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196-062
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 14391'feet None feet true vertical 6156' feet 14205', 14207'feet Effective Depth measured 14009'feet 13764', 13835'feet true vertical 5901'feet 5746', 5789'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" 3-1/2" L-80 L-80 13814' 13861' 5777' 5806' Packers and SSSV (type, measured and true vertical depth)13764' 13835' 5746' 5789' 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: 14347' 5485' 2978' Burst CollapseCasing 6152'14385' 5445' 121'Conductor Surface Production 16" 9-5/8" 80' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 196-062 50-103-20239-00-00 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: ADL0025570, ADL0025571 Kuparuk River Field/ Kuparuk Oil Pool KRU 2A-25 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) 430 Gas-Mcf MDSize 121' 3360 12804300 Well Shut-In 200 324-195 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: BluePack RH Max Packer: Baker 84 SAB HYD SSSV: None Elliott Tuttle elliott.tuttle@conocophillips.com (907) 263-4742Staff RWO/CTD Engineer 13972-13992', 14001-14009', 14010-14030' 5877-5890', 5895-5901', 5901-5914' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 8:08 am, May 24, 2024 Digitally signed by Elliott Tuttle DN: OU=CTD/ RWO Senior Engineer, O=Conoco Phillips, CN=Elliott Tuttle, E=elliott.tuttle@ conocophillips.com Reason: I am approving this document Location: Date: 2024.05.23 14:50:44-08'00' Foxit PDF Editor Version: 13.0.0 Elliott Tuttle DSR-5/24/24 RBDMS JSB 053024 Page 1/5 2A-25 Report Printed: 5/21/2024 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) 4/19/2024 06:00 4/19/2024 07:00 1.00 MIRU, MOVE RURD P Rig down checklists // Secure equipment prep for pulling off well // Pull rig off well stage on pad 0.0 0.0 4/19/2024 07:00 4/19/2024 09:00 2.00 MIRU, MOVE MOB P Clean and inspect cellar // Wait for change out to complete // Prep rig and equip for mob to 2A pad 0.0 0.0 4/19/2024 09:00 4/19/2024 13:00 4.00 MIRU, MOVE MOB P Mobilize rig to 2A pad 0.0 0.0 4/19/2024 13:00 4/19/2024 15:00 2.00 MIRU, MOVE OTHR P Spot mats and prep cellar for spotting rig over 2A-25 0.0 0.0 4/19/2024 15:00 4/20/2024 00:00 9.00 MIRU, MOVE RGRP P Change out annlar due to leaking top seals 0.0 0.0 4/20/2024 00:00 4/20/2024 05:00 5.00 MIRU, MOVE RGRP T Complete annular change outr due to leaking top seals 0.0 0.0 4/20/2024 05:00 4/20/2024 08:00 3.00 MIRU, MOVE OTHR P Hang tree and adapters in cellar prep for backing over well 0.0 0.0 4/20/2024 08:00 4/20/2024 10:00 2.00 MIRU, MOVE RURD P Spot rig over 2A-25 0.0 0.0 4/20/2024 10:00 4/20/2024 12:00 2.00 MIRU, MOVE RURD P Safe out rig // Perform rig up checklists // Complete pre-accept checklist // Spot cuttings tanks 0.0 0.0 4/20/2024 12:00 4/20/2024 14:00 2.00 MIRU, WELCTL RURD P Take on Seawater Rig Accepted @ 12:00 // Rig up Circulating hoses to tree for circ out 0.0 0.0 4/20/2024 14:00 4/20/2024 17:00 3.00 MIRU, WELCTL WAIT T Wait on truck of seawater truck shortage 0.0 0.0 4/20/2024 17:00 4/20/2024 19:00 2.00 MIRU, WELCTL PRTS P Pad operator open SSV // Line up take returns to open top tank 0.0 0.0 4/20/2024 19:00 4/20/2024 23:00 4.00 MIRU, WELCTL DISP P Pump 40 BBl deep clean pill. Stop after all lines flooded to tanks. Isolate tree. PT manifold, choke, tank lines, tank manifild to 2000 PSI. Good. Line back up. Resume displacement to 8.6PPG seawater. Over displace to 800 BBls. Returns milky and gassy. Shut down @ 23:00 0.0 0.0 4/20/2024 23:00 4/21/2024 00:00 1.00 MIRU, WELCTL OWFF P Observe well for flow - 30 minute flow check. At ~20 minutes strt getting fluid from IA. IA sputtering then spitting. Not going into no flow 0.0 0.0 4/21/2024 00:00 4/21/2024 03:30 3.50 MIRU, WELCTL WAIT P More fluid coming, Continue bleeding IA. Tubing dead. Prepare to pump BU. IA never went to no flow. 0.0 0.0 4/21/2024 03:30 4/21/2024 05:15 1.75 MIRU, WELCTL CIRC P 8.6PPG seawater here 580 BBls. Kill tanks vaced out. PJSM to circulate. Kill rate up to 5 BPM @ 998 PSI SPP 0.0 0.0 4/21/2024 05:15 4/21/2024 06:45 1.50 MIRU, WELCTL OWFF P Pumped 373 BBls bottoms up +, Returns clean @ 8.5+. Observe well for flow Well flowing out of IA tubing dead 0.0 0.0 4/21/2024 06:45 4/21/2024 08:45 2.00 MIRU, WELCTL CIRC P Circulate IA volume down IA taking returns up tubing 0.0 0.0 4/21/2024 08:45 4/21/2024 10:00 1.25 MIRU, WELCTL RURD P Rig down circulating equipment // Blow down lines 0.0 0.0 4/21/2024 10:00 4/21/2024 11:00 1.00 MIRU, WHDBOP MPSP P Set BPV // Test from below 1000 psi 10 min good test // 0.0 0.0 4/21/2024 11:00 4/21/2024 13:30 2.50 MIRU, WHDBOP NUND P Nipple down production tree // Function LDS // Bleed voids // Inspect hanger threads look good 0.0 0.0 4/21/2024 13:30 4/21/2024 18:00 4.50 MIRU, WHDBOP NUND P Install DSA, nipple up BOPs 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 4/28/2024 Page 2/5 2A-25 Report Printed: 5/21/2024 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) 4/21/2024 18:00 4/21/2024 20:30 2.50 MIRU, WHDBOP NUND P Nipple up stack, Trip tank hose, Actuator hoses. Install pull lines and center stack 0.0 0.0 4/21/2024 20:30 4/21/2024 22:30 2.00 MIRU, WHDBOP RURD P R/U test equipment. Flood lines purge air 0.0 0.0 4/21/2024 22:30 4/21/2024 23:00 0.50 MIRU, WHDBOP BOPE P Perform Shell test 250 low, 2500 High 0.0 0.0 4/21/2024 23:00 4/22/2024 00:00 1.00 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/2500 PSI for 5 Min each, Tested annular, UVBR's w/ 3 1/2" & 7" test joints. Test blinds rams. Test LPR (Fixed 7" Rams) and Annular w/ 7" test jt 250/3000 5min each 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=1650 PSI, 200 PSI attained =22 sec, full recovery attained =114 sec. UVBR's= 3 sec, LPR’s= 3 sec. Annular= 14 sec. Simulated blinds= 3 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average =2150 PSI. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Sulley Sullivan 0.0 0.0 4/22/2024 00:00 4/22/2024 08:30 8.50 MIRU, WHDBOP BOPE P Initial BOPE test continued, Tested BOPE at 250/2500 PSI for 5 Min each, Tested annular, UVBR's w/ 3 1/2" & 7" test joints. Test blinds rams. Choke valves #1 to #13, upper and lower top drive well control valves. Test 3 1/2" IF FOSV and IBOP. Test 3 ½” 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=1650 PSI, 200 PSI attained =22 sec, full recovery attained =114 sec. UVBR's= 3 sec, LPR’s= 3 sec. Annular= 14 sec. Simulated blinds= 3 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average =2150 PSI. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Sulley Sullivan 0.0 0.0 4/22/2024 08:30 4/23/2024 00:00 15.50 MIRU, WHDBOP RGRP T Annular fail test on 3.5" test jt // Trouble shoot still not working // Open annular change element 0.0 0.0 4/23/2024 00:00 4/23/2024 02:00 2.00 MIRU, WHDBOP BOPE T Continue annular element replacement 0.0 0.0 4/23/2024 02:00 4/23/2024 03:00 1.00 MIRU, WHDBOP BOPE T Perform BOP annular test with 7" test joint 0.0 0.0 4/23/2024 03:00 4/23/2024 03:30 0.50 MIRU, WHDBOP BOPE T Swap out 7" test joint for 3 1/2" test joint 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 4/28/2024 Page 3/5 2A-25 Report Printed: 5/21/2024 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) 4/23/2024 03:30 4/23/2024 06:00 2.50 MIRU, WHDBOP BOPE T Continue annular specific BOP test with 3 1/2" test joint. Good test. P/U 3 1/2" test joint.Having issues with 3 1/2" test. Work annular hydraulics at Koomey. Get passing test 0.0 0.0 4/23/2024 06:00 4/23/2024 07:00 1.00 COMPZN, RPCOMP MPSP P Pull blanking plug. Drain BOPE stack. Pull BPV. 0.0 0.0 4/23/2024 07:00 4/23/2024 08:30 1.50 COMPZN, RPCOMP PULL P Make up landing joint, Set down 15K. Back out lock down screws. Pull hanger to rig floor, PUW=145K. 135K dragging. Clean hanger to floor 13,810.0 13,780.0 4/23/2024 08:30 4/23/2024 10:00 1.50 COMPZN, RPCOMP CIRC P Circulate S X S, 10 BPM @ 1380 PSI, Returns getting dirty. Kick overboard ~ 300 BBls to get cleaned up. Reduce rate to 6 BPM going to tanks. 680 PSI 13,780.0 13,780.0 4/23/2024 10:00 4/23/2024 11:00 1.00 COMPZN, RPCOMP OWFF P Shut down pump, Monitor well. Well static, PJSM for laying down completion 13,780.0 13,780.0 4/23/2024 11:00 4/23/2024 11:30 0.50 COMPZN, RPCOMP PULD P Lay down landing joint and hanger 13,780.0 13,780.0 4/23/2024 11:30 4/23/2024 12:00 0.50 COMPZN, RPCOMP SVRG P Service tongs, Adjust service loop. Tie up hoses to reduce snagging 13,780.0 13,780.0 4/23/2024 12:00 4/24/2024 00:00 12.00 COMPZN, RPCOMP PULL P Pull 3 1/2 completion F/ 13780' T/ 5339', PUW=135K. Heavy corrosion and holes starting on joint #190 OOH. ~6000' T/ ~7300'. 13,780.0 5,339.0 4/24/2024 00:00 4/24/2024 06:00 6.00 COMPZN, RPCOMP PULL P Cont L/D completion F/ 5339' T/ surface. 16.10' cut joint. Cut in good condition. Clear and clear rig floor. 5,339.0 0.0 4/24/2024 06:00 4/24/2024 08:00 2.00 COMPZN, RPCOMP RURD P Load 3 Jts drill pipe, 6.125" string mill, and RBP in shed. Change out elevators to drill pipe. 0.0 0.0 4/24/2024 08:00 4/24/2024 09:00 1.00 COMPZN, RPCOMP BHAH P PJSM, M/U BHA #1 6 1/8" string reamer and bull nose. Trip in hole clean to 95', Trip out 0.0 0.0 4/24/2024 09:00 4/24/2024 10:30 1.50 COMPZN, RPCOMP MPSP P PJSM, M/U BHA #2 RBP. RIH to 85' COE. Set RBP. POOH, PUW=38K 0.0 0.0 4/24/2024 10:30 4/24/2024 11:30 1.00 COMPZN, RPCOMP MPSP P Pressure test RBP 1000PSI / 10 minutes 0.0 0.0 4/24/2024 11:30 4/24/2024 15:30 4.00 COMPZN, CSGRCY NUND P PJSM, Drain stack. Remove fill up line. Nipple down BOPE. Remove casing valves from tubing head 0.0 0.0 4/24/2024 15:30 4/24/2024 16:00 0.50 COMPZN, CSGRCY SFTY P PJSM with HJydratite rep to grow 7" casing. 0.0 0.0 4/24/2024 16:00 4/24/2024 19:30 3.50 COMPZN, CSGRCY NUND P Grow 7" CSG w/ Hydratight. 19.5" of growth. Remove pack off and emergency slips. 0.0 0.0 4/24/2024 19:30 4/24/2024 20:00 0.50 COMPZN, CSGRCY BHAH P M/U BHA #3 7" spear & engage 7" stump. Pull 165K tensions at surface. 46" of growth. OAG = 65.5". 0.0 0.0 4/24/2024 20:00 4/24/2024 20:15 0.25 COMPZN, CSGRCY HOSO P Install new 7" x 11" emergency slips. 0.0 0.0 4/24/2024 20:15 4/24/2024 20:30 0.25 COMPZN, CSGRCY BHAH P L/D BHA #3. 0.0 0.0 4/24/2024 20:30 4/24/2024 23:00 2.50 COMPZN, CSGRCY NUND P Cut excess of w/ Whacks saw. Install pack off. Install new 7 1/16" 5K X 11" 3K tubing head. Install secondary IA valve. 0.0 0.0 4/24/2024 23:00 4/24/2024 23:30 0.50 COMPZN, CSGRCY PRTS P PT pack off T/ 3000 PSI for 15 Min. 0.0 0.0 4/24/2024 23:30 4/25/2024 00:00 0.50 COMPZN, CSGRCY NUND P Install test plug. N/U BOP. Install riser. 0.0 0.0 4/25/2024 00:00 4/25/2024 02:15 2.25 COMPZN, CSGRCY NUND P N/U BOP. Install riser. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 4/28/2024 Page 4/5 2A-25 Report Printed: 5/21/2024 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) 4/25/2024 02:15 4/25/2024 02:45 0.50 COMPZN, CSGRCY RURD P R/U testing equipment. Fill stack w/ fresh water. 0.0 0.0 4/25/2024 02:45 4/25/2024 03:15 0.50 COMPZN, CSGRCY PRTS P PT stack breaks T/ 250/2500 PSI for 5 Min each. 0.0 0.0 4/25/2024 03:15 4/25/2024 04:00 0.75 COMPZN, CSGRCY MPSP P Pull test plug. R/D testing equipment. 0.0 0.0 4/25/2024 04:00 4/25/2024 04:15 0.25 COMPZN, CSGRCY BHAH P M/U BHA #4, RBP retrieval tool T/ 13' 0.0 13.0 4/25/2024 04:15 4/25/2024 04:30 0.25 COMPZN, CSGRCY PACK P RIH engage RBP @ 85'. Equalize & release RBP. 13.0 85.0 4/25/2024 04:30 4/25/2024 05:00 0.50 COMPZN, CSGRCY BHAH P LDDP & BHA #4 & RBP. 85.0 0.0 4/25/2024 05:00 4/25/2024 05:30 0.50 COMPZN, RPCOMP CLEN P Clean & clear RF 0.0 0.0 4/25/2024 05:30 4/25/2024 08:30 3.00 COMPZN, RPCOMP OTHR P Process 3 1/2" EUE-M tubing in pipe shed. 0.0 0.0 4/25/2024 08:30 4/25/2024 18:00 9.50 COMPZN, RPCOMP OTHR P Continue to load completion, Test new tank level monitoring system. Pump a total of 75 BBls to open top. BBls pumped to displayed value at 1 for 1. Fill rate showing 2.5 to 4 BPM while pumping 3 BPM. Increased sampleing rate from 8 seconds to 4 seconds. Will monitor in future. good test. Continue loading completion. 0.0 0.0 4/25/2024 18:00 4/25/2024 19:00 1.00 COMPZN, RPCOMP RURD P R/U tubing handling equipment. Verify joint count & jewelry running order. 0.0 0.0 4/25/2024 19:00 4/25/2024 19:30 0.50 COMPZN, RPCOMP SFTY P PJSM w/ SLB & rig crew on running 3 1/2" completion. 0.0 0.0 4/25/2024 19:30 4/26/2024 00:00 4.50 COMPZN, RPCOMP PUTB P RIH w/ 3 1/2", 9.3#, L-80, EUE-M tubing T/ 2374', PUW=50K, SOW=50K. EUE-M torqued T/ 2350 Ft/lbs. Jet lube Run-n-Seal dope used. 0.0 2,374.0 4/26/2024 00:00 4/26/2024 18:45 18.75 COMPZN, RPCOMP RCST P RIH w/ 3 1/2", 9.3#, L-80, EUE-M tubing F/ 2374 T/ 13791', PUW=105K, SOW=70K. EUE-M torque T/ 2350 Ft/lbs. Jet lube Run-n-Seal dope used. 2,374.0 13,791.0 4/26/2024 18:45 4/26/2024 19:15 0.50 COMPZN, RPCOMP RCST P K/U on joint # 449. Circ @ 2 BPM, 175 PSI. Wash down over stub, PSI increase to 360 PSI @ 13801'. Shear pins popped @ 13803'. Fully locate @ 13806'. 5,293.0 13,806.0 4/26/2024 19:15 4/26/2024 19:45 0.50 COMPZN, RPCOMP HOSO P L/D joint #449, 448 & 447 T/ 13729. M/U 10.25' space out pup. M/U joint #447 T/ 13770'. 13,806.0 13,770.0 4/26/2024 19:45 4/26/2024 20:15 0.50 COMPZN, RPCOMP PULD P M/U hanger T/ landing joint. M/U T/ string. K/U. 13,770.0 13,770.0 4/26/2024 20:15 4/26/2024 23:15 3.00 COMPZN, RPCOMP CRIH P Close UPR. Reverse circ 290 Bbls CI seawater @ 2 BPM, 200 PSI. Chased w/ 85 Bbls neat seawater. Open LPR. 13,770.0 13,770.0 4/26/2024 23:15 4/27/2024 00:00 0.75 COMPZN, RPCOMP RURD P B/D, R/D circ equipment. B/D surface lines. Suck out stack. 13,770.0 13,770.0 4/27/2024 00:00 4/27/2024 00:30 0.50 COMPZN, RPCOMP RCST P RIH & land hanger w/ bottom of overshot @ 13814.38'' ORKB. RILDS. Drop ball & rod. 13,770.0 13,814.0 4/27/2024 00:30 4/27/2024 01:30 1.00 COMPZN, RPCOMP RURD P R/U testing equipment. 13,814.0 13,814.0 4/27/2024 01:30 4/27/2024 02:30 1.00 COMPZN, RPCOMP PACK P Pressure up set packer in 500 PSI increments T/ 2000 PSI, continue pressure up to set T/ 3800 PSI, Hold for 30 Min passing tubing test 13,814.0 13,814.0 Rig: NORDIC 3 RIG RELEASE DATE 4/28/2024 Page 5/5 2A-25 Report Printed: 5/21/2024 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) 4/27/2024 02:30 4/27/2024 03:15 0.75 COMPZN, RPCOMP PRTS P Bleed TBG T/ 1500 PSI. PT IA T/ 2500 PSI for 30 Min. Dump TBG PSI, shear out SOV. Pump down IA @ 2 BPM, 200 PSI. 13,814.0 13,814.0 4/27/2024 03:15 4/27/2024 03:45 0.50 COMPZN, RPCOMP RURD P B/D, R/D TBG testing equipment. Pull landing joint. 13,814.0 13,814.0 4/27/2024 03:45 4/27/2024 04:00 0.25 COMPZN, RPCOMP MPSP P Set HP BPV. 13,814.0 0.0 4/27/2024 04:00 4/27/2024 04:15 0.25 COMPZN, RPCOMP PRTS P PT BPV from below T/ 1000 PSI for 10 Min. 0.0 0.0 4/27/2024 04:15 4/27/2024 05:00 0.75 COMPZN, WHDBOP RURD P B/D, R/D IA testing equipment. 0.0 0.0 4/27/2024 05:00 4/27/2024 06:30 1.50 COMPZN, WHDBOP NUND P N/D BOP. 0.0 0.0 4/27/2024 06:30 4/27/2024 11:30 5.00 COMPZN, WHDBOP NUND P PJSM, Nipple up adapter and tree. 0.0 0.0 4/27/2024 11:30 4/27/2024 12:00 0.50 COMPZN, WHDBOP PRTS P PT hanger void T/ 5000 PSI for 15 Min. 0.0 0.0 4/27/2024 12:00 4/27/2024 12:00 COMPZN, WHDBOP OTHR P PJSM, Pull TWC from tree 0.0 0.0 4/27/2024 12:00 4/27/2024 14:00 2.00 COMPZN, WHDBOP RURD P R/U to PT tree and pump freeze protect. Rig up U-tube. R/U LRS. 0.0 0.0 4/27/2024 14:00 4/27/2024 14:30 0.50 COMPZN, WHDBOP PRTS P PT tree to 5K 0.0 0.0 4/27/2024 14:30 4/27/2024 17:30 3.00 DEMOB, MOVE FRZP P LRS pump 88 Bbls diesel freeze protect down IA @ 2 BPM, 700 PSI. U-tube well for 1 HR. 0.0 0.0 4/27/2024 17:30 4/27/2024 18:30 1.00 DEMOB, MOVE RURD P B/D, R/D circ equipment secure tree & cellar. Take final pressures T/IA/OA = 160/150/0. 0.0 0.0 4/27/2024 18:30 4/28/2024 00:00 5.50 DEMOB, MOVE DMOB P Strip auxiliary equipment away from rig. Pull off well and stage on pad. Clean up around cellar. 0.0 0.0 4/28/2024 00:00 4/28/2024 01:00 1.00 DEMOB, WHDBOP DMOB P Pull sub off of 2A-25 and stage on pad. 0.0 0.0 4/28/2024 01:00 4/28/2024 02:30 1.50 DEMOB, WHDBOP DMOB P Clean up around well. 0.0 0.0 4/28/2024 00:00 4/28/2024 10:30 10.50 DEMOB, WHDBOP NUND P Perform BWM. C/O top seals on UVBR's/ C/O blind blocks w/ new packers. Changed LPR T/ 2 7/8" x 5 1/5" VBR's. BWM completed at 10:30. Roads and pads have removed enough snow to move off pad 0.0 0.0 4/28/2024 10:30 4/28/2024 12:00 1.50 DEMOB, WHDBOP DMOB P Roads and pads have removed enough snow to move off pad. Call for truck to move office Rig released @ 12:00 Hrs, Stand by at 2B pad for CPF change out. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 4/28/2024 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 14,014.0 2A-25 5/16/2024 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Post rig GLD install. Pull plugs, Tag 2A-25 5/16/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: Heavy wt swings w/DMY patch drift starting @ 2060' SLM. Unable to get down with full length 6/29/2023 rogerba Note: Slickline located leak in Tbg between 6046'-6076' RKB 4/27/2022 zembaej NOTE: Heavy Weight Swings w/ Dmy Plug Drift on bottom 1600 lbs 6/7/2019 zembaej NOTE: View Schematic w/ Alaska Schematic9.0 9/15/2010 ninam NOTE: OA FAILED MIT 7/19/2009 lmosbor 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 41.0 121.0 121.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 40.1 5,485.2 2,977.7 40.00 L-80 BTC-M PRODUCTION 7 6.28 38.4 14,385.2 6,152.1 26.00 L-80 BTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 36.9 Set Depth … 13,814.4 String Max No… 3 1/2 Set Depth … 5,776.7 Tubing Description Tubing – Completion Upper Wt (lb/ft) 9.30 Grade L80 Top Connection EUE-M ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 36.9 36.9 0.04 Hanger 6.982 7 1/16" FMC Gen IV tubing hanger, H-BPV, 3 1/2" EUE Lift threads FMC Gen IV 2.952 3,850.3 2,481.3 72.89 Mandrel – GAS LIFT 5.893 3.5" x 1.5" SLB MMG, GLM SLB MMG 2.920 8,592.8 3,944.1 72.08 Mandrel – GAS LIFT 6.001 3.5" x 1.5" SLB MMG, GLM SLB MMG 2.920 13,704.3 5,710.6 54.75 Mandrel – GAS LIFT 5.873 3.5" x 1.5" SLB MMG, GLM SLB MMG 2.920 13,764.1 5,745.9 52.96 Packer 6.280 3-1/2" x 7" BluePack RH Max VAM TOP B/P SLB BluePac k 2.890 13,790.3 5,761.8 52.15 Nipple - X 4.506 3.5" HES 2.813" X-Nipple HES X-Nipple 2.813 13,807.6 5,772.5 51.82 Overshot 5.990 3.5" Baker Poor Boy Overshot ( 6.38' Swallow ) 4ea sheare pins 3' up Baker Poorboy 3.640 Top (ftKB) 13,810.0 Set Depth … 13,860.5 String Max No… 3 1/2 Set Depth … 5,805.5 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 13,825.6 5,783.6 51.58 NIPPLE 4.540 CAMCO W NIPPLE CAMCO W 2.812 13,833.6 5,788.6 51.48 SEAL 4.000 BAKER KBH 22 ANCHOR SEAL ASSEMBLY BAKER MODEL KBH-22 2.992 13,834.5 5,789.2 51.47 PACKER 6.156 BAKER 84 SAB HYD SET PACKER BAKER 84 SAB 3.000 13,850.4 5,799.1 51.26 NIPPLE 4.500 CAMCO D NIPPLE CAMCO D 2.740 13,859.6 5,804.9 51.14 SOS 4.500 BAKER BULL NOSE SHEAR OUT SUB, ELMD @ 13862' ON SWS PERF 9/10/2002 BAKER 3.000 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) 14,205.0 6,030.1 47.93 FISH Junk/Obstruction Push Down & Out TT; See WSR 4/17/96 4/21/1996 14,207.0 6,031.4 47.92 FISH DMY 1" GLV in rathole - 10/20/2002 4/21/1996 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,850.3 2,481.3 72.89 1 GAS LIFT GLV RK 1 1/2 1,265.0 5/14/2024 SLB MMG 0.313 8,592.8 3,944.1 72.08 2 GAS LIFT OV RK 1 1/2 5/15/2024 SLB MMG 0.250 13,704.3 5,710.6 54.75 3 GAS LIFT DMY RK 1 1/2 4/27/2024 SLB MMG Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 13,972.0 13,992.0 5,876.5 5,889.5 C-4, 2A-25 9/10/2002 6.0 APERF 120 Deg Phasing, Powerjet 14,001.0 14,009.0 5,895.4 5,900.6 A-3, 2A-25 9/10/2002 6.0 APERF 120 Deg Phasing, Powerjet 14,010.0 14,030.0 5,901.2 5,914.3 A-3, 2A-25 4/26/1996 4.0 IPERF 2 1/8" Strip Gun; 180 deg. phasing; Oriented (+/-) 90 deg. f/ Low Side of Hole 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) 14,010.0 14,353.0 1 Scale Inhibitor 3/16/1997 0.0 0.00 0.00 2A-25, 5/21/2024 10:40:19 AM Vertical schematic (actual) PRODUCTION; 38.4-14,385.2 FISH; 14,207.0 FISH; 14,205.0 IPERF; 14,010.0-14,030.0 APERF; 14,001.0-14,009.0 APERF; 13,972.0-13,992.0 PACKER; 13,834.5 Nipple - X; 13,790.3 Packer; 13,764.1 Mandrel – GAS LIFT; 13,704.3 Mandrel – GAS LIFT; 8,592.8 SURFACE; 40.1-5,485.2 Mandrel – GAS LIFT; 3,850.3 CONDUCTOR; 41.0-121.0 Hanger; 36.9 KUP PROD KB-Grd (ft) 46.00 RR Date 4/15/1996 Other Elev… 2A-25 ... TD Act Btm (ftKB) 14,391.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032023900 Wellbore Status PROD Max Angle & MD Incl (°) 73.78 MD (ftKB) 9,267.42 WELLNAME WELLBORE2A-25 Annotation Last WO: End Date 4/28/2024 H2S (ppm) 50 Date 12/16/2012 Comment SSSV: NIPPLE CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Jake Henry To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Cc:Company Man, Nordic 3 Subject:Nordic rig 3 BOP test 4-21-24 Date:Thursday, April 25, 2024 1:40:58 PM Attachments:KUP 2A-25 AOGCC 4-21-24.xlsx Some people who received this message don't often get email from jake.henry@nordic-calista.com. Learn why this is important Jake Henry Nordic Calista Dog House 670-6144 907-414-0962 Cell This information is intended only for the use of the individual (s) or entity (ies) named above and may contain confidential or privileged information. Any unauthorized disclosure, copying, distribution or the taking of any action in reliance on the contents of this transmitted information is strictly prohibited. If you are not the intended recipient or have received this transmission in error, please immediately delete it and any attachments from your system and send me an email confirming that you have not disclosed, copied, or distributed this message and that you have deleted this message and any attachments from your system. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Su bm it to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:3 DATE: 4/23/24 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name: PTD #1960620 Sundry #324-195 Operation: Drilling: Workover: xxx Explor.: Test: Initial: xxx Weekly: Bi-Weekly: Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:2261 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 1 P Test Fluid Water Inside BOP 1 P FSV Misc 1 P BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13 5/8"FP Pit Level Indicators P P #1 Rams 1 2 7/8" X 5 1/2"P Flow Indicator P P #2 Rams 1 CSO Rams P Meth Gas Detector P P #3 Rams 1 7" Fixed P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8"P Time/Pressure Test Result HCR Valves 2 3 1/8"P System Pressure (psi)3050 P Kill Line Valves 1 3 1/8"P Pressure After Closure (psi)1550 P Check Valve 0 NA 200 psi Attained (sec)19 P BOP Misc 2 2 1/16" 5000 P Full Pressure Attained (sec)124 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 4@ 2000 P No. Valves 12 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec) Test Result CH Misc 1 P Annular Preventer 24 P #1 Rams 5 P Coiled Tubing Only:#2 Rams 4 P Inside Reel valves 0 NA #3 Rams 4 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:1 Test Time:31.5 HCR Choke 1 P Repair or replacement of equipment will be made within 3 days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 4-19-24/10:45 Waived By Test Start Date/Time:4/21/2024 22:30 (date) (time)Witness Test Finish Date/Time:4/23/2024 6:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Sully Sullivan Nordic Test with 3 1/2" & 7" Test Joints, Annular failed on 3 1/2" test joint, Change out Annular Element Retest Pass Henry/Twedt CPAI Newell/Erdman KRU 2A-25 Test Pressure (psi): gmanager.rig3@nordic-calista.com ic3.Companyman@conocophillips Form 10-424 (Revised 08/2022) 2024-0423_BOP_Nordic3_KRU_2A-25 TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 2AͲ25 50Ͳ103Ͳ20239Ͳ00 196062_2AͲ25_LDL_15Jul2022 196062_2AͲ25_Patch_12Jun2022 2BͲ01 50Ͳ029Ͳ21147Ͳ00 184115_2BͲ01_PPROF_18Feb2023 2BͲ02A 50Ͳ029Ͳ21154Ͳ00 184122_2BͲ02A_LDL_26Jul2023 2BͲ13 50Ͳ029Ͳ21138Ͳ00 184104_2BͲ13_PPROF_02Jun2023 2DͲ07 50Ͳ029Ͳ21169Ͳ00 184143_2DͲ07_IPROF_10Jun2023 2DͲ08 50Ͳ029Ͳ21158Ͳ00 184127_2DͲ08_PPROF_28May2023 2DͲ13 50Ͳ029Ͳ21070Ͳ00 184012_2DͲ13_PPROF_03Jun2023 2DͲ15 50Ͳ029Ͳ21184Ͳ00 184160_2DͲ15_PPROF_04Jun2023 _2EͲ10 50Ͳ029Ͳ21246Ͳ00 184230_2EͲ10_CBL PostͲBiSN_21Aug2023 184230_2EͲ10_CBL PreͲBiSN_28Jul2023 2FͲ13 50Ͳ029Ͳ21032Ͳ00 183156_2FͲ13_WFL_29Jun2023 2HͲ02 50Ͳ103Ͳ20032Ͳ00 184073_2HͲ02_IPROFͲWFL_13Jun2023 6 of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38362 T38363 T38364 T38365 T38366 T38367 T38368 T38369 T38370 T38371 T38733 216-087 2AͲ25 50Ͳ103Ͳ20239Ͳ00 196062_2AͲ25_LDL_15Jul2022 196062_2AͲ25_Patch_12Jun2022 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.23 11:48:05 -08'00' 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? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 14391'14205'MD 14207'MD 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: 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: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 13972-13992' 14001-14009' 14010-14030' 5877-5890' 5895-5901' 5901-5914' 3-1/2" 16" 9-5/8" 80' 5445' Perforation Depth MD (ft): 7"14347' MD 121' 2978' 6152' 121' 5485' 14385' Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 6156' 14009' 5901' 2261 None STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025571 196-062 P.O. Box 100360, Anchorage, AK 99510 50-103-20239-00-00 ConocoPhillips Alaska, Inc. KRU 2A-25 Kuparuk Oil Pool Kuparuk Oil PoolKuparuk River Field N/A Tubing Grade: Tubing MD (ft): Packer: 6044'MD/3146'TVD Packer: 6062'MD/3151'TVD Packer: 6185'MD/3187'TVD Packer: 6218'MD/3196'TVD Packer: 13835'MD/5789'TVD Perforation Depth TVD (ft): Tubing Size: L-80 13861' 4/20/2024 Packer: Patch PIIP Upper pkr Packer: Patch PIIP Lower pkr Packer: Patch PIIP Upper pkr Packer: Patch PIIP Lower pkr Packer: Baker 84 SAB HYD 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: AOGCC USE ONLY Elliott Tuttle elliott.tuttle@conocophillips.com (907) 263-4742 CTD/RWO Engineer Perforate Repair Wepair Well BOP SketchExploratory Stratigraphic Development Service BOP TestMechanical Integrity Test Location Clearance No No Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:12 pm, Apr 02, 2024 Digitally signed by Elliott Tuttle DN: OU=CTD/ RWO Senior Engineer, O=Conoco Phillips, CN=Elliott Tuttle, E=elliott.tuttle@ conocophillips.com Reason: I am approving this document Location: Date: 2024.04.02 14:45:00-08'00' Foxit PDF Editor Version: 13.0.0 Elliott Tuttle 324-195 BOP test to 2500 psig Annular preventer test to 2500 psig SFD 4/4/2024VTL 4/11/2024 Obsolete form. SFD ADL0025570, X SFD X 10-404 DSR-4/12/24JLC 4/12/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.04.12 14:28:53 -08'00'04/12/24 RBDMS JSB 041624 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 2, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Elliott Tuttle Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Producer 2A-25 (PTD# 196-062). Well 2A-25 was drilled and completed in April of 1996 by Parker as a A Sand Producer. 2 Fracs have been pumped into the well first shortly after it was drilled and completed and again in 1997.The C-Sand was perforated in 2002 along with perforating the A3 sands. Tubing leaks were found in 2022 and was repaired with patches. The patches failed to pressure test in 2023 and when we began to retrieve them, subsidence drift concerns were raised. New patches were installed but the well moved to RWO. If you have any questions or require any further information, please contact me at +1-907-252-3347. The tubing will be removed from cut and the production casing will be grown and stretched. The tubing will be replaced with a stack packer above the current production packer. Digitally signed by Elliott Tuttle DN: OU=CTD/ RWO Senior Engineer, O=Conoco Phillips, CN=Elliott Tuttle, E=elliott.tuttle @conocophillips.com Reason: I am the author of this document Location: Date: 2024.04.02 14:45:29-08'00' Foxit PDF Editor Version: 13.0.0 Elliott Tuttle 2A-25 RWO Procedure Kuparuk Producer Pull and Replace Tubing, Grow and Stretch PTD #196-062 Page 1 of 2 Remaining Pre-Rig Work 1. T-PPPOT and T-POT tests. 2. Fish Patches from well, 2 each (6044’-6061’ and 6205’-6217’) 3. Install DV’s in upper most GLMs, open lowest GLM in upper completion. 4. Obtain SBHP. 5. Secure well with plug in D Nipple @ 13850’ RKB and CMIT-IA to 2500 psig. 6. Mechanical cut the tubing nominally at ~13810’ RKB, middle of the first full jnt above nipple @ 13825’ RKB 7. DDT on OA 8. Prepare well within 48 hrs of rig arrival. Rig Work MIRU 1. MIRU Nordic 3 on 2A-25. (No BPV will be set due to risk assessment done on Nordic 3.) 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 250/2,500 psi. Test annular 250/2,500 psi. Retrieve Tubing Section 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to pre rig cut @ ~13810’ RKB 6. Stop and make drift run of WH to confirm GLMs will drift, if it fails to drift: a. hang tubing on storm packer (obtain needed barriers) and move to “Grow and Stretch” b. fish storm packer and lay down rest of completion. Grow and Stretch 7. Obtain needed Barriers, set IBP/ RBP near surface, test from above to confirm 8. ND BOPE. ND old tubing spool. a. Grow/stretch and Cut 7” casing at surface as necessary to deal with subsidence in this step. b. Install Casing slips and Casing PO’s. c. NU tubing spool and test PO to 3Kpsi, NU BOPE, shell test to 2500psi to confirm flange breaks Cleanout Run 9. Perform a Cleanout run if necessary based on tubing condition and dress off 3.5” tubing stub if necessary. Install 3-½” Tubing with Stacked Packer 10. MU 3 ½” completion with overshot, nipple, packer, Sliding sleeve and GLM’s. RIH with completion 11. Once on depth, overshot and space out as needed. Land Hanger and test packoffs. 12. Circulate in CI fluid at opportune time as needed, after CI is in place, set packer. 13. Pressure test tubing to 3000 psi for 5 minutes. 14. Pressure test inner annulus to 2500 psi for 30 minutes on chart. ND BOP, NU Tree 15. Confirm pressure tests, then shear out SOV with pressure differential. 16. Install BPV. test 17. ND BOPE. NU tree, PT tree. 18. Pull BPV, freeze protect well, and set BPV if necessary. 19. RDMO. 2A-25 RWO Procedure Kuparuk Producer Pull and Replace Tubing, Grow and Stretch PTD #196-062 Page 2 of 2 Post-Rig Work 20. Pull BPV 21. Pull any remaining plugs, install GLD. Turn over to operations General Well info: Wellhead type/pressure rating: FMC Gen 4, 3K psi upper casing flange, 5K psi top flange Production Engineer: Kevin Wiggs Reservoir Development Engineer: Adam Becia Estimated Start Date: 4/20/24 Workover Engineer: Elliott Tuttle (907-252-3347/ Elliott.tuttle@conocophillips.com) Current Operations: This well is currently shut in. Well Type: Producer Scope of Work: Pull the existing 3-1/2” completion down to the pre rig cut. Grow and stretch the 7” Production casing then install a new 3-1/2” completion with a stacked packer. BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: MIT-T N/A, will fail once tubing patches are removed CMIT-TxIA Passed 8/21/2023 MIT-OA failed, regular SCLD are performed to 1400psi, passing IC POT &PPPOT PASSED – 3/31/24 TBG POT &PPPOT PASSED – 3/31/24 MPSP: 2261 psi using 0.1 psi/ft gradient Static BHP: 2851 psi / 5900’ TVD measured on 04/10/2017 – plan to obtain more recent pressure prior to rig arrival Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 14,009.0 2A-25 4/9/2017 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Upper Patch 2A-25 8/21/2023 scolem Notes: General & Safety Annotation End Date Last Mod By NOTE: Heavy wt swings w/DMY patch drift starting @ 2060' SLM. Unable to get down with full length 6/29/2023 rogerba Note: Slickline located leak in Tbg between 6046'-6076' RKB 4/27/2022 zembaej NOTE: Heavy Weight Swings w/ Dmy Plug Drift on bottom 1600 lbs 6/7/2019 zembaej NOTE: View Schematic w/ Alaska Schematic9.0 9/15/2010 ninam NOTE: OA FAILED MIT 7/19/2009 lmosbor 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 41.0 121.0 121.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 40.1 5,485.2 2,977.7 40.00 L-80 BTC-M PRODUCTION 7 6.28 38.4 14,385.2 6,152.1 26.00 L-80 BTC-MOD Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 36.7 Set Depth … 13,860.5 Set Depth … 5,805.5 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 36.7 36.7 0.04 HANGER 8.000 TUBING HANGER 3.500 479.0 478.7 4.41 NIPPLE 4.540 CAMCO DS NIPPLE 2.812 2,672.4 2,117.3 69.82 GAS LIFT 5.390 CAMCO KBUG/1/GLV/BK/.188/1280/ Comment: STA 1 CAMCO KBUG 2.920 6,001.7 3,134.0 73.31 GAS LIFT 5.390 CAMCO KBUG/1/OV/BK/.25/1280/ Comment: STA 2 CAMCO KBUG 2.920 9,362.4 4,175.9 73.20 GAS LIFT 5.390 CAMCO KBUG/1/DMY/BK/Comment: STA 3 CAMCO KBUG 2.920 11,847.5 4,940.2 70.34 GAS LIFT 5.390 CAMCO KBUG/1/DMY/BK/Comment: STA 4 CAMCO KBUG 2.920 13,202.4 5,460.4 64.69 GAS LIFT 5.390 CAMCO KBUG/1/DMY/BK/Comment: STA 5 CAMCO KBUG 2.920 13,779.8 5,755.4 52.47 GAS LIFT 6.018 CAMCO MMM/1.5/DMY/RK/Comment: STA 6 CAMCO MMM 2.920 13,825.5 5,783.6 51.58 NIPPLE 4.540 CAMCO W NIPPLE CAMCO W 2.812 13,833.6 5,788.6 51.48 SEAL 4.000 BAKER KBH 22 ANCHOR SEAL ASSEMBLY BAKER MODEL KBH-22 2.992 13,834.5 5,789.2 51.47 PACKER 6.156 BAKER 84 SAB HYD SET PACKER BAKER 84 SAB 3.000 13,850.4 5,799.1 51.26 NIPPLE 4.500 CAMCO D NIPPLE CAMCO D 2.740 13,859.6 5,804.9 51.14 SOS 4.500 BAKER BULL NOSE SHEAR OUT SUB, ELMD @ 13862' ON SWS PERF 9/10/2002 BAKER 3.000 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) 6,044.0 3,146.2 73.30 PACKER - PATCH - UPR 2.725 PIIP UPPER PKR SPACER PIPE ANCHOR LATCH ASSY (17.59' OAL) TTS PIIP CPP3 5233/ CPP3 5189 8/21/2023 1.625 6,054.0 3,149.0 73.30 LEAK - TUBING TUBING LEAK AT 6054' TO 6056' RKB (UPDATED LEAK DEPTH FROM SLB PROCESSED LOG) 5/22/2022 2.992 6,061.6 3,151.2 73.30 PACKER - PATCH - LWR 2.725" PIIP LOWER PACKER W/ MOE @ 6064' RKB, OAL = 4.01' TTS PIIP CPP3 5189 8/20/2023 1.625 6,184.8 3,186.7 73.28 PACKER - PATCH - UPR 2.725 PIIP UPPER PKR SPACER PIPE, ANHCOR SEAL ASSY (19.39' OAL) TTS PIIP CPP3 5126/ CPAL 35199 8/18/2023 1.590 6,201.0 3,191.3 73.29 LEAK - TUBING TUBING LEAK IDENTIFIED AT 6201' TO 6205' RKB ON LDL RUN ON 7/15/22 (UPDATED LEAK DEPTH FROM SLB PROCESSED LOG) 7/15/2022 2.992 6,204.2 3,192.2 73.29 ANCHOR LATCH ON SPACER PIPE 2.70 PBR, SPACER PIPE, ANHOR LATCH ASSY (13.41' OAL 1.59 I.D) TTS PIIP CPPB R3503 6/CPA L3513 5 8/18/2023 1.590 6,217.6 3,196.1 73.30 PACKER - PATCH - LWR 2.725" PIIP LOWER PACKER W/ MOE @ 6220' RKB, OAL = 4.01' TTS PIIP CPP3 5031 8/1/2023 1.625 14,205.0 6,030.1 47.93 FISH Junk/Obstruction Push Down & Out TT; See WSR 4/17/96 4/21/1996 2A-25, 8/22/2023 4:35:33 AM Vertical schematic (actual) PRODUCTION; 38.4-14,385.2 FLOAT SHOE; 14,383.7- 14,385.2 FLOAT COLLAR; 14,296.3- 14,297.6 FISH; 14,207.0 FISH; 14,205.0 IPERF; 14,010.0-14,030.0 APERF; 14,001.0-14,009.0 APERF; 13,972.0-13,992.0 SOS; 13,859.6 NIPPLE; 13,850.4 PACKER; 13,834.5 SEAL; 13,833.6 NIPPLE; 13,825.5 GAS LIFT; 13,779.8 GAS LIFT; 13,202.4 GAS LIFT; 11,847.5 GAS LIFT; 9,362.4 PACKER - PATCH - LWR; 6,217.5 ANCHOR LATCH ON SPACER PIPE; 6,204.2 LEAK - TUBING; 6,201.0 PACKER - PATCH - UPR; 6,184.8 PACKER - PATCH - LWR; 6,061.6 LEAK - TUBING; 6,054.0 PACKER - PATCH - UPR; 6,044.0 GAS LIFT; 6,001.7 SURFACE; 40.1-5,485.2 FLOAT SHOE; 5,483.6-5,485.2 FLOAT COLLAR; 5,404.9- 5,406.2 GAS LIFT; 2,672.4 NIPPLE; 479.0 CONDUCTOR; 41.0-121.0 HANGER; 40.0-44.1 HANGER; 36.7 KUP PROD KB-Grd (ft) 46.00 RR Date 4/15/1996 Other Elev… 2A-25 ... TD Act Btm (ftKB) 14,391.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032023900 Wellbore Status PROD Max Angle & MD Incl (°) 73.78 MD (ftKB) 9,267.42 WELLNAME WELLBORE2A-25 Annotation Last WO: End DateH2S (ppm) 50 Date 12/16/2012 Comment SSSV: NIPPLE Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 14,207.0 6,031.4 47.92 FISH DMY 1" GLV in rathole - 10/20/2002 4/21/1996 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) 2,672.4 2,117.3 69.82 1 GAS LIFT GLV BK 1 1,304.0 4/21/2022 0.188 6,001.7 3,134.0 73.31 2 GAS LIFT OV BK 1 0.0 4/26/2022 0.250 9,362.4 4,175.9 73.20 3 GAS LIFT DMY BK 1 0.0 11/13/2004 0.000 11,847.5 4,940.2 70.34 4 GAS LIFT DMY BK 1 0.0 9/21/2004 0.000 13,202.4 5,460.4 64.69 5 GAS LIFT DMY BK 1 0.0 9/21/2004 0.000 13,779.8 5,755.4 52.47 6 GAS LIFT DMY RK 1 1/2 0.0 7/30/2023 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 13,972.0 13,992.0 5,876.5 5,889.5 C-4, 2A-25 9/10/2002 6.0 APERF 120 Deg Phasing, Powerjet 14,001.0 14,009.0 5,895.4 5,900.6 A-3, 2A-25 9/10/2002 6.0 APERF 120 Deg Phasing, Powerjet 14,010.0 14,030.0 5,901.2 5,914.3 A-3, 2A-25 4/26/1996 4.0 IPERF 2 1/8" Strip Gun; 180 deg. phasing; Oriented (+/-) 90 deg. f/ Low Side of Hole 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) 14,010.0 14,353.0 1 Scale Inhibitor 3/16/1997 0.0 0.00 0.00 2A-25, 8/22/2023 4:35:33 AM Vertical schematic (actual) PRODUCTION; 38.4-14,385.2 FLOAT SHOE; 14,383.7- 14,385.2 FLOAT COLLAR; 14,296.3- 14,297.6 FISH; 14,207.0 FISH; 14,205.0 IPERF; 14,010.0-14,030.0 APERF; 14,001.0-14,009.0 APERF; 13,972.0-13,992.0 SOS; 13,859.6 NIPPLE; 13,850.4 PACKER; 13,834.5 SEAL; 13,833.6 NIPPLE; 13,825.5 GAS LIFT; 13,779.8 GAS LIFT; 13,202.4 GAS LIFT; 11,847.5 GAS LIFT; 9,362.4 PACKER - PATCH - LWR; 6,217.5 ANCHOR LATCH ON SPACER PIPE; 6,204.2 LEAK - TUBING; 6,201.0 PACKER - PATCH - UPR; 6,184.8 PACKER - PATCH - LWR; 6,061.6 LEAK - TUBING; 6,054.0 PACKER - PATCH - UPR; 6,044.0 GAS LIFT; 6,001.7 SURFACE; 40.1-5,485.2 FLOAT SHOE; 5,483.6-5,485.2 FLOAT COLLAR; 5,404.9- 5,406.2 GAS LIFT; 2,672.4 NIPPLE; 479.0 CONDUCTOR; 41.0-121.0 HANGER; 40.0-44.1 HANGER; 36.7 KUP PROD 2A-25 ... WELLNAME WELLBORE2A-25 2A-25 Proposed RWO Completion - 3 1/2" GLD (ET) Modified 4/1/24 COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 121 121 16 15.06 62.5 H-40 Welded Welded Surface 5485 2997 9 5/8 8.835 40 L-80 BTC-M BTC-M Production 14385 6152 7 6.276 26 L-80 BTC-M BTC-M Tubing 13860 5805 3 1/2 2.992 9.3 L-80 EUE Mod EUE Mod Tubing 13810 5775 3 1/2 2.992 9.3 L-80 EUE Mod EUE Mod PROPOSED COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2"x 1 1/2" Camco MMG gas lift mandrels planned @ 3871' RKB, 8605' RKB 3 1/2" Baker CMU Sliding Sleeve @ XXXX' RKB (2.813" ID) - or another MMG if deemed necessary 3-1/2" x 7" packer Bluepack Max @ XXXX' RKB 3-½" X landing nipple at XXXX' RKB (2.813" min ID) 3-1/2" Non-sealing Overshot REMAINING COMPLETION LEFT IN HOLE Tubing stub @ 13810' RKB Planned Baker KBH 22 Anchor Seal Assy @ 13833' RKB Baker SAB Hyd Set Packer @ 13834' RKB Surface Casing Production/Intermediate Casing Conductor C-sand perfs 13,972' - 13,992' A-sand perfs 14,001' - 14,009' 14,010' - 14,030' 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: Tubing Patch 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 14391'feet None feet true vertical 6156'feet 14205', 14207'feet Effective Depth measured 14009'feet 6044', 6062', 6185', 6218', 13834' feet true vertical 5901'feet 3146', 3151', 3187', 3196', 5789' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 13860' MD 5805' TVD Packers and SSSV (type, measured and true vertical depth) 6044' MD 6062' MD 6185' MD 6218' MD 13834' MD N/A 3146' TVD 3151' TVD 3187' TVD 3196' TVD 5789' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River 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: 5485' 2978' Burst Collapse Production Liner 14347' Casing 6152'14385' 5445' 121'Conductor Surface Intermediate 16" 9-5/8" 80' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 196-062 50-103-20239-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0025571 Kuparuk River Field/ Kuparuk River Oil Pool KRU 2A-25 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 121' ~ ~~ Well Remains Shut-In ~~ ~ N/A 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: PIIP Patch Packer Packer: PIIP Patch Packer Packer: PIIP Patch Packer Packer: PIIP Patch Packer Packer: Baker 84 SAB HYD SET Packer SSSV: None Dusty Freeborn Senior Well Integrity Specialist 13972-13992', 14001-14009', 14010-14030' 5876-5889', 5895-5901', 5901-5914' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov dusty.freeborn@conocophillips.com (907) 265-6218 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: Eagle River, Alaska Date: 2023.08.28 11:23:57-08'00' Foxit PDF Editor Version: 12.1.2 Dusty Freeborn P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 28, 2023 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 from ConocoPhillips Alaska, Inc. for the retrievable tubing patches which were pulled and re-set across known tubing leaks in producer KRU 2A-25(PTD 196-062) to investigate suspected subsidence issues. Please contact me at 265-6218 if you have any questions. Sincerely, Dusty Freeborn Senior 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: Eagle River, Alaska Date: 2023.08.28 11:23:19-08'00' Foxit PDF Editor Version: 12.1.2 Dusty Freeborn DTTMSTART JOBTYP SUMMARYOPS 6/29/2023 ACQUIRE DATA BRUSH AND FLUSH TUBING TO 6049' RKB, ATTEMPT TO RUN 27' X 2.72" P2P PATCH DRIFT, S/D @ 2419' SLM, UNABLE TO WORK THROUGH AREA, LRS COME ONLINE PUMPING .5 BBLS/ MIN, NO CHANGE, POOH, SHORTEN PATCH DRIFT AND ATTEMPT TO RUN 21' X 2.72" PATCH DRIFT, HIT TIGHT SPOTS @ 2060' SLM & 2330' SLM, S/D @ 2426' SLM, WORK THROUGH AREA, TIGHT SPOT @ 3842' SLM, TIGHT SPOTS 4316' - 4390' SLM, S/D @ 4660' SLM, UNABLE TO MAKE THROUGH, POOH, WEIGHT SWINGS BACK TO SURFACE, SHORTEN DRIFT AND ATTEMPT TO RUN 12' X 2.72" PATCH DRIFT, WORK THROUGH MANY TIGHT SPOTS FROM 2436' SLM - 4631' SLM, UNABLE TO WORK THROUGH, LRS COME ONLINE PUMPING 2 BBLS/MIN, WORK THROUGH FROM 4631' - 4680' SLM TOOLS FALL TO 5190' SLM, WORK THROUGH TIGHT SPOTS @ 5412', 5453, 5822' SLM, S/D ON TOP OF PATCH @ 6048' RKB, POOH, SEE A 200 LBS WEIGHT GAIN FROM 4100'-2600' SLM, RUN 2.72" RBP DRIFT TO 6048' RKB. NEED PLAN FORWARD 7/15/2023 ACQUIRE DATA DRIFT TUBING WITH 2.72" X 27' DUMMY PATCH DOWN TO 6000' CTMD, PULLED UPPER PACKER/PATCH @ 6042', ALL ELEMENTS AND SEALS RECOVERED. PULL LOWER PACKER FROM UPPER PATCH. ALL ELEMENTS AND SLIPS INTACT. JOB IN PROGRESS. PULL LOWER PACKER/PATCH @ 6187', PULL LOWER PACKER @ 6217'. DID NOT SEE WT SWINGS. JOB COMPLETE. WELL READY FOR SLICKLINE. 2A-25 Tubing Patch Summary of Operations 7/16/2023 ACQUIRE DATA 7/24/2023 ACQUIRE DATA 7/24/2023 ACQUIRE DATA DISPLACED WELL W/ 120 BBLS 776 SLICK DIESEL, SET 2.75" CA-2 PLUG IN D-NIPPLE @ 13,850' RKB, PULLED 1-1/2" DMY VALVE FROM GLM @ 13,779' RKB, LEAVING OPEN POCKET. WELL READY FOR CIRC OUT, JOB IN PROGRESS. CIRC-OUT/ CMIT TXIA TO 2500 PSI PUMPED 420 BBLS 1% CRW CISW FOLLOWED BY 75 BBLS DSL DOWN TBG UP IA TO 2A-19 FL U-TUBE FOR 1 HR MADE 4 ATTEMPTS AT A CMIT-TxIA ALL 4 INCONCLUSIVE LEAKING BY WV. ( SEE LOG) CMIT TXIA PASSED TO 2500PSI JOB COMPLETE 7/25/2023 ACQUIRE DATA 7/26/2023 ACQUIRE DATA UNABLE TO PASS GLM @13,779 RKB W/ CALIPER, PULLED 24 ARM READ CALIPER FROM 13,775' RKB TO SURFACE, JOB IN PROGRESS. DRIFTED TBG W/ 2.72" X 27' P2P DMY PATCH DRIFT TO 6500' RKB, *** NOTE TIGHT SPOTS @ 2425' RKB, 5550' RKB ***, NO WEIGHT SWINGS OR HEAVY PUWTS OBSERVED. JOB COMPLETE. SET 1.5" DMY IN ST#6 @ 13779' RKB, PULL CATCHER @ 13845' RKB, EQUALIZE AND PULL CA-2 PLUG @ 13850' RKB (HAVE WEIGHT SWINGS BETWEEN 6000' UP TO 1800'), JOB IN PROGRESS 7/30/2023 ACQUIRE DATA 8/1/2023 REPAIR WELL SET 2.725"" PIIP PACKER SER# CCP35031 W/ MOE @ 6220' RKB, CCL TO MOE = 11.8', CCL STOP = 6208.2' RKB, CORRELATED TO TUBING TALLY DATED 4/15/96 (CONFIRMED WITH LDL RUN 7/15/22). JOB IS READY FOR SL. 8/17/2023 REPAIR WELL RAN 3 1/2 TTS TEST TOOL TO LOWER 2.72" P2P @ 6217' RKB, CMIT TBG x IA FAILED, TROUBLE SHOOT LEAKING WING VLV, SET 3 1/2 TTS TEST TOOL IN LOWER PACKER @ 6217' RKB. IN PROGRESS 8/18/2023 REPAIR WELL DELAYED START DO TO GETTING FLOW LINE BLINDED, WITH 3 1/2 TTS TEST TOOL IN LOWER 2.72" P2P @ 6217' RKB CMIT TBG x IA 2500 (PASS), PULLED 3 1/2 TEST TOOL @ 6217' RKB, SET 2.70" PBR, SPACER & ANCHOR LATCH, (OAL 13.41' OAL / CPPBR35036 / CPAL35135) @ 6205' RKB, CMIT TBG x IA 2500 W/ 3 1/2 TTS TEST TOOL IN PBR (PASS), SET UPPER 2.72" P2P PATCH ASSEMBLY @ 6190' RKB (CE) TOP @ 6187.55' RKB (OAL 18.33' / SN: CPP35126 / CPAL35199). IN PROGRESS. 8/19/2023 REPAIR WELL CMIT TBG x IA TO 2500 PSI W/ 3 1/2 TTS TEST TOOL IN UPPER 2.72" PACKER @ 6185' RKB. PASSED. READY FOR E- LINE. 8/20/2023 REPAIR WELL SET 3.5" PIIP LOWER PATCH PACKER MID-ELEMENT AT 6064' (SN: CPP35189) JOB COMPLETE, READY FOR SL TO SET UPPER PATCH ASSEMBLY 8/21/2023 REPAIR WELL CMIT TBG x IA 2500 W/ 3 1/2 TTS TEST TOOL IN LOWER PACKER @ 6061' RKB (PASS), SET UPPER 2.72" P2P SPACER ANCHOR LATCH (OAL 15.91' / SN: CPP35233 / CPAL35094) @ 6049' RKB, MIT TBG 2500 W/ 3 1/2 TTS TEST TOOL IN UPPER 2.72" P2P @ 6049' RKB (PASS), CMIT TBG x IA 2500 (PASS). JOB COMPLETE. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 14,009.0 2A-25 4/9/2017 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Upper Patch 2A-25 8/21/2023 scolem Notes: General & Safety Annotation End Date Last Mod By NOTE: Heavy wt swings w/DMY patch drift starting @ 2060' SLM. Unable to get down with full length 6/29/2023 rogerba Note: Slickline located leak in Tbg between 6046'-6076' RKB 4/27/2022 zembaej NOTE: Heavy Weight Swings w/ Dmy Plug Drift on bottom 1600 lbs 6/7/2019 zembaej NOTE: View Schematic w/ Alaska Schematic9.0 9/15/2010 ninam NOTE: OA FAILED MIT 7/19/2009 lmosbor 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 41.0 121.0 121.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 40.1 5,485.2 2,977.7 40.00 L-80 BTC-M PRODUCTION 7 6.28 38.4 14,385.2 6,152.1 26.00 L-80 BTC-MOD Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 36.7 Set Depth 13,860.5 Set Depth 5,805.5 String Ma 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 36.7 36.7 0.04 HANGER 8.000 TUBING HANGER 3.500 479.0 478.7 4.41 NIPPLE 4.540 CAMCO DS NIPPLE 2.812 2,672.4 2,117.3 69.82 GAS LIFT 5.390 CAMCO KBUG/1/GLV/BK/.188/1280/ Comment: STA 1 CAMCO KBUG 2.920 6,001.7 3,134.0 73.31 GAS LIFT 5.390 CAMCO KBUG/1/OV/BK/.25/1280/ Comment: STA 2 CAMCO KBUG 2.920 9,362.4 4,175.9 73.20 GAS LIFT 5.390 CAMCO KBUG/1/DMY/BK/Comment: STA 3 CAMCO KBUG 2.920 11,847.5 4,940.2 70.34 GAS LIFT 5.390 CAMCO KBUG/1/DMY/BK/Comment: STA 4 CAMCO KBUG 2.920 13,202.4 5,460.4 64.69 GAS LIFT 5.390 CAMCO KBUG/1/DMY/BK/Comment: STA 5 CAMCO KBUG 2.920 13,779.8 5,755.4 52.47 GAS LIFT 6.018 CAMCO MMM/1.5/DMY/RK/Comment: STA 6 CAMCO MMM 2.920 13,825.5 5,783.6 51.58 NIPPLE 4.540 CAMCO W NIPPLE CAMCO W 2.812 13,833.6 5,788.6 51.48 SEAL 4.000 BAKER KBH 22 ANCHOR SEAL ASSEMBLY BAKER MODEL KBH-22 2.992 13,834.5 5,789.2 51.47 PACKER 6.156 BAKER 84 SAB HYD SET PACKER BAKER 84 SAB 3.000 13,850.4 5,799.1 51.26 NIPPLE 4.500 CAMCO D NIPPLE CAMCO D 2.740 13,859.6 5,804.9 51.14 SOS 4.500 BAKER BULL NOSE SHEAR OUT SUB, ELMD @ 13862' ON SWS PERF 9/10/2002 BAKER 3.000 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) 6,044.0 3,146.2 73.30 PACKER - PATCH - UPR 2.725 PIIP UPPER PKR SPACER PIPE ANCHOR LATCH ASSY (17.59' OAL) TTS PIIP CPP3 5233/ CPP3 5189 8/21/2023 1.625 6,054.0 3,149.0 73.30 LEAK - TUBING TUBING LEAK AT 6054' TO 6056' RKB (UPDATED LEAK DEPTH FROM SLB PROCESSED LOG) 5/22/2022 2.992 6,061.6 3,151.2 73.30 PACKER - PATCH - LWR 2.725" PIIP LOWER PACKER W/ MOE @ 6064' RKB, OAL = 4.01' TTS PIIP CPP3 5189 8/20/2023 1.625 6,184.8 3,186.7 73.28 PACKER - PATCH - UPR 2.725 PIIP UPPER PKR SPACER PIPE, ANHCOR SEAL ASSY (19.39' OAL) TTS PIIP CPP3 5126/ CPAL 35199 8/18/2023 1.590 6,201.0 3,191.3 73.29 LEAK - TUBING TUBING LEAK IDENTIFIED AT 6201' TO 6205' RKB ON LDL RUN ON 7/15/22 (UPDATED LEAK DEPTH FROM SLB PROCESSED LOG) 7/15/2022 2.992 6,204.2 3,192.2 73.29 ANCHOR LATCH ON SPACER PIPE 2.70 PBR, SPACER PIPE, ANHOR LATCH ASSY (13.41' OAL 1.59 I.D) TTS PIIP CPPB R3503 6/CPA L3513 5 8/18/2023 1.590 6,217.6 3,196.1 73.30 PACKER - PATCH - LWR 2.725" PIIP LOWER PACKER W/ MOE @ 6220' RKB, OAL = 4.01' TTS PIIP CPP3 5031 8/1/2023 1.625 14,205.0 6,030.1 47.93 FISH Junk/Obstruction Push Down & Out TT; See WSR 4/17/96 4/21/1996 2A-25, 8/25/2023 2:05:41 PM Vertical schematic (actual) PRODUCTION; 38.4-14,385.2 FISH; 14,207.0 FISH; 14,205.0 IPERF; 14,010.0-14,030.0 APERF; 14,001.0-14,009.0 APERF; 13,972.0-13,992.0 PACKER; 13,834.5 GAS LIFT; 13,779.8 GAS LIFT; 13,202.4 GAS LIFT; 11,847.5 GAS LIFT; 9,362.4 PACKER - PATCH - LWR; 6,217.5 ANCHOR LATCH ON SPACER PIPE; 6,204.2 LEAK - TUBING; 6,201.0 PACKER - PATCH - UPR; 6,184.8 PACKER - PATCH - LWR; 6,061.6 LEAK - TUBING; 6,054.0 PACKER - PATCH - UPR; 6,044.0 GAS LIFT; 6,001.7 SURFACE; 40.1-5,485.2 GAS LIFT; 2,672.4 NIPPLE; 479.0 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) 46.00 RR Date 4/15/1996 Other Elev 2A-25 ... TD Act Btm (ftKB) 14,391.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032023900 Wellbore Status PROD Max Angle & MD Incl (°) 73.78 MD (ftKB) 9,267.42 WELLNAME WELLBORE2A-25 Annotation Last WO: End DateH2S (ppm) 50 Date 12/16/2012 Comment SSSV: NIPPLE Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 14,207.0 6,031.4 47.92 FISH DMY 1" GLV in rathole - 10/20/2002 4/21/1996 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) 2,672.4 2,117.3 69.82 1 GAS LIFT GLV BK 1 1,304.0 4/21/2022 0.188 6,001.7 3,134.0 73.31 2 GAS LIFT OV BK 1 0.0 4/26/2022 0.250 9,362.4 4,175.9 73.20 3 GAS LIFT DMY BK 1 0.0 11/13/2004 0.000 11,847.5 4,940.2 70.34 4 GAS LIFT DMY BK 1 0.0 9/21/2004 0.000 13,202.4 5,460.4 64.69 5 GAS LIFT DMY BK 1 0.0 9/21/2004 0.000 13,779.8 5,755.4 52.47 6 GAS LIFT DMY RK 1 1/2 0.0 7/30/2023 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 13,972.0 13,992.0 5,876.5 5,889.5 C-4, 2A-25 9/10/2002 6.0 APERF 120 Deg Phasing, Powerjet 14,001.0 14,009.0 5,895.4 5,900.6 A-3, 2A-25 9/10/2002 6.0 APERF 120 Deg Phasing, Powerjet 14,010.0 14,030.0 5,901.2 5,914.3 A-3, 2A-25 4/26/1996 4.0 IPERF 2 1/8" Strip Gun; 180 deg. phasing; Oriented (+/-) 90 deg. f/ Low Side of Hole 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) 14,010.0 14,353.0 1 Scale Inhibitor 3/16/1997 0.0 0.00 0.00 2A-25, 8/25/2023 2:05:42 PM Vertical schematic (actual) PRODUCTION; 38.4-14,385.2 FISH; 14,207.0 FISH; 14,205.0 IPERF; 14,010.0-14,030.0 APERF; 14,001.0-14,009.0 APERF; 13,972.0-13,992.0 PACKER; 13,834.5 GAS LIFT; 13,779.8 GAS LIFT; 13,202.4 GAS LIFT; 11,847.5 GAS LIFT; 9,362.4 PACKER - PATCH - LWR; 6,217.5 ANCHOR LATCH ON SPACER PIPE; 6,204.2 LEAK - TUBING; 6,201.0 PACKER - PATCH - UPR; 6,184.8 PACKER - PATCH - LWR; 6,061.6 LEAK - TUBING; 6,054.0 PACKER - PATCH - UPR; 6,044.0 GAS LIFT; 6,001.7 SURFACE; 40.1-5,485.2 GAS LIFT; 2,672.4 NIPPLE; 479.0 CONDUCTOR; 41.0-121.0 KUP PROD 2A-25 ... WELLNAME WELLBORE2A-25 C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2025-07-25_2252_KRU_2A-25_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22552 KRU 2A-25 50-103-20239-00 Caliper Survey w/ Log Data 25-Jul-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 196-062 T37885 Kayla Junke Digitally signed by Kayla Junke Date: 2023.07.31 13:36:52 -08'00' 6048', 6061', 6187', 6217', 13834' 3147', 3151', 3187', 3196', 5789' By Anne Prysunka at 8:50 am, Nov 02, 2022 C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-05-22_20210_KRU_2A-25_LeakDetectLog_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 20210 KRU 2A-25 50-103-20239-00 Leak Detect Log 22-May-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:196-062 T36677 Kayla Junke Digitally signed by Kayla Junke Date: 2022.06.02 08:58:31 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-05-22_20211_KRU_2A-25_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 20211 KRU 2A-25 50-103-20239-00 Caliper Survey w/ Log Data 22-May-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:196-062 T36676 Kayla Junke Digitally signed by Kayla Junke Date: 2022.06.02 09:01:08 -08'00' Schlumberger -Private 19U062 Originated: 3 1 1 89 Schlumberger Delivered to: TRANSMITTAL + 11-Sep-19 AOGCC 115e 19-J4Y01 PTS -PRINT CENTER 6411 A Street~ ak t' ATTN: Natural Resources Technician II Anchorage, AK 99518 Alaska Oil & Gas Conservation Commision (907) 273-1700 main (907)273-4760 fax `+ 333 W. 7th Ave, Suite 100 ... Anchorage, AK 99501 Schlumberger -Private . • KR(A_ Z-q -&S- D—kJ (ci4vO , Regg, James B (DOA) From: NSK Env Coord Air Quality&Spill Plans <n1037@conocophillips.com> Sent: Saturday,July 23, 2016 10:18 AM To: Regg,James B (DOA) Subject: 20 AAC 25.025 Five Day Report for Spill on 18 July 2016 Below is the five day report for Notification of Accidental Loss of Oil or Gas for the spill on 18 July 2016. Notification of Accidental Loss of Oil or Gas 20 AAC 25.205 Five Day Report To comply with the requirement written report to the commission within five days after the accidental loss, please not the following details: 1. Time of incident: 18 July 2016 at 11:20 AM 2. Location where incident took place: Kuparuk River Unit Drill Site 2A at well 25 3. Volume of crude oil and of natural gas lost: 28 gallons of crude oil and 0 Mscf of natural gas 4. Cause of loss:Valve failure 5. Actions taken and planned to prevent further loss: After completion of initial delineation of the spill, cleanup was completed from the well to the direction of the plume with wipe down of the well head.The cleanup included 18 yards of contaminated gravel, 35 bbl of water, and 2 bags of oily waste. Confirmation photoionization detector readings were completed from well to outer edge of spill with readings of 6 at well and between 3-5 to outer edge.Sorbent boom was placed in the pit surrounding the well as a precautionary measure. 6. Equipment or procedural changes, if applicable, to prevent the loss from recurring: Investigation is underway to determine the cause of the valve failure. Let me know, if you need any further information or have additional questions. Sarah Byam On behalf of Nathan Visser and Wendy Mahan North Slope Environmental Coordinator Air Quality and Spills Plans Office: 907.659.7242 Mobile: 907.943.1545 Pager: 669 E-mail: n1037@conocophillips.com SCANNED JAN 2011, 1 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / ~¢ -~ <:¢)~ c~- File Number of Well History File PAGES TO DELETE Complete RESCAN Color items o Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by,~ianna Vincent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Isl • Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 12, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~~~11~~ NCt1 ~ ~©0? ~,~ ~ ~~ Enclosed please find a spreadsheet with a list of wells.,from the Kuparuk field (KRi~. Each. of - - thesewells was found to have a void in the conductor.- 't`hese voids were filled with a corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous ab eernent 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 corrosion inhibitor/sealant was pumped on November 10, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself or MJ Loveland at 907-659-7043, if you have any questions. Sincerer , "~; ~'„~ Perry Klei ConocoPhillips Well Integrity Projects Supervisor r9~~'~ 0~~ ~ ~ ~ ' ' a" 1,° ~~~ • nC illiS IaSa 9nCo Surface Casing by Conductor Annulus Cerrlent, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) ~_. Kuparuk Field 11 /10/2007 vac We{I Name PTD # Initial top of .cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date 2A-15 2A-16 185-146 185-147 ft 5" 39" bbls NA NA ft 5" 39" " NA NA al 3:5 21 6 11/10/2007 11/10/2007 11/10!2007 2A-19A 2A-20 2A-24 2A-25 201-083 193-151 193-144 196-062 12" 9" 5" 10" NA NA NA NA 12 9" 5" 10" NA NA NA NA 7.5 2 2 11/10/2007 11/10/2007 11/10/2007 - ..... ,~._. PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 October 1, 2002 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 2A-25 (196-062) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the KRU well 2A-25. If there are any questions, please contact me at 263-4574. Sincerely, · oneY Wells Team Leader Phillips Drilling MM/skad RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _XX Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator Conoco Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 4650' FNL, 51' FEL, Sec. 14, T11N, RSE, UM 5. Type of Well: Development __X Exploratory __ Stratigraphic __ Service__ (asp's 498340, 5960050) 6. Datum elevation (DF or KB feet) RKB 135 feet 7. Unit or Property name Kuparuk Unit 8. Well number 2A-25 At top of productive interval 1231' FSL, 1361' FEL, Sec. 16, T11N, R8E, UM At effective depth At total depth 4035' FNL, 1674' FEL, Sec. 16, T11 N, R8E, UM (asp's 486160, 5960676) 9. Permit number / approval number 196-062 / 10. APl number 50-103-20239 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size CONDUCTOR 121' 16" SUR. CASING 5444' 9-5/8" PROD. CASING 14312' 7" 14391 feet Plugs (measured) 6156 feet 14018 feet Junk (measured) 5906 feet Cemented 200 sx AS II 880 sxAS III, 910 sx Class G 220 sx Class G Measured Depth 121' 5485' 14353' True vertical Depth 121' 2978' 6130' Perforation depth: measured 14010'- 14030', 13972' - 13992', 14001' - 14009' true vertical 5902' - 5915', 5877' - 5890', 5896' - 5901' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tbg @ 13860' MD. Packers & SSSV (type & measured depth) BAKER '84-SAB' @ 13834' MD. CAMCO 'DS' @ 479' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl 1595 Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl 3374 2074 501 1478 691 Casing Pressure Tubing Pressure 242 257 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X Gas I Suspended __ Service _ 17. I hereby certify that the foregging is true and correct to the best of my knowledge. SignedMichae/Mooney /~ ~% Title: Wells Team Leader Questions? Carl Mike Mooney 263-4574 Date Prepared by Sharon AIIsup-Drake 263-4612 SCANNED 0.5 200?_ Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE Date Comment 2A-25 Event History 08/31/02 09/1 O/O2 09/19/02 O9/2O/O2 DRIFT & TAGGED W/23' X 2.63" HCDG,TAGGED FILL @ 14028' RKB EST. 2' FILL COMPLETE. [TAG] PERFORATED: C4 13972' - 13992' AND A3 14001' - 14009' WITH 2-1/2" HSD 6 SPF POWER JET, TAGGED FILL AT 14018', USED WATER INJECTION TO ASSIST RUNNING IN HOLE [PERF] INSTALLED GLV @ 2672' RKB. TAGGED FILL @ 14002' RKB. EST. 28' FILL. [TAG, GLV] INSTALLED 1/4"OV @ 6002' RKB. [GLV] Page 1 of I 9/30/2002 THE MATERIAL UNDER THIS COVER HAS BEEN: MICROFILMED ON OR BEFORE JANUARY 03 2001 M E PL ATE .IA U W N D E R K F R C:LORBMFILM. DOC AOGCC Individual Well Geological Materials Inventory Page: 1 Date: 04/20/98 PERMIT DATA T DATA PLUS RUN RECVD 96-062 CBL L SEPIA 96-062 CDN 96-062 CDR 96-062 CDN 96-062 CDR 96-062 7309 96-062 TDTP 96-062 7570 L BL 5390-14390 L BL 5450-14310 L SEPIA 5390-14390 L SEPIA 5390-14390 T CDR-CDN 14391-53870 L 13700-14186 T SCHLUM TDTP 1 05/03/96 FINAL 07/01/96 FINAL 07/01/96 FINAL 06/28/96 FINAL 06/28/96 1,2 06/28/96 FINAL 01/03/97 1 01/03/97 10-407 R COMPLETION DATE / / / DAILY WELL OPS R / / / TO / / / Are dry ditch samples required? yes no And received? Was the well cored? yes no Analysis & description received? Are well tests required? yes no Received? yes no Well is in compliance Initial COMMENTS / / / , / / / yes no yes no T 12/31/96 GeoQuest 500 W. International Airport Road Anchorage, Al( 99518-1199 ATTN: Sherrie NO. 10666 Company: Alaska Oil & Gas Cons Comm Attn' Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia LIS Tape 2A-25 ~/(~'©~'~...,'~''~"~C~ 96382 TDTP 961201 I I I / r~.ase sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RECEIVEtJ DATE: JAN 0 j 1997 :~chorage ARCO Alaska, Inc. Post Office Box 1003~d Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 4, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2A-25 (Permit No. 96-62) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 2A-25. If there are any questions, please call 263-4183. Sincerely, D. K. Petrash Drilling Engineer Kuparuk Drill Site Development DKP/skad STATE OF ALASKA A~_. ~SKA OIL AND GAS CONSERVATION COi~..IISSION WELL COMPLETION OR REOOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL ~] GAS ['~ SUSPENDED [~ ABANDONEI~ SERVICE [~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 96-62 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 .... . ..... 50-103-20239 4 Location of well at surface ' ~:~11~ 9 Unit or Lease Name 626' FSL, 53' FEL, Sec. 14, T11N, R8E, UM i' '.ii.?i~'~- ~ .... ': ,: ;."~¥~1~-i Kuparuk River Unit 1231' FSL, 1361' FEL, Sec. 16, T11N, R8E, UM . 2A-25 At Total Depth ' :' ''; :~?- '.!~-~ 11 Field and Pool 1240' FSL, 1673' FEL, Sec. 16, T11 N, R8E, UM . r_ ~ % ~-:~'~.2¢ KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) J 6 Lease Designation and Serial No. Rig RKB 41' Pad 94'I ADL 25571 ALK 2669 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 116 No. of Completions 05-Apr~96 13-Apr-96 26-Apr-96 (perf'd) NA feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey'120 Depth where SSSV set I 21 Thickness of permafrost 14391' MD & 6156' TVD 14264' MD & 6070' TVD YES F~ NO E~I NA feetMDI =1380'ss APPROX 22 Type Eleclric or Other Logs Run GR/CDR/CDN, GR/CCL/SLTJ 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECOFID 16" 62.58# H-40 SURF. 121' 24" 200 sx AS II 9.625" 40.0# L-80 SURF. 5485' 12.25# 880 sx AS III Lead, 910 sx Class G Tail 7" 26.0# L-80 SURF. 14353' 8.5# 220 sx Class G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 13860' 13834' 14010'- 14030' MD 4 spf 5901-5915'-I-VD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 14010'-14030' 197,237# proppant in formation. 16675# proppant left in wellbore. pumped 21062# 20/40, 169260# 12/18, and 23417# of 10/14 27 PRODUCTION TEST Date First Production JMethod of Operation (Flowing, gas lift, etc.) Ju n-96I FLOWING Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 7/11/96 20 TEST PERIOD ¢ 1 46 150 10 209I 1032 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 230 733 24-HOUR RATE I~ 1 75 180 12 =24° 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED O tlGINkL Alaska 0il 8, Gas Cons. commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ~30. OEO~O~lC M^~<~:Rs FORr,4AT~N TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and tirne of each phase. Top Kuparuk C 13971' 5876' Bottom Kuparuk C 13992' 5890' Top Kuparuk A 13992' 5890' Bottom Kuparuk A 14182' 6015' Freeze protect annulus with diesel 31. LIST OF A'lq-ACHMENTS Daily/ Drillin9 History, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~~-~~. Title ~""~lf~.~..~--~. ~-'lN~¢,_,~, DATE ~["drl~(o 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 Date: 4/17/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 1 NOTE: REPORTING TIMES CHANGED FROM 0600/0600 TO MIDNIGHT/MIDNIGHT WELL:2A-25 RIG:PARKER WELL ID: AK8541 AFC: AK8541 STATE:ALASKA AREA/CNTY' NORTH SLOPE EAST TYPE: FIELD: KUPARUK RIVER UNIT SPUD: START COMP: BLOCK: FINAL: WI: 55% SECURITY:0 AFC EST/UL:$ OM/ OM API NUMBER: 50-103-20239-00 4/2/96 (1) TD: 121'(0) SUPV'GRW DAILY' MW: PV/YP: APIWL: 0 MIRU Released rig from 1F-20 @ 1100 hfs 4/1/96. Move rig. $50,906 CUM: $50,906 ETD' $0 EFC'$50,906 4/3/96 (2) TD' 121'(0) SUPV:GRW DAILY: 4/4/96 (3) TD' 121'(0) SUPV:GRW DAILY: 4/5/96 (4) TD' 2298'(2177) SUPV'GRW DAILY' 4/6/96 (5) TD' 4642' (2344) SUPV'GRW DAILY' 4/7/96 (6) TD' 5495' (853) SUPV:GRW DAILY' MW: PV/YP' APIWL' 0 MIRU Moving rig to DS 2A. $152,309 CUM: $203,215 ETD: $0 EFC'$203,215 MW: PV/YP' 32/38 APIWL: 9.8 DRILLING @ 182' Accept rig @ 1300 hrs. 4/3/96. Warm up rig. $87,728 CUM: $290,943 ETD: $0 EFC:$290,943 MW: 10 PV/YP: 39/45 APIWL: 7.5 RIH W/BIT #2 Drill from 121' to 2298'. Drill string plugged while pumping up survey. POOH wet and tight. Ream up and work pipe out of the hole. $92,830 CUM: $383,773 ETD: $0 EFC:$383,773 MW: 10.1 PV/YP: 35/38 APIWL: 6.2 CIRC AND COND MUD FOR CSG Back ream out of hole w/o pump to 1556'. Drill string plugged w/ cement scale in screen at top of MWD. Change bit. Cleanout MWD. TIH. Wash and ream from 1520-1556', 1770-2024' Drill 2206-4642' $89,911 CUM: $473,684 ETD: $0 EFC:$473,684 MW: 11 PV/YP: 22/15 APIWL: 5.5 POOH TO RUN CSG Drill from 4642'- 5495'. POOH to 4935'. Well flowing. Weight up to 10.2 ppg. Swabbing, not taking correct dis- placement. Well flowing. Wt up to 10.5 ppg, still flowing. Wt up to 10.8 ppg. $87,101 CUM: $560,785 ETD: $0 EFC:$560,785 4/8/96 (7) TD: 5495' (0) SUPV:GRW DAILY: MW: 11.1 PV/YP: 30/49 APIWL: 5.8 TESTING BOPE Raise mw to 11.0 ppg. Hole static. Pump pill. Hold safety meeting. Run 9-5/8" casing to 5484'. Cement casing. CIP @ 21:45 hrs. 4/7/95. N/D diverter. $201,295 CUM: $762,080 ETD: $0 EFC:$762,080 4/9/96 (8) TD: 5870'(375) SUPV:GRW DAILY: MW: 8.7 PV/YP: 7/11 APIWL: 15.2 DRILLING @ 6189' Test all BOPE components to 300/3000 psi for 3 min. Test casing to 2000 psi for 30 min. Drill float equip., shoe jts., and 10' new hole. Perform FIT. Drill 8.5" hole 5495' to 5870' $222,463 CUM: $984,543 ETD: $0 EFC:$984,543 4/10/96 (9) TD: 9254'(3759) SUPV:RLM DAILY: MW: 9.0 PV/YP: 11/15 APIWL: 8.2 WIPER TRIP Directional drill 8.5" hole from 5870' to 9254' $78,494 CUM: $1,063,037 ETD: $0 EFC:$1,063,037 4/11/96 (10) TD: 12046' (2792) SUPV: RLM DAILY: MW: 9.4 PV/YP: 15/24 APIWL: 5.5 DRILLING @ 12505 Directional drill 8.5" hole from 9254' to 9437'.. Pump pill and POOH. First 5 stands tight and swabbing. Backream out to shoe at 5485'. RIH to 9437'. No fill. Directional drill from 9437' to 12046' Circulate hole clean prior to wiper trip. Saw increase in torque, drag and pump pressure. $81,071 CUM: $1,144,108 ETD: $0 EFC: $1,144,108 4/12/96 (11) TD: 13692'(1646) SUPV:RLM DAILY: MW: 10.4 PV/YP: 23/20 APIWL: not available DRILLING @ 13732' Directional drill 8.5" hole from 9254' to 13692' Weighted up to 10.4 ppg above the Kuparuk. Short-tripped. No problems. $85,000 estimate CUM: =$1,148,037 ETD: $0 EFC: =$1,148,037 4/13/96 (12) TD: 14391'(699) SUPV:RLM DAILY: MW: 10.4 PV/YP: 24/14 APIWL: 4.3 POOH Directional drill 8.5" hole from 13692'to 14,391'. Wipe hole to 12,936' pumped out (precautionary). Re-log from 14050' to 14391'. Circulate and condition mud for casing. $79,698 CUM: $1,325,645 ETD: $0 EFC: $1,325,645 4/14/96 (13) TD: 14391'(0) SUPV:RLM DAILY: MW: 10.6 PV/YP: 24/16 APIWL: 5.0 NIPPLE DOWN Held pre-job safety meeting. Run 7" casing to 14,342. Wash to 14,381' TD. Circulate and work casing prior to making up cement head. Hole packed off and pipe stuck at 14353. $269,337 CUM: $1,594,982 ETD: $0 EFC:$1,594,982 4/15/96 (14) TD: 14391' (0) SUPV:RLM DAILY: MW: PV/YP: APIWL: RUN 3.5" TUBING Casing packed off and stuck at 14,353'. Attempt to regain circulation and free casing. No good. Cement casing. CIP @ 0506 hrs. 4/14/96. Test packoff and seals to 3000 psi. Freeze protect 9-5/8" x 7" annulus. Held pre-job safety meeting. $74,403 CUM: $1,669,385 ETD: $0 EFC: $1,669,385 4/16/96 (15) TD: 14391'(0) SUPV: RLM DAILY: MW: PV/YP: APIWL: PREP FOR PAD MOVE Finish lay down 5" drill pipe. Test 7" casing to 3,500 psi for 30 minutes. Held pre-job safety mtg. Run 3.5" completion. Land tubing on hanger w/ tail @ 13,860.49. Set tubing. Lay down landing jt. Nipple down & set out stack. Freeze protect 2A-22 annulus. Original estimated DC&P $1,750,000. Final estimated DC&P 1,911,399. $212,014 CUM: $1,881,399 ETD: $0 EFC: $1,881,399 PAGE NOo *********** ~URVEY PRgGRAM ********~** COMPANY WELL NAME 2A-25 L[~_~TI~ i ~UPAE~K LOCATION 2 ALASEA MAGN~IC DECLINATION 27.66 GRID CONVEE~4CE ANGLE 0.00 DATE: ~-APR-96 WELL NUMBER ~ AFE A~8541 ~I WELL NO: 50-103-20237-00 WELL HEAD '~^~ '~"'/ ~' ARCO ALASRA, iNC. 0,00 DEP(E/-W) AZIMUTH FROM ROTARY TABLE TO TARGET IS TIE IN POINT(TIP) : MEASURED DEPTH 121,00 TRUE VERT DEPFH !~.00 INCLINATION 0.00 AZIMb~ 0,00 LATITUDE(N/-S) 0,00 D~ARTLG:E(~'-W) 0,00 :A-'..!5 .. unF IH DEPTH ft ft ft i21,00 0.0. .~.~'~ ,00 i85.'76 o'",0~ 185,96 275,40 370,58 ?5,2 370~52 ~0,88 '~+3 4~,65 ,.-n A r-ret ft :dea :f. eq ft C,. :~ O, O0 O, O0 0, O0 ' - ," -"- ~ "'. ~-~ ::+~>Z :J,20 .J::-d, D/ '..:,ii ':,,.~ v./7 296,10 3,54 2,88 2~,62 t :52 8,'~: 4,08 281,~ 2,80 ~'t :.-'? 0+00 ~' "'" -0,01 0,11 -0 =.o -3.47 3.79 ~ ,q'. ,-, -'. + .~V 7 + A"~, T Wt1 d.e~ O,O0 353 ~ 312,8i 287,66 deo/ lOOft 0,0(.'. 0,79' 2.21 i 640,39 731.11 912,55 91.0 551,26 88.6 639,03 90,7 727,99 90,6 815,62 90.8 902,07 16..~ 5.75 282.6~_ ,.44-~ ~' 78,31_ ?.52 :~ ~'?~ ,o/" 6.3? 45,92 12.96 278,01 8.61 ?6.69 17.05 "~'4,v~"' '~i~.~o"" -!6.42 17.01 285.14 i,84 -28,0t 28,73 282,86 4,32 -,>,Jo ~$,~/ 280,96 3.79 -68,44 69.41 779.56 4.02 -96,10 '"= ' ~/.lO 778,22 2,8i !001 '~ 1092,82 iluS.O~ 12~,43 1372 '~ 89.2 986,~A '.;'1,1 1071,48 92.9 !157,45 !00,7 1248.97 . . . :r,oo 274,25 i6.04 158.29 2!.18 270.66 17,38 :93,34 ~ ~ =o .~ 235,37 26,i9 269.7~ 17.15 ~5.39 29,05 268.96 16,69 -234,80 2~.42 274.18 2.94 -274.?0 Z75.&O 273.47 3,33 . 1469,41 1561,83 1655,66 1748,74 1842,89 96,5 1408,76 9~.4 1484.26 93,8 1562,12 93,1 i633.34 94,1 1700,79 324,20 31,66 270,85 16.64 ~ ~ ~/l.i~ 17.51 074,50 34,17 .... 4L~,70 37,% o=71,83 18.95 %~.59 42,23 ~3.~ 21,82 555,22 ~.,2o 275.29 26,92 -323.77 324,20 272,94 3.08 -374,i2 374.53 272.68 2,51 -,~.ou ~?,71 772,53 4,00 -149,i2 .489,60 ~v2,55 4.80 -554,57 5~,22 272+78 4,44 i~,74 2029 '~ 2215 ~ 2310,46 91,8 I762,38 Y~,~ 1822.28 91,6 ,87.,45 ?~.0 1928.08 94,9 !775,i4 o~,z7 49,54 275,34 33,23 677,16 52,45 275,69 40.35 770,99 55,07 275,40 47,49 ~49,56 58,34 273,72 53,71 -6~,40 6~,2~ 273.06 3.60 -769,57 /71,03 ~3,Jo 87 -847 o~ ~"" ' ........ 9 2.4,93.45 % 85 2963,00 3245,46 .,,6,..0.64 93.0 2015.89 ~77.4 2120.23 282,1 2212,28 282.5 2301.34 375,2 2414,85 ~015,-o o~,85 272,"o, 62,50 ~.,.z,o~o ~ 69,94 273,0A. 75 1539.10 71.97 271,75 1807,09 7t,26 271.90 94,97 ~i.~.~ 73.52 2~,37 ,~o iwz,~o 273,39 -!536,69 15oW,12 ~3.22 -i804,60 1807,10 273.0i -clo~,,u 2164,60 Z73.1Z 3,98 i,48 0,84 0,26 1,07 oY97,oo 4371,12 4747,~..: 5122,78 J412.~0 376,7 2524.96 373,8 2641,16 376.4 27~. o7o.4 2866.61 289.5 2955, i7 2.,24,.,~ 72,49 274,63 i49,10 2879.77 71.29 273,79 175,18 3238.36 73.~ ,.,°:°,..,,..,_~ 197.08 · D,,J'?O, 7,.o .-" c+.-J ;, 3,18 ii; 3872+59 72,13 771,4i 228.11 -~20,°=~. 2524.M.. 273,39 -~o74,~ 2879,89 '~3,49 o~oo ~n 3238+50 273,49 -:5'590.56 3597.12 ?3.46 -~o.a+~,, 3872,70 :/~,~ 0,33 0,37 0.58 5628,~5 5910.i9 6187.87 6468.70 6846.44 215,'7 :3022,54 281.7 3107+&6 279,7 3188.05 278,8 3~.7,78 .~,/ 3383,65 ...... 232 ....... ~o46+14 73,32 272,70 20),15 ,'~+.8 ,,,J~ 257+01 4881.12 73,49 773,55 775,77 5240,61 70.79 272,44 294,58 0.40 0.9~ 0.62 g+Oq 0.77 MEASURED iNTERVAL VERTICAL DEPTH OEPTH 7~0.67 374,4 3507,26 ?502,42 2~1.5 3602,12 7871,37 $~9,0 :3721,55 8156,48 285,1 38~¢,37 8525,63 369,1 3923.37 SECTION [NCLN. N/-S ft deo dca ft 5574.~ 70,66 u, 274.42 315.71 5859,03 ~9,95 274,07 ..208,u4 72,27 =~ ~ 359,67 4/9,28 71+85 ~/2,V~ 37^.05 oocv,~/ ,'~,17 273,2? 395+29 DEF'AR%"RE ?'~'"" .... ~'¢' ....",?~,',,: ft ft deo %585.17 5594,i0 273,24 -5849.52 5859,13 273,28 -6177,73 6208,16 -64~,49 6479,4i deg/ lOOft 0.63 0.34 0.12 8~01,20 9267,43 9639,51 10580,26 375.6 4040.01 366.2 4148.83 372.1 4259.80 474.0 4409.09 466.7 4551.72 7187.25 71.65 275.44 422.45 7536.69 73.78 274.56 452+92 7891,70 71,51 274,25 480,19 8341,48 71,78 274+55 514.67 8785+75 72.63 273.73 546+73 "" 7 -7175,01 / .~8.,~.o"~ Z73,37 -~2:3,34 ~3,.4,% 273.45 -787'/,4i "" '" . . -&326.0i 8341.9I ~3+54 -876y..'.' 8786.25 ~3.57 0.56 0.63 0.62 0.08 '.'332,oo : £/VJ., ./' 12O65.85 12430,72 376.6 4665.96 9144.62 72.06 271.65 375.7 4779.19 9502.85 72,87 274.28 369,0 4892,32 9854,04 7t,42 272,61 3M+2 5016.49 i0196.i5 68,72 269+2'0 364.9 5150,38 10535,01 68,22 270+21 6o ~o -9127,70 9145.08 273.53 603.30 -9836.00 9854,49 Z73,51 608.80 ~^"~ ~" ~% '~ -zu,/o+~? zv,t..+~_ Z73,42 0,55 0.70 0,58 1.i5 0,29 12794,I4 13164,65 13250.92 13345.96 13437.13 363,4 5291,68 370,5 5444,34 66,3 5481,35 95,0 5524,65 91,2 5567.96 I08~9.2~ 66.01 269.~ 11206.38 65.32 270,32 I1284,21 63.87 270.08 11368.71 61.91 ~0,37 11448.83 61,37 269.4! 605.80 -I0852.48 10669.38 273.19 604,80 -Ii190,08 11206.41 ~3+09 605.08 -!1268.00 11284,23 273.07 .405,41 -I1352.60 I1368+73 ~3,05 605,25 -!1432.82 11448,83 273.03 0,65 0.30 1.70 2.08 1,10 13530.23 13617.67 13709.69 13796.43 13~85.66 93,1 5614.77 87.4 5661.76 92.0 5713.63 86.7 5765.47 189,2 5885,23 11529.15 58.25 269,76 I1602.80 56.74 270,4I 11678.74 54,63 U1.28 11748.26 51.96 272.20 11894,74 49,50 272.49 604.67 -I!513,29 11529,15 273.01 604.77 -I1587.03 11602.80 272.~7 605+88 -11663,02 11678,74 272+97 607.99 -lt7~z.~ 11748.26 272,97 613.98 -ii878.88 11894,74 272+96 3+36 1.84 2.43 q 4 O* ~9 1.31 i4319.i9 .0,33.5 6107.05 PRDJECTED TO TD 14~I.00 71,8 6155,92 12143,74 '~ 47..~ 12196.34 47,12 271.40 67').49 ~127,// 271.40 6LZ.'3.77 -!2!80.38 0.76 · ~.+34 '.-~2.~3 0+00 ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(2A-25(W4-6)) WELL JOB SCOPE 2A-25 PERFORATE, PERF SUPPORT DATE 04/26/96 DAY 1 DALLY WORK INITIAL "A" SAND PERF'S OPERATION COMPLETE J SUCCESSFUL YES I YES InitiaI TbgPress IFinalTbgPress I lnitiallnnerAnn 0 PSI 800 PSI 0 PSI KEY PERSON SWS-WARNER Final Inner Ann I Initial 800 PSI I IJOB NUMBER 0425961904.4 UNIT NUMBER SUPERVISOR CHANEY Outer Ann J Final Outer Ann 0 PSI! 0 PSI DALLY SUMMARY I HOLE W/DIESEL (350 BBLS). INITIAL "A" SAND PERFS SHOT @ 14010'- 14030' RKB. (4 SPF ). WHTP INCREASED 800 PSI WHEN SHOT. PUMPED GUNS DOWN TIME 08:30 09:00 LOG ENTRY MIRU SWS E/LINE AND LRS. HELD SAFETY MTG ( 8 ON LOCATION ). PERFORMED 1ST Q I H SAFETY ASSESSMENT DRILL (GAS LEAK S/D SITUATION) STOODBY FOR RIG CAMP MOVE BEFORE CONNECTING UP GUNS. 11:30 P'PD LUB AND SURFACE LINES TO 4000 PSI. 12:00 RIH W/1-11/16" WEIGHT BAR (6'), CCL, MPD, AND 2-1/8" STRIP GUNS W/BH ENERJET CHARGES 2 SPF 180 DEGREE PHASING +90 DEGREE FROM THE LOW SIDE OF THE HOLE (20'). TOOLS STOPPED FALLING AT 3600' ELM. STARTED PUMPING DIESEL @ 2.5 BPM. CONTINUED DOWN HOLE WITH TOOLS TO 14130' ELM. STOPPED PUMPING DIESEL 160 BBLS PUMPED. 14:00 15:00 13:45 TIED IN TO SHORT JTS OFF CBL DATED 4/18/96. , 15:45 PERF'D "A" SAND 14010' - 14030' RKB. (CLOCKWISE FROM BTM) WHTP INCREASED 500 PSI. POOH. ON SURFACE. ALL SHOTS FIRED. WHTP 800 PSI. RIH W/1-11/16" WEIGHT BAR (6'), CCL, MPD, AND 2-1/8" STRIP GUNS W/BH ENERJET CHARGES 2 SPF 180 DEGREE PHASING - 90 DEGREES FROM LOW SIDE OF THE HOLE (20"). AT 3000' ELM STARTED PUMPING DIESEL @ 2.5 BPM. CONTINUED DOWN HOLE WITH TOOLS TO 14130' ELM. STOPPED PUMPING DIESEL, 190 BBLS OF DIESEL PUMPED. 17:15 TIED IN TO SHORT JTS OFF CBL DATED 4/18/96. 17:25 18:15 18:20 19:00 PERF'D "A" SAND 14010' - 14030' RKB. (COUNTER CLOCKWISE FROM BTM) WHTP CONSTANT @ 800 PSI. ON SURFACE. ALL SHOTS FIRED. INJECTED 5 BBLS OF DIESEL DOWN HOLE PSI INCREASED FROM 800 PSI TO 2600 PSI. BLED OFF SLOWLY FTER PUMP S/D. RDMO SWS E/LINE AND LRS. ARCO Alaska, Inc. Date: June 26, 1996 Transmittal Cf: 9712 RETURN TO: ARCO Alaska, Inc. Attn.: Julie Nash Kuparuk Operations File Clerk ATe-1119 B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. receipt and return one signed copy of this transmittal. 2A-25 CDR Acknowledged' r Please acknowledge 04/13/96 04/13/96 DISTRIBUTION: Mr. Vernon E. Pringle Jr. DeGIoyler and MacNaughton One Energy Square Dallas, TX 75206 Sharon AIIsup-Drake DS Development ATO- 1205 Clifton Posey Geology ATe - 1251 ChapmanZospan NSK Wells Group NSK 69 Larry Grant AOGCC 3001 Porcupine Drive Anchorage, AK 99501 GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. I O256 Company: Alaska Oil & Gas Cons Comm Attn: Howard Okland 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Open Hole) LIS Well Job # Log Description Date BL RF Sepia DIR MWD Tape 2A-25 961 23 CDPJCDN 96041 3 1 2A-25 961 23 CDR 960413 I 1 2A-25 961 23 CDN 960413 I I SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: J L) ~ '~ ,'- 8 1.q..q.~ .~)~sk~ Oi)& 6~s ~n~. Commis~.ion A~chomqe ARCO Alaska, Inc. Date: April 29, 1996 Transmittal #: 9681 RETURN TO: ARCO Alaska, Inc. Attn.: Julie Nash Kuparuk Operations File Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. Please acknowledge receipt and return one signed copy of this transmittal. ~ ~ '" ~O ~___~A-25 Cement Bond Log SLTJ-GR/CCL 04/18/96 Receipt ~ ~~.~~ Acknowledge' ate' 13850-14196 RECEIVED t',',,-, 1996' DISTRIBUTION: Sharon AIIsup-Drake DS Development ATO-1205 Larry Grant (+sepia) AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Alaska Oil & Gas Cons. Commission Anchorage Chapman/Zuspan NSK Wells Group NSK69 ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KAIOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 29, 1996 Michael Zanghi, Drill Site Develop. Supv. ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit 2A-25 ARCO Alaska, Inc. Permit No' 96-62 Sur. Loc. 626'FSL, 53'FEL, Sec. 14, T1 IN, RSE, UM Btmhole Loc. 1256'FSL, 1646'FEL, Sec. 16, T1 IN, RSE, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional perm/ts required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David Chairm BY ORDER OF TIlE COMMISSION dlffEnclosures CC: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. [STATE OF ~ '~SKA OIL AND GAS CONSERVATION COMM¢::~SION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill E] lb Type of Well Exploratory [] Stratigraphic Test [] Development Oil X Re-Entry E] Deepen r"I Service r-I Development Gas E] Single Zone X Multiple Zone E] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 94' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchoracge, AK 99510-0360 ADL 25571, ALK 2669 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 20 AAC 25.025) 626' FSL, 53' FEL, Sec. 14, T11N, RSE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 1240' FSL, 1352' FEL, Sec. 16, T11N, R8E, UM 2A-25 #U-630610 At total depth 9. Approximate spud date Amount 1256' FSL, 1646' FEL, Sec. 16, T11N, RSE, UM 3/29/96 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2A-06 14318' MD 3634 @ TD feet 29,7' @ 350' feet 2560 6136' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 71.39° Maximum surface 1761 psig At total depth (TVD) 3200 psig 18. Casing program Settin~l Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length IV• TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' _+200 CF 12.25" 9.625" 40.0# L-80 BTC 5346' 41' 41' 5387' 2974' 880 Sx Arcticset III & HF-ERW 910 Sx Class G 8.5" 7" 26.0# L-80 BTCMOE 14277 41' 41' 14318' 6136' 170SxClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vedical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ~:~fdacU;t°r RECEIVED Intermediate Production Liner MAR 2 2:1996 Perforation depth: measured true vedical Naska 0il & (~as Cons. Commission Anchora.qe 20. Attachments Filing fee X Property plat [] BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot ~ Refraction analysis I--! Seabed report 1--1 20 AAC 25.050 requirements X 1. I hereby certify that the f~regoing is true and correct to the best of my knowledge 2 Signed I~~~..~CommissionTitle Drill Site DovoI°p' Supv' Date '~"-~/'~Use Only ~ Approval dale . I See cover letter for Permit~;~'b-er~..2. - -- 2. C~2...~ ¢ I ~ '~ ,'~:)"~ '" ,~'~I other requirements Conditions of approval Samples required [--I Yes I~ No Mud log required D Yes ~ No Hydrogen sulfide measures J~ Yes D No Directional survey required .i~ Yes [--I No Required working pressure for BOPE r-J 2M J~J 3M FJ 5M J--J 1OM J-J 15M Other:OJ'J.~,~.'lqi ,~ ~igned. By, Davio Vv. J0hnst0r~ by order of cZ~//~,///~ Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Subn ulicate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 2A-25 , 2, Si 10. 11. 12 13 14 15 16 17 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (5,387')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE to 3000 psi. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (14,318') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing string. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) ND BOPE. NU tubinghead & either full opening valve (if logging planned) or master valve and upper tree assembly (if no logging planned). Note: As a dedicated producer, no cased hole cement bond logs will be run unless there are problems with the cement job. Secure well and release rig. Move in and rig up Nordic #1. Install and test BOPE. Pressure test 7. casing to 3500 psi. Run completion assembly. Set packer and pressure test tubing and annulus. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig in preparation for perforating. DRILLING FLUID PROGRAM Well KRU 2A-25 Spud to 9-5/8" surface casing Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 9.0-10.0 15-25 15-35 50-80' 5-15 15-40 10-12 9.5-10 +_10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators General Notes- Weight up to TD 11.0 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% R£C£ V£D M~R ~. '2_ 1996 kl~tsh~ 0il & Gas Cons. commissio~ Anchorage Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.O33. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1,761 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 2A-25 is 2A-06. As designed, the minimum distance between the two wells would be 29.7' @ 350' MD. Drillin~l Area Risks: Risks in the 2A-25 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. 7" casing will be topset above the Kuparuk and Nordic Rig #1 will drill out a 6-1/8" hole, and run a 5" liner to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 11.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 9-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. ANNULAR PUMPING OPERA-,-,ONS WELL KRU 2A-25 Incidental fluids developed from drilling operations will be pumped down the surface/production casing annulus of an existing well, either 2A-18 or 2A-22 pending AOGCC approval. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2A-25 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface, if the surface shoe is within 200' 'I-VD of the top of the hydrocarbons. Alternatively, if the hydrocarbons are far below the shoe then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 2A-18 and 2A-22 be re-permitted for annular pumping occurring as a result of drilling operations, per proposed regulations 20 AAC 25.080. The original permits were issued under the guidelines of the Alaska Department of Environmental Conservation and expired on December 31, 1995. Specifications for these wells are similar to those noted for 2A-25 below. 2A-18 has been used for annular pumping previously, but the total volume will be monitored to ensure it does not exceed 35,000 bbl. In addition, it is requested that 2A-25 be permitted for annular pumping occurring as a result of drilling operations, per proposed regulations 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Please reference the enclosed directional drilling plan for other formation markers in this well. A list of all publicly recorded wells within 1/4 mile of the disposal operation is included in this permit application. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoes will be set +_200' vertical below the base of the West Sak into the heart of the shales. The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1500 psi Max Pressure - 3360 psi The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. OD Wt Conx Collapse 85% of Burst 85% of (in) (Ib/ft) Grade Range Type (psi) Collapse (psi) Burst 9.625 40 L-80 3 BTC 3090 2627 5750 4888 7.000 26 L-80 3 BTC-M 5410 4599 7240 6154 Fluids to be disposed of in subject annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.254 (g) (1). ARCO ALASKA, Inc. Pad 2A 25 slot #25 Kuparuk River Unit North Slope, Alaska CLEARANCE REPORT by Baker Hughes !NTEQ Your ref : 25 Version Our ref : prop1514 License : Date printed : 19-Mar-96 Date created : 22-Jan-96 Last revised : 19-Mar-96 RECEIVED Field is centred on nTO 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.315,w150 0 46.817 SLot Location is n70 18 7.482,w150 0 48.362 Slot Grid coordinates are N 5960048.241, E 498341.421 Slot Local coordinates are 627.00 N 53.00 W Reference North is True North Main calculation performed with 3-D Minimum Distance method Object weLlpath PMSS <O-14797'>,,22,Pad 2A PMSS <0-11700'),,23,Pad 2A PGMS <0-9785'>,,19,Pad 2A PGMS <0-11545'>,,20,Pad 2A PGMS <0-9888'),,16,Pad 2A PMSS <3841-7425'>,,1,Pad 2A PGMS <0-7630'),,IA,Pad 2A PGMS <O-6673'>,,2,Pad 2A PGMS <0-7131 >,,3,Pad 2A PGMS <0-8156 >,,4,Pad 2A PGMS <0-9185 >,,5,Pad 2A PGMS <0-8205 >,,6,Pad 2A PMSS <0-7763 >,,7,Pad 2A PGMS <0-8535 >,,9,Pad 2A PGMS <0-7260'>,,lO,Pad 2A PGMS <0-6675'>,,11,Pad 2A PGMS <0-7125'>,,12,Pad 2A PGMS <0-8150'>,,13,Pad 2A PGMS <0-8130'>,,15,Pad 2A PGMS <O-7863'>,,14,Pad 2A PGM$ <0-11839'>~21~Pad 2A PGMS <0-8497'>,,8,Pad 2A PGMS <0-9934'>,,17,Pad 2A PGMS <0-9674'>,,24,Pad 2A PMSS <0-6791'>,,18,Pad 2A Closest approach with 3-D minimum distance method Last revised Distance M.D. Diverging from M.D. 30-May-95 307.8 300.0 300.0 10-0ct-93 678.6 240.0 240.0 26-Dec-93 35.8 925.0 10380.0 26-Dec-93 69.0 0.0 11740.0 3-Aug-92 697.7 60.0 300.0 3-Aug-92 294.3 180.0 12360.4 3-Aug-92 294.3 180.0 12360.4 3-Aug-92 281.6 100.0 14317.9 3-Aug-92 281.4 300.0 14120.0 3-Aug-92 294.0 280.0 13796.2 3-Aug-92 90.2 60.0 120.0 3-Aug-92 29.7 350.0 350.0 3-Aug-92 30.0 375.0 375.0 3-Aug-92 387.9 1472.2 1472.2 3-Aug-92 699.0 60.0 625.0 3-Aug-92 756.3 775.0 6720.0 3-Aug-92 818.6 700.0 700.0 3-Aug-92 865.6 60.0 12977.7 3-Aug-92 752.9 300.0 14040.0 3-Aug-92 808.0 325.0 14120.0 2~-Dec-93 575.0 5500.0 5500.0 3-Aug-92 89.7 240.0 10480.7 26-Dec-93 719.4 300.0 300.0 26-Dec-93 107.9 525.0 525.0 12-Dec-95 300.4 300.0 300.0 'Created by : jones For: D PETRASH Date plotted : 19-Mar-g6 Plot Reference is 25 Version #4. Coordinates ore in feet reference slot ~25. True VerUcol Depths ore reference RKB (Parker ~245). ARCO ALASKA, Inc. Structure : Pod 2A Well : 25 Field : Kuporuk River Unit Location : North Slope, Aloska i West Scale 1' 575.00 12750 12000 11250 10500 9750 9000 8250 7500 6750 6000 5250 4500 3750 3000 2250 1500 750 0 750 TD LOCATION: 1256' FSL, 1646' FEL SEC, 16, T11N, ESE TARGET LOCATION: 1240' FSL, 1.352' FEL 750 _ -- 750 _ C~ 1500_ Q) - 2250_ o~ _ ..i-- 3000_ _ 3750_ _ 4500_ I V -- 5250_ 6000_ 6750 _1500 - A I _ 750 I Z _ 750 SEC. 16, T11N, R8E TARGET 1VD=5888 TMD=13933 DEP=11875 NORTH 613 WEST 11859 N 2.96 DEG W 11875' (TO TAi~GET) ESTIMATED SURFACE LOCATION: 627' FSL, 53' FEL SEC. 14, T11N, RSE EST RKB ELEVATION: 135' t 500 KOP TVD=300 TMD=500 DEP=O 9:00 ' I AR 2 1996 2+.oo . ¢ 4 Anchora O EOC ~D:2110 mO:~O OE~='~O0 M~IMUM ANGLE 60 00 ~ s.os wo=~3, ~=~o~ o~v=~,o 71 39 DEG ~'~ ~/~" cs~ v~ w~=~74 mo=~,7 o~v=3~ ~ ~ TABASCO SNDS WD=5074 TMD=5700 DEP=41 58~ 9 DEP=4275 C50 ~D~8 TMD=9566 DEP=7826 C40 ~D=4601 TMD=10484 DEP=8696 C55 ~D=5155 TMD=12219 DEP=10541 BEGIN ANGLE DROP ~D=5554 TMD=12842 DEP=10931 C50 ~D=5521 TMD=15272 BEP=11527 %70.00 64 OD DROP 2 BEG / 100 C20 ~D=5725 TMD=15665 DEP=11661 ~64. , BASE HRZ ~D=5795 TMB=15781 DEP~1757 ~800 ~z~m *~T~T~ K-1 MARKER ~D=5824 TMD=13852 DEP=11797 ~00 t&Eb~l &t~bbb TOP UNIT C / EOB ~D=5874 TMD=13911 DEP=11858 B/ KUP SNDS ~D=6007 TMD=14118 DEP=12016 TD / 7" CSG 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 11250 12000 12750 Scale 1 : 575.00 Verficel Section on 272.96 ~zimufh with reference 0.00 N, 0.00 E from slot ~25 ,Creoted by : jones For: D PETRASH Dote plotted : 19-Mar-96 Plot Reference is 2,5 Version Coordinates ore in feet reference slot //25. True Ver~cal Depths <]re reference RKB (Perker /y245). ARCO ALASKA, Inc.i Structure : Pad 2A Well : 25 Field : Kuparuk River Unit Location : Nor'ih Slope, Alaska J RECEIVED A80 80 120 < West 600 560 520 480 440 400 560 520 280 240 200 160 120 80 40 0 40 80 ~u - / , 600 5rio 520 4gO 440 400 3~0 320 2gO 240 200 1 ~0 120 80 40 0 40 gO < W e s t soo,~ 1 - 20.00 Alaska 0il l Gas Cons. C0mmissb~ Anchorage Scole 1 : 20,00 160 _ _ 120 8o ~ ,, -- ~2o g Scale 1 ' ,50.00 200 100 o 100 g 200 _ .. _ u~ 300 2200 2100 2000 1900 1800 1700 1600 1500 1400 1500 1200 1100 1000 900 800 700 600 500 [ I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I . .~ PROPOSED % oo 5OO 400 _ 300 I 100 o 0 .. 2200 21 O0 2000 1900 1800 1700 1600 1500 1400 1500 1200 11 O0 1000 900 800 700 600 <-~ Wesf ~co,e~. ~o.oo - KUPARUK RIVER Urn;IT 20" DIVERTER SCHEMATIC 6 I4 3 2 O DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. , MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THATAN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) RECEIVED 1. 16"CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20"-2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. Alask~ 0il 8, Gas Cons. commission Anchorage 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. DKP 11/9~J4 ,' 13 5/8" 5000 P'SI BOP STACK 7 6 5 I 4 1. 16'-2000 PSI STARTING HEAD 2. 11' - 3000 PSI CASING HEAD 3. 11' - 3000 PSI X 13-5/8' - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8' -5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3, OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF, 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BO P STACK TE ST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BO'I-I'OM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL ACCOMODATE 3-1/2' TO 5-1/2' OR 5' TO 7' PIPE ODS AS APPROPRIATE. R£C IV£O MAR ?- ?- 1996 Oit & Gas Cons. Commission Anchorage WELL PERMIT CHECKLIST COMPANY /~-w INIT CLASS GEOL AREA PROGRAM~: exp [] dev~ .Iff redrll [] serv [] wellbore seg [] ON/OFFSHORE ADMINISTRATION ENGINEERING 1. Permit fee attached .................. Y 2. Lease number appropriate ............... Y 3. Unique well name and number .............. Y 4. Well located in a defined pool ............. Y 5. Well located proper distance from drlg unit boundary. .Y 6. Well located proper distance from other wells ..... Y 7. Sufficient acreage available in drilling unit ..... Y 8. If deviated, is wellbore plat included ........ Y 9. Operator only affected party ............... Y 10. Operator has appropriate bond in force .......... Y 11. Permit can be issued without conservation order .... Y 12. Permit can be issued without administrative approval...Y 13. Can permit be approved before 15-day wait ....... Y N N N N N N N N N N N N N 14. Conductor string provided ............... ~) N 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . . 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... .~ N 20. Adequate tankage or reserve pit ............ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip list adequate ~ N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to ~CC~D psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N REMARKS GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis of shallow gas zones .......... Y N 33. Seabed condition survey (if off-shore) ........ ~/~ N 34. Contact name/phone for weekly progress reports . . . ./. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMI SS ION: Comments/Instructions: Z O "tFORMS~,cheklist rev 11195 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. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA INC. WELL NAME : 2A - 25 FIELD NAME : KUPARUK RIVER UNIT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 501032023900 REFERENCE NO : 96382 * ALASKA COMPUTING CENTER * . . ****************************** * ............................ . ....... SCHLUMBERGER ....... . ............................ . ****************************** COMPANY NAME : ARCO ALASKA INC. WELL NAME : 2A - 25 FIELD NAME : KUPARUK RIVER UNIT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 501032023900 REFERENCE NO : 96382 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 19:~ PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/12/28 ORIGIN : FLIC REEL NAME : 96382 CONTINUATION # : PREVIOUS REEL '. CO~94ENT · ARCO ALASKA INC, 2A-25, KUPARUK, 50-103-20239-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/12/28 ORIGIN : FLIC TAPE NAME : 96382 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC, 2A-25, KUPARUK, 50-103-20239-00 TAPE HEADER KUPARUK RIVER UNIT CASED HOLE WIRELINE LOGS WELL NAME: 2A - 25 API ~rUMBER: 501032023900 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 28-DEC-96 JOB NUMBER: 96382 LOGGING ENGINEER: BAILEY OPERATOR WITNESS: GAR JORDAN SURFACE LOCATION SECTION: 14 TOWNSHIP: 1 iN RANGE: 8E FNL : FSL : 62 6 FEL: 53 FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: 135. O0 DERRICK FLOOR: 135. O0 GROUND LEVEL: 93.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 9. 625 5485.0 40. O0 2ND STRING 7. 000 14353. 0 26. O0 3RD STRING 3. 500 13860.0 9.30 PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 19:=~ BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: MWD LDWG CURVE CODE: GR RUN NOMBER : PASS NUMBER: 1 DATE LOGGED: 13-APR-96 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH .............. 88888.0 14173.5 14156.5 14142.5 14131.0 14107.0 14104.0 14086.5 14069.0 14068.5 14067.0 14058.0 14053.5 14052.5 14035.5 14032.0 14029.0 14028.5 14022.5 14020.0 14003.5 ! 4002.5 13998.0 13997.0 13987.5 13983.0 13976.0 13975.0 13969.0 13962.0 13951.0 13925.5 13914.0 13910.0 13893 5 13882 5 13880 0 13864 0 13860 5 100 0 $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH SIGM 88891.0 88891.5 14145.5 14111.5 14108.0 14088.5 14070.5 14055.5 14030.5 14023.5 14022.0 14004.0 13998.5 13984.5 13976.5 13970.0 13964.5 13952.0 13912.0 13895.5 13883.0 13861.5 101.0 14177.0 14160.0 14134.0 14088.5 14071.0 14069.0 14060.5 14055.0 14036.0 14033.5 14030.5 14021.5 14004.5 13998.5 13987.0 13975.5 13952.0 13928.5 13915.5 13883.0 13866.5 102.5 ~KS: The depth adjustments shown above reflect cased hole GR to open hole MWD GR and cased hole SIGM to open hole GR. All other TDTP curves were carried with the SIGM shifts. PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 19:=~ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE S~Y LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 14163 . 0 13860.0 TDTP 14188.0 13860.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: NONE PASS NUMBER '. BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP REMARKS: This file contains TDTP Pass #1 (Base Pass #1). pass to pass shifts were applied to this data. $ LIS FORMAT DATA * * DATA FORMAT SPECIFICATION RECORD * * * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 19:~ PAGE: TYPE REPR CODE VALUE 3 73 96 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100621 SIGM TDTP CU 100621 TPHI TDTP PU-S 100621 SBHF TDTP CU 100621 SBHN TDTP CU 100621 SIGC TDTP CU 100621 SIBH TDTP CU 100621 TRAT TDTP 100621 LCO! TDTP 100621 SDSI TDTP CU 100621 BACK TDTP CPS 100621 FBAC TDTP CPS 100621 TCAN TDTP CPS 100621 TCAF TDTP CPS 100621 TCND TDTP CPS 100621 TCFD TDTP CPS 100621 TSCN TDTP CPS 100621 TSCF TDTP CPS 100621 INND TDTP CPS 100621 INFD TDTP CPS 100621 GRCH TDTP GAPI 100621 TENS TDTP LB 100621 CCL TDTP V 100621 GR MWD GAPI 100621 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 19:=~ PAGE: DEPT. 14193.000 SIGM. TDTP -999.250 TPHI.TDTP SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP LCO1.TDTP -999.250 SDSI. TDTP -999.250 BACK. TDTP TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP GRCH. TDTP -999.250 TENS.TDTP -999.250 CCL.TDTP DEPT. 13700.000 SIGM. TDTP -999.250 TPHI.TDTP SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP LCO1.TDTP -999.250 SDSI.TDTP -999.250 BACK. TDTP TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP GRCH. TDTP -999.250 TENS. TDTP -999.250 CCL.TDTP -999. 250 SBHF. TDTP -999. 250 TRAT. TDTP -999. 250 FBAC. TDTP - 999.250 TCFD. TDTP -999. 250 INFD. TDTP -999.250 GR.MWD -999. 250 SBHF. TDTP -999. 250 TRAT. TDTP -999. 250 FBAC. TDTP - 999. 250 TCFD. TDTP -999. 250 INFD. TDTP -999.250 GR.MWD -999 250 -999 250 -999 250 -999 250 -999 250 102 902 -999.250 -999.250 -999.250 -999.250 -999.250 239.547 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION : O01CO1 DATE : 96/12/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION · O01CO1 DATE · 96/12/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CO~RVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 # FILE S~ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 14163.0 13860.0 TDTP 14188.0 13860.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 19:~ PA GE: CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 14171.5 14167.5 14163.5 14159.5 14155.5 14151.5 14147.5 14145.5 14148.5 14143.5 14133.5 14136.5 14131.5 14127.5 14123.5 14119.5 14115.5 14111.5 14107.5 14103.5 14099.5 14095.5 14093.5 14095.0 14091.5 14089.5 14091.0 14079.5 14075.5 14071.5 14067.5 14063.5 14061.5 14062.0 14059.5 14057.5 14058.0 14055.5 14053.5 14053.5 14049.5 14050.0 14047.5 14043.5 14039.5 14035.5 14027.5 14023.5 14021.5 14022.0 14019.5 14017.5 14017. $ 14015.5 14013.5 14014.0 14011.5 .......... EQUIVALENT UNSHIFTEDDEPTH GRCH TDTP 88891.0 88892.5 14176.0 14171.5 14168.0 14164.0 14159.0 14154.5 14150.5 14146.0 1413~.0 14130.5 14125.5 14121 5 14116 5 14113 0 14109 0 14105 5 14100 0 14095.5 14092.0 14080.0 14076.5 14072.0 14068.0 14063.0 14061.0 14056.5 14048.5 14045.0 14040.5 14037.0 14029.0 14025.5 14021.5 14016.5 14013.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 19:~1 PAGE: 14009.5 14005.5 14003.5 14001.5 13999.5 13997.5 13995.5 13993.5 13991.5 13987.5 13985 5 13983 5 13981 5 13979 5 13975 5 13971 5 13967 5 13965 5 13963 5 13961 5 13959 5 13957 5 13949 5 13947 5 13945 5 13943 5 13939 5 13929.5 13925.5 13921.5 13907.5 100.0 $ 14010.5 14006.5 14003.0 13999.5 13996.0 13988.0 13983.5 13967.5 13964.5 13959.5 13951.5 13947.0 13931.0 13927.5 13924.0 102.5 14005.0 14000.5 13996.0 13992.0 13987.5 13984.0 13979.5 13975.0 13971.5 13967.0 13963.5 13959.5 13947.0 13944.0 13939.5 13908.5 101.0 REMARKS: This file contains TDTP Pass #2 (Base Pass #2). The depth shifts shown above relect GRCH Pass #2 to GRCH Pass #1 and SIGM Pass #2 to SIGM Pass #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 92 4 66 1 5 66 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 19~1 PAGE: TYPE REPR CODE VALUE 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELM CODE (HEX) DEPT FT 100621 O0 000 O0 0 2 i 1 4 68 0000000000 SIGM TDTP CU 100621 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI TDTP PU-S 100621 O0 000 O0 0 2 1 1 4 68 0000000000 SBHF TDTP CU 100621 O0 000 O0 0 2 1 1 4 68 0000000000 SBHAV TDTP CU 100621 O0 000 O0 0 2 1 1 4 68 0000000000 SIGC TDTP CU 100621 O0 000 O0 0 2 1 1 4 68 0000000000 SIBH TDTP CU 100621 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT TDTP 100621 O0 000 O0 0 2 1 1 4 68 0000000000 LCO1 TDTP 100621 O0 000 O0 0 2 1 1 4 68 0000000000 SDSI TDTP CU 100621 O0 000 O0 0 2 1 1 4 68 0000000000 BACK TDTP CPS 100621 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC TDTP CPS 100621 O0 000 O0 0 2 1 1 4 68 0000000000 TCAN TDTP CPS 100621 O0 000 O0 0 2 1 1 4 68 0000000000 TCAF TDTP CPS 100621 O0 000 O0 0 2 1 1 4 68 0000000000 TCND TDTP CPS 100621 O0 000 O0 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 100621 O0 000 O0 0 2 1 1 4 68 0000000000 TSCNTDTP CPS 100621 O0 000 O0 0 2 1 1 4 68 0000000000 TSCF TDTP CPS 100621 O0 000 O0 0 2 1 1 4 68 0000000000 INND TDTP CPS 100621 O0 000 O0 0 2 1 1 4 68 0000000000 INFD TDTP CPS 100621 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH TDTP GAPI 100621 O0 000 O0 0 2 1 1 4 68 0000000000 TENS TDTP LB 100621 O0 000 O0 0 2 1 1 4 68 0000000000 CCL TDTP V 100621 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 14192. 500 SIGM. TDTP 40. 525 TPHI. TDTP 59. 861 SBHF. TDTP SBPIN. TDTP 48. 385 SIGC. TDTP O. 320 SIBH. TDTP 55. 952 TRAT. TDTP LCO1. TDTP 3. 671 SDSI. TDTP O. 904 BACK. TDTP 148. 491 FBAC. TDTP TCAN. TDTP 25344. 148 TCAF. TDTP 6857. 833 TCND. TDTP 17649. 098 TCFD. TDTP TSCN. TDTP 2062. 822 TSCF. TDTP 561. 992 INND. TDTP 1819. 412 INFD. TDTP GRCH. TDTP - 999. 250 TENS. TDTP 1295. 000 CCL. TDTP O. 000 44.783 1.835 39.176 4429.253 358.752 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 19:~1 PAGE: DEPT. 13861 . 000 SIGM. TDTP 39. 924 TPHI. TDTP 99. 693 SBHF. TDTP SBHN. TDTP 46. 841 SIGC. TDTP O. 000 SIBH. TDTP 52. 449 TRAT. TDTP LCO1. TDTP 6. 121 SDSI. TDTP 1. 673 BACK. TDTP 139.210 FBAC. TDTP TCAN. TDTP 24323.023 TCAF. TDTP 4100.432 TCND. TDTP 17515.039 TCFD. TDTP TSCN. TDTP 2212.200 TSCF. TDTP 361. 388 INND. TDTP 2069.242 INFD. TDTP GRCH. TDTP -999. 250 TENS. TDTP 1245. 000 CCL. TDTP O. 000 51.334 3.040 28.549 3302.176 373.613 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION - O01CO1 DATE : 96/12/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION · O01CO1 DATE · 96/12/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREM~IVT : O . 5000 FILE SO?4FLARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 14163.0 13860.0 TDTP 14188.0 13860.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS _NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 19:~1 PAGE: 10 BASELINE DEPTH 88888.0 14179.5 14167.5 14163.5 14159 5 14155 5 14151 5 14147 5 14139 5 14135 5 14131 5 14121 5 14113.5 14107.5 14103.5 14099.5 14095.5 14091.5 14087.5 14083.5 14079.5 14075.5 14073.5 14071.5 14067.5 14063.5 14059.5 14051.5 14047.5 14043.5 14035.5 14031.5 14027.5 14023.5 14019.5 14017.5 14015.5 14013 5 14011 5 14007 5 14005 5 14003 5 14001 5 13999.5 13995.5 13993.5 13991.5 13989.5 13987.5 13979.5 13975.5 13973.5 13971.5 GRCH ....... 88891.5 14125.0 14117.0 14075.5 14019.5 14016.0 14008.0 14004.5 13996.5 13992.0 13976.0 TDTP 88891.0 14182.5 14171.0 14166.5 14163.0 14158.5 14154.5 14150.0 14142.0 14138.5 14135.0 14111.0 14108.0 14103.0 14098 5 14094 0 14090 5 14086 0 14082 0 14078 5 14074.5 14070.0 14065.5 14062.0 14054.0 14051.0 14046.0 14038.0 14034.5 14030.0 14025.5 14021.0 14017.5 14013.5 14009.0 14004.5 14001.0 13997.0 13992.5 13988.0 13980.0 13975.5 13972.0 LIS Tape Vermfication Listing Schlumberger Alaska Computing Center 28-DEC-1996 19:~1 PAGE: 11 13969.5 13967.5 13963.5 13959.5 13955 5 13951 5 13937 5 13935 5 13933 5 100 0 $ 13971.5 13939.5 13936.0 102.5 13967.5 13964.0 13960.0 13955.5 13953.0 13938.5 103.0 REMARKS: This file contains TDTP Pass #3 (Base Pass #3). The depth shifts sho~m above relect GRCH Pass #3 to GRCH Pass #1 and SIGM Pass #3 to SIGM Pass #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100621 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM TDTP CU 100621 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI TDTP PU-S 100621 O0 000 O0 0 3 1 1 4 68 0000000000 SBHF TDTP CU 100621 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 19:~1 PAGE: 12 NAM~ SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) SBPiN TDTP CU 100621 O0 000 O0 0 3 1 1 4 68 0000000000 SIGC TDTP CU 100621 O0 000 O0 0 3 1 1 4 68 0000000000 SIBH TDTP CU 100621 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT TDTP 100621 O0 000 O0 0 3 1 1 4 68 0000000000 LCO1 TDTP 100621 O0 000 O0 0 3 1 1 4 68 0000000000 SDSI TDTP CU 100621 O0 000 O0 0 3 1 1 4 68 0000000000 BACK TDTP CPS 100621 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC TDTP CPS 100621 O0 000 O0 0 3 1 1 4 68 0000000000 TCAN TDTP CPS 100621 O0 000 O0 0 3 1 1 4 68 0000000000 TCA? TDTP CPS 100621 O0 000 O0 0 3 1 1 4 68 0000000000 TCND TDTP CPS 100621 O0 000 O0 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 100621 O0 000 O0 0 3 1 1 4 68 0000000000 TSCNTDTP CPS 100621 O0 000 O0 0 3 1 1 4 68 0000000000 TSCF TDTP CPS 100621 O0 000 O0 0 3 1 1 4 68 0000000000 INND TDTP CPS 100621 O0 000 O0 0 3 1 1 4 68 0000000000 INFD TDTP CPS 100621 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH TDTP GAPI 100621 O0 000 O0 0 3 1 1 4 68 0000000000 TENS TDTP LB 100621 O0 000 O0 0 3 1 1 4 68 0000000000 CCL TDTP V 100621 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 14191 . 000 SIGM. TDTP 41 . 202 TPHI. TDTP SBPiN. TDTP 48. 213 SIGC. TDTP O. 328 SIBH. TDTP LCO1. TDTP 3 . 706 SDSI. TDTP 1 . 008 BACK. TDTP TCAN. TDTP 24615. 586 TCAF. TDTP 6448. 987 TCND. TDTP TSCN. TDTP 1951. 909 TSCF. TDTP 526. 650 INND. TDTP GRCH. TDTP -999. 250 TENS. TDTP 1290. 000 CCL. TDTP 61 475 55 562 221 318 17086 371 1868 767 0 000 SBHF. TDTP TRAT. TDTP FBAC. TDTP TCFD. TDTP INFD. TDTP 42.442 1.862 55.730 4288.177 358.101 DEPT. 13862. 500 SIGM. TDTP -999. 250 TPHI. TDTP -999. 250 SBHF. TDTP ~ 999. 250 SBPiN. TDTP -999. 250 SIGC. TDTP -999. 250 SIBH. TDTP -999. 250 TRAT. TDTP - 999. 250 LCO1.TDTP -999.250 SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD.TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP - 999.250 GRCH. TDTP 1 O1. 750 TENS. TDTP - 999. 250 CCL. TDTP - 999. 250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 19:~1 PAGE: 13 **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION . O01CO1 DATE : 96/12/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION . 001 CO1 DATE : 96/12/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS .......................... 1, 2, 3 TDTP $ REMARKS: The arithmetic average of passes 1, 2 & 3 was computed after all depth shifts and clipping was applied. $ LIS FORMAT DATA * * DATA FORMAT SPECIFICATION RECORD * * * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 19:41 PAGE: 14 TYPE REPR CODE VALUE 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100621 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM PNAV CU 100621 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI PNAV PU-S 100621 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF PNAV CU 100621 O0 000 O0 0 4 1 1 4 68 0000000000 SBHNPNAV CU 100621 O0 000 O0 0 4 1 1 4 68 0000000000 SIGC PNAV CU 100621 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH PNAV CU 100621 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT PNAV 100621 O0 000 O0 0 4 1 1 4 68 0000000000 SDSI PNAV CU 100621 O0 000 O0 0 4 1 1 4 68 0000000000 BACK TDTP CPS 100621 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 100621 O0 000 O0 0 4 1 1 4 68 0000000000 TCAN PNAV CPS 100621 O0 000 O0 0 4 1 1 4 68 0000000000 TCAFPNAV CPS 100621 O0 000 O0 0 4 1 1 4 68 0000000000 TCND PNAV CPS 100621 O0 000 O0 0 4 1 1 4 68 0000000000 TCFD PNAV CPS 100621 O0 000 O0 0 4 1 1 4 68 0000000000 TSCN PNAV CPS 100621 O0 000 O0 0 4 1 1 4 68 0000000000 TSCF PNAV CPS 100621 O0 000 O0 0 4 1 1 4 68 0000000000 INND PNAV CPS 100621 O0 000 O0 0 4 1 1 4 68 0000000000 INFD PNAV CPS 100621 O0 000 O0 0 4 1 1 4 68 0000000000 LCO1 PNAV 100621 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH TDTP GAPI 100621 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 14191.500 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBHN. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI. PNAV -999.250 BACK. TDTP 95.701 FBAC. TDTP 29.935 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND. PNAV -999.250 TCFD.PNAV -999.250 TSCN. PNAV -999.250 TSCF. PNAV -999.250 INND.PNAV -999.250 INFD. PNAV -999.250 LCO1.PNAV -999.250 GRCH. TDTP -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 PAGE: 15 DEPT. 13861.000 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBHN. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND.PNAV -999.250 TCFD. PNAV -999.250 TSCN. PNAV -999.250 TSCF. PNAV -999.250 INND.PNAV -999.250 INFD.PNAV -999.250 LCO1.PNAV -999.250 GRCH. TDTP 82.750 ** END OF DATA ** **** FILE TRAILER **** FILE NARIE : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE . FLIC VERSION · O01CO1 DATE · 96/12/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE SUNk4ARY VENDOR TOOL CODE START DEPTH TDTP 14188.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : STOP DEPTH 13706.0 t -DEC- 96 44.2 1500 O1 -DEC-96 14192.0 14193.0 13700.0 14188.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 PAGE: 16 LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY TDTP TDTP SONDE TDTP TDTP CARTRIDGE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 1800.0 NO TOOL NUMBER ........... CGRS -A - 863 TND- P- 7 5 TNC-P-141 5485.0 BOREHOLE CONDITIONS FLUID TYPE '. FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : DIESEL~SEAWATER/DIES -20.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: TIED IN TO SWS CBL DATED 18-APR-96. LOG WAS RUN TO LOOK FOR A CHANNEL WITH TDT/BORAX. HOWEVER, FORMATION WOULD NOT TAKE FLUIDS WELL ENOUGH TO PUMP BORAX DOWN TO PERFORATIONS. RAN TDT LOG SINCE TOOLS WERE ALREADY DOWNHOLE. FLUIDS PUMPED: 30 BBLS DIESEL-->90 BBLS SEAWATER-->136 BBL NO ATTEMPT TO CHANGE TDT CONSTANTS IN TUBING. TDT NOT VAL ABOVE TUBING TAIL. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 19..~. PAGE: 17 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100621 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM PS1 CU 100621 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI PS1 PU 100621 O0 000 O0 0 5 i 1 4 68 0000000000 SBHF PS1 CU 100621 O0 000 O0 0 5 1 1 4 68 0000000000 SBHN PS1 CU 100621 O0 000 O0 0 $ 1 1 4 68 0000000000 SIGC PSi CU 100621 O0 000 O0 0 5 ! 1 4 68 0000000000 SIBH PS1 CU 100621 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT PS1 100621 O0 000 O0 0 5 1 1 4 68 0000000000 LCO1 PS1 100621 O0 000 O0 0 5 1 1 4 68 0000000000 SDSI PS1 CU 100621 O0 000 O0 0 5 1 1 4 68 0000000000 BACK PS1 CPS 100621 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC PS1 CPS 100621 O0 000 O0 0 5 1 1 4 68 0000000000 TCAN PS1 CPS 100621 O0 000 O0 0 5 t 1 4 68 0000000000 TCAFPS1 CPS 100621 O0 000 O0 0 $ 1 I 4 68 0000000000 TCND PS1 CPS 100621 O0 000 O0 0 $ 1 1 4 68 0000000000 TCFD PS1 CPS 100621 O0 000 O0 0 5 1 1 4 68 0000000000 TSCN PSi CPS 100621 O0 000 O0 0 5 1 1 4 68 0000000000 TSCF PS1 CPS 100621 O0 000 O0 0 5 1 1 4 68 0000000000 INND PSi CPS 100621 O0 000 O0 0 5 ! 1 4 68 0000000000 INFD PS1 CPS 100621 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS! LB 100621 O0 000 O0 0 $ 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 19. o~ PAGE: 18 NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) GR PS1 GAPI 100621 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PS1 V 100621 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 14193.000 SIGM. PS1 40.515 TPHI.PS1 60 SBHN. PS1 48.130 SIGC. PS1 0.197 SIBH. PS1 55 LCO1.PS1 0.278 SDSI.PS1 1.046 BACK. PSI 78 TCAN. PS1 25019.602 TCAF. PS1 6774.309 TCND.PS1 18133 TSCN. PS1 2143.898 TSCF. PS1 595.375 IN-ND.PSI 1939 TENS.PSi 1360.000 GR.PS1 48.531 CCL.PS1 0 DEPT. 13706.000 SIGM. PS1 43.053 TPHI.PS1 73. SBHN. PS1 56.952 SIGC. PS1 0.000 SIBH. PS1 75. LCO1.PS1 0.258 SDSI.PS1 1.067 BACK. PSI 99. TCAN. PS1 21574.363 TCAF. PS1 5321.222 TCND.PS1 14657. TSCN. PS1 1383.642 TSCF. PS1 356.912 INND.PS1 1777. TENS.PSi 1190.000 GR.PS1 122.938 CCL.PS1 O. 731 SBHF. PS1 374 TRAT. PS1 634 FBAC. PS1 539 TCFD.PS1 986 INFD.PS1 000 198 SBHF. PS1 386 TRAT. PS1 554 FBAC. PS1 143 TCFD. PS1 696 INFD. PS1 000 39. 873 1. 858 26.310 4484. 077 379. 927 50.956 1.890 25.532 3402.420 307.860 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE . FLIC VERSION · O01CO1 DATE : 96/12/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION · O01CO1 DATE : 96/12/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER RAW CURVES LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 19..~ PAGE: 19 Curves and log header data for each pass in separate files; raw background pass in last file PASS--ER: 2 DEPTH INCREMENT: 0.5000 FILE SO74MARY VENDOR TOOL CODE START DEPTH STOP DEPTH 14188.0 13706.0 TDTP $ LOG HEADER DATA DATE LOGGED: 1-DEC-96 SOFTWARE VERSION: 44.2 TIME LOGGER ON BOTTOM: 1500 O1-DEC-96 TD DRILLER (FT) : 14192.0 TD LOGGER (FT) : 14193.0 TOP LOG INTERVAL (FT) : 13700.0 BOTTOM LOG INTERVAL (FT) : 14188.0 LOGGING SPEED (FPHR): 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GR GAI~MA RAY CGRS- A - 863 TDTP TDTP SONDE TND- P- 75 TDTP TDTP CARTRIDGE TNC- P- 141 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 5485.0 DIESEL/SEA WA TER ~DIES -20.0 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 19. ~ PAGE: 2O BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: TIED IN TO SWS CBL DATED 18-APR-96. LOG WAS RUN TO LOOK FOR A CHANNEL WITH TDT/BORAX. HOWEVER, FORMATION WOULD NOT TAKE FLUIDS WELL ENOUGH TO PUMP BORAX DOWN TO PERFORATIONS. RAN TDT LOG SINCE TOOLS WERE ALREADY DOWNHOLE. FLUIDS PUMPED: 30 BBLS DIESEL-->90 BBLS SEAWATER-->136 BBL NO ATTEMPT TO CHANGE TDT CONSTANTS IN TUBING. TDT NOT VAL ABOVE TUBING TAIL. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100621 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM PS2 CU 100621 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI PS2 PU 100621 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 19:~ PAGE: 21 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SBHF PS2 CU 100621 O0 000 O0 0 6 1 1 4 68 0000000000 SBP~NPS2 CU 100621 O0 000 O0 0 6 1 1 4 68 0000000000 SIGC PS2 CU 100621 O0 000 O0 0 6 1 1 4 68 0000000000 SIBH PS2 CU 100621 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT PS2 100621 O0 000 O0 0 6 1 1 4 68 0000000000 LCO1 PS2 100621 O0 000 O0 0 6 1 1 4 68 0000000000 SDSI PS2 CU 100621 O0 000 O0 0 6 1 1 4 68 0000000000 BACK PS2 CPS 100621 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC PS2 CPS 100621 O0 000 O0 0 6 1 1 4 68 0000000000 TCANPS2 CPS 100621 O0 000 O0 0 6 1 1 4 68 0000000000 TCAFPS2 CPS 100621 O0 000 O0 0 6 1 1 4 68 0000000000 TCND PS2 CPS 100621 O0 000 O0 0 6 1 1 4 68 0000000000 TCFD PS2 CPS 100621 O0 000 O0 0 6 1 1 4 68 0000000000 TSCN PS2 CPS 100621 O0 000 O0 0 6 1 1 4 68 0000000000 TSCF PS2 CPS 100621 O0 000 O0 0 6 1 1 4 68 0000000000 INND PS2 CPS 100621 O0 000 O0 0 6 1 1 4 68 0000000000 INFD PS2 CPS 100621 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 100621 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 100621 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 100621 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 14193.000 SIGM. PS2 41.333 TPHI.PS2 54.067 SBHF. PS2 SBHN. PS2 46.817 SIGC. PS2 0.395 SIBH.PS2 52.395 TRAT. PS2 LCO!.PS2 3.465 SDSI.PS2 1.045 BACK. PS2 129.321 FBAC. PS2 TCAN. PS2 25808.344 TCAF. PS2 7143.270 TCND.PS2 17825.453 TCFD. PS2 TSCN. PS2 2046.796 TSCF. PS2 590.651 INND.PS2 1893.555 INFD. PS2 TENS.PS2 1315.000 GR.PS2 64.875 CCL.PS2 0.000 DEPT. 13704.500 SIGM. PS2 41.637 TPHI.PS2 65.844 SBHF. PS2 SBHN. PS2 57.065 SIGC. PS2 1.118 SIBH. PS2 75.644 TRAT. PS2 LCOi. PS2 3.630 SDSI.PS2 1.082 BACK. PS2 141.317 FBAC. PS2 TCAN. PS2 22373.543 TCAF. PS2 5707.390 TCND.PS2 14323.633 TCFD. PS2 TSCN. PS2 1325.698 TSCF. PS2 365.220 INND.PS2 1853.086 INFD. PS2 TENS. PS2 1180.000 GR.PS2 154.750 CCL.PS2 0.000 39.180 1.766 31.833 4530.135 376.597 50.748 1.765 32.124 3383.850 307.965 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 19:=~ PAGE: 22 **** FILE TRAILER **** FILE NAI~E : EDIT .006 SERVICE ' FLIC VERSION '.O01CO1 DATE : 96/12/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE '. FLIC VERSION · 0 O1 CO1 DATE : 96/12/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE N-UI~BER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCRE~iENT: 0.5000 FILE SUN2VARY VENDOR TOOL CODE START DEPTH STOP DEPTH 14188.0 13706.0 TDTP $ LOG HEADER DATA DATE LOGGED: 1 -DEC- 96 SOFTWARE VERSION: 44.2 TIME LOGGER ON BOTTOM: 1500 O1-DEC-96 TD DRILLER (FT) : 14192.0 TD LOGGER (FT) : 14193.0 TOP LOG INTERVAL (FT): 13700.0 BOTTOM LOG INTERVAL (FT) '. 14188.0 LOGGING SPEED (FPHR) : 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GR GA~gffA RAY CGRS-A-863 TDTP TDTP SONDE TND- P- 75 TDTP TDTP CARTRIDGE TNC- P- 141 BOREHOLE AND CASING DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 19:~ PAGE: 23 OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 5485.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG ) '. DIESEL~SEAWATER~DIES -20.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NOR2~IZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COErNT RATE LOW SCALE (CPS) : 0 FAR COUNT RATE HIGH SCALE (CPS): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): RE~IARKS: TIED IN TO SWS CBL DATED 18-APR-96. LOG WAS RUN TO LOOK FOR A CHANNEL WITH TDT/BORAX. HOWEVER, FORMATION WOULD NOT TAKE FLUIDS WELL ENOUGH TO PUMP BORAX DOWN TO PERFORATIONS. RAN TDT LOG SINCE TOOLS WERE ALREADY DOWNHOLE. FLUIDS PUMPED: 30 BBLS DIESEL-->90 BBLS SEAWATER-->136 BBL NO ATT~IPT TO CHANGE TDT CONSTANTS IN TUBING. TDT NOT VAL ABOVE TUBING TAIL. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 19:~ PAGE: 24 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 66 66 73 66 66 73 65 0 0 92 1 0.5 FT 11 1 2 3 4 5 6 7 8 68 9 65 11 66 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100621 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PS3 CU 100621 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PS3 PU 100621 O0 000 O0 0 7 1 1 4 68 0000000000 SBHF PS3 CU 100621 O0 000 O0 0 7 1 1 4 68 0000000000 SBI~NPS3 CU 100621 O0 000 O0 0 7 1 1 4 68 0000000000 SIGC PS3 CU 100621 O0 000 O0 0 7 1 1 4 68 0000000000 SIBH PS3 CU 100621 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PS3 100621 O0 000 O0 0 7 1 1 4 68 0000000000 LCO1 PS3 100621 O0 000 O0 0 7 1 1 4 68 0000000000 SDSI PS3 CU 100621 O0 000 O0 0 7 1 1 4 68 0000000000 BACK PS3 CPS 100621 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC PS3 CPS 100621 O0 000 O0 0 7 1 1 4 68 0000000000 TCANPS3 CPS 100621 O0 000 O0 0 7 1 1 4 68 0000000000 TCAFPS3 CPS 100621 O0 000 O0 0 7 1 1 4 68 0000000000 TCND PS3 CPS 100621 O0 000 O0 0 7 1 1 4 68 0000000000 TCFD PS3 CPS 100621 O0 000 O0 0 7 1 1 4 68 0000000000 TSCN PS3 CPS 100621 O0 000 O0 0 7 1 1 4 68 0000000000 TSCF PS3 CPS 100621 O0 000 O0 0 7 1 1 4 68 0000000000 INND PS3 CPS 100621 O0 000 O0 0 7 1 1 4 68 0000000000 INFD PS3 CPS 100621 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 100621 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 100621 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS3 V 100621 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 19:=~ PAGE: 25 ** DATA ** DEPT. 14193.000 SIGM. PS3 SBHN. PS3 47.855 SIGC.PS3 LCO1.PS3 3.878 SDSI.PS3 TCAN. PS3 26667.191 TCAF. PS3 TSCN. PS3 1963.680 TSCF. PS3 TENS.PS3 1275.000 GR.PS3 DEPT. 13705.500 SIGM. PS3 SBttN. PS3 59.262 SIGC.PS3 LCO1.PS3 3.675 SDSI.PS3 TCAN. PS3 22271.273 TCAF. PS3 TSCN. PS3 1340.167 TSCF. PS3 TENS.PS3 1205.000 GR.PS3 41.087 TPHI.PS3 0.291 SIBH. PS3 0.872 BACK. PS3 6895.374 TCND.PS3 506.331 INND.PS3 136.250 CCL.PS3 61.498 SBHF. PS3 54.750 TRAT. PS3 222.991 FBAC. PS3 17134.738 TCFD. PS3 1822.149 INFD.PS3 0.000 38.374 1.874 60.994 4211.559 340.836 42.798 TPHI.PS3 68.604 SBHF. PS3 47.883 0.292 SIBH. PS3 80.626 TRAT. PS3 1.776 1.038 BACK. PS3 164.745 FBAC. PS3 38.902 5765.328 TCND.PS3 14463.307 TCFD.PS3 3396.862 364.669 INND. PS3 1899.206 INFD. PS3 314.313 161.125 CCL.PS3 0.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE · FLIC VERSION · O01CO1 DATE : 96/12/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAM~ : EDIT DATE : 96/12/28 ORIGIN : FLIC TAPE NAME . 96382 CONTINUATION # : 1 PREVIOUS TAPE : COI~IENT : ARCO ALASK~ INC, 2A-25, KUPARUK, 50-103-20239-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 96/12/28 ORIGIN : FLIC REEL NAME : 96382 CONTINUATION # : PREVIOUS REEL COMPIENT : ARCO ALASKA INC, 2A-25, KUPARUK, 50-103-20239-00 * AI_J~SKA COMPUTING CENTER . ****************************** . ............................ * ....... SCHLUMBERGER ....... * ............................ ****************************** COMPANY NAME : ARCO ALASKA, INC. WELL NAME : 2A-25 FIELD NAME : KUPARUK RIVER BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-103-20239-00 REFERENCE NO : 96123 JUN 2 8 1995 Oil & G~ OOl~S, Commission Anchora§e * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA, INC. WELL NAME : 2A-25 FIELD NAME : KUPARUK RIVER BOROUGH : NORTH SLOPE STATE : ALASKA API i~73MBER : 50-103-20239-00 REFERENCE NO : 96123 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1996 13:23 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/06/19 ORIGIN . FLIC REEL NAME : 96123 CONTINUATION # .. PREVIOUS REEL : COGENT : ARCO ALASKA, INC., KUPARUK 2A-25, API # 50-103-20239-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/06/19 ORIGIN : FLIC TAPE NAME : 96123 CONTINUATION # : 1 PREVIOUS TAPE : COI~4ENT : ARCO ALASKA, INC., KUPARUK 2A-25, API# 50-103-20239-00 TAPE HEADER KUPARUK RIVER MWD/MAD LOGS WELL NAME: API N73MBER : OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION BIT RUN1 ......... 96123 ST. AMOUR WHITLOCK SECTION: TOWNSHIP: RANGE: FNL: FSL : FEL : FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 2A-25 501032023900 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 19-JUN-96 BIT RUN 2 96123 ST. AMOUR WHITLOCK BIT RUN 3 ......... 14 liN 8E 626 53 135.00 135.00 93.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 5484.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1996 13:23 3RD STRING PRODUCTION STRING Well drilled 08-APR through 13-APR-96 with CDR/CDN. All data was collected in two bit runs. MAD data was collected on bit run 2 for CDN only from 14043'-14135'. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/06/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUMBER: 1 EDITED I4ERGED MWD Clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUM2~4~Y LDWG TOOL CODE START DEPTH ......................... MWD 5392.0 $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH .............. $ MERGED DATA SOURCE LDWG TOOL CODE .............. $ REMARKS: No depth adjustments were made per Dave Shafer. This file also contains the Very Enhanced QRO resisitivity with 2' average that was reprocessed at GeoQuest. $ STOP DEPTH 14390.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... MWD BIT RUN NO. MERGE TOP MERGE BASE 1 5392.0 5686.0 2 5686.0 14390.0 LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1996 13:23 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630369 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD OHMM630369 O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD 0H~630369 O0 000 O0 0 1 1 1 4 68 0000000000 VRA MWD 0Pff4~630369 O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD OPff4~ 630369 O0 000 O0 0 1 1 1 4 68 0000000000 DER MWD OH~M630369 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 630369 O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR 630369 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 630369 O0 000 O0 0 1 1 1 4 68 0000000000 RHOBMWD G/C3 630369 O0 000 O0 0 1 1 1 4 68 0000000000 DRHOMWD G/C3 630369 O0 000 O0 0 1 1 1 4 68 0000000000 PEF MWD BN/E 630369 O0 000 O0 0 1 1 1 4 68 0000000000 CALNMWD IN 630369 O0 000 O0 0 1 1 1 4 68 0000000000 NPHIMWD PU-S 630369 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 14390.000 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD 265.695 FET.MWD GR.MWD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALN.MWD -999.250 NPHI.MWD -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1996 13:23 PAGE: DEPT. 5444.000 RA.MWD VRP.MWD -999.250 DER.MWD GR.MWD 48.350 RHOB.MWD CALN.MWD -999.250 NPHI.MWD -999.250 RP.MWD -999.250 ROP.MWD -999.250 DRHO.MWD -999.250 -999.250 -999.250 -999.250 VRA . MWD FET. MWD PEF. MWD -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION . O01CO1 DATE · 96/06/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 96/06/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NIIMBER: 2 EDITED MERGED MAD Clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... MAD 13944.0 14137.0 $ MERGED DATA SOURCE LDWG TOOL CODE .............. $ REMARKS: This file contains the MAD data collected on Bit Run #2 for CDN only. $ MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1996 13:23 PAGE: 5 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630369 O0 000 O0 0 2 1 1 4 68 0000000000 RHOBMAD G/C3 630369 O0 000 O0 0 2 1 1 4 68 0000000000 DRHOMAD G/C3 630369 O0 000 O0 0 2 1 1 4 68 0000000000 PEF MAD BN/E 630369 O0 000 O0 0 2 1 1 4 68 0000000000 CALNMAD F/HR 630369 O0 000 O0 0 2 1 1 4 68 0000000000 ROP MAD FPH~ 630369 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI MAD PU-S 630369 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 14137.000 RHOB.MAD -999.250 DRHO.MAD -999.250 PEF.MAD -999.250 CALN. MAD 42.453 ROP.MAD -999.250 NPHI.MAD -999.250 DEPT. 13944.000 RHOB.MAD -999.250 DRHO.MAD -999.250 PEF.MAD -999.250 CALN. MAD -999.250 ROP.MAD 37.200 NPHI.MAD -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1996 13:23 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/06/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/06/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NOY4~ER: 3 EDITED MAD PASSES Clipped curves; for each pass of each run in separate files. MAD RUNNUM~ER: 2 MAD PASS NUMBER: 1 DEPTH INCREME1TT: 0.5000 FILE SOI~IARY LDWG TOOL CODE START DEPTH MAD 13944.0 $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ STOP DEPTH .......... 14137.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... ....... This file contains MAD data collected on Bit Run #2 for CDN only. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1996 13:23 PAGE: 7 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630369 O0 000 O0 0 3 1 1 4 68 0000000000 RHOBMAD G/C3 630369 O0 000 O0 0 3 1 1 DRHOMAD G/C3 630369 O0 000 O0 0 3 1 1 PEF MAD BN/E 630369 O0 000 O0 0 3 1 1 CALNMAD F/HR 630369 O0 000 O0 0 3 1 1 ROP MAD FPHR 630369 O0 000 O0 0 3 1 1 NPHIMAD PU-S 630369 O0 000 O0 0 3 1 1 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 ** DATA ** DEPT. CALN. MAD 14137.000 RHOB.MAD -999.250 DRHO.MAD -999.250 PEF.MAD -999.250 42.453 ROP.MAD -999.250 NPHI.MAD -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1996 13:23 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/06/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 96/06/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ltrUM~ER 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 5392.0 5686.0 LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TI~IE) : TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (?T) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESISTIVITY CDN NEUT./DENS. $ 13-APR-96 FAST 2.5 4.0C MEMORY 14391.0 5387.0 5686.0 70 71.1 72.1 TOOL NUMBER RGS055 NDS057 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1996 13:23 PAGE: BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 8.500 5484.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G) '. 10.40 MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OH~) AT TEMPERATURE (DEGF) : MUD AT ~iEASURED TEMPERATURE (MT) .. 2. 930 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 2.640 MUD CAKE AT (MT): NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 1.0 EWR FREQUENCY (HZ): 20000 REMARKS: ************ RUN1 ************* DRILLED INTERVAL 5495' - 5869' RES TO BIT: 41.89'; GR TO BIT: 53.31' NEUT TO BIT: 104.16'; DENS TO BIT: 97.18' ************ RUN2 ************** DRILLED INTERVAL 5869' - 14391' NiEASO-REPOINTS SAME AS RUN1 WASHDOWNFROM 14043' - 14135' $ LIS FORMAT DATA 71.0 71.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 O. 5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1996 13:23 PAGE: 10 TYPE REPR CODE VALUE 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630369 O0 000 O0 0 4 1 1 4 68 0000000000 RA LW1 OH~ff~630369 O0 000 O0 0 4 1 1 4 68 0000000000 RP LW1 OHMM 630369 O0 000 O0 0 4 1 1 4 68 0000000000 DER LW1 OH~ 630369 O0 000 O0 0 4 1 1 4 68 0000000000 ROP LW1 FPHR 630369 O0 000 O0 0 4 1 1 4 68 0000000000 FET LW1 HR 630369 O0 000 O0 0 4 1 1 4 68 0000000000 GR LW1 GAPI 630369 O0 000 O0 0 4 1 1 4 68 0000000000 RHOB LW1 G/C3 630369 O0 000 O0 0 4 1 1 4 68 0000000000 DRHO LW1 G/C3 630369 O0 000 O0 0 4 1 1 4 68 0000000000 PEF LW1 BN/E 630369 O0 000 O0 0 4 1 1 4 68 0000000000 CALN LW1 IN 630369 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI LW1 PU-S 630369 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 5686.500 RA.LW1 -999.250 RP.LW1 -999.250 DER.LW1 ROP. LW1 306. 904 FET. LW1 - 999. 250 GR. LW1 - 999. 250 RHOB. LW1 DRHO.LW1 -999.250 PEF. LW1 -999.250 CALN. LW1 -999.250 NPHI.LW1 DEPT. 5387. 000 RA. LW1 -999. 250 RP. LW1 - 999. 250 DER. LW1 ROP.LW1 -999.250 FET. LW1 -999.250 GR.LW1 -999.250 RHOB.LW1 DRHO.LW1 -999.250 PEF. LW1 -999.250 CALN. LW1 -999.250 NPHI.LW1 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1996 13:23 PAGE: 11 **** FILE TRAILER **** FILE NA24E : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 96/06/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 96/06/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUHMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 5511 . 0 14390.0 LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MA~YIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESISTIVITY CDN NEUT./DENS. $ 13 -APR-96 FAST 2.5 4.0 MEMORY 14391.0 5511.0 14391.0 80 47.1 71.2 TOOL NUMBER RGS055 NDS057 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1996 13:23 PAGE: 12 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) .. 8.500 5484.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10. 40 MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OB?4~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 2. 930 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 2.640 MUD CAKE AT (MT): NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 1.0 EWR FREQUENCY (HZ): 20000 REMARKS: ************ RUN 1 ************* DRILLED INTERVAL 5495 ' - 5869 ' RES TO BIT: 41.89'; GR TO BIT: 53.31 ' NEUT TO BIT: 104.16'; DENS TO BIT: 97.18' ************ RUN 2 ************** DRILLED INTERVAL 5869' - 14391' MEASURE POINTS SAME AS RUN 1 WASHDOWN FROM 14043' - 14135' $ LIS FORMAT DATA 71.0 71.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 O. 5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1996 13:23 PAGE: 13 TYPE REPR CODE VALUE 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630369 O0 000 O0 0 5 1 1 4 68 0000000000 RA LW2 0H~630369 O0 000 O0 0 5 1 1 4 68 0000000000 RP LW2 0P~4~630369 O0 000 O0 0 5 1 1 4 68 0000000000 DER LW2 OH~M 630369 O0 000 O0 0 5 1 1 4 68 0000000000 ROP LW2 FPHR 630369 O0 000 O0 0 5 1 1 4 68 0000000000 FET LW2 HR 630369 O0 000 O0 0 5 1 1 4 68 0000000000 GR LW2 GAPI 630369 O0 000 O0 0 5 1 1 4 68 0000000000 RHOB LW2 G/C3 630369 O0 000 O0 0 5 1 1 4 68 0000000000 DRHO LW2 G/C3 630369 O0 000 O0 0 5 1 1 4 68 0000000000 PEF LW2 BN/E 630369 O0 000 O0 0 5 1 1 4 68 0000000000 CALNLW2 IN 630369 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI LW2 PU-S 630369 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 14390.500 RA.LW2 -999.250 RP.LW2 -999.250 DER.LW2 ROP.LW2 265. 695 FET. LW2 -999.250 GR.LW2 -999.250 RHOB.LW2 DRHO.LW2 -999.250 PEF. LW2 -999.250 CALN. LW2 -999.250 NPHI.LW2 DEPT. 5510.500 RA.LW2 -999.250 RP.LW2 -999.250 DER.LW2 ROP.LW2 -999.250 FET. LW2 -999.250 GR.LW2 -999.250 RHOB.LW2 DRHO.LW2 -999.250 PEF. LW2 -999.250 CALN. LW2 -999.250 NPHI.LW2 -999.250 -999.250 -999.250 -999.250 -999.250 43.400 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1996 13:23 PAGE: 14 **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 96/06/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 96/06/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LOG HEADER DATA FILE HEADER FILE NUMBER 6 RAW MAD Curves and log header data for each pass of each run in separate files. MAD RUN NUMBER: 2 MAD PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SU~ff4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 13944.0 14137.0 DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) '. TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESISTIVITY CDN NEUT./DENS. 13-APR-96 FAST 2.5 4.0 MEMORY 14391.0 13944.0 14137.0 80 47.0 49.0 TOOL NUMBER RGS055 NDS057 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1996 13:23 PAGE: 15 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 8.500 5484.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.40 MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OPff4~) AT TEMPERATURE (DEGF) : MUD AT ~SURED TEMPERATURE (MT): 2. 930 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 2.640 MUD CAKE AT (MT): NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 1.0 EWR FREQUENCY (HZ): 20000 DRILLED INTERVAL 5495' - 5869' RES TO BIT: 41.89'; GR TO BIT: 53.31' NEUT TO BIT: 104.16'; DENS TO BIT: 97.18' ************ RUN2 ************** DRILLED INTERVAL 5869' - 14391' I~EASURE POINTS SA~EAS RUN 1 WASHDOWNFROM 14043' - 14135' $ LIS FORMAT DATA 71.0 71.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 32 4 66 1 5 66 6' 73 7 65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1996 13:23 PAGE: 16 TYPE REPR CODE VALUE .............................. 8 68 0.5 9 65 FT 11 66 32 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630369 O0 000 O0 0 6 1 1 4 68 0000000000 RHOB MAI G/C3 630369 O0 000 O0 0 6 1 1 4 68 0000000000 DRHO MAI G/C3 630369 O0 000 O0 0 6 1 1 4 68 0000000000 PEF MAi BN/E 630369 O0 000 O0 0 6 1 1 4 68 0000000000 CALN MAi IN 630369 O0 000 O0 0 6 1 1 4 68 0000000000 ROP MAi FPHR 630369 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI MAi PU-S 630369 O0 000 O0 0 6 1 1 4 68 0000000000 GR MAi GAPI 630369 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 14138.500 RHOB.MA1 CALN. MA1 -999.250 ROP.MA1 DEPT. 13943.500 RHOB.MA1 CALN. MA1 -999.250 ROP.MA1 -999.250 DRHO.MA1 -999.250 PEF. MA1 -999.250 45.686 NPHI.MA1 -999.250 GR.MA1 -999.250 -999.250 DRHO.MA1 -999.250 PEF.MA1 -999.250 -999.250 NPHI.MA1 37.300 GR.MA1 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION · O01CO1 DATE : 96/06/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1996 13:23 PAGE: 17 **** TAPE TRAILER **** SERVICE NAME : EDIT DATE . 96/06/19 ORIGIN · FLIC TAPE NAME : 96123 CONTINUATION # : 1 PREVIOUS TAPE : CO~4ENT : ARCO ALASKA, INC., KUPARUK 2A-25, API# 50-103-20239-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 96/06/19 ORIGIN : FLIC REEL NAME : 96123 CONTINUATION # : PREVIOUS REEL : COGENT : ARCO ALASKA, INC., KUPARUK 2A-25, API # 50-103-20239-00
