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185-259
1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Replace Tubing Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8123'feet None feet true vertical 6261' feet 7890'feet Effective Depth measured 7890'feet 7413', 7521', 7744'feet true vertical 6120'feet 5808', 5881', 6028'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 2-7/8" 2-7/8" L-80 J-55 7494' 7761' 5863' 6039' Packers and SSSV (type, measured and true vertical depth)7413' 7521' 7744' 5808' 5881' 6028' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 2982' 2833' Burst CollapseCasing 6253'8108' 110'Conductor Surface Production 16" 9-5/8" measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 185-259 50-103-20050-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025587 Kuparuk River Field/ Kuparuk Oil Pool KRU 2H-09 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) 180 Gas-Mcf MDSize 110' 1204 1279174 Well Shut-In 206 324-518 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: BAKER FH Packer Packer: BROWN HB HYD Retrievable Packer: BROWN 1B Packer SSSV: None James Ohlinger james.ohlinger@conocophillips.com (907) 229-3338 RWO/CTD Engineer 7678-7718', 7790-7806', 7832-7872' 5985-6011', 6057-6067', 6084-6109' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov 74' 2946' 8075' By Grace Christianson at 9:15 am, Nov 12, 2024 Digitally signed by James J. Ohlinger DN: C=US, OU=ConocoPhillips, O=Wells - Coiled Tubing Drlling, CN=James J. Ohlinger, E= James.J.Ohlinger@cop.com Reason: I am the author of this document Location: Date: 2024.11.11 14:16:27-09'00' Foxit PDF Editor Version: 13.0.0 James J. Ohlinger Page 1/6 2H-09 Report Printed: 11/6/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/6/2024 00:00 10/6/2024 07:30 7.50 MIRU, MOVE WAIT P Stand by on 2B pad for road matting to 2H 0.0 0.0 10/6/2024 07:30 10/6/2024 13:30 6.00 MIRU, MOVE MOB P Mob rig to 2H pad 0.0 0.0 10/6/2024 13:30 10/6/2024 16:00 2.50 MIRU, MOVE RURD P Spot rig over well // safe out rig // perform rig accept checklist // Rig Accepted 16:00 // Initial Pressures T/IA/OA = 0/1700/0 0.0 0.0 10/6/2024 16:00 10/6/2024 20:00 4.00 MIRU, MOVE OTHR P Take on 12.4# KWF LSND mud // Start rigging up for well kill // Set tiger tank and open top // Set circ manifold 0.0 0.0 10/6/2024 20:00 10/7/2024 00:00 4.00 MIRU, MOVE RGRP T BOP lifting winch. Remove and replace 0.0 0.0 10/7/2024 00:00 10/7/2024 01:00 1.00 MIRU, MOVE RGRP T Continue BOP cellar winch replacement 0.0 0.0 10/7/2024 01:00 10/7/2024 03:00 2.00 MIRU, WELCTL RURD P R/U well kill manifold.Pump open SSV Initial T=1600 PSI, IA=1700, OA=100 0.0 0.0 10/7/2024 03:00 10/7/2024 03:30 0.50 MIRU, WELCTL SEQP P PT kill manifold and lines to tank 3000 PSI\- 0.0 0.0 10/7/2024 03:30 10/7/2024 03:54 0.40 MIRU, WELCTL SFTY P PJSM for well kill ops. Line up on seawater for initial circulationm 0.0 0.0 10/7/2024 03:54 10/7/2024 06:00 2.10 MIRU, WELCTL KLWL P Open IA to choke, Bleed off to 120 PSI. Shut in swap over to tubing. Tubing showing zero. Double check line up - Good. Start pumping down tubing taking returns out IA mainbtaining 1 for 1. 3 BPM @ 208 PSI. Rising slightly as seawater turns corner. 0.0 0.0 10/7/2024 06:00 10/7/2024 07:00 1.00 MIRU, WELCTL OWFF P Observe will Pressure 360 psi @ 5842 tvd = 9.9# Equiv mud wt // Develop plan for KWF 0.0 0.0 10/7/2024 07:00 10/7/2024 12:00 5.00 MIRU, WELCTL WAIT P Wait for 10.3+ NaCl/NaBr 0.0 0.0 10/7/2024 12:00 10/7/2024 13:30 1.50 MIRU, WELCTL DISP P Displace well w/ 10.3 NaCl/NaBr 0.0 0.0 10/7/2024 13:30 10/7/2024 14:00 0.50 MIRU, WELCTL OWFF P OWFF 30 min well on vac 0.0 0.0 10/7/2024 14:00 10/7/2024 15:30 1.50 MIRU, WELCTL MPSP P Rig down circulating equipment // Set BPV // Test below 1000 psi , rolling test due to leak-off 700 psi achieved // Rig down test equipment 0.0 0.0 10/7/2024 15:30 10/7/2024 18:00 2.50 MIRU, WHDBOP NUND P Nipple down production tree, check hanger threads, install bull plug in hanger for SSSV control line 0.0 0.0 10/7/2024 18:00 10/7/2024 20:30 2.50 MIRU, WHDBOP NUND P Nipple up BOPs 0.0 0.0 10/7/2024 20:30 10/7/2024 23:30 3.00 MIRU, WHDBOP OTHR P R/U test equipment, Flood lines, grease valves 0.0 0.0 10/7/2024 23:30 10/8/2024 00:00 0.50 MIRU, WHDBOP BOPE P Obtain shell test on BOPE 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 10/13/2024 Page 2/6 2H-09 Report Printed: 11/6/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/8/2024 00:00 10/8/2024 06:30 6.50 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/3000 PSI for 5 Min each, Tested annular, UVBR's, LVBRs w/ 2 7/8". Test blinds rams. Choke valves #1 to #13, upper and lower top drive well control valves. Test 3 1/2" IF FOSV and IBOP. Test 3 ½ EUE FOSV. Test 2" rig floor Demco kill valve MM #13. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=3000 PSI, after closure=1700 PSI, 200 PSI attained = 20 sec, full recovery attained = 119 sec. UVBR's= 5 sec, LVBRs= 5 sec. Annular= 14 sec. Simulated blinds= 3 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average = 2050 PSI. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Sulley Sullivan 0.0 0.0 10/8/2024 06:30 10/8/2024 09:30 3.00 MIRU, WHDBOP BOPE P Drain stack. Prep and change out UPR's 2 7/8" X 5 1/2 Variable rams. 0.0 0.0 10/8/2024 09:30 10/8/2024 10:00 0.50 MIRU, WHDBOP BOPE T Fill stack, Fluid pack lines 0.0 0.0 10/8/2024 10:00 10/8/2024 12:00 2.00 MIRU, WHDBOP BOPE T Test variable rams with 3 1/2" test joint - Good. Test with 2 7/8" joint - Fail 0.0 0.0 10/8/2024 12:00 10/8/2024 13:30 1.50 MIRU, WHDBOP BOPE T Drain stack, bleed off Koomey. C/O UPR from 2 7/8" X 5 1/2" variable to 2 7/8" fixed 0.0 0.0 10/8/2024 13:30 10/8/2024 14:30 1.00 MIRU, WHDBOP BOPE T Fill stack, Purge air. Test 2 7/8" fixed ram 250/3500 Pass 0.0 0.0 10/8/2024 14:30 10/8/2024 15:00 0.50 MIRU, WHDBOP RURD P Rig down test equipment 0.0 0.0 10/8/2024 15:00 10/8/2024 16:00 1.00 MIRU, WHDBOP MPSP P Pull balnking plug and BPV 0.0 0.0 10/8/2024 16:00 10/8/2024 17:00 1.00 COMPZN, RPCOMP RURD P Monitor for fluid loss, Spooler in shed, Install mouse hole. Static fluid loss 2.2 BPH. 0.0 0.0 10/8/2024 17:00 10/8/2024 18:00 1.00 COMPZN, RPCOMP RURD P M/U Joint to hanger threads, Threads on X-O only went in 7 turns. Pull joint of new 2 7/8" tubing Cross over to 3 1/2 IF Make up to hanger. K/U set 10K down BOLDS. 0.0 0.0 10/8/2024 18:00 10/8/2024 18:30 0.50 COMPZN, RPCOMP PULL P P/U on string pipe free @ 85K. PUW=74K. Pull hanger T/ RF cut @ 7489' T/ 7449'. 7,489.0 7,449.0 10/8/2024 18:30 10/8/2024 19:00 0.50 COMPZN, RPCOMP OWFF P Obtain static loss rate of TT ~12 BPH. 7,449.0 7,449.0 10/8/2024 19:00 10/8/2024 19:30 0.50 COMPZN, RPCOMP CIRC P Circ STB 45 Bbls down TBG @ 2 BPM, 220 PSI, taking dirty returns out to cutting tank. Fluid on IA apeared to clean up. R/U HES spooling unit. 7,449.0 7,449.0 10/8/2024 19:30 10/8/2024 20:00 0.50 COMPZN, RPCOMP PULD P L/D hanger & 2ea 2 7/8" pups. Break out landing joint & L/D. B/D TD. 7,449.0 7,437.0 10/8/2024 20:00 10/8/2024 22:00 2.00 COMPZN, RPCOMP PULL P L/D 2 7/8" completion, spooling up SS control line F/ 7437' T/ 5694. PUW=74K. 31 SS bands recovered. Well drinking ~ 4 BPH. 7,437.0 5,694.0 10/8/2024 22:00 10/8/2024 22:30 0.50 COMPZN, RPCOMP RURD P R/D HES spooling unit. 5,694.0 5,694.0 Rig: NORDIC 3 RIG RELEASE DATE 10/13/2024 Page 3/6 2H-09 Report Printed: 11/6/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/8/2024 22:30 10/8/2024 22:45 0.25 COMPZN, RPCOMP PULL P L/D SSSV & 1 joint T/ 5644', PUW-65 5,694.0 5,644.0 10/8/2024 22:45 10/8/2024 23:15 0.50 COMPZN, RPCOMP SVRG P Remove backup tongs from double stack. Sheared pin made them unusable. 5,644.0 5,644.0 10/8/2024 23:15 10/9/2024 00:00 0.75 COMPZN, RPCOMP PULL P Cont L/D 2 7/8" completion F/ 5658' T/ 5217 PUW=65K. , 6,544.0 5,217.0 10/9/2024 00:00 10/9/2024 07:00 7.00 COMPZN, RPCOMP PULL P L/D 2 7/8" completion F/ 5217 T/ 15.06 Cut joint PUW=65K. , 5,217.0 0.0 10/9/2024 07:00 10/9/2024 07:30 0.50 COMPZN, RPCOMP BHAH P Clean and clear in rig floor 0.0 0.0 10/9/2024 07:30 10/9/2024 08:30 1.00 COMPZN, RPCOMP RURD P Drain stack, R/U to swap out UPR from 2 7/8" fixed to 2 7/8" X 5 1/2" variable rams 0.0 0.0 10/9/2024 08:30 10/9/2024 09:30 1.00 COMPZN, RPCOMP MPSP P Set test plug 0.0 0.0 10/9/2024 09:30 10/9/2024 10:30 1.00 COMPZN, RPCOMP RURD P M/U 2 7/8" donut test joint, R/U testing equipment, Fluid pack BOP & lines 0.0 0.0 10/9/2024 10:30 10/9/2024 12:00 1.50 COMPZN, RPCOMP BOPE P Test UPR's 2 7/8" X 5 1/2" variables with 2 7/8" test joint and 3 1/2" test joint, 250 low 3500 PSI High. Test witness waived by Sully Sullivan, AOGCC 0.0 0.0 10/9/2024 12:00 10/9/2024 12:30 0.50 COMPZN, RPCOMP RUNL P Blow down and rig down testing equipment. B/D choke and kill lines, Drain stack 0.0 0.0 10/9/2024 12:30 10/9/2024 13:00 0.50 COMPZN, RPCOMP MPSP P FMC here. Pull test plug. Install wear ring 0.0 0.0 10/9/2024 13:00 10/9/2024 14:30 1.50 COMPZN, RPCOMP BHAH P Load BHA # 1 to floor / Shed. M/U BHA #1 dress off w/ 6 1/8" string mills T/ 161' 0.0 161.3 10/9/2024 14:30 10/9/2024 22:30 8.00 COMPZN, RPCOMP PULD P PUDP F/ 161' T/ 7375''. PUW=140K, SOW=95K. 161.3 7,375.0 10/9/2024 22:30 10/9/2024 23:30 1.00 COMPZN, RPCOMP REAM P Obtain parameters pump @ 2 BPM, 280 PS, 3 BPM, 580 PSI, 5 BPM, 1450 PSI. Rot @ 20 RPM, 3.5K Free Tq. @ 50 RPM, 4K Free Tq. Ream down, back up, & back down F/ 7375' T/ 7465' @ 5 BPM, 1450 PSI, 4K Tq, ROT=112K. 7,375.0 7,465.0 10/9/2024 23:30 10/10/2024 00:00 0.50 COMPZN, RPCOMP MILL P Pump 3 BPM, 580 PSI. Wash over TBG stub saw PSI increase T/ 635 PSI @ 7477'. Set down 10K @ 7483'. P/U T/ 7470'. Rot @ 30 RPM, 4K Free Tq. Ream down saw PSI increase agaign @ 7478'. Tq increase T/ 6K @ 7482'. Mill T/ 7484'. 7,465.0 7,484.0 10/10/2024 00:00 10/10/2024 00:30 0.50 COMPZN, RPCOMP MILL P Continue dress of tubing stub T/ 7484' shoe depth. Kill Rot wash over stub verify PSI increase @ top of stub 7478', take weight 7484' shoe depth. 7,484.0 7,484.0 10/10/2024 00:30 10/10/2024 01:15 0.75 COMPZN, RPCOMP CIRC P P/U T/ 7469'. CIrc 29 Bbls hi-vis pill around @ 5 BPM, 1115 PSI. 7,484.0 7,469.0 10/10/2024 01:15 10/10/2024 01:45 0.50 COMPZN, RPCOMP OWFF P OWFF - No flow B/D TD. 7,469.0 7,469.0 10/10/2024 01:45 10/10/2024 04:30 2.75 COMPZN, RPCOMP TRIP P POOH F/ 7469' T/ 161', PUW=140K. 7,469.0 161.0 10/10/2024 04:30 10/10/2024 07:00 2.50 COMPZN, RPCOMP BHAH P Lay down BHA #1. Send out of pipe shed 161.0 0.0 10/10/2024 07:00 10/10/2024 07:30 0.50 COMPZN, RPCOMP BHAH P P/U BHA #2 Test Packer 0.0 18.2 10/10/2024 07:30 10/10/2024 11:00 3.50 COMPZN, RPCOMP TRIP P Trip in hole BHA #2 test packer to 7461' 18.2 7,461.0 10/10/2024 11:00 10/10/2024 12:00 1.00 COMPZN, RPCOMP CIRC P Circulate s to s. 6.5 BPM @ 1980 PSI 7,461.0 7,464.0 Rig: NORDIC 3 RIG RELEASE DATE 10/13/2024 Page 4/6 2H-09 Report Printed: 11/6/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/10/2024 12:00 10/10/2024 14:00 2.00 COMPZN, RPCOMP MPSP P Set test packer, 7455 COE, Attempt PT. no go. Retest double block. No better. PUH 24'. COE 7424'. Retest good. 2500PSI/15 minutes. Release packer 7,464.0 7,440.0 10/10/2024 14:00 10/10/2024 21:00 7.00 COMPZN, RPCOMP PULD P POOH laying down DP T/ 18', PUW=135K 7,440.0 18.0 10/10/2024 21:00 10/10/2024 21:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA #2 test packer. 18.0 0.0 10/10/2024 21:30 10/10/2024 22:00 0.50 COMPZN, RPCOMP RURD P Pull wear bushing. 0.0 0.0 10/10/2024 22:00 10/10/2024 22:30 0.50 COMPZN, RPCOMP CLEN P Clean & clear RF. 0.0 0.0 10/10/2024 22:30 10/10/2024 23:30 1.00 COMPZN, RPCOMP RURD P R/U tubing handling equipment. Load jewelry in pipe shed. Verify joint count & jewelry running order. 0.0 0.0 10/10/2024 23:30 10/11/2024 00:00 0.50 COMPZN, RPCOMP SFTY P PJSM w/ Baker & rig crew on running 2 7/8" EUE tubing. 0.0 0.0 10/11/2024 00:00 10/11/2024 03:00 3.00 COMPZN, RPCOMP PUTB P RIH w/ 2 7/8", 6.4#, L-80, EUE-M TBG T/ 1452, SOW=45K EUE-M torque T/ 1700 Ft/lbs. Jet lube Run'n'Seal dope used. 0.0 1,452.0 10/11/2024 03:00 10/11/2024 03:30 0.50 COMPZN, RPCOMP SFTY P Crew C/O, PJSM on running 2 7/8" completion. 1,452.0 1,452.0 10/11/2024 03:30 10/11/2024 11:00 7.50 COMPZN, RPCOMP PUTB P Cont RIH w/ 2 7/8" EUE-M completion F/ 1452' T/ 7464 1,452.0 7,464.0 10/11/2024 11:00 10/11/2024 12:00 1.00 COMPZN, RPCOMP PUTB P KU Joint 235, PUW=75K, SOW=62K Bring pump online 1.5 BPM @ 206 PSI' RIH see pressure increase @ 7487' to 285 PSI, S/D pump. Continue in. Set down 7491. See screw shear @ 8K down. Hard set down @ 7494. Mark pipe, PUH 2'. Mark pipe. Packer setting depth, 7,464.0 7,493.0 10/11/2024 12:00 10/11/2024 12:30 0.50 COMPZN, RPCOMP SFTY P Crew change 7,493.0 7,493.0 10/11/2024 12:30 10/11/2024 13:30 1.00 COMPZN, RPCOMP RURD P R/U PT manifold, KD. Install head pin. Line up on 260 BBls CI 10.3 PPG brine 7,493.0 7,493.0 10/11/2024 13:30 10/11/2024 15:30 2.00 COMPZN, RPCOMP CRIH P Displace annular to 10.2 CI brine. 260 BBl 7,493.0 7,493.0 10/11/2024 15:30 10/11/2024 15:54 0.40 COMPZN, RPCOMP PACK P RBIH to stump. Pick up two feet for packer setting depth 7,494.0 7,492.0 10/11/2024 15:54 10/11/2024 16:30 0.60 COMPZN, RPCOMP PACK P Knock off head pin, Drop ball and rod, Wait 10 minutes for ball to land in RHC. Bring pump online. Immediate pressure. Ball on seat. Observe packer start to set shift @ 1700 PSI. Bring up to 2000 PSI. lock in for 5 minutes. Slack off 10 K below run in weight 52K. Bring tubing up to 3000 PSI. Hold for 5 minutes. Bleed tubing down to 2500 PSI. Pull up on tubing. Looks like pins sheared at 83K. Continue up. stop pulling at 100K. 7,492.0 7,490.0 10/11/2024 16:30 10/11/2024 17:00 0.50 COMPZN, RPCOMP PACK P RBIH to neutral weight. Pressure up tubing to 1500 PSI. PUH see shear @ 91K sheared down to 76K PUH ti 7468, Roll pump 1 BPM @ 120 PSI. RBIH. Observe pressure spike @ 7472'. See seals go into PBR. Bottomed out at 7493. 26.01' of Jt 235 in hole. PUH 6 mark for space out, 7,490.0 7,487.0 10/11/2024 17:00 10/11/2024 17:30 0.50 COMPZN, RPCOMP HOSO P Pull Head pin. L/D 235, 234 and 233, Add Space out pups 10.19' & 10.18'. M/U joint #233. 7,487.0 7,452.0 Rig: NORDIC 3 RIG RELEASE DATE 10/13/2024 Page 5/6 2H-09 Report Printed: 11/6/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/11/2024 17:30 10/11/2024 18:00 0.50 COMPZN, RPCOMP PULD P M/U landing joitn T/ hanger. M/U hanger to string. 7,452.0 7,452.0 10/11/2024 18:00 10/11/2024 18:30 0.50 COMPZN, RPCOMP PUTB P RIH & land hanger w/ bottom of mule shoe @ 7494.15' ORKB w/ seals 5.35' from fully located. 7,452.0 7,494.2 10/11/2024 18:30 10/11/2024 19:30 1.00 COMPZN, RPCOMP RURD P R/U testing equipment T/ TBG & IA. 7,494.2 7,494.2 10/11/2024 19:30 10/11/2024 20:45 1.25 COMPZN, RPCOMP PRTS P PT TBG T/ 3000 PSI for 30 MIn. Bleed TBG T/ 1500 PSI. PT IA T/ 2500 PSI for 30 Min. Dump tubing pressure shear out SOV. Pump down IA @ 2 BPM 370 PSI. 7,494.2 7,494.2 10/11/2024 20:45 10/11/2024 21:15 0.50 COMPZN, RPCOMP RURD P B/D TBG testing equipment. Pull landing joint. 7,494.2 7,494.2 10/11/2024 21:15 10/11/2024 21:30 0.25 COMPZN, RPCOMP MPSP P Set ISA BPV 7,494.2 7,494.2 10/11/2024 21:30 10/11/2024 21:45 0.25 COMPZN, RPCOMP PRTS P PT BPV from below T/ 1000 PSI for 10 Min. 7,494.2 0.0 10/11/2024 21:45 10/11/2024 22:15 0.50 COMPZN, WHDBOP RURD P B/D, R/D IA testing equipment. 0.0 0.0 10/11/2024 22:15 10/11/2024 23:30 1.25 COMPZN, WHDBOP NUND P N/D BOP. 0.0 0.0 10/11/2024 23:30 10/12/2024 00:00 0.50 COMPZN, WHDBOP NUND P IPrep adaptor spool. 0.0 0.0 10/12/2024 00:00 10/12/2024 02:15 2.25 COMPZN, WHDBOP NUND T N/U adaptor spool. Wrong tree ordered for well. Removed 3 1/8" tree from cellar. Called out for old 2 9/16" tree to be returned from valve shop. 0.0 0.0 10/12/2024 02:15 10/12/2024 02:30 0.25 COMPZN, WHDBOP PRTS T PT hanger void T/ 5000 PSI for 15 MIn. 0.0 0.0 10/12/2024 02:30 10/12/2024 03:00 0.50 COMPZN, WHDBOP NUND T Bring old 2 1/16" tree to cellar. Install integral flange. N/U tree. 0.0 0.0 10/12/2024 03:00 10/12/2024 03:30 0.50 COMPZN, WHDBOP SFTY T Crew change out. Welcome back meeting. 0.0 0.0 10/12/2024 03:30 10/12/2024 04:00 0.50 COMPZN, WHDBOP NUND T N/U tree. 0.0 0.0 10/12/2024 04:00 10/12/2024 04:15 0.25 COMPZN, WHDBOP MPSP P Pull ISA BPV. Install tree test plug. 0.0 0.0 10/12/2024 04:15 10/12/2024 05:00 0.75 COMPZN, WHDBOP RURD P R/U circ equipment & LRS. 0.0 0.0 10/12/2024 05:00 10/12/2024 05:15 0.25 COMPZN, WHDBOP PRTS P LRS PT tree T/ 5000 PSI for 10 Min 0.0 0.0 10/12/2024 05:15 10/12/2024 05:30 0.25 COMPZN, WHDBOP MPSP P Pull tree test plug 0.0 0.0 10/12/2024 05:30 10/12/2024 06:30 1.00 COMPZN, WHDBOP FRZP P LRS pump 80 Bbls freeze protect down IA. ICP=500. FCP=1200 PSI all at 2 BPM 0.0 0.0 10/12/2024 06:30 10/12/2024 08:00 1.50 COMPZN, WHDBOP RURD P Open up u- tube. Blow down lines. Warm up moving system, Rig down cellar and clean. Obtain final pressures T/IA/OA =250/250/0 0.0 0.0 10/12/2024 08:00 10/12/2024 09:30 1.50 COMPZN, WHDBOP RURD P Work rig down checklists. Remove all equipment around rig 0.0 0.0 10/12/2024 09:30 10/12/2024 10:00 0.50 DEMOB, MOVE DMOB P PJSM to pull off well. Pull off well. Center up on pad. Set mats under foot and cellar. Set rig down. 0.0 0.0 10/12/2024 10:00 10/12/2024 19:00 9.00 DEMOB, MOVE DMOB P R/D cellar. R/U for BTM on BOP stack. Swap LPR's to 7" fixed. 0.0 0.0 10/12/2024 19:00 10/12/2024 21:30 2.50 DEMOB, MOVE MOB P Move sub F/ 2H T/ 2K. Rig on location @ 21:30 Hrs. Lay herculite & set mats. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 10/13/2024 Page 6/6 2H-09 Report Printed: 11/6/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/12/2024 21:30 10/12/2024 22:30 1.00 DEMOB, MOVE MOB P Hang tree in cellar. Stage wellhead equipment & DSA's behind cellar. 0.0 0.0 10/12/2024 22:30 10/13/2024 00:00 1.50 DEMOB, MOVE MOB Spotting sub oper well 2K-19. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 10/13/2024 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,887.0 2H-09 10/28/2024 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pull plug, Tag. 2H-09 10/28/2024 fergusp Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 36.0 110.0 110.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 35.5 2,981.5 2,832.5 36.00 J-55 BTC PRODUCTION 7 6.28 33.4 8,108.0 6,252.5 26.00 J- 55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 31.6 Set Depth 7,494.2 String Max No 2 7/8 Set Depth 5,862.8 Tubing Description Tubing Completion Upper Wt (lb/ft) 6.40 Grade L-80 Top Connection EUE-M ID (in) 2.44 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 31.6 31.5 0.04 Hanger 6.980 FMC 2-7/8" x 7" Gen 3 TBG Hanger. EUE top thread. ISA BPV profile. FMC Gen 3 2.347 2,651.6 2,565.5 33.67 Mandrel GAS LIFT 5.360 2-7/8" X 1.5" MMG GLM SLB MMG 2.366 5,518.2 4,546.7 47.37 Mandrel GAS LIFT 5.351 2-7/8" X 1.5" MMG, GLM SLB MMG 2.366 7,327.5 5,749.8 47.00 Mandrel GAS LIFT 5.304 2-7/8" X 1.5" MMG, GLM SLB MMG 2.366 7,383.9 5,788.2 47.16 Locator 3.460 Baker locator 2.420 7,385.0 5,788.9 47.16 Seal Assembly 3.220 Baker 80-32 Seal Assembly (21.66' Seals Assembly) 2.440 7,390.3 5,792.6 47.17 PBR 5.850 PBR 80-32 3.250 7,413.3 5,808.2 47.29 Packer 6.380 2-7/8" x 7" Baker FH Packer 2.410 7,465.6 5,843.6 47.65 Nipple - X 3.243 2.313 X Nipple HES X Nipple 2.313 7,487.1 5,858.0 47.79 Overshot 5.898 2 7/8" Poor Boy Non-sealing Overshot (Shear screws 3.90') (7.06 Swallow) Innno Poor Boy Oversho t 2.992 Top (ftKB) 7,489.0 Set Depth 7,760.7 String Max No 2 7/8 Set Depth 6,038.5 Tubing Description Tubing Completion Lower Wt (lb/ft) 6.50 Grade J-55 Top Connection EUE8RD ID (in) 2.44 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,508.5 5,872.4 47.92 PBR 3.500 PBR ((DRIFTED THROUGH PBR W/ 2.28" Gauge Ring & CATCHER)) BROWN 2.250 7,520.7 5,880.5 47.99 PACKER 5.660 BROWN HB HYD SET RETRIEVABLE PACKER BROWN HB 3.500 7,558.5 5,905.7 48.18 GAS LIFT 4.750 CAMCO KBMG CAMCO KBMG 2.347 7,627.9 5,951.9 48.66 GAS LIFT 4.750 CAMCO KBMG CAMCO KBMG 2.347 7,666.0 5,976.9 49.01 BLAST RINGS 3.500 CARBIDE Blast Rings (2) 2.441 7,727.9 6,017.3 49.66 GAS LIFT 4.750 CAMCO KBMG CAMCO KBMG 2.347 7,742.5 6,026.7 49.84 LOCATOR 3.500 LOCATOR SUB w/ 5' SEALS BROWN 2.440 7,744.0 6,027.7 49.85 PACKER 5.660 BROWN 1B PACKER BROWN HB 3.250 7,754.2 6,034.3 49.98 NIPPLE 3.668 CAMCO D NIPPLE CAMCO D 2.250 7,759.8 6,037.9 50.04 SOS 3.750 SHEAR OUT SUB, TTL ELMD @ 7760' on SWS PPROF 8/29/2002 BROWN 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,890.0 6,119.9 51.92 FISH FISH LOST TEL FINGER, SEE DRAWING ON WSR 3/17/2001 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,651.6 2,565.5 33.67 1 GAS LIFT GLV RK 1 1/2 1,219.0 10/23/2024 SLB MMG 0.188 5,518.2 4,546.7 47.37 2 GAS LIFT GLV RK 1 1/2 1,243.0 10/22/2024 SLB MMG 0.250 7,327.5 5,749.8 47.00 3 GAS LIFT OV RK 1 1/2 0.0 10/22/2024 SLB MMG 0.250 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,678.0 7,718.0 5,984.8 6,010.9 C-4, UNIT B, 2H- 09 12/21/1985 12.0 APERF 5" HyperJet II; 120° Ph 7,790.0 7,806.0 6,057.2 6,067.4 A-4, 2H-09 3/18/1986 4.0 IPERF 2 1/8" Tornado Link; 0° Ph 7,832.0 7,872.0 6,083.8 6,108.8 A-3, 2H-09 12/21/1985 4.0 APERF 4" HyperJet II; 90° Ph 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) 7,678.0 7,718.0 1 FRAC 3/8/2001 0.0 0.00 0.00 2H-09, 11/6/2024 10:14:45 AM Vertical schematic (actual) PRODUCTION; 33.4-8,108.0 FISH; 7,890.0 APERF; 7,832.0-7,872.0 IPERF; 7,790.0-7,806.0 PACKER; 7,744.0 GAS LIFT; 7,727.9 APERF; 7,678.0-7,718.0 FRAC; 7,678.0 GAS LIFT; 7,627.9 GAS LIFT; 7,558.5 PACKER; 7,520.7 Nipple - X; 7,465.6 Packer; 7,413.3 Seal Assembly; 7,385.0 Mandrel GAS LIFT; 7,327.4 Mandrel GAS LIFT; 5,518.2 SURFACE; 35.5-2,981.5 Mandrel GAS LIFT; 2,651.6 CONDUCTOR; 36.0-110.0 Hanger; 31.6 KUP PROD KB-Grd (ft) 39.42 RR Date 12/2/1985 Other Elev 2H-09 ... TD Act Btm (ftKB) 8,123.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032005000 Wellbore Status PROD Max Angle & MD Incl (°) 52.73 MD (ftKB) 8,000.00 WELLNAME WELLBORE2H-09 Annotation Last WO: End Date 10/12/2024 H2S (ppm) 100 Date 12/15/2019 Comment SSSV: LOCKED OUT ORIGINATED TRANSMITTAL DATE: 10/9/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5093 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk River PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5093 2H-09 501032005000 Chem Cut 2-Oct-2024 RECIPIENTS ConocoPhillips Alaska, Inc. DIGITAL FILES PRINTS CD'S 1 0 0 0 USPS 0 0 0 0 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 185-259 T39645 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.10.09 12:50:06 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number):10. Field: Kuparuk Oil Pool Kuparuk Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8123'6261' 7890' 6120'3340 None 7890' Casing Collapse Conductor Surface Production Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: 907-229-3338 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng KRU 2H-09 7678-7872' 8075' 5985-6246' 10/20/2024 2-7/8" Brown HB HYD Brown 1B SSSV: Baker FVL Safety Valve 2946' 8108' Perforation Depth MD (ft): 110' 2982' 6253'7" 16" 9.625" 74' Burst 7761' MD 110' 2833' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025587 185-259 P.O. Box 100360, Anchorage, AK 99510 50-103-20050-00-00 ConocoPhillips Alaska, Inc Proposed Pools: AOGCC USE ONLY Tubing Grade:Tubing MD (ft): 7521'MD/5881'TVD 7744'MD/6028'TVD 1804'MD/1797'TVD Perforation Depth TVD (ft): Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size Kuparuk River Field James Ohlinger CTD/RWO Engineer Subsequent Form Required: Suspension Expiration Date: J-55 TVD m n P s 1 6 5 6 t g N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov james.j.ohlinger@conocophillips.com By Grace Christianson at 12:55 pm, Sep 10, 2024 Digitally signed by James J. Ohlinger DN: C=US, OU=ConocoPhillips, O=Wells - Coiled Tubing Drlling, CN=James J. Ohlinger, E=James.J.Ohlinger@ cop.com Reason: I am the author of this document Location: Date: 2024.09.10 12:45:51-08'00' Foxit PDF Editor Version: 13.0.0 James J. Ohlinger 324-518 SFD 10/2/2024 X X DSR-9/13/24 10/7/2024 VTL 10/3/2024 BOP test to 3500 psig Annular preventer test to 2500 psig 10-404 JLC 10/3/2024 Gregory Wilson Digitally signed by Gregory Wilson Date: 2024.10.07 10:47:01 -08'00' 10/07/24 RBDMS JSB 100824 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 9, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: James J. Ohlinger Staff CTD/RWO Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Producer 2H-09 (PTD# 185-259). Well 2H-09 was drilled and completed in December of 1985 by Nabors 26E as a producer into the C&A-sands. Over its life multiple tubing leaks and a packer leak is requiring a rig workover. If you have any questions or require any further information, please contact me at +1 907-229-3338. The tubing above the packer will be cut & pulled and replaced. Replaced with 2-7/8" tubing and stack packer. 2H-09 RWO Procedure Kuparuk Producer - RWO PTD #185-259 Page 1 of 2 General Well info: Wellhead type/pressure rating: FMC Gen III Production Engineer: Kristian Fredagsvik Reservoir Development Engineer: Mandy Pogany Estimated Start Date: Mid-October Workover Engineer: James Ohlinger (265-1102/ James.J.Ohlinger@conocophillips.com) Current Operations: This well is currently shut in; since April 2020 Well Type: Producer Scope of Work: Pull the existing 2-7/8” completion down to the pre-rig cut above the packer. A new 2-7/8” tubing string with a Poor-boy overshot and stack packer. BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: Tubing leaks at 6630’, 7449’, and Packer leak at 7520’ MD MIT-T: Passed 2/7/21 with 2-7/8” TTS Test Tool set @ 6625’ MD MIT-IA: Passed 2/6/21 with 2-7/8” TTS Test Tool set @ 6625’ MD CMIT-T+IA: Passed 2/6/21 with 2-7/8” TTS Test Tool set @ 6625’ MD T & IC POT & PPPOT Passed – 8/26/20 T POT Passed 3/23/21 MPSP: 3340 psi using 0.1 psi/ft gradient Static BHP: 3946 psi / 6064 TVD measured on 2/12/24 Remaining Pre-Rig Work 1. Static Bottom Hole Pressure 2. IC-POT, IC-PPPOT, T-PPPOT and T-POT tests. 3. MIT-OA 4. Open lowest GLM in upper completion, dummy all other GLM 5. Cut the tubing at ~7489 RKB in the middle of the first full joint above the packer @ 7521’ RKB 6. Prepare well within 48 hrs of rig arrival. 2H-09 RWO Procedure Kuparuk Producer - RWO PTD #185-259 Page 2 of 2 Rig Work MIRU 1. MIRU Nabors 7ES on 2H-09 (No BPV will be installed due to risk assessment done for MIRU/RDMO on 7ES w/o BPV.) 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/3,500 psi. Test annular 250/3,500 psi. Retrieve Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 2-7/8” tubing down to pre-rig cut (~7489’ RKB). Subsidence on 7.0” We don’t plan on any repair work of the 7” Casing as there is only an estimated 40” of subsidence. Install in 2-7/8” Completion 6. MU 2-7/8” completion with poor-boy overshot, nipple profiles, stack packer and GLM. RIH with completion. 7. Once on depth, circulate CI brine, space out as needed, land hanger, RILDS, drop B&R, and set packer. 8. Pressure test tubing to 3000 psi for 30 minutes and chart. 9. Pressure test inner annulus to 2500 psi for 30 minutes on chart. ND BOP, NU Tree 10. Confirm pressure tests, then shear out SOV with pressure differential. 11. Install BPV. 12. ND BOPE. NU tree. PT tree. 13. Pull BPV, freeze protect well at opportune time, and set BPV if necessary. 14. RDMO. Post-Rig Work 15. Install GLD. 16. Pull Ball and Rod 17. Pull any remaining plugs in well. 18. Turn over to operations. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,890.0 2H-09 2/11/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Update tag depth 2H-09 2/12/2024 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: *** TUBING SET DEPTH/COMPONENT DEPTHS ARE WLM *** 7/12/2012 osborl 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 36.0 110.0 110.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 35.5 2,981.5 2,832.5 36.00 J-55 BTC PRODUCTION 7 6.28 33.4 8,108.0 6,252.5 26.00 J- 55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 31.6 Set Depth … 7,760.7 Set Depth … 6,038.5 String Max No… 2 7/8 Tubing Description TUBING Wt (lb/ft) 6.50 Grade J-55 Top Connection EUE8RD ID (in) 2.44 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 31.6 31.6 0.04 HANGER 6.000 FMC GEN III TUBING HANGER 2.874 1,803.8 1,796.8 15.39 SAFETY VLV 4.760 BAKER FVL SAFETY VLV (Locked Out 7/6/08) BAKER FVL 2.313 2,282.6 2,244.9 25.00 GAS LIFT 4.750 CAMCO KBMG CAMCO KBMG 2.347 4,035.5 3,532.5 48.95 GAS LIFT 4.750 CAMCO KBMG CAMCO KBMG 2.347 4,975.9 4,177.5 45.77 GAS LIFT 4.750 CAMCO KBMG CAMCO KBMG 2.347 5,480.4 4,521.0 47.16 GAS LIFT 4.750 CAMCO KBMG CAMCO KBMG 2.347 5,951.0 4,833.3 48.58 GAS LIFT 4.750 CAMCO KBMG CAMCO KBMG 2.347 6,484.9 5,183.6 49.80 GAS LIFT 4.750 CAMCO KBMG CAMCO KBMG 2.347 6,989.8 5,519.7 47.06 GAS LIFT 4.750 CAMCO KBMG CAMCO KBMG 2.347 7,464.7 5,842.9 47.64 GAS LIFT 5.500 MMH FMHO MMH FMHO 2.347 7,508.5 5,872.4 47.92 PBR 3.500 PBR ((DRIFTED THROUGH PBR W/ 2.28" Gauge Ring & CATCHER)) BROWN 2.250 7,520.7 5,880.5 47.99 PACKER 5.660 BROWN HB HYD SET RETRIEVABLE PACKER BROWN HB 3.500 7,558.5 5,905.7 48.18 GAS LIFT 4.750 CAMCO KBMG CAMCO KBMG 2.347 7,627.9 5,951.9 48.66 GAS LIFT 4.750 CAMCO KBMG CAMCO KBMG 2.347 7,666.0 5,976.9 49.01 BLAST RINGS 3.500 CARBIDE Blast Rings (2) 2.441 7,727.9 6,017.3 49.66 GAS LIFT 4.750 CAMCO KBMG CAMCO KBMG 2.347 7,742.5 6,026.7 49.84 LOCATOR 3.500 LOCATOR SUB w/ 5' SEALS BROWN 2.440 7,744.0 6,027.7 49.85 PACKER 5.660 BROWN 1B PACKER BROWN HB 3.250 7,754.2 6,034.3 49.98 NIPPLE 3.668 CAMCO D NIPPLE CAMCO D 2.250 7,759.8 6,037.9 50.04 SOS 3.750 SHEAR OUT SUB, TTL ELMD @ 7760' on SWS PPROF 8/29/2002 BROWN 2.441 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) 6,630.0 5,277.0 49.47 LEAK - TUBING LEAK IDENTIFIED W/ RELAY LDL, 0.5 BPM, 400 PSI WHP. first dicovered by E-line LDL 05/07/18. 4/5/2020 7,449.0 5,832.3 47.53 LEAK - TUBING LEAK IDENTIFIED W/ RELAY LDL, 0.5 BPM, 400 PSI WHP 4/5/2020 7,520.0 5,880.1 47.98 LEAK - PACKER Leak at 7520’ RKB that we found - LDL with acoustic tools 4/22/2020 7,890.0 6,119.9 51.92 FISH FISH LOST TEL FINGER, SEE DRAWING ON WSR 3/17/2001 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,282.6 2,244.9 25.00 1 GAS LIFT GLV BK 1 1,260.0 2/7/2021 0.156 4,035.5 3,532.5 48.95 2 GAS LIFT GLV BK 1 1,290.0 2/7/2021 0.188 4,975.9 4,177.5 45.77 3 GAS LIFT DMY BK 1 0.0 5/3/1997 0.000 5,480.4 4,521.0 47.16 4 GAS LIFT OV BK 1 0.0 2/6/2021 0.250 5,951.0 4,833.3 48.58 5 GAS LIFT DMY BK 1 0.0 12/22/1985 0.000 6,484.9 5,183.6 49.80 6 GAS LIFT Ext. Pkg DMY BK 1 0.0 4/14/2018 0.000 6,989.8 5,519.7 47.06 7 GAS LIFT DMY BK 1 0.0 8/9/2015 0.000 7,464.7 5,842.9 47.64 8 GAS LIFT OPEN 1 1/2 8/14/2020 7,558.5 5,905.7 48.18 9 PROD HFCV BEK 1 0.0 8/7/2015 0.000 7,627.9 5,951.9 48.66 1 0 PROD CV BEK 1 0.0 8/7/2015 0.000 7,727.9 6,017.3 49.66 1 1 PROD CV BEK 1 0.0 8/7/2015 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,678.0 7,718.0 5,984.8 6,010.9 C-4, UNIT B, 2H- 09 12/21/1985 12.0 APERF 5" HyperJet II; 120° Ph 2H-09, 2/14/2024 9:44:03 AM Vertical schematic (actual) PRODUCTION; 33.4-8,108.0 FISH; 7,890.0 APERF; 7,832.0-7,872.0 IPERF; 7,790.0-7,806.0 PACKER; 7,744.0 GAS LIFT; 7,727.9 APERF; 7,678.0-7,718.0 FRAC; 7,678.0 GAS LIFT; 7,627.9 GAS LIFT; 7,558.5 PACKER; 7,520.7 LEAK - PACKER; 7,520.0 GAS LIFT; 7,464.7 LEAK - TUBING; 7,449.0 GAS LIFT; 6,989.8 LEAK - TUBING; 6,630.0 GAS LIFT; 6,484.9 GAS LIFT; 5,951.0 GAS LIFT; 5,480.4 GAS LIFT; 4,975.9 GAS LIFT; 4,035.5 SURFACE; 35.5-2,981.5 GAS LIFT; 2,282.6 SAFETY VLV; 1,803.8 CONDUCTOR; 36.0-110.0 KUP PROD KB-Grd (ft) 39.42 RR Date 12/2/1985 Other Elev… 2H-09 ... TD Act Btm (ftKB) 8,123.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032005000 Wellbore Status PROD Max Angle & MD Incl (°) 52.73 MD (ftKB) 8,000.00 WELLNAME WELLBORE2H-09 Annotation Last WO: End DateH2S (ppm) 100 Date 12/15/2019 Comment SSSV: LOCKED OUT Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,790.0 7,806.0 6,057.2 6,067.4 A-4, 2H-09 3/18/1986 4.0 IPERF 2 1/8" Tornado Link; 0° Ph 7,832.0 7,872.0 6,083.8 6,108.8 A-3, 2H-09 12/21/1985 4.0 APERF 4" HyperJet II; 90° Ph 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) 7,678.0 7,718.0 1 FRAC 3/8/2001 0.0 0.00 0.00 2H-09, 2/14/2024 9:44:03 AM Vertical schematic (actual) PRODUCTION; 33.4-8,108.0 FISH; 7,890.0 APERF; 7,832.0-7,872.0 IPERF; 7,790.0-7,806.0 PACKER; 7,744.0 GAS LIFT; 7,727.9 APERF; 7,678.0-7,718.0 FRAC; 7,678.0 GAS LIFT; 7,627.9 GAS LIFT; 7,558.5 PACKER; 7,520.7 LEAK - PACKER; 7,520.0 GAS LIFT; 7,464.7 LEAK - TUBING; 7,449.0 GAS LIFT; 6,989.8 LEAK - TUBING; 6,630.0 GAS LIFT; 6,484.9 GAS LIFT; 5,951.0 GAS LIFT; 5,480.4 GAS LIFT; 4,975.9 GAS LIFT; 4,035.5 SURFACE; 35.5-2,981.5 GAS LIFT; 2,282.6 SAFETY VLV; 1,803.8 CONDUCTOR; 36.0-110.0 KUP PROD 2H-09 ... WELLNAME WELLBORE2H-09 2H-09 Proposed Completion Producer COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Conductor 110' 110' 16" 15.06 62.5 H-40 Surface 2982' 2833' 9-5/8" 8.92 36 J-55 Production 8108' 6253' 7" 6.28 26 J-55 Tubing 7489' 2-7/8" 2.44 6.5 L-80 Tubing 7761' 2-7/8" 2.44 6.5 J-55 Arctic Cement Diesel Pack BBLS BBLS 12/7/85 29.2 55 bbl/ft 0.0297 from surface footage 983.4 1852.3 2-7/8" 6.5# L-80 EUE-M 8rd Tubing to surface Camco KBMG gas lift mandrels @ TBD Baker Hughes PBR 2-7/8"x7" Baker Hughes FH Packer Nipple profile Poorboy Overshot Brown PBR @ 7509' RKB (2.25" ID) Brown HB Packer @ 7521' RKB (3.5" ID) Camco KBMG gas lift mandrels @ 7559', 7628', & 7728' RKB Brown 1B Packer w/ SBE @ 7744' RKB Camco D-nipple at 7754' RKB (2.25" min ID) Brwon SOS @ 7760' RKB Surface Casing Production Casing Conductor A-sand perfs 7790'-7806' RKB C4 Perfs 7678'-7718' RKB Brown HB Packer @ 7521' RKB Tubing Cut 7489' RKB Originated:Delivered to:6-Apr-21 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 1A-23 50-029-22131-00 906975765 Kuparuk River Multi Finger Caliper Field & Processed 12-Feb-21 0 1 2 1B-11 50-029-20657-00 907041775 Kuparuk River Multi Finger Caliper Field & Processed 20-Mar-21 0 1 3 1D-101 50-029-22986-00 n/a West Sak Packer Setting Record Field- Final 14-Mar-21 0 1 4 1D-130 50-029-22815-00 907025874 West Sak Packer Setting Record Field- Final 13-Mar-21 0 1 5 1F-19 50-029-22660-00 906994361 Kuparuk River Packer Setting Record Field- Final 24-Feb-21 0 1 6 1G-02 50-029-20813-00 906996811 Kuparuk River Multi Finger Caliper Field & Processed 24-Feb-21 0 1 7 1L-11 50-029-22034-00 906914692 Kuparuk River Leak Detect Log Field- Final 15-Jan-21 0 1 8 1Q-10 50-029-21215-00 907035266 Kuparuk River Packer Setting Record Field- Final 18-Mar-21 0 1 9 2H-09 50-103-20050-00 907042522 Kuparuk River Packer Setting Record Field- Final 19-Mar-21 0 1 10 3H-21 50-103-20094-00 907045708 Kuparuk River Packer Setting Record Field- Final 22-Mar-21 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: PTD: 1852590 E-Set: 34909 Received by the AOGCC 04/07/2021 04/07/2021 Originated:Delivered to:3-Mar-21 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 1J-170 50-029-23310-00 906951584 West Sak Injection Profile Field & Processed 30-Jan-21 0 1 2 1J-176 50-029-23364-00 906948912 West Sak Injection Profile with TMD3D Field & Processed 29-Jan-21 0 1 3 1J-180 50-029-23329-00 906811709 West Sak Injection Profile with TMD3D Field & Processed 27-Jan-21 0 1 4 1Y-19 50-029-22391-00 906880907 Kuparuk River Packer Setting Record Field- Final 3-Jan-21 0 1 5 2H-09 50-103-20050-00 906910408 Kuparuk River Multi Finger Caliper Field & Processed 8-Jan-21 0 1 6 2H-09 50-103-20050-00 906960677 Kuparuk River Packer Setting Record Field- Final 3-Feb-21 0 1 7 2N-333 50-103-20525-00 906882125 Kuparuk River Multi Finger Caliper Field & Processed 21-Dec-20 0 1 8 3A-08 50-029-21445-00 906879883 Kuparuk River Leak Detect Log Field- Final 20-Dec-20 0 1 9 3B-06 50-029-21336-00 906905927 Kuparuk River Leak Detect Log Field- Final 5-Jan-21 0 1 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 03/08/2021 03/08/2021 PTD: 1852590 E-Set: 34732 Originated:Delivered to:3-Mar-21 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 1J-170 50-029-23310-00 906951584 West Sak Injection Profile Field & Processed 30-Jan-21 0 1 2 1J-176 50-029-23364-00 906948912 West Sak Injection Profile with TMD3D Field & Processed 29-Jan-21 0 1 3 1J-180 50-029-23329-00 906811709 West Sak Injection Profile with TMD3D Field & Processed 27-Jan-21 0 1 4 1Y-19 50-029-22391-00 906880907 Kuparuk River Packer Setting Record Field- Final 3-Jan-21 0 1 5 2H-09 50-103-20050-00 906910408 Kuparuk River Multi Finger Caliper Field & Processed 8-Jan-21 0 1 6 2H-09 50-103-20050-00 906960677 Kuparuk River Packer Setting Record Field- Final 3-Feb-21 0 1 7 2N-333 50-103-20525-00 906882125 Kuparuk River Multi Finger Caliper Field & Processed 21-Dec-20 0 1 8 3A-08 50-029-21445-00 906879883 Kuparuk River Leak Detect Log Field- Final 20-Dec-20 0 1 9 3B-06 50-029-21336-00 906905927 Kuparuk River Leak Detect Log Field- Final 5-Jan-21 0 1 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 03/08/2021 03/08/2021 PTD: 1852590 E-Set: 34731 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Tubing patches ConocoPhillips Alaska, Inc.Development Exploratory 3. Address: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 8123 feet N/A feet true vertical 6261 feet N/A feet Effective Depth measured 7890 feet 7521 feet true vertical 6120 feet 5881 feet Perforation depth Measured depth 7678'-7872' feet True Vertical depth 5985'-6246' feet Tubing (size, grade, measured and true vertical depth)2-7/8" J-55 7761' MD 6039' TVD Packers and SSSV (type, measured and true vertical depth)Packer Brown HB Retrievable 7521' MD 5881' TVD Packer Brown 1B 7744' MD 6028' TVD SSSV Baker FVL (locked out) 1804' MD 1797' TVD 12. Stimulation or cement squeeze summary:N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: 2/9/2021 Contact Phone: N/A Authorized Name: Authorized Signature with date: ----- ----- N/A Senior Engineer:Senior Res. Engineer: 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283 WINJ WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Dusty Freeborn N2549@conocophillips.com 659-7224 Well Integrity & Compliance Specialist Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Production 8075'7"8108'6253' Surface 2946'9-5/8"2982'2833' Conductor 74'16"110'110' true vertical Casing Length Size MD TVD Junk measured Burst Collapse 185-259 50103200500000 ADL0025587 KRU 2H-09 P.O. Box 100630, Anchorage, Alaska 99508 N/A Kuparuk River Field/Kuparuk River Oil Pool Plugs measured Packer measured STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Operator Name N 4. Well Class Before Work:5. Permit to Drill Number: nttttt e Fra O g g g l g yy e 6. A y GGGJ LLLLL PG R essssssss Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 10:09 am, Feb 09, 2021 Digitally signed by Dusty Freeborn DN: OU=AK WELLS, O=ConocoPhillips, CN=Dusty Freeborn, E=dusty.freeborn@conocophillips.com Reason: I am the author of this document Location: Anchorage, Alaska Date: 2021.02.09 09:57:57-09'00' Foxit PhantomPDF Version: 10.1.0 Dusty Freeborn RBDMS HEW 2/10/2021 DSR-2/9/21VTL 02/18/2021 50-103-20050-00-00 SFD 2/9/2021 SFD 2/9/2021 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 9, 2021 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 form from ConocoPhillips Alaska, Inc. for the retrievable tubing patches set across known tubing and packer leaks in producer KRU 2H-09 (PTD# 185-259). Please contact me at 659-7224 if you have any questions. Sincerely, Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Digitally signed by Dusty Freeborn DN: OU=AK WELLS, O=ConocoPhillips, CN=Dusty Freeborn, E=dusty.freeborn@conocophillips.com Reason: I am the author of this document Location: Anchorage, Alaska Date: 2021.02.09 09:57:03-09'00' Foxit PhantomPDF Version: 10.1.0 Dusty Freeborn Date Event Summary Executive Summary Set two tubing patches over known tubing leaks to regain TxIA integrity. 02/07/21 RAN TEST TOOL TO PBR @ 6642' RKB & CMIT TBG X IA TO 2500 PSI (PASS); SET UPPER 2.29" P2P, SPACER PIPE, & ANCHOR LATCH (OAL 20.92' OAL / SN:CPP287037 / CPAL287031) W/ MID ELEMENT @ 6625' RKB; MIT IA TO 2500 PSI (PASS); SET 2 7/8 TTS TEST TOOL @ 6625' RKB; PULLED DV & SET OV @ 5480' RKB. IN PROGRESS. 02/06/21 (WEATHER DELAYED START DUE TO -37°F); SET LOWER 2.29" P2P (3.56' OAL / SN:CPP287051) W/ MID ELEMENT @ 6666' RKB; SET 2.20" PBR, SPACER PIPE, AND ANCHOR LATCH ASSEMBLY @ 6641.82' RKB (22.04' OAL / SN:CPBR287009-CPAL287050). IN PROGRESS. 02/03/21 (WEATHER DELAYED START DUE TO -37°F); SET LOWER 2.29" P2P (3.56' OAL / SN:CPP287051) W/ MID ELEMENT @ 6666' RKB; SET 2.20" PBR, SPACER PIPE, AND ANCHOR LATCH ASSEMBLY @ 6641.82' RKB (22.04' OAL / SN:CPBR287009-CPAL287050). IN PROGRESS. 01/29/21 SET UPPER 2.29" P2P SPACER & ANCHOR LATCH (OAL 34.36' / SN:CPP287062 / CPPAL287024) @ 7431.38' RKB (ME), CMIT TBG x IA 2500 PSI W/ 2 7/8 TTS TEST TOOL IN UPPER P2P @ 7431.38' RKB (PASS), RAN 2 7/8 SMART HOLE FINDER GOOD COMBO 2500 PSI TEST'S FROM 7396' RKB TO 6720' RKB TEST FAILED @ 6645' RKB, RE- RUN 2 7/8 SMART HOLE FINDER NARROW DOWN LEAK BETWEEN GOOD COMBO @ 6665' RKB & FAILED COMBO @ 6660' RKB. JOB SUSPENDED FOR PLAN FORWARD. 01/27/21 BRUSH n' FLUSH PATCH AREA'S FROM 7495' TO 7400' RKB & 6700' TO 6600' RKB, LOAD IA W/ 195 BBLS INHIBITED SEAWATER & 65 BBLS DIESEL FREEZE PROTECT, DEPLOY 2 1/2 AVA STYLE CATCHER, SET 1.5" DV @ 7465' RKB, PULLED 2 1/2 AVA CATCHER @ 7495' RKB. IN PROGRESS. 01/09/21 SET 2.225" SC LOWER P2P W/ ME @ 7530' RKB; RAN TTS TEST TOOL TO LOWER P2P @ 7530 & ATTEMPT TO CMIT TO 2500 PSI (FAILED W/ EST 1.8 GPM LLR @ 2500 PSI); SET 2.285" UPPER P2P, EXPANSION JOINT (6' TOTAL STROKE & OPENED 2'), SPACER PIPE, & ANCHOR LATCH W/ ME OF PKR @ 7496' RKB; RAN TTS TEST TOOL TO UPPER P2P @ 7496' RKB & CMIT TO 2500 PSI (PASS); READY FOR PLAN FORWARD FOR UPPER PATCH DESIGN. Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 7,890.0 3/22/2018 2H-09 jhansen8 Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Installed Tbg Patch & GLD 2/7/2021 2H-09 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 110.0 Set Depth (TVD) … 110.0 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) 35.5 Set Depth (ftKB) 2,981.5 Set Depth (TVD) … 2,832.5 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 33.4 Set Depth (ftKB) 8,108.0 Set Depth (TVD) … 6,252.5 Wt/Len (l… 26.00 Grade J- 55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 2 7/8 ID (in) 2.44 Top (ftKB) 31.6 Set Depth (ft… 7,760.7 Set Depth (TVD) (… 6,038.5 Wt (lb/ft) 6.50 Grade J-55 Top Connection EUE8RD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 31.6 31.6 0.04 HANGER FMC GEN III TUBING HANGER 2.874 1,803.8 1,796.8 15.39 SAFETY VLV BAKER FVL SAFETY VALVE (LOCKED OUT 7/6/08) 2.313 7,508.5 5,872.4 47.92 PBR BROWN PBR ((DRIFTED THROUGH PBR W/ 2.28" GAUGE RING & CATCHER)) 2.250 7,520.7 5,880.5 47.99 PACKER BROWN HB HYD SET RETRIEVABLE PACKER 3.500 7,666.0 5,976.9 49.01 BLAST RINGS CARBIDE BLAST RINGS (2) 2.441 7,742.5 6,026.7 49.84 LOCATOR BROWN LOCATOR SUB w/ 5' SEALS 2.440 7,744.0 6,027.7 49.85 PACKER BROWN 1B PACKER 3.250 7,754.2 6,034.3 49.98 NIPPLE CAMCO D NIPPLE 2.250 7,759.8 6,037.9 50.04 SOS BROWN SHEAR OUT SUB, TTL ELMD @ 7760' ON SWS PPROF 8/29/2002 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 6,624.0 5,273.1 49.60 2.29" UPPER P2P PATCH PKR 2.29" UPPER P2P PATCH PACKER 2/6/2021 1.375 CPP287037 6,627.0 5,275.0 49.53 SPACER PIPE & ANCHOR LATCH SPACER PIPE & ANCHOR LATCH ATTACHED TO UPPER PACKER (20.92' OAL) 2/6/2021 1.372 CPAL287031 6,630.0 5,277.0 49.47 LEAK - TUBING TUBING LEAK IDENTIFIED W/ RELAY LDL, 0.5 BPM, 400 PSI WHP. Leak was first dicovered by E-line LDL 05/07/18. 4/5/2020 6,641.8 5,284.6 49.20 PBR, SPACER PIPE, & ANCHOR LATCH 2.20" PBR, SPACER PIPE, AND ANCHOR LATCH (22.04' OAL / REQUIRES TTS PULLING TOOL TO RETRIVE) 2/3/2021 1.372 CPBR287009 / CPAL287050 6,665.0 5,299.9 48.67 2.29" LWR P2P PATCH PKR 2.29" LWR P2P PATCH PACKER (3.56' OAL) 2/3/2021 1.375 CPP287051 7,431.4 5,820.4 47.41 PACKER - PATCH - UPR Upper Packer assembly= 2 7/8" P2P packer, XO,spacer pipe, & anchor latch. (OAL 34.36') 1/29/2021 1.375 CPP287062 7,435.7 5,823.4 47.44 Spacer Piipe Spacer Pipe & Anchor Latch (OAL length including in upper patch assembly. 1/29/2021 1.610 CPAL287024 7,449.0 5,832.3 47.53 LEAK - TUBING TUBING LEAK IDENTIFIED W/ RELAY LDL, 0.5 BPM, 400 PSI WHP 4/5/2020 7,462.8 5,841.6 47.63 PBR Assembly PBR assembly consisting of PBR, spacer pipe & anchor latch (OAL 31.98') 1/28/2021 0.000 CPAL287051 7,495.0 5,863.3 47.85 2.285" P2P UPPER PATCH PKR 2.285"P2P UPPER PATCH PKR ((NOTE WHEN PULLINGTHE UPPER, EXPANSION JOING, SPACER PIPE, AND ANCHOR LATCH THE OAL=38.43')) 1/9/2021 1.370 CPP287080 7,498.2 5,865.5 47.87 EXPANSION JOINT, SPACER PIPE, & ANCHOR LATCH EXPANSION JOINT (6' MAX STROKE, SET W/ 2' OPEN), SPACER PIPE, AND ANCHOR LATCH 1/9/2021 1.180 CPTJ228003 / CPAL287044S C 7,520.0 5,880.1 47.98 LEAK - PACKER packer leak at 7520’ RKB that we found - LDL with acoustic tools 4/22/2020 7,529.0 5,886.1 48.03 2.225" SC P2P LOWER PATCH PKR 2.225" Special Clearance P2P LOWER PATCH PKR 1/9/2021 1.250 CPPSC28706 8 7,890.0 6,119.9 51.92 FISH FISH LOST TEL FINGER, SEE DRAWING ON WSR 3/17/01 3/17/2001 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,678.0 7,718.0 5,984.8 6,010.9 C-4, UNIT B, 2H -09 12/21/1985 12.0 APERF 5" HyperJet II; 120° Ph 7,790.0 7,806.0 6,057.2 6,067.4 A-4, 2H-09 3/18/1986 4.0 IPERF 2 1/8" Tornado Link; 0° Ph 7,832.0 7,872.0 6,083.8 6,108.8 A-3, 2H-09 12/21/1985 4.0 APERF 4" HyperJet II; 90° Ph Frac Summary Start Date 3/8/2001 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 3/8/2001 Top Depth (ftKB) 7,678.0 Btm (ftKB) 7,718.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,282.6 2,244.9 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,260.0 2/7/2021 2H-09, 2/8/2021 8:51:33 AM Vertical schematic (actual) PRODUCTION; 33.4-8,108.0 FISH; 7,890.0 APERF; 7,832.0-7,872.0 IPERF; 7,790.0-7,806.0 SOS; 7,759.8 NIPPLE; 7,754.2 PACKER; 7,744.0 LOCATOR; 7,742.5 GAS LIFT; 7,727.9 FRAC; 7,678.0 APERF; 7,678.0-7,718.0 GAS LIFT; 7,627.9 GAS LIFT; 7,558.5 2.225" SC P2P LOWER PATCH PKR; 7,529.0 PACKER; 7,520.7 LEAK - PACKER; 7,520.0 PBR; 7,508.5 EXPANSION JOINT, SPACER PIPE, & ANCHOR LATCH; 7,498.2 2.285" P2P UPPER PATCH PKR; 7,495.0 PBR Assembly; 7,462.8 GAS LIFT - OPEN; 7,464.7 Spacer Piipe; 7,435.7 LEAK - TUBING; 7,449.0 PACKER - PATCH - UPR; 7,431.4 GAS LIFT; 6,989.8 2.29" LWR P2P PATCH PKR; 6,665.0 PBR, SPACER PIPE, & ANCHOR LATCH; 6,641.8 SPACER PIPE & ANCHOR LATCH; 6,627.0 LEAK - TUBING; 6,630.0 2.29" UPPER P2P PATCH PKR; 6,624.0 GAS LIFT; 6,484.9 GAS LIFT; 5,951.0 GAS LIFT; 5,480.4 GAS LIFT; 4,975.9 GAS LIFT; 4,035.5 SURFACE; 35.5-2,981.5 GAS LIFT; 2,282.6 SAFETY VLV; 1,803.8 CONDUCTOR; 36.0-110.0 HANGER; 31.6 KUP PROD KB-Grd (ft) 39.42 Rig Release Date 12/2/1985 2H-09 ... TD Act Btm (ftKB) 8,123.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032005000 Wellbore Status PROD Max Angle & MD Incl (°) 52.73 MD (ftKB) 8,000.00 WELLNAME WELLBORE2H-09 Annotation Last WO: End DateH2S (ppm) 100 Date 12/15/2019 Comment SSSV: LOCKED OUT Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 2 4,035.5 3,532.5 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,290.0 2/7/2021 3 4,975.9 4,177.5 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/3/1997 4 5,480.4 4,521.0 CAMCO KBMG 1 GAS LIFT OV BK 0.250 0.0 2/6/2021 5 5,951.0 4,833.3 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 12/22/1985 6 6,484.9 5,183.6 CAMCO KBMG 1 GAS LIFT Ext. Pkg DMY BK 0.000 0.0 4/14/2018 7 6,989.8 5,519.7 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 8/9/2015 8 7,464.7 5,842.9 MMH FMHO 1 1/2 GAS LIFT OPEN 8/14/2020 9 7,558.5 5,905.7 CAMCO KBMG 1 PROD HFCV BEK 0.000 0.0 8/7/2015 1 0 7,627.9 5,951.9 CAMCO KBMG 1 PROD CV BEK 0.000 0.0 8/7/2015 1 1 7,727.9 6,017.3 CAMCO KBMG 1 PROD CV BEK 0.000 0.0 8/7/2015 Notes: General & Safety End Date Annotation 7/12/2012 NOTE: *** TUBING SET DEPTH/COMPONENT DEPTHS ARE WLM *** 2H-09, 2/8/2021 8:51:34 AM Vertical schematic (actual) PRODUCTION; 33.4-8,108.0 FISH; 7,890.0 APERF; 7,832.0-7,872.0 IPERF; 7,790.0-7,806.0 SOS; 7,759.8 NIPPLE; 7,754.2 PACKER; 7,744.0 LOCATOR; 7,742.5 GAS LIFT; 7,727.9 FRAC; 7,678.0 APERF; 7,678.0-7,718.0 GAS LIFT; 7,627.9 GAS LIFT; 7,558.5 2.225" SC P2P LOWER PATCH PKR; 7,529.0 PACKER; 7,520.7 LEAK - PACKER; 7,520.0 PBR; 7,508.5 EXPANSION JOINT, SPACER PIPE, & ANCHOR LATCH; 7,498.2 2.285" P2P UPPER PATCH PKR; 7,495.0 PBR Assembly; 7,462.8 GAS LIFT - OPEN; 7,464.7 Spacer Piipe; 7,435.7 LEAK - TUBING; 7,449.0 PACKER - PATCH - UPR; 7,431.4 GAS LIFT; 6,989.8 2.29" LWR P2P PATCH PKR; 6,665.0 PBR, SPACER PIPE, & ANCHOR LATCH; 6,641.8 SPACER PIPE & ANCHOR LATCH; 6,627.0 LEAK - TUBING; 6,630.0 2.29" UPPER P2P PATCH PKR; 6,624.0 GAS LIFT; 6,484.9 GAS LIFT; 5,951.0 GAS LIFT; 5,480.4 GAS LIFT; 4,975.9 GAS LIFT; 4,035.5 SURFACE; 35.5-2,981.5 GAS LIFT; 2,282.6 SAFETY VLV; 1,803.8 CONDUCTOR; 36.0-110.0 HANGER; 31.6 KUP PROD 2H-09 ... WELLNAME WELLBORE2H-09 0 fD T O w N 0 O l0 O] -T, A W N N j n Z D O t y N O m 0 00 N V �D 3 jj0 O. 0 p N N O O V AQ r O T �? N D W l0 A A W l0 x Z N N �a y 3 o ° d m ` o In 3 0 Q 0 0 0 1p 1p 0 to 0 lA 0 0 1p to 0 0 1p 0 O Q n N N tlC O O 9 p m O 00 N t0 N tp O W O W O W O W O W N lD N l0 N l0 W W N F+ N N O J N W R N N 00 J J� V1 W V1 A J l0 3 � 0 0 0 0 0 0 0 0 0 0 N c O O O O O O O O O p 0 0 0 0 0 m a O< OJ1 01 Q� 0� OVl A 0� A N 3 K N N N W N N W N N A F+ O _< O_ O~i N Q~i N Vii l0 lin V 01 LD m m S V V m 00 O 0 O m lD F+ O � A O � m S R c c c c c c c c c v D u+ D D 0 a a a a a a a a a a n w a m a a a a a a a a a a m m r ro S m c c c c c c c c c c a O Z w 0fD Z a d G ro < ro G m G m <<<w �o ro m G ro G ro G ro D 3 N :� v 3 •+ 0 D S CL a m a a M N O z N G1 a in n a a a n a a n c a n a n a n C O 0 0 LO `D 'n 3 M O T M lU M N N N O ~ a ry N eD .art+ n M co m n < O l� r O O W p 00 00 00 0a O 7 0 p 00 W JJ 00 .T1 0 A m m O n n n 0 m n O 0 0 o 0 o 0 o 0 0 3 • T T T T T T T T T T fD M m m m m m m m M Q_ 0_ Q d Q Q D_ Q Q D_ T _T go T _T T _T T T T D a a o a a a a a a a D { � m a M T W W W F+ W O Vf Vf Vf Vf t%� In (D Vf In N lD O � 'tea -aa 'moo a 'moo G1 1 N N N N N O N N 0 Z a 0 0 0 Q 0 0 0 O O.n 7 O � *r 0 0 0 0 0 0 0 0 0 0 m m d ' m O N O to w LJJ W. m R �N Originated:Delivered to:19-Aug-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Sari 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 Leak Detect Log 2 Plug Setting Record 3 2L-310 50-103-20616-00 906449149 Tarn Packer Setting Record Field-Final 13-Apr-20 0 1 4 2T-37 50-103-20227-00 906480199 Kuparuk Plug Setting Record Field-Final 30-Apr-20 0 1 5 3A-08 50-029-21445-00 906499970 Kuparuk Plug Setting Record Field-Final 17-May-20 0 1 6 Multi Finger Caliper Field-Processed 26-May-20 7 Packer Setting Record Field-Final 27-May-20 8 3H-14B 50-103-20092-02 906486722 Kuparuk Packer Setting Record Field-Final 7-May-20 0 1 9 3K-03 50-029-21602-00 906531280 Kuparuk Plug Setting Record Field-Final 29-May-20 0 1 10 3A-08 50-029-21445-00 906499689 Kuparuk Multi Finger Caliper Field-Processed 16-May-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: 1 3H-03 50-103-20085-00 n/a Kuparuk 0 1 Transmittal Date: 2H-09 50-103-20050-00 906426492 Kuparuk Field-Final 5-Apr-20 0 08/26/2020 Abby Bell Received by the AOGCC 08/26/2020 PTD: 1852590 E-Set: 33687 Originated:Delivered to:19-Aug-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Sari 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 Leak Detect Log 2 Plug Setting Record 3 2L-310 50-103-20616-00 906449149 Tarn Packer Setting Record Field-Final 13-Apr-20 0 1 4 2T-37 50-103-20227-00 906480199 Kuparuk Plug Setting Record Field-Final 30-Apr-20 0 1 5 3A-08 50-029-21445-00 906499970 Kuparuk Plug Setting Record Field-Final 17-May-20 0 1 6 Multi Finger Caliper Field-Processed 26-May-20 7 Packer Setting Record Field-Final 27-May-20 8 3H-14B 50-103-20092-02 906486722 Kuparuk Packer Setting Record Field-Final 7-May-20 0 1 9 3K-03 50-029-21602-00 906531280 Kuparuk Plug Setting Record Field-Final 29-May-20 0 1 10 3A-08 50-029-21445-00 906499689 Kuparuk Multi Finger Caliper Field-Processed 16-May-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: 1 3H-03 50-103-20085-00 n/a Kuparuk 0 1 Transmittal Date: 2H-09 50-103-20050-00 906426492 Kuparuk Field-Final 5-Apr-20 0 08/26/2020 Abby Bell Received by the AOGCC 08/26/2020 PTD: 1852590 E-Set: 33686 0) • • Ol L[) - a) CN 11 (V . . . . . r . . . . . . r r � r � !17 o a; E o L CO N CU m o, m 7 co 4— a co - 0 ° uif, .8 E > , co a, O y a) LO C.) a` cT CU o o v 73 a ro Q 0 t U Q C < C) ud 00 cocci W O o0 W a0 00 00 00 00 00 00 00 CO a) E O 6 m .d CC l.7 P- 01 aJ O L J 1"' MMO � 0T M D QN O 4"' L o U N 7Q v > U v I g. 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J ~-- c~ 5 ~ Well History File Identifier Organization (done) RESCAN [] Color items: [] Grayscale items: Poor Quality Originals: ~'~'~ [] Other: H.f. -- ~)~4~ DIGITAL DATA Diskettes, No. Other, No/Type TOTAL PAGES: ~ NOTES: ORGANIZED BY;~ BREN VINCENT SHERYL MARIA LOWELL Project Proofing OVERSIZED (Scannable) [] Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of.various kinds [] Other By: Date: PROOFED BY: '~BEVERLY E~REN VINCENT SHERYL MARIA LOWELL DATE: lei PAGES: ~ ~ (at the time of scanning) SCANNED BY~ 'BEVERLY BREN VlNCEN~ARIA LOWELL ReScanned{done) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl General Notes or Comments about this file. PAGES: Quality Checked (done) RevlNOTScanned.e~od Cc~co~Phillips a~~ ~EC~Ii~E~ P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 17, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Dan Seamount: S `% ~'l; ~: ~ ~ a • APR ~ ~ zoo ,rases tJii ~ Gas Dons. ~mmissioi ~nchara~e $ ~-- ~~`~ Mr~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRtn. Each of these wells was found to have a void in the conductor. These voids were filled with 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 January 16, March 21, 2010. The corrosion inhibitor/sealant was pumped Apri115, 16 and 17, 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Projects Supervisor • ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field 4/17/2010 2B_ 2E_ 2G_ 2H_ 2K_ 2M_ 2V_ 2W. 2X_ 27 tL 3S POIY_c Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 26-05 50029210670000 1840040 24" Na 24" Na 4.2 4/16/2010 26-08 50029210790000 1840260 21" 3.30 7" 1/16/2010 2.5 4/16/2010 26-16 50029211460000 1 1..40 °. 92" 0.65 3/21/2010 2.5 4/16/2010 2E-10 50029212460000 1842300 SF Na n/a n/a 5.9 4/16/2010 2E-17 50029224190000 1931740 8'9" 1.50 19" 1/16/2010 3.4 4/16/2010 2G-13 50029211600000 1841290 SF n/a 22" n/a 3.4 4/16/2010 2H-07 50103200450000 1851700 SF n/a 17" Na 2.1 4/15/2010 2H-09 50103200500000 1852590 SF Na 17" Na 2.5 4/152010 2H-15 50103200340000 1840860 SF n/a 17" n/a 2.5 4/152010 2H-16 50103200350000 1840870 SF n/a 17" n/a 2.5 4/152010 2K-19 50103201180000 1891090 53" 0.50 9" 1/162010 2.1 4/152010 2M-07 50103201780000 .1920800 SF n/a 17" n/a 3.4 4/152010 2M-08 50103201840000 1921010 SF n/a 17" Na 2.1 4/152010 2M-20 50103201690000 1920480 SF n/a 17" Na 2.5 4/152010 2M-22 50103201700000 1920490 SF Na 17" Na 2.5 4/152010 2M-28 50103201740000 1920700 SF Na 18" Na 2.1 4/15/2010 2V-o6 50029210540000 1831790 SF n/a 19" n/a 7.6 4/16/2010 2V-10 50029213100000 1850480 SF n/a 19" Na 2.5 4/16/2010 2V 16 50029212960000 1850330 SF Na 21" Na 5.1 4/16/2010 2W-03 50029212740000 1850110 SF n/a 3T' Na 4.2 4/16/2010 2X-11 50029211880000 1841640 SF Na 17" Na 6 4/17/2010 2Z-11 50029213790000 1851380 SF Na 19" n/a 2.5 4/152010 2Z-12A 50029213800100 1951480 SF n/a 19" n/a 2.5 4/152010 2Z-13A 50029213600100 2061700 SF n/a 22" n/a 4.25 4/152010 2Z-19 50029218820000 1881300 SF Na 16" n/a 2.1 4/15/2010 3S-o9 50103204320000 2022050 SF Na 45" Na 23 4/17/2010 09/15/08 ,..-_~ ~~ 7 ~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # f`( .~ ry ., 1rri~) ~ .. _ ~~_ ~1~ '~~ ~~ ~~ ~ <w ~ ZO~~ .t4 Vy~ Log Description N0.4871 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 1 C-172A 11978478 PRODUCTION PROFILE ~- 08/19/08 1 1 iC-172A 12080429 GLSlFBHP 08/19/08 1 1 3M-26 12096533 SBHP SURVEY 08/20/08 1 1 3N-02A 11996652 SBHP SURVEY 08/20/08 1 1 3M-22 11966276 SBHP SURVEY - 08/20/08 1 1 3C-17 11996657 SCMT CYZS - /(~ 9 /L/ 08/25/08 1 1 3C-15A 11996659 PERF/SBHP SURVEY :a0~-p~~ I~Gt~(~- 08/27/08 1 1 2U-06 12080428 LDL _p( 08/29/08 1 1 2V-15 11996661 PRODUCTION PROFILE =p 08/29/08 1 1 2T-19 11996663 PRODUCTION PROFILE 08/31/08 1 1 2D-07 11975790 INJECTION PROFILE - j[-l3 ~ O 09/07/08 1 1 H-09 f 1975788 PRODUCTION PROFILE ~ 09/05/08 1 1 iC-174 12096539 INJECTION PROFILE - p 09/07/08 1 1 2H-12 12096540 PRODUCTION PROFILE '- ~ 09/09/08 1 1 30-01 11975792 LDL ~-U~} 09/09/08 1 1 3F-10 11975789 LDL ( 09/06/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • 01/20/06 Schlurnbel'ger NO. 3663 Schlumberger -DCS RECE\VED 2525 Gambell Street, Suite 400 Com pany: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Helen Warman ATTN: Beth JAN 2 4 2006 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~œ&Gascoos.~ Field: Kuparuk ~ Well Job # Log Description Date BL Color CD - 1 E-03 11144062 PROD PROFILE W/DEFT 01/14/06 1 1 F-14 11144063 PRODUCTION PROFILE 01/15/06 1 28-14 11141241 PRODUCTION PROFILE 12/31/05 1 2G-14 11166751 SBHP SURVEY 01/12/06 1 1 E-06 11154118 PROD PROFILE W/DEFT 01/11/06 1 2X-05 11141246 INJECTION PROFILE 01/05/06 1 3A-04 11166752 INJ PROFILEIWFL 01/13/06 1 38-05 11154115 INJECTION PROFILE 01/09/06 1 2X-18 11154114 SBHP SURVEY 01/08/06 1 2X-18 11154117 PROD PROFILE W/DEFT 01/10/06 1 2H-09 1F35 ,.,:)~ 11154103 PROD PROFILE W/DEFT 12/29/05 1 1 G-11 11154113 PROD PROFILE WIDEFT 01/07/06 1 2X-04 11141245 INJECTION PROFILE 01/04/06 1 22-13 11141242 PROD PROFILE W/DEFT 01/01/06 1 1 C-20 11133212 SCMT 12/25/05 1 2C-11 11144065 PROD PROFILE W/DEFT 01/17/06 1 1 -~ 2N-339 N/A BHP SURVEY 12/01/05 20-04 N/A BHP SURVEY 12/03/05 1 2U-13 11166753 PROD PROFILE W/DEFT 01/14/06 1 1 E-05 11166747 PROD PROFILE W/DEFT 12/25/05 1 2M-01 11154119 PROD PROFILE W/DEFT 01/19/06 1 SIGNED: ~ - ·fJ· ',' (;t ~. f'.zOIìB (;.;:_~. r: f1.IM M Þ [:) t. f~ 7.;, eJ 'U' {:2i\;¡V~-~~ë~~Y:-/ ~-f "i( ~ -.: DATE: ~~o 7f "\ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. -) ) ~~!Æ~! : F !Æ~!Æ~~«!Æ AliASIiA OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI. GOVERNOR 333 W. -,m AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 November 26,2004 , ,S~'Yc:Ç9 ,~ Mr. Mike Wheatall Operations Manager ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Dear Mr. Wheatal1: The Alaska Oil and Gas Conservation Commission ("Commission") received a well safety valve system (SVS) test report from ConocoPhillips at Kuparuk River Unit 2H pad ("KRU 2H") dated November 10,2004. Attached is a copy of the SVS Test Report. Regulation at 20 AAC 25.265 requires all wells to be equipped with a Commission approved fail-safe automatic surface SVS capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial lift system where an overpressure of equipment may occur. If installed, a subsurface safety valve must be maintained in working order and is subj ect to performance testing as part of the SVS. An SVS component failure rate of 11.1 percent was identified during the above-noted inspection. Commission policy, 'as outlined in a letter dated November 14, 1995, states that the testing frequency will be increased when a failure rate exceeds 10 percent. The AOGCC-AOGA Safety Valve System Task Force report issued June 13, 2003, supported retention of the 10% failure threshold. Effective November 10, 2004 and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on KRU 2H must be tested every 90 days. When testing is scheduled, you must notify the Commission Field Inspector at 907-659-2714 to provide an opportunity to witness the SVS test. Sincerely, cf~ 'ß~~" James B. Regg - L I Petroleum Inspection Supervisor Attachment SCANNEC IAN 11 2005 ) ) Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: ConocoPhillips Operator Rep: Noble - AES AOGCC Rep: \Vaived Submitted By: Brad Gathman FieldlUnitlPad: KRU 2H Separator psi: LPS Date: 11/10/2004 . ~~tfÆ~l~~1Jlil't;Cf. . Well Permit Separ Number Number PSI 2H-Ol 1840770 2H-02 1840730 2H-03 1840700 2H-04 1840550 2H-05 1851680 96 2H-06 1851690 96 2H-07 1851700 96 2H-08 1851710 96 2H-09 1852590 96 2H-I0 1852600 96 2H-l1 1852610 I 96 2H-12 1852620 96 2H-13 1840960 2H-14 1840950 2H -.15 1840860 2H-16 1840870 2H-17 2000190 96 HPS Set LIP PSI Trip J~.~~{J~g.~~~.~ '1¿~~Il;l{~t~~lZ~ftJ:Jifj~ fi~m~lIpkt;A Test Test Test Date Tested and or Oil, WAG, GINJ, Code Code Code Passed Retest or SI GAS, CYCLE, SI 96 Wells: 9 Components: WAG WAG WAG WAG 70 50 P P OIL 70 65 P P OIL 70 70 P P OIL 70 50 P P OIL 70 55 P P OIL 70 50 P 4 11/11/2004 OIL 70 55 P P OIL 70 60 P 4 11/11/2004 OIL WAG 70 50 P P OIL WAG WAG WAG 18 Failures: Failure Rate: 11.110;2] 90 Day 2 Remarks: 2H-I0 & 12 serviced and passed re-test Pad to be re-tested in 90 days RJF 09/19/02 Page 1 of 1 SVS KRU 2H 11-10-04.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other__ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 130 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 170' FNL, 534' FEL, Sec.35, T11 N, RSE, UM (asp's 497865, 5948693) 2H-09 At top of productive interval 9. Permit number / approval number 1443' FNL, 1398' FEL, Sec.26, T11 N, RSE, UM (asp's 496999, 5952702) 185-259 At effective depth 10. APl number 50-103-20050 At total depth 11. Field / Pool 1095' FNL, 1415' FEL, Sec.26, T11 N, R8E, UM (asp's 496981, 5953050) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 8123 feet Plugs (measured) Tagged Fill (3/14/01) @ 7765' MD. t~ue vertical 6262 feet Effective depth: measured 7765 feet Junk (measured) '-'- true vertical 6041 feet Casing Length Size Cemented . Measured Depth True vertical Depth CONDUCTOR 110' 16" Cemented 110' 110' SURF CASING 2852' 9-5/8" 750 Sx CS III & 615 Sx 2982' 2833' CS II PROD CASING 7978' 7" 450 Sx G & 175 CS I 8108' 6253' Perforation depth: measured 7678- 771 8'; 7790- 7806'; 7832- 7872' R E C E~VE true vertical 5985-6011'; 6057-6067'; 6084- 6109' Alaska 0il & Gas Cons. ~'~ .... Tubing (size, grade, and measured depth) 2-7/8", 6.5#, J-55 Tubing @ 7761' MD. Anchorage Packers & SSSV (type & measured depth) Brown 'HB' Retrv Hyd Set Packer @ 7521' MD; Brown 'I-B' Packer w/5' SBE @ 7744' MD. Baker 'FVL' @ 1804' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Avera.qe Production or Injection Data OiFBbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 783 744 125 - 218 Subsequent to operation 392 547 268 219 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Dally Report of Well Operations __X Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /J~ ~~...~ Title: D a,e Preparedl~ Joh~ Peir~e 265-6471 ,, Form 10-404 Rev 06/15/88 · , SUBMIT IN DUPLICA 2H-09 DESCRIPTION OF WORK COMPLETED HYDRAULIC FRACTURE TREATMENT 2/28/01: RIH & tagged PBTD at 7831' MD. 3/3/01: RU & pumped gelled sand slurry containing 1500 lbs of 20/40 mesh sand, to place an isolation sand plug across the open 'A' sand perforation intervals located at: 7790 - 7806' MD 7832 - 7872' MD 3/5/01: RIH & tagged sand plug at 7776' MD. 3/8/01: MIRU & PT equipment. Pumped a Hydraulic Fracture Treatment using 16/20 & 12/18 mesh proppants through the 'C' sand perforation interval located above the sand plug at: 7678 - 7718' MD Pumped 50 bbls of 12% DAD Acid @ 7 bpm, followed by 50 bbls NH4CI Water @ 2 - 7 bpm, followed by Shutdown. Pumped 20# Linear Gel Breakdown stage @ 14 bpm, followed by Shutdown. Pumped Scour stage w/50 bbls of Scour slurry w/1 ppa 16/20 mesh proppant followed by Shutdown. ISIP @ 1650. Resumed pumping Data Frac stages followed by Shutdown. ISIP @ 1420. Resumed pumping Frac Treatment w/200 bbls of Crosslinked Gelled Pad, followed by Gelled slurry stages w/proppant ramped in from 2 to 10 ppa stages, followed by Gelled Flush, followed by Shutdown. Placed a total of 116,982 lbs of proppant into the formation. Rigged down. 3/14/01: RIH w/CT & jetted proppant from well to 7765' MD to uncover the 'C' sand perforation interval. Left the 'A' sand perf intervals (above) covered by sand plug. Returned well to production w/gas lift & obtained 'C' sand interval well test. MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservati°n CommisSi°n Julie Huesser, .~t?~' DATE: December 2, 2000 Commissioner THRU: Tom Maunder, P. I. Supervisor FROM: Chuck Scheve; Petroleum Inspector SUBJECT: SafetyValve Tests KuParuk River Unit 2H Pad Saturday, December 2,-2000: I traveled to the KuParuk River Field and witneSsed the semi annual safety valve system testing on 2H Pad. : . As the attached AOGCC Safety Valve System Test Report indicates .I witnessed the- testing of 9 wells and 18 comPonents with four failures Observed. The IOWtpressure pilots on wells 2H-5,2H-6 and 2H-12 tripped well below the required Set pOint and the surface safety valve on well 2H-12 failed to Pressure test. The three failed pilots were adjusted and retested at the time of this test. The failed valve will be repaired and retested by the operator. - · The 22.2% failure rate will require, a retest of this pads SafetY valve System in:90 days rather than the normal,~,~day cycle. ' ' Earnie Barndt conducted the testing today he demonstrated gOod teSt Procedure and was a pleasure to work with - Summary: River Field. I witnessed the semi annUal SVS testing at 2H Pad in the Kuparuk KRU 2H Pad, 9 wells, 18 compOnents, Attachment: SVS KRU 2H Pad 12-2-00 CS 4 failures 22% failure rate X Unclassified : confidential (Unclassified if dOc, RemOved) SVS KRU 2H Pad 12-2-00 CS.doc Alaska Oil and Gas ConservatiOn CommiSsion Safety Valve SYstem Test Report 1 Operator: Phillips Submitted By: Chuck Scheve Date: 12/2/00 Operator Rep: Emie Bamdt Field/Unit/Pad: KUparuk / KRU / 2H Pad AOGCC Rep: Chuck Scheve .' Separator psi: LPS 96 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, Gl]NJ, Number Number PSI PSI Trip Code Code Code PasSed GAS or CVCLV. 2H-01 1840770 2H-02 1840730 . 2H-03 1840700 2H-04 1840550 2H-05 1851680 96 70 20 3 P 12/2/00 OIL 2H-06 1851690 96 70! 10 3 e 12/2/00 'OIL 2H'0~ 1851700 96 70! 60 P e ~ OIL 2H-08 1851710 96 70 60 P P - OIL · , 2H-09 1852590 96 70 50 P P: ' OIL 2H- 10 1852600 96 70 50 ' P P OIL 2H-11 1852610 96 70 50 P P oIL 2H-12 1852620 96 70 10 3 4 ~ remarks. :~H-13 1840960 2H-14 1840950 96 70 60 P P OIL , 2H~ 15 1840860 · 2H- 16 1840870 2H'- 17 2000190 Wells: 9 Components: 18 Failures: 4 Failure Rate: 22.0% El90 Day Remarks: three failed pilots repaired and retested, failed SSV to be repaired and reteSted by op Pad on 90 day teSt cycle .- 12/4/00 Page 1 of 1 SVS KRU 2H Pad 12-2-00 CS.xls STATE OF ALASKA r~.~, ALA~f-'(A 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 170' FNL, 534' FEL, Sec. 35, T11N, RSE,. UM At top of productive interval 1443' FNL, 1398' FEL, Sec. 26, T11N, RSE, UM At effective depth 1172' FNL, 1412' FEL, Sec. 26, TllN, RSE, UM At total depth 1095' FNL, 1415' FEL, Sec. 26, TI'IN, RSE, UM 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) RKB 130 7. Unit or Property name Kuparuk River Unit 8. Well number 2H-09 9. Permit number/approval number 85-259 10. APl number 50-103-20050-00 11. Field/Pool Kuparuk River Field/Oil Pool 81 2 3 feet 6260 feet Plugs (measured) None feet Effective depth: measured 8025 true vertical 6201 feet feet Junk (measured) None Casing Length Structural Conductor 80' Surface 2947' Intermediate Production 8074' Liner Perforation depth: measured 7678'-7718', true vertical 5983'-6010', Size 16" 9-5/8" 7" Cemented Measured depth True vertical depth 170 Sx CS II (Est) I 1 0' 750 Sx CS III & 2982' 525Sx CS I I w/ 90 Sx CS I I top job 450 Sx Class G 81 08' 175 Sx CS I 7790'-7806', 6056'-6066', 7832'-7872' 6082'-6107' Tubing (size, grade, and measured depth) 2.875", 6.5#/ft.., J-55 @ 7761' Packers and SSSV (type and measured depth) Pkrs: Brown HB @ 7521' & Brown lB @ 7744'; SSSV: 13. Stimulation or cement squeeze summary 14. 110' 2832' 6251' .RECeiVED JUN 20 1997 Baker FVL @ 1804' - Fracture Stimulate 'A' Sands on 5/7/97 0RI$INAL Intervals treated (measured) 7790'-7806', 7832'-7872' Treatment description including volumes used and final pressure ,~ Pumped 152.4 Mlbs of 20/40 and 12/18 ceramic proppant into formation, fp was 8300 psi Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 9 2 3 1 0 2 3 38 788 222 Subsequent to operation 955 1 1 4 6 19 800 195 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. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-~4 R~~0~/~8~ - - / Date (~-'.,/z~"',~' ~) SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT '~, WELL SERVICE REPORT ~ K1(2H-09(W4-6)) WELL JOb SCOPE JOB ~L~MBER 2H-09 FRAC, FRAC SUPPORT 04~6)¢7~, ,9 DATE DAILY WORK~'S~U~PE~ ~/i~'' UI~RU~R .¢<~ 05/07/97 "A" SAND REFRAC DAY oPERATION C~MPL~E I SUCCESSFUL KEY PERSON - ~ 2 ~ Yes O No~ ~ Yes O No DS-GALLEG0S C~ANEY .~ .. FIELD AF~ C~ DAILY COST AC~UM COST Signed ' ESTIMATE KD1829 230DS28HL $1 09,783 $1 17,509 Initial Tbg Press Final ~bg Press 'Initial Inner Ann Final Inner Ann ~ Initial Outer Ann ~ ~in'~l Outer Ann _. 350 PSl i 500 PSl i 2000 PSI; 500 PSI] 150 PSI~ 200 PSI DALLY SUMMARY I PERF'S. FREEZE PROTECTED W/16 BBLS OF DIESEL DOWN TO 2700' RKB. MAX PRESSURE 8300 PSI. F.G. @ (.66). COMPLETED "A" SAND REFRAC THRU FLUSH. INJECTED 152417 LBS OF PROP IN THE FORMATION W/12# PPA OF #12/18 @ TIME 07:00 10:00 10:15 11:05 12:00 LOG ENTRY MIRU DOWELL FRAC EQUIP, APC VAC TRK, AND HOT OIL TRK. HELD SAFETY MEETING (15 ON LOCATION). PT'D BACKSIDE LINES TO 4000 PSI AND RAISED INNER CSG PRESSURE AS REQUIRED. SET TREESAVER AND PT'D HIGH PRESSURE LINES TO 10500 PSI. PUMP BREAKDOWN W/50# DELAYED XL GW @ 25 TO 15 BPM. VOLUME PUMPED 340 BBLS. USED 6074 LBS OF #20/40 PROP. MAXIMUM PRESSURE 8200 PSI AND ENDING PRESSURE 3350 PSI. S/D AND OBTAINED ISIP OF 1100 PSI W/F.G. @ (.62). MONITORED WHTP AND PULSED FOR CLOSURE. PUMP DATAFRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. VOLUME PUMPED 165 BBLS. MAXIMUM PRESSURE 5000 PSI AND ENDING PRESSURE 3400 PSI. S/D AND OBTAINED ISlP OF 1300 PSI W/F.G. @ (.66). STOOD-BY AND MONITORED WHTP FOR CLOSURE. PUMP FRAC W/50# & 40# DELAYED XL GW @ 5 TO 15 BPM. COMPLETED THRU FLUSH. S/D AND OBTAINED ISIP OF 1656 PSI. VOLUME PUMPED 1215 BBLS. TOTAL PROP PUMPED 153406 LBS (16385 LBS OF #20/40 AND 137021 LBS OF #12/18) INJECTED 152417 LBS OF PROP IN THE FORMATION W/12# PPA OF #12/18 @ PERF'S. LEFT 989 LBS OF PROP IN THE WELLBORE. EST TOP OF FILL @ 7872' RKB. FREEZE PROTECTED W/16 BBLS OF DIESEL DOWN TO 2700' RKB. 13:45 STARTED R/D. DEPRESSURED THE INNER CSG TO 500 PSI AND R/D LRS HOT OIL TRK. 14:30 15:30 REMOVED TREESAVER (50% OF CUPS RETURNED). CONTINUED R/D. R/D COMPLETE AND DOWELL LEAVING LOCATION. WELL SECURED AND NOTIFIED DSO OF STATUS. SER~/ICE COMPANY - SERVICE ' DAILY COST 'ACCUM TOTAL $0.00 $645.00 . . APc $6,000.00 $6,000.00 DIESEL " $400.00 $400.00 DOWELL $99,863.0.0 $99,863.00 HALLIBURTON $0.00 $3,596.00 LITI'LE RED I .$:~1520.00 $7,005.00 TOTAL FIELD ESTIMATE $109,783,00 $117,509.00 .. , STATE Of ALASKA ~.~. ~-~- ALA~-~KA OIL AND GAS CONSERVATION COMMISSION ___/~ ~? REPORT OF SUNDRY WELL OPERATIONS0 I/; ., 1. Type of Request: Operation Shutdown Stimulate X Plugging Perforate _ -" ~ ~ Pull tubing Alter casing Repair well Pull tubing Other w 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 170' FNL, 534' FEL, Sec. 35, T11N, R8E, UM At top of productive interval 1443' FNL, 1398' FEL, Sec. 26, T11N, R8E, UM At effective depth 1210' FNL, 1405' FEL, Sec.26, TllN, RSE, UM At total depth 1095' FNL, 1415' FEL, Sec. 26, T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 81 23' feet Plugs (measured) 6 2 6 0' feet Effective depth: measured true vertical 8025' feet Junk (measured) 6 2 01 ' feet None Casing Length Structural Conductor 1 1 0' Surface 2 9 8 2' Intermediate Production 8 1 0 8' Liner Perforation depth: measured 7678'-7718' true vertical 5985'-601 1 ', Tubing (size, grade, and measured depth Size Cemented 1 6" 200 Sx AS II 9 5/8" 750 Sx CS III & 525 Sx CS II 7" 450 Sx Class G & 175 Sx CS I 6. Datum elevation (DF or KB) RKB 130 7. Unit or Property name Kuparuk River Unit 8. Well number 2H-09 feet 9. Permit number 85-259,/~'~'-~ 10. APl number 5o-1 03-20050 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Measured depth True vertical depth 110' 110' 2982' 2833' 8108' 6253' (C Sand), 7790'-7806', 7832'-7872' 6057'-6068', 6085'-6109' 2 7/8" J-55 EUE, 6.5 Ib/ft, set @ 7761' Packers and SSSV (type and measured depth) Packers' BROWN HB 7521', BROWN lB 7744', Baker FVL @ 1804' (A Sand) RECEIVED 13. Stimulation or cement squeeze summary 'JUL 1 0 Intervals treated (measured) ~ 0n & Q~IJ C01~, CK)~I~ 7790'-7872' (A Sand) ARck0ra~l Treatment description including volumes used and final pressure Screened out refracture stimulation, pumped 360 bbls gelled water and 24,000 lbs of 16/20 Carbo-Lite (11,000 lbs in formation), final pressure 5200 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 81 9 5 6 0 0 7 5 0 1 4 4 Subsequent to operation I 2 5 9 9 5 2 0 1 6 3 0 1 5 3 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 ~)~X~, ~ TitloSR. OPERATIONS ENGINEER Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE AH~;U AlaSKa, Inc. Subsidiary of Atlantic Richfield Compan.~, - WELL 7DT ~ z~-9 798~ -")NTRACTOR FIELD - DISTRICT- STATE K~q, OPERATION AT REPORT TIME do~ CO~4~LE. TE WELL ,,.iEFIVICE FIEPUHT REMARKS 0~0 ~/1~1.1 Z)Ol, UEZL- qEZi.. UP F'~e~'.q-I tVAT~ E6T. P,'eDPPi)NT.,N 7234/¢,Sc, · /$,o00# /l, lhX ZleEATIIVr4 PR.E'~u~.E · 6ZZOP.~I ~_. $C£EEX)OUT' ,/1t..3 /$oo 3#ul'.po~N PuAaP$ ; ~,~i~) t~1 I,.SI P. o_. CC,: r 80674 E..S T ' $ 55000 r--J CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK knota ISigned ARCO Alaska, Inc. Post Office Bo-"'~100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 26, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Attached in triplicate is an Application for Sundry Approval on the following Kuparuk well. Well Action Anticipated Start Date 2H-09 Stimulate May, 1990 If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer cc: J. Gruber ATO 1478 J. R. Brandstetter ATO 1120 w/o attachments L. Perini ATO 1130 ~ .- APR 5 0 19g0 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCom~;~n), · ---- STATE OF ALASKA "~---' ALASKA OIL AND GAS CONSERVATION COMMISSION 0 R APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program_ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate X Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska. Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 170' FNL, 534' FEL, Sec. 35, T11N, R8E, UM At top of productive interval 5. Type of Well: Development Exploratory Stratigraphic Service 1443' FNL, 1398' FEL, Sec. 26, T11N, R8E, UM At effective depth 1210' FNL, 1405' FEL, Sec.26, T11N, R8E, UM At total depth 1095' FNL, 1415' FEL, Sec. 26, T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 81 23' feet Plugs (measured) 6 2 6 0' feet Effective depth: measured true vertical Casing Length Structural Conductor I 1 0' Surface 2 9 8 2' Intermediate Production 8 1 0 8' Liner Perforation depth: measured 7678'-7718' true vertical 5985'-6011', Tubing (size, grade, and measured depth 8025' feet Junk (measured) 6 2 01 ' feet None 6. Datum elevation (DF or KB) RKB 130 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2H-0~) 9. Permit number 85-25~ 10. APl number 5o-103-20050 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Size Cemented Measured depth I 6" 200 Sx AS II I 10' 9 5/8" 750 Sx CS III & 2982' 525 Sx CS II 7" 450 Sx Class G & 81 0 8' 175 Sx CS I (C Sand), 7790'-7806', 7832'-7872' (A 6057'-6068', 6085'-6109' 2 7/8" J-55 EUE, 6.5 Ib/ft, set @ 7761' Packers and SSSV (type and measured depth) Packers: BROWN HB 7521', BROWN lB 7744', Baker FVL @ 1804' True vertical depth 110' 2833' 6253' Sand) 13. Attachments Description summary of proposal _ Refrac A Sand with 26,000 lbs of 16/20 mesh carbolite. 14. Estimated date for commencing operation May, 1990 16. If proposal was verbally approved Detailed operation program ~ BOP sketch_ (Procedure and Wellbore schematic attached). 15. Status of well classification as: Oil X Gas _ Suspended Name of approver Date approved Service 17. I her~y certify [bat the foregoing is true and correct to the best of my knowledge. Si~ned o Title Sr. Operations Engineer FOR COMMISSION USE ONLY Date q-- ,,~-~-~'(.~ Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test__ Location clearance__ Mechanical Integrity Test_ Subsequent form require Approved by the order Commission Form 10-403 Rev 5/03/89 ORIGINAL SIBNED BY LONNIE C. SMITH IAppro~a.I No. - SUBMIT IN TRIPLICATE Messrs Chambers and '-~....~patrick April 2, 1990 Attachment 2 Kuparuk Well 2H-09 'A' Sand Re-Fracture Procedure Cost Tracking AFE #K80674 1. MIRU Slickline unit. Tag bottom. 1 Pull CV's at 7558', 7628', and 7728'. Run DV's at 7558', 7628', and 7728'. RDMO slickline unit. If less than 50 feet of rathole is discovered during the pre-frac wireline operations, a CTU cleanout may be required. Consult with Operations Engineering to determine if the CTU is necessary. 3. Perform A Sand only production test followed by an Automatic Echometer PBU. 4. MIRU Slickline unit. . Pull GLV's at 2282', 4976', 6485' and 7465'. Run DV's at 2282', 4976' and 6485'. Circulate 2 7/8" tubing and 7" annulus with 9.8 ppg brine with a diesel cap. Set DV in GLM at 7465'. Note that DV's are set in GLM's at 4035', 5480', 5951' and 6990'. 6. Set standing valve in Camco 'D' nipple at 7754' MD-RKB. Pressure test the tubing. Pull standing valve. RDMO Slickline unit. 7. RU fracture equipment. Install "Tree Saver". Pressure up 7" annulus to 3500 psi. , Carry out all fluid quality control procedures (Onsite Operations Engineer). Obtain a sample of the proppant and of the gelled diesel with breaker. Check the proppant for fines. Record proppant weight prior to pumping. After the fracture stimulation, verify and record weight of remaining proppant. Obtain samples from pad and slurry stages while pumping. . Pump the 100 Bbl pre-pad at 18 BPM. Shut down and determine the ISIP. The A Sand was perforated with 160 shots, 4 spf, at 90 degree phasing with a 4" SOS Casing Gun and with 64 shots, 4 spf through tubing. 10. Pump fracture treatment per the attached schedule. Record the 2, 5, 10, and 15 minute pressures following the ISIP. Expected wellhead treating pressure: WHTPE - 4785 psig Fracture Gradient = 0.73 psi/ft (6083' TVD) Frac Fluid Gradient = 0.35 psi/ft Tubing Friction = 320 psi/1000'@18 BPM (7761 '-31.5' MD) * If excessive treating pressures are experienced, try reducing the rate in small increments adjusting additive rates as appropriate. With brine on the backside, the maximum recommended treating pressure is 6100 psi based on analysis of tubing strength and PBR type. The maximum treating pressure during the initial fracture treatment was 4370 psi. 1 1. Rig down fracture stimulation equipment. Follow attached flowback schedule. KUPARUK WELL 2H-09 A SAND FRACTURE PUMP SCHEDULE 4/25/90 STAGE FLUID CLEAN VOLUME PUMP RATE PROP. CONC. PROPPANT PROPPANT W'[' DIRTY VOLUME H IT PERFS DESCRIPTION BBLS BPM PPG DESCRIPTION LBS STG/CUM BBLS 1 GW PRE-PAD 100.0 1 8 0 - - 0 1 00 / 1 00 46 ............................................. SHUT DOWN FOR ISIP, FLOW METER CALIBRATION ................................................ 2 GWPAD 140.0 18 0 - - 0 140 / 240 146 3 GW w/2 PPG 9.2 1 8 2 16/20 M CARBO-LITE 772 1 0 / 250 286 4 GWw/4PPG 12.8 18 4 16/20 M CARBO-LITE 2142 15 / 265 296 5 GWw/6 PPG 11.9 18 6 16/20 M CARBO-LITE 2989 15 / 280 311 6 GW wi7 PPG 15.3 18 7 16/20 M CARBO-LITE 4494 20 / 300 326 7 GW w/8 PPG 16.3 18 8 16/20 M CARBO-LITE 5465 22 / 322 346 8 GW w/10 PPG 12.5 1 8 1 0 16/20 M CARBO-LITE 5247 1 8 / 340 368 9 GW w/12 PPG 9.8 1 8 1 2 16/20 M CARBO-LITE 4945 1 5 / 355 386 1 0 SLICK DIESEL FLUSH 44.0 +SV 1 8 0 - - TOTAL DIESEL (pads + 2&4 ppg stages) = NOTES: 13.1 BBLS 26,055 LBS TOTAL GELLED WATER = 314.6 BBLS (excluding diesel) TOTAL GELLED FLUID = 327.7 BBLS TOTAL SLICK DIESEL FOR FLUSH = 44.0 BBLS +SV Stage 1 is Gelled Water. Stage 2 is Gelled Water with 40 lbs/1000 gal silica flour and enough breaker for a 6 hour break. Stage 3 through 9 are Gelled Water with 6 hour breaker WITHOUT silica flour. Stages 1 through 4 will also contain 5% Arctic Diesel by volume for additional fluid loss control. Stage 10 should include a volume adjustment for surface equipment between the wellhead and densimeter. Stages 3 through 10 are scheduled to pump at 18 BPM to limit height growth. However, an increase in treating pressure may warrent a decrease in rate or early flush. This job is intentionally underflushed by 2 bbls. The blender tub should be bypassed at flush. All fluids should be maintained at 100° F on the surface. KUPARUK WELL 2H-09 APl #: 501032005000 SPUD DATE: 11/25/85 ADL LEASE: 25587 PERMIT #: COMPLETION DATE: 12/22/85 WORKOVER DATE: 85-259 SURFACE LOCATION: 170'FNL,534'FEL,SEC35,T11N,R8E TOP OF KUPARUK: 1443'FNL,1398'FEI~SEC26,T11N,R8E TD LOCATION: 1095'FNL,1415'FEL,SEC26,T11N,R8E All depths are MD-RKB to top of equipment unless oltmrwise noted ORIGINAL RKB: 130 CASING and TUBING DETAILS SIZE WEIGHT GRADE DEPTH 16" 62.58 H-40 110 9.625' 36# J-55 2982 7" 26# J-55 8108 2.875 6.5 J-55 EUE 7761 LINER DETAILS SIZE WEIGHT GRADE TOP TUBING SPOOL: 31.5 WELLTYPE: PRODUCER BTM TUBING JEWELRY ITEM TYPE ID DEPTH SSSV BAKER FVL 2.313 1804 SBR BROWN PBR 2.25 7508 PKR BROWN HB 7521 PKR BROWN lB 7744 NOGO CAMCO 'D' NIPPLE 2.25 7754 SHROUT BROWN 7760 PAD ELEVATION: 95 STN 1 2 3 4 5 6 7 8 9 10 11 INTERVAL 7678-7718 7790-7806 7832-7872 GAS LIFT and FLOW INFORMATION VALVE DEPTH MANDREL SIZE 2282 CAMCO KBMG 1.0" 4035 CAMCO KBMG 1.0" 4976 CAMCO KBMG 1.0" 5480 CAMCO KBMG 1.0" 5951 CAMCO KBMG 1.0" 6485 CAMCO KBMG 1.0" 6990 CAMCO KBMG 1.0" 7465 MCMURRY HUGHES FMHO 1.5" 7558 CAMCO KBMG 1.0' 7628 CAMCO KBMG 1.0' 7728 CAMCO KBMG 1.0' PERFORATION DATA ZONE FT SPF PHASE C 40 12 12O A 16 4 A 40 4 90 PORT SIZE · 1875 DV · 1875 DV DY .1875 DV .2500 FO FO FO COMMENTS SOS 5' CSG GUN SOS 4" CSG GUN MISC. DATA DESCRIPTION KICK OFF POINT: MAX HOLE ANGLE: 50 deg HOLE ANGLETHRU KUP: 49 deg LAST TAG BATE: 01/07/89 RATHOLE: ~ ~'L~ ft FISH/OBSTRU CTION: PBTD: PBTDSS: DEPTH 110o 8025 6071 REVISION DATE: 01/07/89 REASON: RUN GLV'S SUNDRY NOTICE - WELL 2H-09 NO BOP'S WILL BE UTILIZED DURING THIS PROCEDURE. BOTTOM HOLE PRESSURE (6200' SS) = 3500 PSI NO WORKOVER FLUID WILL BE USED DURING THIS PROCESS. '1. TYpe of Request: STATE OF ALASKA '~--~' ALASKA OIL AND GAS ~SERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown__ Stimulate X Plugging Perforate Pull tubing Alter casing . ,. Repair well Pull tubing Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 170' FNL, 534' FEL, Sec. 35, T11N, R8E, UM At top of productive interval 1443' FNL, 1398' FEL, Sec. 26, T11N, At effective depth 1210' FNL, 1405' FEL, Sec. 26, T11N, At total depth 1095' FNL, 1415' FEL, Sec. 26, T11N, R8E, UM R8E, UM R8E, UM 12. Present well condition summary Total Depth: measured 81 2 3' true vertical 6260' feet Plugs (measured) feet 6. Datum elevation (DF or KB) RKB 1 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2H-09 Producer 9. Permit number/approval number 8-330 10. APl number 5o-103-20050 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 8 025' true vertical 6201 ' feet Junk (measured) feet Casing Length Structural Conductor 1 10' Surface 2982' Intermediate Production 81 0 8' Liner Perforation depth: measure Size Cemented Measured depth I 6" 200 Sx AS II 110' 9 5/8" 750 Sx CS III & 2982' 525 SX CS II 7" 450 Sx Class G & 81 0 8' 175 Sx Sx CS I 7832'-7872', 7678'-7718', 7790'-7806' MD True vertical depth 110' 2833' 6253' true vertical 6085'-6109', 5985'-6011', 6057'-6068' TVD Tubing (size, grade, and measured depth) 2 7/8", 6.5 Ib/ft, EUE, IPC, J-55, 7761' Packers and SSSV (type and measured depth) SSSV: Baker FVL 1804' Pakers: Brown HB 7521', Brown lB 7744' 13. Stimulation or cement squeeze summary 14. Intervals treated (measured) 7678'-7718' Treatment description including volumes used and final pressure Acidize C Sand with 1000 gallons of 12% HCI. Final Pressure- 3400 PSI Prior to well operation Produce Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 692 936 0 --- Tubing Pressure 165 PSIG Subsequent to operation Produce 695 903 0 175 PSIG 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X_. Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service ,Si~ned,//~~_ ~ ~'~/~~ Title Form 10-404 ~Rev 06/15/88 SUBMIT IN DUPLICATE RCO Alaska, In(, Subsidiary of Atlantic Richfield Compar,,.~..,.~r WELL CONTRACTOR _ REMARKS //oo FIELD-DISTRICT-STATE OPERATION AT REPORT TIME WELL SERVICE REPORT IDA'~S IDATE '/-/-t~r- ~'~ EERING KUPARUK OPERA'I"iON8 ENGIN I1~),,? /1~ · ll o'l Ilia //13 II15 II/~ A ga, ia,s_. _ Oil & Gas Cons. , ..~. ~chora9e I"-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ISigned , / __ STATE OF ALASKA ALAS~-_.. OIL AND GAS CONSERVATION COMIv...~-SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend :; Operation Shutdown ~ ] Re.enter suspended well ~ Alter casing [] Time extension Change approved program L! Plugging ~ Stimulate ~ Pull tubing: i Amend order ~ Perforate [~' Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska: Thc. RKB 130' 3. Address P.0, BOx 100360, Anchoraqe, Alaska 99510 4. Location of well at surface 7. Well number 170' FNL, 534' FEL, Sec. 35, TllN, RSE, UN 2H-09 At top of productive interval 1443' FNL, 1398' FEL, Sec. 26, T11N At effective depth 1210' FNL, 1405' FEL, Sec. 26, T11N At total depth 1095' FNL: 1415' FEL, Sec. 26, T11N 11. Present well condition summary 8123 Total depth: measured true vertical 6260 , R8E, UM , R8E, UM , R8E, UM I feet feet Plugs (measured) feet 6. Unit or Property name Kuparuk River Unit 8. Permi~ g_uj~r 9. APl number 50-- 103-20050 10. -P°°~Kuparuk River' 0il Pool Effective depth: measured 8025 true vertical 6201 feet feet Junk (measured) Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 110 ' Surface 2982' Intermediate 8108' Production Liner Perforation depth: measured true vertical Tubing (size, grade and measured depth) 16" 200 Sx AS II 110' 110' 9-5/8" 750 Sx CS III & 2982' 2833' 525 Sx CS II 7" 450 Sx Class "G" & 8108' ~..6253' 175 Sx Sx CS I 7832' 7872' 7678'-7718' 7790'-7806' MD ~.~- ~ ~..-~ 6085'-6~09' 5985'-60~[' 6057'-6068' T~¢//4. ~: :: ::-' 2 7/8", 6.5 ]b/ft, EUE, [PC, ~-55, 776Z' Packers and SSSV (type and measured depth) $$.~V' Raker 12.Attachments Description summary of proposal [] Detailed operations program,,~ Acidize C Sand ~-ith 1000 gallons 12% HCL. 13. Estimated date for commencing operation April, 1988 ::~:~.,.~..._: '~',. ~, 7 ...... :...:~ 14. If proposal was verbally approved :!; ~!: ,../¢7/7/,~¢..: _.; :., '_/ .'~2,r"~ ..~- Name of approver L ~ ~ //' ,/-~' Date approved 15. I hereby certify that the foregoing is true and correct to t,~e best of my knowledge '"'- ~ ' Commission Use Only 1Rll4' Pakers- Brown HB 7521', Brown lB 7744' BOP sketch [] Conditions of approval Notify commission so representative may witness [] Plug integrity .I-I BOP Test © Location clearance ~,pproved CopY Returned Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner J Approval No. ~,_.~_34~) by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate Messrs. Gerlek and Ho~. April 4, 1988 Page 4 Kuparuk Well 2H-09 Acid Stimulation Procedure (4/4/88) Pre-Stimulation 1. MIRU slickline unit. 2. RIH and pull HFCVs from. 7558', 7628', and 7728' and replace with DVs. 3. RIH with A2 BP and place in D-nipple. 4. Pressure test tubing. 5. Open well to production. Note: Contact Operations Engineering if well does not flow with C Sand only production. 6. Obtain oil sample and have operations engineering pick up for use in determining if a non-emulsifying agent is needed in the treat~ent. (Ensure Samp~le wi 11 betw°obtUbingtai ned.V°lumes) have been produced so that a representati~.i."..~. 7. Check Ph of oil sample with litmus paper and record. Stimulation 1. Ensure 2-7/8"X9-5/8" annulus is filled with diesel and pressure' S'~me 3000 psi. . MIRU acid pump truck and frac tank. RU lines from wing valve through choke manifold into frac tank to allow immediate flowback after job is pumped. Pressure test equipment with diesel. Prior to performing acid treatment contact operations engineering to perform normality check of acid to verify the strength is at 12% HCL by weight. . Establish injection into tubing with diesel to ensure ability to pump into zone. Pump +/- 20 BBL and SD. **Note: With 3000 psi on the annulus, the maximum treating pressure is 4800 psi 4~ Pump the following acid schedule at maximum rate. 1000 gal 12% HCL MSR 100 W/ 2 gal per 1000 A-250 (inhibitor) and I gal per 1000 J-237 (oil soluble resin) Messrs. Gerlek and April 4, 1988 Page 5 · e e Displace acid to perforations with 48 BBL of diesel at maximum rate. (This is an over displacement of 2 BBL to ensure all acid will be placed in the formati on. ) RD&R treaters and begin flow back treatment to tank immediately. Treatment should be flowed back at moderate rate. NOTE: Maintain all personnel upwind of frac tank. Although this well is not known to contain scale, trace amounts of iron sulfide could exist, which would result in H2S liberation when brought in contact with acid. Reduce pressure on annulus to normal operating range. After well has cleaned up to tank put well in test separator and obtain stabilized test. Report results to operations engineering. Note' Compare Ph of samples with prior Ph to determine when well has been flushed adequately. STATE OF ALASKA ALA'~,.~.A OIL AND GAS CONSERVATION COM,,,,,-iSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate ~ Pull tubing [] Alter Casing [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc RKB 130' Feet 3. Address PO Box 10bS60: Anchorage, AK 99510 4. Location of well at surface 170' FNL, 534' FEL, Sec.35, T11N, R8E, UH At top of productive interval 1443' FNL, 1398' FEL, Sec.26, T11N, R8E, UM At effective depth 1366' FNL, 1411' FEL, Sec.26, T11N, R8E, UM ~s' FEL, Sec.26, T11N, R8E, UM 6. Unit or Property name Ku~aruk River Unit 7. Well number 2H-9 8. Approval number N/A 9. APl number 50-- 103-20050-00 10. Pool Kuparuk River 0ii Pool 11. Present well condition summary Total depth: measured 8123 true vertical 6260 feet feet Plugs (measured) None Effective depth: measured 8025 feet true vertical 6202 feet Junk (measured) Nolle Casing Length Size Structural Conductor 78.5' 16" Surface 2950.5' 9-5/8" Production 8076.5' 7" XXXLXii~Z~xxxx Perforation depth: Cemented Measured depth 90SX CS-II 110' HD 750SX CS-III 2982' MD & 525SX CS-II 450SX Class G 8108' MD & 175SX CS-1 measured 7678'-7718' MD, 7790'-7806' MD, 7832'-7872' MD ~ue Vertical depth 110' TVD 2833' TVD 6234' TVD true vertical 5985'-6011' TVD, 6051'-6064' TVD, 6084'-6109' TVD Tubing (size, grade and measured depth) 2-7/8", J-55 EVE @ 7761' MD Packers and SSSV (type and measured depth) Baker FVL SSSV @ 1804'/Brown HB pkr @ 7521'/Brown LB pkr. @ 7744' MD 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 1061 1420 0 800 1071 714 0 800 Tubing Pressure 150 160 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Form 10-404 Rev. '1'2-1-85 Title Sr. Operations Engineer Date 2 ~ ~g/~'~ Submit in Duplicate A ARCOAlaska, In¢ "Subsidiary of Atlantic Richfield Corrpar~'"' WELL )NTRACTOR REMARKS WELL SERVICE REPORT IFIELD - DISTRICT- STATE OPERATION AT REPORT TIME DAYS DATE 0 io~ i0%0 PC~H 2.,~ TeL / 7,.,5'0-0 - 7'../00 7 7?0 '- 7~oG ' ~ ~? F-! CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Wei~ther }Temp. I Chili Factor I Visibility IWind Vel. - Rei~rt °F I *Fi miles ARCO Alaska, Inc Post Office ,.,,.)x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 04-15-86 TRANSMITTAL # 5629 Transmitted herewith are the following items. Please acknoWledge receipt and return one signed copy of this transmittal. Final Prints: Dresser Atlas: One * of each 2H-2 Comp. Neu. Gamma Ray 12-03-85 Run #3 2V-10 Comp. Neu. Gamma Ray 12-02-85 Run # 2V-13 Comp. Neu. Gamma Ray 12-02-85 Run #3 3J-10 Carbon/Oxygen Gamma Ray 01-29-86 Run #1 3J-15 Carbon/Oxygen Gamma Ray 01-30-86 Run #1 7400-7655 7000-7300 8210-8314 2460-2770 2530-2980 Receipt Acknowledged: State of AK*bl/se Vault*films NSK Clerk*bl Drilling*bi ARCO AlasKa. In. Post Office~ox 100360 Anchorage. AlasKa 99510-0360 Telephone 907 276 1215, RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 '- P. O. Box 100360 Anchorage AK 99510-0360 DATE 04-03-86 TRANSMITTAL # 5622 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints: Schl: CET's or CBL's: One * of each 12-03-85 Run #2 7050-7732 02-21-85 Run #1 6390-6964 02-23-85 Run #2 6400-7000 04-16-85 Run #! 0695-4476 01-28-85 Run #1 5346-7359 01-14-85 Run #1 4710-6500 01-13-85 Run -#1 6050-8250 01-13-85 Run #1 5390-7522 12-06-85 Run #1 6000-8016 02-11-85 Run #2 6488-8062 11-03-85 Run #1 6771-8518 11-03-85 Run #1 6086-7545 11-04-85 Run #1 5186-7006 11-14-85 Run #1 5410-6885 Receipt Acknowledqed: Vau!t* fiir~ Dri!!Lng*bl Date: 0il STATE OF ALASKA ALASKA O'1'6 AND GAS CONSERVATION COI~ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-259 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 103-20050 4. Location of well at surface 9. Unit or Lease Name 170' FNL, 534' FEL, 5ec.35, T11N, RSE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1443' FNL, 1398' FEL, Sec.26, T11N, R8E, UM 2H-9 At Total Depth 11. Field and Pool 1095' FNL, 1415' FEL, Sec.26, T11N, R8E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 130' RKB ADL 25587 ALK 2673 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 15. Water Depth, if offshore 116'No'ofC°mpIeti°ns 1 1/25/85 1 2/01/85 1 2/03/85* N/A feet MS LI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8123'MD,6260'TVD 8025'MD,6201 'TVD YES [~X NO []I 1804 feetMD 1500~ (approx) 22. Type Electric or Other Logs Run D IL/SP/SFL, FDC/CNL, GR, Cal, GR/CCL/CET/Gauge ring, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" Conductor report not yi,~t received. 9-5/8" 36.0# J-55 Surf 2982' 12-1/4" 750 sx CS Ill & 525 sx CS II Top job performed w/90 sx CS II 7" 26.0# J-55 Surf 8108' 8-1/2" 450 sx Class G & 175 si~ CS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7872' - 7832' w/90° phasing 2-7/8" 7761' 7521' & 7744' 7718' - 7678' w/12 spf, 120° phasing 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached Addendum (dated 2/27/86) 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED APRO L986 Alaalm Oil & Gas ~, Comml~ion Anchorage Form 10-407 NOTE: Tubing was run and the well perforated 12/22/85. GRU13/WC15 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7678' 5984' N/A Base Kuparuk C 7720' 6011' Top Kupauruk A ' 7758' 6036' Base Kuparuk A 7974' 6170' I 31. LIST OF ATTACHMENTS Addendum (dated 2/27/86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge f ~ Associate Engineer Signed__ ~ ~ Title Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water ,injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas. Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 12/09/85 1/12/86 2H-9 Arctic Pak w/175 sx PF "C", followed by 55 bbls Arctic Pak. Log GR/CCL/CET/gage ring f/8016'-6000'. Rn GCT gyro f/PBTD-surf. Frac Kuparuk "A" sand perfs 7832'-7872' in 3 stages per 1/9/86 procedure using gelled diesel, Musol & 20/40 sand. Press'd ann to 1500 psi w/diesel. Tst ins to 7000 psi; OK. Pmp'd 20 bbls 5% Inflo 40 Musol, followed by 46 bbls cln diesel on 1/11/86. Stage 1: 18 bbls gelled'diesel pad @ 5 BPM @ 3860/3040 psi. Stage 2: 20 bbls gelled diesel w/6 ppg 20/40 mesh sand @ 5.6 BPM @ 2960/2680~psi. Stage 3: 46 bbls gelled diesel flush @ 18.5 BPM w/final press of 4400 psi. Underflushed by 2 bbls. Load to recover 81 bbls of diesel. Job complete @ 1055 hrs, 1/12/86. RECEIVED APRO 1986 Alask~ 0il & Gas Cons. commission Drilling S~perintendent z D~te STATE OF ALASKA ALASKA'~IL AND GAS CONSERVATION C~-'MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER 2. Name of Operator 7. Permit No. ARCO Alaska, Inc 85-259 / 3. Address 8. APl Number P. O. Box 100360, Anchorage, Alaska 99510 5o- 103-20050 4. Location of Well SURFACE LOCATION: 170' FNL, 534' FEL, SEC. 35, T11N, R8E, UM 5. Elevation in feet (indicate KB, DF, etc.) 130' (RKB) 12. I 6 . Lease Designation and Serial No. ADL 25587, ALK 2673 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number ~-9 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER 0IL POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stim u late [] Abandon [] Stim u lation [] Aba ndonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that the "A" Sand be perforated for production. Procedures call for the well to be perforate< through tubing with 4 SPF. Proposed Interval (r4))' 7790- 7806 ANTICIPATED START DATE: March 10, 1986 RECEIVED MAR 0 3 ]986 Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed z~ (7//.,~ /~ - Title The space-~el(~v~or Commission us7 Sr. uperations Engr. Conditions of Approval, if any: Approved by Form 10-403 Rev. 7-1-80 · -... ~_~, ? COMMISSIONfiR By Order of the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 12, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2H-9 Dear Mr. Chatterton: Enclosed is a copy of the 2H-9 Well History (completion details) to include with the Well Completion Report, dated 1/22/86. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU13/L112 Enclosure cc: 2H-9 Well File ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Oil and Gas Company Daily We ! History-Final Report I,n..s, tru.ctions: .,P, re,pare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is.. Plugg, e~;ArAsb~nh~on~d' o, Se d "l-lnal .... Heporz snould be submitted also when operat ons are suspended for an indefinite or appreciable length ,,Df time. un worKoV~.e used ]or' nenreportinan olt ciat t~st is not requ red upon completion, report completion and represenlative test data in blocks provided. The "Final Report form may b g th~ entire operation if space is available. District Alaska ICounty or Parish Lease or Unit Title center c o d~"~--'-'- Alaska Field North Slope Borough Kuparuk River Auth. or W.O. no. AFE AK0049 Roll'N 4 Operator ARCO Alaska, Inc. ADL 25587 Completion IWell no. 2H-9 Spudded or W.O. begun IA.R.Co. Date Complete Date and depth as of 8:00 a.m. Complete record for each day reported API 50-103-20050 W.I. [Total number of wells (active or inactive) on this Icost center prior to plugging and I 56 · 24% Jabandonment of this well I IHour IPrlor status if a W.O. 12/18/85 [ 1400 hrs. I 12/19/85 12/20/85 12/21/85 thru 12/23/85 Old TD Released rig 2000 hrs. Classifications (oil, gas, etc.) Oil Producing method Potential test data Flowing 7" @ 8108' 8025' PBTD, RIH 10.9 ppg NaCl/NaBr Accept ri~ @ 1400 hrs, 12/18/85. ND tree, NU & tst BOPE. w/6-1/8" bit to 8025' f/cond'g trip. RIH 7" @ 8108' 8025' PBTD, Rn'g gage ring/JB 11+ ppg NaC1/NaBr Fin TIH w/tbg, C&C brine to 11 ppg, POOH. RU SOS, perf w/4" gun, 4 SPF, 90° phasing f/7832'-7872'. Perf w/5" gun, 12 SPF, 120° phasing f/7678'-7718'. Rn gage ring/JB. 7" @ 8108' 8025' PBTD, RR 6.9 ppg Diesel Fin rn'g gage ring/JB. Set WL pkr @ 7744'. RU to rn tbg, well flowing. Monitor & bleed off gas. RU CTU, wt up brine to 11.5 ppg. Fill well, monitor f/flow. Fill well, well dead. POOH w/coiled tbg. RIH w/circ string, C&C well to 11.5 ppg, POOH. RU & rn 2-7/8" compl string. Stab into pkr @ 7744'. Set & tst pkr & SSSV. Shear PBR, lnd tbg. ND BOPE, NU & tst tree. Chg well over to diesel. Set BPV. RR @ 2000 hrs, 12/22/85. SSSV @ 1804', HB pkr @ 7521', lB Pkr @ 7744', TT @ 7760' INew TD I PB Depth PBTD 8025' IDate IKind' ofrig 12/22/85 Rotary Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands 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 Elfective date corrected The above is correct Signature J Date ITitle For form preparation and d~tribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Alaska, In~,. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telep.one 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ~~TO 1119 · O. Box 100360 . Anchorage AK 99510-0360 Transmitted herewith the items. following are return one signed copy of this transmittal. Final Prints/ Schl/ Open Hole/ One * of each , 2H-7 5" DIL/SFL-GR 12-18-85 2" DIL/SFL-GR 12-18-85 5" Den/Neu (poro) 12-18-85 2" Den/Neu (poro) 12-18-85 5" Den/Neu (raw) 12-18-85 2" Den/Neu (raw) 12-18-85 Cyberlook 12-18-85 -J" 2H-8 ~ 2H-9 5" DIL/SFL-GR 12-11-85 2" DIL/SFL-GR 12-11-85 5" Den/Neu (poro) 12-11-85 2" Den/Neu (poro) 12-11-85 5" Den/Neu (raw) 12-11-85 2" Den/Neu (raw) 12-11-85 Cyber look 12-11- 85 5" DIL/SFL-GR 12-02-85 2" DIL/SFL-GR 12-02-85 5" Den/Neu-GR (poro) 12-02-85 2" Den/Neu-GR (poro) 12-02-85 5" Den/Neu-GR (raw) 12-02-85 2" Den/Neu-GR (raw) 12-02-85 Cyberlook 12-02-85 DATE 01-28-86 Tk~NSMITTAL # 5531 Please acknowledge receipt and Run #1 2905-8049 Run #1 2905-8049 Run #1 2905-8024 Run 0i 2905-8024 Run 01 2905-8024 Run #1 2905-8024 Run 01 7400-8000 Run 0i 1000-8786 Run 0i 1000-8786 Run #1 8150-8760 Run #1 7350-8760 Run #1 8150-8760 Run 01 7350-8760 Run #1 8150-8730 Run #1 1800-8113 Run 0i 1800-8113 Run #1 3450-8088 Run #1 3450-8088 Run 01 3450-8088 Run #1 3450-8088 Run 01 7450-8088 FEB 0 ISSS Receipt Acknowledged: State of AK*bl/se NSK'Clerk*bl Rathmel!*bl ~ & M'b! Dri!ling*bl Vault*films Date: ARCO Alaska. InC. ~s a SuDs~chary ot Alhtn.cRicnfieldComl3an.v ARCO Alaska, Inc. Post Office Bo~'100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 23, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2H-9 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for the subject well. I have not yet received the 2H-9 Well History (completion details). When I do, I will forward a copy to you' If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU13/L24 Encl osures ARCO Alaska, inc. is a Subsidiary of AtlanticRichfJeldCompany STATE OF ALASKA ALASKA (':~_.AND GAS CONSERVATION cO~,..~AISSION WELL COMPLETION OR RECOMPLETION i EPORT AND LOG 1. Status of Well Classification of Service Well OIL E~x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-259 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 :~' ~ ..... ."..' ::-~ ~'-~ ~'h 50- 103-20050 :' · ',i ~ ~ -~ 9. Unit or Lease Name 4. Location of well at surface t. ,. ~ -, :~ ': ~ ......... 170' FNL, 534' FEL, Sec.35, T11N, R8E, UM Kuparuk River Unit At Top Producing Interval .i'?''. [ i:-: '''! i!.iii_': i[: 10. Well Number 1443' FNL, 1398' FEL, 5ec.26, T11N, R8E, UM 2H-9 At Total Depth . .- .... 11. and Pool 1095' FNL, 1415' FEL, 5ec.26, TllN, R8E, UM~I~:::~;~' :'':~ ~ ?~.].S :]:'..:!:~;~ ~]3:';!?.!~'~-;?;;~ Field i.~;;.::.,,...:~:,:~ Kuparuk Ri vet Fi el d 5. Elevation in ~eet (indicate KB, DF, etc.) 6. Lease Designation and Serial '~Jo. Kuparuk River 0il Pool 130' RKB ADL 25587 ALK 2675 12. Date Spuddedl 1/25/85 13. Date T.D. Reached1 2/01/85 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°nsl 2/03/85* N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8123 'MD ,6260 'TVD 8025'MD,6201 'TVD YES I-~X NO [] 1804 feetMDI 1500' (approx) 22. Type Electric or Other Logs Run DIL/SP/SFL, FDC/CNL, GR, Cal, GR/CCL/CET/Gauge ring, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" Conductor report not y~t received. 9-5/8" 36.0# J-55 Surf 2982' 12-1/4" 750 sx CS Ill & 525 sx CS II Top job performed w/90 sx CS II 7" 26.0# J-55 Surf 8108' 8-1/2" 450 sx Class G & 175 s~ CS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7872' - 7832' w/90~ phasing 2-7/8" 7761 ' 7521 ' & 7744' 7718' - 7678' w/12 spf, 120° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production J Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD e I Flow Tubing Casing Pressure CALCULATED.l~ OIL~BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE i~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None 1 ~oc^~,oNs'-'"-------' . VERIFIED FormlO~07 *NOTE: Tubing was run and the well perforated 12/22/85. Rev. 7-1-80 CONTINUED ON REVERSE SIDE TEMP3/WC58 Submit in duplicate 29. . ,, 30. . .. .. :. GEOLOGiC MARKERS ' FORMATION TESTS _ NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7678' 5984' N/A Base Kuparuk C 7720' 6011' Top Kupauruk A 7758' 6036' Base Kuparuk A 7974' 6170' -. _ · 31. LIST OF ATTACHMENTS Well History~ Gyr.0scopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of'my knowledge ~ ,¢~,6~ Title Associ a'ce Engineer Date /- ~Z-~L¢ Signed /(~0 .... j 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". ~.~r ARCO Oil and Gas Company Well History- Initial Report- Dally Insfl'uctlene: Prepare and submit the "lnlUal Report" on the first Wednesday after a well is spudded or workover operations are started. Dally wor~ prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk'Rtver Auth. or W.O. no. AFE AK0049 Nabors 26E ICounty, parish or borough North Slope Borough Lease or Unit ADL 25587 Title Drill State Alaska IWell no. 2]:[-9 AP1 50-103-20050 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded 11126/85 11/27/85 11/28/85 thru 12/o2/85 Date and depth aa of 8:00 a.m. 12/o3/85 Date IHour 11/25/85 Complete record for each day reported IARCO W.I. Prior status 56.24% if a W.O. 1830 hrs. 16" @ 110' 1182', (1078'), Dr!g Wt. 8.9, PV 19, YP 28, PH 9.5, WL 12.0, Sol -- Accept ri~ @ 1130 hfs, 11/25/85. NU diverter sys. Spud well @ 1830 hrs, 11/25/85. Navi-Drl to 1182', try to build angle @ 900' - 1182' w/o success, POH to chg assy. 16" @ 110' 2662', (1480'), Drlg ~ Wt. 9.0, PV 18, YP 14, PH 9.0, WL 8.2, Sol 6 Navi-Drl & surv 12¼" hole to 2662'. 423', .1°, S70.8E, 423.0 TVD, - .2 VS, .IS, .3E 1027', .2°, N29.2E, 1027.0 TVD, -1.7 VS, 1.4S, 1.7E 1325', 4.6°, N24.SE, 1324.7 TVD, 7.6 VS, 7.9N, .5W 1794', 15.4°, N15.SW, 1787.2 TVD, 81.4 VS, 79.7N, 16.5W 1922', 17.7°, N12.SW, 1909.9 TVD, 117.8 VS, l15.1N, 25.5W 9-5/8" @ 2982' 8123', (5461'), Logging Wt. 10.9, PV 25, YP 13, PH 9.0, WL 5.4, Sol 14 Drl to 3000', wiper trip, circ, POH. RU & rn 75 its, 9-5/8", 36# HF/ERW, J-55 BTC csg w/FS @.2982', FC @ 2899'. Cmt w/750 sx CS III w/10#/sx Gilsonite, followed by 525 sx CS II. Displ using rig pmps, bump plug. ND diverter. Perform90 sx CS II top job. NU & tst BOPE. RIH to 3010', perform formation tst to 12.5 ppg EMW. Navi-Drl to 7359', rotary drl 8½" hole to 8123', wiper trip, C&C, POH. RU Schl, prep to rn triple combo. 2297', 25.3°, N12.SW, 2257.7 TVD, 257.1VS, 250.4N, 59.2W 2923', 37.9°, N 8.8W, 2785.6 TVD, 590.7VS, 575.9N, 133.4W 3284', 50.7°, N12.SW, 3043.4 TVD, 842.3VS, 823N, 180.6W 3783', 48.7°,Nll. SW, 3359.9 TVD, 1227.9VS, 1200.1N, 261.5W 4449', 46.6°, N12.SW, 3796.4 TVD, 1730.7VS, 1692.2N, 365.6W 5897', 49°, NiO.SW, 4775.2 TVD, 2797.2VS, 2740.5N, 562.1W 7279', 47.3°, N9.SW, 5~90.5 TVD, 3832.3VS,.3757.5N, 754.5W 9-5/8" @ 2982' 8123' TD, (0'), RIH w/7" Wt. 10.9, PV 22, YP 14, PH 9.0, WL 5.2, Sol 14 Log DIL/SP/SFL/GR f/8120'-2982', cent w/GR to 180' FDC/CNL/CAL f/8120'-7450', cent w/CAL to 2982'. . Log The above is correct Slgnatu r~). ~ For form preparation ~d distribution, see Procedures Manua3, Section 10, Drilling. Pages 86 and 87. IDate j / I Title Drilling Superintendent ARCO. Oil-and. Gas Company Daily Well History-Final Report Inllrllclionl: Prepare and submit the "Flnll Repert" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Rel~o~t" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test Is not required upon completion, report completion and representative test date in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District JCounty or Parish I Alaska Field ILease or Unit Kuparuk Ri%er Auth. or W.O. no. ~Title I AFE AK0049 Operator ARCO Alaska, Inc. Nabors 26E A.R.Co. W.I. Spudded or W.O. begun Date Spudded Date and depth Complete record for each day reported as of 8:00 a.m. 12/04/85 North Slope Borough. ADL 25587 Drill IAccounting coat center code State Alaska JWell no. 2H-9 API 50-103-20050 ri'otal number of wells (active or inactive) on this Icost center prior to plugging and J 56.24% labandonment of this well I IHour J Prior status if a W.O. 11/25/85 [ 183o hrs. I 7" @ 8108' 8123' TD, 8025' PBTD, RR 10.9 NaCl/NaBr RIH w/187 its, 7", 26#, HF/ERW J-55 BTC csg & lnd w/FS @ 8108' FC @ 8025'. Cmt w/150 sx C1 "G" w/6% gel, 3% A-9, 2.5% FL-19, 1% CD-31 & .25% R-5, followed by 300 sx C1 "G" w/l% FL-19, .5% CD-31 & .3% A-2. Displ w/brine, bump plug. CIP @ 1200 hrs, 12/3/85. ND BOPE, set pack-off, NU lower tbg spool & lower tree. Tst pack-off to 3000 psi. Arctic pack well w/175 sx CSI. RR @ 2000 hfs, 12/3/85. Old TD New TD I PB Depth 8123' ~D I 8025' ?B'~ Released rig Oate l Kind of rig 2000 hrs. 12/3/85 I Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Flowing Official reservoir name(s) Kuparuk Sands 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~~ Date /l~/~ //OO'''~ s JTitle For form preparatior~ ar~ distribution, see Procedures Manuel, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent 8UB. SURFA DIRECTIONAL SURVEY [~]UIDANCE [~ONTINUOU$ ~OOL Cempiny A~CO ALASKA INCORPORATED Wail' Name Fleld/Loe&tlon ~~, NORTH SLOPE, ALASKA Fleferin(:e Ne, 71091 18-DECEMBER- 85 GCT DIRECTIONAL SURVEY CUSTOMER LISTING ARCD ALASKA~ INS. 2H-9 KUP~RUK NORTH SLOPE,ALASKA SURVEY DATE: 05 DEC 85 ENGINEER: URAM METHODS ~F CD'qPUTATIDN T.gL]L LOCATION: T~NGENTIAL- A'VER/N'SED OEVIATION.AND AZIMUTH INTER P'DL.~TI 2N: LINEAR V~RTiCAL SECTION: HgRIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 10 DE~ 47 MIN WEST ARCO ALASKA, INC. 2H-9 KUPARU~ NORTH SLGPE,AL~SKA ME4S DEPTH DEPTH 0.00 0.00 100.00 99.90 200.00 199.90 300.00 299.90 400.00 399.90 500.00 499.90 600.00 5'99.90 700.00 699,90 800.00 799.89 900.00 899,89 C O'qPOT ~TI IN DEPfH , D,E!~ MZN DEG ., -130.00 ,0 0 N 0 -30.10 0 7 S 4~ 69,90 0 lO S 5 169,90 0 9 S 1:30 269,90 0 9 N 73 369,90 0 14 S 49 ~6~.90 0 17 S 1 569.90 0 11 S 53 669.89 0 18 S 43 769.89 0 21 S 2 DATE: ES FOR EVEN VERTIC MUTH S=CTI MIN FEE 0 E O. 57 W -0. 17 W -0. 55 E -0. 4 E -0. 35 E -0. 5 ',i -1. 35 E -1. 10 E -1. 58 E -2. 1000.00 9~9.89 1100.00 1099.89 1200.00 1199.88 1300.00 1299,78 1400.00 1399.37 1500.00 1498.56 1600.00 1597.55 1700.00 1695.90 1800.00 1793.D5 1900.00 1888.77 869.89 0 4 N 8 969.8~ 0 4 N 65 1069.88 1 19 N 16 1169.78 3 47 N 22 1269,37 6 21 N 16 1368.55 7 49 N 10 1467,55 8 53 N 10 1565.90 11 57 N 15 1663,05 15 18 N 17 1758.77 17 42 N 14 44 E -2. 49 E -2. 10 W' -1. 45 W 2. 59 W 11. 22 W 24. 9 W 38. 19 W 56. 21 W 79. 8 W 108. ZO00.O0 1983.86 2100.00 2077.55 2200.00 2169.53 2300.00 2260.50 2400.00 2350.09 2500.00 2437.41 2500.00 2522.20 2700.00 2605.30 2800.00 2687.~5 2900.00' 2767.66 3000.00 2845.70 3100.00 2923.~6 3200.00 2993.58 3300.00 3058.~7 3400.00 3121,98 3500,00 3185.2! 3600,00 3248,16 3700,00 3310,90 3800.00 3376.55 3900.00 3442,71 1853.8,5 18 52 N 12 1'947.58 21 50 N 17 2039.53 24 7 N 1~ 2130.50 25 1! N 13 2220.09 27 40 N 15 2307,41 30 35 N 16 2392.20 33 20 N 16 2475.30 33 59 N 11 2557.45 35 ~7 N I1 2.637,66 37 25 N 9 2716.70 38 10 N 11 2793.46 42 24 N 12 2863.58 48 6 N 13 2928.47 50 17 N 13 2991.98 50 41 N 13 3055.21 50 53 N 13 3118.16 51 10 N 13 3180.90 50 20 N 12 3745_ .55 48 =~9 N 11 3312.71 48 a3 N 11 44 W 139. 5 W 174. 6 W 213. 22 W 254. 24 W 299. 29 W 347. 41W 400. 58 ~ 455. 8 W 512. 25 W 572. 31 W 633. 36 ~ 697. 42 W 768. 58 W 844. 50 W 921. 46 W 999. 19 W 1076. 49 W 1154, 51 W 1230. 52 W 1305. 18-DEC-85 100 FEET OF MEASURE AL DOGLEG RECTAN ON SEVERITY NflRTHI T DEG/IO0 FE O0 0.00 0 08 0.10 0 33 0.24 0 57 0.22 O. 58 0.12 O. 69 0.32 O. 14 0.06 1. 45 0.20 1. 79 0.30 1. 40 0.25 2. 59 0.26 2. 62 0.65 2. 75 2.35 1. 60 2.74 2. 38 2.71 10. 07 0.95 23. 23 2,49 37. 25 3.11 54. 72 3.45 77. 47 1.8¢ 105. 43 3.43 135. 12 2.78 168. 24 1.42 206. 73 2.90 247. 04 2,92 290. 52 3.23 336. 23 Z.54 387. 70 3.22 441. 70 2.03 497. 41 2,.21 556. 66 1.95 616. 69 5.20 678. 76 5.09 748. 80 0.88 822. 92 0.27 897. 29 0.27 972. 91 0.46 lO47. 70 ,3.79, 1123. 10 .,,~0.'31 1197. o8 i:,' 0,.3o, lZ7O.. PAGE 1' DATE OF SURVEY: 05 DEC 85 KELLY BUSHING ELEVATION: 130.00 FT ENGINEER: URAM D OEPTH GUL~R CODRDIN SOUTH EAST./WE T FEET O0 N 0.00 10 S 0.10 38 S 0.20 58 S 55 S 59 S 02 S 34 S 61 S 19 S 39 S 39 S 54 S 57 N 90 N 29 N 25 N 83 N W5 N 15 N 39 N 89 N 70 N 14 N 09 N 86 N 63 N 38 N 36 N 02 N 35 N 98 N 22 N 14 N 11 N 35 N 89 N 7O N 42 N 81 N 0.04 0.24 0.55 0.71 0.76 1.11 1.33 1.~9 1.48 1.25 0.39 3.58 6.38 8.74 12.75 19.48 27.68 34.39 43.86 54.49 63.87 75.23 88.78 103.96 118.21 128.95 140.12 150.74 164.13 180.42 198.75 217.34 235.79 254.02 271.75 287.72 303.12 .: ST W ~';..~' i'.,,':':'"S" 28 32 W 0;'.59 S ~ 2 W E 0.60 S 23 44 E E 0.8~, S: 43 2/' E 1.25 S 3~ 37'~ E 1.54 S 29 36 E E 1.96 S 34 32 E E 2.57 S 3I ~3 E 2.72 S 28 16 E 2.81 S 31 44 E 1.99 S 39 4 E 2.60 N 8 38 W 11.47 N 18 11 W 24.15 N 15 19 W 38.26 N 13 12 W 56.29 N 1 3 5 W 79.86 N 14 7 W 108.73 N 14 45 W 139.69 N 14 15 W 174.50 N 14 33 213.76 N 14 46 W 255.26 N 14 29 299.68 N 14 32 ,,W 348.36 N 14 401.33 N 1 5 0 4.56.94 N 14 59 W 513.80 N 14 32 W 573.40 N 14 8 W 634.51 N 13 4.4 W 698.53 N 13 35 W 76'9.66 N 13 33 W 845.82 N 13 35 W 923.06 N 13 37 W 1000.53 N 13 37 W 107,8.24 N 13 37 W 1156.09 ,~ 13 35 W 1231.50 N 13 30 1306.46 N 13 24 ME~SU DEP COMPUTATION ARCO 4L4SKA, INC. 2 q -9 NDRTH SLOPE,ALASK~ "' ,.,,.,.w. OJJ & Usc TRUE SUB-SEA C3URSE RED VERTICAL VERTICAL DEVIATION ~ZIMUTH TH DEPTH DEPTH... DEG MIN DEG MIN 4000.00 3508.57 3378.57 48 50 N 12 0 W 4100.00 3574.16 3444.16 49 11 N 12 11 W 4200.00 3639.33 3509.33 49 28 N 1Z 19 H ~300,00 3704.11 3574.11 49 39 N 12 26 W 4400.00 3770,03 3840,03 47 8 N 11 50 W 4500.00 3838,84 3708,84 46 26 N ll 22 W 4500,00 3908,77 3778,77 44 9 N 8 lO H 4700,00 3980.95 3850,95 43 42 N 7 27 W 4800,00 4052.72 3922,72 44 57 N ~ 48 W 4900.00 4123,24 39~3,24 45 6 N 9 1 W 5000,00 4193.53 4063.63 45 59 N 10 14 5100.00 4261.73 4131.73 47 27 N 12 23 W 5200.00 4329,44 4199.44 47 19 N 12 23 W 5300,00 4397.35 4267.35 47 9 N 12 37 W 5400.00 4465.18 4335.18 47 18 N 12 45 5500.00 4533.14 4403.14 47 7 N 12 44 W 5600,00 4600.39 4470,39 5700,00 4666,37 4536.37 48 56 N 12 43 5800.00 ~732.26 ~602.26 48 37 N 12 ~6 W' 5900,00 4798.31 4668,31 48 34 N 12 56 6000.00 4864,~4 4734,44 48 35 N 12 58 W 6100.00 4930,67 ' ~800.67 48 34 N 12 51 W: 6200.00 4996.68 4866.68 48 ~9 N 13 0 W 6300,00 5062.34 4932.34 49 9 N 13 0 W 6400,00 5127,48 4997,48 49 33 N 13 11 W 6500,00 5192.08 5062.08 49 51 N 12 53 ~ 6600,00 5256.37 5126.37 50 9 N 11 43 W 6700.00 5321,55 519.1.55 47 52 N 12 25 W 6800,00 5389.34 5259.34 47 19 N 12 54 W 6900,00 5457,3~ 5327,34 47 6 N 11 35 W 7000.00 5525.41 5395.41 47 ' 3 N 11 9 W TlO0,O0 5593,48 5463.48 47 6 N 11 31 W 7200,00 5661.53 5531.63 47 6 N 11 44 W 7300.00 5'729.72 5599.72 46 55 N 12 7 W' 7400.00 5798,02 5668,02 47 12 N 11 27 W 7500,00 5865.~1 5735,41 47 53 N 3 45 W 7500,00 5932.17 5802.17 48 24 N 6 16 W 7700,00 5998.02 5868,02 49 20 N 3 48 W 7800,00 6062.37 5932.37 50 31 N 3 5 W 7900,00 6124.38 5994.88 52 4 N 2 58 W DATE: 18-DEC-85 FOR EVEN 100 FEET VERTISAL SECTION FEET 1380.30 1455.77 1531.60 1607.74 1682,90 1755,46 1826.90 1896.00 1965.55 2036.41 2107.40 2180,61 2254.17 2327.55 2400,98 2474.29 2548.26 2623.36 2698,54 2773,57 2848,53 2923,41 2998,47 3073,83 3149,64 3225.91 3302,48 3378,29 3451,76 3525.0~ 3598,30 3571,54 3744,72 3817,95 3890,97 3964,8:3 ~039,16 ~11~.01 ~189,92 4267.25 OF MEASURE ODGLEG SEVERITY DEG/IO0 PAG~ 2 DATE DF SURVEY: 05 DEC 85 KELLY BUSHING ELEVATION: 130.00 ~l' ENGINEER: UR~M ,15 .35 ,49 ,46 .61 ,72 ,41 .89 ,15 D DEPTH 4.38 0.42 0.39 0.25 0.34 0.08 0.97 0.39 . 0.13 0.55 0.54 0.24 0.30 0.65 0.49 0.74 0.30' 3.19 0.~1 1.73 0 0 0 0 1 Z 2' 1 .31 .56 .33 .85 . 9,3 .21 · 58 .53 .24/ RECTANGULAR NORTH/SOUTH FEET 1 344,43 N 1418,23 N 1492,36 N 1566,75 N 1640.21 N 1711.31 N 1781.62 N 1850.25 N 1919.21 N 1989.23 N 2059,34 N 2130,99 N 2202,88 N 2274,54 N 2346,21 N 2417,75 N 2~89,97 N 2563,29 N 2535.55 N 2709,85 N 2782,95 N 2855,99 N 2929,19 N 3002,68 N 3076,58 N 3150,91 N 3225,79 N 3299,99 N 3371,67 N 3443,22 N 3515,10 N 3586,92 N 3658,60 N 3730,27 N 3801.69 N 3874.40 N 3948,20 N 40.23,18 N 4099,58 N 4177,52 N . .. COORDINATES MB.R~,"~DE PA R TUR E EAST/WEST FEiT F Ei;~~E G MIN ,.,; 318 67 W 1381~i~'~~,~'.13 20 W 350 5g W 1532.:~9.~::?.N'13 i3 366.9~ W 382.99 W 168%-33~""N 13 8 397.49 W 1756',87:,' N" 13 4 /' 410.16 W 1828.2~' 419,21 W 1897.14 N 12 45 W AzB.a3 w ~966.53 N 12 35 W k51,'2a W 2108,21 N 466,37 W 2181,~2 N 12 20 W 482.08 W 2255,01 N 12 20 W 498.00 W 2~28,~2 51~,20 W 2401,89 N 12 21 W 530,38 W 2~7.5,2~ N 12 22 W 5~6,5~ W 25~9,25 N 12 22 W 563,05 W 2624,40 N 12 23 W 579.68 6i3,19 W 2849,71 N 12 25 W 629,90 W 2924,63 646,77 W 2999,7k N 12 27 W N 12 27 W N 12 28 W N 12 29 N 12 28 W N 12 2~ N N 12 29 W 653.71 W 3075.16 680.88 W 3151.03 698.24 W 3227.36 714.41 W 330.3.95 730.01 W 33'79.77 746.36 W 3453.29 762,32 W 3526.60 776,44 W 3599.8¢ 790.86 W 3673.07 805,59 W 3746,25 820,71 W 3819,49 836,00 W 3892,53 849,05 W 3966.34 858.~3 W 4040.53 865,t2 W 4115.16 869,77 W 4190.83 873.90 W 4267.95 N 12 27 W N 12 26 W N 12 25 W N 12 24 W N 12 24 W N 12 21 W N 12 16 ~ N 12 8 W N 11 58 N N Il 48 W COMPUTATION ARCO ALASKA, INC. KUPARUK NDRTH SLDPE,AL~SKA DATE: 18-DEC-85 INTERPOLATED VALUES FOR EVEN 100 FEET DF COURSE DEVIATIDN ~ZIMUTH ~G ~IN DEG 52 44 N I 55 TRUE SuB-SEA ME&SURED VERTICAL VERTICAL DEPTH DEPTH DEPTH:? 8000.00 6185.B6 6055.8~' 8190.00 6246.39 6115.~9 8123.00 5260.32 61~0.32 VERTICAL DOGLEG SECTION SEVERITY FE~T DEG/IO0 4345.67 0.00 ~424.31 0.00 ~442.40 0.00 P~GE ~ DAT: DF SURVEY: 05 DEC 85 KELLY BUSHING ELEVATION: 1~0.00 FT ENGINEER: URAM MEASURED DEPTH RECTANGULAR COORDINATES NORTH/SgUTH EAST/WEST .. , ,~ . ~.~. ,.,. i EG N FE T FEET ~l~~~ii O MI 4256 71 N ,877o23 W 434~¥~'~'~]~JJ 11 38 W 4336 26 N .879.93 W 4624"'&i~::~':'i:~ 11 28 W 4354 55 N 880.55 W 4442;69:::~i~,?,N 11 25 W ,: , ''t 2M-9 KUPARUK N3RTH SLOPE,ALASKA TRUE IEASURED VERTIC 3EPTH DEPT 0.00 O. 1000.00 999. 2OO0.OO 1983. 3000.00 2846. 4000.00 3505. 5000.00 4193. 6000.00 4864. 7000.00 5525. 8000.00 51~5. 8123.00 6260. C OMPU r ATI ON INTERPOLqTED VALU:S FOR SUB-SE& AL VERTICAl. q DEPTH DEG"MIN COORSE' DEVIATION AZIMUTH DEG MIN O0 -130.00' 0 "0 89 869.89' 0 4 86 1853.86 18 52 70 2715.70 38 10 57 337~.57 48 50 63 4063.63 45 59 44 ~734.44 48 35 41 5395.41 4? 3 86 6055.86 52 44 32 6130.32 52 44 N 0 0 = 'N 8 44 .2 N 12 44 W N 11 31 W N 12 OW N 10 14 W N 12 58 W Nil 9 W N 1 55 W N 1 55 W OAT.E: 1 8-DEC-85 EVEN 1000 VERTICAL SECTION FEET 0.00 -2.59 139.43 533.66 1380.30 2107.40 2348.53 3598.30 4345.67 4442.40 PAGE 4 DATE OF SURVEY: 05 DEC 85 KELLY BUSHING ELEVATION: 130.00 ENGINEER: URAM FEET OF MEASURED DEPT ' RECTANGULAR COORDINATES H3~.]i.Z...,',Q:EP-- ~RTURE NORTH/SOUTH EAST/WEST DI :,~' :,..,'"t~ ' · I M U T H FEET FEET FEE::_. ~~..~ MIN 2 · 39 S ~ 2 ~'"~:,' 'S''' 28 515.35 N 150.7~ W .5'1 'N:i~ 4 2059.34 N 451.26 W 2782.95 N S13.19 W 2849.Zl N 1Z 25 ss .ss o.ss DOGLEG SEVERITY DEG/IO0 0.00 0.26 3.43 1.95 0~15 4.38 0.54 0.31 O.O0 0.00 FT ARCO ALASKA, lng. 2d-9 KUDARUK NORTH SLOPE,ALaSKA ..', ~-,- ,- ,-. :.. ~ ,,-r,.'~ [ NT E R P O L ~'t ~'O'"~AL j E $ FOR MEASU DEP 0 3O 130 230 330 430 530 630 730 ~330 TRUE SUB-SEA COURSE RED VERTISAL VERTICAL..,.DE¥I~TIDN AZIMJTH TH D6PTH DEPTH'~,~.<'DE6. MIN DEG MIN .00 0.00 -130.00" 0 0 N 0 0 · 10 30.00 -100.00 0 5 S 2 49 · 10 130,00 0,00 0 8 S 35 54 · 10 230.00 100,00 0 9 S 25 45 ,10 330.00 200.00 0 10 N 84 59 .10 430.00 300.00 0 10 N 83 39 .10 530.00 400.00 0 15 S 31 43 .10 630.00 500.00 0 13 S 6 36 · 10 730,00 600.00 0 14 S 54 19 ,11 830.00 700.00 0 21 S 27 38 930 1030 1130 1230 1330 1430 1531 1632 1734 1838 · 11 930,00 800,00 0 15 S 8 12 · 11 1030,00 900.00 0 7 N 75 42 · 11 1130,00 1000.00 0 13 N 15 30 ,13 1230,00 1100,00 2 7 N 19 43 · 30 1330.00 1200.00 4 39 N 22 42 · 8~ 1430.00 1300,00 7 6 N 13 43 ,75 1530,00 1400,00 7 58 N 9 41 · 88 1630.00 1500.00 9 45 N 11 42 .94 1730.00 1600.00 13 5 N 16 19 .43 1830.00 1700.00 16 33 N 17 12 1943 2049 2155 2256 2377 2491 2609 2729 2852 2978 ,30 1930.00 1809.00 17 56 N 12 25 W ,00 2030,00 1900.00 20 19 N 15 53 W · 77 2130,00 2000.00 23 19 N 15 32 W · 3~ 2230.00 ZlO0.O0 !4 39 N 12 41 W .39 2330.00 2200.00 27 2 N 15 9 N .42 2430.00 2300,00 30 20 N 15 29 W · 37 2530,00 2~00.00 33 30 N 16 32 W · 85 2630,00 2500,00 34 .22 N 10 53 W · 78 2730.00 2600.00 3.5 43 N 10 54 W · 80 2830,00 2700,00 37 55 N 11 0 W 3108 3255 3~12 3571 3729 3880 4032 4185 4339 4487 ,98 2930,00 2800,00 42 55 N 12 43 W · 63 3030.00 2900.00 49 ~9 N 13 58 W .54 3130.00 3000.00 50 42 N 13 48 ~ .08 3230.00 3100.00 51 2 N 13 27 W · 58 3330.00 3200.00 49 17 N 12 25 N ,74 3430,00 3300,00 48 39 N 11 51 W .58 3530.00 3400.00 48 57 N 12 4 W .67 3630.00 3500.00 49 26 N 12 '18 W ,94 3730.00 3600,00 49 8 N 12 27 W ,16 3830.00 3700,00 46 27 N 11 26 W SATE: 18-0EC-85 EVEN 100 VERTICAL SECTION FEET 0.00 -0.01 -0.11 -0.42 -0.58 -0.58 -0.80 -1,28 -1.53 -1,95 -2,58 -2.57 -2.57 -0,86 4.78 14.98 28.45 43,56 53.80 90,22 121.72 155.86 195,80 240.61 288.69 343.22 405,40 472,45 543,93 620,60 703.84 810.83 ~31.69 1054.42 1177,27 1290,61 1404.84 1520.72 1638.15 1746.14 FEET OF PAGE 5 DATE OF SURVEY: 05 DEC 85 KELLY BUSHING ELEVATION: 130,00 ENGINEER: URAM SUB-SEA DEPTH DOGLEG RECTANGULAR COORDINATES SEVERITY NORTH/SOUTH EAS~/WEST DEG/IO0 FEET FEET 0.00 0.00 N 0.00 E 0.62 0.01 S 0.00 W 0.47 0.14 S 0,14 W 0.28 0.46 S 0,19 W 0,18 0,59 S 0,05 E 0,05 0.53 S 0,33 E 0.28 0,70 S 0.64 E 0.34 1.17 S 0.70 E 0,20 1,~0 S 0,85 E 0,22 1.75 S 1,21 E 0.89 2,37 S 1.33 E 0.43 2,36 S 1.32 E 0.96 2.34 S 1.47 E 2.72 0.69 S 0.97 E 2.84 4.63 N' 1.25 W 2,42 14.39 N 4,53 W 0,34 27.60 N 7,13 W 3.34 42.48 N 9,76 W 3.65 62,13 N 14,83 W 3.26 87.52 N 22.69 W 0,90 118,06 N 30,59 W 3.79 151.33 N 38.49 ~ 3.02 189.T9 N 50,04 W 1,28 233.36 N 60,78 W 2,56 280.07 N 72,50 W 2.92 332.71 N 87,55 W 2.28 392.60 N 105.45 N 1,97 457,82 N 121.46 W 2,45 52?,99 N 135.,09 W 2.56 603,55 N 148.11 W 6,00 684,97 N 165,50 W 1.33 789.12 N 190,52 W 0,.40 906,60 N 219,68 W 0,70 1025,99 N 248.82 W 3.51 1145,74 N 276,70 W 0.41 1256,65 N 300,15 W 0.51 1368.43 N 323.78 W 0,35 1481.73 N 348.27 W 2,93: 1596.46 N 373.52 W . 0,36 1702,18 N 395.6.5 W .. H ~R~:~., iL. O E P A R T HU R E 0,'~'20 S:'44 47 W 0.59 S 4 32 5 0.95 S' 42 37) 1.36 S 30 56 5 1.64 S 31 22 6 Z.13 S 34 31 ~ 2,72 S 29 16 E 2,70 S 29 10 E 2,76 S' 32 12 E 1,19 S 54 35 E 4,79 N 15 6 W 15.09 N 17 28 W 28,51 N 14 29 W 43,59 N 12 56 N 63.87 N 13 25 W 90.42 N 14 32 W 121.99 N 14 34 W 156.15 N 14 16 W 196.28 N 14 46 W 241.14 N 14 35 W 289.30 N 14 30 W 344.04 N 14 44 406.52 ~ 15 2 1~, · 473.65 N 14 51 W 544.99 N 16 21 W 621,45 N 13 47 W 704.68 N 13 34 W 811.79 N 13 34 N 932.84 N 13 37 W 1055.73 N 13 37 W 1178.58 N 13 34 W 1292.00 N 13 25 W 1406.22 N 13 18 W 1522.11 N 13 13 W 1639.57 N 13 10 N 1747.55 N 13 5 W FT COMPUTATI3N DATE: 18-DEC-$5 1RCO .&L&SKA, INC. IH-9 ~,UPARUK qDRTH SLOPE,ALASKA TRUE E~SURED VERTICAL DEPTH DEPTH 4529.47 3930.00 4758.03 4030.00 4909.58 4130.00 5053.01 4230.00 5200.83 4330.00 5348.03 4430.00 5495.38 4530.00 5644.77 4530.00 5796.53 4730.00 5947.90 4830.00 6098.99 4930.00 6250.66 5030.00 6403.88 5130.00 6558.85 5230.00 6712.58 5330.00 68'59.85 5430.00 7006.74 5530.00 7153.56 5630.00 7300.42 5730.00 7447.27 5830.00 7596.72 5930.00 7749.39 5030.00 7908.33 6130.00 8072.92 5230.00 8123.00 6260.32 INTERPOLATED VAL SOO-SEA COURSe_ VERTI CHAL, .DE¥IAT ION AZ · t '~,' 'i]"'~.Ji .' 3800.00 ':~'4~;'51 N 3900.00 44 22 N 4000.00 45 5 N 4100.00 47 19 N 1 4200.00 47 18 N 1 4300.00 47 18 N 1 4400.00 47 T N 1 4500.00 48 39 N 1 4600.00 48 38 N 1 4?00.00 48 36 N I 4800.00 48 4900.00 48 58 N 1 5000.00 49 34 N 1 5100.00 50 1 N 1 5200.00 47 31 N 5300.00 47 4 N 1 5400.00 47 3 N 1 5500.00 47 1 N 1 5600.00 46 55 N 1 5700.00 47 38 N 1 5800.00 48 23 N 5900.00 49 57 N 5000.00 52 10 N 5100.00 52 44 N 6130.32 52 44 N UES FOR IMJTH G MIN 7 33 W 5 1i W 9 1 W 2 12 W 2 44 W 2 40 W 2 45 W 2 58 W 2 51 W 2 57 W 3 1Z W 2 0 '~' 2 3B W 2 32 W 1 10 W I 35 W 2 7 W 0 17 W 6 22 W 3 Z5 W 2 55 W 1 56 W 1 56 W EVEN 100 FEET OF PAGE 6 DATE OF SURV'EY: 05 DEC 85 KELLY BUSHING ELEVATION: 130.00 FT. ENGINEER: U'R~M SUB-SEA DEPTH VERTICAL DOGLEG RECTANGULAR SECTION SEVERITY NORTH/SOUTH FEET DEG/IO0 FEET 1847.32 0.92 1801.89 N 1943.06 2.68 1896.96 N 2043.19 0.07 1995.93 N 2145.96 2.35 2097.14 N 2254.78 0.38 2203.48 N 2352,82 0.39 2308.97 N 2470.91 0.11 241~.45 N 2581.82 0.51 2522.74 N 2695.98 0.17 2634.15 N 2809.47 0.29 2744.86 N 2922.65 0.23 2855.26 N 3036.60 D.27 2966.38 N 3152.59 0.49 3079.46 N 3270.89 1.32 3194.86 N 3387.60 2.32 3309.08 N 3495.64 1.47 3414.48 N 3603.23 0.37 3519.95 N 3710.72 0.32 3625.31 N 3818.25 0.86 3730.57 N 3925.78 2.14 3835.88 N 4036.72 2.60 3945.76 N 4151.35 1.23 4060.75 N 4273.77 0.97 4184.09 N 4403.02 0.00 4314,72 N 4442.40 0.00 4354.55 N COORDINATES H3R! ,~:¥~<, PARTURE EAST/WEST O I S "~,i~ ~i ~ ~J T H 412.9! W 1848 54 W 425.49 W 1944 38 W 441.02 W 2044 ":"~:~(2 27 W 458.90 W 2146.?~"'.~,;:~:~'N~.',72 20 W 482.21 W 2255.62~,N:~2 20 W 505,75 w 2~6~.?1. '"Nv~,12 21 ~i' 52~.6~ W 2~T~.aa N '12 22 a 553.9~ W 2582.83 579,11 W 2~9~.06 604.41 W 2810.61 629.73 655.33 681.55 707.96 732.03 756.13 777.40 798.71 820.77 842.58 ,, 85'8.57 867.57 874.25 879.20 880.55 N 12 23 W N 12 23 d N 12 25 N W 2923.88 N 12 26 W W 3037.90 N 12 27 W W 3153.98 N 12 28 W W 3272.36 N 12 29 W W 3389.09 N 12 28 W W 3497.19 N 12 2'9 W W 3604.77 N 12 27 W W 3712.25 N 12 25 W W 3819.79 N 12 24 W W 3927.32 N 12 23 W W 4038.09 N 12 16 W W 4152.39 N 12 3 W 4274.45 N 11 48 W W 4403.38 N 11 31 W W 4442,69 N 11 25 W ARC~ ~LASKA~ INC. 2~-9 KUPARUK N~RTH SLOP~LAS~A MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD COMPUTATION INTERPOLATED VALUES FOR "MEASURED DEPTH BELOW KB 7578.00 7720.00 7758.00 7974.00 8025.00 8123.00 DATE: 18-DEC-85 ~,HOS'E N H]RIZONS ORIGIN: 170' TVD FROM KB SJB-SEA 5983.6~ 5853.64 6011.02 5881.02 6035.53 5905.53 '8170.09 6040.09 6200.99 5070.99 6260.32 6130.32 PAGE 7 DATE OF SURVEY: 05 DEC 85 KELLY BUSHING ELEVATION: 130.00 FT ENGINEER: UR~M SUR CTAN ORTH FNL, 534' ~EL, RE N , RBE,UM ATES WEST CO ALASKA, INC. !-9 IP&RUK IRTM SLOPE,ALASKA COMPUTATIJN gATE: 18-DEC-85 PAGE DATE DF SURVEY: 05 DEC 85 KELLY 5USHING ELEVATION: ENGINEER: URAM FT TOP EASE TOP 8&SE PBTD TD MARKER KUP~RUK S KUPARUK C KUPARUK ~ KUPARUK A ,~,$**$,~**$ STRATIGRAPHIC MEASD'RED DEPTH BELOW K5 7678.00 7720.00 7758.00 7974.00 8123.00 ORIGIN: 170' FNL, TVD FROM KB SUB-SE~ 5983.64 5853.64 5011.02 5881.02 5035.53 5905.53 6170.09 50~9.09 5200.99 5070.99 5260.32 6130.32 534' ~ RE.C NO SJRI:~CE EL, SEC TANGULAR , 006.57 N B64.06 W 038.35 N 86'6.~8 W 057.3~ N 867.95 W 236.05 N 876.5B W 276.60 N 877.90 W 354.55 N 880.55 W FINAL MEASURED DEPTH WELL LOC~TIgN ~T TD: TRUE SdS-SEA VERTICAL VER'TICAL DEPTH DEPTH 8123.00 5260.32 6130.32 HORIZONTAL DEPARTURE DISTANCE AZIMUTH F£ET DEG MIN N 11 25 W SCHLUMBERGER O I RE~CT I ONAL SURVEY COMPANY ARCO ALASKA INC. 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':.I"T'T'I?"TT'T'T"? ...... -?- .-!l~-?-..m-..:,--?--:--?-~ --~- ..!--- .-,:-+.---.l-,~.l,-?-:,.-- ----r--~.-~.---. -.,-~?-?- .~-.-t-. ?? .~--.+-- .--l-?- .---:--?-,.-- :---I--~.-.,--?---? ...... ?~-.-.+..?---.~-?-.-,-..-..-.-? ..... ?.-.?...,:..--~.--~.-.-~.-.t-.?.? ...... ,.-.,...~.--,.... ....... ?-.-?...,... -200o ~--t-.~}fi-f%~-! i~--':i---::.--+--~-?ff-f-[-?t--t-T:-d-'k?~i-+t'?~--?-ff-f'-ffj---?-t+'f'--'---ff-Sff?j--ff'ff--:-'-! ...... H-?:'-'-ff-f-'?'ff'+ ..... i"-i-"t'-!-'i'-+"-:'--!--'+-" -4000 -5000 -2000 - 1000 0 1000 2000 3000 4000 NES? ERST I~I:11.£ = I/I000 IN/FT HORI, JECTION Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. . . O~P, AZOR, ~E-L~~ A~) ~U~R . . Reports and Haterials to be received by: / Date .. ' Required Date Received Remarks , Completion Report ye~ ' /- '~ ' -~/ -c'')C~z ~'~ _ Core Chips . ., ~ - . inclination Survey ~4 --' .... ' . . - / Drill Stem Te~t Report~ ~~/,~__. ~ ,, ~ [~. Prod.c~on Tes~ Reports ~~' b~,~ / Log Run y * .: ~--' '~ ~:_ :~ ~_ ~~ . L. FJ. 04 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 14, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT'. State Reports Dear Mr. Chatterton' Enclosed are the December monthly reports for the following wells' 1A-7 2H-6 3A-13 3F-12 3J-11 4-29 L2-29 1A-13 2H-7 3A-14 3F-13 3J-12 16-15 L3-5 1A-14 2H-8 3A-15 3F-14 4-23 16-19 L3-!9 1H-4 2H-9 3A-16 3F-15 4-24 16-20 L3- I~' 1H-8 2X-8 3F-11 3J-10 4-27 L2-21 If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU13/L05 Enclosures RECEIVED JAN 1 1986 0tl & Gas Cons. I;ommir~s/on /',/RCO A!~ska. Inc i:. ;: .c.u'.~.'.i,fi*ery ol /'.llan;~cRichfi¢',dCompany STATE OF ALASKA ALASKA C~-- AND GAS CONSERVATION COk..~IlSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS ~1. Drilling well ~[ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-259 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 103-20050 4. Location of Well atsurface 170' FNL, 534' FEL, 5ec.35, TllN, RSE, UM 5. Elevation in feet (indicate KB, DF, etc.) 130' RKB 6. Lease Designation and Serial No. ADL 25587 ALK 2673 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2H-9 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of December , 19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 1830 hrs, 11/25/85. Drld 12-1/4" hole to 3000'. Ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 8123'TD (12/01/85). Ran logs. Ran, cmtd, & tstd 7" csg. PBTD = 8025'. Secured well & RR ~ 2000 hfs, 12/03/85. 13. Casing or liner rgn and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set ~ 110'. Conductor report not yet received. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe ~ 2982'. Cmtd w/750 sx CS I11 & 525 sx CS II. Performed top job w/90 sx CS II. 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 8108'. Cmtd w/450 sx Class "G" & 175 sx CS I. 14. Coringresumeand briefdescription [,lone 15. Logs run and depth where run DIL/SP/SFL f/8120' - 2982' FDC/CNL f/8120' - 7450' GR f/8120' - 1800' Ca1 f/8120' - 2982' 6. DST data, perforating data, shows of H2S, miscellaneous data RECEIVED None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ~~.~] TITLE Associate Encjineer DATE NOTE--Report ~ this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~,04 TEMP3/MR09 Submit in duplicate ARCO Alaska, inc. Post Office B~_.-I00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC · ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 12-19-85. TRANSMITTAL # 5473 Transmitted herewith are the following items, please acknowledge receipt and return one signed copy of this transmittal. Open Hole LIS Tape plus listing/ schl/ One copy of each lQ-4/~ 83-18-85 Run #1 4570.0-9471.0 ~2H-9/~ 12-02-85 Run #1 1800.0-8113.0 ref~ 71048 ~2H-10~/ 11-23-85 Run #1 2856.0-7960.0 ref# 71002 '~2H-12 J, 11-07-85 Run #1 2743.0-6829.0 ref# 70947 ~2U-7// 03-19-85 Run #1 3594.5-8179.5 ref# ~2V-16/! 06-03-85 Run #1 2973.0-7168.0 ref_~ 70952-~CO~?~/~ ~3A-10Y! 11-09-85 Run #1 3179.0-7014.0 ref~ 70960 ~3A-11x, 11-16-85 Run #1 3208.0-7330.0 ref~ 70989 3A-12// 11-23-85 Run #1 3797.0-8006.0 ref~ 71003 '~3A-13;/ 12-01-85 Run #1 1800.0-7597.0 ref# 71047 ~3A-14'/ 12-09-85 Run #1 0144.5-7818.0 reft. 71073 3C-9 ~ 07-10-85 Run #1 3920.0-8332.5 reft.. 70996--r~~-; 3F-8~! 11-09-85 Run #1&2 0115.0-7040.0 ref~ 70994 ,~3F-9/~ 11-17-85 Run #1 3410.0-7770.0 ref~ 70990 3F-10u 11-27-85 Run #1 1800.0-6631.0 ref~ 71037 3F-11~ 12-05-85 - Run #1 0148.0-8618.5 ref~ 71061 3J-9.x/ 11-24-85 Run #1&2 0~91.0-6789.0 ref~ 71034 3J-10'~ 12-08-85 Run #1 0096.5-7348.5 ref~ 71074 3 7-3- 3 / 7 Date: Receipt AcknQwledged: 'S~ O~ ~S~~ ARCO Alaska. Inc. ~s a Subsidiar~ of AllanticRic~Del~Com~an~ ARCO Alaska, Inc. Post Office Bo'~'i00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 13, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton: Enclosed are the November monthly reports for the following wells: 2H-9 3A-11 3F-8 4-22 16-19 2H-10 3A-12 3F-9 4-29 L2-3 2H-11 3A-13 3F-10 16-7 L2-21 2H-12 3C-6 3J-9 16-15 L3-15 3A-10 3F-7 3J-10 16-18 WSP-12 WSP-20 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU12/L129 Enclosures RECEIVED OU ~ Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany. · STATE OF ALASKA ALASKA O,,.~AN D GAS CONSERVATION COb_.,.ilSSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling wellY~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-259 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50-103-20050 4. Location of Well atsurface 170' FNL, 5:34' FEL, $ec.:35, T11N, R8E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 1:30' RKB ADL 25587 ALK 2673 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2H-9 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of. November ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 1830 hrs, 11/25/85. Drld 12-1/4" hole to 3000'. Ran, cmtd & tstd 9-5/8" csg. to 7359' as of 11/30/85. Drld 8-1/2" hole 13. Casing or liner run and quantities of cement, results of pressure tests · 16", 62.5#/ft, H-40, weld conductor set @ 110'. Conductor report not yet received. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe @ 2982'. Cmtd w/750 sx CS I!1 & 525 sx CS II. Performed top job w/90 sx CS II. 14. Coringresumeand briefdescription None 15. Logs run and depth where run None 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. RrCE!VED Alaska Oil & Gas Oons, Con]mission Anchora2e NOTE--Report on t~is form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 TEMP2/MR63 Submit in duplicate ARCO Alaska, Inc. Post Office B~)"~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 1, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive AnchoFage, AK 99501 SUBJECT: Conductor As-Built Location Plats - 2H Pad Wells 9-12 Dear Mr. Chatterton: Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU12/L65 Enclosure ARCO Alaska, Inc. is a Subsidiary of AttanticRichfieldCompany 70 60 O ~ O2 04 DRILL TE 2.H CONDUCTORS AS' '~'~Ul LT LOCATIONS WELL 0 Y = 5,948,693.16 -+-.7 864 9' 170' FNL, }34' FEL WELL Y = 5,048,693.14 X = 497,804.92 tTO'FNL, 594'FEL Y = 5,948,693.24 ]70'FNL, 7i4'FEL LAT. 70°i6'i5.792t''' hONG. 150°0i'O3,910,' EL = 9~.8,O6 - 90.5' l.:\?. 70°76'1 $.~Oi©" LONG. 1.50°01'05.656" EL = ga.8,OG = 90.5' LAT. /{.~ 16'15.7929" bO:'.i(,, ~50°01'07.;:'.?'q" EL = 9~.9,0G = 90,4' LOC ATED IN SECTION 35 T II N, R ~E , tJMIAT MERIDIAN. R ECEIVED !or o 4 ! Alaska 0il & 6as Cons. Commission Anchorag8 -E-REBY iE~T :'Y --Aw ' AN~ F-RC'DERLY REGISTERED ~ _.CE%SE' ~'- n~.ACT.CE _AND SoR~E¥iNG IN THE STATE OF A,_ASKA ~ -r,4A~- ?,~ S P~AT ~EFRESENTS A SURVEY MADE ..%3E~ MY ~-k..T Su _:~ S,ON & THAT ALL DETAILS ARE .-- ARCO Alaska, Inc. ~,-:3~-~ ;::~c.ec' h~ortr. Slope Drilling DRILL SiTE 2.H CONDUCTOR AS. BUILT LOC AT I 0 N S --'e October 18,1985 ! j Scaie. ! : { ~g. no.:NSK 85-28 October 30, 1985 Mr. J. B. Kew in Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2H- 9 ARCO Alaska, Inc. Permit No. 85-259 Sur. Loc. 170'FNL, 534'FEL, Sec. 35, TllN, RSE, L~f. Btmhole Loc. 1076'FNL, 1366'FEL, Sec. 26, TllN, R8E, 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. ~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may %~_tness testing before drilling below the shoe of the conductor pipe. Ve~ t r u~y~y~our s Chairman of Alaska Oil and Gas Conservation Commiasion BY ORDER OF THE CO~MISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl, Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office Bo~t"q00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 23, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2H-9 Dear Mr. Chatterton: Enclosed are: An application for Permit to Drill Kuparuk 2H-9, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plot A diagram and description of the surface hole diverter system ° A diagram and description of the BOP equipment We estimate spudding this well on November 25, 1985. any questions, please call me at 263-4970. ~~Re g i~eo rn ea 11y 'Dri 1 l~nee r' JBK/lt PD/L93 Enclosures If you have ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany la. Type of work. STATE OF ALASKA ALASKA OTc AND GAS CONSERVATION COiw~ISSION PERMIT TO DRILL 20 AAC 25.005 lb. Type of well EXPLORATORY [] SERVICE [] DEVELOPMENT OIL E~X SINGLE DEVELOPMENT GAS ~ MULTIPLE 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. ~x 100360, Anchorage, Alaska 99510 DRILL I-X]X REDRILL [] DEEPEN [] 4. Location of well at surface 170' FNL, 53/+' FEL, Sec.35, T11N, R8E, UM At top of proposed producing interval 1/+20' FNL, 1301' FEL, Sec. 26, T11N, R8E, UM At total depth 1076' FNL, 1366' FEL, Sec.26, T11N, R8E, UM 5. Elevation in feet (indicate KB, DF etc.) RKB 130' PAD 95' 6. Lease designation and serial no. ADL 25587 ALK 2673 9. Unit or lease name Kuparuk River Unit 10. Well number 2H-9 11. Field and pool Kuparuk River Field Kuparuk River Oi] Pool 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 30 mi. NW of Deadhorse 16. Proposed depth (MD & TVD) 8125' MD, 6260' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 1350feet. 21 14. Distance to nearest property or lease line miles 170' ~ Surface feet 17. Number of acres in lease fee. t 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE /+8° (see 20AAC25.035 (c) (2) Proposed Casing, Liner and Cementing Program 15. Distance to nearest drilling or completed 2H-10well 60' @ Surface feet 18. Approximate spud date November 25, 1985 3559_ psig@ 80OF Surface psig@ 59~.0 ft. TD (TVD) Hole i24,, 12-1/4" SIZE Casing Weight 16" 62..5# 9-5/8" 36.0# 7 '~ £~.0~ 22. Describe proposed program: CASING AND LINER Grade Coupling H-40 I Weld J-55 I BTC HF-ERW HF-ERW Length M D TOP 80' 36' I I 2900' 36' I 8090' I 35' I 35' SETTING DEPTH TVD MD BOTTOM TVD 36' 116' I 116' 36' 2936' 12760' I 8125' 16260' I I QUANTITY OF CEMENT (include stage data) · 200 cf 690 sx CS III & 340 sx Class G 300 sx Class G ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8125' MD (6260' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOP stack will be installed on the 9-5/8" surface casing. The stack and related equipment will be tested to 3500 psig upon installation and weekly thereafter. Expected maximum surface pressure is 3090 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3500 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 2H-9 will be 60' away from 2H-10 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. (continued on attached sheet) 23. I hereby ce~at the foregoing is true and correct to the best of my knowledge SIGNED ////~/~~4~,z TITLE Regional Drilling Engineer The space ~for (~/on('('m/i n(~r~us - CONDITIONS OF APPROVAL DATE /~, ~/~/~~ Samples required []YES .[~NO Permit number APPROVED BY Form 10-401 Rev. 7-1-80 Mud log required Directional Survey required APl number i--lYES ~LNO I~.YES []NO 50-- / 03 -~O0''-,A'~'O ~ ~ . Approval date / /~/'"-///.~/7 '~-" .~/~)0'85 S EECOVERLETTERFOROTHERREQUIREMENTS _,_.,COMMISSIONER DATE October 30, ] 985 by order of the Commission (LWK) PD/PD107 / // Submit in triplicate PERMIT TO DRILL 2H-9 Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 175 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. ARCO~ ALASKA, : ......... KUPARUK-FI-ELD~(--NORTH 'SUOPE, ~ ALASKA : ~-::~/ ..... ........... HAN- WHIPSIOCK~.:~NC ........... ~ .............. , .......... ~ ............................ ~ ........ ~ .... ....... h ....................... ~ ......... ~ ' - ; ....... : .............. : ; ~ ........ _ .... ......... : ....... KOP- - TVD= 1350~-TMD= t 350- DEP=O ~ ---~ ...... ~--~- : .......... V-4s:-. E-OC --(9-5/8 CS$-PT)~ ..... ~VD'2760-THD=29S6 DEP=622 ..... ~ - ~ ...... : ..... ~ ............ ~ ......... ~ ......... ~ - - ~ - ~ ...... ..... ~ .... ~ ................. i .... ~ ......... ~ ............. p ....... ~ ....: ~ :_~ .......... .......... ~- ' o -' ...... : - - 3 oo0 .' - '-::::.:-.2000:2~::::::-~ooo7:::: :2:::::~00o::;: _ 5000 ........ .... 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'~ >. *",. ~"--:,..:~'"'"'""~ ..... .......... l, .t ..,..-"'"'"-""-.,'..l ,. ~,,,,~ ,~ .~,; .. , , ...... ... ,,, ~ .} ,, ,... t /~|... . .,, , : ; . , { ' , , ..... ~ , ~ ~ . . , , , ~ , ~ , : ', , :. : .,~..,~... ~." .V ~._:. '.' '. ~'.'.. i. :"",/ ........ : -- !' ~" !'..'~'~ :.:..'.-.'- ::... '. ..... ! .... ~ .... :-. !.'.-:-:-~ J.' .... O0 ~' Oo ' i9oo ?oo 6oo ' . '. 500 400 300 200~ 'i'00 KUPARUK RIVER UNIT 20" -DI VE TER SCHEMAT I C n! 7 6 7 DE S CR I PT I ON ,,, i. 16' COt,,EXJCTOR. 2. TAt,KO STARTER WEAD. 3. TAt,KO SAVER SUB. TANKO LOYER QUICK-CC~ECT ASSY. 5. TANKO UPPER QUICK-C~CT ASSY. 20' 2000 PSI DRILLING SPOOL W/I0" OUTLETS. 7. I0' HCR BALL VALVES W/I O' DIVERTER LINES, VALVES OPEN AUTOMATICALLY UPON CLOSURE OF' ANN.~AR PREVENTER. 8. 20" 2000 PSI At,ti. ILAR PREVENTER. 5 4 MAI NTENANCE & OPERAT. I ON , · I. UP'ON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVES " HAVE OPENED PROPERLYo CLOSE AI~LAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE AhINULAR PREVENTER IN THE EVEN'T 'THAT AN I~LUX OF WELL~ FLUIDS OR GAS IS DETECTED. IF NECESSARY, 1',4A~ALLY OVERRIDE AND CLOSE APPROPRIATE VALVE TO ACHIEVE ~IND DIVERSION. DO NOT SHUT IN ~ELL · UNDER ANY ClRCUMSTAh~ES. ii 7 6 5 . 4 > 3 DIAGRAM #1 15-5/8"~~ PS]' RSRRA BOP ~TA(~ I. 16' - 2000 PSI TAN~CO STARTING HE. AD 2. I1' - ~ P~! CA~ING ~ 4. !~8' - ~ ~I PI~ 5. !~8' - ~ ~I ~I~I~ ~ ~~ KI~ LI~ 6. 1~8' - ~ ~I ~ ~ W~I~ ~ ~ 7. 1~8' - ~ ~I ACQ.MJLATOR CAPACITY TEST i. CHEO< AAD FILL A~TOR ~OIR TO PR~]:'ER LEVEl_ WITM HY~IC FLUID. 2. ~ THAT AC~TOR PR~ IS _3000__ PSI WITH 3. OBSERVE TIN~, ~ CLOSE ALL UNITS SII~I.T~~Y AlL l.t~ITS ARE CLOSED WITH Q-I~A~ING PLIVP ~F"F. 4. RE~ ON NADC REPORT, ~ ACCE3:'TABLE LOllER LIMIT IS 45 SE~ CLOSING TINE ~ 12_.00 PSI RE]V~INING 13-5/8" BOP STACK TEST 1. FILL E~ STAa< AAD ~ MANIFCLD WITH ARCTIC DIES~. 2, C~CX THAT ALL LO(:X DOI~N SC~ IN V~]_LJ-F_AD AR~ F1JLLY RETRACTS. SEAT T~T PLUG IN ~ WITH RUNNIN~ J'r AAD RUN IN LO~ SCR~. LIE V.,N_VES AD,./A~ TO BO~ STACX. ALL ~ PRE,~ UP TO 2~ PSI AND HOLD FOR I0 MIN. IN- CREAS~ PRE~ TO 3000 PSI AND NO...D FOR I0 MIN. BLF"~F~ PRE~ TO 0 PSI. OMeN Ah~LLAR PREVENTER AAD MANJAL KILL AhD a-K~E LI~E VALVES. CLOSE TO:~ PIPE ~ AhD NCR VALVES ON KILL AAD ~ LIh~S, TEST TO 250 PSI AAD 3000 PSI AS IN STEP 4. 03NTINdE TESTING ALL VALVFSo LINES° AN] CH/D<ES WITH A 2_50 PSI LQ AND 3000 PSI NIGH, TEST AS IN STE~ ,~. DO ~T F~~ T~sT ANY ~ T~AT ~S ~ ~ F'IJLL CLO~N~ POSITIVE SEAL~. Ct~Y FUNCTI~ T~S~ CHQ<~$ T~AT ~0 N~T FU_LY CLOSE. TEST BOTTCI~ PIPE RAMS TO 250 PSI ~ 3000 PSI. -10o CLOSg BLZN2 RAM~ ~ TEST TO Z50 PSI AN:) 3000 PSI', FLUID. SET ALL VALVES IN ~I~ILLING POSITION, ~z TEST STA~:~IP~ VALVES, X'~LLY. X~L~ COa<So OR!LL PIP~ SAFETY VALVE, A~D ImI:Z ~ TO ~ PSI A~D 3000 PSI. 13. RECCI~ TEST IAFCI:B~ATION CN BLC~OI;r PR~ TEST FORgo SIGN, AhD SE~D TO DRILLING SLF~RVISOR. 14. PERF~ O~E BCPE TEST AF'FER NIPPLING UP AND VlEEKLY THEREAFTER FIJ~IONALLY OP~RA~ BCPE DAILY, I! I I CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee / (2) ~.oc~- .{2 thru 8) . 3. 4. 5. 7. (~.,~..,.,.o, 1~' ~£Z~" . (3) Admin ~ 9 [9 thru 12) 10. (10 and i9) ! -- 12. (13 thru 21) (22 thru 26) 13. · 14. 15. 16. 17. 18. 19·' 20. 21. 22. 23. 24. 25. 26. 27. YES NO Is. the permit fee attached .......................................... Is well to be located in a defined pool ............................· Is Well located proper distance from property line .' . Is well located proper distance from other wells ....1 . . Is sufficient undedicated acreage available in th%s pool ............ Is well to be deviated and is wellbore plat included . ....... Is operator the only affected party .................. '''' ' ' Can permit be approved before ten-day wait .......................... Does operator have a bond in force .................................. Is a conservation order needed ....................................... Is administrative approval needed ............................... ,... ," Is the lease number appropriate ............................. . ........ IS conductor string, provided ...................................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover alt known productive horizons .................. Will surface casing protect fresh water zones... .............. ~en~ion ~n~ b~;st Will all casing give adequate safety in collapse, 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 ............................ ~4~ Is a diverter system required ...... ~ ............................... Are necessary diagrams of diverter and BOP equipment'attached ... Does BOPE have sufficient pressure rating - Test to ~~ psig Does the choke manifold comply w/API RP-53 (Feb.78) ...... · ............ Is the presence of H2S gas probable ................................. Additional requirements ............................................. REMARKS //,/7, Additional Remarks: 0 Geology: Engineering: HWK~ LCS ~- BEW WVA~__ MTM ~ HJH~ rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE , 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. ; £ L = ':".I ,; "I F : ~ ,3 :' ? VERSi3!',I .,: : '4.AX151j;q LS~IGT ,DREvZS;jS :iL,E :;~ :': l .q F ,3 ;7 ;"t q T l ~ · 30 'i : :m ~ .... P R E S: .";-' '-;: ~' 3 ¢4 '"'I E ~ T S 'J 'q IT J !'q I T Tyo~ 003 OOu 333 O00 300 gOO 000 OD"J T y..> 'i .... 000 .... 00 0 3O3 000 .SIZ5 O 19 014 008 " O 0 1 C 09 = 0,.55 055 0 %5 O55 CE.L3= 355 J.'3':_, ;"~O~'IB:::~ ;:,T A"li' 71'3~,:; LD?: L. ":~. CU21".~:Y T2 = 3. !'? '~ : ~ = !,593, '7 ! · 0 71,0 ";' i · n jF LV ¢ '318.~u! V'::-~ ~':.!'=13'J i_ :. S T i ',t ,: P&3E 5FLj ]u3 3TL iL'4 SP ,,gq 3iL ..... .~ , F '3 "q ,...= 3 N GR $ NL 3~PT SP NP~i -1. 5534 ,~ ":3.73 O ,5 SP 300 · '3 O 0 ,'3 .S !::': L ',J -30.2295 3q £. 4 .~i ,') .-., '2: ~ -' '~ 35.546:? "q C ~ _ SP C,E?T ~ 1 56 I ~., "'t F.'. ~. "' J. 55 '_,, ":' L '3 C q S U '~ - T ENTRY' 3 I 33 .lin i 3. 3a9i. iL~'_, 1.2,3.1523 GA O.l.!e6 NR:IT 2055.5000 FCNL 3.7131 1!3.1523 0.1123 NR~T 205~.5036 FC~L ,..,, . 2_,' ;:~ 36 iL3 )9 ,,, :~ S48 "3iR Z357.~000 '~CNL 3.01'98 ,z. ..... 1 523 506.3'30,5 3.435~, 52 3.8~99 F. jS. 390,5 ¢. gl'? 9 9.9 S ,48 3.!Z~l ?~!.BIZ5 2,9670 334.3!Z5 ,59.2773 ILM C A t '1 RNR~ IL~, C,,~ ti E N R' ,~ !3 'R G R C A I. I 030'3033 0003300 30 'O 00 n., ,, i'"'I, "~ '"', ..., ,.,' 30 ~ 33 0003000 O '3 r] O 00 ;] 90OO000 00 0 O O 03 0000000 ,., J J o C ~' n ,,d ,~ 3030000 OSO0000 O iD 0 O 030 O000OO0 ':q3CES O ,30 0 O 0 u 9 O ,.,,., 000093 O0030'3 0 ')0 C.' 00 OO]O00 OOO000 00 ] '3 O 0 000300 0.']3000 OO.OOOO 000000 909000 O000OO 000000 2.'~55! 8.5020 4.0750 -999.2500 -99 -;99 3.5940 '4.0'723 a.0750 9,.0175 3. ,I ~ g 7 9.2500 6,.9695 3.3030 9.2590 7.:3370 3 n 7 ",~ ' ;_¥-) J,.~ O.HJ2 'V'54!;Z ~-'''! ..... 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