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Home My WebLink About181-088Originated: Delivered to:19-May-24 Alaska Oil & Gas Conservation Commiss 19May24-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED 1A-03 50-029-206150-00-00 181-088 Kuparuk River WL Plug FINAL FIELD 3-Feb-24 3S-22 50-10320446-00-00 203-011 Kuparuk River WL IBC-CBL FINAL FIELD 5-Feb-24 3M-05 50-103-20875-00-00 223-126 Kuparuk River WL Isealate FINAL FIELD 10-Feb-24 2F-15 50-029-21048-00-00 183-172 Kuparuk River WL Isealate FINAL FIELD 13-Feb-24 MT7-14A 50-103-20856-01-00 223-064 Greater Mooses Tooth WL PPROF FINAL FIELD 20-Feb-24 MT7-03A 50-103-20830-00-10 223-084 Greater Mooses Tooth WL PPROF FINAL FIELD 29-Feb-24 3G-27 50-103-20801-00-00 219-039 Kuparuk River WL TTiX IPROF FINAL FIELD 2-Apr-24 2W-17 50-029-23370-00-00 207-135 Kuparuk River WL PPROF FINAL FIELD 9-Apr-24 1E-23 50-029-20858-00-00 182-184 Kuparuk River WL IPROF FINAL FIELD 10-Apr-24 1E-01 50-029-20464-00-00 180-039 Kuparuk River WL IPROF FINAL FIELD 11-Apr-24 1D-37 50-029-22992-00-00 200-204 Kuparuk River WL PPROF FINAL FIELD 12-Apr-24 3G-09 50-103-20129-00-00 190-067 Kuparuk River WL Punch-Cut FINAL FIELD 13-Apr-24 2P-420 50-103-20391-00-00 201-182 Kuparuk River WL CIBP-Cut FINAL FIELD 15-Apr-24 CD4-536 50-103-20863-00-00 223-079 Colville River WL TTiX Sampling FINAL FIELD 18-Apr-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private Eset # T38800 T38801 T38802 T38803 T38816 T38817 T38818 T38819 T38820 T38821 T38822 T38824 T38823 T38825 1A-03 50-029-206150-00-00 181-088 Kuparuk River WL Plug FINAL FIELD 3-Feb-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.05.20 12:41:13 -08'00' 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: Pull/Replace Sel Comp 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 8880'feet 8034'feet true vertical 7059' feet 8270', 8314'feet Effective Depth measured 8006'feet 7369', 7489', 7633', 7908', 8016' feet true vertical 6319'feet 5810', 6019', 6019', 6238', 6327' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" 3-1/2" L-80 L-80 7434' 7597' 5861' 5991' Packers and SSSV (type, measured and true vertical depth)7369' 7489' 7633' 7908' 8016' 5810' 6019' 6019' 6238' 6327' 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: Kuparuk Oil Pool 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: 2953' 2684' Burst Collapse Production 2008' Casing 1987'2047' 8863' 7044' 2922' 80'Conductor Surface Tie-Back 16" 10-3/4" 50' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 181-088 50-029-20615-00-00 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: ADL0025647 Kuparuk River Field/ Kuparuk Oil Pool KRU 1A-03 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) 390 Gas-Mcf MD 1200 Size 80' 5500 1150415 350 2504850 255 323-627 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 380 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A SLB Blue Pack Baker FHL Retrievable Baker FHL Baker FHL Baker FB-1 w/seal bore ext SSSV: N/A Adam Klem adam.klem@conocophillips.com (907) 263-4529Staff RWO/CTD Engineer 7820-7888', 7920-7922', 7948-7972', 8108-8110', 8166-8172', 8178-8214' 6168-6222', 6248-6250', 6271-6291', 6402-6404', 6451-6456', 6461-6491' 8824' 7" Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 8:11 am, Mar 05, 2024 Adam Klem Digitally signed by Adam Klem Date: 2024.03.04 13:54:47 -09'00' RBDMS JSB 031324 DSR-3/5/24 Page 1/18 1A-03 Report Printed: 3/4/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/16/2024 08:00 1/16/2024 09:30 1.50 MIRU, MOVE MOB P PJSM - pull rig off well, pick up matting boards, herculite, hang DSA's in cellar and clean up around well 2A-24 0.0 0.0 1/16/2024 09:30 1/16/2024 12:45 3.25 MIRU, MOVE MOB P Move rig from 2A to CPF 2 0.0 0.0 1/16/2024 12:45 1/16/2024 14:30 1.75 MIRU, MOVE MOB P Stop at CPF 2, inspect road make sure snow banks are cleared from road for rig to travel on 0.0 0.0 1/16/2024 14:30 1/16/2024 15:30 1.00 MIRU, MOVE MOB P Move from CPF 2 to the 2C/D access road 0.0 0.0 1/16/2024 15:30 1/16/2024 19:30 4.00 MIRU, MOVE MOB P Stop at 2 C/D access road for crew change out on the CPF 2 side. 0.0 0.0 1/16/2024 19:30 1/17/2024 00:00 4.50 MIRU, MOVE MOB P Cont. rig move from 2 C/D access road to 1G/1R access road. Phase 1 Conditions. 0.0 0.0 1/17/2024 00:00 1/17/2024 03:00 3.00 MIRU, MOVE MOB P Cont. rig move to 1G/R access road. Stop to allow trucks around. Cont. move to 1A Pad. Arrive on pad @ 03:00 0.0 0.0 1/17/2024 03:00 1/17/2024 05:00 2.00 MIRU, MOVE MOB P Prep pad for rig. Clear snow. Hang tree in cellar. Stage wellhead equipment behind well. Clear snow from T-Mats and cellar area. 0.0 0.0 1/17/2024 05:00 1/17/2024 06:00 1.00 MIRU, MOVE MOB P Spot rig on rig mats, line up with 1A-03 well 0.0 0.0 1/17/2024 06:00 1/17/2024 06:30 0.50 MIRU, MOVE SFTY P Crew change, PJSM with all hands on pulling and spotting rig over well 0.0 0.0 1/17/2024 06:30 1/17/2024 08:00 1.50 MIRU, MOVE MOB P Spot rig over 1A-03 well 0.0 0.0 1/17/2024 08:00 1/17/2024 10:30 2.50 MIRU, MOVE RURD P Spot support equipment, build cellar containment, spot returns tanks, spot cuttings tank, complete rig acceptance checklist Accept rig @ 10:30 HRS 0.0 0.0 1/17/2024 10:30 1/17/2024 15:30 5.00 MIRU, WELCTL RURD P Load 8.6 PPG Seawater into Pits. Build 40 Bbls deep clean pill, continue to rig up hard line and hook up circulating lines for well kill, R/U circ manifold for well kill ops on rig floor Obtain RKB's ULDS = 27.47', MLDS = 29.34', LLDS = 31.50', Ground level = 30.62' 0.0 0.0 1/17/2024 15:30 1/17/2024 20:00 4.50 MIRU, WELCTL MPSP P Mobilize lubricator to pull ISA- BPV Pull ISA-BPV, Clear snow from beaver slide. R/D and L/D lubricator. Initial Pressures: T / IA / OA = 250 / 120 / 0 psi. 0.0 0.0 1/17/2024 20:00 1/17/2024 21:30 1.50 MIRU, WELCTL PRTS P PJSM with all hands for well kill operation. Blow air through return lines to confirm clear. Pressure test circ manifold & tiger tank lines T/2500 PSI, Small drip from hardline connection. B/D lines. Tighten up connection. Re- PT to 2,500 psi. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 2/4/2024 Page 2/18 1A-03 Report Printed: 3/4/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/17/2024 21:30 1/18/2024 00:00 2.50 MIRU, WELCTL KLWL P Bleed free gas off of TBG down to 30 psi. Bleed free gas off of IA down to 30 psi. OA = 0 psi. Pump 32 BBLS 8.6 PPG hot seawater deep clean pill. Circulate 408 BBLS 8.6 PPG SW down TBG @ 5 BPM and 900 PSI. Measured 8.54 PPG return density. Clean seawater. Total BBLS pumped = 440 bbls. Strapped 475 BBLS returns. Approx. 17 bbls of ice in bottom of each tank. Bleed 200 psi trapped pressure through choke. Tubing and IA at 0 psi. 0.0 0.0 1/18/2024 00:00 1/18/2024 01:00 1.00 MIRU, WELCTL KLWL P Started to load 3 1/2" DP into ODS pipe shed.. Blowdown Tubing and IA lines to tanks. RU monitoring gauges on Tubing and IA. Bleed off Tubing and IA to 0 psi. OA reading 25 psi. Bleed OA gas to bleed trailer. 0.0 0.0 1/18/2024 01:00 1/18/2024 01:30 0.50 MIRU, WELCTL OWFF P OWFF for 30-minutes. No Flow. 0.0 0.0 1/18/2024 01:30 1/18/2024 01:45 0.25 MIRU, WELCTL RURD P R/D Tubing Hose. Lift Tree cap off. RU T-Bar for setting BPV. 0.0 0.0 1/18/2024 01:45 1/18/2024 02:00 0.25 MIRU, WELCTL MPSP P Set ISA BPV. 0.0 0.0 1/18/2024 02:00 1/18/2024 02:30 0.50 MIRU, WELCTL PRTS P RU PT equipment and IA sensator. Pressure test BPV from below to 1,000 psi for 10-min. Passed. 0.0 0.0 1/18/2024 02:30 1/18/2024 02:45 0.25 MIRU, WELCTL RURD P Blowdown lines. RD pressure testing equipment. 0.0 0.0 1/18/2024 02:45 1/18/2024 05:30 2.75 MIRU, WHDBOP NUND P N/D Tree. Inspect hanger neck threads. Kick old tree out of cellar. Function LDS's. Install slip on blanking plug. Screw into test joint. Use TD to push slip on plug over hanger neck. 0.0 0.0 1/18/2024 05:30 1/18/2024 08:00 2.50 MIRU, WHDBOP NUND P N/U 7 1/16" x 11" 5K DSA on tubing head 0.0 0.0 1/18/2024 08:00 1/18/2024 10:30 2.50 MIRU, WHDBOP NUND P N/U BOP, hook up lines, install riser Obtain RKB's on rams and bag 0.0 0.0 1/18/2024 10:30 1/18/2024 12:00 1.50 MIRU, WHDBOP RURD P Grease kill/choke manuals/HCR valves, grease choke manifold R/U testing equipment, fill stack with water, purge air out of system Attempt to get shell test, LPR door seal leaking, replace seal, obtain good shell test 0.0 0.0 1/18/2024 12:00 1/18/2024 16:00 4.00 MIRU, WHDBOP BOPE P Start weekly BOP test. Test BOPE at 250/3500 PSI for 5 Min each. Test #1 - Test Blind Rams, MM kill valve, Choke manifold #4, #11, and #12, 3 1/2" IF Dart valve, TD IBOP, and Test Spool Valve #1. Test #2 - Blinds, Kill HCR, Choke manifold valves #3, #7, #9, #10, 3 1/2" IF TIW valve, TD manual, Test Spool Valve #2. AOGCC Kam StJohn waived witness 0.0 0.0 1/18/2024 16:00 1/18/2024 16:15 0.25 MIRU, WHDBOP BOPE P Choke Valve #9 failed. Greased and re- tested. Passed. 0.0 0.0 1/18/2024 16:15 1/18/2024 18:00 1.75 MIRU, WHDBOP BOPE P Cont. BOP tests. Test #3 - Blind Rams, Kill Manual, Choke Manifold #2, #5, and #8. PU 7" Test Joint. RU test hose to test spool. Test #4 - LPR and 3 1/2" EUE TIW valve. AOGCC Kam StJohn waived witness 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 2/4/2024 Page 3/18 1A-03 Report Printed: 3/4/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/18/2024 18:00 1/18/2024 18:30 0.50 MIRU, WHDBOP BOPE P 7" LPR's failed. Re-test twice. Still failing. Continue w/ remaining BOP tests. 0.0 0.0 1/18/2024 18:30 1/18/2024 22:00 3.50 MIRU, WHDBOP BOPE P Cont BOP testing. Test #5 - Annular W/ 3 1/2" test joint, Choke valves # 1,2,5,6, and 3 1/2" EUE FOSV. Close manual choke and kill valves. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure = 2,950 PSI. After closure = 1650 PSI, 200 PSI attained = 19 sec, full recovery attained = 124 sec. UVBR's= 5 sec, LVBR’s= 5 sec. Annular= 18 sec. Simulated blinds = 4.5 sec. HCR choke & kill = 1 sec each. 4 back up nitrogen bottles average = 2081 PSI. Test gas detectors, PVT and flow show. Pull 7" test joint. PU 3 1/2" TJ. Test #6 - UPR, Kill Manual, Choke #13. Test #7 - UPR, Kill Manual, Choke HCR. AOGCC Kam StJohn waived witness 0.0 0.0 1/18/2024 22:00 1/18/2024 23:00 1.00 MIRU, WHDBOP BOPE T Test #8 - Annular W/ 3 1/2" test joint, Kill Manual, Choke manual. Test #9 - Annular, Kill Manual, Choke, Super Choke, Press up to 2,000 psi. Bleed to 1,000 psi through manual choke. Bleed to 0 psi through super choke. Drain Stack. PJSM. C/O of 7" Fixed LPR packing elements for re-test. Note: Past 10 hr BOP test time per contract. AOGCC Kam StJohn waived witness 0.0 0.0 1/18/2024 23:00 1/19/2024 00:00 1.00 MIRU, WHDBOP RURD T Drain stack, pull LPR redress with new rubbers 0.0 0.0 1/19/2024 00:00 1/19/2024 01:30 1.50 MIRU, WHDBOP RURD T Cont. to C/O 7" fixed LPR rubbers. reinstall rams and close doors 0.0 0.0 1/19/2024 01:30 1/19/2024 03:00 1.50 MIRU, WHDBOP RURD T RU testing equipment and 7" test joint. Fill stack. Purge air from system. Test #10 - Re-test LPR's. Still failing. 0.0 0.0 1/19/2024 03:00 1/19/2024 05:00 2.00 MIRU, WHDBOP RURD T L/D 7" donut test JT, open ram doors inspect 7" packer elements, look good Inspect test joint, Appears to be slightly egged Sent for 7" test JT from Nabors 7ES 0.0 0.0 1/19/2024 05:00 1/19/2024 06:30 1.50 MIRU, WHDBOP RURD T 7" test JT from 7ES on location Load in pipe shed, P/U steam off box and pin ends M/U X/over stack F/4 1/2" IF T/4" L/H Acme, realize X/over stack up to tall to be able to test 7" LPR. 0.0 0.0 1/19/2024 06:30 1/19/2024 08:00 1.50 MIRU, WHDBOP RURD T Discuss options for testing 7" LPR Attempt to locate X/overs for testing LPR W/ blanking plug P/U 7" donut test joint and inspect and caliper 0.0 0.0 1/19/2024 08:00 1/19/2024 09:00 1.00 MIRU, WHDBOP BOPE T Install 7" test JT to attempt to test again, leak past 0.0 0.0 1/19/2024 09:00 1/19/2024 09:30 0.50 MIRU, WHDBOP RURD T L/D 7" test joint, discuss path forward options for testing LPR 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 2/4/2024 Page 4/18 1A-03 Report Printed: 3/4/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/19/2024 09:30 1/19/2024 10:30 1.00 MIRU, WHDBOP RURD P PJSM, Spot 11" spacer spool behind rig Decide to pull 3 1/2" TBG due to the freeze point of seawater and not being able to bull head down IA 0.0 0.0 1/19/2024 10:30 1/19/2024 11:30 1.00 MIRU, WHDBOP MPSP P PJSM, pull slip over blanking plug and ISA- BPV 0.0 0.0 1/19/2024 11:30 1/19/2024 12:00 0.50 COMPZN, RPCOMP RURD P R/U to pull 3 1/2" TBG, install mouse hole, prep pipe shed for laying down 0.0 0.0 1/19/2024 12:00 1/19/2024 12:45 0.75 COMPZN, RPCOMP THGR P PJSM, M/U landing joint to hanger, screw into with top drive, set DN 10K , BOLDS 0.0 0.0 1/19/2024 12:45 1/19/2024 13:15 0.50 COMPZN, RPCOMP PULL P Pick up hanger off seat at 115K Pick up to 128K on hook, slack back off to 50K, repeat 4 times Seals not free from SBE , consult town 0.0 0.0 1/19/2024 13:15 1/19/2024 15:30 2.25 COMPZN, RPCOMP WAIT P Mobilize yellow jacket Eline to rig with Welltec cutter Install 3 1/2" EUE FOSV, pick up and park pie with 128K on hook no movement, fill hole and monitor well on TT 0.0 0.0 1/19/2024 15:30 1/19/2024 16:00 0.50 COMPZN, RPCOMP ELNE P Discuss job with yellow jacket, and CPAI Eline supervisor Spot unit up on ODS side of rig Set TBG in slips at 100K = 10K over calculated up weight 0.0 0.0 1/19/2024 16:00 1/19/2024 20:00 4.00 COMPZN, RPCOMP ELNE P PJSM, R/U Eline on rig floor. 16:30 WellTec on location. At 17:45 RIH w/ Welltec cutter. RIH to Seal Assembly. Pull tie in pass. Tie into GLM @ 7,402'. CCL to Cutter = 18'. CCL to Anchor = 8'. Shift depth 2' up to avoid setting anchors across GLM pup joint. Pull cutting pass. Park CCL @ 7,411'. Cut depth = 7,411' + 18' = 7,429'. Time to cut approx. 5 minutes. Release Anchors. POOH w/ E-line Welltec Cutter. L/D E-line tools. E-line on standby until pull hanger to rig floor. 0.0 0.0 1/19/2024 20:00 1/19/2024 20:30 0.50 COMPZN, RPCOMP PULL P Pull hanger to rig floor @ 95K. Release and R/D E-line. 7,459.0 7,431.0 1/19/2024 20:30 1/19/2024 20:45 0.25 COMPZN, RPCOMP PULD P L/D Landing Joint and Hanger w/ pup. C/O eckel dies to 3.70" to bite 3.75" OD Hanger pup joint. 7,431.0 7,431.0 1/19/2024 20:45 1/19/2024 21:00 0.25 COMPZN, RPCOMP RURD P RU head pin and circ hose. 7,431.0 7,431.0 1/19/2024 21:00 1/19/2024 22:00 1.00 COMPZN, RPCOMP CIRC P Circ BU. At BU fluid returns were dirty (diesel). Continued circulating STS (283 bbls of 8.6# Seawater) until fluid cleaned up. 4 BPM @ 310 psi. 7,431.0 7,431.0 1/19/2024 22:00 1/19/2024 22:30 0.50 COMPZN, RPCOMP OWFF P OWFF for 30-min. No Flow 7,431.0 7,431.0 1/19/2024 22:30 1/20/2024 00:00 1.50 COMPZN, RPCOMP PULL P Pull 3 1/2" Completions from 7,431' to midnight depth of 7,149'. PUW = 87K. 7,431.0 7,149.0 1/20/2024 00:00 1/20/2024 07:30 7.50 COMPZN, RPCOMP PULL P Cont. to pull 3 1/2" Completions from 7,149' to surface. At 4,466' @ 02:30. PUW = 62K. Crew C/O @ 3:00. Cont. pulling 3 1/2" Completions. Cut JT = 7.84' 7,149.0 0.0 1/20/2024 07:30 1/20/2024 08:45 1.25 COMPZN, RPCOMP RURD P Clean and clear rig floor. Set W/R 0.0 0.0 1/20/2024 08:45 1/20/2024 09:45 1.00 COMPZN, RPCOMP ELNE P RU YJ E-line, RIH and perform CBL from 3,000' to surface, R/D Eline, Review log data, Determine TOC. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 2/4/2024 Page 5/18 1A-03 Report Printed: 3/4/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/20/2024 09:45 1/20/2024 12:00 2.25 COMPZN, RPCOMP ELOG P RIH and perform CBL from 3,000' to surface, TOC @ 2,172' 0.0 0.0 1/20/2024 12:00 1/20/2024 12:45 0.75 COMPZN, RPCOMP ELNE P R/D Eline and L/D tools 0.0 0.0 1/20/2024 12:45 1/20/2024 13:15 0.50 COMPZN, RPCOMP RURD P Pull W/R 0.0 0.0 1/20/2024 13:15 1/20/2024 14:30 1.25 COMPZN, RPCOMP RURD P Set test plug, make up X/over on top and bottom of 7" test JT R/U testing equipment, fill stack and purge air from BOP's 0.0 0.0 1/20/2024 14:30 1/20/2024 18:30 4.00 COMPZN, RPCOMP RURD T Trouble shoot 7" rams, check X/over stack up height - good, measure ram pistons to make sure going all the way in, open ram doors inspect ram/body cavities find cement on BOP ram body, chip out cement and change out packer elements 0.0 0.0 1/20/2024 18:30 1/20/2024 19:00 0.50 COMPZN, RPCOMP RURD T Fill stack and test JT with water, purge air out of system. 0.0 0.0 1/20/2024 19:00 1/20/2024 19:30 0.50 COMPZN, RPCOMP BOPE T Test 7" LPR T/250/3500 PSI F/5 min. Failed. 0.0 0.0 1/20/2024 19:30 1/20/2024 21:45 2.25 COMPZN, RPCOMP RURD T B/D lines, R/D test equipment, Drain Stack. Troubleshoot 7" rams. Pull rams and inspect. Inspect and clean out cavities. Found a set of 4 1/2" x 7" VBR's. Redress and Install VBR'sl. Called YJ and Nabors. Borrowed a set of Nabors 7" ram blocks in case Nordic VBR's fail to test. 0.0 0.0 1/20/2024 21:45 1/20/2024 22:00 0.25 COMPZN, RPCOMP RURD T Fill stack and 7" TJ with water, purge air out of system. 0.0 0.0 1/20/2024 22:00 1/20/2024 22:15 0.25 COMPZN, RPCOMP BOPE T Test 4.5" x 7" LVBR T/250/3500 PSI F/5 min. Failed. One side of VBR's not fully closing. 0.0 0.0 1/20/2024 22:15 1/20/2024 23:30 1.25 COMPZN, RPCOMP RURD T B/D lines, R/D test equipment, Drain Stack. Troubleshoot 4.5" x 7" VBRs. Pull ram blocks. Inspect. Clean out cavities. 0.0 0.0 1/20/2024 23:30 1/21/2024 00:00 0.50 COMPZN, RPCOMP RURD T Cleanup, grease, and Install new 7" Fixed rams blocks borrowed from Nabors. 0.0 0.0 1/21/2024 00:00 1/21/2024 00:30 0.50 COMPZN, RPCOMP RURD T R/U test equipment. Fill stack and 7" TJ with water, purge air out of system. 0.0 0.0 1/21/2024 00:30 1/21/2024 01:00 0.50 COMPZN, RPCOMP BOPE T Re-test 7" LPR (set borrowed from Nabors) T/250/3500 PSI F/5 min. Pass. 0.0 0.0 1/21/2024 01:00 1/21/2024 03:00 2.00 COMPZN, RPCOMP RURD P B/D lines, R/D test equipment, Drain Stack. Pull test plug, break off X/overs from 7" test JT, set W/R. Kick out 7ES 7" TJ and borrowed XO's. Prep rig floor to run 3 1/2" DP. PJSM for BHA M/U. 0.0 0.0 1/21/2024 03:00 1/21/2024 03:30 0.50 COMPZN, RPCOMP BHAH P M/U BHA #1 (Yellow Jacket 7" AS RBP). 0.0 16.8 1/21/2024 03:30 1/21/2024 07:45 4.25 COMPZN, RPCOMP TRIP P TIH w/ BHA #1 T/2,366' 68K UP 67K DN 16.8 2,366.0 1/21/2024 07:45 1/21/2024 08:30 0.75 COMPZN, RPCOMP MPSP P Make up top drive, slack off to 2,375', pick up and put 1/2 turn to right, pick up to 2,373' to set RBP P/U pull T/88K on hook = 20K over, slack off T/60K = 7K DN, COE @ 2,370'' PU off RBP to confirm released. POOH 2 singles and one stand T/2,243' 2,366.0 2,243.0 Rig: NORDIC 3 RIG RELEASE DATE 2/4/2024 Page 6/18 1A-03 Report Printed: 3/4/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/21/2024 08:30 1/21/2024 09:30 1.00 COMPZN, RPCOMP RURD P PJSM, R/U testing equipment, flood lines, purge air out Tighten up gland nuts on LDS 2,243.0 2,243.0 1/21/2024 09:30 1/21/2024 10:00 0.50 COMPZN, RPCOMP MPSP P Test 7" RBP to 1,000 PSI F/10 Min Charted. Initial = 0 PSI 15-min = 1180 PSI, OA Initial = 0 PSI, 15 Min = 0 PSI Pump a total of .6 BBLS Bleed back .6 BBLS 2,243.0 2,243.0 1/21/2024 10:00 1/21/2024 11:00 1.00 COMPZN, RPCOMP RURD P Check for pressure, Open rams, blow down and rig down lines and testing equipment 2,243.0 2,243.0 1/21/2024 11:00 1/21/2024 11:30 0.50 COMPZN, RPCOMP RURD P R/U sand hopper and circ. hose. 2,243.0 2,243.0 1/21/2024 11:30 1/21/2024 18:00 6.50 COMPZN, RPCOMP OTHR P Dump 25 sacks of all purpose sand down on top of RBP Note: Sand was wet and took longer to dump to avoid plugging off drill string 2,243.0 2,243.0 1/21/2024 18:00 1/21/2024 20:00 2.00 COMPZN, RPCOMP WAIT P Wait 2 hours for sand to settle. While waiting, load 7" space out pups and process. 2,243.0 2,243.0 1/21/2024 20:00 1/21/2024 20:15 0.25 COMPZN, RPCOMP TRIP P TIH and lightly tag TOS @ 2,296' (2K down). 2,243.0 2,296.0 1/21/2024 20:15 1/21/2024 20:30 0.25 COMPZN, RPCOMP CIRC P PUH. Stand back 2 stands of DP. Pump 10 bbls through DP to ensure clear. 2,296.0 2,109.0 1/21/2024 20:30 1/21/2024 22:00 1.50 COMPZN, RPCOMP TRIP P TOOH standing back 3 1/2" DP. 2,109.0 8.8 1/21/2024 22:00 1/21/2024 22:15 0.25 COMPZN, RPCOMP BHAH P L/D XO's and BHA #1 Retrieving Head. Pull Wear Ring. 8.8 0.0 1/21/2024 22:15 1/21/2024 22:30 0.25 COMPZN, RPCOMP RURD P Ensure 7" Casing and OA are bled to 0 psi. 0.0 0.0 1/21/2024 22:30 1/21/2024 23:00 0.50 COMPZN, RPCOMP OWFF P OWFF for 30-min. 0.0 0.0 1/21/2024 23:00 1/22/2024 00:00 1.00 PROD1, CSGRCY NUND P Blowdown lines. N/D BOPE from Tubing Head. N/D 11" 5K x 7 1 1/16" spool from bottom of BOP stack. 0.0 0.0 1/22/2024 00:00 1/22/2024 05:00 5.00 PROD1, CSGRCY NUND P Cont. to N/D BOPE. FMC and Hydratite on location. N/D Tubing Head per Hydratite procedure. Starting gap = 1/4". Ending gap = 1.75". Total Growth = 1.5". Call Town Engineer to discuss casing growth. Confirmed we do not need to spear and pull tension. FMC function tested casing head LDS's 0.0 0.0 1/22/2024 05:00 1/22/2024 06:00 1.00 PROD1, CSGRCY NUND P N/U 11" 3K x 11" 5K DSA. N/U 11" 5K x 11" 5K spacer spool 0.0 0.0 1/22/2024 06:00 1/22/2024 07:00 1.00 PROD1, CSGRCY SFTY P PJSM, discuss job and hazards with all hands, pick up cellar area 0.0 0.0 1/22/2024 07:00 1/22/2024 10:00 3.00 PROD1, CSGRCY NUND P Continue to N/U 11" 3K x 11" 5K DSA. N/U 11" 5K x 11" 5K spacer spool 0.0 0.0 1/22/2024 10:00 1/22/2024 14:15 4.25 PROD1, CSGRCY NUND P N/U BOPE, install risrer, mouse hole and hook up lines Install flange and R/U on OA outlet valve for circulating and testing BOP breaks Get new RKB's 0.0 0.0 1/22/2024 14:15 1/22/2024 16:00 1.75 PROD1, CSGRCY MPSP P Flood lines and purge air from system Close blind rams, test BOP breaks T/3000 PSI against RBP F/5min Good test on breaks Flange on kill line swivel leak, tighten up and retest, good test 0.0 0.0 1/22/2024 16:00 1/22/2024 16:30 0.50 PROD1, CSGRCY BHAH P MU BHA #2 (YJ MSC) 0.0 10.0 Rig: NORDIC 3 RIG RELEASE DATE 2/4/2024 Page 7/18 1A-03 Report Printed: 3/4/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/22/2024 16:30 1/22/2024 19:00 2.50 PROD1, CSGRCY TRIP P RIH on DP T/1,956' 65K UP 65K DN 10.0 1,956.0 1/22/2024 19:00 1/22/2024 20:00 1.00 PROD1, CSGRCY CPBO P Locate 7" CSG collars @ 1.8 BPM 150 PSI, locate casing collars @ 1,986.97', 2,034.14' P/U to cut depth @ 2,044' 1,956.0 2,044.0 1/22/2024 20:00 1/22/2024 20:45 0.75 PROD1, CSGRCY CPBO P Obtain perametrs 1.8 BPM 150 PSI Free TQ 70 RPM 5.8K TQ 65K Rot WT Cut CSG @ 70 RPM, 3 BPM 385 PSI, stage up to 4.7 BPM 943 PSI TQ @ 6.2K - 6.7K TQ fall off to 5.6K, turn pumps up to 5.2 BPM 1151 PSI no increase in TQ Cut 7" casing @ 2,044' OA Pre-cut: 0 PSI OA after cut = 0 PSI 2,044.0 2,044.0 1/22/2024 20:45 1/22/2024 21:15 0.50 PROD1, CSGRCY CPBO P Turn pumps down to 2.5 BPM 295 PSI, turn off rotary, P/U see no over pull, S/O set DN 1-2K Turn off pump, P/U see no over pull, pump at 1.8 BPM 150 PSI, S/O set DN 2K on cut 2,044.0 2,044.0 1/22/2024 21:15 1/22/2024 21:30 0.25 PROD1, CSGRCY DISP P Pick up space out for circulating OA Attempt to circulate out cut up OA, pressure up to 700 PSI , bleed down to 530 PSI in 6 min with no returns to tiger tank Shut in line to tank and open up to gauge, pressure up to 700 PSI with no pressure gain on OA Open OA to atmosphere little gas come out 2,044.0 2,044.0 1/22/2024 21:30 1/22/2024 23:00 1.50 PROD1, CSGRCY TRIP P Blow down top drive POOH F/2,044' T/16' 2,044.0 16.0 1/22/2024 23:00 1/22/2024 23:30 0.50 PROD1, CSGRCY BHAH P L/D BHA #2 (MSC). 16.0 0.0 1/22/2024 23:30 1/23/2024 00:00 0.50 PROD1, CSGRCY BHAH P M/U BHA #3 (7" Spear w/ Pack-off). 0.0 13.0 1/23/2024 00:00 1/23/2024 00:15 0.25 PROD1, CSGRCY TRIP P TIH to top of 7" casing in casing hanger @ 29.5'. 13.0 29.5 1/23/2024 00:15 1/23/2024 00:30 0.25 PROD1, CSGRCY FISH P Engage 7" casing w/ spear. PU to 90K (7" casing weight to 2,000' + blocks). 29.5 29.5 1/23/2024 00:30 1/23/2024 00:45 0.25 PROD1, CSGRCY CIRC P Re-attempt circulate to OA. Slowly pressure up to 1,000 psi. Unable to establish ciirculation. Slow bleed off. 29.5 29.5 1/23/2024 00:45 1/23/2024 01:00 0.25 PROD1, CSGRCY FISH P PU to 125K. Pipe stretched/moved uphole approx. 6". 29.5 28.5 1/23/2024 01:00 1/23/2024 01:15 0.25 PROD1, CSGRCY CIRC P Slowly pressure up to 1,500 psi. Unable to establish circulation out OA. Slow bleed off around spear pack-off. Bleed off. Blow down lines out to open top tank. Weather went Phase 2 conditions. 28.5 28.5 1/23/2024 01:15 1/23/2024 01:30 0.25 PROD1, CSGRCY FISH P Slack-off and disengage spear from 7" casing. PUH to surface. 28.5 13.0 1/23/2024 01:30 1/23/2024 01:45 0.25 PROD1, CSGRCY BHAH P L/D BHA #3 (spear). Call Town Engineeer to discuss new plan forward. CBL shows possible cement stringers from approx. 1,710' up to 1,562'. Decide to make 2nd cut in 7" casing @ 1,523'. 13.0 0.0 1/23/2024 01:45 1/23/2024 02:00 0.25 PROD1, CSGRCY BHAH P M/U BHA #4 (7" Casing Cutter). 0.0 4.7 Rig: NORDIC 3 RIG RELEASE DATE 2/4/2024 Page 8/18 1A-03 Report Printed: 3/4/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/23/2024 02:00 1/23/2024 08:30 6.50 PROD1, CSGRCY WAIT P Kuparuk Security called Phase 3 conditions. Hang off BHA at surface. Stab Floor valve. Wait until conditions improve to Phase 2 before continuing TIH w/ cutter. Security called Phase 2 on CPF-1 side @ 08:30. Continue operations. 4.7 4.7 1/23/2024 08:30 1/23/2024 11:00 2.50 PROD1, CSGRCY TRIP P TIH w/ BHA #4 to 1,500'. PUW = 61K SOW = 61K. Bring pumps on @ 1 BPM and 150 psi. Locate collar @ 1,516' on trip in hole. SD Pumps. Repeat collar locate. Set 3K down. Good confirmation. TIH to cut depth of 1,526'. 1,500.0 1,526.0 1/23/2024 11:00 1/23/2024 11:30 0.50 PROD1, CSGRCY CPBO P Obtain parameters 1 BPM @ 143 PSI. Free Torque = 5.2K. Rotation = 70 RPM. Rotating weight = 62K. Start casing cut @ 1.7 BPM and 300 psi. Torque = 5.4K. Increase pump rate to 2.25 BPM and 544 psi. Torque = 6.5K. Increase to 3 BPM and 938 psi. Torque 5.5K. Increase to 4 BPM @ 1418 psi. Torque 5K. OA pressure = 150 psi. Established IAxOA communication. Torque smoothed out. Indication of good cut. SD rotary. SD pumps. Cut 7" casing @ 1,526' OA Pre-cut: 0 PSI OA after cut = 150 PSI 1,526.0 1,526.0 1/23/2024 11:30 1/23/2024 15:30 4.00 PROD1, CSGRCY CIRC P Pick up space out for circulating OA. Line up to open top tank. Established returns @ 3 BPM and 1000 psi. OA = 190 psi. Circ 100 bbls down 3 1/2" DP out OA to open top tank. SD pumps to reconfigure circ path. Blowdown lines. Line up to pump down 7" casing, taking OA returns to open top. Pump 125 bbls 8.6# SW down 7" out OA to tanks to flush Arctic pack from 7" @ 5 BPM / 230 psi. SD Pumps. Blowdown. 1,526.0 1,521.0 1/23/2024 15:30 1/23/2024 22:00 6.50 PROD1, CSGRCY CIRC P R/U LRS to cement line. Spot in hot water truck. PT LRS lines to 3,500 psi. Line up to pump down the 7" casing taking OA returns to cuttings tank. Pump 100 bbls of 140 deg hot fiesel @ 1.8 BPM and 100 psi (heating on the fly) down 7" casing taking OA returns. Pump 150 bbls hot 140 deg FW @ 3.5 BPM and 150 psi. Chase with 5 bbls diesel. SD Pumps. Suck back lines. R/D LRS. Turn over to rig pumps. Pump 30 bbl hi-vis pill. Chase with 180 bbls 8.6# SW @ 6 BPM and 260 psi pumping down DP taking OA returns to open top tank. SD Pumps. Blowdown lines. Wait on OA to equalize 1,521.0 1,521.0 1/23/2024 22:00 1/23/2024 23:00 1.00 PROD1, CSGRCY TRIP P TOOH w/ BHA #4 (MSC).PUW=54K 1,521.0 4.7 1/23/2024 23:00 1/23/2024 23:30 0.50 PROD1, CSGRCY BHAH P L/D BHA #4 (MSC) Inspect cutters. See expected wear pattern on arms 4.7 0.0 1/23/2024 23:30 1/24/2024 00:00 0.50 PROD1, CSGRCY OWFF P OWFF for 30-min.no pass 0.0 0.0 1/24/2024 00:00 1/24/2024 01:30 1.50 PROD1, CSGRCY CIRC P Pump BU @ 5 BPM 162 PSI taking returns from OA, Blow down circ lines 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 2/4/2024 Page 9/18 1A-03 Report Printed: 3/4/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/24/2024 01:30 1/24/2024 02:00 0.50 PROD1, CSGRCY OWFF P OWFF. Approx 18 gal seawater out then stopped flowing. 0.0 0.0 1/24/2024 02:00 1/24/2024 02:30 0.50 PROD1, CSGRCY NUND P Prep to lift BOPE. Deflate riser boot, Drain trip tank, OA started flowing again 8.5 PPG 0.0 0.0 1/24/2024 02:30 1/24/2024 03:00 0.50 PROD1, CSGRCY CIRC P Pump BU 5 BPM @ 215 PSI 0.0 0.0 1/24/2024 03:00 1/24/2024 03:15 0.25 PROD1, CSGRCY OWFF P Wait for OA to stop moving fluid. start flow check. 0.0 0.0 1/24/2024 03:15 1/24/2024 03:45 0.50 PROD1, CSGRCY OWFF P OWFF for 30-min. No Flow. 0.0 0.0 1/24/2024 03:45 1/24/2024 06:45 3.00 PROD1, CSGRCY NUND P Continue ND BOP Stack. BOLDS. Prep cellar to PU on 7". 0.0 0.0 1/24/2024 06:45 1/24/2024 08:30 1.75 PROD1, CSGRCY PULL P TIH to casing head and engage 7" casing. PU on 7" until collar. PU to pull pack off and slips. PUW = 73K to move pipe. 0.0 1,526.0 1/24/2024 08:30 1/24/2024 09:00 0.50 PROD1, CSGRCY NUND P NU BOP to 11" 3K casing head. 1,526.0 1,526.0 1/24/2024 09:00 1/24/2024 10:30 1.50 PROD1, CSGRCY RURD P Prep GBR 7" pipe handling equipment on rig floor. 1,526.0 1,526.0 1/24/2024 10:30 1/24/2024 16:30 6.00 PROD1, CSGRCY PULL P Pull 7" casing to rig floor. L/D 7" spear. Pull 7" Casing from 1,526' to surface. At Joint #18 found one bow missing from bowspring centralizer. L/D cut joint. Length = 10.34'. Clean casing. No indication of cement stringers or debris on backside of 7". 36 Joints + 1 cut joint pulled. 1,526.0 0.0 1/24/2024 16:30 1/24/2024 17:30 1.00 PROD1, CSGRCY MPSP P Drain stack. RU Slickline Stem and X- wing magnets to pickup any potential metal debris/bow springs from wellhead. MU Swizzle Stick and clean stack. Set 11" test plug. 0.0 0.0 1/24/2024 17:30 1/24/2024 20:30 3.00 PROD1, CSGRCY RURD P R/D Slickline magnets and grapple. C/O elevators to DP. R/U spinners, R/D GBR power tongs. C/O saver sub on top drive 0.0 1/24/2024 20:30 1/24/2024 21:00 0.50 PROD1, CSGRCY RURD P M/U wash nozzle to top drive. Flush tack. Lay down nozzle, Blow down top drive 0.0 0.0 1/24/2024 21:00 1/24/2024 23:30 2.50 PROD1, CSGRCY PRTS P Drain stack, Attempt to set test plug. Stack out 2' high. Looks like we are hitting LDS. B/O screws. Still unable to set plug. C/O FMC. Wrong test plug at rig. MOB correct plug. 0.0 0.0 1/24/2024 23:30 1/25/2024 00:00 0.50 PROD1, CSGRCY PRTS P Install test plug. PT BOP Breaks to 250/3,000 psi. Chart. 0.0 1/25/2024 00:00 1/25/2024 00:30 0.50 PROD1, CSGRCY PRTS P Get 250 / 3000PSI PT on BOPE flange breaks. 0.0 0.0 1/25/2024 00:30 1/25/2024 04:00 3.50 PROD1, CSGRCY BHAH P Drain stack, Pull test plug, M/U BHA #5. Spear, jars, intensifier, and drill collars 0.0 232.6 1/25/2024 04:00 1/25/2024 05:00 1.00 PROD1, CSGRCY TRIP P Trip w/ BHA #5 on 3 1/2" DP. PUW = 68K. SOW = 70K. 232.6 1,526.0 1/25/2024 05:00 1/25/2024 05:30 0.50 PROD1, CSGRCY FISH P Engage stub @ 1,526'. Swallow 9' of fish (3.5' to grapple). Est Fish Weight = 11K. PU to 140K (70K over string weight). Pipe moving. PU 3'. Line up to circulate. 1,526.0 1,535.0 1/25/2024 05:30 1/25/2024 06:30 1.00 PROD1, CSGRCY CIRC P Bring pumps on to attempt to circulate. Pressured up to 1,100 psi and gained circulation. Ramp rate up to 5 BPM @ 233 psi. Pump 26 bbl hi-vis pill to help lift in large 3.5" x 10 3/4" annulus. Monitor returns to identify debris/fill. 1,535.0 1,533.0 Rig: NORDIC 3 RIG RELEASE DATE 2/4/2024 Page 10/18 1A-03 Report Printed: 3/4/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/25/2024 06:30 1/25/2024 07:00 0.50 PROD1, CSGRCY OWFF P OWFF. No Flow. 1,533.0 1,533.0 1/25/2024 07:00 1/25/2024 11:00 4.00 PROD1, CSGRCY TRIP P TOOH w/ BHA #5 and 7" fish. 1,533.0 753.0 1/25/2024 11:00 1/25/2024 13:30 2.50 PROD1, CSGRCY BHAH P L/D BHA #5 (7" Spear) and 518' Fish. Cut Joint measured 10.4' long. Found contaminated cement on 7" casing. Lost 3 bows off bowspring centralizer. Likely left downhole in contaminated cement when pulled 70K over to get moving. 753.0 0.0 1/25/2024 13:30 1/25/2024 16:00 2.50 PROD1, CSGRCY CLEN P Clean and clear rig floor. Steam and clean contaminated cement from floor. R/D GBR Tongs and store in corner. Kick out junk 7" casing and centralizers. Load Yellow Jacket tools up elevator cart. Prep driller side pipe shed and start processing 3 1/2" tubing. YJ does not have XO to run RFJB 0.0 0.0 1/25/2024 16:00 1/25/2024 19:00 3.00 PROD1, CSGRCY WAIT P YJ does not have XO to run RFJB. HotShot out of deadhorse. Load BHA #7. Prep shed for 3 1/2" completion 1/25/2024 19:00 1/25/2024 20:00 1.00 PROD1, CSGRCY BHAH P MU BHA #6 (Cleanout Assembly - RCJB w/ inline magnets). 0.0 28.3 1/25/2024 20:00 1/25/2024 22:00 2.00 PROD1, CSGRCY TRIP P TIH w/ cleanout assembly. Wash from 1,526' to 7" stub @ 2,044'. 28.3 1,526.0 1/25/2024 22:00 1/26/2024 00:00 2.00 PROD1, CSGRCY CIRC P Circulate and attempt to suck up lost centralizer bow springs and any other debris around 7" stub. Circ BU's. 2,044.0 2,044.0 1/26/2024 00:00 1/26/2024 00:30 0.50 PROD1, CSGRCY OWFF P OWFF. 2,044.0 2,044.0 1/26/2024 00:30 1/26/2024 02:30 2.00 PROD1, CSGRCY TRIP P TOOH w/ BHA #6 (cleanout) 2,044.0 267.0 1/26/2024 02:30 1/26/2024 03:00 0.50 PROD1, CSGRCY BHAH P Lay down BHA #6 RFJB with magnets. Junk basket packed off w/ contaminated cement. Recovered 1/2 bow from centralizer on magnets. 267.0 0.0 1/26/2024 03:00 1/26/2024 04:00 1.00 PROD1, CSGRCY BHAH P M/U BHA #7 (8 3/4" string mills and magnets). 0.0 46.9 1/26/2024 04:00 1/26/2024 05:00 1.00 PROD1, CSGRCY TRIP P TIH and set down with lower string mill in wear ring. TOOH to confirm depth. Verify string mill is 8.75 OD. TBIH. Drift through wear ring to tight spot @ 327'. Set 5K down. Fell through. Set down at 364'. 46.9 364.0 1/26/2024 05:00 1/26/2024 07:00 2.00 PROD1, CSGRCY MILL P Kelly up. Obtain parameters. PUW = 46K. SOW = 46K. Rotating weight = 46K Free Torque @ 20 RPM = 1.6K. Pump rate = 5 BPM @ 60 psi. Work 8 3/4" string mills from 322' to 415'. Backream up through tight spots. Attempt to dry dirft. Set down 10K at 364' again. Cont. to work string mills across tight spots. Acting like a slight ledge at 364'. See 200 ft-lbs torque increase briefly then slides past. 364.0 415.0 1/26/2024 07:00 1/26/2024 09:00 2.00 PROD1, CSGRCY TRIP P Cont. TIH w/ 8 3/4" OD string mills to 2,042'. Did not see any other tight spots on TIH. 415.0 2,042.0 Rig: NORDIC 3 RIG RELEASE DATE 2/4/2024 Page 11/18 1A-03 Report Printed: 3/4/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/26/2024 09:00 1/26/2024 12:00 3.00 PROD1, CSGRCY CIRC P Pump 30 bbl hi-vis gel pill. Pump Seawater @ 12 BPM and 1,400 psi to clean up contaminated cement from top of 7" stub. Slow circ rate and build hi- vis pull. Pump 26 bbl hi-vis pill to ensure clean before TOOH. Clean fluid after 2nd sweep was circulated out. 2,042.0 2,042.0 1/26/2024 12:00 1/26/2024 12:30 0.50 PROD1, CSGRCY OWFF P SD Pumps. OWFF. 2,042.0 2,042.0 1/26/2024 12:30 1/26/2024 13:30 1.00 PROD1, CSGRCY TRIP P TOOH w/ BHA #7 to just below tight spot at 364'. 2,042.0 364.0 1/26/2024 13:30 1/26/2024 15:00 1.50 PROD1, CSGRCY MILL P Obtain parameters. Free Torque = 3.9K. Spiked up to 4.2K when back reaming. Pumping 5 BPM @ 230 psi. Rotating at 60 RPM. Work string mills across tight spot/ledge at 364'. Cleaned up ledge. Dry drift clean. 364.0 364.0 1/26/2024 15:00 1/26/2024 15:30 0.50 PROD1, CSGRCY TRIP P Blowdown Top Drive. TOOH w/ BHA #7 to surface. 364.0 46.9 1/26/2024 15:30 1/26/2024 16:00 0.50 PROD1, CSGRCY BHAH P L/D BHA #7 (8 3/4" String Mills) 46.9 0.0 1/26/2024 16:00 1/26/2024 16:30 0.50 PROD1, CSGRCY BHAH P MU BHA #8 (Dress Off Shoe). Shoe has 3.65' of swallow to clear backside of 7" for casing 3' swallow patch. 0.0 32.9 1/26/2024 16:30 1/26/2024 17:30 1.00 PROD1, CSGRCY TRIP P TIH w/ BHA #8 to 7" stub @ 2,044'. 32.9 2,044.0 1/26/2024 17:30 1/26/2024 21:30 4.00 PROD1, CSGRCY MILL P Obtain parameters. 6 BPM @ 350 PSI. 30 RPM, 3K torque Dress off 7" stub from 2,044' to 2,045'. Pump sweeps to surface, Blow down top drive 2,044.0 2,045.0 1/26/2024 21:30 1/26/2024 22:00 0.50 PROD1, CSGRCY TRIP P TOOH w/ BHA #8. 2,045.0 0.0 1/26/2024 22:00 1/26/2024 23:00 1.00 PROD1, CSGRCY BHAH P L/D BHA #8. Break down - Load out 0.0 0.0 1/26/2024 23:00 1/27/2024 00:00 1.00 PROD1, CSGRCY CLEN P Clean and clear rig floor. Drain stack 0.0 0.0 1/27/2024 00:00 1/27/2024 03:00 3.00 PROD1, CSGRCY RURD P Continue loading out YJ tools, Pull wear ring, C/O elevator to 7" side door. Rig down pipe spinners. Rig up GBR tongs. Blow through cement line 0.0 0.0 1/27/2024 03:00 1/27/2024 08:30 5.50 PROD1, CSGRCY PUTB P PJSM. Verify Jewelry and run order. Run 7" Tieback string as per Tally. 0.0 2,014.0 1/27/2024 08:30 1/27/2024 09:00 0.50 PROD1, CSGRCY HOSO P Run Joint #50. M/U Space out pups (10.09' and 5.86'). M/U last full joint (#51) of 7" HYD563 casing. PUW = 85K. SOW = 82K 2,014.0 2,014.0 1/27/2024 09:00 1/27/2024 09:30 0.50 PROD1, CSGRCY WASH P Kelly up TD. Bring pumps online at 1 BPM. Wash down over 7" stub @ 2,044'. See pressure indicator. SD Pumps. Slide to No-Go @ 2,047'. Set 40K down. PT to 1,000 psi to confirm seals holding. Bleed off. Pull 50K tension (36K blocks + 46K casing + 50K over) = 132K. Confirm good latch. Slack off. 2,014.0 2,047.0 1/27/2024 09:30 1/27/2024 11:00 1.50 PROD1, CSGRCY RURD P Back out and blowdown TD. R/U pressure testing equipment. R/U Head Pin and Sensator for PT. 2,047.0 2,047.0 1/27/2024 11:00 1/27/2024 12:00 1.00 PROD1, CSGRCY PRTS P Pressure test 7" Casing and Patch to 2,500 psi. Chart. Passed. R/D PT equipment. Screw in w/ TD. Pull to neutral wt. Pressure up to 3,300 psi to open HES cementer. Sheared open @ 3,260 psi. 2,047.0 2,047.0 Rig: NORDIC 3 RIG RELEASE DATE 2/4/2024 Page 12/18 1A-03 Report Printed: 3/4/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/27/2024 12:00 1/27/2024 13:00 1.00 PROD1, CSGRCY CIRC P Circ STS. Pump 160 bbls 8.6# SW @ 40 psi. Set casing in slips at neutral weight. Unscrew from Top Drive. Blowdown Top Drive. Kick out excess 7" casing from ODS. 2,047.0 2,047.0 1/27/2024 13:00 1/27/2024 14:00 1.00 PROD1, CSGRCY OWFF P Drain Stack. OWFF for 30-min. Roll 3 1/2" Tubing row over to ODS. Unload 7" pups and GBR equipment. Load HES Cement Head to warm up in Pipe Shed. 2,047.0 2,047.0 1/27/2024 14:00 1/27/2024 18:30 4.50 PROD1, CEMENT NUND P N/D BOP. Pull 50K tension. Set 7" emergency slips. Cut and L/D excess casing. NU BOP's. HES Cementers on location. Spot and RU cementers. 2,047.0 2,047.0 1/27/2024 18:30 1/27/2024 22:00 3.50 PROD1, CEMENT CMNT P PJSM. Blow air through all return lines out to tanks. Confirm clear flow path to open top and cuttings tank. Line up to take initial returns from the OA. Flood lines. PT Cementers to 4,000 psi. Pump 100 bbls hot FW ahead. Chase w/ 20 bbls 80 deg FW. Push 20 bbl rinsate pill and 5 gallon cement retarder into cuttings tank and open top tank. Load 30 bbl rinsate pill into trip tank. 2,047.0 2,047.0 1/27/2024 22:00 1/27/2024 22:06 0.10 PROD1, CEMENT CMNT P Cement wet @ 21:50, Pump 30 bbls 10# spacer. 2,047.0 2,047.0 1/27/2024 22:06 1/27/2024 22:42 0.60 PROD1, CEMENT CMNT P Pump 268 bbls 15.3# Cement. 4 BPM @ 463 PSI, Getting one for one down 7". Circ pressure 435 @ 80 BBls away. Turned corner 1 for 1 @ 140 BBls cement away 4 BPM @ 435 PSI 2,047.0 2,047.0 1/27/2024 22:42 1/27/2024 23:30 0.80 PROD1, CEMENT CMNT P Roll returns to cuttings box, Pump in contam pill. Blow down open top tank. Start pulling fluid off open top 2,047.0 2,047.0 1/27/2024 23:30 1/28/2024 00:00 0.50 PROD1, CEMENT CMNT P Pumped 294 BBls, Shut down. Drop closing dart, 15.4 PPG cement in returns. Pump 20 BBls freshwater 3.5 BPM @ 550 PSI 2,047.0 2,047.0 1/28/2024 00:00 1/28/2024 00:30 0.50 PROD1, CEMENT CMNT P Pump approx. 34 bbls of 8.6# SW to bump closing plug. Initial circ pressure 350 PSI with 30 PSI on OH. Final circ pressure 980 PSI with 270 PSI on OA. Pressure up per HES cementer to confirm HES cementer is closed. Bleed off to confirm cementer is closed. 2,047.0 2,047.0 1/28/2024 00:30 1/28/2024 04:00 3.50 PROD1, CEMENT RURD P Blow down all lines - Top drive. Start pulling off fluids from outside tanks. Flush stack with rinsate out test port. Clean and clear rig floor. Kickout 7" pups and GBR equipment. Prep cellar to ND stack. 2,047.0 2,047.0 1/28/2024 04:00 1/28/2024 07:00 3.00 PROD1, CEMENT WOC P WOC until 07:00 (100 psi C.S. @ 8.5 hrs after cement wet) 2,047.0 2,047.0 1/28/2024 07:00 1/28/2024 15:30 8.50 PROD1, WELLPR NUND P Drain stack. ND BOP's. Lift to allow access for 7" cutter. FMC cut 7" casing. Install casing pack-off. Unload spacer spool from cellar. Winch in new Tubing head. 2,047.0 0.0 1/28/2024 15:30 1/28/2024 22:00 6.50 PROD1, WELLPR NUND P Make final WACHs cut of 7". Pull packer to redress. Reinstall packer, Tighten LDS. Install new tubing head. Test packoff 0.0 1/28/2024 22:00 1/29/2024 00:00 2.00 PROD1, WELLPR NUND P NU new DSA. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 2/4/2024 Page 13/18 1A-03 Report Printed: 3/4/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/29/2024 00:00 1/29/2024 06:00 6.00 PROD1, WELLPR NUND P Continue to NU new DSA. NU BOP's. Open all doors on BOP clean cavities. Very little / no cement. Swap LPR's from 7" fixed to 2 7/8" x 5.5" VBR's. Reintall BOP doors. Jet stack. Drain stack. Set test plug. Process 3.5" drill pipe for clean out run. 0.0 0.0 1/29/2024 06:00 1/29/2024 08:00 2.00 PROD1, WELLPR RURD P Grease choke manifold. Grease Manual Choke and Kill HCR. Purge air from system. Perform shell test in prep for weekly BOP test. 0.0 0.0 1/29/2024 08:00 1/29/2024 18:00 10.00 PROD1, WELLPR BOPE P Initial BOPE test, Tested BOPE at 250/3500 PSI for 5 Min each, Tested annular, LVBR’s U UVBR's w/ 3 1/2" test joints. Test blinds rams. Choke valves #1 to #13, upper and lower top drive well control valves. Test 3 1/2" IF FOSV and IBOP. Test 3 ½” & 4 ½” EUE FOSV. Test 2" rig floor Demco kill valve MM #13. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=2950 PSI, after closure=1600 PSI, 200 PSI attained =18 sec, full recovery attained =116 sec. UVBR's= 5 sec, LVBR’s= 5 sec. Annular= 19 sec. Simulated blinds= 5 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average =2050 PSI. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Sully Sullivan. 0.0 0.0 1/29/2024 18:00 1/29/2024 20:30 2.50 PROD1, WELLPR BOPE T Cellar H2S sensor failed initial test. Calibrated and passed retest. CMV #10 failed initial test, functioned and greased, passed retest. 0.0 0.0 1/29/2024 20:30 1/29/2024 23:30 3.00 PROD1, WELLPR RURD P Drain stack. R/D testing equipment. L/D test joint. Pull test plug. Found larger 11" test plug was ran. Set 7" test plug. Close blinds. Test BOP break to 3,500 psi. Pull test plug. Set 6" wear ring. Prep rig floor to run 3 1/2" DP. Kick out 7" casing and GBR equipment. 0.0 0.0 1/29/2024 23:30 1/30/2024 00:00 0.50 PROD1, WELLPR RURD P Prep rig floor to run 3 1/2" DP. Kick out 7" casing and GBR equipment. 1/30/2024 00:00 1/30/2024 04:00 4.00 PROD1, WELLPR RURD P PU 3 1/2" DP singles. Build stands and rack back in derrick in prep for cement mill out 0.0 0.0 1/30/2024 04:00 1/30/2024 05:30 1.50 PROD1, WELLPR BHAH P Load up BHA #10, Prep collars 0.0 0.0 1/30/2024 05:30 1/30/2024 06:30 1.00 PROD1, WELLPR SVRG P Lubricate Rig 0.0 0.0 1/30/2024 06:30 1/30/2024 07:30 1.00 PROD1, WELLPR RGRP T Replace leaking O ring on top drive grabber accumulator 0.0 0.0 1/30/2024 07:30 1/30/2024 10:00 2.50 PROD1, WELLPR BHAH P MU BHA #10 (6 1/8" junk mill + boot baskets + magnets). 0.0 183.0 1/30/2024 10:00 1/30/2024 11:00 1.00 PROD1, WELLPR TRIP P TIH w/ junk mill to TOC estimated @ 2,000'. KU PUW=67K, SOW=67K. Work in dry. Mushy. Suspect green cement Tag TOC @ 2016'. 183.0 2,016.0 Rig: NORDIC 3 RIG RELEASE DATE 2/4/2024 Page 14/18 1A-03 Report Printed: 3/4/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/30/2024 11:00 1/30/2024 11:30 0.50 PROD1, WELLPR CIRC P PUH. to 2010'Break circulation. Work pumps up to 4 BPM @ 230 PSI, Pump BU. Getting green cement at shaker 2,016.0 2,016.0 1/30/2024 11:30 1/30/2024 15:30 4.00 PROD1, WELLPR MILL P 2010, start rotary 60 RPM 4.2K torque. Tag @ 2020 clean out green cement. Tag cement valve @ 2032. time mill @ 60 RPM, 4K WOB, 4 BPM @ 230 PSI 2,016.0 2,032.0 1/30/2024 15:30 1/30/2024 20:30 5.00 PROD1, WELLPR MILL P 2033', appears to be transitioning back to cement, 5 BBls/Min @ 300 PSI. Pump Start increasing WOB, Pump lo vis sweep. Milled through ES Cementer @ 2033'. Cont wash & ream through cement stingers @ 4 BPM, 240 PSI, 60 RPM, 4-5K Tq. Tagged hard cement @ 2202', Drill T/ 2213'. ROPE decreased dramatically. PUW-64K, SOW=64K. 2,032.0 2,213.0 1/30/2024 20:30 1/30/2024 21:00 0.50 PROD1, WELLPR CIRC P Circ 5 Bbls low vis followed by 5 Bbls vis nut plug to attempt to clean mill cutting structure. 2,208.0 2,208.0 1/30/2024 21:00 1/30/2024 21:15 0.25 PROD1, WELLPR DRLG P Cont to mill cement F/ 2213' T/ 2215'. ROP 6' / HR. Decision made to make bit trip. L/D 6 1/8" junk mill, M/U 6 1/8" roller cone bit. 2,208.0 2,215.0 1/30/2024 21:15 1/30/2024 21:30 0.25 PROD1, WELLPR CIRC P Pump BU @ 6 BPM, 410 PSI. B/D TD. 2,215.0 2,215.0 1/30/2024 21:30 1/30/2024 22:45 1.25 PROD1, WELLPR TRIP P POOH F/ 2215'' T/ 222' PUW=73K. 222.0 222.0 1/30/2024 22:45 1/30/2024 23:15 0.50 PROD1, WELLPR BHAH P L/D BHA #10 F/ 222' T/ surface. Metal shavings on magnets. Small amount of debris in boot baskets. Check junk mill in gauge, 222.0 0.0 1/30/2024 23:15 1/31/2024 00:00 0.75 PROD1, WELLPR BHAH P M/U BHA #11, 6 1/8" roller cone bit T/ 127'' 0.0 127.0 1/31/2024 00:00 1/31/2024 00:15 0.25 PROD1, WELLPR BHAH P Cont M/U BHA #11, 6 1/8" roller cone bit T/ 222', SOW=43K. 127.0 222.0 1/31/2024 00:15 1/31/2024 02:30 2.25 PROD1, WELLPR PULD P PUDP F/ 222' T/ 2202'. PUW=75K SOW=73KI. K/U wash T/ 2215'. 222.0 2,215.0 1/31/2024 02:30 1/31/2024 03:30 1.00 PROD1, WELLPR DRLG P Drill cement @ 6 BPM, 520 PSI. 90 RPM, 6-7K Tq. 5-10K WOB. T/ 2301''. Turn off pumps. Dry drill on sand top, 60 RPM, 4.5K Tq. 2,215.0 2,301.0 1/31/2024 03:30 1/31/2024 04:00 0.50 PROD1, WELLPR CIRC P P/U T/ 2270'. Circ BU @ 6 BPM. 520 PSI. B/D TD. 2,301.0 2,270.0 1/31/2024 04:00 1/31/2024 05:00 1.00 PROD1, WELLPR TRIP P POOH F/ 2270' T/ 222', PUW=75K. 2,270.0 222.0 1/31/2024 05:00 1/31/2024 05:30 0.50 PROD1, WELLPR BHAH P L/D BHA #10 F/ 222' T/ surface. Metal shavings on magnets. Clean boot baskets. Check roller cone in gauge, 222.0 0.0 1/31/2024 05:30 1/31/2024 07:30 2.00 PROD1, WELLPR BHAH P P/U BHA #12, RCJB, Boot basket, and magnet 0.0 227.0 1/31/2024 07:30 1/31/2024 08:30 1.00 PROD1, WELLPR SVRG P Service Rig, Draw works, top Drive, and pipe skate. Work service loop 227.0 227.0 1/31/2024 08:30 1/31/2024 10:30 2.00 PROD1, WELLPR RGRP T Service loop hoses and electrical cable not riding correctly. Re secure loop to prevent damage while tripping 227.0 227.0 1/31/2024 10:30 1/31/2024 12:00 1.50 PROD1, WELLPR SFTY P COP / Nordic safety on rig. Reenact foot injury. Run multiple scenarios on rig floor 227.0 227.0 1/31/2024 12:00 1/31/2024 15:30 3.50 PROD1, WELLPR PULD P Continue in hole BHA #12 227.0 2,304.0 Rig: NORDIC 3 RIG RELEASE DATE 2/4/2024 Page 15/18 1A-03 Report Printed: 3/4/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/31/2024 15:30 1/31/2024 17:00 1.50 PROD1, WELLPR OTHR P Dry tag 2304', PUW=74K, SOW=72 K, PUH 30' to 2274. Pump 5 BPM @ 428 PSI, 30 RPM, free torque=2.8K Take 5' Bites, reciprocate, Circ BU. Dry tag 2310, Blow down top drive 2,304.0 2,280.0 1/31/2024 17:00 1/31/2024 18:30 1.50 PROD1, WELLPR TRIP P Dry tag @ 2310, Trip outT/ 227', PUW=74K. 2,310.0 227.0 1/31/2024 18:30 1/31/2024 19:30 1.00 PROD1, WELLPR BHAH P L/D BHA #12, Inspect magnet, Clean boot baskets, steal and aluminum debris. Clean RCJB. Finger packed off with large pieces on bow spring blades and pieces of 7" casing. 227.0 0.0 1/31/2024 19:30 1/31/2024 20:30 1.00 PROD1, WELLPR BHAH P M/U BHA #13 RCJB #2 T/ 37', SOW=45K. 0.0 37.0 1/31/2024 20:30 1/31/2024 21:00 0.50 PROD1, WELLPR SVRG P Service rig. Top drive link tilt cylinders. 37.0 37.0 1/31/2024 21:00 1/31/2024 21:15 0.25 PROD1, WELLPR BHAH P M/U BHA #13 RCJB #2 F / 37' T/ 227', SOW=49K. 37.0 227.0 1/31/2024 21:15 1/31/2024 22:00 0.75 PROD1, WELLPR TRIP P RIH F/ 227' T/ 2266', SOW=72K. 227.0 2,266.0 1/31/2024 22:00 2/1/2024 00:00 2.00 PROD1, WELLPR SLPC P Slip & cut 66' of drill line. 2,266.0 2,266.0 2/1/2024 00:00 2/1/2024 00:30 0.50 PROD1, WELLPR SVRG P Service rig. Working on charge pump. 2,266.0 2,266.0 2/1/2024 00:30 2/1/2024 01:30 1.00 PROD1, WELLPR CIRC T Attempt to break circulation. Isolation valve on charge pump failed. Unable to provide fluid from pits to pumps. Replaced butterfly isolation valve. 2,266.0 2,255.0 2/1/2024 01:30 2/1/2024 01:45 0.25 PROD1, WELLPR OTHR P RIH F/ 2266', dry tag sand top @ 2310.. PUH 30' to 2280. PUW=77K, SOW=72K. Pump @ 6 BPM @ 1650 PSI, 30 RPM, free torque=3K Take 5' Bites, rotating and reciprocating. 2,266.0 2,322.0 2/1/2024 01:45 2/1/2024 02:15 0.50 PROD1, WELLPR CIRC P Circ BU @ 6 BPM, 1360 PSI. Dry tag 2322', Blow down top drive 2,322.0 2,322.0 2/1/2024 02:15 2/1/2024 03:15 1.00 PROD1, WELLPR TRIP P POOH F/ 2325' T/ 277', PUW=77K. 2,322.0 277.0 2/1/2024 03:15 2/1/2024 04:00 0.75 PROD1, WELLPR BHAH P L/D BHA #13. Diminishing metal shavings on magnets. Gummed up sand in boot baskets & RCJB - No metal. 277.0 0.0 2/1/2024 04:00 2/1/2024 04:30 0.50 PROD1, WELLPR CLEN P Clean & clear rig floor. 0.0 2/1/2024 04:30 2/1/2024 05:30 1.00 PROD1, WELLPR BHAH P M/U BHA #14 RCJB #3 T/ 277'. Trip in well w/BHA #14 0.0 2,322.0 2/1/2024 05:30 2/1/2024 06:00 0.50 PROD1, WELLPR CIRC P Wash 2322 to 2348 2,322.0 2,348.0 2/1/2024 06:00 2/1/2024 07:00 1.00 PROD1, WELLPR CIRC P PUH, Circ BU 7 BPM @1200 PSI. S/D pump. Dry tag top of sand @ 2348, PUH to 2256, Blow down top drive, Monitor well 2,348.0 2,256.0 2/1/2024 07:00 2/1/2024 08:30 1.50 PROD1, WELLPR TRIP P POOH to BHA , PUW=73K 2,256.0 277.0 2/1/2024 08:30 2/1/2024 09:30 1.00 PROD1, WELLPR BHAH P L/D BHA # 14. No junk in RCJB, Boot basckets clear, Lots of sand. Tiny piece of aluminum 277.0 0.0 2/1/2024 09:30 2/1/2024 10:30 1.00 PROD1, WELLPR BHAH P M/U BHA #15, RBP retrieval tool 0.0 213.0 2/1/2024 10:30 2/1/2024 12:00 1.50 PROD1, WELLPR TRIP P Trip in hole to retrieve RBP 213.0 2,287.0 2/1/2024 12:00 2/1/2024 13:30 1.50 PROD1, WELLPR CIRC P KU top drive. Pump 5 BPM @ 450 PSI, 30 RPM @ 3K Free torque. Weight 73K. Wash down to 2363', Circ BU 2,287.0 2,363.0 Rig: NORDIC 3 RIG RELEASE DATE 2/4/2024 Page 16/18 1A-03 Report Printed: 3/4/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/1/2024 13:30 2/1/2024 14:00 0.50 PROD1, WELLPR DISP P Displace viscosified seawater to clear seawater, 5 BPM @ 450 PSI 2,363.0 2,363.0 2/1/2024 14:00 2/1/2024 14:30 0.50 PROD1, WELLPR FISH P Fish RBP. Latch @ 2373, PUW =73K. RIH past 2373 2,363.0 2,373.0 2/1/2024 14:30 2/1/2024 15:00 0.50 PROD1, WELLPR TRIP P PUH to 2287. Blow down top drive, OWFF. Displace trip tank to clear seawater 2,373.0 2,287.0 2/1/2024 15:00 2/1/2024 16:30 1.50 PROD1, WELLPR TRIP P POOH F/ 2287' T/ 213', PUW=73K 2,287.0 213.0 2/1/2024 16:30 2/1/2024 17:00 0.50 PROD1, WELLPR BHAH P L/D BHA #15 F/ 213' T/ surface. Plug recovered. 213.0 0.0 2/1/2024 17:00 2/1/2024 17:45 0.75 PROD1, WELLPR CLEN P Clean & clear RF. 0.0 0.0 2/1/2024 17:45 2/1/2024 18:15 0.50 PROD1, WELLPR RURD P R/U testing equipment. 0.0 0.0 2/1/2024 18:15 2/1/2024 18:45 0.50 PROD1, WELLPR PRTS P PT 7" CSG T/ 2500 PSI for 30 Min. 0.0 0.0 2/1/2024 18:45 2/1/2024 19:00 0.25 PROD1, WELLPR RURD P B/D, R,D testing equipment. 0.0 0.0 2/1/2024 19:00 2/1/2024 19:45 0.75 PROD1, WELLPR BHAH P M/U BHA #16, dress off mill T/ 215'. SOW=47K 0.0 215.0 2/1/2024 19:45 2/1/2024 23:00 3.25 PROD1, WELLPR TRIP P RIH F/ 215' T/ 7352', PUW=140K, SOW=110K. 215.0 7,352.0 2/1/2024 23:00 2/2/2024 00:00 1.00 PROD1, WELLPR MILL P Obtain parameter. Pump @ 1BPM, 50 PSI, @ 2 BPM, 165 PSI. Rot @ 60 RPM, 8.5K Free Tq. ROT=125K. Wash down @ 1 BPM T/ 7443'. Set down 5K. P/U. Mill down @ 2 BPM, 165 PSI, 30 RPM, 5.8K Free Tq. Set 5K down @ 7450'. PSI increase T/ 240 PSI. Mill T/ 7452'' @ 2 BPM, 850 PSI, 60 RPM, 8.9K Tq Top of stump @ 7444' 7,352.0 7,452.0 2/2/2024 00:00 2/2/2024 01:00 1.00 PROD1, WELLPR CIRC P P/U T/ 7440'. Circ 29 Bbls Hi vis sweep around @ 6 BPM, 1300 PSI. Dumping sweep at surface. . 7,452.0 7,440.0 2/2/2024 01:00 2/2/2024 03:00 2.00 PROD1, WELLPR PULD P B/D TD. LDDP F/ 7440' T/6056', PUW=140K. 7,440.0 6,056.0 2/2/2024 03:00 2/2/2024 05:00 2.00 PROD1, WELLPR RURD P Crew change out. B/D all external circulaing lines to determine what areas are froze up and need to be removed and thawed for tiger tank, open top tank & cuttings tank. 6,056.0 6,056.0 2/2/2024 05:00 2/2/2024 08:00 3.00 PROD1, WELLPR PULD P LDDP F/ 6056' T/ 2351', PUW=115K. 6,056.0 2,351.0 2/2/2024 08:00 2/2/2024 09:00 1.00 PROD1, WELLPR RURD P Off load pipe, SLB working jewelry and pipe tallies 2,351.0 2,351.0 2/2/2024 09:00 2/2/2024 12:00 3.00 PROD1, WELLPR PULD P LDDP F/ 2351' T/ 215', PUW=65K. 2,351.0 250.0 2/2/2024 12:00 2/2/2024 13:00 1.00 PROD1, WELLPR BHAH P Lay down BHA #16. Good indication over tubing stub will dress off mill. 250.0 0.0 2/2/2024 13:00 2/2/2024 13:30 0.50 COMPZN, RPCOMP RURD P Pull wear ring 0.0 0.0 2/2/2024 13:30 2/2/2024 14:30 1.00 COMPZN, RPCOMP RURD P Load out drill pipe and drill collars, Load out all YJ tools, Load out extra GLM, R/D rig tongs and spinners. R/U tubing handling equipment. 0.0 0.0 2/2/2024 14:30 2/2/2024 15:00 0.50 COMPZN, RPCOMP CLEN P Clean - degrease rig floor 0.0 0.0 2/2/2024 15:00 2/2/2024 15:30 0.50 COMPZN, RPCOMP SFTY P PJSM, P/U 3 1/2" completion. Verify joint count and jewelry running order. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 2/4/2024 Page 17/18 1A-03 Report Printed: 3/4/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/2/2024 15:30 2/3/2024 00:00 8.50 COMPZN, RPCOMP PUTB P RIH w/ 3 1/2", 9.3#, L-80, EUE-M completion as per tally T/ 6681'. SOW=76K. EUE-M torqued T/ 2450 Ft/Lbs. Run-N- Seal dope applied. 0.0 6,681.0 2/3/2024 00:00 2/3/2024 02:00 2.00 COMPZN, RPCOMP PUTB P Cont RIH w/ 3 1/2" completion F/ 6681' T/ 7423'. PUW=xxK, SOW=xxK. K/U pump @ 5 BPM, 290 PSI. RIH identify PSI increase T/ 500 PSI @ 7446.5'. Shut off pump. Cont RIH pop shear pins @ 7449'. Fully locate @ 7451.5'. 6,681.0 7,451.5 2/3/2024 02:00 2/3/2024 03:30 1.50 COMPZN, RPCOMP HOSO P L/D joints #235, #234, #233. M/U space out pups 6.22', 10.20', 10.21'. M/U joint #233. M/U hanger and landing joint w/ head pin & circ hose. 7,451.5 7,416.0 2/3/2024 03:30 2/3/2024 05:00 1.50 COMPZN, RPCOMP CRIH P Crew change out. Close annular reverse circ 190 Bbls CI seawater chased w/ 30 Bbls neat seawater @ 3 BPM, 300 PSI. 7,416.0 7,416.0 2/3/2024 05:00 2/3/2024 05:30 0.50 COMPZN, RPCOMP PUTB P RIH and land hanger w/ mule shoe @ 7433.5' ORKB. RILDS. 7,416.0 7,433.5 2/3/2024 05:30 2/3/2024 07:30 2.00 COMPZN, RPCOMP ELNE P PJSM, R/U Eline to set P2P RBP to set SLB packer 7,433.5 7,433.5 2/3/2024 07:30 2/3/2024 10:30 3.00 COMPZN, RPCOMP ELOG P RIH with RBP, Run CCL past GLM @ 7309. . Observed jewelry as run. Wanted to see 10' pup above overshot. Became stuck @ 7436 COE. Unable to go up or done. Consult town. et plug @ 7434 uncorrected. Lift right off. POOH. 7,433.5 7,433.5 2/3/2024 10:30 2/3/2024 11:30 1.00 COMPZN, RPCOMP ELNE P On surface, Lay down RBP running tool, Redress for second packer run. R/U to PT tubing, 7,433.5 7,433.5 2/3/2024 11:30 2/3/2024 13:00 1.50 COMPZN, RPCOMP PRTS P R/U to PT tubing, , Pressure up to 500 PSI, IA tracking with tubing. R/D pressure testing equipment. R/U slick line Prep for second rbp run 7,433.5 7,433.5 2/3/2024 13:00 2/3/2024 15:00 2.00 COMPZN, RPCOMP ELNE P E-Line RIH with RBP, Log CCL. Set @ 7400' COE. POOH 7,433.5 7,433.5 2/3/2024 15:00 2/3/2024 15:30 0.50 COMPZN, RPCOMP PRTS P On surface, R/B E-line. Rig up to pressure test 7,433.5 7,433.5 2/3/2024 15:30 2/3/2024 15:45 0.25 COMPZN, RPCOMP PRTS P Pressure test to 1000 PSI. Stop and monitor. IA is not tracking with tubing 7,433.5 7,433.5 2/3/2024 15:45 2/3/2024 16:45 1.00 COMPZN, RPCOMP PRTS P Continue to pressure in 500 PSI Intervals to 3500PSI. Hold for 30 minutes At pressure 16:05 7,433.5 7,433.5 2/3/2024 16:45 2/3/2024 17:15 0.50 COMPZN, RPCOMP PRTS P Bleed tubing to 1500PSI, Pressure IA to 2500 for 30 Min - Good test 7,433.5 7,433.5 2/3/2024 17:15 2/3/2024 17:30 0.25 COMPZN, RPCOMP PRTS P Bleed off tubing, Observe SOV open. T & IA to zero. 7,433.5 7,433.5 2/3/2024 17:30 2/3/2024 18:30 1.00 COMPZN, RPCOMP RURD P FMC here, R/D PT equipment and landing joint, 7,433.5 7,433.5 2/3/2024 18:30 2/3/2024 19:00 0.50 COMPZN, RPCOMP MPSP P Set HP BPV 7,433.5 0.0 2/3/2024 19:00 2/3/2024 19:30 0.50 COMPZN, WHDBOP PRTS P PT BPV from below T/ 1000 PSI for 10 Min. 2/3/2024 19:30 2/3/2024 20:00 0.50 COMPZN, WHDBOP RURD P B/D, R/D testing equipment. 2/3/2024 20:00 2/3/2024 22:00 2.00 COMPZN, WHDBOP NUND P Remove 2 7/8" x 5 1/2" VBR's from LPR. In preparation of changing out LPR once off of the well. 2/3/2024 22:00 2/4/2024 00:00 2.00 COMPZN, WHDBOP NUND P N/D BOP & DSA Rig: NORDIC 3 RIG RELEASE DATE 2/4/2024 Page 18/18 1A-03 Report Printed: 3/4/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/4/2024 00:00 2/4/2024 02:30 2.50 COMPZN, WHDBOP NUND P Load adaptor spool into cellar. Install tree test dart. N/U adaptor spool & tree. 2/4/2024 02:30 2/4/2024 03:00 0.50 COMPZN, WHDBOP PRTS P PT hanger void T/ 5000 PSI for 15 Min. 2/4/2024 03:00 2/4/2024 04:15 1.25 COMPZN, WHDBOP RURD P R/U circ equipment & LRS. 2/4/2024 04:15 2/4/2024 04:45 0.50 COMPZN, WHDBOP PRTS P PT tree T/ 5000 PSI 2/4/2024 04:45 2/4/2024 05:00 0.25 COMPZN, WHDBOP MPSP P Pull test dart & BPV. 2/4/2024 05:00 2/4/2024 06:30 1.50 COMPZN, WHDBOP FRZP P LRS pump 75 Bbls diesel down IA @ 2 BPM. ICP=700, FCP=900. U-tube well. 2/4/2024 06:30 2/4/2024 08:00 1.50 COMPZN, WHDBOP RURD P B/D, R/D circ equipment. Secure tree & celar. Final pressures. T/IA/OA = 0/0/0 2/4/2024 08:00 2/4/2024 14:00 6.00 DEMOB, MOVE DMOB P Remove auxillary equipment from rig. B/D water on RF. B;D trash pump lines. R/D hard line. Remove snow from rig foot print. Pull off well and stage on 1A pad. Rig released # 14:00 Hrs. Rig: NORDIC 3 RIG RELEASE DATE 2/4/2024 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,006.0 1A-03 2/13/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Install GLD, Pull RBP's, Pull CSA-2 Plug, update tag depth 1A-03 2/13/2024 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL - IA x OA communication. 1/6/2002 triplwj 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 30.0 80.0 80.0 65.00 H-40 WELDED SURFACE 10 3/4 9.95 31.5 2,953.1 2,683.8 45.50 K-55 BTC TIEBACK 7 6.28 28.9 2,047.0 1,986.5 26.00 L-80 HYD563 PRODUCTION 7 6.28 28.9 8,863.0 7,044.2 26.00 K-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 27.0 Set Depth … 7,433.5 String Max No… 3 1/2 Set Depth … 5,860.6 Tubing Description Tubing – Completion Upper Wt (lb/ft) 9.30 Grade L80 Top Connection EUE-M ID (in) 2.99 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 0.00 Hanger 6.980 FMC 3 1/2" Gen 4 Tubing Hanger (EUE w/ H-BPV) 2.920 2,644.5 2,462.2 40.89 Mandrel – GAS LIFT 5.924 3.5" x 1.5" MMG, GLM SLB MMG 2.920 3,204.9 2,855.9 47.00 Mandrel – GAS LIFT 5.930 3.5" x 1.5" MMG, GLM SLB MMG 2.920 7,309.2 5,762.4 37.55 Mandrel – GAS LIFT 5.926 3.5" x 1.5" MMG, GLM SLB MMG 2.920 7,426.6 5,855.1 37.87 Overshot 6.000 Poor boy overshot 6" x 3-1/2", (6.5' swallow to No-Go, 3' to shear pins) Baker Poor Boy OverSho t 3.580 Top (ftKB) 7,429.0 Set Depth … 7,480.7 String Max No… 3 1/2 Set Depth … 5,897.9 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd Mod ID (in) 2.99 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) 7,458.0 5,879.9 37.71 LOCATOR 4.180 BAKER LOCATOR w/SEAL ASSY COLLAR BAKER 2.990 7,459.0 5,880.7 37.71 SEAL ASSY 3.750 BAKER SEAL ASSY BAKER 80-40 PBR 2.990 Top (ftKB) 7,466.0 Set Depth … 7,597.2 String Max No… 3 1/2 Set Depth … 5,990.5 Tubing Description STACKED PACKER Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd Mod ID (in) 2.99 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) 7,466.0 5,886.3 37.67 SBR 5.870 80-40 BAKER 80-40 2.980 7,489.0 5,904.5 37.55 PACKER 5.970 FHL RETRIEVABLE PACKER BAKER FHL RETRIE VABLE 2.910 7,541.5 5,946.2 37.40 NIPPLE 4.500 DS NIPPLE CAMCO DS 2.812 7,589.8 5,984.6 37.28 OVERSHOT 5.990 POORBOY OVERSHOT BAKER POORB OY 2.970 Top (ftKB) 7,591.4 Set Depth … 8,047.0 String Max No… 3 1/2 Set Depth … 6,352.2 Tubing Description TUBING WO 1985 Wt (lb/ft) 9.20 Grade J-55 Top Connection BTC ID (in) 2.99 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) 7,606.9 5,998.2 37.27 SBR 4.000 BAKER SBR BAKER SBR 2.810 7,633.1 6,019.1 37.33 PACKER 5.968 BAKER FHL PACKER BAKER FHL 3.000 7,672.7 6,050.5 37.43 GAS LIFT 5.313 OTIS LBX 2.875 7,749.8 6,111.8 37.25 GAS LIFT 5.313 OTIS LBX 2.900 7,892.4 6,226.0 36.08 GAS LIFT 5.313 OTIS LBX 2.900 7,907.8 6,238.4 35.92 PACKER 5.968 BAKER FHL PACKER BAKER FHL 3.000 7,921.0 6,249.1 35.79 GAS LIFT 5.313 OTIS LBX 2.900 7,932.1 6,258.2 35.68 BLAST RING 4.500 BLAST RINGS (3) 2.867 7,995.0 6,309.5 35.05 GAS LIFT 5.313 OTIS LBX 2.900 8,014.2 6,325.2 34.89 LOCATOR 4.500 BAKER LOCATOR 3.000 8,016.0 6,326.7 34.88 PACKER 5.875 BAKER FB-1 PACKER W/ 5" SEAL BORE EXT BAKER FB-1 4.000 8,034.4 6,341.8 34.74 NIPPLE 4.540 CAMCO D NIPPLE NO GO CAMCO D 2.750 8,046.2 6,351.5 34.65 SOS 4.000 CAMCO SHEAR OUT SUB. ***ELMD @ 8047' ON SWS PPROF 5/17/200*** 2.992 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) 28.9 28.9 0.00 EMERGENCY SLIPS C-21 11" x 7" emergeny slips 1/28/2024 7.000 7,634.0 6,019.8 37.34 LEAK - PACKER LEAK FOUND AT PACKER @ 7641' Leak at the top PKR @ 7634' (6/29/08) 5/17/2000 1A-03, 3/4/2024 12:24:30 PM Vertical schematic (actual) PRODUCTION; 2,044.0-8,863.0 FISH; 8,314.0 FISH; 8,270.0 RPERF; 8,180.0-8,214.0 IPERF; 8,178.0-8,210.0 IPERF; 8,166.0-8,172.0 SQZ; 8,108.0-8,110.0 Cement; 8,108.0 ftKB PLUG; 8,034.4 SAND; 8,020.4 PACKER; 8,016.0 GAS LIFT; 7,995.0 IPERF; 7,948.0-7,972.0 RPERF; 7,948.0-7,972.0 GAS LIFT; 7,921.0 Cement; 7,920.0 ftKB SQZ; 7,920.0-7,922.0 PACKER; 7,907.8 GAS LIFT; 7,892.4 RPERF; 7,820.0-7,888.0 IPERF; 7,820.0-7,888.0 GAS LIFT; 7,749.8 GAS LIFT; 7,672.7 LEAK - PACKER; 7,634.0 PACKER; 7,633.1 PACKER; 7,489.0 Packer (Tubing); 7,369.1 Mandrel – GAS LIFT; 7,309.2 Mandrel – GAS LIFT; 3,204.9 SURFACE; 31.5-2,953.1 Mandrel – GAS LIFT; 2,644.5 TIEBACK; 28.9-2,047.0 Production String 1 Cement; 28.9 ftKB CONDUCTOR; 30.0-80.0 EMERGENCY SLIPS; 28.9 Hanger; 27.0 KUP PROD KB-Grd (ft) 39.01 RR Date 7/24/1981 Other Elev… 1A-03 ... TD Act Btm (ftKB) 8,880.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292061500 Wellbore Status PROD Max Angle & MD Incl (°) 48.00 MD (ftKB) 3,600.00 WELLNAME WELLBORE1A-03 Annotation Last WO: End Date 2/4/2024 H2S (ppm) 45 Date 1/29/2019 Comment SSSV: NIPPLE 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) 8,020.4 6,330.3 34.85 SAND 14' OF SILICA SAND ON TOP OF PLUG 2/12/2015 8,034.4 6,341.8 34.74 PLUG 2.75" CA-2 PLUG 2/12/2015 8,270.0 6,538.0 32.48 FISH Retainer Pin f/ GU Adapter Lost Downhole 12/1/1996 0.000 8,314.0 6,575.2 32.22 FISH 5" Vann Gun 450' Long 7/24/1981 7/24/1981 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,644.5 2,462.2 40.89 1 GAS LIFT GLV RK 1 1/2 1,210.0 2/8/2024 SLB MMG 0.313 3,204.9 2,855.9 47.00 2 GAS LIFT OV RK 1 1/2 2/8/2024 SLB MMG 0.375 7,309.2 5,762.4 37.55 3 GAS LIFT DMY RK 1 1/2 0.0 2/7/2024 SLB MMG 0.000 7,672.7 6,050.5 37.43 6 PROD DMY RM 1 1/2 0.0 2/9/1997 CLSD 0.000 7,749.8 6,111.8 37.25 7 PROD DMY RM 1 1/2 0.0 6/22/2010 0.000 7,892.4 6,226.0 36.08 8 PROD DMY RM 1 1/2 0.0 1/17/2010 0.000 7,921.0 6,249.1 35.79 9 PROD DMY RM 1 1/2 0.0 1/17/2010 0.000 7,995.0 6,309.5 35.05 1 0 PROD DMY RM 1 1/2 0.0 4/27/2010 0.000 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) 2,031.4 1,973.2 30.63 Collar - Stage 8.270 7" ES Cementer (SN#: 101899235) Halliburto n HES Cementer 6.171 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,820.0 7,888.0 6,167.8 6,222.5 C-4, C-3, 1A-03 7/24/1981 12.0 IPERF 5" Vann Guns 7,820.0 7,888.0 6,167.8 6,222.5 C-2, 1A-03 5/10/1985 4.0 RPERF 120° Ph, 4" JumboJet II 7,920.0 7,922.0 6,248.4 6,250.0 C-2, 1A-03 5/5/1985 4.0 SQZ Squeezed 7,948.0 7,972.0 6,271.1 6,290.7 C-1, 1A-03 7/24/1981 12.0 IPERF 5" Vann Guns 7,948.0 7,972.0 6,271.1 6,290.7 C-1, 1A-03 5/10/1985 4.0 RPERF 120° Ph, 4" JumboJet II 8,108.0 8,110.0 6,402.5 6,404.1 UNIT B, 1A-03 5/5/1985 4.0 SQZ Squeezed 8,166.0 8,172.0 6,450.7 6,455.7 A-5, 1A-03 7/24/1981 12.0 IPERF 5" Vann Guns 8,178.0 8,210.0 6,460.7 6,487.5 A-4, 1A-03 7/17/1993 4.0 IPERF 180° Ph, 2.5" Titan Guns 8,180.0 8,214.0 6,462.4 6,490.9 A-4, 1A-03 7/24/1981 12.0 RPERF 5" Vann Guns Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,920.0 7,922.0 6,248.4 6,250.0 Cement 8,108.0 8,110.0 6,402.5 6,404.1 Cement 1A-03, 3/4/2024 12:24:31 PM Vertical schematic (actual) PRODUCTION; 2,044.0-8,863.0 FISH; 8,314.0 FISH; 8,270.0 RPERF; 8,180.0-8,214.0 IPERF; 8,178.0-8,210.0 IPERF; 8,166.0-8,172.0 SQZ; 8,108.0-8,110.0 Cement; 8,108.0 ftKB PLUG; 8,034.4 SAND; 8,020.4 PACKER; 8,016.0 GAS LIFT; 7,995.0 IPERF; 7,948.0-7,972.0 RPERF; 7,948.0-7,972.0 GAS LIFT; 7,921.0 Cement; 7,920.0 ftKB SQZ; 7,920.0-7,922.0 PACKER; 7,907.8 GAS LIFT; 7,892.4 RPERF; 7,820.0-7,888.0 IPERF; 7,820.0-7,888.0 GAS LIFT; 7,749.8 GAS LIFT; 7,672.7 LEAK - PACKER; 7,634.0 PACKER; 7,633.1 PACKER; 7,489.0 Packer (Tubing); 7,369.1 Mandrel – GAS LIFT; 7,309.2 Mandrel – GAS LIFT; 3,204.9 SURFACE; 31.5-2,953.1 Mandrel – GAS LIFT; 2,644.5 TIEBACK; 28.9-2,047.0 Production String 1 Cement; 28.9 ftKB CONDUCTOR; 30.0-80.0 EMERGENCY SLIPS; 28.9 Hanger; 27.0 KUP PROD 1A-03 ... WELLNAME WELLBORE1A-03 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV UNIT 1A-03 JBR 03/07/2024 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:4 Tested with 3 1/2 " test joint with doughnut. - 30 degrees out and wind combatted with heaters made for thermal issues along with a few relatively new hands and troubleshooting leaks made for long test. H2s sensor was new style wireless that had no signal to control panel. Electrician relocated antennas in cellar and dog house, retested and pass. F/P on CMV #10, greased cycled and passed also greased #8 CMV at the same time before testing per my reccomendation. F/P Annular, excercised and increase closing pressure, retest , Pass. No other failures. FSV Misc.: EUE FOSV BOP Misc.: 2 each 2 1/16” 5K gate valves on test spool located on BOP stack below the lower rams. Choke Misc.: 3” Demco valve located on the downstream of the manifold Test Results TEST DATA Rig Rep:Jake HenryOperator:ConocoPhillips Alaska, Inc.Operator Rep:Jim Newell Rig Owner/Rig No.:Nordic 3 PTD#:1810880 DATE:1/29/2024 Type Operation:WRKOV Annular: 250/3500Type Test:WKLY Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopSTS240201082152 Inspector Sully Sullivan Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 12.5 MASP: 2515 Sundry No: 323-627 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P FSV Misc 1 P 12 FPNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 1 PCH Misc Stripper 0 NA Annular Preventer 1 13 5/8 FP #1 Rams 1 2 7/8 x 5 1/2 v P #2 Rams 1 Blinds P #3 Rams 1 2 7/8 x 5 1/2 v P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8 P HCR Valves 2 3 1/8 P Kill Line Valves 1 3 1/8 P Check Valve 0 NA BOP Misc 2 2 1/16 P System Pressure P2950 Pressure After Closure P1600 200 PSI Attained P18 Full Pressure Attained P116 Blind Switch Covers:Pall stations Bottle precharge P Nitgn Btls# &psi (avg)P4@2050 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector FP FPH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P19 #1 Rams P4 #2 Rams P4 #3 Rams P4 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1         CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Al Hansen To:Regg, James B (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay Cc:Company Man, Nordic 3; Dave Hiler Subject:KUP 1A-03 1-18-24 AOGCC Date:Monday, January 22, 2024 7:29:53 AM Attachments:KUP 1A-03 1-18-24 AOGCC.xlsx Al Hansen Rig Manager Rig 3 907-440-6928 Cell This information is intended only for the use of the individual (s) or entity (ies) named above and may contain confidential or privileged information. Any unauthorized disclosure, copying, distribution or the taking of any action in reliance on the contents of this transmitted information is strictly prohibited. If you are not the intended recipient or have received this transmission in error, please immediately delete it and any attachments from your system and send me an email confirming that you have not disclosed, copied, or distributed this message and that you have deleted this message and any attachments from your system. .XSDUXN5LYHU8QLW$ 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bmitt to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:3 DATE: 1/18/24 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #1810880 Sundry #323-627 Operation: Drilling: Workover: xxx Explor.: Test: Initial: Weekly: xxx Bi-Weekly: Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:2515 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 1P Standing Order Posted P Misc.NA Ball Type 1P Test Fluid Water Inside BOP 1P FSV Misc 1P BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13 5/8"P Pit Level Indicators PP #1 Rams 1 2 7/8" X 5 1/2"P Flow Indicator PP #2 Rams 1 CSO Rams P Meth Gas Detector PP #3 Rams 1 7" Fixed FP H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8"P Time/Pressure Test Result HCR Valves 2 3 1/8"P System Pressure (psi)2950 P Kill Line Valves 1 3 1/8"P Pressure After Closure (psi)1650 P Check Valve 0NA200 psi Attained (sec)19 P BOP Misc 2 2 1/16" 5000 P Full Pressure Attained (sec)124 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 4@2081 P No. Valves 12 FP ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 1P Annular Preventer 18 P #1 Rams 5 P Coiled Tubing Only:#2 Rams 5 P Inside Reel valves 0NA #3 Rams 5 P #4 Rams NA Test Results #5 Rams NA #6 Rams NA Number of Failures:2 Test Time:11.5 HCR Choke 1 P Repair or replacement of equipment will be made within 3 days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 1/16/24/09:00 Waived By Test Start Date/Time:1/18/2024 12:00 (date) (time)Witness Test Finish Date/Time:1/18/2024 23:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Kam StJohn Nordic Tested with 3 1/2" & 7" test joints.Choke valve #9 fail grease function retest pass LPR'S fail function retest fail change out 7" packers retest fail. 7" fixed ram bodies were changed out on 1-21-22 Tested 250/3500 Passed Hansen/Borgen CPAI Pickworth/Wiese KRU 1A-03 Test Pressure (psi): gmanager.rig3@nordic-calista.com ic3.Companyman@conocophillips Form 10-424 (Revised 08/2022) 2024-0118_BOP_Nordic3_KRU_1A-03 9 9 9 9 9 9999 9 9 9 9 9 - 5HJJ FP FP Choke valve #9 fail LPR'S fail function retest fail change out 7" 9 j g packers retest fail. 7" fixed ram bodies were changed out on 1-21-22 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8880'8270', 8314' Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 12/25/2023 3-1/2" Packer: Baker FHL Retrvbl Packer Packer: Baker FHL Packer Packer: Baker FHL Packer Packer: Baker FB-1 Packer w Seal Bore Ext. SSSV: None Perforation Depth MD (ft): L-80/J-55 2922' 7820-7888', 7920-7922', 7948- 7972',8108-8110', 8166-8172', 8178-8214' 8834' 6168-6222', 6248-6250', 6271- 6291', 6402-6404', 6451- 6456',6461-6491' 7" Perforation Depth TVD (ft): 80' 2953' 7044'8863' 16" 10-3/4" 50' 6352' MD 80' 2684' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Kuparuk River Oil Pool TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025647 181-088 P.O. Box 100360, Anchorage, AK 99510 50-029-20615-00-00 Kuparuk River Field Kuparuk River Oil Pool AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 7489' MD nad 6019' TVD 7633' MD and 6019' TVD 7908' MD and 6238' TVD 8016' and 6327' TVD N/A Adam Klem Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: adam.klem@conocophillips.com (907) 263-4529 Staff RWO / CTD Engineer KRU 1A-03 7059' 7542' 5946 2515 7542', 8034' N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:34 am, Nov 20, 2023 Adam Klem Digitally signed by Adam Klem Date: 2023.11.20 08:23:10 -09'00' 323-627 BOP test to 3500 psig Annular preventer to 2500 psig VTL 12/19/2023 X SFD 11/27/2023 10-404 X DSR-11/20/23*&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.12.19 13:04:06 -09'00'12/19/23 RBDMS JSB 122623 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 16, 2023 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Adam Klem Staff RWO/CTD Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Producer 1A-03 (PTD# 181-088). Well 1A-03 was drilled and completed in 1981 as a Kuparuk A/C sand producer. In 2013 a RWO was completed to grow and stretch the casing and stack a packer. In 2022 a casing leak was discovered and it has been shut in since. Therefore, a subsidence workover is planned. If you have any questions or require any further information, please contact me at +1-907-263-4529 The RWO is to pull tubing from seals, then set a plug in the 7" casing. We will log log the 7" for shallow cement, cut and pull the shallow 7", overshot with casing patch and cement the 7" to surface. We will then run a new tubing into the seals. Adam Klem Digitally signed by Adam Klem Date: 2023.11.20 08:23:38 -09'00' 1A-03 RWO Procedure Kuparuk Producer Subsidence Repair PTD #181-088 Page 1 of 2 Completed Pre-Rig Work 1. T-PPPOT, T-POT, IC-PPOT, IC-POT tests all passed 2. CMIT to 2500psi for 30 min, passed Remaining Pre-Rig Work 3. Dummy off top GLMs, leaving GLM at 7402 open Rig Work MIRU 1. MIRU Nordic 3 on 1A-03. Circulate well over to SW. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/3,500 psi. Test annular 250/3,500 psi. Retrieve Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing out of seals at 7459’. Log Cement, Secure casing. Cut and pull casing 6. Rig up eline and run CBL from ~2900’ up to find TOC 7. RIH with 7” G-Plug and set at ~150’ below TOC’ PT to 1000psi for 30minutes. 8. ND BOPE. 9. ND tubing head. 10. NU BOPe to casing head 11. RIH with multi string cutter and cut 7” casing above TOC 12. Spear 7” casing 13. Shut in annular if necessary and circ surface to surface heated SW down through cut and up OA to circulate out arctic pack. 14. POOH LD 7” casing Run new casing and cement 15. Dress off 7” stump 16. RIH with new 7”, HES cementer and overshot patch 17. Land 7” and confirm patch seals with 2500psi PT 18. Cement 7” as per design from HES cementer to surface 19. ND BOP. NU tubing spool. NU BOP. Test break Mill stage collar, pull plug 20. PU mills to mill through cement plug and collar in 7”. Mill and grind material on sand above plug while circulating back to surface. POOH 21. Run in to wash sand off top of plug. 22. Pull plug Run new Tubing 23. RIH with new 3 ½” completion to stab into sealbore. 24. Fully locate, PU above seals. Circulate in CI brine 25. Land tubing hanger. Install packoffs 26. PT tubing to 3000psi for 30min. Holding 2000psi on tubing, PT IA to 2500psi for 30minutes 27. Shear SOV 28. Install BPV. PT through SOV 29. ND BOP, NU WH 30. Circ in freeze protect tbg and IA 1A-03 RWO Procedure Kuparuk Producer Subsidence Repair PTD #181-088 Page 2 of 2 Post Rig Work 1. Pull SOV, install GLD 2. Pull 2.812” CA2 plug General Well info: Wellhead type/pressure rating: FMC Gen 1 Production Engineer: Adam Becia Surveillance Reservoir Engineer: Jennifer McLeod Estimated Start Date: 12/25/23 Workover Engineer: Adam Klem (907 263-4529/ Adam.klem@conocophillips.com) Current Operations: This well is currently shut in. Well Type: Producer Scope of Work: Pull the existing 3-1/2” completion, subsidence repair 7” casing and run new 3-1/2” tubing BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: CMIT-TxIA – passed 11/7/23 IC POT & PPPOT passed 11/7/23 TBG POT & PPPOT passed 11/7/23 MPSP: 2,515 psi using 0.1 psi/ft gradient Static BHP: 3130 psi/ 6146’ TVD (measured 9/16/22) COMPLETION INFO OD (in) Nom. ID (in) MD (ft RKB) TVD (ft RKB) Weight (lb/ft)Grade Thread Conductor 16 15.06 80 80 65 H-40 Welded Surface Casing 10-3/4"9.95 2953 2684 45.5 K-55 BTC Production Casing 7"6.28 8863 7044 26 K-55 BTC Tubing 3-1/2"2.992 7480 5898 9.3 L-80 EUE-Mod 1A-03 Proposed RWO Schematic PROPOSED COMPLETION Production Tubing: 3-1/2" 9.3# L-80 EUE Tubing to surface 3-1/2" 2.813" 'X' Nipple ~500' RKB 3-1/2" x 1" Camco KBMG GLM @ TBD 3-1/2" x 1" Camco KBMG GLM @ TBD 3-1/2" x 1" Camco KBMG GLM @ TBD 2.813" X-nipple @ ~7420 3-1/2" Baker 80-40 GBH-22 seal assembly @ 7459 7" Subsidence Tieback 7" 26# L-80 Hyd563 to surface 7" HES Cementer 7" Sealing Casing Overshot Lower Completion: 3-1/2" x 7" Baker FHL packer @ 7489 2.813" DS-nipple @ 7541 3.5" Overshot @ 7590' 3-1/2" x 7" Baker FHL packer @ 7634 3-1/2" x 7" Baker FHL packer @ 7908 3-1/2" Blast Rings @ 7932 3-1/2" x 7" Baker FB-1 packer @ 8016 2.75" D nipple @ 8034 Surface Casing Conductor Production Casing TOC est 2306' based on arctic pack Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,222.0 1A-03 6/24/2022 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set CSA-2 Plug, Catche, & Pulled DV 1A-03 9/16/2022 zembaej Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL - IA x OA communication. 1/6/2002 triplwj Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 30.0 Set Depth (ft… 80.0 Set Depth … 80.0 Wt/Len (lb/ft) 65.00 Grade H-40 Top Connection WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 31.5 Set Depth (ft… 2,953.1 Set Depth … 2,683.8 Wt/Len (lb/ft) 45.50 Grade K-55 Top Connection BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 28.9 Set Depth (ft… 8,863.0 Set Depth … 7,044.2 Wt/Len (lb/ft) 26.00 Grade K-55 Top Connection BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 27.0 Set Depth … 5,897.9 String Ma… 3 1/2 Tubing Description TUBING W0 2013 Set Depth (ftKB) 7,480.7 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd Mod ID (in) 2.99 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 0.00 HANGER 8.000 FMC TUBING HANGER FMC 2.992 498.7 498.7 0.00 NIPPLE 4.520 CAMCO DS NIPPLE CAMCO DS 2.875 2,833.4 2,600.7 44.83 GAS LIFT 5.968 CAMCO MMG 2.920 4,678.0 3,855.7 46.06 GAS LIFT 5.968 CAMCO MMG 2.920 5,994.1 4,781.8 45.50 GAS LIFT 5.968 CAMCO MMG 2.920 6,975.2 5,496.8 38.19 GAS LIFT 5.968 CAMCO MMG 2.920 7,402.1 5,835.8 37.99 GAS LIFT 5.968 CAMCO MMG 2.920 7,458.0 5,880.0 37.71 LOCATOR 4.180 BAKER LOCATOR w/SEAL ASSY COLLAR BAKER 2.990 7,459.0 5,880.7 37.71 SEAL ASSY 3.750 BAKER SEAL ASSY BAKER 80-40 PBR 2.990 Top (ftKB) 7,466.0 Set Depth … 5,990.5 String Ma… 3 1/2 Tubing Description STACKED PACKER Set Depth (ftKB) 7,597.2 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd Mod ID (in) 2.99 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) 7,466.0 5,886.3 37.67 SBR 5.870 80-40 BAKER 80-40 2.980 7,489.0 5,904.5 37.55 PACKER 5.970 FHL RETRIEVABLE PACKER BAKER FHL RETRIE VABLE 2.910 7,541.5 5,946.2 37.40 NIPPLE 4.500 DS NIPPLE CAMCO DS 2.812 7,589.8 5,984.6 37.28 OVERSHOT 5.990 POORBOY OVERSHOT BAKER POORB OY 2.970 Top (ftKB) 7,591.4 Set Depth … 6,352.2 String Ma… 3 1/2 Tubing Description TUBING WO 1985 Set Depth (ftKB) 8,047.0 Wt (lb/ft) 9.20 Grade J-55 Top Connection BTC ID (in) 2.99 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) 7,606.9 5,998.2 37.27 SBR 4.000 BAKER SBR BAKER SBR 2.810 7,633.1 6,019.1 37.33 PACKER 5.968 BAKER FHL PACKER BAKER FHL 3.000 7,672.7 6,050.5 37.43 GAS LIFT 5.313 OTIS LBX 2.875 7,749.8 6,111.8 37.25 GAS LIFT 5.313 OTIS LBX 2.900 7,892.4 6,226.0 36.08 GAS LIFT 5.313 OTIS LBX 2.900 7,907.8 6,238.4 35.92 PACKER 5.968 BAKER FHL PACKER BAKER FHL 3.000 7,921.0 6,249.1 35.79 GAS LIFT 5.313 OTIS LBX 2.900 7,932.1 6,258.2 35.68 BLAST RING 4.500 BLAST RINGS (3) 2.867 7,995.0 6,309.5 35.05 GAS LIFT 5.313 OTIS LBX 2.900 8,014.2 6,325.2 34.89 LOCATOR 4.500 BAKER LOCATOR 3.000 8,016.0 6,326.7 34.88 PACKER 5.875 BAKER FB-1 PACKER W/ 5" SEAL BORE EXT BAKER FB-1 4.000 8,034.4 6,341.8 34.74 NIPPLE 4.540 CAMCO D NIPPLE NO GO CAMCO D 2.750 8,046.2 6,351.5 34.65 SOS 4.000 CAMCO SHEAR OUT SUB. ***ELMD @ 8047' ON SWS PPROF 5/17/200*** 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Make Model SN ID (in) 7,539.5 5,944.6 37.40 CATCHER 2.72" AVA CATCHER (34" OAL) 9/16/2022 0.000 7,542.0 5,946.6 37.40 TUBING PLUG 2.812" CSA-2 Plug (30" OAL) 9/16/2022 0.000 7,634.0 6,019.8 37.34 LEAK - PACKER LEAK FOUND AT PACKER @ 7641' Leak at the top PKR @ 7634' (6/29/08) 8,020.4 6,330.3 34.85 SAND 14' OF SILICA SAND ON TOP OF PLUG 8,034.4 6,341.8 34.74 PLUG 2.75" CA-2 PLUG 8,270.0 6,538.0 32.48 FISH Retainer Pin f/ GU Adapter Lost Downhole 0.000 8,314.0 6,575.2 32.22 FISH 5" Vann Gun 450' Long 7/24/1981 0.000 1A-03, 9/17/2022 5:51:37 PM Vertical schematic (actual) PRODUCTION; 28.9-8,863.0 FISH; 8,314.0 FISH; 8,270.0 RPERF; 8,180.0-8,214.0 IPERF; 8,178.0-8,210.0 IPERF; 8,166.0-8,172.0 SQZ; 8,108.0-8,110.0 Cement; 8,108.0 ftKB SOS; 8,046.2 PLUG; 8,034.4 NIPPLE; 8,034.4 SAND; 8,020.4 PACKER; 8,016.0 LOCATOR; 8,014.1 GAS LIFT; 7,995.0 RPERF; 7,948.0-7,972.0 IPERF; 7,948.0-7,972.0 GAS LIFT; 7,921.0 Cement; 7,920.0 ftKB SQZ; 7,920.0-7,922.0 PACKER; 7,907.8 GAS LIFT; 7,892.4 IPERF; 7,820.0-7,888.0 RPERF; 7,820.0-7,888.0 GAS LIFT; 7,749.8 GAS LIFT; 7,672.7 LEAK - PACKER; 7,634.0 PACKER; 7,633.1 SBR; 7,606.9 OVERSHOT; 7,589.8 TUBING PLUG; 7,542.0 NIPPLE; 7,541.5 CATCHER; 7,539.5 PACKER; 7,489.0 SBR; 7,466.0 SEAL ASSY; 7,459.0 LOCATOR; 7,458.0 GAS LIFT; 7,402.1 GAS LIFT; 6,975.2 GAS LIFT; 5,994.1 GAS LIFT; 4,678.0 SURFACE; 31.5-2,953.1 GAS LIFT; 2,833.4 NIPPLE; 498.7 CONDUCTOR; 30.0-80.0 HANGER; 27.0 KUP PROD KB-Grd (ft) 39.01 RR Date 7/24/1981 Other Elev… 1A-03 ... TD Act Btm (ftKB) 8,880.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292061500 Wellbore Status PROD Max Angle & MD Incl (°) 48.00 MD (ftKB) 3,600.00 WELLNAME WELLBORE1A-03 Annotation Last WO: End Date 9/6/2013 H2S (ppm) 45 Date 1/29/2019 Comment SSSV: NIPPLE Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,833.4 2,600.7 44.83 1 GAS LIFT GLV RK 1 1/2 1,243.0 3/24/2020 CAMCO MMG 0.188 4,678.0 3,855.7 46.06 2 GAS LIFT OV RK 1 1/2 0.0 3/23/2020 CAMCO MMG 0.250 5,994.1 4,781.8 45.50 3 GAS LIFT DMY RK 1 1/2 0.0 3/26/2018 CAMCO MMG 0.000 6,975.2 5,496.8 38.19 4 GAS LIFT DMY RK 1 1/2 0.0 6/2/2015 CAMCO MMG 0.000 7,402.1 5,835.8 37.99 5 GAS LIFT OPEN OPEN 1 1/2 0.0 9/16/2022 CAMCO MMG 0.000 7,672.7 6,050.5 37.43 6 PROD DMY RM 1 1/2 0.0 2/9/1997 CLSD 0.000 7,749.8 6,111.8 37.25 7 PROD DMY RM 1 1/2 0.0 6/22/2010 0.000 7,892.4 6,226.0 36.08 8 PROD DMY RM 1 1/2 0.0 1/17/2010 0.000 7,921.0 6,249.1 35.79 9 PROD DMY RM 1 1/2 0.0 1/17/2010 0.000 7,995.0 6,309.5 35.05 1 0 PROD DMY RM 1 1/2 0.0 4/27/2010 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,820.0 7,888.0 6,167.8 6,222.5 C-4, C-3, 1A-03 7/24/1981 12.0 IPERF 5" Vann Guns 7,820.0 7,888.0 6,167.8 6,222.5 C-2, 1A-03 5/10/1985 4.0 RPERF 120° Ph, 4" JumboJet II 7,920.0 7,922.0 6,248.4 6,250.0 C-2, 1A-03 5/5/1985 4.0 SQZ Squeezed 7,948.0 7,972.0 6,271.1 6,290.7 C-1, 1A-03 7/24/1981 12.0 IPERF 5" Vann Guns 7,948.0 7,972.0 6,271.1 6,290.7 C-1, 1A-03 5/10/1985 4.0 RPERF 120° Ph, 4" JumboJet II 8,108.0 8,110.0 6,402.5 6,404.1 UNIT B, 1A-03 5/5/1985 4.0 SQZ Squeezed 8,166.0 8,172.0 6,450.7 6,455.7 A-5, 1A-03 7/24/1981 12.0 IPERF 5" Vann Guns 8,178.0 8,210.0 6,460.7 6,487.5 A-4, 1A-03 7/17/1993 4.0 IPERF 180° Ph, 2.5" Titan Guns 8,180.0 8,214.0 6,462.4 6,490.9 A-4, 1A-03 7/24/1981 12.0 RPERF 5" Vann Guns Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,920.0 7,922.0 6,248.4 6,250.0 Cement 8,108.0 8,110.0 6,402.5 6,404.1 Cement 1A-03, 9/17/2022 5:51:38 PM Vertical schematic (actual) PRODUCTION; 28.9-8,863.0 FISH; 8,314.0 FISH; 8,270.0 RPERF; 8,180.0-8,214.0 IPERF; 8,178.0-8,210.0 IPERF; 8,166.0-8,172.0 SQZ; 8,108.0-8,110.0 Cement; 8,108.0 ftKB SOS; 8,046.2 PLUG; 8,034.4 NIPPLE; 8,034.4 SAND; 8,020.4 PACKER; 8,016.0 LOCATOR; 8,014.1 GAS LIFT; 7,995.0 RPERF; 7,948.0-7,972.0 IPERF; 7,948.0-7,972.0 GAS LIFT; 7,921.0 Cement; 7,920.0 ftKB SQZ; 7,920.0-7,922.0 PACKER; 7,907.8 GAS LIFT; 7,892.4 IPERF; 7,820.0-7,888.0 RPERF; 7,820.0-7,888.0 GAS LIFT; 7,749.8 GAS LIFT; 7,672.7 LEAK - PACKER; 7,634.0 PACKER; 7,633.1 SBR; 7,606.9 OVERSHOT; 7,589.8 TUBING PLUG; 7,542.0 NIPPLE; 7,541.5 CATCHER; 7,539.5 PACKER; 7,489.0 SBR; 7,466.0 SEAL ASSY; 7,459.0 LOCATOR; 7,458.0 GAS LIFT; 7,402.1 GAS LIFT; 6,975.2 GAS LIFT; 5,994.1 GAS LIFT; 4,678.0 SURFACE; 31.5-2,953.1 GAS LIFT; 2,833.4 NIPPLE; 498.7 CONDUCTOR; 30.0-80.0 HANGER; 27.0 KUP PROD 1A-03 ... WELLNAME WELLBORE1A-03 Imag ect Well History File Cover e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewal:Jle by direct inspection of the file. l ~ l- ~ ~ -~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable, by / large scanner /~ Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds NOTES: [] Other Project Proofing BY: ~OBIN VINCENT SHERYL MARIA WINDY DATE:~,~ ,(_.~ ~..._/S/ Scanning Preparation Production Scanning Stage 1 PAGE COUNT FROM SCANNED FLEE: t / ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES NO Stage2-IFNOINSTAGE1,PAGE(S)DISCREPANClESWEREFOU~:/ YES NO RESCANNEDBY~ BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: I$1 General Notes or Comments about this file: Quality Checked (do.e) 12/10102Rev3NOTScanned.wpd STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMARION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell 17 Plug Perforations r Perforate r Other r Alter Casing f Pull Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 181-088 • 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-20615-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25647 • 1A-03 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool . 11.Present Well Condition Summary: Total Depth measured 8880 feet Plugs(measured) 7631 true vertical 7059 feet Junk(measured) 8270, 8314 Effective Depth measured 8765 feet Packer(measured) 7489,7633, 7908, 8016 true vertical 6960 feet (true vertical) 5905,6019,6238,6327 Casing Length Size MD TVD Burst Collapse CONDUCTOR 50 16 80 80 SURFACE 2922 10.75 2953 2684 PRODUCTION 8834 7 8863 7044 R 4 '' ,x -n 4. d SCANNED 'j\t'' ` �. ?Gt i Perforation depth: Measured depth: 7820-7888,7948-7972, 8166-8172,8178-8210,8180-8214 O(+,a .. True Vertical Depth: 6168-6223,6271-6291,6451-6456,6461-6487,6462-6491 Tubing(size,grade,MD,and TVD) 3.5, L-80, 7481 MD,5898 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER FHL RETRIEVABLE PACKER @ 7489 MD and 5905 TVD PACKER-BAKER FHL PACKER @ 7633 MD and 6019 ND PACKER-BAKER FHL PACKER @ 7908 MD and 6238 ND PACKER-BAKER FB-1 PACKER @ 8016 MD and 6327 ND NIPPLE-CAMCO DS NIPPLE @ 499 MD and 499 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): none Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 274 885 2121 -- 154 Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development F7" Service r Stratigraphic r 16.Well Status after work: Oil P-• Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND r WAG r GINJ r j SUSP r SPLUG r 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: 313-400 Contact Brett Packer Cad 265-6845 Email J.Brett.Packer(a�conocophillips.com Printed Name Brett Packer Title Wells Engineer Signature . ' ._> ^-- L % Phone:265-6845 Date 9/Z lbt 3 Form 10-404 Revised 10/2012 1,1 r- /070171, Submit Original Only /a//57/ 3 SIOZ I 1 100 9vg -I a ,, KUP PROD i IA-03 Conoco`'hillips r�� .'Weil Attributes Max Angie eM ;~ � '' Alaska inc. °� 1,,y51 Wellbore API/UWI Field Name Wellbore Status lint/(°) MD(ftKB) Act Btm(ftKB) L.. ..1.uy,,4i: 500292061500 KUPARUK RIVER UNIT PROD 48.00 3,600.00 8,880.0 ••• Comment I H2S(ppm) 'Date Annotation 1 End Date KB-Grd(ft) 'Rig Release Date 1A-03,9/18/20139:59.10 AM SSSV:NIPPLE 120 8/24/2012 Last WO: 9/6/2013 39.011 7/24/1981 Vertical schematcfactua3 Annotation Depth(ftKB) End Date Annotation 'Last Mod By End Date -- -_---- .0 ---- Last Tag:SLM 8,170.0 6/16/2013 Rev Reason:WORKOVER 'Last ea 9/11/2013 HANGER,27.0 -„IIRI. 99 Casing Strings C g D r ption OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(!..Grade Top Thread �, u� CONDUCTOR 16 15.062 30.0 80.0 80.0 65.00 H-40 WELDED "� nen Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(!..Grade Top Thread SURFACE 103/4 9,950 31.5 2,953.1 2,683.8 45.50 K-55 BTC .AAA CONDUCTOR,30.0-80.0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread PRODUCTION 7 6.276 28.9 8,8610 7,044.2 26.00 K-55 BTC NIPPLE;498.7 Tubing Strings Tubing Description !String a...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt lb/ft Grade Top Connection I TUBING WO 2013 I g 31/21 2.9921 27.01 748071 p (5,897.91 ( 9301 L-80 1EUE 8rd Mod GAS LIFT,2,833.4 Completion Details Nominal ID Top(ftKB) Top(ND)(ftK8) Top Inel(°) Item Des Com (in) 27.0 27.0 0.00 HANGER FMC TUBING HANGER 2.992 498.7 498.7 0.00 NIPPLE CAMCO DS NIPPLE 2.875 SURFACE;315-2.953.1 7,458.0 5,880.0 37.71 LOCATOR BAKER LOCATOR w/SEAL ASSY COLLAR 2.990 7,459.0 5,880.7 37.71 SEAL ASSY BAKER SEAL ASSY 2.990 Tubing Description 'String Ma...1ID(in) 1 Top(ftKB) 'Set Depth(R..1 Set Depth(ND)(...I Wt OWft) Grade 'Top Connection STACKED PACKER 3 1/2 2.992 7,466.01 7,597.2 5,990.5 9.30 L-80 EUE-8rd Mod 4 Completion Details GAS LIFT;4.678.0 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Inc!(°) Item Des Corn (in) 7,466.0 5,886.3 37.67 SBR BAKER 80-40"PBR"POLISH BORE RECEPTACLE 2.980 GAS LIFT,5,994.1 7,489.0 5,904.5 37.55 PACKER BAKER FHL RETRUEVABLE PACKER 2.910 M 7,541.5 5,946.2 37.40 NIPPLE CAMCO DS NIPPLE w/RHC PLUG 2.812 111 7,589,8 5,984.6 37.28 OVERSHOT BAKER POORBOY OVERSHOT 2.970 GAB LIFT,6,975.2 It Tubing Description I String Ma 2ID(in) TUBING WO 1985 31/ 29921 To (RK5)9 1.41 Set Depth 4(7ft.0 Set Depth(ND) (lb/ft) 'Grade Top Connection 6352 9.20 J-55 BTC Completion Details GAS LIFT;7,4021 llC Nominal ID I I Top(ftKB) Top(ND)(ftKB) Top Intl(°) Item Des CoCorn (!n) II 7,606.9 5,998.2 37.27 SBR BAKER SBR 2.810 LOCATOR;7,458.0 I IF 7,633.1 6,019.1 37.33 PACKER BAKER FHL PACKER 3.000 SEAL ASSY;7,459 0, 7,907.8 6,238,4 35.92 PACKER BAKER FHL PACKER 3.000 SBR,7,466.0 - 7,932.1 6,2582 35.68 BLAST RING 2.867 PACKER,7,4890 i 8,014.2 6,325.2 34.89 LOCATOR BAKER LOCATOR 3.000 II i 8,016.0 6,326.7 34.88 PACKER BAKER FB-1 PACKER W/5"SEAL BORE EXT 4.000 8,034.4 6,341.8 34.74 NIPPLE CAMCO D NIPPLE NO GO 2.750 NIPPLE;7,541 5 z: ri 8,046.2 6151,5 34.65 SOS CAMCO SHEAR OUT SUB.-ELMD @ 8047'ON SWS 2.992 a PPROF 5/17/200"' 'Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) OVERSHOT,7,589.8 I� 'I Top(ND) Top not IF Top(ftKB) (ftKB) (°( Des Corn Run Date ID(in) SBR,7,606.9 7,631.0 6,017.4 37.33 PLUG BAKER 2.55"COMPOSITE PLUG 8/8/2013 0.000 PACKER'7,633.1 '" 8,270.0 6,538.0 32.48 FISH Retainer Pin f/GU Adapter Lost Downhole 12/1/1996 12/1/1996 0.000 GAS LIFT;7,672.7 4 8,314.0 6,575.2 32.22 FISH 5"Vann Gun 450'Long 7/24/1981 7/24/1981 0.000 0 4 Perforations&Slots gi Shot GAS LIFT;7,749.8- a: Dens i Top(ND) Btm(ND) (shots/ • Top IRKS) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn 7,820.0 7,8880 6,167.8 6,222.5 C-2,1A-03 5/10/1985 4.0 RPERF '120 deg.Ph,4" JumboJet II RPERF;7,820.0-7,888.0 IPERF;7,820.0-7,888.0 7,820.0 7,888.0 6,167.8 6,222.5 C-4,C-3,1A- 7/24/1981 12.0 IPERF 5"Vann Guns 03 7,920.0 7,922.0 6,248.4 6,250.0'C-2,1A-03 5/5/1985 4.0 SQZ Squeezed GAS LIFT,7,892.4 l 7,948.0 7,972.0 6,271.1 6,290.7 C-1,1A-03 5/10/1985 4.0 RPERF 120 deg.Ph,4" PACKER;7,907.8 JumboJet II Cement,7.920.0 7,948.0 7,972.0 6,271.1 6,290.7 C-1,1A-03 7/24/1981 12.0 IPERF 5"Vann Guns SQZ,7920.0-7,922.0-�� ✓, S! 1� 8,108.0 8,110.0 6,402.5 6,404.1 UNIT B,1A- 5/5/1985 4.0 SQZ Squeezed GAS LIFT;7,921.0 03 II 8,166.0 8,172.0 6,450.7 6,455.7 A-5,1A-03 7/24/1981 12.0 IPERF 5"Vann Guns RPERF;7,948.0-7,972.0 - IPERF;7,948.0-7,972.0 8,178.0 8,210.0 6,460.7 6,487.5 A-4,1A-03 7/17/1993 4.0 IPERF 180 deg.Ph,2.5"Titan _ Guns l 8,180.0 8,214.0 6,462.4 64909 A-4,1A-03 7/24/1981 120 RPERF 5"Vann Guns GAS LIFT;7,995.0 LOCATOR 8,014.1 Cement Squeezes PACKER 8,0160 r Top(ND) Blot(ND) Top(ftKB) Btm(ftKB) (ftKB) IRKS) Des Start Date Corn 7,920.0 7,922.0 6,248.4 6,250.0 Cement Squeeze 5/6/1985 NIPPLE,8,034.4 II 8,108.0 8,110,0 6,402.5 6,404.1 Cement Squeeze 5/6/1985 SOS;8.046.2 Cement,8,108.0 Mandrel Details SQZ,8,108.0$,1100-y' ✓ St at! C IPERF;8,166.0-8,172.0- on Top(ND) Valve Latch Port Size TRO Run o No Top(ftKB) (ftKB) Make Model OD(!n) Sery Type Type (in) (psi) Run Date m 6 7,672.7 6,050.5 OTIS LBX 1 1/2 PROD DMY RM 0.000 0.0 2/9/1997 IPERF;8,1780-8,210.0 Closed RPERF;8,1600$.214.0 7 77498 6,111.8 OTIS LBX 11/2 PROD DMY RM 0.000 0.0 6/22/2010 See FISH:8,270.0 * Note 8 7,892.4 6,226.0 OTIS LBX 11/2 PROD DMY RM 0.000 0.0 1/17/2010 FISH,8.314.0 0 9 7,921.0 6,2411 OTIS LBX 11/2 PROD DMY RM 0.000 0.0 1/17/2010 1 7,995.0 6,309.5 OTIS LBX 1 1/2 PROD DMY RM 0.000 0.0 4/27/2010 0 PRODUCTION;28.9-8,863.0- KUP PROD • IA-03 ConocooPhillips 1 Alaska,Inc. 1A-03.9/18/20139'.59'.11 AM Vert ical schematic(actual) 1 HANGER,27.0 y I.�E Mandrel Details �41� 111 st en I�`R 14 .,°° p( ) To ND Valve Latch Port Size TRO Run 11111111 Pill No Top(kKB) (kKB) Make Model 00 Seev Type Type (in) (psi) Run Date m .nnn CONDUCTOR;30.0-800• 1 2,833.4 2,600.7 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/5/2013 2 4,678.0 3,855.7 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/5/2013 NIPPLE;498.7 3 5,994.1 4,781.8 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/5/2013 4 6,975.2 5,496.8 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 9/5/2013 !i II 5 7,402.1 5,835.8 CAMCO MMG 1 1/2 GAS LIFT SOV RKP 0.000 2,000.0 9/5/2013 DCR-1 GAS LIFT;2,833.4 IR II Notes:General&Safety End Date Annotation 5/11/1985 NOTE:WORKOVER(remaining tubing completion @ wireline measurement) 1/16/1997 NOTE:C 3,4 Sand:Open.C 1 Sand:Open.Tubing Tail ELMD SURFACE;31.5-2,953.1 5/172000 NOTE:Suspected leak at upper Packer.Broken latch DMY valve @4910'. 1/6/2002 NOTE:WAIVERED WELL-IA x OA communication. 5/7/2006 NOTE:LEAKS DETECTED @ 7644'AND 7783' a 7/29/2010 NOTE:View Schematic w/Alaska Schematic9.0(2 pages) GAS LIFT;4,678.0 it GAS LIFT'5994.1 II GAS LIFT;6,975.2 M: B GAS LIFT;7,402.1 -. r. a a LOCATOR.7.458.0 SEAL ASSY;7,459.0 SBR;7,466.0 1, 1 PACKER;7,489.0 B NIPPLE;7,541.5 ,— OVERSHOT;7,589.8 I SBR;7,606.9 PACKER;7,633.1 GAS LIFT;7,672.7 11 + GAS LIFT;7,749.8 RPERF;7,820.0.7,888.0 IPERF;7,820.0.7,888.0. I -_ GAS LIFT;7,892.4—i., PACKER;7,907.8 Cement;7,920.0 SO2;7,920.0-7,922,0—� GAS LIFT;7,921.0 RPERF;7,948.0-7,972.0 _ '— IPERF;7,948.0.7,972.0 -- GAS LIFT;7,995.0 ' LOCATOR;8,014.1 PACKER;8,016.0 i I_. NIPPLE;8,034.4 It SOS;8,046.2 Cement;8,108.0 SO2;8,108.0-8,110.0—El 11g F IPERF;8,166.0.8,172.0 IPERF;8,178.0.8210.0 RPERF;8,180.0-0,214.0. FISH;0,270.0ip FISH;8,314.0 PRODUCTION;289-8,863.0—At A 4603 Pre-Rig Well Work Summary DATE SUMMARY • 6/16/2013 DRIFT w/8'- 1875", 5'-2.5"S/D 120' ABLE TO PASS TO 8170'SLM, DRIFT w/3.5"OK-1 TO STA 15 @ 8029' RKB, DRIFT w/6'- 1.875"STEM, 3'-2.24"TO 8170' SLM (EST 13' FILL IN BOTTOM PERFS)WILL RETURN FOR SBHP.IN PROGRESS 6/19/2013 MEASURED BHP @ 8169' RKB: 2134 psi. COMPLETE. 6/20/2013 C SAND SCALE SQUEEZE. PUMPED 50 BBLS SW AHEAD OF TREATMENT. PUMPED 25 BBLS OF SEAWATER PRE-FLUSH CONTAINING 80 GALLONS OF WAW-5206. PUMPED 144 BBLS OF SEAWATER CONTAINING 790 GALLONS OF SCW-4004. PUMPED 390 BBLS SW OVERDISPLACEMENT.PUMPED 20 BBLS DIESEL FP TUBING. 7/31/2013 DISPLACED TBG WITH 100 BBLS SLICK DIESEL; RAN 2.55" BAKER COMPOSITE PLUG DRIFT& UNABLE TO PASS 116'SLM; RAN 2.52" INTERWELL PLUG DRIFT& UNABLE TO PASS 109'SLM; RAN 1.80" INTERWELL PLUG DRIFT DOWN TO 8000' SLM NO PROBLEMS. BRUSHED& FLUSHED TBG DOWN TO 8035' RKB; RE-RAN DRIFTS W/2.52" DRIFT UNABLE TO PASS 109'SLM, BUT ABLE TO WORK 2.55" BAKER COMPOSITE DRIFT THROUGH TIGHT SPOT @ 116'SLM WITH LIGHT JARRING TO PASS& DRIFT TO 8035' RKB. IN PROGRESS. 8/1/2013 .DRIFT THROUGH TIGHT SPOTS W/2.64" BARBELL&2.72" BARBELL DRIFTS W/NO PROBLEM. UNABLE TO PASS 109'SLM W/2.79" DMY WRP;ABLE TO PASS TIGHT SPOTS W/MODERATE JARRING W/2.69 DMY WRP. RAN BROACHES THROUGH TIGHT SPOTS FROM 100& 130'SLM (LIGHT SCALE & METAL SHAVINGS ON BROACH). W/LIGHT JARRING ABLE TO DRIFT PASS TIGHT SPOTS W/2.55 BAKER COMPOSITE PLUG DRIFT. IN PROGRESS. 8/2/2013 PULLED OV&SET DV @ 6704' RKB. PULLED GLV @ 5602' RKB. IN PROGRESS. 8/3/2013 SET DV @ 5602' RKB; PULLED GLV&SET DV @ 3758' RKB. IN PROGRESS. 8/4/2013 PULLED GLV&SET DV @ 1907' RKB (GOOD DDT ON IA); ATTEMPTED TO PULL DV FROM 7565' RKB. IN PROGRESS. 8/5/2013 PULLED DV @ 7565' RKB. RAN BARBELL ASSY's(2.64"CENT&2.61" BROACH) THROUGH TIGHT SPOTS FROM 90'TO 300' SLM; DRIFTED W/2.55" BAKER COMPOSITE PLUG DRIFT TO 8000'SLM (HAVE TO JAR MODERATELY THROUGH TIGHT SPOTS FROM 110'TO 130'SLM); UNABLE TO WORK 2.61" &2.70" BROACH BARBELL ASSY THROUGH 115'SLM (SPANGS BIND UP). RAN 9'x 1.75" STEM & 5'x 2.5" BAILER THROUGH TIGHT SPOTS (LIGHT JARRING REQUIRED). READY FOR E-LINE (PENDING PROCEDURE). 8/8/2013 SET BAKER 2.55"COMPOSITE BRIDGE PLUG @ 7630'. PLUG SETTING CORRELATED TO HALLIBURTON MULTI-FINGER CALIPER LOG DATED 1-8-2013. EXPERIENCED TENSION BOBBLES WHILE RUNNING IN HOLE FROM 50'-250' BUT TOOLSTRING DID NOT SIT DOWN. LRS PUMPED 70 BBLS OF SLICK DIESEL DOWN TUBING. 8/10/2013 (PRE RWO)CMIT TXIA(PASSED). 8/12/2013 (PRE RWO) C DDT T X IA(IN PROGRESS). 8/13/2013 (PRE RWO) MONITOR WHPS, T FL, IA FL. 8/14/2013 (PRE-RWO): T&IA DDT TO 0 PSI. IN PROGRESS. 8/15/2013 (PRE-RWO): T& IA DDT- FAILED DUE TO CONTINUAL SLOW BUILD UP. 8/18/2013 PRE RWO, FUNCTION TEST LDS. ALL 8 IC LDS SEIZED INSTALLED LUCKIES. ALL OC LDS NORMAL. 8/19/2013 (PRE-RWO): BLED DOWN OA 8/22/2013 (PRE-RWO): BLEED IA&OA TO 0 PSI-IN PROGRESS. 8/23/2013 (PRE-RWO): BLEED IA&OA TO 0 PSI. (IA INCREASED 34 PSI AND OA INCREASED 37 PSI OVERNIGHT). BLED IA TO 0+ IN 7 HOURS. BLED OA TO 0+ IN 3 HOURS. T/I/O/OO= SI/1/3/0 ConocoPhillips Time Log & Summary WelMewWeb Reporting Report I �s7H'tkPithiPb�h�2in �d�Tx Well Name: 1A-03 Rig Name: DOYON 141 Job Type: RECOMPLETION Rig Accept: 8/27/2013 1:00:00 PM Rig Release: 9/7/2013 12:00:00 AM Time Loge �"'l Pli f 111 1111111 bate From To.._. Dur Pli S yep li .beoth Phase bode Subcode' Comm ei, 41,7 08/26/2013 24 hr Summary RDMO 10 pad. Move complexes and sub base to 1A pad. Spot sub base over well. 18:00 00:00 6.00 MIRU MOVE MOB P Move complexes and sub base to 1A pad. Spot sub base over well. 08/27/2013 Moved rig f/1Q-11 to 1A-03. Spot rig and R/U.Accept rig @ 13:00 hours.Take on fluid and circulate out freeze protect,set BPV. 00:00 05:00 5.00 MIRU MOVE MOB P Mobilize sub and pipe sheds to 1A pad. 05:00 06:30 1.50 MIRU MOVE MOB P Spot sub base over 1A-03. 06:30 07:30 1.00 MIRU MOVE MOB P Level pad and lay rig mats. 07:30 10:00 2.50 MIRU MOVE MOB P Spot pits, pump room, motor room, boiler room, pipe sheds and rockwasher. 10:00 13:00 3.00 MIRU MOVE RURD P PJSM, hook up electrical,steam, water and fuel lines.Work on rig acceptance checklist. Rig accepted @ 13:00 hours. 13:00 15:00 2.00 MIRU WHDBO RURD P Take on fluid into mud pit.8.5 ppg slick seawater. R/U scaffolding in cellar and R/U circ lines. 15:00 16:30 1.50 MIRU WHDBO RURD P PJSM, P/U lubricator and pressure test to 250/2500 PSI. Pull BPV. 16:30 17:45 1.25 MIRU WHDBO RURD P R/U tiger tank and hard line. 17:45 20:45 3.00 MIRU WHDBO DISP P PJSM,flood lines and pressure test to 250/2500 PSI. Reverse circulate out freeze protect. Pumped 320 bbls of 8.5 ppg slick seawater @ 2.5 BPM. ICP=400 PSI and FCP=250 PSI. Shut down when 8.5 ppg sea water was observed at tiger tank. 20:45 21:00 0.25 MIRU WHDBO OWFF P OWFF,slight flow. Decision made to CBU to ensure well in balance. 21:00 22:00 1.00 MIRU WHDBOCIRC P CBU @ 3 BPM=250 PSI. 22:00 22:30 0.50 MIRU WHDBO OWFF P OWFF, blow down circulating lines. 22:30 23:15 0.75 MIRU WHDBO SEQP P Install BPV and test to 1000 PSI. 23:15 00:00 0.75 MIRU WHDBO RURD P PJSM, R/D scaffolding in cellar. 08/28/2013 N/D tree, install blanking plug and N/U BOPE.Test BOPE to 250/3000 PSI,witness waived by AOGCC rep Bob Noble. M/U landing joint and attempt to pull hanger,pull up to 80%of tbg, nogo. R/U E-line to cut tbg. 00:00 01:00 1.00 MIRU WHDBO NUND P PJSM, N/D tree. 01:00 03:00 2.00 MIRU WHDBO NUND P N/U adapter flange and install FMC blanking plug. Pagel of 9 Ttme Logs„M :" •4 tll,, 111141,1, ■li i ild Date From To De36th E,Depth Phase Code Subcrde T Co Tent 11' tl 03:00 04:30 1.50 MIRU WHDBO NUND P PJSM, N/U BOPE. 04:30 06:30 2.00 MIRU WHDBO NUND P Have welder add 8"of length to the riser. SIMOPS, R/U BOP test equipment and hold PJSM on testing BOPE. 06:30 07:30 1.00 MIRU WHDBO NUND P Install riser and make up XO to test joint. Fill stack and choke manifold with H2O. 07:30 11:00 3.50 MIRU WHDBO BOPE P Test BOPE to 250/3000 PSI w/ 3-1/2"and 4"test joints.Test#1: Top pipe rams, manual kill, CV 1,12,13 and 14. Test#2: Upper IBOP, NCR kill, CV 9 and 11.Test #3: Lower IBOP, CV 5,8 and 10. Test#4: Dart valve, CV 4,6 and 7. Test#5: Floor valve and CV 2.Test #6: HCR choke,4"kill line Demco. Test#7: Manual choke. Test#8: Annular preventer. Test#9: Blind rams and CV#3.Accumulator test: System pressure=3000 PSI,200 PSI attained after 35 sec,full pressure attained after 172 sec. Five bottle nitrogen avg=2050 PSI. Witness of BOP test waived by AOGCC rep Bob Noble. Unable to test lower rams w/3-1/2"test joint due to length of tool joint and blanking plug height. 11:00 12:00 1.00 MIRU WHDBO RURD P R/D BOP test equipment,blow down choke line, kill line and choke manifold. Suck all fluid out of BOP stack. Clean and clear rig floor. 12:00 12:45 0.75 COMPZ RPCOM SVRG P Hold PJSM and fill out HRW. CIO swivel packing and pressure test to 250/3000 PSI. 12:45 13:30 0.75 COMPZ RPCOM SEQP P PJSM, pull BPV as per FMC rep. 13:30 14:00 0.50 COMPZ RPCOM THGR P Pick up XO and make up to joint of drill pipe.XO nogo'd on hanger profile. Mobilize one joint of 3-1/2" IBT tubing from KCS warehouse. 14:00 15:00 1.00 COMPZ RPCOM PULD P P/U casing tools from beaver slide and R/U casing tools. 15:00 15:45 0.75 COMPZ RPCOM PULD P P/U 3-1/2"IBT landing joint and M/U to top drive. 15:45 17:00 1.25 0 7,630 COMPZ RPCOM RTWH P PJSM, BOLD's.The tubing shot up 8"and took 15K off block weight. Attempt to pull hanger to floor, P/U 149K,w/35K block weight. Cont. working tubing pull 149K with no success. Decision made to call out E-line. 17:00 19:30 2.50 7,630 7,630 COMPZ RPCOM CUTP P Cont to work tubing, pulling 149K while waiting on E-line. 19:30 23:00 3.50 7,630 7,630 COMPZ RPCOM RURD P Spot HES E-line truck, mobilize 2" RCT from deadhorse. SIMOPS, L/D control line spooler and power tongs. Page 24A 9 • 1Ji- -'_' w"'"viii " hVWpa Time Logs Date From Abut S. Death sE.Oep h Phase bode ISubcode ` i,Conmrn Oti s "VIIli gill' d 23:00 00:00 1.00 7,630 7,630 COMPZ RPCOM RURD P PJSM, Pull tubing string in 20K tention, 120K on weight indictor.R/U HES E-line. 38/29/2013 RIH w/RCT cutter on E-line,cut tbg @ 7595'. POOH and R/D E-tine. Pull hanger to floor and CBU. POOH L/D 3-1/2"tbg. M/U mule shoe and RIH on 4"DP to set storm packer. 00:00 01:15 1.25 7,630 7,630 COMPZ RPCOM RURD P PJSM, P/U and R/U HES E-line as per Halliburton rep. 01:15 04:45 3.50 7,630 7,630 COMPZ RPCOM ELOG P RIH w/string shot,fire string shot @ 7595'. POOH and C/O E-line BHA. 04:45 07:00 2.25 7,630 7,630 COMPZ RPCOM ELOG P RIH with RCT cutter on E-line,cut tbg @ 7595'. Log up and observe 4' of movement on CCL after cutting. POOH with E-line. 07:00 08:00 1.00 7,630 7,630 COMPZ RPCOM RURD P R/D HES E-line as per Halliburton rep. 08:00 08:30 0.50 7,630 7,580 COMPZ RPCOM PULL P Pull hanger to rig floor, P/U=100K. Disconnect control line. 08:30 09:15 0.75 7,580 7,580 COMPZ RPCOM CIRC P R/U and circulate surface to surface @ 9 BPM=1000 PSI, 60%flow. 09:15 10:00 0.75 7,580 7,580 COMPZ RPCOM OWFF P OWFF,static. L/D 1 joint and blow down top drive. 10:00 12:15 2.25 7,580 6,544 COMPZ RPCOM PULL P POOH L/D 3-1/2"tbg to SSSV @ joint#58. Observed 10-12K over pull as SSSV passed—400'MD.The control line was broken @ the SSSV, recovered 29 SS bands,good hole fill. R/D Camco spooling unit. 12:15 19:30 7.25 6,544 0 COMPZ RPCOM PULL P Cont.to L/D 3-1/2"tbg,9 GLMS, 1 SSSV,248 joints, 1 cut joint( 15.83') and 29 SS bands.Total length= 7591.96' 19:30 20:00 0.50 0 0 COMPZ WELLPF PULD P L/D tbg tools, clean and clear rig floor. 20:00 20:30 0.50 0 0 COMPZ WHDBO RURD P PJSM, R/U to test lower pipe rams with 3-1/2"test joint. 20:30 21:15 0.75 0 0 COMPZ WHDBO BOPE P PJSM,Test lower pipe rams to 250 PSI low, pressure up to 3000 PSI, leaking out IA. Pull test pull and inspect, good. Run back in and pressure up to 3000 PSI, leaking out IA. Inspect tbg hanger, hanger showed damage. Based on the condition of the tbg hanger the conclusion was made the tbg spool was also damaged when the hanger lock downs where removed and the string jumped uphole 8".Will test lower pipe rams with 3-1/2"test joint after new tbg spool is installed before running any 3-1/2"down hole. 21:15 00:00 2.75 0 527 COMPZ WELLPF TRIP P PJSM, RIH picking up 4"drill pipe. Begin taking 2-4K weight @ 150'. Kelly up and rotate down @ 30 RPM w/4 K Tq.Actual displacement= 3.06 bbls, Calculated displacement= 3.06 bbls. Page °of:9 Y X714 K tl 4, .0 _ I P ' T me Logs _ I I1li[1 r 'Date" f ;From loo °`= Dur " S.IDeoth E Deoth Phase Gode Subcoce T Commei tai". 6l°j 9ii. ° I 08/30/2013 24 hr Summary RIH P/U DP to 2093'. Make up strom packer and set 62'below wellhead and test to 1500 PSI. Bleed pressure off OA and N/D BOPE. Observe pressure building in OA, cont bleeding gas from OA. 00:00 05:15 5.25 527 2,093 COMPZ WELLPF TRIP P M, " pipe to 2093PJS '(22 Cont standsto )P/U Tight 4 drill hole, kelly up e j R 's, 3-4K very Tq.oint P/U-and 95KROT, S/0-40@ 40 ,35K PMot UBE pill around block weight.backsideSp, pill SAFEL reduced rotary torque and added 5K Rot weight. 05:15 06:15 1.00 2,093 62 COMPZ WELLPF PACK P P/U strom packer and M/U: Pick up 3 singles and RIH.Set storm packer as per Baker rep.Top of packer 62' below wellhead. 06:15 06:45 0.50 62 62 COMPZ WELLPF PRTS P R/U and test strom packer to 1500 PSI for 10 min on chart,good. 06:45 07:15 0.50 COMPZ WELLPF OTHR P Blow down choke and kill line. SIMOPS, OA pressure 140 PSI, bleed off pressure. 07:15 08:15 1.00 COMPZ WELLPF NUND P PJSM, N/D BOPE. 08:15 08:30 0.25 COMPZ WELLPF SFTY P Hold PJSM on R/U Hydratight. 08:30 12:00 3.50 COMPZ WELLPF DGAS P Mobilize Hydratight tools to cellar. All gas was bleed of OA.While OA was shut in, pressure build back to 20 PSI. Open OA back and cont to bleed gas to bleed tank. 12:00 00:00 12.00 COMPZ WELLPF DGAS P PJSM, Cont bleeding gas off OA to tiger slows A slowing down.tank. Ga SIMOPSflow from, scrub Ois and paint wind wall, paint mud pumps. C/O water pump#1,paint rockwasher, pipe shed and pits. 38/31/2013 Bleed gas off OA,slowing down.Work in painting and cleaning rig. 00:00 12:00 12.00 COMPZ WELLPF DGAS P PJSM, Co SIMOPS,scrub n bleeding wind walls gas and off OA.paint in pits, pumps,floor and rockwasher. Stage 2-7/8"X 5"VBR in cellar. 12:00 00:00 12.00 COMPZ WELLPF DGAS P PJSM,Con bleeding gas off OA. SIMOPS,send 2-7/8"X 5"VBR to shop Cled walls for re-build.and centrifugal an room.and scrub wind Pakn w pintall ew int belts in roc ad guards asher on and ts.#1 water pump. Install 2-7/8"X 5"VBR in lower rams. 39/01/2013 Bleed gas of OA. Made fluid level shot,—300'. Pumped 10.6 bbls of diesel down OA,gas stopped. R/U Hydratight, BOLDS, one snapped off. Mobilize mag drill to rig. 00:00 06:00 6.00 COMPZ WELLPF DGAS P e and paint Cont.rigbl,work eding in off centrifugal OA. Scrub room, pits, pumps and pipe shed.Turn in SAA/RAA log and screen usage. 06:00 12:45 6.75 COMPZ WELLPF DGAS P Cont. bleeding off OA. Scrub and paint rig. Preform fluid shot @ 8:00 hrs,fluid level 300'below wellhead. Page 4 tf,9 ,Time,Logs_ r � 4± , � y1,Y1111 � baler From To ry ,Dur =©eoth E.Depth Phase Code Subcode T` i Comment "F IP 12:45 15:45 3.00 COMPZ WELLPF OTHR P PJSM, R/U LRS and pressure test lines to 250/2000 PSI. Pump down OA @ 1/4 bbl per minute,then slow rate to 1/8 bbl per minute, ICP-40 PSI, FCP=50 PSI. Pumped a total of 10.6 bbls down OA,bleed gas off or 15 min then gas stopped. 15:45 17:15 1.50 COMPZ WELLPF NUND P PJSM, remove tbg spool, install spacer bushing and re-install tbg spool. 17:15 20:45 3.50 COMPZ WELLPF RTWH P PJSM, R/U Hydratight on tbg spool and apply 200K compression on 7" casing hanger until it relaxed. Loosen gland nuts and BOLDs. Three lock downs would not back off. Cont to work on the lock downs, able to remove two.The last lock down snapped at the pin.Mobilize crew to drill out the last lock down. 20:45 00:00 3.25 COMPZ WELLPF RTWH P Personal to drill lock down will not be able to come to the rig until tomorrow. Cont to paint and scrub rig.Work on MP2s. 39/02/2013 Mobilize drill to rig. Drill out lock down screw,grow 7"casing with Hydratight.Total growth 26-1/4". 00:00 12:00 12.00 COMPZ WELLPF RTWH P PJSM, mobilize drill to rig to drill out lock down screw. Paint and scrub rig,work in MP2s. Repair shaker bed and trough on#1 shaker. 12:00 13:45 1.75 COMPZ WELLPF RTWH P PJSM, cont to paint.Paint iron roughneck,stairs and hand rails. Weld in mud pits, remove Willis choke and rebuild in shop and install. 13:45 17:00 3.25 COMPZ WELLPF RTWH P Hold PJSM with Cameron. Drill out lock down screw as per Cameron rep. 17:00 18:00 1.00 COMPZ WELLPF RTWH P Change out damaged blades on drill bit. 18:00 21:30 3.50 COMPZ WELLPF RTWH P Cont to drill out lock downs,after drilling out lock down the casing jumped up. Pressure on Hydratight jacks went from 10,000 PSI to 19,000 PSI=300K down. 21:30 22:00 0.50 COMPZ WELLPF RURD P R/D Camron equipment. 22:00 22:15 0.25 COMPZ WELLPF SFTY P Hold PJSM with PESI and rig crew on growing casing with Hydratight. 22:15 00:00 1.75 COMPZ WELLPF RTWH P Grow 7"casing using 1-1/8" Hydratight jacks, 16-1/2". 39/03/2013 Grow and stretch 7"casing, cut 59.25"total. Install packoff and tubing spool, N/U and test BOPE to 250/3000 psi. 00:00 01:00 1.00 2,077 2,077 COMPZ WHDBO CUTP P PJSM-Continue growing casing w/ Hydratight, casing grew a total of 26.25". 01:00 01:30 0.50 2,077 2,077 COMPZ WHDBO SEQP P FMC Rep prepare wellhead, remove tubing head and packoffs. Page aof9 it iu gs �. �rW Ar Time Lo ¢ ' ' w. of 9d� i� id�i Fa i e pink ila! i i i 6 : � i�iai t Date'' mmoFrorri 'o Dur .. §depth E.teptjr Phase Code Su`ticode T .Corrimar►tg .; 401,1 10 01:30 02:00 0.50 2,077 2,077 COMPZ WHDBO CUTP P PJSM-M/U Spear,spear 7"casing and put in 200k tension,stretch casing additional 33". 02:00 03:00 1.00 2,077 2,077 COMPZ WHDBO CUTP P Install 7"slips,slack off&release spear, laydown spear. 03:00 05:00 2.00 2,077 2,077 COMPZ WHDBO CUTP P PJSM-Rigup Sawzall and rough cut 7"casing. R/U WACHS cutter and cut/bevel casing.Total casing cut 59.25". 05:00 05:30 0.50 2,077 2,077 COMPZ WHDBO SEQP P Install 7"Packoff 05:30 07:00 1.50 2,077 2,077 COMPZ WHDBO SEQP P Dress casing stub, N/U tubing spool. 07:00 11:00 4.00 2,077 2,077 COMPZ WHDBO NUND P PJSM-N/U BOPE, body test 250/3000 psi for 10 minutes. Continue N/U BOPE. Open upper ram doors and inspect rams. 11:00 12:00 1.00 2,077 2,077 COMPZ WHDBO RURD P R/U Test equipment,flood stack. 12:00 12:45 0.75 2,077 2,077 COMPZ WHDBO BOPE P PJSM-R/U to test BOPE 12:45 15:00 2.25 2,077 2,077 COMPZ WHDBO BOPE P PJSM and test BOPE w/3-1/2"and 4"test jts to 250/3000 psi for 5 min each.#1 Valve 1,12,13,14. (Valve 13 failed, C/O bonnet)Re-test good. 15:00 19:45 4.75 2,077 2,077 COMPZ WHDBO BOPE P #2 Valves 9& 11,#3 Upper IBOP, Valves 5,8 and 10,#4 Valves 4,6,7,Lower IBOP.(SIMOPS-Open doors, C/O top ram seals and C/O test plug. 19:45 00:00 4.25 2,077 2,077 COMPZ WHDBO BOPE P #5 Dart Valve&Valve 2, Manual Kill, #6 HCR Choke, HCR Kill, Floor Valve,#7 Manual Choke Valve,4" Demco Kill line valve,#8 Annular preventer,#9 Lower pipe rams,#10 Blind rams,valve 3.Accumulator system pressure 3000 psi, pressure after closing-1700 psi,200 psi attained-40 sec,full pressure attained-200 sec, N2 bottle avg-2000 psi. AOGCC-Jeff Jones waived witness of test. 39/04/2013 Retrieve and UD Storm Packer, P/U scraper assy, RIH, CBU and POOH, L/D. P/U string mill assy, RIH and reverse circulate clean. 00:00 01:30 1.50 2,077 2,077 COMPZ WHDBO RURD P PJSM-Pull test plug,set wear bushing, rig down test equipment. Blow down choke and kill lines. 01:30 02:45 1.25 2,077 1,970 COMPZ WELLPF PULD P PJSM-M/U Storm Packer retrieving tool, RIH and engage Storm Packer. Retrieve and L/D same. P/U=65k, S/O=64k. 02:45 04:00 1.25 1,970 0 COMPZ WELLPF TRIP P Monitor well, POOH rack back DP- P/U 60k.Actual Fill=13.2 bbl, Calc Fill=12.4 bbl. 04:00 04:30 0.50 0 0 COMPZ WELLPF RURD P Monitor well static, P/U Baker tools f/Beaverslide. 04:30 07:15 2.75 0 339 COMPZ WELLPF PULD P PJSM-M/U BHA V 339'MD. Page 6 of • Time Logs1'` ll� i�i�i� ii sunbOrIrr' Date From To Dur S.Death E.Depth1 Phase Code '''i"Subcode Tom"o emmei� "w T' 9i�i i ' 07:15 12:00 4.75 339 5,553 COMPZ WELLPF TRIP P RIH to 2521'with pipe from derrick, continue single in to 5553'MD. P/U=112k, S/0=88k no snags. Actual Disp=35.9 bbl, Calc Disp=34.5 bbl. 12:00 13:30 1.50 5,553 7,579 COMPZ WELLPF TRIP P PJSM-Continue singling in hole f/ 5553'MD to 7579'MD. P/U=140k, S/0=110k. 13:30 13:45 0.25 7,579 7,612 COMPZ WELLPF CIRC P Pump 5 bpm @ 450 psi,wash down f/7579't/7612'MD tagged up and set down 5k. Confirmed top of tubing cut @ 7600'DP MD D141 RKB with pump pressure. (12'Washpipe) 13:45 14:30 0.75 7,612 7,599 COMPZ WELLPF CIRC P CBU @ 7599'MD, 11 bpm, 1475 psi. B/D Topdrive. SPR's @ 7599'MD,6400'TVD.8.5 ppg #1- 30 spm=170 psi,40 spm=290 psi. #2-30 spm= 170 psi,40 spm=280 psi. 14:30 14:45 0.25 7,599 7,599 COMPZ WELLPF OWFF P PJSM, HRW on POOH(SIMOPS monitor well,static) 14:45 17:00 2.25 7,599 355 COMPZ WELLPF TRIP P POOH f/7599'MD to 355'MD. Monitor well at collars. 17:00 17:45 0.75 355 200 COMPZ WELLPF TRIP P Rack back collars 17:45 18:30 0.75 200 0 COMPZ WELLPF PULD P PJSM-L/D BHA,clean magnets. <5 lbs fine debris on magnets. No other observations on scraper BHA. 18:30 19:00 0.50 0 0 COMPZ WELLPF PULD P PJSM-L/D magnets and 7"csg scraper, P/U mills from slide. 19:00 19:30 0.50 0 319 COMPZ WELLPF PULD P Make up BHA, P/U String mills. 19:30 22:30 3.00 319 7,527 COMPZ WELLPF TRIP P RIH from 319'MD to 7527'MD, P/U=141k, S/O=110k. 22:30 22:45 0.25 7,527 7,612 COMPZ WELLPF CIRC P Wash down f/7527'MD t/7612'MD @ 5 bpm long way,450 psi.Tagged up,set down 5k,saw pressure increase to 800 psi confirming top of tubing cut at 7600'DP MD D141 RKB. Calc Disp=47.3 bbl,Actual Disp=47.1 bbl. 22:45 23:00 0.25 7,612 7,609 COMPZ WELLPF RURD P PJSM-R/U to reverse circulate @ 7609', 3'off bottom. 23:00 00:00 1.00 7,609 7,609 COMPZ WELLPF CIRC P Reverse circulate @ 7 bpm, 800 psi, pumped 320 bbl total. Saw some returns @ 80 bbl, DP bottoms up then cleaned up good. 09/05/2013 POOH&L/D BHA#3. Slip&Cut line. Repair leaky riser boot. R/U and run 3-1/2"Completion,displace to inhibited brine,drop ball&rod. 00:00 00:30 0.50 7,609 7,609 COMPZ WELLPF OWFF P PJSM-Monitor well for flow,static. R/D circulating equipment. 00:30 04:15 3.75 7,609 0 COMPZ WELLPF TRIP P POOH t/319'MD, Monitor well at collars. L/D BHA. Calc Fill=48.6 bbl, Actual Fill=49 bbl. 04:15 04:45 0.50 0 0 COMPZ WELLPF RURD P Clean and clear rig floor,send out Baker cleanout tools. 04:45 06:30 1.75 0 0 COMPZ WELLPF SLPC P Slip and cut 78'drilling line,service topdrive and draworks. Page 7 of 9 Time Logs a'Date from . To Our S.Death—E.DepthiPhase Cede,ft—Subco de f h_..Commeht Nl s . 11; "" 06:30 07:00 0.50 0 0 COMPZ RPCOM RURD P Pull wear bushing. 07:00 07:30 0.50 0 0 COMPZ RPCOM RURD P R/U Casing equipment 07:30 11:30 4.00 0 1,705 COMPZ RPCOM RCST P PJSM-RIH with 3-1/2"Overshot Stacked Packer GL Completion per detail to 1705'MD.Actual Disp=5.3 bbl, Calc Disp=5.4 bbl. 11:30 12:00 0.50 1,705 1,705 COMPZ RPCOM OTHR T Discover leaking bell nipple boot, Drain stack, prep to C/O Boot. 12:00 13:00 1.00 1,705 1,705 COMPZ RPCOM OTHR T PJSM, HRW,C/O boot on stack. 13:00 18:45 5.75 1,705 7,593 COMPZ RPCOM RCST P PJSM-Continue RIH w/3-1/2" Tubing GL completion. Ran Overshot, DS Nipple, Packer and PBR seal assy, GLV w/SOV,4 GLM Dummy, DS Nipple and 238 jts to tag. P/U=88k, S/O=75k. 18:45 19:15 0.50 7,593 7,597 COMPZ RPCOM RCST P PJSM-R/U to pump on jt 238 50 gpm @ 100 psi.Tag up on shear pins @ 7593'MD,set down 8k, weight fell off indicating pins sheared, pressure increase and tagged up at 7597'MD,set do 5k no-go. P/U 10' to circulate. 19:15 21:00 1.75 7,597 7,587 COMPZ RPCOM OTHR T Clean and clear rig floor, rig up lines in cellar while waiting on vac truck with inhibited brine. Delayed due road and bridge repair,Truck left Kup at 07:00 for the brine, returned at 21:00. 21:00 23:15 2.25 7,587 7,587 COMPZ RPCOM CRIH P PJSM-Reverse displace well with 80 bbl 8.6 brine from pit 5, 190 bbl 8.6 ppg brine inhibited with 1% CRW-132,chase with 10 bbl clean 8.6 ppg from pill pit to flush lines. Pumped at 3 bpm, 175 psi. 23:15 00:00 0.75 7,587 7,587 COMPZ RPCOM PACK P R/D circ lines,drop ball/rod. 39/06/2013 Land completion, N/D BOP and N/U-test tree. Displace to Freeze protect, secure well. Laydown drill pipe and prep for move. Rig released at 24:00 hrs 9-6-2013 00:00 00:45 0.75 7,587 7,597 COMPZ RPCOM PACK P PJSM-Set packer per Baker rep, pressure up to 2,000 psi and hold 5 min,saw shear out @ 94k up wt. Bleed tubing to 0 psi. PT IA t/1500 psi for 5 min to ensure packer set. Put 1500 psi on tubing and S/O of PBR w/85k up wt. 00:45 01:15 0.50 7,597 7,597 COMPZ RPCOM HOSO P Space out seals 7'above fully located position per Baker rep, L/D 3 jts, P/U 2 pups, 10.20 and 10.15, P/U jt 236. P/U=88k, 5/0=72k 01:15 02:15 1.00 7,597 7,597 COMPZ RPCOM HOSO P M/U hanger and landing joint, land hanger and RILDS. Page 8of9 'time LO g$ 01 ii sil` 3#. °IL fi @iIi ,• Date From To, -Dur.'; S. Deaths E.`Detoth Phase Code' Subcode Tii ACornin no"III I 4'at 02:15 03:30 1.25 7,597 7,597 COMPZ RPCOM PRTS P Pressure test tubing 2500 psi 10 minutes, hold tubing pressure and PT IA to 3500 for 30 minutes. Bleed IA to 0,tubing to 0. Ramp up IA and shear out SOV 2400 psi,charted. Bleed off all pressure. 03:30 04:00 0.50 7,597 7,597 COMPZ RPCOM OWFF P R/D Circ lines and monitor well for 30 minutes. 04:00 04:30 0.50 7,597 0 COMPZ WHDBO PRTS P Set BPV and test 1000 psi from below via IA. 04:30 07:30 3.00 0 0 COMPZ WHDBO NUND P N/D BOPE and adapter flange, SIMOPS-DROPS inspection personnel rigging up ropes in Derrick, performing DROPS inspection. 07:30 08:30 1.00 0 0 COMPZ WHDBO SVRG P Service draworks,clean pits, blow down mud pumps, DROPS insp completed. 08:30 10:00 1.50 0 0 COMPZ WHDBO NUND P N/U adapter flange and tree.Test adapter flange and hanger seals to 250/5000 psi 5/15 min 10:00 12:00 2.00 0 0 COMPZ WHDBO PRTS P Pull BPV, install tree test plug.Test tree to 250/5000 psi 5/10 minutes charted. 12:00 13:00 1.00 0 0 COMPZ WHDBO RURD P PJSM-R/U lines to freeze protect. 13:00 14:00 1.00 0 0 COMPZ WHDBO FRZP P PT lines to 2500 psi, reverse in 75 bbl of LEPD @ 1.5 bpm,600 psi. 14:00 16:00 2.00 0 0 COMPZ WHDBO RURD P Communicate tubing and IA to U-tube, Clear rig floor and R/U to L/D 4"drill pipe. 16:00 16:45 0.75 0 0 COMPZ WHDBO RURD P Blow down and R/D lines,clear hoses and fittings from cellar area. 16:45 17:30 0.75 0 0 COMPZ WHDBO MPSP P Set BPV, Install IA flange and secure tree and cellar. 17:30 22:00 4.50 0 0 COMPZ WHDBO PULD P PJSM-Lay down 4"drill pipe from derrick. UD mouse hole, unload pipeshed. 22:00 00:00 2.00 0 DEMOB MOVE DMOB P PJSM-Prepare rig for move. Blow down steam and water lines,start rig move checklist. Rig release at 24:00 hrs. Page 9rf 9 • w w��\\OF I%%7 s� THE STATE Alaska Oil Gas OfALAsKA Conservation CCommission ,TR,, GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Brett Packer �A�N�Q NOV' 0 CDI Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 1' 0 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1A-03 Sundry Number: 313-400 Dear Mr. Packer: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this�day of August,2013. Encl. STATE OF ALASKA 0( RAccRhy&D A KA OIL AND GAS CONSERVATION COMIOION APPLICATION Q ICATION FOR SUNDRY APPROVALS fI JUL 2 20 20 AA 25.280 pp 4Q9 1.Type of Request: Abandon r Rug for Redrill f Perforate New Pool (" Repair w ell :r Change A Suspend Rug Perforations r Perforate r Pull Tubing Nj Time Extension Operational Shutdown E Re-enter Susp.Well r Stimulate Alter casing Other: I- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Development f. Exploratory '"' 181-088• 3.Address: Stratigraphic Service 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-20615-00. 7.If perforating, ha`I/ 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes l .. No ( 1A-03. 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25647% Kuparuk River Field/Kuparuk River Oil Poole 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 8880. 7059* 8765' none 8270,8314 Casing Length Size MD . TVD Burst Collapse CONDUCTOR 50 16 80' 80' SURFACE 2922 10.75 2953' 2684' PRODUCTION 8834 7 8863' 7044' Perforation Depth MD(f 7820-7888, t Perforation Depth TVD(ft): 6168-6223, Tubing Size: Tubing Grade: Tubing MD(ft): 7948-7972,8166-8172,8178-8210,8180-8214 6271-6291,6451-6456,6461-6487,6462-6491 3.5 J-55 8080 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER FHL PACKER MD=7667 TVD=6046" PACKER-BAKER FHL PACKER MD=7941 TVD=6266• PACKER-BAKER FB-1 PACKER W/5"SEAL BORE EXT MD=8050 TVD=63544 SSSV-CAMCO TRDP-1A-ENC MD=1869 TVD=1831 t, 12.Attachments: Description Summary of Proposal .( ' 13. Well Class after proposed work: Detailed Operations Program [ BOP Sketch f Exploratory C Stratigraphic Development Si Service 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 8/17/2013 Oil r.% Gas — WDSPL r Suspended r 16.Verbal Approval: Date: VVINJ GINJ E WAG r Abandoned Commission Representative: GSTOR r SPLUG r- 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brett Packer @ 265-6845 Email: J.Brett.Packeranconocophillios.com Printed Name Brett Packer Title: Wells Engineer ? '� ?/?-1/i 3 Signature � Phone:265-6845 Date Commission Use Only Sundry Number 3_ �J�J y00 Conditions of approval: Notify Commission so that a representative may witness ✓! / Z Plug Integrity 1 BOP Test Mechanical Integrity Test f•• Location Clearance r RBDMS AUG - 2 20 Other: Z?Up tri/ 10 00 0 /j5._G Spacing Exception Required? Yes ❑ No 17f Sbsequent Form Required: /0-- 4-6 4 APPROVED BY Approved by: tA)Plcr -- a pli ti i v QMI ONO the from the PRO COMMISSION rval. Date. —( —/3 Form 10-403(Revised 1 1tt7 1 i ! Submit Form and Attachments in Duplicate \� KLW3I1(3 • • ✓ RECEIVED 2 5 2013 Conoco Phillips JUL Alaska A0000 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 July 24,2013 Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to workover Kuparuk Producer Well 1A-03 (PTD# 181-088). 1A-03 was drilled& completed with a triple selective in July 1981. The well is currently online, and although still maintaining integrity, the tubing is severely corkscrewed. The first indications of corkscrewed tubing were noted back in 2009 when coil attempted to FCO the well but experienced heavy weight swings and aborted the job. Drillsite 1A has known subsidence issues, and as part of our subsidence monitoring program, we began gathering gyro surveys of all suspected subsidence wells. In November 2012,we attempted a gyro survey of this well and the toolstring stacked out at 140 feet. We ran a drift for a plug to ensure that we could still secure this well downhole, but a regular plug would not drift. Pre-rig plans are to drift for a slimhole plug and set it in the slickstick above the packer if possible. Currently,we can still drift the tubing to bottom with smaller OD tools,but without the ability to properly secure the well downhole, we have opted to proactively work this well over before the tubing gets any worse and we cannot get any tools to bottom. This well has a leak just below the packer in the C-sand selective, thus,we cannot secure this well with a plug below the packer. Due to this leak,the RWO plans are to stack a packer so that we can effectively isolate the reservoir in the future. This leak will be addressed using non-rig options following the RWO. The workover scope of work is to pull&replace the tubing and the inner casing packoffs which will also allow us to relieve any compression in the 7" production casing. The biggest unknown is the condition of the 7" production casing due to subsidence. The 7" and the 10 3/4" casing strings still have pressure integrity, but whether they are buckled close to failure is unknown. We won't know until we try to pull the tubing and the SSSV (5.937" OD) through the shallow subsidence affected zone. If the SSSV drifts the 7"casing just fine coming out of the well,we can be confident that the 7"casing is still in decent shape. If we see any restriction from the SSSV while pulling the tubing, we will go down the path of cutting & pulling the 7" casing down to top of cement, replacing it with new casing,and cementing the 7"x 10 3/4"annulus,similar to what we have done on numerous wells already. Technically, under Conservation Order 261, which currently waives the requirements of 20 AAC 25.280(a) for certain wells in the Kuparuk River Oil Pool, this producing well would not require a sundry for simply pulling & replacing the tubing. Nevertheless,this sundry is intended to document the plan should we need to go down the path of cutting&pulling the 7"casing. If you have any questions or require any further information,please contact me at 265-6845. Sincerely, Brett Packer Wells Engineer CPAI Drilling and Wells • • 1A-03 Rig Workover Pull & Replace Tbg, Possible Subsidence Style Repair (PTD #: 181-088) Current Status: This well is currently online. Scope of Work: Pull&replace tubing&inner casing packoffs. IF any restriction pulling the SSSV through the shallow subsidence affected zone,perform subsidence style RWO(i.e. cut&pull 7"casing above top of cement and replace w/new casing.) General Well info: Well Type: Producer MPSP: 1,488 psi based on recent SBHP and using a 0.1 psi/ft gradient. Reservoir Pressure/TVD: 2,133 psi/6,453' TVD(6.4 ppg)from Panex gauges on 6/19/13. Wellhead type/pressure rating: FMC Gen I Retro,7-1/16"5M psi top flange BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: TIFL passed on 8/23/12 MIT-IA passed on 9/15/10 MIT-OA passed on 8/23/12 Earliest Estimated Start Date: August 17,2013 Production Engineer: Dana Glessner/David Lagerlef Workover Engineer: Brett Packer(265-6845/j.brett.packer @cop.com) Pre-Rig Work 1. RU Slickline: a. Pull 1"GLV's&OV from GLM's#1,2,4,and 7,replace all with DV's. b. Pull 1.5"DV from GLM#10,leave pocket open for RWO circulation point. c. RIH and dummy drift for the following: (Document Tight Spots) i. 2.55"Baker Composite Bridge Plug(4'x 2.55"and 9' of 1.75"setting tool) ii. 2.52"Interwell Retrievable Plug(5.5' x 2.52"OD Plug and 9' of 2.25"setting tool) iii. 1.80"Interwell Retrievable Plug(5.9'x 1.80"OD Plug and 11' of 1.70"OD setting tool) iv. Drift as deep as possible with plug dummy,or at least to the production mandrel @ 7,673'KB. Record exact toolstring drift details in the WSR to allow town engineers to develop a plan forward for securing the well prior to the RWO. RDMO. 2. RU E-line: If Slickline drifts were successful,RIH&set slimhole plug inside the slickstick. 3. PT tubing and casing packoffs,FT LDS's. 4. Set BPV w/i 24 hrs of rig arrival. Proposed Procedure 1. MIRU. 2. Pull BPV. Reverse circulate 8.6 ppg seawater. Obtain SITP&SICP,if still seeing pressure,calculate new KWF,weight up,and repeat circulateion. Verify well is dead. • 3. Set BPV. ND tree. NU BOP stack&test. $U f7 7y5 D G G/7 5-L - 4. Pull blanking plug and BPV. 5. POOH laying down tubing. If tubing pulls free,save SBR for re-use in stack packer completion. a. If tubing will not pull free from SBR,RU E-line: Fire a string shot and cut the tubing in the middle of the first full joint above the SBR. • • 1A-03 Rig Workover Pull & Replace Tbg, Possible Subsidence Style Repair (PTD #: 181-088) IF SSSV pulls from well without restriction follow Procedure`A',otherwise follow Procedure`B'. PROCEDURE `A' 6. During TOH after SSSV is laid down,hang off storm packer w/old completion hanging below. 7. ND BOP stack. ND tubing head using Hydratight Tensioners to safely allow 7"casing to grow. Spear 7"csg, pull in tension,and re-land in slips. RU Wachs cutter and cut 7"casing growth. Install new packoff assembly and tubing head. PT packoffs. NU BOP's and shell test breaks. 8. Pull storm packer and continue POOH laying down old completion. Skip to Step#28. PROCEDURE `B' 9. Run casing scraper assembly to top of tubing stub. Circulate well clean. 10. RU E-Line. Run caliper log,gyro survey,and cement bond log in 7"casing from tubing stub to surface. RIH and fire string shot across the 2nd collar above the TOC as determined from the CBL. RD E-Line. 11. Set retrievable bridge plug below top of cement. Pressure test RBP. If unable to set a slimhole tubing plug pre- rig,set a second bridge plug above the first and PT. Dump sand on top of(upper)RBP. 12. ND BOP stack. ND tubing head using Hydratight Tensioners to safely allow 7"casing to grow. Spear 7"csg, pull in tension,and re-land in slips. RU Wachs cutter and cut 7"casing growth. Tack weld slips to casing if permissible. 13. NU BOP's on casing head. (With 2 barriers in the well,BOP stack will be considered a diverter at this point. Testing the BOP's would test against the 10'/4"casing&cement shoe which we typically do not test our surface casing to>1800 psi.) 14. Cut 7"casing with mechanical cutter above TOC. 15. Circulate Arctic Pack from the 7"x 10 3A"annulus with w/heated diesel followed by heated seawater. 16. Spear 7"casing and POOH sideways. 17. Run 10 3/4"casing scraper to top of 7"stub. Circulate clean. 18. Run dummy drift for ES cementer. 19. Run back off tool and back off casing stub. 20. Spear and recover backed off 7"casing stub. 21. RIH with new 7"casing and Halliburton ES cementer. Screw into top of 7"casing. Pressure test casing. 22. Open ES cementer and pump cement into 7"x 10 3A"annulus to surface. Close cementer. 23. While waiting on cement,ND BOP,pull casing in tension and land in slips. Cut 7"casing,install packoff. NU new tubing head. 24. NU BOP's and shell test breaks. 25. Drill out cement&ES cementer. Pressure test 7"casing to 3500 psi. Continue down until tag up on top of sand,dry drill on sand to break up debris.Circulate well clean. 26. RIH with wash shoe,boot baskets,magnets,etc.and circulate out sand on top of RBP. POOH. 27. RIH w/RBP retrieving tool on work string. Release RBP and POOH. (RIH and retrieve 2nd RBP if run). Run Final Completion 28. RIH with poor-boy overshot or original SBR and FHL stack packer assembly on new 3 '/2'tubing. Circulate in corrosion inhibited fluid,engage tubing stub,space out,drop ball&rod and set FHL packer. PT IA to 3500 psi. Shear the PBR,space out tubing,mark the pipe and pull out two joints. • 1A-03 Rig Workover • Pull & Replace Tbg, Possible Subsidence Style Repair (PTD #: 181-088) 29. Space out w/pups,MU tubing hanger and land. RILDS. 30. Pressure test tubing to 3,000 psi,PT IA to 3500 psi. Shear SOV. 31. Install BPV. ND BOP. NU tree,pull BPV,install tree test plug and pressure test tree. Pull tree test plug. 32. Freeze protect well. 33. Set BPV. 34. RDMO. Post-Rig Work request: 1. Pu11 BPV. 2. RU Slickline: Pull ball&rod,pull SOV and run GLD. Pull RHC plug. Pull slimhole plug if installed. 3. Return well to production. 1A-03 Proposed RWO Modified by JBP 7-17-13 2.875" Camco DS nipple at 500' MD 16"65# H-40 shoe 3-1/2"9.3#L-80 EUE 8rd-Mod Tubing to surface @80' MD 3-1/2"x 1-1/2" Camco gas lift mandrels at 10-3/4"45.5# K-55 _ shoe @ 2953' MD • --�--__ Baker GBH-22 Locator Seal assembly/ PBR Baker Model FHL Retrievable packer at—7,620' RKB fr ' 2.813" Camco DS nipple Baker Poor-boy Overshot riginal Completion Baker Model FHL Retrievable packer at—7,667 RKB C2/C3/C4-sand perfs t 3-1/2"x 1" Camco Production mandrels 7820-7888' MD _ _..__. Baker Model FHL Retrievable packer at—7,941' RKB C1 sand perfs — ∎■ 3-1/2"x 1" Camco Production mandrels 7948' -7972' MD 1 Baker Model FB-1 Permanent packer at—8,050' RKB • \ Baker GBH-22 Locator Seal assembly/ SBE 2.75" Camco DS nipple Shear-out Sub @ 8,080' RKB `' WLEG @-8,081' ELMD A4/A5-sand perfs 1 8166' -8214' MD 7"26#J-55 shoe @ 8863' MD KUP 1A-03 Conoco Phillips 9- Well Attributes Max Angle&MD TD Alaska,Inc Wellbore API/UWI Field Name Well Status !nc!I') MD(ftKB) Act Btm(ftKB) car.ttwhnkps 500292061500 KUPARUK RIVER UNIT PROD 48.00 3,600.00 8,880.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date "' SSSV:LOCKED OUT 120 8/24/2012 Last WO: 5/11/1985 39.01 7/24/1981 Well Confp:-1A-03,1/30/201363234 AM Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:WLM 8,176.0 6/3/2008 Rev Reason:WELL REVIEW osborl 1/30/2013 HANGER,27 i pi. Casing Strings Casing Description String 0... String ID...Top(ft(B) Set Depth(1...Set Depth(TVD)...String Wt..String.. String Top Thrd a,.:. CONDUCTOR 16 15.062 30.0 80.0 80.0 65.00 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(6...Set Depth(ND)...String Wt...String...String Top Thrd ill ,, SURFACE 10 3/4 9.950 31.5 2,953.1 2,683.8 45.50 K-55 BTC t• Casing Description String 0... String ID...Top(ROB) Set Depth(f...Set Depth(ND)...String Wt...String.. String Top Thrd PRODUCTION 7 6.276 28.9 8,863.0 7,044.2 26.00 K-55 BTC CONDUCTOR, Tubing Strings 30-80 Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd SAFETY VLV, , TUBING 31/2 2.992 26.8 8,080.6 6,379.8 9.20 J-55 BTC 1,869 ,... MI Completion Details GAS LIFT, Top Depth 940 ; (TVD) Top Inc! Noml,,. Top(BOB) (RKB) (1 Rem Description. Comment ID(in) 26.8 26.8 0.00 HANGER FMC HANGER 3.500 SURFACE 1,868.8 1,830.8 27.38 SAFETY VLV CAMCO TRDP-1A-ENC SAFETY VALVE.Locked out 5/3/95. 2.812 31-2.953 7,640.5 6,025.1 37.80 SBR BAKER SBR 2.810 7,666.7 6,045.8 37.67 PACKER BAKER FHL PACKER 3.000 41' 7,941.3 6,265.8 35.59 PACKER BAKER FHL PACKER 3.000 GAS LIFT. / 3791 .-:;.,`a 7,965.7 6,285.6 35.34 BLAST RING 2.867 8,047.7 6,353.0 34.90 LOCATOR BAKER LOCATOR 3.000 GAS LIFT. 8,049.6 6,354.5 34.88 PACKER BAKER FB-1 PACKER W/5"SEAL BORE EXT 4.000 4'994 8,068.0 6,369.5 34.65 NIPPLE CAMCO D NIPPLE NO GO 2.750 GAS LIFT, 5.635 8,079.8 6,379.2 34.50 SOS CAMCO SHEAR OUT SUB.***ELMD @ 8047'ON SWS PPROF 2.992 5/17/200*** GAS LIFT, : *Ls s,DO3 Other In Hole Wireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT, Top Depth 6,370 (ND) Top Inc! i Top(ftKB) (ftKB) (1 Description Comment Run Date ID(In) GAS LIFT, _.. � 8,270.0 6,538.0 32.33 FISH Retainer Pin(/GU Adapter Lost Downhole 12/1/1996 12/1/1996 0.000 6,737 GAS LIFT, 8,314.0 6,575.2 32.22 FISH 5"Vann Gun 450'Long 7/24/1981 7/24/1981 0.01)0 7,047 CT_ GAS LIFT, Perforations&Slots 7,379 Shot Top(ND) Btm(TVD) Dens Top(ftKB)Btm(ROB) (ftKB) (ftKB) Zone Date OM-- Type Comment GAS LIFT, 7,820.0 7,888.0 6,168.1 6,222.5 C-4,C-3,1A-03 7/24/1981 12.0 IPERF 5"Vann Guns 7,598 7,820.0 7,888.0 6,168.1 6,222.5 C-2,1A-03 5/10/1985 4.0 RPERF 120 deg.Ph,4"JumboJet II 7,920.0 7,922.0 6,248.4 6,250.0 C-2,1A-03 5/5/1985 4.0 SQZ Squeezed SBR,7,640 PACKER,7,667 - _-• w 7,948.0 7,972.0 6,271.2 6,290.7 C-1,1A-03 7/24/1981 12.0 IPERF 5"Vann Guns L.--- _ 7,948.0 7,972.0 6,271.2 6,290.7 C-1,1A-03 5/10/1985 4.0 RPERF 120 deg.Ph,4"JumboJet II PRODUCTION. I - 8,108.0 8,110.0 6,402.6 6,404.2 UNIT B,1A-03 5/5/1985 4.0 SQZ Squeezed 7,706 8,166.0 8,172.0 6,450.7 6,455.7 A-5,1A-03 7/24/1981 12.0 IPERF 5"Vann Guns 8,178.0 8,210.0 6,460.7 6,487.4 A-4,1A-03 7/17/1993 4.0 IPERF 180 deg.Ph,2.5"Titan Guns 8,180.0 8,214.0 6,462.4 6,490.8 A-4,1A-03 7/24/1981 12.0 RPERF 5"Vann Guns PRODUCTION,__ 7793 [ Cement Squeezes ( Top Depth Btm Depth I (ND) (ND) Top(ftKB)Btm(ftKB) (MB) (RKB) Description Start Date Comment IPERF, 7,920.0 7,922.0 6,248.4 6,250.0 Cement Squeeze 5/6/1985 7.620-7,888\ - - 8,108.0 8,110.0 6,402.6 6,404.2 Cement Squeeze 5/6/1985 7.025-7,000 \ e: Notes:General&Safety..... SQZ, End Date Annotation 7.920-7,922"- U2 I M 1/16/1997 NOTE:C 3,4 Sand:Open.C 1 Sand:Open.Tubing Tail ELMD Cement,7,920 PRODUCTION. 5/172 ', 5/17/2000 NOTE:Suspected leak at upper Packer.Broken latch DMY valve @4910 7.926 1/6/2002 NOTE:WAIVERED WELL-IA x OA communication. PACKER.7,941, _- ." 5/7/2006 NOTE:LEAKS DETECTED @ 7644'AND 7783' PRODUCTION, _ IPERRF, , 7/29/2010 NOTE:View Schematic w/Alaska Schematic9.0(2 pages) 7,948-7,972 RPERF, ...,i 7,948-7,972 I I PRODUCTION. 8,029 4 I LOCATOR. j°'�` 8,048 PACKER,8,060 111 w At' IMMI NIPPLE.8.068 IN sos,8,080 l Mandrel Details S Top Depth Top Sort 8,108$110l1e 1 (ND) Inc' OD Valve Latch Size TRO Run Cement,8,108 - N...Top(ftKB) (ftKB) (1 Make Model (in) Seri Type Type (In) (psi) Run Date Com... 8,1668,1 IPER72 F• 1 1,940.3 1,893.7 28.81 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,228.0 10/2/2010 IPERF, 2 3,791.4 3,252.8 47.98 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,274.0 10/2/2010 8,178-8,210- 3 4,943.9 4,041.2 45.53 CAMCO KBMG 1 GAS LIFT DMY Broke 0.000 0.0 5/11/1985 RPERF, 8.180'8.214 4 5,635.2 4,531.5 46.00 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,281.0 10/2/2010 5 6,002.9 4,787.0 44.51 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/11/1985 FISH,8,270-11 6 6,370.0 5,046.8 44.97 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 2/9/1997 FISH.8.314 = 7 6,737.0 5,312.9 41.26 CAMCO KBMG 1 GAS LIFT OV BKO-3 0.188 0.0 10/2/2010 8 7,047.5 5,553.7 37.00 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 2/9/1997 9 7,379.4 5,817.9 37.90 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 8/1/1992 PRODUCTION, 10 7,597.7 5,990.8 37.24 CAMCO KBMG 1 12 GAS LIFT DMY RM 0.000 0.0 2/9/1997 T�,880 ' •AL as KUP • 1A-03 ConocoPhillips ; Alaska,Inc. caros "^" KB-Grd(R) Rig Release Date 39.01 7/24/1981 Well Confis Sch-1A-03ematic-1130/2013632:34 AM Aduel HANGER,27 e CONDUCTOR, 3080 SAFETY VLV, �o 1169 GAS LIFT, f 1,940 SURFACE, j 31-2,953 GAS LIFT, 3,791 GAS LIFT,_ ._. 4,944 GAS LIFT, 5,635 GAS LIFT, 6,003 ' GAS LIFT, 6,370 GAS LIFT, 6,737 GAS LIFT, 7,047 GAS LIFT, 7,379 GAS LIFT, 7,598 SBR,7,640 PACKER,7,667 PRODUCTION, 7,706 PRODUCTION, 7,783 IPERF, 7,8207E,888 RPRF, 7,820-7,888 SCIZ, 7,9207,922 _ a Cement,7,920 PRODUCTION, �e - 7,926 E PACKER,7,941 PRODUCTION, 7,955 IPERF, , 7,948-7,972 ,A RPERF, 7,948-7,972 PRODUCTION, 8,029 LOCATOR, 8,048 PACKER,8,050 NIPPLE,8,068 t= SOS,8.080 (. Mandrel Details 5l Top De Top Port 8,1nt,8,108 IS (ND) Inc! OD Valve Latch Size TRO Run Cement 8,108 N...Top(RKB) (RKB) (°) Make Model (in) Sere Type Type (in) (psi) Run Date Coin... 8,1 I P II% 11 7,706.3 6,077.2 37.47 OTIS 3.5 x 1.5 1 12 PROD DMY RM 0.000 0.0 10/5/1996 Closed IPERF, 12 7,783.4 6,138.5 37.08 OTIS 3.5 x 1.5 1 12 PROD DMY RM 0.000 0.0 6/22/2010 See 8,1788,210 Note RPERF, 8,180-8,214 13 7,925.9 6,253.2 35.74 OTIS 3.5 x 1.5 1 12 PROD DMY RM 0.000 0.0 1/17/2010 14 7,954.5 6,276.5 35.45 OTIS 3.5 x 1.5 1 12 PROD DMY RM 0.000 0.0 1/172010 FISH,8,270 15 8,028.6 6,337.5 35.14 OTIS 3.5 x 1.5 1 12 PROD DMY RM 0.000 0.0 4272010 FISH,8,314 = PRODUCTION, 29-8,863\ TO,8,880 . ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 June 27, 2011 Commissioner Dan Seamount Alaska Oil and Gas Commission assior� 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 4Cg Commissioner Dan Seamount: 03 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 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 on 3/21, 5/9, 5/23 and 5/24, 2011. The corrosion inhibitor /sealant was pumped 6/18, 6/19, 6/20 and 6/21, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, MJ L veland ConocoPhillips Well Integrity Projects Supervisor • 0 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 06/27/2011 1A,1B,1E,1L,1Q,1Y PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped _ cement date inhibitor sealant date ft bbls ft gal 1A-03 50029206150000 1810880 16" N/A 23" N/A 1.7 6/20/2011 1A -04A 50029206210100 2001940 18" N/A 23" N/A 2.5 6/20/2011 1A -16RD 50029207130100 _ 1820310 SF N/A 22" N/A 5 6/18/2011 1B -03 50029205880000 1810560 SF N/A 23" N/A 5 6/21/2011 1B -04 50029205950000 1810650 18" N/A 18" N/A 2.5 6/21/2011 1B -05 50029202370000 1770010 31" 6.40 2'9" 5/24/2011 6 6/21/2011 1B-07 50029206160000 1810890 72" 1.00 22" 5/9/2011 2.5 6/21/2011 1B-08A 50029206350100 1971120 18'8" N/A 29" N/A 4.5 6/21/2011 1B-09 50029206550000 1811340 SF N/A 23" N/A 5 6/20/2011 1B -10 50029206560000 1811350 SF N/A 23" N/A 6 6/21/2011 1B -12 50029223650000 1930610 13'4" 2.00 24" 5/9/2011 6 6/21/2011 18-101 50029231730000 2031330 3" N/A 22" N/A 1.7 6/21/2011 1B -102 50029231670000 2031220 112" 0.60 36" 5/9/2011 1.7 6/21/2011 1E -05 50029204790000 1800580 19" N/A 19" N/A 1.7 6/19/2011 1E-22 50029208840000 1822140 14" 1.75 17" 3/21/2011 1.7 6/19/2011 1E-23 50029208580000 1821840 58' 10.75 2'S" 5/23/2011 3.4 6/19/2011 1E -30 50029208140000 1821390 15'5" _ 1.75 16" 3/21/2011 2.5 6/19/2011 1E -105 50029232430000 2050060 20" N/A 20" N/A 6 6/19/2011 1L-16 50029212020000 1841810 14'9" 2.00 35" 5/23/2011 6 6/20/2011 1L-18 50029221450000 _ 1910350 SF N/A 18" N/A 2.5 6/19/2011 1Q -24 50029225840000 1951210 7'8" 1.00 12" 5/9/2011 5 6/18/2011 1Y -02 50029209410000 1830590 40'10" 5.00 41" 5/9/2011 8.5 6/18/2011 • • Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] ~~~~ (~~~ I la Sent: Saturday, September 04, 2010 5:38 PM K To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: 1A-03 (PTD 181-088) Report of failed TIFL Attachments: 1A-03 schematic.pdf Tom, Jim, Guy Kuparuk gas lifted producer 1A-03 (PTD 181-088) failed a diagnostic TIFL. The TIO prior to the test was 1200/1340/780 with the well SI upon arrival. A leaking is suspec a Slickline will troubleshoot and repair if possible. Attached is a schematic and a 90 day TIO plot. Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 ~i() 1 ~I~-U~}° 9/7/2010 KRU 1A-03 PTD 1810880 9/4/2010 Tin Pressures 30 2 30 30 30 0. 0. 0. 0. 0. (t . 0. SC 3000 2700 2400 2100 18DD 1500 1200 900 600 300 0 WELL NAME WLKRUlA-03 q •1 1l%~t - Li--- r ~_~-_ --tom-- -- ', w PLOT START TLME 06-JUN-10 17:38 ~* TiG NINE ~ WL1A-03-CHOKE SCRATCH 48 SCRATCH_48 AI-P1A5007-03 SCRATCH_48 ~ SCRATCH_48 MINOR TIME PLOT I)I1RAT'ION PLOT END "I'IMF. MAJOR TIME WEER 1~21b0:00:Ob HRS D4-5EP~10 17:3 PICK TIRE 04-SEP-10 17:33:30 ~~~~~~ ~~~ DESCRIPTION r> w~,} PF ':.,','TEST FLOW TUBING CHOKE ~a?7aa? DRILLSITE WELL PREY WELL FLOW TUBING PRESSURE ?????7? l a 0 3 FLOW TUBING TEMP ??????? ~ NEXT WELL GL CASING PRE55URE 7?????? ??????? ENTRY TYPE OPERATOR 7?????? OPERATOR VERIFIED INNER ANtJI)LUS PRES X777777 SYSTEM AUTO ENTRY OUTER ANNULUS PRES ??????? BOTH • • - ~F`-_~ KUP _ 1A 03 __ _ ~0(lOC{?f X11 ~ ~ I CJS ~ ~ ~~ Well Attributes Max Ankle & MD TD ... ( I .. ~... ~ "1420 10 7'.32'.53 AM HANGER, 27- ~-, ~- -~~ ~ f CONDUCTOR F 30 80 - i SAFETY VLV, 1,836 _ GAS LIFT. j '- - 1,907 SURFACE, 29-2,953 I GAS LIFT, ) r--~ 3,758 ~ GAS LIFT - - ~ ---' 4,911 ~_ GAS LIFT, {"-' 5,602 GAS LIFT, 5,970 GAS LIFT, '_ 6,337 GAS LIFT, r' "' 6,704 - -~ GAS LIFT, 7,o1a 1 _._ GAS LIFT. r' J 7,346 ti,= GAS LIFT, 7.565 SBR, 7.607 PACKER. 7,634 - .w~~ PRODUCTION, -- 7,fi73 Wellbore API/UWI FVeltl Name Well Statue Incl (`) MU (nhb) i.c[Btm (ftKB) 500292061500 KUPARUK RIVER UNIT PROD 48.00 3,600.00 8,880.0 Comment H25 (ppm) Date Annotation Entl Date KB-Grd (R) Rig Release Date SSSV: LOCKED OUT 190 7/10/2009 Last W0: 5/11/1985 39.01 7/24/1981 Annotation Depth (iR(B) End Date Annotation Last Mod ... Entl Date Last Tag'. WLM 8,176.0 6/3/2008 'Rev Reason: FORMAT UPDATE 9.0 Imosbor 8/14/2.0.10 Casin Strin s Casing Description Siring 0... String ID ... Top (ftKB) Set Daplh (1... Set Depth (T': L{... String Wt... String... String T.:p rhrd CONDUCTOR 16 15.062 30.0 80.0 80.0 65.00 H-00 WELDED Casing Description String 0... Stnng ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE 103/4 9.794 29.0 2,953.0 2,683.7 4550 K-55 Casing Description String 0... String ID ... lop (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.151 28.9 8,863.0 7,044.2 26 00 K-55 BTC iTubulg Stnngs T-wng Lesoripti..n `[ ~ g 0... rSiring ID ... Top (ftKB) Set Dep[h (t... Set Depth (~Wt...'S[ g ... String Top Thrd V TUBING ~ 3 1/2 2.992 26 8 8,047.6 6.352.9 - 9 20 J 55 _ BTC _ Completion Details_ __ -~- ~- Top Depth (ND) Top Inel Noml... Top (ftKB) IRKS) (°I Item Description Comment ID (in) 26.8 26.8 0.00 HANGER FMC HANGER 3.500 1,835.8 1,801.2 26.72 SAFETY VLV CAMCO TRDP-IA-ENC SAFETY VALVE. Locked out 5/3/95. 2,812 7,607.5 5,999.2 37.96 SBR BAKER SBR 2.810 7,633.7 6,019.8 37.83 PACKER BAKER FHL PACKER 3.000 7,908.3 6,238.9 35.92 PACKER BAKER FHL PACKER 3.000 8,014.7 6,326.3 35.32 LOCATOR BAKER LOCATOR 2,992 8,016.6 6,327.8 35.29 PACKER BAKER FB-1 PACKER W/ 5" SEAL BORE EXT 3.000 8,035.0 6,342.6 35.06 NIPPLE CAMCO D NIPPLE NO GO 2.750 8,046.8 6,352.2 34.92 SOS CAMCO SHEAR OUT SUB. "'ELMD @ 8047' ON SWS PPROF 2.992 5/17/200»• Other In Hole Wireline retrievable plugs,-valves, pumps, fish, etc.1 Top Depth (ND) lop Incl Top (ftKB) (ftKB) (°) Description Comment Run Date ID (in) 8,270 6,538.0 32.33 FISH Retainer Pin U GU Adapter Lost Downhole 12/1/1996 12/1/1996 8,314 6,575.2 32.22 FISH 5"Vann Gun 450' Long 7/24/1981 7/24/1981 Perfora tions & Slots Top (ftKB) Btm (ftKB) Top (ND) (ftKB) Btm (fl 7,820 7,888 6,168.1 6, 7,820 7,888 6,168.1 6, 7,920 7,922 6,248.4 6, 7,948 7,972 6,271.2 6, 7,948 7,972 6,271.2 6, 6,108 6,110 6,402.6 6, 6,166 6,172 6,450.7 6.. 6,176 6,210 6,460.7 6.. 8,180 6,214 6,462.4 6.. Cement Squeez es IPERF, 7,820.7,888 k' RPERF,, '~ 7,820-7,888 7 J PRODUCTION, ~`- 7,893 .~ PACKER, 7,908 - ;•4 -- SOZ. ..A ~II .~..~ 7,920.7,922 S Cement, 7,920 PRODUCTION, 7,922 S __ ~~ IPERF, ~-~ 7.948-7,972 ~ RPERF, ~, I 7,948-7,972 r~ PRODUCTION. ~+ 7996 ti-~,;~ LOCATOR, 8.015 PACKER, 8,017 ~' 9' - - - NIPPLE, 8,035 SOS, 8,047 - i soz, a,1o6-6,110\-. Cement, 8,108 IPERF, . 8,16&8,172 IPERF, 8,178-8.210 RPERF, ~ - 8.180b,214 y FISH, 8.270 FISH, 8,314 PRODUCTION, 29-8,863 TD, 6,880 Zone I Date at upper LL-IAx Start Date Tubing Comment Mandrel Details T.,p Oep[h Top Port (ND) Incl OD Valve Latch Size 7R0 Run Stn Top (tRCB) (ftKB) (`) Make Motlei (in) Sarv Type Type lint (psi) Run Data Com... 1 1,907.3 1,864,3 28.15 CAMCO 3.5 x 1 1 GAS LIFT GLV BK 0.156 1,225.0 6/17/2006 2 3,758.4 3,230.6 47.90 CAMCO 3.5 x 1 1 GAS LIFT GLV BK 0.188 1,265.0 6/17/2006 3 4.910.9 4.018.0 45.70 CAMCO 3.5 x 1 1 GAS LIFT DMY Broke 0.000 0.0 5/11/1985 X X X X - ,~_ i1 ~'~ ~ KUP 1A-03 CQtIOCOP~'tllll~35 ~~ ~' ,~ + ~ •• • KB-Grd (Tt) Rig Release Date ... - weii c. - - 39.01 / _ __.. _ __ ___ sm.,. ~~. -.... - HANGER, 27----- .{~ _f~ Ri:' ~~ ~I 1 ) ~ I CONDUCTOR, ~ 30.80 SAFETY VLV, ~ , 1,836 r__~ GAS LIFT, r"~' 1,907 6URFACE, '~;. 292,953 ~.~:. „ GAS LIFT, ~-`-' 3,758 GAS LIFT, -~~~ 4,911 r..~. GAS LIFT, '- 3 5,602 ~. GAS LIFT, f' ~y 5,970 _ GAB LIFT, -- y ) 6,337 GAB LIFT, ~~ 6,704 - GAS LIFT, 7,014 ~ GAS~1 8 ~'" ~~ GAS LIFT, Y I ~ 7,565 _~_ I~ SBR, 7,fi07 PACKER, 7,634 ^-]~~-5 PRODUCTION, j'- ~ 7,fi73 `~~ PRODUCTION, ~y 7so 4 7 __... _ , ~~ --~ i IPERF, -- 7,820.7,888 RPERF, 7,820.7,868 ~ .+ J PRODUCTION, ~ 7,893 _r PACKER, 7,908®a ~'-+-~~°+E ~! + SOZ, f ~~~~ 7.920.7,922 ~ ~ ~i --?. ': Cement, 7,920 PRODUCTION. I 7 922 ~ . ,~ IPERF, 7,94&7,972 ~ RPERF, , 7.9497,972 I - ~ I PRODUCTION, '~ ~~ 7,9% LOCATOR, 8,015 PACKER. 8,017 +3~''+•! ~ -7 NIPPLE, 8,035 ~~ II _J SOS, 8,047 { - snz, Mandrel D etails . _.- - - 8,108-8,110-~ ;.. :. . ._ ToP Depth Top .._- ~ Vort Cement, 8,108 (ND) Incl OD Valve Lateh Size TRO RUn IPERF, Stn Top (ttK8) (RKB) (°) Make Model (in) Serv Type Type 1i^) (psi) Run Date Com... e,1fi6-6,nz 11 7,673.3 6,051.0 37.63 OTIS 3.5 x 1.5 1 1/2 PROD DMY RM 0.000 0.0 10/5/1996 Closed IPERF, 12 7,750.4 6,112.3 37.25 OTIS 3.5 x 1.5 1 1/2 PROD DMY RM 0.000 0.0 6/22/2010 See 8,178-8,210 ~ . NOte , _ RPERF, 8.180.8,214 13 7,892.9 6,226.5 36.07 OTIS 3.5 x 1,5 1 12 PROD DMY RM 0.000 0.0 1/17/2010 14 7,921.5 6,249.6 35.78 OTIS 3.5 x 1.5 1 1Y2 PROD DMY RM 0.000 0.0 1/17/2010 I FISH, 8.270 15 7,995.6 6,310.0 35.04 OTIS 3.5 x 1.5 1 1/2 PROD DMV RM 0.000 0.0 4/27/2010 FISH. 8,314 PRODUCTION, 29-8,883 TD, 8,880 C~ WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Gas Lift Survey: 1A-03 Run Date: 3/31/2010 June 25, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1A-03 __. Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-20615-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 `-O ~ ~ l g °~ 3~ Fax: 907-273-3535 ~ ~ rafael.barr i _ ~~~~ ~~ `~°°- ~ ~' -' ''' Signed: Date: ~, 3 ` :. ~~ • I ~ /r ~_~ ____ 06/10/08 ~~ NO. 4741 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~~~~~ SUN ~ ~ 2Q0$ Log Description Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 2W-13 11970689 GLS/PROD PROFILE (0 05/27/08 1 1 3J-17 11970690 GLS/PROD PROFILE /~ - v 05/28/08 1 1 2M-08 11996642 PROD PROFILE/DEFT / / fj 06/03/08 1 1 1B-10 11994672 PROD PROFILE/DEFT G 05/31/08 1 1 1A-20 11994673 PROD PROFILE/DEFT -/ 06/01/08 1 1 1G-13 11994674 PROD PROFILE/DEFT 3 - ~(oS/5/~ 06/02/08 1 1 1A-03 11994673 PROD PROFILE/DEFT - /~py~y 06/04/08 1 1 2W-17 11996644 PROD PROFILE/DEFT ®~e/ 06/05/08 1 1 1C-125 11994677 INJECTION PROFILE -~- - c~~~~(0 06/05/08 1 1 1C-127 11994675 INJECTION PROFILE U _ ~, ~~e.®~~ 06/03/08 1 1 1F-09 11994671 PROD PROFILE/DEFT --/ ®~c/~ 05/30/08 1 1 1C-27 11994679 SBHP SURVEY ~`~ ®C/ 06/07/08 1 1 • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. RECEIVED 05/18/06 Scblumberger ¡'1AY 2 4 2006 ~ C~ & Gas wos. CcmmÍ$SÍCQ A~e NO. 3808 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~ ;,0 Kuparuk \ ftb \ ;~'i: t, 1",;'1 ¡;;:. ;.' . -.J "",,"'''it,) \;' ~-c....,~1 ~ I' t\...1 Field: Well BL Color CD Job# Log Description Date 1 G-01 (REDO) 11213744 INJECTION PROFILE ì'ðd -ì3ò 05/03/06 1 1 Q-26 11258706 PRODUCTION LOG WIDEFT IC':'\- ¡ ~d 05/06/06 1 1 A-03 11258708 PRODUCTION LOG W/DEFT I 'Is ¡ - Q 71"1\ 05/07/06 1 1Y-15A 11216294 PRODUCTION LOG WIDEFT ,e, 7( _ I q(" 05/08/06 1 1 A-02 11258709 SBHP SURVEY I.' '! e. I ~ l - ò":T \ 05/09/06 1 1R-13 11258711 INJECTION PROFILE I' "1 è \ 'X""- - ,,-r-. 05/10/06 1 2M-34 11216296 INJECTION PROFILE 0Ì:~ \ q C... - (ì--:A 05/11/06 1 2F-03 11216298 SBHP SURVEY ¡ '-;o.{. \ "Ír~ - i4--r- 05/14/06 1 2F-14 11216299 SBHP SURVEY OCt'f' ¡~"'(-, "q 05/14/06 1 1 A-06 11258712 INJECTION PROFILE ~) "'t: c... I';;'" - I} L 05/14/06 1 3Q-11 11216301 LDL ¡ '5"G-/1I7,- 05/16/06 1 1J-184 11216297 USIT r) ï (' ;:::\ ." ,', ,').:..Ji..f 05/12/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. L'_ß--- ~/9S-(o~ 9 e e ARCO Alaska, Inc.[ .... Post Office ~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 2'/'6 1215 October 7, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION ~i"~ ---1A-03 Stimulate 35-t~ -1G-12 Stimulate q~-o~ -~1 H-01 Perforate -- 2C-09 Stimulate ~q- ;~?' ~..- 3H- 14 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior .Engineer Kuparuk Petroleum Engineering RECEIVED OCT 1 1 t993 Alaska 0il & Gas Cons. Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B-6003-C AI.A~ ~L ~D ~ ~E~ATION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing ~ Alter casing 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Stimulate X Repair well 5. Type of Well: Development ~X Exploratory _ Stratigraphic _ 4. Location of well at surface 1139' FSL, 313' FWL, Sec. 5, TllN, R10E, UM At top of productive interval 1391' FNL, 1902' FEL, Sec. 5, T11N, R10E, UM At effective depth 1352' FNL, 1675' FEL, Sec. 5, TllN, R10E, UM At total depth 1313' FNL FEL UM 12. Present well condition summary Total Depth: measured 8880 feet true vertical 7059 feet Plugging Perforate Other 6. Datum elevation (DF or KB) 7. Unit or Property name Kuparuk River Unit feet 8. Well number 9. Permit number/approval number 10. APl number 11. Field/Pool River Field/Oil Pool Plugs (measured) None. Effective depth: measured 8 7 6 5 feet true vertical 6960 feet Junk (measured) Top of 450' long Vann Gun @ 8315' Casing Length Structural Conductor 8 0' Surface 2 9 2 8' Size Cemented 1 6" 200 Sx CS II 10-3/4" 1300 Sx PF"E" III & Measured depth True vertical depth 80' 80' 2953' 2683 Intermediate Production Liner Perforation depth: 8834' 7" measured 7820'-7888', true vertical. 6168'-6222' 250 Sx PF "C" 1325 Sx Class G 41 bbls AS II 7948'-7972', , 6271'-6291', Tubing (size, grade, and measured depth) 3-1/2", 9.2#, J-55 @ 8080' Packers and SSSV (type and measured depth) 8166'-8172', 6451 '-6456', 8863' 7052' 8178'-8214' 6462'-6491' RECEIVE OCT 1 1 199 ~laska Oil & t~as 0otis, Anchorage PKR: Baker FHL @ 7667', Baker FHL @ 7941', Baker FB-1 @ 8050'; SSSV: Camco TRDP-1A-ENC ~ 1835' 13. Stimulation or cement squeeze summary Refractured "A" sands on 8/22/93. Intervals treated (measured) 8178'-8210' Treatment description including volumes used and final pressure Pumped 94 Mlbs of 16/20 & 12/18 ceramic proppant into formation, fl:) was 5500 psi. 14. Reoresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 1 83 137 12 1010 270 1 38 ~ 123 154 1180 248 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas ~ Suspended __ Service Sic,~ned~/~~~' ~/~ Title Senior Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE WELL ARCO Alaska, Inc. ~ub~idlary of Atlantic Richfield Company WELL SERVICE REPORT KUPARUK PETROLEUM ENGiNEERiNG ~ --- ~ ._ -_-~ : ~-_: . ARCO Alaska, Inc.£~o.,x{, Post Office B ~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 9, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in duplicate are multiple Report of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION 1A-03 Perforate 1 E-10 Other 1H-01 Stimulate 1H-02 Stimulate 1Q-03 Perforate 1Q-08 Perforate 1Q-12 Perforate 1R-10 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Sr. Engineer Kuparuk Petroleum Engineering RECEIV D ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARSB-6003-C?, STATE OF ALASKA ~MM~L, ON ~ O, LAND ~S ~E~VAT,ON EPO T OF SUND ¥ OPEEAT ONS 1. Operations Performed: Operation Shutdown Stimulate Pull tubing Alter casing Repair well "2. Name of Operator 5. Type of Well: Development X :ARCO Alaska. Inc, Exploratory _ 3. Address Stratigraphic _ !P. O. Box 100360, Anchorage, AK 99510 Service 4. Location of well at surface 1139' FSL, 313' FWL, Sec. 5, T11N, R10E, UM Plugging Perforate X '- Other 6. Datum elevation (DF or KB) RKB 100 7. Unit or Property name Kuparuk River Unit 8. Well number 1A-03 feet At top of productive interval 1391' FNL, 1902' FEL, Sec. 5, T11N, R10E, UM At effective depth 1352' FNL, 1675' FEL, Sec. 5, T11N, R10E, UM At total depth 1313' FNL~ 1631' FELt Sec. 5~ T11N~ R10E~ UM 12. Present well condition summary Total Depth: measured 8880 feet true vertical 7059 feet 9. Permit number/approval number 81-88 10. APl number $o-029-20615 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None. Effective depth: measured 8 7 6 5 feet true vertical 6960 feet Junk (measured) Top of 450' long Vann Gun @ 8315' Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 8 0' I 6" 200 Sx CS II 8 0' 8 0' Surface 2928' 10-3/4" 1300 Sx PF"E" III & 2953' 2683 Intermediate 250 SX PF "C" Production 8 8 3 4' 7" 1325 Sx Class G 8 8 6 3' 7 0 5 2' Liner 41 bbls AS II Perforation depth: measUred 7820'-7888', 7948'-7972', 8166'-8172', 81 78'-821 4' true vertical 6168'-6222', 6271 '-6291', 6451'-6456', 6462'-6491' Tubing (size, grade, and measured depth) 3-1/2", 9.2#, J-55 @ 8080' Packers and SSSV (type and measured depth) PKR: Baker FHL @ 7667', Baker FHL ~ 7941', Baker FB-1 @ 8050'; SSSV: Camco TRDP-1A-ENC ~ 1835' Reperforated "A" sands on 7/17/93 @4 spf &180° phasing. R [[ ~" [ I V ~ D 13. Stimulation or cement squeeze summary Intervals treated (measured) 14. 8178'-8210' Treatment description including volumes used and final pressure ~,~G ~ ~ ~) N/A .... ,.. n~ ~, c.~.~ t~0ns, r~ot~m~so.o~-:~ Reoresentative Daily Average Production or In!eb~la~'Ca'- '""' -'-~ll~tt0t'Sgt~ OiI-Bbl Gas-Mcf Water-Bbl s~n~ ~'ressure Tubing Pressure Prior to well operation Subsecluent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 6 0 0 600 1500 1300 220 6 0 0 ~ 600 1500 1300 220 16. Status of well classification as: Oil X Gas Suspended ~ Service 17. I hereby/~rtify that the foregoing is true and correct to the best of my knowledge. Si~lned ¢ Title Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ARCO Alaska,/nc. Subsidiary of Atl~lt¢ Richfield Comp~my WELL OF WORK lA-03 Perforate 'A' sands DATE 7/17/93 DAY 1 CONTRACTOR ! KEY PERSON Schlumberger / Schwartz PB~ (RKB) LAST TAG (RKB) . DATE 9860' 8231 - 7/16/93 KI~ARUK RIVER UNIT WELL SERVICE REPORT AFC/CC#. SCA# FIELD COST EST. $9,754 SSSV TYPE / STATUS 998107/. 80223 ACCUMULATED COST $9,754 1A-ENC / in service 0600 . 0700 MIRU pump truck. Hold safety meeting. PT pump lines, BOPs & LUB to 2500g ...... separately. . 0815 RIH w/1 11/16" Rs., WB, CCL, MPD, 2.5" Swiv. el, 20' Titan gun. w/16' of shots. Gun arranged 4 spf, 180° phasing, alternating BH/DP charges w!t.h BH 9riented to bottom. Gun oriented 25° CCW.. from high side of casing. Start pumping at 1 bpm. 0925 S.D. pump. Total pu..mped 61 bbls..Tie in with CBL dated.7/21/81. Confh'med with Prod. Log .. ........ d.ated 1/27/82. Noted th.e original lower, two sets of perfs were s. hot 6' high and the depths noted . on the well schematic were incorre.c.t.as well as the. original tubing tally dated 5./10/85. . . . Tagged fill at 8247' rkb. and noted the tubing tail at 8047' rkb. . . 11.50.. pull up to 8.186.5' (CCL) and perf 8194'- 8210'. 1200. POOH. All shots fired. NU 2nd gun, same. as..l~t gun. . 1320 RXH and tie in. 1445 Pull.up to. 8170.5' (CCL) and p.erf.~ 8178' - 8194'. . .1.455 ..... POOH logging from 82.30' to..3700' to verify tubing jewelry..L, ost CCI., at 3700'. 1600 OOH. All shot fired. RDMO. Summary: Perforated 'A' sands from 8178' to 8210' rkb referenced to CBL dated 7/21/81 with 2.5" Titan .... guns, 4 spf, alte. mating BH/DP shots w/180° phasing at 250 CCW fi'om TDC.. Tagged ~l at 8247' rkb for 39' of rathole. Logged up from 8230' to 3700' to d.e.!ermine correct peff depths ........ .and. tubing jewelry since recompleti0n in 1985. . ..... ii i i ~ i i i i ii i iiii i i AUG 1 1 1993 Alaska Oil & Gas. Cons. Corem'issiort Anchorage .... I cHECK .... IF SUMMARY IS '" .... ' '" INCOMPLETE TtHS BLOCK CONTINUED ON BACK IXl COMPLET~ I ii I I1 I III I I I I I I I III II I IIIII IIIIII I II II iii I ii I i II I I [ II I I II I IIIIIIII Weather ITemp' Chill FaCtor I Visibility IWind Vel. [Signed Report 166 F I Fog m'° I I I I I I Illl II I I I I [ Ill II Ill I I I I I II Ill II II I I I I I I Illllll ! I REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed: Operation Shutdown Pull tubing Alter casing 2. Name of Operator 15. I ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1139' FSL, 313' FWL, Sec.5, T11N, R10E, UM At top of productive interval 1391' FNL, 1902' FEL, $ec.5, T11N, R10E, UM At effective depth At total depth 1313' FNL~ 1631' FELt Sec.5, T11N~ R10E~ UM 12. Present well condition summary Total Depth: measured 8 8 8 0' feet true vertical 7059' feet Effective depth: measured 8 7 6 5' feet true vertical 6960' feet Stimulate X Plugging Perforate _ Repair well O t h e r Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RKB 100 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1A-03 9. Permit number 81 -88/90-467 10. APl number 5o-029-2061 5 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Plugs (measured) Cement: 8765'-8880' Junk (measured) 13. Casing Length Size Structural Conductor 8 0' I 6" Surface 2 9 5 3' I 0 - 3 / 4" Intermediate Production 8 8 6 3' 7" Liner Perforation depth: measured 7820'-7888' 8166'-8172' true vertical 6168'-6222', Tubing (size, grade, and measured depth 3-1/2" J-55 set at 8048' Packers and SSSV (type and measured depth) Cemented Measured depth True vertical depth 200 Sx AS I 8 0' 8 0' 1300 Sx Fondu & 2953' 2683' 250 Sx AS II 1325 Sx Class G 8863' 7052' 41 bbls AS II 12 SPF , 7948'-7972' 12 SPF 12 SPF, 8182'-8214' 12 SPF 6271'-6291', 6451'-6456', 6464'-6491' TVD Baker FHL ~ 7634', Baker FHL @ 7909', Baker FB-1 @ 8017', Stimulation or cement squeeze summary A Sand Re-frac Camco TRDP @ 1 ~-~ ,~ ~, t t I r' Pt KEn,tv 14. Intervals treated (measured) 8166'-8172', 8182'-8214' DEC 2 8 1990 Treatment description including volumes used and final pressure See Attached WSR Alasl 0il & Gas Cons. Reoresentative Daily Averaoe Production or Iniection Data - OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 70 91 0 - 1200 120 Subsecluent to operation 3 4 0 2 3 0 0 - 1 2 0 0 15. Attachments 116. Status of well classification as: Copies of Logs and Surveys run -- I Water Injector ~ Daily Report of Well Operations ;~ Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service 120 ISi~ned ~ Title Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE ARCO Alaska, In~:: * 5ul~idi~y of Atlantic Richfield Company WELL SERVICE REPOR WELL IPBDT 3NYP, ACTOR REMARKS FIELD- DISTRICT- STATE OPERATION AT REPORT TIME ID~I~S IDATE 7-a$-9o / ~'C~ " ~ " ~0 " ~o " ?'0 " ~0 " 80" 2o " · {~CHECK THIS BLOCK IF SUMMARY CONTINUED ON SACK WeatherRelxwt !Temp' REMARKS CONTINUED: DESCRIPTION DAILY ACCUM. TOTAL CAMCO i OTIS ~"~,I~ .,~ i scHLUMBERGER I DRESSER.ATLAS ...... DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER B. J. HUGHES Roustabouts Diesel Methanol .... Supe~ision ~/~ ~ ~or O~'~wc~s ~ 4 ~ O~ ...... Pr~Job Safety M~ting AFL ~ ~O~ql TOTAL FIELD ESTIMATE ARco Alaska, inc~(~r Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 15, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate is an Application for Sundry Approval on the following Kuparuk well. Well Action Anticipated Start Date 1A-03 Stimulate June, 1990 If you have any questions, please call me at 263-4241. Sincerely, P. S. White' Senior Operations Engineer cc: J.R. Brandstetter ATO 1120 w/o attachments L. Perini ATO 1130 KOE1.4-9 RECEIVED JUN 1 9 1990 Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieidCornp~ny ' STATE OF ALASKA C"'~ !%ISSION~v,,v, A~,ASKA OIL AND GAS CONSERVATION APPLICATION FOR SUNDRY APPROVALS ORIGINAL 1. Type of Request: Abandon 2. Name of Operator ARCO Alaska. Inc. 3. Address Suspend _ .5. Type of Well: Development .~_ Exploratory _ Stratigraphic _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate X Pull tubing _ Variance _ Perforate _ Other _ 6. Datum elevation (DF or KB) P. O. Box 100360, Anchorage, AK 99510 Service 4. Location of well at surface 1139' FSL, 313' FWL, Sec.5, T11N, R10E, UM At top of productive interval 1391' FNL, 1902' FEL, Sec.5, T11N, R10E, UM At effective depth .. RKB 100 7. Unit or Property name feet At total depth 1313' FNL~ 1631' FEL~ Sec.5~ T11N~ R! 12. Present well condition summary Total Depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical measured true vertical Length 80' 2953' 8863' measured OEp UM 8880' feet Plugs (measured) 7059' feet Cement: 8765' feet Junk (measured) 6 9 6 0' feet None Size Cemented 1 6" 200 Sx AS I I 0 - 3 / 4" 1300 Sx Fondu & 250 Sx AS II 7" 1325 Sx Class G 41 bbls AS II 7820'-7888' 8166'-8172' true vertical 6168'-6222', Tubing (size, grade, and measured depth 3-1/2" J-55 set at 8048' Kuparuk River Unit 8. Well number 1A-03 9. Permit number 81 -88 10. APl number so-029-2061 5 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 8765'-8880' Measured depth True vertical depth 80' 80' 2953' 2683' 8863' 7052' 12 SPF , 7948'-7972' 12 SPF 12 SPF , 8182'-8214' 12 SPF 6271 '-6291', 6451 '-6456', 6464'-6491' Packers and SSSV (type and measured depth) Baker FHL @ 7634', Baker FHL @ 7909'~ Baker FB-1 @ 8017' 13. Attachments Description summary of proposal _ Refrac A Sand 14. Estimated date for commencing operation ' ' 15. July. 1990 15. If proposal was verbally approved RECEIVED TVD JUN 1 9 1990 Alaska 0il & Gas Cons. COlp~ Anchorage BOP sketch Camco TRDP @ 1836' Detailed operation program X Suspended Status of well classification as: Oil x Gas Name of approver Date approved. Service 17. I hell,by certify t_hat the f~egoing is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance m Mechanical Integrity Test_ Subsequent form require JApproval No. Approved by the order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner Form 10-403 Rev 5/03/89 Approved Copy SUBMIT I~! TI~PI'ICATE Well 1A-03 Application for Sundry Approval June 12, 1990 It is proposed to refracture Well 1A-03's A Sand. The well will be refractured with gelled water and 16/20 Carbolite pumped at 20 BPM, and no workover fluid will be used. No BOP is required. A surface manifold with tanks will be present and used to produce the well for the first few days. The expected bottom hole pressure of the A sand is 3200 psi. RECEIVED JUN 1 9 1990 Alaska 01t & ~as Cons, C:ommission Anchorage Messrs Gibbs and Hutchins 6/15/90 Page 3 Kuparuk Well 1A-03 'A' Sand Re-Fracture Procedure Charge Code: AFE No. K80941 PRE. FRAC SLICKLINE 1. Obtain a 24 hour well test. 2. MIRU Slickline Unit. 3. RIH with 2" gauge ring and tag bottom. 4. RIH with 2.79" gauge ring to check-for scale. NOTE: If scale is found consult with Operations Engineering. 5. RIH and pull GLV's, OV, CV's and DV at 1908', 5604', 7012', 7565', 7783', 7926', and 7954' MD RKB. 6. Replace with DV's @ 1908', 5604', 7012', 7565', and 7783'. 7. Run tubing monitor Petredat gauge to 7926' RKB. 8. Run casing monitor Petredat gauge to 7954' RKB. NOte: Petredat gauges should be programmed to record data in the following sequence. . 10. 11. Time Period Time Increment 16 Hours I Hour 10 Hours 15 Seconds' Remaining Memory I Hour The time periods are set up so that the fracturing operation will begin approximately when the Petredat gauge begins to record data every 15 seconds. Amount of I hour sampling can be adjusted as necessary to coordinate pre-frac slickline work with start-up of the fracture treatment. RIH with Standing Valve and set in CAMCO 'D' nipple at 8037'. Pressure test tubing to 4500 psi. Pull SV. RDMO Slickline Unit. NOTE' Fill was 'last tagged on 09/29/89 at 8259' MD RKB'. Consult with Operations Engineering if fill is tagged any higher to evaluate if a pre-refrac CTU cleanout is required. Obtain a 24 hour well test. R E ¢ E IV D J Ubi 1 9 1990 Alaska 0il & Gas Cons. Gomm~on Anchorage Messrs Gibbs and Hutchins 6/15/90 Page 4 PROPPANT FRACTURE TREATMENT 1 2. RU fracture equipment. Install "Tree Saver". Pressure up 7" annulus to 3500 psi. Carry out all fluid quality control procedures (On-site Operations Engineer). Obtain samples of: - Clean proppant - Pre-pad, pad, 2, 6, 10, & 12 ppa stages, and flush 14. Record proppant weight before and after the frac. Pump the 150 bbi pre-pad. Shut down for ISIP and 10 minute pressure fall-off. Calculate tubing and perforation friction from step rate data. 15. Pump fracture treatment per the attached schedule: WHTPE = 3700 psi Fracture Gradient = 0.77 - 6350' TVD Tubing Friction = 160 to 250 psi/1000' - 8000' MD (Dependent on vendor selected) Recommended Max. WHP = 6000 psi If treating pressure during the job exceeds 5500 psi, reduce the rate to 15 bpm. 16. Rig down frac equipment. POST FRAC 17. RU Slickline Unit and pull Petredat gauges. 18. Follow attached flowback schedule. After well has completed flowback, obtain a 24 hour test. The well should be left on °A' Sand only production for about 3 weeks. Obtain a 24 hour well test at one week intervals. Contact Operations Engineering for a new gas lift design following evaluation of the increased productivity. RE¢'EIVED JUN 1 9 1990 Alaska 0il & Gas Cons. Commission Anchorage Me~srs Gibbs and' Hutchins 6/15/90 Page 5 1A-03 REFRACTURE TREATMENT AFE #K80941 WELL SPECIFICATIONS Wellhead (FMC Gen III) SSSV (Baker FVL) GLM's (CAMCO KBUG 1") GLM's (Otis 1.5") Packer (Baker FHL) Packer (Baker FHL) Packer (Baker FB-1) "NOGO" (CAMCO 'D') Tubing Tail A Sand Perforations 12 SPF Tagged Fill PBTD Maximum Hole Angle Hole Angle Across Perfs TUbing Casing Flush to top of A Sand Perfs TVD Depth to Top A Sand Perf NOTE: All Depths are MD-RKB 5000 psi MAWHP 1836' 1908',3759'., 6338', 6704', 7565', 7674', 8028'. 7634' 7909' 8017' 8037' 8047' 8166-8172', 8259' 8765' 48° at 3800' 35° 3 1/2", 9.3 Ib/ft 7", 26.0 Ib/ft 74 bbl 6353' 4911', 5604', 7012', 7347', 7783', 7926', 8182-8214' 5970', 7565'. 7954', (1) (2) FRACTURING FLUID SPECIFICATIONS Base fluid to be clean fresh water with 2% KCI and Biocide added. - water samples to be taken from each tank prior to job and checked (actual tests will be worked out with vendor once selected) A 40# HPG fluid with a non-delay.ed Borate crosslinker is recommended. Options include: EG YF240 Halliburton Bora-Gel BJ Titan Terra Frac RXL II B Nas~ 0it & G~S Gons. STAGE _ -FLUID DESCRIPTION KUPARUK WELL 1A-03 °A' SAND REFRACTURE PUMP SCHEDULE GELLED WATER FRACTURE TREATMENT 6/12190 CLEAN VOLUME PUMP RATE PROP. CONC. PFIOPPANT PROPPANT WT DIRTY VOLUME BBLS Bt:WI PPG DESCRIPTION LBS STG/CUM HIT PERFS BBLS GW PRE-PAD 80.0 20 0 -- 0 80/80 25.0 25 0 - - 0 25 105 20.0 20 0 - - 0 20 125 15.0 15 0 -- 0 15 140 10.0 10 0 -- 0 10 150 -- SHUT DOWN 10 MINS FOR ISIP; TUBING AND PERFORATION FRICTION CALCULATIONS; FRACTURE CLOSURE PRESSURE MEASUREMENT GW PAD 600.0 20 0 - - 0 600 / 750 GW w/2 PPG 73.5 20 2 16/20 M CARBO-LITE 6176 80/ 830 GW wi4 PPG 42.5 20 4 16/20 M CARBO-LITE 7141 501 880 GW wi6 PPG 47.5 20 6 16/20 M CARBO-LITE 11958 60 / 940 GW wi8 PPG 51.8 20 8 16/20 M CARBO-LITE 17389 70/ 1010 GW w/10 PPG 55.5 20 10 16/20 M CARBO-LITE 23322 801 1090 GW w/12 PPG 45.8 20 1 2 16/20 M CARBO-LITE 23076 70 / 1160 SUCK DIESEL FLUSH 72.0 +SV 20 0 - - 0 72 ! 1232 74 224 824 904 954 1014 1084 1164 TOTAL GELLED WATER =- 1029.0 BBLS TOTAL CLEAN DIESEL = 37.5 BBLS TOTAL SLICK DIESEL = 72.0 BBLS +SV 16/20 M CARBO-LITE 89O61 LBS NOTES: Stages I through 8 are Gelled Water. Stages 1&2 are Gelled Water with 5% Arctic Diesel, 40 lbs/1000 gal silica flour and enough breaker for a 4 hour break. Stage 2 should be increased to 650 bbl if on-site personnel decide to pump a~diesel or non-crosslinked flush after Stage 1. Stages 3 through 8 are'Gelled Water with 4 hour breaker and without diesel or silica flour. Stage 9 (flush) should include a volume adjustment for surface equipment between the wellhead and densimeter. The rate during the final 15 bbl of the flush (i.e. after 12 ppa stage has hit formation) should be gradually reduced to zero. This job is intentionally underflushed by 2 bbl. The blender tub should be bypassed at flush. All fluids should be maintained at + 90° F on the surface. WELL 1A-03 FLOWBACK SCHEDULE The following flowback procedure for water-based gel fracture stimulations has been discussed and approved by Operations Engineering (KOE), Facility Engineering (KFE) and Production Operations. Deviations from or modifications to this procedure/piping installation are expected, but they should be reviewed/approved by each of these groups. 1. Establish baselines for comparison by visually inspecting choke and performing NDT of erosion prone areas, immediately down stream of choke, all elbows and all tees, that will be exposed to flowback fluids. Document these inspections on the attached Flowback Log. 2, Based on the NDT results on the choke and piping, replace as necessary after reviewing with Corrosion Engineering. 3. Check that modified 6" S-riser has been installed. 4. Nipple up modified S-riser. Perform service leak test. Install erosion probe that is tied into wellhead safety system. If the current production choke is not a 4"x3" choke, a 4"x3" choke should be installed if the necessary parts are available. NOTE: There is an increased frequency monitoring schedule if the 3"x3" choke is used. , Open well up flowing .to the test separator, the initial targeted nominal rate should be 300 BLPD. Set Iow flowrate alarm for 50 BLPD. Set high flowrate alarm on test separator for 600 BLPD for a 3" choke or at 1100 BLPD for a 4" choke. On bottoms up, verify that gel is broken. If excessive proppant, or unbroken gel is present,.SI well and contact KOE Coordinator. Do not exceed 500 BLPD for the first 12 hours of flowback. After the first 12 hrs, open the choke and flow well at 500 BLPD for the next 12 hrs. Record rates, choke settings and WHPs on Flowback Log. . After the first 24 .hrs of flowback, decrease wellhead pressure in 50 psi increments at regular time intervals (minimum two hours) until the-well is producing at header pressure. LIMIT THE FLOW RATE INCREASE TO NO MORE THAN 750 BLPD IN A 24 HOUR PERIOD. Reset high flowrate alarm to stay below erosional velocity as predicted by the table provided by Corrosion Engineering and shown below in step 10. Alarm settings should be based on the maximum flowrate fOr the average GLR from the first 24 hrs of flow. If GLR changes again by more than 250 scf/bbl, change high flowrate alarm as appropriate. Record rates, choke settings, and WHP's during the flowback period on the Flowback Log. Take BS&W samples at bottoms up after every choke change and/or every 8 hrs and record results on the Flowback Log. If excessive proppant or unbroken gel is found contact KOE Coordinator. RECEIVED Page 1 JUN 1 9 1990 Alaska 0il & Gas Cons. Commission Anchorage m Inspect the choke internals visually and the erosion prone areas, down stream of the choke and the S-riser, twice during the first week and weekly thereafter until it is confirmed that an erosive condition does not exist. Maximum flowrates should be limited to those specified in the following table, if these maximums are exceeded choke the well back and inspect the erosion prone areas. G~ 4" CHOKE 3"CHOKE LIQUID MAXIMUM MAXIMUM RATIO 300 SC~BBL 3500 BLPD 2000 BLPD 500 2800 1600 1000 2000 1100 1500 1500 800 2000 1300 700 3000 1000 500 5000 700 400 . Flowrates are to be increased over the maximums outlined in the previous table only after a non-erosive condition is verified through inspection and confirmed by Corrosion Engineering. Document on the Flowback Log. If erosion in the piping or choke body is identified, the well will be choked back to the previous non-erosive rate until some indication is obtained that the solids production has decreased and an assessment of the damage has been made. Appearance of any erosive conditions will trigger more intensive monitoring than stated above. 9. Once the FTP has returned to normal line pressure, send all Flowback Logs and other pertinent information to KOE Coordinator. NOTE: Documentation of choke changes, all inspections, shake out results, etc., in addition to the flow data on the Flowback Log, will be very helpful in further refining the erosion potential and appropriate monitoring plans. Page 2 RECEIVED JUN 1 9 1990 Alaska Oil & Gas Cons. (;ommission Anchorage KUPARUK RIVER UNIT STIMULATION FLOW BACK DATA SHEET / LOG WELL: 1A-03 DATE OF STIMULATION: IS WELL FLOWING TO:_ SEPARATOR OR X TANKS DATE OF PRE-FLOW BACK CHOKE INSPECTIQN: DATE OF PRE-FLOW BACK NDT INSPECTIQN: RESULTS OF PRE-FLOW BACK INSPECTIONS: TEST PRE-FLOW BACK SHUT IN TUBING PRESSURE.; PSI DATE AND TIME WELL OPENF~.D: OPEN WELL UP FLOWING TO THE TEST SEPARATOR, TARGETED NOMINAL FLOWRATE SHOULD BE 300 BLPD. VERIFY SETTINGS FOR FLOWRATE ALARMS ON TEST SEPARATOR. DO NOT EXCEED 500 BLPD FOR THE FIRST 12 HOURS OF FLOWBACK. OPEN CHOKE AND FLOW WELL AT 500 BLPD FOR THE SECOND 12 HRS. AFTER FIRST 24 HRS, DECREASE FTP BY 50 PSI AT REGULAR TIME INTERVALS (MINIMUM TWO HOURS) UNTIL THE WELL IS PRODUCING AT THE CURRENT HEADER PRESSURE. LIMIT FLOWRATE INCREASES TO A MAXIMUM OF 750 BLPD IN ANY 24 HOUR PERIOD. INSPECT THE' CHOKE INTERNALS VISUALLY AND THE EROSION PRONE AREAS, DOWN STREAM OF THE CHOKE AND THE S-RISER, TWICE DURING' THE FIRST WEEK AND WEEKLY THEREAFTER, UNTIL IT IS CONFIRMED THAT AN EROSIVE CONDITION DOES NOT EXIST. INSPECTION FREQUENCY IS DOUBLED FOR 3" CHOKES. MAXIMUM FLOWRATES SHOULD BE LIMITED TO THOSE SPECIFIED IN THE FLOWING CHART, IF THESE MAXIMUMS ARE EXCEEDED CHOKE THE WELL BACK AND INSPECT THE EROSION PRONE AREAS. GAS 4" CHOKE 3"CHOKE LIQUID MAXIMUM MAXIMUM RATIO ~ .~ 300 SCF/BBL 3500 BLPD 2000 BLPD 500 2800 1600 1000 2000 1100 RECEIVED 2000 1300 700 3000 1000 500 5000 700 JUN 1 9 3990 400 Alaska 0il & Gas Cons. (;ommission Anchorage KRU STIMULATION FLOW BACK LOG WELL: 1 A- 0 3 PAGE NO. OF DATE TIME LIQUID RATE BLPD GAS RATE MCFD WATER CUT FTP CHOKE % PSI 64THS COMMENTS ii II IIIII i i ii i iii iii ! I i I Comments should include, but not be limited to, notes on choke changes, choke inspections and changes in high flowrate alarm. Inspect the choke internals visually and the erosion Prone areas, down stream of the choke and the S-riser, twice during the first week and weekly thereafter until it is confirmed that an erosive condition does not exist. Maximum flowrates should be limited to those specified in the following table, if these maximums are exceeded choke the well back and inspect the erosion prone areas. ~ ~ 4" CHOKE 3"CHOKE _o. ~ LIQUID MAXIMUM MAXIMUM ~' c:::c-- 1"1'3 RATIO FLOW RATE ~ ~ ~ ~:~ ~ 300 SCF/BBL 3500 BLPD 2000 BLPD =~o ~ --' r'~ 500 2800 1600 ~ ~ ~ -.-, 1000 2000 1100 · ~ ~ ,~ 2000 1300 700 '::, c:~ r'T'l 3000 1000 500 ARCO Alaska, inc. AncO, A-,ska 99510-0360 ~-Telephone 907 276 1215 September 2, 1986 · Mr. C.V. atterton ...: ,. Alaska Oil and Gas Conservation ConTnission 3001 Porcupine Drive _. Anchorage, Alaska 99501 Subject- Kuparuk River Field . Production Surveys _ _ -- Dear Mr. Chatterton: In compliance with Rule 9 of Conservation Order Number 173, Kuparuk River Field Rules, we are hereby submitting production survey informa- tion for the second quarter of 1986. Production survey information consists of production logs and production tests as identified in Attachment 1. Production logs (spinners} identified in this attachment will be sent under separate cover. Note that several initial spinners not previously submitted to the State are being submitted at this time. : : . ._If you have any questions concerning the infor~nation reported, please contact me at {907) 263-4935. Sincerely, V. L. Ferguson Senior Operations Engineer VLF-pg:O074 · ~i~C~, Alaska. :nC. is I Sub~&e,,v of Atiaflt.;cRichfieidCom~any ~ STATE OF ALASKA ALASKAuIL AND GAS CONSERVATION C(~iv, MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOq / 1. Status of Well Classification of Service Well ~' OIL Yi~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-88 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20615 4. Location of well at surface 9. Unit or Lease Name 1139' FSL, 313' FWL, Sec.5, TllN, RIOE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1391' FNL, 1902' FEL, Sec.5, TllN, RIOE, UM lA-3 At Total Depth 11. Field and Pool 1313' FNL, 1631' FEL, Sec.5, T11N, RIOE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0il Pool 100' RKBI ADL 25647 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 07/03/81 07/16/81 07/24/81 w N/A feet MS LI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 8880 'MD ,7059 'TVD 8765 'MD ,9960 'TVD YESJ~] NO [] 1869 feetMD 1650' (Approx) , 22. Type Electric or Other Logs Run .... D IL/BHCS, CBL/VDL/CCL/GR, FDC/CNL/GR/Cal, GR/CBL, Gyro, CRT 23. CASING, LINER AND CEMENTING RECORD ..... , ........ SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 1~*' 65.0# H-40 Surf 80'1 24h' ' 20"0 sx Permafrost "' 10-3/4" '45.5# K-55 Surf 2953' 13-3/4" i300 sx Fondu & 250 sx A.c II 7" 26.0# K-55 Surf 8863' 8-3/4" 1325 sx Class G & 41 bbl.~ AS II , , '24. Perforations open to P;oduction (MD+TvD of Top and Bottom and 25. TUBING REcoRD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7820' - 7888' 3-1/2'" 8081 ' 7667',7941', & 8050'i 7948' - 7972' w/12 spf 8166' - 8172' 26. ACID, FRAcTuRE', CEMENT SQUEEZE, ETC. ,, 8182' - 8214' DEPTH INTERVAL'(MD) AMOUNT& KINDOF MATERIAL USED 8108' - 8110' 100 sx Class G .... .... 7920' - 79'22' 100 sx Class G , Fractured well w/2 :7 bbl s qelled dies. el ............................ 12676# of 100 mesh .l& 20/40 sand a~ p. roppant 27. PRODUCTION TEST Date First Production Method of Operation (Flowing~ gas lift, etc.) 12/25/81 F1 owing Date of Test Hours Tested PRODUCTION FOR OIL-BBL ' 'GA's-McF "WATER-BBL cHOKE SIZE GAS:oIL RATIO 1/28/82 11 TEST PERIOD I~ 1382 643 -- 176/64 455 'F~'10w'Tubing Casing Pressur'e' CA'LCULATED OIL~BBL GAs-MCF " wATER-BBL' OIL GRAV'ITY-API'(corr) Press. 157 -- 24-HOUR RATE I~ 3062 1393 -- 23.7 , , 28. CORE DATA ........ Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED JUN 1 8 198 Alaska 0il & Gas Cons. C0mmJssio~ Anchorage , .... , , Form 10-407 * NOTE: Wel 1 was recompl eted 5/12/85. WC1/039 Submit in duplicate Rev. 7-1-80 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 Sands 7783' 6138' N/A Top Upper Sands 7819' 6167' Base Upper Sands 7868' ~206' Top Lower Sands 8158' ~444' Base Lower Sands 8213' ~490' Base Kuparuk Sands 8258' 5528' ., 31. LIST OF ATTACHMENTS Workover Well Hi story 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ,/~_~~/ ~~)~... _, Associate Engineer ~. Signed , /itle____ __ uate ~.~-/(~ '~ 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 ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned. or Sold. "Final Rel3ort" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District Icounty °r Parish ITM Alaska Alaska North Slope Borough Field IL ...... Upi, IWell no. Kuparuk River ADL 25647 lA-3 W/O Auth. or W.O. no. ~Title AFE 603015 I Recompletion Pool #102 API 50-029-20615 Operator ARCO Alaska, Inc. Spudded or W.O. begun Workover 5/lO/85 Date and depth as of 8:00 a.m. 5/11/85 thru 5/13/85 IA.R.Co. W.I. 56.24% IDate 4/30/85 Complete record for each day reposed Iotal number of wells (active or inactive) on this est center prior to plugging and bandonment of this well our I Prior status if a W.O. I 1230 hrs. 7" @ 8863' 8320' Fsh, TIH w/scrpr 10.0+ ppg NaC1/NaBr Drl on retnr @ 7945'. 8320'. Drl on btm plug @ 8144' & push to btm @ 7" @ 8863' 8320' PBTD, RR Crude w/diesel cap RIH to PBTD w/bit & scrpr, circ hole cln. RU DA, re-perf 7948'-7972' & 7820'-7888'. Rn 6.125" GR/JB. Rn & set Bkr FB-1 pkr @ 8017'. LD DP. RIH w/3½" CA, stab into FB-1 pkr, space out, drop ball, lnd hgr. Press tbg to 2500 psi. Set hyd pkrs & tst tbg. PU & shear SBR. Tst ann to 2500 psi. Set BPV. ND BOPE, NU & tst tree to 250/5000 psi. Displ well to diesel & crude. SITP = SICP = 250 psi. Tst SSSV & orifice; OK. Shear out ball w/3600 psi. Set BPV. RR @ 2400 hrs, 5/12/85. Old TD New TD PB Depth Released rig Date K nd of rig 2400 hrs. 5/12/85 C~assifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil. Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data 8320' PBTD Rotary Well no. Date Reservoir P[oducing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparati .... d dis;rib~tion, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. RECEIVED AR3B-459-3-C Drilling Superintendent JUN 1 8 1886 las they are prepared for each well. Alaska 0il & Gas Cons. Division ~f AtlantlcRIchfieldCompany ARCO Oil and Gas Company Well History - Initial Report - Daily Inst~acttone: Prepare and submit the "lniltll Rlllm'f' on the flat Wednesday after a well is spudded or workover operations are started. Daily wori~ prior to Sledding should be summarized on the form giving inclusive dates only. District ICounty. parish or borough Alaska I North Slope Borough Alaska Field ILease or Unit I~Vell no. Kuparuk River I ADL 25647 / lA-3 W/O I Title I Recompletion Auth. or W.O, no. AFE 603015 Pool #102 API 50-029-20615 Operator ARCO W.I, ARCO Alaska, Inc. 56.24% Workover 4/30/85 1230 hrs. Date and depth Complete record for each day reported as of 8:00 a.m. 5/01/85 5~02~85 5/03/85 5~04~85 thru ' 5/06/85 5/07/85 5/08/85 5/09/85 7" @ 8863' 8765' PBTD, Pull'g GLV's & replace w/dummies Accept ri~ @ 1230 hfs, 4/30/85. Bleed press off ann; no holding. Pull GLV's & repl w/dummies. 7" @ 8863' 8765' PBTD, Circ NaC1 Pmp 10.0 ppg brine dn ann. Pmp BridgeSal pill. 7" @ 8863' 8765' PBTD, POH w/tbg & chg colrs 10.0 ppg NaC1/NaBr Circ brine, set BPV, ND tree, NU & tst BOPE. POH & chg out colrs to AB Mod BTC. Shear out SBR. Pmp pill, 7" @ 8863' 8765' PBTD, ND BOPE 10.0+ ppg NaCl/NaBr POH w/tbg & chg out colrs w/AB Mod. RIH, rel pkr. Rn CET log. RIH w/perf gun, 4 SPF, 90° phasing, perf 8108'-8110' & 7920'-7922'. Set BP 8130'. RIH w/RTTS, set @ 7986'. Pmp I00 sx C1 "G" w/l% CFR-2, .3% Halad-24 & 5% KC1, stage in. POH w/RTTS. RIH w/BP, set @ 7930'. Rn 2n( BP, set @ 7895'. RIH w/3½" DP & stinger, tag BP. Sqz perfs @ 7920'-792~ w/lO0 sx C1 "G" w/l% CFR-2, .3% Halad-24 & 5% KC1. POH w/stinger. Prep to settemp BP & chg out tree. 7" @ 8863' 8765' PBTD, ND BO?E 10.0+ ppg NaC1/NaBr Set BP @ 300'. ND BOPE & tbg head. 10-3/4" x 7" pack-off seals blew out Tbg head & BOP's reinstl'd. Tst BOPE. RIH &retrv BP. Set BP @ 7700' tst. POH. ND BOPE. Prep to chg out tbg head. 7" @ 8863' 8765' PBTD, Rig repair 10.0+ ppg NaC1/NaBr ND BOPE, chg FMC tbg head to 5000 psi equip. RIH, tag cmt @ 7909'. Drl on cmt retnr. Tst BOP. RIH, retrv BP. 7" @ 8863' 7945' EZ Drl, GIH w/bit 10.0+ ppg NaC1/NaBr Drl CR @ 7909'. Drl cmt. Drl CR #2 @ 7945' The above is correct For form pr~p~'r~tio, and ~li~t~o~tio~, ' see Procedures Manual, Secti&n 10, Drilling, Pages 86 and 87. Date 6/12/85 RECEIVED ITitle Drilling Superintendent AR3B-459-1-D JUN 1 8 lgSG laNsU~hbe~raa/eI dailywell hist°ry fprepared for each ....... well.secutlvely Alaska 0il & Gas Cons. C0mm)~m0n Anch0m.Oe iP ag].e no. ARCO Alaska, Inc(' Post Officebox 100360 Anchorage, Alaska 99510-0360 '~ Telephone 907 276 1215 RSTU:RN TO=- DATE= 10-31-85 TRANSMITTAL NO = 5421 'KUPARUK OPERATIONS ENGINEERING R~COm~S' CLEaK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HERI~WITH ARt~ THE FOLLOWING IT~4S. RECEIPT AND R~TURN ON~ SIGNED COPY OF T~IS TI~%NSMITTAL. FINALS/ SCHL/ CEMENT <ON~ * OF EACH> ~~3 / CEMENT. EVALUATION TOOL '~lB-4'~ .C~:MENT EVALdATION TOOL "X,lR-9 / CF.T LOG 1R-10~ ~CET LOG ~R-11 / CET/C~L '~1R-12/ CET LOG ~A-13- CBL/VDL k2A-13/ CET/C~L '~U-3~ C~ENT EV~UATION TOOL ~2U-10/ CEMENT EVALUATION TOOL '~2Z-1~ CET LOG ~2Z-14 ~ CET LOG ~2Z-15~ C~T LOG 2Z- 16'- C~T LOG ~3B-4/ C~NT ~V~UATION TOOL %%3B-12-- C~T LOG "3B-12 / CEMENT EV~UATION LOG W/ AC ~3B-16~ CEMENT ~V~UATION TOOL ~3C-9/ CET LOG ~3C-10~' C~T LOG PL~.ASE ACKNOWLEDGE 05-04-85 RUN %1 7468-8287 05-28-85 RUN %1 7200-7995 07-17-85 RUN %1 5990-8084 07-16-85 RUN %1 7500-8632 07-25-85 RUN %1 5744-7129 07-26-85 RUN %1 4992-8144 07-13-85 RUN %1 6388-7554 07-24-85 RUN %1 6382-8032 03-26-85 RUN %2 6100-6600 05-19-85 RUN %1 5450-6950 07-09-85 RUN %1 6000-8411 07-09-85 RUN %1 5500-8173 07-01-85 RUN %1 2700-6617 07-01-85 RUN %1. 6100-8011 05-31-85 RUN %'1 6000-7743 07-14-85 RUN %2 6139-8089 07-06-85 RUN %1 5500-8096 05-09-85 RUN %1 6186-7762 07-14-85 i~UN %1 7485-8210 07-14-85 RUN %1 8190-8805 RECEIPT ACKNOWLEDGED: DISTRIBUTION: BPAE DRILLING*BL W. PASHER B. CURRIER L. JOENSTON , EXXON CHEVRON MOBIL P~ILLIP$ OIL D & M NSK CLERK*BL J. RAT~MELL -An~_~ ... ~s Cons._.._ .Co= ,~,miSsion ~ so~o / s~ UNION VAULT/~O* FILMS ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfielclCompany ARCO Alaska, Inc.' Post Office BOx 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 09-18-85 TRANSMITTAL NO: 5358 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCttORAGE, AK 99510 TRANSMITTED HER~1NITtt AKE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE P,I~CEIPT AND RETURN ONE SIGNED COPY OF T~tIS TRANSMITTAL. PRESSURE DATA SEQU]~NCk' OF EVENTS lA-3 C1 SAND PBU 08-11-85 DKESSER ATLAS --'-~I_B-2 PBU C-1 SAND 08-05-85 DRESSER ATLAS 1C-5 PBU 07-29-85 Dt{ESSER ATLAS '"~2H-1 A SAND POST FRAC PBU 08-24-85 DRESSER ATLAS SEQUENCE OF EVENTS FRUM WELL SERVICE REPORTS -"~iG-11 SlBhP & I, JISC. 09-09-85 1G~-ll SIBHP & MISC. 09-10-85 CAMCO CAMCO KUi~-.~RUK WELL PRESSURE t~EPORT ENVELOPE DATA ~ lB-?. PBU C-1 SAND 08-05-85 ~ 1C-~ PBU 07-29/30-85 DRESSER ATLAS DRESSER ATLAS RECEIPT ACKNOWLEDGED: BPAE* B. CURRIER CHEVRON* D & M* DRILLING L. JOHNSTON MOBIL* N~K CLEKK DISTt{IBUTION: W. PAStiER EXXON PHILLIPS OIL* J. RATHMELL* DATE: Alaska Oil ,z ~ ,, STATE OF ~ASK~a SOHIO* UNION* K. TULIN/VAULT ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc.~, Post Offid( ~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DAT~:09-05-85 TkANSMITTAL NO:5332 RETURN TO: ARCO ALASKA, INC. KUPARUK. OPERATIONS ENGINEERING RECORDS CLEkK ATO-1115B. P.O. BOX 100360 ANCHORAGE, AK 99510 .TKANSMITTED HERESdITH ARE THE FOLLOWING ITDYlS. kECEIPT AND RETURN OMb SIGNED COPY SEQUENCE OF EVENTS PRESSURE DATA 1H-3 / PBU 03-07-85 2A-l-- 'C' SAND PBU 08-03-85 2B-13-' 'C' SAND PBU 08-01-85 2C-U 'A' SAND PBU 08-16-85 2V-2 - 'A' SAND PBU 07-27-85 2V-5 ~ 'A' SAND PBU 06-25-85 PLEASE ACKNOWLEDGE OF THIS TRANSMITTAL. SEQUENCE OF EVENTS FROM ia-8 ~ bBHP & MISC. la-5 PBU & MISC. la- 3-'"' PBU la- 3--- PSU lB-2-- 'C' SAND PnU 1B-2~-- 'C' SAND PBU lB-5 ~ ~TATIC TEMP.LOG 1E-21-' RUN BHP & MISC 1F- PBU 'A' & 'C' 1F-5 / P~U 1G-15~' 'C' SAND PBU 1G-15~ 'A' SAND Pi~U 1G-15/ 'C' SAND PBU 1~-1o.-~ $HP & MISC. 1R-9/ BHP & Mibc. !R-12 ..-- BHP & MISC. 2A-l~ 'C' SAND PBU 2A-1'/ 'A' SAND BHP 2A-1-~ 'C' SAND PBU 2A-13-' BHP '& MISC. 2B-13~ 'A' SAND BBP 2B-13z 'C' SAND PBU 2B-13-~ DATA FROM Blip 2B-13~ 'C' SAND PbU 2C-8" PBU 2G-16" PBU 2G-16/ PBU RECEIPT ACKNOWLEDGED: BPAE B. CURRIER CHEVRON D & M WELL SERVICE REPORTS/PRESSURE DATA bAND (IBLTD) & MISC. SURVEY 08-22-85 08-14-85 08-12-85 08-11-85 08-05-85 08-06-85 08-15-~5 08-03-85 08-18-8 5 08-17-85 08-10-85 08-06-85 08-09-85 08-15-85 08-15-85 08-19-85 08-04-85 08-04-85 O8-03-85 0~-25-85 08-02-85 08-02-85 08-03-85 08-01-85 08-17-85 08-17-85 08-1~-85 BUTION: D~ILLING W. PASHER L. JOHNSTON EXXON [,~OBIL P~ILLIPS OIL NbK CLERK J. kAk'~I, iELL *PLEASE NOTE--DISTRIB- . NEXT PAGE. so~o "~ c~,~ ~ ~ 'l~~L ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, inc. (~' Post OfficeB~_ 100360 Anchorage, Alaska 99510-03(,0 Telephone 907 276 1215 DATE: 09-09-85 TRANSMITTAL NO: 5337 I{ETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK A~'O-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 ~ T~UkNSMITTED hEt<EWI%'H ~RE THE FOLLOWING ITE~IS. ~EASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. 1A-3 ~- 8/11/85 1G-15/ 8/.9-10/85 1Y-8 J 8/8/85 1Y-12j 8/11/85 2G-16 '/ 8/17/85 2U-1 ~" 8/23/85 PBU "C" SAlaDS PBU "C" SANDS FLOWING PRESSURE GRADIENT "A" & "C" SDS FLO~ING PRESSURE GRADIENT "A" & "C" SDS FLOWING PRESSURE GRADIENT & PBU PBU "C" SANDS RECEIPT ACKNONLEDGED: BPaE* B. CURRIER CHEVRON* D & M* DRILLING L. JOHNSTON HOBIL* NSK CLERK DIbTRIbUTION: ~. PASBER EXXON PHILLIPS OIL* J.. RATHMELL* A T ': =; . . SOHIO* UNION* K. TULIN/VAULT ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc.~~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 1, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Subsequent Sundry Reports Dear Mr. Chatterton: Enclosed are Subsequent Sundry Reports 1A-3 1A-4 DS 4-9 DS 9-16 If you have any questions, Sincerely, Gruber Associate Engineer please call JG/tw GRU10/L37 Enclosures for the following wells: me at 263-4944. ARCO Alaska, Inc. is a Subsidiary o! AtlanlicRichlieldCompany STATE OF ALASKA ALASKA'~[' _ AND GAS CONSERVATION C~'- VIISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE L LX{~] OTHER [] 2. Name of Operator /~D/~ Al ~,-I~ I~,.~ 3. Address 4. Location of Well Surface: 1139' FSL~ 313' FWL~ Sec,5~ T11N~ R10E~ UN 5. Elevation in feet (indicate KB, DF, etc.) RKB 100' I 6. Lease Designation and Serial No. ADL 25647 ALK ~65 7. Permit No. ~,~ _on 8. A P ~'1~ u~::)er 50-- G29-2GG15 9. Unit orLease [~ame Kuparuk River Un~ 10. Well Number 1A-3 11. Field and Pool . Kuparuk River Field Kuparuk River 0il Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made ~, Other Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form t0-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Accepted rig ~ 1230 hrs, 4/30/85. Killed well. ND tree. NU BOPE & tstd to 3000 psi- ok. Pulled 3-1/2" tubing. Retrieved pkr. Ran CET. Perf'd 8108' - 8110' & 7920' - 7922'. Set EZSV bridge plug ~ 8130'. Set RTTS pkr ~ 7704' & tstd ann to 2000 psi - ok. Set pkr (~ 7986'; pumped & squeezed 100 sx Class G cmt. Set bridge plug ~ 7930' & second EZSV ~ 7895'. Squeezed perfs (7920' - 7922') w/lO0 sx Class G. Drld cmt retainers and hard cmt to 81~4'. Drld btm bridge plug & pushed to btm (8320'). Perforated the following interval s: 7948' - 7972' 7820' - 7888' Set FB-1 pkr. ~ 8017'NLM. Ran 3-1/2" completion assy. Set pkrs. ND BOPE. NU tree & tstd to 5000 psi - ok. Disp well w/diesel & crude. Set BPV. Secured well and released rig ~ 2400 hrs, 5/12/85. RECEIVED J U L 0 ) 1985 Alaska Oil & Gas Cons. Commission 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed &'~ ~_~~L~, Title A.,,oc,.'ate Eng!?.eer The space belo~ for Commission use Conditions of APproval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 GRU10/SN03 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc.'~'B,0{x Post Office ' 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 24, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached in duplicate are subsequent following wells at the Kuparuk River Field: Well Action Date 1A-3 Fracture 1A-4 Fracture lC-5 Perforate 1E-3 Perforate 1E-3 Fracture 1E-4 Perforate 1E-4 Fracture 1E-1 6 Fracture 1E-17 Fracture 1E-29 Fracture 1F-1 6 Perforate 1F-16 Fracture 1G-1 Fracture 1L-15 Fracture 1L-16 Fracture 1Q-1 Fracture 1Q-4 Acidize 1Q-4 Fracture 1Q-5 Fracture 1Q-6 Fracture 1Q-7 Fracture 1Q-7 Acidize 2C-1 0 Perforate 2D-3 Ac idi ze 2W-1 3 Ac idi ze 2X-12 Ac id i ze not ices on the Performed 5/30/85 6/1/85 4/27/85 3/28/85 4/3/85 4/20/85 5/7/85 4/14/85 3/26/85 4/12/85 4/11/85 4/15/85 4/1/85 3/31/85 3/31/85 5/31/85 5/17/85 5/31/85 5/1/85 4/19/85 4/27/85 5/26/85 4/21/85 5/11/85 5/20/85 5/12/85 If you have any questions, please call T. M. Drumm Kuparuk Operations Coordinator TMD / kmc Attachment (Duplicate) me at 263-4212. RECEIVED JUN 2 6 1985 Alaska Oil & Gas Cons. Con]~liSSJorl Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany A(U STATE OF ALASKA ~, ALASK IL AND GAS CONSERVATION C vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ID( OTHER [] 2. Name of Operator ARCO ALASKA, INC. ANCHORAGE, ALASKA 99510 3. Address P. O. BOX 100360, 4. Location of Well SURFACE LOCATION: 1139' TllN, R10E, UM FSL, 313' FWL, Sec. 5, 7. Permit No. 81-88 8. APl Number 50- 029-20615 9. Unit or Lease Name KUPARUK RIVER UNIT 5. Elevation in feet (indicate KB, DF, etc.) 100' (RKB) 12. I6. Lease Designation and Serial No. ADL 25647 ALK 0465 10. Well Number lA-3 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [~ Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] [] Other [] Pulling Tubing [] Pull Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10'407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 2'0 AAC 25.105-170). On May 30, 1985, the "A" sands of Kuparuk well lA-3 were hydraulically fractured and propped to improve production. The treatment consisted of 227 BBLS of gelled diesel as pad and carrying fluid and 12,676 LBS of 100 mesh and 20/40 sand as proppant. 80 BBLS of gelled diesel was used as a flush. Prior to pumping, equipment and lines were tested to 5000 psi. RECEIVED JUN 2 6 1985 Alaska 0il& Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. KUPARUK 6 / 18 / 85 Signed J.~~ ~/-~ Title OPERATIONS COORDINATOR Date The space below for Commission use Z +~ .... ~? Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. { Post Office B(~X 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Hay 28, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton. Attached are our notices field well 1Q-7 and to 1Q-2, 1Q-3, and 1Q-4. of intention fracture we l Is If you have any questions, please call me to acidize Kuparuk 1A-3, 1A-4, 1Q-1, at 263-4543. paruk Operations Coordinator / kmc Attachment (In Triplicate) ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ( STATE OF ALASKA O(M ALASKA OIL AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, I NC. 81 -88 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-20615 FSL, 313' FWL, Sec. 5, 4. Location of Well SURFACE LOCAT ! ON: 11 39 ' T11N, R10E, UM 6. Lease Designation and Serial No. ADL 25647 ALK 0465 5. Elevation in feet (indicate KB, DF, etc.) 100' (RKB) 12. 9. Unit or Lease Name KUPARUK RIVER UN I T 10. Well Number 1A-3 11. Field and Pool KUPARUK RIVER F I ELD KUPARUK RIVER OIL POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate []~ Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Re pr fr ge pr r phone conversation with~! (AOGCC) on 5/'24/85, it is oposed that the "A" sand in Kuparuk well 1A-3 be hydraulically actured and propped to improve production. The treatment uses lied diesel as the pad and carrying fluid and 20/40 sand as the oppant. Diesel w II be used as a flush. Lines and equipment will be pressure tested to 5000 psi prior to starting job. Fluid: Gelled diesel 310 BBLS Proppant. 20/40 sand 11,844 LBS ANTICIPATED START DATE: May 25, 1985 Work Reported RECEIVED MAY 2 9 1985 Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. KUPARUK The space below for Commission use ~/ -- Date 5/28/85 Conditions of Approval, if any: Iit l!lll~ll[ IL $~llI~ By Order of Approved by COMMISSIONER the Commission Approvecl Cop? Returned Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc.f" Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 05-15-85 I'RANSMITTAL N0'5183; RE'I'UF(N TO: ARCO ALA.'.';I<A, INC. Al'TN' R['ilCORDS CLERI< Al'O-t i t 5B F'.O. BO)': t00S60 ANCi"IORA(;E, AK 9951 0 I'RANSHITI'ED HEREWITH Al:RE I'HE FOl._LOWING RECEIF'I' AiqD RE'FURN ONE ~IGNED COPY OF 'I'HIS I I'i-ZHS .~]A,S'E ACK NOWLEDGE TRANSMITTAL. WSR/$FqtJENCIT. OF EVENI'$ (ONE COPY 01-- EACI. I) t A-t F'BLi 04-21 -8'5 CAMCO -2 '* - 85 tA-i F'BU 04 ..: ':. CAMCO t A - 2 R U N L Y N [:". S R E C 0 R I) E R S (.) 4 - 21 -. 8.5 C A M C 0 t A'-2 END I-"-'DU/RUN HRDF' 04 ~" "':' - 3-8.> CAMCO J A-S SBI'IF' 04-~ 9-85 CAMCO J A'4 SBi'-IP '04-J 9-8'5 CAMCO J A-5 i::'BU 04-2~ -85 CAMCO ~ A-5 i::'ULL F'BU (~4-'22-85 CAMCO J A-6 PBU 84-2~-85 Ol'IS J A-6 HANG OFF L. YNES i>RE$.~'UF~E B(]HBS FOR F'BU (~4--2J-85 [)TIS ~ A - 6 F I N I S I"! F' B [J (-) 4 - 22 - 85 0 T I S iA-~O RUN LYNES RECOF~DERS (')~ ~-,. t -85 CAMC[) iA-t~ F'LILL LYNES I:<ECORDEir<~ 04-22/23-85 CAMCO i B-S PBU 04-2t-'8D t B-3 F'BLI 04-22-85 CAMCO t C-4 .S' I':{ i"1 I::' 0'1-2~-'85 CAMCO t C-4 SBI--IF' (t4-25-85 CAMCO lC-6 RUN LYNES RECOF(I)ERS G4-2i-'85 OTIS' t C-6 RETRIEVE LYNES F<ECOi:(I)EI=<S ~4-"~'~-°':~ t E-4 RUN SPINNER/TEHPERATUF(E SLIRVEY---LEAK DETECTION 04-22-85 CAHCO tE-5 RUN F'BU SURVEY ~4-'26-85 CAMCO iE-i& IN,JECI'IVII'Y TEST ~4-t9-85 tE-t6 INJECTIVITY TEST (;)4-2~-85 ARCO t E-27 IN,JECTION TEST/' A'SAND 04-22-8~ ARCO t E-27 TEMF'ERATURE/SF'INNER-- LEAl( DETECTION ~4-2'7--85 O"F I S t F'-~ RUN LYNES TANDEM F'RE$3URE BOMBS F'OR PBU 04-2t -8~ O'i"I 1F-~ REi'i:(IEVE LYNES RECORI)ER3 ~4-2~-85 OTIS 1F-5 RUN LYNE$ RECORDERS .... ' C' SAND ONi..Y ~4-'2i -85 OTIS' iF-5 RETRIEVE LYNE$ i'::ECOF(DERS ~4-'22-85 OTIS RECEIPT ACKNOWLEDGED: - ............ .......... ~ ,i, ~} i iN J. ~? ~.; i & u i · - BPAE* DRIL. I_ING W. PASi-iER B. CURR I ER* t .... JOHN.S'TON EXX ON C l..I E V R 0 N* * H 0 B I I... , P I-I I L L I I::'S 01 L D & H* N:~I< Cl..El:RI< .x-J. F<Ai'HMI~LL DATE: *STATE OF ALASKA *$.0H I 0 *UNION i<. 'F LJ 1., I N / V A U L_ 1' ARCO Alaska, Inc. Post Office'ir~ 100360 Anchorage,~ ~,aska 99510-0360 Telephone 907 276 1215 i i i i i i i i i t i i i l:;,' Ei'F UI~ N TO' ,--~l..,I...~.. AI..ASI<A, INC A T 'T' N R E [.'. 0 R I).S' ,., L E I";,' K .. ! :..'. ~'., · A T ~l--i i i ..-.:, P., 0. BOX i {:' C' ?.: 6 '::) ANCHOF::A[;E, A!< 975i9 ,:: R ["' W I T 1"i "' '" - :-.,kl:: THE f.'nl..l._rlWIN[~ I::ETURN ONE ;.?IC-i'.!ED COF'Y OF' ' .... C .. P ,.~ l ~-,~T I BI..I STAT I C BHP S T A T I C B H P ,'.'.," T A T :[ C'. B I..I F' :' r..'. .::. T A T I B !.-I P DATA DA'T'A I) A I'A DA'FA D A T'A DATA BHF' BHI'"' DATA B H F:' , f':! / 'C: e :..,I'I s'rl[.'/' A' eANL~ PBU I ....: I.."" . ,,. ;:'?TATIC'. BHF' DA'TA ':' 0 ['"' "F'P, LI ~..'. . .-' .~. F'BU DATA ~ .....rt..,. R "' ..., 1 A 1 ~. ..: I-'1 t" D A'T A ,?'i" A 'F I C B 1"I P D A T A :." F1 I::' / '.'.' T:! !..I E.*, * A I .~, F:'B U D A'T A . S 0 E /F' B U , [.'., ,S'A N D 'I · ~'I" I T E bt.S'~ F- L. E. A ,.~. E A C: I< N 0 W L..E D 6 T i"11 $ T F;..' A N .':? H I T '1' A I.., i/2.4/85 ;. ~-....~ / ,::', .. i/2q/85 ri. Ii i/":'::/ 2/t f/85 2/~ '.:3/8~ ~:/i ;"~. I ,::,_.:. ") / ,.'.', / o, ~' :.~...' *** · ;.. #;' 21:7185 2/24/85 n/'2-/ .,:.. :# t : ~,. ~: ,:~ / 2 ? / :., ..:, :*) / ;') ~ " ,:.., ,:. ,' / [J .? F:'.: I: .... ,:: 'r F' T A r:. I< b:: f]*.,tl F: ~) 6 E t'~. I) 12'T F:,' I B U 1' I 0 N · !) R I L. I... I N [; W, F'A $ I--1E R L.,. ..] 0 H N ,? T 0 N r:.:. X x 0 N M(]B I !... PHI !_I... I F',:S' OIL. N2K C'.t...I::.F, Iq J,. RATHMELL ARCO Altskl, Inc. I$ I Sub~idilry ~t AllnnticRichtield¢omplny ARCO Alaska, Inc.'~'l~6{x Post Office 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 22, 1985 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: Kuparuk 1A-3 Dear Mr. Chatterton: Enclosed is a Sundry Notice for the subject well. We propose to convert 1A-3 to a selective single completion. Since we expect to start this work on April 24, 1985, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, A~~ngineer JBK/KLB/tw SN/L026 Enclosure RECEIVED APR 2 2 198-5 0il & GaS Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WE LLx~] OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage~ AK 99510 4. Location of Well Surface; 1139' FSL, 313' FWL, Sec.5, TllN, RIOE, UN 5. Elevation in feet (indicate KB, DF, etc.) RKB 100' I 6. Lease Designation and Serial No. ADL 256~.7 ALK ~.~5 7. Permit No. 81-88 8. APl Number 50-- 02q-?oR1 r~ 9. Unit or Lease Name Kuparuk River U?.'t 10. Well Number 1A-3 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] [] Other [j~ Pulling Tubing [] Pull Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to convert well 1A-3 to a selective single completion. The procedure will be as fo11 ows: 1. Well will be killed with brine. Weight to be determined after running pressure bomb. 2. Current completion assembly will be pulled. A CRT will be run to test for zone isolation between the A and C Sand. A squeeze will be performed, if required. 4. A retrievable packer will be run to test casing. 5. The well will be completed as a selective single with three (3) packers. 6. After the rig is released, an acid and/or frac job will be done. A 13-5/8", 5000 psi, SERA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A non-freezingfluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: April 24, 1985 subsequent Work ltepe~e~l RECEIVED APR 2 2 14. I hereby e~rtif)/that the foregoing is true and correct t° the best of my knowledge. '"A[aS~(a 0il & Gas Cons, Commission //~.~- ,~.,~.~-w ' Anchorage /__.,/,/,~~-- Signed .... Title Area Dr~]~nq Eng~nee~ Date The space~o~ ~ ~ssion use ~ ~- Conditions of App/ ' ' roof any: Approved Cof>y _ P~eturr~ ,// .,/..~-- BV Order of Approved by COMMISSIONER the Co.mission Date Form 10-403 (KLB) SN/050 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc Post Office( x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 2/05/85 Transmittal No: 4824 RETURN TO: -. ~CO ALAS~, INC. ATTN: Records Clerk ATO-1115B Box 100360 Transmitted herewith are the following it,s. and retu~ one signed copy of this tra~mittal. Please acknowledge receipt PBU SURVEYS & --2X-7/ 8/16/84 ~---2Z-6/ 9/03/84 2X-6v" 8/16/84 2X-4,/ 8/16/84 ---2X-1V' 8/16,19 ~2V-5/ 8/16,19 ~-~-2V-2~'" 9/07/84 - -2F-9'/° 8/28/84 ---2F-8'~'~.. 10/08/84 --2F-7'/ 10/07/84 --2B-1G"" 9/03/84 ~2C-5 / 8/17/84 .-1Y-13/ 8/16/84 ~lY-9/ 9/07/84 ~lY-5/ 9/14/84 1Y-5~ 9/06/84 ~lG-6~ '8/25/84 ~lH-4~ 9/04/84 --1F-12¥ 9/09/84 ---.1F-9 F 8/17,18/84 <-lF-SZ~ 8/16,17/84 ---1E-8//. 10/12/84 ~-lD-5/ 10/07/84 ~lA-4w× 9/02/84 ~', ~'~ 9~02/84 Gearhart Otis Gearhart Camco /84 Camco /84 Dresser "HP 232" Otis Otis Camco Otis Otis Otis Dresser "HP 233" Camco Camco Otis Otis Otis Otis Camco Camco Otis Camco Otis Otis Receipt Acknowledged: B. Currier Drilling SEQUENCE OF EVENTS 9/06/84 "SBI-]P" 9/05/84 "Static BHP" 8/17/84 "PBU"" 8/16/84 "PBU" 10/13/84 "SBHP" "E Line" 10/07/84 "Pressure Falloff" DISTRIBUTION W. Pasher State of AK BPAE Geology G. Phillips Sohio Chevron Mobil Phillips Oil Union D&M NSK Ops. J. Rathme!l Well Files KUPARUK Ei~GI,~:EERIHG TO' ~_ FROM- D. Fay Allison DATE: ~/~ /~/~ WELL HAME' CJ Transmitted herewith are 'the following- see below PLEASE NOTE' BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE,<~ PHOTOCOPY Well Descript ion Date Run .i ".l IJJ r, - P,[C~I PI ACLkO._EDu~_D' ~/~LEASE RETURH RECEIPT TO' ARCO ALASKA, INC. ATTt'~' D. FAY ALLISON - ATO/1115-B P. O. BOX 100360 ANCHORAGE, AK. 99510 KLIPA~ F~IG I NEER I NE; TRA~LSM i TTAL #~ ~: D. iV. Bose/Shelby 3. F~tthews ' -. Transmitted herewith are the fol lowing: PLEASE NOTE: BL- BLUELINE, S- SEPIA, F- FI~A, T- TAPE,(....~~, /" P~E RERJRN RECEIPT TO:r · ATTN: SHELBY J. k~A'FiTt~'~ - ATO/1115-B P. O. BOX 100360 ANQ-IOF~E, AK. 99510 *~ KUPARLK E~ I NEERI NS '~' D. W. Bose/Shelby J. Matthews ' TranSmitted herewi th are the fol lowing: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F FILM, T - TAPE, IPT ~VLED~ED: · PLEASE ~ RECE! PT TO: ~ ALASKA, INt3. AT1'N: SHELBY J. M&TTH~',.S - ATO! 1115-B - P. O. BOX 100360 ~E, AK. 99510 ARCO Alaska, Inc.( ~: Post Office B,. ~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 October 19, 1982 C. V. Chatterton State of Alaska Oil and Gas Conservation Co~n. 3001 Porcupine Drive Anchorage, Alaska 99504 'Dear Mr. Chatterton: Enclosed is the subsequent report for Kuparuk wells lA-3 covering acid stimulations. Sincerely, E. A. S~nsen ~/cl CC: D. J. Caffrey - AFA 330 w/o Attachment L. B. Kelly - AST 306 w/Attachment L. M. Sellers - ANO 332 w/Attachment H. C. Vickers - AFA 326 w/o Attachment OCT 2 5 Alaska Oil & Gas Cons. Anchorage ARCO Alaska, I~c, is a Subsidiary, of At anticRichfieldCompany SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-88 3. Address 8. APl Number P.0.Box 560, Anchorage, AK 99510 50- 029-20615 4. Location of Well SL: 1159'FSL, 515'FWL, See 5, T11N, RIOE, UN BHL: 852'FNL, 1445'FEL, Sec 5, T11N, R10E, UN 5. Elevation in feet (indicate KB, DF, etc.) 100' RKB 6. Lease Designation and Serial No. ADL 25647 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1A-5 11. Field and Pool Kuparuk River Field Kuparuk River 0±1 Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25,105-170). ARCO Aiaska, Inc. has decided · No deferrai requested, not to stimulate Well 1A-5 with acid. A-19 OCT 2 5 982 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. AJaska 0ii & Gas Cons, A~choraga Cc~nmis::ion Area Operations Engineer Title Date Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ( SCHLUMBE][ .R OFFSHORE SERVICES 5000 GULF FREEWAY, P.O. BOX 2175 HOUSTON, TEXAS 77001, (713) 928-4000 PLEASE REPLY TO 500 W. INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA October 12, 1982 ARCO ALASKA, INC. P.O. Box 360 Anchorage, AK Dear Customer' We have discovered an error in the Library Tapes for the following well' COMPANY NAME' ATLANTIC RICHFIELD COMPANY WELL NAME: 1A-3 LOGGING DATE: Z3/JUL/~,L~'~I JOB NUMBER: 62032 Enclosed are replacement tapes for the above listed well. Please destroy the original tapes you have already received and replace with these enclosed. We apologize for any in- convenience this has caused. Thank you, S.E. K1 SEK: smm cc: distribution JANICE NEVIL, EXPLORATION A DIVISION OF SCHLUMBERGER LIMITED OCT 2 1982 ~aska Oil & C~as ~;,:m~,. · Anchorage ~'nmissior~ TO:' William VanAlen · D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: PLEASE NOTE: BL- BLUELINE, S - SEPIA, F - FII/~, PC - PHOTOCOPY R~CEI~ A~.RnGED: PT~ASE RETURN R~CEIPT TO: ATI~: LORIE L. JOHNSON - AFA/311AIaska 0ii & Gas Cons. Commission P. O., BOX 360 Anchorage ANCHOPAGE, AK. 99510 KUPARUK ENGINEERING TO: TRANSMITTAL # ~~ ~ ~ FROM: D.W. Bose/Lorie L. Johnson DATE: 7/2B/~'- WELL NAME: Transmitted herewith are the following: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE RECEIPT ACKNOWLEDGED: PLEASE RETURN RECEIPT TO: DATE: JUL 982 ARCO ALASKA, INC. Alaska 0il & Gas Cpss. C0mm~si0n ATTN: LORIE L. JOHNSON - aFSjfc$o}~e____~ P. O. BOX 360 ANCHORAGE, AK 99510 (r' STATE OF ALASKA ( ALASKA ~IL AND GAS CONSERVATION C(~',v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [Z~( 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81 -88 3. Address P,0,Box ~60~ Anchoraqe~ AK 99510 4. Location of Well SL: 1139'FSL, 313'FWL, Sec BHL: 832'FNL, 1445'FEL, Sec 5, T11N, RIOE, UM 5, T11N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) --. !00 ' RKB 12. I 6 . Lease Designation and Serial No. ADI 256/,7 OTHER [] 8. APl Number 50- 029-20615 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1A-3 11. Field and Pool Kuparuk River Field Kuparuk River 0il Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data Poo~ SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate ~( Abandon [] Stimulation Repair Well [] Change Plans [] 'Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to stimulate the Kuparuk Sands with acid. Acid wiiI be spotted with. a coiied tubing unit with BOP assembiy tested to 4000 psi. Aii circuIated and fiowed fiuids wiii be diverted to tankage on iocation. The weIi wiIi be tested subsequent to the stimuiation. Expected start date is May 30, 1982. RECEIVED MAY 2 81982 Alaska 0il & Gas Cons. Commission Anchorage A-19 14. I hereby certify th,~t the fore.~g~oing is true and correct to the best of my knowledge. Signed,, ~ _TitleDate The space b(PJow for Commission use (~ Conditions of Approval, if any: Approved ~p¥ i. Returned , O. RIG! I SI NED i BY L'OHHIE C. SMITII -.¥ O -der Approved by. COMMISSIONER the Commission Date __ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate NORTtt ~LOPE E~:GIHEERIi:G ! TRAilSHITTAL ~ $~- ~ J. J. Pav,'elek/Ann Simonsen ...... ~ted here:,,,ith are the following: o... PLEASE ~:OTE' BL - BLUEL!~E, S - SEPIA, F - FIL:, T - TAP- RE[EfVED APR 0 ,8 !982 DATE' Al?.sk~ Oil & Gas Cons. Commission ARCO ALAS}iA, I:'~ Anchorage ATT~ =,',~ : I~.~.:~:~' A:>./311 P.O. BOX 360 A;iC~0~'~: '" 9951 WELL COMPLETION OR RECOMPLETION REPORT AND LOG · 1. Status of Well Classification of Service Well -' OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-88 3, Address 8, APl Number P.0.Box 360, Anchorage, AK 99510 s0- 029-20615 4. Location of well at surface 1139'FSL, 313'FI~1_, Sec 5, TllN, R10E, UM 9. Unit or Lease Name Kuparuk 25647 At Top Producing lnterval 1391'FNL, 1902'FEL, Sec 5, TllN, R10E, UM 10. WellNumber $32 ~, 1A-3 At Total Depth J~'FNL, FEL, See 5, T11N, R10E, UM 11. Field and Pool E.-a% Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 100' RKB ADL 25647 Kuparuk River 0il Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 7/3/81 7/16/81 7/24/81I __ feetMSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MEH-TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8880' MD'7oE~ilV0 8765' ~)~c~f~O'W~ YES[~ NO[--]I 1677 feetMD 1650 (approx) - 22. Type Electric or Other Logs Run DIL/BCHS, CBL/VDL/CCL/GR, FDC/CNL/GR/CAL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" ~;,;# H-Z~O g,,rf g~ 2~ 200 s× Permafrost !0 3/.~." 45 ";;~ It-";"; .g, mrf 79";~ 1t t/~ !300 Sx Fond,_, & 75~) $~ AS TT , . 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) 3 1/_~ 7?73 7700 7820' -7888' 79'48'-7972' w/12 SPF 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8166'.-8172' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8182'-8214' N/A' ' · ¢ . . · , . · 27. ·" PRODUCTION TEST ' - · Date.First Produc;,tion Method of Qperation (Flowing, gas lift, etc.) 12125/fl F]nw inn . Date o~ Test' Hours Tested PRODUCTION ~i~ OIL-BBL GAS-MCF WATER-DB[: CHOKE SIZE IGAS'OILRATIO l/~g/g? 11 hr~_ TESTPERIOD I~ '1382 __I Fl~v'~l~i~g-_ Casing' Pr~u~ CALCULATED I~ OIL-BBL G~A'S~-MCF WATER-B~.L OI'L'(~F~;ITY-API (~r) PresS.157 ... 24-HOUR RATE -~ 30~ .... 1393 -- ;' 23.7° · 28. CORE DATA · Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A · .. .... - · ~rm 10-407 Submit in duplicate Rev. 7-1~80 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 River Form. 7783' 6138' Base Kuparuk River Form. 8258' 6528 ' 31. LIST OF ATTACHMENTS , , 32. I hereby certify that the foregoing is true and correct to the best of my knowledge MAR 1 0 1982 Signed k. ~.-~'~~ Area Ops. Engr. Title Date -- A /I ,, ( 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 d!sposal, 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 a,nd 24' If this Well is completed for separate production frO~ more than one interval (multiple completion), so state in item 16, andin item 24 show,the producing intervals for only the interva['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 s~ould 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 TRAilS;-iITTAL .-~ TS' FROM' J.J. Pav:elek/Ann Simonsen Tra"~...mi~t~d herev:ith are the following' ... PL-.~ I:OTE' BL -'BLUEL~L, S - SE?.;,-',, F - FILM, T- TAP; NORTIi ~LOPE E;iGI''~''-,,~.r_RI~,G''~ ~''' TS- J. J. Pawelek/Ann Simonsen Transmitted herewith are the following' PLc'z'c:~,,~. HOTE' BL - BLUELT;'E,.,, , S - SEPIA, F- FILM, T - TAPE F. LC~_! ?T AC~,,~O,';L Eu~ED: Sz ,'.~,U,q,I f'..~.~,'T TO: V FLg.~~, DATE' A!~ska Oil & G~s Co~s. Oommi$$io~ Anchorag~ ~' SOHIO ALASKA PETROLEUM COMPANY 100 PINE STREET, SAN FRANCISCO, CA 941 1 1 October 17, 1980 ARCo Oil and Gas Company North Slope District P. O. Box 360 Anchorage, Alaska 99510 Attention: Mr. S. R. Jaime LAND D ~.~ .FrF. .o OCT °?,7 1980 .. NORT]~! ~¢_LAS KA ARCo Oil and Gas Company, by letter of September 23, 1980, has requested a letter of non-objection by Sohio Alaska Petroleum to the drilling of the following development wells: Well No. Bottom Hole Location · E-6 B-3 A-1 A-2 ,_A-3 A-6 A-7 500' NSL, 2640' EWL, Sec. 16, TllN, R10E, UM 1320' NSL, 1320' EWL, Sec. 9, TllN, R10E, UM 1320' SNL, 1320' WEL, Sec. 6, TllN, R10E, UM 1320' NSL, 1320' EWL, Sec. 6, TllN, R10E, UM 1320' SNL, 1320' WEL, Sec. 5, TllN, R10E, UM 1320' NSL, 1320' EWL, Sec. 8, TllN, R10E, UM 1320' NSL, 1320' EWL, Sec. 7, TllN, R10E, UM Please-be advised that Sohio Alaska Petroleum Company does not object to the drilling of the proposed wells. For your information consent to E-6 was previously forwarded by Sohio to the Conservation Commission at the request of P. A. Van Dusen of your office. Sohio's concurrence to the drilling of the listed wells is with the understanding that ARCo, Sohio and other affected working interest owners will proceed in good faith toward an equitable unitization of the Kuparuk Reservoir and that such unitization is achieved prior to the commencement of production from the wells. GJA:c cc: P. Hardwick, BPAE P. Rumley, Anchorage Yours very truly, .~/J-. Abraham BPAlaska Exploration ! nc. 255 California S!,eet. San Frnnci.~c,o. Cali~ornia 94111. Telephone (415)445-921' AROO Oil & Gas Co, any North S/ope District P.O. Box 360 Anchorage, Al,a.%ka 99510 Attention: .%.%r. $.R. Jaime .Letter of Non-Objection ~ AR(]9 Oil '~ind C~ 'Le-~.~e ADL 25651 C~nt ] emen: V~e .~fer to your letter of 23 ~pta'd~er 1.980, in which you adq~ised us of yot~r intention to dr~]l the £o]]owing develot~nt %%ells: A-'I A-Z · -- ^-3 A-6 tk~tt~n Hole 'I~:a.~ion .-- ,~0' ~,~ ' , ~,,.L, 2C~iO ~ff,, ~ec. 16, '~ILN R]OE, UM 1320' ~;~, 1320' E5%%, Sec. 9, ~IN, R1OE, o~ SML= 't320' %~, ~ec. 6, ~.].N, R].~, ]220' NSL, 1320' A%%, Sec. 6, TI]N, RiOE, ~'.~7'? ~, 3320' 15~, Sec. 5, TI~, RIOE, ],'."-": )'.:'fL, ]320' ~L, Sec. 8, Ti~,~, Ri~, b%~ ' ~ '~ ';Z:QO' ~%~, ~c. 7, T1LN, RiO~, ...... ~'; t~. ~.,O...:. :c. ~ affected Lcssee of Rec~ord, hereby C©O:.'." -. t;l~; ;~.": '- ~ .... .'-:-}-~...." i.¢.~n.~ to the appli~mt~on for Pe~lt to ;"?:;"'vc.'.'~ u~-'f'~:tc'~ ]:: ' data-hand.tng that t~ly ~d ~nafide ~m~es to ~micxze Zhe Kup, .,.'~;~ce'rvoir in a fair '~d c~uit~le ~n~er adopted by tho p~,?? ~volv~], ~amh that said p~ies ~y the te~ of ~uch ~mit~tion ~d 'their ro~ctive rights ~d obligations therein, prior to the m~nc~nt of ~y pr~ucution fr~ the Kup~ Yours very truly, · 'o~' ),tr. G. Abr,~h,~m, Sohio, ~F ALASK ~L AND GAS CONSERVATION C ,v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. See below 3. Address 8. APl Number P.O.Box 360, Anchorage, AK 99510 50- See below 4. Location of Well l- 9. Unit or Lease Name See below 10. Well Number See below See below 11. Field and Pool Kuparuk River Field ! 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 12. Check Appropriate B~x-fo I~d~-a~-e'Nature of Notice, Report, or O~-I~r~O-~-a ................ NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other X[~ Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). During August 1981 ARCO Alaska, Inc. performed a water injectivity test in the Kuparuk Sands to gain pertinent reservoir data in preParation for its Increment I Waterflood of the Kuparuk Sands. Injection was successfully achieved in that Upper and Middle Kuparuk Sands in Well lB-2 but not achieved in the Lower Sand in Well lB-1. Reservoir pressure response was monitored in two wells, lA-3 and lB-5. Water for the test was produced from our water source well No. 1. A brief review of test is attached. Well API Number Location Elev. Unit Name Lease Designation lB-1 50-029-20465 Sec.9 TllN R10E KB-98' Kuparuk 25648 ADL 25648 lB-2 50-029-20531 Sec.4 TllN R10E KB-98' Kuparuk 25648 ADL 25648 50-029-20237 Sec.9 TllN R10E KB-89.5 Kuparuk 25648 ADL 25648 50-029-20615 Sec.5 TllN R10~ KB-100' Kuparuk 25647 ADB 25647 50-029020090 Sec.9 TllN R10E KB--98' Kuparuk 25648 ADL 25648 ECEiVED . NOV 0 2 1~.1 ~ ///'-~cU'~Z~ ~ask~ Oil & Gas Cons. he ~fZg ' ,^nchorag,~ 14. I hereby~~certify ~att oing is tr t to the best of my knowledge. Signed .~:~~~q,,,,,/ Title Senior Operations EngineeDate The spa,~°w f°r C/~mmissi°n use~ ~,~ Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date__ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Attachment to Sundry Notices and Reports on Wells Kuparuk Water Injectivity Test The Kuparuk Water Injectivity Test began on August 7, 1981 with injection into the Upper and Middle Sands in Well lB-2 at a constant surface pressure of + 1050 psi. Injection continued until August 24, 1981. A stabilized injection rate during this period of +1050 BWPD was observed. An average BHP of + 3850 psi during this period yielded an injectivity index of + 1.7. Injection profiles run during the test indicated that the majority (70%+) of the water was going into the Middle Sand. After completion of the steady state injection period, injec- tion was stopped for a pressure fall off test. Following this shut in period, a step rate test was run. Results of the step rate test indicated a reservior parting pressure of + 4320 psi. Having successfully demonstrated the injectability of the Upper and Middle Sands in lB-2, attention was turned to the Lower Sand in Well lB-1. On August 27 attempts were begun to estab- lish injection in lB-1. Two attempts to begin injection with surface pressures of up to 2250 psi were unsuccessful. A coiled tubing unit was used to displace wellbore fluids with diesel and again attempt to inject. This too proved unsuccess- ful. The well was flowed to be sure that the perforations were open. No further efforts to inject were made. It is felt that some sort of plugging is preventing injection in the well. The test was concluded on August 30, 1981. During the injectivity test, reservoir pressure response was monitored in two offset wells, lA-3 and lB-5. A bottom hole pressure increase of + 3.7 psi and + 8.0 psi respectively was measured in the wells. Attached as part of this report' are charts and plots of injec- tion parameters, step rate testing, and offset pressure response. HCV 10/26/81 NOV 0 2 1 °1i Oil & Gas Cons. Anchorag~ KUPARUK ~ATER INJEC~MTY TEST Monitor Wells Pressure Response DATE 8 6 8 7 8 8 8 9 8 10 8 11 8 12 8 13 8 14 8 15 8 16 8 17 8 18 8 19 8 20 8 21 8 22 8 23 8 24 8 25 8 26 8 27 8 28 8 29 KUPARUK lB-5 BKP TEMP 3261.8 157.1 3262.1 157.1 3261.6 157.2 3262.6 157.4 3263.5 157.6 3263.8 157.6 3264.4 157.7 3264.3 157.9 3265.3 157.9 3265.7 158.0 3266.4 158.1 3266.9 158.2 3267.4 158.3 3267.9 158.4 3268.4 158.5 3268.6 158.6 3269.3 158.5 3269.8 158.6 3270.0 158.7 3269.9 158.7 3270.2 158.7 3270.3 158.7 3270.2 158.8 3270.2 158.8 KUPARUK lA-3 BHP TEMP 3173.4 158.2 3173.4 158.4 3173.4 158.6 3173.6 158.8 3173.8 159.0 3173.9 159.1 3174.0 159.2 3174.2 159.4 3174.4 159.6 3174.6 159.7 3174.9 159.9 3175.1 160.0 3175.3 160.1 3175.5 160.1 3175.7 160.2 3175.9 160.3 3176.2 160.4 3176.4 160.6 3176.7 160.7 3176.8 160.8 3177.1 161.0 Pressure Response + 8.0 PSI Pressure Res~nse ± 3.7 PSI iqO¥ 0 2 8! Oil & G~,s Cons. Commissiori KUPARU~ WATER INJEC~~ TEST Step Rate Test INJ PRESS 750 1000 1250 1550 1800 2000 INJ RATE BHP ~ A P II 0 3260 122. 336 3433 117. 173 1.94 692 3797 109. 537 1.29 1266 4068 100. 808 1.57 3060 4344 77. 1084 2.82 4648 4490 70. 1230 3.78 7968 4554~ 64. 1294 6.16 KUPARUK ~LATER IN~MTY TEST Steady State Injection DATE INJ RATE BHP TE~4P 6 0 3230.9 160.2 7 2448 3847.9 76 8 2398 3827.3 69 9 2273 3817.5 69 10 1520 3854.2 77 11 1254 3861.0 77 12 1210 3867.5 77 13 1301 3811.4 77 14 1297 3855.3 76 15. 1018 3850.1 76 17 1063 3846.7 77 18 1068 3843.7 77 19 1112 3848.9 76 20 1082 3842.4 76 21 975 3844.3 75 22 1063 3846.5 77 23 1050 3844.8 75 24 923 3860.8 78 A p II 617.0 3.97 596.4 4.02 586.6 3.87 623.3 2.44 630.1 1.99 636.6 1.90 580.5 2.24 624.4 2.08 619.2 1.64 615.8 1.73 612.8 1.74 618.0 1.80 611.5 1.77 613.4 1.59 615.6 1.73 613.9 1.71 629.9: 1.47 Cumulative Steady State Injection = 22 MBW NOV 0 2 l~! Alaska 0il & Gas Cons, Comm/ssior~ ~chorag~ - ....... 2500- · . 2000- -.. 1500- 'l.z.I - I--' . -- ~ 1000- KUPARUK WATER IHJECTIVITY TEST ItlJECTION RATE KUPARUK 1Dz2 16 1 .... 4000~ . .... 380O- · 36OO-. : 3400-- .. - . .: 3200~ ; '; KUPARUK WATER INJECTIVITY TEST. INJECTION, BHP .o IIIJECTIVITY INDEX KUPARUK 1B-2 . _5 _3 _2 _1_ ~ ........ ., .... KUPARUK WATER' INJECT/IVITY: TEST .... - .t i, - ' i-'i, STEP RATE TEST i } I ' ,''',, . , :, KUPARUK~lb-2: i .; ~ f.-t-.l--J--t--f r'J"l'J-~j 1-I j i 'i i ............. . ~ .... ~ ~, ~ ~,, , -~-.' ~ ~-~ ~ ~' ~~ Part~nq Pressu~e..~j.4320 PSI. '40 ,, ..... , ....................... , I ~-~.. . '"~=-? '" :'~"~ .... ~' ~",''-r" ': ~ .... . ~ ~ ~ ..xi; I ~.~. -~ ........... * ~ ...... , . : ' J , : ~ . , ~ t , , ! , ' : : i , ~ i ~ .L.* · .~..i. J. J...; .... ~ : . ~ ~ t · ~ ' - ~ ' ;] -i '~ ' ''~ .... ~ "~ ; ~ ' ' ~ ' :' .... ~ I , :': "I T t ; FI'- i t ; * ~ J ; ;;';;L .. ' 'N" ~'' '~'' ~L" ~.Z~J]X..,~ ........... ~.-~, ~ ~ . ' ' ~' ~ IHJECTION A ' J i 3180.0 - 3177.5 ~ 3175.0 - ._ 3172.5 3170.0 KUPARUK WA_TER iNJECTIVITY TEST MONITOR WELLS PRESSURE RESPONSE i ' I '1 ' '1 4 6 8 . - .32,6Y,."5 - 3265.:0 - 3'262.15 - 3260.0 '- __ Kuparuk 1A-3 . ' 10 12 .14 16 ._ 18 ... 20 122 "24 ' .... ,~l.~m,,2 Oil & Gas Cons. Commissim~ ............. Kupa'ruk ~'i~rag~ ....... · . I..-.; I" - ~ ~ t "i-~ I"" ....... - 1 ...... I i "l" I ~ 2 4 6 8 10 12 14. 16 18 .20 22 24 ...... ................... ~. . - . . .............. ,. ]. - ..... : ....... ................... NORTH ~LOPE ~.r, GIr, E~RII:G TRAHSMITTAL ~ ~7~7 .. . DATF' f-:..~ ~ - EF f' WELL NAME' ,/~-'.~ Transmitted herewith are the following' PLEASE HOTE' BL - BLUELIHE, S - SEPIA, F - FILM, T - TAPE RECEIPT ACK;iO',.:L EDL~ .... --- ~S: RETURrl n~"~ ~ ~,L~,~_ I PT TO' DATE' i~l I,, i~ i,, i iv i,, ~ I~ I: ~,l: I V I' L/ ARCO ALASKA, INC. ATTH' ANH SIMONq~''''_-,, P.O. BOX 360 Ai"~Cn0~.~c, AK 99510 OCT - AFA/311 Alaska Oil & Gas Cons. Commission Anchora[le ARCO Alaska, Inc. ( Post Office Anchc, raae Telephone 907' September 28, 1981 Mr. Harry Kugler State of Alaska Alaska Oil and Gas Conservati on Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 12-11 DS 16-4 West Sak #18 DS 12-12 DS 16-5 A-2 DS 14-9A DS 16-14 A-3 · DS 14-19 DS 17-7 B-4 DS 1 4-20 DS 1 7-8 C-8 DS 16-1 DS 17-9 Dear Sir: Enclosed please find the Completion Reports for the following wells: A-2, A-3, B-4 and C-8. Although these Kuparuk wells have been per- forated, production test data has not been obtained; this information will be forwarded to your office when available. Also enclosed are Completion Reports for the following wells: DS 12-12, DS 14-19, DS 14-20, DS 16-4, DS 16-5, DS 17-7, DS 17-8 and DS 17-9. Production test information is not applicable for these wells since they have not yet been perforated but will be submitted to your office when we obtain the information. Previously unreported information such as locations for bottom hole, producing interval and geological forma- tions have been added to the updated Completion Reports. DS 14-9A and West Sak #18 have been plugged and abandoned. An updated Completion Report with Drilling Histories for these wells is enclosed. Information regarding West Sak #18 is of a confidential nature and we would appreciate securely storing the report where it will receive minimum exposure. The initial Gyroscopic Survey for DS 16-1 was unacceptable and a rerun is presently being authorized by our engineering staff. An updated Completion Report for this well will be sent to your office subsequent to our receiving an acceptable survey. The remainder of the requested information - an overdue Completion Report on DS 16-14 and an incomplete Completion Report for DS 12-11 was sent to your office August 27, 1981 and was apparently enroute at the. time of your September 2, 1981 letter to this department. Also included are completion Gyroscopic Surveys for DS 12-12, DS 17-7 and DS 17-9. Sincerely, ~j~str~i~ct. Dri 1.1 i ng Engineer ..... SEP) 0 1981 0il & (~as Cons. Comrniss)or~ Anchorage STATE OF ALASKA '":~ ALASKA 'AND GAS CONSERVATION C ,,,?,AISSION WELL COMPLETION OR RECOMPLETION REPO'RT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] sERvIcE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-88 3. Address 8. APl Number P.O. Box 360, Anchorage, AK 99510 50- 029-20615 4. Location of well at surface 9. Unit or Lease Name l139'FSL, 313'FWL, Sec 5, TllN, RI0E, UM LOC, T,o T Kuparuk 25647 At Top Producing Interval i VERiFiED , 10. Well Number 1391'FNL, 1902'FEL, Sec 5, TllN, R10E, UH J$,Jrf._ E / A-3 At Total Depth ~'3o2 ~/=/VL; I',I~-15/FEI,, ID. H.. ~J 11. Field and Pool 1313'FNL, 'tf:r3-1-'FEL, Sec 5, TllN, R10E, UH Kuparuk River Field 5. Elevation in feet iindicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i I Po01 100' RKB ADL 25647 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ] 15. Water Depth, if offshore I16. No. of Completions 7/3/81 7/16/81 7/24/81I -- feet MSLI 1 17. Total Depth (MD+TVD)8880'MD 18. Plug Back Depth (MD+TVD) 8765+MD YES [~X 19. Directional Survey NO i--1 I20' Depth where SSSV set 1677 feet MD I21 16'50 Thickness of Permafrost (appr0x) 22. Type Electric or Other Logs Run DIL/BHCS, CBL/VDL/CCL/GR, FDC/CNL/GR/CAL . 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 65# H-40 Surf 80 24 200sx Permafrost 10-3/4" 45.5# K-55 Surf 2953 13-3/4 1300sx Fondu & 250sx II 7" 26# K-55 Surf 8863 8,3/4 !325sx Class .G 24. Perforat ons. open to Production (MD+TVD of Top and Bottom and . 25. TUBING RECORD , ., , "'. interval, size and number) . SIZE DEPTH SET (MD) PACKER SET (MD) 7820-7888 3- l/2 7773 7700 7948-7972 w/12 sfp 8166-8172 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8182~8214 . . .~,:. ~:.: DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED n/a , . , , 27. PRoDUcTION TEST Date Eirs!¥Production . I ~Method .of O~peration (Flowing, gas !irt, etc.) I n/a .. , , Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ]GAS-OILRATIO .,- ... ..... TEST PERIOD..~ .,~ . I Flow T~u'b!in'g · 'Casing Pressure . CA'LCULAT,ED .1~i OIL-BBL ' GAS-MC, F WATER-BBL OIL GRAVITY-APl (corr) .... 24-HOUR RATE -r i Press., ': ...-. . 28. COP E DATA Brief description of lithology, porosity, fractures, apparent diPs and presence of oil, gas or water. Submit core chips. .n/ag£C£1vEO' · SEp o 198.1 , . ' '~ · AJ'aska Oil & 8as Cons. AnC.~orage C°m~i$,ior~ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29, 30. ' :' "' .... GEOLOGIC MARKERS FORMATION TESTS NAME I nclu de interval tested, pressure data, all fluids recovered and gray it¥, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk 7783' 6172' n/a Top Upper Sand 7819' 6204' Base Upper Sand 7868' 6244' Top Lower Sand 8158' 6489' Base Lower Sand 8213' 6527' TD 8352' 6637 31. LiST OF ATTACHMENTS Drilling HiStory : 32. I hereby certi'fy th~'t the foregoing is true and correct to the best of my knowledge 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 2,.4,:~ If this well is completed for selS~rate production from mo, re than one interval (multiple completion), sd'~tate in item 16,-~and in item 24 show the producing interval'S: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". September 2, :1981 · . . Mr,' P. A. Van Dusen District Drilling Engineer .. Arco Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99501 Re~ Overdue Data Submission Dear Mr. Van Dusen: wells on the attached lists'are those for which Completion ~eports (form 10-407) are either incemplete or apparently overdue, with completion,~ abandonment, or suspension dates prior~~'tO ~August l, 1981. { ' The first list is of those wells for which an incomplete Completion Deport was filed, with the comment that the locations at the top of the producing interval and at the total depth were "to be submitted" or "N/A." The'~ccmpletion dates go back to January 9. The second list is of thosc~ Wells for which available information indicates the wells have been cc~.~pleted, but the 30 day filing period has passed without a Completion Report having been submitted. we need to be brought up2to-date on directional survey problems that may be responsible for these late filings, or have the required directional survcy~ and reports submitted to us. We would appreciate a response at your earliest convenience. Sincerely yours, Harry Rug ler Commissioner B~K/JAL/g 11% A. 'Van Duse~ September 2, i981 Incomplete Completion Reports Well Name and Number Comp 1 e t ion / Aba ndonme nt S_u~pension Late Prudhoe BaY Unit DS 16-1 Prudhoe Bay Unit DS 14-9A Prudhoe Bay Unit DS 16-4 West Sak 18 Prudhoe Bay Unit DS 16-5 KUparuk C-8 Prudhoe Bay Unit DS 14-19 Prudhoe Bay Unit DS 17-7 prudhoe Bay Unit DS 14-20 Prudhoe Bay Unit DS 12-11 Kuparuk A-2 Prudhoe Bay Unit DS 17-8 1-9-81 3-21-81 3-27-81 4-17-81 4-21-81 5-15-81 6-6-81 6-10-81 6-30-81 7-1-81 7-2-81 7-2-81 Overdue (?) Completion Reports Prudhoe Bay Unit DS-16-14 Kuparuk B-4 Prudhoe Bay Unit DS 17-9 Prudhoe Bay Unit DS 12-12 7-9-81 7-14-81 7-24-81 7-25-81 7-26-81 ARC'O Alaska, Inc. Post Office B 60 Anchorage, Alaska 99510 Telephone 907 277 5637 August 27, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservati on Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 12-11 DS 12-12 DS 13-5 DS 14-11 DS 1 6-14 DS 17-9 DS 17-10 ~DS A-3 DS A-4 .DS B-4 DS B-5 Dear Sir: Enclosed please find' 1. The Monthly Drilling Reports for DS 14-11, DS 13'-5, DS 17-10, DS A-4. , The subsequent Sundry Notice for DS 16-12. e The Well Completion Reports for DS 12-11, DS 12-12, DS 16-14, DS 17-9, DS A-3, DS B-4, DS B-5. Sincerely, P. A. VanDusen District Drilling Engineer PAV/GLA-sp Enclosures , STATE OF ALASKA ALASKA ,,g, ND GAS CONSERVATION CO ,,,,ilSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL8 GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-88 3. Address 8. APl Number P.O. Box 360, Anchorage, AK 99510 50-029-20615 4. Location of well at surface 9. Unit or Lease Name ]139'FSL, 313'FWL, Sec 5, TllN, R10E, UM Kuparuk 25647 At Top Producing Interval 10. Well Number To be submitted. A-3 At Total Depth 11. Field and Pool To be submitted. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 P0ol 100' RKBI ADL 25647 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 7/3/81 7/16/81 7/24/81 __ feet MSLJ -17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set I 21. Thickness of Permafrost ~880'MD 8765 MD YES[~X NO[],1677 feetMD 11650 (approx) 22. Type Electric or Other Logs Run DIL/BHCS, CBL/VDL/CCL/GR, FDC/CNL/GR/CAL 23. CASING, LINER AND CEMENTING RECORD SETT. ING DEPTH MD CASING SIZE WT.'PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" . 65# H-40 Surf Rfl 74 200sx Permafrost 10-3/4" 45.5# K-55 Surf 29.6:3 1~-.~/4 l~flfl~ Fnnrl~ ~, ?~;fl~Y TT 7" 26# K-55 Surf 8R63 8-3/4 13_25s× Class G 24. Perforations open to Production (MD+TV'D of Tol~ and Bott~)m and 25. TUBING RECORD interval, size and number) ' SIZE DEPTH SET (MD) PACKER SET (MD) 7820-7888 3-1/2 ?773 7700 7948-7972 w/12 spf . 8166-8172 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 81 82-8214. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED · , 27. PRODUCTION TEST Date First Production I Method of. Operation (Flowing, gas lift, etc.) , . · n/a ' · ·: .' ~ · · Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO T, EST PERIOD .11~ . · I . Flow Tubing- Casing PressuCe CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. .· 24-HO~JR RATE I~ 28. · ' CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core, chips. - · - RECEIVED n/a ,.. , ' ..... " AUG ~ 1 1'9 81 Alaska Oil & Gas Cons. Commission · ' ~.. , · Anchorage ,~ . , , Form 10-407 Submit in duplicate - Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. : GFOLOGIC 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. Io be submitted n/a · 3~. L~ST oF.ATTAC.M~Tq 1 ing Hi story 32. I hereby certify that the foregoing is true and correct to the'best Of my knowledge Signed _ Title Date _ / 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: ~lndicate 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 onb~'iinterval (multiple completion.), so state in item 16, and in item 24 show the producing int:ervals 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". A-3 Drilling History NU Hydril & diverter. Spudded well @ OlO0 hrs, 7/3/81. Drld 13-3/4" hole to 2970' Ran multishot. Ran 71 jts 10-3/4" 45.5#/ft K-55 csg w/shoe @ 2953'. ~mtd 10-3/4" csg w/1300 sx Fondu & 250 sx AS II. ND Hydril & di- verter. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-3/4" hole to 8352'. Ran DIL/BHCS, CBL/VDL/CCL/GR, FDC/CNL/GR/CAL. Drld 8-3/4" hole to 8874'. Ran FDC/CNL/GR/CCL. Drld 8-3/4" hole to 8880' TD. Ran 200 its 7" 26#/ft K-55 csg w/shoe @ 8863'. Cmtd 7" csg w/1325 sx Class G. Instld 7" packoff & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Cleaned out cmt to 8765- PBTD. Arctic packed 7" x 10-3/4" annulus w/300 bbls H?O, 250 sx AS II & 112 bbls Arctic Pack Displaced well to NaC1/NaBr.- Tstd csg to 1500 psi - ok. Ran CBL/V~L/GR/ CCL, Gyro. Ran 3½" perf completion assy w/tail @ 7773' & pkr @ 7700'. Tstd tbg hanger & packoff to 3000 psi - ok. Displaced well to diesel. Set pkr. ND BOPE. NU tree & tst to 3000 psi - ok. Tstd tbg to 3500 psi & ann to 200 psi - ok. Tstd tbg to 200 psi & ann to 3500 psi - ok. Dropped Perf bar & perf'd 7820-7888, 7948-7972, 8166-8172 & 8182-8214 @ 12 spf. Flowed well to tst tanks, to cleanup. SI well. Released perf guns. Bull headed 50 bbl diesel. Pulled dummy valve. Clo~sed SSSV. Instld tree cap & tstd 3000 psi - ok. Secured well & released rig @ 0900 hrs, 7/24/81. RECEIVED AUG ~ 1 1981 Alaska Oil & Gas Cons. Commission Anchorage Eastman/ 1 A PETROLANE COWPANY REPORT of¸ SUB-SURFACE DIRECTIONAL SURVEY ARCO ALASKA, INC. COMPANY Pad A, Well Number: 3 WELLNAME Kuparuk Field, North Slope, Alaska LOCATI ON JOB NUMBER AllS1G0094 SURVEY BY M Lund TYPE OF SURVEY Gyro Multishot RECEIVED NOV 1 6 Alaska Oil & Gas Cons. Commissfon Anchorag~ ....... OFFICE Alaska DATE 21-Jul-81 Eastman P. O. Box 4-1970/Anchorage, Alaska 99509/(907) 349-4617 November 6, 1981 ARCO ALASKA, INC. P.O. Box 1479 Anchorage, Alaska 99510 Well Number: Pad A, Well Number: 3 Location: Kuparuk Field, North Slope, Alaska Type of Survey: Gyro-Multishot Date: 21-Jul-81 Method of Computation: Radius of Curvature Surveyor: Max Lund Job Number: Al181G0094 Attn: Bob Hines Dear Mr. Hines, I am enclosing the original and one copy of the Gyro-Multishot Survey run on the above mentioned well. We wish to take this opportunity to thank you for calling on our services and trust that we may continue to serve you in the future. Sincerely, ANDY HICKMAN District surveyor AH/bb cc: file enclosure Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide 500., :'30 0 .- 00 4 ") (',-' ,, 00 600 ~-00 .............0 ,, O0 - 50':.') .: O0 7 0 0 ,- 0 ':} 0 :. 2':::: 6 0:3'., 0 0 S 0 0 .. 0 0 :} -:. 6 7 7 0 ::} ,, 3 0 ,.--. ,. ;-.,. ,~ ~:.,..~. f~ 0 ::; -:;:: :. :.'?} "-',< {:::,} .I.' .... ': · -iIjF'P~FtLJK 7J-.E~i...l!~: NORTH SL. OF'E~ A L. ~:.': S i'( ?-', ............................................. v ::: r', , .~ ~l: p~ ... 9' K F~ T !' C: R L. Zi ~!~ P T }-i ~ N (.'ii L. E D i F'-.i E C T. i 0 N L. E N t.~ T, ,!4, D ~.i~ i::' -'-, H S ~f ,C: T i ~'....-, :, -::. ::'>3 ~'=" 43 46 ,., o 00, 0 N 0 5700. 46 0 N 46 0 ["' ,5800. 46 0 N 47 0 E: ~900, 4~'"30 "N 47 0 7 :.:' :' '-"-- ...::' ':. NO:i :3 NORT~, SLOI ....... HOR] ZONTRE'.' SCRLE DEPTH F!INRL 8880 I;82: T~D 'NORTH 3308.9t 'ERST 3521.95' ~6 47, l! E I000 FEE: T.OR: HO J ii i ' i, ~ (SEC' 5~i , T11Ni .RIOE~' U.:~] i . ~000 ~ ......... I ........... '3000~ . . , ............... : ........ · ':4000 6000 8500 ............. suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. Operator, Reports and Materials to be received by: Date Required Date Received Remarks Completion Report Yes ..... Well History Yes .... , /~. Core ~scription r;* Registered Su~ey Plat 7 ~ ,,, , , Inclination Su~ey .. Dire~ional ~ey ~ .... Drill St~ Test Re~s ~ ~ ~- , ....... Pr~u~ion T~t Re~rts ~S R~ Yes NORTH ~LOPE TO' J. J. Pav,,elek/Ann Simonsen DATE' ~ ~ -~I' WELL,,,~,,.,_"' ~"P" · Transmitted herewith are the follo,.,:ing' PLEASE ~ ~ B~ ~S~ ~O..~E: - BLUELIHE, - SEPIA, .L F - FILM, T - TAPE T ~,C ,';L~:D 'PLEAS.- RETu,,,, REC~_I?T TO:' CO AL S.'~, I~ ATTH'~,~'"' ~qIMO?'.ISEi.! - AFA/311 P.O. BOX 360 A~iCHORAGE, AK 99510 RECEIVED DATE: Allfi t~ 7 1§8! ;Alaska Oil tx Gas Cons. Commission Anchorage FRO~q- J.J. Pa;velek/Ann Simonsen · Transmitted herewith are the following' PL~'~'~ [tOTE' B~ B''~'T.'''?,_..~,,.,,_- ,_v-,_,,,,.., (~ SEPIA,- ... T - TAPE RECEIPT" ......... r- ,",-', . :. L~PLEASE RETURrl RECEIPT TO' DATE' - AFA/31 1 RECEIVED · aska 0il & .~as Cons. Co, mis · ,~Chorage Sior~ HORTH SLOPE EHGI"r,r_r_v,J. HG ..../ TRM~,~,'!!TTAL # J. J. Pawelek/Ann Simonsen BATE- ~---'/.~-- ~ / WELL ,,~,...,,..,c. . · Transmitted here;vi th are the following' F - FILM, T - TAPE RECEIPT AC ~ ' -'~ E' K~IOWLEDu · .~ ~,~~DAT ~PLEASE RETURt'I RECEIPT TO' RECEIVED AUG'i 4 1981 ARCO ALAS~A, INC. ATTN: ANN SIHONSE!'t - AFA/311 P.O. BOX 360 ANCHORAGE, AK 99510 Oil & Gas Cons. Commission Anchorage NORTH SLOPE EHGINEERIHG TRAilSHITTAL / ~9 J. Pawelek/Ann Simonsen DATE' c~- '7'"~,/ WELL NAME' Transmitted herewith are the following' PLEASE HOTE' BL - BLUELIilE, S - SEPIA, F - FILM~ ~ TAPE RECEIPT AC,,,IO!',LED . ,-. ~ [- iiD. ,, ET,..tl RECEIPT TO' ARCO ALASKA, I!~C. ATT~I' AN~'I S P.O. BOX 360 ANCF,©RAGE, AK' 99510 t?~;',r.h.~ .-,,,- L'5!IIrll!S[:!O['I - AFA/311 ALASKA OIL AND GAS CONSERVATION COMMISSION Thru: Hoy le Chairman Lonnie C. Smith~ Commissioner Bobby Foster"~ Petroleum Inspector July 08, 1981 Witness B.O.P.E. Test on ARCO ' S A-3~ ./!~,l,~/~J'/t ~ ~ Sec. 5, TllN, ~ R10E, UM Permit #81-88. Mond~ July 06, 1981~ I traveled this date to Prudhoe Bay to ~tness %he Upco~h~ B.O.P.E. test at ARCO'S Kuparuk A-3. Tuesday JUlY 0.7,._ 1981~ The test began at 2:30 AM and was con- ~ded a-~i 4~0'0 AM. '~as the attached B.O.~P.E. inspection report shows there was one failure, that being the check valve, which was repaired and tested. In summary, I witnessed the B.O.P-E. test on ARCO'S Kuparuk A-3. O&G #4 4/80 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Ope rator Representative Well ..... ~/- ~ Permit # Location: Sec _~ /'~.~£~M / ~t/?"~> /~/~'~sing Set @ ft ~ Drilling Contractor.f~"'f'~i{ f![ ~% '? Rig ~-.J C", Representativ~ ~':~.%J~'~ ~ .... ~]'V'P~, ~cation, General ~~ ' ACCUMU~TOR SYSTEM Well Sign ~~' Full Charge Pressure~~<~ psig General Housekeeping ~~ Pressure After Closure ~J~ psig Reserve pit 200 psig Above Precharge Attained: m~n~/ser Rig ... ~ Full Charge Pressure Attained: =~ min~se( Controls: Master / Remotef~,~ Blinds switch cover l BOPE Stack Test Pres~re Kelly and Floor Safety Valves Annular'Preventer J ~~ Upper Kelly / Test Pressure ~.3 f/_._X"~ Pipe Rams ~ ~~ Lower Kelly.../ Test Pressure~p¢O Blind R~s / ~(~?Or~ Ball Type / Test .Pressure Choke Line Valves / ~' / Test Pressure <~"~>~.~ ~'.> Ins ide BOP ~ H.C.R. Valve / ~3~>'~,> Choke Manifold ~(~ Test Pressure Kill Line Valves .... ~ ,~<~>C.~ NO. Valves Check valve / ~7~ ~ ...~.- ~- NO. flanges / Adjustable Chokes ~ ..... / '"'~ Hydrauically operated choke Test Results: Failures ~-- Test Time ~ hrs Repair or Replacement of .failed equipment to be made within ...... days and Ins~ctor/Com~ssion office notifi¢d. R~arks: / Distribution orig - LO&GCC cc - Operator cc - Supervisor / ~' STATE OF ALASKA ,~ ALAS )IL AND GAS CONSERVATION (, VIMISSION SUNDRY'NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER E~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 360, Anchorage, AK Location of Well See bel ow 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. See below see below 12. 7. Permit No. 8. APl Number 50- See below 9. Unit or Lease Name See be1 ow 10. Well Number See bel ow 11. Field and Pool Kuparuk River Fi eld Kuparuk River Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate · [] Alter Casing [] .,, Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other ~] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). In preparation for its Increment I Waterflood of'the Kuparuk S~nds, ARCO Alaska, Inc. intends to perform a water injectivity test in 'two wells in late July and August, 1981. The purpose of the .test is to gain pertinent data on the ability of the Upper, Middle, and Lower Kuparuk Sand segments to accept injected waters. In addition, reservoir pressures in offset wells will be monitored to attempt to determine response to the injection. We anticipate a maximum of three weeks of testing, injecting into the B-1 (Lower Kuparuk) and B-2 (Upper & Middle Kuparuk) wells. Continuous monitoring of pressures and periodic production logging will be used to aid in determining injection characteristics. Monitoring of reservoir pressures in three offset wells during the injection, .the A-3, B-4, and B-5 will be used in evaluating reservoir response to the injection. Water for' the injection testing will be produced from our water Source well No. 1.. W[~[cted start date is July 27, 1981. . ·API NUMBER LOCATION ",ELEVATIONS UNIT NAME LEASE DESIGNATION B-1 50-029-20465 Sec 9 TllN RIOE KD = ·98' Kuparuk 25648 ADL 25648 B-2 50-029'20531 Sec 4 Tl lN RI OE KB = 98' Kuparuk 25648 ADL 25648 B-4 50-029-20595 Sec 9 TllN RIOE KB = 98' Kuparuk 25648 ADL 256'48 B-5 50-029-20237 Sec 9 TllN RIOE KB = 89.5' Kuparuk 25648 ADL 25648 Not Assigned Sec 5 TllN RIOE KB = 100" Kuparuk 25647 ADL 25647 - 50-029-20090 Sec 9 Tll. J~. RIOE KB = 98' Kuparuk 25648 ADL 25648 / 14. I hereby certify that the foregoing is true and c_.fbrrect to the best of my knowledge. Signed ~~"~-~ ~/~/~'~'~.,- ~'~ Title The space~elow for Commission use Conditions of Approval, if any' Approved by B~'*c)rdler o'f -- COMMISSIONER the Commission tlY tlARR¥ W. Date Form 10~,03 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate June 26, 1981 Mr. P. A. VanDusen District Drilling Engineer ARCO Alaska, Inc. P. O. Bo~ 360 AnChorage, Alaska 99510 Rez Kuparuk 25647 ARCO Alaska, Inc. Permit No. 81-88 Sur. Loc.~ 1139'FSL, 313'FWL, Sec 5, TllN, R10E, Bottomhole L~c.z 898'FNL, 1235'FKL, Sec 5, 911~, R10E, UM Dear Mr. VanDusenz Enclosed is the approved application for permit to drill the above referenced well. well samples and a mud log are not required. A directiona! survey is required. If available, a tape containing the digitized information shall be submitted on all logs for copying except experimental Iogs, velocity surveys ana dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadrom.ous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to-commencing operations you may be conta~ed by the Habitat Coordinator'G office, Department of Fish and Game. Pollution of a~y waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder ('Title 18, Alaska A4ministrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Mr. P. A. VanDusen Kuparuk 25647 A-3 -2- June 26, 1981 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the commission may be present to witness testing of blowout preventer equipment before surface casing shoe is dr il led. In the event of suspension or abandonment, please give this office adequate advance notification so. that we may have a witness present. Very truly yours, H<~y H. Hamilton Chairman of ~Y ORDER O~ Alaska Oil & Gas Conservation Commission Enc lo sure cc~ t~partment of Fish & Game, Habitat Section w/o encl. Department of .Environmental Conservation w/o/encl. ARCO Alaska, Iii Post office c~ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 June 24, 1981 Mr. Hoyle Hamil ton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: Kuparuk A-3 Dear Sir: Enclosed please find the following: le 2. 3. 4. 5. 6. The application for Permit to Drill Kuparuk A-3 and a $100.00 check for the application fee. A diagram showing the propoSed horizontal and vertical projections of the wellbore. An as-built drawing of "A" pad indicati.ng the propoSed surface location. A proximity map indicating the relative locations of Kuparuk wells A-2~ and A-3. A diagram and description of the surface hole diverter system. A diagram and description of the BOP equipment. In addition, please note that this well is subject to letters of Non-Objection from BP Alaska Exploration Inc. and Sohio Alaska Petroleum Company. These letters should be on file with your office. Please contact me at 263-4270 if your records indicate otherwise. P.A. VanDusen District Drilling Engineer PAV/DSS:sr Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany PERMIT TO DRILL 20 AAC 25.005 ~~ [] la. Type of work. DRILL ~ lb. Type of well EXPLORATORY [] SERVICE [] STRAT REDRILL [] DEVELOPMENT OIL [~ SINGLE ZONE ~] DEEPEN ~ DEVELOPMENT GAS ~ MULTIPLE ZONE ~ 2. Name of operator ~(~" ..... ARCO Alaska, Inc. P.0. Box 360, Anchorage, AK 99510 4. Location of well at surface 9. Unit or lease name ~10~ 1139'FSL, 313'FWL, Sec. 5, T/IN, R10E, UM Kuparuk 25647 At top of proposed producing interval 10. Well number 1320'FNL, 1720'FEL, Sec. 5, T11N, R10E, UM A-3 At total depth 11. Field and pool 898'FNL, 1235'FEL, Sec. 5, T11n, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF etc.) ~ 6. Lease designation and serial no. 61'GL, 66' Pad, 100' RKB~ ADL 25647 Kuparuk River 0il Pool 12. Bond information (see 20 AAC 25.025) lvp~ Statewide S~tv~"d/°rnumb~Fed. Ins. Co. 8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi NW of Deadhorsem,~, (at TD) 898 ~,t ~"" (at surf) 120 ~,,t 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 8727' MD/6761 'TVD ~,~t 2560 ._.Z/01/81 .... 19. If deviated (see 20 AAC 25.050) ~20. Anticipated pressures ~ psig~ ~U~ Surface KmK OFF POINT 1031 ~,.t. MAXIMUM HOLE ANGLE 45 o~ (s.~ 2o AAC 25.035 <m ~2> 3155 p,~ 6120 ~.-T~(TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTO~ TVD (include stage data) 24 16" 65~ H-40 Welded 80' Pad ~ Pad 114~ 114 + 20~ ft3 13 3/4 10 3/4 45 5~ K-55 BT&C 2948 Pad ' Pad 2982' 2700 -1200 sx foudu+250 " , Pad 8727 ~ 6761 830 sx Class G 8 3/4 7 26~ K-55 BT&C 8693 Pad I ~ I 22. Describe proposed program: ARCO Alaska, Inc. proposes to drill a Kuparuk River Field, Kuparuk River 0il Pool devel- opement well to approximately 8727'MD, 6761'TVD. Selected intervals will be logged. A 20" x 2000 psi annular diverter will be installed on. the 16" conductor while drilling the surface hole. A 13-5/8" 5000 psi RSRRA BOPE stack will be installed on the 10-3/4" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig. Expected maximum surface pressure will be 2646 psig.based on cooling of a gas bubble risi.ng at constant volume. The well will be completed with 3~" 9.3# J-55 buttress tubing. Non-freezing fluids'will be left on uncemented annuli thru the permafrost interval. Selected intervals will be perforated within th~ Kuparuk formation and reported on subsequent reports. A downhole safety valve will be intalled and tested upon conclusion of job. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge The space below for Commission use CONDITIONS OF APPROVAL Samples required Mud log required Directional Survey required ] APl number ~YES ~NO ~YES ~NO ~Y~S ~NO~ 50-- ., Approval. date Permit number ~/- ~ 06/26/81 ~ SEE COVER LETTER FOR OTHER REQUIREMENTS .... APPROVED BY ~ ,COMMISSIONER DATE ~e 26~ 1~81 by order of the Commission Form 10-401 Submit in triplicate Rev. 7-1-80 -ZOO0 'FEE -i';- PER I00 FT.. EOC ''' TYD=338~i CRSZNG POINT TVD=2700iTHD=2982'DEP~878' .... TVD=3300, THD=383t--;r ~- ~- K- l al.i'~.vo=3600 ~TI'IB=4aSS OEP = l ! . ~ * ; 1 · : [TOP.': KUP'{SRND$ } ~'-: L'.'. ~TOP LOi~ER SRND5 ;'~rVD=6520' rHD=OI03 BRSE KUP SRNDS TVD=6425i THD=8252 ~. THD--"/8eO I' :'.~-';; DEP=4301, .. --~ ERST 3E47.' .; ~,z.,?,..! ,.; .J .... LOSGZNG POXNT.. TVD=6566 THD=8451 DEP=4748. TD ,{:HRX} TVD=6761 THD=8727 DEP=4943 !ii',; I ~ WELL A1 Y = 5,971,467.25 " "~ X = 540,'1 78.17 . LAT = 7~°19' 58.741'~ '1' ~ > ~ ,..LONG =.- 149°40'26.679'' l~~ i WELL 'A2 ~Y = .5,971,346.82 ~l~e' AIL X = 540 178 32 Z~ , . ,_ LAT : 70°19' 57.557'' .> ~ ~ LONG = 149o40'26.693'' :~i~I A~ ~ WELL A3 Y = 5,971,227,31 .... ~'--'-~ X = 540,178.51 ~ LAT = 70°19'56.381'' < ~ LONG = 149°40'26.707'' ~1~w A~~~ ........... WELL A ' Y = 5,971,\106.83 . > ' ~ X = 540,178,52 ' ~ LAT = 70o19' 55. 196" ~)12' A41 -- -- ----Q~~i~ ~ LONG = 149o40'26-725'' <I ~1 WELL A5 Y = 5,970,986 86 ' O X : ~40,178.61 ~ '~ll' AE(~ LAT = 70o19' 54 016" ..... i- ~ '~fI . ~LONG = 149o40'26.741'' ' WELL A6 Y = 5,970,866,70 ~1o' .... : ~AE,(~_~ I X = 540,178.7 1 ~' I LAT = 70o19'52.834' ~II~~ '~' LONG = 149o40,26.757, ' $~Ot~' A'/ WELL A7 Y = 5,970,746.7'3 ~ $ ' X : 540,178.55 , LAT 70°19' 51.654'' ' .. LONG = 149°40' 26. 781' ?07' AI~__~, W~T, -"--- < . ~Ad, i~1'2 WELL J I X ' 540,178.59 'I LAT = 70°19' 50.475'' i . .~.,?~.~,¢~...'~.t,:~/,,x~,.~ I HEREBY CERTIFY THAT I AM Z~..?,"~,'" ~., ~'-,,?,~;. PROPERLY REGISTERED AND LICENSED .'L-~:9'~' -.~:?,:.~.-.;:~ ", ~, (.TO PRACTI CE LAND SURVEY I NG I N -:'"'-*-' ,'~::;~"-~ ~:'-:~.. '-~ ,~.' THE STATE OF ALASKA AND THAT / :.::,,~ ,//,/~, ~ /~ ~: ................... -: ......... E...,' THIS PLAT REPRESENTS AN AS- ~ ., i/~:.;,/~ ,. C~_~t,.'~ ,~ ~ THAT ALL DIHENSIONS AND OTHER ,?~ :~,'. ,'~.~]. ~,~-,~ .. ~' ~.~ DETAILS ARE CORRECT, AS OF: AtlanticFlichfieldCompany ~ DATE: DRAWING No: NORTH AMERICAN PRODUCING DIVISION IO.~Z-~o ALASKA DISTRICT- KUPARUK , II i! 1. 16" Bradenhead. 2. 16" x '20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/lO" side outlets. 4. 10" ball valves, hyraulically actuated, w/lO" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. 20" bell nipple. Maintenance & Operation ~ 1. Upon initial installation close annular ! preventer and verify that ball valves ! h_ave opened properly. ~ i 2. Close annular preventer and blow air ~__ . through diverter lines every 12 hours. 3. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually over- ride and close ball valve to upwind diverter line. Do not shut in well under anS circumstances. 16I' Conductor .... 13-5/8" 5000 PSI RSRRA BOP ST~'~' RNNULRR PREVENTOR 9 ) ) BLIND8 RRHS ) l- ) RILLING SP6OOL ) PIPE RRHS PIPE RRMS ~ 5 TBG HD CSG HD 2 1 1. 16" Bradenhead 2. 16" 2000 PSI x 10" 3000 PSI casing head 3. lO" 3000 PSI tubing head 4. lO" 3000 PSI x 13-5/8" 5000 PSI adapter spool 5. 13-5/8" 5000 PSI 6. 13-5/8" 5000 PSI and kill lines 7. 13-5/8" 5000 PSI 8. 13-5/8" 5000 PSI 9. 13-5/8" 5000 PSI pipe rams drilling spool w/choke pipe rams bl i nd rams annular ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME THEN CLOSE ALL UNITS SIMULTANE- OUSLY AND RECORD THE TIME AND PRESSURE REMAIN- ING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RE- TRACTED. PREDETE~qINE 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 MANIFOLD. ~ 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR l0 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR l0 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST R~IAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM SET OF PIPE RAMS. lO. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. ll. OPEN BOTTOH SET OF PIPE RAMS. BACK OFF RUN- NING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR lO MINUTES. BLEED TO ZERO PSI 12. OPEN BLIND RAMS A~D RECOVER TEST PLUG. '"~i~. SURE MANIFOLD AND LINES ARE FULL OF ARCTIC'~> DIES ND ALL VALVES ARE SET IN D I -~. POSITION ..... 13. TEST STANDPIPE VALVES TO 3000 PSI. 14 TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH K00HEY PUMP. 15 RECORD TEST INFO~4ATION ON BLOWOUT PREVENTER TEST FOP~I SIGN AND SEND TO DRILLING SUPER- VISOR. 16. PERFO~4 C~IPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. cHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee :~ ~- L~-'~I (2) Loc ~f~_ i~Vf~ thru 8) (3) Admin ~/~. g~ ~5'-~'/ ~ thru 11) (4) Casg __~ ~.~-~ u 20) ' (5) BOPE _~ ~-g~ g~ (21 thru 24) Company ,. :~o 1. Is the permit fee attached ....................................... 2. Is well to be located in a defined pool ................ 3. Is well located proper distance from property linel .i.[~i!i{ iii{ 4. Is well located proper distance from other wells ..... 5. Is sufficient undedicated acreage available in this pool .. . 6. Is well to be deviated and is well bore plat included .. 7. Is operator the only affected party ............................... 8. Can permit be approved before ten-day wait ........................ Lease & Well No. e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. YES NO REMARKS Does operator h bOnd in forc ' ave a e .................................. Is a conservation order needed ' Is administrative approval needed ................................... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zOnes .................... ,.. Will all 6asing give adequate safety in collapse, tension and burst.. ~__ Is this well to be kicked off from an existing wellbore ..... ........ Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... ~_ 21. 22. 23. 24. Is a diverter system required ....................................... ~ Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating - Test to 3~ psig .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. (6) Add: ~ ~-2~"~! 25. Additional requirements ............................................. ~__ Additional Remarks: Geology: Engineering: HWK LCS BEW WVA JK~ PAD JAL rev: 03/10/81 INITIAL GEO. UNIT I ON/OFF POOL CLASS STATUS AREA NO.I SHORE Well Histo.ry 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. ;. o o. - GVP OiO,HOl _. ORIGIN : DAT~ :82/10/'~:7 - ~: OR~GIN CONTINUATION # ~0i COMMENTS :TAPE COM:MEN~S MNEM CON:~.:B.NT.S: ::.: · ~ UNI.T :TY~P'E~: CATB. S~Z~ mmmm mm~mmmm mmmm mmmm mmmi mWm~ RANG:: '. I:0B~.:. : TOWN: lin · ' ' A A '" " ' ~TA:Ti h BK.A MNBM CON T~EN T:~ O22 OO3 0O7 ~i~O00 000 003 000 000 OO3 00:0 000 001 000' 000 01I :.000 000 006 0 CODE 065 065 065 065 065 065 065 065 CODE 06b ** COMMENTS ,JOB # 10707~620~2 DIb RUN ~1~ bOGGBD 13'dUb'81 BOTTOM bOG NTERVAb TOP LOG INT~RVAb CA$ING-bOGGER- BIT'-SIZE TYPE HObE FbUID DENSITY- VISCOSITY PH FLUID bUSS RM 8 MEAS, TEMP, .~c ~ ~. ~.~. RM 9 BHT MATRIX SANDSTONE AND BHC RUN IN COMBINATION PAGg ENTRY BLOCKS ~ ..... '. ~i · TYPE SIZE REPR CODE ENTRY 4 1 66 1' 8 6 73 60 0 I 66. MNEM SERVICE'SERVICE :'UNIT APl AP1 APl AP1 FILE SIZE; PROCESS SAMPLE I.D': "' ORDER! ~ 60G TYPE CLASS MOD ~N'O~ DEPT "- F~ 0 0 - 0 0 O' 4 -'0 i SFLU .OiL O~MM 0 IbM Dib OHMM 0 ~P D15 4 OR Bib 32'. 0 0 4 o NPHi FDN 2 0 0 4 0 RHOB. FDN G7!:C3= ~42 3:5 I 0 0 DRHO FDN G/C3 42 44 0 0 0 4 0 1 Ca~Z FDN I.N..4:2. :2.8 3 0 0 4 0 I OR -- FDN GAPI 42 3! 32 0 0 4 0 NR:AT FDN : "~ : .42 ~:42 '1 0 0 NCNb FON CPS42 34 92 0 0 4 0 1 FC. Nh FDN 93 0 0 DT "' BHC 32 0 0 4 GR BH.C GAPZ-~ 60 31 32 0 0 0 ~ . ~ - . REPR CODE 68 68 68 b8 ~8 DATA DEP~ SP NCN~ 'O.:O'Ot.O:~ C.Abi 1767;0000 FCN~ 2,693~ 91'328i NPHI 48.8281 RX'OB I1,0547. 37'9,2500 DT 105,37'50 OR SP .... -~,0~:~> OR ? , 49 3906 NPHZ 2:9 DRHO v,0'I86 CAI..i ' 8:9766 GR 48:I3::~6:~75 'R:HO~NRAT NCNb 30:b.:4.-.OOOO:..FC:N~ 961,0000 DT 95*0000 OR DEP~ ~IO00::O OO ~F:b~ 4,4023 IbM 4,33'98 IbP &P - -'-73 7'~1~ OR - 88,5781 NPHI 33,0078 RHO~ DRH'O -0' 0~:5~-::' '.: C:Abi Ii, 3:98~: GR ' : .:~9~:t:'8:::~ NR:A~ NCN~ 2550 0000 FC:N~ 69'2'0000 D'I' ~3.:3750 G~ .... , .. , . . .... . 2,3242 -999,2~00 '999,2500 2,3262 2.1895 3,986~ 91,328I 16.937~ '775~ ,390e 578I 010.HuI DEPT DRHU NCNE D~PT DRHO NCNb DEPT DRHU NCN~ DEP~ DRHU NCNb DEP~ DRHU NCNb -- .. DEP~ DRHU NCNB .. DEPT DRHU NCNb o. DEP~ DRHU NCNb DEP~ DRHO NCNb D£PT DRHO NCNb D£PT DRHU NCN~ ~0U0,OuOU --U~,.570J GR - - .0~05 CAb~ 2502,0~00 FCNU /guo,OUOO ''bT,765b GR - "0.0~5~ CAbI JIJ8,0UOU rCNb 7800.0000 SFBU -0,0~98 CAb[ 23~2,0~00 FCN~ -g~g.2~O0 CAbl -999,2~00 rCN~ ~ · -- ~600,0~00 &FbU ~ ,2b00 CAB[ - J 2813 OR *- 9~9,2~00 CAb~ :9~9,2900 FCNB 7400.0000 SFbU 5,~31 GR - -- --69 197 GR - -9~9,2~00 CAb1 -9~9,2~00 FCNb 7200,0000 ''25.2~00 OR -9~9,2~00 CAbi -~9,2~00 rCN~ .1562 OR - -9~9.2~00 CAb[ -999,2~00 rCNb 70UO,OUOU 5rBU -999,2~00 CAbZ -999,2~0U rCN~ il 4,6914 81'4063 NPHi i0,890e GR 1213,0000 D~ 3, 1. 01 ~: 01568281 OR N P H.Z._ '~:.!~.09; 937'5 g"9 ~ ::::::::::::::::::::::::::::::::::::: NRAT :: 794,5 O00 D ~ ~ 9:2 ~0000 ::O:~: :'::~: :'::: :' :::::::::::::::::::::::::::::: . .117,4063 N~H:[ :999'25'00 .... RHOB =999,'2500 999,25 O: 0 · G ~ : ::': ::.:.: ~ ~'.':,.'...9:99 ~-:2::5~::0:.0~ -~,2500 ~t 1~:?';'5'b25 Ga ~' '~'?;40'63 ~ I 8,593:8. -999,2500 GE - "9~9'";'2':50'0 .... NRA'~ ~'~9;2500 8437 -99~, 2500 -99 ,2500 DT 3,.3125 [b~ ..... 3'101 =999: 2500 GR ' ,"'9~9 ;'25:00 HR'A'I' -' -999,2500 DT 2,6836 . i 23,0625' NPH'I ':=999'::,'2'~0:~:0 -':':::R'HOB =9 '2500 5.0469 .106~7544...:NP:HI 999,250'0 GR - -999,250.0 DT 173,8750 'NPH~ -999,2500 :GR ' =999 , 2500 D'T 7188 iq 999,2500 GR -- :" ;9~9:";"250'0': NRA"T ;'9'99';'2500 -999,25o0 D~ ..:~ .. ::. ?..:.:~: · .:;~. :.' :;~;;::.:: ~:. :~::::;::~;: DEPT 6900-OO00: ~.~L~ 3.0293 ~'P --25'218'7 GR-'~ .133,5938 DR HO -9~9-.2~:00:: CAGZ ~9'9:9 ~ 2500 GR NCNb '9~9~2~00 .... FCNb '999.2500 DT D~PT . DRHU -999' 2500 Ca~i NCN ~ ' 9:99.2~.0:0 S~ :'22,7813 DR H ~ - 999.2:~ 00:~:: NCNb '9~9.2'500 FCN~ -9 =99.9,25 00 DT .i83'8437 NPHI '999'2500 DT 999,2500 RH~B ',,~,9::9:9.-~:2'50::01 NRAT i07,5625 GR -999°2500 RHOB -99:g:, 2:5:00 N RAT ! 17.56'25 GR 0195 -999.2500 1~3.5938 3.2363 -999.2500 -999,2500 133.1875 2,3027 -999.2500 '999.2500 183,8437 8135 2500 2500 O00U $:P ': ..!8 2:bO0: ::GR ~ I:6~!.0:000 N. PHI :999.2'5:00:~ RH..OB -999. D'RHO -999'2500 CAbI: :999.2500 GR 9'9'9~2500 NRAT -999 NCNb -g~g~2~:~O:O.::::FCN~ .~,'~,999.2500 DT. 141: - .- .. D~.PT ~:.O:O. OUOO:~::~'.$:Fb~ 1,2695 IbM i-690.:4i SP - :;'2:5;~:375 G'R = .172;1562 NPHI -999i2500 RHOB D:RHO !,,,,,999.2500 GR -g9'9...2500 ,':NRAT NCnb '9'~9'2500 FCN~ -999,2500 OT II0.1875 GR DEPT b30.O.OO.O0: SP ='29'75'00 GR DRHO 'g::9':9~2:~00~ NCNb '99'9.2b00 FCNb I ~;5:2'2207 ZbH .0313 NPHI -9'99'2500 Rfl'~ ~9:9i9.:2'500 GR -9;9.9.2~:!500 NRAT '999.2500 DT 1!5,0000 GR 1,7500 '999,2b00 '999.2500 ~72'1~62 · 3.0449 99~2500 t28.4063 2.0293 -999.2500 '999.2500 155.0313 2.3510 -999°2500 -999.2500 127.1~6Z 2,60~4 -g99,25 0 -999.2500 93~2500 2.1328 '999,2bO0 -9~9~2500 86,5~5b 3,3730 '999.2~00 -- . ="18,2'18'7 GR - DEPT 3 1'191 SP 93i2500 NPHI DRHO "999 2500 G:'R NCNb '999,2500 DT 63 SP ....... 86: ~56: ~PHI DRHU -9'9'9 2:500CA'~ -999. 500 GR NCN~ -999 2.~0.0: FCN~ '999.2500 DT D~PT Se '20;0~56 GR - DR'HO . .2,:58.79 tbD :999;2500 RH'OB ,,~,, 999 ~ 2500 NRAT i03,00'00 OR -999:-2500' RHO~ -999,2§00 NRAt Io?.56,25 o. -- I'00;2i87 '999.'2'500 OR ' -999.:2:5::00 NRA.T bVP 010.HUI V~RiFICA~ION · NCNb -9~9,2~00 FCNb DEPT ~SOO.OOOO SFbU SP '*Z2,015~ GR - D~HO -999,2~0~ NCN~ -999,2~00 FCN~ DR~U -9~9,~00 CA~I NCN~ -9~9, ~00 FCNU _ -. DEPT 56~O,OUOU DRHU '9~9.2~0~ CA~I NCNb '999,2~0U FCN~ D~P*~ ~SuO.OOOu 6Fbu SP '-~5,2Z6b GR -' DRHu -999,2~Oo CAb1 NCNb -9~9.2~0U FCNu D~PI b4UO.OUOO DRHU -9~9,2b00 Ckb~ NGNU -9~9,2~00 FCNU DEPT ~3uO.OUOU 8FbU 5P - '-ZT,4~Su 6R - DRHU :9~9.2~00 CAb& NCN~ 999,2~0U FCNu -- NCNb -9~9,2~0U FCN~ 5P - ' ~ .9067 GR- DRHU :9~9,2=00 CAbl NCNb 9~9.2~0U FCN~ S~ - -~ .218'1 GR- DRHU 9~ .2~00 CAb/ NCN~ 9~9,2~0U FCNU D~PT ~guO,OuOu ~Fbu DRHU -9~9~2~00 CA~I NCN~ -999,2~0U FCNU DEPT 6SUO,OUOO SFbu SP - ~*-44,4127 GR - bISTING -999.2500 DT 2 4023 tb~ 71~0938 NPHI -999.2500 GR "' -999.2500 DT -'999 ; 2500 'RHOt~ -999.2.5'00 99;"75'00 .... OR ~ ~'1;0938 999'2500 GR "- 999'25'00 NRA'T ...... 999'25'00 -999.2500 2,9 766 102;9531 NPHI -999;2'500 ...... RH'O~ -999 2500 -999,2~00 D~ ~0'2;562~ ......GR ~ lo~ 9531 ' 999.2500 DF ~:00~:,~:5025: ::::.: :'::GR :. i'::. 9:2:1:,ii..?~ :I~:!7:~ "~: !~ 3,0508 ;[,~ ~ 3* ~::~::0:,~ :'::.: :;ZbP~ ::. :..3~ 88.453I NPHI -999':; 250'0 R'~O~ '999,2~00 - 999 · '25 00 . G R ~ ~' ':":99:9:'~'2~OO.::'::~::'::~N~A~:::::~:' ~::.::' "9:9:::9~:~ =999.2500 DT ~"07; 7500 GR : ~8,453'I 79.7 3~ 6 N P H I =-~9:~:i~2:50:O:':':~:'::::~:::RHO~'~::: .::: : :~:::: 999 :* 2:'5~:~:~ -999.2500 'G~ :- 999:~:25:00 NRAT 9~9;2'500 2.6941 !b~ ~;::: :?2. :6::~:99 ~:.: :. :Z:bD::~::. '::.: . :::. ::;:2.7 ~5:.9 62 ' 63 ? 5 NPH ~ ' 999:' :2'500 'R"HO'~ : =9'99"; 2500 '999 2500 GR "999 ~ 2~O:O.~ :'~::~R:A~: ::::~ :':.:~?~*79:99 i-2.~:00 -999:2500 D~ ~ 1'4. ~:'75~ OR':'':'~ : 82;4375 2,6504 . 68,7500 NPHZ 999,2500 GR '999,2500 DT SP .... '~3:2~44 G:R'~ 80'6875 NPH~ DRHU .... 9:9,~ NCNb -99'9"2'500: FC'N~ '-' 999'2500 DT DRHU -9~9 2'500 NCNb D~P~ NCNb -9~9'2"b00 FCN~ . 80'8594..!.NPH! 999~2500 OR '999.2'500' D~ ,9 9., 25 00 GR =999 ;2500 ,,'9:~':9 .:2:50:0::: : -999; 2'500 NRA~ I::ZO w:5:.~,2 .. G:-R '999; 2'50'0 RHOB -999 lI8~3'750 OR' ~ ~12 -999.2500 96,9~87 3,0315 -999.2500 '999 2500 ~0~6875 2.62~1 -999,2500 -999'2500 ~0.8594 6055 ~250u ,250o ,5781 0564 2~Ou 2500 76,406J 5 9~35 -999i2~0o -9~9 2500 64 6094 O.:O::~:.:::..EC~..~ 99:9-2500 5.:.0:547' 64'6094 NPHi :9'99,25:00 RHO~ :~9!9:9.~2:500 :999'2500 D~ 1'11,'000'0 OR b~Hu "9'~:i:~;'125'06:::':'~A~! '999;2500 GR - '999,25'00 NRA~ -999.2500 NCNb .-9:~9.2~O0~:';:::~:F.¢N~ :-9:99~2500 D~ ~09.Si:625.;.:O:R:' ~6.7969 :'5'0,0':0'~9 75'i250 NPHI '.999'2500 RHOB SP · DR. HO ' 9.:~9:~:~2:5:00.~:::~:::~CA~ -9:~99.2500 OR .-9.99. NCH~ '999'2500 FCN~ '999.2500' DT I~9~'7500 ':OR 75, SP. ~: ~:-::.~5 ~..7~9:b~: GR:'~. ~ :' : 76 ,~75 00 · N.P:H I -999 ~ 2.500: : R'H:O~ : 999. DA'HO '999',"2~0'0: '¢Ahi '999,2:500 OR - '999,2500 NRA~ 999. DE:P~ ~9.00,O0:O"O:.i.::5.F:hU 11.:7891ZbM SP '~-~1;0:0'00 GR .... 5'8'9062 NPHI DRH.O OR NCN~ -999'2':~0'0 FCN~ 999,2500 DT DRHO -9)9', 25'00 C'ALJ[ NC;N~ -:9:'9:9 ~ 2:i~00..:::. ~CiN~ DE:P~i: .' · 3~:00..000.0:~' ::.. :SF::G.U 7.2:266 IbM 9~:~.:4'2:972L, D = ;2'5'00 RI-IO~ 999,2'~:'00 RAt ! 33 · 5000 GR ~00: RH:.Oi~ 500 N:RAT 0:0'00':: O!~; 7,86.'3JlbD 1.2 58' ....... ,999~ '999, 8, ~211 2500 2900 1250 0938 250O 2500 7500 2031 2500 2500 9062 8750 2500 2~00 8984 281~ UYP 010.HU1 Sp -~6.2J44 GR DRHU :9~9.2~00 CAUl NCNb 9~9,2~00 rCNb DEP~ 3600.0000 SFGU Sp -'~6.2b~7 GR - DRHU :9~9.2~00 CAUl NCNb 9~9.2b00 FCNb DEP~ d~U0,0O00 SFbU Sp .... b6.?bSb GR - DRHU -9M9.2~00 CAUl NCNb -9~9,2b00 FCNb DEP~ J4UO.OO00 SFbU Sp --74.904~ GR .... D~HU -9~9.2~00 CAUl DRHU NCNb -9~9.2~00 .. . -- DEP~ J~O0,0000 Sp 04,257~ OR - DRHU -9~9,2~00 CAUl NCNb -9~9.2~00 FCND ,ooo.o oo DRHO '9'2'9 ~00 CAb1 DEP~ z9~,SuOu SFLU SP - '-~l,TbSb GR - DRHU -9~9,2~00 CAUl NCNb bISTING -999.2500 D~ i2'0,7500 G"R 71,5i56 75,9219 NPH -999'2500 GR - -999,2500 DT ii! 13.0313 IbM 63,8750 NPH~ -999,2500 GR.." -999,2500 D~ 11,1250 IbM 36,1406 'NPH~ '999.2500 GR ' '999.2500 DX 11.8828 ibm 30.1836 NPHI -999,25:0'0 GR -999,2500 D~ 250'0 NRA'~ ' 7':~0:0 i'iO'R:'::::i?:.?-i~. 5:6i;.~:.iI::~:0:~'.' : ': 2500 R~:O~ -9~9; 2500' ~5' i::250 ....... OR" '::' 30 , ~836 68 I875 :NPH! -999;2500 GR -- - 999,250. 0 D2' 1 Z- 7,37 59 :::~'. ============================== ::::' ::::.:" 68 -999.2900 D~ ~9:,5938 G'R ~ ' 39'39'84 SERVICE-NAME - T - V~R~IUN #- ; DAT~ t ' MAXIMUM U~NGTH ; 1024 NEXT FI~E NAME DAT~ ~.82!I'0~ '! ....... CON~INUATIO~ ~ PAGE COMMENTS :R~Eb COMMENTS