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DIO 023
~ • INDEX DISPOSAL INJECTION ORDER #23 IVAN RIVER 1) May 17, 2001 Application for Disposal Injection Order 2) May 22, 2001 Notice of Hearing, ad orders for Anchorage Daily News And Clarion, affidavits of publication, mailing list 3) June 15, 2001 Misc documents from Unocal to AOGCC regarding sundry Well operations Ivan River Well 14-31 4) June 21, 2001 Sign in Sheet for meeting 5) June 22, 2001 Request for Additional Information DIO 6) Various e-mails 7) March 31, 2004 Unocal's request for Rule #4 Change (DIO 23.001) 8) August 9, 2006 e-mail from AOGCC to Operator 9) August 15, 2006 Disposal report for 14-31 Well 10) September 26, 2006 Letter to Unocal re: Disposal report for Ivan River Unit 14- 31 11) July 9, 2007 2006 Annual Report for UIC Class II disposal operations IRU 14-31 12. July 16, 2007 Memo to File: Annual Disposal Injection Performance Report; IRU 14-31 2006 Offsets TIO Report 13. -------------- Annual Reports 14. September 24, 2008 Chevron's request for an Administrative Approval to dispose of Class II waste into Ivan River 14-31. (DI023- 002) 15. --------------------- AOGCC background information Disposal Injection Order #23 - .. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue, Suite 100 Anchorage Alaska 99501 Re: THE APPLICATION OF ) UNOCAL Corporation for disposal ) of Class II oil field wastes by ) underground injection in Upper ) Sterling Formation, Ivan River Unit ) well IR 14-31, Section 1, TI3N, ) R9W, S. M. ) Disposal Injection Order No. 23 Ivan River Field Upper Sterling Formation August 9,2001 IT APPEARING THAT: 1. By correspondence dated May 16, 2001 Unocal requested authorization for a disposal order to allow the underground injection of Class II oil field waste fluids into the Sterling formation oflvan River Unit well 14-31 ("IRU 14-31") located on the Ivan River production pad in the Ivan River Field, Matanuska-Susitna Borough, Alaska. 2. By correspondence dated April 26, 2001, Unocal applied for a Freshwater Aquifer Exemption, (received May 16,2001) for all fresh water aquifers within a 11 mile radius and below 2500' measured depth (MD) in well IRU 14-31. 3. Additional information supporting the request for Class II disposal in well IRU 14-31 and for the freshwater aquifer exemption was received by correspondence dated June 22, 2001 and by sundry notice and reports dated June 13, 2001. 4. Notice of opportunity for public hearing was published in the Anchorage Daily News and Peninsula Clarion on May 14,2001 in accordance with 20 AAC 25.540. 5. The Commission did not receive any protest or a request for a public hearing. 6. The U.S. Environmental Protection Agency Region 10 did not object to the Aquifer Exemption Order ("AEO") for the Ivan River IRU 14-31 well. -.~. « . . . Disposal Injection Order #23 Ivan River Unit August 9, 2001 Page 2 of? FINDINGS: 1. Unocal is the operator of the Ivan River Field. There are no other operators within a one-half mile radius of the proposed disposal injection well. The State of Alaska is the surface owner. 2. Unocal proposes to conduct disposal operations in well IRU 14-31 between 3145' and 3420' measured depth ("MD"). 3. In order to accommodate the current and future Ivan River Field disposal injection operations, Unocal has requested exemption for all freshwater aquifers within a 11 mile radius and below 2500' MD in well IRU 14-31. 4. The nearest drinking water wells are two freshwater wells completed at approximately 200' MD on the Ivan River production pad. 5. The proposed disposal interval in IRU 14-31 extends from 2821' to approximately 3040' true vertical depth subsea ("TVDss"). Unocal interprets the sediments above 3100' TVDss in this well as glacial outwash, although noting the distinction is problematic due to the lithologic similarities with Upper Sterling Formation sediments. Upper Sterling Formation is used to identify the disposal zone described in this order. 6. The lithologies in the proposed disposal zone consist of permeable sandstones and conglomerates interbedded with shales and clay-rich sandy siltstones. 7. The salinities of the sands in this interval show a high degree of variability with depth. The interpretation of these salinity variations indicates the sands must be hydraulically isolated from each other. 8. Over 170 net vertical feet of sandstone are present in the proposed disposal interval. Water Pump-In tests have shown these sands to be highly permeable. 9. Twelve (12) vertical net feet of shale and 280 net vertical feet of very low permeability sandy siltstone and clay- rich sandstones confine the proposed disposal zone from the shallowest non-exempt aquifer. 10. The proposed disposal zone is confined below by over 700 net vertical feet of impermeable lithologies. . . Disposal Injection Order #23 Ivan River Unit August 9, 2001 Page 3 of7 11. Analysis of wire line logs from nearby well IRU 44-1 indicate that above a depth of 2300' MD, fresh water with salinities less than 3000 parts per million ("ppm") NaCI are present. Wire line log analytical techniques, which comply with EP A recommended methods as described in "Survey of Methods to Determine Total Dissolved Solids Concentrations", (KED A Project No. 30-956), were used to characterize formation water total dissolved solids content in well IRU 44-1. 12. Well IRU 14-31 was not logged above 2038' MD. Calculated salinity ranges in IRU 14-31 range from 6100 to 9230 ppm NaCI (associated with the interval from 3145' to 3420' MD, respectively) through the proposed injection zone. Wireline log analytical techniques, which comply with EP A recommended methods as described in "Survey of Methods to Determine Total Dissolved Solids Concentrations", (KED A Project No. 30-956), were used to characterize formation water total dissolved solids content in well IRU 14-31. 13.IRU 14-31 was drilled to a depth of 10,958' MD. The casing design for IRU 14-31 includes the following: 20" from surface to a depth of 40 1', 10-%" from surface to 2018' MD, and 7" casing from surface to 7018". The well was suspended on August 18, 1975. A cement retainer was set at 3225' MD with a cement plug placed from 3350' to 3508' MD. There is also one cement plug in the 5 W' liner and two cement plugs in the openhole section ofthe well, from 7600' to 9927' MD, from 10,100' to 10,350' MD and from 10,650' to 10,900' MD, respectively. Unocal received sundry approval from the Commission in 1993 to run 2-7/8" tubing to 2982' MD, with an isolation packer positioned at 2903' MD. This change was requested to allow for conversion to disposal service pending approval of disposal injection and aquifer exemption orders. 14. There are five wells in the 11 mile radius of well IRU 14-31. The well names, associated wellbore separation at the top ofthe proposed injection interval to proposed disposal well IRU 14-31 and current well status are listed below: IRU 13-31, 114' to North, gas producer, Tyonek IRU 44-36, 342' to North, gas producer, Beluga IRU 41-1,665' to South, gas producer. Beluga and Tyonek IRU 44-1,1155' to South, gas producer, Tyonek IRU 23-12, approximately 2600' to Southwest, P&A 15. The waste stream will consist of produced water, drilling, completion and workover fluids, rig wash, drilling mud slurries, NORM scale, tank bottoms, and other Class II fluids generated from drilling, production, workover and completion operations. The composition of the waste stream and constituent volumes will vary depending on drilling, workover, stimulation and maintenance activity. . . Disposal Injection Order #23 Ivan River Unit August 9, 2001 Page 4 of7 16. Unocal estimates that the average daily injection volume to be 1,000 barrels per day ("BPD") at a rate of approximately 2.5 barrels per minute ("BPM"). Later, produced water disposal rates are estimated to be in the range of 1 00 BPD. 17. Unocal estimates maximum surface injection pressure of 3300 pounds per square inch ("psi"), with an average disposal injection pressure of 2800 psi at a rate of 2.5 BPM. 18. The workoverldrilling program is estimated to generate a maximum of 30,000 barrels of oilfield waste. In addition, 100,000 barrels of produced water with a salinity ranging from 6,000 to 18,000 ppm may be injected. Unocal states that these volumes would create a waste plume that could range from 80-150 feet surrounding the injection point. 19. Unocal requested a waiver of20 AAC 25.412(b) to allow more than 200' MD between the packer and the perforations. Commission approval was obtained to perforate interval 3189' -3209' MD (286' MD below the packer) in proposed disposal well IRU 14-31 for the purpose of performing a water injection step rate test. The test results were filed by sundry on June 13,2001. 20. Two step-rate tests were performed on consecutive days with a total of 750 barrels water injected. In the second test, formation fracture pressure was exceeded at approximately 1.15 BPM, 2000-psi surface pressure and a water gradient. The pressure quickly dropped off after pump shutdown indicating high leak-off and good injectivity. 21. Fracture propagation within the disposal interval is an integral part of the process of placing waste fluids into the rock matrix. Fractures will be created as the disposal zone begins to plug. Fractures (or disaggregation of the clogged pores and rock matrix) provide pathways to transport waste fluids to undamaged storage volume within the disposal zone. 22. Unocal also submitted fracture-modeling results that support the conclusion that injected wastes would not reach or penetrate the confining interval at 2945' MD (2714' TVD). An Aquifer Exemption Order was approved July 23,2001, exempting aquifers between 2500' and 3420' MD in the area around well IRU 14-31. 23. Both inner and outer annulus pressures were monitored in wells IRU 14-31, IRU 13- 31 and IRU 14-36 during the IRU 14-31 step-rate tests. No annulus pressure response was seen in any of these three wells. 24. Unocal indicated that the 7" annulus of proposed disposal well IRU 14-31 was successfully tested to 1500 psi prior to recent perforation operations. 25. The 7", 23 pound per foot ("ppf'), N-80 casing meets the requirements of AAC 252.412. . . Disposal Injection Order #23 Ivan River Unit August 9, 2001 Page 5 of7 26. A segmented cement bond log was run in the 7" of Well IRU 14-31 on Jan 31, 1993. This log shows adequate cement to isolate fluids to the proposed injection intervals. 27. For all wells within a Yz mile radius of the proposed disposal well, Unocal submitted cementing and mechanical integrity records. These records were reviewed and all affected wells appear to be sufficiently cased and cemented. 28. The injection pump will be continuously manned during actual injection into IRU 14- 31. The annulus pressures of all wells within the Yz mile radius will be checked and recorded prior to and after each injection cycle. In addition, the existing IRU 13-31 Glycol High Level Alarm will also alarm at the injection pump so that the injection pump operator can immediately shut down the pump in the event that pressure communication develops between IRU 14-31 and IRU 13-31. In that event, injection would not be re-initiated until Commission approval was obtained and it was determined that safe operations could continue. CONCLUSIONS: 1. The requirements of20 AAC 25.252(c) have been met. 2. After review ofUnocal's application for aquifer exemption, the Commission issued an AEO on July 23, 2001. The AEO exempts freshwater aquifers lying between 2500' and 3420' MD in Unocal's Ivan River well IRU 14-31 and within a one-half (Yz) mile radius in accordance with 40 CFR 147.102(b)(2)(i) and 20 AAC 25.440(c). 3 . Waste fluids authorized for disposal under this order in the IR U 14-31 well will consist exclusively of Class II waste generated from drilling, completion, workover and production operations. 4. Waste fluids will be contained within appropriate receiving intervals by the confining lithology in the Upper Sterling Formation, cement isolation of the wellbore and operating conditions. 5. Periodic fracturing and stimulation will be required to place solids into the disposal interval. Disposal injection operations in the IRU 14-31 well will be conducted at rates and pressures below those estimated to fracture the confining zone. 6. Evaluation of operational performance data and reservoir surveillance data will aid in preventing fracturing of the confining zone. 7. Surveillance of disposal material, daily monitoring of operational parameters, and demonstration of mechanical integrity prior to injection will reasonably assure the waste fluids are contained within the disposal interval. . . Disposal Injection Order #23 Ivan River Unit August 9,2001 Page 6 of7 8. Disposal injection of Class II wastes into well IRU 14-31 will not cause waste, jeopardize correlative rights, or impair ultimate recovery. NOW, THEREFORE, IT IS ORDERED THAT: RULE 1 Authorized Injection Strata for Disposal. Class II oil field fluids may be injected in conformance with Alaska Administrative Code Title 20, Chapter 25, for disposal into the Upper Sterling Formation between 3145' and 3420' MD in well IRU 14-31. RULE 2 Authorized Fluids This authorization is limited only to Class II waste fluids as follows: produced water, drilling, completion and work over fluids, rig wash, drilling mud slurries, NORM scale, tank bottoms, and other Class II fluids generated from drilling, production, workover and completion operations. The Commission may authorize the disposal of additional fluids not identified above on a case-by-case basis if the Commission determines they are suitable for disposal in a Class II well. RULE 3 Packer Distance From Perforations The requirement of 20 AAC 25 .412(b) stipulating maximum distance between packer and perforations of200' MD is waived in well IRU 14-31. RULE 4 Monitoring Program. Operating parameters including disposal rate, disposal pressure, annulus pressures (for both the disposal well and offsets) and volume of fluids and solids pumped must be monitored and reported according to requirements of20 AAC 25.432. An initial report of operations must be provided after one month of injection. An annual report evaluating the performance of the disposal operation, including an annual MIT and temperature log must be submitted by July 1 of each year. RULE 5 Notification of Improper Class II Injection The operator must immediately notify the Commission if it learns of any improper Class II injection. Additionally, notification requirements of any other State or Federal agency remain the operators' responsibility. RULE 6 Administrative Action Upon request, the Commission may administratively revise and reissue this order or any of its rules upon proper showing that the change is based on sound engineering practices, will not allow waste fluids to escape from the disposal zone, and will not cause waste. . . Disposal Injection Order #23 Page 7 of 7 Ivan River Unit August 9, 2001 RULE7 Statewide Requirements Except where a rule state above substitutes for a statewide requirement, statewide requirements under 20 AAC 25 apply in addition to the above rules. DONE at Anchorage, Alaska and dated August 9,2001. ~ M.. ~{;~f Julie M. Heusser, Commissioner Alaska Oil and Gas Conservation Commission AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23rd day following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the lO-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30-day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., 10th day after the application for rehearing was filed). OFFICE OF THE GOVERNOR, JOHN KATZ STE 518 444 N CAPITOL NW WASHINGTON, DC 20001 LIBRARY OF CONGRESS, STATE DOCUMENT SECTION EXCH & GIFT DIV 10 FIRST ST SE WASHINGTON, DC 20540 US GEOLOGICAL SURVEY, LIBRARY NATIONAL CTR MS 950 RESTON, VA 22092 AMOCO CORP 2002A, LIBRARY/INFO CTR POBOX 87703 CHICAGO, IL 60680-0703 ALFRED JAMES III 107 N MARKET STE 1000 WICHITA, KS 67202-1811 XTO ENERGY, SUSAN LILLY 210 PARK AVE STE 2350 OKLAHOMA CITY, OK 73102-5605 OIL & GAS JOURNAL, LAURA BELL POBOX 1260 TULSA, OK 74101 US DEPT OF ENERGY, ENERGY INFORMATION ADMINISTRATION MIR YOUSUFUDDIN 1999 BRYAN STREET STE 1110 DALLAS, TX 75201-6801 XTO ENERGY, MARY JONES 810 HOUSTON ST FORT WORTH, TX STE 2000 76102-6298 . PIRA ENERGY GROUP, LIBRARY 3 PARK AVENUE (34th & PARK) NEW YORK, NY 10016 ARENT FOX KINTNER PLOTKIN KAHN, LIBRARY WASHINGTON SQ BLDG 1050 CONNECTICUT AV NW WASHINGTON, DC 20036-5339 U S DEPT OF ENERGY, PHYLLIS MARTIN MS EI823 1000 INDEPENDENCE SW WASHINGTON, DC 20585 DPC, DANIEL DONKEL 1420 NORTH ATLANTIC AVE, STE 204 DAYTON BEACH, FL 32118 ILLINOIS STATE GEOL SURV, LIBRARY 469 NATURAL RESOURCES BLDG 615 E PEABODY DR CHAMPAIGN, IL 61820 MURPHY E&P CO, ROBERT F SAWYER POBOX 61780 NEW ORLEANS, LA 70161 IOGCC, POBOX 53127 OKLAHOMA CITY, OK 73152-3127 GAFFNEY, CLINE & ASSOC., INC., LIBRARY 16775 ADDISON RD, STE 400 ADDISON, TX 75001 DEGOL YER & MACNAUGHTON, MIDCONTINENT DIVISION ONE ENERGY SQ, STE 400 4925 GREENVILLE AVE DALLAS, TX 75206-4083 SHELL WESTERN E&P INC, G.S. NADY POBOX 576 HOUSTON, TX 77001-0574 . NY PUBLIC LIBRARY DIV E, GRAND CENTRAL STATION POBOX 2221 NEW YORK, NY 10163-2221 US MIN MGMT SERV, CHIEF OCS STATS & INFO 381 ELDEN ST MS 4022 HERNDON, VA 20170-4817 TECHSYS CORP, BRANDY KERNS PO BOX 8485 GATHERSBURG, MD 20898 SD DEPT OF ENV & NATRL RESOURCES, OIL & GAS PROGRAM 2050 W MAIN STE #1 RAPID CITY, SD 57702 LINDA HALL LIBRARY, SERIALS DEPT 5109 CHERRY ST KANSAS CITY, MO 64110-2498 UNIV OF ARKANSAS, SERIALS DEPT UNIV LIBRARIES FAYETTEVILLE, AR 72701 R E MCMILLEN CONSULT GEOL 202 E 16TH ST OWASSO, OK 74055-4905 BAPIRAJU 335 PINYON LN COPPELL, TX 75019 STANDARD AMERICAN OIL CO, AL GRIFFITH POBOX 370 GRANBURY, TX 76048 H J GRUY, ATTN: ROBERT RASOR 1200 SMITH STREET STE 3040 HOUSTON, TX 77002 PURVIN & GERTZ INC, LIBRARY 2150 TEXAS COMMERCE TWR 600 TRAVIS ST HOUSTON, TX 77002-2979 OIL & GAS JOURNAL, BOB WILLIAMS 1700 W LOOP SOUTH STE 1000 HOUSTON, TX 77027 MARATHON OIL CO, GEORGE ROTHSCHILD JR RM 2537 POBOX 4813 HOUSTON, TX 77210 EXXON EXPLORATION CO., T E ALFORD POBOX 4778 HOUSTON, TX 77210-4778 PHILLIPS PETROLEUM COMPANY, W ALLEN HUCKABAY PO BOX 1967 HOUSTON, TX 77251-1967 EXXONMOBIL PRODUCTION COMPANY, J W KIKER ROOM 2086 POBOX 2180 HOUSTON, TX 77252-2180 MARATHON, Ms. Norma L. Calvert POBOX 3128, Ste 3915 HOUSTON, TX 77253-3128 TEXACO INC, R Ewing Clemons PO BOX 430 BELLAIRE, TX 77402-0430 INTL OIL SCOUTS, MASON MAP SERV INC POBOX 338 AUSTIN, TX 78767 DIANE SUCHOMEL 10507D W MAPLEWOOD DR LITTLETON, CO 80127 . RAY TYSON 2016 MAIN #1415 HOUSTON, TX 77002-8844 PETRAL CONSULTING CO, DANIEL L LIPPE 9800 RICHMOND STE 505 HOUSTON, TX 77042 UNOCAL, REVENUE ACCOUNTING POBOX 4531 HOUSTON, TX 77210-4531 CHEVRON USA INC., ALASKA DIVISION ATTN: CORRY WOOLlNGTON POBOX 1635 HOUSTON, TX 77251 WORLD OIL, DONNA WILLIAMS POBOX 2608 HOUSTON, TX 77252 PENNZOIL E&P, WILL D MCCROCKLIN POBOX 2967 HOUSTON, TX 77252-2967 ACE PETROLEUM COMPANY, ANDREW C CLIFFORD PO BOX 79593 HOUSTON, TX 77279-9593 WATTY STRICKLAND 2803 SANCTUARY CV KATY, TX 77450-8510 BABCOCK & BROWN ENERGY, INC., 350 INTERLOCKEN BLVD STE 290 BROOMFIELD, CO 80021 GEORGE G VAUGHT JR POBOX 13557 DENVER, CO 80201 . CHEVRON, PAUL WALKER 1301 MCKINNEY RM 1750 HOUSTON, TX 77010 MARK ALEXANDER 7502 ALCOMITA HOUSTON, TX 77083 EXXON EXPLOR CO, LAND/REGULATORY AFFAIRS RM 301 POBOX 4778 HOUSTON, TX 77210-4778 PETR INFO, DAVID PHILLIPS POBOX 1702 HOUSTON, TX 77251-1702 EXXONMOBIL PRODUCTION COMPANY, GARY M ROBERTS RM 3039 POBOX 2180 HOUSTON, TX 77252-2180 CHEVRON CHEM CO, LIBRARY & INFO CTR POBOX 2100 HOUSTON, TX 77252-9987 PHILLIPS PETR CO, PARTNERSHIP OPRNS JIM JOHNSON 6330 W LOOP S RM 1132 BELLAIRE, TX 77401 TESORO PETR CORP, LOIS DOWNS 300 CONCORD PLAZA DRIVE SAN ANTONIO, TX 78216-6999 ROBERT G GRAVELY 7681 S KIT CARSON DR LITTLETON, CO 80122 US GEOLOGICAL SURVEY, LIBRARY BOX 25046 MS 914 DENVER, CO 80225-0046 C & R INDUSTRIES, INC." KURT SALTSGAVER 7500 W MISSISSIPPI AVE STE C4 LAKEWOOD, CO 80226-4541 RUBICON PETROLEUM, LLC, BRUCE I CLARDY SIX PINE ROAD COLORADO SPRINGS, CO 80906 US GEOLOGICAL SURVEY, LIBRARY 2255 N GEMINI DR FLAGSTAFF, AZ 86001-1698 BABSON & SHEPPARD, JOHN F BERGQUIST POBOX 8279 VIKING STN LONG BEACH, CA 90808-0279 TEXACO INC, Portfolio Team Manager R W HILL POBOX 5197x Bakersfield, CA 93388 H L WANGENHEIM 5430 SAWMILL RD SP 11 PARADISE, CA 95969-5969 MARPLES BUSINESS NEWSLETTER, MICHAEL J PARKS 117 W MERCER ST STE 200 SEATTLE, WA 98119-3960 TRUSTEES FOR ALASKA, 1026 W. 4th Ave, Ste 201 ANCHORAGE, AK 99501 GUESS & RUDD, GEORGE LYLE 510 L ST, STE 700 ANCHORAGE, AK 99501 STATE PIPELINE OFFICE, LIBRARY KATE MUNSON 411 W 4TH AVE, STE 2 ANCHORAGE, AK 99501 . JERRY HODGDEN GEOL 408 18TH ST GOLDEN, CO 80401 JOHN A LEVORSEN 200 N 3RD ST #1202 BOISE, ID 83702 MUNGER OIL INFOR SERV INC, POBOX 45738 LOS ANGELES, CA 90045-0738 ANTONIO MADRID POBOX 94625 PASADENA, CA 91109 US GEOLOGICAL SURVEY, KEN BIRD 345 MIDDLEFIELD RD MS 999 MENLO PARK, CA 94025 ECONOMIC INSIGHT INC, SAM VAN V ACTOR POBOX 683 PORTLAND, OR 97207 FAIRWEATHER E&P SERV INC, JESSE MOHRBACHER 7151ST #4 ANCHORAGE, AK 99501 DEPT OF ENVIRON CONSERVATION, DIV OF ENVIRONMENTAL HEALTH JANICE ADAIR 555 CORDOVA STREET ANCHORAGE, AK 99501 DEPT OF REVENUE, OIL & GAS AUDIT DENISE HAWES 550 W 7TH A V STE 570 ANCHORAGE, AK 99501 FOREST OIL, JIM ARLINGTON 310 K STREET STE 700 ANCHORAGE, AK 99501 . NRG ASSOC, RICHARD NEHRING POBOX 1655 COLORADO SPRINGS, CO 80901- 1655 TAHOMA RESOURCES, GARY PLAYER 1671 WEST 546 S CEDER CITY, UT 84720 LA PUBLIC LIBRARY, SERIALS DIV 630 W 5TH ST LOS ANGELES, CA 90071 ORO NEGRO, INC., 9321 MELVIN AVE NORTH RIDGE, CA 91324-2410 SHIELDS LIBRARY, GOVT DOCS DEPT UNIV OF CALIF DAVIS, CA 95616 US EPA REGION 10, THOR CUTLER OW-137 1200 SIXTH AVE SEATTLE, WA 98101 DEPT OF ENVIRON CONSERVATION, DIV OF AIR & WATER QUALITY TOM CHAPPLE 555 CORDOVA STREET ANCHORAGE, AK 99501 DUSTY RHODES 229 WHITNEY RD ANCHORAGE, AK 99501 DEPT OF REVENUE, BEVERLY MARQUART 550 W 7TH A V STE 570 ANCHORAGE, AK 99501 DEPT OF REVENUE, CHUCK LOGSTON 550 W 7TH AVE, SUITE 500 ANCHORAGE, AK 99501 DEPT OF REVENUE, DAN DICKINSON, DIRECTOR 550 W 7TH AVE, SUITE 500 ANCHORAGE, AK 99501 ALASKA DEPT OF LAW, ROBERT E MINTZ ASST ATTY GEN 1031 W 4TH AV STE 200 ANCHORAGE, AK 99501-1994 DEPT OF REVENUE, OIL & GAS AUDIT FRANK PARR 550 W 7TH AVE STE 570 ANCHORAGE, AK 99501-3540 AK JOURNAL OF COMMERCE, OIL & INDUSTRY NEWS ROSE RAGSDALE 4220 B Street Ste #210 ANCHORAGE, AK 99501-3560 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS JULIE HOULE 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 N-I TUBULARS INC, 3301 C Street Ste 209 ANCHORAGE, AK 99503 ANADARKO, MARK HANLEY 3201 C STREET STE 603 ANCHORAGE, AK 99503 FINK ENVIRONMENTAL CONSULTING, INC., THOMAS FINK, PHD 6359 COLGATE DR. ANCHORAGE, AK 99504-3305 US BUREAU OF LAND MNGMNT, ANCHORAGE DIST OFC DICK FOLAND 6881 ABBOTT LOOP RD ANCHORAGE, AK 99507 UOA/ ANCHORAGE, INST OF SOCIAL & ECON RESEARCH TERESA HULL 3211 PROVIDENCE DR ANCHORAGE, AK 99508 . YUKON PACIFIC CORP, JOHN HORN VICE CHM 1049 W 5TH AV ANCHORAGE, AK 99501-1930 GAFO, GREEN PEACE PAMELA MILLER 125 CHRISTENSEN DR. #2 ANCHORAGE, AK 99501-2101 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 DEPT OF NATURAL RESOURCES, DIV OIL & GAS WILLIAM VAN DYKE 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 BAKER OIL TOOLS, ALASKA AREA MGR 4710 BUS PK BLVD STE 36 ANCHORAGE, AK 99503 ALASKA OIL & GAS ASSOC, JUDY BRADY 121 W FIREWEED LN STE 207 ANCHORAGE, AK 99503-2035 ARLEN EHM GEOL CONSL TNT 2420 FOXHALL DR ANCHORAGE, AK 99504-3342 US BUREAU OF LAND MNGMNT, ANCHORAGE DIST OFC PETER J DITTON 6881 ABBOTT LOOP ROAD ANCHORAGE, AK 99507 US BLM AK DIST OFC, GEOLOGIST ARTHUR BANET 949 EAST 36TH AVE STE 308 ANCHORAGE, AK 99508 . PRESTON GATES ELLIS LLP, LIBRARY 420 L ST STE 400 ANCHORAGE, AK 99501-1937 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS TIM RYHERD 550 W 7th AVE STE 800 ANCHORAGE, AK 99501-3510 DEPT OF NATURAL RESOURCES, PUBLIC INFORMATION CTR 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS JIM STOUFFER 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 BRISTOL ENVIR SERVICES, JIM MUNTER 2000 W. INT'L AIRPORT RD #C-1 ANCHORAGE, AK 99502-1116 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 AMERICA/CANADIAN STRATIGRPH CO, RON BROCKWAY 4800 KUPREANOF ANCHORAGE, AK 99507 THOMAS R MARSHALL JR 1569 BIRCHWOOD ST ANCHORAGE, AK 99508 VECO ALASKA INC., CHUCK O'DONNELL 949 EAST 36TH AVENUE ANCHORAGE, AK 99508 US MIN MGMT SERV, RESOURCE STUDIES AK OCS REGN KIRK W SHERWOOD 949 E 36TH A V RM 603 ANCHORAGE, AK 99508-4302 US MIN MGMT SERV, FRANK MILLER 949 E 36TH A V STE 603 ANCHORAGE, AK 99508-4363 US MIN MGMT SERV, RESOURCE EVAL JIM SCHERR 949 E 36TH AV RM 603 ANCHORAGE, AK 99508-4363 CIRI, LAND DEPT POBOX 93330 ANCHORAGE, AK 99509-3330 PHILLIPS ALASKA, JOANN GRUBER ATO 712 POBOX 100360 ANCHORAGE, AK 99510-0360 PHILLIPS ALASKA, LEGAL DEPT MARK P WORCESTER POBOX 100360 ANCHORAGE, AK 99510-0360 PHILLIPS ALASKA, KUP CENTRAL WELLS ST TSTNG WELL ENG TECH NSK 69 POBOX 196105 ANCHORAGE, AK 99510-6105 US BUREAU OF LAND MGMT, OIL & GAS OPRNS (984) J A DYGAS 222 W 7TH AV #13 ANCHORAGE, AK 99513-7599 JODY COLOMBIE 6811 ROUND TREE DRIVE ANCHORAGE, AK 99516 . TRADING BAY ENERGY CORP, PAUL CRAIG 5432 NORTHERN LIGHTS BLVD ANCHORAGE, AK 99508 US MIN MGMT SERV, RICHARD PRENTKI 949 E 36TH AV ANCHORAGE, AK 99508-4302 REGIONAL SUPRVISOR, FIELD OPERATNS, MMS ALASKA OCS REGION 949 E 36TH A V STE 308 ANCHORAGE, AK 99508-4363 JOHN MILLER 3445 FORDHAM DR ANCHORAGE, AK 99508-4555 PHILLIPS ALASKA, LAND MANAGER JIM RUUD P.O. BOX 100360 ANCHORAGE, AK 99510 PHILLIPS ALASKA, LAND DEPT JAMES WINEGARNER POBOX 10036 ANCHORAGE, AK 99510-0360 PHILLIPS ALASKA, STEVE BENZLER ATO 1404 POBOX 100360 ANCHORAGE, AK 99510-0360 AL YESKA PIPELINE SERV CO, PERRY A MARKLEY 1835 S BRAGAW - MS 575 ANCHORAGE, AK 99512 ANCHORAGE DAILY NEWS, EDITORIAL PG EDTR MICHAEL CAREY POBOX 149001 ANCHORAGE, AK 99514 JWL ENGINEERING, JEFF LIPSCOMB 9921 MAIN TREE DR. ANCHORAGE, AK 99516-6510 . US MIN MGMT SERV, AK OCS REGIONAL DIR 949 E 36TH AV RM 110 ANCHORAGE, AK 99508-4302 GORDON J. SEVERSON 3201 WESTMAR CIR ANCHORAGE, AK 99508-4336 US MIN MGMT SERV, LIBRARY 949 E 36TH AV RM 603 ANCHORAGE, AK 99508-4363 USGS - ALASKA SECTION, LIBRARY 4200 UNIVERSITY DR ANCHORAGE, AK 99508-4667 ANCHORAGE TIMES, BERT TARRANT POBOX 100040 ANCHORAGE, AK 99510-0040 PHILLIPS ALASKA, MARK MAJOR A TO 1968 POBOX 100360 ANCHORAGE, AK 99510-0360 PETROLEUM INFO CORP, KRISTEN NELSON POBOX 102278 ANCHORAGE, AK 99510-2278 AL YESKA PIPELINE SERV CO, LEGAL DEPT 1835 S BRAGAW ANCHORAGE, AK 99512-0099 DAVID W. JOHNSTON 320 MARINER DR. ANCHORAGE, AK 99515 NORTHERN CONSULTING GROUP, ROBERT BRITCH, P.E. 2454 TELEQUANA DR. ANCHORAGE, AK 99517 GERALD GANOPOLE CONSULT GEOL 2536 ARLINGTON ANCHORAGE, AK 99517-1303 ARMAND SPIELMAN 651 HILANDER CIRCLE ANCHORAGE, AK 99518 JACK 0 HAKKILA POBOX 190083 ANCHORAGE, AK 99519-0083 MARATHON OIL CO, LAND BROCK RIDDLE POBOX 196168 ANCHORAGE, AK 99519-6168 EXXONMOBIL PRODUCTION COMPANY, MARK P EVANS PO BOX 196601 ANCHORAGE, AK 99519-6601 BP EXPLORATION (ALASKA) INC, PETE ZSELECZKY LAND MGR POBOX 196612 ANCHORAGE, AK 99519-6612 AMSINALLEE CO INC, WILLIAM 0 VALLEE PRES PO BOX 243086 ANCHORAGE, AK 99524-3086 D A PLATT & ASSOC, 9852 LITTLE DIOMEDE CIR EAGLE RIVER, AK 99577 COOK INLET KEEPER, BOB SHAVELSON PO BOX 3269 HOMER, AK 99603 DOCUMENT SERVICE CO, JOHN PARKER POBOX 1468 KENAI, AK 99611-1468 . DAVID CUSATO 600 W 76TH A V #508 ANCHORAGE, AK 99518 HALLIBURTON ENERGY SERV, MARK WEDMAN 6900 ARCTIC BLVD ANCHORAGE, AK 99518-2146 ENSTAR NATURAL GAS CO, PRESIDENT TONY IZZO POBOX 190288 ANCHORAGE, AK 99519-0288 UNOCAL, POBOX 196247 ANCHORAGE, AK 99519-6247 BP EXPLORATION (ALASKA), INC., MARK BERLINGER MB 8-1 PO BOX 196612 ANCHORAGE, AK 99519-6612 BP EXPLORATION (ALASKA) INC, INFO RESOURCE CTR MB 3-2 POBOX 196612 ANCHORAGE, AK 99519-6612 L G POST O&G LAND MGMT CONSULT 10510 Constitution Circle EAGLE RIVER, AK 99577 JAMES RODERICK PO BOX 770471 EAGLE RIVER, AK 99577-0471 RON DOLCHOK POBOX 83 KENAI, AK 99611 KENAI PENINSULA BOROUGH, ECONOMIC DEVEL DISTR STAN STEADMAN POBOX 3029 KENAI, AK 99611-3029 . ASRC, CONRAD BAGNE 301 ARCTIC SLOPE AV STE 300 ANCHORAGE, AK 99518 OPSTAD & ASSOC, ERIK A OPSTAD PROF GEOL POBOX 190754 ANCHORAGE, AK 99519 MARATHON OIL CO, OPERATIONS SUPT W.C. BARRON POBOX 196168 ANCHORAGE, AK 99519-6168 UNOCAL, KEVIN TABLER POBOX 196247 ANCHORAGE, AK 99519-6247 BP EXPLORATION (ALASKA) INC, SUE MILLER POBOX 196612 M/S LR2-3 ANCHORAGE, AK 99519-6612 BP EXPLORATION (ALASKA) INC, MR. DAVIS, ESQ POBOX 196612 MB 13-5 ANCHORAGE, AK 99519-6612 PINNACLE, STEVE TYLER 20231 REVERE CIRCLE EAGLE RIVER, AK 99577 DEPT OF NATURAL RESOURCES, DGGS JOHN REEDER POBOX 772805 EAGLE RIVER, AK 99577-2805 PHILLIPS PETROLEUM CO, ALASKA OPERATIONS MANAGER J W KONST P 0 DRAWER 66 KENAI, AK 99611 NANCY LORD PO BOX 558 HOMER, AK 99623 ~.... .....---.- '" PENNY VADLA PO BOX 467 NINILCHIK, AK 99639 PACE, SHEILA DICKSON POBOX 2018 SOLDOTNA, AK 99669 AL YESKA PIPELINE SERVICE CO, VALDEZ CORP AFFAIRS SANDY MCCLINTOCK POBOX 300 MS1701 VALDEZ,AK 99686 UNIV OF ALASKA FAIRBANKS, PETR DEVEL LAB DR V A KAMATH 427 DUCKERING FAIRBANKS, AK 99701 C BURGLlN POBOX 131 FAIRBANKS, AK 99707 K&K RECYCL INC, POBOX 58055 FAIRBANKS, AK 99711 UNIV OF ALASKA FBX, PETR DEVEL LAB SHIRISH PATIL 437 DICKERING FAIRBANKS, AK 99775 DEPT OF ENVIRON CONSERV SPAR, CHRIS PACE 410 WILLOUGHBY AV STE 105 JUNEAU, AK 99801-1795 . BELOWICH, MICHAEL A BELOWICH 1125 SNOW HILL AVE WASILLA, AK 99654-5751 KENAI NATL WILDLIFE REFUGE, REFUGE MGR POBOX 2139 SOLDOTNA, AK 99669-2139 VALDEZ VANGUARD, EDITOR POBOX 98 VALDEZ, AK 99686-0098 RICK WAGNER POBOX 60868 FAIRBANKS, AK 99706 FRED PRATT POBOX 72981 FAIRBANKS, AK 99707-2981 ASRC, BILL THOMAS POBOX 129 BARROW, AK 99723 UNIVERSITY OF ALASKA FBKS, PETR DEVEL LAB DR AKANNI LAWAL POBOX 755880 FAIRBANKS, AK 99775-5880 . JAMES GIBBS POBOX 1597 SOLDOTNA, AK 99669 VALDEZ PIONEER, POBOX 367 VALDEZ,AK 99686 NICK STEPOVICH 543 2ND AVE FAIRBANKS, AK 99701 FAIRBANKS DAILY NEWS-MINER, KATE RIPLEY POBOX 70710 FAIRBANKS, AK 99707 DEPT OF NATURAL RESOURCES, DIV OF LAND REG MGR NORTHERN REGION 3700 AIRPORT WAY FAIRBANKS, AK 99709-4699 RICHARD FINEBERG PO BOX416 ESTER, AK 99725 SENATOR LOREN LEMAN STATE CAPITOL RM 113 JUNEAU, AK 99801-1182 . ~~ ffi1 ~ E ill F ffi1 ~ffi1~ ~~ffi1 . AI/A.SIiA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL NO. DIO 23.001 Mr. Larry Greenstein Unocal Alaska P.O. Box 196247 Anchorage, AK 99519-6247 RE: Disposal Injection Order 23-lvan River Unit Well 14-31 (175-008) Request to Change Mechanical Integrity (MIT) Interval Dear Mr. Greenstein: By letter dated March 31, 2004, Unocal requested an Administrative Approval under Rule 6 of Disposal Injection Order No. 23 to change the interval between Mechanical Integrity demonstrations (MIT) for the Ivan River Unit Well 14-31 (175-008) from annual to once every 4 years. Unocal's basis for the request is that the well is used intermittently and a 4-year test interval is specified for other intermittent service disposal wells. Unless superceded by a conservation order, 20 MC 25.252 (d) requires that the mechanical integrity (MI) of a disposal well be demonstrated at least once every 4 years as specified in 20 AAC 25.412 (c). 010 No. 23 was issued March 9, 2001. In Rule 4, the MIT interval specified was 1 year and in addition to the standard inner annulus pressure test a temperature log was required. Findings in the order file indicate the annual MIT frequency was specified because of close proximity to 2 production wells on the pad. Finding 14 of 010 No. 23 indicated IRU well 13-31 is 114' north and IRU well 44- 36 is 342' north of the disposal well at the top of the injection interval. Unocal has disposed of Class II wastes in accordance with 010 No. 23 from September 9 - November 27, 2001 and July 19 - August 11, 2002. A successful pressure MIT was performed in advance of each injection and a temperature log was obtained August 14, 2002. Approximately 39,000 barrels of waste were injected at about 1.5 bpm and 2000 psi. The rate and pressure correspond to the fracture initiation pressure determined by the injectivity test performed in June 2001. The temperature log showed cooling reversals at about 3050' md and in the perforated interval at 3190' md. The temperature plot appears to validate Finding 22 of the injection order that the planned disposal will not "... reach or DIO 23.00 1 June 1, 2004 Page 2 of2 . . penetrate the confining interval at 2945' md". Aquifer Exemption Order NO.6 exempts aquifers between the measured depths of 2500' - 3450'. After mid 1999, MIT intervals were specified at 2 years in 5 of the 7 orders issued on disposal wells. The basis for the decreased test interval is to increase scrutiny of wells that inject solids from waste grinding operations. Ivan River 14- 31 is approved for the disposal of liquid and ground solid waste. Intermittent operation has not been a consideration with regard to the MIT interval. A temperature log has not been required in the other orders, however none of the other disposal wells have wells in such close proximity to the disposal well. Disposal of liquefied solids slurry is accomplished via fracturing the receiving formation (Finding 21). A temperature log after slurry is pumped is a valid method to confirm the slurries are confined to the receiving formation. Surveillance of offset well annular pressure is the best method to identify slurry breakthrough to a nearby well. The diagnostic information provided by Unocal indicates that the wastes disposed have been contained as designed and in accordance with 'the requirements of 010 No. 23. Increasing the time interval between MIT demonstrations should not result in an increased risk of contaminating fresh water provided future disposal operations are conducted as required by the 010. Unocal has not requested modification of any other rule in the Order. Now therefore, as provided by Rule 6 of 010 No. 23, it is Ordered that: 1. When disposal operations are resumed, Unocal shall perform an MIT and thereafter at intervals of not more than once every 2 years. 2. A temperature log will not be routinely required, except when operating parameters or offset well annular pressures indicate liquefied slurry may be leaving the confined receiving interval; or; if requested by the Commission. rage, Alaska and dated June 1,2004. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION Orders and Administrative Approvals . . ¡DIO 23.001.dOci! Content-Type: applicationlmsword lof2 6/16/20048:08 AM Orders and Administrative Approvals . . Content-Encoding: base64 Content-Type: applicationlmsword AI03.3.doc Content-Encoding: base64 ..____.__."_._.. _mm._..._...__·_...··_ Content-Type: applicationlmsword : AI04C.02.doc! Content-Encoding: base64 -- Content-Type: applicationlmsword Content-Encoding: base64 Content-Type: applicationlmsword D I 025( Corrected).docl Content-Encoding: base64 20f2 (. 6/16120048:08 AM Citgo Petroleum Corporation PO Box 3758 Tulsa, OK 74136 Kelly Valadez Tesoro Refining and Marketing Co. Supply & Distribution 300 Concord Plaza Drive San Antonio, TX 78216 Jerry Hodgden Hodgden Oil Company 408 18th Street Golden, CO 80401-2433 Kay Munger Munger Oil Information Service, Inc PO Box 45738 Los Angeles, CA 90045-0738 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Ciri Land Department PO Box 93330 Anchorage, AK 99503 David Cusato 600 West 76th Ave., #508 Anchorage, AK 99518 James Gibbs PO Box 1597 Soldotna, AK 99669 Richard Wagner PO Box 60868 Fairbanks, AK 99706 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 .. ...", Jo,,, XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 Robert Gravely 7681 South Kit Carson Drive Littleton, CO 80122 Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 Samuel Van Vactor Economic Insight Inc. 3004 SW First Ave. Portland, OR 97201 Schlumberger Drilling and Measurements 3940 Arctic Blvd., Ste 300 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Jack Hakkila PO Box 190083 Anchorage, AK 99519 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 Cliff Burglin PO Box 70131 Fairbanks, AK 99707 North Slope Borough PO Box 69 Barrow, AK 99723 .. David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 John Levorsen 200 North 3rd Street, #1202 Boise, ID 83702 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle, WA 98119-3960 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 GOrdon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 Darwin Waldsmith PO Box 39309 Ninilchick, AK 99639 Penny Vadla 399 West Riverview Avenue Soldotna, AK 99669-7714 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 /lJhll/ec{ ,J Ú/)ié/tJ ý i d ~ ~ ~j SARAH PALIN, GOVERNOR L~lIC1-7~ OIL A1~TD GA5 333 W. 7th AVENUE, SUITE 100 C01~5ER~ATIOI~T CODII-IISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL NO. DIO 23.002 Ms. Jean Bodeau Waste Specialist Chevron North America Exploration and Production P.O. Box 196247 Anchorage, AK 99519-6247 Re: Disposal Injection Fluids Dear Ms. Bodeau: Disposal Injection Order (DIO) 23 approved the injection of Class II waste fluids into the upper Sterling formation within the Ivan River Unit (IRU) Well 14-31. On September 24 and clarified on September 25 and October 16, 2008 Chevron North America Exploration and Production (Chevron) requested approval to dispose of precipitation collected from bermed secondary containment areas associated with exploration and development in west side Cook Inlet fields operated by Union Oil Company of California (Union), a Chevron Company. Your request is APPROVED. DIO 23 authorizes the disposal injection of drilling, completion, production and workover fluids; rig wash; drilling mud slurries; naturally occurring radioactive material scale; tank bottoms; and other Class II fluids generated from drilling, production, workover and completion operations. Union operates several production pads and facilities on the west side of Cook Inlet, each with a variety of secondary containment areas designed to capture any release of solid and liquids that could result in pollution. Materials in question include both fluids that have been downhole or are intended to be placed in the well to accomplish a specific purpose. IRU 14-31 is one of two Class II disposal injection wells operated by Union on the west side of Cook Inlet. Confinement of fluids to the intended injection zone in IRU 14-31 has been shown from the historical injection performance data provided by Union. Well integrity has been demonstrated by successful mechanical integrity testing and monitoring the well's annular pressures. A passing mechanical integrity test on IRU 14-31 was witnessed by a Commission inspector on October 26, 2008, The disposal injection of precipitation and any spilled materials recovered from secondary containment areas (including but not limited to areas around drilling rigs, grind DIO 23.002 • October 29, 2008 Page 2 of 2 and inject equipment, drilling and production material storage, and well cellars) into IRU 14-31 will have no detrimental effect on the confinement of fluids. Well integrity and correlative rights will not be negatively impacted because of the proposed inclusion of the recovered precipitation and any spilled materials in the disposal injection fluid stream. Waste will also not occur because of the addition of recovered fluids from the bermed secondary containment areas. Approval applies only to this specific request and is not intended to provide for a blanket authorization to inject these or similar non-hazardous fluids down other Class II disposal wells. DONE at Anchorage, Alaska and dated October 29, 20( aniel T. S ount, Jr. Chair Cathy . F erster Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 3I.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Page 1 of 1 • ~. Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Thursday, October 30, 2008 12:33 PM Subject: dio23-002 and Weatherford Generation 2.0 Multiphase Metering Admin Approval Attachments: dio23-002.pdf; Weatherford generation 2.0 Multiphase Metering AA.pdf BCC:'Aaron Gluzman'; caunderwood@marathonoil.com; 'Dale Hoffman'; Fridiric Grenier; Jason Brink; 'Joe Longo'; 'Lamont Frazer'; Marc Kuck; 'Mary Aschoff; Maurizio Grandi; P Bates; 'Sandra Lemke'; 'Scott Nash'; Sherry Corley; 'Steve Virant'; Tom Gennings; 'Willem Vollenbrock'; 'William Van Dyke'; 'Aleutians East Borough'; 'Anna Raff; 'Barbara F Fullmer'; 'bbritch'; 'Bill Walker'; 'Brad McKim'; 'Brandon Gagnon'; 'Brian Gillespie'; 'Brian Havelock'; 'Brit Lively'; 'Bruce Webb'; 'buonoje'; 'Cammy Taylor'; 'Cande.Brandow'; 'carol smyth'; 'Cary Carrigan'; 'Charles O'Donnell'; 'Chris Gay'; 'Cliff Posey'; 'Dan Bross'; 'dapa'; 'Daryl J. Kleppin'; 'David Brown'; 'David Hall'; David House; 'David L Boelens'; 'David Steingreaber'; 'ddonkel'; 'Deborah J. Jones'; 'doug_schultze'; 'Eric Lidji '; 'Evan Harness'; 'eyancy'; 'foms2@mtaonline.net'; 'Francis S. Sommer'; 'Fred Steece'; 'Garland Robinson'; 'Gary Laughlin'; 'Gary Rogers'; 'Gary Schultz'; 'ghammons'; 'Gordon Pospisil'; 'Gregg Nady'; 'gregory micallef; 'gspfoff; 'Hank Alford'; 'Harry Engel'; 'jah'; 'James Scherr'; 'Janet D. Platt'; 'jejones'; 'Jerry McCutcheon'; 'Jim Arlington'; 'Jim White'; 'Jim Winegarner'; 'Joe Nicks'; 'John Garing'; 'John S. Haworth'; 'John Spain'; 'John Tower'; 'John W Katz'; johnny.aiken@north-slope.org; 'Jon Goltz'; 'Julie Houle'; 'Kari Moriarty'; 'Kaynell Zeman'; 'Keith Wiles'; knelson@petroleumnews.com; 'Krissell Crandall'; 'Kristin Dirks'; 'Laura Silliphant'; 'Lois'; 'Lynnda Kahn'; 'mail=akpratts@acsalaska.net'; 'mail=fours@mtaonline.net'; 'Marilyn Crockett'; 'Mark Dalton'; 'Mark Hanley'; 'Mark Kovac'; 'Mark P. Worcester'; 'Marquerite kremer'; 'Matt Rader'; Melanie Brown; 'Mike Bill'; 'Mike Mason'; 'Mikel Schultz'; 'Mindy Lewis'; 'MJ Loveland'; 'mjnelson'; 'mkm7200'; 'Nick W. Glover'; NSK Problem Well Supv; NSU, ADW Well Integrity Engineer; 'Patty Alfaro'; 'Paul Decker'; 'Paul Winslow'; Pierce, Sandra M (DNR); 'Randall Kanady'; 'Randy L. Skillern'; 'rcrotty'; Rice, Cody J (DNR); 'rmclean'; 'Rob McWhorter '; rob.g.dragnich@exxonmobil.com; 'Robert Campbell'; 'Robert Fowler'; 'Robert Province'; 'Roger Belman'; 'Rudy Brueggeman'; 'Scott Cranswick'; 'Shannon Donnelly'; 'Sharmaine Copeland'; 'Sondra Stewman'; 'Sonja Frankllin'; 'Stan Porhola'; 'stanekj'; 'Steve Lambert'; 'Steve Moothart'; 'Steven R. Rossberg'; 'tablerk'; 'Tamera Sheffield'; 'Temple Davidson'; 'Teri Arion'; 'Terrie Hubble'; 'Tim Lawlor'; 'Todd Durkee'; Tony Hopfinger; 'trmjrl'; 'Walter Featherly'; 'Walter Quay'; 'Wayne Rancier'; Birnbaum, Alan J (LAW); Crisp, John H (DOA); Davies, Stephen F (DOA); Fleckenstein, Robert J (DOA); Foerster, Catherine P (DOA); Grimaldi, Louis R (DOA); Johnson, Elaine M (DOA); Jones, Jeffery B (DOA); Laasch, Linda K (DOA); Mahnken, Christine R (DOA); Maunder, Thomas E (DOA); McIver, C (DOA); McMains, Stephen E (DOA); Noble, Robert C (DOA); Norman, John K (DOA); Okland, Howard D (DOA); Paladijczuk, Tracie L (DOA); Pasqual, Maria (DOA); Regg, James B (DOA); Roby, David S (DOA); Saltmarsh, Arthur C (DOA); Scheve, Charles M (DOA); Seamount, Dan T (DOA); Smith, Chasity R (DOA); Williamson, Mary J (DOA) Attachments:dio23-002.pdf;Weatherford generation 2.0 Multiphase Metering AA.pdf; Jody J. Colombie Special Assistant to the Commission Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 (907) 793-1221 Direct Line (907) 276-7542 Fax 10/30/2008 Mary Jones David McCaleb Cindi Walker XTO Energy, Inc. IHS Energy Group Tesoro Refining and Marketing Co. Cartography GEPS Supply & Distribution 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 300 Concord Plaza Drive Ft. Worth, TX 76102-6298 Houston, TX 77056 San Antonio, TX 78216 George Vaught, Jr. Jerry Hodgden Richard Neahring PO Box 13557 Hodgden Oil Company NRG Associates Denver, CO 80201-3557 408 18th Street President Golden, CO 80401-2433 PO Box 1655 Colorado Springs, CO 80901 John Levorsen Mark Wedman Schlumberger 200 North 3rd Street, #1202 Halliburton Drilling and Measurements Boise, ID 83702 6900 Arctic Blvd. 2525 Gambell Street #400 Anchorage, AK 99502 Anchorage, AK 99503 Ciri Baker Oil Tools Ivan Gillian Land Department 4730 Business Park Blvd., #44 9649 Musket Bell Cr.#5 PO Box 93330 Anchorage, AK 99503 Anchorage, AK 99507 Anchorage, AK 99503 Jill Schneider Gordon Severson Jack Hakkila US Geological Survey 3201 Westmar Cr. PO Box 190083 4200 University Dr. Anchorage, AK 99508-4336 Anchorage, AK 99519 Anchorage, AK 99508 Darwin Waldsmith James Gibbs Kenai National Wildlife Refuge PO Box 39309 PO Box 1597 Refuge Manager Ninilchick, AK 99639 Soldotna, AK 99669 PO Box 2139 Soldotna, AK 99669-2139 Penny Vadla Richard Wagner Cliff Burglin 399 West Riverview Avenue PO Box 60868 PO Box 70131 Soldotna, AK 99669-7714 Fairbanks, AK 99706 Fairbanks, AK 99707 Bernie Karl North Slope Borough K&K Recycling Inc. PO Box 69 PO Box 58055 Barrow, AK 99723 Fairbanks. AK 99711 /~3 / ~ /e~ ~~~ MIT_IRU_14-31_10-26-08 Page 1 of 1 Regg, James B (DOA) From: Greenstein, Larry P [Greensteinlp@chevron.com} ,~-~ Sent: Monday, October 27, 2008 10:12 AM `~1, To: Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA); DOA AOGCC Prudhoe Bay Cc: Fortney, Richard H; Lott, Michael J; Ross, Gary D; Orr, Gary A.; Bodeau, Jean; Sullivan, Sharon T; Myers, Chris S Subject: MIT IRU_14-31_10-26-08 Attachments: M1T IRU14-31 10-26-08.x1s Here is the official report for the Ivan River Unit 14-31 MIT completed on 10/26/08. Larry «MIT IRU14-31 10-26-08.x1s» 10/27/2008 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: Union Oil of California West Side / Ivan River Unit / Ivan River Pad 10/26/08 Rick Fortney Bob Noble ~~ Packer Depth Pretest Initial 15 Min. 30 Min. Well IRU 14-31 .Type Inj. N TVD 2,682' Tubing 20 20 20 20 Interval O P.T.D. 1750080 Type test P Test psi 1500 Casing 75 1560 1560 1560 P/F P Notes: Two Year MIT cycle -started test at 1100. OA 0 0 0 0 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W = Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 2008-1026 MIT IRU 14-31 bn.xls Request to dispose precipitation in IRU 14-31 (DI023) Page 1 of 4 • Regg, James B (DOA) From: Regg, James B (DOA) Sent: Thursday, October 16, 2008 10:14 AM ~~~ ~~~ (~, ~~~3 To: 'Bodeau, Jean' Subject: RE: Request to dispose precipitation in IRU 14-31 (D1023) Thank you for the discussion about fluid compatibility; analogous experience into Sterling sands will be sufficient. I will issue the administrative approval when the MIT has been completed. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Bodeau, Jean [mailto:BodeauJ@chevron.com] Sent: Thursday, October 16, 2008 7:37 AM To: Regg, James B (DOA) Subject: RE: Request to dispose precipitation in IRU 14-31 (DI023) Jim, Thanks for all of your help on this issue. Larry Greenstein replied to you separately regarding the MIT testing of both 14-31 and 13-31, and he will schedule the AOGCC witnessing of the test. I appreciate you noting the MITs in your email to me. I wanted to address the issue of compatibility of precipitation (and other minor residues from containment areas) with fluids currently being injected into IRU 14-31, and with the receiving formation (Sterling sands). Based on our extensive experiences with injection conditions nearly identical to the proposed injection scenario, we do not anticipate any issues of compatibility with either the fluids or the formation. Specifically, we have injected precipitation with minor containment area residue (principally small amounts of dirt and organic dust} into disposaP wells at the Swanson River Field (A1013} and NNA-1 {D1028) along with produced water and other drilling and production wastes. Our experiences at these wells have repeatedly empirically demonstrated that there are no compatibility issues of any kind; there have been no problems with plugging, formation of scale or precipitates, or injection rates. There have been no observable impacts on either the wells or the formation due to the dilution effect of freshwater on the produced fluids. Nevertheless, when deemed necessary by our corrosion and chemical engineers, the injected fluids will receive appropriate chemical treatment prior to injection. This winter we plan to dispose drill cuttings and exhumed reserve pit materials via slurry injection into wells 13-31 and 14-31 after all approvals are in place. Freshwater will be used as make-up fluid, and we anticipate no difficulties with compatibility, as previous G&I projects have demonstrated at Ivan River, Happy Valley and Swanson River fields. We expect to plumb both wells into the grind and inject equipment, to enable cycling of injection, and are seeking this approval so that the same rules apply to both webs in the event that precipitation needs to be disposed rather than beneficially reused as make-up fluid. Thanks much for the opportunity to clarify these points. I appreciate your help on this matter. Please call or email if you have any other questions or concerns. Best Regards, Jean 10/16/2008 Request to dispose precipitation in IRU 14-31 (DI023) Regg, James B (DOA} From: Bodeau, Jean [Bodeau)@chevron.com~ Sent: Thursday, October 16, 2008 7:37 AM ~~~ i~~l~(~ To: Regg, James B (DOA) ~'L Subject: RE: Request to dispose precipitation in IRU 14-31 (D1023) Page 1 Jim, Thanks for all of your help on this issue. Larry Greenstein replied to you separately regarding the MIT testing of ~ both 14-31 and 13-31, and he will schedule the AOGCG witnessing of the test. I appreciate you noting the MITs in your email to me. I wanted to address the issue of compatibility of precipitation {and other minor residues from containment areas) with fluids currently being injected into IRU 14-31, and with the receiving formation {Sterling sands). Based on our extensive experiences with injection conditions nearly identical to the pro o~ sed injection scenario, we do not anticipate any issues of compatibility with either the fluids or the formation. Specifically, we have injected precipitation with minor containment area residue {principally small amounts of dirt and organic dust) into disposal wells at the Swanson River Field (A1013) and NNA-1 D1028) along with produced water and other drilling and production wastes. ur experiences at these wells have repeatedly empirically demonstrated that there are no compatibility issues of any kind; there have been no problems with plugging, formation of scale or precipitates, or injection rates. There have been no observable impacts on ei- the bells or the formation due to the dilution effec o~ f freshwater on the produced fluids. Nevertheless, when deemed necessary by our corrosion and chemical engineers, the injected fluids will receive appropriate chemical treatment prior to injection. This winter we plan to dispose drill cuttings and exhumed reserve pit materials via slurry injection into wells 13-31 and 14-31 after all approvals are in place. Freshwater will be used as make-up fluid, and we anticipate no difficulties with compatibility, as previous G&I projects have demonstrated at Ivan River, Happy Valley and Swanson River fields. We expect to plumb both wells into the grind and inject equipment, to enable cycling of injection, and are seeking this approval so that the same rules apply to both wells in the event that precipitation needs to be disposed rather than beneficially reused as make-up fluid. Thanks much for the opportunity to clarify these points. I appreciate your help on this matter. Please call or email if you have any other questions or concerns. Best Regards, Jean From: Regg, James B (D mailto:jim.regg@alaska.gov] Sent: Thursday, October 09, 2 11:41 AM To: Bodeau, Jean Subject: RE: Request to dispose precipi n in IRU 14-31 (DI023) One more item -the last MIT in our weN fifes was 1 2006; that was a passing test witnessed by a Commission inspector. Next is due no later than 12/5/2008. Given this admin approval request and the application for a DIO f~ a witnessed MIT early so the results can be included as support for' me about scheduling a Commission inspector for witness of the MIT Jim Regg AOGCC 333 W.7th Avenue, Suite 100 U 13-31, it would be appropriate to perform ~6.~mmission's decisions. Please contact Thanltvcou. 10/16/2008 Request to dispose precipitation in IRU 14-31 (DI023) Page ls€~ • Regg, James B (DOA) From: Greenstein, Larry P [Greensteinlp@chevron.com] Sent: Tuesday, October 14, 2008 9:25 AM ~~~, is ~ t~ ~ o~ To: Bodeau, Jean 11 Cc: Regg, James B (DOA); PORHOLA, STAN T Subject: RE: Request to dispose precipitation in IRU 14-31 (D1023) Jean, We had considered this too. Turns out the drilling guys are going to be over there making another disposal well. Timing wise they believe they can do the MIT for both wells at once and still make it by 1215. If it looks like the drilling efforts are going to be delayed. We'll bump up the MIT for 14-31 and get it done as a stand alone. / Larry From: Bodeau, Jean Sent: Monday, October 13, 2008 4:51 PM To: Greenstein, Larry P Subject: FW: Request to dispose precipitation in IRU 14-31 (DI023) Larry, Jim Regg had some some suggestions in regard to MIT on the Westside. Jean om: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sen , hursday, October 09, 2008 11:41 AM To: Bode Jean Subject: RE: uest to dispose precipitation in IRU 14-31 (DI023) One more item -the last in our well files was 121512006; that was a passing test witnessed by a Commission inspector, Next is due na later n 12!5/2008. Given this admin approval request and th plication far a DIO for IRU 13-31, it would be appropriate to perform a witnessed MIT early so the results can be in ded as support for the Commission's decisions. Please eontaet me about scheduling a Commission inspector for w ss of the MIT. Thank you. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Regg, James B (DOA) Sent: Thursday, October 09, 2008 11:33 AM To: 'Bodeau, Jean' Subject: RE: Request to dispose precipitation in IRU 14-31 (DI023) 1 am wrapping up an approval letter (administrative approval under DIO 23}. One of the criteria we are using in 10/16/2008 Request to dispose precipitation in IRU 14-31 (DI023) Page 1 of 4 Regg, James B (DOA) From: Greenstein, Larry P [Greensteinlp@chevron.com] Sent: Tuesday, October 14, 2008 9:25 AM ~~ l ~~tr~~~ To: Bodeau, Jean Cc: Regg, James B (DOA); PORHOLA, STAN T Subject: RE: Request to dispose precipitation in IRU 14-31 (D1023) Jean, We had considered this too. Turns out the drilling guys are going to be over there making another disposal well. Timing wise they believe they can do the MIT for both wells at once and still make it by 1215. If it looks like the drilling efforts are going to be delayed. We'll bump up the MIT for 14-31 and get it done as a stand alone. Larry From: Bodeau, Jean Sent: Monday, October 13, 2008 4:51 PM To: Greenstein, Larry P Subject: FW: Request to dispose precipitation in IRU 14-31 (DI023) Larry, Jim Regg had some some suggestions in regard to MIT on the Westside. Jean From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, October 09, 2008 11:41 AM To: Bodeau, Jean Subject: RE: Request to dispose precipitation in IRU 14-31 (DI023) One more item -the last MIT in our well files was 1215/2006; that was a passing test witnessed by a Commission inspector. Next is due no later than 121512(}08. Given this admin approval request and the application for a DIO for IRU 13-31, it would be appropriate to perform a witnessed MIT early so the results can be included as support for the Commission°s decisions. Please contact me about scheduling a Commission inspector for witness of the MIT. Thank you. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Regg, James B (DOA) Sent: Thursday, October 09, 2008 11:33 AM To: 'Bodeau, Jean' Subject: RE: Request to dispose precipitation in IRU 14-31 (DI023) I am wrapping up an approval letter (administrative approval under DIO 23}. One of the criteria we are using in 10/14/2008 Request to dispose precipitation in IRU 14-31 (DI023) Page 2 of 4 our decision is the compatibility of precip {and any recovered materials from the bermed areas} with fluids currently being injected into 14-31, and compatibility with the receiving formation. We need a compatibility analysis and Chevron's assesment before the admin approval can be finished. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Bodeau, Jean [mailto:BodeauJ@chevron.com] Sent: Thursday, September 25, 2008 3:31 PM To: Regg, James B (DOA) Subject: RE: Request to dispose precipitation in IRU 14-31 (DI023) Dear Mr. Regg, Thanks for your response and the opportunity to clarify the basis of this request. In the letter sent previously, I detailed the specific containment areas where precipitation might be gathered for possible injection disposal, as follows: I am writing to request approval to dispose precipitation collected from bermed secondary containment areas associated with exploration and developmenf in our Westside fields, such as those around fhe drill rig, G&1 facility, drilling material storage areas, production material storage areas, and well cellars. The primary rationale for requesting this approval is the precedence of existing AOGCC Class II Disposal Injection Orders that authorize this fluid as compatible with Class II disposal. The Injection Orders where this is noted include: • DIO 26.003 (Kustatan Field Well #1 } • DIO 28A (NNA-1) • DIO 30A (NNA-2) -admittedly this is expired • DIO 16.001 (WMRU 4D) -one time authorization In addition, the AOGCC regulations 20 AAC 25.526 on Conduct of Operations state: An operator shall carry on all operations and maintain the property at all times in a safe and skillful manner in accordance with good oil field engineering practices and having due regard for the preservation and conservation of the property and protection of freshwater. Controlling runoff is necessary to comply with this regulatory requirement. All of these areas are uniquely associated with oil and gas exploration, production and development, and are a fundamental part of these operations. Without the oil and gas operations, there would be no need to have these areas or control runoff. The precipitation is non-hazardous, and injection disposal is the most environmentally sound disposal method available (compared with discharge to pad, or shipping offsite for disposal). Thank you again for your consideration. Please contact me if you require additional information, or with a determination. Sincerely, Jean Bodeau Jean M. Bodeau, CPG Hydrogeologist Waste Specialist 10/14/2008 Request to dispose precipitation in IRU 14-31 (DI023) Page 3 of 4 • Chevron North America Exploration and Production Company P.O. Box 496247 Anchorage, AK 99519-6247 Tel. (907) 263-7308 Fax (907)263-7321 Mobile (907) 382-1678 BodeauJ~chevron.com From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, September 25, 2008 9:18 AM To: Bodeau, Jean Subject: RE: Request to dispose precipitation in IRU 14-31 (DI023) please describe °'exploration and production-related secondary containment areas" and why you believe this is Class CID eligible. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Bodeau, Jean [mailto:BodeauJ@chevron.com] Sent: Wednesday, September 24, 2008 3:24 PM To: Regg, James B (DOA) Subject: Request to dispose precipitation in IRU 14-31 (DI023) Dear Mr. Regg, I am writing to request authorization via administrative approval (similar to Fluid Clarification DIO 26.003 issued for Forest Oil Kustatan Well #1) to dispose precipitation collected from exploration and production-related secondary containment areas into IRU 14-31 (DIO 23} in the Ivan River Unit on the west side of Cook Inlet. The attached letter contains more details. For your reference, I will forward separately an email from you authorizing a similar request for our NNA-1 well in November 2007. Please contact me if you have any additional questions or concerns. Thank you very much for your assistance. Best Regards, Jean «Westside D1023.pdf» Jean M. Bodeau, CPG Hydrogeologist Waste Specialist Chevron North America 10/14/2008 Request to dispose precipitation in IRU 14-31 (DIO23) Page 4 of 4 Exploration and Production Company P.O. Box 196247 Anchorage, AK 99519-6247 Tel. (907) 263-7308 Fax (907)263-7321 Mobile (907) 382-1678 B©dea_uJ_r?a chevron.com 10/14/2008 Request to dispose precipitation in IRU 14-3I (DI023) Page 1 of 2 • • Regg, James B (DOA) From: Bodeau, Jean [Bodeau)@chevron.com] Sent: Thursday, September 25, 2008 3:31 PM To: Regg, James B (DOA) Subject: RE: Request to dispose precipitation in IRU 14-31 (D1023) Dear Mr. Regg, Thanks for your response and the opportunity to clarify the basis of this request. In the letter sent previously, I detailed the specific containment areas where precipitation might be gathered for possible injection disposal, as follows: I am writing to request approval to dispose precipitation collected from bermed secondary containment areas associated with exploration and development in our Westside fields, such as those around the drill rig, G&1 facilify, drilling material storage areas, production material storage areas, and well cellars. The primary rationale for requesting this approval is the precedence of existing AOGCC Class II Disposal Injection Orders that authorize this fluid as compatible with Class II disposal. The Injection Orders where this is noted include: DIO 26.003 (Kustatan Field Well #1) • DIO 28A (NNA-1) • DIO 30A (NNA-2) -admittedly this is expired • DIO 16.001 {WMRU 4D) -one time authorization In addition, the AOGCC regulations 20 AAC 25.526 on Conduct of Operations state: An operator shall carry on all operations and maintain the property at all times in a safe and skil/fu! manner in accordance with good oil field engineering practices and having due regard for the preservation and conservation of the property and protection of freshwater. Controlling runoff is necessary to comply with this regulatory requirement. All of these areas are uniquely associated with oil and gas exploration, production and development, and are a fundamental part of these operations. Without the oil and gas operations, there would be no need to have these areas or control runoff. The precipitation is non-hazardous, and injection disposal is the most environmentally sound disposal method available (compared with discharge to pad, or shipping offsite for disposal). Thank you again for your consideration. Please contact me if you require additional information, or with a determination. Sincerely, Jean Bodeau Jean M. Bodeau, CPG Hydrogeologist Waste Specialist Chevron North America Exploration and Production Company P.O. Box 196247 Anchorage, AK 99519-6247 Tel. (907) 263-7308 Fax (907) 263-7321 Mobile (907) 382-1678 BndeauJ~chevron.com 9/26/2008 Request to dispose precipitation in IRU 14-31 (DI023) Page 2 of 2 • • From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, September 25, 2008 9:18 AM To: Bodeau, Jean Subject: RE: Request to dispose precipitation in IRU 14-31 (DI023) please describe "exploration and production-related secondary containment areas" and why you believe this is Class IID eligible. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Bodeau, Jean [mailto:BodeauJ@chevron.com] Sent: Wednesday, September 24, 2008 3:24 PM To: Regg, James B (DOA) Subject: Request to dispose precipitation in IRU 14-31 (DI023) Dear Mr. Regg, I am writing to request authorization via administrative approval (similar to Fluid Clarification DIO 26.003 issued for Forest Oil Kustatan Well #1) to dispose precipitation collected from exploration and production-related secondary containment areas into IRU 14-31 (DIO 23} in the Ivan River Unit on the west side of Cook Inlet. The attached letter contains more details. For your reference, I will forward separately an email from you authorizing a similar request for our NNA-1 well in November 2007. Please contact me if you have any additional questions or concerns. Thank you very much for your assistance. Best Regards, Jean «Westside D1023.pdf» Jean M. Bodeau, CPG Hydrogeologist Waste Specialist Chevron North America F~cploration and Production Company P.O. Box 196247 Anchorage, AK 99519-6247 Tel. (907) 263-7308 Fax (907)263-7321 Mobile (907) 382-1678 Bodeau)@chevron.coi~ 9/26/2008 ~~ Chevron Sep#ember 24, 2008 lean Boileau, CPG Hydrogeologist Waste Specialist Mr. James Regg Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 • Chevron Nortl>E America Exploratlon and production 909 West 9"' Avenue PA. Box 196247 Anchorage, AK 99519-6247 Tet 907 263 7308 Pax 907 263 7323 Cell 907 382-1678 Email BodeauJ~thevran.com RE. REQUEST FOR OPINION ON DIO 23 FOR IVAN RIVER FIELD WELL IR 1d-31 Dear Mr. Regg: Disposal Injection Order No. DIO 23, issued by AOGCC on August 9, 2001, authorised Union Oil Company of California to perform disposal injection of Class II oilfield waste fluids in#o the Upper Sterling Formation within the Ivan River Unit well 14-31 (IRU 14-31). The fluids approved under DIO 23 include drilling, completion, production, and workover fluids; rig wash, drilling mud slurries, NORM scale, tank bottoms, and other Glass 11 fluids generated from drilling, ~raduction, worlcover and. completion operations. t am writing to request approval to dispose precipitation collected from bermed secondary containment areas associated with. exploration and development in our Westside fields, .such as those around the Brit! rig, any G81 facility, drilling material storage areas, production material storage areas, and well cellars, Please contact me at (907) 263-7308 or by email at bodeauj(c~chevron cQm if you require additional information. Thank you very much for your consideration and assistance. Kest regar S, 1 Je n Bod u tN ste Specialist M)dtontlnent/Alaska 5BU/Chevron Month Amerlea Exploratlon and Production http://www.chevron.cam Bcc: Mr. Gary Ross, Chevron Mr. Evan Harness, Chevron Mr. Larry Greenstein, Chevron • X13 Hilcorp Alaska, LLC 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: 907-777-8300 Fax: 907-777-8580 June 9, 2022 Mr. Chris Wallace, Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Subject: 2021 Annual Disposal Report for Ivan River Unit 13-31 & 14-31 (DIO 35 & 23) Dear Mr. Wallace: In accordance with DIO 35 (Rule 6) and DIO 23 (Rule 4), Hilcorp Alaska, LLC hereby submits the annual disposal report for Ivan River Unit 13-31 (PTD # 192-088) and Ivan River Unit 14-31 (PTD # 175-008) for the year 2021. Surveillance Summary Both IRU 13-31 and IRU 14-31 were used for disposal operations in 2021. Injection and annuli pressures indicate no mechanical concerns. All indications from the injection rates and pressures are that the injected fluid is contained to the approved disposal zone. Specific items to note for this reporting period (applicable to both 14-31 and 13- 31): • The biennial MIT’s will be performed in June 2022. • The regulatory limit of 4.0 bpm and 5000 psi were not exceeded. • Maximum injection pressure in either well was below 2000 psi. • In 2021, the fluids injected into IRU 14-31 (1811 bbls) and IRU 13-31 (3216 bbls) were produced water from the Ivan River, Pretty Creek, and Lewis River fields. Should you have questions, please contact Chris Stone at 777-8378 or Josh Allely at 777-8505. Sincerely, Chris Stone Reservoir Engineer Date Tubing IA OA Water Injection 12/31/2021 0 0 0 30 12/30/2021 0 0 0 27 12/29/2021 0 0 0 37 12/28/2021 0 0 0 0 12/27/2021 1088 0 0 41 12/26/2021 1140 0 0 33 12/25/2021 1120 0 0 30 12/24/2021 1124 0 0 47 12/23/2021 1115 0 0 40 12/22/2021 0 0 0 0 12/21/2021 1118 0 0 29.3 12/20/2021 1050 0 0 25.2 12/19/2021 1053 0 0 31.31 12/18/2021 1149 0 0 33.3 12/17/2021 1190 0 0 26.3 12/16/2021 1206 0 0 38.6 12/15/2021 16 0 0 0 12/14/2021 1251 0 0 66.3 12/13/2021 879 0 0 10 12/12/2021 1159 0 0 26.4 12/11/2021 1203 0 0 28.5 12/10/2021 14 0 0 0 12/9/2021 12 0 0 0 12/8/2021 11 0 0 0 12/7/2021 1517 0 0 121.2 12/6/2021 1120 0 0 16 12/5/2021 1120 0 0 20 12/4/2021 1183 0 0 31.7 Date Range: 01/01/2021 - 12/31/2021 Well: IRU 14-31 Desc: Disposal Permit to drill: 1750080 Admin Approval: DIO #23 API: 50-283-20045-00-00 12/3/2021 1079 0 0 18 12/2/2021 5 0 0 0 12/1/2021 7 0 0 0 11/30/2021 1105 0 0 38 11/29/2021 1 0 0 0 11/28/2021 1092 0 0 29 11/27/2021 188 100 0 42.2 11/26/2021 12 0 0 0 11/25/2021 1095 0 0 29.5 11/24/2021 0 0 0 0 11/23/2021 1080 0 0 21 11/22/2021 1127 0 0 18.2 11/21/2021 1067 0 0 21.2 11/20/2021 1096 0 0 29.5 11/19/2021 1138 0 0 25.1 11/18/2021 1078 0 0 24 11/17/2021 1162 0 0 34 11/16/2021 0 0 0 0 11/15/2021 0 0 0 0 11/14/2021 1050 0 0 35 11/13/2021 11 0 0 0 11/12/2021 1139 0 0 30 11/11/2021 16 0 0 0 11/10/2021 12 0 0 0 11/9/2021 1017 0 0 57 11/8/2021 11 0 0 0 11/7/2021 1185 0 0 29 11/6/2021 0 0 0 0 11/5/2021 0 0 0 0 11/4/2021 0 0 0 0 11/3/2021 0 0 0 0 11/2/2021 0 0 0 0 11/1/2021 0 0 0 0 10/31/2021 0 0 0 0 10/30/2021 0 0 0 0 10/29/2021 0 0 0 0 10/28/2021 0 0 0 0 10/27/2021 0 0 0 0 10/26/2021 0 0 0 0 10/25/2021 0 0 0 0 10/24/2021 0 0 0 0 10/23/2021 0 0 0 0 10/22/2021 0 0 0 0 10/21/2021 0 0 0 0 10/20/2021 0 0 0 0 10/19/2021 0 0 0 0 10/18/2021 0 0 0 0 10/17/2021 0 0 0 0 10/16/2021 0 0 0 0 10/15/2021 0 0 0 0 10/14/2021 0 0 0 0 10/13/2021 0 0 0 0 10/12/2021 0 0 0 0 10/11/2021 0 0 0 0 10/10/2021 0 0 0 0 10/9/2021 0 0 0 0 10/8/2021 0 0 0 0 10/7/2021 0 0 0 0 10/6/2021 0 0 0 0 10/5/2021 0 0 0 0 10/4/2021 0 0 0 0 10/3/2021 0 0 0 0 10/2/2021 0 0 0 0 10/1/2021 0 0 0 0 9/30/2021 0 0 0 0 9/29/2021 0 0 0 0 9/28/2021 0 0 0 0 9/27/2021 0 0 0 0 9/26/2021 0 0 0 0 9/25/2021 0 0 0 0 9/24/2021 0 0 0 0 9/23/2021 0 0 0 0 9/22/2021 0 0 0 0 9/21/2021 0 0 0 0 9/20/2021 0 0 0 0 9/19/2021 0 0 0 0 9/18/2021 0 0 0 0 9/17/2021 0 0 0 0 9/16/2021 0 0 0 0 9/15/2021 0 0 0 0 9/14/2021 0 0 0 0 9/13/2021 0 0 0 0 9/12/2021 0 0 0 0 9/11/2021 0 0 0 0 9/10/2021 0 0 0 0 9/9/2021 15 0 0 0 9/8/2021 15 0 0 0 9/7/2021 15 0 0 0 9/6/2021 15 0 0 0 9/5/2021 15 0 0 0 9/4/2021 15 0 0 0 9/3/2021 15 0 0 0 9/2/2021 0 0 0 0 9/1/2021 0 0 0 0 8/31/2021 0 0 0 0 8/30/2021 0 0 0 0 8/29/2021 0 0 0 0 8/28/2021 0 0 0 0 8/27/2021 0 0 0 0 8/26/2021 0 0 0 0 8/25/2021 0 0 0 0 8/24/2021 15 0 0 0 8/23/2021 15 0 0 0 8/22/2021 15 0 0 0 8/21/2021 14 0 0 0 8/20/2021 14 0 0 0 8/19/2021 14 0 0 0 8/18/2021 14 0 0 0 8/17/2021 14 0 0 0 8/16/2021 14 0 0 0 8/15/2021 14 0 0 0 8/14/2021 14 0 0 0 8/13/2021 14 0 0 0 8/12/2021 14 0 0 0 8/11/2021 14 0 0 0 8/10/2021 14 0 0 0 8/9/2021 14 0 0 0 8/8/2021 14 0 0 0 8/7/2021 13 0 0 0 8/6/2021 14 0 0 0 8/5/2021 15 0 0 0 8/4/2021 15 0 0 0 8/3/2021 12 0 0 0 8/2/2021 12 0 0 0 8/1/2021 12 0 0 0 7/31/2021 890 0 0 74 7/30/2021 1200 0 0 127 7/29/2021 0 0 0 0 7/28/2021 1289 0 0 39 7/27/2021 18 0 0 0 7/26/2021 19 0 0 0 7/25/2021 18 0 0 0 7/24/2021 18 0 0 0 7/23/2021 18 0 0 0 7/22/2021 18 0 0 0 7/21/2021 18 0 0 0 7/20/2021 16 0 0 0 7/19/2021 16 0 0 0 7/18/2021 16 0 0 0 7/17/2021 16 0 0 0 7/16/2021 16 0 0 0 7/15/2021 16 0 0 0 7/14/2021 16 0 0 0 7/13/2021 15 0 0 0 7/12/2021 15 0 0 0 7/11/2021 14 0 0 0 7/10/2021 7 0 0 0 7/9/2021 1096 0 0 32 7/8/2021 1130 0 0 60 7/7/2021 1160 0 0 84 7/6/2021 1110 0 0 70 7/5/2021 26 0 0 0 7/4/2021 26 0 0 0 7/3/2021 27 0 0 0 7/2/2021 27 0 0 0 7/1/2021 27 0 0 0 6/30/2021 27 0 0 0 6/29/2021 27 0 0 0 6/28/2021 27 0 0 0 6/27/2021 27 0 0 0 6/26/2021 27 0 0 0 6/25/2021 27 0 0 0 6/24/2021 27 0 0 0 6/23/2021 27 0 0 0 6/22/2021 27 0 0 0 6/21/2021 27 0 0 0 6/20/2021 27 0 0 0 6/19/2021 27 0 0 0 6/18/2021 27 0 0 0 6/17/2021 27 0 0 0 6/16/2021 25 0 0 0 6/15/2021 27 0 0 0 6/14/2021 27 0 0 0 6/13/2021 27 0 0 0 6/12/2021 27 0 0 0 6/11/2021 27 0 0 0 6/10/2021 27 0 0 0 6/9/2021 26 0 0 0 6/8/2021 27 0 0 0 6/7/2021 27 0 0 0 6/6/2021 27 0 0 0 6/5/2021 27 0 0 0 6/4/2021 26 0 0 0 6/3/2021 26 0 0 0 6/2/2021 26 0 0 0 6/1/2021 26 0 0 0 5/31/2021 26 0 0 0 5/30/2021 27 0 0 0 5/29/2021 26 0 0 0 5/28/2021 26 0 0 0 5/27/2021 25 0 0 0 5/26/2021 25 0 0 0 5/25/2021 25 0 0 0 5/24/2021 25 0 0 0 5/23/2021 25 0 0 0 5/22/2021 24 0 0 0 5/21/2021 24 0 0 0 5/20/2021 22 0 0 0 5/19/2021 19 0 0 0 5/18/2021 28 0 0 0 5/17/2021 27 0 0 0 5/16/2021 28 0 0 0 5/15/2021 28 0 0 0 5/14/2021 28 0 0 0 5/13/2021 28 0 0 0 5/12/2021 28 0 0 0 5/11/2021 28 0 0 0 5/10/2021 28 0 0 0 5/9/2021 28 0 0 0 5/8/2021 27 0 0 0 5/7/2021 27 0 0 0 5/6/2021 27 0 0 0 5/5/2021 27 0 0 0 5/4/2021 27 0 0 0 5/3/2021 27 0 0 0 5/2/2021 25 0 0 0 5/1/2021 23 0 0 0 4/30/2021 1116 0 0 40 4/29/2021 48 0 0 0 4/28/2021 48 0 0 0 4/27/2021 48 0 0 0 4/26/2021 47 0 0 0 4/25/2021 47 0 0 0 4/24/2021 47 0 0 0 4/23/2021 47 0 0 0 4/22/2021 48 0 0 0 4/21/2021 48 0 0 0 4/20/2021 48 0 0 0 4/19/2021 48 0 0 0 4/18/2021 48 0 0 0 4/17/2021 48 0 0 0 4/16/2021 48 0 0 0 4/15/2021 48 0 0 0 4/14/2021 48 0 0 0 4/13/2021 48 0 0 0 4/12/2021 48 0 0 0 4/11/2021 48 0 0 0 4/10/2021 47 0 0 0 4/9/2021 49 0 0 0 4/8/2021 48 0 0 0 4/7/2021 47 0 0 0 4/6/2021 47 0 0 0 4/5/2021 47 0 0 0 4/4/2021 48 0 0 0 4/3/2021 48 0 0 0 4/2/2021 47 0 0 0 4/1/2021 48 0 0 0 3/31/2021 48 0 0 0 3/30/2021 48 0 0 0 3/29/2021 48 0 0 0 3/28/2021 47 0 0 0 3/27/2021 48 0 0 0 3/26/2021 48 0 0 0 3/25/2021 48 0 0 0 3/24/2021 48 0 0 0 3/23/2021 48 0 0 0 3/22/2021 48 0 0 0 3/21/2021 48 0 0 0 3/20/2021 48 0 0 0 3/19/2021 48 0 0 0 3/18/2021 48 0 0 0 3/17/2021 47 0 0 0 3/16/2021 48 0 0 0 3/15/2021 48 0 0 0 3/14/2021 47 0 0 0 3/13/2021 47 0 0 0 3/12/2021 47 0 0 0 3/11/2021 48 0 0 0 3/10/2021 48 0 0 0 3/9/2021 48 0 0 0 3/8/2021 48 0 0 0 3/7/2021 48 0 0 0 3/6/2021 48 0 0 0 3/5/2021 48 0 0 0 3/4/2021 48 0 0 0 3/3/2021 48 0 0 0 3/2/2021 48 0 0 0 3/1/2021 49 0 0 0 2/28/2021 48 0 0 0 2/27/2021 48 0 0 0 2/26/2021 48 0 0 0 2/25/2021 49 0 0 0 2/24/2021 48 0 0 0 2/23/2021 48 0 0 0 2/22/2021 48 0 0 0 2/21/2021 48 0 0 0 2/20/2021 48 0 0 0 2/19/2021 48 0 0 0 2/18/2021 48 0 0 0 2/17/2021 48 0 0 0 2/16/2021 47 0 0 0 2/15/2021 47 0 0 0 2/14/2021 47 0 0 0 2/13/2021 45 0 0 0 2/12/2021 45 0 0 0 2/11/2021 43 0 0 0 2/10/2021 1083 0 0 16 2/9/2021 19 0 0 0 2/8/2021 26 0 0 0 2/7/2021 26 0 0 0 2/6/2021 26 0 0 0 2/5/2021 26 0 0 0 2/4/2021 25 0 0 0 2/3/2021 25 0 0 0 2/2/2021 25 0 0 0 2/1/2021 25 0 0 0 1/31/2021 25 0 0 0 1/30/2021 26 0 0 0 1/29/2021 26 0 0 0 1/28/2021 26 0 0 0 1/27/2021 25 0 0 0 1/26/2021 25 0 0 0 1/25/2021 26 0 0 0 1/24/2021 26 0 0 0 1/23/2021 26 0 0 0 1/22/2021 26 0 0 0 1/21/2021 26 0 0 0 1/20/2021 26 0 0 0 1/19/2021 26 0 0 0 1/18/2021 26 0 0 0 1/17/2021 25 0 0 0 1/16/2021 25 0 0 0 1/15/2021 25 0 0 0 1/14/2021 25 0 0 0 1/13/2021 25 0 0 0 1/12/2021 25 0 0 0 1/11/2021 25 0 0 0 1/10/2021 25 0 0 0 1/9/2021 25 0 0 0 1/8/2021 25 0 0 0 1/7/2021 25 0 0 0 1/6/2021 25 0 0 0 1/5/2021 25 0 0 0 1/4/2021 25 0 0 0 1/3/2021 25 0 0 0 1/2/2021 25 0 0 0 1/1/2021 26 0 0 0 Date Tubing IA OA OOA Water Injection 12/31/2021 0 180 0 0 0 12/30/2021 0 180 0 0 0 12/29/2021 0 190 0 0 0 12/28/2021 0 190 0 0 0 12/27/2021 0 190 0 0 0 12/26/2021 0 190 0 0 0 12/25/2021 0 190 0 0 0 12/24/2021 0 190 0 0 0 12/23/2021 0 190 0 0 0 12/22/2021 0 190 0 0 0 12/21/2021 0 180 0 0 0 12/20/2021 0 180 0 0 0 12/19/2021 0 180 0 0 0 12/18/2021 0 180 0 0 0 12/17/2021 0 180 0 0 0 12/16/2021 0 180 0 0 0 12/15/2021 0 180 0 0 0 12/14/2021 0 180 0 0 0 12/13/2021 0 180 0 0 0 12/12/2021 0 180 0 0 0 12/11/2021 0 180 0 0 0 12/10/2021 0 180 0 0 0 12/9/2021 0 180 0 0 0 12/8/2021 0 180 0 0 0 12/7/2021 0 180 0 0 0 12/6/2021 0 180 0 0 0 12/5/2021 0 180 0 0 0 12/4/2021 0 180 0 0 0 Date Range: 01/01/2021 - 12/31/2021 Well: IRU 13-31 Desc: Disposal Permit to drill: 1920880 Admin Approval: DIO #35 API: 50-283-20086-00-00 12/3/2021 0 180 0 0 0 12/2/2021 0 180 0 0 0 12/1/2021 0 180 0 0 0 11/30/2021 0 180 0 0 0 11/29/2021 0 180 0 0 0 11/28/2021 0 185 0 0 0 11/27/2021 0 185 0 0 0 11/26/2021 0 185 0 0 0 11/25/2021 0 185 0 0 0 11/24/2021 0 200 0 0 0 11/23/2021 0 200 0 0 0 11/22/2021 0 200 0 0 0 11/21/2021 0 200 0 0 0 11/20/2021 0 200 0 0 0 11/19/2021 0 200 0 0 0 11/18/2021 0 200 0 0 0 11/17/2021 0 200 0 0 0 11/16/2021 0 200 0 0 0 11/15/2021 0 200 0 0 0 11/14/2021 0 200 0 0 0 11/13/2021 0 200 0 0 0 11/12/2021 0 200 0 0 0 11/11/2021 0 220 0 0 0 11/10/2021 0 220 0 0 0 11/9/2021 0 220 0 0 0 11/8/2021 0 220 0 0 0 11/7/2021 0 220 0 0 29 11/6/2021 0 220 0 23 11/5/2021 0 220 0 0 17 11/4/2021 1 220 0 0 39.2 11/3/2021 1 220 0 0 36.1 11/2/2021 2 220 0 0 43.3 11/1/2021 1 220 0 0 38.6 10/31/2021 1 220 0 0 0 10/30/2021 1 220 0 0 0 10/29/2021 1259 220 0 0 67.8 10/28/2021 0 220 0 0 0 10/27/2021 0 220 0 0 40.5 10/26/2021 0 220 0 0 0 10/25/2021 1487 220 0 0 59 10/24/2021 0 220 0 0 0 10/23/2021 1521 220 0 0 30 10/22/2021 1449 220 0 0 35.3 10/21/2021 0 220 0 0 0 10/20/2021 0 220 0 0 0 10/19/2021 28 220 0 0 0 10/18/2021 1452 220 0 0 27 10/17/2021 1512 220 0 0 30.7 10/16/2021 0 220 0 0 0 10/15/2021 1436 220 0 0 27 10/14/2021 0 220 0 0 0 10/13/2021 1440 220 0 0 16.2 10/12/2021 1420 240 0 0 21 10/11/2021 1518 240 0 0 36.7 10/10/2021 0 200 0 0 0 10/9/2021 0 200 0 0 0 10/8/2021 0 200 0 0 0 10/7/2021 16 200 0 0 0 10/6/2021 1409 200 0 0 95 10/5/2021 1426 200 0 0 66 10/4/2021 1509 200 0 0 129 10/3/2021 28 200 0 0 0 10/2/2021 28 200 0 0 8 10/1/2021 30 200 0 0 28 9/30/2021 0 225 0 0 0 9/29/2021 0 225 0 0 0 9/28/2021 0 225 0 0 25.9 9/27/2021 0 225 0 0 13.6 9/26/2021 0 225 0 0 12.5 9/25/2021 1635 225 0 0 79.6 9/24/2021 0 220 0 0 26 9/23/2021 0 186 0 0 0 9/22/2021 1620 220 0 0 78 9/21/2021 1750 220 0 0 71 9/20/2021 1500 220 0 0 259 9/19/2021 1485 220 0 0 26 9/18/2021 0 220 0 0 0 9/17/2021 0 220 0 0 0 9/16/2021 1535 220 0 0 62.7 9/15/2021 0 220 0 0 16.8 9/14/2021 1543 205 0 0 22.1 9/13/2021 1475 210 0 0 62.2 9/12/2021 1355 200 0 0 27 9/11/2021 1350 210 0 0 21 9/10/2021 0 210 0 0 0 9/9/2021 1350 200 0 0 32 9/8/2021 1385 225 0 0 26.2 9/7/2021 15 205 0 0 0 9/6/2021 5 205 0 0 0 9/5/2021 22 205 0 0 0 9/4/2021 22 210 0 0 0 9/3/2021 22 215 0 0 0 9/2/2021 22 220 0 0 0 9/1/2021 1305 330 0 0 15 8/31/2021 1048 330 0 0 9 8/30/2021 1198 330 0 0 9 8/29/2021 0 330 0 0 0 8/28/2021 1297 325 0 0 11.5 8/27/2021 1382 340 0 0 12 8/26/2021 1382 300 0 0 32 8/25/2021 0 220 0 0 0 8/24/2021 1390 280 0 0 28 8/23/2021 0 215 0 0 0 8/22/2021 0 215 0 0 0 8/21/2021 0 215 0 0 19.7 8/20/2021 0 215 0 0 0 8/19/2021 1300 215 0 0 28.75 8/18/2021 1299 210 0 0 36 8/17/2021 1329 210 0 0 9.6 8/16/2021 1357 215 0 0 16.8 8/15/2021 129 200 0 0 11 8/14/2021 160 185 0 0 17 8/13/2021 129 200 0 0 0 8/12/2021 1329 200 0 0 56 8/11/2021 1345 230 0 0 94 8/10/2021 1423 230 0 0 105 8/9/2021 1470 230 0 0 121 8/8/2021 1410 230 0 0 123 8/7/2021 1140 210 0 0 127 8/6/2021 350 245 0 0 12.8 8/5/2021 1200 200 0 0 117 8/4/2021 1190 200 0 0 121 8/3/2021 1200 200 0 0 80 8/2/2021 1230 200 0 0 42 8/1/2021 1136 200 0 0 82 7/31/2021 0 200 0 0 0 7/30/2021 0 200 0 0 0 7/29/2021 0 200 0 0 0 7/28/2021 0 200 0 0 0 7/27/2021 0 200 0 0 0 7/26/2021 0 200 0 0 0 7/25/2021 0 200 0 0 0 7/24/2021 0 200 0 0 0 7/23/2021 0 200 0 0 0 7/22/2021 0 200 0 0 0 7/21/2021 0 200 0 0 0 7/20/2021 0 200 0 0 0 7/19/2021 0 200 0 0 0 7/18/2021 0 200 0 0 0 7/17/2021 0 200 0 0 0 7/16/2021 0 200 0 0 0 7/15/2021 0 200 0 0 0 7/14/2021 0 200 0 0 0 7/13/2021 0 200 0 0 0 7/12/2021 0 200 0 0 0 7/11/2021 0 200 0 0 0 7/10/2021 0 200 0 0 0 7/9/2021 0 200 0 0 0 7/8/2021 0 200 0 0 0 7/7/2021 0 200 0 0 0 7/6/2021 0 200 0 0 0 7/5/2021 0 200 0 0 0 7/4/2021 0 200 0 0 0 7/3/2021 0 200 0 0 0 7/2/2021 0 200 0 0 0 7/1/2021 0 200 0 0 0 6/30/2021 0 200 0 0 0 6/29/2021 0 200 0 0 0 6/28/2021 0 200 0 0 0 6/27/2021 0 200 0 0 0 6/26/2021 1300 220 0 0 19 6/25/2021 1300 200 0 0 46 6/24/2021 0 200 0 0 0 6/23/2021 0 200 0 0 0 6/22/2021 0 200 0 0 0 6/21/2021 0 200 0 0 0 6/20/2021 0 200 0 0 0 6/19/2021 0 200 0 0 0 6/18/2021 0 200 0 0 0 6/17/2021 0 200 0 0 0 6/16/2021 0 204 0 0 0 6/15/2021 1250 190 0 0 10 6/14/2021 0 190 0 0 0 6/13/2021 0 190 0 0 0 6/12/2021 0 190 0 0 0 6/11/2021 0 190 0 0 0 6/10/2021 0 185 0 0 0 6/9/2021 0 185 0 0 0 6/8/2021 0 185 0 0 0 6/7/2021 0 185 0 0 0 6/6/2021 0 185 0 0 0 6/5/2021 0 185 0 0 0 6/4/2021 0 185 0 0 0 6/3/2021 0 185 0 0 0 6/2/2021 0 185 0 0 0 6/1/2021 0 185 0 0 0 5/31/2021 0 185 0 0 0 5/30/2021 0 185 0 0 0 5/29/2021 0 190 0 0 0 5/28/2021 0 190 0 0 0 5/27/2021 0 190 0 0 0 5/26/2021 0 190 0 0 0 5/25/2021 0 190 0 0 0 5/24/2021 0 190 0 0 0 5/23/2021 0 190 0 0 0 5/22/2021 0 190 0 0 0 5/21/2021 0 190 0 0 0 5/20/2021 0 190 0 0 0 5/19/2021 0 190 0 0 0 5/18/2021 0 190 0 0 0 5/17/2021 0 190 0 0 0 5/16/2021 0 190 0 0 0 5/15/2021 0 190 0 0 0 5/14/2021 0 190 0 0 0 5/13/2021 0 190 0 0 0 5/12/2021 0 190 0 0 0 5/11/2021 0 190 0 0 0 5/10/2021 0 190 0 0 0 5/9/2021 0 190 0 0 0 5/8/2021 0 190 0 0 0 5/7/2021 0 190 0 0 0 5/6/2021 0 190 0 0 0 5/5/2021 0 190 0 0 0 5/4/2021 0 190 0 0 0 5/3/2021 0 190 0 0 0 5/2/2021 0 190 0 0 0 5/1/2021 0 190 0 0 0 4/30/2021 0 190 0 0 0 4/29/2021 0 183 0 0 0 4/28/2021 0 183 0 0 0 4/27/2021 0 183 0 0 0 4/26/2021 0 185 0 0 0 4/25/2021 0 185 0 0 0 4/24/2021 0 185 0 0 0 4/23/2021 0 185 0 0 0 4/22/2021 0 0 0 0 4/21/2021 0 185 0 0 0 4/20/2021 0 185 0 0 0 4/19/2021 0 185 0 0 0 4/18/2021 0 180 0 0 0 4/17/2021 0 180 0 0 0 4/16/2021 0 180 0 0 0 4/15/2021 0 190 0 0 0 4/14/2021 0 190 0 0 0 4/13/2021 0 190 0 0 0 4/12/2021 0 190 0 0 0 4/11/2021 0 190 0 0 0 4/10/2021 0 190 0 0 0 4/9/2021 0 190 0 0 0 4/8/2021 0 190 0 0 0 4/7/2021 0 190 0 0 0 4/6/2021 0 190 0 0 0 4/5/2021 0 190 0 0 0 4/4/2021 0 190 0 0 0 4/3/2021 0 190 0 0 0 4/2/2021 0 190 0 0 0 4/1/2021 0 190 0 0 0 3/31/2021 0 190 0 0 0 3/30/2021 0 190 0 0 0 3/29/2021 0 190 0 0 0 3/28/2021 0 190 0 0 0 3/27/2021 0 190 0 0 0 3/26/2021 0 190 0 0 0 3/25/2021 0 190 0 0 0 3/24/2021 0 190 0 0 0 3/23/2021 0 190 0 0 0 3/22/2021 0 190 0 0 0 3/21/2021 0 190 0 0 0 3/20/2021 0 190 0 0 0 3/19/2021 0 190 0 0 0 3/18/2021 0 190 0 0 0 3/17/2021 0 190 0 0 0 3/16/2021 0 190 0 0 0 3/15/2021 0 190 0 0 0 3/14/2021 0 190 0 0 0 3/13/2021 0 190 0 0 0 3/12/2021 0 190 0 0 0 3/11/2021 0 190 0 0 0 3/10/2021 0 190 0 0 0 3/9/2021 0 190 0 0 0 3/8/2021 0 190 0 0 0 3/7/2021 0 190 0 0 0 3/6/2021 0 190 0 0 0 3/5/2021 0 190 0 0 0 3/4/2021 0 190 0 0 0 3/3/2021 0 190 0 0 0 3/2/2021 0 190 0 0 0 3/1/2021 0 190 0 0 0 2/28/2021 0 190 0 0 0 2/27/2021 0 190 0 0 0 2/26/2021 0 190 0 0 0 2/25/2021 0 190 0 0 0 2/24/2021 0 190 0 0 0 2/23/2021 0 190 0 0 0 2/22/2021 0 190 0 0 0 2/21/2021 0 190 0 0 0 2/20/2021 0 190 0 0 0 2/19/2021 0 190 0 0 0 2/18/2021 0 190 0 0 0 2/17/2021 0 190 0 0 0 2/16/2021 0 190 0 0 0 2/15/2021 0 190 0 0 0 2/14/2021 0 190 0 0 0 2/13/2021 0 190 0 0 0 2/12/2021 0 190 0 0 0 2/11/2021 0 190 0 0 0 2/10/2021 0 200 4 0 0 2/9/2021 0 200 4 0 0 2/8/2021 0 200 4 0 0 2/7/2021 0 200 4 0 0 2/6/2021 0 200 4 0 0 2/5/2021 0 190 0 0 0 2/4/2021 0 190 0 0 0 2/3/2021 0 190 0 0 0 2/2/2021 0 190 0 0 0 2/1/2021 0 190 0 0 0 1/31/2021 0 190 0 0 0 1/30/2021 0 190 0 0 0 1/29/2021 0 190 0 0 0 1/28/2021 0 190 0 0 0 1/27/2021 0 190 0 0 0 1/26/2021 0 190 0 0 0 1/25/2021 0 190 0 0 0 1/24/2021 0 190 0 0 0 1/23/2021 0 190 0 0 0 1/22/2021 0 190 0 0 0 1/21/2021 0 190 0 0 0 1/20/2021 0 190 0 0 0 1/19/2021 0 190 0 0 0 1/18/2021 0 190 0 0 0 1/17/2021 0 190 0 0 0 1/16/2021 0 190 0 0 0 1/15/2021 0 190 0 0 0 1/14/2021 0 190 0 0 0 1/13/2021 0 190 0 0 0 1/12/2021 0 190 0 0 0 1/11/2021 0 190 0 0 0 1/10/2021 0 190 0 0 0 1/9/2021 0 190 0 0 0 1/8/2021 0 190 0 0 0 1/7/2021 0 190 0 0 0 1/6/2021 0 190 0 0 0 1/5/2021 0 190 0 0 0 1/4/2021 0 190 0 0 0 1/3/2021 0 190 0 0 0 1/2/2021 0 190 0 0 0 1/1/2021 0 190 0 0 0 Hilcorp Alaska, LLC Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 100 Anchorage, AK 99503 July 2, 2019 Phone: 907/777-8322 Fax: 907/777-8580 Mr. Hollis S. French, Chair E '— p , ED Alaska Oil & Gas Conservation Commission 333 W. 71' Avenue, Suite 100 JUL 9 2 201g Anchorage, Alaska 99501-3539 Re: 2018 Annual Disposal Report for the 13-31 & 14-31 Wells in the Ivan River Unit Dear Mr. French, This is the 2018 Annual Report for the UIC Class II disposal operation in the IRU 13-31 (DIO 35) and IRU 14-31 (DIO 23) wellbores. The attached plots shows that injection rates and pressures for both wells were well below the regulatory limit of 4 barrels per minute and 5000psig. Furthermore, injection and annuli Pressures indicate no mechanical concerns and that the injected fluid was contained to the approved disposal zone. Specific items to note for this reporting period: • A MIT is required every two years and the last MIT was performed 5-20-18. • In 2018, the fluids injected into the IRU 13-31 and 14-31 (17,525 and 10,991 barrels, respectively) wells were produced water from the Ivan River, Pretty Creek, and Lewis River fields. • Maximum pressures in both wells during injection never exceeded 2,000 psig. Sincerely, �t&4 ��tt Trudi Hallett Reservoir Engineer Attachment 1 — IRU 13-31 Injection rates and pressures Attachment 2 — IRU 14-31 Injection rates and pressures 1500 1000- +mi IRU 014-31 WDW 01/2016 02/2018 03/2018 04/2018 05/2018 06/2018 07/2018 08/2018 09/2018 10/2018 11/2018 12/2018 —Tubing — IA — OA OOA — Water Injection ME 500 mi 300 200 100 Well: IRU 14-31 Desc: Disposal Permit to drill: 1750080 Admin Approval: DID #23 API: 50-283-20045-00-00 Date Range: 01/01/2018 - 12/31/2018 Date Tubing IA OA ODA Water Injection 12/31/2018 43 100 15 0 12/30/2018 43 100 15 0 12/29/2018 43 153 15 0 12/28/2018 43 153 15 0 12/27/2018 43 153 15 0 12/26/2018 41 153 15 0 12/25/2018 37 197 15 0 12/24/2018 28 296 15 0 12/23/2018 1365 637.9 15 219 12/22/2018 34 386 15 0 12/21/2018 1350 780 15 123 12/20/2018 1329 120 16 246 12/19/2018 1388 110 16 265 12/18/2018 1020 110 16 240 12/17/2018 1010 110 16 270 12/16/2018 1020 110 16 212 12/15/2018 1120 110 16 198 12/14/2018 1108 220 16 240 12/13/2018 1120 220 16 265 12/12/2018 1090 220 15 310 12/11/2018 897 220 15 300 12/10/2018 995 220 15 270 12/9/2018 30 220 15 0 12/8/2018 35 220 15 0 12/7/2018 26 220 15 0 12/6/2018 1055 220 15 310 12/5/2018 1095 220 15 300 12/4/2018 1080 180 380 12/3/2018 1086 180 240 12/2/2018 1086 180 220 12/1/2018 1060 180 80 11/30/2018 1080 180 300 11/29/2018 1180 180 360 11/28/2018 1120 180 310 11/27/2018 1300 180 260 11/26/2018 1065 180 300 11/25/2018 30 180 70 11/24/2018 1100 180 0 70 11/23/2018 1160 180 0 410 11/22/2018 0 180 0 0 11/21/2018 0 180 0 0 11/20/2018 0 180 0 0 11/19/2018 0 180 0 0 11/18/2018 5 180 0 0 11/17/2018 5 180 0 0 11/16/2018 5 180 0 0 11/15/2018 5 180 0 0 11/14/2018 5 180 0 0 11/13/2018 5 180 0 11/12/2018 5 180 0 11/11/2018 5 180 0 11/10/2018 4 180 0 0 11/9/2018 2 180 0 0 11/8/2018 30 180 0 0 11/7/2018 30 180 0 0 11/6/2018 30 180 0 0 11/5/2018 30 180 0 0 11/4/2018 30 180 0 0 11/3/2018 30 180 0 0 11/2/2018 30 180 0 0 11/1/2018 30 180 0 0 10/31/2018 30 180 0 0 10/30/2018 30 180 0 296 10/29/2018 30 180 0 0 10/28/2018 1200 180 0 253 10/27/2018 1175 180 0 403 10/26/2018 1077 180 0 436 10/25/2018 1168 180 0 307 10/24/2018 1254 180 0 416 10/23/2018 1074 180 0 345 10/22/2018 1064 180 240 10/21/2018 1046 180 155 10/20/2018 1020 180 244 10/19/2018 1120 180 295 10/18/2018 1050 180 185 10/17/2018 780 180 40 10/16/2018 780 180 100 10/15/2018 47 180 0 10/14/2018 47 180 0 0 10/13/2018 47 180 0 0 10/12/2018 47 180 0 0 10/11/2018 47 180 0 0 10/10/2018 48 180 0 0 10/9/2018 48 180 0 0 10/8/2018 48 180 0 10/7/2018 48 180 0 10/6/2018 48 180 0 10/5/2018 48 180 0 10/4/2018 48 180 0 10/3/2018 48 180 0 10/2/2018 48 180 0 10/1/2018 48 180 0 9/30/2018 48 180 0 9/29/2018 48 180 0 9/28/2018 48 180 0 9/27/2018 48 180 0 9/26/2018 48 180 0 9/25/2018 48 180 0 9/24/2018 48 180 0 9/23/2018 48 180 0 9/22/2018 48 180 0 9/21/2018 48 180 0 9/20/2018 48 180 0 9/19/2018 48 180 0 9/18/2018 47 180 0 0 9/17/2018 47 180 0 0 9/16/2018 47 180 0 0 9/15/2018 47 180 0 0 9/14/2018 47 180 0 0 9/13/2018 47 180 0 0 9/12/2018 47 180 0 0 9/11/2018 47 180 0 0 9/10/2018 47 180 0 0 9/9/2018 47 180 0 0 9/8/2018 47 180 0 0 9/7/2018 47 180 0 0 9/6/2018 47 180 0 0 9/5/2018 47 180 0 0 9/4/2018 47 180 0 9/3/2018 47 180 0 9/2/2018 46 180 0 9/1/2018 47 180 0 8/31/2018 47 180 0 8/30/2018 47 180 0 8/29/2018 47 180 0 0 8/28/2018 48 178 0 8/27/2018 48 180 0 8/26/2018 48 180 0 8/25/2018 48 180 0 0 8/24/2018 48 180 0 8/23/2018 47 180 0 8/22/2018 47 180 0 0 8/21/2018 47 180 0 0 8/20/2018 47 180 0 0 8/19/2018 47 180 0 0 8/18/2018 47 180 0 0 8/17/2018 47 180 0 0 8/16/2018 47 180 0 0 8/15/2018 47 180 0 0 8/14/2018 47 180 0 0 8/13/2018 48 180 0 0 8/12/2018 48 180 0 0 8/11/2018 47 180 0 0 8/10/2018 47 180 0 0 8/9/2018 47 180 0 0 8/8/2018 47 180 0 0 8/7/2018 47 180 0 0 8/6/2018 47 180 0 0 8/5/2018 47 180 0 0 8/4/2018 47 180 0 0 8/3/2018 47 180 0 0 8/2/2018 47 185 0 0 8/1/2018 47 185 0 0 7/31/2018 47 180 0 0 7/30/2018 47 180 0 0 7/29/2018 47 180 0 0 7/28/2018 47 180 0 0 7/27/2018 47 180 0 0 7/26/2018 47 180 0 0 7/25/2018 47 180 0 0 7/24/2018 47 180 0 0 7/23/2018 47 180 0 0 7/22/2018 47 180 0 0 7/21/2018 47 180 0 0 7/20/2018 47 180 0 0 7/19/2018 47 180 0 0 7/18/2018 47 180 0 0 7/17/2018 48 180 0 7/16/2018 48 180 0 7/15/2018 48 180 0 7/14/2018 48 180 0 7/13/2018 48 180 0 7/12/2018 48 180 0 7/11/2018 48 180 0 7/10/2018 48 180 0 7/9/2018 47 180 0 7/8/2018 47 180 0 7/7/2018 50 180 0 7/6/2018 50 180 0 7/5/2018 50 180 0 7/4/2018 48 180 0 0 7/3/2018 48 180 0 7/2/2018 47 180 0 7/1/2018 47 180 0 6/30/2018 47 180 0 6/29/2018 47 180 0 6/28/2018 47 180 0 6/27/2018 47 180 0 0 6/26/2018 47 180 0 0 6/25/2018 47 180 0 0 6/24/2018 47 180 0 0 6/23/2018 47 180 0 0 6/22/2018 47 180 0 0 6/21/2018 47 180 0 0 6/20/2018 47 180 0 0 6/19/2018 47 180 0 0 6/18/2018 47 180 0 0 6/17/2018 47 180 0 0 6/16/2018 47 180 0 0 6/15/2018 47 180 0 0 6/14/2018 47 180 0 0 6/13/2018 47 180 0 0 6/12/2018 47 180 0 0 6/11/2018 47 180 0 0 6/10/2018 47 180 0 0 6/9/2018 47 180 0 0 6/8/2018 47 180 0 0 6/7/2018 47 180 0 6/6/2018 47 180 0 6/5/2018 47 180 0 6/4/2018 47 180 0 6/3/2018 47 180 0 6/2/2018 47 180 0 6/1/2018 47 180 0 5/31/2018 47 180 0 5/30/2018 47 180 0 5/29/2018 47 180 0 5/28/2018 47 170 0 5/27/2018 47 170 0 5/26/2018 47 170 0 5/25/2018 47 170 0 5/24/2018 47 170 0 5/23/2018 46 170 0 5/22/2018 48 170 0 5/21/2018 48 170 0 5/20/2018 48 80 0 5/19/2018 48 78 0 5/18/2018 42 78 0 5/17/2018 42 78 0 5/16/2018 42 78 0 5/15/2018 42 95 0 0 5/14/2018 42 95 0 0 5/13/2018 42 95 0 0 5/12/2018 42 95 0 0 5/11/2018 42 95 0 0 5/10/2018 42 95 0 0 5/9/2018 42 95 0 0 5/8/2018 42 95 0 0 5/7/2018 42 95 0 0 5/6/2018 42 95 0 0 5/5/2018 42 95 0 0 5/4/2018 42 90 0 0 5/3/2018 42 90 0 0 5/2/2018 42 80 0 0 5/1/2018 42 80 0 0 4/30/2018 941 80 0 55 4/29/2018 45 80 0 0 4/28/2018 42 80 0 0 4/27/2018 37 80 0 0 4/26/2018 1015 80 0 64 4/25/2018 36 80 0 0 4/24/2018 950 80 0 0 4/23/2018 960 80 0 0 4/22/2018 47 80 0 0 4/21/2018 47 80 0 0 4/20/2018 45 80 0 0 4/19/2018 42 80 0 0 4/18/2018 1076 100 0 33 4/17/2018 1011 100 0 20 4/16/2018 47 95 0 0 4/15/2018 46 95 0 0 4/14/2018 46 95 0 0 4/13/2018 70 95 0 0 4/12/2018 1250 95 0 33 4/11/2018 58 95 0 0 4/10/2018 58 95 0 0 4/9/2018 102 95 0 0 4/8/2018 1111 95 0 33 4/7/2018 60 95 0 0 4/6/2018 44 95 0 17 4/5/2018 44 95 0 0 4/4/2018 43 95 0 0 4/3/2018 43 95 0 0 4/2/2018 43 95 0 0 4/1/2018 42 95 0 0 3/31/2018 42 95 0 0 3/30/2018 40 95 0 0 3/29/2018 35 95 0 0 3/28/2018 38 96 21 3/27/2018 38 96 0 3/26/2018 38 96 0 3/25/2018 38 96 0 3/24/2018 38 96 0 3/23/2018 38 96 0 3/22/2018 38 95 0 3/21/2018 38 95 0 0 3/20/2018 39 95 0 0 3/19/2018 39 95 0 0 3/18/2018 38 95 0 0 3/17/2018 37 95 0 0 3/16/2018 34 95 0 0 3/15/2018 34 95 0 0 3/14/2018 33 95 0 0 3/13/2018 30 95 0 0 3/12/2018 1166 95 0 12 3/11/2018 1622 95 0 43 3/10/2018 22 95 0 14 3/9/2018 22 95 0 0 3/8/2018 21 95 0 0 3/7/2018 20 95 0 0 3/6/2018 1014 95 0 19 3/5/2018 1079 95 0 53 3/4/2018 22 95 0 0 3/3/2018 1120 95 0 19 3/2/2018 51 95 0 23 3/1/2018 49 100 0 0 2/28/2018 45 100 0 0 2/27/2018 1332 100 0 18 2/26/2018 57 100 0 0 2/25/2018 57 100 0 0 2/24/2018 57 100 0 0 2/23/2018 57 100 0 0 2/22/2018 57 100 0 0 2/21/2018 57 100 0 0 2/20/2018 56 100 0 0 2/19/2018 56 100 0 0 2/18/2018 56 100 0 0 2/17/2018 56 100 0 0 2/16/2018 55 100 0 2/15/2018 55 100 0 2/14/2018 50 100 0 2/13/2018 50 100 0 2/12/2018 50 100 0 2/11/2018 50 100 0 2/10/2018 50 100 0 2/9/2018 50 100 0 2/8/2018 53 100 0 2/7/2018 53 100 0 0 2/6/2018 53 100 0 0 2/5/2018 53 100 0 0 2/4/2018 1540 100 0 0 2/3/2018 63 100 0 0 2/2/2018 62 100 0 0 2/1/2018 62 100 0 0 1/31/2018 62 100 0 0 1/30/2018 62 100 0 0 1/29/2018 62 100 0 0 1/28/2018 62 100 0 0 1/27/2018 62 100 0 0 1/26/2018 60 90 0 1/25/2018 60 90 0 1/24/2018 60 90 0 0 0 1/23/2018 61 90 0 0 0 1/22/2018 61 90 0 0 0 1/21/2018 61 90 0 0 0 1/20/2018 60 90 0 0 0 1/19/2018 60 90 0 0 0 1/18/2018 60 90 0 0 0 1/17/2018 59 90 0 0 0 1/16/2018 56 90 0 0 0 1/15/2018 1109 90 0 0 0 1/14/2018 44 90 0 0 0 1/13/2018 44 90 0 1/12/2018 44 90 0 0 0 1/11/2018 43 95 0 0 0 1/10/2018 42 100 0 0 0 1/9/2018 41 90 0 0 0 1/8/2018 38 95 0 0 0 1/7/2018 38 95 0 0 0 1/6/2018 1248 98 0 0 13 1/5/2018 42 80 0 0 0 1/4/2018 42 80 0 0 0 1/3/2018 41 100 0 0 0 1/2/2018 39 100 0 0 0 1/1/2018 1280 100 0 0 20 Hilcorp Alaska, LLC March 27, 2018 Mr. Hollis S. French, Chair RECEIVED ` APR 0 2 2018 AOGCV Alaska Oil & Gas Conservation Commission 13 333 W. 7u Avenue, Suite 100 Anchorage, Alaska 99501-3539 Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 100 Anchorage, AK 99503 Phone: 907/777-8322 Fax: 907/777-8580 Re: 2017 Annual Disposal Report for the 13-31 & 14-31 Wells in the Ivan River Unit Dear Mr. French, This is the 2017 Annual Report for the UIC Class II disposal operation in the IRU 13-31 (DIO 35) and IRU 14-31 (DIO 23) wellbores. The attached plots shows that injection rates and pressures for both wells were well below the regulatory limit of 4 barrels per minute and 5000psig. Furthermore, injection and annuli pressures indicate no mechanical concerns and that the injected fluid was contained to the approved disposal zone. Specific items to note for this reporting period: • A MIT is required every two years and the last MIT was performed 6-28-16. • In 2017, the fluids injected into the IRU 13-31 and 14-31 (432 and 314 barrels, respectively) wells were produced water from the Ivan River, Pretty Creek, and Lewis River fields. • Maximum pressures in both wells during injection never exceeded 1600psig. Sincerely, l #JOL* Trudi Hallett Reservoir Engineer Attachment 1 — IRU 13-31 Injection rates and pressures Attachment 2 — IRU 14-31 hijection rates and pressures IN 019-31 wow -150.0587.00041 0112017 0212017 03/2017 0412017 05/2017 0612017 0712017 00/2017 09/2017 1012017 11/2017 12/2017 —Tubing —IA —OA OOA — Water Injedion Well: IRU 13-31 Desc: Shut -In Permit to drill: 1920880 Admin Approval: DIO #35 API: 50-283-20086-00-00 Date Range: 01/01/2017 - 12/31/2017 Date Tubing IA OA OOA Water Injection 12/31/201' 80 170 0 0 0 12/30/201' 80 170 0 0 0 12/29/201' 80 170 0 0 0 12/28/201 80 170 0 0 0 12/27/201' 80 170 0 0 0 12/26/201' 80 170 0 0 0 12/25/201' 80 170 0 0 0 12/24/201' 80 170 0 0 0 12/23/201' 80 170 0 0 0 12/22/201 80 170 0 0 0 12/21/201' 80 170 0 0 0 12/20/201' 80 170 0 0 0 12/19/201' 80 170 0 0 12/18/201' 80 170 0 0 0 12/17/201' 80 170 0 12/16/201' 80 170 0 12/15/201' 80 170 0 12/14/201' 80 170 0 12/13/201 80 170 0 0 0 12/12/201' 80 170 0 0 0 12/11/201' 80 170 0 0 0 12/10/201' 80 170 0 0 0 12/9/2017 81 170 0 0 0 12/8/2017 80 170 0 0 0 12/7/2017 80 170 0 0 0 12/6/2017 80 170 0 0 0 12/5/2017 80 170 0 0 0 12/4/2017 80 170 0 0 0 12/3/2017 80 170 0 0 0 12/2/2017 80 170 0 0 0 12/1/2017 80 170 0 0 0 11/30/201 80 170 0 0 0 11/29/201 80 170 0 0 0 11/28/201 80 170 0 0 0 11/27/201 80 170 0 0 0 11/26/201 80 170 0 0 0 11/25/201 80 170 0 0 0 11/24/201 80 175 0 0 0 11/23/201 80 175 0 0 0 11/22/201 80 180 0 0 0 11/21/201 80 180 0 0 0 11/20/201 80 180 0 0 0 11/19/201 80 180 0 0 0 11/18/201' 80 180 0 0 0 11/17/201 80 180 0 0 0 11/16/201 80 180 0 0 0 11/15/201' 80 180 0 0 0 11/14/201 80 170 0 0 0 11/13/201 80 170 0 0 0 11/12/201 80 170 0 0 0 11/11/201 80 170 0 0 0 11/10/201 80 170 0 0 0 11/9/2017 180 170 0 0 0 11/8/2017 180 170 0 0 0 11/7/2017 180 170 0 0 0 11/6/2017 180 170 0 0 0 11/5/2017 180 170 0 0 0 11/4/2017 180 170 0 0 0 11/3/2017 180 170 0 0 0 11/2/2017 180 170 0 0 0 11/1/2017 182 170 0 0 0 10/31/201 183 170 0 0 0 10/30/201 181 160 0 0 0 10/29/201 183 160 0 0 0 10/28/201 184 160 0 0 0 10/27/201 180 160 0 0 0 10/26/201 1346 160 0 0 31 10/25/2017 212 160 0 0 0 10/24/201' 212 160 0 10/23/201' 212 160 0 10/22/201' 212 160 0 10/21/201' 212 160 0 10/20/201' 212 160 0 10/19/201' 212 160 0 0 0 10/18/201' 211 160 0 0 0 10/17/201' 210 160 0 0 0 10/16/201' 215 190 0 0 0 10/15/201 1375 190 0 0 30 10/14/201' 1235 190 0 0 30 10/13/201' 1210 190 0 0 23 10/12/201' 40 190 0 0 0 10/11/201' 1250 190 0 0 11 10/10/201' 1250 190 0 0 30 10/9/2017 1215 190 0 0 10 10/8/2017 1139 190 0 0 20 10/7/2017 90 190 0 0 0 10/6/2017 90 190 0 0 0 10/5/2017 90 190 0 0 0 10/4/2017 90 190 0 0 0 10/3/2017 90 190 0 0 0 10/2/2017 90 190 0 0 0 10/1/2017 80 190 0 0 0 9/30/2017 90 190 0 0 0 9/29/2017 80 190 0 0 0 9/28/2017 50 195 0 0 0 9/27/2017 50 200 0 0 0 9/26/2017 1050 180 0 0 17 9/25/2017 80 180 0 0 0 9/24/2017 80 180 0 0 0 9/23/2017 80 180 0 0 0 9/22/2017 80 180 0 0 0 9/21/2017 80 180 0 0 0 9/20/2017 80 180 0 0 0 9/19/2017 80 180 0 0 0 9/18/2017 80 180 0 0 0 9/17/2017 80 180 0 0 0 9/16/2017 80 190 0 0 9/15/2017 1321 250 0 0 9/14/2017 80 180 0 0 9/13/2017 80 180 0 0 9/12/2017 80 180 0 0 9/11/2017 80 180 0 0 9/10/2017 80 180 0 0 9/9/2017 80 180 0 0 9/8/2017 80 180 0 0 9/7/2017 80 180 0 0 9/6/2017 80 180 0 0 9/5/2017 80 180 0 0 9/4/2017 80 180 0 0 9/3/2017 80 180 0 0 9/2/2017 80 190 0 0 9/1/2017 80 180 0 0 8/31/2017 80 180 0 0 8/30/2017 80 180 0 0 8/29/2017 80 180 0 0 8/28/2017 80 180 0 0 8/27/2017 80 180 0 0 8/26/2017 80 180 0 0 8/25/2017 80 180 0 0 8/24/2017 80 190 0 0 8/23/2017 80 190 0 0 8/22/2017 80 188 0 0 8/21/2017 80 188 0 0 8/20/2017 80 185 0 0 8/19/2017 50 180 0 0 8/18/2017 50 180 0 0 8/17/2017 42 170 0 0 8/16/2017 42 170 0 0 8/15/2017 42 175 0 0 8/14/2017 42 175 0 0 8/13/2017 42 175 0 0 8/12/2017 42 185 0 0 8/11/2017 48 175 0 0 8/10/2017 48 175 0 0 8/9/2017 80 170 0 0 0 26 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 8/8/2017 80 170 0 0 0 8/7/2017 80 170 0 0 0 8/6/2017 80 170 0 0 0 8/5/2017 77 170 0 0 0 8/4/2017 78 170 0 0 0 8/3/2017 78 170 0 0 0 8/2/2017 70 170 0 0 0 8/1/2017 70 170 0 0 0 7/31/2017 66 170 0 0 0 7/30/2017 66 170 0 0 0 7/29/2017 62 170 0 0 0 7/28/2017 62 170 0 1 0 7/27/2017 62 170 0 1 0 7/26/2017 63 170 0 1 0 7/25/2017 63 170 0 1 0 7/24/2017 1425 170 0 1 31 7/23/2017 1370 170 0 1 30 7/22/2017 1246 170 0 1 22 7/21/2017 64 170 0 1 0 7/20/2017 60 170 0 1 0 7/19/2017 57 170 0 1 0 7/18/2017 49 170 0 7/17/2017 46 160 0 7/16/2017 43 160 0 7/15/2017 43 160 0 7/14/2017 43 160 0 7/13/2017 43 160 0 7/12/2017 72 160 0 0 0 7/11/2017 76 160 0 0 0 7/10/2017 1237 160 0 0 23 7/9/2017 73 170 0 0 0 7/8/2017 75 170 0 0 0 7/7/2017 74 170 0 0 0 7/6/2017 74 170 0 0 0 7/5/2017 75 170 0 0 0 7/4/2017 75 170 0 0 0 7/3/2017 75 170 0 0 0 7/2/2017 75 170 0 0 0 7/1/2017 75 170 0 0 0 6/30/2017 75 170 0 0 6/29/2017 75 170 0 0 6/28/2017 75 170 0 0 6/27/2017 75 170 0 0 6/26/2017 48 163 0 0 6/25/2017 48 163 0 0 6/24/2017 48 163 0 0 6/23/2017 48 163 0 0 6/22/2017 48 163 0 0 6/21/2017 47 163 0 0 6/20/2017 48 163 6/19/2017 48 163 6/18/2017 48 160 6/17/2017 48 163 6/16/2017 48 163 6/15/2017 48 163 6/14/2017 48 163 0 2 6/13/2017 36 160 0 2 6/12/2017 36 160 0 2 6/11/2017 37 160 0 2 6/10/2017 36 160 0 2 6/9/2017 36 160 0 2 6/8/2017 36 160 0 2 6/7/2017 36 160 0 2 6/6/2017 40 160 6/5/2017 40 160 6/4/2017 40 160 6/3/2017 40 160 6/2/2017 40 160 6/1/2017 40 160 5/31/2017 40 160 5/30/2017 40 160 5/29/2017 40 160 0 2 5/28/2017 36 160 0 2 5/27/2017 36 160 0 2 5/26/2017 32 160 0 2 5/25/2017 32 160 0 2 5/24/2017 33 160 0 2 5/23/2017 38 160 0 2 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 5/22/2017 45 160 0 2 0 5/21/2017 58 160 0 2 0 5/20/2017 64 160 0 2 0 5/19/2017 1307 160 0 2 28 5/18/2017 1305 160 0 2 28 5/17/2017 1295 160 0 2 30 5/16/2017 1295 160 0 2 34 5/15/2017 1305 160 0 2 30 5/14/2017 1295 160 0 2 20 5/13/2017 100 160 0 2 0 5/12/2017 100 160 0 2 0 5/11/2017 100 160 0 2 0 5/10/2017 100 160 0 2 0 5/9/2017 100 160 0 2 0 5/8/2017 100 160 0 2 0 5/7/2017 100 170 0 2 0 5/6/2017 100 170 0 2 0 5/5/2017 100 170 0 2 0 5/4/2017 46 170 0 2 0 5/3/2017 46 170 0 2 0 5/2/2017 48 165 0 2 0 5/1/2017 48 165 0 2 0 4/30/2017 48 165 0 2 0 4/29/2017 48 165 0 2 0 4/28/2017 48 165 0 2 0 4/27/2017 48 165 0 2 0 4/26/2017 48 165 0 2 0 4/25/2017 48 165 0 2 0 4/24/2017 48 165 0 2 0 4/23/2017 48 165 0 2 0 4/22/2017 48 165 0 2 0 4/21/2017 48 165 0 2 0 4/20/2017 48 165 0 2 0 4/19/2017 48 165 0 2 0 4/18/2017 48 165 0 2 0 4/17/2017 48 165 0 2 0 4/16/2017 48 170 0 2 0 4/15/2017 48 170 0 2 0 4/14/2017 48 170 0 2 0 4/13/2017 48 170 0 2 0 4/12/2017 48 170 0 2 0 4/11/2017 48 170 0 2 0 4/10/2017 48 170 0 2 0 4/9/2017 48 170 0 2 0 4/8/2017 48 110 0 2 0 4/7/2017 48 110 0 2 0 4/6/2017 48 170 0 2 0 4/5/2017 48 170 0 2 0 4/4/2017 48 170 0 2 0 4/3/2017 48 170 0 2 0 4/2/2017 48 170 0 2 0 4/1/2017 48 170 0 2 0 3/31/2017 48 170 0 2 0 3/30/2017 48 170 0 2 0 3/29/2017 48 170 0 2 0 3/28/2017 48 170 0 0 0 3/27/2017 48 170 0 0 3/26/2017 48 170 0 0 0 3/25/2017 48 170 0 0 0 3/24/2017 48 170 0 0 0 3/23/2017 48 170 0 0 0 3/22/2017 48 170 0 0 0 3/21/2017 48 170 0 0 0 3/20/2017 48 170 0 0 0 3/19/2017 48 185 0 0 0 3/18/2017 48 185 0 0 0 3/17/2017 48 185 0 0 0 3/16/2017 48 170 0 0 0 3/15/2017 48 170 0 0 0 3/14/2017 48 170 0 0 0 3/13/2017 48 170 0 0 0 3/12/2017 40 170 0 0 0 3/11/2017 38 170 0 0 0 3/10/2017 38 170 0 0 0 3/9/2017 38 170 0 0 0 3/8/2017 38 170 0 0 0 3/7/2017 38 170 0 0 0 3/6/2017 38 170 0 0 0 3/5/2017 38 170 0 0 0 3/4/2017 38 170 0 0 0 3/3/2017 38 170 0 0 0 3/2/2017 38 170 0 0 0 3/1/2017 38 170 0 0 0 2/28/2017 38 170 0 0 0 2/27/2017 38 170 0 0 0 2/26/2017 38 170 0 0 0 2/25/2017 38 170 0 0 0 2/24/2017 38 170 0 0 0 2/23/2017 38 170 0 0 0 2/22/2017 38 170 0 0 0 2/21/2017 38 170 0 0 0 2/20/2017 1406 170 0 0 18 2/19/2017 28 185 0 0 0 2/18/2017 28 170 0 0 0 2/17/2017 28 170 0 0 0 2/16/2017 28 170 0 0 0 2/15/2017 28 170 0 0 0 2/14/2017 28 170 0 0 0 2/13/2017 28 170 0 0 0 2/12/2017 28 170 0 0 0 2/11/2017 28 170 0 0 0 2/10/2017 28 170 0 0 0 2/9/2017 28 170 0 0 0 2/8/2017 28 170 0 0 0 2/7/2017 28 170 0 0 0 2/6/2017 28 170 0 0 0 2/5/2017 28 170 0 0 0 2/4/2017 28 170 0 0 0 2/3/2017 28 170 0 0 0 2/2/2017 28 170 0 0 0 2/1/2017 28 170 0 0 0 1/31/2017 28 170 0 0 0 1/30/2017 28 170 0 0 0 1/29/2017 28 170 0 0 0 1/28/2017 28 170 0 0 0 1/27/2017 28 170 0 0 0 1/26/2017 28 170 0 0 0 1/25/2017 28 170 0 0 0 1/24/2017 28 170 0 0 0 1/23/2017 28 170 0 0 0 1/22/2017 28 170 0 0 0 1/21/2017 28 170 0 0 0 1/20/2017 28 170 0 0 0 1/19/2017 28 170 0 0 0 1/18/2017 28 170 0 0 0 1/17/2017 28 170 0 1/16/2017 28 170 0 1/15/2017 28 170 0 1/14/2017 28 170 0 1/13/2017 28 170 0 1/12/2017 28 170 2 0 0 1/11/2017 45 170 0 1/10/2017 46 170 0 1/9/2017 118 170 0 0 0 1/8/2017 18 170 0 0 0 1/7/2017 18 170 0 0 0 1/6/2017 18 170 0 0 0 1/5/2017 18 170 0 0 0 1/4/2017 18 170 0 0 0 1/3/2017 18 170 0 0 0 1/2/2017 20 170 0 0 0 1/1/2017 30 170 0 0 0 522 IRU 014-31 WDW - [50.0587.0003] 01/2017 02/2017 03/2017 04/2017 05/2017 06/2017 07/2017 08/2017 09/2017 10/2017 11/2017 17/2017 — Tubing — IA — OA DOA — Water Injection 200 150 100 M Well: IRU 14-31 Desc: Disposal Permit to drill: 1750080 Admin Approval: DIO #23 API: 50-283-20045-00-00 Date Range: 01/01/2017 - 12/31/2017 Date Tubing IA OA OOA Water Injection 12/31/201 46 100 0 0 0 12/30/201 46 100 0 0 0 12/29/201 45 100 0 0 0 12/28/201 45 100 0 0 0 12/27/201 45 100 0 0 0 12/26/201 45 100 0 0 0 12/25/201 44 100 0 0 0 12/24/201 43 100 0 0 0 12/23/201 43 100 0 0 0 12/22/201' 41 100 0 0 0 12/21/201 38 100 0 0 0 12/20/201 1200 100 0 0 21 12/19/201 42 100 0 0 12/18/201 42 100 0 0 12/17/201 42 100 0 12/16/201 42 100 0 12/15/201 42 100 0 12/14/201 42 100 0 12/13/201 42 100 0 0 0 12/12/201 42 100 0 0 0 12/11/201 42 100 0 0 0 12/10/201 42 100 0 0 0 12/9/2017 41 100 0 0 0 12/8/2017 40 100 0 0 0 12/7/2017 40 100 0 0 0 12/6/2017 39 95 0 0 0 12/5/2017 35 95 0 0 0 12/4/2017 35 95 0 0 0 12/3/2017 1140 95 0 0 20 12/2/2017 43 95 0 0 0 12/1/2017 43 95 0 0 0 11/30/201 44 95 0 0 0 11/29/201 44 95 0 0 0 11/28/201 43 95 0 0 0 11/27/201 43 95 0 0 0 11/26/201 43 95 0 0 0 11/25/201 43 95 0 0 0 11/24/201 43 95 0 0 0 11/23/201 43 95 0 0 0 11/22/201 43 95 0 0 0 11/21/201 43 95 0 0 0 11/20/201 42 110 0 0 0 11/19/201 42 110 0 0 0 11/18/201 41 110 0 0 0 11/17/201 40 110 0 0 0 11/16/201 40 110 0 0 0 11/15/201 35 110 0 0 0 11/14/201' 1078 110 0 0 12 11/13/201 40 110 0 0 0 11/12/201 40 110 0 0 0 11/11/201 39 110 0 0 0 11/10/201 1200 110 0 0 8 11/9/2017 45 110 0 0 0 11/8/2017 45 110 0 0 0 11/7/2017 45 110 0 0 0 11/6/2017 44 110 0 0 0 11/5/2017 45 110 0 0 0 11/4/2017 44 110 0 0 0 11/3/2017 44 110 0 0 0 11/2/2017 44 110 0 0 0 11/1/2017 44 110 0 0 0 10/31/201 36 110 0 0 0 10/30/201 36 110 0 0 0 10/29/201 36 110 0 0 0 10/28/201 36 110 0 0 0 10/27/201 36 110 0 0 0 10/26/201 36 110 0 0 0 10/25/2017 36 110 0 0 0 10/24/201 36 110 0 10/23/201 36 110 0 10/22/201 36 110 0 10/21/201 36 110 0 10/20/201 36 110 0 10/19/201 35 110 0 0 0 10/18/201 35 110 0 0 0 10/17/201 35 110 0 0 0 10/16/201 35 120 0 0 0 10/15/201' 35 120 0 0 0 10/14/201 35 120 0 0 0 10/13/201 35 120 0 0 0 10/12/201' 35 100 0 0 0 10/11/201 35 100 0 0 0 10/10/201 35 100 0 0 0 10/9/2017 36 100 0 0 0 10/8/2017 45 100 0 0 0 10/7/2017 45 100 0 0 0 10/6/2017 45 100 0 0 0 10/5/2017 45 100 0 0 0 10/4/2017 45 100 0 0 0 10/3/2017 45 100 0 0 0 10/2/2017 45 100 0 0 0 10/1/2017 44 100 0 0 0 9/30/2017 44 100 0 0 0 9/29/2017 44 90 0 0 0 9/28/2017 44 90 0 0 0 9/27/2017 45 90 0 0 0 9/26/2017 45 90 0 0 0 9/25/2017 45 90 0 0 0 9/24/2017 44 90 0 0 0 9/23/2017 44 90 0 0 0 9/22/2017 44 90 0 0 0 9/21/2017 44 90 0 0 0 9/20/2017 44 90 0 0 0 9/19/2017 44 90 0 0 0 9/18/2017 44 90 0 0 0 9/17/2017 44 90 0 0 0 9/16/2017 44 90 0 0 0 9/15/2017 44 90 0 0 0 9/14/2017 44 120 0 0 0 9/13/2017 44 100 0 0 0 9/12/2017 44 100 0 0 0 9/11/2017 44 100 0 0 0 9/10/2017 44 105 0 0 0 9/9/2017 44 105 0 0 0 9/8/2017 44 105 0 0 0 9/7/2017 43 105 0 0 0 9/6/2017 43 110 10 0 0 9/5/2017 42 110 10 0 0 9/4/2017 41 110 10 0 0 9/3/2017 39 110 10 0 0 9/2/2017 37 110 10 0 0 9/1/2017 41 110 10 0 0 8/31/2017 47 110 10 0 0 8/30/2017 47 110 10 0 0 8/29/2017 47 110 10 0 0 8/28/2017 47 100 10 0 0 8/27/2017 47 110 10 0 0 8/26/2017 48 100 10 0 0 8/25/2017 47 100 10 0 0 8/24/2017 47 110 12 0 0 8/23/2017 47 110 12 0 0 8/22/2017 47 110 12 0 0 8/21/2017 47 110 13 0 0 8/20/2017 45 118 14 0 0 8/19/2017 45 120 15 0 0 8/18/2017 1100 120 15 0 7 8/17/2017 44 125 15 0 0 8/16/2017 42 125 15 0 0 8/15/2017 44 125 15 0 0 8/14/2017 44 125 15 0 0 8/13/2017 41 100 15 0 0 8/12/2017 1118 195 15 0 25 8/11/2017 66 100 15 0 0 8/10/2017 68 100 15 0 0 8/9/2017 66 100 20 0 0 8/8/2017 66 100 20 0 8/7/2017 68 100 20 0 8/6/2017 66 100 20 0 8/5/2017 69 100 20 0 8/4/2017 70 100 20 0 8/3/2017 70 100 20 0 8/2/2017 65 100 20 0 8/1/2017 65 100 20 0 7/31/2017 64 100 20 0 7/30/2017 65 100 20 0 7/29/2017 64 100 20 0 7/28/2017 42 100 20 0 7/27/2017 42 100 20 0 7/26/2017 43 100 20 0 7/25/2017 43 100 20 0 7/24/2017 43 100 20 0 7/23/2017 43 100 20 0 7/22/2017 43 125 20 0 7/21/2017 43 125 20 0 7/20/2017 43 125 20 0 7/19/2017 43 125 20 0 7/18/2017 43 125 7/17/2017 43 100 7/16/2017 43 100 7/15/2017 43 100 7/14/2017 43 100 7/13/2017 40 100 7/12/2017 40 100 0 0 7/11/2017 42 100 0 0 7/10/2017 48 100 0 0 7/9/2017 49 100 0 0 7/8/2017 48 100 0 0 7/7/2017 48 100 0 0 7/6/2017 48 100 0 0 7/5/2017 48 100 0 0 7/4/2017 48 100 0 0 7/3/2017 48 100 0 0 7/2/2017 48 100 0 0 7/1/2017 48 100 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 6/30/2017 48 100 0 0 0 6/29/2017 48 100 0 0 0 6/28/2017 48 100 0 0 0 6/27/2017 48 100 0 0 0 6/26/2017 48 100 0 0 0 6/25/2017 48 100 0 0 0 6/24/2017 48 100 0 0 0 6/23/2017 48 100 0 0 0 6/22/2017 48 100 20 0 0 6/21/2017 47 100 20 0 0 6/20/2017 48 100 0 6/19/2017 49 100 0 6/18/2017 48 100 0 6/17/2017 48 100 0 6/16/2017 48 100 0 6/15/2017 48 100 0 6/14/2017 48 100 0 0 0 6/13/2017 50 105 0 0 0 6/12/2017 48 105 0 0 0 6/11/2017 51 105 0 0 0 6/10/2017 44 110 0 0 0 6/9/2017 50 110 0 0 0 6/8/2017 50 110 0 0 0 6/7/2017 50 110 0 0 0 6/6/2017 50 110 0 6/5/2017 48 110 0 6/4/2017 48 110 0 6/3/2017 48 110 0 6/2/2017 48 110 0 6/1/2017 48 110 0 5/31/2017 48 110 0 5/30/2017 48 110 0 5/29/2017 48 110 0 0 0 5/28/2017 48 110 0 0 0 5/27/2017 48 110 0 0 0 5/26/2017 48 110 0 0 0 5/25/2017 48 110 0 0 0 5/24/2017 48 110 0 0 0 5/23/2017 48 110 0 0 0 5/22/2017 48 110 0 0 0 5/21/2017 48 110 0 0 0 5/20/2017 48 110 0 0 0 5/19/2017 48 110 0 0 0 5/18/2017 48 110 0 0 0 5/17/2017 48 110 0 0 0 5/16/2017 48 110 0 0 0 5/15/2017 48 110 0 0 0 5/14/2017 49 110 0 0 0 5/13/2017 48 110 0 0 0 5/12/2017 48 110 0 0 0 5/11/2017 48 110 0 0 0 5/10/2017 48 110 0 0 0 5/9/2017 48 110 0 0 0 5/8/2017 48 110 0 0 0 5/7/2017 48 110 0 0 0 5/6/2017 47 110 0 0 0 5/5/2017 47 110 0 0 0 5/4/2017 46 110 0 0 0 5/3/2017 44 110 0 0 0 5/2/2017 1705 110 0 0 26 5/1/2017 43 110 0 0 0 4/30/2017 1705 110 0 0 28 4/29/2017 48 110 0 0 0 4/28/2017 1105 110 0 0 32 4/27/2017 48 110 0 0 0 4/26/2017 48 110 0 0 0 4/25/2017 49 110 0 0 0 4/24/2017 49 110 0 0 0 4/23/2017 49 110 0 0 0 4/22/2017 49 110 0 0 0 4/21/2017 49 110 0 0 0 4/20/2017 49 110 0 0 0 4/19/2017 49 110 0 0 0 4/18/2017 48 110 0 0 0 4/17/2017 48 110 0 0 0 4/16/2017 48 110 0 0 0 4/15/2017 48 110 0 0 0 4/14/2017 48 110 0 0 0 4/13/2017 48 110 0 0 0 4/12/2017 48 110 0 0 0 4/11/2017 48 110 0 0 0 4/10/2017 48 110 0 0 0 4/9/2017 48 110 0 0 0 4/8/2017 48 110 0 0 0 4/7/2017 48 110 0 0 0 4/6/2017 90 115 0 0 0 4/5/2017 1062 110 0 0 0 4/4/2017 1062 110 0 0 23 4/3/2017 46 110 0 0 0 4/2/2017 46 110 0 0 0 4/1/2017 46 110 0 0 0 3/31/2017 46 110 0 0 0 3/30/2017 46 110 0 0 0 3/29/2017 46 110 0 0 0 3/28/2017 46 110 0 0 0 3/27/2017 46 110 0 0 0 3/26/2017 46 110 0 0 0 3/25/2017 46 110 0 0 0 3/24/2017 45 110 0 0 0 3/23/2017 45 110 0 0 0 3/22/2017 44 110 0 0 0 3/21/2017 41 110 0 0 0 3/20/2017 1074 110 0 0 22 3/19/2017 45 110 0 0 0 3/18/2017 45 110 0 0 0 3/17/2017 45 110 0 0 0 3/16/2017 50 110 0 0 0 3/15/2017 50 110 0 0 0 3/14/2017 50 110 0 0 0 3/13/2017 50 110 0 0 0 3/12/2017 45 110 0 0 0 3/11/2017 40 119 0 0 0 3/10/2017 40 119 0 0 0 3/9/2017 40 119 0 0 0 3/8/2017 40 119 0 0 0 3/7/2017 40 119 0 0 0 3/6/2017 1100 119 0 0 20 3/5/2017 18 119 0 0 0 3/4/2017 18 119 0 0 0 3/3/2017 18 119 0 0 0 3/2/2017 18 119 0 0 0 3/1/2017 21 119 0 0 0 2/28/2017 22 119 0 0 0 2/27/2017 15 119 0 0 0 2/26/2017 15 119 0 0 0 2/25/2017 15 119 0 0 0 2/24/2017 15 119 0 0 0 2/23/2017 15 119 0 0 0 2/22/2017 15 119 0 0 0 2/21/2017 15 119 0 0 0 2/20/2017 15 119 0 0 0 2/19/2017 15 119 0 0 0 2/18/2017 15 119 0 0 0 2/17/2017 15 119 0 0 0 2/16/2017 15 119 0 0 0 2/15/2017 15 119 0 0 0 2/14/2017 15 119 0 0 0 2/13/2017 15 119 0 0 0 2/12/2017 15 119 0 0 0 2/11/2017 15 119 0 0 0 2/10/2017 15 119 0 0 0 2/9/2017 16 119 0 0 0 2/8/2017 16 119 0 0 0 2/7/2017 15 119 0 0 0 2/6/2017 15 119 0 0 0 2/5/2017 15 119 0 0 0 2/4/2017 33 119 0 0 0 2/3/2017 1390 119 0 0 20 2/2/2017 9 119 0 0 0 2/1/2017 10 119 0 0 0 1/31/2017 11 119 0 0 0 1/30/2017 11 119 0 0 0 1/29/2017 11 119 0 0 0 1/28/2017 12 119 0 0 0 1/27/2017 15 119 0 0 0 1/26/2017 16 119 0 0 0 1/25/2017 17 119 0 0 1/24/2017 29 119 0 0 1/23/2017 29 119 0 0 1/22/2017 1350 119 0 0 1/21/2017 16 119 0 0 1/20/2017 16 119 0 0 1/19/2017 16 119 0 0 1/18/2017 16 119 0 0 1/17/2017 16 119 1/16/2017 13 119 1/15/2017 16 119 1/14/2017 17 119 1/13/2017 19 119 1/12/2017 45 119 18 0 1/11/2017 45 115 1/10/2017 45 115 1/9/2017 45 115 18 0 1/8/2017 40 115 18 0 1/7/2017 40 115 18 0 1/6/2017 40 115 18 0 1/5/2017 1100 115 18 0 1/4/2017 44 118 18 0 1/3/2017 44 118 18 0 1/2/2017 44 118 18 0 1/l/2017 44 118 18 0 0 0 0 18 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 17 0 0 0 0 Hilcorp Alaska, LLC July 7, 2017 Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 100 Anchorage, AK 99503 Phone: 907/777-8322 Fax: 907/777-8580 Mr. Hollis S. French, Chair RECEIVED Alaska Oil & Gas Conservation Commission 333 W. 7h Avenue, Suite 100 JUL 10 2017 Anchorage, Alaska 99501-3539 �4AGCC Re: 2016 Annual Disposal Report for the 13-31 & 14-31 Wells in the Ivan River Unit Dear Mr. French, This is the 2016 Annual Report for the UIC Class II disposal operation in the IRU 13-31 (DIO 35) and IRU 14-17 (DIO 23) wellbores. The attached plots shows that injection rates and pressures for both wells were well below the regulatory limit of 4 barrels per minute and 5000psig. Furthermore, injection and annuli pressures indicate no mechanical concerns and that the injected fluid was contained to the approved disposal zone. Specific items to note for this reporting period: • A MIT is required every two years and the last MIT was performed 6-28-16. • In 2016, the fluids injected into the IRU 13-31 and 14-31 (432 and 314 barrels, respectively) wells were produced water from the Ivan River, Pretty Creek, and Lewis River fields. • Maximum pressures in both wells during injection never exceeded 1600psig. Sincerely, q 'V, Jim Young Reservoir Engineer Attachment 1 — IRU 13-31 Injection rates and pressures Attachment 2 — IRU 14-31 Injection rates and pressures 4 �- Vanessa Hughes Reservoir Engineer O C .J O O O O O O O O ISd y N O W R N ti ti ti H 4 Well: IRU 13-31 Desc: Shut -In Permit to drill: 1920880 Admin Approval: DID #35 API: 50-283-20086-00-00 Date Range: 12/30/2015 - 01/02/2017 Date Tubing IA OA ODA Water Injection 1/2/2017 20 170 0 0 0 1/1/2017 30 170 0 0 0 12/31/201 141 170 0 0 0 12/30/201 141 170 0 0 0 12/29/201 141 170 0 0 0 12/28/201 141 170 0 0 0 12/27/201 141 180 0 0 12/26/201 141 180 0 0 0 12/25/201 141 180 0 0 0 12/24/201 141 180 0 0 0 12/23/201 141 180 0 0 0 12/22/201 141 180 0 0 0 12/21/201 141 180 0 0 0 12/20/201 50 170 0 12/19/201 50 170 0 12/18/201 50 170 0 12/17/201 50 170 0 12/16/201 50 170 0 12/15/201 50 170 0 12/14/201 50 170 0 12/13/201 0 12/12/201 120 170 0 0 0 12/11/201 120 170 0 0 0 12/10/201 120 170 0 0 0 12/9/2016 120 170 0 0 0 12/8/2016 0 12/7/2016 140 170 0 0 0 12/6/2016 55 175 0 0 0 12/5/2016 55 175 0 0 0 12/4/2016 55 175 0 0 0 12/3/2016 55 175 0 0 0 12/2/2016 55 175 0 2 0 12/1/2016 55 175 0 2 0 11/30/201 55 175 0 2 0 11/29/201 55 175 0 2 0 11/28/201 120 175 0 0 0 11/27/201 120 175 0 0 0 11/26/201 120 175 0 0 0 11/25/201 120 175 0 0 0 11/24/201 120 175 0 0 0 11/23/201 100 170 0 0 0 11/22/201 100 170 0 0 0 11/21/201 100 170 0 0 0 Date Tubing IA OA OOA Water Injection 11/20/201 100 170 0 0 0 11/19/201 100 170 0 0 0 11/18/201 52 178 0 2 0 11/17/201 52 178 0 2 0 11/16/201 52 178 0 2 0 11/15/201 52 178 0 2 0 11/14/201 52 178 0 2 0 11/13/201 52 178 0 2 0 11/12/201 52 178 0 2 0 11/11/201 52 178 0 2 0 11/10/201 52 178 0 2 0 11/9/2016 52 178 0 2 0 11/8/2016 52 178 0 2 0 11/7/2016 52 178 0 2 0 11/6/2016 52 178 0 2 0 11/5/2016 52 178 0 2 0 11/4/2016 52 178 0 2 0 11/3/2016 52 178 0 2 0 11/2/2016 52 180 0 2 0 11/1/2016 52 180 0 2 0 10/31/201 52 180 0 2 0 10/30/201 52 180 0 2 0 10/29/201 52 180 0 2 0 10/28/201 52 180 0 2 0 10/27/201 52 180 0 2 0 10/26/201 52 180 0 2 0 10/25/201 52 180 0 10/24/201 52 180 0 10/23/201 2 180 0 10/22/201 52 180 0 10/21/201 52 180 0 10/20/201 52 180 0 10/19/201 52 180 0 10/18/201 52 180 0 2 0 10/17/201 52 180 0 2 0 10/16/201 52 180 0 2 0 10/15/201 52 180 0 2 0 10/14/201 52 180 0 2 0 10/13/201 52 180 0 2 0 10/12/201 52 180 0 2 0 10/11/201 52 180 0 10/10/201 52 180 0 10/9/2016 52 180 0 10/8/2016 52 185 0 10/7/2016 52 185 0 10/6/2016 52 185 0 10/5/2016 52 185 0 10/4/2016 52 185 0 2 0 10/3/2016 52 185 0 2 0 10/2/2016 52 185 0 2 0 10/1/2016 52 185 0 2 0 Date Tubing IA OA ODA Water Injection 9/30/2016 52 185 0 2 0 9/29/2016 52 185 0 2 0 9/28/2016 51 185 0 2 0 9/27/2016 1140 185 0 2 19 9/26/2016 56 185 0 2 0 9/25/2016 56 185 0 2 0 9/24/2016 54 185 0 2 0 9/23/2016 54 185 0 2 0 9/22/2016 53 185 0 2 0 9/21/2016 50 185 0 2 0 9/20/2016 54 185 0 2 0 9/19/2016 54 185 0 2 0 9/18/2016 53 185 0 2 0 9/17/2016 53 185 0 2 0 9/16/2016 53 185 0 2 0 9/15/2016 53 185 0 2 0 9/14/2016 50 185 0 2 0 9/13/2016 50 185 0 2 0 9/12/2016 50 185 0 2 0 9/11/2016 50 185 0 2 0 9/10/2016 48 185 0 2 0 9/9/2016 46 185 0 2 0 9/8/2016 44 185 0 2 0 9/7/2016 60 185 0 2 0 9/6/2016 60 180 0 2 0 9/5/2016 60 180 0 2 0 9/4/2016 60 180 0 2 0 9/3/2016 60 180 0 2 0 9/2/2016 60 180 0 2 0 9/1/2016 60 180 0 2 0 8/31/2016 60 180 0 2 0 8/30/2016 60 180 0 2 0 8/29/2016 60 180 0 2 0 8/28/2016 60 180 0 2 0 8/27/2016 60 180 0 2 0 8/26/2016 60 180 0 2 0 8/25/2016 60 180 0 2 0 8/24/2016 60 180 0 2 0 8/23/2016 60 180 0 2 0 8/22/2016 60 180 0 2 0 8/21/2016 60 180 0 2 0 8/20/2016 60 180 0 2 0 8/19/2016 60 180 0 2 0 8/18/2016 60 180 0 2 0 8/17/2016 60 180 0 2 0 8/16/2016 60 180 0 2 0 8/15/2016 60 180 0 2 0 8/14/2016 60 180 0 2 0 8/13/2016 60 180 0 2 0 8/12/2016 60 180 0 2 0 8/11/2016 60 180 0 2 0 Date Tubing IA OA ODA Water Injection 8/10/2016 60 180 0 2 0 8/9/2016 60 180 0 2 0 8/8/2016 60 180 0 2 0 8/7/2016 60 180 0 2 0 8/6/2016 60 180 0 2 0 8/5/2016 60 180 0 2 0 8/4/2016 60 180 0 2 0 8/3/2016 60 180 0 2 0 8/2/2016 60 195 0 2 0 8/1/2016 60 195 0 2 0 7/31/2016 1223 215 0 2 5 7/30/2016 62 195 0 2 0 7/29/2016 62 195 0 2 0 7/28/2016 62 195 0 2 0 7/27/2016 62 195 0 2 0 7/26/2016 61 195 0 2 0 7/25/2016 1341 195 0 2 14 7/24/2016 60 195 0 2 0 7/23/2016 1277 195 0 2 14 7/22/2016 61 195 0 2 0 7/21/2016 61 195 0 2 0 7/20/2016 61 195 0 2 0 7/19/2016 61 195 0 2 0 7/18/2016 61 195 0 2 0 7/17/2016 61 195 0 2 0 7/16/2016 61 195 0 2 0 7/15/2016 61 195 0 2 0 7/14/2016 61 195 0 2 0 7/13/2016 61 195 0 2 0 7/12/2016 61 195 0 2 0 7/11/2016 61 195 0 2 0 7/10/2016 61 195 0 2 0 7/9/2016 61 195 0 2 0 7/8/2016 61 195 0 2 0 7/7/2016 61 195 0 2 0 7/6/2016 61 195 0 2 0 7/5/2016 61 195 0 2 0 7/4/2016 61 195 0 2 0 7/3/2016 1373 290 0 2 26.5 7/2/2016 45 160 0 2 0 7/1/2016 45 160 0 2 0 6/30/2016 45 160 0 2 0 6/29/2016 45 160 0 2 0 6/28/2016 45 160 0 2 0 6/27/2016 50 175 0 2 0 6/26/2016 50 175 0 2 0 6/25/2016 50 175 0 2 0 6/24/2016 50 175 0 2 0 6/23/2016 50 175 0 2 0 6/22/2016 50 175 0 2 0 6/21/2016 44 175 0 2 0 Date Tubing IA OA OOA Water Injection 6/20/2016 44 175 0 2 0 6/19/2016 44 175 0 2 0 6/18/2016 44 175 0 2 0 6/17/2016 44 175 0 2 0 6/16/2016 44 175 0 2 0 6/15/2016 44 175 0 2 0 6/14/2016 44 175 0 2 0 6/13/2016 44 175 0 2 0 6/12/2016 44 175 0 2 0 6/11/2016 44 175 0 2 0 6/10/2016 44 175 0 2 0 6/9/2016 44 175 0 2 0 6/8/2016 43 175 0 2 0 6/7/2016 43 175 0 2 0 6/6/2016 44 175 0 2 0 6/5/2016 44 175 0 2 0 6/4/2016 60 170 0 2 0 6/3/2016 60 170 0 2 0 6/2/2016 60 170 0 2 0 6/1/2016 60 170 0 2 0 5/31/2016 60 170 0 2 0 5/30/2016 60 170 0 2 0 5/29/2016 60 170 0 2 0 5/28/2016 60 170 0 2 0 5/27/2016 60 170 0 2 0 5/26/2016 60 170 0 2 0 5/25/2016 60 170 0 2 0 5/24/2016 60 165 0 2 0 5/23/2016 60 165 0 2 0 5/22/2016 60 165 0 2 0 5/21/2016 60 160 0 2 0 5/20/2016 60 160 0 2 0 5/19/2016 60 160 0 2 0 5/18/2016 60 160 0 2 0 5/17/2016 60 160 0 2 0 5/16/2016 60 160 0 2 0 5/15/2016 1363 160 0 2 32 5/14/2016 60 160 0 2 0 5/13/2016 1273 160 0 2 32 5/12/2016 61 160 0 2 0 5/11/2016 61 160 0 2 0 5/10/2016 61 160 0 2 0 5/9/2016 61 160 0 2 0 5/8/2016 1298 225 0 2 36 5/7/2016 60 165 0 2 0 5/6/2016 60 165 0 2 0 5/5/2016 1350 225 0 2 31 5/4/2016 62 160 0 2 0 5/3/2016 1328 160 0 2 38 5/2/2016 1424 160 0 2 38 5/1/2016 1342 160 0 2 32 Date Tubing IA OA OOA Water Injection 4/30/2016 63 160 0 2 0 4/29/2016 63 160 0 2 0 4/28/2016 63 160 0 2 0 4/27/2016 63 160 0 2 0 4/26/2016 63 160 0 2 0 4/25/2016 63 160 0 2 0 4/24/2016 63 160 0 2 0 4/23/2016 63 160 0 2 0 4/22/2016 63 160 0 2 0 4/21/2016 63 160 0 2 0 4/20/2016 63 160 0 2 0 4/19/2016 63 160 0 2 0 4/18/2016 63 160 0 2 0 4/17/2016 63 160 0 2 0 4/16/2016 63 160 0 2 0 4/15/2016 63 160 0 2 0 4/14/2016 63 160 0 2 0 4/13/2016 63 160 0 2 0 4/12/2016 63 160 0 2 0 4/11/2016 63 160 0 2 0 4/10/2016 63 160 0 2 0 4/9/2016 63 160 0 2 0 4/8/2016 63 160 0 2 0 4/7/2016 63 160 0 2 0 4/6/2016 63 160 0 2 0 4/5/2016 63 160 0 2 0 4/4/2016 63 160 0 2 0 4/3/2016 63 160 0 2 0 4/2/2016 63 160 0 2 0 4/1/2016 63 170 0 4 0 3/31/2016 63 170 0 4 0 3/30/2016 63 170 0 4 0 3/29/2016 63 170 0 4 0 3/28/2016 63 170 0 4 0 3/27/2016 63 170 0 4 0 3/26/2016 63 170 0 4 0 3/25/2016 63 170 0 4 0 3/24/2016 1251 220 0 3 14 3/23/2016 58 160 0 3 0 3/22/2016 58 160 0 3 0 3/21/2016 58 160 0 3 0 3/20/2016 58 160 0 3 0 3/19/2016 58 160 0 3 0 3/18/2016 58 160 0 3 0 3/17/2016 58 160 0 3 0 3/16/2016 58 160 0 3 0 3/15/2016 58 160 0 3 0 3/14/2016 56 160 0 3 0 3/13/2016 53 160 0 3 0 3/12/2016 50 160 0 3 0 3/11/2016 47 160 0 3 0 Date Tubing IA OA OOA Water Injection 3/10/2016 44 160 0 3 0 3/9/2016 63 160 0 3 0 3/8/2016 63 160 0 3 0 3/7/2016 63 160 0 3 0 3/6/2016 63 160 0 3 0 3/5/2016 63 160 0 3 0 3/4/2016 63 160 0 3 0 3/3/2016 63 160 0 3 0 3/2/2016 63 160 0 3 0 3/1/2016 63 160 0 3 0 2/29/2016 63 160 0 3 0 2/28/2016 63 160 0 3 0 2/27/2016 63 160 0 3 0 2/26/2016 63 160 0 3 0 2/25/2016 63 160 0 3 0 2/24/2016 63 160 0 3 0 2/23/2016 63 160 0 3 0 2/22/2016 63 160 0 3 0 2/21/2016 63 160 0 3 0 2/20/2016 63 160 0 3 0 2/19/2016 63 160 0 3 0 2/18/2016 63 160 0 3 0 2/17/2016 63 160 0 3 0 2/16/2016 63 160 0 3 0 2/15/2016 63 160 0 3 0 2/14/2016 63 160 0 3 0 2/13/2016 63 160 0 3 0 2/12/2016 63 160 0 3 0 2/11/2016 63 160 0 3 0 2/10/2016 63 160 0 3 0 2/9/2016 63 160 0 3 0 2/8/2016 63 160 0 3 0 2/7/2016 63 160 0 3 0 2/6/2016 63 160 0 3 0 2/5/2016 63 160 0 3 0 2/4/2016 63 160 0 3 0 2/3/2016 63 160 0 3 0 2/2/2016 63 160 0 3 0 2/1/2016 63 160 0 3 0 1/31/2016 63 160 0 3 0 1/30/2016 63 160 0 3 0 1/29/2016 63 160 0 3 0 1/28/2016 63 165 0 3 0 1/27/2016 53 165 0 3 0 1/26/2016 53 165 0 3 0 1/25/2016 59 165 0 3 0 1/24/2016 61 165 0 3 0 1/23/2016 59 165 0 3 0 1/22/2016 63 165 0 3 0 1/21/2016 1277 165 0 3 16 1/20/2016 63 165 0 3 0 Date Tubing IA OA OOA Water Injection 1/19/2016 63 165 0 3 0 1/18/2016 63 165 0 3 0 1/17/2016 63 165 0 3 0 1/16/2016 63 165 0 3 0 1/15/2016 63 165 0 3 0 1/14/2016 63 165 0 3 0 1/13/2016 58 165 0 3 0 1/12/2016 58 165 0 3 0 1/11/2016 63 165 0 3 0 1/10/2016 62 165 0 3 0 1/9/2016 1464 165 0 3 30 1/8/2016 1579 165 0 3 55 1/7/2016 58 165 0 3 0 1/6/2016 46 165 0 3 0 1/5/2016 46 165 0 3 0 1/4/2016 46 165 0 3 0 1/3/2016 48 165 0 3 0 1/2/2016 48 165 0 3 0 1/1/2016 46 165 0 3 0 12/31/201 44 165 0 3 0 12/30/201 63 165 0 3 0 gild O O O O O O O O O O O O O ti O m �D y N Well: IRU 14-31 Desc: Disposal Permit to drill: 1750080 Admin Approval: DID #23 API: 50-283-20045-00-00 Date Range: l2/30/2015-01/02/2017 Date Tubing IA OA OOA Water Injection 1/2/2017 44 118 18 0 0 1/1/2017 44 118 18 0 0 12/31/201 44 118 18 0 0 12/30/201 44 118 18 0 0 12/29/201 44 118 18 0 0 12/28/201 44 118 18 0 0 12/27/201 44 118 18 0 0 12/26/201 43 118 18 0 0 12/25/201 41 118 18 0 0 12/24/201 1160 118 18 0 20 12/23/201 40 118 18 0 0 12/22/201 41 118 18 0 0 12/21/201 42 118 18 0 0 12/20/201 42 118 0 12/19/201 42 118 0 12/18/201 42 118 0 12/17/201 42 118 0 12/16/201 42 118 0 12/15/201 42 118 0 12/14/201 42 118 0 12/13/201 0 12/12/201 100 118 0 18 0 12/11/201 100 118 0 18 0 12/10/201 100 118 0 18 0 12/9/2016 100 118 0 18 0 12/8/2016 0 12/7/2016 100 118 0 18 0 12/6/2016 40 118 0 18 0 12/5/2016 39 118 0 18 0 12/4/2016 1207 118 0 18 13 12/3/2016 42 118 0 18 0 12/2/2016 1021 110 0 20 14 12/1/2016 100 110 0 20 0 11/30/201 100 110 0 20 0 11/29/201 100 118 0 20 0 11/28/201 100 110 0 0 0 11/27/201 75 110 0 0 0 11/26/201 60 110 0 0 0 11/25/201 53 110 0 0 0 11/24/201 52 110 0 0 0 11/23/201 50 110 0 0 0 11/22/201 50 110 0 0 0 11/21/201 50 110 0 0 0 Date Tubing IA OA OOA Water Injection 11/20/201 50 110 0 0 0 11/19/201 50 110 0 0 0 11/18/201 50 110 0 0 0 11/17/201 50 110 0 0 0 11/16/201 44 118 0 0 0 11/15/201 44 118 0 0 0 11/14/201 44 118 0 0 0 11/13/201 44 118 0 0 0 11/12/201 44 118 0 0 0 11/11/201 44 118 0 0 0 11/10/201 44 118 0 0 0 11/9/2016 44 118 0 0 0 11/8/2016 43 118 0 0 0 11/7/2016 44 118 0 0 0 11/6/2016 43 118 0 0 0 11/5/2016 43 120 0 0 0 11/4/2016 43 120 0 0 0 11/3/2016 43 120 0 0 0 11/2/2016 43 130 0 0 0 11/1/2016 43 130 0 0 0 10/31/201 42 130 0 0 0 10/30/201 42 130 0 0 0 10/29/201 42 130 0 0 0 10/28/201 42 130 0 0 0 10/27/201 42 130 0 0 0 10/26/201 42 130 0 0 0 10/25/201 42 130 0 10/24/201 42 130 0 10/23/201 42 130 0 10/22/201 42 130 0 10/21/201 42 130 0 10/20/201 42 130 0 10/19/201 42 130 0 10/18/201 42 130 0 0 0 10/17/201 41 130 0 0 0 10/16/201 41 130 0 0 0 10/15/201 42 130 0 0 0 10/14/201 40 130 0 0 0 10/13/201 1071 130 0 0 33 10/12/201 42 130 0 0 0 10/11/201 42 130 0 10/10/201 41 130 0 10/9/2016 41 130 0 10/8/2016 40 100 0 10/7/2016 40 100 0 10/6/2016 40 100 0 10/5/2016 40 100 0 10/4/2016 38 100 0 0 0 10/3/2016 1088 100 0 0 23 10/2/2016 41 100 0 0 0 10/1/2016 41 100 0 0 0 Date Tubing IA OA OOA Water Injection 9/30/2016 41 100 0 0 0 9/29/2016 41 100 0 0 0 9/28/2016 41 100 0 0 0 9/27/2016 41 100 0 0 0 9/26/2016 41 120 0 0 0 9/25/2016 41 120 0 0 0 9/24/2016 41 120 0 0 0 9/23/2016 41 120 0 0 0 9/22/2016 41 120 0 0 0 9/21/2016 41 120 0 0 0 9/20/2016 41 120 0 0 0 9/19/2016 41 120 0 0 0 9/18/2016 41 120 0 0 0 9/17/2016 41 120 0 0 0 9/16/2016 41 120 0 0 0 9/15/2016 41 120 0 0 0 9/14/2016 41 120 0 0 0 9/13/2016 41 120 0 0 0 9/12/2016 41 120 0 0 0 9/11/2016 41 120 0 0 0 9/10/2016 41 120 0 0 0 9/9/2016 41 120 0 0 0 9/8/2016 41 120 0 0 0 9/7/2016 41 120 0 0 0 9/6/2016 40 120 0 0 0 9/5/2016 40 120 0 0 0 9/4/2016 38 120 0 0 0 9/3/2016 39 120 0 0 0 9/2/2016 38 120 0 0 0 9/1/2016 33 120 0 0 0 8/31/2016 1000 120 0 0 17 8/30/2016 43 120 0 0 0 8/29/2016 41 120 0 0 0 8/28/2016 995 120 0 0 22 8/27/2016 43 120 0 0 0 8/26/2016 43 120 0 0 0 8/25/2016 42 120 0 0 0 8/24/2016 42 120 0 0 0 8/23/2016 42 120 0 0 0 8/22/2016 42 120 0 0 0 8/21/2016 42 120 0 0 0 8/20/2016 42 120 0 0 0 8/19/2016 41 120 0 0 0 8/18/2016 41 120 0 0 0 8/17/2016 41 120 0 0 0 8/16/2016 34 120 0 0 0 8/15/2016 41 120 0 0 0 8/14/2016 41 120 0 0 0 8/13/2016 41 120 0 0 0 8/12/2016 41 120 0 0 0 8/11/2016 41 120 0 0 0 Date Tubing IA OA ODA Water Injection 8/10/2016 41 120 0 0 0 8/9/2016 41 120 0 0 0 8/8/2016 40 120 0 0 0 8/7/2016 40 140 0 0 0 8/6/2016 40 140 0 0 0 8/5/2016 41 140 0 0 0 8/4/2016 37 140 0 0 0 8/3/2016 1030 140 0 0 20 8/2/2016 37 105 0 0 0 8/1/2016 972 105 0 0 30 7/31/2016 50 105 0 0 0 7/30/2016 50 105 0 0 0 7/29/2016 50 105 0 0 0 7/28/2016 50 105 0 0 0 7/27/2016 50 105 0 0 0 7/26/2016 50 105 0 0 0 7/25/2016 50 105 0 0 0 7/24/2016 50 105 0 0 0 7/23/2016 50 105 0 0 0 7/22/2016 50 105 0 0 0 7/21/2016 50 105 0 0 0 7/20/2016 50 105 0 0 0 7/19/2016 50 105 0 0 0 7/18/2016 50 105 0 0 0 7/17/2016 50 105 0 0 0 7/16/2016 50 110 0 0 0 7/15/2016 50 110 0 0 0 7/14/2016 50 110 0 0 0 7/13/2016 50 110 0 0 0 7/12/2016 50 110 0 0 0 7/11/2016 50 110 0 0 0 7/10/2016 50 105 0 0 0 7/9/2016 50 105 0 0 0 7/8/2016 50 105 0 0 0 7/7/2016 50 105 0 0 0 7/6/2016 50 105 0 0 0 7/5/2016 50 105 0 0 7/4/2016 50 105 0 0 7/3/2016 50 95 0 0 0 7/2/2016 50 95 0 0 0 7/1/2016 50 95 0 0 0 6/30/2016 43 95 0 0 0 6/29/2016 43 95 0 0 0 6/28/2016 43 95 0 0 0 6/27/2016 42 35 0 0 0 6/26/2016 42 35 0 0 0 6/25/2016 42 35 0 0 0 6/24/2016 42 35 0 0 0 6/23/2016 42 35 0 0 0 6/22/2016 42 35 0 0 0 6/21/2016 37 35 0 0 Date Tubing IA OA OOA Water Injection 6/20/2016 37 35 0 0 6/19/2016 37 35 0 0 6/18/2016 43 35 0 0 6/17/2016 43 35 0 0 6/16/2016 43 35 0 0 6/15/2016 43 35 0 0 6/14/2016 43 35 0 0 0 6/13/2016 43 35 0 0 0 6/12/2016 43 35 0 0 0 6/11/2016 43 35 0 0 0 6/10/2016 43 35 0 0 0 6/9/2016 43 35 0 0 0 6/8/2016 61 35 0 0 0 6/7/2016 61 35 0 0 0 6/6/2016 60 35 0 0 0 6/5/2016 60 35 0 0 0 6/4/2016 60 35 0 0 0 6/3/2016 60 35 0 0 0 6/2/2016 60 35 0 0 0 6/1/2016 54 35 0 0 0 5/31/2016 42 35 0 0 0 5/30/2016 42 35 0 0 0 5/29/2016 42 35 0 0 0 5/28/2016 42 35 0 0 0 5/27/2016 42 35 0 0 0 5/26/2016 42 35 0 0 0 5/25/2016 42 35 0 0 0 5/24/2016 42 40 0 0 0 5/23/2016 42 40 0 0 0 5/22/2016 42 40 0 0 0 5/21/2016 42 40 0 0 0 5/20/2016 42 40 0 0 0 5/19/2016 42 40 0 0 0 5/18/2016 42 40 0 0 0 5/17/2016 42 40 0 0 0 5/16/2016 42 40 0 0 0 5/15/2016 42 40 0 0 0 5/14/2016 42 40 0 0 0 5/13/2016 42 40 0 0 0 5/12/2016 42 40 0 0 0 5/11/2016 42 40 0 0 0 5/10/2016 42 40 0 0 0 5/9/2016 42 40 0 0 0 5/8/2016 42 40 0 0 0 5/7/2016 42 40 0 0 0 5/6/2016 42 40 0 0 0 5/5/2016 42 40 0 0 0 5/4/2016 42 40 0 0 0 5/3/2016 42 40 0 0 0 5/2/2016 42 40 0 0 0 5/1/2016 42 40 0 0 0 Date Tubing IA OA OOA Water Injection 4/30/2016 42 40 0 0 0 4/29/2016 40 40 0 0 0 4/28/2016 961 40 0 0 33 4/27/2016 44 40 0 0 0 4/26/2016 44 40 0 0 0 4/25/2016 44 40 0 0 0 4/24/2016 44 40 0 0 0 4/23/2016 44 40 0 0 0 4/22/2016 44 40 0 0 0 4/21/2016 44 40 0 0 0 4/20/2016 43 40 0 0 0 4/19/2016 43 40 0 0 0 4/18/2016 43 40 0 0 0 4/17/2016 43 40 0 0 0 4/16/2016 43 40 0 0 0 4/15/2016 43 40 0 0 0 4/14/2016 42 40 0 0 0 4/13/2016 43 40 0 0 0 4/12/2016 43 40 0 0 0 4/11/2016 43 40 0 0 0 4/10/2016 43 40 0 0 0 4/9/2016 43 40 0 0 0 4/8/2016 43 40 0 0 0 4/7/2016 40 40 0 0 0 4/6/2016 40 40 0 0 0 4/5/2016 1089 40 0 0 28 4/4/2016 63 40 0 0 0 4/3/2016 62 40 0 0 0 4/2/2016 62 40 0 0 0 4/1/2016 62 40 0 0 0 3/31/2016 63 40 0 0 0 3/30/2016 63 40 0 0 0 3/29/2016 63 40 0 0 0 3/28/2016 63 40 0 0 0 3/27/2016 63 40 0 0 0 3/26/2016 63 40 0 0 0 3/25/2016 63 40 0 0 0 3/24/2016 63 40 0 0 0 3/23/2016 63 40 0 0 0 3/22/2016 63 40 0 0 0 3/21/2016 63 40 0 0 0 3/20/2016 63 40 0 0 0 3/19/2016 63 40 0 0 0 3/18/2016 63 40 0 0 0 3/17/2016 44 40 0 0 0 3/16/2016 44 40 0 0 0 3/15/2016 44 40 0 0 0 3/14/2016 44 40 0 0 0 3/13/2016 44 40 0 0 0 3/12/2016 44 40 0 0 0 3/11/2016 44 40 0 0 0 Date Tubing IA OA ODA Water Injection 3/10/2016 44 40 0 0 0 3/9/2016 43 40 0 0 0 3/8/2016 43 40 0 0 0 3/7/2016 43 40 0 0 0 3/6/2016 43 40 0 0 0 3/5/2016 43 40 0 0 0 3/4/2016 43 40 0 0 0 3/3/2016 43 40 0 0 0 3/2/2016 43 40 0 0 0 3/1/2016 42 40 0 0 0 2/29/2016 42 40 0 0 0 2/28/2016 42 40 0 0 0 2/27/2016 43 40 0 0 0 2/26/2016 42 40 0 0 0 2/25/2016 42 40 0 0 0 2/24/2016 40 60 0 0 0 2/23/2016 1108 60 0 0 37 2/22/2016 42 60 0 0 0 2/21/2016 42 60 0 0 0 2/20/2016 42 60 0 0 0 2/19/2016 42 60 0 0 0 2/18/2016 40 60 0 0 0 2/17/2016 1079 60 0 0 24 2/16/2016 45 30 0 0 0 2/15/2016 45 30 0 0 0 2/14/2016 45 30 0 0 0 2/13/2016 45 30 0 0 0 2/12/2016 45 30 0 0 0 2/11/2016 45 30 0 0 0 2/10/2016 44 30 0 0 2/9/2016 44 30 0 0 2/8/2016 44 30 0 0 2/7/2016 44 30 0 0 2/6/2016 44 30 0 0 2/5/2016 58 30 0 0 2/4/2016 58 30 0 0 2/3/2016 58 30 0 0 2/2/2016 58 30 0 0 2/1/2016 58 30 0 0 1/31/2016 58 30 0 0 1/30/2016 58 30 0 0 1/29/2016 58 30 0 0 1/28/2016 58 25 0 0 1/27/2016 58 25 10 0 1/26/2016 58 25 0 0 1/25/2016 58 25 10 0 1/24/2016 58 25 10 0 1/23/2016 58 25 10 0 1/22/2016 58 25 10 0 1/21/2016 58 24 10 0 1/20/2016 58 24 10 0 Date Tubing IA OA OOA Water Injection 1/19/2016 58 24 0 0 1/18/2016 58 24 0 0 1/17/2016 58 24 0 0 1/16/2016 58 24 0 0 1/15/2016 58 24 0 0 1/14/2016 58 24 0 0 1/13/2016 58 24 0 0 1/12/2016 58 25 0 0 1/11/2016 58 25 0 0 1/10/2016 58 25 0 0 1/9/2016 58 25 0 0 1/8/2016 58 25 0 0 1/7/2016 43 25 0 0 1/6/2016 58 25 0 0 1/5/2016 43 25 0 0 1/4/2016 43 25 0 0 1/3/2016 43 25 0 0 1/2/2016 43 25 0 0 1/1/2016 43 25 0 0 12/31/201 43 25 0 0 12/30/201 43 25 0 • • Chevron %10 David A. Cole Union of California Technical Team Lead Ops P.O. Box OiI 196247 Company Anchorage, 99519-6247 Tel el 907 7 7 263 7805 Fax 907 263 7847 Email dcole @chevron.com January 30, 2012 RECIVED Mr. Tom Maunder Alaska Oil & Gas Conservation Commission ( AOGCC) P B 0 2 2012 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 A!aska Oil & Gas Cons. Commission Anchorage Re: Disposal Report for the 14 -31 Well in the Ivan River Unit Dear Mr. Maunder: zl I v This is the 2011 Annual Report for UIC Class II disposal operations in the IRU 14 -31 wellbore. These disposal operations are governed by AOGCC Disposal Injection Order #23 issued 08/09/01. The attached plot shows that the injection pressures and low rates are relatively predictable and stable and do not indicate any reservoir or mechanical concerns. Specific items to note for this reporting period: • In 2011 the fluids injected into the IRU 14 -31 well were essentially produced water from the Ivan River, Pretty Creek and Lewis River fields. • No MIT was required in 2011 e u to (ze -( I Z _ As you are aware, Union sold its Cook Inlet Oil and Gas operations to Hilcorp Alaska LLC. The closing date was December 31, 2011. If you have any questions or concerns going forward about the enclosed information, please contact Larry Greenstein, who now works for Hilcorp. His phone number is 777 -8322. Sincere! David A. Cole Technical Team Lead - Operations Attachment Union Oil Company of California / A Chevron Company http: / /www.chevron.com Plot • ssure & Rate vs Time - Well IVAN R 14111 400 200 180 350 -7" -9 5/8" 16" 160 300 - Tubing - -_ -- -Vol 14 -31 140 250 120 • n 200 102 E a ` 80 150 60 100 ■ 40 50 111111 20 o '� 11,111,1,1,��1,111,11,11,�'111 •i��•: a . o o . a ao n 17 , m 17 co Q m O . M m N N N N N N n In n co Date 7" 9 5/8" 16" Tubing Vol 14 -31 TIO Report 01/01/12 10 0 0 100 0 12/31/11 10 0 0 _ 100 Data Sheet 12/30/11 10 0 0 100 12/29/11 10 0 0 100 12/28/11 10 0 0 100 o IVAN R 14 -31 12/27/11 10 0 0 100 0 12/26/11 ` 10 0 0 100 0 12/25/11 10 0 0 100 0 INJECTION 12/24/11 10 0 0 100 0 12/23/11 10 0 0 100 0 12/22/11 10 0 0 100 0 Permit # 12/21/11 10 0 0 ;100 22 12/20/11 10 0 0 100 0 12/19/11 10 0 0 100 0 API # 50- 283 - 20045 -00 12/18/11 10 0 0 100 0 12/17/11 10 0 0 100 0 12/16/11 10 0 0 100 0 12/31/2010 to 01/01/2012 12/15/11 • 10 0 0 100 0 12/14/11 10 0 0 100 0 12/13/11 10 0 0 100 0 12/12/11 10 0 0 100 0 12/11/11 10 0 0 100 0 12/10/11 10 0 0 .100 0 12/09/11 10 0 0 100 12/08/11 10 0 0 100 0 12/07/11 10 0 0 100 0 12/06/11 10 0 0 = 100 0 12/05/11 10 0 0 ' 100 0 12/04/11 10 0 0 100 0 12/03/11 10 0 0 100 0 12/02/11 10 0 0 100 0 12/01/11 10 0 0 100 0 11/30/11 10 0 0 100 0 11/29/11 10 0 0 100 0 11/28/11 0 0 0 100 0 11/27/11 10 0 0 100 0 • • Chevron Chantal Walsh Union Oil Company of California Petroleum Engineer P.O. Box 196247 %.1 Anchorage, AK 99519 -6247 Tel 907 263 7627 Fax 907 263 7828 Email walshc @chevron.com June 7, 2011 Mr. Tom Maunder PI Alaska Oil & Gas Conservation Commission (AOGCC) 333 West 7 Avenue, Suite 100 f �l l� Anchorage, AK 99501 tEn tht & Cut, Cons. C mirnission Re: Disposal Report for the 14 -31 Well in the Ivan River Unit AnchRritge Dear Mr. Maunder: This is the 2010 Annual Report for UIC Class II disposal operations in the IRU 14 -31 wellbore. These disposal operations are governed by AOGCC Disposal Injection Order #23 issued 08/09/01. The attached plot shows that the injection pressures and low rates are relatively predictable and stable and do not indicate any reservoir or mechanical concerns. Specific items to note for this reporting period: • In 2010 the fluids injected into the IRU 14 -31 well were essentially produced water from the Ivan River, Pretty Creek and Lewis River fields and fluids from stimulation and well work prep. • On October 22, 2010 a successful MIT was witnessed by the SOA on IRU 14 -31. Please contact me if I can be of further assistance at 907 - 263 -7627. Best regards, L L Chantal Walsh cc: Dave Whitacre Gary Ross Larry Greenstein Well File Union Oil Company of California / A Chevron Company http: / /www.chevron.com • Plot Pressure & Rate vs Time - Well IVAN R 14 -31 400 - ,. — 200 180 350 _ — - -- - -- ---- Tubing 160 300 Vol 14 -31 -- 140 _ 120 a N N 200 - - - — 100 _ 21 di a 80 150 - - - --- -- - --- - -- - - I 60 100 _ — - . 40 ■ _. _ — 50 ' _ . —I ' n I 11 20 ° °. o 0 0 0 0 0 0 0 0 0 0 0 M o L'1 O L'1 L'1 P2 N N co N N N Date 12/31/2009 60 157 0 TIO Report 1/1/2010 60 156 0 Data Sheet 1/2/2010 60 209 21 1/3/2010 60 157 0 Ivan R 14 -31 1/4/2010 60 - 157 0 1/5/2010 60 157 0 Injection 1/6/2010 60 157 0 1/7/2010 60 157 0 Permit # 1920880 1/8/2010 60 157 0 1/9/2010 60 208 19 API# 50- 283 - 20086 -00 1/10/2010 60 156 0 1/11/2010 60 157 0 12/31/2009 to 1/01/2011 1/12/2010 60 157 0 1/13/2010 60 157 0 1/14/2010 60 157 0 1/15/2010 60 157 0 1/16/2010 60 157 23 1/17/2010 60 157 0 1/18/2010 60 157 0 1/19/2010 60 157 0 1/20/2010 60 157 0 1/21/2010 60 157 18 1/22/2010 60 157 0 1/23/2010 60 157 0 1/24/2010 60 157 0 1/25/2010 60 157 0 1/26/2010 60 157 0 1/27/2010 60 157 0 1/28/2010 60 157 0 1/29/2010 60 157 0 1/30/2010 60 227 18 1/31/2010 60 157 0 • • • Chevron Chantal Walsh Union Oil Company of California Petroleum Engineer P.O. Box 196247 Anchorage, 99519-6247 Tel 907 7 7 263 7627 Fax 907 263 7828 Email walshc @chevron.com December 22, 2010 Mr. Tom Maunder t� Alaska Oil & Gas Conservation Commission (AOGCC) 333 West 7 Avenue, Suite 100 tl'N 4 (1j Anchorage, AK 99501 a , ,ry p y /py Re: Disposal Report for the 14 -31 Well in the Ivan River Unit 4ih;nLr^mt Dear Mr. Maunder: k *5 -Q® This is the 2009 Annual Report for UIC Class II disposal operations in the IRU 14 -31 welibore. These disposal operations are governed by AOGCC Disposal Injection Order #23 issued 08/09/01. The attached plot shows that the injection pressures and low rates are relatively predictable and stable and do not indicate any reservoir or mechanical concerns. Specific items to note for this reporting period: • In 2009 the fluids injected into the IRU 14 -31 well were essentially produced water from the Ivan River, Pretty Creek and Lewis River fields and fluids from stimulation and well work prep. • The jump in tubing pressure from —35 psi to —170 psi in April, 2009 was due to the clearing up of a plugged needle valve on the tubing gauge resulting in inaccurate tubing pressure measurements prior to May 01, 2009. Please contact me if I can be of further assistance at 907 - 263 -7627. Best regards, Chantal Walsh cc: Dave Whitacre Gary Ross Larry Greenstein Well File Union Oil Company of California / A Chevron Company http: / /www.chevron.com ' Plot Pressure & Rate vs Time - Well IVAN R 14 -31 , 400 - .'P^ 200 180 350 .— - - --- - 7" —9 5/8" 16" 160 ••Tubing 300 - -- -- — - - -- -- —Vol 14 -31 - 140 250 120 ■ P. N 200 -- 100 y m a` • — , 80 150 -- 60 100 • 40 50 1H 20 0 0 1144.. m m rn a m a a m a a m rn a 0 0 0 0 0 0 0 0 0 0 0 0 0 M en O c y 0 M N N co N N co N co l'7 O �D 1� co O O O O O o a O O O Date 7" 9 5/8" 1 16" rnbtrtg 'Vol 14 =31 TIO Report 01/01/10 60 0 0 156 0 12/31/09 60 0 0 157 o Data Sheet 12/30/09 60 0 0 157 0 12/29/09 60 0 0 157 0 12/28/09 60 0 0 157 o IVAN R 14 -31 12/27/09 60 0 0 157 0 12/26/09 60 0 0 157 23 12/25/09 60 0 0 157 0 INJECTION 12/24/09 60 0 0 157 0 12/23/09 60 0 0 157 0 12/22/09 60 0 0 157 0 Permit # 1750080 12/21/09 60 0 0 157 0 12/20/09 60 0 0 156 0 12/19/09 60 0 0 156 14 API # 50- 283 - 20045 -00 12/18/09 60 0 0 i 156 32 12/17/09 60 0 01 157 0 12/16/09 60 0 0 i 157 0 12/31/2008 to 01/01/2010 12/15/09 60 Of 0 157 0 12/14/09 60 0 0 157 0 12/13/09 60 0 0 ' 156 0 12/12/09 60 0 0, 156 0 12/11/09 60 0 0 156 0 12/10/09 60 0 0 156 0 12/09/09 60 0 0 156 0 12/08/09 60 0 0 156 0 12/07/09 60 0 0 156 0 12/06/09 60 0 0 156 0 12/05/09 60 0 0' 156 12/04/09 60 0 0' 156 12/03/09 60 0 0 j 156 0 12/02/09 60 0 0 157 0 12/01/09 60 0 0 . 156 0 11/30/09 60 1* 0 156 0 11/29/09 60 0 0 156 0 11/28/09 60 0 0 156 0 11/27/09 S8 0 0 156 24 12/30/2010 10:27 AM - TIO Reports 7e.xls J J Dolan Master Well List TIO Report 2010 01 01.xIs IVAN R 14 -31 Chevron ~ July 13, 2009 Chantal Walsh Petroleum Engineer ~~~,d'~'~~~ ~u~. Y ~ ~no~ Mr. Jim Regg Alaska Oil & Gas Conservation Commission (AOGCC) 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Disposal Report for the 14-31 Well in the Ivan River Unit Dear Mr. Regg: ,~igska Oil & Gas ~~ns. G~mmi~~io~~ Anchorage This is the 2008 Annual Report for UIC Class II disposal operations in the IRU 14-31 wellbore. These disposal operations are governed by AOGCC Disposal Injection Order #23 issued 08/09/01. The attached plot shows that the injection pressures and low rates are relatively predictable and stable and do not indicate any reservoir or mechanical concerns. Specific items to note for this reporting period: • In 2008 the fluids injected into the IRU 14-31 well were essentially produced water from the Ivan River, Pretty Creek and Lewis River fields and fluids from stimulation and well work prep. • On October 26, 2008 a successful MIT was completed on IRU 14-31. Please contact me if I can be of further assistance at 907-263-7627. Best regards, ,, ~ ~ ~.J Chantal Walsh cc: Dave Whitacre Chris Holden Larry Greenstein Well File Union Oil Company of California P.O. Box 196247 Anchorage, AK 99519-6247 Tel 907 263 7627 Fax 907 263 7828 Email walshc@chevron.com Union Oil Company of California / A Chevron Company http://www.chevron.com Plot Pressure & Rate vs Time - Well IVAN R 14-31 1000 3000 1 i ~ ~,~ i = 900 ~9 5/8" i 2500 - i ~g~ - ----- - ---- ~Tubing ~ 800 ~Vol 1431 I I - 700 ~: - 2000 - -- - - - -- --- --- --- - - - f 600 ~ 7 1500 - - - y 5C y ~ - -- - _ _ _ _ --- - - (~ ~ a ~ 400 1000 - _ --- t i 300 - 200 500 - - - - - - 100 ' 0 0 0 0 0 0 0 0 0 0 0 ~n ~m Lnm ~m r~m N t+J t0 ~ N ~ O O O ~ Date 7" 9 5/8" 16" Tubing Vol 1431 12/31/08 80 0 0 30 0 12/30/08 80 0 0 30 0 12/29/08 80 0 0 30 0 12/28/08 80 0 0 30 0 12/27/O8 80 0 0 30 0 12/26/08 80 0 0 30 0 12/25/08 80 0 0 30 0 12/24/O8 80 0 0 30 0 12/23/08 80 0 0 30 0 12/22/08 0 0 0 30 0 12/21/O8 80 0 0 30 0 12/20/08 0 0 0 30 0 12/19/08 0 0 0 30 0 12/18/08 0 0 0 30 0 12/17/08 0 0 0 30 0 12/16/08 30 0 12/15/O8 30 0 12/14/08 0 0 0 31 0 12/13/08 0 0 0 30 0 12l12l08 0 0 0 30 0 12/11 /08 0 0 0 30 0 12/10/08 80 0 0 30 0 12/09/08 80 0 0 30 0 12/08/08 80 0 0 30 0 12/07/O8 80 0 0 30 0 12/06/O8 80 0 0 30 0 12/05/08 80 0 0 30 0 12/04/08 80 0 0 30 0 12/03/08 80 0 0 30 0 12/02/08 80 0 0 30 0 12/01 /08 80 0 0 30 0 11/30/08 SO 0 0 30 0 11/29/O8 80 0 0 30 0 11/28/08 80 0 0 30 0 11J27/08 80 0 0 30 0 11/26/08 80 0 0 30 0 7/13i2009 3:05 PM - T IO Reports 7e.xls J J Dolan TIO Report Data Sheet IVAN R 14-31 INJECTION Permit # 1750080 API # 50-283-20045-00 12/30/2007 to 12/31/2008 IRU 14-31 2008 TIO (4).uls IVAN R 14-31 Chevron September 8, 2008 Gary A. Orr Reservoir Engineer Mr. Jim Regg Alaska Oil & Gas Conservation Commission (AOGCC) 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Disposal Report for the 14-31 Well in the Ivan River Unit Dear Mr. Regg: SEP 0 9 2008 Alaska ail ~ ~~~ ~©ns. Con~~nission AnCi iGi'~~2 This is the 2007 Annual Report for UIC Class II disposal operations in the IRU 14-31 wellbore. These disposal operations are governed by AOGCC Disposal Injection Order #23 issued 08/09/01. The attached plot shows that the injection pressures and low rates are relatively predictable and stable and do not indicate any reservoir or mechanical concerns. Specific items to note for this reporting period: • In 2007 the fluids injected into the IRU 14-31 well were essentially produced water from the Ivan River, Pretty Creek and Lewis River fields. Please contact me if I can be of further assistance at 907-263-7800. Best regards, ~d .,~ ~ Gary Orr cc: Dave Whitacre Jean Bodeau Larry Greenstein Well File Union Oil Company of California P.O. Box 196247 Anchorage, AK 99519-6247 Tel 907 263 7800 Fax 907 263 7828 Email orrga@chevron.com Union Oil Company of California / A Chevron Company http://www.chevron.com Plot Pressure & Rate vs Time -Well IVAN R 14-31 F 200 1600 7" ~9 5/8" 180 1400 Tubing Vol 14-31 160 1200 140 1000 120 d L d 1 N 800 ~ L a so 600 60 400 40 200 20 0 0 ~ o 0 0 0 0 0 0 0 0 0 ~ ~ o • a ~ • i~~~ i'~i~~~ Fi~i~ 1I~~~i I 1 ~~ ~ SPUD ~ 5 SUS $11 ~J76 ~tY ~+D' ~ 1' 7G ~ rte' Far 7" ~. 2~7' ~.d~ 11E-~q FJt~tt Tublra~ 1 ~-3f4" +'1~a~ l1~56 gar ~-H Per 8t ~'9K~~` ~ ~ 1 ~ 'F Proflf~ ax $' { 31 1~~ TTY ~ ~y' based oar , B6r Vw'L I~enhy ~3ttlde at 29$x' F~I~ , ~ 1~~~ Perts X789' - 329' 12 sPF s-8-0'1 ~~d sin Equali~atlon ~am~nt F#~t~ln~r ~t ~' Thru Flit B~ ~ ~an~snt Pit~~ - 35~0~' ~ta~ t:allar ~ ~' d Annulu^ 1T Bafwarr~ #~i5' and X1058' €CBL ~~ nclualv+a} ' - ' Bgz'~d 200 5~€ 7" ~ , ~~ F`~h ~1 BHA Tam! LingtF~ 221 P~bet~i} ~n Buttam at 1~,~4' Top ~ 74' ~-t#prrr $ ~'~~?i' Flsh #~ Yw.~. ~ ~,.'~ ~~ngth ' ~ Tap ~ 7:~4fi" B~attam Q T~' Flsh #4~ 2~~'6' 2,2f3' T~# & ~3,2Q~ 31 ' b_ P. Tip ~ 3610' 8~#tx~t ~ 956' Cemerr# PIuQ ~' - '~' 5 ils' ~,~n*r ~ 1 ~t)00` (%~ 1 ~ ~emerrt l~lu~ 1 ~, y 0~ - 7 a'te' mnrtit FHup 1.65# - 1 ~,~C?0' i k 1`C} ~ y 0.958' ~ - _ -#12 . . AOGCC Memorandum Date: July 16, 2007 To: DIO 23 From: Jim Regg, Petroleum Engineer ~e.¡1 1¡1~ò1 Subject: Annual Disposal Injection Performance Report Chevron submitted the 2006 Ivan River Unit ("IRU") Annual Disposal Injection Performance Report on July 9,2007 as required by Disposal Injection Order ("DIO") 23, Rule 4 and 20 AAC 25.432. Supplemental information - namely well pressures for wells offsetting disposal injector IRU 14-31 - was provided on July 16, 2007 at the Commission's request. I have completed a review of the disposal injection performance report and find it to be complete. Based on the performance data provided, I concur with the findings of Chevron that there is no indication of any reservoir or mechanical concerns with the ongoing disposal injection operations. The next mechanical integrity test is due December 2008. Monitoring ofIRU 14-31 disposal operations should continue as directed in DIO 23. . Regg, James B (DOA) From: Sent: To: Cc: Subject: Greenstein, Larry P [Greensteinlp@chevron.com] Monday, July 16, 2007 11:46 AM Regg, James B (DOA) Orr, Gary A.; Whitacre, Dave S; Bodeau, Jean 2006 Annual Disposal Report for IRU 14-31 (010 #23) IRU 14-31 2006 Offsets TIO Report.xls Attachments: IRU 14-31 2006 Offsets 110 Rep... «IRU 14-31 2006 Offsets TIO Report.xls» Jim, . éJ 1l ¡folO? \L.,~1 In addition to the disposal well plot provided in the main body of the annual report sent to you last week, please find attached plots for the tubing and casing pressures for the /. offset wells at the Ivan River Field. Two of the wells were producing and two of the v' wells were shut-in for the 2006 reporting period. If there is anything else you would like to see, feel free to call me. Larry 263-7661 1 1 f.D e l"- e ..... 900 700 400 200 41 vs 41 1800 1600 1400 1200 1000 800 600 400 200 o -9 5/8" 3/8" -Vol 44-36 f.D e I"- vs #11 . . Chevron === Gary A. Orr Reservoir Engineer Union Oil Company of California P.O. Box 196247 Anchorage, AK 99519-6247 Tel 907 263 7800 Fax 907 263 7828 Email orrga@chevron.com July 9, 2007 E(~E\VED Mr. Jim Regg Alaska Oil & Gas Conservation Commission (AOGCC) 333 West ih Avenue, Suite 100 Anchorage, AK 99501 JUL 1 0 2007 commission O'! 0 i\.!a:::KCí ut <y Re: Disposal Report for the 14-31 Well in the Ivan River Unit Dear Mr. Regg: This is the 2006 Annual Report for UIC Class II disposal operations in the IRU 14-31 wellbore. These disposal operations are governed by AOGCC Disposal Injection Order #23 issued 08/09/01. The attached plot shows that the injection pressures and low rates are relatively predictable and stable and do not indicate any reservoir or mechanical concerns. Specific items to note for this reporting period: · In 2006 the fluids injected into the IRU 14-31 well were essentially produced water from the Ivan River, Pretty Creek and Lewis River fields and workover fluids associated with coil tubing operations at Pretty Creek and Lewis River Fields. · On December 5, 2006 a successful MIT was completed on IRU 14-31. Please contact me if I can be of further assistance at 907-263-7800. ::1;S~ ~ cc: Dave Whitacre Jean Bodeau Larry Greenstein Well File Union Oil Company of California I A Chevron Company http://www.chevron.com 3000 2500 2000 1500 1000 500 o -7" -9 5/8" Plot Pressure & Rate vs - Well IVAN R 14-31 600 500 400 300 200 100 o 0- :aD' 20- W 0 4211 . 12311 For ,- C$G. , '. 10-314" 40.51 K-55 o 20ar 1050 SXS TTC 0 51· Baud on Holt Ske . 1818' B..d on Equ811mt1on Thru Float Shot Stage Coli., . ,*,1 S89 SXS Annulu. TIC BeIw..n ~I 8nd 4056' (CBL NO! ConclUlIYe) r 231 28 . 29t N-80 . 101 II øoo $XS 5 112- Un.r 0 1o..00Ct . . Ivan River Field Well 14-31 . , . .. . . . ".1. -, . . 4 '-----~ SPUD 5Æl75 SUSP 8/1 W75 2.-7/8· 6." N-8O Butt Tubing Baker 3-tI Pack$r at 2903- IF" ProfU. at 29491 {2.312 10) Baker WL Reentry Guide at 29821 /peñs 3189· - 3209· 12 SPF 6-8-01 Cement RetaIner at 32251 /camønt Plug 33W . 3508' 6862" .6882' Sqz'd 200 SX . F''-ih'1 BHA Total Length 228" P~y 0fI Bottom at lO,064' Ash 12 2206' of 2 7181 D. P. Top 0 74961 Bottom 0 9701 þ FIsh #3 W.O. Assy & D.C.·s Length aæ Top 0 7345' Bottom Q T12S1 FI23h;M 2878' 2-213- TBG & 3200 51121 D.P. Top 0 3ð 1 rJ Bottom 0 9586" Cement Plug 7eocr .992T Osment Plug 10.100" ·10,350' Cement Plug 10.65(1 . 1019001 TO a 10.958' 05-01 1 :tlD . . 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501·3539 PHONE (907) 279-1433 FAX (907) 276-7542 FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION September 26,2006 Mr. Jeff Smetanka Reservoir Engineer U nocal Alaska PO Box 196247 Anchorage, AK 99519 Re: Disposal Report for Ivan River Unit 14-31 Dear Mr. Smetenka: The Alaska Oil and Gas Conservation Commission has reviewed your annual report for disposal operations in Ivan River Unit, Well 14-31 dated August 15,2006. The pressure data and observations documented in the report appear to demonstrate that the injected Class II fluids continue to be confined to the permitted disposal injection zone. Please be reminded that the annual report is due on or before July 1 (refer to Disposal Injection Order 23, Rule 4). An extension may be granted on a case-by-case basis upon request should it not be possible to meet that requirement. Sincerely, -----. ~' ..' '. ,O;i'W< ~ k. e/À!:C/~ '-..J ," ""-J0' ! \- James B. Regg \ ' Sr. Petroleum Engineer #q Hilcorp Alaska, LLC March 27, 2018 Mr. Hollis S. French, Chair APR 0 2 2018 A®GCC Alaska Oil & Gas Conservation Commission 333 W. 7u' Avenue, Suite 100 Anchorage, Alaska 99501-3539 Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpolnt Drive Suite 100 Anchorage, AK 99503 Phone: 907/777-8322 Fax: 907/777-8580 Re: 2017 Annual Disposal Report for the 13-31 & 14-31 Wells in the Ivan River Unit Dear Mr. French, This is the 2017 Annual Report for the UIC Class II disposal operation in the IRU 13-31 (DIO 35) and IRU 14-31 (DIO 23) wellbores. The attached plots shows that injection rates and pressures for both wells were well below the regulatory limit of 4 barrels per minute and 5000psig. Furthermore, injection and annuli pressures indicate no mechanical concerns and that the injected fluid was contained to the approved disposal zone. Specific items to note for this reporting period: • A MIT is required every two years and the last MIT was performed 6-28-16. • In 2017, the fluids injected into the IRU 13-31 and 14-31 (432 and 314 barrels, respectively) wells were produced water from the Ivan River, Pretty Creek, and Lewis River fields. • Maximum pressures in both wells during injection never exceeded 1600psig. Sincerely, 1�k&' I 4jat* Trudi Hallett Reservoir Engineer Attachment 1 — IRU 13-31 Injection rates and pressures Attachment 2 — IRU 14-31 Injection rates and pressures 1600- 1400 1200 1000 800 600 400 200 0' r- 0112017 IN 013-31 WDW - [50.0587.00041 0212017 0312017 04,12017 05/2017 0612017 07/2017 08/2017 0912017 10/2017 11/2017 — Tubing — IA — OA OOA — Water Injection 12/2017 200 ISO 100 50 0 Well: IRU 13-31 Desc: Shut-in Permit to drill: 1920880 Admin Approval: DID #35 API: 50-283-20086-00-00 Date Range: 01/01/2017 - 12/31/2017 Date Tubing IA OA OOA Water Injection 12/31/201 80 170 0 0 0 12/30/201' 80 170 0 0 0 12/29/201 80 170 0 0 0 12/28/201 80 170 0 0 0 12/27/201 80 170 0 0 0 12/26/201 80 170 0 0 0 12/25/201' 80 170 0 0 0 12/24/201 80 170 0 0 0 12/23/201' 80 170 0 0 0 12/22/201' 80 170 0 0 0 12/21/201 80 170 0 0 0 12/20/201' 80 170 0 0 0 12/19/201 80 170 0 0 12/18/201" 80 170 0 0 0 12/17/201 80 170 0 12/16/201 80 170 0 12/15/201' 80 170 0 12/14/201 80 170 0 12/13/201' 80 170 0 0 0 12/12/201' 80 170 0 0 0 12/11/201' 80 170 0 0 0 12/10/201' 80 170 0 0 0 12/9/2017 81 170 0 0 0 12/8/2017 80 170 0 0 0 12/7/2017 80 170 0 0 0 12/6/2017 80 170 0 0 0 12/5/2017 80 170 0 0 0 12/4/2017 80 170 0 0 0 12/3/2017 80 170 0 0 0 12/2/2017 80 170 0 0 0 12/1/2017 80 170 0 0 0 11/30/201' 80 170 0 0 0 11/29/201' 80 170 0 0 0 11/28/201' 80 170 0 0 0 11/27/201' 80 170 0 0 0 11/26/201 80 170 0 0 0 11/25/201' 80 170 0 0 0 11/24/201' 80 175 0 0 0 11/23/201' 80 175 0 0 0 11/22/201' 80 180 0 0 0 11/21/201' 80 180 0 0 0 11/20/201' 80 180 0 0 0 11/19/201' 80 180 0 0 0 11/18/201' 80 180 0 0 0 11/17/201' 80 180 0 0 0 11/16/201' 80 180 0 0 0 11/15/201 80 180 0 0 0 11/14/201' 80 170 0 0 0 11/13/201' 80 170 0 0 0 11/12/201' 80 170 0 0 0 11/11/201 80 170 0 0 0 11/10/201' 80 170 0 0 0 11/9/2017 180 170 0 0 0 11/8/2017 180 170 0 0 0 11/7/2017 180 170 0 0 0 11/6/2017 180 170 0 0 0 11/5/2017 180 170 0 0 0 11/4/2017 180 170 0 0 0 11/3/2017 180 170 0 0 0 11/2/2017 180 170 0 0 0 11/1/2017 182 170 0 0 0 10/31/201' 183 170 0 0 0 10/30/201' 181 160 0 0 0 10/29/201' 183 160 0 0 0 10/28/201' 184 160 0 0 0 10/27/201 180 160 0 0 0 10/26/201' 1346 160 0 0 31 10/25/2017 212 160 0 0 0 10/24/201' 212 160 0 10/23/201 212 160 0 10/22/201' 212 160 0 10/21/201' 212 160 0 10/20/201' 212 160 0 10/19/201' 212 160 0 0 0 10/18/201- 211 160 0 0 0 10/17/201' 210 160 0 0 0 10/16/201' 215 190 0 0 0 10/15/201 1375 190 0 0 30 10/14/201' 1235 190 0 0 30 10/13/201' 1210 190 0 0 23 10/12/201' 40 190 0 0 0 10/11/201' 1250 190 0 0 11 10/10/201' 1250 190 0 0 30 10/9/2017 1215 190 0 0 10 10/8/2017 1139 190 0 0 20 10/7/2017 90 190 0 0 0 10/6/2017 90 190 0 0 0 10/5/2017 90 190 0 0 0 10/4/2017 90 190 0 0 0 10/3/2017 90 190 0 0 0 10/2/2017 90 190 0 0 0 10/1/2017 80 190 0 0 0 9/30/2017 90 190 0 0 0 9/29/2017 80 190 0 0 0 9/28/2017 50 195 0 0 0 9/27/2017 50 200 0 0 0 9/26/2017 1050 180 0 0 17 9/25/2017 80 180 0 0 0 9/24/2017 80 180 0 0 0 9/23/2017 80 180 0 0 0 9/22/2017 80 180 0 0 0 9/21/2017 80 180 0 0 0 9/20/2017 80 180 0 0 0 9/19/2017 80 180 0 0 0 9/18/2017 80 180 0 0 0 9/17/2017 80 180 0 0 0 9/16/2017 80 190 0 0 0 9/15/2017 1321 250 0 0 26 9/14/2017 80 180 0 0 0 9/13/2017 80 180 0 0 0 9/12/2017 80 180 0 0 0 9/11/2017 80 180 0 0 0 9/10/2017 80 180 0 0 0 9/9/2017 80 180 0 0 0 9/8/2017 SO 180 0 0 0 9/7/2017 80 180 0 0 0 9/6/2017 80 180 0 0 0 9/5/2017 80 180 0 0 0 9/4/2017 80 180 0 0 0 9/3/2017 80 180 0 0 0 9/2/2017 80 190 0 0 0 9/1/2017 80 180 0 0 0 8/31/2017 80 180 0 0 0 8/30/2017 80 180 0 0 0 8/29/2017 80 180 0 0 0 8/28/2017 80 180 0 0 0 8/27/2017 80 180 0 0 0 8/26/2017 80 180 0 0 0 8/25/2017 80 180 0 0 0 8/24/2017 80 190 0 0 0 8/23/2017 80 190 0 0 0 8/22/2017 80 188 0 0 0 8/21/2017 80 188 0 0 0 8/20/2017 80 185 0 0 0 8/19/2017 50 180 0 0 0 8/18/2017 50 180 0 0 0 8/17/2017 42 170 0 0 0 8/16/2017 42 170 0 0 0 8/15/2017 42 175 0 0 0 8/14/2017 42 175 0 0 0 8/13/2017 42 175 0 0 0 8/12/2017 42 185 0 0 0 8/11/2017 48 175 0 0 0 8/10/2017 48 175 0 0 0 8/9/2017 80 170 0 0 0 8/8/2017 80 170 0 0 0 8/7/2017 80 170 0 0 0 8/6/2017 80 170 0 0 0 8/5/2017 77 170 0 0 0 8/4/2017 78 170 0 0 0 8/3/2017 78 170 0 0 0 8/2/2017 70 170 0 0 0 8/1/2017 70 170 0 0 0 7/31/2017 66 170 0 0 0 7/30/2017 66 170 0 0 0 7/29/2017 62 170 0 0 0 7/28/2017 62 170 0 1 0 7/27/2017 62 170 0 1 0 7/26/2017 63 170 0 1 0 7/25/2017 63 170 0 1 0 7/24/2017 1425 170 0 1 31 7/23/2017 1370 170 0 1 30 7/22/2017 1246 170 0 1 22 7/21/2017 64 170 0 1 0 7/20/2017 60 170 0 1 0 7/19/2017 57 170 0 1 0 7/18/2017 49 170 0 7/17/2017 46 160 0 7/16/2017 43 160 0 7/15/2017 43 160 0 7/14/2017 43 160 0 7/13/2017 43 160 0 7/12/2017 72 160 0 0 0 7/11/2017 76 160 0 0 0 7/10/2017 1237 160 0 0 23 7/9/2017 73 170 0 0 0 7/8/2017 75 170 0 0 0 7/7/2017 74 170 0 0 0 7/6/2017 74 170 0 0 0 7/5/2017 75 170 0 0 0 7/4/2017 75 170 0 0 0 7/3/2017 75 170 0 0 0 7/2/2017 75 170 0 0 0 7/1/2017 75 170 0 0 0 6/30/2017 75 170 0 0 0 6/29/2017 75 170 0 0 0 6/28/2017 75 170 0 0 0 6/27/2017 75 170 0 0 0 6/26/2017 48 163 0 0 0 6/25/2017 48 163 0 0 0 6/24/2017 48 163 0 0 0 6/23/2017 48 163 0 0 0 6/22/2017 48 163 0 0 0 6/21/2017 47 163 0 0 0 6/20/2017 48 163 0 6/19/2017 48 163 0 6/18/2017 48 160 0 6/17/2017 48 163 0 6/16/2017 48 163 0 6/15/2017 48 163 0 6/14/2017 48 163 0 2 0 6/13/2017 36 160 0 2 0 6/12/2017 36 160 0 2 0 6/11/2017 37 160 0 2 0 6/10/2017 36 160 0 2 0 6/9/2017 36 160 0 2 0 6/8/2017 36 160 0 2 0 6/7/2017 36 160 0 2 0 6/6/2017 40 160 0 6/5/2017 40 160 0 6/4/2017 40 160 0 6/3/2017 40 160 0 6/2/2017 40 160 0 6/1/2017 40 160 0 5/31/2017 40 160 0 5/30/2017 40 160 0 5/29/2017 40 160 0 2 0 5/28/2017 36 160 0 2 0 5/27/2017 36 160 0 2 0 5/26/2017 32 160 0 2 0 5/25/2017 32 160 0 2 0 5/24/2017 33 160 0 2 0 5/23/2017 38 160 0 2 0 5/22/2017 45 160 0 2 0 5/21/2017 58 160 0 2 0 5/20/2017 64 160 0 2 0 5/19/2017 1307 160 0 2 28 5/18/2017 1305 160 0 2 28 5/17/2017 1295 160 0 2 30 5/16/2017 1295 160 0 2 34 5/15/2017 1305 160 0 2 30 5/14/2017 1295 160 0 2 20 5/13/2017 100 160 0 2 0 5/12/2017 100 160 0 2 0 5/11/2017 100 160 0 2 0 5/10/2017 100 160 0 2 0 5/9/2017 100 160 0 2 0 5/8/2017 100 160 0 2 0 5/7/2017 100 170 0 2 0 5/6/2017 100 170 0 2 0 5/5/2017 100 170 0 2 0 5/4/2017 46 170 0 2 0 5/3/2017 46 170 0 2 0 5/2/2017 48 165 0 2 0 5/1/2017 48 165 0 2 0 4/30/2017 48 165 0 2 0 4/29/2017 48 165 0 2 0 4/28/2017 48 165 0 2 0 4/27/2017 48 165 0 2 0 4/26/2017 48 165 0 2 0 4/25/2017 48 165 0 2 0 4/24/2017 48 165 0 2 0 4/23/2017 48 165 0 2 0 4/22/2017 48 165 0 2 0 4/21/2017 48 165 0 2 0 4/20/2017 48 165 0 2 0 4/19/2017 48 165 0 2 0 4/18/2017 48 165 0 2 0 4/17/2017 48 165 0 2 0 4/16/2017 48 170 0 2 0 4/15/2017 48 170 0 2 0 4/14/2017 48 170 0 2 0 4/13/2017 48 170 0 2 0 4/12/2017 48 170 0 2 0 4/11/2017 48 170 0 2 0 4/10/2017 48 170 0 2 0 4/9/2017 48 170 0 2 0 4/8/2017 48 110 0 2 0 4/7/2017 48 110 0 2 0 4/6/2017 48 170 0 2 0 4/5/2017 48 170 0 2 0 4/4/2017 48 170 0 2 0 4/3/2017 48 170 0 2 0 4/2/2017 48 170 0 2 0 4/1/2017 48 170 0 2 0 3/31/2017 48 170 0 2 0 3/30/2017 48 170 0 2 0 3/29/2017 48 170 0 2 0 3/28/2017 48 170 0 0 0 3/27/2017 48 170 0 0 3/26/2017 48 170 0 0 0 3/25/2017 48 170 0 0 0 3/24/2017 48 170 0 0 0 3/23/2017 48 170 0 0 0 3/22/2017 48 170 0 0 0 3/21/2017 48 170 0 0 0 3/20/2017 48 170 0 0 0 3/19/2017 48 185 0 0 0 3/18/2017 48 185 0 0 0 3/17/2017 48 185 0 0 0 3/16/2017 48 170 0 0 0 3/15/2017 48 170 0 0 0 3/14/2017 48 170 0 0 0 3/13/2017 48 170 0 0 0 3/12/2017 40 170 0 0 0 3/11/2017 38 170 0 0 0 3/10/2017 38 170 0 0 0 3/9/2017 38 170 0 0 0 3/8/2017 38 170 0 0 0 3/7/2017 38 170 0 0 0 3/6/2017 38 170 0 0 0 3/5/2017 38 170 0 0 3/4/2017 38 170 0 0 3/3/2017 38 170 0 0 3/2/2017 38 170 0 0 3/1/2017 38 170 0 0 2/28/2017 38 170 0 0 2/27/2017 38 170 0 0 2/26/2017 38 170 0 0 2/25/2017 38 170 0 0 2/24/2017 38 170 0 0 2/23/2017 38 170 0 0 2/22/2017 38 170 0 0 2/21/2017 38 170 0 0 2/20/2017 1406 170 0 0 2/19/2017 28 185 0 0 2/18/2017 28 170 0 0 2/17/2017 28 170 0 0 2/16/2017 28 170 0 0 2/15/2017 28 170 0 0 2/14/2017 28 170 0 0 2/13/2017 28 170 0 0 2/12/2017 28 170 0 0 2/11/2017 28 170 0 0 2/10/2017 28 170 0 0 2/9/2017 28 170 0 0 2/8/2017 28 170 0 0 2/7/2017 28 170 0 0 2/6/2017 28 170 0 0 2/5/2017 28 170 0 0 2/4/2017 28 170 0 0 2/3/2017 28 170 0 0 2/2/2017 28 170 0 0 2/1/2017 28 170 0 0 1/31/2017 28 170 0 0 1/30/2017 28 170 0 0 1/29/2017 28 170 0 0 1/28/2017 28 170 0 0 1/27/2017 28 170 0 0 1/26/2017 28 170 0 0 0 0 0 0 0 0 0 0 0 0 0 18 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1/25/2017 28 170 0 0 0 1/24/2017 28 170 0 0 0 1/23/2017 28 170 0 0 0 1/22/2017 28 170 0 0 0 1/21/2017 28 170 0 0 0 1/20/2017 28 170 0 0 0 1/19/2017 28 170 0 0 0 1/18/2017 28 170 0 0 0 1/17/2017 28 170 0 1/16/2017 28 170 0 1/15/2017 28 170 0 1/14/2017 28 170 0 1/13/2017 28 170 0 1/12/2017 28 170 2 0 0 1/11/2017 45 170 0 1/10/2017 46 170 0 1/9/2017 118 170 0 0 0 1/8/2017 18 170 0 0 0 1/7/2017 18 170 0 0 0 1/6/2017 18 170 0 0 0 1/5/2017 18 170 0 0 0 1/4/2017 18 170 0 0 0 1/3/2017 18 170 0 0 0 1/2/2017 20 170 0 0 0 1/1/2017 30 170 0 0 0 522 1500 - 1000 - F9DI 0 01/2017 02/2017 03/2017 04/2017 IRU 014-31 WDW - (50.0587.0003] 05/2017 06/2017 07/2017 08/2017 09/2017 10/2017 11/2017 — Tubing — IA — OA OOA — Water Injection 12/2017 200 150 100 50 0 Well: IRU 14-31 Desc: Disposal Permit to drill: 1750080 Admin Approval: DIO #23 API: 50-283-20045-00-00 Date Range: 01/01/2017 - 12/31/2017 Date Tubing IA OA ODA Water Injection 12/31/201' 46 100 0 0 0 12/30/201' 46 100 0 0 0 12/29/201' 45 100 0 0 0 12/28/201' 45 100 0 0 0 12/27/201 45 100 0 0 0 12/26/201 45 100 0 0 0 12/25/201' 44 100 0 0 0 12/24/201 43 100 0 0 0 12/23/201' 43 100 0 0 0 12/22/201' 41 100 0 0 0 12/21/201 38 100 0 0 0 12/20/201 1200 100 0 0 21 12/19/201' 42 100 0 0 12/18/201' 42 100 0 0 12/17/201 42 100 0 12/16/201' 42 100 0 12/15/201 42 100 0 12/14/201 42 100 0 12/13/201 42 100 0 0 0 12/12/201 42 100 0 0 0 12/11/201' 42 100 0 0 0 12/10/201' 42 100 0 0 0 12/9/2017 41 100 0 0 0 12/8/2017 40 100 0 0 0 12/7/2017 40 100 0 0 0 12/6/2017 39 95 0 0 0 12/5/2017 35 95 0 0 0 12/4/2017 35 95 0 0 0 12/3/2017 1140 95 0 0 20 12/2/2017 43 95 0 0 0 12/1/2017 43 95 0 0 0 11/30/201 44 95 0 0 0 11/29/201 44 95 0 0 0 11/28/201 43 95 0 0 0 11/27/201 43 95 0 0 0 11/26/201 43 95 0 0 0 11/25/201 43 95 0 0 0 11/24/201 43 95 0 0 0 11/23/201 43 95 0 0 0 11/22/201 43 95 0 0 0 11/21/201 43 95 0 0 0 11/20/201 42 110 0 0 0 11/19/201 42 110 0 0 0 11/18/201 41 110 0 0 0 11/17/201 40 110 0 0 0 11/16/201 40 110 0 0 0 11/15/201 35 110 0 0 0 11/14/201 1078 110 0 0 12 11/13/201 40 110 0 0 0 11/12/201 40 110 0 0 0 11/11/201 39 110 0 0 0 11/10/201 1200 110 0 0 8 11/9/2017 45 110 0 0 0 11/8/2017 45 110 0 0 0 11/7/2017 45 110 0 0 0 11/6/2017 44 110 0 0 0 11/5/2017 45 110 0 0 0 11/4/2017 44 110 0 0 0 11/3/2017 44 110 0 0 0 11/2/2017 44 110 0 0 0 11/1/2017 44 110 0 0 0 10/31/201 36 110 0 0 0 10/30/201 36 110 0 0 0 10/29/201 36 110 0 0 0 10/28/201 36 110 0 0 0 10/27/201 36 110 0 0 0 10/26/201 36 110 0 0 0 10/25/2017 36 110 0 0 0 10/24/201 36 110 0 10/23/201' 36 110 0 10/22/201' 36 110 0 10/21/201' 36 110 0 10/20/201' 36 110 0 10/19/201' 35 110 0 0 0 10/18/201 35 110 0 0 0 10/17/201' 35 110 0 0 0 10/16/201 35 120 0 0 0 10/15/201 35 120 0 0 0 10/14/201' 35 120 0 0 0 10/13/201 35 120 0 0 0 10/12/201' 35 100 0 0 0 10/11/201 35 100 0 0 0 10/10/201' 35 100 0 0 0 10/9/2017 36 100 0 0 0 10/8/2017 45 100 0 0 0 10/7/2017 45 100 0 0 0 10/6/2017 45 100 0 0 0 10/5/2017 45 100 0 0 0 10/4/2017 45 100 0 0 0 10/3/2017 45 100 0 0 0 10/2/2017 45 100 0 0 0 10/1/2017 44 100 0 0 0 9/30/2017 44 100 0 0 0 9/29/2017 44 90 0 0 0 9/28/2017 44 90 0 0 0 9/27/2017 45 90 0 0 0 9/26/2017 45 90 0 0 0 9/25/2017 45 90 0 0 0 9/24/2017 44 90 0 0 0 9/23/2017 44 90 0 0 0 9/22/2017 44 90 0 0 0 9/21/2017 44 90 0 0 0 9/20/2017 44 90 0 0 0 9/19/2017 44 90 0 0 0 9/18/2017 44 90 0 0 0 9/17/2017 44 90 0 0 0 9/16/2017 44 90 0 0 0 9/15/2017 44 90 0 0 0 9/14/2017 44 120 0 0 0 9/13/2017 44 100 0 0 0 9/12/2017 44 100 0 0 0 9/11/2017 44 100 0 0 0 9/10/2017 44 105 0 0 0 9/9/2017 44 105 0 0 0 9/8/2017 44 105 0 0 0 9/7/2017 43 105 0 0 0 9/6/2017 43 110 10 0 0 9/5/2017 42 110 10 0 0 9/4/2017 41 110 10 0 0 9/3/2017 39 110 10 0 0 9/2/2017 37 110 10 0 0 9/1/2017 41 110 10 0 0 8/31/2017 47 110 10 0 0 8/30/2017 47 110 10 0 0 8/29/2017 47 110 10 0 0 8/28/2017 47 100 10 0 0 8/27/2017 47 110 10 0 0 8/26/2017 48 100 10 0 0 8/25/2017 47 100 10 0 0 8/24/2017 47 110 12 0 0 8/23/2017 47 110 12 0 0 8/22/2017 47 110 12 0 0 8/21/2017 47 110 13 0 0 8/20/2017 45 118 14 0 0 8/19/2017 45 120 15 0 0 8/18/2017 1100 120 15 0 7 8/17/2017 44 125 15 0 0 8/16/2017 42 125 15 0 0 8/15/2017 44 125 15 0 0 8/14/2017 44 125 15 0 0 8/13/2017 41 100 15 0 0 8/12/2017 1118 195 15 0 25 8/11/2017 66 100 15 0 0 8/10/2017 68 100 15 0 0 8/9/2017 66 100 20 0 0 8/8/2017 66 100 20 0 8/7/2017 68 100 20 0 8/6/2017 66 100 20 0 8/5/2017 69 100 20 0 8/4/2017 70 100 20 0 8/3/2017 70 100 20 0 8/2/2017 65 100 20 0 8/1/2017 65 100 20 0 7/31/2017 64 100 20 0 7/30/2017 65 100 20 0 7/29/2017 64 100 20 0 7/28/2017 42 100 20 0 7/27/2017 42 100 20 0 7/26/2017 43 100 20 0 7/25/2017 43 100 20 0 7/24/2017 43 100 20 0 7/23/2017 43 100 20 0 7/22/2017 43 125 20 0 7/21/2017 43 125 20 0 7/20/2017 43 125 20 0 7/19/2017 43 125 20 0 7/18/2017 43 125 7/17/2017 43 100 7/16/2017 43 100 7/15/2017 43 100 7/14/2017 43 100 7/13/2017 40 100 7/12/2017 40 100 0 0 7/11/2017 42 100 0 0 7/10/2017 48 100 0 0 7/9/2017 49 100 0 0 7/8/2017 48 100 0 0 7/7/2017 48 100 0 0 7/6/2017 48 100 0 0 7/5/2017 48 100 0 0 7/4/2017 48 100 0 0 7/3/2017 48 100 0 0 7/2/2017 48 100 0 0 7/1/2017 48 100 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 6/30/2017 48 100 0 0 6/29/2017 48 100 0 0 6/28/2017 48 100 0 0 6/27/2017 48 100 0 0 6/26/2017 48 100 0 0 6/25/2017 48 100 0 0 6/24/2017 48 100 0 0 6/23/2017 48 100 0 0 6/22/2017 48 100 20 0 6/21/2017 47 100 20 0 6/20/2017 48 100 6/19/2017 49 100 6/18/2017 48 100 6/17/2017 48 100 6/16/2017 48 100 6/15/2017 48 100 6/14/2017 48 100 0 0 6/13/2017 50 105 0 0 6/12/2017 48 105 0 0 6/11/2017 51 105 0 0 6/10/2017 44 110 0 0 6/9/2017 50 110 0 0 6/8/2017 50 110 0 0 6/7/2017 50 110 0 0 6/6/2017 50 110 6/5/2017 48 110 6/4/2017 48 110 6/3/2017 48 110 6/2/2017 48 110 6/1/2017 48 110 5/31/2017 48 110 5/30/2017 48 110 5/29/2017 48 110 0 0 5/28/2017 48 110 0 0 5/27/2017 48 110 0 0 5/26/2017 48 110 0 0 5/25/2017 48 110 0 0 5/24/2017 48 110 0 0 5/23/2017 48 110 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 5/22/2017 48 110 0 0 0 5/21/2017 48 110 0 0 0 5/20/2017 48 110 0 0 0 5/19/2017 48 110 0 0 0 5/18/2017 48 110 0 0 0 5/17/2017 48 110 0 0 0 5/16/2017 48 110 0 0 0 5/15/2017 48 110 0 0 0 5/14/2017 49 110 0 0 0 5/13/2017 48 110 0 0 0 5/12/2017 48 110 0 0 0 5/11/2017 48 110 0 0 0 5/10/2017 48 110 0 0 0 5/9/2017 48 110 0 0 0 5/8/2017 48 110 0 0 0 5/7/2017 48 110 0 0 0 5/6/2017 47 110 0 0 0 5/5/2017 47 110 0 0 0 5/4/2017 46 110 0 0 0 5/3/2017 44 110 0 0 0 5/2/2017 1705 110 0 0 26 5/1/2017 43 110 0 0 0 4/30/2017 1705 110 0 0 28 4/29/2017 48 110 0 0 0 4/28/2017 1105 110 0 0 32 4/27/2017 48 110 0 0 0 4/26/2017 48 110 0 0 0 4/25/2017 49 110 0 0 0 4/24/2017 49 110 0 0 0 4/23/2017 49 110 0 0 0 4/22/2017 49 110 0 0 0 4/21/2017 49 110 0 0 0 4/20/2017 49 110 0 0 0 4/19/2017 49 110 0 0 0 4/18/2017 48 110 0 0 0 4/17/2017 48 110 0 0 0 4/16/2017 48 110 0 0 0 4/15/2017 48 110 0 0 0 4/14/2017 48 110 0 0 0 4/13/2017 48 110 0 0 0 4/12/2017 48 110 0 0 0 4/11/2017 48 110 0 0 0 4/10/2017 48 110 0 0 0 4/9/2017 48 110 0 0 0 4/8/2017 48 110 0 0 0 4/7/2017 48 110 0 0 0 4/6/2017 90 115 0 0 0 4/5/2017 1062 110 0 0 0 4/4/2017 1062 110 0 0 23 4/3/2017 46 110 0 0 0 4/2/2017 46 110 0 0 0 4/1/2017 46 110 0 0 0 3/31/2017 46 110 0 0 0 3/30/2017 46 110 0 0 0 3/29/2017 46 110 0 0 0 3/28/2017 46 110 0 0 0 3/27/2017 46 110 0 0 0 3/26/2017 46 110 0 0 0 3/25/2017 46 110 0 0 0 3/24/2017 45 110 0 0 0 3/23/2017 45 110 0 0 0 3/22/2017 44 110 0 0 0 3/21/2017 41 110 0 0 0 3/20/2017 1074 110 0 0 22 3/19/2017 45 110 0 0 0 3/18/2017 45 110 0 0 0 3/17/2017 45 110 0 0 0 3/16/2017 50 110 0 0 0 3/15/2017 50 110 0 0 0 3/14/2017 50 110 0 0 0 3/13/2017 50 110 0 0 0 3/12/2017 45 110 0 0 0 3/11/2017 40 119 0 0 0 3/10/2017 40 119 0 0 0 3/9/2017 40 119 0 0 0 3/8/2017 40 119 0 0 0 3/7/2017 40 119 0 0 0 3/6/2017 1100 119 0 0 20 3/5/2017 18 119 0 0 0 3/4/2017 18 119 0 0 0 3/3/2017 18 119 0 0 0 3/2/2017 18 119 0 0 0 3/1/2017 21 119 0 0 0 2/28/2017 22 119 0 0 0 2/27/2017 15 119 0 0 0 2/26/2017 15 119 0 0 0 2/25/2017 15 119 0 0 0 2/24/2017 15 119 0 0 0 2/23/2017 15 119 0 0 0 2/22/2017 15 119 0 0 0 2/21/2017 15 119 0 0 0 2/20/2017 15 119 0 0 0 2/19/2017 15 119 0 0 0 2/18/2017 15 119 0 0 0 2/17/2017 15 119 0 0 0 2/16/2017 15 119 0 0 0 2/15/2017 15 119 0 0 0 2/14/2017 15 119 0 0 0 2/13/2017 15 119 0 0 0 2/12/2017 15 119 0 0 0 2/11/2017 15 119 0 0 0 2/10/2017 15 119 0 0 0 2/9/2017 16 119 0 0 0 2/8/2017 16 119 0 0 0 2/7/2017 15 119 0 0 0 2/6/2017 15 119 0 0 0 2/5/2017 15 119 0 0 0 2/4/2017 33 119 0 0 0 2/3/2017 1390 119 0 0 20 2/2/2017 9 119 0 0 0 2/1/2017 10 119 0 0 0 1/31/2017 11 119 0 0 0 1/30/2017 11 119 0 0 0 1/29/2017 11 119 0 0 0 1/28/2017 12 119 0 0 0 1/27/2017 15 119 0 0 0 1/26/2017 16 119 0 0 0 1/25/2017 17 119 0 0 0 1/24/2017 29 119 0 0 0 1/23/2017 29 119 0 0 0 1/22/2017 1350 119 0 0 18 1/21/2017 16 119 0 0 0 1/20/2017 16 119 0 0 0 1/19/2017 16 119 0 0 0 1/18/2017 16 119 0 0 0 1/17/2017 16 119 0 1/16/2017 13 119 0 1/15/2017 16 119 0 1/14/2017 17 119 0 1/13/2017 19 119 0 1/12/2017 45 119 18 0 0 1/11/2017 45 115 0 1/10/2017 45 115 0 1/9/2017 45 115 18 0 0 1/8/2017 40 115 18 0 0 1/7/2017 40 115 18 0 0 1/6/2017 40 115 18 0 0 1/5/2017 1100 115 18 0 17 1/4/2017 44 118 18 0 0 1/3/2017 44 118 18 0 0 1/2/2017 44 118 18 0 0 1/1/2017 44 118 18 0 0 . . Chevron === Jeff W. Smetanka Reservoir Engineer Union Oil Company of California P.O. Box 196247 Anchorage, AK 99519-6247 Tel 907 263 7622 Fax 907 263 7847 Email smetankaj@chevron.com ~..~~ August15,2006 F RECEi~ r Mr. Jim Regg Alaska Oil & Gas Conservation Commission (AOGCC) 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 A! u~ ~l diU,) AI:;¡~.'....l.·.. .....'. t·, , R !; -..", íi}',,;~[mm$SIOn AIWhQlâijê ..J Re: Disposal Report for the 14-31 Well in the Ivan River Unit Dear Mr. Regg: Attached is the 2005 Annual Report for UIC Class II disposal operations in the IRU 14-31 wellbore. These disposal operations are governed by AOGCC Disposal Injection Order #23 issued 08/09/01. The attached plot shows that the injection pressures and low rates are relatively predictable and stable and do not indicate any reservoir or mechanical concerns. Specific items to note for this reporting period: · The fluids injected into the IRU 14-31 well were essentially produced water from the Ivan River, Pretty Creek and Lewis River fields. · The data acquisition during 2005 was improved to include more annulus readings and more consistent data entry. · The current monthly injection volume into the 14-31 well averages approximately 100 bbls with injection rates of less than 70 bpd performed on 1-3 days per month in 'batch mode'. · The injection pressure is approximately 1800 psig which is well within the permitted 3300 psig injection pressure maximum. · The consistent pressure, low water volumes and low water rates support continued containment and lack of growth outside of permitted zones for the injection fluids. Please contact me if I can be of further assistance at 907-263-7622. Best regards, cc: Dave Whitacre Laura Hammond / Jean Bodeau Larry Greenstein Well File Union Oil Company of California / A Chevron Company http://www.chevron.com .. . .. . . . ...... .. .. . .' . . . 20-".'421- ..... ......'.~.,.r.· CS¢' ... .. . ..... . ... ... . ,. .. ,. .. ... ... 1o..3l4-i40..5Im· . . . .. .. " ., . .~r1ö!5tJ$p 1!1Ø.'1'~"~óQ . . ........... . toIOli....1.a1.. ···~~i'teqJ.l..IÏtåJÔli . .' 'Thrufló81Shôë .$.çq~..,.:= ~"U~g."'~J.~ ':"a.cs". . i:'an" ·;·d···..· ... . . . t(:âL·.Ot~nd.HëJ "r.. ~J.2..'-,.~I~ ··..·:1018i·lOOtxS. ..... ·..·~·1~)!'·.~I~r..·1o,tN;JQ¡;· . . 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Il. 800 - 600 400 IRU 14-31 Pressure Observations for 2005 Annual Report ""--~^".~------- -20" -10 3/4" -B-Rate ---~._._- ----- ---~.._-----------,~-- -~------------,_.~-------- -------.- ---~- ------------_.__._,-,~- ----------------~.- -----------,--~------------ 200~--~-~~-~ o 11/09/04 12/29/04 02/17/05 04/08/05 Printed on 8/15/2006 at 12:57 PM 150 _._--------------,-------- ------ "------ --------------- 135 ---- 120 105 ------ ----- -- -- -----,--- 90 ,--- ------ ------ ____m_____________ -------.-.---..--- OS/28/05 07/17/05 Date 09/05/05 10/25/05 12/14/05 75 60 45 "-~ 30 -..-----.-, 02/02/06 15 o 03/24/06 IRU 14-31 Pressure Data 2006 01 26.xls INJDATE HRS_ON API 01/26/06 0 0 502832004500 01/25/06 0 25 0 0 502832004500 01/24/06 0 25 0 0 502832004500 01/23/06 0 25 0 0 502832004500 01/22/06 0 25 0 0 502832004500 01/21/06 0 25 0 0 502832004500 01/20/06 0 25 0 0 0 502832004500 01/19/06 0 25 0 0 502832004500 01/18/06 0 25 0 0 502832004500 01/17/06 0 25 0 0 502832004500 01/16/06 0 25 0 0 5028320045.0.0 .01/15/.06 0 25 .0 0 50283200450.0 .01/14/.06 0 25 0 0 5028320045.00 01/13/06 0 25 0 0 502832.0.0450.0 01/12/.06 0 25 0 .0 5.02832.0.0450.0 .01/11/06 0 25 0 0 502832004500 01/09/.06 0 25 0 0 5028320.045.00 01/08/06 0 25 0 .0 502832004500 01/07/06 0 25 0 0 5028320045.00 01/06/06 0 25 0 0 502832004500 01/05/06 0 25 0 0 5028320045.0.0 01/04/06 0 25 0 0 502832004500 01/03/06 0 25 0 0 502832004500 01/02/06 0 25 0 0 502832004500 01/01/06 0 25 0 0 502832004500 12/31/.05 0 25 0 0 50283200450.0 12/3.0/.05 0 25 0 .0 502832.0045.0.0 12/29/.05 0 25 .0 0 5.028320.045.0.0 12/28/.05 0 25 0 0 5028320.04500 12/27/.05 0 25 0 0 502832.0.0450.0 12/26/.05 0 25 0 0 5.02832004500 12/25/05 .0 25 .0 .0 5028320.04500 12/24/05 .0 25 .0 .0 502832004500 12/23/05 0 25 0 0 502832004500 12/22/05 .0 25 0 0 502832004500 12/21/05 0 25 0 0 502832004500 12/20/05 0 25 0 0 502832004500 12/19/05 0 25 0 0 502832004500 12/18/05 0 25 0 0 502832004500 12/17/05 0 25 0 0 502832004500 12/16/05 0 25 0 0 502832004500 12/15/05 0 25 0 0 502832004500 12/14/05 0 25 0 0 502832004500 12/13/05 0 25 0 0 502832004500 12/12/05 0 25 0 0 502832004500 12/11/05 0 25 0 0 502832004500 12/10/05 0 25 0 0 502832004500 12/09/05 0 25 0 0 502832004500 12/08/05 0 25 0 0 502832004500 12/07/05 0 25 0 0 502832004500 12/06/05 0 25 0 0 502832004500 12/05/05 0 25 0 0 502832004500 12/04/05 0 25 0 0 502832004500 12/03/05 0 25 0 0 502832004500 12/02/05 0 25 0 0 502832004500 12/01/05 0 25 0 0 502832004500 11/30/05 .0 25 0 0 5028320.04500 11/29/05 0 25 0 0 502832004500 INJDATE HRS_ON API 11/28/05 0 0 0 502832004500 11/27/05 0 25 0 0 502832004500 11/26/05 0 25 0 0 502832004500 11/25/05 0 25 0 0 502832004500 11/24/05 0 25 0 0 502832004500 11/23/05 0 25 0 0 502832004500 11/22/05 0 25 0 0 502832004500 11/21/05 0 25 0 0 502832004500 11/20/05 0 25 0 0 502832004500 11/19/05 0 25 0 0 502832004500 11/18/05 0 1850 0 0 70 502832004500 11/17/05 0 1850 0 0 0 70 502832004500 11/16/05 0 50 0 0 502832004500 11/15/05 0 1850 0 0 70 502832004500 11/14/05 0 300 0 0 502832004500 11/13/05 0 300 0 0 502832004500 11/12/05 0 300 0 0 502832004500 11/11/05 0 300 0 0 502832004500 11/10/05 0 300 0 0 502832004500 11/09/05 0 300 0 0 502832004500 11/08/05 0 300 0 0 502832004500 11/07/05 0 300 0 0 502832004500 11/06/05 0 300 0 0 502832004500 11/05/05 0 300 0 0 502832004500 11/04/05 0 300 0 0 502832004500 11/03/05 0 300 0 0 502832004500 11/02/05 0 300 0 0 502832004500 11/01/05 0 50 0 0 502832004500 10/31/05 0 50 0 0 502832004500 10/30/05 0 50 0 0 502832004500 10/29/05 0 50 0 0 502832004500 10/28/05 0 50 0 0 502832004500 10/27/05 0 50 0 0 502832004500 10/26/05 0 50 0 0 502832004500 10/25/05 0 50 0 0 502832004500 10/24/05 0 50 0 0 502832004500 10/23/05 0 50 0 0 502832004500 10/22/05 0 50 0 0 502832004500 10/21/05 0 50 0 0 502832004500 10/20/05 0 50 0 0 502832004500 10/19/05 0 50 0 0 502832004500 10/18/05 8 1600 0 0 74 502832004500 10/17/05 8 1600 0 0 74 502832004500 10/16/05 8 1600 0 0 74 502832004500 10/15/05 8 1600 0 0 74 502832004500 10/14/05 0 250 0 0 502832004500 10/13/05 0 250 0 0 502832004500 10/12/05 0 250 0 0 502832004500 10/11/05 0 1625 0 0 35 502832004500 10/10/05 0 162 0 0 502832004500 10/09/05 9 1625 0 0 35 502832004500 10/08/05 0 140 0 0 502832004500 10/07/05 0 140 0 0 502832004500 10/06/05 0 140 0 0 502832004500 1 0/05/05 0 140 0 0 502832004500 10/04/05 0 400 0 0 502832004500 10/03/05 7 1650 0 0 30 502832004500 10/02/05 7 1650 0 0 30 502832004500 INJDATE HRS_ON API 10/01/05 0 1650 0 10 30 502832004500 09/30/05 13 1650 0 0 55 502832004500 09/29/05 0 0 0 0 502832004500 09/28/05 0 0 0 0 502832004500 09/27/05 0 0 0 0 0 502832004500 09/26/05 0 0 0 0 502832004500 09/25/05 0 0 0 0 502832004500 09/24/05 0 0 0 0 502832004500 09/23/05 0 0 0 0 502832004500 09/22/05 0 0 0 0 502832004500 09/21/05 0 0 0 0 502832004500 09/20/05 0 0 0 0 502832004500 09/19/05 0 0 0 0 502832004500 09/18/05 0 0 0 0 502832004500 09/17/05 0 0 0 0 502832004500 09/16/05 0 0 0 0 502832004500 09/15/05 0 0 0 0 502832004500 09/14/05 0 0 0 0 502832004500 09/13/05 0 0 0 0 502832004500 09/12/05 0 0 0 0 502832004500 09/11/05 0 0 0 0 502832004500 09/10/05 0 0 0 0 502832004500 09/09/05 0 0 0 0 502832004500 09/08/05 0 0 0 0 502832004500 09/07/05 0 0 0 0 502832004500 09/06/05 0 0 0 0 0 502832004500 09/05/05 0 0 0 0 502832004500 09/04/05 0 0 0 0 502832004500 09/03/05 0 0 0 0 502832004500 09/02/05 0 0 0 0 502832004500 09/01/05 0 0 0 0 502832004500 08/31/05 0 0 0 0 502832004500 08/30/05 0 0 0 0 502832004500 08/29/05 0 0 0 0 502832004500 08/28/05 0 0 0 0 502832004500 08/27/05 0 0 0 0 502832004500 08/26/05 0 0 0 0 502832004500 08/25/05 0 0 0 0 502832004500 08/24/05 0 0 0 0 502832004500 08/23/05 0 0 0 0 502832004500 08/22/05 0 0 0 0 0 502832004500 08/21/05 0 0 0 0 0 502832004500 08/20/05 0 0 0 0 0 502832004500 08/19/05 0 0 0 0 502832004500 08/18/05 0 0 0 0 502832004500 08/17/05 0 0 0 0 502832004500 08/16/05 0 0 0 0 502832004500 08/15/05 0 0 0 0 502832004500 08/14/05 0 0 0 0 502832004500 08/13/05 0 0 0 0 502832004500 08/12/05 0 0 0 0 502832004500 08/11/05 0 0 0 0 502832004500 08/10/05 0 0 0 0 502832004500 08/09/05 0 0 0 0 502832004500 08/08/05 0 0 0 0 502832004500 08/07/05 0 0 0 0 502832004500 08/06/05 0 0 0 0 502832004500 08/05/05 0 0 0 0 502832004500 ----------- INJDATE HRS_ON API 08/04/05 0 0 0 0 502832004500 08/03/05 0 0 0 0 502832004500 08/02/05 0 0 0 0 502832004500 08/01/05 0 0 0 0 502832004500 07/31/05 0 0 0 0 502832004500 07/30/05 0 0 0 0 502832004500 07/29/05 0 0 0 0 502832004500 07/28/05 0 0 0 0 502832004500 07/27/05 0 0 0 0 502832004500 07/26/05 0 0 0 0 502832004500 07/25/05 0 0 0 0 502832004500 07/24/05 0 0 0 0 502832004500 07/23/05 0 0 0 0 502832004500 07/22/05 0 0 0 0 502832004500 07/21/05 0 0 0 0 502832004500 07/20/05 0 0 0 0 502832004500 07/19/05 0 0 0 0 502832004500 07/18/05 0 0 0 0 502832004500 07/17/05 0 0 0 0 502832004500 07/16/05 0 0 0 0 502832004500 07/15/05 0 0 0 0 502832004500 07/14/05 0 0 0 0 502832004500 07/13/05 0 0 0 0 502832004500 07/12/05 0 0 0 0 502832004500 07/11/05 3 1020 0 0 8 502832004500 07/10/05 0 40 0 0 502832004500 07/09/05 0 40 0 0 502832004500 07/08/05 0 40 0 0 502832004500 07/07/05 0 40 0 0 502832004500 07/06/05 0 40 0 0 502832004500 07/05/05 0 40 0 0 502832004500 07/04/05 0 40 0 0 502832004500 07/03/05 0 40 0 0 502832004500 07/02/05 0 40 0 0 502832004500 07/01/05 0 50 0 0 502832004500 06/30/05 0 40 0 0 502832004500 06/29/05 0 40 0 0 502832004500 06/28/05 0 40 0 0 502832004500 06/27/05 0 1350 0 0 502832004500 06/26/05 0 1350 0 0 502832004500 06/25/05 0 1350 0 0 502832004500 06/24/05 0 1350 0 0 502832004500 06/23/05 0 1350 0 0 502832004500 06/22/05 0 1350 0 0 502832004500 06/21/05 0 1350 0 0 502832004500 06/20/05 0 1350 0 0 502832004500 06/19/05 0 1350 0 0 502832004500 06/18/05 0 1350 0 0 502832004500 06/17/05 0 1350 0 0 502832004500 06/16/05 0 1350 0 0 502832004500 06/15/05 18 1350 0 0 100 502832004500 06/14/05 18 1350 0 0 100 502832004500 06/13/05 0 1350 0 0 502832004500 06/12/05 0 1350 0 0 502832004500 06/11/05 0 50 0 0 502832004500 06/10/05 0 50 0 0 502832004500 06/09/05 0 50 0 0 502832004500 06/08/05 0 50 0 0 502832004500 INJDATE HRS_ON API 06/07/05 0 0 1 502832004500 06/06/05 0 50 0 0 502832004500 06/05/05 0 50 0 0 502832004500 06/04/05 0 50 0 0 502832004500 06/03/05 0 50 0 0 502832004500 06/02/05 13 1050 0 0 50 502832004500 06/01/05 13 1050 0 10 50 502832004500 05/31/05 0 1050 0 10 502832004500 05/30/05 0 1050 0 10 502832004500 OS/29/05 0 1050 0 10 502832004500 OS/28/05 0 1050 0 10 502832004500 OS/27/05 0 1050 0 10 502832004500 OS/26/05 0 1050 0 0 502832004500 OS/25/05 0 1050 0 0 502832004500 OS/24/05 0 1050 0 0 502832004500 OS/23/05 0 1050 0 0 502832004500 OS/22/05 0 1050 0 0 50 502832004500 OS/21/05 0 1050 0 0 50 502832004500 OS/20/05 0 1050 0 0 50 502832004500 05/19/05 0 1050 0 0 50 502832004500 05/18/05 0 1050 0 0 50 502832004500 05/17/05 0 1050 0 0 50 502832004500 05/16/05 0 1050 0 0 50 502832004500 05/15/05 0 50 0 0 502832004500 05/14/05 0 50 0 0 502832004500 05/13/05 0 50 0 0 502832004500 05/12/05 0 50 0 0 502832004500 05/11/05 0 50 0 0 502832004500 05/10/05 0 50 0 0 502832004500 05/09/05 0 50 0 0 502832004500 05/08/05 0 50 0 0 502832004500 05/07/05 0 50 0 0 502832004500 05/06/05 0 50 0 0 502832004500 05/04/05 0 50 0 0 502832004500 05/03/05 0 50 0 0 502832004500 05/02/05 0 50 0 0 502832004500 05/01/05 0 50 0 0 502832004500 04/30/05 0 50 0 0 502832004500 04/29/05 0 50 0 0 502832004500 04/28/05 0 50 0 0 502832004500 04/27/05 0 50 0 0 502832004500 04/26/05 0 50 0 0 502832004500 04/25/05 0 50 0 0 502832004500 04/24/05 0 50 0 0 502832004500 04/23/05 0 50 0 0 502832004500 04/22/05 0 50 0 0 502832004500 04/21/05 0 50 0 0 502832004500 04/20/05 0 50 0 0 502832004500 04/19/05 0 50 0 0 502832004500 04/18/05 0 50 0 0 502832004500 04/17/05 0 50 0 0 502832004500 04/16/05 0 50 0 0 502832004500 04/15/05 0 50 0 0 502832004500 04/14/05 0 50 0 0 502832004500 04/13/05 0 50 0 0 502832004500 04/12/05 0 50 0 0 502832004500 04/11/05 0 50 0 0 502832004500 04/10/05 0 50 0 0 502832004500 -------- - - ------------ INJDATE HRS_ON API 04/09/05 0 50 0 0 502832004500 04/08/05 0 50 0 0 502832004500 04/07/05 0 50 0 0 502832004500 04/06/05 0 50 0 0 502832004500 04/05/05 0 50 0 0 502832004500 04/04/05 0 50 0 0 502832004500 04/03/05 0 50 0 0 502832004500 04/02/05 0 50 0 0 502832004500 04/01/05 0 50 0 0 502832004500 03/31/05 0 50 0 0 502832004500 03/30/05 0 50 0 0 502832004500 03/29/05 0 50 0 0 502832004500 03/28/05 0 50 0 0 502832004500 03/27/05 0 50 0 0 502832004500 03/26/05 0 50 0 0 502832004500 03/25/05 0 50 0 0 502832004500 03/24/05 0 50 0 0 502832004500 03/23/05 0 50 0 0 502832004500 03/22/05 0 50 0 0 502832004500 03/21/05 0 50 0 0 502832004500 03/20/05 0 50 0 0 502832004500 03/19/05 0 50 0 0 502832004500 03/18/05 7 1260 0 0 40 502832004500 03/17/05 7 1260 0 0 40 502832004500 03/16/05 0 50 0 0 502832004500 03/15/05 7 1250 0 0 35 502832004500 03/14/05 7 1250 0 0 35 502832004500 03/13/05 0 50 0 0 502832004500 03/12/05 0 50 0 0 502832004500 03/11/05 0 50 0 0 502832004500 03/10/05 0 50 0 0 502832004500 03/09/05 0 50 0 0 502832004500 03/08/05 0 50 0 0 502832004500 03/07/05 0 50 0 0 502832004500 03/06/05 0 50 0 0 502832004500 03/05/05 0 50 0 0 502832004500 03/04/05 0 50 0 0 502832004500 03/03/05 0 50 0 0 502832004500 03/02/05 0 50 0 10 502832004500 03/01/05 0 50 0 0 502832004500 02/28/05 0 50 0 0 502832004500 02/27/05 0 50 0 0 502832004500 02/26/05 0 50 0 0 502832004500 02/25/05 0 50 0 0 502832004500 02/24/05 0 50 0 0 502832004500 02/23/05 0 50 0 0 502832004500 02/22/05 0 50 0 0 502832004500 02/21/05 0 50 0 10 502832004500 02/20/05 0 50 0 0 502832004500 02/19/05 0 50 0 0 502832004500 02/18/05 0 50 0 0 502832004500 02/17/05 0 50 0 0 502832004500 02/16/05 0 50 0 0 502832004500 02/15/05 0 50 0 0 502832004500 02/14/05 0 50 0 0 502832004500 02/13/05 0 50 0 0 502832004500 02/12/05 0 50 0 0 502832004500 02/11/05 0 50 0 0 502832004500 --------- INJDATE HRS_ON API 02/10/05 0 0 0 502832004500 02/09/05 0 50 0 0 502832004500 02/08/05 0 50 0 0 502832004500 02/07/05 0 50 0 0 502832004500 02/06/05 0 50 0 0 502832004500 02/05/05 0 50 0 0 502832004500 02/04/05 0 50 0 0 502832004500 02/03/05 0 50 0 0 502832004500 02/02/05 0 50 0 0 502832004500 02/01/05 0 50 0 0 502832004500 01/31/05 6 50 0 0 80 502832004500 01/30/05 0 50 0 0 502832004500 01/29/05 0 50 0 0 502832004500 01/28/05 0 50 0 0 502832004500 01/27/05 0 50 0 0 502832004500 01/26/05 0 50 0 0 502832004500 01/25/05 0 50 0 0 502832004500 01/24/05 0 50 0 0 502832004500 01/23/05 0 50 0 0 502832004500 01/22/05 0 50 0 0 502832004500 01/21/05 0 50 0 0 502832004500 01/20/05 0 50 0 0 502832004500 01/19/05 0 50 0 0 502832004500 01/18/05 0 50 0 0 502832004500 01/17/05 0 50 0 0 502832004500 01/16/05 0 0 0 10 502832004500 01/15/05 0 0 0 10 502832004500 01/14/05 0 0 0 10 502832004500 01/13/05 0 0 0 0 502832004500 01/12/05 0 0 0 10 502832004500 01/11/05 0 0 0 10 502832004500 01/10/05 0 0 0 10 502832004500 01/09/05 0 0 0 10 502832004500 01/08/05 0 0 0 10 502832004500 01/07/05 0 0 0 10 502832004500 01/06/05 0 0 0 10 502832004500 01/05/05 0 0 0 10 502832004500 01/04/05 0 0 0 0 502832004500 01/03/05 0 0 0 0 502832004500 01/02/05 0 0 0 0 502832004500 01/01/05 0 0 0 0 502832004500 12/31/04 0 0 0 0 502832004500 12/30/04 0 0 0 0 502832004500 12/29/04 0 0 0 0 502832004500 12/28/04 0 0 0 0 502832004500 12/27/04 0 0 0 0 502832004500 12/26/04 0 0 0 0 502832004500 12/25/04 0 0 0 0 502832004500 12/24/04 0 0 0 0 502832004500 12/23/04 0 0 0 0 502832004500 1 2/22/04 0 0 0 0 ~8 RE: Ivan River 14-31 . . Thanks for the review Tom. Looks like we are both thinking the same way for the continued use of this well. We will be tracking the volumes to see where we end up at the end of this fall's CT efforts. I'll verify that the annual report was prepared and sent over to you guys. Larry -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Thursday, August 10, 2006 9:23 AM To: Greenstein, Larry P Cc: Jim Regg Subject: Re: Ivan River 14-31 Larry, I looked at the order and the application. Here are my opinions. 1) Finding 18 basically restates what was contained in the application. It particularly references the workover program planned at that time and then includes a produced water volume likely developed for some unstated time into the future. It is possible that these estimated volumes are also linked to the "frac study" where different rates and injection durations were analyzed. You are correct that there is no volume limit stated in the rules. For class II injection, I don't believe that the Commission has specified a volume limit in the orders I have worked on and clearly no volume limit is specified within these rules and there is no volume limit specified in the regulations. Chevron does need to keep track of the cumulative volumes since there are comments regarding the proximity of other wells at IR and a statement regarding the potential size of the waste plume. Monitoring the offset wells' annular pressures was required so that any potential communication would be identified. If the total volume were to approach the estimates, which you say is unlikely, it might be appropriate to reexamine the frac study, however monitoring the annular pressures should provide information to demonstrate continued integrity. 2) I believe that Chevron will need to do both the monthly reporting and the annual report regardless of what waste is injected. The monthly reporting is pretty well standard for production and injection projects. Annual reports are pretty well standard as well and such reports is something that Jim Regg looks for as he oversees the Class II program. I hope these comments answer your questions. Call or message with anything further. Tom Maunder, PE AOGCC Greenstein, Larry P wrote, On 8/9/2006 2:41 PM: Sorry to hear about the teleconference. Two questions on DIO #23 for IRU 14-31: 1) waste' Curious about the 'estimated maximum of 30000 bbls of oilfield limit in Finding #18 as well as the 100000 bbls of PW listed. I 10f2 8/1 0/2006 10: 17 AM RE: Ivan River 14-31 . . believe we are about half way there or so on the 'oilfield waste' and 1/250th of the way on the PW. We are going back over to do somemore CT work on three or four wells that will be generating somemore of the oilfield wase type of fluid (nowhere near 15000 bbls though). The limi t was not part of the Rules listed at the end. I'm not worried about the PW component at this time, but people are asking how firm is this estimated limit for oilfield waste in the findings when it is not listed in the Rules?? Do we need to firm up our running total of this type of fluid to make sure we stay away from this estimated maximum limit? ? 2) If we use the well for somemore of this oilfield waste type fluid, does the normal monthly volume and pressure reporting suffice, or as part of Rule #4, do we need a special 'annual report evaluating the performance of the disposal operation' done next July I?? This is not a grind and inject project, just some desanded cleanout fluids. Any performance issues that might arise this fall would lead to us talking with you and dealing with them at that time. Thanks Tom for listening. I'll be in the office tomorrow morning also if you would like to discuss. Larry 263-7661 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, August 09, 2006 1:56 PM To: Larry Greenstein Subject: Ivan River 14-31 Larry, I am hooked up with a teleconference. What are your questions about Ivan? Tom 20f2 8/1 0/2006 10: 17 AM --- ~.--- $lJ1E~ ]~[E ~- r~ lill G~ ! .. ~ '" -.; ~....; <. ~- "--. I.U ~~ . - ll\ ; : '1 -~ i í FRANK H. MURKOWSKI. GOVERNOR j / C]d) j ~~ ~ ,Li U A."tA.~1iA. OIL Alft) GAS CONSERVATION COMMISSION j 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 September 27, 2004 Proposals to Amend Underground Injection Orders to Incorporate Consistent Language Addressing the Mechanical Integrity of Wells The Alaska Oil and Gas Conservation Commission ("Commission"), on its own motion, proposes to amend the rules addressing mechanical integrity of wells in all existing area injection orders, storage injection orders, enhanced recovery injection orders, and disposal injection orders. There are numerous different versions of wording used for each of the rules that create confusion and inconsistent implementation of well integrity requirements for injection wells when pressure communication or leakage is indicated. In several injection orders, there are no rules addressing requirements for notification and well disposition when a well integrity failure is identified. Wording used for the administrative approval rule in injection orders is similarly inconsistent. The Commission proposes these three rules as replacements in all injection orders: Demonstration of Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before lnJection begins, at least once every four years thereafter (except at least once every two years in the case of a slurry injection well), and before returning a well to service following a workover affecting mechanical integrity. Unless an alternate means is approved by the Commission, mechanical integrity must be demonstrated by a tubing/casing annulus pressure test using a surface pressure of 1500 psi or 0.25 psi/ft multiplied by the vertical depth of the packer, whichever is greater, that shows stabilizing pressure and does not change more than 10 percent during a 30 minute period. The Commission must be notified at least 24 hours in advance to enable a representative to witness mechanical integrity tests. Well Integrity Failure and Confmement Whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, log, or other evidence, the operator shall immediately notify the Commission and submit a plan of corrective action on a Form 10-403 for Commission approval. The operator shall immediately shut in the well if continued operation would be unsafe or would threaten contamination of freshwater, or if so directed by the Commission. A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating well integrity failure or lack of injection zone isolation. Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. The following table identifies the specific rules affected by the rewrite. Affected Rules Injection Order "Demonstration of "Well Integrity "Administrati ve Mechanical Failure and Action" Integrity" Confinement" Area Injection Orders Ala 1 - Duck Island Unit 6 7 9 Ala 2B - Kuparuk River Unit; Kuparuk River, 6 7 9 Tabasco, Ugnu, vVest Sak Fields Ala 3 - Prudhoe Bay Unit; 6 7 9 Western Operating Area AIO 4C - Prudhoe Bay Unit; 6 7 9 Eastern Operating Area AIO 5 - Trading Bay Unit; 6 6 9 NlcArthur River Field AIO 6 - Granite Point Field; I Northern Portion 6 7 9 AIO 7 - Middle Ground 6 7 9 Shoal; Northern Portion AIO 8 - Middle Ground 6 7 9 Shoal; Southern Portion AIO 9 - Middle Ground 6 7 9 i Shoal; Central Portion I AIO lOB - Milne Point Unit; Schrader Bluff, Sag River, 4 5 8 Kuparuk River Pools AIO 11 - Granite Point 5 6 8 Field; Southern Portion AIO 12 - Trading Bay Field; 5 6 8 Southern Portion AIO 13A - Swanson River 6 7 9 Unit AIO 14A - Prudhoe Bay 4 5 8 Unit; Niakuk Oil Pool AIO 15 - West McArthur 5 6 9 -....",.,.... -~ Affected Rules "Demonstration of "Well Integrity "Administrative Injection Order Mechanical Failure and Action" Integrity" Confmement" River Unit AIO 16 - Kuparuk River 6 7 10 Unit; Tam Oil Pool 6 8 AIO 17 - Badami Unit 5 AIO 18A - Colville River 6 7 II Unit; Alpine Oil Pool AIO 19 - Duck Island Unit; 5 6 9 Eider Oil Pool AIO 20 - Prudhoe Bay Unit; 5 6 9 Midnight Sun Oil Pool AIO 21 - Kuparuk River 4 No rule 6 U nit; Meltwater Oil Pool AIO 22C - Prudhoe Bay 5 No rule 8 U nit; Aurora Oil Pool 6 9 AIO 23 - Northstar Unit 5 AIO 24 - Prudhoe Bay Unit; 5 No rule 9 Borealis Oil Pool AIO 25 - Prudhoe Bay Unit; 6 8 13 Polaris Oil Pool AIO 26 - Prudhoe Bay Unit; 6 No rule 13 Orion Oil Pool Disposal Injection Orders DIO 1 - Kenai Unit; KU No rule No rule No rule WD-I DIO 2 - Kenai Unit; KU 14- No rule No rule No rule 4 DIO 3 - Beluga River Gas No rule No rule No rule Field; BR WD-l DIO 4 - Beaver Creek Unit; No rule No rule No rule BC-2 DIO 5 - Barrow Gas Field; No rule No rule No rule South Barrow #5 DIO 6 - Lewis River Gas No rule No rule 3 Field; WD-l DIO 7 - West McArthur 2 3 5 River Unit; WIvfRU D-I DIO 8 - Beaver Creek Unit; 2 3 5 BC-3 DIO 9 - Kenai Unit; KU 11- 2 3 4 17 010 10- Granite Point 2 3 5 Field; GP 44-11 Inj ection Order "Demonstration of Mechanical Integrity" 2 DIG 11 - Kenai Unit; KU I 24-7 ! DIG 12 - Badami Unit; WD- I 1, WD-2 DIG 13 - North Trading Bay Unit; S-4 DIG 14 - Houston Gas Field; Well #3 DIO 15 - North Trading Bay Unit; S-5 DIO 16 - West McArthur River Unit; WMRU 4D DIG 17 - North Cook Inlet Unit; NCill A-12 DIG 19 - Granite Point Field; W. Granite Point State 17587 #3 DIO 20 - Pioneer Unit; Well 1702-15DA \VDW DIO 21 - Flaxman Island; Alaska State A-2 DIO 22 - Redoubt Unit; RU D1 DIO 23 - Ivan River Unit; IRU 14-31 DIO 24 - Nicolai Creek Unit; NCU #5 DIO 25 - Sterling Unit; SU 43-9 DIO 26 - Kustatan Field; KFl Storage Injection Orders SIO 1 - Prudhoe Bay Unit, Point McIntyre Field #6 SIO 2A- Swanson River Unit; KGSF #1 SIO 3 - Swanson River Unit; KGSF #2 Enhanced Recovery Inj ection Orders EIO 1 - Prudhoe Bay Unit; Prudhoe Bay Field, Schrader Bluff Formation Well V-I05 2 2 2 2 2 2 3 3 " .) 3 No rule 3 3 No rule 2 2 No rule Affected Rules "Well Integrity "Administrative Fail ure and Action" Confinement" 3 4 3 5 3 6 3 5 3 Rule not numbered 3 5 3 6 4 6 4 6 4 7 No rule 6 No rule 6 Order expired 4 7 4 7 No rule No rule No rule 6 No rule 7 No rule 8 Injection Order EID 2 - Redoubt Unit; RU-6 '-' "Demonstration 0 f Mechanical Integrity" 5 ............ Affected Rules "Well Integrity Failure and Confmement" 8 "Administrative Action" 9 I 02-902 (Rev. 3í94) Publisher/Original Copies: Department Fiscal, Department, Receiving AO.FRM STATE OF ALASKA ADVERTISING ORDER NOTICE TO PUBLISHER ADVERTISING ORDER NO. INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTiFIED AO-02514016 AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COpy OF ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE F AOGCC 333 West th Avenue, Suite 100 Aú1chorage,AJ( 99501 907-793-1221 AGENCY CONTACT DATE aF A.a. R o M Jody Colombie September )7,)004 PHONE PCI\J (907) 793 -11.).1 DATES ADVERTISEMENT REQUIRED: T a Journal of Commerce 301 Arctic Slope Ave #350 Anchorage, AJ( 99518 October 3, 2004 THE ~L\ TERIAL BETIVEEN THE DOliBLE LINES MCST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOW"i. SPECIAL INSTRUCTIONS: United states of America AFFIDAVIT OF PUBLICATION REMINDER State of ss INVOICE MUST BE IN TRIPLICATE AND MUST REFERENCE THE ADVERTISING ORDER NUMBER. A CERTIFIED COPY OF THIS AFFIDAVIT OF PUBLICATION MUST BE SUBMITTED WITH THE INVOICE. ATTACH PROOF OF PUBLICATION HERE. division. I Before me, the undersigned, a notary public this day personally appeared who, being first duly sworn, according to law, says that he/she is the of Published at in said division and state of and that the advertisement, of which the annexed is a true copy, was published in said publication on the day of 2004, and thereafter for _ consecutive days, the last publication appearing on the _ day of , 2004, and that the rate charged thereon is not in excess of the rate charged private individuals. Subscribed and swam to before me This _ day of 2004, Notary public for state of My commission expires Public Notices "- ~---- Subject: Public Notices From: lody Colombie <jody_colombie@admin.state.ak.us> Date: Wed, 29 Sep 2004 13:01:04 -0800 To: undisclosed-recipients:; . BeC: Cynthia B Mciver <bre~ mciver@admin.state.ak.us> ~ Angela Webb <angie_webb@adrnin.state.ak.us>, Robert E Mmtz <robert~tpÎI1~@I~w..state.alcus>; Christine Hansen <c.hansen@iogcc.state.ok.us>, Terrie Hubble <hubblet!@bp.c:om>, Sondra Stewman <StewmaSD@BP .com>, Scott & Cammy Taylor <staylor@alas~.net>, s~cltj <stanekj@unocal.com>, ecolaw <ecolaw@trustees.org>, rose~sdale <roseragsdale@gci.net>, tnnjrl <trmjr 1 @aol.com>, jbriddle <jbridclJe@marathonoiI.com>"rockhill <rockhìll@aoga.oig>, shaneg <shaneg@evergreengas.com>, jdarlington <jdarIington@f{)re$t~il.co~> ,n~lson <knelson@petroleumnews.com>, cboddy <cboddy@usibelli.cOn;t>,~:pa1ton . <mark.dalton@hdrinc.com>, Shannon Donnelly <shannon.donneny@Conocophillips.com>~, '~Mark P. Worcester" <mark.p.worcester@conocophiIHps.com>, "JerryC.Dethlefs"" " · " <jerry .c.dethlefs@conocophillips.com> ,Bob <bob@inletkeeper.()rg>,~dv<wØv@dnr.state.ak.us>, tjr <tjr@dnr.state.ak:.us>, bbritch <bbritch@alaska.net~~tÍ1jnelson <ntjne~n@p~rV41gertz.com>, . Charles O'Donnell <charl~s.o'donnell@veco~com>, "Rár1dy L~Skillemtr- <SkílleRL@BP.com>, "Deborah J. Jones" <JonesD6@BP.com>, "Paul G..HyattU <hyatipg@BP.com>, "StevenR. Rossberg" <RossbeRS@BP.com>, Lois <lois@inletkeeper.org>., Dan Br-oss;<kw1cnéws@kuac.org>, Gordon Pospisil <PospisG@BP.com>, "Francis S. Sommer" <So~erES@BP.com>~ Mik,el Schultz <MikeI.Schultz@BP .com>, "Nick W. Glover'! <GloverNW@Bp.eom>; "DarylJ.Kleppin" <KleppiDE@BP.com>, "Janet D. Platt" <PLattJD@BP.com>, lI~osanneM.Jacpbsen" <J acobsRM@BP .com>, ddonkel <ddonkeI@ctl.rr.com>, CoIlli1s·M0urrt <collins_mount@revenue.state.ak.us>, mckay <mckay@gci.Iiet>"Barb~a F Fidfmér <barbara.£fullmer@conocophillips.com>, bocastwf <~castwf@bp.com>~ Charles Bark~r : <barker@usgs.gov>, doug_schultze <doug_ schultze@xtoenergy.çom>,Hank Alford <hank.alford@exxonmobií.com>, Mark Kovac <yeSnol@gêi.net>, gspfoff <gspfoff@aurorapower.com>, Gregg Nady <gregg.nady@sheU.coin>,Fred Steece <fredsteece@state.sd.us>, rcrotty <rcrotty@ch2m.com>, jejones<jejones@aurorapower.com>, clapa <dapa@alaska.net>, jroderick <jroderick@gci.net>, eyancy <eyatwy@seal-tit~~J1et>-, "James M. Ruud" <james.m.ruud@conocopbillìps.com>, Brit L~vely <mapàIagka@al<.net>, jail <jah@dnr.state.ak.us>, Kurt E Olson <kurt,- olson@legis:stat¢"äk.us>,_bt1O!1oje <bttonoje@bp.cOlIl>, Mark Hanley <m~k _ hanley@anadarko.com>,loren_lernan <loten _)em@@gov ~state.ak.us>, Julie Houle <';ulie_houle@dnr.state.ak.us>, John W Katz <jwk~@sso~Qrg>,S~ .fHill <suzan _ hill@dec.state.ak.us>, tablerk <tablerk@ullocal.com>, ~rady <br~ga.org>.) Brian Havelock <beh@dnr.state.ak.us>, bpopp <bpopp@borough.ke~Lak.us>, JiinWhîte <j imwhite@satx.rr.com>, It John S. Haworth" <john~s.ha.w()1th@e~onffiobil.col1l>, marly , <marty@rkindustrial.com>, ghammons <ghamm?ns@ao).com>, IÌ).1cle.an. - <nnclean@pobox.a1aska.net>, mkm 7200 <mkri17200@~ö[com>, ~Briari'Gillespie <ifbmg@Uaa.alaska.edu>, David L Boelens <dbpelens@a~QiapOwer.co111>, 'Topd J?Urkee <TDURKEE@KMG.cøm>, Gary Schultz <gal)'_schultZ@drit.sfåte.ak.uS>iW ayn~:~ancier <RANCIER@petro-cariada.ca>, ,Bill Miner <Bill~ M~le~xtoaI~þr:G~tp>, -Btand(:)~ Gagn.on <bgagnon@brenalaw.com>, P~uI Winslow <pmwinslow@foresfuil.com>, ~GarryCatron <catrongr@bp.com>, Sharmaine CopeJand:<CQþelasv@bp~com>, StJistnneAllèxan . <sallexan@heImenergy.com>, Kristin Dirks <kristin ~ dirlçs@dnr~$te.ak.us>.~ KayrtellZeman <kjzeman@marathonoi1.coµl>, John Tower <John.Towei@eia.doe:goy>,BillFowler· . <BiIl_ F owler@anadarko.COM>, Vaughn Swartz c<vaughn.swartz@roccm.'com>,sèott Cranswick 10f2 9/29/2004 1:10 PM Public Notices <.scoit.éranswick@nuTI.s.gov>, Brad>McKim«rnck.ímbs@BP.cof)1> p:r.$a.f¡effind 'the>' at.taChed '.Not:LceaIic.i.Attåcl1.me.ntfÔri:.~7 ~f9#?:c>~~d' ameriâmel1.t àf un.ª~rground,injection orders ,and,·thePuBJ.i.c l'1ot.ice'~appYV[alJ..ey #10. J(jdy,Colombie : ., ., ",'. ,"', , ' " ' ,,'. ' .,',,", ..,,"', ,,' ,',,', ,imC()ptent"'I'ype=ª1Jplicationlmsworcl: ¡Mechanlçallntegrlty:propo~al.d9C¡ , '",.'.> '.','.... ,'..'",."','.,.'..< .);.;. ,.""£:'4.' . ". ',', "," , ,," ',. "·",:c:ontent-Enco9µtg:t)êlS~u - ---_._,,~..__._--- --_._-~---~_.._..--_. .__._. .--_.__..------~-- ._...._.m____ ______.___'___.,_ n,_ .-_.__'-_..__......__.....,_._ . '. ., ..."..',.......,.,.".".".< ,., " " ,'..',.,..','..", ,u>*..Jern~tént..·H'~þe:a.þþlicati()nl:rrtsw()td . MechamcalIntegrlty"ofWellsNotlçe..doCI, '.,'. '..".'.'",.,.',."..'...'.'.' > ,',>. ".'" ""'b' '.,'. 6."4"" ¡ Content-EnCtlcl1ng: ,ase . c;ontent-'Fy~: ~IìøatÌonJrn.sw()rd HappyVaUeyIO _ HearingNotice.doc ,",,',"...' ."'. C~ntellt-EpcOlling:hAA¢64 __. _..... .__.____~.mr._~ ._¥_._._________. .....___. _......<..-__. ___~._""_~'--:.._~.....,_._...;.__.__.:'-_____...;, .....____.~ _._._._.._~______~___~_____¥ __._~______________._. .__h __---'---___._____'-"'" 20f2 9/29/2004 1: 10 PM Public Notice ...~ - Subject: Public Notice From: lady Colombie <jody _ colombie@admin.state.ak.us> Date: Wed, 29 Sep 2004 12:55:26 -0800 To:.legal@alaskajòumal.com Please publish the attached Notice on October 3, 2004. Thank you. Jody Colombie Content- Type: applicationlmsword Mechanical Integrity of Wells Notice.doc' b : Content-Encoding: ase64 Ad Order form.doc ----p--- --------- 1 of 1 9/29/2004 1: 1O PM Citgo Petroleum Corporation PO Box 3758 Tulsa, OK 74136 Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 /'1alj~d Ic¡íþ"J David McCaleb I IHS Energy Group GEPS 5333 Westheimer, Ste 100 Hous~n,TX 77056 Kelly Valadez Tesoro Refining and Marketing Co. Supply & Distribution 300 Concord Plaza Drive San Antonio, TX 78216 Robert Gravely 7681 South Kit Carson Drive Littleton, CO 80122 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 Jerry Hodgden Hodgden Oil Company 408 18th Street Golden, CO 80401-2433 Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 John Levorsen 200 North 3rd Street. #1202 Boise, 10 83702 Kay rvlunger Munger Oi/lnformation Service, Inc PO Box 45738 Los Angeles, CA 90045-0738 Samuel Van Vactor Economic Insight Inc. 3004 SW First Ave. Portland, OR 97201 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle. WA 98119-3960 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage. AK 99502 Schlumberger Drilling and Measurements 2525 Gambell Street #400 Anchorage, AK 99503 David Cusato 200 West 34th PMB 411 Anchorage, AK 99503 Baker Oil Tools 4730 Business Park Blvd.. #44 Anchorage, AK 99503 Ciri Land Department PO Box 93330 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 Jack Hakkila PO Box 190083 Anchorage, AK 99519 Darwin Waldsmith PO Box 39309 Ninilchick, AK 99639 James Gibbs PO Box 1597 Soldotna, AK 99669 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 Penny Vadla 399 West Riverview Avenue SOldotna, AK 99669-7714 Richard Wagner PO Box 60868 Fairbanks, AK 99706 Cliff Burglin PO Box 70131 Fairbanks, AK 99707 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 North Slope Borough PO Box 69 Barrow, AK 99723 [Fwd: Re: Consistent Wording for Injection ~rs - Well Integrity ... <- '-~ Subject: [Fwd: Re: Consistent Wording for InjectiÓtl OrdeFs'~', WeH:futegritr@.evised.)] From: John Norman <john_norman@admin.s}ate.ak.ll~> Date: Fri, 01 Oct 2004 11:09:26 -0800 To: lody J Colombie <jody___colOm.bie@adiniiL.stâ.t~.åìtû~> more -------- Original Message -------- Subject:Re: Consistent Wording for Injection Orders - Well Integrity (Revised) Date:Wed, 25 Aug 2004 16:49:40 -0800 From:Rob Mintz <robert mintz@law.state.ak. us> To:j ¡m regg@Jadmin.state.ak. us CC:dan seamount@admin.state.ak.us, john norman@admin.state.ak.us Jim, looks good, but I still think maybe it would be good to include the following sentence or something like it in the well integrity and confinement rule: "The operator shall shut in the well if so directed by the Commission." My thinking is that otherwise, an operator might argue that the Commission can only require the well to be shut in by going through an enforcement action, issuing an order after notice and opportunity for hearing, or meeting the strict requirements for an emergency order under the regulations. The proposed language makes clear that it is a condition of the authorization to inject, that the operator must shut in the well if directed by the Commission after a notification of loss of integrity, etc. »> James Regg <jim regg@admin.state.ak.us> 8/25/2004 3:15:06 PM »> Rob - Thanks for the review; here's a redraft after considering your comments. I have accepted most of the suggested edits; also attached is response to questions you pose (responses are embedded in the comments, using brackets [JBR - ...J to set apart from your questions). Jim Regg Rob ~fintz wrote: Jim, I have some questions about the draft language, which are shown as comments on the first document attached. Based on my current guesses about what the answers will be to my questions, I also have some suggested edits, which are shown as redlines on the second document attached. »> James Regg <jim regg@admin.state.ak.us> 8/1712004 4:33:52 PM »> Please delete previous version (email sent 8/9/04); I found another inconsistency in the injection orders regarding well integrity that I have integrated into the proposed fix. Attached is a proposal for consistent language in our injection orders addressing 3 rules related to well integrity: - "Demonstration of Tubing/Casing Annulus Mechanical Integrity" - "Well Integrity Failure" - "Administrative Actions". This proposal includes input from all Sr. staff (except Jack). If you agree with the approach, I'll work with Jody to prepare the public notice. Main points - Demonstration of Tubing/Casing Annulus Mechanical Integrity - standardizes the wording used for mechanical integrity demonstrations, and establishes abililty to grant alternate methods (e.g., temp survey, logging, pressure monitoring in lieu of pressure testing lof2 1012/20044:07 PM [Fwd: Re: Consistent \Vording for Injection ers - \Vell Integrity .,. - specific to AIO 2C for Kuparuk, there is wording that is more appropriately included in \VelI Integrity Failure (i.e., more frequent NUTs when communication demonstrated) - establishes more frequent I'vUT schedule for slurry injection wells (every 2 yrs) which is consistent with our current practice (but not addressed in regulations) Well Integrity Failure - retitles to "\Vell Integrity Failure and Confinement"; inserted language regarding injection zone integrity (see DIO 25 and 26) - consistent language regardless of type of injection (disposal, EOR, storage); - eliminates requirement for immediate shut in and secure; allows continued injection until Commission requires shut in if there is no threat to freshwater; - eliminates delay in notifying Commission after detect leakage or communication ("i.e., "immediately notify"); - removes language about notifying "other state and federal" agencies; - requires submittal of corrective action plan via 10-403; - requires monthly report of daily injection rate and pressures (tubing and all casing annuli); this is a requirement we currently impose \vhen notified of leak or pressure communication; - notice and action not restricted to leaks above casing shoe as stated in several DIOs Administrative Actions - adopts" Administrative Actions" title (earlier rules used" Administrative Relief'); - consistent language regardless of type of injection (disposal, EOR, storage); - uses "administratively waive or amend" in lieu oftenns like "revise", "reissue", etc.; - adds geoscience to "sound engineering principles"; - language is more generic regarding fluid movement out of zone; existing versions mention varying combinations of protecting "freshwater", "aquifers", "USDWs"; "risk of fluid movement"; "fluid escape from disposal zone" Jim Regg --'-~._._, _,_,...;...__-_ u.'_ ._ .~__ _,'-_u_____ John K, Norman <John Nonnan~admin.state.us> Commissioner Alaska Oil & Gas Conservation Commission 20f2 1 On0004 4,07 PM [Fwd: Re: Consistent Wording for Injection I rs - \Vell Integrity ... "- Subject: [Fwd: Re: Consistent Wording for InjëctionOrders -'Wèllmtëgrity{Revised)] From: John Norman <john_norman@admin.stäte.ak.us> Date: Fri, 01 Oct 2004 11:08:55 -0800 To: lody J Colombie<jody_colombie@admin.state.ak.us> please print all and put in file for me to review just prior to hearing on these amendments. thanx -------- Original Message -------- Subject:Re: Consistent Wording for Injection Orders - Well Integrity (Revised) Date:Thu, 19 Aug 2004 15 :46:31 -0800 From:Rob Mintz <robert mintz@law.state.ak.us> To:dan seamount@admin.state.ak.us, Jim regg@admin.state.ak.us, john norman@)admin.state.ak.us Jim, I have some questions about the draft language, which are shown as comments on the first document attached. Based on my current guesses about what the answers will be to my questions, I also have some suggested edits, which are shown as redlines on the second document attached. »> James Regg <jim regg@admin.state.ak.us> 8/17/20044:33:52 pIvr »> Please delete previous version (email sent 8/9/04); I found another inconsistency in the injection orders regarding well integrity that I have integrated into the proposed fix. Attached is a proposal for consistent language in our injection orders addressing 3 rules related to well integrity: - "Demonstration of Tubing/Casing Annulus Mechanical Integrity" - "Well Integrity Failure" - "Administrative Actions" . This proposal includes input from all Sr. staff (except Jack). If you agree with the approach, I'll work with Jody to prepare the public notice. Main points - Demonstration of Tubing/Casing Annulus lVlechanical Integrity - standardizes the wording used for mechanical integrity demonstrations, and establishes abililty to grant alternate methods (e.g., temp survey, logging, pressure monitoring in lieu of pressure testing - specific to AIO 2C for Kuparuk, there is wording that is more appropriately included in Well Integrity Failure (i.e., more frequent MITs when communication demonstrated) - establishes more frequent MIT schedule for slurry injection wells (every 2 yrs) which is consistent with our current practice (but not addressed in regulations) Well Integrity Failure - retitles to "Well Integrity Failure and Confinement"; inserted language regarding injection zone integrity (see DIO 25 and 26) - consistent language regardless of type of injection (disposal, EOR, storage); - eliminates requirement for immediate shut in and secure; allows continued injection until Commission requires shut in if there is no threat to freshwater; - eliminates delay in notifying Commission after detect leakage or communication ("i.e., "immediately notify"); - removes language about notifying "other state and federal" agencies; - requires submittal of corrective action plan via 10-403; - requires monthly report of daily injection rate and pressures (tubing and all casing annuli); this is a requirement we currently impose when notified of leak or pressure communication; - notice and action not restricted to leaks above casing shoe as stated in several DIOs Administrative Actions lof2 10/2/20044:07 PM [Fwd: Re: Consistent Wording for Injection ;rs - Well Integrity... - adopts "Administrative Actions" title (earlier rules used "Administrative Relief'); - consistent language regardless of type of injection (disposal, EOR, storage); - uses "administratively waive or amend" in lieu of terms like "revise", "reissue", etc.; - adds geoscience to "sound engineering principles"; - language is more generic regarding fluid movement out of zone; existing versions mention varying combinations of protecting "freshwater", "aquifers", "USD\Vs"; "risk of fluid movement"; "fluid escape from disposal zone" Jim Regg John K. Nonnan <John Norman@admin.state.us> Commissioner Alaska Oil & Gas Conservation Commission Content-Type: applicationlmsword Injection Order language - questions.doc Content-Encoding: base64 - - -------- - ~ __ _. __ ~____ - _.n_ _.____ _. __ ___~__.____ _ ____ . ____.____~____ ___ _____ ___________ _______. __ _ . __._. __ _ __ ___.___ _u___ _ ____.._______... Content-Type: applicatiot1/msword Injection Orders language edits. doc Content-Encoding: base64 20f2 10í2/2004 4:07 PM - - Standardized Language for Injection Orders Date: August 17, 2004 Author: Jim Regg Demonstration of Tubing/Casing Annulus Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before injection begins, after a workover affecting mechanical integrity, and at least once every 4 years while actively injecting. For slurry injection wells, the tubing/casing annulus must be tested for mechanical integrity every 2 years. The MIT surface pressure must be 1500 psi or 0.25 psi/ft multiplied by the vertical depth, whichever is greater, must show stabilizing pressure and may not change more than 10% during a 30 minute period. Any alternate means of demonstrating mechanical integrity must be approved by the Commission. The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests. Well Integrity Failure and Confinement The tubing, casing and packer of an injection well must demonstrate integrity during operation. The operator must immediately notify the Commission and submit a plan of corrective action on Form 10-403 for Commission approval whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, or log. If there is no threat to freshwater, injection may continue until the Commission requires the well to be shut in or secured. A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating pressure communication or leakage. Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. Standardized Language for Injection Orders Date: August 17, 2004 Author: Jim Regg Demonstration of Tubing/Casing Annulus Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before injection begins, at least once every four, years thereafter (except at least once every two years in the case of a slurry injection \vell), and before returning a wen to service follo\ving aftBf a workover affecting mechanical integrity, and at leQ~;t once e\'~ry ,I years \\'hite actively injecting. Fo·r slurry injection \vells, the tubing/casing amlulus inust bè tesh;d for mechanica.l integrity every 2 years. Unless an alternate lTIeanS is approved by the COlnnlission. lnechanìc.al integrity lTIUst be dcn10nstrated by a tubin,£! pressure test using a +B-e ~surface pressure of must be 1500 psi or 0.25 psi/ft multiplied by the vertical depth, whichever is greater, that ffi-H-S-Í-show3, stabilizing pressure that does2.nd lTIJY not change more than 104:é- percent during a 30 minute period. --A:tty altenlate nleans <..l-f dernonstrating lncchanic.al integrity must be approved by the COlnnlission. The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests. Well Integrity Failure and Confinement Except as othenvise provided in this rule. +1he tubing, casing and packer of an injection well must demonstrate lnaintain integrity during operation. \Vhenever any pressure conlmunication. leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, log. or other evidence. t+he operator mæt-shall immediately notify the Commission and submit a plan of corrective action on a Form 10-403 for Commission approval.:. v..:henever any pressure cOlnlnunication~ lça.kage or lack of injection zone isolation is indicated by injection rate. operating pressure observation, test, survey, or log. The operator shall shut in the well if so directed by the COlTIlnission. The operator shall shut in the \vell \vithout awaitin,g a response hom the Commission if continued operation \vould be unsafe or would threaten contamination of freshwaterIf there is no threa.t to fresh\vaxer. injection lnay continue until the C0l111nission requires the \\'e11 to be shut in or secured. Until corrective action is successfully cOIl1p1eted. ª monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating pressure communication or leakage. Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. ~[Fwd: Re: [Fwd: AOGCC Proposed WI Lan~ ~ for Injectors]] -- '..,..,/ SubJect: [Fwd: Re: [Fwd: AOGCC Proposed WI Language for Irtjectors]] From: Winton Aubert <winton _aubert@admin.state.ak.us> Date: Thu, 28 Oct 2004 09:48:53-0800 To: Jody J Colombie <jody__colombie@admin.state.alcus> This is part of the record for the Nov. 4 hearing. WGA -------- Original Message -------- Subject: Re: [Fwd: AOGCC Proposed WI Language for Injectors] Date: Thu, 28 Oct 2004 09:41:55 -0800 From: James Regg <jim regg@admin.state.ak.us> Organization: State of Alaska To: Winton Aubert <winton aubert@admin.state.ak.us> References: <41812422.8080604@admin.state.ak.us> These should be provided to Jody as part of public review record Jim Winton Aubert wrote: FYI. -------- Original Message -------- AOGCC Proposed WI Language for Tue, 19 Oct 2004 13:49:33 -0800 Engel, Harry R <EngeIHR@BP.com> winton aubert@admin.state.ak.us Injectors Subject: Date: From: To: Winton... Here are the comments we discussed. Harry *From: * NSU, ADW Well Integrity Engineer *Sent: * Friday, October 15, 2004 10:43 PM *To: * Rossberg, R Steven¡ Engel, Harry Ri Cismoski, Doug Ai NSU, ADW Well Operations Supervisor *Cc: * Mielke, Robert L.¡ Reeves, Donald F¡ Dube, Anna T¡ NSU, ADW Well Integrity Engineer *Subject: * AOGCC Proposed WI Language for Injectors Hi Guys. John McMullen sent this to us, it's an order proposed by the AOGCC to replace the well integrity related language in the current Area Injection Orders. Listed below are comments, not sure who is coordinating getting these in front of Winton/Jim. Overall, looks okay from an Operations perspective. We do have a few comments, but could live with the current proposed language. Note the proposed public hearing date is November 4. The following language does not reflect what the slope AOGCC inspectors are currently requiring us to do: liThe mechanical integrity of an injection well must be demonstrated before injection begins, at least once every four years thereafter (except at least once every two years in the case of a slurry injection well), and * before* ** lof3 10/28/2004 11:09 AM [Fwd: Re: [Fwd: AOGCC Proposed \VI LanL .ß for Injectors]] returnj.ng a well to service following a workover affecting mechanical integrity." After a workover, the slope AOGCC inspectors want the well warmed up and on stable injection, then we conduct the AOGCC witnessed MITIA. This language requires the AOGCC witnessed MITIA before starting injection, which we are doing on the rig after the tubing is run. Just trying to keep language consistent with the field practice. If "after" was substituted for "before", it would reflect current AOGCC practices. It would be helpful if the following language required reporting by the "next working day" rather than "immediately", due to weekends, holidays, etc. We like to confer with the APE and get a plan finalized, this may prevent us from doing all the investigating we like to do before talking with the AOGCC. "Whenever any pressure communication¡ leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, log, or other evidence, the operator shall * immediately* ** notify the Commission" - This section could use some help/wordsmithing: "A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating well integrity failure or lack of injection zone isolation." Report content requirements are clear, but it's a little unclear what triggers a well to be included on this monthly report. Is it wells that have been reported to the AOGCC¡ are currently on-line and are going through the Administrative Action process? A proposed re-write would be: "All active injection wells with well integrity failure or lack of injection zone isolation shall have the following information reported monthly to the Commission: daily tubing and casing annuli pressures, daily injection rates." Requirements for the period between when a well failure is reported and when an administrative action is approved are unclear. This document states "the operator shall immediately notify the Commission and submit a plan of corrective action on a Form 10-403". If we don't plan to do any corrective action, but to pursue an AA, does a 10-403 need to be submitted? The AOGCC has stated they don't consider an AA as "corrective action". Let me know if you have any questions. Joe -----Original Message----- From: Kleppin, Daryl J Sent: Wednesday, September 29¡ 2004 1:37 PM To: Townsend, Monte Ai Digert, Scott Ai Denis, John R (ANC) i Miller¡ Mike Ei McMullen, John C Subject: FW: Public Notices FYI -----Original Message----- From: Jody Colombie [ mailto:jody colombie@admin.state.ak.us Sent: Wednesday, September 29, 2004 1:01 PM Subject: Public Notices Please find the attached Notice and Attachment for the proposed amendment of underground injection orders and the Public Notice Happy Valley #10. Jody Colombie «Mechanical Integrity proposal. ZIP» «Mechanical Integrity of Wells Notice.doc» 2 of3 1 nO~/?nn4 1 1 ·nq AM *1 . Unocal Alaska Union Oil Company of California 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7661; Fax (907) 263-7847 . UNOCAL. Larry P. Greenstein Prodction Technician Date: March 31,2004 Commission Chair John Norman Alaska Oil and Gas Conservation Commission 333 W. ih Ave., Suite #100 Anchorage, AK 99501-3539 Attn: Tom Maunder Re: DIO #23 -IRU 14-31 - Rule #4 Change Dear Chair Norman, Union Oil Company of California, d.b.a. Unocal, requests that Rule #6 of Disposal Injection Order #23 for the Ivan River Unit well 14-31 be used to provide the administrative relief clause to authorize the following wording change within Rule #4 - Monitoring Program. Remove the words - "An annual report evaluating the performance of the disposal operation, including an annual MIT and temperature log must be submitted by July 1 of each year." Replace with the sentences - "A schedule must be developed and coordinated with the Commission that ensures the tubing-casing annulus is pressure tested at least once every 4 years. The casing must be tested at a surface pressure of 1500 psi or 0.25 psi/ft multiplied by the true vertical depth of the packer, whichever is greater, but may not be subjected to a hoop stress greater than 70% of the minimum yield strength of the casing. The test pressure must show stabilizing pressure and may not decline more than 10% within thirty minutes. The Commission must be notified at least twenty-four (24) hours in advance to enable a representative to witness pressure tests." All other reporting and monitoring requirements for this well will remain in effect. The I RU 14-31 well is an intermittent Class II water disposal well and, so far, has been used for water disposal, safely handling a total of around 40,000 bbls of fluid. The well has been shut-in since the last injection cycle in October of 2002. This well has passed all previous MITs performed. The well will be asked to handle more of the day to day produced water disposal function for the West Side gas fields as the Lewis River Unit 0-1 well is phased out of service. Similar to Granite Point Field GPP 44-11 (010 #10, Rule #2 dated June 16, 1995), and Granite Point State 17587 #3 (010 # 19, Rule #3 dated July 6, 1999), both intermittent Class II disposal wells which were regulated to demonstrate tubinglcasing annulus mechanical integrity every 4 . . years, Unocal believes IAU 14-31 can safely be utilized as a Class /I disposal well with a MIT frequency of every four years. Thank you for your consideration and if you have any questions regarding this, please contact me at 263-7661. Sincerely, /', p" OJ) 7/ ~ljf < /...}{e,zM47!1fi.' Larry P. ¿{eenstein cc: Dave Whitacre Jeff Smetanka MIT book Well File RE: Ivan River e e Subject: RE: Ivan River From: "Greenstein, Larry P" <greensteinlp@unoca1.com> Date: Wed, 07 Apr 200409:57:09 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> Took me a while to find this Tom, but here is the electronic version of the temp survey done 8/13/02. Tim B. is out of town dealing with that nasty helicopter crash in the GOM. So I couldn't talk with him about what he had sent over to you. Hope this helps. Larry -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Tuesday, April 06, 2004 1:00 PM To: Larry Greenstein Subject: Ivan River Larry, I am looking more closely at your letter and the file. According to the records, Tim Brandenburg ran a temperature log August 13, 2002. He sent me the electronic information October 14, 2002. I no longer have that information. Is it possible for you to send it to me in e form?? Thanks, Tom Maunder, PE AOGCC Content-Description: QTData 8-13-02.xls QTData 8-13-02.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 1 of 1 5/26/2004 4:25 PM .. 61.86 RIH .. 61.853 .. 61.848 Temp Degree F .. 61.841 60 61 62 .. 61.828 2500 .. 61.81 .. 61.797! .. 61.778 2600 .. 61.766 .. 61.737 .. 61.714 2700 .. 61.688 i .. 61.659 .. 61.636 2800 .. 61.605 .. 61.573 III ~ .. 61.545 0::: :S 2900 .. 61.502 c.. .. 61.477 CI) c 61.441 .. 3000 .. 61 .406 .. 61.371 61.333 3100 61.303 .. 61.269 .. 61.229 3200 .. 61.195 .. 61.156 .. 61.125 3300 .. 61.087 .. 61.047 ! RIH Temp Degree F 59 o 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 m 1500 æ 1600 .r: 1700 õ.. 1800 ~ 1900 2000 2100 2200 2300 2400 ·,,7500 2600 2700 2800 ~ 2900 3000 3100 3200 - 3300 3400 60 61 62 m 61.86 61.853 m 61.848 m 61.841 61.828 · 61.81 .. 61.797 · 61.778 · 61.766' .. 61.737 .. 61.714 · 61.688 " 61.659 " 61.636 " 61.605 .. 61.5731 i m 61.545 i m 61.502 61.477 m 61.441 ~ 61.406 · 61.371 · 61.333, . 61.303' " 61.269 " 61.229 · 61.195 ~ 61.156 ~ 61.125 61.087 · 61.047 4t;-{p Ivan River, additional , . Subject: Ivan River, additional Date: Sat, 30 Jun 2001 22:12:26 -0800 From: Jane Williamson <Jane_ Williamson@admin.state.ak.us> Organization: Alaska Oil & Gas Conservation Commission To: Wendy D Mahan <wendy_mahan@admin.state.ak.us>, Julie M Heusser <julie _ heusser@admin.state.ak.us> Wendy, Julie I forgot to address a waiver request from requirement of 20AAC25.41 Ob on the Ivan River (see Well Construction item (6). which states the perfs have to be within 200 fet MD of packer. Final potential perfs are 242' from packer. Current perfs are 299' from packer. I don't see a problem with this, but Julie, you may wish to review. Jane 1 of 1 ,'._.....,,'.......-~'-'" 7/2/01 9:07 AM Ivan River AEO and DIO . , Subject: Ivan River AEO and DIO Date: Sat, 30 Jun 2001 18:06:16 -0800 From: Jane Williamson <Jane_ Williamson@admin.state.ak.us> Organization: Alaska Oil & Gas Conservation Commission To: Wendy D Mahan <wendy_mahan@admìn.state.ak.us>, Julie M Heusser <julie _ heusser@admin.state.ak.us> CC: Daniel T Seamount JR <dan_seamount@admin.state.ak.us>, Stephen F Davies <steve_davies@admin.state.ak.us>, Thomas E Maunder <tom _ maunder@admin.state.ak.us>, Camille 0 Taylor <cammy_taylor@admin.state.ak.us> 1//Mi/Orders_Draft/Ivan River AEO.doc ///MI/Orders_Draft/lvan River DIO.doc Wendy and Julie, I concluded engineering analysis on Ivan River disposal in 14-31, and attempted to draft AEO and DIO as provided in the paths noted above on the M drive (Highlight doc above, right click, press browse and it will take you there). The attached drafts need the water salinity and geologic info, prior injection into this strata and correct legal lingo. I'm sure you'll have a lot of changes, but hope this helps you. Unocal intends to use this site in early September. Wendy you indicated that the EP A needs 45 days review, so I guess the AEO needs to be out by Mid Ju1y. Bottom line, from an engineering standpoint, the disposa1 into 14-31 shou1d be approved, assuming they have provided all the information you need to proceed, Wendy from your standpoint. My findings are in the attached drafts. I am suggesting a few requirements, restrictions differing from their request. Following summarizes my concerns, and suggested action. I have reviewed completions of all wells, and the fracture model they provided. The fracture modeling in very pessimistic cases would not see extension of fractures vertically into strata at 2500' (2350'TVD). It would be confined by the 14' shale at 2945'. I am satisfied with the vertical analysis. However, it may be a different story laterally. Their modeled fracture half-length exceeds that of the proximity of the closest well 14-31. The proximity of the injection we]] to IRU 13-31 at 114' from IRU 14-31 has given me a 1itt1e concern (perhaps unwarrented) along with some of the specifics about the 13-31. Well 13-31 was drilled in 1992-93. The 95/8" is well cemented (excellent) from shoe to 2560'- so no problem up the 9 5/8" backside. The 9 5/8" had significant drilling based wear at the 1500' mark based upon caliper in 1993. Unocal wanted to use this as an annular disposal well (into the same zone we're talking about here). Because ofthe weak spot, they were limited to 1800 psi at surface (80% of burst) and could not get away at this pressure. This is about 3400 psi at the shoe (with 10.8 ppg mud), which is really close to the fracturing pressure downhole. 7" was run to 10,350' where it became stuck. The 7" was cemented with top of cement at 5000'. They then started disposal, and the rate droped to less than 1/4 BPM with the lower pressure limit imposed by the weak spot in 9 5/8". Unocal requested a change in operations to cement the annular space between the 95/8" and 7" from 2590-surface through the stage collar at 2793'. This would allow annular injection through the 7", into the stage collar, and then out the lower 7" x 95/8" annulus. On 12/8, they retested stage collar with retrievable set above, then below stage collar. They found the collar leaked @ 2500psi but casing held at 1500 psi with 10#/gal mud. We don't have a CBL after 2nd cement jobs but calculations indicate it is more than sufficient for cementing of the 7"x9 5/8" with a total of 1697 ___~ ......"'''''Ii''' ,",} ~'<.7"""" 1 of2 7/2/01 9:07 AM Ivan River AEO and DIO . , sax. Now, very worst case scenario is if the fracture hits the 7" of 13-31, travels up the 7"x 9 5/8" annulus to the DV and goes into that weak spot of 9 5/8". With all the cement that was pumped, this is very unlikely. While it is a remote possiblility that they would see a problem at the offset wells, I recommend a few precautions: · They have asked to be able to inject at up to 3300 psi at surface. I'm recommend the max pressure should lowered to 2800 psi. They have been able to demonstrate that they can get fluids away (2-5 BPM) at that pressure. This would help minimize potential of overpressuring 9 5/8" in 13-31, with friction drop and head. · Linocal should test the mechanical integrity of the 7" casing in Well 13-31 as well as the disposal well. · I recommend Unocal provide more depth on annular monitoring in the disposal and otTset wells, the potential hazards, and appropriate procedures. Unocal provided a proposed monitoring program for 13-31 which would monitor the glycol tank level. If level goes to high, it will all arm at both the 13-31 location and 14-31, and an automatic si of the 13-31 annulus would occur, and they would manually SI 14-31. I'm not fully comfortable that this is the correct path, and don't have enough information on these surface facilities to make a judgement. We should go ahead with the AEO and DIO, but just require that they provide this information before injection starts. I haven't run these proposed restrictions by Brandenburg and others at Unocal. The worst case scenarios I have mentioned here are remote, and I am not opposed to you taking them out. Hope this is sufficient. I will give you a call next week and see how it is going. Jane Name: Ivan River AEO.doc [:]Ivan River AEO.doc Type: WINWORD File (application/msword) Encoding: base64 20f2 7/2/01 9:07 AM --- ( . Ivan River 13-31 Monitoring during injection . I Subject: Ivan River 13-31 Monitoring during injection Date: Mon, 25 Jun 2001 15:45:59 -0700 From: "Brandenburg, Tim C -Contract" <brandenburgt@unocal.com> To: "'j ane _ williamson@admin.state.ak.us'" <j ane _ williamson@admin.state.ak.us>, "'wendy _ mahan@admin.state.ak.us'" <wendy _ mahan@admin.state.ak.us> For the protection of Ivan River 13-31, the following systemslprocedures will be in place prior to commencing injection into Ivan River 14-31: * As a part of the heater string I glycol system, Ivan River 13-31currently is equiped with an automatic shut in valve that will isolate the tubing x casing annulus in the event that a high level alarm in the glycol system should occur (i.e. if the fluid level should change in the glycol system therby indicating a loss or a gain in fluid from the annulus). Any communication into IR 13-31 tubing x casing annulus from any source would automatically shut in the annulus. * * The existing IR 13-31 Glycol High Level Alarm will be set up to also annunciate at the injection pump so that the injection pump operator can immediately shut down the pump in the event that communication developed to IR 13-31. In that event injection would not be re-initiated until it was determined that safe operations could continue and with commission approval. * * All annulus pressures will be checked and recorded prior to and after each injection cycle. * --~ -"-'._T. 1 of! 7/2/01 9:06 AM Unocal Application for Ivan River Aquifer ExemP. I Subject: Unocal Application for Ivan River Aquifer Exemption Date: Tue, 15 May 2001 15:56:01 -0700 From: Cutler. Thor@epamail.epa.gov To: Bob _ Crandall@admin.state.ak.us CC: Williams.J onathan@epamail.epa.gov, Terada.Calvin@epamail.epa.gov, KenknighU eff@epamail.epa.gov, N ogi.Jill@epamail.epa.gov RE:Unocal Application for Ivan River Aquifer Exemption, dated April 26,2001 received at EPA May 14, 2001. To: Bob Crandall, AOGCC USEPA recieved a UNOCAL application for freshwater aquifer exemption for the Ivan River Well 14-31 Section 1, T13N,R9W, S.M. Matanuska Borough, Ak on May 14, 2001. Perhaps you can assist me in seeking answers to the following questions: W~t bo~~ ... 1'ial.. ,.,~ 1) Why does the Unocal request ask for 1/2 mile as opposed to a 1/4 mile 1 V~~71f) radius? LONt.. TU ~ O~"~""110"J~J ~-A N¡"'l Y,Q.oÕV ~ INAt~1L ç-",. c;~~ F;f:::..~D~_ <-. 2) Why not inject into a deeper horizon? W,-¡..&.. 1'''(Jb~E:.O @ '.!t~SO\ ~~~....w.- C,.ÐNIHTlðJo-l- "IDA · 3) will the sands work in the Tyonek Formation? t~'::;) .. t\I"" hI Te..sr - 4) Would a well bore diagram be useful for the aquifer exemption request ? ~ - ~ ~a.ra'~~ 5) Should Unocal ask for a Class I Injection Well Permit (not ClassII) to .. manage a broader crossection of fluids? ~ t-.)C .. Sincerely, Thor Cutler 206-553-1673 fax 206-553-1280 cutler.thor @epa.gov 0TtbSL ·tk ~K-11'\)0 t()~- OIl.- Go. 7'0 GD ME. 1l'P vJ I ¡J Hi N6GO Yz M ) .. ~ J JJOCAl-- - tNt-1\ l)'~4>o~~)- INT~f"'L- ,- '1 UJ~rLJ C.:Z \.VI PLV6 é))l... Co~ NELo-s To ßU¡~ ~Ú)1Lù _ Tð p :> . 1 of 1 5/1'/'11:55 AM Unocal Application for Ivan River Aquifer ExemPt I Subject: Unocal Application for Ivan River Aquifer Exemption Date: Tue, 15 May 2001 15:56:01 -0700 From: Cutler.Thor@epamail.epa.gov To: Bob _ Crandall@admin.state.ak.us CC: Williams.J onathan@epamail.epa.gov, Terada. Calvin@epamail.epa.gov, Kenknight.J eff@epamail.epa.gov, N ogiJ ill@epamail.epa.gov RE:Unocal Application for Ivan River Aquifer Exemption, 26,2001 received at EPA May 14, 2001. dated April zL~ ,Cfd fJ('JJ i '" ~vhY\ ~Ce/r questions, /: It It/¡ , to a 1/4 mile~5í ¿::¡ feJ'e ¡:; &t r/~ -I~~ To: Bob Crandall, AOGCC USEPA recieved a UNOCAL application for freshwater aquifer exemption for the Ivan River Well 14-31 Section 1, T13N,R9W, S.M. Matanuska Borough, Ak on May 14, 2001. Perhaps you can assist me in seeking answers to the following 1) Why does ~ge/unocal request ask for 1/2 mite as opposed radius?- ~/:1.i' de ~ak ~ .f; r;¿.,¡j."[l,-",-I¡6'11 \ (( 2) Why not inject into a deeper horizon? C¿~/",> ;'"):) /' (34)) will the sands work in the Tyonek Formation? ,,/' .2o<:¡G /' ç).j.... Would a well bore diagram be useful for the aquifer exemption request? 2(;)c~ 5) Should Unocal ask for a Class I Injection Well Permit (not ClassII) to ';,-." manage a broader crossection of fluids? Sincerely, Thor Cutler 206-553-1673 fax 206-553-1280 cutler.thor @epa.gov \\ !~ \ \ " " / I Il~.:r t? ct. ()., J A ii Mc-{ P / ~;'~:"j.<~ / , -', /7-3/ , '"' ""?(;?2l~_ ..-.--.",,, . ./ &nJ:lf~n J 1!J ~)j ;5 :f r~}r4j)V! :)\) (j leG' C? , 1 of 1 5/23/01 10:08 AM . . I ~-v A(\.( R\ ý=r.? , uJGtLLC:::; No R'T"J1 q.4~~. ~ ~. ,/ ,;'. ;' ;' ~ ./ / , . I I. ' , I ·1 / '/ 2c06', » .' ;' . ;' , ~/ , ~ . ~ . ....29+' .- .(1 t \G) o \tc::) .~' t:\. . . ' . 7, . \=- . r 4loo' ~. , ~a:t) ~ '~ . " ~ I I. ~ I , I , ,~ '/ , I ,~ ~ l ~. I ' ~l'foo'" ~, ~...,_..~ '- - - ~ ~ ~ . ~'33'3+" :Ü<õJ.K) . . (if' O":J~'í l' ,f-, þ.;\cf'^ l3-3~ f . M.A: r,' '4-~', ' 1 . ': f Ij . . · 1'1 r· · ~/ :~ · ~~,. . ';'" ' ~ I .: 'T tøz5 r ~.I./ t , ~ ~.as" ~ ~,' .' /, " . ~ ~ . t.\P:í' ~ ~...;. \2.?ð). . J, 7 &. ; ¡f.(TTC, 0~ 'waArC I / ' ~ ~ . PbiAl'f 1'- . % V~ /1::)'001' ~~ ~. .... ~J~C:O , .~~. ~', , t/ ./ tw~. ê.oo~ ~ . , _ .~...... Ce,~ /. ~ ~~.:' " ~ - ~~"'- , ~() <5-.-1':.:$ s..'2.+ . l"'1Ù\ /". ' I"') /, . / I' . . h .' . ~.~,~. 4-\-( . tJ. &f..e 5/õ'J,."- +k.:tLc . :7 ,3~. ' ./ '/ ./ ./ I / I I . I ( / /' , I \...' ~~13 ;. .; .; ~ if' I ~ I ..'I . ~ I . . í , . ~ ,~ . . i ,;' ~C97 ~If " . If' ;, .If :1- .' I : I, :/ · , · , I .' I ~. " · r. !SSZ-' . r 4Sðf "1 I. " J :, 1· .v . ., ./ 228" 114' 665' ::OcJ,-,.{ . ,*-'l -' ' .' ~ ' ." 'jTõ~::r'!; '. ~ C:.E3~ Tbp ,~' , / ~ ~ ~. z 2 ~. ~ . ,.." , \999 AcPùl ~e F<- , , '6(."" ÞM 0 ^- : (?:.- "æ 'TÙD) ··.T .~. . , '. . 7'40:::13 , , ~ , .'~' . "/ . r f.' . " ~ ~' / ~ .. -' .: ':., 490' , \ < I 342,'1 ><:, 11155' I > I I . ',1 WELLBORE SEPARATIONS AT 2821 SS TOP OF INJECTION INTERVAL -#-5 RE: Ivan River Unit Disposal e ;> e \ ~ðl'" \G~ (. \ ~- ~ \ \ ~ 5;-0 a k~,s. \ð~r\)-<J\~~ \1s~-tt Subject: RE: Ivan River Unit Disposal Date: Mon, 4 Aug 2003 10:47:25 -0800 From: "Greenstein, Larry P" <greensteinlp@unocal.com> To: ''Tom Maunder" <tom_maunder@admin.state.ak.us> CC: "Jim Regg" <jim_regg@admin.state.ak.us> You bet Tom. That is exactly what was going on last October. The reserve pit clean up (grind & inject) shut down then. The normal water production from all the wells at Ivan River is collected in a plastic tank on the pad. Once a week, or every other week, a water truck offloads what it can carry and delivers it to the plastic tanks at Lewis River 0-1 disposal pad. After enough volume collects at Lewis River 0-1 pad, the operator starts up the pumps and pushes the water into the 0-1 disposal well. The 0-1 well also handles the water, if any, from Pretty Creek #4 as well as the other Lewis River wells. Hope this is what you were looking for Tom. Larry -----Original Message----- From: Tom Maunder rmailto:tom maunder@admin.state.ak.usl Sent: Monday, August 04, 2003 7:54 AM To: Larry Greenstein Cc: Jim Regg Subject: Ivan River Unit Disposal Hi Larry, , I was looking at the DNR letter approving the Unit Operations Plan (dated July 24) and pulled up the production/disposal information. According to the information I was able to pull up, the last time there was any disposal into 14-31 was October of last year. I believe there was some reserve pit cleanup going on. Although the reported monthly water production is low, I am curious how that volume is being handled. Would you check into this and get back to me. Thanks. Tom Maunder, PE AOGCC 'I IR 14-31 e ( e ( Subject: IR 14-31 Date: Mon, 14 Oct 2002 15:07:50 -0700 From: "Brandenburg, Tim C -Contract" <brandenburgt@unocal.com> To: '''Tom Maunder'" <tom_maunder@admin.state.ak.us> \ '\ 5 -'0(;:)<6 b\C) d~ Tom, Injection commenced into Ivan Rille!' 14-31 Class II Well on September 9, 2001 and continued until Ncwember 27,2001 at which time grinding and injection ops were suspended due to unseasonably cold weather. Grinding and injection was reinitiated July 19,2002 and continued to August ~ 11, 2002. A total of 31,870 bls have been injected to date. The Injected volume consists of slurried cuttings, drilling mud, completion fluids and flush waters generated from the dliUìng of local wells PCU NO.4 and LRU C-1 during the 2001 DIUUng Program. The injection pressure has averaged 1984 psi at a rate of 1.5 BPM. The attached temperature survey indicates the near-surface effects of circulating heated glycol in adjacent pad wells to a depth of about 1500 feet: Between 1500 feet and 2750 feet. the profile shows a gradient of 0.59 psi/100 feet of depth. BelDIN 2750 feet, the effect of injecting cold fluids causes a gradient shift to the left. The temp CUNe plots as antiCipated, but over all the entire CUNe is shifted left or is COOler than one may anticipate. Beyond that the log does not appear exceptional. A!!, I believe you have heard, the Environmental group intends to de-water to some extent the Ivan River Pit. They are planning to reJ11O\Ie the pit (next year I believe) and want to lower the water IeIIeIln the pit to help them with their technical plans. It is anticipated that they could inject between 5,000 bbls and 15,000 bbls depending on Fish and Game Permit expiration for the project. Once you have reviewed the attached, please call me at 263-7657 or (907) 252-3923. Thanks, Tim «QTData.zip» Name: QTData.zip ~QTData.ZiP Type: Zip Compressed Data (application/x-zip-compressed) Encoding: base64 1 of 1 1nt1,4l?nn? ~.¡:;-:t ¡:: IRU 14-31 Serial # Top:2108 Serial # Bottom:2168 Time bombs activated· Upper Time bombs activated - Lower Time bombs deactivated - Upper Time bombs deactivated - Lower Pressure test/Open Swab Valve Tubing Hanger RIH T 5005 RKB Depth _____,_... _!_____ h_ I Bottom stop for Temp & Press i - - -.' . -- '.. - -- -' .-.. ,-,1 .. 1 POOH --- -....------...-. .-.-....-...__.~_..-.__.__. --------.-.--., Close Swab Valve -- .--~- -._._-_.~_. -.-. ....___.....____.._._ .. .... _._n ..."U_... I ] e ( e t Wireline Stop-Time I Depth Sheet Survey Date: 8/13-14/02 22:42 22:42 02:19 02:19 Stops 20' 1000' 2000' 3000' 3200' 3000' 2000' 1000' 20' -..,___..0__'_- __.._ ___ ._. .._ 0..._ k___...-.__. _.__ ......_.. ____._ ...._._.._._...... . _h_O_..·__... _ .-......-..-...--...--.--...-. --. --,-----~-_... . -.. -.... ,_.,-..,,-- --......-.-..-.-. -------. ...----*--,-.------....-..- .--.-.....-.- ..,.. __.__._n. __., . _______m___n_____.___.__.__ ~__ _.._. .' h___, _,,~._...._. ____. _____ ._, - ·__...u __...___.__..__ø·_. --.,.;... ._- .-.... .. '. . ...-.....-.. u.ld - ..---. ---..-~- - ----_.~-_._-_.- - - - .---..-.- .----.- --~ .... . .....-- -- -.- .....~..__.._._., ..-- Page 1 of 1 Swab Open: Swab Closed: Wireline Operators FiIIlr Encoder on: 22:50 Name: Kirsch Encoder off: 01 :52 Stop time TIME ON TIME OFF Comments 10min 22:53 23:03 5min 23:19 23:24 5min 23:41 23:46 Smin 00:02 00:07 30min 00:12 00:42 Smin 00:45 00:50 .--. 5min 01:05 01:10 .....-.... - .. -- 5min 01:26 01:31 5min 01:47 01:52 ... . .---.-,,--- - ~..._-- 01:52 -.-----.-..--- ~-------- ...- .-.-- --.- . -....-.---. ....-- -......-.....--.. .__u_.._.___... ..-.--..-.- ....--... i . . ..--.~. -.---.--.-- ...-..- ---.._.~. -----.-----.--.----- ___'_ø_._.___._ ____"'+._.. _ _.....__·__..+...ø ".__.. _..._.___ _.. ._ __.__..__._". ___. _.__..~._._._______._.._.. _ _..._ ._._.. n____... __.._.~._._ .,_ I { e e Depth RKB (..) (..) 0'1 0 o 0 o 0 ï~ ---- -.. 'I,) 0'1 o o I\) ..... o CJ1 o 0 o 0 0'1 o o ..... o o o . ...,.-.-..- -.--- ._" ~ -~ ..,..~"-,, ." :"' .,..." . ...... t 'v t), -'(/ J' sf' ~ o' (J ~ 0 (/ ,; vJ' í~ t :; S~ ;" ~r Y ~ ~ P ...f1q¡1 o I ,¡ · · .. ,,' '. ., · · .þ. o ( .þ. C11 CJ1 o -I CD 3 'C en c <! CD '< -I CD 3 '0 o CD &Q i "TJ C11 C11 0> o 0> 0'1 (e ,e ( , State of Alaska Alaska Oil and Gas Conservation Commission MEMORANDUM TO: Cammille O. TaYIOrw1 Chair DATE: September 7, 2001 SUBJECT: Mechanical Integrity Test THRU: Tom Maunder 1G1h..1\. ~ Unocal Petroleum Engineer,Ø-.2- ,.t~ ~, Ivan River s.~\(~ ,~\ IRU 14-31 FROM: Lou Grimaldi Petroleum Inspector Ivan River Field NON- CONFIDENTIAL WellllRU 14-311 Type Inj'l P.T.D. 175-008 Type test No1es: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N :;: NOT INJECTING N P Packer Depth Pretest I Tov.D_1 2903 I Tubing I ·0 Test psi 1500 Casing -0 Initial 15 Min. 30 Min. 10 I 10 I 10 I Interval I I 1800 1785 1785 PIF P Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal RadioactNe Tracer Survey A= Temperature Anomaly SUM)' Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workowr D= Differential Temperature Test 0= Other (describe in notes) Test's Details While standing-by for a BOP test on H&R #9 I witnessed a MIT on IRU 14-31. The well has not been put on injection yet. This well passed this pre-injection MIT and should be "OK" to start injection but should be considered for another MIT once injection commences. M.I.T.'s performed: 1 Number of Failures: None Attachments: Wellbore schematic Total Time during tests: 2 hours ~ M IT report form 5/12100 l.G. MIT IRU 14-31 9-7-01 LG.xls 9/10/01 Ivan River Injectivity Test--Approval301-132 e e Subject: Ivan River Injectivity Test--ApprovaI301-132 From: Tom Maunder <tom _ maunder@admin.state.ak.us> Date: Fri, 25 May 2001 15:52:10 -0700 To: Dan Williamson <williamsond@orion.unocal.com> CC: Wendy Mahan <wendy_mahan@admin.state.ak.us> BCC: Cammy Oechsli <Cammy_Oechsli@admin.state.ak.us>, Julie Heusser <julie_heusser@admin.state.ak.us>, Daniel T Seamount JR <dan_seamount@admin.state.ak.us> Dan, We are in receipt of Unocal's application to conduct an injectivity test into the Ivan River Unit 14-31 (PTD 175-008). We understand that this test is planned to assess the suitability of converting this suspended well to a Class II disposal well to support your upcoming drilling and workover program. We concur with your reasons for proposing the injectivity test. By copy of this email you have approval to conduct the planned test, subject to the following conditions. In the absence of a Disposal Injection Order (DIO), subsurface placement of fluids may be approved provided the pumped fluid does not degrade the quality of the native fluids present in the receiving formation. We understand your potential water sources are source well water and water that has collected in the reserve pit at the well site. You may meet this requirement by testing either water for Total Dissolved Solids (TDS) and comparing that determined value with the formation water TDS derived from the available logs. If the pit water is used, it would be prudent to test for hydrocarbons and assure none are detectable using the standard test. No total volume to pump is specified in the sundry application, but you are approved to pump sufficient volume that prudent engineering requires to obtain the pressure information needed. Good luck. Please pass this approval to Don Andrews. Should there be any questions, please call. Tom Maunder, PE Petroleum Engineer AOGCC Tom Maundcr <tom maunder(àJadmin.state.ak.us> Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 1 4/5/20043:08 PM (e (e Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7677 RECEIVED \\·¡AY 1 -" 2001 UNOCALe ¡!.!aska OU & Gas Gens. Commission Anchorage Dan R. Williamson Drilling Manager Wednesday, May 16, 2001 AOGCC 333 West ¡th, Suite 100 Anchorage, AK 99501 APPLICATION FOR SUNDRY APPROVAL IVAN RIVER UNIT WELL 14-31, SEC. 1 T13N, R9W, S.M. Matanuska Borough, Alaska Unocal requests that the Commission approve an injection test on Ivan River well 14-31 in support of the pending Ivan River disposal injection order application. Ivan River 14- 31 is currently a suspended well. It's use as a disposal well is critical to the rig program planned for July 2001 and subsequent daily production operations. Q;t~ Dan R. Williamson Drilling Manager Attachments ORfGINAL e e hI, (sf" ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Alter casing: _ Repair well: Change approved program: Pull tubing: Operation shutdown: Plugging: _ Variance: 5. Type of well: Development: Exploratory: Stratigraphic: Service: x Re-enter suspended well: ~ Time extension: Stimulate: Perforate: Other: 6. Datum elevation (DF or KB) 2. Name of Operator Union Oil Company of California dba Unocal 3. Address P.O. Box 196247 Anchorage, AK 99519 4. Location of well at surface I.,¡./ 723' N, 757 W' SE Corner, Sec. 1, T13N, R9W SB&M At top of productive interval N/A At effective depth 1088' Nand 17 West of surface At total depth 46.4 feet 7. Unit or Property name Ivan River Unit 8. Well number 14-31 9. Permit number \ '\.s -00 ~ 10. API number .../ 50- 283-20045 11. Field/Pool 12. Present well condition summary Total depth: measured true ve rtical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 20' 421' 2037' 7018' 10,958' feet '1/ Plugs (measured) 10958'-10650',10350'-10100', 8,895' feel"'/ 9927'-7600',3508'·3350' 3325' feet Junk (measured) 2989' feet Size Cemented Measured depth True vertical depth 30' Yes 20' Yes 421' 421' 10-3/4' 1050 sx 2034' 1960' 7" 1189 sx 7018' 5829' Effective depth: measured true vertical measured 6882'-6862' (20') Cement squeeze 200 sx RECEIVED true vertical 5728'·5713' Tubing (size, grade, and measured depth) 2-7/8', N-80 Butt, 6.4 #Ift. at 2982' MD MAY 1 (' 2001 13. Attachments X Description summary of proposal: X Detailed operations program: ,tUaska Oií & Gas Cons. Commission Anchorage BOP sketch: Packers and SSSV (type and measured depth) Baker 3-H Packer at 2903' MD 14. Estimated date for commencing operation 5/21/01 16. If proposal well verbally approved: 15. Status of well classification as: Oil: Gas: Suspended: ~ Name of approver Date approved Service: Class II Disposal application pending 17. I hereb~ that t, ~1T~Oing is true and correct to the best of my knowledge. signed~M 1i ¿{~ Titie: ¡)"./!, '::!1 A JJ ~ JI', FOR COMMISSION U¡ ~~ fl Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance Mechanical Integrity Test_ Subsequent form required 10- 4 ~ t , . . ~-'>MÇ~ ~~~o...'\\~ o..~·"'r~.~ DateS --16 --() I APproval NO"~/J¡' /1;:2.. Approved by order of the Commissioner .iRr.G!NAL SiGNID ~ Ji. M. Heusser Commissioner Date (C.J.() / Form 10-403 Rev 06115/88 r¡f'....~r0~r( ,. 1-( . l _, " , I' h SUBMIT IN TRIPLICATE 0' 20' 0; ~... 20" 94# @ 4211 ~i;:~ TTC 0 1238' For 7" CSG. 10-314" 40.5# K-55 o 2037' 1050 SXS TIC @ 51' Based on Hole Size @ 13181 Based on Equalization Thru Float Shoe Stage Collar @ 4234' 689 SXS Annulus TTC Between 48451 and 4056' (CSL Not Conclusive) 7" 23, 26 & 29# N-80 @ 7018' 500 SXS 51/2" Liner @ 10,000' (a (..e Ivan River Field Well 14-31 ~' ~ ~ ~ ~ ~ I ~ . - ~ ~ ~ :-: .:". ... ::..:: ~ ~ ~ ~ ~ ~ ;:;; ~ 4 ~ . ~ \ 1 ,.. ~ I I ~ L-____I SPUD S/6flS sUSP 8/1 ens 2-7/8" 6.4# N-80 Butt Tubing ... Baker 3-H Packer at 2903' 'P Profile at 2948' (2.312 ID) Baker WL Reentry Guide at 2982' Cement Retainer at 3225' Cement Plug 3350' - 3508' 6862' - 6882' Sqz'd 200 SX " Fish #1 BHA Total Length 228' Probably on Bottom at 10,064' Fish #2 2206' of 27/8" D.P. -~ Top @ 7495' Bottom @ 9701' Fish #3 W.O. Assy & D.C.'s Length 380' Top @ 7345' Bottom @ 7725' Fish #4 2876' 2-2138 TBG & 3200' 31/2" D.P. Top @ 3510' Bottom @ 9586' Cement Plug 7600' - 9927' Cement Plug 10,100' - 10,350' Cement PI~,mlJr..J~ TD = 10,958' 05-01-01 ( . ¡ ( e ( . Attachment to Sundry Application: Ivan River well 14-31. An application is pending to convert suspended well Ivan River 14-31 to a Class II waste disposal well. An injection test is necessary to determine if the disposal zone will accept fluids, mud, and possibly slurried cuttings at anticipated pressures. The well recently passed a 1500 psi mechanical integrity test and the proposed injection test will verify and support the pending disposal injection order application. Well work and the test would proceed as follows: . Perforate the interval from 3180'- 3220' MD, or as deep as possible if there is fill on top fo the cement retainer at 3225' MD. . Inject pit water as follows: · Step rate sequence from Ÿ'2 BPM TO 6 BPM. · Record break down pressure if this occurs. · Shut well in and obtain pressure fall-off data for 3 hours or until pressure decline stabilizes. ~~_.~- ,=".~. · Unocal Corporation 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7685 Facsimile 263-7901 I UNOCALe F?~C~/V~D JUN 2 AlaskaOi/& 2200! Gasc Anchor;:'~' COtr¡tr¡¡~^. -= "'>'On Faye W. Sullivan Advising Environmental Scientist June 22, 2001 Ms. Wendy Mahan Alaska Oil and Gas Conservation Commission 333 West 7th, Suite 100 Anchorage, Alaska 99501 Dear Wendy: Application for Disposal Injection Order Request for Additional Information Ivan River Well 14-31, Section 1, T13N, R9W, S.M. Matanuska-Susitna Borough, Alaska As discussed in the meeting yesterday with Tim Brandenburg, Don Andrews, and Erik Graven, the following information is submitted in response to your questions concerning Unocal's application for a disposal injection order. (1) The disposal interval conflicts with top of plug in well. The log indicates good invasion between 3145'-3420' MD. We propose to perforate this whole interval if necessary. It is expected that perforations placed on top of the retainer at 3225' MD, or as deep as possible, will allow injected wastes to be pushed below the retainer, possibly to the base of the injection zone at 3420'. If necessary, a well workover could remove the retainer and cement plug currently inside the casing, thereby adding more direct access to the lower part of the interval. (Note: Unocal has requested that the injection zone include everything from a depth of 2962' MD to the unconformity at 3420' MD). (2) Why was a % mile radius around 14-31 requested, rather than the standard Y4 mile radius? If 14-31 fails, we would like to have the option to permit a new disposal well at the same location. It is likely that such a well would need to be located outside the ~ mile radius. (3) Why were some procedural pages included in Exhibit 8? Also, following the sundry notice some hand written notes dated 7/8/75 are included. What was actually done regarding construction on well 14-31? i:. Ms. Wendy Mahan June 22, 2001 Page 2 . I Exhibit 8 should consist of one page, which is the well schematic. Please discard any other pages. Exhibit 9 consists of the casing and cementing records on IRU 14-31. Exhibit 9 should include the following: Page 1 Well completion report 8/26/75 to AOGCC. Page 2 Sundry notice 9-22-86 to AOGCC. Page 3 Record of actual daily events describing cementing of the surface casing. Page 4 Original plan for cementing surface casing. This can be discarded since it duplicates page 3. Page 5 Record of actual daily events describing cementing of the 7 inch, long string. Pages 6-7 Plan to cement the 7 inch casing. This can be discarded since it duplicates page 5. (4) Well 13-31 has a DV leak. Please note there is a write-up on what occurred, and the final leak status, at the start of Section (c) 12. (5) Summarize what was disposed of down surface casing annuli and the problems that occurred. See the attached letter for details of annular disposal on the Ivan River pad. Injected wastes were exempt drilling rig fluids, mud, and cuttings from the three Ivan River wells drilled in 1992. These wastes were pumped down the annuli after being stored in a pit for several months. (Wells drilled were 13-31,41-1,44-36). Problems occurred on two of the three wells during annular injection. As the attachment shows, after 11,686 barrels were injected through 44-36, the annulus plugged and pressured up to 3900 psi. The problem that occurred on 13-31 is summarized at the start of section (c)12. Please let me know if you need any additional information. Thank you for your assistance. Sincerely, J~ -W~ Faye W. Sullivan Enclosure cc: Tim Brandenburg, Don Andrews .··...'r--·'~··· RECEiVED JUN 2 2 2001 Alaska Oil & Gas C Anchor: CommisSion ( . , . Unocol Nonh _an I 'a. Divl.1on Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCALe May 14, 1993 Environmental Affairs Alaska Region ., CERTIFIED MAIL RETURN RECEIPT REQUESTED State of Alaska Department of Environmental Conservation South central Regional Office 3601 C Street, Suite 1350 Anchorage, AK 99503 State of Alaska Department of Environmental Conservation Mat-Su District Office P. O. Box 871064 Wasilla, AK 99687 IVAN RIVER PAD #44-1, ANNULAR INJECTION WELLS WASTEWATER DISPOSAL PERMIT NO. 9240-DB002-2B FINAL REPORT OF DISPOSAL In accordance with Condition IV. B. of General Permit 9240-DB002, attached is a summary of annular pumping operations of drilling muds, cuttings and fluids from Unocal's recent developmental drilling program at Ivan River. Be advised that Unocal has now completed disposal of wastes into the annuli of wells on Ivan River Pad #44-1, therefore, this report is considered final. Please contact me at 263- 7685 if you have any questions or require any additional information. Thank you for your assistance with this project. Very truly yours, 4 ;' \; /1 II. I -Ýcáf- lAJ~;~V£Z--t- --"....,.-..... Faye W. Sullivan Environmental Coordinator Enclosure cc: John Beitia George Buck · I UNOCAL SUMMARY OF ANNULAR PUMPING OPERATIONS IVAN RIVER WELL #13-31 Daily Slurry Daily Average Daily Average Cumulative Injected Daily Flush Injection Pressure Barrels per Minute Injected Date (bbls) (bbls) ~ Processed (bbls) 11/20/92 1440 0 2675 2.5 1 ,440 11/21/92 1440 0_ 2675 2.5 2,880 11/22/92 1440 0 2675 2.5 4,320 11/23/92 1440 0 2675 2.5 5,760 11/24/92 1440 200 2675 2.5 7,400 IV AN RIVER WELL #41 -1 Daily Slurry Daily Average Daily Average Cumulative Injected Daily Flush Injection Pressure Barrels per Minute Injected Date (bbls) (bbls) ~ Processed (bbls) 02/09/93 1591 585 2675 2.55 2,176 02/10/93 850 100 2350 2.44 3,126 02/11/93 0 0 0 3,126 02/12/93 0 0 0 3,126 02/13/93 1407 100 2150 1.77 4,633 02/14/93 1588 100 2150 2.1 6,321 02/15/93 0 0 0 6,321 02/16/93 1855 0 2600 8,176 02/17/93 580 200 2500 8,956 02/18/93 0 0 0 8,956 02/19/93 0 0 0 8,956 02/20/93 405 0 2900 2.82 9,361 02/21 /93 1790 105 3000 2.67 11 ,256 02/22/93 0 0 0 11 ,256 02/23/93 950 200 2900 2.01 12,406 02/24/93 1100 205 2900 3.1 13,711 02/25/93 0 0 0 13,711 02/26/93 1010 205 2700 2.97 14,926 02/27/93 0 0 0 14,926 02/28/93 0 0 0 14,926 03/01/93 0 0 0 14,926 03/02/93 2135 200 2500 2.6 17,261 03/03/93 0 0 0 17,261 03/04/93 0 0 0 17,261 03/05/93 1717 200 2450 2.34 19,178 · , , UNOCAL SUMMARY OF ANNULAR PUMPING OPERATIONS IVAN RIVER WELL #44-36 Daily Slurry Daily Average Daily Average Cumulative Injected Daily Flush Injection Pressure Barrels per Minute Injected Date (bbls) (bbls) ~ Processed (bbls) 03/13/93 600 697 2150 2.2 1,297 03/14/93 0 0 0 1,297 03/15/93 2727 126 2200 2.1 4,150 03/16/93 0 0 0 4,150 03/17/93 0 0 0 4,150 03/18/93 1554 136 2300 2.86 5,840 03/19/93 0 0 0 5,840 03/20/93 0 0 0 5,840 03/21/93 1875 117 2547 3.29 7,832 03/22/93 0 0 0 7,832 03/23/93 0 0 0 7,832 03/24/93 1970 195 2518 2.99 9,997 03/25/93 782 120 2741 2.89 10,899 03/26/93 0 0 0 10,899 03/27/93 567 125 2621 2.5 11,591 03/28/93 95 0 3900 1.6 11,686 TOTAL VOLUMES INJECTED 38,264 . . . . Attachment 4 IR 14-31 Injection Test Results During discussions relating to the pending Ivan River disposal injection order, AOGCC staff requested that a step rate test and pressure fall-offbe done on well 14-31. Accordingly, attached are pressure-rate graphs for the two step-rate tests that were performed on June 8th and June 9th. (Tabular data can be provided if desired). The attached log shows the interval from 3189-3209 that was perforated, 12 shots per foot. It also shows that the tighter 20 foot thick interval that was shot, is bounded both on the top and bottom by 30 foot thick intervals of more porous rock. Injection Results: Attached is a plot of rate versus pressure resulting from the two tests. The plot shows that two fractures were generated on the first day. This is interpreted to mean that the lower porous interval was most probably perpetrated since the perforations are in the top of that interval. The second injection shows that the earlier fractures were reopened and the same flow system re-established. The pressure falloff data indicates that a good leak- off coefficient exists since the pressure declined to almost zero in a matte! of minutes. Annular Pressures: The following annuli were monitored for any pressure response resulting from the injection. Wells 13-31 and 44-36 are the two wells closest to 14-31. · No pressure in 14-31 inner annulus (tubing by 7 inch casing ). · No pressure in 14-31 surface casing annulus (7 by 10 % casing). · No pressure in 13-31 surface casing. · No pressure in 44-36 surface casing. , . ,~ ,~ ¡ '.,~ 1 ~;l 4~ '~ ~ì~' ,..~ ~. . ....1 ~.:.. "." - '. : ,". >. ':;'< . '. . - ;' _._,,_ " . ..... i . ....,~:.:.~,'..,. :.,.....,."...,.,...., . :""., ..;.;;,..;' ··1 :~,i·:::~i.:f~.:·\?::ki:(~;::;:.,,·~ ' _.,)~, ::r -~;~j: ¡~ ~?~ i~ ¡~~: ~¡it eh... ot{,!"! ~¡~1 Uir~';,¡" ~it: -I~ ~1~ ~~ -g¡j~ -51~~ .-!~ Elfi¡ ~¡~ II &~ ~l~ ~ f _I,. .g'1 ~~ fl:~ CÞ -, 't~ :~., ~t~F" o~ ~R 6~ .2~ ëj1J:.: OJi~: -i~~ aì !;!.¡- e1!,,, CI'~ , r::f.I~ ;~ ~f,:~'·:,..,:.' ~t i .....¡¡ : j: t· . r .:~ ~ I}: 'j; W!~: ~;1~~ 0' . ....:, . ~¡ : ¡'~Ri I : f ;: JJ '··'7~~~~~~,."~~:~'~..,~:~:::~~~·;rt~~~:?~~:.~:;;~1Ä1~1~~~'1fr.W1~:~;J;:0:f~f~~~~1f:t10t;:~~~r:-~~::~ . ."':'.' ....:..-.... z ~..o 0- Þ- ::Þ 9 g< .::1 Ow w u ¡¡:-...a ~ Permanent Datum: Log, Measured From Drilling Measured From Date Run No. Depth-':Driller Depth-Logger 8tm. Log Interval Top Log Interval Casing-Driller Casing-logger Bit Size Type Fluid in Hole Fluid Level Dens. I Vise. pH I Fluid Los Source of Sample Rm @ Meas: Temp. ,. Rmf@Meal.Temp. ; ~"'.:,~,:;.. ìe::; I Rm @ 8HT 'I:' Time Since Cire. Max. Ree. 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I I J J' t : ! ~ . 3100 3000 2900 2800 - 2700 _ 2600 II) oS: 2500 Q) 5 2400 II) ~ 2300 .. ~ 2200 c :c 21 00 :s ~ 2000 1900 1800 1700 1600 1500 0.0 IVAN RIVER 14-31 INJECTION TEST ~ ,/ . .' .' ....... ...... ....... , ........ .... þ. ...... .' .... ... II ...... ..... .... .. .... ...... ..,.... ...... - .... ...... ,..... .+ ..."... .... ...... ... .'II.. .+ .... ...... .- ._~1 .... ,,+ ..... ... .... .. .... ..- ..... .... .' .' " .' .... .' ... ..' . 6/8/01 . 6/9/01 . , I , 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 4.5 5.0 Injection Rate (BPM) .' .., 5.5 f . . . . , IVAN RIVER 14-31 INJECTION TEST 6/8/01 Step Rate Test #1 6/9/01 Step Rate Test #2 Tbg. Press. BPM Psi 0.5 2200 1 .13 2500 2.1 2800 2.9 2875 3.9 3000 3.9 2680 (Fmn. Broke) 5.0 2870 4.6 2830 BPM 0.3 1.0 2.0 3.1 4.18 5.1 Tbg. Press. Psi 1650 1980 2225 2480 2665 2890 "-~--~'-'-'--""----~_.--"---._--~-_.- , . ÐÞ~!~ Well Field Country Time 06108I01 20:00:40 20:01:30 _ 20:15:00 _ 20:28:30 - 20:42:00 _ 20:55:30 _ ..' . 1\ VI tv" 2: ~- 21:09:00 - -Ÿ 21:22:30 _ 21 :36:00 - 21 :49:30 _ : 22:03:00 _ ~ ¡.; ¡.; N hh:mm:ss 8 ¡¡s 06108I01 22:10:09 ~ . Mart< of Schlumberger i.JO-\f;fB.; ~ t IVAN RIVER 14-31 IVAN RIVER USA I' - CumVoI I. I: I. i: I: i: i: I: I: bbl . Cementing Job Report , 1 : ~ : ! "'t ¡ · ¡ I: , : . : i' · ( : : 1 : : I : i: : j: , ¡ , : i· : I: ; ¡ ; ; i ~ ; i: : i, · 1 ' : ! : · : . · : . ·r· " r,. : ! : : ¡ . ~ ! ~ : ¡ . I a I I"' . I " 350 0 psi Client UNOCAL . SIR No. Job Date 6/8/20018:00:40 PM Pressure UI ¡ , ¡ ì: ! I:! 1· . I: ¡ . ì " ' I \1. : Ii: :0j¡: i\ (:1: :! I,: . : I .: . l1'i . i : I : J. . i : . ,¡ : : ¡ I: : ¡ ~i ..: (: i ~ .: ::=. ' -. !: ", \ : y . ¡ . , j' I: ! \',; I j': i ¡ . j . ¡ , i '~ i i ~ : ¡ ~ : i ' , i \. : : 1· : I) : : :,~'" ¡ " .. .' " . , : ¡ , : . , . i : ¡ - TotFIowrattI ~ I: . ~N ~ " 11 I I I I I J' I I . . I . J I 3500 0 bpm 6 PRlSM* V2.23 Mesoages -sTART ACQUISITION "Pressure Test Lines "Bleed Off Pressure -¡CumVoI)=.3534 bbl _Volume Start Pumping Water ·I~ PumpRalø -sTOP ACQUISITION . _.u______"__________ . ~. Well Field Country Time 0610910110:11:53 W¡QQ:£O 10:15:00 _ 10:30:00 -. : 10:45:00 _ 11:00:00- 11:15:00 - 11:30:00 _ 11:45:00 _ 12:00:00 _ c: ~ g " .ö o ..., 12:15:00 _ ~ ti ö o ~ iò o hh:mm:ss 0 06109101 12:22:08 . Mark å Schlumberger [~!'»\Nt~~£f IVAN RIVER 14-31 IVAN RIVER USA CumVol bbl . ¡ I ! i I ! ! ! ! j i i .H r: i 400 Cementing Job Report . Client UNOCAL SIR No. Job Date 6/9/2001 10:11 :53 AM Pressure UI ; - ; , i ---1 -..,.. : i ! i ~ ¡ : ¡ . ¡ : ! : 1 : ¡ ! ~ :, ~ , : i ...... I ~: ! Ii -. ! ~i ~' :~ :¡: .- :~ : I: _. , " .. o psi 3500 o TotFlowrete ; ¡ - : ¡ I j , ¡ ¡ : ¡ ~ !: ; - I' i ~i :~ : , , , i i ; i . I ; 1 : ! : I :, . . : ' ~ ¡ : ¡ ~ : j ¡ ¡ ~ ¡ i'" I' bpm PRISM* V2.23 Messages ·START ACQUISITION "Increase Pump Rate "User defined message "User defined message ·Shutdown 6 ~A- . . ALASKA OIL AND GAS CONSERVATION COMMISSION Date: 6/2-1' 0 , Time 10 Þ.M MEETING - Subiect- !\fAN ~Vf..Ø- D}O, Aé.-Õ ~\)68T~ NAME - AFFILIATION (pLEASE PRINT) WI t-:)frj MA ~ "",.,j $kb<-- :DÆVI¿~ ])é) ~ 41 ~ ¿J_~.-'-;7 -- 'E~t::- &w,I/éJj )~ 6~/!!j~_ ~ ~é 1+~4:: J a k ¿t fA.)ýllit~~ TELEPHONE /fo~ LL U ¡1J ()C kL t.åJOcA l- t1.. JJ OC-M Acqcc_ 4.. 0('.. (J / '1~~ - J 2..36 7P3 - /zz-ý :103 707h '2 ¿,:S 7S.<' "1 2<;3- 9G~ '1'73 - (2.-3z- "'$ VS--7'7 y :#'3 ,. . . UNOCALe 1Ói( J1A.cu¡~ ~1_'l Dan R. Williamson Drilling Manager RECEIVED JUN 1 5 Z001 Alaska Oil & Gas Cons. Commission Anchorage Wednesday, AOGCC 333 West 7th, Suite 100 Anchorage, Alaska 99501 Report of Sundry Well Operations Ivan River Unit Well 14-31 Sec. 1 T13N, R9W, S.M. Matanuska Borough, Alaska The sundry notice and associated attachments reports results obtained from perforating and performing a step rate injection test on IR 14-31. The following is included: 1. Sundry Report 2. Test procedure 3. Reserve Pit Water Analysis 4. Results from Injection Test Including: Pressure/rate Data Log Showing Perforated Interval Injectivity Plot This test is submitted, as directed, in support of the pending Ivan River disposal injection order application. c (~ \.~ 'c- ,~¿¡1~/f f2 fl--IO· ,~/ d fo3 - 7 Io~ 7 t}~'ì1à 0 t ~'d?J~ Dan R. Williamson Drilling Manager RECEIVED JUN 1 5 2001 Alaska Oil & Gas Cons. COIlJmissiOIL ~r@!' . DUPLICATE ... . STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Pull tubing: Stimulate: Alter casing: . Plugging: Repair wëii: 5. Type of Well: Development: Exploratory: Stratigraphic: Service: x Perforate: x Other: Injection Test 6. Datum elevation (DF or KB) 46 7. Unit or Property name feet 2. Name of Operator Union Oil Company of California dba Unocal 3. Address P. O. Box 196247, Anchorage, AK 99519 4. Location of well at surface 723' N, 757' SE Comer, Sec. 1, T13N, R9W, SB&M At top of productive interval N/A At effective depth 1088' Nand 17 W of surface At total depth Ivan River Unit 8. Well number 14-31 9. ?1i;U~~1 number~ 10. API number 50-283-20045 11. Field/Pool 12. Present well condition summary Total depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 20' 421' 2037' 7018' 10,958' feet Plugs (measured) 10958'-10650',10350'-10100', 8,895' feet 9927'-7600',3508'-3350' 3325' feet Junk (measured) 2989' feet Size Cemented Measured depth True vertical depth 30" Yes 20" Yes 421' 421' 10-3/4" 1050 sx 2034' 1960' 7" 1189 sx 7018' 5829' Effective depth: measured true vertical measured 3189'-3209' (12 shots per foot) RECEIVED true vertical 2886'-2901' Tubing (size, grade, and measured depth) 2-7/8", N-80 Butt, 6.4 #/ft. at 2982' MD JUN 1 5' 2001 Packers and SSSV (type and measured dept~) Baker 3-H Packer at 2903' MD Alaska Oil & Gas Cons. Commission Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) 3189'-3209' Treatment description including volumes used and final pressure Step Rate Injection Test (704 bbls water) 14. Representative Dailv Averaae Production or Injection Data Oil-BBL Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation (See attached) Subsequent to operation 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: x Oil: Gas: Suspended: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Service: x S~"OO~~ Form 10-404 Rev 06/15/88 Till, ~I~' Mt¡r. DUPLICATE Date: C ../3 ~é')t SUBMIT IN DUPLICATE . . Attachment 2 IR 14-31 Injection Test Procedure (As Performed 6/8/01 and 6/9/01) Day 1 (6/8/01) : · RIH with GR/CCL and 20 feet of perforating gun to TD at 3209 MD. · Logged up to 2710 feet and correlated with Dual-Laterolog dated 6/29/75. · Went back to TD. Shot interval from 3189-3209 on 6/29/75 log. · Repeated perforating run with second 20-foot gun and re-shot same interval as first gun run (Final density is 12 shots per foot). · Partially rigged down Schlumberger but did not remove BOP. · Charged system with Dowell pump and prepared Îor injection test. · Verified pressure, rate, computer recording system and conducted test as follows: Approx. Rate Approx. Length (BPM) (Minutes) ~ 15 1 15 2 15 3 15 4 15 5 15 (pump max' d out at + 5 BPM) · Pumped 324 barrels of pit water. · Shut in well and recorded pressure fall-off. Day 2 (6/9/01) : · Repeated injection test as above. · Pumped 380 barrels of pit water. · Shut well in and recorded pressure fall-off. · Secured well and moved off location. . . . Attachment 3 Ivan River Pit Water Analysis (Sample Date 5/21/01 ) Attached are results of the water sample taken on May 21, 2001. Hydrocarbons: Benzene Ethylbenzene Toluene Xylenes, Total Lead: Chloride Flouride Sulfate Total Nitrate and Nitrite Calcium Magnesium Potasium Sodium Non-detectable Non-detectable Non-detectable Non-detectable Non-detectable 22.5 mgll Non-detectable Non-detectable 0.100 mg/l 8.7 mg/l 1.5 mg/l 4.3 mg/l 22 mg/l ~ . . Analytica Alaska IncoIporated website: www.analyticagroup.com ANALYTICA ALASKA INC. 811 W. 8th Avenue, Anchorage", AK 99501 · (907) 258-2155· FAX (907) 258-6634 Unocal Oil and Gas PO Box 196247 Anchorage, AK 99519 Attn: Don Andrews Work Order #: AOI05088 Date: 5/25/01 Work ID: Ivan River Reserve Pits Date Received: 5/24/01 Sample Identification Lab Sample Number AOI05088-01 Client Description Ivan River Lab Sample Number Client Description Enclosed are the analytical results for the submitted sample(s). Please review the CASE NARRATIVE for a discussion of any data and/or quality control issues. Listings of data qualifiers, analytical codes, key dates, and QC relationships are provided at the end of the report. Sincerely, Jason Gray Project Manager .~ @ Printed on Recycled Paper t . . t- Case Narrative Work Order: AOJ05088 ADEC Laboratory Approval Number: UST-OI4 The samples was received in a IL polyethylene bottle at 5.6°C and was refrigerated upon receipt. Sample was subsampled into a 40ml VOC by the laboratory . QUALITY CONTROL All applicable ADEC methodology requirement were followed and all quality control objectives were met for this project. Analyst ~ \.) J.:U../ cf~1 Date . 'A ANALYTICA . Cooler Receipt Form . Client: Project: Unocal Oil and Gas Ivan River Reserve Pits Client Code: 008676 Order #: A0105088 Cooler 10: 1 A. Preliminarv Examination Phase: Date cooler opened: Cooler opened by: 5/24/01 BO 1. Was airbill Attached? Ves 2. Custody Seals? 3. Seals intact? N/A N/A Airbill #: 294037 How many? 0 Location: Carrier Name: Seal Name: 4. Screened for radiation? No 5. cac Attached? Ves Properly Completed? 6. Project Identification from custody paper: Ivan River 7. Preservative: BlueGel Temperature: Yes Signed by AEL employee? Ves . Designated person initial here to acknowledge receipt: Comments: I' .1. Date: tÞ ðM.o\ I Client contacted to advise of vials not filled as instructed. Laboratory de ted 40ml. of water from 1 L. poly bottle into 40ml.vial as per method requirements. Laboratory to proceed wit rEX 8021b analysis per DA. B. Loa-In Phase: Samples Log-in Date: 1. Packing Type: Bubblewrap 2. Were samples in separate bags? Yes· 3. Were containers intact? Yes 5/24/01 Log-in By: BO 4. Number of bottles received: 4 5. Correct containers used? No 6. Sufficient sample volume? Yes 7. Bubbles in VOA samples? No 8. Was Project manager called and status discussed? No 9. Was anyone called? Yes Who was called? Comments: Don Andrews contacted regarding above discrepancy. Labels agree with CaC? Ves Number of samples received: 1 Correct preservatives added? No . By whom? Date: Page 1 of . . . Detailed Analytical Report Project: Client: Client Project Number: Analytica Alaska Inc. Workorder (SDG): A0105088 Ivan River Reserve Pits Unoeal Oil and Gas Unocal Corporation Report Section: Client Sample Report Client Sample Name: Ivan River ~ Collection Date: 5/23/01 Lab Sample Number: AO 1 05088-0 1A Prep Date: 5/21/01 Matrix: Aqueous Analysis Date: 5/251'()1 11:26:00AM . Analytical Method ID: BTX by Method 8021B Instrument: Natasha Prep Method ID: 5030 File Name: NI052507.D Dilution Factor: 1 Prep Batch Number: AOI0521007 RR#: 1 Analyte CASNo Result Flags Units PQL MDL Spike % Reeov LCL UCL Analyte Results: Benzene 71-43-2 ND ug/L 1.0 0.25 Ethylbenzene 100-41-4 ND ug/L 1.0 0.27 Toluene 108-88-3 ND Ug/L 1.0 0.26 Xylenes, Total 1330-20-7 ND ug/L 3.2 1.1 Surrogate Results: Bromofluorobenzene(pID) 1072-85-1 70 ug/L 1.0 0.10 100 70.1 60 120 Difluorobenzene(PID ) 540-36-3 50 Ug/L 1.0 0.10 50 99.2 60 120 Page 3 on .. . . Detailed Analytical Report Analytica Alaska Inc. Workorder (SDG): AOI05088 Project: Client: Client Project Number: Ivan River Reserve Pits Unocal Oil and Gas Unocal Corporation Report Section: Method Blank Report Client Sample Name: 1MB ~ Collection Date: 5/21/01 Lab Sample Number: AOI0521007-MB Prep Date: 5/21/01 Matrix: Aqueous Analysis Date: 5/24/01 1:14:00PM Analytical Method ID: BTX by Method 8021B Instrument: Natasha Prep Method ID: 5030 File Name: NI052414.D Dilution Factor: 1 Prep Batch Number: AOI0521007 RR#: 1 Analyte CASNo Result Fla2s Units PQL MDL Spike % Recov LCL UCL Analyte Results: Benzene 71-43-2 ND ug/L 1.0 0.25 Ethylbenzene 100-41-4 ND ug/L 1.0 0.27 Toluene 108-88-3 ND ug/L 1.0 0.26 Xylenes, Total 1330-20-7 ND ug/L 3.2 1.1 Surrogate Results: Bromofluorobenzene(PID) 1072-85-1 70 ug/L 1.0 0.10 100 70.3 60 120 Difluorobenzene(PID) 540-36-3 49 ug/L 1.0 0.10 50 99.0 60 120 Page 4 of7 · . Detailed Analytical Report Analytica Alaska Inc. W orkorder (SDG): AO I 05088 QC Recovery Report Work Order:AOI05088 Prep Batch Number: A010521007 Base Sample AOI0521007-MB Anal. Method: BTX by Method 8021B Spike Sample AOI0521007-LCS Sample Prep Date: 5/21/01 12:00:00AM Spike Duplicate: AOl 0521 007-LCSD Analysis Units: ug/L LCS/LCSD Report Matrix: Aqueous Analyte Base Samp. Spike Sp. Dup Spike Spike Sp. Dup SpikeD RPD LCL DCL RPD Reeov. RPD Result Result Result Cone Reeov Cone. Reeov Lim. Flag Flag Analytes Benzene ND 15 14 14 105.5 14 103.7 1.7 60 120 20 Toluene ND 80 !SU 85 94.1 85 94.4 0.3 óU 120 20 Ethylbenzene ND 20 2U 20 99.7 20 100.3 0.6 óU 120 20 Xylenes, Total ND 92 92 99 92.6 99 93.1 0.5 óU 120 20 Surrogates: Difluorobenzene(pID) 49 51 51 50 102.8 50 102.0 0.8 60 120 20 Hromotluorobenzene(P lU) 70 72 73 100 72.3 100 72.6 0.4 óU '120 20 Page 5 of7 . . . Detailed Analytical Report Analytica Alaska Inc. Workorder (SDG): A0105088 QC BATCH ASSOCIATIONS - BY METHOD BLANK Lab Project ID: 3,524 Lab Project Number: AOI05088 Test: BTX by Method 8021B Prep Date: 5/21/01 ' Lab Method Blank Id: A010521007-MB Prep Batch ID: A010521007 Method: BTX by Method 8021B This Method blank and sample preparation batch are associated with the following samples, spikes, and duplicates: SampleNum ClientSampleName DataFile AnalysisDate A010521007-LCS LCS N1052415.D 5/24/01 1:43:00PM A010521007-LCSD LCSD N1052416.D 5/24/01 2:1l:00PM A0105088-01A Ivan River N1052507.D 5/25/01 11:26:00AM Page 6 of7 . . . Detailed Analytical Report Analytica Alaska Inc. Workorder (SDG): AOl05088 DATA FLAGS AND DEFINITIONS Result Field: ND = Not Detected at or above the Reporting Limit Shown NA = Analyte not applicable (see Case Narrative for discussion) Qualifier Fields: LOW = Recovery is below Low Control Limit HIGH = Recovery, RPD, or other parameter is above Upper Control Limit E = Reported concentration is above the instrument calibration upper range DIL = Sample required dilution to bring analytes within calibration range of the instrument. At the dilution level required, the surrogate could not be quantified due to the resulting low surrogate concentration and/or coelution interference from the sample. Organic Analysis Flags: B = Analyte was detected in the laboratory method blank Inorganic Analysis Flags: B = Analyte was detected above the MDL or IDL but below the Reporting Limit W = Post digestion spike did not meet criteria S = Reported value determined by the Method of Standard Additions (MSA) Page 7 of7 ~A.V.-31-:Z00 1 ~ - 03:07 PM __.AN.TICA AK SE 90.80 6670 p.e1 Analytlca Alaaka Southelat 5438 Sh8une Drive Juneau, AK 99801 (907) 780-8668 FIx (907) 780-e070 5/31/01 Unocal Oil and Gas PO Box 196247 Anchorage, AK 99S19 Ann: Don Anclrcws Work Ordcr #: JOI0'058 Date: 5/31/01 Work m: Ivan River Reserve Pits Date Received: $124/01 Sample Identification Lab Sample Number J01050$8-01 Client Description Ivan River Lab Sample Number Client Oeecrlptlon Enclosed ere the analytical results for the Bubmltted .ample(a). PleaBe review the CASE NARRATIVE for a discussion of any dete end/or quality controll.sues. Listings of date qualifiers, an,lytical codes, key detes, end QC relationships are provided 8t the end of the report. Sk\cerely, 'I \J(~¿þr '-.erðJect Manager -~~ "The Science of Ana/ysls, The Aft of Service- IIH 1.-6~-..::t"'''J. 1:::16 :1:::11:1 t-'M AN.. .LL;A AI'\. ~t:. Detailed Analytical Report . Workorder (8DO): Project: Client: Client Project Number: Report Section; Client Simple N.me: Matrix: Lab Sample Number: Prep Date: Analytical Method ID: . Pre., Method ID: Prep Bateh Number: Report Basis: AD.lyee Chlorid~ fluoride Sulfate TOlal Nitnlle A. Nitrile .. N Lab Sample Number: Prep Date: Analytical Method ID: Prçp Method ID: Prep Balch Number: Repon Basis: ADalyte Lead Page 3 of7 JOI05058 Ivan River Relerve Pit. Unoell 011 and Ga. Unoe.1 Corporation Client Sample Report Ilvan Klver AqucoUI . JUIU.5U5".UIA S/2S/0t Jnðrsanlc Anion. by Ion Chromatography 300.0 1010.530004 A, Reçeived ~ Keltllt Flap Unitt W- maIL ND maIL I'm m¡/L 0.100 J møIL JOI050S8-01B 's/29/01 239.2. Lead by QFAA . Total 3020 JOI0530009 As Received ~ 7439-92-1 Fllg, Unitt uWL ~ ND ';: I:::I.I:II:::J bb(.1:::J Analytica Alaska Southeast PQL 1.0 0.10 2.0 0.10 lnection Date: Analyeis Date: Imtrumcnt: File Name: Dilution Factor: Analyst Initials: MDL 0.0'8 0.OJ2 0.1.1 0.019 Analysis Date: InllrurneJ1t: File Name: Dilution Factor: Analyst Initials: N!! MDL . 1.0 0.16 P.Ø3 5/23/01 3:44:00PM 5/25/01 I :28:S8PM IC 1 JO Rerun ,: I 5/29/01 1l:52:.50AM GFM_l 1 sw RerUD tJ: 1 MAY.31-2001 03:09 PM AHWTICA At< SE 90-.e0 6670 P.04 Detailed Analytical Report Analytic. Al.ska Southeast VVorkorder (5))0): JOI05058 Project: IVln River Rete.."e Pitt Client: Vooe.' OU and G.. Cttent Project Number: Uooes. Corpor.t'oo Report Section: Method Blank Report CUent Sample Name: . 1MB . Matrix: Aqucou. ~Uecdon Date: 5129f01 12:00:00AM lab Sample Number: Prep Date: Aualytical Method ID: Prep M(:tbod ID: Prep Batch Number: Report Basil: ~.~te Leod JbTb!.w\JoAtI 5/29/01 239.2. Lead by OPAA . Tot.1 3020 '01 OS 30009 D¡y Wc:ight Bui, CASNo !!!!!!! 7439·92·1 ND AnalYli. Date: Instrument: File Name: DiJution Factor: 5/29/01 11 :S2:S0AM OFAA_l 1 FlaK' Unlb u¡lt. Analyst Initials: PQL MPL 1.0 0.16 sw Re~~ ø: I Page 4 of7 ( . MA·(.-31-21313 1 133: 139 PM 90.813 66713 A"YTICA AK SE P.135 Detailed Analytical Report Analytic. Al..ka Soutbea.t Workorder (SDO): 10105058 Project: Ivan River Relene Plte Client: Unocal 011 and Ga. Client Project Number: Unoel. Corporation QC Recovery Report Work Ord,r:J0105058 Prep Batcb Number: JOt 0530009 Hase Sample J0105050-04C QC Sample JOI050S0-04C.MS SampleAnalytfs Date: QC: Rample A ...1~¡a Oale: Analytc Lead Base Sample QC Sample QC Dup1icate: !lamplcAnalytll Dale: QC: Rampl" ^...I~¡. Dale' Analyte Lead 5/29/01 1 I :52:S0AM 5129101 11:52:50AM Simp. Spike Relult RiI.. 4.99 28.2 Anal. Metftoct ¡''''I.I. - ....o.d by ul"^^ - 10lal Sample Prep Date: 5/29/0 I 12:00:00AM Analysis Units: uatI. Matrix: AqueoulI Q(: PUl'SIImpJe AnIIlyaÏI Dale: Spila: RccoY LCL UCL RJ'D RccP1 Conc: 25.0 93 " 12' JOI0S30009-MB Anal. Method: 239.2 - Lead by OFAA - Total J0105JOOO9·LCS Sample Prep Date: OS/29/01 12:00:00AM JOI05JOOO9-LC:SD Analysis Units: ugII.. 5/29/01 I I :S2:S0AM Matrix: AqueoulI '129/01 II :'Z:'OAM QC ourSanlple An.I,... Date: S/29101 II :52:50AM 5&1111. Spike SI' Dup Spike Recov Spi1ceDup SPDUP.R. leI. vet. RJ'D RPDPI Rcc FI Retull Ra. Re. Conc: Cone Be ND z(\., 26.7 25.0 106 25.0 107 8S I IS 0.86 FOOTNOTES TO QC REPORT Note 1: Results are shown to three significant figures to avoid rounding elTor. in calculations. Note 2: I(the sample concentration is greater than" times the spike level, a recovery is not calculated, and the result should be used as a replicate. In such cases the spike ia not as high as expected random measurement variability ofthc sample result itself. Note 3: For sample duplicates, ¡fthe result is IC$5 than the PQL, tÞe duplicate RPD Is not applicable and is shown as O. If the sample iUJd duplicate results are not five times the PQt or greater, then the .kPD is not expected to fan within the window shown and the comparison should be made on the basis of the absolute difference. Analytica uses the criterion that the absolute difference should be less than the PQL for water or less than 2XPQL for other matrices. Page S of7 MA~~31-2aal ~3:1a PM ) ANWTICA AK SE -"IðWB.., 66('" 1-'...,6 Detailed Analytical Report - Workorder (SDG): 10105058 ProJCl:t: Ivan River Re.erve Pits Client: Unoea. 011 and Gal Client Project Number: Vnoe.. Corporation QC BATCH ASSOCIATIONS. BY METHOD BLANK Analytica Alaa1ca Southcut L.b Project 10: 3,579 Lab ProJect Number: J0105058 Test: 239.2 . Lead by ütAA .' 1'0181 Prop Date: $/29/01 Lab Method Blank Id: JOIOS30009-MB Prep Batch ID: JOIOS30009 Method: 239.2 . Lead by OFAA - Total This Method blank and sample preparation batch are associated with the following samples, spikes. and duplicatcs: SampleNum CJientSampleName DataFile ADa1yafsD!t~~ JO I OSOSo-04C Batch QC 5/29/01 11 :S2:S0AM JOIOS058·0lB Ivan River 5/29101 11:~2:S0AM JOIOS30009·LCS LCS 5/29/01 1l:52:50AM JOIOS30009-LCSD LCSD 5/29/01 U:52:S0AM J0105050-04C-MS MS .5/29/01 11:S2:S0AM Page 6 of' (, . I·IHT..~':>~-¿OOOO~ OO.:>;~~....... HN.T I ~~H Hr<.. :::>t:. '='10 .1:110 bb (-10 Detailed Analytical Report - Worlcorder (SDO): J0105058 ProJett: IVln RIver Hellrv. Pit. Client: Unoeal 011 and GI. Clleot Project Number: Uooell Corporltloo Analytica Alaska Southeast DATA FLAGS AND DEFINITIONS Result Field: ND - Not Detected at or above the R.cporting Limit Shown NA = Analytc not applicable (8ee Caeo Nanadve tor dilcullion) Qualifier Fields: LOW - Recovery i. below Low Control Limit HIGH = Recovery, RPD, or other parameter i. above Uwer Control Limit E = Reported concentT.tion is above the jnstrument calibration upper range . OIL'" Sample required dilution to bring analytes within calibration range of'thc inst'r\lrnent. At the dilution level required, tbe surrogate could nOI be quantified due to the resulting low surrogate concentration and/or co.lution interference from the sample. Organic Analysis Flags: B .. Analyte was detected in the taboratory method blank J = AnaJyte Wa$ detected above 2 x MOL but below the Reporting LimU (Quant Lindt) Inorganic Analysis Flags: B = Analyte was detected above the MDL or IDL but below the Reporting Limit W = Post digestion spike did nor meet criteria ,S '" Reponed value detcnnined by the Method of Standard AddItions (MSA) \2,Q, POì::hN.j L t M. ~T . I, D.eT~\10N LIM tr PCP'L- 'PAoc.1ÌW M DL - Me11ï<>cL ~SuLTS - A ~~~ COM pDti",d 'lõ Sho vJ 'iT ,Is. f\JT IN ~ , UJO V le...I II) S '-J 'S~VQ CA"T-€ rage 7 of7 .....1::7(' ~ ì V"V A1e...uT " .. Environmental Laboratories 6/11/01 Unocal Oil and Gas PO Box 196247 Anchorage, AI( 99519 Attn: Don Andrews Lab Sample Number B0105283-01 . . 12189 Pennsylvania St. Thornton, CO 80241 (303) 469-8868 Fax (303)469-5254 Work Order #: B0105283 Date: 6/11/01 Work ill: Ivan River Reserve Pits Date Received: 5/25/01 Sample Identification Client Description Ivan River Lab Sample Number Client Description Enclosed are the analytical results for the submitted sample{s). Please review the CASE NARRATIVE for a discussion of any data and/or quality control issues. Listings of data qualifiers, analytical codes, key dates, and QC relationships are provided at the end of the report. Sincerely. Joe Egry Project Manager "The Science of Analysis, The Art of Service" . J . Case Narrative Analytica Environmental Laboratories, Inc. WorkOfder: BOI05283 Samples were prepared and analyzed according to methods outlined in the following references: o Methods for the Detennination of Metals in Environmental Samples, EP A/600/R-941111, May 1994. Problems encountered with the analyses are discussed in the following narrative. . <f< . . )< Detailed Analytical Report Analytica Environmental Laboratories, Inc. Workorder (SDG): BOl05283 Project: Ivan River Reserve Pits Client: Unoea) on and Gas Client Project Number: Unoea) Corporation Report Section: Client Sample Report Client Sample Name: Ivan River ~ Matrix: Aqueous Collection Date: 5/23/01 3:44:00PM The folIowing test was conducted by: Analytica - Thornton Lab Sample Number: BOI05283-01A Prep Date: 5/29/01 Analytical Method ill: 200. 7 - Metals and Trace Elements by ICP - Total Prep Method ill: 3010A Prep Batch Number: BOI0529004 Report Basis: As Received AnaMe CASNo Calcium 7440-70-2 Magnesium 7439-96-5 Potassium 7440-09-7 Sodium 7440-23-5 Analysis Date: Instrument: File Name: Dilution Factor: 5/30/01 5:49:00PM ICP_2 E053001 1 1.5 4.3 22 Units mg/L mg/L mg/L mg/L 0.10 1.0 3.0 Analyst Initials: MDL 0.018 0.030 0.25 0.36 MG Result 8.7 FIR!!S POL 0.10 Rerun #: I Page 3 of7 ~ '( . Detailed Analytical Report Workorder (SDG): BOI05283 Project: Ivan River Reserve Pits Client: Unocal Oil and Gas Client Project Number: Unocal Corporation Report Section: Method Blank Report Client Sample Name: 1MB Matrix: Magnesium Potassium Sodium Page 4 of7 . Analytica Environmental Laboratories, Inc. Aqueous BO I 0529004-MB 5/29/01 200. 7 - Metals and Trace Elements by ICP - Total 3010A BO 1 0529004 Dry Weight Basis CASNo 7440-70-2 7439-96-5 7440-09-7 7440-23-5 Result ND Fla!!s Units mgIL mgIL mgIL mgIL , The following test was conducted by: Analytica - Thornton Lab Sample Number: Prep Date: Analytical Method ID: Prep Method ID: Prep Batch Number: Report Basis: Analvte Calcium ND ND ND ~ Collection Date: Analysis Date: Instrument: File Name: Dilution Factor: POL 0.10 0.10 1.0 3.0 Analyst Initials: MDL 0.018 0.030 0.25 0.36 5/29/01 12:00:00AM 5/29/01 2:46:00PM ICP_2 E052901 1 MG Rerun #: 1 r * . . , Detailed Analytical Report Analytica Environmental Laboratories, Inc. Workorder (SDG): BOI05283 Project: Ivan River Reserve Pits Client: Unocal Oil and Gas Client Project Number: Unocal Corporation QC Recovery Report Work Order:BOl 05283 Prep Batch Number: BOI0529004 Base Sample BOIOS29004-MB Anal. Method: 200. 7 - Metals and Trace Elements by ICP - Total QC Sample BOI0529004-LCS Sample Prep Date: 5/29/01 12:00:00AM Analysis Units: mgIL SampleAnalysis Date: 5/29/0] 2:46:00PM Matrix: Aqueous QC Sample Analysis Date: 5/29/0] 2:50:00PM QC DUPSample Analysis Date: Analyte Samp. Spike Spike Recov LCL VCL RPD Rec Fl Result Res. Cone Calcium ND 9.10 ]0.0 91 80 ]20 Magnesium ND 9.57 10.0 96 80 ]20 Potassium ND ]1.6 ]0.0 116 80 ]20 Sodium ND 11.0 10.0 110 80 ]20 FOOTNOTES TO QC REPORT Note 1: Results are shown to three significant figures to avoid rounding errors in calculations. Note 2: If the sample concentration is greater than 4 times the spike level, a recovery is not calculated, and the result should be used as a replicate. In such cases the spike is not as high as expected random measurement variability of the sample result itself. Note 3: For sample duplicates, if the result is less than the PQL, the duplicate RPD is not applicable and is shown as O. If the sample and duplicate results are not five times the PQL or greater, then the RPD is not expected to fall within the window shown and the comparison should be made on the basis of the absolute difference. Analytica uses the criterion that the absolute difference should be less than the PQL for water or less than 2XPQL for other matrices. Page 5 of7 , . . . . " Detailed Analytical Report Workorder (SDG): B0105283 Project: Ivan River Reserve Pits Client: Unocal Oil and Gas Client Project Number: Unocal Corporation QC BATCH ASSOCIATIONS - BY METHOD BLANK Analytica Environmental Laboratories, Inc. Lab Project ID: 3,550 Lab Project Number: BOI05283 Test: 200.7 - Metals and Trace Elements by ICP - Total Prep Date: 5/29/01 Lab Method Blank Id: BOI0529004-MB Prep Batch ill: BOI0529004 Method: 200. 7 - Metals and Trace Elements by ICP - Total This Method blank and sample preparation batch are associated with the following samples, spikes, and duplicates: SampleNum ClientSampleName DataFile AnalvsisDate BOI0529004-LCS LCS E052901 5/29/01 2:50:00PM BOI05283-01A Ivan River E053001 5/30/01 5:49:00PM BOI05283-OlA-DUP DUP E05300l 5/30/01 5:53:00PM BOI05283-01A-MS MS E053001 5/30/01 5:58:00PM BOI05283-01A-PDS PDS E053001 5/30/01 6:02:00PM Page 6 of7 ~~~***************************************************************************************************** ~ . . P,Ol ~ "., , - TRANSACT I ON REPORT "., * MAY-22-01 TUE 10:08 AM * * * * SEND(M) * * * * DATE START RECEIVER TX TIME PAGES TYPE NOTE M# DP * * * * MAY-22 10:06 AM 19072833299 1/14" 3 SEND ( M) OK 117 * * * ***************************************************************%**************************************** .. . . PUBLISHER'S AFFIDAVIT .. UNITED STATES OF AMERICA, STATE OF ALASKA ... 55: ~ being first duly .-------------' .....:--:~, ------..-...~ ........... ........ I ' STATE OF ALASKA ., I Alaska 011 and Gas Conservation Commission I IRe: Disposal Injection Order, Sterling Foundation, Ivan River ~I I Unit Unocal Corporation. I I Unocal CQrporation by letter dated May 17, 2001hassUb-1 · mittect an AppIicatiÒn for Disposal Injection Order for ~ IRU I #14-31 inthe Ivan River unit, Cook Inlet, Alaska. The request- .1 · ed order would authorize injection of Class II ftuids,into well ,. .IRU #14-31 between 3145-3420' measured depth. .. · A person may submit written comments regarding this appli- .. I cation prior to June 27, 2001 to the Alaska Oil and Gas " , I Conservation CQmmission at 333 West 7th Avenue, Suite 100,1 I Anchorage, Alaska 99501. In addition, the CQmmission has . · tentatively set a public hearing on June 27, 2001 at 9:30 am. I at the Alaska Oil and Gas CQnservation Commission at 3331 I West 7th Avenue, Suite 100, Anchorage, Alaska 99501. A per- .1 sons may request that the tentatively scheduled hearing be ; held by filing a written request with the CQmmission prior to . I June 13, 2001. I Ilf a request for a hearing is not timely filed, the Commission ; will consider the issuance of an order without a hearing. To ! I learn if the Commission will hold the public hearing, please ¡ I call 793-1221. I I ,If you are a person with a disability who may need a special Irnodi~tion.in order to comment or to attend the public hear· . ; lng, pI~contact Jody Colombie at 793-1221 before June I 120,2001. . I , ' Cammy Taylor I I C;:, OU and."- 0:,,,'.-1(,)\ Commission . I PUBLISH: 5!:l7" ' . , 2157fm74 I .----------------------------. Denise Reece sworn, on oath deposes and says: That I am and was at all times herein this affidavit mentions, Supervisor of Legals of the Peninsula Clarion, a newspaper of general circulation and published at Kenai, Alaska, that the Disposal Injection Order/Sterling Foundation AO-0211425 a printed copy of which is hereto annexed was published in said paper one each and every day for one successive and consecutive day in the issues on the following dates: May 27,2001 x ¡J ;/?./~¡z, ",f..Þ' þ' /? ~ SUBSCRIBED AND SWORN to before me this 31st day of May 2001 ð~ NOTARY PUBLIC in and for the State of Alaska. My Commission expires 1O-Jul-02 ~ . STATE OF ALASKA .4DVERTISING ORDER . NOTICE TO PUBLISHER . ADVERTISING ORDER NO. INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTIFIED AFFIDAVIT OF PUBLICATION (PART2 OF THIS FORM) WITH ATTACHED COpy OF AO-0211424 ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE F AOGCC R 333 W 7th Ave, Ste 100 o Anchorage, AK 99501 M AGENCY CONTACT DATE OF A.O. Jody Colombie May 22,2001 PHONE PCN ¿ Anchorage Daily News POBox 149001 Anchorage, AK 99514 (907) 793 -1 ?? 1 DATES ADVERTISEMENT REQUIRED: May 23, 2001 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: Type of Advertisement I:8J legal o Display o Classified DOther (Specify) SEE ATTACHED PUBLIC HEARING NOTICE REF TYPE 1 VEN 2 ARD 3 4 FIN AMOUNT 1 2 3 NUMBER AOGCC, 333 W. 7th Ave., Suite 100 )\nchora~e,AJ(9950l AMOUNT DATE 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 A RElð~üJ~t- IDG::A;~.I 02-902 (Rev. 3/94) Publisher/Original Copies: Department Fiscal, Department, Receiving AO.FRM . . Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: Disposal Injection Order, Sterling Formation, Ivan River Unit Unocal Corporation Unocal Corporation by letter dated May 17, 2001 has submitted an Application for Disposal Injection Order for well IRU #14-31 in the Ivan River Unit, Cook Inlet, Alaska. The requested order would authorize injection of Class II fluids into well IRU #14-31 between 3145-3420' measured depth. A person may submit written comments regarding this application prior to June 27, 2001 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 June 27, 2001 at 9:30 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 June 13,2001. If a request for a hearing is not timely filed, the Commission will consider the issuance of an order without a hearing. To learn if the Commission will hold the public hearing, please call 793-1221. If you are a person with a disability who may need a special modification in order to comment or to attend the public hearing, please contact Jody Colombie at 793-1221 before June 20, 2001. ,-, - {\ ~ ..þ:"'J\'-1~' ~:u·'-"'" ~ I, ( .. u '._' Cammy Taylor Chair, Oil and Gas Conservation Commission Published May 23,2001 ADN AO#-02114024 Clarion AO#-021 14025 5/a7/p J STATE OF ALASKA ADVERTISING ORDER INV.MUST BE 1~~r~~T~ S~211~:'~~;~~'~~~E. CERTIFIED ADVERTISING ORDER NO. AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COPY OF AO"02114024 ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE F AOGCC R 333 West 7th Avenue, Suite 100 o Anchorage,AJC 99501 M AGENCY CONTACT DATE OF A.O; Jody Colombie May 2?, ?001 PHOI'JE PCN (907) 793 -1 n 1 DATES ADVERTISEMENT REQUIRED: ¿ Anchorage Daily News POBox 149001 Anchorage, AJC 99514 May 23,2001 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: United states of America AFFIDAVIT OF PUBLICATION REMINDER State of ss INVOICE MUST BE IN TRIPLICATE AND MUST REFERENCE THE ADVERTISING ORDER NUMBER. A CERTIFIED COpy OF THIS AFFIDAVIT OF PUBLICATION MUST BE SUBMITTED WITH THE INVOICE. ATTACH PROOF OF PUBLICATION HERE. division. Before me, the undersigned, a notary public this day personally appeared who, being first duly sworn, according to law, says that 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 Î'UBLISHER ******************************************************************************************************** ! . . P.01 ! <1\ , \ TRANSACT I ON REPORT <1\ * ' MAY-22-01 TUE 10:05 AM * * * * SEND (M) * * * * DATE START RECEIVER TX TIME PAGES TYPE NOTE M# DP * * * * MAY-22 10:04 AM ANCH NEWS 1'12" 3 SEND ( M) OK 116 * * * ******************************************************************************************************** ~,. :, . Anchorage Daily News Affidavit of Publication 1001 Northway Drive, Anchorage. AK 99508 AD# DATE PRICE PER DAY PO ACCOUNT 891511 OS/23/2001 STOF0330 $101.08 02114025 $101.08 STATE OF ALASKA THIRD JUDICIAL DISTRICT Eva Alexie, being first duly sworn on oath deposes and says that she is an advertising representative of the Anchorage Daily News, a daily newspaper. That said newspaper has been approved by the Third Judicial Court Anchorage, Alaska, and it now and has been published in the English language continually as a daily newspaper in Anchorage, Alaska, and it is now and during all saia 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 puólished in regular issues (and not in supplemental form) of said newspaper on the above dates and that such newspaper was regularly distributed to its subscribers during all of said period. That the full amount of the fee charged for the foregoing publication is not in excess of the rate charged private individuals. ç (",c " Signed (___~_5ê_,-- '-:L~-Q 0/"'-1 UL Subscribed and sworn to me before this date: ~jptfß/ Notary Public in and for the State of Alaska. Third Division. Anchorage, Alaska I MY COMMISSION EXPIREs:/c9/..oj/ 1~?!!£' þ ~ \\'~~~\.A; .~. rfrr,/ ~:4...' ---···~b-- ~ (J:·~OTA/1» "'~ ....... __ }..(rI- '- -. - ~ : ÞUSLir : Z - . ( ) ..,.,.-- :::.i . ~ --- ~: ~ ..; ~"'A #." ..", ~ . ;~-OF A\J"·· .~:\' ~ '. '. . . .' '\.'\\'\ //¡ f"ptres'~'\\ , /L.IJ}J)JI¡)\ OTHER CHARGES $0.00 $0.00 $0.00 . OTHER CHARGES #2 $0.00 $0.00 $0.00 Notice of Public Hearing STAT ¡¡ 01' ALASKA Alaska Oil and Gas Conservation Committee Re: DisPosal Iniection Order. Sterling Forma- tion. Ivan River Unit Unoc:ol Corporation Unoc:al Corporation bY lettel' doted May 17. 2001 has requested on Applica- tion for Disposal Inlec- tlon Order for well I R U #14,,-31 in the Ivan River Unot. Cook Int!!t. Alaska. The request'ed order would authorize Inlection of Closs II fluids into,well I R U #14-31 between 3145-3420' measu red I depth. i A person may submit I written comments re" , garding the requested re- !;Jg~~~r;~'}[I~~k~b~r l:d , Gas Conservation Com- I mission at 333 West 7th ¡ Avenue. Suite 100. An- ~ chol'age. Alaska 99501. In : addition. the Commission ¡ has tentatively set 0 pub- 1 lie hearing on June 27, 12001 at 9:30 om at the Alaska 011 and Gas Con- i servatlan Commission at ! t333 West 7th Avenue, 'Suite 100, Anchorage. 'I Alaska 9950,1. A person , may I'equest that the ten- 1, tativelyscheduled hear- ing be held bY filing 0 i writtenl'equest with the I Commission prior to June 113,2001. I If 0 request for 0 hear- I jng is not timelY filed, the I Commission will con- : sider the issuance of on larder without a hearing. iTa leal'nif the Commls- I sion will hold the public : hearing. please call 1 793·122l. i If YOU ore a. person with 10, disability ,who may I need 0 special modifica- tion in ol'der to comment lor to aUend the public \ hearing. please contact JodY Colt)mbie at 793-1221 I before June 20. 2001. i Is! Cammy Taylor ¡ Choir. Oil and Gas I Conservation Commission : AO-o2114025 ~ Pub.: May 24. 2001 I _.~__~__,,__. _. ___ GRAND TOTAL $101.08 $0.00 $101.08 ~- "--- Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: Disposal Injection Order, Sterling Fonnation, Ivan River Unit Unocal Corporation Unocal Corporation by letter dated May 17, 2001 has submitted an Application for Disposal Injection Order for well IRU #14-31 in the Ivan River Unit, Cook Inlet, Alaska. The requested order would authorize injection of Class II fluids into well IRU #14-31 between 3145-3420' measured depth. A person may submit written comments regarding this application prior to June 27,2001 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 June 27, 2001 at 9:30 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 June 13,2001. If a request for a hearing is not timely filed, the Commission will consider the issuance of an order without a hearing. To learn if the Commission will hold the public hearing, please call 793-1221. If you are a person with a disability who may need a special modification, in order to comment or to attend the public hearing, please contact Jody Colombie at 793-1221 before June 20,2001. ~/¡ ~ammy Ta910~ Chair, Oil and Gas Conservation Commission ADN AO#-02114024 - Published 5/23/01 Clarion AO#-02114025 - Published 5/27/01 I certify that on 5· a3 0 J a copy of the above was faxed/mailed to each of the fo~"9. at their addresses of record: JU /// VQ 1'0 - ClnorQJ ,~( .-.-- Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: Disposal Injection Order, Sterling Fonnation, Ivan River Unit U nocal Corporation Unocal Corporation by letter dated May 17, 2001 has submitted an Application for Disposal Injection Order for well IRU #14-31 in the Ivan River Unit, Cook Inlet, Alaska. The requested order would authorize injection of Class II fluids into well IRU #14-31 between 3145-3420' measured depth. A person may submit written comments regarding this application prior to June 27,2001 to the Alaska Oil and Gas Conservation Commission at 333 West ih Avenue, Suite 100, Anchorage, Alaska 99501. In addition, the Commission has tentatively set a public hearing on June 27, 2001 at 9:30 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 June 13, 2001. If a request for a hearing is not timely filed, the Commission will consider the issuance of an order without a hearing. To learn if the Commission will hold the public hearing, please call 793-1221. If you are a person with a disability who may need a special modification in order to comment or to attend the public hearing, please contact Jody Colombie at 793-1221 before June 20, 2001. ~~ Cammy Taylor Chair, Oil and Gas Conservation Commission ADN AO#-02114024 - Published 5/23/0 I Clarion AO#-02114025 - Published 5/27101 PIRA ENERGY GROUP, LIBRARY 3 PARK AVENUE (34th & PARK) NEW YORK, NY 10016 OFFICE OF THE GOVERNOR, JOHN KATZ STE 518 444 N CAPITOL NW WASHINGTON, DC 20001 ARENT FOX KINTNER PLOTKIN KAHN, LIBRARY WASHINGTON SO BLDG 1050 CONNECTICUT A V NW WASHINGTON, DC 20036-5339 LIBRARY OF CONGRESS, STATE DOCUMENT SECTION EXCH & GIFT DIV 10 FIRST ST SE WASHINGTON, DC 20540 U S DEPT OF ENERGY, PHYLLIS MARTIN MS EI823 1000 INDEPENDENCE SW WASHINGTON, DC 20585 US GEOLOGICAL SURVEY, LIBRARY NATIONAL CTR MS 950 RESTON, VA 22092 DPC, DANIEL DONKEL 1420 NORTH ATLANTIC AVE, STE 204 DAYTON BEACH, FL 32118 AMOCO CORP 2002A, LlBRARYIINFO CTR POBOX 87703 CHICAGO, IL 60680-0703 ILLINOIS STATE GEOL SURV, LIBRARY 469 NATURAL RESOURCES BLDG 615 E PEABODY DR CHAMPAIGN,IL 61820 ALFRED JAMES III 107 N MARKET STE 1000 WICHITA, KS 67202-1811 MURPHY E&P CO, ROBERT F SAWYER POBOX 61780 NEW ORLEANS, LA 70161 CROSS TIMBERS OPERATIONS, SUSAN LILLY 210 PARK AVE STE 2350 OKLAHOMA CITY, OK 73102-5605 IOGCC, POBOX 53127 OKLAHOMA CITY, OK 73152-3127 OIL & GAS JOURNAL, LAURA BELL POBOX 1260 TULSA, OK 74101 GAFFNEY, CLINE & ASSOC., INC., LIBRARY 16775 ADDISON RD, STE 400 ADDISON, TX 75001 US DEPT OF ENERGY, ENERGY INFORMATION ADMINISTRATION MIR YOUSUFUDDIN 1999 BRYAN STREET STE 1110 DALLAS, TX 75201-6801 DEGOL YER & MACNAUGHTON, MIDCONTINENT DIVISION ONE ENERGY SO, STE 400 4925 GREENVILLE AVE DALLAS,TX 7520&4083 CROSS TIMBERS OIL COMPANY, MARY JONES 810 HOUSTON ST STE 2000 FORT WORTH, TX 76102-6298 SHELL WESTERN E&P INC, G.S. NADY PO BOX 576 HOUSTON, TX 77001-0574 "~ NY PUBLIC LIBRARY DIV E, GRAND CENTRAL STATION POBOX 2221 NEW YORK, NY 10163-2221 US MIN MGMT SERV, CHIEF OCS STATS & INFO 381 ELDEN ST MS 4022 HERNDON, VA 20170-4817 TECHSYS CORP, BRANDY KERNS PO BOX 8485 GATHERSBURG, MD 20898 SD DEPT OF ENV & NA TRL RESOURCES, OIL & GAS PROGRAM 2050 W MAl N STE #1 RAPID CITY, SD 57702 LINDA HALL LIBRARY, SERIALS DEPT 5109 CHERRY ST KANSAS CITY, MO 64110-2498 UNIV OF ARKANSAS, SERIALS DEPT UNIV LIBRARIES FAYETTEVILLE, AR 72701 R E MCMILLEN CONSULT GEOL 202 E 16TH ST OWASSO, OK 74055-4905 BAPIRAJU 335 PINYON LN COPPELL, TX 75019 STANDARD AMERICAN OIL CO, AL GRIFFITH PO BOX 370 GRANBURY, TX 76048 ENERGY GRAPHICS, MARTY LINGNER 1600 SMITH ST, STE 4900 HOUSTON, TX 77002 H J GRUY. ATTN: ROBERT RASOR 1200 SMITH STREET STE 3040 HOUSTON, TX 77002 PURVIN & GERTZ INC, LIBRARY 2150 TEXAS COMMERCE TWR 600 TRAVIS ST HOUSTON, TX 77002-2979 CHEVRON, PAUL WALKER 1301 MCKINNEY RM 1750 HOUSTON, TX 77010 OIL & GAS JOURNAL, BOB WILLIAMS 1700 W LOOP SOUTH STE 1000 HOUSTON, TX 77027 MARK ALEXANDER 7502 ALCOMIT A HOUSTON, TX 77083 MARATHON OIL CO, GEORGE ROTHSCHILD JR RM 2537 PO BOX4813 HOUSTON, TX 77210 EXXON EXPLORATION CO., T E ALFORD PO BOX 4778 HOUSTON, TX 77210-4778 EXXON EXPLOR CO, LAND/REGULATORY AFFAIRS RM 301 POBOX 4778 HOUSTON, TX 77210-4778 PETR INFO, DAVID PHILLIPS POBOX 1702 HOUSTON, TX 77251-1702 PHILLIPS PETROLEUM COMPANY, W ALLEN HUCKABAY PO BOX 1967 HOUSTON, TX 77251-1967 EXXONMOBIL PRODUCTION COMPANY, J W KIKER ROOM 2086 POBOX 2180 HOUSTON, TX 77252-2180 EXXONMOBIL PRODUCTION COMPANY, GARY M ROBERTS RM 3039 POBOX 2180 HOUSTON, TX 77252-2180 CHEVRON CHEM CO, LIBRARY & INFO CTR POBOX 2100 HOUSTON, TX 77252-9987 MARATHON, Ms. Norma L. Calvert POBOX 3128, Ste 3915 HOUSTON, TX 77253-3128 PHILLIPS PETR CO, PARTNERSHIP OPRNS JIM JOHNSON 6330 W LOOP S RM 1132 BELLAIRE, TX 77401 TEXACO INC, R Ewing Clemons PO BOX 430 BELLAIRE, TX 77402-0430 TESORO PETR CORP, LOIS DOWNS 300 CONCORD PLAZA DRIVE SAN ANTONIO, TX 78216-6999 INTL OIL SCOUTS, MASON MAP SERV INC POBOX 338 AUSTIN, TX 78767 DIANE SUCHOMEL 10507D W MAPLEWOOD DR LITTLETON, CO 80127 GEORGE G VAUGHT JR POBOX 13557 DENVER, CO 80201 ~' RAY TYSON 2016 MAIN #1415 HOUSTON, TX 77002-8844 PETRAL CONSULTING CO, DANIEL L LIPPE 9800 RICHMOND STE 505 HOUSTON, TX 77042 UNOCAL, REVENUE ACCOUNTING POBOX 4531 HOUSTON, TX 77210-4531 CHEVRON USA INC., ALASKA DIVISION ATTN: CORRY WOOLlNGTON POBOX 1635 HOUSTON, TX 77251 WORLD OIL, DONNA WILLIAMS POBOX 2608 HOUSTON, TX 77252 PENNZOIL E&P, WILL D MCCROCKLIN POBOX 2967 HOUSTON, TX 77252-2967 ACE PETROLEUM COMPANY, ANDREW C CLIFFORD PO BOX 79593 HOUSTON, TX 77279-9593 WATTY STRICKLAND 2803 SANCTUARY CV KA TY, TX 77450-8510 ROBERT G GRAVELY 7681 S KIT CARSON DR LITTLETON, CO 80122 BABCOCK & BROWN ENERGY, INC., JULIE WEBER 600 17TH STREET STE. 2630 SOUTH TOWER DENVER, CO 80210 US GEOLOGICAL SURVEY, LIBRARY BOX 25046 MS 914 DENVER, CO 80225-0046 C & R INDUSTRIES, INC." KURT SAL TSGA VER 7500 W MISSISSIPPI AVE STE C4 LAKEWOOD, CO 80226-4541 NRG ASSOC, RICHARD NEHRING POBOX 1655 COLORADO SPRINGS, CO 80901- 1655 RUBICON PETROLEUM, LLC, BRUCE I CLARDY SIX PINE ROAD COLORADO SPRINGS, CO 80906 TAHOMA RESOURCES, GARY PLAYER 1671 WEST 546 S CEDER CITY, UT 84720 US GEOLOGICAL SURVEY, LIBRARY 2255 N GEMINI DR FLAGSTAFF, AZ 86001-1698 LA PUBLIC LIBRARY, SERIALS DIV 630 W 5TH ST LOS ANGELES, CA 90071 BABSON & SHEPPARD, JOHN F BERGQUIST POBOX 8279 VIKING STN LONG BEACH, CA 90808-0279 ORO NEGRO, INC., 9321 MELVIN AVE NORTHRIDGE, CA 91324-2410 TEXACO INC, Portfolio Team Manager R W HILL POBOX 5197x Bakersfield, CA 93388 SHIELDS LIBRARY, GOVT DOCS DEPT UNIV OF CALIF DAVIS, CA 95616 H L WANGENHEIM 5430 SAWMILL RD SP 11 PARADISE, CA 95969-5969 US EPA REGION 10, THOR CUTLER OW-137 1200 SIXTH AVE SEATTLE, WA 98101 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 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 REVENUE, DAN DICKINSON, DIRECTOR 550 W 7TH AVE, SUITE 500 ANCHORAGE, AK 99501 FORCENERGY INC., JIM ARLINGTON 310 K STREET STE 700 ANCHORAGE, AK 99501 -- JERRY HODGDEN GEOL 408 18TH ST GOLDEN, CO 80401 JOHN A LEVORSEN 200 N 3RD ST #1202 BOISE, ID 83702 MUNGER OIL INFOR SERV INC, POBOX 45738 LOS ANGELES, CA 90045-0738 ANTONIO MADRID POBOX 94625 PASADENA, CA 91109 US GEOLOGICAL SURVEY, KEN BIRD 345 MIDDLEFIELD RD MS 999 MENLO PARK, CA 94025 ECONOMIC INSIGHT INC, SAM VAN VACTOR PO BOX 683 PORTLAND, OR 97207 DUSTY RHODES 229 WHITNEY RD ANCHORAGE, AK 99501 STATE PIPELINE OFFICE, LIBRARY KATE MUNSON 411 W 4TH AVE, STE 2 ANCHORAGE, AK 99501 FAIRWEATHER E&P SERV INC, JESSE MOHRBACHER 7151ST #4 ANCHORAGE, AK 99501 DEPT OF REVENUE, CHUCK LOGSTON 550 W 7TH AVE, SUITE 500 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 GAFO,GREENPEACE PAMELA MILLER 125 CHRISTENSEN DR. #2 ANCHORAGE, AK 99501-2101 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS TIM RYHERD 550 W 7th AVE STE 800 ANCHORAGE, AK 99501-3510 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS BRUCE WEBB 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 DNR, DIV OF OIL & GAS JAMES B HAYNES NATURAL RESRCE MGR 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS JIM STOUFFER 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 AK JOURNAL OF COMMERCE, OIL & INDUSTRY NEWS ROSE RAGSDALE 4220 B Street Ste #210 ANCHORAGE, AK 99501-3560 BRISTOL ENVIR SERVICES, JIM MUNTER 2000 W. INT'L AIRPORT RD #C-1 ANCHORAGE, AK 99502-1116 BAKER OIL TOOLS, ALASKA AREA MGR 4710 BUS PK BLVD STE 36 ANCHORAGE, AK 99503 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 ANADRI LL-SCHLUMBERGER, 3940 ARCTIC BLVD #300 ANCHORAGE, AK 99503-5711 ARLEN EHM GEOL CONSL TNT 2420 FOXHALL DR ANCHORAGE, AK 99504-3342 JAMES E EASON 8611 LEEPER CIRCLE ANCHORAGE, AK 99504-4209 US BUREAU OF LAND MNGMNT, ANCHORAGE DIST OFC PETER J DITTON 6881 ABBOTT LOOP ROAD ANCHORAGE, AK 99507 US BUREAU OF LAND MNGMNT, ANCHORAGE DIST OFC DICK FOLAND 6881 ABBOTT LOOP RD ANCHORAGE, AK 99507 TRADING BAY ENERGY CORP, PAUL CRAIG 5432 NORTHERN LIGHTS BLVD ANCHORAGE, AK 99508 THOMAS R MARSHALL JR 1569 BIRCHWOOD ST ANCHORAGE, AK 99508 '- ALASKA DEPT OF LAW, ROBERT E MINTZ ASST ATTY GEN 1031 W 4TH AV STE 200 ANCHORAGE, AK 99501-1994 DEPT OF REVENUE, OIL & GAS AUDIT FRANK PARR 550 W 7TH AVE STE 570 ANCHORAGE, AK 99501-3540 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS JULIE HOULE 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 DEPT OF NATURAL RESOURCES, PUBLIC INFORMATION CTR 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 HDR ALASKA INC, MARK DALTON 2525 C ST STE 305 ANCHORAGE, AK 99503 ANADARKO, MARK HANLEY 3201 C STREET STE 603 ANCHORAGE, AK 99503 FINK ENVIRONMENTAL CONSULTING, INC., THOMAS FINK, PHD 6359 COLGATE DR. ANCHORAGE, AK 99504-3305 AMERICA/CANADIAN STRATIGRPH CO, RON BROCKWAY 4800 KUPREANOF ANCHORAGE, AK 99507 US BLM AK DIST OFC, RESOURCE EVAL GRP ART BONET 6881 ABBOTT LOOP RD ANCHORAGE, AK 99507-2899 UOA/ ANCHORAGE, INST OF SOCIAL & ECON RESEARCH TERESA HULL 3211 PROVIDENCE DR ANCHORAGE, AK 99508 VECO ALASKA INC., CHUCK O'DONNELL 949 EAST 36TH AVENUE ANCHORAGE, AK 99508 US MIN MGMT SERV, RESOURCE STUDIES AK OCS REGN KIRK W SHERWOOD 949 E 36TH A V RM 603 ANCHORAGE, AK 99508-4302 US MIN MGMT SERV, 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, LEGAL DEPT MARK P WORCESTER POBOX 100360 ANCHORAGE, AK 99510-0360 PHILLIPS ALASKA, 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 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 -~... US MIN MGMT SERV, RICHARD PRENTKI 949 E 36TH AV ANCHORAGE, AK 99508-4302 GORDONJ.SEVERSON 3201 WESTMAR CIR ANCHORAGE, AK 99508-4336 US MIN MGMT SERV, RESOURCE EVAL JIM SCHERR 949 E 36TH A V RM 603 ANCHORAGE, AK 99508-4363 USGS - ALASKA SECTION, LIBRARY 4200 UNIVERSITY DR ANCHORAGE, AK 99508-4667 ANCHORAGE TIMES, BERT TARRANT POBOX 100040 ANCHORAGE, AK 99510-0040 PHILLIPS ALASKA, STEVE BENZLER ATO 1404 POBOX 100360 ANCHORAGE, AK 99510-0360 PETROLEUM INFO CORP, KRISTEN NELSON POBOX 102278 ANCHORAGE, AK 99510-2278 AL YESKA PIPELINE SERV CO, LEGAL DEPT 1835 S BRAGAW ANCHORAGE, AK 99512-0099 DAVID W. JOHNSTON 320 MARINER DR. ANCHORAGE, AK 99515 GERALD GANOPOLE CONSULT GEOL 2536 ARLINGTON ANCHORAGE, AK 99517-1303 --- US MIN MGMT SERV, AK OCS REGIONAL DIR 949 E 36TH AV RM 110 ANCHORAGE, AK 99508-4302 REGIONAL SUPRVISOR, FIELD OPERATNS, MMS ALASKA OCS REGION 949 E 36TH A V STE 308 ANCHORAGE, AK 99508-4363 US MIN MGMT SERV, FRANK MILLER 949 E 36TH A V STE 603 ANCHORAGE, AK 99508-4363 CIRI, LAND DEPT POBOX 93330 ANCHORAGE, AK 99509-3330 PHILLIPS ALASKA, JOANN GRUBER ATO 712 POBOX 100360 ANCHORAGE, AK 99510-0360 PHILLIPS ALASKA, MARK MAJOR A TO 1968 POBOX 100360 ANCHORAGE, AK 99510-0360 PHILLIPS ALASKA, KUP CENTRAL WELLS ST TSTNG WELL ENG TECH NSK 69 POBOX 196105 ANCHORAGE, AK 99510-6105 US BUREAU OF LAND MGMT, OIL & GAS OPRNS (984) J A DYGAS 222 W 7TH AV #13 ANCHORAGE, AK 99513-7599 JWL ENGINEERING, JEFF LIPSCOMB 9921 MAIN TREE DR. ANCHORAGE, AK 99516-6510 DAVID CUSATO 600 W 76TH A V #508 ANCHORAGE, AK 99518 ASRC, CONRAD BAGNE 301 ARCTIC SLOPE AV STE 300 ANCHORAGE, AK 99518 OPSTAD & ASSOC, ERIKA OPSTAD PROF GEOL POBOX 190754 ANCHORAGE, AK 99519 MARATHON OIL CO, OPERATIONS SUPT POBOX 196168 ANCHORAGE, AK 99519-6168 UNOCAL, POBOX 196247 ANCHORAGE, AK 99519-6247 BP EXPLORATION (ALASKA) INC, PETE ZSELECZKY LAND MGR POBOX 196612 ANCHORAGE, AK 99519-6612 BP EXPLORATION (ALASKA) INC, MR. DAVIS, ESQ POBOX 196612 MB 13-5 ANCHORAGE, AK 99519-6612 PINNACLE, STEVE TYLER 20231 REVERE CIRCLE EAGLE RIVER, AK 99577 DEPT OF NATURAL RESOURCES, DGGS JOHN REEDER POBOX 772805 EAGLE RIVER, AK 99577-2805 RON DOLCHOK POBOX 83 KENAI, AK 99611 NANCY LORD PO BOX 558 HOMER, AK 99623 ~- ARMAND SPIELMAN 651 HILANDER CIRCLE ANCHORAGE, AK 99518 JACK 0 HAKKILA POBOX 190083 ANCHORAGE, AK 99519-0083 MARATHON OIL CO, BRAD PENN POBOX 196168 ANCHORAGE, AK 99519-6168 EXXONMOBIL PRODUCTION COMPANY, MARK P EVANS PO BOX 196601 ANCHORAGE, AK 99519-6601 BP EXPLORATION (ALASKA) INC, 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 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 '---- HALLIBURTON ENERGY SERV, MARK WEDMAN 6900 ARCTIC BLVD ANCHORAGE, AK 99518-2146 ENSTAR NATURAL GAS CO, BARRETT HATCHES POBOX 190288 ANCHORAGE, AK 99519-0288 UNOCAL, KEVIN TABLER 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, SUE MILLER POBOX 196612 MIS LR2-3 ANCHORAGE, AK 99519-6612 L G POST O&G LAND MGMT CONSULT 10510 Constitution Circle EAGLE RIVER, AK 99577 JAMES RODERICK PO BOX 770471 EAGLE RIVER, AK 99577-0471 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 PACE, SHEILA DICKSON POBOX 2018 SOLDOTNA, AK 99669 AL YESKA PIPELINE SERVICE CO, VALDEZ CORP AFFAIRS SANDY MCCLINTOCK POBOX 300 MS1701 VALDEZ, AK 99686 NICK STEPOVICH 543 2ND AVE FAIRBANKS, AK 99701 FAIRBANKS DAILY NEWS-MINER, KATE RIPLEY POBOX 70710 FAIRBANKS, AK 99707 DEPT OF NATURAL RESOURCES. DIV OF LAND REG MGR NORTHERN REGION 3700 AIRPORT WAY FAIRBANKS, AK 99709-4699 RICHARD FINEBERG PO BOX416 ESTER, AK 99725 SENATOR LOREN LEMAN STATE CAPITOL RM 113 JUNEAU, AK 99801-1182 .,,~ JAMES GIBBS POBOX 1597 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 ,--' KENAI NATL WILDLIFE REFUGE, REFUGE MGR POBOX 2139 SOLDOTNA, AK 99669-2139 VALDEZ VANGUARD, EDITOR PO BOX 98 VALDEZ, AK 99686-0098 RICK WAGNER POBOX 60868 FAIRBANKS, AK 99706 FRED PRATT POBOX 72981 FAIRBANKS, AK 99707-2981 ASRC, BILL THOMAS POBOX 129 BARROW, AK 99723 UNIVERSITY OF ALASKA FBKS, PETR DEVEL LAB DR AKANNI LAWAL POBOX 755880 FAIRBANKS, AK 99775-5880 :#a. STATE OF ALASKA ·~DVeRTISING ORDER , . NOTICE TO PUBLISHER . ADVERTISING ORDER NO. INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTIFIED AFFIDAVIT OF PUBLICATION (PART2 OF THIS FORM) WITH ATTACHED COpy OF AO-0211425 ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE F AOGCC R 333 W 7th Ave, Stel00 o Anchorage, AK 99501 M AGENCY CONTACT DATE OF A.O. Jody Colombie May 22,2001 PHONE PCN ¿ Clarion Newspaper POBox 3009 Kenai, AK 99611 (907) 791 -1 ?21 DATES ADVERTISEMENT REQUIRED: May 23, 2001 ffþy a,? 2¿JO / . /Ø/Ch-,"/~/z THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: Type of Advertisement ~ Legal D Display D Classified DOther (Specify) SEE ATTACHED PUBLIC HEARING NOTICE REF TYPE 1 VEN 2 ARD 3 4 FIN AMOUNT NUMBER AOGCC, 333 W. 7th Ave" Suite 100 Anchorage, AK 99501 AMOUNT DATE 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 RE~v;nlDQ~ ID~SION APP~~: J '" l fu~/6<-C5-/ 02-902 (Rev. 3/94) Publisher/Original Copies: Department Fiscal, Department, Receiving AO.FRM . . Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: Disposal Injection Order, Sterling Formation, Ivan River Unit Unocal Corporation Unocal Corporation by letter dated May 17, 2001 has submitted an Application for Disposal Injection Order for well IRU #14-31 in the Ivan River Unit, Cook Inlet, Alaska. The requested order would authorize injection of Class II fluids into well IRU #14-31 between 3145-3420' measured depth. A person may submit written comments regarding this application prior to June 27, 2001 to the Alaska Oil and Gas Conservation Commission at 333 West ih Avenue, Suite 100, Anchorage, Alaska 99501. In addition, the Commission has tentatively set a public hearing on June 27, 2001 at 9:30 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 June 13,2001. If a request for a hearing is not timely filed, the Commission will consider the issuance of an order without a hearing. To learn if the Commission will hold the public hearing, please call 793-1221. If you are a person with a disability who may need a special modification in order to comment or to attend the public hearing, please contact Jody Colombie at 793-1221 before June 20, 2001. _,~;,' ,j\'1,"~c""-.^,",.. ( , Cammy Tãylor Chair, Oil and Gas Conservation Commission Published May 23, 2001 ADN AO#-02114024 ClarionAO#-021140255)l7Þ; STATE~QF ALASKA . AP\Í1:RTISING . ORDER ,-* MU", ee ,~~!~E,I; ~,~~!R~~,!;!,~,f CERTIFIED ADVERTISING ORDER NO. AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COpy OF A 0-02114025 ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE F AOGCC 333 West 7th Avenue, Suite 100 o Anchorage,AJ( 99501 M R T o Clarion Newspaper POBox 3009 Kenai, AJ( 99611 AGENCY CONTACT DATE OF A.O. Jody Colombie M~y??, 7001 PHONE PCN (907) 793 -1 ?? 1 DATES ADVERTISEMENT REQUIRED: May 23, 2001 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRElY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: United states of America AFFIDAVIT OF PUBLICATION REMINDER State of S5 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 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 and 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. AO.FRM PUBLISHER ( . ~1 . Unocal Corporation Agricultural Products 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7685 Facsimile 263-7901 . RECEIVED UNOCALe MAY 1 8 2001 Faye W. Sullivan Advising Environmental Scientist Alaska Oil & Gas Cons. Commission Anchorage May 17, 2001 Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th, Suite 100 Anchorage, Alaska 99501 Dear Dan: Application for Disposal Injection Order Ivan River Well 14-31 , Section 1, T13N, R9W, S.M. Matanuska-Susitna Borough, Alaska In accordance with 20 MC 25.252, enclosed is an application requesting the Commission to authorize the underground disposal of oil field wastes suitable for disposal in a Class II well, as defined in 40 CFR 144.6(b) as revised as of July 1, 1998. Exempt wastes would be injected in the interval between 3145-3420 feet (2862 TVD - 3074 TVD). This application is in conjunction with my letter of April 26, 2001 requesting a Freshwater Aquifer Exemption. It is anticipated that drilling mud, slurried drill cuttings, and other exempt wastes would be injected during a three well rig program on the West Side of Cook Inlet beginning July, 2001. Subsequently, small amounts of produced water associated with production of natural gas would be disposed. Injection pressures will be above the fracture gradient. While fractures will develop, it has been shown that they will be minor in nature. Numerous confining intervals exist between the injection zone and the fresh water sands that lie above 2500 feet, 2350 TVD. Injected wastes should not penetrate the confining shale member at 2945 feet (2715 TVD) because of the limited fracture domain and lack of natural faulting. The wells lying within the area of review are properly cased and cemented. Please let me know if you need any additional information. Thank you for your assistance. Sincerely, :1~; ') -Iu! Q diU/"+- <::' ...J" ,.1:. vv. ~-¿#..¥ Faye . Sullivan Enclosure cc: Tim Brandenburg, Don Andrews ~ . . Application For Disposal Injection Order Ivan River Unit Cook Inlet Basin 20 ACC 25.252 Well IRU-14-31 May 2001 . Alaska Code 20 AAC 25.252 (c) 1 (c) 2&3 (c) 4 (c) 5 (c) 6 (c) 7 (c) 8 (c) 9 (c) 10&11 (c) 12 (d) & (e) Exhibit Number Section 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 (c) 1 (c) 4 (c) 4 (c) 4 (c) 4 (c) 4 (c) 4 (c) 4 (c) 6 (c) 6 (c) 6 (c) 9 (c) 9 (c) 12 (c) 12 (c) 12 (c) 12 . Table of Contents Plat of Well Locations Surface Owners/Operators Geologic Details Well Logs Well Construction Waste Types and Volumes Injection Pressures Fluid Confinement Formation Water Salinities Wells Within AOR Mechanical Integrity of Injection Well Plat of Well Locations Regional Map, Cook Inlet Area Regional Map, Cook Inlet Area Spider Map of Well Courses Geologic Cross section IRU 14..31 Well Log Resistivity Chart Resistivity Chart IRU 14-31 Well Schematic IRU 14-31 Completion/Cementing Records IRU 14-31 Directional Survey Fracture Modeling Fracture References IRU 41-1 Completion/Cementing Records IRU 44-36 Completion/Cementing Records IRU 13-31 Completion/Cementing Records IRU 44-1 Completion /Cementing Records . . Well Locations 20 AAC 25.252 (c) 1 The map on the following page shows the development pad location within the Ivan River Unit, in addition to the well surface locations. The IRU 14-31 well surface location is 727.6 feet north and 757.4 feet west of the SE comer of Section 1, T13N, R9W, Seward Meridian, State of Alaska lease number ADL 32930. Exhibits 1 and 2 are regional maps showing the general location of the Unit. Exhibit 3 also outlines the unit area and provides a view of the existing well courses. The ~ mile area of review is shown at the top of the injection interval in well IRU 14-31 at a depth of 3145 feet measured depth (2821 feet subsea.). Three wells lie within the area of review. 1 / ~II!II I I /~ / / ~ ~ 11IIII ~ ~ ~ ~ ~/ I~ I ~ ~ / I ù\/, I ~I I ~ I I I I@ lRU 14~31i~ SURFACE LQCATION / ~ ~ ~ ~¡ IVAN t 1 MI E l . . Surface Owners and Operators 20 AAC 25.252 (c) 2&3 The State of Alaska is the only surface owner within Ivan River Unit and no other operators are in the development area. Therefore, no copies of the application need to be distributed and no notification affidavits are required. The State of Alaska is also the royalty owner. , . ·.. " . Geologic Details 20 AAC 25.252 (c) 4 The geology of the area, and the injection zone and confining intervals, was discussed in the Aquifer Exemption Application submitted to the Oil and Gas Conservation Commission on April 26, 2001. That narrative is attached and includes Exhibit 1 through Exhibit 7. Exhibit 3 has been revised to more correctly locate the intersection of we1114-31 with the top of the injection interval (2821 feet subsea). Also, the intersections of 13-31 and 44- 36 were mis-labeled. That error is now corrected. Exhibit 4 is a cross-section showing lithology and structure, and Exhibit 5 is the IRU 14- 31 well log. The injection interval is identified on the log as 3145 - 3420 feet, while the total injection zone would extend fÌ"om the base of the shale at 2962 feet to the unconformity at 3420 feet. . . 1 Geologic Report for Ivan River Unit 14-31 Injection Permit Application Exhibit 1 - Regional Map Exhibit 2 - Regional Map Exhibit 3 - Well Location Map Exhibit 4 - Cross Section Exhibit 5 -IRU 14-31 Log Exhibit 6 - Resistivityof Equivalent Solutions Exhibit 7 - Rw vs. Rweq Chart This report describes the geology of the area surrounding the IRU 14-31 well and provides geologic evidence in support of UNOCAL's application for a freshwater aquifer exemption. The index maps presented on Exhibits 1 and 2 show the location of the Ivan River Unit and surrounding gas fields (Beluga, Pretty Creek, Stump Lake, and Lewis River). The structure and stratigraphy of the geologic units underlying this area is described below. The Ivan River structure is a broad doubly plunging anticline. At the shallower depths that are the focus of this application, the structure is nearly flat, and it is unfaulted. A thick layer of glacial outwash deposits covers the surface. These sediments were deposited by high-energy braided streams and are comprised of bedload sands and gravels, interlayered with low permeability floodplain deposits consisting of clay-rich sandy silts, and shales. The thickness of these glacial deposits is difficult to determine due to their lithologic similarity to the underlying Sterling Formation, although they appear to extend down to a depth of approximately 3100 feet. The sediments of the Sterling Formation were deposited by a meander belt stream system (Hayes et. aI., 1976). The resulting deposits generally include fining-upward sequences of bedload conglomerates overlain by thick quartz-rich sands which are often capped by flood plain siltstones and mudstones. Because deposition was rapid as the meanders migrated across the flood plain, the siltstones and mudstones were not completely eroded. The result of this process is extensive lateral continuity of both the coarse grained and fine grained lithologies. Coals are also common and represent the vegetative cover of abandoned meanders. The effective winnowing of the high-energy . . 2 channel deposits and their relatively poor consolidation creates excellent porosity and permeability in many of the Sterling Formation sands. This formation is approximately 2000' thick at the Ivan River Field. Underlying the Sterling Formation are the meander belt and braided stream deposits of the Beluga Formation. This unit is comprised of fine grained sandstones, siltstones and coals, with minor conglomerates. Due to the nature of their deposition, the sands in the Beluga are much thinner than those of the Sterling Formation and they are relatively limited in lateral extent. These sands are also relatively rich in clay which decreases their permeability. The thickness of the Beluga Formation at Ivan River Field is approximately 2600'. Underlying the Beluga formation is the Tyonek Formation. Like the Sterling Formation, these sediments were deposited in a meander belt stream system and consist of laterally extensive sandstones, siltstones, shales and coals. The Tyonek Formation is over 4500' thick at Ivan River. The location of existing wells at Ivan River field is shown on Exhibit 3. These wells (with the exception of IRU 14-31 and IRU 23-12) currently produce gas from the Tyonek formation at a vertical depth of 7800' to 7900' below sea level (BSL). Injection is proposed in the I RU 14-31 well into coarse grained glacial outwash sands and gravel at measured depths of 3145'-3420' (2821'-3028'BSL). These sands are colored yellow on the dual induction log presented as Exhibit 4 and they are colored orange adjacent to the IRU 14-31 well bore on the cross section presented as Exhibit 5. On the right side of the dual induction log (Exhibit 4), two resistivity logs are presented: 1) the laterolog-8 (RLLS) which is presented as a solid curve and 2) the deep induction log (RILD) which is presented as a bold dashed curve. The laterolog-8 device measures the resistivity of the formation near the well bore where the formation has been flushèd by the drilling fluid. The deep induction device measures the resistivity of the formation at greater distances from the well bore (approximately 6') where the formation has not been affected by the drilling fluid. Sands on this log are easily recognized by increases in the resistivity curves while finer grained clay-rich sands and silts are indicated by lower resistivity values (colored orange on Exhibit 4). The sands targeted for injection are overlain by an impermeable twelve-foot-thick confining shale or clay (colored grey-brown on Exhibit 4 and Exhibit 5). These sands and the overlying confining shale can also be recognized on the electric logs of IRU 44-1 and IRU 23-12, indicating that they are laterally extensive units (Exhibit 5). Because this confining shale is laterally extensive and impermeable, it can be expected to serve as an excellent barrier to vertical migration of injected fluids. The equivalent salinity of the formation water at various depths in the IRU 14-31 well is shown on Table 1. The method used for the determination of formation water salinity is ...,," -.-.,..' --- .~ . . 3 described in Appendix A. The calculated salinity of the formation water near the top and near the bottom of the zone targeted for injection is 6100 ppm and 9230 ppm respectively. This is well above the 3000 ppm maximum acceptable. limit for fresh water. The deepest sand that contains fresh water (below 3000 ppm NaCI) is at 2297' MD (-2145 BSL). In addition to the 12' of primary confining shale, there are 280 net vertical feet of impermeable silt and clay-rich sand (colored brown on Exhibit 4) between the proposed injection zone and the deepest fresh-water sand. The sudden changes in formation water salinities with depth suggests that the sands are hydraulically isolated by the interlayered silts and clays (Exhibit 4). If they were not hydraulically isolated, the salinities of the sands would be more similar. Although the IRU 14-31 well was not logged above 2038' MD, the adjacent IRU 44-1 well was logged at shallow depths. The IRU 44-1 logs show very high resistivity readings (in excess of 100 ohmm) above 2000' MD indicating that fresh water is present at these shallow depths. Although Ivan River Field is currently remote from even small population centers, fresh water at these shallow depths can (and is) easily be tapped by inexpensive wells should the need arise. With continuous recharge from precipitation and snow-melt runoff, this supply of freshwater is virtually limitless. Thus, it would be economically impractical to attempt recovery of drinking water from the underlying saltwater sands. TABLE 1 DEPTHS ~D-N R. RWA TFM Salinity ('Yo) (Ohmm) (Ohmm) (OF) (ppm NaCI) MD SS BGL 2203 2062 2089 16 70 2.20 59 3000 2297 2142 2169 20 55 2.79 60 2300 2471 2290 2317 16 55 1.73 62 3700 2523 2333 2360 17 40 1.43 62 4500 2654 2441 2468 15 42 1.15 64 5500 2670 2454 2481 14 48 1.13 64 5600 2760 2526 2553 16 34 1.07 65 5900 2801 2558 2585 15 38 1.03 65 6000 2990 2703 2730 16 32 1.00 67 6100 3034 2737 2764 17 27 0.96 67 6300 :3175 2844 2871 20 19 0.96 68 6200 3238 2892 2919 16 21 0.66 69 9200 3290 2931 2958 20 14 0.71 69 8500 3330 2961 2988 15 25 0.68 70 8800 . . 4 REFERENCES Asquith, G. and Gibson, C., 1982, Basic well log analysis for geologists: Tulsa, Oklahoma, American Association of Petroleum Geologists, 216 p. 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 Symposium Proceedings, p. J 1-J27. Atlas Wireline Services, 1988, Log interpretation charts: Houston Texas, Western Atlas International, Inc., 203 p. Schlumberger, 1989, Log interpretation charts: Houston Texas, Schlumberger Educational Services, 151 p. APPENDIX A Using standard log analysis techniques, the equivalent salinity of formation water (in ppm NaCI) can be estimated in two ways: 1) the Rwa method and 2) the SP method. Because the SP log lacks any systematic character across the interval of interest in these wells, only the Rwa method can be applied across the entire section. This technique is based on the following relationships: Rwa = R¡F where F = 0.62/f·15 (Humble Formula) Rwa Apparent formation fluid resistivity Rt True formation resistivity F Formation resistivity factor f Porosity For a given sand, if porosity, formation temperature (Tfm) and apparent fluid resistivity are known, it is possible to estimate equivalent salinity (in ppm NaC/). It is assumed that NaCI is the dominant salt where specific knowledge of the actual fluid chemistry is unavailable. Resistivity, read from the deep induction curve (RILD), is assumed to be the best approximation of true resistivity of the formation beyond the zone that was invaded by . . 5 drilling fluids at the time of logging. The formation resistivity factor eliminates the effect of the rock itself from the resistivity measurement so that the resulting value (Rwa) represents only the contained fluid. Rwa values, when corrected for temperature, can be used to estimate salinity with a standard nomograph or set of equations (Exhibit 6; Atlas Wireline Services, 1988). The salinities presented in Table 1 were calculated by calibrating to an equivalent resistivity at 75°F and then solving for salinity, although similar results may be obtained by using a straight line through any value for Rwa (on the right stem) and the corresponding formation temperature (on the left stem). This line will intersect the equivalent salinity (on the middle stem). Since determination of salinity in this manner involves an exponential of porosity (see Humble formula above), a small error in porosity is reflected as a much larger error in the calculated salinity. In the IRU 14-31 well, a formation density log was used in conjunction with a neutron log to determine porosity. This was done by using the standard practice of averaging the porosity values indicated by the two curves for any given depth (Asquith and Gibson, 1982). An alternative method is to simply use the porosity value indicated by the density tool alone, however using this method in the IRU 14-31 well produces unrealistically high salinities due to the low porosities indicated by the density curve. Thus, the salinity values listed in Table 1 are conservative and could be much higher. Although the SP method of determining water salinities cannot be applied to most of the section due to the lack of character of the SP curve, an attempt was made to apply this method to the sand at 2990'. The SP method is based on the following relationship: Essp = -Kclog(Rmfeq/Rweq) Where Essp = Static SP which is measured as the amount of SP curve deflection from the shale baseline Kc = 61 + 0.133 Tf Rmfeq == the equivalent mud filtrate resistivity if it were a pure NaCI solution. This value is calculated by multiplying the true mud filtrate resistivity (Rmf) at formation temperature by 0.85. Rweq == the equivalent water resistivity if it were a pure NaCI solution. In IRU 14-31, the Essp = -28 mv, Kc = 61 + 0.133(67) = 69.9, and Rmf = 2.34 ohmm at 64 degrees. This equates to 2.2 ohmm at formation temperture of 67 degrees, resulting . . 6 in Rmfeq of 2.20hmm(0.85) = 1.910hmm. Inserting these values into the equation above and solving for Rweq results in a value of 0.76 ohmm. Using the chart shown in Exhibit 7 (Schlumberger, 1989), results in a Rw value of approximately 1.1 phmm. This is very close the 1.0 ohmm value determined for Rw from the Rwa method, and it indicates that the application of the Humble equation to these sands results in valid Rw values and salinities. Porosities, calculated as described above, within the coarse-grained sands of the upper Sterling Formation range from 14% to 20% (Table 1). Porosities in the finer- grained clay- rich sands and silts (colored brown on Exhibit 4) are considerably higher at 33% to 36%; however, this does not indicate that permeabilities in these inteNals are higher. In fact, the opposite is true. The higher porosities in the clay-rich sands are caused by interstitial water trapped between the unconsolidated microscopic clay particles. However, these interstitial pores are too small to allow fluid to pass through, making the inteNals relatively impermeable. Likewise, the porosity in the twelve-foot-thick confining shale or clay (colored grey on Exhibit 4) is 39%. This high porosity value is caused by the very high concentration of clay particles that are trapping interstitial water and effectively blocking the movement of fluid. The formation temperatures that were used were based on a thermal gradient of 1.15°F/100'. This gradient was determined using a linear interpolation between mean surface temperature (MST; 35°F for the Cook Inlet region) and the maximum recorded temperature downhole (Tmax). The latter is usually measured at TO after the temperature of the mud in the borehole has equilibrated to the temperature of the surrounding formation. In the case of IRU 14-31 this temperature was found to be 136°F at 10,794' MO or 8739' BGL. This results in a thermal gradient (TG) as follows: TG = (Tmax - MST)/Oepth BGL/100' = (136°F - 35°F)/8739'/100' = 1.156°F/100' . . REQUEST FOR FRESHWATER AQUIFER EXEMPTION UPPER STERLING FORMATION IVAN RIVER FIELD (April 26, 2001) (Well: IR 14-31, Seçtion 1, T13N, R9W, S. M.) In accordance with 20 AAC 25.440, Unocal submits this Aquifer Exemption Application for all aquifers below 2500 feet in Well 14-31, for an areal extent of ~ mile radius around Well 14-31. As detailed in the attached geologic report, the aquifers below 2500 feet meet the criteria for exemption as specified in both State and Federal regulations (MC 25.440 and CFR 40 146.4). Salinity of formation water at this depth is greater than 4,000 ppm NaCl. This request is in support of planned subsurface injection activities that would occur in W ell 14- 31 in the inj ection interval between 3145 - 3420 feet. Accordingly, and application for Class II disposal ofRCRA exempt wastes is being prepared to accommodate well workover and drilling activity in July of this year. A Sundry notice to test well injectivity is also being prepared for Commission approval. Areal Considerations The July well work might generate 20,000 - 30,000 barrels of waste. Ongoing disposal of produced water might generate +1- 100,000 barrels for disposal at this site. These volumes would create a waste plume that could range from 80 -150 feet surrounding the injection point. Since there is little, or no, natural pressure gradient in the disposal zone, and since there is no other subsurface injection in the area, the plume should not migrate laterally after disposal ceases. Accordingly, an aquifer exemption is requested for an area encompassing ~ mile around the inj ection point, shown on Exhibit 3 at the top of the inj ection interval (3145 feet in Well 14-31). Background of the Area, Facilities, and Current Operations The geographical area in which application is made lies immediately west ofthe Susitna River. The terrain is featureless wetlands which in 1976 was included in the Susitna Flats State Game Refuge. Predating establishment of the Refuge, lands were leased for oil and gas exploration, development, and production, and operations under these leases have taken place and continued compatibly. Regional maps, Exhibits 1 and 2, show the location of the various oil and gas fields and unit . . boundaries. The only improvements in the area, other than those incidental to oil and gas operations, are a number of "duck shacks" seasonally used by duck hunters. There are no known permanent residents in the area, nor should they be expected because of the marshy conditions stretching for miles and the designation of the lands as a game refuge. In addition to the unsuitability of the surface terrain for "people" uses and its designation as a game refuge, the evidence submitted by Unocal shows some 1000 feet of unconsolidated sediments containing available intervals of potentially fresh water. Potential users of drinking water in the area would rather target a surface collection system or one of the shallow aquifers. At the Ivan River production pad there are two freshwater wells completed at approximately 200 feet. These get used intermittently when well work is required. It would be economically impractical to recover water from the underlying saline aquifers and put it through a desalinization process for human consumption. Comparative Considerations Aquifer exemptions exist at similar depths in the Lewis River Unit to the north and at Beluga River Unit and North Cook Inlet Unit to the South. Fresh water used for human consumption and other purposes at Beluga River comes from shallow wells completed at approximately 200 feet. The Tyonek platform in North Cook Inlet Unit uses a seawater distillation unit and sometimes supplements this with freshwater brought to the platform by boat. There are no plans to use underlying aquifers as a source of drinking water at the platform. -+~ It! ~ .. . . Detailed Analytical Report Workorder (SDG): B0105283 Project: Ivan River Reserve Pits Client: Unocal Oil and Gas Client Project Number: Unocal Corporation Analytica Environmental Laboratories, Inc. DATA FLAGS AND DEFINITIONS Result Field: ND = Not Detected at or above the Reporting Limit Shown NA = Analyte not applicable (see Case Narrative for discussion) Qualifier Fields: LOW = Recovery is below Low Control Limit HIGH = Recovery, RPD, or other parameter is above Upper Control Limit E = Reported concentration is above the instrument calibration upper range DIL = Sample required dilution to bring analytes within calibration range of the instrument. At the dilution level required, the surrogate could not be quantified due to the resulting low surrogate concentration and/or coelution interference fÌ'om the sample. Organic Analysis Flags: B = Analyte was detected in the laboratory method blank J = Analyte was detected above 2 x MDL but below the Reporting Limit (Quant Limit) Inorganic Analysis Flags: B = AnaIyte was detected above the MDL or IDL but below the Reporting Limit W = Post digestion spike did not meet criteria S = Reported value detennined by the Method of Standard Additions (MSA) Page 7 of7 ~ . . Attachment 4 IR 14-31 Injection Test Results During discussions relating to the pending Ivan River disposal injection order, AOGCC staff requested that a step rate test and pressure fall-offbe done on well 14-31. Accordingly, attached are pressure-rate graphs for the two step-rate tests that were perfonned on June 8th and June 9th. (Tabular data can be provided if desired). The attached log shows the interval from 3189-3209 that was perforated, 12 shots per foot. It also shows that the tighter 20 foot thick interval that was shot, is bounded both on the top and bottom by 30 foot thick intervals of more porous rock. Injection Results : Attached is a plot of rate versus pressure resulting from the two tests. The plot shows that two fractures were generated on the first day. This is interpreted to mean that the lower porous interval was most probably perpetrated since the perforations are in the top ofthat interval. The second injection shows that the earlier fractures were reopened and the same flow system re-established. The pressure falloff data indicates that a good leak- off coefficient exists since the pressure declined to almost zero in a matter of minutes. Annular Pressures: The following annuli were monitored for any pressure response resulting from the injection. Wells 13-31 and 44-36 are the two wells closest to 14-31. · No pressure in 14-31 inner annulus (tubing by 7 inch casing ). · No pressure in 14-31 surface casing annulus (7 by 10 % casing). · No pressure in 13-31 surface casing. · No pressure in 44-36 surface casing. ,~ '~ i '1 .~ .~: .~ ..~~. ""1 \~ ,..¡ ~ ~ :~ ~. '.\\;1 J 'I 'j~ p', - ,."; ¡J, j\/~ {~ IiI I ..:1;,:,", cu' e!·, olF; ...,,;-,t ~ U~~, Ui~.~ Q)JffJ .J: r,'fi -¡if >,.,tl·,·,,· ~;;,. ¡..; -o!i: Q) r.' .J:l,- .~j~ C:¡'~¡ ~~h ~¡~ì ttf GIFt. ~¡~ ~r~ ' 'iI' o~ .g'I~· 4), U' c: t ~I:.I! ~.~~ ~'~f!;, .r. . Q):' , Õ~~r' .J:~', ',' .... "., '" " ~ . o~ ' n·¡! .~ -0,,_ 6:t~ ,~~ c: rî~ Oi.:r: .-.,~' ...... 0.1··1 U;~~ ..2i'~ C1Ì {)i' ~:,.il·,ìr, ,': CUI.: ~j . I '. CII'. ; .J:: ¡ .. t-th, ·!to' . ír~ lt~ il..,." h:· jf\.: w '~ ~¡~~: 0" ....i ,; OJ ,,', II. : I_,~ J ,¡;~ ¡ ~, W J " ';, " .....;... "-, -.,....,-. .... . 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I Ii ¡ . ¡ : -! ! r: ¡ ¡ : i'7'TI' ..--.- ..--t..-.-=-~._ ~ -._ ~, I . ; i,' I , I -" ~- , : !! : 3100 3000 2900 2800 2700 _ 2600 1ii ~ 2500 Q :; 2400 en m 2300 ... ~ 2200 c :s 21 00 :s I- 2000 1900 1800 1700 1600 1500 0.0 IVAN RIVER 14-31 INJECTION TEST ~ ~..... ....... . .' ..... ....... ~ ~ ,..7'..... ~ ...;...... .... ...... .... .' ....... .... .' .' ..... .... .... .' ...... ." _..... .. .' ..- .- .. .... .e .... ... .... .. .... ...:... ..\' .....·:.4 ...... .... .... t .._ ..... .... ..' ..' .' .... ..' .' .' . / . . . 6/8/01 . . 6/9/01 , ~ , , . , 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 4.5 5.0 5.5 Injection Rate (BPM) . . IVAN RIVER 14-31 INJECTION TEST 6/8/01 Step Rate Test #1 6/9/01 Step Rate Test #2 Tbg. Press. BPM Psi 0.5 2200 1.13 2500 2.1 2800 2.9 2875 3.9 3000 3.9 2680 (Fmn. Broke) 5.0 2870 4.6 2830 BPM 0.3 1.0 2.0 3.1 4.18 5.1 Tbg. Press. Psi 1650 1980 2225 2480 2665 2890 .--~----_.._..._-----_.._-------~-_.~.. . . . _!$:i}f~~ Well Field Country Time 06108I01 20:00:40 20:01:30 - 20:15:00 - 20:28:30 -. 20:42:00 - 20:55:30 ."' . A. - 21:09:00 ¡:;; l\I":: a V ~- 21 :22:30 - 21:36:00 - 21 :49:30 - j o c: :> .ö .s¡ 22:03:00 - ~ ~ t! i? '" o o I::! co Q :g hh:mm:ss 06108I01 22:10:09 . Mark of Schtumberger [~C';\\'E:'~;: IVAN RIVER 14-31 IVAN RIVER USA \ \ , " í; ! . ¡ : . CumVol bbI . II I I 350 ¡ i . ¡ ~ : I :..¡.¡ r¡ '. I' : i : I ~ I . !. . I ' o Cementing Job Report . Client UNOCAL SIR No. Job Date 6/8/2001 8:00:40 PM Pressure UI ! : ; . , ' , h I : ¡, : :f\. ! : I ; ¡ I : , ~ . ~. : : 1 ~ - : ") ! . l' . : I ,: ,¡ : i .: ..: ¡ (: ~ ~ .: , I psi =-- 1 - , , · .i · ; · j I ¡ ¡ I i ~:¡ I! I 'I' 3500 .~ . t , i; ¡". : ~¡ :~ - TotF_ ; , I: ¡ ; i , . , ! : , . :4-t. :¿ ~ I bpm , I . 6 PRlSM* V2.23 Messages ·ST ART ACQU1S111QN "Pr8ssUre Test Lines "Bleed OIfPres&ure " CumVol)=.3534 bbI R_VoIume SIart Pumping Water ·Increase Pump Rate "STOP ACQUISITION .------.------------------..-------.----. ' , -~~!¡.~ Well Field Country Time 0610910110:11:53 1 QlQO:O? 10:15:00 - 10:30:00 __ : 10:45:00 _ 11:00:00_ 11:15:00 _ 11:30:00 _ 11:45:00 _ 12:00:00 _ ~ " ~ 12:15:00 _ ~ ~ $! g ~ '" o hh:mm:ss 06109/01 12:22:08 . Mark of Schlumberger ~)n\jveti: IVAN RIVER 14-31 IVAN RIVER USA CumVoI . ; : ¡ , 1 : ¡ bbl . I 400 . (¡: . i. Cementing Job Report . Client UNOCAL SIR No. Job Date 6/9/200110:11:53 AM Prossure U1 · ¡ · , , · ¡ : ¡ , . """"""= i i il · , ~ ¡ , ; ¡ ~:i ~.¡ I : ! ~ ~ : I . , - i! ; "I :1 ,.. I ' ~: :~ :-W- ¡ : ¡ : i! : .....; :t, :~ : .: :~: · I · ; · I I: ~ ¡ i: ¡ ! : . , : ! - I 1 . ¡ ; psi 3500 o TotFIowrato , ! : = i : i ~ ¡ : , i; ~ , . :" : : . .. : j : I : I . I : j ..... ; ! : ! . : ! ! :~ ~ : ¡ : i : ¡ . ; ¡ ~ : ! , ! . , l' I' bpm 6 PRISM" V2.23 Mossogos ·ST ART ACQUISITION .,_ Pump R018 "User dofinod mossoge ·User dofinod message "Shuldown STUMP LAKE &. - Unoca! I 15 N NOR- o Raw R9W " ~_I '" J ANNA ~ITE PT.I. 353700 2655000 Ivr R 13 31 2650000 }4 MILE ~US 1 \ r 12MILE V RADIUS \ ft- ..... - \ I \ I I I / I / I / IR44-1 / I _ _ ...J 2645000- I :von I I X INTERSECTION OF WITH TOP OF INJECTION INTERVAL (2821'SS) 2640200 r-..... : EX~IBIT 3 (Rev.) UNIT BOUNDARY WESt· SIDE COOK INLET IV N RIVER AREA PROPOSEdlR14-31 INJEC'I''rON I 360000 353700 364700 I I I I I I ~ . Resistivity of Equivalent Na.IUtions Temperature (oF) (0C) 500- 260 ''¡- - - 240 . - Equivalent NaCl _- 220 Concentration 400-:'200 ( ppm ) (.~n~) <- or @ 24°0 '~180 mg/kg or 75°F "'- 200-_ ':'160 - 300-:- 300- :- 140 --=-20 400- . ~ "- ~30 "'" 600~ 250 --- 120 ~4O "'" 800 '3:. 50 - 1,000 --= .r100 - 200- - :::100 .- 90 2.000...... ..r . -80 3.000 ~ -200 -70 4,000 ~ '='300 150...... 6.000 3:. 400 -60 8,000:: 500 ..r 10,000 ~ .rOO - :;: 1000 20.000 - -40 . - 100- 30,000 : - 2000 40,000 ...... 90- :;""3000 ......30 60.000 ~ 4000 80- 80,000 :::: 5000 100,000 <: := 10,000 70- -20 200.000 -:-13.000 300,000 -17.500 60- 50 - 10 English: Salinity (ppm at 75°F) = lOx ( Ti' + 6.77 ) Rw2 = Rwl ; of T2, + 6.77 XQ.! 3.562 - log <Rw.¡s - 0.0123) 0.955 Metric: ( Tl + 21.5 ) Rw2 = Rwl ; °C T2 + 21.5 Rw ~ 0.0123 + 7S 3647.5 [NaCl(ppm)]O.9SS 1-5 .w, =-= A~~c...-, R (2'm) -::-20 = -10 :8 -=-6 '='5 -=4 :3 -=2 - -1 .=. 0.8 : 0.6 -0.5 -=- 0.4 = -=- 0.3 -=0.2 = - -=- 0.1 : 0.08 .=.. 0.06 -0.05 -= 0.04 - : 0.03 =-0.02 -0.01 Exhibit 6 . . SPONTANEOUS POTENTIAL I.. ..J .....llfliil.HI'I!{;¡, Rw versus Rweq and Formation Temperature ExhTbif1'< , 'i:..-- ~~'T"_ ~ _ . . Well Logs 20 AAC 25.252 (c) 5 Well logs fÌ"om the Ivan River wells, adjacent Units, and exploratory holes have been provided to the Oil and Gas Commission. Additional copies can be provided if necessary. . . Well Construction 20AAC 25.252 (c) 6 IRU 14-31 was drilled to a depth of 10,958 MD (8896 TVD). After logging and testing, the well was plugged back to 3350 MD (3009 TVD) with 158 feet of cement in the 7 inch casing. It was suspended on August 18, 1975. On January 31, 1993, a retainer was set at 3225 feet and a cement bond log run from 3218 feet to the surface. The bond log shows good cement from 3218 up to a depth of2320 feet, with some micro-annulus possibly present from 2320 to 2040 feet. The log then becomes non-definitive once above the surface casing shoe. (Good cement isolates the injection zone and confining intervals from the fresh water sands above 2500 feet.). The bond log can be provided upon request. The tubing-casing annulus was tested to 1500 psi, the tubing to 3000 psi, and the tubing-packer to 1500; and the well again suspended. Exhibit 8 shows the status ofthe well and Exhibit 9 includes state reports and other records detailing the casing, cementing, and tubing-packer equipment status. The 7 inch casing below the packer is 23 #, N-80 with an unsupported burst pressure of6340 psi. This exceeds the maximum bottom hole injection pressure by more that 25 percent as required by AAC 252.412. The 7 inch casing collapse pressure is 3840 psi. With the 2 7/8 X 7 annulus full of packer fluid, an exterior pressure would have to become 5015 psi for 7 inch collapse to occur. This would not be attained even if a fracture could somehow reach the annulus. (Maximum estimated fracture height is well below the packer.). The tubing burst pressure is 10,570 psi and the packer is good for 10,000 psi differential. The well surface location is 727.6 feet north and 757.4 feet west of the SE comer of section 1, T13N, R9W, Seward Meridian. The top ofthe injection interval at 2821 feet subsea is 1045.3 feet north and 20.5 feet west ofthe surface. Exhibit 10 is the directional survey dated August 26, 1975 that was used to plot the well course. Waiver Request: A waiver is requested from the requirement of20 AAC 25.410 (b) which states the packer must be within 200 feet measured depth of the upper perforation. With the top of the inj ection interval at 3145 MD and the packer at 2903 MD, the current completion has a distance of 242 feet. . . Well mu 14-31 Exhibit 8 Well Schematic Exhibit 9 Completion and Cementing Records Exhibit 10 Directional Survey · . Ivan River Field Well 14-31 Ë)( H \ ß)T B 2010... W ~_.- 2011 94# @ 4211 ~i\~ ... TTC @ 12381 For 711 CSG. ~ ~ ~ ~ ~ - ~ 1::::1 ~ . - ~ ~ ~ ::.: 10-31411 40.5# K-55 @ 2037' 1050 SXS TTC @ 511 Based on Hole Size @ 13181 Based on Equalization Thru Float Shoe Stage Collar @ 42341 689 SXS Annulus TTC Between 48451 and 40561 (CBL Not Conclusive) 711 23, 26 & 29# N-80 @ 70181 500 SXS 5 1/211 Liner @ 10,0001 01 :.':: 4 '.- ~ ~ ~ ~ ~ ~ ~ ~ ~ ~. ~ \ 1 ,.. ~~ I ~ I L-_____ - -~ SPUD 5/6/75 SUSP 8/18175 2-7/8" 6.4# N-80 Butt Tubing .... Baker 3-H Packer at 29031 IF' Profile at 29481 (2.312 ID) Baker WL Reentry Guide at 29821 Cement Retainer at 3225' Cement Plug 3350' - 35081 6862' - 68821 Sqz'd 200 SX' Fish #1 BHA Total Length 2281 Probably on Bottom at 10,0641 Fish #2 22061 of 2 7/8" D.P. Top @ 7495' Bottom @ 9701' Fish #3 W.O. Assy & D.C.'s Length 3801 Top @ 73451 Bottom @ 77251 Fish #4287612-213" TBG & 32001 31/2/1 D.P. Top @ 3510' Bottom @ 95861 Cement Plug 76001 - 9927' Cement Plug 10,100' - 10,3501 Cement Plug 10,650' - 10,900' TO = 10,958' 05-01-01 -----~) t"'''1 f'. '; A>\ . EX H I BiT .9 · "~.~f~ ' ,. CONFmaITlti'· . "!! 'J . I:V8)IJT IN ».1.1:'- . . . ·STATE OF ALASKA· ..........;;,,,. '\ .' ."\lr:".n~ In" :I. A ' NUM.&IUCAL CUUI:; 011 AND GAS CONSERVAtiON COMMITTEE f~V¥"'" .....: ADL 32930 WELL COMPLETION OR RECOMPLETION REPORT AND LOG * 6. Lt;J\::.~ U!::.1m.ôll¡A·I·IU.'I: .\',\;1.) ::;1:1>1.\1. NO. , , I.. 1 Yl',t; Ok' \\'r. .~. uu. LJ ~~~L i!J DUO (llb"r --S.uspeno(-'o WÞ:LL "- TYPE or COMPLETJONI None. ~r:w 0 ,,·..ftl( 0 PE':P, 0 "I.tti 0 IUFr, 0 ." t:I t ,,\r.te r.'( D4rK nJ:NVA. Othn 7, U' NUIAN, AJeW'I' 'J::£ vii ' 'lUlI!:: NA1\IE: .. tJNI'r,Jo"AlU\t 011 I..&.\::¡t: :~AME: :¡. ~.u..: "F Ur¡KATlln , , Standard Oil Company of California~ WOI .1. A"IJK& ¡¡II OF ora;114T'JK ' Ivan River Unit 11.\\11::1..1.1'10. Þ. O. Box 7-83~, Anchorage, Alaska 99510 .., '.or...r ( ~ or \\'I;'.L IJi~þo'" /ucu/ion C/"O"/I/ u"d in aceordunCc It'I"I an / .s,u/, rtv"¡",m,,,,")· ..U IUrtact 727.6', from south line and 757.4' from east line, section 1, T13N, R9W, SB&M .U t"lI prod. Intern/ reported beluw '. 14-31 10. ¡'ll;LJ) AND PUOL., 011 WIU)CAT ....',,"''-,.. Wildcat (Exploratory) u. $1::(;.. 1'., 11., M.. t ¡;U'I'rU:'1 lIùU; OUJECTlVE:, . Sec. 31; ~14N, R8W SB&M At total depth 957' from south line .&i. ~169' from west line, section 31, T14N, ~8W, SB&M 12. PJ'..ßMIT NO. 75-8 I:. 1.>A·"£ Sl'liLJ!JED lB. u.\ll: T.D. HEACJ ~ f15' 1>AT:EC(' :01P ::;USP OR ABA.-.D. liB. EU:VATIO:-;S IJJ!', ItKlI. R'I', GR, ~ . jJ-;. £LEV. C.\SJNGJlEAD 5/6/75 7/2n5·, 8/18/75 . K.EI. 46.4' ,! ." a. lùTAL IH;I"TH, :'oW 4c l'VDr~' PLCC. ·UAI.:K , ~11> .. TVDr·1F ~nl1.TIPLE êo~L.", t 21, 'STJ:.., .41.11 IJRII.I.I:U I.T . 10958 MD 3350 MD :. HOW MANY· .orAIIY TOOU ~ '=AIII.£ rool./I 8896 TVD . 3009 TVD O-'Oq~R :2. PROPUCI:\C !N1"£II\'..\ 1.($ '. OF THIS CO:'lP1.ETION'-TOP, BOTTOllot, NAME (M1> AND TVDI· ZI. WAS DIIIEC.'TIO:'olAL. I S!': t\'J::V ;\/,\1>1: I None' . . Yes :;. T\"I>£ J::1..F.C:T¡:IC A;o;P uTHER LOGS RUN 1EL, FDC-CNL, BHC, PML, Dipmeter. CBL 2:>. (.'.\SI:-;C !fECOnD ,n"pufI :all ~:,.rtas set m ,,'1 U CASCJ(; SIZ1: WEICHT. LB FT!; CRADE DI:PTn SET ,:\-11>. HOLE :aZE 30" Line Pipe 59' 20" 94# H-40 421' 10 3/4" 40.5 K-55 2037' 7" . 23#,26#,29*' N-80 7018' 2G 1.1~Z:::1 HF.C:01W I . 26" 950 cu. ft. "G" cement 15" 1050 sa.cks_ fiG" cewet t " 9 7/S- Shoe - YZ4 Cu.Ft G çm~. r ,P -1' c¡a r-" - 'F't fiG" r.mt.._ :t. Tt.'Blxa H£~~:J.J ct;;,ltXTI:-1G RECOI:D I /.~":Ol.':'\T P1:1.L1:D Driven None None None None $JZ!1 TOP c~.IDI 1;(.'1"0:\1 1;lIDI S,\('I{S CE:~I&:':1'· SC.·,I:O: ,;\:0, SIZE 2 7/8'" DEI>1'H SE1' I~.:DI : P.-\C¡;~ SET ':'011>1 92' None " 211 N:It",,,f(A 1 ,O:"S OP~" TO PH.OJJUC-.nù:; None (intel"\,..I. sue: and J:urnburÞ í), !> ~~ \\~' !I!t¡" , !;;,ti' !,ß,( t~~", ._ ¡Ly}1,\ It. '. iâ il,....ti ::J M.IU, s"cr. !·,:.\;"I':I:~, ~"'.II:.""'1' SQ::==":::. t:1':= ," \rf···j¡r¡;¡"'~ ~t::¡ [~ . fiii :A11:: Fm~T PI:Ul,\Ut.TION (' PC01HIC1'lùN ro.:~~f:~t.~;::i¡':;'I'''''I'Ú, P""'IIIna:-Ili... a,tel U'pu Of pump· ~'~~m::::'.....~';) ".au.I,-.n) . -------- Suspended CIl0:~E SIZ& Irl:OD':~ 1'011 O!1,-1;U1.. ·".\&-.\LCF. . \\·/QElt-BBL. 1 ";,\S·UII. ~O 1'1::;'1' ¡'J::lI.!OD I I I "- ---- --.. ---- ---- --- --- FLa\\'. 1'~'¡;INü l.'A:>L:';C; PRESStlIU: '·AI.C'lI1.ATED 01L-Bl!!.. GAS-MCF. WATEfV-DI3J.. 1011. CRA\'1'.I'\·-A.PI (COltR.1 '·Iœ..,;.~ :!-UOUR n,,,TF. I ----- . ------ ). ------- t -----...-1 . ------- - ------ 31.1~ ;I'Ulln·IOS OF CAS ,,s,,,,,, u..'1f Jur Jud. L'tA/.", cle.' ra;ST wn"F.s,n,/J "I DI:;>ll¡ 1::1 £HV.-\L ;lID. "~.I"l::II r :M-:D h!~: ) UF ~.I."1<:::~AL l:SED 6862' - '6882' Squeezed w/200 cu. ft. "G" Cm' "ATE or TeST. H~\:RS ~J:.;S"1'E:D 3:. 1ST ùl' 41'r..CID.tS1:t Core description ;.;\. I I"'r"h)' 1'.rUr)· Ih,,! tbp lurr':"1U1: 1,,11 ..~~;u I. CUIlIIII.t. Bud c:urr~c:t .Ii ù.t.rwlt...ù Ir..1U "Jj &I\'IIiI:lI.'lr r..r:..roJ;;þ;/ Þ _ SImn:I' __~~_M. MC_~~!l_~~r._~~.:..~trTLE ~~~~.!l9'.!,!~~r ____. [>ATI'; -tf,/./C/. 7(-- , -(Su Instructions and Spaces For Additional Data on Reverse Side) ~ . '" ."~"\ J-»', ; STATE OF ALASKA ' ~ ALAS""" OIL AND GAS CONSERVATION COaSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon O· Suspend 0 Operation Shutdown 0 Re-enter suspended well 0 Alter casing 0 Time extension XI Change approved program 0 Plugging 0 Stimulate 0 Pull tubing 0 Amend order 0 Perforate 0 Other 0 2. Name of Operator 5. Datum elevation (OF or KB) Chevron U.S.A. Inc.K.B. 46.4 3. Address 6. Unit or Property name P.O. Box 107839, Anchorage, AK 99510 Ivan River Unit 4. Location of well at surface 7. Well number 14-31 feet 727.62 N, 757.40 W of SE Corner Sec. 1, T13N, R9W, SB&M At top of productive interval N/A At effective depth 1183' N, 2.~' W of Surface Location At total depth 5509' N, 1926' E of Surface Location 11. Present well condition summary Tot~1 depth: measured true vertical 8. Permit number 9. API number 50- ?R~-20041) 10. I?ool N/A 10,958 feet 8,895 feet Plugs (measured) 10958'-10650', 10350'-10100' 9927'-7600', 3508'-3350' (all measured depth) Junk (measured) Drill pipe below 35'14' Effective depth: . measured true vertical 3,350' feet 3,008' feet Casing Structl.lral Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True Vertical depth 20' 421' 30" 20", 94# 950 cu.ft. 20' 421 ' 20' 421' 7018' 7",26#,29# 1189 sack 7018' 5829' measured 6882'-6862' (20') 4-1/2" JHPF Cmt Squeezed. true vertical 5728'-5713' Tubing (size, grade and measured depth) Tubing 2-7/8", N-80 Butt to 92.46' w /Gray Back Pressure valve installed. Installed 8". 5000# blind flange. Packers and SSSV (type and measured depth) - 12.Attachments Description summary of proposal tX Detailed operations program 0 BOP sketch 0 See cover letter. 13. Estimated date for commencing operation 14. If proposal was verbally approved Name of approver . Date approved 15. ( hereby cerhZe foregoing is true and correct to the best ~f my knowledge Signed AI! _ W- Title h17K4 A_ ~rWJ SV/UJ1IT8tiJfJr1" Date 9~tt-8' Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. D Plug integrity 0 BOP Test 0 Location clearance Approved by Form 10-403 Rev 12-1-85 Commissioner by order of the commission Date Submit in triplicate ~ ') 4t.t .. '". -'<"'" ..... ......,....~ _.._~_. .... . . . . .~. , . " ...-- SJRÞAct;::. '.. :','" ,..,":-. ,';:'.' " . C:A~ 1~"J,:fSf..,~~ ::;~: -:', '?:...., '",:" "'.- '" .'" ," .. (143 t) . .~ .... :', .MaY 13 ï 1975 ,. '>-, , ........-. .... ,- "-,..-"'- '..- - -, .,~_. .-. ~ ".. '. _... ...- ... ........' . ---.,- . ""~'''' ~, '. .. -' Dyna-drilled 15" hole' .' 1,406'-1,549' .': .~:.... ': . :. . - .' 75 pcf mud :' .' .' 'u . , :..(' .' '. :", ::.' -. '~ay 14, 1975' ..u···.._. ...::h_: '. ... ., .- '- '. .". ~., . ...- oY~a-~iÙ~'d is."... hà1.e _ , . .'~_".. 1,549'-1,575 '.. Drilled 15" hole .-- 1,5?5'-1,S84C ..: '~. :. ~"-"'" - ~" ";'-, '., u . ., .·,..c.._....._ . -...... --. , . .. (26' ) " , . .-. . . \ (309') '. 75 pcf mud. .. . , . . ::. . 'May 15; '1975 . " Drilled 15" hole . 1,884'-2,075' " (1~1') Circulated and condition~ã mud for 10 3/4" casing., Getti~g 20'':''30' fill each wiper run. ., ,., 1 .' . 75 pcf mud . . 'May '16; 1975 '!W1: 10 3/4", 405# K-55 Buttress casing and landed at' 2,037" Cemented wi th 85e së!ÇJt_S,._9f__'~G"...çeJDent followed by 200 sacks of "G" cément. treated with C?%c:âlcium chlor~~e_.7 Good retµrns. '. . _. _" __.____-~ ~v . 75 pcf mud May 17, 1975 .1 CUt off 20Q and 10 314" casings and installed 12", 3,000 psiS.O.W. casing. head. 75 pcf mud , . May 18; 1975 Installed Class III 12" BOPE. .. 75 pcf mud .- . 'May 19, 1975 Tested BOPE per operating instruction D-17. ,75 pcf múd , 'May' 20, 1975 Iccated top of cement with . ,mud to 74 pcf and ~OO sec. tested 10 3/4" casing with 2,010'-2,047'. 9 7/8" bit at 625'. Circulating and conditioned Drilled out cement 625'-2,010'. Pressure 2,500 psi, ok. Drilled out cement and shoe ' 74 pcf mud . . ~. :,.-.. ! " ~"- . -.-.' -,-,.,.' .-.' ". .;_...;. .. >' .. . " . .', ;:'. :. .. . ._n· .,~. ".: 5. . -' .~ . ~ . .' t":' . Proposal for Dri¡lirig Opel'ation~ ., Drilling Progrüm "". '" ~ . .. ;. .o. --'. 3 . . . '. - - --. ...--"-'-" ~""-"'-"" - .,.-,-.-' .....-. .. '..,. ..- ,~.. .,: ...... ~. ." .;. ",,' . , '" '. '. . '. ....:!. ,.' .,~ . . " . . "', . . 'o. ~ . "í Test BOPE per 0E,erating Instructions ])-17.: . . A. . Ð. . B\ÍFS't' c\n 20"; 94.f/ft, 'H-40 casi~g is' 1'530 psi .without. a~afety . ~actor. Do not exceed 900 psi surfaè~ pressure on test. .,:. , '-", :. ". " ... '.... ,'.. ". . ., Drill out cement and shoe of 20" ca,sing." Drill àhead in' 15" hole to . 7St ~'" '; " 4 .."'>' >. ... .. ., . ......', .,' ~;:, . .. ,,#" Run dynadri11 and 15"' bit ana directiona1Iydrill ahead to 2000' as follows: '. . ". . . Build 2°/100' along course N16°E.. Required'deviat:ion is 5200'. T~get is top of Ivan River 44-1. sand located 500' north and 800' west of the SW corner' of Section. 31, Tl4N,. RSW,: SB &M. Plat will· be furnished. . I· . '1 B. Maintain mud prClperties per the attached prograJV.. Severe hole .prob1em~ ëevelo?cd while directionally drilling well IR 23-12.. The 'section drilled from the surface to 6000' 'is essentially' ,.' gl:avel. . .. . ". A.' .. .. . 7. At 2000' condition holè for 10 3/4" casing. .' .' ,. APPROVED 1 PROG:~AA\ ,10. C. N. ~'~~.IIi~lr . . 8. . . Run 2000' o£ 10 3/4" OD, 40.5#/zoot, K-SS, LSR casing and cement to the surface as follows (have stage collar on location in case lost circulation occurs or·. hole conditions, åictate its use}: A. Use f1oa! shoe and Duplex (stab-in) collar 'one jofW ~i::hJ7tt6rri\ii' i~ .,\' !1\.\ ,'~ '-, u 11 fb 1J: j . . jjÙ').~ .r> Li/ i .r.z." B. Lock Bottom five joints of 1U 3/4" casing. . c. C t 1· . ab h (~'..*.'''': 1', . '.. .. en ~a.~ze cas~ng ove s oe. .', '.....,. ..... ; .:/ ,..,.".... L"' , . _. .. ....,., 1·. ; ,- t.:..... # J ;. '1·'( ¡{"'l" . " r. '. . Run drill pipe and stab into Duplex collar.. Cement throûgh the : Duplex collar with 'sufficient Class '''C'' cement premixed ",ith 2.4~ gel, by weight. of water to reach the surface. Follow the gel . cement \"i th 200 sacJ~s of neat. Total excess is 33%. D. . Basis: Yield Class "G" = 1.15· ft.3¡sack Yield Class "G" + 2~4\ge1by weic¡ht of water.= '1.86 ;t.~/sack E. If cement returns are not received at the surf:ace, do a top job. 9. Cut off 10 3/4" casing 36" below the top of the cellar to allow the top flange of the tubing head to be above ~round level after completion. Install 12"· - 3000 psi 10 3/4" SOi~ c,,"5ing head. Tc~t welded l<1p to 2500 p!:i. t) ..;. >e) ~. " .\..,:,,:::'~..' ~~.'tb-:,:,STr.i.,~.~..~.· ': -.:;.::::> 'Ju1y' 4; '1975'. , . . . , p' êi~~l~ted ~d:~~~J:Ltio~ed 'mud for ce~nt PIU·~S·.· Equalized two cement ·p1ugs 10,9,oQ'- 10,650' and 10,35Ó'-10,100'. Circulated and conditioned _ ' mud. p . Mud frOm the bottom was cement con tamina ted. - . ~ , . . .,~ ';""'., ';'C-, ," July 3, 1975 ,-.~... ,., . - '" .~. ,,~,.-.~,-, Circulated and conditioned mud. . '. ( "0" .. ,-...- ;:-,,-'~"'.':".";:.. -. -_. .--'-.......-.....- ..~., --., , .\ . , July 5, 1975 . " . .- '. .....- ..... . . . .- .' . Built mud volume and circulated and conditioned mud. '., . 'Ju1Y'6,1975 '.., f. . .'. " ,- ," ", . ~"+ .....""- ...~,"" . ".--.-" , "-.,-,,,'.-." . . -','~ '.", . . . . 85 pcf mud· '!. . " ' 85 p~f mud . .;. " .85 pcf mud. . .; . . . 7" . Casing Detail '. , Ran 168 joints of 7" casing. Casi.nq st~k at 7,018' while maki?g connection. . Top . 73 joints 3',064.29 · .' 1.2·6' " .1,166.03' 1.80 . 1,451.74' 1.42', 1,288.44' 1.42' 41.18' " 1.70' 7,019.28' 28 joints'. 35 joints 31 joints.. . .,I 1 joint Bottom· Casing Landed at: 'Julý 7, 1975 ,. 23#8rd N-SO LT&è " x-over 26# Srd N-80 LT&C 'Stage Collar. 26# 8rd N-SO LT&C x-over 29# 8rd N-SO LT&C. Float Collar '29# 8 rd N-80 LT&C Baker Float Shoe 85 pcf mud . PUIl\Ped 40 bbls. caustic Water around shoe and then 40.bbls.. diesel Oil. July 8, 1975 8~ pcf mud Reduced mud weight to -82 pcf and 65 sec. Cemented 7" casing in·2 stages. J 500 sacks "G" cement through shoe at 7 ,01S'. Preceded cement with 35 cu.ft. . Water and displaced with 35 cu. ft. Water and 1,545 cu. ft. mud. Good cir- culation. Opened stage collar at 4,234' and circulated out cement and mud. . Cemented through stage 'collar w£th 689 sacks "G" cement, preceded with 35 cu. ft. Water and displaced with 35 cu. ft. Water and 966 cu. ft. mud. Good circulation. No cement returns to surface. 82 pcf mud " ... .' .Dsr. / " '\) .J LR /2/G- f Z j . ." /219"; ftec.O WOS Ja< ·S;' (Z J l/Vl~T '- J.:" i.';:' De'" " 9' 8~[) "rl ¡,¡. f. ,;"'t,'Yi <- wp./8 ~ :JK:·) :N~·A· ,- . ~VfÌl'I RIlIst¿ /4-8/ Jt $UPPt.t!'ME'A/,or¡:}2/r ftæet71f) "1 DelLl..!/\!;J S,;Pi!'eW~ì(::rV íiZß'ð$I'IT $ífJrL)S J ~, I, ' ïõ¡fiJJ.. ÞePrIl: !ð16S . !1.vSGI!D: /t>9Cfj·J06éO ~}ND /()3ð'() ·/o/()C) . ) ~ I !l,.USGé:tJ Dep¡fI" IO/ð() NOi.E Si M j 9 ';þ " CIl$/N S " ~. II , /()'~:t¡ ~mf/ýíFD I9T 2ô8? I / ) 1'1 ., , / #' " Ii ' I ., it ï STUCK ¡:¡¡ IIJOi9 Å Z9.J N-&::> '7Q1S-5¿Bbi 2G, )N-&J õ'80-~~.,; 23 J IV-go ~8:' 0 , 1 ; f"t.Ot:fT 8fjOS.70Iß) Fl.ôlfi c.OI..(..I9~ 11995) .s7RG..!' C.ElI1eN71.NC], cò(./..;:.jI~ - 128-9 " tk~,é?lìtr¡ Ii STI1Ge / , I9T r¡O}9 1/'1 rINo STI9<l.$ ,q,s rtJtt.OWS,' 111 1]0/'1' ~5¢ í/f/ê(.¡f.)(J17 SJlÓß'¡t INITI1 (!!!9 ó'flC¡($ ç;:: ~i!mß'N'" P'Cg'¡JJI/$O Wlit'! Z./%êEi. B'It.v.e;Sl/i Ó;:· IniXI!'/(/, W/ì.V¡(;;, I' II t:-l.flõIS Q I. Cet7lß',Yi 7" CArS/¡\) B /..J PoOII.D:J O~ t1.EL. ¡¿E:¡J;UI,e¡;:O P£¡¿ tt)8Jc.~ï Ç,':: (')I9TE~ I. If "t..). ¡.:r ô~ Wl}ìS'¡¿ ¡eeQ.IJ¡I¿EfD P£,~ ð'1fC.<, 0lve.eÿ YIEI-O I /,63' t /.,), ¡.':"¡ / $19C.k'j SLURR.'Y W£!i,.~"'" 102 p,,¡::; SL/.)!2/etr V()¿(.,>!ìi$ åJJ.C,{J1..1I7£:D it) /Z,¡¡;¡:.¡cW I STI9{JE' e.OJ./..HE fìT 4234) Sf1$J;D oN CAt..IP~¡¿ i..ÓG W ¡TH No Gyæ6S. . B, STAGE Z íllfê()Vc5l1 STRG£ Cot.J..JW¿ f::;r 1Z34: ()§ìfì¡;V't )/117",1-1 690 SF);J($ o J~ CJ.f.JßS J'G '/ CE/lJßNr Pf:.fff¡;'¡~r'$() f1I:i !1!3()VIf, J'''!-~2(!.,:1 ~'....~/.(.Jm~ CAJ.c,l.Ju)"rEO iD I~ ;; HCN 8()£~fJC£ )/ý /T/1 } No tZ.rCI!3'S .8/9<..~!J oN C/9I./ pE.e. . ./ ~ ..' . 2. L1fN() CRS/N(J. IiNJ) INßil9J.1.. ß()p-=. a. Ví2/Lj. 0(.)7 c£mÛV7 TO VÝ/Th'liŸ 2D I e;¡.: SNtjE. 1. ;2/~ uP I'7NJ) ,r2()/ý Cò /Ni~(?/>·r?r/O;'I¡;J. ¡Vi!vi.eo!l U-m.ð?lï ,ßÒlVlJ toG ,¡:O!!';lf? ,TO." &;,r: C~m¡;Ní To ïflE SU2r"liCð. ,5'Na,.·~I'¡I£e£ 70 W/TN;,5'ó--S. s: í1-:: $,'S$l.,J.e£ TES'" CI96'//l/ð 70 25óO !-'lS; .s()£Ç~ I',(tFa>'(.'Æ'4:!.. w.· .c(,J~7iWi/? /:;JZ"Ç;/,;.'J,QIf,'(¡ 7b ,c{)/./.O(..) I JUL 3 '75 RMM J.l. ;:'''''''1'11:)/." j ., ~)F.: Þ 1/ - . rv. /ì...(C.,,...J....¡,,Æ./~t~.. 7'8'.76 . . ,; E)(H\BIT ID GREAT LAND DIRECTIONAL DRILLING INC. \ REPORT OF SUB·SURFACE DIRECTIONAL SURVEY STANDARD OIL COMPANY COMPANY IVAN RIVER 14-?1 WELL NAME TV AN RTVER FJET,n lOCATION AL571J-D6 JOB NUMBER STNGT,F, SHOrp TYPE SURVEY R-;:>6-75 DATE THIS IS A RECORD OF A SUB·SURFACE SURVEY OF YOUR WELL We have retained a copy of your survey report in our files for your convenience; however, should you so desire, all copies of the survey report will be forwarded to you on written request. All surveys are kept in a locked file and are held in strictest confidence. Additional copies of your survey report can be made from the original by any blueprint company. ... ~~ ~ / COMPLETION REPORT AUGUST 26. 1975 STANDARD OIL CO. OF CALIF. I VAN RIVER ·WELL 14-31 ~AGNETIC SINGLE-SHOT SURVEY DECLINATION 24 DEG. E TANGENTIAL METHOD OF CQt.,¡PUT AT IONS K B ELEV. 45.90 FEET· COMPUTED FOR GREAT LAND DIRECTIONAL DRILLING. INC. BY F.-M. LINDSEY AND ASSOC.· RECORD OF SURVEY ALL CALCULATIONS PERFORMED 8'1' I B M ELECTRONIC COMPUTER . TRUE DOG LEG MEAS. DRIFT VERTICAL SUB DRIFT TOTAL COORDINATES C L 0 S U R E S SEVERITY SEC T ION DEPTH ANGL.E DEPTH SEA' DIREC DI STANCE, ANGLE DEG/100FT DISTANCE D !\1 DEG. D M S 0 0 0 0.00 -45~90 N 0 E 0.00 S 0.00 W 0.00 S 0 0 0 W ,. 0.000 0.00 475 0 0 475.00 429.10 N 0 E 0.00 S. ,0.00 W 0.00 S . ° . ° o w 0.000 .. 0.00 531 '\}) 0 530.98 485.08 N 6 W 1.46 N- 0.07 W 1.46 N 2 59 59 - \'/ 5.357 1.35 571 3 :30 .. 570.91 525.01 N 7 W :3.71 N 0.33 W 3.73 N 5 7 33 W 1.258 3.39 635 :3 30 6:34.79 583.99 N 13 W 7.56 N 1.01 W 7.63 N 7 37 7 W . 0.572 .- 6.80 697 3 30 696.68 650.78 N 10 \V 11.27 N 1.76 W 11.41 N 8 54 19 .~..¡ 0.295 10.05 738 :3 30 7:37.60 691.10 N :3 W 13.76N-- 2.04 W 1 :3 . 91. N-. 8 28 21 W 1.042 12.31 7.66 4 ·30 765.53 719.63 N 2 E 15.71 .N . 2.06 W 15.84 N ·1 29 35·W 3.779 .' 14.15 197 5 30 796.41 750.51 N a E 18.40 N 1.83 W 18.49 N 5d 40 56, W - 3.636 1~6 927 6 30 826.25 780,35 N 4 E 21.52 N 1.50 W 21.57· N :3 59 45 W 3.611,· 1: 2 958 B 0 857.00 811.10 N 4 E 25.42 N - 1.23 W 25.45 N 2 46 16 vJ ·4.839 2 3 ~ q 946 10 0 943.92 898.02 N 2 W 39.19 N 0.99 W 39.20 N 1 26 51 W 2.508 36~~å 1009 10 :30 1004.93 959.03 N 1 W 5 0 . 21 N- 1.27 W 50.23 N 1 27 33 W .0.856 46.98 ~099 12 15 1094.14 1C4S.24 N 1 f. 68.16 N 1.27 W 68.17 N 1 4 30 w 1.971 63.92 l222 16 45 1213.22 1167.32 N :3 E 98.94 N 0.20 W 98.94 N 0 7 6 W 3.681 93.33 131~ 17 30 1 300" 19 1254.29 N 4 E 125.69 N 1.43 Ë 12~.69 N 0 39 8 E 0.885 119.12 1406 1S 30 138'8~ 64 1242.74 N 6 E 154.32N 3.93 E 154.37 N 1 27 39 E 1.264 146.97 1500 20 15 1477.:31 1431.41 N 7 E 185.:30 N 7.46 E 18~.45 N 2 18 26 E 1.895 177.38 .1528 20 15 1503.56 1457.68 N 3 E 194.95 N. d 8.31 E 195.13 N 2 26 27 E 4.944 186.77 1594 21 0 1565.35 1519.45 N 4 W 21~.20 N 8.10 E 216.35 N 2 7 40 E 3.902 208.65 J.719 22 15 1681.55 1635.65 N 4 W 264.16 N 4.89 E 264.20 N 1 3 41 E 1.000 250.97 1811 25 0 1765.8~ 1719.94 N 4 \oJ 300.93 N 2.32 E 300.94 N, 0 26 32 E 2.989 284.84 '1~3 7 29 ';-~1; 1878.11 18:32.21 N :3 W 358.03 N 1.16 W 35-3.03 N 0 11 13 '.¡J 3.195 337.59 " ~'j . ~,). , :"..,\ .") --. SURVEY- S M EL-E-ë:TRON I CCOMPUTER ." ..' _. . I 'RECORD OF ALL CALCULATIONS PERFORMED BY ON . SECT! D.ISTA . ..,.~~_., -.. .~.- DOG_LEG. SEVER ITY_ DEG/100FT. C LOS U RES. STANCE ANGLE. D M S I D TOTAL COORDINATES DRIFT DIREC DEG. SUB SEA TRUE VERTICAL DEPTH DRIFT ANGLE D ~ "lEAS. !)EPTH 422.21 457.92 519.02 _.__ 581 . 59 ., 629 . 11 _669.76 _..721.56 794.07 _879..25 992.96 1109.55 1208.83 1274.89 1349.51 1423._ 1496.~ 157.1.01,.. 1696. 7L~ 1789.50 1881.32 2003.10 2086.43 2161.37 2217.28 2272.59 2363.66 243e.50 2561,03 2720.47 .". ....-....._.- 0, 9. 2 W 1.292 o ~3 l_W 0.946 o 11,,29.I¡J 1.100 _" o _ 16 __ 4_4__W u _______0.5 S:3 ,__ o 20 __,1_ w____.,_ 0.806 ___ o 22. _ 27__W _________1.._623_ 0_ 29 _.,31_.'w_.__._2. 214__.. o 37 51_.W _.___. _ 1.800.._ 040 _ Q_ W 0 . 9 e 6 _ o .49, 14____W..._~ .0.7.57__ 1 :3 9 W ..,,0.363__, 123. 6 W._ ,.. O. 803 1 6 51 W 5.699 0- 37 --5 9--'W- ··---2.126-- o 12. 5 w·" 0.397 0.13_40_E 0.524. o 3730__E 0.000 1 13 20E 0.231 1 39 36_EO~407. 2 5 53 E 0.381_ 2 40 46 E 0.380 3 2 8 E 0.365. :3 27 55_E 1.968 3 51 42 E 2.675 4 14 10.E 0.000 4 51 10 E 0.500 5 19 40 E 1.220 6 2,56 E 2.162 6 53 44 E 0.532 447.69 N 485.15 N 550.47 N 617.17 N 667.82 N 711.15 N 766.71 N 644.50 N 935.30 N 1057.30 N 1183.20 N 1291.87 N 1360.06 N 1435.24 N 1510.25 N 1583.54 N 1658,OB N 1784.54 N 1877.48 N 1969.10 N 2090,74 N 2173.08 N 2246.29 N 2299.94 N 2353.13 N 2440.51 N 2512.52 N 2630.75 N 2765.18 N ,.-.. ._..~."---._.. .-' .---- 447.69 N_ 1.17t4._ 485.74 N 1.84 \¡OJ___ 550.47 "I. 1.84_.W._. 617.16 N 3.00 W 667. aON---·---:3. sa--w--- 711. 13~N ~_=~~.:. 4 .6()(_. 766.68 N 6.58 W 844.45 - N -.~~==~- 9·.30·~-W-· 935.24 N 10.88 W 10S7,19'-N-- 'lS,14dW 1183 ,00 .,. N---'-' 21 . -73"- W 1291.49 N H_,,_ 31,22 YJ 1359. 80 N --. 26 . 45 'N 143 5 . 15- N -- 15.86 - W- 1510.25N- -- 5.30·W 1583.52 N 6.29 E 165 7 .99 N---··-··lB. 09 E 1784.14 N 38.07 E 18 76 . 69 N_____._. 54. 39 E 1967.78 N 72.09 E 2088.45 N 97.74 E 2170.03N11S.08 E 2 242 . 18- N --135, 77 E 2294.72 N 154.~9 E 2346.70 N ·173.·81-E 2431,76 N 206.46 E 2501.66 N 233,30 E 2616.11 N 277.23 E , , 2765.03 N 334.39 E o W 1 W o W 1 W 1 'vI 1 W 2 W 2 W 1 \oJ 2 W 3 W 5 IN 4 1= 8 E 8 E 9 E 9 E 9 E 10 E 11 E 12 E 12 E 16 E 20 E 20 E 21 E 21 E 21 ·E 21 E N N N N N N N N N N N N N N N N N N N N N N N N N N N N N 1945.09 2009.71 2114.30 2220,02 2298.02 2361.66 2437.47 2535.29 2644.47 2784.85 2931.06 3056.34 3142,42 3241,59 3342,22 3441.58 3542.54 371-6 . 73' 3843.74 3969.14 4132.86 4241.55 4340.25 4415.fll 4490.57 4615.97 4713.55 4852.11 5024.68 30 0 1990.99 30 30 2055,'61 31 45 2160.20 32 15 2265,92 33 0 2343.92 34 15 2407.56 36 15 2483.37 38 30 2581.19 39 45 26~0,37 41 0 283.o.}5 40 45 297fre96 41 0 3102.24 38 30 3189.32 37 '30 3287.49 37 0 3388.12 36 45 3487.48 36 45 3588.44 36 15 3762.63 36 30 3889.64 36 30 4015.04 37 0 4178.76 37 30 42.137.45 37 15 4386.15 36 30 4461.71 36 30 4536.47 36 0 4661.87 37 30 4759.45 41 30 4898.01 42 4~5070.58 ~ 2075 2150 2273 2398 2491 256A 2662 -:'7P1 2929 3!15 ? 3"'(1 '3 3474 35P4 ?:709 :S35 ';(959 40 I:¡ 5 4301 44'59 4615 4e?O 49~ì "'::)Pl 51-, .:; '526P 5423 ')546 5731 59f-,6 2) " ... _.~. - ... - --. . £_"... .~ --"'---~'''--'''-'- .'-'·.W.__ _._ ~.,_.__..__ ..._.... '.--.¥ ,.........--. ...-...., SURVEY ~. n·. _ ·_."h... ._. ". RECORD OF ......._- ...,.....-. ......... ".--...,----......-...--...- _.~._.. ALL CALCULATIONS· PERFORMED BY I B M_.El..~CTRON IÇ___ÇOMPUTER ~. .'- ........~»-,~. _... --. _..~_~_w__.__.~_._. .._". ._,,~",_ . .... . - -., . --... , -. ~_._., ..~. .-....-. ~ .-.........-,......-.. . _ _ ". "~' _...~ ,_......_'.~__. n."·· ._~. .- .......,.....-.- --- ,..-.- ,.,.~,- ._"M .-.._... ~-.~ ... ~.._..'" ...... .... '''.. TRUE .. DOG J..E:G ,.. MfAS. D~IFT VERTICAL SUB DRIFT TOTAL COORDINATES C L a s u R E S SEVER! TY._ .SECTION SlEPT,", A"JGLE DEPTH SEA DIREC DIST ANCE ... ANGL.E DEG/100F.T... . DISTAl. D· ~1 DEG. () M S , . ~.'" .... '¡ 60ge 44 0 5165.53 5.119.63 N 22 E 2850.05 N 368.74 _E._ 2873.80.,N,. 7 22,_ 19 ..,E 1.080_.._.._ 28 12 . Ot../ 61~9 44 0 5230,99 5185.09 N 21 E 2909.06 N___... 391.40 E 2935.28 N 7 39" 46 E o . 7 Ó 3_._. 2875.25 6346 45 15 5341.52 5295.62 N 22 C' 3012.44 N 433.17 E 3043.43.N a 10 57 E 0.913__ 2986.62 ... . , _. 64~1 45 0 5436.98 5391.08 N 22 E 3100.95 N 468.93 E 3136.2 LN__.8_. 35_.57... E .,... u_.' 0,185___.._. _ .3081.97 .~. - ..-. .- .--- - .-"-. .. 6668 44 0 5571.50 5525.60 N '22 E 3221.39 N 517.59 E 3262.71N 9 7 n 40 E. 0.535. 3211.73 6950 42 45 5778.57 5732.67 N 23 E 3397.60 N 592.38 E 3448,85 N 9 53 25 .. E 0.506._ .3402.74 7262 41 0 6014.04 596A.14 N 23 E '. 3 58 6 . 02 N____ 672.36 r:: 3648.51 ,_N 10 37 10 E 0.561.,. 3607.00 .- .... 7420 40 45 6133.74 6087.84 N 23 E 3680,95 N 712.66 E 3749.31 N 10 57 26 E 0.158 3709.92 7609 39 30 6279.58 6233.69 N 22 E 3792.42 N 757.69 E 3867.37 N 11 17 54 E 0.744 3830.0U '1732 35 45 6379.40 6333.50 N 30 E 3854.65 N 793.63 E 3935.51 N 11 38 2 E .. 5.001 3900.61 .' 78PQ 35 30 6507.22 6461.32 N 30 E 3933.61 N 839.21 E 4022.13 N 12 2 35 E 0.~59 39S'u.1ß ~o~ 2 36 30 6654.32 6608.42 N :31 E 4026.91 N 895.27 E 4125.23 N 12 32 3 E 0.634 4096.76 8176 36 30 6737.92 6692.02 N 31 E 4079.94 N 927.13 E 4183.96 N 12 48 9 E 0.000 4157.33 ,-- ~~--- ._- e395 34 45 6917.86 6871.96 N 31 E 4186.94 N 991.43 E 4302.72 . ' N 13 .19 18 E 0.799 4279,55 85(,4 34 15 7057.56 7011.66 N 32 E 4267.60 N 1041.83 E 4392.93 N 13 .. 43 8 'E 0.447 4372. Øf,63 34 30 7139.15 7093.25 N '32 E 4315.15 N 1071.54 E 4446.21 N 13 56 44 E ..0.253._... _ 4427. .. .' --.--. Ø757 34 0 7217.07 7171.17 N 33 E 4359.24 N 1100.17 E 4495.93 N 14 9 51 E 0.801 4478.G ee40 37 0 7283.36 7237.46 N 34 E 4400.65 N 1128.10 E 4542.94 N 14 22 41 E 3.681 4526.40 P.933 3P 30 7356.14 7310.24 N 32 E 4449.75 N 1158.78 E 4598.16 N 14 35 .' 47 E 2'.082 4582.87 ,., 90")R 40 15 7451.55 7405.65 N 32 E 4518.24 N 1201.58 E 4675.29 N 14 53 33 E 1.400 4661.65 C)400 42 30 7703.70 7657.PO N 33 E 4712.02 N 1327.42 E 4895.42 N 15 43 59 E 0.686 4886.10 °613 43 0 7859.48 781:3.58 N 34 E 4832.45 N .1408.65, E 503:3.57 N 16 15 5 E 0.396 5026.59 o'¡:;41 4'; 0 8022.11 7976.21 N 36 E 4964.02 N 1504.25 E 5186.93. N 16 51 30 E 1.059 51e2.34 lO374 41 15 8421.34 8375.44 N 37 E 5243.63 N 1714.95 E 5516.95. N 18 6 38 E 0.718 5515.82 lC6f.6 3"1 30 8653.00 8607,10 N 38 E 5383.71 N 1824.39 E 5 6 8 4 . i+ :3 N 18 43 12 E 1.302 5684.17 lO95? 3~ 45 e?95.79 8?49.A9 N 39 E 5509.78 N 1926.48 E 5836087 N 19 16 19 E 1.300 5836.87 qOTTO'~OU: CLOSURE 5836. : 7 FEET, AT N 19 16 19 E '~f ~ ''<!~ - . INTERPOLATED TRUE VERTICAL DEPTHS. COORDINATES AND CLOSURES FOR GIVEN DEPTHS CODE NA"'1E ',', ?' .'~~' ~.-.."~._-~-_.._..._- ~.__. .,-.'- MEASURED- DEPTH -..-...., -""~-'_.'-""'" .,.,......~ .---.....- . -... -~ ..._-..._, .'. ...... -_._-,. -- .. ..._..~-~.-., - _,..... 'H_.,,- ..... <i:ti.:ò. -:Çv TRUE VERTICAL DEPTH TOTAL _. . -,.-.--....,'....., , .. . _ ... ·w·_,_·~... ,_~.,_~...._ _,_. ......,_...._~, ',__., ...~.,__.._ ~ -'-'--'-"~"- .... COO R.DI N A.r 1; S _ _,_.__ _ ._ C LOS U R E DISTANCE ANG~E D ,M 5 ....._. -._. - ~¥,. . - -~.' --_._.,._-,~.,._- .-., ..- ","---.-. ..-.....-. - ,.._-_._._.-~-", . _.._"__"H'" ..~_._._ . "..--, ., ---",¥' "'--"'~ - "..,..-..-------.--... ~- ~. '~-'--"'. .'-'~" -.-.-... .' . .- ",... ".,,-- .. .,...---....--.. '.-.-.". .---.- ,. . . . ,- .~.._....,...'" . -...- _.. . .-. .-,-..-.... .' -.-.. . ..--. .._.~~...-_.._. +.....~_..._....... ..._. ... ..+-...~..+, _. .~-_.... ..~...._......-.~. ...... .-_..-..._.---- .~._+ -.....----.-.--..- . .- .~. .....~. - ....-. -- -~ -.'-- -~._- .... ....-"' "....-...._,.. ,,~.. .' .··_._~____~."w_·",,__.__~.·. _ ._. ,...n.n' ... .. " '. - - _~ ..._,u. .. - -.- ...-~-...". " .. ~'. ~ "....~. '.. ..-.. ., -.-. .... '''-'-.'' -, -- ~-. - ..-. ...---. SUB ____ ___ _ .SEA..,. _.__ ___ .'- '.._-~-.'_.' ..-......--.....-- .. -- _.. ._~. H." .W· .".. .. '" __" ~..._. _ . .~ .. -..¥ .-_. . ,,--,.-. ._, ... ..... ._.._...~~.~_... ·,'_.......··~_·W..__·._.._... ............-._..._·h .~_. . .-,_...." --.... _. - .-...... "_ _..'_.'__'~" '. '."n.¥ _...._. ......_"...__ .. .'-,.,-_.. -- --- .. ...---. ... -.... ---- ...-".- .-¿ 7 .. . .'. ".~ . ~.~....... . .... ,_. '.. .h_'·_"_". . ~.,_...,~_...__..,~.__.._.~~_ ..__ .... .'...........~- .--"......- .~_..<-_."._. - _.... .._'......~.._- ...--.-.... _......_._-. .__...__~ _.h._ ...,.. ...u. ... ._____ _. _",,~ ,.. _ _.._... ._.....~._, .....--..., .-.'-. -..., .,- __"" _....__,.__ ·_~_~"_~_M··· _.. .. "-"".'-- "'-' "...-..-.. -...' ..'-.-. .... .~.. .... ~ ~ ~ - , .- MFA~W~ED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. Q,-. _ .-.,. .~- . -.~".. ._.'~ ...-....- .-..----_._-.. . '.., TRUE - .._.~ '.-' ..--_. _. . . h.__...__...... ....___..._ m S .....---...- _.u..._ .. -. ---.._..~. -.. .~"- . '_"__'_"___'W_"_' .. ~F.ASURED VERTICAL SUB MD-TVD VERTICAL >_..... _.._w~._¥_._.___~ ...~... . ..-_... ~,,--~-., ---...--.-.' DEPTH DEPTH SEA DIFFERENCE . CORRECTION. .. TOTAL COORDINATES . .... .~-_..- -.. .. '"..~ ... ....-.-..-- . -.." ..-_... n .'~'.¥.. ._.. ..' ·-·"---T45' ~_._. ..~--.._. .~.~_..--. .. _ ~""W_' " .~- 146 100. 0 0 0.00 S 0.00 W .. 246 245. 200. 0 ·0 0.00 S 0.00 W 346 345. 300. 0 0 0.00 S 0.00 W . . A._~ 4. '''... .'_' 400. -.' ......... .h.·.__~.... ""'-' "._.. 446 445. 0 0 0.00 S 0.00 \.J 546 545. 500. 0 0 3.8? N 0.41 W 646 645. 600. 0 0 9.81 N 1.60 W 745. 0 ._.w_~~... .,. ~ _~.._.__ 746 700. 0 16.03 N 2.24 W 847 845. aoo. 1 1 26.67 N 1.35 \ý 948 945. 900. :3 2 43.92 N 1.78 W 1050 ---·'-1045. Q-1000. 5 ----" --_... ...-.-'-' ...... 63.77 N 1.81 \~ 2 1154 1145. 1100. 8 3 89.B6 N 0.80 W 1258 1245. 1200. 13 .. 5 120.40 N 0.98 E ... .._,....~ .... - 1364 1345. 1300. 18 . ---~. 5 ~_._--'"- 152.73 N 3.80 E 1470 1445. 1400. 24 . ~.. - ..-. 6 .,.~-_..--~- 188.00 N 7.89 E 1577 1545. 1500. 31 7 . . 225.44 N 8.47 E 1684 . ..-~. ... "'~"~'-- 1645. 1600. 39 - ...~.- -- s----- ..-_...--,_............ -..-..... 265.84 N 5.64 E 1794 1745. 1700. 48 ......... -~~. --.., - 310.53 N. 2.52 E 9 ... 1908 1845. 1800. 6¿ 14 364.52 N 0.43 W --- .--.--.".. ...-_.~. ..... ----IS --.-_..,~ ".-.'.þ-'.. _.~._...-."-- --- ~......~...._. ...... * .,.-.'-' 2023 1945-, 1900. 77 421,.65 N 1.17 \v .-. 2139 204~. 2000. 93 16 480.02 N 1.74 w' ,.. 2145. 110 N 2256 2100. 17 541.62 1.84 W ~-..~.__. .~ --.. .-- . 2374 2245. 2200. 128 18 604.53 N 2.78 W 2493 234,5 . 2300. 147 19 669.15 N 3.91 W 2616 2445. 2400. 170 23 739.22 N 5.62 W 2742 2545. 2500. 196 26 816.39 N 8.32 \1 2871 2645. 2600. 225 29 898.25 N 10.23 W 3003 2745. 2700. 257 32 983.47 N 12.56 W 3135 2845. 2 B 0,0 . 289 32 1070.22 N 15.82 W 3267 2945'\ 2900. 321 32 115'6.2ì N 20 ..3 :3 W 3,99 3045. 3000. 353 32 1242.70 N 26.96 W 3530 3145. 3100. 384 31 1326.13 N 28.80 vi ;~57 3245. 3200. 411 27 1403.55 N 20.30 W -:;~82 3345. 3300. 436 25 1478.74 N 9.73 W 'j~90 7 3445. 3400. 461 25 ,. . 1552.86 N 1.43 E .. .."£. . N 403'2 3545. :3500. 486 25 1626.61 13.12 E . . ~ ....__. .", -"'" .. -.'._-~ -.' "....-.. ~EASU~ED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET-OF SUB SEA DEPTH. -.-.- -..-. -. .~ - -. --.. h._ '.. 6 ~_. ,_.." _.....,.~_.- ,--- .----'.... -_.,,----~_._. ...,----,..-. ..... -" .' .-.~.~. -..- .,.... ....-. . _....- .. -- '"---"~ '. .....- ...._--~ ..., ..... .... ..n..... .,._..._."__" .... _...__...... ....._. _',h ...._._. TRUE --- .'-,-" '. . ".-...'--'-"-- -.....-.- MEASU~ED VERTICAL SUB MD-TVD VERTICAL -.. ' -, .-' .....-...., .~-_..._...-'..-.... .' ...' . -.. DEPTH DEPTH SFA DIFFERENCE CORR~CTION ____J QT .A. 1.._ COORDINATES -.-.... - .-........_..,_... - . -. ... .- ~.... .. ... 4156 3645. 3600. 510 24 1699.60 N 24.68 E ..... ----.. ._.~...-. 4?8,0 3745 ') 3 7'00 . 534 24 1772.02 N 36.15 E 4405 3845. 38,00, 559 25 1844.81 N .. 48.77 E ....- ..-.....---. -..-. .._" _... ..- '-.._-..~ . -.... -- ..~-."..,.,-,..... . 4529 3945. 3900. 583 24 1917.55 N 62_. :3 3 . E .... ~ 4654 4045. 4000. 608 25 1990.52 N 76.93 E 4779 4145. 4100. 633 .__._. ..... h,.._....·. 25 - "- -_._._-_. 2064.23 N 92.59 f 4905 4245. 4200. 659 26 2138.84 N 108.45 E 5030 4345. 4300. 685 26 2212.75 N 127.33_ E 5155 4445. 4400. 709 24 2283.72 N 150..89 E -'." ...------. . . ..- .---- .--'-'.--'" '-'-' ....".. "---'~"-'- 5280 4545. 4500. 734 25 2353.09 N 176.27 E 5403 4645. 4600. 757 23 2420.92 N 202.30 c ... --, 5529 4745. 4700. 783 26 2491.95 N -. 229.57 E 5661 4A45. 4600. 816 33 2573.06 N 260.70 E ,. 5796 4945. 4900. 850 34 2657.4,3 N 293.09 E 5932 5045. 5000. 886 36 . "-'.-' .----....' ,-..-.--,. 2743.73 N ,.326.22 .- E "'+,.-..- ~'~-"--' .. . _. _".__._._.._...A_,. ___._.~_______, 'W'_~" .__._ 6071 5145. 5100. 925 39 2832.47 N 361.64 E 6210 5245. 5200. 964 39 2923.00 N 397.03 E 6352 5345. 5300. J.006 42 3016.50 N 434.80 c .. ,., .. ... .~..._,- ~.- ~ -'-- -.. 6493 -..,---.----- 5445. 5400. 1047 -- 41 3108.93 N 472.15 E 6632 5545. 5500. 1087 40 3198.47 N 508.33 .. E' . 6769 5645. 5600. 1123 36 3284.70 N 544.46 E 6905 ,. "~'-'--'''''- 5745. 5700. 1160 37 3369.79 N 580.58 E 7039 584'5. 5800. 1193 33 3451.47 N 615.25 E 717'2 5945. SqOO. 1226 33 3531.49 N 649.21 E . -..~---_..,. 1258 '"".-'"''..-''' N 683.08 .. E 7304 6045. 6000. 32 3611.28 7436 6145. 6100. 1290 32 3690.2'+ N 716.41 E 7565 6245. 6200. 1319 29 3766.68 N 747.29 E 7691 63.45. 6300. 1345 26 3833.77 N 781.57 E 7824 6445. 6400. 1368 23 3895.73 N 817.34 E 7937 6545. 6500. 1391 23 3958.14 N 853.95 E 8062 6645. 6600. 1416 25 4021.57 N 892.06 E e 186 6745. 6700. 1440 24 4084.68 N 929.98 E ~~ 8307 6845. 6800. 1462 22 4144.1lf N 965.71 E H429 6945. 6900. 1483 21 ., 4203.13 N 1001.54 E 8550 7045. 7000. 1504 21 4260.87 N 1037.62 E ...- - .." _.-...., - ~EASU~F~ DEPTH AND OTHER DATA FOR EVERY. EVEN 100 FEET OF SUB SEA DEPTH. ,"w1EASURED DEP TH 86:'71 8793 8920 9051 9186 9322 9458 9594 9735 9875 10008 10141 10274 10405 10531 10657 ~ 1> ~,,~~ "'ò....,b v_ Çt_..... _....__. __ ... __. TRUE VERTICAL SUB MD-TVD' DEPTH SEA DIFFERENCE 7145 . 7245. 7345. "'-7445. 7545. 7645. 7745. 7845. 7945. n'" .,-- 8045. .. ., ,-., 8 145 . 8245. 8345. 8445. 8545. -'-- 8645. -.._.-*-."-~.~. ..'^,-..,.. . >'._.-."--_.._---..._~--.~_. -.._...--,--~._---_.~- .. ~,.._..._~*._-,------- .,..~-_.._., 7100. 7200. 7300. 7400. 7500. 7600. 7700. 7800. 7900. 8000. 8100. e200. 8300. 8400. 8500. 8600. 1525' 1547 1574 1605 1640 1676 1712 " 1749 1789 '1829 ___..'___u._"_ 1862 1895 1928 1959 1985 2011 .. _.~,.'_ _._~.'_, ..,.. H VERTICAL h"'_"_"'_'_"__'-_ CORRECTION TOTAL COORDINATES n,-.- -.~--~:·7:",.. _.."~..,,-----~.. ~ 2 f-····---------· 4 3 Ie . 97 N ._-~- ~. . -. -_..._._- .. 22 4377.24 N 27 4442.83 N ._-..--_._-,--,..,~--..'- 31 4514.18 N ...~"....""_ ._.___... n... _. _ 35 4590.74 N ~'--"'-""'''-''-'' . 36 4667.59 N __.__ .__. ...____.,_. ·h. 364744.64 N - 37 4821.95 N 40 4902.36 N _....n____.__M.· .._'__' 40 4980.68 N ------_..... _. ...--.- .. 33 5050.72 N 33 5120.76 N ._~..__. .__.,,,._.._,..~_. _w.~·_~··_·'~..__... 33 5190.79 N 3f- 5258.48 N 2~' . 5318.95 N 26 5379.41 N .~ -. ..- ~.. ,- . . -. ."... ..._-- _. .. n·....·._.·· . .~. .._~~.-, -'..» . ~,.~....._- -"-~-'-"-""- - ~...- ...~~ -~"'''''' ~.. . .-. ..-.... 1014.02.E 1112.32 E 1154.46 E 1199.05 E 1248.67 E 1298.58 E 1349.43.E _ _.'''__ .".... 1401,57 E 1459.45 E._.___. _. ___......_._.,.. ..", 1516 , 8 0 '. _E _., _____.___,...___.. ,.,._ 1569. 58 E ,_ _ " .___ _.._..__.._____ 1622.36_ E.._ _______.._.._..._... .._. . __, ,. 1675,13 E___,..,. 1726.55 E 1773.79 E 1821.04 E , .- .."..... ..- ""-" . ....___~,_.'~w_._. ,...'. -, '·_.__"·M~·"··""_ ~ ..... .--_... . .-.-,- . - --._.. ...-- '. --, .,._--*. - . .. ·<__,,'__w __,...~.~_ ..., ..~......-..- '.. '*,"- "-'''-''-''''._-''.~- -_.-._-.....-_. ~- .,-'-,"". "-,' ..... .'·~'·~'~h____·__ .#_'~__'_.__'" . . H.'. ...._. ..._.. . ~~'-'-"--"-""'-' ..._~.. _... .... __.__n .._. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH.___ " . ............_.. .... __. . ...~.·,__.__,,__.n_,,_~..__¥_. . v1EASURED DEPTH TRUE 'VERTICAL DEPTH TOTAL COORD-INATE-S - -q ..- . ....- -~ ... -.- - SUB SEA ...... .....-. .".. ~ ~...- --...-....,....-..... 1000 996. 950. 53.31 N 1.94 W 2000 1926. 18BO. 41 0 . 19 N .-- 1.17 W 3000 .---.. -...._._--~-_._.- 2743. 2698. 981.79 N .~..,._.-.- ._._- 12.51 .'O- W 4000 3520. 3474. 1607.75 N 10.13 E 5000 4321. 4275. 2195.05 N 122~26 E 6000 ----------·---5095 ~.m 5049. 2786.93--N--------·343-.'24 E 7000 5816. 5770. 3427.79 N ..-. 605.20 E 8000 q 6596. 6550. 3990.20 N 873.22 E 9000 . -~."-" ._-._..- 7407. 7361. 4486.46 N 1181.72 E 10000 8140. 8094. 5046.69 N 1566.55 E ...... .-.......-.----... . .,~.....- -. ..-.-. -'. -- --_..- .-.-.....~.. -....--. ...-_...-._.._-_......~. .-.,...--............-.....,- ... ^.....p._-~._- ...._......- ,_..'".. .--.. - -. ......,..~-_....-..... 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Waste Sources, Types and Volumes 20 AAC 25.252 (c) 7 Resource Conservation Recovery Act (RCRA) exempt Class II wastes will be injected in the disposal well. This will include drilling muds and cuttings, produced water not usable for enhanced recovery, and a class of waste termed "other associated waste". Other associated wastes specifically includes waste materials intrinsically derived from primary field operations associated with the exploration, development, or production of crude oil and natural gas. "Intrinsically derived from primary field operations" is intended to distinguish exploration, development, and production activities from transportation and manufacturing. With respect to crude oil, primary field operations include activities occurring at or near the wellhead and before the point where the oil is transferred from an individual field facility or a centrally located facility to a carrier for transport to a refinery or a refiner. It also includes the primary, secondary and tertiary production operations. Crude oil processing, such as water separation, de-emulsifying, degassing, and storage at tank batteries associated with a specific well or wells, are examples of primary field operations. In general, the exempt status of an exploration and production waste depends on how the material was used or generated as waste, not necessarily whether the material is hazardous or toxic. The following tabulation lists examples of exempt oil and gas wastes included in EPA publication 530-K-95-003 (May 1995). Crude Oil and Natural Gas Exploration and Production Wastes: Exemption from RCRA Subtitle C Regulations. . . Examples of Exempt Oil and Gas Wastes drilling fluids and cuttings, including well completion, treatment, and stimulation fluids, excess cement slurries, and cement cuttings drilling fluids and cuttings from offshore operations disposed of onshore produced water and constituents removed from produced water before it is injected or otherwise disposed of accumulated materials such as hydrocarbons, solids, sand, and emulsion from production separators, fluid treating vessels, and production impoundments pit sludges and tank bottoms from storage or disposal of product or exempt wastes produced sand workover fluids and packer fluids well stimulation acids and chemicals cooling tower blowdown dehydration wastes, including glycol-based compounds, glycol filters, filter media, backwash, and molecular sieves gases removed from the production stream, such as hydrogen sulfide, carbon dioxide, and volatilized hydrocarbons iron sulfide light organics volatilized from exempt wastes in reserve pits, impoundments, or production equipment. liquid hydrocarbons removed from the production stream but not from oil refming materials ejected from a producing well during the process known as blowdown naturally occurring radioactive materials (NORM) in pipe scale pigging wastes from gathering lines pipe scale, hydrocarbon solids, hydrates, and other deposits removed from piping and equipment prior to transportation production line hydrates/preserving fluids utilizing produced water rigwash soil containing downhole hydrocarbons, crude, or produced water spent filters, filter media, and backwash (assuming the filter itself is not hazardous and the residue in it is from an exempt waste stream) sweetening wastes, including catalyst, filters, filter media, backwash, precipitated amine sludge, iron sponge, and hydrogen sulfide scrubber liquid and sludge waste crude oil from primary field operations and production wastes from subsurface gas storage and retrieval, except for listed non-exempt wastes . . The following wastes are the major components of the injection stream. A short paragraph discusses the source and characteristics of each. They are divided into two major categories: Wastes requiring little or no grinding prior to injection and injectable wastes requiring grinding prior to injection. Wastes Requiring little or no Grinding or Slurrification: 1. Drilling Muds, Water-Based: Spent drilling muds have been used for cooling and flushing of cuttings during the drilling of wells. The muds consist of water, clay (usually bentonite), cuttings which include soil and rock fragments and small amounts of dissolved chemicals which enhance certain properties of the mud. The mud is typically dark gray in color, viscous and lacks a distinctive odor. The mud may carry a significant amount of solids. Muds are denser than water and may contain barium compounds. Spent drilling mud is used to suspend solids during the grinding and injection disposal process. 2. Drilling Muds, Oil-Based: Oil based drilling muds are used for cooling and for the flushing of cuttings during the well drilling process. Oil based mud is typically a mixture of a hydrocarbon fluid (usually mineral oil or diesel), clay or asphalt, some water, cuttings which will include soil and rock fragments and dissolved chemicals which enhance certain properties of the mud. The mud is dark gray in color, viscous and may carry a significant amount of solids. The odor is characterized by the hydrocarbon fluid. Drilling muds are denser than water and may contain significant amounts of barium compounds. 3. Workover Fluids: Workover fluids are wastes from the maintenance of a hydrocarbon production well. The fluid may contain small amounts of chemicals, crude oil and solids; however, the fluid is predominantly water. The workover fluids are about neutral in pH. 4. Stimulation Fluid: Stimulation fluids are chemical compounds which have been designed to enhance the productivity or the injectivity of a well. They are injected into producing or injection zones. The fluid is normally acidic and may contain various chemicals to enhance its properties. The fluid is usually non-viscous, low in pH and has a pale color except for the soil contaminants which will sometimes be present. 5. Clean-Up Fluids: Clean-up fluids, or washwaters, are predominantly water which has been contaminated in the process of washdown of an area, engine, etc. The fluid is normally turbid, has a moderate pH, contains some amount of hydrocarbon material and has a density very close to water. . . 6. Crude Oil: Contaminated crude oil is generated during spills of crude oil or as a waste :trom a well workover. The contaminants in the crude oil are normally water and some amounts of soil. Crude oil is basically a blend of many types of hydrocarbons with some impurities. It is black in color, somewhat acidic, viscous and has an odor somewhat like refined motor oil. It may contain nitrogen and sulfur compounds, salts and trace metals. 7. Diesel: Diesel fuel wastes are generated from a variety of sources by workers who use diesel as a workover fluid or as a :treeze prevention fluid. The diesel will normally be contaminated with small amounts of chemicals or water. It will be pale in color, fluid, near neutral in pH and have a characteristic hydrocarbon odor. 8. Annulus Pack: Annulus Pack is often a proprietary product which can consist of diesel with some gel additives. It is used to prevent freezing of well facilities which are exposed to cold weather. It will be disposed as a result of contamination by water, soil, or hydrocarbons, or as a result of a well workover. It is pale in color, moderate in pH, fluid and has a characteristic hydrocarbon odor. 9. Spent Acid: Acids are used widely as a well stimulation fluid. They will be characterized by low pH and sometimes will have a biting odor. The acids will normally be fluid with moderate to low reactivity 10. Glycol: Glycol is an alcohol which is widely used in circulating fluid systems to prevent freezing. It will be disposed of when contaminated with water, hydrocarbons or solids. Glycol is pale in color, denser than water, moderate in pH, fluid and has a characteristic hydrocarbon odor. 11. Methanol: Methanol is a light alcohol which is widely used as a rreeze prevention fluid. It is often used in combination with other materials, such as glycol, and will often be a contaminant in wastes of other characteristics. Methanol is a pale fluid which is less dense than water, has a somewhat low pH and has a distinctive chemical odor. 12. Production Chemicals: This broad category includes chemicals used in the production or transportation of crude oil to achieve certain desirable effects. Examples are corrosion inhibitors, emulsion breakers and foam suppressants. Other production chemicals include proprietary compounds used in drilling fluids, muds and cleaning products. . . 13. Source Water: This is subsurface water, frequently saline, produced for the purpose of reinjection into a hydrocarbon reservoir and/or for making drilling mud. It can have a high dissolved solids content and is frequently useful only for industrial purposes. The specific gravity can range from 1.0 to 1.034. This water is not considered a waste and is required for the normal operation of a grinding system, mud slurry make-up water, and well flushing to minimize the risk of solids plugging the perforations. 14. Miscellaneous Waters: This includes produced water from production wells and sometimes sea water. These wastes may contain small amounts of contaminates and significant amounts of salt and dissolved solids. These waters will be clear in color, of moderate pH, fluid, lacking in characteristic odor and will be near or slightly above the density of pure laboratory water. 15. Boiler Blowdown Water: This is fresh water used in boilers, typically to make steam for drilling rigs. It is collected when the boiler is taken out of service for some reason. It will not be contaminated but will have some amount of cations/anion concentration reflective of the initial fresh water source. The volume will be small. Wastes Requiring Grinding Prior to Injection 16. Drill Cuttings: Drill cuttings are generated when the drill bit penetrates the rock fonnation. Drill cuttings are circulated to the surface with the drilling mud and are separated from the liquid mud with the use of a "shale shaker". Cuttings can be composed of sand, gravel, clay, shale, hydrocarbon bearing rock or other naturally occurring formation solids and are denser than water. Residual mud (water or oil base) can remain on the cuttings following the shale shaker. Water base mud is typically used to suspend cuttings during transport from the point of generation to the grinding and injection facility if it is not located adjacent to the drilling rig. Mud is also required to maintain suspension of solids during processing through the grinding and injection circuit. > 17. Frac Sand: Certain well stimulations utilize propp ant or "frac sand" to fill the producing formation fracture space created during a well stimulation. The stimulation objective involves keeping the frac sand in the formation fracture to increase well productivity. At the well head, "loose" frac sand can be backflowed to the surface as part ofthe frac job or later as part of a well clean-out. Frac sand can be transported from down hole to production facility separation vessels, where it will accumulate until removed during a vessel clean-out. In addition, small quantities of frac sand can be found in flow line pigging material. Frac sand is an . . inert ceramic material, and as a waste it is commonly accompanied with crude oil, fresh or sea water, fonnation solids, small amounts of chemicals and spent acid. Carbo-Lite is a common propp ant used on the North Slope and is composed primarily of aluminum oxide and silicon oxide. As with drill cuttings, transportation to and processing of frac sand at the grinding and injection facility requires the use of mud to maintain solids in suspension. 18. Vessel Sludge/Sand: Fine solids particles from the oil producing formation, biomass, pipe scale, or frac sand can accumulate in test separators, tanks, production facility vessels, and heat exchangers. These solids are periodically removed and can be associated with crude oil, fresh or sea water, and production chemicals or solvents. The solids are denser than water, have a distinctive hydrocarbon odor, and usually assume the dark brown or black color of crude. Mud can be used to transport vessel solids to the grinding and injection facility and would be required to suspend solids during processing. 19. Contaminated Gravel: Contaminated gravel is the result of spills associated with various oil field operations. The major source of gravel contamination is caused by fuel and crude spills; however, spills of the other injectable wastes can be the source of gravel contamination. The characteristics of the contaminated gravel will be dependent on the source and concentration of spilled material in the gravel. Gravel that is not readily treatable for reuse can be disposed of by grinding and injection. Pre-crushing of the gravel may be required before it enters the ball mill grinding process, and the addition of mud would be required to suspend the solids through the grinding process. 20. Line Pigging Màterial: Crude oil pipelines and produced water or sea water pipelines require pigging to remove materials which have built up on the pipe walls. Normally the pigging waste is pushed through the pipelines back to the production facilities and is deposited in facility vessels where it is later removed as vessel sludge/sand. Occasionally pigging waste will be removed directly from the pipelines at certain locations. The pigging waste composition can include crude, produced or sea water, biomass, paraffm, formation solids, frac sand, calcium scale, and iron sulfide. Pigging waste has a density greater than water, can be a thick viscous sludge, and typically has a very strong hydrocarbon or rotten egg odor. 21. Naturally Occurring Radioactive Material (NORM): NORM is a weakly radioactive natural material which sometimes forms as pipe scale or sludge in production pipelines, tubing, and separation vessels. This material has been approved for injection in Class II disposal wells in Alaska by the state agencies and the EP A. The material is below activity levels of concern by the NRC. The EP A ~ . . UIC office has specifically referred to this material as "pipe scale" or "vessel sediments" which are cited in UIC regulations as material which can be injected in Class II wells. The material is typically found as barium sulfate scale with some radium 226 or 228 co-precipitating with barium to provide radiation levels of 1 to 2 millirems per hour. Compatibility With Injection Zone The wastes to be injected at this site are typical of numerous exempt waste streams injected in other similar disposal formations. The injection zone is of typical lithology, being composed of conglomertic gravels, inert quartz, and clay matrix materials. The resident aquifer with a salinity of 6000 - 9000 ppm NaCI will mix with the wastes without reaction. There is no reason to suspect a compatibility problem between the injected materials and the receiving formation. W aste Volumes It is anticipated that the upcoming three well workover/drilling program might generate 20,000 to 30,000 barrels of waste. Ongoing disposal of produced water associated with production ITom the gas wells might generate +1- 100,000 barrels of fluid with a salinity ranging from 6,000 - 18,000 ppm NaCl.. A maximum disposal condition might involve 200,000 barrels that would need to be injected over the life of this disposal site. Injection Rates The disposal pump will probably operate at 2.5 BPM. During rig activity a typical daily disposal rate might average 1000 barrels per day. After completion of well activities, the ongoing disposal of produced water should be in the range of 100 barrels per day. . Injection Pressures 20 AAC 25.252 (c) 8 . Injection pressure is estimated to average 2800 psi while injecting either mud or slurried cuttings because the densities and other properties willbe similar. This should also be a reasonable pressure to expect when injecting produced water and other clear fluids because of the decrease in hydrostatic gradient relative to the mud. This pressure is above the fracture gradient and the flow mechanism will involve fractures in some form.. A maximum pressure of 3300 psi could be reached int~rmittent1y should sporadic plugging of the perforations, or gradual plugging ofthe fracture flow channels occur due to settling or packing of solids. Pressures obtained from leak off tests on three adjacent wells yielded an average breakdown gradient of 1.0 psilfoot at this depth. Subsequent annular injections at this depth on other Ivan River wells averaged 2650 +1- psi, with some excursions to 2900. With an injection rate of2.5 BPM, fì'Ìctionallosses in the tubing should push the average disposal pressure to 2800 psi. ., . . Waste Confinement . 20 AAC 25.252 (c) 9 Injection of drilling mud and slurried cuttings will require pressures greater than the breakdown pressure. Initially a single planar vertical fracture should develop. This primary fracture can be expected to gradually plug with solids and also experience tip screen out. As the local stress regime is altered, appendages can develop, creating a vertical fracture system of some oblique fashion. The dimensions of the fracture domain will depend upon the amount of mud/cuttings injected and the rock properties controlling storage mechanics. The development of multiple fractures will have the effect of minimizing the lateral, and to some extent, the vertical growth of a primary fracture plane. Simulation modeling was performed to determine the maximum dimension that could be developed by a single planer vertical fracture. Five field cases were run, all with reservoir rock properties that generate maximum fracture dimensions for the fluid being injected. (Example: Sandy intervals are estimated to have penneabilities ranging from 10- 1000 millidarcy, with an average between 400-600. All modeled sand intervals were specified to have a tight rock permeability of 10 md.). In all cases the injection rate was 2.5 BPM. Volumes pumped ranged from 14,000 barrels to 1,500 barrels in a single cycle. The cases are summarized in the following table and the simulation details are included in Exhibit 11. Case lA approximates a situation where 14,000 barrels of drilling mud was stored and injected in one cycle. Cases 2A-4A represent what more likely would occur in the field; however, even these cases are overstated because typically one injection cycle involves about 1000 barrels, with an average shut-in time of2-3 days before the next injection. Case 5A is a simulation/modeling verification run that duplicates a very large, designed fracture treatment, using a gelled carrier fluid and propp ant. Case 6A represents still more closely what might occur during a single injection cycle. It injects 1,500 barrels of drilling mud; however, the fluid density was held at 10.3 #/gallon, which is itself excessive and would not occur at this volume. . . FRACTURE SIMULATION-IVAN RIVER FIELD CONDmONS MODEL APPROXIMATIONS MODEL RESULTS Mud Mud F1uIh Total Mad8I8d - Frac. F.... Volume Weight Volume VOlume Volume CaIrIer Sand DIII1IIIy HI. 1/2 Length CommenII IB_) (#/Gal) (-) (B_) (IIarreIo) IlIIGaI.) (#/Gal) (#/GaL) (Feet) (Feet) CASE IA Injoel An Mud On One Cyde WIth Flushing 12000 9.8 2000 14000 14832 9.0 1.0 9.8 50S 235 CASE 2A In Od on ReaIIs1Ic Cyde Schedule WIth FIuatmg 2400 9.8 800 3110O 3135 9.0 1.0 9.8 335 185 CASE 3A In eel on Realistic Cycle NoFiush 3000 9.8 3000 3135 U 9.8 335 185 CASE 4A In Od on ReaIIs1IcCyde Heaw MudlSIuny· No Flush 3000 1G.3 3000 3273 9.3 10.3 320 150 CASE 5A Large Frac11ø8 Tra/IIJ'*II WFI3D _of Modal WIth PRlPpanI NIA NIA NIA NlA 3271 3D. Gal NlA I_n and RunnlnO eas. SA Actual FIoJd Volume But SIIIa MoxImum FIoId and WIth a Dens. DrIIIng Mud 1500 1D.3 Small 1500 3271 9.3 1G.3 285 135 FracturinO SIIuaIIon Other considerations: It is a well known phenomenon that fracture geometry changes with depth. At shallow depths, where the least principal stress is vertical, horizontal fractures develop in preference to vertical fractures because it is easier to lift the overburden than to part it vertically. This has been recorded with tiltmeters and other instruments at two locations on the North Slope. At one location a bimodal system developed at 2800 +/- feet. Here, the vertical fracture grew upward and then turned horizontal, perhaps when it made contact with a more competent lithology. In the other case, a horizontal fracture was recorded by tiltmeters at 2000 feet at Prudhoe Bay Pad-3. This is reported in SPE paper number 18757. Horizontal fracturing is germane to this disposal site because, with a fracture gradient of 1.0 psi/foot at 2800 feet, the situation is approaching a condition where a horizontal fracture might develop. It is a reasonably possibility that the mechanics could change enough with time so that with vertical growth, a vertical fracture plane could become reoriented to the horizontal. Numerous articles in the literature make reference to fracture domains and horizontal fractures; however, there is considerable uncertainty as to the depths and conditions that these things occur, and to their dimensions. Some references that are relevant to the storage mechanism while injecting mud and cuttings are listed in Exhibit 12. . . Conclusions: Injected wastes should not penetrate the lower confining interval, the 13 foot thick shale at 2945 MD (2715 TVD), nor jeopardize any fresh water sands because: (1) There are no improperly cased and cemented wells within the area of review. (2) There are no natural faults present that can transmit fluids through the confining intervals. (3) Fracture modeling supports the disposal operation and the confinement of wastes to the injection zone in the maximum fracturing situation. . . Oilfield Services 3940 Arctic Boulevard Anchorage, Alaska 99503 Tel. (907) 273-1700 Fax (907) 561-8317 I:: )(\-\1 BIT , I Schlumberger Unocal Alaska 909 West 9th. Avenue Anchorage, Alaska 99501 April 26,2001 Attention: Mr. Don Andrews Re: Ivan River 14-31 - Fracture Modeling for Disposal Dear Sir; A disposal well has been proposed for the Ivan River Field. The injection will be down tubing into a perforated interval from 3180 ft to 3220 ft MD in the Ivan River 14-31 well. The purpose of this work is to ensure that any fracture resulting from the injection process will not make sufficient height as to "grow" into undesired zones above. Using the Schlumberger fracture modeling simulator, FracCAD£ and raw input data supplied by Unocal, a number of variations were input into the model in an attempt to determine how this well would react to disposal operations. The wellbore configuration is shown in the following tables: Tubing Data 00 Weight 10 Depth (in) (lb/ft) (in) (ft) 2.875 6.4 2.441 2903.0 Casing Data 00 Weight 10 Depth (in) (lb/ft) (in) (ft) 7.000 23.0 6.366 3508.0 Perforation Data Top Top Bottom Bottom Shot Number Diameter MD TVD MO TVD Density (ft) (ft) (ft) (ft) (shot/ft) () (in) 3180.0 2893.7 3220.0 2924.1 4.00 160 0.20 U¡¡oæ! Ak¡ska . lie: ÎV<m River 74-3! " FracillfiJ !v;u"e!¡r¡g for Disposal Page 2 . Formation Mechanical Properties Zone Name Top MD Zone Frac Insitu Youngs Poissons Tough-ness (ft) Height Grad. Stress Modulus Ratio (psLinO.5) (ft) (psi/ft) (psi) (psi) CLEAN-SANDSTONE 2609.B 191.0 1.075 2736 4.000E+04 0.20 500 SILTSTONE 2B50.9 74.0 1.165 3120 B.000E+05 0.30 2000 SHALE 2946.0 13.0 1.183 3220 B.000E+05 0.35 2000 CLEAN-SANDSTONE 2962.9 67.0 1.075 2969 4.000E+04 0.20 500 SILTSTONE 3050.1 95.0 1.103 3120 B.000E+05 0.30 2000 CLEAN-SANDSTONE 313B.2 214.0 1.000 2969 4.000E+04 0.20 500 SILTSTONE 3420.3 300.0 1.000 3226 B.000E+05 0.30 2000 A number of assumptions had to be made with regard to the fluid. and the pump schedule in order to get the software to run. Based on previous disposal and injection experience. it was assumed that the base fluids would have a density of between 9.0 Ibs/gal (ppg) and 9.3 ppg. and that water would be used for flush. A trial using WF 130, a 10.0 ppg 'frac' fluid. plus 2 ppg 100 mesh sand was also used for comparison. The associated fluid properties were estimated to be as follows: Fluid Properties Fluid Name 19.0 Fluid 19.3 Fluid I WF 130 I Pure Water Spurt (ga 1/1 00ft2) 0.0 0.0 0.0 0.0 Fluid Loss C, (ft/minO.5) 4.2E-2 2.0E-4 2.6E-2 2.6E-2 Behavior Index (N') 0.6B 0.70 1.00 100 Rheology Consist. Index (K') (lbf.s^n/ft2) 7.30E-4 4.18E-3 2.96E-5 1.49E-5 Viscosity @ Shear Rate (cP) 6.757 42.874 1.415 0.715 Shear Rate (1/s) 170 170 170 170 The data described above was input into the Schlumberger FracCADEsimulator using the pump schedules that follow, In an attempt to accurately predict the fracture geometry that may occur in this disposal situation. a number of assumptions were made. based on the worst case that may be seen in the field. 1. A pump rate of 2.5 bpm was used. 2. Volumes pumped ranged from 14,000 bbls to 3000 bbls 3. 100 mesh sand was added in an attempt to simulate cuttings and solids. 4, Fluid density. rheological properties and sand concentration was based on previous disposal experience and the fluid properties determined from that experience. 5. A water based frac fluid, WF130, with a 30 Ib gel concentration and 2 ppg 100 mesh was used as a comparison. Unoc,¡/ Aí"sf.¡, . . He: Ivan Hiver J 4-31 - F",(;tare k ""ing for OJ~~p(}sa/ Page 3 Below, a description of the estiamted pmp parameters used in each case is outlined. Thes parameters were chosen in an attempt to realisticly and accurately estimate those that may be seen in the worst case scenario during disposal operations, For actual disposal operations, it is estimated that a maximum of 1500 bbls of fluid would be closer to the norm. Case 1 A Job Descri ]tion Stage Name Pump Fluid Name Stage Auid Stage Prop. Prop. Rate Volume Slurry Type and Mesh Cone. (bbl/minj (gal) Volume (bbl! (PPA) Disposal 2.5 9.0 Fluid 600000 14931.7 100 Mesh Sand 1.0 Case 2A Job Descri ]tion Stage Name Pump Fluid Name Stage Fluid Stage Prop. Prop. Rate Volume Slurry Type and Mesh Cone. (bbl/min) (gal) Volume (PPA) (bbl! Disposal 2.5 9.0 Fluid 126000 3135.7 100 Mesh Sand 1.0 Case 3A Job Descri ]tion Stage Name Pump Fluid Name Stage Fluid Stage Prop. Prop. Rate Volume Slurry Type and Mesh Cone. (bbl/min (gal) Volume (PPA (bbl! Disposal 2.5 9.3 Fluid 126000 3135.7 100 Mesh Sand 1.0 Case 4A Job Descri ]tion Stage Name Pump Fluid Name Stage Fluid Stage Prop. Prop. Rate Volume Slurry Type and Mesh Cone. (bbl/min) (gal) Volume (PPAj (bbl! Disposal 2.5 9.3 Fluid 126000 3135.7 100 Mesh Sand 2.0 Case 5A Job Descri ]tion Stage Name Pump Fluid Name Stage Auid Stage Prop. Prop. Rate Volume Slurry Type and Mesh Cone. (bbl/min) (gal) Volume (PPA) (bbl) Disposal 2.5 WF130 126000 3271.3 100 Mesh Sand 2.0 Case 6A Job Descri ]tion Stage Name Pump Fluid Name Stage Fluid Stage Prop. Prop. Rate Volume Slurry Type and Mesh Cone. (bbl/min (gal) Volume (PPA) (bbl! Disposal 2.5 9.3 Fluid 63000 1635.6 100 Mesh Sand 2.0 ) . , r· U¡¡DC{~! A!,QSk3 . He: Mm River i4·3! .. Fr,?cture ,~. ,¡ling for Œ~po$c?! Page4 . In all cases, a 'Penny' Frac model was utilized to determine the fracture geometry. A graphical summary of the results achieved is attached. From this information, it is our opinion that no subtantial frac height will be achieved, especially since the actual injection procedure will likely involve substantially less volume on a daily basis, as well as the fact the operation will not be continuous. Closure and re-initiation will be an ongoing occcurance, lending itself to little or no substantial height growth. We trust you will find the above information satisfactory, however, should you require anything further, or have any comments or questions, please do not hesitate to contact the undersigned at 907 -273-1700. Sincerely, r ~~f0 Rob Montgomery Schlumberger Oilfield Services Anchorage, AK FracCADE* Fracture Profile - Case 1 A 2550 2700 - 2850- '?€~RS. ---:~ ::: oS 3000- ! ~ 3150- 3300 - 3450 2600 "Mark of SchlllmhArn..r -./ ..... I 3000 Stress· psi I I · I · I · I I I I -~ \3'S¡.jAL.-¡;" 3400 . I I I I ) · I I I I ~ ~ 4 0 2 4 6 Width at Wellbore - in Unocal Alaska Resources Ivan River 14-31 9.0 Fluid + 1 ppg w 14000 bbls 04-19-2001 C ~. 8 -it( EN- NhHl) . . o I 100 200 Fracture Half-Length· ft 300 ScldulD~8Pgep FracCADE* Fracture Profile - Case 2A 2700 2800- 2900- >: ;:: . .r: 3000 - Õ. CD o ~ 3100- 3200 - 3300 2600 *Mark of SchlumhArOf~r ~< I 3000 Stress - psi 3400 -2 I I I \3 '~,µþ,Lf:: I -1 0 1 Width at Wellbore - in Unocal Alaska Resources Ivan River 14-31 9.0 Fluid + 1 ppg w 3000 bbls 04-19-2001 C C) ì.{) .k'"" ..I. {) -i gAJ. 2 I 50 I 150 I 100 Fracture Half-Length - ft o '. ',.}j)) . . 200 Schlumblll FracCADE* Fracture Profile - Case 4A " 2700 IL.:. -=:J < 2800- 2900 - 4:: . .s:: õ.. CD c ~ 3000 - 3100- 3200 2600 I 3000 Stress - psi 3400 -4 *Mark of Schlllmh.un..r 1 I )3' I 'SHA LE" I -2 0 2 Width at Wellbore . in Unocal Alaska Resources Ivan River 14·31 9.3 Fluid + 2 ppg w/3000 bbls 04-19-2001 (\0, 3 ~/C..,A'- JV\ ut) . . L o I 60 120 Fracture Half-Length - ft 180 khlum~8Pl8P FracCADE* Fracture Profile - Case 6A 2700 2800 - 2900 - = , .c ã. ~ ã; ~ 3000 - 3100- 3200 2600 *......... _" C!-_Io...._..._____ ~-< I 3000 Stress - psi 3400 -2 \3 ' sHAt_E' I ,I -1 0 Width at Wellbore - in Unocal Alaska Resources Ivan River 14-31 9.3 Fluid + 2 ppg w/1500 bbls 04-19-2001 ( \0.3 o/MC- ('i\ ùJ;¡ ) . . 2 I 50 100 Fracture Half-Length - It 150 o Sc~lum~IPII . . Exhibit 12 Fracturing References Stress fields: 1. Swolfs, H. S., "The Triangular Stress Diagram - A Graphical Representation of Crustal Stress Measurements," Geological Survey Professional paper #1291, USGS 1984. 2. ARCO Letter to Harold Scott, EP A Region 10, dated October 29,1987 regarding Class I permit in Prudhoe Bay Field. Item #106 addressing injection pressure converted data in reference #1 above into a more understandable fonnat. Fracture Domains: 3. SPE# 25757, "Disposal of Oily Cuttings by Downhole Periodic Fracturing Injections in Valhall-North Sea: A Case Study and Modeling Concepts", 1993. An example of disposal domain in which a lot more solids were displaced than is explainable with a single plainer fracture. 4. SPE# 36452, "Characterization of a Remotely Intersected Set of Hydraulic Fractures: Results ofIntersection Well No. I-B, GRI/DOE Multi-Site Project". Evidence of multiple fractures with multiple injections. 5. SPE# 22756, "Active and Passive Seismic Imaging of a Hydraulic Fracture in Diatomite". Example of micro-seismic monitoring that gives good results. It reveals that the fracture domain is more complicated than a single planer surface, even during short injections. . 6. SPE# 27896, "Reorientation of Propped Refracture Treatments in Lost Hills Field". Propped re- fracture treatments in Lost Hills, California, resulted in azimuths and dips different from original fracture planes. Good reference list. 7. "Class I fracture Slurry Injection", USEPA National Underground Injection Control Technical Work Group, Report No.1, February 26, 1998. A good discussion on fracture mechanics, the status of accepted knowledge, and a proposal to revise regulations accordingly. 8. SPE# 52738, "Large-Scale Injection of North Slope Drill Cuttings", 1999. A case study involving how different storage mechanics can interplay and how current fracture models can not account for all physical events. 9. "On the Dilatancy of Media Composed of Rigid Particles in Contact With Experimental Illustrations", The London, Edinburg, and Dublin Philosophical Magazine of Science, Fifth Series, December 1885, Professor Osborne Reynolds, LL.D., F.R.S. . , . . Horizontal Fractures: 10. SPE# 29646, "Economic Disposal of Solid Oil Field Wastes Through Slurry Fracture Injection", and companion paper: "Slurry Fracture Injection for Disposal of Large Volumes of Low-toxicity Wastes", Proceedings ARMS, Seoul, Korea, October 11-13, 1997. Examples of field activities in Canada using tiltmeters to monitor shallow disposal operations. 11. SPE# 18757, "Evaluation of Oily Waste Injection Below the Permafrost in Prudhoe Bay field". Example of an injection test at 2000 feet in which tiltmeters were used to observe a horizontal fracture opening and closing. Companion papers that have not been completely reviewed, but are understood to report on multiple horizontal fractures at Oak Ridge and in Melton Valley. 12. Belter, G. W., "Deep Disposal Systems for Radioactive Wastes", Underground Waste Management and Environmental Implications, AAPG Publications, 1972, pp 341-350. 13. DeLaguna, W., etal, "Engineering Development of Hydraulic Fracturing as a Method for Permanent Disposal of Radioactive Wastes", Oak Ridge National Laboratory Report, ORNL-4259, 1968. 14. Haase, C. S., "Geological and Petrophysical Considerations Relevant to the Disposal of Radioactive Wastes by Hydraulic Fracturing; An Example at the U. S. DOE's Oak ridge National Laboratory", Proc. Of Material Research Society Symposium, Vo1.15, 1983, pp 307-314. ~ . Formation Water Salinity and Aquifer Exemption 20 AAC 25.252 (c) 10 & 11 Salinities of formation waters and an Aquifer Exemption Request, according to 20 AAC 25.440, was submitted to the Alaska Oil and Gas Conservation Commission on April 26, 2001. The exemption was for all aquifer below 2500 feet (2306 feet subsea), as shown on the IRU 14-31 well log. The request and supporting data is included in the geologic section, part (c) 4. . . Wells Within Area of Review 20 AAC 25.252 (c) 12 The ~ mile area of review around the injection point is shown on Exhibit 3. This perimeter encompasses three existing wells: IRU 41-1, 44-36, 13-31. All the wells are cased and cemented so as to not provide a conduit for injected wastes to escape the injection zone. No corrective action plans are required. Well 41-1: Exhibit 13 includes the well schematic, completion, and cementing records. The 9 5/8 surface casing is set at 3453 MD (3334 TVD). Cement was recorded at the surface. Logging shows good bond from 3420 - 2700, with poor bondirig above 2700 feet. The 7 inch casing has cement up to a depth of 5000 feet. This well is an active gas producer. Well 44-36: Exhibit 14 includes the well schematic, completion, and cementing records. The 9 5/8 surface casing is set at 3449 MD (2941 TVD). Cement was recorded at the surface. Logging shows good bonding ITom 3449 - 2400 feet, with fair bond up to 1600 feet. The 7 inch cementing was designed so the cement top would be at 4120 feet. Logging shows good bond up to 4400 feet, with some cement to 4250 MD. This well is a shut-in producer waiting on a workover. Well 13-31: Exhibit 15 includes the well schematic, completion, and cementing records. The 9 5/8 surface casing was set at 3460 MD ( 2930 TVD). The cement job went well with the theoretical top at the surface. Logging shows good bonding from 3460 - 2560 feet, then poor bond above 2560 feet. The 7 inch casing was cemented around the shoe with a calculated top at 5000 feet MD. There is no bond log above 6400 feet to check this depth. The 7 inch stage collar at 2793 leaked. · It was squeezed, up-hole, with 25-30 Bbls of cement. · A bond log shows some bonding between 750-2400 feet and no bond ITom 2400-2780 feet. · The DV would not pressure test after the up-hole squeeze and leaked ITom 3000 psi to 850 psi in 10 minutes. · 7400 Bbls were injected through the DV at 2.5 BPM at 2650 psi over a five day period. . . · The DV was down squeezed with 16.5 Bbls of cement., (Hesitation squeeze from 2000 to 2800 psi at low rates.) The squeeze tested okay at 2500 psi for 15 minutes on two separate occasions. · Later, when completing the well, the DV would not test using an RTTS above and below the DV. The leak bled from 2500 to 350 psi in 15 minutes. · The uncemented 7 inch casinglborehole annulus probably has remnants of to.8 #/gal mud in it. · Conclusion: A small leak exists at the stage collar that must connect to the formation below the 9 5/8 casing shoe. The well is an active gas producer. Well 44-1: Exhibit 16 includes the well schematic, completion, and cementing records. The 13 3/8 surface casing was set at 1999 MD'(1992 TVD). Cement did not reach the surface and at top job was done at 220 feet. Logging shows cement from the shoe up to 500 feet, with some to 300 feet. The 9518 casing was cemented in two stages with a CBL showing good cement from the shoe to 7540 feet, and then again from the stage collar at 6347 up to 4050 feet. The well is an active gas producer. . . Well IRU 41-1 Exhibit 13 Completion and Cementing Records 20" at 165' 13-3/8" at 895' . .. IVAN RIVER FIELD WELL 41-1 l~· . ç-" ~S ~/ >- .. /' / HEATEA STRING FLUID ¡' PAOPEL YNE GLYCOL / / / I /- í . 9-5/8" at 3498' 4 A ŒBL. Tc? 'T-r £!.. 5x:o 52J)b ~:. ,...- ./ / / ~ / L SHOAT STRING: 1-1/~ J-55, 1 DAD, TUBING @ 2994' BAKER "CMU' SUDING SLEEVE AT 2988' BAKER 'FH" PACKEA AT 3034' LONG STRING 2-7/8" N-80, ABC MODIFIED TUBING " / / / / / .,( / / ~~' / 7' / I I TOF ESTIMATED AT 8896' / (DROP OFF GUNS) ETD AT 9078' 7' CASING AT 9152' TO AT 917(1 / ¡' (. ¿,///////////~ BAKEA '31-1' PACKEA AT 8629' BAKEA 'A" PROFILE AT 8650' TUBING TAIL AT 8693' TYONEK GAS SANDS 8710' - 8725' 8745' - 8700' 8783' - 8803' 8815' - 8875' GRB 2-19.:.f) DEA4-?..:,-O\ .J $TATE OF ALASKA , ' A~ ,AND GAS CONSERVATION COM_~'\ , WELL COMPLE-.--. OR RECOMPLETION FW "RT AND LOG 1. Slatus of Well Classification of Service Well OIL 0 GAS Œ SUSPENDEDD ABANDONEDD SERVICE 0 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAl) 3. Address P.O. BOX 196247 ANCHORAGE, AK 99519 4. Location ofwellatsurface 712' FSL, 737' FEL OF SEC. 1, T13N, R9W, SM At Top Producing Interval (8710') 3262'N, 768' FEL OF SEC. 1, T13N, R9W, SM 7. Permit Number 92-109 8. API Number .J'"O.283-20088 9. Unit or Lease Name IVAN RIVER 10. Well Number 41-1 11. Field and Pool IVAN RIVERlUNNAMED At Tolal Depth (9170') 4174' FSt, 759' FELOF SEC. 1, T13N, R9W, SM 1Îb S. Elevation In feet Qndicate KB, DF, etc.) Ie. Lease Designation and Serial No. S1'KB IVAN RIVER 12. Date Spudded 13. Date T.D. Reached 114. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 12/20/92 01/15/93 01/26/93 N/A FeetMSL 1 17. Tolal Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 119. DirectionalsurvÕ 120. Depth where SSSVsat 121. Thickness of Permafrost 9170'-8283' 9078'-8209' YES Œ NO N/A feet MD N/A 22. Type Electric or Other Logs Run CNLJC- DENSITY/DILJBHC-ACOUSTIC/GR/SP 23. CASING SIZE I' WT. PER FT.I GRADE 2(1' 94# WELDED 13-3/8" 68# K-SS 9-5/8" 47# S-9S, N-80 7" 29# N-80 SBT/GR/CCL CASING, LINER AND CEMENTING RECORD I SETTING DEPTH MD I I TOP J BOTTOM HOLE SIZE CEMENTING RECORD 26' 16S' . DRIVEN 26' 895' 17.5" 130 BBIli 2S' 3498' 12.2S" 281 BBLS. 25' ~ 8.5· 171 BBLS ,. q~ I AMOUNT PULLED 24. Peñorations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 8710'-8725' 8745'-8768' 8783'-8803' 681S'-887S' 7867' -7882' 7899' -7921' 7934'-7952' 7963'-8017' 12 SPF, 0.5· 12 SPF, 0.5" 12 SPF, 0.5· 12 SPF, 0.5" 2S. TUBING RECORD SIZE I DEPTH SET (MD) I PACKER SET (MD) 2-7/8· 8693' 8829'-3034' 1-1/2" 2994' N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED N/A MD TVD 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 2/22/93 FLOWING Date otTest Hours Tested PRODUCTION FOF OIL-BBL GAS-MCF 2/22/93 TEST PERIOD Flow Tubing Casing Pressure CALCULATED Oll-BBl GAS-MCF Press. 2300 0 24-HOUR RATE 6580 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. WATER-BBL CHOKE SIZE I G~=~llRATIO WATER-BBL Oil GRAVITY-API (corr) NONE Form 10':;'407 rev. 7-1-80 Submit in duplicate CONTINUED ON REVERSE SIDE -ð'Þ· ÀJ X?--!f3 29. . . . , 30. GEOLOGIC MARKERS FORMATION TESTS MEAS.DEPìH Include interval tested, pressure data, all fluids recovered and gravity, TRUE VERT. DEPTH GOR, and time of each phase. NAME BELUGA FM. TYONEK FM. 5757 8677 5217 NONE 7787 31. LIST OF ATTACHMENTS 32. I hereb~~rrectto the bast of my knowledge Signed G. RUSSELL SCHMIDT Title DRILLING MANAGER Date 02J22l93 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one Interval (multiple completion), so state in item 16, and In item 24 show the producing intervals for only the interval reported in Item 27. Submit a separate form for each additional Interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental recordsforthiswellshould show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, Indicate "none". .' . .r ......... , '''_''_ri'~''''''_'_'_'_'''''''''''''''''''''' . ....... ..,........M........ ",. 'M ..... ............ ..... ......._.8......._... ..., .. ..... .................................. ....M.................._, --...-...-...-.-- . "on , Lease:IVAN R!V~R Well : :Þ41-1 Field r VAN HI lJEJ~ Riq Lontractor uate G~HLE DRILLING CU. #154 12/¿¿/Y Slot Report AFE # AFE Amount DailY Amount cum Amount Foreman # 3 # 3 321058 4500000.00 $ a10~0 I' 3Ø~7~q b. Buck 1 . I Wlud Type GEL SPUD Mud Weight 1'0 FIG 9.4 pcf 907 na E 1.01 V.o t.jØl <jlilb Cu!'~!'~ent Ope!'~at ion: INSTALLING THE 2lðll BUPE Current Formation:na Since Spud Days 2 Hou!'~s Drlg hrs Down hrs Trip hrs 'fotal GPM HV .oP 18. n,'a na 2. 'il. ILl. ø AV VL lð. Ii) Conductor Csg Surface Csg Intermediate Production Linerl'op 20."@ 165 13.375"@ 895 0. "I!! ø Ø."@ ø ø. "1]1 0 Bot to III ._~.__.._....._........._._..__._.._........._._._____._.._._...._._.._..~.._......__._._..,... .... ..... ._...., ....... N.....>.~· II ___.__......_........__.._........_._.........._........._....._..._.........__.......__......_..._MM.....__...._............._...._...__._........_............. .....~.... . Remarks ØØØ0 - 0330.... RAN 13-3/8" C~~SIi'.IG AND LANDED WITH SHOE:: AT 895', STf.Œ IN f.)f 8::;3 0330 - 050Ø....PRESSURE TESTED NATIONAL S~AL ASS~MBLY TO 1100 PSI FUR 10 MIN. ...............RELEASED LANDING JOIN'r AND BROKE DUWN. RIGGED DOWN WEATH~RFURU 050Ø - 0730....PICKED UP 5" DRILL PIP~ AND RIH WITH HALLIBUR1'üN STAb IN AN~ ...............CEN·fRHLIZER GUIDE. STABBED INTO THE FLOAT CULLAR Af 853'. 0730 - 09Ø0....CIRCULATED AND CONDITIONED MUD. 090'ZL. - 103121.... CHANGED 4" Vf4LVE UNDER THE NAr lù1'J~~L 21£1" HEAD, GATE WUULD NU r OPEN.. . . . . .... . . . . . UNPLUGGED 4" HUS~ RETW~N1N¡;¡ FI:~UM THE:. UNDER TH~ 20" H~~IJJ CGRAVEL).103Ø - 1130....PUMPED 40 BBLS WA'IER, 10B BBLS OF LEAD LEMENr, 32 BELS OF . . . . . . . . . . . . . . . TAr L CElvIENT. FULL RETURNS. APPHiJX 5Ø BBl,..S CI:::t71I::.NT riETURNS TO '. . . . . . . . . . . . . . . SI.,J.REB.¡;';E. - LEAD SLURR'{ COI\fg-r sTËü w::: 12. 9 -PPl:iCLHbS --~ ....--.,. "G" CElv'ENT WITH............... 10';1. ~:'EPTrZ~D GE:.L, 2';1. CHLCIU/v CHLURl.tJE. ?-'lhliJ Ø.25% CFR-3. ...............TAIL SLURRY CONSISTED OF 15.8 PPG LLHbS "l:i" CEMENT WITH Ø.15¡<' ............... CFR-3 AND 2¡<. C¡:'~LCIUlvl CHLUHIDI:::..E:.NTH~t:. JO.l~ Wf.)S PU/yIPED AT . . . . . . . . . . . . . . . 6 I:\BL/I~1I N. LEI"IENT I I'J PLACE A r 11 ¿Ii,) HI:.cS. 1130 - 1330....UNSTABBED FROM THE COLLAR AND VERIFIED THAT THE FLO~l'S HELD. . . . . . . . . . . . . . . . C r RCULATED, R.ECOVERED m:'PROX I 1~ f:~TEL Y 2tZt BBLS UF U::.I,IEN f CUN I HiTI MUD1330 - 1530....POOH AND LAYED DOWN 5" DRILL PIPE. 1600 - 1700....CLEANED FLOOR, WASHED UP FROM THE TR!P. 1700- 2130.... REIYJOVED THE PITCHER NIPPLE AND 20" DIVERTER. 2130 - 2400....DRESSING THE NATIONAL 13-3/8" WELLHEAD, INSTALLED PLUGS iN TEb ' ...............IN TEST PORTS, INTALLED ANCHOR SCREWS AND PACKING. .' . ..-..- ......_._....__.._....._._.....~. .....~..,...........,........- ylud Type GEL/GELEX l~ll.ld We i ght 9.4 pcf Dðf}Y ?mountlcum Amount I ~oreman ~' , 218507 1$ 97121149 'LYNCH I - - I I TD' FIG I ETO TVD 3512 na I 3512 334b .. -...... '..... '~-'" -.... . ... -..~ .....~ ..... .......... ..-- .........- ..... ,- f' .. .......... Hl~ Contractor ¡uate GH~CE DRILLING CU. #lb4 12/~0/~2; Lease:IIJAN RIVEH Well #41-1 Field lVi-iN HIVEH Slot Report AFE # # 3 # lØ 321058 AFE Amount 45Ø0ØØ0.ØØ Current Operation:W.U.C. RID CGG TOOLS I 1 I _.1 I Current Formation:na Since Spud Days 9 HOllt's Drlg hrs Down hrs Trip hrs Total GPM AV DP lB. 2.5 na na ø. 0.0 AV DC ø. iii Conductor Csg Surface Csg Intermediate Production Liner Top 20. "@ 165 13.375u@ 895 9.625"@ 3'+98 0. u@ 0 ø. "1]1 ø bottom III ..---.............--............................-.- ..........---.....,...-.... .........-..,_.._...~..._._..._.._.....-..._-_.-..............,....-....-.... .......... ........... , -.. .... .... ...... II ____ ._..........._..._._..........__......__.M__...._....._..._~_.··.~_._.... ..... .........._... ...._..__............__... ._..~__ _'..~' .._.~_....h_...~_..M"....___._.........4..._............... .._................... ........... Remarks ØØ0Ø-0230. . . FINISH POH W/BHA #4. . 023Ø-Ø6ØØ. . . CHANGED FM/5" TO 9-5/8" HHIY S & TI::.STElJ TO 2=:'01lt-¡::.'Sl. 060Ø-0730... RIU CSG TOOLS, 1~1/U 9-5/8" NUWeO Cö\;j -'lEiH & U~NDING Jl, LI-~NlJ£¡) u. J~., · . . . . . . . . . . . LID SAME. 0730-16Ø0...RAN 9-5/B" CSG TO 858', CBU, H/U 350-10N CBG EQUIP, CON'I'D RUN LSb ............TO 3492' STOPPED, R/U HOWeD CMT HEAD & WASHED DUWNrO 35Iltb). 16Ø0-1830...CIRC/COND MUD, MOVING CBG WINO PRUBLEMS AT 30' S·I·K8. 1830-2200...TESTED LINES @3ØØ0-PSI, PUMPED 50-BBLS WA'J'Ek, 40-BBLS IÜ.~ DUHL ............SPACER, K.O. BTM PLUGJ M ~ P L~AD: 510-SXS (187-BBLS) N~Hl LMI HI · . . . . . . . . . . . 1-2. 9-PPG WI 10¡<. PE:PT {:z.~D_._ GE:-L,.. ._;:J.~_ ..J.~t 1-2, . 2~1- Lt-:, i-;;S 'fA £L: 'tb-¡¿I"'::;;X;; · . . . .. . . . . . .~1;¡.S) NEAT ClvlT AT 15.8-PPG, W/2't. CaCl-2, . 1510 CFf<-3,t f~t~DP ............PLUG, DISP W/9.3-PPG MUD, BUMPED PLUG W/25ØØ-PSI, FLUHTS DID HOLÛ, · . . . . . . . . . . . CIP @2140-HRS, W/FLOAT SHOE @3498', FLOAT CULLAR @ 34~5Ø~. ************WHILE RELEASING TOP PLUG STUCK CBG ~ABOVE DEP'fHB, WONKED Sl'UCK ebb ************50k TO 54Øk LOST DRAWWOHKSPOWER, TRIPPED MAIN HELHYS. 2200-2400. . . W. O. C. , WASHED OUT BOP STACK, RIO CI~ T LINES 8. CaG TUULS. HAD APPOX., 25-BBI R .eMT RiNS. B. WAZELL AOGCC WAVtED WITNËSSING BOPE TEST 29-DEC-92. II . ......_---_...._......_...._.__..~_...................... ....... '.'~"'" ~... ...... ..... . Remarks from Ø00Ø to 06Ø0 hrs ØØ00-0600...CONT'D W.O. C., RIU TO PICK UP Sl'ACK TO SET EMERG SLIPS & PACK O~F. ............CLEANED SAND TRAP, DE-SANDER & OE-SILTER PITS, WELL STABLE4 RIU Tu ............LEVEL DERRICK AFTER 9-5/8" LANDED. Comments (Union Drilling Only) WALK AROUND WELDING/MECH S'fACK, DON'T BLOCK FIRE EX'rS'flNERS AND WALKWAYS. .__. ._..._.__._..........___.._...... ................~.. ._.....ø........ ..._ ... ..... ..~.......ø. ..... ~............._.......~....... . ._...._ . . . ........, ..._.......~.. .. .... .."... .... ..." PlIm p I~iod e 1 . Type Stt"oke Liner BPI.., Pres. Slow SPM Slow Pres #1 *t2 GDPZ10 GDPZ lilt , T T 10. lØ. 5Lt. I I ._-_...._..._._-_............_.._...._....~. ........ ....-......... ....-...-....... ...-.-..- .....-......... ..~.. ....... ........ .....". . .... ....... 6.5 6 '" .¡.;¡ Ill. 1Zt. ø. t-b. 1£1. iii. Ið. Slot Report AFE # # 3 # 31 321058 .< --¡--- Field I VAN RIlJER AFE Amount Daily L.::¡ØØIZlI{)IZI. IlIØ $ .. ÞII.\d Type DISPERSED Ylud I-Je i qht 10.6 pcf TD ~171/J '---'-"1"'"'''---''' ""--.,..,-..-"--- ....-....-..-.... ..-....................... ..--...-........-......,.'(' ......... .-- . .. ··..····11 ¡Rig Contractor Date I GHHCI::: DRILLING CO. #154 lðl/1'-;j/'-;;,3 ~b}~~""~I~~t Cum Amount Foreman :1,1 '_~U7 $ 2427611 LHRRY MCALLISIER .11 II II I' I I I I I FTG E'rD 1;)170 rVD I· I I:kB3 I Lease:IVRN RIVER Well #Ltl-l na CI.\I'''rent Operat ion: DISPLACE 7" ctrrf JUB Current Formation: TYONEK Since Spud Days 30 Hours 18. Dr 1 9 hrs Down hrs T1''' i p hrs 'f ot a 1 GPI~1 AV DP na na na 233.. 121.1 HV DC 1 ìi:::. 4 Conductor Csg Surface Csg 2Ø. "1]1 165 13.375"1]1 895 Intermediate 9.625"@ 3498 Production Linerrop 7. /Ill'! ':) 152 Ill. "I!' III ..._....M......_....__._...._.._...._.___._.._._._..... _.....__.._..~.._.._._._...._._.... .. . , Bottom It). _II ~ ..._.___.__.nM._..'__....._......_...._...._.~_._.._.___.........,.. .._..._...._... ................__._... ......... , .......-........ II II II Remat"ks 0ØØØ - 02ØØ... PULL WEAR RING - CHG T/PIPE RAMS TO 'I" & lST SAÞIE 02ØØ - Ø3ØØ...R/U WTHFD & PREP TO RUN 711 eSG Ø30Ø - 18~Ø...RUN 7" CSG TO 9152' - RAN SMOOTH (No glitches) - RECIPRUCH'r~u CSG ..............W/O PUMP - BROKE CIRCULATION - FULL RETURNS WHILE RECIPRUCAIINb ..............LANDED CSG HEAD 10" BELOW MARK ON LANDING JT (Where we had pre- ..............landed, prio1''' to job) - AFTER 3) RECIPROCATIONS WE WERE 1/211 BELOW..............MARK - NOT SURE IF WE WERE SEATED OR NOT - STOPPED CIRCULATION - ..............BK'd/OUT HOLD/DN PIN, DRAIN~D STALK TO SEE IF WE WERE IN PROFILE ..............AFTER 5 MIN UF HECIPROC~·rION, WE WERE UNABL~ 10 P/U - RE-ESTABLISH..............CIRCULATION & WERE STILL UN~BLE TO RECIPRUCHIE 1830 - 24Il1Ø...R/U HDWeD & PERFORMED CM'r JOB: PRES~rS'I'U LINES - DRUPPED L~HU ..............PLUG - PUMPED 18 BBLS CAUS1'lC (2~ by wt). 50 BBLS DUAL SPHCEH ..... ..... .... (12ppg), llZ1 BBLS H20, 2tZJ BBLS SUPI::J~FLUSH, 11£1 BBLS H20.~}11 Bf:\LS ..............12 PPG TRINI1Y TIGHT CMT WITH 1.2,~ HALAD 344, DROPPED THIL PLUG ..............PUMPED 8 BELS H20 & DISPLACED WITH 10.5PPG MUD . . IRU 41-1 9170' DAY 31 (1/19/93) 20" DRIVEN TO 165' 13-3/8" @ 895' 9-5/8" @ 3498' 7" @ 9152' 546 PSI PULL WEAR-BUSHING. INSTALL 7" CASING RAMS IN BOPE AND TEST. RAN 7" CASING TO 9152'. RECIPROCATE AND CIRCULATE CASING. ATTEMPTED TO LAND HANGER TO CHECK SPACE-OUT. 7" CASING STUCK- UNABLE TO RECIPROCATE. PUMPED CEMENT JOB: 171 BBLS TRINITY- LIGHT @ 12 PPG. ---- IRU 41-1 9170' DAY 32 (1/20/93) 20" DRIVEN TO 165' 13-3/8" @ 895' 9-5/8" @ 3498' 7" @ 9152' 546 PSI BUMPED PLUG @ 0200 HRS. CHECKED FLOATS, OK. ATTEMPTED TO SET WELLHEAD PACKOFF SEAL WITHOUT SUCCESS. HANGER NOT SEATED. INJECTED 494 BBLS MUD, MUD DOWN 7" X 9-5/8"ANNULUS. LIFTED BOP STACK. FOUND BOW SPRING CENTRALIZER PARTS UNDER THE CASING HANGER PREVENTING IT FROM SEATING. IRU 41-1 9170' DAY 33 (1/21/93) 20" DRIVEN TO 165' 13-3/8" @ 895' 9-5/8" @ 3498' 7" @ 9152' 546 PSI SPEARED 7" CASING AT 35' RKB. REMOVED CENTRALIZER JUNK FROM WELLHEAD. LANDED CASING HANGER. INSTALLED AND TESTED BOPE TO 2200 PSI, OK. INSTALLEq BOPE. CHANGED TO 2-7/8" RAMS. TESTED BOPE TO 5000 PSI, OK. RAN WEAR SLEEVE. BEGAN RUNNING SBT. ....: e- IRU 41-1 907' DAY 4-8 (12/23-28/92) 20" DRIVEN TO 165' 13-3/8" @ 895' 484 PSI FINISH REMOVING 20" DIVERTER. INSTALLED BOPE. TEST BOPE, RIH DRILL FC, TST CSG NO TEST. DRILL SHOE & OPEN HOLE TO 917': CIRC. POOH. RIH WITH A 13-3/8" RTTS & SET @ 790', TAIL @'. 883'. TEST ANNULUS TO 1500 PSI-OK. PERFORMED L.O.T. POOH: RIH TO 917'. DRILL 12-1/4" DIR HOLE FROM 917' TO 1396'. pooli F/MWD. RIH & DRILL 12-1/4" DIR HOLE FRM 1396' TO 2228'. CB.U.: POOH F/BIT & BHA. RIH & DRILL 12-1/4" DIR HOLE FRM/2228'TO 2903'. CBU. SHORT TRIP TO 1880. DRILL 12-1/4" DIR HOLE FRM/2903' TO 3147'. CBU. POOH F/BIT. . IRU 41-1 3512' DAY 9 (12/29/92) 20" DRIVEN TO 165' 13-3/8" @ 895' 484 PSI RIH. REAMED 3013'-3147'. DRILLED 12-1/4" HOLE F/3147'-3512'. SHORT TRIP TO 857'. REAMED 3451'-3512'. CIRC.POOH. IRU 41-1 3512' DAY 10 (12/30/92) 20" DRIVEN TO 165' 13-3/8" @ 895' 9-5/8" @ 3498' 484 PSI CONT'D POOH. CHANGED FROM 5" TO 9-5/8" RAMS AND TESTED TO 2500 PSI, OK. RAN AND CEMENTED 9-5/8" CASING @ 3498'. CEMENT TO SURFACE CLEANED STACK AND WELL HEAD. ·.. . IVAN RIVER <41-1 IRU 41-1 9020' DAY 1 (12/20/92) 20" DRIVEN TO 165' 504 PSI CONT'D MOVING RIG. ACCEPT RIG @ 0600 HRS. FUNCTION TST. DIVERTER SPUDDED WELL AT 2030 HRS 12/20/92. DRILLED/OUT FM 55' TO 183'-17-1/2" HOLE. IRU 41-1 907'/724' DAY 2 (12/21/92) 20" DRIVEN TO 165' 520 PSI DRILLED 17-1/2" DIRECTIONAL HOLE F/183' TO 907'. SHORT TRIP TO 20" SHOE. RIB TO 907'-NO FILL. POOH. RUN 13-3/8" CSG. IRU 41-1 907' DAY 3 (12/22/92) 20" DRIVEN TO 165' 13-3/8" @ 895' 488 PSI -7 RAN 13-3/8" CSG TO 895'. STAB IN & CMT SAME W/10S BBLS LEAD AT 12.9 PPG PLUS 32 BBLS TAIL AT 15.8 PPG. CMTTO SURFACE. NIPPLE/DOWN 20" DIVERTER. . . Well IRU 44-36 Exhibit 14 Completion and Cementing Records . " " ." , ,." ,".,.. IVAN RIVER FIELD WELL 44-36 PRESENT / Y,' 20' at 88' ~;/ ~/ p/' 13-318' at 908' .:::::'~ í / ~ ~ ~ 9-518' ~ I ~ -;q53 . I L 2-318', 4.6#, N-80, Butt to 2987' "" BAKER CMU SUOING SLEEVE 3104' BAKER 'FH' PACKER AT 3058 ~ ß L '"Thp 4-4Ð ò ~ / '7 / ,r r r / / / /' / / 2-7/8' 6.4#, N-80 BUTT COMPLETION / / / /' :/ ~~ ,/ f '/ / II" {' /' ./ /' BAKER 'FH' PACKER AT 6339' BAKER 'R' PROFILE (2.257" 10) 6351' TAIL AT 6425' PERFORATIONS 12 SPF 6431' - 6440' 6557' - 6568' 6836' - 6852' 438' 4-318' TCP PERF GUNS '.,¡J" 7" CASING AT 8308' ;/ 1'// / / / / / / / / / / ~ TO AT 8308' NOTE: TUBING MEASUREMENTS ARE 13' DEEPER THAN OIL GRB 3-18-92 ~ ' STATE OF ALASKA ." '. A ' ,)IL AND GAS CONSERVATION CO ,""" ,ON WEll COMPlE \..IN OR RECOMPlETION RL..~ORT AND lOG 1. Status of Well Classification of Service Well OIL 0 GAS Œ SUSPENDED 0 ABANDONEDD SERVICE 0 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE, AK 99519 4. Location of well at surface 742' FSL, 777' FEL OF SEC. 1, T13N, R9W, SM At Top Producing Interval (6431') 4382'FSL, 817' FELOF SEC. 1, T13N, R9W, SM 7. Permit Number 93-22 8. API Number 283-20089 9. Unit or Lease Name IVAN RIVER 10. Well Number 44-36 11. Field and Pool IVAN RIVER/UNNAMED At Tolal Depth (8308') 298' FSL, 932' FEL OF SEC, 36, T14N, R9W, SM 5. Elevation in feet Qndlcate KB, DF, etc.) 16. Lease Designation and Serial No. 51'KB IVAN RIVER 12. Date Spudded 13. Date T.D. Reached 114. Date Comp., Susp. or Aband. 115. Water Depth, If offshore 116. No. of Completions 02/10/93 03/01/93 03/07/93 NIA Feet MSL 1 17. Tolal Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 119. DlrectlOnalSu~ 120. Depth whereSSSVset 121. Thickness of Permafrost 8308'/6438' 8272'/6408' YES Œ NOU NIA feetMD N/A 22. Type Electric or Other Logs Run CNL/C- DENSITY/DIL/BHC-ACOUSTIC/GR/SP 23. CASING SIZE I wr. PER FT.I GRADE 20" 94# 13-3/8" 68# 9-5/8" 47# 7" 29# K-55 N-80 N-80 SBT/GR/CCL CASING, LINER AND CEMENTING RECORD I SETTING DEPTH MD I I TOP I BOTTOM HOLE SIZE CEMENTING RECORD 26' 88' DRIVEN 26' ~908' - 17.5" - 115 BBLS (to surface) 25' 3 < 12.25" 270 BBLS (to surface) 25' 8308' 8.5" 129 BBLS I AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) Measured TVD 25. TUBING RECORD SIZE I DEPTH SET (MD) I PACKER SET (MD) 2-7/8" 6425' 3058' & 6339' 2-318" 2987' None 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED NIA 6431'-6440' 6557'-6568' 6836' -6852' 5000'-5005' 5090'-5097' 5295' -5306' 27 PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 2/22/93 FLOWING Date of Test Hours Tested PRODUCTION FOF OIL-BBL GAS-MCF 2122193 TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF Press. 2300 0 24-HOUR RATE 6580 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. WATER- BBL CHOKE SIZE I GA~=~IL RATIO WATER-BBL OIL GRAViTY-API (corr) NONE Form 10-407 rev.7-1-80 Submit In duplicate CONTINUED ON REVERSE SIDE 4 --/3'13 29. . .\ - ,...... 30. GEOLOGIC MARKERS FORMATION TESTS MEAS.DEPiH Include interval tested. pressure data; all fluids recovered and gravity, TRUE VERT. DEPiH GOR, and time of each phase. NAME Top Beluga 6748 5128 NONE 31. LIST OF A1TACHMENlS 32. 'h_graro..··_mm'''''''''''''',. Signed G. RUSSELL SCHMIDT rrtle DRILLING MANAGER Date 04/13/93 .t.a. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion Item 5: Indicatewhich elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing Intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (OF, 1<8, etc.). Item 23: Attached supplemental recordsforthiswell should show the details of any multiple stage cement- ing and the location of the cementing tool. item 27: Method of Operation: Flowing, Gas Uft, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, Indicate "none". .. .>; Lea s e : r IJt:~N R I V E R We I! *~44-36 Field Rig contt"actor....···· V~:Ì;e""'·c" ,II IVAN RIVER l:H~HL£ l.HHLLING cu. #15".. f£'I:::/li:::/':J.~ll AFE # AFt:: Hmount Daily HmOttnt ILum' Hmol.lnt I FO)'''eman II 321060 $3,200.00 $ 1~2~6~ \. ~a0~b~ ILHRHY MLALLlbl~H II I ~I MI.ld We i ght T1). FTG IE rù rVD I 9.3 pcf . 916 161 916 ~11 I I Current Operation: R/DN PITCHER NIPPLE, ANNULAH & DrV~HrUR I _-.J I I II II 1/ II II Ii II Hottomll iii II 1\ Since Spud Days 2 Hours na I I Drlg hrs Down hrs Tri~ hrsl~~~al GPMIHVo~P. , 3. 5 n a ~. c. -;¡¡;; .. I "" ¡;; . ( I I I I Csg Surface Csg intermediate ,¡prOduction 94 13.375"@ 91218 0. "fit III 0. "Ii' III HV D(" 2Y.!j Slot Report 1# 15 # 3 Mtld Type GEL/GELEX Current Formation:na Conductor 20."@ Line\''' lop Ill. "IS' III ..,.._---_...-._~-- .-. ..-_.....~.. ..~. .", .." ...... '. .. ...... .. . .. ~ . . '" . .... .... -.............. ~..,..~.,. .... --" ...... ............... II -.-----.- .__...,.~..~.._...-...-....... "-.- ........' ....-......... ..-..... ..... "'" . ,"'. 0-..... ._..... ... ......,.. .. ....... ... ....... .._...... .. ...... , Ii u Hemarks 000Ø - Ø33121... DRILL 17 12" DIfVI~lWD HOLE FIiI¥I/ 7ô5' ïU i:>16' 0330 - 0400...CIRC BTM/UP 040Ø - 0430...BLOW KELLEY & CLEAN SCR~EN ~RM/ bHVEH SUB 0430 - 0531Z1...POOH (Good short trip)& WURK f/8iB IHHU 2Ø" bl" U~ 0530 - 06Ø0...RIH - 3 FT FILL 06121Ø - 0730...CIRC & CONDITiON HOLE FI CbG 0430 - 0900...BLO KELLEY & REMOVE SCREENS FHM/ bHVEH bU~ - PUUH l'U HUN LbG Ø9Ø0 - 143121... R/U WTHFD 1"0 HUN 13 3/8" CSG - RUN SAI~I£ TU 9\ðcl' 1430 - 1730...R/U CM" HU , ClRC - R~LIµ LbG (~~K/UP & b~K/dn) - Ibl ~UH~ L1NLb ..............PUMP 50 BBLe H20 SPACER. CHuP LEAD PLUG. PUMP 80 BBLS L~HU bLURRy .............. (14.2 ppg with £t¡<' ReI, ~'ý. l;aLI, .2~;:' LFH-~) - ~luJ71,..'-~::, J::I.\:IL~ -n:·:¡TL- ..............SLURRY (15.8 ppq with 2't. CaCI. .1~'ý. L~H-3) - DHuP T~lL PLUG - PLUG..............BUMPED·WlfH EXAC1'LY 130 bBLS U18PLHCEMENI ~PumDed 15 bbls ~ 3 bpm ..............& last 5 bbs @ 1 bpm} - CIP = 1736 HHS - RECIPROCATED THROUGHOUT ........'0..... JOB - LSG ùlLJ NUl HYDW4UL1L BUr H~'I-'HUi-lCH~U "rLUHI lNt:;" - L-JENT TO . . . . . . . . . . . . . . 7Ø ~/up & 45rUdn - HANGING WT = 42K - GUT B B.I:ILS CONTAMINATED CMT ..............·IU SURFACE - BLu/Urr rLUA'IS HELD ~1/2 bbl back) - LOST PARTIAL .....~........RETURNS 2/3 ' 'HHU DIbP - AFTER BLD/ü~~ i-INN DROPPED 15' & STABILIZED1730 - 2100...WùC 2100 - 2131Z1...SLACK/OFF - CSG S'rATIONARY - H/CN Wl'H~U ELEVATOHS & .I::.IHILb 213121 - 2400...SET/OUT ROTARY & NIP/DN ANNULAR & DIV~RIUH .. .", ......, .' .' L;~-;;·~···ÏvÃï~··-f~"IvËR··-"_·-"-------'-· ··..;:..¡··;ï·d·-·-····-··-··....-..- .---.... .., ,.-.. -'1",< i··~· ë ~'~t;-~~t .~.~" ..-...... .... ......-.., Well #44-36 IVAN RIVER IGRAL~ DHILLING CO. #1~4 Slot Report AFE # AFE Amount Daily Amount Cum Amount ~oreman # 15 # 10 321060 53,200.00 $ 2230~7 $ 977~w5 LYNcH .. I IDate I t¿1¿121£1/~3 I IYlud Type GEL/GELEX Mud Weight TD ~TG 9.3 pcf 3453 na ~TD TVü 3453 2943 Cu~"rent Operation:N/U 13-5/B" 5IYI BOPE Current Formation:na 5i nce 5pl.ld Days 9 Hours na Drlg hrs Down hrs Trip hrs Total G~II'I AV UP na na na 0. 0.0 AU DC Ill. 0 Conductor Csg Surface Csg Intermediate Production Liner Top 2Ø."@ 9413.375"@ 90B 9.625"@ 3449 0."@ 0 0. "@ 0 Bottom ø ..___..___..._...__.-..._.__._.._...._ ._.........._.____.... ...._. ............._ .._,..............____. ............-......_...._......_._. _., .__.,_ __._.... ", N....·. ...._........ ..........._....... ._._ II.. H··;..~..~·k·~-·..-_·_-_··_·_·..··-·__··::·····--··:·=:··-.........-.--...-..-.....-........-.. ... .. .... '., ......-.... ØØ0Ø-0b30. . . RAN BØ-JTS, 9-5/8" 4'/#, N-BIi:I BTC CSG Td ;?A53~ ~"/U HUWCU 1Zi630-0B3fZ1... CIRC & CUND tr1UD, <PF<E-J'OB SI-H=ETY fYIEErINþ}. :,/'< 0S30-1130...TESTED SURFACE EQUIP TO 3000-PSI, PUMPED bØ-B~LS WIH, 4Ø-BHLS DUAL ............SPACER l]lltZ1.5-PPG, N & J..:' LEAD 18Ø-~BLS ":.91 sxs 10;; NUN-P~PTI:lEIJ GEL .. .......... CMT, @12. g-PPG, 2" CaC12, .25" CfR-3, THIL ~ø-.l::\BU:í 44Ø-sxs uG" UilT ............ @15. 8-PPG, 2;; CaCI2, . 151- CFR-3, DISP'D ¡"J/9-:'-3"::PPG '~ UD, F~ECIPRUCATE ............CSG 851- OF DISP W/APPOX 35-BHLS CM1' RTNS TU SURFACE, LANDED W/SHUE .. ---------- ............@3449' FLOAT COLLAR @33b3', BUNPED PLUG W/20ØØ-J..:'SI, FLUATS DID HuLD ............ BLED BACK 2-BBLS, C. 1. :.'. @1115-HHS. 1130-1401£'. . . WOC, CENTER UP 9-5/8" CSG, WASHED STACK/FLOW LINE, S HHT CLI::.HN :"'ll b 1400-2401£'. . . P/U STACK & HUNG, SET VETCO 9-5/8" X 12". LSG HGH W/3t1kS' RG W r. I'IAIJ~ ............CSG ROUGH CUT, REMOVED RENTAL DSA& SPACER SPOUL. MADE FIN~ CUI, ............INSTALLED 9-5/8" VETCO CWC PACK OFF ASSLY. RESET SlACK. I::.N· ERZIIJED ............PACK OFF & TESTED TO 30Ø0-PSI F/15-NINS, CON'f'D CLEHN PITS. FULL RTNS THRU OUT CMT JOB. II ----....----.,-.......... ...,...__......~R..·......·.._.~'......... .... ,'" .... ... Remarks from øøøø to 0600 hrs ØØØØ-060Ø...N/U BOP & CLEANING tr1UD PITS. Comments <Union Drilling Only) WALK AROUND PUMP HOUSE NO EXC PI.lmp Vlodel Type St ro k e :1*1 G/D PZltZ! T 10. #2 G/D PZ10 T 1Ø. _._-~.__._._. ....-...-..--.-....-----.--. .,,- .'....._--..--...-........... Liner SPM Pres. Slow SPM Slow Pres þ.5 0. 0. 5B. 0. b.5 0. I 0. 52. Ilt. __.,......___......_._,_.__..._.~~_ ........_........_... ,._, ..,". ._...___.....__.__..__.__..... ...... . ...._. ,_.... "~' ........... ..._................, ,........_~.._..<..... .,_. ..M.... ....._ _......_...~.._._,-..... .._ . ...... .,... -.- '. ...... :-:... r..··-····-······--····...·····..·..······....··--········-··.-... .....--...-..-.--.... '..... ................ . ......,..... -......... ......-.......... ...... .... Lease:IVAN RIVER Field Well #44-36 IVAN RIVER Since Spud Days 20 Hours na Dj·...l 9 h¡-"'s Down h¡-"'s Tri p h¡-"'s Total GP 1 HV ÜP na na 4. 25Ø.. 12'~. '7 ·1' Ii 1J.at e. .' .1 #1"";":+ ~ IILI.~/ILlj:::/·-:)''::'1 I ._J I I I II II /I II II II II II II I¡ II .__J! I ! J Intermediate Production Liner Top Bottom~ 9. 625"1~ ~4~~._........_...._.~.~.~~.~._~:~~_~......_.._......_... ~..~_.'~..:~.._............ t~.. ,..... ..... .lll..I.1 ,... . .........., . -.......--......-... ... .......-... ..... "'..'" . ..... .. I Hi g Contt...act o¡-' tGRACE DRILLING Lu. I Amount/Cum Amount Foreman 88Y61 1$ 1898732 MCHLLiSr~H FTG ElD lVD na 8308 6437 Slot Report AFE # # 15 # 21 321060 AFE Amount Daily 1i 3, 2 IZ1 III . øø ~:Ii I~I,-\d Type ,DISPERSED 1~1ud ¡" eight 10. pcf' TD . 831¿¡/3 CI_\rrent Operat ion: CEI~1ENT 7" CSG Current Formation:na HV JJL 21"4. i::: Cond'-~ç'tot~ CSQ Su¡·...face Csg 20. "I~ 94 13.375"@ 9tZ1a II Remarl·{s "11 __.~.......__,_.____._........._..~__.._.____...~._....._...._.._"-...............-...._._.....__....._..._...,0._... '. ØøøØ - iZl4ØØ... BRK I-<ELLEY - POOH & L Y I:ON 5" HW.ùP & BHA 1Z14ØØ - iZl6Ø0... PULL ¡"JEAR BUSHING - SI::.T TST PLUG & CHG R(-) VIS TO -," & TST SHI-il::: Ø60Ø - 203Ø... R/U & RUN 7" CSG - FLT SHUE lit 83ØS' & FL T CULLAR Ii' 8261' 21213121 - 24Ø0...CIRC & RECIP CSG - CIRC 11Z1 BBLSl:AUSTIC WITH RIG. SWITCH TLJ HOWCO,..............DRUP PLUG #1 & TST LINES - PUMP DUAL SPA8ER H20, & SUP~R FLUSH & ..............H20 & 95 BBLS OF CMT SLURRY Ir"···:--· ............---..--..- ....._.........._._.......__..,_..~...- .._.._...._.._.~..._. ......'.. ...... ...... .......-..-......-.... .............. ..- ......... ........ ....... .......~....._..._... ." . ,. ... ,... . .. ......... Ii II Remarks from ØØØ0 to 0600 hrs ØØ00 - 01 Ø0. . . PUI~IP LAST 3Lt BBLS OF CN r SLUHR 'y' (::iIl\¡I,. HHLHD 344, .25't. C ;:;·R-..s l!t . 1 ~¡t,. .............. HR-5) TO A SLURRY w'r OF 13.2 PPG - TUTAL 01- 129 BBLS (t.50 SX) ..............& DISPLACED - PLUG BUMPED WI1H 14 BBLS OVER ~rH~OHHrIC~L UlbPL~C~M ..............MENT - CIP @ Ø10Ø HRS - RECIPRUCATED CBG l'HRUU8HUUT JUB - Uk - Ø1ØØ 02ØØ...WOC / 020Ø - 030121... INJECT DOWN ANNULUS WITH HUWCO 1.5 ANNULAR VOLUME Ø3ØØ - 0600...WOC Comments (Union Drilling Only) #1 GID PZ11Z1 #2 GID PZ10 HOWCD UN1T - NU EXCEPTIONS - H~LD PRI:::-JUB SHI-El'Y ClvlT JOB - DID \ OT HAVE TO USE 1~lfo:¡NLIFr -----..-....-. ---'-'.-'-'-"-.-'--'.'-'-'-' '-" ...-..----.-..... .- .. .-"... ...... ..... ... .' ... ,...... ..... Ii Type Stroke Liner SPIV Pt"'es. Slow SPIV Slow Pres II . II T 10. 6.5 5B. 4ØØ. 51. IZI. II T 10. b.5 0. 0. 55. 0. .._____..._..__..._..._.._.,__..........._. ........._,.;...._............_ ... ..". ......' ........1 WALK - A-BOUT RIG FLOOR ß MEETINGS BEFORE CSG JOB & Pump Model .". , .:.'. ..-'.:....,-', IVAN RIVER #44-36 IRU 44-36 DAY 1 (2/10/93) 20" @ 94' CONT'D TO MOVE RIG. ACCEPTED GRACE RIG #154 AT 0600 HRS. MIXED MUD. DRILLED 17-1/2" HOLE TO 136'. STABALlZER HUNG UP ON THE 20" DRIVE SHOE. POOH. IRU 44-36 916'/619' DAY 2 (2/11/93) 20" @ 94' CONT'D POOH. DRESSED 20" DRIVE SHOE AT 94'. RIH WITH BHA, 17.5" STAB WOULD NOT PASS SHOE. POOH. DRESSED 20" DRIVE SHOE. R1H AND DRILLED 17-1/2" HOLE FROM 136'-755'. IRU 44-36 2234'/1318' DAY 3-5 (2/12-14/93) 20" @ 94' DRILLED 17-1/2" HOLE TO 916'. SHORT TRIP. POOH. RAN AND CEMENTED 13-3/8" CASING AT 908'. REMOVED DIVERTER. INSTALLED AND TESTED BOPE TO 2000 PSI, OK. RIH AND TAGGED CMT AT 854'. TESTED CASING TO 1500 PSI, OK DRILLED 12-1/4" HOLE TO 916'. PERFORMED LEAK OFF TEST, GOOD. DRILLED 12-1/4" HOLE TO 1654'. TRIPPED FOR BHA. DRILLED 12.:.1/4 HOLE TO 2234'. IRU 44-36 2234'/1318' DAY 6 (2/16/93) 20" @ 94' DRILLED 12-1/4" HOLE FROM 2234'-2634'. TRIP FOR BIT. DRILLED TO 2834'. · .. "." . IVAN RIVER #44-36 IRU 44-36 2234' /1318' DAY 7 (2/17/93) 20" @ 94' DRILLED 12-1/4" HOLE FROM 2834'-3400'. SHORT TRIP. IRU 44-36 2234'/1318' DAY 8 (2/18/93) 20" @ 94' DRILLED 12-1/4" HOLE FROM 3400'-3453'. WIPER TRIP. CHANGED TO 9-5/8" RAMS. R/U AND RAN 9-5/8" CASING. IRU 44-36 4290' /887' DAY 9-11 (2/19-21/93) 20" @ 94' 0.484 PSI RAN 9-5/8" CASING TO 3453'. CEMENTED 9-5/8" CASING WITH 270 BBLS CEMENT. WOC. REMOVED BOPE. SET SLIPS. CUT CASING. INSTALLED AND TESTED PACKOFF, OK. INSTALLED BOPE, AND TESTED TO 5000 PSI, OK: RIH AND DRILLED CEMENT F/3342'-3365'. TESTED 9-5/8" CASING TO 1500 PSI, OK. DRILLED 8-1/2" HOLE TO 3465'. PERFORMED L.O.T., OK. DRILLED TO 4290'. IRU 44-36 5025' /735' DAY 12 (2/22/93) 20" @ 94' 0.484 PSI DRILLED 8-1/2" HOLE TO 4290'-4452'. TRIPPED FOR BIT. DRILLED FROM 4452' -5025'. . .,.","., . . ....... IVAN RIVER #44-36 IRU 44-36 6235'/1210' DAY 13 (2/23/93) 20" @ 94' 494 PSI DRILLED 8-1/2" HOLE FROM 5025'-5564. SHORT TRIP. DRILLED FROM 5564'- 6235'. IRU 44-36 6866' /631' DAY 14 (2/24/93) 20" @ 94' 13-3/8" @ 908' 9-5/8" @ 3449' 499 PSI DRILLED 8-1/2" HOLE FROM 6235'-6306'. SHORT TRIP. DRILLED FROM 6306'- 6866' . IRU 44-36 7100'/234' DAY 15 (2/25/93) 20" @ 94' 13-3/8" @ 908' 9-5/8" @ 3449' 499 PSI DRILLED 8-1/2" HOLE FROM 6866'-7050'. SHORT TRIP. DRILLED FROM 7050'- 7082'. TRIP FOR WASHOUT. DRILLED FROM 7082'-7100'. IRU 44-36 8120' /1020' DAY 16-18 (2/26-28/93) 20" @ 94' 13-3/8" @ 908' 9-5/8" @ 3449' 520 PSI DRILLED 8-1/2" HOLE FROM 7100'-8120', CIRC & COND FOR LOGS, RAN ATLAS GRAND SLAM (DIL-GR-SP-CNL-DENSITY-CALlPER). RUN #2 4 ARM CALIPER. RUN #3 SBT 3450' - SURFACE RUN #4 DIA-LOG 64 ARM CSG CALIPER. RIGGED DN LOGGERS. TEST BOPE. TRIP IN W /RITS. .\ .,ì IVAN RIVER #44-36 IRU 44-36 8308' /188' DAY 19 (3/01/93) 20" @ 94' 13-3/8" @ 908' 9-5/8" @ 3449' 522 PSI RIH TO 3425' W/RTTS. SET TOOL PRESS 9-5/8" CSG TO 4100 PSI. 30 MINS. GOOD TEST. POOH DN RTTS. RIH W/BHA. DRILLED 8-1/2" HOLE F/8120'8308'. CIRC & COND HOLE FROM CSG. POOH BREAKING 5" D.P. IRU 44-36 8308' DAY 20 (3/02/93) 20" @ 94' 13-3/8" @ 908' 9-5/8" @ 3449' 7" @ 8308' 522 PSI BREAK KELLY 4D 5" HWDP & BHA. R/U & RUN 7" CSG TO 8308' CMT CSG @ 2400 HRS. 550 SXS TRINITY LIGHT W/ADDITIVES. IRU 44-36 8308' DAY 21 (3/03/93) 20ft @ 94' 13-3/8" @ 908' 9-5/8" @ 3449' 7ft @ 8308' 522 PSI CMPTD CMT 7ft CSG WITH 550 SXS TRINITY LIGHT CEMENT PLUS ADDITIVES AT 13.2 PPG. CIP@0100. WOC 1HR INJECTED DOWN BACKSIDE (7" X 9-5/8" . ANNULUS) 100 BBLS 2100 PSI @ 2 BPM. LIFTED STACK. SET CSG ON VETCO . "W" SLIPS CUT OFF CSG. N/U TBG SPOOL TEST SAME. INSTALL 2-7/8" RAMS IN BOPE. RAN STACK TEST. L/D 5" D.P. FROM DERRICK. . . Well IRU 13-31 Exhibit 15 Completion and Cementing Records . . IVAN RIVER FiELD WEll 13·3' CURRENT 20" at 166' j~ ~ DRIVEN ~~.~ 13-318" at 866' 7 ~ CEMENTTOSURFACE~~ ' , ~~FROM~~ ~'m_ ~ CEMENT TO SURFACE ~I.p 11Oo~; ~. TOC AT 5000' (CALCULATED) % ~ ~ ~ ~ ~ \\ ~ ~ ~ ~ ~~ ~ = r ( 7" CASING AT 10,350' C,..SL íö.p ^, ï" :SPðE" / 1/ 5", 15.5#, UNER / FROM 10.028'-11,581' :; NOTE: MIN ID IN HANGER 4.193" / TIW HANGER HAS A PACKER -::: / / - ~////////^- - - L· 7" x HEATER STRING ANNUlAR VOLUME FIUED WITH PROPYLENE GLYCOL ~ 7" STAGE COUAA AT 2793' MIN ID ... 6.171" 2-1/16" x 1-1/2' HEATER STRING TAIL AT 3034' ' XO FROM 2-1/16" -1-112' AT 1226' E,AIŒR CMU SUDING SLEEVE AT 3030' (CLOSED) E¡AKER FH PACKER AT 3075' BAKER "P PROFILE AT 3118' 7" X LONG STRING ANNUlAR VOLUME FIUED WI1H 10% KCI BRINE TIW 4.4" SEAL ASSEMBLY AND lOCATOR SUB IN 1HE UNER TIEBACK BORE AT 10.028' BAKER "R" PROFILE AT 11,138' 2.257" ID 2-7/8" TUBING TAIL AT 11,218' TYONEK SANDS 6 SPF 11,208' -11,238' (Dll) 11,27Z - 11,296' (Dll) BAKER 2-718' DROP OFF GUNS (103' SHOTS FIRED HAVE NOT VERIFIED IF GUNS DROPPED JUNK AT 11,444' DPM TO ... 11,575' GRB 12-30-92 UNOCAL8 .'.....) RKB to TBG Head = 24.2 Tree connection: 2·9/16" 5,000# A SIZE WT 20" 94 13-3/8" 68 9-5/8" 47 7" 29 5" 15.5 Tubing: LS 2-7/8" 6.4 SS 2-1/16" 3.25 SS 1-1/2" 2.75 L ~ B L ~ NO. Depth OD 24.2' Iva~·~· Unit Wel..3t Actual 11/1 0/00 CASING AND TUBING DETAIL GRADE CONN ill TOP 19.124 Surf 12.415 Surf 8.681 Surf 6.184 Surf K-55 N-80 N-80 Butt Butt Butt . N-80 N-80 J-55 Butt CS Hydri1 lOrd 2.441 Surf Surf 1,225' ill BTM. 166' 866' 3,460' 10,350' 11,5~1' 11,218' 1,225 ' 3,033' Item 13..5/8" Dual National Hanger. LS B~VP BADI Long String Slidjng Sh::eve, 2-7/8", Baker, "CMU" (Closed) Pac1œr, Baker Mod "FH" Nipple, Baker Mod. "P" Bridge Plug Hi!ater String Landing Nipple, National Crossove~, 2-3/8" Butt P x 2-l/16" CS Hydril P Crossover, 2-1/16" CS Hydri1 B x 1-1/2" lOrd Pin Mule SHoe, 1-1/2", lOrd , I DV @ 2,793' I 1 3,030' 3.750" 2.312" 2 3,075', 5.968" 2.44" 3 3,118' 3.500" 2.312" . C 4 9,622' 1 - I' I 24.2' L ~ A 25.6' 2 >< ~ ' -=::::><::::: B 1,226' ~~5 C 3,033' _ 3 F I ø ---/loò ......ch@ 3,128' ~ I 2,996' 2.25 1.875 ELM ß 7,420' .......,r- ----.r----- DIL Cd>z.5 ' 60-2 '. 75-7 4 Zone 60-2 73-2 74~8 75-3 75-7 Tyonek Tyonek Th.I! 6,882' 7,322' 7,480' 7,532' 7,570' 11 ,208' 11;272' ~~kmm¥¡¡¡j:mE~iHf:!jm¡~¡~~¥.~¡~1imf.4fiii*mmm~imf:>#¡~ PBTD = 7,420' TD = 11,575' MAX HOLE ANGLE = 52° IR 13-31 11-10-00.doc Btm 6,905' 7,335' 7,490' 7,559' 7,591' 11,238' 11,296' Other Equipment Tubing Patch, 71' Long, Owen Oil Tool Covering hole in tubing at 3,045' SLM. Bridge Plug, 2-7/8" w/ 20' of cement dump balled on top Perforation Data Amount 23' 13' 10' 27' . 21' 30' 24' Comments 1-11/16" PJ EJ, 6spf, 0 deg. 136 discs lost in hole 1-11/16" PJ EJ, 6spf, 0 deg. 9 discs lost in hole Abandoned Abandoned Abandoned Abandoned Abandoned Completed: 12/14/92 REVISED: 11/14/00 \. DRAWN BY: TCB ~ APR-25-01 WED 10:19 AN A~ FAX NO. 907 278 7542 P,01 . : STATE OF ALASKA . ~ \. ..' AI.Ã5~·OIL AND GAS CONSERVATION COMM. ...~N \~.\. ¡. 1. Opetal~nspe..,~~~~!.~ ~ 5 ~~~RY~;.~L 0 p'~A TIO ~ \ \ (ï . Pull tubing ._ Altere;asln9_ ..~epa"wèll _ Pullt\Jbm9 Otho~_ 5. Type of WGII: 6. D~tum elavatio':! (DF or KB) Oeveloptneftt 2L ~Iomtory S1raligrçhk; SeNice 2. Name of Operata" At ettsctive depth 24.S' 7. Unit or Property narTie . Iv.an River 6. Well number 13-31 9. Permit number/approval number 92-~ 'æ 10. API number 50-283 -20086 , ,. FieldlPool Ivan RiverjUnnamed f~ø.t" Llnlon 011 Comp'~ny of Califomia (UN9CAL) 3. Address P,O. tÐx 196247 Anchorage, AK_99S19 4. Location of well at sl.l'face 682'N, 699'W of S.!:: Cornel', Seo. 1, 113N, F$W, SM At top of productive Interval (11.206~ 2Q11'N, 624'E of S.W. Comer of Sec. 31, T14N, R8W, 8M (11,57512209'N, 811'Eof S.W. Comer of Sec. 31, T14N, R8W, SM 1 i" p're~ent well oondition summary . Total depth: measlled 11,575' true vertical 8161' At total depth feet teet Plugs (measured) N/A Effective depth: meas~ed 11,444' feet Junk (measured) true veltlcal 8072' feet Casing Length Size Cemented structural 142' 20" Drtlren Conductor Surface 838' 13-3/8· 782 sx Intermediate . 3443' 9-518" 849 $X Production 10,234' 7" 913 sx 1',444'-Bit Junk Measured .depth 166' True vertical depth. 166' 866' 3460' 10,350' 866' 2938' Uner Perforation depth: me3slXed R EC E IV Ëfj' 11 ,20S'-11 ,2:38', 11.272'-11,2~' ·JAN 141993 ~lask.a .Oil.& Gas COilS. lìommission 1UIchoraga 2-7/8",6.4#, N-80 at 11 ,218' - production string . 2-1/16",S.25#, N-80 x 1-1/2", 2.7511, J-55 at3034'-heater string TlW seal assembly at 10,028', Baker FH packer at 3075' true vertical 7912'-7930',7954'-7971' Tubing (size, grade, and measured depth) Packers and SSSV (type and measLl'ed depth) 13_ Stimüla'tïon'ò¡: cement squeeze summary 47 bbls, 17 ppg cmt1tTough DVat 2793', taking retl.rnsüp the 9-5/8" X 7" annulus, 500 P$i. . :Intervals "eated (measured) 30 bbls, 17 ppg emt through DVat 2793', 1800.psi Stage (DV) collar at 2793' 20 bblS. 17 ppg emt tlYough DVat 2793', 2300 PSi . Treatment des;ription ircluding vo lI,m as used and final pressure 14. Represøntative Dailv AveraQe Production, or Injection Data Oil-6bl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subseq.uent to operation j s. Aitachments . Caples of Logs and Surveys run Daily Report of Well Operations ~_ Oil Gas ~_ Suspended _ ..;;. herebÿ'(~~r~~ correct to me tJestot my koowlecJge. Signed G. RUSSEl II Schmidt . Title Drilling Manager Form 10-404 Rev 06/15/88 5180' 1 16. Status of well classification as: o 2725 Service i.~~.. <:4:~ Date S SUBMIT IN Dl.f'L.1CAT< J APR-25-01 WED 10:19 AM AI. . FAX NO. 4iiÞ2:6 7542 P. 03 , . ...- ,-' DAY 55 (11/18/92) 11,575'TD 20" DRIVEN TO 166' 13-3/8" C @ 866' 9-5/8" C @ 3460' P /U STACK INSTALLED EMERGENCY SUPS_ CUT CASING_ INSTALLED AND TESTED PACK OFF, OK. DAY 56 (11/19/92) 11,575'TD 20" DRIVEN TO 166' 13-3/8" C @ 866' 9-5/8" C @ 3460' LANDED eOp STACK. CHANGED RAMS TO 3-1/2". TESTED BOPE, OK. DROPPED THE STAGE COLLAR OPENING BOMB. DAY 57-59 (11/20·22/92.) 11,575'TD 20" DRIVEN TO 166' 13-3/8'1 C @ 866' 9-S/B" C @ 3460' P /U AND RIH WITH RETRIEVABLE PACKER. CIRC. PUSHED OPENING BOMB INTO PLACE.. SET PACKER WITH TAIL AT 2783'. OPENED STAGE COLLAR. CIRC. CEMENTED 9-5/8" & 7" ANNULUS ABove STAGE COLLAR. POOH. RIH WITH CEMENT BOND LOG, STOPPED AT 2330'. P /U BIT AND' SCRAPER. CLEANED OUT TO 2791'. RAN SBT FROM 2790'-SURFACE. INJECTED 50 BBlS AT 5 BBl/MIN. PERFORMËD LO.T. OK. CONrD INJECl1NG FLUID. LAYED DOWN 5" D.P. P/U 3-1/2" D.P. DAY 60 (11/23/92) 1 t,575'TD 20" DRIVEN TO 166' 13-3/8" C @ 866' 9-5/8" C @ 3460' 7" C @ 10,350' 535 PSI PUMPED AWAY. Rt=rpi\¡çf\ ....\.......J V;...:!../ JAN' 1 4 1993 AlasRa .Oil &. Gas Cons. com:.nisslOl1 . Anchorage APR-25-01 WED 10:20 AM AI FAX· NO, 4iiÞ2~6 7542 p, 04 '-.- '''~'/ DAY 61 (11 /24/92) 11,575'TD 20" DRIVEN TO 166' 13·3/8" C @ 866' 9-5/8" C @ 3460' 7" C @ 10.350' 535 PSI PUMPED AWAY FLUIDS AND CUTTINGS. DAY 62-66 (11 /25-29/92) 11,575'TD 20" DRIVEN TO 166' 'J, ,13--3/8" C @ 866' 9-5/8" C @ 3460' 7" C @ 10,350' 541 PSI '.. CONTINUED PUMPED AWAY FLUIDS AND CUTI1NGS. RIH WITH STAGE· COLLAR CLOSING TOOL TO 2790'. PUMPED 30 BBLSCMTTHROUGH STAGE COLLAR AT 2793' AND CLOSED COLLAR. ATIEMPTED TO TEST STAGE COLLAR NEG. POOH. RIH WITH A 6" BIT AND 7" CASING SCRAPER TO 2620'.' PRESSURE TESTED CASING TO 3000 PSI, OK. DRILLED OUT STAGE COLLAR PRESSURE TESTED, NEG.· POOH. RAN AND SET 7" DRILLABLE BRIDGE PLUG AT 2818'. RIH WITH A RETRIEVABLE PKR AND SET WITH TAIL AT 2565', SQUEEZED 16.5 BBLS CMT THROUGH STAGE COLLAR. RELEASE~ RTTS. POOH. TESTED BOPE, OK. TESTED CASING TO 2500 PSI, OK. . CLEANED OUT CMT 2720'·2807' AND TESTED CASING AND STAGE COLLAR TO 2500 PSI, OK. . DRILLED CMT AN.D DRILlABLE BRIDGE PLUG AT 2818', RIH TO 4000'. POOH. P/U A 6" DRILLING ASSEMBLY: CLEANED OUT TO FLOAT COLLAR AT 10260', RETESTED 7" CASING AT 2500 PSI, OK. CLEANED OUT FLOAT EQUIPMENT, SHOE TRACK AND CMT TO 10352'. WASHED 8-1/2" HOLE FROM 10,352'· . 11,575'. POOH. RIH WITH AN 8·1/4" UNDERREAMER. UNDER-REAMED FROM 10,350'-11,468'. WORKED AND CLEARED INTERVAL (COAL) FROM 11,465'- 11560', UNDER-REAMED TO T.D. AT 11,575'. CONDITIONED HOLE FOR 5" LINER. POOH. RAN IN HOLE WITH 5',15 PPF, N"80, BUTTRESS LINER. . R ErE! It.~ :¡'" 1"'0., III ~ . r '~j' r ~ ~ -'- ~ V :io~iJ -; 1\ ",\1 '1.'j '9~";. yJ-\ 'I¡ 1 T l vY' ..t\laska Dil & Ga" Co~- I """f",I$'::I'O)1 i=" .;..Q:. "",,,,hA ,,,. _ . Anchorage APR-25-01 WED 10:20 AM AI FAX NO. 4iiÞ2~6 7542 P. 05 ',-,' '--..' DAY 67 (11/30/92) 11,575'TD 20" DRIVEN TO 166' 13-3/8" C @ 866' 9~5/8" C @ 3460' 7" C @ 10,350' 551 PSI RAN 5" LINER. INDICATIONS OF DAMAGE TO TOP' OF 7" CASING IN WELLHEAD. PULLED 5" LINER AND DRESSED TOP OF 7" CASING, OK. RAN TOTAL 39 JOINTS 5" LINER PLUS LINER HANGER ON 3~1 /28 DRILL PIPE. DAY 68 (12/01/92) ,,' . 11,575'TD 20" QRIVEN TO .166' 1-3-3/8" C @ 866' 9~5/8'1 C @ 3460' 7" C @ 10,350' 551 PSI CONTINUED RUNNING IN WITH 5" LINER ON 3-1/2° DRILL PIPE. TO T.D. AT 11,575'. CIRC. CEMENTED 5" LINER. RELEASED FROM LINER. SET LINER TOP PACKER. REVERSE CIRC. POOH. LAID DOWN 3-1/2" HWDP. DAY 69 (12/92/92) 11,575'TD 20" DRIVEN TO 166' 13~3/8" C @ 866' 9-5/8" C @ 3460' 7;' C @ 10,350' 551 PSI RIH W/2-7/8" D.P. AND 4-1/8" BIT. STOPPED AT 1345'. POOH. BIT LEFf IN HOLE. RIH WITH IMPRESSION BLOCK AND SET DOWN AT.1345'. POOH. TESTED BOPE, OK. RIGGED UP WIRELlNE. R'E r ,- q, ¡; ~' r"t t·, .- ä "'I ~ . J ·...d... ~ '1/ L i'J ~ JAN 1 4 1993 Aíaska Oil & Gas Caris. í;l)mï¡'\¡SSi':)~ Anchorage APR-25-01 WED 10:20 AM AOGCC . FAX NO. 4iiÞ276 7542 P. 06 '--~' "-' DAY 70 (12/Q3/92) 11,575'TD 20" DRIVEN TO 166' 13-3/8" C @ 866' 9-5/8". C @ 3460' 7" C @ 10,350' 551 PSI RIH W/ELECTRO MAGNET TO 1345', NO RECOVERY. RUN #1 W/DUMBLE GRAB TO 1345', NO RECOVERY. RUN #2 W/DUMBLE G~B TO 1345', INDICATIONS OF BEING OVER FISH, NO RECOVERY. RUN #3 W /DUMBLE GRAB TO 1345', ATTEMPT TO ENGAGE; POOH; LEFT 2 ARMS IN HOLE. RIH W/ELECTRO MAGNET TO 1343', NO RECOVERY. RIH W/GLOBE BASKET TO 1345', NO RECOVERY, INDICATIONS OF BEING OVER FISH. RIH WITH "POOR~ BOY" OVERSHOT, SWALLOW FISH, POOH-NO RECOVERY. . . DAY 71-73 (12/04-06/92) 11,575'TD 2011 DRIVEN TO 166' 13-3/8" C @ 866' 9-5/8" C @ 3460' 7" C @ 10,350' 5~1 PSI RECEIVED REPLACMENT DUMBLE GRAB TOOL. RIH AND RECOVERED ONE ARM FROM FIRST DUMBLE GRAB. MADE THREE MORE ATTEMPTS TO RECOVER THE SECOND ARM FROM THE FIRST DUMBLE GRAB, INDICATIONS THAT THE ARM PULLED FREE. RIH WITH A CLOSE CATCH ,OVERSHOT, ENGAGED AND RECOVERED THE SECOND ARM AT 1346'. RIH WITH A BURN" OVER SHOE. BURNED OVER FISH AT 1348'. FISH FELL. RIH TO 1622'; NO . OBSTRUCTIONS. POOH. RIH WITH ELECTRO MAGNET ON WIRELINE. TAGGED FISH AT 2652', NO RECOVERY. R/HWITH GLOBE BASKET. CHASED FISH TO 10,028~ DPM (LINER TOP AT 10,034' DPM). POOH. RECOVERED ONE CONE. RIH. TO 10,028' DPM, ROTATED. DROPPED BALL AND REVERSE CIRCULATED. POOH. NO 'RECOVERY. INDICATIONS THAT THE BASKET HAD ' BEEN ON THE LINER TOP. RIH WITH ONE JOINT OF 2~7/8" DRILL PIPE AND A 4..1/8" MILL. CHASED FISH THROUGH LINER TOP TO 10,066', POOH: RIH WITH 2-7/8" D.P. AND 4-1/8" MILL. CHASED FISH TO 11,444'. POOH TO 9930'. TESTED CASING TO 2500 PSI, NO TEST. POOH. R-rl:IV?'D _ tl:C¡ t. .' . . . . . ". 1 ) 1n9~ L'<N c.¡.~;;¡: v' v,.:-.,,· ~ ~ . l\!as¡<~ <JiI &. Gas Cons. Ct)í(;mlsSicn Ancho¡age APR-25-01 WED 10:20 AM AOGCC .. \..,./ FAX NO. 4ijþ2767542 P. 07 '\"--'"'"' DAY 74 (12/07/92) 11,575'TD 2011 DRIVEN TO 166' 13-3/8" e @ 866' 9-5/8'1 e @ ~460' 7" e @ 10,350' 551 PSI CONTD POOH. RIH WITH 6" BIT AND 7" eSG SCRAPER TO 4000'. POOH. R/U WIRELlNE. LOGGED FROM 11,447'-9945' WIT.H MULTI POLE ACOUSTIC TOOL LOGGED FROM 11,447'·9945' WITH eBL/SBT, GOOD BOND. POOH. LOGGED· FROM 10,026'-6400' WITH CBL/SBT. POOH. '\.\ DAY 75 (12/08/92) 11,575'TD 20" DRIVEN TO 166' 13-3/8'1 C @ 866' 9-5/8" C @ 3460' . 7" e @ 10,350' 551 PSI CONTD POOH. RAN GYRO SURVEY FROM 11,444'-SURFACE. RIH WITH 7" RETRIEVABLE PACKER TO 2913'. PRESSURE TESTED TO 2500 PSI BELOW PKR, OK. RESET PKR AT 2692'. PRESSURE TESTED TO 2500 PSI BELOW THE PKR, BLED OFF, INDICATING THE STAGE COLLAR IS LEAKING. POOH. PRESSURE TESTED THE CASING TO 1500 pSf, OK. RIH WITH 2-7/8"·D.P., A : STRING MILL AND 3-1/2" D.P. TO 11,400'. POLISHED LINER TIE BACK BORE AT 10,028'. DAY 76 (12/09/92) 11,575'TD 20" DRIVEN TO 166' ':,. 1S-:-S/Þ/' C @ aS6' 9-5/8" C @ 3460' 7" e @ 10,350' 551 PSI CLEANED PITS AND MIXED 8.8 PPG KCL BRINE. SPOlTED FILTERED KCL IN THE 5" LINER. POOH. LID 3.1/2" D.P. R'...'·"""-·· .......\ ' I"'La.'~~ .. ~ \.. L ! V t u 'V ~ ... '1 ~ ~')~~ ¡J A )\~ :~; ~:'ij :j,., Afask8, .OiJ & Gas Cons. ComrrÜ$SiCil1 :A.1c!10rage. APR-25-01 WED 10:21 AM AOGCC . FAX NO, ~278 7542 p, 08 ... ---... ',,--0' DAY 77 (12/10/92) 11,575'TD 20" DRIVEN TO 166' 13-3/8" C @ 866' 9-5/8" C @ 3460' 7" C @ 10,350' 551 PSI POOH AND L/D D.P. PULLED WEAR SLEEVE. CHANGED TO 2-7/8'1 RAMS. TESTED TO 5000 PSI, OK. RIH WITH TUBING CONVEYED DROP OFF GUNS AND 2-7/8" TUBING. DAY 78-80 (12/11-13/92) 'I i . 11 ,575'TD 20" DRIVEN TO 166' 13-3/8" C @ 866' 9-5/8" C @ 3460' 7" C @ 10,350' 463 PSI :1. CONT'D TO RIH WITH COMPLETION. TESTED THE SEALS IN THE SEAL BORE AT 10,012' OIL TO 1500 PSI, OK. CORRELATED GUNS WITH WIRELlNE, OK. DISPLACED TUBING VOLUME WITH CLEAN FILTERED BRINE. LANDED HANGER. RERAN CORRElATION LOG, OK. SET FSG PLUG IN THE "F" PROFILE AT 3115'. SET 7" PACKER AT 3056' W/3500 PSI. PULL TESTED TO ENSURE PACKER SET, OK. TESTED HANGER SEAL TO· 2500 PSI, OK. RETRIEVED FSG PLUG. RAN 2-1/16" X 1-1/2" HEATER STRING TO 3034', SET SPY'S. REMOVED BOPE. FOUND LONG STRING BPV NOT FULLY ENGAGED AND INDICATIONS OF DAMAGE TO THREADS IN HANGER. ATTEMPTED TO CHASE THREADS WITH TOOL FROM WELLHEAD SUPPLlER-NE.GATIVE. INSTALLED DUAL X-MAS TREE AND TESTED BONNET AT 5000 P51/15 MIN-OK. TESTED SHORT STRING TREE VALVES AND NIPPLES AT 5000 PSI/15 MIN-OK. WIREUNÉ SET BLANKING PLUG IN LONG STRING SLIDING SLEEVE @ 3028' WLM. ATTEMPTED TO TEST LONG STRING AGAINST PLUG WITHOUT SUCCESS. RETRIEVE PRÙNG & PLUG FROM SLIDING SLEEVE @ 3028' WLM. WIRELlNE IN LONG STRING TO ENSURE SLIDING SLEEVE FULLY CLOSED. . . R'.' \I""' G· ~ t:. f \Ii r::. D.. ' ....., ..~ '- 1... 1... :...'" : H: '1 If 1Qa~ :;r.";'.. ! 'T ...t,,_ Aiaska: Vii & Gas COiiS. Conwr.1ssl0n. Anchorage APR-25-01 WED 10:21 AM AOGCC . FAX NO. 1276 7542 p, 09 , '.""", ',-- DAY 81 (12/14/92) 11,575'TD 20" DRIVEN TO 166' 13-3/8" C.@ 866' 9-5/8" C @ 3460' 7" C @ 10,350' CLOSED SLIDING SLEEVE IN LONG STRING AT 3028'. RAN AND SET PLUG IN "p. PROFILE AT 3115', TESTED TREE TO 5000 PSI, OK. RETRIEVED PLUG AND OPENED SLIDING SLEEVE IN LONG STRING.AT 3028' WLM. DISPLACED BRINE FROM LONG STRING WITH FIELD GAS, FINAL PRESSURE 1200 PSI. CLOSED SLIDING SLEEVE AT 3028'. DROPPED BAR. GUNS· FIRED. RECOVEREq 63 . . BBlS BRINE. MAX RATE 5.18 MMCFD @ 2725' PSI TBG PRESSURE. SET PLUG IN "F" PROFILE AT 3115'. INSTALLED BPV IN SHORT STRING. CLEANING PITS. DAY 82 (12/15/92) 11,575'TD 20" DRIVEN TO 166' 13-3/8" C @ 866' 9-5/8" C @ 3460' r C @ 10,350' 5" L 10,028'-11,581' 458 PSI CONT'D CLEANING PITS. RELEASED GRACE RIG FOR TURNKEY RIG MOVE AT 0600 HRS. MOVING RIG. DAY 83 (12/16/92) 11,57S'TD 20" DRIVEN TO 166' 13-3/8" C @ 866' 9-5/8" C @ 3460' 7& C @ 10,350' 5" L 10,028'..11,581' 458 PSI CONT'D MOVING RIG, , _ of! '\ " rT\ '1""'"..~ ~ ~_."\ R t ... .... I .~ " ;...-t , \.;.. L. 1 " ..-' .. a "I)(:r~ \ ,\ N. \ q. ¡;;."" v..... ~t<:¡i\ 1"I·...··m¡\ßÿ· '" r",,,,e, bOHn' ,.. .~. t'ka Oil & Üas 'IIV"~' ... ø;)1as~ .. ~chOrags APR-25-01 WED 10:21 AM AOGCC . '----- FAX NO, 4iiÞ2767542 P. 10 \0.....-.: DAY 84 (12/17/92) 11,575'TD 20" DRIVEN TO 166' 13,"3/8" C @ 866' 9-5/8" C @ 3460' 7" C @ 10,350' 5" L 10,028'-11,581' 458 PSI CONT'D MOVING RIG. DAY 85 & 86 (12/18 .& 19/92) 11,575'TD 20" DRIVEN TO 166' 13-3/8" C @ 866' 9-5/8" C @ 3460' 7" C @ 10,350' 5" L 10,028'-11,581' 458 PSI CONT'D MOVING RIG. RIG RELEASED 0600 HRS 12/20/92. FINAL REPORT. w~~·~"'f'\ 1'\'0 ':,CC:: .l,.fI~ 1: ~~ 'l!1 r 'U ~p ~...~. r'i \I' .... t'~ L.. 10.,. .- !- ";"....Cf1; 1:10, 1 '=t )"; ,,~.... .}.;.\3 ~ ",' ~ '. ¡.{, \':,$\c\~ r..""".-,:' . .\.í'~("P' '.lot" ".. Gas \,J~)1w.. ...., .""..df;;! v1l C/.' _ -Mt¡Ci......~,. .~'!'\~!:t~!'z.~a ....:.' APR-25-01 WED 10:19 AM AOGCC . "-' FAX NO. 4iiÞ2~6 7542 P.02 '-..,. ,THE CHANGE OF APPROVED PROGRAM BEGAN ON DAY S6 AFTER THE 7 tI CASING BECAME STUCK OFF BOTTOM. THE FOLLOWING IS THE DAILY REPORT OF OPERATIONS FROM THAT DAY FORWARD. ~ REC:EIVED . . JAN 1 4 1993 Alaska Oil !.. Gas Cons. coromi5Sioo Anchorage . . Well IRU 44-1 Exhibit 16 Completion and Cementing Records ."J .'7 IVAN RIVER FIELD WELL 44·1 ..\3 YS CEAi\E:t-!T T~ .::ro 13 (B "2.20' 0' f' Heater String (fluid propelyne glycoQ: 2-3/8', 4.6#, N-80, SCButt at 3015' ID of entire string = 1.995' Production String: 2-7/8', 6.4#, N-80, SCButt. at 7728'. ID of A nipple = 2.25' ID of CMU sleeve = 2.31' CBLTO~ 560.' 22' ~ /~ ~~ /~ #. 22' @ 314' '~ 660 SXS ~ ~ ~ ~ ~ 13-3/8' 61 # ~ @1999' ~ ~ 3285 SXS 1. SS Baker CMU sliding sleeve at 3005' (won't open) Baker FH packer at 3050' ~ ANNULUS TOC @ 4050' ~ (CBt) % DV COllAR AT 6347 % 500 SXS ~ ANNULUS TOC @ 7540' (CBt) ~ % % A % Baker FH packer at 7657 Baker A nipple at 7697 Baker SC-1 packer at 7831' Qeaking) 7905' - 7955' Open Upper Tyonek Gravel packed with 20-40 sand Baker Model 'D' Packer at 7965' Packer Junk and fill at 8098' Sqz Packer @ 8885' , 9-5/8',43.5#,P-110 AND N-80 @ 8948' 1000 SXS ~------------------------_. % T.O.C. @ 8577 W////////////; Bridge Plug @ 8665' ~ " - /j = % - ~ % % %'- -- .. 8715' - 8730' Isolated" Upper Tyonek T.O.C. @ 8760' 8780' - 8785' Squeezed Upper Tyonek 200 SACKS T.D. for the current path "7' 9111' T.D. for the original path = 15,269' GAB 10122192 1 ,',j ~ .~'~" ;···._;t: ."'. ':- -,\t -;~ ,'.,,j . )-' Of .1\ ~'._., . j. '~ ;: -~ ,¡ ¡;¡ {¡ i ~ ~ :.~ STATE 0;: ALASJ<. . svn:.lrr IN DUPI.ICh·¡F.· (1;,." n I h"r hi. øtruct.ìonK on rever.. ~iù.) k;¡iccllvc: July 1. 1~Ci1 OIL AND GAS CO~·::'::RVAïlON ':OMN,ISS¡O;-.J G:ï:;~^·-.f: OI;¡;IGI>AT/OS AND Hz:nIAI.' liO, : !G. í,Y¡'i';\)r -\';;-Zi.Î..: WELL COMPLETION OR OH. 0 WI;\'\' IH:I;I'" 0 e:> R~COMPLEï!ON R¡:PORT AND LOG * ..\DL 3.0ì.30 G. 1" 11'<01.\:>, ALLOTT¡;~ OR TIU/n: NA.)I!: --------- ~ 1~ ',I ( ¡ ~ 1'- T\"PE OF COMI'I.E7ION: ~·J~~~L [X ~\~·(:~I(~ 0 lOA.'; tlJ PRY 0 W,:I,L I Olher pr,p(; 0 PU'I'. 0 OAC" Iu;>;vn. Other 7. UNIT AGnl:l;)I¡';;.;r /'IAMI: , . .~ , . Iva.n River Unit 6, TAr')1 on L&A.Siõ.;oIA)I:J: 2.' XAlf& OJ'' Of'J:J\ATon IV<l:1 River .. '"ii:"WËLL NO. Sta.hcì.a:rd Oil Co;:;¡;any of California, íWI - Operator 3.~.;'Dn¡:ss 07 (J¡:¡;~- , P.O. 130:·: -;'-339 I ,\nchorace, Al1Skr. 99501 . 0ñëATiõ~~' w;:ï.ï.(li, ,,;rCïüëïïiiõiïëliã';:iYalidiiïiïëëõrï¡;¡;lcc wit/, 'ifill ,<jf.1lIJ ,.cguircmcnll)· ~,aurcace b61' ~:orth and 6bl~' vlcGt from Southea.st Corner of : Section 1, T13N, R9W, SB&Þ-1 4' top prod, Internl rtjlorted below . ,... .' '. 44-1 ïõ:-FiËiõ A.~O 1'001., Oil 1\'II.DC.T f" .' .J '.' " Hildcn.t . ~.I .' ~íÚ;ë:-T':;ïL~,-il-;; (¡IIIII,OCII ANO HUUY¡;]( on ARI;A. 1 - T13N-R9~ S~M '." ," J .- .Å t total <\d'U¡ r"ï1......iiï~îiT-NO. I ------------- 10, 6ì;ï66D~D Ifì. Ûï;9Î66;AClU;.0 Ii. OAT ) r~lí8J66dll to prod.) 18. 20, TOfAL D'M' (:~D-121-;-rï:Uõ:ñÄëK 1'.0.. ~ID .. T\'D \22. />. ~1I·ï.Tlrl.,; COMI'I.o" now MANY· 15, 269'~ 8577' ------ 24, ,l'noüüëïï<;¡"II,i~s).õT 1'1111I cO~II'¡.~Tiõ:;¡-.:=;:¡¡r,ïii)TTO O(, NAME (MD AI'ID TVD)' DATY IUIW¡;;U ". 'i~' ~õñõü;';r--¡-f:í:-8TÃ-i;¡-'- ¡., '1iusitn8.- . Ñß.te.n1JSka. Alacka. ¡;;LI':V^'l'6IONB (DJI', RIiD, liT, on, E'l"~-;-- 10. &LEV.' cAs~ii:iD 4 'KB . 123. ':>Tf:RVAI,H, nOTAnY TOOLII . DIIII,L~;O 011' . '~ r 0 - T.D. CAUL& TOOLS 2:;. W.\:¡ DinJ;C1"IO~4L s¡;n\'¡¡y loUD;; 7935'-79551 26. x'yr¡; ¡;\'¡;CTRIC AND OTJlr.n LOGO RUN Yes (Totco) 21. WA.9 WeLl. coa£D DIL, Sonic) ì':icro} FDL.I em-I \ - Yes 28, c,\m:-;r; H¡';COHD (I~"port 1111 .trillUO oct in lOell) ~i:::::"'-~~i~~~ ~r~r':i~:J~CJ~i;::~-- ":;~"~;;;~;~ __~5/8" 4~l~f iJ9L.8r --12.j~" 1500 sacks I __4_·'_ AMOI1I\T ,·tll,Lr.D '. . . 29. 81ZE; 1'01' PID) LI:-;I';H ¡mCORD DOT;~;-;-¡-;~~A:_t~~1 I 30. 'I'UßING In:conD -.-- ¡;Cnl:&N (MO) SI~C D¡;rTII SET (NO) , 1',\CI¡¡;n S&6: ()¡o) _ _.2J1Ô'.:...· 1_~60 , :2 ~/8" 1971( He9,t.er S ~"rinf") 32. ACID, SHOT, FRACTURE, Cr;:.!ENT SQUEEZE, ETC. al. PI:Rr'ORATIOI" I'LCORD (/IIIel'\:al. size and !lumber) Four 1/2" HIF 87'30 I -8785' (Squee ze<i) Four 1/2" l{/F 87151-8730' (Plugged) Four 1/2" H/F 7935' -7955' ,(See back side .for pluge;.ing record) P&,I'TII "INTr.RVA.L ¡MD) A)IOtlNT A:>ÓO 1\1;010 O~· MATERIA.L US&P 8780'_0.7QI:'_ S ~ ,/')('\('\, 1,.... - ,""",'¡' 0-W.,./.. .. <1 uee ze\.c }Lµ_~\l-i2SJ...C~Qt'J~ ßJ5 '-8730' SClueezed ",/25 bbls.-· 15% Ficr. 33.' I'ROPUCTION D"T& I'IRIiT I'ROIHiCTION t I'ROD¡;CTION METHOD tt'iOIl:jll¡/. /Ja~ /ilt, p"'''pin(l-~ize alld IIIPe 01 pump) 0 W&I.I. :nATua (P"oducinl1 or .hllt·ill) 9/27/66 (Testi;~gl F'lo'vin,~'" Shut-In D.n; OF TEST II/0liR'! n:9TED I CIIOK& 1HZ;; I l'noO'N. ¡"OR Ollr-IIIIL. r.AS-) C~·. - WA1·1.:R-¡¡¡¡L; I G"S'OIL ILA.TIO : l'¡;.~T rl;¡IIOD I I I . 10/A/66 ------- 16/ó}¡" ---1- > ---------- ---------- ---------- -------_____ FLOW. TUBINO I'R&89./ C"aINO l'II¡;SSt:RC I CALCl't.ATI;D OIL-DOl.. GAS-I\IC~·. '.WA.TCR-DBI., lOlL OIlAVI'l'\"UI (CORD,) 2'1~TlOClt UATJi: I . 2985 ------ > --------- 5900 I ----------- ---~------______ 34. DISPOSITION ~I' OAS (Sold. ,..cd Jor IUel, L'tnted, ttc.) . .,tusçs \\'~~dSSSDt~Ite Repre æ nt- ~'¡ell Shut-In Q r- r r.: I \/ :- 0 ::itl ve!> ,.' 3:\. LI8T or A.TTAClIM&:>óT'! \ . ~ .... I \. L '. . LOGS HAVE_~EN S~l'{T _____ n::-(' l:~ 19(-)fì . . . 36."1 hercby cert.1.ty tbat ÙO.. torc¡;ol,o; and attached lnfo.rmatlon'1ø-c6I11plctc ond correct IU dctcrwtncd Cram all avallabìe records / ) // " /---:~. ,/ --;'.---" ,.,' . .y (.(' .;..~ , .-'/ ."" .. 'J, I~"!I" '~.....Ot D~,,,·;,,~.t·C.'\¡\:~·:;·\I~rl· n"'enQ"en.o. l? I \~ /60" SIGNED \-_ .",," . -:-__...:.._._~__".III 't't.Tùl:j k') v: ...._ U 'ù1...~\,;; .L v v DATE _, - " --"~, . V.... ~}I.t\.'7'rr~RrpnI\:._______. ANLïll)j\f\\"'.,¡: .. (S~~: Ir.~,·¡'·".t;OqS \-jf ~~ :î': :;...:cs f()r r\,..J(;ítiono) D\')fi.J on R,~v('!r~.:- ~' d\~) / ~ STA1E OF ALASKA a..... ~ OIL AND GAS CONSERVATION C~ION REPORT OF SUNDRY WELL OPERATIONS Plugging _. Perforate Repair well ~_ Pull tubing _ Other 5. Type of Well: 6. Datum elevation (DF or KB) Dellelopment X Union Oil Company of Califomia (Unocal) Exploratory _ 3, Address Stratigraphic _ P.O. Box 196247, Anchorage, AK 99519 Service 4, Location of well at sllface661'N, 664'W, from ti.!:::. l;omer of Section 1, T13N,R9W, SB&M ' At top of productive interval Straight Hole At effective depth Straight Hole At total depth Straight Hole 12. Present well condition summary Total depth: measll'ed true vertical 1. Operations performed: Operation shutdown _ Stimulate Pull tubing _ Alter casing_ 2. Name of Operator Effective depth: 15,269' 15,269' 8,577' 8,577' feet feet Junk (measured) feet feet Plugs (measured) measll'ed true vertical Casing Structural Conductor Surfæe Intermediate Production Liner Perforation depth: measlI'ed Length Size Cemented 2211 660 SXS 3285 SXS 1500 SXS 314' 1999' 8948' 13-3/811 9-5/811 46' KB 7. Unit or Property !lame Ivan River unit 8. Well number 44-1 9. Permit number/approval number 66-21/92-215 10. API number 50-283-10008- 00 11. Field/Pool Ivan River/Unnamed feet See schematic Packer junk at 8098' Measured depth True vertical depth 314' 1999' 8948' 314' 1999' 8948' 7905'-7955',8715'-8730',8780'-8785' true vertical S1RAIGHT HOLE Tubing (size, grade, and measured depth) 2-7/8·,6.5#, N-80, PRODUCTION STRING AT 7728' 2-3/8",4.7#, N-70 HEATER STRING AT3015' Packérs and S$SV (type and measll'ed depth) BAKER "D" PKR AT 7965' SC-1 PKR AT 7831 ' BAKER IIFH" PACKERS AT 7657' AND 3050' 13. Stimulation or cement squeeze summary Intervals treated (measured) 7905'-7955' (GRAVEL PACKED WITH 20-40 SAND) Treatment description including volll11es used and final pressure 14. Representative Dailv AveraQe Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 2500 Subsequent to operation 15. Attà'chments Copies of Logs and Surveys run X Daily Report of Well Operations ~_ Oil Gas ~_ Suspended _ 17. I hereby certify that the foregoing is true and correct to the best of my krowledge. Signed "~RYS. BUS£)"'"'\ S, ~v-ð I.-. rme DRilliNG MANAGER Form 10-404 Rev 06/15i~ 0 Prior to well operation 5,000 2 4,100 2 16. Status of well classification as: o o 2500 Service Date lo J 2.8 /91- SUBMIT IN DUPLICATE · UNITED STATES · DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Budget Bureau No. 42-R356.5. Approval expires 12-31-60. LAND OFFICE ~E.<:h_'!.E!,!g_~_LA1~_~_1s_~ lEAsE N(¡¡;~;~m~---~-U~-?---.------7 UNIT ----c::=-ª-tl--Jliy-e.r-jf.4f:t.~.l:J LESSEE'S MONTHLY REPORT OF OPERATIONS Greater Matanuska & Sta te ___________~_~ª_~}s.!:!___________ Oounty _ª-'1ê_j._t..g,ª__'»"Q.!:'Q.~zh_____ Fie7,d ______________~~P-.!Q!ªJ;º!y______________ ________________ The lollowin~ is a correct report 01 operations and produètion (incluàin~ drillin~ and produ()in~ wells) for the month 01 ________~~..!1~_________________________, 19_§§_, ______~_~~~~~!:~__º!!.__Ç.~~E~!!l__~~__~~_~.?:_~~E~_~~__ .,1~entJ8 address __________~_.___O_.__.B_ºx_L_:_8.3..9___________________________ Oompany ~~.Þ;~~~;t..i~Sy.l.~k-...------7- \ -------~-----------------------------~~~hº:r:::î--Alš1Skš1--9..9.5_0.1_____.____ Sitned ---'=%~~c~~i~tf~----J!.~ç; Phone _________________________________.::_____________________________________________ .,1~entJ:I title î>'i:'frtrìat--SUperìntendent-------- O G GALLONS or BABB111t8 or REMARKS u. FT. or AS GABOLINB W ATIIB (If (If drIUID&. depth; If .hut dow.., .._, (In thousands) RJ:coVIIBBD none, 80 state) <Jato oDd ~~1 ~:":i lIBBOIiDe SIIC. AND ~OI'U TwP. RANGE WIILL ~~~ BABBIILS 01' OIL GBJ. VlTY No. ~......""... CONFDENTIJ..L IVAN RIVER UNIT 4,44-1 SE~ SE~ 1 Tl3N R9H Spudded at 1:00PM, 6-5-66 Drilled 14 3/4" hole to 314' and opened hole to 26 In'' to 314'. Cemen:ed 2211 conductor at 314 I '-lith 660 sacks cemen : . Ins ta II ed HOPE. Drilled 12 1/4" hole to 2000'. Ran D1.1a1 Induction Laterolog and Sonic Log 314' - 200C' Opened hole to 18 5/8" to 2000'. Ran a:ld cemented 13 3/8" casing at 20CO' with 3000 sacks construction cement. Did top job with 285 sacks ce~ent. In~tal1ed ~nd tested Class IV BOPE Drilled 12 1/4" hole to 8948'. Drilllng. DISTRIBUTION: U. S. G. S. - W. J. Linton - 2 Sta te - T. R. Harsha 11 H. C. Jam:"son R. 1. Levorsen L.ß-i1e , NOTE.-There were_____________________________________ runs or sales of oil; _____________________________________________ M cu. ft. of gas sold; ____________________________________________ runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.-Report on this form is required for eaoh calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. Forxn 9-329 (lanuary 1960) 18-25766-8 u. S. GOVERNMENT PltlNTING OFFICE · UNITED STATES . DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Budget Bureau No. 42-R356.5. Approval expires 12-31-60. Anchorage LAND OFFICE __________________________________ lEASE NUMBER AD.L__1Z2.4.2._____________ UNIT -__________l~.an__Ri\œ.r.__Unit_ 44· LESSEE'S MONTHLY REPORT OF OPERATIONS Greater Matanuska & State __._____~_~~_~"~~______________ Oounty _~~~~~~~__~~.:~~-ª~___~_ Field _____.~~E_~_~_:_~_~_~EX_____.___________________.____________ The lollowint is a correct report 01 operations and production (includint drillint and producin~ wells) lor the month 01 ________J.u1..y_________________________, l~iJ___, .st.and.a.r.d._.D.iJ-_£Dmp.an.y__.o.:L ç~' j f,,.rni;¡ _______ ~~:~~__~~._8~=-~~~~~~-~;~:~~~:9i~î:=:== :;:~:~~~~~# Phone ___________________________________________________________________--------------- Atent 8 title -Ðis-t:'l'i-et;---Sü1'e'l'i:nt:e nde nt'------- GALLONS or BABIIJILS or REMARKS SEC. AND Twp. RANGE WBLL D~... BABBELSorOIL GBAVlTY Cu. For. or GAS GASOLINE WATBB(If (lfclriDJDa,depth: liohutdowD.O.uae: J( or J( No. PBODVOIl1> (In thousands) RBCOvø:OD none, so state) date aDd =..u::,.~f:;n ~r KMOIiD. CONF IDENT':AL IVAN RIVER JNIT #44~1 SE~ SEk T13KR9t.¡ Depth 8948'. Ran logs and t00k sidew~ll samples. Cemented 9 5/8" casir:g at 8943' with:"OOO sacks cement around shoe a~d 500 sa:ks throLgh DV at 6347'. Removed BO:?E, installed 10"-5;)00 psi J.anding head, installed \;lass IV BCPE and tested to 3000 psi - ok. Drilled ou~ DV and tested to 3000 psi -ok. Drilled ou~ float collar, cement and &hoe and drilled 8 5/8" hole to 10,81C'. Cored. Core #1, 10,810' - lC,828'. ~ecovere¿ 18'; Drilled ahead to 1l,~l6'. Ra-:1 logs. Drilled ahead to 13,344'. Circulated and conditioned mu1. Drilled ahead to 13,427'. ~an logs. Drilling a~ 13,699'. DISTRIhUTICN: U. S. G. S. - W. J. Lintcn - 2 State - T. R. }~rsh&ll H. C. :amison R. 1. Levorsen File " ~ NOTE.-There were ______________________________________ runs or sales of oil; ___________________._________________________ M cu. ft. of gas sold; ____________________________________________ runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.-Report on this form is required for eaoh calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th of the succeeding month, unleBsotherwise directed by the supervisor. Form. 9-329 (1anuary 1950) 16-25766-S U. S. GOVERNMENT PRINTIHG OFFICE . . Mechanical Integrity 20 ACC 25.252 (d) (e) Mechanical integrity on IRU 14-31 will be verified as required in parts 25.252 (c) 6 and 252.412. The 27/8 X 7 annulus was recently tested to 1500 psi and the tubing-packer-rathole tested to 1500 psi prior to the well being perforated. Because of equipment constraints and available fluid volumes, a limited step rate test is planned that should provide breakdown pressure and some injectivity data. A maximum test rate of 6 BPM is being planned, which is about twice the disposal rate. Pressure fall-off data will also be recorded. A second annulus pressure test will be performed with an AOGCC witness prior to disposal operations. Subsequent testing, monitoring, and reporting will conform to the requirements of these sections.
