The URL can be used to link to this page

Home My WebLink AboutAEO 007 e e INDEX AQUIFER EXEMPTION ORDER NO 7 REDOUBT UNIT WELL REDOUBT UNIT Dl 1. May 8, 2001 2. May 9, 2001 3. June 1,2001 4. June 5, 2001 5. June 15,2001 6. June 20, 2001 7. July 25,2001 8. July, 2001 9. July, 2001 10. August 1,2001 11. August3, 2001 12. August 3,2001 Forest Oil's Application for Underground Injection and Aquifer Exemption Notice of Hearing, ad order and mailing list AOGCC letter (Tom's) questions regarding Application Forest answers to questions AOGCC questions regarding Application Forest response to questions Sign In Sheet for meeting w/Forest Oil Forest Oil's Revised Application for Underground Injection And Aquifer Exemption Lease Descriptions EP A's letter to Commission re: Application Casing Schematic Forest Oil's submittal ofRU DI Casing Schematic AQUIFER EXEMPTION ORDER NO 7 . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: THE REQUEST OF FOREST OIL CORPORATION for an Aquifer Exemption Order for the Redoubt Unit #D 1 well, Sec.14, T7N, R14W, Seward Meridian, offshore Cook Inlet. ) Aquifer Exemption Order No.7 ) ) Upper Tyonek Formation ) Redoubt Unit Well Redoubt Unit #D1 August 1, 2001 IT APPEARING THAT: 1. Forest Oil Corporation ("Forest") submitted an application, dated May 9, 2001, requesting that the Alaska Oil and Gas Conservation Commission issue an aquifer exemption for purposes of Class II disposal in the Redoubt Unit #D 1 well. Additional information requested by the Commission was received on June 5, June 22 and July 5, 2001. Subsequent to numerous changes, a revised application for aquifer exemption and disposal injection orders was submitted on July 27,2001. 2. The Commission published notice of an opportunity for a public hearing in the Anchorage Daily News and Peninsula Clarion on May 14, 2001. 3. The Commission did not receive any protest or request for a public hearing. 4. The Commission has jurisdiction in this matter under AS 31.05.030(h), 20 AAC 25.440, and 40 CFR 147, Subpart C - Alaska. 5. The Commission submitted a copy of Forests' Aquifer Exemption application to the U.S. Environmental Protection Agency, Region 10, ("EPA Region 10") on May 10, 2001, in accordance with Section 14 ofthe November 22, 1991 Memorandum of Agreement between EP A Region 10 and the Commission. A copy ofthe revised application was submitted to EPA Region 10 on July 27,2001. 6. The Commission submitted a copy of a proposed aquifer exemption order to EP A Region 10 on July 31,2001. 7. EP A Region 10 did not obj ect to the aquifer exemption order for the Redoubt Unit. FINDINGS: 1. In correspondence dated May 8, 2001 Forest requested an order authorizing Class II disposal into the Tyonek Formation in the Redoubt Unit #D1 well. Subsequent to numerous plan changes and data correction efforts, a revised application was submitted on July 27,2001. 2. The Redoubt Unit ("RU") is located offshore in Cook Inlet, approximately 2 miles east the West Forelands area, and is being developed from the Osprey platform. . . Aquifer Exemption Order #7 Redoubt Unit August 1, 2001 Page 2 3. Development of the RU calls for drilling the surface hole sections with water-based drilling fluid systems and the lower hole sections with oil-based systems. Operators in Cook Inlet are prohibited from discharging oil-based drilling fluids. Current disposal options are limited to either annular disposal or Class II injection in approved wells. 4. Wire line log analytical techniques, which are compliant with EP A recommended methods as described in "Survey of Methods to Determine Total Dissolved Solids Concentrations", (KEDA Project No. 30-956), were used to characterize formation water salinities in the Redoubt Unit. 5. Wireline log analysis from the RU #Dl well show the proposed Class II disposal injection zone contains freshwater with a total dissolved solids (TDS) concentration generally between 3,000 and 10,000 mgll. 6. Current perforations in the RU #Dl well are between 8216' and 8450' measured depth (MD), within sandstones of the Tyonek Formation. Forest intends to also perforate and inject into another sand interval between 7650' and 7900' MD. A packer is currently set at 7620' MD. 7. Forest has requested an Aquifer Exemption Order (AEO) for all aquifers below 3749' MD (3650' true vertical depth subsea) and within one-half mile radius ofthe RU #Dl well, to prepare for the possibility of a need for Class II disposal into intervals at shallower depths than originally anticipated. 8. The proposed disposal interval is overlain and confined by siltstones, coals and shales within the Tyonek and Beluga Formations which will prevent vertical migration of Class II wastes into formation waters with TDS content less than 3000 mgll. 9. The closest drinking water well to the RU is located onshore, approximately 8 miles to the northwest, in the West McArthur River Unit. 10. All freshwater used by the Osprey platform is brought to the platform by boat. Forest has no plans to use the underlying aquifers as a source of drinking water. 11. Development of the freshwater aquifers below the RU by entities other than Forest is economically impractical because of the offshore location, water depths and currents, drilling costs and readily available alternative freshwater sources onshore. 12. The Commission's authority to act in this matter is embodied in 40 CFR 147 Subpart C, the Alaska Oil and Gas Conservation Act (AS 31.05), and the Alaska Administrative Code (20 AAC 25.005 through 20 AAC 25.570). 13. Portions of aquifers beneath the Cook Inlet underlying the Granite Point, McArthur River, Middle Ground Shoal and Trading Bay fields, regardless of total dissolved solids content, were exempted for Class II injection activities by EPA under 40 CFR 147.102. 14. On September 29, 1998, the Commission exempted the portions of aquifers in North Cook Inlet Field common to and which correlate with the interval below 2900' MD in the NCIU A-12 well. CONCLUSIONS: 1. Those portions of freshwater aquifers occurring beneath the Redoubt Unit do not currently serve as a source of drinking water. Aquifer Exemption Order #7 Redoubt Unit August 1, 2001 . . Page 3 2. Those portions of freshwater aquifers occurring beneath the Redoubt Unit are situated at a depth and location that makes recovery of water for drinking water purposes economically impractical. 3. Those portions of aquifers occurring beneath and within one-quarter mile radius of the Redoubt Unit cannot reasonably be expected to serve as an underground source of drinking water. 4. Those portions of aquifers occurring within a one-half mile radius and below the depth of 3749' MD in the Redoubt Unit #DI well qualify as exempt freshwater aquifers under 20 AAC 25.440(a)(2). NOW, THEREFORE, IT IS ORDERED THAT the aquifers occurring within a one-half mile radius and below the depth 0[3749' MD (3650' TVDSS) in the Redoubt Unit #Dl well are exempt under 20 AAC 25.440. DONE at Anchorage, Alaska, and dated August 1, 2001. fiLL¿¿· ÞI-e~u:A-:2e/r-- Julie M. Heusser, Commissioner Alaska Oil and Gas Conservation Commission AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23rd day 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 IO-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30-day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., 10th day after the application for rehearing was filed). OFFICE OF THE GOVERNOR, JOHN KATZ STE 518 444 N CAPITOL NW WASHINGTON, DC 20001 LIBRARY OF CONGRESS, STATE DOCUMENT SECTION EXCH & GIFT DIV 10 FIRST ST SE WASHINGTON, DC 20540 US GEOLOGICAL SURVEY, LIBRARY NATIONAL CTR MS 950 RESTON, VA 22092 AMOCO CORP 2002A, LlBRARYIINFO CTR POBOX 87703 CHICAGO, IL 60680-0703 ALFRED JAMES III 107 N MARKET STE 1000 WICHITA, KS 67202-1811 XTO ENERGY, SUSAN LILLY 210 PARK AVE STE 2350 OKLAHOMA CITY, OK 73102-5605 OIL & GAS JOURNAL, LAURA BELL POBOX 1260 TULSA, OK 74101 US DEPT OF ENERGY, ENERGY INFORMATION ADMINISTRATION MIR YOUSUFUDDIN 1999 BRYAN STREET STE 1110 DALLAS, TX 75201-6801 XTO ENERGY, MARY JONES 810 HOUSTON ST FORT WORTH, TX STE 2000 76102-6298 . PIRA ENERGY GROUP, LIBRARY 3 PARK AVENUE (34th & PARK) NEW YORK, NY 10016 ARENT FOX KINTNER PLOTKIN KAHN, LIBRARY WASHINGTON SQ BLDG 1050 CONNECTICUT AV NW WASHINGTON, DC 20036-5339 US DEPT OF ENERGY, PHYLLIS MARTIN MS EI823 1000 INDEPENDENCE SW WASHINGTON, DC 20585 DPC, DANIEL DONKEL 1420 NORTH ATLANTIC AVE, STE 204 DAYTON BEACH, FL 32118 ILLINOIS STATE GEOL SURV, LIBRARY 469 NATURAL RESOURCES BLDG 615 E PEABODY DR CHAMPAIGN,IL 61820 MURPHY E&P CO, ROBERT F SAWYER POBOX 61780 NEW ORLEANS, LA 70161 10GCC, POBOX 53127 OKLAHOMA CITY, OK 73152-3127 GAFFNEY, CLINE & ASSOC., INC., LIBRARY 16775 ADDISON RD, STE 400 ADDISON, TX 75001 DEGOL YER & MACNAUGHTON, MIDCONTINENT DIVISION ONE ENERGY SQ, STE 400 4925 GREENVILLE AVE DALLAS, TX 75206-4083 SHELL WESTERN E&P INC, G.S. NADY POBOX 576 HOUSTON, TX 77001-0574 . NY PUBLIC LIBRARY DIV E, GRAND CENTRAL STATION POBOX 2221 NEW YORK, NY 10163-2221 US MIN MGMT SERV, CHIEF OCS STATS & INFO 381 ELDEN ST MS 4022 HERNDON, VA 20170-4817 TECHSYS CORP, BRANDY KERNS PO BOX 8485 GATHERSBURG, MD 20898 SD DEPT OF ENV & NA TRL RESOURCES, OIL & GAS PROGRAM 2050 W MAIN STE #1 RAPID CITY, SD 57702 LINDA HALL LIBRARY, SERIALS DEPT 5109 CHERRY ST KANSAS CITY, MO 64110-2498 UN IV OF ARKANSAS, SERIALS DEPT UN IV LIBRARIES FAYETTEVILLE, AR 72701 R E MCMILLEN CONSULT GEOL 202 E 16TH ST OWASSO, OK 74055-4905 BAPIRAJU 335 PINYON LN COPPELL, TX 75019 STANDARD AMERICAN OIL CO, AL GRIFFITH POBOX 370 GRANBURY, TX 76048 H J GRUY, ATTN: ROBERT RASOR 1200 SMITH STREET STE 3040 HOUSTON, TX 77002 PURVIN & GERTZ INC, LIBRARY 2150 TEXAS COMMERCE TWR 600 TRAVIS ST HOUSTON, TX 77002-2979 OIL & GAS JOURNAL, BOB WILLIAMS 1700 W LOOP SOUTH STE 1000 HOUSTON, TX 77027 MARATHON OIL CO, GEORGE ROTHSCHILD JR RM 2537 POBOX 4813 HOUSTON, TX 77210 EXXON EXPLORATION CO., T E ALFORD POBOX 4778 HOUSTON, TX 77210-4778 PHILLIPS PETROLEUM COMPANY, W ALLEN HUCKABAY PO BOX 1967 HOUSTON, TX 77251-1967 EXXONMOBIL PRODUCTION COMPANY, J W KIKER ROOM 2086 POBOX 2180 HOUSTON, TX 77252-2180 MARATHON, Ms. Norma L. Calvert POBOX 3128, Ste 3915 HOUSTON, TX 77253-3128 TEXACO INC, R Ewing Clemons PO BOX 430 BELLAIRE, TX 77402-0430 INTL OIL SCOUTS, MASON MAP SERV INC POBOX 338 AUSTIN, TX 78767 DIANE SUCHOMEL 10507D W MAPLEWOOD DR LITTLETON, CO 80127 . RAY TYSON 2016 MAIN #1415 HOUSTON, TX 77002-8844 PETRAL CONSULTING CO, DANIEL L LIPPE 9800 RICHMOND STE 505 HOUSTON, TX 77042 UNOCAL, REVENUE ACCOUNTING POBOX 4531 HOUSTON, TX 77210-4531 CHEVRON USA INC., ALASKA DIVISION ATTN: CORRY WOOLlNGTON POBOX 1635 HOUSTON, TX 77251 WORLD OIL, DONNA WILLIAMS POBOX 2608 HOUSTON, TX 77252 PENNZOIL E&P, WILL D MCCROCKLIN POBOX 2967 HOUSTON, TX 77252-2967 ACE PETROLEUM COMPANY, ANDREW C CLIFFORD PO BOX 79593 HOUSTON, TX 77279-9593 WATTY STRICKLAND 2803 SANCTUARY CV KATY, TX 77450-8510 BABCOCK & BROWN ENERGY, INC., 350 INTERLOCKEN BLVD STE 290 BROOMFIELD, CO 80021 GEORGE G VAUGHT JR POBOX 13557 DENVER, CO 80201 . CHEVRON, PAUL WALKER 1301 MCKINNEY RM 1750 HOUSTON, TX 77010 MARK ALEXANDER 7502 ALCOMITA HOUSTON, TX 77083 EXXON EXPLOR CO, LAND/REGULATORY AFFAIRS RM 301 POBOX 4778 HOUSTON, TX 77210-4778 PETR INFO, DAVID PHILLIPS POBOX 1702 HOUSTON, TX 77251-1702 EXXONMOBIL PRODUCTION COMPANY, GARY M ROBERTS RM 3039 POBOX 2180 HOUSTON, TX 77252-2180 CHEVRON CHEM CO, LIBRARY & INFO CTR PO BOX2100 HOUSTON, TX 77252-9987 PHILLIPS PETR CO, PARTNERSHIP OPRNS JIM JOHNSON 6330 W LOOP S RM 1132 BELLAIRE, TX 77401 TESORO PETR CORP, LOIS DOWNS 300 CONCORD PLAZA DRIVE SAN ANTONIO, TX 78216-6999 ROBERT G GRAVELY 7681 S KIT CARSON DR LITTLETON, CO 80122 US GEOLOGICAL SURVEY, LIBRARY BOX 25046 MS 914 DENVER, CO 80225-0046 C & R INDUSTRIES, INC." KURT SALTSGAVER 7500 W MISSISSIPPI AVE STE C4 LAKEWOOD, CO 80226-4541 RUBICON PETROLEUM, LLC, BRUCE I CLARDY SIX PINE ROAD COLORADO SPRINGS, CO 80906 US GEOLOGICAL SURVEY, LIBRARY 2255 N GEMINI DR FLAGSTAFF, AZ 86001-1698 BABSON & SHEPPARD, JOHN F BERGQUIST POBOX 8279 VIKING STN LONG BEACH, CA 90808-0279 TEXACO INC, Portfolio Team Manager R W HILL POBOX 5197x Bakersfield, CA 93388 H L WANGENHEIM 5430 SAWMILL RD SP 11 PARADISE, CA 95969-5969 MARPLES BUSINESS NEWSLETTER, MICHAEL J PARKS 117 W MERCER ST STE 200 SEATTLE, WA 98119-3960 GUESS & RUDD, GEORGE LYLE 510 L ST, STE 700 ANCHORAGE, AK 99501 TRUSTEES FOR ALASKA, 1026 W. 4th Ave, Ste 201 ANCHORAGE, AK 99501 FOREST OIL, JIM ARLINGTON 310 K STREET STE 700 ANCHORAGE, AK 99501 . JERRY HODGDEN GEOL 408 18TH ST GOLDEN, CO 80401 JOHN A LEVORSEN 200 N 3RD ST #1202 BOISE, ID 83702 MUNGER OIL INFOR SERV INC, POBOX 45738 LOS ANGELES, CA 90045-0738 ANTONIO MADRID POBOX 94625 PASADENA, CA 91109 US GEOLOGICAL SURVEY, KEN BIRD 345 MIDDLEFIELD RD MS 999 MENLO PARK, CA 94025 ECONOMIC INSIGHT INC, SAM VAN VACTOR POBOX 683 PORTLAND, OR 97207 DEPT OF REVENUE, OIL & GAS AUDIT DENISE HAWES 550 W 7TH A V STE 570 ANCHORAGE, AK 99501 STATE PIPELINE OFFICE, LIBRARY KATE MUNSON 411 W 4TH AVE, STE 2 ANCHORAGE, AK 99501 DEPT OF ENVIRON CONSERVATION, DIV OF AIR & WATER QUALITY TOM CHAPPLE 555 CORDOVA STREET ANCHORAGE, AK 99501 DEPT OF REVENUE, DAN DICKINSON, DIRECTOR 550 W 7TH AVE, SUITE 500 ANCHORAGE, AK 99501 . NRG ASSOC, RICHARD NEHRING POBOX 1655 COLORADO SPRINGS, CO 80901- 1655 TAHOMA RESOURCES, GARY PLAYER 1671 WEST 546 S CEDER CITY, UT 84720 LA PUBLIC LIBRARY, SERIALS DIV 630 W 5TH ST LOS ANGELES, CA 90071 ORO NEGRO, INC., 9321 MELVIN AVE NORTH RIDGE, CA 91324-2410 SHIELDS LIBRARY, GOVT DOCS DEPT UNIV OF CALIF DAVIS, CA 95616 US EPA REGION 10, THOR CUTLER OW-137 1200 SIXTH AVE SEATTLE, WA 98101 FAIRWEATHER E&P SERV INC, JESSE MOHRBACHER 7151ST #4 ANCHORAGE, AK 99501 DEPT OF ENVIRON CONSERVATION, DIV OF ENVIRONMENTAL HEALTH JANICE ADAIR 555 CORDOVA STREET ANCHORAGE, AK 99501 DUSTY RHODES 229 WHITNEY RD ANCHORAGE, AK 99501 DEPT OF REVENUE, CHUCK LOGSTON 550 W 7TH AVE, SUITE 500 ANCHORAGE, AK 99501 DEPT OF REVENUE, BEVERLY MARQUART 550 W 7TH A V STE 570 ANCHORAGE, AK 99501 ALASKA DEPT OF LAW, ROBERT E MINTZ ASST ATTY GEN 1031 W 4TH AV STE 200 ANCHORAGE, AK 99501-1994 DEPT OF REVENUE, OIL & GAS AUDIT FRANK PARR 550 W 7TH AVE STE 570 ANCHORAGE, AK 99501-3540 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS JULIE HOULE 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 AK JOURNAL OF COMMERCE, OIL & INDUSTRY NEWS ROSE RAGSDALE 4220 B Street Ste #210 ANCHORAGE, AK 99501-3560 HDR ALASKA INC, MARK DALTON 2525 C ST STE 305 ANCHORAGE, AK 99503 BAKER OIL TOOLS, ALASKA AREA MGR 4710 BUS PK BLVD STE 36 ANCHORAGE, AK 99503 FINK ENVIRONMENTAL CONSULTING, INC., THOMAS FINK, PHD 6359 COLGATE DR. ANCHORAGE, AK 99504-3305 US BUREAU OF LAND MNGMNT, ANCHORAGE DIST OFC DICK FOLAND 6881 ABBOTT LOOP RD ANCHORAGE, AK 99507 US BLM AK DIST OFC, RESOURCE EV AL GRP ART BONET 6881 ABBOTT LOOP RD ANCHORAGE, AK 99507-2899 . YUKON PACIFIC CORP, JOHN HORN VICE CHM 1049 W 5TH AV ANCHORAGE, AK 99501-1930 GAFO,GREENPEACE PAMELA MILLER 125 CHRISTENSEN DR. #2 ANCHORAGE, AK 99501-2101 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS BRUCE WEBB 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 DNR, DIV OF OIL & GAS JAMES B HAYNES NATURAL RESRCE MGR 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS JIM STOUFFER 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 ANADARKO, MARK HANLEY 3201 C STREET STE 603 ANCHORAGE, AK 99503 ALASKA OIL & GAS ASSOC, JUDY BRADY 121 W FIREWEED LN STE 207 ANCHORAGE, AK 99503-2035 ARLEN EHM GEOL CONSL TNT 2420 FOXHALL DR ANCHORAGE, AK 99504-3342 US BUREAU OF LAND MNGMNT, ANCHORAGE DIST OFC PETER J DITTON 6881 ABBOTT LOOP ROAD ANCHORAGE, AK 99507 UOA/ ANCHORAGE, INST OF SOCIAL & ECON RESEARCH TERESA HULL 3211 PROVIDENCE DR ANCHORAGE, AK 99508 . PRESTON GATES ELLIS LLP, LIBRARY 420 L ST STE 400 ANCHORAGE, AK 99501-1937 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS TIM RYHERD 550 W 7th AVE STE 800 ANCHORAGE, AK 99501-3510 DEPT OF NATURAL RESOURCES, DIV OIL & GAS WILLIAM VAN DYKE 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 DEPT OF NATURAL RESOURCES, PUBLIC INFORMATION CTR 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 BRISTOL ENVIR SERVICES, JIM MUNTER 2000 W. INT'L AIRPORT RD #C-1 ANCHORAGE, AK 99502-1116 N-I TUBULARS INC, 3301 C Street Ste 209 ANCHORAGE, AK 99503 ANADRILL-SCHLUMBERGER, 3940 ARCTIC BLVD #300 ANCHORAGE, AK 99503-5711 JAMES E EASON 8611 LEEPER CIRCLE ANCHORAGE, AK 99504-4209 AMERICA/CANADIAN STRATIGRPH CO, RON BROCKWAY 4800 KUPREANOF ANCHORAGE, AK 99507 THOMAS R MARSHALL JR 1569 BIRCHWOOD ST ANCHORAGE, AK 99508 VECO ALASKA INC., CHUCK O'DONNELL 949 EAST 36TH AVENUE ANCHORAGE, AK 99508 US MIN MGMT SERV, RESOURCE STUDIES AK OCS REGN KIRK W SHERWOOD 949 E 36TH A V RM 603 ANCHORAGE, AK 99508-4302 US MIN MGMT SERV, FRANK MILLER 949 E 36TH A V STE 603 ANCHORAGE, AK 99508-4363 US MIN MGMT SERV, RESOURCE EVAL JIM SCHERR 949 E 36TH A V RM 603 ANCHORAGE, AK 99508-4363 CIRI, LAND DEPT POBOX 93330 ANCHORAGE, AK 99509-3330 PHILLIPS ALASKA, LEGAL DEPT MARK P WORCESTER POBOX 100360 ANCHORAGE, AK 99510-0360 PHILLIPS ALASKA, JOANN GRUBER A TO 712 POBOX 100360 ANCHORAGE, AK 99510-0360 PHILLIPS ALASKA, KUP CENTRAL WELLS ST TSTNG WELL ENG TECH NSK 69 POBOX 196105 ANCHORAGE, AK 99510-6105 US BUREAU OF LAND MGMT, OIL & GAS OPRNS (984) J A DYGAS 222 W 7TH AV #13 ANCHORAGE, AK 99513-7599 JODY COLOMBIE 6811 ROUND TREE DRIVE ANCHORAGE, AK 99516 . TRADING BAY ENERGY CORP, PAUL CRAIG 5432 NORTHERN LIGHTS BLVD ANCHORAGE, AK 99508 US MIN MGMT SERV, RICHARD PRENTKI 949 E 36TH AV ANCHORAGE, AK 99508-4302 REGIONAL SUPRVISOR, FIELD OPERA TNS, MMS ALASKA OCS REGION 949 E 36TH A V STE 308 ANCHORAGE, AK 99508-4363 JOHN MILLER 3445 FORDHAM DR ANCHORAGE, AK 99508-4555 PHILLIPS ALASKA, LAND MANAGER JIM RUUD P.O. BOX 100360 ANCHORAGE, AK 99510 PHILLIPS ALASKA, LAND DEPT JAMES WINEGARNER POBOX 10036 ANCHORAGE, AK 99510-0360 PHILLIPS ALASKA, MARK MAJOR A TO 1968 POBOX 100360 ANCHORAGE, AK 99510-0360 AL YESKA PIPELINE SERV CO, PERRY A MARKLEY 1835 S BRAGAW - MS 575 ANCHORAGE, AK 99512 ANCHORAGE DAILY NEWS, EDITORIAL PG EDTR MICHAEL CAREY POBOX 149001 ANCHORAGE, AK 99514 JWL ENGINEERING, JEFF LIPSCOMB 9921 MAIN TREE DR. ANCHORAGE, AK 99516-6510 . US MIN MGMT SERV, AK OCS REGIONAL DIR 949 E 36TH AV RM 110 ANCHORAGE, AK 99508-4302 GORDON J. SEVERSON 3201 WESTMAR CIR ANCHORAGE, AK 99508-4336 US MIN MGMT SERV, LIBRARY 949 E 36TH A V RM 603 ANCHORAGE, AK 99508-4363 USGS - ALASKA SECTION, LIBRARY 4200 UNIVERSITY DR ANCHORAGE, AK 99508-4667 ANCHORAGE TIMES, BERT TARRANT POBOX 100040 ANCHORAGE, AK 99510-0040 PHILLIPS ALASKA, STEVE BENZLER ATO 1404 POBOX 100360 ANCHORAGE, AK 99510-0360 PETROLEUM INFO CORP, KRISTEN NELSON POBOX 102278 ANCHORAGE, AK 99510-2278 AL YESKA PIPELINE SERV CO, LEGAL DEPT 1835 S BRAGAW ANCHORAGE, AK 99512-0099 DAVID W. JOHNSTON 320 MARINER DR. ANCHORAGE, AK 99515 NORTHERN CONSULTING GROUP, ROBERT BRITCH, P.E. 2454 TELEQUANA DR. ANCHORAGE, AK 99517 GERALD GANOPOLE CONSULT GEOL 2536 ARLINGTON ANCHORAGE, AK 99517-1303 ARMAND SPIELMAN 651 HILANDER CIRCLE ANCHORAGE, AK 99518 JACK 0 HAKKI LA POBOX 190083 ANCHORAGE, AK 99519-0083 MARATHON OIL CO, LAND BROCK RIDDLE POBOX 196168 ANCHORAGE, AK 99519-6168 EXXONMOBIL PRODUCTION COMPANY, MARK P EVANS PO BOX 196601 ANCHORAGE, AK 99519-6601 BP EXPLORATION (ALASKA) INC. PETE ZSELECZKY LAND MGR POBOX 196612 ANCHORAGE, AK 99519-6612 AMSINALLEE CO INC, WILLIAM 0 VALLEE PRES PO BOX 243086 ANCHORAGE, AK 99524-3086 D A PLATT & ASSOC, 9852 LITTLE DIOMEDE CIR EAGLE RIVER, AK 99577 COOK INLET KEEPER, BOB SHAVELSON PO BOX 3269 HOMER, AK 99603 DOCUMENT SERVICE CO, JOHN PARKER POBOX 1468 KENAI, AK 99611-1468 . DAVID CUSATO 600 W 76TH A V #508 ANCHORAGE, AK 99518 HALLIBURTON ENERGY SERV, MARK WEDMAN 6900 ARCTIC BLVD ANCHORAGE, AK 99518-2146 ENSTAR NATURAL GAS CO, PRESIDENT TONY IZZO POBOX 190288 ANCHORAGE, AK 99519-0288 UNOCAL, POBOX 196247 ANCHORAGE, AK 99519-6247 BP EXPLORATION (ALASKA), INC., MARK BERLINGER MB 8-1 PO BOX 196612 ANCHORAGE, AK 99519-6612 BP EXPLORATION (ALASKA) INC, INFO RESOURCE CTR MB 3-2 POBOX 196612 ANCHORAGE, AK 99519-6612 L G POST O&G LAND MGMT CONSULT 10510 Constitution Circle EAGLE RIVER, AK 99577 JAMES RODERICK PO BOX 770471 EAGLE RIVER, AK 99577-0471 RON DOLCHOK POBOX 83 KENAI, AK 99611 KENAI PENINSULA BOROUGH, ECONOMIC DEVEL DISTR STAN STEADMAN POBOX 3029 KENAI, AK 99611-3029 . ASRC, CONRAD BAGNE 301 ARCTIC SLOPE AV STE 300 ANCHORAGE, AK 99518 OPSTAD & ASSOC, ERIK A OPSTAD PROF GEOL POBOX 190754 ANCHORAGE, AK 99519 MARATHON OIL CO, OPERATIONS SUPT W.C. BARRON POBOX 196168 ANCHORAGE, AK 99519-6168 UNOCAL, KEVIN TABLER POBOX 196247 ANCHORAGE, AK 99519-6247 BP EXPLORATION (ALASKA) INC, SUE MILLER POBOX 196612 MIS LR2-3 ANCHORAGE, AK 99519-6612 BP EXPLORATION (ALASKA) INC, MR. DAVIS, ESQ POBOX 196612 MB 13-5 ANCHORAGE, AK 99519-6612 PINNACLE, STEVE TYLER 20231 REVERE CIRCLE EAGLE RIVER, AK 99577 DEPT OF NATURAL RESOURCES, DGGS JOHN REEDER POBOX 772805 EAGLE RIVER, AK 99577-2805 PHILLIPS PETROLEUM CO, ALASKA OPERATIONS MANAGER J W KONST PO DRAWER 66 KENAI, AK 99611 NANCY LORD PO BOX 558 HOMER, AK 99623 PENNY VADLA POBOX 467 NINILCHIK, AK 99639 PACE, SHEILA DICKSON POBOX 2018 SOLDOTNA, AK 99669 AL YESKA PIPELINE SERVICE CO, VALDEZ CORP AFFAIRS SANDY MCCLINTOCK POBOX 300 MS/701 VALDEZ,AK 99686 UNIV OF ALASKA FAIRBANKS, PETR DEVEL LAB DR V A KAMATH 427 DUCKERING FAIRBANKS, AK 99701 C BURGLlN POBOX131 FAIRBANKS, AK 99707 K&K RECYCL INC, POBOX 58055 FAIRBANKS, AK 99711 UNIV OF ALASKA FBX, PETR DEVEL LAB SHIRISH PATIL 437 DICKERING FAIRBANKS, AK 99775 DEPT OF ENVIRON CONSERV SPAR, CHRIS PACE 410 WILLOUGHBY AV STE 105 JUNEAU, AK 99801-1795 . BELOWICH, MICHAEL A BELOWICH 1125 SNOW HILL AVE WASILLA, AK 99654-5751 KENAI NATL WILDLIFE REFUGE, REFUGE MGR POBOX 2139 SOLDOTNA, AK 99669-2139 VALDEZ VANGUARD, EDITOR POBOX 98 VALDEZ, AK 99686-0098 RICK WAGNER POBOX 60868 FAIRBANKS, AK 99706 FRED PRATT POBOX 72981 FAIRBANKS, AK 99707-2981 ASRC, BILL THOMAS POBOX 129 BARROW, AK 99723 UNIVERSITY OF ALASKA FBKS, PETR DEVEL LAB DR AKANNI LAWAL POBOX 755880 FAIRBANKS, AK 99775-5880 . JAMES GIBBS POBOX 1597 SOLDOTNA, AK 99669 VALDEZ PIONEER, POBOX 367 VALDEZ, AK 99686 NICK STEPOVICH 543 2ND AVE FAIRBANKS, AK 99701 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 RICHARD FINEBERG PO BOX416 ESTER, AK 99725 SENATOR LOREN LEMAN STATE CAPITOL RM 113 JUNEAU, AK 99801-1182 #12 K e Ie ~~~~ -rD'V~}~F~ ~ FOREST OIL CORPORATION Alaska Division ·(W··········II'JII~i¿;\¿i;;;¡0;.¡¡;.fï~~ii(Ifif!ì1!:li§.:~¡:2!.ii· \. . ê, '{f:~i(1~~~~~¡~~~;ij~~~~·~~~!~~'5i,ÇI.F~'2;¡;;':' COMPANY:';;;, : :"'. ":' ;,.::qfiEsr (JIL CqFlÞ~,,") ;':'::' ..... , ..:: , .' ,: }[;":";'::,;:? ;~.:.' ,\'.,~:;':~';!;(' i'J{\i);¡£\:;:~i;'·;;1;."B~'!iJ,.' ;;;~i;C ,:,,~ .;. , .' _'~4Rt=J\Ç~~~~VATI.qN~_,·~-·.._:__."·:,, }t/L.<~~y:::";:'~_"»'."""__':_::'~":-"_' ,'" '; " . :'LÖéAl~lÒN~;~);'!¡!I;·':);ri::!:<'i:~I:!;(r¡!:1.. ..." .šCíf. ã~Ô~:FEL,·'. ,. ',". ,",tJATtlM ¡:OÂ ËlEVATlpt.F;,;··(MêíiH SèIiLével,·'<y',:.... Date Plotted: 26~:,~:~:~,,;~~~i{1¡~~i~~;~:~~1~1i~l~¿,~t::';"\'·GèolDSisl: arts ' <.- ',ì,'.i"....~_.:·~··_,.,. I,,, . "~ ," . ""," ", I,' ¡'" ; ','," _ . \ ,-' I ".:~".,;~i'/:.\:::-~.,,),;:;.,..: 1\,,_. :;:. ';~,'. :X;'-:"~_:,:^~:j:' ^'f ;, 'r':,',,"-:" "': .. j~~ ~ leAL 2 " "- - '3 1 ~ i\ ~ 81" -- ::¡,,, ~:., Q'" I-j GR - 1 'M" I'·, !',(\ " d) ;n," RWJ\l IJT,2 DISPOSAL I ï;.;¡i[:~ AT90_2 RIlOB_2 PHIT_l eOAL_. , 2515 I;/C.~ ;, "', \ '. ¡'Itl . .. ·x "--, :.., #11 O~/O~/~ FAX 907 258 . FOREST OIL ALASKA . Ig UU11 UUZ @) FOREST OIL CORPORATION I .. t , 310 K Street, Suite 700 Anchorage, Alaska 99501 (907) 258-8600 - Office (907) 258-8601 - Fax FROM: . -)'¡~H ¡)QVI?Õ ;;.. 76 - 7S~2.. ó/J/tJ/ ~¿ ö,l/m'on. .. TO: FAX NUMBER: DATE: PHONE NUMBER: TIME: 1'.: OS A.J1 Tot~,1 Number of Pages Including Cover Sheet: 2- I· , j COMMENTS: Ó*Ioé./ $ 0"'" 7 ,¡( ...,-1- "., ·S ik .£ fA. ..se~,....../tz. -1_ -ftc "¡YJ?tJ ,'1\ etll#4C4'/ ~ A ¡tI-¿J/ 1Jf,//' .;r ~ yfJ.... C ð,,/ II' f -It.. 'It.'! C Ð f-,. ~ r:/..øI (j"''' . 11<- c. et..s¡'",,ý .$~k",.-ic. J:. '? 11 ~ /tJ,Yð 3 1'-- re,e'I",,.tt.. ~ ?;(~ ~ ~b AUG 0 3 2001 Alaska Oil & Gas Cons. GomffilSSIOI' Anchoral}8 f O~:O:h~ FAX 907 258 . 4 FOREST OIL ALASKA . ~ UV",I vu,," RU #Dl Casing Schematic 36" Piles 95/8" 47#, L-80 BTC 7 5/8" 29#. L-80 Hyd 521 200' 3 112" 9.3# tubing 2517' Baker Model SC-2P Packer 7,620' Perforations 8,216' - 8,450' 8600' RECEIVED AUG 0 J 2001 Alaska Oil & Gas Gons. GommlSSIOlI Anchorage #10 ~~ c~¿.,. -1~$,f. /luG' () ~b qqi'cf ß :) Qó's <00; -1/1e',?, COIì. ol"ó'!le"oS. C000,' vss,' 10/1 . . ; ~g¡S7'...~~<I' ið=r, s-œ-m ~ !¡ ~~ "'~ "t PRO~C. UNITED STATES ENVIRONMENTAL PROTECTION AGENCY REGION 10 1200 Sixth Avenue Seattle, WA98101 Reply To Attn Of: OW-137 August 1, 2001 Ms. Cammy Taylor, Commissioner Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue, Suite 100 Anchorage, Alaska 99501 FE: Proposed Aquifer Exemption for Lite Upper Tyonek FonnationRedoubt Unit #D1 Well, Osprey Platfonn, 1915 feet from the south line, 322 feet from the east line, of Section 14, T07N, R14W,Seward Meridian, Cook Inlet, Alaska Dear Ms. Taylor: My staff has reviewed the application by Forest Oil Corporation for an Aquifer Exemption of the Upper Tyonek Formation in the vicinity of the Redoubt Unit #D1 well on the Osprey Platform located approximately two miles east of the West Forelands area. The Alaska Oil and Gas Conservation Commission (AOGCC) permitted Class II disposal well is located in Section 14, T07N, R14W, Seward Meridian, Cook Inlet, Alaska. The Redoubt #D 1 well will be used to dispose of Class II oilfield waste fluids. Injection will be into the Upper Tyonek Formation below a depth of 3749 feet measured depth (MD) and the injected fluids are to remain below that depth. Your fmdings and our review indicate the Upper Tyonek Formation in the vicinity of the well contains fluids with a total dissolved solids (TDS) content of over 3,000 mg/liter. The applicant has supplied information Lfldicating the oil, and gas platform is located in the Cook Inlet, there are no known permanent residents in the area which is also very remote from all existing communities. In fact, the only known development in the area is oil and gas development and the closest drinking water well is at the West McArthur River Unit oil field located onshore approximately eight miles north of the Osprey Platform. Evidence submitted by the applicant also shows the proposed interval is overlain and confmed bysilt stones, coals and shales of the Beluga and Upper Tyonek Formations which will prevent vertical migration of the Class II fluid wastes into formation waters whose TDS content is less than 3,000 mg/l. The oil and gas Osprey platform drinking water is presently supplied by boat. Forest Oil has no plans to use the underlying aquifers as a source of drinking water. The applicant further reports it would be economically impracticable to utilize the portions of fresh water aquifers located under the Redoubt Unit for drinking water purposes. o Printed on RecYCled paper . . ... 2 Based your fmdings and our review, the Environmental Protection Agency (EPA) has determined that the Upper Tyonek Formation below 3749 feet MD within ~ mile of the Redoubt #D 1 well is not reasonably expected to supply water to a public water system. There was an absence of comments during the public comment period. EP A has consulted with Katy McKemey of Alaska Department of Environmental Conservation (ADEC) and understands tbat the proposed exemption is consistent with the Alaska ground water standards. The ground water standards are contained within the Alaska Water Quality Standards (18AAC-70.050). EP A does not object to an exemption for the Upper Tyonek Formation below 3749 feet MD within ~ miJe of the well. As a result of this exemption, the Upper Tyonek Formation below 3749 MD within ~ mile of the Redoubt#D 1 Class II disposal well will no longer be defmed as an underground source of drinking water (USDW). The exemption is considered to be a minor modification of the AOGCC's program for the regulation of Class II injection wells under Section 1425 of the Safe Drinking Water Act, as defmed by Underground Injection Control (UIC) Program Guidance 34 and 40 CFR 145.32. Thank you for the opportunity to review and provide comments on this proposal. If you have any questions regarding these comments, please contact Mr. Thor Cutler, at (206) 553-1673 or by email at cutler.thor@cpa.gov. Sin~. reI ..../ /IJJw ~~ Tim Hamlin, Manager Ground Water Protection Unit cc: M. Salazar, OGWDW Joseph Ryan, RIO-aRC Katy McKemey, ADEC, Juneau #9 Redoubt Unit lease descriptions , . . PLACk. LOP i ),...) 'ßoí~ Aw ~ D/t) r;- t-Æ:.-S -- ~ fV\ - t Subject: Redoubt Unit lease descriptions Date: Fri, 6 Jul 2001 17:54:59 -0600 From: Jim Arlington <JDArlington@forestoil.com> To: '''wendy _ mahan@admin.state,ak.us'" <wendy _ mahan@admin.state.ak.us> CC: Paul White <PDWhite@forestoil.com>, Nancy Culverhouse <NKCulverhouse@forestoil.com> Wendy, Attached is the information you were requesting to include in the aquifer exemption for the injection order at Redoubt. If you need more information, please let me know. «Redoubt Unit Lease Descriptions_7-06-01.doc» Jim Arlington Land Manager-Alaska Business Unit e-mail: jdarlington@forestoil.com Forest Oil Corporation 310 "K" Street, Suite 700 Anchorage, Alaska 99501 Office Phone: (907) 258-8600 Direct Line: (907) 868-2112 Fax: (907) 258-8601 L~_.·...·.·. . ."".".....·.""..ww.~~,....· ,,·..···.·.·w....m.mm_..._... ,. ........... ..mmm...._ ..........~._·_._~...m...M«.. m.._....·w····ww.w.w~"w, ' "".....". Name: Redoubt Unit Lease ~g::: R d b U . L D " 7 06 01 d Descriptions_7-06-01.doc ë:;','ò e ou t mt ease escnptlOns - - . oc T WINWORD F'l ( I· t· n/ d) .... ype: 1 e app Ica 10 mswor Encoding: base64 1 of 1 7/9/01 10:52 AM . . Redoubt Unit Lease Deseriptions The Redoubt Unit is comprised of five State of Alaska leases in their entirety described below: ADL·374002: ADL-378114; ADl-381003: ADl·381201: ADL-381203; T7N, R13W, Seward Meridian, Alaska Section 19, Protracted, All, 615 acres; Section 20, Protracted, All, 640 acres; Section 21, Protracted, An, 640 acres; Section 28, Protracted, All, 640 acres; Section 29, Protracted. All, 640 acres; Section 30, Protracted, All, 617 acres; Section 31, Protracted, All, 619 acres; Section 32, Protracted, AU, 640 acres; Section 33, Protracted, All, 640 acres; Containing approximately 5,691 acres. T7N, R13W, Seward Meridian, Alaska Section 4, Protracted. All, 640 acres; Section 5, Protracted, All, 640 acres; Section 6, Protracted, All, 610 acres; Section 7, Protracted, All, 612 acres; Section 8, Protracted, All, 640 acres; Section 9, Protracted, All, 640 acres; Section 16, Protracted, All, 640 acres; Section 17, Protracted, All, 640 acres; Section 18, Protracted, All, 613 acres; Containing approximately 5,675 acres. T7N, R14W, Seward Meridian, Alaska Section 33, Protracted, All, 640 acres; Section 34, Protracted,AII, 640 acres; Section 35, Protracted, All, 640 acres; Section 36, Protracted, All, 640 acres; Containing approximately 2,560 acres. T6N, R14W, Seward Meridian, Alaska Section 1 ,Protracted, All, 640 acres; Sec:tion2,Protracted,A1I, 640 acres; Section 3,Protracted, All, 640 acres; Section 10,Protracted, AU, 640 acres; Section 11, Protracted, All, 640 acres; Section 12,Protracted, All, 640 acres; Section 13, Protracted, AU, 640 acres; Section 14, Protracted, All, 640 acres; Section 15, Protracted, All, 640 acres; Containing approximately 5,760 acres. T7N, R14W, Seward Meridian, Alaska Section 13, Protracted, All, 640 acres; Section 14, Protracted, All, 640 acres; Section 23, Protracted, All, 640 acres; Section 24, Protracted, All, 640 acres; Section 25, Protracted, All, 640 acres; Section 26, Protracted, All, 640 acres; Containing approximately 3,840 acres. ~ ;¿ , . @ FOREST OIL CORPORATION .J -I 0 dY{' á./Íjceel - aÙr/:e 700 Qc::1;lchOJ!<U¡.e, QYÝ/aJha .9.9.'iO-l , (.907) 2,;8-8600 · (907) 2.;8-8601 (@a.r) July 17, 2001 Tom Maunder State of Alaska Alaska Oil And Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RECEIVED JUL 1 7 2001 Alaska Oil & Gas Cons. Commissior Anchorage Dear Mr. Maunder, We are in the process of completing Redoubt Unit #D-I (injection well). We have set 7 5/8" casing at 8,600'. In examining the logs (quad combo) that was run before casing job the chlorides are not consistently above 10,000 ppm as originally anticipated. I am attaching copies of the logs and a time line for completion of this well. We are planning to perforate 8,216' to 8,450' (234') for the initial target injection sand. The backup sand which we do not intend to perforate at this time is 7,650' to 7,900' (250'). Our permit to drill issued July 7,2001 #201-085 stated that authorization to set a packer, perforate or inject in this well is contingent upon subsequent approvals. Attached to this letter is a 10-403 showing the current status of the well. We would like approval to perforate and set a completion packer as shown in the attached diagram after running the cement bond log. We understand that the injection order we are seeking will be subject to an acquifer exemption because of the chloride concentration. .,. Please call me at 868-2134 if you have any questions. Paul White Drilling Manager, Forest Oil Corporation ~O~'\p~ \ ~ ~~().~ ~~ ~'rf\.1 (.,~"'~~ ~«>~~~~ ~'4':\\ \ ~"t ~~D \':> ~,(),,\-Q~ . I.<,.~\>~art CA.~~-.\\~ .\",~ ~~~\ M.9'fVl "\ h '\ - c \ oRtGlr~AL t. .... STATE OF ALASKA .. ALASKA OIL.ðO GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS t.Dã 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: - - Stimulãte: X Repair well: Plugging: Time extension: Change approved program: Perforate: - Pull tubing: Variance: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Forest Oil Corporation Development: 90' MSL - 3. Address Exploratory: 7. Unit or Property name - 310 K Street, Suite 700 Stratigraphic: Redoubt Unit Anchorage, Alaska 99501 Service: X 4. Location of well at surface 8. Well number 1915' FSL, 322' FEL, Sec. 14, T7N, R14W, SM RU #D1 At top of productive interval 9. Permit number 201-085 At effective depth 10. API number 1915' FSL, 322' FEL, Sec. 14, T7N, R14W, SM 50-733-20502-00 At total depth 11. FieldlPool Redoubt Shoal Oil Field 1915' FSL, 322' FEL, Sec. 14, T7N, R14W, SM Redoubt Shoal 12. Present well condition summary Total depth: measured 8,611' Plugs (measured) true vertical 8,611' Effective depth: measured 8,520' Junk (measured) true vertical 8,520' Casing Length Size Cemented Measured depth True vertical depth Structural 200' 36" Driven 200' 200' Conductor Suface 2,517' 9518" to Surface 2,517' 2,517' Irtermediate 8,600' 7518" TOC 2,000' (estimated) 8,600' 8,600' Production (Uner) Uner Perforation depth: measured RECEIVED true vertical JUL 1 7 2001 I Tubing (size, grade, and measured depth) Alaska Oil & Gas Cons. Commissior Packers and SSSV (type and measured depth) Anchorage 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: - - - 14. Estimated date for commencing operation 15. Status of well classification as: 18-Jul-01 16. If proposal well verbally approved: Oil: Gas: Suspended: - - - Name of ~pver Date approved Service: Class II Disposal 17. I hereby t ~e foregoing is true and correct to the best of my knowledge. J Signed: \ à / Title: Drilling Manager, Forest Oil Corporation Date: I j t1 C\ FOR COMMISSION USE ONLY I Conditions of approval: Notify Commission so representative may witness Approval N030 \. ~c4 Plug integrity_ BOP Test_ Location clearance Mechanical Integrity Test~ Subsequent form required 10- 407 f1pp"öYCÚ ,firr ~ ~ ~21e - ð~ MP tfU' r~~lj)~ I~: i3£lL/L LLf'. perfs t)¿lt apptvY"e.Á.a'- f114s fl'rnt., D1sfX:fS(d .Op...a.mon5 QI¿ a\hh~! ~ 111L ð<J.VI11~S1 £11 0/- Infoft"{" !-. ðJ'P~g1 of- ;\ß,uito€.r EKmp n on ordß.,t- L J)j s~ ðnj.e...dlan on:tJ¿r, ORIGiNAl SIGNED BY 7/;9/0 I Approved by order of the Commissioner J. M, Heusser Commissioner Date Form 10-403 Rev 06115/88 ORIGINAL SUBMIT IN TRIPLICATE i --. -- RU #Dl Casing Schematic 36" Piles 9 5/8" 47#, L-80 BTC 7 5/8" 29#, L-80 Hyd 521 200' 3 1/2" 9.3# tubing RECEIVED JUL 1 7 2001 2517' Alaska Oil & Gas Cons. Commissior Anchorage Baker Model SC-2P Packer 7,620' Perforations 8,612' - 8,450' 8600' Osprey Platform I Su Mo Tu We~~MO ID ð Task Name Duration Start Finish 15 I 16 17 18 ! 19 20-1- 21 22-t-~·ll· 1 Redoubt Unit #D1 194 hrs Ju11512:00 PM Jul 23 2:00 PM - - - - - - 2 !iB Run and Cement 7 5/8" Casing 48 hrs Jul15 12:00 PM Jul17 12:00 PM ~ - 3 Cleanout 7 5/8" 24 hrs Jul17 12:00 PM Jul18 12:00 PM ~ .".-." , - . . 4 Run Gyro 6 hrs Jul18 12:00 PM Jul 18 6:00 PM : - " 5 Run Usit Log in 7 5/8" 8hrs Jul18 6:00 PM Jul19 2:00 AM ~ - " 6 Perforate on Drillpipe 24 hrs Jul19 2:00 AM Jul 20 2:00 AM r - 7 Run Baker Retrievable Packer 20 hrs JuJ 20 2:00 AM Jul 20 10:00 PM D- .... - " 8 Lay Down Drillpipe 12 hrs Jul 20 10:00 PM Jul21 10:00 AM µ - 9 Run 3 1/2" Completion 24 hrs Jul21 10:00 AM Jul22 10:00 AM - 10 Nipple Down BOP 12 hrs Jul 22 10:00 AM JuJ 22 10:00 PM ::;:¡ - : 11 Nipple Up Tree 12 hrs Jul22 10:00 PM Jul 23 10:00 AM - : 12 Perform MIT 4hrs JuI2310:00.AM Jul 23 2:00 PM - - - RECEIVED ,JUL 1 7 2001 Alaska Oil & Gas Cons. Commission Anchorage - - - - Task !ill Summary . Rolled Up Progress Split Rolled Up Task W External Tasks Project: Redoubt Unit Gantt Chart IIII .:.:.; ...... Date: Jul17 2:51 PM Progress - Rolled Up Split Project Summary I II Milestone . Rolled Up Milestone <> - Page -'1 & Gas ConS. CommiSSIOn 1 a. Type of work Drill: X Redrill: 1 b. Type of well Exploratory: Stratigraphic Test: DeÞ.eIdponigft Oil: Re-Entry: Deepen: X Service: x Developement Gas: Single Zone: Multiple Zone: 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Forest Oil Corporation 90' MSL Redoubt Shoal Oil Field 3. Address 310 K Street, Suite 700 6. Property Designation Redoubt Shoal Anchorage, Alaska 99501 381203 4. Location of well at suñace 7. Unit or property Name 11. Type Bond (see 20 MC 25.025) 1915' FSL, 32Z FEL, Section 14, T07N, R14W, SM Redoubt Unit At total depth 8. Well number Type: Statewide Oil and Gas Bond 1915' FSL, 32Z FEL, Section 14, T07N, R14W, SM Redoubt Unit #D1 RLB0001940 9. Approximate spud date Amount: 1-Aua-01 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MO and TVD) prOperty line 3365 feet 6800 feet 23,526 8,600' MD I 8,600' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 MC 25.035 (e)(2) Kickoff depth: nla feet Maximum hole angle: nIa Maximum surface 817 psig At total depth (TVD) 3150 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) Driven 36" Welded 200' Suñ Suñ 200' 200' nla 12114" 95/8" 47# L-80 BTC 2,500' Suñ Suñ 2,500' 2,500' 2690 cu ft 811Z' 75/8" 29.7# L-80 Hyd 521 8,600' Suñ Suñ 8,600' 8,600' 1047 cu ft 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Suñace Intermediate Production Liner Peñoration depth: measured proposed depending on logs 7,650'-7,820' and 8,250'-8,400' true vertical same 20. Attachments: Filing fee: x Property Plat: BOP Sketch: Diverter Sketch: Drilling program: Drilling fI).IidJ: rogram: Time vs. depth plot: Refraction analysis: Seabed report: 20 AAC 25.050 requirements: X 21 . I herby ce~ ifyt at the foregoing is true and correct to the best of my knowledge: , \.. \ Signed: \ \1\ ....... "") Paul White Title: Drilling Manager Date: -Z t (" ~ \ Commission Use Only I Permit Number API number I Approval date See cover letter 20/- 0 >?S 50- ..7 33'- z.. 0 .5 cJ ::;L for other requirements Conditions of approval Samples required: [ ]Yes ,NNo Mud log required: [ ]Yes MNo Hydrogen sulfide measures [ ] Yes MNo Directional survey required [ ] Yes "þ4 No Required working pressure for BOPE [ ] 2M; [X] 3M; [ ]5M; [ ] 1QM; [ ] 15M Other: CJt.~,,\-o..\X).. \l~ ~~rK\T ,j ," by order of Approved by Commissioner the Commission Date: . STATE OF ALASKA. RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL JUL 0 62001 20 MC 25 005 Form 10-401 Rev. 12-1-85 Submit in triplicate @ . . FOREST OIL CORPORATION .fl{) cf/{Q9Iræl . Q~41e 700 Qçd;"tchOI("/Je, Q9fladko .9.9501 (.907) 2.58-/JôOO · (907) 2.5/i'-8ôOf (Q'ßŒ') July 5,2001 Re: Deepen RU D-l (10-403) RECEIVED JUL 0 52DD1 ·AJaska Oil & Gas Cons Commission ~ Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: We are in the process of drilling the above referenced well and would like to revise the depth we. had stated on our original well plan. We would like to drill the well to 9,000' MDfTVD and are looking at perforating for injection úom 7,650'-7,820' and 8,250'-8,400' depending on open hole logs. Perforating at these depths should get us well above the 10,000 ppm chloride levels that are of concern. However we want to continue to pursue the acquifer exemption we have applied for. If you have any questions, please contact me at 258-8600. Q~ Paul D.White Drilling Manager - Alaska Division Forest Oil Corporation #8 ¡ I. I JUL 2 7 2001 Applicåtionfor Underground Injection of Oil Field Wastes and an . Aquifer Exemption RECEIVED Alaska Oil & Gas Cons. Commission Anchorage for the Redoubt Unit #Dl Well Osprey Platform . . . . . . . - . . . . . . . . . . . . . . . . [~N~~lJIN~ ~~~~r . .. ..... . .. . . . . .... . . . . . . . . . . . . . . . . . . . . . . . .. I I I I I I I 1 I I I I I I I I I I I . Table of Contents Overview Section 1. Location Section 2. Operators and surface owners Section 3. Affidavit Section 4. Description of Confining and Receiving Zones Section 5. Logs of disposal well . Section 6. Casing program and procedure for demonstrating MIT Section 7. Type of oil field waste Section 8. Injection pressure Section 9. Fracture Propagate Section 10.Water quality Section lI.Freshwater exemption Section 12.Mechanical condition of adjacent wells Section 13.Disposal Injection Order, Proposed Findings Proposed Conclusions Proposed Rules Section 14.Aquifer Exemption Order, Proposed Rules Proposed Conclusions Attachments: #Dl Well Log #Dl Cement Quality Log Page 1 2 4 5 7 8 10 13 14 15 16 17 18 19 21 22 24 25 A B I I I I I I I I I I I I I I I I I I I . . Overview Forest Oil Corporation requests authorization to inject Class II waste fluids into permeable sands of the Upper Tyonek Formation, at depths below 7650 feet TVD in its Redoubt Unit #D 1 well. The RU #D 1 well was drilled as a straight hole from the Osprey Platform. The well is located approximately 1915 feet from the south line, 322 feet from the east line of Section 14, T07N, RI4W, Seward Meridian. A copy of the permit is on file with the AOGCC. The total dissolved content of formation water encountered in the drilling of the #Dl well indicates that salinity below 3,650 feet TVD is greater than 3,000 mg/l, and often exceeds 10,000 mg/l. Forest Oil requests an aquifer exemption be granted under 40 CFR l47.102(b)(2)(i) and 20 AAC 25.440(c) for the all horizons below 3,650 feet TVD within a one-half mile radius of the #Dl well. Forest Oil believes that any freshwater encountered within the proposed injection zone will have a total dissolved solids (TDS) content greater 3,000 mg/l, and that such water could not reasonably be expected to supply a public water system because of its location, depth and the abundant availability of water elsewhere in the region. The information included in the following sections is intended to satisfy the submission requirements under 20 AAC 25.252 and 20 AAC 25.440. In addition, Forest Oil has included proposed findings, conclusions and rules for the Commission's consideration in developing the requested disposal injection and aquifer exemption orders. 1 I I I I I I I I I I I I I I I I I I I . . Section 1 Location 120 AAC 25.252(c)(1)} The Redoubt Unit (RU) is located in the Cook Inlet, approximately two miles east of the West Forelands area. The field is being developed ffom the Osprey Platform located at latitude 600 41' 46.3" north, longitude 151040' 10.2" west. The RU #Dl disposal well was drilled as a vertical well to approximately 8600 feet TVD. It will be used to inject oil-based drilling muds, produced wastes and other approved Class II fluids. The Osprey Platform sets in approximately 45 feet of water. The platform is a four column steel structure similar to other Cook Inlet platforms. Production wells ffom the platform are directionally drilled to the producing formation. The RU #D 1 disposal well is the only vertical well planned ffom the platform. Consequently, significant separation, on the order of one-half mile or more, will exist at the top of the proposed injection zone at 7650 feet TVD between RU #Dl and other wells drilled ffom the platform. At this date, the proposed RU-3 well is the closest well to the RU #Dl well, and is offset by more than 3000 feet at the disposal zone top. A plat showing the location of the proposed RU #D 1 disposal well and surrounding wells is attached as Exhibit I-I. 2 I . . I Exhibit 1-1 Location Map I 35 36 31 32 33 I I 2 1 6 5 4 I I 11 12 7 8 9 I Osprey I 14 OUST BAY U lW 16 RU I SH U 2 I 23 20 21 I I 30 FOREST OIL I REDOUBT UNIT RU 01 31 --, I I I 2 1 6 5 4 I I 3 I I I I I I I I I I I I I I I I I I I . . Section 2 Operators and Surface Owners 120 AAC 25.252(c)(2)} Forest Oil Corporation is the only operator within one-quarter mile radius ofthe RU #Dl well. The company's address is: Forest Oil Corporation 310 K Street, Suite 700 Anchorage, Alaska 99501 The State of Alaska is the only surface owner within one-quarter mile radius of the RU #Dl well. The Department of Natural Resources, Division of Oil and Gas, manages the state lands under lease for oil and gas development. DNR's address is: Department of Natural Resources, Division of Oil and Gas 550 West 7th Ave., Suite 800 Anchorage, AK 99501 4 I I I I I I I I I I I I I I I I I I I . . Section 3 Affidavit {20 AAC 25.252(c)(3)1 The affidavit of Paul White, Drilling Manager for Forest Oil Corporation is attached as Exhibit 3.1 5 I I I I I I I I I I I I I I I I I I I . . Exhibit 3.1 Affidavit of Paul White I, Paul White, as agent for Forest Oil, Inc. declare and affirm hat have knowledge of the matters set forth in this application and that on 7 7 0 ( , the following surface owner, as sole owner within one-quarter mile oft e doubt Unit, was provided a copy ofthis revised application for a disposal injection order by certified United States mail from Anchorage, Alaska. State of Alaska Dept. of Natural Resources Division of Oil & Gas 550 West 7th Ave., Suite 800 Anchorage, AK 99501 Attention: Mark Meyer, Director Responsible Official: -~ Paul White Drilling Manager Forest Oil Corporation *************** Notarization The foregoing affidavit was acknowledged before me the ~)\ day of\. \ IC\ '\ .. , 2001, by Paul White, who is personally known to me or who has produced ~ ~ C'{) 1@ as identification and who did take an oath. Ck~:Y) LdV'~ J Notary Pu 'c 'A. f'í\ u \f\. ~".)(Od eJ(\ Printed, Typed, or Stamped Name Commission Number: \ LP ~ "6 L\ Commission Expires: t) \ \ 5\ t>"3 6 I I I I I I I I I I I I I I I I I I I . . Section 4 Confining and Receiving Zones 120 AAC 25.252(c)(4)1 Geologic information on the confining and receiving zones is based upon log data from the RU #D 1 well. Iniection Zone: Forest Oil has identified two sands within the Upper Tyonek Formation for disposal injection in the RU #Dl well. The upper sand is located between 7650 feet TVD and 7900 feet TVD. The lower sand is located between 8216 feet TVD and 8450 feet TVD. The lower sand will be the primary injection zone and the upper sand the secondary injection zone if injection problems develop within the deeper sand. The Upper Tyonek Formation is fluvial in nature and, at this location, consists primarily of anastomozing stream channels, which produced blanket-like sand intervals that are continuous both horizontally and vertically. Porosity and permeability are good within the Tyonek sands, which are very friable and generally medium grained, well- rounded and well-sorted. Porosities range from 20 % to 30 %. Confining Zone: Interbedded with the Upper Tyonek sands are numerous claystones, siltstones and coal, which will serve as effective barriers to upward migration. Between the upper and lower sand, from approximately 7850 feet TVD to 8100 feet TVD, and above the upper sand, from 7250 feet TVD and 7500 feet TVD, are two claystone layers that will serve as the primary confinement zone for injection within the #D 1 well. In addition to the interbedded claystones of the Upper Tyonek Formation, the numerous thick coal seams and extensive interbedded claylsiltstones within the overlying Beluga section will also act as confining layers preventing the upward migration of disposal fluids. At the proposed RU#Dl welllocatien,approxim-ately 1600 feet to 1800 feet of Beluga Formation overlies the Upper Tyonek Formation. The Beluga Formation is also fluvial, but stream channels are less numerous and more isolated by siltstone, clay and coal deposits and than in the Tyonek. Log data from the adjacent RU-l well reveals that the Beluga section contains thick silt/claystone intervals, with numerous thick coal seams and interbedded sands, from the surface to 1800 feet MD. The mud log from the Redoubt Shoal State 29690 #1 well confirms the existence of confining rock throughout the Beluga section. The mud log reveals at least 440 feet of clay and 170 feet of siltstone within the Beluga section between 700 feet and 1800 feet MD. Based upon log analysis, Forest Oil believes that the effective porosity of the various silt/claystone sections penetrated by the #Dl well is zero. Accordingly, the numerous impermeable siltstones and claystones within the section should serve as effective barriers to upward migration of injected fluids. In addition, the thick coal seams also have an effective porosity of zero and should help act as confining barriers as well. 7 I I I I I I I I I I I I I I I I I I I . . Section 5 Logs of disposal well [20 AAC 25.252(c)(5)1 The well log for the RU #D 1 well is included with this revised application. In addition, well logs for the recently drilled RU #1 and RU #2 wells, as well as the Redoubt Shoal State 29690 #1 well, drilled in 1967, are also helpful in understanding the geology ofthe area. These well logs are on file with the Commission. Based upon seismic data from the area, continuity appears good between these two wells and the proposed RU #Dl well (see Exhibit 5.1). 8 - - - - - - - - - - - - - - - - - - - - - - RU 11 - Disposal Well Cross Section 1 Exhibit 5 lei -500 -1000 -1500 -2000 -2500 -3000 - 3500 -4000 - i -4500 '9 -5000 (I) i -5580 II.. - -6000 = t -6500 CI -7000 -7500 -6000 -6500 -9000 -9500 Scale ~ 0 500 tooo 1500 2000 Feet I I I I I I I I I I I I I I I I I I I . . Section 6 Casing program and MIT procedures 120 AAC 25.252(c)(6)} The proposed casing and cementing programs for the RU #D 1 well is listed below. Exhibit 6-1 shows the well bore diagram for the RU #Dl well. _________m_____mmmm____...m__m_m______.L§~~!l:gº~R~h----___ Program j Specifications : Top Bottom Casitigr W cightTGrad~-Le;;gthrMD-m---TTVD·- TVD 36" : 200' Surf. Surf 200' ·--3..---....···..···j......-·.........-····..·....···· ....................-.......... 9 Is" : 47# : L-80 17' Surf. Surf. 17' 7 5/s'~--r2-ëj:7#---·-L_8Ò-m- 8,600' Surf. Surf. 8,600' Quantity Cement _........._----~.- N/A .......--....--...........--............-... 3074 cu. ft. ".._..---- 806 cu. ft. Casing Joint Strength Body Strength Burst Collapse K Ibs Klbs Psi Psi 9 5/s" 47# L-80 122 1086 6870 4760 7 'Is" 29.7# L-80 566 683 6890 4790 Tension Burst Collapse Straight Hook Load - Ignoring Deviation and Buoyancy Full Column of Gas against deepest formation pressure Full evacuation of the inside backed by expected formation gradient of.45 psilft on the outside of casing. 95/8" 47# L-80 Surface Casinl! Tension =2517' x 47# Rated = 1086 =118.3 K Safety Factor = 9.2 Burst =(8611 ' x .45)-(.1 0 x 8611 ') Rated = 6870 psi =3014 psi Safety Factor = 2.3 Collapse =(2517' x 45)-(.1 0 x 2517') Rated = 4760 psi =881 psi Safety Factor = 5.4 75/8" 29.7# L-80 Intermediate Casing Tension =8600' x 29.7# Rated = 1086 =255.4 K Safety Factor = 4.2 Burst =(8611' x .45)-(.10 x 8611') Rated = 6870 psi =3014 psi Safety Factor = 2.3 Collapse =(2517' x 45)-(.10 x 2517') Rated = 4760 psi =881 psi Safety Factor = 5.4 A 3~-inch tubing string and packer is set at 7,620 feet TVD. Mechanical Integrity After the packer and tubing was run in the well, the casing x tubing annulus was pressure tested to 2500 Ibs on July 22,2001. The well passed the mechanical integrity test, witnessing ofthe test was waived by AOGCC. 10 I I I I I I I I I I I I I I I I I I I . . Forest Oil also ran a cement quality log to demonstrate the adequacy of cement to contain potential wellbore pressures and fluids. The cement quality log is enclosed as Attachment B. Packer Setting Depth Variance under 20 AAC 25.412(b) Forest Oil requests that the AOGCC approve the placement of the packer at a location more than 200 feet above the top of the perforations as required by 20 AAC 25.412. Forest Oil has place the packer at about 7,620 feet TVD. The top ofthe perforations in the #Dl well is 8216 feet. As stated earlier, Forest Oil has identified two separate sand layers that should be capable of accepting injected fluids, and proposes to initiate injection in the deeper-most sand interval, located between 8216 feet TVD and 8450 feet TVD. Placing the packer at 7620 feet TVD will allow Forest Oil to move injection to the upper sand if problems develop within the deeper sand. 11 I I I I I I I I I I I I I I I I I I I Exhibit 6-1 . . RU #Dl Casing Design 36" Piles 9 5/8" 47#, L-80 BTC 7 5/8" 29#, L-80 Hyd 521 12 200' TVO 31/2" 9.3# tubing 2517' MO, 2500' TVD Baker SC-2p Packer 7620' TVO Perforations 8216' - 8450' 8600' TVD I I I I I I I I I I I I I I I I I I I . . Section 7 Type of Oil Field Waste 120 AAC 25.252(c)(7)} Only approved Class II fluids will be injected into the RU #Dl well. This waste will consist of produced water, drilling, completion and workover fluids, rig wash, drilling mud slurries, NORM scale, tank bottoms, and other fluids brought to the surface in connection with oil and gas development activity on the Osprey Platform. Forest Oil estimates that the average volume of fluids to be disposed will be approximately 600 bbl/day, with a maximum volume of 1000 bbl/day. The average and maximum density of injected fluids will be 10.0 ppg and 11.5 ppg, respectfully. Based upon experience elsewhere in the Cook Inlet, most fluids proposed for disposal should be compatible with the disposal zone. Compatibility problems, however, may exist for certain small volumes of non-routine Class II fluids. If a compatibility problem is identified, Forest Oil will either chemically treat the fluid to resolve any problems or will dispose the fluid by other approved means. 13 I I I I I I I I I I I I I I I I I I I . . Section 8 lniection pressure 120 AAC 25.252(c)(8)} The average anticipated surface injection pressure will be approximately 3600 psi. The maximum anticipated pressure will be approximately 4000 psi. This is based on an injection depth of approximately 8216 feet TVD, an injection pressure at the injection perforations of 18.5 ppg EMW, calculated with a 10.0 ppg slurry for the average injection case and an 8.5 ppg saltwater density for the maximum injection pressure case. Injection rate is assumed to be about five barrels per minute. Forest Oil will perform a step rate test to establish optimum injection rates and pressures. The step rate test will be incrementally increased to pump rates 100% in excess ofthe maximum anticipated injection rates for waste disposal. Pressure fall off data will be collected at the end of the step rate test. 14 I I I I I I I I I I I I I I I I I I I . . Section 9 Fracture Propagate 120 AAC 25.252(c)(9)} Forest Oil estimates that the fracture pressure ofthe disposal zone is about 6150 psi. This is based upon a fracture gradient of approximately .75 psi/ft and an injection depth of about 8216 feet TVD. Fracture propagation within the disposal interval will be an integral part of the process of placing waste fluids into the disposal interval. Fractures will be created as the disposal zone begins to plug. Fractures provide pathways to transport waste fluids to undamaged storage volume within the disposal zone. Forest Oil requested BJ Services to conduct a fracture propagation modeling study of the proposed injection zone. BJ concluded that induced fractures will be localized near the well bore and confined to the injection zone. This study was previously submitted to AOGCC as part ofthe original application. Forest Oil plans to use reservoir surveillance techniques including, but not limited to, step rate injection tests, disposal rate and pressure monitoring, and temperature logging, to track near wellbore fluid movement, estimate the dimensions of disposal fractures, and to detect changes in disposal zone characteristics. Evaluation of operation performance and reservoir surveillance will aid in preventing any fractures being propagated into and through the confining zone. 15 I I I I I I I I I I I I I I I I I I I . . Section 10 Water quality 120 AAC 25.252(c)(10)} The total dissolved content of formation water encountered in the #D 1 well below 3,650 feet TVD is greater than 3,000 mg/l, and often exceeds 10,000 mg/l. Average salinity below 3,650 feet TVD in clean sands with V-shale less than 15 percent is between 5,000 to 12,000 mgll. 16 I I I I I I I I I I I I I I I I I I I . . Section 11 Freshwater Exemption 120 AAC 25.252(c)(11)} Water salinity below 3,650 feet TVD exceeds 3,000 mg/l, and often exceeds 10,000 mg/l. Because 10,000 mg/l is the upper threshold for freshwater as defined under state and federal regulations, Forest Oil requests an aquifer exemption be granted under 40 CFR 147.102(b)(2)(i) and 20 AAC 25.440(c) for the all horizons below 3,650 feet TVD within a one-half mile radius of the #Dl well. Forest Oil believes that any freshwater encountered within the proposed injection zone will have a total dissolved solids (TDS) content greater 3,000 mg/l, and that such water could not reasonably be expected to supply a public water system because of its location, depth and the abundant availability of water elsewhere in the region. 17 I I I I I I I I I I I I I I I I I I I . . Section 12 Mechanical Condition of Adiacent Wells 120 AAC 25.252(c)(l2)} Wells in close proximity to the RU #Dl well are the RU #1 and #2 wells and the Redoubt Shoal State 29690 #1 and #2 wells. The RU #1 and #2 wells were recently drilled and completed in accordance with state drilling standards under 20 AAC 25. The Redoubt Shoal State 29690 #1 well was drilled in 1967, side tracked as the #2 well in 1968, which was abandoned in 1993 according to AOGCC records. Drilling and abandonment ofthe Redoubt Shoal State 29690 #1 and #2 wells were done under standards that are the same or equivalent to those in place today. At the top ofthe disposal zone at 7,650 feet TVD, the closest well to the RU #Dl well will be the proposed RU #3 well, which will be over 3000 feet away at that depth. The offset between #Dl well and the existing RU #2 and RU #1 wells at that depth is over 3,500 feet and 4,000 feet, respectively. Forest Oil has previously submitted a cross- section showing the well offsets to AOGCC. 18 I I I I I I I I I I I I I I I I I I I . . Section 13 Disposal Injection Order Proposed Findings 1. Forest Oil is the operator of the Redoubt Unit. There are no other operators within a one-quarter mile radius of the proposed disposal injection well. 2. Forest Oil proposes to conduct disposal operations in the proposed RU #Dl injection well in strata that correlates with the Upper Tyonek Formation between the depths of 7650 feet TVD and 8450 feet TVD. At the injection depth, there are no other wells within one-quarter mile radius of the RU #D 1 well. 3. Forest Oil has identified two separate sand layers, between 7650 feet TVD and 7900 feet TVD and 8216 feet TVD and 8450 feet TVD, within the proposed injection interval that should be capable of accepting fluids for disposal. Forest Oil plans to limit injection to the deepest most sands, unless injection problems require the shallower sand to be used. 4. Interbedded with the Upper Tyonek sands are numerous claystones, siltstones and coal, which will serve as effective barriers to upward migration. Between the upper and lower sand, from approximately 7850 feet TVD to 8100 feet TVD, and above the upper sand, from 7250 feet TVD and 7500 feet TVD, are two claystone layers that will serve as the primary confinement zone for injection within the #Dl well. 5. In addition to the interbedded claystones ofthe Upper Tyonek Formation, the numerous thick coal seams and extensive interbedded claylsiltstones within the overlying Beluga section will also act as confining layers preventing the upward migration of disposal fluids. At the proposed RU #D 1 well location, approximately 1800 feet of Beluga Formation overlies the Upper Tyonek Formation. 6. Cased hole logs and cement records show that the RU #Dl well is cemented adequately to isolate the proposed disposal interval. 7. The RU #Dl well was completed with 36 inch conductor set at 200 feet TVD, 95/8 inch surface casing set at 2517 feet TVD and cemented to surface, and 75/8 inch production casing set at 8600 feet TVD and cemented back to 5,635 feet. 8. The RU #Dl well is equipped with 3~ inch tubing string and packer set at about 7,620 feet TVD. Placement of the packer at 7,620 feet is more than 200 feet above the top of the existing perforations. 9. The waste stream will consist of produced water, drilling, completion and workover fluids, rig wash, drilling mud slurries, NORM scale, tank bottoms; and other Class II fluids generated from drilling, production, workover and completion operations. 19 I I I I I I I I I I I I I I I I I I I . . 10. Forest Oil estimates that the average injection volume will be about 600 bbl/day and the maximum volume about 1000 bbl/day. 11. Forest Oil estimates the average injection pressure will be about 3600 psi, with a maximum daily injection pressure of 4000 psi, at an injection rate of five barrels per minute. 12. Fracture propagation within the disposal interval is an integral part ofthe process of placing waste fluids into the disposal interval. Fractures will be created as the disposal zone begins to plug. Fractures provide pathways to transport waste fluids to undamaged storage volume within the disposal zone. 13. Evaluation of operation performance and reservoir surveillance will aid in preventing fracturing of the confining zones. 14. The portion of freshwater aquifers beneath Cook Inlet described by a one-half mile radius from RU #Dl well at a depth greater than 3650 feet are exempt aquifers under 40 CFR 147.1 02(b )(2)(i) and 20 AAC 25 .440( c) by order of the Commission. 20 I I I I I I I I I I I I I I I I I I I . . Disposal Injection Order Proposed Conclusions 1. The requirements of20 AAC 25.252(c) have been met. 2. Waste fluids authorized for disposal under this order will consist exclusively of Class II waste generated from drilling, completion, workover and production operations on the Osprey Platform. 3. Permeable strata, which reasonably can be expected to contain the total volume of disposal fluids anticipated for this project, are present in the Upper Tyonek Formation. 4. Waste fluids will be contained within appropriate receiving intervals by confining lithologies in the Upper Tyonek and Beluga Formations, cement isolation of the wellbore and operating conditions. 5. Placement of the packer at 7,620 feet is appropriate given the thickness and depth of the confining zone, and will allow for operational flexibility should injection be required in the shallower sands of the proposed injection zone. 6. Disposal injection operations in the RU #D1 well will be conducted at rates and pressures below those required to fracture the confining zone. 7. Periodic fracturing and stimulation will be required to place solids into the disposal interval. Fracture growth can be contained within the disposal interval by controlling the rate and volume of injection. 8. Surveillance of disposal material movement, monitoring of operating parameters and demonstration of mechanical integrity every four years will ensure the waste fluids are contained within the disposal interval. Changes in baseline data may be an indication that fluid is escaping beyond the designated confining zone. 9. The mechanical integrity of the tubing, packer and production casing in the RU #D 1 well has been demonstrated in accordance with 20 AAC 25.412. 10. Disposal injection operations in the RU #D1 well will not cause waste, jeopardize correlative rights, or impair ultimate recovery. 21 I I I I I I I I I I I I I I I I I I I . . Disposal Injection Order Proposed Rules Rule 1 Authorized Iniection Strata for Disposal. Class II oil field fluids may be injected in conformance with Alaska Administrative Code Title 20, Chapter 25, for disposal into the Upper Tyonek Formation from 7650 feet TVD to 8450 feet TVD in the RU #Dl well. Rule 2 Authorized Fluids This authorization is limited only to Class II fluids. The Commission must be notified immediately if any non-Class II fluids are injected into the well. Rule 3 Demonstration of Tubing/Casing Annulus Mechanical Integrity A schedule must be developed and coordinated with the Commission that ensures the tubing-casing annulus is pressure tested at least once every four years. The casing must be tested at a surface pressure of 1500 psi or 0.25 psi/ft multiplied by the true vertical depth of the casing shoe, whichever is greater, but may not be subjected to a hoop stress greater than 70% ofthe minimum yield strength of the casing. The test pressure must show stabilizing pressure and may not decline more than 10% within thirty minutes. The Commission must be notified at least twenty-four (24) hours in advance to enable a representative to witness pressure tests. Rule 4 Well Integrity Failure Whenever disposal rates and/or operating pressure observations or pressure tests indicate pressure communication or leakage of any casing, tubing or packer; the operatormust notify the Commission on the first working day following the observation, obtain Commission approval of a plan for corrective action and obtain Commission approval to continue injection. Rule 5 Surveillance Operating parameters including disposal rate, disposal pressure, annulus pressures and volume of fluids and solids pumped must be monitored and reported according to requirements of20 AAC 25.432. An annual report evaluating the performance of the disposal operation must be submitted by July 1 of each year. Rule 6 Placement of the Packer The packer may be placed more than 200 feet above the top of the perforations. Rule 6 Administrative Action 22 I I I I I I I I I I I I I I I I I I I . . Upon request, the Commission may administratively revise and reissue this order or any of its rules upon proper showing that the change is based on sound engineering practices, will not allow waste fluids to escape from the disposal zone, and will not cause waste. 23 I I I I I I I I I I I I I I I I I I I . . Section 14 Aquifer Exemption Order Proposed Findings 1. Forest Oil seeks authorization exempt aquifers below 3650 feet TVD in its Redoubt Unit #D 1 well. 2. The RU #Dl well was drilled from the Osprey Platform, and is located approximately 1915 feet from the south line, 322 feet from the east line of Section 14, TOm, RI4W, Seward Meridian. 3. There no water wells in the vicinity of the RU #Dl well. 4. Other oil and gas wells drilled from the Osprey Platform are the RU #1 and #2 wells. The RU #3 well will be completed in the near future. 5. The Redoubt Shoal State 29690 #1 and #2 wells are also located nearby. The wells were plugged and abandoned in 1968 and 1993, respectively. 6. The #Dl well is completed in sediments ofthe Upper Tyonek Formation. The Upper Tyonek is fluvial in nature with blanket-like sand layers that are continuous both horizontally and vertically. Interbedded with the sands are numerous claystones, siltstones. Based upon log analysis, Forest Oil believes that the effective porosity of the various siltstone and claystone sections penetrated by the #D 1 well is zero and that theses layers will serve as impermeable barriers to upward migration of injected fluids. 7. Forest Oil used a method endorsed by EPA in publication "Survey of Methods to Determine Total Dissolved Solids Concentration" (KEDA Project No. 30-956) for calculating TDS content from wireline log data. 8. Salinity data from the #D 1 well shows that the TDS content of formation waters exceeds 3,000 mg/l below 3650 feet TVD, and exceeds 10,000mg/l in some intervals. 9. Development of the freshwater aquifers below the Redoubt Unit by entities other than Forest Oil is economically impractical because of the offshore location, water depths and currents, drilling costs and readily available alternative freshwater sources onshore. 10. The Commission's authority to act in this matter is embodied in 40 CFR 147 Subpart C, the Alaska Oil and Gas Conservation Act (AS 31.05), and the Alaska Administrative Code (20 AAC 25.005 through 20 AAC 25.570). 24 I I I I I I I I I I I I I I I I I I I . . Aquifer Exemption Order Proposed Conclusions 1. The portion of the aquifer proposed for exemption in the RU #D 1 well will likely have a TDS content greater 3,000 mg/l, with some intervals exceeding 10,0000 mg/I. 2. The portions ofthe aquifers underlying the Redoubt Unit do not now serve as a source of drinking water. 3. All aquifers below 3,650 feet that are underlying and within one-half mile radius of the Redoubt Unit are not likely to serve as underground sources of drinking water because of their location, depth and abundant availability of drinking water elsewhere in the region. It is reasonable, therefore, for purposes of underground injection, to exempt any freshwater aquifers with salinity greater than 3000 mg/l that may be encountered in the area. 4. Those portions of aquifers underlying and within one-half mile of the RU #D 1 well below 3650 feet qualify as exempt freshwater aquifers under 20 AAC 25.440(a)(2). 25 I I I I I I I I I I I I I I I I I I I . . Schlulßberger Cement Advisor Company Field Well Date Logged Date Processed API Number Log Ana Iyst FOREST OIL CORPORATION Redoubt Shoal Oil Field REDOUBT UNIT D1 19-JUN-2001 24-JUL-2001 50-733-20501-00 Jesse Cryer Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 (907) 273-1700 f'l1¡ interpretations are opinions based on inferences from electrical or other measurements and we cannot, and do not guarantee the accuracy or correctness of any Interpretations and ¡,ve shall not, except in the case of gross or willful negligence on our part, be liable or responsible for any loss, cost, damages or expenses incurred or sustained by anyone resulting rom any interpretation made by any of our officers, agents or employees. These interpretations are also subject to clause 4 of our general terms and conditions as set out in our current þrice schedule. I I I I I I I I I I I I I I I I I I I . . Forest Oil Corporation Redoubt Unit D1 Redoubt Shoal Oil Field 1. Cement Advisor Objectives The objective of this logging suite was to determine the quality of the cement job on Forest Oil Corp's well Redoubt Unit 01. A Cement Bond Tool (CBT) was logged in Redoubt Unit 01 from 2500 ft to 8472 ft and 1110 ft to 1296 ft inside 7.625 in 29.7 Iblft casing. A repeat pass was also recorded from 8250 ft to 8480 ft. 2. Cement Advisor Interpretation This CBT interpretation is based on the Variable Density display (VOL) and Discriminated (DA TN) and Near Pseudo Attenuation (NA TN) data. The VOL display and attenuation curves indicate good cement from total depth (TO) to 5635 ft. The VOL presentation clearly shows strong formation signal and weak to nonexistent casing signal. Casing collars are not evident in the VOL display confirming the interpretation of good cement. From 5635 ft to 2700 ft, the attenuation curves migrate to less attenuation indicating progressively poorer cement bond with decrease depth. Casing collar arrivals are faintly evident in the VOL display confirming the decrease in bond quality at this point. Above 2700 ft, the CBT tool indicates free pipe with the attenuation curves reading zero and strong casing signal on the VOL. This free pipe signal matches that recorded around 1200 ft. ~ . . . . . ~ . . . . . . . . q . $ . . . . . . e _ ~ ~ $ . e _ . * . . . . . . c . ~ ~ . $ . . . . . ~ . ~ $ ø 3 . Ú ~ . . @ . ~ * ~~N~~lIIN~ ~~~~r . . . . . . $ . . . . . . . . . . . . . * . . . . . . . .. . . . . . . . * . G . . . . 0 $ . @ e . ~ . . . . . ~ . . 9 0 * . $ ð . C- e e ..W~~;;·~!~t~~Wii~~~>':~ '" ~ .,: ;.~ '. ";" ~.>,¿.", -,",'/,.>,;-,: ;:,~).~~','1?i [~'f ~.c "'>:'.'1", ' ,~t \ : ", ,~..,. , ". l~/'~:! _' ~ . ~ ~ ~, &i lit ~ ~I,; tJ)t,¡ '" tljh' " " GR_ 5 CM'I , ~}! } 130 I ~ i() RWA....2 DISPOSAL AT90_5 RHOB_5 Všii'21 If.' ;'nn01l1' I,W\ (;/C.~ )(I~, :'110 , , 7',() -t'" ',f)() f 'i!.,r) I r++ ,W() : : ,I',() . . ~ ( I( \ 111(1 'i(H\ e e ôV<..V\./·2...J". t.f- L. ""'" '6/1"0.. ~_ c:. 0 ~ v~J ~ODJ f~ ftrt v_.,;,.,._....·..'",...,~,,·~·.·, 0 .....J W ü: .....J ð .....J W ~ a.: .....J LL Ci IT: oCt: b t: 0 C N Ü I (") Z (J) cd :J .....J In .....J .- ð z (J) ID .- 0 :J LL :J (J) ~ <ë 0 ëo 0 w z 0 ~ 0 IT: Ü ~ w m w f2 0 IT: ~ IT: .....J I CJ » :J c: c: 0 !tI 0 :¡¡¡ c.. IT: "0 E 0 ã> 8 ~ 8 ro ü: .....J Schllllbørgør 1918' FSL & 320' FEL Permanent Datum: Log Measured From: Drilling Measured From: API Serial No. 50-733-20501-00 19-Jul-2001 3 8475 ft 8482 ft 8472 ft 2500 ft 5% KCL 500000 m 8.6 Ibm/ aJ Oft 8.500 in Size 7.625 in 29.7 Ibm/ft CEMENT BOND TOOL ULTRA SONIC IMAGING TOO Mean Sea Level Kellv BushinQ Kellv BushinQ Elev.: KB. 59.69 ft G.L. Oft D.F. 59.69 ft Elev.: Oft 59.7 ft above Perm. Datum Max. Hole Devi. 2deg Longitude Latitude 12:00