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180-050
Originated: Delivered to:12-Nov-25HalliburtonAlaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun333 West 7th Avenue, Suite 1006900 Arctic Blvd.Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1D-30 50-029-22965-00 910358412 Kuparuk River Leak Detect Log Field- Final 14-Oct-25 0 12 1D-30 50-029-22965-00 910358412 Kuparuk River Multi Finger Caliper Field & Processed 15-Oct-25 0 13 1D-30 50-029-22965-00 910390851 Kuparuk River Packer Setting Record Field- Final 31-Oct-25 0 14 1E-02 50-029-20472-00 910390619 Kuparuk RiverMulti Finger CaliperField & Processed 28-Oct-25 0 15 1E-36 50-029-22927-00 910357198 Kuparuk River Tubing Cut Record Field- Final 19-Oct-25 0 16 2U-06 50-029-21282-00 910390614 Kuparuk River Multi Finger Caliper Field & Processed 19-Oct-25 0 17 3K-20 50-029-23019-00 910390195 Kuparuk River Packer Setting Record Field- Final 22-Oct-25 0 18 3R-17 50-029-22242-00 910433126 Kuparuk River Packer Setting Record Field- Final 11-Nov-25 0 1910PLEASE 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 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:200-104180-050198-213185-019201-088192-005T41088T41088T41088T41089T41090T41091T41092T41093Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.11.12 11:46:38 -09'00'180-0501E-0250-029-20472-00 910390619Kuparuk RiverMulti Finger CaliperField & Processed28-Oct-2501 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: 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 8440'feet N/A feet true vertical 6514'feet 8200', 8206'feet Effective Depth measured 8222'feet 7700', 7789', 8081'feet true vertical 6316'feet 5849', 5926', 6188'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" 3-1/2" L-80 J-55 7755' 7750' 5897' 8112' Packers and SSSV (type, measured and true vertical depth)7700' 7789' 8081' N/A 5849' 5926' 6188' N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 3051' 2702' Burst Collapse Production 8389' Casing 6497'8421' 3019' 80'Conductor Surface 16" 10-3/4" 46' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 180-050 50-029-20472-00-00 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: ADL0025651 Kuparuk River Field/ Kuparuk Oil Pool KRU 1E-02 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 215 Gas-Mcf MD 600 Size 80' 6653 12501879 0 7000 240 323-170 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Blue Packer RH Max Baker FHL Baker FB-1 SSSV: N/A Jonathan Coberly jonathan.coberly@conocophillips.com (907) 265-1013Staff RWO/CTD Engineer 7959-8050', 8182-8204', 8219-8234' 6078-6160', 6280'-6300', 6313-6327' Development Service GINJ SUSP SPLUG Gas 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 11:31 am, Jun 22, 2023 Page 1/8 1E-02 Report Printed: 6/20/2023 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) 5/16/2023 00:00 5/16/2023 03:00 3.00 MIRU, MOVE MOB P Remove PolyDike containment berm system from around the rig. Clean up mats, elevate rig stairs and landings, back rig off mats outside of containment berm. Remove rig mats from pit liner. Move pit 50' x 100' pit liner to 1E-02 and place rig mats. Called Pad Op to witness. Spot rig over 1E-02. 5/16/2023 03:00 5/16/2023 09:00 6.00 MIRU, MOVE RURD P Level rig over well. Begin rig acceptance check list. Measure distance from rig floor to upper LDS's (Nordic 3 RKB). Build containment for cuttings box. Spot cuttings box and align auger chute. Spot choke skid. RU hardline from rig downcomer to choke skid. Pull BPV. Ensure gauges are clear and gather initial T/I/O pressures. T/I/O = BPV / 600 psi / 0 psi. Load 10.2# kill weight brine into pits. Accept rig @ 09:00. 5/16/2023 09:00 5/16/2023 16:00 7.00 MIRU, WELCTL OTHR P RU choke and kill lines to cellar circ manifold w/ 2" HP hose. RU Tee's and gauges to T and IA in cellar. PJSM, w/FMC. R/U BPV lubricator. to pull BPV. PT to 1500 PSI. Pull BPV. Unstab Lubricator. No BPV. M/U lubricator on well. PT to 1500 PSI. Pull BPV. Unstab lubricator with BPV. T=850 PSI, IA=760 PSI, OA=0 5/16/2023 16:00 5/16/2023 18:00 2.00 MIRU, WELCTL PRTS P PJSM for well kill. Trace all lines / flow path. Blow air through system to tanks to confirm flow path for well kill. Send 10 BBls to TT line to fluid pack. Shut line. PT to 2500 PSI. Nordic crew change out. PJSM. Identified leaking hardline on choke skid. Red tagged and isolation. Re-tested. Passed. 5/16/2023 18:00 5/16/2023 22:00 4.00 MIRU, WELCTL KLWL P Bring pumps online at 1 BPM and stage up to kill rate of 4 BPM. Pumped 20 bbls of DeepClean pill followed by 400 bbls of 10.2# NaCl/Nabr down Tubing taking returns from the IA. Held +/- 800 psi backpressure during kill to prevent influx limiting downstream choke pressure to 100-150 psi. Held 1:1 returns or slightly less at tank during kill. 1502 Swing began weeping. Swapped to 2nd tank to isolate leaking swing, At 380 bbls away measured 10.2# NaCl/NaBr returns. Staged pumps down from 4 BPM to 1 BPM. Shut down pumps and shut in choke. 1502 Swing began weeping. Swapped to 2nd tank to isolate leaky swing, 5/16/2023 22:00 5/17/2023 00:00 2.00 MIRU, WELCTL OWFF P Blow down lines to tanks. RD Kill and Choke hoses. Observe well for flow on both Tubing and IA side. Monitor for 30 minutes through whitey valves at tree with bucket. 5/17/2023 00:00 5/17/2023 00:30 0.50 MIRU, WELCTL MPSP P RU T-Bar and Install BPV. 0.0 0.0 5/17/2023 00:30 5/17/2023 01:00 0.50 MIRU, WELCTL PRTS P Perform rolling 1,000 psi BPV test from below. Monitor opening whitey on tubing to check for BPV leak. Passed. Blowdown lines. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 5/26/2023 Page 2/8 1E-02 Report Printed: 6/20/2023 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) 5/17/2023 01:00 5/17/2023 06:00 5.00 MIRU, WHDBOP NUND P Clean up cellar area. Hang hoses out of the way. Build floorkit above conductor to improve footing during NU/ND operations. FMC on location to assist with N/D of 3 1/8" tree and tubing head adapter. N/D tree. FMC verified hanger neck threads in decent condition and hanger threads are stamped Buttress. Lift old tree out of cellar. MU IBTM blanking plug into 3 1/2" hanger neck threads. Counted 9.25 turns. PU test joint and counted 10.25 turns to MU LH thread box to blanking plug pin. Measured distance from rig floor to blanking plug threads. 0.0 0.0 5/17/2023 06:00 5/17/2023 18:00 12.00 MIRU, WHDBOP NUND P N/U 7 1/6" x 13 5/8" DSA. N/U BOPs. Torque DSA and BOP flanges. Attempt to insall flow riser/bell nipple. Found bell nipple was 1' short. Previously cut and welded to accomodate the new test spool on bottom of BOP stack. Welder on location to cut/fit/re-weld bell nipple and riser to work with new BOP stack height. Install choke and kill lines. Load 3.5" Drill Pipe on Driller side elevators and process. Begin installing accumulator hoses. 0.0 0.0 5/17/2023 18:00 5/17/2023 20:00 2.00 MIRU, WHDBOP RURD P Repair cantilever overhead winch. Continue bell nipple welding to lengthen by approx. 1'. Load 3 1/2" IBTM landing joint into pipe shed. Receive Yellow Jacker Fishing tools and FOSV's. 0.0 0.0 5/17/2023 20:00 5/18/2023 00:00 4.00 MIRU, WHDBOP RURD P Complete bell nipple modification. Install new bell nipple. Fill stack and surface lines with fresh water. Purge air from system. 0.0 0.0 5/18/2023 00:00 5/18/2023 04:00 4.00 MIRU, WHDBOP BOPE T Perform initial shell test to confirm system has been purged and valves/lines are holding. Initial test failed. Purge air from system and re- test. Crew walking lines and monitoring BOP and valves for leaks. Rig electrician repaired remote choke panel. 5/18/2023 04:00 5/18/2023 12:00 8.00 MIRU, WHDBOP BOPE T Continue to troubleshoot failing BOP shell test. Closed pipe rams to isolate blanking plug from test. Leak signature did not change. Blanking plug likely not the culprit. Greased suspect valves on choke manifold, mud manifold, annular, and dart valve. Tests improved but a slow leak remains. 5/18/2023 12:00 5/18/2023 14:00 2.00 MIRU, WHDBOP BOPE T Got a passing BOP shell test but the 4 way koomey valve is bad. Pulled and replaced the Koomey valve. Called Guy Cook to witness BOPE test at 12:06. Rig: NORDIC 3 RIG RELEASE DATE 5/26/2023 Page 3/8 1E-02 Report Printed: 6/20/2023 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) 5/18/2023 14:00 5/18/2023 18:00 4.00 MIRU, WHDBOP BOPE P Started BOPE test. Test #1: UPR, MM Kill, CM#4, #11, #12, Upper IBOP, BOP Aux. #2, FOSV, ISBOP. Failed. Use TIW valve to isolate ISBOP, TIW valve failed. Test #2: CM #3, #7, #9, #10, Kill HCR, Lower IBOP, BOP Aux #1. Test #3: CM #2, #5, #8, Manual Kill. Test #4: CM #6, Swap test hose to test joint. Test #5: CM #1. Test #6: CM #13. Pressure loss on chart. Determined manual kill was leaking. Called out Yellow Jacket 3 1/2" dart valve from Deadhorse to replace/re-test. Yellow Jacket 3 1/2" dart valve failed @ 20:00. Called Kevin Walker @ PESI to arrange for a 3 1/2" IF dart valve to be pressure tested and shipped out. 5/18/2023 18:00 5/19/2023 00:00 6.00 MIRU, WHDBOP BOPE T Continued BOP testing while waiting on PESI 3 1/2" dart valve from Deadhorse. Upper pipe rams failed. C/O upper pipe rames while waiting on dart valve. FMC pulled blanking plug. Looked clean. Redressed and re-set. PESI 3 1/2" IF dart valve and TIW arrived on location. 5/19/2023 00:00 5/19/2023 04:00 4.00 MIRU, WHDBOP BOPE P PESI 3 1/2" IF valves arrived on location. Continue BOP testing. Tested PESI 3 1/2" IF dart valve. Passed. Tested Upper Pipe rams after re-dress. Passed. Attempt to test annular. Failed. Bumped up pressure from 1,100 psi to 1,200 psi. Failed. Cycled annular to re- test. Koomey unit air pumps having issues. Made repairs. Re-tested annular. Passed. 5/19/2023 04:00 5/19/2023 06:00 2.00 MIRU, WHDBOP BOPE P Finished BOP test at 06:00 with 7 fail/passes total. Annular fail function retest pass,UPR fail replace retest pass,Manual kill fail service retest pass,floor ball valve fail replace retest pass,Dart valve fail X2, Replace retest pass, ACC Misc fail mufflers on air pumps plugged removed mufflers X3, retest pass. Mufflers to be replaced in approx. 10 days. BOP Misc 13 5/8" test spool with 2 2.125 5000psi valves, CH Misc 3" Demco 5000psi valve 5/19/2023 06:00 5/19/2023 09:00 3.00 MIRU, WHDBOP PULD P LD test joint and blanking plug. Pulled BPV. Made up landing joint. Set down 10K and backed out LDS. Pulled 90K to unseat tubing hanger. 5/19/2023 09:00 5/19/2023 12:00 3.00 MIRU, WHDBOP CIRC P Close Upper pipe rams. Circulate bottoms up at 4 BPM 350 PSI 5/19/2023 12:00 5/19/2023 12:30 0.50 MIRU, WHDBOP OWFF P Perform 30 min no flow test - Good 5/19/2023 12:30 5/19/2023 14:30 2.00 COMPZN, RPCOMP PULL T Pick up on tubing to max pick up. Not moving. Hook back up to service loop. Work pipe while pumping. No go. Consult town, Plan forward to perform second cut 5/19/2023 14:30 5/19/2023 18:30 4.00 COMPZN, RPCOMP PULL T Work pipe while waiting on E-line unit Rig: NORDIC 3 RIG RELEASE DATE 5/26/2023 Page 4/8 1E-02 Report Printed: 6/20/2023 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) 5/19/2023 18:30 5/19/2023 20:00 1.50 COMPZN, RPCOMP RURD T E-line on location. Spot units. Load Welltec cutter and E-line toolstring to rig floor. Wait for 3 1/2" IBT pup joints to arrive. M/U IBT pup joints and pull tubing into tension (72K string weight + 36K block weight, 108K total), COP X- over from IBT to EUE, PESI 3 1/2" EUE FOSV, COP X-over 3 1/2" EUE to 2 7/8" EUE, 2 7/8" Yellow Jacket pump-in sub. 5/19/2023 20:00 5/19/2023 20:15 0.25 COMPZN, RPCOMP SFTY T PJSM w/ Yellow Jacket E-line crew, Welltec crew, and Nordic crew. 5/19/2023 20:15 5/19/2023 20:30 0.25 COMPZN, RPCOMP ELNE T P/U WL sheave and hang on elevators. M/U E-line pack-off assembly on top of pump in sub. 5/19/2023 20:30 5/19/2023 23:30 3.00 COMPZN, RPCOMP ELNE T RIH w/ 2 3/8" OD Welltec mechanical cutter. Tie-in to GLM #4 @ 7,731' w/ Welltec CCL @. Cut Tubing @ 7,750' at 23:15. POOH. 5/19/2023 23:30 5/20/2023 00:00 0.50 COMPZN, RPCOMP ELNE T POOH with E line from 7750' 5/20/2023 00:00 5/20/2023 01:00 1.00 COMPZN, RPCOMP ELNE T Cont. POOH w/ E-line. R/D E-line. L/D FOSV. 5/20/2023 01:00 5/20/2023 01:30 0.50 COMPZN, RPCOMP PULL T Pulled tubing hanger to rig floor. Max PUW = 110K. Released E-line crew. 5/20/2023 01:30 5/20/2023 02:30 1.00 COMPZN, RPCOMP RURD T Slack off to break out IBT pups. 70K down weight. Set slips. R/D 3 1/2" IBT pup joints. Confirmed SSSV locked out and bled off before cuttinga and capping control line. R/U control line spooler. 5/20/2023 02:30 5/20/2023 04:00 1.50 COMPZN, RPCOMP CIRC P R/U pump in sub. Circulate BU. Perform 30 min NFT. 5/20/2023 04:00 5/20/2023 16:00 12.00 COMPZN, RPCOMP PULL P Pull 3 1/2" tubing. Recover 31 SS bands from control line. Program says 33 total installed. @ 2800' slip broke in airslips and went down hole. At ~1340' overpull to 19K over. Unable to move pipe up or down. Fish notes - Estimated slip dimensions are 1.2" wide x 6" long (x2). Estimated retaining pin dimensions are 3/16" pin x 6" long (x1). 7,750.0 1,340.0 5/20/2023 16:00 5/20/2023 21:00 5.00 COMPZN, RPCOMP PULL T Crew C/O. Discuss new plan forward. Order Lube 776 to circulate down Tubing up the IA. Set down weight (limited) to attempt to free pipe. Decided not to use Top Drive weight to mitigate risk of buckling old tubing. Drain stack and inspect BOP stack and hanger area for broken die/retaining ring. Nothing in stack or on top of wellhead. 1,340.0 1,340.0 5/20/2023 21:00 5/21/2023 00:00 3.00 COMPZN, RPCOMP PULL T RU pump in sub and circ hose in prep to circulate. Wait on 4 drums of Lube 776 from Deadhorse. Mix 100 bbls of 10.2# NaCl/NaBr w/ 3% Lube 776 in Pit #4. 1,340.0 1,340.0 5/21/2023 00:00 5/21/2023 01:30 1.50 COMPZN, RPCOMP CIRC T Yellow Jacket and Welltec on location. Spot unit. Circulate 55 bbl 10.2# NaCl/NaBr with 3% Lube 776 around. 1,340.0 1,340.0 5/21/2023 01:30 5/21/2023 02:30 1.00 COMPZN, RPCOMP PULL T Attempt to free pipe. Down weight limited to tubing hanging weight. No movement. 1,340.0 1,340.0 5/21/2023 02:30 5/21/2023 03:30 1.00 COMPZN, RPCOMP RURD T R/U 3 1/2" EUE FOSV w/ IBT Pin X- over. RU E-line pump-in sub and pack- off. 1,340.0 1,340.0 Rig: NORDIC 3 RIG RELEASE DATE 5/26/2023 Page 5/8 1E-02 Report Printed: 6/20/2023 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) 5/21/2023 03:30 5/21/2023 06:00 2.50 COMPZN, RPCOMP ELNE T RIH with 2 3/8" OD Welltec cutter. Tied into GLM #4 @ 1,326'. PUH to middle of full joint above and cut tubing @ 1,312'. POOH w/ E-line tools. 1,340.0 1,340.0 5/21/2023 06:00 5/21/2023 10:00 4.00 COMPZN, RPCOMP PULL P Pull joint 203 & 204. Pipe cut successful. PUW=45K Load out 3rd party equipment. Continue pulling 3 1/2 tubing. PUW=40K On surface with cut joint #246. 15.2' of joint 1,340.0 0.0 5/21/2023 10:00 5/21/2023 11:00 1.00 COMPZN, RPCOMP SVRG P Service Crown, blocks. Perform derrick inspection 0.0 0.0 5/21/2023 11:00 5/21/2023 12:00 1.00 COMPZN, RPCOMP BHAH P Bring in 6 drill collars. Yellow jacket fishing tools intoshed 0.0 0.0 5/21/2023 12:00 5/21/2023 13:00 1.00 COMPZN, RPCOMP OTHR P PJSM, Set wear ring in place 0.0 0.0 5/21/2023 13:00 5/21/2023 17:30 4.50 COMPZN, RPCOMP BHAH T PJSM, P/U BHA #1 fishing BHA w/overshot, Up Jars,LBS, 6 drill collars. 0.0 0.0 5/21/2023 17:30 5/21/2023 19:00 1.50 COMPZN, RPCOMP TRIP T RIH w/ BHA #1 to just above top of fish. 0.0 1,312.0 5/21/2023 19:00 5/21/2023 20:00 1.00 COMPZN, RPCOMP FISH T Park BHA #1 above top of fish. PUW = 59K. SOW = 58K. Tag fish @ 1,315'. Set down 4K. PU to confirm latch. No latch. Reattempt. Set 4K down on top of fish. Rotate 1/4 turn. Lost Weight. Good indication we are over fish. Swallowed 1' of fish. Set down 10K. PU to 70K (10K over). Confirmed good latch. 1,315.0 1,316.0 5/21/2023 20:00 5/21/2023 23:00 3.00 COMPZN, RPCOMP PULL T Bleed off jars. Prep to hit down with bumper sub. Pulled 98K (39K over) to confirm good latch. Pipe moved uphole. PU to 110K. Lost weight. Continue POOH. Dragging fish uphole @ 75K (15K over) for 15'. Drag dropped off. Slip/debris may have got around GLM. Continue POOH with fish. 1,316.0 53.0 5/21/2023 23:00 5/22/2023 00:00 1.00 COMPZN, RPCOMP FISH T Park with GLM fish just below BOP stack. Drain stack. No slips or retainer pin on top of fish. 53.0 0.0 5/22/2023 00:00 5/22/2023 01:00 1.00 COMPZN, RPCOMP FISH P L/D fish (15' partial if Joint #246 + GLM #4 + 19' 3" partial Joint #247 below with failed chem cut and good Welltec cut). M/U BHA #2 (Dress off shoe, Wash Pipe, Rattle Magnet, String Mill, Jars, 6 DC's). 53.0 0.0 5/22/2023 01:00 5/22/2023 06:00 5.00 COMPZN, RPCOMP BHAH P M/U BHA #2 (Flutted Shoe, Wash Pipe, Boot Basket, Rattle Magnet, String Mill, Jars, 6 DC's). 0.0 225.0 5/22/2023 06:00 5/22/2023 14:00 8.00 COMPZN, RPCOMP TRIP P RIH w/ BHA #2. on DP singles 225.0 4,560.0 5/22/2023 14:00 5/22/2023 14:45 0.75 COMPZN, RPCOMP TRIP P Set down @ 4560, Jt # 141 Partial. Confer w/tool hand. P/U 10K over pop free. PUW=100K. Kelly up, Rotate, see torque break over @ 4000Lb/Ft. Stop rotation. Trip in past setdown with no indication of setdown. Wipe Jt. P/U RIH w/142 clean. 4,560.0 4,600.0 5/22/2023 14:45 5/22/2023 20:00 5.25 COMPZN, RPCOMP TRIP P Continue TIH to 7,677'. PUW = 147K. SOW = 103K. 4,600.0 7,677.0 Rig: NORDIC 3 RIG RELEASE DATE 5/26/2023 Page 6/8 1E-02 Report Printed: 6/20/2023 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) 5/22/2023 20:00 5/22/2023 21:00 1.00 COMPZN, RPCOMP REAM P Rotate Joint #242 @ 25 RPM. Top Drive stalled out at 3,600 ft-lbs. Troubleshoot. Adjust top drive torque to 7,000 ft-lbs. Rotate Joint #242 @ 13 RPM. Free Torque = 4,600 ft-lbs. PUW = 130K. SOW = 110K. 7,677.0 7,677.0 5/22/2023 21:00 5/22/2023 22:00 1.00 COMPZN, RPCOMP REAM P TIH on Joint #242. Clean up packer set depth with string mill from 7,677 - 7,705'. Rotating at 13 RPM. Torque = 4,900 - 5,300 ft-lbs. PU Joint #243 and continue to clean down to 7,740'. PUW = 147K. SOW = 103K. TIH on #243 and tag tubing stub @ 7,750' Set 5K down. PUH to 7,745'. 7,677.0 7,740.0 5/22/2023 22:00 5/22/2023 23:00 1.00 COMPZN, RPCOMP WASH P TIH on #243 and lightly tag tubing stub @ 7,750' Set 5K down. PUH to 7,745'. Bring pumps online @ 2 BPM (34 SPM) to establish circulation. Pump Press = 223 psi. PUW = 140K. SOW = 102K. Rotate slowly to swallow stub. Got weight back. Increase pump rate to 3 BPM (50 SPM) @ 492 psi. TIH slowly. Stalled TD @ 7,300 ft-lbs. PU off stub. Increase rotation to 35 RPM. 5300 - 5500 free torque. Slowly TIH to stub. Set 2K down at 7,750'. Torque = 6300 - 7000. Slowing got weight back and torque reduced to 5500 - 6000. Washed in hole to 7,755 setting 1-2K down and letting weight fall off. 7,740.0 7,755.0 5/22/2023 23:00 5/23/2023 00:00 1.00 COMPZN, RPCOMP CIRC P PUH to 7,747' just above the stub. PUW = 124K. Clean PU. Rotate and reciprocate pipe. Pump 35 bbl Duo Vis gel pill @ 3 BPM (510 psi). Chase with 253 bbls of 10.2# NaCl/NaBr (STS) to clear wellbore of debris. Begin to process 3 1/2" EUE completion tubing. 7,755.0 7,747.0 5/23/2023 00:00 5/23/2023 01:00 1.00 COMPZN, RPCOMP CIRC P Cont. to circulate Duo Vis gel pill around. Pump 35 Bbls Duo Vis. Chased with 253 Bbls 10.2# NaCl/Nabr brine (STS). Begin processing 3 1/2" EUE completion tubing. 7,747.0 7,747.0 5/23/2023 01:00 5/23/2023 06:00 5.00 COMPZN, RPCOMP TRIP P POOH w/ BHA #2 racking back 3 1/2" Drill Pipe. Continue processing 3 1/2" EUE completion tubing as Operations allow. POOH to 4519' and saw a 15K over pull. Popped through. Called Town Engineer. Decision made to work string mill across interval from 4,500' - 4,570'. 7,747.0 4,500.0 5/23/2023 06:00 5/23/2023 11:42 5.70 COMPZN, RPCOMP TRIP P Continue to POOH with BHA #2., PUW=95K 4,500.0 183.0 5/23/2023 11:42 5/23/2023 15:00 3.30 COMPZN, RPCOMP BHAH P PJSM L/D BHA #2, Static fluid loss 4 BPM 183.0 0.0 5/23/2023 15:00 5/23/2023 15:30 0.50 COMPZN, RPCOMP SVRG P Service rig - crown, blocks, TD & draw works. 0.0 0.0 5/23/2023 15:30 5/23/2023 16:00 0.50 COMPZN, RPCOMP SFTY P PJSM, M/U BHA #3, Test packer 0.0 0.0 5/23/2023 16:00 5/23/2023 16:30 0.50 COMPZN, RPCOMP BHAH P MU BHA #3 test packer T/ 14' 0.0 14.0 5/23/2023 16:30 5/23/2023 23:15 6.75 COMPZN, RPCOMP TRIP P RIH w/ BHA #3, passed through 4500' - 4600' clean 80K SOW. Continue run n hole T/ 7730' , PUW=135K,. SOW=100K. 14.0 7,730.0 5/23/2023 23:15 5/23/2023 23:30 0.25 COMPZN, RPCOMP PACK P Set storm packer @ 7722' COE. 7,730.0 7,722.0 Rig: NORDIC 3 RIG RELEASE DATE 5/26/2023 Page 7/8 1E-02 Report Printed: 6/20/2023 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) 5/23/2023 23:30 5/24/2023 00:00 0.50 COMPZN, RPCOMP RURD P R/U testing equipment. 7,722.0 7,722.0 5/24/2023 00:00 5/24/2023 00:30 0.50 COMPZN, RPCOMP PRTS P PT 7" casing against test packer T/ 2500 PSI for 30 Min - Good test 7,722.0 7,722.0 5/24/2023 00:30 5/24/2023 01:00 0.50 COMPZN, RPCOMP RURD P R/D, B/D testing equipment. 7,722.0 7,722.0 5/24/2023 01:00 5/24/2023 01:15 0.25 COMPZN, RPCOMP PACK P Release test packer. 7,722.0 7,711.0 5/24/2023 01:15 5/24/2023 01:30 0.25 COMPZN, RPCOMP SFTY P PJSM on LDDP. 7,711.0 7,711.0 5/24/2023 01:30 5/24/2023 05:30 4.00 COMPZN, RPCOMP PULD P LDDP F/ 7711' T/ 5000' PUW=135K. 7,711.0 5,000.0 5/24/2023 05:30 5/24/2023 12:00 6.50 COMPZN, RPCOMP PULD P LDDP 5000' to 14', PUW=90K 5,000.0 15.0 5/24/2023 12:00 5/24/2023 12:30 0.50 COMPZN, RPCOMP BHAH P Lay down test packer. Some marks on packer. Photos to town. Move forward 15.0 0.0 5/24/2023 12:30 5/24/2023 13:00 0.50 COMPZN, RPCOMP SVRG P Service rig, Crown cluster, Top drive, Traveling blocks 0.0 0.0 5/24/2023 13:00 5/24/2023 13:30 0.50 COMPZN, RPCOMP MPSP P Pull wear bushing. 0.0 0.0 5/24/2023 13:30 5/24/2023 14:00 0.50 COMPZN, RPCOMP RURD P Load out test packer, Load completion jewelry in shed. Lay out in running order. Count tubing to run. 0.0 0.0 5/24/2023 14:00 5/24/2023 14:30 0.50 COMPZN, RPCOMP SFTY P PJSM P/U 3 1/2" completion per tally 0.0 0.0 5/24/2023 14:30 5/24/2023 15:30 1.00 COMPZN, RPCOMP RURD P Bring up pup. Test tongs, Torque to 2250 Lb/Ft. Change out elevators 0.0 0.0 5/24/2023 15:30 5/24/2023 18:00 2.50 COMPZN, RPCOMP PUTB P RIH w/ 3 1/2", 9.3#, L-80 EUE-M tubing string per tallyT/ 407', SOW=40K. EUE- M torqued T/ 2250 Ft/lbs w/ Run-N-Seal dope. 0.0 407.0 5/24/2023 18:00 5/24/2023 18:30 0.50 COMPZN, RPCOMP SFTY P Crew change. PJSM w/ SLB and rig crew on running 3 1/2" EUE-M completion. 407.0 407.0 5/24/2023 18:30 5/25/2023 00:00 5.50 COMPZN, RPCOMP PUTB P RIH w/ 3 1/2" EUE completion string F/ 407' T/ 2732', SOW=58K. 407.0 2,732.0 5/25/2023 00:00 5/25/2023 08:30 8.50 COMPZN, RPCOMP PUTB P Continue run in hole with 3 1/2" EUE completion as per tally T/ 6200 2,732.0 6,200.0 5/25/2023 08:30 5/25/2023 08:42 0.20 COMPZN, RPCOMP PUTB P P/U Jt 243 with X-O to top drive. Kelly up. PUH 10', PUW=95K, SOW=74K. 6,200.0 7,740.0 5/25/2023 08:42 5/25/2023 09:30 0.80 COMPZN, RPCOMP PUTB P PUW=95K, SOW=74K. Circulate down tubing 4 BPM @366PSI, SOW=73K. See Pressure increase 466 PSI @ 7751'. Shut down pumps. RIH to see shear pins shear @ 7753' 14K set down.Continue in to 7757' set down with -15K set down. PUH PUW=95k, Set back down @ 7756.5' with 2K set down 7,740.0 7,756.0 5/25/2023 09:30 5/25/2023 11:00 1.50 COMPZN, RPCOMP PUTB P PUH 2', Measure up for space out, 11' Jt 243 below floor. Lay down 243, 242, & 241 Space out length 12.34. P/U 10.23 and 2.07 pups, 12.3'. P/U Jt 241 7,756.0 7,723.0 5/25/2023 11:00 5/25/2023 12:00 1.00 COMPZN, RPCOMP PUTB P M/U Hanger to landing joint. Make up to tubing string 7,723.0 7,723.0 5/25/2023 12:00 5/25/2023 14:00 2.00 COMPZN, RPCOMP CIRC P PJSM to pump CI, 3 BPM @ 215 PSI, Pumped 248 BBls CI. Chase with 10 BBls water. S 7,723.0 7,723.0 5/25/2023 14:00 5/25/2023 15:00 1.00 COMPZN, RPCOMP HOSO P Pump out stack to land hanger, Lower hanger and land 7754.65' 7,723.0 7,754.7 5/25/2023 15:00 5/25/2023 15:30 0.50 COMPZN, RPCOMP PULD P Land hanger, Verify hanger is landed. RILDS 7,754.7 7,754.7 Rig: NORDIC 3 RIG RELEASE DATE 5/26/2023 Page 8/8 1E-02 Report Printed: 6/20/2023 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) 5/25/2023 15:30 5/25/2023 17:30 2.00 COMPZN, RPCOMP RURD P Drop ball and rod, Pull mouse hole. Rig up to set packer and PT tubing/packer 7,754.7 7,754.7 5/25/2023 17:30 5/25/2023 18:30 1.00 COMPZN, RPCOMP SFTY P PJSM, Purge air from surface lines. Line up to pump down tubing set packer 7,754.7 7,754.7 5/25/2023 18:30 5/25/2023 20:00 1.50 COMPZN, RPCOMP PRTS P Pressure up on tubing against ball and rod to set blue pack max packer T/ 3820 PSI. Held for 30 Min - Good test. Bleed tubing T/ 1500 PSI. Pressure test IA T/ 2500 PSI for 30 Min - Good test. Dump tubing pressure and shear out SOV. 7,754.7 7,754.7 5/25/2023 20:00 5/25/2023 20:15 0.25 COMPZN, RPCOMP RURD P Line up circ manifold to pump down IA taking returns up tubing. 7,754.7 7,754.7 5/25/2023 20:15 5/25/2023 20:30 0.25 COMPZN, RPCOMP CIRC P Circ @ 2 BPM, xxx PSI pumping down IA taking returns through tubing. 7,754.7 7,754.7 5/25/2023 20:30 5/25/2023 21:15 0.75 COMPZN, RPCOMP RURD P Blow down surface lines into stack. R/D circulating equipment on landing joint. Pull landing joint. 7,754.7 7,754.7 5/25/2023 21:15 5/25/2023 21:30 0.25 COMPZN, RPCOMP MPSP P Set HP BPV. 7,754.7 7,754.7 5/25/2023 21:30 5/25/2023 22:00 0.50 COMPZN, RPCOMP PRTS P PT BPV T/ 1000 PSI for 10 Min from below - Good test. 7,754.7 0.0 5/25/2023 22:00 5/26/2023 00:00 2.00 COMPZN, RPCOMP NUND P Pull riser from BOP. 0.0 0.0 5/26/2023 00:00 5/26/2023 02:30 2.50 COMPZN, RPCOMP NUND P Break choke and kill lines off of BOP. N/D BOP, rack back on stump. N/D DSA. Cleaning pits. 0.0 0.0 5/26/2023 02:30 5/26/2023 03:30 1.00 COMPZN, WHDBOP SFTY P Crew change out. PJSM on un hanging and N/U tree. 0.0 0.0 5/26/2023 03:30 5/26/2023 06:30 3.00 COMPZN, WHDBOP NUND P Install tree test dart. N/U tree to adaptor spool. Install companion flange on production valve. N/U tree to wellhead. 0.0 0.0 5/26/2023 06:30 5/26/2023 07:00 0.50 COMPZN, WHDBOP PRTS P PT hanger void T/ 5000 PSI for 15 Min - Good test. 0.0 0.0 5/26/2023 07:00 5/26/2023 09:00 2.00 COMPZN, WHDBOP PRTS P MIRU LRS , test tree to 5K, charted 10 min test 0.0 0.0 5/26/2023 09:00 5/26/2023 11:00 2.00 COMPZN, WHDBOP FRZP P PJSM, Pump 70 BBls down IA 2 BPM 850 PSI, Returns to TT. Allow well to U tube 0.0 0.0 5/26/2023 11:00 5/26/2023 12:00 1.00 COMPZN, WHDBOP OTHR P PJSM P/U BPV lubricator. Install BPV. Final pressures 250/50/50 0.0 0.0 5/26/2023 12:00 5/26/2023 13:00 1.00 DEMOB, MOVE MOB P Remove TT from rig, RDMO to 1D-145 Rig released # 13:00 Hrs 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 5/26/2023 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,222.0 1E-02 5/31/2023 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Install Post Rig GLD, pull B&R, RHC, catcher, RBP, update Tag depth 1E-02 5/31/2023 rogerba 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 15.25 34.0 80.0 80.0 65.00 H-40 WELDED SURFACE 10 3/4 9.95 32.4 3,051.0 2,702.3 45.50 K-55 BTC PRODUCTION 7 6.28 31.7 8,420.9 6,497.2 26.00 K-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 26.5 Set Depth 7,754.7 Set Depth 5,896.5 String Ma 3 1/2 Tubing Description Tubing Completion Upper Wt (lb/ft) 9.30 Grade L80 Top Connection EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 26.4 26.4 0.00 Hanger 6.980 3.5" x 6" FMC Tubing Hanger Gen 4 W/ H Profile FMC Gen4 2.920 516.7 516.7 0.00 Nipple - X 4.504 3.5" x 2.813" X-Nipple Halliburt on X 2.813 2,779.4 2,516.1 46.00 Mandrel GAS LIFT 5.980 3.5" x 1.5" MMG GLM SLB MMG 2.990 3,556.1 3,003.6 55.14 Mandrel GAS LIFT 5.910 3.5" x 1.5" MMG GLM SLB MMG 2.990 7,639.9 5,797.0 31.10 Mandrel GAS LIFT 5.940 3.5" x 1.5" MMG GLM SLB MMG 2.990 7,700.2 5,848.9 29.75 Packer 6.280 3.5" x 7" BluePack RH Max VAM TOP B/P SLB BluePac k 2.990 7,726.4 5,871.8 29.29 Nipple - X 4.504 3.5" x 2.813" X-Nipple Halliburt on X 2.813 7,747.8 5,890.4 28.91 Overshot 5.980 3 1/2" x 7" PoorBoy Overshot w/ shear screws 6.65' of swallow (space out 2' off tag) Baker Poorboy Oversho t 3.620 Top (ftKB) 7,750.0 Set Depth 8,112.4 Set Depth 6,216.3 String Ma 4 1/2 Tubing Description Tubing Completion Lower Wt (lb/ft) 9.20 Grade J-55 Top Connection FL4S ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,760.2 5,901.3 28.70 SBR 4.000 BAKER SBR 3.000 7,788.5 5,926.2 28.20 PACKER 6.156 BAKER FHL PACKER 2.890 7,944.2 6,064.5 26.34 BLAST RINGS 4.500 CARBIDE BLAST RINGS (4) 2.992 8,081.3 6,188.2 25.30 PACKER 6.156 BAKER FB-1 PACKER w/ 5' SEAL BORE EXTENSION 4.000 8,100.1 6,205.2 25.25 NIPPLE 4.540 CAMCO D LANDING NIPPLE w/ 2.75" NO GO PROFILE 2.750 8,111.6 6,215.6 25.13 SOS 4.570 BAKER SHEAR OUT SUB & RE- ENTRY GUIDE 3.015 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,750.0 5,892.4 28.88 CUT Tubing Cut @ 7,750' 5/19/2023 0.000 7,790.0 5,927.5 28.18 LEAK - PACKER PACKER LEAK AT 7790' RKB IDENTIFIED BY EL ACOUSTIC LDL 12/15/2022 2.992 8,200.0 6,295.9 24.25 FISH Lost P2P packer slip 3/21/2023 0.000 8,206.0 6,301.4 24.27 FISH Valve & Wobble Ring Lost from GLM @ 4870'; "Could be anywhere" 8/17/1992 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,779.4 2,516.1 46.00 1 GAS LIFT GLV RK 1 1/2 1,214.0 5/30/2023 SLB MMG 0.250 3,556.1 3,003.6 55.14 2 GAS LIFT OV RK 1 1/2 0.0 5/30/2023 SLB MMG 0.313 7,639.9 5,797.0 31.10 3 GAS LIFT DMY RK 1 1/2 0.0 5/30/2023 SLB MMG 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,959.0 8,050.0 6,077.8 6,159.9 C-4, C-1, 1E-02 8/17/1981 4.0 IPERF 8,182.0 8,204.0 6,279.5 6,299.6 A-5, 1E-02 8/17/1981 4.0 IPERF 8,219.0 8,234.0 6,313.2 6,326.9 A-4, 1E-02 8/17/1981 4.0 IPERF 1E-02, 6/19/2023 9:23:28 AM Vertical schematic (actual) PRODUCTION; 31.7-8,420.9 FLOAT SHOE; 8,419.0-8,420.9 FLOAT COLLAR; 8,331.0- 8,332.5 IPERF; 8,219.0-8,234.0 FISH; 8,206.0 FISH; 8,200.0 IPERF; 8,182.0-8,204.0 SOS; 8,111.6 NIPPLE; 8,100.1 PACKER; 8,081.3 PRODUCTION; 8,059.3 IPERF; 7,959.0-8,050.0 PRODUCTION; 7,901.4 PRODUCTION; 7,827.1 PACKER; 7,788.5 LEAK - PACKER; 7,790.0 SBR; 7,760.2 Overshot; 7,747.8 CUT; 7,750.0 Nipple - X; 7,726.4 Packer; 7,700.2 Mandrel GAS LIFT; 7,639.9 Annular Fluid - Saltwater/Brine; 2,000.0-7,754.7; 5/25/2023 Mandrel GAS LIFT; 3,556.1 SURFACE; 32.4-3,051.0 Mandrel GAS LIFT; 2,779.4 Annular Fluid - Diesel; 26.4- 2,000.0; 5/26/2023 Nipple - X; 516.7 CONDUCTOR; 34.0-80.0 HANGER; 31.7-35.3 Hanger; 26.4 KUP PROD KB-Grd (ft) 38.99 RR Date 6/18/1980 Other Elev 1E-02 ... TD Act Btm (ftKB) 8,440.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292047200 Wellbore Status PROD Max Angle & MD Incl (°) 56.00 MD (ftKB) 3,800.00 WELLNAME WELLBORE1E-02 Annotation Last WO: End Date 5/26/2023 H2S (ppm) 20 Date 9/10/2016 Comment SSSV: LOCKED OUT Certificate Of Completion Envelope Id: 50C480DE3C8540768A37F5C92A71B176 Status: Completed Subject: Here is your signed document: KRU 1E-02 10-404 (PTD 180-050).pdf Source Envelope: Document Pages: 10 Signatures: 1 Envelope Originator: Certificate Pages: 5 Initials: 0 Jonathan Coberly AutoNav: Disabled EnvelopeId Stamping: Disabled Time Zone: (UTC-06:00) Central Time (US & Canada) 600 N Dairy Ashford Rd Houston, TX 77079-1100 Jonathan.Coberly@conocophillips.com IP Address: 138.32.8.5 Record Tracking Status: Original 6/22/2023 1:09:38 PM Holder: Jonathan Coberly Jonathan.Coberly@conocophillips.com Location: DocuSign Signer Events Signature Timestamp Jonathan Coberly Jonathan.Coberly@conocophillips.com Security Level: Email, Account Authentication (None) Signature Adoption: Pre-selected Style Using IP Address: 138.32.8.5 Sent: 6/22/2023 1:10:03 PM Viewed: 6/22/2023 1:10:12 PM Signed: 6/22/2023 1:14:42 PM Freeform Signing Electronic Record and Signature Disclosure: Accepted: 10/21/2021 1:38:44 PM ID: 816074ce-6cf9-4a8e-a803-d7ca1a5695a7 In Person Signer Events Signature Timestamp Editor Delivery Events Status Timestamp Agent Delivery Events Status Timestamp Intermediary Delivery Events Status Timestamp Certified Delivery Events Status Timestamp Carbon Copy Events Status Timestamp Amy Conklin Amy.A.Conklin@conocophillips.com Security Level: Email, Account Authentication (None) Sent: 6/22/2023 1:14:43 PM Electronic Record and Signature Disclosure: Not Offered via DocuSign Jenna Taylor Jenna.L.Taylor@conocophillips.com ConocoPhillips Security Level: Email, Account Authentication (None) Sent: 6/22/2023 1:14:43 PM Viewed: 6/22/2023 2:08:55 PM Electronic Record and Signature Disclosure: Not Offered via DocuSign Witness Events Signature Timestamp Notary Events Signature Timestamp Envelope Summary Events Status Timestamps Envelope Sent Hashed/Encrypted 6/22/2023 1:10:03 PM Certified Delivered Security Checked 6/22/2023 1:10:12 PM Signing Complete Security Checked 6/22/2023 1:14:42 PM Completed Security Checked 6/22/2023 1:14:43 PM Payment Events Status Timestamps Electronic Record and Signature Disclosure ELECTRONIC RECORD AND SIGNATURE DISCLOSURE From time to time, ConocoPhillips (we, us or Company) may be required by law to provide to you certain written notices or disclosures. 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By selecting the check-box next to I agree to use electronic records and signatures, you confirm that: You can access and read this Electronic Record and Signature Disclosure; and You can print on paper this Electronic Record and Signature Disclosure, or save or send this Electronic Record and Disclosure to a location where you can print it, for future reference and access; and Until or unless you notify ConocoPhillips as described above, you consent to receive exclusively through electronic means all notices, disclosures, authorizations, acknowledgements, and other documents that are required to be provided or made available to you by ConocoPhillips during the course of your relationship with ConocoPhillips. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV UNIT 1E-02 JBR 06/16/2023 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:7 3.5 test joint used for testing. TIW failed and was replaced and passed. Two different dart valves failed and were replaced twice before getting the third dart to pass. The manual kill valve failed and serviced to pass. The UPR failed and were pulled, replaced and retested for a pass. Pulled the blanking plug and had it redressed as well during the testing process. The annular failed and was cycled and passed. The accumulator air pumps (3 pumps) were not working properly. The mufflers were clogged and restricted enough to not allow the pumps to run. The mufflers were replaced and the pumps will be run without them until replacements can be installed. All three air pumps and the hydraulic triplex pump on the accumulator had been replaced during their maintenance period before going to work for Conoco. Test Results TEST DATA Rig Rep:A. Hensen/R. BorgenOperator:ConocoPhillips Alaska, Inc.Operator Rep:J. Newel/T. Wiese Rig Owner/Rig No.:Nordic 3 PTD#:1800500 DATE:5/19/2023 Type Operation:WRKOV Annular: 250/3500Type Test:INIT Valves: 250/5000 Rams: 250/5000 Test Pressures:Inspection No:bopGDC230518113300 Inspector Guy Cook Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 16 MASP: 2334 Sundry No: 323-170 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 FP Inside BOP 1 FP FSV Misc 0 NA 12 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8 5000 FP #1 Rams 1 2 7/8"x5.5" V FP #2 Rams 1 Blinds P #3 Rams 1 2 7/8"x5.5" V P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8" 5000 P HCR Valves 2 3 1/8" 5000 P Kill Line Valves 1 3 1/8" 5000 FP Check Valve 0 NA BOP Misc 2 2 1/16" 5000 P System Pressure P3000 Pressure After Closure P1600 200 PSI Attained P20 Full Pressure Attained P131 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P4@2000 ACC Misc F1 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P22 #1 Rams P4 #2 Rams P4 #3 Rams P5 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P2 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 FP FP FP FP FP F TIW failed Two different dart valves failed manual kill valve failed UPR failed annular failed accumulator air pumps (3 pumps) were not working properly. X SFD 3/24/2023 10-404 BOP test to 2500 psi. BJM 4/6/2023 DSR-3/22/23GCW 04/07/23 04/07/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.04.07 08:32:41 -08'00' RBDMS JSB 040723 C:\Users\mdguhl\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\LCF4WGUY\2022-12-15_15893_KRU_1E-02_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 15893 KRU 1E-02 50-029-20472-00 LeakPoint Survey 15-Dec-22 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 By Meredith Guhl at 8:51 am, Dec 29, 2022 180-050 T37397 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.12.29 08:52:09 -09'00' Regg, James B (DOA) From: NSK Prod Engr Specialist <n1139@conocophillips.com> Sent: Tuesday, January 19, 2016 10:40 AM 41,1 Z\I C. To: Regg,James B (DOA); Brooks, Phoebe L (DOA) Cc: NSK Fieldwide Operations Supt Subject: Com.leted Deficiency Reports: 1E-02, 03, 12, & 14 Attachments: E-02 AOGCC Deficiency Rpt Complete 01-16.pdf; 1E-03 AOGCC Deficiency Rpt Complete 01-16.pdf; 1E-12 AOGCC Deficiency Rpt Complete 01-16.pdf; 1E-14 AOGCC Deficiency Rpt Complete 01-16.pdf Mr. Regg, Attached are the completed AOGCC Deficiency reports, with documentation, for KRU wells 1E-02,03, 12, & 14. Bob Christensen/ Darrell Humphrey NSK Production Engineering Specialist ConocoPhillips Alaska, Inc. • sCANNEDu ib Kuparuk Office: 907.659.7535 Kuparuk Pager: 659.7000;#924 CPAI Internal Mail: NSK-69 This email may contain confidential information. If you receive this e-mail in error, please notify the sender and delete this email immediately. 1 • • State of Alaska Oil and Gas Conservation Commission Deficiency Report Location: KRU 1E-02 Date: jji 2 't6 PTD: 1800500 Operator: Conoco/Phillips Alaska Inc. Type Inspection: SVS Operator Rep: Bob Christensen Inspector: Guy Cook Position NSK Production Engineering Specialist Op.Phone: 907-659-7535 Correct by(date): 1/18/2016 Op.Email: n1139@conocophillips.com Follow Up Required: No Detailed Description of Deficiencies Date Corrected 1 E-02 has a lock down screw gland nut leak. Torque should be checked and the void should be pressure tested to confirm integrity. xi bAl Operator Rep t /C t /lo Signatures: ` /5''-fr- G ,Y^-_" AOGCC Inspector *After signing,a copy oehis form is to be left with the operator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC(Attention:Inspection Supervisor)within 7 days of receipt. Include the "Date Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must requested and accompanied by justification(Attention:Inspection Supervisor). Failure to provide the required documentation of corrective actions constitutes a violation of 20 MC 25.300 and is subject to enforcement action under 20 AAC 25.535 Revised 3/9/2015 • • S ConocoPhilliPS AOGCC EXCEPTION REPORT Alaska Location: 1E-02 Date: 1/9/2016 AOGCC Inspector: Guy Cook AOGCC EXCEPTIONS NOTED: 1E-02: Cl n nuts leatun Action Taken to Correct Problem: 1E-02: Gland nuts torqued and cleaned. PO test done to verify no leaking. Date: 1/12/16 Initials: BAR Date: Initials: Date: Initials: Date: Initials: Date: Initials: Date: Initials: Return completed form to Prod.Engr.Specialist: nil39CcD_conocophillips.com Distribution: CPF DSLT CPF OPS Supv Prod. Engr.Specialist C.C. CPF1&2 Ops Supt CPF3 Ops&DOT Pipelines Supt NSK Fieldwide Operations Supt C ` • • J.% z'zfi6 State of Alaska Oil and Gas Conservation Commission Deficiency Report Location: KRU 1E-02 Date: 1/11.12016 ,I k, PTD: 1800500 Operator: Conoco/Phillips Alaska Inc. Type Inspection: SVS Operator Rep: Bob Christensen Inspector: Guy Cook Position: NSK Production Engineering Specialist Op. Phone: 907-659-7535 Correct by(date): 1/18/2016 Op. Email: n1139@conocophillips.com Follow Up Required: No Detailed Description of Deficiencies Date Corrected 1 E-02 has a lock down screw gland nut leak. Torque should be checked and the void should be pressure tested to confirm integrity. Signatures: Operator Rep yi `tn AOGCC Inspector *After signing,a copy of is form is to be left with the operator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC(Attention:Inspection Supervisor)within 7 days of receipt. Include the "Date Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must requested and accompanied by justification(Attention:Inspection Supervisor). Failure to provide the required documentation of corrective actions constitutes a violation of 20 AAC 25.300 and is subject to enforcement action under 20 AAC 25.535 Revised 3/9/2015 ConacoPhillips ~~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 16~', 2010 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: • ,4~~il~ ~, 2(JiiJ ~kg ~! ~ Gas Gox~. G~nission ~ncl~~~age 1$° .o i~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRtn. Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped November 25~' 2007 & March 21 2009, the corrosion inhibitor/sealant was pumped July 6~', 7~', 8~' 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, Perry Klein 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 7116110 1 A. 1 C.1 E PAD r Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-11 50029206850000 1811730 10" n/a 10" Na 3.4 7/8/2010 1A-12 50029206880000 1811780 2" Na 2" Na 1.7 7/8/2010 1A-13 50029207000000 1811950 11" n/a 11" n/a 3.4 7/8/2010 1A-14 50029207060000 1820100 4" n/a 4" Na 2.1 7/8/2010 1 C-01 50029205260000 1801280 SF n/a 24" Na 4.3 7/6/2010 1 C-02 50029205320000 1801350 24" n/a 24" Na 8.5 7/6/2010 1 G03A 50029205350100 2070630 SF n/a 16" Na 7.7 7/6/2010 1C-04 50029205470000 1801550 SF n/a 5" n/a 2.6 7/6/2010 1C-06 50029205640000 1810250 76 17.70 32" 3/21/2009 9.4 7/6/2010 1 C-09 50029208590000 1821850 38' 8.00 6" 11 /25/2007 6.8 7/6/2010 1C-10 50029208650000 1821930 37'6" 8.00 8" 11/25/2007 6.8 7/6/2010 1E-02 50029204720000 1800500 21" Na 21" Na 1.7 7/7!2010 1 E-03 50029204770000 1800560 4" n/a 4" Na 2.4 717/2010 1 E-06 50029204930000 1800780 12" n/a 12" Na 13.6 7/7/2010 1 E-07 50029204950000 1800800 5" n/a 5" Na 2.6 7/7/2010 1E-08 50029204960000 1800810 5" n/a 5" n/a 2.6 7/7/2010 1 E-10 50029207250000 1820360 2" n/a 2" Na 1.7 7/7/2010 1 E-13 50029207500000 1820780 5" n/a 5" Na 2.6 7/7/2010 1E-19 50029209050000 1830170 1" Na 1" Na 1.7 7/7/2010 1E-21 50029208920000 1830020 3" Na 3" n/a 2.6 7/7/2010 1E-24A 50029208570100 1971870 2" n/a 2" n/a 1.7 7/7/2010 1E-25 50029208440000 1821700 3" Na 3" n/a 1.7 7/7/2010 1E-28 50029208320000 1821580 4" Na 4" n/a 2.5 7/8/2010 1 E-29 50029208280000 1821540 7" Na 7" n/a 2.5 7/8/2010 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth • Well Job # ~• NO.4482 ;~. ,~ ~~~~,,~ r,, ~;~ ; ;i~.s i ~=~ ,,~ NOV .~ ZQ07 Company: Alaska Oil 8~ Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Log Description c . _ _, _. ~_ pate,. BL Color CD 11 /07/07 3J-10 11850465 SBHP SURVEY 1 ~ 10/31/07 1 1B-08A 11839682 INJECTION PROFILE ~ 10131/07 1 1D-01 11846458 LDL - 11101!07 1 2A-15 11846459 PRODUCTION PROFILE 5 - (o _ 11!02107 1 1E-02 11850470 PRODUCTION PROFILE 'fj -~S 11/04/07 1 2N-310 11745242 SCMT 11/04/07 1 1E-119 10687772 OH LDWG EDIT ~ <f 04108/04 1 1E-119 10687772 CMR ~pL - 04/08/04 1 1 E-119 10687772 MDT 04/08/04 1 • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ¢ l FOO oo MEMORANDUM TO: Julie Heusser, Chairman State of Alaska Alaska Oil and Gas Conservation Commission DATE: January 4, 2001 THRU: Tom Maunder, P. I. Supervisor FROM: Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Kuparuk River Unit 1E Pad Thursday, January 4, 2001: I traveled to the Kuparuk River Field and witnessed safety valve system testing on 1E Pad. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 9 wells 18 components on 1E pad with 2 failures. The Pilot on well 1E-07 was frozen and the Surface Safety valve on well 1E-24A had a slow leak when pressure .tested..A portable heater was brought to location and the above mentioned pilot was thawed out. I requested the portable heater remain on this well until repairs are made on the catalytic heater in the wellhouse. The failed safety valve will be serviced and retested when the grease crow becomes available Earnie Barndt conducted the testing today; he demonstrated good test procedures and was a pleasure to work with. I also inspected 'the well houses on this pad while witnessing SVS testing. ,All the wellhouses were clean and the equipment appeared to be in good condition. Summary: I witnessed the SVS testing at 1E Pad in the Kuparuk River Field. KRU I'E Pad, 9 wells, 18 components, 2 failure, 11.1% failure rate 16 wellhouse inspections Attachment: SVS KRU 1E Pad 1-4-01 CS X Unclassified Confidential Confidential (Unclassified if doc; removed ), SVS KRU 1E Pad 1-4-01 CS.doc .~ . '.. ( ( .. . .' Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Operator Rep: Earnie Barndt AOGCC Rep: Chuck Scheve. Submitted By: Chuck Scheve Date: FieldlUnit/Pad: ~aruk I KRU / IE Pad Separator psi: LPS 85 HPS 1/4/0 I Well Permit Separ Set LIP Test I Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE I E-02 1800500 85 70 60 P P OIL lE-03 1800560 85 70 45 P p . OIL IE-OS 1800580 . 1 E-06 1800780 I E-07 1800800 85 70 0 2 P OIL lE-IO 1820360 IE-II 1820510 IE-12 1820600 . IE-14 1820790 . I E-18 1830160 85 .. 70 50 P P OIL 1 E-19 1830170 . . IE-20 1830050 85 70 50 P P OIL IE-21 1830020 lE-23 1821840 --;- IE-24A 1971870 85 70 70 P 4 OIL lE-26 1821660 lE-28 1821580 .. lE-29 1821540 lE-31 1971380 85 70 65 P P OIL IE-33 1971510 IE-34 . 1971660 85 70 50 P P OIL lE-36 1982130 85 70 60 P P OIL . Wells: . 9 Components: . 18 Failures: 2 Failure. Rate: 11.10/£190 Day Remarks: Pilot on 1 E-07 frozen. Portable heater placed on pilot until catalytic repaired Surface Safety on lE-24A had slow leak, valve to be serviced and retested. 1/9/01 Page 1 of 1 SVS KRU IE Pad 1-4-01 CS.xls ,,-...., ~ Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Ine Op~morRep: E.Barnili AOGCC Rep: John H. Spaulding Submitted By: John H. Spauld Date: FieldlUnitlPad: Kuparuk!Kuparuk R. 0.11 Separator psi: LPS 91 HPS 7/22/00 Well Permit Separ Set LIP Test Test Test Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code GAS or CYCLE 1800500 91 70 65 P P OIL 1E-03 1800560 SI IE-OS 1800580 1E-06 1800780 SI 1E-07 1800800 91 60 55 P P OIL IE-IO 1820360 IE-ll 1820510 1E-12 1820600 SI 1E-14 1820790 IE-I 8 1830160 91 60 46 P P OIL 1E-19 1830170 1E-20 1830050 91 60 48 P P OIL 1E-21 1830020 1E-23 1821840 1E-24A 1971870 91 70 70 P P OIL 1E-26 1821660 SI 1E-28 1821580 SI 1E-29 1821540 SI 1E-31 1971380 91 70 70 P P OIL 1E-33 1971510 1E-34 1971660 91 70 70 P P OIL 1E-36 1982130 91 70 70 P P OIL Wells: 8 Components: 16 Failure Rate: 9.0% D90Day Remarks: 8/7/00 Page I of I svs kuparuk kru Ie 7-22-00js.xls .. .. ,,-...., .~ Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Ine Operator Rep: E. Barndt AOGCC Rep: John H. Spaulding Submitted By: John Spaulding Date: FieldlUnitlPad: KuparuklKuparuk R.l2X Separator psi: LPS 96 HPS 22-Jul Well Permit Separ Set LIP Test Test Test Oil, WAG,GINJ, Number Number PSI PSI Trip Code Code Code GAS or CYCLE 2X-Ol 1830840 2X-02 1831030 2X-03 1831090 2X-04 183 II 80 3000 2000 2000 P P WAG 2X-05 1831070 3000 2000 2000 P 4 WAG 2X-06 1831100 3000 2000 2000 P P WAG 2X-07 1831130 3500 2000 2000 P P WAG 2X-08 1831140 2X-09 1841620 96 70 60 P P OIL 2X-1O 1841630 96 70 65 P P OIL 2X-ll 1841640 96 60 60 P P OIL 2X-12A 1951760 2X-13 1841740 2X-14 1841750 2X-15 1841760 96 70 70 P P OIL 2X-16 1841720 2X-17 1951710 96 60 50 P P OIL 2X-18 1951600 96 60 50 P P OIL 2X-19 1951750 20 Failures: Failure Rate: 5.0% D90Day Wells: 10 Remarks: 8/15/00 Page I of 1 svs kuparuk kru 2x 7-22-00js.xls ...!' IÞ i' , .. ) <?ð -Q5ð ( ( MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount, Or:) DATE: July 22, 2000 Commissioner ð/ /o/ð ~ THRU: Blair Wondzell, ~ SUBJECT: SVS Tests P. I. Supervisor e[1( 070 Pads 1E & 2X Kuparuk River Unit John H spaulding~ ¡L --8. Kuparuk River Field FROM: Petroleum Inspector JulY 22. 2000: I traveled to Philips Alaska Inc.'s Kuparuk Field to witness the SVS Tests on 1E and 2X pads. The AOGCC form is attached for reference. As noted on the test reports a minimal amount of failures were observed (1 on each pad). Ernie Barndt the PAl representative and his helper did an excellent job of testing. SUMMARY: I witnessed the SVS tests on: PAl, KRU, 1E &1X 1 E -- 8 wells, 16 components, 1 failure;/9% failure rate, 12 well house insp. .%*;';;;~;,Q'.wells;;2Q;compnents, 1 failure';å% failure rate, 12 well house insp. Attachment: Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: E. Barndt AOGCC Rep: John H. Spauldin~ Submitted By: John H. Spauld Date: Field/Unit/Pad: ~aruklKuparuk R. U./ 1 Separator psi: LPS 91 HPS 7/22/00 Well Permit Separ Set LIP Test Test Test Oil. WAG, GINJ, Number Number PSI PSI Trip Code Code Code GAS or CYCLE ~ I 1800500 91 70 65 P P OIL 1 £-03 1800560 SI 1 £-05 1800580 1 E-06 1800780 SI 1 E-07 1800800 91 60 55 P P OIL 1 E-1 0 1820360 1 E-11 1820510 1 E-12 1820600 SI 1 E-14 1820790 1 E-18 1830160 91 60 46 P P OIL 1 E-19 1830170 1 E- 20 1830050 91 60 48 P P OIL 1 E- 21 1830020 1E-23 1821840 1E-24A 1971870 91 70 70 P P OIL 1E-26 1821660 SI 1E-28 1821580 SI 1E-29 1821540 SI lE-31 1971380 91 70 70 P P OIL 1 E- 33 1971510 1E-34 1971660 91 70 70 P P OIL 1 E- 36 1982130 91 70 70 P P OIL Wells: 8 Components: 16 1 F aUure Rate: 9.00/0 090 Day Remarks: 8/7/00 Page 1 of 1 svs kuparuk kru Ie 7-22-00js.xls .... tit ( ( Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Inc OpermorRep:E.BmD~ AOGCC Rep: John H. Spau1din~ Submitted By: John Spauldin8.. Date: FieldlUnitIPad: ~aruk/Kuparuk R.l2X Separator psi: LPS 96 HPS 22-Jul Well Permit Separ Set LIP Test Test Test Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code GAS or CYCLE 2X -01 1830840 2X -02 1831030 2X-03 1831090 2X -04 1831180 3000 2000 2000 P P WAG 2X-05 1831070 3000 2000 2000 P 4 WAG 2X -06 1831100.0 3000 2000 2000 P P WAG 2X-07 1831130 3500 2000 2000 P P WAG 2X -08 1831140 2X -09 1841620 96 70 60 P P OIL 2X -1 0 1841630. 96 70 65 P P OIL 2X-l1 1841640 96 60 60 P P OIL 2X-12A 1951760 2X -13 1841740 2X -14 1841750 2X -15 .1841760 96 70 70 P P OIL 2X -16 1841720 ° 2X-17 1951'71 0 96 60 50 P P OIL 2X -18 .1951600 0.96 60 50 P P OIL 2X-19 . 1951750 -:- Wells: 10 20 Failures: 1 Failure Rate: 5.0% 0 90 Day Remarks: 8/15/00 Page 1 of 1 svs kuparuk kru 2x 7-22-00js.xls ..iI"- ,.> ( STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ~ ~' ,'.' Stimulate lL.. casing - Repair 5. Type of Well: Development X Exploratory Stratigraphic Service Plugging - Perforate well Pull tubing Other - 6. Datum elevation (DF or KB) 1. Type of Request: Operation Shutdown - Pull tubing Alter 2. Name of Operator AR 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 294' FSL, 636' FEL, Sec. 16, T11 N, R10E, UM At top of productive interval 1752' FSL, 1667' FWL, Sec. 22, T11 N, R10E, UM At effective depth 1533' FNL, 1729' FWL, Sec. 22, T11N, R10E, UM At total depth 1533' FSL, 1729' FWL, Sec. 22, T11 N R10E UM 12. Present well condition summary Total Depth: measured 8440 true vertical 65 1 4 1 , RKB feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1 E-2 9. Permit number/approval number 10. API number - 2 - 472 11. Field/Pool Ku aruk River Oil Pool feet feet Plugs (measured) Effective depth: measured 8 3 3 1 true vertical 64 1 4 feet feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 7959'-8050', 8182'-8204', 8219'-8234' MD true vertical 6078'-6160', 6280'-6300', 6313'-6327' TVD Tubing (size, grade, and measured depth) 3 1/2" 9.3 I bItt , J-55, 8103' MD RKB Packers and SSSV (type and measured depth) Cameo TRDP SSSV 1802'; Baker FHL Packer 13. Stimulation or cement squeeze summary Length Size Cemented Measured depth True vertical depth 80' 80' 3051' 2702' 8421' 6498' 80' 3051 ' 1 6" 240 Sx AS II 10 3/4" 840 Sx Fondu & 250 Sx AS II 7 " 575 Sx Class "G" 8421 ' !i \: }' '. . ',.' ., ."_..~"""'.V' .", . , '-'.;.¡."i¡.".:..J,å 7786', Baker FB-1 ackelf;,@::80..~' Intervals treated (measured) 8182'-8204' & 8219'-8234' Treatment description including volumes used and final pressure The A Sand in Well 1 E-2 was fracture stimulated on 8-27 -88. The treatment is described in the attached well service re ort. 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation (A Sand) 0 93 0 49 0 0 500 1120 11 7 Subse uent to 0 eration A Sand 15. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations X Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,3 Title J A.. 130 16. Status of well classification as: Service Date ç -- 'J.-> ~~'i j SUBMIT IN DUPLICATE ARCO Alaska, In~ g) Subsidiary of Atlantic Richfield Company WELL IPBDT CONTRACTOR IFIELD - DISTRICT- STATE e_PF- i I r~o oPERATION A'f R~=I:~RT TIME WELL SERVICE REPORI DAYS JDATE z,:, '9,,_$ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK REMARKS CONTINUED: DESCRIPTION DAILY ACCUM. TOTAL ~ ~ ~, ~, ~, ~ ~ .......... ;, ....... ~"',',i'/;~ .... OTIS sCHLUMBERGE'R ........... ............ DRESSER-ATLAS DowELL ................................ ..... , ...... HALLIBURTON "' - ARCTIC COIL TUBING .............. '"FRACMASTER ................. '"~~,~.~ "' ~,,~¥,~t..~; ~,~... I ~o'¢, ~o, -,~ ~o~..^ ... ~'~"~~.... ~,r. ~.¢ ~. ¢, ,- ............. ,',., ~, Diesel Methanol ................... Su,PervisiOn ............. pre-Job Safety Meeting '" ,,, ' ...... I ............. , AFE ....... ......... ............ , ,, ............. .......... , ...... ..... TOTAL FIEI'D ESTIMATE ...... /~ .j ~ ~' ~,C~C~,~j ,,, ARCO Alaska, Inc. Date: September 21, 1988 Transmittal #: 7296 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. 1 L- 0 4 Kuparuk Fluid Level Report 9 - 0 6 - 8 8 Casing 3 B - 1 3 Kuparuk Fluid Level Report 9 - 0 5 - 8 8 Casing Kuparuk Fluid Level Report 9 - 0 5 - 8 8Casing Kuparuk Fluid Level Report 9 - 0,5 - 8 8 Casing Kuparuk Fluid Level Report 9- 0 1 - 8 8 Casing ' 1 D- 0 8 Kuparuk Fluid Level Report 9- 0 1 - 8 8 Tubing - 0 3 Kuparuk Fluid Level Report 8 - 3 1 - 8 8 Casing Kuparuk Fluid Level Report 8- 3 1 - 8 8 Casing Kuparuk Fluid Level Report 8 - 3 1 - 8 8 Casing "/ 1 E-0 6 . Kuparuk Fluid Level Report 9- 1 7-8 8 Casing {~ 1 E-02. Kuparuk Fluid Level Report 9-1 7-88 Casing Receipt Acknowledged' SEP 2 2 1.988' ., ~ ~.~:~. 0ii & Oas Cons, Commiss;c,~ ............................ :~'--'u a [ e :^,~c~ or-~.~3 .......... DISTRIBUTION: D&M State of Alask~ Chevron Unocal Mobil SAPC ARCO Alaska, Inc.~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 26, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate are multiple Applications for Sundry Approvals on Kuparuk wells 1E-2 and 1E-6. We are generating our own form 10-403's and 404's on Macintosh PC's. The attached applications are our first 403's presented to you by this method. We hope you will approve this nearly identical document. Well Action ~ Refracture 1 E- 6 Refracture If you have any questions, please call me at 265-6840. Sincerely, G. B. Smallwood Senior Operations Engineer GBS:kjr Attachments cc: J. Gruber ATO 1478 M. L. Hagood ATO 1120 S. P. Twiggs ATO 1130 KOE1.4-9 Anticipated Start Date August, 1988 August, 1988 ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Chanqe approved pro,q, ram [] Pluqqinql-'l Stimulate]~;[ 2. Name of Operator ARCO Alaska, Inc. Pull tubing[] 3. Address P.O. Box 100360 Anchorage, Alaska 99510-0360 Amend order[] Perforate [] Other [] 5. Datum elevation (DF or KB) 105' RKB Feet 6. Unit or Property Name Kuparuk River Unit 4. Location of well at sudace 294' FSL, 636' FEL, Sec. 16, T11N, R10E, UM At top of productive interval 1725' FSL, 1667' FWL, Sec. 22, T11N, R10E, UM At ettecuve aeptn 1533' FSL, 1729', FWL, Sec. 22, T11N, R10E, UM At total depth 1533' FSL, 1729', FWL, Sec. 22, T11N, R10E, UM 1. Present well condition summary Total depth: measu red 8 44 0' feet true vertical 6 514' feet 7. Well number 1E-2 8. Pe r~t0_nb~nbor 9. APl number 50- 029-20472 10. Pool Kuparuk River Oil Pool Plugs (measured) Effective depth: measured 8331' feet true vertical 641 4' feet Junk (measured) Casing Length Size Structural . Conductor 8 0' 1 6" Sudace Intermediate 30 51' 10.75" Production 842'1' 7" Liner . Perforation depth: measured 7959'-8050', 8182'-8204', true vertical 6078'-6160', 6280'-6300', Tubing (size, grade and measured depth) 3.5" J-55 @ 8103' Packers and SSSV (type and measured depth) Cemented Measured depth True Vertical Depth 240 sx AS II 80' 80' 840 sx Fondu 3051' 2702' &250 sxAS II 575 sx Class G 8421' 6498' R[C[IVED 6313'-6327' ?~U L:~' '~ g~- © !:;;~'b AlasXa 0il & C~s Cons. CommissJo~ Camco TRDP S$SV @ 1802', Baker FHL packer @ 7786', Baker FB-1 packer @ 8081' 12. Attachments Description summary of proposal I~ Detailed operations program I~ BOP sketch 13. Estimated date for commencing operation 8/88 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~' Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. D Plug integrity r"l BOP Test r'l Location Clear_ancel Approved Copy.7 .. Ret.urn~i~'~' ~ ~//~_~ ~;:;" ~ "'~'~"/~by order of Approved by r" k.. Form 10-403 Rev 12-1-85 L._~~ Commissioner the commission Date ~'-2_.. ~-~ Submit in triplicate M. Anderson/G. Wylie'~~ 8/25/88 Page 2 WELL 1 E-2 A SAND FRACTURE STIMULATION PROCEDURE CC: 230DS10EL Pre-frac Slickline and Musol Treatment: 1. RU Slickline. 2. RIH with gauge ring and tag fill (last tag @ 8286'RKB on 12-5-87). 3. Pull C Sand CV at 8061' RKB and replace with DV. 4. Pull GLV's at 7721', 6262', 4866', 3513' and 1869' RKB and replace with DV's (mandrels at 5764', 5269', 4520', 4172', 3829' and 2951' contain DV's already). 5. Run standing valve in Camco "D" nipple at 8091'RKB and pressure test tubing to 3000 psi. Pull SV. 6. RDMO slickline. 7. RU pump truck. 8. Pump diesel/10% Musol and flush with diesel as shown on the attached pump schedule. Let soak overnight. 9. RDMO pump truck. Fracture Stimulation: 10. RU fracture equipment. Install tree saver. Assure that the annulus is loaded with diesel and has _+ 2500 psi pressure on it. 11. Check diesel for contamination. Perform quality control tests to assure good gel is obtainable (Onsite Operations Engineering personnel to coordinate gel testing). Obtain samples of proppant and gelled diesel with breaker. Check proppant for excessive fines. Record proppant weight before and after the fracture stimulation. 12. Pump fracture treatment per the attached schedule. Obtain samples of the pad, slurry and flush during the stimulation. Maintain pressure on the annulus as close as possible to 2500 psi during treatment. Anticipated treating conditions are as follows: WHTPE= 4220 psi Fracture Gradient= 0.77 psi/ft Tubing Friction= 140 psi/1000 ft Recommended Maximum Treating Pressure= 6200 psi 13, SI well. RDMO frac equipment. ARCO Alaska Inc. is a subsidiary of Atlantic Richfield Company KUPARUK WELL 1E-2 A SAND FRACTURE PUMP SCHEDULE: 8/24/88 REVISED STAGE FLUID CLEAN VOLUME PUMP RATE PROP. CONC. PROPPANT PROPPANT WT DIRTY VOLUME HIT PERFS DESCRIPTION BBLS BPM PPG DESCRIPTION LBS STG/CUM BBLS 1 DIESEL/10% MUSOL 50.0 I 0 2 DIESEL FLUSH 73.0 1 0 ............................................. SHUT DOWN OVERNIGHT 3 GD PRE-PAD 100.0 2 0 0 ............................................... SHUT DOWN FOR 4 GDPAD 415.0 20 0 5 GD w/2 PPG 23.0 20 2 6 GD w/4 PPG 42.5 2 0 4 7 GD w/6 PPG 59.3 2 0 6 8 GD w/8 PPG 73.9 2 0 8 9 GD w/10 PPG 55.5 20 1 0 1 0 GD FLUSH 72.0 +SV 2 0 0 TO SOAK ISIP 0 5O/ 5O 73 0 73/ 1 23 1 23 0 100/ 100 73.0 0 415/ 515 173.0 20/40 M SAND 1930 25/ 540 588.0 20/40 M SAND 7141 50/ 590 613.0 20/40 M SAND 14947 75/ 665 663.0 20/40 M SAND 24841 100/ 765 738.0 20/40 M SAND 23322 80/ 845 838.0 - - 0 72/ 837 918.0 NOTES: 20/40 M SAND = 7 21 81 LBS TOTAL GELLED DIESEL= 841.3 BBLS +SV TOTAL MUSOL = 5.0 BBLS TOTAL DIESEL = 118.0 BBLS Stage 1 is Diesel with 10% Musol Stages 3 & 4 are Gelled Diesel with enough breaker for an 8 hour break and with 40 Ibs./1000gal silica flour. Stages 5 through 10 are Gelled Diesel with Iow temperature breaker (6 hour break) and without silica flour. Stage 10 should include a volume adjustment for surface equipment between the wellhead and densitometer (SV). This job is intentionally underflushed by I bbl. The blender tub should be bypassed at flush. All fluids should be maintained at 70 to 90 F on the surface. STATE OF ALASKA ALASKA LAND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL l~( OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 80-50 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20472 4. Location of Well Surface: 294' FSL, 636' FEL, Sec.16, T11N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 98 ' 6. Lease Designation and Serial No. ADL 25648 9. Unit or Lease Name Kuparuk River Unit 1 o. w b er 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Puli Tubing [] Other [] Pulling Tubing ~ (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Accepted rig ~ 1800 hfs, 06/08/85. Killed well. ND tree. NU BOPE & tstd. Stuck tubing while attempting t~ recover. Cut tubing ~ 7610'; POH. Tagged fish @ 7618'; POH w/2 jts tbg and GLM. Retrieved pkr. Made scraper run to PBTD ~ 8312'. Ran 3-1/2" completion assy w/tail @ 8112', pkrs ~ 8081' & 7788', & SSSV ~ 1800 ND BOPE. NU tree & tstd. Secured well & released rig ~ 1530 hfs, 06/17/85. i. RECEIVED JUN :!. 'L 6 AlasKa Oil & Gas Cons. Coalt'nissi:~r~ Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~ ~(j~ ,~,~l~/~ Title Associate Engineer The space below for Commission use Conditions of APproval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 GRU1/SN01 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Attachment ! ! Page g Drill Site 1H Well No. ~1H-4 ~'1H-7 ~'/H-8 _Log Date -- 8/16/82 8/13/82 6/21/82 7/20/82 7/22/82 Drill Site 1E Well No. _Log Date -- 1E-lA xl)/lg/81 1E-2 ~8/17/81~,7 _~"1/17/84/ 1E-3 '"lO/18/81~, "-1117181/ '"{~ I,"' -~-~a/< !E-5 "10/27/81. 1E-6 '~10/21/81 '-~ "-11/12/82,// %'1E-7 '~)/28/81'q, ~ "']o/28/8L,2 --~ 1E-8 '""8/28/81",,, ~11/1/81.,/' 1E-12 "'"11/28/84 1£-15 _'~8/26/82 1E-16 "8/29/82 1E-17 "'"9/1/82 1E-20 '"~5/7/83 .1E-24 "'-2/17/83 1E-25 ~'1/17/83 1E-26 ~'1/13/83 1E-27 '"',110/31/82 1E-2S ~'10/27/52 ]2 '",.6/13/83 l~-e~ ',,lO/~8/82% ',.7/18/83 / 1E-30 '"-10/16/82 Drill Site 1G Well No. .'~1G-1 'x~lg_2 "~1G-3 '~1G-4 %.~G-5 %1G-8 _Log Date -- 9/7/82 - 9/25/8_~ 9/28/82/ 12/8/84/ 10/13/82 11/12/82 3/12/83 1/22/83 Drill Site 1F Well No. _Log Date IF- 1 F-2 F-3 "1F-4 %1F-5. '~1F-6 '~ 1F-7 2119/83 2~3~83 1/31/83 5129183 10/25/82 10/28/82' 11/19/82~ ~ 5/7/83 j FEB 2 1 1986 AJaska 011 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Post Office B 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 24, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1E-2 Dear Mr. Chatterton: Enclosed is a copy of the 1E-2 Workover Well History to include with the Well Completion Report dated 8/21/85. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU11/L112 Enclosure RECEIVED OCT O e Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Oil !i~o Gas Company Well History - Initial Report - Dally Inltn~tiMil: Prepare and mubmit the "IMIMi I~eMt" on ~ flrlt WedneKlay after a well ia aPudded or workowr operetlonl ere mtartod. Dilly work pl~or tO aPlKl(ltne M~uld be ~mml~zed on the form giving inclullvl did[Il only. Field Kuparuk River Au~. or W.O. no. ~ 904503 County. pan~ or Oorough North Slope Borough LeeM or Unit ADL 25648 Title Recompletion State Alaska 1E-2 Pool 102 APl 50-029-20472 ARCO Alaska, Inc. Spudd~ or W.O. begun Vorkover Date and depth ii of 8:00 a.m. 6/10/85 6111/85 thru 6/12/85 6/13/85 6114185 The above is correct Signature For form ~reParatlon' and-~stribufion, see Procedurea Manual, S~ction 10, Drilling, Pagan 86 and 87. D-,e 6/8/85 [.our Complete record for elch dly reported 1800 hrs. ^.co w.,. 56.24% Prior status if & W.O. 7" @ 8421' Wt 11.1+ NaCi~, Kill'g well Accept rii @ I800 hfs, 6/8/85. Repl live GLV w/dummies. brine & BridgeSal pill. Load well w/HgO. A~t to pull dummy GLV; couldn't pull. Cut wiri. RIB w/UA, circ charge & shoo~ hole. Pump 50 bbls BridgeSal. ~cc¢-l-c>~.'F~ /~q 7" @ 8421' 11.1 ppg NaCi? Kill well· ND-tree, NU & tst HOPE. POOH· ch$'g out colrs to A~ Mod. Hole taking fluid. Mx & spot sqz SridgeSal pill. Pull 1 std, cbg stuck. RIH, cuC tbg @ 7610'. POH, chg out couplin$ to A~ Nod. 7" @ 8421' 11.1 ppg Nat19 RIH w/OS, tag~fsh @ 7618', POH w/2 its tbs & GI~. circ bskt, push pkr dn to 7941' POH · RIH v/rev 7" @ 8421' 11.1 ppg NaCI~ RIH w/OS, tag~SBR @ 7949'. POH w/pkr. RIH w/mill, tag contrl in rubbers @ 8027'. Push to btm to mill. RECEIVED OCT 0 2D~'ug Superintendent i 'e& Gas Cons. tommiu~iaa Alaska .......... 7/02/85 Date Number all daily well history forms consecutively as they are prepared for each well. iPage no. AR3B-459-1-D ARCO O!'i dnd Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Rll~rl" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned. or Sold. "Flail Rl~rt" should be submitted also when oPerations are suspended for an indefinite or appreciable length of time. On workovers when an official test ie not required upon completion, report completion and representative test data in blocks provided The "Flail Rel~rt" form may be used for reporting the entire operation if SD&Ce is available. I Accounting cost center code District [County or Parish State Alaska .a~.aska North Slope Borough Field I Lease or Umt I Well no. Kuparuk River ADL 25648 I rE-2 W/O Auth. or W.O. no. ITitie AFE 203882 I RecompleCion Pool 102 Operator [ A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun I Date Workover I 6/8/85 Date and depth is of 8:00 a.m. 6/15/85 thru 6/17/83 6/18/85 Complete record for each day reported AP1 50-029-20472 I otal number of wells (active or inactive) on this oat center prior to plugging and bandonment of this well 1 our IPrior status if a W.O. 1800 hrs. 7" @ 8421' 11.1 ppg NaCI? Mill & wsh co5trl in rubbers. RIH, set BP @ 7880'. Chg out tbg head to 5000#. NU &tst BOPE. POH w/BP. RIH f/scrpr rn to PBTD @ 8312'. RU WL, RIH w/pkr & tailpipe assy. RIH w/perm pkr & tailpipe assy. RIH w/3½" CA. Set pkr, shear SBR, sec BPV, ND BOPE, NU &tst tree. Displ well to crude. 7" @ 8421' Crude/Diesel Displ well w/diesel cap, followed by crude. 1530 hfs, 6/17/85. Tsc SSSV. RE @ Old TD Released rig 1530 hrs. New TD PB Depth Date Kind of rig 6/17/85 IType completion (single. duet, etc.) Single I Officia~ reservoir name(s) Kuparuk Sands Classifications (oil, gas. etc.) Oil Producing method Flowing Potential test data Rotary Well no. Date Reservoir Producing interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P, Water % GOR Gravity Allowable Effective date corrected I, ~/'/~ ~.~~ 7102185 perint endent For form preparation a~ distribution, see Procedures Manual. Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C OCT o 2 Alaska 0il & 6as Cons. 60mmission Anchorage Number ali daily well history forms consecutively I Pagano. as they are prepared for each well. DivisiOn o! AtllntlcRl~MleldCompaay ARCO Alaska, Inc. ~ Post Office B~,, 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 21, 1985 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1E-2 Dear Mr. Chatterton' Enclosed is the Well Completion Report for 1E-2. I have not yet received the Workover Well History. When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU11/L12 Enclosure RECEIVED AUG 0 1985 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] · 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 80-50 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 " 50- 029-20472 4. Location of well at surface 9. Unit or Lease Name 294' FSL, 636' FEL, Sec.16, T11N, R10E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1725' FSL, 1667' FWL, Sec.22, T11N, R10E, UN 1E-2 At Total Depth 11. Field and Pool 1533' FSL, 1729' FWL, Sec.22, T11N, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 105' RKB! ADL 25651 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 06/02/80 06/11/80 06/18/80'I -- feet MSLI 1 17. Total Depth (MD+TV D) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8440'MD,6514'TVD 8331 'MD,6414'TVD YES I~X NO [] 1811 feet MDI 1500' (approx) 22. Type Electric or Other Logs Run BHCS/GR, DLL/NSFL/Cal/GR, CBL/VDL/CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 65.0# H-40 Surf 74'(GL) 24" 240 sx AS II r10~3/4" ,45.5# .~ K-55 Surf 3051' 13-3/4" 840 sx Fondu & 250 sx ilS II 7" 26.0# K-55 Surf 8421' 9-7/8" 575 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 2§. TUBING ,RECORD interval, size and number} SIZE DEPTH SET (MD} PACKER SET (MD) 7959' - 8050' 3-1/2" 8112' 7795' & 8090' 8182' - 8204' w/4 spf 8219' - 8234' 26. ACID, FRACTURE, CEMENT sQuEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production I Method of Operation (FlOwing, gas lift, etc.) 12/15/81I F1 owl ng LDate of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-oIL RATIO 8/18/81 13.4 TEST PERIOD m~ 1572 ** -- 48/64 -- Flow Tubing Casing pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 570 -- 24-HOUR RATE m~ 2750 .... 24.8 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or ware r. Submit core chips. ** Not measured due to separator problems. .,^ RECEIVED AUG 0 Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Rev. 7-1-80 * NOTE: Well was recompleted on 6/17/85. TEMP/WC88 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 7958' 8040' 8168' 8233' 6077' 6151' 6267' 6326' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge · ...... 1 ~?,_ I.~.. ,~},. , Title .... Signed ,' l ?' L:->~) 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 t© be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: 'Attached supplemental records for this well should show the details of any multiple stage cement- 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 ARCO Alaska, Inc.B~ Post Office 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 23, 1985 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1E-2 Dear Mr. Chatterton: Enclosed is a Subsequent Sundry Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU10/L88 Enclosure If RECEIVED JUL Z 0 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany (' STATE OF ALASKA ~' ALASKA OIL AND GAS CONSERVATION C~MlSSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 COMPLETED WE LLx~ OTHER [] 4. Location of Well Surface: 29/+' FSL, 636' FEL, Sec.16~ T11N~ R10E, UN 7. Permit No. 80-50 8. APl Number 50- 0~9-20Z~72 9. Unit or Lease Name Ku.na ruk R~ v~.r 10. Well Number 1E-~ 11. Field and Pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) RKB 98' 12. I 6. Lease Designation and Serial No. Kuparuk River 0i l Pool ADL 256~8 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing I-~ Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other X Pull Tubing [] Other [] Pulling Tubing ~ (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Accepted rig ~ 1800 hrs, 6/8/85. Killed well. ND tree. NU BOPE & tstd. Pulled tubing and recovered pkr. Tstd csg to 2000 psi - ok. Reamed to PBTD. Set FB-1 pkr ~ 8081'WLM. Ran 3-1/2" completion assy w/tail 8112', pkrs ~ 8090' & 7795', & SSSV ~ 1811'. ND BOPE. NU tree & tstd - ok. Disp well w/diesel & crude. Tstd tubing to 2000 psi - ok. Secured well & re]eased rig ~ 1530 hrs, 6/17/85, RECEIVED J U L 3 0 ]985 Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~O~ ~JJ- ~ Title Associate Engi neet The space belov~or Commission use Date Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Form 10-403 GRU10/SN11 Rev. 7-1-80 and "Subsequent Reports" in Duplicate ARCO- Alaska, I Post Offic~ Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 I',f'" "r I r', i'. T .... --,,:- , ..!,-:,.,: 'f' f"l .................................................................~i.:' (::: I !::.:'.'. .................... f':' :1: ,5' ']" 1::: :l: :('""' 'f' ]: '-; i'J ' t..) -.1 ......... /V;*,ska. Oii;,& 6~ C.k,~o-~. ~,,.,.,..::..., · % i. ;-~ ~ ~.- I-.= 'r'.,f:::','l I '"f',!;:;. ',' 1.. ;. ; ,'... I.., ,::. ,-,. ',: ;.:: ~:'..t.L!~. ,r..,,... ,,., .~;--;',,:'~? .... ~ ........ "':' ........ .' '" /~Or:?¢~r::tq~,., "r'~ ~..~.. r-.,,.., -:.~.~. ~.....',: :iF:' H Z'~... L. T F:' ,}7 Ill) Z',. . ..',;.. i I..:1 i'-,~ ..... ]i ~'"' ~'-J '~'. ~i i,! .... ':' ,""i F:' ::~[:' ,.I r' · ..... . ;-./r"~ , ,::. /.. ,, ........ .., ,',,~-: II'1, ~,: ......... ~':'5 K AIaCO ¢,las~a. Inc ~s a subsidiary' Of /~llanllcR,chqe~.~C-ompan'Y ARCO Alaska, Inc. ( Post Office B6~-~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 23, 1985 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: Kuparuk 1E-2 Dear Mr. Chatterton: Enclosed is a Sundry Notice for the subject well. We propose to convert 1E-2 to a selective single completion. Since we expect to start this work on June 1, 1985, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, A~~ a~~~g Engineer JBK/KLB/tw SN/L034 Enclosure '~nchoragnes' Corn~71~ior/ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELLx~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P, 0, Box 100360, Anchorage, AK 99510 4. Location of Well Surface; 294' FSL, 636' FEL, Sec.16, T11N, RIOE, UN 5. Elevation in feet (indicate KB, DF, etc.) RKB 98' 12. 7. Permit No. 80-50 8. APl Number 50- 029-20472 9. Unit or Lease Name KH,nam,k R~Ve~' I_l.~t 10. Well Number 1E-2 11. Field and Pool Kuparuk River Field 6. Lease Designation and Serial No. Kuparuk River Oi 1 Pool ADL 25R4R Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data Perforate Stimulate Repair Well NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) [] Alter Casing [] Perforations [] Altering Casing ~ Abandon [] Stimulation [] Abandonment [] Change Plans [] Repairs Made [] Other Pull Tubing ~ Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 fro' each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to convert well 1E-2 to a selective single completion. The procedure will be as follows: 1. Well will be killed with brine. Weight to be determined after running pressure bomb. 2. Current completion assembly will be pulled. 3. A retrievable packer will be run to test casing. 4. The well will be completed as a selective single. 5. After the rig is released, an acid and/or frac job will be done. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally~ested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: June 1, 1985 14. I here/~rtify)that// //'~~ ' .the foregoing is true and correct t° the best of my knowledge. ' Signed~/./---~'~..,~~~ Title Area Drilling Engineer T h e space.ow f~r ~/or~ iSsi~n us; Alaska 0j~ & Gas Cons. Cornmiss~0n Arm. hnr~n,, Date ~~~.~/~'"~ Conditi~'ns of Approval, if any: Approved by Illl'llkL $1tlEI Approved Co97' Returned By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 (KLB) SN/058 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office ~' 360 Anchorage,,", ~ka 99510 Telephone 907 :;77 5637 RET~ TO: ARCO AI2~, INC. ATTN: Records Cler~ ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Date- ~ y" ~. Transmittal No: 49%'~ ~-~- - Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. -CAMCO- .BHP REP. ORI~/~.U : ~ .. ?.ORQUE 'TURN PBU &. TEMP 12/02, 03/84 ~/1Gi4 12/10,11/84 /lB-3 11/26/84 / /~G-2 12/08/84 ~E-8 12/12,13/84 /lA-.6 10/21,22/84 ~/~C-9 10/12,14/84 ~-11 10/10,12/84 w/iE-3 10/15/84 /2B-4 10/19/84 / 2B-3 10/19/84 SURVEYS ~-4 12/12, 13/84 Gauge #64009 i / 1E-2 10/15/84 /cat Receipt Acknowledged: B. Currier D. rill~ng DISTRIBUTION W. Pasher RECEIVED State of AK BPAE Geology' G. Phillips Sohio Chevron Mobil Phillips Oil Union D&M NSK Ops. J. Rathmell Well Files ARCO Alaska, Inc. Post Offic~..'=ox 360 Anchorag~ ,aska 99510 Telephone 907 277 5637 Date: 1/07/85 Transmittal No: 4942 RETURN TO: ARCO ALASKA, INC. ATTN: Records Cler~ ATO-1115B Box 100360 orage, AK 99510 · ed herewith are the following items. Please acknowledge receipt n one signed copy of this transmittal. · -CAMCO .BHP RERORT~/.f~U : , .. %0RQUE .'TURN PBU &. TEMP SURVEYS · 1F-7 J'~12/02, 03/84 1F-4.? 12/12, 13/84 Gauge f/64009 1G-4 ,L 12/10,11/84 'lB-3 .,,;,' 11/26/84 lO-2/~ 12/08/84 1E-8"' 12/12,13/84 lA-6?'~ 10/21,22/84 1C-9~.~""10/!2,14/84 . . lB-11 ·10/10,12/84 1E-3 ' 10/15/84 2B-4 .... 10/19/84 2B-3 - 10/19/84 1E-2~'' 10/15/84 /cat Receipt Acknowledged: B. Currier DISTRIBUTION Alaska Oil 5, Gas Cons. Co;nmission · ~t~choraqe Drilling W. Pasher State of AK BPAE Geology' G. Phillips Sohio Chevron Mobil Phillips Oil Union D&M NSK Ops. J. Rathmell Well Files ARCO Alaska, Inc. is a subsidiary o! AtlantlcRichtieldCcmpan¥ KUPARUK ENGINEERING TRANSMITTAL TO: Wi'lliam Van Allen FROM: D.W. Bose/Shelby J. Matthews Transmitted herewith are the following' PLEASE NOTE' BL- BLUELINE, S- SEPIA, F- FILM, T-'TAPE, C~---'~ R~E I PT. ACKNOWLEDGED' /~LEASE RETURN RECEIPT TO: · ARCO ALASKA, INC. ATTN' SHELBY J. MATTHEWS - AFA/3!I P.O. BOX 360 ANCHORAGE, AK. 99510 . .- ( STATE Of ALASKA ~i ALASKA .,~ AND GAS CONSERVATION C .,~IlSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ' ,. 1. Status of Well Classification of Service Well OIL (~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 80-50 3. Address B. APl Number P.0.Box 360, Anchorage, AK 99510 50- 029-20/+72 4. Location of well at surface 294'FSL, 636'FEL, Sec 16, TllN, R10E, UN 9. Unit or Lease Name . Kuparuk 25651 At Top Producing lnterval 1725'FSL, 1667'FWL, Sec 22, T11N, RIOE, UM lO, WellNumber 1E-2 At Total Depth 1533'FSL, 1729'FWL, Sec 22, TllN, R10E, UM ll. Field and Pool Kuparuk River FieId .5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 105 RKB ADL 25651 Kuparuk River 0il P. ool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ] 15. Water Depth, if offshore 116. No. of Completions 6/2/80 6/11/80 6/18/80[ __ feetMSLI 1 .17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19, Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 8/+/+0' 651/+' 8331 ! 6/+1/+I YES F-IX NO [] 1826' feetMD 1650' 22. Type Electric or Other Logs Run RHCF,/CR; 131 I /MRFI /CA~ /CE, CR~ /Vnl /CC~ ~CE 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED !6" 65# ~eI,.!ed H-q0 Surf. 80' 2~.'' 2~,0 sx Arct[csst II cmt ~' , 250 sx Arcticset II c~t · · ?,, )K~ n,, K-55 Surf ..8/~.2!! (~ 7/8 575 sx Class G cmt 24. Perforat'ionS ~pen to P~6~tion (MD+TVD of Top and Bottom and 25. TUBING RECORD . interval, size and number) . SIZE DEPTH SET (MD) PACKER SET (MD) . 3 !/2" 7~71 ' 783t: ' 7959'-8050' ' - ' _ _ · 8182'-8204' 26. ACID, FRACTURE, CEMENT SQUEEZE, Nrc, - 821-9'-823/+', w//+ SPF , , DEPTH INTER.VAL (MD) AMOUNT & KIND OF MATERIAL USED. .~!/A 27. PRoDUcTION. " ' ' TEST Date Fdrst Production , Method of Operation (Flowing, gas lift, etc.) ._ 12/1~/R1 I F1 Am{nh Date 0~e's:~ ' - Hours Tested PRODUC~I~)~I"F~:51~ OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-01L RATIO - R/.,iR/R1. 1'~ /, TESTPERIOD ,m~ ~,1~-/,~ .x.~ ~,o/~hII __ · , FIo~'lZu'~In'~' C,~n~r.essure CALCULATED OIl.'-~l~' ,i GAS-MCF WATER:BBL· OI~'G/R'~-~VITY-API(corr) Press. 570 -- .. 24-HOUR:. RATE.I~. 275~ORE D~,TA 2/," 28. -" Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips, · *Not, measured due to separator p~obZems. : ' '" N/A REC. E'IYED . -' ',FJ~tr;I~ ~ & 6as Cons. Commis.~io~ Submit in duplicate 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. -'- 30.' GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kupacuk River Form. 7958' " 6077' Base Kuparuk River Form. 8273' 6362' ,. 31. LIST OF ATTACHMENTS , ,, 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ' Signed '~. (~ .(~~~ Title Area 0ps. En.r. Date MAR 10'19~ /1.' '-._ /¢ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log .on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production'.from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the .:data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- 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 i;O~'i-ll '~LP,?:Z EilGI~'EEF',ii'~' F~,CM' J.J. PLEACE._, ,,O~L" ?~' BL - BLU~-LI,~- "E, S - SEPIA, F - FILM, T - TAPE .... , . ,, ......... . ~ ~ p,~ ,~ Al:dca OH & Gas Cm~,s. Commission PLC2,~~ kETI;,,,,, LLu~¢,'l TO. A,~Cu At_,,¢¢~, Jl,~. Mchola. gc 'L ATT~' At~t~ SLMO;~&Er! - AFA/311 P.O. BOX 3~0 STATE OF ALASKA (,r. ALASKA ~L AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O.BOx 360, Anchoraqe, AK 99510 4. Location of Well Surface Location: 294' FSL, 636' FEL, Sec. 16, TllN, R10E COMPLETED WELL [] X 7. Permit No. 80-50 8. APl Number OTHER [] 50- 029-2-472 9. Unit or Lease Name Kuparuk 25651 10. Well Number 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River Field KB=!05' ~nr. ?KR~I R,]p~rn~ River Oil. Pod. 1 12. Check Appropriate B~-T~ I~-d~c~'e-Nature of Notice, Report, or Oth~r~a~a NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [~ Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed'work, for Abandonment see 20 AAC 25.105-170). Began cleanout operations on 8/14/81. RU CTU & test to 4000psi. RIH & pump diesel to 4810'. Could not get past gas lift mandrel. POH & change BHA. RIH & pump diesel to 7000'. Change over to Gel WTR. & RIH to 8310'. Displaced TBG Vol. Pumped total 115 bbl Gel WTR. Change over to diesel, pumped 60 bbl. POH & RD CTU. RU to perf & test lub to 3000 psi. Perf'd intervals 8219'-8234', 8182'-8204', 8020'-8050 7990'-8020', & 7959'-7990' w/Schlumberger 2 1/8" Enerjet w/4 SPF. RIH with Gradio, Temp, Spinner & HP. Open well to flow @ rate of 2750 BOPD. FTP=570 psi, FBHP=2347 psi. Ran production logs. SI well f/PBU. Final BHP=3093 psi. Secure well on 8/19/81 NOTE: HP Tool set at 5944'ss 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed I~.~)~,~)~ Tit,e Area Operations Engineer The space be for Commission u~ Conditions of Approval, if any: %/ Date By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate S0H I(1 COHF I DEIqT I AL SOHIO ALASKA PETROLEUM COMPANY ARCO C, ctty 31 1 1 "C" S1HEET ANCHORAGE, ALASKA IELEPHON[ 1907) 265-0000 MAIL: POUCH 6-612 ANCI. tORAGE. ALASKA 99502 Date: 9/16/81 # ]06_3 R[~ ERFNCE: SOHIO FINAL DATA The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:- SFO/UNIT/STATE: (-Marathon) C-5 Bottom-Hole Pressure Data Form & Survey (Go) 9/3/81 :~E-2 " " " " " " (Go) 8/3]./81 ~~r~/~~~e ter ~3ment Geology '~ecord s NORTH'~LOPE E~GI~.~EERIi;G (" J. J. Pa;velek/Ann Simonsen Transmitted herewith are the following' S - SEPIA, F - F~LM, T - TAPE .ACK;:OWLED~~' .... , -.. //E?,,SERETL:R~ RECEI?T TO: ARco ' ALAS>CA, INC. ..... ;,I ;..q ,~1 ATTN A,~,~ SI,.0,~E,. , - AFA/31 l P.O. BOX 36O RECEIVED DATE- SEP 1 4 ]98] Alaska Oil & Gas Cons. Commission Anchorage LATE' ~---_C~ WELL Transmitted herev:ith are thc, folie~,:ing' PLEASE ~:OTE~_~-BLUELiiiE, ~S)- SEP~', ! F - FiLhi~ T - TAPE - AFA/31 1 1. DRILLING WELL [] COMPLETED WELL ~x OTHER 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 80-50 3. Address 8. APl Number P. O. Box 360, Anchorage, Alaska 99510 50- 029-20472 4. Location of Well Surface Location: 5. Elevation in feet (indicate KB, DF, etc.) KB : 105 12. 294' FSL, 636' FEL Sec. 16 TllN-R10E I6. Lease Designation and Serial No. ADL 25651 9. Unit or Lease Name Kuparuk 25651 10. Well Number 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing StimL~late E] Abandon [] Stimulation [] Abandonment Repair Well r-] Change Plans [] Repairs Made [] Other Pull Tubing [] Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to cleanout drilling fluids in cased hole which cover the Lower Kuparuk Sands. The work will be done using a coil tubing unit with BOP assembly tested to 4000 psi. The well will. then be perforated in both the Upper and Lower Kuparuk Sands. A 3000 psi lubricator will be used for all wireline work. All circulated and flowed fluids will be diverted to tankage on location. The well will not be tested at this time. Expected start date 8-15-81. SuSsequent Work lte~orted 1 · I 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. , Conditions~ofThe space ~41ow for Commission usc i Approval, any' if COMMISSIONER ~he Commission Dale__ 8/ 2/s1 Form 10-403 Rev. 7-1-80 Subm,t "Intentions" in Triplicate and "Subsequent Reports" in Duplica;e I ..... i coM ' -I NORTH SLOPE DISTRICT ENGINEERING /_---~NG-----' ,, TRANSMITTAL # ~5/~~'- L~r-i'-GEo~~N~---'-- " TO' ~v ¢~-. ~/~' FRO.' Jerry O. Paw.el eL/Leo L~s~:;~~-- DATE' ~F ~-, ~' ~ ~6 WELL NAME' ~e,~& E-~ ~tF~ ~ T~ansm~ed herewith a~e ~he ~ollow~ng ~o~ ~he sub~ec~ well: BL DATE SCALE XEROX SEPIA LINE FILM BHC Sonic/Gamma Ray Log Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. COre Description (SWC) - Interval Core Description (Conv.) - Core No. Directional Survey - Gyro Single Shot Multi-shot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Spectral og TVD-DIL Differential Temperature Log Spinner Survey Fluid Density Casing Collar Log Perforating Record Neutron Lifetime Log Carbon-Oxygen Log RECEIPT ACKNOWLEDGED FOR: DATE: L~~EASERETURN RECEIPT TO- ARCo Oil and Gas Company /~ttn: Mr. Leo Lash P.O. Box 360- Rm. #311-FAB Anchorage, AK 99510 September 24, 1980 Mr. Hoyle Hamilton State of Alaska Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' As-Built Survey Plats Dear Sir' '"~"~ ...... '"" In an effort to insure that your files are complete, we hay c copies of our well location as-built survey plats for all wells permitted thus far in 1980, excluding those included in our original drilling permit applications. Very truly yours, P. A. VanDusen District Drilling Engineer PAV/JBK/jh Attachments I HEREBY CE EROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS AN AS- BUILT SURVEY MADE BY ME, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT, AS OF: _ F-'6.~ ~ > . EZ 7TIFY THAT I AM WELL WELL #7 WELL #6 WELL WELL ,~4 WELL /3 WELL #2 WELL Y 5,960,600°230 X = 549,889°825 LAT ~ 70°18Illo283,, LONG = 149o35'45°185,, Y = 5,960,480.368 X = 549,889.486 LAT = 70918'100104" LONG = 149o35545o219,, Y = 5,960~360.207 X = 549,889.255 LAT = 70°]8~08o923,, LONG = 149o35~45o249'', Y = 5,960,240.4]0 X = 549,889.039 LAT = 70°18~07o744,, LONG = 149o35'45°278TM Y = 5,960,120o]55 X = 549,889o818 LAT = 70°18106o56lI, LONG = 149o35,45o279,, Y : 5,960,000o596 X = 549,889°506 LAT = 70o18'05.386,, LONG = 149o35'45.311,, X = 5,959,88o°504 Y = 549,889.996 LAT =' 70°18~04o204,, LONG = ]49,35'45°320" X = 5,959,760.244 Y = 549,889.514 LAT = 70°1'8~03o022,, LONG = 149o35'45°358'' I).:o. F::: WELLS 1-$) LOOATIo AllanlicFlichfieldCompany ~i~ DAF~'~.~-"'- ]DRAWING NO.TH AMERICAN PRODUCING DIVISION I,~/17/~01 ALASKA DISTRICT--'"---KUPAIRUK · No: NORTH SLOPE DISTRICT ENGINEERING TRANSMITTAL TO' ~ ¥ ~ ~ FROM' Jerry J. Pawelek/Leo Lash Transmitted herewith are the following for the subject well · T-~PE BL DATE · ~ XEROX SEPIA LINE ,, .... cOMM_j~ CoMr<~-----] CONFER: FILF: FILM BHC Sonic/Gamma Ray Log Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. COre Description (SWC) - Interval Core Description (Conv.) - Core No. Directional Survey - Gyro Single Shot Multi-shot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Spectral og TVD-DIL Differential Temperature Log Spinner Survey Fluid Density Casing Collar Log Perforating Record Neutron Lifetime Log Carbon-Oxygen Log RECEIPT ACKNOWLEDGED FOR: DATE: ASE RETURN RECEIPT TO' ARCo 0i] ~nd G~s Company Attn: Mr. L~o L~sh P.O. Box ~0 - Rm. #~-FAB Anchor~g~ Al( gg~lO NORTH SLOPE DISTRICT ENGINEERING TRANSMITTAL FROM' Jerry J. Pawelek/Leo Lash WELL NAME' Transmitted herewith are the following for the DATE. BHC Sonic/Gamma Ray Log Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No, Core Description (SWC) - Interval Core Description (Conv,) - Core No, Directional Survey - Gyro Single Shot Multi-shot Drill Stem Test - Test No, Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Spectralog TVD-DIL Differential TemPerature Log Spinner Survey Fluid Density Casing Collar Log Perforating Record Neutron Lifetime Log Carbon-Oxygen Log subject well' BL SCALE XEROX SEPIA LINE FILM RECEIPT RETURN " 8, 1980 DATE' RECEIPT TO' ARCo 0~1 an~ Gas Company A~n H~. Leo Lash P.O. BoX 360 - Rm. ~3~-FAB Anchorage, AK 99510 NORTH SLOPE DISTRICT ENGINEERING TRANSMITTAL TO' )~1 v' ~v,, DATE' -~-//~/~) FROM' Jerry J. Pawelek/Leo Lash WELL NAME' /~.P,~./C_ ~- Transmitted herewith are the following for the subject well' DATE SCALE XEROX SEPIA BHC Sonic/Gamma Ray Log Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.) - Core No. Directional Survey - Gyro O-9'~,~" Single Shot Multi-shot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Spectral og TVD-DIL Differential TemPerature Log Spinner Survey Fluid Density Casing Collar Log Perforating Record Neutron Lifetime Log Carbon-Oxygen Log BL LINE FILM RECEIPT ACKNOWLEDGED FOR' DATE- PLEASE RETURN RECEIPT TO- ARCo Oil and Gas Company Attn' Mr. Leo Lash P.O. Box 360 - Rm. #311-FAB Anchorage, AK 99510 BY' NORTH SLOPE DISTRICT ENGINEERING TRANSMITTAL # ~_~o~ ~- FROM' Jerry J. Pawelek/Leo Lash WELL NAME' /~/~1 ~P-~ Transmitted herewith are the following for the subject well' -FI,LF~ ' , DATE SCALE XEROX SEPIA _ . BHC Sonic/~y Log Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density ,,~'~ Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.) - Core No. Directional Survey - Gyro Single Shot Multi-shot Drill Stem Test - Test NQ. Dual ~ Laterolog Formation Density Log Formation Density Log/Gamma Ray Spectral og TVD-DIL Differential TemPerature Log ' Spinner Survey Fluid Density Casing Collar Log Perforating Record Neutron Lifetime Log Carbon-gxyge~ Log -- RECEIPT ACKNOWLEDGED FOR: DATE :A~ PLEASE RETURN RECEIPT TO' ARCo 0~1 and Gas Compan~ A~n: Hr. Leo L~sh P.O. Box 360 - Rm. ~311-FAB Anchorage, AK 99510 BY' BL LINE FILM ! ARCO Oil and Gas Company ~ North Siop~ .... ~Irict Post Office ~.~x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 11, 1980 Mr. Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99507 Subject' DS 6-14, Permit No. 80-31 KuParuk Well E-2, Permit No. 80-50 Dear Sir'. Enclosed please find Completion Reports with corresponding Drilling Histories and Gyroscopic Surveys for the above-mentioned wells. Very truly yours, P. A. VanDusen District Drilling Engineer PAV'cs Enclosures ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Form P--7 .~ SUBMIT IN DU ' ,t, lc* STATE OF ALASKA (See other in- structions on reverse side) OIL AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: OwIELLL~-~ GAS r--I WELLI I DRYD Other b. TYPE OF COMPLETION: NEW WORK DEEP- r--I PLUG r'-I DIFF. WELL[~] OVER['--] EN I I BACKI I RESER.r-'I Other 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360 Anchorage, Alaska 99510 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface 294'NSL, 636'WEL, Sec 16, TllN, RIOE, UM At top prod. interval reported below 1725'NSL, 1667'EWL, Sec 22, TllN, RIOE, UM At total depth 1533'NSL, 1729'EWL, Sec 22, T11N, RIOE, UM 5. APl NUMERICAL CODE 50-029-20472-.00 6. LEASE DESIGNATION AND SERIAL NO. ADL 25651 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Kuparuk 25651 9. WELL NO. E-2 (23-22-11-10) 10. FIELD AND POOL, OR WILDCAT rudhoe~lav- uparuK ~lve? Oil Pool 11 ~ ~E~C.;' T.; R., M.,~(~OTTOM I-:IOL~E OBJECTIVE) Sec 22, T11N, RiOE, UM 12. PERMIT NO. 80-50 13. DATE SPUDDED 6/2/80 18. TOTAL DEPTH, MD&TVD 119. PLUG BACK MD&TVDI20.1F MULTIPLECOMPL., 8440'MD 6514'TVDI D~i'MD, 6414'T~DHOW,I~I.~NY% ~ng/e ~ .1R OTARY TOOLS 22. PRODUCING INTERVAL(S), OF THIS COMPLETION - TOP, BOTTOM, NAME (MD & TVD)* Tg~.._Upp._e_~..,_..~:nsI 795~3'MD 6077'TVD Top Lower Sand 8168'MD 6267'TVD Base Upper Sand 8040'MD 6151'TVD Base Lower San, d 8233'MD 6326'TVD 24. TYPE ELECTRIC AND OTHER LOGS RUN BHCS/GR~ DLL/MSFL/CAL/GR~ CBL/VDL/CCL/GR 25. CASING RECORD (Report all strings set In well) 16" 65# Wel'ded I H-40 174'belowGL 24" 240 10-3/4" 145.5# Butt I K-55 I 3051' 13-3/4" 840 7" 126# Butt I K.55 I R421' I 9-7/8" I 575 INTERVALS DR ILLED BY i CABLE TOOLS ~ 23. WAS DIREC'~IONAL Base K~paSrU~EY MADE ~~D,.~,6:3,~ ~ T V~Y])~ Yes 26. LINER RECORD SIZE TOP (MD) BOTTOM (MD) CEMENTING RECORD sx Arcticset II cmt sx Fondu cmt & 250 sx Class G cmt AMOUNT PULLED x Arc~ icseti cmt N/A 28. PERFORATIONS OPEN TO PRODUCTION SACKS CEMENT* I 27. I .TUBING RECORD SCREEN (MD) SIZE DEPTH SET (MD) 3-1/2I'7871' PACKER SET (MD) 7834' N/A 30. (Interval, size and number) 29. ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) I AMOUNT AND KIND OF MATERIAL USED PRODUCTION /; ~ ........... PRODUCTION METHOD (Flowing, gas lift, pumplng~lze and type of pump) ....... :~':'~ .~, (' ~ELL STATUS (Producing or OIL--BBL. GAS-MCF. WATER-B~L'~ ~ GAS-OI L RATIO I DATE FIRST PRODUCTION N/^ DATE OF TEST. I HOURS TESTED CHOKE SIZE I PROD'N FOR I I TEST PERIOD FLOW TUBING ICASING PRESSURE CALCULATED OIL-BBL. PRESS. I 24-HOUR RATE 31. DISPOSITION OF GAS (Sold, used for fuel vented, etc.) GAS--MCF. WATER-BBL. I OIL GRAVITY-APl (CORR.) I TEST WITNESSED BY 32. LIST OF ATTACHMENTS Drilling Histor.¥ & Gyroscopic Survey 33.1 hereby certify t~.agoing and ~ached In~;{rmatlon Is complete and correct as determined from all available records. 7~/,/~. ~/~ District Drlg. Engineer SIGNED TITLE DATE 7/9/80 *(See instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other sp§ces on this form and in any attachments. Items 20, and 22: If this well is completed for separate production from more than one interval zone (multiple corn; pletion), so state in item 20, and in item 22 show the producing interval, or intervals, top(s), bottom(s) and name(s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produced, showing the additional data pertinent to such interval. Item 26' "Sacks Cement"' Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, 35. GEOLOGIC MARKERS WATER AND MUD NAME ME'~,S. DEPTH TRUE VERT. DEPT None Top Upper Sand 7958' 6077' Base Upper Sand 8040' 6151' Top Lower Sand 8168' 6267' Base Lower Sand 8233' 6326' Base Kuparuk 8252' 6343' 36. CORE DATA, ATTACH BRIEF DESCRIPTIONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS AND DETECTED SHOWS OF OIL, GAS OR WATER. _ None DRILLING HISTORY KUPARUK WELL E-2 (23-22-11-10) API 50-029-20472, ADL 25651, Permit No. 80-50 Spudded well @ 1500 hrs 6/2/80. Drld 13-3/4" hole to 3084'. Ran 10-3/4" 45.5# K-55 csg w/shoe @ 3051'. Cmtd csg w/840 sx Fondu cmt followed by 250 sx Arcticset II cmt. Did 120 sx Arcticset II top job. Installed pkoff & tstd to 2000 psi. NU BOP & tstd to 3000 psi. Drld thru FC, FS, cmt + 10' new hole. Tstd form to 12.5 ppg EMW. Drld 9-7/8" hole to 8440'. Ran DIL, tool failed. Ran density log, BHCS/GR, & DLL/MSFL/CAL/GR tools. Reamed & circ to TD. Made 55 stand trip, tight @ 8238' Had 10' fill on btm. Fnd mud gas cut to 10.3 ppg. Unable to pull wear b~shing. Ran 10-3/4" bridge plug to 532' & set & tstd. ND BOP & spools. Replace & NU new spools. NU BOP & tstd. Pulled bridge plug. Stage in hole to TD, normal drag. Ran 7" 26# K-55 csg w/shoe @ 8421'. Cmtd csg w/575 sx Class G cmt. Set pkoff & tstd. Ran gage rng & ink bskt to FC. Ran Gyro/CCL & CBL/VDL/CCL/GR. Ran CBL. Downsqueezed 50 sx Arcticset II cmt followed by 116 bbls Arctic Pack in 10-3/4" x 7" ann. Ran 3-1/2" tbg w/tail @ 7871' & pkr @ 7834'. Set pkoff. Reversed out mud w/H20 & HeO w/diesel Set pkr & tstd tbg, pkr, & hanger. Began 48 hr tbg tsp. Rel6-ased rig @ ~000 hrs 6/18/80. C d. A. Fouch~ President _Mr. Bob Hines Arco Oil & Gas P. O. Box 360 Anchorage, Alaska Dear~. Hines: 99510 Re: June 6, 1980 Our Magnetic Multi-Sho~Survey Job No. MS-16601 Well E-2 Kuparuk Field North Slope, Alaska Date of Survey: June 5, 1980_. Operator: Blaine Baertsch Please find enclosed, the "Original'~ and one copy of our Magnetic Multi-Shot Directional Survey on the above well. Also included are the field data sheet and film[ giving us this opportunity to be of service. Thank you for o~ Yours very truly, K~/kc SPERRY-SL~N, INC. District Manager Enclosures RECEIVED JUL 1 0 1980 ~. ~ , ~ ., OIL AND GAS KUPARUK FIELD ALASKA PAGE 1 DATE OF SURVEY dUNE 5, 1980 V E R-'T-i'C'X L ' S E'C TI'ON ..... D IR' E'CT'I-ON--'S ~- 30 "-'39'; 00 E MAGNETIr._.!.... ~ ................................................................................................................................................ MS-16601 ..... ~ ,'~ULTI,~HOT .................................................................. SPERRY-SUN, INC, RECORD OF SURVEY TRUE SUB COURSE COURSE DOG-LEG TOTAL "~~-~'~ ...... V E ~ T I C A L S E A I DJ C E"~Y~6~-- .... ~"i' ~ ~'~'T '~'~'N-- .......... ~'~'V ........ ~i~"O~-A-N-~-L~-R ......... C~-dR"D"f ~I'T'E'S ........... V E R'T I c'~ L DEPTH DEPTH TVD DEG' MIN DEG MIN DEG/iO0 NORTH/SOUTH EAST/WEST SECTION ........................................................................................................900.00 900.00 795.00 ASSUME VFRTICALZ ............................................. TO DO0 FEFTZ ............................... ~"20'0 ~ ..................... 1020,00 1019.97 914,97 1 ~5 S 54 0 E 1,~6 1,OB S 1111.oo 1~0.~9 lOO5.89 $ o s ~ o E 1.65 ~.89 S .... i-'20'2~00 ............ ~'~01.62 1096.62 5 30 $ 33 0 .... E ..... 2~-75 9'",'55 .... S 1294.00 12m2, .72 1187.7~ 10 15 S 33 0 E 5.16 20.11 S O.O0'E ........... 0.'00 1.48 E 1.68 3.90 E 5.34 7;58 .... E ............. 1'2~07 14.44 E 2~.66 1385.00 1~81.81 1276.81 13 i5 S 32 0 1476.00 1469.99 1364.99 15 15 S 34 0 E 2.26 54.52 S 56.60 E 65.56 1568.00 1558.54 lq53.54 ]6 15 S 36 0 E 1.24 7~o96 S 50.93 E 90.45 .......... .... ~'659.00 .......... i~4'~"~88 1539.88 20 30 S 59 0 E 1750,00 1729_ .~,=2 1624.32 23 15 S AO' O E 3.05 123.80 S 90,02 E 152,~0 1953,00 1892.65 2027.00 1972.13 2121.00 2C48.89 2215.00 2]22.69 1707.69 1787.65 1867.13 19q3.89 2017,69 26 45- .......... -S .... $"~/': ....... b--'E-- ..... --~-~-0-5 ...................... f5~-;'2'G ...... S .................. 1-1-4g'17 ..... E ............ 190';'9'1 ............ 30 15 S 56 0 E 3.88 189.17 S 139.97 E 234,10 34 15 S 34 0 'E 4.~0 230.27 S 16~,.69 E 284.10 -- ~ 6 15 S ~-5---~' -E '2';2 ! ................ 2'7'4-;-9'7-S 199 ', z¢ 3'- F. ............. ~ ~'8',- 22 ........ 40 15 S 35 0 E 4.26 322.63 S 232.80 E 396.2~ 2403.00 2258,29 2153.29 2492.00 2320.11 2215.11 2591.00 2389.04 2284.0~ 2692.00 2459.36 2354.36 44 30 46 0 46 0 45 45 46 0 S 34 0 E ~.5'8 ................... ~'7~;A-4'-'~ ..................... 2'A'-SlGS"E ............... ~59;'43--~ S 34 0 E 1.60 ~30.18 S 305.9~ E 526.07 S ~4 0 E 0.00 ~83.26 S 3ql.78 E 589.98 S 34' d'-'-E ........... ;'25 ............... 542;17 .... g 381"'52-F ............ 660;92 ........... S 34 0 E .25 602.28 S A22.06 E 733.30 -'--2-~f ~/~,''' O0 2519. i 0 24 14.10 46 0 S ~4 0 'E ............. 0-.-'0'0- ................... 65'.~';'5'6'---S ...................... 45'6"~-6'6' 'E ............ 795','0"6 .......... 2872.00 2b~4.~0 2479.40 q6 0 S 3q: 0 E 0.00 709.62 S 494.47 E 862.56 2966.00 26qS.BO 25~3.80 47 30 S 33 0 E 1.77 766.71 S 532.25 E 930.93 -"~-~'~i'6'~-- '~:'f'~;-~"~--2565.~7-- ~7 A5 S 33 ...... O E .7'8 "?'86-2'5'~---S-- '545';"12-'E ............. 954,'56 3'08~.00 2728.19 2623.19 47 ~5 S 33 0 E 0.00 839.93 S 579.79 E lO18.1& JUL 0 ........ Alaska Of! & G,.~ [.:. ARCO OIL AND GAS PAGE E-Z DATE OF SURVEY dUNE 5, 1980 K~p~'~K .... ~-T'F~-6 ........... VE'~"I'C~['-S'E'CT~i~N"DIREC¥'i-~'-S-30'3~-O0-£ .ALASKA .M&GNETIC .... ~ULT,!S.!t,O~ .................................................................... MS-lf601 SPERRY-SUN~ INCo R[CORD OF SURVEY ..................................... ** THE CALCULATIONS ARE BASED ON THE MINI-M-U~i--R--A--~-I-'O-S---O-F--~-UR-V~"TO-R-E--M-E"T-F~'bD .... ~'* .................................................... ................................. H C.R.I.Z O.N._T...~: L .... [~_I ~ P L.A. C E ~_~..N_'_T.._=_ ........... 1.0 2 0 ,. 6 ,!._. E F E T .... .A. l'__. S °.U T_H.__.3...~ .D E..G -. .... 3.~ .... M I N..._ ._..E A. ~ T .. (. T R U E ) START OF SURVEY WAS 105.00 FEET ABO-VE SEA LEVEL E=stm n / A PETROLANE COMPANY REPORT of SUJg-SURF~CE DiRECTiONaL SURVEY ARCO OIL & GAS COMPANY Pad ~E, Well NO: 2 WELL NAME Kuparuk Field, North Slope, Alaska LOCATION JOB NUMBER A580R0358 TYPE OF SURVEY DATE p~ Hagnetic Single ~ ?,,:~;"',,;~ , /:.~ ! / July 8 198( .~ :, SURVEY BY Don LeJeune OFFICE Alaska Eastman P. O. Box 4-1970/Anchorage, Alaska 99509/(907) 349-4617 TWX 910-881-5066/Cable: EASTCO July 8, 1980 ARCO OIL & GAS P.O. Box 1479 Anchorage, Alaska 99510 Well Number: Pad E, Well No: 2 Location: Kuparuk Field, North Slope, Alaska Type of Survey: Sperry Sun, MMS, 0-2998 MD Eastman Whipstock, Magnetic Single Shot from 3335-8360 Surveyor: Don LeJeune .~ Job Number: A580R0358 ATTN: Bob Hines Dear Mr. Hines, I am enclosing the original and one copy of the Magnetic Single Shot Survey run on the above mentioned well. We wish to take this opportunity to thank you for calling on our services and trust that we may continue to serve you in the future. Sincerely. District Operations Manager Alaska District JT/cw cc: file enc. Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide AI:?.CO 'J:I:L. ANB G~.~S F'A'[:I E:~ NEI..L NO: t~UPARUt~' FIEI..~)., i'~ORTH SL. OF'E~ AL. ASKA .......0-'-2998 tl.0~ Ni"lS~ BY SF'EI:~:RY--SUN~ BATE: RUN~ ~[--.,JLti'-~-80 ' ' ' 'J C' A",: "Z 'i' "" i:." [ .z, :., ~ _, ~ ,~ ,., - 8~.,o":' ,'~,.. M II ? D R I. L. L E R ~ B L. E ~.t U E N ["' ,JOB ~(3~ AAS':.')D0371 V fi!: R 'i" .1: C: A L. ;ii; E C 'T' ]: 0 N ~:; A L. C U L A T E I) Z N F' L. A N E O F F' R 01::' 0 S A L I:~IR[:-/;T:[ON~ S 30 OE:G. 39 MiN. E RECORO OF' SL.IRVEY RAZ~II.JS OF' CURVATURE: METI"IOB · . ,::LOf:'E;, ALA."',K~.~ X U P.A R U 1'( F' I I:i: L. D, N 0 F;; T I--I '] . "' "" COMPUTATION T I i'fiE DA TE 10 ~ '? 8.1 '" '" . .... .... ,...,.t, 07-. II IL -80 PAGE] NO~ · 1 · ...... TF:,'UE ..... "iEASLJRED I) RIF'"T DRIFT COURSI:': VERTICAL. VERTICAL SUBSEA R E [.'. 'l' A N G U L. A R C L. 0 S U R E I) OGLEG ;OEF:"T'F'I ANGL. E I) tREC:TION. L.E:NGTH DEPTH SEC. TION TVI) C 0 0 I:;,' I) I ~ A T E S I) IE;TANCE I) IRI::'CTION SEVERIT F' E E T D M D i'"i F E E T F' E fi: T F' E E T F:' E: E T F' E E T F' E E: ']" i) i"i i] G / :L 00 I::' · Oo 0 0 0 0 0. 0,00 0+00 -105,00 0,00 0.00 900, 0 0 0 0 900 + 900,00 0,00 79':5. O0 O, O0 0. O0 :1. 0...'? o,.. 1 4 ..,'::' .q.. ,..~-'l 4 0 E: 140 · 1019. q:'. 1:.~ 1, :, :::: 9. 14 .98 J.. 08 S t. 48 [:' 11t. 1, 3 0 :i3 33 0 L:; 91. 11.10.9'0 5.34 1005.90 S,80 S 4.06 E 120"-), t', '30 S :'.~: 3 () El 91 1201,64 1 "'. "~'" _ '" . .... .:: ~.o 1,';';'4,64,.,_ 9,45 S 7,74 E O, 00 0 0 0. O0 0 0 :1., 83 c:..~':4 0 E: Ei '":; ' c. .,._o .., 46 57 E 1"2,21 S 39 18 E 0,00 0,00 i. 46 1.6..'5 2+75 ~4, 10 15 S 33 0 F: 138,_,':'-, 17 :I. ,.':; S 3..:"' 0 E 1476o 15 1.5 S 3.4 0 E 1568, 16 1,., =' S ,.".~,4_ 0 E ,1659, 20 30 S 39' 0 E: 92. 1292,75 24,67 1187,75 20,02 S "~-4 .... ~" 91. 1381,8S'' ' 43,19 1~.7~.,83 · .~.),~).. S 910 1470,03 65,57 1365,03 54,43 S ~o 1 ='=~ ~; ' ~:;-~ ~' TM -' ' '- ~ ~ 8,.. 7. 9. 0,46 1.4 ,.. ~, .,, / 4 ~ ~ 9 S 91, 1644,91 ........ 118,94 1.539,91 97,64 S 5,1.6 3.30 1+24 4,78 1750, 23 1,.., =' .,:I.. 40 0 IE 1 ,..'~ . :-'~ , c.,-t.-: 2,-% 45 S 37' 0 E: 19'"'(3. 30 1~'~.,E; 3.5 0 E: .,:0.,.7, 34. 1,_ S ..-, 0 E: ":21:21, 36 15 S 35 0 E 2692, 46 0 S 3.4 0 E 2778, 46 0 S 34 0 E 2872, 46 0 S .]~4 0 E: 2966, 47 30 S 33 0 E 91, :1. 7,_') 9.35 :'~ :': 1 .-,,:. ~:' "', 4~-' 1 6._'~ 4 · 75 1 '"'~-.:.:,-', fi: 0 S 90 · :1. 0 E: ¢~,2. 1~12,;: 190,94 ::' 1707,'72 : 1;, ~4''.22 E;, 1i4,30 E 91, 1892,68 ':: ':'x : 13; 1 -" <''-' 68 1 ':" ... ~..., 4, ,. ,::, / . ,., 9,12 S : 1-40 · 1 ':' E: ...... ,:: 8E: 94. 197"'~.J. 6 2:":~4,1~ :: 1867,16 03'0.20 S ' ' -" ~"~ 274 90 S .7199,61 E: 9.:I,'- 2048,9'2 338 +:26, 194,~, . ~ , , · .. 94, 21''~'::' 73: 396,:')? 2017,/ 'X':)':, ":'~'. 232 ,~ .......... · ,..~,., S ,98 E: ..... ~ :1. 1 S 36 3 E 191 , 9._. =: ._q 36 ~.':._. TM E 235.,37 S S6' 72 E: 285,50 S S6 :L6 E S79,73 "'B,~,':='~ ,.,='~'"/ E: 397 · 90 .c; -.,,..- ~-. ,. ,.a,._, oO E: 94, 2192,16 · 459,47 2087,16 S74,76 S 268,86 E 461+23 'S 35 39 E:.' 94, 2258,33 526,11 21.53,33 430,10 S 306,19 E 527~96 S S5 27 E .~9, .~...~. ,1,4.. 590,02 .~..1...16 483,1~ S 1.99 E .. 91~..9,4_ S,~o:' 17 E: 99, ': TM o ~, 08 66":. 96 "~ o o . . ~ ' S 81, E 663.01 S 35 9 E 101, 2459,40 733,34 2354,40 86, 2519,14' 795+09 2.414,14 94, 7'~;° ~. .a .... '.') 6 '~ .,:._,_,.I,, 4 uo,_, .0 .,::,17'9 · 44 ,.% .--~ -- ~.° -.v :~ 4, 2648 + 84 9~0, '-/8 '754,:~ + 84 :5,88 4,40 '2.21 4,26 4,5,9 1,60 0,00 0 + 00 0000 1 · 7-',. "' ]" . S I'IE IN F:'OiNT F:'RC,'t SF'ERRY LIN i"if'iS · ":; "" '::; ......... 44 .,_'7998, :iv, 4'":".,., 2 ........ 33 0 E: 32, 2670,41 ':"54,,..~ 256 ,4:1. /::::6+46 .':::; t',.4=;,3,.~'"" E: 957,03' S 3:t E: 0,78 3¢3,..,'::', '::'.4.; 15 S :~2 ...."~(') E 3646, 5'::'._, AO_ S 3'?,_ .?JO E ,I 0 '~ o ,:' ,;' 2 .... ., q5 S 30 E .'.. ~.. # . ? . . 337, 288..,..'), .S 8 1 ~.. '? 16.1. 8 .,:.'J 77 -,/, ..... .:~, c:., 1006., o' 1 b"' 311, 3061.,,..."~ :I. l-q70.41 .~..~9~:;z,.. ,_,. 31 1. ,,.~ :1.~. ~... .. 14 S 37:;,... 327;3,60 1780+69 31':°,-,,-,. 60 :1.488,48 S 6 a 6, c,,., 4 F:: :1. .,... ''~ 18,67 S 34 1.9. E 8,...,..'::' ':4,61 E I z,... 7 .,:.'-', ¢', 2. S.. ;34 0 E 981,09 E: 1 TM, q~,.,"" :', ,. ':> S 3 S ,..'? :5 E 1,93 0,40 0,88 ':(UF:'.ARUI'( i::']'EL.D, NOR'T'H SLOF"E~ AL_ASKA .1.0: 28: 2S 07-JUL-80 PAGE NO., ,~2 T R tJ 'ili::ASURED £~RI:i::'T BRIF'T COURSi:-": VERTICAL. VERTICAL SUBSEA R E C T A N (3 U L. A R C: L. 0 S U R E: I) OGL. E lIE P 1' H A N G L I:"' D I R E: C ]" i 0 N. I... E N G '[ I"i I:~ E I::' T H .9 F:: C T I 0 N T V D C 0 0 R D I N A i' E c,..:: P I S T A i'".l C E :0 :r R E C: T I 0 N S F V E R I T F E E 1' D M D i',~ I::' E E 'T' F' E E "," F'E E T F' E E 1' F' E E T F' E E T i3 Pi B G / 10 0 4S77, "" ":' ,_,,., 0 S ~..:o S0 E · 46920 '='"' ... ,.,a, :'~0 S 29 0 E ~";1.91. ~;0 30 8 27 30 E ',56~;9. 46 SO S :27 0 E: 6175;. 42 1.5 ~_ ....~ '''~'q 0 E: '"'": ...... ""~ 'Z ""0+S1 174f";,'"'.1. .c.; 11':)0+48 E 2073.9<.~, c: .:.-; 42 ': ,J,.,, ~, 4 / ,... S 1 20 '72,61 S ,' ~- ...... "' --' --, ~- S1,5. J659.3~5 ~..':>=:"~8~ 10,. ,. S!5"::4,_, . :S~; 1969..S3 S 12-,i. 3.43 i~"..: ,..":~329, ~';3,, S S2 16 5: 499. 3966,5S "' ";' .... ~ 3861 ":'3 "'~ ........... ~.:., 20 · ¥ ~.. .,.., ,...:~ 1. 5~ 66 ~.:; 1429 + 52 E: 27 '.'",... ]. · ,:, 6 ,_?; ,.~ 141 49.:.;". 4 ...... '? ~'; .44 ~ ~.'") 9:~ ~.-'. 17 ,I 1 9 t . q 4 26 ..... 4 / 0 18 S 1600.... '"~ 7 E 7,, 09 ~: · .,.'> 9 S S 1 9 I:"' .... 4,_. 1 / ~.:, / · 7 E :5:32 7 -".) 8 E 486, .4,542; · '?. ~.~.;,'~; ..... .q. S 2 · :-i 6 4 ~'; S ~:~ · / ._.% ,.,.'"" 9 ' o · :59 S .......... :I 4 , 4 ,.,c:' 2'. 0 0,21 0,49 0 .,. 0,81 ~"'"~76, 40 0 S 29 0 717-':-!, 36 0 S 28 0 E / o o,.:., ,, 31 0 .c:;21 0 E: 8043,, ?.6 0 S 15; 0 E '8S600 24 0 S 1..'., 0 E: 501.. 5021 11. 3761 7l 491o+11 ~2..$8,15 S 191"' .... -.: ,~:.:3 E S761~71 S :.'.{0 -' =' E ,:96, ,5411 . 8::' 4066.79 ,5S06 + 89 3506,4,5; S 2060.06 -. =. ,.- c:; 7 :z.. --' /. 4'-76. 582~:.;,7:';6 ,:~':No 79 5172r~.S~ 2'.,'o,_, 32; 21 .48 g 4:.37;k:.9~5 .q 30 --.. E · . ~.. ~-- . ~.. · S-',' 5. e--'." 154 ~ 82 4 ':'5.1.,_.'z, 1 ~:'., 604 ~:'. , 8.2 S' 925 · :_'!; -': S ,..'-' ,~. ''~ '='.:. ,-.c' · 73 E ,~ z ,.,. ,':,'"; ' 226 2 ' ' "~ S 17, 6-°, 42,10 *., ,.,-,- 1. ,.. :. ,S ~3 S 7 · 10 4 0 =' =' · . ,..,,., 07 S .27 E 4,>4S 43 S 9 5;' g 0.47 0.82 1,27 1.52; 0.6,-1 FI,NAL. CL.C~SLIRE - DIRECTION D l STANCE: S; 29 DEGS 9 MINS-24:SECS E 46.43.4 S I.':' E E T RRCO OIL RND GRS PRO E. WELL NO: 2 ~" ~U_P_~.RUK___F_.!_E_ L D ;_.N. 0 R_.T. H_ ..SL ERSTMRN WHIPSTOCK, INC. ' HOR I ZONTRL--PR OJECT I ON-- SCRLE ! IN. = 500 FEET ' DEPTH. INDICRTOR: I I Vo ......... I . , . _'I~T] ....... I I .................... :il ............I_jL ........... ........ J ......... ~. ::.: .::.: :::l:[ ........... ~ I . Ill - - - t .....j . l ......... j ...................... : ...............~ ............ ,. -FINRL STRTION: ..... . ' '': ......... ~'' DEPTH 8360 HD. 6442.10 TVD ....... ....... . ........................ , ........... ~ CLOSURE 4643.;43 S ........ t ......... I ............ t ....................t ..... ..... [ .................... Jla. ] ' ............ ~ _l~. ~ ....... j ~ ............................... ............ : ............................ i ....... ~ ...... : .............: ...... ~ ........... ~ ....... ~... ...... , .... ............ ~ . , _ ~~ ~ . .... ~ ............. I j ' ........... ~ i ~ ....... ~ .......... ~ ', , .......... j ....... L ............ ARCO OIL RND GAS PAD E. WELL NO: 2 : ; VERTI CRL'PRO3ECTISN- SCALE 1 IN. = 1000 FEET ....... !_~ .... K.U P_R .RU..._K___F_I.[_.L.D,_..._ N_O~T.H.__SL 0 .P_~E,_-_RLRS_K~ ............... L _.:_' ' EASTMAN WHIPSTOCK; INC.: - ' ' ~ i ' .... : - · i ~ - -j- -i ...........' ..'-~ ....... I ''~ ..... ~ ..... ! ......................... J ...... ~ ...... ~ ......... ~, ......... i_ ., t ...... i- - -I - , '~- --I ' i' ' '_ ......... j .... ~-'- ........ '- I ....... i . . ......... , , t ~Si"' ! :-":":"-': .............. t ........... ~ ............ j .......................... :'-"::'--":-:::::: !--':::--::::-' :'-: .... ~ ..... '-":' :-::::-':'-! :"::':':':'t ......... ~ ............ t ........ , ..................... ..... I ......... ~'t .......... t : ....... j::i~iC-. ....... "-' ........... i ..... '-:I' ', ::.. i . :':. .... ! ....... i !_. ii :'.::":': '-:_:-:._:_.i_!': SCIENTIFIC DRILLING CONTROLS 700 WEST ~1.~t ST}~EET ~ GYROSCOPIC D!PECTIO~]AI, SUAVE¥ FOF * ARCO OIL & CBS * *****,************* · JOB MU~BFF: 44 03 ?~EI,L N~MF: LOCDTION: ~,UP;~PUK F-2 · PR U DH OE SUFVEY DATE: 6-17-80 SU}TVFY E~]GINEEF: PI-II L GFAFFT GYRO REFEPFt,TCE BE~PIbIG: N00-00F i !'F. THOD OF CALCULATIO?~: RADIUS OF CURVATUFE ***DEPT~! ~,~FaSUPFD .IN FEFT*** COM~.F,~7?S: T~AN I< YOU *THIS SUFVUY IS COPP?CT TO TIFF. * *BEST OF }'Y !{~O$;~_,FDCF ;%ND IF * *SUPPOFTED BY ~,CTUAL FIEI.n COMPLETION REPORT ARCO OIL & GAS GYROSCOPIC SURVEY RADIUS OF CURVATUR~ METHOD OF COMPUTED FOR SDC BY FM LINDSEY 17 JUNE DS E-2 K B ELEV COMPUTATION & ASSO¢ JOB 4403 ALL RECORD OF SURVEY CALCULATIONS PERFORMED BY I B M ELECTRONIC 8O 105,00 COMPUTER TRUE MEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH D M 0 0 0 0o00 100 0 ~ 100,00 200 0 0 200,00 300 0 0 300,00 400 0 0 400.00 500 0 0 500.00 600 0 0 600,00 700 0 0 700.00 800 0 0 800,00 900 0 0 900.00 1000 1 0 999.99 llO0 .3 45 1099,89 1200 6 15 1199,51 1300 11 30 1298.27 1400 14 0 1395.80 1500 15 30 1492.50 1600 18 30 1588,12 1700 22 0 1681,93 1800 25 15 1773,53 1900 30 0 .1862,11 · 2000 34 0 1946,90 . 2100 35 30 2029.06 2200 40 0 2108,11 2300 45 0 21~1.81 2400 45 30 2252.21 SUB DRIFT SEA DIREC DEG, -105.00 N O,OOE -' -4.99 N O,OOE '~. 95.00 N O,OOE 195,00 N O,OOE 295,00 N O,OOE 395,00 N O,OOE 495.00 N O,OOE 595.00 N O, OOE 695,00 N O,OOE 795,00 N O,OOE 894,99 S66,00E 994.89 S41,00E 1094,51 S24,00E 1193,27 S28,00E 1290,80 S28,00E 1387,50 S33,00E 1483,12 S32,00E 1576.93 S38,00E 1668,53 536,00E 1757,11 535,00E 1841.90 1924,06 S36,00E 2003,11 S35,00E 2076,81 534,00E 2147,21 $34.00E TOTAL COORDINATES 0,00 S 0.00 W : : 0.00 S 0,00 W 0.00 S 0.00 W 0.00 S 0,00 W 0.00 S ~ 0,00 W 0,00 S 0,00 W 0.00 S ~:0'00 W 0.00 S 0.00 W 0,00 S 0,00 W 0,00 S 0o00 W 0,40 N 0,61 E 2.04 S 3,92 E 9-36 S 8,58 E 23,22 S 15,34 E 42-71 S 25,70 E 64,64 S 38,62 E 89.29 S 54,33 E 117.63 S 74.17 E 149,63 S 98.28 E 187.36 S 125.20 E 231.03 S 155,21E 277.71 S 187.90 E 327-54 S 223,44 E 383.20 S 261,69 E 442,08 S 301,41 E C L O DISTANCE 0o00 0,00 0,00 0,00 0.00 0,00 0,00 0,00 0,00 0,00 0,73 4,42 12,70 27.83 49.85 75.30 104,52 139.06 179,02 225.35 278,32 335,31 396,50 464.03 535.05 S U R E S ANGLE D M DOG LEG SEVER I TY DEGIiOOFT $ 0 0 0 W S 0 0 0 W S 0 0 0 W S 0 0 0 W $ 0 0 0 W S 0 0 0 W $ 0 0 0 W $ 0 0 0 W S 0 0 0 W S 0 0 0 W N 57 0 0 E S 62 27 50 E S 42 30 35 E S 33 27 12 E S 31 2 32 E S 30 51 32 E S 31 19 4 E S 32 13 59 E S 33 17 55 E S 33 45 5 E S 33 53 38 E 534 4 55 E S 34 18 3 E S 34 19 47 E S 34 17 9 E 0.000 0.000 0,000 0,000 0,000 0.000 0,000 0,000 0,000 0,000 1,001 2,752 2.508 5,252 2,500 1,542 3,002 3.600 3,270 4.757 4.012 1.645 4.519 5.025 0.500 SECT"~ DISTANCE 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 -0,03 3.74 27..~ 49.84 75.29 104.51 138.99 178.79 224,96 277.81 334.62 ~95.59 ~62~95 533.83 ARCO' DS E-2 GYROSCOPIC SURVEY JOB 4403 17 JUNE 80 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER MEAS, DRIFT DEPTH ANGLE D M 2500 46 0 2600 46 0 2700 46 0 2800 46 0 2900 46 0 3000 47 45 3100 49 0 3200 53 45 3300 54 30 3400 54 3O 3500 55 0 3600 55 15 3700 55 30 3800 56 0 3900 56 0 4000 53 30 4100 56 0 4200 55 0 4300 '55 0 4400 54 45 4500 54 15 4600 54 0 4700 53 15 4800 53 0 4900 52 30 5000 51 0 5100 51 0 5200 50 0 53O0 5O 0 TRUE VERTICAL SUB DRIFT TOTAL COORDINATES C L'"O DEPTH SEA DIREC DISTANCE DEG, 2321,99 2216,99 S34.67E 501.23 S 341,81 E 606,68 2391.46 2286,46 534,00E 560.63 S 382.38 E 678,61 2460,92 2355,92 S35.00E 619.91 S 423.12 E 750,55 2530,39 2425,39 535,00E 678.83 S 464.38 E 822,48 2599,85 2494,85 S36.00E 737.39 S 506,15 E 894,40 2668,21 2563,21 S35,00E 796.81 S 548.54 E 967,37 2734-,63 2629.63 S35,00E 858,04 $ 591,41 E 1042,12 2797,04 2692,04 S34.00E ._ 922.41 S 635,65 E 1120,22 2855.64 2750,64 S34,00E 989.58 S 680,96 E 1201,24 2913,71 2808,71 S34,50E 1056,88 S 726,78 E 1282,65 2971,42 2866,42 S33,00E 1124.78 S 772.15 E 1364,31 3028,60 2923,60 S33,00E 1193,58 S 816,83 E 1446,32 3085,42 2980,42 S32,00E 1262.98 S 861,04 E 1528,57 3141,70 3036,70 S33.00E 1332.69 S 905,45 E 1611,19 3197,62 3092,62 S30.OOE 1403-37- S 948,77 E 1693-99 3255,33 3150,33 S29,00E 1474.44 S 988,97 E 1775,40 3313,04 3208,04 S29.00E 1545.86 S 1028.56 E 1856.78 3369,68 3264,68 S30,00E 1617.59 S 1069.14 E 1938,99 3427,04 3322,04 S30,OOE 1688,53 S 1110,10 E 2020,76 3484,58 3379,58 S29.00E 1759.72 S 1150,38 E 2102,37 3542,65 3437,65 S29.00E 1830,92 S 1189,85 E 2183,58 3601,25 3496,25 S29,00E 1901,79 S 1229.13 E 2264,41 3660,56 3555,56 S30,OOE 1971,86 S 1268,78 E 2344,79. 3720,56 3615,56 S30.OOE 2041.14 S 1308,77 E 2424,70 3781,09 3676,09 S30.OOE 2110,08 S 1348,57 E 2504,21 3843,00 3738,00 S30.OOE 2178.09 S 1387,84 E 2582,67 3905,93 3800,93 S29,00E 2245.72 S 1426,11 E 2660,28 3969,54 3864,54 S29,00E 2313.21 S 1463.51 E 2757,30 4033,82 3928,82 S29,00E 2380.21S 1500,65 E 2813,78 S U R E S ANGLE D M S 34 17 30 E S 34 17 47 E S 34 18 57 E S 34 22 32 E S 34 27 58 E S 34 32 38 E S 34 34 36 E S 34 34 17 E S 34 31 58 E S 34 30 53 E S 34 28 9 E S 34 23 9 E S 34 17 3 E S 34 11 34 E S 34 3 40 E $ 33 51 5 E S 33 38 18 E S 33 27 45 E S 33 19 20 E S 33 10 25 E S 33 1 6 E S 32 52 28 E S 32 ~+5 31 E S 32 40 4 E S 32 34 59 E S 32 3O 16 E S 32 25 0 E S 32 19 14 E S 32 13 48 E DOG LEG SEVERITY DEG/IOOFT 0.608 0,482 0.719 0,000 0,719 1,834 1.250 4,794 0,750 0,407 1.124 0,250 0,724 0,850 2.487 2;~82 2,500 1,204 0,000 0,712 0,500 0,250 0,987 0.250 0,500 1,500 0,777 1.000 0.000 SECTION DISTANCE 605.29 677,06 748~ 820,pl 892,16 964,86 1039,37 1117,27 1198,14 1279,37 1360.90 1442.85 1525,09 1607,69 1890.57 1772,22 1853,85 1936.25 2o18. 2099, + 2181,33 2262,33 2342.83 2422,83 2502,42 2580.95 2658,66 2735.79 2812.37 ARCO DS E-2 GYROSCOPIC SLJRVEY JOB 4403 17 JUNE 80 " ALL CALCULATIONS RECORD OF SURVEY PERFORMED BY I B M ELECTRONIC COMP~JTER MEAS, DEP TH DRIFT ANGLE 54O0 49 15 5500 48 0 5600 47 30 5700 46 0 58O0 45 0 59O0 44 0 6000 42 45 6100 42 30 6200 42 30 6300 42 0 6400 41 45 6500 41 0 6600 40 15 6700 40 30 68O0 39 0 6900 38 30 70O0 37 45 7100 37 15 7200 35 15 7300 35 0 7400 34 15 7500 32 45 7600 32 0 7700 29 45 78O0 28 0 7900 27 0 8000 25 30 8100 25 15 82OO 24 15 TRUE VERTICAL SUB DEPTH SEA 4098,60 3993-60 4164,69 4059,69 4231,93 4126,93 4300,45 4195,45 4370.54 4265-54 4441,86 4336,86 4514,55 4409,55 4588,13 4483,13 4661.85 4556,85 4735,88 4630-88 4810,34 4705,34 4885,37 4780,37 4961.27 4856,27 5037.45 4932.45 5114,34 5009,34 51.92,33 5087,33 5270,99 5165,99 5350.33 5245.33 5430.97 5325,97 5512.76 5407.76 5595,04 5490,04 5678.43 5573.43 5762.89 5657,89 5848,71 5743.71 5936,27 5831.27 6024.97 5919.97 6114,66 6009,66 6205,01 6100,01 6295-82 6190,82 DRIFT DIREC DEG. S2 S2 S2 52 S2 S2 S3 53 S3 S3 53 S3 53 S3 53 S3 53 S3 53 52 S2 S2 S2 S2 S2 Si SI S1 S1 9.00E 8.00E 9.00E 9.00E 8.00E 9,00E O.OOE O.OOE O,OOE 2oOOE 1.OOE 1,00E 1.00E I .OOE 2.00E 3,00E 1.00E 1.00E O.OOE 7,00E 5.00E 5.00E 5,00E 2,00E O.OOE 7.00E 9,0OE 7,00E 8.00E TOTAL COORDINATES C L 0 D I STANCE S U R E S ANGLE D M 2446.84 S 1537.59 E 2889.85 S 32 2512.79 S 1573,39 E 2964,74 $ 32 2577.84 S 1608.71 E 3038.62 S 31 2641.54 S 1644,02 E 3111,36 S 31 2704-22 'S 1678,05 E 3182-56 S 31 2765.81 S 1711.50 E 3252.53 S 31 2825.59 S 1745.32 E 3321.16 S 31 2884-23 S 1779.18 E 3388.85 S 31 2942.74 S 1812,95 E 3456,38 S 31 3000,37 S 1847,58 E 3523,61 S 31 3057,28 S 1882.46 E 3590.36 S 31 3113.94 S 1916.50 E 3656.45 S 31 3169.75 S 1950,04 E 3721.56 S 31 3225.28 S 1983,40 E 3786,33 S 31 3279.80 S 2016,81E 3850,27 S 31 3332.59 S 2050.44 E 3912.86 S 31 3384.94 S 2083.15 E 3974.59 S 31 3437.12 S 2114.51 E 4035,46 S 31 3488,07 S 2144,52 E 4094,58 S 31 3538-62 S 2171,97 E 4152,03 S 31 3589,69 S 2196,87 E 4208.58 S 31 3639.71S 2220,20 E 4263,43 S 31 3688.24 S 2242,83 E 4316,64 S 31 3735.29 S 2263,29 E 4367,48 3780.37 S 2280,59 E 4415,01 3824.15 S 2295,24 E 4460,08 3866,22 S 2308.91 E 4503.19 3906,97 S 2322.15 E 4544,98 3946.90 S 2334.74 E 4585,74 8 42 E 3 10 E 57 59 E 53 49 E 49 15 E 44 57 E 42 10 E 4O 8 E 38 10 E 37 26 E 37 18 E 36 38 E 35 59 E 35 22 E 35 17 E 36 9 E 36 32 E 35 59 E 35 1E 32 28 E 27 59 E 22 58 E 18 14 E S 31 12 45 E S 31 6 5 E S 30 58 19 E S 3O 5O 44 E S 30 43 32 E S 30 36 21 E DOG LEG SEVER I TY DEG/iOOFT 0,750 1,367 0.739 1,500 1.118 1,110 1,332 0,250 0,000 1,026 0,509 0,750 0,750 0,250 ! 1,551 0,633 1,060 0,500 2,028 1,018 0.982 1,500 0.750 2,368 1.805 1.176 1,545 0,442 1.014 SECTION DISTANCE 2888,53 3037.=1 3110,32 3181.60 3251,65 3320,32 3388,04 3455,59 3522.82 3589,56 3655.66 3720.76 3785.54 3849.47 3912.02 3973.73 4093, 4151,23 4207,87 4262,82 4316,13 4367,06 4414,70 4459.87 4503,06 4544.91 4585.72 ~ARCO DS E-2 GYROSCOPIC SURVEY JOB 4403 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER 17 JUNE 80 TRUE ~EAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG, TOTAL COORDINATES 8300 24 30 6386.91 6281.91 S17.00E 3986.26 S 2347.15 E 8360 24 I5 6441,56 6336,56 S18,00E 4009,87 S 2354,59 E THE FOLLOWING INFORMATION IS EXTRAPOLATED TO T,D, 8440 24 15 6514,50 6409.50 S18,00E 4041.12 'S 2364.75 E BOTTOM HOLE CLOSURE 4682.17 FEET AT 5 30 20 5 E DOG LEG C L'O 5 U R E S SEVERITY DISTANCE ANGLE DEG/IOOFT D M 5 4625,95 S 30 29 24 E 4650,08 S 30 25 17 E 4682,17 S 30 20 5 E 0,303 0,503 0,000 SECTION DISTANCE 4625.94 4650.~8 4682.17 .ARCO DS E-2 GYROSCOPIC SURVEY JOB 4403 INTERPOLATED TRUE VERTICAL DEPTHS, COORDINATES AND CLOSURES FOR GIVEN DEPTHS TRUE CODE MEASURED VERTICAL TOTAL COORDINATES C L O $ U R E NAME DEPTH DEPTH DISTANCE ANGLE D M 17 JUNE 80 SUB SEA T K SAN1 7958 6076.85 3848.88 S 2303.08 E B K SAN1 8040 6150.78 3882.51S 2314.39 E T K SAN2 8040 6150.78 3882.51S 2314.39 E B K SAN2 8051 6160.71 3886.99 S 2315.85 E T K SAN3 8168 6266.68 3934.31S 2330.69 E B K SAN3 8233 6325.90 3959.82 S 2338.90 E B KUPAR 8252 6343.21 3967.29 S 2341.26 E 4485,32 S 30 53 43 E 5971.85 4519.99 S 30 47 58 E 6045.78 4519,99 S 30 47 58 E 6045.78 4524,59 S 30 47 10 E 6055.71 4572,84 S 30 38 33 E 6161e68 4598.98 S 30 34 6 E 6220e90 4606,62 S 30 32 47 E 6238,21 ARCO DS 15-2 ?~EA'SURE D DEPTH AND OTHER DATA GYROSCOPIC suRVEy FOR EVERY EVEN 100 JOB 4403 FEET OF SUB SEA DEPTH. 17 JUNE 8O MEASURED D,_FPTH 205 305 405 505 605 705 8O5 905 1005 1105 1206 1307 1409 1513 1618 1725 1835 1950 2070 2196 2333 2475 2619 2763 2907 3055 3213 3385 3558 3734 3913 4086 4261 4435 4606 TRUE VERTICAL SUB DEPTH SEA 205. 100 305. 200 405. 300 505. 400 605. 500 705. 600 805, 700 905. 800 1005. 900 1105. 1000 1205. 1100 1305. 1200 1405. 1300 1505. 1400 1605. 1500 1705. 1600 1805. 1700 1905, 1800 2005. 1900 2105. 2O00 2205. 2100 2305. 2200 2405. 2300 2505. 2400 2605. 2500 2705. 2600 2805. 2700 2905. 2800 3005. 2900 3105. 3000 3205. 3100 3305, 3200 3405, 3300 3505. 3400 3605. 3500 MD-TVD DIFFERENCE VERTICAL CORRECTION 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 - 0 I 1 4 3 7 3 ' 12 5 19 7 30 11 45 15 65 20 90 25 127 37 17o 43 214 44 258 44 302 44 350 48 408 58 480 72 553 73 629 76 708 79 780 72 856 76 930 74 1001 71 TOTAL COORDINATES 0.00 S 0.00 0.00 S 0.00 S 0.00 S 0.00 S 0.00 S 0.00 N 0.36 N 2.29 S 9.92 24,44 S 44.63 S 67,59 S 94.14 S 125.16 S 162,11 $ 208.53 S 263,64 S 325,44 S 402.48 486.57 571.94 S 657.03 S 741.47 S 830.34 .S 931.10 1046.95 S 1164.66 1286,72 S 1412,78 S 1535.73 S 1660,86 1784.69 S 1906.03 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.70 4.13 8.83 15.99 26.74 40,53 57.42 80.00 107.29 139.88 177.80 221.97 274.69 331,42 390.04 449.12 509.11 572.01 641,51 719,65 798,04 875.98 954.18 1022,95 1094.13 1164,22 1231'48 W W W W W W E E E E E E E E E E E E E E E E E E E E E E E E E E E E ~ARCO DS E-2 MEASURF..D DEPTH AND OTHER DATA GYROSCOPIC SURVEY FOR EVERY EVEN 100 JOB 4403 FEET OF SUB ,SEA DEPTH. 17 JUNE 8O MEASURED DEPTH TRUE VERTICAL DEPTH SUB ,SEA MD-TVD DIFFERENCE VERT I CAL CORRECTION TOTAL COORDINATES 4774 4939 -5098 5255 5410 5560 5706 5848 5987 6123 6258 6393 6526 6657 6788 6916 7043 7168 7290 7412 7531 7649 7764 7877 7989 8100 8210 8320 8430 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 .56 57 58 59 60 61 62 63 64 65 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 O5 05 05 05 05 05 05 05 05 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 5100 5200 5300. 5400 5500 5600 5700 58O0 5900 6000 6100 620O 6300 6400 1069 1134 1193 1250 1305 1355 1401 1443 1482 1518 1553 1588 t621 1652 1683 1711 1738 1763 1785 1807 1826 1844 1859 1872 1884 1895 1905 1915 1925 68 65 59 57 55 50 46 4'2 39 36 35 35 33 31 31 28 27 25 22 22 19 18 15 13 12 11 10 10 10 2023.15 S 2136,77 S 2244.37 S 2350,06 S 2453.33 S 2551.99 S 2645.31 S 2733.99 $ 2817,91 $ 2897,62 S 2976.38 S 3053.20 S 3128,51 S 3201,37 S 3273.35 S 3340,94 S 3407,42 3472,00 S 3533.52 S 3595,81 S 3654,86 3711,55 S 3764,36 S B814.15 S 3861.72 3906.96 $ 3950,81 S 3994.12 S 4037,05 S 1298.39 1363,98 1425,35 1483,94 1541,17 1594,50 1646,11 1694,05 1740.89 1786.90 1832.84 1880,00 1925,26 1969,03 2012,79 2055,83 2096,66 2135,19 2169,34 2199,73 2227.26 2253.33 2274.65 2292.11 2307.37 2322.15 2336.00 2349,58 2363.42 'ARCO DS E-2 GYROSCOPIC SURVEY JOB /+/+03 17 JUNE 80 INTERPOLATED VALUES FOR EVEN TRUE MEASURED VERTICAL DEPTH DEPTH 1000 999. 2000 1946, 3000 2668. 4000 3255. 5000 3843. 6000 4514. 7000 5270, 8000 6114. lO00 FEET OF MEASURED DEPTH, SUB SEA TOTAL COORD !NATES 894. 0.40 N 0,61 E 1841. 231,03 S 155,21 E 2563, 796.81 S 548,54 E 3150. 1474.44 S 988.97 E 3738. 2178.09 S 1387.84 E ~409. 2825.59 S 1745.32 E 5165. 3384.94 S 2083.15 E 6009. 3866.22 S 2308,91 E HORIZONTAL VIEW ARCO OIL & GAS DRILL SITE E-2 RADIUS OF CURVATURE GYROSCOPIC SCALE I" = I000' JUNE :~6t 1980 63,5' ALL DEPTHS SHOWN ARE TVD. 15 22 SEC. 16~ T. II N.t R.IO E.~ U.M. ,,5~O0 ~oo° · 8,0° ~o~o° · ooo · oo TVD = 6515' TMD = 8440' 0 - VERTICAL SECTION ARCO OIL 8~ GAS DRILL SITE E-2 RADIUS OF CURVATURE GYROSCOPIC SCALE I" = I000' JUNE 26, 1980 40O 800 1200- 16°°1 2800 ~ .'5600 ,~ '~' 4000 ;~ 4400 '~ 4800 ,~ 520~a~10~ ALL 'DEPTHS SHOWN ARE TVD. TVD = 6515' TMD = 8440' TO' DATE' NORTH SLOPE DISTRICT ENGINEERING TRANSMITTAL # ~) ~- .i ! STA? TEC-1 FROM' Jerry J. Pawelek/Leo Lash WELL NAME' Transmitted herewith are. the following for the subject well' DATE SCALE XEROX BL SEPIA LINE FILM BHC Sonic/Gamma Ray Log Cement Bond LOg/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv) - Core No. Directional Survey - Gyro Single Shot Mul ti-shot/~ -~) Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Spectral og TVD-DIL Differential Temperature Log Spinner Survey Fluid Density Casing Collar Log Perforating Record Neutron Lifetime Log Carbon-Oxygen Log RECEIPT ACKNOWLEDGED FOR' DATE' PL~~EAsERETURN RECEIPT TO ARCo Oil and Gas Company Attn' Mr. Leo Lash P.O. Box 360 - Rm. #311-FAB Anchorage, AK 99510 RECEIVED JULt 0 Anohurag~ BATE' NORTHTRANSMITTALSLOPE DISTRICT# ,~oENGINEERING~ / Lash ---i-STAT ¥~C FROM' Jerry d. Pawelek/Leo ~h_ ~ WELL NAME' ~t ~ ~l~V- Transmitted herewith are the following for the subj'ect well: DATE BL SCALE XEROX SEPIA LINE FILM BHC Sonic/Gamma Ray Log Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.) - Core No. Directional Survey - Gyro Single Shot Multi-shot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Spectral og TVD-DIL Differential Temperature Log Spinner Survey.~ Fluid Density Casing Collar Log Perforating Record Neutron Lifetime Log Carbon-Oxygen Log '" DATE- /¢[EASE RETURN RECEIPT TO' RECEIPT ACKNOWLEDGED .... ARCo Oil and Gas Company Attn: Mr. Leo Lash P.O. Box 360 - Rm. #311-FAB Anchorage, AK 99510 BY: ALASKA OIL ~_ND GAS CONSERVATION COMMISSION Thru: Hoyle H. Hamilton Chairman/Commissi Lonnie C. Smith ~/~ ; Commissioner Doug Amos /~ Petroleum Inspector June 26, 1980 /C .... ":: Witness B.O.P.E. Tests at ARCO ' s Kuparuk~~ well, Sec. 22, Tl%~' R10E, U.M. Permit No. 80-56, on Rowan Rig No~J 34 and Sohio's J-11 ~-- Well, Sec.9, TllN, R13E U.P.M. Permit No. 80-35 on N~or's Rig No. 1dE. .Sun_daY, jg~ne 22,_ 198~: i departed my residence at 1:30 p.m. for a 2:30 p.m. departure on Wien Flight No. 75. I arrived at ARCO's Kuparuk E-3 Well, Rowan Rig No. 34 at 7:30 p.m. .Monday., June..23, 1)89: Testing commenced at 6:00 a.m. and. was concluded at 9:30 a.m. I filled out an A.O.G.C.C.B.O.P.E. Test report, which is attached. I was contacted by Mr. Gary Moore, Sohio representative and in- formed that Nabors Rig No. 1dE was ready to test B.O.P.E. at Sohio's J-11 Well. I arrived Nabors 18E at 2:30 p.m., testing commenced at 4:30 p.m. The Annular Preventor failed to test and. the bag was replaced and Annular retested. The tests were 'con- cluded at 8:30 p.m. Tuesday, June 24, 1980. I filled out an A.O.G.C.Co B.O.P.E. Test Report, which is attached. In summary: I witnessed the B.O.P.E. Test at ARCO's Kuparuk E-3 Well on Rowan Rig No. 34 and Sohio's J-11 Well on Nabors Rig No. 18E, all tests were good. I filled out an A.O.G.C.C.B.O.P.E. Test Report for each test, which are attached. · O&G #4 4/80 ALASKA STATE~ ~OF ALASKA OIL & GAS CONSERVATION COblMISSION B.O.P.E. Inspection Report Inspector Date Operator Well {<~ Location: Sec ~_ Drilling Contractor Rig Location, General Well Sign General Housekeeping Reserve pit Rig ACCUMULATOR SYSTEM Full Charge Pressure ~OcDO psig Pressure After Closure ~~ psig 200 psig Above Precharge Attained: Full Charge Pressure Attained: min ~ s, min BOPE Stack Annular Preventer Pipe Rams Blind Rams CD Choke Line Valves H.C.R. Valve Kill 'Line Valves Check Valve CD ~'~ Test Pres sure ~oO Controls: Master ,O~ Remo~e ~91~-. Blinds switch cover Kelly and Floor Safety Valves Upper Kelly ~ Test Pressure Lower Kelly 0~$ Test Pressure Ball Type o ~ Test Pressure Inside BOP ~DWC Test Pressure Choke Manifold _~3~ Test Pressure NO. Valves [ J~ No. flanges .A. dj ustable Chokes Hydrauically operated choke Test Results: Failures ~0~~- Test Time Repair Or Replacement of failed equipment to be made within , . Inspector/Comrnission office notified. Remarks: ~- ~ -~ f~T~2 ~ hrs. ~0 ~ ' days and Distribution orig. - AO&GCC cc - Operator .. · cc - Supervisor i~spector ~C;%/¢~ ALASKA OIL AND GAS CONSERVATION COMMISSION Hoyle H. Hamilton ?~~~f'~ Chairman/Commi s s ione~ ' Thru: Lonnie C. Smith Commissioner Harold R. Hawkins //~il~>,~.~ Petroleum Inspector June 9, 1980 To witness B.O.P.E Test: Kuparuk No. E-2 ARCO Oil & Gas Company Monday, J.une......2, 1989 I left Prudhoe Bay at 8 pm. on an Otter airplane, owned by ARCO Oil & Gas Company, to the West Kuparuk field, arriving at $:15 pm. Purpose of the trip was to witness the B.O.P.E test on Kuparuk Well number E-2. Tuesday,. J.une. 3, .1~98.0 The B.O.P.E tests started at I pm. and were completed at 5 pm. I filled out an A.O.& G.C.C. Field inspection report, copy attached. In summary: I witnessed the B.O.P.E tests on Kuparuk well No. E-2, for ARCO Oil & Gas company. There were no failures, the B.O.P.E tests were satisfactory. O&G #4 4/s0 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report I ns pecto r .~/_~ .n~.~ Operator /~-~ E~ 0/~ Location: Sec Drilling Contractor Permit # Repre sentat iv~-.~. /r~ ~//A; Location, General Well Sign / General HousekeePing Reserve pit Rig BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C,R. Valve Kill Line Valves Check Valve Test Results: Failures Test Pressure ACCUMULATOR SYSTEM Full Charge Pressure ~/~f.O psig Pressure After Closure / ~,,,,~"-d~' psig 200 ps ig Above Precharge Attained: miny~- Full Charge Pressure Attained: ~ ' min~-s 2 Controls: Mas'ter ~ /% Remote (3,.~ Blinds switch cover KellZ and Floor SafetM Valves Upper Kelly. Lower Kelly Ball Type Inside BOP Choke Manifold No. Valves ? ~ Test Pressure Test Pressure Test Pressure_ Test Pressure. Test Pressure NO. flanges, '!Hydrauically operated choke, Test Time ~s. of failed equipment to be made within ~/./'~7 Repair or Replacement Inspector/Commission office notified. ~',. Remarks: %/~/'~\,/' ~ p .7~E ~ 2~' days and ! / Distribution orig. - AO&GCC cc - Operator cc - Supervisor April 16, 1980 Mr. P. A. VanDusen District drilling Engineer ARCO Oil and Gas Company P. O. Box 360 Anchorage, Alaska 99510 Kuparuk 25651 E-2 Atlantic Richfield Company Permit No. 80-50 Sur.. Loc.= 294tNSL, 636.~WEL, Sec 16, TllN, R10E, UM. Bottomhole ~c.~ 1320~NSL, 1320tEWL, .Sec 21, TllN, RiOE, Dear Mr. VanDusen~ Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the cover letter, dated March 18, 1980, accompanying the original approved permit are in effect for th~s revision. Very truly your s, H. Hamilton Chairman of .~¥ Q~DZ~ OF T}{7. CO~,~M ' Alaska Oil & Gas Conservation Com~t'~'ion Enc l o sure ces Department of Fish & Game,-Habitat Section w/o encl. Department of Environmental Conservation w/o/eno1. Department of Labor~ Supervisor, Labor LaW ~.~pliance D~vision w/o encl. HH~ be # ARCO Oil and Gas ~ ~any North Slope D~s[rict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 11, 1980 Hoyl e Hami 1 ton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Kuparuk Well E-2, Permit No. 80-50 Dear Sir' Enclosed please find the amended application for Permit to Drill the above-mentioned well. Please note the new bottom- hole location submitted for your approval. Very truly yours, P. A. VanDusen District Drilling Engineer PAV/ls Enclosure ARCO Oil and Gas Company is a Division of AllanticRichfieldCompany Form REV. 1-1-71 SUBMiT iN Tdr ~TE (Other instructt6ns'~n reverse side) STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN la. TYPE OF WORK DRILL ~-~ b. TYPE OF WELL OIL GAS WELL [] WELL n DEEPEN SINGLE~ MULTIPLE I--1 OTHER ZONE I /~ ZONE I I 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360,',Afichorage, Alaska 99501 4. LOCATION OF WELL At surface API #50-029-20472 5. 6. LEASE DESIGNATION AND SERIAL NO. ADL 25651 7. IF INDIAN, ALLOTI'EE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Kuparuk 25651 9. WELL NO. 10. FII~LD AIq~D POOL. OR WlI.I~AT Er. ueno~ .l~a~ ~paruk K~ver u3I vooi 11. SEC., T., R., M., (BO/"rOM · ~ ¢-IOLE OBJECTIVE) 294'NSL, 636'WEL, Sec 16, TllN, RIOE, UMAI::~.<: .:ii., .~,. At proposed prod. zone , 6050'SS, 1674'NSL~ 16T4'EWL, Sec 22, TllN, RIOE, ~¢/'~''~"~ 13.' DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 30.0 miles NW of Deadhorse 14. BOND INFORMATION: Oil and Gas Bond ' TypE.~r. af. OWidRS~e~ana/orNo. 8011-3.8-40. (Federal Insur. ance Co.) 15. DISTANCE FROM PROPOSED * 16. No. OF ACRES IN LEASE ' LOCATION TO NEAREST PROPERTY OR LEASE LI,NE, FT. 4644' 2560 (Also to nearest dtig, unit, if any) 18. DISTANCE FROM PROPOSED LOCATION 19. PROPOSED DEPTH TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 120' 6453'TVD 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 71.5 GL RKB 105.'5 23. PROPOSED CASING AND CEMENTING PROGRAM Sec 22, TllN, RIOE, EM 12. $1oo,ooo 17. NO°ACRES ASSIGNED TO THIS WELL 160 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START 3/25/80 , .. SIZE OF HOLE SIZE OF cAsING WEIGHT PER FOOT GRADE SETTING DEPTH Quantity of cement 24" 16" 65 . H-40 80+ MD '. Cmt 'to surf - approx 200 ft~ 13-3/4" 10-3/4" 45.5 K-55BTI; 3011+ MD Cmt to surf '- approx 3390 ft~ q-7/R" 7" . .26 K-55BTi; 8516~ MD Cmt .w~th approx 3100,ft primar - ' -93 ft secondary ~ Arctic Pack from +300'MD to sur rf Atlantic Richfield Com)any. proposes to dr ll a Prudhoe Bay Kuparuk River Oil Pool develop- ment well to approximately ±8516'MD, ~6453'TVD. Selected intervals will be logged and tested. A 20" x 2000 psi annular diverter will be installed on the 16" conductor wh)le drilling the surface hole. A 13-5/8" 5000 psi RSRRA BOPE stack will be installed ~d t'he surface pipe. It will be tested upon installation and weekly thereafter. TestR~6ssure will be 3000 psig. The well will be completed with 3½" 9.2# J-55 buttress tubiff~'. Non- freezing fluids will be left on uncemented annuli thru the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent report. A downhole safety valve will be installed and tested upon conclusion of job. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen directionally, give pertinent data on subiurface locations and measured and true vertical depths. Give blowout preventer program. (This space for State office use) SAMPLES AND CORE CHIPS REQUIRED MUD LOG [] ~s [] NO [] YES DIRECTIONAL SURVEY REQUIRED. 80-50 [~ YES [] NO CONDITIONS OF APPROVAL, IF ANY: OTHER REQUIREMENTS: [] NO A.P.I. NUMERICAL CODE 50-029-20472 PERMIT NO. APPROVAL DATE BY ORDER OF 6E C05~g~SSION *See Instruction On Reverse Side DATE 04/16/80 March 18, 1980 Mr. P. A. VanDusen DiStrict Drilling Engineer ARCO Oil and Gas Company P. O. Box 360 Anchorage, Alaska 99510 Kuparuk 25651 Atlantic R/ch,field Company Permit No. 80-50 Sur. Loc.= 294tNSL, 636"WEL, Sec 16, TIlN, R10E, Bottomhole Loc.= 1320~NSL, 1320~EWL, Sec 21, TllN, R10E, Dear Mr. VanDusen~ Enclosed is the approved application for permit to drill the above referenced wel I. Well samples, core chips and a mud log are not required. A directional survey is required. If available, a tape contain- ing the digitized log information on all logs shall be sub- mitred for copying except experimental logs., velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the .regulations promulgated thereunder (Title 5, Alaska Administrative Code}. Prior to commencing operatiOns you may be contacted by the Habitat Coordinator~s office, Depar~ent of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Mr. P. A. VanDusen Kuparuk 25651 E-2 -2- March 18, 1980 commencing o~erations you may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to drill. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the commission may be present to witness testing of' Blowout preventer equi~ment before surface casing shoe is dr il led. In the event of suspension or abandonment, please 9ire this office ade~ate advance notification so that we may have a witness present. Very truly yours, ~. Hamil ton Chairman of BY .0~ _O.F_ !/'/~ COM.~,~O~ Alaska Oii & Gas Conservation Commission Enclosure cc~ Department of Fish & Game, Habitat Section w/o eric1. Department of Environmental Conservation w/o/en¢l. Depar~ent of Laborl Supervisor, Labor Law Compliance Division w/o en~'l. ARCO Oil and Gas~ mpany North Alask~ ,strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 March 14, 1980 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: Kuparuk Well E-2 Dear Sir: Enclosed please find an Application for Permit to Drill Kuparuk Well E-2, the $100.00 filing fee, and the required survey plat. Very truly yours, P. A. VanDusen District Drilling Engineer PAV:cs Enclosures ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany ? Form 10401* REV. 1-1-7'1 STATE O F ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN la. TYPE OF WORK DRILL ~ DEEPEN ['-'] b. TYPE OF WELL WELL WELL OTHER 2.NAME OF OPERATOR Atlantic Richfield Company SUBMIT IN T ,TE (Other instructions on reverse side) SINGLE MULTIPLE P.O. Box 360 Anchorage, Alaska 99510 4. LOCATION OF WELL At surface J~k.~..,;. ~J:. ~ ........ : i~-;qiGf~ 294'NSL, 636'WEL, Sec 16, TllN, RIOE, UM ~,ai*~.~;~!.::~ At proposed nrod. zone 5840'SS, 1320'NSL, 1320'EWL, Sec 21, TllN, RIOE, UM API #50-029-20472 13.' DISTANCE IN MILES AND DIRECTIONFROM NEAREST TOWN OR POST OFFICE* 12. 300 miles NW of Deadhorse 5. : LEASE DESIGNATION AND SERIAL NO. · ADL 25651 IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Kuparuk 25651 9. WELL NO. E-2 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Kuparuk River Oi' 11. SEC., T., R., M., (BOTTOM Poo' HOLE OBJECTIVE) Sec 21, TllN, RIOE, UM 14. BOND INFORMATION: 0il and Gas Bond WE Statewides~tyand/orNo: 8011'-38-40 (Federal Insurance -Co. ) 15. DISTANCE FROM PROPOSED * l 16.: No.: OF ACRESIN LEASE LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. 4644' 2560 (Also to nearest dfig, unit, if any) 18. DISTANCE FROM PROPOSED LOCATION 19. PROPOSED DEPTH TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 120' 6314" TVD Amount $100,000 17. NO.ACRES ASSIGNED TO TH!S WELL 320 20. ROTARY OR CABLE TOOLS Rotary 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 22. APPROX. DATE WORK WILL START 71.5 GL RKB 105.5 23. 'PROPOSED ,CASING AND CEMENTING PROGRAM ., SIZE OF HOLE SIZE OF CASING ~ ' WEIGHT ,PER FOOT GRADE SETTING DEPTH Quantity of cement 24" 16" ..65. ,.:. ,H-40 80_+MD Cmt to surf- approx, 200 ftj 13-3/4" 10-3/4" 45.5 K-55BTC 3061+MD Cmt to surf- approx 3300 ft3 9-7/8". 7" ~. .26. , K-55BTC ' '9151+MD Cmt with :approx. 3200 ft3 primary- 93 ft3 secondary Arctic Pack from -+2000'MD to sur Atlantic Richfield Company proposes to drill' a Prudhoe Bay Kuparuk River Oil Pool . develop- ment well to approximately _+9151'MD, +_6314'TVD. Selected interVal's will be logged and tested. A 20" x 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8" 5000 psi RSRRA BOPE stack will be installed on the surface pipe. It will be tested upon,installation and weekly thereafter. Test pressure will be 3000 psig. The well will be completed with 2~" 9.2# J-55 buttress tubing. Non- freezing fluids will be left on uncemented annuli thru the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent report. A downhole safety valve will be installed and tested upon conclusion of job. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen directionally, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer progxam. DATE 3 / 14/80 TITLE District Drlg. Enginee) Crhisspacefor State office use) SAMPLES AND CORE CHIPS REQUIRED IMUD LOG [] ~s 'I~I ~o [ [] YES ~ NO DIRECTIONAL SURVEY REQUIRED, ~ YES [] No CONDITIONS OF APPROVAL, IF ANY: OTHER REQUIREMENTS: A.P.I. NUMERICAL CODE PERMIT NO. u APPROVAL DATE ~-O~OF ;~ ~i ;See Instruction On' Reverse Side BY' OaDE ' TH~ O SS~O March 18, 1980 DATE 03/18/80 . ~ WELL //8 Y 5,960'600.230 X = 549,88.9 o825 LAT.-- 70°18t11.283'' ¥ ~ LONG = 149°35~45.185'' i ' WELL //7 Y = 5,960,480.368 X = 549,889.486 ~2_e' < LAT = 70.°18' 10.104" '~n i WELL //6 Y =' 5,9609360 207 - :~ f~ ~,1 ' ° _O_ i-~ J ~- X = 549,889.255 E~t-~ - LAT = 70°18t08o923'' ~''~ LONG = 149°35~45.249''' ~ WELL ~5 Y = 5,960,240.410 X = 549,889.039 ~' > LAT = 70°18~07.744'' ~ .~ ~'~ LONG = 149°35~45.278'' ~i~ '~ WELL ~4 Y : 5,960,1200155 ~ ~' X = 549,8890818 ~ ~ '> ~ ~ LAT = 70°18~060561'' ~ ~ ; LONG = 149°35~45~279'' m ~' WElL ~3 Y = 5,960,000 596 E~ X = 549,889o506 J~~ > LAT = 70°18~05.386" ~ LONG = 149°35'45o311" EZ~ WEEL ~2 X = 5,9~9,88Oo504 J~-- ~ ' Y = 549,889.996 ~ i ~ ~' LAT = 70°18~04~204'' El '~ -- LONG = 149,35~45~320'' ~ WELL ~1 X = 5,959,760.244 ~ Y = 549,889.514 ~ LAT = 70°~8~03.022'' ~ LONG = 149°35145~358'' ~i~ ~, ~lo~,u.~.) 2I I HEREBY CERTIFY THAT ! AM i PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEY lNG IN , THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS AN AS- THAT ALL DIMENSIONS AND 0 ~d~s~,~2 DETAILS ARE CORRECT, AS 0 : ". v ~i ~4' ~ ~ > (ri~ N, ~lO~,U.~.) 2 I RTIFY THAT ! AM , O.,~,. E: ? W ~ L.. [... $ .t- ~ L oC,AT~ o ~ ~ A,r-...,-I'~u ~ 'ltlanticRichfieldCompany ~ DATE: DRAWING No: NORTH AMERICAN PRODUCING DIVISION 2/17/t~O' ALASKA DISTRICT -- - KUPARUK I I CHECK LIST FOR NEW WELL PERMITS Item Approve Date (1) Fee ~g_ ~./7-~oI, / (2) Loc. (3) /k:lrrd_n. ('~c-,~ '3./7-)'0 ( 4 ) Casg F.)7o ~0 ( 5 ) BOPE _ Yes No 1. Is the permit fee attached .......................................... ~ -- 2. Is w~ll to be located in a defined pool ............................. 3. Is a registered survey plat attached ................................ 4. Is well located proper distance frcm property line ................. .//~ 5. Is well located proper distance frcm other wells .................... .~ 6. Is sufficient undedicated acreage available in this pool ............ / 7. Is well to be deviated .............................................. ~. 8. Is operator the only affected party ................................. 9. Can permit be approved before ten-day wait .......................... / 10. Does operator have a bond in force .................................. / 11. Is a conservation order needed ...................................... 12. Is administrative approval needed ................................... 13. Is cor~uctor string provided ............ ............................ ~ 14. Is enough cement used to circulate on conductor and surface ......... ~ 15. Will cement tie in surface and intermediate or production strings .. 16. Will cement cover all known productive horizons .................... 17. Will surface casing protect fresh water zones ...................... 18. Will all casing give adequate safety in collapse, tension and burst. 19. Does BOPE have sufficient pressure rating - Test to ~gPO~ psig . Approval Reccmmended: Lease & Well No. ~L~,~DK~/c Remarks Additional Requirements: Geology: WVA~ rev: 03/05/80 Well Histocy File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPEN. DIXi No special'effort has been made to chronologically organize this category of information. 11 1111 1111 11 11 11 11 11 11 111111 111111 .... · .000000. 000000 O0 O0 · 00 .-'00 O0 0000 O0 0000 O0 O0 O0 0000 O0 O0 O0 O0 O0 000000 000000 - 7777777777,~,; 7777777777 77 77 77 77 77 77 77 77 77 '000000 000000 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 0000 O0 O0 O0 O0 O0 000000 000000 777777777 777777777~ 77 77 77 77 77 77 77 77 77 0000 O0 77 666666 000000 666666 000000 66 O0 O0 66 O0 O0 66 O0 0000 66 O0 0000 66666666 O0 O0 O0 66666666 O0 00 00 66 66 0000 O0 66 66 0000 O0 66 66 O0 O0 66 66 O0 O0 666666 000000 666666 000000 666666 666666 66 bb 66 66 66666666 66666666 66 66 66 66 66 66 66 66 666666 666666 22 22 22 22 22 22 22 22 22 22 22 22 22 22 2222222222 2222222222 44 44 44 44 44 44 44 44 44 44 44 44 4444444444 4444444444 44 44 44 44 44 44 GGGG H H BBBB PPPP RRRR G H H B B P P R R G H H B B P P R R G HHHHH BBBB ..... PPPP RRRR G GGG H H B B P R R G G H H B B P R R GGG H H BBBB P R R O U DDDD U U D D U U D D U U D D U O D D U U D D UUUUU DDDD H H 000 EEEEE H H 0 0 E H H 0 0 E HHHHH 0 0 E~EE H H 0 0 L H H 0 0 E H H 000 EEEE~ *START* USER PCAb [10707,b0624] JOB MONITOR SWS ~h10537 APR-80. *START* *START* USER PCAh [10707,60624J dOB SHIP SEQ. 1655 SHIP SEO. 1655 DATE ]O-JUL-80 DATE ]O-JUL-80 12:42:38 12:42:38 SSSSS$SS NH HH SSSSSSSS HH HH SS HH HH SS HH HH SS HB HH SS HH HH SSSSSS HHHHHHHHHH SSSSSS HHHHHHHHHH SS HH HH SS HH HH SS HH HH SS HH HH SSSSSSSS HH HH SSSSSSSS HH HH II 1I II II III1 IIII II II II II II II II II II II IIII IIII PPPPPPPP PPPPPPPP PP PP PP PP PP PP PP PP PPPPPPPP PPPPPPPP PP PP PP PP PP PP TTTTTTTTTT OO00OO TTTTTTTTTT O.OOOOO TT OO OO TT 00 OO TT 00 00 TT 00 OD TT OD DO TT 00 OO TT O0 O0 TT 00 OO TT OO OO TT OO OO TT O.OOOOO TT 0.00000 *START* USER PCAL [10707,60624] dOB SHiP SEQ. 1655 DAT~ 3D-JUL-80 MONITOR SWS KLlOE37 APR'80. *START* . FILE: DSKH:SHIP.T.O(255>[10707 60624] CREATED: 30-JUL 80 12:15:23 PRINTED: 30-JUL-80 1~:4]:47 QUEUE SWITCHES{ /FiLE:FORT /COPIES:I /SPACING:I /LIMIT:128 /FORMS:NORMAL 12:42:38 SHIPP1NG INSTRUCTIONS ISSUED 30-JUL-R0 12~14 SHiP TO : VENTURA, CALIFORNIA 93003 PCCC BY GHB PCCC V¥ YV EEEEEEEEEE RRRRRRRR V¥ VV EEEEEEEEEL BRRRRRRR VV VV EE R~ RR VV VV EE R~ RR VV VV EL R~ RR VV VV EL RR RR VV VV EEEEEELE RRRRRRRR VV VV EEEEEEEE RRRRRRRR VV VV EE .RR RR VV VV EE RR RR VV VV EL RR RR VV VV EE RR RR VV EEEEEEEEEE R~ RR VV EEEEEEEEEE RR RR Iiiiii IIIIii II II II II I! II II II II II iiiiii IIIIII YY YY ¥¥ YY YY YY YY YY YY 000000 000000 11 000000 000000 11 O0 O0 O0 00 1111 O0 O0 O0 O0 1111 O0 0000 O0 0000 11 O0 0000 O0 0000 11 O0 O0 O0 O0 O0 O0 11 O0 O0 O0 O0 O0 O0 11 0000 O0 0000 O0 11 0000 O0 0000 O0 11 O0 O0 O0 O0 11 O0 O0 O0 O0 11 000000 000000 111111 000000 000000 111111 *START* USLR PCAL [10707,60624] dOB SHIP SEQ. MONITOR SWS KLIOE]7 APR-80. *START* Flhg: DSKHIVERiF¥.00~<05!>[10707t606241 CREATED: PRINTED: ]0 UUL 80 12:44:00 OUEUE SWITCHES: /FILE:FORT /COPIES~I , /SPACING:I /LIMIT~128 /FORMS:NORMAL 1655 DATE 30-JUL-80 30-OUL-80 12:40:40 12:42:38 SCHLUMBERGER COMPUTING C~NTER 10707,60624 REEL HEADER LENGTH: 112 BYTES REEL NAME: P.C.A.L. SERVICE NAME: EDIT REEL CONTINUATION NUMBER: PREVIOUS REEL NAME: COMMENTS: LIS FORMAT CUSTOMER TAPE DATE: 8O/ 7/30 TAPE HEADER LENGTH: 112 BYTES TAPE NAME: 60624 DATE: 80/ 7/30 SERVICE NAME: EDIT TAPE CONTINUATION NUMBER: O1 PREV1UUS TAPE NAME: COMMENTS: UNIQUE WELL IDENTIFICATION NUMBER IS 50-029-20472 TAPE COMMENTS CSG=l].375~]O50/BTSZ:62.5/FLUID=SALT MUD/DENS:IO.]/VISC:44/PH=9.0/ FL=5,6/RM=.{7~62/RMf=.12~62/HMC=.35~b2/BHT=I47 EOF FILE HEADER LENGTH: 62 BYTES FILE NAME: EDIT .00! MAXIMUM PHYSICAL RECORD LENGTH: PREVIOUS FILE NAME: 1024 BYTES WELL SiTE LENGTH: COMPANY: WELL: F'IELD: RANGE: TOWN: SECTION: COUNTY: STATE: INFORMATION RECORD 180 OYTES ATLANTIC RICHFIELD CO. KUPARUK E-2 KUPARUK IOE 16 N. SLOPE ALASKA DATA f~O~MAT SPECIFICATION LENGTH: 810 BYTES ENTR'~ BLOCKS: TYPE 0 ! REP CODE 66 ENTR~ 0 DATUM ,SPEC. If'iCATION BI.,OCK$: ENTRY IC TOOL I DEPT 2 LLD DLL bLS DLL 4 GR DLL 5 CALI DLb 7 SGR CNL 8 CAbI CNL 9 DRHO FDC 10 NPHI CNL 11 RHOB CN5 12 NRAT CNb NCNL CNL 14 FCNL CNL 15 POTA 16 THOR 17 URAN 18 GRST 19 GR BHC 20 DT BHC SVORD# UNITS APl APl AP1 APi FILE# SIZE EXP PROC SAM REP FT 0 0 0 0 0 4 0 0 1 68 0 0 OHMM 11 22 10 0 0 ~ 0 0 1 b8 0 0 OHM~ 11 22 9 0 0 4 0 0 1 68 0 0 GAPI 11 31 32 O 0 4 0 0 1 b8 0 0 IN 11 28 2 0 0 4 0 0 1 68 0 0 OHMM 11 27 1 0 0 4 0 0 1 b8 0 0 GAPI 42 31 32 0 0 4 0 0 1 68 0 0 IN 42 28 1 0 0 4 0 0 1 b8 0 0 G/CB 42 44 0 0 0 4 0 0 1 b8 0 0 PU 42 68 B 0 0 4 0 0 1 68 0 0 G/C3 42 35 1 0 0 4 0 0 1 68 0 0 C/C 42 42 I 0 0 4 0 0 1 68 0 0 CPS 42 34 92 0 0 4 0 0 1 b8 0 0 CPS 42 34 93 0 0 4 0 0 1 68 0 0 PPM 0 0 0 0 0 4 0 0 1 68 0 0 PPM 0 0 0 0 0 4 0 0 1 68 0 0 PPM 0 0 0 0 0 4 0 0 1 b8 0 0 GAPI 0 0 0 0 0 4 0 0 1 68 0 0 GAPI 60 31 32 0 0 4 0 0 1 68 0 0 U$/~ 60 52 32 0 0 4 0 0 1 b8 0 0 ~ · e o e · · e e · e · o e o · · · · · · · e · · · · · · · · · e · e · · Z ~~ ~~0 ~~0 0~~ ~~ ~0~ ~~0 0~o~o 0~~ ~ oeooe oeeee emcee oeoo. oeec. eeoeo oooee eeeee eeeoe ~ · · e e o e · · e e · · o e o e · · · · · · · e e · · o · · · · · · e · o e o e e e e. · Z 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 :X: 0 0 0 0 0 0 0 0 0 ~ · · · · · · e · · ~ ~'~ 0 0 0 0 0 0 0 0 ~] ~ 0 0 0 0 0 0 0 0
