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Home My WebLink About188-0261. 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: Replace Tubing 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 9195'feet 8697'feet true vertical 6826' feet 9033'feet Effective Depth measured 8877'feet 8558',8644'feet true vertical 6572'feet 6321',6388'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" 2-7/8" L-80 J-55 8619' 8750' 6368' 6471' Packers and SSSV (type, measured and true vertical depth)8558' 8644' 6321' 6388' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 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: 324-553 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker FH Retrievable Packer: Brown HR SSSV: None Adam Klem adam.klem@conocophillips.com (907) 263-4529 RWO/CTD Engineer 8819-8841', 8852-8890', 8906-8934', 8944-8984', 8998-9018' 6526-6543', 6552-6582', 6595-6617', 6625-6657', 6668-6684' 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) N/A Gas-Mcf MDSize 110' Well Shut-In measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 188-026 50-029-21793-00-00 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: ADL0025520, ADL0025513 Kuparuk River Field/ Kuparuk Oil Pool KRU 3O-18 Plugs Junk measured Length 8928' Casing 6807'9171' 5064' 110'Conductor Surface Production 16" 9-5/8" 80' 2937' 2371' Burst Collapse 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 1:38 pm, Dec 05, 2024 Digitally signed by Adam Klem DN: CN=Adam Klem, E=adam.klem@ conocophillips.com, C=US Reason: I am approving this document Location: Date: 2024.12.05 12:27:44-09'00' Foxit PDF Editor Version: 13.0.0 Adam Klem Page 1/8 3O-18 Report Printed: 12/2/2024 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) 10/31/2024 05:00 10/31/2024 10:30 5.50 MIRU, MOVE MOB P Pick up rig mats, and clean up around well. Wait on pilot car for rig move. 10/31/2024 10:30 10/31/2024 23:30 13.00 MIRU, MOVE MOB P Pull sub off location, and move to 3O- 18. Arrive on location at 11:30 PM. 10/31/2024 23:30 11/1/2024 00:00 0.50 MIRU, MOVE SFTY P PJSM to spot sub over well. Called Pad operator to witness and open SSV. 11/1/2024 00:00 11/1/2024 02:30 2.50 MIRU, MOVE MOB P MIRU Spot sub over well. call sow to spot in pits. Operator opened SSV. 11/1/2024 02:30 11/1/2024 07:30 5.00 MIRU, MOVE MOB P Move pits into position. Turn steam on to rig. Unload trucks. Install berming around sub. Run electrical cables for shop, and office. 11/1/2024 07:30 11/1/2024 08:00 0.50 MIRU, MOVE RURD P Raise the derrick. 11/1/2024 08:00 11/1/2024 15:30 7.50 MIRU, WELCTL RURD P Shim pit module, insulate breeze way. Hook up interconects. R/U Cuttings box. Spot kill tanks and R/U hardline. Fill the pits. RIG ACCEPTED 1100 HOURS. 11/1/2024 15:30 11/1/2024 17:00 1.50 MIRU, WELCTL RURD P Load pits with seawater. 11/1/2024 17:00 11/1/2024 22:00 5.00 MIRU, WELCTL CIRC P Attemtped to pressure test hard line to kill tanks, made reapairs as needed. Verified line up. Bled gas and pressure off well. Circulated 589 BBLS seawater 7BPM 2500 PSI 11/1/2024 22:00 11/1/2024 22:30 0.50 MIRU, WELCTL OWFF P Flow check well blow down lines. 11/1/2024 22:30 11/1/2024 23:00 0.50 MIRU, WHDBOP MPSP P Set BPV and tested to 1000 PSI for 10 minutes. 11/1/2024 23:00 11/2/2024 00:00 1.00 MIRU, WHDBOP NUND P N/D tree and adpater. Adapter difficult to remove. 11/2/2024 00:00 11/2/2024 01:00 1.00 MIRU, WHDBOP NUND P Install test dart and function test LDS. Functioned X-O in hanger neck. Recored RKB measurements. 11/2/2024 01:00 11/2/2024 05:00 4.00 MIRU, WHDBOP NUND P Install DSA on tubing spool. NU BOP's. Sim-Ops: Process DP, organize yard. 11/2/2024 05:00 11/2/2024 07:00 2.00 MIRU, WHDBOP RURD P R/U Test equipment on the rig floor. 11/2/2024 07:00 11/2/2024 07:30 0.50 MIRU, WHDBOP BOPE P Shell test BOPs 2" Demco on kill line leaking. Replace paddle, and seat. Rig: NABORS 7ES RIG RELEASE DATE 11/10/2024 Page 2/8 3O-18 Report Printed: 12/2/2024 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) 11/2/2024 07:30 11/2/2024 17:30 10.00 MIRU, WHDBOP BOPE P Start testing BOPE. Initial BOPE test, Tested BOPE at 250/3000 PSI for 5 Min each, Tested annular on 3-1/2" and 2-7/8" test joints, UVBR's, w/3-1/2" and LVBR's 2-7/8" test joint. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 3 1/2" HT-38 safety valve, 3-1/2" FOSV, and IBOP. Test 2" rig floor Demco kill valves. 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=3000 PSI, after closure=1650 PSI, 200 PSI attained = 15 sec, full recovery attained = 123 sec. UVBR's= 5 sec, Annular= 17 sec. Simulated blinds= 5 sec. LVBRs=6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2050 PSI. Test gas detectors, PVT and flow show. Test Witnessed by AOGCC rep Josh Hunt. 11/2/2024 17:30 11/2/2024 20:00 2.50 MIRU, WHDBOP BOPE T Start testing BOPE. Initial BOPE test, Tested BOPE at 250/3000 PSI for 5 Min each, Tested annular on 3-1/2" and 2-7/8" test joints, UVBR's, w/3-1/2" and LVBR's 2-7/8" test joint. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 3 1/2" HT-38 safety valve, 3-1/2" FOSV, and IBOP. Test 2" rig floor Demco kill valves. 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=3000 PSI, after closure=1650 PSI, 200 PSI attained = 15 sec, full recovery attained = 123 sec. UVBR's= 5 sec, Annular= 17 sec. Simulated blinds= 5 sec. LVBRs=6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2050 PSI. Test gas detectors, PVT and flow show. Test Witnessed by AOGCC rep Josh Hunt. 11/2/2024 20:00 11/2/2024 22:00 2.00 COMPZN, RPCOMP RURD P RD from testing blow down lines drain stack. clear floor, RU power tongs, spooler and handling equipment. 11/2/2024 22:00 11/2/2024 22:30 0.50 COMPZN, RPCOMP PULL P MU landing joint to hanger, BOLDS, pull hanger to floor. PUW=65K weight broke back to 60K block=30K 6,812.0 6,784.0 11/2/2024 22:30 11/2/2024 23:00 0.50 COMPZN, RPCOMP OWFF P Fill hole, OWFF 6,784.0 6,784.0 11/2/2024 23:00 11/3/2024 00:00 1.00 COMPZN, RPCOMP PULL P Terminate control line and secure at floor. LD landing joint and tubing hanger. 6,784.0 6,784.0 11/3/2024 00:00 11/3/2024 00:30 0.50 COMPZN, RPCOMP RURD P RU to circulate BUS. 6,784.0 6,784.0 11/3/2024 00:30 11/3/2024 01:00 0.50 COMPZN, RPCOMP SVRG P Service black jack 6,784.0 6,784.0 Rig: NABORS 7ES RIG RELEASE DATE 11/10/2024 Page 3/8 3O-18 Report Printed: 12/2/2024 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) 11/3/2024 01:00 11/3/2024 02:30 1.50 COMPZN, RPCOMP CIRC P Circulate BUS. 6,784.0 6,784.0 11/3/2024 02:30 11/3/2024 15:00 12.50 COMPZN, RPCOMP PULL P POOH L/D 2 7/8" pipe. All connections tight. Pulled 222 Joints, SSSV, 3 GLMs, and 25 Stainless steel bands. 2 GLMS, and 41 jts of tubinng remaining in the hole. 6,784.0 0.0 11/3/2024 15:00 11/3/2024 15:30 0.50 COMPZN, RPCOMP CLEN P Clean and clear rig floor. R/D power tongs, change out handling equipment on the rig floor. 0.0 0.0 11/3/2024 15:30 11/3/2024 16:00 0.50 COMPZN, RPCOMP OTHR P Set bowl protector. 0.0 0.0 11/3/2024 16:00 11/3/2024 16:30 0.50 COMPZN, RPCOMP SVRG P Rig service. 0.0 0.0 11/3/2024 16:30 11/3/2024 17:30 1.00 COMPZN, RPCOMP BHAH P Load BHA in pipe shed and MU BHA. 0.0 17.0 11/3/2024 17:30 11/4/2024 00:00 6.50 COMPZN, RPCOMP PULD P Single in with F/27.16' T/6500' PUW=120K SOW=80K 17.0 6,500.0 11/4/2024 00:00 11/4/2024 01:00 1.00 COMPZN, RPCOMP PULD P Continue to RIH F/6500' T/7231' kelly up on joint 232 PUW=135K SOW= 90K 6,500.0 7,345.0 11/4/2024 01:00 11/4/2024 01:30 0.50 COMPZN, RPCOMP WASH P Wash down to top of fish at 7348.95' 6,500.0 7,349.0 11/4/2024 01:30 11/4/2024 02:15 0.75 COMPZN, RPCOMP FISH P 1.5 BPM 110-115 PSI. Set down 10K attempt to pull fish unable to get a bite. Set down 15K PU 140K weight broke back Rotated over top of fish set 20K no bit grapple slipped ROT down at 5RPM 3.2K torque worked down to 7353' PU to 145K weight slipped off. ROT down set down 25K torque 3.2K free torque PU to 145K weight slipped off. repeated 3 more times with same result. 7,349.0 7,349.0 11/4/2024 02:15 11/4/2024 02:45 0.50 COMPZN, RPCOMP RURD P L/D 2 joints blow down top drive. 7,349.0 7,349.0 11/4/2024 02:45 11/4/2024 03:15 0.50 COMPZN, RPCOMP SVRG P Service rig. 7,349.0 7,349.0 11/4/2024 03:15 11/4/2024 08:00 4.75 COMPZN, RPCOMP TRIP P TOOH F/7348' T/17' PUW=135K 7,349.0 100.0 11/4/2024 08:00 11/4/2024 08:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA # 1. Marks on the inside of cut lip shoe. Minimal markings on inside of control. No marks on control packoff or grapple dies. 100.0 0.0 11/4/2024 08:30 11/4/2024 09:00 0.50 COMPZN, RPCOMP CLEN P Clean and clear rig floor. Bring pieces for next BHA to the rig floor, and pipe shed. 0.0 0.0 11/4/2024 09:00 11/4/2024 10:00 1.00 COMPZN, RPCOMP BHAH P M/U BHA #2 ( Crown shoe, wash pipe, and tripple connect with concave mill). 0.0 33.0 11/4/2024 10:00 11/4/2024 11:00 1.00 COMPZN, RPCOMP PULD P P/U singles of drill pipe from 33' to 1545' 33.0 1,545.0 11/4/2024 11:00 11/4/2024 14:00 3.00 COMPZN, RPCOMP SLPC P Cut and slip drilling line. 1,545.0 1,545.0 11/4/2024 14:00 11/4/2024 14:30 0.50 COMPZN, RPCOMP SVRG P Rig service top drive, and handling equipment. 1,545.0 1,545.0 11/4/2024 14:30 11/4/2024 16:00 1.50 COMPZN, RPCOMP RGRP T Repair leak on hydraulic return line. 1,545.0 1,545.0 11/4/2024 16:00 11/4/2024 19:30 3.50 COMPZN, RPCOMP TRIP P Cont RIH F/ 1545' to 7317' PUWT: 135 SOWT: 95K 1,545.0 7,317.0 Rig: NABORS 7ES RIG RELEASE DATE 11/10/2024 Page 4/8 3O-18 Report Printed: 12/2/2024 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) 11/4/2024 19:30 11/4/2024 21:00 1.50 COMPZN, RPCOMP MILL P Kelly up to stand. Start pumps @ 63 GPM @ 100 PSI. Wash down, and tag top of fish @ 7239'. P/U engage rotary @ 10 RPM @ 4K TQ. Slack off observe 3 K bobble @ 7739', continue to slack off and tag top of fish w/ inner concave mill @ 7743' (4' Swallow). Mill top of fish to 7746' @ 210 GPM @ 880 PSI 100 RPM @ 8-8.5 K TQ. 3-5K WOB. 7,317.0 7,350.0 11/4/2024 21:00 11/4/2024 22:00 1.00 COMPZN, RPCOMP CIRC P Pump 20 BBL High vis sweep. 325 GPM @ 1800 PSI. 7,350.0 7,350.0 11/4/2024 22:00 11/4/2024 22:15 0.25 COMPZN, RPCOMP OWFF P OWFF 10 MIN: STATIC. 7,350.0 7,350.0 11/4/2024 22:15 11/5/2024 00:00 1.75 COMPZN, RPCOMP TRIP P POOH F/ 7350' to 2250' 7,350.0 2,250.0 11/5/2024 00:00 11/5/2024 01:00 1.00 COMPZN, RPCOMP TRIP P POOH F/ 2250' to surface. 2,250.0 0.0 11/5/2024 01:00 11/5/2024 01:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA # 2 (dress off BHA) 0.0 0.0 11/5/2024 01:30 11/5/2024 02:00 0.50 COMPZN, RPCOMP BHAH P M/U BHA # 3 (over shot BHA) 0.0 27.0 11/5/2024 02:00 11/5/2024 04:30 2.50 COMPZN, RPCOMP TRIP P TIH F/27' T/7314' PUW=135K SOW=95K 27.0 7,314.0 11/5/2024 04:30 11/5/2024 09:00 4.50 COMPZN, RPCOMP FISH P Kelly up to string and wash over and engage top of fish w/ over shot @ 7349' Pumping 84 GPM @ 140 PSI. Observe 120 PSI pressure increase. Continue to slack off to 7352' NO-GO out w/ 10K down. P/U 20K over. Work fish from down weight up to 50K over. Increase flow rate to 168 GPM @ 1000 PSI. Pump 40 BBL high vis sweep in an attempt to clear debris around fish. Mobilize E-line to the rig. Continue to circulate and work pipe. PUWT: 135 K SOWT: 95 K 7,314.0 7,352.0 11/5/2024 09:00 11/5/2024 09:30 0.50 COMPZN, RPCOMP CIRC P Circulate around 20 BBL high vis sweep @ 168 GPM @ 1000 PSI. 7,352.0 7,352.0 11/5/2024 09:30 11/5/2024 11:00 1.50 COMPZN, RPCOMP ELNE P Set string in slips w/ ~ 35K tension. Break out double from string. R/U AK E- line on the rig floor. 7,352.0 7,352.0 11/5/2024 11:00 11/5/2024 11:30 0.50 COMPZN, RPCOMP ELNE P AK E-line M/U drift run tool string. 7,352.0 7,352.0 11/5/2024 11:30 11/5/2024 17:30 6.00 COMPZN, RPCOMP ELNE P AK E-line RIH F/surface T/8,606' ELMD, unable to pass cut/slag POOH, LD drift. confer with town team, MU 1-11/16 RCT Cutter, TIH, tag 8,606' ELMD, log up hole to 8,100.4' ELMD RBIH, cut @ 8,605' ELMD. POOH, LD RCT Cutter. 7,352.0 7,352.0 11/5/2024 17:30 11/5/2024 17:45 0.25 COMPZN, RPCOMP FISH P Attempt to pull tubing PU=185K unable to get slips out of the table. 7,352.0 7,352.0 11/5/2024 17:45 11/5/2024 23:30 5.75 COMPZN, RPCOMP ELNE P Rebuild new RCT discussed with town engineer RU Eline W/RCT cutter RIH correlate to tubing tally F/1988. Cut tubing at 8569.8' POOH W/E-Line. RD 7,352.0 7,352.0 11/5/2024 23:30 11/5/2024 23:45 0.25 COMPZN, RPCOMP FISH P PU on fish PUW=140K 7,352.0 7,352.0 Rig: NABORS 7ES RIG RELEASE DATE 11/10/2024 Page 5/8 3O-18 Report Printed: 12/2/2024 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) 11/5/2024 23:45 11/6/2024 00:00 0.25 COMPZN, RPCOMP CIRC P Circulate BUS. 6.5 BPM 1145 PSI 7,352.0 7,352.0 11/6/2024 00:00 11/6/2024 01:30 1.50 COMPZN, RPCOMP TRIP P TOOH F/7352' T/6557' 7,352.0 6,557.0 11/6/2024 01:30 11/6/2024 02:00 0.50 COMPZN, RPCOMP SVRG P Service roughneck. 6,557.0 6,557.0 11/6/2024 02:00 11/6/2024 05:00 3.00 COMPZN, RPCOMP TRIP P Con't TOOH F/6557' T/surface 6,557.0 27.1 11/6/2024 05:00 11/6/2024 05:30 0.50 COMPZN, RPCOMP BHAH P LD BHA #3 27.1 11/6/2024 05:30 11/6/2024 08:00 2.50 COMPZN, RPCOMP PULD P LD BHA and fish 37 joints and a cut joint, Fish 1,220' and cut joint length 14.69'. Current TOF @ 8,569.8' 0.0 0.0 11/6/2024 08:00 11/6/2024 10:00 2.00 COMPZN, RPCOMP BHAH P MU Washover BHA - XO 3.5" IF x HT38 DP, 4.375" fishing jar, bumper sub, XO 3.5" IF x 5.375" washpipe 1 joint and 3 pups, and 6.125" crown burn shoe. Total length=73.4' 0.0 73.4 11/6/2024 10:00 11/6/2024 13:45 3.75 COMPZN, RPCOMP TRIP P TIH, w/BHA #4 73.4 8,560.0 11/6/2024 13:45 11/6/2024 17:30 3.75 COMPZN, RPCOMP FISH P Kelly up to DP, PUW=150k, SOW=100k, bring pump online 4 bpm/169 gpm @ 560 psi Rot Weight=125k, Free TQ=5,700 ft/lbs, RPM=80 Burn over w/1-2k WOB TOF=8,557' Trash=8,566' GLM=8,575' 8,560.0 8,606.0 11/6/2024 17:30 11/6/2024 18:45 1.25 COMPZN, RPCOMP CIRC P Set down on no-go 8,611', Circulate SXS w/25 bbl high-vis sweep 8,606.0 8,606.0 11/6/2024 18:45 11/6/2024 19:15 0.50 COMPZN, RPCOMP OWFF P Blow down top drive and surface lines. OWFF 8,606.0 8,606.0 11/6/2024 19:15 11/6/2024 22:30 3.25 COMPZN, RPCOMP TRIP P TOOH F/8606' PUW=148K, 8,606.0 73.4 11/6/2024 22:30 11/6/2024 23:30 1.00 COMPZN, RPCOMP BHAH P LD Washpipe recovered 17.89' of tubing above GLM, Merla GLM 9.89' and14.5' of tubing in wash pipe. Puts bottom of fish in at 8611'. 73.4 0.0 11/6/2024 23:30 11/7/2024 00:00 0.50 COMPZN, RPCOMP SVRG P Service top drive. 0.0 0.0 11/7/2024 00:00 11/7/2024 01:30 1.50 COMPZN, RPCOMP BHAH P Remove fish from wash pipe. 0.0 0.0 11/7/2024 01:30 11/7/2024 02:30 1.00 COMPZN, RPCOMP CLEN P Clean and clear floor 0.0 0.0 11/7/2024 02:30 11/7/2024 05:00 2.50 COMPZN, RPCOMP BHAH P PJSM for PU BHA. PU skirted pilot mill BHA W/6-1/8" string mills for dress off/clean out run. 0.0 60.1 11/7/2024 05:00 11/7/2024 08:00 3.00 COMPZN, RPCOMP TRIP P TIH w/BHA #5 60.1 8,591.0 11/7/2024 08:00 11/7/2024 12:30 4.50 COMPZN, RPCOMP REAM P Kelly up to DP, PUW=150k, SOW=105k, bring pump online 5-8 bpm/210 gpm @ 1,100 /2,500 psi Rot Weight=125k, Free TQ=4,500-5,000 ft/lbs, RPM=67 Wash down F/8,591' T/8,612', hard spot @ 8,608' Circulate 320 lsrv sweep 25 bbl, returns=Frac Sand/minimal metal. 7 - 5 gal buckets Continue to work pipe, 8,591.0 8,612.0 11/7/2024 12:30 11/7/2024 14:00 1.50 COMPZN, RPCOMP CIRC P Unable to make progress past 8,612', Circluate final sweeps until clean 8,612.0 8,579.0 Rig: NABORS 7ES RIG RELEASE DATE 11/10/2024 Page 6/8 3O-18 Report Printed: 12/2/2024 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) 11/7/2024 14:00 11/7/2024 14:30 0.50 COMPZN, RPCOMP REAM P PUH, ream/polish packer setting area F/8,579' T/8,515' PUW=150k, SOW=100k 8,579.0 8,515.0 11/7/2024 14:30 11/7/2024 18:00 3.50 COMPZN, RPCOMP TRIP P TOOH w/dress off BHA 8,515.0 60.1 11/7/2024 18:00 11/7/2024 20:30 2.50 COMPZN, RPCOMP BHAH P LD 2-7/8" skirted packer mill assembly. Metal wedged next to body of mill. Recovered bebris from inside shoe. Looks like tubing top pattern on mill face and in debris next to stinger. PU BHA #6 2-7/8" Skirted concave mill BHA. 60.1 43.8 11/7/2024 20:30 11/7/2024 23:30 3.00 COMPZN, RPCOMP TRIP P TIH F/43.77' T/8601' PUW=140K SOW=107K 43.8 8,601.0 11/7/2024 23:30 11/8/2024 00:00 0.50 COMPZN, RPCOMP SVRG P Service black jack on top drive 8,601.0 8,601.0 11/8/2024 00:00 11/8/2024 00:30 0.50 COMPZN, RPCOMP MILL P Establish milling parameters PUW=145K SOW=110K Rot 100 RPM, torque off=3.8K Rot wt=125K PR=5 BPM 840 PSI. Dry tag top at 8603' top of stump. Rotate over top of stump 2 times. Found top of stump at 8603' 7ES RKB. 8,601.0 8,603.0 11/8/2024 00:30 11/8/2024 04:15 3.75 COMPZN, RPCOMP MILL P Mill top of stump F/8603' T/8604' 2-3K WOB PR=5 BPM 850 PSI Torque on 3.7K-4.3K Mill top of stump F/8604' T/ 8605' 2-3K WOB PR=5BPM 890-900 PSI Torque on 6K Circulate SxS sweep off stump clean sweep returned. 8,603.0 8,607.6 11/8/2024 04:15 11/8/2024 04:45 0.50 COMPZN, RPCOMP RURD P Shut down rotary. Rack one stand. Blow down top drive and surface lines. 8,605.0 8,511.0 11/8/2024 04:45 11/8/2024 05:00 0.25 COMPZN, RPCOMP OWFF P OWFF for 15 minutes. No flow. 8,511.0 8,511.0 11/8/2024 05:00 11/8/2024 05:30 0.50 COMPZN, RPCOMP TRIP P TOOH 5 stands. 8,511.0 8,041.0 11/8/2024 05:30 11/8/2024 06:00 0.50 COMPZN, RPCOMP RURD P RU to test casing to 2500 PSI for 30 minutes. Bleed OA 1,400 psi to 220 psi. 8,041.0 8,041.0 11/8/2024 06:00 11/8/2024 07:30 1.50 COMPZN, RPCOMP PRTS P Pressure test casing to 2500 PSI, while monitoring OA. Good Test 8,041.0 8,041.0 11/8/2024 07:30 11/8/2024 10:15 2.75 COMPZN, RPCOMP TRIP P TOOH on stands F/8,041' T/surface 8,041.0 43.8 11/8/2024 10:15 11/8/2024 10:30 0.25 COMPZN, RPCOMP BHAH P LD and inspect concave mill Mill report - Groove on face of mill, measured 2-3/8"-2-7/8" with no depth, center wear, no marks on OD. 1' x 3" piece of J-55 tubing recovered on uphole side of stabilizer. 43.8 0.0 11/8/2024 10:30 11/8/2024 11:30 1.00 COMPZN, RPCOMP BHAH P MU gutted over shot w/5.3' swallow 0.0 7.8 11/8/2024 11:30 11/8/2024 14:00 2.50 COMPZN, RPCOMP TRIP P TIH, w/ PBOS with no grapple, BHA #7 F/Surface T/8,605' 5.3' of swallow T/8,610.3' 7.8 8,605.0 11/8/2024 14:00 11/8/2024 14:30 0.50 COMPZN, RPCOMP TRIP P Space out, LD 2 single HT38 DP, (Pickup HT38 joints 14.95' & 10.5') Slickline on location, spot in equipment 8,605.0 8,605.0 11/8/2024 14:30 11/8/2024 15:00 0.50 COMPZN, RPCOMP TRIP P Bring pump online 1.0 bpm/175 psi, 8,610.3' pressure increase T/700 psi. 8,605.0 8,605.0 Rig: NABORS 7ES RIG RELEASE DATE 11/10/2024 Page 7/8 3O-18 Report Printed: 12/2/2024 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) 11/8/2024 15:00 11/8/2024 16:00 1.00 COMPZN, RPCOMP SLKL P Prep RF for slickline 8,605.0 8,605.0 11/8/2024 16:00 11/8/2024 17:30 1.50 COMPZN, RPCOMP SLKL P RIH w/slickline,drift W/2.23" centralizer. T/8620' SLMD, 7ES RKB. 8629' ORKB. POOH W/SLick line and R/D. 8,605.0 8,605.0 11/8/2024 17:30 11/8/2024 18:30 1.00 COMPZN, RPCOMP CIRC P Circ high vis sweep SxS 6BPM at 975 PSI 8,605.0 8,605.0 11/8/2024 18:30 11/8/2024 19:00 0.50 COMPZN, RPCOMP RURD P LD 1 joint and 2 pup joints, blow down top drive. 8,605.0 8,555.0 11/8/2024 19:00 11/8/2024 20:30 1.50 COMPZN, RPCOMP SLPC P Slip and cut drilling line. 8,555.0 8,555.0 11/8/2024 20:30 11/8/2024 21:00 0.50 COMPZN, RPCOMP SVRG P Clean under draw works and grease and inspect brake linkage. 8,555.0 8,555.0 11/8/2024 21:00 11/9/2024 00:00 3.00 COMPZN, RPCOMP PULD P LD DP F/8555' PUW=140K, T/5430 PUW=100K 8,555.0 5,430.0 11/9/2024 00:00 11/9/2024 04:30 4.50 COMPZN, RPCOMP PULD P Continue to LD DP F/5430' T/7.82' 5,430.0 7.8 11/9/2024 04:30 11/9/2024 05:30 1.00 COMPZN, RPCOMP BHAH P L/D Overshot break down jars and bumper sub. 7.8 0.0 11/9/2024 05:30 11/9/2024 06:00 0.50 COMPZN, RPCOMP OTHR P RU and pull wear ring 0.0 0.0 11/9/2024 06:00 11/9/2024 07:30 1.50 COMPZN, RPCOMP PUTB P Prep RF for completion operations. Verifiy jewelry order and joint count Confirm tongs working correctly with test pup. 0.0 0.0 11/9/2024 07:30 11/9/2024 08:00 0.50 COMPZN, RPCOMP SFTY P PJSM 0.0 0.0 11/9/2024 08:00 11/9/2024 17:30 9.50 COMPZN, RPCOMP PUTB P PU 2-7/8" EUE L-80 tubing Tripping speed 90 fpm RIH F/Surface to 8595' PUW=75K SOW=60K Blocks=30K 0.0 8,595.0 11/9/2024 17:30 11/9/2024 18:30 1.00 COMPZN, RPCOMP RURD P RU to circulate. 8,595.0 8,595.0 11/9/2024 18:30 11/9/2024 19:15 0.75 COMPZN, RPCOMP HOSO P Space out PBOS RIH to tag at 8611' (7ES RKB) saw shear screws shear 10K down. Con't to fully located at 8615' (7ES RKB) 5K down PU to neutral weight at 75K (8613' 7ES RKB). PU to 8611' (7ES RKB) (8619' ORKB). marked joint at floor. PU to 8599' 8,595.0 8,611.0 11/9/2024 19:15 11/9/2024 19:30 0.25 COMPZN, RPCOMP SFTY P PJSM W/ASRC/Nabors/Baker/CPAI for circulating CI. 8,611.0 8,611.0 11/9/2024 19:30 11/9/2024 21:30 2.00 COMPZN, RPCOMP CIRC P Circulate 290 BBL's CI 3BPM=530 PSI. 8,611.0 8,611.0 11/9/2024 21:30 11/9/2024 21:45 0.25 COMPZN, RPCOMP HOSO P RIH to 8611' (7ES RKB) 8,611.0 11/9/2024 21:45 11/9/2024 23:15 1.50 COMPZN, RPCOMP PACK P RD hardline drop ball and rod. RU hardline to set packer. Allow ball and rod to fall for 30 minutes. Blow down secondary kill line. Line up to pump down tubing to set packer. Pressure up to 1925 PSI saw packer set at 1700 PSI. Shear out seal assembly PUW=90K. Bled pressure off tubing PUH 5' off locate to 8504', confirmed top of PBR 8509' 7ES RKB 2K down 2 times. 11/9/2024 23:15 11/10/2024 00:00 0.75 COMPZN, RPCOMP HOSO P Space out seal assembly 2' off tag. Top of PBR at 8509' (7ES RKB) 11/10/2024 00:00 11/10/2024 00:30 0.50 COMPZN, RPCOMP THGR P Land tubing hanger RILDS. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 11/10/2024 Page 8/8 3O-18 Report Printed: 12/2/2024 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) 11/10/2024 00:30 11/10/2024 02:30 2.00 COMPZN, RPCOMP PRTS P PT tubing T/3000 psi, 30 min, good test Dump tubing to 1,500 psi PT casing 2,500 psi, 30 min, good test Dump tubing pressure to shear SOV RD testing equipment 0.0 0.0 11/10/2024 02:30 11/10/2024 03:00 0.50 COMPZN, RPCOMP MPSP P Set BPV. Test under BPV to 1000 PSI for 10 minutes. 0.0 0.0 11/10/2024 03:00 11/10/2024 15:00 12.00 COMPZN, RPCOMP RURD P Washed stack w/Johnny whacker. Wash pipe started leaking when washing stack. Started to perform BWM C/O LPR's to 3.5" x 5.5" VBR's. Swap out annular 0.0 0.0 11/10/2024 15:00 11/10/2024 19:00 4.00 COMPZN, WHDBOP NUND P ND BOP's NU Adapter and tree. Tested void to 5000 PSI for 15 Min. Tested tree to 5000 PSI for 10 minutes. No visible leaks. 0.0 0.0 11/10/2024 19:00 11/10/2024 19:30 0.50 COMPZN, WHDBOP MPSP P Pulled HP BPV. 0.0 11/10/2024 19:30 11/10/2024 22:00 2.50 COMPZN, WHDBOP FRZP P LRS Pumped 75 BBL's Diesel down IA 2.5 BPM=1400 PSI. taking returns up the tubing to the kill tanks. U-Tube well for 1 hours Rig: NABORS 7ES RIG RELEASE DATE 11/10/2024 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 8,877.0 3O-18 8/17/2015 lehallf Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set hold open sleeve in SSSV. 3O-18 10/5/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 8/31/2009 ninam NOTE: 2.25" X 11' DRIFTED VERY TIGHT BELOW PACKER 9/8/2001 triplwj NOTE: CALIPER SHOWED TBG CORKSCREWED FROM 4000' TO PACKER @ 8644' 9/8/2001 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 33.0 110.0 110.0 62.50 H-40 Welded SURFACE 9 5/8 8.83 35.0 2,937.4 2,370.8 36.00 J-55 BTC PRODUCTION 7 6.28 33.0 9,170.9 6,806.8 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 29.6 Set Depth 8,619.0 String Max No 2.867 Set Depth 6,368.3 Tubing Description Tubing Completion Upper Wt (lb/ft) 6.50 Grade L-80 Top Connection EUE ID (in) 2.44 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) 62.6 62.5 0.15 Hanger 7.125 Cameron 7-1/16" x 2-7/8" EUE tubing hanger Camero n CXS 2.400 3,377.9 2,694.6 42.04 Mandrel GAS LIFT 5.454 2-7/8" MMG GLM SN# 079AG06 2000 PSI SOV. SLB MMG 2.366 6,314.7 4,693.4 46.65 Mandrel GAS LIFT 5.454 2-7/8" MMG GLM SN# 082AG06 DV SLB MMG 2.366 8,048.8 5,937.6 41.79 Mandrel GAS LIFT 5.454 2-7/8" MMG GLM SN# 083AG06 DV SLB MMG 2.366 8,482.5 6,263.3 40.42 Mandrel GAS LIFT 5.454 2-7/8" MMG GLM SN#129AE11 DV SLB MMG 2.366 8,530.8 6,300.2 39.94 Locator 3.450 Locator Baker 2.440 8,531.8 6,301.0 39.93 Seal Assembly 3.240 Seal assembly OAL=21.67' spaced out 2.88' off locator 18.79' buried in PBR Baker 80-32 2.440 8,534.7 6,303.2 39.89 PBR 4.260 Baker 20' PBR 80-32 Baker 80-32 3.250 8,558.2 6,321.2 39.59 Packer 6.276 Baker FH Retrievable 2-7/8" x 7" Packer Baker FH 2.441 8,589.9 6,345.7 39.18 2.313" X 3.467 2.313" HES X-Nipple Halliburt on "X" 2.313 8,610.9 6,362.0 38.94 Overshot 5.898 Poorboy overshot 3.9' to shear screws 7.06' of swallow. 2.' off tag Northern Solution s Mule shoe bottom 2.992 Top (ftKB) 8,614.0 Set Depth 8,750.0 String Max No 2 7/8 Set Depth 6,471.2 Tubing Description Tubing Completion Lower Wt (lb/ft) 6.50 Grade J-55 Top Connection EUE 8rd AB Mod ID (in) 2.44 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) 8,631.1 6,377.7 38.75 PBR 5.870 BAKER PBR Baker 2.380 8,643.5 6,387.5 38.63 PACKER 6.062 BROWN HR PACKER Brown HR 2.375 8,715.0 6,443.6 38.04 NIPPLE 3.668 CAMCO D NIPPLE Camco D 2.250 8,749.1 6,470.4 37.93 SOS 2.875 BROWN SHEAR OUT SUB Brown 2.438 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) 8,689.0 6,423.1 38.19 CATCHER Set junk catcher on HEX plug (2.21" OD, OAL 93") 9/26/2024 0.000 8,697.0 6,429.4 38.12 TUBING PLUG 180-288 HEX PLUG W/ MOE = 8700' RKB, OAL = 5.64' INTERW ELL HEX 45840 8 10/31/2023 0.000 9,033.0 6,696.3 36.76 FISH 1 1/2" GLV Empty pocket; Lost in Hole 12/10/1989 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) 3,377.9 2,694.6 42.04 4 GAS LIFT GLV RK 1 1/2 1,265.0 11/17/2024 CAMCO MMG 0.125 6,314.7 4,693.4 46.65 3 GAS LIFT GLV RK 1 1/2 1,230.0 11/19/2024 CAMCO MMG 0.125 8,048.8 5,937.6 41.79 2 GAS LIFT DV RK 1 1/2 0.0 11/10/2024 MMG CAMCO 0.000 8,482.5 6,263.3 40.42 1 GAS LIFT OV RK 1 1/2 0.0 11/19/2024 Camco MMG 0.125 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,819.0 8,841.0 6,525.7 6,543.1 C-1, UNIT B, 3O -18 4/4/1989 6.0 APERF 2 1/8" EnerJet, 0 deg. pH 8,852.0 8,890.0 6,551.8 6,582.0 UNIT B, 3O-18 4/4/1989 6.0 APERF 2 1/8" EnerJet, 0 deg. pH 8,906.0 8,934.0 6,594.8 6,617.1 A-5, A-3, 3O-18 4/4/1989 12.0 APERF 2 1/8" EnerJet, 60 deg. pH 8,944.0 8,984.0 6,625.1 6,657.1 A-2, 3O-18 4/3/1989 12.0 APERF 2 1/8" EnerJet, 60 deg. pH 8,998.0 9,018.0 6,668.3 6,684.3 A-1, 3O-18 6/11/1988 8.0 IPERF 4.5" HSD Csg Gun, 45 deg. pH 3O-18, 12/2/2024 1:21:43 PM Vertical schematic (actual) PRODUCTION; 33.0-9,170.9 IPERF; 8,998.0-9,018.0 APERF; 8,944.0-8,984.0 APERF; 8,906.0-8,934.0 APERF; 8,852.0-8,890.0 APERF; 8,819.0-8,841.0 TUBING PLUG; 8,697.0 CATCHER; 8,689.0 PACKER; 8,643.5 2.313" X; 8,589.9 Packer; 8,558.2 Seal Assembly; 8,531.8 Mandrel GAS LIFT; 8,482.5 Mandrel GAS LIFT; 8,048.8 Mandrel GAS LIFT; 6,314.7 Mandrel GAS LIFT; 3,377.8 SURFACE; 35.0-2,937.4 CONDUCTOR; 33.0-110.0 Hanger; 62.5 KUP PROD KB-Grd (ft) 34.98 RR Date 4/2/1988 Other Elev 3O-18 ... TD Act Btm (ftKB) 9,195.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292179300 Wellbore Status PROD Max Angle & MD Incl (°) 50.98 MD (ftKB) 2,000.00 WELLNAME WELLBORE3O-18 Annotation Last WO: End DateH2S (ppm) 140 Date 12/6/2014 Comment SSSV: TRDP ORIGINATED TRANSMITTAL DATE: 11/12/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5155 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5155 3O-18 50029217930000 Tubing Cut Record 5-Nov-2024 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 188-026 T39766 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.11.12 10:07:54 -09'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV UNIT 3O-18 JBR 01/10/2025 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:2 Tested with 2-7/8" & 3-1/2" Test Joints. F/P on UPR with 3-1/2" Functioned/ Passed. F/P on LPR with 2-7/8", Functioned/ Passed.. Test Results TEST DATA Rig Rep:Tony Morales/ Ralph LaOperator:ConocoPhillips Alaska, Inc.Operator Rep:Seth Burson/ Mark Adams Rig Owner/Rig No.:Nabors 7ES PTD#:1880260 DATE:11/2/2024 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopJDH241108205311 Inspector Josh Hunt Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 12 MASP: 2258 Sundry No: 324-553 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 2 P Inside BOP 1 P FSV Misc 0 NA 16 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13-5/8" T90 P #1 Rams 1 3-1/2"x5-1/2" FP #2 Rams 1 Blind P #3 Rams 1 2 7/8 x 5"FP #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8" Gate P HCR Valves 2 3 1/8" Gate P Kill Line Valves 2 3 1/8" & 2"P Check Valve 0 NA BOP Misc 2 2 1/16" Gate P System Pressure P3000 Pressure After Closure P1650 200 PSI Attained P15 Full Pressure Attained P123 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P5@2050 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P17 #1 Rams P5 #2 Rams P5 #3 Rams P5 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 99999 9 9 9 9 9 9 9 9F/P on UPR F/P on LPR FP FP ORIGINATED TRANSMITTAL DATE: 10/21/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5096 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk River PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5096 3O-18 500292179300 Tubing Cut Record 3-Oct-2024 RECIPIENTS ConocoPhillips Alaska, Inc. DIGITAL FILES PRINTS CD'S 1 0 0 0 USPS 0 0 0 0 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 188-026 T39700 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.10.21 15:12:16 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com 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: Replace Tubing 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?N/A Yes No 9. Property Designation (Lease Number): 10. Field: Kuparuk Oil Pool Kuparuk Oil Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9195'2258 9033' Casing Collapse Conductor Surface Production 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: 907-263-4529 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 8697' 9-5/8" 80' Brown HR Packer SSSV: Baker FVLD 6826' 8877' 6572' 7" 16" KRU 3O-18 8819'-8841' 8852-8890' 8906-8934' 8944-8984' 8998-9018' 8928' 6526-6543' 6552-6582' 6595'-6617' 6625-6657' 6668-6684' 5064' 9171' Perforation Depth MD (ft): 110' 10/20/2024 2-7/8" 110' 2937' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025520 188-026 P.O. Box 100360, Anchorage, AK 99510 50-029-21793-00-00 ConocoPhillips Alaska, Inc AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 8644'MD/6388'TVD 1724'MD/1567'TVD 8750' 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. Proposed Pools: 2371' Burst Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size Kuparuk River Field TVD Perforation Depth TVD (ft): MD 6807' Adam Klem adam.klem@conocophillips.com RWO/CTD Engineer Subsequent Form Required: Suspension Expiration Date: J-55 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Adam Klem DN: CN=Adam Klem, E=adam.klem@ conocophillips.com, C=US Reason: I am approving this document Location: Date: 2024.09.25 07:22:43-08'00' Foxit PDF Editor Version: 13.0.0 Adam Klem 324-553 By Grace Christianson at 9:07 am, Sep 25, 2024 X SFD 10/4/2024 10-404 Annular preventer test to 2500 psig X DSR-9/27/24 , ADL0025513 SFD BOP test to 3000 psig VTL 10/21/2024 10/28/2024 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.10.21 11:35:00 -08'00'10/21/24 RBDMS JSB 102224 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 19, 2024 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 work over Kuparuk Producer 3O-18 (PTD# 188-026). Well 3O-18 was drilled in 1988 as a Kuparuk A sand producer. It was subsequently frac’d and has had two refracs. It has never been worked over and has the original tubing, which developed multiple tubing leaks and is currently secured with a plug and shut in. To bring the well back online, we request approval to proceed with a pre rig tubing cut above the packer and then rig workover to pull and replace the tubing and stack a packer above a pre rig tubing cut stub. The 2-7/8” tubing will be pulled from a pre-rig cut above the packer, and a new 2-7/8” completion including a non-sealing overshot, gas lift mandrels, and a stacked packer will be installed. If you have any questions or require any further information, please contact me at 907-263-4529. Adam Klem Rig Workover Engineer CPAI Drilling and Wells Digitally signed by Adam Klem DN: CN=Adam Klem, E= adam.klem@conocophillips.com, C=US Reason: I am approving this document Location: Date: 2024.09.25 07:22:52-08'00' Foxit PDF Editor Version: 13.0.0 Adam Klem 3O-18 Kuparuk Producer Pull and Replace Tubing with Stacked Packer RWO PTD: 188-026 Page 1 of 2 PPre-Rig Work Remaining 1. Dummy off all GLM, leaving lowest GLV open for circulation 2. Cut tubing at ~8,615’ RKB 3. T-POT/PPPOT and IC-POT/PPPOT. 4. Function test LDS. 5. CMIT to 2500psi 6. Prepare well within 48 hrs of rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 3O-18. No BPV will be set for MIRU due to Nabors 7ES internal risk assessment. 2. Circulate seawater. Record shut-in pressures on the T & IA. Circulate KWF as needed and complete 30-minute NFT. Verify well is dead. 3. Set BPV and confirm as barrier if needed, ND tree, NU BOPE and test to 250/3,000 psi. Test annular 250/3,000 psi. Retrieve 2-7/8” Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 2-7/8” tubing down to the pre-rig cut at ~8,618’ RKB. Cleanout to Tubing Stub 6. PU DP. RIH with casing scraper and dress off mill to tubing stub and dress off stub as needed. POOH LD DP. Install 2-7/8” Completion with Stacked Packer 7. MU new 2-7/8” completion with non-sealing overshot, packer, nipple profile, and GLMs. RIH to tubing stub. 8. Once on depth, space out as needed. Circulate corrosion inhibited fluid. 9. Land tubing hanger, RILDS, drop ball/rod, and set packer. 10. Pressure test tubing to 3,000 PSI. 11. Pressure test IA to 2,500 PSI. ND BOP, NU Tree 12. Shear out SOV with pressure differential. 13. Install BPV and test. ND BOPE. NU tree. PT Tree and packoffs. 14. Pull BPV and freeze protect well. 15. RDMO. Post-Rig Work 1. Pull DVs and SOV. Install GLD. 2. Pull ball/rod used for setting packer. 3. Pull RBP and catcher. 3O-18 Kuparuk Producer Pull and Replace Tubing with Stacked Packer RWO PTD: 188-026 Page 2 of 2 GGeneral Well Information: Estimated Start Date: 10/20/2024 Current Operations: Shut-In Well Type: Producer Wellhead Type: CIW KRU Gen 4. 11” 3M casing head top flange. 7-1/16”- 5M tubing head top flange. BOP Configuration: Annular / Pipe Rams / Blind Rams / Pipe Rams Static BHP: 2,806 psi / 5,481’ TVD measured on 10/2/23 MPSP: 2,258 psi using 0.1 psi/ft gradient Scope of Work: Pull the existing 2-7/8” completion to a pre-rig cut, perform cleanout run, install a new 2-7/8” completion with a stacked packer. Personnel: Workover Engineer: Adam Klem (907-263-4529 / adam.klem@conocophillips.com) Reservoir Surveillance Engineer: Kaylie Plunkett Production Engineer: Sydney Autry Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 8,877.0 3O-18 8/17/2015 lehallf Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added leak depths found by Relay 3O-18 11/23/2023 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 8/31/2009 ninam NOTE: CALIPER SHOWED TBG CORKSCREWED FROM 4000' TO PACKER @ 8644' 9/8/2001 triplwj NOTE: 2.25" X 11' DRIFTED VERY TIGHT BELOW PACKER 9/8/2001 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 33.0 110.0 110.0 62.50 H-40 Welded SURFACE 9 5/8 8.83 35.0 2,937.4 2,370.8 36.00 J-55 BTC PRODUCTION 7 6.28 33.0 9,170.9 6,806.8 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 33.0 Set Depth … 8,750.0 String Max No… 2 7/8 Set Depth … 6,471.2 Tubing Description TUBING Wt (lb/ft) 6.50 Grade J-55 Top Connection EUE 8rd AB Mod ID (in) 2.44 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) 33.0 33.0 0.08 HANGER 5.000 CIW TUBING HANGER 2.441 1,724.2 1,566.5 44.73 SAFETY VLV 4.620 BAKER FVLD SAFETY VALVE, AS PER DESIGN, 2.31" FVLD FLAPPER CANNOT BE LOCKED OPEN. ONLY HYDRAULIC SHEAR SLEEVE CAN BE OPENED. Baker FVLD 2.310 3,128.0 2,507.8 42.66 GAS LIFT 4.750 G.L.M. McMurry FHMO 2 7/8" x 1" McMurry FHMO 2.347 5,634.3 4,229.0 48.95 GAS LIFT 4.750 G.L.M. McMurry FHMO 2 7/8" x 1" McMurry FHMO 2.347 7,225.1 5,335.4 44.37 GAS LIFT 4.750 G.L.M. McMurry FHMO 2 7/8" x 1" McMurry FHMO 2.347 8,100.4 5,976.1 41.77 GAS LIFT 4.750 G.L.M. McMurry FHMO 2 7/8" x 1" McMurry FHMO 2.347 8,589.1 6,345.1 39.19 GAS LIFT 5.460 G.L.M. MERLA TGPD 2 7/8" x 1 1/2" MERLA TGPD 2.347 8,631.1 6,377.8 38.75 PBR 5.870 BAKER PBR Baker 2.380 8,643.5 6,387.5 38.63 PACKER 6.062 BROWN HR PACKER Brown HR 2.375 8,715.1 6,443.6 38.04 NIPPLE 3.668 CAMCO D NIPPLE Camco D 2.250 8,749.1 6,470.5 37.93 SOS 2.875 BROWN SHEAR OUT SUB Brown 2.438 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) 3,630.0 2,880.1 43.33 LEAK - TUBING Suspect tubing leak. Bracketed with D&D holefinder between 3630' - 3730'. Need LDL to pinpoint leak. 10/14/2023 0.000 5,634.0 4,228.8 48.95 LEAK - TUBING Relay LDL identified leak @ 5634' RKB 11/19/2023 0.000 7,352.0 5,426.1 44.44 TIGHT SPOT Tubing tight spot encountered. Attempted to broach and had to beat both up and down through the tight spot. Had metal sliver, suspect tubing impingement not scale. Encountered @ 7322' SLM, 30 CF to 7352' RKB 10/14/2023 1.970 7,355.0 5,428.2 44.44 LEAK - TUBING Relay LDL identified leak @ 7355' RKB 11/19/2023 0.000 8,697.0 6,429.4 38.12 TUBING PLUG 180-288 HEX PLUG W/ MOE = 8700' RKB, OAL = 5.64' INTERW ELL HEX 45840 8 10/31/2023 0.000 9,033.0 6,696.3 36.76 FISH 1 1/2" GLV Empty pocket; Lost in Hole 12/10/1989 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) 3,128.0 2,507.8 42.66 1 GAS LIFT GLV BK 1 1,310.0 8/22/2009 0.125 5,634.3 4,229.0 48.95 2 GAS LIFT GLV BK 1 1,378.0 6/12/2013 0.188 7,225.1 5,335.4 44.37 3 GAS LIFT OV BK 1 0.0 6/12/2013 0.188 8,100.4 5,976.1 41.77 4 GAS LIFT DMY BK 1 0.0 6/5/2000 0.000 8,589.1 6,345.1 39.19 5 GAS LIFT DMY RK 1 1/2 0.0 6/5/2000 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,819.0 8,841.0 6,525.7 6,543.1 C-1, UNIT B, 3O -18 4/4/1989 6.0 APERF 2 1/8" EnerJet, 0 deg. pH 8,852.0 8,890.0 6,551.8 6,582.0 UNIT B, 3O-18 4/4/1989 6.0 APERF 2 1/8" EnerJet, 0 deg. pH 8,906.0 8,934.0 6,594.8 6,617.1 A-5, A-3, 3O-18 4/4/1989 12.0 APERF 2 1/8" EnerJet, 60 deg. pH 8,944.0 8,984.0 6,625.1 6,657.1 A-2, 3O-18 4/3/1989 12.0 APERF 2 1/8" EnerJet, 60 deg. pH 3O-18, 9/24/2024 9:54:00 AM Vertical schematic (actual) PRODUCTION; 33.0-9,170.9 IPERF; 8,998.0-9,018.0 APERF; 8,944.0-8,984.0 APERF; 8,906.0-8,934.0 APERF; 8,852.0-8,890.0 APERF; 8,819.0-8,841.0 TUBING PLUG; 8,697.0 PACKER; 8,643.5 GAS LIFT; 8,589.1 GAS LIFT; 8,100.4 LEAK - TUBING; 7,355.0 TIGHT SPOT; 7,352.0 GAS LIFT; 7,225.1 GAS LIFT; 5,634.3 LEAK - TUBING; 5,634.0 LEAK - TUBING; 3,630.0 GAS LIFT; 3,128.0 SURFACE; 35.0-2,937.4 SAFETY VLV; 1,724.2 CONDUCTOR; 33.0-110.0 KUP PROD KB-Grd (ft) 34.98 RR Date 4/2/1988 Other Elev… 3O-18 ... TD Act Btm (ftKB) 9,195.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292179300 Wellbore Status PROD Max Angle & MD Incl (°) 50.98 MD (ftKB) 2,000.00 WELLNAME WELLBORE3O-18 Annotation Last WO: End DateH2S (ppm) 140 Date 12/6/2014 Comment SSSV: TRDP Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,998.0 9,018.0 6,668.3 6,684.3 A-1, 3O-18 6/11/1988 8.0 IPERF 4.5" HSD Csg Gun, 45 deg. pH 3O-18, 9/24/2024 9:54:00 AM Vertical schematic (actual) PRODUCTION; 33.0-9,170.9 IPERF; 8,998.0-9,018.0 APERF; 8,944.0-8,984.0 APERF; 8,906.0-8,934.0 APERF; 8,852.0-8,890.0 APERF; 8,819.0-8,841.0 TUBING PLUG; 8,697.0 PACKER; 8,643.5 GAS LIFT; 8,589.1 GAS LIFT; 8,100.4 LEAK - TUBING; 7,355.0 TIGHT SPOT; 7,352.0 GAS LIFT; 7,225.1 GAS LIFT; 5,634.3 LEAK - TUBING; 5,634.0 LEAK - TUBING; 3,630.0 GAS LIFT; 3,128.0 SURFACE; 35.0-2,937.4 SAFETY VLV; 1,724.2 CONDUCTOR; 33.0-110.0 KUP PROD 3O-18 ... WELLNAME WELLBORE3O-18 3O-18 Proposed RWO Completion PROPOSED COMPLETION 2-7/8" 6.5 # L-80 EUE-M 8rd Tubing to surface 2-7/8" Camco MMG gas lift mandrels @ TBD 2-7/8"" by 7" Packer @ ~8,500' RKB 2-7/8" X landing nipple (2.313" min ID) 2-7/8"" Non-sealing Overshot @ ~8,600' RKB REMAINING COMPLETION LEFT IN HOLE Brown HB Retreivable Packer @ 8,644' RKB Camco D nipple @ 8,715' RKB (2.25" ID) SOS @ 8,749' RKB 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:Loepp, Victoria T (OGC) To:Klem, Adam Subject:KRU 3O-18 10-403 Date:Monday, October 21, 2024 10:22:00 AM Yes, approved. Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Wednesday, October 9, 2024 1:56 PM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]KRU 3O-18 10-403 Victoria, I was informed this is an outdated wellhead, that we will have to do a c-bowl conversion to. So, after our dress off run step #6 we will add steps to set a shallow plug and then ND BOP and then perform the c-bowl conversion. We will then nipple back up the BOP, test and continue with step 7. Let me know if this is acceptable. Thanks, Adam Klem From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Thursday, October 3, 2024 7:56 AM To: Klem, Adam <Adam.Klem@conocophillips.com> Subject: [EXTERNAL]KRU 3O-18 10-403 CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Adam, What is the TOC outside the 7” production casing? Will the stacked packer be placed below that TOC? Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 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:Klem, Adam To:Loepp, Victoria T (OGC) Subject:RE: [EXTERNAL]KRU 3O-18 10-403 Date:Thursday, October 3, 2024 8:15:32 AM EST TOC based on the CBL is ~7,220’ MD. Planned packer depth is ~8,500’ so it will be below TOC. From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Thursday, October 3, 2024 7:56 AM To: Klem, Adam <Adam.Klem@conocophillips.com> Subject: [EXTERNAL]KRU 3O-18 10-403 CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Adam, What is the TOC outside the 7” production casing? Will the stacked packer be placed below that TOC? Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 Originated: Delivered to:29ͲNovͲ23 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & PerforatingAttn.:Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska99501 Anchorage, Alaska 99518 Office: 907Ͳ275Ͳ2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concernstotheattention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # 13KͲ26 50Ͳ029Ͳ22764Ͳ00 n/a Kuparuk River Patch Setting Record FieldͲFinal 16ͲJulͲ23 0 1 23KͲ27 50Ͳ029Ͳ22751Ͳ00 n/a Kuparuk River Leak Detect Log FieldͲFinal 15ͲOctͲ23 0 1 33OͲ18 50Ͳ029Ͳ21793Ͳ00 n/a Kuparuk River Leak Detect Log FieldͲFinal 19ͲNovͲ23 0 1 4WSWͲ06 50Ͳ029Ͳ20851Ͳ00 n/a Kuparuk River Packer Setting Record FieldͲFinal 13ͲOctͲ23 0 1 5 6 7 8 9 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 1. 3K-36 PTD: 197-077 T38175 2. 3K-27 PTD: 197-046 T38176 3. 3O-18 PTD: 188-026 T38177 4. WSW-06 PTD:182-177 T38178 12/1/2023 33OͲ18 50Ͳ029Ͳ21793Ͳ00 n/a Kuparuk River Leak Detect Log FieldͲ Final 19ͲNovͲ23 0 1 Kayla Junke Digitally signed by Kayla Junke Date: 2023.12.01 12:13:24 -09'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2023-10-31_21171_KRU_3O-18_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21171 KRU 3O-18 50-029-21793-00 Caliper Survey w/ Log Data 31-Oct-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 188-026 T38119 11/2/2023 Kayla Junke Digitally signed by Kayla Junke Date: 2023.11.02 14:46:18 -08'00' Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. /¢~'~_ - .~.~~ Well History File Identifier Organization {done) --~Two-Sided RESCAN DIGITAL DATA olor items: [] Diskettes, No. [] Grayscale items: [] Other, No/Type [] Poor Quality Originals: [] Other: ORGANIZED ' BREN VINCENT SHERYL MARIA LOWELL DATE: OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other ~si Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ Scanned {done) PAGES: SCANNED BY: (at the time of scanning) BEVERLY BREN VINC~~ARIA LOWELL RESCANNED BY: BEVERLY BR~~HERYL MARIA LOWELL DATE: General Notes or Comments about this file: PAGES' Quality Checked (done) ~f~ COI'IOCOP~'11~ ~1 pS Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 30, 2008 ~~.A~~~d~~ AUu ~ ~s 200$ C] ~ $g_ oaf Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped July 27, 2008. The corrosion inhibitor/sealant was pumped July 3 and July 30, 2008. 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 Perry Klein at 907-659-7043, if you have any questions. Sincerely, (~ ~~ ..~ M.J. Loveland ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/30/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1Y-06A 197-134 6" NA 6" NA 1 7/3/2008 1 Y-08 183-062 6" NA 6" NA 1 7/3/2008 1Y-18 193-106 15" NA 15" NA 1.7 7/3/2008 1 Y-19 193-107 25" NA 25" NA 4.25 7/3/2008 1 Y-23 193-071 14" NA 14" NA 1.7 7/3/2008 1 Y-25 188-089 12" NA 12" NA 2.5 7/3/2008 30-01 188-073 SF NA 16" NA 3.5 7/30/2008 30-OZA 207-158 SF NA 15" NA 3.1 7/30/2008 30-03 188-075 SF NA 16" NA 3.2 7/30/2008 30-06 188-060 18' 4.90 18" 7/27/2008 5.25 7/30/2008 30-08 188-064 9' 4" 9.50 36" 7/27/2008 25 7/30/2008 30-10 188-059 15' 3.00 16" 7/27/2008 6.3 7/30/2008 30-11 188-042 53' 5.90 46" 7/27/2008 12 7/30/2008 30-13 188-040 SF NA 12" NA 2 7/30/2008 30-15 188-031 32' 5.80 23" 7/27/2008 5.3 7/30/2008 30-18 188-026 39' 5.30 18" 7/27/2008 10 7/30/2008 MEMORANDUM TO' Julie Heusser, Commissioner THRU- State of Alaska Alaska Oil and Gas Conservation Commission Tom Maunder, P. !. Supervisor DATE: FROM: Chuck Scheve; SUBJECT: Petroleum Inspector January 26, 2001 Safety Valve Tests Kuparuk River Unit 30 Pad Friday, Jan.gary .26, 2001' I traveled to the Kuparuk River Field and witnessed the 90-day retest of the safety valve systems on 30 Pad. As the attached AOGCC Safety Valve System Test Report indicates i witnessed the testing of 12 wells and 24 components with one failure observed. The Low pressure pilot on WAG injector 30-05 tripped below the required set point. This pilot was retested and passed at the the time of this test. Earnie Barndt conducted the testing today he demonstrated good test procedure and was a pleasure to work with All the wellhouses entered at this location were clean and all related equipment appeared to be in good condition. Summary:, I witnessed the 90-day SVS testing at 30 Pad in the Kuparuk River Field. KRU 30 Pad, t2 wells, 24 components, 1 failure 4.1% failure rate 12 wellhouse inspections Attachment: SVS KRU 30 Pad 1-26-01 CS X Unclassified Confidential (Unclassified if doc. Removed) SVS KRU 30 .Pad 1-26-01 CS.doc AlaSka Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Operator Rep: Eamie Barndt AOGCC Rep: C, huck,,.Scheve Submitted By: Chuck Scheve Field/Unit/Pad: Kupamk / KRU / 30 ., Separator psi: LPS _ 67 ...... Date: 1/26/01 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number ,, P,SI ,. PSI Trip ' Code Code Code Passed GAS or CYCL~ 30-01 1880730 67 70 80! ' P '~ ..... OIL 30-02 1880740 67 70 60 P P OIL 30-03~ " 1880756 ' 67 70 '60! P P ' '' OIL 30'04 1880620 67 70 ' 65' L p 'P ' ' 'OiL 30-06 lg80600' .............. 30-08, ' 1886640! 67 " 70 ..' ' 70,. P' 'P .... . . ..' I~ILi 30-09 1880610: 67 70 40 P P OIL 30-11" 1880420' '" ' 6~ 70 ' 60" ' P' ~'P .......... OIL 30-13 1880400 67 70 60 P P OIL 30-14 1880390 ' 30-15 1880310 671 70 70 i~ P OIL 30-18 18.80260 6;/i '70 55 "'i~ V' OIL , , ~ 30-20 1970450 67 70 60 P P OIL 30'05 " ' 18807i~i) ~750!' "2000 1100 3 P ....... 1/2{}/01 WAG · Wells: 12 Components: 24 Failures: 1 Failure Rate: 4.17% Elg0 Bay Remarks: Pilot on WAG injector 30-05 tripped below required set pressure. Pilot was retested .,~,..d pass~..,, this date. RJF 1/16/01 Page 1 ofl SVS KRU 30 Pad 1-26-01 CS.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate X Plugging _ Perforate _ Pull tubing Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X. 58' RKE 3. Address: Exploratory ___, 7. Unit or Property: P.O. Box 100360 Stratagrapic__ Anchorage, AK 99510-0360 Service __ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 1149' FNL, 2085' FWL, Sec 22, T13N, RgE, UM 30-18 At top of productive interval: 9. Permit number/approval number: 1605' FNL, 1100' FEL, Sec 27, T13N, RgE, UM 88-26 At effective depth: 10. APl number: 1236' FNL, 1026' FEL, Sec 27, T13N, RgE, UM 50-029-21793-00 At total depth: 11. Field/Pool: 1294' FSL, 1000' FEL, Sec 27, T13N, RgE, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 9195 feet Plugs (measured) None true vertical 6826 feet Effective Deptt measured 9088 feet Junk (measured) None true vertical 6740 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 175 Sx AS I 110° 110' Surface 2902' 9-5/8" 900 Sx AS III & 2937' 2370' 300 Sx AS II Production 9138' 7" 965 Sx Class G 9171' 6807' Liner Perforation Depth ORIGINAL measured 881 g'-8841 ';8852'-88gO';8gO6'-SgS4';Sg44'-Sg84';SggS'-9018' tFue verfical 6526'-6543';6552'-6582';6595'-6617';6625'-6657';6668'-6684' . · Tubing (size, grade, and measured depth) 2.875", 6.5 lb/fi, J-55 @ 8750' Packers and SSSV (type and measured depth) Packer: Brown HR @ 8644'; SSSV: Baker FVLD @ 1724' ..- '. ~.~ ;~ ,~ ,. 13. Stimulation or cement squeeze summary Fracture stimulate "A" sand on 6/5/98. Intervals treated (measured) 8819'-8841' Treatment description including volumes used and final pressure Pumped 250,200 lbs of 16/20 & 12/18 ceramic proppant into formation, fp was 6890 psi. 14. Representitive Daily Average Production or Injection Data Oii-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 681 950 318 1303 199 Subsequent to operation 889 1153 524 1314 191 15. Attachments MIT form 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations ~X Oil _X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Form 10-404 ReI t 18 SUBMIT IN DUPLICA ~'T~ ' , ~-KUPARUK RIVER UNIT ,RCO Alaska, Inc. .~ ~,~ .-'LL SERVICE REPORT ~ 30-18(4-1)) WELL JOB SCOPE JOB NUMBER 30-18 FRAC, FRAC SUPPORT 0529982044.19 UNIT NUMBER DATE O6/O5/98 DAY 4 FIELD ESTIMATE DALLY WORK A SAND REFRAC OPERATION COMPLETE ISUCCESSFUL IKEYPERSON ~ Yes O No ('~ Yes O No DS-YOKUM AFC# ICC# I DAILY COST ACCUM COST KD2369 230DS36OL $146,060 $159,794 InitialTbg IFinalTbg IlnitiallA IFinallA IlnitialOA IFinalOA ITTLSize 340PSII 500PSII 630 PSI 500 PSI 250PSI 250PSII 0.000 " SUPERVISOR JORDAN Signed Min ID ] Depth 0.000" 0 FT DAILY SUMMARY ~PUMPEDA~ANDREFRACT~RETREATMENT~2BBL~NDERFLU~HTUB~NGANDLEFT4~BBLD~E~ELCAP~PLACED25~~2~~ I LB PROP IN FORMATION AND LEFT 799 LB PROP IN TUBING. MAX TREATING PRESS 6890 PSI. [Frac-Refrac] TIME LOG ENTRY 06:00 MIRU DS FRAC UNIT - YOAKUM; LRS; APC. TGSM, 14 ON LOCATION. SB FOR VALVE SERVICE. SB FOR TREE SAVER. 11:00 SET TREE SAVER. PT TO 10,600 PSI OK. 11:37 PUMP BREAKDOWN / CONDITION / SCOUR STAGES. ISIP 1428 PSI. 13:05 PUMP BREAKDOWN / CONDITION / SCOUR STAGE. ISIP 1465 PSI. 13:56 PUMP DATA FRAC AND SD. ISIP 1501 PSI. ADJUST PAD. 15:00 PUMP FRAC ACCORDING TO SCHEDULE RAMPING PROPPANT FROM 2 PPA TO 10 PPA WITH 50# GEL. REDUC GEL TO 40# AND STAY FLAT AT 10 PPA. 16:55 BEGIN 2 BBL UNDER FLUSH AT 250,631 LBS PROP PUMPED. 10 BBL NON XL GEL WATER WITH 40 BBL DIESEL CAP. 16:58 SHUTDOWN. 250,200 LBS PROPPANT PLACED IN FORMATION. 799 LBS PROP LEFT IN PIPE. MAX TREATING PRESSURE 6890 PSI. RDMO DS FRAC UNIT. NOTIFIED OPERATOR OF WELL STATUS. SERVICE COMPANY - SERVICE DALLY COST ACCUM TOTAL $0.00 $906.00 APC $5,000.00 $5,000.00 DOWELL $138,060.00 $138,060.00 GAS LIFT VALVES $0.00 $0.00 HALLIBURTON $0.00 $8,610.00 LITTLE RED $3,000.00 $7,218.00 TOTAL FIELD ESTIMATE $146,060.00 $159,794.00 · .--. STATE OFALASKA ~_~ .i; ~..' AJ "~ OILAND GAS CONSERVATION ~t ~ION REPOHr OF SUNDRY WELL OPEHATIONS 1. Operations Performed: Operation Shutdown __ Pull tubing Alter casing Stimulate ~ Plugging Perforate _ Repair well Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development * Exploratory ._ Stratigraphic _ Service _ 4. Location of well at surface 1149' FNL, 2085' FWL, Sec. 22, T13N, R9E, UM At top of productive interval 1605' FNL, 1100' FEL, Sec. 27, T13N, At effective depth 1236' FNL, 1026' FEL, Sec. 27, T13N, At total depth 1294' FSL, 1000' FEL, Sec. 27, T13N, 12. Present well condition summary Total Depth: R9E, UM R9E, UM R9E, UM measured 91 95' feet true vertical 6826' feet Plugs (measured) 6. Datum elevation (DF or KB) 58' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 30-18 9. Permit number/approval number 88-26 10. APl number 50-029-21793 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 9 0 8 8' feet Junk (measured) true vertical 6740' feet Casing Length Size Cemented Measured depth True vertical depth Conductor 8 0' 1 6" 175 Sx AS I 1 1 0' I 1 0' Surface 2902' 9 5/8" 900 Sx AS III & 2937' 2370' 300 Sx AS II Production 91 3 8' 7" 965 Sx Class G 91 71' 6 8 0 7' Perforation depth: measured 8818'-8840°, 8852'-8890', 8906°-8934', true vertical 6524'-6543', 6651°-6582', 6594'-6617', Tubing (size, grade, and measured depth) 2-7/8" 6.5# J-55, EUE 8 RD, ABMOD, Tail @ 8750' Packers and SSSV (type and measured depth) SSSV: Baker FVLD @ 1724'~ Packer: Brown HB ~ 8644' 13. Stimulation or cement squeeze summary 14. 8944'-8984' & 8998'-9018' 6625'-6657' & 6668'-6684' ! ECEIVED Intervals treated (measured) Alask8 0il & Gas Cons. c0mm~sS~og Perforated interval.. Anchorage Treatment description including volumes used and final pressure Refractured A Sand w/193.0 M LBS proppant & 1005 BBL gelled sea water. Final pressure 7500 psi. RePresentative Daily Averaoe Production or Injection Data -- OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 928 364 - 0 - 1220 138 2465 / 941 19 1020 151 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys. run~ Water Injector .__ Daily Report of Well Operations X Oil ~. Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Si,ned C.(,~. ~ Form 10-404 Rev 09/1 Title Petroleum Engineer Date ~/~---'~ / (~ ~-'~ SUBMIT IN DUPLICATE · ARCO Alaska, Subsicflary of Atlantic Richfield Company WELL CONTRACTOR/ , ,--MARKS JFIELD - DISTRICT- STATE OPERATION AT REPORT TIME .~. WELL SERVICE REPORT IDAYS I DATE 12_35" / .,lz ,, 1992 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather l Temp' 1 Chill Fact°r lVlslbillty IWlnd Vel'Re.ri OF OF mile. Anchorage 'REMARKS CONTINUED: CAMCO OTIS SCHLUMBERGER DRESSER.ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMA6TER B, J. HUGHES Roustabouts Diesel Methanol Supervision Pre-Job Safety Meeting TOTAL FIELD ESTIMATE DESCRIPTION I NJ,,, 3.;-? ACCUM. TOTAL /.3 Z ~r? ISigned/~. / STATE OF ALASKA I ,SKA OIL AND GAS CONSERVATION COMMISSIO~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL ~-~ GAS ~ SUSPENDED [---} ABANDONED r~ SERVICE r'-'] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 88-26 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-21793 4 Location of well at surface .... , ....... ..~. ~.~. 9 Unit or Lease Name ,~ -"~-'~ .... -' ,.. KUPARUK RIVER UNIT At Top Producing Interval i .......... ! 10 WellNumber 1605' FNL, 1100' FEL, SEC 27, T13N, ROE UM~ ~/i:~ ~:i~ ~'~ 30-18 At Total Depth ';~ ~. ......... I j~' ~ !11 Field and Pool 1294' FSL, 1000' FEL, SEC 27, T13N, R9E UM KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) ] 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 58'I ADL: 25520 12 Date SpuddedMARCH 24 1988 13 Date T.D. ReachedMARCH 31 1988 14 -L~Date Comp., SuMp. or Aband. J 15 Water Depth, if offshOreNA feet MSL!16 No. of Completionsl 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set I 21 Thickness of permafrost 9195' MD & 6826' TVD 9088' MD & 6740' TVD YES ~-~ NO~b_~I 1724, feet MD 1 700' (approximate) 22 Type Electric or Other Logs Run DIL,SFUGR,CAL,SP,FDC,CNL, CBL,GYRO 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 110' 24" 175 SX AS III 9 5/8" 36# J-55 SURF 2937' 12-1/4" 900 SX AS III & 300 SX CLASS G 7" 26# J-55 SURF 9171' 8-1/2" 965 SX CLASS G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8998'-9018' MD, 4-1/2" W/8 SPF 6668' - 6684' TVD 2-7/8", J-55 8750' 8644' 6625' - 6657' TVD 8906' - 8934' MD, 2-1/8" W/12 SPF 6594' - 6617' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 8852' - 8890' MD, 2-1/8" W/6 SPF 6651' - 6582' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8819'- 8841' MD, 2-1/8" W/6 SPF 6525' - 6543' TVD 8998'- 9018' 62,092 lbs 16/20 CARBOLITE 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas liE, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD ,,~ FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEDi.,(X~IC MARKER FORMATION TESTS N,NVlE Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. 'FOP KUPARUK C 877g' 6494' NA BOTTOM KUPARUK C 8821' 6527' TOP KUPARUK A 8902' 6591' BOTTOM KUPARUK A 9051' 6710' 31. LIST OF'ATTACHMENTS 32. I hereby certify that 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 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 separatelyproduced, 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- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL 30-18 12/2/88 Frac Kuparuk "A" sand perfs 8998'-9018' in seven stages as follows. Stage 1: Pmp 150 bbls Gel Diesel @ 11-20 bpm 6600-5100 psi Stage 2: Prop 625 bbls Gel Diesel pad @ 20 bpm 5077-4700 psi Stage 3:45 bbls Gel Diesel w/2 ppg 16/20 Carbolite. @ 20 bbm 4747-4875 psi Stage 4:75 bbls Gel Diesel w/4 ppg 16/20 Carbolite @ 20 bpm 5071-5180 psi Stage 5:95 bbls Gel Diesel w/6 ppg 16/20 Carbolite @ 20 bpm 5650-6084 psi Stage 6 100 bbls Gel Diesel w/8 ppg 16/20 Carbolite @ 19.5-18+17.5 bpm 5900-6100-6000 psi Stage 7 54 bbls Gel Diesel w/10 ppg 16/20 Carbolite @ 17.3-6.3 bpm 6188-7200 psi Screen out at 7200 psi with tbg lei~ full of 10 ppg slurry. Breakdown and pad contained 40 pptg Silica flour. Fluid to recover: ll00bbls Sand in zone: 62092 lbs Sand in csg: 15626 lbs Avg pressure: 5800 psi D~~ervisor .... Date ARCO Alaska, Inc. Date: May 12, 1989 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #: 7470 Transmitted herewith are the following items. one signed copy of this transmittal. 30-18 . '~3A-03 ~'3A-08 ~"'3 O- 11 ~"30-13 '"'"3 O- 17 B-14 D 08 '~'3A-08 '~ 30-12 30 18 2B 14 ~1 R-02 '~', 3F-16 ~ 3F-16 ~1 R-02 ~1Y-06 '~' 2T-07 ~1 E-25 Please acknowledge receipt and return Sub-Surface Pressure Survey 2- 1 5- 8 9 Kuparuk Fluid Level Report 4 - 2 3 - 8 9 Kuparuk Fluid Level Report 4 - 2 3 - 8 9 Kuparuk Fluid Level Report 4 - 2 2 - 8 9 Kuparuk Fluid Level Report 4 - 2 2 - 8 9 Kuparuk Fluid Level Report 4 - 2 2 - 8 9 Kuparuk Fluid Level Report 4 - 2 4 - 8 9 Kuparuk Fluid Level Report 4 - 2 4 - 8 9 Kuparuk Fluid Level Report 4 - 2 4 - 8 9 Kuparuk Fluid Level Report 4 - 2 4 - 8 9 Kuparuk Fluid Level Report 4- 2 9 - 8 9 Kuparuk Fluid Level Report 4 - 2 9 - 8 9 Kuparuk Fluid Level Report 4- 2 9 - 8 9 Kuparuk Fluid Level Report 4 - 3 0 - 8 9 Kuparuk Fluid Level Report 4 - 2 9 - 8 9 Kuparuk Fluid Level Report 5-03-89 Kuparuk Fluid Level Report 5 - 0 4 - 8 9 Kuparuk Fluid Level Report 5 - 0 3 - 8 9 Kuparuk Fluid Level Report 5 - 0 8 - 8 9 Kuparuk Fluid Level Report 5 - 0 7 - 8 9 Kuparuk Well Presure Report 1 I - 0 7- 8 8 #64613 Casing Casing Casing CasIng Casing Casing Casing Casing CasIng Casing Casing Casing Casing Casing Tubing Tubing Casing Casing Casing Amerada Receipt Acknowledged: ........................... Date: ............ DISTRIBUTION: D&M ~ SAPC Chevron Mobil Unocal ARCO Alaska, Inc. Date: April 24, 1989 Transmittal #: 7462 RETURN TO: ARCO Alaska, Inc. Attn' Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 30-18 Sub-Surface Pressure Survey 2-1 1 -89 #64613 30-08 Bottom Hole Pressure Surveyq 2-26-89 #962636 30-05 Sub-Surface Pressure Survey 2-1 6-89 #29855 30-14 Sub-Surfece Pressure Survey 1-23-89 #72655 30-18 Kuparuk Well Pressure Report 2 - 1 1 - 8 9 Sand 'A° 30-14 Kuparuk Well Pressure Report 1-23-89 Sand'A' 3 O- 08 Kuparuk Well Pressure Report 2 - 2 3 - 8 9 Sand 'A' 30-17 Kuparuk Well Pressure Report 3-04-89 Sand'A' Receipt Acknowledged: DISTRIBt. JTIQN' D&M State of Alaska SAPC Mobil Chevron Unocal ARCO Alaska,. Inc. Date: March 24, 1989 Transmittal #: 7447 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. Please acknowledge receipt and return "-"'- 30-16 -i. 30-10 -'-' 30-13 ...~30-03 ,.-- 30-15 ,.-.... 2G- 14 '~- 2G-13 '~ 2G-09 ~1E-03 ~ I E-05 30-18 """" 3 H- 1 0 ~3A-03 "~"'3 H-04 ~2B-1 4 "~'-., 3 O- 13 · I..,30.10 "~"'- 30-16 ~1B-07 ~1B-03 ~1B-05 '"'"'""~1 B-07 ~1B-07 ~,i,~1 L- 04 '""3 H- 10 ~3M-01 Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Well Pressure Report Well Pressure Report Well Pressure Report Well Pressure Report Well Pressure Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Kuparuk Fluid Level Report Sub-Surface Pressure Survey Sub-Surface Pressure Survey Sub-Surface Pressure Survey Kuparuk Fluid Level Report Kuparuk Ku 2aruk Ku 2aruk Ku ~aruk Ku2aruk Ku3aruk Ku2aruk Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report 1 o 3 - 1 89 Sand 'A' 2 - 04 - 89 Sand 'A' 2 o 08 - 89 Sand 'A' Sand 'A' 1 -09-89 3-04-89 3-11-89 3-11-89 3-11o89 3-09-89 3-09-89 3-09-89 3-09-89 3-09-89 3-04-89 3-13-89 "2-08-89 2-04-89 1 -31 -89 3-31 -88 I -27-88 1 -27-88 4-27-88 I -27-88 2-12-88 2-12-88 Fluid Level Report 3-17-89 Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing #72665 #72655 #72655 Casing Tubing Tubing Tubing Tubing Tubing Tubing . .C._asj.n g - Ku3aruk Fluid Level Report 3- ~'",,a30-09 Kuparuk Fluid Level Report 3-1 8-89 Casing ~""~30-18 Kuparuk Fluid Level Report 3 - 1 8 - 89 Casing ~ O- 18 Kuparuk Fluid Level Report 3 - 1 7- 89 Casing '~~OB-09 Kuparuk Fluid Level Report 3-1 7-89 Casing - 13 Kuparuk Fluid Level Report 3 - 1 7- 89 Casing Receipt Acknowledged' - .......................... Date' - ........... DISTRIBUTION: D&M State of Alaska SAPC Chevron Unocal Mobil ~ Ar~ct~orsge STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMN,,,.,$1ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging ~ Perforate [] Pull tubing Alter Casing ~ Other [~ WORKOVER 2. Name of Operator 5. Datum elevation (DF or KB) ARCO A]aska, I nc. RKB 58' Feet 3. Address 6. Unit or Property name P.O. Box 100360, Anchorage, AK 99510-0360 Kuparuk River Unit 7. Well number 30-18 4. Location of well at surface 1149' FNL, 2085' FWL, Sec.22, T13N, RgE, UM At top of productive interval 1065' FNL, 1100' FEL, Sec.27, T13N, RgE, UM At effective depth 1236' FNL, 1026' FEL, Sec.27, T13N, R9E, UM At total depth 1294' FNL, 1000' FEL, Sec.27, T13N, RgE, UM 8. Approval number 8-556 9. APl number 50-- 029-2179:3 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical 9195 ' MD 6826' TVD Effective depth: measured 9088'MD true vertical 6740'TVD Length Size 80 ' 16" 2902 ' 9-5/8" 9138' 7" Casing Conductor Surface Production feet feet feet feet Plugs (measured) None Junk (measured) None Cemented Measured depth True Vertical depth 175 sx AS I 110'MD ll0'TVD 900 sx AS Ill & 2937'MD 2370'TVD 300 sx AS II 965 sx Class G 9171 'MD 6807'TVD Perforation depth: measured 8998'-9018'MD true vertical 6668'-6684'TVD 12. Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail ~ 8750' Packers and SSSV (type and measured depth) Brown 'HB' pkr ~ 8644', Baker FVLD SSSV ~ 1724' Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED Alaska 0il & 6~s Cons. Commissio~ Anchorage 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Workover Wel 1 History & Addendum, dated 6/29/88) Daily Report of Well Operations Ex Copies of Logs and Surveys Run ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~.,~Z. -/_/S.--..~z~'.~''~ Form 10-404 Rev. 12-1-85 Title Associate Engineer Date ~',,~/-~ (Dani) SW03/007 Submit in Duplicate ADDENDUM WELL: 5/09/88 6/22/88 30-18 RU Schl. Rn CET f/7500'-2700'. RD Schl. Rn temp & spinner log f/8775' - 8100'. Log indicated fluid moving f/tbg to ann @ 8678' & indicated 13' separation between seal assy & PBR. RD Otis. · ing Su-~ervlsor ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO Alaska, Inc. KUPARUK RIVER UNIT ICounty, parish or borough NORTH SLOPE BOROUGH Lease or Unit ADL: 25520 Title WORKOVER Field Auth. or W,O, no. AK3102 JState 30-18 jWell no. Operator ARCO API: 50-029-21793 I ARCO w.I. I 56.0000 IPrior status if a w,o. JHour 1930 HRS Spudded or W.O. begun ACCEPT I Date 06/27/88 Date and depth as of 8:00 a.m. 06/28/88 TD: 9195 PB: 9088 SUPV:DL/KR 06/29/88 ( 1. TD: 9195 PB: 9088 SUPV:DL/KR Complete record for each day reported NORDIC 1 POH W/2-7/8" TUBING 7"@ 9171' MW:10.0 NACL/NABR MOVED RIG FROM 30-10 TO 30-18. ACCEPTED RIG @ 1930 HRS, 6/27/88. PULLED BPV. SITP & SICP = 600 PSI. CIRCULATE WELL WITH 10.0 PPG BRINE. MONITORED WELL; NO LOSS. SET BPV. ND TREE. NU BOPE & TESTED TO 3000 PSI. POOH WITH 2-7/8" TUBING. DAILY:S28,337 CUM:$1,391,979 ETD:S1,226,756 EFC:$1,640,223 RIH W/SPEAR 7"@ 9171' MW:10.0 NACL/NABR POH WITH 2-7/8" COMPLETION EQUIPMENT AND SEAL ASSEMBLY. RIH WITH PKR RET. TOOL ON 3-1/2" DP. UNABLE TO RELEASE PACKER. POH WITH RETRIEVING TOOL & DP. RIH WITH SPEAR. DAILY:S29,100 CUM:$1,421,079 ETD:S1,255,856 EFC:$1,640,223 The above is correct Signature For form preparation a stribution, see Procedures Manuah.~Section 10, Drilling, Pages 86 and 87, IDate I Title ASSO~A~ ENGINEER 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 Report" 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. Accounting cost center code District County or Parish NORTH SLO?E Lease or Unit ADL: 25520 ITitle WORKOVER State AK 30-18 Well no, ARCO Alaska, Inc. Field KUPARUK RIVER UNIT Auth. or W.O. no. AK3102 Operator IA.R.Co. W.I. ARCO 56.0000 Spudded or W.O. begun IDate ACCEPT I 06/27/88 Date and depth as of 8:00 a.m. 06/30/88 ( TD: 9195 PB: 9088 SUPV:WM/L 07/01/88 ( D: 9195' B: 9088' Old TD Released rig Complete record for each day reported NORDIC I Iotat number of wells (active or inactive) on this i ost center prior to plugging and bandonment of this well our I Prior status if a W.O, I 1930 HRS POOH, LDDP 7"@ 9171' MW:10.0 NACL/NABR CONTINUED RIH WITH SPEAR; RECOVERED PACKER AND TAILPIPE ASSY. RUN 7" SCRAPER. POOH AND LD DRILL PIPE. DAILY:S29,100 CUM:$1,450,179 ETD:S1,284,956 EFC:$1,640,223 RELEASED RIG 7"@ 9171' LDDP AND BHA. RAN COMPLETION ASSY WITH TAIL @ 8750', HR PKR @ 8644', FVLD SSSV @ 1724' DISPLACED WELL WITH 340 BBLS DIESEL. SECURED WELL AND RELEASED RIG @ 0430 HRS, 7/1/88. New TD Date PB Depth Kind of rig Classifications (oil, gas, etc.) Producing method Type completion (single, dual, etc,) Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test 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 Signature I Date I Title Drilling, Pages 86 and 87. ASSOCIATE ENGINEER STATE OF ALASKA ALASh,~ OIL AND GAS CONSERVATION COMM,SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well © Alter casing D Time extension [] Change approved program © Plugging [] Stimulate ~ Pull tubing~. Amend order ~ Perforate ~ Other~ 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 58' 3. Address 6. Unit or Property name P. O. Box 100360, Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of well at surface 7. Well number 1149' FNL, 2085' FWL, Sec. 22, T13N, R9E, UM 30-18 At top of productive interval 8. Permit number 1 065 ' FNL, 11 O0 ' FEL, Sec. At effective depth 1236' FNL, 1026' FEL, Sec. At total depth 1294' FNL, 1000' FEL, Sec. 27, T13N, R9E, UM 27, T13N, R9E, UM 27, T13N, R9E UM 88-26 · 9. APl number 50-- 029-21793 10. Pool Kuparuk River Oil Pool feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Length 80' 2902 ' 9138' Production 91 95 ' M D feet 6826 ' TVD feet 9088 'MD feet 6740 ' TVD feet Plugs (measured) None Junk (measured) None Size Cemented Measured depth 1 6" 1 75 sx AS I 110 ' MD 9-5/8" 900 sx AS III 2937'MD & 300 sx AS II 7" 965 sx Class G 9171 'MD ~ue Verticaldepth ll0'TVD 2370'TVD 6807'TVD Perforation depth: measured 8998' - 9018' true vertical 6668' - 6684' ~bing(size, grade and measured depth) 2-7/8", J-55, tubing w/tail ~ 8750' Packers and SSSV(type and measured depth) HB packer @ 8676', FVLD SSSV ~ 1788' 12.Attachments Description summary of proposal RECEIVED JUL ! 5 Alaska 0il & 6as Cone. Commission All ~;' J'.,:'" Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation June 30~ 1988 14. If proposal was verbally approved Subsequent Work Reported on Form No./~,_f/O~/Dated___~/~3/./.~ Name of approver Mike Minder, AOGCC Date approved 6- 2 9 - 8 8 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ ~C~.,I/.,,rL~/ Title A ssocia te Engineer d Commission Use Only (5A3/001 9) (JC) Date Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Form 10-403 Rev-¥2-1-8~' -- 'Approved Copy Returned Commissioner Approval No. the commission Date t_~ ..-~2 in triplicate/,~ Kuparuk River unit 30-18 Workover Purpose of Workover The purpose of the workover is to pull the tubing and recover the packer that released and fell down the hole when the well was originally completed. Rig Operations 1. MIRU Nordic Rig #1. 2. Kill well with 10.0 ppg brine. Set BPV~ND tree. NU BOPE and test to 3000 psi. 3. Pull hanger to rig floor. POOH with tubing, standing back. 4. PU PBR retrieving tool. RiH latch PBR, POOH with PBR and packer. 5. PU 6-1/8" bit and 7" casing scraper, RiH 8800'. POOH. 6. Run completion with new PBR/PKR. 7. Release rig. Turn well over to Production for testing. Note: Verbal approval was received by Mike Minder 6/29/88 BHP: 3000 psi Fluid: 10.0 ppg NaC1/NaBr Brine RECEIVED J U L l Alaska Oil & (}as C,~. Commission LPAD/30-18d ih ANNULAR PREVENTER PIPE RAMS 4 BLIND RAMS 5 TUBING HEAD 1. 16" CONDUCTOR SWAGED TO 9-5/8" 2, 11"-3000 PSI STARTINO HEAD 3, 11 "-$000 PSI X 7-1 / 16"-5000 PSI TUBING HEAD 4, 7-1/16" - 5000 PSt PIPE RAMS ,5, 7-1/16" - $000 PSI BLIND RAMS 6. 7-1/16" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1 . CHECK AND FILL ACCUMULATOR RESERVOIR TO P~OPED LEVEL WITH HYDRAULIC FLUID. '-'..-~ Z~SSLIPE THAT ACCUMULATOR. PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR, ,,, OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED 'WITH CHARGING PUMP OFF. 4, RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1, FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL, 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED, PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD, 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 ,PSI AND HOLD FOR 10 MINUTES, BLEED TO ZERO PSI, 6. OPEN ANNULAR PREVENTER AND CLOSE 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 REMAINING UNTESTED MANIFOLD VALVES. IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM, BLEED SYSTEM TO ZERO PSI, 9, OPEN PIPE RAMS. BACKOFF RUNNING JOINT AND PULL OUT OF HOLE, CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES, BLEED TO ZERO PSI. lO. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES AP.E FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION, 11, TEST STANDPIPE VALVES TO 3000 PSI. 12, TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13, RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM, SIGN AND SEND TO DRILLING SUPERVISOR, 14, PERFORM COMPLETE BORE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BORE DAILY. RECEIVED JUL 1 6 ]. 88 Alaska 0il & Ci-~s C,.~,n..,~.. Commissit~(3 JULY 28, 1986 An~":..~,.',' (NORDIC RIG 9-5/8") STATE OF ALASKA -' ALAS.,.., OIL AND GAS CONSERVATION COM~,..$SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate [] Plugging [] Perforate ~ Pull tubing Alter Casing ~ Other ~ COMPLETE 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, inc. RKB 58' Feet 3. Address 6. Unit or Property name P.O. Box 100360, Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of well at surface 1149' FNL, 2085' FWL, 5ec.22, T13N, R9E, UM At top of productive interval 1065' FNL, 1100' FEL, Sec.27, T13N, R9E, UM At effective depth 1236' FNL, 1026' FEL, Sec.27, T13N, RgE, UM At total depth 1294' FNL, 1000' FEL, 5ec.27, T13N, R9E, UM 7. Well number 30-18 8. Approval number 8-284 9. APl number 50-- 029-21793 10. Pool Kuparuk River 0il Pool 11. Present well condition summary Total depth: measured true vertical 9195 'MD 6826 'TVD Effective depth: measured 9088 'MD true vertical 6740'TVD Casing Length Size Conductor 80 ' 16" Surface 2902 ' 9-5/8" Production 9138' 7" feet feet feet feet Plugs (measured) None 'Junk (measured) None Cemented 175 sx AS I 900 sx AS III & 300 sx AS II 965 sx Class G Measured depth 1lO'MD 2937'MD 9171 'MD True Vertical depth 110'TVD 2370 'TVD 6807'TVD Perforation depth: measured 8998'-9018'MD 12. true vertical 6668 ' -6684 'TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail ~ 8750' Packers and SSSV (type and measured depth) HB pkr ~ 8676'~ FVLD SSSV @ 1788' Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf WateroBbl Casing Pressure Tubing Pressure 14. Attachments (Compl. Well H~tory & Addendum, dated 5/24/88) Daily Report of Well Operations ~ Copies of Logs and Surveys Run ~ Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~'~' ~L./_ ~ ,: Title Associate Engineer Form 10-404 Rev. 12-1-85 (Dani) SW03/007 Date Submit in Duplicat~ $ UB.$ URFA CE DIRECTIONAL SURVEY I'll UIDANCE 'r~'IONTINUOUS F'~ OOL Coml:)arly ARC0, . , ALASKA, TNC. Well Name 30-18 (1149' FNL~2085.,' FWL~,SE,C 22,T13N~R9E~UM) FieldlLocationKUPARUK~ NORTH SLOP, E~ AL,,ASKA Job Referenc,e No, 72722 MCBRIDE D.at,,e 4-APR-88 Computed By: KRUWELL GCT DIR~]CTI()NAb SURVEY A~CO ALASKA, INC, KUBARUK NURTH SLOPE,ALASKA SURVEY DAT~;: 04-APR-B8 Ei~GINEER: ~, MCBRIDE NETHODS OF COmPuTATION TOOL LOCATION: TANGENTIAL- Averaged deviation and azimuth INTERPOLATION: LINEAR VERTICAL ~ECTIUN: HONIZ. DIST, PROOECTED ONTO A TARGET AZIMUfH OF 60UTH 20 DEG ~! MIN EA~T ARCO AbASKA, INC, KUPARU~. NORTH SLOPE,AbASKA COMPUTATIDN DATE{ 4.,MA¥-88 PAGE DATE OF 6URVE¥{ 04-APR=B8 KELLY BUSHING ELEVATION{ 58,00 ENGINEER{ M, MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FE~T Of' MEATURED DEPTH TRUE ~UB-6EA COURSE ~iEASURED VERTICAL VERTICAb DEVIATION AZIMUTH DEPTH DEPTH 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 60O O0 70O O0 800 O0 900 O0 1000 O0 1100 1400 1500 1600 1700 1800 1900 DEPTH DEG MIN DEG ~IN 0,00 '58,00 0 0 N 0 0 E 100,00 42,00 0 14 S 65 42 W 200.00 142.00 0 20 S 58 58 W 299,99 241,99 1 24 $ 2 30 W 399,81 ~41.81 5 12 $ 3 47 E 498,99 440,99 9 5 S 16 27 E 597,3U 539,38 11 45 S 17 48 E 694 50 636,50 15 25 $ 15 41E 790~12 732,12 18 52 $ 18 31 E 883.60 825.60 22 9 S 16 37 E 975 65 917,65 23 53 O0 1065 97 1007.97 27 14 O0 1153 38 1095,38 30 41 O0 1237 97 1179,97 33 33 O0 1119 89 1261,89 36 24 O0 1399 25 1341,25 38 31 O0 1475 7~ 1417,73 41 32 O0 1549 10 1491,10 44 13 00 1519 29 1561,29 46 19 O0 1686.58 1628,58 48 48 2000 O0 1750.8~ 1692.88 50 58 2100 O0 1813.93 1755,93 50 41 2200 O0 1878,09 1820,09 49 17 2300 O0 1944,52 188b,52 47 22 2400 O0 2011.11 1953,11 49 20 2500 O0 2076,78 2018,7@ 48 27 2600 O0 2142,0~ 20~4.06 49 ]b 2700 O0 2208,06 2150,06 47 42 2800 O0 2275,92 2217,92 47 35 2900 O0 2143,92 2285,92 46 18 3000 O0 2414,5~ 2356.58 44 29 3100 O0 2486 74 2428,74 43 2 , O0 2550,76 2502,76 41 40 O0 2635,85 2577,85 40 58 O0 2710,85 2652,85 42 20 O0 2784,55 2725,55 42 20 O0 2857,82 2799,82 4] ~6 O0 2930,Bb 2872,86 43 28 O0 3002,43 2944,43 44 29 O0 3073.89 3015,89 44 20 3200 3300 3400 3500 3600 ]700 3800 3900 VERTICAL DOGbf]G RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH F'~;ET DEG/IO0 ~"EET FEET FEET DEG MEN 0,00 0,00 O,OU N 0,00 '0.01 0,07 O,Ob $ 0,18 0.06 0.03 0.30 S 0.63 0.76 3'22 1.20 6 1,06 6,06 3.97 6,75 $ 0,81 18.51 2.19 19,1~ S 1,60 36,33 4,15 35,09 $ 7,14 60.05 2,71 58,9! 5 13.77 89,18 ~,54 86,80 S 22,35 124,52 2,05 120,54 ~ ~3,29 $ 18 33 g 163.62 S 20 46 E 205.51 $ 20 26 E 255.04 S 20 20 g 308.34 $ 19 55 E 365.69 S 19 35 E 426152 S 19 23 E 490192 S 16 43 E 558.79 S 15 41 E 629,82 S 16 27 E 703,59 S 18 28 E 780,09 S 18 11E 857.67 S 17 30 E 934 30 S 17 14 g 1008:94 $ 17 23 E 1083.44 $ 17 18 E 1158.77 $ 18 40 E 1234,~5 S 18 50 g 1309,55 $ 19 1 E 1382.98 S 19 4 E 1455,28 $ 19 16 E 1527.02 $ 19 17 E 1596,24 S 19 42 E 1663.47 S 19 44 g 1729.51 S 19 54 E 1795,65 $ 19 54 E 1863,24 S 20 1~ E 1931.29 S 20 23 E 1999,58 $ 20 1 E 2069,43 $ 20 32 E 2139,37 0,00 N 0 0 E 0,19 S 71 55 W 0,70 $ 64 57 W 1,60 $ 41 40 W 6,80 $ 6 48 W 19,20 $ 4 46 E 36,79 S 11 11 E b0,50 S 13 9 E 89 63 S 14 26 E 125:05 S 15 26 E 3,29 4,29 2,89 2,60 3.0'I 2,74 2.53 3,75 2,79 2,22 157.92 5 44 62 E 164 10 S 15 46 E 198,2J 5 59:29 g 206:90 $ 16 39 E 243,60 $ 76'52 E 255,34 S 17 26 E 29],62 $ 94,95 E 308,59 $ 17 55 E 347040 S 114 84 E 365.89 S 18 17 E 404 70 $ !35 28 E 426,71 S 18 29 E 465 34 S 156 96 E 491.10 $ 18 30 E 529 95 S 177 91E 559 02 S 18 33 E 598 41 S 197 54 E 630:17 S 18 16 E 669 47 5 218,06 E 704,09 $ 18 2 E 0 96 0i95 I 57 2 O2 1,01 0,81 1.84 2,36 0,97 2,45 742 48 5 816 12 5 889 14 $ 950 49 $ 1031 58 5 1103 65 5 1175 74 $ 1246 88 $ 1316 35 S 1385 68 ~ 241 16 E 780,66 265i69 E 858,27 289 15 E 934,97 311 38 E 1009,71 333 66 E 1084,29 356,15 E 1159,71 379,43 E 1235,45 403,56 E 1310,56 427,42 E 1384,01 451,27 E S 17 59 £ S 18 1E $ 18 0 E $ 17 57 E S 17 55 g S 17 53 E 8 17 53 E S 17 56 E $ 17 59 E 1457,31 $ 1~ 2 E 0,26 1,44 0.42 0.37 2,23 I O3 0 89 2 51 2 11 0 35 1452 54 5 474.42 E 1528,05 $ 18 5 E 1517 87 $ 497.30 E 1597,2U S 18 8 E 519.77 E 1664,48 1730,49 S 18 15 E 1796,62 1581 1643 1705 1769 1833 1897 1962 2028,30 S 682.93 E 2140,19 24 S S 18 11E 41 $ 542 06 g 64 S 554:48 E S 18 18 £ 22 S 587,40 g 1864,19 S 18 22 g 09 S 610,88 E 1932.20 S 18 25 E lb $ 634,52 E 2000,46 S 18 29 E 74 S 658,57 E 2070,28 S 18 32 E 18 36 £ ARCO ALASKA~ 3 O'18 EUPARUK NORTH SLOPEwAbASKA COMPUTATION DATE: 4-1~A¥'-8 8 PAGE 2 DAT~ OF SURV~¥~ 04-APR-88 KELLY ~UfiHING EbEVATLON: 58,00 FT ENGiNEER~ M. MCBRIDE INTERPOLATED VAbUES FOR EVEi~ 100 FEE3' OF hlEA$URED DEPTH TRUE SUB-SEA COURSE VER'flCAL DOGLEG RECTANGUhAR COORDINATES HORlZ, DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAS2~/WEST DIST, AZIMUTH DEPTH DEPTH DEPTH DEG MIN 4000 O0 3144,77 3086,77 45 26 4100 O0 3214 91 3156,9! 45 37 4200 430O 4400 4500 4600 4700 4800 4900 O0 3283 37 3225.37 47 45 O0 3350 44 3292,44 48 2 O0 3417 09 3359.09 48 1 O0 3483 71 3425,71 48 6 O0 3550 45 3492.45 48 23 O0 3616 80 3558.80 48 36 O0 3682:92 3624 92 48 43 O0 3748.58 3690:58 49 0 5000 O0 3813 98 3755.98 49 6 5100 O0 3879:40 3821 40 49 17 5200 O0 3944 72 3886:72 49 18 5300 5400 5500 5600 5700 580O 5900 O0 4010 18 3952 18 49 4 O0 4075 55 4017:55 49 12 O0 4140 81 4082,81 49 18 O0 4206 08 4148,08 49 15 O0 4271 71 421],71 48 21 O0 4339,48 4281.48 46 39 00 4408,31 4350,31 46 26 6000 O0 4477 14 4419.14 4b 37 6100 6200 O0 4614,99 6300 6400 6500 6600 6700 6800 6900 O0 4545 90 4487.90 46 37 45 4556.45 46 49 O0 4682 4624.99 46 39 O0 4751.65 4693.65 46 36 O0 4820.28 4'162.28 46 42 O0 4889,46 ~831.~ 45 22 O0 4950.35 4902.35 44 39 O0 5031.57 4973.57 44 37 O0 5102.76 5044.76 44 28 7000 O0 5174 15 5116.15 44 25 7100 7200 7300 7400 7500 7600 7700 7800 7900 O0 5245 O0 5317 O0 5388 O0 5460 O0 5531 O0 5604 O0 5678 62 5187.62 44 19 19 5259.19 44 21 63 5330.63 44 25 08 5402.08 44 27 50 5473.50 44 lO 34 5546,34 42 23 25 5620,25 42 20 O0 5752 27 5694.27 42 13 O0 5826.44 5758.44 41 58 DEG MIN FEET S 20 13 g 2209.92 $ 20 19 E 2281,19 $ 20 48 f 2354 08 $ 21 23 E 2428~24 S 21 40 E 2502i76 S 21 51 E 2577 32 s 21 59 ~: 2~51 75 $ 22 10 E 2726:52 $ 22 19 E 2801 49 s 22 28 E ~76~86 S 22 22 E 2952.45 S 22 15 g 3028.03 $ 22 19 g 3103 70 S 22 36 E 3179:24 S 22 38 E 3254.84 S 22 41 E 3330 55 S 22 54 E 3406:23 $ 22 53 E 3481~59 S 22 50 E 3555.04 S 22 53 E 3627.5! $ 22 55 E 3699.96 S 23 5 E 3772.49 S 23 31 E 3845,19 S 23 55 E 3917.87 S 24 33 E 3990.38 $ 24 45 E 4062.89 S 25 1E 4134.86 S 25 28 E 4205,12 S 26 0 E 4274.98 S 26 30 E 4344.82 $ 26 41 E 4414.39 $ 26 51 E 4483.87 S 27 3 E 4553.22 $ 26 58 E 4622.69 S 27 0 E 4692.15 S 26 40 E 4761.67 S 25 21 E 4829.82 S 25 29 E 4896.90 S 25 29 E 4963.85 S 25 39 E 5030,b3 DEG/IO0 FEET FEET FEET DEG 0.41 1,87 1,22 0,65 0,93 1,90 0,87 0,49 0,48 0,81 2094,41 a 707 56 E 2210,70 $ 18 40 E 2161,2'I fi 732 27 E 2281,95 $ 18 43 E 2229.54 S 757 79 E 2354 80 $ 1U 46 g 2298.70 S 784 59 E 2428 90 $ 18 50 E 2368 Ob S 811 91E 2503 38 $ 18 55 E 2437 31 $ 839,58 E 2577 87 $ 19 0 E 2506 38 ~ 867,44 E 2652 24 S 19 5 E 2575 69 $ 895,57 E 2726 95 $ 19 10 E 2645 12 S 923.98 E 2801 86 $ 19 15 E 2714 86 & 952,71E 2877 18 S 19 20 E 0.92 0.14 0 46 0 15 0 23 0 33 0 47 2 21 0 32 0 13 2784 78 S 981.61 E 2952 72 S 19 25 E 2854 70 5 1010.31 E 3028 26 S 19 29 E 2924 2994 3064 3134 3204 3273 3341 3408 83 S 1039,00 E 3103 68 S 1067,93 E 3179 52 S 1097,03 E 3254 47 S 1126,19 E 3330 30 ~ 1155,56 E 3406 77 $ 1184,99 E 3481 55 S 1213,49 E 3555 40 ~ 1241,66 E 3627 89 S 19 33 E 40 $ 19 37 g 96 S 19 41E 64 S 19 45 E 29 $ 19 49 g 63 S 19 53 E 07 $ 19 57 E 52 $ 20 0 E 0,13 0,73 0,42 0,51 0,08 0,30 2,33 0,40 0.24 0,51 3475 22 S 1269 87 E 3699.97 $ 20 4 E 3542 07 $ 1298 24 E 3772.49 S 20 7 E 3608 94 $ 1327 04 E 3845,19 S 20 11E 3675 bi S 1356 31 E 3917.87 S 20 15 E 3741 90 $ 1386 15 E 3990,40 S 20 19 E 3807 99 S 1416 52 k 40~2,92 $ 20 24 E 3873 50 ~ 1446 89 E 4134,91 $ 20 28 E 3937 31 6 1476 95 & 4205.21 S 20 33 E 4000 54 S 1507 42 E 4275.12 S 20 38 E 4063 51S 1538.54 E 4345,02 $ 20 44 E 0,35 0,71 0,42 0,54 0,42 1,52 0,68 0,89 1,01 0,58 4126,08 S 1569,95 E 4414,67 S 20 49 E 4188,51 S 1501,51 g 4484,24 S 20 55 g 4250,73 S 1633,23 E 4553,69 S 21 1 g 4313 06 fi 1665,03 E 4623,29 S 21 6 E 4375 37 S 1696,82 E 4692.88 S 21 11E 4437 77 $ 1728.56 E 4762.53 S ~1 16 E 4499 37 $ 1758.50 E 4830,80 S 21 20 E q5bO 21 S 1787,43 E 4898,00 $ 21 24 E 4620 89 S 1816.38 E 4965.07 S 21 27 E 4681 40 S 1845,35 E 5031,98 $ 21 30 E %RCO ALASKA, t 0-18 UORTH SLOPE,ALASKA COMPUTA, I'ION DATE: 4-MAY-88 ~AGE 3 DATE OF SURVEY: 04-APR-88 KELLY BUSHING ELEVATIONS 58,00 FT INTERPOLATED VALUE6 FOR EVEN 100 FEET OF MEASURED D~PTH TRUE SUB-SEA COURSE ~ASDRED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG SIN DEG SIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARWURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIMT, AZIMUTH FEET DEG/IO0 FEET FEET ~000 O0 5900.94 5~42,94 41 48 8100 O0 5975 47 5917,47 41 45 ~200 O0 6050 06 5992,06 41 48 ~]00 O0 6124 83 6065,83 41 14 ~400 O0 6200 26 6142,26 40 49 ~500 O0 6276 lb 6218,16 40 20 8600 O0 6~53 15 6295,15 39 2 8700 O0 6431 36 6373,36 38 5 ~800 O0 6510 21 6452,2~ ~7 46 Bgo0 O0 6589 59 6531.59 37 ll ~000,00 ~100,00 ~195,00 6659,5! 6611.51 36 45 6749,62 6691,~2 36 45 6825,73 6767,73 36 45 S 25 53 E 5097 02 S 26 I E 5163:37 S 26 13 E 5229,61 S 26 33 E 5295,62 $ 26 56 E 5360.84 S 26 35 E 5425.51 $ 25 17 E 5489,01 $ 23 56 E 5551,14 $ 23 35 E 5612,52 $ 23 28 E 56'13,23 S 23 47 E 5733,24 S 23 49 E 5792,98 $ 23 49 E 5849,73 0,33 0,54 0,82 0 8O 0!66 1 5O 0,43 0 69 1~13 1,57 0,00 0,00 ~741,48 8 1874.33 E 5098.50 S 21 34 E 4801 4~ S 1903,50 E 5164,99 S 21 37 E 4861 23 S 1932 85 E 5231,39 $ 21 40 E 4920 72 6 1962:32 E 5297,56 S 21 44 E 4979 34 S 1991,88 E 5362 97 $ 21 48 E 5037 43 6 2021 27 E 5427:83 S ~1 51E b094,7~ S 2049 27 ~ 5491.49 S ~1 54 E 5151,51S 2075 06 E 555] 73 $ ~! 56 E 5207,80 S 20~9 8] E 5615:20 $~1 57 g 5263,57 $ 2124 06 E 5675,98 $ 21 58 E 5318,65 S 2148,17 E 5736 08 S 21 59 E 5373,41 S 2172,34 g 5795:91 S 22 0 g 5425,43 $ 2195,30 E 5852,74 S 22 1E ARCO ALASKA, INC. 3 0-18 KUPARUK NORTH SLOPE,ALASKA CUNPUTATION [)ATE: 4-MA~-BB PAGE 4 DATE OF SURVEY: 04-APR-SH KELLY BUSHING ELEVATION: 58,00 FT ENGINEER: M, MCBRIDE INTERPOLATED VALUES FOR EVEN 1000 f'EET OF MEASORED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG 0 O0 1000 2000 3000 4000 5000 6O0O 7000 8000 9000 0 O0 '58,00 0 0 O0 975 65 917,~5 23 53 O0 1750 88 1692,88 50 58 O0 2414 58 2356,58 44 29 O0 3144 77 3086.77 45 26 O0 3813 98 3755,98 49 6 00 4477 14 4419,14 46 37 O0 5174 15 5116,15 44 25 O0 5900 94 5842.94 41 48 O0 6669.51 6611,51 36 45 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/~EST DIST. AZIMUTH FEET DEG/IO0 FEET FE~T FEET DEG MXN N 0 0 E 0,00 $ 18 33 E 163,62 S 18 28 E 780,09 S 19 16 E 1527 02 $ 20 13 E 2209:92 $ 22 22 E 2952,45 S 22 55 E 3699,96 S 26 41 E 4414,39 S 25 53 E 5097 02 S 23 47 E 5733:24 9195,00 6825,73 6767,73 36 45 $ 23 49 E 5849,73 0 o0 3:29 0,96 ,26 ..,41 0 92 0 13 0 35 0 33 I ~7 0 O0 h 157 742 1452 2094 2784 3475 4126 4741 5318 0 O0 E 92 ~ 44:62 E 164 48 S 241.16 E 780 54 5 474,42 E 1528 41 S 707,56 E 2210 78 $ 981,61 E 2952 22 $ 1269,87 E 3699 O~ $ 1569,9b E 4414 48 S 1874.33 E 5098 6b S 2148,17 E 5736 0 O0 N 0 0 E 10 $ 15 46 E 66 $ 17 59 E 05 $ 18 5 E 70 $ 18 40 E 72 $ 19 25 E 97 $ 20 4 E 67 $ 20 49 E 50 $ 21 34 E 21 OB S E 0.00 5425,4~ ~ 2195,30 E 5852,74 S 22 1E ARCO ALASKA, INC, 3 0'18 KUPARUK NORTH SLOPE,ALASKA C[~PUTATIO~ ~ATE~ 4-~AY-88 PAGE 5 DATE OF SURYE¥: 04-APR-SU KE6bY BUSHING ELEVATZONI 58,00 FT ENGINEER= N, MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA CO{IRSE MEASURED VERTICAL VERTICAL DEVZATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG 0 O0 58 O0 t58 O0 258 O0 358 06 458 56 559 88 662 25 766 19 872 40 0,00 -58,00 0 0 N 0 0 E 58,00 0,00 0 13 S 82 36 W 158,00 100,00 0 17 S 61 29 ~ 258 O0 200,00 0 32 S 32 13 ~ 358~00 300,00 3 25 S 2 54 E 458'00 400.00 7 42 S !1 37 E 558,00 500,0() 10 27 S 18 40 E 600,00 14 16 S 15 45 E 658,00 758,00 700 O0 17 24 S 17 34 E 858,00 800:00 21 37 S 17 33 E 980 73 1091 1205 1324 1447 1576 1712 1856 2011 2169 958 O0 900,00 23 27 06 1058 OO 1000,00 26 51 38 1158 O0 1100,00 30 50 13 1258 O0 1200,00 34 14 69 1358 O0 1300.00 37 25 42 1458 O0 1400,00 40 58 46 1558 O0 1500,00 44 37 97 1658 O0 1600,00 47 57 32 1758,00 1700.00 51 4 03 1858,00 1800.00 49 49 2319 92 1958,00 2471 64 2058,00 2624 2773 2920 3060 3196 3329 34 1900,00 47 24 2000,00 48 37 49 2158,00 2100,00 49 9 54 2258 O0 2200,00 47 11 24 2458:0~ 2300,00 45 40 52 2458,00 2400,00 43 35 30 2558,00 2500,00 41 41 35 2658,00 2bO0,O0 41 1 04 2758.00 2700,00 42 33 25 2858.00 2800.00 43 16 3737 66 2958.00 2900.00 44 15 3877 76 3058,00 3000.00 44 26 3158,00 4018 4162 4311 4461 4611 4762 4914 5067 87 3100,00 45 30 44 3258,00 3200,00 47 10 32 3358,00 3300,00 48 7 37 3458,00 3400,00 48 23 37 3558,00 3500,00 48 23 26 3658,00 3600,00 48 ]6 36 3758,00 3700.00 49 2 21 3858,00 3800,00, 49 11 VERTICAL DOGLEG RECTANGULAR COORI)I~ATES HURIZ, DEPARTURE SECTION SEVERITY NURTH/SUUTH EAST/wEST DIST, AZZMUTH FEET DEG/IO0 FEET FEET FEET DEG 0,00 0,00 '0,01 1,00 0,02 0'00 0,21 1,22 3.03 4.37 12.47 5.04 2~.66 2.70 50,41 ~ 43 78.63 4~24 114.34 2,73 0,00 0,00 $ O, 18 O 57 6 3595 13 26 S 28 80 S 49 bO S 76 77 $ ~10.70 0,00 0,03 0,43 0,93 0,97 0,09 4.72 11,16 19,07 30.27 0,00 N 0 0 £ 0,03 S 89 28 W 0,47 S 67 17 W 1,09 $ 58 29 W 3,72 S 15 8 W 13,25 S 0 23 E 29 18 $ 9 17 E 40 79,10 S 13 56 E 114,76 $ 15 17 E S 17 36 E S 20 40 E S 20 23 E S 20 23 g S 19 34 E S 19 43 E S 16 28 E S 16 12 E 2; 18 31 E S 17 40 E 155 87 2,73 202!4~ 4.]4 257 7 2.92 321,80 3,17 394 37 1 44 475:37 2i68 567,49 3 80 671.51 2 03 788,88 0.65 910.76 1,99 lbO,bO 5 194 42 $ 57 246 lU $ 77 306 23 5 99 374 4O S 124 450 69 5 151 538 30 $ 180 638,61 S 209 750,82 S 243 866,68 S 282 42 21E 156,36 S 15 39 E 85 E 202,85 S 16 34 E 48 E 258,08 S 17 28 E 63 E 322,03 S !8 i E 51 E 394.56 S 18 23 E 75 E 475,55 $ 18 36 40 E 567,73 $ 18 31 g 02 E 671,94 S 18 7 E 95 E 789,45 S 17 59 E 03 E 911,41 $ 18 1E S 17 21 E 1023,59 S 17 15 E 1137.54 5 18 44 E 1253,04 S 19 2 g 1363 51 S 19 3 E 1470:83 S 19 17 E 1569,17 S 19 42 E 1661,01 S lq 45 E 1748.76 S 19 45 E 1838,98 S 20 lb E 1931,46 1,76 1,85 1,87 2,17 3,56 1,95 0,36 0,56 0,68 0,89 974 50 $ 315,74 E 1024.37 ~ 17 57 E 1083:37 S 349 84 E 1138,45 S 17 53 E 1193,35 $ 385 39 E 1254,04 S 17 53 E 1297,94 S 421 07 E 1364,53 $ 17 58 E 1399,43 S 456 02 E 1471,86 S 18 2 E 1492,32 S 4~8 36 E 1570,20 S 18 7 E 1578,93 ~ 518 94 E 1662,02 S 18 11E 16~1,53 S 548 56 E 1749,74 S 18 16 E 174b,40 $ 579 17 E 1839,93 S 18 20 E 1833,25 S 610 94 E 1932,$7 S 18 25 E ~ 20 12 g 2025,70 S 20 31 g 2123,82 S 20 13 g 2223,37 5 20 30 E 2326,38 S 21 24 E 2436,66 $ 21 47 E 2548,49 S 22 I E 2660,25 S 22 16 E 2773.17 $ 22 28 E 2887.70 S 22 16 E 3003,21 2 08 0 56 0 09 2 21 0 60 0 55 0 92 0 44 0 68 0 75 1921 2013 2107 2203 2306 2410 2514 2618 2724 2831 66 S 643,59 E 2026,57 S 18 30 E 74 $ 677,47 E 2124 64 S 1835 E 03 S 712,21E 2224 14 S 18 40 E 62 S 748,00 E 2327 11 S 18 44 E 54 S 787,66 E 2437 32 S 18 51E 54 $ 828,86 E 2549 Ob S 18 58 E 26 S 870,62 E 2660 73 S 19 5 E 90 S 913.23 E 2773,56 S 19 13 E 89 $ 956,86 f 2888,01 S 19 20 E 77 5 1000,90 E 3003,45 $ 19 27 E ARCO AI, A~KA, INC, 3 0'18 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 4-MAY-88 PAGE b DATE OF SURVEYI 04-APR-8~ KEb[.,Y BUSHING ELEVATION: 5B,00 FT ENGINEER: ~, NCBRIDE INTERPOLATED VAGUES FOR EVEN 100 f'EET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZINUTH SECTION SEYERITY NORTH/SOUTH EAST/WEST DIST, AZIMUT~ DEPTH DEPTtt DEPTH DES NIN 537 5526 5679 582~ 597 b~17 6263 6409 6554 34 3958.00 3900,00 49 11 ~3 4058,00 4000.00 49 12 36 4158.00 4100,00 49 13 30 4258,00 4200,00 48 45 96 4358,0U 4300,00 46 33 14' 445R.00 4400.00 46 32 63 4558,00 4500 O0 46 41 60 4658,00 4600:00 46 40 24 4758,00 4700.00 46 37 ~7 4858.00 4800,00 46 ~5 6696 70 4958 O0 4900,00 44 40 6837 15 5058:00 5000,00 44 40 6977 38 5158,00 5100.00 44 27 7117 7257 7397 7536 7672 7807 7942 30 5258,00 5200,00 44 19 09 5358,00 5300.00 44 25 08 5458,00 5400,00 44 26 77 5558,00 5500,00 43 30 60 5658,00 5600.00 42 20 73 5758.00 5700.00 42 40 5858,00 5UO0,O0 41 49 8076 57 5958 O0 5900,00 41 48 8210 66 6058 O0 600U,O0 41 48 8344 8476 8606 8733 8860 8985 ~.9~95 04 6158 O0 610o.00 41 4 14 6258 O0 6200.00 40 32 24 6358 O0 6300,00 38 59 82 6458,00 6400,00 37 58 29 6558.00 6500.00 37 20 64 6658.00 6bO0.O0 36 46 00."6825.7~ 6767.73 36 45 DES ~IN FEET DEG/100 FEET FEET FEET DEG NIN S 22 23 g 3119 10 0.80 S 22 37 g 3234:52 0,27 $ 22 46 g 3350.50 0,45 G 22 57 E 3466.09 1,77 $ 22 50 E 3574,61 0,36 $ 22 5~ E 3679.74 0,31 S 23 8 E 3785,2g 0,91 S 23 45 E 3891.45 0.36 $ 24 34 E 3997,08 0 14 $ 24 53 E 4102,61 2:30 2939 08 $ 1044 86 E 3119,28 $ 19 34 E 3045:75 $ 10~9~21E 3234,65 $ 19 40 E ~152,89 6 1133,91 E 3350,59 $ 19 46 E 3259,48 S 1178 95 E 3466,14 $ 19 53 E 3359,61S 1221:09 E 3574,64 $ 19 58 E 3456,58 $ 1261'99 E 3679,75 S ~0 3 E 3553.86 S 1303,27 E 3785,29 $ 20 8 E ~651,40 S 1345,61 E 3891,45 S 20 13 E 3748,01S 1388.94 E 3997,09 $ ~0 20 E 3844,16 S 1433,24 E 4102,65 $ 20 26 E $ 25 27 E 4202.81 $ 26 14 E 4300,95 S 26 43 E 4398,65 S 26 57 E 4495,88 S 27 2 E 4592 85 S 27 0 E 4690:12 $ 26 1E 4787;02 S 25 29 g 4878,53 S 25 29 E 4969.02 S 25 43 E 5058,81 76 0 15 0,47 1,33 0,40 2.47 0,46 0,74 0,19 3935 22 5 1475 95 E 4202,90 $ 20 33 E 4023 9~ $ 1518 91E 4301,11 S 20 40 E 4111 93 $ 1562 84 E 4398,91 $ 20 48 E 4199 29 $ 1606 98 E 4496,26 S ~0 56 E 4286 2~ S 1651 38 E 4593,40 $ 21 4 E 4373,55 $ 1695 89 E 4690 84 $ 21 1t E 4460,61 6 1739 89 E 4787 93 S 21 18 E 4543 55 & 1779,49 E 4879 59 S 21 23 E. 4626:58 S 1818.61 E 4970 24 $ 21 27 E 4706,91 6 1857,62 E 50~0 21 $ 21 32 E S 25 5~ E 5147.~3 S 26 lb E 5236.68 $ 26 43 E 5324,42 S 26 44 E 5410,13 S 25 IO E 5492,92 S 23 45 E 5571,93 S 23 27 E 5649,20 S 23 39 E 5724.66 $ 23 49 E 5849,73 0 43 0 47 0 52 1 21 1 55 0 86 0 34 1,35 4787,40 $ 1896 66 E 5149,42 $ 21 36 E %867,60 $ 1935:99 E 5238,47 $ 21 41E t946,62 S 1975:32 E 5326 44 $ 21 46 E 5023,b0 S 2014 33 E 5412 40 S 21 50 E b098,35 S 2050,94 E 5495 41 S 21 54 E bl';O,Sb ~ 2083,48 E 5574 55 $ 21 56 E 5241,49 $ 2114,50 E 5651 93 S 21 58 E 6310,78 $ 2144,71 E 5727,49 S 21 59 E 0,00 :~425,4~ S~195,30 g 5852,74 S 22 1 E ARCO ALASKAw INC, 3 KUPARUK NORTH SDOPEvALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP K!IPARUK A BASE KUPARUK A PBTD TD COMPUTATION DATE: 4-NA¥-88 PAGB 7 DATE OF 5URVEYt 04-APR-8~ KELLY ~USHING EbEVATIONt 58,00 FT ENGINEER: M, MCBRIDE INTERPObATED VAbdES FOR CHOSEN HORIZONS MEASUAED DEPTH BELO~ KB SURFACE bOCATION AT ORIGIN= 1149 FNLw2OSb F~L ~C. 2~.'r13N ~gE,UM 8779 O0 8~2! O0 8902 O0 9051 O0 9088 O0 9195,00 649~ 62 6435 62 6710.37 6652;37 6740 O1 6682,01 6825:73 ~767,73 5196 O0 8 5219 57 S 5264 68 S 5346 58 $ 5~66 84 $ 5425 43 S 2094 67 g 2104 97 g 2124 54 g 2160 49 E 2169 44 E 2195 30 g ARCO ALASKA, INC, 3 0'18 KUPARUK NORTH SLOPE,ALASKA CONPUTATION DATE: 4-MA¥-88 DATE OF 6URVE¥1 04-APR-8~ KELLY OUSHING ELEVATION: 5B.O0 FT ENGINEER: M, MCBEIDE MARKEP TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD NEASURED DEPTH BELOW KB 8779,00 8821,00 8902,00 9051,00 9U88,00 9195,00 1149 FhL,2085 6493,62 64J5.62 652b,82 6468 82 6591,19 ~53]i19 6710,37 6652 37 6740,U1 6682,01 6825.73 6767.73 5196,~0 ~ 5219, 7 S 46,58 $ 5~66,84 $ 5425,4~ $ 2094 67 g 2104 97 E 2124 54 F, 2160 49 E 2169 2195 ~4 E 0 E FINAL WELL LOCATION AT TD{ TRUE SUB-SEA ~EASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 9195,00 b~25,7] b707,73 HORIZONTA£, DEPARTURE DISTANCE AZIMUTH FEET DEG 5~52.74 $ 22 1E SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA, INC., WELL 3 O- 18 FIELD KUPARUK COUNTRY U.S.A. 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J.4_~_~.~4..4.4_~.. -4-$4-~.....4.4.4-..~ ....... ;.4-~4.4.4.4...~.~.., i i i ! i i i ~ i :, ~ i I ~ ~ i i ~ i i ~ i ~ ~ i i i i ~ i i ~ i ! i i i ! i ~ ~ i !.i..i...'...~..~...i._~...r...:..L..:...: ...... :...!...i...: ...... :--.:.-'...1 ....... '...~.-.;..-~ -~t'~"'~"-'-~m'T-E;.7~ZE]Z!Z ]Z]JZN"~]]ZZ;]Z ]]]E]]] ]..Li i. 4...M.4...Li.4.4...i.....4.4-.i.4... ~...i.4,..i.4 ....... i...i...i...i...~...i...~...~.4... ',4..,i...i...! ...... N...N .... 7000 160. PROJECTION ON VERTICAL PLANE 1S0. - 940. SCALED IN VERTICAL DEPTHS HORIZ SCALE = 1/]000 IN/FT Memory MultkFinger Caliper Log Results Summary Company: Phillips Alaska, Inc. Well: 30-18 Log Date: August 9, 2001 Field: Kuparuk Log No.: 4397 State: Alaska Run No.: 1 APl No.: 50-029-21793-00 Pipe Desc.: 2 7/8" 6.5 lb AB-Mod Top Log Intvh 8,030 Ft. (MD) Pipe Use: Tubing Bot. Log intvh 8,730 Ft. (MD) Inspection. ,,Type' Pre-Jet Pump Run Inspection COMMENTS: This log was run to assess the condition of the tubing near the bottom gas lift mandrel for the purpose of setting a jet pump across the mandrel. The caliper recordings indicate that the tubing is in good condition with respect to corrosive damage over the interval logged, with no wall penetrations in excess of 20% wall thickness recorded. Light deposits or scaling is recorded throughout the interval, but no accumulations in excess of 0.10" are indicated. The most significant feature of concern that is recorded is moderate tubing buckling recorded in the interval above the packer. Slight ovality, caused by the bending of the tubing, is recorded in many of the joints logged above the packer. The minimum ID measured at any single depth is 2.28" in Jt. 279 - just above the bottom GLM. Cross-sectional drawings of the ovality recorded at two representative locations are included in the report. This buckling may prevent long objects with an OD smaller than the minimum ID's recorded from traversing this interval. The top joint logged has been estimated to be the 263rd full length joint below the tree, and may be incorrect. MAXIMUM RECORDED WALL PENETRATIONS: No penetrations in excess of 20% wall thickness are recorded throughout the interval logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional metal loss (> 5%) are recorded throughout interval logged. MAXIMUM RECORDED ID RESTRICTIONS: Ovality Due to Bending Ovality Due to Bending Ovality Due to Bending Ovality Due to Bending Ovality Due to Bending 2.28" Min. ID Jt. 279 @ 8,570' MD 2.28" Min. ID Jt. 281 @ 8,650' MD 2.30" Min. ID Jt. 263 @ 8,062' MD 2.30" Min. ID Jt. 266 @ 8,147' MD 2.30" Min. ID Jt. 267 @ 8,180' MD I Field Engineer' L. Koenn Analyst: J. Burton Witness: T. Johns ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 Tubing Size Weight G~a~e &-r~read Nora.OD 2_875 ins 6 5 ~ .g55 AB-Mod 2 875 ins PDS Calip~er Ovende. w Body Re~i°n Analysis August 9. 200] M1:C24 No.99628 penetration body met~ loss body O 5O 263 GDV~ 4 1 oo PDS CALI~ JOINT TABULATION SHEET~ Pipe: 2.875 ins 6.5 ppi J-55 AB-Mod Wall thickness~ Body: 0~21 g.ns Upset = 0.217ins Nominal ID: 2.441 ins Well: 30-18 Field: Kuparuk River Unit Company: PHILLIPS ALASKA. Country: USA Date: August g. 2001 penetration body met. al loss body Joint Penetration Meta / Projqct on Minimum Damage profile No~ Upset Body Loss Upset Body ID i Comments (% wall~ inches inches % % 1 inches inches inches I 0 50 3 1 _ 0 ] .10 -- 2.30 O"~-~. L'~OGGED. Buckled Tubing' -- . g. - "'T-" - 263 0 .03 16 3 I 0 ] .05 2.34 !Shallowpitting. kt. Oeposits. __ -264.1 0 0 I 0 ] 0 2.31 ] GLM4 (Latch@4:30) 265 4 .07 I .06 2.31 I Shallow pitting. Buckled Tubing. 266 4 0 .05 -~l~'plttlng. EL Deposits. 26_7__ - 0 .03~ 15 3 .06 .07 2.30 Shallow plttg.g. Buckled Tubing. 268 0 .02 I 1t 4 0 .06 2.32 / Lt. Dep~s. ' ~ 269 0 I .03 ] 12 4 0 .05 2_3~ ] Buckled Tubing. ~70 0 .04 I 16 2-31 ]LL Deposits. Buckled Tubing. 272 0 .03 ~ 12 4~0~ .04 2.33 ]guck]edTubing. 274 0 .03 ~ 15 3 0 -~ .04 2-7~-- 0 _03 I 15 4 0 I .04 2.35 _ _ -- 2.30 Shallow pitting. ~1 0 05 2.35 LL Deposits. 279 0 .02 I 11 3 I 0 03 2.28__ Buck ed Tubing. 279.1 0 0 i 0 0 ~ 0 0 2_31 IGLMS(La~d~@11:00) 280~ 0 0 0 0 2.28 ~CKER 281 0 .03 16 2 i 0 .08 2.28 Sh~'~wpit~ng. Lt. Deposits. 282 0 .03 t4 4 i 0 .07 232 Lt. Depos ts. ~ 282.1 0 0 0 0 ! 0 0 2.26 ] D-Nlp~ Damage C]assil]cauons Penetration / projection class, in order of oamage severity Hole - penetration exceeds 85% of nominal wall thickness Ring - damage area exceeds 75% of drcumference, but depm range does not exceed 1 ~ p~pe ID Line- damage depth range exceeds 5 ~ pipe ID, but extends less than 20% of drcumference General- oamage depth range exceeds ! ' pipe ID end/or extends more thag 20% of circumference Isolated ~ damage depth range does not e~ceed 5 * pipe ID or extend more than 20% of drcumference Damage reporting threshold: 30 thou inches deviation in body, 50 thou g. upset. Modal line'" length: 0.185 leer. Pipe Tabulations page Welk FiekI: Company: Countrv: Tubing; 30-1[3 Kut~aruk RiVer Unit PHILLIPS ALASKA, INC USA 2.875 ins 6.5 ppf ~-55 AB-Mod Tool Type: Tool Size: No, of Fingers: Anaiysea: August 9, 2001 MFC24 No~99628 1.69~ 24 ]. Burton CrOss section Tool speed = 51 Nomh~al ID = 2.441 N~mina] OD ~ 2,875 Remaining wa ] area = 99 % Tool deviation = 40 ~ for Joint 263 at depth 8064.52 fi Finger 23 Projection =-0,098 ins Slight OvaliW due to Tubing Buckling Min. ID = Z.30 in Cross-Sections page '1 ~ [NC ppf 1-55 AB-Mod PDS Caliper Sections Surve~ Date; August 9, 2001 Tool Type: MFC24 No,9%28 Tool Size: 1,69" No, of Fingers: 24 Analysed: I, Burton cr0s~ Se~[ion for Joint 267 N6~i~ial iD ~ 2~44,1 ~1 arsa at depth 8179.53 fl Finger 23 Projection =-0.069 ins Slight ovallty due to Tubing Buckling Min, iD = 2.30 in. Cross-Sections page 2 PDS C~t_IPER JOINT TALLY SHEET Pipe: 2.875 ins 6.5 I~l~f J-55 AB-Mod Wa]] thickness. Body: 0J217ins Upset = 0.217ins Nominal ID: 2.441 ins Joint Depth Length Measured Type No. ID feet feet inches 263 8036.32 32.25 2.433 264 8068.57 31.45 2.428 264.1 8100.02 7.37 nominal GIm4 265 8107.39 33.21 2.447 266 8140.60 32.58 2.429 267 8173~18 30.78 2.433 268 8203.96 31.2 7 2.446 269 8235.23 33J04 2.448 270 8268.27 33.09 2.446 271 8301.36 31.67 nominal 272 8333.03 33.43 2.429 273 8366.46 32.40 2.452 274 8398.86 29.03 nominal __ 275 8427.89 32.36 2.424 276 8460.25 31.82 nominal 277 8492.07 32.38 2.438 278 8524.45 33.56 nominal 279 8558.01 31.04 2.438 279.1 8589.05 9.54 nominal G]m5 280 8598.59 30.45 nominal 280.1 8629.04 12.02 nominal PBR 280.2 8641.06 7.46 nominal PKR 281 8648.52 33.45 2.433 282 8681.97 31.56 2.436 282.1 8713.53 1.97 nominal 283 8715.50 unknown 2.433 Well: 30-18 Field: Kuparuk River Unit Company: PHILLIPS ALASKA, INC. Country: USA Date: August 9, 2001 Joint Depth Length Measured Tyl~e No. ID feet feet inches . ___ Joint Tally page 1 ARCO Oil and Gas Company Daily Well History-Final Report Inslructiona: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold, "Final Report" 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. Accounting cost center code District ICounty or Parish State ARCO ALASKA INC. I NORTH SLOPE AK Field Itease or Unit IWell no. KUPARUK RIVER UNIT I ADL: 25520 30-18 Auth. or W.O. no. ITitle AK3102 I COMPLETE API: 50-029-21793 Operator I AR.Co. W.I. ARCO I 56.0000 Spudded or W.O. begun ~Date ACCEPT J 06/11/88 06/12/88 ( TD: 9195 PB: 9088 SUPV:TA/KR 06/13/88 ( TD: 9195 PB: 9088 SUPV:TA/KR Date and depth as of 8:00 a.m. Complete record for each day reported NORDIC i I otal number of wells (active or inactive) on this est center prior to plugging and bandonrnent of this well our I Prior status if a W.O. I 0630 HRS TEST TUBING @ 2500 PSI 7"@ 9171' MW:10.0 NACL/NABR ACCEPTED RIG @ 0630 HRS, 6/11/88. TESTED BOPE TO 3000 PSI. RU SOS. PERF'D 'A' SAND F/8998'-9018' W/8 SPF, 45 DEGREE PHASING. RIH WITH COMPLETION ASSY. TESTED SSSV TO 5000 PSI. TESTED CSG HANGER TO 5000 PSI. LANDED TUBING & SET PACKER WITH 2500 PSI. TESTING TUBING. (PACKER @ 8676', SSSV @ 1788', TAIL @ 8750') DAILY:S121,080 CUM:$1,154,276 ETD:S1,154,276 EFC:$1,475,000 RIG RELEASED 7"@ 9171' MW: 6.9 DIESEL FINISHED TESTING TUBING TO 2500 PSI. SHEAR PBR. LANDED TUBING. TESTED ANN. TO 2500 PSI. TESTED SSSV TO 1000 PSI. SET BPV. ND BOPE. NU TREE AND TESTED TO 5000 PSI. DISPLACED W/315 BBLS DIESEL. PRESSURED TUBING AND CASING TO 500 PSI; SET BPV. SECURED WELL AND RELEASED RIG @ 1330 HRS, 6/12/88. DAILY:S44,143 CUM:$1,198,419 ETD:S1,198,419 EFC:$1,475,000 Old TD I New TD I PB Depth I I Released rig I Date IKind of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test 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 prepar~tJon and distribution, see Procedurestblanual, Section 10, Drilling, Pages 86 and 87. Date ITitle ASSOCIATE ENGINEER ADDENDUM WELL: 30-18 5/09/88 l~IJSchl. RnCEr f/7500'-2700' RD Schl. ~/7 O, ft. Pump incr. cio~, V.r~, 200 p~tg .... ' -'' / Full Ci~arg~- vres~u~e /,~?,~d: , ~-~ ~,.~ · -.~_ ~.~ . --- ~- . . . ' ~ ~ _-_q...~: ..... K~v ~d Floor Sofocy ~~o .... . .... .. _ -- _ .- -1- ---, orig. - AO&GCC 'cc- -'Opera;or cc - Supervi~or Alaska Oil & Gas Coos. commi~Sio~ Anchorage ' ARCO Alaska, Inc. Date: May 26, 1988 Transmittal #: 7168 RETURN TO: -- ARCO Alaska, Inc. Attn: Sabrina A. McKnuckles Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 H - 21 Cement Evaluation Log 4 - 2 0 - 8 8 4 6 0 0 - 1 I 1 9 8 ' 3 H - 1 8 Cement Evaluation Log 5 - 0 5 - 8 8 8 8 9 3 - 1 0 0 81 30-16A/ Cement Evaluation Log 5 - 0 9 - 8 8 90-8111 30-1 8j Cement Evaluation Log 5-09- 88 2690-751 5 3 O- 1 7 Cement Evaluation Log 5 - 0 9 - 8 8 2 4 9 0 - 7 9 6 8 3 H - 1 6 Cement Evaluation Log 5 - 2 1 - 8 8 7 7 9 5 - 9 61 4 If you have any questions, concerning this or any other transmittals please call me at 265-6835. .. Receipt Acknowledged' - .......................... Date' ~ ........... DISTRIBUTION: NSK illing [~ ! ~ D State ka (+sepia) ~r ' ~ Alaska 0il & Gas Cons. Commi~aion ~ Anchoraflo ARCO Alaska, Inc. Date: May 3, 1988 Transmittal #: 7154 RETURN TO: ARCO Alaska, Inc. Attn: Sabrina A. McKnuckles Kuparuk Records Clerk ' ATO-1119 . P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 30-1 7 OH Edit Tape and Usting OH Edit Tape and Listing 4-23-88 4-22-88 : · · #72673 MAYO 4 1988 ~as~a u, a ~as Cons. Comml~ If you have any questions concerning this or any other transmittals, please call me at 265-6835. Receipt Acknowledged- DISTRIBUTION: Lynn Goettinger Date- State of Alaska ARCO Alaska, Inc. Date: May 3, 1988 Transmittal #: 7156 RETURN TO: ARCO Alaska, Inc. Attn: Sabrina A. McKnuckles Kuparuk Records Clerk ATe-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please 'acknowledge receipt and return one signed copy of this transmittal. ~~ Cement Bond Log 4 - 1 9 - 8 8 - 6 9 9 5 9 0 5 9 3 H - 2 2 Cement Evaluation Log 4 - 2 4 - 8 8 7 9 6 2 - 9 9 6 4 Anchorage If you have any questions concerning this or any other transmittals, please call me at 265-6835. Receipt Acknowledged' DISTRIBUTION: NSK Drilling Date' State of Alaska(+sepia) !---, STATE OF ALASKA ALAS .... OIL AND GAS CONSERVATION COMI,,..SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown ;~] Re-enter suspended well [] Alter casing r--' Time extension ~ Change approved program [] Plugging [] stimulate [] Pull tubing [] Amend order ~ PerforateL_~- Other 2. Name of Operator ARCO Alaska~ Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1149' FNL, 2085' FWL, Sec.22, T13N, R9E, UM At top of productive interval 1320' FNL, 1192' FEL, Sec.27, T13N, R9E, UM At effective depth 1319' FNL, 1273' FEL, Sec.27, T13N, R9E, UM At total depth 1378' FNL, 1249' FEL, 5ec.27, T13N, R9E~ UN 11. Present well condition summary Total depth: measured true vertical 91 95 ' MD feet 6842 ' TVD feet (approx) (approx) (approx) Plugs(measured) 5. Datum elevation(DF or KB) RKB 59' 6. Uniter Property name Kuparuk River Unit 7. Wellnumber 30-18 8. Permit number 88-2R 9. APl number 50-- 029-21793 10. Pool Kuparuk River 0il Pool None Effective depth: measured true vertical Casing Length Conductor 80 ' Surface 2902' Producti on 91 38 ' 9088'MD 6757 ' TVD Size I 6" 9-5/8" 7 '! feet feet Junk (measured) None Cemented 175 sx AS I 900 sx AS II I 300 sx AS II 965 sx Class G Measured depth Rue Verticaldepth 1lO'MD 110'TVD 2937'MD 2379'TVD 9171'MD 6823'TVD Perforation depth: measured None true vertical No ne Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None 12.Attachments Well Hi story Description summary of proposal [] Detailed operations program [] BOP sketch 13. Estimated date for commencing operation May, 1 988 14. If proposal was verbally approved Name of approver Work B, eported on ' Date approved Approved by Date 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed 4 ~ _ _.c~_~L../ Title Associ ate Enqin~r Commission Use Only (Dani) SA3/80 -- Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOPTest [] Location clearanceI ~' Approved Copy ORIGINAL SIGNED BY Returned LONNIE C. SMITH by order of Commissioner the commission Date feet Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Oil and Gas Company Daily Well' History- Final Report Instructions: Prepare and submit the ',Final Rel~ert" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when oDeratlon8 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 Accountlng cost center code District I statL ARCO Alaska, Inc. I County or Parish NORTH SLOPE J Lease or Unit KUPARUK RIVER UNIT ~ ADL: 25520 30-18 Title DRILL no. Field Auth. or W.O. no. ~;~3102 Operator ARCO I A.R.Co. Spudded or W.O. begun IDate I SPUD Date and depth Complete record for each day reported as of 8:00 a.m. API: 50-029-21793 W.t. rTotal number of wells (active or inactive) on this Icost center prior to plugging and 56. 0000 Jabandonment of this well i I Hour I Prlor status if a W.O, 03/24/88 J 1300 04/02/88 ( 1 TD: 9195'( SUPV:JP DOYON 14 Old TD New TD Released rig Date Classifications (oil, gas, etc.) Producing method Potential test data RIG RELEASED 7"@ 9171' MW:10.0 VIS: FINISHED POOH; LDDP & BHA. RAN 7", 269, J-55, BTC CASING WITH SHOE @ 9171'. CMTD CASING WITH 550 SX TLW & 415 SX CLASS G. BUMPED PLUG TO 3500 PSI. CIP @ 2300 HRS, 4/1/88. ND BOPE. INSTALLED TUBINGHEAD & TESTED FLANGE TO 3000 PSI. SECURED WELL & RELEASED RIG @ 0600 HRS, 4/2/88. DAILY:S247,128 CUM:$1,033,196 ETD:S1,033,196 EFC:$1,475,000 PB Oepth K nd of rg IType completion (single, dual, etc.) Official reservoir name(s) Well no. Date Reservoir Producing Interval Oil or ga~Test time Production OII on te~t Gas per ~a~," · Pump size, SPM X length . Choke size T.P. C.P. Water % GOR Gravity Allowable Effeclive a,,~- corrected .. _. The above is correct For form preparation ~{'~ distribution, see Procedures Manu/~l/Section 10, Drilling. Pages 86 and~87. AR3B-459-3-C INumber all daily well history forms consecutively as they are prepared for each well. Dlvl*do~ of Atlantk:R~:f~tee~r.~y ARCO Oil a~,_ Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently then every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish Istate NORTH SLOPE AK Lease or Unit 30-18 Field ARCO Alaska, Inc. KUPARUK RIVER UNIT JWell no. Date and depth as of 8:00 a.m. 04/01/88 ( TD: 9195'( SUPV:JP Complete record for each day while drilling or workover in progress DOYON 14 9) 54) LDDP 9-5/8"@ 2937' MW: 9.8 VIS: 52 CUT DRILL LINE. FINISHED TIH. REAMED F/8500'-9100' REPLACED OIL PUMP ON ROTARY CHAIN. REAMED F/9100'-9141' DRILLED TO 9163'. REPAIRED OIL PUMP ON ROTARY CHAIN. CONTINUED DRILLING TO 9195'(TD). CIRCULATE BOTTOMS UP. REAMED TO 9195'. CIRCULATE HOLE CLEAN AND SPOTTED DIESEL PILL. POOH, LDDP. DAILY:S46,401 CUM:$786,068 ETD:S786,068 EFC:$1,475,000 The above is correct For form preparation and ~l~tribution see Procedures Manual Seq~ion Drilling, Pages 86 and 87~J JDate JTitle Af:~OCiATE AR3B-459-2-B Number all daily well history forms consecutively as Ihey are prepared for each we I. - Daily~ i Inlin{¢liolt~; Prepare and submit the "lnll~l R~lf' on the first Wednesday after · well is spudded or workover operations Ire Daily wort; pr{or to sP~ddlng~,_~hould be summarized on the form giving inclusive dates only. .. . District ARCO Alaska, Inc. Field KUPARUK RIVER UNIT JCounty. parish or borough NORTH SLOPE Lease or Unit ADL: 25520 Title DRILL [Stat~%K IWell no. 30-18 Auth. or W.O. no. AK3102 API: 50-029-21793 Operator ARCO SDudded or W,O. begun SPUD Date and depth as of 8:00 a,m. 03/24/88 ( TD: 110'( SUPV:RB 03/25/88 ( TD: 1980' ( 1 SUPV:RB 03/26/88 ( TD: 2963'( SUPV:RB 03/27/88 ( TD: 4660'( 1 SUPV:RB 03/28/88 ( TD: 7159'( 2~ SUPV:RB 03/29/88 ( TD: 9075'( 1 SUPV:RB 03/30/88 ( TD: 9141'( SUPV:RB 03/31/88 ( TD: 9141'( SUPV:JP IDate 03/24/88 IHOur Complete record for each day reported DOYON 14 1300 IARCO w.i. 56.0000 Prior status if a W,O. .) .lO) :) ',70) ,) '83) ) 97) ) 99) ) 16) ) 66) ) o) STRAPPING BHA 16" @ 110' MOVE RIG TO 30-16. ACCEPT RIG AT 0230 HRS 3/24/88. NU 20" DIVERTER AND LINES. STRAPPING BHA. DAILY:S129,541 CUM:$129,541 ETD:S129,541 EFC:$1,475,000 DRLG AT 1980' 16" @ 110' MW: 8.7 VIS: 58 SPUD AT 1300 HRS 3/24/88. MU BHA. RIH. DRLD 12-1/4" HOLE TO 1980' DAILY:S47,257 CUM:$176,798 ETD:S176,798 EFC:$1,475,000 ND DIVERTER 9-5/8"@ 2937' MW: 9.1 VIS: 45 NAVIDRILL 12-1/4" HOLE TO 2963'. RUN 74 JTS OF 36~ J-55 BTC 9- 5/8" SURFACE CASING. FC @ 2857'. FS @ 2937'. CEMENT WITH 900 SX OF 12.~ PPG AS III LEAD, FOLLOWED BY 300 SX OF 15.2 PPG AS II TAIL. CIP @ 0400 HRS 3/26/88. DAILY:S159,782 CUM:$336,580 ETD:S336,580 EFC:$1,475,000 DRILLING @ 4660' 9-5/8"@ 2937' MW: 8.7 VIS: 30 NU AND TEST BOPE. DRILL OUT FLOAT EQUIPMENT. PERFORM LOT TO 10.3 EMW. TURBODRILL 8-1/2" HOLE TO 4660'. DAILY:S42,788 CUM:$379,368 ETD:S379,368 EFC:$1,475,000 DRILLING @ 7159' 9-5/8"@ 2937' MW: 9.4 VIS: 46 TURBODRILL 8-1/2" HOLE TO 7159'. DAILY:S47,857 CUM:$427,225 ETD:S427,225 EFC:$1,475,000 DRILLING @ 9075' 9-5/8"@ 2937' MW: 9.9 VIS: 44 TURBODRILL 8-1/2" HOLE TO 9075'. DAILY:S87,866 CUM:$515,091 ETD:S515,091 EFC:$1,475,000 RD SOS LOGGERS 9-5/8"@ 2937' MW:10.0 VIS: 48 DRILLED 8-1/2" HOLE TO 9141'. SHORT TRIP FROM BOTTOM OF HOLE TO THE 9-5/8" SHOE. CIRCULATE & CONDITION MUD. DROPPED SINGLE SHOT SURVEY & SPOTTED DIESEL PILL. POOH 10 STDS. POOH & LD BHA. RU SOS LOGGING. RAN DIL/SFL/GR/SP FROM 9141'-2937', FDC/CNL FROM 9141'-2937', CAL FROM 9141'-2937'. RD SOS LOGGING. DAILY:S65,542 CUM:$580,633 ETD:S580,633 EFC:$1,475,000 TIH TO CASING SHOE 9-5/8"@ 2937' MW: 9.8 VIS: 42 TIH TO 8390'; STUCK PIPE. WASHED AND REAMED F/8390'-8489' TIH TO 9027'; STUCK PIPE. WORKED AND JARRED PIPE; PIPE CAME FREE. POOH. CHANGED OUT JARS. TIH TO CASING SHOE. DAILY:S159,034 CUM:$739,667 ETD:S739,667 EFC:$1,475,000 The above is correct For form preparation ~/J distribution, see Procedures Manu~l,/ Section 10. Drilling, Pages 86 and.,67. jDate Title 4-~-(~,~ I A880CIATE ENGINEER AR3B-459-1-D JNumber all daily well histor7 forms consecutively as they are prepared for each well. ARCO Alaska, Inc. Date: Apdl 8, 1988 Transmittal#: 7138 RETURN TO: ARCO Alaska, Inc. Attn: Sabrina A. McKnuckles Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. i_. 2" & 5" Porosity FDC. 3 - 2 9 - 8 8 2 93 2 - 91 0 7 5" Dual Induction 3-29-88 2932-91 32 2" Dual Induction 3 - 2 9 - 8 8 2 9 3 2 - 91 3 2 2" & 5" Raw FDC 3-29-88 2932-91 07 Oil & Gas Cons, Oommissio,~ Anchora§e Receipt Acknowledged: DISTRIBUTION: Drilling Franzen Date: D&M State of Alaska(+sepia) L. Johnston (vendor package) ., March 23, 1988 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 ~mchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: 'Kuparuk River Unit 30-18 ARCO Alaska, Inc. Permit No. 88-26 Sur. Loc. l149'FN, L, 2085'FWL, Sec. 22, T13N, R9E, UM. Btmhole Loc. 1511'FNL, I122'FEL, Sec. 27, T13N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. ~. truly v~rs, Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COI'~fISSION dlf' Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o enc!. STATE OF ALASKA ' ALASKA ,.~IL AND GAS CONSERVATION C_ ,vIMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill t~, Redrill FII lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone ~ Multiple Zone IJ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool iARCO Alaska, Inc. RKB 59', PAD 24' feet Kuparuk River Field Kuparuk River Oil Pool 3. Address 6. Property Designation P.O. Box 100360, Anchorage, AK 99510-0360 ADL 25520 ALK 2556 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1149'FNL, 2085'FWL, Sec.22, T13N, RgE, UM Kuparuk River Unit Statewide At top of productive interval (~ target) 8. Well nu.mber Number 1320'FNL, 1192'FEL, Sec.27, T13N, RgE, UM 30-18 #8088-26-27 At total depth 9. Approximate spud date Amount 1511'FNL, 1122'FEL, 5ec.27, T13N, RgE, UM 03/25/88 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property l~.3ProDosed depth (MD and TVD) property line 30-1 7 (conductor) 45 'MD 1122'~ TD feet 25' 8 Surface feet 2560 (6867'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth 300 feet Maximum hole angle 46 0 Maximum surface 1 140 psig At total depth (TVD) 3066 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' +200 cf 12-1/4" 9-5/8" 36.0# J-55 BTC 2587' 35' 35' 2622' 2219' 900 sx AS I I I & HF-ERW 300 sx AS II 8-1/2" 7" 26.0# J-55 BTC 9311' 3/+' 34' 9345' 6867' 450 sx TLW lead & HF-ERW 200 sx Class G tail 19. To be completed for Redrill, Re-entry, and Deepen Operations. Tuc 50t)' above .UGNU Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ~..E~E ~V ~ C ond u ctor i!~,~ !~ :,;:~,. }i!i!!~ ! ~!i' }7!!i Surface Ct~/':,,~,-~ 2' '; ':.i.,.... Intermediate ' ;!'~::;i!, ;:*:. :,,:i Production Alaska Oi~ & Gas Con Perforation depth: measured true vertical M0~, SO--i¢ i,~. 'J~bc "'~'' 20. Attachments Filing fee 1~ Property plat [] BOP Sketch [] Diverter Sketch ~ Drilling program Drilling fluid,pr,-o~am ~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21. I hereby/certify/ that the ,/f~ g~_,pEls true and correct to the best of my knowledge Signed(? //~~/.~/,3~ ~,~¢¢/~.//'4/~/ Title Regional Engineer Dat / Drillingy ~ ~ / ~ Oo ,ss,on seO l , Permit Nd'mber / I APl number I Approval d (TEM I See cover letter ~'-26J 50- c, a9 - ~17%~, I 03/23/88 J for other requirements Conditions of approval Samples required [] Yes ~ No Mud Icg required [] Yes ~No Hydrogen sulfide m~sures [] Yes g No Directional survey required [] Yes [] No Required work. j,~t~'~pre~sur~~~2M~ ~iJc, SM; []SM; [] 10M; [] 15M Other: ( ///~// f~~~.~~ by order of Approved by ~..., ' "'/' ,~ '~d'~~ Commissioner the commission Dat Form 10-401 Rev. 12-1-85 Submit i~f ;ate GENERAL DRILLING PROCEDU~. KUPARUK RIVER FIELD DEVELOPHENT WELLS 1. Move in rig. 2. Install FHC diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test, casing to 2000 psig. 6, Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8¥' hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. 10. Run and cement 7" casing. Pressure test to 3500 psis. 11. Dovnsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12, Nipple down blow out preventer and install temporar~ XAse tree. 13. Secure well and release 14. Eun cased hole loss. 15. Hove in workover res. Nipple up blow out preventer, 16. Pick up 7" casing scraper and tubing, trip in hole to plus back total depth. Circulate hole with clean brine and trip out of hole tubing back. 17, Perforate and run completion assembly, set and test packer. I8, Nipple dovublow out preventer and install Xmas tree. .19. Change over t° diesel. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate. SHALE _ SHAKERS MUD ~_~ CLEANER ST~T STIR '-~ ~ STIR MUD [ [CENTRIFUO CLEANER I f L~4/ih TYPICAL MUD SYSTEM SCHEMATIC Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 Weight Up to TD 10.3 PV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 12.0 ppg EMW and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. LWK5 / ih In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack ~upon completion disposal. of the fluid .......... K. up~_:~'u_k_'.F!_e:!~_d_,.i_Nor'_t h_. S I!o p e. A I ·eik e. · I : . · . KOP'~ TVD'300. THO'300 DEP'O : 18 ~ BUELD 3 ....... %~'i~0'0-'-:-Tvo-1680 THO' 1 842 DEP'S.~g '-' B/ PERMAFROST TVD"1719 THD 1.899 DEP'630 C S~ PT 9 5/8" TV, = 2219 TMD=2622 DEP:1T53 'stores i:VO; 2eeg. ' 1~1D~33 iie ...... anon_ ; ' : ............................ , ........... - . ~. ~ I ' T/ W SAK SNDS~ TVD-3474;T~-4437 ~P"2464 ' ~ K-12 TVD.387g' THD=5023 OEP=2888 ~ AVERAGE ANGLE ........ ~ 46 DEO 16 ~IN _ . ~ . : K-5 TVD"SZgg~ THD-Z800 DEP'4894 T/ ZONE~ D TVD-6434 THD-8718 DEP-5558 : T/ ZONE~ C TVD-6526 THB-8851 DEP-5.654 ............................. ; ....... T/[.~E~ A-. TVD-661Z T~-8g~ DEP-5~4g TARGET CNTR : TVD-6673TMD-g064 DEP 5807 , B/~ KUP SNDS ~ TVD-6729 THD=g145 OEP-5866 ' ........... ~000 TD[ (LO0~ PI) TVD-6867 1~D-9545 DEP-6010 , , ~ , ~ 1000- ~ ~000 $000 ~000 ~000 8000 ............... , ............................. ~ ................. ~ VERTICAL SECTION- · : 7001 HOR"-":0~N:TAL ..... ~RO JEC T.I.0 N IN. = 1000 FEET ~cO ^L^SK^. Pad 30, Well No" 18 Pr'ol)o~ed Kupar'uk FI · I a, Nor-t:h SI ope, Al a~ka 1 000 0 2000 WEST-EAST 1000 I u~ S 20 DEG s , 5807' (TO CENTER TVD-(r~Z3 Ti"lO-90~4 D~P-5807 SOUTH ,~1.51 3000 I 11 MINE TARGET) TARGET LOCAT[ONt 132.,,0' FNL. 1193' FEL ~'C. 27. TI3N. R~: TD LOCATION, 1511' FNL. 1122' FEL ~.. az.. ~,],~. no(: .KUPARUK RIVER UNIT 20' DIVERTER SCHEHATIC L DESCRIPTION 1, 16" CONDUCTOR 2. FHC SLIP-ON WELD STARTIN6 HEAl:) 3. FHC OlVERTER ASSEHBLY WITH TWO 2-I/16' 2000 PSI BALL VALVES 4. 20' 2000 PSI DRILLII~ ~ ~//10' OUTLEI~ 5. 10" HCR BALL VALVES ~//10" DIVERTER LINES, A SINeI. E VALVE ~ AUTOI~TICALLY UPON CL~ OF ANIe, JU~. I:~EVENll~. VALVES CAN REHOTELY CONTROLL~ TO ACHIEVE DIVERSION. 6. 20' 2000 PSI ANNULAR PREVENTER 4 ARCO ALASKA, INC., REQUESTS API~OVkL OF THIS DIVERTER SYSTEH AS A VARIANCE FROH 20AAC25.035(b) I"IAtNTENANCE & OPERATION 3 UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE D~NWlND DIVERSION, 2 O0 NOT SHUT IN WELL UNDER ANY C:IRCUHSTANCES 7 6 A~T(~ CAPACITY TEST I. CI.~ AI~ FILL A(33,M.I.ATCR I~~IR TO ~ LEVEL WITH ~IC FLUID, 2. ~ THaT AC~TIlR I1~ I~ ~ P~I WITH 15130 PSI CX3~'~TI~.~ CF TI~ I~gJ.ATCR. ~ TIbE., TI~N ~ ~ ~ SIXThlY I5 45 ~~ ~I~ TI~ ~ I~ ~I ~I~ 5 STACK' TE I', I. FILL ~ STAC~ ~ CI4:KE NIINIFCLD Wi'T1,4 DIE$~L. 2. C~CK THAT ~LL LCIiX ~ ~ IN V"~I.~ F'LLLY I~~E~ SEAT T[$T PLUG IN IAELLI-F..AO V~TH I:~l~ll~ JT At4) ~ IN LIIXiX[XII~ 3. CLCISE ~ I~'VENTI~ ~ MM~JAI. KILL A/~ LZhE VALVES ADJ~ TO B(~ STACK. ALL VALVE5 AI~ ~ ~ BE ~ 4. PI~LRE UP TO 250 PSZ MN) HOLD FOR I0 MIN. I~- ~ PRE59..RE TO 34:X30 I~! A/~ I-CLD FOR )0 Rm ~ED PRE~9..RE TO 0 1~3~. LZh~ V~4.VES. CLCIS~ TCP PII:~ PJU~ ~ ~ VALvF. S CN KILL AI~ O-ICI<E LZI~ES. 'r'EsT TO 250 1~31At~ ~CIC)O F,3] A~ ZN S'TE:p 4. 7.CO~II~LE I'E:STIkG ALL VALVES,, LXI'~.S. ~ Wl l'H A 250 P"J! LOW AI~ ~ I~! HIGH. TL~T 8o'r'rO~ ~I1~ ~ ?0 ~ I~! ~ ~ 1::,'5I. II. Clan BLII~ R.lh45 ~ RL~'~ZEV~ TE~T ~ MAK~ MI~FGI. D AN3 L]:I~S AI~ FLI. L CF NI~N-FREL~:rNG FLU[D. SET ALL VALVF~ IN I~]:LLING 12. TEST STNd3::~]:PE VALVE~ idyll yo KELLY ~ PIPE SAFETY VALVE. AN3 I1~]:1~: BC~ TO 250 P~! FC]RI~ SIGI~ ~ SE:]~ TO CR:]:LL1:NG 14. PE~CRN ~ Ba~ TEST AFTE~ NIPPL:II~ uP V~:E:KLY TI~AFTER F~ICNALLY ~TE ~ APR-18-'90 10:2~ TEL NO:DO?-~65-~Zi~ NOTES I, AU. COORDINATES ARE A,$.P., ZONE 4. ~.. ALL DISTANCES ~NOWN ARE TRUE, 3. E]..EVATION$ ARE: 4, REFER. FIELD BOOK L-68-~ ~5-~S. 5. O.G. ELEVATIONS FROM CED- RIXX- $365 ,& ~,, HORIZONTAL I",O$1TION BASED ON ~ CONTROL MONUMENTS ~ I. DUN~SURY & ...................O ST. DIST. .... -P D Well ¥ ASPs X LATITUDE LONGITUDE: F, NL /;, ~/L ..... i. i LI iii_ I 6,0;~ ;~,095. Z7 525,478. Z7 700~8' 17.338'° 1490 47'30.897'' 724" 1842' 17.5' 23.9' 2 6,022. ,073. 89 $~$ ,490.94 7002.9. 17.128 "' 149o 47 '$0.5~,6" 745' 1555'I ~ $ 6,0Z:~,052. I$ 525,505.67 70028', 16915". - t49°47'~00 , . I~",, 76Y 1~67' 17'7'?.9 4 6,02~,030.~ 5~5,515.5a ~28, I~ 149 47 Z98~ TS~ ~aTS~ ~e,O: 7~Z6, ! 49047', 29:4~,~ 811, ? 6~021 ~965,~ 5~5~53,~ , ~9 14~47 28,~. 8~; 1917, 18.2. 9 6,0~ 1 t~Z~, IZ 5~ ,578.Z7 t5.63Z 149 47 27.974 89~ 1941 18.4 23.2 I0 6~OZ I ~84~ ~ 525 ~6~3.6~ ~28' 14.~3" 149047'26.6~" 975' 1956' 18.~' ~35' I I 6,0~1,822. ~ 525 ~635~7t ~' '14.651" 149° 47'~6.~" ~Z' t998' 18.8' ~312 6,02~6'02 ,8~. 8716 525525 ;648. ~,66i .~7~28', 14, 4~7" 149° 47', ~. 9~ % 10~9' 20Ii' 10.8', ,779. ~o~ J4, 223'" 149°47,25.~, 104t~ 20Z4', 18.~, 23.0, ' 149047,25,~. t0~ 20~, 19. U, 15 6,021,735.76 $Z$,~6. IZ ~3.~5 149°4724.~, I0~ 2046, 19.0, 17 6,0ZI ~69~ 5Z5 +710.85 ~' J3.~6~" 149°47'Z4.0~ I tZ~ 2073 19.0' t8 6,0~ 1,670.97 525,7~.~ ~29' i3. t57" 149047'~3,733' 1149' 2085' 19.0' 23.3' i · , ,, ~ · j, i ...... I HEREBY CF-qTIlry TI"I~T I AM PROPERLY REGISTERED AND ~,C~:NSED TO ~ TICE LAND SURVI~i'ING IN THE · I'AT~, OF ALA,,'g<A AND THAT THIS PI. AT R;' PRESENT$ A .LOCATION SURVEY MAD~ BY ME OR UNDER. MY SUPERVISION, AND THAT AI.L DIMENSION3 ANO OTI,IF.R ARE CORRECT A~, Olt ~.,/~/88. D.S. 3.0 . WELL coNDUCTOR AS:BUILT LOUNSBURY socio[ ANCHORAGE ................. :: :._, ~A _ CHECK LIST FOR NEW WELL PERMITS Company ~ I~ C O ITEM APPROVE DATE YES (1) Fee fj{._~ ~/~1~5. 1. Is the permit fee attached .......................................... d~ (2 thru 8) (9 thru 13) 10. (10 and 13) 12. 13. (4) Cas g ~/~.~.~f. 3- ~2- f~' (14 thru 22) (5) BOPE (23 thru 28) 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 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 wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... Lease & Well No. ~ ~ ~O-l~ NO REMARKS 14. 15. 16. 17. 18. 19. 20. 21. 22. Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ Does the well have a unique name and number ......................... ~ 23. 24. 25. 26. 27. 28. Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... 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 all casing 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 wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate/f~,. Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to 3Oo~ psig .. ,,~ Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. I (29 thru 31) For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ................. 30. Are seismic analysis data presented on shallow gas zones ............ / 31. If an offshore loc., are survey results of seabed conditions present/~ 32. Additional requirements ............................................. .. O ~Z mm Geolqgy: Eng~ering: ww~ 5R LCS ~5'BEW /" rev: 02/17/88 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ,~.?o.~oo i.pLc-v -t OiL ~?o /{ 16o ©~ Additional Remarks: