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Home My WebLink AboutAEO 008 ·- . INDEX AQUIFER EXEMPTION ORDER NO 8 COHOE UNIT #1 1) December 27,2001 2) January 22,2002 3) --------------- 4) May 2,2002 5) May 30, 2002 6) June 5, 2002 Unocal's Application for Freshwater Exemption Notice of Hearing, ad order, affidavit and bulk mailing list Various E-mails Additional Questions for Operator Letter from Unocal to EPA Response letter from EP A to Unocal Aquifer Exemption Order No 8 _'ØHL... ......f1/IIWIW'JIMIIS. ·l~;¡·"II."'fnlll'Ii" Ace_I no, I,'; .. '~J: I· ~ t . r'" Comp,ny ft'''''' , . Shlpp~", n(llme /' Addt"" lip t(Jðe t,equt,ed) 'I /" ~..It',,I;IIi. ,·ui ~~dVIJIII 1-800-CALL-DHL ~"ÙŠr:'''''' ....ø AOOIIl$S: ....._.df>t.... ..... '1 ,'" ,. . ~ . .. .' i, . ,I . II /jl/:' ~:) 8302279812 Qunte this shJømeni "rtmber in ,n 1rtf$U1fv Dœilill'¡!\J.I:I,.II· Domestic Seryfce, [;:)uSA Ovt:nNfGf-n !tJ!n""flone' S",yfee' LJ,"f'l IJOCUM£'" ~Xrn~5S ~~,:!~,!;=~;,l=~~,." .~~~~~~':f"''''C'4f'':N",~,,,,,,,,,,,,,,"::Atd.No........... . : WerfdM." 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I( () f II I:toJ,Ji'I'l!I"I4)~·It~'" ~ r N.. ., "..... » 5i .~ ?( !" \ We'gh' " mil E"þlC~$ Docflmnn, t1~d"fI'''11 & ust!d. ""'fJ' XO t; Dlme"s"'"' I" Inchcs Z Ibf! I .. -, 1:1 w ~ ___.\., x Z rl.e", I"ngfh wir!/h h"'gM 8 ÐlM£NSlONlIll1:"""GtD wtlGllt !;j :J; Z "'tJ :u ~ :0 I1t ~ o o o o ~ ~ ø .. o m 'f; r,,_ CODES Cf.^"G~S Se,vk.el S,ntetll' sorvfees 'n,utllme Uro" 0011'1 bp.C"nte, II TOTAL TnIlNSPOIIf COll~CT STICK£n N., II) :r .. 'S' PICK£D UP BY " ~ ¡; ,', "t 'On. , f '+-r- b' bal' '.' f I' . ~ e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: THE REQUEST OF UNION ) OIL COMPANY OF CALIFORNIA ) for an Aquifer Exemption Order for the ) Cohoe Unit #1 Well, Section 8, T3N, ) R11W, Seward Meridian. ) Aquifer Exemption Order No.8 Beluga Formation Sterling Formation Cohoe Unit #1 Well June 6, 2002 IT APPEARING THAT: 1. Union Oil Company of California ("UNOCAL") submitted an application, dated December 27, 2001, requesting that the Alaska Oil and Gas Conservation Commission issue an aquifer exemption for purposes of Class II disposal in the Cohoe Unit #1 well located near Kasilof, Alaska. Additional information requested by the Commission was received on February 25, 2002 and March 28, 2002. 2. The Commission published notice of an opportunity for a public hearing in the Anchorage Daily News on January 25,2002. 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 the UNOCAL Aquifer Exemption application and a copy of a proposed aquifer exemption order to the U.S. Environmental Protection Agency, Region 10, ("EP A Region lO") on April 2, 2002, in accordance with Section 14 of the November 22, 1991 Memorandum of Agreement between EP A Region 10 and the Commission. 6. EP A Region 10 did not object to the aquifer exemption order for the Cohoe # 1 well. FINDINGS: 1. In correspondence dated December 27, 2001 UNOCAL requested an aquifer exemption to accommodate disposal injection of Class II oil field waste into the Sterling and Beluga Formations in the Cohoe Unit #1 well. Additional information was received on February 25, 2002 and March 28, 2002. e . 2. Unocal has requested an aquifer exemption for all aquifers within a one-half mile radius and below 2,800' measured depth (MD) in the Cohoe Unit #1 well. 3. The Cohoe Unit #1 well is a fonner wildcat exploration well drilled in 1973 to a total depth of 15,683' MD and subsequently plugged and abandoned. The well is located on the Kenai Peninsula approximately 3 miles northwest of Kasilof and 2 miles south of the Kenai Gas Field. 4. Wireline log analytical techniques, which comply with EP A recommended methods as described in "Survey of Methods to Detennine Total Dissolved Solids Concentrations", (KEDA Project No. 30-956), were used to characterize fonnation water total dissolved solids (TDS) contents in the Cohoe Unit #1 well. 5. Wireline log analysis from the Cohoe Unit #1 well demonstrates that the interval for which UNOCAL has requested the aquifer exemption contains water with a TDS concentration between 3,000 and 10,000 mg/l. 6. The EP A exempted all freshwater aquifers in the adjacent Kenai Gas Field below a depth of 1300 feet in 40 CFR 147.102. 7. Two disposal wells in the Kenai Gas field, the KU 11-17 and KU 14-4, are injecting Class II wastes in stratigraphic intervals equivalent to that proposed for the Cohoe Unit #1 well. 8. The KU 11-17 and KU 14-4 are both injecting in the Sterling Fonnation between true vertical depths of 3,970 to 4,570 and have safely disposed of over 687,000 and 829,000 barrels of oil field waste respectively. 9. The perfonnance of the KU 11-17 and KU 14-4 wells demonstrates the Sterling Fonnation contains significant confining layers that are sufficient to prevent movement of Class II wastes into sources of freshwater. 10. Six water wells have been identified within a mile of the Cohoe Unit #1 well. The nearest water well is approximately .6 miles from the proposed injection site. 11. The deepest water wells in the Cohoe Unit #1 vicinity are approximately two hundred feet. Potable water in this area is confined to Quaternary deposits that are approximately 150 thick in the Cohoe Unit #1 well. 12. Those portions of freshwater aquifers occurring within a one-half mile radius and below 2800' MD in the Cohoe Unit #1 well do not currently serve as a source of drinking water. CONCLUSIONS: 1. Those portions of freshwater aquifers occurring below 2800' MD in the Cohoe Unit #1 well are situated at a depth and location that makes recovery of water for drinking water purposes economically impractical. Aquifer Exemption Order #8 Cohoe Unit #1 June 6, 2002 Page 2 e e 2. Those portions of aquifers occurring within a one-half mile radius and below 2800' MD in the Cohoe Unit #1 well cannot reasonably be expected to serve as an underground source of drinking water. 3. Those portions of aquifers occurring within a one-half mile radius and below the depth of 2800' MD in the Cohoe Unit #1 well qualify as exempt freshwater aquifers under 20 AAC 25.440(a). NOW, THEREFORE, IT IS ORDERED THAT the aquifers occurring within a one-half-mile radius and below the depth of 2800' MD in the Cohoe Unit #1 well are exempt under 20 AAC 25.440. DONE at Anchorage, Alaska, and dated June 6, 2002. ',." ð'<""'~'" C~I~~ Alaska Oil and G Conservation Commission ø Daniel T. Seamount, Jr., Commissioner Alaska Oil and Gas Conservation Commission AS 3] .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 10-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the 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., lOth day after the application for rehearing was filed). Aquifer Exemption Order #8 Cohoe Unit #1 June 6, 2002 Page 3 NY PUBLIC LIBRARY DIV E, GRAND CENTRAL STATION POBOX 2221 NEW YORK, NY 10163-2221 US MIN MGMT SERV, CHIEF OCS STATS & INFO 381 ELDEN ST MS 4022 HERNDON, VA 20170-4817 TECHSYS CORP, BRANDY KERNS PO BOX 8485 GATHERSBURG, MD 20898 SD DEPT OF ENV & NATRl RESOURCES, all & GAS PROGRAM 2050 W MAIN STE #1 RAPID CITY, SD 57702 LINDA HAll LIBRARY, SERIALS DEPT 5109 CHERRY ST KANSAS CITY, MO 64110-2498 IOGCC, POBOX 53127 OKLAHOMA CITY, OK 73152-3127 BAPIRAJU 335 PINYON IN COPPEll, TX 75019 STANDARD AMERICAN all CO, Al GRIFFITH POBOX 370 GRANBURY, TX 76048 H J GRUY, ROBERT RASOR 333 CLAY STREET SUITE 3850 HOUSTON, TX 77002 CHEVRON, PAUL WALKER 1301 MCKINNEY RM 1750 HOUSTON, TX 77010 e 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 BP EXPLORATION (ALASKA), INC., LIBRARY/INFO CTR POBOX 87703 CHICAGO, Il 60680-0703 ALFRED JAMES III 107 N MARKET STE 1000 WICHITA, KS 67202-1811 R E MCMillEN CONSULT GEOl 202 E 16TH ST OWASSO, OK 74055-4905 US DEPT OF ENERGY, ENERGY INFORMATION ADMINISTRATION MIR YOUSUFUDDIN 1999 BRYAN STREET STE 1110 DALLAS, TX 75201-6801 XTO ENERGY, MARY JONES 810 HOUSTON ST STE 2000 FORT WORTH, TX 76102-6298 PURVIN & GERTZ INC, LIBRARY 2150 TEXAS COMMERCE TWR 600 TRAVIS ST HOUSTON, TX 77002-2979 all & GAS JOURNAL, BOB WilLIAMS 1700 W lOOP SOUTH STE 1000 HOUSTON, TX 77027 e ARENT FOX KINTNER PLOTKIN KAHN, LIBRARY WASHINGTON SQ BlDG 1050 CONNECTICUT AV NW WASHINGTON, DC 20036-5339 U S DEPT OF ENERGY, PHYLLIS MARTIN MS EI823 1000 INDEPENDENCE SW WASHINGTON, DC 20585 DPC, DANIEL DONKEl 2121 NORTH BAYSHORE DR #616 MIAMI, Fl 33137 ILLINOIS STATE GEOl SURV, LIBRARY 469 NATURAL RESOURCES BlDG 615 E PEABODY DR CHAMPAIGN,ll 61820 UNIV OF ARKANSAS, SERIALS DEPT UNIV LIBRARIES FAYETTEVillE, AR 72701 all & GAS JOURNAL, LAURA BEll POBOX 1260 TULSA, OK 74101 DEGOl YER & MACNAUGHTON, MIDCONTINENT DIVISION ONE ENERGY SQ, STE 400 4925 GREENVlllE AVE DALLAS, TX 75206-4083 SHEll WESTERN E&P INC, G.S. NADY POBOX 576 HOUSTON, TX 77001-0574 RAY TYSON 2016 MAIN #1415 HOUSTON, TX 77002-8844 AURORA GAS, G. SCOTT PFaFF 10333 RICHMOND AVENUE, STE 710 HOUSTON, TX 77042 PETRAL CONSULTING CO, DANIEL L LIPPE 9800 RICHMOND STE 505 HOUSTON, TX 77042 MARATHON OIL COMPANY, GEORGE ROTHSCHILD JR RM 2537 PO BOX4813 HOUSTON, TX 77210 EXXON EXPLORATION CO.. T E ALFORD POBOX 4778 HOUSTON, TX 77210-4778 PETR INFO, DAVID PHILLIPS POBOX 1702 HOUSTON, TX 77251-1702 EXXONMOBIL PRODUCTION COMPANY, GARY M ROBERTS RM 3039 POBOX 2180 HOUSTON, TX 77252-2180 CHEVRON CHEM CO, LIBRARY & INFO CTR POBOX 2100 HOUSTON, TX 77252-9987 WATTY STRICKLAND 2803 SANCTUARY CV KA TY, TX 77450-8510 INTL OIL SCOUTS, MASON MAP SERV INC POBOX 338 AUSTIN, TX 78767 ROBERT G GRAVELY 7681 S KIT CARSON DR LITTLETON, CO 80122 US GEOLOGICAL SURVEY, LIBRARY BOX 25046 MS 914 DENVER, CO 80225-0046 e GAFFNEY, CLINE & ASSOC., INC., LIBRARY 1360 POST OAK BLVD., STE 2500 HOUSTON, TX 77056 UNOCAL, REVENUE ACCOUNTING POBOX 4531 HOUSTON, TX 77210-4531 TEXACO EXPLORATION & PRODUCTION INC, CORRY WOOLlNGTON PO BOX 36366 HOUSTON, TX 77236 PHILLIPS PETROLEUM COMPANY, W ALLEN HUCKABAY PO BOX 1967 HOUSTON, TX 77251-1967 EXXONMOBIL PRODUCTION COMPANY, J W KIKER ROOM 2086 PO BOX2180 HOUSTON, TX 77252-2180 MARATHON OIL COMPANY, NORMA L CALVERT POBOX 3128, Ste 3915 HOUSTON, TX 77253-3128 TESORO PETR CORP, LOIS DOWNS 300 CONCORD PLAZA DRIVE SAN ANTONIO, TX 78216-6999 XTO ENERGY, DOUG SCHULTZE 3000 N GARFIELD SUITE 175 MIDLAND, TX 79705 DIANE SUCHOMEL 10507D W MAPLEWOOD DR LITTLETON, CO 80127 C & R INDUSTRIES, INC... KURT SAL TSGA VER 7500 W MISSISSIPPI AVE STE C4 LAKEWOOD, CO 80226-4541 e MARK ALEXANDER 7502 ALCOMITA HOUSTON, TX 77083 EXXON EXPLOR CO, LAND/REGULATORY AFFAIRS RM 301 POBOX 4778 HOUSTON, TX 77210-4778 CHEVRON USA INC., ALASKA DIVISION ATTN: CORRY WOOLlNGTON POBOX 1635 HOUSTON, TX 77251 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 JIM WHITE 4614 BOHILL SAN ANTONIO, TX 78217 BABCOCK & BROWN ENERGY, INC., 350 INTERLOCKEN BLVD STE 290 BROOMFIELD, CO 80021 GEORGE G VAUGHT JR POBOX 13557 DENVER, CO 80201 JERRY HODGDEN GEOL 408 18TH ST GOLDEN, CO 80401 NRG ASSOC, RICHARD NEHRING POBOX 1655 COLORADO SPRINGS, CO 80901- 1655 PLAYER GAS CO., GARY PLAYER 1671 WEST 546 S CEDER CITY, UT 84720 BABSON & SHEPPARD, JOHN F BERGQUIST POBOX 8279 VIKING STN LONG BEACH, CA 90808-0279 US GEOLOGICAL SURVEY, KEN BIRD 345 MIDDLEFIELD RD MS 999 MENLO PARK, CA 94025 ECONOMIC INSIGHT INC, SAM VAN VACTOR POBOX 683 PORTLAND, OR 97207 DUSTY RHODES 229 WHITNEY RD ANCHORAGE, AK 99501 FAIRWEATHER, DUANE VAAGEN 715 L STREET STE 7 ANCHORAGE, AK 99501 FOREST OIL, JIM ARLINGTON 310 K STREET STE 700 ANCHORAGE, AK 99501 STATE PIPELINE OFFICE, LIBRARY KATE MUNSON 411 W 4TH AVE, STE 2 ANCHORAGE, AK 99501 DEPT OF REVENUE, DAN DICKINSON, DIRECTOR 550 W 7TH AVE, SUITE 500 ANCHORAGE, AK 99501 e RUBICON PETROLEUM, LLC, BRUCE I CLARDY SIX PINE ROAD COLORADO SPRINGS, CO 80906 US GEOLOGICAL SURVEY, LIBRARY 2255 N GEMINI DR FLAGSTAFF, AZ 86001-1698 ANTONIO MADRID POBOX 94625 PASADENA. CA 91109 SHIELDS LIBRARY, GOVT DOCS DEPT UNIV OF CALIF DAVIS, CA 95616 US EPA REGION 10, THOR CUTLER OW-137 1200 SIXTH AVE SEATTLE, WA 98101 GUESS & RUDD, GEORGE LYLE 510 L ST, STE 700 ANCHORAGE, AK 99501 DEPT OF REVENUE, OIL & GAS AUDIT DENISE HAWES 550 W 7TH A V STE 570 ANCHORAGE, AK 99501 DEPT OF ENVIRON CONSERVATION, DIV OF AIR & WATER QUALITY TOM CHAPPLE 555 CORDOVA STREET ANCHORAGE, AK 99501 DEPT OF ENVIRON CONSERVATION, DIVOF ENVIRONMENTAL HEALTH JANICE ADAIR 555 CORDOVA STREET ANCHORAGE, AK 99501 PRESTON GATES ELLIS LLP, LIBRARY 420 L ST STE 400 ANCHORAGE, AK 99501-1937 e JOHN A LEVORSEN 200 N 3RD ST #1202 BOISE, 10 83702 MUNGER OIL INFOR SERV INC, POBOX 45738 LOS ANGELES, CA 90045-0738 ORa NEGRO, INC., 9321 MELVIN AVE NORTHRIDGE, CA 91324-2410 H L WANGENHEIM 5430 SAWMILL RD SP 11 PARADISE, CA 95969-5969 MARPLES BUSINESS NEWSLETTER, MICHAEL J PARKS 117 W MERCER ST STE 200 SEATTLE, WA 98119-3960 DEPT OF REVENUE, BEVERLY MARQUART 550 W 7TH A V STE 570 ANCHORAGE, AK 99501 TRUSTEES FOR ALASKA, 1026 W. 4th Ave, Ste 201 ANCHORAGE, AK 99501 AURORA GAS, J. EDWARD JONES 1029 W 3RD AVE, STE 220 ANCHORAGE, AK 99501 DEPT OF REVENUE. CHUCK LOGSTON 550 W 7TH AVE, SUITE 500 ANCHORAGE, AK 99501 ALASKA DEPT OF LAW, ROBERT E MINTZ ASST ATTY GEN 1031 W 4TH AV STE 200 ANCHORAGE, AK 99501-1994 GAFO,GREENPEACE PAMELA MILLER 125 CHRISTENSEN DR. #2 ANCHORAGE, AK 99501-2101 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS JULIE HOULE 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 AK JOURNAL OF COMMERCE, OIL & INDUSTRY NEWS ROSE RAGSDALE 2000 INTL AIRPORT RD W #A10 ANCHORAGE, AK 99502 HDR ALASKA INC, MARK DALTON 2525 C ST STE 305 ANCHORAGE, AK 99503 ANADARKO, MARK HANLEY 3201 C STREET STE 603 ANCHORAGE, AK 99503 FINK ENVIRONMENTAL CONSULTING, INC., THOMAS FINK, PHD 6359 COLGATE DR. ANCHORAGE, AK 99504-3305 AMERICA/CANADIAN STRATIGRPH CO, RON BROCKWAY 4800 KUPREANOF ANCHORAGE, AK 99507 US BUREAU OF LAND MNGMNT, ANCHORAGE DIST OFC DICK FOLAND 6881 ABBOTT LOOP RD ANCHORAGE, AK 99507 VECO ALASKA INC., CHUCK O'DONNELL 949 EAST 36TH AVENUE ANCHORAGE, AK 99508 e DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS TIM RYHERD 550 W 7th AVE STE 800 ANCHORAGE, AK 99501-3510 DNR, DIV OF OIL & GAS JAMES B HAYNES NATURAL RESRCE MGR 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 DEPT OF NATURAL RESOURCES, DIV OIL & GAS WILLIAM VAN DYKE 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 BRISTOL ENVIR AND ENG SERVICE, MIKE TORPY 2000 W. INT'L AIRPORT RD #C-1 ANCHORAGE, AK 99502-1116 YUKON PACIFIC CORP, 1400 W BENSON BLVD STE 525 ANCHORAGE, AK 99503 ALASKA 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 ROSE RAGSDALE 3320 EAST 41ST AVENUE ANCHORAGE, AK 99508 TRADING BAY ENERGY CORP, PAUL CRAIG 5432 NORTHERN LIGHTS BLVD ANCHORAGE, AK 99508 e 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 BRUCE WEBB 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 ALASKA JOURNAL OF COMMERCE, ED BENNETT 2000 INTL AIRPORT W #A10 ANCHORAGE, AK 99502 BAKER OIL TOOLS, ALASKA AREA MGR 4710 BUS PK BLVD STE 36 ANCHORAGE, AK 99503 N-I TUBULARS INC, 3301 C Street Ste 209 ANCHORAGE, AK 99503 ANADRILL-SCHLUMBERGER, 3940 ARCTIC BLVD #300 ANCHORAGE, AK 99503-5711 JAMES E EASON 8611 LEEPER CIRCLE ANCHORAGE, AK 99504-4209 BUREAU OF LAND MANAGEMENT, GREG NOBLE 6881 ABBOTT LOOP ROAD ANCHORAGE, AK 99507 UOA/ ANCHORAGE, INST OF SOCIAL & ECON RESEARCH TERESA HULL 3211 PROVIDENCE DR ANCHORAGE, AK 99508 THOMAS R MARSHALL JR 1569 BIRCHWOOD ST ANCHORAGE, AK 99508 us BLM AK DIST OFC, GEOLOGIST ARTHUR BANET 949 EAST 36TH AVE STE 308 ANCHORAGE, AK 99508 US MIN MGMT SERV, AK OCS REGIONAL DIR 949 E 36TH AV RM 110 ANCHORAGE, AK 99508-4302 US MIN MGMT SERV, LIBRARY 949 E 36TH A V RM 603 ANCHORAGE, AK 99508-4363 JOHN MILLER 3445 FORDHAM DR ANCHORAGE, AK 99508-4555 PHILLIPS ALASKA INC., LAND MANAGER JIM RUUD P.O. BOX 100360 ANCHORAGE, AK 99510 PHILLIPS ALASKA INC., STEVE BENZLER ATO 1404 POBOX 100360 ANCHORAGE, AK 99510-0360 PETROLEUM INFO CORP, KRISTEN NELSON POBOX 102278 ANCHORAGE, AK 99510-2278 AL YESKA PIPELINE SERV CO, LEGAL DEPT 1835 S BRAGAW ANCHORAGE, AK 99512-0099 JWL ENGINEERING, JEFF LIPSCOMB 9921 MAIN TREE DR. ANCHORAGE, AK 99516-6510 DAVID CUSATO 600 W 76TH A V #508 ANCHORAGE, AK 99518 e US MIN MGMT SERV, RICHARD PRENTKI 949 E 36TH AV ANCHORAGE, AK 99508-4302 GORDON J. SEVERSON 3201 WESTMAR CIR ANCHORAGE, AK 99508-4336 Us MIN MGMT SERV, FRANK MILLER 949 E 36TH A V STE 603 ANCHORAGE, AK 99508-4363 USGS - ALASKA SECTION, LIBRARY 4200 UNIVERSITY DR ANCHORAGE, AK 99508-4667 PHILLIPS ALASKA INC., JOANN GRUBER ATO 712 POBOX 100360 ANCHORAGE, AK 99510-0360 PHILLIPS ALASKA INC., MARK MAJOR ATO 1968 POBOX 100360 ANCHORAGE, AK 99510-0360 PHILLIPS ALASKA INC., KUP CENTRAL WELLS ST TSTNG WELL ENG TECH NSK 69 POBOX 196105 ANCHORAGE, AK 99510-6105 ANCHORAGE DAILY NEWS, EDITORIAL PG EDTR MICHAEL CAREY POBOX 149001 ANCHORAGE, AK 99514 NORTHERN CONSULTING GROUP, ROBERT BRITCH, P.E. 2454 TELEQUANA DR. ANCHORAGE, AK 99517 ASRC, CONRAD BAGNE 301 ARCTIC SLOPE AV STE 300 ANCHORAGE, AK 99518 e 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, RESOURCE EVAL JIM SCHERR 949 E 36TH A V RM 603 ANCHORAGE, AK 99508-4363 REGIONAL SUPRVISOR, FIELD OPERATION, MMS ALASKA OCS REGION 949 E 36TH A V STE 308 ANCHORAGE, AK 99508-4363 CIRI, LAND DEPT POBOX 93330 ANCHORAGE, AK 99509-3330 PHILLIPS ALASKA INC., LEGAL DEPT MARK P WORCESTER POBOX 100360 ANCHORAGE, AK 99510-0360 PHILLIPS ALASKA INC., LAND DEPT JAMES WINEGARNER POBOX 10036 ANCHORAGE, AK 99510-0360 AL YESKA PIPELINE SERV CO, PERRY A MARKLEY 1835 S BRAGAW - MS 575 ANCHORAGE, AK 99512 DAVID W. JOHNSTON 320 MARINER DR. ANCHORAGE, AK 99515 GERALD GANOPOLE CONSULT GEOL 2536 ARLINGTON ANCHORAGE, AK 99517-1303 ARMAND SPIELMAN 651 HILANDER CIRCLE ANCHORAGE, AK 99518 HALLIBURTON ENERGY SERV, MARK WEDMAN 6900 ARCTIC BLVD ANCHORAGE, AK 99518-2146 JACK 0 HAKKILA POBOX 190083 ANCHORAGE, AK 99519-0083 MARATHON OIL COMPANY, 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 SHA VELSON PO BOX 3269 HOMER, AK 99603 DOCUMENT SERVICE CO, JOHN PARKER POBOX 1468 KENAI,AK 99611-1468 PENNY VADLA PO BOX 467 NINILCHIK, AK 99639 e TESORO ALASKA COMPANY, PO BOX 196272 ANCHORAGE, AK 99519 ENSTAR NATURAL GAS CO, PRESIDENT TONY IZZO POBOX 190288 ANCHORAGE, AK 99519-0288 UNOCAL, POBOX 196247 ANCHORAGE, AK 99519-6247 BP EXPLORATION (ALASKA) INC, MR. DAVIS, ESQ POBOX 196612 MB 13-5 ANCHORAGE, AK 99519-6612 BP EXPLORATION (ALASKA) INC, SUE MILLER POBOX 196612 MIS LR2-3 ANCHORAGE, AK 99519-6612 PINNACLE, STEVE TYLER 20231 REVERE CIRCLE EAGLE RIVER, AK 99577 JAMES RODERICK PO BOX 770471 EAGLE RIVER, AK 99577-0471 PHILLIPS PETROLEUM CO, ALASKA OPERATIONS MANAGER J W KONST P 0 DRAWER 66 KENAI, AK 99611 KENAI PENINSULA BOROUGH, ECONOMIC DEVEL DISTR STAN STEADMAN POBOX 3029 KENAI, AK 99611-3029 BELOWICH, MICHAEL A BELOWICH 1125 SNOW HILL AVE WASILLA, AK 99654-5751 e OPSTAD & ASSOC, ERIK A OPSTAD PROF GEOL POBOX 190754 ANCHORAGE, AK 99519 MARATHON OIL COMPANY, OPERATIONS SUPT W.C. BARRON POBOX 196168 ANCHORAGE, AK 99519-6168 UNOCAL, KEVIN TABLER POBOX 196247 ANCHORAGE, AK 99519-6247 BP EXPLORATION (ALASKA) INC, INFO RESOURCE CTR MB 3-2 POBOX 196612 ANCHORAGE, AK 99519-6612 BP EXPLORATION (ALASKA), INC., MARK BERLINGER MB 8-1 PO BOX 196612 ANCHORAGE, AK 99519-6612 L G POST O&G LAND MGMT CONSULT 10510 Constitution Circle 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 NANCY LORD PO BOX 558 HOMER, AK 99623 JAMES GIBBS POBOX 1597 SOLDOTNA, AK 99669 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 NICK STEPOVICH 543 2ND AVE FAIRBANKS, AK 99701 RICK WAGNER POBOX 60868 FAIRBANKS, AK 99706 DEPT OF NATURAL RESOURCES, DIV OF LAND REG MGR NORTHERN REGION 3700 AIRPORT WAY FAIRBANKS, AK 99709-4699 RICHARD FINEBERG PO BOX416 ESTER, AK 99725 SENATOR LOREN LEMAN STATE CAPITOL RM 113 JUNEAU, AK 99801-1182 e KENAI NATL WILDLIFE REFUGE, REFUGE MGR POBOX 2139 SOLDOTNA, AK 99669-2139 VALDEZ VANGUARD, EDITOR POBOX 98 VALDEZ, AK 99686-0098 UNIV OF ALASKA FAIRBANKS, PETR DEVEL LAB DR V A KAMATH 427 DUCKERING FAIRBANKS, AK 99701 FAIRBANKS DAILY NEWS-MINER, KATE RIPLEY POBOX 70710 FAIRBANKS, AK 99707 K&K RECYCL INC, POBOX 58055 FAIRBANKS, AK 99711 UNIV OF ALASKA FBX, PETR DEVEL LAB SHIRISH PATIL 437 DICKERING FAIRBANKS, AK 99775 DEPT OF ENVIRON CONSERV SPAR, CHRIS PACE 410 WILLOUGHBY AV STE 105 JUNEAU, AK 99801-1795 e VALDEZ PIONEER, POBOX 367 VALDEZ,AK 99686 EVERGREEN WELL SERVICE CO., JOHN TANIGAWA PO BOX 871845 WASILLA, AK 99687 COOK AND HAUGE BERG, JAMES DIERINGER, JR. 119 NORTH CUSHMAN, STE 300 FAIRBANKS, AK 99701 C BURGLlN POBOX 131 FAIRBANKS, AK 99707 ASRC, BILL THOMAS POBOX 129 BARROW, AK 99723 UNIVERSITY OF ALASKA FBKS, PETR DEVEL LAB DR AKANNI LAWAL POBOX 755880 FAIRBANKS, AK 99775-5880 #6 #'ß)S7""~ i ft ~ ~~~ "'1?: ~~ '4{ PR~C. UNaSTATESENVIRONMENTALPROTECT~GENCY REGION 10 \ 1200 Sixth Avenue Seattle, WA 981 01 Reply To Attn Of: OW-137 June 5, 2002 RECEIVED Ms. Cammy Taylor, Commissioner Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue, Suite 100 Anchorage, Alaska 99501 11 Ii'!. "[1 "002 ,.,u¡ ~ I J (. ¡~$kà{n!& Gems. Gomffi1SS10í' Anchorage RE: Request for an Aquifer Exemption for the Cohoe Unit #1 well, Kasilof, Alaska - Seward Meridian, T3N, RllW, Section 8, 819 feet south, 1,302 feet East. Dear Ms. Taylor: My staff has reviewed the application by Unocal Corporation for an Aquifer Exemption of the Sterling Formation below 2800 feet measured depth (MD) in the vicinity of the Cohoe Unit #1 Well in the Cook Inlet Basin near Kasilof, Alaska. The Alaska Oil and Gas Conservation Commission (AOGCC) permitted Class IT disposal well is located in Section 8, T3N, RIIW, S.M. 819 Ïeet South, 1302 feet East. Kenai Borough, Alaska. The Cohoe #1 Well will be used to dispose of Class IT oilfield waste fluids. As you know, aquifer exemptions are limited to only those areas related to a specific permit and for the intervals needed for injection. We understand that the initial injection will occur at approximately 5000 feet MD, however Unocal's representative, Faye Sullivan, on May 30, 2002 has informed EP A that the interval up to 2800 feet is likely to be utilized for injection due the nature of the geology. The applicant has requested an aquifer exemption due to the uncertainty regarding the injectivity of the sands and they have stated it is likely they will need to utilize all available sands for the disposal of wastes. Injection will be into the Sterling Formation below a depth of 2800 feet MD and the injected fluids are to remain below that depth. Your findings and our review indicate the Sterling Formation in the vicinity of the well contains fluids with a total dissolved solids (TDS) content of over 3,000 mglliter. The applicant has supplied information indicating the Cohoe Well is located approximately three (3) miles northwest of Kasilof approximately 2 miles south of the Kenai Gas Field, and located approximately ~ mile north of Coal Creek, a tributary of the Kasilof River. Six water wells were located within about a one mile area of the site and the nearest well is located 0.6 miles from the injection site. Vicinity well logs show the presence of two primary fresh water o Printed on Recycled Paper ~ e 2 bearing zones, both in quaternary deposits, extending to a depth of about 45 feet and a deeper unit that extends to a depth of about 200 feet, both beneath and between blue clay units. The deeper water wells tend to be located in units in the uplands near the site where the quaternary unit tends to be thicker. Your conclusions include that those portions of aquifers occurring below 2800 feet MD in the Cohoe#1 well are situated at a depth and locations that makes recovery of water for drinking water purposes economically impractical and those portions of aquifers within Y2 mile radius and below 2800 feet cannot reasonably be expected to serve as an underground source of drinking water. Evidence submitted by the applicant also shows the surface glacial aquifers are commonly underlain by over 2000 feet of inter-bedded low energy, low permeability inter-fluve deposits of flood plain siltstone shale and high energy braided stream deposits plus continental sequence meandering stream deposits and associated coals comprised of bed-load conglomerates and point bar sandstones commonly overlain by flood plain siltstones and mudstones. Based your findings. and our review, the Environmental Protection Agency (EP A) has determined that the Sterling Formation below 2800 feet MD within Y2 mile of the Cohoe # 1 Well is not reasonably expected to supply water to a public water system. Because of the absence of comments during the public comment period, EP A assumes that the proposed exemption is consistent with the Alaska ground water standards. The ground water standards are contained within the Alaska Water Quality Standards (18AAC-ìO.OO5) (Rebecca Smith, ADEC). EPA does not object to an exemption for the Sterling Formation below 2800 feet MD within Y2 mile of the well. As a result of this exemption, the Sterling Formation below 2800 feet MD within Y2 mile of the Cohoe #1 Class II disposal well will no longer be defined 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 defined 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@epa.gov. Sincerely, .J~ ~/L) Tim Hamlin, Manager cvr- t Ground Water Protection Unit cc: M. Salazar, OGWDW Joseph Ryan, RlO-ORC Rebecca Smith, ADEC, Juneau #5 ifjActUlkfllk,ud / Mø (& \,' . Unocal Alaska __ Union Oil Company of Calif~ 909 West 9th Avenue, P.O. Sox 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7685 Facsimile 273-7685 or 263-7901 UNOCALe Faye W. Sullivan Advising Environmental Scientist May 30,2002 Mr. Thor Cutler U.S. Environmental Protection Agency Region 10, Water Compliance Section 1200 Sixth Avenue, OW-133 Seattle, WA 98101 Dear Mr. Cutler: Cohoe #1 Freshwater Aquifer Exemption Request As Tim Brandenburg and I discussed with you on Friday, May 10; 2002; Unocal has requested a Freshwater Aquifer Exemption for all strata below 2800 feet MD/TVD. We have demonstrated to the best of our ability with all the data available that the sands within the proposed freshwater exemption interval are effectively sealed off from the surface glacial aquifer by hundreds of aggregate feet of shale, coal and low permeability siltstone, Due to uncertainties regarding the injectivity of the sands within the proposed injection interval, Unocal has requested an aquifer exemption for an interval substantially larger than the injection interval to allow for the possibility that we may have to seek an injection permit for some additional sands shallower within the freshwater exemption intervql. .It has been our intent to prepare for such a possibility by demonstrating that all strata below 2800' MD/TVD should qualify for freshwater exemption. Further, our disposal options in Alaska are very limited and we will rely on this well for disposal of wastes from several of our Kenai Peninsula facilities. It is likely that Unocal will need to utilize all available sands within the proposed injection interval for the disposal of wastes. Please contact me should you have further questions. Sincerely, 3¥id ~ (j Faye W. Sullivan cc: Robert Crandall, AOGCC Dan Seamount, AOGCC Tim Brandenburg Mark Lynch RECEIVED Jü¡\¡ 0 5 2002 Alaska Oil & Gons. ;.JOH\¡ìlISSI(P AnchoraQ€ #4 . . Subject: Date: Thu, 02 May 2002 15:32:02 -0700 From: Cutler. Thor@epamail.epa.gov To: cammy _ taylor@admin.state.ak.us 1) Special thanks to Tom and you for the grant work.. It is in the works. 2) The letter (Surfcote temp rule authorization) in the mail to you and BP 3) Cohoe #1 Well aquifer Authorization.... in the batting box. I note they ask for Aq Exempt from 2800 (bottom of casing) and deeper. They need aq exempt for the injection zone, which is at 5100 feet. A confining layer is from 5000 to 5100 feet MD. Therefore I have called Faye Sullivan and asked her to help me understand why they want the upper portion ... I am looking for a justification for exempting from 2800 to 5000 feet MD, otherwise we will lean toward exempting what they need (mnamely, aq. exempt from 5000 and lower. I await Faye's call back, otherwise without justification, we will support Aq exempt below 5000 (the confining/injection zone. Sincerely Thor Cutler 206-553-1673 fax 206-553-1280 cutler.thor @epa.gov 10ft 5/30/0210:04 AM . . A note to file on salinity calculations in the Cohoe Unit #1 Well submitted by Unocal 3/29/02 Robert Crandall The Unocal application for aquifer exemption in the Cohoe Unit #1 well relies on the SP log to calculate formation water salinity. This is perhaps appropriate for this well because significant (but probably none commercial) saturations of gas occur throughout the well. Gas saturations will cause salinity estimates derived the resistivity-porosity method to be much to low or fresh. AOGCC policy has been to use the resistivity-porosity methods when possible and we have found them applicable to this well. Attachment 1 to this memo is a e-mail from Unocal to me of a spread sheet comparing resistivity-porosity derived salinities to SP calculated ones. (the spread sheet wrapped which makes it hard to read) In all cases below 1750 the average of these values is above 3,000, but I feel two of the values (2940 and 4710) are skewed by gas saturations toward low salinity. Attachment 2 is a section of the Cohoe mud log from 2700-3100. Note the gas in the mud falls off significantly below 2960, while penetration rates remain very high. Attachment 3 are some calculations I made that compare salinity estimates from resistivity-porosity methods at 2940 and 2960. The 2960 sand is continuous to approximately 2800. The 2960 estimate (3100 ppm) is some 25% higher than the 2940 estimate using the same method. This exercise establishes the formation waters below 2800 have salinities exceeding 3000 ppm. RE: Coho Salinity Data.xls . . Subject: RE: Coho Salinity Data.xls Date: Thu, 28 Mar 2002 13:49:57 -0800 From: "Buthman, David B" <buthbdb@unocal.com> To: "Crandall, Robert P -Vendor" <Bob_Crandall@admin.state.ak.us> Union Oil Company of California Cohoe Unit #1 Sec. 8-T3N-R11W Salinity Calculations from Well Logs Cohoe Unit #1 SP METHOD Rwa METHOD Depth Tgrad Tf SP Kc Rmf @Tf Rmfeq Rweq Salinity Porosity Rt F Rwa Salinity (ft) (F/ft) (F) (mv) (ohmm) (ohmm) ( ohmm) (ppm) (ohmm) (ohmm) (ppm) 115 0.0083 66 -30 69.8 3.3 2.8 7.5 770 0.3 380 8.3 46.0 97 160 0.0083 66 23 69.8 3.2 2.8 1.3 4600 0.3 120 8.3 14.5 400 560 0.0083 70 20 70.3 3.1 2.6 1.4 4200 0.3 130 8.3 15.8 350 960 0.0083 73 16 70.7 3.0 2.5 1.5 4000 0.3 90 8.3 10.9 475 1750 0.0083 80 25 71. 6 2.7 2.3 1.0 5000 0.3 52 8.3 6.3 800 2940 0.0083 89 32 72.9 2.5 2.1 0.8 6250 0.28 18 9.6 1.9 2500 3820 0.0083 97 27 73.9 2.3 1.9 0.8 5100 0.28 12 9.6 1.3 3500 4710 0.0083 104 24 74.8 2.1 1.8 0.9 4600 0.26 17 11.2 1.5 2700 5360 0.0083 109 20 75.6 2.0 1.7 0.9 4200 0.24 10 13 .3 0.8 5100 6300 0.0083 117 20 76.6 1.9 1.6 0.9 4200 0.18 15 24.7 0.6 6000 6890 0.0083 122 24 77.3 1.8 1.6 0.8 4300 0.17 20 28.0 0.7 5000 7950 0.0083 131 25 78.4 1.7 1.5 0.7 4700 0.12 22 59.2 0.4 8000 Notes: Tsurface = 65 F Italics estimates; bold = core values; underline = gas show Rmf @ 65 F = 3.3 Salinity from Schlumberger Chart - Resistivity of NaCL Solutions (1991) Base of freshwater indicated on Dual Induction log at 125' MD Did the above work? ] 0£2 3/28/2002 2:36 PM . . ! ..I..·:'.'."":J.'. , '¡',-. .L-!.... 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Enter yellow values. Depth Phi Rt m Rw RhoMA RhoS temp tds Coho2940 Coh02960 Coho3820 Coh04710 Coho5360 Coho6300 calculatiom 3/26 RPC 0.891136 2.65 2.65 2.13 2.13 2.28 96 101 110 2,600 3,100 3,400 2,OOOgas 3,700 4,500 . . e UNOCAL8 Alaska Resources Memo To: Mr. Steve Davies, Geologist Alaska Oil & Gas Conservation Commission 333 West 7th Ave., Ste. 100 Anchorage, Alaska 99501 From: Mark Lynch, Geologist Unocal Alaska 909 W. 9th Ave Anchorage, AK 99501 ~. ~t;. . va· "'if.· ~\~ 1. ~'/ "q,x -'tÞ, ""q>, T~ ¡ c ~. "'+(J'J.; '-~~,-;~¡Z ~ç.r' v~ Date: February 25, 2002 Re: Addendum to Freshwater Aquifer Exemption Application Cohoe Unit #1 Well, Kasilof, Alaska. Reason for Addendum This Addendum is submitted at the request of the office of AOGCC to address the possible occurrence of gaseous hydrocarbons in sandstones within the proposed Freshwater Aquifer Exemption interval in the Cohoe Unit #1 well. The Mud Log from the subject well indicates the presence of methane gas in sandstones of the Sterling and Beluga formations below 4700' MD. Unocal has asked for a Freshwater Aquifer Exemption for all sands below 2800' MD in the subject well. Figures attached in support of this discussion:: 1. Seismic Base Map and Time Structure Map on the Top of Tyonek Formation 2. North-South 2D Seismic Line UN99-7 3. East-West 2D Seismic Line C72-2 4. Mud Log for the Cohoe Unit #1 well (attached) Evidence for Gas within the Proposed Injection Interval Mud Log data from the subject well indicates an abrupt increase in background and total gas at approximately 4700' MD, which can be attributed to an increase in the amount and thermal maturity of coal seams within the Sterling and Beluga formations below that depth. The increased occurrence of gas "shows" with increasing depth drilled is a commonly observed phenomenon on the Kenai Peninsula. Taken alone, the Mud Log data suggest the possibility of gas reservoirs within the subject interval. Unocal's analysis of the open hole wireline log data from this well suggests that gas is present within these sands but in quantities or saturation too low to be produced. The Petrophysical Composite Log submitted as Attachment 5 to the Freshwater Aquifer Exemption Application indicates that water . Page 1 e . saturation in sands with good gas shows on the Mud Log ranges from 60% to 80% (Le., gas saturation ranges from 40% to 20%). Experience demonstrates that gas can not be produced from Sterling and/or Beluga reservoirs when water saturation is that high. At the time of drilling (1973) Unocal as operator of the well tested two possible gas sands within the proposed injection interval through perforations at 5347' to 5357' MO and 5610' to 5620' MO, as described in the Freshwater Exemption Application which preceded this Addendum. As summarized in that document, the fluid recovered during a drill stem test (OST #9) of the perforated intervals consisted of gas cut salt water that was most likely contaminated with completion brine or drilling mud filtrate. Still, the fact that some gas was recovered on test suggests that some small amount of gas is present in that sand. The failure to flow gas at a commercially viable rate can be attributed to the low gas saturation in that sand. Discussion of Cohoe Unit #1 Salinity Calculations Gaseous hydrocarbons are more resistive than saline connate formation waters; thus, the presence of gas mixed with salt water in a reservoir may result in a freshwater-like log response-that is, the normally highly conductive saline water will appear fresher (more resistive) due to the increased resistivity gained from the gas in the reservoir. It can be very difficult to determine if a high resistivity response is due to the presence of fresh water or gas in a sandstone. Unocal analyzed the well logs from the Cohoe Unit #1 well to determine the salinity of formation waters within and above the proposed injection interval; these data were presented to AOGCC in the Freshwater Aquifer Exemption Application that preceded this Addendum. Unocal's analysis suggests that sandstones within the proposed injection interval have formation water salinity in the range of 4000 to 6000 ppm, at the low end of the normal range of salinity for rocks at these depths in this area. It is Unocal's opinion that the low calculated salinity is a result of partial gas saturation in these sands, rather than an indication of truly fresh connate water. The sandstones within the interval in which Unocal is seeking a Freshwater Aquifer Exemption (below 2800' MO) contain low saturation gas which has the net effect of making salinity calculations from well log data appear "fresher" than normal for this area. In its analysis, Unocal attempted to calculate salinity from only the "wettesf' looking sands, to avoid the possibility that the data would be affected by partial gas saturation in the chosen sands. A different interpreter might choose to do calculations on different sands; should those sands have a higher partial gas saturation, they might calculate a fresher water response. Unocal maintains that the salinity of the connate waters in sands of the Sterling and Beluga formations is at least as high as Unocal's calculations would suggest, and possibly even higher if gas is in fact present in those same rocks. It is unlikely that the formation water is any fresher than calculated, as that would have resulted in a much higher resistivity log response in the absence of any gas shows. The presence of gas in these rocks effectively suppresses the calculated water salinity; thus it is possible that the true water salinity is greater than calculated by Unocal. Potential for Loss of Gas Reserves Mud Log data suggests that most or all sandstone bodies below 4700' MO contain some amount of low saturation background gas. The consistent occurrence of gas "shows" in this interval is a direct result of the uniform distribution of coals in the geologic section, which are actively degassing into the neighboring sandstones. The gas shows do not necessarily indicate the presence of a working petroleum system or an efficient hydrocarbon trap. The unsuccessful OST of the Sterling sands at 5347' to 5357' MO and 5610' to 5620' MO confirm that gas is present in these sands in saturation too low to be produced. Similarly . Page 2 e . poor DST results from Beluga sandstones at 6872' to 6911' MD confirm the presence of low saturation gas in the section. Unocal's petrophysical analysis of the open hole wireline data (presented in the Freshwater Aquifer Exemption Application as Attachment 5, Composite Log) suggests that gas saturation in these sands averages about 20% of pore volume, an amount too low for gas to be produced from these reservoirs. There is no reason to think that economically significant gas reserves will be lost if the sandstones below 4700' MD are utilized for injection purposes. The results of the DSTs in the Cohoe well confirm that some small amount of background or "show" gas is present in these rocks, but at a saturation too low to be commercially viable. Moreover, as the attached 2D seismic data shows, the Cohoe well was drilled on a southward-plunging structural nose on the southern flank of the Kenai Gas Field, where production from this same section is known to occur. The Cohoe well penetrated the crest of the flanking nose structure some 1,300 feet down dip of the limits of the Kenai Gas Field and failed to find gas in produceable quantities. The attached seismic lines demonstrate clearly that there is no trapping configuration updip of the Cohoe Unit #1 well; hence, there is little or no chance that additional gas reserves are trapped updip of the Cohoe well within this structure. Summary Well log analysis corroborated by DST data indicates that methane gas is present in low saturation within some of the sandstones in the interval in which Unocal is seeking a Freshwater Aquifer Exemption and Class II Disposal Well Injection permit. Well test results confirm that no economically viable accumulation of gas exists within the Cohoe structure. It is highly unlikely-given the discouraging results of the Cohoe well and the absence of a significant untested trap-that any operator would attempt to red rill this structure for the purpose of exploring for natural gas in the shallow Sterling and Beluga section. The water within these sandstone units would not normally be considered useable as a likely source of freshwater because true formation water salinity is at least as high and maybe higher than the 4000 to 6000 ppm calculated, and moreover because gas is present in some minute quantity within most--if not all--of these sands. It is highly unlikely-given the depth of these sands and the quality of the water contain therein-that they would ever be utilized as a source of water for human consumption. It is Unocal's opinion that the sandstone beds below 4700' in the Cohoe Unit #1 well are neither viable gas reservoirs nor are they potential freshwater aquifers. Rather, they most likely contain normal connate formation waters contaminated with methane gas in minute, non-produceable quantities. I sincerely hope this Addendum addresses the concerns raised by AOGCC. Please do not hesitate to call me if you have any additional requests or comments. Thank you, ~~( Mark T. Lynch Geologist, Unocal Alaska . Page 3 FIGURE 1 Top Tyonek Time Structure Map. Structure contours (white lines) are superimposed ona2D seismic basemap (orange lines). The two seismic lines referenced in Figures 2 and 3 are highlighte:¡d in yellow; township lines are shown in blue; wells are shown in green. The large cluster of wells. nearìhe center of the map represents the:¡ limits of the Kenai Gas Field. Note that the Cohoe Unit #1weIL\iVas drilled to the south and well dOwndipof the Kenai field along the crest ofa south-plunging anticlinal nose. There is no trapping configuration present between the Cohoe structure and the Kenai Gas Field updip; it is fairto assume that most (or all) ofìhe gas in the Sterling and Beluga Formations has migrated updip to become trapped in the Kenai field, where it has been proven to exist .. Page 4 FIGURE 2 North-South 2D Seismic Line UN99...7. The top of the Beluga Formation is indicated by the dark blue horizon; the top of the Tyonek Formation is indicated by the purple horizon; the top of the Hemlock Conglomerate is indicated by the yellow horizon. Note that the Cohoe Unit #1 well (on the right) Wª$ drilled well downdip of the lowest wells on the Kenai Gas Field structure (to the left). .. Page 5 .. , FIGURE 3 East-West 2DSeismic LineC72-2. The top ofthe Beluga Formation is indicated by the dark blue horizon; the top of the Tyonek Fqrmation is indicated by the purple horizon; the tOPQf th~ Hemlock Conglomerate is indicated by the yellow horizon. NotethattheCohoe Unit#1weUwas driHed Œ:}arthe crest of the anticlinal structure; there is little to no possibility of any gas being presentupdip of thisweU in this structure. 4» Page 6 #3 Cohoe #1 AEO . . Subject: Cohoe #1 AEO Date: Mon, 25 Feb 2002 10:48:34 -0900 From: "Dan T. Seamount" <Dan _ Seamount@admin.state.ak.us> Organization: doa-aogcc To: Jody J Colombie <jody_colombie@admin.state.ak.us> CC: "Camille O. Taylor" <Cammy_Taylor@admin.state.ak.us>, Julie Heusser <julie_heusser@admin.state.ak.us> Jody, We have just received the additional information from Unocal regarding the Cohoe #1 ABa which will be sufficient to allow us to make a decision without holding an hearing. Please advise Unocal that we will not be having the hearing on Tuesday 2/26/02. thanks dan 1 of 1 2/25/02 10:42 AM RE: Cohoe Unit # 1, Aquifer Exemption, Unocal . . Subject: RE: Cohoe Unit # 1, Aquifer Exemption, Unocal Date: Mon, 4 Peb 200216:36:09 -0900 From: "Bob Shavelson" <bob@in1etkeeper.org> To: "'Jody Colombie'" <jody_co10mbie@admin.state.ak.us> Thanks Jody; would you please fax the application to 235-4069? In need the supplemental information, maybe I can stop by your office later this week? Thanks for your help - Bob Cook Inlet Keeper P.O. Box 3269 Homer, AK 99603 ph: (907) 235-4068 ext. 22 fax: (907) 235-4069 bob@inletkeeper.org www.inletkeeper.org -----Original Message----- From: Jody Colombie (mailto:jody-colombie@admin.state.ak.us] Sent: Monday, February 04,20024:04 PM To: Bob Shavelson Subject: Re: Cohoe Unit # 1, Aquifer Exemption, Unocal Mr. Shavelson: The Cohoe Unit #1 Aquifer Exemption application is not e-mailable. It was provided by the operator in hard copy form. The application is eight pages in length, but there is quite a few attachments, including logs. If you would like the application only, I would be happy to fax it to you. Please provide me with your fax number if this is what you wish me to do. Jody Colombie Special Staff Assistant Bob Shavelson wrote: Ms. Colombie - I am interested in the above-referenced AOGCC review, and would like to get a copy of the application. Because the deadlines for hearing and comment are fast approaching, curious if such materials would be emailable?Thank you - Bob Shavelson Cook Inlet Keeper P.O. Box 3269 Homer, AK 99603 ph: (907) 235-4068 ext. 22 fax: (907) 235-4069 bob@inletkeeper.org 10f2 2/5/02 8:32 AM #2 STATE OF ALASKA ADVERTISING ORDER . NOTICE TO PUBLISHER . INVOICE ST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., ..: TIFIED AFFIDAVIT OF PUBLICATION (PART2 OF THIS FORM) WITH ATTACHED COpy OF ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE ADVERTISING ORDER NO. AO-02214020 F AOGCC R 333 W 7th Ave, Ste 100 o Anchorage, AK 99501 M AGENCY CONTACT Jody Colombie PHONE DATE OF A.O. January 24.2002 PCN ¿ Anchorage Daily News POBox 149001 Anchorage,AK 99514 (907) 793 -1 7.?1 DATES ADVERTISEMENT REQUIRED: January 25, 2002 THE MA TERlAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: Type of Advertisement X Legal D Display Account #STOF0330 Advertisement to be published was e-mailed D Classified DOther (Specify) SEE ATTACHED PUBLIC HEARING REF TYPE 1 VEN 2 ARD 3 4 FIN AMOUNT NUMBER AOGCC, 333 W. 7th Ave., Suite 100 Anchorage, AK 99501 AMOUNT DATE I I TOTAL OF I PAGE 1 OF ALL. PAGES$ 2 PAGES COMMENTS 02910 SY CC PGM LC ACCT FY NMR DIST LID 01 02140100 73540 2 3 4 REQUISITIONED BY: IOlllf<~ 02-902 (Rev. 3/94) Publisher/Original Copies: Department Fiscal, Department, Receiving AO.FRM e e Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: Cohoe Unit #1 Well Aquifer Exemption Application, Beluga Formation Kasilof, Alaska - Sec. 8, T3N, R11 W Union Oil Company of California Union Oil Company of California ("Unocal") by letter dated December 27,2001, has submitted an application for a Freshwater Aquifer Exemption in support of an application for a Class II Underground Injection Well in the Cook Inlet Basin near the town of Kasilof, Alaska. The requested order would exempt from consideration as freshwater, all porous, water-bearing formations below a depth of 2,800 feet for an areal extent of Y2 mile radius around the Cohoe Unit #1 well, located 819 feet from the south line and 1,302 feet from the east line of Section 8, T3N, R11 W, Seward Meridian. This exemption will allow Unocal to inject Class II oil field wastes into formations that have been penetrated by the Cohoe Unit #1 wellbore. A person may submit written comments regarding the requested exemption prior to February 26, 2002 to the Alaska Oil and Gas Conservation Commission at 333 West ih Avenue, Suite 100, Anchorage, Alaska 99501. In addition, the Commission has tentatively set a public hearing on February 26, 2002 at 9:00 am at the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. A person may request that the tentatively scheduled hearing be held by filing a written request with the Commission prior to February 11, 2002. If a request for a hearing is not timely filed, the Commission will consider the issuance of an order without a hearing. To learn if the Commission will hold the public hearing, please call 793-1221. If you are a person with a disability who may need a special modification in order to comment or to attend the public hearing, please contact Jody Colombie at 793-1221 before February 19, 2002. . b=~~ Chair Published January 25, 2002 Anchorage Daily News AO#0221420 Re: Ad order . it Subject: Re: Ad order Date: 24 Jan 2002 16:31:28 -0900 From: Lorene Solivan <lsolivan@adn.com> To: Jody Colombie <jody_colombie@admin.state.ak.us> JODY, Thank you, your ad is good to go for tomorrow. Lorene 257-4296 On Thursday, January 24, 2002, Jody Colombie <jody_colombie@admin.state.ak.us> wrote >Please publish 1/25/02. > >Thank you. Jody > > 1 of 1 1/24/02 4:40 PM . Anchorage Dally News Affidavit of Publication . 1001 Northway Drive, Anchorage, AK 99508 AD# DATE PO ACCOUNT PRICE PER DAY OTHER CHARGES OTHER CHARGES #2 GRAND TOTAL 285746 01 /25/2002 02214020 STOF0330 $131.52 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $131.52 $0.00 $0.00 $131.52 $131.52 Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Subscribed and sW~;Z0re this date: Notary Public in and for the State of Alaska. Third Division. Anchorage, Alaska Re:Cohoe Unit #1 Well Aquifer Exemption Application, Beluga Formation Kasllof, Alaska - Sec. 8, T3N, RllW Union Oil Company of ,California Union Oil Company of California ("Unocal") by letter dated DecembE1r 27, 2001, has submitted an application for a Fresh- water Aquifer Exemp- tion in support of an ap- plication fora Class II Underground Iniection Well in the Cook InletBa- sin near the town of Kasl- lo!' Alaska. The re- quested order would exempt from consider- ation as freshwater, all porous', water~bearing formations be,low a depth of 2,800 feet for an areal extent of 1/2 mile radius around the Cohoe Unit #1 well, located 819 feet fram the south line and r.302.1eet from the east line of Section 8, T3N, RllW, Seward Meridian. This exemption will al- low Unocal to iniect Class II oil field wastes into formatfons that have been penetrated bY the Cohoe Unit #1 wellbore. A perso,n may submit written :comments re- garding the requested eX- emption prior to Febru- arv 26, 2002 to the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 9950l. In addition, the Commis- : sian has tentativelv set a public hearing on Febru- arv 26, 2002 at 9:00 am at the Alaska Oil and Gas Conservation Commis- sion at 333 West 7th Av- enue, Suite. 100, Anchor- age, Alaska .99501. A person may request that, the tentotivelv scheduled hearing be held by filing a written request with the Commission prior to Feb" ruarv 11, 2002. If a request for a hearing is not timelv filed, the Commissiori.·will·. con- sider the Issuance of an order without a hearing. To learn if the Commls-, sian will hold thepublic ' hearing, please call 793-1221. STATE OF ALASKA THIRD JUDICIAL DISTRICT Lorene Solivan, being first duly sworn on oath deposes and says that she is an advertising representative of the Anchorage Daily News, a daily newspaper. That said newspaper has been approved by the Third Judicial Court, Anchorage, Alaska, and it now and has been published in the English language continually as a daily newspaper in Anchorage, Alaska, and it is now and dunng all saiâ time was printed in an office maintained at the aforesaid place of publication of said newspaper. That the annexeâ is a copy of an advertisement as it was published in regular issues (and not in supplemental form) of said newspaper on the above dates and that such newspaper was regularly distributed to its subscribers during all of said period. That the full amount of the fee charged for the foregoing PUbl?' . n is not in excess of the rate charged private individua!S. S;; '-.i ,) , Signed C::;/ --- 'if+¿~ MY COMMISSION EXPIRES: a//\) /,/ " ., ~.~'V~ / I \\l((((({lrr \~\\.\.\~. ~'.IJ';,/r... ~of:;J··· ...... '. ....'i'.~ ~ (t'.' 0 'T AR,.: :~. ~;~. ~ : ~ ___ ø.::: g : PuSUC : It) ~ ~;.~ ...... §.:~~ ~'"9.. . . ~ OF ,.\J!.'~:V" ~,~. . ,.' ~.§fÞ,\..... ///J}})~m\\\" If YOU (Ire a per$on with a disabi I itv who may need a special modification in. order to comment or to' allend the ¡>ublic hearing, I>lease contact Jody CO" lombiè at 793-1221 before February 19, 2002. Commy Oechsll ToylQr Chair Pub: Januo1'Y25, 2002 . STATE OF ALASKA ADVERTISING ORDER I NOTICE TO PUBLISHER _ ADVERTISING ORDER NO. INVOICE: UST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., vcRTIFIED AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COPY OF AO-02214020 ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE F AGENCY CONTACT DATE OF A.O. Jody Colombie Janmny 24, ?OO? PHONE PCN (907) 793 -I?? 1 DATES ADVERTISEMENT REQUIRED: AOGCC 333 West 7th Avenue, Suite 100 o Anchorage, AK 99501 M R T o Anchorage Daily News POBox 149001 Anchorage, AK 99514 January 25, 2002 THE MATERIAL BElWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON mE DATES SHOWN. SPECIAL INSTRUCTIONS: Account #STOF0330 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 2001, and thereafter for _ consecutive days, the last publication appearing on the _ day of . 2001, and that the rate charged thereon is not in excess of the rate charged private individuals. Subscribed and sworn to before me This _ day of 2001, Notary public for state of My commission expires 02-901 (Rev. 3/94) Page 2 AO.FRM PUBLISHER NY PUBLIC LIBRARY DIV E, GRAND CENTRAL STATION POBOX 2221 NEW YORK. 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CA 95969-5969 MARPLES BUSINESS NEWSLETTER. MICHAEL J PARKS 117 W MERCER ST STE 200 SEATTLE, WA 98119-3960 DEPT OF REVENUE, BEVERLY MARQUART 550 W 7TH AV STE 570 ANCHORAGE, AK 99501 DEPT OF REVENUE, OIL & GAS AUDIT DENISE HAWES 550 W 7TH AV STE 570 ANCHORAGE, AK 99501 DEPT OF REVENUE, CHUCK LOGSTON 550 W 7TH AVE, SUITE 500 ANCHORAGE, AK 99501 FOREST OIL, JIM ARLINGTON 310 K STREET STE 700 ANCHORAGE, AK 99501 e NRG ASSOC. RICHARD NEHRING POBOX 1655 COLORADO SPRINGS, CO 80901- 1655 TAHOMA RESOURCES, GARY PLAYER 1671 WEST 546 S CEDER CITY, UT 84720 BABSON & SHEPPARD, JOHN F BERGQUIST POBOX 8279 VIKING STN LONG BEACH, CA 90808-0279 US GEOLOGICAL SURVEY, KEN BIRD 345 MIDDLEFIELD RD MS 999 MENLO PARK, CA 94025 ECONOMIC INSIGHT INC, SAM VAN VACTOR POBOX 683 PORTLAND, OR 97207 STATE PIPELINE OFFICE, LIBRARY KATE MUNSON 411 W 4TH AVE, STE 2 ANCHORAGE, AK99501 DUSTY RHODES 229 WHITNEY RD ANCHORAGE, AK 99501 DEPT OF ENVIRON CONSERVATION, DIV OF AIR & WATER QUALITY TOM CHAPPLE 555 CORDOVA STREET ANCHORAGE, AK 99501 AURORA GAS. J. EDWARD JONES 1029 W 3RD AVE, STE 220 ANCHORAGE, AK 99501 YUKON PACIFIC CORP, JOHN HORN VICE CHM 1049 W 5TH AV ANCHORAGE, AK 99501-1930 PRESTON GATES ELLIS LLP, LIBRARY 420 L ST STE 400 ANCHORAGE, AK 99501-1937 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS TIM RYHERD 550 W 7th AVE STE 800 ANCHORAGE, AK 99501-3510 DNR, DIV OF OIL & GAS JAMES B HAYNES NATURAL RESRCE MGR 550 W 7TH AVE. SUITE 800 ANCHORAGE, AK 99501-3560 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS BRUCE WEBB 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 AK JOURNAL OF COMMERCE, OIL & INDUSTRY NEWS ROSE RAGSDALE 2000 INTL AIRPORT RD W #A10 ANCHORAGE, AK 99502 N-I TUBULARS INC, 3301 C Street Ste 209 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 BUREAU OF LAND MANAGEMENT, GREG NOBLE 6881 ABBOTT LOOP ROAD ANCHORAGE, AK 99507 UOA/ ANCHORAGE, INST OF SOCIAL & ECON RESEARCH TERESA HULL 3211 PROVIDENCE DR ANCHORAGE. AK 99508 e ALASKA DEPT OF LAW, ROBERT E MINTZ ASST ATTY GEN 1031 W 4TH AV STE 200 ANCHORAGE, AK 99501-1994 DEPT OF REVENUE, OIL & GAS AUDIT FRANK PARR 550 W 7TH AVE STE 570 ANCHORAGE. AK 99501-3540 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS JULIE HOULE 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 DEPT OF NATURAL RESOURCES, PUBLIC INFORMATION CTR 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 BRISTOL ENVIR AND ENG SERVICE, MIKE TORPY 2000 W. INT'L AIRPORT RD #C-1 ANCHORAGE, AK 99502-1116 HDR ALASKA INC, MARK DALTON 2525 C ST STE 305 ANCHORAGE, AK 99503 ANADRILL-SCHLUMBERGER, 3940 ARCTIC BLVD #300 ANCHORAGE, AK 99503-5711 JAMES E EASON 8611 LEEPER CIRCLE ANCHORAGE, AK 99504-4209 US BUREAU OF LAND MNGMNT, ANCHORAGE DIST OFC PETER J DITTON 6881 ABBOTT LOOP ROAD ANCHORAGE, AK 99507 US BLM AK DIST OFC, GEOLOGIST ARTHUR BANET 949 EAST 36TH AVE STE 308 ANCHORAGE, AK 99508 e GAFO,GREENPEACE PAMELA MILLER 125 CHRISTENSEN DR. #2 ANCHORAGE, AK 99501-2101 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS JIM STOUFFER 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 DEPT OF NATURAL RESOURCES, DIV OIL & GAS WILLIAM VAN DYKE 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 ALASKA JOURNAL OF COMMERCE, ED BENNETT 2000 INTL AIRPORT W #A 10 ANCHORAGE, AK 99502 BAKER OIL TOOLS. ALASKA AREA MGR 4710 BUS PK BLVD STE 36 ANCHORAGE, AK 99503 ANADARKO, MARK HANLEY 3201 C STREET STE 603 ANCHORAGE, AK 99503 FINK ENVIRONMENTAL CONSULTING, INC., THOMAS FINK, PHD 6359COLGA TE DR. ANCHORAGE, AK 99504-3305 AMERICA/CANADIAN STRA TIGRPH CO, RON BROCKWAY 4800 KUPREANOF ANCHORAGE, AK 99507 US BUREAU OF LAND MNGMNT, ANCHORAGE DIST OFC DICK FOLAND 6881 ABBOTT LOOP RD 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 AV RM 603 ANCHORAGE, AK 99508-4302 US MIN MGMT SERV, RESOURCE EVAL JIM SCHERR 949 E 36TH AV RM 603 ANCHORAGE, AK 99508-4363 REGIONAL SUPRVISOR, FIELD OPERATNS, MMS ALASKA OCS REGION 949 E 36TH A V STE 308 ANCHORAGE, AK 99508-4363 CIRI, LAND DEPT POBOX 93330 ANCHORAGE, AK 99509-3330 PHILLIPS ALASKA, MARK MAJOR ATO 1968 POBOX 100360 ANCHORAGE, AK 99510-0360 PHILLIPS ALASKA, LEGAL DEPT MARK P WORCESTER POBOX 100360 ANCHORAGE, AK 99510-0360 PHILLIPS ALASKA, KUP CENTRAL WELLS ST TSTNG WELL ENG TECH NSK 69 POBOX 196105 ANCHORAGE, AK 99510-6105 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 e 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 US MIN MGMT SERV, LIBRARY 949 E 36TH A V RM 603 ANCHORAGE, AK 99508-4363 JOHN MILLER 3445 FORDHAM DR ANCHORAGE, AK 99508-4555 PHILLIPS ALASKA, LAND MANAGER JIM RUUD P.O. BOX 100360 ANCHORAGE, AK 99510 PHILLIPS ALASKA, LAND DEPT JAMES WINE GARNER POBOX 10036 ANCHORAGE, AK 99510-0360 PHILLIPS ALASKA, JOANN GRUBER ATO 712 POBOX 100360 ANCHORAGE, AK 99510-0360 AL YESKA PIPELINE SERV CO, PERRY A MARKLEY 1835 S BRAGAW - MS 575 ANCHORAGE, AK 99512 DAVID W. JOHNSTON 320 MARINER DR. ANCHORAGE, AK 99515 GERALD GANOPOLE CONSULT GEOL 2536 ARLINGTON ANCHORAGE, AK 99517-1303 e US MIN MGMT SERV, AK OCS REGIONAL DIR 949 E 36TH AV RM 110 ANCHORAGE, AK 99508-4302 GORDONJ.SEVERSON 3201 WESTMAR CIR ANCHORAGE, AK 99508-4336 US MIN MGMT SERV, FRANK MILLER 949 E 36TH A V STE 603 ANCHORAGE, AK 99508-4363 USGS - ALASKA SECTION, LIBRARY 4200 UNIVERSITY DR ANCHORAGE, AK 99508-4667 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 JWL ENGINEERING, JEFF LIPSCOMB 9921 MAIN TREE DR. ANCHORAGE, AK 99516-6510 DAVID CUSATO 600 W 76TH A V #508 ANCHORAGE, AK 99518 ARMAND SPIELMAN 651 HILANDER CIRCLE ANCHORAGE. AK 99518 TESORO ALASKA COMPANY. PO BOX 196272 ANCHORAGE, AK 99519 ENSTAR NATURAL GAS CO, PRESIDENT TONY IZZO POBOX 190288 ANCHORAGE, AK 99519-0288 UNOCAL, POBOX 196247 ANCHORAGE, AK 99519-6247 BP EXPLORATION (ALASKA). INC., MARK BERLINGER MB 8-1 PO BOX 196612 ANCHORAGE, AK 99519-6612 BP EXPLORATION (ALASKA) INC, MR. DAVIS, ESQ POBOX 196612 MB 13-5 ANCHORAGE, AK 99519-6612 D A PLATT & ASSOC, 9852 LITTLE DIOMEDE CIR EAGLE RIVER, AK 99577 JAMES RODERICK PO BOX 770471 EAGLE RIVER, AK 99577-0471 PHILLIPS PETROLEUM CO, ALASKA OPERATIONS MANAGER J W KONST P 0 DRAWER 66 KENAI, AK 99611 KENAI PENINSULA BOROUGH, ECONOMIC DEVEL DISTR STAN STEADMAN POBOX 3029 KENAI, AK 99611-3029 e 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, PETE ZSELECZKY LAND MGR POBOX 196612 ANCHORAGE, AK 99519-6612 BP EXPLORATION (ALASKA) INC. SUE MILLER POBOX 196612 MIS LR2-3 ANCHORAGE, AK 99519-6612 PINNACLE, STEVE TYLER 20231 REVERE CIRCLE EAGLE RIVER, AK 99577 DEPT OF NATURAL RESOURCES. DGGS JOHN REEDER POBOX 772805 EAGLE RIVER, AK 99577-2805 RON DOLCHOK POBOX 83 KENAI, AK 99611 NANCY LORD PO BOX 558 HOMER, AK 99623 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, 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,INFO RESOURCE CTR MB 3-2 POBOX 196612 ANCHORAGE, AK 99519-6612 AMSINALLEE CO INC, WILLIAM 0 VALLEE PRES PO BOX 243086 ANCHORAGE, AK 99524-3086 L G POST O&G LAND MGMT CONSULT 10510 Constitution Circle EAGLE RIVER, AK 99577 COOK INLET KEEPER, BOB SHA VELSON PO BOX 3269 HOMER, AK 99603 DOCUMENT SERVICE CO, JOHN PARKER POBOX 1468 KENAI, AK 99611-1468 PENNY VADLA PO BOX 467 NINILCHIK, AK 99639 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 COOK AND HAUGEBERG, JAMES DIERINGER, JR. 119 NORTH CUSHMAN, STE 300 FAIRBANKS. AK 99701 FAIRBANKS DAILY NEWS-MINER, KATE RIPLEY POBOX 70710 FAIRBANKS. AK 99707 ASRC, BILL THOMAS POBOX 129 BARROW, AK 99723 UNIVERSITY OF ALASKA FBKS. PETR DEVEL LAB DR AKANNI LAWAL POBOX 755880 FAIRBANKS, AK 99775-5880 e JAMES GIBBS POBOX 1597 SOLDOTNA, AK 99669 AL YESKA PIPELINE SERVICE CO, VALDEZ CORP AFFAIRS SANDY MCCLINTOCK POBOX 300 MS/701 VALDEZ, AK 99686 NICK STEPOVICH 543 2ND AVE FAIRBANKS, AK 99701 RICK WAGNER POBOX 60868 FAIRBANKS, AK 99706 DEPT OF NATURAL RESOURCES, DIV OF LAND REG MGR NORTHERN REGION 3700 AIRPORT WAY FAIRBANKS, AK 99709-4699 RICHARD FINEBERG PO BOX 416 ESTER, AK 99725 SENATOR LOREN LEMAN STATE CAPITOL RM 113 JUNEAU, AK 99801-1182 e PACE, SHEILA DICKSON POBOX 2018 SOLDOTNA, AK 99669 VALDEZ PIONEER, PO BOX 367 VALDEZ,AK 99686 UNIV OF ALASKA FAIRBANKS, PETR DEVEL LAB DR V A KAMATH 427 DUCKERING FAIRBANKS, AK 99701 C BURGLlN POBOX 131 FAIRBANKS, AK 99707 K&K RECYCL INC. POBOX 58055 FAIRBANKS, AK 99711 UNIV OF ALASKA FBX, PETR DEVEL LAB SHIRISH PATIL 437 DICKERING FAIRBANKS, AK 99775 DEPT OF ENVIRON CONSERV SPAR, CHRIS PACE 410 WILLOUGHBY AV STe 105 JUNEAU, AK 99801-1795 · e Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: Cohoe Unit #1 Well Aquifer Exemption Application, Beluga Fonnation Kasilof, Alaska - Sec. 8, T3N, Rll W Union Oil Company of California Union Oil Company of California ("Unocal") by letter dated December 27,2001, has submitted an application for a Freshwater Aquifer Exemption in support of an application for a Class II Underground Injection Well in the Cook Inlet Basin near the town of Kasilof, Alaska. The requested order would exempt from consideration as freshwater, all porous, water-bearing fonnations below a depth of 2,800 feet for an areal extent of 'is mile radius around the Cohoe Unit #1 well, located 819 feet ITom the south line and 1,302 feet from the east line of Section 8, T3N, Rl1W, Seward Meridian. This exemption will allow Unocal to inject Class II oil field wastes into fonnations that have been penetrated by the Cohoe Unit #1 wellbore. A person may submit written comments regarding the requested exemption prior to February 26, 2002 to the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. In addition, the Commission has tentatively set a public hearing on February 26, 2002 at 9:00 am at the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. A person may request that the tentatively scheduled hearing be held by filing a written request with the Commission prior to February 11,2002. If a request for a hearing is not timely filed, the Commission will consider the issuance of an order without a hearing. To learn if the Commission will hold the public hearing, please call 793-1221. If you are a person with a disability who may need a special modification in order to comment or to attend the public hearing, please contact Jody Colombie at 793-1221 before February 19, 2002. . b~~:f Chair Published January 25, 2002 Anchorage Daily News AO#022 1420 i certify that on J,~ Ljl) I a copy of the above was faxed/mailed to ~ of the ~ng at ~r addresses of record: r7::V y e .5lJ / // tb . ^---' ~, / J C Ú/}t'CQí #1 EI e Unocal Alaska e Union Oil Company of California 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7685 Facsimile 273-7685 or 263-7901 · UNOCAL. Faye W. Sullivan Advising Environmental Scientist December 27,2001 Alaska Oil and Gas Conservation Commission 333 West 7th Ave #100 Anchorage, AK 99501-3539 RE: Application for a Freshwater Exemption for the Cohoe Unit #1 Well, Kasilof, Alaska - Seward Meridian, T3N, Rll W, Section 8, 819' South, 1,302' East · Dear Commissioner: Union Oil Company of California dba Unocal is submitting this application for a Freshwater Aquifer Exemption in support of the application for a Class II Underground Injection Well in the Cook Inlet Basin, near the town ofKasilof, Alaska. Attachment 1, Site Vicinity Map, shows the project location, while Attachment 2 presents a detail of the project area. Unocal proposes to reconfigure and redesignate the Cohoe Unit #1 well, which is currently designated a P&A (plugged and abandoned) well. In order to accommodate current and future disposal injection operations, a Freshwater Aquifer Exemption is requested for all porous water-bearing formations below a depth of 2,800 feet as seen in the Cohoe Unit #1 well, for an areal extent of ~ mile radius around the existing wellbore. If approved, Resource Conservation and Recovery Act (RCRA) exempt wastes generated by workover and drilling activity will be disposed within formations penetrated by the Cohoe Unit #1 wellbore. Other applications being submitted in coordination with this application include: · Application for a Class II Underground Injection Well (to be submitted at a later date). · Permit to Drill, Form 10-401. · Recompletion Application, Form 10-407 (to be submitted following reconfiguring the well). · Unocal Freshwater Aquifer Exemption Application - 12/19/01 · · · e e Supporting documentation is presented in this letter in the following format: pertinent regulations contained in 20 Alaska Administrative Code (AAC) 25.440 are cited, followed by a description of how each requirement is or will be met. Additionally, background information is summarized and graphical materials are attached as necessary. 20 AAC 25.440-FRESHW ATER AQUIFER EXEMPTION. (a) Upon receipt of a letter of application, and in accordance with (b) of this section, the commission will, in its discretion, issue an order designating a freshwater aquifer or portion of it as an exempt freshwater aquifer, if the freshwater aquifer meets the following criteria: (1) it does not currently serve as a source of drinking water, and it cannot now and will not in the future serve as a source of drinking water because (A) it is hydrocarbon-producing or can be demonstrated by the applicant to contain hydrocarbons that, considering their quantity and location, are expected to be commercially producible; (B) it is situated at a depth or location that makes recovery of water for drinking water purposes economically or technologically impractical; The proposed injection zone extends from 'approximately 5,140 to 6,000 measured depth (MD) as seen in the Cohoe Unit #1 well, or 5,121 to 5,981 feet below ground surface. There are numerous groundwater aquifers in the area found at shallow depths, beginning at about 30 feet. The deepest potable water well within 1 mile of the site is approximately 100 feet deep, and located 0.6 miles to the east- northeast of Cohoe Unit #1, as shown on AUachment 2 (Well 17542). Currently, the deepest water supply well in Alaska is approximately 1,140 feet deep (Westberg, 2001). It is extremely unlikely that exploration for potable water would extend to a depth approaching the proposed injection zone, or that any aquifer below 2,800 feet would be useful as a source of freshwater for human consumption. The background section below contains more information about local groundwater conditions. (C) it is so contaminated that recovery of water for drinking water purposes is economically or technologically impractical; or (2) the total dissolved solids content of the groundwater is more than 3,000 and less than 10,000 milligrams per liter (mgIL), and it is not reasonably expected to supply a public water system. Additionally, it should be noted that, while the United States Environmental Protection Agency (EP A) defines freshwater as containing less than 10,000 parts per million (ppm) Total Dissolved Solids (TDS), the Alaska Drinking Water Unocal Freshwater Aquifer Exemption Application - 12/19/01 - Page 2 of 8 e e . Secondary Maximum Contaminant Level for TDS in public water systems is 500 ppm [18 AAC 80.300(c)). Two sources of data exist for determining the TDS of aquifers within the subject interval in the Cohoe Unit #1 well-direct measurement of produced waters, and inferred measurements by borehole geophysical logs (K.E. Davis Associates, 1988). Laboratory measurements of water salinity in the subject interval in Cohoe Unit #1 are presented in Table 1. These data were compiled from water quality analyses of samples recovered on drill stem tests from perforated intervals 5,347to 5,357 feet and 5,610 to 5,620 feet within the proposed injection interval. This data was acquired in 1973, and was originally received by the office of the Alaska Oil and Gas Conservation Commission (AOGCC) on January 16, 1974, in the Well Completion or Recompletion Report and Log notice filed for the subject well. A copy of the original Well Completion Report and the Water Analysis Report for the subject interval are provided in Attachment 3. Table 1 Measured Salinity of Proposed Injection Interval . Sample Number 1 2 3 4 TDS mg/L 84,467 67,844 12,765 157,448 Sample Description - DST #9: perfs 5347-57' and 5610-20' Cloudy yellow water, floating scum, clear yellow filtrate Cloudy light brown water, clear yellow filtrate Cloudy water, filtrate clear Cloudy brown water. Filtrate clear light brown water The high measured TDS values reported in Table 1 suggest that the recovered fluid was likely contaminated with completion fluid filtrate, which was a 3 percent potassium chloride (KCI) solution with 250,000 ppm soldium chloride (NaCl,) as noted in the attached Well Completion Report. Therefore, additional salinity estimates for the subject interval and other intervals in the well were calculated from borehole geophysical logs. EP A guidelines regarding the calculation of water salinity from geophysical logs state that the Spontaneous Potential (SP) Method of calculation is preferred when: (1) low salinity or freshwater borehole fluids were used during logging; (2) formation and borehole resistivities are significantly different, resulting in large SP deflections; and (3) thick sand/shale beds are present (K.E. Davis Associates, 1988). The conditions present in the Cohoe Unit #1 well satisfy all of these requirements: the well was drilled with freshwater-based mud (300 ppm chlorides) and thick sands and shales with good SP deflection are present throughout the interval of interest. . EP A guidelines further note that the Resistivity (RwaJ Method is to be used when: (1) low porosity, thin bed carbonates are present; (2) accurate formation porosity Unocal Freshwater Aquifer Exemption Application - 12/19/01 - Page 3 of 8 e e is available; and (3) salt-based muds occupied the borehole during logging. None of these requirements are present in or satisfied by the conditions in the Cohoe Unit #1 well. Therefore, the SP Method is considered the most valid method of calculation in this case. · The calculations used in the SP Method of investigation are presented at the end of this report in Attachment 4. The results of these calculations are presented in Table 2. The salinities calculated by the SP Method show a predictable trend of increasing salinity with depth, and are therefore considered accurate and indicative of the true formation water salinities. These calculations demonstrate clearly that the water in the proposed injection interval is in the normal range of salinity for salt water-bearing subsurface formations. The TDS of the connate waters In formations within the proposed injection interval is estimated to be in the range of 4,000 to 6,000 mg/L, well above the minimum level of 3,000 ppm. Table 2 Calculated Salinity of Proposed Injection Interval Cohoe Unit #1 SP METHOD Depth Tgrad Tf SP Kc Rmf @Tf Rmfeq Rweq Salinity (ft) (F/ft) (F) (mv) (ohmm) (ohmm) (ohmm) (ppm}1 · 115 0.0083 66 -30 69.8 3.3 2.8 7.5 160 0.0083 66 23 69.8 3.2 2.8 1.3 560 0.0083 70 20 70.3 3.1 2.6 1.4 960 0.0083 73 16 70.7 3.0 2.5 1.5 1,750 0.0083 80 25 71.6 2.7 2.3 1.0 2,940 0.0083 89 32 72.9 2.5 2.1 0.8 3,820 0.0083 97 27 73.9 2.3 1.9 0.8 4,710 0.0083 104 24 74.8 2.1 1.8 0.9 5,360 0.0083 109 20 75.6 2.0 1.7 0.9 6,300 0.0083 117 20 76.6 1.9 1.6 0.9 6,890 0.0083 122 24 77.3 1.8 1.6 0.8 8,190 0.0083 133 23 78.7 1.7 1.4 0.7 Notes: 1 - Salinity from Schlumberger Chart -- Resistivity of NaCL Solutions (1991) Additionally, close examination of the Dual Induction Laterolog, included in Attachment 5 reveals that the base of Quaternary alluvium, which contains the majority of freshwater aquifers in the area, is at or near 125 to 155 feet measured depth/true vertical depth (MD/TVD) in the Cohoe Unit #1, or approximately 106 to 136 feet below ground level. The transition from freshwater to salt water is evidenced by the high resistivity of formations above 125 feet and the steady decrease in resistivity below. A discernable change in the SP curve response at 125 feet corroborates this relationship: above 125 feet the SP curve exhibits a · Unocal Freshwater Aquifer Exemption Application - 12/19/01 - Page 4 of 8 e e · "positive" response (deflected to the right) indicating freshwater, whereas below 125 feet it exhibits a normal "negative" response (deflected to the left) denoting saline connate formation waters. The SP curve exhibits a normal "negative" response throughout the remainder of the well to total depth. (b) To apply for exemption of a freshwater aquifer, an operator shall submit to the commission a letter of application that includes sufficient data to justify the proposal, including data to substantiate that the criteria in (a) of this section are met. The commission will provide 15 days legal notice and the opportunity for a public hearing on the matter in accordance with 20 AAC 25.540. This letter is submitted in application for a freshwater aquifer exemption. (c) Freshwater aquifers within the state that, as of June 19, 1986, are designated as exempt aquifers by the United States Environmental Protection Agency under 40 C.F.R. 147.102 are accepted as exempt aquifers by the commission. The proposed aquifer exemption zone is not included among the aquifers exempted by 40 CFR 147.102. BACKGROUND INFORMATION · The proposed injection well, Cohoe Unit #1, is a former wildcat exploration well originally drilled in 1973 and subsequently plugged and abandoned. It is currently plugged at a depth of approximately 5,000 feet. Cohoe Unit #1 is located on the Kenai Peninsula approximately 3 miles northwest of Kasilof and approximately 2 miles south of the Kenai Gas Field. It is located in an upland area approximately Yz-mile north of Coal Creek, a tributary to Kasilof River. The surface casing shoe in the Cohoe Unit #1 well extends to a depth of 2,712 feet MD. Drilling reports reveal that the casing was cemented with full returns; therefore, it is probable that a good cement bond exists from the casing shoe all the way to surface. Shallow Groundwater and Subsurface Deposits Publicly available records were searched to identify water wells in the site vicinity. Attachment 6 presents a summary of identified water wells. There were no water wells identified within ~- mile of the site. Six water wells were identified within about I-mile of the site. One additional well (Well 16145, Section 17, Gene Eaton) could potentially be located within either ~- or 1- mile, but there is insufficient location information to pinpoint the well beyond the section level. However, the descriptive location of the well is "Clam Gulch area," suggesting that it is not near the site. Records searched include: Division of Natural Resources Division of Mining Land and Water, Well Log Tracking database; Kenai Peninsula Borough tax records; Kenai Peninsula Borough phone directory; Kenai Peninsula Borough plat maps. · The nearest identified water well is approximately 0.6 miles from the injection site (Well 17452). Vicinity well logs show the presence of two primary freshwater bearing zones (both in Quaternary deposits): a shallow zone extending to a depth of about 45 feet, and deeper zones Unocal Freshwater Aquifer Exemption Application - 12/19/01 - Page 5 of 8 · · · . e which lie beneath and between blue clay units that range in thickness up to 40 or more feet. The deeper water bearing zones supplying local wells extend to depths of up to nearly 200 feet. Importantly, the deeper wells tend to be located in the uplands near the site, where the Quaternary blanket is thicker. Quaternary deposits extend to a depth of about 125 to 150 feet in the Cohoe Unit #1 well. Generally, the subsurface deposits containing aquifers in the Cohoe Unit #1 area are described as a complex mixture of glacial, eolian, marine, lacustrine, and bedrock materials. Most of the aquifers are discontinuous, and many are partially confined by clay lenses. According to Glass (1996), because of the complexity of subsurface deposits, "the depths, yields, water levels, and water quality of closely spaced wells are commonly dissimilar" . Bedrock Geology The anticipated injection unit is the Sterling Formation, which has been described as a continental sequence of meandering stream deposits and associated coals (Hayes et aI., 1976). Rocks in this sequence commonly include stacked successions of fluvial deposits that are characterized by bedload conglomerates and point bar sandstones, which are often overlain by floodplain siltstones and mudstones. Coals, where present, represent the vegetative cover that grew in abandoned channel meanders and oxbow lakes. Underlying the Sterling Formation are the meander belt and braided stream deposits of the Beluga Formation. This unit is typically composed of thinner, finer-grained sandstones, siltstones, and associated coals, with lesser amounts of bedload conglomerate. The top of the Beluga Formation occurs at 5,803 feet MD/TVD in the Cohoe Unit #1 well; the proposed injection interval encompasses approximately 200 feet of strata in the Beluga Formation. Overlying the Sterling Formation are glacial deposits comprised of interbedded high-energy braided stream deposits (sandstones and conglomerates) and low-energy, low-permeability interfluve deposits of floodplain siltstone and shale. The lithologic similarity between the glacial deposits and the underlying Sterling Formation makes the exact contact between the two units difficult, if not impossible, to determine. (There is no Mud Log :fÌom this well.) Unocal is seeking an aquifer exemption for all strata below a depth of 2,800 feet MD/TVD, as seen in the Cohoe Unit #1 well. The proposed injection zone comprises four or more massive and distinct packages of sandstone in the overall interval of 5,095 to 6,000 feet MD/TVD, as described in the Application for Class II Underground Injection Well which will be filed in the near future. Overlying these sandstones at a depth of 5,013 to 5,095 feet MD/TVD is a continuous shale and coal sequence that is over 80 feet thick; this section is more than adequate to act as a confining bed for the underlying sandstones in the proposed injection interval. Overlying this confining bed is an additional 4,800 feet of interbedded Sterling Formation sandstones and shales before the base of the Quaternary deposits, which contain the majority of useful :fÌeshwater aquifers, is reached at about 150 feet MD. Evaluation ofthe wireline logs :fÌom the Cohoe Unit #1 well reveals that the section overlying the proposed injection interval is comprised of no less than 1,000 feet of confining material, including almost 900 feet of shale and 325 feet of coal. (Wireline logs for this well are presented in Attachment 5). There is, for all Unocal Freshwater Aquifer Exemption Application - 12/19/01 - Page 6 of 8 · · · e e practicable purposes, no chance that fluid and material injected into the proposed injection interval will ever be able to breach the overlying section and come into contact with the shallow fresh water aquifers. This issue is discussed further in the application for a Class II Underground Injection Control well, which will be submitted in the near future. Comparative Considerations Precedent exists for injection of oilfield waste into the equivalent interval in at least two nearby wel1bores. AOGCC records show that the Kenai River Unit 11-17 well, with surface location in See 18, T4N, R11 W, Seward Meridian, is a designated disposal well in the interval 4,468 to 5,152 feet MD [3,970 to 4,570 feet TVD] in the Sterling Formation; aquifers below 1,300 feet are exempted in this wellbore. Records show that 687,535 barrels of waste have been injected into this wellbore as of June 2001. There is an aggregate 500 feet of confining beds present between the top ofthe injection interval and the base of the exemption zone at 1,300 feet TVD. AOGCC records also indicate that the Kenai River Unit 14-4 well is a designated disposal well in the interval 3,950 to 4,560 feet TVD, also in the Sterling Formation. More than 829,000 barrels of waste has been injected into this well since 1989. Both the Kenai River Unit 11-17 and 14-4 wells operate under a freshwater aquifer exemption authorized by the EP A in 40 CFR 147.102 for all aquifers below a depth of 1,300 feet within the Kenai Gas Field. A geologic cross section that demonstrates the stratal equivalency between proposed injection interval in the Cohoe Unit #1 and the existing injection intervals in the other two disposal wells has been provided as Attachment 7. Please contact me at (907) 263-7685 if you have questions or require additional information. Thank you for your attention to this matter. Sincerely, Jdf# ~~ Faye W. Sullivan Advising Environmental Scientist Unocal Freshwater Aquifer Exemption Application - 12/19/01 - Page 7 of 8 · · · e e REFERENCES K.E. Davis Associates (subcontract to Engineering Enterprises, Inc.), 1988, Survey of methods to determine total dissolved solids concentrations: U.S. EP A Underground Injection Control Program, EPA LOE Contract No. 68-03-3416, Work Assignment No. 1-0-13, Washington D.C. Glass, Roy, 1996. Ground-water Conditions and Quality in the Western Part of the Kenai Peninsula, Southcentral Alaska. U.S. Geological Survey Open-File Report 96-466. Hayes, J. B. et aI., 1976, Contrasts between braided and meandering stream deposits, Beluga and Sterling Formations (Tertiary), Cook Inlet, Alaska: in Alaska Geological Society Proceedings, p. 11-J27. Schlumberger, 1991, Log Interpretation Charts. Westberg, Wayne, 2001. Personal communication with Jean Bodeau, November 2001. ATTACHMENTS 1. Cohoe Unit # 1 Area Map 2. Cohoe Unit #1 Well Site Map 3. Original Well Completion Report and Water Analysis Report 4. Methodologies for Computing Salinity Measurements from Well Log Data 5. Well Logs Dual Induction Laterolog, Top101 feet MD - Base 15,636 feet MD (AOGCC and EPA only) Borehole Compensated Sonic Log: Top 101 feet MD - Base 6232 feet MD (AOGCC and EPA only) UNOCAL Petrophysical Composite Log: Top 2700 feet MD - Base 6800 feet MD 6. Summary of Existing Water Wells 7. Cross Section through Cohoe Unit #1 and Existing Disposal Injection Wells COMPANION APPLICATIONS 1. Application for Class II Underground Injection Well 2. Permit to Drill, Form 10-401 3. Recompletion Application, Form 10-407 Unocal Freshwater Aquifer Exemption Application - 12/19/01 - Page 8 of 8 · · · . ATTACHMENT 1 COHOE UNIT #1 AREA MAP e Unocal Freshwater Aquifer Exemption Application - 12/12/01 ~ \ is ü m ãJ o .c o 9 ¡¡; ü o c o ãJ ü ro w 3 õ' is. D ro ü N c::> AT I--i SCALE IN FEET -.--' o 20,000 o o o <Ó OJ co ro ATTACHMENT 1 UNOCAL ROAD GAS PERMITTING ò Z aJ Q COHOE UNIT #1 AREA MAP e e . ATTACHMENT 2 COHOE UNIT #1 WELL SITE MAP . . Unocal Freshwater Aquifer Exemption Application - 12/12/01 D ü N ill ill o .c o )) i1i ü o c o ill ü ro ø J o ~ v ro ü o :; o o N cD OJ ó z [!) o -, -I Cohoe Unit #1 Lat: 60 Deg 21 '38.4038" long: -151 Deg 13'08.1138" E: 279,306.9108 N: 2,325,791.0333 ADl: 389182 -I NC::>ATt-i SCALE IN FEET 212000 o 4,000 2'76000 ATTACHMENT 2 UNOCAL ROAD GAS PERMITTING COHOE UNIT #1 WELL SITE MAP ..\, ,~ e e · ATTACHMENT 3 Original Well Completion Report and Water Analysis Report · · Unocal Freshwater Aquifer Exemption Application - 12/12/01 ¡ ~', /.¡"~~:,""<;," -ìiifijì~f · . STATE O~ ALASKA SU"",T I·;I:~~:;~Ù; . ^,., NC,"',"CM cuuc '""''''''''~~~';;''''''i~:;~:=~,;¡:,,,,,,,..~..'i¡;pIL AND GAS CON'SmVATrON CO¡"~itdTTEE 50-133-20257 .~"-·""WELL Cèfl~ÃPLETIOI~~-ÕR"RËèÕ~¡\PLÊtiõ'r--i R-ÊPORT -AND LO¿:¡u, 1;~~Lt:_~~il~~\'n()~ ^-~u ~t:HLAL: . "ï';::"'ì·Ÿfi:;QT'\\'ì..t~ --l.ii:··-O . ~~~ -O¡-~-'--G";---' -' ,- - - a ~ ~-4. " 1" . WI:LL "111.1. DRY ~ Ûlh,'r ... .t .NülA..', ALL01"I1::t: OH '1"iUUI::: NA b. TYPE O~' COMPLETION: " ',~ ., , ;~ I I ¡ ! . . SI:\'1 rVl \\I:I..~ \\'01\1( 0 (1\·r.h o 1'1.1:<; 0 n.""K "lFr. 0 I~J:R\'n, Wildcat Other ____ .... ___ --.---_._ 8. UNIT,t-,\Jt.\1 01\ LE.-\St: NA;\lE Union-1\c,·.'IT1on t -Clark IU:}:I'· r.s 2. S.4Ml: or C!'·:HiI.'1·un UNION OIL Ca·1PJ\¡\JY OF CALIFOnNIA ~ÕfU.S.s 01" or£;;::::)J\ 909 Ì\'cst 9th Avenue, Jmchoragc, A1as)~a 9. Wl:1.L NO, Cohoe Unit III. -lö:ï:"úîi) A..'D POOL. OR WILDCAT Wildcat 99501 4. I.OCA'!lDS o¡-" W[Ll. (Rrport location clearly Clnå in occunJrHtCC u::itlt arty òtatr rCQu¡rfmcHI..)· At.l:.-1w 819.4'N & 1301.6'\\' of the SE corner, Section 8: . lUlW, S. M. A. t top p;·o~. Ir.tenal reported below T3N, 11. St:c., 1'., H., :>1.. (U01TO;ll HOW; ODJI:::CTIVE¡ At totll.J depth Not dircctional1y drilling. Section 8: T3N, R11W, 12. Pt:R.\IIT :-'0. 73-25 1:1. ;~~E2S,;;;UÒ r O~~~'~~~,¡;;Cii£O ri~;';l~O;; ~~:;:;(:;~:~D. rG. F~'~~~'nf~~ßD~,~u;;S~r. (;1\, ~rc)·117' '22V5 ~A~b~~~DM 18. 'rl¡)5·i'¡")L6D8El3~,rH'i.1D Ó< TVDI9. PLL;G, lJACK MD oS< -rVDI7!J' L..- ;\lULTI1"LE CO;.IPL.. \21,. ISTr.H' A1.5 DI\lLt.!:1J hY HOW MANY· ROTAR\' ;¡;00J."'· \ CAUL& TOOLS 200'O-1~ 083' . ' 22. Pr'W1'1'.1VCI1';G pn;:pw.\LlSI .Q~ TIllS ~O;lIPLE1.·ION-r.oP3 Jl.QT'0;lI, 1'F'1E ~lMl' A¡O;U -rVD) , . ~.·WAS DIR£C"I10:olAl 3e uga ö,-+S8'-G3/.J' ..)terl~ng:', 4U -5,0451 '}Tone1\: 10,9~2'-1J.t225' ; SUIlVEYl\lADÈ Hemlock 14,945'-15,520' "G" Sé.lJ1d 12,545'-14,785 Vertical hole ~.jJ) & TVD I No-Straight Same. I 24. 'rYl'E ELECTiClC A;ol!) OTHER LOGS HUN ')IT D¡IC_C--.7\';r r'T< _1"',....nL~...y Fr·n c· rR-lrr')D (l~-"--:cter ~1::,,::=;..\.-~~~ _........".I-..J._~_~~:::~,:_~:.~;A~...~.;....~~!..~.-_.:....'-- .ll.}J\ __: . ~'. CAS~~;C :T:.:CCnD (Rcpon :::.d) s.nngs $ct :!i wc:U) CJ'..5U~G-5-':2:;;-r--;E.·r..Î"r~ ., D·1;-OT' ì~ --:....-.:._~'"~~-'·i } 51:13 AT1i\CliEp I -- " GRADE {-E;:;VI'II SET (~ID) !...2!.~":: SlZr: ¡ t L:i.:~\Ir.~T¡;'G HECOIU> A;\IOU;';T PULLED --.-.- -..-- .. . :IN:¿:;:~ ;'ŒCCltD 2-:. 1'UßI:':C l~E'::'::>î..D SI:¿E, I T0P (~ID) I EOTTor,~ (;llD) ¡ SAC;:!; CE~JI:..-:-'-T· [ SCnEE:'I (;lWI SIZE DEPTH SET (~:D : PACh:I:H SET (;\!D¡ 'í--;#-:~;-- I j -. I . . SJ~,:: At_..'J\CllE...4..-_ I J ) í .~ "-'I' i"· -..-......\..___J__r-._.~.-L,---,-... '-"'r-~'---"-' - --- -, 28. PERFORATJOr..;S OP"E,."l TO ~JHOrUC·:.:.o~ (jntc:"v;¡), ~p,c and ;1~¡r.bcr) i~' "/\(.l?). SilOr. F;\.A::1 üRE. C=:.·.lL~TSQ:n:::::z.:::, ETC, . . þ) Œ.~ -æ U \:J~ ~~I?~r~"'TEiW!..L (~!D' I A~¡jU;\'r ¡,,'<D I';¡";O OF :llA1E?..lAL USED SEE ATTACHED J \1 ,L') . \ , ~ ~\~ ! h F.'I \ -. 2G. :w, _·_-l:';;T'otJÚëi:ioN-'' 1...-1). n:!,./ c;\:,- DATE rmS1: pnUDUC'l'WN ¡ I'RODUCT;ON l'l¡;lJ!ODA:~~Z;¡"¡::.i:f~,tI.~~umpir.~-,j.~ "r.d Iype o{ purr,pl ",'ELL STATUS (Pl'oduciac or :'Ilul-,n) ¡jAY" 01' Tl:S7. t¡~OUI\S 110T!::D Cl!O:U~ S!Zt; TPr-:.OI),N ¡.'em 01 !--1J 1: L. G¡-..s-;lICF. W'''fER-BBL. I GA5-0I1, 1t.'\TIO JTES'!" p.i.::.H.:OD , -~ -j.'LÒ\\"TL'UING iCASL'IG PIŒSSURE CA¡_CU1.A·.rr:;n OiL-,JSL, GA~Mcr. WATI::I1.-DBL. ¡OIL GHAVITY·APl (CO,lU\, PRESS. , 2·!-HOUH HATI: \. _ ., ____-1.-=:-,.. 3" CISI'OJ;TlOJ<: or (¡AS (,~vld. ;lrd Ja, iucl, "c'''''d, .,Ie.) WITS&SS¡;U IIY ¡nsy ---,y- 32. l.I.9T ùY ~:.1·TA{:F :.¡~~~~~~ Csg~[r Liner rccoEª-s, DST tfF9, Perf. OlK:¡:cd for DST' ~ p¡ perf. oncnecl fQr c~\1cczc. ----:1"rl hl'f(.h;""(".(Irl1f.r lhllt the ir.JJ('",~:il.nt; II. or:" .:dladu"d Infl:rlli.llthHJ Is ccn,.ll~te ¡i,nG corrcct t\H u¡,:h.':mllll'd (run1 an avuUnt.h· fl,r;r¡r.. ) J .. .-¡',~ ,Ir ..- ",- .....,.... . ~ /(.t,A-~¡";:; /~~ :/.;/;j./ t~,.t,.;Zdlf ;',")/ --/'< '-.D' S(;.,,~¡; -Jim-IZ-:--C<i'1-1cndcr TJTLE - 1 st. Dr1g..--..Suµt.._.. ...... '"-- DAn: ~/SJIL4_.__.. ..........~ ;--~ ...~----_._- ..~---~ ." ... "'(S~e Instructions and Spaces for Additional Date on Reverse Side) . - General: This form is designed for submilling a comle all types of lan:.!s and leases in Alaska. Item: '16: Indica Ie which elevation is used as reference (wherc not o:herwis~ shown) for deplh measure· ments givcn in ether Spijces on this form and in any. alla::hl11cnl,s. and correct wellcompJetion. r£'pC"rt ê!r.d log On Items 20, and 22:: If this well is completed for sepðrJfc prcd~cti0n from more than one interval zone (multiple completion), so stale In item 20, and in irc", '22 show the prc:!ucir1!J intErval; or intervals, top(s), bottom(s) and name (s) (if any) for only the intervdl rcporled in ¡tcm 30. Submit 'J sepJrate report (pilQe) on this form, adequately identified, for each additional inle,vill to be seperalely produced, show- ing the additional data pertinen.l to such interval. Item26: "Sacks Cement": Allached supplemental records for this well shoul:) show the details of any mul· tiple stage cementing and the location of the cemen ting tool. /tern 28: Submit a separate completion report on this form for each interv(J1 to be separately producw. (See instruction for items 20 and 22 above). J~. SV:'l:'IAIlY tH' t'OIIMATIU~ Tl:STS INVl.VI)';(: INTEIIVAL Tf.STEn. 'lIf:SSI!III:: DATA A."'"D REC'OVF.IIIF.$ OF OIL GAS. WATCH AND MUO 1:7 §8 ffiñJ .~ See Attached ...: (,) o ». :..( '- ~? (I -r: CFiJ=U =..:.J :t- ~ Î'I ::;;0 :>;- t':: ~') , ~11 :; 1-'" » .~ {( . ~ u=ïrJ ~--_._j ,. ~- 6 (.) -; ..... ~'1 JR. ('01lF. DATA. Al"rAC11 lintEr DE.<;CIÜPITION" OF LITHOLOGY. ponO!;ITY. FIIAC'TUIIF.s. APPARENT DIPS AND IJl:TEL'1'EI> SHOWS Ot" OIL, GAS Olt WA1-¡;;It. No Cores 35 liEOLOGIC" 1\1 ARKERS . - " ... . e· - NAME I ~IE^~ nf:I'TI~ Inll'!: \'1:1\T OD','\ Sterling 5340' 5645' Beluga 6263' 8488' Tyonek 10,989' 11,225 [ "G" Sand· 12,545' 14,785' Hemlock 14,945' 15,520' Straight IIole e -- ,.' e- - COI JOE UN I T {fI · 1)ST III-IJ/22/73: . Mixed and clisplaccd dril1:iJ1g mud \4 73# cu. ft. 3% KCL fluid. Go-Interna- tional perforated from 15,405' to 15,435' 'w/ 4" on ]);"11... X.XIII Casing GlU1 4 1/2" IJPP. RIll H/ 7" IJm,'co Testing Toolan dry 3 1/2" and 5" Dr hi 9600 I diesel cushion. Set packer at 15,287' \4 tail at 15,.305'. Opened tool "r/ 5/8" btm. choke and 1/2" top choke against _9.600' (3500 psí) diesel cushion at 12: 00 Noon. No blow on opening of tool. 12: 05 pm, 1mcl \\'oak blow and fluid started fal1ing in annulus. Closed tool-fluit1 continued' to fall indicating that circ. shear sub failed. Reversed out coltmm or . diesel and circ. DP wI 73# cu. ft. 3% KCL fluid. Pooh. Tool \\'<15 plugged wI ont. and pipe scale. Shear sub had failed. Te?t-D9J: .good. No formation fluid entered DP .- 72 hr. 48 hr. 48 hr. n hr. outside outside inside ins ide 1H 8000 7990 8010 8017 IF 3352 3312 3360 3352 · FF 7397 6993 7333 7413 FH 7882 7876 7875 7903 T~nperature - 2200 Æ rH~[E tl ~ ~ [0 ,f.} ~\' 1 r::. 1,~ 7;! ~ pST #2-11/25/73: BTD 15,593'Ld. Collar. r '{\ ,"',",:";,, . . '.: '-.!' ,.- .... -..,._...,J'J: ......, \.....:~ l.!·:~ C;\':.J ;. \.,',-qr '¡;) :" f"';~' .. .....' ~'-.. í..r~.....]_ Go-International TIB H/ 411 OD D:-"[. XXIII Casing Gun and perforated wi 4 1/2" HPF from 15,405' to 15,435'-30' 1'1/ 120 holes and 15,372' to 15,402'-30' wI 120 ho¡es. RIB ì\,/ 7" IJO\vco Testing Toolan dry 3 1/2" and 5" Dr wI 9615' diesel cushion. Set packer at 15,274'. Tail at 15,295'. Opened tool at 12 :40 pm \4 5/8" btm. choke and 1/2" tap choke. Light blow at 12 :45 pm. StroI1ß .blow at 1:00 pm. Initial shut in at 1:25 pm. for 1 1/2 hrs.-opened 1:091 for final flow at 2: 55 pm. Fluid level at 8: 00 pm at 2iWO' -(1 rise of 2859=50.7 bbls entry rate of 8.7 bbls/hr. Opened time - 5 hr5. SO min. Continued final flow to 12:30 am, 11/26/73 shut-in fluid level 1073' below surface 1'1/ total entry of 80 bbls. fOl1nation fluid. Total tjmc tool open-10 hrs. 20 min @ a rate. of 7.7 bhls/hr. Reversed out diesel cushion and 449, cu, ft. formation water. Fi.nal shut-in of 9 h1'5. 30 min. Pulled packer loose at 10:00 am. 11/26/73. Test fluid 73ff cu. ftl 3~o KCL \4 Nac1 above 2,25,000 PPM. · .. . " . . " \ '. "'-.. e DST 1/2-11/25/73: (cant..) {'" ( I I 48 hrs. outside 72 hrs. inside 12 hrs. , outside 48 hrs. insiòe 111 1Fl FF1 ISI IF2 FF2 L_l~1 7732 3724 3951 7934 3990 5550 7932 7761 7737 3716 3956 7941 3988 4365CTE* CTE 7743 3699 3933 . 7941 3960 5530 7936 7779 7743 3733 3970 7946 4002 5554 7939 7797 / , f i Temperature - 222° IF 35 miD-...)..lS11.hr. 30 min., FF 9 hrs~ 30 min., fS1 9 hrs. 30 min'. *12 ]n:5., chart time c)...1)Üed approximately 95 min. after tool set. ~rel1mlJ1ar)' an::1lysis oLf~u:ißs.: Na.::l-myLL.. S~J1e #1 39,720 Sænple #5 Sample # 10,254 Sample 116 Sarnp1e #3 10,490 Test Tool Sarrvle #4 10,514 Test Tool 172,076 270,360 16,194 14,575 ÆŒ©~HjŒ[ , . A' 1-7 1 .!;~ :\1 ~ 8 .~ I, ETD 15,250' Bridge plug. C'!\¡'::SJS r: ::, ¡: () lL i\l'!D GI~ t'..!'.!í:t~C)r~l.GE DST #3 & 114-10/27/73 thru 10/28/73: \ 'I" .' '. " 73#. cu. ft. 3% KCL Nacl 250,000 ppm. IF 30 min., ISI 1 hr., FF 11 hrs. 18 min., FS1 1 hr. 42 min. Go-Intcmanational ran 4" OD n~lL XXIII cSP'. iùrì~-41/2"'HPF and perforated..the Upper lIemlock from 14,980' to 14,9ŠO'-30', 120 holes and."G1'. Zone from 14,784' to 14,754 '-30', 120 holes. Ran 7" Howco Tester on dry 3 1/2" & 5" DP w/ 4100' diesel cushion (1500 psi). Set tester at 14,886' w/ tail .at 14,904'. Btm. choke 1/2", top choke 1/4". .Opened tool at 1:20 pm above the Upper I-:emlock perforations at 14,980' to 14,950'. Fluid fell in annulus. Reset test tool at 14,880' wi the tail at 14,898'. Reopened tester. Fluid fell in aJmulus. Closed tool anù pulled up to 14,668'. Set tester w/ tail at 14 þ 696' for DST 1/4 above the "G" Zone to test the Upper Hemlock and fiG" Zone perforations from 14,980' to 14,950' and frOD 14,784' to 14.754'. Opened tool at 2: 15 pm for initial flow-30 min. Total Hydro-Hd at opening of tool 2000 psL \\'~ak blow after 4 mins. ISI at 2:45 pm for 1 hr. 5 min. Reopened tool for FF at 3:50 pm w/ good hlo", on buhble hose. Diesel cushion to surface at 8:35 pm. Tool opcned6 hrs. 20 min. Entry rate avcrage-25 bbls/hr. ",hen diesel surfaced. Rate declined to 3 boIs/hr. by 2:30 am, 10/28/73. Floh' pressure at surface 10 psi and declining. Closed tool for final pressure at 3:00 ron. Surface pressure built to 400 psi immediately. Opened reverse ports. !lad 1000 psi differential indicating fluid entry. Had a .436 gradient. Heverseù out 12 cu. ft. diesel, 100 cu. ft. mud and 1100 cu. ft. fonnatjon \,'ater=(178 bb1s 'vater) Final shut- in 1 hr. 42 mins. Pooh w/ tester at 4: 42 pm. I~m !lowco I~ZSV retainer set at 14,606' and squeezed 76 sx. Class "G" ont. ,,1/ 1% CFR2 below retainer and 24 SX. onto on top. Estimated top of cement at 14,367'. . ....,¡. . . , e' e.' · DST #3 G #4-10/27/73 thru 10/28/73~ (cant. . .) 48 hrs. 12 hr5. 48 hrs. 72 hrs. outside outside inside inside HI 7457 7463 7471 7463 IFI 2718 2708 2762 2763 ! FFt 3082 3030 3108 3090 I SIPI 7056 7044 . . 7049 7051 i . i l IF2 3254 3232 3314 3284 i FF2 6531 4420* 4328:';* 6533 I I SI1'2 7044 CIE 7044 7044 , a./ FII 7455 CTE 7468 7463 i *CT£ Chart time expired. ** End of 7S min. c1ocJ,-apparently stopped. <, Temperature - 2160 Preliminary ar:3.1ysis of fluids: Sample #l 58,735 Sample It 2 14,746 Sample #3 14,467 N.acl-mg/l. Sample 114 Sample tiS S3111plc fl6 13,199 12,568 12,260 \n re (( ~ n ~ Œ D\'\ o l; ~:J .::. U .lhJ . t. .. ..... ~ , ~ '1 J. C' I,",'''. \. 1\ I n ,oW· ¡ .' . - _.. .-..., /\.1'0 G;'{-:; n" !.:-:-!'=-~ ~.~ '.,J ,.. \......! - -.. ~ - . . ,- . . -, . rH} .\ r.: ¡: t. :"\: t. ..'; : '--., 1\ r. .... -, ,- · Dsr it5~10/31/73: E'l1) 11,062' Bridge Plug.· 7311 cu. ft. 3% KCL, ~acl 250,000 ppm. Co-International ran 4" OD D~IL XXIII Csg. Gun 4 1/2" }¡PF and perforated "D-3" Sand from 11,020' to 10,990.'-30', 120 J-JPF. Ran IIO\"co 9 5/8" rester on dry 5" DP 'vi 4100' diesel cushion= (1500 psi Hydro-lid.) Set Tester at 10,890' wi tail at 10,911'. Opcneded tested at 2:00 for 30 min. IFI". Had medium bIoh' on bubble hose.",/ - 1/2" btm choke-1/4" surface. Closed for ISIP at 2: 30 élm for 1 hr. Reopened tester at 3:30 am for FFP. IJad medium hloh' on bubble hose. . Checked fluid level at 8:0p am. Fluid at 3000' belmv surface. Showed 67 bbls of f0111\ation fluid entry in 5 hr5. Average entry rate of 13.4 bblslhr. Continued final flow test to 10: 00 am. Total fluid entry 78 bbls. Average rate of entry 11.1 bbls/hr. ovcr 7 hr. test = 6 hr5. FSI. Reversed out diesel, 7 bbls ratholc fluid and 71 bbls of gas and fonr.ation ,,'atcr (5000 PPIT! cl). Released test tool at 3:00 pm and Pooh. . .... J. Temperature - 1750 12 hrs. 48 hrs. 24 hrs. 72 hI's. outside outside inside inside --- III 5535 5534 5556 5557 IF! 1801 1789 1838 1816 FFI 1965 1974 1973 1981 · SIPI 4786 4783 4794 4799 IF2 2007 2017 1978 2041 FF2 3339 3432 3453 3452 SIP2 CfE* 4780 4794 4799 Fll erE 5534 5556 5557 *CTE ChaTt t j me expired. . ." e' - 'DST //5-10/31/73: ETD 11,0621 Bri<lec plug. (cant...) · Preliminary analysis of fluids: Nacl-mg/l . Sample #1 Sample 112 Sample #3 73,298 15,550 10,705 Test'Tool Test Tool 7,704 8,856 DST //6-11/1/73: E1D 10,895' Onto Plug 73/f cu. ft. 3% KCL, Nacl 250,000 ppm. Go-International perforated. ]<(111 7" aD spreader strip Csp,. GW1-2 5/8" HPF, 80 gram Saber Jet charges and perforated from 8465' to 8450'-15', 30 holes, and from 8182' to 8192'-10', 20 holes Lmÿcr Beluga. Hem 9 5/8" IIm·,'co tester and set at 8065' w/ tail at 8084'. Opened tool at 5: 00 pm. Initial flow 30 mins. ¡¡ad fair to good blow on bubble hose. Btrn. choke 1/2", surface cho].;:c 1/4" and 470 psi diesel cushion. Initial shut-in at 5:30 pm for 1 hr. Reopened tool at 6:30 pm for final flow. Had strong blow on bubble hose. Closed tool at 12:52 am 11/2/73. Reversed out 22 bbls diesel cushion, 28 bbls of rathole fluid. Little or no entry of formation fluid. Average rate of entry 3.7 bbls/hr. No show of oil or gas,. .. ". .... 12 hrs. 48 hr5. 24 hr5. 72 hrs. · outside outside inside inside 11-1 4109 4126 4132 4118 \ IFI 714 645 705 684 FFI 699 690 713 696 SIPI 2464 2464 2480 2490 ~ . IF2 820 788 839 771 j FF2 1119 1118 1140 1126 ¡ , SIP2 1958 CTE* 2489 2510 2498 , FH CTE*. 4099 4108 4096 ................--. ' *CTE Chart time Expired. Tenperature - 1540 Preliminary analysis of fluid: ~\acl-mg/l. . Sample fl1 Sample il2 Samp 1 e 113 272,422 256,424 246,506 Sample 114 Sample /15 Test Tool Test Tool 232,462 199,243 181,025 174,541 ~œ~~Jti~~ , ~", 1 .U ;\1 .:. f) !~/t.. ~r/::i:::! .:,F C'IL .¡-\;'::) G/\~ t),:;::t!or~;.\GE · e' e e DST #7-11/2/73: ElD 8,045' Cmt. Plug. 73# cu. ft. 3% KCL, Nacl 250,000 ppm. Go International perforated \v/ 7" OD spreader strip Csg. Gun "'/ 80 gr:1JJI Saber Jet charges, 2 5/8" ¡·O)F. The Upper Beluga from 68S5' to 6870'-15', 30 holes and from 6913' to 6898'-15', 30 }lolcs. Ran 9 5/8" Joweo Tester on dry 5" DI' wi 200 psi diesel eushj on. Set at 6776' wi the tail at 6792'. Opened tool for 1/2 hI's. IF at 5:45 pm. !lad Hlcdiwn blm"r on bubble hose wi htm, choke 1/2" éUld top 1/4". Initial SI for 1 111'. at 6:15 pm. Opened tool at 7:15 pm for finéìl flow-had medium hlo,,", on bubble hose. Decreased almost to zero. Closed tool far final SI at 9:30 pm. Reversed out diesel and 11 bbls rathole· flui(l :md 91 bbls formation fluid. No oil shmv. Heeovered muddy gas eut salt water. Released tool at 12:00 pm. Temperature - 1070 48 h1'. 12 hr. 72 hr. 24 hr. outside outside inside insidc I I IH 3439 3444 3449 3445 \ IFI 565 1477 Q 584 568 I ¡ FF! 1486 1483 1496 1522 I SIPI 2857 2861 2875 2868 i IF2 1655 1649 1685 1667 , FF2 2854 2870 2861 ( SIP2 2850 eí HI 2864 2870 2883 2873 3356 3377 3379 3364 ~_._. Q Questionab1é Rathole 120,183 ~reliminar)' anal}:'sis of.i}uids: S(lmple #1 7545 Sample #2 4558 SÐmplè #3 3941 S~p1e #4 12,621 N3cl-mp,/1. .Sample 115 Sample #6 SéUlìple il7 Sample It 8 'Test Tool Test Tool 3742 3089 2856 2742 10,404 10,283 IF 30 min., IS1 1 hr. FF2hrs. 15 min., FSI 2 hrs., 30 min. After rclct1sing tool, fluid in annulus fell. Pooh. Squeezed and retested same zone. Squeezed w/ 485 SX, ccmcnt below and 15 sx. above. e ~ [ @ ~ Ù íj ~ --- I· l 'il . ", \ -., .) .s 1: ill) r ~ 1 .", .I~r\' ~ h ,:::'/~~ ' D""'7f"'" -'f" rì'l 't ':-\ . ,.....; JI·~ '-" . .I...,!.... I~..::,...I G¡'~': Þ~;,\r.:~ic!r~.1·.G !: . , :' e e DST II 8 -11 / 4 /73 : ETD ü9S0' Cmt. Plug. . 6811 cu. ft. 3~ KCL, Nacl 250,000 ppm. Co- Interníltional reperforatcd the Upper Beluga from 6885' to 6870' amI from 6913' to 6898' \.!/ 4" OD J);>'IL XXIII Csg. Gun,. 4 1/2" IIPF, 30 1, 120 holes. Ran 9 5/8" nOh'CO Tester on dry 5" DP \\./ 374 psi diesel cushion and set tool at 6810 H/ tail at 6824'. Opened tester at 6:45 am for 1/2 hr. lEI'. S1 at 7:15 am for ISIP. neopened tester at 9:15 am for FSIP. IIad 88 bbls of fluid entry at 58.7 bb15/11r. Reversed out c1iesel cushion slightly gas cut SéJ.1t \\'ater \\./ somc séJ.nd. Rcleased tool at 12: IS pm. IF 30 min., ISI 1 hr., FF 1 111'., F5I 3 hr5. Temperature - 1050 . IH 3225 IF 929 FFI 2179 FSI 2870 IE2 2278 FF2 2793 FS2 2883 Hi 3225 Preliminary analysis of fluids: Samp 1 e It 1 Sample 112 Sample 113 Sample If 4 Sample Ii 5 3221 923 2179 2868 2271 2792 2876 3221 Nélcl-m~/l. ,!- 1~l,016 130,123 111,184 91,970 95,196 72 11r5. 24 hr5. inside inside 3246 3242 972 967 2194 2201 2883 2884 2309 2302 2802 2804 2893 2893 3246 3242 Sample 116 95,196 Sa¡ rqll e 117 106,577 Test Tool 90,179 Test Tool 88,187 . 12 hr5. outside 48 hr5. outside DST 119-11/4/73: ETD 6765' Cmt..Plug. 68# cu. ft. 3% KCL. Go-International perforated the Sterling Zone from 5357' to. 5347' and from 5620' to 5610'. Total of 20' w/ 4" OD D~rL XXIII Csg. Gun, 4 1/2" lIrF-80 holes. Ran 9 5/8" IJO\vco Tester on dry 5" Dr wi 374 psi diesel cushion and set at 5272' \d the tail at 5290'. Opened tester at 9:45 pEl for 1/2 hr. initial flow pressure. SI at 10:15 pm for initial 51 pressure for 1 hr. Reopened tester at 11:15 pm for final flow. TItm. choke 1/2" élnd top 1/4" bubble hose. 1\'eak blO\" on bubble hose. 51 at 11:25 pm for final S1 pressure. Reversed out diesel and rathole fluid 68 bbls. Est. 42 bbls fOl1natior~lUrjJlþ rr 1 t\,~ rë' ~7:'\ Released tester at 1: 20 (lll1, 11/5/73. Pooh. R\ l\: ~, ri: u IJ ~ 1[: I If 30 min., ISI 1 hr., FF 25 min., FS1 1 hr. L!J . I " f 1 1 r- 'a ~ ..,~, , e L\ \ ,_ r'\ .... to: Temperature - 91Q [:~\./::r~ t! .:' r c';~ /.!:) Gi\S /. ~,!:-L:r \r.I '. r- r: 48 hrs. 12 11rs. 24 hrs. r-.. .' ...... "72 "hr5. outside outside inside inside e --- Ilf 2504 2503 2509 2516 , IFI 1591 1596 1658 1681 PH 1998 1996 2003 2024 I i FSI 2166 2164 2171 2024 , . e . DST #9-11/4/73: ['m 6765' Cmt. Plug. ( con t . . .) ..../~-_., 48 hrs. outside IF2 2030 FF2 2135 FS2 2171 L-.. FH 2385 Preliminary analysis of fluids: Sample Dl 84,467 Sample #2 67,844 Sample #3 12,765 Sample #4 157,448. Ran 9 5/8" EZSV and set at 5247'. . . 12 hrs. outsÜle 2035 2133 2170 2411 Nacl-mp,/l. e - 24 hrs. inside 72 hrs. "ì insiùé / 2041 2140 2174 2415 2183 / 2150 í 2189 I ~40?'__j , . ... . .. .". . ,,, ".... [5) i~ íí; rc J ¡IIi [,' ~'.\ [ffi tl \b ~ lJ L£ f L! i ",' '.' f ~ !"i;¡ ID 1'.1\ "'~Jr'l , .-.. ~. {,~ '."" . .'- r:'1 .. h) C . ".:" .,--'1_ l.! ~~ . ':~~ A~\....: '(.If) .','" '-: .. '"r.·...)~ HALLIBURTON SERVICES DUNCAN,OKL-AHOMA ~ ·-mr..... w-~~:':::::":'::::::"::'':'.::'_'!=:l'!.__ ::.~ 1111111111111111111111111~111~~lllllllllllllllmlllllllI ROCKALL RE:00007161 ------._-----~ C--Ý{<0' ¿j:.I2,' ;' " I Format;o.'ir Testing Sérv~'e Report - ----' . .- ! I ! I _ -S=-J'/ I . 1 I ~ FLUID Ft. Ft. Vir- IDII) fi~ C . - -Ir- S ~o ( 'On .Q .= t , ~~ ? r-¡. ~ l- I) Z 0 CO 3 I /I IJ,) 2: . ..... ~ . T A 11-4-73 Ticket 251636 -- Date .~ Number P.S.I.G. at Surface Kind Halliburtol . of Job HOOK WALL Bistrict N CRO RAGE Tester MR. MANN Witness MR. JOHNSON SAMPLE Sampler Pressure Recovery: Cu. Ft. Gas cc. Oil cc. Water ~_ ~_-rr cc. Mud Tot. Liquid cc. Gravity Gas/Oil Ratio .-: ,"¡ Re<:overy Water ° API @. OF. Drilling Contractor BRINKERHOFF DRILLlliG CO., INC. DR S EQUIPMENT & HOLE DATA cu. ftJbbl. Formation Tested S ter 1 ing CHLORIDE Elevation 243. 6 CONTENT I Net Productive Interval 20 ppm All Depths Measured From Kelly Bushing ppm Total Depth 6765 ' ppm Main Hole/Casing Size 9 5/8" ppm Drill Collar length ppm Drill Pipe Length Packer OepthCs) cp Depth Tester Valve Depth Back Surface Bottom Ft. Pres. Valve Choke 5/16 -1/2" Choke RESISTIVITY _ @ _oF. Recovery Mud _ @ _ OF. Recovery Mud Filtrate _ @ _ of. Mud Pit Sample _ @ _ of. Mud Pit Sample Filtrote _ @ _ of. Mud Weight 661F/cu. ft. vis 5225' 5272' 5248' TYPE AMOUNT Cushion .1002.3' Diese 1 Recovered Recovered Recovered 1002 Feet of diesel cushion 1434' Feet of rat hole fluid 2396' Feet of formation fluid slightly gas-cut. Recovered Feet of Recovered . Feet of Remarks SEE PRODUCTION TEST DATA SHEET . Initial Hydrostatic Initial 'E] Flow ü: ¡ Final '1 < - 0. Closed in "0"0 Initial c 0 Flow §'~ Final VIa. Closed in Initial ~] Flow '__.~~~ Final Closed in Final Hydrostatic 2498 TEMPERATURE Est. of. 5290' ActuaC} 1 ° F. rORM III-PRINTED IN U.S...... Gauge No. 3647 Gauge No. 3646 Gauge No. 3637 Depth: 5259 Ft. Depth: 5263 Ft.. Depth: 5284 Ft. 48 Hour Clack 12Hour Clock 24Hour Clock Blanked Off No Blanked Off No Blanked Off Yes Pressures Pressures Pressures Field Office Field Office Field Office 2498 2504 2505 2503 2507 2509 1591 1591 1614 1596 1663 1658 1974 1998 1981 1996 1990 2003 2149 2166 2156 2164 2162 2171 1 974 2030 2016 2035 2024 2041 2131 2135 2138 2133 2145 7140 2166 2171 2173 2170 ?16? ?174 2385 2415 2470 2411 2472 FORMATION TEST DATA Ft. 471ft 1.0. - 1.0. 4.276" :Et-\ ~ z p Ft. Ft. 1/2" -I II) ~.~ p >:!! ~ gå: p 'TI ~ a H 3 t'" ~ Ö ~ C') ~ .~ < Q <" II) \. -I ! III !!;. r III a. ?: ( III - :¿ ( 2.\. Q c ~ '< TIME x t%j ~ H Tool 11-4-7ÆM. txI o Opened 21: 45 P.M. ~ Opened 11-5-73M. C G') Bypass 01: 20 P.M. ::è Reported Computed C r- C ~ : S ~ o : :¡: ~ ¡¡¡ ~ " n ( 3 ~ 'tJ g ~ '< . z t o ¡. 3 ~ III ( ~ ~ Minutes Minutes ~ ~ 30 29 III 60 n 0_ --.. > 10 '4 ~ (/) 11'5 10? ~ LITTL.I!:'S 83874 1M Bin ~ / FLUID SAMPLE Sampler Pressure Recovery: Cu. Ft. Gas cc. Ojl cc. Water cc. Mud Tot. Liquid cc. Recovery Mud Recovery Mud Filtrate Mud Pit Sample Mud Pit Sample Filtrate _ @ _ of. ~=---:r Gravity Gas/Oil Ratio Recovery Water _ @ _oF. _@_oF. _@_oF. _@_oF. RESISTIVITY Mud Weight TYPE AMOUNT Cushion Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of ._-=.~ Remarks TEMPERATURE Est. of. Actual of. 'nitial Hydrostatic Initial ~~ Flow Final u..QI a. Closed in 'U1J Initial c 0 Flow ~.~ Final VIa. Closed in ,1J Initial :.Q Flow ~~ Æ Final Closed in Finol Hydrostatic rOH'" IBI-PHINTED IN U.S.A. Gauge No. Depth: Blanked Off Field 2513 1670 2018 2183 2055 2147 2183 ?471 Pressures VIr- /1)/1) !''g '- ~r- :EO 'Co . 0 I~ ~o :]:3 ~ r ( ~ ~ 00 ~ t III I Z t W D Z 3 I III "'""'" ;: Ft. Ft. Ft. ~ ~ ~ Ft. Z !' Ft. \ T A 11-4-73 .~/ Ticket 251636 Date Number P.S.I.G. at Surface Kind Halliburton of Job HOOK WALL District ANCHORAGE Tester MR. MANN Witness MR. JOHNSON ° API @ Drill ing Contractor BRINKERHOFF DRILLING COMPANY, INC. OF. E QUI P MEN T & HaL E D A T A cu. ft ./bbl. CHLORIDE CONTENT vis Formation Tested Elevation Net Productive Interval All Depths Measured From Total Depth Main Hole/Casing Size Drill Collar Length Drill Pipe length Packer DepthCs) cp Depth Tester Valve I.D. I.D. ppm ppm ppm ppm ppm Depth Back Ft. Pres. Valve Surface Choke Bottom Choke 3636 Gauge No. Gauge No. 5289 Ft. Depth: Ft. Depth: Ft. 7 2 :: Jur Clock Haur Clock Hour Clock Yes Blanked Off Blanked Off ~ t:tj TIME ~ H A.M. ~ P.M. ë5 A.M. c::: P.M. §à Computed Pressures Pressures Office Tool Opened Opened Bypass Reported Office 2516 1681 2024 2024 2183 2150 2189 Field Office Field Minutes Minutes ?407 FORMATION TEST DATA LITTLE'S n97.4 5101 S/73 >:!! ~ àå: p ~ ~ o H ~. b ~ ~ ~ t-3 < o <' ID ~ 0+ ~\Q "- ... ... ~ I ~ C ~ ... 0. C ã: "- (þ < ~ n o c ~ '< § § ~ ~ Q C l- t r- ( 2 c :'D ~ 0;:; ~ :x ~ ~ ~... n o C .g. 1':1 o ~ & ~ t 3 ~ ~ 1':1 C § ~ > ~ en ~. ~347-.5J.5/' Casing perfs.5610- 5620' Gas gravity Spec. gravity l~_,Jm choke Oil gravity Chloride~ INDICATE TYPE AND SIZE OF GAS MEASURING DEVICE USED Date Time a.m. p.m. Choke Size 21:45 22:15 23:15 23 : 25 01:20 .-~~ .-=--:_~.,~,,/ FORM In-PRINTED IN U.S.A. Surface Pressure psi Gas Rote MCF 1/2" Liquid Rate BPD Surf. temp_ /5 GOR ppm Res. OF Ticket No. 251636 ~ OF Remarks 0genedmol with a weak blow on bubble t Closed tool on 1/4" bubble hose Closed tool Opened tool with a weak blow on bubble Pulled loose PRODUCTION TEST DATA LITTLE'S 93915 ,'" 017 . " . . '-' ~. - '. .. . -. ..' ..'- . . _h~" . ."" Gauge No. 3647 Depth 5259' Clock No. 9300 48 hour Ticket 251636 No. First I First Second Second Third Third Flow Period Closed In Pressure Flow Period Closed In Pressure Flow Period Closed In Pressure Time Defl.1 PSIG I Time Defl. Log t + () PSIG Time Defl. PSIG Time Defl. Log t + () PSIG Time Deft. PSIG Time Defl. Log t + e P~IG .000" Temp. .000" Temp. .000" Temp. .000" Temp. .000" Temp. .000" Temp. Corr. . () Corr. Corr. () Corr. Corr. f) Corr. o . 000 I 1591 1.000 1998 .000 2030 .000 2135 1 .0066 1685* .0067 2143 .0067 2047 .0069 2161*,0(' 2 . 0149 1764 .0134 2150 .0134 2068 .0189 2164 3 . 0232 1865 .0201 2156 .0201 2093 .0309 2166 4 .0315 19Ì1 .0268 2157 .0268 2110 .0429 2168 5 .0398 1 958 .0335 2159 .0335 2124 .0549 2170 -.- ( 6 . 0480 1998 .0402 2161 .0400 2135 .0669 2171 7 .0469 2163 .0789 2171 8 .0536 2164 .0909 2171 9 .0603 2166 .1029 2171 10 .0670 2166 .1149 2171 1 1 .0737 2166 .1269 2171 12 .0804 2166 . 1389 2171 13 .0871 2166 .1509 2171 14 .0938 2166 .1629 2171 15 .1010 2166 .1750 2171 Gouge No. 3646 Depth 5263' Clock No. 4L85 hour 12 o .000 1596 .000 1996 .000 2035 .000 2133 1 .0266 1685* .0263 2142 .0262 2040 .0267 2159** 2 .0599 1760 .0526 2150 .0524 2061 .0735 216¡- 3 .0932 1861 .0789 2154 .0786 2086 . 1203 2164 4 . 1265 1909 . 1052 2157 .1048' 2105 .1671 2166 ( 5 .1598 1953 .1315 2159 . 1310 2121 . 2139 2168 6 . '930 1996 .1578 2161 .1570 2133 .2607 2170 7 . 1841 2163 .3075 2170 8 ~?104 2164 .3543 2170 9 .?367 2164 .4011 2170 10 .?630 2164 .4479 2170 1 1 ,?R91 2164 .4947 2170 12 , 31 1)6 2164 .5415 2170 13 ,3419 2164 .5883 2170 14 "~h8? 2164 .6351 2170 151 .~950 2164 .6820 2170 Reading Interval 5 ·4 4 7 Minutes REMARKS: * F;t"~'t ;ntprv~l P ql1;:¡ 1 'to 4 rn;nl1'tp.~ *'1'\-4 minute~. PRINTED IN u.s..... CDL'~1 ^ J at:) L'C CJ J n r::' nA'ï"'A LITTLE'S ......- ~. .." .." .-^. - ..... .....~. . .-..... - . --.,.; . - ." . .. \ ( Gauge No. 3637 Depth 5284' Clock No. 8739 24 hour Ticket 251636 No. First First Second Second Third Third Flow Period Closed In Pressure Flow Period Closed In Pressure Flow Period Closed In Pressure I Time Deft. PSIG I Time Deft. Log t + 0 PSIG Time Defl. PSIG Time Def!. Log t + 0 PSIG Time Defl. PSIG Time Def!. Log t + () P:fG I .000" Temp. .000" Temp. .000" Temp. .000" Temp. .000" Temp. .000" Temp. Corr. 0 Corr. Corr. () Corr. Corr. fI Corr. 0 .000 1658 .000 2003 .000 2041 .000 2140 1 .0135 1720* .0133 2150 .0133 2048 .0137 2164** 2 .0304 1789 .0266 2157 .0266 2072 .0377 2167- 3 .0473 1881 .0399 2160 .0399 2093 . 0617 2169 4 .0642 1926 .0532 2162 .0532 2112 .0857 2171 5 .0811 1967 .0665 2165 .0665 2128 .1097 2172 6 .0980 2003 .0798 2167 .0800 2140 .1337 2174 7 .0931 2169 .1577 2174 8 .1064 2171 . 1817 2174 9 · 1197 2171 .2057 2174 10 .1330 2171 .2297 2174 1 1 .1463 2171 .2537 -ªZL- 12 · 1596 2171 .2777 2174 13 · 1729 2171 .3017 2174 14 · 1 862 2171 .3257 2174 15 1qqO ?171 .3'500 ?174 Gouge No. 3636 Depth 5289' Clock No. 10394 hour 72 0 .000 1681 .000 2024 .000 2059 .000 2150 1 .0044 1 7 42~\- · 0043 . 2159 .0042 2060 .0046 2178*:" 2 .0099 1857 .0086 2167 .0084 2077 .0126 2183 --- 3 .0154 1907 .0129 2172 .0126 ,2101 .Ge06 2185 4 .0209 1949 .0172 2176 .0168 2115 .0286 2187 ( 5 .0264 1991 .0215 2178 .0210 2136 .0366 2189 6 .0320 2024 .0258 2179 .0250 2150 .0446 2189 7 .0301 2181 .0526 2189 8 .0344 2183 .0606 2189 9 .0387 2183 .0686 2189 10 .0430 2183 .0766 2189 1 1 .0473 2183 .0846 2189 12 .0516 2183 .0926 2189 13 .0559 2183 .1006 2189 14 .0602 2183 .1086 2189 151 .06'50 ?183 .1170 2189 Reading Interval 5 4 4 7 Minutes REMARKS: * Fi,..~'" ; ntp.rv~l p. qn::! 1 tn 4.mint1te~ *"l(-4 minutes. PRINTED IN U.S.A.. ,-. r-'\ r-" "..... I \ I .- .-,. r- ,.... ,..... . r-. ..- - .. --- .. -r~_~/ I:, . ! ;~tJl:} .Ir",~; -~ it , ~ ~ r 4 i3 8 íR r -- Drill Pipe or Tubing .... . . . . . . . . . Reversing Sub . . . . . . . . . . . . . . . . . . . . . . Water Cushion Valve . . . . . . . . . . . . . . . . Drill Pipe ........................ Drill Collars ...................... Handling Sub & Choke Assembly ...... Dual CIP Valve ................... Dual CIP Sampler . . . . . . . . . . . . . . . . . . Hydro-Spring Tester ... . . . . . . . . . . . . . o - Multiple CIP Sampler . . . . . . . . . . . . . . . Extension Joint . . . . , .:f/: l' . . . . . . . . . . . AP Running Case . . . .1~~. . . . . . . . . . . . Hydraulic Jar .. . . . . , . . . .. ....... v VR Safety Joint ....,....,. Pressure Equalizing Crossover ......... Packer Assembly . . . . . . . . . . . . . . . . . . . Distributor. . . . . . . . . . . . . . . . . . . . . . . . ..:.. Packer Assembly . . . . . . . . . . . . . . . . . . . Flush Joint Anchor ................. Pressure Equalizing Tube .. ......... Blanked-Off B.T. Running Case ....... =>- "'""Q Drill Collars ...................... Anchor Pipe Safety Joint ............ v -, ~ Packer Assembly . . . . . . . . . . . . . . . . . . . I~~ I ; Distributor........................ ~ Packer Assembly . . . . . .. . . . . . . . . . . . , I I IJ Anchor Pipe Sofety Joint ............ I Side Wall Anchor.... . .. . . . ... . . ... CU Drill Collars .. )?~.:r: ~ ~ ~. . . . . . . . . . . . 61J. B -Rush ~oint-"'n<hor". .BT. /Þ.l . . . . . . . . . . ffi Blanked-Off B.T. Running Case .112 . . . . ....... o Total Depth. . . . ~~~~~ . .~~~~.. ..... -, L.."",,-~ O.D. I. D. -~""- 5.00" 4.276" 5.00" 5.00" 5.00" .87" .50" 1.00" 5.00" 5.00" 5.00" .87" 3.75" 3.75" 5.00" . 87" 5.00" 1.00" 8.10" 1.62" 2.88" 2.259" 3.88" 3.88" FOAM \l7-I"AINTEO IN U.I.A. EQUIPMENT DATA LENGTH 5225' 5.53' 8. 70' 8.37' 7.23' 4.05' 4.02' 3.85' 3.00' --'-- 4~59' 8.87' 4.05' 4.08' .98' ------ DEPTH 5248' 5259' 5263' 5272' 5284' 5289' ;llg " LITTLE'S 93971 ~M 8/73 ..~ ~ ,/ CHEMICAL . ~ clEOLOGICAl lABORAltn1ltS TELEPHONE (907) 279-4014 P. O. BOX 4.. 1 276 ANCHORAGE, ALASKA 99509 OF ALASKA, Ir~c. 2603 ARCTIC SLVD. ~ .,..".,. WATER ANALYSIS REPORT OPBRATOP WELL RO. .FIELD COUNTY ·STAT"r. UNION OIL COMPANY OF CALIF." DAT'F; Novef!1ber. 8. 1973 LAB RO. 1268-26 LOCATION PORMATION INTERVAT.. ALASKA ¡A~PLE FROIF DST #9. #1 Sterling UKARXS It CONCLUSIONS! Cloudy yellow water. floating scum. Clear yellow filt~ate. ~Iron (Fe). rng/l. . . . . .. 2.0 ijarium (Ba). m~/l. . . . . .. 1.7 Strontium (Sr) mg/l. . . . .~ . 2.1 Chromium (Cr) J mg/I. ". . . . . (0.1 Catbøl 5!J. .!5!! ~ons !5ll IDIÇ/l &Jðlttft' .. - - .. - 30855 1342.17 Sutfate .. .. - .. 325 6.76 ~.·Wft .. .. .. - .. 3088 79.05 CbJodc1. 50000 1410.00 - .. . .. ~,,~ .. 105 5,24 CarbOaato 135 4.50 J"a,..- 'ñbu .. .. .. .. ,. 1 0.08_ Bic&rboD&te 0 IroA * H"droJddc .. .. .. 90 5,29 Ttrizl Catloaa 1426.55 Totd AD10Gs .- .. 1 49.6 A 55 " Total cUNomd ..u4I, IJq/I 84599 Specific nêItat&co @ 6ð 0p.: HI.Cl ~aift1ct, me/l 84467 Oblc'vfd 0..106 oIuD-~ Ot n-..At pH .. - - .. .. 11..7 ~d .. .. .. - 0..10 oåm-~ WATER ANALYSIS PÂTTEIL.~ Scdø Sample abov. desc:nÞed KEQ per UDit 50 'j -. t II I, -, '/ I, ~ I . t I ' ~ : t I ',1 I J .1" Na ' I.; I ¡ " ¡ " :. J,; ( ';. '.' .) I ,}' I ' ¡ .' I,..~' .'" ... "1 !! ~ Ca T I~ I í : ¡, .- . " .' It! r d" t , , f ¡ t (. , .,' \ f . ,'. " I .'t' . I ",,! Mg ~':-f' l . .~.. _. \ " }' " . I . I Fe \ ! ¡"I" - ~ , I' Ifill' ' "I {J, it ',/. 'i- .. ' Cl ---;. . f I , II .1 :. ~ , II I I fJ"'~I' .1'1. , I Ca' " I ~ ....' Cl 500 f . ) HCQ3 - 50 , . " Nil '. , . ," HC03 , . ') y " I K£ ' ~ SO. i" .. SO. jJ H ",f" \', --,",, ,COs , 1 \..J": I ( -., j: ¿ ~¡ ! iLl. " 50 " I ':1 I ¡; ¡lr~ '. ¡'II Ii:' :: I' Fe :' . I : COa .._-=~ (He.... Ia aMft cnpM ~ Milo E..,- U) X.OTIC: ¥cIl=KII1Ir;raø per lite 11«1/1= -ßIIcnrn equfonleGta I*' Uter Iocüaai t:WItridQ. ~t=1tF n.... 4 HawtkonM n,",,~ &.. ;'1.I'\-ftIJl,-ta ..~ ~ CHEMICAL· ãr GEOLOGICAL lABORATtmlES ,OF ALASKA, INC. TELEPHONE (907) 2ï9-4014 P.O. BOX 4-1276 2603 ARCTIC BLVD. ANCHORAGE, ALASKA ~9509 ~',c..,.,? WATER ANALYSIS REP'ORT ALASKA DAT~ November 8, 1973 LOCAT~ON FORMATION' XNTBRV AT· SAMPLE FROJ.~ DST #9, LAD NO- 1268-27 OPERATOR WELL MO· FIELD COUNTY STAT~ UNION OIL COMPANY OF CALIF. #2 Sterlin~ UJlA.RES &t CONCLUSIONS: Cloudy 1i~ht brown water. Clear yellow fj 1 tratP.a .* Iron (Fe), mg/l. . .'. .. 1. 0 Barium (Ba), mg/l. . . . . . 1.1 Strontium (Sr). m~/l. . . .. .0.8 Chromium (Cr),: mg/l. . . . . (0.1 Cadøøa 51.! .!!!!l! AnIofis ï!!!JfJJ fI*l,/~ ~"'"' - - - . 27417 1062.13 Sulfate ?1:ï 4,47 PonI'::~--"1 3015 7'l.aJJL CbIoddo . . . 40000 11 ?fL 00 ClJdut'1 .. .. - 42 2.10 CarbÓaate 158 5.26 K!,~nluw . - - - - 1 0..08 BJcarboDl.tG 0 IroA - - . - * H~zldc 64 3.76 Totd Catlaaa - .. - - ] J 41 .. 49 TCå!l ~ .- -. 1141.49 .-....:.~. Total ~Ind IOU4I, mcI1 ,_~ -R- '7./- _ 67912 -.::J~ Specific ~te.cø @ 65°1'.: HaC1 ~1dft1ct, mrdl _ _ rp 1 "'. If.1 _ .- &V 0 t 4. - ~ Oblle:T.d - - .. .. Obcl':'''Y'S pH _ _ .. _ .. _ .. .. .. .. 11.3' r..c.c.:v'cted.. - - .. 0.137 0..13 oJam..lDItc::'a oåm-lIIIfiI&CD WATBR ANALYSIS PATTImN ScaIe Sample above descnòed !IRQ per t1øit Ca ~ -, , I r J f 't \ , ) ~ ~ Cl 500 'í 1'ì·Pi·1 1- "ll:'I1I ,!: Na . I ,{:.\ 11 JI.! . ~' \ . , . , ca;·¡.J; i; I , " II I,l \ fl.;:" I 1 .' f J Kg {¡ , I 1 I' f I. t I f ~ . I , '-1"1'11-11 ~ I I II ! Fe t ~ " t I, ~ I) " f \ 'f " ,~, " I t I '; . > I,' ,', i If I Ii I' ~""J'" ,~' :' tI 11.';1 L H}', :¡\ .11. I, ,I ( ì 11~1 I 11- ~ I 1 , 11 \ , ' ,. , ì I Cl Ne . \ \ ' ~ HC03 ,HC03 50 " ., :' iii .~ .~ · i J _ . 804 50 so.. ,( , 11 · '11 I ' . I I I ( ¡', . ; I·¡~ } ·Ll.d" II II~ COa 14 . -~='" , 1 ',' I - t-t I ,~ I . f 'ì: I ;¡ Lt' , < } _~A COs 50 Fe . . (tie ft1ut Ie ..... ".... ..... tI.. x..aa4 U) Jr.OTŒ: laE/l=JCßHcraIM pel' liter .-.11= MIDfcnaa equift1eatl I*' 11. IocSMua dIIoricIe ~t=~ þ...... ~ H""'" .\:\n¡~It"':~r¡ froM ::," .-i1I~ts Â:..~ - ',fA,. W.', S .' I.'~ --- CHEMICAL lx,:'GEOlOGICAl lABORATbrlli:S TELEPHONE (907) 2ï9-4014 P.O. BOX 4-1276 ANCHORAGE, ALASKA 99509 OF ALASKA, Ir~c. 2603 ARCTIC BLVD. ~-- WATER ANALYSIS REPORT OPERA-TaB UNION OIL COMPANY OF CAL{F. WELL HO~ Plt:LD COUNTY 8TAT~ Alaska DATf1. November 8. 1973 LAFZ NO. 1268-29 LOCATION FORM,Á TIOlrl INTBRV AT. SAIlPLE PRO~ DST #9 J #4 Sterling REMARKS I: CONCLUSIOn!: Cloudy water. Filtrate clear. *Iron (Fe)~ mg/1. . . . . . . 2.5 Barium (Ba). mg/l. . . . . . . 1.8 Strontium (Sr), mg/1. . . . . .2.1 Chromium (Cr), mg/1. . . . . .(0.1 Catloaa .!5lJ.. .!!5!! . AnfOZUl s;!J, IDICl/l sr.Mtm,. - . - - .. . 56364 2451.82 SallAta - .. .. .. 327 6.80 J'oIv. !tlftl 6892 17§..:.ii ChIorido - . .. - - - .. 93000 2622.60 CI1~ - 543 27.10 CarbOaate 97 3.23 M....-rw.'W4& .. .. .. - .. 1 0.08 BL:arboøa.ta 0 Iroa * Hydrazide - .. - - - 388 22.81 Totd Ca~ .. .. .. .. 2655..44 Totd A.n1o:w .- - 2655.44 Total &.olYed I01It1e, mall 157612 Specific nústtnce @ 65°9.: NeC! eq,uift1ct, lDll/l . .. .. .. 157448 OberYed .. .. - .. 0.062 olllD-~ Ob.Ir'Y~ pH .. .. .. .- .. 12.0 ,....kn,....~ . .. .. .. - 0.062 ...~ I Fe : . J . } . , II .. I.:. !¡.~ " , . f " . _f. . .~ ¡ t I} . I ~ltl", '.~. J' :.tf ..' " SO" ,é ! !., I r!-- . COs r J WATER ANALYSIS PATTERN Scats MEQ per Unit 0..·.0! III I u ! / I III ¡, '.. . Na ' ·1'.. ~l'lt H"- . . r t !:' I. ..' I· I . Ca I,~: 11 r 'I' f If- f ' \, f , ' ~ ( Kg I H , i I , 'i .¡ ì ' f . J I, . If Fe ",111) . , ¡. · 'Ij ¡' 't""!: I ¡i :llr'1lfJj l 1 i d, ·1 . ,'-I ¡ I " h -, 'if '.}' 'Hi... :1 . Sample above da.cnõed '. Ca' . ) '0/ II \ It' I 500 1.1 II . ll' i ~ ,., /I I \ , I', N. .. Cl ~ , Cl , I , J . ~ '. ~ ,'1 .HC03 , I ~ I . ~ r . I I HCOs 50 . . Kg: I 50 ; I ·804 50 I 1/ I ' CO. , , (.. - , I It i II" I f ,_ ': \ tl I..' - ~ - (H. ftlae Ira ÛOft ~ IIIdo4ae N.. K..I'M! U) X.OTE: 1f£lt=~11J.tura:aø pa' ·Ut«' liteqJl= XW1cra= iIq~t1J I*' I{tœ IocUcuD ddori4a ..wr"t=~ DUMIe;p a E~ ,rJabfow. frota CiÞillllØ__to .~ ~ CHEfVlICAl,'~ GEOLOGICAL lABORATwH:S TELEPHONE (907) 279-4014 P.O.80X 4-1276 ANCHORAGE. ALASKA 99509 -- . WATER ANALYSIS REPOR'l~ OF ALASKA, ir~C. 2603 ARCTIC BLVD. OPERATO:e WELL 110- IrIKLD COUNTY 'STATY! UNION· OIL COMPANY OF CALIF. DATR November 9, 1973 !.AD NO.. 1268-28 LOCATION FORIUTION DfTERVAT~ ALASKA SAKPLf: FROY DST #9, #3 Sterling IUCKARXS a CONCLUSIONS~ Cloudy brown water. Filtrate clear light brown water. *Iron (Fe), m~/l. . . ~. 1.3 Barium CBa}. m~/1 . . .. 0.5 Strontium (Sr), mg/I. .. 0.4 Chromium (Cr), mg/1. .' . . 0.4 Catloall 5L! ~ Anions 3!! --rJ¡ f' oc'",", .. .. .. .. 4752 206.69 SaIlato .. - .. . 95 1.98 Pct-,-.) -'" 467 11...!!L C!zJadda ... .. .. 7000 197.40 ('''~ .. _. .. - .. .- 16 0.80 Cuboc&to 206 6.86 K:It"'--~ .. - - .. .. ? 0.16 Bicarbonate .. .- 815 13.37 Iroa .. - .. .. * Hydromdo TotIl Catbc.a .. . .. . 2).9.61 Totd JudomJ .. '. 219.61 ~~--- Totd &Iolnd I01ktø, rtJIdl 12939 Specific ~ @ 65°11.: HaC! eqafft1ct, me/l . .. . - 12765 ObIw:Nld 0.518 oIìm-DIta'S Obi. . ~.>I pH - .. .. - .. 9.3 CIlk.n~ttd .. . .. .. 0.52 oIma-~ WATER ANALYSIS PATTEID-t Scale KEQ per Unit . : Sample abov. dncnõed !: I I I . I: Cl 100 . .iI::, fI' I J ' p' Na p,iril!, ï¡. . ;··1 :J: ~'f 'I: II , f t I \' .' 1 Ca - J i.1jf . ,I ' :" ¡ : 'I'!:¡ '"" .. ¡II , '" ¡ ,,¡I-. II, I q' Mg '. ~¡ 11' '..¡ "_ . j " . "j I ; I- I Fe ,,'tj;'.i'1ì- ''11,' t;l' I I \ I 'I ¡" ~ 11 · . " J II I p;. I \ I· \. r' J J I t I I' H dill I .j' 1'~' I ! · I /I f' .,.. · I' L.-.· R .' .1'1 . , . ~ í Ca . /{ ~ I j l ¡ .1 . I I( ]I !Ie . ~ ; 'I ,I HC03 10 SO.c 10 , ,. 1 ' . \ . . ".~ , I . f ~. 1 Fe' 'I ~11'llt,·. :.~. Ii, ~~. "C03 ~ :¡¡¡ ¡i 1': '.: 1J I j! J tIJ ~" . ., < - I . ,,[ 'l. I.... ,I ., ~: I 10 "-:.~ (If a ftJøe hi &IwN ~ Iac:Ja4ø Na. E,.1&4I U) II.OTE: KUI=K~ pcIi' 1ftc M«:Il= lfiWcraas ~tG I*' 1ft« Ioöua ~ "ulnllat=~ Duak¡p I: HIIWthonIe H~~ &e. :::n~,,-t;¡; .' ¡' , I í1 f d. tJ )I!~ , I · · ~ I ~ I' fl' '.' . II. ;. ~ Cl . " . ~ "( ; . i : f t ',. HC03 , , I , ~ I . I '~ SO.. . I' ,. , ... I,. "C021 , . d: f, '. )~ f; {¡f¡~"f i7 l;'" I: II I ~ . 1 L ATTACHMENT 4 Methodologies for Computing Salinity From Well Log Data Two methods employed for the purpose of estimating formation water salinity from available well log data are provided below: 1) Resistivity (Rva) Method The Rwa Method of estimating salinity of a given formation in a well is based on the relationship between formation resistivity and porosity, which is expressed by the following equation: Rwa = ~ / F where F = 0.62 / 2.15 Rwa = Apparent formation fluid resistivity ~ = True formation resistivity F = Formation resistivity factor = Porosity The salinity of any given formation fluid can be estimated if the porosity, temperature and resistivity of that formation are known. True formation resistivity (RJ can be read from the Deep Induction log curve; the equation shown above removes the effects of the rock itself from the resistivity measurement, so that the resulting ~a value represents only the formation fluid itself. ~a values corrected for formation temperature can be used to estimate formation water salinity. 2) Spontaneous Potential (SP) Method The SP Method of calculating salinity is based on the relationship between the resistivity of the mud filtrate and formation water and the amount of deflection in the SP curve in a 100 percent water saturated zone, and can be demonstrated by the following equations: SSP = -Kc [log(RweqlRveq)] where SSP = Static SP departure from shale baseline Kc = 61 + 0.133 Tf Rnfeq = Equivalent mud filtrate resistivity of a pure NaCL solution ~lfeq =(Rnf)(0.85) where Unocal Freshwater Aquifer Exemption Application - 12/12/01 '- Rnr = true mud filtrate resistivity at formation temperature Rweq = Equivalent formation water resistivity of a pure NaCL solution Values that had to be adjusted to true formation temperature were adjusted assuming a geothermal gradient of O.83°F/IOO ft. This gradient was calculated by linearly interpolating between the mean surface temperature in the Kenai Peninsula region (65° F) and the recorded bottom hole temperature in the well, by the equation: Tgrad = (BHT - MST)/(d/lOO) where: MST = 65° Unocal Freshwater Aquifer Exemption Application - 12/12/01 '-- ATTACHMENT 5 WELL LOGS .- Unocal Freshwater Aquifer Exemption Application - 12/12/01 -- ATTACHMENT 6 SUMMARY OF WATER WELLS IN THE COHOE UNIT #1 WELL VICINITY 1 Distance Well Owner at Time of Date of Depth Sub- Legal from Site Identification Install Completion (feet) Section Section Driller SECTION 4 2286 Kessler, Tim 9/10/80 176 4 B Kraxberger Irish Hills > 1 Drilling L B 2792 Gillilan, Billie 9/9/82 185 4 BCBC Echo Lake Irish Hills > 1 Drilling LA3 & LA4 3760 Madden, Marjorie J 6/7/83 119 4 DA Echo Lake Near Madden, > 1 Drilling Lots 3902 Madden, Casey 10/4/83 126 4 CDCB Echo Lake Madden 1 Resub > 1 Drilling L3A 8264 Derleth, Larry 4/12/84 115 4 B Kraxberger Irish Hills > 1 Drilling L 13 B2 15973 Kessler, Tim 9/19/85 177 4 B Kraxberger Irish Hills > 1 Drilling L B 16410 Morgan, Guy 9/4/82 169 4 BACD Kraxberger Irish Hills > 1 Drilling TR-C 18515 Lawrence, Brian 6/10/86 175 4 BACB Echo Lake Irish Hills > 1 Drilling TR-B1 20014 Kessler, Tim 9/19/85 177 4 BBBC Kraxberger Spruce Park Est > 1 Drilling L02 B2 20015 Dullerty, Donald L. 3/24/79 69 4 BABB Echo Lake Spruce Park Est > 1 Drilling L01 B1 20016 Nichols, Alfred 5/23/76 196 4 BCBB Echo Lake O'Rourke > 1 Drilling TR-C 20786 Gillilan, Billie 9/9/82 185 4 BBDD Echo Lake Irish Hills LA3 & > 1 Drilling A4 21489 Nickols, Alfred 5/28/76 196 4 BCAA Echo Lake O'Rourke > 1 Drilling TR-B 21752 Gillilan, Dennis 8/28/72 190 4 BACC Unknown Irish Hills > 1 TR-B 22569 Taylor, Pam 4/5/91 155 4 BBCB Kraxberger Spruce Park > 1 Drilling EST 1 L06 B 23652 Jackinsky, G 10/29/92 127 4 D Echo Lake Madden TR D2 > 1 Drilling B2 SECTION 5 16626 Kenai PB SWS 1/1/82 39 5 ACBC Unknown Kasilof Site- >1 Investi 1, TH-1 16627 Kenai PB SWS 1/1/82 81 5 Unknown Kasilof Site- >1 Investi 1, TH-2 - Unocal Freshwater Aquifer Exemption Application - 12/19/01 '-- Attachment 6 (cont.) '_ Summary of Water Wells in the Cohoe Unit #1 Well Vicinityl Distance Well Owner at Time of Date of Depth Sub- Legal from Site Identification Install Completion (feet) SECTION 6 641 Jenks, Del 4/4/78 30 6 CCCO Echo Lake Old Kasilof > 1 Drilling L13 1974 Pendleton, Kim 6/26/80 34 6 Kraxberger Old Kasilof > 1 Drilling L06 2093 Davis, William 6/27/80 35 6 Kraxberger Old Kasilof > 1 Drilling L 16305 Mcconnell, Larry 8/20/83 37 6 Kraxberger Old Kasilof > 1 Drilling L 16449 Clouston, George 6/28/82 250 6 CBBD Kraxberger Old Kasilof > 1 Drilling L30 20788 Vincent, Dave 7/24/85 153 6 AABD Kraxberger Old Kasilof > 1 Drilling L23 TR-1 SECTION 7 1975 B&D Development 10/19/81 57 7 BBAD Kraxberger Old Kasilof :> 1 Drilling L15A 16348 Wilkensen/ 1 0/22/82 55 7 CBCA Kraxberger Coal CR CNTRY > 1 Wikstrom Drilling EST L01 B7 19730 Eveland, Benjamin C 6/27/83 43 7 CBCD Kenny Coal CR CNTRY > 1 Carver EST 1 Drilling SECTION 8 - NO WELLS IDENTIFIED IN SECTION 8 SECTION 9 2275 Hall, 0 H 10/16/79 95 9 ADBD Kraxberger Eastview L 10 B ~-1 Drilling 2802 Dumond, Donald 6/10/82 82 9 ADAD Echo Lake Eastview L07 > 1 Drilling B1 17452 Gauthier, William 100 9 CAC Unknown Clam Gulch ~-1 Area 18402 Thorton, Jim 11/30/84 99 9 AADB Northland Coal Lake L06 > 1 Drilling B2 19263 Burford, Dallas 85 9 ACD Unknown Kasilof Area > 1 20784 Hall, Odean 4/3/85 95 9 ADBC Kraxberger Eastview L 11 > 1 Drilling B2 21744 Glendening, James 95 9 ADD Unknown Eastview L06 > 1 B1 21745 Construction Service 0 9 ACD Kraxberger Eastview L01 Drilling B1 21746 Collins, Marlin 9/1/78 87 9 ADCC Unknown Eastview L03 > 1 B01 Unocal Freshwater Aquifer Exemption Application - 12/12/01 Attachment 6 (cont.). ""- Summary of Water Wells in the Cohoe Unit #1 Well Vicinity! .....- Well Owner at Time of Date of Depth Sub- Legal Identification Install Completion (feet) Section Section Driller SECTION 16 - NO WELLS IDENTIFIED IN SECTION 16 SECTION 17 16145 Eaton, Gene 0 17 Unknown Clam Gulch Area Unknown 2 19212 Barnes, Frank 10/1/90 43 17 CAB Kraxberger Sec 17 Lots %-1 SECTION'18 2777 Robson, Rob 7/1/82 43 18 BBAC Echo Lake Coal Cr Cntry > 1 Drilling Est 8104 Grimes, Robbie 10/31/84 129 18 BBDB Echo Lake COALCR >1 Drilling CNTRY EST 12662 McLane, Michael 4/18/83 13 18 AAAC McLane & Loon Lake TR %-1 Assoc 4A TH-1 15793 Duncan, Thelma 6/19/84 38 18 Kraxberger Kasilof/Behind > 1 Drilling Airport 18493 Jackinsky, George 6/7/90 105 18 Kraxberger K Beach Rd Mi 2 > 1 Drilling Kasilof 18971 Jennings, Gary 7/31/85 126 18 BBC Smith Well Loon Lake %-1 Drilling TR-03 19209 Duncan, Jack 6/4/90 110 18 BA Kraxberger kasilof >1 Drilling 19237 Croskey, William 6/30/89 133 18 B Kraxberger Kasilof Airstrip K >1 Drilling Beach 19290 Smyth, Sharon 6/29/88 83 18 ADBB Hefty Beaver Brook >1 Drilling EST L2 B3 19737 Handsen, Michael 6/1/85 39 18 BBBB Echo Lake Coal Cr Cntry >1 Drilling Est L01A B2 19739 Johnson, Lee 1/1/81 85 18 BCC Echo Lake Coal Cr Cntry >1 Drilling Est LOS B3 20017 McLane, Michael 7/1/77 41 18 AAAC Unknown Loon Lake TR %-1 4A Notes: 1 - Well log information obtained from Alaska Department of Natural Resources, Division of Mining, Land and Water. All wells located in T3N R11W, Seward Meridian. 2 - No location information was available beyond section number; therefore, distance from Cohoe Unit #1 is unknown. The distance could range from less than ~ mile to more than 1 mile. Unocal Freshwater Aquifer Exemption Application - 12/12/01 "'- ATTACHMENT 7 '---~ CROSS SECTION THROUGH COHOE UNIT #1 AND EXISTING DISPOSAL INJECTION WELLS "'---~ "'. ="" Unocal Freshwater Aquifer Exemption Application - 12/12/01