The URL can be used to link to this page

Home My WebLink About187-1341. 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 9050'feet None feet true vertical 6321'feet None feet Effective Depth measured 9050'feet 8453', 8523'feet true vertical 6321'feet 5906', 5970'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 8728' MD 6096' TVD Packers and SSSV (type, measured and true vertical depth) 8453' MD 8523' MD N/A 5906' TVD 5970' TVD 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: 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 Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 4092' 3045' Burst Collapse Production Liner 8987' Casing 6300'9020' 4057' 115'Conductor Surface Intermediate 16" 9-5/8" 79' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 187-134 50-103-20093-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0025531, ADL025523 Kuparuk River Field/ Kuparuk River Oil Pool KRU 3H-20 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 115' ~ ~~ Well Remains Shut-In ~~ ~ Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: MFT Feedthru Packer Packer: Baker FHL Packer SSSV: None Dusty Ward dusty.ward@conocophillips.com (907) 265-6531Senior Workover Engineer 8681-8691', 8706-8720', 8740-8780' 6064-6071', 6081-6091', 6105-6133' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Sundry Number or N/A if C.O. Exempt: 322-628/322-669 By Samantha Carlisle at 2:02 pm, Jan 23, 2023 Page 1/7 3H-20 Report Printed: 1/13/2023 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) 12/14/2022 12:00 12/14/2022 16:00 4.00 MIRU, MOVE MOB P Pull pits away from sub and stage on pat. Moving sub off 3H-12. Hang WellHead in cellar, spread pit liner and stage wellhead adaptor spool and DSA for BOP stack. Clean up 3H-12. 12/14/2022 16:00 12/14/2022 19:00 3.00 MIRU, MOVE MOB P Spot sub over well, lay mats and herculite. Spot pits to sub, lay mats and herculite. 12/14/2022 19:00 12/14/2022 20:30 1.50 MIRU, MOVE MOB P Berm in rig. Hook up inter connect. Turn steam and air on to pits. Spot cuttings tank. R/U tiger tank line & Choke House 12/14/2022 20:30 12/14/2022 22:00 1.50 MIRU, MOVE MOB P Get measurements for riser height from tubing spool height. Complete rig acceptance checklist. Offloading 13.1 PPG LSND into pits. Rig accepted @ 22:00 Hrs. 12/14/2022 22:00 12/15/2022 00:00 2.00 MIRU, WELCTL RURD P Rig up circ manifold in cellar. Continue offloading 13.1 PPG LSND into pits. 12/15/2022 00:00 12/15/2022 01:00 1.00 MIRU, WELCTL RURD P Continue offloading 13.1 PPG LSND into pits. Bleed OA F/ 210 PSI T/ 5 PSI - Mostly gas. 12/15/2022 01:00 12/15/2022 01:15 0.25 MIRU, WELCTL PRTS P PT circ manifold and tiger tank lines. Initial pressures: TBG=500, IA=210 12/15/2022 01:15 12/15/2022 04:15 3.00 MIRU, WELCTL KLWL P Bleed free gas off of TBG. Tubing down T/ 200 PSI, IA T/ 0 PSI. Circ355 Bbls 13.1 PPG LSND down tubing taking returns from IA to tiger tank @ 3 BPM, Initially holding 500 PSI back pressure in choke house. FCP w/ open choke 950 PSI. 12/15/2022 04:15 12/15/2022 05:15 1.00 MIRU, WELCTL OWFF P OWFF - Trickle out or IA diminishing to nothing. Tubing sputtering diminishing to nothing Suck out tiger tank. 12/15/2022 05:15 12/15/2022 06:30 1.25 MIRU, WELCTL MPSP P Set Type H BPV and PT same to 1000 psi for 10 mins. 12/15/2022 06:30 12/15/2022 12:30 6.00 MIRU, WHDBOP NUND P ND Down Wellhead and NU DSA and BOP Stack. 12/15/2022 12:30 12/15/2022 16:30 4.00 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/3500 PSI for 5 Min each, Tested annular, UVBR's, w/ 3 1/2" test joints. Test blinds rams. Choke valves #1 to #16, upper and lower top drive well control valves. Test 3 1/2" HT-38 FOSV, and IBOP. Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=3000 PSI, after closure=1500 PSI, 200 PSI attained =21 sec, full recovery attained = 109 sec. UVBR's= 6 sec, Annular= 30 sec. Simulated blinds= 5 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 1945 PSI. Test gas detectors, PVT and flow show.Test Witness Waived by AOGCC rep Bob Noble. 12/15/2022 16:30 12/15/2022 17:00 0.50 MIRU, WHDBOP RURD P Blow down and Rig down testing equipment. 12/15/2022 17:00 12/15/2022 17:30 0.50 MIRU, WHDBOP MPSP P Check for pressure under BPV and pull same. Rig: NABORS 7ES RIG RELEASE DATE 12/25/2022 Page 2/7 3H-20 Report Printed: 1/13/2023 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) 12/15/2022 17:30 12/15/2022 18:00 0.50 COMPZN, RPCOMP OWFF P Observe well for flow. 12/15/2022 18:00 12/15/2022 18:30 0.50 COMPZN, RPCOMP RURD P M/U landing joint. M/U TD. Set down 10K on hanger. BOLDS. 8,540.0 12/15/2022 18:30 12/15/2022 18:45 0.25 COMPZN, RPCOMP PULL P Pull hanger, hanger of seat @ 70K, pipe free @ 155K, PUW 90K. Pull T/ 8510'. 8,540.0 8,510.0 12/15/2022 18:45 12/15/2022 20:15 1.50 COMPZN, RPCOMP CIRC P Circ well with 13.1 PPG LSNG @ 4 BPM, 830 PSI. Fluid lightened up pumping 11.8 PPG down hole. R/U HES spooling unit. 8,510.0 8,510.0 12/15/2022 20:15 12/15/2022 23:15 3.00 COMPZN, RPCOMP COND T Condition mud system up T/ 13.3 PGG. Circ hole @ 2 BPM, 785 PSI. 8,510.0 8,510.0 12/15/2022 23:15 12/15/2022 23:30 0.25 COMPZN, RPCOMP OWFF P OWFF - No flow 8,510.0 8,510.0 12/15/2022 23:30 12/16/2022 00:00 0.50 COMPZN, RPCOMP PULL P L/D hanger. Connect control lines T/ spooler. L/D completion T/ 8450', PUW=90K. 8,510.0 8,450.0 12/16/2022 00:00 12/16/2022 01:00 1.00 COMPZN, RPCOMP PULL P Continue L/D completion F/ 8450', T/ 8000', PUW=90K. 8,450.0 8,000.0 12/16/2022 01:00 12/16/2022 01:30 0.50 COMPZN, RPCOMP CIRC P Pump 25 Bbls dry job. B/D TD. 8,000.0 8,000.0 12/16/2022 01:30 12/16/2022 06:00 4.50 COMPZN, RPCOMP PULL P Continue L/D completion F/ 8000', T/ 5030', PUW=84K. 8,000.0 5,030.0 12/16/2022 06:00 12/16/2022 07:00 1.00 COMPZN, RPCOMP PULD P L/D Orbit Valve and R/D Spooling unit. 5,030.0 5,030.0 12/16/2022 07:00 12/16/2022 08:15 1.25 COMPZN, RPCOMP CIRC P Circulate Surface to Surface @ 3.5 bpm, 400 psi. 5,030.0 5,030.0 12/16/2022 08:15 12/16/2022 11:00 2.75 COMPZN, RPCOMP PULL P Continue L/D completion F/ 5030' T/2086' 5,030.0 2,086.0 12/16/2022 11:00 12/16/2022 11:45 0.75 COMPZN, RPCOMP CIRC P Circulate Surface to Surface @ 3.0 bpm, 120 psi. 2,086.0 2,086.0 12/16/2022 11:45 12/16/2022 15:00 3.25 COMPZN, RPCOMP PULL P Continue L/D completion F/ 2086', While TOOH with Completion, Tubing had holes with heavy scale from Joint #226. Joint #258 had parted and only 6 feet of 258 was recovered. Bottom 6" parted joint had 3 1/4" ID. Leaving 240' of completion in hole. Estimated top of fish, 8300'. 2,086.0 270.0 12/16/2022 15:00 12/16/2022 16:00 1.00 COMPZN, RPCOMP CLEN P Clean and clear RF and pipe shed. 270.0 12/16/2022 16:00 12/16/2022 19:30 3.50 COMPZN, RPCOMP PULD T Process 98 joints of drill pipe for fishing ops. 6ea 4 3/4" DC's. Load Yellowjacket fishing tools in pipe shed. 0.0 0.0 12/16/2022 19:30 12/16/2022 20:00 0.50 COMPZN, RPCOMP SVRG T Service rig. Grease IR and draw works. 0.0 0.0 12/16/2022 20:00 12/16/2022 20:30 0.50 COMPZN, RPCOMP RURD T Install wear bushing. 0.0 0.0 12/16/2022 20:30 12/16/2022 21:00 0.50 COMPZN, RPCOMP SFTY T Crew change out PJSM w/ rig crew on picking up BHA #1 Overshot. 0.0 0.0 12/16/2022 21:00 12/16/2022 23:30 2.50 COMPZN, RPCOMP BHAH T M/U BHA #1 Overshot T/ 224', SOW=40K. 0.0 224.0 12/16/2022 23:30 12/17/2022 00:00 0.50 COMPZN, RPCOMP PULD T PUDP T/ 476', SOW=41K. 224.0 476.0 12/17/2022 00:00 12/17/2022 01:30 1.50 COMPZN, RPCOMP PULD T PUDP F/ 476' T/ 1743;, SOW=53K. 476.0 1,743.0 12/17/2022 01:30 12/17/2022 02:00 0.50 COMPZN, RPCOMP SVRG T Service rig. 1,743.0 1,743.0 12/17/2022 02:00 12/17/2022 03:45 1.75 COMPZN, RPCOMP PULD T PUDP F/ 1743' T/ 3311', PUW=75K, SOW=60K. 1,743.0 3,311.0 Rig: NABORS 7ES RIG RELEASE DATE 12/25/2022 Page 3/7 3H-20 Report Printed: 1/13/2023 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) 12/17/2022 03:45 12/17/2022 06:00 2.25 COMPZN, RPCOMP CIRC T Circ STS @ 3 BPM, 550 PSI. Mud in pits 68*, Mud coming back at 1000' 50*, @ 1500' 52*, @ 2000' 53*. 3,311.0 3,311.0 12/17/2022 06:00 12/17/2022 06:45 0.75 COMPZN, RPCOMP PULD T Continue to circulate while processing more drill pipe in pipe shed 3,311.0 3,311.0 12/17/2022 06:45 12/17/2022 08:45 2.00 COMPZN, RPCOMP PULD T PUDP F/ 3311' T/ 6151', PUW=80K, SOW=65K. 3,311.0 6,151.0 12/17/2022 08:45 12/17/2022 09:15 0.50 COMPZN, RPCOMP SVRG T Service Rig 6,151.0 6,151.0 12/17/2022 09:15 12/17/2022 12:00 2.75 COMPZN, RPCOMP CIRC T Circ STS @ 4 BPM, 980 PSI. Mud in pits 68*, Mud coming back 63* Load pipe shed with more drill pipe 6,151.0 6,151.0 12/17/2022 12:00 12/17/2022 13:15 1.25 COMPZN, RPCOMP PULD T PUDP F/ 6151' T/ 7954', PUW=90K, SOW=75K. 6,151.0 7,954.0 12/17/2022 13:15 12/17/2022 14:45 1.50 COMPZN, RPCOMP CIRC T Circ STS @ 4 BPM, 1200 PSI. Mud in pits 67*, Mud coming back 63* Load pipe shed with more drill pipe 7,954.0 7,954.0 12/17/2022 14:45 12/17/2022 15:15 0.50 COMPZN, RPCOMP PULD T PUDP F/ 7954' T/ 8200', PUW=95K, SOW=80K. 7,954.0 8,200.0 12/17/2022 15:15 12/17/2022 16:00 0.75 COMPZN, RPCOMP WASH T Wash down F/8200' to estimated top fish @ 8270' at 3 bpm, 1150 psi. Dry PUW=165K, SOW 85K. W/ pumps on PUW=150K, SOW=80K. 8,200.0 8,295.0 12/17/2022 16:00 12/17/2022 18:00 2.00 COMPZN, RPCOMP FISH T Located top fish @ 8295' swallowed 5' of stub to 8300' with no-go. Working seals in PBR without jarring. Straight pulling T/ 200K. @ 2BPM, 1130 PSI. Continue to work seals to try to free tubing stub. - No movement. 8,295.0 8,295.0 12/17/2022 18:00 12/17/2022 18:30 0.50 COMPZN, RPCOMP SVRG T Service Rig 8,295.0 8,295.0 12/17/2022 18:30 12/18/2022 00:00 5.50 COMPZN, RPCOMP WAIT T Consult w/ town - decision made to call out E-line and cut tubing above CTD fish in tubing. Mobilize E-line tools for Deadhorse. Set in slips w/ 30K tension. R/D, B/D TD. M/U XO, 3 1/2: EUE FOSV and head pin. R/U cement hose. Pumping 50 Bbls @ 2 BPM, 1200 PSI every hour. Cleaning pit #1. 8,295.0 8,295.0 12/18/2022 00:00 12/18/2022 03:00 3.00 COMPZN, RPCOMP WAIT T Wait on E-line. Verify jewelry tally and running order. Pumping 50 Bbls @ 2 BPM, 1200 PSI every hour. 8,295.0 8,295.0 12/18/2022 03:00 12/18/2022 03:30 0.50 COMPZN, RPCOMP SVRG T Service rig. 8,295.0 12/18/2022 03:30 12/18/2022 08:30 5.00 COMPZN, RPCOMP RURD T Spot E-line unit. E-line re-head. R/U pump in sub and packoff. R/U 1.75" RCT tool string. 8,295.0 8,295.0 12/18/2022 08:30 12/18/2022 12:45 4.25 COMPZN, RPCOMP ELNE T RIH. Unable to get E-Line cutter and tools passed 8120' made several attempts with no success. POOH and Rig down ELine. 8,295.0 8,295.0 12/18/2022 12:45 12/18/2022 13:15 0.50 COMPZN, RPCOMP TRIP T Release overshot from tubing stub and POOH T/ 8168', PUW=160K. . 8,295.0 8,168.0 12/18/2022 13:15 12/18/2022 13:30 0.25 COMPZN, RPCOMP OWFF T OWFF - no flow 8,168.0 8,168.0 12/18/2022 13:30 12/18/2022 14:00 0.50 COMPZN, RPCOMP CIRC T Pump 20 Bbls dry job @ 2 BPM, 1050 PSI. 8,168.0 8,168.0 12/18/2022 14:00 12/18/2022 19:00 5.00 COMPZN, RPCOMP TRIP T POOH F/ 8168' T/ 224'', PUW=160K. . 8,168.0 2,210.0 12/18/2022 19:00 12/18/2022 20:00 1.00 COMPZN, RPCOMP BHAH T Standback Drill Collars and L/D BHA #1 T/ surface, PUW=38K. 224.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 12/25/2022 Page 4/7 3H-20 Report Printed: 1/13/2023 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) 12/18/2022 20:00 12/18/2022 20:30 0.50 COMPZN, RPCOMP SVRG T Service rig. 0.0 0.0 12/18/2022 20:30 12/18/2022 21:00 0.50 COMPZN, RPCOMP SFTY T PJSM w/ Yellowjacket and rig crew on picking up BHA #2 0.0 0.0 12/18/2022 21:00 12/18/2022 22:15 1.25 COMPZN, RPCOMP BHAH T M/U BHA #2, 5 joints of wash pipe and outside cutter w/ ported float T/ 164', SOW=35K 0.0 164.0 12/18/2022 22:15 12/18/2022 22:45 0.50 COMPZN, RPCOMP PULD T PUDP T/ 416', SOW=37K. 164.0 416.0 12/18/2022 22:45 12/19/2022 00:00 1.25 COMPZN, RPCOMP TRIP T RIH F/ 416' T/ 2049', SOW=53K. Filling DP every 15 stands. 416.0 2,049.0 12/19/2022 00:00 12/19/2022 02:30 2.50 COMPZN, RPCOMP TRIP T RIH F/ 2049' T/ 8171', PUW=156K, SOW=83K. Filling DP every 15 stands. 2,049.0 8,171.0 12/19/2022 02:30 12/19/2022 03:00 0.50 COMPZN, RPCOMP SVRG T Service rig 8,171.0 8,171.0 12/19/2022 03:00 12/19/2022 04:30 1.50 COMPZN, RPCOMP WASH T Obtain parameters, pump @ 2 BPM, 1180 PSI, @ 3 BPM, 1320 PSI, @ 4 BPM, 1470 PSI, Rotate @ 60 RPM, 7.8K Free torque. ROT=100K. Wash down @ 2 BPM, F/ 8171', saw collar @ 8321.5'. @ 8345K took 10K sting weight. Increase pumpsT/ 4 BPM, attempt T/ rotate, stalled @ 10.5K. Let torque out, worked pipe up and down, pulled free @ 165K. Attempt T/ wash down again @ 4 BPM took weight in same spot. 8,171.0 8,345.0 12/19/2022 04:30 12/19/2022 07:00 2.50 COMPZN, RPCOMP CPBO T P/U engage cutter on collar @ 8322'. S/O T/ 8325'. ROT @ 60 RPM, 7.8K Tq. Slowly walk pipe back up T/ engage collar and cut pipe @ ~8324' After two hours, no real indication that tubing is cut. 8,345.0 8,324.0 12/19/2022 07:00 12/19/2022 10:00 3.00 COMPZN, RPCOMP BHAH XT Start working Drill pipe to get free from Collar at 8321' worked pipe F/8321' to 8343' while pumping @ 3 bpm, 1380 psi, 50 rpm with 8.5K of torque, Dn Wt - 10k, Up Wt 195k. 8,324.0 8,343.0 12/19/2022 10:00 12/19/2022 13:30 3.50 COMPZN, RPCOMP TRIP T After three hours of working drill pipe, was able to get movement again. Blow down top drive and TOOH to check BHA. Up Wt 150k 8,324.0 165.0 12/19/2022 13:30 12/19/2022 14:30 1.00 COMPZN, RPCOMP BHAH T OOH with Drill Pipe. Break down BHA and Inspect same. Recovered entire BHA, lost 1 cutter blade and the tip of another blade in hole, and all 5 springs on the Anchor Assy. 165.0 0.0 12/19/2022 14:30 12/19/2022 15:00 0.50 COMPZN, RPCOMP SVRG T Rig Service. 0.0 0.0 12/19/2022 15:00 12/19/2022 16:30 1.50 COMPZN, RPCOMP BHAH T PU/MU BHA #3. Wash Over Pipe and Waive Bottom Burn Shoe Assy with Jars T/ 188', SOW=38K. 0.0 188.3 12/19/2022 16:30 12/19/2022 21:00 4.50 COMPZN, RPCOMP TRIP T RIH F/ 188' T/ 8132', PUW=157K, SOW=82K. Filling DP every 30 stands. 188.3 8,132.0 Rig: NABORS 7ES RIG RELEASE DATE 12/25/2022 Page 5/7 3H-20 Report Printed: 1/13/2023 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) 12/19/2022 21:00 12/20/2022 00:00 3.00 COMPZN, RPCOMP WASH T Obtain parameters, pump @ 2 BPM, 1220 PSI, @ 3 BPM, 1350 PSI, @ 4 BPM, 1510 PSI, Rotate @ 60 RPM, 8K Free torque. ROT=100K. Wash down @ 2 BPM, F/ 8132' T/ 8295', Rotate over tubing stub @ 20 RPM, 8K Tq. Wash down T/ 8321'. Rotate over collar @ 20 RPM, 8.5K Tq. Wash down T/ 8343', took weight. Burn down F/ 8330' @ 3 BPM, 1300 PSI, 60 RPM, 8-9.5K Tq. Saw heavy work F/ 8341' T/ 8346'. Burn down T/ 8352. 8,132.0 8,352.0 12/20/2022 00:00 12/20/2022 04:15 4.25 COMPZN, RPCOMP REAM T Burn down F/ 8352' @ 3 BPM, 1300 PSI, 60 RPM, 8-9.5K Tq. Saw heavy work at collar @ 8352''. Burn down T/ GLM @ 8424'. Set down 5K. 8,352.0 8,424.0 12/20/2022 04:15 12/20/2022 06:00 1.75 COMPZN, RPCOMP CIRC T Circ BU @ 5 BPM, 1945 PSI. Rotating and reciprocating. 8,424.0 8,416.0 12/20/2022 06:00 12/20/2022 06:30 0.50 COMPZN, RPCOMP SVRG P Rig Services 8,416.0 8,416.0 12/20/2022 06:30 12/20/2022 08:30 2.00 COMPZN, RPCOMP TRIP T Blow down top drive. TOOH f/8416' to 2420' 8,416.0 2,420.0 12/20/2022 08:30 12/20/2022 10:00 1.50 COMPZN, RPCOMP SLPC P Slip & Cut 69 feet of drill line 2,420.0 2,420.0 12/20/2022 10:00 12/20/2022 10:45 0.75 COMPZN, RPCOMP TRIP T TOOH f/2420' to BHA 2,420.0 188.0 12/20/2022 10:45 12/20/2022 12:00 1.25 COMPZN, RPCOMP BHAH T L/D BHA #3. Wash Over Pipe and Waive Bottom Burn Shoe Assy with Jars. 188.0 0.0 12/20/2022 12:00 12/20/2022 14:45 2.75 COMPZN, RPCOMP WAIT P Waiting for offsite tools from Yellowjacket. 0.0 0.0 12/20/2022 14:45 12/20/2022 16:00 1.25 COMPZN, RPCOMP BHAH T PU/MU BHA #4, 5 joints of wash pipe and outside cutter w/ ported float OAL- 164' 0.0 164.0 12/20/2022 16:00 12/20/2022 19:30 3.50 COMPZN, RPCOMP TRIP T RIH F/ 164' T/ 8,321'. Filling DP every 30 stands. 164.0 8,321.0 12/20/2022 19:30 12/20/2022 20:00 0.50 COMPZN, RPCOMP WASH T Wash down F/8,210' - 8,420' @ 42 gpm, 900 psi. (had no problem washing pass the collar @ 8,414') PUW=155k- SOW=85k- ROT=105k 8,321.0 8,420.0 12/20/2022 20:00 12/21/2022 00:00 4.00 COMPZN, RPCOMP CPBO T Cut Tbg. @8,420 ' pumping @ 42gpm, 165 psi. 45 rpm. Tq 8.7k PUW=155k- SOW=85k- ROT=105k 8,420.0 8,415.0 12/21/2022 00:00 12/21/2022 02:00 2.00 COMPZN, RPCOMP CIRC P Circ. B/U @ 2bpm 1050 psi. ( Low pump rate due not pumping the fish off. 8,415.0 8,415.0 12/21/2022 02:00 12/21/2022 02:30 0.50 COMPZN, RPCOMP OWFF P Pull 2 stands, monitor well (static) pump dry-job 8,415.0 8,201.0 12/21/2022 02:30 12/21/2022 06:00 3.50 COMPZN, RPCOMP TRIP P TOOH F/8,201' - T/2,526 8,201.0 2,526.0 12/21/2022 06:00 12/21/2022 06:30 0.50 COMPZN, RPCOMP SVRG P Rig Service 2,526.0 2,526.0 12/21/2022 06:30 12/21/2022 07:30 1.00 COMPZN, RPCOMP TRIP P TOOH f/2,526' to BHA. 2,526.0 164.0 12/21/2022 07:30 12/21/2022 11:30 4.00 COMPZN, RPCOMP BHAH P TOOH, starting breaking down BHA. Recovered 121' of 3.5" TBG with 12' of CT BHA Inside. New top Tubing Stub 8,416', Top of CT BHA 8,411' 164.0 0.0 12/21/2022 11:30 12/21/2022 12:30 1.00 COMPZN, RPCOMP PULD P L/D Third Party tools. Clean and Clear Rig Floor. 0.0 0.0 12/21/2022 12:30 12/21/2022 14:30 2.00 COMPZN, RPCOMP WAIT P Discuss options with Town. Order Grapple Assy. from YellowJacket Shop. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 12/25/2022 Page 6/7 3H-20 Report Printed: 1/13/2023 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) 12/21/2022 14:30 12/21/2022 15:45 1.25 COMPZN, RPCOMP BHAH P PU/MU BHA #5. 5-3/4" Oversized Guide w/4-11/16" Overshot Bowl 1.25"ID Grapple. 0.0 19.9 12/21/2022 15:45 12/21/2022 19:15 3.50 COMPZN, RPCOMP TRIP P TIH w/BHA #5, f/20' to top of CT Fish @ 8411' filling every 30 stands of drill pipe.PUW=145k SOW=87k 19.9 8,411.0 12/21/2022 19:15 12/21/2022 21:45 2.50 COMPZN, RPCOMP FISH P Wash over the top if the fish, @ 42 gpm. 450psi. Engauge fish @ 8,415. Work the pick up weight up to 196k (50k over pick up weight) pull on fish until fish came free. 8,411.0 8,415.0 12/21/2022 21:45 12/22/2022 00:00 2.25 COMPZN, RPCOMP CIRC P Pull up to 8,369 and circ. and condition mud 8,415.0 8,369.0 12/22/2022 00:00 12/22/2022 03:30 3.50 COMPZN, RPCOMP CIRC P Pull up to 8,369 and circ. and condition mud @ 2bpm 1100psi.. mud weight is coming back 13,1 - 13.2 ppg mud weight going in 13.3ppg 8,369.0 8,369.0 12/22/2022 03:30 12/22/2022 04:15 0.75 COMPZN, RPCOMP OWFF P Turn pumps off, check for flow (static) pump dry-job, blow down equipment. 8,369.0 8,369.0 12/22/2022 04:15 12/22/2022 08:30 4.25 COMPZN, RPCOMP TRIP P TOOH F/8,390' to BHA #5 8,369.0 20.0 12/22/2022 08:30 12/22/2022 10:30 2.00 COMPZN, RPCOMP BHAH P L/D BHA #5, L/D 3.5" TBG with CT BHA stuck inside. L/D No-Go Pup and Seal Assembly 20.0 0.0 12/22/2022 10:30 12/22/2022 11:30 1.00 COMPZN, RPCOMP CLEN P L/D Fishing Tools and clean and clear Rig floor. 0.0 0.0 12/22/2022 11:30 12/22/2022 12:30 1.00 COMPZN, RPCOMP PULD P Unload junk tubing and BHA from pipe shed and load next BHA in shed. 0.0 0.0 12/22/2022 12:30 12/22/2022 13:00 0.50 COMPZN, RPCOMP SVRG P Rig Service. 0.0 0.0 12/22/2022 13:00 12/22/2022 14:30 1.50 COMPZN, RPCOMP BHAH P PU/MU BHA #6. 7" Scraper, boot basket, string magnet, jars and drill collars. OAL=253 ft. 0.0 253.1 12/22/2022 14:30 12/22/2022 17:15 2.75 COMPZN, RPCOMP TRIP P TIH w/BHA #6 253.1 8,386.0 12/22/2022 17:15 12/22/2022 19:00 1.75 COMPZN, RPCOMP WASH P Wash F/8,386' - T/8,533' 8,386.0 8,533.0 12/22/2022 19:00 12/22/2022 20:30 1.50 COMPZN, RPCOMP CIRC P Pull out to 8,511' Circ & condition mud @ 4bpm 1400 psi. 8,533.0 8,511.0 12/22/2022 20:30 12/23/2022 00:00 3.50 COMPZN, RPCOMP TRIP P TOOH F/8,511' - T/1,750 8,511.0 1,750.0 12/23/2022 00:00 12/23/2022 01:00 1.00 COMPZN, RPCOMP TRIP P TOOH F/1,750' - T/253 1,750.0 253.0 12/23/2022 01:00 12/23/2022 02:00 1.00 COMPZN, RPCOMP BHAH P L/D BHA # 6 253.0 0.0 12/23/2022 02:00 12/23/2022 02:30 0.50 COMPZN, RPCOMP SVRG P Service the draw works, & Top Drive 0.0 0.0 12/23/2022 02:30 12/23/2022 03:30 1.00 COMPZN, RPCOMP BHAH P P/U BHA #7 Test Packer 0.0 15.0 12/23/2022 03:30 12/23/2022 07:15 3.75 COMPZN, RPCOMP TRIP P TIH f/15' to 8492'. Up Wt 165k / SOW 85k. Set Test Packer at 8492' 15.0 8,492.0 12/23/2022 07:15 12/23/2022 08:00 0.75 COMPZN, RPCOMP PRTS P RU Testing Equipment and PT 7' CSG to 1450 psi for 15 mins. Good Test. Release Test Packer. Blow Down Top Drive and Testing Equipment. 8,492.0 8,492.0 12/23/2022 08:00 12/23/2022 14:00 6.00 COMPZN, RPCOMP TRIP P TOOH Sideways with Drill Pipe. 8,492.0 0.0 12/23/2022 14:00 12/23/2022 14:30 0.50 COMPZN, RPCOMP OTHR P Pull Wear Bushing 0.0 0.0 12/23/2022 14:30 12/23/2022 16:00 1.50 COMPZN, RPCOMP RURD P rig up to run 3 1/2 tubing. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 12/25/2022 Page 7/7 3H-20 Report Printed: 1/13/2023 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) 12/23/2022 16:00 12/24/2022 00:00 8.00 COMPZN, RPCOMP RCST P PU/MU and RIH with 3.5 Completion Pre-Tally 0.0 2,405.0 12/24/2022 00:00 12/24/2022 07:15 7.25 COMPZN, RPCOMP RCST P Continue RIH with 3.5 Completion Pre- Tally f/2405' 2,405.0 8,492.0 12/24/2022 07:15 12/24/2022 09:00 1.75 COMPZN, RPCOMP THGR P PU/MU Space Out Pup's, Hanger and Landing Joint. Land Hanger, RILDS. Up Wt 100K / Dn Wt 55K 8,492.0 8,526.0 12/24/2022 09:00 12/24/2022 09:15 0.25 COMPZN, RPCOMP MPSP P Pull Landing Joint and Set BPV. 8,526.0 8,526.0 12/24/2022 09:15 12/24/2022 09:30 0.25 COMPZN, RPCOMP PRTS P PT BPV from below to 1000 psi for 5 mins. 8,526.0 8,526.0 12/24/2022 09:30 12/24/2022 14:00 4.50 COMPZN, WHDBOP RURD P Drain Stack and Pull Riser. RD BOPE and DSA. RU Wellhead. 8,526.0 8,526.0 12/24/2022 14:00 12/24/2022 15:00 1.00 COMPZN, WHDBOP PRTS P PT Tubing Hanger Void to 5K. PT Wellhead to 5K. (Good Test) 0.0 0.0 12/24/2022 15:00 12/24/2022 15:30 0.50 COMPZN, WHDBOP MPSP P Check for Pressure under BPV and Pull Same. PT Manifold. 0.0 0.0 12/24/2022 15:30 12/24/2022 16:45 1.25 COMPZN, WHDBOP RURD P RU Hoses and manifold for circulating and testing operations. 0.0 0.0 12/24/2022 16:45 12/24/2022 22:00 5.25 COMPZN, WHDBOP CIRC P Reverse Circulate 70 bbl FreshWater Spacer follow by 240 bbls of CI Brine down the IA taking return up the TBG to the open top tank. Pumping 2.5 bpm at 1150 psi. 0.0 0.0 12/24/2022 22:00 12/25/2022 00:00 2.00 COMPZN, WHDBOP PACK P Install Lubricator and Drop 1.375" OD Ball & Rod. Pressure up to set Packer. 0.0 0.0 12/25/2022 00:00 12/25/2022 01:00 1.00 COMPZN, WHDBOP PRTS P PT Tubing to 3500 psi for 30 mins. Bleed down Tubing to 2000 psi and PT IA to 2500 psi for 30 mins. Dump pressure on Tubing to shear the SOV. 0.0 0.0 12/25/2022 01:00 12/25/2022 02:00 1.00 COMPZN, WHDBOP RURD P Blow Down Surface Lines. MIRU LRS. 0.0 0.0 12/25/2022 02:00 12/25/2022 06:00 4.00 COMPZN, WHDBOP FRZP P Circulate 80 bbls of Diesel Down IA, RU Jumper hose and allow well to equalize. 0.0 0.0 12/25/2022 06:00 12/25/2022 12:00 6.00 DEMOB, MOVE DMOB P Clean Mud from Pits. RDMO 7ES. Clean around location and Cellar. Release Rig. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 12/25/2022 DTTMSTART JOBTYP SUMMARYOPS 12/14/2022 RECOMPLETION Pull pits away from sub. Pull sub off of 3H-12A. Clean up around well. Transport sub to 3H-20. Spot sub over well. Spot pits to sub. Berm in rig. Hook up interconnect and electrical to pits. Turn on steam and air. Spot cuttings tank. Get measurements for riser height from tubing spool height. Take initial pressures T/IA/OA. Complete acceptance checklist. Offload 13.1 PPG LSND into pits. Rig up circ manifold in cellar. Pressure test circ manifold & tiger tank. 12/15/2022 RECOMPLETION Continue offloading 13.1 PPG LSND into pits. Pressure test circ manifold & tiger tank. Bleed free gas off TBG/IA. Circ 355 Bbls down tubing taking returns up IA T/ tiger tank. Good 13.1 PPG returns at tiger tank. OWFF, suck out tiger tank. Set BPV and PT same. ND Tree and NU DSA & BOPE. Perform Initial BOP Test per Sundry. Pull test dart & BPV. Make up landing joint. BOLDS. Pull hanger to rig floor. Circulate well with 13.3 PPG LSND. Lay down hanger connect control lines to spooling unit. Lay down 3 1/2" completion T/ 8450'. 12/16/2022 RECOMPLETION Lay down completion T/ 8000'. Pump dry job. Continue lay down completion T/ 5030, lay down orbit valve. RIg down HES spooling unit. Circulate STS to warm mud up. Continue lay down tubing T/ 2000'. Circulate STS. Continue to lay down completion - Parted pipe at joint #258 @ ~8300'. Process 98 joints of drill pipe and BHA #1 overshot. Run in hole with BHA #1 T/ 224'. Pick up drill pipe T/ 476' 12/17/2022 RECOMPLETION Continue pick up drill pipe T/ 3311. Circulate STS. Process more drill pipe. Continue pick up drill pipe T/ 6151. Circulate STS. Process more drill pipe. Continue pick up drill pipe T/ 8200. Wash down, located top fish @ 8295' swallowed 5' of stub to 8300'. Attempt to work seals free, straight pull T/ 50K over pull -no movement. Consult w/ town - decision made to call out E-line and cut tubing above CTD fish in tubing. Mobilize E-line tools from Deadhorse. Set in slips w/ 30K tension. Clean pit #1. 12/18/2022 RECOMPLETION Waiting on E-line. Verify jewelry tally. Spot E-line unit. E-line re-head. Rig up pump in sub and packoff. Rig up Alaska E-line w/ 1.75" RCT tool string. Run in hole, pumping to assist E-line down. Could not pass 8120'. Pull out of hole and rig down E-line. Release overshot from tubing stub. Pump dry job. Pull out of hole. Lay down BHA #1. Make up BHA #2 wash pipe with outside cutter. Run in hole. Pick up drill pipe T/ 416'. Run in hole T/ 2049'. 12/19/2022 RECOMPLETION Continue running in hole T/ 8178'. Establish parameter and wash over tubing stub F/ 8295' T/ 8344'. Took weight. Attempt T/ cut @ 8324' - Unsuccessfully. Work pipe break activation fingers off or cutter - pipe free. Pull out of hole and lay down BHA #2 - 1 cutter blade and fingers missing 1 more cutter blade with broken tip. Make up BHA #3 washpipe with burns shoe. Run in hole T/ 8132'. Establish parameter and wash over tubing T/ 8343''. Burn over tubing saw heavy work @ 8341' T/ 8346'. Burn T/ 8352'. 12/20/2022 RECOMPLETION Burn over tubing F/ 8352' T/ GLM @ 8242'. Circulating bottoms up, Service Rig, TOOH f/8416' to 2420', Slip & Cut 69 feet of drill line, Continue TOOH to BHA #3, P/U BHA #4 TIH to 8,420, Cut off tubing @ 8420, CBU @ 2bpm, TOOH, 12/21/2022 RECOMPLETION Circ. B/U, Pull 2 stands, monitor well (static) pump dry-job, TOOH F/8,201' - T/2,526, Rig Service, Continue TOOH F/2,526 T/surface, breaking down BHA. Recovered 121' of 3.5" TBG with 12' of CT BHA Inside, P/U BHA #5, TIH, Engage fish and pull out, Circ. B/U 12/22/2022 RECOMPLETION Continue Circ and condition mud,TOOH with BHA #5, L/D Fish,Pick up clean out assembly.,TIH to clean out t`he PBR abd scrape the casing, Cir. S/S, TOOH, L/D BHA#5 12/23/2022 RECOMPLETION Pick up BHA #6, TIH and test casing. Pull out and l/d drill pipe. Clean off floor, rig up and run 3 ½ completion 12/24/2022 RECOMPLETION Stab old, stripped seal assembly into old PBR (8523 RKB). Record up/down weights. Mark pipe and space out. Land the tubing hanger. RILDS. Pressure test the packoffs. Pull landing joint. Install BPV. Pressure up on the IA to 1,000 psig for 10 mins to test the BPV in direction of flow. ND BOPE / NU Wellhead and PT same. Pull BPV and Circulate CI, drop Ball & Rod. Set Packer and PT Tubing and IA. Freeze Protect Well w/Diesel. 3H-20 RWO Summary of Operations 12/25/2022 RECOMPLETION Freeze protecct I/A, U-Tube. Clean Pits. RDMO 7ES Workover Rig. 12/30/2022 PUMPING TRACKING ONLY FREEZE PROTECT FLOWLINE WITH 15 BBLS METH JOB COMPLETE 12/31/2022 ACQUIRE DATA SET BAITED CATCHER ON TOP OF BALL & ROD @ 8483' RKB, SWAPPED STATIONS 1 & 3 DVs TO GLVs @ 3051 & 6447' RKB,.PULLED STATION 5 SOV @ 8392 RKB & REPLACED W/ OV, SUCCESSFUL TEST TO 2500 PSI ON TBG. IN PROGRESS. 1/1/2023 ACQUIRE DATA PULLED BAITED CATCHER FROM 8483' RKB (BALL & ROD WAS NOT LATCHED) RAN PUMP BAILER TO REMOVE FILL ON TOP OF BALL & ROD, PULLED BALL & ROD AND RHC FROM 8483' RKB. IN PROGRESS. 1/2/2023 ACQUIRE DATA RAN 1.75 SAMPLE BAILER TAG IN TBG @ 8610' RKB (BAILER CONTAINED THICK MUD). WELL READY FOR FCO. 1/7/2023 ACQUIRE DATA RAN 2-5/8' VENTURI TWO TIMES, TAGGED AT 8581' CTMD ON FIRST RUN, WHILE POOH, WHP SHOT UP FROM 500 TO 1425 PSI. TAGGED 14' HIGHER AT 8567' CTMD ON 2ND RUN, AND WAS ABLE TO PUSH TO 8630' CTMD HARD TAG. MINIMAL RECOVERY IN VENTURI BOTH TIMES, HAD MARKS ON MULE SHOE BOTTOM BOTH TIMES, SOME BENT FINGERS INSIDE FINGER CAGE. RAN 2.79' LIB, TAGGED AT 8628' CTMD WITH -8.5K, 1 JAR HIT. POOH, REACH SURFACE AT MIDNIGHT. 1/8/2023 ACQUIRE DATA INSPECT LIB, MARKS WERE INCONCLUSIVE. RUN 1.75" OD DJN AND STINGERS. NOGO'D ON LINER TOP WITH 2.12" XO, GOT ~10' DEEPER WITH DJN. ATTEMPTED TO INJECT INTO WELL, COIL PRESSURED UP, INDICATING LINER IS PLUGGED OFF BELOW LINER TOP. CIRCULATED 17 BBL DIESEL GEL PILL, RECIP AT LINER TOP, CHASE OOH. BLOW DOWN REEL WITH N2, RDMO FOR REEL SWAP TO 1.5". NEED PLAN FORWARD FOR 3H-20 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB( in TBG) 8,610.0 3H-20 1/2/2023 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Post GLD, pull Ball & Rog, RHC, tag 3H-20 1/2/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: PARTIALLY MILLED P2P PACKER AND CT BHA LEFT IN HOLE. Top of fish 8,394' CTM. 8/19/2020 kolsts NOTE: Orbit Valve control lines/system at wellhead, marked open or closed, OPEN AT 3493. 3/24/2016 lehallf NOTE: Orbit Valve is NOT a safety valve, it does not fail to closed position. 3/24/2016 lehallf Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 36.0 115.0 115.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 35.0 4,091.7 3,044.8 36.00 J-55 BTC PRODUCTION 7 6.28 33.0 9,019.9 6,299.9 26.00 J-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 30.0 Set Depth 8,526.0 Set Depth 5,956.2 String Ma 3 1/2 Tubing Description Tubing Completion Upper Wt (lb/ft) 9.30 Grade L-80 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) 30.0 30.0 0.03 Hanger 7.100 Tubing Hanger, Cameron C-bowl w/ 3.5 EUE 8rd Box x Box Camero n C-Bowl 2.950 451.4 451.4 1.13 Nipple - X 4.496 3.5" x 2.813" X-Nipple SN# 4739293 -8 HES X Nipple 2.813 3,051.5 2,492.1 56.23 Mandrel GAS LIFT 5.800 GLM, 3.5" x 1.5" MMG SLB MMG 2.920 5,125.1 3,688.6 47.92 Mandrel GAS LIFT 5.800 GLM, 3.5" x 1.5" MMG SLB MMG 2.920 6,477.0 4,596.1 48.51 Mandrel GAS LIFT 5.800 GLM, 3.5" x 1.5" MMG SLB MMG 2.920 7,512.2 5,282.4 49.26 Mandrel GAS LIFT 5.850 GLM, 3.5" x 1.5" MMG SLB MMG 2.920 8,392.1 5,864.3 46.85 Mandrel GAS LIFT 5.800 GLM, 3.5" x 1.5" MMG SLB MMG 2.920 8,452.7 5,905.8 46.65 Packer 6.280 3.5" x 7" MFT Feedthru Packer. SN#4117587-02 HES MFT 2.897 8,482.7 5,926.4 46.55 Nipple - X 4.498 3.5" x 2.813" X-Nipple SN# 4739293 -7 HES X Nipple 2.813 8,493.7 5,934.0 46.51 Perforated Joint 3.500 3.5" 9.3# L-80 8rd EUE PERF Pup (IPC) 2.992 8,503.7 5,940.9 46.47 NO-GO 4.180 Baker 80-40 locator sub Baker 2.992 8,504.7 5,941.6 46.47 Seal Assembly 3.980 Baker 80-40 Seal Assembly w/ 7ft space out Baker Baker Seal Assy 2.992 Top (ftKB) 8,523.2 Set Depth 8,728.0 Set Depth 6,096.3 String Ma 3 1/2 Tubing Description Tubing Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd 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) 8,523.2 5,954.3 46.40 PBR 5.010 Baker 80-40 PBR Baker 80-40 PBR 4.000 8,546.3 5,970.2 46.31 PACKER 5.930 Baker 7" 26# FHL packer Baker FHL packer 2.890 8,631.3 6,029.1 46.05 NIPPLE 3.500 3.5 X 2.813 X nipple HES X nipple 2.813 8,643.2 6,037.4 46.03 XO Enlarging 4.500 3.5 EUE 8rd Box X 4.5" STC pin ported sub Baker Ported sub 2.992 8,645.0 6,038.6 46.03 LINER 4.500 4.5 X 12.6# STC W / 6" OD wear soxs Wear sox 3.958 8,686.7 6,067.6 45.97 LINER 4.500 4.5 X 12.6# STC W / 6" OD wear soxs Mule shoe Wear sox 3.958 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 8,667.3 6,054.1 46.00 CTD LINER 3H-20 L1-05 LINER 5/13/2016 1.900 8,676.0 6,060.2 45.99 WHIPSTOCK Baker GII Dealta Whipstock 5/3/2016 8,703.0 6,079.0 45.95 WHIPSTOCK Baker GII Dealta Whipstock 4/6/2016 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,051.5 2,492.1 56.23 1 PROD GLV RK 1 1/2 1,233.0 12/31/2022 Schlumb erger MMG RK Latch,41 30 0.188 5,125.1 3,688.6 47.92 2 PROD DMY RK 1 1/2 12/24/2022 Schlumb erger MMG RK Latch,41 30 0.000 6,477.0 4,596.1 48.51 3 PROD GLV RK 1 1/2 1,223.0 12/31/2022 Schlumb erger MMG RK Latch,41 30 0.188 7,512.2 5,282.4 49.26 4 PROD DMY RK 1 1/2 12/24/2022 Schlumb erger MMG RK Latch,41 30 0.000 3H-20, 1/13/2023 12:45:46 PM Vertical schematic (actual) CTD LINER; 8,667.3 PRODUCTION; 33.0-9,019.9 IPERF; 8,760.0-8,780.0 APERF; 8,740.0-8,760.0 FRAC; 8,681.0 APERF; 8,706.0-8,726.0 RPERF; 8,710.0-8,720.0 WHIPSTOCK ; 8,703.0 L1-03 Liner; 8,694.6-9,102.0 SLOTS; 8,695.0-9,091.0 RPERF; 8,681.0-8,691.0 APERF; 8,681.0-8,691.0 WHIPSTOCK ; 8,676.0 L1-05 Liner; 8,667.3-11,192.0 SLOTS; 8,670.0-11,191.0 NIPPLE; 8,631.3 PACKER; 8,546.3 Packer; 8,452.7 Mandrel GAS LIFT; 8,392.1 Mandrel GAS LIFT; 7,512.2 Mandrel GAS LIFT; 6,477.0 Mandrel GAS LIFT; 5,125.1 SURFACE; 35.0-4,091.7 Mandrel GAS LIFT; 3,051.5 CONDUCTOR; 36.0-115.0 Hanger; 30.0 KUP PROD KB-Grd (ft) 42.01 RR Date 1/25/1988 Other Elev 3H-20 ... TD Act Btm (ftKB) 9,050.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009300 Wellbore Status PROD Max Angle & MD Incl (°) 58.84 MD (ftKB) 4,000.00 WELLNAME WELLBORE3H-20 Annotation Last WO: End Date 12/25/2022 H2S (ppm) 110 Date 5/8/2019 Comment SSSV: NONE 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) 8,392.1 5,864.3 46.85 5 PROD OV RK 1 1/2 0.0 12/31/2022 Schlumb erger MMG REK Latch,41 30 0.188 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,681.0 8,691.0 6,063.7 6,070.6 A-3, 3H-20 12/5/2006 6.0 RPERF 2' HSD, 60 Deg ph, 2006 PF Charges 8,681.0 8,691.0 6,063.7 6,070.6 A-2, 3H-20 7/15/1988 12.0 APERF 60 deg. ph; SOS 2 1/8" EnerJet 8,706.0 8,726.0 6,081.0 6,095.0 A-2, 3H-20 7/15/1988 8.0 APERF 60 deg. ph; SOS 2 1/8" EnerJet 8,710.0 8,720.0 6,083.8 6,090.8 A-2, 3H-20 12/5/2006 6.0 RPERF 2' HSD, 60 Deg ph, 2006 PF Charges 8,740.0 8,760.0 6,104.7 6,118.6 A-1, 3H-20 11/13/1999 4.0 APERF 2 1/8" Energjet, 180 deg phasing +/- 90 deg 8,760.0 8,780.0 6,118.6 6,132.6 A-1, 3H-20 5/2/1988 4.0 IPERF 120 deg. phasing; 4 1/2" Csg Gun Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 8,681.0 8,780.0 1 FRAC 1/13/2002 0.0 0.00 0.00 3H-20, 1/13/2023 12:45:48 PM Vertical schematic (actual) CTD LINER; 8,667.3 PRODUCTION; 33.0-9,019.9 IPERF; 8,760.0-8,780.0 APERF; 8,740.0-8,760.0 FRAC; 8,681.0 APERF; 8,706.0-8,726.0 RPERF; 8,710.0-8,720.0 WHIPSTOCK ; 8,703.0 L1-03 Liner; 8,694.6-9,102.0 SLOTS; 8,695.0-9,091.0 RPERF; 8,681.0-8,691.0 APERF; 8,681.0-8,691.0 WHIPSTOCK ; 8,676.0 L1-05 Liner; 8,667.3-11,192.0 SLOTS; 8,670.0-11,191.0 NIPPLE; 8,631.3 PACKER; 8,546.3 Packer; 8,452.7 Mandrel GAS LIFT; 8,392.1 Mandrel GAS LIFT; 7,512.2 Mandrel GAS LIFT; 6,477.0 Mandrel GAS LIFT; 5,125.1 SURFACE; 35.0-4,091.7 Mandrel GAS LIFT; 3,051.5 CONDUCTOR; 36.0-115.0 Hanger; 30.0 KUP PROD 3H-20 ... WELLNAME WELLBORE3H-20 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 3H-20L1 lehallf Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: ADD LATERALS; GLV C/O 3H-20L1 5/23/2016 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: lehallf Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1 Liner 2 3/8 1.99 9,264.7 11,354.0 6,073.2 4.60 L-80 ST-L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,264.7 6,087.2 91.82 BILLET 2.630 Aluminum OH Anchored Billet (milled down from 11.39') Baker OH Anchored Billet 1.900 9,299.7 6,086.6 89.60 BILLET 2.630 Aluminum Liner Top Billet (Milled off on the L1-01PB1) Baker Billet 1.900 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,265.0 11,354.0 6,087.1 6,073.2 A-1, 3H-20 4/11/2016 SLOTS Alternating solid/slotted pipe - .0125" x 2.5" @ 4 circumferential adjacent rows 3H-20L1, 1/13/2023 12:45:49 PM Vertical schematic (actual) L1 Liner; 9,264.7-11,354.0 SLOTS; 9,265.0-11,354.0 L1-01 Liner; 9,024.8-10,049.0 SLOTS; 9,025.0-10,048.0 L1-06 Liner; 8,801.2-11,575.0 SLOTS; 8,810.0-11,574.0 PRODUCTION; 33.0-9,019.9 WHIPSTOCK ; 8,703.0 L1-03 Liner; 8,694.6-9,102.0 SLOTS; 8,695.0-9,091.0 FRAC; 8,681.0 CTD LINER; 8,667.3 APERF; 8,681.0-8,691.0 RPERF; 8,681.0-8,691.0 WHIPSTOCK ; 8,676.0 L1-05 Liner; 8,667.3-11,192.0 SLOTS; 8,670.0-11,191.0 NIPPLE; 8,631.3 PACKER; 8,546.3 Packer; 8,452.7 Mandrel GAS LIFT; 8,392.1 Mandrel GAS LIFT; 7,512.2 Mandrel GAS LIFT; 6,477.0 Mandrel GAS LIFT; 5,125.1 SURFACE; 35.0-4,091.7 Mandrel GAS LIFT; 3,051.5 CONDUCTOR; 36.0-115.0 Hanger; 30.0 KUP PROD KB-Grd (ft) 42.01 RR Date 1/25/1988 Other Elev 3H-20L1 ... TD Act Btm (ftKB) 11,354.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009360 Wellbore Status PROD Max Angle & MD Incl (°) 101.30 MD (ftKB) 8,900.20 WELLNAME WELLBORE3H-20 Annotation Last WO: End Date 12/25/2022 H2S (ppm) 110 Date 5/8/2019 Comment SSSV: NONE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 3H-20L1-01 lehallf Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: ADD LATERALS; GLV C/O 3H-20L1- 01 5/23/2016 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: TD is 10,353, BOL is 10,049 5/18/2016 lehallf Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1-01 Liner 2 3/8 1.99 9,024.8 10,049.0 6,081.1 4.60 L-80 ST-L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,024.8 6,097.2 95.65 BILLET 2.630 OH Anchored Aluminum Billet Baker OH Anchored billet Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,025.0 10,048.0 6,097.2 6,081.0 A-1, 3H-20 4/17/2016 SLOTS Alternating solid/slotted pipe - .0125" x 2.5" @ 4 circumferential adjacent rows 3H-20L1-01, 1/13/2023 12:45:51 PM Vertical schematic (actual) L1-01 Liner; 9,024.8-10,049.0 SLOTS; 9,025.0-10,048.0 L1 Liner; 9,264.7-11,354.0 L1-06 Liner; 8,801.2-11,575.0 SLOTS; 8,810.0-11,574.0 PRODUCTION; 33.0-9,019.9 WHIPSTOCK ; 8,703.0 L1-03 Liner; 8,694.6-9,102.0 SLOTS; 8,695.0-9,091.0 FRAC; 8,681.0 CTD LINER; 8,667.3 RPERF; 8,681.0-8,691.0 APERF; 8,681.0-8,691.0 WHIPSTOCK ; 8,676.0 L1-05 Liner; 8,667.3-11,192.0 SLOTS; 8,670.0-11,191.0 NIPPLE; 8,631.3 PACKER; 8,546.3 Packer; 8,452.7 Mandrel GAS LIFT; 8,392.1 Mandrel GAS LIFT; 7,512.2 Mandrel GAS LIFT; 6,477.0 Mandrel GAS LIFT; 5,125.1 SURFACE; 35.0-4,091.7 Mandrel GAS LIFT; 3,051.5 CONDUCTOR; 36.0-115.0 Hanger; 30.0 KUP PROD KB-Grd (ft) 42.01 RR Date 1/25/1988 Other Elev 3H-20L1-01 ... TD Act Btm (ftKB) 10,353.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009361 Wellbore Status PROD Max Angle & MD Incl (°) 101.30 MD (ftKB) 8,900.20 WELLNAME WELLBORE3H-20 Annotation Last WO: End Date 12/25/2022 H2S (ppm) 110 Date 5/8/2019 Comment SSSV: NONE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 3H-20L1-02 lehallf Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: ADD LATERALS; GLV C/O 3H-20L1- 02 5/23/2016 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: lehallf Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1-02 Liner 2 3/8 1.99 9,800.2 11,700.0 6,092.8 4.60 L-80 ST-L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,800.2 6,121.9 91.16 BILLET 2.630 Aluminum Billet Baker OH Anchored billet Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,809.0 11,700.0 6,121.8 6,092.8 A-1, 3H-20 4/23/2016 SLOTS Alternating solid/slotted pipe - .0125" x 2.5" @ 4 circumferential adjacent rows 3H-20L1-02, 1/13/2023 12:45:53 PM Vertical schematic (actual) L1-02 Liner; 9,800.2-11,700.0 SLOTS; 9,809.0-11,700.0 L1-06 Liner; 8,801.2-11,575.0 SLOTS; 8,810.0-11,574.0 PRODUCTION; 33.0-9,019.9 WHIPSTOCK ; 8,703.0 L1-03 Liner; 8,694.6-9,102.0 SLOTS; 8,695.0-9,091.0 FRAC; 8,681.0 CTD LINER; 8,667.3 APERF; 8,681.0-8,691.0 RPERF; 8,681.0-8,691.0 WHIPSTOCK ; 8,676.0 L1-05 Liner; 8,667.3-11,192.0 SLOTS; 8,670.0-11,191.0 NIPPLE; 8,631.3 PACKER; 8,546.3 Packer; 8,452.7 Mandrel GAS LIFT; 8,392.1 Mandrel GAS LIFT; 7,512.2 Mandrel GAS LIFT; 6,477.0 Mandrel GAS LIFT; 5,125.1 SURFACE; 35.0-4,091.7 Mandrel GAS LIFT; 3,051.5 CONDUCTOR; 36.0-115.0 Hanger; 30.0 KUP PROD KB-Grd (ft) 42.01 RR Date 1/25/1988 Other Elev 3H-20L1-02 ... TD Act Btm (ftKB) 11,700.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009362 Wellbore Status PROD Max Angle & MD Incl (°) 101.30 MD (ftKB) 8,900.20 WELLNAME WELLBORE3H-20 Annotation Last WO: End Date 12/25/2022 H2S (ppm) 110 Date 5/8/2019 Comment SSSV: NONE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 3H-20L1-03 lehallf Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: ADD LATERALS; GLV C/O 3H-20L1- 03 5/23/2016 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: TD IS 10,065, BOL IS 9102 5/14/2016 lehallf Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1-03 Liner 2 3/8 4.60 8,694.6 9,102.0 ST-L 2.375 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,694.6 DEPLOY 2.625 Shorty deployment sleeve 1.950 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,695.0 9,091.0 A-1, 3H-20 5/2/2016 SLOTS Alternating solid/slotted pipe - .0125" x 2.5" @ 4 circumferential adjacent rows 3H-20L1-03, 1/13/2023 12:45:54 PM Vertical schematic (actual) L1-03 Liner; 8,694.6-9,102.0 SLOTS; 8,695.0-9,091.0 PRODUCTION; 33.0-9,019.9 FRAC; 8,681.0 APERF; 8,681.0-8,691.0 RPERF; 8,681.0-8,691.0 CTD LINER; 8,667.3 WHIPSTOCK ; 8,676.0 L1-05 Liner; 8,667.3-11,192.0 SLOTS; 8,670.0-11,191.0 NIPPLE; 8,631.3 PACKER; 8,546.3 Packer; 8,452.7 Mandrel GAS LIFT; 8,392.1 Mandrel GAS LIFT; 7,512.2 Mandrel GAS LIFT; 6,477.0 Mandrel GAS LIFT; 5,125.1 SURFACE; 35.0-4,091.7 Mandrel GAS LIFT; 3,051.5 CONDUCTOR; 36.0-115.0 Hanger; 30.0 KUP PROD KB-Grd (ft) 42.01 RR Date 1/25/1988 Other Elev 3H-20L1-03 ... TD Act Btm (ftKB) 10,065.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009363 Wellbore Status PROD Max Angle & MD Incl (°) 100.84 MD (ftKB) 8,890.45 WELLNAME WELLBORE3H-20 Annotation Last WO: End Date 12/25/2022 H2S (ppm) 110 Date 5/8/2019 Comment SSSV: NONE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 3H-20L1-04 lehallf Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: ADD LATERALS; GLV C/O 3H-20L1- 04 5/17/2016 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: lehallf Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1-04 Liner 2 3/8 1.99 10,154.7 11,100.0 6,156.4 4.60 L-80 ST-L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 10,154.7 6,165.1 93.94 BILLET 2.630 Aluminum Liner Top Billet Baker Aluminum LTB 1.900 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,162.0 11,088.0 6,164.6 6,157.1 A-1, 3H-20 5/11/2016 SLOTS Alternating solid/slotted pipe - .0125" x 2.5" @ 4 circumferential adjacent rows 3H-20L1-04, 1/13/2023 12:45:56 PM Vertical schematic (actual) L1-04 Liner; 10,154.7-11,100.0 SLOTS; 10,162.0-11,088.0 L1-05 Liner; 8,667.3-11,192.0 SLOTS; 8,670.0-11,191.0 PRODUCTION; 33.0-9,019.9 WHIPSTOCK ; 8,676.0 CTD LINER; 8,667.3 NIPPLE; 8,631.3 PACKER; 8,546.3 Packer; 8,452.7 Mandrel GAS LIFT; 8,392.1 Mandrel GAS LIFT; 7,512.2 Mandrel GAS LIFT; 6,477.0 Mandrel GAS LIFT; 5,125.1 SURFACE; 35.0-4,091.7 Mandrel GAS LIFT; 3,051.5 CONDUCTOR; 36.0-115.0 Hanger; 30.0 KUP PROD KB-Grd (ft) 42.01 RR Date 1/25/1988 Other Elev 3H-20L1-04 ... TD Act Btm (ftKB) 11,100.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009364 Wellbore Status PROD Max Angle & MD Incl (°) 98.13 MD (ftKB) 8,911.48 WELLNAME WELLBORE3H-20 Annotation Last WO: End Date 12/25/2022 H2S (ppm) 110 Date 5/8/2019 Comment SSSV: NONE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 3H-20L1-05 lehallf Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: ADD LATERALS; GLV C/O 3H-20L1- 05 5/23/2016 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: lehallf Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1-05 Liner 2 3/8 1.99 8,667.3 11,192.0 4.60 L-80 ST-L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,667.3 6,054.2 46.00 DEPLOY 2.630 Shorty Deployment Sleeve Baker Aluminum LTB 1.900 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,670.0 11,191.0 6,056.1 6,215.2 A-1, 3H-20 5/13/2016 SLOTS Alternating solid/slotted pipe - .0125" x 2.5" @ 4 circumferential adjacent rows 3H-20L1-05, 1/13/2023 12:45:57 PM Vertical schematic (actual) L1-05 Liner; 8,667.3-11,192.0 SLOTS; 8,670.0-11,191.0 PRODUCTION; 33.0-9,019.9 WHIPSTOCK ; 8,676.0 CTD LINER; 8,667.3 NIPPLE; 8,631.3 PACKER; 8,546.3 Packer; 8,452.7 Mandrel GAS LIFT; 8,392.1 Mandrel GAS LIFT; 7,512.2 Mandrel GAS LIFT; 6,477.0 Mandrel GAS LIFT; 5,125.1 SURFACE; 35.0-4,091.7 Mandrel GAS LIFT; 3,051.5 CONDUCTOR; 36.0-115.0 Hanger; 30.0 KUP PROD KB-Grd (ft) 42.01 RR Date 1/25/1988 Other Elev 3H-20L1-05 ... TD Act Btm (ftKB) 11,192.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009365 Wellbore Status PROD Max Angle & MD Incl (°) 102.69 MD (ftKB) 10,245.90 WELLNAME WELLBORE3H-20 Annotation Last WO: End Date 12/25/2022 H2S (ppm) 110 Date 5/8/2019 Comment SSSV: NONE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 3H-20L1-06 lehallf Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: ADD LATERALS; GLV C/O 3H-20L1- 06 5/17/2016 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: lehallf Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1-06 Liner 2 3/8 1.99 8,801.2 11,575.0 6,067.2 4.60 L-80 ST-L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,801.2 6,125.2 79.85 BILLET 2.630 Aluminum Billet Baker OH Anchored billet Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,810.0 11,574.0 6,126.5 6,067.2 A-1, 3H-20 4/26/2016 SLOTS Alternating solid/slotted pipe - .0125" x 2.5" @ 4 circumferential adjacent rows 3H-20L1-06, 1/13/2023 12:45:59 PM Vertical schematic (actual) L1-06 Liner; 8,801.2-11,575.0 SLOTS; 8,810.0-11,574.0 L1-02 Liner; 9,800.2-11,700.0 PRODUCTION; 33.0-9,019.9 WHIPSTOCK ; 8,703.0 L1-03 Liner; 8,694.6-9,102.0 SLOTS; 8,695.0-9,091.0 FRAC; 8,681.0 CTD LINER; 8,667.3 APERF; 8,681.0-8,691.0 RPERF; 8,681.0-8,691.0 WHIPSTOCK ; 8,676.0 L1-05 Liner; 8,667.3-11,192.0 SLOTS; 8,670.0-11,191.0 NIPPLE; 8,631.3 PACKER; 8,546.3 Packer; 8,452.7 Mandrel GAS LIFT; 8,392.1 Mandrel GAS LIFT; 7,512.2 Mandrel GAS LIFT; 6,477.0 Mandrel GAS LIFT; 5,125.1 SURFACE; 35.0-4,091.7 Mandrel GAS LIFT; 3,051.5 CONDUCTOR; 36.0-115.0 Hanger; 30.0 KUP PROD KB-Grd (ft) 42.01 RR Date 1/25/1988 Other Elev 3H-20L1-06 ... TD Act Btm (ftKB) 11,575.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009366 Wellbore Status PROD Max Angle & MD Incl (°) 101.30 MD (ftKB) 8,900.20 WELLNAME WELLBORE3H-20 Annotation Last WO: End Date 12/25/2022 H2S (ppm) 110 Date 5/8/2019 Comment SSSV: NONE STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:7ES DATE:12/15/22 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #1871340 Sundry #322-669 Operation:Drilling:Workover:X Explor.: Test:Initial:X Weekly:Bi-Weekly:Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:3251 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 2 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13 5/8" T90 P Pit Level Indicators P P #1 Rams 1 2 7/8' x 5"P Flow Indicator P P #2 Rams 1 Blinds P Meth Gas Detector P P #3 Rams 1 3 1/2" x 5 1/2"P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8" Gate P Time/Pressure Test Result HCR Valves 2 3 1/8" Gate P System Pressure (psi)3000 P Kill Line Valves 2 3 1/8" & 2"P Pressure After Closure (psi)1500 P Check Valve 0 NA 200 psi Attained (sec)21 P BOP Misc 2 2 1/16" Gate P Full Pressure Attained (sec)109 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):5@1945 P No. Valves 16 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 30 P #1 Rams 6 P Coiled Tubing Only:#2 Rams 6 P Inside Reel valves 0 NA #3 Rams 6 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:5.5 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 12/14/22 7:37 Waived By Test Start Date/Time:12/15/2022 11:30 (date)(time)Witness Test Finish Date/Time:12/15/2022 17:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Bob Noble Nabors Tested with 3 1/2" Test joint. Kelly Cozby / Jim Marmon ConocoPhillips Dale Rowell / Kevin Barr KRU 3H-20 Test Pressure (psi): kelly.cozby@nabors.com nskrwo.cm@conocophillips.com Form 10-424 (Revised 08/2022)2022-1215_BOP_Nabors7ES_KRU_3H-20          J. Regg; 4/27/2023 Annular must close within 30 seconds of actuation; jbr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y Anne Prysunka at 8:05 am, Nov 22, 2022 '65'/% ; %23 WHVW WR SVL $QQXODU WHVW WR SVL EMP ; %-0 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2022.11.23 10:25:14 -09'00' RBDMS JSB 112322 3H-20 RWO Procedure Kuparuk Producer PTD #187-134 &XUUHQW2SHUDWLRQV7KLVZHOOLVFXUUHQWO\VKXWLQDQGDZDLWLQJD5:2 6FRSHRI:RUN3XOOWKHH[LVWLQJ´FRPSOHWLRQDQGLQVWDOODQHZ´FRPSOHWLRQ *HQHUDO:HOOLQIR :HOO7\SH 3URGXFHU 0363 SVLXVLQJSVLIWJUDGLHQW 6WDWLF%+3 SVL ¶79' SSJ(0: PHDVXUHGRQ :HOOKHDGW\SHSUHVVXUHUDWLQJ 0F(YR\*HQ0SVLWRSIODQJH0SVLERWIODQJH %23FRQILJXUDWLRQ $QQXODU3LSH5DPV%OLQG5DPV3LSH5DPV 0,7UHVXOWV &0,77[,$3$66(' 0,72$3$66('± ,&327 333273$66('± 7%*327 333273$66('±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´WXELQJIURP3%5DW¶0' 5,+ZLWKWHVWSDFNHU7HVW´FDVLQJWRFRQILUPLQWHJULW\%HJLQWR322+ :LWKSOHQW\RIVWULQJZHLJKWVHWVWRUPSDFNHULQ´DQGWHVWWRFRQILUPDVEDUULHU 1'%23(DQG7XELQJ6SRROWRFKDQJHWRQHZ&ERZO7XELQJVSRRO 18QHZWXELQJVSRRORQROGFDVLQJVSRRO7HVWFDVLQJWRQHZWXELQJVSRROIODQJHEUHDNWRSVLJ)ODQJH OLPLWDWLRQRISVLJRQROGFDVLQJKHDG 18%23(WRQHZWXELQJIODQJHDQGWHVWWR%23(SUHVVXUH 5HWULHYHVWRUPSDFNHUDQGILQLVK322+ 08ò´FRPSOHWLRQZLWK*/0VDQG5,+ZLWKFRPSOHWLRQ 2QFHRQGHSWKVSDFHRXWa¶DVQHHGHG5HHQJDJHPXOHVKRHLQWR3%5ZRVHDOV/DQGRXW5,/'67HVW 3DFNRIIV ,QVWDOO%397HVW%39 1'%23(18WUHH7HVWWUHH3XOO%39 &LUFXODWHIOXLGVDVQHFHVVDU\IRUFRUURVLRQLQKLELWLRQ6HWSDFNHUSHUHTXLSPHQWYHQGRUUHSUHVHQWDWLYH 3UHVVXUHWHVWWXELQJWRSVLIRUPLQXWHVRQFKDUW 3UHVVXUHWHVWLQQHUDQQXOXVWRSVLIRUPLQXWHVRQFKDUW &RQILUPSUHVVXUHWHVWVWKHQVKHDURXW629ZLWKSUHVVXUHGLIIHUHQWLDO )UHH]HSURWHFWZHOODVQHFHVVDU\ 5'02 3RVW5LJ:RUN 5HVHWZHOOKRXVHVDQGIORZOLQHVRIDGMDFHQWZHOOV 3H-20 RWO Procedure Kuparuk Producer PTD #187-134 3XOO%39 586OLFNOLQH3XOO629EDOO URGDQGUXQ*/' +DQGRIIWRRSHUDWLRQVWRSXWEDFNRQSURGXFWLRQ +3URSRVHG5:26FKHPDWLF-VKRH# 0'-VKRH# 0'+VKRH# 0'$VDQGSHUIV 72:6/(8(UG7XELQJWRVXUIDFH&DPFRJDVOLIWPDQGUHOV#7%'[3DFNHUa 5.%;QLSSOH7%'PLQ,'1RQVHDOLQJPXOHVKRH%DNHU3%5# 0'%DNHU)+/SDFNHU# 0';QLSSOH 0'PLQ,'%LJ7DLO3LSH 0'Modified by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ƌǇĂŶĂŶĚdŽtŚŽŵŝƚŽŶĐĞƌŶƐ͕ ,ŽƉĞƚŚŝƐĨŝŶĚƐǇŽƵǁĞůů͘ /ŚĂĚϯŵĂŝŶƵƉĚĂƚĞƐƚŽŵĂŬĞĨŽƌƚŚĞĂƉƉƌŽǀĞĚĂƚƚĂĐŚĞĚƐƵŶĚƌǇĨŽƌϯ,ͲϮϬ͘ WĞƌŽƵƌĐŽŶǀĞƌƐĂƚŝŽŶŽŶƚŚĞŽƚƚŽŵŚŽůĞƉƌĞƐƐƵƌĞŽĨϯ,ͲϮϬZtKĐŽŵŝŶŐƵƉ͕ǁĞĚŝĚũƵƐƚŐĞƚ ĂŶƵƉĚĂƚĞĚ^,WůĂƐƚǁĞĞŬƚŚĂƚƐŚŽǁƐĂĚĞĐƌĞĂƐĞĚďŽƚƚŽŵŚŽůĞƉƌĞƐƐƵƌĞ͘ /ƚǁĂƐŵĞĂƐƵƌĞĚϯϴϯϰƉƐŝŐĂƚϱϴϯϲ͛dsŽŶϭϭͬϭϳͬϮϬϮϮ͘ DtсϯϴϯϰƉƐŝŐͬϬ͘ϬϱϮͬϱϴϯϲ͛dsсϭϮ͘ϳƉƉŐDt DW^WсϯϴϯϰƉƐŝŐʹ;ϱϴϯϲ͛dsǆϬ͘ϭƉƐŝͬĨƚͿсϯϮϱϭƉƐŝŐ tŝƚŚƚŚŝƐŶĞǁƉƌĞƐƐƵƌĞĚĂƚĂͲƉŽŝŶƚ͕/ƵƉĚĂƚĞĚŽƵƚZtKƐƵŵŵĂƌǇƚŽĂĐĐŽƵŶƚĨŽƌůŽǁĞƌ ƚĞƐƚƉƌĞƐƐƵƌĞƐ͘ ĚĚŝƚŝŽŶĂůůǇ͕ĚƵĞƚŽƚŚĞĂŐĞŽĨƚŚĞǁĞůůŚĞĂĚ͕/͛ǀĞĚŝƐĐŽǀĞƌĞĚǁĞŶĞĞĚƚŽƐǁĂƉƚŚĞƚƵďŝŶŐƐƉŽŽů ƚŽĂŶĞǁĞƌŽŶĞƚŚĂƚǁĞŚĂǀĞƉĂƌƚƐĨŽƌ͘dŚŝƐƌĞƋƵŝƌĞƐƵƐďƌĞĂŬŝŶŐƚŚĞŽůĚĞƌϯϬϬϬƉƐŝŐƌĂƚĞĚ ĨůĂŶŐĞĂŶĚƐƚĂĐŬŝŶŐĂŶĞǁƐƉŽŽůŽŶŝƚ͘ tĞ͛ůůŽŶůǇďĞĂďůĞƚŽƚĞƐƚƚŚĞKůĚĐĂƐŝŶŐƐƉŽŽůƚŽƉͲĨůĂŶŐĞďƌĞĂŬƚŽϯϬϬϬƉƐŝŐĚƵĞƚŽ ĨůĂŶŐĞƐƉĞĐƐ͘ tĞƐŚŽƵůĚďĞĂďůĞƚŽƐƚŝůůƚĞƐƚƚŚĞŶĞǁƚƵďŝŶŐƐƉŽŽůƚŽƉͲĨůĂŶŐĞƚŽKWƉƌĞƐƐƵƌĞŽĨ ϯϱϬϬƉƐŝŐ͘ >ĂƐƚůǇ͕ĚƵĞƚŽƐĞĂůĂǀĂŝůĂďŝůŝƚǇ͕/͛ŵƉůĂŶŶŝŶŐƚŽƐƚĂĐŬĂƉĂĐŬĞƌǁŝƚŚƐƚƌŝƉƉĞĚƐĞĂůƐŽƌũƵƐƚĂŶŽŶͲ ƐĞĂůŝŶŐŵƵůĞƐŚŽĞŝŶƚŽƚŚĞŽůĚWZĂƚƚŚŝƐƉŽŝŶƚ͕ǁŚŝĐŚĐŚĂŶŐĞƐŵǇŽƌĚĞƌŽĨŽƉĞƌĂƚŝŽŶƐĨŽƌ ĐŝƌĐƵůĂƚŝŶŐŝŶŽƌƌŽƐŝŽŶ/ŶŚŝďŝƚĞĚďƌŝŶĞŝĨǁĞ͛ƌĞŽŶŵƵĚĂƐ<t&͘ ůůŽĨĂďŽǀĞŝƐƌĞĨůĞĐƚĞĚŝŶĂƚƚĂĐŚĞĚŚĂŶŐĞKĨ^ƵŶĚƌǇƌĞƋƵĞƐƚĨŽƌŵ͖ǁŝƚŚĐŚĂŶŐĞƐƉƌŝŵĂƌŝůǇŝŶZŽĨ ƚŚĞƐƵŵŵĂƌǇƚŽŚŝŐŚůŝŐŚƚƚŚĞĚŝĨĨĞƌĞŶĐĞƐ͘ ƉŽůŽŐŝĞƐĨŽƌƚŚĞĐŚĂŶŐĞ͕ďƵƚ/ƚŚŝŶŬƚŚĂƚŐĞƚƐŝƚĨƵůůǇƵƉƚŽƐƉĞĞĚ͘ dŚĂŶŬƐĨŽƌǇŽƵƌƚŝŵĞ͘WůĞĂƐĞƌĞĂĐŚŽƵƚƚŽŵĞŝĨǇŽƵŚĂǀĞĂŶǇŵŽƌĞƋƵĞƐƚŝŽŶƐ͘ ƵƐƚǇtĂƌĚͮĚƵƐƚǇǁ ^ĞŶŝŽƌtĞůůƐŶŐŝŶĞĞƌ KĨĨŝĐĞ͗ϵϬϳͲϮϲϱͲϲϱϯϭ Ğůů͗ϱϬϯͲϰϳϲͲϮϱϭϵ /DVW7DJ $QQRWDWLRQ 'HSWKIW.% (QG'DWH :HOOERUH /DVW0RG%\ /DVW7DJ6/0 + IDPDM /DVW5HY5HDVRQ $QQRWDWLRQ (QG'DWH :HOOERUH /DVW0RG%\ 5HY5HDVRQ&7%+$6WXFNLQKROH + NROVWV &DVLQJ6WULQJV &DVLQJ'HVFULSWLRQ &21'8&725 2'LQ ,'LQ 7RSIW.% 6HW'HSWKIW.% 6HW'HSWK79'« :W/HQO« *UDGH + 7RS7KUHDG :(/'(' &DVLQJ'HVFULSWLRQ 685)$&( 2'LQ ,'LQ 7RSIW.% 6HW'HSWKIW.% 6HW'HSWK79'« :W/HQO« *UDGH - 7RS7KUHDG %7& &DVLQJ'HVFULSWLRQ 352'8&7,21 2'LQ ,'LQ 7RSIW.% 6HW'HSWKIW.% 6HW'HSWK79'« :W/HQO« *UDGH - 7RS7KUHDG %7& 7XELQJ6WULQJV 7XELQJ'HVFULSWLRQ UG833(5 &203/(7,21 6WULQJ0D« ,'LQ 7RSIW.% 6HW'HSWKIW« 6HW'HSWK79'« :WOEIW *UDGH / 7RS&RQQHFWLRQ (8(UG &RPSOHWLRQ'HWDLOV 7RSIW.% 7RS79' IW.% 7RS,QFO ,WHP'HV &RP 1RPLQDO ,'LQ +$1*(5 (8(UG;&DPHURQ0F(YR\*HQ+DQJHU %$.(525%,7 9$/9( %DNHU;2UELWYDOYH:GULIW /2&$725 %DNHUORFDWRUVXE 6($/$66< %DNHU6HDODVVHPEO\:IWVSDFHRXW 7XELQJ'HVFULSWLRQ /2:(5 &203/(7,21 6WULQJ0D« ,'LQ 7RSIW.% 6HW'HSWKIW« 6HW'HSWK79'«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y Anne Prysunka at 1:35 pm, Oct 27, 2022 Ronald Phillips Digitally signed by Ronald Phillips Date: 2022.10.24 13:37:51 -08'00' ; ; '/% 3UHVVXUH WHVW WXELQJ WR SVL ; %-0 '65 %23 WHVW WR SVL $QQXODU WHVW WR SVL *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2022.11.18 14:48:52 -09'00' RBDMS JSB 112322 !!"##"$ %&'%#(% '%#(%"')%# $#*%"$ !!"##"$ +#,-*$.." $-%/'%#(% 0% !!"##"$1 $-"''"2# %&&+''#$/"$ 30"''"$/%$4+''# $-"''"2#'%#(%3$-5#.!"#%$22'"%"$&.$4522*%'6(*74. 890:;, < +'' 6%#4"''4"$;;505$ %$4!2'454"%#%24."$-.2%.(#%$4#9- 6''6%#6(4*"$ 5%#,%# 04"''4 !'%%'#"$-.2%.(#%$4#&-"# 6''"$ +'' 6%#3$,= =&%+4#*%'."$/'%(#%$4%($&"#-"$/#2%#.( "$ 2%- % ; > 3&5.-%*%$5?.#"$#?."%$5&.-"$&!%"$2'%#$%!% 9-22#46(*#2& 6"''"$'.42.''"$/- =@!2'"$%$4"$#%''"$/%$6 =@ !2'"$ Ronald Phillips Digitally signed by Ronald Phillips Date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y Samantha Carlisle at 9:42 am, Jun 17, 2021 321-301 Ron Phillips Digitally signed by Ron Phillips Date: 2021.06.17 08:26:09 -08'00' DSR-6/17/21VTL 7/22/21 DLB 06/17/2021 -00 DLB X 10-404XX BOP test to 4000 psig Annular preventer test to 2500 psig JLC 7/22/2021 dts 7/22/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.22 12:26:35 -08'00' RBDMS HEW 7/22/2021 If you have any questions or require any further information, please contact me at 265-6312. P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 14, 2021 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Producer 3H-20 (PTD# 187-134). Well 3H-20 was drilled in 1988 by Doyon 14 and completed by Nordic 1 as a producer into the Kuparuk A-sands. The well was worked over in 2016 by Nabors 7ES. Nabors CDR2 drilled 6 more laterals in the Kuparuk A-sands.for this well in 2016. Well 3H-20 was SI on 7/23/2019 for a RWO do to several tubing leaks and a broken fishing spear stuck in patch at 8392'. The proposed workover scope for 3H-20 will include pulling the 3-1/2" completion and installing a new 3-1/2" completion. Ron Phillips Senior Wells Engineer CPAI Drilling and Wells Ron Phillips Digitally signed by Ron Phillips Date: 2021.06.17 08:26:46 -08'00' The proposed workover scope for 3H-20 will include pulling the 3-1/2" completion and installing a new 3-1/2" completion. 3H-20 RWO Procedure Kuparuk Producer PTD #187-134 1 Current Operations: This well is currently shut-in and awaiting a RWO. Scope of Work: Pull the existing 3-1/2” completion and install a new 3-1/2” completion. General Well info: Well Type: Producer MPSP: 3,885 psi using 0.1 psi/ft gradient Static BHP: 4,442 psi / 5,952’ TVD (14.4 ppg EMW) measured on 05/06/2021 Wellhead type/pressure rating: McEvoy Gen 3, 5M psi top flange BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Rams MIT results: CMIT-TxIA PASSED -7/1/2020 MIT-OA PASSED – 12/3/2015 IC POT &PPPOT PASSED – 12/29/2018 TBG POT &PPPOT PASSED – 12/1/2015 Production Engineer: Lynn Aleshire Workover Engineer: Ron Phillips (263-6312/ Ron.L.Phillips@ConocoPhillips.com) Pre-Rig Work 1. CMIT testing. SBHP test. TBG and CSG PO tests. 2. Dummy all GLMs leaving the deepest GLM open as a circulation point. 3. FT LDS, grease tree valves and set BPV. Workover Procedure 1. MIRU Nabors 7ES on 3H-20. Pull BPV if need to circulate. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/4,000 psi. Test annular 250/2,500 psi. 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing from PBR at 8,523’ MD. 6. MU 3 ½” completion with GLMs and sting seals into PBR. 7. Once on depth, space out ~3’ as needed. 8. Pressure test tubing to 3000 psi for 5 minutes. 9. Pressure test inner annulus to 2500 psi for 30 minutes on chart. 10. Confirm pressure tests, then shear out SOV with pressure differential. 11. Install BPV. 12. ND BOPE. NU tree. 13. Pull BPV, freeze protect well, and set BPV if necessary. 14. RDMO. Post-Rig Work 1. Reset well house(s) and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline. Pull SOV, ball & rod and run GLD. 4. Handoff to operations to put back on production. for 30 minutes and chart 9-5/8" 36# J-55 shoe @ 4092' MD7" 26# J-55 shoe @ 9020' MD16" 62.5# H-40 shoe @ 115' MDA-sand perfs 8681' - 8691'8706' - 8726'8740' - 8780'8702' TOWS Baker Orbit Valve at 3493' MD (2.835" minimum ID)3-1/2" 9.3# L-80 EUE 8rd Tubing to surface3-1/2" Camco gas lift mandrels @ 3053', 4962', 6310', 7309', 7993' & 8428'Baker PBR @ 8523' MDBaker FHL packer @ 8546' MD 3-1/2" HES landing nipple 8640' ELM (8631' RKB)(2.812" min ID)3H-20L1-01 TD @ 10,353' MDLiner from 10,049' to TOL @ 9025' MD3H-20L1-03 TD @ 10,065' MDTOL @ 8695' MDBOL @ 9102'3H-20L1-04PB1 TD @ 10108' MDBillet @ 9517' MD3H-20L1-05 TD @ 11,192' MDTop of Liner @ 8667' MD3H-20L1 TD @ 11,354' MDTOL @ 9265' MD3H-20L1-02 TD @ 11,700' MDTOL @ 9800' MD3H-20L1-01PB1TD @ 10,130' MD Billet @ 9292' MD3H-20L1-06 TD @ 11,575' MDTOL @ 8800' MD3H-20L1-03PB1TD @ 9650' MDBillet @ 9087' MD8676' TOWS 3H-20L1-04 TD @ 11100' MDBillet @ 10153' MD3H-20 SchematicModified byRLP 6/11/2021 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 8,577.0 6/30/2020 3H-20 famaj Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: CT BHA Stuck in hole 8/19/2020 3H-20 kolsts Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 115.0 Set Depth (TVD) (… 115.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 35.0 Set Depth (ftKB) 4,091.7 Set Depth (TVD) (… 3,044.8 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 33.0 Set Depth (ftKB) 9,019.9 Set Depth (TVD) (… 6,299.9 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description 3.5 8rd UPPER COMPLETION String Max … 3 1/2 ID (in) 2.99 Top (ftKB) 30.0 Set Depth (ft… 8,540.0 Set Depth (TVD) (ft… 5,965.9 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd Completion Details Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 30.0 30.0 0.03 HANGER 3.5 " EUE 8rd X 7" Cameron McEvoy Gen 3 Hanger 3.000 3,493.7 2,732.9 58.09 BAKER ORBIT VALVE Baker 3.5" X 5.89 " Orbit valve W/ 2.8 drift 3500' 2.880 8,517.7 5,950.6 46.42 LOCATOR Baker 80-40 locator sub 2.990 8,518.7 5,951.2 46.42 SEAL ASSY Baker 80-40 Seal assembly W/ 7 ft space out 2.990 Tubing Description LOWER COMPLETION String Max … 3 1/2 ID (in) 2.99 Top (ftKB) 8,523.2 Set Depth (ft… 8,728.0 Set Depth (TVD) (ft… 6,096.3 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd Completion Details Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 8,523.2 5,954.3 46.40 PBR Baker 80-40 PBR 4.000 8,546.3 5,970.2 46.31 PACKER Baker 7" 26# FHL packer 2.890 8,631.3 6,029.1 46.05 NIPPLE 3.5 X 2.813 X nipple 2.813 8,643.2 6,037.4 46.03 XO Enlarging 3.5 EUE 8rd Box X 4.5" STC pin ported sub 2.992 8,645.0 6,038.6 46.03 LINER 4.5 X 12.6# STC W / 6" OD wear soxs 3.958 8,686.7 6,067.6 45.97 LINER 4.5 X 12.6# STC W / 6" OD wear soxs Mule shoe 3.958 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 5,612.0 4,017.7 47.83 LEAK - TUBING Leaks found at 5612' and 5644'. Possible additional leak at 5769' 11/23/2019 2.992 5,924.0 4,228.8 47.45 LEAK - TUBING Tubing Leaks at 5924', 6001', 6048', 6100', and 6216' 7/2/2020 2.992 8,282.1 5,789.3 47.11 PACKER - PATCH - LWR 2.72" P2P OAL 4' 7/1/2020 1.625 CPP35249 8,394.0 5,865.6 46.85 CT BHA CT BHA stuck while milling P2P packer. Burn shoe, venturi, motor, centralizer, and TJ lower disconnect left in hole. BHA Picked #27 up on 8/13 and in WV for details. 8/13/2020 0.880 8,520.0 5,952.1 46.41 LEAK - TUBING TUBING LEAK IN SEAL ASSEMBLY BETWEEN 8522' RKB & 8520' RKB 3/23/2020 2.990 8,667.3 6,054.1 46.00 CTD LINER 3H-20 L1-05 LINER 5/13/2016 1.900 8,676.0 6,060.2 45.99 WHIPSTOCK Baker GII Dealta Whipstock 5/3/2016 8,703.0 6,079.0 45.95 WHIPSTOCK Baker GII Dealta Whipstock 4/6/2016 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,681.0 8,691.0 6,063.7 6,070.6 A-3, 3H-20 12/5/2006 6.0 RPERF 2' HSD, 60 Deg ph, 2006 PF Charges 8,681.0 8,691.0 6,063.7 6,070.6 A-2, 3H-20 7/15/1988 12.0 APERF 60 deg. ph; SOS 2 1/8" EnerJet 8,706.0 8,726.0 6,081.0 6,095.0 A-2, 3H-20 7/15/1988 8.0 APERF 60 deg. ph; SOS 2 1/8" EnerJet 8,710.0 8,720.0 6,083.8 6,090.8 A-2, 3H-20 12/5/2006 6.0 RPERF 2' HSD, 60 Deg ph, 2006 PF Charges 8,740.0 8,760.0 6,104.7 6,118.6 A-1, 3H-20 11/13/1999 4.0 APERF 2 1/8" Energjet, 180 deg phasing +/- 90 deg 8,760.0 8,780.0 6,118.6 6,132.6 A-1, 3H-20 5/2/1988 4.0 IPERF 120 deg. phasing; 4 1/2" Csg Gun Stimulation Intervals Interval Numbe r Type Subtype Start Date Top (ftKB) Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 1 FRAC 1/13/2002 8,681.0 8,780.0 0.0 0.00 0.00 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,053.8 2,493.4 56.24 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 7/12/2019 5:00 2 4,962.3 3,579.9 48.27 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 7/13/2019 2:30 3 6,311.2 4,486.5 48.74 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/24/2016 8:00 4 7,309.9 5,147.1 47.75 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/8/2016 11:00 5 7,994.2 5,595.8 48.49 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/8/2016 1:00 6 8,429.3 5,889.7 46.73 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/8/2016 9:00 3H-20, 6/11/2021 8:20:45 AM Vertical schematic (actual) CTD LINER; 8,667.3 PRODUCTION; 33.0-9,019.9 IPERF; 8,760.0-8,780.0 APERF; 8,740.0-8,760.0 FRAC; 8,681.0 APERF; 8,706.0-8,726.0 RPERF; 8,710.0-8,720.0 WHIPSTOCK ; 8,703.0 LINER; 8,686.7 L1-03 Liner; 8,694.6-9,102.0 SLOTS; 8,695.0-9,091.0 APERF; 8,681.0-8,691.0 RPERF; 8,681.0-8,691.0 WHIPSTOCK ; 8,676.0 L1-05 Liner; 8,667.3- 11,192.0 SLOTS; 8,670.0-11,191.0 LINER; 8,645.0 XO Enlarging; 8,643.2 NIPPLE; 8,631.3 PACKER; 8,546.3 PBR; 8,523.2 SEAL ASSY; 8,518.7 LEAK - TUBING; 8,520.0 LOCATOR; 8,517.7 GAS LIFT; 8,429.3 CT BHA; 8,394.0 PACKER - PATCH - LWR; 8,282.1 GAS LIFT; 7,994.2 GAS LIFT; 7,309.9 GAS LIFT; 6,311.1 LEAK - TUBING; 5,924.0 LEAK - TUBING; 5,612.0 GAS LIFT; 4,962.3 SURFACE; 35.0-4,091.7 BAKER ORBIT VALVE; 3,493.7 GAS LIFT; 3,053.8 CONDUCTOR; 36.0-115.0 HANGER; 30.0 KUP PROD KB-Grd (ft) 42.01 Rig Release Date 1/25/1988 3H-20 ... TD Act Btm (ftKB) 9,050.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009300 Wellbore Status PROD Max Angle & MD Incl (°) 58.84 MD (ftKB) 4,000.00 WELLNAME WELLBORE3H-20 H2S (ppm) 110 Date 5/8/2019 Comment SSSV: NONE Annotation Last WO: End Date 3/9/2016 Notes: General & Safety End Date Annotation 8/19/2020 NOTE: PARTIALLY MILLED P2P PACKER AND CT BHA LEFT IN HOLE. Top of fish 8,394' CTM. 3/24/2016 NOTE: Orbit Valve control lines/system at wellhead, marked open or closed, OPEN AT 3493. 3/24/2016 NOTE: Orbit Valve is NOT a safety valve, it does not fail to closed position. 3H-20, 6/11/2021 8:20:46 AM Vertical schematic (actual) CTD LINER; 8,667.3 PRODUCTION; 33.0-9,019.9 IPERF; 8,760.0-8,780.0 APERF; 8,740.0-8,760.0 FRAC; 8,681.0 APERF; 8,706.0-8,726.0 RPERF; 8,710.0-8,720.0 WHIPSTOCK ; 8,703.0 LINER; 8,686.7 L1-03 Liner; 8,694.6-9,102.0 SLOTS; 8,695.0-9,091.0 APERF; 8,681.0-8,691.0 RPERF; 8,681.0-8,691.0 WHIPSTOCK ; 8,676.0 L1-05 Liner; 8,667.3- 11,192.0 SLOTS; 8,670.0-11,191.0 LINER; 8,645.0 XO Enlarging; 8,643.2 NIPPLE; 8,631.3 PACKER; 8,546.3 PBR; 8,523.2 SEAL ASSY; 8,518.7 LEAK - TUBING; 8,520.0 LOCATOR; 8,517.7 GAS LIFT; 8,429.3 CT BHA; 8,394.0 PACKER - PATCH - LWR; 8,282.1 GAS LIFT; 7,994.2 GAS LIFT; 7,309.9 GAS LIFT; 6,311.1 LEAK - TUBING; 5,924.0 LEAK - TUBING; 5,612.0 GAS LIFT; 4,962.3 SURFACE; 35.0-4,091.7 BAKER ORBIT VALVE; 3,493.7 GAS LIFT; 3,053.8 CONDUCTOR; 36.0-115.0 HANGER; 30.0 KUP PROD 3H-20 ... WELLNAME WELLBORE3H-20 Originated:Delivered to:16-Oct-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 3B-13 50-029-21286-00 906617822 Kuparuk River Plug Setting Record Field- Final 22-Jul-20 0 1 2 3H-20 50-103-20093-00 906518944 Kuparuk River Leak Detect Log Field- Final 2-Jul-20 0 1 3 3N-07 50-029-21539-01 906614634 Kuparuk River Plug Setting Record Field- Final 23-Jul-20 4 3N-07 50-029-21539-01 906604302 Kuparuk River String Shot Record Field- Final 16-Jul-20 5 3N-07 50-029-21539-01 906659750 Kuparuk River Leak Detect Log Field- Final 21-Aug-20 6 2K-04 50-103-20099-00 906595531 Kuparuk River Multi Finger Caliper Field& Processed 9-Jul-20 7 2K-04 50-103-20099-00 906595531 Kuparuk River Plug Setting Record Field- Final 8-Jul-20 8 3A-17 50-029-22691-01 906634080 Kuparuk River Plug Setting Record Field- Final 2-Aug-20 0 1 9 3K-23 50-029-22771-00 906648363 Kuparuk River Tubing Punch Record Field- Final 10-Aug-20 0 1 10 3N-19 50-029-23056-00 906659750 Kuparuk River Leak Detect Log Field- Final 21-Aug-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 0 1 0 1 Received by the AOGCC 10/16/2020 PTD: 1871340 E-Set: 34115 10/20/2020 Abby Bell Originated:Delivered to:1-Oct-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #CD # 1 2T-08 50-103-20070-00 906569204 Kuparuk River Multi Finger Caliper Field & Processed 25-Jun-20 0 1 2 3H-20 50-103-20093-00 906581746 Kuparuk River Multi Finger Caliper Field & Processed 30-Jun-20 0 1 3 1F-19 50-029-22660-00 906611163 Kuparuk River Multi Finger Caliper Field & Processed 20-Jul-20 0 1 4 1G-05 50-029-20908-00 906614905 Kuparuk River Packer Setting Record Field- Final 27-Jul-20 0 1 5 1R-34 50-029-22534-00 906617820 Kuparuk River Plug Setting Record Field- Final 22-Jul-20 0 1 6 2C-15 50-029-21219-00 906631899 Kuparuk River Multi Finger Caliper Field & Processed 31-Jul-20 7 2C-15 50-029-21219-00 906631899 Kuparuk River Plug Setting Record Field- Final 30-Jul-20 8 2T-08 50-103-20070-00 906595629 Kuparuk River Packer Setting Record Field- Final 13-Jul-20 0 1 9 2U-02 50-029-21268-00 906629021 Kuparuk River Multi Finger Caliper Field & Processed 29-Jul-20 10 2U-02 50-029-21268-00 906629020 Kuparuk River Leak Detect Log Field- Final 29-Jul-20 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 0 1 0 1 Received by the AOGCC 10/05/2020 PTD: 1871340 E-Set: 34062 10/07/2020 Abby Bell Originated: Schlumberger PTS - PRINTCENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to; AOGCC ;y ATTN: Natural Resources Technician II ' Alaska Oil& Gas Conservation Commision 333 W. 7th Ave, Suite 100 -may Anchorage, AK 99501 187134 FRANSMITrALOATE �- TRANSMITTAL p . - • , nt Please return via courier or sign/scan and email a copy Date lumberger and CPAL Schlumberger -Private A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. 1F-17 50-029-22657-00 E5C2.00015 r91:111 KUPARUK RIVER LTJ I Of.0 - 1 PPROF FINAL FIELD 15 -Nov -19 1 2N-341 50-103-20263-00 EOSH-00114 KUPARUK RIVER WL Caliper FINAL FIELD 78•Nov-19 1 1B-03 1D-135 50.029-20588.00 50-029-22816-00 ESC2-00019 E5C2.00020 KUPARUK RIVER KUPARUK RIVER WL WL PPROF LDL,Caliper FINAL FIELD 21 -Nov -19 1 3H-2050-103-20093-00 3N-15 50-029-21592-00 E5C2-00021 E5C2-00022 KUPARUK RIVER KUPARUK RIVER WL WL LDL Caliper FINAL FIELD FINAL FIELD FINAL FIELD 22 -Nov -19 23•Nov-19 24 -Nov -19 1 1 1 1 D•02 50-029-20429-00 E5C2.00026 KUPARUK RIVER WL Caliper FINAL FIELD 28 -Nov -19 1 I . 7 nt Please return via courier or sign/scan and email a copy Date lumberger and CPAL Schlumberger -Private A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. RUCEIVED • • 1AY10 £ ! AOGCC WELL LOG TRANSMITTAL#903201990 To: Alaska Oil and Gas Conservation Comm. May 5, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 M K.BENDER RE: Jewelry Log: 3H-20 Run Date: 3/26/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3H-20 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20093-00 Jewelry Log (Field Print) 1 color log 50-103-20093-00 SCANNEV PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed:/ AL / „44:ea' • • Krait 31+-7-0 Regg, James B (DOA) From: Regg, James B (DOA) -> Sent: Thursday, March 03, 2016 9:49 AM �� To: Packer,J.Brett Cc: Loepp,Victoria T (DOA); Schwartz, Guy L(DOA); Quick, Michael J (DOA); DOA AOGCC Prudhoe Bay Subject: RE: 3H-20 (PTD#187-134)Influx Attachments: Industry Guidance Bulletin 10-03.pdf See attached. Report is required by regulation. Report in this situation was required. Oil price environment has no impact on regulatory compliance. Also, as you read the regulation—e.g., 20 AAC 25.285(f)(2)—you will note that all components used must be tested. Jim Regg Supervisor, Inspections SEP 2 3206 AOGCC sCANNED 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: Packer, J.Brett [mailto:J.Brett.Packer@conocophillips.com] Sent: Thursday, March 03, 2016 9:37 AM To: Regg, James B (DOA); Loepp, Victoria T(DOA) Subject: RE: 3H-20 (PTD#187-134) Influx Jim, Sorry, I forgot to mention it was on Nabors 7ES. Also, in this new oil price environment, CPAI is constantly in the pursuit of reduced bureaucracy and paperwork, so the question came up in our meeting this morning, does the AOGCC want or need to be notified every time we close the BOP's, even for these minor events when we expect gas or possible pressure under a packer? Or, is it something the AOGCC could just read in our 10-404 report and verify that we tested the BOP component used after we got out of the hole? Also, I'm still a little fuzzy on this, unlike this well, in a situation where we have it in our procedure to close the bag and circulate out packer gas after pulling the packer free, and the well is static once the gas is circulated out, does this require notification to the AOGCC and does the bag require testing afterwards if it was a planned event? J.Brett Tacker r13ring s2 Was Supervising WorkaverEngineer Work,# (907)265-6845 Celt# (907)980-9467 1 • • From: Regg,James B (DOA) [mailto:iim.regg@alaska.gov] Sent:Thursday, March 03, 2016 8:33 AM To: Loepp,Victoria T(DOA) <victoria.loeppC«@alaska.gov>; Packer,J.Brett<J.Brett.Packer@conocophillips.com> Subject: [EXTERNAL]RE: 3H-20 (PTD#187-134) Influx Rig? Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or iim.regg@alaska.gov. From: Loepp, Victoria T(DOA) Sent: Wednesday, March 02, 2016 11:12 PM To: Packer, J.Brett; Regg, James B (DOA) Subject: Re: 3H-20 (PTD#187-134) Influx Brett, Thanx for the notification. As you outlined, upper pipe rams must be tested as soon as you trip out of hole. Victoria Sent from my iPhone On Mar 2, 2016, at 10:44 PM, Packer, J.Brett<J.Brett.Packer@conocophillips.com>wrote: Victoria, I just wanted to make you aware of a well control incident that just occurred on 3H-20. We were in the process of fishing our packer, once the packer released, we began circulating a bottoms up because we expect a certain amount of packer gas trapped beneath the packer. During this circulation, we saw an 8 bbl pit gain due to gas expansion, but after the gas had been circulated to surface,we had lost 5 bbls for a net gain of 3 bbls. We circulated 1.5x the hole volume again and then stopped to check for flow and the well was still flowing. At this point, we shut in the upper pipe rams, monitored the well for 15 minutes, and observed a shut-in drillpipe pressure of 320 psi. The well currently has 10.2 ppg KWF and the new KWF is calculated to be 11.3 ppg down to our circulation point at 5900'TVD. The current plan is to weight up our fluid system to 11.3+ ppg and perform a standard well kill. Afterwards, we will open the well back up and check for flow. Assuming the well is dead at this point, we will continue pulling out of the hole with our drillpipe and fish and once out of the hole, we will re-test the upper pipe rams to 250/3000 psi. If you have any questions, please don't hesitate to call or email. 2 • • * Thanks! J.Brett Backr Drifting GZ WeQ Supervising Worfwver Engineer Work# (907)265-6845 Cell# (907)980-9467 3 Loepp, Victoria T (DOA) From: Packer,J.Brett <J.Brett.Packer@conocophillips.com> Sent: Wednesday, March 02, 2016 10:43 PM To: DOA AOGCC Prudhoe Bay; Loepp, Victoria T (DOA) Cc: Kane, Danny;Alvord, Chip; Rauchenstein, Rock D; Herbert, Frederick 0; Nabors 7ES Company Man Subject: 3H-20 (PTD#187-134)Influx Follow Up Flag: Follow up Flag Status: Flagged Victoria, I just wanted to make you aware of a well control incident that just occurred on 3H-20. We were in the process of fishing our packer,once the packer released,we began circulating a bottoms up because we expect a certain amount of packer gas trapped beneath the packer. During this circulation,we saw an 8 bbl pit gain due to gas expansion, but after the gas had been circulated to surface,we had lost 5 bbls for a net gain of 3 bbls. We circulated 1.5x the hole volume again and then stopped to check for flow and the well was still flowing. At this point,we shut in the upper pipe rams, monitored the well for 15 minutes, and observed a shut-in drillpipe pressure of 320 psi. The well currently has 10.2 ppg KWF and the new KWF is calculated to be 11.3 ppg down to our circulation point at 5900'TVD. The current plan is to weight up our fluid system to 11.3+ppg and perform a standard well kill. Afterwards,we will open the well back up and check for flow. Assuming the well is dead at this point,we will continue pulling out of the hole with our drillpipe and fish and once out of the hole, we will re-test the upper pipe rams to 250/3000 psi. If you have any questions, please don't hesitate to call or email. Thanks! �.Brett Tacker ung eZ WelEs Supervising Worfpver Engineer ,. 16 `Work# (907)265-6845 . ` CeIT# (907)980-9467 1 Image Project Well HistorY File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. --_~_~- /_~--._~ Well History File Identifier ! Organization (done) '~Two-Sided RESCAN [] Color items: [] Grayscale items: '~ Poor Quality Originals: n Other: ,DIGITAL DATA [] Diskettes, No. [] Other, No/Type TOTAL PAGES: NOTES: ORGANIZED BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE OVERSIZED (Scannable) o Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Is/ Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /s/ PAGES: ~-'/.~ (at the time of scanning) SCANNED BY; BEVERLY BREN,VlNCE~ARIA LOWELL RESCANNEDBY;~BREN VINCENT SHERYL MARIA LOWELL General Notes or Comments about this file: PAGES: Quality Checked (done) Rev 1 NOTScanned.wpd ~ ~ COI'10~ ~ ~ ~ oPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 11, 2009 Mr. Tom Maunder i ~3 ~ Alaska Qil & Gas Commission i~~ 333 West 7~' Avenue, Suite 100 ` ~-' ~ Anchorage, AK 99501 - ~ 144'":` „ '~, ~;'.'w..., - Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped July 30~` 2009 and the corrosion inhibitor/sealant was pumped August 8~`, 9~' and 10~' 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please ca11 Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, v~G~~ ( MJ Lov land 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 08/11/09 ~r± ~u ~v o ~n o..a 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 bbis al 3G-12 50103201310000 1900730 24' 4.00 20" 7/30/2009 4.25 8/10/2009 3G-13 50103201370000 1901160 17" n/a 17" n/a 2.97 8/10/2009 3G-15 50103201390000 1901210 18" n/a 18" n/a 2.97 8/10/2009 3G-23 50103201440000 1901320 17" n/a 17" n/a 1.27 8/10/2009 3H-02 50103200830000 1871070 21" n/a 21" n/a 3.82 8/8/2009 3H-06 50103200780000 1870780 8'5" 2.00 18" 7/30/2009 5.52 8/8/2009 3H-07 50103200790000 1870790 17" n/a 17" n/a 2.97 8/8/2009 3H-09 50103200860000 1871120 17" n/a 17" n/a 5.52 8/8/2009 3H-106 50103200870200 2031600 16" n/a 16" n/a 2.55 8/8/2009 3H-12 50103200880000 1871290 2'7" n/a 2'7" n/a 8.92 8/9/2009 3H-15 50103200820000 1871030 19" n/a 19" . n/a 3.4 8/9/2009 3H-16A 50103200960100 2000220 15' 2.75 17" 7/30/2009 1.7 8/9/2009 3H-18 3H-20 50103200950000 50103200930000 1880090 1871340 SF 16' n/a 3.75 17" 16" n/a 7/30/2009 5.52 2.25 8/9/2009 8/9/2009 3H-22 50103200970000 1880110 27'6" 4.25 21" 7/30/2009 8.5 8/9/2009 3H-25 50103202030000 1990400 30" n/a 30" n/a 7.65 8/9/2009 3H-26 50103202080000 1940290 SF n/a 9" n/a 2.12 8/9/2009 3H-28A 50103202360100 1960370 SF n/a 18" n/a 5.1 8/9/2009 3H-32 50103203220000 2000010 10" n/a 10" n/a 1.27 8/9/2009 3K-102 50029233786000 2071650 n/a n/a 5" n/a 1.27 8/8/2009 3Q-01 50029222200000 1911250 15'7" 2.00 17" 7/30/2009 4.25 8/8/2009 3Q-02 50029216880000 1870040 41' 4.75 21" 7/30/2009 5.52 8/8/2009 3Q-04 50029222190000 1911240 4'10" 1.50 16" 7/30/2009 4.25 8/8/2009 3Q-07 50029216820000 1861940 6" n/a 6" n/a 1.7 8/9/2009 3Q-12 50029216770000 1861890 7" Na 7" n/a 2.97 8/8/2009 3Q-13 50029216640000 1861760 44'6" 5.00 21" 7/30/2009 8.92 8/8/2009 3Q-15 50029216660000 1861780 49'S" 4.50 20" 7/30/2009 9.35 8/8/2009 3Q-16 50029216670000 1861790 46' S25 30" 7/30/2009 8.5 8/8/2009 . . RECE\VED DEC 1 9 2006 STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Repair Well D Pull Tubing D Operat. ShutdownD 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 76' 8. Property Designation: ADL 25531: ALK 2657 11. Present Well Condition Summary: Total Depth measured 9050' . 6321' . true vertical Effective Depth measured 8599' true vertical Casing Structural CONDUCTOR SUR. CASING PROD. CASING Length Size 115' 4016' 8944' 16" 9-518" 7" Perforation depth: Plug Perforations D Perforate New Pool D Perforate 0 4. Current Well Status: Development 0 Stratigraphic D Stimulate 0 Waiver D Re-enter Suspended Well D 5. Permit to Drill Number: 187-1341 6. API Number: 50-103-20093-00 Exploratory D Service D 9. Well Name and Number: 3H-20 . 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool feet feet feet feet Plugs (measured) Junk (measured) MD Collapse TVD Burst 115' 4092' 9020' 115' 3045' 6300' Measured depth: 8681'-8691',8706'-8726',8740'-8780' true vertical depth: 6064'-6071',6081'-6095',6105'-6133' . . . . <··r<,. nt" r'o I.) '.¡¡'" ,1..~N<¡;;';~·. L ¡,;. \~ (,' .." .).~.~ _,;.;.!if;¡-,.¡....... Tubing (size, grade, and measured depth) 2-7/8", J-55, 8559' MD. Packers & SSSV (type & measured depth) pkr= CAMCO 'HRP-1-SP' pkr= 8484' Cameo TRDP-1A-SSA SSSV= 1788' 12. Stimulation or cement squeeze summary: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 450 68 113 476 . 15. Well Class after proposed work: Exploratory D Development 0 16. Well Status after proposed work: Oil0 GasD WAGD GINJD WINJ D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Oil-Bbl 129 . 134 Daily Report of Well Operations _X Contact Guy Schwartz @ 265-6958 Guy'Schw Printed Name Signatú're OR\G\N Form 10-404 Revised 04/2004 8681 '·8780' pumped 246,233 pds total Casin Pressure Tubin Pressure 158 121 Service D WDSPL D Title Wells Group Engineer Phone ';l {, -:> - &, 7 S' 9 Date I Z '-18 -0 , Pared b haron AlIsu -Drake 263-4612 ~?-I -;)--(. .41> IZ.·I'·O~ Su~Original On!t ~ r3/zr. (CJÓ DATE 11/22/06 11/23/06 11/24/06 11/26/06 11/27/06 11/28/06 12/3/06 12/5/06 12/5/06 12/6/06 12/11/06 . 3H-20 Well Events Summary . Summary TAGGED D-NIPPLE @8524' RKB, IN PROGRESS. SET 2.25" CA-2 PLUG @ 8524' RKB, PULLED GLV'S FROM STA'S 1,2,3, SET 1" DV'S IN STA'S 3, 2, IN PROGRESS. SET 1" DV IN STA# 1, PULLED 1.5"OV FROM STA# 5, PERFORMED CIRC OUT, SET 1.5"DV IN STA# 5, PERFORMED MIT ON TBG, & lA, BOTH PASSED, PULLED 2.25" CA- 2 PLUG @ 8524' RKB, SET FRAC SLEEVE @ 1788' RKB. ATTEMPTED A SAND RE-FRAC. UNABLE TO GET THROUGH TUBING HANGER WITH TREESAVER. SUSPECT SCALE OR ICE. PUMPED HOT DIESEL AND PUT HEATER ON TREE, RE-ATTEMPT SETTING TREESAVER, NO SUCCESS. RIG DOWN TO ALLOW SL TO BRUSH/BROACH HANGER. BRUSHED 3 1/2" TREE DOWN TO 2 7/8" TBG W /2.85" GAUGE RING AND BLB TO 4' SLM GAUGED TREE 2.91" TO 2 7/8" TUBING @ 4' SLM. JOB COMPLETE. ATTEMPTED TO PUMP AN A SAND FRACTURE TREATMENT. PUMPED A 260 BBL BREAKDOWN STAGE AND SAW MINIMAL BREAKDOWN. CONTINUED WITH THE SCOUR STAGE USING 40# X-LINKED GEL @ 15 BPM WITH 1 PPA OF 16/20 CARBO- LITE. PUMPED A 400 BBL DATAFRAC @ 20 BPM. PULLED ISO SLEEVE FROM SSSV @ 1788' RKB. DRIFTED WITH 2.23" CENT ON 10' x 2-1/8" STEM TO 8742' RKB. PERFORATED: 8681'-8691' & 8710'-8720' USING 2" HSD GUNS LOADED WITH 6 SPF 2006 POWERFLOW CHARGES. API DATA: PENETRATION = 4.5", ENTRANCE HOLE= 0.45" TAGGED TD AT 8738' SET 2.31" ISOLATION SLEEVE IN TRDP @ 1778' RKB. "A" sand data frac and frac with 40# gel. Ramped to 9 ppg concentration. Pumped 246,233 pds total, 246,094 pds in perfs. Pumped full flush, 30 bbls diesel in tubing. Average rate 15 bpm @ 5100 psi. Tree cups and backside pressures held OK. Full recovery of tree cups. 12/12/06 PULLED ISO SLEEVE FROM SSSV @ 1778' RKB. TAGGED FILL @ 8599' RKB, EST. 181' FILL. PULLED DV @ 8419' RKB, REPLACED WITH OV. IN PROGRESS. 12/13/06 PULLED DVs @ 3182',5810',7112' RKB. REPLACED WITH GLVs. .' .- .. . .. . . KRU 3H-20 ConocoPhillips Alaska, Inc. 3H·20 -- Anale @ TS: 46 deQ ~ 8656 Angle @ TD: 46 deg @ 9050 SLEEVE (1788-1789, 002.350) SSSV (1788-1789, 00:2.875) Gas Lift mdrel/Oummy Valve 1 (3182-3183, 00:5.313) Gas Lift 'ndrel/Dummy Valve 2 (5810-5811, OD:5.313) Gas Lift 'ndrel/Dummy Valve 3 (7112-7113, 00:5.313) Gas Lift 'ndrel/Dummy Valve 4 (7799-7800, 00:5.313) Gas Lift mdrel/Oummy Valve 5 (8419-8420, 00:5.750) PBR (8460-8461, 00:2.875) PKR (8484-8465, 00:6.151) NIP (8524-8525, OD:2.875) TUBING (4-8559, 00:2.875, 102.441) SOS (8558-8559, OD:2.875) Perf (8681-8691) Perf (8681-8691) Perf (8710-8720) Perf ~ (8706-8726) Perf (8740-8760) FRAC (8681-8780) i .-/-- ~ ~ API: 501032009300 SSSV Type: TRDP Well Tvpe: PROD Orig 1/25/1988 Completion: Last W/O: Rev Reason: NEW GLD Annular Fluid: Reference LOQ: Last Taa: 8599' RKB Last Tag 1211212006 Date: Casino Strino - All STRINGS DeseriDtion Size CONDUCTOR 16.000 SUR. CASING 9.625 PROD. CASING 7.000 Tubino Strino - TUBING Size I TOD Bottom 3.500 I 0 4 2.875 I 4 8559 Perforations SummarY Interval TVD Zone 8681 - 8691 6064 - 6071 A-3 Ref Log Date: TD: 9050 ftKB Max Hole 59 deg @ 4000 AnQle: Last Update: 12114/2006 Grade H-40 J-55 J-55 Thread Bottom TVD Wt 115 115 62.50 4092 3045 36.00 9020 6300 26.00 TVD Wt 4 9.30 5979 6.50 Status Ft SPF Date Tvne Comment 10 18 1215/2006 RPERF 2' HSD, 60 Deg ph, 2006 PF Charaes 4 8 17/15/198aAPERF 60 deg. ph; SOS 2 1/8" EnerJet 10 14 1215/2006 RPERF 2' HSD, 60 Deg ph, 2006 PF Charges 6 8 17l15/1981!APERF 60 deg. ph; SOS 2 1/8" EnerJet 20 4 1/13/199 [APERF 2 1/8" Energjet, 180 deg phasing +/- 90 dea 20 4 5/211988 IPERF 120 deg. phasing; 4 1/2" Csg Gun Comment A-SAND RE-FRAC, 172,000# 16/20 & 12118 CARBO LITE, 10 PPA ON PERFS u V Mfr V Type V OD latch Port TRO TOD o o o Grade J-55 J-55 Thread EUE 8RD AM MOD EUE 8RD AM MOD 8706 - 8710 6081 - 6084 A-2 8710 - 8720 6084 - 6091 A-2 8720 - 8726 6091 - 6095 A-2 8740 - 8760 6105 - 6119 A-1 ... 8760 - 8780 6119 - 6133 A-1 h ::::;2: ~ ~, ~ :~ tS ~ Stimulations & Treatments Interval Date TVDe 8681 - 8780 1/13/2002 FRAC Gas lift MandrelsNalves St MD TVD Man Man Type Mfr 1 3182 2564 eMurra FMHO 2 5810 4151 eMurra FMHO 3 7112 5015 eMurra FMHO 4 7799 5467 eMurra FMHO 5 8419 5883 Cameo MMG Other ( IUDs I QuiD. etc.\ - COMPLETION DeDth TVD TVDe 1788 1668 SSSV 1788 1668 SLEEVE 8460 5911 PBR 8484 5927 PKR 8524 5955 NIP 8558 5978 SOS 8559 5979 TTL Vlv Cmnt GLV GLV GLV DMY OV - 1.0 BK-2 1.0 BK-2 1.0 BK-2 1.0 BK-2 1.5 RK - . DeseriDiion Date Run 0.156 1382 2113/200 0.156 1355 2113/200 0.188 1369 2113/200 0.000 0 5/211988 0.188 0 2113/200 ID 2.313 2.310 2.297 2.347 2.250 2.441 2.441 Cameo'TRDP-1A-SSA' ISO SLEEVE set 1216/2006 Cameo 'OEJ' Cameo 'HRP-1-SP' Cameo 'D' Nipple NO GO Cameo ELMD 8556' ON SWS 1215/2006 ~._. . STATE OF ALASKA APR 2 0 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cons. Commission REPORT OF SUNDRY WELL OPERATIONS Anchora r,¡ o Time Extension 0 o . 1. Operations Performed: Abandon 0 Alter Casing 0 Repair Well 0 Pull Tubing 0 Operat. ShutdownD Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 76' 8. Property Designation: KuparukRiver Unit "1)(.. 1.t;t;.31 .ß V·').j¡'o~ 11. Present Well Condition Summary: Total Depth measured 9050' 6321' true vertical Effective Depth measured true vertical Casing Structural CONDUCTOR SUR. CASING PROD. CASING Length Size .- 115' 4016' 8944' 16" 9-5/8" 7" Perforation depth: RECEIVED Plug Perforations 0 Perforate New Pool 0 Stimulate 0 Waiver 0 Other Perforate 0 4. Current Well Status: Development 0 Stratigraphk: 0 Re-enter Suspended Well 5. Permit to Drill Number: 187-1341 ~ 6. API Number: 50-103-20093-00 . Exploratory Service o o 9. Well Name and Number: 3H-20 . 10. Field/Pool( s): Kuparuk River Field 1 Kuparuk Oil Pool . feet feet feet feet Plugs (measured) Junk (measured) MD Bu.rSt '''¥-, '~?"apse . TVD 115' 4092' 9020' 115' 3045' 6300' 1640 3520 4980 630 2020 4330 Mea.sured depth: 8681-8691,8706-8726,8740-8760 true vertical depth: 6064-6071, 6081-6095, 6105-6119 Tubing (size, grade, and measured depth) 2-7/8", J-55, 8559' MD. :iÇ!\~~NE~·· Packers & SSSV (type & measured depth) pkr= CAMCO 'HRP-1-SP' pkr= 8484' SSSV= SSSV SSSV= 1788' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A Subsequent to operation NIA 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory- 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: oil0 GasD WAG 0 GINJ 0 WINJ 0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt N/A Form 10-404 Revised 04/2004 RBDMS BFl APR 2 S 2006 Title Phone Problem Wells Supervisor 907-659-7224 Date 4/18/2006 AL Lþ 4· z..¡,.ofp ,~¡. I.. . /'J 11K'I/Jtltlt Submit Original Only JTt. . ¡ . . 3H-20 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 4/10/2006Set CA2 plug in Camco D nipple @ 8524' 4/16/2006 Repair Braidenhead thread leak with 3 pass seal weld. IMITOA to 1800 psi, - Passed IpulI plug and normal up well to BOL "~.....~' :"$' ~~ -4G- ~DVd $IHJ~ ~I~I(IN/I ~IVI~iVIN ALVIN ANV ~[DV~Id iON 0(2 00/~[/0! Cl~IIN~II~IO~DIIN pHii'LIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 February 19, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7t~ Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 3H-~~I~Illl~ Dear Commissioner Oechsli Taylor: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation activity on the KRU well 3H-20. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney Wells Team Leader Phillips Drilling MM/skad RECEIVED FEB ?~ 0 ?_007_ Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 76 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk Unit 4. Location of well at surface 8. Well number 1004' FNL, 4997' FEL, Sec. 12, T12N, RSE , UM (asp's 498656, 6000650) 3H-20 At top of productive interval 9. Permit number / approval number 1397' FNL, 2059' FEL, Sec. 1, T12N, R8E, UM (asp's 501592, 6005540) 187-134/ At effective depth 10. APl number 50-103-20093 At total depth 11. Field / Pool 1126' FNL, 1968' FEL, Sec. 1, T12N, R8E, UM (asp's 501680, 6005809) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 9050 feet Plugs (measured) true vertical 6321 feet Effective depth: measured 8779 feet Junk (measured) true vertical 6132 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 115' 16" 250 sx AS ~ 115' 115' SUR. CASING 4016' 9-5/8" 1340 sx AS III, 400 sx Class G, 36 4092' 3045' PROD. CASING 8944' 7" 700 sx Class G, 175 sx AS I 9020' 6300' Perforation depth: measured - RECEIVED true vertical 6064'- 6071', 6081'- 6095', 6105'- 6133'FEB Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 Tbg @ 35' MD; 2-7/8",6.5#, J-55 Tbg @ 8559' MD. Ala~ka0il &Gas Cons. Commission Anchorage Packers & SSSV (type & measured depth) CAMCO 'HRP-1-SP' @ 8484' MD. CAMCO q'RDP-1A-SSA' @ 1788' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) 8681'- 8780' Treatment description including volumes used and final pressure 172000# 16/20 & 12/18 carbolite, 10 ppa on perfs 141 Representative Daily Averaqe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 275 925 48 - 103 Subsequent to operation $1 - 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __ X Gas __ Suspended __ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Mike Mooney 263-4574 Signed ~,~z;;~FF, v~ Title Wells Team Leader Date Michael Mooned/ Prepared b~/ Sharon AIIsu~.Drake 263.4612 Form 10-404 Rev 06/15/88 · G!i, AL SUBMIT IN DUPLICATE Date Comment 3H-20 Event History 01 / 10/02 01/11/02 01/12/02 01 / 13/02 01/21/02 TAG FILL @ 8779 RKB, EST 1' PERFS COVERED; PULLED GLV'S @ 7099' & 5810' RKB, IN PROGRESS. [FRAC-REFRAC] PULLED-GLV @ 3182' RKB; SET DV'S @ 3182', 5810' & 7112' RKB; PULLED 1.5" OV @ 8419' RKB; SET 2.25" A-2 PLUG @ 8524' RKB; DISPLACED TBG & IA WI SEAWTR W/1500' DSL FP; SET 1.5" DV @ 8419' RKB; PT IA TO 3500#. IN PROGRESS. [FRAC-REFRAC] PULLED A-2 PLUG @ 8524' RKB; SET 2 7/8" FRAC SLEEVE @ 1773' WLM. [FRAC-REFRAC] PUMPED A SAND REFRAC. PUMPED BREAKDOWN, SAW 4120 PSI EXCESS FRIC. PUMPED INCREASED SCOUR STAGE, EXCESS FRICTION REDUCED TO 2400 PSI. PUMPED DATAFRAC, ADJUSTED PAD TO 360 BBLS. TREATING PRESSURES VERY HIGH THOUGHOUT JOB, BORDERING ON MAXIMUM PRESSURE T CLEANED FILL TO 5510' CTM W/1.75" JETSWIRL NOZZLE USING SEAWATER J313. GOT HUNG UP AT 5510', SUSPECT TREE-SAVER CUP(S). ABLE TO WORK FREE. WELL FREEZE PROTECTED W/DIESEL TO 2500'+. WILL RETURN AFTER S/L HAS PULLED FRAC SLEEVE AND FISHED RUBBERS. [FCC] 01/22/02 01/27/02 01/28/02 PULLED FRAC SLEEVE @ 1788' RKB, A-I-FEMTED TO FISH TREE SAVER RUBBER'S, IN PROGRESS [SSSV WORK] MADE SEVERAL ATTEMPTS TO FISH SUSPECTED TREE SAVER RUBBER @ 5147' SLM, NO SUCCESS. RECOVERED FULL SAMPLE BAILER OF SAND @ 5147' SLM. LOST TOOTH OFF OF SPEAR. APPOX 1.5" LONG X 1/2" THICK. BAILED SAND FROM 5147' TO 5150' SLM. ATTEMPTED TO SPEAR TREE SAVER RUBBER, NO SUCCESS.RECOVERED TOOTH FROM SPEAR THAT WAS LOST 1-27-02. [FISH] Page I of I 2/11/2002 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Pull tubing _ Alter casing _ Repair well _ Perforate _X Other_ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1004' FNL, 4997' FEL, Sec. 12, T12N, R8E, UM At top of productive interval 1397' FNL, 2059' FEL, Sec. 1, T12N, R8E, UM At effective depth At total depth 1126' FNL, 1968' FEL, Sec. 1, T12N, R8E, UM 5. Type of Well: Development __X Explorato~__ Stratigraphic_ Service__ (asp's 498656, 6000650) (asp's 501592, 6005540) (asp's 501680, 6005809) 6. Datum elevation (DF or KB feet) RKB 76 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3H-20 9. Permit number / approval number 187-134 10. APl number 50-103-20093 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 9050 feet Plugs (measured) 6321 feet Tagged Fill (3/17/00) @ 8579' MD. Effective depth: measured true vertical 8579 feet Junk (measured) 5993 feet Casing Length CONDUCTOR 115' SURFACE CSG 4016' PROD CSG 8944' Size Cemented Measured Depth True vertical Depth 16' 250 Sx AS I 115' 115' 9-5/8" 1340 Sx AS III, 400 Sx G, 4092' 3045' & 36 Sx AS I 7" 700 Sx CIG & 175 AS I 9020' 6300' Perforation depth: measured true vertical 8681 - 8691'; 8706 - 8726'; 8740 - 8780' 6064- 6071'; 6081 - 6095'; 6105 - 6133' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55, Tbg @ 35' MD; 2.875", 6.5#, J-55, Tbg @ 8559' MD. ~ackers & SSSV (type&measured depth) CAMCO 'HRP-I-SP' Packer @ 8484' MD. R E C [ IV [ D CAMCO 'TRDP-1A-SSA' @ 1788' MD. 13. Stimulation or cement squeeze summary ~_~ ~ ~) ~00i Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure ~,laska 0il & Gas [;un~ ,,,u~,mssm' Arl~hnrnn~e 14. Representative Daily Average Production or Injection Data OiFBbl Gas-Md Water-Bbl Casing Pressure Prior to well operation 439 121 14 - Subsequent to operation 495 219 20 - Tubing Pressure 155 147 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 16. Status of well classification as: Oil __X Gas ~ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title: Form 10-404 Rev 06/15/88 o Date ~, ~ Prepare(~ by John Peirce 26S-6471 3H-20 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 11/10/99: RIH w/dummy gun & tagged PBTD @ 8775' MD. 11/13/99: MIRU & PT equipment. RIH w/perforating guns & shot 20' of perforations as follows: Added perforations: 8740 - 8760' MD Used 2-1/8" Enerjet carriers & shot the perfs at 4 spf at 180 degree phasing. POOH w/guns. RD. 3/17/00: RIH & tagged fill @ 8579' MD. Returned the well to production w/gas lift and obtained a valid well test. ' STATE OF ALASKA ,N~,~KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS !1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate X Plugging Perforate Repair well Other ~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1007' FNL, 282' FWL, SEC.12, T12N, RSE, UM At top of productive interval 1394' FNL,~ 2061' FWL, SEC.12, T12N, R8E, UM At effective depth 1206' FNL, 1999" FWL, SEC.12, T12N, R8E, UM At total depth 1129' FNL, 1974' FWL, SEC.12, T12N, R8E, UM 12. Present well condition summary Total Depth: measured 9050 feet true vertical 6320 feet 6. Datum elevation (DF or KB) RKB 72 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3H-20 9. Permit number/approval number 87-134 10. APl number 50-029-20093-00 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None Effective depth: measured 8938 feet true vertical 6242 feet Junk (measured) None Casing Length Size Structural Conductor 8 0' 1 6" Surface 4 0 5 7' 9 - 5 / 8" Intermediate Production 8987' 7" Liner Perforation depth: measured 8681'-8691', true vertical 6063'-6070', Cemented Measured depth 250 SX AS1 1 1 5' 1340 Sx AS III & 4092' 400 Sx Class G w/36 Sx AS I Top Job 700 Sx Class G & 9 0 2 0' 175 Sx AS I 8706'-8726' 6081'-6095' 8760'-8780' 6118'-6133' Tubing (size, grade, and measured depth) 2.875", 6.5#/ft., J-55 @ 8559' Packers and SSSV (type and measured depth) PKR: Camco HRP-1-SP @ 8484'; SSSV: Camco TRDP-1A-SSA @ 1788' True vertical depth 115' 3045' 6300' 13. Stimulation or cement squeeze summary RECEIVED MAR 20 tgg? 14. Fracture Stimulate 'A' Sands on 6,4,96 NAL Intervals treated (measured) ORI 61 8681 '-8691', 8706'-8726', 8760'-8780' Treatment description including volumes used and final pressure Pumped 219.3 Mlbs of 20/40,12/18, & 10/14 ceramic proppant into formation, fl:) was 7300 psi Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 51 5 3 7 7 19 845 158 Subsequent to operation 8 8 3 5 7 5 90 848 160 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. Si,ned Form 1~1~4~4 [R~v/06/~5/88~-- I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Wells Superintendent Date .~--/~'~P SUBMIT IN DUPLICATE ,..ARCO Alaska, Inc. .... KUPARUK RIVER UNIT WELL SERVICE REPORT ~ K1(3H,20(W4-6)) WELL JOB SCOPE JOB NUMBER 3H-20 ' FRAC, FRAC SUPPORT 0602961831.1 DATE DAILY WORK UNIT NUMBER 06/04/96 'A' SAND REFRAC 1 (~) Yes O No (~) Yes O ,o DS-GALLEGOS ESTIMATE KM1186 230DS36H L $154,86-1 $160,891 Initial Tb.(:l Press Final Tb.cl Press Initial Inner Ann Final Inner Ann I Initial Outer An~/[ Final Outer Ann 50 PSI 900 PSI ~950 PSI 500 PSII 225 PSII 400 PSI DAILY SUMMARY REFRAC'D 'A' SAND AS DESIGNED. PLACED 219,280 LBS SAND BEHIND PIPE, LEFT 5,957 LBS IN WELLBORE. TOP 5,500' OF TUBING IS DIESEL-FILLED. USED 11,365 LBS 20/40, 209,700 LBS 12/18 AND 4,171 LBS 10/14 PROPPANT. TIME LOG ENTRY ' · 06:30 MIRU DOWELL FRAC EQUIP & APC SUPPORT EQUIP. 08:50 HOLD PRE,JOB SAFETY MEETING, WORK UP AND QC FLUIDS, PRIME PUMPING EQUIP, PRESSURE TEST TO 10,000 PSI. 09:55 START PUMPING CONDITIONING STAGE. 10:10 11'15 11:30 13:05 13:20 13:25 14:05 14:10 14:12 14:30 16:00 END CONDITIONING, S/D. FFP = 6,257 PSI, ISIP = 1,611 PSI. CONDUCT PULSE TESTING. START DATAFRAC. · END DATAFRAC, S/D. MONITOR PRESSURE. ISIP = 1584 PSI. START FRAC- PUMP PAD. END PAD, START ADDING 20/40 PROPPANT @ 2 PPA. SWAP TO 12/18 PROPPANT @ 2 PPA, RAMP UP TO 10 PPA, THEN PLATEAU @ 10 PPA. SWAP TO 10/14 PROPPANT @ 10 PPA. SWAP TO XL GW FLUSH FOR 9 BBLS,'THEN TO SLICK DIESEL FLUSH FOR 39 BBLS. END FRAC, S/D. FFP = 7,300 PSI, ISIP = 2,367 PSI. MONITOR PRESSURES. END PRESSURE MONITORING. FSIP = 1,648 PSI. RDMO DOWELL & LRS. WELL SECURED, EVERYBODY OFF LOCATION. SERVICE COMPANY- SERVICE DAILY COST ACCUM' TOTAL $0.00 $504.00 APC $6,185.00 $8,285.00 , ARCO $580.0,0 $580.00 .DOWELL $143,506.00 $1 43,506.00 HALLIBURTON $0.00 $3,426.00 LITTLE RED $4,590.00 $4,590.00 TOTAL FIELD ESTIMATE $154,861.00 $160,891.00 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 27, 1996 Dave Johnston Commission Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: Notification of Lost-in-Hole Radioactive Sources Dear Mr. Johnston: This letter is to notify the Commission that two small radioactive sources were left in the wellbore of KRU Well 3H-28A. The drillstring became packed-off and stuck while tripping out of the hole on February 17, 1996. Subsequent fishing attempts were unsuccessful, and the BI-lA was covered with cement and the well sidetracked. Two small RA sources were left downhole: an Americium source that is part of the Anadrill CDN tool and a Cesium source that is part of the CDR tool. Both sources are contained in the respective tool collars and have been covered with cement per NRC regulations for abandonment. The NRC was notified of the abandonment plans prior to cementing the BHA with verbal approval given on February 20, 1996, by Linda Howell of the NRC. If you have any questions or need more details, please contact the Drilling Engineer, Denise Petrash at 263-4183, or myself at 265-6206. Mike Za~ai ~. Drill Site llZe~elopment Supervisor CC: Blair Wondzell Denise Petrash AOGCC ATO-1286 FEB 29 1996 Alaska Oil & Gas Cons. Ccmraission Anchorage AR3B-6003-93 242-2603 1. Type of Request: Operation Shutdown ..... Pull tubing 2. Name of Operator ARCO Alaska, Inc, 3. P. 4, 1 ~"~ STATE OF ALASKA ~"~ ~J~, OIL AND GAS COI~BVA~ COMMISL. REPORT OF SUNDRY WELL OPERATIONS ,_n_= Plu~i~ Perforate , Other Address O. Box 100360, Anchorage, AK 99510 Location of well at surface 007' FNL, 282' FWL, SEC.12, T12N, At top of productive interval 1394' FNL, 2061' FEL, SEC. 1, T12N, At effective depth 1206' FNL, 1999' FEL, SEC. 1, T12N, At total depth 1129' FNL~ 1974' FEL~ SEC.I~ T12N~ R8E~ UM ..... Stimulate X Alter casing ~ Repair well 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ R8E, UM R8E, UM R8E, UM 9050' feet 632 0' feet 12. Present well condition summary Total Depth: measured true vertical Plugs (measured) 6. Datum elevation (DF or KB) BKB 76 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3H-20 9. Permit number/approval number 87-134 / ADDrV. N/A . . 10. APl number 5o-103-2009300 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 8938' true vertical 6242' feet Junk (measured) feet ~ Casing Length Size Structural Conductor 80' 1 6" Surface 4057' 9-5/8" Intermediate Production Liner Perforation depth: 8987' 7" Cemented Measured depth 250 SX AS I 115' 1340 SX AS III & 4092' 400 SX Class G TOP JOB w/36 SX AS I 700 SX Class G & 9 0 2 0' 175 SX AS 1 measured 8681 '-8691', 8706'-8726', true vertical 6064'-6070', 6081 '-6251', Tubing (size, grade, and measured depth) 2-7/8" J-55 TBG w/TAIL @ 8559' :)ackers and SSSV (type and measured depth) HRP1-SP PKR ~ 8484' AND TRDP-1A-SSA SSSV ~ 1788' 13. Stimulation or cement squeeze summary A SAND FRACTURE STIMULATION Intervals treated (measured) 8681 '-8691', 8706'-8726', 8760'-8780' Treatment description including volumes used and final pressure SEE ATTACHED WELL SERVICE REPORT SUMMARY 8760'-8780' 6118'-6132' True vertical depth 115' 3045' 6300' 14. Prior to well operation Subsecluent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Reoresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure 304 159 0 1161 716 665 15 1175 16. Status of well classification as: Water Injector__ Oil ~, Gas , , Suspended __ Service Tubing Pressure 155 135 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE H£-SG ~6/9'1:/c~00i ~6/9'1:/c~0 ARCO Alaska, Inc. Date: July 29, 1988 Transmittal #: 7239 RETURN TO: '~ 3H-20' ,~3H-19 ~ 3H-20 3H-19 ARCO Alaska, inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk A'['O-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- ~ Kuparuk Well Pressure Report 7 - 1 2- 8 8 Amerada Kuparuk Well Pressure Report 7-1 2-88 PBU Bottom-Hole Pressure Survey 7 - 0 9 - 8 8 PBU Bottom-Hole Pressure Survey 7 - 09- 88 PBU Kuparuk Fluid Level Report 7 - 21 - 8 8 Casing Receipt Acknowledged: Date' ................... -Ar~,~'bil & G~s C0~s. Cammfssi0r~ D&M Mobil State o! Naska Unocal Chevron sAPC '/"~'~ STATE OF ALASKA ~ (~ ALASKA OIL AND GAS CONSERVATION COI~.MISSION 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, I nc. 87-134 3. Address 8. Apl Number P. 0. Box 100360, Anchorage, AK 99510 50- 103-20093 4. Location of well at surface 91 Unit or Lease Name 1007' FNL, 282' FWL, Sec.12, T12N, R8E, UM Kuparuk River Unit _ At Top Producing Interval 10. Well Number 1394' FNL, 2061' FEL, Sec. 1, T12N, R8E, UM 3H-20 At Total Depth 11. Field and Pool 1129' FNL, 1974' FEL, Sec.l, T12N, R8E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 76' RKB J ADL 25531 ALK 2657 12' Date Spudded01/10/88 13. Date T.D. Reached01/24/88 14' Date Comp" Susp' °r Aband' ] 15' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns06/18/88* N/Afeet MSL1 17. Total Depth (MD+TVD) i18. Plug Back Depth (MD+TVD)! 19. DirectionalSurvey I 20' Depth where SSSV set [ 21. Thickness of Permafrost 9050'MD/6320'TVD 8938'ND/6242'TVD YES ~] NO [] · 1788 feet MD 1600' (approx) 22. Type Electric or Other Logs Run D IL/SP/SFL, FDC/CNL, Cal, GR, CBT~ (;CT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED ,, 16" 62.5# H-40 Surf 115' 24" 250 ~X AS I ... 9-5/8" 36.0# J-55 Surf 4092' 12-1/4" 1340 sx AS Ill & 400 sx (:lass G Top job w/36 sx AS I '"7" 26.0# J-55 Surf 9020' 8-1/2" 700 sx Class G & 175 sx AS I 24. Perforations open to Production (MD+TVD of Top and BOttom and 25. TUBING RECORD interval, size and number) SIZE ' ' 'l DEPTH..SET (MD) PACKER SET (MD) Perforated w/4 spf, 90° Phasing 8760 '-8780 'MD/6118' -6132 'TVD 26. ACI D, FRACTURE, CEMENT SQUEEZE, ETC. DE_P.TH IN.T..E_R_V~A. L~(~M_D_). AMOUNT & KIND OF MATERIAL USED ~,ug T/io~z'-zuuu. 800 sx AS i ~'lug 'r/u~Zbb'-u~:351, 2U0 sx ~;lass (3 See attacheo Aoden~lum Outed 6/2~/88 for Fracture data 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) N/A Date of Test Hours Tested ' PRODucTION FOR OI L-BB'L GAS-MCF WATER-BBL C. HOKE SIZE '1 GAs-oiI' RATIO TEST PERIOD II~ Fiow Tubing Casing Pressure CALCULATED=1~ oIL-BBL GAS-MCF WATER-BBL 0IL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief descripti°n °f lith°l°gy' P°r°sity' fractures' apparent dips and presence °f °il' gas °r water' Submit c°re chipsj~ ECE ~ VED None JUL 2 Alaska 011 &' Gas Cons. Commission · NOTE: Drilled RE 01/25/88. Perforated Well and ran tubing 5/2/88. Fractured well 6/~.a~]e Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE , , 29. ( 3O. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity,, MEAS. DEPTH TRUE VERT. DEPTH GOR0 and time of each phase. Top Kuparuk C 8661' 6049' N/A Base Kuparuk C 8661' 6049' Top Kuparuk A 8664' 6051' Base Kuparuk A 8817' 6158' ,, 31. LIST OF ATTACHMENTS Addendum (dated 6/29/88) · 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ (~)/J(~/~,.~ ~'~1 ~/,~J[ J Title Associate Enai neet Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing interVals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 3~29~88 5/18/88 6/13/88 6/16/88 6/18/88 3H-20 RU Schl. Rn GR/JB f/surf to 8922'. Rn CBT f/8904'-4100'; §ood bond. Rn GCT f/8880'-surf. RU GSL. Pmp 5% Musol w/diesel. Displ w/56 bbls diesel. No drop in pressure as Musol entered perfs. SI well. RD GSL. Notify Production. Att to frac well w/o success. Frac cancelled. Displ diesel w/10% Musol to perfs w/57 bbls diesel. Frac Kuparuk "A" sand perfs 8760' - 8780' per procedure dated June 16, 1988, as follows: Prepad: Pad: Ramp: 200 bbls diesel @ 20 BPM, 4863 - 6360 psi 543 bbls diesel @ 20 BPM, 4950 - 6176 psi 101 bbls gelled diesel, 0 - 2 ppg, 16/20 @ 20 BPM, 4918 - 5193 psi 70 bbls gelled diesel @ 4.5 - 6 ppg, 16/20 @ 20BPM, 5675 psi 14 bbls gelled diesel, 7.8 - 9.1 ppg, 16/20 @ 20 BPM, 5974 - 6066 psi No screen out. Fluid to Recover: Sand in Zone: Sand in Csg: Avg Pressure: 709.5 diesel 28,850# 0 5300 psi Drilling- ~upervisoF 993MnB)l ~e i~nowoo BB-BVN-6 [ ~i3B~IVS ~! peDOO9 LggZL 'ON eou&J6~eEI ClOP " ¥~S¥9¥ '3d09S HIBO'N '~nuvdh~ UOl~eOoglPlel~ , ~ ' ' '3NI 'V~SVgV 03ur u~dwoc) 'ItYNOI. LO MIO snonNI.I. NO~'~ aON¥Oln[~] SCHLUMBERGER GCT DIRECTIONAL CUSTOMER LISTING A~CO ALA6KA, INC, L~H-20 KUPANUK NORTH 5LOP~,ALASKA SURVEY DATE: 19-MAR-88 ENGINEER: G, SARBER METHODS UF COMPUTAT1UN TOOL LUCATION: TANGENTIAL- Averaqed deviation and azimuth INTERPOLAT1UN: I.,I~EAR VERTICAL SECTION: HORIZ, DIST, B~gJEC~'ED ONTO.A JARGET AZIMUTH OF NORTH ARCO ALASKA, LNC, 3H-20 KUPARUK NORTH SLOPE,ALASKA TRUE SUB-SEA COURSE ~EASURED VERTICAL VgRTICAL D~VIATION AZIMUTH DEPTH DEPTH DEPTH, 900 O0 893,23 81723 16~18 1000 00 988,68 912,68 18 22 1100 00 1082,90 1006,90 21 9 1200 00 1174,87 1098,87 24 50 1300 00 1264,24 1188,24 28 26 1400 00 1351 18 1275,18 1500 00 1436~14 1360,14 32 54 1600 O0 1518,53 1442,53 36 15 1700 O0 1597,56 1521,56 38 3 1~§ 00 1677,27 1601 27 37 7 1 ~ 00 1756,4! 1680:41 38 48 2000 O0 1832,7'1 1756,77 4j 20 2100 00 1906,87 18]0,87 43 32 2200 00 1977,45 1901,45 46 24o- oo 21o .4 2 500 O0 2172,10 2096.10 51 48 2600 00 2233.13 2157,13 52 58 2700 O0 2292,53 22~b.53 54 13 2800 O0 2350.43 2274.43 54 2900 O0 24U7,51 2331,5~ 55 3000 00 2463 59 2387.59 56 10 3100 ~0 2519 04 2443.04 56 17 3200 00 2574 40 2498,40 56 3300 O0 2629 12 2553,12 57 0 400 O0 2683 14 2607,14 57 39 500 O0 273& 27 2660,27 58 7 3600 00 2788 88 27~2,88 58 21 3700 00 2841:23 2765,23 58 28 3800 O0 2893,34 2817,34 58 43 3900 00 2945.21 2869,21 58 42 CO~iPUTAT1ON DATE:, 5-APR-88 PAGE' DATE OF SURVEY{ 19-MAR-S8 · KELL'¥ BUSHING ELEVATION{ 76,00 ENGINEER! G, SARBER. · INTERPOLATED VALUES FOR EVEN 100 FEET UF ~EASURED DEPTH VERTICAL DC)GbEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORtH/SOUTH EAST/NEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET. .DEG N 0 0 E O0 .0 5 N 69 25 E O0 0 7. N 84 36 E 60~ 05 S 87 8 E DO O: 16 N 53 16 E ~ 1"'55 N 12 :?, 5 17 N 16 11 E 80 10 28 N 24, 37 E ~ 26 49 E N 27 6 E 26 58 E 27 28 E 27 38 E ,27 44 ~ 28 14 E 28 49 E 30 30 E 31 19 E 39 2 E 43 54 E 0,00 0,15 0 26 0 37 0 55 2 25 7 6! 21 27 42 15 ~7 61 97 33 130 72 169 83 214 56 263 87 316 51 373,13 434,38 494,59 554,57 N 42 30 L b17,75 N 40 42 E 683.87 ~ 38 50 E 753 96 ~ 36 % E 827 39 k 35 55 E 903 55 ~ 37 4 E 981 17 ~ 37 33 E 1059 97 N 37 51 E 1139,95 N 38 15 E 1220,96 N 38 37 E 1302,47 N 38 54 E 1384,60 N 39 29 E 1467,08 N 40 10 E 1549,48 ~ 40 24 E 1632,20 i~ 40 38 E 1715,33 N 40 52 E 1798.94 N 40 57 E ~882.84 a 41 3 E 1966.88 h 41 15 E 2051,03 ~ 41 25 E 2135,27 0 O0 0 O0 0 00 0 00 0 81 1 41 5 58 4 33 2 47 2 79 2 28 4 06 3 52 2 2 30 3 09 4 24 4 53 4 21 2:63 1,81 4 41 2 44 3 24 2 13 1 14 1 O4 1 43 0 70 0 83 0,61 0,76 0 61 0 4O 0 78 0 39 0 22 o o o :!7 0 O0 N 0 10 N 0 10 N 0 12 N 0 lU N 86 N 32 N 20 23 N 39 09 N 61 80 N 0 O0 E 0 13 E 0 34 E 0 53 E 0 78 E I 27 g 2 62 E 7 71 E 16 89 g 28 55 E 2 7 65, N 20 51 58 N 23 22 08 N 24 47 E 88 37 N 118 152 192 236 282 331 384 433 478 42 08 E 18 N 57 81N 75 63 N 96 17 N 119 58 N 144 76 N 172 51N 203 7'1N 238 84 N 280 97 88 N 25 27 E 69 E 1 32 E 215 64 E 264 66 E 317 77 E 374 92 g 435 76 E 495 O1E 554 .~6 N 25 52 E 74 N 26 51 E 45 N 27 6 E 05 N 27 3O E 7 56 23 N 2 E 14 N 28 49 E 70 N ~{0 19 E 525 79 N 324 29 E 617 75 N 31 39 E 576 630 689 751 813 876 940 1004 1068 04 N 368 48 N 414 Ol N 459 06 N 503 60 N 550 59 N 598 25 N 647 46 N 697 75 N 748 83 E 684 13 E 754 12 E 827 64 E 904 11E 982 14 E 1061 O0 N 32 37 E 32 N 33 17 E 97 N 33 40 E 29 N 33 50 E 13 N 34 3 E 22 N 34 18 E 57 E 1222 93 N 3 65 E 1304,87 N 35 0 1133 30 N 800 50 E 1387 50 N 35 14 E 1197 1261 1325 1389, 1453 1517 1582 1646 1710 82 N 853 05 E 1470 75 N 906 43 E 1553 58 N 9bO 57 E 1637 56 N 1015 23 E 1720 71N 1070 57 E 1805 98 N 1126,26 E 1890 20 N 1182,18 E 1975 53 N 1238,34 E 2060 71N 1294,82 E 2145 53 N 35 27 E 58 03 ~ 35 92 $ 36 9 E 37 N 36 22 E lb N ]6 34 E 12 N 36 45 E 23 N 36 56 E 48 N 37 ? E ARCO ALASKA, 3H-20 KUPARUK COMPUTATION DAng: 5-APR=88 PAGE' DATE OF SURVE¥I 19-MAR-BB BUSHING ELEVATIONI '76,00 ENGXNEERI G, SAR~ER- INTERPOLATED VALUES FOR EVEN i00 FEET OF NEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL D~VIATION AZIMUTH DEPTH DEPTH DEPTH, DEG MIH DEG MIN. VEATICAb DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE ~ECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/iO0 FEET FEE~ FEET .DEG MIN 4000 O0 2997 09 2921 4100 O0 3048 4400 4500 4~00 4700 4800 4900 ,09 , 5 50 94 2972'94~ ':5~ 23 51 3025,51 ' 58 18 '08 5 '15 '99 5.~ 51 N ~1 37 g 2219.47 ~ 41 36 E 2303,63 2387,45 2470,86 00' 3155 O0 3213 O0 3277 O0 3341 O0 3406 O0 3472 O0 3538 N 41 9 E 08 3079 ~ 39 13 g 99 3137 N 34 9 E 2551,25 16 3201e16 49 57 N 31 44 E 2628,75 49 9 N 64 3265,64 5 32 43 E 2705.17 42 3330.42 49 15 N 33 3 E 2781.33 07 3396,07 48 40 N 32 57 E 2856:7,3 29 3462,29 48 22 N 32 14 E 2931. 66 5000 O0 3604 82 3528,82 48 12 5100 5200 53OO 5400 55OO 5600 57OO 5800 5900. O0 3671 O0 3738 00' 38O6 O0 3874 O0 3942 Oo 4009 O0 4076 O0 4144 00 4212 59 3595 59 48 0 70 3662:70 47 39 33 3730,33 47 16 lb 3790'16 47 17 03 386~,03 47 14 5L 39~3,56 47 51 75 4000,75 47 36 44 4o68 44 47 7 51 4136:51 47 16 N 31 20 E 3006,31 N 30 34 E 3080 75 N 29 49 E 3154 N 29 11 g 3228 N 28 3O g 3301 N 27 45 E 3375 N 27 7 E 3448 N 26 20 E 3522 N 25 42 E 3595 N 25 4 E 3668 86 48 19 75 56 82 66 6000 O0 4279,73 4203,73 6100 O0 4346,65 4270.65 48 13 6200 O0 4412,95 43,36,95 48 36 6300 QO 4478,95 4402.95 48 45 6400 00 4544 95 446~,95 48 36 bSO0 00 4611~05 4535,n5 48 29 6600 O0 4677 44 460J,~4 48 20 6700 O0 4743 92 4~67,9~ 48 31 6800 00 4809 81 4733.81 48 48 6900 O0 4875 67 4799,~7 48 52 N 24 11 E 3742 17 !~ 23 49-E 3815:83 N 23 16 ~: 3889 ~ 22 23 E 3964 N 21 36 E 4038 ~ 20 51. E 4112 ~ 20 37 E 4185 ~ 22 2b E 4259 ~ 22 30 E 4333 ~ 24 19 E 4407 98 24 33 16 58 15 45 91 7000 O0 4941 24 4865.24 49 9 7100 7400 7500 7600 7700 7800 7900 O0 5006 O0 5073 O0 5140 O0 5207 O0 5274 O0 5338 O0 5402 O0 5467 O0 5533 99 4930,99 48 44 23 4997,23 48 12 17 5064,17 47 46 65 5131,65 47 28 21 5198.21 49 6 61 5262.61 50 ~3 73 5326,73 49 43 73 5391,73 49 20 15 5457.15 48 53 N 26 4 E 4482,98 {~ 25 18 E 4557,94 N 24 35 E 4632,35 N 25 B E 4706,12 ~ 25 20 E 4779.47 ~ 26 11E 4853,72 N 26 30 E 4929,92 N 25 45 g 5006,32 N 24 55 E 5081,87 m 24 16 E 5156,95 0,22 1,61 0,38 5,55 5,03 1 3O 0 49 0 61 0 ~7 0 57 0,66 0,66 0,61 0 49 0 57 0 ~7 0 74 0 56 0 56 ! 27 0.87 1 10 0 7O 0 58 0 66 0 57 I 02 1 45 0 49 2 01 0,54 8O O, I774 71 N 1351 51 E 2230 1838 59 N 1408 34 E ~i~)O5 1902 42 N 1464 1966 U7 N 1519 2031 34 N 1567 2096 69 N 1609 2161 34 N lb50 2225 29 N 1691 2288 50 N 1732 2351,62 N 1773 58 E 35 E 36 E 264~ 1~ E 271 52 E 279 68 E 287~ 06 E 2945 2415 Ob N 1812 41 E 3019 49 N 36 53 E 2478 90 N 1850 71 E 3093 55 N 36 44 E 2542 2607 2671 2736 2801 2867 2933 3000 97 N 1887 08 N 1924 42 N 1959 18 N 1994 65 N 2028 79 N 2061 -92 N 2094 10 N 2125 9 g 3167 ~9 g 3240 77 E 3313 42 E 3385 37 E 3458 69 E 3531 ~i E 3604 E 3676 N 36 35 E N 36 25 E 18 N 36 15 E 91 N 36 554 E 83 a 35 ~ 97 N 35 42 E 54 N 35 3O E 68 N 35 18 E 3067,35 N 2156 3135'28 N 2186 3203,8e N 2216 3273,12 N 2245 3342~78 N 2273 3412,70 N 2300 3482,71N 2327 3552,18 N 2354 362~,67 N 2383 3690,81N 2413 38 E 3749 48 N 35 6 E 50 g 3822 41 N 34 53 g N 34 40 E 49 E 3895 62 E 3969 78 E 4042 98 E 4115 54 E 4335 23 E 4409 85 40 N 34 27 E 80 N 3413 E 95 N 33 59 E 73 N 33 45 E 64 N 33 74 N 33 10 ~ 3759 O0 N 2445 63 E 4484 55 S 33 2 E 3826 88 N 2478 N 32 55 g 3894 80 a 2509 N 32 47 g 3962 27 N 2541 02 E 4707 06 N 32 40 E 4029 4096 4164 4233 4302 4371 08 N 2572 26 N 2604 77 N 2638 64 N 2672 3O N 2705 08 N 2736 33 E 4559 30 93 E 4633 49 40 g 4780 24 N 32 33 g 86 E 4854 34 N 32 27 E 92 E 4930 43 s 32 2t E 77 E 5006 73 N 32 15 E 31E 5082.18 . 32 9 g 78 E 5157,16 N 32 3 E 3 9£ OE ~ 66 ~ O~ N 9O 3Z;t TEN N 3 ~ OE N q6'SL6~ 30t'~O~ N 6L'L~T~ 3 Lg OE N 96'[~6~ 3 £0'£t0£ N £L8~ 3 88 066~ N ~08g ~ 99 896~ N 6~'L86~ ~£LS 3 ~0 9~6~ N 6E 6t6~ 99g 30t £~6~ N O~ 6SS 30L 66~8 ~ ~L 3 8~~E N £~GOEG 3 £G q6L~ N ~E 809~ 3 9G ~E N ~g ~£~G 3 6~ LOL~ N ~L 6~ 00'0 00~0 LL'LL69 3 6~ L% N ~6'~69 3 69 LT N O0~ 00'(~00 06 06 00'0 g8 0 L8 0 98 0 £6 0 b~'ELS9 :( 6S LT N L~ g) 6L~6EI9 6L'Si~9 E9'£089 ~ ET 8~ N )) S) L6,6909 L6*G)g9 £L*££Lg 3 ££ B~ ~ LG ~ ~£~0009 EE*OL09 [9'£q99 3 8£ 8~ ~. 9 9~ ~8,0i6§ L8'9009 0'£6~§ ~ g 6t N 6g 9~ ~8.t99~ ~B'LE6~ 6['8L£g ~ q~ I~ N [~ L~i ~I. 0:~L§99 tO'EELS Lt*§O£§ 3 SE gE ~ 0 8~.~!;'~L,68~ 6L*§995 O0 0068 O0 0088 O000L8 OO ~098 O0 0~8 O0 00~8 O0 O0 8 O0 00~8 oo 00~8 O0 000~ 3~fl&~3d '2I~0~ ~3~VNIOHO03 ~VqADNV~D~ DRqDOd "IVDI£~2A ~g~AOD V~g-~fl9 ~ H~d~(:! d3~fl~V~W ,~0 &~3,t 00[ N~A~ ~OJ g~f'lqVA d~ZYqOd~2&NI ~'O0'9L INOi&VA3q3'DNIHgRq Xqq2~ 88-SdV-G :~gVO NOi~;V£ndN03 V~gVqV*3dOqg H~80N O~-HE ARCO ALASKA, INC. 3H-20 KUPARUK NORTH SLOPE,AI, ASKA COMP[.JTATIUN [)ATE: 5-APR,.S8 PAGE' DATE OF SURV£Y: 19-M'AR-88 KELLY BUSHING EbEVATIONI 76,00 ENGINEER: G, SARBER- INTERPOLAIED VALUES FOR EVEN 1000 FEET Of' NEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAI~ VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG VENTICAL DOGLEG RECTANGULAR COORDINATES HOR~Z. DEPARTURE SECTION SE:VERITY NURTH/$OUTH EAST/WEST DIBT. AZIMUTH FEET DEG/IO0 FEET FEET FEEX DEG MIN 0 O0 1000 2000 3000 4000 5000 6000 7000 8000 9000 0.o0 76.00 0 0 O0 988 O~ ;12'68 '~ 22 O0 1832 77 1756,~:77 ' 20 O0 2463 59 2387;59 ,~56 10 oo o. O0 3604 82 3528'82 48 12 00 4279 73 4203,g3 4T 58 00 4941 24 4865'24 49 9 O0 5599 15 5523,~5 ~ ~ 27 O0 62~5 53 6209.53 .4S 47 N 0 0 E N 2~ 58 E 97 N ~2 3{) E bi7 N 38 54 E 1384 N 41 37 E 2219 N 31 20 E 30O6 N 24 11 ~ 3742 N 26 4 E 4482 N 23 34 E 5231 N 17 59 E 5942 0 O0 3,3 75 60 47 31 17 41. 92 0,00 2,28 1,81 0,61 0,22 0,66 87 0'54 0'93 §:oo O,OO N 88,37 N 42 08 E 97 525,79 N 324 29 E 6~7 1133,30 N 800 50 E 138~ 1774,71 N 1351 51 £ 223 2415.06 N 1812 41E 3019 3067.35 ~ 2156 38 E 3749 3759.00 N 2445 63 E 4484 4439,72 N 2767 29 E 5231 5123,71N 3013 03 E 5943 0,00 E 0 O0 N 0 0 E 88 N 25 27 g 75 N 31 39 50 N 35 14 g 73 N 37 17 E 49 N 36 53 E 48 N 35 55 N 33 54 N 31 56 96 N 30 27 E 9050,00 6320.39 6244,39 45 47 N 17 59 E 5977,77 0.00 5157,79 N 3024,10 E 5978.96 N 30 23 E ARCO AEASKAv INC, 3H-20 KUpARUK NORTH SLOPE,AhASKA CDMPUTATION DA~: 5-APR-B8 PAGE' 5' DATE OF SURVEYI 19-MAR-88 , KELLY BUSHING EbEVAT[ONI 76.00 ~T ENGINgERI G, SARBER- INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH 'DEG MIN DEG MIN 0 O0 0 O0 -76'00 '0 0 76 O0 76 00 0,~*;~ ,:,~,0~ 7 176 O0 176 OO 10~, :u!'.~:.~ O~ 8 276 O0 276 O0 200~00 '0 6 376 O0 376 O0 300,001 7 6 01 476 O0 400~'00 ~ I 30 76 11 576 O0 500,00 4 3 676 85 676 O0 600~00 :~ ~ 22 778 88 776 OU 700,00 1~ 54 8.82 07 876 O0 800'00 15 47 986 66 976 O0 900,00 18 5 ,o,= ,o oo ,ooo.oo =o 1201 24 1176 O0 1100.00 24 53 1~13 39 1276 O0 1200,00 28 45 1429 05 1376 O0 1300,00 31 26 1547 88 1476 O0 ~400,00 34 25 1672 55 1576 O0 lbO0,O0 38 21 1798 41 1676 OO 1600,00 37 6 1925 28 1776 O0 1700,00 39 31 2057 91 1876 O0 1800,00 42 10 2197 90 1976,00 1900,00 46 15 2347 83 207~,00 2000 00 49 50 2506 30 2176,00 2100:00 51 52 2844 59 2376,00 2300,00 55 8 3022 32 2476,00 2400,(}0 56 17 3202 91 2576,0o 2500,00 56 36 3386 67 2676,0o 2600,00 57 33 3575 46 2776,00 2700,00 58 19 3766 64 2876,0U 2800,00 58 38 3959 30 2976,0o 2900,0o 5a 45 4151 46 307~,0~ 30~0,00 58 14 4336 77 3176 O0 3100,00 54 27 4498 20 3276 O0 3200,00 ~9 59 4653 25 3376 O0 3300,00 49 35 4805 95 3476 OW 3400.00 48 39 4956 73 3576 Ow 3500,00 48 16 5106 59 3676 O0 3600,00 47 59 5255 25 3776 O0 3700,00 47 24 5402 72 3876 O0 3800,00 47 17 VgRT1CAL DOGLEG &ECTION SEVERITY NORTH/SOUTH EAST/WES~ FEET DEG/! O0 E'EET FEET N 0 U L 0.00 N 53 57 E 0,11 N 88 18 E 0.23 1~87 20 g 0 35 N 76 6 E 0:46 N 12 47 g 1,57 N 14 21 E 5,77 h 23 21E 17,33 N 26 29 g 37,37 N 27 12 E 62,68 93 21 128 07 170 36 220 95 278 92 343 O1 417 ~9 4934 570 18 655,66 N 26 57 i N 27 20 E N 27 37 E N 27 57 E N 28 7 E N 29 44 E N 30 30 g N 38 55 g N 43 46 E N 41 25 E N 38 52 E 752 46 k 35 25- E 863 60 N 37 6 E 986 09 N 37 ~4 E 1117 33 N 38 27 g 1257 23 N 38 59 E 1403,00 r~ 4o lO E 1551,88 N 40 35 E 1704,21 N 40 55 E 1862,23 N 41 10 E 2022,94 ~ 4J 32 E 2185 19 a 41 22 E 2346 75 N 37 30 E 2500 88 N 31 44 E 2627 37 N 32 56 E 2745 84 N 32 55 E 2861 21 N 31 45 E 2974 03 N 30 30 E 3085 65 ~ 29 29 E 3195 59 N 28 29 E 3303 87 0,00 0,00 0,00 0.00 0 25 2 03 4 83 5 18 2 15 3 O0 ,20 3.98 3,53 56 3.53 0.82 04 69 2,36 1,01 1,15 1,55 0,74 0,66 0.60 0,88 0,22 0,25 0 3O 1 O3 6 61 1 39 0 97 0 62 0 84 0 65 0 66 0 56 · . RECTANGULAR COORDINATES HORIZ, DEPARTUR~ DI~T, AZIMUTH FEET !DEG 0,00 E 0 09 E 028E 0 49 E 0 69 E 1 12 E 0 O0 N 0 07 N 0 09 a 0 12 N 0 12 N I 16 N 5 47 N 16 59 N 34 80 N 57 41N 2 12 E 609E 14 74 E 26 30 E 0 O0 N 0 OE .0 0 0 0 17 37 63 :N 51 9 E N 71 54 E :N 76 42 E 70. N 80 24 E 8 N 20 9 N 22 57 N 24 36 E 84 69 N 115 153 198 249 305 369 433 490 554 40 21E 83 N 56 28 N 75 29 N 99 45 N 126 71N 157 91N 195 02 N 238 36 m 291 47 N 350 93 75 N 25 23 E 11 E 128 70 N 25 50 E iE 171 g 221 E'279 62 E 343 E 494 07 E 570 04 E 655 77 S 2 E 81 N 26 56 E 96 N 27 16 E 26 N 27 49 E 2O N 28 48 E 24 N 30 41E 72 N 32 15 E 718 817 922 1033 1147 1263 1381 1502 629 29 N 413 18 E 752 81 N 33 17 E 51 N 480 30 E 864 26 N 33 45 g 34 4 g 56 N 553 26 N 633 10 N 720 73 N 812 09 E 987 07 N 38 E 1118 81 N 34 28 g 25 E 1259 39 N 34 52 16 E 1406 02 N 35 17 E I bO N 907 99 E 1556,00 N 35 41 E 02N 1007 91 g 1709.70 N 36 7 "'~ 20 N 1112 56 E 1869.33 .36 1625,09 N 1219,57 E 2031,81 N 36 1748 68 N 1328 40 E 2196,02 S 37 13 E 1871 38 N 1437 34 E 2359 Ob N 37 31E 1990 38 N 1538 10 E 2515 43 N 37 41 ~ 2095 2195 2292 2387 2483 2578 2673 51N 1608 51N 1672 25 N 1735 55 N 1795 12 N 1853 39 N 1908 18 N 1960 63 E 2641 18 E 2759 11 E 2874 52 E 2987 20 E 3098 16 E 3207 72 E 3315 75 N 37 30 E 79 ~ 37 17 E 90 N 37 7 E 36 N 36 56 E 42 N 36 44 g 67 N 36 30 E 16 N 36 15 g 3 ~Z 0£ N q6*SL6G 3 0t'9~0£ 3 8 TE' N ~£*~9~ ~ £L'ET6~ N 6L~LGT~ N ~L 9TOS N flO~616~ N 69 0~9~ 8L6~ N ~6 T~9~ N t~ 006~ N 6L q~L~ N ~L 60L~ N ~0 9G9~ N RO ~09~ ~ TT O~L~ 8609 L66E 3 0T £E NTT 3 L~ t~ N 3 L g£ N L6T9 30L LL09 3 69 996£ 3 £E GSL£ 3 89 69£~ N 96 qE£E N OE 9RE~ N T9 66T~ N ES T69£ OLZ£ £9O£ 3 N L6 L£gE 3 99 GE NT TE'G[' ."4 ££ T90~ N 8 3 6G ~E N O~ ~E 3 6~ ltOZ N ~6 6qL~ 00'0 £6 0 T~L 0 8L 0 OL 0 99 0 £6 0 ~6 T LL 0 DO T T~ 0 EO Z; 9T 0 66 0 Ec.j 0 L.q 0 T9 0 EOt 99 0 cig 0 c_;fl 0 90"6Z~S ~ gE 6t N E~ T609 ~ 6~ ~ N TL 9£6~ N L 9~ N 9L 9S89 3 ET 9~ N 66'£8T~ ~ 9E O~ N 80*ELO~ 3 8T T~ N ~6'096E 3 S~ ~ N L~"8~SE ~ l~ EE N gO'8ELE ~ St ~E q L9 Sb 6E'~SZ9 T~ S~ O0'OOT9 LS 59 O0'O00q TE q~ O0*O06g oo 9LT9 00'9L09 oO'qL6S 8~ 99 00'008S o0'9L89 S6 £T Lt O0'OOL~ O0'9LL5 6E 99 L9 00'009§ OOe9L9S 9~ 8E 8~ O0'OOq§ O0*9L~ ~0 6! 69 00'00~9 O0 9L9S 69 9 O~ O0'OOE§ O0 9L£~ 09 8 69 O0*OOg9 O0 9Lg~ ~L OE L9 O0*OOIS O0 9LTg 6T Ot 89 00'0009 O0 9LO§ ti Og 89 00'006~ O0 qL6~ 96 60t8 ~9~8 ~TT8 ~96L ITSL 6S9L lOlL £SEL tOiL iSOL ZS 8~ O000LT O0~9LL~ £9 oogT O0*qL9~ £8 O09t O0~9LS~ O0 0099 00~9L99 £~ OOf~ O0,9LE9 6I Og 89 O0 T9 89 O0 G¥ 89 O0 6E 89 O0 ~ L9 O0 0069 6~L9 6~9 6~9 998~ 869~ 3~fl&~Vd~O *~HOH g~&VNIOHOOD HY"IflDN¥~D~H D~qDO0 ARCO ALASKA, [NC. 3H-20 KUPARUK NORTH SLOPE,ALASKA C(J~¥iPOTATION DATE: 5-APR-8O · [')ATE OF SURVEY: 19-MAR-88 , KELLY BUSHING E~EVATiON{ ?6,00~FT ENGZNEER{ G, SAR~ER- MARKER TOP KUPARUK C BASE KUPARtJK C TOP KUPARUK A BASE KUPARt!K A PBTD TD INTERPOLATED VALUES FOE CHO6EN HURIZONS ~EASURED DEPTH BEbOk KB 8001.00 8661 O0 8664 O0 8817 O0 8938 O0 9050 O0 SURFACE LOCATION ORIGIh= 1007 FNL, 282 F~L. SEC.. 12. TIRN. RSE,U# TVD RECTANGULAR COORDINATES FROM KB SiJ~-SEA NORTH/SOUXH ~AST/WEST 6049,2~ 6049,22 6051,31 6157,83 6242,29 6320,39 5973,22 5973 22 5975 31 6OB1 83 6166 29 6244 39 4892 81N 4892 81N 4894 86 N 4999 05 N 5081 44 N 5157 79 N 2937 2937 2937 2972 2999 O9 E 8 ~ 4'/ £ $0 £ ARCO ALASKA, IRC, 3H-20 KUPARUK NORTH SLOPEwABASKA CO~PUTA'I'iUN t)ATg: 5-APR'88 DATE OF SURVE¥~ 19-MAR-88 ~, ~ELL¥ BUSHING EbEVATION~ ?b,OO,rT ENGIN~ERI G, SARBER' HARKEN TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD ?D NgA,SUREI) DEPTh 8661.0o 866!.00 86~4,00 8817,00 8938,00 9050,00 AT ORIGIN= 1007 FNL, 282 FWL ~EC. 12. T12N. RSE,U# TVD RECTaNGUlAR COORD][NATE~ FROM KS SUB-SEA NORTH/SOUTH EA~T/~E~T 6049,22 6049,22 6051,3] 6157,83 6242"29 6320,39 5973 22 5973 22 5975 31 6081 83 6166 29 6244 39 4892,81N 2937 489~,81 N 2937 489 ,86 N 2937 4999.05 N 2972 5081,44 N .~999 5157,79 N 024 9 E 78 E 47 E 30 E 10 E .) FINAL WELL LOCATION AT TRUE SUB-SEA ~EASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 9050,00 6320,39 6244,39 HORIZONTAL DEPARTURE DISTANCE AZimUTH FEET DEG 5978,96 N 30 23 ~ L~9~L 'W's'n O;~-HE: · 3N I ' Id),,ISU"]ld 03~U OBO009 B£UO Nna ,l, WINf]O3 09BI_4 993M ANUclW03 ABAWFIS 9UNO 1133W I 0 W3OWBSN~]gH3S HORIZONTAL PROJECTION WELL' 3H-20 (1007' FNL, 282' FWL, SEC 12, T12N, R8E, UM) NORTH '7000 8OOO 4OO0 1000 SOUTH - 1000 -2000 I, IEST REF 726,~? SCALE = ! / 1 O00 I N/FT .... ,:.-?'-f-.t..-:.-].4.++- --::-.--::--±--?p-t,-~?? '4-4'".t-[-" f-?--..'-'-.t--t ...... ?-f'--?--?'-t--t. "t"?? ...... f".?...t....?"t~..?.?...t..?:.-i..+.??..t.4".?:...`::."t.........;...t...t"4"~t"Ht.".+"+" -::::?-',:: :.-b---'-:'"-:-'"":"'"":"'"'" '*'? ?'"-'-' ...... "]'": '' ~ ~ ....... ~"~'" ~'" '"~'4'--~" 4'" ~'.J'"~"-~-'.~-4-".L~' 2"4--' "-~--.~---?i-'-~-f'-~-'4'-'*~'-'~-- --~'4"-;[-'-i--4---i---~'--.~'--~---i .L~...~..-~.-4.--t--i.---i.--~-.-~--..---~---.~'-4---i--4"4-'-~-'-~.---~---. :- -: · .......... · 4..H-4.- .-*.4...H ...... ;...~..,.+..,_,..~._,..~...-+..~.,...,..4_:..4..4..,.....,._:_,_4...~..:._:...~..4 ...... ~..~..,.4 ....... ,...;...~..,,..,-,..~.;...,...-.,..4...,..~_._;..~..,..,. ~..~..~_:..,._...;...,...~...~._L~_.;._~...,_j .....,...~..4..., .¢.4.&-.+ .... ~.4...;-;.4...~..-L.L4... ,.,.H}..-L.~.4.-.&4..&4... ,..~..4-?'."-b': .I--~.4..4'...}.-..~4~.4.4.~4~½.4-;~-.~;~4~-;.~-L~;~.~.~:~4~4.~.L~.~LL;~.~.~- .-L..t...~..4.4..-L.;....L..L. [.±]i]±:~T.. :]~:ijZ~21 -4..+++.-'-i-+-~-?---.-r--r-b..HL-::'~+...-r· .--:.-:-r-:.'-H--'r--T'+-r"--?-r .:-~--M'-}-H-¥4--¢4.-+-4-. 4.--bb.-b-~-4-4-¢-N-4---4-.-H--4.4.4-4-b~ -J..~....i-...;... ,-4-.4..~,...4--. --;....i--g...*.., ..4--.~--*..*- ,,..b.4-4..4-.,[.-.~-.;...;...~ ,..*..4.-..~-~--.~.....~-.~....~.4.....~-4-.:f-.4....[.-..;...~...4..4-..-.-L.-.[-4.--~...4..4-J.-'~ J..- -:- i:'(;H'"(: Z(47':JZ'J"~'JL' !'4f5'~:+" "':'"~"? T',::~J? :T: '~J''+- -.H.-.H-." .~ ]4L..L.~.4...,-.4-4....b.;-~-.,S4..4-.;.- -L4...b4.----;-.-(4]j.- -4...?'.-4...~.--..*-4-.-i..4..--..LN.4... ,.4-4.4...:-b .4-.~4..4... ;.4.4..?"...b ...¢4.4..4.4...:;.4.4- t,.. L¢~..-.,%~.~ ..4..L.L;..' ...~.4.-~.44.a.4-~.4- +/"?"?'"~ .... : :: : : ~* ~ ~::: ::~: ~:~: '~:~,~,~ .... : : ~ ~ , :i ~! "T'T-T-'?- 'TT'T?T'T'T,T"T" '"['T'T"T" ff.-f.4w.:-.-+..t-?t.-- -+.?H--4-H-:*---"+-H'-~ !"*;'5"t'+r'-~'e'f"--H-½' .-++.',,~. · --r~'-r-"..'-' -r..--..,..-t--r.:..-r-fr--:. .... ,'--*..-~--r..- w.?..*'"? -'t'-t-t:-t-'- . .............. -.'.;"T-..,t".,+''''':..''''~''t-''1''t'..''T' .w ~"*:,-T'T'? "'T-Fi ,:-F'"-T.:"?T:"T' i'"i } '~ ~'~'" - '"' .... ,..,,-, ..... ...... ,-.,-,- ..................... 4i.5: 5: -[ ~, ~, ..+.4-.4.-+... --.b.4..4,.4---,-..*--'~--~'---4....--.b.4..-q....i-----*.-4-.-b4..-[.---b-~.-..~..-.i----.~-4-.-:.-~.: .,.~-3--3-~.-~- .....[-.+'...~.'...-4-4"+'4"' 4"4'4"4.:"'"'4"4'4'4'--.~.4..4.-4...b4-.4-4.-H ,.t-H-.+H-.~.-¢H-+-++-j-+--¥~4... +H.H--+:'-t:~+-½---~-f--H~--H--HH+ ~-H- ~4-++-~.4¥+--½H4:- ?:-H+ .-~,~.-L4.I.:. ....... .' .... ;..--,.4-*..~...~ ~ -i-.-~-,.x;,~ ..... .-4-4-4 ............................ ~'-'T: 4..4-~-.-,..4-4...;-. ....... ..4-4...~-...~.:; :_? ~: ' ; :-k ~--~.~-: , · : t : ~ , ~'4'4'-k'£'-4..-g4..~. ~ .i--~-i.- ............ 4.4.-~.4 · ~ L~.4_ .+.i-H .... b444 ...... b-.~4.-.b +H..4- 4..-.:;4.-b-4+44--.H-i-4-47..:.:H- -~.444--.44--4.~-~-+4.-~'-~.. ¢¢.&4-.b ~4-4¢~.- -i.--.:'-4 '-P'?-!--P- ".+-t-++- -k-?fi-'+'- -f .:-i-.+-f'- -i- ..-i~: '±- -i--r-?Y- -..*-~- --~- ?-ih?.*%-..-.~-.-.+ff.'--f..' ~--f: ~:: i::?:±-+:~- ~ ..-i-t-, -f:- +--:;-.!- '~'l-'t-?'"'-i'--P+-'i ....... ;"'?'t'" ..-t..-i-~-~.-'",.:"'t~"~' "'~"~'"t'?--'t.-~t' ~'-f"t"?'7-?-i"~'":'.'v'~-?'-t'~'"~.:'"'f-i-4-~'f :-i-.t-- ~;"~d-?' ~ t :~ "..'~" ! ...... ~"4"'~"- ".-r'-~"'?'-? ....... H'?"'?-'?'"' '"r'~"'?"~.-' -.~'"."'*'"?'" '"-t."-t'?'~.- ".-?'...*-r'-?-- .~-?.-.?.--~- -T--r--?--~.'..*--.?..~-.-,-..?-- ---?--+-q-.' 4...-!---~--~-.-.~--~-- ~-~--r-"-?- --t-q'"+-~'- "'+-f~.'~: .... T'T'r- 'T't""t ..... T"'~'T'? '" -t-.-.r..r--r- W--r"?."T- "-r ~.."?' ..~ "",-rT' .~" t-t..-~P-r ', , -..~ '*-'T-.T'"t?"-, ?"~"T-t-+ ??":* .... ..'-~-..'- --f-?.'-t~t- ~ .... 9-.-r-4.-..-?..4.~ . ...... -? 4..4--*-... .................. .4-4..+.4-..4...;-4-4...--,-4..4..4-.-.~-.~...4-~-..~.~...;,¢..~4- ....... -4--,-4-4---~--r.'.'-r.~.'-.. ?t .-t-t.-.' ' ' "4 .-r?-?m.- .... __-?~.-~.'-+-' ' '.- -.-t'.- .-t-~?' ' '- -~..-~_~...- .... t'~-~ "~t"'+.-4'-- -t"~ .-~.' .... -~+-+- --t..-.~-.+-..-4-r%~-. - -.,..4 :~.'- ..~ -.~:--t~--- --+~:-~ '-.;--~--~'T'~+~ ~-- --~.' .--~.' ' -+.' -: '.~:" '+' .-~-+~-' ....... J"'~"'t"~ "T"y'J'"?'"1 -t'"?"-F'T"" '"?"'t'"T"t,-' "T?'?"?"" "'T"~--r"?- -7'T'-[--t/':'~"~.,"- -T'-t-'t"r'---r-?-"?-'?-'-.~t.-~-~..-t.-t-~.-,~.-t-., -t---t.-t-t.--,-m--r-t--?-- -t-'-?-?-~ .- H-f-F.x --,.T.4-.t-! ~.+.4-+-.--~--~-+-~.---+-¢+4 ..... e+4.-~-.-~-H+~-, - ~1~-.' --4-b4H-.-4:-b~-H .-~..~.'--b .4-+.+ i~ ~ ~ 4 ~ t. ;, .~-..~4- ~ .'-~.'- .... ~.4-4-X .. "~4,.4..4...~ .-L.4-4-;.... -~..-~4-4..- -4..4-4~-L.- -4-.~-4...4- -~-&,~..4....~.4..4-.'~.- -¢-4-;-4 .... ~-4-~.4- -4-4.4-4-4..4-4.-~-.4- ..4-4.4-4- .-4-.4-4..4... ...... I..4-4' ....... i...:.4...~.....J,4..44 ..... ~..4...~..£.-...:'..4-~.....4.4..4...~..4....~.~.4.4..4.4..4 ..... ~-4..~-L....~4...~-4.-...4..&&4..~-4-L.~.4..- 4..44..~-,-4.4.44.- I : I : : I : i i : . : ! : : : ! : : ; . ! ~ : : : : : : ' : : ~ I .....l : 'i'"~'l~""l l'"lL4"': '[ '''i''--' "'$'''i'""i' ....... : i : i'--i--$''--i'--" "'~'''4'"4--4'''''ii:: ~i'~'4''':: · :''--i-- ~'' ;--4--4''''i'--i''l'~'''''b'' ! i : : ' : : : : '"~''4~'i'--'4: ~ [ : ..... ,; : : : ~' "~'' ''''~'--'~'''~'--'~--::::4::;:--']''''~''' i~__,~__., ,.__~..__~..~__~...:::: I i : : : ...~__ '.~..~.__,~,,. __.~...~...~....~__. 1.,.+.,..,.....+4.1., .............. :..-,.-.:..--:..,?.-:--- -..?,--,-?...,.-~.Z-~ .--,~,-.-,-,-.?-?..?--l-:..-.-.:.. ':-bl-,.--,-~? ..-??~.-+~.+.m'- ~-~..+-,-+-,---:--,+---:--?~--:--]:+..:..;-:- "-['"H~+, ..+-4-.4.-+.-....~.-H~..-- -4-.-~- .:-b+- -+-~--~--}.-.-f.~-4,~:~ ~--'.-b-Hr--f---+-F+-+'~'-[-++H .-*.. q---t.'--+--[-H--4-f'-. ~'--H-~;-[-+--H--H l-t-t-+i.-~ .-t..+-+...t ...... +.+++...-,.~-..-[~.~--,b- --.~---+.-',.~-.~--., '--'~l~.l"~." .'~ '"'--~.~T~.l-"~~ "."~--~ '~"~--l--'+"--~,~'t"m.'"'~'~.'-"["'"t'-~,'--~~.l_ .~...~.~...._~...~...~.,?l....[ ..... .F.4_[_+..j_+...i_H.H. ~_.l~...,,~,,..,.~,.,,~,:.~,...,~,,.,~.,.. 1,~l ' : ' ' .[ i i ~, ~ i i [ [ I i ] i i i i i : i i i i i i ~ i i ~ [ i ~ i I ~ i i i i i i [ ~ [ [ [ [ :: i [ [ i i i i i -',4-~4.....4.4-bb.-~..i..~-.~ ...... 1.4.4.4~ ~-~..~ ~: 44-~- ! i, ! ~ ~.4 .... ~-.~..,~44-~.-b..4-N.4.4-¢4..4.4..--4..4-~-¢44-~-¢4--4.4.4.4-i.¥..b¢4- "-"?'.i~ <" "--u'~"':tlll ....... '"':1-'~'4'"' "J'"'~"'~'"~'-- "~"i ! ~ ! : ~ ~. ~- -4--~-4-4- ~ il it tt~ ! ! T-~! i~ :4-4- . ~.4-4.-&.. ii i i ~--4- ~--L . .- 4--~, ! ! i i i ~-4~].~ ~! J, 4 -~--~ 41 !i~ ~ ~ ~-4-~.i i .~-~, J, 4- ! ! i i~ -F-.,:...~..~_ ......... -1. ........... .~...4..-li -*~...~-4--.L... ..... ...*.--4.-..~..o+i ....... .~ -.~-~. --4--.~4--~ I I : -~I-- :Ti ~ i-~-.~--..~ -..,-~-i--~...~ ~ i i '"-~-~'"'~"'~'-'~ i i ...................... ..~b-$..4..4-...4-.-i.-..b4-...4..~i..4-;...~..4...~.-~....~... --$...~....i..4...... -i.-4-..I..-.ii~ : .... -.-H.4..~ .-4--+-4.-~-.-.~-4..4-~ ....... i..4--.~- '4- y-.~--.~44---~ ~-~- ~-~-~4-¢+..-+4-+-~.-.4-H~4-.4-.~-4..4-4--.-4--4--4-4-4-.4-4.4..+.- -H..~-i..! ............ ~i~ :::: ........ 't ?::::+..~:::.;::.:-..,::?.:..::~-,..~-.:..-..-.....:>,::_; .~...; ..................... H+H-:~H--4-.-4-4-i-4--'-.-!.+H .... '"' ~" ...... · ......... ...... :x::x:: ::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::: ,,, 'TH'T'i T+?-!'"'"T-Fr,- ,.-- -wt-. r~ .... t'"?:"~-t'T',"--t:.'"t-..+--?''t'!'~-T''t''t'''t''',.*'''' '-'t-P't:-tTt-i'-t'? - 1000 0 1000 2000 :3000 4000 ~000 6013[:1 E~T 'W'£ L L · 3H- 20 (1007' FNL, 282' FWL, SEC 12, T12N, R8E, UM) .. VERTICAL PROJECTION - 1000 0 0 1000 2000 9000. 4000 SO00 6000 7000 PROJECTION ON VERTICAL PLANE 92. - 212. SCALEO IN VERTICAL OEP'TI-IS HORIZ SCALE = 1/1000 IN/FT ~ STATE OF ALASKA · ALAS_ ,~ OIL AND GAS CONSERVATION COM",/"~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: 2. Name of Operator ARCO Alaska, Inc. Operation shutdown [] Stimulate [] Plugging [] Alter Casing [] Other C)[ COMPLETE 3. AddreSs P.0. Box 100360, Anchorage, AK 4. Location of well at surface 99510-0360 1007' FNL, 282' FWL, Sec.12, T12N, R8E, UM At top of productive interval 1394' FNL, 2061' FEL, Sec. 1, T12N, RSE, UM At effective depth 1206' FNL, 1999' FEL, Sec. 1, T12N, R8E, UM At total depth 1129' FNL, 1974' FEL, Sec. 1, T12N, R8E, UN 9050'MD 6320'TVD 11. Present well condition summary Total depth: measured true vertical Effective depth: measured 8938 'MD true vertiCal 6242 'TVD Casing Length Size Conductor 80 ' 16" Surface 4057 ' 9-5/8" Producti on 8987 ' 7" Perforation depth: measured feet feet feet feet Perforate ~ Pull tubing [] 5. Datum elevation (DF or KB) RKB 76' 6. Unit or Property name Kuparuk River Unit 7. Well number 3H-20 8. Approval number 8-88 9. APl number 50-- 103-20093 10. i~uOpOalruk Ri ver Oi 1 Pool Plugs (measured) Plug f/1692' - 2000' w/800 sx AS 1 cmt Plug f/4266' - 4537' w/200 sx Class G Junk (measured) None Cemented 250 sx AS I 1340 sx AS III & 400 sx Class G Top job w/36 Sx AS I 700 sx Class G & 175 sx AS I Feet Measured depth True Vertical depth 115 'MD 115 'TVD 4092 'MD 3045'TVD :~' 9020'MD 6300'TVD 8760'- 8780'MD true' vertical 6118' - 6132' TVD Tubing (size, grade and measured depth) 2-7/8", J-55 tbg w/tail @ 8559' 12. Packers and SSSV (type and measured depth) HRP1-SP pkr (~ 8484' & TRDP - 1A-55A 555V (~ 1788' 'Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description inCluding volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 14. Attachments (Compl. Well History) Daily Report of Well Operations (~ Copies of Logs and Surveys Run ~ Tubing Pressure 15. I hereby certify th~i~ the foregoing is true and correct to the best of my knowledge Signed . ~ Title Ass~c~ _~te Form 10-404 Rev. 12-1-85 (~ (Dani) 5W03/77 Date 5-2~'-~ Submit in Duplicate Gyro ARCO Oil and Gas Company Well History - Initial Report- Dally Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations -,re started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ~ ~. ]County, parish or borough ARco Alaska, In~:.-'-- I NORTH SLOPE Field Lease or Unit KUPARUK RIVER FIELD ADL: 25531 Auth or W.O. no. ITitle AK2637 J COMP LET ION 3H-20 IWell no. Operator ARCO API: ~ Spudded or W.O. begun IDate ACCEPT I 05/01/88 Date and depth as of 8:00 a.m. 05/01/88 ( TD: PB: 8938 SUPV:DL 05/02/88 ( TD: ~B: 8938 SUPV:DL Complete record for each day reported NORDIC ! IHour IARCO W.I, 56.0000 Prior status if a W,O. 0415 HRS NU BOPE 7"@ 9020' MW:10.0 NACL/BR MOVE RIG F/ 2H-21 TO 3H-20. ACCEPT RIG AT 0415 HRS 5/1/88. ND TREE. NU BOPE. CHANGE RAMS TO 2-7/8". DAILY:S44,541 CUM:$1,272,~08 ETD:S1,272,308 EFC:$1,414,000 TEST SSSV 7"@ 9020' MW=10.0 NACL/BR SET TEST PLUG. TEST BOPE TO 3000 PSI. PULL TEST PLUG. ND BOPE. REPAIR HEAD. NU BOPE AND TEST TO 3000 PSI. PERF "A" SAND F/ 8760' TO 8780'. RIH W/ 2-7/8" COMP EQUIPMENT. LOST CONTROL LINE PRESS ON TIH. POOH TO SSSV. FOUND HOLE TO CL 4 JTS ABOVE SSSV. REPLACE CONTROL LINE AND RIH. MU HANGER. TEST CONTROL LINE TO 5000 PSI. LAND TBG. SET PKR AT 2500 PSI. TEST TBG AND ANNULUS TO 2500 PSI. SSSV @ 1788', PKR @ 8484', TAIL @ 8559' DAILY:S136,898 CUM:$1,409,206 ETD:S1,409,206 EFC:$1,414,000 The above is correct For form prepi~f'~lon and distribution, see Procedure~.~lanual, Section 10, Drilling, Pages"86 and 87. IDate ITitle ARCO Oil and was Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well ia Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovera when an official test Is not required upon completion, report completion and representative test data In blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available, District ICounty or Parish NORTH ST.OPE Lease or Unit ADL: 25531 Title COMPLETION IAccounting StatL cost center code 3~,CO Alaska, Inc. Field KUPARUK RIVER FI~-LD Auth. or W.O. no. ~2 637 Operator ARCO Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m. 05/03/88 TD: PB: 8938 SUPV:DL 3H-20 IWell no. .,5o - IO3,- ?.ooq5 AP1: .~,, I A.R.Co. W.{. ITotal number of wells (active or inactive)on this, I Icost center prior to plugging and I Date 56. 0000 labandonment of this well 05/01/88 / 0415 HRS . Complete record for each day reported NORDIC RIG RELEASED 7"@ 9020' ~: 6.9 DIESEL TEST SSSV TO 1500 PSI. SET BPV. ND BOPE. NU TREE AND TEST TO 5000 PSI. DISPLACE WELL W/ DIESEL. TEST CV TO 1000 PSI. SET BPV. SECURE WELL. RELEASE RIG AT 1200 HRS, 05/02/88. DAILY:S12,365 CUM:$1,421,571 ETD:S1,421,571 EFC:$1,414,000 Old TD New TD Released rig Date Classifications (oil, gas, etc.) Producing method Potential test data IPB Depth Kind of rig IType completion (single, dual, etc.) Official reservoir name(s) Well no. Date Reservoir Producing Interval Oil or gas Test time Production OII on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form prepar~ion and distribution, see Proceduresqglanual, Section 10, Drilling, Pages 86 and 87. ASSO(~TE ENI31NEER ARCO Alaska, Inc.- Date: RETURN TO: March 28, 1988 ARCO Alaska, Inc. Attn: Sabrina A. McKnuckles Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #: 7131 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 H- 1 9 Cement Evaluation Log 3 - 1 8 - 8 8 6 6 0 0- 8 5 0 6 Cement Bond- Log 3 - 1 8 - 8 8 41 0 0 - 8 9 0 4 .. Receipt Acknowledged' DISTRIBUTION; NSK Drilling ~sta~t~ ~)-f AlaSka(+Sepia~ STATE OF ALASKA ALASK,, OIL AND GAS CONSERVATION COMM,_SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown~ Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator 5. ARCO Alaska, Inco R 3. Address 6. P. 0.. Box 100360, Anchorage, AK 99510-0360 K 4. Location of well at surface 7. 1007' FNL, 282' FWL, 5ec.12, T12N, R8E, UM 3 Datum elevation (DF or KB) KB 76' Unit or Property name uparuk River Unit Well number H-20 At top of productive interval 132-0' FNL, 1950' FEL, Sec. 1, T12N, R8E, UM (approx) At effective depth 1199' FNL, 2022' FEL, Seco 1, T12N, R8E, UM (approx) At total depth 1123' FNL, 1999' FEL, Sec. 1, T12N, R8E, UM (approx) 8. Permit number 87-1 .~4 9. APl number 50-- 02~)-21775 10. 'Pool Kuparuk River 0il Pool 11. Present well condition summary Total depth: measured true vertical 9050 ' MD feet 6331 ' TVD feet Effective depth: measured 8938 ' ND feet true vertical 6252 ' TVD feet Casing Length Size Conductor 80' 16" Surface 4057' 9-5/8" Production 8987' 7" Plugs(measured) Plug f/1692'-2000' w/800 sx AS I cmt Plug f/4266'-4537' w/200 sx Class C Junk(measured) None feet Cemented Measured depth True Vertical depth 115'MD ll5'TVD 4092'MD 3055'TVD 9020'MD 6310'TVD Perforation depth: measured None true vertical None ~bing(size, grade and measured depth) None Packers and SSSV(type and measured depth) None Gas Cons. commission Anchorage 12.Attachments Well Hi story 250 sx AS I 1340 sx AS III & 400 sx Class G Top job w/36 sx AS 700 sx Class G Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation Narch, 1988 14. If proposal was verbally approved ~.~~ Date approved Name of approver 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed .~ ~ .~_c~.~j_~ Title Ass cc ia te Engineer Commission Use Only (Dani) 5A3/57 Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI ORIGINAL SIGNED BY LONNIE C. SMITH Approved Copy Returnea Approved by Date Commissioner Form 10-403 Rev 12-1-85 by order of ,~__ ,~...~ the commission Date Submit in triplicate ARCO Oil and Gas Company InEtrucflonl Prepare and .Submit the .initial Reporr. on the We _ ARCO Alaska Auth. or W.O, no. - .... -'~L v~R FIELD AK2637 Spudd~ SPUD _ ' DOYoN 14 01/10/88 I 01/11/88 0Z/12/88 ( ) D~ ' su~v:~/~ 01/13/88 TD: 3960, SUPV : jp 01/14/88 ( TD: 1735,( SUPV:RcB 553L___~RiLL 1 ~21775 I t · ' SHORT TRIp TO 1103'. CIRCULATE POOH. RU AND RUN 103 BTC CASING W/ FS AT 4092, DAILY:s43,760 · CIRC AND COND MUD . CUM:$352,631 ETD- ~ "'---"---~._~ --.$352 631 E-- - ..... anua~ ....... - - ~ ' Associate Engineer 01/15/88 ( 6 CUM: $262,886 ETD:S262,88 TD: 3333,( 15j DRILLING 6 EFC.$1 4 ' , ~, U ' 1, ~ . SUPV:RCB / POOH, UNPLUGGED B ..... 2334' POO" ~ ~z'. RIH & NAVI D .... ~w: 9.0 VIS: 55 - DAZLy:$~5 985 01/16/88 -( 7~ ' C~H:~308,871 gTD:$308,871 gPC:$1,414,000 C~RCULATZNG 412~,( ~1) DRLD 12-1/~,. HOL~ ~/ 3333, TO 412~ 9.2 V~S: 57 PV:RcB - 9-5/8,,~ ~092' woc. ~I~ TO :Z3~0, ~ MW &_ DRILLED CEMEN ..,, . D_ WASHED TO 162 , :_ 8.9 VIS: 61 DP CH--" T ~v 1647' C-- 2 . ~;OC RI" - · ANGED OUT ~,.- ' ~aCULATE ~ .... ' n TO 1622, ORIENT & r~.- ~a. RIH TO 16 , '~*~'QMS UP. POH . DAZ~g:$43' ~68 uRZ~D 12-1/4- · 0 2735, CONDITIONED HOLE. 2965'. POO SHORT TRIp T , H. CHANGED BHA TI~ 1500-. UNABLE TO GET PAST CONTINUED DR ....... ' .WITH NO PROBLEMs. NO FILL. ~N~ 12-1/4, HOLE TO 3486,. DAILY:s70'847 CUM:$139,052 ETD:S139,052 EFC:$1 414,000 WAITING ON CEMENT , DRILLED 12-1/4, HOLE TO 3960'. CIRC. &MW 9 3 VIS 78 TRIp TO HWDp. TIH. : ' : 2195'. MWD V~ .... TIGHT @ 1985' ..... COND. MUD. OPEN ENDED TO 2000,. CIRC. & COND. ~' POH. "~ IN OLD HOL" SPOTTED BALANCED PLUG F/1500,_2000' W/800 SX AS I. ~D. RU DOWELL & 8 STUDS' CIRC. OUT CMT. FINISHED POH. WOC. DAILy: $80,666 PULLED CUM:$219'718 ETD:S219,718 EFC:$1,414,000 KICKING OFF 8 1692, MW: 0.0 VIS: MOvED RIG F/3H-13 TO 3H-20. NU 20- DivERTER' ACCEPTED RIG STEAM AND STRAp BHA. CUM: $23,000 ETD:S23,000 EFC: $1,414,000 MU BHA. TEST DIVERTER SYST MW: 9.3 DRILLED 12-1/4- HOLE TO ao~fM' SPUDDED @ 08,^ . '~' 73 2195,. CIRC. AND DR .... ~_o~ . NAVI-DRILLE uu HR_S, 1/10/88. '~r~'""D SURVEy --- D 12-1/4- HOLE CUM:$68,205' · ~'oOH TO CHANGE B/fA. ETD :$68,205 EFC:$1,414,000 CHANGED , ? To 89o . WASHED , 92 DRILLED 12-1/4 HOLE' ' : : SHOWED WE HAD _ TO 2976,. SI _AMED TO 2195, LOW-SIDED HOL- - DETRACKED @ 18~' · ~ ~ 1890,. CIRCULATE ;u . SURVEy ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not Jess frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish I State NORTH SLOPE AK Lease or Unit 1Well no. I ADL: 25531 3M-20 Field ARCO Alaska, Inc. KUPARUK RIVER FIELD Date and depth as of 8:00 a.m. 01/17/88 ( TD: 4134'( SUPV:RCB 01/18/88 ( TD: 4535'( SUPV:RCB 01/19/88 ( TD: 4092'( SUPV:RCB 01/20/88 ( TD: 4532'( SUPV:RCB 01/21/88 ( TD: 5580'( SUPV:JP 01/22/88 ( TD: 7575'( SUPV:JP Complete record for each day while drilling or workover n progress DOYON 14 8) 10) 9) 0) 0) 0) 1) 440) 2) ~048) .3) .995) MU BMA 9-5/8"@ 4092' MW: 8.5 VIS: 33 CIRCULATE. CMT 9-5/8" CSG W/ 1340 SX AS III AND 400 SX CLASS G. PERFORMED TOP JOB W/ 36 SX AS I. ND DIVERTER. INSTALL AND MU BRADEN MEAD. NU BOPE. RU TO TEST AND SHEAR LOCKDOWN SCREWS. ND BO?E. REPLACE LOCKDOWN SCREWS. NU BOPE AND TEST. MU BHA AND BIT #3 & RIH. ATTEMPT TO FISH JUNK. DRILL F/C, F/S & CEMENT AND 10' OF NEW HOLE. TEST FORMATION TO 12.5# EMW. CMNG OUT MUD. POOM. MU NEW BMA. DAILY:S190,212 CUM:$542,843 ETD:S542,843 EFC:$1,414,000 MU BHA 9-5/8"@ 4092' MW: 8.7 VIS: 34 MU BIT # 4 AND RIH. DRLD 8-1/2" HOLE F/4134' TO 4534'. POOH TO CHECK TURBINE. LD BIT, BHA. MU ROTARY BMA. RIM AND DRLD 8-1/2" HOLE F/ 4543' TO 4535'. POOH W/BIT #3 (LOST CONES). LD BHA AND PREPARE TO RIM SLICK. WO TRISTATE TOOLS. RIM W/ GLOBE BASKET AND WASH TO BTM. DAILY:S56,035 CUM:$598,878 ETD:S598,878 EFC:$1,414,000 WAITING ON CEMENT 9-5/8"@ 4092' MW: 8.7 VIS: 35 WASH W/ GLOBE BASKET TO 4535' RIG SERVICE. MILL ON JUNK. POOH. RIH W/ DP AND WO DOWELL. RU DOWELL AND MIX AND PUMP 40 BBLS. OF CLASS G CEMENT. POOH 9 STANDS. CIRC. LD 41 JTS OF DP. MU BMA AND RIH TO 3500 PSI. CUT DRILL LINE. CIRC. WOC. WASH CEMENT TO 4183' (NOT HARD). POOM TO SMOE AND WOC. DAILY:S98,681 CUM:$697,559 ETD:S697,'559 EFC:$1,414,000 DRLG 8-1/2" MOLE AT 4532' 9-5/8"@ 4092' MW: 8.5 VIS: 30 WOC. RIM AND WASM CEMENT F/ 4185' TO 4260'. PU 45' OFF BTM AND WOC. DRESS CEMENT TO 4266' - PUMP SWEEP. CIRC. POOH AND MU BHA. RIH. ORIENT AND DRILL 8-1/2" HOLE F/ 4266' TO 4455'. POOH. LD BHA AND MU BHA AND BIT. RIH. DRLD 8-1/2" HOLE F/ 4455' TO 4532'. DAILY:S44,326 CUM:$741,885 ETD:S741,885 EFC:$1,414,000 DRLG 8-1/2" HOLE AT 5580' 9-5/8"@ 4092' MW: 9.0 VIS: 36 DRLD 8-1/2" HOLE TO 4786' POOH TO CHANGE BHA. MU TURBINE AND RIM. TIGHT AT 4556'. BIT PLUG. POOH. UNPLUG BIT. TIM. WASH 3 JTS TO BOTTOM. DRLG F/ 4786' TO 5580'. DAILY:S65,549 CUM:$807,434 ETD:S807,434 EFC:$1,414,000 DRILLING AT 7575' 9-5/8"@ 4092' MW: 9.2 VIS: 35 DRLD 8-1/2" HOLE TO 5894'. SHORT TRIP TO CASING SHOE. DRLG F/ 5894' TO 7575' DAILY:S42,894 CUM:$850,328 ETD:S850,328 EFC:$1,414,000 The above is correct For form preparation and clistFf'~ution see Procedures Manual Secti~b~ 10, Drilling, Pages 86 and 87 %./ Associate Engineer ARCO Oil and Gas Company Daily Well History--interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish . ARCO Alaska, Inc. I NORTH SLOPE Field I Lease or Unit KUPARUK RIVER FIELD I ADL: 25531 Date and depth Complete record for each day while drilling or workover in progress as of 8:00 a.m. DOYON 14 IState AK 3H-20 IWell no, 0i/23/88 ( ) TD: 9010' ( 35) SUPV: JP 01/24/88 ( ~) TD: 9050' ( 40) SUPV:JP 01/25/88 ( TD: 9050'( SUPV:JP o) PREP FOR LOGS 9-5/8"@ 4092' MW: 9.9 VIS: 38 TURBODRILL 8-1/2" HOLE T© 9010'. CBU. SHORT TRIP TO CASING SHOE. DAILY:S50,591 CUM:$900,919 ETD:S900,919 EFC:$1,414,000 POOH LDDP 9-5/8"@ 4092' MW:10.0 VIS: 41 CIRCULATE HOLE CLEAN. RUN OH LOGS. DIL/SP/SFL FROM 9010'-4092'; FDC/CNL FROM 9010'-8450', 4850'-4400'; CAL FROM 4010'-4092'; GR FROM 9010'-SURFACE. DRILL 8-1/2" HOLE TO 9050'. DAILY:S105,038 CUM:$1,005,957 ETD:S1,005,957 EFC:$1,414,000 NU TUBING HEAD 7"@ 9020' MW:10.0 BRINE POOH LDDP. RUN 229 JTS OF 7" 26# J-55 BTC CASING. ~S @ 9020', FC @ 8938'. CEMENT WITH 500 SX 12.0 PPG POZ 50/50 LEAD. FOLLOWED BY 200 SX 15.8 PPG CLASS 'G' TAIL. CIP @ 1215 HR,. 1/25/88. INSTALL PACKOFF AND TUBING HEAD WITH SEAL ASSEMBLY. DAILY:S216,810 CUM:$1,222,767 ETD:S1,222,767 EFC:$1,414,000 The above is correct Signature // For form preparat'o J~g/rib ' see Procedures Manual SelCt~on 10, Drilling, Pages 86 and 87 '~/ IDate ]Title Associate Engineer ARCO Oil and GaS Company .~' Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" o1: the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test ie not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ARCO AlaSka, Inc. Field KUPARUK RIVER FIELD Auth. or W.O. no. AK2637 ICounty or Parish NORTH SLOPE Lease or Unit ADL: 25531 Title DRILL IAccounting cost center code State AK I well no. 3H-20 50-029-21775 Operator I A.R.Co. W.I. ARCO I 56. 0000 Spudded or W.O. begun I Date SPUD I 01/10/88 Date and depth Complete record for each day reported as of 8:00 a.m. DOYON 1~, 0) 01/26/88 TD: 9050' SUPV: JP Old TD New TD Released rig Date Iotal number of wells (active or inactive) on thisI ost center prior to plugging and I bandonment of this well our I Prior status if a W.O. I 0800 RIG RELEASED 7"@ 9020' MW 10.0 BRINE TEST FLANGE TO 3000 PSI. CHANGE OUT CASING HEAD VALVE AND INJECT 60 BBLS OF DIESEL. RELEASE RIG @ 0700 HRS 1/25/88. DAILY:S5,000 CUM:$1,227,767 ETD:S1,227,767 EFC:$1,414,000 IPB Depth Kind of rig Classifications (oil, gas, etc.) IType completion (single, dual, etc.) Official reservoir ~ame(s) Producing method Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature ~l~l~()~/ r~'~ ./_[.~'~'~__.'' IDate For form preparation/and distribution, see Procedures Ma~tj~al, Section 10, Drilling, Pages 86 and 87. I Title AssociateEngineer AuedmO~pla!lq3!U3!iuell~ to AJefp!sqns e s! *3Ul 'eHselv 03UV ~a~UT==ao9 uuK~ :pa~palaou~ov AV~ S~ MNI&NMIVA A&~VH £8~g~# 88-I[-I ~UT=ST] pue adei alOH uado MuT~sT% pu~ ad~i alOH uado · i~TmSUSa~ sTq~ ~o KdoD psuMls auo uan~aa pu~ ~dTaoaa a~paiaou~o~ ase~I& .small ~UTaOIiO~ aq~ aa~ q~a~aaq p~Tmsuea& 09£0-0Ig66 )IV ,a~aoqouv 09[00I xog 'O'd 6III-O&V ~aaI9 spaooa~ ~na~dn~ :u~v · ~uI '~s~Iv ODMV : OT. 680£ :# IV~Tmsu~& S[~[ 9/.Z/.06 euoqdalel 09gO-OLS66 e)iselv 'efieJoqouv 09gO0[ xo8 ao!JlO lSOd ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: January 28, 1988 Transmittal # 7074 RETURN TO: ARCO Alaska, Inc. Attn: 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. Cyberlook ~ 2" & 5" Porosity FDC 5" Dual Induction 2" & 5" Raw Data FDC 2" Dual Induction 1-23-88 8450-8900 1-23-88 4400-8983 1-23-88 1000-9009 1-23-88 4400-8983 1-23-88 1000-9009 Receipt Acknowledged: DISTRIBUTION: Alaska 0ii & Gas Cons. Commission Anchorage Date: NSK Drilling Franzen D & M Lucille Johnston(vendor package) ARCO Alaska, Inc. is a Subsidiary of AtianticRichfieldCompany :. $~A'iT,' Dr ALASKA ' ":: -AL_ AS~ o!~-~ CAS-C~S.~!iVA~OH ¢O~ISS]OSl ' : . - · .- , 1' ' ;~ ' ' ~ Ir f' ~' - ' . -' ~7----~. Locat~_- bec ~=l_ ' ;.~~ - '- ~ .- ,-.'- - · '. ~ .. ~'7_ "~ ' ;f ' "*~'"'* Re~*~e'senta' ire' - ' '- ? . ' :" -" '- "*.' "'."- ~ .Reserve.~.j~. ~ -.. _ '. .,..,, -~ ~ _ . ~ ,~ · ;..- ':-- ..[l.-.m;-' . '-~- ' ...... - ......'-- .':. Ptt:~auge :~._--' 1~ ~._. '- -: -..'- : '-,-. ~7 - '~'[1' z-.::' "7 - ~ '-'- '.:'-' - Ya~ ~. ' ' ,' ' '- --,.:~" -' '-:' .- ~' '-"~'"" -" ' -' ' " ' '- ~ ' - - ' -':~0~ ' ' "~'~' '. ,' t- ~,-. '. -' ':g~--~ -~¢ . ~~?'est ~.~-~-~ [t'~P"~-~~-..~':' ~ ~ ~m - - --:-- ' '" ' .... ' ........ ~ - ~ ...... ': '. -..:. ? .: . . :., . ' . · - -. . .~ - .'~, . ,.. . .,.'.:' ,...,. ~ - .'~..~ ..,~ :....' :~.. ~:.,', .~ .'.:. _ _ . - . _ . . . :~:~~'.~~ · _ _ . :...,/~~.:~ _..--.:..-..-. ~. ' s.l~. · ~ O-r.~.-, - ..... ·' ---~~a"~ ~'~ ~~rs"-. ...... "'..'.~,:-.' t .... --" ' . ~ '. o. -':' - .(:. e.. "-:-'." ' :: ~ -' " ff!-ce'~OCtfi~- - ... "-'-"" ':' '?:';-:. '~-' · ~on o . . . .., .,- ,- , ., .... - ........... C~ . . · _ .. .. _ ,. . ..... . :. : .. · · -- .....er. - '..~. .......: , ..~ . ~.swa-~. - :-~ __ . . _ .: _. ~ .. _~~,,~..~..-,- ~"'-',~'::.-". . .'.' " .- ' -' '.- .-.':" :. .,':.'~ ,-:.:'. a. . ~J-::..- :.: ~ .'~ · - ~'' ' " . . "' '-" ~:=~ ~ .~ . ."- ~:~. - ~ ~':" _. ~ ~ ......... ~.:.. ' -- . ' . - KJLRIIPll ...... ' . .~; ,-._ --"--~~ .... _ _- -'SD~Eor ~'~ ~'~'~- ,~ : - ~upe , ,, . . · ' .,. . _~_.:-,.. ..,:. January 19, 1988 TELECOPY NO.. (907) 276-7542 Mr. Jeffery B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O.' Box 100360 Anchorage, AK 99510-0360 Re: Correction of A.P..I, Numbers for KuparUk River Unit Wells 3H-11, 3H-14, and 3H-20 Dear Mr. Kewin.. An error was made in the assignment by the Commission of A.P.I, numbers for K.R.U. wells 3H-11, 3H-14 and 3H-20. The erroneous · assignments were based on the bottom hole locations of these wells. They should have been based on the surface locations.' Accordingly, the A.P.I, numbers for these wells have been corrected by the Commission as follows: KRU 3H-11 (Permit No. 87-124) API number erroneously assigned as 029-21771 has been corrected to 103-20091. KRU 3H-14 (Permit No. 87-123) API Number erroneously assigned as 029-21770 has been corrected to 103'20092. KRU 'Permit No. 87-134) API N%,mber erroneously assigned as 029- has been corrected to~ Petroleum Information has been notified and the Tuesday repOrt of the Commission Will list the corrections. For your reference, I. am enclosing corrected copies of the Commission's permits to drill (10-401) for these wells. Accordingly, please correct your records. Please telephone me at (907) 279-1433 if you need further infor- mation. Sincerely, ~ W; W. Barnwell Commissioner dlf: 1. WWB. 22 ~ Attachment · ARCO Alaska, In~, Post Office box 100360 Anchorage, Alaska ~9510-0360 Telephone 907 276 1215 January 15, 1988 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 'SUBJECT: Conductor As-Built Location Plat (Wells 1-22) Dear Mr. Chatterton: Enclosed is an as-built location plat for any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG:pk GRU1/86 Enclosure the 3H Pad subject wel 1 s. If you have JAr~ 1 9 Alaska 0il & Gas Cons. C0mmissi0r/ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlantlcRichfleldCompany VICINITY MAP SCALE 1"8 2MILES ALL WELLS LOCATED IN SEC. 12, T. 12 N., R.8 E., UMIAT MERIDIAN. I. ALL COORDINATES ARE A.S.P., ZONE 4. 2. ALL DISTANCES SHOWN ARE TRUE. 3. ELEVATIONS ARE B.P.M.S.L. 4. REFER. FIELD BOOK L-87-19, 35-441 L-87-11, 29-32. i 5. O.G. ELEVATIONS FROM CED-RIXX- 3471Z~. 6. HORIZONTAL POSITION BASEDON 3H CONTROL MONUMENTS PER LOUNSSURYS~ Assoc. ASPs 'X' 6,000,110.73 6,000,135.5 ! 6,000, 160.57 6,000, 185.28 6,000,210.66 6,000, 235. 50 6, 000, 260.34 6,000, 285.82 6,000,310.30 6,000, $ 35.43 6,000,42 5.37 6, 000,450.51 6,000,475.46 6,000, 500.41 6,000, 525.44 6,000, 550.46 6,000,575.45 6,000,600.44 6,000,625.20 6,000,650.45 6,000,675.40 6,000,700.42 498,655.44 498,655.43 498,655.39 498,655.43 498,655.47 498,655.40 498,655.41 498,655.44 498,655.45 498,655.44 4 98,655.44 498,655.:38 498,655.42 498,655.43 498,655.41 498, 655.47 498,655. 55 498,655.59 498,655.52 4 98,655.49 LATITUDE 70 ° 24 '41.531" 70 ° 24' 41. ?75" 70 ° 24' 42.022", 70 ° 24: 70 ° 24 42.514' 70o 24: 70° 24 43.003 700 z~' 70° 24' 43.494 70o24'43.741'' 70o 24'44.626" 70o24'44.875"! 70024. 45.119" 7o~_24: 70°24 45.610 70024'45.856'' 70°24'46. IOZ" 70024'46.$48" 70o24'46.592'' 70o24'46.84~' 498,655.65 70°24'47.085" LONGITUDE 150° 00' 39.416" I$0°00' 39.417' 150° 00~ 39.418" 15 0° 00, 39.417" ~5o° oo 3e.~s" 15oo oo; 50° O0 39.418 150° 00' 39.417" 150° 00', 39.417" 150°00 39.417" 150o00' 39.418'' 150o 00'39.4;~' 150° 00'39.419" 50° O0 39.419r' 150000. 39.417" ! 50°00' 39.415" 150o00'39.414" 150o00'39.417.' 150o00'39.416" 15 0°00 498,655.75 70°24'47.3:31" 150°00'39.410'' Disf F.N.L. 154 6' 1522' 149 7,' 1472, 1446 1422', 1397 1 322 1232' 1207' 1182' 1107' 1082' 1057' 1032' I007' 982' 957' Dist KW.[.. 281' 281' 281' 281' 281' 281: 281 281' 281', 281 261' 281' 281' 26~', 281 281' 282' 262' 282' 282' 282' 282' 0.(~. Elev. 34.0' 34.0' 33.9: 33.8, 33.7 33,7: 33.6 33.61 $3.6, 33.6 33.7' 33.8' 33.8' 33.8', 33.8 33.8' 33.8' 33.8' 33.9' $3.9' $3.9' Pod Elev. 38.8' 38.8' 38. 7° 38.7' 38.8' 38.e; 38.9 36.7', 38.6, 38.6 38.7' 38.8' 38.8' 38.7~ 36.7 36,7' 36.8' 38.9' 38.7' 3,8.7' 38.6' 38.6' f IHEREBY CERTIFY THAT lAM PROPERLY IARCO Alaska Inc. REGISTERED AND LICENCED TO PRAC- L TICE LAND SURVEYING IN THE [I "'~E['~'1~ STATE OF ALASKA AND THAT THIS **o-,. Il- PLAT REPRESENTS A LOCATION ~ L MY SUPERVISION, AND THAT ALL ~ ~ ,r~ .. ,...,,......, . WEL CONDUCTOR AS-BUiLT DIMENSIONS AND OTHER DETAILS ~ ~ - 3' : ~N W. ;An~ ~ - - .. . ' - LOUNSBURY& Associates ,~ eOeoeeeeee OWN BY: PJW - CH~BY: JWT ,Ev. CO,D. ,- ,-ce [ REV.~ ADD C0ND. 20~21~22. 7'30-87 -December 23, I987 Mr. J. B. Kewin Regional Drilling Engineer AR~O Alaska, Inc. P' O. Box 1'00360 Anchorage. Alaska 995.10-0360 Re: Telecopy: (907) 276-7542 .. Kuparuk River Unit 3H-20 ARGO: Alaska, Inc. Permit No, 87-134 Sur. Loc. IO0.7'FNL, 282"I5~L, Sec. 12, T12N, R8E, UM. Btmhole Loc. ll09'FNL, 1820'FEL, Sec. 1, T12N, RSE, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced 'well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing, installation of the blowout prevention equipment, so. that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. c. v. c it:aTM Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ~ STATE OF ALASKA ALASKA', ,L AND GAS CONSERVATION C~/~:MISSION PERMIT TO DRILL 20 AAC 25.005 & la. Type of work Drill [~ Redrill I-11 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] Deepenr--!I Service [] Developement Gas [] Single Zone .1~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 76' , PAD 39' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River 0il P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25531 ~'"'ALK 2657 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2o AAC 25.O25) IO07'FNL, 28;~'FWL, Sec.12, T12N, R8E, UM Kuparuk River Unit Statewide At top of productive interval (~ target) 8. Well nurpber Number 1320'FNL, 1950'FEL, Sec. 1, T12N, R8E, UM 3H-20 #8088-26-27 At total depth 9. Approximate spud date Amount ll09'FNL, 1820'FEL, Sec. 1, T12N, RSE, UM 01/ 6/88 $500,000 12. Distance to nearest 13. D3il~t.aln~e to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line ' 9066' MD 1109'~ TD feet 75' @ Surface feet 2560 (6266'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 Kickoff depth 500 feet Maximum hole angle 520 Maxirnumsurface I 832 psig At total depth (TVD) 3040 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5~ H-40 Weld 80' 35' 35' 115 115' +200 cf 12-1/4' 9-5/8" 36.0~ J-55 BTC 3948' 35' 35' 3983 3096' 1255 sx AS II I & HF-E~W 400 sx Class G blend 8-1/2" 7" 26.0( J-55 BTC 9032' 34' 34' 9066' 6266' 200 sx Class G(minirnu) HF-E{W TOC 500' abc ve top of Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ConductorRECEIVED Surface Intermediate DEC1 7 1987 Production Liner AlaS~ Oil & Gas Cons. Commission Perforation depth: measured Anchorage true vertical 20. Attachments Filing fee ~ Property plat [] BOP Sketch ]~ Diverter Sketch I~ Drilling program J~ Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25,050 requirements 21. I hereby p~ that the foregojng, is true and correct to the best of my knowledge Signed Title Regional Drilling Engineer Date J ///4/ // ""'-- Commission Use Only (AWM) PD2/66 Permit Number I APl number , O]; 2oc~1:~ I Approval date I See cover letter ~'-z' -[.~z/. 50- ~ 1 2 / 23 / 8 7 for other requirements Conditions of approval Samples required [] Yes I~--~qo Mud Icg required ~ Yes [~--t~1o Hydrogen sulfide measures [] Yes E~-'lqo Directional survey required [~Yes [] No Requiredwo~~~~; ©5M; [] 1OM; I-] 15M Other: by order of Approvedbyl~ _...~../~'. ~ , .~V~.~,C~,~"k" Commissioner the commission Date Form 10-401 Rev. 12-1-85 Sub :ate 0 0 o 0 0 0 0 TI)lIE' VI:'i:)TTPAI rtI:'PTH t. : ' Flli.~. I FEI. ;. I · TI 2N. I - 1.000 TARGET CENTER TVD-e(:m~ DEP-S.21 NORTH 4304~ .... EAST RECEIVED DEC 1 7 1987 ~l~sk~ Oil & Gas Cons. Commission Anchorage sum=.~c[ 11 ~ ~o =oo ~ =~o =oo ~ =~o ~oo i ~oOo 10,50 1100 11~0 1 200 D~VELOPHENT ~£LLS 1. Hove f~ r~,l. 3. Drill t2~" hole co 9-~/8" surface ca~inl point accordinl co d~recciona~ p~an. ~uu ~d c~uc 9-S/8" c/8~nl, S. ~noca~ ~d teac b~ o~c p~eveucer. Teac cao~ co 2~ poXf. 6. Dr~ ouC coMnc 8~ LO* ney ho~e. Per~o~ Zea~ff 9. ~nC~ drtZZ~ ~' ho~e co provide Z~* beau PZus back cociZ depth ~d boccm of Eupa~k 12. ll~e ~ b~ out preventer ~d ~,ca~X t~ora~ ~ tree. Se~re w~ ~ rehaoe IS. ~ ~ wr~er r~S. N~ppXe up bX~ ~c' pr~ucer, 16. ~t~ ~ 7" ~o~ ecra~r ~ c~~, cr~p ~ ~b Co pl~ back cecal depth. C~r~ce ~le ~th cle~ brae ~ trip ~B of 17. Perorate ~ ~ c~ett~ ,coolly, sec ~ Coot 18. Nipple ~ bl~ out pr~eucer ~d ~ocall ~ ~e ~er Co diesel. 20. FI~ wLl Co c~s. Shuc 21. Se~re veil ~d Feleaee 22. Fracture DEOA~SER HUD CLEANER SHALE STIR STIR STIR' SHAKERS HUD CENTRIFUGE CLEANER TYPICAL MUD SYSTEM SCHEMATIC L~4 / th RECEIVED DEC 1 7' 19~7 Naska Oil & Gas Cons. Commission Anchorage I · DItILLING FLUID Spud to 9-5 8'* ,,Surface Caeint 9.6-9.8 Drill out to ,Yeisht Up 8.7-9.2 5-1:5 8-L2 35-40 2-4 4-8 10-20 9.$-10.5 4-7 Weisht Up co TO LO.3 9-13 8-12 3-5 5-12 6 9.5-10.5 9-12 Drilltnt Fluid Systea** - T~l° Tandem Shale Shaker - 2 Hud Cleaners - Centrifuse - Desasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid A$itators Notes: Drtllin$ fluid practices will be in accordance with the appropriate resulacions stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using, a surface casin$ leak-off of 13.5 pp$ E~W (Xuparuk averase) and a sas sradient of .11 ps~/~c. This shows chat formation breakdown would occur before a surface pressure of 3000 pst could be reached. Therefore, ARCO Alaska~ Inc. will test BOP equipment co 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. In accordance with Area Injection Order No. ~, excess non-hazardous fluids developed from well operations and ~hose fluids necessary to control the fluid l~vel in reserve will be pumped down the surface/production casing annulus. The annulus will be lef~ with a non-freez£n$ fluid durln$ az-. extended shutdown in dlsposal operations, The annulus will sealed with I75 sx of cemen~ followed by arctic pack upc:~ completion of the fluid disposal. Lb'KS/ih 9~£-t I Dr S3:)N¥.LSKIn:3~II:)' ANY u3ON£~ ll3~ NI J. nHg' ION O0 ~I/N~C~3 ~^]IHDV O~ ~AIYA ~L¥1UdOOOd~ N3cK) ~v ~].LN]^]Ud ]~OID 'N01.~VllV.~SNI I¥1.LINI NOdn ~ NOI ~¥~3d'O =2"'3'~NYN2£N 1¥6J _1 DI.I. VH3H3S ~I:].Lt::IgAIO .0~ .LINrl ~3Ali:l )ll'l~Vdrl)l I i i i, i i i~ - II 12 · i VICINITY MAP S-"-c~L~: I" · ~ MiL~.$ ALL WELLS LOCATED IN SEC. 12, T. 12 N.,R.8 E., UMIAT MERIDIAN. ASPs 'X' 6,000,I10.73 6,000,135. $1 6,000,160.57 6,000, 185.28 6,000,210.66 ~,000,235.50 S, O00, 260.34 6,000,285.82 6,000,310.30 6,000, 335.43 6,000,425.37 6,000,450.51 6,000~475.46 6,000, 500.41 6,000, 525.44 6,000,550.46 6,000,5?5.45 6,000,600.44 6,000,650.45 6,000,675.40 6,000,700.4?_ 498,65.5.44 498,655.43 498,655.39 498,6.53.43 496,655.47 498,655.40 498,655.41 498,655.44 498,655.45 498,65.5.44 498,655.44 498,655.$8 498,655.42 498,655.43 498,635.4l 498,65.5.47 498,655.55 408,655.59 498,655.49 49 8,655.63 498,655.?$ LATITUDE LONGITUDE 70o24'41.531" 150o00'39.416'' 709 24'41.7T5'' 70°24,'42.02~', 150900'~.418, ~o ~4' 42.514' 15~ ~ ~9.416' ~' z4 4].~5s;I 150e~' ~9.4~7"1 70° Z4'43.494, I 70°Z4'43.~41' I 150~00 ~0o24'44.873'' 150e 00'39.4~1 7~24'45.1~9" 150e 00'39.419~ ~0e~4;45.3~ 150e O0'~g. 41( 70°~4 45.610 ?0e24'45.8~'' 15OEO0' 39.417' ?0e24'46.1~'' i ~e00'~9.415" ~0~4'~.~! 7oot4'47.085"l 100o~'$9.41~' TO°24'4T. 331" 150°~'39.41~ I HEREBY CERTIFY THAT lAM PROPERLY REGISTERED ANDLICENCED TO PRAC- TICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER * MY SUPERVISION,AND THAT ALL ARE CORRECT AS OF 6/9/87. ~e~eee,eee,,,oeo,,* eepee,~ %~*,~,,,,,*' NOTES I. ALL COORDINATES ARE A.S.P., ZONE 4. P. ALL DISTANCES SHOWN ARE TRUE. $. ELEVATIONS ARE B,P.M.$.L. 4. REFER. FIELD BOOK L-BT-19, $5-44; L-~ 1'-I1~ 29-$2. B.O.O. ELEVATIONS FROM CED-RlXX-$4'rld~ 6. HORIZONTAL POSITION BASEDON SH CONTROL MONU"EI~I~E~ LVI.~IURY & ABOC. OiflF. N.L. ; ~a~ka Oil 522', 49 7, 472, 446 422' 397' 371', 347, 322 1232' I~07' 1182' 1132 1107' 1082' 1007' 982' 957' J('-; J ] _l_-,/j Disl F.'W. L. Ga,~ Cons. Co~ Ar~kdrage 281 281' 281~ 2Eli' 261', 281 28 I* 201' 2 8l' 281', 281' 28 2' 282' E82' 282' 262~' OG E!ev. 34.0 33, 9', 33.8, 33,7; 33.6 · 33 33.6, 33.6 $3.1" $3.9' 33. e', 33.8, 33.8 33.8* 3:5.8* 33.9' 33.9' 33.9' Pod Elev. 38.9' 39.7 36,9' 3e.e'. 36.9 36.T', 38.6, 36.6 39.?' 36.$' 38.$' 39.? 38.7' 39.9' Il.O' 59.7' 39.6' :5 8.6' ARCO 'Aloska Inc. D.S. 3H WELL, CONDUCTOR AS-BUILT LOUNSBURY Associales ANCHORAGE ALASKA CHECK' LIST FOR NEW WELL PERMITS Company A~ Lease & ITEM APPROVE DATE YES (1) F,ee ~ /~f~Z 1. Is the permit fee attached .......................................... ~__ Well No. -~]~[] NO REMARKS (2) Loc (2 thru (9 t_hru 10. (10 and 13) 12. 13. (14 thru 22) (23 thru 28) (6) OraER 2. Is well to be located in a defined pool ............................. 3. Is, well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 9t/h~ For 29. ("2 31) 30. 31. (6) Add: ~.~.~//f'.Zf'~¢" 32. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number Is conductor string prOvided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... z~ , , Is the drilling fluid program schematic and list of equipment adequate~_~__ 'Are necessary diagrams and descriptions of diverter and BOPE attached./g4f Does BOPE have sufficient pressure rating - Test to _~OOC) psig .. ~ Does the choke manifold comply w/AMI RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. __ exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of Seabed conditions presented/'~__, Additional requirements ............................................. o ~z mm Geology: Engipeering: Lcs/ rev: 01/28/87 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE 4~3{'c~o ]3~v-/ O,'a 8~ ~ /f/Go oA) Additional Remarks: Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. LVP 010.~02 VERIFICATION LISTING PAGE ** REEL HEADER SERVICE NAME DATE :88/02/ ORIGIN : REEL NAME :72577 CONTINUATION ~ ~0! PREVIOUS R£EL COMMENT8 :EDIT LIS,ARCO KUPARUK )H-20, API# 50-10)-2009) *$ TAPE HEADER ERVICE NAME ATE 88/02/ R ~RZGI~ ;7257 APE NAME CONTIHUATION # ~0! PREV)OUS TAPE COMMENTS :EDI? LIS~ARCO KUPARUK ]H-20, AP1 # $$ FILE HEADER FILE N~E :EDIT VERSION ~ DATE : ~AXIMU~ LENGTH : 1024 FILE TYPE PREVIOUS FILE INFORMATION RECORDS MNEM CONTENTS UNI? TYPE CATE SIZE. CODE c. , ..co ALASKA, ~.¢ ooo ooo ~N : 3H-;20 ' 000 000 0 0 FN : KUPARUK 000 000 008 ~ANG, SE 000 000 002 o oo°°' ooo oo°°o ~o~.,.o~...o~ oooo~o ~~ ~~ oooo o CTR¥IUSA 000000 003 065 ** COMMENTS ************************************************************************************** * SCHLUMBERGER LVP OlO,H02 VERIFICATION LISTING PAGE ALASKA COMPUTING CENTER COMPANY w ARCO ALASKA XNC WELL ~ 3H-20 Ap! ~ = 50-103-200g3 FIELD m KUPARUK COUNTY I NORTH SLOPE BOROUGH STATE I ALASKA JOB NUMBER AT AKCCI 72577 RU~ #~. DATE bOGGEDI 23-JAN-88 ~DPI RICK KRU~E~b CASING TYPE FLUID DENSITY VISCOSITY FLUID LOSS = g.625" g 40g2~(DRILbER) - BIT SIZE = 8,5" TO gOIO'(DRILLER) - ~EIGHTED PO~Y"ER "38~'~s~/~ R. . ~.~ ~ ?~ Dr I g,5 RMC w 2, DF i 4,g C3 RM AT BHT ~ 2,335 P 143 DF MATRIX SANDSTONE NOTEI 1, )FILE EDfT 001N CONTAINS DUAL INDUCTION (DIL) FORMATION DENSITY (FDC) ~, .COMPENS T~D ~UTRON (CNL)_DATA OF.BLUELIN~ ~Ibg 18, GAMMA RAY THRU CA~ING (C~G) FORMATION DENSITY (rD5), AND COMPENSATED NEUTRON (CNS) SAMPLED ~ .5' LVP 010,H02 VERIFICATiOns! LISTING PAGE 3 CHANNELS WITH THE EXTENSION FD5 AND CN5 ARE FROM BbUEbINE FILE& LABELED INPUT FILE 5 AND ARE OVER THE CObVIbbE INTERVAL, THIS ~NFORMATZON IS BEING PRESENTED DUE TO BETTER DRHO RESPONSE, 2,)FIEENEuTRoNEDIT OOH]2C~N ~OANTAIN$~PLED ~.HI1,2"RES FORMATION DENSITY (FDH), COMPENSATED THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVERLAYS FIELD PRINTS SCHLUMBERGER LOGS INCLUDED WITH THIS MAGNETIC TAPEI DUAL INDUCTION SPHERICALLY FOCUSED LOg (DIL) FILE 18 DATA AVAILABLE: 9009' TO 4099' FORMATION DENSITY bOG (roe) FILE 18 DATA AVAILABLE{ 8983 TO 8448' FILE 18 DATA AVAILABbEI 4850,5 COMPENSATED NEUTRON~LOG (CNL] rILE 18 DATA AVAILABLEt 8968' TO 8448' FILE 18 DATA AVAIbABbEI 4850,5' TO 4396' RAY THRU CA${NG CCSG) GAM~AFILE 22 DATA AVAIbABLEI 4095' TO 993' FORMATION DENSITY bOG HI RES LVP OlOe~02 VERIFICATION LISTING FILE 13 DATA AVAILABbEI 8983' TO 8449' COMPENSATED NEUTRON LOG HI RE,S i,2" (~NH) FILE 13 DATA AVAILABL I 8968 TO 8449' FORMATION DENSITY bOG (FD5 FILE 5 DATA AVAILABLE: 4718' TO 4465' COMPENSATED NEUTRON LOG (C.5) FILE 5 DATA AVAILABLE: 4?03' TO 4465' ****************************** PAGE ** DATA FORMAT RECORD ** ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 ! 66 0 4 I 66 8 4 73 60 9 4 65 ,tin 16 ! 66 0 1 66 0 ~ATUM SPECIFICATION BLOCKS NEM SERVICE SERVICE UNIT APl APl APl APl FILE IO ORDER ~ LOG TYPE CLASS MOD NO, DEPT FT 00 000 00 0 0 FI,~U Dlla OHMM 00 220 01 0 0 !aD DIla OHM~ O0 1,~200 46 0 0 lam DIb OH~ O0 I 0 44 0 OiL ~V O0 t0 01 0 0 D D~~.. GAP, 00 , 0 0 0 ,~ oo ,~'o o,o o G/C3 O0 02 0 0 ~HOB ~RHO FDC G/C3 O0 DPHI FDC PU O0 0 0 000 0 ~,~ ~ ~ oo o ,..~ ~.~ oo ,~o o~o o .~.~ c.~ .u oo ,,o ooo o .c,~ c.~ c.soo ooo ooo o .c,~c.~ c.,oo ooo ooo o SIZE SPb REPR PRO!CESS CODE (OCTAb) 4 I 68 00000000000000 4 ! 68 00000000000000 4 i 68 00000000000000 4 ! 8 00000000000000 4 ! 8 00000000000000 1 ~ 00000000000000 I 00000000000000 1 ~8 00000000000000 1. 8 00000000000000 00000000000000 ~ oooooooooooooo ~, oooooooooooooo , .~ oooooooooooooo ' ~I oooooooooooooo ! oooooooooooooo ~I oooooooooooooo oooooo:oooooooo ~8 oooooooooooooo ~ o8 oooooooooooooo ~ o, oooooooooooooo 00! 666' O0 O0 } '0! 0018 o0~ &~oa O0 3O~J 00~{ $o a oos 0000~ ~U~ 0000 0000 £81L £ gg3~ OOgg &N3~ OOg~ 30JJ OOg~ ~OHa 00~[ aD 0000 ~a~& ooo ogaQ aD 0000 666- 666- 666' 666' Wq! L~,DL ~. 000000000000o0 89 I 00000000000000 89 00000000000000 89 00000000000000 89 O00OO000OO0000 89 00000000000000 89 00000000000000 89 ~ 00000000000000 89 , 00000000000000 89 00000000000000 89 00000000000000 89 00000000000000 g, O00000000OO000 89 00000000000000 89 00000000000000 gq 00000000000000 I~ ~ OOO00000000000 00000000000000 89 00000000000000 89 00000000000000 89 000000000000o0 eg 000000000o0000 89 OOOO00000oo000 89 t t t t DN3Z. Oq! : gN3~ 00S~:666' D&ND DOJJ OOS:StS goHa O!tg,9 aqI £ ~L ~ gN~ 00gC~666' 3[ND 00$~'666' IHdN O0~666- DOJN 00S[,666~ ~NDX 989~,6E 3033 000g,8~8 gOHa OttS;9 gN3& 0~L8;£0~ 0 0 0 0 tO 0 0 ~0 0 0 0 0 oo 0 0 O0 0 0 O0 0 0 OD 0 0 DO 0 0 oD 0 0 I0 0 0 ~0 0 o 0 0 0 oo 0 0 o o 0 0 0 0 0 0 0 o 0 tO o 0 0 0 O0 0 0 oo oooo:o, O00Sj oooo D&~DJD o0, 666' O( 666e N~H 00! 666~ HdO O0~ 666' OH80 D&ND 069 30:jN 90g nqJg 0000 0006 8D 00S[~666' ~£JD 00Sg,666' 666 00S''666 0" IgdO OOS[. " H gN3& OOg~:666- DOJN O00O,O~Z~ O000!S~" c.:jI9 o0 ~lq 0 E o0 IdV.') 0 E O0 IdVD gl9 O0 000 O0 000 O0 000 O0 000 O0 068 o0 O0 O~t oo o0 t~ o0 t OO o0 oo 8'I gdD nd ~Jd;) gd3 nd OS~ DO 08 o0 NX oo Id~ OO ~E9 OD gq 000 Do 0o0 OD Dg3 gN3& 6ND 3&N3 ~N3 !HdN ~aj iH~o SO~ OHUQ saj goga go~ 9N3& DNIZgYq NOIZVDIJiH3A ~0~'0'~0 dAq , ~ Ol 6' i6' 8 /. O0 ~66' O0 i6o O0 0 i6e i6' ,' 00! ' 00! 00~ 3DVd I N3& N3U OHBO Ug gN3& ZNDU 90HU OOgg 666~ OOSg 666a o000 60LL oooo 0000 ~OLL ~66~ 666' 00~ 666' 00~ 666' 0069666' 0000 9~6L ooo~ O0'O0:~6L 006g*666' oo :666- 005~666- 000.'8008 St~9,66~ OOOO:ET~ 000016006 TL~08 00~:666- 0061.666' 0061~666' :rteL g9 000 ; ~ A 00S,666' 66' 006 :'66 00S8:666- 006~,'6 - O000.O~t8 SOgL,~66~ ooog 9~9 ZHd~ ' 666' 30JN gN3~ &ND8 ~8 30~J 0 686 goHa gN3~ ~ TT N3& OOG~[666- AND OOG~:666- ZHd~ OOgge666- DQJN OOgg.666- gN3~ £0~6:90LT goHa aN3& G~TB,~TT Oqi LL~6 T gN3~ gg~i 666- 3&N~ 666. ZXdN 00! i66' DOJN O0~ 166' Xq~3 O( gN3~ E ND~ Ld Od3 O( 86 GOHU ~ oql ZHdN gN3Z gOHa gN3~ OOg~ 666- OOS~ 666- E6~ gN3& ZHdN 3qJN ! V3 ~NDa 008:666' 00~.666 0 ~666' 06Tf.8£ 0006 gN3~ i66" 3~N3 :g~ 303N T n,IJg 066 aD lUdN 3Q~N OOgi 66:6~ O0 666' oo~1666- OOS~ 666' ~0 ¢ 0000' 6L 0000' 096 ¥ OH~1 3Z ,Ld3 aD OOg; 666' D&JD 00~ 666~ aN&~ O~ 666' YaNk lHdO 0 666- OHiO &N3 6 3OJN ~ IHda lqVD O~ 006 ~D 00gg~666' ~ UN~U 00G~.666- VUN~ IHdO OOgg.&66- OHiO IHdN 8 aa&a 3O&N L~.~t.' T IHdO O00S;l~' dg NqJ~ 0000 0068 &d3d 006~7666' ~N&~ 00Gg~666- VaN~ lHdO 00Gg;666~ OHSO gN3& 00Gg~666- . VERIFICATION bISTING PAGE 7 RCFT -999,2500 ~TC GR -999,2500 DEFT 8400 0000 8FLU P -44 R EN$ -g! ~Ab! DPH! ., ,00 aFDC RTNR .. ,00 NPH! CFTC -99~ ,00 CNTC OR -99~ ,00 TENS DRHO -99 )0 DPH! TaRA -99! RTNR RCFT -999 2500 CFTC GR -999 2500 GR DEPT 8300 0000 SFbU CAb! DPH! t500 NrDC RTNR .,! ~§ 1500 NPHI CFTC -9' CNTC ~R -9' TENS DRHO e, iO0 DPH! TaRA ,~ iO0 RTNR RCr? -~ iO0 CFTC GR -~ GR DEFT 820 ~0 6FLU ~NS '~ AUI @PHi .i NFDC RTNR -' iO0 NPH! GR ;:0o TEN8 DRHO -9' 0000 DPHI ~N~A .9~ RTN~ ~CFT .9! ,00 CFTC 6R -999 !500 GR DEPT 8100 ~000 SFbU SP -, ~R' TENS -~ Abl DPHi " NFDC RTNR -! NPHI CFTC "9! CNTC GR -9' TEaS ~RHO .~ ~0 DPHI TNRA .i iO0 RTNR RCFT -.9,9, ,00 CFTC GR ,00 GR DEFT 80~ SFbU TENS -! ~AbI 500 '222, 5oo 500 990!500 999,~500 -99~,~500 -99~,!500 -999.~500 -999;~500 -999,!500 -999~500 -999~500 o -99 O0 '99 O0 ~99 O0 "99 O0 0 C~TC TENS IbD TENS RHOB RCNT TENS CAbI N~DC NPHI CNTC TENS TENS RHOB FFDC RCNT TENS CAbI NFDC NPHI CNTC TENS TENS RHOB T~N$ CAbI NrOC NPH! CNTC TEN~ ID T~NS RHOB FPDC RCNT CALX aFDC NPH! TENS ILO TENS AH:OB '999. 500 TENS -999.)500 '99 500 '99V~ !00 ooOO 99~ 500 '9 ~00 O0 -9 500 '9~.2500 · ,999,2500 3 758 -99 -999 -999 -999 -999 -999 ~999 IbM 57 GR "99' O0 DRHO -' O0 TNRA -~ O0 RCFT -9! ~00 OR -' ~0 RHOB ~' 0 rrOC -' 0 RCgT -' 0 TENS -99 0609 oooo 2500 DRHO RCFT 0 GR 500 RCNT 00 TENS O0 '00 RCNT , O0 ?04~*~$40 IbM ,0000 -909i2500 -999;2:S00 TaRA "999,{500 RCFT -999 iO0 RCNT '999~2500 -999.2500 4,1344 IL, M '999, DRHO -9 lO0 -99! O0 ~0 )0 -' O0 -9: O0 -9! ;00 '86 .-! )0 O0 iO0 .! - iO 0 -99" O0 O( O0 0 0 ~6 0 ,66' 0 0 i66" 0 i66' 6~ o0 ,666' i666- 005~666~ ~N:DH OH~a IN3~ gN3& &NDU gOHU YHN& gN OOS~ 666' OOg~ 666~ O0~Z 666' O0~C 166~ 00~ 00~ 666~ 00~ 6661 0000 ~9g9 t~ze o05~:666- 00G~,666- ~666- OOG~: 00~.~6- 0000 966~.6~9 00tZ'666- 00~'666- 00~:~666- 00~:666- 06~I;'666' ~666- .666~ 00~C~666' OOgCe6661 006~,666- 1666- O0~g~666- OOSg~666- 00~g,666~ Q000.~89 00~666' 00S~.666' 00S~666' 00t~1666- 00gg'666' OOg~666- 00g~666~ 00g~°666~ IHdN GOH~ GOH~ IHdN :qVD IHdN gOHH gN3& IHdN O0 6 6 O0 ~666- O0 ,666~ 00~;666- Oi! *666" O0 ~666" .666' 00tg.666~ .666- 9C9~ ,K'666' 00!;~'666- 00t~666- 00~.660 00t~.666- ~06g.666' L[6.90! OOtl 666- O0Sg 666- OOfg 666- O0ig 666- OOig 666- OOS~ 666: OOtC 666- Og/8 ~8 ~89~ H 00~C:6:66- aN&~ 00gg.666- IH~O 00i~6:66- gN3& 00G~6:66' OOGti666' IHdN oog~,666~ I~YD oo ;666- aD O00~,8t' dg fl~ 0000 0086 ~d~ ~g 00~ 666' D&iD 00! 666' SJD aN&a O0 666- IHd~ O0 666~ gN3& 00, 66,- oo~ ~- ~&ND 00~ aN&t HdN 1q¥3 00, 666- gna ~3S 0000 006~ id3, .666- HN~H 00Sg,666- VHN 00gg.666- IHdO 00S~,666- OH~ 00gg.666- gN3& OOgg.666- 00gg.666- D&ND 00~.666- 00fg:666- IHdN 00gg.666- 00~ 666- D~&N OOSZ 666- IHdO J O( O~ 0~1 Ot Ol O0 ,66' O0~ 0 Ol o i6'., - 00' O~ o 0 i6o O0 i66' 0 0 0 6° 6'* 0 O0 O0 O~ i6o 00~'666e 00~ 6660 gN3~ 00~ 666= gN3& 00! 666° DZND 006 666' ND~ 00~ ,:66' IHdN 0 6.0 ~JJ O( ' DOJN O! 6o ~9 00~ ' ~N~ O0 V~N& O( ,' Da · OH~ 00~ re gOHa ~0 ' O0 O06t; D iJ 00~i aaJ~ 005~i'666° ~0.~ 006.~:666- I~VD 00,,_666- HD ~JDU 00! 666* gN~& 005~666- O0~i .666o &ND~ 005~,666o ,,,, =,, [jj. o0~ Da~j 0oG~666- 30JN 00 gOH~ 00~'666o ~V~ 006C ~D 00S~666e gN3~ 006~ oN~a 006~:~666- goH~ ,~ 0000:j,t, oos~ 666- 666° 666~ 66- 66- 666~ 666- 666o 8 gN3& 3&ND 3OJJ VHN& DaJ3 OHUO gON~ ug gN3& 006~ 6660 O0'g~ 666- OOS~ 6660 666- 006~ 6660 00, 666° O0 ;666' O~L8,~Ot 66~0 00~0666' gN3:Z 00~'6660 006 .* 666- 006 ' 666- I~g o~ nqjg 0 OIL ~D O0 ~66i ~N~8 gN3~ O0 DiN 00' iHdN O0 DO~N O0 n~ oooo ~g O0 gN3& 00' I &ND O0 ~6 Hd~ 00! D~&N O0 nqJ~ ooo D$~D 0 661. VHdO 0 66' D&ND 0 6 ~ oo~: ~3N 006~* I~VD OOG~' fl~39 0000 O0~L aD 001 D&3D 00! 1o 00! 006~ ~ 0000'006~ ~g 00;g'666' d ~ O~ d ub Ix~a 6 3DVd DNI~gIq NOI~VDIJI~3A COHiOIO ~VP O~O~H02 V£RIFiCATIO~ L~$TING PAG~ 10 GR -999; TENS DRHO 0999'2500 ~PHI TNRA -999.~500 RTN~ GR -vv~. GR DEPT 7000 0000 6FLU DPHI .i ~0 NFDC RTNR .i lO NPHI CFTC -~ ,00 CNTC GR -9~ ;00 TENS OaHO -999.999 ,00 OPH! TNRA ,00 RTNR RCFT 099~ 1500 CFTC GR -999 !500 DEPT 6900 0000 SrbU ue~! )0 aFDC RT~R -999 15:00 NPHZ gFTC -' CNTC DRHO -' }0~0 DPH! TNRA -' )0 CFT -9~ CFTC R -g! 1500 DEPT 680, )00 8rbU ~S -: O0 RTNR .., NPHI CPT~ -' ~500 CNTC ~9! DPH! '* RTNR RCFT .~ CFTC GR -9~ 1500 DEPT 670'0 ~00 SFbU EN8 -' )0 _R R~HI -; NFDC NR -' ,00 NPHI CFTC ., ,0o C~TC OR -' TENS DRHO .~ ~00 DPHI TNRA e~ ~00 RTNR '9 , 0 RC 99 , 500 CAbI '999~ .~00 NFDC ~0209 D ' 9, HOB -~, 0 RCNT '~, 0 TENS -~Z,~500 ~PHI ~v~,2500 CNTC .9~i~9186 IbD OB '999, FFD . ."999 *2500 CA~Z "999,2S00 NFDC '999" 2~00 NPHZ -999; 2~00 -999.2500 TENS iO0 RHDB .~ ~ FFDC RC~'T '( iO0 TEN~ '9~ NFDC ." ~0 CALl 0 ~PHI CNTC TEN~ 0 " : 0 FFDC ~ 0 ~CNT ' ~ TENS -99~ CALl -9~ O0 NFDC ~9~ O0 NPHi 500 ."9 '°°soo 500 500 TNRA RCFT GR RHOB FFDC RCNT TENS 580 DRHO -99~ 500 TNRA '"99! $$00 RC~T RHOB -99 0 Free '999 55~0 RCNT Ig°o 4, 943 tl l: OOoo '99 0 -99§: ~0 -9~ 500 -9! 500 .-999 oo O0 37930 5764 0000 '999 2500 '999 2500 '999 '2500 -999 2500 -999 2500 -999 .9,{SO0 ~3~00 '999,~500 -' iO0 "' iO0 " DRHO -! ~0 T N R A ,.'i RCFT .i i O OR '~ )0 R H 0 B FFDC ., ~00 RCNT ,,,! ):0 ~t~ .' t9 DRHO ,,,~ TNRA -~ )0 RCFT '9! GR '~ ~0 RHOB FFDC ,'~ RCNT TENS -' iO0 IbH ~ -~ i,O0 rHO TNRA -9! )0 GR -' iO0 RHOB FFDC RCNT -: ~0 TENS 00! i&' O0 i! 666' 0 666' 0 · ~6o O0 89 00~Z:'666- 00! 66~ gN~& 00! D~J gOgH 00:~:; VaNS 0 O0 0~ ~L9 ~N3& DOii O0 aD o0$g :666- OHaO 006~"666- ~3s :666- gOH~ 00iI~666- ~&DaaN& 00~S~666i OH:aa oo~c;66 - a~ oooo ~t ~I 0660~ '~ OOfl 666- ~N~S OOS '666' 3aJ~ .os gONa 0 666' aD 666' &&D~ OOS: '666' VaNS OOt, ,6' OHHa OOg: ,60 89 000( Nq! ~LI~ t 00gg'666' gN3,I, OOg~' 666' gN3$ 0 gN3& O0 gOHU 0 ~qI o~.6~ :666- ~666- 6 - 666- D~N3 666- !HaN ~ 666- 3oJg 666- gN3$ 666- 666' gN3& i 666' 3&ND 0Gt.666- 0 ' I~V3 00~g;666 ~N3~ 00gg,666' Da~J 00g~6660 s.3z OqI ~01~ T' t gN3& O~Z 666 3OJN 006~.666- 00. Iq,3 00~ 666' ~N3& 666- &NOg OOS~ 666- 3OJJ 00~ 666- ~N3~ tOT Oq! gN3& 00g~'666' D&ND 00gg'666- l'qV::) 00gg;'666- ~qtg O000'OOB9 ~D D&ND HdN n~ 00~ O( OO! 00! 00~ O0 O~ &d.'"lCl aD OOSl 3I~D OOgt NZa 00~ H~a O~ O0 O0 oo - - cJN~ 0~9 3&JD 0 aN&a OOG; lHdO O0 gNaS O0 3&N300g; IHdN OOg DOJN OOg IqV300g~ V ' i6'. t9 :ag OOgi~ Flqdg 0000 0c~9 Y~NZ OHaO aD OOil 666* aD DiJD O0 666* ~3~ oo 666: IIVD 0 i6- aD 000! ' NqJg 0000 099 O( O0 O0 O0 00~ 00'~ O0 O~ i66~ 00! ,- oo~ ii~: 00~ &ND~ O0 66~ ~.~ 0 gOHU ~N:& 0 666' OHHO OOtl ~66~ U~ 0 g 68S Hq! ~l gN3i O~ 6661 0 666' gO~ OOt:l il61 HD 00! 6~ YUN~ 0 6~6o OH~fl 0 ~' 6o U9 000 ~S 00¢~"666i ~NDH 00GC,666o Y~N$ O0 ';666- OOt ~S~& 00~ ~ 00~ ~a'iJ O0 gOHU 00~ U~ OOS &'iOU O01 ~& O0 000 !666 666 ~666o ~666 .666' ~666o e666 1666' gOHU 00t~;666o 00!~666' 00f~d666o 00f~666o oos~leee- oo~c::ee6o ootl 666- IHdN 0 i66o i~VD O0 gN3$ 0 &ND~ '666- 3~ii 0 :666i gOHU 0 gN3$ O0~i : 6 - oo[~ ~. ~OJ~ 66- i66~ SND~ 00! i66~ IHdO D&ND IHdN n~Jg oo~ i66' ,6*' 00! oo, OOi Ot D~JD 00~ ~iSa 00! ~Hd:N 00' '~D O( D& D O( IHd~ 00! IHd~ 00! ,6~ D~ 00! IqVD O' fl~i'~ 000~ 0009 ~666 I~YD 00$~.666- O( o, ~: gOHH oosg,666- 3aJH 00~g; sN3, 0000,~ IqYDUD ~[~ a~z 90st a~s o~o'~bx9 gN3$ 0 ~.~ o~ IHdN 00~ D~tN O0 I~V300SI ~N~£ 00~ ~o~ oo~ ~ 00~ 66o 66~ 6660 6660 6660 IHda 3&ND IHdN OOg~ 6660 OOS~ 6661 00~ ~: OOgt' ;666' Oosl OHa aNna gN3& d~ u~ UD d~ ~d3a OH~Q iHdO ~! 39Yd DNI&gI~ NOI&YDI~Ia3A [OH'OtO LVP 010,~02 VERIFICATION blSTING PAGE ReFT -99~,2500 GC;TC GR -999,2500 DEPT 5700 0000 SFbU GR uP.I -' 2500 NFDC RTNR -99~ 2500 NPH! CfTC -9~' CaTC GR '9 TENS DRHO '99' ~00 DPH! TNRA -99' ,00 RTNR RC~T -999; }00 CFTC GR e999. GR )EPT )RNO rNRA GR )EPT ;p R NRA R EPT R i0 R EPT P TENS 5600,0000 -24,1562 -999,2500 e999 2500 '999 2500 O0 -999 )lO0 '999 '999 2190 -999 .* -~' O0 -9' ~00 '9~ )0 · ,' JO ,,' O0 ,,' iO0 54( 0 -' ,00 -' O0 -' O0 " 00 °9~ O0 '999 -999 5300 0000 SrbU GR CALI NFDC CNTC DPHI RTNR CFTC GR SFLU GR CAb! NFDC NPHI TENS DPH! RTNR CFTC GR SFLU GR NFDC C~TC RTNR 8FLU ALI -999. 500 -999,t500 8 0 '99 0 0999, 0 '999, ~0 -999, -999~2500 -999 2500 -999~2500 -999 2500 2:6780 .9,9 '999 '999 2500 '999.2500 -999 2500 -999 2500 -999 2500 -999 2500 -~22: o, -~, O, -92~; o, '*~, 8oo -~. oo o, '999 '~00 -999 oo : oo 0 -999 0 TENS RHOB FFDC ReNT TENS CALI NFDC NPH! CNTC TENS ILD TENS RHOB rroc ReNT ?~NS CALl NFDC NPH! CHiC TENS ILD TENS RHOB FFDC ReNT T~N$ CAb! aFDC NPH! CNTC TENS ILD TENS RHOB FFDC ReNT TENS CAb! NFDC NPH! CNTC TENS LD ~ENS RHOB -999,2500 TENS '999,2500 0999 500 TNRA '999 500 ReFT '999;2500 GR -999,2500 RHOB -99902500 FFDC -999,9500 ReNT -999t~500 TENS -999,2500 2 5080 "999 "999 '999 ~999, 999~ 0999 -999 ~03 ILN 5i0 TNRA O0 iiio 0 RHOB :508 FFDC RCN? 0 TENS 0 3 '999 '999 '999 '999 '999 '999 '99 '99~ -999,2500 -' !0 " )0 .,~ iO0 ,' iO0 -9! tO0 -9! )00 09 ~00 -99 -g ~0 -g )0 - ~0 ,.9 )0 e' " )0 o ;..o '*~ ,o 1i"5° ..! :"00 TNRA ~500 GR -9 r C )0 TENS 099' lO :0000 ,2500 DRHO 666i 00! O0 O~ Ol 00! 0~ . 00 ! ,6' O0 60 00! b66m O( 6 00! 00! 00! 00! 666' 00! 6660 00! 666' O0 666- ~ND~ O0 66' D~ O0 66' O"~g O0~I ' ~OHa OHHO 00~:666' 00Sg,666' 00~:666' O0~g 666' O0~g 666' OOS~ 666- 00~ 666- 00~'666- ~66~' O0~i ~ND~ 00~: 30~ OOS; HD 00! i66- £&D~ O( V~N~ 00! ,66' OHiO oOSi ,6- ~D 0001 ~q! 6~9 00;~!666- 9~3& 001~ 666' &~3H 00Gti'666- ¥SN& oO~g~666- ,HuG oosg='666- aD o,,,:e,et wqI tLOI~ O0~g:666- ff~ OOGg:666- &~Da O0~666- DaJ& 00~'666- aD O0~:666- &~Da 006~.666' VHN& OOgg 666' ~OHa 00!...-666' ;666' 00~:666' oo~;~ o0~g i ~8'6~ ~N3~ 00! 666- 3&ND O( D~JN O( 666- ~NDB O~ i66' 303~ O, 666' gN3& O~ 3&N3 9N3& gN3& 3&ND IHdN 0Sg:'666' 00!~g'666' '666' 00!.,666. 00! 666' ii' O0 i.6668 666' O0 '~666- OOf '666- OOf 00g!:666- OOS .666' O0 00~ .666' ~Oi .666' ;666- OOSg:666- 00~g,666- O0 .OOb' 00~ ,666' ~666~ OOg~ 666' gN3~ 3~ND IHdN 303N ~g N~ HdO lHdN IqYD H d N " DO~N O0 ' IHdO nq~ 6 6~ ~d~a: ~D OOS~ ~66" IHdO OOg~ ,6- OH~ 3~N3 i6- IHdN O0 ' 3~3N O0 ' lH,d~ o, os oos '. 00~I ,'666' ' 6660 : ;666- ;666' 0000 OOT~ 00~666- O0~g :666s :6660 00$1 OOg~ ~D 00gg~666* 3~3 O0~t :666- ~N~ OOgge666- IHdO 00gg:666* OHiO DN3Z 00g~,666' 3ZND OOG~.666- DO~N OOg~ '666' ;L a;:) H I~dCl gN3~ &d3Cl )l 3DYd DNI&glq NOIIVDI,JI~IL, IA gOH~OlO ~lAq 0 I~ 0 00i i6i 00t 6 GL6 G O0 6- 89 O0 ~q! 90L OOS~ 666' 000 0~0~ &JDH ~8 0 ~86T ooo :ts .4¥ oooo;~/o, °°i 9N3& 00~ &#3H O01 ~ O0 OHHO H~ 000 Nq! OT~ 666- 666- 00Gt'666' ~N~& OOB '666' ~J 000~ 9 gOHU ~N3~ P~ O~Z T D~JD OT UN~U D&ND ~ TT ZHdN nqJe 00( $~ 3aJN lHdO L gN3& OOS~: lqVD ~N3& 8E69 90HU gN3& 1666- 66$ Cf'Il 966~ 't %HdN OOS~ gOHU aq! 666- '666- '969 6 66 '6 ~ oo ~. ;:) 00~I'666- IHdN flqdg 00' ~Lt dg &d3Cl &, d &JDU N~H )~ i66i HdQ i OH~4 ~,.~~: ii' D&iD DOJN %Hdq Iq~ 000( ~t NqJg 0000 O06t &d3~ HD 005;~:666- 3~.43 00gg'666- i66~ Od 00~ O( 0¢ O( :'iii Ot ' 00! 00! O0 O0 08 00! 666" 00~ 000 gN3& OOS AND. O0 oa~ o0~ 666' gOH~B~ ~ 666'666. ~JDB O0 666' V~N& O0 666" OHiO 00! 666' N~; 0000 0000 O00g O0 gN3& 001 66 $NDB 00' Da~ 00~ gO~'~ O0 '6' 00~ ;6' ~JDB 0 V~N& ~, 66- gN3& A~DU VUN~ 00Sg~666- O0~g~666- 00~g.666- L, 8T 00066L HdN 0 ~ iqV3 O0 ' ~N3& O0 66- &ND~ O0 66- gOH~ i66- AND IHd~ gg3& OH~ gN3& gN3A ~NDU ~N3~ gN3$ ;6- 00' 00' ~666" OOg~: 666,. 666' 666' Ol 666' i66' i66' 00! ;66' 00! 666' 00~ 666' O0 : 666" '666' ~666' .l~Ol OOG~ OOgg' 666~ 666' 00o0 IHdO 00! N3& ~HdN 00, .66" oooo 00! BNZ8 OOg; ZHdO OOS; .- I~$~ OOi DOJN O( aD 00~,~ D&JD O( BN~ 00! !H~ O0i ~ND lXdN 00' i66' OaJN nq,g O000:~t OOSi i66- OOGi 001 ,6' 666' O( 666* 666' OOg; ;6- OOSl IHaO AND !HdN 'm VBNA °"2 ~Haa 3& oNHo lHda Ad3a lXdO OHaq ZHdN UNA8 3GJN IHdq 9{ 3DVd DNT;r. gIEI NOIAVDI.dlH3A g;o~iol;O'dAq ~VP 010~H02 V£RIFICATION LISTING PAGE RCFT GR DE:PT SP TENS DPH! RTNR CFTC DRNO TNRA ,CFT R DEPT Se TENS RTNR DR~O TNRA GR DEPT RT~R RHO NRA GR DEPT T~N~ -999,2500 '999,2500 3900 0000 SFbU -99! 1500 GR -99' 1500 CAb! NPH! -999 1500 CNTC lO0 DPH~ iO0 RTNR -999 GR ]800 ,00 -999 -999 ;00 -9~9 )0 )0 SFbU GR CALl NFDC NPH! CNTC TENS RTNR ]701,0000 -'9d9,~500 GR '999"2500 NFDC -999e~500 NPHZ -999*2500 CNTC e999,2500 TEN& - O0 DPH! '~9~'t~00 RTN~ ~000 *0 ~0 ~0 ~00 )0 tO0 )oOo m; NFDC NPH! CNTC TENS DPHX RTNR '999.. O0 '999,2500 -999; '999 '999 "999, O0 '999 [500 -99~ "! iO0 .¢ !0 '99' '999. ~00 '99! ~00 -99! )0 -9! -' 'SO0 58 ~063 -99! gO0 -99! !.500 -99! iO0 '! ~0 -999 e999 -999 1500 50 m999 '999 '9! '9! '9! '999 '99~ 1500 ~999~ 1500 '999.2500 CtaTC TENS !LD TEN& RHOB FFDC RCNT TENS CAb! ~DC NPH! CNTC TENS ILO TENS RHOB FFDC RCNT TENS Ckb! NFDC NPH! CNTC TENS TENS RHOB rroc ~CNT ENS NFDC NPH! CNTC TENS 9 500 -999 2500 -999 O0 "999 500 '999 :~00 '999 ~00 -999 500 '999 500 '999 500 3330 000 -999, 500 -9 - 0 :!9! ~0000 "99 500 $00 -~ 500 - 500 - O0 -9 500 "99! 500 '999, 500 3224 000 XLD '9 :500 TENS $00 RHOB - O0 FFDC ' RCNT TEN~ CAb! NFDC NPHX CN~'C '9 iO0 ?~N8 3~:0 ~000 It, D RHOB "9 ~ 0 TENS "999,2500 XLN -9~ iO0 GR "* )0 DRHO -' iO0 TNRA RCFT -9~ GR ' O0 RHOB * O0 rDC C#~ TENS -' )0 DRHO TNRA RCFT GR RHOB RCNT ~ENS -999 O0 TNRA RCFT ~:0 GR eg' O0 RHOB rroc RCNT 0~ ~0 TENS -' DRHO TENS R DRHO -9' ~0 O0 00~ 0:i O~ Ol O! ~- 001 . m O0 " m m ~ O0 666" 6- &N3~ 00! ~OH~ OH~Q Oi 666~ O~ OE ~ND& 0 6~ &NDa 00! DO.ag 00~ 0 ~N~ 0~0 0 66' 00! OOOoo ~0~ OOG ~O~D 00~ . VaN& OOS .666- Wq! OOf '666- 000 &NDhl OOS 666" Da&J OOS 666' gOHtt 000~ 666- aD 0 666" ~$ 0 OH,O 0~[ - 00~ gN3~ 00o0!)%%£ 00~%!666" oo~g:66e- oo~:666- gOH~ DOaN gN3~ 6OHU D~ND IHdN gna& %HdN gOHU gN3& %HdN NDU OOt 66- OOf i66- OOt O0 666' 666- O0~l 666- .6 '1666' ,666- 00' ,661 :666- ,666- 00~666' OOg~' 66 00$~.666- 00S:1666- 00f:.666- O0~ .666' OO! .666' OOG~ 666' ~g90:%9 00Sg.666" 00f~.666' 00tg.666" 666- 00G11666- o0t~.666- o0f~666- o0f~.666- oof~ 666- lHd(:l OOtl ," D&ND ;6" IHdN O0 DOaN O( l"ll~ O( ,- {]qag 00~ ~lD O( D,i, DD I: FI~Cl00! IHdN O0 :)ClatN O0 ' ~IN,i, ti ~6" IHdO ~NDZ O( 35N3 6": Itt(IN O( '6' 3(I~N O( ' Iq¥::) ~JD OOiil ~tN&U O0~G I Hel(l OOG~ gna& OOG; :)~N,,3 OOill; IHdN DO~N O( I~I~ 00~ ,0 00' UN& a %HdQ OH~I g:N D~ IH ;N &d~ &aDH VaN& OHUQ UD UN a &d30 D&ND 3&aD iHdN ~N$~ DO~N iHdO 9% 3D~d DNI&glq NOI~VDIaI~A ~OH'*OtO'dA1 6T O~ O{ O( 666' O( 00 666' ,0 00! O~ ,41 00 ~- O0 00St*666"* 3DYd OHHCl DQ'~J YH:N& OHUO ooG~ oo~ 666o o00~ 00! 00! o o ONaO 00! - 9N3& NDH GOHU Ug gND,,T, 000 OT6C 00~ 6660 OOG 666~ O0i 666u 0 68 og 00~ 00~ 16' OOf~ 666o O0 08~ 00~ 0 666- OOG 666- 00~ 606' 666° OOG 6660 OOG 666* OOG 666' OOG 666* OOf 666* 000 '088~ 00~'666"' 80H H D&ND ~OX~ gNDZ HdN gNl& ~OH~ D~N3 .tHdN D~JN SS3& NDU aoHu D&ND IHdN DOaN gN3& gOHH gN3Z ~ND,L DI, ND OOi 666- OOg O( O( O( 66- 6- 666i O0 00' O0~ '666' OE 666' O0i 666- O( 666' Ol OOi 001 OO! i66' 666' 00~i'666" 00' 00~ 00;~:666- OOS:' 666' 00~.666- oos~666- o0~'~6- ,666- ,666= OOfl 666' O0 DNI£~Iq IqVD 001 ,o ltd 00! ~,, ~Ng~ DO~N: 006; OOg; 00! 00~ 00! 00! 00! aN:&~ 666' iHdO 666- gS3~ D&:ND OOt; iHdN 001 DOaN 00! 001 666= IHdO ~6' o0, DIND 00~ IHdN OOtl 666' DOaN 00t~666- a9 00~ 666' nqD:g 0000 006~ gN3, ~g 001 ,6' D&aD 00! ,6o IHdO 00' ,o gN3& 00! ,o 3&ND 00! * ZHaN OOS~: )6- UN~ ~Q&N OOtl ~ ~ 00~ ~tS 0o00 O0Of ~g 00g~'666o aD ~OI&VDIJlaDi ~OH~O~O dAq 00~ O0 O0 ,., em. OI O~ 00 O~ O~ 00! o 04 04 Ot O0 i6o O0 164,. O0 ND00~ 6- 0 ~6o, oo &~'D~ 660 660 VaN& 0 66' OH:aa 6- N 00~i ~66- 000 9N3~ OOS 66 i ~N~H 00! 666- 00( gND~ Da,da aD 00! O000~OLLt gg3& 00~Ci666' DO~ 00~t~666 eOHU OOSC:e66- ~D 00S~,~66,6- ~N& :666- OHUa ~666' Hq! 00S~'666' O000tOOeC ~N3~ 00~,666' DO&~ O0 ~666" .666' &aD~ O0 ,666' VSN& O0 666' HdN gN3~ ~ND8 HdN DOaN BOH~ gN3~ ZHdN ina& gN3& &NDB gOH~ gN3~ gN3~ gna& 00~ i66" 00! - O~ ~6' OOt 6i 00~ 00~ 6' 00~ 6' 00~; 66" 666- O0 666" 00~.~ 666' 0 0 666' 00~ 6668 00~ 6660 ~90~'~ o0~e:666- oos~,ee6- oosc,666- oo~c:666- oos~ 00~ 666' OOGg 666' O0gg 666' e, 6 OOS~ .666- ;666' ,666' 6666 IH~N 00! 00~ 00~ 000~ lmm HdO D&ND ~H~N O0 O0 O0 0 00~ 00~ D&DD 0 ~N~ ~666e D&N3 ~ IHdN 00! ;666~ DOaN 0 ?666* flq3g 0 °00~ OHa~ d ,Ld3 ,D 00~666o D&ND 0 ~666' DOaN flqag 0000 00~8 &d3O 00S~;666- &aDd lHda .666- OHUa gN3~ 00St,666~ D&ND 00S~,666" 00~ ,6' 0 ( 0:! 665:" Oi ii( O~ 00! i6'" " 666' OO o, O~ i66: 666- 04 00! 01 04 666- 00tg'666" ~N3~ iN3{ 3O,,dN gOH~ ~a3,!r, OOG~ 666' 666' SL~t t~ 00~ 666' 66 gN3& 00~,666' ~&ND O0~,666- &ND~ 00~,666- XHdN oO~;666- DOJJ O0~Z 666- DO~N OOS~666- gOH~ 00i~'666- I~D OOS&=666s ~&DB 00G~:666' VaN& 006~,666- OHiO OOg:Z 666- gOHB 006 : 6660 u~ oose: .~' 009~ 666- 000 09~ N3 ~OJ~ OOS; 3O&N O~Ba OOg666- NqX 00~ 666- 00S~,666., 0 O~G~'666'.666' 006~;666- 00~ '666' 00~[ 666- 666- 0 0 &~D8 006g,666' ~a~ oo~z 666- aD OOG~. 666- O0 ~JDB 00~ 666- vaN& 666- O,H~ OOG~ 666- 666- D&ND O~[.666- ZHd.0000~ '~i66-'66' DO&N XqVD o~ 6 ~N3& ~ 6660 &ND~ O0 666' BOH~DO~3 000611666' 666' 006 666' O000'~E9~ gN3& 009~'666' 3&N3 666- lHdO DOJN XHdO HdN ~JN HdN OOg~ 00! 00~ oo, O0~ 00' 00 g 0000 00~ 666" 00! 006; 0061 00! 00~ i6T OOS; 666" 00' O~ Ot O, 006[ 666' 0000000[ 006~,666' 00~g'666- 0000 00{~ 006 ~666 o06 '666- 31; oHa U~ II &d3; ~N3& IHdN DOJN lHdO XqV3 nq3~ LVP 010,H02 VER[FICA?ION DPH! RTNR CFTC GR DRHO TNRA RCFT GR -999 2500 -999 2500 -999 2500 -999 2500 i999'999 {~ -999 2500 -999 2900 ~ENS 2500 DpH! -999 1500 RTNR -999 1500 CFTC -99 500 Ga -99 500 DRHO . 500 TNRA , 500 RCFT -9, 500 GR -999 500 DEPT UPH! RTNR CFTC DRHO TNRA RCFT DEPT RTNR CFTC TNRA RCFT DEPT P ~gNs RTN~ CFTC ORHO TNRA 15000000 -9 iO0 -999 e99~ -999 iO0 '99:9 '999 2500 NFDC NPHI CNTC TENS DPHI RTNR TTC NFDC NPHI CNTC TENS DPH! RTNR CF?C LISTING '999,2500 "999,2500 '99~'2500 -999,2500 41,1875 -9992500 "999 2500 '999 2500 "999 -999 2500 -999 2500 -999 999 2'500 22 9375 50 CA~I '999, !50~ NFDC -999 )0 Ng~! ~ggg ,o DPHI -99' }00 RTNR -99! iO0 CFTC "gg' iO0 GR 2~ 594 riO0 0000 SFbU -99g -,9, -999 NFDC '99 NPHI -9 iO0 CNTC - ;00 DFHI -99' RTNR .9 -g99 1500 -999 )0 -ggg -ggg iO0 -gg! ~00 '( )0 -999 'g9! ~00 " }00 41 ~000 13000000 '999 2900 '999 2'500 O0 '999:2500 '9 2,00 2500 -999.2500 SFL'U 'gg9,2500 '999,2500 NFDC '999;2500 NPHI "ggg.2500 NTC -99! )0 EN$ '9! )0 DPHI "g99 )0 aTNR -ggg ~00 FFDC RCNT TENS NFDC NPHI CNTC TENS ILD TENS RHOB rrDC RCNT CALX NFDC N~H! CNTC TENS I:LD TENS RHOB FFDC RCNT TENS CALl NFDC NPH! CNTC TENS ILD TENS RHOB FFDC RCNT TENS CALl NFDC NPHI CNTC TENS ILD TENS RHOB FFDC ~CHT IENS AL! NFDC NPH! -ggg,2500 O0 000 N A GR RHO8 FFDC RCNT -999, -999l -999~ "999, "999' -999~ 2220; '999 I 2500 G~M O0 {Ob DRHO 500 TNRA 500 RCFT 500 GR 500 RHOB 900 true 500 RCNT '500 TENS 000 O0 O0 -999 TNRA "'999 RCFT ,250 RHOB 250 rFDC ° 2220,000~ TENS -9g 2500 l~a '99 !500 -99! ~500 DRHO ' 0 TNRA 99 ~0 RCFT O0 RHOB ~999 O0 FFDC 'gg9 ~00 RCNT ~0 -999,2500 t~ '999,2500 -g99,2500 ~R~O m999'2500 ~NRA '999,2500 RCFT -999~2500 OR -999,2500 RHOB -999~2500 FFDC -999,2500 RCNT PAGE 22 )0 ~00 ~0 ~00 O0 O0 0 0 ~00 ~00 ~0 ~00 ~00 ~00 ~00 )0 )0 ~0 ~0 ;00 ~0 ~00 iO0 LV~ OtO,H02 VERIFICATION LISTING PAGE 23 FT PEPT DPH! CFTC ORHO RCFT DEPT TENS RTNR CfTC DRHO TNRA RCFT GR DEPT TENS CFTC VkHO TNRA ~CFT '999.2500 CFTC *999.2500 GR -,,,' '999, .2500 NPHX -999;2500 CNTC *999;2500 TENS *999,2500 DPHX **999,2500 *999,2500 CFTC =999.2500 t; 0000 SFLU ** 2500 GR -9 3500 CAL! ~9 NFDC -9! !500 NPH! * 1500 CNTC - !500 TENS -99! 1500 DPN! -99! 1500 '-99! )0 CFTC ~999 GR i~ 0000 SFLU - ~500 **9: -: ~500 NFDC ~' NPHX =' CNTC -~ 1500 TENS ~9! ,00 DPH! *9! iO0 RTNR "9! ~00 ~TC ~9! 1500 992 )00 -9 *99 NFDC **9 $00 NPH! ~9' 500 CNTC -9: 1500 TENS DPHI RTNR FXL[ILE TRAILER ** NAME IED[T ,00! -999,~500 CNTC 31,7656 TENS -999 =999 -999 *999 *999 =999 '999 '999 '999 '999 41 2500 ILD 2500 TENS 2500 RHOB 2500 FFDC 2500 RCNT 2500 TENS 3500 C~bl 2~00 NFDC 2 O0 NPHX 2500 CNTC 3750 TENS -999,2500 ILD -999,2500 TENS *999,2500 RHOB -999;2500 FFDC -999,2500 RCNT ~999.2500 TENS .999,2500 CALX ~999~2500 NFDC ~999,250.0 NPH! 999~2500 CN?C 46;03t3 TENS -999,250~ LD -999.250u ~ENS -999,2500 RHOB -999.2500 FFDC ~999.2500 RCNT -999.,2500 CALX '999;2500 NFDC '999.2500 NPHX '999*2500 CNTC 35.03t3 TENS *999,2500 IbD '9~,:2500 TENS -99:~,2500 RHOB O0 RCNT **~.2500 TENS '999,2500 CALl -9~,2500 NFDC '999.2500 NPH! =9~*:2500 C~TC ~7,28t3 TENS -999.2500 TENS 2050.0000 ~999,2500 IbM 999,2500 GR *999.2500 DRHO -999~2500 TNRA *999,2500 RCFT '999~2500 OR '999.~ RHOB **999, FFDC =999;2500 RCNT -999~2500 TENS 1.945,0000 -999, -999, *999 "999 "999 *999 1950 2500 !O0 GR 0 DRHO ~0 TNRA O0 RCFT -999 *999 *999 =999 -999 -999 -999 *999 *999 *999 1860 o RC~? 500 GR 500 RHOB 500 rrDc 500 RCNT 0 TENS -999' GR -9, : ~3500 RHOB ,2500 RCNT ,0000 -999.2500 -9 ~SO0 **! O0 "! O0 **999 ~SO0 "999,3~00 -99 ,~00 .,,;.t:ioo -999,~S00 o999~S00 0999,:2S00 ,999, 2s0,0 - iO0 =9993500 *.9~ ,,, iO0 -9! )0 O0 0999 -99~ " iO0 )0 )0 ~00 O0 000~ 000~ 00~ 00~ o Nil* 0 0 0 0 0 O0 0 0 o0 0 0 ~o0 0 0 O0 o O0 o ¥o 0 0 0 8 o o oo oo O00 O0 0o0 O0 000 O0 OO oo oo O0 O0 O0 Sd3 Sd3 HN3 aOHU 0 o0 o0 0 TO O0 f3/9 0 0 {0 O0 ~3/9 0 0 O0 NI 0 ~ O0 9q XOJ 0 0 TO oo ldVD HOd 0 O0 000 O0 ~J ~3q g~bOqg NOZ&V31~I33a~ 99 99 S9 99 99 3Zig 6 6 IdX~ 3WVN 33IA83~ t 3WVN 3qI& &X3N I # aOI~a3A {~g 3DVd 9Nl&Elq NOIiV3IjIBgA ZOH"OtO JA'l ~0~ 8~g6 O0OS,SL9 ~9S96 0000 L g906 ~ O00~,06L B~L9 9 S~ 3DVd OaJN HdN DO&N DG~N ~N~ lqV3 HdN 3Q~N HdN IqVD DO~N gN3Z gN3~ ~N&~ ~N&~ ~H~G ~N~ XHdO anna XHda dN&d lHd~ GLST (09L 8TgL [~00 LGT 06~9 8606 cato o~9 ~0 00~ 8EfT OOSL SLE6 OSI9 L950 90T6 Og~ 0~9 t~$o Og~9 eT l T L L t6 908 0 96 0 96 L9 0 LET LET 9L9 0 LET DNligI1 TOO' Ug OHttCI VdN& OHiO Ug V ~1N3r. ~D ,1C,~3u VUN,t UD YUN& OH~O J, J3~l OHUo ~lg 000 *' 9 oooo ooo~og6L O00~9~L 0O8 "80Z:8 0000. 88 00 L 8 oooo:r, L 9Lg8,t g; 0000.9 t ~LSG,~ ee6t ooee o000 ~I08 ttBg 6T 0000 OL9 6~6t t 686t 0068 gN3& gN3$ gS3~ ~ND8 ~O,Ha ~d3O gN3& &ND8 &d3a gN3& gOH &d3~ ~OH gOH NOZ~VDIJZ~3A ~OH*OTO dAq 10) ~ NOI&V~NI&NO~ LLS~L: 3WVN q33a : NIDISO B /~O/8B: 3&V~ &I03: 3~VN g~IA~3~ t6OOg-tOg-Og # Id) ~O~-H( ~ABVdA~ ODBVWglq ~IO3:g~N3WW03 ~ 3NVN 3dV~ ~X~N 10: # NOX&VONI&NOD LS;LI ~IDIUo : 3W~N 391~ &X3N 3dX& 3~I~ ~Ot : H&gN39 W~IXV~ DNI~919 NO)&Y~I~IB3A ~OH~OtO