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Home My WebLink AboutDIO 016 Image" .bject Well History File C"Jer 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. ~ J 0 - 0 1 (r¿ Well History File Identifier Organizing (done) o Two-sided 1111111111111111111 D Rescan Needed 1 RESCAN DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Color Items: D Greyscale Items: D Poor Quality Originals: D Diskettes, No. D Other, No/Type: Scanning Preparation BY: Helen ~ x 30 = + OVERSIZED (Non-Scannable) ~s of various kinds: ~ D Other:: Date: 7 á/, OS Isl W 1 - Date: 7 ::LI n..s-/s/M P . = TOTAL PAGES J 0 J- (Count do~s not "nclude cover sheet) al1A ¿) Date: 7 :J-J (Os- Isl V r v, . I 1 I D Other: NOTES: BY: Helen C Maria) Project Proofing BY: Helen,-~ Production Scanning Stage 1 Page Count from Scanned File: I 0 3 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES NO Helen ~ Date: 7, ,;)",,1, oSlSI vvtP If NO in stage 1 page(s) discrepancies were found: YES NO BY: Stage 1 BY: Helen Maria Date: Isl 11I.1111111 Jill 11111 11I1111111111111111 111- Date: 151 Quality Checked 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: • • INDEX Disposal Injection Order 16 West McArthur River Unit 4D 1. June 10, 1998 2. September 2, 1998 3. June 18, 1998 4. September 27, 2004 5. October 14, 2004 6. October 15, 2004 7. October 19, 2004 8. June 17, 2005 9. November 18, 2005 10. November 23, 2005 11. February O1, 2007 12. March 15, 2007 13. May 7, 2008 14. March 9, 2009 Forcenergy Application for Disposal Injection Order West McArthur River Unit #4(d) Forcenergy letter clarifying cementing information and MIT II Notice of Hearing, Affidavit of publication, e-mail Distribution list, bulk mailing Proposals to Amend Underground Injection Orders to Incorporate Consistent Language Addressing the Mechanical Integrity of Wells Request for Administrative Approval to Inject Alternative Fluids WMRU 4D and DIO No. 16 e-mail from Forest to AOGCC Operators response to DI O 16.1 e-mail from Forest Oil and AOGCC re: WMRU 4D Forest Oil Corp request the authorized injection interval Monthly Water Injection Report Forest Oil Corp Notification of Conversion of Class II Disposal Wells to Class I Wells EPA ltr re: Final approval to inject into UIC Class I West McArthur River Unit #4D Well, EPA UIC Permit No. AK-1107-A Pacific Energy Resources request to rescind Order Pacific Energy Resources, Ltd. Filing of Chapter 11 Restructuring Disposal Injection Order 16 . . State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: THE REQUEST OF FORCENERGY, INC. for an order allowing the disposal of Class II fluids by underground injection in the West McArthur River Unit 40 well ) Disposal Injection Order No. 16 ) ) West McArthur River 40 well ) West McArthur River Unit September 3, 1998 IT APPEARING THAT: 1. By correspondence dated June 12, 1998, Forcenergy, Inc. requested authorization from the Alaska Oil and Gas Conservation Commission to inject Class II waste fluids into the West McArthur River Unit ("WMRU") 40 well. 2. The Commission published notice of an opportunity for public hearing in the Anchorage Daily News on June 18, 1998. 3. The Commission did not receive protest or a request for a public hearing. FINDINGS: 1. Forcenergy, Inc. is operator of the WMRU 2. The Cook Inlet Region, Inc., SalamatofNative Association, Inc., Phillips Petroleum and the State of Alaska are offset owners within a one-quarter mile radius of the WMRU 40 well. Each has been duly notified of the proposed disposal plans. 3. The following wells penetrate the proposed disposal zone within a one-quarter mile radius of the WMRU 40 well: WMRU 0-1, WMRU lA, WMRU 2A, WMRU 3, WMRU 5, and Pan Am West Foreland Unit 2. 4. All the wells listed above were constructed in accordance with 20 AAC 25.030; each well has adequate cement coverage to protect freshwater aquifers. 5. Openhole wireline logs from the West Foreland Unit 2 well, located less than 2500 feet north ofWMRU 40, were used to analyze formation water salinity in the vicinity ofWMRU 40 well. 6. Log data from the West Forelands Unit 2 well was analyzed consistent with recommended practices described in EPA publication "Survey of Methods to Determine Total Dissolved Solids Concentrations" (KEDA Project No. 30-956). 7. Log analyses of the West Forelands Unit 2 well indicate formation water salinity generally increases with depth, and that freshwater (i.e., water with TDS less thanlO,OOO mg/I) is present to a depth of approximately 4000 feet subsea in the vicinity of the WMRU 40 well. 8. The depth to the base of freshwater appears about the same in the WMR U 0-1 disposal well, located about one-mile northwest of the WMRU 40 well. Disposal Injection Ordel. 16 West McArthur River 4D well September 3, 1998 . Page 2 9. Water salinity in the disposal zone is about 20,000 mg/l based upon log analyses from adjacent wells. 10. The proposed disposal zone is within the TyonekFormation between 5743' and 6305' measured depth ("MD") in the WMRU 40 well. It consists of approximately 490 feet of porous and permeable coarse-grained clastic sediments, predominately sandstone in nature. 11. More than 150 feet of tuffaceous claystone, which serves as a confining zone within the Tyonek Formation, lies between the proposed disposal zone and the base of freshwater in the vicinity of the WMRU 40 well. 12. The WMRU 4 well was originally drilled to a depth of 11,875' MD in early 1998. The well was then plugged back and sidetracked to a depth of 6,243' MD and renamed the WMRU 40 well in June 1998. 13. Sidetrack operations involved placing a cement plug from total depth to 9,731' MD, setting a bridge plug at 5,960' MD and kicking out from the original wellbore just below the 9 5/8" shoe, at 5,743' MD and drilling to 6,243' MD. 14. The current WMRU 40 well is constructed with 20" conductor pipe driven to 120' MD, 13 3/8" casing set at 2,265' MD, 9 5/8" casing set at 5,743' MD and 7 5/8" liner set at 6,243' MD. A string of2 7/8" tubing is set at 5,646' MD, and a packer at 5,572' MD. 15. An evaluation of the cement bond logs run in the WMRU 40 indicates good bonding throughout the logged interval from about 4640' MD to about 5630' MD. 16. The estimated average surface injection pressure will be between 3,000 psi and 3,300 psi, with a maximum estimated injection pressure of 4,000 psi. 17. The average anticipated injection rates for drilling fluids is 2,000 to 3,000 barrels per day ("BPD"). Produced water will be injected at rates up to 6,000 BPD. Average annual injected volume is expected to be one to two million barrels. 18. The estimated radius of invasion around the wellbore after 10 years of disposal at 1,500,000 barrels per year was calculated at 630 feet. 19. Waste drilling mud, diluted drilling mud, drill cuttings slurry, completion fluids, produced water and other wastes derived from drilling, completion and production activities are acceptable Class II fluids. 20. Fracture simulation, using rates and pressure exceeding proposed conditions in the WMRU 40 well, indicate that induced fractures would be confined to the disposal zone. 21. The operator plans to monitor the 7 5/8" by 27/8" tubing annulus pressure and report the results monthly on the Monthly Injection Report. 22. A mechanical integrity test is required according to 20 AAC 25.412 prior to the start of disposal. CONCLUSIONS: 1. The approval of disposal injection operations at WMRU 4(0) will not jeopardize correlative rights. 2. Permeable strata which reasonably can be expected to accept injected fluids at pressures less than the fracture pressure of the confining strata are present in the WMRU 40 well between 5743 feet to 6305 feet MD. Disposal Injection Ordel. 16 West McArthur River 4D well September 3, 1998 e Page 3 3. Aquifers below 4000 feet subsea in the WMRU 40 well do not qualify as freshwater. 4. No application for a freshwater aquifer exemption is required for the proposed disposal injection project in the WMRU 4D,Well because the total dissolved solids content for formation fluids exceeds 10,000 mgll within the proposed disposal zone. 5. Adequate confining zones exist above the disposal zone in the WMRU 40 well to prevent disposal fluids from entering overlying freshwaters. 6. Disposal fluids injected at WMRU 40 will consist of Class II waste generated form drilling, completion and production operations. 7. WMRU 40 is constructed in conformance with the requirements of20 AAC 25.412. 8. Well integrity must be demonstrated in accordance with 20 AAC 25.412 prior to initiation of disposal operations in WMRU 40. 9. Routinely monitoring operational parameters at the WMRU 4(0) for indications of abnormal operating conditions will help insure that disposed fluids remain confined to the disposal zone. 10. Disposal injection operations in the WMRU 40 well will be conducted routinely at pressures less than the disposal zone parting pressure. NOW, THEREFORE, IT IS ORDERED THAT: Rule 1 Authorized Iniection Strata for Disposal Class II fluids may be injected in conformance with 20 AAC 25 for the purpose of disposal into the Tyonek Formation interval between the measured depths of 5743 feet and 6305 feet in WMRU 40 well. Rule 2 Demonstration of Tubing-Casing Annulus Mechanical Integrity A schedule must be developed and coordinated with the Commission that ensures that the tubing- casing annulus is pressure tested prior to initiating disposal and at least once every four years thereafter. A test surface pressure of 1500 psi or 0.25 psi/ft. multiplied by the vertical depth of the packer, whichever is greater, but not to exceed a hoop stress greater than 70% of the minimum yield strength of the casing to be used. The test pressure must show stabilizing pressure and a decline ofIess than 10% in a thirty-minute period. The Commission must be notified at least twenty-four (24) hours in advance to enable a representative to witness pressure tests. Rule 3 Well Integrity Failure Whenever operating pressure observations or pressure tests indicate pressure communication or leakage of any casing, tubing or packer, the operator must notify the Commission on the first working day following the observation, obtain Commission approval of a plan for corrective action, and obtain Commission approval to continue injection. Rule 4 Step Rate Test Prior to sustained injection the operator shall perform a step rate test to determine a formation fracture gradient and optimum injection pressure. Disposal Injection Ordel. 16 West McArthur River 4D well September 3,1998 . Page 4 Rule 5 Administrative Action Upon request, the Commission may administratively amend any rule stätedabove as long as the operator demonstrates to the Commission's satisfaction that sound engineering practices are maintained and the amendment will not result in an increased risk of fluid movement into a freshwater aquifer. DONE at Anchorage, Alaska and dated September ~~ CamiIlé Oechsli, Commissioner 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 following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the lO-day period. An affected person has 30 days fTom the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30-day period for appeal to Superior Court runs fTom the date on which the re uest is deemed denied i.e., 10th da after the a lication for rehearin was filed. ~ " DRI / MCGRAW HILL RANDALL NOTTINGHAM 24 HARTWELL LEXINGTON MA 02173 OVERSEAS SHIPHOLDING GRP ECON DEPT 1114 AV OF THE AMERICAS NEW YORK NY 10036 ALASKA OFC OF THE GOVERNOR JOHN KATZ STE 518 444 N CAPITOL NW WASHINGTON DC 20001 OIL DAILY CAMP WALSH 1401 NEW YORK AV NW STE 500 WASHINGTON DC 20005 US MIN MGMT SERV CHIEF OCS STATS & INFO 381 ELDEN ST MS 4022 HERNDON VA 20170-4817 - . 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ENERGY ADVISORS MARGARET ALLEN 16775 ADDISON RD, STE 400 DALLAS TX 75248 MOBIL OIL JAMES YOREK POBOX 650232 DALLAS TX 75265-0232 STANDARD AMERICAN OIL CO AL GRIFFITH POBOX 370 GRANBURY TX 76048 SHELL OIL CO J F CORDARO POBOX 2463 HOUSTON TX 77001 e e MOBIL OIL CORP MORRIS CRIM POBOX 290 DALLAS TX 75221 GCA ENERGY ADV RICHARD N FLETCHER 16775 ADDISON RD STE 400 DALLAS TX 75248 JERRY SCHMIDT 4010 SILVERWOOD DR TYLER TX 75701-9339 PRITCHARD & ABBOTT BOYCE B BOLTON PE RPA 4521 S. 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CALVERT POBOX 3128, STE 3915 HOUSTON TX 77253-3128 PHILLIPS PETR CO JOE VOELKER 6330 W LP S RM 492 BELLAIRE TX 77401 e e EXXON CO USA RESERVES COORD RM 1967 POBOX 2180 HOUSTON TX 77252-2180 EXXON CO USA 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 ERICH R. RAMP 6330 W LOOP SOUTH BELLAIRE TX 77401 PHILLIPS PETR CO PARTNERSHIP OPRNS JERRY MERONEK 6330 W LOOP S RM 1132 BELLAIRE TX 77401 TEXACO INC R EWING CLEMONS POBOX 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 AMOCO PROD CO C A WOOD RM 2194 POBOX 800 DENVER CO 80201-0800 C & R INDUSTRIES, INC. 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ANCHORAGE AK 99504-3305 RUSSELL DOUGLASS 6750 TESHLAR DR ANCHORAGE AK 99507 US BUREAU OF LAND MNGMNT ANCHORAGE DIST OFC DICK FOLAND 6881 ABBOTT LOOP RD ANCHORAGE AK 99507 e DEPT OF NATURAL RESOURCES DIV OF OIL & GAS LINDA WESTWICK ROYALTY ACCT SECT 3601 C ST STE 1390 ANCHORAGE AK 99503-5948 DEPT OF NATURAL RESOURCES DIV OF OIL & GAS JIM STOUFFER 3601 C STREET STE 1380 ANCHORAGE AK 99503-5948 ARLEN EHM GEOL CONSLTNT 2420 FOXHALL DR ANCHORAGE AK 99504-3342 STU HIRSH 9630 BASHER DR. ANCHORAGE AK 99507 US BLM AK DIST OFC RESOURCE EVAL GRP ART BONET 6881 ABBOTT LOOP RD ANCHORAGE AK 99507-2899 e THOMAS R MARSHALL JR 1569 BIRCHWOOD ST ANCHORAGE AK 99508 UNIVERSITY OF ALASKA ANCHORAGE INST OF SOCIAL & ECON RESEARCH TERESA HULL 3211 PROVIDENCE DR ANCHORAGE AK 99508 US MIN MGMT SERV AK OCS REGIONAL DIR 949 E 36TH AV RM 110 ANCHORAGE AK 99508-4302 REGIONAL SUPRVISOR, FIELD OPERATNS MINERALS MANAGEMENT SERVICE ALASKA OCS REGION 949 E 36TH AV STE 308 ANCHORAGE AK 99508-4363 US MIN MGMT SERV RESOURCE EVAL JIM SCHERR 949 E 36TH AV RM 603 ANCHORAGE AK 99508-4363 e CASS ARIEY 3108 WENTWORTH ST ANCHORAGE AK 99508 US MIN MGMT SERV RICHARD PRENTKI 949 E 36TH AV ANCHORAGE AK 99508-4302 US MIN MGMT SERV RESOURCE STUDIES AK OCS REGN KIRK W SHERWOOD 949 E 36TH AV RM 603 ANCHORAGE AK 99508-4302 US MIN MGMT SERV LIBRARY 949 E 36TH AV RM 603 ANCHORAGE AK 99508-4363 US MIN MGMT SERV FRANK MILLER 949 E 36TH AV STE 603 ANCHORAGE AK 99508-4363 JOHN MILLER 3445 FORDHAM DR ANCHORAGE AK 99508-4555 TUNDRA TIMES GIL GUITERREZ POBOX 92247 ANCHORAGE AK 99509-2247 GAFO GREENPEACE PAMELA MILLER POBOX 104432 ANCHORAGE AK 99510 BRISTOL ENVIR SERVICES JIM MUNTER POBOX 100320 ANCHORAGE AK 99510-0320 ARCO ALASKA INC JOANN GRUBER ATO 712 POBOX 100360 ANCHORAGE AK 99510-0360 e e USGS - ALASKA SECTION LIBRARY 4200 UNIVERSITY DR ANCHORAGE AK 99508-4667 CIRI NANCY MOSES POBOX 93330 ANCHORAGE AK 99509-3330 ANCHORAGE TIMES BERT TARRANT POBOX 100040 ANCHORAGE AK 99510-0040 ARCO ALASKA INC JENNY KEARNEY ATO 1255 POBOX 100360 ANCHORAGE AK 99510-0360 ARCO ALASKA INC LEGAL DEPT MARK P WORCESTER POBOX 100360 ANCHORAGE AK 99510-0360 ARCO ALASKA INC STEVE BENZLER ATO 1404 POBOX 100360 ANCHORAGE AK 99510-0360 ARCO ALASKA INC MARK MAJOR ATO 1968 POBOX 100360 ANCHORAGE AK 99510-0360 ARCO ALASKA INC SAM DENNIS ATO 1388 POBOX 100360 ANCHORAGE AK 99510-0360 ARCO ALASKA INC SHELIA ANDREWS ATO 1130 PO BOX 100360 ANCHORAGE AK 99510-0360 ARCO ALASKA INC KUP CENTRAL WELLS ST TSTNG WELL ENG TECH NSK 69 POBOX 196105 ANCHORAGE AK 99510-6105 e e ARCO ALASKA INC LIBRARY POBOX 100360 ANCHORAGE AK 99510-0360 ARCO ALASKA INC LAND DEPT JAMES WINEGARNER POBOX 10036 ANCHORAGE AK 99510-0360 ARCO TRANSPORATION AK INC M D KYRIAS ATO 926 POBOX 100360 ANCHORAGE AK 99510-0360 PETROLEUM INFO CORP KRISTEN NELSON POBOX 102278 ANCHORAGE AK 99510-2278 ALYESKA PIPELINE ROSS C. OLIVER, TAPS PLANNER 1835 S BRAGAW ST ANCHORAGE AK 99512 ALYESKA PIPELINE SERV CO PERRY A MARKLEY 1835 S BRAGAW - MS 575 ANCHORAGE AK 99512 ALYESKA PIPELINE SERV CO LEGAL DEPT 1835 S BRAGAW ANCHORAGE AK 99512-0099 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 DAVID CUSATO 600 W 76TH AV #508 ANCHORAGE AK 99518 e e ALYESKA PIPELINE SERV CO CHUCK O'DONNELL 1835 S BRAGAW - MS 530B ANCHORAGE AK 99512 US BUREAU OF LAND MGMT OIL & GAS OPRNS (984) J A DYGAS 222 W 7TH AV #13 ANCHORAGE AK 99513-7599 JWL ENGINEERING JEFF LIPSCOMB 9921 MAIN TREE DR. ANCHORAGE AK 99516-6510 GERALD GANOPOLE CONSULT GEOL 2536 ARLINGTON ANCHORAGE AK 99517-1303 ASRC CONRAD BAGNE 301 ARCTIC SLOPE AV STE 300 ANCHORAGE AK 99518 SCHLUMBERGER DARREN AKLESTAD 1111 E 80TH AV ANCHORAGE AK 99518 OPSTAD & ASSOC ERIK A OPSTAD PROF GEOL POBOX 190754 ANCHORAGE AK 99519 ENSTAR NATURAL GAS CO RICHARD F BARNES PRES POBOX 190288 ANCHORAGE AK 99519-0288 MARATHON OIL CO BRAD PENN POBOX 196168 ANCHORAGE AK 99519-6168 UNOCAL KEVIN TABLER POBOX 196247 ANCHORAGE AK 99519-6247 e e HALLIBURTON ENERGY SERV MARK WEDMAN 6900 ARCTIC BLVD ANCHORAGE AK 99518-2146 JACK 0 HAKKILA POBOX 190083 ANCHORAGE AK 99519-0083 MARATHON OIL CO OPERATIONS SUPT POBOX 196168 ANCHORAGE AK 99519-6168 UNOCAL JANET BOUNDS POBOX 196247 ANCHORAGE AK 99519-6247 EXXON COMPANY USA MARK P EVANS PO BOX 196601 ANCHORAGE AK 99519-6601 " e e BP EXPLORATION (ALASKA) INC MR. DAVIS, ESQ POBOX 196612 MB 13-5 ANCHORAGE AK 99519-6612 BP EXPLORATION (ALASKA) INC BOB WILKS MB 5-3 POBOX 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 SUE MILLER POBOX 196612 M/S LR2-3 ANCHORAGE AK 99519-6612 BP EXPLORATION (ALASKA), INC. MARK BERLINGER MB 8-1 PO BOX 196612 ANCHORAGE AK 99519-6612 AMERICA/CANADIAN STRATIGRPH CO RON BROCKWAY POBOX 242781 ANCHORAGE AK 99524-2781 AMSI/VALLEE 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 DIANA FLECK 18112 MEADOW CRK DR EAGLE RIVER AK 99577 " D 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 RON DOLCHOK POBOX 83 KENAI AK 99611 PHILLIPS PETR J A LANDRUM KENAI REG MGR P 0 DRAWER 66 KENAI AK 99611 PENNY VADLA POBOX 467 NINILCHIK AK 99639 e e PINNACLE STEVE TYLER 20231 REVERE CIRCLE EAGLE RIVER AK 99577 COOK INLET VIGIL JAMES RODERICK POBOX 916 HOMER AK 99603 DOCUMENT SERVICE CO JOHN PARKER POBOX 1137 KENAI AK 99611 KENAI PENINSULA BOROUGH ECONOMIC DEVEL DISTR STAN STEADMAN POBOX 3029 KENAI AK 99611-3029 BELOWICH COAL CONSULTING MICHAEL A BELOWICH HC31 BOX 5157 WASILLA AK 99654 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 UNIV OF ALASKA FAIRBANKS PETR DEVEL LAB DR V A KAMATH 427 DUCKERING FAIRBANKS AK 99701 RICK WAGNER POBOX 60868 FAIRBANKS AK 99706 - e PACE SHEILA DICKSON POBOX 2018 SOLDOTNA AK 99669 ALYESKA PIPELINE SERVICE CO VALDEZ CORP AFFAIRS SANDY MCCLINTOCK POBOX 300 MS/701 VALDEZ AK 99686 VALDEZ VANGUARD EDITOR POBOX 98 VALDEZ AK 99686-0098 NICK STEPOVICH 543 2ND AVE FAIRBANKS AK 99701 JACK HAKKILA POBOX 61604 FAIRBANKS AK 99706-1604 C BURGLIN POBOX 131 FAIRBANKS AK 99707 FRED PRATT POBOX 72981 FAIRBANKS AK 99707-2981 K&K RECYCL INC POBOX 58055 FAIRBANKS AK 99711 RICHARD FINEBERG POBOX 416 ESTER AK 99725 UNIVERSITY OF ALASKA FBKS PETR DEVEL LAB DR AKANNI LAWAL POBOX 755880 FAIRBANKS AK 99775-5880 e e FAIRBANKS DAILY NEWS-MINER KATE RIPLEY POBOX 70710 FAIRBANKS AK 99707 DEPT OF NATURAL RESOURCES DIV OF LAND REG MGR NORTHERN REGION 3700 AIRPORT WAY FAIRBANKS AK 99709-4699 ASRC BILL THOMAS POBOX 129 BARROW AK 99723 UNIV OF ALASKA FBX PETR DEVEL LAB SHIRISH PATIL 437 DICKERING FAIRBANKS AK 99775 SENATOR LOREN LEMAN STATE CAPITOL RM 113 JUNEAU AK 99801-1182 e . DEPT OF ENVIRON CONSERV SPAR CHRIS PACE 410 WILLOUGHBY AV STE 105 JUNEAU AK 99801-1795 SNEA(P) DISTR FRANCE/EUROPE DU SUD/AMERIQUE TOUR ELF CEDEX 45 992078 PARIS LA DE FE FRANCE e ~1r&\1rŒ (ID~ &\~&\~[\&\ . AI1ASIiA. OIL AlU) GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. pH AVENUE, SUITE tOO ANCHORAGE. ALASKA 9950t -3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL NO. DIO 16.001 Mr. Bob Elder HSE Manager Forest Oil Corporation 310 K Street, Suite 700 i\nchorage,AK 99501 Re: Request for Disposal of Mixture of Class II fluids and Non-hazardous Commingled Wastes Dear Mr. Elder: By letter dated October 14,2004, Forest Oil Corporation ("Forest") requested authorization to dispose of non-hazardous wastes, other than those wastes returned from downhole, into West McArthur River Unit (WMRU) 4D, a Class II disposal well. Additional clarification was provided by electronic mail dated October 15,2004. This well is located at the WMRU production facility, and is used in conjunction with a Disposal Waste Management Area for the disposal of wastes associated with exploration, development and production. The specific wastes identified by Forest are a combination of used drilling mud and cuttings from the West Foreland No.2 well currently being drilled by Forest, and fluids from a nearby well plug and abandonment operated by Pelican HilI, including unused brine solution, rig floor wash, cellar water, and cement water (cement returns and potable mix water). Total volume of the commingled fluids is approximately 650 barrels. The brine solution consists of potassium chloride and possibly a small amount of sodium chloride. Both chlorides are not hazardous as defined in 40 CFR 261. Forest provided the Material Safety Data Sheet (MSDS) for potassium chloride. Likewise, potable water used for mixing cement does not exhibit hazardous characteristics. The remaining wastes are exempt from Resource Conservation and Recovery Act Subtitle C hazardous waste regulations, and are eligible for injection into the Class II well. The fluids noted in Forest's request are generated in primary field operations directly associated with oil and gas exploration, development and production activities, and the proper abandonment of wells that have no future utility. The fluids are consistent in composition with materials already authorized under Disposal Injection Order No. 16 and pose no risk of fluid movement into an underground source of drinking water. The underground injection into the Class II disposal well WMRU 4D represents the environmentally preferable option for managing the noted non-hazardous waste stream. The Alaska Oil and Gas Commission ("Commission") also agrees with Forest's interpretation that under guidance provided by the Environmental Protection Agency, a non-hazardous waste commingled with an exempt waste renders the entire waste mixture exempt. The Commission believes that exempt wastes are eligible for disposal into a Class II well. The Commission determines that the mixture of fluids within the WMRU Disposal Waste Management Area, as represented in Forest's request for administrative approval, namely unused brine solution, floor Mr. Bob Elder October 15, 2004 Page 2 of2 e . wash, cellar water, cement water, and used drilling mud and cuttings, are suitable for disposal in the WMRU 4D as proposed. Approval applies only to this specific request and is not intended to provide for a blanket authorization to inject these or similar non-hazardous fluids down other Class II disposal wells. As part of this administrative approval, the Commission requires Forest to provide, in writing, the procedural changes that will improve the waste management practices employed at the WMRU Disposal Waste Management Area. and dated October 15,2004. Original Signed By . (,t l- OAN SEAMOUNT '\ ..¡v' . f\ \ ,1ð-' 'J\ 0'\ '¥-o (0" . 1).0 \i~ oç DanIel T. Seamount, Jr. jt¿ <1" Commissioner, DIG 16.1 e e lof2 lO!l512004 4:06 PM DIG 16.1 e e 20f2 10/15120044:06 PM Citgo Petroleum Corporation PO Box 3758 Tulsa, OK 74136 Kelly Valadez Tesoro Refining and Marketing Co. Supply & Distribution 300 Concord Plaza Drive San Antonio, TX 78216 Jerry Hodgden Hodgden Oil Company 408 18th Street Golden, CO 80401-2433 Kay Munger Munger Oil Information Service, Inc PO Box 45738 Los Angeles, CA 90045-0738 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 James Gibbs PO Box 1597 SOldotna, AK 99669 Richard Wagner PO Box 60868 Fairbanks, AK 99706 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 e Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 Robert Gravely 7681 South Kit Carson Drive Littleton, CO 80122 Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 Samuel Van Vactor Economic Insight Inc. 3004 SW First Ave. Portland, OR 97201 Schlumberger Drilling and Measurements 2525 Gambell Street #400 Anchorage, AK 99503 Ciri Land Department PO Box 93330 Anchorage, AK 99503 Jack Hakkila PO Box 190083 Anchorage, AK 99519 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 SOldotna, AK 99669-2139 Cliff Burglin PO Box 70131 Fairbanks, AK 99707 North Slope Borough PO Box 69 Barrow, AK 99723 e David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 John Levorsen 200 North 3rd Street, #1202 Boise, ID 83702 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle, WA 98119-3960 David Cusato 200 West 34th PMB 411 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Darwin Waldsmith PO Box 39309 Ninilchick, AK 99639 Penny Vadla 399 West Riverview Avenue Soldotna, AK 99669-7714 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 ~~'I itiqþ/ Citgo Petroleum Corporation PO Box 3758 Tulsa, OK 74136 Kelly Valadez Tesoro Refining and Marketing Co. Supply & Distribution 300 Concord Plaza Drive San Antonio, TX 78216 Jerry Hodgden Hodgden Oil Company 408 18th Street Golden, CO 80401-2433 Kay Munger Munger Oil Information Service, Inc PO Box 45738 Los Angeles, CA 90045-0738 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 James Gibbs PO Box 1597 Soldotna, AK 99669 Richard Wagner PO Box 60868 Fairbanks, AK 99706 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 e Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 Robert Gravely 7681 South Kit Carson Drive Littleton, CO 80122 Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 Samuel Van Vactor Economic Insight Inc. 3004 SW First Ave. Portland, OR 97201 Schlumberger Drilling and Measurements 2525 Gambell Street #400 Anchorage, AK 99503 Ciri Land Department PO Box 93330 Anchorage, AK 99503 Jack Hakkila PO Box 190083 Anchorage, AK 99519 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 Cliff Burglin PO Box 70131 Fairbanks, AK 99707 North Slope Borough PO Box 69 Barrow, AK 99723 e David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 John Levorsen 200 North 3rd Street, #1202 Boise, ID 83702 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle, WA 98119-3960 David Cusato 200 West 34th PMB 411 Anchorage, AK 99503 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 · ~],LÆ],Œ lID~ LÆ~LÆ~[{LÆ e\ AI,ASIiA. ORAND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. ]T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-t433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL NO. DIO 16.002 Mr. Ted Kramer Production Manager Forest Oil Corporation 310 K Street, Suite 700 Anchorage, AK 99501 Re: Request to Revise the Authorized Injection Interval DIO 16 West McArthur River Unit #4D (197-234) Dear Mr. Kramer: The Alaska Oil and Gas Conservation Commission ("Commission") grants Forest Oil Company ("Forest") request to amend Disposal Injection Order ("DIO") 16 for West McArthur River Unit #4D ("WMRU #4D" - 197-234). By letter dated November 18, 2005, Forest Oil Corporation ("Forest") requested the Commission amend Disposal Injection Order ("DIO") 1 6 for West McArthur River Unit #4D ("WMRU #4D" - 197-234) to revise the authorized injection interval. Forest requested this revision in order to correct perforation depths originally supplied to the Commission. Discrepancies were discovered when Forest made application to workover the well. Depths actually perforated when the well was completed are not the same as those listed in the Disposal Order application. Rule 5 of DIO 16 allows the Commission to administratively amend any rule"... as long as the operator demonstrates to the Commission's satisfaction that sound engineering practices are maintained and the amendment will not result in an increased risk of fluid movement into a freshwater aquifer." According to DIO 16, the authorized injection interval in WMRV 4D begins at 5,743' measured depth ("md"). This is coincident with the 9-5/8" casing shoe. As originally completed, the 7" liner was perforated from 5,708' - 5,758' as well as in two deeper intervals. In the application, Forest provided an analysis regarding the occurrence of fresh water in the strata penetrated by the well. The Commission found (Finding 7) that fresh water as defined by the VIC regulations did not occur below 4,000' md and it was further determined that the 9-5/8" casing was satisfactorily cemented from the shoe to at least 4,640' md (Finding 15). Although 35' of perforations were shot above the authorized top of the injection interval, this did not compromise the isolation provided by over 1,000' md of cement outside the 9-5/8" casing. Based on the available information, the Commission concludes that revising the authorized injection interval will not increase the risk of fluid movement into fresh water. Mr. Ted Kramer December 7, 2005 Page 2 of2 e e It is therefore ordered that Rule 1 of DIO 16 is amended to read: Rule I Authorized Iniection Strata for Disposal Class II fluids may be injected in conformance with 20 AAC 25 for the purpose of disposal into the Tyonek Formation interval between the measured depths of 5,708 feet and 6,305 feet in the WMRU 4D well. ch rage, Alaska and dated December 7,2005, I and Gas Conservation Commission KF~ Daniel T. Seamount, Jr. Commissioner I~ DI0l6.002 West McArthur River Unit#4D e e ethlefs <sheffield@aoga.org>, arI@conocophillips,com>, g>, P tt faro Krat on. com>, Gary lof2 12/8/20052: 11 PM DI016.002 West McArthur River Unit#4D e e Rogers <gary_rogers@revenue.state.ak.us>, Arthur Copoulos <Art <ken@seco· >, Steve Lambert <salambert@unocaLcom n <susitnahydronow@yahoo.com>, Paul Todd < t> I ..! Content-Type: app i DIOI6.002.pdf! I Content-Encoding: bas 20f2 .us>, Ken enai.com>, 11 Walker 12/8/2005 2: 11 PM 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 e e Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 Robert Gravely 7681 South Kit Carson Drive Littleton, CO 80122 Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 Samuel Van Vactor Economic Insight Inc. 3004 SW First Ave. Portland, OR 97201 Schlumberger Drilling and Measurements 2525 Gambell Street #400 Anchorage, AK 99503 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, ID 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 • • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 CANCELLATION DISPOSAL INJECTION ORDER NO. 16 DISPOSAL INJECTION ORDER NO. 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 Well 4) and Disposal Injection Order 22 (Redoubt Unit Well D 1). 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 i Daniel . Seamount, Jr. CathyrP. Foerster Commissioner oner • • 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 Wertheimer, Ste 100 300 Concord Plaza Drive Ft. Worth, TX 76102-6298 Houston, TX 77056 San Antonio, TX 78216 George Vaught, Jr. Jerry Hodgden Richard Neahring PO Box 13557 Hodgden Oil Company NRG Associates Denver, CO 80201-3557 408 18th Street President Golden, CO 80401-2433 PO Box 1655 Colorado Springs, CO 80901 John Levorsen Michael Parks Mark Wedman 200 North 3rd Street, #1202 Marple's Business Newsletter Halliburton Boise, ID 83702 117 West Mercer St, Ste 200 6900 Arctic Blvd. Seattle, WA 98119-3960 Anchorage, AK 99502 Baker Oil Tools Schlumberger Ciri 4730 Business Park Blvd., #44 Drilling and Measurements Land Department Anchorage, AK 99503 2525 Gambell Street #400 PO Box 93330 Anchorage, AK 99503 Anchorage, AK 99503 Ivan Gillian Jill Schneider Gordon Severson 9649 Musket Bell Cr.#5 US Geological Survey 3201 Westmar Cr. Anchorage, AK 99507 4200 University Dr. Anchorage, AK 99508-4336 Anchorage, AK 99508 Jack Hakkila Darwin Waldsmith James Gibbs PO Box 190083 PO Box 39309 PO Box 1597 Anchorage, AK 99519 Ninilchick, AK 99639 Soldotna, AK 99669 Kenai National Wildlife Refuge Penny Vadla Richard Wagner Refuge Manager 399 West Riverview Avenue PO Box 60868 PO Box 2139 Soldotna, AK 99669-7714 Fairbanks, AK 99706 Soldotna, AK 99669-2139 Cliff Burglin Bernie Karl North Slope Borough PO Box 70131 K&K Recycling Inc. PO Box 69 Fairbanks, AK 99707 PO Box 58055 Barrow, AK 99723 Fairbanks, AK 99711 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 f~ Barrow, AK 99723 /~~ ! ~[~' ~/~o/ ~~' • Page 1 of 1 i Colombie, Jody J (DOA) 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 Lidj i '; '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 ~~ 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 Long Beach, California 90802 Telephone: (562) 628-1526; Fax: (562} 628-1536 Files for Chapter 11 to Facilitate a Restructuring \j\O 1~ 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 Bankruptcy Court that will enable it to continue operating its business in the ordinary course of business. The requested approvals include requests for the authority to make wage and salary payments and continue various benefits for employees. In addition, the Company has negotiated a commitment for $40 million in debtor-in-possession ("DIP") financing. The DIP facility wraps and replaces two of the Company's three asset-based credit facilities and is being provided by the lenders of the two credit facilities that are being replaced. Upon Court approval, the DIP financing combined with the Company's operating revenue will provide sufficient liquidity to fund working capital, meet ongoing obligations and ensure that normal operations continue without interruption during its restructuring. About Pacific Energy Resources Pacific Energy Resources Ltd. is an oil and gas exploration and production company based in Long Beach, California, U.S.A. Additional information relating to the Company may be found on SEDAR at www.sedar.com. The Company's web site is www.PacEnergy.com. ON BEHALF OF THE BOARD OF DIRECTORS U PACIFIC ENERGY RESOURCES LTD. Pacific Energy Resources l.td. 310 K. Street, Suite 700 fl.nchara~e, .AK 99507 Office: 907-2~8-8600 Fa.~: 907-258-8601 David I~a~l Alaska Operations ~l~lunager Main: '907-868-2133 Cell: 907-317-8239 d mh al l~pace nerav. c om ~v~vw.~acenerw.com X13 PACIFIC ENERGY RESOURCES, LTD. 310KStreet, Suite 700 Anchorage, AK 99501 Phone: (907) 258-8600 • Fax: (907) 258-8601 May 7, 2008 ~ ~ v ~ ~ ~~ MAY ! ,2 [~G~~ Mr. Dan Seamount, Chair Alaska Oil and Gas Conservation Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Alaska Oil & Gas Cons. Commission Anchorage 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, /,' cam,.:,-~ ~c~/~~-~-c , David Hall Alaska Operations Manager Pack Energy Resources Ltd. Pacific Energy Resources Ltd., 111 West Ocean Blvd ,Suite 1240, Long Beach, CA 90802 Ph: 56228-1526 Fax: 562-628-1536 #12 .#ØJ ~,.~ f&~ - w i ~ ~~ ~ð 'f£ PRO~C. .~ UNITED STATES ENVIRONMENTAL PROTECTION AGENCY REGION 10 1200 Sixth Avenue Seattle, Washington 98101 1 5 MAR 2007 ~ R~ply To Attn Of: OCE-127 , . CERTIFIED l\'IAIL . RETURN RECEIPT REQUESTED Mr. Robert Elder Forest Oil CorporationlFOREST Health, Safety and En vironment Manager 310 K Street, Suite 700 Anchorage, Alaska 99501 t:P:"o Ib ~ ~<t1- ¡~ 7 '- 2.34- Re: Final Approval to Inject into VIC Class I West MacArthur River Unit #4D Well, EPA VIC Permit No. AK-1I007-A Dear Mr. Elder: The United States Environmental Protection Agency (EPA) Region.10 has witnessed the mechanical integrity tests (MIT) conducted on Forest Oil Corporation's (FOREST) West MacArthur River Unit (WMRU) #4D Class I well and FOREST operations. On March 13,2007, EPA received your report confinning the success of the tests. EP A concurs with your findings. Based on your report and the observations by Thor Cutler and Talib Syed, EPA grants final approval to inject under EPA urc Permit No. AK-1I007-A at FOREST WMRU #4D Class r well. This document authorizes the referenced facility to inject to the subsurface as indicated in the pennit. We appreciate the cooperation of your staff during the planning, permitting, testing, and operating phases of the well that serves as an example in leadership for industry in environmental management of waste in the exploration and production field under harsh, sensitive environments. Please call Thor Cutler of my staff at (206) 553-1673 if you have any questions or need additional clarification. sinc!JY'/1 ¡ v( AlJ-J Michael A. ~ll, Director Office of Compliance and Enforcement cc: Jim Regg, AOGCC, Anchorage /' . Trevor Fairbanks. ADEC. Anchorage Sharmon Stambaugh. ADEC. Anchorage o PrlntBd on Røcycled Paper #11 . . @ FOREST OIL CORPORATION _/7'/' _o? _09 5100/1/ C;yU<PÆ(:. Q/tu'(:g 700 Qr;>t;zchoJt£lllßJ Qçxf¡a6kü. .9.9501 (907) 258-/1600 · (.907) i!.58-860f (QßCt.r) February 1,2007 RECEIV'ED n 2 Mr. John Norman Commissioner Alaska Oil and Gas Conservation Commission 333 W. ih Avenue, Suite 100 Anchorage, Alaska 99501-3539 Alaska Oil & 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 penn it (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 ofEPA is presently on-site at WMRU witnessing the well tests (step-rate, mechanical integrity, temperatUTe, 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 EPA for WMRU 4D. Redoubt Unit #Dl 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 VIC program. Please feel rree to contact me at 868-2139 or rgelder@forestoil.com with any questions or concerns. Sincerely, ~ Bob Elder HSE Manager #10 e e Inject.XLS ]) I ð ,.--... Ib '''~ ~: '... ""'¡; ,,: »'.~:;O;1'!ft',¡ FORCENERGY +'-~~\.;:-JJ!''''' WEST McARTHUR RIVER UNIT MONTHLY WATER INJECTION REPORT October-05 PROD. Storm DWMA BJ TYPE OF I TOTAL DATE WATER water Water WATER FLUID I BBLS. 1 4,467 40 80 0 ' " ' 2 4,527 40 160 0 " 3 4,527 0 47 0 , 4 4,537 0 200 0 , 5 4,425 0 240 0 6 4,417 0 0 0 7 4,310 0 0 0 8 3,176 60 0 0 , ' , 9 4,529 0 160 0 ' , 10 4,766 0 0 0 I 11 3,190 35 0 0 12 4,572 35 175 0 13 3,291 55 70 0 14 4,279 30 0 0 , , 15 4,034 0 0 0 ' ; , 16 3,287 0 0 210 ~ <-1 17 3,298 60 75 40 4(-1 18 3,241 0 120 100 , 19 3,265 0 420 0 ''', ' , 20 4,461 0 525 0 ;, 21 4,544 25 50 0 , ; , 22 5,507 0 0 0 23 3,317 0 630 0 24 2,066 0 140 0 25 1,935 100 150 0 26 1,685 0 140 0 ' , 27 1,805 0 225 60 , 28 1,828 0 265 0 ' " 29 1,825 0 270 5 -1 ' 30 1,873 0 0 0 , 31 2,053 0 70 5 ' if: , " ~ ==:1" I 113,739 #9 e e @ FOREST OIL CORPORATION .110 DXè:J-J'fræ(: - QYr~t:te 700 Qc;:4;ìc/W/fCa/l'3, QQt&lJka ,9,9,1)01' (907) ,25/5-6'600 - (907) ,2.5/5-/56'01 (Q'ßax) November 18, 2005 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED NOV 1 8 2005 Re: West McArthur River Unit # 4D Request to Amend DIO 16 AI..k. OU 8¡ (i,1 Ctml. Commission Anchor.ge Dear Mr. Norman: Forest Oil Corporation requests that the Commission under Rule Number 5 of 010 # 16 amend the above injection order to reflect the following correct well information. During the preparation ofthe work-over to clean out the above mentioned well it was discovered that some of the perforations were inadvertently shot 35 feet above the top ofthe permitted injection interval. The permitted interval in DIO # 16 is currently 5,743 - 6,305 feet and the top perforation was shot at 5,708 feet. Forest regrets this oversight and respectfully requests that the permitted injection interval be changed to 5,708 - 6,305 feet I to reflect the correct perforation depths. Forest offers the following in support of this change: 1. Finding Number 7 indicates that the base of the :fresh water in this area occurs at 4,000', well above the top of the requested interval. 2. Finding number 15 indicates that there is good cement bonding :from 4,640' to 5,630'. This was re-confirmed with CBL logs. 3. The top of the requested perforated interval is in the Tyonek formation which is the original interval designated for injection. Enclosed with this letter please find a log that was spliced :from the parent Well WMRU 4 and the Side Tracked well WMRU 4D. This log has been marked with the proposed top ofthe permitted injection interval, the current top of the permitted injection interval, and all current and proposed perforations (for the upcoming work over). Also enclosed is a well bore schematic for WMRU 40. Please contact me at 868-2137 if you have any questions or concerns. Sincerely, ~~~ Ted E. Kramer Production Manager Ltr to AOGCC re WMRU 4D 111805.doc 11118/2005 7 5/8" Liner 6,243' MD 5,556' TVD . WMHU #4(0) Schematic 8.9 ppg gel mud e 20" @ 120' MD I 120' TVD 133/8" @ 2,265' MD I 2,203' TVD Packer @ 5,576' MD Liner Top @ 5,628' 95/8" @ 5,743' MD I 5,136' TVD Bridge Plug 5,960' MD 15,322' TVD Top of Cement 9,731' MD I 8,875' TVD TD @ 11,875' MD I 10,951' TVD #8 Subject: WMRU #4d From: Paula Inman <PRInman@forestoil.com> Date: Fri, 17 Jun 2005 11: 18:58 -0600 To: 'Thomas Maunder' <tom_ maunder@admin.state.ak.us> \Sl d~Y Tom, ~\) \0 \ lp I talked with Greg Kirkland (868-2141), our Geologist for WMRU 4D, about our selection for additional perforation 5791' to 5899'. He said that 5900-5910' is a coal and the best zone to perforate would 5856'-5899'. If you need additional information please feel free to contact him. I have included the step-rate test that I have found on file. Thanks, Paula Inman Production Engineer Forest Oil Corporation (907) 868-2135 office (907) 317-8231 cell Content-Type: application/vnd.ms-excel Injection Test.xls Content-Encoding: base64 ofl 6/17/2005 10:20 M. Injection Test WMRU #4(D) 3500 3000 2500 ëñ 2000 - Rate 0- - Pressure 1500 500 - ~. jJ a /' ;; 0 0 ( 2 3 4 5 6 7 8 9 I V ...- ~ BPM C r - 1000 "-. , Rate Pressure 1 2450 1.5 2650 2 2800 2.5 3000 3 3150 3.5 3250 4 3450 4.5 3500 5 3600 . · \ S. 'ì - d--S L...\ '\)~O-lLP #7 "~ . FOREST OIL . CORPORATION oJ 1 0 dYC cJJl;¡ceel. 9ftulø 700 QX'tnc~a1fø, Q9t"1a¿'a gg/i 01 (907) 25/1-/16'00 · (907) 2.5'/1-/16'01 (~.:r:) October 19, 2004 Mr. Jim Regg Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 , n'"f" ~} 'j 20U4 \j\"., ì ¡¿ \. . , Corúmì5SICn Re: Response to Letter of Approval for Injection of Alternative Fluids WMRU 4D Administrative Approval No. DIO 16.001 Dear Mr. Regg: Forest Oil Corporation is in receipt of the Commission's Administrative Approval No. DIO 16.001, dated October 15,2004. As part of that approval, the Commission requested a description of the procedural changes that will improve waste management practices employed at the WMRU Disposal Waste Management Area. Please accept the following as a response to that request: 1) Drilling personnel have been notified of the implications of the incident. 2) A spreadsheet outlining the conditions of waste disposal permit #0123- BA001(ADEC) has been issued to the rig (Kuukpik #5) at WF#2. Included were instructions that used drilling muds and cuttings are the only wastes permissible at the DWMA from the WF#2 drilling operation. 3) Instructions have been issued that only the WMRU production foreman has approval authority for use of the DMW A and the wastes disposed of therein. 4) Pelican Hill has been notified that 3rd party wastes are not acceptable in the DWMA. 5) A sign(s) will be posted at the DWMA cautioning that only exempt waste is permitted in the DWMA and that prior approval of the Forest Oil production foreman is required. · e Please eall me at 686-2139 with arIY questions or if you need additional information. We sincerely appreciate your assistance in this matter. Sincerely, i<~¡&~ Bob Elder HSE MarIager Bee: Tim Savoy Ted Kramer Jim Arlington #6 Forest Oil Request for Approval of Disposal of Alternative Waste Jim- In response to your questions on the above issue: In the affidavit signed by the Pelican Hill tool pusher, there is reference to NaGI, in addition KGI, that was added to Forest Oil's OWMA cell at West McArthur River Unit. The majority of the non-exempt fluid that was added was KG!. We are not sure what percentage of NaGI was in that solution, but that is irrelevant to the argument that the entire mixture was non-hazardous because, regardless of the amount of NaGI in the mixture, the entire mixture did not contain a listed or characteristic hazardous waste. This is because NaGI, in itself, is not hazardous by either definition. Another reference in the affidavit is to "potable water". The potable water described here was fresh water used to wash exempt wastes (used drilling muds) from the floor of the drilling rig into a collection sump that also contained used (down-hole) cement water returns. This entire mixture was exempt RGRA waste that was subsequently commingled with unused brine (KGI, and a minimal amount of NaGI, both of which are non-hazardous). Therefore, the fluids that are in the OMWA cell and need to be injected into the Glass II disposal well at WMRU 40 are all exempt and eligible for Glass II injection. Thanks for your continuing assistance on this issue. Sincerely, Bob Elder 1 of! 10/l5/2004 3:52 PM #5 ~ . FOREST OIL . CORPORATION .'J 1 0 áYC Cf;¿Jceet - ~Æ;W 700 Qr;>fnclu)/}cull~J Q9/la6ka .9,9501 (907) 2.5'8-86'00 · (907) 258-86'01 (Q'Þœr) October 14, 2004 RECEIVED OCT 1 ,4 2004 Mr. Jim Regg Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 9950 I Alaska Oì/ & Gas Cuns, Commission Anchorage Re: Request for Administrative Approval to Inject Alternative Fluids WMRU 4D DIO No. 16 Dear Mr. Regg: As I reported to you yesterday, Forest Oil Corporation (Forest Oil) operates a Disposal Waste Management Area (DWMA) at its West McArthur River Unit (WMRU) facility. The DWMA is permitted by the State of Alaska through the Department of Environmental Conservation (permit #0123-BA001) for the disposal of wastes associated with the exploration, development, and production of crude or natural gas ( exempt waste) and is used primarily for the disposal of used drilling muds and cuttings. Liquids from the DWMA are removed and injected into the West McArthur River 4D Class II disposal well, operated under Disposal Injection Order No. 16. On the evening of October 13,2004, Forest Oil became aware of third party liquids that were inadvertently placed in the DWMA from Pelican Hill, an independent oil and gas company operating a drilling rig on the west side of Cook Inlet, very near the WMRU. The Pelican Hill operation is not affiliated with any operations of Forest Oil but apparently a Forest Oil contract company man supervising the Forest Oil drilling operation at West Foreland No.2 (WF#2) gave Pelican Hill verbal approval to dispose of an unused brine solution mixed with rinsate (rig floor wash), cellar water, and used cement water in the DWMA. A Forest Oil operations supervisor discovered the error and quickly stopped the transfer but not until after approximately 50 bbls ofthe brine/rinsate/cellar water/used cement water mixture had been mixed with approximately 600 bbl of Class II liquids already in the DWMA. None of the brine has yet been injected in the 4D well. e e Forest Oil fully understands the requirement to dispose of only Class II fluids in 4D arId will implement procedures to prevent future occurrences like this. In the mearItime, Forest Oil is in the midst of drilling the WF#2 well arId needs to immediately resume regular use ofthe DWMA arId the 4D injection well. This will require approval to inject the existing liquids in the DWMA, containing the 50 bbls of the brine/rinsate/cement fluid mixture, into 4D to provide space for continued drilling operations. The brine solution was comprised primarily of potassium chloride (an MSDS is enclosed). Potassium chloride is neither a listed hazardous waste, not does it exhibit arIY of the characteristics of hazardous waste. Approximately 20 bbls of the brine solution was mixed in a vac truck with about 30 bbls of rig floor wash, cellar water, arId cement water (all of which are exempt). A signed statement from the Pelican Hill tool pusher describing the characteristics of the mixture is attached. Forest Oil respectfully requests arI administrative approval from AOGCC to inject the brine solution, about 20 bbls, now commingled with Class II liquids into 4D. The rationale for this one-time request is that under EP A guidance a non-hazardous waste commingled with arI exempt waste renders the entire mixture exempt. Please call me at 686-2139 with arIY questions or if you need additional information. Sincerely, /:DtJf æÄ Bob Elder HSE MarIager FROM : BARal D J<Et.A I Pl-D-E NO. 19Ø77763957 Oct. 13 2æ4 07: 16PM P4 e e Not Determined Acute Acute Ac:uteAlgae T C&emicaI ft. . ppm (Crangon Not detetmìned SWy In a ficenMd landfill sit appIic:abte nationar Land Tnmsportation ADR Not restricted Air Transportation :FA . Sea Transportation IMDG Not rMtrictêd Other &hippi aIion Labels: None EC Supply"'llQg R9q\l~ and is not subjGct to the I~ requirements of ec Dírectives 67I5481EEC Cas amendèd_ Classification Risk Phrases Not ~fK.I None KCl. POfASSIUM çtlLORtQ& Pap 4 of5 #4 . . [)/O / lÞ ~ ,¡d j :! .~~ jj 1ÞijH uib t~ A.",A.~1iA. OIL AND GAS CONSERVATION COJDIISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 September 27, 2004 Proposals to Amend Underground Injection Orders to Incorporate Consistent Language Addressing the Mechanical Integrity of Wells The Alaska Oil and Gas Conservation Commission ("Commission"), on its own motion, proposes to amend the rules addressing mechanical integrity of wells in all existing area injection orders, storage injection orders, enhanced recovery injection orders, and disposal injection orders. There are numerous different versions of wording used for each of the rules that create confusion and inconsistent implementation of well integrity requirements for injection wells when pressure communication or leakage is indicated. In several injection orders, there are no rules addressing requirements for notification and well disposition when a well integrity failure is identified. Wording used for the administrative approval rule in injection orders is similarly inconsistent. The Commission proposes these three rules as replacements in all injection orders: Demonstration of Mechanical Inte~ty The mechanical integrity of an injection well must be demonstrated before Injection begins, at least once every four years thereafter (except at least once every two years in the case of a slurry injection well), and before returning a well to service following a workover affecting mechanical integrity. Unless an alternate means is approved by the Commission, mechanical integrity must be demonstrated by a tubing/casing annulus pressure test using a surface pressure of 1500 psi or 0.25 psi/ft multiplied by the vertical depth of the packer, whichever is greater, that shows stabilizing pressure and does not change more than 10 percent during a 30 minute period. The Commission must be notified at least 24 hours in advance to enable a representative to witness mechanical integrity tests. Well Integrity Failure and Confinement Whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, log, or other evidence, the operator shall immediately notify the Commission and submit a plan of corrective action on a FOnTI 10-403 for Commission approval. The operator shall immediately shut in the well if continued operation would be unsafe or would threaten contamination of freshwater, or if so directed by the Commission. A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating well integrity failure or lack of injection zone isolation. e . Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. The following table identifies the specific rules affected by the rewrite. Affected Rules Injection Order "Demonstration of "Well Integrity "Administrative Mechanical Failure and Action" Integrity" Confinement" Area Injection Orders AIO I - Duck Island Unit 6 7 9 AIO 2B - Kuparuk River Unit; Kuparuk River, 6 7 9 Tabasco, Ugnu, West Sak Fields AIO 3 - Prudhoe Bay Unit; 6 7 9 Western Operating Area AIO 4C - Prudhoe Bay Unit; 6 7 9 Eastern Operating Area AIO 5 - Trading Bay Unit; 6 6 9 McArthur River Field AIO 6 - Granite Point Field; 6 7 9 Northern Portion AIO 7 - Middle Ground 6 7 9 Shoal; Northern Portion AIO 8 - Middle Ground 6 7 9 Shoal; Southern Portion AIO 9 - Middle Ground 6 7 9 Shoal; Central Portion AIO 10B - Milne Point Unit; Schrader Bluff, Sag River, 4 5 8 Kuparuk River Pools AIO 11 - Granite Point 5 6 8 Field; Southern Portion AIO 12 - Trading Bay Field; 5 6 8 Southern Portion AIO 13A - Swanson River 6 7 9 Unit AIO 14A - Prudhoe Bay 4 5 8 Unit; Niakuk Oil Pool AIO 15 - West McArthur 5 6 9 . . Affected Rules "Demonstration of "Well Integrity "Administrative Injection Order Mechanical Failure and Action" Integrity" Confinement" River Unit AIO 16 - Kuparuk River 6 7 10 Unit; Tam Oil Pool 6 8 AIO 17 Badami Unit 5 AIO 18A - Colville River 6 7 11 Unit; Alpine Oil Pool AIO 19 - Duck Island Unit; 5 6 9 Eider Oil Pool AIO 20 - Prudhoe Bay Unit; 5 6 9 Midnight Sun Oil Pool AIO 21 - Kuparuk River 4 No rule 6 Unit" Meltwater Oil Pool , AIO 22C - Prudhoe Bay 5 No rule 8 Unit Aurora Oil Pool 9 , 6 AIO 23 Northstar Unit 5 AIO 24 - Prudhoe Bay Unit; 5 No rule 9 Borealis Oil Pool AIO 25 - Prudhoe Bay Unit; 6 8 13 Polaris Oil Pool AIO 26 - Prudhoe Bay Unit; 6 No rule 13 Orion Oil Pool Disposal Injection Orders DIO 1 - Kenai Unit; KU No rule No rule No rule WD-l DIO 2 - Kenai Unit; KU 14- No rule No rule No rule 4 DIO 3 - Beluga River Gas No rule No rule No rule Field; BR WD-I DIO 4 - Beaver Creek Unit; No rule No rule No rule BC-2 DIO 5 - Barrow Gas Field; No rule No rule No rule South Barrow #5 DIO 6 - Lewis River Gas No rule No rule 3 Field; WD-1 DIO 7 - West McArthur 2 3 5 River Unit; WMRU D-1 DIO 8 - Beaver Creek Unit; 2 3 5 BC-3 DIO 9 - Kenai Unit; KU 11- 2 3 4 17 DIO 10- Granite Point 2 3 5 Field; GP 44-11 . . Affected Rules "Demonstration of "Well Integrity "Administrative Injection Drder Mechanical Failure and Action" Integrity" Confinement" DID 11 - Kenai Unit; KU 2 3 4 24-7 DID 12 - Badami Unit; WD- 2 3 5 1, WD-2 DID 13 - North Trading Bay 2 3 6 Unit; S-4 DID 14 - Houston Gas 2 3 5 Field; Well #3 DID 15 - North Trading Bay 2 3 Rule not numbered Unit; S-5 DID 16 - West McArthur 2 3 5 River Unit; WMRU 4D DID 17 - North Cook Inlet 2 3 6 Unit; NClli A-12 DID 19 - Granite Point 6 Field; W. Granite Point State 3 4 17587 #3 DID 20 - Pioneer Unit; Well 3 4 6 1702-15DA WDW DID 21 - Flaxman Island; 3 4 7 Alaska State A-2 DID 22 - Redoubt Unit; RU 3 No rule 6 Dl DID 23 - Ivan River Unit; No rule No rule 6 IRU 14-31 DID 24 - Nicolai Creek Drder expired Unit; NCU #5 DID 25 - Sterling Unit; SU 3 4 7 43-9 DID 26 - Kustatan Field; 3 4 7 KFI Storage In.iection Orders SID 1 - Prudhoe Bay Unit, No rule No rule No rule Point McIntyre Field #6 SID 2A- Swanson River 2 No rule 6 Unit; KGSF #1 SID 3 - Swanson River Unit; 2 No rule 7 KGSF #2 Enhanced Recovery In.iection Orders EID 1 - Prudhoe Bay Unit; No rule 8 Prudhoe Bay Field, Schrader No rule Bluff Formation Well V-I05 . . Affected Rules Injection Order "Demonstration of "Well Integrity "Administrative Mechanical Failure and Action" Integrity" ConfInement" EIO 2 - Redoubt Unit; RU-6 5 8 9 · . ~ I I 02-902 (Rev. 3/94) Publisher/Original Copies: Department Fiscal, Department, Receiving AO.FRM STATE OF ALASKA ADVERTISING ORDER NOTICE TO PUBLISHER ADVERTISING ORDER NO. INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTIFIED AO-02514016 AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH AITACHED COpy OF ADVERTISEMENT MUST BE SUBMIITED WITH INVOICE F AGENCY CONTACT DATE OF A.O. AOGCC 333 West ih Avenue, Suite 100 o Anchorage,AJ( 99501 M 907-793-1221 R DATES ADVERTISEMENT REQUIRED: T o Journal of Commerce 301 Arctic Slope Ave #350 Anchorage, AJ( 99518 October 3,2004 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED tN 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 he/she is the of Published at in said division and state of and that the advertisement, of which the annexed is a true copy, was published in said publication on the day of 2004, and thereafter for _ consecutive days, the last publication appearing on the _ day of , 2004, and that the rate charged thereon is not in excess of the rate charged private individuals. Subscribed and swam to before me This _ day of 2004, Notary public for state of My commission expires Public Notices . . Subject: Public Notices From: Jody Colombie <jody _colombie@admin.state.ak.us> Date: Wed, 29 Sep2004 13:01:04 -0800 10f2 9/29/2004 1: 10 PM Public Notices e . 20f2 9/29/2004 I: 10 PM Public Notice . . Subject: Public Notice From: Jody Colombie <jody _ colombie@admin.state.ak.us> Date: Wed, 29 Sep 2004 12:55:26 -0800 Please publish the attached Notice on October 3, 2004. Thank you. Jody Colombie Content- Type: applicationlmsword Mechanical Integrity of Wells N otice.doc Content-Encoding: base64 Content- Type: applicationlmsword Ad Order form.doc Content-Encoding: base64 1 of 1 9/29/2004 1: 10 PM Citgo Petroleum Corporation PO Box 3758 Tulsa, OK 74136 Kelly Valadez Tesoro Refining and Marketing Co. Supply & Distribution 300 Concord Plaza Drive San Antonio. TX 78216 Jerry Hodgden Hodgden Oil Company 408 18th Street Golden, CO 80401-2433 Kay Munger Munger Oi/lnformation Service, Inc PO Box 45738 Los Angeles. CA 90045-0738 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage. AK 99502 Baker Oi/ Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 James Gibbs PO Box 1597 Soldotna, AK 99669 Richard Wagner PO Box 60868 Fairbanks, AK 99706 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 . . Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 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 Dri/fing and Measurements 2525 Gambell Street #400 Anchorage, AK 99503 Ciri Land Department PO Box 93330 Anchorage, AK 99503 Jack Hakki/a 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 /lJal'kd !tJ/¡1tlJ David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 George Vaught, Jr. PO Box 13557 Denver. CO 80201-3557 John Levorsen 200 North 3rd Street, #1202 Boise, ID 83702 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle. WA 98119-3960 David Cusato 200 West 34th PMB 411 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage. AK 99508 Darwin Waldsmith PO Box 39309 Ninilchick. AK 99639 Penny Vadla 399 West Riverview Avenue Soldotna, AK 99669-7714 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks. AK 99711 ·[Fwd: Re: Consistent Wording for Injection ers - Well Integrity .., . s..... ub.....jec.· t: [Fw.d.: R. .... e: COIl.sist. en. t... W. örd. in...........g.·.............fi..o...... r.....InJ.. ·..ection.........O..··... rdet~ ..WêllÙ"1t¢grit.y{R.~viseq)] .- "<'" -', .-.- .-.-'- .-.- ": '-::" '-', ,'....: :",: -':" .- ',<.- ',' ......- .- ...... .... .....:.... ..... -,: ..... : ....:.:..::::. <', :......: ..'..:.>:....:.:..:::-... ", .- -.- ..",.-".- .-.-.- ,- ~ F~om:. John Norman.<j~hn=norman@ac.tmínistate.ak.us> Dâte:Fri, 01 Oct 200411:09:26;..0800 more -------- Original Message -------- Subject:Re: Consistent Wording for Injection Orders - Well Integrity (Revised) Date:Wed, 25 Aug 2004 16:49:40 -0800 From:Rob Mintz <robert mintz~law.state.ak.us> To: j im regg~admin.state.ak. us CC:dan seamount~admin.state.ak.us, john norman~admin.state.ak.us Jim, looks good, but I still think maybe it would be good to include the following sentence or something like it in the well integrity and confinement rule: "The operator shall shut in the well if so directed by the Commission." My thinking is that otherwise, an operator might argue that the Commission can only require the well to be shut in by going through an enforcement action, issuing an order after notice and opportunity for hearing, or meeting the strict requirements for an emergency order under the regulations. The proposed language makes clear that it is a condition of the authorization to inject, that the operator must shut in the well if directed by the Commission after a notification of loss of integrity, etc. »> James Regg <jim regg@admin.state.ak.us> 8/25/2004 3:15:06 PM »> Rob - Thanks for the review; here's a redraft after considering your comments. I have accepted most of the suggested edits; also attached is response to questions you pose (responses are embedded in the comments, using brackets [JBR - ...] to set apart from your questions). Jim Regg Rob Mintz wrote: Jim, I have some questions about the draft language, which are shown as comments on the first document attached. Based on my current guesses about what the answers will be to my questions, I also have some suggested edits, which are shown as redlines on the second document attached. »> James Regg <iim regg(ajadmin.state.ak.us> 8/17/20044:33:52 PM »> Please delete previous version (email sent 8/9/04); I found another inconsistency in the injection orders regarding well integrity that I have integrated into the proposed fix. Attached is a proposal for consistent language in our injection orders addressing 3 rules related to well integrity: - "Demonstration of Tubing/Casing Annulus Mechanical Integrity" - "Well Integrity Failure" - "Administrative Actions". This proposal includes input from all Sr. staff (except Jack). If you agree with the approach, I'll work with Jody to prepare the public notice. Main points - Demonstration of Tubing/Casing Annulus Mechanical Integrity - standardizes the wording used for mechanical integrity demonstrations, and establishes abiWty to grant alternate methods (e.g., temp survey, logging, pressure monitoring in lieu of pressure testing lof2 10/2/2004 4:07 PM [Fwd: Re: Consistent Wording for Injection.rs - Well Integrity ... . - specific to AIO 2C for Kuparuk, there is wording that is more appropriately included in Well Integrity Failure (i.e., more frequent MITs when communication demonstrated) - establishes more frequent MIT schedule for slurry injection wells (every 2 yrs) which is consistent with our current practice (but not addressed in regulations) Well Integrity Failure - retitles to "Well Integrity Failure and Confinement"; inserted language regarding injection zone integrity (see DIO 25 and 26) - consistent language regardless of type of injection (disposal, EOR, storage); - eliminates requirement for immediate shut in and secure; allows continued injection until Commission requires shut in if there is no threat to freshwater; - eliminates delay in notifying Commission after detect leakage or communication ("i.e., "immediately notify"); - removes language about notifying "other state and federal" agencies; - requires submittal of corrective action plan via 10-403; - requires monthly report of daily injection rate and pressures (tubing and all casing annuli); this is a requirement we currently impose when notified of leak or pressure communication; - notice and action not restricted to leaks above casing shoe as stated in several DIOs Administrative Actions - adopts" Administrative Actions" title (earlier rules used" Administrative Relief'); - consistent language regardless of type of injection (disposal, EOR, storage); - uses "administratively waive or amend" in lieu ofterms like "revise", "reissue", etc.; - adds geoscience to "sound engineering principles"; - language is more generic regarding fluid movement out of zone; existing versions mention varying combinations of protecting" freshwater", "aquifers", "USDW s"; "risk of fluid movement"; "fluid escape from disposal zone" Jim Regg John K. Norman <John Norman~adrnin.state.us> Commissioner Alaska Oil & Gas Conservation Commission 20f2 10/2/2004 4:07 PM JFwd: Re: Consistent Wording for Injection.s - Well Integrity... . S~bject: [Fwd: Re:Consistent Wording for Injection Or4ers."'. WèllI11tegrity (R.evis~d)] ~~om: John Norman <john__norman@admin.state.ak.µs> Date: Fri, 01 Oct 2004 11:08:55 -0800 please print all and put in file for me to review just prior to hearing on these amendments. thanx -------- Original Message -------- Subject:Re: Consistent Wording for Injection Orders - Well Integrity (Revised) Date:Thu, 19 Aug 200415:46:31 -0800 From:Rob Mintz <cobert mintz(G¿law.state.ak.us> To:dan seamount(G¿admin.state.ak.us, jim regg(G¿admin.state.ak.us, john nonnan(G¿admin.state.ak. us Jim, I have some questions about the draft language, which are shown as comments on the first document attached. Based on my current guesses about what the answers will be to my questions, I also have some suggested edits, which are shown as redlines on the second document attached. »> James Regg <iim regg(a;¡admin.state.ak.us> 8/17/20044:33:52 PM »> Please delete previous version (email sent 8/9/04); I found another inconsistency in the injection orders regarding well integrity that I have integrated into the proposed fix. Attached is a proposal for consistent language in our injection orders addressing 3 rules related to well integrity: - "Demonstration of Tubing/Casing Annulus Mechanical Integrity" - "Well Integrity Failure" - "Administrative Actions". This proposal includes input from all Sf. staff (except Jack). If you agree with the approach, I'll work with Jody to prepare the public notice. Main points - Demonstration of Tubing/Casing Annulus Mechanical Integrity - standardizes the wording used for mechanical integrity demonstrations, and establishes abililty to grant alternate methods (e.g., temp survey, logging, pressure monitoring in lieu of pressure testing - specific to AIO 2C for Kuparuk, there is wording that is more appropriately included in Well Integrity Failure (i.e., more rrequent MITs when communication demonstrated) - establishes more frequent MIT schedule for slurry injection wells (every 2 yrs) which is consistent with our current practice (but not addressed in regulations) Well Integrity Failure - retitles to "Well Integrity Failure and Confinement"; inserted language regarding injection zone integrity (see DIO 25 and 26) - consistent language regardless of type of injection (disposal, EOR, storage); - eliminates requirement for immediate shut in and secure; allows continued injection until Commission requires shut in if there is no threat to rreshwater; - eliminates delay in notifYing Commission after detect leakage or communication ("i.e., "immediately notifY"); - removes language about notifYing "other state and federal" agencies; - requires submittal of corrective action plan via 10-403; - requires monthly report of daily injection rate and pressures (tubing and all casing annuli); this is a requirement we currently impose when notified of leak or pressure communication; - notice and action not restricted to leaks above casing shoe as stated in several DIOs Administrative Actions lof2 10/2/2004 4:07 PM [Fwd: Re: Consistent Wording for Injectioners - Well Integrity ... . - adopts "Administrative Actions" title (earlier rules used "Administrative Relief'); - consistent language regardless of type of injection (disposal, EOR, storage); - uses "administratively waive or amend" in lieu of terms like "revise", "reissue", etc.; - adds geoscience to "sound engineering principles"; - language is more generic regarding fluid movement out of zone; existing versions mention varying combinations of protecting "freshwater", "aquifers", "USDWs"; "risk of fluid movement"; "fluid escape from disposal zone" Jim Regg John K. Norman <John Norman(á}adrnin.state.us> Commissioner Alaska Oil & Gas Conservation Commission Content-Type: applicationlrnsword Injection Order language - questions. doc Content-Encoding: base64 Injection Orders language Content-Type: applicationlrnsword Content-Encoding: base64 20f2 10/2/20044:07 PM . . Standardized Language for Injection Orders Date: August 17, 2004 Author: Jim Regg Demonstratìon of Tubing/Casing Annulus Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before injection begins, after a workover affecting mechanical integrity, and at least once every 4 years while actively injecting. For slurry injection wells, the tubing/casing annulus must be tested for mechanical integrity every 2 years. The MIT surface pressure must be 1500 psi or 0.25 psi/ft multiplied by the vertical depth, whichever is greater, must show stabilizing pressure and may not change more than 10% during a 30 minute period. Any alternate means of demonstrating mechanical integrity must be approved by the Commission. The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests. Well Integrity Failure and Confinement The tubing, casing and packer of an injection well must demonstrate integrity during operation. The operator must immediately notify the Commission and submit a plan of corrective action on Form 10-403 for Commission approval whenever any pressure communicatìon, leakage or lack of injectìon zone isolatìon is indicated by injection rate, operating pressure observation, test, survey, or log. If there is no threat to freshwater, injection may continue untìl the Commission requires the well to be shut in or secured. A monthly report of daily tubing and casing annuli pressures and injectìon rates must be provided to the Commission for all injection wells indicating pressure communication or leakage. Administratìve Actìons Unless notìce and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. . . Standardized Language for Injection Orders Date: August 17, 2004 Author: Jim Regg Demonstration of Tubing/Casing Annulus Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before injection begins, at least once every four years thereafter (except at least once everv two years in the case of a slurry injection well), and before returning a well to service following aft€f a workover affecting mechanical integrity, and at least once every <I years v,hile actively injecting. For :;lurry injection \velIs, the tubing/casing ar.nulus must be tested for mechanical integrity every 2 years. Unless an alternate means is approved bv the Commission. mechanical integrity must be demonstrated by a tubing pressure test using a =Ffle Mfr.-surface pressure oEmust be 1500 psi or 0.25 psi/ft multiplied by the vertical depth, whichever is greater, that ffH:15t-show~ stabilizing pressure that doesand may not change more than 10%- percent during a 30 minute period. --Afly alternate means of demonstrating mochanical integrity mu::;t be approved by the Commission. The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests. Well Integritv Failure and Confinement Except as othef\vise provided in this rule, +!he tubing, casing and packer of an injection well must demonstrate maintain integrity during operation. ~Whenever any pressure communication, leakage or lack of injection zone isolation is indicated bv injection rate. operating pressure observation, test, survey, log. or other evidence, t+he operator :fTH±St-shalI immediately notify the Commission and submit a plan of corrective action on a Form 10-403 for Commission approval~ \vhene'.'er any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, sUf\'ey, or log. The operator shall shut in the well if so directed bv the Commission. The operator shall shut in the well without awaiting a response from the Commission if continued operation would be unsafe or would threaten contamination of freshwaterIf there is no threat to fresh',mter, injection may continue until the Commission require::; the '_,'ell to be shut in or secured. Until corrective action is successfullv comp1eted, Aª monthly report of daily tubing and casing annuli pressures and injection rates múst be provided to the Commission for all injection wells indicating pressure communication or leakage. Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. . ,[Fwd: Re: [Fwd: AOGCC Proposed WI Lan.e for Injectors]] . §µþJect: [Fwd: Re: [Fwd: AOGCCProposed WI Language for Injectors]] ~r()m:.Winton Aubert <winton _aubert@adrnin.state.ak.us> Dat~:. 'fhu, 28 Oct 200409:48.:53.-08.00 This is part of the record for the Nov. 4 hearing. WGA -------- Original Message -------- Subject: Re: [Fwd: AOGCC Proposed WI Language for Injectors] Date: Thu, 28 Oct 2004 09:41:55 -0800 From: James Regg <jim regg@admin.state.ak.us> Organization: State of Alaska To: Winton Aubert <winton aubert@admin.state.ak.us> References: <41812422.8080604@admin.state.ak.us> These should be provided to Jody as part of public review record Jim Winton Aubert wrote: FYI. -------- Original Message -------- AOGCC Proposed WI Language for Tue, 19 Oct 2004 13:49:33 -0800 Engel, Harry R <EngelHR@BP.com> winton aubert@admin.state.ak.us Injectors Subject: Date: From: To: Winton... Here are the comments we discussed. Harry *From: * NSU, ADW Well Integrity Engineer *Sent: * Friday, October IS, 2004 10:43 PM *To: * Rossberg, R Steven¡ Engel, Harry Ri Cismoski, Doug Ai NSU, ADW Well Operations Supervisor *Cc: * Mielke, Robert L.¡ Reeves, Donald F¡ Dube, Anna T¡ NSU, ADW Well Integrity Engineer *Subject: * AOGCC Proposed WI Language for Injectors Hi Guys. John McMullen sent this to us, it's an order proposed by the AOGCC to replace the well integrity related language in the current Area Injection Orders. Listed below are comments, not sure who is coordinating getting these in front of Winton/Jim. Overall, looks okay from an Operations perspective. We do have a few comments, but could live with the current proposed language. Note the proposed public hearing date is November 4. The following language does not reflect what the slope AOGCC inspectors are currently requiring us to do: "The mechanical integrity of an injection well must be demonstrated before injection begins, at least once every four years thereafter (except at least once every two years in the case of a slurry injection well), and * before*_** 10f3 10/28/2004 11 :09 AM ... [Fwd: Re: [Fwcf: AOGCC Proposed WI Laee for Injectors]] . returnj.ng a well to service following a workover affecting mechanical integrity." After a workover, the slope AOGCC inspectors want the well warmed up and on stable injection, then we conduct the AOGCC witnessed MITIA. This language requires the AOGCC witnessed MITIA before starting injection, which we are doing on the rig after the tubing is run. Just trying to keep language consistent with the field practice. If "after" was substituted for "before", it would reflect current AOGCC practices. It would be helpful if the following language required reporting by the "next working day" rather than "immediately", due to weekends, holidays, etc. We like to confer with the APE and get a plan finalized, this may prevent us from doing all the investigating we like to do before talking with the AOGCC. "Whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, log, or other evidence, the operator shall * immediately* ** notify the Commission" This section could use some helpjwordsmithing: "A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating well integrity failure or lack of injection zone isolation." Report content requirements are clear, but it's a little unclear what triggers a well to be included on this monthly report. Is it wells that have been reported to the AOGCC, are currently on-line and are going through the Administrative Action process? A proposed re-write would be: "All active injection wells with well integrity failure or lack of injection zone isolation shall have the following information reported monthly to the Commission: daily tubing and casing annuli pressures, daily injection rates." Requirements for the period between when a well failure is reported and when an administrative action is approved are unclear. This document states "the operator shall immediately notify the Commission and submit a plan of corrective action on a Form 10-403". If we don't plan to do any corrective action, but to pursue an AA, does a 10-403 need to be submitted? The AOGCC has stated they don't consider an AA as "corrective action". Let me know if you have any questions. Joe -----Original Message----- From: Kleppin, Daryl J Sent: Wednesday, September 29, 2004 1:37 PM To: Townsend, Monte A; Digert, Scott Ai Denis, John R (ANC) i Miller, Mike E; McMullen, John C Subject: FW: Public Notices FYI -----Original Message----- From: Jody Colombie [ mailto:jody colombie@admin.state.ak.us Sent: Wednesday, September 29, 2004 1:01 PM Subject: Public Notices Please find the attached Notice and Attachment for the proposed amendment of underground injection orders and the Public Notice Happy Valley #10. Jody Colombie «Mechanical Integrity proposal. ZIP» «Mechanical Integrity of Wells Notice.doc» 2 00 1 0/28/2004 11 :09 AM #3 , ,/ ) Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: Disposal Injection Order for West McArthur River Unit, Cook Inlet Forcenergy Inc. by letter dated June 12, 1998 made application to the Commission for a Disposal Injection Order for the underground injection of Class II drilling and production wastes into the West McArthur River Unit Well No. 4(D) well in the West McArthur River Unit, Cook Inlet. A person who may be harmed if the requested order is issued may file a written protest prior to 4:00 PM July 2, 1998, with the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska 99501, and request a hearing on the matter. If the protest is timely filed and raises a substantial and material issue crucial to the Commission's determination, a hearing on the matter will be held at the above address at 9:00 AM on July 21, 1998, in conformance with 20 AAC 25.540. If a hearing is to be held, interested parties may confirm this by calling the Commission's office, (907) 279-1433, after July 2, 1998. If no protest is filed, the Commission will consider the issuance of the order without a hearing. 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 Diana Fleck at 279-1433 no later than July 14, 1998. Published June 18, 1998 ADN AO 02814055 if: 14412 STOF0330 AO-02184055 $65.52 ") -, ) AFFIDAVIT OF PUBLICATION June 18, 1998 ~otlc~(~ P~Þ~i(Ii~C!riÌ1g .';.STATEoF'ALA~KÄ::" r O,lapd Gas;Consèrvati!)1I "'~O~~'iSSiClI!'I":'!' l,I', Re: ,D;i~pos~I"" In ìè(;~'~n: 1,II'or~~r for : W~s" Mc~rth'u'r,' Ri¡vèpr:U'ì1it,i Cllok 'n'et:."<':"'i, i' '.,',.,I-''''I,I;,,''r', . ¡=O~c~¡'E'rg~ ' Ir,~:'e~r' aat~a Jun,¡. 1 ~ 1998, rnaaa ,OQpllc:aTIe¡n 10 Th", ':ommbs,on tor a D,s. co~al I roi'!'CTI(\n urae-r Tor ThE ur'o'!'rgrOund Inle"ie¡n 01 ':IO~~ II Drllllr,g ()r,a DrOaueTion "O;t"'~ !riTe¡ rhe V\le~t McArThur ~Iv..r UniT WE'll No 41 D I "'~II In In.. W'¡'~I M, Arthur ~""r ur,11 (o,,~, InlE'T . " Der~on .\hO ma, 0.. r,orm ¿a " Ir,.. r"':¡ue-STE:D ,:,ra,¡.r I; "";u..a mo. Io'e a \IIr,IT.." Dre,- '~;'I, crl"r 10 J (II) PM Jul\ ~ ~"~IJ .~lIh Tr,F.- o1la~KO (oil one .11)', (or, ,&r, otle¡n Comrrol; "Ion a\)ill ~orcuPlneDr'VEl,A~lhôr: age" AlaSkQ:99501J"qb~tEl,QlIElSt a I1,,"orlng en tl1.. rnO'ii.¡.r II' In.. c're,I"'~T ,; l,m~l, lIe" ()na rol !¿~ 0 sut.!,rOnT1ol'ond I l,:"ot.¡.rtOI 1;~'Je- .:rueIOI TO th", l..omnllSSlon:~ ,",'Clø,t,ermlha,floi:\/~,i hearln~", on thé:",mdtterWIII":/:)Q held" Q,t, the, c:r~ove Clddr'êss1ót; 9:00 AMo.n,~\lIY21,1998,Jn conformance WIth, '20 .,'ArAC ,25.540; If "ahe(l~ing"lsJo,P"be held, , ¡nteres,ted: pprt1a$ ,6ìåv conflr~,th¡s' ,bvcallin(,th~ Comr:nlsslon'~ ,',offICe;i(907) 279-1433,' 9fter July 2; 1998. 'If' no P!,otest IS fi I,ed, the COmmIS- slon ,WII!" conSider Iss,uonca' of the order without 0 ~eorin~\. ',' . Ifv()u ore 0 persöñ :Wlt~:'to d~~Oblit,.· ",1,110 ma. na&'II,I,O '['I:'CIOI mudlfl.all,;,n ,n order 10 commam ortQI èittend:.:tae public hearing, pleose' contcict Diona, Fleck ot, "279,'1'433""',',~~Oi later than J u/v 14,'1998.' " ':":Ji1: Is/David W: Johnst6n "'::""::'M',I Ch,olrmon, " , ,:, : ":'i'\:":i\!\I~I': AQ,028l'40S5,: ,,~':,,!i'::il'/I,I, f!:1þ;~,,"~,µ(I~c1 ?81.19~~:,.:.m:~~!¡~~I$; STATE OF ALASKA, THIRD JUDICIAL DISTRICT. Eva 1'1. Kaufmann . . . . I .. . . .. .. .. .. .. . .. .. .. .. .. .. .. .. .. . .. .. .. .. .. .. being first duly sworn on oath deposes and says that he/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 Engl ish language continually as a daily newspaper in Anchorage, Alaska, and it is now and during all said time was printed in an office maintained at the aforesaid place of publication of said newspaper. That the annexed is a copy of an advertisement as it was published in regular issues (and not in supplemental form) of said newspaper on and that such newspaper was regu larly distributed to its subscribers during all of said period. That the full amount of the fee charged for the foregoing publication is not in excess of the rate charged private i nd ividuals. ~~ Subscribed and sworn efore me this ;;£~day oÚc/Lf!-.-, 9- 7" 19:.:~¡! : l,.,..i7h<... Notary lic in and for the State of Alaska. Third Division. Anchorage. Alaska MY COMMISSION EXPIRES . .::::..:kÁ::?...:J:f?.[ ¿ c #2 1.1, " :r"':! ) ') Forcenergy Inc September 2, 1998 ORIGINAL Alaska Oil and Gas Conservation Commission Mrs. Wendy Mahan 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Disposal Injection Order West McArthur River Unit #4(d) RECEIVED SEP 02 1998 Alaska Oil & Gas Cons. Commission Anchorage Dear Mrs. Mahan: This letter is a follow-up correspondence to our phone conversations concerning the Application for Disposal Injection Order for West McArthur River Unit #4(d). You had two concerns on the 9 5/8" casing cement. The first was the origin of the top of cement calculation for the annular cement. This was stated as 5,640' MD in the application. Indeed, this is incorrect and was transcribed over from a previous document as the top of the cement plug in the 9 5/8" casing on the original suspension. As you will see in the attached previous Application for Sundry Approval on WMRU #4, dated 2/20/98, that the calculated top of cement based on displacement volumes was 4,270' JVID. The second concern that you had was why the Cement Bond Log covered the depths of 4,600' MD to 5,600' MD. This CBL was run prior to drilling the 8 ~" hole for the injection liner. The purpose of running the log was to verify good cement above the 9 5/8" casing shoe and look at the possibility of using the lower 1,000' of 9 5/8" as an injection zone. This idea was abandoned based on our desire to get farther away from the existing injection zone for WMRU #Dl. We felt that the CBL showed more than adequate isolation between our injection zone and the zones above. I apologize for the confusion that the incorrect cement depth has caused. If there are any questions, please contact me at 258-8600. ~~~ Rob Stinson Drilling Engineer F orcenergy Inc. HEADQUARTERS Forcenergy Center 2730 SW 3rd Avenue Suite 800 Miami, Florida 33129-2237 REGIONAL OFFICE TELEPHONE 305/856-8500 FAX 305/856-4300 310 K Street Suite 700 Anchorage, Alaska 99501 TELEPHONE 907/258-8600 FAX 907/258-8601 2. Name of Operator Forcenergy Inc. 3. Address 310 K Street. Suite 700 Anchorage, Alaska 99501 4. Location of well at surface 2083' FSL, 3346' FEL Sec 16 T08W R14W, SM At top of productive interval 288' FSL. 481' FEL. S16, T08N. R14W, SM At total depth 316' FSL, 5039' FEL, Sec 15 T08N R14W, SM .' ' '" 1. Type of Request: ) STATE OF ALASKA ') ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Abandon: X Suspend: Operation shutdown: Alter casing: Repair well: Plugging: ~ Change approved program: PuiitUbing: Variance: 5. Type of well: Development: Exploratory: Stratigraphic: Service: Re-enter suspended well: Time extension: Stimulate: Perforãtë': Other: 6. Datum elevation (DF or KB) 140' KB X 7. Unit or Property name West McArthur River Unit feet 8. Well number #4 9. Permit number 97 -234 10. API number 50- 133-20481 11. Field/Pool West Foreland Field 12. Present well condition summary Total depth: measured true vertical Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 11.875 feet Plugs (measured) 10,952 feet feet Junk (measured) feet Size Cemented Measured depth True vertical depth 20" Driven 120' 120' 13 3/8" To Surface 2,265' 2,200' 95/8" Calculated top 4.270' 5,743' 5,120' Length 120' 2,265' 5.743' measured true vertical [':1 . .f ~ ,: J:, . ¥- \..", ( " ¡ C" ¡ I, L.I ,./ Tubing (size, grade, and measured depth) 13. Attachements Packers and SSSV (type and measured depth) BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: February 21, 1998 16. If proposal well verbally approved: 0 ~ Oil: Gas: Blair Wondzell 2/19/98 ~ Name of approver Date approved Service: 17. I hereb\ ~ that th: foregoing is true and correct to the best of my knowledge. Signed: \'\Jv\^ Þ Paul White Title: Dnlling Manager FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity--.L... BOP Test ~ Location clearance_ Mechanical Integrity Test_ Subsequent form required 10- ti d l' Description summary of proposal: X Detailed operations program: Suspended: X Date: 2/20/1998 Approval No. .39B~ CJ<ÇL-l Form 10-403 Rev 06/15/88 Commissioner Date 0',/,8 SUBMIT IN TRIPLICATE 0"1 ~ ,,-~ ) ') WMRU #4 Plug and Abandon AlII ~ 20" @ 120' All ~ 13 3/8" @ 2,265' . =>< Top of Cement 5,643' 95/8" @ 5,743' / ! Bridge Plug 5,960' 8 1/2" Hole \\ \ Top of Cement 9,800' \ \ \ _ _Lap.of .Hemlac.k. _ JD...8.1.5.'_ _ _ __ -------------------------- \. -------------------------- _ _ _Lap.of _W.e.st F Drclands _ .1L3.QO' ~ TD @ 11,875' ) ) APPLICATION FOR DISPOSAL INJECTION ORDER WEST McARTHUR RIVER UNIT WELL NO.4 (D) FORCENERGY INC Submitted to the ALASKA OIL AND GAS CONSERVATION COMMISSION Prepared by Forcenergy Inc Anchorage, Alaska With assistance from Northern Consulting Group Anchorage, Alaska June 1998 T .j ,'I. ) wMR-.ü 4LD) 9~ - 2-31- MECI-LWICLL It-i"TEGRITY RE:?ORT· ". SPUD DA~E: ~ '110 ~~ \ ?,IG 2.E:~~)'~SE: b{.\l~~ CPER &. FIELD t;~f.~~ wl1~lj ~\~L.L NUKBER '9 i - 'L~ 4- 7~ t,.LL DATA ""'R~ Cas ing :9fö L....80 ~.~~ I., =-:1 e r: 1 s¡~ L.." ßo TD: t, ~~ till, ~55L. TVD ; ?BTD: bZ."; Š HD 55 5 b Tim S hoe: .C) 7 -t ':\ HD 5T~~ - Shoe: b2:t.3 till Hole Size }~Y1 12 ï""1 ana C),/ TVD ; DV: ~1D 'I":lIJ j 'IC? : I ,ill T\ì'1) í Set ~... 55:¡ ~ c. L Perfs .C::-=J 0 ~ to ·J:'"rvu :-O:ìD !ubi~g: 7-::J/~ Packer 5~1£ MD b/3 D ' ~-ŒC2.ÞJrI C.AL INTEGRITY - ? Þ-P~T ! 1 Annulus Press Test: I? 15 min ~o m.in Comments: .--- HECHÞ....r\fICAL INTEGRITY - PP...RT /2 Cement Volumes:' .Amt. Liner Jo~ L+ ; Csg 81b e:Ç; DV Cillt ~ol to cover Der£s i ~ 2.9.:fi ~ -e-- . --e-- 1'1· Z- :'\'1 . '2.-'-0 '3 ~ u- ~ /f,2-13· ~ 2.13) 7\ · ~8 + LQ.13 - b 2:1~~. ~ ~-t , + ( ~1.-+.3 - 510 8y' c;:¡.qJ ~ 4 · z.. CF= =- · 2.S~~ '-'?Lf'Theore tical Toe . ~ Yz. -:. . '5 ~-bg ~'f./J.t· ,..- \ ..L - 1- J : .~~ I (.11...1= 5"1 Q ~ - l-L )O~ - -41:2- J . I o'1-=J1 ~ ~ ö Z.O 1S¡ò ~ B 'I2.~ Cement Bond Log (Yes or No) 'f~ In AOGCC File (.:I.:.:1j ~ ~ 0 t$/J...F C:3L :::",,"2..1 ua tion, ::one above p erÍs AD~\J-Aí't. ~f\,JJ) TML.ou(:,tio\J'7 /,..J:i666.^ I ~T~Al-. 4600' " P::-oduc.tion Log: Type ¡Evaluation CONCLUSIONS: ? ar t f 1 : :3.=-:: ;2: !\J\) 1~ }~j~lé_f\.7fÌ'\ WM 7/Z3/ð)8 rev. OS/20/87 (' n7R ) .) .., WMRU #4101 Schematic ..,.¡ .... 20" @ 120' rvID / 120' TVD ..,.¡ .... 13 3/8" @ 2,265' tv1D / 2,203' TVD :z :z: Packer @ 5,576' :MD 7 5/8" Liner 6,243' :MD 5,556' TVD Liner Top @ 5,628' 95/8" @ 5,743' :MD / 5,136' TVD Bridge Plug 5,960' rvID /5,322' TVD 8.9 ppg gel mud Top of Cement 9,731' rvID / 8,875' TVD ~ " TD @ 11.875' :MD / 10,951' TVD West McArthur River 4(0) Area of Review Data WMRU D-1 Casing size wtlft 13 3/8" 72.0# 9 5/8" 43.5# 7" 29.0# 2 7/8" tbg 6.5# CMT log evaluation: CBT/CET 1250-4380' Good bond below 1520'.,1426-1510 channel, a few voids in the area 2090-2500', otherwise overall excellent bond. ptd# 92-156 Igrade NT80CHYE L-80 N-80 perfs: 4289-4351' top I bottom I hole size surface 131' 13 3/8" surface 1361' 121/4" surface 45001 8 1/2" 4196' TD: 4500' pbtd: 4406' Icementing record Calc. Top Driven 801 cf "G" 510 cf "G" Surf (94% excess) 478' DIO #7 WMRU 2A ptd# 93-155 perfs: 12480-13050' TD: 13475' pbtd: 13093' -~ Casing size wtlft Igrade top bottom I hole size Icementing record Calc. Top 20" 133 J-55 0 2190 26" 2696 sx "G" 94' 13 3/8" 68 N-80 0 - 6429 17.5" 1700 sx "G" 3566' 9 5/8" 47-53.5 NT95/L80 0 11390 12.25" 765 sx "G" 8532' 7 5/8" 29 NT95/L80 11039 12981 8.5" 350 sx "G" 7654' 5 1/2" 17 L80 12790 13390 6.75" 115 sx "G" 11777' 3 1/2" tbg 12445' CMT log evaluation: Formation microscanner 11380-12970' WMRU 1A ptd# 95-118 perfs: 13572-13844' Casing size wt/ft grade top bottom hole size 20" 133 K-55 Surf 2201 26" 133/8" 68 NT-80 Surf 6211 17 1/2" 95/8" 47&53.5 L-80 Surf 11502 121/4" 75/8" 29.04 L-80 10031 13456 8 1/2" 5 1/2" 17 L-80 13348 14200 63/4" 3 1/2" tbg 13844' CMT log evaluation: (CBT/CET/GR/CCL) 12985-14100' Excellent bond below 13170' TD: 14200' pbtd: 14119' Icementing record Calc. Top 4896 cf "G" Surf (32% excess) 2543 cf "G" 2550' 1224 cf "G" 7594' 121 cf "G" 11884' 115 cf "G" 12823' -~ WMRU 3 ptd# 94-11 3 perfs: 14696-14860' TO:' 15450' pbtd: 15280' Casing size wt/ft grade top bottom hole size Icementing record Calc. Top 20" 133 K-55? Surf 117 Driven 16" 75 K-55 Surf 2361 2027 cf "G" Surf (82% excess) 10 3/4" 45.5 K-55 Surf 7343 511 cf"G" 7 5/8" 29 L-80 6817 14161 286 cf "G" 10445' 5 1/2" 17 L-80 13494 15450 6 3/4" 80 bbls 15.8 ppg 2 7/8" tbg 1460 l' CMT log evaluation: Formation microscanner 12680-14130' WMRU 4(D) ptd# 97-234 perfs: 5708-6130' Casing size wtIft Igrade top bottom Ihole size 20" 133 K-55 Surf 120 13 3/8" 68 L-80 Surf 2265 9 5/8" 47 L-80 Surf 5743 7 5/8" 29.7 L-80 5743 6243 2 7/8" tbg 5646 CMT log evaluation: adequate bond througout logged interval below 4600'. TD: pbtd: 6243 Icementing record ICalc. Top Driven 17 1/2 2811 cf "G" 12 1/4 846 cf "G" 8 1/2 109 cf "G" Surf (89% excess) 3042' 4827' 20" in 26" = 1.505 cf/lf, 1.286 sx/lf 13 3/8" in 17 1/2" = .6946 cf/lf, .5936 sx/lf 7 5/8" in 8 1/2" = .07695 cfllf, .0657 sx/lf 5 1/2" in 6 3/4" = .0835 cf/lf, .0713 sx/lf ~ #1 APPLICATION FOR DISPOSAL INJECTION ORDER WEST McARTHUR RIVER UNIT WELL NO.4 (D) FORCENERGYINC Submitted to the ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED Prepared by Jun 15 '\998 Forcenergy Inc Anchorage, Alaska ,i\laska Oil 8l Gas Cons. CommlSSÎQn Anchorage With assistance from Northern Consulting Group Anchorage, Alaska June 1998 Forcel\ðrgy Inc June 12, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: David W. Johnston, Commissioner Subject: Application for Disposal Injection Order by Forcenergy Inc West McArthur River Unit Well NO.4 (0) Cook inlet Area, Alaska Dear Commissioner Johnston: Forcenergy Inc, as operator of the West McArthur River Unit (WMRU), hereby makes application for a Disposal Injection Order to authorize the injection of Class II drilling and production wastes into the above referenced well. These wastes will be generated from drilling and production operations within the WMRU. The WMRU Well No 4 was originally drïHed as a production well and is being modified to accept Class II wastes, The modificatïons to convert the well to an injection well have been discussed with Mr. Blair Wonzell and Mr. Robert Crandall of your office; the enciosed application formally presents those topics discussed. A suitable injection zone has been identified between 5,136 ft and 5,556 ft TVD in the Well NO.4. The attached information supporting this application has been prepared and organized to address the eleven specific required components as outlined in 20 AAC 25.252 (c), Should you have any questions, please contact either Paul White or Rob Stinson in our Anchorage office (258-8600). Sincerely, ~~ Gary E. Carlson Vice President HEADQUARTERS Forcenergy Center 2730 SW 3rd Avenue Suite 800 Miami, Florida 33129-2237 REGIONAL OFFICE TELEPHONE 305/856-8500 FAX 305/856-4300 310 K Street Suite 700 Anchorage, Alaska 99501 TELEPHONE 907/258-8600 FAX 907/258-8601 ) ') ) TABLE OF CONTENTS 1. . LOCATION PLAT ......................................................................... 1-1 2. OPERATORS AND SURFACE OWNERS ....................................... 2-1 3. AFFIDAVIT OF OPERATOR AND LAND OWNER NOTIFICATION ........ 3-1 4. GEOLOGIC INFORMATION ........................................................... 4-1 4.1 GENERAL INFORMATION .......~.............................................. 4-1 4.2 WMRU WELL NO.4 (D) ......................................................... 4-1 5. WELL LOGS ............................................................................... 5-1 APPENDIX 5-A WELL LOG-WMRU WELL NO.4 (MD) APPENDIX 5-B WELL LOG-WMRU WELL NO.4 (TVD) 6. CASING AND CEMENTING PROGRAM ........................................... 6-1 6.1 CASING DESIGN ........................................................ ........ ... 6-1 6.2 CEMENTING PROGRAM ........................................................ 6-1 'APPENDIX 6-A CEMENT EVALUATION GAMMA RAY-COLLAR LOG APPENDIX 6-B COMPENSATED CEMENT BOND GAMMA RAY- COLLAR LOG FLUIDS INJECTED ..... ......... ..... ....... ... ...... ............. ........... ............ 7-1 7.1 TYPES AND COMPOSITON OF FLUIDS .................................. 7-1 7.2 AREA OF INJECTION ............................................................. 7-1 7. ) 8. 9. 10. 11. INJECTION PRESSURES ............................................................. 8-1 FRACTURE INFORMATION .......... .... ... ...... ........... ... .......... ...... ...... 9-1 WATER QUALITY IN INJECTION ZONE ...........................................10-1 APPENDIX 10-A SALINITY PLOTS FOR WFU-2 FRESHWATER EXEMPTIONS ..................................................... ..11-1 #1 l 1.0 LOCATION PLAT The attached Figure 1-1 shows the' locations of the following wells that penetrate the proposed injection zone within % mile of the proposed injection well (per 20 MC 25.252 (c)(1 )): Other Wells Description WMRU Disposal Well No. 1 (Existing) WMRU Well No.4 (D) (Proposed) WMRU Well No. 1A WMRU Well No. 2A WMRU Well No. 3ST WMRU Well No.5 Pan Am West Foreland Unit Well No.2 Item Storage and Disposal Wells Production Wells ~ 1-1 01 4000feet -----WMRU::3L,. , . I WMRU-5 WMRU6sT , /0WMRU-14 I ~~ I I WMRU-~ I , / : --I------t- / I I , I I t I I ......... ~ WMRU-4 , --+--------t- , I I , t I : 22 : I I I ( , t ~. -+------ ( I , W~RU Qt( ~ I I , .... . ..... .... -t--r-~- 1 Y4 -Mile Radius I I I I , I ( 9 I West Foreland Unit #2 ~5 2~ Figure 1-1. Locations of Existing and Proposed Wells. 1-2 #2 ~ ( 2.0 OPERATORS AND SURFACE OWNERS The following provides a list of all operators and surface owners within % mile of the proposed injection well: Classification Operator-West McArthur River Unit Operator-West Foreland Unit Surface Owner-Surface Location Subsurface Owner-Disposal Zone Subsurface Owner-Adjacent Lands Namel Address Forcenergy Inc 310 K Street, Suite 700 Anchorage, Alaska 99501 Phillips Petroleum Company P.O. Drawer 66 Kenai, Alaska 99611 Salamatof Native Association, Inc. 110 Willow Street, Suite 150 Kenai, Alaska 99611 Cook Inlet Region, Inc. P. O. Box 93330 Anchorage, Alaska 99509-3330 State of Alaska Department of Natural Resources Division of Oil and Gas 3601 C Street, Suite 1380 Anchorage, Alaska 99503-5948 ( Figure 2-1 shows nearby boundaries for these owners and operators. 2-1 I .......r.............r------...~........r....-... ,........_._~____~________: · · · · · · ~ · · · · · · · · · · · · · · · 5 \ Forcenergy ADL 359111 4 3 Unocal ADL 17602 2 'VMRU-5 . · :WMRU-3ST 8 9 WV1RU-2A 1~ · ~MRU_111 · · · · ~ Salamatof Native Assoc. I CIRI I + WFU-2 ~16 15 WMRJ D-1(- ....~ . . _'~"",~, 1/4 Mile Radius : . WMRU-4 · ........................ ....~....~....~.. · · Salamatof Native Asšoc. 17 14 20 21 22 Forcenergy ADL 359112 ( · r"1 Phillips 29 A-035017 27 ....~'l3. ... ..., ... .\ Salamatof Native Assoc. . I CIRI I 33 ~4 Cook Inlet Bluff \_- 35 .................~ I I I Forcenergy : ADL : 381012 : I · · · · ~ 32 1? · · · · · ....I!...~ 13 ................ 24 25 36 Scale: 1" = 1 mile T8N, R14W, Seward Meridian Figure 2-1. Location Map for Operators and Suñace Owners 2-2 #3 ) ) 3.0 AFFIDAVIT OF OPERATOR AND LAND OWNER NOTIFICATION ) The attached affidavit a~tests that all owners and operators within % mile of the injection well have been provided a copy of this application. ) 3-1 ) AFFIDAVIT OF NOTIFICATION OF OPERATORS AND SURFACE OWNERS ) THIRD JUDICIAL DISTRICT STATE OF ALASKA I, Gary E. Carlson, declare and affirm that I am an Officer for Forcenergy Inc, that I have personal knowledge of the matters set forth in this affidavit, and that on the I 2.~ day of June, 1998, the following operators and surface owners were provided a copy of this permit application: Cook Inlet Region, Inc. P.O. Box 93330 Anchorage, Alaska 99509-3330 Salamatof Native Association, Inc. 110 Willow Street, Suite 105 Kenai, Alaska 99611 Phillips Petroleum Company P. O. Drawer 66 Kenai, Alaska 99611 ) ) State of Alaska Department of Natural Resources Division of Oil and Gas 3601 C Street, Suite 1380 Anchorage, Alaska 99503-5948 by placing said copy in the United States Mail with postage prepaid and certified at Anchorage, Alaska. ~. ~-I . ':rZ r!dki~~,j Ga E. Carlson tl-", Subscribed and Sworn to before me on this 12 day of June, 1998. My Commission expires: / () v/_, 0'0 ~,,\\\\\\IJ.IIIII"~ ~¿\-.£: r~O~ ~.... .Yo C!I a III ~ ~."",,~fI .srAð.~~ .::::; '" - Q 0,' 1fT e"p -:;. =:~. '£'O~::: -- ~ '""'" ..- -.eotlllllii¡ 1!fc;>lRI\\",," e - -.z:; .. Þ.. - :::. 0A) ~e;: ~ ø 'iRB" ~ 01$~ ~ 4D..0 U "". ~i§ ~-11~ ~ II ... ~~ ~/, ~~. Of ~~~ 1IIIU~n~\\\\\~ /.~~ /' . ...! ../" b-··~·-/ ~ Notary Public in the State of Alaska 3-2 #4 ) ) ) 4.0 GEOLOGIC INFORMATION 4.1 General Conditions Geological sequences for the WMRU Well No.4 (D) are indicated on Table 4-1 as follows: Table 4-1. General Stratigraphy for the Area. Depth (feet, TVD) 0-400 est. Sequence Quarternary Deposits 400-600 est. Beluga Formation 600-11,300 est. Tyonek Formation ) Description Unconsolidated and poorly sorted mixture of clay, silt, sand and cobbles. Huge angular igneous boulders are locally present (a result of glaciation). Thin intercalcated beds of claystone, siltstone, sandstone, and lignitic to sub-bituminous coal. Contains massive sandstone and coal beds. The sandstone is fine to medium grained, interbedded with bentonitic claystone, siltstone, and lignitic to sub-bituminous coal. The sandstone is light to medium gray, loosely cemented by a bentonitic clay matrix. Coarse sand grains and pebbles are scattered throughout the sandstone along with volcanic rock grains. Examination of information for the general area suggests the stratigraphy is generally trackable between wells. 4.2 WMRU Well No.4 (D) The proposed disposal zone lies within the Tyonek Formation between depths of 5,136 ft to 5,556 ft TVD (5,743 to 6,243 ft MD). Because of the well design (see Section 5), it is anticipated that some communication will occur between the injection area and the original wellbore for the WMRU Well No.4. If this occurs disposed materials could migrate down the original wellbore to the top to the cement plug at a depth of 8,875 ft TVD or 9,731 ft MD (see Section 6). For demonstration of compliance with the provisions of 20 AAC 25.252, it is assumed that the injection zone will be from 5,136 ft to 8,875 ft TVD (5,743 to 9,731 ft MD). 4-1 ) ) ) Table 4-2 provides a detailed analysis of specific stratigraphy for the WMRU Well No.4 (D) including potential confining layers above the proposed injection area. The stratigraphic sequence of the WMRU Well No.4 (D) is as follows: Depth 2,815-4~090 ft TVD (2,985-4,500 ft MD) 4,090-4,170 ft TVD (4,500-4,595 ft MD) 4,1.70-5,136 ft TVD (4,595-5,743 ft MD) 5,136-5,635 ft TVD (5,743-6,305 ft MD) 5,136-8,875 ft TVD (5,743-9,731 ft MD) 8,875-8,980 ft TVD (9,731-9,840 ft MD) ), ,1 Comments 8 confining layers ranging in thickness from 15 to 90 ft (total confining thickness of 320 ft). . Probable extension of zone of injection at WMRU Well No. D-1. 6 confining layers ranging in thickness from 1 0 to 40 ft (total confining thickness of 175 ft). Proposed zone of injection for WMRU Well No. 4 (D). Includes two layers containing sand (139 and 350 feet thick). Zone where fluids may enter through communication through the wellbore for WMRU Well No.4. Includes 17 layers containing sand (ranging from 20 to 360 ft thick). 105 ft thick bottom confining layer to prevent downward migration. There are at least 14 confining layers between the proposed injection zone and the surface having a total thickness of at least 495 feet. There is at least one thick (105 ft) confining zone beneath the area where injected fluids could flow. 4-2 ) ) Table 4-2. Detailed Stratigraphy for the WMRU Well No.4 (D). Depth Depth Thickness Primary Comments (feet, TVD) (feet, MD) (feet) Lithology 2,815-2,905 2,985-3,090 90 Tuffaceous claystone Confining Layer 2,905-3,055 3,090-3,270 50 Sand wI coal seams 3,055-3,070 3,270-3,285 15 Tuffaceous claystone Confining Layer. 3,070-3,245 3,285-3,495 175 Sand wI coal seams 3,245-3,260 3,495-3,510 15 . Tuffaceous claystone Confining Layer 3,260-3,275 3,510-3,530 15 Sand wI coal 3,275-3,300 3,530-3,560 25 Tuffaceous claystone Confining Layer 3,300-3,555 3,560-3,865 255 Sand wI coal and claystone seams 3,555-3,570 3,865-3,880 15 Coal Confining Layer 3,570-3,760 3,880-4,110 190 Sand wI coal and claystone seams 3,760-3,780 4,110-4,135 20 Coal and claystone Confining Layer 3,780-3,900 4,135-4,275 120 Sand, claystone, and coal 3,900-4,015 4,275-4,415 115 Tuffaceous claystone Confining Layer and coal .,/" 4,015-4,065 4,415-4,4 70 50 Sandstone and claystone 4,065-4,090 4,4 70-4,500 25 Tuffaceous claystone Confining Layer ( and coal ) 4,090-4,170 4,500-4,595 80 Sand wI claystone Probable Well D-1 Disposal Zone 4,170-4,195 4,595-4,625 25 Coal and claystone Confining Layer 4,195-4,395 4,625-4,860 2QO Sand wI coal seams 4,395-4,405 4,860-4,875 1,,10;, Tuffaceous claystone Confining Layer 4,405-4,420 4,875-4,895 15 N/A 4,420-4,460 4,895-4,940 40 Tuffaceous claystone wI Confining Layer coal seams ..-- 4,460-4,590 4,940-5,095 130 Sand wI claystone seams 4,590-4,625 5,095-5,135 35) Tuffaceous claystone Confining Layer '/' 4,625-4,665 5,135-5,180 40 Sand and claystone 4,665-4,715 5,180-5,240 50 Tuffaceous claystone wI Confining Layer coal seams 4,715-4,895 5,240-5,455 189 Sand wI coal seams 4.895-4,910 5,455-5,475 1q Tuffaceous claystone Confining Layer ./" 4,910-5,136 5,475-5,743 226 Sand wI claystone and coal \ 5,136-5,275 5,743-5,915 139 Sand wI claystone and Disposal Zone ---r I":. ') coal seams _..~ . 5,275-5,295 5,915-5,940 20 Coal wI claystone Disposal Zone 5.295-5,635 5,940-6,305 350 Sand and claystone wI Disposal Zone coal seams ) 4-3 ) 'Table 4-2. Detailed Stratigraphy for the WMRU Well No.4 (D) (Cont'd). ) Depth Depth Thickness Primary Comments (feet, TVD) (feet, MD) (feet) Lithology 5,635-5,685 6,305-6,355 50 Tuffaceous claystone wI Confining Layer coal seams 5,685-5,815 6,355-6,495 130 Tuffaceous claystone wI sand and coal seams 5,815-5,895 6,495-6,580 80 . Tuffaceous claystone Confining Layer and coal 5,895-5,915 6,580-6,600 20 Sand and claystone 5,915-6,185 6,600-6,890 270 Tuffaceous claystone Confining Layer and coal 6,185-6,210 6,890-6,915 25 Sand and claystone 6,210-6,800 6,915-7,535 590 Tuffaceous claystone Confining Layer and coal 7,535-7,695 150 Sand and claystone 7,695-7,775 75 Tuffaceous claystone Confining Layer and coal 7,775-7,845 65 Sand, claystone, and tuff 7,845-7,910 60 Tuffaceous claystone Confining Layer and coal 7,910-7,940 30 Sand and claystone ') 7,940-8,050 105 Tuffaceous claystone, Confining Layer shale, and coal 8,050-8,100 50 Sand and claystone 8,100-8,200 95 Tuffaceous claystone, Confining Layer tuff, and coal 8,200-8,540 360 Sand wI coal seams 8,540-8,750 200 Tuffaceous claystone Confining Layer and coal 8,750-8,805 50 Sand wI claystone and coal 8,805-8,840 35 Tuffaceous claystone Confining Layer and coal 8,840-8,885 45 Sand and claystone 8,885-8,935 50 Tuffaceous claystone Confining Layer and coal 8,935-9.050 110 Tuffaceous claystone wI sand and tuff 9,050-9,095 45 Coal wI shale and Confining Layer claystone 9,095-9,165 65 Sand wI coal and claystone 9,165-9,230 60 Tuffaceous claystone wI Confining Layer coal and shale 9,230-9.300 65 Claystone wI sand, coal and tuff 4-4 ) ) Table 4-2. Detailed Stratigraphy for the WMRU Well No.4 (D) (Cont'd). ) Depth Depth Thickness Primary Comments (feet, TVD) (feet, MD) (feet) Lithology 9,300-9,325 25 Coal Confining Layer 9,325-9,385 60 Claystone wI sand, coal and tuff 9,385-9,400 15 Coal wI claystone Confining Layer 9,400-9,435 35 Claystone wI sand and shale 9,435-9,485 50 Tuffaceous claystone Confining Layer and coal 9,485-9,560 70 Claystone wI sand 9,560-9,585 25 Tuffaceous claystone Confining Layer and coal 9.585-9,625 40 Claystone wI sand 9,625-9,840 70 Tuffaceous claystone wI Confining Layer- clay and tuff Top of Cement at 9,731' MD ) 4-5 #5 ) 5.0 WELL LOGS WeUlogs for the WMRU Well No.4 are provided in the pocket behind this page. A description to the general stratigraphy is provided in the previous section. Logs for the well are provided in the following Appendices. ): 'II ,I 5-1 ) ') ) \.\ APPENDIX 5-A WELL LOG-WMRU WELL NO.1 (MD) ) \ .~ APPENDIX 5-8 WELL LOG-WMRU WELL NO.1 (TVD) #6 ') ) 6.0 CASING AND CEMENTING PROGRAM 6.1 Casing Design Figure 6-1 provides a schematic of the WMRU Well No.4 (D). Casing used is as indicated as follows: Table 6-1. Summary of Casing/Liners for the WMRU Well No.4 . Depth Depth Size . Description Comments (feet, TVD) (feet, MD) (inches) 0-120 0-120 20 133 Ib/ft; K-55; Internal Driven casing Yield of 3,060 psi. 0-2,203 0-2,265 13 3/8 68 Ib/ft; L-80 BTC; Drilled casing Internal Yield of 5,020 psi. 0-5,136 0-5,743 9 5/8 47 Ib/ft; L-80 BTC; Drilled casing Internal yield of 6,870 psi. 0-5.056 0-5,646 2 7/8 6.5 Ib/ft, L-80 AB Mod Injection line threads, Plastic coated; Internal yield of 10,570 psi; Packer to 9 5/8 set at 4,994' TVD (5,572' ) MD). 5,136-5,556 5,743-6,243 7 5/8 29.7 Ib/ft; L80 wI FL-4S Drilled and thread; Internal yield of perforated liner 6,890 psi. (Injection zone) 6.2 Cementing Program The 13 3/8" casing has been cemented from the bottom of the casing (2,203' TVD; 2.265' MD) to the ground surface. The 9 5/8" casing has been cemented from 5,051 to 5,136 feet TVD (5,640 to 5,743 feet MD) and has been pressure tested to 1,000 psi with no pressure loss in 15 minutes. The cement logs for the well are provided in Appendix 6-A and 6-8. 6-1 ) ) Packer @ 4,994' TVD; 5.572' MD z z 27/8" Tubing @ 5.056' TVD; 5.646' MD J 7 5/8" Liner @ 5,556' TVD; 6,243' MD Cemented and Perforated Driven 20" @ 120' TVD; 120' MD Cement to Sùrface 13 3/8" @ 2,203' TVD; 2,265' MD ~'" 4bOÓ " PL.L R.o6 &ttl\l~ON ~ '1/'l-Jqß Top of Cement @ 5.051' TVD; ~ MD 95/8" @ 5.136' TVD; 5,743' MD Bridge Plug @ 5.322' TVD; 5,960' MD Top of Cement @ 8.875' TVD; 9,731' MD TD @ 11,875' MD, 10,951' TVD Figure 6-1. Schematic of the WMRU Well No.4 (D). 6-2 ) ,~I \ ~ ) APPENDIX 6-A CEMENT EVALUATION GAMMA RAY-COLLAR LOG #7 ) ) 7.0 FLUIDS INJECTED 7.1 Types and Composition of Fluids Fluids planned to be injected into the injection well may include: 1. Waste drilling muds 2. Diluted drilling muds 3. Slurried drill cuttings 4. Completion fluids '5. Produced water 6. Waste cement (watered down) 7. Gray water and sanitary discharges from camp All waste fluids will be derived from and associated with oil and gas drilling and production at the West McArthur River Unit. All listed fluids are classified as non- hazardous by the U. S. Environmental Protection Agency and are suitable for injection into Class II wells. Both water-based and oil-based drilling muds may be disposed of in the injection well. General characteristics of the various types of discharges are contained in tables provided on the following pages. 7.2 Area of Injection It is estimated that up to 6,000 barrels per day of fluids may be injected during periods of maximum ÎIljection activity. Produced water could be injected at a rate of about 3,000 to 4,000 barrels per day. Average anticipated injection rates for drilling fluids will be about 2,000 to 3,000 barrels per day during drilling operations. The total annual volume of injected fluids will be dependent on the duration of future drilling operations but is anticipated to be about 1,000,000 to 2,000,000 barrels. The radius of invasion around the wellbore may be estimated by: R = (V/1th~)1/2 where R = radius of invasion (feet) V = volume injected (ft3) h = height of thickness of disposal zone (feet) ~ = porosity (%) For this analysis, the following values have been assumed: V = (1,500,000 barrels/year)(10 years) = 84,200,000 ft3 H = (5,556 - 5,136 ft)(75% permeable) = 336 ft ~ = 20 0/0 With these assumptions the radius of invasion would be on the order of 630 feet after 10 years of injection to the well. 7-1 ) ) Table 7-1. General Composition of Water Based Drilling Muds. Material Percent by Weight Water Bentonite Barite Potassium Chloride (KCI) Polyanionic Cellulose Potassium Hydroxide Caustic Soda PHPA Polymer Sodium Nitrate Lime Caustic Soda Soda Ash Sodium Bicarbonate . Chrome-free Lignosulfonate Drilled Solids/Cuttings Cement 80 - 90 3-4 2 - 20 0-5 0-0.7 0-0.1 0-1.1 0-0.5 o - 0.02 0-0.5 0-1 0-0.5 0-1 0-2 1 0 - 20 0-5 Table 7-2. General Composition of Oil Based Drilling Muds. Material Percent by Weiaht Diesel Water Bentonite Barite Potassium Chloride (KCI) Polyanionic Cellulose Potassium Hydroxide Caustic Soda PHPA Polymer Sodium Nitrate Um~ Caustic Soda Soda Ash Sodium Bicarbonate Chrome-free Ugnosulfonate Drilled Solids/Cuttings Cement 65-75 10-20 3-4 2 - 20 0-5 0-0.7 0-0.1 0-1.1 0-0.5 o - 0.02 0-0.5 0-1 0-0.5 0-1 0-2 10 - 20 0-5 7-2 ) Table 7-3. General Composition of Completion Fluids Material Percent by Weight Water Potassium Chloride Corrosion Inhibitor Defoamer 75 24 0.5 0.5 Table 7-4. General Composition of Gray Water/Sanitary Wastes. Material Percent by Weight Water Human Wastes Detergents Paper Products 60-90 1 0-20 0-5 0-5 ) 7-3 #8 ) 8.0 INJECTION PRESSURES The average surface injection pressure is estimated to be approximately 3,000 to 3,300 psi, and the maximum surface injection pressure will be 4,000 psi. At a depth of 5,136 feet, the formation fracture pressure is estimated to be as much as 4,100 psi. The casing head has a 5,000 psi working pressure and 10,000 psi test pressure. The internal yield of the 9 5/8" casing is 6,870 psi, and the 2 7/8" injection line has an internal yield of 10,570 psi. ) 8-1 #9 9.0 FRACTURE INFORMATION The proposed injection formation may be fractured periodically to enhance the ability of the formation to accept fluids. The induced fractures will, however, be localized near the wellbore and confined to the injection zone. The proposed injection formation is confined above and below by a series of tight interbedded claystones, siltstones, and coals (see Section 4), which are known to be effective confining layers and barriers to fracture propagation in the Cook Inlet Basin. In addition, the claystones in particular are plastic in nature and further augments their ability to provide containment. The injection zone and associated confining beds are laterally continuous in the general area based on well. A specific correlation of the general geology of the area was previously described in the Application for Disposal Injection Order for the West McArthur River Unit Well No. D-1 that was submitted by Stewart Petroleum CompanylENSR Consulting and Engineering (dated March 1993). Well logs provided for the WMRU Well No.4 (D) are consistent with the conditions described in this previous application. This previous application also reported results of fracture modeling for the existing disposal well (WMRU Well No. D-1) which considered a higher confining zone. The model was run at a pumping rate of 5 barrels per minute (7,200 barrels per day) and at a maximum surface pressure of 5,000 psi; results of this model indicate that: ( II... Even under these worst case (impossible) injection conditions, the model demonstrates that induced fractures would be confined to the injection zone. ... These conclusions are also believed to be appropriate for the proposed injection well. ( 9-1 #10 10.0 WATER QUALITY IN INJECTION ZONE Estimates of injection zone salinities are based on well data from the West Foreland Unit #2 (WFU-2) well located just north of the proposed injection well WMRU Well NO.4 (0). Comparison of logs indicate that the primary injection zone in the proposed injection well (5,136-5,556 ft TVD; 5,743-6,643 ft MD) correlates to the interval of approximately 5,175-5,600 ft TVO (5,520-5,980 ft MD) in the WFU-2 well. Appendix 10-A provides a log for the WFU-2 well that provides a plot of salinities with depth. Salinities were calculated using the Schlumberger method which accounts for fluid conductivities and temperatures. Within the primary injection zone (5,136-5,556 ft TVD; 5,743-6,643 ft MO in the proposed injection well), the average salinities are on the order of 20,000 ppm. These levels are considered suitable for use as an injection zone for Class II fluids. ~ ( 10-1 \, APPENDIX 10-A SALINTY PLOTS FOR WFU-2 ~ #11 11.0 FRESHWATER EXEMPTIONS Forcenergy Inc does not intend to submit an application for a freshwater aquifer exemption in the disposal zone in the WMRU We1l No.4. Formation fluids in the zone have total dissolved solids in the formation fluids greater than 10,000 ppm. ( 11-1 APPENDIX 6-B COMPENSATED CEMENT BOND GAMMA RAY-COLLAR LOG