanthrene, whereas enhanced minerai oils typically have a PAH content of 0.001 or lower weight percent PAH expressed as phenanthrene. 31. "Enq of well" describes the point during drilling when the greatest well depth is obtained. <" ,..:', '\;:;'.~iF.-F" i,:lCI\~ 9 6jj 2000 .~." . 0,' . ~! ~,~ f,~ ¿¡i ,JJ !.?ìf #13 · -J UN. 2 1. þ 2 0 0 2 9 : 2 Ú AM Jun-17-20DZ D3;55pm From- LAW OFFICES ) v NO, 5206 P. 2 ) 1-638 P.0061012 F-398 --... IN THE SUPE)ll OR. COURT O¡.' THE ST ^ TE OF ALASKA THIRD JUDICIAL DJSTR1C'r AT ANCHORAGE COOK lNlE1" KEEPER, v. ) ) ) ) ) ) ) ) ) ) ) ) ) ) ) INTERVENOR-APPFT J ~'E.) .) APPEL.tAN'''; STATE OF ALASKA. OF]:¡CE Of MANAGEMENT AND BUDGET, DIVISJON OF GOVERNMBNTAL COORDINATJON, APPELLEE, FOREST OIL CORPORATJON, Superior COI,lTL No. 3AN-99-3482 JOIN1" STJPULA TJQN TO ST A \' )>ROC]~EDINGS ON AM'END)~D NOTJCE 01: APPEAl.. , The panies 10 the above-captiQned malter hereby slipulale to slay pn~ceedjngs on the Am<::nded Notice of App~aJ in this m~mer. which cIH1])el1g~s the Fina! Consistency DeLerminalion for the Redoubl Shoal OJ) ~md Gas Exploralion PrQject (R~rnand) ("Osprey exploration project"), cl~Hed June 121 2002,' ~nd which Amended Notice of AppeaJ is t11~d simuh3neously herewith, upon the fol] owing conditions: }. This slipu1i:stion is enle.red inlù soleJy for the purpose of compromising Cook lnlet Keepcr1s challenge to the Osprey exploJ'sLÎon project. 'Iñis sIJpu1ation ,shaH ¡:¡pp]y and remain in cffct:t so ]ong as discharges fram the Osprey John $\Ipulatioø .SG,¡~\I~ f~ ED J U ~»(aJl.{Kl4k£¡ 1026 W. 4'6 Ave. SWIf 20] I\ndzofQge. ^ltUka 99.5()J (907) 27tS-4244 , J UN. 21, \ 20 0 2 9 : 2 0 AM JLln-17-2UDZ 03:55pm From- LA~ OFFICES ) ) NO. 5206 P. 3 T~saB P.DUB/01Z F.¡9B ',--" ,,-..,I exploraTion project ¡tre regu13ted by the Cook J1'11etGeneral NPDES Peml1L No. AKG28500Q. 2. For the r~msining life or the Osprey expJoration Pl'Ojecl. inc)uding Redoubt No. 5 we11 and any subscCuem ~~p]o~\lìon or d£:line~ûon wells, 1m e¡'v en or- Appellee Foresl Oil Corpora1ion ("Forest Oir') its ~uccessors, assigns, and contractorS shaH inject an drjlJing muds and cuuings, as defined by the Cook , ]n]et General N'PDES perm.it no. AKG28S0001 ~§ 27 and 28, into the existing Chi~S n injection wen allhe Osprey exp1oration projeCt, 3. Fore~[ Ojl shal1 nOt later than June 17, 2002, subn,it an application to the A]as'ka Oil and Gas Conservation Ccunn)h;sion ("AOGCC'~) lO amend its Ch\ss II injectÌl.:u) well pem1Íl to anow it \0 inject ~n fluids collected from the deck drains on tht:: Osprey p]stfonnJ so·cal1ed "deck drainage" ~ defined by The Cook In]et General NPDES permJl no. AKG285000, § 21. 4. )f the amended injection pe1mil is issued~ ForeSl Oil wi11 make good faith efforts to insuù] the nec:e!;sary equipmen\ and b~gin 101nject an deck dr3iTlage jnw tht C1~ss ]] iT\j~clion wen as sOOn 3S possible, but no 1au~r rhaIl ]0 days. aftcr I'ect:ipt of its ~1.nhoriz~ljon_ FOJ'esl Oil wi 11 inject aU deck drðinage fDf the remaining life of the Osprey explonuioT'l project except dLlring upset condition$, during whic:h Foresl Oil may discharge deck drainasc under the NPDES General Permit AK 0285000. "Upset cnndjÜons" means an unforeseeable malfunc\JoTl or bn:akdown of mechanical suñace equipment on the Osprey platfonn needed to inject waste~ or a malfunction Or breakdown of the Class 1] InjeCtion we11. which malfunction ar breakdo~ prevents use of the well for ,~ . , E:-' JUN 2, 3 2Dn~ s~ANN (, 7,,.r~es¡OfA/øþJ Joint StipUJäliol\ 2 1026 w. '" I'\Vt, Suile 20] AnCMT(l.Rø, Aløs~ ~9S01 (907) 27ð-4244 , JUN, 21. '2002 9: 20AM J~n-1T-2DQ2 03:66pm rram- LÞW OF FIe E S ) ) NO. 5206 P. 4 T-636 P.D01/012 F-398 ',-", ,-/ injection of wastes until repaired. Fore~t Oil shan act in good faith [0 repair promplIy any slJch maJfunctions or breakdowns. 5. Upon nOlifjcatinn from AOOCC that the pennÜ has been j~SL\ed1 the par1ies shall fUe a Consenl Decree and Joint Slipul:uion for DismissaJ With Prejudice, each pany to bear j\S own costs. incJuding atlomeys' fees, incurred subsequent 10 May 28. 2002 (the d=ste of fi}jng jn th~ SL1peTior CouTl and Supreme CoUrt of Appel1:m['~ M01ions for AUomey~s Fees on the orisina1 Notice of Appea]), provid~d ,hat this Coun shaH retain jU];Sdiction to enforce. th~ terms of sueh Conse!n1 !Jecree and John Stipu]ation for Dìsmissa1 With Prejudice. which shall dismiss with prejudice this appeal ,md aJl c1aims that were broughl in it. 6. If the ~mcnded injection peJmh is denied by AOGCCt the p&n1CS ~ha11 anernpl to reach agrcèmem on a. mUnH-1J1y ::.cceplab1e 3J1emative disposal method for deck d]'ail,oge. :If lhe parlies cannot rel:1ch such an agreemem within 7 days of ~hf:: peJmitts denial, Cook ]n1et Keeper rCsðrves its rj'ght to seek preHminary relief and ~ resoJu\ion of the rnerits in this maller Ihereaflel'. 7. If Forest Oi) is ¡s~ued the í.1mended injecl30n pennit, ForðSt Oi1 win notify the parties when it has imp1eJJ\emcd the injection of deck drainage. Upon such nOlice Lhe pani~s shaH file with the COUJ1 a Ccmsent DecJ'ee for the dismissal with prejudice of this app~al and an claims That 'Wcre brought in it, jn accordance With lhe terms and cOT1diticms o/this stipulation. 8. Not\~dthslanding tht= stay of proceedings entered pursuant 10 (hi~ Joint StipU}Slion, the St~te of Alaska, Office of Management and Budget, Division of Jolnl Stipul~tion 3 - . ~ ~)) ~; 2'OD~· C¡('ß\NNEI~ JÜN f,~ ~ ~".?Ih . 1 ru~I~~J' før AlasktJ J026 W. 4M Ave. SlAiI~ 201 J\nc:hOI'fl,8£. AIQskt2 99501 (901) 276-4244 > JUN,21.'2002 9:20AM J~n~17-ZDD2 D3:56pm Frcm- 08/17/2002 14:04 fA! 4~~ UJ~~ Jun-l!~2~02 02131pm FrQm- LÞ\M OFFICES ) ') NO, 5206 p, 5 T-636 p.DQe/01Z F-39S T-Sa4 Þ,DU5lUØã F-SD4 A.. I.v.a. ...."'., 'Y.................._ .... -_ - - - - v '-' Oovermnental COQrdination shill prcpæe th~ administrative :eccrd in this man=: Wi though rbc stay were TLot is¡ effect. 9. Upon mopon¡ the court may eD~r an OrdèT against any pan)' shown to be in violation of the terms of this Joint StipulatLon. Pared: .rune ~ 7__ 2002 R::spcctfOUy submitœd, ~~~~ - - - _. -," . - . R.cbetca L. Bernard Michae) J. Frank Trostcç.S for Alask¡ 1026 W. 4111 A'Vt., Suite 201 Ancl1arageJ AK 99:501 Attanu:ys for Appellan[ 6¿ ~ , ~~\N~ lei tl:¥! S'lvanSDZI ~ Assistant Anomey General Department of Law State of Alaska P.O. Bo~ 110300 JuneauJ AK 99801-0300 Aaomc:y fQt Appt.U= ~ ~' , yle W~arlu:z '0- David J. MiYbeny Patt.on BDSr I.lP 601 West S Avenue, Suite 700 Abchorag~ AX 9!JSOl Attorneys fOf Inte:rvcncr-Appelleti Joint srip11l:atiQG 4 " II ~) q <101ì.1 SCAJ\~I~~~EC JtH~ t.J J r.. U'""I TTK1It~JQr ,.~ lQ2,) w. 4'* .4",. SlliJ~20J AMMI'4p. ~~trJ. Þ!ASDJ (901) ]16-4244 JUN. 2l. 2002 9: 20AM lA~ OFFICES Jun-lr-ZD02 D3:6Bpm from- , ......". ) " NO. 5206 p, 6 ' T"836 P.D1D/D12 ~-398 '- IN THE SUPER]OR COURT OF THE STATE OF ALASJ{A THJRD JUD)CIAL DJSTRJCT AT ANCHORAGE ) ) ) ) ) ) ) ) ) ) ) ) ) ) ) INTERVENOR-APPELLEE. ) .-J COOK D'tLET KEEPER., APPELLANT, v. ST A TE OF ALASKA, OFF)CE OF MANAGEMENT AND BUDGET, PIV1SJON OF GOVERNMEN1~AL COORDINAT10N, APPELLEE~ FOREST O!LCORPORATJON, Superior Court No. 3.AN..99-3482 (PROPOSEDj ORDER The pat1ics \0 this mat1er having 111ed a Joim Stipula.tion to Stay Proceedings on the Amended N01]Ce of Appea] in this ma1l~r, The Court hereby orders that the proceedings are !:ì\i:l.yed in accorda.nGe with the panies' Joim Stipu1atíon until further ord~ of this Court. This Coun's Order Regard111g Briefing Sc),edule, dated June ]3,2002, js h~r~by vacated. Notwithstanding tbi1ì Stay ofl)Ioceedings, AppeUee State of Alaska, Office of Mi:l11agem~nt and Budget~ Djvisìon of Gù\lemmeIna1 Coordinadon shan prepare ~d file the adJT'linistralive record in this matter wit11in 40 days of the date of this Ord~. It is so ordered. Dated: June -' 2002 (PROPOSED] 01U>ER Larry Card. J\Jdge of the S~perior Cõun \ e~.. ~ ¿ûD~ -.-< jU\~ (,,' cli "I'A\~N\tl/ . Tf1Utee~jö"AI5illko ~t.? 1026 'If. lid Ave. Sui,e 20J AnchDrage. Alruk.a 99501 (9D7) 276-4244 JUN.21.2002 9:20AM LAW OFFICES ') Jun-17-ZDD2 DS:SBp~ From- ',-- ,./ Distribution: Rebecca L. Bemard Michat:) J. Frank Trusw,es for Alaska 1026 w. 4th Ave. Suite 201 Anchorage1 AK 99501 Kirsten Swanson Assistant AHomey Genera] Depanment of Law PO Box ]] 0300 Juneal\, Ala~ka 998] 1-0300 Ky}e W. Parker David J. MaybeI'I)' Patton Boggs L.L.P. . 601 W. 501 Ave., Suite 700 AnclÌorage, A]aska 99501 John Marlin Duane Sf leI" Patton Búggs LLC 2550 M St. NW Washington, D.C. 20037 \'PRÖPOSED) ORDER 2 '- ') NO. 5206 P. 7 T-636 P.Ol1/01Z F-SBS .........'" " G @ 'JQlì t',¡ .. ~U\~ r.." ¿$ t. -, uc,~ 1 "'4~I,~¡ JOT A larka 1026 w. 4'· Avl!'. s,.ù~ 2D1 Anch(mar~. Al4.~~ ~950J (907) 276.4244 JUN. 2). 2002 9:20AM LAW OFFICES NO. 5206 P. 8 J un" 17-2 D02 03 r56pm Prom- ') ') T"Bas P.DIZ/Oa F-39B ".......,) ',-" CERTIFICATE 0);' SERVICE I hereby cenify that] served a copy of the enclosed Amended Notice of Appeal) S~ipuJa\ion to Stay Procf,edings on The Amended Notice of Appea]) and Proposed Order on June 17,2002) via facsimi1e :.Jnd U.S. Mai1~ postage prepaid on: patrick Gahdn Direc\or Offjc~ of Ma11àgem~nl and Bodg~t1 Division of Governmental Conrdination Sw.te. of AJaska P.O. Box 110020 Juneau, AK 99801-0300 Bruce M. Botelho AnOll1ey General Pepartm~nI of Law P.O. Box 110300 Juneau, AK 998lJ-0300 KirSlen Swanson Assistant Attorney Genera) D~pann1ent of Law P.O. Box 110300 Juneau, AK 99811-0300 KyJe W. Parker David J. Mayberry Patton Bog!S L.L,P. 60] West 51 Ave., Suite 700 AnchoJ"agè, AK 9950] John Marun Duane Siler P,uton Boggs L.L.C. 2550 M St. NW Washington, D.C. 20037 joa~~~k:·j)· ~ Legal Assistant Truslees For Alaska , -1 >¡ 2-0ct. ~c¡\NNEC JUN {,..~' ,'" '...... \t:A./r \.. '{ ^ mended Notiœ of Appe.al 4 1TwltfS for Alasktl J026 W. ~" ^~. Sl.Ù4f 2DJ Anch(Jrtl.S~, AlastQ 9~'OJ (907) 2'76-4244 FW: Redoubt Exploration Litigation -- Joint Stipulat;.. .') ) Subject: FW: Redoubt Exploration Litigation -- Joint Stipulation Date: Thu, 20 Jun 2002 12:55:31 -0400 From: "Mayberry, David" <DMayberry@PattonBoggs.com> To: "'jody _ colombie@admin.state.ak.us'" <jody _ colombie@admin.state.ak.us> > Resend > > -----Original Message----- > From: Mayberry, David > Sent: Wednesday, June 19, 2002 3:54 PM > To: 'jody-columbie@admin.state.ak.us' > Cc: Gary Carlson (E-mail) > Subject: Redoubt Exploration Litigation -- Joint Stipulation > > Jody, > Gary Carlson asked that I email you the attached Joint Stipulation > executed by the parties in Cook Inlet Keeper v. State of Alaska, Superior > Court Case No. 3AN-99-3482 CI, on June 17, 2002. Please contact me if you > have any questions. David > > «STIPULATION - FINAL 6-17-02.DOC» > > > This e-mail messagecontainsconfidential.privileged information intended solely for the addressee. Please do not read, copy, or disseminate it unless you are the addressee. If you have received it in error, please call us (collect) at (202) 457-6000 and ask to speak with the message sender. Also, we would appreciate your forwarding the message back to us and deleting it from your system. Thank you. To learn more about our firm, please visit our website at http://www.pattonboggs.com. ~-: Name: STIPULATIO~ - FIN~L ~-17-02.DOC I ~STIPULATION - FINAL 6-17-02.DOC) Type: WINWORD FIle (apphcatlOn/msword) , ;'""wr, ~, n :! ~~~~,diI?-g:w,ba~e64 ,.", ~~ b~" 2'JD[\. f..j (,I) 1 of 1 6/20/2002 10:05 AM #12 ') \ , ) ~ FOREST OIL CORPORATION .'1/(} 07((¡YÎ;reel . DYtule 7(}() DÇ~r;lc¡;(Jnrr7e, c91lrr,¡ka .9.{}:; () / (.907) :-()/;S-SÚ'()(! · (.r;07) ,'!,;S-Sú'O I (C\Þ;u) June 17,2002 Cammy Taylor - Chair Alaska Oil And Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Dear Commissioner Taylor: Forest Oil currently injects permitted Class II wastes into the Redoubt Unit #D1 disposal well. Our current permit does not specifically include the injection of storm water that has gathered on the deck of the Osprey Platform. The calculated volume of these waters is approximately 3500 barrels, per year. Our current anticipated volumes of other drilling wastes that we are injecting are approximately 80,000 barrels per year. We request the use of this Class II disposal well for the disposal of storm water collected in the platform's deck drain system. If your staff has any questions, please feel free to contact Paul White at 868-2134 or myself at 258-8600. Thanks in advance for your help on this issue. Sincerely, / '/,' " ¿.·,/~t ~ /l;' /:)/ ();¡Zú 'é,,¡¿f-Ø:~ ." Gary E. Carlson Senior Vice President Forest Oil Corporation RECEI\lED j! !! ¡ .~ ï ("'¡ Ii f'? " u¡\~ I D.;l.',- Alaska Oil & L;;, ,» ::,".. 0.f¡ehr'¡r':' , .__ , \' "\\'\ (:,"¡¡ b~ t"}f1<'ì ~ ,~~(...l-\,~~~\\;~[;:'L' ,-,!\L'(: t~, 0: c:.uL>-ij' Date Modified: 6/17/02 Date Prepared: 6/17/02 n P:\GEC Docs 2002\Letter_AOGCC_6_17 _02.doc #11 , ) ~ FOREST OIL CORPORATION October 4, 2001 .'1/ () r:),{'rV//feel . CVr~tlf~ 7(}() DÇ{;/f'ho)fffrVf!, D(>I/a);;a ,9,95()/ (907) ~,'!/¡S-S6'()(} · (.9()7) 2/¡S-Sú'()J (01/-;',1) Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, AK, 99501 RECEIVED Attention: Commissioner Cammy Taylor OCT 0 9 Zn01 Re: Redoubt Unit (RU) #D1 well, fracture model Alaska Oil & Gas Cons. Commission Anchorage Dear Commissioner Taylor: Forest Oil Corporation has completed the fracture model, requested in a letter from Wendy Mahan dated August 9,2001. This letter was a cover letter to the Disposal Injection Order #22. It was requested that Forest Oil provide a fracture propagation analysis for the primary injection zone (8,216' to 8,450') and the secondary backup injection zone (7,650' to 7,900'). Please find attached the results, provided by BJ Services. Please call me if you or your staff have any questions about this request or require additional information. Forest Oil will be pleased to meet with you or answer any questions you or your staff may have. Thank You. y~ -::> Paul D. White Drilling Manager - Alaska Division Forest Oil Corporation Attachments: RU # D1 Fracture Model - BJ Services " ~ _., \il)~\" eo)' é~ l')f\fIF'. ".è: ,( '"f' t',.~\ ~,..j c: t "I ~I t> (:) c.. v", 'ï; ~I\U -"t~¡ \.b.L. \1... ..' ) ) Wj September 21, 2001 Mr. Rob Stinson Forest Oil 310 K St. Anchorage, AK 99501 Mr. Stinson, Enclosed you will find two Fracpro PT fracture analysis reports for Rud-l disposal well, There is one report for each of the two intervals you specified in our telephone conversation on September 18th (7650' -7900' and 8216'-8450'). The purpose of this letter is to briefly explain the input parameters used for the model and the subsequent results. To determine the input parameters, data from the electronic log was broken down into layers above, through, and below the perforated intervals. Data such as layer thickness, Poisson's Ratio, Young's Modulus and closure stress were computed from log data and input into the Fracpro PT model. Many simulations were run using various values for leak-off coefficients, pump rates, and pump times to evaluate their impact on the model, and determine if the fractures would break out of zone. A final set of values was selected that provide a reasonable output but would not cause the simulator to fail (i.e. obtaining values beyond which the simulator could reasonably process, or even the absence of a fracture at all due to high leak-off rates). The pUlnp schedule for each perforated interval was 2.3 bpm for 370 days, during which 1 million barrels of clean fluid with 5 ppg of 100-mesh sand added. This is equivalent to 1.22 million barrels of slurry pumped over 370 days. The time span of just over 1 year was used due to time limitations (both real and program imposed) and the volume approximates the total amount of fluid expected to be pumped into the well, 1.1 million barrels. The 2.3 bpm rate was chosen to accomplish this amount of fluid in such a short time span. After completion of the many simulation runs, there does not appear to be any concern about the fracture growing out of zone, according to the model. Actual fracture length will vary significantly depending on pumping rate, leak-off rate, and start-stop operations. If you have any questions or would like further detail on the model process, please feel free to call me anytime at 661-396-4441. Thank you, f\ ~ .~>~ ~~ Andrew Katon Pacific Region Engineer BJ Services Company Cc: Jay Gamer SCh,~\\NE[ CN,' LJ 2 On'! í· c) _JL'~( BJ Services Company, U.S.A. · 1401 South Union Avenue · Bakersfield, CA 93307 Office: (661) 831-5084 · Fax: (661) 836-8903 · R E.. COM M E ,N, D A T ION.. [~ FracproPT10.0 Hydraulic Fracture Analysis Date: Well Name: Location: Formation: Job Date: Filename: September 21, 2001 Redoubt Unit#1 Cook Inlet Basin, Alaska. Rud-1 Disposal 8216'-8450' Fracture Geometry Summary 560 Propped Half-Length (ft) 185 Total Propped Height (ft) 8211 Max. Fracture Width (in) 8396 Avg. Fracture Width (in) 1.0 Avg. Proppant Concentration (lb/ft2) 0.00 Fracture Half-Length (ft) Total Fracture Height (ft) Depth to Fracture Top (ft) Depth to Fracture Bottom (ft) Equivalent Number of Multiple Fracs Fracture Slurry Efficiency All values reported are for a single fracture Model has run until 533100.00 min Fracture Conductivity Summary Dimensionless Conductivity Proppant Damage Factor 0.00 Ref. Formation Permeability (mD) 0.50 Proppant Permeability (mD) All values reported are for a single fracture Model Net Pressure (psi) Observed Net Pressure (psi) Hydrostatic Head (psi) Fracture Pressure Summary 37 BH Fracture Closure Stress (psi) o Closure Stress Gradient (psi/ft) 5424 Surface Pressure (psi) Averages reported during Main Frac Total Clean Fluid Pumped (bbls) Total Slurry Pumped (bbls) Pad Volume (bbls) Pad Fraction (%) Main Fluid Operations Summary 1219166 Total Proppant Pumped (klbs) 1219166 Total Proppant in Fracture (klbs) o Avg. Hydraulic Horsepower (hp) o Max. Hydraulic Horsepower (hp) DISPOSAL Main Proppant FLUID Averages reported during Main Frac '-'l"" f\NNL_.---'I;" on ~}'i 0; ~~ ~)nrq ......:, I~ I .. ~ ,\ ij '" {.. "'" "_~. U 0'i;;.;1J -.>- FracproPTIO.O o o 0.03 0.02 0.00 25.0 20000 6222 0.750 845 210099.3 0.0 66 3331 100-Mesh C:\My Documents\Al...Well\Rud-1 Disposal B J 5 E R V ICE S COM PAN Y R E COM M E ,~, D A T ION , _~ lBJ ¡ ~ ~ ---- Treatment Schedule Stage Elapsed Fluid Clean Prop Stage Slurry Proppant # Time Type Volume Cone. Prop. Rate Type min.see (bbls) (ppg) (klbs) (bpm) Well bore Fluid DISPOSAL 79.5 FLUID 1 ' 370:days DISPOSAL 999999.9 5.00 210000.0 2.30 1 DO-Mesh FLUID Scheduled clean vol (bbls) Scheduled slurry vol (bbls) 999999.94 1226116.75 Scheduled sand total (klbs) 209999.98 SC/\NNEC JUN 2 3 2DD~ FracproPTlO.O 2 C:\My Documents\Al...Well\Rud-l Disposal B J S E R V ICE S COM PAN V , R E COM M ,~ f~ D A T ION .. " [BJ \ " ,.' ~\ "."'~~ -.- ~ " LeakoffParameters Reservoir type Gas Filtrate to reservoir fluid perm. ratio, Kp/KI 10 Reservoir pore pressure (psi) 3609 Initial fracturing pressure (psi) 6722 Reservoir fluid compressibility (1/psi) 2.77e-004 Cold filtrate viscosity (cp) 1.00 Hot filtrate viscosity (cp) 1.00 Cold reservoir viscosity (cp) 0.03 Hot reservoir viscosity (cp) 0.03 Porosity 0.10 Gas Leakoff Percentage 100.00 Reservoir Parameters Reservoir temperature (OF) 140.00 Depth to center of Perfs (ft) 8333 Perforated interval (ft) 234 Initial frac depth (ft) 8296 Layer Parameters Layer # Top of Stress Top of Young's Poisson's Top of Total Ct PoreFluid zone (psi) zone modulus ratio zone (ft/min%) perm. (ft) (ft) (psi) (ft) (md) 1 0.0 6000 0.0 1.7e+006 0.31 0.0 3.985e-002 2.50e+001 2 8000.0 6008 8000.0 1.7e+006 0.31 8000.0 3.985e-002 2.50e+001 3 8020.0 6425 8020.0 1 .4e+006 0.33 8020.0 O.OOOe+OOO O.OOe+OOO 4 8043.0 6041 8043.0 1.7e+006 0.31 8043.0 3.985e-002 2.50e+001 5 8066.0 6470 8066.0 1 .4e+006 0.33 8066.0 O.OOOe+OOO O.OOe+OOO 6 8110.0 6091 8110.0 1.7e+006 0.31 8110.0 3.985e-002 2.50e+001 7 8133.0 6529 8133.0 1 .4e+006 0.33 8133.0 O.OOOe+OOO O.OOe+OOO 8 8190.0 6147 8190.0 1.7e+006 0.31 8190.0 3.985e-002 2.50e+001 9 8203.0 6568 8203.0 4.4e+005 0.39 8203.0 O.OOOe+OOO O.OOe+OOO 10 8218.0 6222 8218.0 1.7e+006 0.31 8218.0 3.985e-002 2.50e+001 11 8373.0 6704 8373.0 4.4e+005 0.39 8373.0 O.OOOe+OOO O.OOe+OOO 12 8388.0 6311 8388.0 1.7e+006 0.31 8388.0 3.985e-002 2.50e+001 13 8440.0 6757 8440.0 4.4e+005 0.39 8440.0 O.OOOe+OOO O.OOe+OOO 14 8452.0 6339 8452.0 1.7e+006 0.31 8452.0 3.985e-002 2.50e+001 SCI\NNEC c~UN ~, ~, ZDD.~· FracproPT 1 0.0 3 C:\My Documents\Al... Well\Rud-l Disposal B J S E R V ICE S COM PAN Y 'R E, COM M E ,~ D A T ION ,'_= [BJ Lithology Parameters Layer # Top of Lithology Top of Fracture Top of Tip zone zone Toughness zone Effects (ft) (ft) (psi·in%) (ft) Factor 1 0.0 Sandstone 0.0 1000 0.0 1.00 2 8000.0 Sandstone 8000.0 1000 8000.0 1.00 3 8020.0 Shale 8020.0 2000 8020.0 1.00 4 8043.0 Sandstone 8043.0 1000 8043.0 1.00 5 8066.0 Shale 8066.0 2000 8066.0 1.00 6 8110.0 Sandstone 8110.0 1000 8110.0 1.00 7 8133.0 Shale 8133.0 2000 8133.0 1.00 8 8190.0 Sandstone 8190.0 1000 8190.0 1.00 9 8203.0 Coal/Clystne 8203.0 1000 8203.0 1.00 10 8218.0 Sandstone 8218.0 1000 8218.0 1.00 11 8373.0 Coal/Clystne 8373.0 1000 8373.0 1.00 12 8388.0 Sandstone 8388.0 1000 8388.0 1.00 13 8440.0 Coal/Clystne 8440.0 1000 8440.0 1.00 14 8452.0 Sandstone 8452.0 1000 8452.0 1.00 ~C?\NNE[) I>-HjN 2. ~) ¿De)} FracproPT 1 0,0 4 C:\My Documents\Al...Well\Rud-1 Disposal B J S E R V ICE S COM PAN Y ~! - Width Profile [1f"I) Concentration of Proppant in Fracture (lblft9 ~ s... ... P... ~ ~ ~ ~ ~ ~ " ~ c£ ~ ¡¡ac re ~ . ~ ,~ ¡---~ . ~ ! ïtI : ~ .~.. -~~-~ ,~ ~ . ~ ,,~ .~ .~ .~ :~ :~ ~_u,,_~_ j¡ tt· ~ Z m I~ ) ('~ c;: :z M ~ N e::J ("'::) cÇ>:> · R, E COM M E ,.,N,~" D A T I 0 N_~ g FracproPT10.0 Hydraulic Fracture Analysis Date: Well Name: Location: Formation: Job Date: Filename: September 21 , 2001 Redoubt Unit#1 Cook Inlet Basin, Alaska. Rud-1 Disposal 7650'·7900' Fracture Geometry Summary Fracture Half-Length (ft) 1403 Propped Half-Length (ft) 0 Total Fracture Height (ft) 151 Total Propped Height (ft) 0 Depth to Fracture Top (ft) 7613 Max. Fracture Width (in) 0.15 Depth to Fracture Bottom (ft) 7764 Avg. Fracture Width (in) 0.09 Equivalent Number of Multiple Fracs 1.0 Avg. Proppant Concentration (lb/ft2) 0.00 Fracture Slurry Efficiency 0.00 All values reported are for a single fracture Model has run until 447550.00 min Fracture Conductivity Summary Dimensionless Conductivity Proppant Damage Factor 0.00 Ref. Formation Permeability (mD) 0.50 Proppant Permeability (mD) All values reported are for a single fracture Model Net Pressure (psi) Observed Net Pressure (psi) Hydrostatic Head (psi) Fracture Pressure Summary -20 BH Fracture Closure Stress (psi) o Closure Stress Gradient (psi/ft) 5077 Suñace Pressure (psi) Averages reported during Main Frac Total Clean Fluid Pumped (bbls) Total Slurry Pumped (bbls) Pad Volume (bbls) Pad Fraction (%) Main Fluid Operations Summary 1022484 Total Proppant Pumped (klbs) 1022484 Total Proppant in Fracture (klbs) o Avg. Hydraulic Horsepower (hp) o Max. Hydraulic Horsepower (hp) DISPOSAL Main Proppant FLUID 75.0 20000 5823 0.750 737 176356.0 0.0 41 63 100-Mesh Averages reported during Main Frac S~::;h~~~~!;':¡-' p ¡H ~ ~ 00" 0 t1 1:....,,",- v I..~n\ f.. ~ L! 'J. FracproPTlO.O C:\My Documents\AL.l\Rud-l Disposa12a B J S E R V ICE S COM PAN Y ^ R E, COM M E .N,,~, D A T ION ,_ r~ Treatment Schedule Stage Elapsed Fluid Clean Prop Stage Slurry Proppant # Time Type Volume Conc. Prop. Rate Type min.sec (bbls) (ppg) (klbs) (bpm) Wellbore Fluid DISPOSAL 72.1 FLUID 1 370:days DISPOSAL 1000000.1 5.00 210000.0 2.30 100-Mesh FLUID Scheduled clean vol (bbls) Scheduled slurry vol (bbls) 1000000.13 1226117.00 Scheduled sand total (klbs) 210000.02 ~.r'" to k\,~ :r~'~I""'F r¡--- I: \ ~h\¡ e!; (j'I) 20rU, ·\-lI~'J.r"M~ ,'\J .,._1" I d Ut\! f.:, 0 U 8 FracproPTIO.O 2 C:\My Documents\Al...l\Rud-l Disposa12a B J S E R V ICE S COM PAN Y R E COM M E N_, D A T ION ,_, fBJ j) i{ . \, _.__ _--' LeakoffParameters Reservoir type Gas Filtrate to reservoir fluid perm. ratio, Kp/KI 10 Reservoir pore pressure (psi) 3377 Initial fracturing pressure (psi) 6323 Reservoir fluid compressibility (1/psi) 2.96e-004 Cold filtrate viscosity (cp) 1.00 Hot filtrate viscosity (cp) 1.00 Cold reservoir viscosity (cp) 0.03 Hot reservoir viscosity (cp) 0.03 Porosity 0.10 Gas Leakoff Percentage 100.00 Reservoir Parameters Reservoir temperature (OF) 140.00 Depth to center of Perfs (ft) 7775 Perforated interval (ft) 250 Initial frac depth (ft) 7764 Layer Parameters Layer # Top of Stress Top of Young's Poisson's Top of Total Ct PoreFluid zone (psi) zone modulus ratio zone (ft/min%) perm. (ft) (ft) (psi) (ft) (md) 1 0.0 5517 0.0 1.7e+006 0.31 0.0 6.716e-002 7.50e+001 2 7356.0 5891 7356.0 4.4e+005 0.39 7356.0 O.OOOe+OOO O.OOe+OOO 3 7372.0 5543 7372.0 1.7e+006 0.31 7372.0 6.716e-002 7.50e+001 4 7409.0 5930 7409.0 4.4e+005 0.39 7409.0 O.OOOe+OOO O.OOe+OOO 5 7417.0 5580 7417.0 1.7e+006 0.31 7417.0 6.716e-002 7.50e+001 6 7464.0 6351 7464.0 1.4e+006 0.33 7464.0 7.755e-002 1.00e+002 7 7479.0 5647 7479.0 1.7e+006 0.31 7479.0 6.716e-002 7.50e+001 8 7580.0 6446 7580.0 1 .4e+006 0.33 7580.0 7.755e-002 1 .00e+002 9 7587.0 6078 7587.0 4.4e+005 0.39 7587.0 O.OOOe+OOO O.OOe+OOO 10 7608.0 5755 7608.0 1.7e+006 0.31 7608.0 6.716e-002 7.50e+001 11 7739.0 6196 7739.0 4.4e+005 0.39 7739.0 O.OOOe+OOO O.OOe+OOO 12 7750.0 5823 7750.0 1.7e+006 0.31 7750.0 6.716e-002 7.50e+001 13 7778.0 6244 7778.0 4.4e+005 0.39 7778.0 O.OOOe+OOO O.OOe+OOO 14 7832.0 5877 7832.0 1.7e+006 0.31 7832.0 6.716e-002 7.50e+001 15 7841.0 6694 7841.0 1 .4e+006 0.33 7841.0 O.OOOe+OOO O.OOe+OOO 16 7910.0 5939 7910.0 1.7e+006 0.31 7910.0 6.716e-002 7.50e+001 17 7928.0 6778 7928.0 1 .4e+006 0.33 7928.0 O.OOOe+OOO O.OOe+OOO 18 8020.0 6025 8020.0 1.7e+006 0.31 8020.0 6.716e-002 7.50e+001 19 8046.0 6035 8046.0 1.7e+006 0.31 8046.0 6.716e-002 7.50e+001 IT H~,~'\-I'- It )~I\ì (1) CJ¡ 20t\1 ~¡(- L;,."'" !I\ :.--L ' . ¡ t' i" r.;,.. (;j - I."., ij 'i.,.....,'~\,-1J/j Ù \..I" ~..... ~ -...: ¡. \ FracproPTIO,O 3 C:\My Documents\Al...l\Rud-1 Disposal 2a B J S E R V ICE S COM PAN Y R. E COM MEN D A T ION ~ l~ t.:1 ~ -------" Lithology Parameters Layer # Top of Lithology Top of Fracture Top of Tip zone zone Toughness zone Effects (ft) (ft) (psi·inYz) (ft) Factor 1 0.0 Sandstone 0.0 1000 0.0 1.00 2 7356.0 Coal/Clystne 7356.0 1000 7356.0 1.00 3 7372.0 Sandstone 7372.0 1000 7372.0 1.00 4 7409.0 Coal/Clystne 7409.0 1000 7409.0 1.00 5 7417.0 Sandstone 7417.0 1000 7417.0 1.00 6 7464.0 Shale 7464.0 2000 7464.0 1.00 7 7479.0 Sandstone 7479.0 1000 7479.0 1.00 8 7580.0 Shale 7580.0 2000 7580.0 1.00 9 7587.0 Coal/Clystne 7587.0 1000 7587.0 1.00 10 7608.0 Sandstone 7608.0 1000 7608.0 1.00 11 7739.0 Coal/Clystne 7739.0 1000 7739.0 1.00 12 7750.0 Sandstone 7750.0 1000 7750.0 1.00 13 7778.0 Coal/Clystne 7778.0 1000 7778.0 1.00 14 7832.0 Sandstone 7832.0 1000 7832.0 1.00 15 7841.0 Shale 7841.0 2000 7841.0 1.00 16 7910.0 Sandstone 7910.0 1000 7910.0 1.00 17 7928.0 Shale 7928.0 2000 7928.0 1.00 18 8020.0 Sandstone 8020.0 1000 8020.0 1.00 19 8046.0 Sandstone 8046.0 1000 8046.0 1.00 SCP~U~l~~I¡;:-¡!," J:I: r:[\U ci! 6) ?nnq, /h,;L '" W.I¡J !.r {:.II c..UULjo FracproPTIO.O 4 C:\My DocumentsW...l\Rud-1 Disposa12a B J S E R V ICE S COM PAN Y .:¡;. ~) ;~ z f'n ~ c:: & ~~ 0.~ 25 d ~ s... ... P... ~ ~ ~ ~ ~ ~ I ~ I ! -- f ~. .1.' ~ ~ ~'~ ~ ~ ~ ~: ~ ,~._.j ~ C~5 ~ i:-~~ ~ ~ ~ ~ ---~._.~ - Concentration of Proppant in Fracture (Ib/~) ~ .~ .~ ~ ) FOREST OIL ') CORPORATION .1/0 Q/{OYll((?(?/. º9t~lÞ! 70{) QçfnchOF(fr'l(?' Qçfkoka ,9,9501 (9()?) 2/}eS'-,S'Ú'O(} · (9(J7) )!/¡S-c.S'Ú'O) (C/:f/a,r) August 15,2001 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Attention: Tom Maunder Re: Redoubt Unit #D 1 well Temperature Log and Injection Step Test Dear Mr. Maunder, Forest Oil is required under Disposal Injection Order #22 to furnish AOGCC a temperature survey and injection step test prior to disposal operations on the Redoubt Unit #D 1 well. Attached are the graphs of both the temp log and step test. The step test was performed as per the previously agreed procedure. No anomalies were encountered during this test. At this time, Forest Oil requests to commence regular disposal operations on the Redoubt Unit #Dl well. Please contact me at 258-8600 if you have any further questions. ~- Paul D. White Drilling Manager - Alaska Division Forest Oil Corporation RECEIVED AUG 1 5 2001 Alaska Oil & Gas Cons, Commission Anchorage I;Hkg ß'\ì C] 20rn ."':' ,JU¡~ t(; ~li -lí!:.J. 8/14/01 INJECTION STEP TEST D-1 SLURRY VIS = 48 SLURRY WT =9.2 PPG 4500 - 15:09 3 BPM ~ 500 ,+. ~ ·4000 3500 3000 =ND1 8PM' - 14:33" , 14:37 2500 2000 ¡ I-PSI -A J 1500 /J "'.. t ~,... , > 1000 .ç Z mi· ~j ~ <-=- c: ~ ~;-~ / ¡ -." .'., - ..,...,-~" .1 ~~:"..'."::.;:'- ~ II; I1II i I ((111111111111"111·' ¡ 1'111111 i ~~ o (:,<." í""...) r::) (=' c{::-ë> ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~~#~~~~~~~~~~~~~~~~~~~#~~~~#~~ ~~#~~,~,~,~,~,~~~~,~,~~~#~~~,## TIME /r (~ 160 ---- 150 140 130 120 - !:!:. e! 110 ~ .. I! G) Co 1 00 E {!!. 90 80 70 ...... 60 -- 50 0 .-- ;z -" ~ fD ? c:: Z .!':.f) 0~ N c:J c:::) ~--'I "- 1000 Redoubt Unit #D1 - Temp Log August 12, 2001 .~ ~ 2000 3000 4000 5000 Depth (ft) 6000 ~ 9000 7000 8000 t . )- . STATE OF ALASKA . ALASKA OIL A~D GAS CONSE,RVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS t.Ðã 1. Type of Req uest: Abandon: Suspend: Alter casing: X Repair well: Change approved program: Puli"iübing: Operation shutdown: Plugging: Vaiiãñce: 5. Type of well: Development: Exploratory: Stratigraphic: Service: Re-enter suspended well: _ Time extension: Stimulate: Perforäte: Other: 6. Datum elevation (DF or KB) 90' MSL 7. Unit or Property name Redoubt Unit 2. Name of Operator Forest Oil Corporation 3. Address 310 K Street, Suite 700 Anchorage, Alaska 99501 4. Location of well at surface 1915' FSL, 322' FEL, Sec. 14, T7N, R14W, SM At top of prod uctive interval x At.. effective depth 1915' FSL, 322' FEL, Sec. 14, TIN, R14W, SM At total depth 1915' FSL, 322' FEL, Sec. 14, TIN, R14W, SM 12. Present well condition summary Total depth: measured true vertical 8. Well number RU #D1 9, Permit number 201-085 10. API number 50-733-20502-00 11. Field/Pool Redoubt Shoal Oil Field Redoubt Shoal 8,611' 8,611' Plugs (measured) Effective depth: measured 8,520' true vertical 8,520' Casing Length Size Structural 200' 36" Conductor Surface 2,517' 95/8" Intermediate 8,600' 75/8" Production (Uner) Uner Perforation depth: measured Junk (measured) Cemented Driven Measured depth 200' True vertical depth 200' to Surface TOC 2,000' (estimated) 2,517' 8,600' 2,517' 8,600' true vertical RECEIVED JUL 1 7 2001 Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Alaska Oil & Gas Cons. Commissior Anchorage 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: 14. Estimated date for commencing operation 18-Jul-01 16. If proposal well verbally approved: 15, Status of well classification as: Oil: Gas: . Suspended: Name of pp over Date approved Service: Class II Disposal 17. I hereby that the foregoing is true and correct to the best of my knowledge. Signed: / Title: Drilling Manager, Forest Oil Corporation Date: 11~'l C \ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness. Approval N030 \. ~ rv l Plug integrity_ BOP Test_ Location clearance_ 0¡l!1 Mechanical Integrity Test~ Subsequent form required 10- 4ö7 f11JpttwCÚ ,fiff ~ ftGYn 53210' - ð~ MP (fZr' r.e,~.w~ ,~ ~ ~lLlL LLf, perfs i1ðt arpt~R-Lt.ð'I-~S -hI rYLt' '.Dt.$fx:15td .op:.xzúi'an) ar f.~ CÜhtl~! ~ thL ðtL.bmf,:) S 1 '11 o(~ I nfok-y'" t- - dp P rUý '&1 of. ~lli-f<€.r ~t1'fJt1on on:LU'- t.. B1 s~ ðr\1-ut1an orc.ttr·,~. ' ,~, r b) f"'I i] ORIGiNAl SIGNED BY ~t.;åIl\!N!:l; JU!'\J (, <9 2DD\¡ ,/. Approved by order of the Commissioner J. M. Heusser Commissioner Date 71J q /0 I Form 10-403 Rev 06115/88 ORIGINAL SUBMIT IN TRIPLICATE &" . . RU #D 1 Casing Schematic 36" Piles 9 5/8" 47#, L-80 BTC 7 5/8" 29#, L-80 Hyd 521 200' 3 1/2" 9.3# tubing 2517' RECEIVED JUL 1 7 2001 Alaska Oil & Gas Cons. Gommissior Anchorage Baker Model SC-2P Packer 7,620' Pen orations 8,612' - 8,450' 8600' SC/'tNNEL )~ pi~ '-"]I ~ 20nA t. L!\i t., {;.,¡¡¡.;L.J. ID ð I Task Name 1 Redoubt Unit #01 2 rn:3 Run and Cement 7 5/8" Casing 3 Cleanout 7 5/8" 4 Run Gyro 5 Run Usit Log in 7 5/8" 6 Perforate on Drillpipe 7 Run Baker Retrievable Packer 8 Lay Down Drillpipe 9 Run 3 1/2" Completion 10 Nipple Down BOP 11 Nipple Up Tree 12 Perform MIT :¡¡; () j7 ~ z m 0 L~ C -;;;::: ¡¡.~ ~ª r-...J CJ c::; ,.f:- Task Project: Redoubt Unit Gantt Chart Date: Jul17 2:51 PM Split Progress Milestone Duration 194 hrs 48 hrs 24 hrs 6 hrs 12 hrs 4 hrs RECEIVED JUL 1 7 2001 Osprey Platform I Start Jul15 12:00 PM Finish Jul 23 2:00 PM Jul15 12:00 PM Jul17 12:00 PM Jul17 12:00 PM Jul18 12:00 PM Ju11812:00 PM Jul 18 6:00 PM Jul18 6:00 PM Jul19 2:00 AM Jul 19 2:00 AM Jul 20 2:00 AM Jul 20 2:00 AM Jul 20 10:00 PM - -----~-- ~ Jul 20 10:00 PM Jul21 10:00 AM Jul 21 10:00 AM Jul 22 10:00 AM Jul22 10:00 AM Jul 22 10:00 PM -----.-------" -------- ---- - Jul 22 10:00 PM Jul 23 10:00 AM - ------- ----- Jul 23 10:00 AM Jul 23 2:00 PM Alaska Oil & Gas Cons. Commission Anchorage I ~ ~ ~ t~ ~ ¡ ~ m m ¡~ m mw ~~ ~~ ~~ ~~ I III1IIIII IIII1IIIII . Summary Rolled Up Task . .... [~¡~ ¡ m H ¡~ ~ ~~ ~ H t ~ ~ @ ¡ ~ ~ ~ ¡~ ¡ ~ ¡ I Rolled Up Split I I I I I I I I I I I I I I I I I I I Rolled Up Milestone 0 Page 1 Su 15 .... MO 16 ITh 19 Isa 21 ITU 17 we 18 I Fr 20 ~ -- . - . -- - -- -.- , . -~ ....... -........... ...... ...... -...................... ...... -...................... ......................-.-.-......... .. - -.................... -.. ........ -.................... ......-.-......................... ...... - -.................... . . . I I . . I····'---~ . ................ . ................ , , , , , I .:.:-: I .:-:.: , . ~ ~ , , ;..j,. , , ~.._--"~ I ~....._......... , , , , . I"-"---~ ' , · ....... I ....... · ...... , . · , : : W??? · , . Rolled Up Progress External Tasks Project Summary ~ . "n"--~ ~ I Su I Mo ..- 22 23 .... ~ ., .. ,~ ~ . ~ FOREST OIL COR PO R AT ION ..3'10 dY(ÇV;n~el. e;Jl;u./i? 700 cRÝ;? (~ho)(a;fFJ, QYi/c;r,¡¡{:a ,9,9:;01' (1)()7) 2.sÔ'-rS'6'()(J · (.9()7) 2/J8-S6'()j (d~a,r) July 17, 2001 Tom Maunder State of Alaska Alaska Oil And Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RECEIVED JUL 1 7 2001 Alaska Oil & Gas Cons. Commissior Anchorage Dear Mr. Maunder, We are in the process of completing Redoubt Unit #D-l (injection well). We have set 7 5/8" casing at 8,600'. In examining the logs (quad combo) that was run before casing job the chlorides are not consistently above 10,000 ppm as originally anticipated. I am attaching copies of the logs and a time line for completion of this well. We are planning to perforate 8,216' to 8,450' (234') for the initial target injection sand. The backup sand which we do not intend to perforate at this time is 7,650' to 7,900' (250'). Our permit to drill issued July 7, 2001 #201-085 stated that authorization to set a packer, perforate or inject in this well is contingent upon subsequent approvals. Attached to this letter is a 10-403 showing the current status of the well. We would like approval to perforate and set a completion packer as shown in the attached diagram after running the cement bond log. We understand that the injection order we are seeking will be subject to an acquifer exemption because of the chloride concentration. ìL Please call me at 868-2134 if you have any questions. crn;'1k you, ~&WW Paul White Drilling Manager, Forest Oil Corporation ~O~~~~ \ ~ ().~().\"1è ~~ ~'«\.I (,.,t¡,T\"C)+ ~~~O~~ ~~~\ \ ~"{( ~t:CJ \~~,~"~cl . 1:~~~~a~ ú.~~~\~ ~"'\~ "'\~~~ If:,~~I\'-C\ ,.\ IN" (;'11 t3 ?OD ~ c::"...,~~., 't\\"'~.' \\.·\~\\\\\CI;-., II~ ¡: '\ ,¡',' J', ;:,.,¡. \~\:;:).ritl'tJD\Jbl1-,,; <:þ~,ii ",,,, L. OR\G\NAl_ ) ') PLACk. LO Pi) ,.j ~o·r~ Af::::.t) T DJb Fi"~s - ~J fV\ - :doubt Unit lease descriptions ,~ I Subje£t: Redoubt Unit lease descriptions Date: Fri, 6 Jul2001 17:54:59 -0600 From: Jim Arlington <JDArlington@forestoi1.com> To: "'wendy _ mahan@admin.state.alcus'" <wendy _mahan@admin.state.alcus> cc: Paul White <PDWhite@forestoi1.com>, Nancy Culverhouse <NKCulverhouse@forestoil.com> Wendy, Attached is the information you were requesting to include in the aquifer exemption for the injection order at Redoubt. If you need more information, please let me know. «Redoubt Unit Lease Descriptions_7-06-01.doc» Jim Arlington Land Manager-Alaska Business Unit e-mail: jdarlington@forestoi1.com Forest Oil Corporation 310 "K" Street, Suite 700 Anchorage, Alaska 99501 Office Phone: (907) 258-8600 Direct Line: (907) 868-2112 Fax: (907) 258-8601 ".....:...,,,,,............,,,,,,.......,..,,...,.....,,.,,......,,,,............,,,....... .... ,,,....,,,,,,,,........,,,,,,,.,,,,,,'......',,,,,,,,,.,,.,,.....,,,,,,,,..,,..,,,..,,....,,,,.....,.......................,...............,......................"...............................",..".............................,......,.,..,..,..,.............."..,..............,....,..,....,.."........,,,...... Name: Redoubt Unit Lease ~ b· L D .. 7 06 01 d ! Descriptions 7-06-01.doc ,llit:JRedou t UnIt ease escnptIons - - . oCr Type: WINWORD-File (application/msword) l Encoding: base64 ),. . f .U'..... ...... ........ ..... ... ....... I"''' _r'" <~C.l~,lr~;\ïFL !:I: i!~j:' ~).I (;.1) 2no~n '... v IV; t", t(.· Ç]J u 4- 1 nf' 1 7/9/01 10:52 AM ,) STATE OF ALASKA ) RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL JUL 0 6 '2001 20 AAC 25.005 Drill: X Re-Entry: 2. Name of Operator Forest Oil Corporation 310 K Street, Suite 700 Anchorage, Alaska 99501 4. location of well at surface 1915' FSl. 322' FEl, Section 14, T07N, R14W, SM At total depth 1915' FSl, 322' FEl, Section 14, T07N, R14W, SM 1 a. Type of work 1 b. Type of well Service: x Redrill: Deepen: X 3. Address 12. Distance to nearest property line 13. Distance to nearest well 3365 feet 16. To be completed for deviated wells Kickoff depth: nla feet 18. Casing program size Casing 36" 6800 feet Maximum hole angle: nla Exploratory: Developement Gas: 5. Datum Elevation (OF or KB) 90' MSl 6. Property Designation 381203 7. Unit or property Name Redoubt Unit 8. Well number Redoubt Unit #01 9. Approximate spud date 1-Aug-01 14. Number of acres In property Nas~a Oil R, Gas ConS. Commission DeAeIdporigt Oil: Multiple Zone: Stratigraphic Test: Single Zone: 10. Field and Pool Redoubt Shoal Oil Field Redoubt Shoal 11. Type Bond (see 20 MC 25,025) Type: Statewide Oil and Gas Bond RlBOOO1940 Amount: $200,000 15. Proposed depth (MD and TVD) 23,526 8,600' MD I 8,600' TVD 17. Anticipated pressure (see 20 MC 25.035 (e)(2» Maximum surface 817 psig At total depth (TVD) 3150 Setting Depth feet psig Hole Driven 121/4" 8 1/2" Specifications Top Bottom Quantity of cement Grade Coupling length MD TVD MD TVD (include stage data) Welded 200' Surf Surf 200' 200' nla l-80 BTC 2,500' Surf Surf 2,500' 2,500' 2690 cu ft L-80 Hyd 521 8,600' Surf Surf 8,600' 8,600' 1047 cu ft measured proposed depending on logs 7,650'-7,820' and 8,250'-8,400' true vertical same 20. Attachments: Filing fee: x Property Plat: BOP Sketch: Drilling ~rogram: Time vs. depth plot: Refraction analysis: 21 . I herby ce i':: at the foregoing is true and correct to the best of my knowledge: Signed: ~ Paul White Title: Drilling Manager Commission Use Only Permit Number API number Approval date See cover letter Z ð / - 0 <6 S 50- /'3.:3 - .z. 0 .5 cJ Z- for other requirements Conditions of approval Samples required: [] Yes .N No Mud log required: [] Yes M No Hydrogen sulfide measures [] Yes M No Directional survey required [] Yes "Þ4 No Required working pressure for BOPE [] 2M; [ X ] 3M; [] 5M; [] 10M; [] 15M other: c.æ.~,,\-o.~\l~ ~(j'K\T Weight 95/8" 75/8" 47# 29.7# 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet true vertical feet Effective depth: measured feet true vertical feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Approved by Form 10-401 Rev. 12-1-85 Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth Diverter Sketch: Seabed report: Drilling program: 20 AAC 25.050 requirements: X Date:' ~ ~ \ Commissioner by order of the Commission Date: §ct.W~~\\N\\FJ;n~~1 ~. ~~ ~DD~j· Submit in triplicate . \ è .J ) ) FOREST OIL CORPORATION .:JI() QY{'oY/n?-e/. ¿¡¡;~/:té 700 Qçýnr:hOlr('~ve J QRt'k"dk.a .9.9.501 (.907) 2/;S-<S'6'O(l · (907) 2.irY-S6'Of (d.øa.r) July 5, 2001 Re: Deepen RUD-l (10-403) RECEIVED JUL 0 5 'zOOT . Alaska 011 & Gas ~ Commission Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7ili Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Weare in the process of drilling the above referenced well and would like to revise the depth w~ had stated on our original well plan. We would like to drill the well to 9,000' MDffVD and are looking at perforating for injection from 7,650'-7,820' and 8,250'-8,400' depending on open hole logs. Perforating at these depths should get us well above the 10,000 ppm chloride levels that are of concern. However we want to continue to pursue the åcquifer exemption we have applied for. If you have any questions, please contact me at 258-8600. ~~~ Paul D.White Drilling Manager - Alaska Division Forest Oil Corporation ~(C" 1Ì\ ~t.¡¡¡r\g µ';':¡I .) Ii Ii Ii í,," G.,Þ t:.(~ CJDfLí¡ 1dJ~V-l\U'i'J~\J~ib. ~,\J,;~ to!! <,:Ji L li'"t " ' ) ) Redoubt Unit Lease Descriptions The Redoubt Unit is comprised of five State of Alaska leases in their entirety described below: AOL-374002: ADL-378114: ADL-381003: ADL-381201 : ADL-381203: T7N, R13W. Seward Meridian, Alaska Section 19. Protracted, All, 615 acres; Section 20, Protracted, All, 640 acres; Section 21, Protracted, An, 640 acres; Section 28. Protracted, All. 640 acres; Section 29, Protracted, All, 640 acres; Section 30, Protracted, All, 617 acres; Section 31, Protracted, All, 619 acres; Section 32. Protractt)d, AU, 640 acres; Section 33, Protracted, All, 640 acres; Containing approximately 5,691 acres. T7N, R13W, Seward Meridian, Alaska Section 4, Protracted, All, 640 acres; Section 5, Protracted, All, 640 acres; Section 6, Protracted, All, 610 acres; Sedlon 7, Protracted, All, 612 acres; Section 8, Protracted, AIt, 640 acres; Section 9, Protracted, All, 640 acres; Section 16, Protracted, All, 640 acres; Section 17, Protracted, All, 640 scres; Section 18, Protracted, AU, 613 acres; Containing approximatefy 5,675 acres. T7N, R14W, Seward Meridian, Alaska Section 33, Protracted, All, 640 acres; Section 34, Protracted,'AtI, 640'acres; Section 35, Protracted, All, 640 acres; Section 36, Protracted, All, 640 acres; . ~. ~ ,"" . . 'hO ~ Containing approximately 2,560 acres. - ,-, --.. .,-,.. .'- T6N, R14W. Seward Meridian, Alaska Section 1 ,Protracted, All, 640 acres; SediOn"2,Protractèd,-AfI, ~;O acres; Section 3,Protracted, AU, 640 acres; Section 10,Protracted, AU, 640 acres; Section 11, Protracted, All, 640 acres; Section 12,Protracted, All, 640 acres; Section 13, Protracted, All, 640 acres; Section 14, Protracted, All, 640 acres; Section 15, Protracted, All, 640 acres; Containing approximately 5,760 acres. T7N, R14W, Seward Meridian, Alaska Section 13, Protracted, All, 640 acres; Section 14. Protracted, All, 640 acres; Section 23, Protracted, All, 640 acres; Section 24, Protracted, Alt, 640 acres; Section 25, Protracted, All, 640 acres; Section 26, Protracted, All, 640 acres; Containing approximately 3,840 acres. #10 ') ~,~cr.mlír,E 0rre @~ @@;fl,® @ 1 tJ=\1 U Lb (lJ If W G Ul'J ® LJ ~ Ul'J "' ~. ) ,f f ! ;, {' I' e J.. M , ALASIi& OIL AND GAS eOlVSERVATION..,ÇOMMlSSION / / I I TONY KNOWLES, GOVERNOR 333 W. TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 .,. ~'. .' August 9, 2001 Paul White Forest Oil Corporation 310 K Street, Suite 700 Anchorage, AK 99501 Re: Well Redoubt Unit #D 1 Disposal Considerations Dear Mr. White: The Commission granted Disposal Injection Order #22 today, governing injection in the Redoubt Unit #Dl well. The Order was issued with the understanding that Forest will obtain and supply to the Commission, as soon as possible, results of fracture modeling for the two injection zones authorized for disposal by the Order, from 7650' to 8450' measured depth. Forest should also consult with Commission staff regarding your ability to meet the requirements stated in the Order prior to initiating injection into the RU #D 1 well. At a minimum, annual, regular fill depth tags are also required. Also annually, additional investigative monitoring including, but not limited to temperature surveys, step rate tests and pressure falloff tests may be required as determined following consultation with the Commission. Injection into any intervals other than those identified in the Order will require, at a minimum, sundry request and Administrative Approval. The Commission may also impose surveillance measures at that time such as additional cement bond logs or other diagnostic tools to help ensure confinement of injected wastes into any other proposed disposal zones. Please feel free to call either myself or Tom Maunder if you have any additional questions. Sincerely, \0~M.J\¿- Wendy Mahan Natural Resource Manager ·S·ClJ\~¡~E[' JUN ~ 3 2.00~· #9 · 08/03/~ FAX 907 258 8 ) ~ i @ TO: FAX NUMBER: DATE: FROM: PHONE NUMBER: TIME: COMMENTS: ó'~fof./ ...s 0"'" 7 ~ --I-- r,J ¡oS ~ .R~ ~ek~.../tz. FOREST OIL ALASKA ) I(lJ UU1; uuz FOREST OIL CORPORATION II ' , 310 K Street, Suite 100 Anchorage, Alaska 99501 (907) 258-8600 - Office (907) 258-8601 - Fax: .5'"1(f.#J- ,I)a VI~ 2.7,( - 7Sf/¿ .O/J/ðl :Rø ¿, Ö .f/hf'O'1 .. t,; OJ .4.11 Tot~,1 Number of Pages In,clu~i!,g Cover Sheet; Z- -f ~ -ftc .¡ 7 ¡? . "/I :fir- C. el"S" "!J $& k,., ..:t c. Ie :#t.. rh '7 17 ~ /ð-Yð J -fur- 7 -P yð..... C ð,,/ re".,l. t'" ì!- 74- C {J"''' t! e:/..øI (/,,(1 " 4, /I"e4~ #¿)I µr,//, W¡"/1... '#/'3 ?,:{~ ;;:r ~b RECf1VfP - AUG 0 3 2001 A\aaka Oil & Gas Cons. Gomffi\Ss'Ot; AnchoraQe SC/-Ü~~\ij\t\-~ n 1~" ")1 ~~ ?nQ:1, , 08/03/:__ FAX 907 258 8 ) ~ FOREST OIL ALASl\A , j RU #D 1 Casing SchelIlatic 36" Piles 9 518" 47#. L-80 BTC 7 5/8" 29#, L-80 Hyd 521 200' 3 1/2" 9.3# tubing , 2517' ) It!:J VV,,"I VV,," aaker Model SC-2P Packer 7,620· Perfomtions 8,216' - 8ASO" 8600' RECEIVED AUG 0 J 2001 Alaska Oil & Gas Cons. ComnvsslOlI Anchorage $C!-~~\H\gEr' If!. U~D Ci) ~ 2nn (¡ " u ~,; ~\: ~:~ 0J -U uGJ. #8 JUL 2 7 2001 RedoubtUnit,.'#DlWell Osprey.,',.,·Platform RECEIVED Alaska Oil & Gas Cons. Commission Anchorage prepared for Forest Oil Corporation 310 K Street, Sliite 700 ... 1 Å 1 1 ^r'\.",^~ r1...u~¡J.J.v.1 aõ~, r1...1U.;).1"-U ././..J V 1. ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~I ~ ~ ~ ~ ~ ~ Q ~ V ~ ~ ~ ~ ~ ~ ~ ~ Q Q V ~ 6 ~J $ ~ i~ ~ ~ ~ ~ 0 Q ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~,' ~ ~I ~ ~ ~ ~Efl;f:r9 Revised Application July 2001 , , ~ ~ (,:: ¡ T j' j i' L U ~~ .J U i 11 1\ Ú ¡:~ ~~ ¡~ h 11 u ¡¡ U i.J j ,..-...-'. ." ;""1 ..' L.; ¡J, ~ u w ...' ~ I.¡ ..;" v ,,:., ~ ~ __ ..J ". W ". ..... ..... ..;;' .;:.. l:" ¡,.,; .;.. ;'¡' '-, i.;.. :,; ~. .... ,.I 0 ..... ...: oJ ...:; ..... u 0:; ...., ...:, ;... ..J .... ....' LlJ v ~ '...' oJ ..... -' ..;. ... ..:.. ~~. 1.1 \.::.. ..: :.... 'J: ,,~ ." ::t (<" ""t'o r;¡ SCl~,~\\\~'\n:r: JUN [. ,;) It ¡!J~ä' ( Table of Contents Page Overview 1 Section 1. Location 2 Section 2. Operators and surface owners 4 Section 3. Affidavit 5 Section 4. Description of Confining and Receiving Zones 7 Section 5. Logs of disposal well 8 Section 6. Casing program and procedure for demonstrating MIT 10 Section 7. Type of oil field waste 13 Section 8. Injection pressure 14 Section 9. Fracture Propagate 15 Section IO.Water quality 16 Section II.Freshwater exemption 17 Section 12 .Mechanical condition of adj acent wells 18 Section 13.Disposal Injection Order, Proposed Findings 19 Proposed Conclusions 21 Proposed Rules 22 Section 14.Aquifer Exemption Order, Proposed Rules 24 Proposed Conclusions 25 Attachments: #D1 Well Log #Dl Cement Quality Log A B ( ( Overview Forest Oil Corporation requests authorization to inject Class II waste fluids into permeable sands of the Upper Tyonek Formation, at depths below 7650 feet TVD in its Redoubt Unit #D 1 well. The RU #D 1 well was drilled as a straight hole ftom the Osprey Platform. The well is located approximately 1915 feet ITom the south line, 322 feet ITom the east line of Section 14, T07N, R14W, Seward Meridian. A copy of the permit is on file with the AOGCC. The total dissolved content of formation water encountered in the drilling of the #D1 well indicates that salinity below 3,650 feet TVD is greater than 3,000 mg/l, and often exceeds 10,000 mg/I. Forest Oil requests an aquifer exemption be granted under 40 CFR 147.102(b)(2)(i) and 20 AAC 25.440(c) for the all horizons below 3,650 feet TVD within a one-half mile radius of the #D1 well. Forest Oil believes that any ITeshwater encountered within the proposed injection zone will have a total dissolved solids (TDS) content greater 3,000 mg/l, and that such water could not reasonably be expected to supply a public water system because of its location, depth and the abundant availability of water elsewhere in the region. The information included in the following sections is intended to satisfy the submission requirements under 20 AAC 25.252 and 20 AAC 25.440. In addition, Forest Oil has included proposed findings, conclusions and rules for the Commission's consideration in developing the requested disposal injection and aquifer exemption orders. 1 ( ,( Section 1 Location r20 AAC 25.252(c)(1)] The Redoubt Unit (RU) is located in the Cook Inlet, approximately two miles east of the West Forelands area. The field is being developed from the Osprey Platfonn located at latitude 600 41' 46.3" north, longitude 151040' 10.2" west. The RU #DI disposal well was drilled as a vertical well to approximately 8600 feet TVD. It will be used to inject oil-based drilling muds, produced wastes and other approved Class II fluids. The Osprey Platfonn sets in approximately 45 feet of water. The platfonn is a four column steel structure similar to other Cook Inlet platfonns. Production wells from the platform are directionally drilled to the producing fonnation. The RU #DI disposal well is the only vertical well planned from the platform. Consequently, significant separation, on the order of one-half mile or more, will exist at the top of the proposed injection zone at 7650 feet TVD between RU #DI and other wells drilled from the platform. At this date, the proposed RU-3 well is the closest well to the RU #DI well, and is offset by more than 3000 feet at the disposal zone top. A plat showing the location of the proposed RU #D 1 disposal well and surrounding wells is attached as Exhibit 1-1. 2 3 4 5 6 1 2 1-21-_-_1 I I I- I - 31 I .~ ; '. ,- ¡' ", ',," ,." 06N i~Wœ=~ 06N 13W II - I -, ., " ",;,;t REDOUBT UNIT RU 01 : b7f'J 13W D;.~¡ I Q7N I.JW ' D8N 13W ,-\w """ '-----' FOREST OIL 30 21 20 23 RU 16 Osprey J,?latforrn 14 ~ 13 9 8 7 12 1 1 4 5 6 1 2 33 32 31 36 35 Location Map Exhibit 1-1 ( ( ( Section 2 Operators and Surface Owners r20 AAC 25.252(c)(2)] Forest Oil Corporation is the only operator within one-quarter mile radius of the RU #Dl well. The company's address is: Forest Oil Corporation 310 K Street, Suite 700 Anchorage, Alaska 9950 I The State of Alaska is the only surface owner within one-quarter mile radius of the RU #Dl well. The Department of Natural Resources, Division of Oil and Gas, manages the state lands under lease for oil and gas development. DNR's address is: Department of Natural Resources, Division of Oil and Gas 550 West 7th Ave., Suite 800 Anchorage, AK 99501 4 \ ( Section 3 Affidavit [20 AAC 25.252(c)(3)] The affidavit of Paul White, Drilling Manager for Forest Oil Corporation is attached as Exhibit 3.1 5 I ( (- Exhibit 3.1 Affidavit of Paul White I, Paul White, as agent for Forest Oil, Inc. declare and affirm that I have knowledge of the matters set forth in this application and that on'} j 7/ Q I , the following surface owner, as sole owner within one-quarter mile ofJ.¡e R,kdoubt Unit, was provided a copy of this revised application for a disposal injection order by certified United States mail from Anchorage, Alaska. State of Alaska Dept. of Natural Resources Division of Oil & Gas 550 West ih Ave., Suite 800 Anchorage, AK 99501 Attention: Mark Meyer, Director Responsible Official: Q~ Paul White Drilling Manager Forest Oil Corporation *************** Notarization The foregoing affidavit was acknowledged before me the 6J I day of ~ \1 I (\. ~ , 200~-<.,by Paul White, who is personally known to me or who has produced '-~ir l~ l)() \ as identification and who did take an oath. (\~'.I F\ ~ N~~~~ (\ fY) ~ ff\. r,.:yrod e h Printed, Typed, or Stamped Name COíi1mis$,ion E;(ph'F3· Commission Number: llo <6~L\ ~I \5\0""3 Commission Expires: 6 t ( Section 4 Confining and Receiving Zones [20 AAC 25.252(c)(4)1 Geologic information on the confining and receiving zones is based upon log data from the RU #D1 well. ~, Injection Zone: Forest Oil has identified two sands within the Upper Tyonek Formation for disposal injection in the RU #D1 well. The upper sand is located between 7650 feet TVD and 7900 feet TVD. The lower sand is located between 8216 feet TVD and 8450 feet TVD. The lower sand will be the primary injection zone and the upper sand the secondary injection zone if injection problems develop within the deeper sand. The Upper Tyonek Formation is fluvial in nature and, at this location, consists primarily of anastomozing stream channels, which produced blanket-like sand intervals that are continuous both horizontally and vertically. Porosity and permeability are good within the Tyonek sands, which are very friable and generally medium grained, well- rounded and well-sorted. Porosities range from 20 % to 30 %. Confining Zone: Interbedded with the Upper Tyonek sands are numerous claystones, siltstones and coal, which will serve as effective barriers to upward migration. Between the upper and lower sand, from approximately 7850 feet TVD to 8100 feet TVD, and above the upper sand, from 7250 feet TVD and 7500 feet TVD, are two claystone layers that will serve as the primary confinement zone for injection within the #D 1 well. In addition to the interbedded claystones of the Upper Tyonek Formation, the numerous thick coal seams and extensive interbedded clay/siltstones within the overlying Beluga section will also act as confining layers preventing the upward migration of disposal fluids. At the proposed RU #D 1 well location, approximately 1600 feet to 1800 feet of Beluga Formation overlies the Upper Tyonek Formation. The Beluga Formation is also fluvial, but stream channels are less numerous and more isolated by siltstone, clay and coal deposits and than in the Tyonek. Log data from the adjacent RU-1 well reveals that the Beluga section contains thick silt/claystone intervals, with numerous thick coal seams and interbedded sands, from the surface to 1800 feet MD. The mud log from the Redoubt Shoal State 29690 #1 well confirms the existence of confining rock throughout the Beluga section. The mud log reveals at least 440 feet of clay and 170 feet of siltstone within the Beluga section between 700 feet and 1800 feet MD. Based upon log analysis, Forest Oil believes that the effective porosity of the various silt/claystone sections penetrated by the #D1 well is zero. Accordingly, the numerous impermeable siltstones and claystones within the section should serve as effective barriers to upward migration of injected fluids. In addition, the thick coal seams also have an effective porosity of zero and should help act as confining barriers as well. 7 ( i( Section 5 Logs of disposal well r20 AAC 25.252(c)(5)] The well log for the RU #D 1 well is included with this revised application. In addition, well logs for the recently drilled RU #1 and RU #2 wells, as well as the Redoubt Shoal State 29690 #1 well, drilled in 1967, are also helpful in understanding the geology of the area. These well logs are on file with the Commission. Based upon seismic data from the area, continuity appears good between these two wells and the proposed RU #D1 well (see Exhibit 5.1). 8 Exhibit 5.1 Scale ~ o 500 1000 1600 2000 F..t RU #1 Disposal Well -leee9 -9500 -990e -6509 -8999 -7599 = t -6599 Q -7000 i &¡,. .... " I i en R U # 1 - Disposal Well Cross Section 1007 ( ( Section 6 Casing program and MIT procedures [20 AAC 25.252(c)(6)] The proposed casing and cementing programs for the RU #DI well is listed below. Exhibit 6-1 shows the well bore diagram for the RU #D 1 well. i ! Settin 0 Depth Quantity f::.·.':..¢·~i(~·g:,·,~.~~á~~.!!.i:,·:::.r::'.'::::::,·,·::,·::::::,':::::.~·p~:~IQ~.~!:(~~:~:::·::::::.·,·:.·~::...':..:::.......1.":.',.::..:.:.':::..:..::....:.'....:.·.·.t~.P:::,·.·,·,·:,::::.·,·:.·:::::::,·::,],·':::.',·::.·:::.·::.·.'·.·::.·.·...·:.·:::.ª:.~.~.~.!!i::.':.:~:'...'...'::...:.'.~':.:.:..::.,.......ç.~,~,~~~........,.,..,...................... Hole I Casing I Weight I Grade.. Length MD l TVD j MD I TVD Driven i 36" I i 200'! Surf. 'Surf I 200' i 200' NI A :....................................................,......................................................·.........,·..·...................·..·.......·....·....·.............·..........·......r........,........·......·..,........,..........................·..·..·....l..........·......·..·.......................,..............................................................'.....'............................................................. ! 12114" 9 Is" 47# i L-80 2,517' \ Surf. Surf. 12,517' i 2,517' 3074 cu. ft. ["...8...·y;;·;......·......···....7....5j8;·;........·..·....·2~f7#....·......T....L:·áo..·....·.._....·á:·6'óó';........r...S~~{·...........·......S~~f."..·..·..r..·8';(5·0ó';..........·...r..·8..;·6'óó';......................·_......ifÖ(j....~~·:·..·it:·...·.........·..·..·..··· Casing Joint Strength K lbs 122 566 Body Strength Klbs 1086 683 Burst Psi 6870 6890 Collapse Psi 4760 4790 9 5/s" 47# L-80 7 5 Is" 29.7# L-80 Tension Burst Collapse Straight Hook Load - Ignoring Deviation and Buoyancy Full Column of Gas against deepest formation pressure Full evacuation of the inside backed by expected formation gradient of.45 psi/ft on the outside of casing. 95/8" 47# L-80 Surface Casing Tension =2517' x 47# =118.3 K Burst =(8611' x .45)-(.10 x 8611 ') =3014 psi Collapse =(2517' x 45)-(.10 x 2517') =881 psi Rated = 1086 Safety Factor = 9.2 Rated = 6870 psi Safety Factor = 2.3 Rated = 4760 psi Safety Factor = 5.4 75/8" 29.7# L-80 Intermediate Casing Tension =8600' x 29.7# =255.4 K Burst =(8611' x .45)-(.10 x 8611 ') =3014 psi Collapse =(2517' x 45)-(.10 x 2517') =881 psi Rated = 1086 Safety Factor = 4.2 Rated = 6870 psi Safety Factor = 2.3 Rated = 4760 psi Safety Factor = 5.4 A 3'i'2-inch tubing string and packer is set at 7,620 feet TVD. Mechanical Integrity After the packer and tubing was run in the well, the casing x tubing annulus was pressure tested to 2500 lbs on July 22, 2001. The well passed the mechanical integrity test, witnessing of the test was waived by AOGCC. 10 ( "l Forest Oil also ran a cement quality log to demonstrate the adequacy of cement to contain potential wellbore pressures and fluids. The cement quality log is enclosed as Attachment B. Packer Setting Depth Variance under 20 AAC 25.412(b) Forest Oil requests that the AOGCC approve the placement of the packer at a location more than 200 feet above the top of the perforations as required by 20 AAC 25.412. Forest Oil has place the packer at about 7,620 feet TVD. The top of the perforations in the #Dl well is 8216 feet. As stated earlier, Forest Oil has identified two separate sand layers that should be capable of accepting injected fluids, and proposes to initiate injection in the deeper-most sand interval, located between 8216 feet TVD and 8450 feet TVD. Placing the packer at 7620 feet TVD will allow Forest Oil to move injection to the upper sand if problems develop within the deeper sand. 11 Exhibit 6-1 ( ( RU#Dl Casing Design 36" Piles 95/8" 47#, L-80 BTC 7 5/8" 29#, L -80 Hyd 521 ~ 12 200' TVD 3 1/2" 9.3# tubing 2517' MD, 2500' TVD Baker SC-2p Packer 7620' TVD , Perforations 8216' - 8450' 8600' TVD ( ~( Section 7 Type of Oil Field Waste [20 AAC 25.252(c)(7)] Only approved Class II fluids will be injected into the RU #D 1 well. This waste will consist of produced water, drilling, completion and workover fluids, rig wash, drilling mud slurries, NORM scale, tank bottoms, and other fluids brought to the surface in connection with oil and gas development activity on the Osprey Platfonn. Forest Oil estimates that the average volume of fluids to be disposed will be approximately 600 bbl/day, with a maximum volume of 1000 bbl/day. The average and maximum density of injected fluids will be 10.0 ppg and 11.5 ppg, respectfully. Based upon experience elsewhere in the Cook Inlet, most fluids proposed for disposal should be compatible with the disposal zone. Compatibility problems, however, may exist for certain small volumes of non-routine Class II fluids. If a compatibility problem is identified, Forest Oil will either chemically treat the fluid to resolve any problems or will dispose the fluid by other approved means. 13 ( \. Section 8 Injection pressure f20 AAC 25.252(c)(8)1 The average anticipated surface injection pressure will be approximately 3600 psi. The maximum anticipated pressure will be approximately 4000 psi. This is based on an injection depth of approximately 8216 feet TVD, an injection pressure at the injection perforations of 18.5 ppg EMW, calculated with a 10.0 ppg slurry for the average injection case and an 8.5 ppg saltwater density for the maximum injection pressure case. Injection rate is assumed to be about five barrels per minute. Forest Oil will perform a step rate test to establish optimum injection rates and pressures. The step rate test will be incrementally increased to pump rates 100% in excess of the maximum anticipated injection rates for waste disposal. Pressure fall off data will be collected at the end of the step rate test. 14 ( '( Section 9 Fracture Propagate [20 AAC 25.252(c)(9)] Forest Oil estimates that the fracture pressure of the disposal zone is about 6150 psi. This is based upon a fracture gradient of approximately .75 psi/ft and an injection depth of about 8216 feet TVD. Fracture propagation within the disposal interval will be an integral part of the process of placing waste fluids into the disposal interval. Fractures will be created as the disposal zone begins to plug. Fractures provide pathways to transport waste fluids to undamaged storage volume within the disposal zone. Forest Oil requested BJ Services to conduct a fracture propagation modeling study of the proposed injection zone. BJ concluded that induced fractures will be localized near the well bore and confined to the injection zone. This study was previously submitted to AOGCC as part of the original application. Forest Oil plans to use reservoir surveillance techniques including, but not limited to, step rate injection tests, disposal rate and pressure monitoring, and temperature logging, to track near wellbore fluid movement, estimate the dimensions of disposal fractures, and to detect changes in disposal zone characteristics. Evaluation of operation performance and reservoir surveillance will aid in preventing any fractures being propagated into and through the confining zone. 15 (I' " (l Section 10 Water quality r20 AAC 25.252(c)(lO)] The total dissolved content of formation water encountered in the #D 1 well below 3,650 feet TVD is greater than 3,000 mg/l, and often exceeds 10,000 mg/I. Average salinity below 3,650 feet TVD in clean sands with V-shale less than 15 percent is between 5,000 to 12,000 mg/I. 16 ( il," " Section 11 Freshwater Exemption [20 AAC 25.252(c)(11)] Water salinity below 3,650 feet TVD exceeds 3)000 mg/l, and often exceeds 10,000 mg/l. Because 10,000 mg/l is the upper threshold for fteshwater as defined under state and federal regulations, Forest Oil requests an aquifer exemption be granted under 40 CFR 147.102(b)(2)(i) and 20 AAC 25.440(c) for the all horizons below 3,650 feet TVD within a one-half mile radius of the #D1 well. Forest Oil believes that any fteshwater encountered within the proposed injection zone will have a total dissolved solids (TDS) content greater 3,000 mg/l, and that such water could not reasonably be expected to supply a public water system because of its location, depth and the abundant availability of water elsewhere in the region. 17 ( ( Section 12 Mechanical Condition of Adjacent Wells [20 AAC 25.252(c)(12)] Wells in close proximity to the RU #Dl well are the RU #1 and #2 wells and the Redoubt Shoal State 29690 #1 and #2 wells. The RU #1 and #2 wells were recently drilled and completed in accordance with state drilling standards under 20 AAC 25. The Redoubt Shoal State 29690 #1 well was drilled in 1967, side tracked as the #2 well in 1968, which was abandoned in 1993 according to AOGCC records. Drilling and abandonment of the Redoubt Shoal State 29690 #1 and #2 wells were done under standards that are the same or equivalent to those in place today. At the top of the disposal zone at 7,650 feet TVD, the closest well to the RU #Dl well will be the proposed RU #3 well, which will be over 3000 feet away at that depth. The offset between #Dl well and the existing RU #2 and RU #1 wells at that depth is over 3,500 feet and 4,000 feet, respectively. Forest Oil has previously submitted a cross- section showing the well offsets to AOGCC. 18 (' ( Section 13 Disposal Injection Order Proposed Findings 1. Forest Oil is the operator of the Redoubt Unit. There are no other operators within a one-quarter mile radius of the proposed disposal injection well. 2. Forest Oil proposes to conduct disposal operations in the proposed RU #D1 injection well in strata that correlates with the Upper Tyonek Formation between the depths of 7650 feet TVD and 8450 feet TVD. At the injection depth, there are no other wells within one-quarter mile radius of the RU #D 1 well. 3. Forest Oil has identified two separate sand layers, between 7650 feet TVD and 7900 feet TVD and 8216 feet TVD and 8450 feet TVD, within the proposed injection interval that should be capable of accepting fluids for disposal. Forest Oil plans to limit injection to the deepest most sands, unless injection problems require the shallower sand to be used. 4. Interbedded with the Upper Tyonek sands are numerous claystones, siltstones and coal, which will serve as effective barriers to upward migration. Between the upper and lower sand, from approximately 7850 feet TVD to 8100 feet TVD, and above the upper sand, from 7250 feet TVD and 7500 feet TVD, are two claystone layers that will serve as the primary confinement zone for injection within the #D1 well. 5. In addition to the interbedded claystones of the Upper Tyonek Formation, the numerous thick coal seams and extensive interbedded clay/siltstones within the overlying Beluga section will also act as confining layers preventing the upward migration of disposal fluids. At the proposed RU #D 1 well location, approximately 1800 feet of Beluga Formation overlies the Upper Tyonek Formation. 6. Cased hole logs and cement records show that the RU #D1 well is cemented adequately to isolate the proposed disposal interval. 7. The RU #D1 well was completed with 36 inch conductor set at 200 feet TVD, 95/8 inch surface casing set at 2517 feet TVD and cemented to surface, and 75/8 inch production casing set at 8600 feet TVD and cemented back to 5,635 feet. 8. The RU #D1 well is equipped with 3~ inch tubing string and packer set at about 7,620 feet TVD. Placement of the packer at 7,620 feet is more than 200 feet above the top of the existing perforations. 9. The waste stream will consist of produced water, drilling, completion and workover fluids, rig wash, drilling mud slurries, NORM scale, tank bottoms; and other Class II fluids generated from drilling, production, workover and completion operations. 19 ( f 10. Forest Oil estimates that the average injection volume will be about 600 bbl/day and the maximum volume about 1000 bbl/day. 11. Forest Oil estimates the average injection pressure will be about 3600 psi, with a maximum daily injection pressure of 4000 psi, at an injection rate of five barrels per minute. 12. Fracture propagation within the disposal interval is an integral part of the process of placing waste fluids into the disposal interval. Fractures will be created as the disposal zone begins to plug. Fractures provide pathways to transport waste fluids to undamaged storage volume within the disposal zone. 13. Evaluation of operation performance and reservoir surveillance will aid in preventing fracturing of the confining zones. 14. The portion of freshwater aquifers beneath Cook Inlet described by a one-half mile radius from RU #D1 well at a depth greater than 3650 feet are exempt aquifers under 40 CFR 147.102(b)(2)(i) and 20 AAC 25.440(c) by order of the Commission. 20 I I [ [ I I I [ ( Disposal Injection Order Proposed Conclusions 1. The requirements of 20 AAC 25 .252( c) have been met. 2. Waste fluids authorized for disposal under this order will consist exclusively of Class II waste generated from drilling, completion, workover and production operations on the Osprey Platform. 3. Permeable strata, which reasonably can be expected to contain the total volume of disposal fluids anticipated for this project, are present in the Upper Tyonek Formation. 4. Waste fluids will be contained within appropriate receiving intervals by confining lithologies in the Upper Tyonek and Beluga Formations, cement isolation of the well bore and operating conditions. 5. Placement of the packer at 7,620 feet is appropriate given the thickness and depth of the confining zone, and will allow for operational flexibility should injection be required in the shallower sands of the proposed injection zone. 6. Disposal injection operations in the RU #D 1 well will be conducted at rates and pressures below those required to fracture the confining zone. 7. Periodic fracturing and stimulation will be required to place solids into the disposal interval. Fracture growth can be contained within the disposal interval by controlling the rate and volume of injection. 8. Surveillance of disposal material movement, monitoring of operating parameters and demonstration of mechanical integrity every four years will ensure the waste fluids are contained within the disposal interval. Changes in baseline data may be an indication that fluid is escaping beyond the designated confining zone. 9. The mechanical integrity of the tubing, packer and production casing in the RU #D 1 well has been demonstrated in accordance with 20 AAC 25.412. 10. Disposal injection operations in the RU #D1 well will not cause waste, jeopardize correlative rights, or impair ultimate recovery. 21 0( ( Disposal Injection Order Proposed Rules Rule 1 Authorized Injection Strata for Disposal. Class II oil fiel4 fluids may be injected in conformance with Alaska Administrative Code Title 20, Chapter 25, for disposal into the Upper Tyonek Formation from 7650 feet TVD to 8450 feet TVD in the RU #D 1 well. Rule 2 Authorized Fluids This authorization is limited only to Class II fluids. The Commission must be notified immediately if any non-Class II fluids are injected into the well. Rule 3 Demonstration of Tubing/Casing Annulus Mechanical Integrity A schedule must be developed and coordinated with the Commission that ensures the tubing-casing annulus is pressure tested at least once every four years. The casing must be tested at a surface pressure of 1500 psi or 0.25 psi/ft multiplied by the true vertical depth of the casing shoe, whichever is greater, but may not be subjected to a hoop stress greater than 70% of the minimum yield strength of the casing. The test pressure must show stabilizing pressure and may not decline more than 10% within thirty minutes. The Commission must be notified at least twenty-four (24) hours in advance to enable a representative to witness pressure tests. Rule 4 Well Integrity Failure Whenever disposal rates and/or operating pressure observations or pressure tests indicate pressure communication or leakage of any casing, tubing or packer, the operator must notify the Commission on the first working day following the observation, obtain Commission approval of a plan for corrective action and obtain Commission approval to continue inj ection. Rule 5 Surveillance Operating parameters including disposal rate, disposal pressure, annulus pressures and volume of fluids and solids pumped must be monitored and reported according to requirements of20 AAC 25.432. An annual report evaluating the performance of the disposal operation must be submitted by July 1 of each year. Rule 6 Placement of the Packer The packer may be placed more than 200 feet above the top of the perforations. Rule 6 Administrative Action 22 ( Upon request, the Commission may administratively revise and reissue this order or any of its rules upon proper showing that the change is based on sound engineering practices, will not allow waste fluids to escape from the disposal zone, and will not cause waste. 23 ( ( Section 14 Aquifer Exemption Order Proposed Findings 1. Forest Oil seeks authorization exempt aquifers below 3650 feet TVD in its Redoubt Unit #D 1 well. 2. The RU #D1 well was drilled from the Osprey Platform, and is located approximately 1915 feet from the south line, 322 feet from the east line of Section 14, T07N, R14W, Seward Meridian. 3. There no water wells in the vicinity of the RU #D1 well. 4. Other oil and gas wells drilled from the Osprey Platform are the RU #1 and #2 wells. The RU #3 well will be completed in the near future. 5. The Redoubt Shoal State 29690 # 1 and #2 wells are also located nearby. The wells were plugged and abandoned in 1968 and 1993, respectively. 6. The #Dl well is completed in sediments of the Upper Tyonek Formation. The Upper Tyonek is fluvial in nature with blanket-like sand layers that are continuous both horizontally and vertically. Interbedded with the sands are numerous claystones, siltstones. Based upon log analysis, Forest Oil believes that the effective porosity of the various siltstone and claystone sections penetrated by the #D 1 well is zero and that theses layers will serve as impermeable barriers to upward migration of injected fluids. 7. Forest Oil used a method endorsed by EP A in publication "Survey of Methods to Determine Total Dissolved Solids Concentration" (KEDA Project No. 30-956) for calculating TDS content from wireline log data. 8. Salinity data from the #D 1 well shows that the TDS content of formation waters exceeds 3,000 mg/l below 3650 feet TVD, and exceeds 10,000mg/1 in some intervals. 9. Development of the freshwater aquifers below the Redoubt Unit by entities other than Forest Oil is economically impractical because of the offshore location, water depths and currents, drilling costs and readily available alternative freshwater sources onshore. 10. The Commission's authority to act in this matter is embodied in 40 CFR 147 Subpart C, the Alaska Oil and Gas Conservation Act (AS 31.05), and the Alaska Administrative Code (20 AAC 25.005 through 20 AAC 25.570). 24 ( ( Aquifer Exemption Order Proposed Conclusions 1. The portion of the aquifer proposed for exemption in the RU #Dl well will likely have a TDS content greater 3,000 mg/l, with some intervals exceeding 10,0000 mg/I. 2. The portions of the aquifers underlying the Redoubt Unit do not now serve as a source of drinking water. 3. All aquifers below 3,650 feet that are underlying and within one-half mile radius of the Redoubt Unit are not likely to serve as underground sources of drinking water because of their location, depth and abundant availability of drinking water elsewhere in the region. It is reasonable, therefore, for purposes of underground injection, to exempt any freshwater aquifers with salinity greater than 3000 mg/l that may be encountered in the area. 4. Those portions of aquifers underlying and within one-half mile of the RU #Dl well below 3650 feet qualify as exempt freshwater aquifers under 20 AAC 25.440(a)(2). 25 ,( ( ( ~ FOREST OIL CORPORATION .J J (' c/( "c-Y/r('('1 - rYule 7(/(/ (Jcl)I('¡I('n~f/f', (JC/lrt,;J.a J)J):;(}J (.')(17) /;S-Sr),Ni · (.')('7) ~.;S-S(}'(i/ (r-/0,r) May 8, 2001 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Attention: Commissioner Julie Heusser Re: Redoubt Unit #D1 well Application for a disposal injection order and aquifer exemption Dear Commissioner Heusser: Forest Oil Corporation requests authorization to inject Class II waste fluids into permeable sands of the Upper Tyonek Formation, at depths below 3270 feet TVD in its proposed Redoubt Unit #D1 well. The RU #D1 well will be drilled as a straight hole from the Osprey Platform. The well is located approximately 1915 feet from the south line, 322 feet from the east line of Section 14, T07N, R14W, Seward Meridian. Because the salinity profile from the adjacent RU #1 wells shows some intervals with a TDS content less 10,000 mg/l, Forest Oil is also applying for an aquifer exemption for the proposed disposal zone underlying the Redoubt Unit Enclosed is Forest Oil's application for a disposal order and aquifer exemption. Please call me if you or your staff have any questions about this request or require additional information. Forest Oil will be pleased to meet with you or answer any question you or your staff may have. Thank you. Attachment ~?~ Robert S~~ Drilling Engineer SC¡~\¡f\\11~E.D ~ßUN 2 3 2004 RECEIVED MAY 0 8 2001 Alaska Oil & Gas Cons, Commission Anchorage ) ) (!alJ1lnlf ~ FOREST OIL CORPORATION .J-Iod7Cg9'~. 8euœ 700 ~J~.9.9501 (.907) 258-86'00 · (.907) 258-86'0'/ (çfØaa) May 8, 2001 . . Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 ' Anchorage, AK 99501 Attention: Commissioner Julie Heusser Re: Redoubt Unit #Dl well Application for a disposal injection order and aquifer exemption Dear Commissioner Heusser: Forest Oil Corporation requests authorization to inject Class II waste fluids into penneable sands of the Upper Tyonek Formation, at depths below 3270 feet TVD in its proposed Redoubt Unit #Dl well. The RU #Dl well will be drilled as a straight hole from the Osprey Platform. The weÜ is located approximately 1915 feet from the south line, 322 feet from the east line of Section 14, T07N, RI4W, Seward Meridian. Because the salinity profile from the adjacent RU #1 wells shows some intervals wi~ a TDS content less 10,000 mg/l, Forest Oil is also applying for an aquifer exemption for the proposed disposal zone underlying the Redoubt Unit Enclosed is Forest Oil's application for a disposal order and aquifer exemption. Please call me if you or your staff have any questions about this request or require additional information. Forest Oil will be pleased to meet with you or answer any question you or your staff may have. Thank. you. ~ Drilling Engineer Attachment ~iV¿'..l~~~'~f.C;' n ¡P\f¡ C'i' (;,.~ 200 n - .......'-- UU¡~ (-.; è), 'it /^ . 1/lovJ C hay} II¡ ¡~ ito'- , ] "Hr" n ','] 1 j ) ) ï\.;' I,'J ;'i, ()~prey P!atfor~ ,J" J . " " '.' ;'".:',.' ~'~" (, ~ i ': I', ' '. ..',." ,::. ,~' :,:,.>\;~::\:~', J':).....' ", ' ;1/", ", '.' I"'" ;', ". """ ,\ .,;':. " , ,..,' ,~:':,":'" ,- .'.> :,>:' " , , I","'" ",;'i " ~:: ' " ¡,.,', . .\ ~ ",; .' <;' ¡ :,/. .~ ì '. , , I""" ',;'" , ',',',,; '';-'" :,"r;', ¡":"" ,", ;1':.. \, . .':'ù~ "" . . . . .. . . . . . . . . . . . . . . . . . 1 I . J J J [ I N ~ ~ III N ~ ~ I ~ ~,r '!"',""~':., ~~:,.'.',.~/!~'-;"..' .. . . . . . . . . . . . . . . . . . '1 ' J ,1 ~1NtI ,.\i.ij\\ (, J 2.DO,~ } ) Table of Contents . Page Overview 1 Section 1. Location 2 Section 2. Operators and surface owners 4 Section 3. Affidavit 5 Section 4. Description of Confining and Receiving Zones 7 Section 5. Logs of disposal well 8 Section 6. Casing program and procedure for demonstrating MIT 10 Section 7. Type of oil field waste 13 Section 8. Injection pressure 14 Section 9. Fracture Propagate 15 Section IO.Water quality 16 Section II.Freshwater exemption 17 Section I2.Mechanical condition of adjacent wells 18 I '! "I Section I3.Disposal Injection Order, Proposed Findings Proposed Conclusions Proposed Rules 19 21 22 Section, 14.Aquifer Exemption Order, Proposed Rules Proposed Conclusions 24 26 Attachments: Permit to Drill #D 1 Well Fracture Simulation Study RU #1 Well Log A B C " \~"¡;'~E'L. ,}UN ~ ~ 2nO;;¡ '. "V Wi ~f ¡ . I ) ) ) :1 I ) . Overview ". J Forest Oil Corporation requests authorization to inject Class II. waste fluids into permeable sands of the Upper Tyonek Formation, at depths below 3270 feet TVD in its proposed Redoubt Unit #D 1 well. The RU #D 1 well will be drilled as a straight hole from the Osprey Platform. The well is located approximately 1915 feet from the south line, 322 feet from the east line of Section 14, T07N, RI4W, Seward Meridian. A copy of the permit to drill (Form 10-401) is enclosed at Attachment A. ,I The total dissolved content of formation water encountered in the drilling of the adjacent RU #1 well indicates that salinity within the proposed injection zone is generally greater than 10,000 mg/l, but occasionally drops below this threshold in some intervals. Forest Oil believes the lower salinity readings are the result of lithology changes and clay content, and not an indication of freshwater. . I ¡ Although freshwater is not likely within the disposal interval, Forest Oil believes that the best course of action given the lower salinity readings is to request an aquifer exemption for the disposal zone under 40 CFR 147J02(b)(2)(i) and 20 AAC 25.440(c). Forest Oil believes that any freshwater encountered within the proposed injection zone will have a total dissolved solids (TDS) content greater 3,000 mg/I, and that such water could not reasonably be expected to supply a public water system because of its location, depth and the abundant availability of water elsewhere in the region. \ ,.. The information included in the following sections is intended to satisfy the submission requirements under 20 AAC 25.252 and 20 AAC 25.440. In addition, Forest Oil has included proposed findings, conclusions and rules for the Commission's consideration in developing the requested disposal injection and aquifer exemption orders. , ., \ . j ~CJ'~~H..~EL JUN 2: 3 200~· 1 ) ) Section 1 Location [20 AAC 25.252(c)(1)] '.¡ , J The Redoubt Unit (RU) is located in the Cook Inlet, approximately two miles east of the West Forelands area. The field is being developed from the Osprey Platform located at latitude 60° 41' 46.3" north, longitude 151040' 10.2" west. The RU #Dl 'disposal well will be drilled as a vertical well to approximately 7000 feet TVD. It will be used to inject oil-based drilling muds, produced wastes and other approved Class II fluids. .i The Osprey Platform sets in approximately 45 feet of water. The platform is a four column steel structure similar to other Cook Inlet platforms. Production wells"from the platform are directionally drilled to the producing formation. The RU #D 1 disposal well is the only vertical well planned from the platfonrt. Consequently, significant separation, on the order of one-quarter mile or more, will exist at the top of the proposed injection zone between RU #Dl and other wells drilled from the platform. At this date, the RU-l wells is closest to the proposed RU #Dl well, and is offset by more than 2000 feet at the disposal zone top. A plat showing the location of the proposed RU #Dl disposal well and surrounding wells is attached as Exhibit 1-1. Please note that RU-3 has not yet been drilled. : ! , ' ! j 2 )' ') ¡ j ,.1 ·1 Exhibit 1-1 Location Map 35 36 31 32 33 2 1 6 5 £} 1 1 12 7 8 9 Osprey ~?latfor7n 1 q 13 23 16 RU 21 ì ! .. -~..- , i \,w oaN 13W 30 FOREST OIL ~ REDOUBT UNIT 13W RU 01 - '"'" ¡-ø-IIIIII-zw 31 ... I ·1 I I 06N 13W 2 1 6 5 q 3 ,I' "':'1 - ] ¡ ·1 " -.. ~ ." . ,.",- . ) Section 2 Operators and Surface Owners [20 MC 25.252(c)(2)] Forest Oil Corporation is the only operator within one-quarter mile radius of the - RU #Dl well. The company's address is: Forest Oil Corporation 310 K Street, Suite 700 Anchorage, Alaska 99501 The State of Alaska is the only surface owner within one-quarter mile radius of the RU #Dl well. The Department of Natural Resources, Division of Oil and Gas, manages the state lands under lease for oil and gas development. DNR's address is: Department of Natural Resources, Division of Oil and Gas 550 West 7th Ave., Suite 800 Anchorage, AK 99501 4 " ¡ I ,I ) ) ," , 1,' , I ',j 'I 1 Section 3 Affidavit '[20 AAC 25.252(c)(3)] The affidavit of Paul White, Drilling Manager for Forest Oil Corporation is attached as Exhibit 3.1 1 ..I ì ¡ ' ¡ ¡ I ,! ì , I 5 ) ) . '1 i ) Exhibit 3.1 ¡ J Affidavit of Paul White ,I ¡ I, Paul White, as agent for Forest Oil Corporation declare and affirm that I have knowledge of the ,matters set forth in this application and that on , the following surface owner, as sole owner within one-quarter mile of the Redoubt Unit, was provided a copy of this application for a disposal injection order by certified United States mail from Anchorage, Alaska. State of Alaska Dept. of Natural Resources Division of Oil & Gas 550 West 7th Ave., Suite 800 Anchorage, AK 99501 Attention: Mark Meyer, Director Responsible Official: V~ Paul White Drilling Manager Forest Oil Corporation *************** Notarization ! ! The foregoing affi~avit wa~ acknowledged before me the ¥- ý( day of ~/' 2001, by Paul White, who IS personaJly knowq to me or who has produced ____ as identification and who did take an oath. \\\l({(({f(II¡: \. \ n ARt,,,. 1"/ \.\ ~ v: . . . . ./lrQ 'l \.' ~ ,. --- . . ~ ~ ~ f·~OTARJ--".~ '- "'j. ~ --- .-.,,-. '- . ~ : PUB\-\C : ê - ·.ft .v"" ::: .v~ ___ ~.. ~ - . "'1h-. ..9 . ~ ~ . ·'~'OF ,..u:. ~ -:/ .... ,.. :\' :/..1,/ *, \\\ //JJ}JJJJ}\))'\ Q~ IS), ¿j¿(~ ~Iic I :JaI(ß.5 ~ . Ar¿d~-/d"f Printed, Typed, or Stampeã"Name Commission Number: &'7-5""90 Commission Expires: ;1t,,,.~1t /3 ~()~ ~ 6 \ l ) 'j Section 4 Confining and Receiving Zones [20 AAC 25.252(c)(4)] ( ! Geologic information on the confining and receiving zones is based upon log data from the nearby RU-l well. The RU #Dl well is ~bout 2000 feet from the RU-l well at the top of the proposed injection zone. Injection Zone: The intravel proposed for disposal injection in the RU #Dl well is within the Upper Tyonek Formation, and is common to and correlates with strata in the RU-l well between 3706 feet MD (3270 feet TVD) and 6879 feet MD (5810 feet TVD). The Upper Tyonek is fluvial in nature and, at this location, consists primarily of anastomozing stream channels, which produced blanket-like sand intervals that are continuous both horizontally and vertically. Interbedded with the sands are claystones, siltstones and coal. Porosity and permeability are good within the Tyonek sands, which are very friable and generally medium grained, well-rounded and well-sorted. Porosities range from 20 % to 30 %. Within the injection interval, Forest Oil has identified 13 separate sand layers that should be capable of accepting injected fluids. The sand intervals have been marked on the RU-l well log submitted with this application. Forest Oil proposes to initiate injection in the deeper-most sand intervals (i.e., sands 11-13), located between 6010 feet MD (5112 feet TVD) and 6879 feet MD (5810 feet TVD). Injection in the upper sands will only occur if injection problems develop within the deeper sands. Confining Zone: At the proposed RU #D 1 well location, approximately 1600 feet to 1800 feet of Beluga Formation overlies the Tyonek sands. The Beluga Formation is also fluvial, but stream channels are less numerous and more isolated by siltstone, clay '/ and coal deposits and than in the Tyonek. The numerous thick coal seams and extensive (" ,.., ...,.. "Ínterbedaedclàÿ/siltstoriés within tñri' övëfIyilig 'Bël1Igásectîûà will 'aèf'as confining' layers preventing the upward migration of disposal fluids. , ï .¡ Log data from the RU-l well reveals that the Beluga section contains thick silt/claystone intervals, with numerous ,thick coal seams and interbedded sands, from the surface to 1800 feet MD. Based upon log analysis, Forest Oil believes that the effective porosity in the silt/claystone sections is zero. Accordingly, these impermeable siltstones and claystones should serve as effective barriers to upward migration of injected fluids. In addition, the thick coal seams also have an effective porosity of zero and should help 'j act as confining barriers as well. The mud log from the Redoubt Shoal State 29690 #1 well confirms the existence of confining rock throughout the Beluga section. The mud log reveals at least 440 feet of clay and 170 feet of siltstone within the Beluga section between 700 feet and 1800 feet MD. 7 i I , 1 I \ ) ) ì I Section 5 Logs of disposal well . [20 AAC 25.252(c)(5)] The RU #Dl well has not yet been drilled so no logs are available from the well at this time. As an alternative, the well log for the nearby RU #1 well, recently drilled and completed, is included as Attachment B. Also, well logs from the Redoubt Shoal State 29690 # 1 well, drilled in 1967, are also helpful in understanding the geology of the area. The Redoubt Shoal State 29690 #1 well logs are on file with the Commission. Both wells are closely adjacent to the proposed RU #D 1 disposal well. Based upon seismic data rrom the area, continuity appears good between these two wells and the proposed RU #D1 well (see Exhibit 5.1). Logs will be submitted rrom the RU #Dl well when they become available. ¡ I 8 RU #1 - Disposal Well Cross Sectton IOe::: Scale -=-=:J o eoo 1 ,:. 1eoo 2000 RU #1 Exhibit 5.1 ¡ I I , Section 6 ) ) Casing program and MIT procedures [20 AAC 25.252(c)(6)1 The proposed casing and cementing programs for the RU #DI well is· listed below. Exhibit 6-1 shows the well bore diagram for the RU #D 1 well. Casing Program Hole Casing Driven 36" 12 y.." 9 5 Is" 8 ~" 7 5/s" Casing 9 5/s" 47# L-80 7 5 Is" 29.7# L-80 Tension Burst Collapse Specifications Weight Grade Length; MD 200' Surf. 47# L-80 2,500' Surf. 29.7# L-80 7,000' Surf. Setting Depth Bottom TVD ,200' 2,500' 7,000' N/A 2,690 cu. ft. 518 cu. ft. Quantity Cement Top TVD Surf Surf. Surf. MD 200' 2,500' 7,000' Joint Strength Klbs 122 566 Body Strength Klbs 1086 683 Burst Psi 6870 6890 Collapse Psi 4760 4790 Straight Hook Load - Ignoring Deviation and Buoyancy Full Column of Gas against deepest fonnation pressure Full evacuation of the inside backed by expected fonnation gradient of .45 psi/ft on the outside of casing. 95/8" 47# L-80 Surface Casin~ Tension =2500' x 47# =117.5 K Burst =(7000' x .45)-(.10 x 7000') =2450 psi Collapse =(2500' x 45)-(.10 x 2500') =875 psi Rated = 1086 Safety Factor = 9.2 Rated = 6870 psi Safety Factor = 2.8 Rated = 4760 psi Safety Factor = 5.4 75/8" 29.7# L-80 Intermediate Casing Tension =7000' x 47# =117.5 K Burst =(7000' x .45)-(.10 x 7000') =2450 psi Collapse =(2500' x 45)-(. ro x 2500') =875 psi Rated = 1086 Safety Factor = 9.2 Rated = 6870 psi Safety Factor = 2.8 Rated = 4760 psi Safety Factor = 2.0 A 3~-inch tubing string and packer will be set at about 3320 feet TVD. Mechanical Integrity After the packer and tubing has been run in the well, the casing x tubing annulus will be pressure tested to a surface pressure of 0.25 psi/ft multiplied by the true vertical depth of the casing shoe, or approximately 1750 psi, as required under 20 AAC 25.412. Forest Oil will also run a cement quality log to demonstrate the adequacy of cement to contain potential well bore pressures and fluids. Sufficient notice will be provided to 10 ) ) ,¡ i ¡ AOGCC so a witness may be present for the MIT. Injection will not begin until the casing is pressure tested and approved for injection. Packer Setting Depth Variance under 20 AAC 25.412(b) i I . ¡ Forest Oil requests that it be allowed to place the packer more than 200' feet above the top of the perforations as required by 20 AAC 25.412. Forest Oilproposes to place the packer at about 3320 feet TVD. As stated earlier, Forest Oil has identified 13 separate sand layers that should be capable of accepting injected fluids, and proposes to initiate injection in the deeper-most sand intervals (i.e., sands 11-13), located between 5112 feet TVD and 5810 feet TVD. Placing the packer at about 3320 feet TVD will allow Forest Oil to more easily and cost effectively move injection to the upper sands if problems develop within the deeper sands. , I .i ¡ 'I " ! 11 Exhibit 6~ 1 "I 1 j , , ) ,) RU #Dl Casing Design 36" Piles 9 5/8" 47#, L-80 BTC 7 5/8" 29#, L-80 Hyd 521 12 200' MD, 200' lVD 3 1/2" 9.3# tubing TOe 2000' :MD 2500' MD, 2500' lVD 7000' MD, 7000' lVD ) ,) : 'I 'I "I Sectiôn 7 Type of Oil Field Waste [20 AAC 25.252(c)(7)] : ¡ Only approved Class II fluids will be injected into the RU #D 1 well. This waste will consist of produced water, drilling, completion and workover fluids, rig wash, drilling mud slurries, NORM scale, tank bottoms, and other fluids brought to the surface in connection with oil and gas development activity on the Osprey Platfonn. Forest Oil estimates that the average volume of fluids to be dispose will be approximately 600 bbl/day, with a maximum volume of 1000 bbl/day. The average and maximum density of injected fluids will be 10.0 ppg and 11.5 ppg, respectfully. Based upon experience elsewhere in the Cook Inlet, most fluids proposed for disposal should be compatible with the disposal zone. Compatibility problems~ however, may exist for certain small volumes of non-routine Class II fluids. If a compatibility problem is identified, Forest Oil will either chemically treat the fluid to resolve any problems or will dispose the fluid by other approved means. \...,..... '1 I , .j I i .1 13 :' I " ~I ) ¡ 1 I Section 8 Injection pressure [20 AAC 25.252(c)(8)] , 1 I , \ I 'j The average anticipated surface injection pressure will be approximately 2650 psi. The maximum anticipated pressure will be approximately 3120 psi. This is based on an injection depth of approximately 5800 ft TVD, an injection pressure at the injection perforations of 18.5 ppg EMW, calculated with a 10.0 ppg slurry for the average injection case and an 8.5 ppg saltwater density for the maximum injection pressure case. Injection rate is assumed to be about five barrels per minute. Forest Oil will perfonn a step rate test to establish optimum injection rates and pressures. The step rate test will be incrementally increased to pump rates 100% in excess of the maximum anticipated injection rates for waste disposal. Pressure fall off data will be collected at the end of the step rate test. 14 ¡ :: I ) ) ,j ¡ "] Section 9 Fracture Propagate [20 AAC 25.252(c)(9)] Forest Oil estimates that the fracture pressure of the disposal zone is about 4350 psi. This is based upon a fracture gradient 'of approximately .75 psi/ft and an injection depth of about 5800 feet TVD. Fracture propagation within the disposal interval will be an integral part of the process of placing waste fluids into the disposal interval. Fractures will be created as the disposal zone begins to plug. Fractures provide pathways to transport waste fluids to undamaged storage volume within the disposal zone. Forest Oil requested BJ Services to conduct a fracture propagation modeling . study of the proposed injection zone. BJ concluded that induced fractures will be localized near the well bore and confined to the injection zone. This study is included as Attachment C. Forest Oil plans to use reservoir surveillance techniques including, but not 'limited to, step rate injection tests, disposal rate and pressure monitoring, and temperature logging, to track near wellbore fluid movement, estimate the dimensions of disposal fractures, and to detect changes in disposal zone characteristics. Evaluation of operation performance and reservoir surveillance will aid in preventing any fractures being propagated into and through the confining zone. I I I t .', , 15 ,",,'I ) ) Section 1 o· . Water quality [20 AAC 25.252(c)(IO)1 ¡ .J The total dissolved solids (TDS) content of formation waters in the recently completed RU #1 well generally ranges between 3,000 mg/l and 10,000 mg/l from about 1832 feet (where logging began) to about 2450 feet TVD. Below 2450 feet TVD, the TDS content increases to above 10,000 mg/l, but occasionally drops below 10,000 mg/l through some intervals. Forest Oil believes the lower salinity reading are due to lithology changes and clay content, and does not necessarily indicate freshwater. Mean salinity below 2450 feet TVD is about 50,000 mg/I. f . i :. The TDS content in the RU #1 well generally dovetails with the Redoubt Shöal State 29690 #1 well, where salinity exceeds 10,000 mg/l below 2400 feet TVD. The TDS profile in both wells is based upon petrophysical analysis of log data using an EP A approved method for determining salinity. The RU #1 well logs is included with this application; the Redoubt Shoal State 29690 # 1 well log is on file with the commission. Through the disposal zone, the RU #Dl well about 2000 to 3000 feet from the RU #1 well and within one mile of the Redoubt Shoal State 29690 #1 well. Accordingly, the salinity profile for the RU #DI well should correlate well with both the RU #1 and the Redoubt Shoal State 29690 # 1 wells. 16 .::] ) ) Section 11 Freshwater Exemption [20 AAC 25.252(c)(II)] "1 , j Water salinity in the disposal zone is generally over 10,000 mg/l, but occasionally drops below 10,000 mg/l through some intervals. In no case, however, does water salinity drop below 3,000 mg/!. Because 10,000 mg/1 is the upper threshold for freshwater as defined under state and federal regulations, Forest Oil respectfully requests that an aquifer exemption be granted under 40 CFR 147.102(b)(2)(i) and 20AAC 25.440(c) for the proposed injection intravel between 3,270 feet TVD and 5,810 feet TVD beneath Cook Inlet within an area one-quarter mile beyond and lying directly below the Redoubt Unit. ':'1 Forest Oil believes that an aquifer exemption may be granted under 40 CFR 147. 1 02 (b)(2) (i) and 20 AAC 25.440(a)(2) because of any freshwater that may be encountered in the RU #Dl well will have a TDS content greater than 3,000 mg/l, and that such water is not reasonably expected to supply a public water system because of the location, depth and abundant availability of drinking water elsewhere in the region. I 1 1 I 17 "¡ ) ) .( 1 ,I Section 12 Mechanical Condition of Adjacent Wells r20 AAC 25.252(c)(12)] î I Wells in close proximity to the RU #D 1 well are the RU # 1 and #2 wells and the Redoubt Shoal State 29690 # 1 and #2 wells. The RU # 1 and #2 wells were recently drilled and completed in accordance with state drilling standards under 20 AAC 25. The Redoubt Shoal State 29690 #1 well was drilled in 1967, side tracked as the #2 well in 1968, which was abandoned in 1993 according to AOGCC records. Drilling and abandonment of the Redoubt Shoal State 29690 # 1 and #2 wells were done under standards that are the same or equivalent to those in place today. , ! At the top of the disposal zone at 3706 feet TVD, the closest well to the RU #Dl well is the RU #1 well, which is over 2000 feet away at that depth. The offset between the two wells increases to about 3150 feet at the bottom of the injection zone at about 5810 feet TVD. (,.. ¡ f , ,~ 18 \ " ) " 1 .I Section 13 Disposal Injection Order Proposed Findings 1. Forest Oil is the operator of the Redoubt Unit~ There are no other operators within a· one-quarter mile radius of the proposed disposal injection well. 2. Forest Oil proposes to conduct disposal operations in the proposed RU #DI injection well in strata that correlates with the Upper Tyonek Fonnation between 3706 feet MD (3270 feet TVD) and 6879 feet MD (5810 feet TVD) in the Redoubt Unit R-I well. At the injection depth, there are no Qther wells within one-quarter mile radius of the RU #Dl well. ., , i \ 3. Forest Oil has identified 13 separate sand layers within the proposed injection interval that should be capable of accepting fluids for disposal. Forest Oil plans to limit injection to the deepest most sands (#11-#13), unless injection problems require the shallower sands to be used. 4. The proposed disposal zone in the RU #D I well is overlain by approximately 1800 feet of Beluga F onnation. 5. The Beluga Fonnation is dominated by impenneable lithologies, consisting primarily of interbedded siltstone, mudstone, and coal. 6. Cased hole logs and cement records must demonstrate that the RU #D 1 well is cemented adequately to isolate the proposed disposal interval before injection may be allowed in the RU #D 1 well. 7. The RU #Dl well will be completed with 36 inch conductor set at 200 feet TVD, 95/8 ,." . "inch suríàce casing set at 2"5 Ö-OTëéf TVU and cemented to süifacë, and 75/8 hid) production casing set at 7000 feet TVD and cemented back into the surface casing. 8. The RU #DI well will be equipped with 3~ inch tubing string and packer set at about 3320 feet TVD. Placement of the packer at 3320 feet is more than 200 feet above the top of the perforations that are initially planned to allow injection into sands #11-#13. 9. The waste stream will consist of produced water, drilling, completion and workover fluids, rig wash, drilling mud slurries, NORM scale, tank bottoms; and other Class II fluids generated from drilling, production, workover and completion operations. 10. Forest Oil estimates that the average injection volume will be about 600 bbI/day and the maximum volume about 1000 bbl/day. II. Forest Oil estimates the average injection pressure will be about 2,650 psi, with a maximum daily injection pressure of 3120 psi, at an injection rate of five barrels per minute. 19 ) ) i i 12. Fracture propagation within the disposal interval is an integral part of the process of placing waste fluids into the disposal interval. Fractures will be created as the disposal zone begins to plug. Fractures provide pathways to transport waste fluids to undamaged storage volume within the disposal zone. 13. Forest Oil will use reservoir surveillance techniques in~luding, but hot limited to, step .rate injection tests, disposal rate and pressure monitoring, and temperature logging, to track near wellbore fluid movement, estimate the dimensions of disposal fractures and detect changes in disposal zone characteristics. 14. Evaluation of operation perfonnance and reservoir surveillance will aid in preventing fracturing of the confining zones. 15. The portion of freshwater aquifers beneath Cook Inlet described by a one-quarter mile area beyond and lying directly below the Redoubt Unit at a depth greater than 3270 feet are exempt aquifers under 40 CFR 147. 1 02(b)(2)(i) and 20 AAC 25.440(c) by. order of the Commission. 20 "":,j '. ) ) ) ! ,"\ Disposal Injection Order Proposed Conclusions i ¡ j 1. The requirements of20 AAC 25.252(c) have been met. , :¡ I ,\ 2. Waste fluids authorized for disposal under this order will consist exclusively of Class II waste generated from drilling, completion, workover and production operations on the Osprey Platfonn. i I i , I 3. Penneable strata, which reasonably can be expected to contain the total volume of disposal fluids anticipated for this project, are present in the Upper Tyonek Fonnation. . " I 'I I 4. Waste fluids will be contained within appropriate receiving intervals by confining lithologies in the Beluga Fonnation, cement isolation of the wellbore and operating conditions. 5. Placement of the packer at 3320 feet is appropriate given the thickness and depth of the confining zone, and will allow for operational flexibility should injection be required in the shallower sands of the proposed injection zone. 6. Disposal injection operations in the RU #Dl well will be conducted at rates and pressures below those required to fracture the confining zone. 7. Periodic fracturing and stimulation will be required to place solids into the disposal interval. Fracture growth can be contained within the disposal interval by controlling the rate and volume of injection. ¡ -- ¡ 8. S1lrvei1iance of dlsposafmaterial movement, moniiorÌl1g ôròperatÌng paraffietërsand demonstration of mechanical integrity every four years will ensure the waste fluids are contained within the disposal interval. Changes in baseline data may be an indication that fluid is escaping beyond the designated confining zone. 9. The mechanical integrity of the tubing, packer and production casing in the RU #D 1 well must be demonstrated in accordance with 20 AAC 25.412 prior to commencing injection operations. 10. Disposal injection operations in the RU #D 1 well will not cause waste, jeopardize correlative rights, or impair ultimate recovery. 21 ,( l' l I ) , 'I ! j } Disposal Injection Order Proposed Rules Rule 1 Authorized Injection Strata for Disposal. , '1 I I \ Class II oil field fluids may be injected in conformance with Alaska Administrative Code Title 20, Chapter 25, for disposal into the Upper Tyonek Formation from 3270 feet TVD to 5810 feet TVD in the RU #DI well. Rule 2 Authorized Fluids This authorization is limited only to Class II fluids. The Commission must be notified immediately if any non-Class II fluids are injected into the well. Rule 3 Demonstration of Tubing/Casing Annulus Mechanical Integrity A schedu!e must be developed and coordinated with the Commission that ensures the tubing-casing annulus is pressure tested prior to initiating disposal and at least once every four years thereafter. The casing must be tested at a surface pressure of 1500 psi or 0.25 psi/ft multiplied by the true vertical depth of the casing shoe, whichever is greater, but may not be subjected to a hoop stress greater than 70% of the minimum yield strength of the casing. The test pressure must show stabilizing pressure and may not decline more than 10% within thirty minutes. The Commission must be notified at least twenty-four (24) hours in advance to enable a representative to witness pressure tests. Rule 4 Well Integrity Failure Whenever disposal rates and/or operating pressure observations or pressure tests indicate p'ressure communication or' ¡eäkage of anY èasirig, fubing or packer, llië oþeiätör" must notify the Commission on the first working day following the observation, obtain Commission approval of a plan for corrective action and obtain Commission approval to continue injection. Rule 5 Surveillance Operating parameters including disposal rate, disposal pressure, annulus pressures and volume of fluids and solids pumped must be monitored and reported according to requirements of20 AAC 25.432. An annual report evaluating the performance of the disposal operation must be submitted by July 1 of each year. Rule 6 Placement of the Packer The packer may be placed more than 200 feet above the top of the perforations, but in no case may the packer be placed higher than 3320 feet TVD in the RU #Dl well. 22 ,.[ l i ); ) , i I \ Rule 6 Adininistrative Action \ i Upon request, the Commission may administratively revise and reissue' this order or any of its rules upon proper showing that the change is based on sound engineering practices, will not allow waste fluids to escape ftom the disposal zone, and will not cause waste. . ¡ I ¡ . I ! 23 ') ) . :j , :J :t Section 14 Aquifer Exemption Order Proposed Finding's 1. Forest Oil seeks authorization to inject Class II waste fluids into permeable sands of the Upper Tyonek Formation, at depths below 3270 feet TVD in its proposed Redoubt Unit #Dl well. 2. . " I ¡ 3. 4. The RU #Dl well is proposed to be drilled from the Osprey Platform. The well's planned coordinate location are approximately 1915 feet from the south line, 322 feet from the east line of Section 14, TOm, RI4W, Seward Meridian. There no water wells in the vicinity of the RU #Dl well. Other oil and gas wells drilled from the Osprey Platform are the RU #1 and #2 wells. Currently, Forest Oil is drilling the RU #3 well. 5. The Redoubt Shoal State 29690 #1 and #2 wells are also located nearby. The wells were plugged and abandoned in 1968 and '1993, respectively. 6. The RU #1 well appears to provide excellent control for estimating stratigraphic conditions at the RU #Dl well location. 7. The RU #1 well encountered Upper Tyonek sediments from about 1800 feet TVD to about 8000 feet TVD. The Upper Tyonek is fluvial in nature with blanket-like sand layers that are continuous both horizontally and vertically. Interbedded with the sands are numerous claystones, siltstones and coals. I i 8. The proposed disposal zone in the RU #D 1 well is overlain by approximately 1800 -feetof BelugaF ormation. 9. The Beluga Formation is. dominated by impermeable lithologies, consisting primarily of interbedded siltstone, mudstone, and coal, which should act as confining layers preventing the upward migration of disposal fluids. 10. Forest Oil used a method endorsed by EPA in publication "Survey of Methods to Determine Total Dissolved Solids Concentration" (KEDA Project No. 30-956) for calculating TDS content from wireline log data. , i 11. Salinity data from the RU # 1 well shows that the IDS content of formation waters is generally greater than 10,000 mg/l below 2450 feet TVD, but occasionally is less than 10,000 mg/I through some'intervals. In no case, however, does salinity become less than 3,000 mg/l within the proposed RU #Dl disposal zone. 12. Development of the freshwater aquifers below the Redoubt Unit by entities other than Forest Oil is economically impractical because of the offshore location, water depths 24 :1 ) ) . ,. ·ì I I and currents, drilling costs and readily available alternative freshwater sources onshore. , ~ì I 'I [ 13. The Commission's authority to act in this matter is embodied in 40 CFR 147 Subpart C, the Alaska Oil ahd Gas Conservation Act (AS 31.05), and the Alaska Administrative Code (20 AAC 25.005 through 20 AAC 25.570). I \ ....- , - I ·1 'I . I 25 , j ¡ ) ) 1 I Aquifer Exemption Order Proposed Conclusions 1. The portion of the aqµifer proposed for disposal operations in the RU #D 1 well will likely have a IDS content greater 10,000 mg/l, although some interval may have' salinity more than 3,000 mg/l but less than 10,0000 mg/I. . ,'".i : ~::l , .../ :.':'.1 2. The lower salinity readings may be the result of lithology changes and clay content, and may not necessarily indicate freshwater. ':.:..:¡ ,:.::::1 }j 3. The portions of the aquifers underlying the Redoubt Unit do not now serve as a source of drinking water. :,,' I I .. ¡ I I 11. All aquifers below 3,270 feet that are underlying and within one-quarter miie radius of the Redoubt Unit are not likely to serve as underground sources of drinking water because of their location, depth and abundant availability of drinking water elsewhere in the region. It is reasonable, therefore, for purposes of underground injection, to exempt any freshwater aquifers with a salinity greater than 3000 mg/I that may be encountered in the area. 4. Those portions of aquifers underlying and within one-quarter mile of the Redoubt Unit that are common to and correlate with the interval below 3270 feet in the proposed RU #D 1 well qualify as exempt freshwater aquifers under 20 AAC 25.440(a)(2). , ¡ "[' n"-'C' rUt\.: C» ':r 200P, :S(,t~";,y~~ t~ t'. ~ , ~ I~ f...; <;.þ ~. 26 I. . l' : I , \ I I , 1 I . 1 I ¡ - . ! ! _.j . ! ~ ) "F 0 RE S T ) o IL CORPORATI.ON 310ØCg9'~ .',g9'~ 700 ~f¡eJ ~.9.9501 (.907) 258-86'00 · (.907) 258-8ôO~ (dØaa;) May 3, 200'1 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska· 99501 Re: Application for Permit to Drill (Form 10-401) Redoubt Unit #D 1 Enclosed is the Application for the Permit to, Drill the Redoubt Unit #D 1 class n disposal well from Forest Oil's Osprey Platfonn. This welI is pJarmed to be a vertical well drill into and completed in the mid Tyonek fonnation. The well will be drilled using water based mud in which the cuttings will be discharged overboard under our NPDES discharge permit #AKG285024. If there are any questions, please contact me at 258-8600. ~ c·,~ Paul White Drilling Manager Forest Oil Corporation - Alaska Division \,. "'. \.1i\1E:;:', .ìjJ\\l 2 3 20D4· ) STATE OF ALASKJ, ) -ALASKA Oil AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 SpecifICations Top Bottom Quantity of cement Grade Coupling length MD TVD MD TVD (include stage data) Welded 200' Surf Surf 200' 200' nla l-80 BTC 2,500' Surf Surf 2,500' 2,500' 2690 cu ft l-80 Hyd 521 7,000' Surf Surf 7,000' 7,000' 518 cu ft measured true vertical 20. Attachments: Filing fee: X Property Plat: X BOP Sketch: X Drilling fluid program: X Time vs. depth plot: X Refraction analysis: 21. I herby ce~ir!t the foregoing is true and correct to the best of my knowledge: . Signed: Y ~ "'^.,.../' Paul White Title:' Drilling Manager Commission Use Only Approval date Î 1 a. Type of work . Dnl': X Re-Entry: 2. Name of Operator Forest Oil Corporation 310 K Street, Suite 700 Anchorage, Alaska 99501 4. locatiòn of well at surface 1915' FSl, 32Z FEl, Section 14, T07N, R14W. SM At total depth 1915' FSl, 32Z FEl, Section 14. T07N, R14W, SM RednU: Deepen: 1b. Type of wen Service: x ') 3. Address ."¡ ! 12. Distance to nearest property line 13. Distance to nearest well 3365 feet 16. To be completed for deviated wells Kickoff depth: nla feet 18. Casing program size Casing 36" 9 5/8" , 7 5/8" 6800 feet Maximum hole angle: ' n/a Hole Driven Weight 12 1/4" 8 1/T 47# 29.7# 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet true vertical feet Effective depth: measured feet true vertical feet ¡ ,\ Casing Structural Conductor Surface Intermediate Production liner Perforation depth: Size length Pennit Number API number 50- ConáJtions of approval Samples required: (] Yes Hydrogen sulfide measures [ ] Yes (] No ì Required working pressure for BOPE [] 2M; ( X ] 3M; f~ ¡. other: Exploratory: DeveJopement Gas: , 5. Datum Elevation (DF or KB) 90' MSL 6. Property Designation 381203 '7. Unit or property Name Redoubt Unit 8. Well number Redoubt Unit #D1 9. Approximate spud date 1-Aug-01 14. Number of acres in· property Stratigraphic Test Single Zone: 10. Field and Pool Redoubt Shoal Oil Field Redoubt Shoal Development Oil: Multiple Zone: 11. Type Bond (see 20 MC25.025) Type: Statewide Oil and Gas Bond RlBOOO1940 Amount: $200,000 15. Proposed depth (MD and lVD) 23,526 7,000' MD 17,000 TVD 17. Anticipated pressure (see 20 MC 25.035 (e)(2» Maximum surface 817 pslgAttolaldepth(TVD) 3150 Setting Depth feet pslg Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth Diverter Sketch: Seabed report: Drilling program: X 20 MC 25.050 requirements: Date: ~ 0., See cover letter for other requirements ( ] No Mud log required: (] Yes [] No Directional survey required ( ] Yes () No ( ] 5M; [) 10M; [] 15M ApproVed by Form 10-401 Rev. 12-1-85 Commissioner by order of the Commission Date: SCANNEL! JUN 2 3 ZGGL} Submit in triplicate ) , 1 j' Attachments I. Outline Procedure 2. Well schematic 3. Unit Boundary Plat wI Proposed Well Path 4. Drilling Fluids Program 5. Pressure Information 6. Casing Design 7. Cement Calculations 8. Well Head Schematic 9. Nabors BOP schematic 10. Nabors BOP equipment list 11. Nabors Drilling Fluid System Description ) . \,'\ n\~1 Gp ~, 200~· 1") t.J' ù:! ~'" \1. .. ") ) Redoubt Unit #Dl OUTLINE PROCEDURE i : ,I 1. Rig-up Rig on Osprey Leg #3, Slot #3. 2. Install weld-Qn starting head on 36" Pile. 3~ Mix Spud Mud. 4. Nipple up 20" low pressure riser to bell.nipple with 21 ~"~M ,diverter: Diverter will have a 16" outlet. 5. Function test diverter system. Notify AOGCC 24 hours prior to test. 6. ' Use 3 ~" Drill pipe for this entire well, as long as surface torque ,does not ~xceed pipe . capabilities. 7. Drill 12 ~"hole to 2,500' MD. Note: Annular velocity and mud viscosity will be important for proper hole cleaning in the 36" pile. Discharge cuttings through platfonn pulltube. 8. Condition hole to run casing. 9. Run and cement 9 5/8" surface casing trom 2,500' MD to Surface. Hang 9 5/8" casing in the 20" landing ring. A stab-in cement job will be perfonned with 5" drill pipe. Discharge cement returns overboard. Note: If there are no returns at surface, perfonn top-job. AOGCC needs to be notified of any top-jobs so that they may witness. 10. Nipple down diverter, diverter spool and 24" riser. 11. Nipple up Vetco-Gray 13 5/8" 5M Multi-bowl wellhead assembly on the 9 5/8". 12. Nipple up 13 5/8" 5M high pressure riser assembly and Nabors 13 5/8" 5M BOPE. 13. Test wellhead and BOPE to 3,000 psi Notify AOGCC 24 hours prior to test. ,.14.RIH. Test casing to 3,000 psi. 15. Drill out cement and float equipment. 16. After drilling 20', but no more than 50' of new fonnation, perfonn Fonnation Integrity Test to 10'.5 ppg EMW. 17. Drill 8 ~"hole to 7,000 MD. Discharge cuttings through platfonn pull~be. 18. Condition hole for casing. 19. Run wireline logs: Quad Combo trom 7,000' MD to base of 36" Pile. 20. Run and cement 7 5/8" intermediate casing from 7,000' MD to Surface. Planned top of cement will be 2,000' MD. Hang casing with 7 5/8" mandrel hanger in wellhead. 21. Back off7 5/8" landingjoint. 22. Test 7 5/8" packoff. 23. RIH ~th 7 5/8" scraper assembly. Test casing to 3,000 psi. 24. Change hole over to 5% KCL. POOH 25. Run USIT log. . t !,;~ \ , : 1;\ \\~ ~¡, 3: ?GD4r ì ,,I ) i ) . , 'ì ',¡ 26. Perforate injection sands on wireliIie 27. RIH with 3 ~"tubing and packer 28. Nipple up injection tree. I " ¡ I , ! i ßf'ln b~ 1../' JUN 2, ¡:)?~ -j' ) ] "' RU #Dl Casing Design 36" Piles ! : 9 5/8" 47#, L-80 BTC ·7 5/8· 29#, L-80 Hyd 521 200' MD, 200' TVD 3 1/2" 9.3# tubing" TOC 2000' MD 2500' MD, 2500' TVD ¡OOO'.MD, 7000' TVD ), ) ì 35 36 31 32 .33 \ I . \ \ 2 1 . 6 5 4 1 I \ 1 1 12 7 8 9 Osprey .I?latfornl, 14 13 16 RU 23 19 20 21 u 2 . .. ... ....",...-"" ~ç 08N 13W 30 fOREST OIL ~ REDOUBT UNIT 13W RU 01 - r.- I-~I 31 - I I I 06N 13W 2· 1 6 <'.~'.@¡\~'".. 1;¡tl'¡J! til1 ~4-Dq ',' ", ':,. \! f.J..; ',/ U 1'\1 !.J 1iJ} t'iJ ~., ·1 -, I 1 .'·,o"¡ . 1 ¡ . ¡ :, ,) Redoubt Unit #Dl DRILLING:{fLum" PROGRAM ~C?\N:~EL ~.njN ~?, ~:) 2D2fj. ) ) Interval Summa'ry - W,BM Forest 'Oil COlporation, Inc. Redoubt Shoal Unit #»1 , ) '1 .ì ! ' 0-600 600-2500 8.6 - 9.0 9.0 - 9.4 35 -' 45 30-35 3 t05 <7% . N/C 12 - 14 150-250 100 -125 8-12 12 - 18 !fß~~,"""'~':'; ·"'·~""·~·i'·}f.:~,' -~~¡Iir;,,'r.' ;"r~f.,j~,!~.,,~.,......~ - >\':",","';:"kn ."'! ":::~ ~~f'~~';':¡:' e; ';:. ' ,,,,,.; ~ ':',....,., ,,' . , ,. "- "",.....- ,,: ~~~f'ì1.,~:";~Þ't"l."': ii'--'" ~ëJ'·,i" .~".... ".~,,'~I'~_" .,':' ":;'-·'L~~£Ø)ítØ1'ê~n·d·Et€t IS 'U,lq: F~~rn1a,,:qS" "'. ", ~"~( I:: ~',- .. '\Ii ~~::f~~;~~:\~;0~~~~~:~;i~:~~/~;<,~:L:.!tt~:~~::' .'~'.. ...... . ..M:......,,,.. __.,........_~. ",·:~,'0;;·c;~U·:;:~ Mixing Procedure · Fill rig pits with drill water (Insure oil residue is completely removed from pits before be- ginning) · Add 0.25 ppb Soda Ash to reduce hardness · Add 22 - 25 ppb M-I Gel and let shear and hydrate through gun Hnes. · Adjust pH to 9.0 with Caustic Soda as needed. At time of spud, adj~st rheology with Gelex ad- ditions as needed. Mixing Procedure · Add 45 barrels of spud mud to slugging pit. Mix blend of LCM products &. spot across theft zone. M-I LLC. 721 W. 1st Avenue Anchorage, Alaska 9950] Tel: (907) 274-5564 · Fax: (907) 279-6729 L::r' .'. iLl (¡Jo f'l, Ç)f\flF ~.A \o~\~\...-.:::ø. J V ~ Ñ ~, 1.1; ..,. V .",,~ =~\FE~~ } ) , í i Interval, Summary, Cant. Forest Oil Corporation, Inc. Redoubt Shoal Unit #D1 I i ! . . , . . .,." '. .. - o to 2,500' M.D. - 12 1'14" Hole - Set 9 5/8" Casing · ROP, GPM · Estimated ROP for this interval is 40 ftIhr. · Estimated flowrate of this interval is 600 GPM. · Use Virtual Hydraulics models as a guideline for flowrates and hole cleaning. · Bit ballibg · Drilling Detergent may be used 'to reduce the possibility of bit and/or BHA balling. · Hole cleaning · High viscosity GellGelex sweeps may be needed to ensure cleaning of gravel zon~s just below the 36'7 drive pipe. · - Lost Circulation · Seepage losses may be controlled with moderate additions ofM-I Seal Fine & Medium · Sev~re lost circulation should be handled with LCM pills such as the one listed for this inter- val. · Casing running fluid properties · The mud should be conditioned prior to POOH to run casing. Moderate or reduce yield point and progressive gel strengths in order to reduce surge pressure while running casing. A smaJI addition ofPo]ypac UL should help lower the fluid Joss (10 - 12 cc7s) and tighten the wall cake prior to running casing. . The IFE Mud Engineer will communicate dailywith ~e I~ Office IFE Coordinator. y , ,."., ~ =~;;IÆ~~ M-] L.LC. 721 W. 1st Avenue Anchorage, Alaska 99501 Tel: (907) 274-5564 · Fax: (907) 279-6729 " ) Interval Summary - WBM Forest Oil Corporation, IDe. Redoubt Shoal UDit #Dl '1 I ~"1I~~¥.'''*-~'''~~.'~~'~~.i-!'\.' '~";;<r! '. "-:!r;¡~"<.'Ii~'ifm;'''''r.'''''''')I.~t'''·~_r~··· (""t"'~''''i<'''~'~'..v:."·:,~.,.,>,...,,~..,.,,,.,~~..~'?t:'~'i';.j!R' ~:;r~1~'··,'?~~T~;:t~'è~f" : t( ~.~~Jr "'d;'!h~".~;{" .,._~,\.:":7'''''~''''v,~~,,,,-",,,,,~,:~,:,t.~~.~ ~~illi.~)~;;~~:i;d;.2i.L.,;;;¡___ ·~~l¿~~~fM¿L~.¿~.c,,j:;;;~:.; . . . . ~ : .., .' '. . I·,r -,'. '.. " . .' , 1..7, . I," " ,- ~ . ~ ,'" 1'10: '. . ''',,' '...i '" -'."'" .. _' .j' .1...·..'..-1·.. ~.... " It' " " .! . . I· M _ .' . Spot Soltex pill across suspected sloughing coal bed J Prior to pulling out of hole for' bit trip. '. . <--;. ,,'-',";';;:-. ,:~"":d~~': , " . .' . -, '. '" ' . ~~ :'~'~'~,~~~~~:,'~"' :,1·.;~I:·~i4~~~ Pump high viscosity sweep while reciprocating and J rotating drillstring. Do not stop pumping until pill has suñaced. M-I LLC. 721 W. 1st Avenue Anchorage, Alaska 99501 Tel: (907) 274-5564 · Fax: (907) 279-6729 ~:'IFEœm c..~ ¡,r"" 'h !! I",. I) ~~- \.-.... ',' ':' t'-,. 'I ¡II(¡ ~ ~, f"'¡ n ,,1' , '-~ ~'Y ,) ) Interval Summary, Cont. Forest O¡i Corporatiou, IDe. Redoubt Shoal Unit #int ì ! ,,( . I I I . ¡ . . . . . ... t. ". . ....... . .." '. . ..... ..... ......... t... 2,500 to 7,OOO~ M.D. - 8 112" H'ole - Set 7 5/8" Ca'sing' · ROP,GPM · Estimated ROP for this interval is 30 ftIhr. · Estimated flowrate for this interval is 650 GPM. · Use Virtual Hydraulics models as a guideline for flowrates and hole cleaning. · Bit Balling · Drilling Detergent may be used to reduce the possibility of bit <µIdlor BHA balling. · . Lost Circulation · Seepage losses may be controlled with moderate additions ofM-I Seal Fine & Medium · Severe lost circulation should be handled with LCM pills such as the one listed for this interval.. · Coal Beds~ · Sloughing/running coal should be treated by increasing the concentration of Soltex in the mud system to 2 - 4 ppb depending on the severity of the problem. · For severe coal sloughing, a concentrated pill consisting of 15 - 20 ppb Soltex may be spotted across the coal bed prior to POOH for a trip.. A slight amount of pressure (equal to the annular pressure loss) may be applied to the pill to squeeze i~ into the coal bed. · Casing running ßuid properties · The mud should be conditioned prior to POOH to run casing. Moderate or reduce yield point and progressive gel strengths in order to reduce surge pressure while nmning casing. Additions of Þölypac UL should help· tower the fluid loss (10 - 12cc'·s J arid "tighten the wall ëäke·pnóÌ'lö nmning casing. · The IFE Mud Engineer will communicate daily with the In Office IFE Coordinator. ~~,., Ülf'òJlli~nr.:w' Ii~ UN· ~1: 6.? 200& ".,~)~1/,;1 ,-,~"~r'tJ~~· ~~u (~Q)) u u . .... M-I L.LC. 721 W. 1st Avenue Anchorage, Alaska 9950] Tel: (907) 274-5564 · Fax: (907) 279-6729 . 17 . . . =- ~FE - ',1 I , ¡ ) ) ¡ :: ,j 1 ! REDOuBT UNIT #Dl 'PRESSURE INFORMATION :j ! The folIowing presents data used for calculation of anticipated suñace pressures (ASP) during drilling of the Redoubt Unit # 1. ' I i l Redoubt Shoal State 29~90-1, P=5309 psi @ 12,070' TVD nom DST #2 (as per 407 Comp Report, 1/9/68) EMW = 8.46 ppg Gradient = 0.440 psi/ft Redoubt Shoal State 29690-2, P:=5249 psi @ 12,202' TVD from DST #1 (as per 407 Comp Report, 10/15/68) EMW = 8.27 ppg Gradient = 0.430 psl/ft 'ì Redoubt Bay Unit #1, P=4800 psi @ 10,953' TVD from DST (as per monthly drilling report, 12/13/76) EMW = 8.43 ppg Gràdient == 0.438 psi/ft I ~ The most conservative (highest) fonnation pressure gradient of 8.65 ppg or .45 psi/ft was used in these calculations. Procedure for Calculatin2 Anticipated Surface Pressure o¡ i ASP is determined as the lesser of 1) surface pressure at breakdown of the fonnation at the casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point and a 1/3 gas gradient plus a 2/3 saltwater gradient to the surface. We have chosen this method based on no sign of gas in the Redoubt Unit # 1 well. 1) ASP = «PO x .052) - 0.10) x D \ . ~ i where: ASP = Anticipated Surface Pressure in psi FG = Fracture Gradient at the casing seat in lb/gal 0.052 = Conversion from lb/gal to psi/ft 0.10 = gas gradient in psi/ft ' o = true vertical Depth of casing seat in ft RKB OR 2) ASP= FPP-( 1/3 x 0.10 x D) - (2/3 x .45 x D) .:.... ~l , y JUt{ 2' 3lGDl: where: FPP = Formation Pore Pressure at the next casing point which is tied back to surface or at TD (total depth) ~·,Gl~\~~~NEL. ~JUN 2 ~ 200~. i ') , \ ASP = (7000'.x .45) - ( 1/3 x .10 x 7000') - (2/3 x .45 x 7000) = 817 psi OR ASP = «FO x .052)- 0.10) x D = «10.5 x .052) - 0.1 0) x 7000' = 3122 psi Drilling below Suñace Casing (9 5/8") I ASP Calculations } ) , ) ) REDOUBT UNIT #Dl CASING DESIGN ! i í , ,I Settin~ Depth Size Specifications Top Bottom Hole Casing Weight Grade Coupling length MD TVD MD TVD Driven 36" Welded 200' Surf. Surf. 200' 200- 12 114" 9 5/8" 47# l-SO BTC 2,500' Surf. Surf. 2,500' 2,500' S%" 7 5/S" 29.7# l-SO Hydñl 521 7,000' Surf. Surf. 7,000' 7,000' Casing Joint StreD~th Klbs 1122 566. Body StreD~th Klbs 1086 683 . Burst Psi 6870 6890 Collapse Psi 4760 4790 9 5/8" 47# l-SO BTC 75/8" 29.7# l-SO Hydñl521 . ~ . ~ Desi~n Criteria Tension Burst Collapse Straight Hook Load - Ignoring Deviation and Buoyancy Full Column of Gas against deepest fonnation pressure Full evacuation on the inside backed by expected formation gradient of .45 psi/ft. on the outside. 9 5/8" Surface Casin2 ! ,! Collapse = 2500' x 47# = 117.5 K :;; (7000' x .45)- (.10 x 7000') = 2450 psi ' = (2500' x .45) - (.10 x 2500') = 875 psi Rated = 1086 K Safety Factor = 9.2 Rated = 6870 psi Safety Factor = 2.8 Rated = 4760 psi Safety Factor = 5.4 Tension '. -- Burst .... ¡ ] 7 5/8" Intermediatè Casin~ Burst = 7000' x 29.7# = 207.9 K = (7000' x .45) - (.10 x 7000') , = 2450 psi = (7000' x .45) - (.10 x 7000') = 2450 psi Rated = 566 K Safety Factor = 2.7 Rated = 6890 psi Safety Factor = 2.8 Rated = 4790 psi Safety Factor = 2.0 I I I Tension . Collapse ~f"lì.\;\H'\~íC\:-, HJN2, 3 2[¡D~: ~~~ \\._.1 /f'A~ ~ A ~ \:j l\.....~. '" ~ ] ¡ ,j ì ' j ! I , I ! ) ) 'REDOUBT UNIT #Dl CEMENTING PROGRAM , . ',',,;\; i\j iF~' ~-' Ii i: i r,1 G:b 6\ 20 ().'l . ..' ,.- r," t. ~ ,) ð:.~ ~ IJ~ Gr4109 Sf' :'~\ j\Î ì\¡ F~ ~ -, J U N .r~ ') 2 0 0 ,PI . ~,,",.~ .~:' ", '~;;;JQ.....I ".;,. '. j 4 ~ ....:!- 43bbls - 9.4 ppg 350 sacks 15.8 ppg 1.16 cf/sack 1,087 sacks 12.5 ppg 2.10 cflsack 30 bbls 8.4 ppg Page 1 9 S/8in, 47 Ibslft - Drill Pipe 5" 0.0. (4.276~ .1.0)19.5 ## 14,731 gals 2,500 It 2,500 It 12.25 in Proposal No: 17011001378 !£j ) Report Printed en M;rçto 15. 20011205 PM Displacement DtillingMud Density Tail Slurry Class G Cement Density Y".eld Pre-flush . Fresh Water Density Lead Slurry Class G Cement Density Yield Total Mix Wat~r Required Pump Via Casing Size/Weight : .'Hole Size . . Depth (lVD) ..Depth (MD) \ I JOB AT A GLANCE ¡ , i operator Name: Forest Oil Cl~ation Well Name: REDOUBT UNIT #01 Job Description: 9-5/8" SURFACE CASING Date: March 15, 2001 :-;,:: { Operator Name: Forest Oil ( þration Well Name: REDOUBT UNIT #D1 Job Description: 9-5/8" SURFACE CASING Date: March 15, 2001 ) r!~ ~","j,'~,'" , I.:d 1 ¡ I , J Proposal No: 1701100137B WELL DATA ANNULAR GEOMETRY J .",= I 9i~;~'.. ~·;i;~{:::\';,:t£M}i~1:it~;7~JSy:;~;,~?}}::}:;~~{;~~~~g:~I~~¡~~{I~ 34.750 CASING 12.250 HOLE 200 2,500 200 2,500 SUSPENDED PIPES ...' ,}.'.:/;::' ~:',,'" ')',,'D":,'A' -i.iðTER" "':'(~' ,.)-:....:-: ,:~;,~',,:. ;, " ,"' ',,' , ,'" _"..~, ' In ,', ,',,_ ,.." ',' ", " ?~S-:.~-·".' . O~O~!:'~"~~','.;~.~/·: tõ ':':.: -':·'·':"r~[)~':I:~"/,:'..>. 9.625 I 8.681 . ,\.~~.,::·;:~~~i~~~~'t~~Äir I 47 I 2,500 I 2,500 Float Collar set @ Mud Density Est. Static Temp. Est. Circ. Temp. 2,420 n 9.40 ppg 82 OF 750 F ¡ : ¡ VOLUME CALCULATIONS 20011 x 6.0810 cflft 1,704 ft x 0.3132 cflft 596 11 x 0.3132 cflft 8011 x 0.4110 cflft with 0 % excess = with 100 % 'excess = with 100 % excess = with 0 % excess = TOTAL SLURRY VOLUME = 1216.2 cf 1067.1 cf 373.6 cf 32.9 cf (inside pipe) 2689.7 cf 479 bbls = Report Pñnled en: March 15, 200112:05 PM Page 2 Gr4115 v' sr',f\ J\,~:',P"":-:'''''' . ",' u, ~, ~ "H'H"1I~' Î Operator Name: . Forest Oil ClJ.ation Well Name: REDOUBT UNIT #01 . Job Description: 7-5/8" INJECTION STRING Date: March 15, 2001 ) Lm PropOsal No: 1701100137B JOB AT A GLANCE Depth (TVD) 7,000 ft I Depth (MD) 7,000 ft Hole Size 8.5 in Casing SizeJWèight : 7 5/8 in, 29.7 Ibs/ft .Pump Via, Casing 7 5/8" 0.0. (6.875" .1.0) 29.7 # Total Mix Water Required 2,858 gals Pre-flush Fresh Water wi MCS-AG 30 bbls Density 8.4 ppg Lead Slurry Class G Cement 214 sacks Density 12.5 ppg Yield 2.09 cf/sack Tail Slurry Class G Cement 62 sacks Density 15.8 ppg Yield 1.15 cf/sack Displacement DñllingMud 318bbls . Density 9.4 ppg §CP~~i~.UiFr, J, ~)~:\: <>];I, ~) 2', OP,L1 "'ðJ J ~__" \';. ~l, U ~j ~1 (.J vl..r Report Pñr1Ied 00: March 15, 20011205 PM Page 5 Gr4109 Operator Name: Forest Oil Co )alion Well Name: REDOUBT U~I r #01 Job Description: 9-5/8" SURFACE CASING Date: March 15, 2o.(}1 "'1 , :¡ J FLUID SPECIFICATIONS Pre-flush FLUID VOLUME VOLUME CU-FT 'FACTOR Lead Slurry 2283 / 2.1 Tail Slurry 406/ 1.16 Displacement CEMENT PROPERTIES Slurry Weight (ppg) Slurry Yield (cf/sack) Amount of Mix Water (gps) Amount of Mix Fluid (gps) ./ Report Printed en: March 15. 2001 1205 PM ) .E£j. Pr9Posa1No:17o.11o.o.137B 30..0. bbls Fresh Water @ 8.4 ppg AMOIJNT ANn lYPF OF CFMFNT = 10.87 sacks Class G Cement + 0..5% bwoc Calcium Chloride + .0..4% bwoc CD-32 + 1 gal5/100 sack FP-6~ + 2% bwoc Sodium Metasilicate + 106% Fresh Water = 350 sacks Class G Cement + 1.5% bwoc Calcium Chloride + 0..3% bwoc CD-32 + 1 gal5/1 aD sack FP-6l +. 44.1 % Fresh Water 43.0. bbls Drilling Mud @ 9.4 ppg SLURRY SLURRY 'NO.1 NO.2 12.50. 15.80 2.10 1.16 11.95 4.97 11.96 4.98 C 1("- ,\ I' ~ r. i E (, , II r,¡ 1;):' ~ 2 On I' ~)' Wh,! ~ I~ _ . t_ "¡', \: (" ,) _ v'" Page 3 Gr4129 , ::~I I Operator Name: . Forest Oil Cc )ation Well Name: . REDOUBT Ur...f #D1 Job Description: 7-5/8R INJECTION STRING Date: March 15; 2001 ) W] ,¡ .J .\ I Proposal No: 17011001378 WELL DATA ANNULAR GEOMETRY ;;t~<{)1:;:§;~'~?j.~¡r;~5et~:;,:,t;~&~;~~\:t~;i:;~~~~;:~,~=b~~~~¡i§K; I' I 8.681 CASING 8.500 HOLE 2,500 7,000 2,500 7,000 ." .! SUSPENDED PIPES . . '0 7 ::;;¡;¡';/;:-'\::.~~·,(i~} '.i:·t>.:?:··~· ~.. ,;~~!'t~ f!:<:{ it' .',., '. ;~::J .~~~~;-1: Yf~::;:;,:';::;; ,c, ....-, . ',-.' . -OK.<.,f-,-'·.· "'..- ··",·:....·,;r.D~ '~.. ".,r...(ttiSJft\" ··,~·,·MEASURED'·'··I ,,'·TRUE-VERTlCAL.- ".' ;-,,:..,' ,~LI..." ;....:_L,..I.: I.... ..... ". ... I I' '.'~'" . . _. . ...-:- '::'. .~ . '.' ,., 7.625 I 6.875 I 29.7 I 7,000 I 7,000 Float Collar set @ Mud Density Mud Type Est. Static Temp. Est. Circ. Temp. 6,920 It 9.40 ppg Water Based 123 0 F 101 0 F VOLUME CALCULATIONS 500 It x 0.0939 cflft 4,000 It x 0.0770 cflft 500 ft x 0.0770 cflft 80 11 x 0.2578 cflft with 0 % excess = with 30 % excess = with 30 % excess = with 0 % excess = TOTAL SLURRY VOLUME = 47.0 cf 400.2 cf 50.0 cf 20.6 cf (inside pipe) 517.8 cf 92· bbls . ¡ I ' = Report PrinlO!d 00: Man:h 15" 20011205 PM Page 6 Gr4115 '.: ~ Ii~.¡\ ur) ~¡ ?ßD1~ J ~j ~ 1-J (c1 ç., ~ ',', ¡'. '....,J ¡~ F ~' ~ \ I il,~ b~ ~ 6)OOF, . ,.,.., ,to! ':: l' ~. c.. "'1i Gr4129 Page 7 SLURRY SLURRY NO.1 NO.2 12.50 15.80 2.09 1.15 11.92 4.94 11.93 4.95 = 214 sacks Class G Cement + 0.4% bwoc CD-32 + 1 gal5l1oo sack FP-6L + 2% bwoc Sodium Metasilicate + 105.8% Fresh Water = 62 sacks Class G Cement + 0.3% bwoc CD-32 + 0.4% bwoc FL-33 ... 1 gafs/100 sack FP-6L + 43.9% Fresh Water 317.7 bbls Drilling Mud @ 9.4 ppg AMnllNT ANn TYPi= nF CFMFNT 71 I 1.15 447 I 2.09 Report f'rir¡(ed at: Mard115, 2001 12:06 PM °1 Slurry Weight (ppg) Slurry Yield (cf/sack) Amount of Mix Water (gps) Amount of Mix Fluid (gps) Displacement CEMENT PROPERTIES Tail Slurry Lead Slurry VOLUME VOLUME CU-FT ,FACTOR FLUID ,PróposaiNo:1701100137B f£j ) ~flush 'ì ,FLUID SPECIFICATIONS , - :1 , Operator Name: Forest Oil Co '~tion ,I Well Name: REDOUBT UJ\,. ¡' #01 I Job Description: 7-5/8" INJECTION STRING Date: March 15, 2001 ", ! ,I Operator Name: Forest Oil Co. " )ation Well Name: REDOUBT UNIT #D1 Date: March 15, 2001 ) E£j ':'1 Proposal 'No: 17011 001378 PRODUCT DESCRIPTIONS CD...32 A patented, he-flowing, water soluble polymer that is an efficient and effective dispersant for primary and remedial ceme.nting. . Calcium Chloñde A powdered, flaked or pelletized material used to decrease thickening time and increase the rate of strength development. Class G Cement . Intended for use as a basic cement from suñace to 8000 It as manufactured, or can be used with accelerators and retarders to cover a wide range of wßII depths and temperatures. '., FL-33 A patented cement fluid loss additive that provides exceptional ftuid loss control across a wide range of temperatures, salinity conditions, and remedial cementing applications at low to high temperature ranges. . FP-6L A clear liquid that decreases foaminQ in slurries durinQ mixinQ. MCS-AG . A surfactant used in cement spacer systems to prevent mud incompatability and improve bondinQ. Sodium Metasilicate An extender used to produce an economical. low density cement slurry. ¡ I ! Report ~ en: March 15, 20011206 PM Page 10 Gr4163 1,'::[' .JUN 2~ ~ 2004 " 1·,' '\Jj OJ! 2ft fì ~ .' ;I ;.1!~ t!J rji UU<.f, I OOAWING NO. I· , SP-4482-1A . f'OREST œ: OSPÆY ~CT NO.: ~AJ£: 2G UAR 2001 ~ ~AJ£: I»-A IscAæ NA 36 X 9-5/8 X 7 X 3-1/2 aD 5.~O MSP MUll1BOWL ASSY DISPOSAL "WEll ~ ENGDŒERING ADB VETCO GRAY ~ -- .~~." ~ "- 38- 00 CASJH(; ~ "- 9-s¡r œ CASING -¡a OD CASIMG 3-1¡r co 1tØNG 19.!50'" . ; ~ ì rl .- - - '"t.a J50 ~. 13-5/8 5000 6BX I I ~II " '; f ~~ :=s~y~ ~::i \2-1~.~,," J::r=l- iÞ:i .~ J ,--' =.) ...d I ( )00'= 13-5/8 5000 6BX ~ ( ~Ð-¿þ I, I ''IC :oJ -:-- ! 2-1L!L.5000 W/VR .ø- - 'I f .., .. .~i ." . ~ Ør--:J .-f ....:E'-. .' _ .~_ ..,'~ _ .,. ~. '-l." . .. ... . _ ' :.J "'-...... ~ ~ ..~L. 24.75 2800 80.&8"' ~ ,- 24.31- - ) ) bAA. BY: C. RICE ÞÇ, APPR.: ABB VØIco Øra)' ji I... ,.,.... ,..-- IU .DIMENSIONS ÞÆ. APPROx.. , ; ¡ I . ¡ ¡ ), ) ì I ¡ 1 NabQfs'Rig 429 13;.5/8" 5000 psi BOP Stack· Redoubt Unit #D 1 , " 5000 psi Annular ~ / 5000 psi Blind Rams 5000 psi Pipe Rams 3" Kill Line =:Þ<I:><L Mud Cross ~ 3" Choke Line I 2 2 1 ·l=··HC-R- Valve 2 = Gate Valve 5000 psi Pipe "Rams . ¡ 13 318" 5M ~ Wellhead =r><J 9-5/8" Surface Casing 7-5/8" Intennediate <":.i':·:;,H\"H=~ n bl¡l.jl (:,) ~ 20f!t~ . \.',\J~\.J.,:"' t.;,~t:l~~ &~ r.w U-v ) ') Î .1 I ¡ BLOWOUT PREVENTION EQUIPMENT NABORS RIG No .'429 21 Y;"Diverter EQui,pment 1 ea Hydril MSP 21 1;4" x 2000 psi WP annular blowout preventer 1 ea 21 1;4" 2000 psi WP diverter spool with 16" ANSI 300 outlet flange 1 ea Fabri-VaIve Style 36 16" ANSI flanged full port valve with 3000 psi hydraulic operator 1 ea 100' of 16" Sch 40 diverter line " 13-5/8" BOP Equipment 3 ea 13-5/8" x 5000 psi wp ram type preventers (Hydril) 1 ea 13-5/8" x 5000 psi wp annular preventer (Hydril) 1 ea 13-5/8" x 5000 psi wp drilling spool with 2 ea 4" side outlets (choke and kill), HCR and manual valves on both choke and kill lines. I . I ì 1 ea BOP accumulator, Koorney Model 1'20000-3S blowout preventer control unit with 280 gallon volume tank, main energy provided by two 20 HP electric motor driven triplex plunger pump charging 16 each II-gallon bladder type separate accumulator bottles. Secorid energy charging system consists of two air pumps. Above two energy systems backed up by six each 220 cubic feet.nitrogen bottles connected to the manifold system. All above system controlled by a Model SU2KB7S S series manifold with six manual control stations at the unit. DRILLING FLUID SYSTEM DESCRIPTION Mud Pumps i _ i , 2 ea IDECO TI600 (triplex, single acting pistons), 5000 psi fluid end discharge manifold system. Gear end equipped with electric driven lube oil pump, filtration. Pumps are driven by two each traction motors designed to stroke pumps at a maximwn -of 120 SPM under full load. Pwnps are charged by two 40 HP, 1200 RPM Mission 5" x 6" centrifugal pumps. ':';i.J..~Ü\JNE[ JUN 2 3 200{. , ) I .:1 ) I' j Mud TankSvstem (975 bbls Total Volume) Tank #1 (de sander tank) appx. 170 bbls.. Tank #2 (mud cleaner tank) appx. 145 bbls. Tank #3 (centrifuge tank) appx. 145 bbls. Tank #4 (~uction tank) appx. 44 bbls. Tank #5 (pill tank) appx. 44 bbls. Tank #6 (volwne tank) appx. 430 bbls. Trip Tank appx. 40 bbls. Located in the substructure. Mud System Equipment ) 3 ea Derrick dual tandem shale shakers 1 ea Derrick 20 cone desilter 1 ea Geosource sidewinder mud hopper 3 ea Brandt 15 HP mud agitators 2 ea Brandt 5 HP mud agitators 3 ea Mission Magnum pwnps, 6" x 8" centrifugal with 100 HP motors 1 ea Mission Magnum pwnp, 4" x 5" centrifugal with 25 HP motor 1 ea DEMCO desander, two 12" cones 1 ea Brandt Model CF - 2 centrifuge ! -I " ~,' iAiç "-, n í \\1 t!::¡' ~ 6} 0 0>"1 ,: ~,,'i\\ 1 ~j ;',?U ,J '>oj d t.¡ ~ t:.. ,...r '" .~~ ) ·1 I i I 'I , \ .i Redoubt,Unit'#Dl . SummarY of Drillin2 Hazards POST TIDS NOTICE IN THE DOGHOUSE' ..J No abnormal pressures are expected. '" No shallow gas expected. "" Coals will be encounter~d throughout the Tyonek formation. Tripping speed and mud weight wiU help alleviate stuck pipe tendencies. "" Lost-circulation is unlikely, however lost circulation potential increases when crossing faults. " H2S has never been encountered in the Redoubt Unit Field. CONSULT THE WELL PLAN FOR ADDITIONAL INFORMATION \ \. Schlumberger Cement Advisor [ I I [ [ I [ [ l [ Company Field Well Date Logged Date Processed API Number Log Analyst FOREST OIL CORPORATION Redoubt Shoal Oil Field REDOUBT UNIT D1 19-JUN-2001 24-JUL-2001 50-733-20501-00 Jesse Cryer Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 (907) 273-1700 All interpretations are opinions based on inferences from electrical or other measurements and we cannot, and do not guarantee the accuracy or correctness of any interpretations and we shall not, except in the case of gross or willful negligence on our part, be liable or responsible for any loss, cost, damages or expenses incurred or sustained by anyone resulting from any interpretation made by any of our officers, agents or employees, These interpretations are also subject to clause 4 of our general terms and conditions as set out in our current price schedule, ~CANNEDI JUN 2 3 2DDi~ (' ( Forest Oil Corporation Redoubt Unit D1 Redoubt Shoal Oil Field 1. Cement Advisor Objectives The objective of this logging suite was to determine the quality of the cement job on Forest Oil Corp's well Redoubt Unit 01. A Cement Bond Tool (CBT) was logged in Redoubt Unit 01 from 2500 ft to 8472 ft and 1110 ft to 1296 ft inside 7,625 in 29.7 Ib/ft casing. A repeat pass was also recorded from 8250 ft to 8480 ft. 2. Cement Advisor Interpretation This CBT interpretation is based on the Variable Density display (VOL) and ~iscriminated (OATN) and Near Pseudo Attenuation (NATN) data. The VOL display and attenuation curves indicate good cement from total depth (TO) to 5635 ft. The VOL presentation clearly shows strong formation signal and weak to nonexistent " casing signal. Casing collars are not evident in the VOL display confirming the interpretation of good cement. From 5635 ft to 2700 ft, the attenuation curves migrate to less attenuation indicating progressively poorer cement bond with decrease depth. Casing collar arrivals are faintly evident in the VOL display confirming the decrease in bond quality at this point. Above 2700 ft, the CBT tool indicates free pipe with the attenuation curves reading zero and strong casing signal on the VOL. This free pipe signal matches that recorded around 1200 ft. ,5CPùNNEtD ~Y¡UN 2 3 200t' #7 ~{('^N~'Er.' n ~:;q G~ I.) ?on:1 ~~,!'VIJ·':~n \~ ~ { '_.ð\,,'.I'¡ ,..J~.:l ~'\-¿ I:~ Q)J L... ^". t¡".;t) -=t9'~~-' 2.-36 7 '7.~ -1;<., 2._~ 79:3-/6z <I ~<; ~ - \~~O 7/~9- /dl'1 ?6~~/9/ IN0':'D"/ MA~A.Ñ ) <;. ,," ú.l; l U (/, .H 1J~, Oaf' 5 ~ <J!-.e- u-e.-, "-:-bû v/è_ < >Acx; c: c~_ ~~ ~rL~~~r ~C)c.,,-,- M é4~Y ./Îa~G-~ 4eT d.4¿//f//A.£># H;,e&ST~/¿:. (PLEASE PRINT) TELEPHONE NAME - AFFILIATION MEETING-Subject iZ0 J)\Ct AED) ~~'\)0J.:AP-- Dófb2>AL- ALASKA OIL AND GAS CONSERV A TION COMMISSION Date: 7,p, :;-/~ I Time ?.- ~ ?-. S- ) ~, il) ) #6 ) ) ~ FOREST OIL CORPORATION :Jl(} dY-('oYÎn>el . DYt~(I(! 7()(} ()Ç>¡;U'hoJr(frv~e, Opfla,¡ka ,9.95 () 1 (9()7) 2/¡S-S6'()() · (9()7) 2.-;S-S6'()J (d.~;',I) June 20,2001 Alaska Oil and Gas ConselVation Commission 333 West 7ili Avenue, Suite 100 Anchorage, AK 99501 RECE'VED Attention: Wendy Mahan JUN 22 Z001 Re: Redoubt Unit #D 1 well Alaska Oi\ & Gas con~. Commission Anchorage Dear Ms. Mahan: In response to your letter addressing questions posed by EPA Region 10 regarding Forest Oil Corporation's planned Class 2 disposal well, I submit the following: 1. The purpose of our proposed Redoubt Unit #D 1 disposal well is primarily as a backup to our ongoing muds and cuttings annular disposal program. During early stages of production and before the commencement of waterflood (reselVoir pressure maintenance) operations, the well will be used to dispose of produced water. We expect this to be a year or less and with the expected low water cuts, the volumes of produced water handled should be low. A better estimate of the volume will be available when production is begun. We expect to utilize tills well throughout the lifespan of our development drilling program for cuttings and class 2 exempt fluids. 2. The reason Forest Oil has selected eleven sand packages for disposal is primarily for backup and redundancy. When injecting cuttings from Cook Inlet wells there is always a large amount of coal. Coal has a tendency to plug off disposal wells and could necessitate moving up and perforating an additional zone. To move the drilling rig back to tills well to do remedial work would be time consuming and expensive. We designed the well so that higher sands could be perforated below the packer without pulling the completion. We may never need to do this. The initial perforations will be into sands #9, # 1 0 and # 11. We would only perforate higher sands if the lower perforations fail to accept cuttings or exempt waste. 3. There is more than sufficient confinement to prevent contamination of the fresher water zones. Supporting documentation for this can be found in Section 4 of the Application for Injection Order. BJ Services provided Forest Oil Corporation with a fracture simulation for the RU Dl well, The fracture simulation includes a total volume of 1,000,000 gallons if a 10.5 ppg fluid system transporting 5 ppg 100 mesh sand at a pump rate of 5 bpm. The simulator output data shows the injected fluids to be fully contained within the sand packages designated as potential injection sands, The fracture model is attached to the application. (Due to the plentiful nature of fresh water in the area, the offshore location and depth would not, reasonably, ever be considered as a source of drinking water.) 4. A petrophysical analysis was perfonned on the logs from the Forest Oil,RU #1. The salinities are all well above 3,000 ppm and as such are exemptable. . c, ',""" r) rì \ì ," SCf\N\\!E\~ ,(\.\\\"1 ',' " ", ) ) Redoubt Unit #Dl June 22, 2001 5. Forest Oil Corporation has designed tills disposal well to accommodate our grind and inject operations as well as production operations. Placing the packer at the shallower depth will allow additional perforations to be added at a later time at minimal expense. Moving the drilling rig back over tills well at a later date and then retunúng to the leg it was working on will cost an estimated 1.8 :MM$. In addition to this cost the workover cost to the well to move the packer will cost an estimated 750 k$. Setting the packer as outlined in our proposal will eliminate this cost and provide the option to inject in an alternate sand simply by perforating with wireline. This provides for a backup plan in the event of a problem with the lower sands. Setting the packer at the depth we have proposed and perforating sand packages #9,10 and 11 will isolate the lowermost, more saline zones for initial injection. The approval of the acquifer exemption for which we have applied will make the sands above also available with out having to move the rig over the well and do remedial work. I hope this has answered the questions sufficiently. If you have any more questions please let me know, ~ Paul White Drilling Manager Forest Oil Corporation SCANNEC ~fUN 2 j 200~· #5 iditional questions for ABO - RU #Dl well ) ) Subject: Additional questions for AEO - RU #Dl well Date: Thu, 14 Jun 2001 08 :07: 17 -0800 From: Wendy Mahan <Wendy _ Mahan@admin.state.ak.us> Organization: doa-aogcc To: Paul White <pdwhite@forestoi1.com>, Rob Stinson <RDStinson@forestoi1.com> CC: Robert P Crandall <bob_crandall@admin.state.ak.us> Mr. White: EP A Region 10 has aasked for a more detailed discussion of your planned operations at Redoubt Unit in order to justify the Aquifer Exemption request. I suggest you submit a letter to the AOGCC with detailed explanations responsive to the questions below. Please keep in mind that the audience may not necessaily be familiar with oilfied operations. 1) Explain the purpose of the disposal well (muds/cuttings disposal and/or produced water?) and estimated lifespan? 2) Why would Forest need 11 disposal intervals? What is the expected performance/capacity of each identified sand interval? 3) Is there sufficient confinement to prevent contamination of underground sources of drinking water? How much and at what depths? 4) What are the TDS concentrations in each potential disposal zone? 5) Please explain why Forest needs to place the packer at such shallow depth. Could Forest place in the well either two packers or some other device to isolate the lowermost, more saline zones for initial injection? If not, why not? Please explain cost/operational restrictions or other problems. Please feel free to call me or Bob Crandall if you have any questions. Thanks, Wendy Mahan Natural Resource Manager ·Sc;AANED JUN 2 3 2DD4 t _.£' 1 7/25/019:34 AM #4 ) ,) ~ FOREST OIL CORPORATION .5 j () D/( (-V;)(()(~I . DYt~r/e 7 ()() D(/Y;lchora//e, (ìÇý"/rr.Jka ,9,9:;()/ (9()7) 2/¡S-S6'()(} · (.907) ,;:J,;¡S-S6'()j (0~j/;'.1) June 5, 2001 Tom Maunder Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 Re: Questions regarding Redoubt Unit Aquifer Exemption and Disposal Injection Order Applications Dear Mr. Maunder: The depth discrepancies on the type log previously submitted have been corrected. The reason for the confusion was due to the sand packages being labeled in Measured Depth from the Redoubt Unit #1 well, as opposed to the MD I TVD for the RU #Dl well. Also, note that we have eliminated the uppermost sands which were in salinities of less than 10,000 ppm. The packer will now be set at 3,500'. This should eliminate the need for an Aquifer Exemption. This Class II disposal well will be treated as a back-up to our ongoing annular disposal program. Sands #9 (5,115'-5,166'), #10 (5,366'-5,595'), and #11 (5,701'-5,812') will be the only sands initially perforated. The upper zones are intended as double back-up providing for injection in the event annular injection failed and the lower disposal sands in this well failed. If you have any questions, please contact me at 258-8600. Paul D.White Drilling Manager - Alaska Division Forest Oil Corporation Attachment: Revised Pseudo-log wi TVD notations RECEIVED JUN 0 5 2001 8ÇPJ~~H\jFL' /iI' ~~j 6)) ~;i\ 20n'" ~, , (1...... ' 1:;;: \\.~ ~ ~ I.. çJl ". .i', Alaska Oil & Gas Coos. Commission Anchorage #3 1', , ) / ~:~~ì ~ F ~~~~~~:Æ TONY KNOWLES, GOVERNOR ~ AlASKA. OIL AND GAS CONSERVATION COMMISSION 333 W. "'{TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 June 1,2001 Paul White Drilling Manager Forest Oil Corporation 310 K Street, Suite 700 ~chorage,AJ( 99501 Re: Questions regarding Redoubt Unit Aquifer Exemption and Disposal Injection Order Applications Dear Mr. White: The Commission is currently reviewing the applications for Aquifer Exemption and Disposal Injection Orders submitted May 8, 2001. After consultation with EPA Region 10 and internal review, we have a few questions and comments. The injection intervals identified on the type log submitted did not correspond to the sands. Please resubmit the type log with the sand and proposed injection intervals more closely aligned, tabulating the net feet of sand per interval. Please also submit a SP log. You have requested thirteen sand intervals for consideration and propose to set a packer above the uppermost sand. It appears that the lowermost three sands are quite extensive and injection into these three sand intervals would not require an aquifer exemption order. Please explain why you think you may need to inject into all thirteen sands intervals. If you plan to utilize the lowermost three sands initially, have you considered either installing the packer deeper or providing some other isolation mechanism. Since your platform operations will be zero discharge, the proposed disposal well will have to accommodate a significant mud and cuttings volume and is critical to your operations. Have you considered a backup plan in the event the disposal well fails? If so, please provide an explanation of any alternative disposal methods under consideration? If you have any questions regarding this request, please feel free to call Bob Crandall, Wendy Mahan or myself at the above phone number. Sincerely, t~~~~ Petroleum Engineer TEM/jjc #2 STATE OF ALASKA ADVERTISING ORDER ') i NOTICE TO PUBLISHER } INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTIFIED AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH AlTACHED COPY OF ADVERTISEMENT MUST BE SUBMllTED WITH INVOICE ADVERTISING ORDER NO. AO-0211421 4;;:~;;:,~:~~~:·~~~~~Ž:~~ F AOGCC . . 333 W 7th Ave, Ste 100 o Anchorage, AK 99501 M AGENCY CONTACT DATE OF A.O. Jody Colombie PHONE May 9, 2001 PCN ~ Clarion Newspaper P.o. Box 3009 Kenai Alaska 99611 (907) 791 -1 ),),1 DATES ADVERTISEMENT REQUIRED: May 14, 2001 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: Type of Advertisement [8J Legal D Display D Classified DOther (Specify) SEE ATTACHED PUBLIC HEARING NOTICE . REF TYPE 1 VEN 2 ARD 3 4 FIN AMOUNT NUMBER AOGCC, 333 W. 7th Ave., Suite 100 , Anchorage, AK 99501 AMOUNT DATE TOTAL OF PAGE 1 OF All PAGES$ 2 PAGES COMMENTS 02910 Sy CC PGM LC ACCT FY NMR DIST llO 01 02140100 73540 2 3 ~ .~~: Q/ØPðMt-- 02-902 (Rev. 3/94) (Q((~"~~2.\.BIl~~ -'LlJN1"\ \.:ij ')('Iflll Publisher/Original Copies: Department Fiscal, DepamnenGIKeceivilllt-- j ..~", -~":¡ ':- - .". AO.FRM ì ..1 ) j Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: RU #Dl Well Disposal and Aquifer Exemption Orders, Upper Tyonek Formation, Redoubt Unit Forest, Oil Corporation Forest OilCorpöration by letter dâted May 8, 2001 has submitted an application , for Disposal mjection and Freshwater Aquifer Exemption Orders at the Redoubt Unit, offshore Cook Inlet, Alaska. The requested orders would exempt from consideration as freshwater, the Upper Tyonek Formation, allowing Forest Oil Corporationto'dispös~ of Class II oilfield waste fluids generated from drilling activities on the Osprey Platform into the RU #Dl Well. A person may submit written comments regarding the requested revision ppor to June 26, 2001 to the Alaska Oil and Gas Conservation ComÏnission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. In addition, the Commission has tentatively set a public hearing on June 26, 2001 at 1 :30 PM at the Alaska Oilattel Gas Conservation Commission at 333 West ih Avenue, Suite 100, Anchorage, Alaska 99501. A person may request that the tentatively scheduled hearing be held by filing a written request with the Commission prior to June 5, 2001. 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. If you are a person with a disability who may need a special modification in order to comment or to attend the public hearing, please contact Jody Colombie at 793.;.1221 before June 19,2001. Published May 14,2001 Anchorage Daily News AO#02114020 Clarion AO#-02114021 SC,j~\N N E L ~Hn\) ") ';: ') n !I 1 l ·STATE OF ALASKA ADVERTISING ORDER ) ) } NOTICE TO PUBLISHER) ADVERTISING ORDER NO. INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO" CERTIFIED AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COPY OF A 0-02114021 ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE ~r' F - AOGCC 333 West 7th Avenue, Suite 100 i\nchorage,AJe 99501 AGENCY CONTACT DATE OF A.O. T o Clarion Newspaper POBox 3009 KenaiAK 99611 lody Colombie May 9, ?,OOl PHO~E PCN (907) 791 -l??,l DATES ADVERTISEMENT REQUIRED: May 142001 M 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 .¡She is the Published at of 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 2001, and thereafter for _ consecutive days, the last publication appearing on the _ day of , 2001, 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 2001, Notary public for state of My commission expires . I 02-901 (Rev. 3/94) AO.FRM Page 2 PUBLISHER 8CAt~NEL JUNi ~)~ :1; .1.00,') 5~' '~) n I' :--; C 1\ ~I~ ,I\! E f"' **********************************'*~***********************************w~***************************** * ,}. , P, 0 1 * * j TRANSACTION REPORT) * * MAY-09-01 WED 12:29 PM * * * * SEND(M) * * * * DATE START RECEIVER TX TIME PAGES TYPE NOTE M~ DP * * * * MAY-09 12:28 PM 19072833299 1'IIH 3 SEND ( M) OK 094 * * . * ******************************************************************************************************** ] PUBLISHER'S AFFIDAVIT ) ) UNITED STATES OF AMERICA, STATE OF ALASKA } 88: .-------~---~~~~--~~~--------. . . N()tl(:eqt,P~bllc Helrlng 'I '..,.".' ,'STATE OF~~ASKA . . ,I "Alalk'a'Olfand"Ga's Conserv8t'onco'mm'.",?n.l Re: RU '#01 Well" . '.. ' .... ',... ..111'1, Disposal and Aquifer Exemption Orders, Upper Tyon.ek "'11 FormatIon, Redoubt Unit ',:' Forest Oil Corporation " . ,. ,',I . Forest Oil Corporation by l(¡Itter dated May 8, 2001 h$s ,sub~l mitted an appHcation for Disposal Injection and Freshwat~~'il' Aquifer Exemption Order at the Redoubt ,Unit, offshore CO~~'I' Inlet, ,Alaska. The requested.orders woulçl exempt from con~1 sideration as freshwa~er, .the Upper TyonekFQrmatlon,.alo\'l{~;:;.,I:; 1 ing Forest QilCorporatlon to dispose of Class II'ollfleld wast~'.,I, fluid generated from drilling activities on the Osprey Platfor"",", lintotheRU #D1 Well. .' '. ,,:":1 1 .' A person may submit written comments regarding the 11 1 'requested revision· prior to June 26, 2001 to the Alaska Olland::'II" 1 Gas Conservation Commission at 333 West 7th Avenue, Suit~1 : 1 00, Anchorage, Alaska 99501, In addition, the Commissloril · has tentatively set a public hearing on June. 26, 2001 at1 :301 · . PM· at the. Alaska Oil and Gas Conservation Commission.· ~~:I' 1333 West 7th Avenue, Suite 100,Anchorage, Alaska,9950.1.A,1 1 person may request thatthe tentatively scheduled ,hearing b~.'I :' held, by filing 'a written request with the Commission, prior tp,l 1 June 5, 2001. .... .,:" · If a request fora hearing is not timely filed, the CommlsSion:1 I, will consider the' issuance of an .order without. a h~arlng. To I:, '. learn if the Commission will hold the public hearing, please,l) I. call 793-1221. . . . . "I:',: I: If you are a person with a disability ~þo may neecJ a SPeClal"l! .' modification in order to comment or to attend the public hear~.l' 1:lng, please contact Jody Colombie aì793-1221 before Junø,.I'., .,,19, 2001. . ", ,,:;:.,,, . 1~:Daniel T. Seamount, Jr. .;,1 1:;011 and Gas Conservation Commission . ":1 I,,'PLJBLISH: 5/15, 2001 ':, .,.. . '. . . 212~/2074 I, .____________--M-~-_---__--~_~ II! ' ' " I Denise Reece being first duly sworn, on oath deposes and says: That I am and was at all times herein this affidavit mentions, Supervisor of Legals of the Peninsula Clarion, a newspaper of general circulation and published at Kenai, Alaska, that the Notice of Public Hearing AO-0211421 a printed copy of which is hereto annexed was published in said paper one each and every day for one successive and consecutive day in thei ssues on the following dates: May 15,2001 X ¡JJÞ./J<;.#~ J(JJÞI) -R SUBSCRIBED AND SWORN to before me this 17th day of May 2001 y/~ ~~5? ~/) ~ NOTARY PUBLIC in aor the State of Alaska. 10-Jul-02 My Commission expires j\\) ~ ~0} 20Ci\ sct-\NNEL, !' -., s)r ATE OF ALASKA ADVERTISING ORDER 1 , ) ADVERTISING ORDER NO. NOTICE TO PUBLISHER INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO;, CERTIFIED AFFIDAVIT OF PUBLICATION (PART2 OF THIS FORM) WITH ATTACHED COPY OF ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE AO;.0211420 F . o AOGCC 333 W 7th Ave, Ste 100 Anchorage, AK 99501 AGENCY CONTACT DATEOFA.O. Jodv Colombie PHONE May 9, 2001 PCN M ~ Anchorage Daily News POBox 149001 Anchorage,AK 99514 (907) 791 -1 ?,?1 DATES ADVERTISEMENT REQUIRED: May 14, 2001 TIlE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: Type of Advertisement [8] Legal D Display D Classified DOther (Specify) SEE ATTACHED PUBLIC HEARING NOTICE . REF TYPE 1 VEN 2 ARD 3 4 FIN AMOUNT 1 2 3 NUMBER AOGCC, 333 W. 7th Ave., Suite 100 Anchorage, AK 99501 AMOUNT DATE TOTAL OF PAGE 1 OF ALL PAGES$ 2 PAGES COMMENTS 02910 Sy CC PGM LC ACCT FY NMR DIST lIQ 01 02140100 73540 II .QU~O;;:¿:QcJ~ 02-902 (Rev. 3/94) ~(;t~NNELI' JUN , ~J; 20Q!~ Publisher/Original Copies: Department Fiscal, Department, Receiving AO.FRM } i J Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: RU #Dl Well Disposal and Aquifer Exemption Orders, Upper Tyonek Formation, Redoubt Unit Forest Oil Corporation Forest Oil Corporation by letter dated May 8, 2001 has submitted an application for Disposal Injection and Freshwater Aquifer Exemption Orders at the Redoubt Unit, offshore Cook Inlet, Alaska. The requested orders would exempt from consideration as freshwater, the Upper Tyonek Formation, allowing Forest Oil Corporation to dispose of Class II oilfield waste fluids generated from drilling activities on the Osprey Platform into the RU #Dl Well. A person may submit written comments regarding the requested revision prior to June 26, 2001 to the Alaska Oil and Gas Conservation Commission at 333 West ih Avenue, Suite 100, Anchorage, Alaska 99501. In addition, the Commission has tentatively set a public hearing on June 26, 2001 at 1 :30 PM at the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. A person may request that the tentatively scheduled hearing be held by filing a written request with the Commission prior to June 5, 2001. 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. If you are a person with a disability who may need a special modification in order to comment or to attend the public hearing, please contact Jody Colombie at 793-1221 before June 19, 2001. //)~ ~ar::-;:- ~eamount, Jr. Oil and Gas Conservation Commission Published May 14,2001 Anchorage Daily News AO#02114020 Clarion AO#-02114021 C(¡·-'·^~~r-3r- - II'cfií\: trþ (:¡ 20[ ~ <,~\\¿J'-'~5'¡~~\JCL) t}~n,1 (, ,J _ 1.1:'1 , STATE OF ALASKA ADVERTISING ORDER ) ) I NOTICE TO PUBLISHER! ADVERTISING ORDER NO. INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO" CERTIFIED AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COPY OF A 0-02114020 ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE F - ~ Anchorage Daily News POBox 149001 Anchorage, AK 99514 AGENCY CONTACT DATE OF A.O. Jociy Colombie MflY 9, ),001 PHONE PCN (907) 791 -1 ?1 1 DATES ADVERTISEMENT REQUIRED: May 14,2001 AOGCC 333West 7th Avenue, Suite 100 Anchorage, AK 99501 M 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 SUBMllTED 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 .'she is the Published at of 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 2001, and thereafter for _ consecutive days, the last publication appearing on the _ day of . 2001, and that the rate charged thereon is not in excess of the rate charged private individuals. Subscribed and swom to before me This _ day of 2001. Notary public for state of My commission expires , K:", 8·"h'1~J\.\.t.. ¡,~.::~ .... ,~~ ~tlR 9 ~ (JOfl/¡ \J'v.J4..~~'I;;1L.E.../ vu~'iJ t..; <.,;,1 f.. 1.,;, 02-901 (Rev. 3/94) Page 2 AO.FRM PUBLISHER ) / Anchorage Daily News Affidavit of Publication 1001 Northway Drive, Anchorage, AK 99508 AD# PRICE PER DAY DATE $113.05 874479 05/14/2001 $113.05 STATE OF ALASKA THIRD JUDICIAL DISTRICT Eva Alexie, 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 newsparer in Anchorage, Alaska, and it is now and durmg all saïa time was printed in an office maintained at the aforesaid rlace of publication of said newsparer. That the annexed is a copy of an advertisement as it was puólished 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 fore~oing publication is not in excess of the rate charged private indIviduals. C 1\0 Signed (.-JL~\..-, \.JL" '-QJ..{-L~,' Subscribed and sworn to me before this date: ,-~/ Þ / Notary Public in and for the State of Alaska. Third Division. Anchorage, Alaska MY COMMISSION EXPIRES: / ~41 40c;¿ t2 ~ \ l1'('('rN ({ \.\\.~~~.':'~~ .~.rrl"".,/ ,\. v .' ...... '. Q~ ....... ~ :'~or~'" ··.oS '-. ... ~J-' ¿,::. ~ . Å_...... ·rn-- :::: :;z: : CIJ -vl:3L Ie : ~ -:z.~ . ...... -~~...... ....... -:::. .,~ ... ~. ~ ~ ..,..~ ALþ..~·~ -\' ./ . . . . 'Þ",\' /J L'. ')... \\ -'./,( çx,DItes'QeC' \\ I)JJ)JJ})))' ~ / t~ECEiVEf) MAY ~)O 2001 t\laska Oil & Gas Cor;~;;, LOnHn!SS~c' OTHER OTHE~nchorage GRAND CHARGES CHARGES #2 TOTAL $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 I ':'::-"<1 ~ i"', ~ Nlltic:e 'o,f. , I ,',' ,PubUcHearlng , '~':.. ", .1, " ~ ". : ',. 'f>.'." ':,. ,: I ,I '~ STATE.'è:):¡':A~ASK~ AlaskøO!lcmdGa$ <' C on~er~~ti,o~.~o~ "1jt~,e' 'Re:'R'l:,¡I'Dî,well,:<.'.;,·'. . Disposal'ClndAqul,fer ' Exemption 'O.rders, , .. Upper TYOl'le,i<I7:Qr,J:nO" I tion,Redpubt.lJnlt' ',' . " For~st9i,I.s~r~,?~?ti.0~,ii Fo'rest 'Oil CO~Di:\rtltl"n ,D, 1""'.,.raOI",aMo, 8 ~(¡IJI t¡o~ requ"'~,IE'a on op, I "lleo' Jr.n lor Di"po~ol In- i""lIor, ona Frf ;,hllllolE'r ':'au,TE-r Exem"tion Or, l'E-r~ 01 Ine RE'aOUD' Un" I 0 f f s.n o.r eC 00'1( I nfe'T, A' las. k,.P ~'. .,.'TI,'. i"..~,e. .".'~,',e"",q, "u,.e, ,st....e. ,..,d, o rde.rs','wdulà·: exempt,' from'conSidè'ròtl"no~ ' r""t,""OIE'r Tne UP DE' I" , T ,"n",I<, FormOTlon, allo",,- , ,n9 Foresl 001 Cc-rDoro- II,Jr, ,,, ai.¡,posE' r.t Closs II :o.I'I'''ldll\.O;,I.: fluid. gero, ¡ ",r(;llea from arllllng oc- II'o.I.t:-:. úr. It_-:- O~pl'"'e'r' : Plotlorm inlo I'M RUjD1 ¡W~I!:" .1."":".',..>:, I .. pero;¡on mo,' 'Oubmll.' I ,'.rIITE-n commenT.. rE'- ,~?iP~ ~Vr~~{~~~j~t;~~f, <:001 TO ,hE' Alo"~o 011 ona, C·o.. ConservaTion Com- I rY,,;;,.lon 0' ~3J WE'..t 7Th .:. .",nUE- 5ul,E' 100 An" ,norogE- A 10..1(0 99501 In (;I(ail;on It,E- Comrn'....'on , noo¡, TenTat,llIel,· ~et 0 pub·' I;, hE-Dring con Jul'lE- 26, ' I N01 01' 1:30 PM 01' The , ':'10.1<,0 Oi' ond Go.. Con-' , 1~;~0~~~f~w,m~s;~~,:~~ :)uITE' 100, Anchoroge... ':'100;.1(0 99:i01, A person moy requestthatThe Ten, tativet)'scheduled heat:',' ing be held by filing 0' written recK!est with the" Commission priorto~June ' 5, 200L If a request for a hea~';' , lng' Is not timely filed, the,;' Commission will 'con"' sider the J$su6nce .of an . order 'wlthou,t chearlng, : To learn if the Commis. sion will hold the pl)blic ' : hearing, please call 1 793-1221. ' I. If VO, u are .ape. rs.o, n with' a disability who may l need: a'sP,ecial modifiea- ! tionin Ql'der to comment :' or fóa:ttend the -public hearing; please contact Jodv Colombie at 793-122t , before June 19,2Q01. Is/Daniel T~ Seamount Jr 011 and Gas ConservQtion Commission : AO-02114020 Pub.: May 14, 2001 ..---- sr;J~1NNED JUN 2 :~ 2004 $113.05 $0.00 $113.05 S(,,;\~~,H\\ E~\ J \ 1 N1, ~ 'ì f' \\,1 **********************************~~\***********************************~l***************************** * J P,Ol * * J TRANSACTION REPORT * * MAY-09-01 WED 12:26 PM * * * * SEND(M) * * * * DATE START RECEIVER TX TIME PAGES TYPE NOTE M~ DP * * * * MAY-09 12:25 PM ANCH NEWS l'14N 3 SEND ( M) OK 093 * * * ******************************************************************************************************** ) l I Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: RU #D1 Well Disposal and Aquifer Exemption Orders, Upper Tyonek Formation, Redoubt Unit Forest ,Oil Corporation Forest Oil Corporation by letter dated May 8, 2001 has submitted an application. for Disposal Injection and Freshwater Aquifer Exemption Orders at,the Redoubt Unit, offshore Cook Inlet, Alaska. The requested orders would exempt from consideration as freshwater, the Upper Tyonek Formation, allowing Forest Oil Corporation to dispose of Class II oilfield waste fluids generated from drilling activities on the Osprey Platform into the RU#Dl Well. A person may submit written comments regarding the requested revision prior to June 26, 2001 to the Alaska Oil and Gas Conservation Commission at 333 West ih Avenue, Suite 100, Anchorage, Alaska 99501. In addition, the Commission' has tentatively set a public hearing on June 26, 2001 at 1 :30 PM at the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. A person may request that the tentatively scheduled hearing be held by filing a written request with the Commission prior to June 5, 2001. 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. If you are a person with a disability who may need a special modification in order to comment or to attend the public hearing, please contact Jody Colombie at 793-1221 before June 19,2001. Published May 14, 200 I Anchorage Daily News AO#02114020 Clarion AO#-021 14021 ~'~ ~., rl \J ~\i\ ."~ ,", ~\ÜN\~' \"~ ," __It.' i\ ~.,' ~ ~\\ t.\. ' ' ~'J' ~,I' Ii " 1 certify that on ). 9,:Ô J a copy of the above was faxedhfi8iréd)o each of the fol~ng at the~ of record6~/J?~ A..;; !t7/?'S/ c7il' J c OFFICE OF THE GOVERNOR, JOHN KATZ STE 518 444 N CAPITOL NW WASHINGTON, DC 20001 LIBRARY OF CONGRESS, STATE DOCUMENT SECTION EXCH & GIFT DIV 10 FIRST ST SE WASHINGTON, DC 20540 US GEOLOGICAL SURVEY, LIBRARY NATIONAL CTR MS 950 RESTON, VA 22092 AMOCO CORP 2002A, LIBRARY/INFO CTR POBOX 87703 CHICAGO, IL 60680-0703 ALFRED JAMES III 107 N MARKET STE 1000 WICHITA, KS 67202-1811 CROSS TIMBERS OPERATIONS, SUSAN LILLY 210 PARK AVE STE 2350 OKLAHOMA CITY, OK 73102-5605 OIL & GAS JOURNAL, LAURA BELL POBOX 1260 TULSA, OK 74101 US DEPT OF ENERGY, ENERGY INFORMATION ADMINISTRATION MIR YOUSUFUDDIN 1999 BRYAN STREET STE 1110 DALLAS, TX 75201-6801 CROSS TIMBERS OIL COMPANY, MARY JONES 810 HOUSTON ST STE 2000 FORT WORTH, TX 76102-6298 ) / J PIRA ENERGY GROUP, LIBRARY 3 PARK AVENUE (34th & PARK) NEW YORK, NY 10016 NY PUBLIC LIBRARY DIV E, GRAND CENTRAL STATION POBOX 2221 NEW YORK, NY 10163-2221 ARENT FOX KINTNER PLOTKIN KAHN, LIBRARY WASHINGTON SO BLDG 1050 CONNECTICUT A V NW WASHINGTON, DC 20036-5339 US MIN MGMT SERV, CHIEF OCS STATS & INFO 381 ELDEN ST MS 4022 HERNDON, VA 20170-4817 U S DEPT OF ENERGY, PHYLLIS MARTIN MS EI823 1000 INDEPENDENCE SW WASHINGTON, DC 20585 TECHSYS CORP, BRANDY KERNS PO BOX 8485 GATHERSBURG, MD 20898 DPC, DANIEL DONKEL 1420 NORTH ATLANTIC AVE, STE 204 DAYTON BEACH, FL 32118 SD DEPT OF ENV & NA TRL RESOURCES, OIL & GAS PROGRAM 2050 W MAl N STE #1 RAPID CITY, SD 57702 ILLINOIS STATE GEOL SURV, LIBRARY 469 NATURAL RESOURCES BLDG 615 E PEABODY DR CHAMPAIGN,IL 61820 LINDA HALL LIBRARY, SERIALS DEPT 5109 CHERRY ST KANSAS CITY, MO 64110-2498 MURPHY E&P CO, ROBERT F SAWYER POBOX 61780 NEW ORLEANS, LA 70161 UNIV OF ARKANSAS, SERIALS DEPT UNIV LIBRARIES FAYETTEVILLE, AR 72701 IOGCC, POBOX 53127 OKLAHOMA CITY, OK 73152-3127 R E MCMILLEN CONSULT GEOL 202 E 16TH ST OWASSO, OK 74055-4905 GAFFNEY, CLINE & ASSOC., INC., LIBRARY 16775 ADDISON RD, STE 400 ADDISON, TX 75001 BAPIRAJU 335 PINYON LN COPPELL, TX 75019 DEGOL YER & MACNAUGHTON, MIDCONTINENT DIVISION ONE ENERGY SO, STE 400 4925 GREENVILLE AVE DALLAS, TX 75206-4083 STANDARD AMERICAN OIL CO, AL GRIFFITH POBOX 370 GRANBURY, TX 76048 SHELL WESTERN E&P INC, G.S. NADY POBOX 576 HOUSTON, TX 77001-0574 H J GRUY, ATTN: ROBERT RASOR 1200 SMITH STREET STE 3040 HOUSTON, TX 77002 '.. ' '' U' ~" !>}.; '» 2 GOl.1 I." -.. '-'. ).1I\\~~H~ \\ \ I IV (.! çj. '1 :.J!\.¡ð'M'ì~r\'~I};.¡..U,..J ~ \, ~ . ENERGY GRAPHICS, MARTY LINGNER 1600 SMITH ST, STE 4900 HOUSTON, TX 77002 CHEVRON, PAUL WALKER 1301 MCKINNEY RM 1750 HOUSTON, TX 77010 MARK ALEXANDER 7502 ALCOMIT A HOUSTON, TX 77083 EXXON EXPLORATION CO., T E ALFORD POBOX 4778 HOUSTON, TX 77210-4778 PETR INFO, DAVID PHILLIPS POBOX 1702 HOUSTON, TX 77251-1702 WORLD 01 L, DONNA WI LLlAMS POBOX 2608 HOUSTON, TX 77252 PENNZOIL E&P, WILL D MCCROCKLIN POBOX 2967 HOUSTON, TX 77252-2967 ACE PETROLEUM COMPANY, ANDREW C CLIFFORD PO BOX 79593 HOUSTON, TX 77279-9593 WATTY STRICKLAND 2803 SANCTUARY CV KA TV, TX 77450-8510 ROBERT G GRAVELY 7681 S KIT CARSON DR LITTLETON, CO 80122 ') j ¡~ PURVIN & GERTZ INC, LIBRARY 2150 TEXAS COMMERCE TWR 600 TRAVIS ST HOUSTON, TX 77002-2979 RAY TYSON 2016 MAIN #1415 HOUSTON, TX 77002-8844 OIL & GAS JOURNAL, BOB WILLIAMS 1700 W LOOP SOUTH STE 1000 HOUSTON, TX 77027 PETRAL CONSULTING CO, DANIEL L LIPPE 9800 RICHMOND STE 505 HOUSTON, TX 77042 MARATHON OIL CO, GEORGE ROTHSCHILD JR RM 2537 POBOX 4813 HOUSTON, TX 77210 UNOCAL, REVENUE ACCOUNTING POBOX 4531 HOUSTON, TX 77210-4531 EXXON EXPLOR CO, LAND/REGULATORY AFFAIRS RM 301 POBOX 4778 HOUSTON, TX 77210-4778 CHEVRON USA INC., ALASKA DIVISION ATTN: CORRY WOOLlNGTON POBOX 1635 HOUSTON, TX 77251 PHILLIPS PETROLEUM COMPANY, W ALLEN HUCKABAY PO BOX 1967 HOUSTON, TX 77251-1967 PHILLIPS PETR CO, ALASKA LAND MGR POBOX 1967 HOUSTON, TX 77251-1967 EXXONMOBIL PRODUCTION COMPANY, J W KIKER ROOM 2086 POBOX 2180 HOUSTON, TX 77252-2180 EXXONMOBIL PRODUCTION COMPANY, GARY M ROBERTS RM 3039 POBOX 2180 HOUSTON, TX 77252-2180 CHEVRON CHEM CO, LIBRARY & INFO CTR POBOX 2100 HOUSTON, TX 77252-9987 MARATHON, Ms. Norma L. Calvert POBOX 3128, Ste 3915 HOUSTON, TX 77253-3128 PHILLIPS PETR CO, PARTNERSHIP OPRNS JIM JOHNSON 6330 W LOOP S RM 1132 BELLAIRE, TX 77401 TEXACO INC, R Ewing Clemons PO BOX 430 BELLAIRE, TX 77402-0430 TESORO PETR CORP, LOIS DOWNS 300 CONCORD PLAZA DRIVE SAN ANTONIO, TX 78216-6999 INTL OIL SCOUTS. MASON MAP SERV INC POBOX 338 AUSTIN, TX 78767 DIANE SUCHOMEL 105070 W MAPLEWOOD DR LITTLETON, CO 80127 GEORGE G VAUGHT JR POBOX 13557 DENVER, CO 80201 8CA.NNEi.,\' JON ~" ~~ 20011 BABCOCK & BROWN ENERGY, INC., JULIE WEBER 600 17TH STREET STE. 2630 SOUTH TOWER DENVER, CO 80210 JERRY HODGDEN GEOL 408 18TH ST GOLDEN, CO 80401 JOHN A LEVORSEN 200 N 3RD ST #1202 BOISE, ID 83702 MUNGER OIL INFOR SERV INC, POBOX 45738 LOS ANGELES, CA 90045-0738 ANTONIO MADRID POBOX 94625 PASADENA, CA 91109 US GEOLOGICAL SURVEY, KEN BIRD 345 MIDDLEFIELD RD MS 999 MENLO PARK, CA 94025 ECONOMIC INSIGHT INC, SAM VAN VACTOR PO BOX 683 PORTLAND, OR 97207 DEPT OF REVENUE, BEVERLY MARQUART 550 W 7TH A V STE 570 ANCHORAGE, AK 99501 DUSTY RHODES 229 WHITNEY RD ANCHORAGE, AK 99501 GUESS & RUDD, GEORGE LYLE 510 L ST, STE 700 ANCHORAGE, AK 99501 ) US GEOLOGICAL SURVEY, LIBRARY BOX 25046 MS 914 DENVER, CO 80225-0046 NRG ASSOC, RICHARD NEHRING POBOX 1655 COLORADO SPRINGS, CO 80901- 1655 TAHOMA RESOURCES, GARY PLAYER 1671 WEST 546 S CEDER CITY, UT 84720 LA PUBLIC LIBRARY, SERIALS DIV 630 W 5TH ST LOS ANGELES, CA 90071 ORO NEGRO, INC., 9321 MELVIN AVE NORTHRIDGE, CA 91324-2410 SHIELDS LIBRARY, GOVT DOCS DEPT UNIV OF CALIF DAVIS, CA 95616 US EPA REGION 10, THOR CUTLER OW-137 1200 SIXTH AVE SEATTLE, WA 98101 TRUSTEES FOR ALASKA, 1026 W. 4th Ave, Ste 201 ANCHORAGE, AK 99501 DEPT OF REVENUE, OIL & GAS AUDIT DENISE HAWES 550 W 7TH A V STE 570 ANCHORAGE, AK 99501 DEPT OF REVENUE, DAN DICKINSON, DIRECTOR 550 W 7TH AVE, SUITE 500 ANCHORAGE, AK 99501 J C & R INDUSTRIES, INC." KURT SALTSGAVER 7500 W MISSISSIPPI AVE STE C4 LAKEWOOD, CO 80226-4541 RUBICON PETROLEUM, LLC, BRUCE I CLARDY SIX PINE ROAD COLORADO SPRINGS, CO 80906 US GEOLOGICAL SURVEY, LIBRARY 2255 N GEMINI DR FLAGSTAFF, AZ 86001-1698 BABSON & SHEPPARD, JOHN F BERGQUIST POBOX 8279 VIKING STN LONG BEACH, CA 90808-0279 TEXACO INC, Portfolio Team Manager R W HILL POBOX 5197x Bakersfield, CA 93388 H L WANGENHEIM 5430 SAWMILL RD SP 11 PARADISE, CA 95969-5969 MARPLES BUSINESS NEWSLETTER, MICHAEL J PARKS 117 W MERCER ST STE 200 SEATTLE, WA 98119-3960 STATE PIPELINE OFFICE, LIBRARY KATE MUNSON 411 W 4TH AVE, STE 2 ANCHORAGE, AK 99501 FAIRWEATHER E&P SERV INC, JESSE MOHRBACHER 7151ST #4 ANCHORAGE, AK 99501 FORCENERGY INC., JIM ARLINGTON 310 K STREET STE 700 ANCHORAGE, AK 99501 DEPT OF REVENUE, CHUCK LOGSTON 550 W 7TH AVE, SUITE 500 ANCHORAGE, AK 99501 ALASKA DEPT OF LAW, ROBERT E MINTZ ASST ATTY GEN 1031 W 4TH AV STE 200 ANCHORAGE, AK 99501-1994 DEPT OF REVENUE, OIL & GAS AUDIT FRANK PARR 550 W 7TH AVE STE 570 ANCHORAGE, AK 99501-3540 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS JULIE HOULE 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 DEPT OF NATURAL RESOURCES, PUBLIC INFORMATION CTR 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 HDR ALASKA INC, MARK DALTON 2525 C ST STE 305 ANCHORAGE, AK 99503 ANADARKO, MARK HANLEY 3201 C STREET STE 603 ANCHORAGE, AK 99503 FINK ENVIRONMENTAL CONSULTING, INC., THOMAS FINK, PHD 6359 COLGATE DR. ANCHORAGE, AK 99504-3305 AMERICA/CANADIAN STRATIGRPH CO, RON BROCKWAY 4800 KUPREANOF ANCHORAGE, AK 99507 US BLM AK DIST OFC, RESOURCE EVAL GRP ART BONET 6881 ABBOTT LOOP RD ANCHORAGE, AK 99507-2899 ') / YUKON PACIFIC CORP, JOHN HORN VICE CHM 1049 W 5TH AV ANCHORAGE, AK 99501-1930 GAFO,GREENPEACE PAMELA MILLER 125 CHRISTENSEN DR. #2 ANCHORAGE, AK 99501-2101 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS BRUCE WEBB 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 DNR, DIV OF OIL & GAS JAMES B HAYNES NATURAL RESRCE MGR 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 AK JOURNAL OF COMMERCE, OIL & INDUSTRY NEWS ROSE RAGSDALE 4220 B Street Ste #210 ANCHORAGE, AK 99501-3560 BAKER OIL TOOLS, ALASKA AREA MGR 4710 BUS PK BLVD STE 36 ANCHORAGE, AK 99503 ALASKA OIL & GAS ASSOC, JUDY BRADY 121 W FIREWEED LN STE 207 ANCHORAGE, AK 99503-2035 ARLEN EHM GEOL CONSL TNT 2420 FOXHALL DR ANCHORAGE, AK 99504-3342 US BUREAU OF LAND MNGMNT, ANCHORAGE DIST OFC PETER J DITTON 6881 ABBOTT LOOP ROAD ANCHORAGE, AK 99507 THOMAS R MARSHALL JR 1569 BIRCHWOOD ST ANCHORAGE, AK 99508 ) PRESTON GATES ELLIS LLP, LIBRARY 420 L ST STE 400 ANCHORAGE, AK 99501-1937 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS TIM RYHERD 550 W 7th AVE STE 800 ANCHORAGE, AK 99501-3510 DEPT OF NATURAL RESOURCES, DIV OIL & GAS WILLIAM VAN DYKE 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS JIM STOUFFER 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 BRISTOL ENVIR SERVICES, JIM MUNTER 2000 W. INT'L AIRPORT RD #C-1 ANCHORAGE, AK 99502-1116 N-I TUBULARS INC, 3301 C Street Ste 209 ANCHORAGE, AK 99503 ANADRILL-SCHLUMBERGER, 3940 ARCTIC BLVD #300 ANCHORAGE, AK 99503-5711 JAMES E EASON 8611 LEEPER CIRCLE ANCHORAGE, AK 99504-4209 US BUREAU OF LAND MNGMNT, ANCHORAGE DIST OFC DICK FOLAND 6881 ABBOTT LOOP RD ANCHORAGE, AK 99507 TRADING BAY ENERGY CORP, PAUL CRAIG 5432 NORTHERN LIGHTS BLVD ANCHORAGE, AK 99508 ~Cß~NN\EJj ~.\J\UIN ~: $1, 2nn¿~! on ~,,~ If'i) (Î)) C)OfLí UOAl ANCHORAGE, INST OF SOCIAL & ECON RESEARCH TERESA HULL 3211 PROVIDENCE DR ANCHORAGE, AK 99508 US MIN MGMT SERV, RESOURCE STUDIES AK OCS REGN KIRK W SHERWOOD 949 E 36TH A V RM 603 ANCHORAGE, AK 99508-4302 US MIN MGMT SERV, LIBRARY 949 E 36TH A V RM 603 ANCHORAGE, AK 99508-4363 JOHN MILLER 3445 FORDHAM DR ANCHORAGE, AK 99508-4555 PHILLIPS PETR CO, JIM RUUD P.O. BOX 100360 ANCHORAGE, AK 99510 PHILLIPS ALASKA, LEGAL DEPT MARK P WORCESTER POBOX 100360 ANCHORAGE, AK 99510-0360 PHILLIPS ALASKA, MARK MAJOR A TO 1968 POBOX 100360 ANCHORAGE, AK 99510-0360 PHILLIPS ALASKA, KUP CENTRAL WELLS ST TSTNG WELL ENG TECH NSK 69 POBOX 196105 ANCHORAGE, AK 99510-6105 AL YESKA PIPELINE SERV CO, LEGAL DEPT 1835 S BRAGAW ANCHORAGE, AK 99512-0099 DAVID W. JOHNSTON 320 MARINER DR. ANCHORAGE, AK 99515 ) J ) US MIN MGMT SERV, RICHARD PRENTKI 949 E 36TH AV ANCHORAGE, AK 99508-4302 US MIN MGMT SERV, AK OCS REGIONAL DIR 949 E 36TH AV RM 110 ANCHORAGE, AK 99508-4302 GORDONJ.SEVERSON 3201 WESTMAR CIR ANCHORAGE, AK 99508-4336 REGIONAL SUPRVISOR, FIELD OPERATNS, MMS ALASKA OCS REGION 949 E 36TH A V STE 308 ANCHORAGE, AK 99508-4363 US MIN MGMT SERV, RESOURCE EVAL JIM SCHERR 949 E 36TH A V RM 603 ANCHORAGE, AK 99508-4363 US MIN MGMT SERV, FRANK MILLER 949 E 36TH A V STE 603 ANCHORAGE, AK 99508-4363 USGS - ALASKA SECTION, LIBRARY 4200 UNIVERSITY DR ANCHORAGE, AK 99508-4667 CIRI, LAND DEPT POBOX 93330 ANCHORAGE, AK 99509-3330 ANCHORAGE TIMES, BERT TARRANT POBOX 100040 ANCHORAGE, AK 99510-0040 PHILLIPS ALASKA, JOANN GRUBER ATO 712 POBOX 100360 ANCHORAGE, AK 99510-0360 PHILLIPS ALASKA, STEVE BENZLER ATO 1404 POBOX 100360 ANCHORAGE, AK 99510-0360 PHILLIPS ALASKA, LIBRARY POBOX 100360 ANCHORAGE, AK 99510-0360 PHILLIPS ALASKA, LAND DEPT JAMES WINE GARNER POBOX 10036 ANCHORAGE, AK 99510-0360 PETROLEUM INFO CORP, KRISTEN NELSON POBOX 102278 ANCHORAGE, AK 99510-2278 AL YESKA PIPELINE SERV CO, CHUCK O'DONNELL 1835 S BRAGAW - MS 530B ANCHORAGE, AK 99512 AL YESKA PIPELINE SERV CO, PERRY A MARKLEY 1835 S BRAGAW - MS 575 ANCHORAGE, AK 99512 US BUREAU OF LAND MGMT, OIL & GAS OPRNS (984) J A DYGAS 222 W 7TH AV #13 ANCHORAGE, AK 99513-7599 ANCHORAGE DAILY NEWS, EDITORIAL PG EDTR MICHAEL CAREY POBOX 149001 ANCHORAGE, AK 99514 JWL ENGINEERING, JEFF LIPSCOMB 9921 MAIN TREE DR. ANCHORAGE, AK 99516-6510 NORTHERN CONSULTING GROUP, ROBERT BRITCH, P.E. 2454 TELEQUANA DR. ANCHORAGE, AK 99517 Q)~t~~~\\\~EU JDN 2; 3 2DDl} GERALD GANOPOLE CONSULT GEOL 2536 ARLINGTON ANCHORAGE, AK 99517-1303 ARMAND SPIELMAN 651 HILANDER CIRCLE ANCHORAGE, AK 99518 JACK 0 HAKKILA POBOX 190083 ANCHORAGE, AK 99519-0083 MARATHON OIL CO, BRAD PENN POBOX 196168 ANCHORAGE, AK 99519-6168 EXXONMOBIL PRODUCTION COMPANY, MARK P EVANS PO BOX 196601 ANCHORAGE, AK 99519-6601 BP EXPLORATION (ALASKA) INC, SUE MILLER POBOX 196612 MIS LR2-3 ANCHORAGE, AK 99519-6612 AMSINALLEE CO INC, WILLIAM 0 VALLEE PRES PO BOX 243086 ANCHORAGE, AK 99524-3086 D A PLATT & ASSOC, 9852 LITTLE DIOMEDE CIR EAGLE RIVER, AK 99577 COOK INLET KEEPER, BOB SHA VELSON PO BOX 3269 HOMER, AK 99603 DOCUMENT SERVICE CO, JOHN PARKER POBOX 1468 KENAI, AK 99611-1468 ì ) DAVID CUSATO 600 W 76TH A V #508 ANCHORAGE, AK 99518 ASRC, CONRAD BAGNE 301 ARCTIC SLOPE A V STE 300 ANCHORAGE, AK 99518 HALLIBURTON ENERGY SERV, MARK WEDMAN 6900 ARCTIC BLVD ANCHORAGE, AK 99518-2146 OPST AD & ASSOC, ERIKA OPSTAD PROF GEOL POBOX 190754 ANCHORAGE, AK 99519 ENSTAR NATURAL GAS CO, BARRETT HATCHES POBOX 190288 ANCHORAGE, AK 99519-0288 MARATHON OIL CO, OPERATIONS SUPT POBOX 196168 ANCHORAGE, AK 99519-6168 UNOCAL, KEVIN TABLER POBOX 196247 ANCHORAGE, AK 99519-6247 UNOCAL, POBOX 196247 ANCHORAGE, AK 99519-6247 BP EXPLORATION (ALASKA), INC., MARK BERLINGER MB 8-1 PO BOX 196612 ANCHORAGE, AK 99519-6612 BP EXPLORATION (ALASKA) INC, INFO RESOURCE CTR MB 3-2 POBOX 196612 ANCHORAGE, AK 99519-6612 BP EXPLORATION (ALASKA) INC, PETE ZSELECZKY LAND MGR POBOX 196612 ANCHORAGE, AK 99519-6612 BP EXPLORATION (ALASKA) INC, MR. DAVIS, ESO POBOX 196612 MB 13-5 ANCHORAGE, AK 99519-6612 PINNACLE, STEVE TYLER 20231 REVERE CIRCLE EAGLE RIVER, AK 99577 L G POST O&G LAND MGMT CONSULT 10510 Constitution Circle EAGLE RIVER, AK 99577 JAMES RODERICK PO BOX 770471 EAGLE RIVER, AK 99577-0471 DEPT OF NATURAL RESOURCES, DGGS JOHN REEDER POBOX 772805 EAGLE RIVER, AK 99577-2805 PHILLIPS PETR, ALASKA OPERATIONS MANAGER J W KONST P 0 DRAWER 66 KENAI, AK 99611 RON DOLCHOK PO BOX 83 KENAI, AK 99611 KENAI PENINSULA BOROUGH, ECONOMIC DEVEL DISTR STAN STEADMAN POBOX 3029 KENAI, AK 99611-3029 NANCY LORD PO BOX 558 HOMER, AK 99623 Ð)(;;t\~~\~SEU "liON ~), ~)) ?OrV,\, I! ,~\ " 0.', n ~ 1 L'\ SENATOR LOREN LEMAN STATE CAPITOL RM 113 JUNEAU, AK 99801-1182 RICHARD FINEBERG PO BOX416 ESTER, AK 99725 DEPT OF NATURAL RESOURCES, DIV OF LAND REG MGR NORTHERN REGION 3700 AIRPORT WAY FAIRBANKS, AK 99709-4699 FAIRBANKS DAILY NEWS-MINER, KATE RIPLEY POBOX 70710 FAIRBANKS, AK 99707 NICK STEPOVICH 543 2ND AVE FAIRBANKS, AK 99701 AL YESKA PIPELINE SERVICE CO, VALDEZ CORP AFFAIRS SANDY MCCLINTOCK POBOX 300 MS/701 VALDEZ, AK 99686 PACE, SHEILA DICKSON POBOX 2018 SOLDOTNA, AK 99669 UNIVERSITY OF ALASKA FBKS, PETR DEVEL LAB DR AKANNI LAWAL POBOX 755880 FAIRBANKS, AK 99775-5880 ASRC, BILL THOMAS POBOX 129 BARROW, AK 99723 FRED PRATT POBOX 72981 FAIRBANKS, AK 99707-2981 RICK WAGNER POBOX 60868 FAIRBANKS, AK 99706 VALDEZ VANGUARD, EDITOR POBOX 98 VALDEZ, AK 99686-0098 KENAI NATL WILDLIFE REFUGE, REFUGE MGR POBOX 2139 SOLDOTNA, AK 99669-2139 BELOWICH, MICHAEL A BELOWICH 1125 SNOW HILL AVE WASILLA, AK 99654-5751 ~ DEPT OF ENVIRON CONSERV SPAR, CHRIS PACE 410 WILLOUGHBY AV STE 105 JUNEAU, AK 99801-1795 UNIV OF ALASKA FBX, PETR DEVEL LAB SHIRISH PATIL 437 DICKERING FAIRBANKS, AK 99775 K&K RECYCL INC, POBOX 58055 FAIRBANKS, AK 99711 C BURGLlN POBOX 131 FAIRBANKS, AK 99707 UNIV OF ALASKA FAIRBANKS, PETR DEVEL LAB DR V A KAMATH 427 DUCKERING FAIRBANKS, AK 99701 VALDEZ PIONEER, PO BOX 367 VALDEZ, AK 99686 JAMES GIBBS POBOX 1597 SOLDOTNA, AK 99669 PENNY VADLA PO BOX 467 NINILCHIK, AK 99639 ì #1 ) I"; J J April 24, 2001 i , ¡ ¡ Mr. Rob Stinson Forest Oil Corporation 310 K. Street, Suite 700 Anchorage, Alaska 99501 Dear Mr. Stinson, BJ Services Company, USA welcomes the opportunity to provide Forest Oil Corporation with the attached fracture simulations for the RUD 1 well. As requested simulations have been performed for Sands No's 3, 4 and 5 as a group and for Sand No. 12 as a discreet package. The simulations are based on the treatment parameters and LAS well log data provided by Forest Oil Corporation previously. Each simulation includes a total volume of 1,000,000 gallons (23,810 bbls) of a 10.5 ,ppg fluid system transporting 5 ppg 100 mesh sand at a pump rate of 5 bpm. The resulting simulator output data shows the injected fluids to be fully contained within the sand packages described above. For you review you will find output data in numeric and plot formats. \ . I BJ Services Company is proud to offer Forest Oil Corporation the highest quality products and services currently available in the oil and gas industry. We have enjoyed an excellent business relationship with Forest Oil in the past and we look forward to a continued success. Should you ,have ~ny q:U~$tj911S concerning t.h~ il1fQQ11ªtion cli~cµs$ed in thi,sJetter or any of our products and services please contact me at our Pacific Region Office (907) 349-6518. 1 I ì/ctfuIlY, . :6~¿b --- BJ~~Ø1COMPANY, U.S.A. Corporate Account Manager cc: Internal Customer Distribution ... ""A"1\~~~::t L;li . ,,\''\Jj:t <'h'._L \:......) ~~ I\:.' \ '~". 0:: ') p r,' I BJ Services Company, U.S.A. · 6927 Old Seward Hwy., Suite 105 · Anchorage, AK 99518 Office: (907) 349-6518 · Fax: (907) 349-1486 ) ], J ) ) .I FracproPT10.0 . Hydraulic Fracture Analysis' -Date: Wellname: Location: Formatting: Job Date: Filename: April 24, 2001 Redoubt Unit#1 Cook Inlet Basin, Alaska. Sand#3,#4,#5 4/18/2001 12:44:44 PM Ru-1-345 , ¡ Fracture Half-Length (ft) Total Fracture Height (ft) Depth to Fracture Top (ft) Depth to Fracture Bottom (ft) Equivalent Number of Multiple Fracs Fracture Slurry Efficiency Fracture Geometry Summary o ,Propped Half-Length (ft) o Total Propped Height (ft) 3784 Max. Fracture Width (in) 3784 Avg. Fracture Width (in) 1.0 Avg. Proppant Concentration (lb/fP) 0.00 ¡ , All values reported are for a single fracture Model has run until 5849.00 min Fracture Conductivity Summary Dimensionless Conductivity Proppant Damage Factor ,I All values reported are for a single fracture 0.00 Ref. Formation Permeability (mD) 0.50 Proppant Permeability (n,D) Modëf'NefPressUre"{psir' Observed Net Pressure (psi) Hydrostatic Head (psi) Fracture Pressure Summary -530 BHFracture'elosureS,tress·(ps~) o 'Closure Stress Gradient ,(psi/ft) 2474 Suñace Pressure (psi) . ! Averages reported during Main Frac Fracture Geometry Summary Total Clean Fluid Pumped (bbls) 29184 Total Proppant Pumped (klbs) Total Slurry Pumped (bbls) 29184 Total Proppant in Fracture (klbs) Pad Volume (bbls) 0 Avg. Hydraulic Horsepower (hp) Pad Fraction (%) 0 Max. Hydraulic Horsepower (hp) Main Fluid DISPOSAL Main Proppant FLUID 0:; Averages reported during Main Frac FracproPTIO.O ~f'-'/\\ì\F¡,ö:e:\) llii 0jÎ\~ ? b) ?nDi~ t ~.t}-':¡', _ hH.:~,,, ,H. ~\. " (~~ ,_. .f o o 0.01 0.01 0.00 1000.0 20000 -2748- 0.726 o 5000.9 0.0 117 38176 100-Mesh 1 C:\JBG Documents\Ru-I-345 · ,¡ . ,/ · '., ¡ . , : i j I ! ,] , j I · I I·- . ¡ ') ) Stage # Concentration of Proppant in Fracture (lb/ft2) Length UpperHt LowerHt Upper Cone (ft) (ft) (ft), (1b/W) 54.6 54.6 54.6 0.00 Lower Cone (Ib/fP) Q.OO 1 Fracture Conductivity (mC-ft) Stage # Length (ft) 54.6 LowerHt (ft) 54.6 Lower Cond (mD·ft) 0.00 Upper Cond (mO·ft) 0.00 UpperHt (ft) 54.6 1 Treatment Schedule Stage Elapsed Fluid Clean Prop Stage Slurry Proppant # Time Type Volume Cone. Prop. Rate Type min.sec (kgal) (ppg) (klbs) (bpm) Wellbore Fluid DISPOSAL 3.0 FLUID 1 5838:39 DISPOSAL 1000.0 5.00 5000.0 5.00 1 aD-Mesh FLUID 2 5848:39 SHUT-IN 0.0 0.00 0.0 0.00 Scheduled clean vol (kgal) Scheduled slurry vol (kgal) 1000.00 1226.12 Scheduled sand total (klbs) 5000.00 SCA~NE[; JUN 2 ~3 200¿~ FracproPflO.O 2 C:\JBG Documents\Ru-I-345 ·:.) I ' 1 I , I . I ! ! ) All Fluid info is at a reservoir temperature of 140.0 eF) All Viscosities at Shear Rate of 511 (1/sec) Fluid Parameters Fluid Name DISPOSAL FLUID Initial Rheology Viscosity n- k- Rheology ~ 4.0 hours Viscosity n- k- Gel Density Spurt Loss Wall Building Flowrate #1 Fric Press #1 Flowrate #2 Fric Press #2 Flowrate #3 Fric Press #3 WB Fric Mult 1.01 1.000 2.100e-05 1.01 1.000 2.100e-05 1.25 0.0 0.0 10.00 17.66 20.00 64.11 40.00 232.7 0.100 ) Wellbore Friction pressures shown are the interpolated values multiplied by the Wellbore Friction Multiplier. Viscosity Îsdispraÿed iñ(ëp) K' is displayed in (lbf·s^n/ft2) Gel Density is displayed as (sg) Spurt Loss is displayed iri (gal/ft2) Wall Building is displayed in (ftIminY2) Friction pressure is displayed in (psi/1000 ft.) Flowrate is displayed in (bpm) Friction is displayed for longest well bore segment FracproPfIO.O .~)~ C /.'{ vý,' ~~¡.; F ~~\ ! \ -...,"_. "J 5 9) ~~'n¡¡ ': C:\JBG Documents\Ru-I-345 ,/ ) ) -,1 ' ¡ ì ', leakoffParameters Reservoir type Filtrate to reservoir fluid perm. ratio, KplKl Reservoir pore pressure (psi) Initial fracturing pressure (psi) Reservoir fluid compressibility (1/psi) Cold filtrate viscosity (cp) Hot filtrate viscosity (cp) Cold reservoir viscosity (cp) Hot reservoir viscosity (cp) , Porosity Gas Leakoff Percentage Gas 1.0 1646 3248 6..o8e-.o.o4 1..0.0 1..0.0 .0..03 .0..03 .0.1.0 1.0.0..0.0 Reservoir Parameters Reservoir temperature eF) Depth to center of Perfs (ft) Perforated interval (ft) Initial frac depth (ft) 14.0 ..0.0 3784 162 3784 Layer Parameters Layer # Top of Stress Top of Young's Poisson's Top of Total Ct PoreFluid zone (psi) zone modulus ratio zone (ftImin%) perm. (ft) (ft) (psi) (ft) (md) 1 .0..0 1278 .0..0 2..oe+.o.o6 .0.2.0 .0..0 1.812e-.o.o1 1..o.oe+.o.o3 2 18.0.0..0 2155 18.0.0..0 5..oe+.o.o6 .0.25 18.0.0. .0 5.73.oe-.o.o4 1..o.oe-.o.o2 3 3269.8 2396 3269.8 2..oe+.o.o6 .0.2.0 3269.8 1.812e-.o.o1 1. .o.oe+.o.o3 4 3478.8 3.0.04 3478.8 5..oe+.o.o6 .0.25 3478.8 5.73.oe-.o.o4 1..o.oe-.o.o2 ì 5 3589.7 2748 3589.7 2..oe+.o.o6 .0.2.0 3589.7 1.812e-.o.o1 1..o.oe+.o03 I , 6' 4t50~2 3545 41"59~2 . .s~Oe+OO6 0.,25 415.0.2 -- 5.73Qe~O.o4.. .'. ,j.o.o.e~OO2,. [ 7 4191.6 3.0.08 4191.6 2..oe+O.o6 .0.2.0 4191.6 1.812e-.o01 1.0.oe+003 8 4281.6 3683 4281.6 5..oe+O.o6 .0.25 4281.6 5.730e-.o.o4 1.0.oe-.o.o2 I 9 4384.6 3248 4384.6 2..oe+.o.o6 .0.2.0 4384.6 1.812e-.o.o1 1.0.oe+.o.o3 10 4763.5 4196 4763.5 5..oe+.o.o6 .0.25 4763.5 5.73.oe-.o04 1..o.oe-.o.o2 11 51.08.6 3645 51.08.6 2..oe+.o.o6 .0.2.0 51.08.6 1.812e-.o.o1 1.0.oe+.o03 12 5158.6 4473 5158.6 5..oe+.o.o6 .0.25 5158.6 5.73.oe-.o.o4 1.0.oe-.o.o2 13 5366.8 3894 5366.8 2..oe+.o.o6 .0.2.0 5366.8 1.812e-.o.o1 1.0.oe+.o03 14 56.01.4 48.06 56.01.4 5..oe+.o.o6 0.25 56.01.4 5.73.oe-.o.o4 1.0.oe-.o.o2 15 57.07..0 4.091 57.07..0 2..oe+.o.o6 .0.2.0 57.07.0 1.812e-.o.o1 1..o.oe+.o03 16 5818.2 4945 5818.2 5..oe+.o.o6 .0.25 5818.2 5.73.oe-.o.o4 1. .o.oe-O.o2 \~ ((' ~. r' -, I ~ ; '!\~ ". J] " 1 " I I " FracproPfIO.O 6 C:\JBG Documents\Ru-I-345 I ) ) - -, Lithology Parameters Layer # Top of Lithology Top of Fracture Top of Tip zone zone Toughness zone Effects (ft) (ft) (psi-inYz) (ft) Factor 1 0.0 Sandstone 0.0 1000 0.0 1.00 2 1800.0 Coal/Clystne 1800.0 1000 1800.0 1.00 ¡ 3 3269.8 Sandstone 3269.8 1000 3269.8 1.00- I 4 3478.8 Coal/Clystne 3478.8 1000 3478.8 1.00 5 3589.7 Sandstone 3589.7 1000 3589.7 1.00 6 4150.2 Coal/Clystne 4150.2 1000 4150.2 1.00 7 4191.6 Sandstone 4191.6 1000 4191.6 1.00 8 4281.6 Coal/Clystne 4281.6 1000 4281.6 1.00' 9 4384.6 Sandstone 4384.6 1000 4384.6 1.00 10 4763.5 CoallClystne 4763.5 1000 4763.5 1.00 11 5108.6 Sandstone 5108.6 1000 5108.6 1.00 12 5158.6 CoallClystne 5158.6 1000 5158.6 1.00 13 5366.8 Sandstone 5366.8 1000 5366.8 1.00 14 5601.4 Coal/Clystne 5601.4 1000 5601.4 1.00 15 5707.0 Sandstone 5707.0 1000 5707.0 1.00 16 5818.2 Coal/Clystne 5818.2 1000 5818.2 1.00 SCi,AN,\jEf., JUN ~,~ ~.\: ?PíI:,¡ FracproPflO.O 5 C:\JBG Documents\Ru-1-345 ) ) Wellbore Configuration . ; Segment Segment Tubing ID. Tubing OD Casing ID ¡ Length Type (in) (in) (in) (ft) 3320 Tubing 2.992 0.000 0.000 931 Casing 0.000 0.000 6.875 Tubular Goods are defined to the TOP of the deepest set of perforations that are being modeled. Top of Peds - TVD (ft) Bot of Peñs - TVD (ft) Perf Diameter (in) # of Peñs Frac #1 3702 3865 0.330 600 Near Well bore Friction Parameters & Perf "" -.- - - Time Flow Rate Flow Rate Delta P Peñ Coeff (min:sec) #1 #2 (psi) Multiplier (bpm) (bpm) 0:00 0.00 0.00 0.00 1.00 S(;;~\ J'\i ¡'H~: T_ J ¡\: ~, :-; ) fir: i FracproPTIO.O 6 C:\JBG Documents\Ru-I-345 3740 g :6 3770 Q. Q) Q 3800 ,':(':- f ~~' ~ z m -~ ..... . ...~J I:; ....;J --, 3950 2CXX) : : I ! I I I I I ¡ I I I -----t----t~---l----_r----r----t----i----- I I I I I I I I I I ~ I I I -~---~----+----~----~----~----+----~----- I I I I I I I I I ~ I I I -----t----i----1---- ~~---t----1----- I I I : I I I -----t----¡----¡----1ì----t----t----¡----- I I I ¡ I I I I I I II I -----L----~____~__________L_,___~____J_____ -----l----l----J--------~---l----j----- I I I I I I I I I I I I I I I I I -----~----+----~----------~----+----~----- I 1 I I I I I I I I I I I I I I I I I I I I I I -----T----ì----,----------í----T----ì----- I I I I I I I I I I I I I I I I I I -----r----+----~----------r----+----,----- I I I I I I I I I I I I I I I I I I I I I I I I 400J 150 113 75 38 0 38 75 113 150 Propped Length (ft) Hydraulic Length (ft) Stress Profile 3650 3680 - 3710 3830 3800 3890 3920 - 2500 3CXX) 35CX) Closure Stress (psi) . 0" ______.. Redoubt Unit#1 ----- -- Log View Sands 1, 2 & 3 TVD, ft Rocktype Stress (psi) 1000 ! I ç.) " >" -:.~ L \T\ ~ -~-' Modulus (psi) Pore Permeability (mD) (ni 5000 2e+006 Se+o06 0.01 1000 '-' --- ~ ~..~.,..,··..·.··..·.··..·..·.·...........·."i.,.··....~.....,., ~~ ~'<"'>'~:{"::""':<'.":":~::::>'~'<':':<:< , ~I I I 'I .. I .1 :¡ ì I . I j ¡ -.. ) ) FracproPT10.0 Hydraulic Fracture Analysis Date: Wellname: Location: Formatting: Job Date: Filename: April 24, 2001 ' Redoubt Unit#1 Cook Inlet Basin, Alaska. Sand#12 4/18/2001 12:44:44 PM Ru-1-12 Fracture Half-Length (ft) :r otal Fracture Height (ft) . pepth to Fracture Top (ft) Depth to Fracture Bottom (ft) Equivalent Number of Multiple Fracs Fracture Slurry Efficiency Fracture Geometry Summary o Propped Half-Length (ft) o Total Propped Height (ft) 5477 Max. Fraçture Width (in) 5477 Avg. Fracture Width (in) 1.0 Avg. Proppant Concentration (lb/ft2) 0.00 All values reported are for a single fracture Model has run until 5849.00 min Fracture Conductivity Summary Dimensionless Conductivity Proppant Damage Factor All values reported are for a single fracture 0.00 Ref. Formation Permeability (mD) 0.50 Proppant Permeability (mD) Model Net Pressure (psi) Observed Net Pressure (psi) Hydrostatic Head (psi) Fracture Pressure Summary .- ';'744' BKFtaetore-CtGsure'Stress'(psi} o Closure Stress Gradient (psi/ft) 3581, Suñace Pressure (psi) Averages reported during Main Frac Fracture Geometry Summary Total Clean Fluid Pumped (bbls) 29185 Total Proppant Pumped (klbs) Total Slurry Pumped (bbls) 29185 Total Propp ant in Fracture (klbs) Pad Volume (bbls) 0 Avg. Hydraulic Horsepower (hp) Pad Fraction (%) 0 Max. Hydraulic Horsepower (hp) Main Fluid DISPOSAL Main Proppant FLUID Averages reported during Main Frac FracproPTIO.O §(;A,lNNË[ JUN ~" 3 2['\(1/) o o 0.01 0.01 0.00 1 000.0 20000 ·3894, 0.711 o 5000.9 0.0 48 102 100-Mesh 1 C:\JBG Documents\Ru-I-12 ';':1 .:j ) 1 ! . i Stage # 1 Concentration of Proppant in Fracture (lb/ft2) Length UpperHt LowerHt Upper Cone (ft) (ft) (ft) (lb/ft2) 54.8 54.8 54.8 0.00 Lower Cone (lb/ft2) 0.00 - 1 ! Fracture Conductivity (mD-ft) 1 Length (ft) 54.8 UpperHt (ft) 54.8 LowerHt (ft) 54.8 Upper Cond (mD·ft) 0.00 Lower Cond (mD·ft) 0.00 . [ ! Stage # ..¡ j Treatment Schedule Stage Elapsed Fluid Clean Prop Stage Slurry # Time Type Volume Cone. Prop. Rate min.see (kgal) (ppg) (klbs) (bpm) Wellbore Fluid DISPOSAL 7.2 FLUID 1 5838:39 DISPOSAL 1000.0 5.00 5000.0 5.00 FLUID 2 5848:39 SHUT-IN 0.0 0.00 0.0 0.00 Proppant Type 1 DO-Mesh Scheduled clean vol (kgal) Scheduled slurry vol (kgal) 1000.00 1226.12 Scheduled sand total (klbs) 5000.00 .... ... - n_. ,,~. ,~ . S(,;b¡ !~J ~~ E::, ~) :.~ 'Hi It .'~ "I ¡ FracproPTIO.O 2 C:\JBG Documents\Ru-1-12 I j ,1 ) All Fluid info is at a reservoir temperature of 140.0 eF) An Viscosities at Shear Rate of 511 (1/sec) I I Fluid Name Fluid Parameters Initial Rheology Viscosity n' k' Rheology @ 4.0 hours Viscosity n' k' Gel Density Spurt Loss Wall Building Flowrate #1 Fric Press #1 Flowrate #2 Fric Press #2 Flowrate #3 Fric Press #3 we Fric Mult i , I i i .. ! DISPOSAL FLUID 1.01 1.000 2.100e-05 1.01 1.000 2.100e-05 1.25 0.0 0.0 10.00 17.66 20.00 64.11 40.00 232.7 0.100 ,) Well bore Friction pressures shown are the interpolated values multiplied by the Wellbore Friction Multiplier. . Vrscösì£yìs dìsprãÿedin(cp) K' is displayed in (lbf·s^n/ft.2) Gel Density is displayed as (sg) Spurt Loss is displayed in (gallft2) Wall Building is displayed in (ftImin'%) Friction pressure is displayed in (psi/1000 ft.) Flowrate is displayed in (bpm) Friction is displayed for longest wellbore segment FracproPTIO.O SC,~\N\jE~.~ JUN ~? :.¡ ?f) (~'! 3 C:\JBG Documents\Ru-I-12 ) " I' J ì leakoffParameters ! .) Reservoir type Gas :: I Filtrate to reservoir fluid perm. ratio, KplKl 10 Reservoir pore pressure (psi) 2383· Initial fracturing pressure (psi) 4394 . ) Reservoir fluid compressibility (1/psi) 4.20e-004 I : ! Cold filtrate viscosity (cp) 1.00 Hot filtrate viscosity (cp) 1.00 ) Cold reservoir viscosity (cp) 0.03 I Hot reservoir viscosity (cp) 0.03 Porosity 0.10 Gas Leakoff Percentage 100.00 Reservoir Parameters Reservoir temperature eF) 140.00 Depth to center of Perfs (ft) 5477 Perforated interval (ft) 84 Initial frac depth (ft) 5477 Layer Parameters Layer # Top of Stress Top of Young's Poisson's Top of Total Ct PoreFluid zone (psi) zone modulus ratio zone (ftlminYz) perm. (ft) (ft) (psi) (ft) (md) 1 0.0 1278 0.0 2.0e+006 0.20 0.0 2.025e-001 1.00e+003 2 1800.0 1825 1800.0 3.0e+005 0.45 1800.0 2.025e-001 1.00e+003 3 3269.8 2396 3269.8 2.0e+006 0.20 3269.8 2.025e-001 1 .00e+003 4 3478.8 3004 3478.8 5.0e+006 0.25 3478.8 6.404e-004 1 .00e-002 5 3589.7 2748 3589.7 2.0e+006 0.20 3589.7 2.025e-001 1.00e+003 6 '-4f50~2 . '. '3545' '4150";2 ' ···-S-.'o-e-ofõOð6 ,. - 0:'25- 4150.2 - 6~404e-004' ., 1'.OOe-002 7 4191.6 3008 4191.6 2.0e+006 0.20 4191.6 2.025e-001 1.00e+003 8 4281.6 ' 3683 4281.6 5.0e+006 0.25 4281.6 6.404e-004 1 .00e-002 9 4384.6 3248 4384.6 2.0e+006 0.20 4384.6 2. 025e-00 1 1.00e+003 10 4763.5 4196 4763.5 5.0e+006 0.25 4763.5 6.404e-004 1.00e-002 11 5108.6 3645 5108.6 2.0e+006 0.20 5108.6 2.025e-001 1.00e+003 I 12 5158.6 4473 5158.6 5.0e+006 0.25 5158.6 6.404e-004 1.00e-002 ; ¡ 13 5366.8 3894 5366.8 2.0e+006 0.20 5366.8 2. 025e-00 1 1.00e+003 , .I 14 5601.4 4806 . 5601.4 5.0e+006 0.25 5601.4 6.404e-004 1.00e-002 15 5707.0 4091 5707.0 2.0e+006 0.20 5707.0 2.025e-001 1.00e+003 16 5818.2 4945 5818.2 5.0e+006 0.25 5818.2 6.404e-004 1 .00e-002 SCl\N~\]f.l~ UI\: ~ '? 7(11'1',' FracproPTIO.O 4 C:\JBG Documents\Ru-I-12 · '\ ) ) I I '.',¡ I I Lithology Parameters Layer # . Top of Lithology Top of Fracture Top of Tip· . zone zone Toughness zone Effects (ft) (ft) (psi·in~) (ft) Factor 1 0.0 Sandstone 0.0 1000 0.0 1.00 2 1800.0 Bitum Coal 1800.0 500 1800.0 1.00 i 3 3269.8 Sandstone 3269.8 1000 3269.8 1.00 ¡ 4 3478.8 CoallClystne 3478.8 1000 3478.8 1.00 5 3589.7 Sandstone 3589.7 1000 3589.7 1.00 6 4150.2 CoallClystne 4150.2 1000 4150.2 1.00 7 4191.6 Sandstone 4191.6 1000 4191.6 1.00 8 4281.6 CoallClystne 4281.6 1000 4281.6 1.00 9 4384.6 Sandstone 4384.6 1000 4384.6 1.00 10 4763.5 CoallClystne 4763.5 1000 4763.5 1.00 11 5108.6 Sandstone 5108.6 1000 5108.6 1.00 12 5158.6 Coal/Clystne 5158.6 1000 5158.6 1.00 13 5366.8 Sandstone 5366.8 1000 5366.8 1.00 14 5601.4 Coal/Clystne 5601.4 1000 5601 .4 1.00 15 5707.0 Sandstone 5707.0 1000 5707.0 1.00 16 5818.2 Coal/Clystne 5818.2 1000 5818.2 1.00 i i , .1 SC/\f\'h'Ef .HJN ?, .~ } Ql.1 !; FracproPTIO.O 5 C:\JBG Documents\Ru-I-12 ) ) '\ ! Wellbore Configuration Segment Segment Tubing ID Tubing OD Casing ID Length Type (in) (in) (in) (ft) 3320 . Tubing 2.992 0.000 0.000 3085 Casing 0.000 0.000 6.875 Tubular Goods are defined to the TOP of the deepest set of perforations that are being modeled. Top of Peñs - TVD (ft) Bot of Perfs - TVD (ft) Peri Diameter (in) # of Peñs Frac #1 5435 5519 0.330 600 Near Wellbore Friction Parameters & Peri . Time Flow Rate Flow Rate Delta P Pert Coeff (min:sec) #1 #2 (psi) Multiplier (bpm) (bpm) 0:00 0.00 0.00 0.00 1.00 FracproPTl o. 0 6 \(' _: , ' '. C:\JBG Documents\Ru-1-12 C}IC.r\NNEL HJ}¡¡ ? ~~ ?DO 1 t.._H ,,,J 0"",14 '-f I I I I I I I I I ¡ I I I -~---~----+----~----~----~----+----~----- I I I ~ I I I I I I ~ I I I I I I I I I I, -----~----+----~----~----~----+----~----- I I I I I I I I I I ~ I I I I I I ~ I I I I I I ~ I I I -----T----T----¡----¡r----r----T----ì----- I I I 1; I I I -----L----l----J---- ~L----l----J----- I I I i I' I I I I I I I - I I I I I I I I -----r----I----1-----~i----i----I--~-- I I I I I I -~---I----Î----Î----------I----Î----I----- I I I I I I I I I I I I I I I I -----~----+----~----------~----+----4----- I I I I I I I I I I I I I I I I I I I I I I I I -~---T----T----Î----------í----T----ì----- I I I I I I I I I I I I I I l I I I -----r----+----~----------r----+----,----- I I I 1.1 1 I I I I I I I I I I I I I eoco 250' 188 125 63 0 63 125 1S8 250 Propped Length (ft) Hydraulic Length (ft) '-- Redoubt Unit#1 3750 4SOO 5250 Closure Stress (psi) Stress Profile 5750 3CXX) ~ f"...) c::J 5700 - Z ::;.<~ f._ 1'""= '25650 (iJj 5550 P .....--;....",' .;;; 2 Z rn56CX) t'i 5400 g ~ ã. 54SO Q) 0 5500 5350 5300 5250 5440 g :[ 5470 Q) 0 ~5500 r(; "-. op'~ ~ ž PC "'- C :2:: 55ðJ ~ '~L~ !"'0 C) 5590 c::J ~~;;» Stress Profile Redoubt Unit#1 5360 I I I r I I I I I I ~ I I I I I I ! I I I -~---}----+----~----~----~----+----~----- I I I ~ I I I I I I { I I I I I I I I I I -----~----+----~----4r----~----+----~----- I I I r I I I I I I r I I I -----t----t----~---- i --~---t----i----- I I I r I I I I I I ¡ I I I -----T----+----~----~----r----+----,----- I I I I I I I I I I I I I I I I I I -----r----1----1--------~--1----1----- -----¡----î----,------ --,----j----,----- I I I I I I I I I I I I I I I I I I -----~----+----~----------~----+----4----- I I I I I I I I I I I I I I I I I I I I I I I I -----T----i----¡----------r----T----ì----- I I I I I '1'-""', :> ';-;.- .,':....(,\:.- , I I I I I I I ' - 'r' -- ,.', _ - I I I I I I : -U~/;\~;~;;tt;;i;;~ -----r----r----l----------r----r--~-l----- 3CXXJ 3750 45CX) 5250 &XX> 150' 113 75 36 0 38 75 113 150 Closure Stress (psi) Propped Length (ft) Hydraulic Length (ft) 5380 ~/- 5410 S530 ---- .: ¡ ~ ;1 3-D WellboreVie'\V . ) ) .. :/1 ] ,\ .\ ¡ !' ì ¡ ',I ;\ o'J; ')nn,l\ __ ~ Il , Î.\', '(.J, C) L \.II.., " Ih..-- r' fi} N í\! t: t~ ~. -"!, ....,_.·,-ylr" ~