Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
197-093
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, August 4, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1Q-08A KUPARUK RIV UNIT 1Q-08A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/04/2025 1Q-08A 50-029-21225-01-00 197-093-0 W SPT 5363 1970930 1500 2400 2400 2400 2400 100 100 100 100 4YRTST P Guy Cook 7/2/2025 Test completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1Q-08A Inspection Date: Tubing OA Packer Depth 780 1800 1770 1760IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC250701125413 BBL Pumped:0.6 BBL Returned:0.8 Monday, August 4, 2025 Page 1 of 1 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov April 20, 2023 Mr. Luke Lawrence Wells Manager ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Re: Docket Number: OTH-23-009 Notice of Violation - RESCINDED Kuparuk River Unit 1Q-08A (PTD 1970930) Dear Mr. Lawrence: The Alaska Oil and Gas Conservation Commission has reviewed ConocoPhillips Alaska Inc.’s response to the subject notice of violation dated April 12, 2023. The notice of violation is rescinded. Sincerely, Brett W. Huber, Sr. Jessie L. Chmielowski Gregory C. Wilson Chair, Commissioner Commissioner Commissioner cc: Greg Hobbs (Greg.S.Hobbs@conocophillips.com) Phoebe Brooks Victoria Loepp Chris Wallace Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.04.20 10:30:25 -08'00' Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.04.20 10:32:30 -08'00' Gregory Wilson Digitally signed by Gregory Wilson Date: 2023.04.20 10:34:21 -08'00' April 12, 2023 Brett W. Huber, Sr. Chair, Commissioner Alaska Oil and Gas Conservation Comm’n 333 West Seventh Avenue, Suite 100 Anchorage, Alaska 99501-3572 Jessie Chmielowski Commissioner Alaska Oil and Gas Conservation Comm’n 333 West Seventh Avenue, Suite 100 Anchorage, Alaska 99501-3572 Gregory Wilson Commissioner Alaska Oil and Gas Conservation Comm’n 333 West Seventh Avenue, Suite 100 Anchorage, Alaska 99501-3572 VIA E-MAIL (samantha.carlisle@alaska.gov) Re: Docket Number OTH-23-009 Notice of Violation Kuparuk River Unit 1Q-08A (PTD 197-093) Commissioners Huber, Chmielowski, and Wilson: This letter responds to the above-referenced notice of violation (NOV) received by ConocoPhillips Alaska, Inc. (CPAI) on April 3, 2023. The NOV states that CPAI failed to comply with Conservation Order (CO) 261B requirements for remedial operations on a Kuparuk River Unit (KRU) injector (KRU well 1Q-08A) with “pressure communication or leakage between the tubing and tubing- casing annulus.” Respectfully, this is a case of miscommunication. At no point did KRU well 1Q-08A indicate pressure communication or leakage between the tubing and tubing-casing annulus. Inner annulus (IA) pressures have been stable with significant differential between IA and tubing pressure, as shown in this pressure chart from October 12, 2022 to April 10, 2023: Luke Lawrence Wells Manager 700 G Street, ATO 1576 Anchorage, AK 99510 (907) 265-6306 (office) luke.j.lawrence@conocophillips.com By Samantha Carlisle at 10:26 am, Apr 13, 2023 2 Because there was no leak or pressure communication, no repairs were conducted. As shown in the 10-404 submitted by CPAI on January 23, 2023 with respect to work done on December 23, 2022 (full 10-404 attached; schematic pasted on the left), the operation was for conformance only, not remediation, as the patch was installed below the production packer to shut off existing perforations. The 10- 404 referred to this operation as a “Selective C Sand Patch.” It diverted water from the Kuparuk C sand to the Kuparuk A sand to reduce water production in 1Q-08A’s offset producer. Because the well was not repaired, the AOGCC-required MIT on January 30, 2023 did not test the integrity of completed repairs (which had not been done), but rather tested tubing integrity as it existed both before and after the selective C sand patch operation. The successful MIT showed 1Q-08A had no leak or pressure communication between the tubing and the annulus. This confirmed the above data that showed stable pressures before and after the selective C sand patch operation. The above demonstrates that there was no tubing leak in 1Q-08A, contrary to the factual summary in the NOV. CPAI has investigated, and we have determined that we are partly to blame for a series of miscommunications that led the AOGCC to the mistaken conclusion that 1Q-08A had a tubing leak that required repair. We determined: x The CO 261B sundry matrix requires a 10-403 for a “tubing patch” in injection wells but does not require a 10-403 for installation of a “mechanical device (plug or packer) to control fluid movement in zone.” x Here, the selective C sand patch operation met the “mechanical device” definition in the CO 261B sundry matrix, as it comprised two packers with spacer pipe between them over existing C sand intervals, and so did not require a 10-403. x However, CPAI commonly files 10-403s for any patches installed in injectors, including conformance patches / mechanical devices to control fluid movement in zone, even though conformance patch sundries are not required by the CO 261B sundry matrix. 3 x In this case, when completing the 10-404 on January 23, CPAI determined that a 10-403 had not been submitted. CPAI immediately informed the AOGCC; in that conversation, CPAI may have incorrectly referred to the operation as a “tubing patch” (no tubing was ever patched). Under the belief that the well was being repaired, the AOGCC then required an AOGCC-witnessed MIT. x The 10-404 submitted by CPAI on January 23 was partly incorrect and confusing, as it referred to the operation as “repair well” and “patch” rather than “plug perforations” and “mechanical device (plug or packer).” As described above, and as shown in the 10-404 schematic above, the 10-404 also contained information that clarified the operation was a mechanical device to control fluid movement in zone, rather than a well repair / tubing patch, but in context it was reasonable for the AOGCC to be confused by our submittal. x In the NOV, the AOGCC states that on January 30, at the AOGCC-required MIT, the AOGCC MIT inspector was told that the well had a tubing leak. CPAI has not been able to confirm whether this occurred, but if it did, the information provided to the inspector was incorrect. In light of the above, CPAI believes that we contributed to miscommunications that led the AOGCC to erroneously believe that 1Q-08A had a tubing leak. However, no tubing leak actually existed (as shown in the above pressure data and the successful MIT), no “tubing patch” was installed, and no “repairs to the well” were undertaken. For these reasons, no Form 10-403 was required under the CO 261B sundry matrix, 20 AAC 25.280,1 or Area Injection Order (AIO) 2C, Rule 7.2 Therefore, no violation occurred. For completeness, following are responses to the AOGCC’s three specific questions in the NOV: x When did KRU 1Q-08A begin to indicate pressure communication or leakage between the tubing and tubing-casing annulus? As shown in the pressure data chart above and successful MIT on January 30, no pressure communication or leakage between the tubing and tubing-case annulus existed in 1Q-08A. 1 20 AAC 25.280(a): “An Application for Sundry Approvals (Form 10-403) must be submitted to and approved by the commission in order to enter a well and conduct one or more of the following types of well workover operations: (1) the perforation or reperforation of casing; (2) stimulation; (3) the pulling of tubing; (4) alteration of the casing; (5) repairs to the well” (emphasis added). Here, the well was not repaired. 2 AIO 2C, Rule 7: “Whenever operating pressure observances of pressure tests indicate pressure communication or leakage of any casing, tubing or packer, the operator must notify the AOGCC on the first working day following the observation, obtain AOGCC approval of a plan for corrective action, and when an USDW is not endangered, obtain AOGCC approval to continue injection.” Here, at no point were there any indications of pressure communication or leakage. 4 x Describe CPAI’s policy and practice when an injection well indicates pressure communication or leakage of any casing, tubing or packer? CPAI’s policy and practice are as follows: 1. Injector pressure data (similar to that shown in the pressure data chart above) and annuli bleed trends (where applicable) are monitored for problematic pressure trends. Where pressure or bleed data may indicate a potential problem, or where otherwise required by AOGCC or CPAI, MITs are conducted. 2. CPAI reports any suspected annular communication to the AOGCC immediately (or, in accordance with AIO 2C, Rule 7, on the next working day), together with all information required under 20 AAC 25.280 and AIO 2C, Rule 7. Reports include well name, PTD number, suspected failure type, a brief plan for diagnostics and monitoring, a current well bore schematic, and a 90-day pressure data plot (the same type of data shown in the chart above). 3. After diagnostic work is complete, results and monitoring data are reported to the AOGCC, with additional diagnostic plans, if applicable. 4. Once appropriate repairs are identified, sundries are submitted for AOGCC approval, in accordance with 20 AAC 25.280 and AIO 2C, Rule 7. x Describe what has or will be done in the future to prevent this violation’s recurrence. As explained above, a violation did not occur. While CPAI contributed to miscommunication that led AOGCC to erroneously believe that 1Q-08A had a tubing leak, no tubing leak actually existed (as shown in the pressure data and the successful MIT), no “tubing patch” was installed, no repairs were conducted, and no 10-403 was required under the CO 261B sundry matrix, 20 AAC 25.280, or AIO 2C Rule 7. To prevent recurrence of this type of miscommunication, CPAI has emphasized to both the town- based engineering teams and North Slope-based execution teams the importance of completing AOGCC forms completely and correctly, and the importance of clear communication to AOGCC at all times. CPAI will also endeavor to continue its practice of submitting 10-403s for conformance patches on injectors, even though such 10-403s are not required by the CO 261B sundry matrix, 20 AAC 25.280, or AIO 2C, Rule 7. Sincerely, Luke Lawrence Wells Manager ConocoPhillips Alaska, Inc. Attachment – January 23, 2023 Form 10-404 Digitally signed by Luke Lawrence DN: C=US, OU="GPBU ", CN=Luke Lawrence , E=luke.j.lawrence@conocophillips.com Reason: I have reviewed this document Location: Date: 2023.04.12 19:11:10-08'00' Foxit PDF Editor Version: 12.0.1 Luke Lawrence 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured feet None feet true vertical feet None feet Effective Depth measured feet 5979', 7019', 7069'feet true vertical feet 5362', 6125', 6155'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 6005' MD 5384' TVD Packers and SSSV (type, measured and true vertical depth) 5979' MD 7019' MD 7069' MD 495' MD 5362' TVD 6125' TVD 6155' TVD 495' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 3544' Burst Collapse Production Liner 6176' 1873' Casing 5554' 4-1/2" 6210' 7866' 6539' 3698' 103'Conductor Surface Intermediate 16" 9-5/8" 75' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 197-093 50-029-21225-01-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025641 Kuparuk River Field/ Kuparuk River Oil Pool KRU 1Q-08A Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 103' ~ ~~ INJECTOR ~~ ~ N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker SABL Perm Packer Packer: PIIP Patch Packer Packer: PIIP Patch Packer SSSV: Camco DB Nipple w/ NO GO Allen Eschete allen.eschete@conocophillips.com (907) 265-6558 Intervention Engineer Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov 3733' 7868' 6540' 7418' 6345' 7026-7060', 7365-7375', 7399-7441', 7446-7450', 7575-7588' 6129-6150', 6319-6324', 6336-6356', 6359-6361', 6416-6422' By Samantha Carlisle at 2:02 pm, Jan 23, 2023 Digitally signed by Allen Eschete DN: CN=Allen Eschete, E=Allen.Eschete@ ConocoPhillips.com Reason: I am the author of this document Location: Date: 2023.01.23 13:13:27-09'00' Foxit PDF Editor Version: 12.0.1 Allen Eschete DTTMSTART JOBTYP SUMMARYOPS 8/2/2022 PUMPING TRACKING ONLY FREEZE PROTECTED TBG WITH 34 BBLS DIESEL. JOB COMPLETE 10/24/2022 OPTIMIZE WELL RIH WITH 2" DJ NOZZLE. DRY TAG AT 7,418' CTMD. CLEANOUT DOWN TO HARD TAG AT 7754' CTMD (166' OF RATHOLE) WITH SLICK SEAWATER. MAINTAIN 1:1 RETURNS THROUGHOUT. JOB COMPLETE. 10/28/2022 OPTIMIZE WELL DRIFT & TAG TD @ 7412'RKB. DRIFT W/ DUMMY PATCH TO 7100'RKB. RUN PDS CALIPER FROM 7150' RKB TO SURFACE. READY FOR PATCH INSTALL. 11/17/2022 OPTIMIZE WELL BRUSH n' FLUSH PATCH INTERVAL FROM 6900'-7200' RKB. READY FOR PATCH 12/9/2022 OPTIMIZE WELL SET QUADCO 4.5" SPECIAL CLEARANCE PIIP LOWER PACKER MID-ELEMENT AT 7072.0', CCL TO ME = 10.6', CCL STOP DEPTH = 7061.4'. DISCOVERED ICE IN LUBRICATOR ONCE BACK AT SURFACE, UNABLE TO SHUT SWAB VALVE, SHUT MASTER VALVE, CALL FOR PUMP SUPPORT TO ASSIST IN THAWING ICE IN LUB, FREEZE PROTECT TUBING AGAIN WITH 45 BBLS HOT DIESEL, UNABLE TO FUNCTION SWAB AFTER PUMPING, GREASE CREW SERVICED SWAB, FINISH RIG DOWN. JOB COMPLETE, READY FOR SL TO SET UPPER PATCH ASSEMBLY 12/9/2022 PUMPING TRACKING ONLY FREEZE PROTECT PUMPED 45 BBLS DSL FOLLOWED BY 17 METH FRMO MFB THROUGH FL DOWN TBG ( JOB COMPLETE ) 12/23/2022 OPTIMIZE WELL ((SELECTIVE C SAND PATCH))SET 4.5'' PBR, SPACER PIPE, ANCHOR LATCH ASSEMBLY @ 7037' RKB. (UTILIZING 2.75'' DPU) SET 4.5'' QUADCO P2P, SPACER PIPE, ANCHOR LATCH ASSEMBLY @ 7016' RKB. SET 4.5'' TEST TOOL @ 7016' RKB & OBTAIN PASSING MITT TO 2500, PULLED TEST TOOL. JOB COMPLETE. PBR: CBRR45007 P2P: CPSCHP45010 ANCHOR LATCH: CPAL4502 1Q-08A Patch Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 7,418.0 1Q-08A 10/28/2022 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Upper packer 1Q-08A 12/23/2022 fergusp Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 28.0 103.0 103.0 62.58 H-40 WELDED SURFACE 9 5/8 8.76 35.5 3,733.1 3,544.1 36.00 J-55 BTC PRODUCTION Post S/T 7 6.28 33.7 6,210.0 5,554.4 26.00 J-55 BTC WINDOW 7 6.00 6,194.0 6,206.0 5,551.1 LINER 4 1/2 3.96 5,992.9 7,866.0 6,538.8 12.60 L-80 NSCT Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 27.0 Set Depth 6,005.3 Set Depth 5,384.4 String Ma 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.75 Grade L-80 Top Connection EUE8rdMOD ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 27.0 27.0 0.04 HANGER 10.000 McEVOY GEN 3 TUBING HANGER 4.500 495.1 495.1 0.12 NIPPLE 5.563 CAMCO 'DB' NIPPLE w/NO GO PROFILE 3.875 5,931.8 5,323.3 33.76 SLEEVE 5.500 BAKER CMU SLIDING SLEEVE 3.812 5,978.0 5,361.7 33.74 ANCHOR SEAL 5.563 BAKER KBH-22 ANCHOR SEAL NIPPLE 3.875 5,978.7 5,362.2 33.74 PACKER 5.312 BAKER 'SABL' PERMANENT PACKER 3.875 5,983.9 5,366.5 33.74 BLAST JT 5.250 BLAST JOINT PUP (OAL 9.57') 3.833 5,993.4 5,374.5 33.73 NIPPLE 5.563 OTIS 'X' LANDING NIPPLE w/3.812 SELECTIVE PROFILE 3.812 5,994.6 5,375.4 33.73 LOCATOR 5.140 BAKER GBH LOCATOR 3.875 5,995.1 5,375.9 33.73 SEAL ASSY 4.750 BAKER SEAL ASSEMBLY w/10' STROKE 3.875 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,019.0 6,124.5 51.57 PACKER - PATCH - UPR Upper patch assembly speacial clearance 3.66" P2P, XO, Spacer pipe, & anchor latch (OAL 23') TTS PIIP CPSC HP45 010 12/23/2022 2.000 7,024.0 6,127.6 51.69 SPACER PIPE Spacer Pipe CPAI 12/23/2022 2.000 7,037.0 6,135.7 52.01 OTHER PBR, SPACER PIPE & ANCHOR LATCH (oal 32') CPBR 45007 12/23/2022 2.000 7,069.0 6,155.2 52.78 PACKER - PATCH - LWR 4-1/2" SPECIAL CLEARANCE PIIP MID-ELEMENT AT 7072' RKB, OAL 4.89' TTS PIIP CPSC HP45 009 12/9/2022 2.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,992.9 5,374.1 33.73 SLEEVE 4.500 BAKER C-2 LINER SETTING SLEEVE 3.833 5,994.1 5,375.0 33.73 PBR 5.875 BAKER 80-47 PBR 4.750 6,844.9 6,013.2 51.10 NIPPLE 5.000 CAMCO DB LANDING NIPPLE 3.750 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,026.0 7,060.0 6,128.9 6,149.8 C-4, C-3, 1Q- 08A 1/17/2006 0.5 RPERF 2.5" HSD, 60 deg phase 7,056.0 7,057.0 6,147.3 6,147.9 C-3, 1Q-08A 12/31/2005 1.0 APERF 1 SINGLE PERF HOLE w/2.5" gun, w/no orientation 7,365.0 7,375.0 6,319.3 6,324.3 A-4, 1Q-08A 7/28/1997 6.0 IPERF 60 deg. ph; 2.5" HSD 7,399.0 7,421.0 6,336.1 6,346.8 A-3, 1Q-08A 7/29/1997 6.0 IPERF 60 deg. ph; 2.5" HSD 7,400.0 7,440.0 6,336.6 6,355.9 A-3, 1Q-08A 8/17/1997 4.0 IPERF 0 deg. ph; 2 1/8" EnerJet 7,421.0 7,441.0 6,346.8 6,356.3 A-3, 1Q-08A 7/28/1997 6.0 IPERF 60 deg. ph; 2.5" HSD 7,446.0 7,450.0 6,358.7 6,360.6 A-3, 1Q-08A 7/28/1997 6.0 IPERF 60 deg. ph; 2.5" HSD 7,575.0 7,588.0 6,416.3 6,421.8 A-2, 1Q-08A 7/29/1997 6.0 IPERF 60 deg. ph; 2.5" HSD 1Q-08A, 1/18/2023 12:29:32 PM Vertical schematic (actual) LINER; 5,992.9-7,866.0 IPERF; 7,575.0-7,588.0 IPERF; 7,446.0-7,450.0 IPERF; 7,421.0-7,441.0 IPERF; 7,400.0-7,440.0 IPERF; 7,399.0-7,421.0 IPERF; 7,365.0-7,375.0 PACKER - PATCH - LWR; 7,069.0 APERF; 7,056.0-7,057.0 OTHER; 7,037.0 RPERF; 7,026.0-7,060.0 SPACER PIPE; 7,024.0 PACKER - PATCH - UPR; 7,019.0 PRODUCTION Post S/T; 33.7- 6,210.0 WINDOW; 6,194.0-6,206.0 PACKER; 5,978.7 SURFACE; 35.5-3,733.1 NIPPLE; 495.1 CONDUCTOR; 28.0-103.0 KUP INJ KB-Grd (ft) 36.15 RR Date 2/5/1985 Other Elev 1Q-08A ... TD Act Btm (ftKB) 7,868.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292122501 Wellbore Status INJ Max Angle & MD Incl (°) 66.25 MD (ftKB) 7,606.99 WELLNAME WELLBORE1Q-08A Annotation Last WO: End Date 7/7/1997 H2S (ppm) DateComment SSSV: NIPPLE 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured feet None feet true vertical feet None feet Effective Depth measured feet 5979', 7019', 7069'feet true vertical feet 5362', 6125', 6155'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 6005' MD 5384' TVD Packers and SSSV (type, measured and true vertical depth) 5979' MD 7019' MD 7069' MD 495' MD 5362' TVD 6125' TVD 6155' TVD 495' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: 3544' Burst Collapse Production Liner 6176' 1873' Casing 5554' 4-1/2" 6210' 7866' 6539' 3698' 103'Conductor Surface Intermediate 16" 9-5/8" 75' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 197-093 50-029-21225-01-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025641 Kuparuk River Field/ Kuparuk River Oil Pool KRU 1Q-08A Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 103' ~~~ INJECTOR ~~ ~ N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker SABL Perm Packer Packer: PIIP Patch Packer Packer: PIIP Patch Packer SSSV: Camco DB Nipple w/ NO GO Allen Eschete allen.eschete@conocophillips.com (907) 265-6558 Intervention Engineer Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov 3733' 7868' 6540' 7418' 6345' 7026-7060', 7365-7375', 7399-7441', 7446-7450', 7575-7588' 6129-6150', 6319-6324', 6336-6356', 6359-6361', 6416-6422' DTTMSTART JOBTYP SUMMARYOPS 8/2/2022 PUMPING TRACKING ONLY FREEZE PROTECTED TBG WITH 34 BBLS DIESEL. JOB COMPLETE 10/24/2022 OPTIMIZE WELL RIH WITH 2" DJ NOZZLE. DRY TAG AT 7,418' CTMD. CLEANOUT DOWN TO HARD TAG AT 7754' CTMD (166' OF RATHOLE) WITH SLICK SEAWATER. MAINTAIN 1:1 RETURNS THROUGHOUT. JOB COMPLETE. 10/28/2022 OPTIMIZE WELL DRIFT & TAG TD @ 7412'RKB. DRIFT W/ DUMMY PATCH TO 7100'RKB. RUN PDS CALIPER FROM 7150' RKB TO SURFACE. READY FOR PATCH INSTALL. 11/17/2022 OPTIMIZE WELL BRUSH n' FLUSH PATCH INTERVAL FROM 6900'-7200' RKB. READY FOR PATCH 12/9/2022 OPTIMIZE WELL SET QUADCO 4.5" SPECIAL CLEARANCE PIIP LOWER PACKER MID-ELEMENT AT 7072.0', CCL TO ME = 10.6', CCL STOP DEPTH = 7061.4'. DISCOVERED ICE IN LUBRICATOR ONCE BACK AT SURFACE, UNABLE TO SHUT SWAB VALVE, SHUT MASTER VALVE, CALL FOR PUMP SUPPORT TO ASSIST IN THAWING ICE IN LUB, FREEZE PROTECT TUBING AGAIN WITH 45 BBLS HOT DIESEL, UNABLE TO FUNCTION SWAB AFTER PUMPING, GREASE CREW SERVICED SWAB, FINISH RIG DOWN. JOB COMPLETE, READY FOR SL TO SET UPPER PATCH ASSEMBLY 12/9/2022 PUMPING TRACKING ONLY FREEZE PROTECT PUMPED 45 BBLS DSL FOLLOWED BY 17 METH FRMO MFB THROUGH FL DOWN TBG ( JOB COMPLETE ) 12/23/2022 OPTIMIZE WELL ((SELECTIVE C SAND PATCH))SET 4.5'' PBR, SPACER PIPE, ANCHOR LATCH ASSEMBLY @ 7037' RKB. (UTILIZING 2.75'' DPU) SET 4.5'' QUADCO P2P, SPACER PIPE, ANCHOR LATCH ASSEMBLY @ 7016' RKB. SET 4.5'' TEST TOOL @ 7016' RKB & OBTAIN PASSING MITT TO 2500, PULLED TEST TOOL. JOB COMPLETE. PBR: CBRR45007 P2P: CPSCHP45010 ANCHOR LATCH: CPAL4502 1Q-08A Patch Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 7,418.0 1Q-08A 10/28/2022 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Upper packer 1Q-08A 12/23/2022 fergusp Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 28.0 103.0 103.0 62.58 H-40 WELDED SURFACE 9 5/8 8.76 35.5 3,733.1 3,544.1 36.00 J-55 BTC PRODUCTION Post S/T 7 6.28 33.7 6,210.0 5,554.4 26.00 J-55 BTC WINDOW 7 6.00 6,194.0 6,206.0 5,551.1 LINER 4 1/2 3.96 5,992.9 7,866.0 6,538.8 12.60 L-80 NSCT Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 27.0 Set Depth … 6,005.3 Set Depth … 5,384.4 String Ma… 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.75 Grade L-80 Top Connection EUE8rdMOD ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 27.0 27.0 0.04 HANGER 10.000 McEVOY GEN 3 TUBING HANGER 4.500 495.1 495.1 0.12 NIPPLE 5.563 CAMCO 'DB' NIPPLE w/NO GO PROFILE 3.875 5,931.8 5,323.3 33.76 SLEEVE 5.500 BAKER CMU SLIDING SLEEVE 3.812 5,978.0 5,361.7 33.74 ANCHOR SEAL 5.563 BAKER KBH-22 ANCHOR SEAL NIPPLE 3.875 5,978.7 5,362.2 33.74 PACKER 5.312 BAKER 'SABL' PERMANENT PACKER 3.875 5,983.9 5,366.5 33.74 BLAST JT 5.250 BLAST JOINT PUP (OAL 9.57') 3.833 5,993.4 5,374.5 33.73 NIPPLE 5.563 OTIS 'X' LANDING NIPPLE w/3.812 SELECTIVE PROFILE 3.812 5,994.6 5,375.4 33.73 LOCATOR 5.140 BAKER GBH LOCATOR 3.875 5,995.1 5,375.9 33.73 SEAL ASSY 4.750 BAKER SEAL ASSEMBLY w/10' STROKE 3.875 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,019.0 6,124.5 51.57 PACKER - PATCH - UPR Upper patch assembly speacial clearance 3.66" P2P, XO, Spacer pipe, & anchor latch (OAL 23') TTS PIIP CPSC HP45 010 12/23/2022 2.000 7,024.0 6,127.6 51.69 SPACER PIPE Spacer Pipe CPAI 12/23/2022 2.000 7,037.0 6,135.7 52.01 OTHER PBR, SPACER PIPE & ANCHOR LATCH (oal 32') CPBR 45007 12/23/2022 2.000 7,069.0 6,155.2 52.78 PACKER - PATCH - LWR 4-1/2" SPECIAL CLEARANCE PIIP MID-ELEMENT AT 7072' RKB, OAL 4.89' TTS PIIP CPSC HP45 009 12/9/2022 2.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,992.9 5,374.1 33.73 SLEEVE 4.500 BAKER C-2 LINER SETTING SLEEVE 3.833 5,994.1 5,375.0 33.73 PBR 5.875 BAKER 80-47 PBR 4.750 6,844.9 6,013.2 51.10 NIPPLE 5.000 CAMCO DB LANDING NIPPLE 3.750 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,026.0 7,060.0 6,128.9 6,149.8 C-4, C-3, 1Q- 08A 1/17/2006 0.5 RPERF 2.5" HSD, 60 deg phase 7,056.0 7,057.0 6,147.3 6,147.9 C-3, 1Q-08A 12/31/2005 1.0 APERF 1 SINGLE PERF HOLE w/2.5" gun, w/no orientation 7,365.0 7,375.0 6,319.3 6,324.3 A-4, 1Q-08A 7/28/1997 6.0 IPERF 60 deg. ph; 2.5" HSD 7,399.0 7,421.0 6,336.1 6,346.8 A-3, 1Q-08A 7/29/1997 6.0 IPERF 60 deg. ph; 2.5" HSD 7,400.0 7,440.0 6,336.6 6,355.9 A-3, 1Q-08A 8/17/1997 4.0 IPERF 0 deg. ph; 2 1/8" EnerJet 7,421.0 7,441.0 6,346.8 6,356.3 A-3, 1Q-08A 7/28/1997 6.0 IPERF 60 deg. ph; 2.5" HSD 7,446.0 7,450.0 6,358.7 6,360.6 A-3, 1Q-08A 7/28/1997 6.0 IPERF 60 deg. ph; 2.5" HSD 7,575.0 7,588.0 6,416.3 6,421.8 A-2, 1Q-08A 7/29/1997 6.0 IPERF 60 deg. ph; 2.5" HSD 1Q-08A, 1/18/2023 12:29:32 PM Vertical schematic (actual) LINER; 5,992.9-7,866.0 IPERF; 7,575.0-7,588.0 IPERF; 7,446.0-7,450.0 IPERF; 7,421.0-7,441.0 IPERF; 7,400.0-7,440.0 IPERF; 7,399.0-7,421.0 IPERF; 7,365.0-7,375.0 PACKER - PATCH - LWR; 7,069.0 APERF; 7,056.0-7,057.0 OTHER; 7,037.0 RPERF; 7,026.0-7,060.0 SPACER PIPE; 7,024.0 PACKER - PATCH - UPR; 7,019.0 PRODUCTION Post S/T; 33.7- 6,210.0 WINDOW; 6,194.0-6,206.0 PACKER; 5,978.7 SURFACE; 35.5-3,733.1 NIPPLE; 495.1 CONDUCTOR; 28.0-103.0 KUP INJ KB-Grd (ft) 36.15 RR Date 2/5/1985 Other Elev… 1Q-08A ... TD Act Btm (ftKB) 7,868.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292122501 Wellbore Status INJ Max Angle & MD Incl (°) 66.25 MD (ftKB) 7,606.99 WELLNAME WELLBORE1Q-08A Annotation Last WO: End Date 7/7/1997 H2S (ppm) DateComment SSSV: NIPPLE 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov March 30, 2023 CERTIFIED MAIL – RETURN RECEIPT REQUESTED 7018 0680 0002 2052 9679 Mr. Luke Lawrence Wells Manager ConocoPhillips Alaska PO Box 100360 Anchorage, AK 99501 Re: Docket Number: OTH-23-009 Notice of Violation Kuparuk River Unit 1Q-08A (PTD 1970930) Dear Mr. Lawrence: On January 28, 2023, the Alaska Oil and Gas Conservation Commission (AOGCC) received a notification from ConocoPhillips Alaska, Inc. (CPAI) for the opportunity to witness a mechanical integrity test on Kuparuk River Unit (KRU) Well 1Q-08A, a water-alternating-gas injector. The test was scheduled for January 30, 2023, which an AOGCC Petroleum Inspector confirmed would be witnessed. CPAI’s notice was for a routine pressure test of the tubing-casing annulus in conjunction with other nearby wells requiring mechanical integrity tests. Upon arrival at location on January 30, 2023, the AOGCC Inspector was told that KRU 1Q-08A had developed a tubing leak that was addressed by installing a tubing patch in late December 2022. The pressure test was to demonstrate mechanical integrity had been restored so the well could return to injection. The AOGCC Inspector requested a copy of the approved Sundry application (AOGCC Form 10-403) to confirm the required test pressure. The CPAI representative provided an unsigned 10-403 with “N/A” in the Sundry Number field. AOGCC initiated a review of KRU 1Q-08A after receiving the Inspector’s report of a witnessed mechanical integrity test. Information gathered indicates that a CPAI representative contacted AOGCC by telephone on January 23, 2023, acknowledging the failure to submit a Sundry application for installing a tubing patch in KRU 1Q-08A. A search of AOGCC records confirmed that no 10-403 was provided to AOGCC for review. The Sundry Matrix 1 for Kuparuk River Unit well work operations clearly references the requirement to submit a 10-403 for installing a tubing patch in an injection well. In the January 23, 2023, telephone call, CPAI was instructed by AOGCC to submit a Report of Sundry Well Operations (AOGCC Form 10-404) and to arrange for AOGCC witness of a mechanical integrity test. The 10-404 was subsequently provided to 1 Conservation Order 261B, October 26, 2020; AOGCC Docket CO-20-016. Docket Number: OTH-23-009 March 30, 2023 Page 2 of 2 AOGCC the same day, and AOGCC witnessed a passing mechanical integrity test on January 30, 2023. CPAI’s failure to obtain AOGCC approval prior to installing a tubing patch in KRU 1Q-08A is a violation of 20 AAC 25.280 and Area Injection Order 2C, Rule 7. Within 14 days of receipt of this letter, you are requested to provide the AOGCC with a written summary of CPAI’s internal review of this violation and address the following: - When did KRU 1Q-08A begin to indicate pressure communication or leakage between the tubing and tubing-casing annulus? - Describe CPAI’s policy and practice when an injection well indicates pressure communication or leakage of any casing, tubing, or packer? - Describe what has or will be done in the future to prevent this violation’s recurrence. This information request is made pursuant to 20 AAC 25.300. Failure to comply with this request will be an additional violation. The AOGCC reserves the right to pursue additional an enforcement action in this matter according to 20 AAC 25.535. Questions regarding this notice should be directed to Jim Regg at (907) 793-1236 (email: jim.regg@alaska.gov). Sincerely, Brett W. Huber, Sr. Jessie L. Chmielowski Gregory C. Wilson Chair, Commissioner Commissioner Commissioner cc: Phoebe Brooks Chris Wallace 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC 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 AOGCC 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 AOGCC 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 AOGCC mails, OR 30 days if the AOGCC 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 AOGCC 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 AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on 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. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.03.30 09:05:28 -08'00' Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.03.30 09:20:37 -08'00' Gregory Wilson Digitally signed by Gregory Wilson Date: 2023.03.30 09:53:59 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, March 17, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1Q-08A KUPARUK RIV UNIT 1Q-08A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/17/2023 1Q-08A 50-029-21225-01-00 197-093-0 W SPT 5363 1970930 1500 2400 2400 2400 2400 100 100 100 100 OTHER P Guy Cook 1/30/2023 Operator failed to submit a 10-403 for setting a tubing patch. They were instructed to submit a 10-404 by Victoria Loepp and to get a State witnessed MITIA. The Sundry did not include a sundry number. N/A was in the location where a sundry number would be. Testing was completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1Q-08A Inspection Date: Tubing OA Packer Depth 525 1800 1765 1750IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC230130150549 BBL Pumped:0.8 BBL Returned:0.7 Friday, March 17, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 Operator failed to submit a 10-403 for setting a tubing patch. James B. Regg Digitally signed by James B. Regg Date: 2023.03.17 15:16:28 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-10-28_21108_KRU_1Q-08A_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21108 KRU 1Q-08A 50-029-21225-01 Caliper Survey w/ Log Data 28-Oct-11 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:197-093 T37216 Kayla Junke Digitally signed by Kayla Junke Date: 2022.11.01 14:09:12 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday, July 15, 2021 � / I P.I. Supervisor I \ �G �(/(� �'l SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 1Q -08A FROM: Brian Bixby KUPARUK RIV UNIT IQ -08A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry JoZ NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1Q -08A API Well Number 50-029-21225-01-00 Permit Number: 197-093-0 Insp Num: mitBDB210713095421 Rel Insp Num: Inspector Name: Brian Bixby Inspection Date: 7/12/2021 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IQ -08A PTD 1970930 Type Inj W - TVD 5363 - Tubing 2430 -j 2430. - '[ a Test SPT -'fest SI YP � p Sol o IA sao � 1900 - 2430 - 2430 I860 - 1860 - ----- - -- BBL Pumped: l 0.4 -BBL Returned: 0.4 OA 140 140 140 140 Interval ! 4YRTST — P/F P - Notes: Thursday, July 15, 2021 Page I of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Monday,July 17,2017 Jun Rp �� `1 1 i 7 P.I.Supervisor SUBJECT: Mechanical Integrity Tests 1� Zl1 ` CONOCOPHILLIPS ALASKA,INC. 1Q-08A FROM: Guy Cook KUPARUK RIV UNIT IQ-08A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 5E2— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1Q-08A API Well Number 50-029-21225-01-00 Inspector Name: Guy Cook Permit Number: 197-093-0 Inspection Date: 7/15/2017 Insp Num: mitGDC170716142136 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1Q-08A Type Inj W 'TVD 5363 " Tubing 2200 2200 2200 • 2200 " PTD 1970930 Type Test SPT Test psi 1500 IA 420 1680 " 1640 1630 BBL Pumped: 0.7 BBL Returned: 0.8 ' OA 150 150 150 - 150 - Interval 4YRTST P/F P V Notes: SINS SES` 2 5 2.47 Monday,July 17,2017 Page 1 of 1 A Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning Project. They are available in the original file and viewable by direct inspection. File Number of Well HistoFy File .^~ ~0 ~'~ Complete RESCAN n Color items - Pages: GraYScale, halftones, pictures, graphs, charts- Pages: ~- ~ Z~ Poor Quality Original'- Pages: [] Other- pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type -OVERSIZED .Logs of vadous kinds Other COMMENTS: Scanned b~ildred- D'aretha Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: /s/ ~ ~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday, July 14, 2009 Jim Regg P.I. Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 Q-08A FROM: John Crisp tcur~tu[c [uv urirr iQ-osa Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv _ NON-CONFIDENTIAL Comm Well Name: KUPARiIK RN L1NIT 1Q-08A API Well Number: 50-029-21225-01-00 Insp Num: mic.TCr090713134006 Permit Number: 197-093-0 ~ Rel Insp Num: Inspector Name: John Crisp Inspection Date: ~~12/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We~] 1Q-~gA Type Inj. N 'j~~ 5367 jA 0 1960 1940 1930 P.T.D 1970930 TypeTest SPT Test psi zooo pA o io io io Interval 4YRTST P~ P-~ Tubing 2450 2475 2475 2450 NOtes' 23 bbl's pumped for test. Due to high tubing pressure the Operator could not pressure IA 500 psi above tubing. ~t, ~ - '~`~- ~~s~.-~ I SaL~s. , r~~; =~X.'~ ~ - i _ ~- ~,, f ('~. 2~- , [~. ~~r_1 Tuesday, July 14, 2009 Page 1 of 1 C®1'1000P~'11 I ~ 1 S p Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 4, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • 3 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped November 20, 2008 and the corrosion inhibitor/sealant was pumped December 2-3, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, Perry Klei ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1 Q-01 184-231 10' 1.25 22" 11 /20/2008 6.80 12/2/2008 1 Q-04 184-234 10' 1.25 22" 11 /20/2008 3.40 12/3/2008 1 Q-07A 198-234 9' 1.10 24" 11 /20/2008 2.95 12/3/2008 1 Q-08A 197-093 8' 1.00 22" 11 /20/2008 3.40 12/3/2008 1 Q-09 184-192 2" NA 2" NA 4.25 12/2/2008 1 Q-11 184-199 4'S" 0.50 22" 11 /20/2008 4.25 12/2/2008 1 Q-12 184-193 21 " NA 21 " NA 6.80 12/2/2008 1 Q-13 185-044 18" NA 18" NA 5.10 12/2/2008 1Q-14 185-045 24" NA 24" NA 4.25 12/2/2008 1 Q-23 195-141 24" NA 24" NA 3.40 12/3/2008 MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation CommissIOn TO: Jim Regg P.I. Supervisor ~ 1<.--. ¡ ¡ 1 J?fC¡ ?(U}i:G DATE: Wednesday, July 19,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 Q-08A KUPARUKRIV UNIT lQ-08A \qÎ~oq3 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv .Jßf2:- Comm Well Name: KUPARUK RIV UNIT lQ-08A API Well Number 50-029-21225-01-00 Inspector Name: Chuck Scheve Insp Num: mitCS0607181 0 1153 Permit Number: 197-093-0 Inspection Date: 7/17/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well IQ-08A iType Inj. ¡ w i TVD 5362 I IA 710 ì 2900 2870 2870 I i i I P.T. I 1970930 ITypeTest : SPI I Test psi 1500 lOA. 240 ! 510 500 500 Tubing I I I Interval 4YRTST P/F P 2200 2200 2200 2200 I Notes Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. NON-CONFIDENTIAL ~C'~ N.\ŒJ2 ,.)\t~""'. ,\OJ .............- c-~ì ,,-" f. Wednesday, July 19,2006 Page 1 of I 05/09/06 SCblumbepgep NO. 3792 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 1111' .,... f',', SCÅJ~NED ,) \J~ 1 ¿ Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~ Field: Kuparuk l q 1- V q Well Color CD Job# Log Description Date BL 1 Y -29 11213739 PRODUCTION PROFILE W/DEFT L~- {..C\ I 04/28/06 1 3M·25A N/A SHUT IN 8HP Ictt..t -a~<C 04/23/06 1 2N-303 N/A LDL Ç)',l.' - I ¿"C.. 04/21/06 1 1 R-21 11213737 PRODUCTION PROFILE W/DEFT \~1-t\3 04/25/06 1 3F-07 N/A INJECTION PROFILE I~";-- fj4f...- 04/23/06 1 18-16 11235353 PRODUCTION PROFILE W/DEFT Ie, '-/-('-":l.,'":} 04/04/06 1 38-15 11213741 INJECTION PROFILE 4'K - I~ ;::¡.:.,- 04/30/06 1 1G-07 N/A PRODUCTION LOG W/DEFT ¡ '1í ~ - ~l' \ 04/19/06 1 1 A-20 11235356 PRODUCTION LOG W/DEFT 1(.',0 - /i,,;;) 04/26/06 1 1 H-18 N/A INJECTION PROFILE IC¡'?~ -l':.:lb 04/24/06 1 1 R-12 11213738 PRODUCTION LOG W/DEFT ¡ ~';) -0'171 04/27/06 1 1Y-13 11213740 INJECTION PROFILE 1"'6~ - C' \<;- 04/29/06 1 2N-318 11213742 LDL ;:)00 -!öD 05/01/06 1 1 Q-08A 11213743 INJECTION PROFILE I ~ -1- -i'c,·:2, 05/02106 1 1 G-01 11213744 INJECTION PROFILE ¡Ýd.-- l~D 05/03/06 1 3J-17 11258704 PRODUCTION LOG W/DEFT íC,G -ILI"'1- 05/04/06 1 1 R-26 11258705 INJECTION PROFILE ì '1 I - (,~ ' 05/05/06 1 2A-04 11249902 INJECTION PROFILE ¡ ~L., -l'<~ 05/06/06 1 1 G-06 11249903 INJECTION PROFILE I 11' d - ;:}.':+t', 05/07/06 1 1 E-18 11216193 MEMORY PRODUCTION PROFILE , .q::z. - - L" 05/07/06 1 1G-14 11249904 INJECTION PROFILE I "Í< '7, -- /'- { I 05/08/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. e e e ConocóÃ,illips e Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 February 3, 2006 Commissioner ~::~~~6~11~~as Conservation Commission ~CANNED FED G '? 20Gb 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 1 Q-08A (APD # 197-093) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforations operations on the Kuparuk well 1 Q-08A. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, ;1, /tit tJlJ~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION e e RECEIVED FEB 0 7 2006 Alaska on & Gas Cons. CDf11I11issiot REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other ~chorage Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: 0 0 . ConocoPhillips Alaska, Inc. Development Exploratory 197-0931 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21225-01 7. KB Elevation (ft): 9. Well Name and Number: RKB 86' 1 Q-08A 8. Property Designation: 10. Field/Pool(s): ADL 25641, ALK 2572 Kuparuk River Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7868' feet true vertical 6540' feet Plugs (measured) Effective Depth measured 7417' feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 116' 116' SUR. CASING 3700' 9-5/8" 3733' 3544' PROD. CASING 6173' 7" 6206' 5551' LINER 1871' 4-1/2" 7866' 6539' Perforation depth: Measured depth: 7026'-7060',7365'-7375',7399'-7441', 7446'-7450', 7575'-7588' true vertical depth: 6129'-6150',6301'-6306',6319'-6342', 6344'-6346', 6413'-6420' Tubing (size, grade, and measured depth) 4-112" , L-80, 6005' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'SABL' PERM. pkr= 5979' Cameo 'DB' Landing nipple @ 495' 12. Stimulation or cement squeeze summary: . ~~I FIB () 7 2006 Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casina Pressure Tubina Pressure Prior to well operation -- -- -- Subsequent to operation -- -- 721 -- 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _ X 16. Well Status after proposed work: oilD GasD WAG 0 GINJD WINJD WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Mike Mooney @ 263-4574 Printed Name Mike Mooney Title Wells Group Team Lead Signature )lJ duM Phone Date Prenared bv Sh~mn AlIsun-Drakp 263-4612 I -> Form 10-404 Revised 04/2004 OR\G\NAL Submit Original Only e 1 Q-08A Well Events Summary e Dttmstart Summaryops 01/14/0606:00 AM DRIFTED TBG & TAGGED FILL WITH 23' x 2.5" DUMMY GUN @ 7397' RKB. PROPOSED PERFs: 7026 - 7060'. 01/15/0609:30 AM PERFS: 7040 - 7060 FT (C SAND, 0.5 SPF, 21/2" HSD PJ 2506, 60 DEG PHASING) 01/17/0608:30 AM PERFS: 7026 - 7039 FT (C SAND, 0.5 SPF, 21/2" HSD PJ 2506, 60 DEG PHASING ConocoPhillips Alala, Inc. t 1 Q-08A e KRU 1Q-08A API: 500292J 2250t . Well Type: i INJ Angle @ TS: 51 deo @ 6996 SSSV Type: Nipple Orig 7/9/1997------- . Angle @ TD: 64 deg @ 7868 Completion: NIP (495-496, Annular Fluid: Last W/O: Rev Reason: TAG FILL, PERF 00:4.500) TUBING Reference Loa: Ref Loa Date: Last UDdate: 1/2/2006 (0-6005. Last Tao: 7417 TD: 7868 ftKB 004.500, Last Taa Date: 12/22/2005 Max Hole Anale: 66 º~9..@]60Z_ 10:3.958) ------. Casinc Strinc - Ä_LL,.8TRINGS ---.--. ...-- í-Threaër--- Description , Size Top i Bottom TVD Wt Grade SLEEVE-C CONDUCTOR 16.000 0 103 103 62.58 H-40 (5932-5933, SUR. CASING 9.625 0 3733 3544 36.00 J-55 00:4.500) PROD. CASING 7.000 0 6206 5551 26.00 J-55 LINER 4.500 5995 7866 6539 12.60 L-80 ,. i< ',.i :Wil:; il.' ::,i :i:',,:, I Size I Top I Bottom I TVD I Wt I Grade Thread ANCHOR 4.500 I 0 I 6005 I 5384 I 12.75 I L-80 .-,. ~--_. EUE 8RD MOD SEAL - J:-~rforations Summary (5978-5979. ....--.....-.. ..... r- Typëï --- Interval ! TVD Zone Status Ft 'SPF Date Comment 004.500) 7056 - 7057 6136 - 6137 C-3 1 1 12/31/2005 APERF 1 SINGLE PERF HOLE PKR - (5979-5980. w/2.5" aun, wIno orientation 00:6.156) 7365 - 7375 6301 - 6306 A-4 10 6 7/28/1997 IPERF 60 deo. ph; 2.5" HSD 7399 - 7400 6319 - 6320 A-3 1 6 7/29/1997 IPERF 60 dea. ph; 2.5" HSD 7400 - 7440 6320 - 6341 A-3 40 10 8/17/1997 IPERF o deo. ph; 2 1/8" EnerJet NIP - 7440 - 7441 6341 - 6342 A-3 1 6 7/28/1997 IPERF 60 dea. ph; 2.5" HSD (5993-5994. 00:4.500) 7446 - 7450 6344 - 6346 A-3 4 6 7/28/1997 IPERF 60 deo. ph; 2.5" HSD 7575 -7588 6413 - 6420 A-2 13 6 7/29/1997 IPERf..6Q ¡j~g:'ph; 2.5" HSD ºth~dplµ_g!)!~q~ip., etc.) - JEWELRY:-~·~=:___ _____ ___··.··.·_.._n peptb _J\/DI Type Description .- ...... .---.-----.. ID 495 .- 495 ---NIP Camco 'DB.-L~-ridirigN¡p.P.le NO GO n_.___... -.-- 3.875 SEAL - D 5932 5323 SLEEVE-C Baker 'CMU' SLIDING SLEEVE 3.812 (5995-5996. 5978 5362 ANCHOR Baker 'KBH-22' 3.875 00:4.500) SEAL PBR -. 5979 5362 PKR Baker 'SABL' Perm. 3.875 (5995-5996. 5993 5374 NIP Otis 'X' Landino 3.812 00:4.500) 5995 5376 SEAL Baker SEAL ASSEMBLY 3.875 5995 5376 PBR Baker 'GBH-22' 4.000 TTL - .- . 6005 5384 TTL 3.958 (6005-6006. 6847 6015 NIP Cameo 'DB' Landino Nipple NO GO 3.750 00:4.500) NIP (6847-6848. 00:3.828) - - Perf - - (7365-7375) - f----- - f----- - f-------- ;::;;;:;: f----- Perf F= (7399-7421) = F= Perf = F= (7400-7440) = Þ== = =; - f----- = F= = ~ Perf == f== (7421-7441) = Þ== = Þ== = Þ== = Þ== Perf - f----- (7446-7450) - f----- - f----- Perf - f----- (7575-7588) - f----- - f----- - f----- ) ) Mike Mooney Wells Group Team Leader Drilling & Wells ConocóPhillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 January 12, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 RECEIVED .IAN 1 7 ?UU~ Alaska 0;' & Gøs [;ij~S" C~Jm!r¡¡;;}$irm Anchorage Subject: Report of Sundry Well Operations for 1 Q-08A (APD # 197-093) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforations operations on the Kuparuk well 1 Q-08A. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, f"· t \;' ~r,~IE"~-\) ,II~} ~\.~ Ii Ç¡ 2006 û,k",UYlM\Jf:= p I>HUI¡ I.\} )I{ .;1 ifðÞ~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells M M/skad ) ) RECEIVED JAN 1 7 2006 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TIONtska Oil & Gas Cons. Commission Abandon D Repair Well D Plug Perforations D Stimulate D Other Aht~ayø Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Operat. ShutdownD Perforate 0 Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development D Exploratory D 197-0931 3. Address: Stratigraphic D Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21225-01 7. KB Elevation (ft): 9. Well Name and Number: RKB 86' 1 Q-08A 1. Operations Performed: 8. Property Designation: ADL 25641, ALK 2572 11. Present Well Condition Summary: 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING LINER Perforation depth: measured 7868' feet true vertical 6540' feet measured 7417' feet true vertical feet Length Size MD 80' 16" 116' 3700' 9-5/8" 3733' 6173' 7" 6206' 1871' 4-1/2" 7866' Plugs (measured) Junk (measured) Burst Collapse TVD 116' 3544' 5551' 6539' Measured depth: 7056'-7057',7365'-7375',7399'-7441', 7446'-7450', 7575'-7588' true vertical depth: 6136'-6137',6301'-6306',6319'-6342', 6344'-6346', 6413'-6420' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 6005' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'SABL' PERM. pkr= 5979' Cameo 'DB' Landing nipple @ 495' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable RBDMS 8Ft ,IAN 1 7 2006 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mef Water-Bbl Casinç¡ Pressure 900 900 Tubinç¡ Pressure Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ 15. Well Class after proposed work: Exploratory D Development D Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: OilD GasD WAG 0 GINJD WINJ D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Printed Name Signature WDSPL 0 Mike Mooney @ 263-4574 Mike Mooney I{ Jl/Æ7~) Title Phone Wells Group Team Lead Date t /;~ /0(., Prepared bv Sharon Allsup-Drake 263-4612 ORIGINAL Submit Original Only Form 10-404 Revised 04/2004 ) ConocoPhillips AlasJa. Inc. 1Q"08A NIP (495-496, 00:4.500) TUBING (0-6005, 00:4,500, 10:3.958) SLEEVE-C (5932-5933, 00:4.500) ANCHOR SEAL (5978-5979, 00:4.500) PKR (5979-5980, 00:6.156) NIP (5993-5994, 00:4,500) SEAL (5995-5996, J 00:4.500) PBR (5995-5996, 00:4.500) TTL (6005-6006, 00:4.500) NIP (6847 -6848, 00:3,828) Perf (7365-7375) Perf (7399-7421) Perf (7400-7440) Perf (7421-7441 ) Perf (7446-7450) Perf (7575-7588) ,. -11111 - KRU 1:l-08A Angle @ TS: 51 deg @ 6996 Angle @ TD: 64 deg @ 7868 API: 500292122501 SSSV Type: Nipple Well Type: INJ Orig 7/9/1997 Completion: Last W/O: Ref Log Date: TD: 7868 ftKB Max Hole Angle: 66 deg @ 7607 Annular Fluid: Reference Log: Last Tag: 7417 Last Tag Date: 12/22/2005 Casing String - ALL STRINGS Description Size CONDUCTOR 16.000 SUR. CASING 9.625 PROD, CASING 7.000 LINER 4.500 Tubing String - TUBING Size I Top 4.500 0 Rerfbrå¡tiòrisSuro·mårY Interval TVD 7056 - 7057 6136 - 6137 Top o o o 5995 Bottom 103 3733 6206 7866 Rev Reason: TAG FILL, PERF Last Update: 1/2/2006 TVD 103 3544 5551 6539 Grade H-40 J-55 J-55 L-80 Wt 62.58 36.00 26.00 12.60 Thread Ft SPF Date Type Comment 1 12/31/2005 APERF 1 SINGLE PERF HOLE w/2.5" gun, wIno orientation IPERF 60 deg. ph; 2.5" HSD IPERF 60 deg. ph; 2.5" HSD IPERF 0 deg. ph; 2 1/8" EnerJet IPERF 60 deg. ph; 2.5" HSD IPERF 60 deg. ph; 2.5" HSD IPERF 60 deg. ph; 2.5" HSD Zone C-3 Status 10 1 40 1 4 13 6 7/28/1997 6 7/29/1997 10 8/17/1997 6 7/28/1997 6 7/28/1997 6 7/29/1997 7365 - 7375 6301 - 6306 A-4 7399 - 7400 6319 - 6320 A-3 7400 - 7440 6320 - 6341 A-3 7440 - 7441 6341 - 6342 A-3 7446 - 7450 6344 - 6346 A-3 7575 - 7588 6413 - 6420 A-2 Other :plugs, equip., etc.) - JEWELRY Depth TVD Type Description 495 495 NIP Camco 'DB' Landing Nipple NO GO 5932 5323 SLEEVE-C Baker 'CMU' SLIDING SLEEVE 5978 5362 ANCHOR Baker 'KBH-22' SEAL PKR Baker'SABL' Perm. NIP Otis 'X' Landing SEAL Baker SEAL ASSEMBLY PBR Baker 'GBH-22' TTL NIP 5979 5993 5995 5995 6005 6847 5362 5374 5376 5376 5384 6015 Camco 'DB' Landing Nipple NO GO ID 3.875 3.812 3.875 3.875 3.812 3.875 4.000 3.958 3.750 ) 1 Q-08 Well Events Summary ) DATE Summaryops 12/22/05 DRIFT WI 11' X 2.5" DUMMY GUN DOWN TO 7417' RKB AND TAGGED FILL (PERF TARGET DEPTH 7056' RKB). EST 171' OF FILL 12/31/05 PERF'D THE "C" SAND @ 7056' RKB WI 2.5" 2506 POWERJET, SINGLE SHOT GUN. *NO PRESSURE CHANGE AFTER PERFORA TION* JOB COMPLETE. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator Phillip.s.. Alaska, .!..nc..... 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1543' FNL, 1298' FEL, Sec. 26, T12N, R9E, UM At top of productive interval 1627' FNL, 1177' FWL, Sec. 25, T12N, R9E , UM At effective depth At total depth 2216' FNL, 3543' FEL, Sec. 25, T12N, R9E, UM 12. Present well condition summary 5. Type of Well: Development Exploratory ~ Stratigraphic Service~X (asp's 528326, 5984326) (asp's 531363, 5983666) 6. Datum elevation (DF or KB feet) RKB 86 feet - 7~-unit o~ Property ~me ' ' Kuparuk Unit , ,, 8. Well number 1Q-08A '9. Permit r~umber / approv~i number 197-093 / 10. APl "r~ur~be~;" 50-029-21225-01 1'1. Field'/Pool ...... Kup. aruk 0il Pool ... Total depth: measured 7868 feet Plugs (measured) true vertical 6540 feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 103' 16" 240 sx CS, 103' 103' SUR. CASING 3647' 9-5/8" 850 sx CS II! & 600 sx Class G 3733' 3544' PROD. CASING 6120' 7" 376 sx Class G & 250 sx CS I 6206' 5551' LINER 1871' 4-1/2" 243 sx Class G 7866' 6539' LINER Perforation depth: measured ~~iii~§~~i~i~i!i~:_~~iii~:~;~ ~ ~~7~ ;~ :: ~.:: - 13. Stimulation or cement squeeze summaw Treatment description including volumes used and final pressure ========================================= · ; :' .. :. :.': .; '.....~ ..... :- . . · 14, ' Representative Daily Average Production Or I~i~ction Data ..... Prior to well operation Subsequent to operation , , 15. Attachments Copies of Logs and Surveys run ~ Daily Report of Well Operations ~X OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Questions? Call Jeff Spencer 659-7226 Date Prepared bi~ Robert Christe. nsen 659-7535 SUBMIT IN DUPLICATE 17. I hereby c~rtify~l~at the foregoing is truej~nd/~orrect to the best of my knowledge. Signed //~k.]l'-lA/~~~ fl. ~]~//~ /~ Engineering Supervisor Jeff A Spencer ¢' V~' ~ ~ v ~ -"~~~~ ~¢~~~Title Pr°ducti°n O-R SI ,IAL Form 10-404 Rev06/15/88- SCANNED JUN 2 & 20OZ 1Q-08A DESCRIPTION OF WORK COMPLETED SUMMARY .......Date :" ' Even~"S'~mmary " ' ' " ..... ' ..... ' .... - MEMORANDUM TO' THRU: Tom Maunder, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission Julie Heusser, /-J'~\3~' DATE: May 17, 2001 Commissioner FROM: John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests Kuparuk River Unit lQ Pad May 17 ,.2001' I traveled to Phillips Alaska's Kuparuk River Field to witness Safety Valve System tests. Ernie Barndt was Phillips Rep. in charge of SVS testing. Testing was conducted in a safe & efficient manner. I witnessed' one failure, the SSV on 1Q-05 would not pass the DP test. The valve was serviced & would not pass the re-test. Well 1Q-05 is shut in until repaired & re-tested. The AOGCC test report is attached for reference. I inspected 20 well houses on lQ Pad w/no problems witnessed. SUMMARY: I witnessed SVS testing in Kuparuk River Field. 15 wells, 30 components tested. I failure witnessed. 3,33% failure rate, 20 well houses inspected. Attachments' SVS KRU lQ 5-17-01jc CC; NON-C. ONF!DENTI ,A.L SVS KRU lQ 5-17-01jc Alas~ Oil and Gas Conservation Commis~..~a Safety Valve SysteTM Test Report Operator: P,,hil!ip,,s Alaska Operator Rep:, ,E, rnie Barndt AOGCC Rep: John'Crispi ',' Submitted By: Jo,,hr~, Crisp ..... Date: Field/Unit/Pad: K,upamk,,Riye, r Unit lQ P,,a~,,.,, Separator psi: LPS . .85. HPS 5/17/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCL~ 'iQ'02A 1~'51'940i ............... lQ~03 1842330 85 70 ' "65!' 'p" -P ......... 0IL lQ-04. 18423401 851 60 55 P ,.,P ........ OIL ,lQ-05 1842170 85: 70 '" 54! P 4 OIL lQ-06 18420801 ..... 85'i "60 '55 P ""~ Q-09 1841920, 3750 2000 1900 P P WAG 1Q-.I, 0,, 1841980~ "' 85 70 " 62] P P ....... .'. OIL lQ-11 1841990' ' lQ-12 1841930: 1Q71.5.'.'... !8_5046.'.° ........ ...' ... '.i,' , . ', ' ', "' lQ-16 1850470 85] 70 ' '64i P" ~ P OIL Q-20A i~515~0 ,,'- 85: '" 70 , '60 P P ........ . ' . (~IL lQ-21 1951330 1Q-22 1951400 " 85 70' 55 P "P " oIL Q-23 ' 19~1'4ib' ' 85! 70 .... 50 P 'e ................. (~IL 1Q-26 195132'0' 8~! " ' 70' ' 52 P" e '" OIL lQ-08' 197093'0 37~i "2000 1850 " e "ii .... WAG lQ-13 1850440' 3756! 2000 1'850 p P ...... WAdi lQ-14 1850450 3756! 2000 1850 P P .... WAG! 1Q-2.4 195121.'0 .-.,3750 ,, '5000 2i09 , P ,P ...... WAG' , Wells: 15 Components: 30 Failures:___. 1 Failure Rate: 3.33% [~ 90 Day Remarks: 1Q-05 was serviced & re-tested, re-test failed & well was shut in for repairs. RJF 1/16/01 Page 1 ofl SVS KRU lQ 5-17-01jc ON OR BEFORE ANuARY 03 2001 W c:LOi~MI:~lvI.DOC MEMORANDUM TO: Julie Heusser, Commissioner State of Alaska Alaska Oil and Gas Conservation Commission ~"~ ~ DATE: November 13, 2000 THRU: Blair Wondzell, ,43~ P. I. Supervisor ~(.(t~oo FROM: John Crisp, Jo~.~ SUBJECT: Petroleum Inspector Safety Valve Tests Kuparuk River Unit lQ Pad November 13, 2000' I traveled to Phillips AlaSka's KRU lQ Pad to witness Safety Valve System tests. Kuparuk's problem wells group now has a down hole diagnostics crew for wells work, this includes SVS testing. The gentlemen I worked with were not comfortable with testing procedures for MI wells in Kuparuk. Test procedures were discussed & everyone agreed that improvements in procedures could be implemented. We were able to test one producer & two MI wells after my arrival on lQ Pad. DHD crew was scheduled for safety training after lunch. When DHD crew's training is completed & test procedures are in place it will be a good improvement for State testing in Kuparuk. SUMMARY: I witnessed SVS testing in KRU on lQ pad. 3 wells, 6 components tested. No failures witnessed. Attachments' SVS KRU lQ 11-13-00jc cc; NON-CONFIDENTIAL SVS KRU lQ 11-13-00jc.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Operator Rep: Pete Nezaticky AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: Kuparuk River Field 1Q Pa Separator psi: LPS 88 HPS 11/13/00 Well Permit Separ Set L/P Test Test Test 'Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code COde Passed GAS or CYCLE 1Q-02A 1951940 lQ-03 1842330 lQ-04 1842340 lQ-05 1842170 lQ-06 1842080 lQ-09 1841920 lQ-10 1841980 1Q-Il 1841990 ~ , 1Q:12 1841930, lQ-15 18504601 lQ-16 1850470 1Q-20A 1951560 88 70 54 P P OIL lQ-21 195i3301 ' 1Q-22 1951400 1Q-23 1951410 1Q-26 1951320 lQ-08 1970930 4000 2000 1850 P P WAG lQ-14 1850450 4000 2000 1990 P P WAG Wells: 3 Components: 6 Failures: ~ 0 Failure Rate: 0.0% ~] 90 Day Remarks: 11/16/00 Page 1 of l SVS KRU lQ 11-13-00jc.xls AOGCc Geological Materials Inventory 97-093 ARCO Log Data Sent Reeieved 7785 /_..$C~H LU M PDC/GR 8/27/97 8/28/97 8090 ~s-~R RY GR/ROP 9/3/97 9/3/97 8304 ~'HLUM PDC/CCL 1/20/98 1/29/98 BH SRY/TEMP/PRES ~7500 9/22/97 9/29/97 CBT c4'~'-7380 8/27/97 8/28/97 MWD SRVY ~d~E'SRRY 6094.85-6942 9/29/97 10/1/97 NGP-MD ~:O_24-6942 9/3/97 9/3/97 NGP-TVD tw5565-6080 9/3/97 9/3/97 SRVY CALC [.~" 6095.-7868. 1/7/98 1/12/98 ~ff~07 Completion Date _4~/[ )/ ~t ) Daily well ops (45/~/C/?- ?J~)?/Q'? Are d~ ditch samples required? yes ~no . yes ~- no yes ~-no Initial Was the well cored? Are tests required? Well is in compliance Comments And received? ~s __ no-' Analysis description recievt4X3---~-y~~ .-~ no Received? ~-- _~ ' Box UIC Tuesday, August 31, 1999 Page 1 of 1 STATE OF ALASKA AU ::_?,A OIL AND GAS CONSERVATION COMMISb~,'N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown m Pull tubing Alter casing Stimulate __ Plugging Repair well Perforate X__ ~//~{'t¥ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1549' FNL, 1298' FEL, Sec 26, T12N, At top of productive interval 1627' FNL, 1177' FWL, Sec 25, T12N, At effective depth 2185' FNL, 1656' FWL, Sec 25, T12N, At total depth 2251' FNLr 1716' FWL~ Sec 25~ T12Nr 12. Present well condition summary Total Depth: measured 7 8 true vertical 6 5 5. Type of Well: Development __ Exploratory _ Stratigraphic Service X R9E, UM R9E, UM R9E, UM R9E, UM 6. Datum elevation (DF or KB) RKB 91 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1 Q-08A 9. Permit number/approvaLnumber 84-209, 397-098 10. APl number 5o-029-21225-01 11. Field/Pool Kuparuk River Field/Oil Pool 70 31 feet feet Plugs (measured) Bridge plug @ 6217' Balanced plug @ 6415'-6650' Elfective depth: measured 7 7 71 true vertical 6 4 9 0 feet feet Junk (measured) None 13. 14. Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 80' 1 6" 240 Sx CS II 1 16' 1 16' 3700' 9.625" 850SxCSIII& 3733' 3545' 600 Sx Class G 7311' 7" 376SxClassG& 7339' 6516' 250 Sx CS I measu red 7365'-7375',7399'-7441',7444'-7450',7575'-7588' true vertical 631 9'-6324',6336'-6356',6358'-6361 ',641 6'-6422' Tubing (size, grade, and measured depth) 4.5", 12.8#/ft., L-80 @ 6005' & 4.5", 12.6#/ft., L-80 @ 5995'-7866' Packers and SSSV (type and measured depth) Packer: Baker SABL perm w/K Anchor @ 5979; SSSV: None, nipple @ 495' Stimulation or cement squeeze summary Perforated 'A' sands on 8/17/97. Intervals treated (measured) 7400'-7440' Treatment description including volumes used and final pressure Perforated using UJ HNS charges at 6 SPF, fp = 3750 psi. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 100 Subsequent to operation 0 0 169O 100 2542 15, Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil Gas Suspended Service X 7. I here/~f-~rtify that the foregoing is true and correct to the best of my knowledge. Signed(~ k"TZ""~'~,~, '~~,~.,~.~ ~., Title Wells Superintendent Form 10/¢¢'0-4 ~-e"~//~6f~/l~-~ -' i..~i~ ~ .:~' i-~,~' '~ SUBMfTI'N DUPliCATE ARCO Alaska, Inc. -~_,., KUPARUK RIVER UNIT '' WELL SERVICE REPORT ~~' KI(Q-0eA(W4-6)) WELL JOB SCOPE JOB NUMBER 1Q-08A .PERFORATE, PERF SUPPORT 0813972020.7 DATE DAILY WORK UNIT NUMBER 08/17/97 PERFORATE F/7400-7440' ELM 8337 'DAY bPERATION COMPLETE SUCCESSFUL KEY PERSON 'SUPERVISOR 1 (~ Yes' O No (~) Yes O No SWS-MAOCHER BLACK~ FIELD AFC~ CC~ DAILY COST ACCUM COST ~~,""~ ESTIMATE AK8877 230DS10QG $11,51 9 $24,630 InitialTbclPress FinalTb~Press Initial lnner Ann. 'FinallnnerAnn I Initial Outer Ar~n I Final Out~r Ann 600 PSI 1500 PSI 0 PSI 0 PSIIOPSll 0 PSI DAILY SUMMARY PERFORATED F/7400 - 7440 W/2~118" EJ DP @ 0 DEG PHASING (DOWN) & 4 SPF. TIME 07:30 09:00 09:30 11:45 12:30 14:30 15:00 16:00 LOG ENTRY MIRU SWS (MAJCHER & CREW- UNIT 8337). TGSM - JOB OVERVIEW & GUN SAFETY. MU GUN ASSEMBLY - 20'- 2-1/8" EJ DP/2-1/8" MPDF/1-11/16" GR & CCL/6'-2-1/8" WT/HD (TL-35'). PT ROPE TO 3500 PSI. RIH TO 7651' CCL ELM. TIE W/GR & CCL W/SWS 7/28/97 GR. PERFORATE F/7420 - 7440' ELM W/2-1/8" EJ DP @ 0 DEG PHASED DOWN & 4 SPF (SAW ..'-UR?ACE ?4D~CATIONS OF SHOT). MAKE LOGGING PASS & POOH AT SURFACE. WELLHEAD PRESSur~'L7 DROPPFD TO 400 PSI. ALL SHOTS FIRED. MU GUN ASSEMBLY #':. AS BEFORE). PT. RIH W/GUN ASSEMBLY & TIE IN AS BEFORE. PERFORATE F/7400 - 7420' ELM W/SAME GUNS AS BEFORE (SAW SURFACE INDICATIONS). ATTEMPT LOGGING PASS AFTER PERFORATING (TROUBLE W/GR TOOL) & POOH. AT SURFACE. ENSURED GUN FIRED & RU LRS F/INJECTIVlTY TEST. INJECTED F/.5 - 1 BPM DIESEL. PRESSURE BROKE BACK @ 3750 PSI TO 3200 PSI (INJECTED TOTAL OF 10 EELS). RD LRS & SWS. OFF LOCATION & TURN OVER TO PRODUCTION F/HPBD. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $500.00 $3,000.00 ARCO $0.00 $500.00 DOWELL $0.00 $7.,500.00 HALLIBURTON $0.00 $812.00 LITTLE RED $660.00 $2,460.00 SCHLUMBERGER $10,359.00 $10,359.00 TOTAL FIELD ESTIMATE $11,519.00 $24,631.00 STATE OF ALASKA ALf-~,~ OIL AND GAS CONSERVATION COMMIS~,-,JN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown m Pull tubing Alter casing Stimulate __ Plugging Repair well Perforate X__ ?[ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1549' FNL, 1298' FEL, Sec 26, T12N, R9E, UM At top of productive interval 1627' FNL, 1177' FWL, Sec 25, T12N, R9E, UM At effective depth 2185' FNL, 1656' FWL, Sec 25, T12N, R9E, UM At total depth 2251' FNL, 1716' FWL, Sec 25, T12N~ R9E, UM 12. Present well condition summary Total Depth: measured 7870 feet true vertical 6531 feet 5. Type of Well: Development __ Exploratory _ Stratigraphic Service X Plugs (measured) 6. Datum elevation (DF or KB) RKB 91 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1 Q-08A 9. Permit number/approval,a,um~er _/3..~ 84-209. 397-098 I10. APl number 5o-029-21225-01 11. Field/Pool Kuparuk River Field/Oil Pool Bridge plug @ 6217' Balanced plug @ 6415'-6650' Effective depth: measured 7 7 71 feet true vertical 6490 feet Junk (measured) None 13. 14. Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 80' 1 6" 240 Sx CS II 1 16' 1 16' 3700' 9.625" 850SxCSIII& 3733' 3545' 600 Sx Class G 7311' 7" 376SxClassG& 7339' 6516' 250 Sx CS I measured 7365'-7375',7399'-7441',7444'-7450',7575'-7588' true vertical 6319'-6324',6336'-6356',6358'-6361',6416'-6422' Tubing (size, grade, and measured depth) 4.5", 12.8#/ft., L-80 @ 6005' & 4.5", 12.6#/ft., L-80 @ 5995'-7866' Packers and SSSV (type and measured depth) Packer: Baker SABL perm w/K Anchor @ 5979; SSSV: None, nipple @ 495' Stimulation or cement squeeze summary Perforated 'A' sands on 7/28-29/97. Intervals treated (measured) 7365'-7375',7399'-7441',7444'-7450',7575'-7588' Treatment description including volumes used and final pressure Perforated using UJ HNS char,qes at 6 SPF, fp = 2862 psi. Representative Daily Average Production or Injection Data OiI-Bbl ORtGINALI Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 100 Subsequent to operation 0 0 1690 100 2542 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil Gas Suspended Service X 17. I hereb,~rtify that the foregoing is true and correct to the best of my knowledge. /I Si~ned Title Wells Superintendent Fo r m ~4~' ~'~/0~'~'8 ~ Date /,.--- SUBMrT IN DUPLICATE A'RCC~ Alaska, Inc. KL ,RUK RIVER UNIT - WELL~SERVICE REPORT A KI(Q-0eA(W4-6)) WELL JOB SCOPE JOB NUMBER 1Q-08A PERFORATE, PERF SUPPORT 0714971852.4 DATE DAILY WORK UNIT NUMBER 07/28/97 GR LOG/PERFORATE 2 7/8" HSD 8337 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 3 O Yes L'~ NoI ® Yes O No SWS-WALSH JORDAN FIELD AFC# ~ DALLY COST ACCUM COST Signed ESTIMATE AK8877 230DS10QG $1 6,250 $36,685 Initial Tb.q Press Final Tbq Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSI 200 PSI 0 PSI 0 PSII 400 PSII 400 PSI DAILY SUMMARY JRERAN GR LOG. PICKED PERFS AND SHOT 744~-50', 7421-41' 7365-75', 6 SPF, 60 DEG PHASE, 34J UJ HNS CHARGES. WILL FINISH PERF 7-29. TIME LOG ENTRY 10:30 MI-TGSM-RU SWS WALSH & CREW 12:00 RIH WITH GPJCCL. 1.6875" OD, 21.3' LOG ZONE OF INTEREST. TOOH 13:50 PT 4000 PSI. RIH WITH CCL/10' GUN/6' GUN 15:10 16:30 17:15 00:00 18:10 SHOOT 7444-50' 6 SPF WITH 500 WHP. PRESSURE DROPPED TO 400 PSI. SHOOT 7365-75'.6 SPF WITH 400 WHP. PRESSURE DROPPED TO 300 PSI. TOOH RIH WITH CCL/20' SHOOT 7421-41' 6 SPF Wh H 400 PSI WHP. DROPPED TO 200 PSI AFTER TOOH. USED 34J UJ HNS CHARGES. EH=0.3", PEN=21.97', 19 GRAMS, 60 DEG PHASE. RD FOR NIGHT. SWS EQUIP ON LOCATION. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $10.00 APC $600.00 $3,100.00 ARCO $0.00 $1,000.00 DOWELL $0.00 $6,019.00 HALLIBURTON $0.00 $846.00 LITTLE RED $0.00 $1,060.00 SCHLUMBERGER $15,650.00 $24,650.00 TOTAL FIELD ESTIMATE $16,250.00 $36,686.00 ARCO Alaska, Inc. j KUPARUK RIVER UNIT WELL SERVICE REPORT KI(Q-08A(W4-6)) WELL JOB SCOPE JOB NUMBER 1Q-08A PERFORATE, PERF SUPPORT 0714971852.4 DATE DAILY WORK UNIT NUMBER 07/29/97' PERFORATE; STATIC 8337 DAY OPERATIQ" COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 4 (~) Yes O No (~) Yes O No SWS-WALSH ODELL FIELD AFC~ CC# DAILY COST ACCUM COST Signed -- ,,--- ESTIMATE AK8877 230DS10QG $1 7,308 $53,994 Initial Tb.q Press Final Tb.cl Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 300 PSI 1 00 PSI 0 PSI 0 PSII 400 PSII 400 PSI DAILY SUMMARY IPERFORATED 7575-88' & 7399-7421'. RECORDED STATIC Bo-Ir'OM HOLE PRESSURE. TIME LOG ENTRY 09:00 MI-TGSM-RU. SWS WALSH & CREW 10:00 PT 3000 PSI. RIH WITH CCL/2' GUN/13' GUN 11:30 SHOT 7575-88' 12:0C 13:00 13:45 14:20 14:45 15:50 16:20 17:30 ;_:.HO ';'419-21'. TOOH ...... AT SURFACE. RU CCL/20' GUN. RIH SHOT 7399-7419'. TOOH AT SURFACE. ALL SHOTS FIRED ON ALL GUNS. USED 34J UJ HNS CHARGES 19 GRAM, 21.97" PEN, 0.3" EH, 6 SPF, 60 DEG PHASE. RIH WITH GR/CCLFFEMP/PRESS. 24' 2.125" MAX OD. TAKING STATIC BO'I-I'OM HOLE PRESSURE AND TEMPERATURE AT 7410'. SURVEY COMPLETED. T=161 DEGF, P= 2862 PSI. TOOH RDMO SWS. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $10.00 APC $600.00 $3,700.00 ARCO $0.00 $1,000.00 DOWELL $0.00 $6,019.00 HALLIBURTON $0.00 $846.00 LI-I-I'LE RED $0.00 $1,060.00 SCHLUMBERGER $16,708.00 $41,359.00 TOTAL FIELD ESTIMATE $1 7,308.00 $53,994.00 1/20/98 GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 A'FI'N: Sherrie NO. 11730 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 ,Field: Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia LIS Tape 1E-34 '/, ~ "~"~ 0'~,~ 97571 TDTP 971129 1 1E-34 ~ 97571 TDTP-DEPTH CORRECTED 971129 I 1 1 E-34 /' 97571 TDTP BORAX/SPINNER 9711 29 I 1 1Q'08A ~' ~ ~,~ O~ 98006 GPJCCL (PDC) 970728 1 3C-05 INJECTION PROFILE 971 21 3 I 1 3 C-12 INJECTION PROFILE 9 8 01 0 6 I 1 3 F-01 PRODUCTION PROFILE 9 8 01 0 5 I 1 3 F-12 INJECTION PROFILE 971 20 2 I 1 3 F-15 INJECTION PROFILE 971 21 2 I 1 3 H-06 INJECTION PROFILE 971 20 5 I 1 3 H- 1 5 INJECTION PROFILE 971 2 09 I 1 30-11 ' GAS LIFT SURVEY 971 027 I 1 WS 1 D-130 ,-" ' CBT 9711 0 7 1 I 1'053 ~.tsq ,-[~ SIGNED: _ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 7, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1Q-08A (Permit No. 97-93) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 1Q-08A. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Development WSI/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well I--1 GAS I--I SUSPENDED I--I ABANDONE© SERWCE [] ,NJECTOR 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 97-93 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-21225-01 4 Location of well at surface ~. !9 Unit or Lease Name ' '~-' ~ ' ' ~~~-'~'~ ~ .... ~'-~-~' Kuparuk River Unit 1549' FNL, 1298' FEL, Sec. 26, T12N, R9E, UM :. z?/~ 10 Well Number At Top Producing Interval i ~"/~./ ~ 1676' FNL, 1215' FWL, Sec. 25, T12N, R9E, UM -.,~:: ;'." '~ · 1Q-08A !~' ~,~A~.,- ~j.~..~: r 11 Field and Pool At T otal Depth 2221' FNL, 1736' FWL, Sec. 25, T12N, R9E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Sedal No. Kuparuk River Oil Pool RKB 86', Pad 54'I ADL 25641 ALK 2572 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 16 No. of Completions 30-Jun-97 05-Ju1-97 17-Aug-97I NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 7868' MD & 6531' TVD 7771' MD & 6489' TVD YES X~ NO U NA feet MD 1465' APPROX 22 Type Electric or Other Logs Run GR/CCL, CBT 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16' 62.5# H-40 SURF. 116' 24' 240 sx Cold Set II 9.625' 36.0# J-55 SURF. 3733' 12.25' 850 sx CS III & 600 sx Class G 7' 26.0# J-55 SURF. 6194' 8.5' 376 sx Class G & 250 sx CS I 4.5' 12.6# L-80 5995' 7866' 6.125' 256 sx Class G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7575'-7588' MD 6416'-6422' TVD 4.5' 6005' 5979' 7446'-7450' MD 6358'-6360' TVD 7421'-7441' MD 6346'-6356' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 7365'-7375' MD 6319'-6324' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7399'-7421' MD 6336'-6346' TVD 7365'-7375', 7399'-7441', used 1680# rock salt and 4637# of 6 spf #20/40 prop for HPBD 7446'-7450', 7575'-7588' 127 PRODUCTION TEST ' ' Method of Operation i Date F~rst Production (Flowing, gas lift, etc.) Injector iDate of Test IHours Tested PRODUCTION ECl OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOI: Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBI OIL GRAVITY-APl (corr) !Press. 24-HOUR RATE: '28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A ORIGINAL Form 10-407 Submit in duplicate Rev. 7-!-80 CONTINUED ON REVERSE SIDE 29. 30. ~ -' GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 6996' 6110' Bottom Kuparuk C 7121' 6186' Top Kuparuk A 7331' 6302' Bottom Kuparuk A 7593' 6424' 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Prepared by Name/Number Sharon Allsup-Drake/263-4612 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 records for this well should show the details of any multiple stage cement- lng 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". Form 10-407 Date: 11/26/97 ARCO ALASKA INC. WELL SUMMARY REPORT L_ . Page: 1 WELL:iQ-08A RIG:NORDIC WELL ID: AK8877 TYPE: AFC: AK8877 AFC EST/UL:$ 948M/ 1128M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER I/NIT BLOCK: SPUD:06/30/97 START COMP: WI: 0% SECURITY:0 API NIIMBER: 50-029-21225-01 FINAL: 07/08/97 06/26/97 (D1) TD: 6650' (6650) SUPV: RLM DAILY:$ 06/27/97 (D2) TD: 6415 ' ( SUPV: RLM o) DAILY:$ 06/28/97 (D3) TD: 6217' ( 0) SUPV: RLM DAILY: $ 06/29/97 (D4) TD: 6217 ' ( SUPV: RLM o) DAILY: $ 06/30/97 (D5) TD: 6223' ( 6) SUPV: RLM DAILY: $ 07/01/97 (D6) TD: 6641' (418) SUPV: RLM DAILY: $ 07/02/97 (D7) TD: 6942' (301) SUPV: RLM DAILY:$ MW: 10.0 VtSC: 63 PV/YP: 23/24 APIWL: 5.2 TRANSFER HEAVY MUD F/STORAGE Move rig from 3M pad to lQ pad. Rig up. Accept rig @ 1600 hrs. 6/26/97. Held pre-job safety meeting. 36,490 CUM:$ 36,490 ETD:$ 0 EFC:$ 984,490 MW: 12.6 VISC: 51 PV/YP: 20/21 APIWL: 4.5 LAY DOWN 3.5" TUBING Pump mud to kill well. Well dead. N/D tree, N/U BOPE. Function test stack. Lay balanced plug from 6650' to 6415' Pump cement. 55,566 CUM:$ 92,056 ETD:$ 0 EFC:$ 1,040,056 MW: 9.8 VISC: 65 PV/YP: 24/26 APIWL: 4.0 BUILDING NEW PIPE RACKS POOH w/3.5" tubing. Set Baker bridge plug with top at 6217' 54,519 C UM:$ 146,575 ETD:$ 0 EFC:$ 1,094,575 MW: 9.9 VISC: 68 PV/YP: 21/28 APIWL: 4.0 BUILDING NEW PIPE RACKS Continue building new pipe racks. Reload pipe shed with drill pipe. RIH w/whipstock. Shallow test MWD. Could not get pulse. POOH. Change out probe. 79,569 CUM:$ 226,144 ETD:$ 0 EFC:$ 1,174,144 MW: 10.0 VISC: 70 PV/YP: 24/40 APIWL: 4.0 M/U DIRECTIONAL BHA RIH w/whipstock to 6164'. Change over to 9.6 ppg milling fluid. Mill window from 6194' to 6223' 44,719 CUM:$ 270,863 ETD:$ 0 EFC:$ 1,218,863 MW: 9.8 VISC: 50 PV/YP: 15/20 APIWL: 4.2 CIRC. FAX LOGS TO TOWN Perform formation integrity test, 12.6 EMW. Drill from 6223' to 6641' 63,862 CUM:$ 334,725 ETD:$ 0 EFC:$ 1,282,725 MW: 11.6 VISC: 50 PV/YP: 21/22 APIWL: 4.0 RIH W/ROTARY ASSEMBLY Directional drill and survey with MWD from 6641' to 6942'. Well flowing, mud gas and oil cut from 10.8 to 9.5 ppg. Shut in well @ 0800. Increase mud weight to 11.4 ppg. Shut down, observe well. CBU. Gas and oil cut mud. Weight up to 11.6 ppg. CBU, no gas or oil cut. POOH. 50,657 CUM:$ 385,382 ETD:$ 0 EFC:$ 1,333,382 07/03/97 (D8) TD: 7323' ( 381) SUPV: RLM DAILY: $ ., MW: 11.5 VISC: 48 PV/YP: 19/18 ROTARY DRILLING Directional drill from 6942' to 7323' 36,853 CUM:$ 422,235 ETD:$ 0 EFC:$ APIWL: 4.0 1,370,235 Date: 11/26/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 07/04/97 (Dg) TD: 7650' ( 327) SUPV: RLM DAILY: $ 07/05/97 (D10) TD: 7868' ( 218) SUPV: RLM DAILY:$ 07/06/97 {Dll) TD: 7771' ( 0) SUPV: RLM DAILY: $ 07/07/97 (D12) TD: 7771' ( 0) SUPV: RLM DAILY: $ 07/08/97 (D13) TD: 7771' ( 0) SUPV: DLW DAILY: $ 07/09/97 (D14) TD: 7771' ( 0) SUPV: DLW DAILY:$ MW: 11.6 VISC: 47 PV/YP: 20/18 APIWL: 3.8 RUN INTO DEEPEN HOLE Directional drill from 7323' to 7650' Circulate hole clean and raise mud weight from 11.5 to 11.6. Drop tandem single shot survey. 35,191 CUM:$ 457,426 ETD:$ 0 EFC:$ 1,405,426 MW: 11.4 VISC: 46 PV/YP: 17/15 APIWL: 3.8 RUN IN WITH LINER ON DP Make up BHA and RIH to 7637'. Tight on bottom, probable out of gauge hole. Ream out of gauge hole from 7637' to 7650' Rotary drill from 7650' to 7868'. Reduced mud weight to 11.4 ppg. Circulate hole clean. No gas or oil cut mud on bottoms up. Drop tandem single shot survey. 36,953 CUM:$ 494,379 ETD:$ 0 EFC:$ 1,442,379 MW: 11.5 VISC: 54 PV/YP: 23/19 APIWL: 3.8 LAY DOWN DP Run 4.5" liner. Held safety meeting. Cement liner. 116,555 CUM:$ 610,934 ETD:$ 0 EFC:$ 1,558,934 MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 NIPPLE UP TREE Lay down 3.5" drill pipe. Run 4.5" completion. 170,850 CUM:$ 781,784 ETD:$ 0 EFC:$ 1,729,784 MW: 8.4 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG MOVE F/iQ TO 3K @ CPF-3 Continue running 4.5" completion. N/D BOPE. N/U tree. Test packoff to 5000 psi, OK. Test tree to 250/5000 psi. Freeze protect with diesel. Prepare rig for turn key pad to pad rig move. Release rig @ 0100 hrs. 7/9/97. 49,048 CUM:$ 830,832 ETD:$ 0 EFC:$ 1,778,832 MW: 8.4 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RELEASED RIG @ 0100 HRS 7/9/97 Move rig off well. Released rig for turn key pad to pad rig move from lQ to 3K. Released rig @ 0100 hrs. 7/9/97. 1,309 CUM:$ 832,141 ETD:$ 0 EFC:$ 1,780,141 End of WellSummary for Well:AK8877 ARC() Alaska, Inc. KUPARUK RIVER UNIT KI(1Q-08A(W4-6)) WELL SERVICE REPORT WEM. JOB SCOPE JOB NUMBER IQ-08A PERFORATE, PERF SUPPORT 0714971852.4 DATE DAILY WORK UNIT NUMBER 07/28/97 GR LOG/PERFORATE 2 7/8" HSD 8337 DAY OPERATION COMPLETE I SUCCESSFUL KEYPERSON SUPERVISOR 5 NoI YES SWS-WALSH JORDAN Initial Tbg Press [FinalTbgPress IlnitiallnnerAnn Final lnner Ann IlnitialOuterAnn ] Final Outer Ann 0 PSI 200 PSI 0 PSI 0 PSI 400 PSI 400 PSI DAILY SUMMARY RERAN GR LOG. PICKED PERFS AND SHOT 7446-50', 7421-41', 7365-75', 6 SPF, 60 DEG PHASE, 34J UJ HNS CHARGES.WILL FINISH PERF 7-29. TIME LOG ENTRY 10:30 MI-TGSM-RU SWS WALStt & CREW 12:00 RIH WITH GR/CCL. 1.6875" OD, 21.3'LOG ZONE OF INTEREST. TOOH 13:50 PT 4000 PSI. RIH WITH CCL/I 0' GUN/6' GUN 15:10 SHOOT 7444-50' 6 SPF WITH 500 WHP. PRESSURE DROPPED TO 400 PSI. SHOOT 7365-75' 6 SPF WITH 400 WHP. PRESSURE DROPPED TO 300 PSI. TOOH 16:30 RIH WITH CCL/20' GUN. 17:15 SHOOT 7421-4 !' 6 SPF WITH 400 PSI WHP. DROPPED TO 200 PSI AF1T~ TOOH. 00:00 USED 34J UJ HNS CHARGES. EH--0.3", PEN=21.97', 19 GRAMS, 60 DEG PHASE. 18:10 RD FOR NIGttT. SWS EQUIP ON LOCATION. KUPARUK RIVER UNIT WELL SERVICE REPORT · 'J KI(1Q-08A(W4-6)) ~ JOB SCOPE JOB NUMBER 1Q-08A PERFORATE, PERF SUPPORT 0714971852.4 DATE DAILY WORK UNIT NIJMBER 07/29/97 PERFORATE; STATIC 8337 DAY OPERATION COMPLETE [ SUCCESSFUL 6 YES [ YES Initial Tbg Press [ Final Tbg Press [ Initial Inner Ann 300 PSI] 100 PSI[ 0 PSI DAILY SUMMARY KEY PERSON SWS~WALSH SUPERVISOR ODELL Final Inner Ann I Initial Outer Annl0 PSI 400 PSI Final Outer Ann 400 PSI PERFORATED 7575-88' & 7399-7421'. RECORDED STATIC BOTI'OM HOLE PRESSURE. TIME LOG ENTRY 09:00 MI-TGSM-RU. SWS WALSH & CREW 10:00 PT 3000 PSI. RIH WITH CCL/2' GUN/13' GUN 11:30 SHOT 7575-88' 12:00 SHOT 7419-21'. TOOH 13:00 AT SURFACE. RU CCL/20' GUN. RIH 13:45 SHOT 7399-7419'. TOOH 14:20 AT SURFACE. ALL SHOTS FIRED ON ALL GUNS.USED 34J UJ HNS CHARGES 19 GRAM, 21.97" PEN, 0.3" EH, 6 SPF, 60 DEG PHASE. 14:45 RIH WITH GR/CCL/TEMP/PRESS. 24' 2.125" MAX OD. 15:50 TAKING STATIC BOTFOM HOLE PRESSLIRE AND TEMPERATURE AT 7410'. 16:20 SURVEY COMPLETED. T=161 DEGF, P= 2862 PSI.TOOH 17:30 RDMO SWS. ARCO Alaska, Inc. A KUPARUK RIVER UNIT WELL SERVICE REPORT KI(1Q-08A(W4-6)) K?-08A DATE 08/17/97 DAY 1 JOB SCOPE JOB NUMBER PERFORATE, PERF SUPPORT 0813972020.7 DAILY WORK UNIT NUMBER PERFORATE F/7400 ~ 7440' ELM 8337 OPERATION COMPLETE [ SUCCESSFUL [ KEYPERSON SUPERVISOR YES YES SWS-MAJCHER BLACK Initial Tbg Press [FinalTbgPress Initial lnner Ann IFinallnnerAnn [~nitialOuterAnn [ Final Outer Ann 600 PSI 1500 PSI 0 PSI 0 PSI 0 PSI 0 PSI DAILY SUMMARY PERFORATED F/7400 - 7440 W/2-1/8" El DP @ 0 DEG PHASING (DOWN) & 4 SPF. TIME 07:30 09:00 09:30 I 1:45 12:30 14:30 15:00 16:00 LOG ENTRY MIRU SWS (MAJCHER & CREW- UNIT 8337). TGSM- JOB OVERVIEW & GUN SAFETY. MU GUN ASSEMBLY- 20'- 2-1/8" F,J DP/2-1/8" MPDF/1-11/16" GR & CCL/6'-2- 1/8" WT/HD (I'L-35'). PT BOPE TO 3500 PSI. RIH TO 7651' CCL ELM. TIE W/GR & CCL W/SWS 7/28/97 GR. PERFORATE F/7420 - 7440' ELM W/2-1/8" F_J DP@ 0 DEG PHASED DOWN & 4 SPF ISAW SURFACE INDICATIONS OF SHOT). MAKE LOGGING PASS & POOH. AT SURFACE. WELLHEAD PRESSURE DROPPED TO 400 PSI. ALL SHOTS FIRED. MU GUN ASSEMBLY #2 (SAME AS BEFORE). PT. RIH W/GUN ASSEMBLY & TIE IN AS BEFORE. PERFORATE F/7400 - 7420' ELM W/SAME GUNS AS BEFORE (SAW SURFACE INDICATIONS). ATIEMPT LOGGING PASS AFFER PERFORATING (TROUBLE W/GR TOOL) & POOH. AT SURFACE. ENSURED GUN FIRED & RU LRS F/INJECTIVITY TEST. INJECTED F/.5 - 1 BPM DIESEL. PRESSURE BROKE BACK @ 3750 PSI TO 3200 PSI (INJECTED TOTAL OF 10 BBLS). RD LRS & SWS. OFF LOCATION & TURN OVER TO PRODUCTION F/HPBD. SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-86298 Sidetrack No. 1 Page 1 of 1 [!.r~_-i Company ARCO ALASKA, INC. Rig Contractor & No. Nordic Drilling Co. - Rig II Field KUPARUK RIVER UNIT .~=~a~ Well Name & No. PAD 1Q/8A Survey Section Name Definitive Survey BHI Rep. KIRT CHRISTENSEN WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -1549.00 Grid Correction 0.000 Depths Measured From: RKB ~] MSL0 SS~- Target Description Target Coord. E/W Slot Coord. E/W -1298.00 Magn. Declination 27.850 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30m[~ 10m0 Vert. Sec. Azim. 143.41 Magn. to Map Corr. 27.850 Map North to: OTHER --, SURVEY DATA __ Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (FT) (F-'I~ (F~ (Per 100 F'r) Drop (-) Left (-) GMS 6095.00 33.98 81.50 5458.86 1055.93 206.38 2048.99 TIE IN POINT -- 01 -JUL-97 MWD 6194.00 33.65 81.60 99.00 5541.11 1081.65 214.48 2103.49 0.34 -0.33 0.10 Interpolated KOP .__ 01 -JUL-97 MWD 6364.63 39.30 109.00 170.63 5679.18 1149.06 203.71 2202.08 10.02 3.31 16.06 4 3/4" M1/XL 1.5 DEG AKO __ 01-JUL-97 MWD 6458.17 40.70 124.40 93.54 5751.01 1202.47 176.77 2255.39 10.67 1.50 16.46 01 -J UL-97 MWD 6553.99 43.00 138.00 95.82 5822.53 1264.68 134.74 2303.14 9.75 2.40 14.19 02-J UL-97 MWD 6650.50 47.80 142.30 96.51 5890.29 1333.24 81.96 2347.05 5.90 4.97 4.46 -, 02-J U L-97 MWD 6747.21 52.00 141.80 96.71 5952.57 1407.18 23.64 2392.54 4.36 4.34 -0.52 02-J UL-97 MWD 6841.81 51.20 141.00 94.60 6011.33 1481.27 -34.30 2438.79 1.07 -0.85 -0.85 02-J UL-97 MWD 6886.72 49.70 141.70 44.91 6039.93 1515.87 -61.34 2460.42 3.55 -3.34 1.56 04-JUL-97 MWD 7607.00 66.25 138.00 720.28 6420.65 2122.97 -525.21 2854.07 2.34 2.30 -0.51 Magnetic Single Shot Survey 05-JUL-97 MWD 7827.00 64.25 138.00 220.00 6512.75 2321.86 -673.67 2987.75 0.91 -0.91 0.00 Magnetic Single Shot Survey 05-JUL-97 MWD 7868.00 64.25 138.00 41.00 6530.57 2358.62 -701..12 3012.46 0.00 0.00 0.00 Projected Data - NO SURVEY ... __ ._ _ ARCO ALASKA INC. KRU / 1Q-08A 500292122501 AK-MW- 70193 COMPUTATION DATE: SPERRY- SUN DRILLING SERVICES ANCHORAGE ALASKA 9/24/97 DATE OF SURVEY: 070297 MWD SURVEY JOB NUMBER: AK-MW-70193 KELLY BUSHING ELEV. = OPERATOR: ARCO ALASKA, PAGE 85.95 FT. INC. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS INCLN DIRECTION DG MN DEGREES DG/100 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST VERT. SECT. 6094.85 5458.80 5372.85 33 58 N 81.50 E .00 206.53N 2049.58E 6194.00 5541.18 5455.23 33 39 N 81.60 E .34 214.64N 2104.16E 6364.63 5679.24 5593.29 39 17 S 71.00 E 10.02 203.87N 2202.75E 6458.17 5751.08 5665.13 40 42 S 55.60 E 10.67 176.93N 2256.06E 6553.99 5822.60 5736.65 43 0 S 42.00 E 9.75 134.90N 2303.81E 1055.90 1081.92 1149.33 1202.74 1264.95 6650.50 5890.36 5804.41 47 47 S 37.70 E 5.90 82.12N 2347.73E 6747.21 5952.64 5866.69 52 0 S 38.20 E 4.36 23.80N 2393.22E 6841.81 6011.40 5925.45 51 12 S 39.00 E 1.07 34.13S 2439.47E 6886.72 6039.99 5954.04 49 42 S 38.30 E 3.55 61.17S 2461.09E 6942.00 6075.74 5989.79 49 42 S 38.30 E .00 94.26S 2487.22E 1333.51 1407.45 1481.54 1516.14 1558.28 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 2489.01 FEET AT SOUTH 87 DEG. 49 MIN. EAST AT MD = 6942 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 143.41 DEG. TIE-IN SURVEY AT 6094.85.00' MD WINDOW POINT AT 6194.00' MD PROJECTED SURVEY AT 6942.00' MD 0CT 0 1 1997 _.-'%iaska Oil & Gas C rm. ..... ORIGINAL SPE '-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA INC. KRU / 1Q-08A 500292122501 AK-MW- 70193 COMPUTATION DATE: 9/24/97 DATE OF SURVEY: 070297 JOB NUMBER: AK-MW-70193 KELLY BUSHING ELEV. = 85.95 FT. OPERATOR: ARCO ALASKA, INC. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 6094.85 5458.80 5372.85 6942.00 6075.74 5989.79 206.53 N 2049.58 E 636.05 94.26 S 2487.22 E 866.26 230.21 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPEI '-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC. KRU / 1Q-08A 5002921225o1 AK-MW-70193 COMPUTATION DATE: 9/24/97 DATE OF SURVEY: 070297 JOB NUMBER: AK-MW-70193 KELLY BUSHING ELEV. = OPERATOR: ARCO ALASKA, 85.95 FT. INC. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD DIFFERENCE VERTICAL CORRECTION 6094.85 5458.80 5372.85 206.53 N 2049.58 E 636.05 6127.59 5485.95 5400.00 209.23 N 2067.68 E 641.64 6248.11 5585.95 5500.00 216.47 N 2134.44 E 662.16 6373.30 5685.95 5600.00 201.99 N 2207.92 E 687.35 5.59 20.52 25.19 6504.48 5785.95 5700.00 158.20 N 2280.08 E 718.53 6644.01 5885.95 5800.00 85.87 N 2344.78 E 758.06 6801.20 5985.95 5900.00 9.54 S 2419.55 E 815.25 6942.00 6075.74 5989.79 94.26 S 2487.22 E 866.26 31.18 39.52 57.19 51.00 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS OF:IICI--lNG S E I:! ~J I I-- I:: S September 29, 1997 ARCO Alaska, Inc. AOGCC, Lori Taylor 700 G Street Anchorage, AK 99501 Re: MWD Survey 1Q-08A Dear Sir/Madam, Enclosed is two hard copy of the above mentioned file(s). Well 1Q-08A MWD survey Tie-In point at 6094.85.00% Window point at 6194.00 and a Projected survey at 6942.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachments. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 9/22/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 A'I-I'N: Sherrie NO. 11366 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk 1B-8A C~-/- /Ic~ CEMENT BOND LOG 970811 I 1 IIQ-08A c~7- C)~'~ STATIC BOTTOM HOLE SURVEY 970729 I 1 1R-34 (~- J(~- GAS LIFTSURVEY 970810 I 1 3 F- 12 Z~ ~' ~ ~ ~> {..~ tC-~ INJECTION PROFILE 97 061 9 1 1 31-02 ~,~- ~<3 ~ t~ C.~ INJECTION PROFILE 970818 I 1 31-06 ~ c/._ (~.~ {~ ~ INJECTION PROFILE 970708 I 1 3K-23 ~- C~Cl~ CEMENT EVALUATION LOG W/GR 970629 I 1 3K-23 ~ CEMENT BOND LOG W/GE 970629 I 1 3K-26 ~"] - O-/'~ STATIC BHP LOG 970723 I 1 3 M- 17 ~ '-/ - C:) ~ c{ GAS LIFT SURVEY 970707 I 1 3 M- 23 C{ '~ .. i.~-j GAS LIFT SURVEY 970704 I I ..~ 3N-03 ~(o- O1(~ (,,IL, I C--~INJECTION PROFILE 970703 I 1 ~..... 3N-7 '~ (~" O~ PRODUCTION PROFILE 970702 I I ,,, 3N-7 ',1/' DEFT LOG 970702 I I Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RECEIVED SEP 2 9 ]997 Alsska Oil & Gas Coi~s. Commission Anchorage WELL LOG TRANSNHTTAL To.' State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs September 3, 1997 1Q-08A, AK-MW-70193 The technical data listed below is being submitted herewith. Please address any problems or concems to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1Q-08A: 2" x 5" MD Gamma Ray Logs: 50-029-21225-01 2"x 5" TVD Gamma Ray Logs: 50-029-21225-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia S£P 0 5 ]997 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company nRII_I_I NI:3 '=~ERL/Ir'E=; WELL LOG TRANSM/TTAL To: State of Alaska September 3, 1997 Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor ~' 3 O01 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 1Q-08A, AK-MW-70193 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Yah Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-21225-01 R CE VED S £P 0 3 ]997' 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 8/27/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11291 Company: Alaska Oil & Gas Cons Comm Attn' Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Reservoir Analysis Logs) , Well Job # Log Description Date BL RF Sepia LIS Tape 1Q-08A ~7' 07"~ 97378 PDCGR "J::J~7'~'~ 970720 1 1Q-08A ~ 97378 CBT/GR 970720 I 1 1E-31 c~7--/3~ 97379 PDCGR ~ ~'7 ~ 970802 1 1E-31 ~ 97379 CBT/GE 970802 1 1 Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RECEIVED AUG 2.8 1997 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial ARCO 1Q-eA 7" Set @ x Weekly Workover: Nordic Rig No. 2 PTD # 97-93 Rep.: Rig Rep.: 7,339 Location: Sec. Other DATE: 6/27/97 Rig Ph.# 659-7115 Bobby Mordson Shane McGeehan 26 T. 12N R. 9E Meridian UM MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location Yes Standing Order Posted Yes Well Sign OK Drl. Rig Hazard Sec. OK BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams 1 Blind Rams 1 Choke Ln. Valves '/ HCR Valves Kill Line Valves Check Valve FLOOR SAFETY VALVES: Quan. Upper Kelly / IBOP Lower Kelly / IBOP Ball Type 2 Inside BOP 1 Test Pressure 250/3,500 250/3, 500 250/3, 500 250/3,500 Quan. Test Press. P/F Test 250/3, 000 P Pressure 250/3500 250/3, 000 250/3500 250/3500 250/3500 1 250/3500 2 250/3500 N/A N/A P P P N/A P/F P F P P CHOKE MANIFOLD: No. Valves 12 No. Flanges 24 Manual Chokes Hydraulic Chokes '/ 250/3,000 Functioned Functioned P/F P P P P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure MUD SYSTEM' Visual Alarm 200 psi Attained After Closure minutes 12 Trip Tank OK OK System Pressure Attained n~llltes 55 sec. Pit Level Indicators OK OK Blind Switch Covers: Master:. OK rleB~8: OK Flow Indicator OK OK Nitgn. Btl's: 4~ 2200 Meth Gas Detector OK OK Psig. H2S Gas Detector OK OK 3000I 2200 Number of Failures: 1 ,Test Time: 3.0 Hours. Nuntherofvalvestestsd 20 Repair or Replacement of Failed Equipment will be made within 1 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Omee at: Fax No. 276-7542 Inspector North Slope Pager No. 659-.3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: The lower Kelly valve failed to test and will be changed out before drilling begins. Distribution: orig-Well Fiie c - Oper./Rig c- Database c - Trip Rpt File c- Inspector F1-021 L (Rev.12/94) STATE WITNESS REQUIREDP YES x NO 24 HOUR NOTICE GIVEN YES x NO Waived By: Witnessed By: AAVKF1 EE.XLS Chuck$cheve MEMORANDUM TO: David John/~,/ Chairmar¢~, TM THRU: Blair Wondzell, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 27, 1997 FILE NO: aavkflee. DOC FROM: Chuck Scheve, ~-~ SUBJECT: Petroleum Inspector BOPE Test Nordic 2 KRU 1Q-8A PTD 97-93 Friday June 27~1997: I traveled to ARCOs KRU lQ Pad to witness the initial BOPE Test on Well 8A being redrilled by Nordic Rig 2. As the attached AOGCC Test Report shows the test lasted..~hours and there was 1 failure. The lower Kelly valve failed to pressure test and will~,changed out, and an inspector notified, after the tubing is laid down. The rig was clean and all related equipment appeared to be in good condition. The location was well organized] allowing good access to all areas of the rig. SUMMARY: I witnessed the initial BOPE test on Nordic Rig 2 redrilling ARCOs KRU 1Q- 8A Well. Nordic 2, 6127197, Test Time 3 hours, 1 Failures Attachments: aavkflee.xls X Unclassified Classified Unclassified with Document RemoVed TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 May21, 1997 Michael Zanghi Drill Site Development Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 1Q-08A ARCO Alaska. inc. Permit No. 97-93 Sur. Loc. 1549'FNL, 1298'FEL, Sec. 26, T12N, R9E? UM Btmnhole Loc. 2128'FNL, 1549'FWL, Sec. 25, T12N, R9E. UM Dear Mr. Zanghi: Enclosed is the approved application tbr permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. Chairman Inston BY ORDER OF THE COMMISSION dlf/Enclosures Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA 'ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill Redrill X lb Type of Well Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry BI Deepen r-1 Service X Development Gas E] Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 86', Pad 54' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorac~e, AK 99510-0360 ADL 25641, ALK 2572 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1549' FNL, 1298' FEL, Sec. 26, T12N, R9E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 1945' FNL, 1413' FWL, Sec. 25, T12N, R9E, UM 1Q-08A #U-630610 At total depth 9. Approximate spud date Amount 2128' FNL, 1549' FWL, Sec. 25, T12N, R9E, UM 5/22/97 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1Q-26 7717' MD 1945' @ Top Intvl feet 14.5' @ 400' feet 2560 6557' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.O35(e)(2)) Kickoff depth 6192' feet Maximum hole angle 51.5° Maximumsurlace 2845 psig At total depth (TVD) 3520 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 6-1/8" 4-1/2" 12.6# L-80 NSCT 1727' 5990' 5367' 7717' 6557' 243 sxs Class G 19. To be completed lot Redrill, Re-entry, and Deepen Operations. Present well condition summary I'~A~ ~ 6 1997 Effective depth: measured 7254 feet Junk (measured) - · true verlica 6443 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 80' 1 6" 240 Sx AS II 1 1 6' 1 1 6' Surface 3697' 9-5/8" 850 sx CS III, 600 sx G 3733' 3545' Intermediate Production 7304' 7" 376 sx Class G. 250 sx Permafrost C 7339' ~r ] L~, _1~1,'i1~, j~ Liner I L3/I J L Perlorationdepth: measured 6850'-6892', 6936'-6944', 6979'-6983', 7040'-7074', 7098'-7114' MD true vertical 6096'-6132'. 6170'-6177', 6207'-6210', 6259'-6288'. 6308'-6322'TVD 20. Attachments Filing fee X Property plat r"] BOPSketch X Diverter Sketch E] Drilling program X Drilling fluid program X Time vs depth plot r-] Refraction analysis [] Seabed repod r-~ 20 AAC 25.050 requirements X 21. I hereby cerffy that lhe foregging is true and correct to the best of my knowledge: (Contact William Isaacson at 263-4622 with questions.) Signed :'b ., '/~,.~/,,. Title Drill Site Develop. Supv. Date ~,? ,~)- Commission Use Onlyl/'7/ J Permit Number I number J Approval dale~/.~_~.~_ i _. ~/~.. --~ See cover letter for .. .-- other requirements ?2' T50-o2..<:/ 2_.. 5'- -,3 1 ,.,., ,.... Conditions of approval Samples required [] Yes [;~ No Mud log required [] Yes [~ No Hydrogen sulfide measures .~ Yes [] No Directional survey required [] Yes E] No Required working pressure for BOPE [] 2M ~] 3M D 5M ~ 1OM E] 15M Other: ,;I idil-laJ~ SJggOd ~':I by order of e~_ .....(~:~/_.-. Approved by i)avid W. Johnston Commissioner the commission Ddt Fnrm 10-401 Rn.v 7-24-R.q Rllhmil in trinlic..-qt¢. REDRILL PLAN SUMMARY Well 1Q-08A Type of well (producer/injector): Surface Location' Top Producing Interval- Bottom Hole Location: MD- TVD- Rig- Estimated Start Date- Operation Days to Complete: Injector 1549' FNL, 1298' FEL, SEC 26, T12N, R9E, UM 1945' FNL, 1413' FWL, SEC 25, T12N, R9E, UM 2128' FNL, 1549' FWL, SEC 25, T12N, R9E, UM 7717' 6557' Nordic Rig 2 5-22-97 13 Drill Fluids Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Program- Milling Window in 7" casing 9.6 >25 35-40 65-75 15-20 24-30 .. 8.5-9.5 Kick off to weight up 9.5-9.7 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 11.3 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System- Swaco Geolograph Adjustable Linear Shaker Brandt SMC-10 Mud Cleaner Triflow 600 vacuum Degasser, Poor Boy Degasser Pit Volume Totalizer (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators and Jetting Guns Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Page 1 Casing/Tubing Hole size 6-1/8" Program: Csg/Tbg 4-1/2", 12.6#, L-80, NSCT Tubing 4-1/2", 12.75#, L-80, EUE Length Top (MDrTVD) Btm (MD/TVD 1727' 5990'/5367' 7717'/6557' 5964' 26'/26' 5990'/5367' Cement Calculations: Casing to be cemented: 4-1/2" in 6-1/8" open hole Volume - 243 sxs of class G Blend @ 1.19 cu ft/sx Based on: Shoe volume, open hole volume + 64%, & 200' liner lap. Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed. Maximum anticipated surface pressure is estimated at 2,845 psi and is calculated using a gas column to surface. The expected leak-off at the section cut in the 7" casing is estimated at 14.5 ppg EMW. With an expected formation pressure in the Kuparuk of 3520 psi and a gas gradient of 0.11 psi/fi, this shows that formation breakdown would not occur before a surface pressure of 2,845 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3500 psi. See attached BOPE schematic. Drilling Hazards: Lost Circulation: Overpressured Intervals: Other Hazards: The suspect lost circulation zones throughout the Kuparuk field are the K- 10 and the K-5 intervals. The sidetrack 1Q-08A, will kick off out of the 7" casing below both the K-5 and K-10. The 7" casing has good quality cement up to and above the planned kick-off window, which should isolate the K-10 and K-5 from the sidetrack operations. If the Formation Integrity Test shows that the K-10 and K-5 intervals are not isolated and will not hold the desired equivalent mud weight, a cement squeeze at the window could be performed to help isolate these intervals. Off-set drilling data shows that wells in the area of 1Q-08A have been drilled to TD with 11.6 ppg mud and no loses. The kick-off point in 1Q-08A is below any zones which would be of pressure concern prior to weighting up for the Kuparuk interval. Good drilling and tripping practices are vital for avoidance of differential sticking across the A Sand. Directional: KOP: Max hole angle: Close approach: 6192' MD / 5539' TVD 51.5° (in sidetrack portion) No Hazards Page 2 41.1 ° (in original well at 3900' MD) Logging Program: Open Hole Logs: GR/Resistivity Cased Hole Logs: GR/CET/CCL Notes: All drill solids generated from the 1Q-08A sidetrack will be hauled to CC-2A in Prudhoe Bay for grind and inject. If the Kuparuk River bridge outage will not allow trucking of these solids to Prudhoe, they will be stored and later processed or disposed of in a permitted solids disposal area. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or to Parker 245 to be disposed by annular pumping into the permitted annulus Parker is connected to at that time. The permitted well will be within the Kuparuk River Unit. Page 3 KRU 1Q-08A GENERAL SIDETRACK PROCEDURE PRE-RIG WORK: . RU CTU. RIH with inflatable cement retainer on CTU. Set inflatable in 3-1/2" tubing immediately below top production packer. Mix cement. Circulate the cement down coil to immediately above circulating valve on top of retainer. Close circulation valve and down-squeeze cement below retainer into A Sand perfs. Use sufficient volume to fill 3-1/2" tubing down through tubing tail and 7" casing from top of fill to tubing tail, plus excess to squeeze away into perfs if possible. Unsting from retainer and circulate well clean on top of inflatable retainer. RDMO CTU. 2. RU slickline unit. RIH and chemical cut tubing in middle of first joint above top production packer. WORKOVER RIG WORK: 1. MIRU Nordic Rig 2. Lay hard-line to tree. 2. Verify well is dead. Load pits w/water. Circulate well to water. 3. Pressure test wellbore to 2500 psi testing cement squeeze and retainer, to ensure isolation from perforations. Set BPV. 4. ND tree. NU and test BOPE. . Screw in landing joint. Pull tubing hanger to rig floor. Spot a 150' cement plug on top of top production packer. Pull above cement plug top and reverse circulate tubing clean. POOH laying down all tubing and jewelry. 6. RU E-line unit. Run gauge ring through bridge plug setting depth. RIH and set permanent bridge plug at 6217' MD-RKB. . MU and RIH with bottom trip whipstock and window milling assembly. Tag bridge plug and set down weight to set whipstock. Shear free with milling assembly, circulate well to milling fluid, and mill window in 7" casing. POOH LD milling assembly. . RIH w/6-1/8" bit, mud motor, MWD / LWD, and steerable drilling assembly. Slide out window, kick-off well, and directionally ddll to total depth as per directional plan. Short trip to window in casing. POOH. 9. Run 4-1/2" liner to TD w/200' of overlap to top of milled window. 10. Cement liner. Set liner hanger. POOH w/DP. 11. RIH w/completion assembly and sting into polished bore receptacle at top of liner. Space out. Displace well to sea water at max rate. Set production packer. Test tubing, liner, and annulus. 12. ND BOPE. NU and test tree. Freeze protect well with diesel. RDMO Nordic. 13. Clean out well to PBTD w/coiled tubing. Run Cement Evaluation tool & perforate through tubing. Lower Limit: 10 days Expected Case: 12 days Upper Limit: 18 days No problems milling window, drilling new hole, or running completion. Difficulties encountered milling window, or drilling new hole., Page 4 i~'x'~ ' iu~,¢ ARCO ALASKA, Inc. Structure : Pad 10 Well: 8A Field : Kuparuk River Unit Location : North Slope, Alaska Creoted by jones For: B Isaacson] Date p{otted : 14-Moy-.97 Plot Reference is 8A Verslon Coordinetes ore in feet reference slot ~'SA. True Ve~col Oept~~~e RKB (Nordic {2). WELL PROFILE DATA Point MD Inc Dir TVD North East V. SectDeg/lO0 KOP 6192.00 53.66 81.60 5539.44 214-.32 2102.58 1081.02 0.00 I'nd of Build/Turn 6677,84 51.54- 143.4-15910.91 74.39 2361.67 1347,92 9.00 Target 1Q-a(St) Rvsd 1 7425.67 51.54- 143.41 6376.00 -395.84- 2710.72 1933.55 0.00 End of Hold 7517.35 51,54- 14-3,4164-35,00-453.47 2753.50 2005.32 0.00 T.D. & End of Hold 7717.33 51.54 143.41 6557.39 -579.22 2846.86 2161.94 0.00 5400 5500 56O0 5700 '~ 5600 Q) 5900 6000 61 O0 6200 6300 6400 65O0 66O0 6700 143.41 Azimuth 2162' (TO TD) ***Plane of Proposal*** East (feet) -> 2000 21 O0 2200 2300 2400 2500 2600 2700 2800 2900 I I II II~x.. I { II II II {I I { I Bose E0C 33.63 KOP - Sidetrack Pt 37.08 DLS: g.o0 deg per 100 ft 34.37 41.36 46.78 Bose HRZ EOC K-1 Marker Top Kuporuk Top Unit C K- 1 Marker Top Kuporuk Top Unit C Top Unit B TARGET - Top A3 Bose Kup Top Unit A Top Unit B 4O0 300 20O lOO o 100 200 300 v 4OO 500 6OO 7O0 Top Unit A TARGET - Top A3 Interval Bose Kup Sands TD AVERAGE ANGLE 51.54 DEG ] [ i i i [ i i i i [ i i i i [ i i i i~ i i i i i i i go0 1000 1100 1200 1~00 1400 1500 1600 1700 1800 leO0 2000 2100 2200 2~00 Verficol Secfion (feel) -> Azimufh 14.5.41 wifh reference 0.00 N, 0.00 E from sial #SA 9-5/8" 36#, J-55 set at 3728' MD 1Q-08A Proposed' ompletion 4-1/2" landing nipple profile RKB = 86' Pad Level = 54' ** All Depths are reference Nordic 2 RKB 4-1/2", 12.75#, L-80 EUE 8rd Mod tubing to Surface 4-1/2" Sliding Sleeve 4-1/2" liner top at +/-5990' MD 7"x 4-1/2" permanent production packer at +/-5970' MD 4-1/2" landing nipple profile Liner Top: - Baker 5-1/2" setting sleeve (4.997" ID). - Baker 10' Seal Bore Extension (4.75" seal bore, 5.875" OD). - Baker 5" x 7" 18# L-80 'CMC' mechanical liner hanger (4.276" ID) w/4-1/2" NSCT pin on bottom. Window in 7" 6191'- 6204' MD Cement Retainer at +/- 6212' MD Abandoned C Sand Peds 4-1/2"landing nipple profile set+/-100'MD above top ofthe C Sand. Abandoned A Sand Perfs 7", 26#, J-55 set at 7334' MD 4-1/2" L-80 NSCT liner @ +/-7717' MD 7-1/16" 5000 PSI BOP STACK ACCUMULATOR CAPACITY TEST I 6 PIPE RAM ,] I · I 5 BLIND RAM> I MUD CROSS 4 L~ 3 P PERAM ~= / J I l . 1 I I 1 , I 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURETHAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 5 MINUTES. INCREASE PRESSURE TO 3500 PSI AND HOLD FOR 5 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND INSIDE MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS, HCR VALVE ON CHOKE LINE, AND OUTSIDE MANUAL VALVE ON KILL LINE. 6. TEST TO 250 PSI AND 3500 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3500 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOq-FOM PIPE RAMS. TEST BOq-FOM RAMS TO 250 PSI AND 3500 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. 10. CLOSE BLIND RAMS AND TEST TO 3500 PSI FOR 5 MINUTES. BLEED TO ZERO PSI. 11. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 12. TEST STANDPIPE VALVES TO 3500 PSI. 13. TEST KELLY COCKS AND INSIDE BOP TO 3500 PSI WITH KOOMEY PUMP. 14. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 15. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1.11" - 3000 PSI CASING HEAD 2.11"- 3000 PSI x 7-1/16" 5000 PSI TUBING HEAD 3.7-1/16" - 5000PSI SINGLE GATE W/PIPE RAMS 4.7-1/16"- 5000 PSI DRLG SPOOL W/CHOKE & KILL LINES 5.7-1/16" - 5000 PSI SINGLE GATE W/ BLIND RAMS 6.7-1/16" - 5000 PSI SINGLE GATE W/PIPE RAMS 7.7-1/16" - 5000 PSI ANNULAR PREVENTER NORDIC RIG g2 LEVEL 1 z 28'-6" ~'I1RES: 40-57 73'-0" 25'-0' .~ lJ ~''1 ~.~ SPIRAL n' /Ii~'-'~"T-" STAIRS _ : I :2o EMSCO F-800(~~ o TRIPLEX MUD · , PUMP ,-, .... T TRIPLEX MUD PUMP SPIRAL ~ , STAIRS 1 cON~O'L ~ONSOU~ _L_ - 36'-0' I 53'-0' ~ORDIC RIG g2 LEVEL 2 I I 1 NORDIC RIG g~2 LEVEL 3 I UNE I 1 SPOOL I WATER TANK /GLYCOL TANK USTER AIR HEATER MUD TANK 750 BSLS HYDRAUUC CHOKE MANIFOLD LOFRCE 84'-0' 123'-0' 1 7'--11' '--" STATE OF ALASKA ~-'-'" ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __X Suspend_ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well_ Plugging __X Time extension Stimulate Change approved program _ Pull tubing _ Variance _ Perforate _ Other Plugback for X Reddll 2. Name of Operator ARCO Alaska, Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at sudace 1549' FNL, 1298' FEL, Sec. 26, T12N, R9E, UM At top of productive interval 1281' FNL, 1149' F-WL, Sec 25, T12N, R9E, UM At effective depth 1254' FNL, 1356' FWL, Sec. 25, T12N, R9E, UM At total depth 1248' FNL, 1423' F-WL, Sec. 25, T12N, R9E, UM 12. Present well condition summary Total Depth: measured (approx) true vertical Effective depth: measured (approx) true vertical 7387' 6557' 7254' 6443' feet Plugs (measured) feet feet Junk (measured) feet 6. Datum elevation (DF or KB) RKB 91', Pad Elev. 54' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1Q-08 9. Permit number 84-209 10. APl number 50-029-21225 11. Field/Pool Kupurak River Field/ Kuparuk River Oil Pool ORIGINAL Casing Le n g t h Structural Conductor 8 0' Surface 36 97' Intermediate Production 7 3 04' Liner Perforation depth: measured 6850'-6892', true vertical 6096'-6132', Size 16' 9-5/8' 7" 6936'-6944', 6170'-6177', Cemented Measured depth True vertical depth 240 SxASII 116' 116' 850 sx CS Ill & 3733' 3545' 600 sx Class G 376 sx Class G & 7339' 6516' 250 sx CS I 6979'-6983', 6207'-6210', Tubing (size, grade, and measured depth) 3-1/2", J-55, @ 7027' MD Packers and SSSV (type and measured depth) Baker 'FHL' @ 6691', Baker 'FB-I' @ 7004', Baker SSSV @ 1883' 6259'-6288', 6308'-6322' i 1997 ~laslCa, .Oj! .& Was O0ns, 13. Attachments Description summary of proposal __X Contact William Isaacson at 263-4622 with any questions. 14. Estimated date for commencing operation May 20, 1997 16. If proposal was verbally approved Detailed operation program __ BOP sketch_ 15. Status of well classification as: Oil __ Gas _ Suspended _ Name of approver ,~ Date approved 17. I hereby certip that the forefoing is true and correct to the best of my knowledge. "'~~-"~C Title Drill-Site Development Supv Signed FOR COMMISSION USE ONLY Conditions of approval: Notify '"Commission so representative may witness Plug integrity __¢-" BOP Test ~ Location clearance Mechanical Integrity Test _ Subsequent form require 10- z.('_,~...~. . _. uF~g~na: ~gne. o Approved by the order of the Commission David W. Johnston Service Commissioner Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE WELL PERMIT CHECKLISTco .Y /~,r C'_ .~'-'_~ WELL NAME ~N~ C~,ASS /' ~J~l / O- ~ ~/~ PROGRAM: expF1 dev [] redrl~ serv• wellbore seg• ann disp para req• GEO~ ~A ~? ~ UN~# /?/~ O./OF~ SHO~ ~ ~j ADMINISTRATION Permit fee attached ................... Lease number appropriate ................ Unique well name and number ............... Well located in a defined pool ............. Well located proper distance from drlg unit boundary. Well located proper distance from other wells ...... Sufficient acreage available in drilling unit ...... If deviated, is wellbore plat included ........ Operator only affected party .............. Operator has appropriate bond in force ......... Permit can be issued without conservation order .... Permit can be issued without administrative approval. Can permit be approved before 15-day wait ....... ENGINEERING REMARKS APPR 14. Conductor string provided ................ Y N~ 15. Surface casing protects all known USDWs ......... Y N 16. CMT vol adequate to circulate on conductor & surf csg. . Y N 17. CMT vol adequate to tie-in long string to surf csg . . .Y__ N 18. CMT will cover all known productive horizons ...... Y~ N' 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved. ~ N--/~' 22. Adequate wellbore separation proposed .......... ~ 23. If diverter required, is it adequate ........... 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ...................... ~ N 26. BOPE press rating adequate; test to ~ psig.~ N 27. Choke manifold complies w/API RP-53 ~~-~... ~ N 28. Work will occur without operation shutdown ....... Y~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY APPR DATE 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/_ Data presented on potential overpressure zones ..... Y 32.31. Seismic analysis of shallow gas zones .......... ~/~ /U~ 33. Seabed condition survey (if off-shore) ........ ./T N 34. Contact name/phone for weekly progress reports . . ..,/. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMI SS ION: Comments/Instructions: HOW/dlf- A:\FORMS\cheklist rev 01/97 Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * * ............................ . ....... SCHLUMBERGER ....... . ............................ . COMPANY NAME : ARCO ALASKA, INC. WELL NAFIE : lQ - 08A FIELD NAFiE : KUPARUK RIVER UNIT BOROUGH : NORTH SLOPE STATE : ALASKA API NUPiBER : 500292122501 REFERENCE NO : 98006 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JAN-1998 10:09 PAGE: **** REEL HEADER **** SERVICE NA~E : EDIT DATE : 98/01/ 6 ORIGIN : FLIC REEL NAME : 98006 CONTINUATION # : PREVIOUS REEL : COM~ElVT : ARCO ALASKA INC, DS 1Q-OSA, KUPARUK RIVER ,API #50-029-21225-01 **** TAPE HEADER **** SERVICE NA~E : EDIT DATE : 98/01/ 6 ORIGIN : FLIC TAPE NA~E : 98006 CONTINUATION # : 1 PREVIOUS TAPE : COM~IEAUf : ARCO ALASKA INC, DS 1Q-O8A, KUPARUK RIVER ,API #50-029-21225-01 TAPE ~ER Kuparuk River Unit CASED HOLE WIRELINE LOGS WELL NA~IE: iQ - 08A API NUMBER: 500292122501 OPERATOR: ARCO Alaska, Inc. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 7-JAN-98 JOB NUM~ER: 98006 LOGGING ENGINEER: R. Walsh OPERATOR WITNESS: B. Odell SURFACE LOCATION SECTION: 26 TOWNSHIP: 12N RANGE: 9E FNL: 1549 FSL: FEL: 1298 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 86. O0 DERRICK FLOOR: 85. O0 GROUND LEVEL: 49. O0 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 9. 625 3733. 0 36. O0 2ND STRING 7. 000 6206.0 26. O0 3RD STRING 4. 500 7866.0 12.60 PRODUCTION STRING 4. 500 6005.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD (FIEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JAN-1998 10:09 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: SCHLUFiBERGER WELL SERVICES BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH ....... THIS TAPE CONTAINS THE LDWG EDIT FOR ARCO ALASKA WELL 1Q-OSA LOGGED 28-JUL-97. THIS LOG IS THE PRIMARY DEPTH CONTROL FOR THE WELL. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE AUJFI~ER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE S~Y LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 7770.0 6981.0 $ CURVE SHIFT DATA - PASS TO PASS (M~ASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUM~ER : BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH ....... REMARKS: THIS FILE CONTAINS THE CLIPPED DATA FOR PASS #1, MAIN PASS. LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JAN-1998 10:09 PAGE: $ LIS FO~T DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** ....................................................................................... NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) ....................................................................................... DEPT FT 1088383 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH GR GAPI 1088383 O0 000 O0 0 1 1 1 4 68 0000000000 TENS GR LB 1088383 O0 000 O0 0 1 1 1 4 68 0000000000 CCL GR V 1088383 O0 000 O0 0 1 1 1 4 68 0000000000 ....................................................................................... ** DATA ** DEPT. 7770.000 GRCH. GR -999.250 TENS.GR 1285.000 CCL.GR DEPT. 6982.000 GRCH. GR 82.547 TENS.GR 1235.000 CCL.GR 0.000 O. 056 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JAN-1998 10:09 PAGE **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ArOI~BER 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREFIFJFT: 0.5000 FILE SL~fMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 7783.0 6981.0 GRCH $ LOG HEADER DATA DATE LOGGED: 28-JUL-97 SOFTWARE VERSION'. CP 44.2 TIME LOGGER ON BOTTOM: 1220 2-JUL-97 TD DRILLER (FT) : 7771.0 TD LOGGER (FT) : 7770.0 TOP LOG INTERVAL (FT) : 7300.0 BOTTOM LOG INTERVAL (FT) : 7765.0 LOGGING SPEED (FPHR): 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GRCH GAM~A RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : TOOL NUMBER ........... CGRS-A- 863 3733.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JAN-1998 10:09 PAGE: LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : Produced Fluids 162.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): RE,lARKS: Tied into SWS CBT dated 20-JUL-1997. Ran log to determine correct gamma ray through zone of interst. Two CBLs have been run on this well and the gamma rays do not agree. This is the primary depth control for the well. 8337 Crew: Tom Foreman & Richard Wall THIS FILE CONTAINS THE RAW DATA FOR MAIN PASS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 16 4 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JAN-1998 10:09 PAGE: 6 TYPE REPR CODE VALUE .............................. 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAM~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEI~I CODE (HEX) ....................................................................................... DEPT FT 1088383 O0 000 O0 0 2 1 1 4 68 0000000000 GR PDC GAPI 1088383 O0 000 O0 0 2 1 1 4 68 0000000000 TENS PDC LB 1088383 O0 000 O0 0 2 1 1 4 68 0000000000 CCL PDC V 1088383 O0 000 O0 0 2 1 1 4 68 0000000000 ....................................................................................... ** DATA ** DEPT. 7783.500 GR.PDC 57.188 TENS. PDC 870. 000 CCL.PDC 0.004 ** END OF DATA ** **** FILE TRAILER **** FILE NAlVlE : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JAN-1998 10:09 PAGE: **** TAPE TRAILER **** SERVICE NAM~ : EDIT DATE : 98/01/ 6 ORIGIN : FLIC TAPE NAFZE : 98006 CONTINUATION # : 1 PREVIOUS TAPE : COI~4ENT : ARCO ALASKA INC, DS 1Q-OSA, KUPARUK RIVER ,API #50-029-21225-01 **** REEL TRAILER **** SERVICE NAFIE : EDIT DATE : 98/01/ 6 ORIGIN : FLIC REEL NA~iE : 98006 CONTINUATION # : PREVIOUS REEL : COMlViENT : ARCO ALASKA INC, DS 1Q-O8A, KUPARUK RIVER ,API #50-029-21225-01 Sperry-Sun Drilling Services LIS Scan Utility Thu Aug 28 10:07:17 1997 Reel Header Service name ............. LISTPE Date ..................... 97/08/28 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/08/28 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPDfNY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 3 AK-MW-70193 ERIC CRIBBS BOB MORRISON ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 1Q-08A 500292122501 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 28-AUG-97 26 12N 09E 1549 1298 86.00 84.40 54.00 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 80.0 9.625 3733.0 7.000 7339.0 6.125 6942.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL GAMMA RAY DATA (SGRD) IS DOWNHOLE RECORDED. 3. MWD RUNS 1 AND 2 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 4. MWD RUN 3 IS DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP). 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 6942'MD, 6080'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 6164.0 6884.0 ROP 6225.5 6945.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 6164.0 6201 0 6203 0 6205 5 6207 5 6208 5 6221 5 6230.0 6236.5 6241.5 6253 . 0 6258. 0 6260.5 GR 6161.5 6198 5 6201 0 6203 0 6205 0 6207 0 6220 0 6228 0 6234 0 6238 5 6251 5 6256 0 6258 5 EQUIVALENT UNSHIFTED DEPTH 6266 6270 6273 6277 6279 6280 6284 6286 6288 6289 6292 6295 6296 6304 6306 6310 6312 6320 6325 6328 6331 6332 6343 6346 6349 6353 6359 6360 6362 6364 6365 6366 6373 6382 6384 6387 6392 6394 6397 6399 6404 6407 6409 6410 6413 6413 6416 6421 6423 6430 6433 6436 6438 6439 6441 6446 6447 6451 6453 6455 .5 5 5 0 0 5 5 5 5 5 .5 .0 .5 .0 .0 .5 .5 .5 .0 .5 .0 .0 .5 .0 .5 .0 .0 0 5 0 5 5 5 0 0 5 5 5 5 5 0 0 0 5 0 5 0 0 0 5 5 0 0 5 5 0 5 5 5 0 6265 6269 6272 6275 6277 6279 6282 6285 6287 6288 6291 6294 6296 6304 6306 6309 6311 6319 6323 6327 6329 6331 6340 6344 6347 6350 6355 6357 6359 6360 6362 6364 6370 6378 6380 6387 6389 6392 6393 6395 6399 6405 6406 6408 6411 6412 6413 6419 6421 6427 6431 6434 6435 6437 6440 6444 6445 6448 6450 6453 .0 0 0 5 0 5 5 0 5 0 0 0 0 0 0 5 5 0 5 0 5 5 0 5 5 5 5 0 0 5 5 .0 5 5 5 5 0 0 0 5 .5 .5 5 0 0 0 5 0 0 5 0 5 5 0 0 0 5 0 5 0 6457 6461 6464 6466 6471 6477 6480 6482 6484 6488 6490 6493 6494 6496 6500 6503 6505 6506 6510 6513 6514 6517 6519 6523 6526 6530 6536 6541 6547 6550 6551 6553 6558 6569 6572 6574 6577 6580 6584 6592 6596 6601 6603 6606 6609 6611 6648 6649 6700 6704 6781 6782 6786 6788 6789 6798 6800 6803 6816 6818 5 5 5 0 5 5 0 0 0 0 .0 .0 .0 .5 5 0 5 5 0 0 0 0 0 5 .0 5 0 0 5 0 0 0 0 0 6454 6458 6462 6464 6469 6475 6477 6478 6481 6485 6488 6490 6492 6494 6499 6501 6503 6505 6508 6511 6512 6515 6517 6521 6524 6528 6534 6541 6545 6548 6550 6552 6558 6565 6571 6573 6575 6578 6581 6590 6595 6600 6602 6605 6607 6609 6646 6647 6699 6703 6779 6782 6784 6785 6787 6797 6799 6801 6814 6817 5 0 0 5 5 0 .0 .5 0 0 0 5 5 5 0 5 0 0 5 0 5 .0 5 0 0 5 0 0 5 0 .0 .0 0 5 5 0 0 5 5 5 0 0 0 5 5 0 5 5 5 0 0 0 0 5 5 0 0 5 5 0 6824.5 6822.5 6827.5 6825.5 6853.0 6850.5 6855.0 6852.5 6873.5 6870.5 6876.0 6873.0 6945.0 6942.0 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 3 $ REMARKS: MERGED MAIN PASS. $ MERGE TOP MERGE BASE 6224.0 6942.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD AAPI 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 6164 6945 6554.5 1563 6164 GR 51.31 939.93 141.513 1441 6164 ROP 16.6 251.8 81.7704 1440 622~.5 First Reading For Entire File .......... 6164 Last Reading For Entire File ........... 6945 Last Reading 6945 6884 6945 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 6161 . 5 6881 . 0 ROP 6224 . 0 6942 . 0 $ LOG HEADER DATA DATE LOGGED: 02-JUL- 97 SOFTWARE SURFACE -SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 34.3 MAXIMUM ANGLE: 52.0 MSC 1.32 / ISC 5.06 2.042 / 5.74 MEMORY 6942.0 6224.0 6942.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : TOOL NUMBER NGP SPC 176 6.130 6.1 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMIC) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND HT 9.80 50.0 9.5 25OO 4.2 .000 .000 .000 .000 49.5 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .7 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 AAPI 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 6161.5 6942 6551.75 1562 6161.5 GR 51.31 1003.8 141.637 1440 6161.5 ROP 16.6 251.8 81.6406 1437 6224 Last Reading 6942 6881 6942 First Reading For Entire File .......... 6161.5 Last Reading For Entire File ........... 6942 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/08/28 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 97/08/28 Origin ................... STS Reel Name ................ UAVANO~ Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Library. Library. Scientific Scientific Physical EOF Physical EOF End Of LIS File * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... RECEIVED AUG 28 3997' Alaska Oil & Gas C,~So Com~ COMPANY NAME '. ARCO ALASKA INC. WELL NAME : 1Q-O8A FIELD NAME : KUPARUK RIVER BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-21225-01 REFERENCE NO : 97378 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-AUG-1997 12:48 PAGE **** REEL HEADER **** SERVICE NAlViE : EDIT DATE : 97/08/24 ORIGIN : FLIC REEL NA~E : 97378 CONTINUATION # : PREVIOUS REEL : COI4~ENT : ARCO ALASKA INC, 1Q-O8A, KUPARUK RIVER, API #50-029-21225-01 **** TAPE HEADER **** SERVICE NADIR : EDIT mATE · 97/08/24 ORIGIN : FLIC TAPE NAME : 97378 CONTINUATION # : 1 PREVIOUS TAPE : COI~4F2V-T : ARCO ALASKA INC, 1Q-O8A, I<UPARUK RIVER, API #50-029-21225-01 TAPE HEADER KUPARUK RIVER CASED HOLE WIRELINE LOGS WELL NAME: 1Q-O8A API NU~ER: 500292122501 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 24-AUG-97 JOB NUMBER: 97378 LOGGING ENGINEER: G. JOHNSON OPERATOR WITNESS: M. CHANEY SURFACE LOCATION SECTION: 26 TOWNSHIP: 12N RANGE: 9E FArL: 1549 FSL: FEL: 1298 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 86. O0 DERRICK FLOOR: 85.00 GROUND LEVEL: 49.70 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 9. 625 3733.0 36. O0 7. 000 6206.0 26. O0 4. 500 7866.0 12.60 4. 500 6005.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-AUG-1997 12:48 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: RUN NUFiBER : 1 PASS NUMBER: 1 DATE LOGGED: 20-JUL-97 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH $ CONTAINED HEREIN IS LDWG FORMATTED PRIMARY DEPTH CONTROL GAMPIARAY DATA ACQUIRED ON ARCOALASKA'S 1Q-O8A WELL. $ $ PAGE: **** FILE HEADER **** FILE NAiViE : EDIT .001 SERVICE · FLIC VERSION : O01CO1 DATE : 97/08/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMeNT: 0.5000 FILE SUI~4ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 5800.0 7380.0 $ CURVE SHIFT DATA - PASS TO PASS (FiEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUM~ER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH REMARKS: THIS FILE CONTAINS THE MAIN LOG PRIMARY DEPTH CONTROL GAMMA RAY DATA. ALL DATA HAVE BEEN CLIPPED FOR LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-AUG-1997 12: 48 PAGE: INVALID DATA BEFORE FIRST READING AND AFTER LAST READING. NO DEPTH CORRECTION HAVE BEEN MADE SINCE THIS IS THE PRIMARY DEPTH CONTROL GAM~A RAY. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 255 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1065775 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CET GAPI 1065775 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CET LB 1065775 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CET V 1065775 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 5800.000 GRCH. CET 54.313 TENS.CET 1350.000 CCL.CET DEPT. 7380.000 CRCH. CET 64.125 TENS. CET 1070.000 CCL.CET O. 019 -0.003 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-AUG-1997 12:48 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 97/08/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 97/08/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUf~BER 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 5800.0 7380.0 CBL $ LOG HEADER DATA DATE LOGGED: 20-JUL-97 SOFTWARE VERSION: CP42.2 TItlE LOGGER ON BOTTOM: TD DRILLER (FT) : 7752.0 TD LOGGER (FT) : 7386.0 TOP LOG INTERVAL (FT) : 5800.0 BOTTOM LOG INTERVAL (FT) : 7380.0 LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL COLLAR LOCATOR CR GAF~VA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): TOOL NUMBER ........... CAL- YA- 92 SCC-SA-27 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-AUG-1997 12:48 PAGE: DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 7866.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : SEAWATER NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: PRIMARY DEPTH CONTROL USED: MAGNETIC MARKS CEMENT DATA: 256 SX TYPE G CEMENT, 15.8 PPG PUMP RATE= 4.25 BPM, IN PLACE AT 1616 ON 7/6/97 GOOD CEMENT FROM 7380' TO 6035' LOG RUN GOING DOWN HOLE THIS FILE CONTAINS THE RAW MAIN LOG PRIMARY DEPTH CONTROL GA~ff4A RAY. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-AUG-1997 12:48 PAGE: 6 TYPE REPR CODE VALUE 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1065775 O0 000 O0 0 2 1 1 4 68 0000000000 GR CBL GAPI 1065775 O0 000 O0 0 2 1 1 4 68 0000000000 TENS CBL LB 1065775 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CBL V 1065775 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 5794.000 GR.CBL 54.313 TENS.CBL 1570.000 CCL.CBL DEPT. 7387. 500 GR. CBL 71. 938 TENS. CBL 940. 000 CCL. CBL -0. 012 -0. 003 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-AUG-1997 12:48 PAGE: **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/08/24 ORIGIN : FLIC TAPE NAME : 97378 CONTINUATION # : 1 PREVIOUS TAPE : CO~_~T : ARCO ALASKA INC, 1Q-O8A, KUPARUK RIVER, API #50-029-21225-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/08/24 ORIGIN : FLIC REEL NA~E : 97378 CONTINUATION # : PREVIOUS REEL : CO~I~ENT : ARCO ALASKA INC, 1Q-O8A, KUPARUK RIVER, API #$0-029-21225-01
