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Home My WebLink About201-210Originated: Delivered to:8-Oct-25HalliburtonAlaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun333 West 7th Avenue, Suite 1006900 Arctic Blvd.Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPEDATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1B-06 50-029-20603-00 910356999 Kuparuk River Multi Finger Caliper Field & Processed 6-Oct-25 0 12 1B-06 50-029-20603-00 910356999 Kuparuk River Packer Setting Record Field- Final 7-Oct-25 0 13 1B-10 50-029-20656-00 910292758 Kuparuk River Leak Detect Log Field- Final 5-Sep-25 0 14 1B-10 50-029-20656-00 910292758 Kuparuk RiverMulti Finger CaliperField & Processed 1-Sep-25 0 15 1B-10 50-029-20656-00 910292758 Kuparuk River Plug Setting Record Field- Final 2-Sep-25 0 16 1E-36 50-029-22927-00 910357582 Kuparuk River Multi Finger Caliper Field & Processed 4-Oct-25 0 17 1E-36 50-029-22927-00 910293121 Kuparuk River Plug Setting Record Field- Final 8-Sep-25 0 18 1H-116 50-029-23594-00 910313707 Kuparuk River Multi Finger Caliper Field & Processed 22-Sep-25 0 19 1R-35 50-029-23050-00 910312848 Kuparuk River Leak Detect Log Field- Final 19-Sep-25 0 110 1R-35 50-029-23050-00 910312848 Kuparuk River Multi Finger Caliper Field & Processed 18-Sep-25 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:181-075181-135198-213218-012201-210T40969T40969T40970T40970T40970T40971T40971T49072T40973T490731R-3550-029-23050-00910312848Kuparuk RiverLeak Detect LogField- Final19-Sep-2501101R-3550-029-23050-00910312848Kuparuk RiverMulti Finger CaliperField & Processed18-Sep-2501Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.10.09 12:57:29 -08'00' 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 12630'feet 12297'feet true vertical 7008'feet None feet Effective Depth measured 12245'feet 11607', 11769'feet true vertical 6638'feet 6057', 6198'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth)3-1/2" L-80 11533' 5993' Packers and SSSV (type, measured and true vertical depth)11607' 11769' 6057' 6198' 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: 7923'4225' Burst Collapse Tie-Back String Liner 11936' 11794' Casing 6385' 6233' 11974' 11808' 12637'7015' 7882' 158'Conductor Surface Production 16" 9.625" 117' measured TVD 7" 5.5" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 201-210 50-029-23050-00-00 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: ADL0025627, ADL0025635 Kuparuk River Field/ Kuparuk Oil Pool KRU 1R-35 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) N/A Gas-Mcf MDSize 158' Well Shut-In 325-004 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: SLB Blue Pack Packer: BAKER ZXP Top Packer SSSV: None Leslie Manning leslie.manning@conocophillips.com (907) 263-3731Staff RWO/CTD Engineer 12194-12208', 12352-12392' 6590-6603', 6740-6779' 868'3.5" Fra O s 6. A PG , g 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 2:18 pm, Mar 28, 2025 DSR-4/2/25JJL 4/9/25 RBDMS JSB 040325 Page 1/5 1R-35 Report Printed: 3/27/2025 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) 2/27/2025 00:00 2/27/2025 08:00 8.00 MIRU, MOVE DMOB P 1D-pad Continue swapping bridal lines. 0.0 0.0 2/27/2025 08:00 2/27/2025 09:30 1.50 MIRU, MOVE DMOB P Warm up moving system. remove Move off 1D-133 stage at edge of pad. clear traffic start to mobilize to 1R-35 0.0 0.0 2/27/2025 09:30 2/27/2025 17:00 7.50 MIRU, MOVE MOB P Travel from 1D to 1R-35 0.0 0.0 2/27/2025 17:00 2/27/2025 21:00 4.00 MIRU, MOVE RURD P Hang tree in cellar, Spot well head eq. MIRU on 1R-35. Spot in pits, Start working rig acceptance checklist. 0.0 0.0 2/27/2025 21:00 2/27/2025 22:30 1.50 MIRU, MOVE RURD P PJSM, stand derrick up 0.0 0.0 2/27/2025 22:30 2/27/2025 23:30 1.00 MIRU, MOVE RURD P Bridle down and secure lines 0.0 0.0 2/27/2025 23:30 2/28/2025 00:00 0.50 MIRU, MOVE RURD P RU cellar and enterconnect, spot in cuttings tank RU heaters to tiger/kill tank. *** Note: Rig accept midnight 0.0 0.0 2/28/2025 00:00 2/28/2025 03:00 3.00 MIRU, MOVE RURD P Continue to RU pit module, while taking on 8.5 ppg SW into pits Finish RU cellar for well kill Pump open SSV Initial pressures T/IA/OA 0/0/0 0.0 0.0 2/28/2025 03:00 2/28/2025 03:30 0.50 MIRU, MOVE SEQP P PJSM. Fluid pack surface lines and test 2,500 psi. 0.0 0.0 2/28/2025 03:30 2/28/2025 03:45 0.25 MIRU, MOVE RURD P Blow down lines secure tanks. 0.0 0.0 2/28/2025 03:45 2/28/2025 06:15 2.50 MIRU, WELCTL KLWL P Circulated 534 BBL's 8.5# seawater at 4 BPM @1100 PSI. 0.0 0.0 2/28/2025 06:15 2/28/2025 06:45 0.50 MIRU, WELCTL OWFF P OWFF for 30 minutes 0PSI no flow at wellhead. 0.0 0.0 2/28/2025 06:45 2/28/2025 08:30 1.75 MIRU, WELCTL MPSP P Attempt to set BPV unable to engage leading thread on hanger profile. Ran no-go gauge on plug to confirm plug. Ran tap in hanger threads. Set BPV in hanger 53 STKS to pressure up to 1000PSI. Tested under BPV to 1000 PSI for 10 minutes. Continue to load pipe shed with 366 joints of DP strap and tally. 0.0 0.0 2/28/2025 08:30 2/28/2025 09:30 1.00 MIRU, WELCTL NUND P Bleed off adapter void, function test LDS. ND tree and adapter. 0.0 0.0 2/28/2025 09:30 2/28/2025 11:00 1.50 MIRU, WHDBOP NUND P NU DSA and BOP's. Install riser. 0.0 0.0 2/28/2025 11:00 2/28/2025 13:00 2.00 MIRU, WHDBOP RURD P RU floor to test BOP's Run Landing joints in stack and mark space out for each joint. RU testing quipment. Fill stack and function all rams HCR valves and annular. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 3/6/2025 Page 2/5 1R-35 Report Printed: 3/27/2025 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) 2/28/2025 13:00 2/28/2025 19:30 6.50 MIRU, WHDBOP BOPE P Start testing BOPE. Initial BOPE test, Tested BOPE at 250/3500 PSI for 5 Min each, Tested annular on 2-7/8" and 3-1/2" test joint, UVBR's, LVBR's w/2-7/8" and 3-1/2" test joints. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 3 1/2" HT- 38 safety valve, FOSV, and IBOP. Tested 3-1/2" EUE FOSV Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=1500 PSI, after closure=1500 PSI, 200 PSI attained =18 sec, full recovery attained = 140 sec. UVBR's= 6 sec, Annular= 20 sec. Simulated blinds= 6 sec. LVBR’s=6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2,075 PSI. Test gas detectors, PVT and flow show. Test Witness Waived by AOGCC rep Guy Cook 0.0 0.0 2/28/2025 19:30 2/28/2025 20:00 0.50 MIRU, WHDBOP RURD P RD and blowdown testing equipment 0.0 0.0 2/28/2025 20:00 2/28/2025 21:30 1.50 MIRU, WHDBOP RURD P Pickup T-bar and stand back Load landing joint into pipe shed and clean theads. Pull BPV, backout gland nuts 0.0 0.0 2/28/2025 21:30 2/28/2025 22:00 0.50 MIRU, WHDBOP PULL P BOLDS Pull hanger free 80k PUW 91k 0.0 0.0 2/28/2025 22:00 3/1/2025 00:00 2.00 MIRU, WHDBOP CIRC P Circulate SxS, 6.0 bpm/1,570 psi 0.0 0.0 3/1/2025 00:00 3/1/2025 01:00 1.00 MIRU, WHDBOP CIRC P Continue circulating 8.5 ppg SW, total 1,013 bbls w/deep clean pill 0.0 0.0 3/1/2025 01:00 3/1/2025 02:00 1.00 COMPZN, RPCOMP RURD P Prep RF for laying down tubing 0.0 0.0 3/1/2025 02:00 3/1/2025 14:30 12.50 COMPZN, RPCOMP PULL P Begin Laying Down 2.7/8" L-80 EUE-M tubing F/11,814' ORKB, 5 GLM, 368 jts of tubing Observe cut on last joint out of hole. LD Seal assembly and locator. 11,754.0 0.0 3/1/2025 14:30 3/1/2025 19:30 5.00 COMPZN, WELLPR BHAH P MU Cleanout/drift assembly w/6-1/4" OD OAL=262.75' 0.0 262.8 3/1/2025 19:30 3/1/2025 20:00 0.50 COMPZN, WELLPR SVRG P Service rig 262.8 262.8 3/1/2025 20:00 3/2/2025 00:00 4.00 COMPZN, WELLPR TRIP P Single in hole w/3.5" DP 262.8 5,998.0 3/2/2025 00:00 3/2/2025 02:00 2.00 COMPZN, WELLPR TRIP P Conitinue singling IH F/5998' T/7,915' hard set down Work pipe free, PUW=120k, SOW=82k 5,998.0 7,905.0 3/2/2025 02:00 3/2/2025 03:00 1.00 COMPZN, WELLPR WASH P Bring pump online 5.0 bpm/1,083' psi Work pipe 2-4k ROT=50 rpm, ROTQ=5,700 ft/lbs, ROTW=95k Make 2 passes with a clean dry drift. Top Drive at floor, still a little torque. 7,905.0 7,926.0 Rig: NABORS 7ES RIG RELEASE DATE 3/6/2025 Page 3/5 1R-35 Report Printed: 3/27/2025 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) 3/2/2025 03:00 3/2/2025 03:30 0.50 COMPZN, WELLPR WASH P MU another joint, continue to wash down ROT=50 rpm, ROTQ=4,800 ft/lbs, ROTW=93k 7,926.0 7,945.0 3/2/2025 03:30 3/2/2025 08:00 4.50 COMPZN, WELLPR PULD P Continue singling in the hole w/DP BHA #1 T/11759' tagged liner top. Set down 10K. 7,945.0 11,759.0 3/2/2025 08:00 3/2/2025 09:45 1.75 COMPZN, WELLPR CIRC P Circulate high vis sweep 4 BPM at 1700 PSI. 11,755.0 11,755.0 3/2/2025 09:45 3/2/2025 10:00 0.25 COMPZN, WELLPR OWFF P OWFF while blowing down lines and top drive. 11,755.0 11,755.0 3/2/2025 10:00 3/2/2025 15:30 5.50 COMPZN, WELLPR PULD P LD DP F/11759', PUW=138K SOW=70K T/4708' 111,759.0 4,708.0 3/2/2025 15:30 3/2/2025 16:15 0.75 COMPZN, WELLPR MPSP P MU Storm packer and storm valve single in to 110.56' COE' 103.80' top of twin thread. PUW=80K, SOW=70K 4,708.0 4,816.0 3/2/2025 16:15 3/2/2025 16:30 0.25 COMPZN, WELLPR RURD P MU wear ring R&R tool to joint of DP. Pull wear ring 4,816.0 3/2/2025 16:30 3/2/2025 17:30 1.00 COMPZN, WELLPR PRTS P Line up to pressure test. Circulate air out of lines. Close blind rams open HCR kill. Pressure test casing and storm packer to 1000 PSI for 10 minutes. 4,816.0 4,816.0 3/2/2025 17:30 3/2/2025 18:00 0.50 COMPZN, WELLPR BHAH P LD Storm packer setting tools. 4,816.0 4,816.0 3/2/2025 18:00 3/2/2025 20:00 2.00 COMPZN, WELLPR SVRG P Pull wear ring and install upper test plug. Replace UPR and LPR W/3.5” x 5.5” VBR’s. 4,816.0 4,816.0 3/2/2025 20:00 3/2/2025 22:00 2.00 COMPZN, WELLPR SVRG P Perform BWM 4,816.0 4,816.0 3/2/2025 22:00 3/3/2025 00:00 2.00 COMPZN, WELLPR MPSP P Test UPR and LPR on 3.5” and 5.5” and annular on 5.5” to 3500 PSI. 4,816.0 4,816.0 3/3/2025 00:00 3/3/2025 01:30 1.50 COMPZN, WELLPR MPSP P Continue testing UPR and LPR on 3.5” and 5.5” and annular on 5.5” to 3500 PSI. 4,816.0 4,816.0 3/3/2025 01:30 3/3/2025 02:00 0.50 COMPZN, WELLPR RURD P RD testing equipment, LD test joints, break down choke and kill lines, pump out stack Clean RF 4,816.0 4,816.0 3/3/2025 02:00 3/3/2025 02:30 0.50 COMPZN, WELLPR SVRG P Service Top Drive and washpipe 4,816.0 4,816.0 3/3/2025 02:30 3/3/2025 03:00 0.50 COMPZN, WELLPR TRIP P Install wear ring, pull test plug and install wear ring 4,816.0 4,816.0 3/3/2025 03:00 3/3/2025 04:30 1.50 COMPZN, WELLPR BHAH P MU Joint of DP, equilize and release storm packer Fill hole 6 bbls PUH and LD setting tool and packer. 4,816.0 4,816.0 3/3/2025 04:30 3/3/2025 08:00 3.50 COMPZN, WELLPR TRIP P TOOH, LD/DP F/4,816' T/BHA 4,816.0 262.8 3/3/2025 08:00 3/3/2025 10:00 2.00 COMPZN, WELLPR BHAH P LD BHA 262.8 0.0 3/3/2025 10:00 3/3/2025 10:30 0.50 COMPZN, WELLPR RURD P Pull wear ring 0.0 0.0 3/3/2025 10:30 3/3/2025 14:00 3.50 COMPZN, WELLPR RURD P Process 5.5" casing. RU rig floor to run casing. 0.0 0.0 3/3/2025 14:00 3/3/2025 14:30 0.50 COMPZN, WELLPR RURD P Verify running order in pipe shed 0.0 0.0 3/3/2025 14:30 3/3/2025 15:30 1.00 COMPZN, WELLPR SFTY P PJSM to run casing W/GBR SLB Nabors CPAI. discussed hazards and mitigations, roles and responsibilities . 0.0 0.0 3/3/2025 15:30 3/4/2025 00:00 8.50 COMPZN, WELLPR PUTB P PU 5.5" casing tie back string RIH F/surface T/8121' 0.0 8,121.0 Rig: NABORS 7ES RIG RELEASE DATE 3/6/2025 Page 4/5 1R-35 Report Printed: 3/27/2025 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) 3/4/2025 00:00 3/4/2025 04:30 4.50 COMPZN, WELLPR PUTB P PU 5.5" casing tie back string RIH F/surface T/11,810' 8,121.0 11,810.0 3/4/2025 04:30 3/4/2025 06:30 2.00 COMPZN, WELLPR PUTB P Pump down F/11,751' 1 bpm @ 300 psi, observe 200 psi increase as seals enter SBE @ 11,793.53' shut down pump, continue IH T/11,810' w/15k down on SBE, PUT= neutral weight, PUW=180k 11,805.65', LD Joint 280, MU pup joints 10.44' and 7.81' 5.5" collar 14.16' below WH. 11,810.0 11,807.8 3/4/2025 06:30 3/4/2025 08:00 1.50 COMPZN, WELLPR CIRC P Circulate 8.5 ppg Inhitbited Seawater 110 bbls 2.5 bpm/Inital pressure 840 psi Final circ pressurse 940 psi 11,807.8 11,807.8 3/4/2025 08:00 3/4/2025 08:30 0.50 COMPZN, WELLPR PUTB P PU Joint #279, with pups 10.44' and 7.81', TIH T/11,810', PUH 11,807.8' 11,807.8 11,807.8 3/4/2025 08:30 3/4/2025 09:00 0.50 COMPZN, WELLPR PRTS P Pump down the 5.5" and test 1,000 psi for 10 mins on chart 11,807.8 11,807.8 3/4/2025 09:00 3/4/2025 10:00 1.00 COMPZN, WELLPR PRTS P Bring pressure up to 3,650', hold for 30 mins. RD testing equipment 11,807.8 11,807.8 3/4/2025 10:00 3/4/2025 13:00 3.00 COMPZN, RPCOMP MPSP P MU 5.5" RBP. PU and RIH with 3.5" new tubing joints and set RBP COE at 159' PT RBP to 1000 psi for 10 minutes. Good test. 11,807.8 11,807.8 3/4/2025 13:00 3/4/2025 15:00 2.00 COMPZN, RPCOMP OWFF P Watch 7" x 9-5/8" annulus for flow. Diminishing diesel returns for 1.5 hrs then observed 30 minute no flow. 11,807.8 11,807.8 3/4/2025 15:00 3/4/2025 16:00 1.00 COMPZN, RPCOMP NUND P Break bolts on DSA/Test Spool. Change out API ring on Kill LIne. PU stack two feet. ND BOP stack. Set slips in bowl W/50K over string weight. RU Wachs cutter and cut 5-1/2" casing. 11,807.8 0.0 3/4/2025 16:00 3/4/2025 20:00 4.00 COMPZN, RPCOMP NUND P Install packoffs, NU new tubing spool, test packoffs. NU BOPE, install test plug and test flange breaks T/sundry 0.0 0.0 3/4/2025 20:00 3/5/2025 00:00 4.00 COMPZN, RPCOMP NUND P NU BOPE, install test plug and test flange breaks T/sundry 0.0 0.0 3/5/2025 00:00 3/5/2025 01:30 1.50 COMPZN, WHDBOP PRTS P Pressure test BOP, RU test pump, obtain shell test, test break on stand and kill line 250/3500 psi, good test. RD testing equipment, 0.0 0.0 3/5/2025 01:30 3/5/2025 02:00 0.50 COMPZN, WHDBOP MPSP P Pull test plug 0.0 0.0 3/5/2025 02:00 3/5/2025 02:30 0.50 COMPZN, WHDBOP PRTS P Test Tiger tank line T/2,500 psi. *** Note: RU LRS to displace 5.5" x 7" and 9-5/8" to 8.5 CI. Freeze protect w/100 bbls down the 5.5" x 7" Hook up hole to allow U-tube. 0.0 0.0 3/5/2025 02:30 3/5/2025 03:00 0.50 COMPZN, WHDBOP MPSP P RU to pull RBP from 159' Trip in hole, Equilize and release plug 0.0 159.0 3/5/2025 03:00 3/5/2025 03:30 0.50 COMPZN, WHDBOP MPSP P Trip out of hole, LD plug and 3-1/2" tubing 159.0 0.0 3/5/2025 03:30 3/5/2025 04:00 0.50 COMPZN, WHDBOP SFTY P PJSM w/crews 0.0 0.0 3/5/2025 04:00 3/5/2025 18:00 14.00 COMPZN, WHDBOP PUTB P Run 3.5", L-80, 9.3#, EUEM completion per approved tally. F/surface T/no-go 11,535.7 w/5k SO 0.0 11,535.7 Rig: NABORS 7ES RIG RELEASE DATE 3/6/2025 Page 5/5 1R-35 Report Printed: 3/27/2025 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) 3/5/2025 18:00 3/5/2025 20:30 2.50 COMPZN, WHDBOP PUTB P Observe seals enter top of SBE, No-go out at the bottom of SBE @ 11,535.7'. Set down 5K to confirm x 2. L/D 3 joints, P/U space out pups, and P/U one full joint of tubing. P/U tubing hanger and M/U to string. Lower pipe in hole T/11,508' 11,535.7 11,508.0 3/5/2025 20:30 3/5/2025 21:00 0.50 COMPZN, WHDBOP PUTB P Lower hanger to RF, MU head pin to pup joints. 11,508.0 11,508.0 3/5/2025 21:00 3/5/2025 23:00 2.00 COMPZN, WHDBOP DISP P Line up and circulate 230 bbls of 8.5 ppg CI. 11,508.0 11,508.0 3/5/2025 23:00 3/6/2025 00:00 1.00 COMPZN, WHDBOP PUTB P Land hanger, RILDS and torque to spec as per wellhead rep 11,508.0 11,533.7 3/6/2025 00:00 3/6/2025 02:00 2.00 COMPZN, WHDBOP PRTS P Line up to pressure test down the tubing 3,000 psi, (good test) bleed pressure down to 1,500 psi, Pressure test down the IA 2,500 psi, bleed pressure to 2,000 psi, dump tubing to shear SOV *** Note: pressure dumped slowly, we have a partial shear, circulate 1.75 bpm/2,650 psi. Circulate 10 bbls. Will notify LRS when we freeze protect. 0.0 0.0 3/6/2025 02:00 3/6/2025 03:00 1.00 DEMOB, MOVE RURD P RD testing equipment, Back out landing joint, Set and test BPV (CIW H-plug) 0.0 0.0 3/6/2025 03:00 3/6/2025 06:00 3.00 DEMOB, MOVE RURD P Swap UPR to 2-7/8" x 5" ND BOPE 0.0 0.0 3/6/2025 06:00 3/6/2025 10:00 4.00 DEMOB, MOVE RURD P NU tubing head adapter NU 3-1/8" 5k tree Test hanger and tree to 5k Clean pits Work pre-move checklist 0.0 0.0 3/6/2025 10:00 3/6/2025 12:00 2.00 DEMOB, MOVE FRZP P RU LRS, freeze protect well with 50 bbls down the tubing RD LRS MU 2" hose and allow to U-tube. RD hose. Complete pre-move checklist 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 3/6/2025 Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: RKB 12,208.0 1R-35 3/25/2025 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Install post rig GLD, pull RHC, Open CMU, Pull HEX plug, update tag depth 1R-35 3/25/2025 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: Dump Bail 4' CaCO3 on Plug 10/18/2013 osborl Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR1615.06 41.0 158.0 158.062.58 API5LGrB PEB SURFACE 9 5/88.83 40.5 7,922.6 4,224.9 40.00 L-80 BTC PRODUCTION 7 6.28 38.4 11,973.8 6,384.7 26.00 L-80 BTC-MOD Tie-Back String 5.5x3.5" at 11534' 5 1/2 4.95 13.7 11,807.8 6,232.7 15.50 L-80 563 LINER 3 1/2 2.99 11,769.1 12,637.0 9.30 L-80 SLHT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth… 11,532.7 String Max No… 3 1/2 Set Depth… 5,993.3 Tubing Description Tubing – Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 36.3 36.2 0.11 Hanger 10.860 FMC Gen 5 11" x 3-1/2" 5K EUE 8rd x EUE 8rd tubing hanger FMC TC1A- EMS 2.900 3,725.1 2,521.9 64.02 GLM 4.727 3.5" x 1" KBG2-9 GLM IBT x IBT SLB KBG 2-9 2.818 5,818.23,373.166.67 GLM 4.727 3.5" x 1" KBG2-9 GLM IBT x IBT SLB KBG 2-92.818 7,876.7 4,206.1 65.59 GLM 4.727 3.5" x 1" KBG2-9 GLM IBT x IBT SLB KBG 2-9 2.818 10,777.3 5,424.2 51.35 GLM 4.727 3.5" x 1" KBG2-9 GLM IBT x IBT SLB KBG 2-9 2.818 11,461.1 5,933.1 33.46 Nipple - X 4.500 2.813" HES X nipple HES 2.813 2.813 11,514.0 5,977.5 32.42 Locator 4.490 Baker locator Baker Baker 2.970 11,514.8 5,978.2 32.40 Seal Assembly 3.980 Baker 80-40 Seal assembly Baker Baker 2.970 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,889.5 4,211.4 65.68 LEAK - CASING PC LEAK IDENTIFIED AT 7889.5' VIA ACOUSTIC LDL 11/11/2024 0.000 12,296.8 6,687.3 16.67 NIPPLE REDUCER 2.75" NIPPLE REDUCER SET IN LINER NIPPLE 10/16/2013 2.250 12,296.86,687.316.67PLUG2.25" CA-2 PLUG SET IN NIPPLE REDUCER 10/18/2013 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 3,725.1 2,521.9 64.02 1 GAS LIFT GLV BTM 1 1,210.0 3/21/2025 CAMCO KBG-2-9 0.188 5,818.2 3,373.1 66.67 2 GAS LIFT GLV BTM 1 1,250.0 3/20/2025 CAMCO KBG-2-9 0.250 7,876.7 4,206.1 65.59 3 GAS LIFT OVBTM 1 3/20/2025CAMCOKBG-2-90.250 10,777.3 5,424.2 51.35 4 DV BTM 3/5/2025CAMCOKBG-2-9 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 13.7 13.7 0.04Paker 245 ORKB to MLDS 36.21' 7ES RKB to MLDS=24.57' 0.000 Paker 245 ORKB to MLDS 36.21' 7ES RKB to MLDS=24.57' 0.000 11,513.7 5,977.232.43 XO Threads 5.500 5.5" 15.5# L-80 Hydril 563 box x 5.5" 15.5# L-80 Hydril 521 pin XO N/A N/A 4.950 11,515.4 5,978.7 32.39 PBR 5.030 Baker 80-40 SBE Baker Baker 4.000 11,550.1 6,008.0 31.69 Mandrel – GAS LIFT 4.730 3.5" KBG 2-9 GLM S#24410-07 DV installed SLB KBG 2-9 2.818 11,607.7 6,057.330.82 Packer 6.2763.5" x 7" SLB Blue pack packer SLB SLB 2.885 11,665.2 6,106.9 29.93 Sleeve - Sliding 4.260 Baker CMU sliding sleeve W/2.81" BX nipple profile ***OPENED 03-19-25*** Baker "BX" Profile CMU 2.813 11,721.4 6,155.9 28.49 Nipple - X 4.503 2.813" X nipple HES 2.81" "X" 2.810 11,770.0 6,198.9 27.21 Locator 4.500 Baker Mechanical locator assembly Baker2.992 11,769.16,198.127.24PACKER 5.980 BAKER ZXP TOP PACKER w/ HR PROFILE 4.400 11,787.0 6,214.1 26.75 NIPPLE 5.520 BAKER RS NIPPLE w/ COLLAR 4.250 11,819.8 6,243.4 25.86 XO THREAD 5.030 2.970 12,296.86,687.316.67 NIPPLE 4.520 HALLIBURTON XN NIPPLE W/ 2.75" NO GO; 2.813" BORE - 2.75" NIPPLE REDUCER w/2.25" ID SET 10/16/2013 2.250 12,541.4 6,922.6 14.68 LANDING COLLAR 4.280 2.960 1R-35, 3/27/2025 10:48:43 AM Vertical schematic (actual) LINER; 11,769.1-12,637.0 APERF; 12,352.0-12,392.0 PLUG; 12,296.8 NIPPLE REDUCER; 12,296.8 IPERF; 12,194.0-12,208.0 FRAC; 12,194.0 PRODUCTION; 38.4-11,973.8 Tie-Back String 5.5x3.5" at 11534'; 13.7-11,807.8 Seal Assembly; 11,514.8 Nipple - X; 11,461.1 GLM; 10,777.3 SURFACE; 40.5-7,922.6 GLM; 7,876.7 GLM; 5,818.2 GLM; 3,725.1 CONDUCTOR; 41.0-158.0 Hanger; 36.3 KUP PROD KB-Grd (ft) 42.30 RR Date 12/10/200 1 Other Elev… 1R-35 ... TD Act Btm (ftKB) 12,630.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292305000 Wellbore Status PROD Max Angle & MD Incl (°) 68.76 MD (ftKB) 6,523.29 WELLNAME WELLBORE Annotation Last WO: End Date 3/7/2025 H2S (ppm) 25 Date 9/10/2016 Comment SSSV: NIPPLE Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 12,194.0 12,208.0 6,589.7 6,602.9 C-1, 1R-35 4/21/2002 6.0 IPERF 2.5" Powerjet 12,352.0 12,392.0 6,740.2 6,778.6 A-5, A-4, A-3, 1R -35 4/3/2004 6.0 APERF 2" HSD, 60 deg phase 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) 12,194.0 12,208.0 1 FRAC 11/8/2002 0.00.00 0.00 1R-35, 3/27/2025 10:48:45 AM Vertical schematic (actual) LINER; 11,769.1-12,637.0 APERF; 12,352.0-12,392.0 PLUG; 12,296.8 NIPPLE REDUCER; 12,296.8 IPERF; 12,194.0-12,208.0 FRAC; 12,194.0 PRODUCTION; 38.4-11,973.8 Tie-Back String 5.5x3.5" at 11534'; 13.7-11,807.8 Seal Assembly; 11,514.8 Nipple - X; 11,461.1 GLM; 10,777.3 SURFACE; 40.5-7,922.6 GLM; 7,876.7 GLM; 5,818.2 GLM; 3,725.1 CONDUCTOR; 41.0-158.0 Hanger; 36.3 KUP PROD 1R-35 ... WELLNAME WELLBORE 1 Gluyas, Gavin R (OGC) From:Lau, Jack J (OGC) Sent:Wednesday, February 5, 2025 2:27 PM To:AOGCC Records (CED sponsored) Subject:PTD 201-210 [EXTERNAL]RE: Tieback Completion Design for Failed Casing Isolation From: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Sent: Wednesday, February 5, 2025 2:17 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Dodson, Kate <Kate.Dodson@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com> Subject: RE: [EXTERNAL]RE: Tieback Completion Design for Failed Casing Isolation Jack, Greg forwarded on your request for more information regarding the 1R-35 RWO well type. I appreciate you framing your ask in a table so that it was easier for my team to give you the exact information you are requesting. Our additions to the table are bolded for easy reference. Give me a call if there are any additional questions. E Erica Livingston Intervention & Integrity Supervisor, P.E. | ConocoPhillips Alaska +1 907 854 6886 (cell) ekappel@conocophillips.com Risk Assessed Mitigations Frequency Threshold/Trigger 1. The IA, OA & OOA have a pressure transmitter to alert operations of abnormal trends. Realtime Abnormal pressure trends. OA & OOA have an operating pressure limit of 1000 psi (OA > 1000 psi indicates a potential gas lift leak via IAxOA). 2. Alternating every 2-years: Tubing integrity fluid level (TIFL), and mechanical integrity test of the tubing (MITT) which includes the short section of tubing below the new tieback and new packer Annually, alternating MITT and TIFL Pass / Fail. 2 3. Obtain OA and OOA fluid levels. Annually If the OA fluid level has dropped out more than 200'. From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Tuesday, February 4, 2025 12:12 PM To: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: [EXTERNAL]RE: Tieback Completion Design for Failed Casing Isolation CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Greg – I’ll give you a call to discuss. The full team met today to discuss single barrier wells and the 1R-35 sundry application. A single barrier is only acceptable if tested, verified, and risk- mitigated. The mitigations provided should include testing frequency, trigger thresholds, and threshold actions. This will tie the sundry to industry practices and our regulations. I have included an example with the red text indicating the gaps for ConocoPhillips to address. We can approve as soon as this is completed. Was a risk assessment performed for operating this well with a single barrier? If so, would you be willing to share it? Risk Assessed Mitigations Frequency Threshold/Trigger 1. The OA has a pressure transmitter to alert operations of abnormal trends. Realtime What well specific OA and OOA pressure would indicate potential flow? 2. Alternating every 2-years: Tubing integrity fluid level (TIFL), and mechanical integrity test of the tubing (MITT) which includes the short section of tubing below the new tieback and new packer Annually, alternating MITT and TIFL Pass / Fail. 3. Annual OA and OOA fluid levels. ? ? 3 Thanks, Jack From: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Sent: Thursday, January 30, 2025 9:55 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: Tieback Completion Design for Failed Casing Isolation Jack, Thank-you for your call last Friday regarding the 1R-35 sundry application. You wanted more detail on the timing of pressure and fluid level monitoring for this completion and background regarding our completion approach for similar wells. This completion (see attached schematic) is appropriate because it establishes isolation, allows for monitoring, and provides flexibility for future recompletions or repairs. This approach establishes isolation in compliance with regulatory requirement 20 AAC 25.200. As noted in the meeting last week, this producer recompletion design also protects the failed original intermediate or production casing from lift gas pressure with the tieback, is fully monitorable for integrity, and can be pulled and replaced in the event of an integrity loss of its envelope. This design allows long term production of the asset with future repair options that would be eliminated by cementing or packer options. This design has been internally reviewed and risk assessed. Responsive to your question about monitoring, the following integrity compliance monitoring and testing is performed: 1. The OA has a pressure transmitter to alert operations of abnormal trends. 2. Alternating every 2-years: Tubing integrity fluid level (TIFL), and mechanical integrity test of the tubing (MITT), which includes the short section of tubing below the new tieback. 3. Annual OA and OOA fluid levels. We will advise you if our monitoring plans or policies for these recompletions change in the future. Please do not hesitate to reach out if you have any further questions. Greg Greg Hobbs, P.E. Regulatory Engineer | Wells Team ConocoPhillips Alaska Inc. Office: 907-263-4749 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. 4 Cell: 907-231-0515 <1R-35_2024_RWO_Prop_Schematic 5.5 in Tie-back.pdf> ORIGINATED TRANSMITTAL DATE: ALASKA E-LINE SERVICES TRANSMITTAL #: 5254 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5254 1R-35 50029230500000 Plug Setting Record 19-Jan-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 201-210 T40021 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.28 10:07:21 -09'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ORIGINATED TRANSMITTAL DATE: 1/27/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5259 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5259 1R-35 50029230500000 Tubing Cut Record 22-Jan-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 201-210 T40020 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.28 09:58:59 -09'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number): 10. Field: Kuparuk Oil Pool Kuparuk Oil Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 12630 2038 None Casing Collapse Conductor Surface Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. W ell Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: 907-263-3731 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Baker ZXP Top Packer SSSV: None 7008' 12245' 6638'11729', 12297' KRU 1R-35 12194-12208' 12352-12392' 11936' 3.5" 6590-6603' 6740-6779' 7882' 11974' Perforation Depth MD (ft): 2/11/2025 12637'868' 2-7/8" 7008' 158' 7923' 6385'7" 16" 9-5/8" 117' Burst 11814' MD 158' 4225' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025627, ADL0025635 201-210 P.O. Box 100360, Anchorage, AK 99510 50-029-23050-00-00 ConocoPhillips Alaska, Inc Proposed Pools: AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 11769'MD/6198'TVD Perforation Depth TVD (ft): Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size Kuparuk River Field Leslie Manning leslie.manning@conocophillips.com CTD/RWO Engineer Subsequent Form Required: Suspension Expiration Date: L-80 TVD Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov -DQ 325-004 By Samantha Coldiron at 2:46 pm, Jan 08, 2025 X Witnessed BOP to 3500 psi and Annular Test to 2500 psi. Operator shall operate well per " risk assessed single barrier mitigation table" attachment. 10-404 SFD 1/21/2025 DSR-1/8/25JJL 2/5/25 *&: 2/5/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.02.05 15:52:23 -09'00' RBDMS JSB 020625 Risk Assessed Mitigations Frequency Threshold/Trigger Action Abnormal pressure trends.Further diagnostics to verify well integrity still exists. OA & OOA have an operating pressure limit of 1000 psi (OA > 1000 psi indicates a potential gas lift leak via IAxOA). Confirmation of IAxOA communication voids the risk assessment and allowance for gas lift. A failing IF[ reŗuires the well to be repaired within 1͓ days or the well must be secured.Ϛ A failing MIT, which cannot be repaired, requires the well to be secured. Further diagnostics to verify well integrity still exists. Confirmation of IAxOA communication voids the risk assessment and allowance for gas lift. Single Barrier Risk Assessed Mitigations 3. Obtain O anî OO ċīŪiî īôŽôīŜ.Ϛ Annually If the OA fluid level has dropped out more than 200'. ͐. Ϛēô IA, OA & OOA ēave a pressure transmitter to alert operations of abnormal trends. Realtime ͑. AlternatinČ everƅ ͑ϱƅearsϡ ubinČ inteČritƅ fluid level ϼI>[ϽϠ and meèēanièal inteČritƅ test of tēe tubinČ ϼaIϽ ſēièē inèludes tēe sēort seètion of tubinČ beloſ tēe neſ tiebaèħ and neſ paèħer AnnuallƅϠ alternating aI and I>[ ass ϯ >ail. P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 7, 2025 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Leslie Manning Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Producer 1R-35 (PTD# 201-210). Well 1R-35 is a producer drilled in 2001 and completed with 3.5" tubing and liner and 7" casing. Tubing leaks have been identified at 7017' MD, 7374' MD, and 7390' MD. Production casing leaks have been identified at 7072' MD and 7888' MD. Therefore, a RWO is needed to pull the tubing and repair the leak. The RWO plan is to pull the tubing then isolate the 7" casing with a 5.5" tieback liner, then run 3.5" tubing. 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Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 36.2 36.2 0.11 HANGER 10.840 FMC TUBING HANGER FMC CPAI PN: MM 1061993 9, FMC gen5, FMC# P120191 -0002 2.992 70.9 70.9 0.22 XO Reducing 4.550 3-1/2" 9.3# L-80 EUE-m box x 2- 7/8"6.5# EUE pin crossover 2.441 531.1 529.88.50 NIPPLE 3.703 CAMCO 'DS' NIPPLE Camco PN: 134232, SN: T091162 2.312 3,903.4 2,594.867.14 GAS LIFT 4.750Camco 2-7/8" x 1" KBMG PN: 100164401, Ser # 330AE03 WFT KBMG2.347 6,910.5 3,799.667.79GAS LIFT 4.750Camco 2-7/8" x 1" KBMG PN: 100164401, Ser # 330AE03 WFT KBMG2.347 9,134.4 4,705.165.78GAS LIFT 4.750Camco 2-7/8" x 1" KBMG PN: 100164401, Ser # 330AE03 Camco KBMG2.347 10,649.2 5,347.0 54.55 GAS LIFT 4.750Camco 2-7/8" x 1" KBMG PN: 100164401, Ser # 330AE03 Camco KBMG2.347 11,306.6 5,806.136.33 GAS LIFT 4.750Camco 2-7/8" x 1" KBMG PN: 100164401, Ser # 330AE03 WFT KBMG2.347 11,674.36,114.829.70GAS LIFT 4.750Camco 2-7/8" x 1" KBMG PN: 100164401, Ser # 330AE03 Camco KBMG2.347 11,729.5 6,163.028.28 NIPPLE 3.660 HALLIBURTON 'X' NIPPLE Camco X-line, M10000 5672 2.313 11,776.26,204.4 27.04LOCATOR4.500BAKER LOCATOR (above locate)Baker 2.980 11,777.06,205.227.02 LOCATOR 3.990 BAKER LOCATOR (below locate)Baker 2.980 11,802.5 6,228.026.32 SEAL ASSY 3.990 BAKER 80-40 BONDED SEAL ASSEMBLY Baker PN: H450-01 -4081 & H06- 57870- 00 2.980 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,017.03,841.965.91 LEAK - TUBING TUBING LEAK(S) BRACKETED WITH HOLEFINDER 7222'-7017' 5/28/2024 2.440 7,374.0 3,992.1 65.15 LEAK - TUBING Leaks at 7374'6/4/2019 2.440 7,390.0 3,998.8 65.15 LEAK - TUBING Leaks at 7390'6/4/2019 2.440 7,888.0 4,210.8 65.67 LEAK - CASING PC LEAK IDENTIFIED AT 7888' VIA ACOUSTIC LDL 11/11/2024 6.280 11,720.3 6,155.0 28.52 OTHER 2-7/8" BAIT SUB (28") & PRONG (77"), OAL = 105" 10/3/2024 0.000 11,729.0 6,162.6 28.29 TUBING PLUG 2.313" PX PLUG W/ EXT (OAL = 48") 10/3/2024 0.000 12,296.8 6,687.3 16.67 NIPPLE REDUCER 2.75" NIPPLE REDUCER SET IN LINER NIPPLE 10/16/2013 2.250 12,296.8 6,687.3 16.67 PLUG 2.25" CA-2 PLUG SET IN NIPPLE REDUCER 10/18/20130.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 3,903.4 2,594.867.14 1 GAS LIFT DMY BK 1 10/19/2024 Schlumb erger Camco 1R-35, 11/12/2024 4:33:49 PM Vertical schematic (actual) LINER; 11,769.1-12,637.0 SHOE; 12,635.1-12,637.0 LANDING COLLAR; 12,541.4- 12,542.5 APERF; 12,352.0-12,392.0 NIPPLE; 12,296.8-12,298.4 PLUG; 12,296.8 NIPPLE REDUCER; 12,296.8 IPERF; 12,194.0-12,208.0 FRAC; 12,194.0 PRODUCTION; 38.4-11,973.8 FLOAT SHOE; 11,972.4- 11,973.8 FLOAT COLLAR; 11,888.7- 11,890.0 SBE; 11,799.8-11,819.7 SEAL ASSY; 11,802.5 HANGER; 11,789.7-11,799.8 SPACE OUTS 2.96" ID; 11,777.5 NIPPLE; 11,787.0-11,789.7 PACKER; 11,769.1-11,787.0 LOCATOR; 11,777.0 LOCATOR; 11,776.2 TUBING PLUG; 11,729.0 NIPPLE; 11,729.5 OTHER; 11,720.3 GAS LIFT; 11,674.3 GAS LIFT; 11,306.6 GAS LIFT; 10,649.2 GAS LIFT; 9,134.4 SURFACE; 40.5-7,922.6 FLOAT SHOE; 7,920.9-7,922.6 LEAK - CASING; 7,888.0 FLOAT COLLAR; 7,840.0- 7,841.5 LEAK - TUBING; 7,390.0 LEAK - TUBING; 7,374.0 LEAK - TUBING; 7,017.0 GAS LIFT; 6,910.5 GAS LIFT; 3,903.4 PORT COLLAR; 1,096.0- 1,098.7 NIPPLE; 531.1 CONDUCTOR; 41.0-158.0 HANGER; 40.5-42.0 HANGER; 38.4-40.4 HANGER; 36.2 KUP PROD KB-Grd (ft) 42.30 RR Date 12/10/200 1 Other Elev… 1R-35 ... TD Act Btm (ftKB) 12,630.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292305000 Wellbore Status PROD Max Angle & MD Incl (°) 68.76 MD (ftKB) 6,523.29 WELLNAME WELLBORE Annotation Last WO: End Date 10/29/2013 H2S (ppm) 25 Date 9/10/2016 Comment SSSV: NIPPLE 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) 6,910.5 3,799.6 67.79 2 GAS LIFT DMY BK 1 10/19/2024 9,134.4 4,705.1 65.78 3 GAS LIFT DMY BK 1 7/6/20190.000 10,649.2 5,347.0 54.55 4 GAS LIFT DMY BK 1 7/6/2019Schlumb erger Camco 0.000 11,306.6 5,806.136.33 5 GAS LIFT DMY BK 1 6/22/2015 0.000 11,674.36,114.829.70 6 GAS LIFT OPEN BK 1 10/4/2024 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 11,769.1 6,198.1 27.24 PACKER 5.980 BAKER ZXP TOP PACKER w/ HR PROFILE 4.400 11,787.0 6,214.1 26.75 NIPPLE 5.520 BAKER RS NIPPLE w/ COLLAR 4.250 11,819.8 6,243.4 25.86 XO THREAD 5.030 2.970 12,296.8 6,687.3 16.67 NIPPLE 4.520 HALLIBURTON XN NIPPLE W/ 2.75" NO GO; 2.813" BORE - 2.75" NIPPLE REDUCER w/2.25" ID SET 10/16/2013 2.250 12,541.4 6,922.6 14.68 LANDING COLLAR 4.280 2.960 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 12,194.0 12,208.0 6,589.7 6,602.9 C-1, 1R-35 4/21/2002 6.0 IPERF 2.5" Powerjet 12,352.0 12,392.06,740.26,778.6 A-5, A-4, A-3, 1R -35 4/3/2004 6.0 APERF 2" HSD, 60 deg phase 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) 12,194.0 12,208.0 1 FRAC 11/8/2002 0.00.00 0.00 1R-35, 11/12/2024 4:33:49 PM Vertical schematic (actual) LINER; 11,769.1-12,637.0 SHOE; 12,635.1-12,637.0 LANDING COLLAR; 12,541.4- 12,542.5 APERF; 12,352.0-12,392.0 NIPPLE; 12,296.8-12,298.4 PLUG; 12,296.8 NIPPLE REDUCER; 12,296.8 IPERF; 12,194.0-12,208.0 FRAC; 12,194.0 PRODUCTION; 38.4-11,973.8 FLOAT SHOE; 11,972.4- 11,973.8 FLOAT COLLAR; 11,888.7- 11,890.0 SBE; 11,799.8-11,819.7 SEAL ASSY; 11,802.5 HANGER; 11,789.7-11,799.8 SPACE OUTS 2.96" ID; 11,777.5 NIPPLE; 11,787.0-11,789.7 PACKER; 11,769.1-11,787.0 LOCATOR; 11,777.0 LOCATOR; 11,776.2 TUBING PLUG; 11,729.0 NIPPLE; 11,729.5 OTHER; 11,720.3 GAS LIFT; 11,674.3 GAS LIFT; 11,306.6 GAS LIFT; 10,649.2 GAS LIFT; 9,134.4 SURFACE; 40.5-7,922.6 FLOAT SHOE; 7,920.9-7,922.6 LEAK - CASING; 7,888.0 FLOAT COLLAR; 7,840.0- 7,841.5 LEAK - TUBING; 7,390.0 LEAK - TUBING; 7,374.0 LEAK - TUBING; 7,017.0 GAS LIFT; 6,910.5 GAS LIFT; 3,903.4 PORT COLLAR; 1,096.0- 1,098.7 NIPPLE; 531.1 CONDUCTOR; 41.0-158.0 HANGER; 40.5-42.0 HANGER; 38.4-40.4 HANGER; 36.2 KUP PROD 1R-35 ... WELLNAME WELLBORE COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top)Thread (btm) Conductor 158 158 16 15.06 62.58 API5LGrB PEB PEB Surface 7,922.60 4,224.90 9.625 8.83 40 L-80 BTC BTC Production/ Intermediate 11,973.80 6,384.70 7 6.28 26 L-80 BTC-MOD BTC-MOD Liner 12,637 7,015 3.5 2.99 9.3 L-80 SLHT SLHT Tie-Back Liner ~11,745 6,177 5.5 4.95 26 L80 HYD563 MS HYD563 MS Tubing ~11,600 6,051 3.5 2.99 9.3 L80 HYD563 HYD563 1R-35 Proposed RWO Completion (Cut & Pull Tbg - 5-1/2" Tie-back to address PC Leak) PROPOSED 5-1/2" TIE-BACK LINER 5-1/2" 15.5# L-80 HYD563 MS Casing to Surface PBR to recieve 80-40 seal assembly 3-1/2" x 1" GLM 3-1/2" x 7" Packer 3-1/2" X Nipple Profile (2.813" min ID) 2-7/8" Non-sealing Overshot PROPOSED COMPLETION 3-1/2" 9.3# L-80 HYD563 tubing to surface 3-1/2" x 1" GLMs 3-½" X Nipple (2.813" min ID) 80-40 Locator Seal Assembly REMAINING COMPLETION LEFT IN HOLE Baker ZXP Packer @ 11,769' RKB (4.4" ID) RS nipple @ 11,787' RKB (4.250" ID) XO @ 11,820' RKB (2.970" ID) XN Nipple @ 12,297' RKB (2.960" ID) 9-5/8" OD Surface Casing 7923' MD 7" OD Production Casing 11,974' MD 16" OD Conductor 158' MD A-sand perfs 12,352 - 12,392' MD Isolated w/ Plug C-Sand Perfs 12,194 - 12,208' MD 3-1/2" OD Liner 12,637' MD From:Livingston, Erica J To:Lau, Jack J (OGC) Cc:Hobbs, Greg S; Dodson, Kate; Livingston, Erica J; Coberly, Jonathan Subject:RE: [EXTERNAL]RE: Tieback Completion Design for Failed Casing Isolation Date:Wednesday, February 5, 2025 2:16:57 PM Jack, Greg forwarded on your request for more information regarding the 1R-35 RWO well type. I appreciate you framing your ask in a table so that it was easier for my team to give you the exact information you are requesting. Our additions to the table are bolded for easy reference. Give me a call if there are any additional questions. E Erica Livingston Intervention & Integrity Supervisor, P.E. | ConocoPhillips Alaska +1 907 854 6886 (cell) ekappel@conocophillips.com Risk Assessed Mitigations Frequency Threshold/Trigger Action 1. The IA, OA & OOA have a pressure transmitter to alert operations of abnormal trends. Realtime Abnormal pressure trends. OA & OOA have an operating pressure limit of 1000 psi (OA > 1000 psi indicates a potential gas lift leak via IAxOA). Further diagnostics to verify well integrity still exists. Confirmation of IAxOA communication voids the risk assessment and allowance for gas lift. 2. Alternating every 2-years: Tubing integrity fluid level (TIFL), and mechanical integrity test of the tubing (MITT) which includes the short section of tubing below the new tieback and new packer Annually, alternating MITT and TIFL Pass / Fail. A failing TIFL requires the well to be repaired within 14 days or the well must be secured. A failing MIT, which cannot be repaired, requires the well to be secured. 3. Obtain OA and OOA fluid levels. Annually If the OA fluid level has dropped out more than 200'. Further diagnostics to verify well integrity still exists. Confirmation of IAxOA communication voids the risk assessment and allowance for gas lift. From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Tuesday, February 4, 2025 12:12 PM To: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: [EXTERNAL]RE: Tieback Completion Design for Failed Casing Isolation CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Greg – I’ll give you a call to discuss. The full team met today to discuss single barrier wells and the 1R-35 sundry application. A single barrier is only acceptable if tested, verified, and risk-mitigated. The mitigations provided should include testing frequency, trigger thresholds, and threshold actions. This will tie the sundry to industry practices and our regulations. I have included an example with the red text indicating the gaps for ConocoPhillips to address. We can approve as soon as this is completed. Was a risk assessment performed for operating this well with a single barrier? If so, would you be willing to share it? Risk Assessed Mitigations Frequency Threshold/Trigger Action 1. The OA has a pressure transmitter to alert operations of abnormal trends. Realtime What well specific OA and OOA pressure would indicate potential flow?? 2. Alternating every 2-years: Tubing integrity fluid level (TIFL), and mechanical integrity test of the tubing Annually, 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. (MITT) which includes the short section of tubing below the new tieback and new packer alternating MITT and TIFL Pass / Fail.? 3. Annual OA and OOA fluid levels. ??? Thanks, Jack From: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Sent: Thursday, January 30, 2025 9:55 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: Tieback Completion Design for Failed Casing Isolation Jack, Thank-you for your call last Friday regarding the 1R-35 sundry application. You wanted more detail on the timing of pressure and fluid level monitoring for this completion and background regarding our completion approach for similar wells. This completion (see attached schematic) is appropriate because it establishes isolation, allows for monitoring, and provides flexibility for future recompletions or repairs. This approach establishes isolation in compliance with regulatory requirement 20 AAC 25.200. As noted in the meeting last week, this producer recompletion design also protects the failed original intermediate or production casing from lift gas pressure with the tieback, is fully monitorable for integrity, and can be pulled and replaced in the event of an integrity loss of its envelope. This design allows long term production of the asset with future repair options that would be eliminated by cementing or packer options. This design has been internally reviewed and risk assessed. Responsive to your question about monitoring, the following integrity compliance monitoring and testing is performed: 1. The OA has a pressure transmitter to alert operations of abnormal trends. 2. Alternating every 2-years: Tubing integrity fluid level (TIFL), and mechanical integrity test of the tubing (MITT), which includes the short section of tubing below the new tieback. 3. Annual OA and OOA fluid levels. We will advise you if our monitoring plans or policies for these recompletions change in the future. Please do not hesitate to reach out if you have any further questions. Greg Greg Hobbs, P.E. Regulatory Engineer | Wells Team ConocoPhillips Alaska Inc. Office: 907-263-4749 Cell: 907-231-0515 <1R-35_2024_RWO_Prop_Schematic 5.5 in Tie-back.pdf> C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2024-11-09_16012_KRU_1R-35_VividLeakDetectLog_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 16012 KRU 1R-35 50-029-23050-00 VIVID Leak Detect Log 09-Nov-24 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 201-210 T39838 12/6/2024 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.12.06 11:07:45 -09'00' C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2024-10-20_22625_KRU_1R-35_Caliper Survey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22625 KRU 1R-35 50-0229-23050-00 Caliper Survey w/ Log Data 20-Oct-24 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 201-210 T39711 10/23/2024 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.10.23 13:04:23 -08'00' Originated: Delivered to:9-Jul-24 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET# 1 1H-10 50-029-22346-00 909358839 Kuparuk River Patch Setting Record Field- Final 27-May-24 0 1 2 1H-104 50-029-23610-00 909292908 Kuparuk River Leak Detect Log with ACX Field & Processed 22-Apr-24 0 1 3 1L-06 50-029-21164-00 n/a Kuparuk River Leak Detect Log Field- Final 7-May-24 0 1 4 1L-06 50-029-21164-00 909298478 Kuparuk River Multi Finger Caliper Field & Processed 8-May-24 0 1 5 1L-06 50-029-21164-00 n/a Kuparuk River Plug Setting Record Field- Final 7-May-24 0 1 6 1L-24 50-029-22170-00 909422478 Kuparuk River Multi Finger Caliper Field & Processed 4-Jul-24 0 1 7 1L-24 50-029-22170-00 909422478 Kuparuk River Patch Setting Record Field- Final 6-Jul-24 0 1 8 1R-35 50-029-23050-00 909353301 Kuparuk River Multi Finger Caliper Field & Processed 29-May-24 0 1 9 2A-14 50-103-20040-00 909382630 Kuparuk River Patch Setting Record Field- Final 13-Jun-24 0 1 10 2B-11 50-029-21089-00 n/a Kuparuk River Plug Setting Record Field- Final 11-May-24 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: T39155 T39156 T39157 T39157 T39157 T39158 T39158 T39159 T39160 T39161 193-030 218-084184-133 191-066201-210 185-145184-035 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.10 13:13:09 -08'00' 191 066201-210 185 145 1R-35 50-029-23050-00 909353301 Kuparuk River Multi Finger Caliper Field & Processed 29-May-24 0 1 T39159 WELL LOG TRANSMITTAL #905823296 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 1R-35 Run Date: 7/7/2019 20 1210 31128 August 21, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1R-35 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-23050-00 RECEIVED AUG 2 7 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: ( 7 Signed: 7. Property Designation (Lease Number): STATE OF ALASKA R E C ENE D 8. Well Name and Number: KRU 1R-35 ALASKA OIL AND GAS CONSERVATION COMMISSION 10. Field/Pool(s): 11. Present Well Condition Summary: REPORT OF SUNDRY WELL OPERATIONS JUL 1 7 measured 12,297 feet true vertical 7,008 feet Junk 2019 1. Operations Performed: Abandon ❑ Plug Perforations Fracture Stimulate ❑ g ❑ ❑ Pull O shutdown ❑ true vertical 6,228 feet Casin Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing[] �erations CfAd o am ❑ Ar.:.1e 2. Operator Plug for Redrill ❑ 'erforate New Pool ❑ Repair Well ❑� Re-enter Susp Well ❑ Other: Tubing Patch ❑� Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. 3. Address: Development Q Exploratory ❑ P. O. Box 100360, Anchorage, Alaska Stratigraphic ❑ Service F-16. API Number: 201-210 Perforation depth Measured depth 12194-12208 & 12352-12392 feet 99510 True Vertical depth 6490-6603 & 6740-6779 feet 7. Property Designation (Lease Number): DU-UL`J -L3UbU-VU ADL0025627/ADL0025636 8. Well Name and Number: KRU 1R-35 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Ku aruk River Field / Ku aruk River Oil Pool Total Depth measured 12,630 feet Plugs 9 measured 12,297 feet true vertical 7,008 feet Junk measured None feet Effective Depth measured 12,245 feet Packer measured 11,803 feet true vertical 6,638 feet true vertical 6,228 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 117 feet 16" 158' MD 158' TVD SURFACE 7,882 feet 9 5/8 " 7,923' MD 4,225' TVD PRODUCTION 11,935 feet 7 11,974' MD 6,385' TVD LINER 868 feet 3 1/2 " 12,637' MD 7,008' TVD Perforation depth Measured depth 12194-12208 & 12352-12392 feet True Vertical depth 6490-6603 & 6740-6779 feet Tubing (size, grade, measured and true vertical depth) 2.875 L-80 11,776' MD 6,204' TVD Packers and SSSV (type, measured and true vertical depth) SEAL ASSY -BAKER 80-40 BONDED SI 11,803' MD 6,228' TVD Nipple - Camco "DS" Nipple 531' MD 530' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Prior to well operation: Water -Bbl Casing Pressure Tubing Pressure Subsequent to operation: '114.Attachments (required per 20 AAC 25.070, 25.071, & 25283) 15. Well Class after work: Daily Report of Well Operations ❑ Exploratory ❑ Development Q Service ❑ ❑ SUatigraphic and Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 21 Printed and Gas ❑ WDSPL ❑ Fracture Stimulation Data ❑ GSTOR E]WINJ ❑ WAG E:1GINJ ❑ SUSP ❑ SPLUG E]17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Authorized Name: Dusty Freeborn Contact Name: Dusty Freeborn / Jan Byrne Authorized Title: Well Integrity & Compliance Specialist Contact Email: N1617@conocophillips.com Authorized Signature:Date: 14 July 19 Contact Phone: 907-659-7224 Form 10-404 Revised 4/2017 �'`�l /i RBDMS JUS 18 2019 Submit Original Only ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 14, 2019 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 patch set across a known tubing leak in producer KRU 1R-35 (PTD 201-210). Please contact Jan Byrne or myself at 659-7224 if you have any questions. Sincerely, Z�� Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. 07/08/1 07/07/1 IR -35 DESCRIPTION OF WORK COMPLETED SUMMARY 3 SECT P2P (#CPP287041), SPACER PIPE, ANCHOR LATCH (#CPAL287032) MID-ELEM @ 7369' RKB. MITT TO 2500 (PASS) & SPACER, TO 2500 (PASS) JOB COMPLETE g PULLED 2.31" XX PLUG @ 11,729' RKB. BRUSHED & FLUSHED TBG F/ 7300'- 7500' RKB. DRIFTED TO 7500' RKB W/ 2.29" DMY PATCH ASSY. SET 2.29" P2P (#CPP287042) MID- ELEM @ 7399' RKB. CMIT TO 2500 (PASS). IN PROGRESS. 06/05/19 PERFORM BASELINE TEMPERATURE PASS, LOG UP LOOKING FOR LEAK. LRS PUMPING 1.0 BBL/MIN @ 2000 PSI. LEAK FOUND AT 7374' & 7390', PERFORM STATION SURVEYS @ 7520', 7510', 7500', 7390', 7380', 7370'. PERFORM UP/DOWN PASSES OVER INTERVAL 7250'- 7650'@ 80 FPM. 06/03/19 (AC EVAL) LL R TA ESTABLISHED LLR OF 10.5 GPM (COMPLETE). 04/08/19 (AC EVAL) : PROACTIVE TIFL FAILED DUE TO IA INFLOW. ConocoPhillips Alaska, Inc. Last Tag rmnwnm wpm lnKel End wm Lase Moe ey walmn AK All Wellbores Schem Lag Tag: RKB 12.2460 19202017 pproven 11435 11436 awmla ]:wg>Me Last Rev Reason v.ma pTemadelanu+) MnouwnI End wte lvFi Moe By WeRUom --w.Xeen.ssa_ ' mnpunoe:uD nal MM. .11- ( } (J$IJFr: A92a4 rwa uFr; a,.Ds Pa]cx>.4M.D IFAIcs'L4]4o SpncERPVETA.'. pattH2ava0 DaBUFi: Klv e Oas upr, Ip..Bz OPS LIFT: 11. d 6 D.W LIFr: 11 `17. xIPPUE If.na.s LDUTOR n,Tl6.2 LUF TWtl n.m.P sP^cEOI]tai_pnln` ,TR.s BEaLAEsv: n.L@.4 pxOWClpHl ee4 n.Waa FR/C, 121.0 IPExP; 121..6 f @.0 pLVG: u,xpa.e XIPRE RE11 E8 .PERF: tf,wx.0 1 ..p, lf,]ap. t-11¢120 Rev Reason: do GI -Vs, pull plug. sal Patch I/6/2019 Jamal 114-35 Notes: General & Safety EM Data Ann000poo WerEart 10/1&2013 NOTE: Dump Ball4'CaCO3 on PIuB 114-35 Casing Strings sal wpm(1vD) "'RI Rueq Werbon EaD.,O.M.l ID (Inl iap (rtxe) SM wplb (MI InRMI 662) GrWe EB CONDUCTOR i6 15.06 410 156.0 158.0 62.58 APISLGr FEB i0.-35 B SURFACE 998 8.83 1 4n5 1 7,922.6 4,224.9 4000 L -M BTC 11435 PRODUCTION7 6.28 38.4 11.M.8 6,304.) 26.00 U83 BTC -MOD 114.35 LINER 31 Z99I 11,769 11 12,837.0 9.30 L-80 IbUUI i.35 Tubing Strings we sang Mu Nemllul OOIMI 10 (Inl Tap6MB) SHMI IRKBI 9HwKSRj ) Mxe) w1(MMI Gnee Tep Thna4 WellEm TUBING WO 2]/8 2.44 36.2 11,814.0 6,238.3 6.50 L-80 EUE-m i0.-35 Completion Details Top RVO) Top I Nomlrnl Top(ftp) 61Xn) C) IIM Deal wm Unpin) We1160n 36.2 36.2 011 HANGER FMCTUBINGHANGER 2992 1R-35 70.9 70.9 0. XO RMucing 3.1?9.36L30EUE-mboxx2-71S'B.5r EUEpjr »ver 2.4411R-35 531.1 529.8 8.50 NIPPLE CAMCOYIS'NIPPLE 2312 1R-35 11729.5 6163.0 262E NIPPLE HAWBURTON'X'NIPPLE 2313 11435 11,]763 6,201./ 2].Oa LOCATOR BAKER LOCATOR (above lDcale) 2.980 1R-35 11.777.0 6,2053 0.02 LOCATOR BAKER LOCATOR (bekm locale) 2.980 1R-35 11,002.5 6.228.0 26.32 6EAL ASSY BAKER 80.40 BONDED SEAL ASSEMBLY 2980 1R-35 Other In Hole (MmIlne retrievable plugs, valves, pumps, Bah, etc.) Top "D) I. "I Prul) TOP. -n Dea Dmn Rww4 /Dnp) IMM.M 7.369.0 3,990.0 85.15 PATCH P2P PACKER(CPIpn] l)WI SPACER 7l&2019 1.375 1835 PIPE AND ANCHOR LATCH (CPAL28M32) OAL3VMAXOD2.29 7,373.0 3,991.8 65.15 SPACER PIPE 26 OF 2 1M P-110 SPACER PIPE. 702019 1.800 1835 7,3]4.0 $992.1 65.15 LEAKS Leaks W 14. anti )390 94rz019 2.440 W-% 7.399.0 4002.8 85.15 PATCH 2JI8'P2P PACKER (CPP28RM2)OAL655' 7742019 1.375 1R-35 MAXO1)2.M 12,296. ,7.3 16.6] NIPPLE REDUCER 279 NIPPLE REDUCER SET IN LINER 1011 2.250 11435 88 NIPPLE 12,296.8 6.687.3 16.67 PLUG 2.25 CA -2 PLUG SET IN NIPPLE 1011M2013 0000 114-35 REDUCER Liner Details TWMD) Nominal lD T"MKBl 61Na1 TUP,w I•) Eem Dn can 6n) wan WA 38.4 a12 HANGER 6.151 1R-35 4015 40.5 0.13 HANGER 8,835 1835 41.0 41.0 0.13 CONDUCTOR 15.062 114-35 1,096.0 1,062.2 24.62 PORT COLLAR 8.810 IR -35 11.789.1 6,196.1 2724 PACKER BAKER ZXP TOP PACKER w1 HR PROFILE 4.400 IR -35 11,787.0 6214.1 28.75 NIPPLE BAKER RS NIPPLE w1 COLLAR 4.250 TR 11,789.7 6,216.5 26.67 HANGER BAKER FLEX LOCK II HYD ROTATING 4440 1R35 MANGER 11,799.8 82255 26A0 SBE BAKER SEAL BORE EXTENSION w/ 4.000 WM COLLARS 12,296.8 6,687.3 16.6] NIPPLE HALLIBURTON XN NIPPLE WI 295' NO GO; 2.250 114.35 2.213' BORE -2.75 NIPPLE REDUCER w22510 SET 10/16/2013 Perforations & Slots TopMD) TW(nKS) SWIMS) MB) eonlTVDI 1-8) LMkWU- n.1 Slwt wu Isnaa2 Type wm WN®ore 12,1910 12,MB.0 6,5893 6,602.9 C-1,114-35 4/21/2004 6.0 IPERF 12, Powxjnl 1R35 12.352.D 12.3920 6.7402 6.>J8.6 A-S,A-0.A-3. i0. 4130080 35 6.0 APERF 2-H50,806tgpD 114-35 Mandrel Im erls m PPrt I" 17,D) valve IAlcll sm TRD Run NO T+P(193) Mal Make MOM/ OD (in) Eery Type Type (N6 (qB Run wM wm WMbm 1 3,901.4 2,599A NTT KBMG t GAS LIFT GLV BK 0.159 1.355.0 782019 11435 2 6.910.5 3780.8 WFr KBMG i GASUFT OV BK CLASS 0.0 782019 IR 3-7-.131.4 4,)05.1 Cameo KBMG 1 GASUFi DMY BK 0.080 70-M1911435 4 10.6192 5,347.0 Cameo KBMG 1 GAS LIFT DMY BK 0.080 JBlM19 11435 5 11,3116.6 6806.1 WFT KBMG 1 GA6LIFf OMY BN 0.000 022/M15 t0.-% 6 11.6743 6.114.8 Camra KBMG 1 GA6 LIFT DMY SK 0080 M22/2015 114-35 Stimulation Intervals surto. PMPwr4 Designed lml Pmpp.HMFomallal (16) tl/820D200:00 Frac Summary Sryu w+D.ro I Top MKIR BDn ("B) unkw nuw I vaceenmM va 3lary mM) t 11/02002 12.194.0 12,208.0 VS -11. ProActive Diagnostic Services, Inc. WELL LOG TRANSMITTAL To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : 1) Caliper Report 2) Signed Print Name: READ Cased Hole, Inc. Attn: Diane Williams 130 West International Airport Road Suite C Anchorage, AK 99518 Dianw.Williams(&readcasedhole com 06 -Jun -19 1R-35 CD -1- 1 ��rr 201? 10 s�� c RECEIVED JUL 0 3 2019 AOGCC 50-029-23050-00 Date : V C/l q PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W, INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE(CDMEMORVLOGCOM WEBSITE: WWW.MEMORVLOG.COM https//reedcasedhole-my. charepoinccompusonal,diana williams veadcesedhole_com/Documents/DDnvUTempCelipedlR- ODCPM—Kup_Caliper Template: CD Parts/ConocoPMllips_TreasmiLdoc 3049 zo 12 10 Company: Log Date: Log No.: Run No.: Pipe Description: Pipe Use: Pipe Description: CASED Memory Multi -Finger Caliper HOLE Log Results Summary ConocoPhillips Alaska, Inc. June 6, 2019 14386 2 3.5 inch 9.3 Ib. L-80 EUE-M Tubing 2.875 inch 6.5 Ib. L-80 EUE-M Well: Field: State: API No. Top Log Interval: Bottom Log Interval: Top Log Interval: Bottom Log Interval: Inspection Type: Corrosive and Mechanical Damage Inspection COMMENTS: This caliper data is tied into the top of GLM 6 at 11,674.3 feet (Driller's Depth). 1 R-35 Kuparuk Alaska 50-029-23050-00 Surface 59 Ft. (MD) 59 Ft. (MD) This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate the 3.5 inch tubing appears to be in good condition, with no significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions recorded. The caliper recordings indicate the 2.875 inch tubing logged appears to range from good to poor condition, With a maximum recorded wall penetration of 74% in joint 232 (7,374 ft). Additional wall penetrations between 20% and 74% wall thickness are recorded in 210 of the 385 joints logged. Cross-sectional wall loss of 16% metal volume is recorded in an area of general corrosion in joint 230 (7,302 ft). No other significant areas of cross-sectional wall loss or I.D. restrictions are recorded throughout the tubing logged. This is the second time a READ caliper has been run in this well and the first time this 3.5 inch and 2.875 inch tubing have been logged since the RWO dated October 29, 2013. MAXIMUM RECORDED WALL PENETRATIONS: Description Percent Wall Penetratici Joint Depth Line Corrosion 74 232 7,374 Ft. (MD) Line Corrosion 74 283 8,978 Ft. (MD) Line Corrosion 73 263 8,359 Ft. (MD) Line Corrosion 72 255 8,119 Ft. (MD) Line Corrosion 71 218 6,939 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: Description Per: om Will Loss Joint Depth Corrosion 16 230 7,302 Ft. (MD) No other significant areas of cross-sectional wall loss (> 14%) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the tubing logged. C. Geordt C. Waldrop J. Fame Fielr9 Enrgnoer(s) 1n 1k t(,) ProActive Diagnostic Services, Inc. / P.O. Box. 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: PDSAnglysis@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 Correlation of Recorded Damage to Borehole Profile 'Pipe 1 3.5 in (25.7'-59.1') Well: 1R-35 Pipe 2 2.875 in (59,1'- 11,719.91) Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: June 6, 2019 ■ Approx. Tool Deviation ■ Approx. Borehole Profile 29 50 1,601 3,176 GLM i 150: ! 4,768 L C 200 6,335 a GLM 2 7,932 GLM 3 9,525 GLM 4 GLM 5 11,112 GLM 6 11,719 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) Bottom of Survey = 367.1 i i 11 - r J —moi CASED Body Region Analysis HOLE Survey Date: June 6, 2019 Tool Type: UW MFC 24 No. 218527 Company: Conoco Phillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Analvst WoIdrnn Pipe Nom.OD Weight Grade & Thread Nom.ID Top Depth Bottom Depth 3.5 in. 9.3ppf L-80 EUE-M 2.992 in. 26 ft. 59 h. 2.875 in. 6.5 ppf L-80 EUE-M 2.441 in. 59 ft. 11,720 k. Damage Profile (% wall) Penetration body Metal loss body 0 50 100 GLM 1 (8:00) GLM 2 (12:00) GLM 3 (4:00) GLM 4 (6:00) GLM 5 (7:00) GLM 6 (6:00) Bottom of Survey = 367.1 =_ Well: 1 R-35 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Joint Tabulation Sheet Survey Date: June 6, 2019 Analyst: Waldrop Pipe Description 3.5 in. 9.3 ppf L-80 EUE-M Tubing 2.875 in. 6.5 ppf L-80 EUE-M Tubing Nom. ID Body Wall 2.992 in. 0.254 in. 2.441 in. 0.217 in. Top Depth 26 ft 59 ft Bottom Depth 59 ft 11,720 ft. Joint No. It. Depth Pen. (Ft.) Upset (in.) Pen. Body (in.) Pen. % Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 0.1 26 0 0.02 8 2.92 Pup Lt. Deposits - 1 29 0 0.03 11 2.95 _ 1.1 59 0 0 0 2.46 Cross-over 1.2 60 0.04 0.03 13 2.39 Pu 13 71 0 0.04 16 2.39 Pup Shallow Line of Pits. 2 75 0 0.03 14 2.39 3 105 0 0.03 15 2.39 Shallow Pitting. 4 5 138 0 169 0 0.02 0.03 8 12 2.40 2.41 6 201 0 0.02 8 2.41 7 8 233 n 261 0 0.03 0.02 14 11 2.39 2.39 9 293 0 0.03 12 2.40 10 325 0 0.02 8 2.40 11 356 0 0.03 13 2.39 12 385 0 0.02 11 2.41 13 417 0 0.03 14 2.39 14 449 0.02 10 2.40 15 480 0 0.02 9 2.41 15.1 512 U 1 0.03 12 2.40 Pu 15.2 520 0 0 1 2.31 Camco DS Ni le 15.3 521 0 0.03 14 2.39 Pu 16 530 G 0.02 11 2.40 17 562 0 0.03 15 2.40 Shallow Line of Pits. 18 594 0 0.03 12 2.41 19 626 o 0.02 8 2.41 20 657 0 0.02 11 2.39 21 689 0 0.03 14 2.40 22 720 U 0.02 11 2.39 23 752 0 1 0.03 12 2.41 24 783 0 0.02 7 2.40 25 815 0 0.03 12 2.40 26 847 0 0.02 10 2.41 27 879 0 0.03 13 2.42 28 911 0 0.03 13 2.41 29 941 0 0.03 14 2.41 30 973 0 0.02 10 2.42 31 1005 0 0.02 10 2.41 32 1037 0 0.02 9 2.41 33 1067 0 0.02 10 2.41 34 1099 0 0.03 12 2.40 35 1131 0 0.03 1 12 1 2.41 36 1163 0 0.02 9 2.41 37 1194 0 0.02 11 2.42 38 1227 0 0.02 9 2.41 39 1259 0 0.02 10 2.41 40 1291 0 0.02 8 2.39 41 1320 0 0.02 11 2,39 _ 42 1350 0 0.02 10 2.40 43 1379 0 0.03 12 2.41 Penetration Body Metal Loss Body Page 1 =t=== Joint Tabulation Sheet Well: 1 R-35 Survey Date: June 6, 2019 Field: Kuparuk Analyst: Waldrop Company: ConocoPhillips Alaska, Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE-M Tubing 2.992 in. 0.254 in. 26 ft 59 ft 2.875 in. 6.5 ppf L-80 EUE-M Tubing 2.441 in. 0.217 in. 59 ft 11,720 ft. Joint No. Jt. Depth (Ft.) Pen. Upset (in.( Pen. Body (in.) Pen, % Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 44 1411 0 0.04 16 2.42 Shallow Pitting. 45 1442 0 0.02 10 2.40 46 1474 0 0.02 10 2.41 47 1505 0 0.02 11 2.39 48 1537 0 0.02 10 2.41 49 1569 0 0.02 1 9 2.41 50 1601 0 0.02 8 2.40 51 1633 0 0.02 11 2.40 52 1665 0 0.02 10 2.39 53 1695 0 0.02 10 2.3 54 1724 0 0.03 14 2.39 55 1756 0 0.03 12 2.40 56 1788 0 0.03 14 2.42 57 1820 11 0.02 8 2.40 58 1850 0 0.04 17 2.41 Shallow Line of Pits. 59 1882 0 0.02 8 1 2.40 60 1912 0 0.02 8 2.41 61 1944 9 0.02 9 2.40 62 1976 0 0.02 10 2.41 63 2006 1 0 0.02 11 2.40 64 2038 0.02 9 2.41 5 2070 a 0.03 15 2.40 Shallow Line of Pits. 66 2103 0 0.02 11 2.41 19 67 2133 d 0.03 14 2.41 68 2165 0 0.04 18 2.41 Shallow Line of Pits. 69 21.97 (l 0.02 10 j j 2.42 70 2229 0 0.04 18 2.42 Shallow Line Corrosion. 71 2261 0 0.02 11 2.41 72 2293 0 0.03 12 2.42 73 2325 0 0.03 13 2.41 74 2357 1 0 1 0.02 10 2.41 75 2390 0 0.02 10 2.40 76 2419 n 0.03 12 2.40 77 2449 0 0.03 14 2.41 78 2481 0 0.03 12 2.42 79 2513 fi 0.02 9 1 1 2.42 80 2545 0 0.02 10 2.42 81 2577 0 0.03 12 2.42 82 2608 0 0.02 10 2.40 83 2641 0 0.03 12 2.41 84 2673 1 0 1 0.03 12 2.40 85 2705 fi 0.01 6 2.41 86 2737 0 0.02 9 2.43 87 2768 0 0.02 8 2.42 88 2800 0 0.02 11 2.43 89 2831 0 0.02 7 2.41 90 2863 0 0.03 12 2.42 91 2894 0 0.02 9 2.40 _ 92 2926 0 0.03 12 2.40 93 2957 0 0.03 1 13 1 1 2.41 Penetration Body Metal Loss Body Page 2 =- Well: Field: Company: La 1R-35 Kuparuk ConocoPhillips Alaska, Inc. Joint Tabulation Sheet Survey Date: June 6, 2019 Analyst: Waldrop Pipe l- Description 3.5 in. 9.3 ppf L-80 EUE-M Tubing 2.875 in. 6.5 ppf L-80 EUE-M Tubing Nom. ID Body Wall 2.992 in. 0.254 in. 2.441 in. 0.217 in. Top Depth Bottom Depth 26 ft 59 ft 59 ft 11,720 ft Joint No. It. Depth Pen. (Ft.) Upset (in.) Pen. Body (in.) Pen. % ... Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 94 1 2989 0 0.02 11 2.4 95 3020 0 0.02 8 2.42 96 3051 0 0.02 7 2.40 97 3082 0 0.02 11 2.39 98 3114 0 0.03 12 2.43 99 3145 0 1 0.02 11 2.42 100 3176 0 1 0.03 15 2.40 Shallow Line of Pits. 101 3208 0 0.02 10 2.42 102 3240 0 0.02 7 2.42 103 3270 0 0.03 12 2.39 104 3301 o 0.03 12 2.42 105 3332 0 0.03 12 3 2.39 106 3364 0 0.03 12 2.40 107 3395 0 0.03 13 2.41 108 3428 0 0.02 8 2.43 109 3459 0 0.02 it 2.42 110 3490 0 0.02 10 2.43 111 3521 0 0.03 14 2.39 112 3553 0 0.03 12 2.44 113 3584 0 0.02 7 2.38 Lt. Deposits. 114 3616 0 0.03 13 2.40 115 3647 0 0.03 13 ! 2.38 Lt. Deposits. 116 3679 0 0.03 12 2.39 117 3710 1 0 0.02 10 2.40 118 3742 0 0.02 10 2.40 119 3773 0 0.03 12 2.39 120 3803 0 0.03 12 2.41 121 3835 0 0.03 12 2.40 122 3866 0 0.03 14 2.42 122.1 3898 0 0.03 16 2.41 Pulp Shallow Line of Pits. 122.2 3906 0 0 0 2.34 GLM i Latch @ 8:00 122.3 3913 0.05 0.03 12 2.39 Pu 123 3921 0 0.05 21 2.41 Line of Pits. 124 3953 0 0.05 21 2.39 Line of Pits. 125 3983 0 0.04 17 2.40 low Line of Pits. 126 4014 0 0.04 17 2.40 low Line of Pits. 127 4046 �! 0.03 15 2.39 low Line of Pits. 128 4077 0.04 0.05 22 2.40 of Pits. 129 4108 0 0.05 22 2.36 of Pits. Lt. Deposits. 130 4140 O 0.05 23 2.38 of Pits. Lt. Deposits. 131 4171 0 X04 0.05 23 2.39 of Pits. 132 4203 0.03 0.05 24 2.38 of Pits. Lt. De osits. 133 4234 O.Oj 0.06 29 2.40 of Pits. !!ij 134 4265 0.04 0.06 28 2.38 of Pits. 135 4297 0.04 0.07 32 2.37 Corrosion. Lt. Deposits. 136 4329 0 0.05 21 2.38 of Pits. 137 4360 0 0.05 23 2.38 of Pits. Lt. Deposits. 138 4391 0.04 0.07 34 2.38 of Pits. Lt. De osits. 139 4423 0 0.06 26 2.37 of Pits. Lt. Deposits. 140 4454 n.04 0.06 27 2.39 of Pits. Penetration Body Metal Loss Body Page 3 CASCO - = Well: 1R-35 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Joint Tabulation Sheet Survey Date: June 6, 2019 Analyst: Waldrop Pipe Description 3.5 in. 9.3 ppf L-80 EUE-M Tubing 2.875 in. 6.5 ppf L-80 EUE-M Tubing Nom. ID Body Wall Top Depth 2.992 in. 0.254 in. 26 ft 2.441 in. 0.217 in. 59 ft Bottom Depth 59 ft 11,720 ft. Joint No. Jt. Depth Pen. (Ft.) Upset (in.) Pen. Body (in.) Pen. % `Loss �� Min. LD. (in.) Comments Damage Profile (%wall) 0 50 100 141 4486 0.05 0.05 24 - 2.39 142 4518 0.03 0.08 35 2.37 iaDeposits.143 4549 0.04 0.06 28 4 2.38 ECorrosion. L144 4581 0 0.07 34 ,+ 2.37 L , 145 4612 0 0.06 27 4 2.40 L 146 4644 0 0.06 29 4 2.39 Line of Pits. 147 4675 0 0.07 30 2.41 Line Corrosion. 148 4707 0.04 0.06 28 2.40 Line of Pits. 149 4738 0.04 0.06 29 -t 2.39 Line of Pits. 150 4768 0 0.06 29 1 - 2.41 Line Corrosion. 151 4799 0 0.06 29 4 2.39 Line of Pits. 152 4830 0.64 0.06 26 4 2.39 Line of Pits. 153L498 0.04 0.07 31 - 2.40 Line Corrosion. 1540.05 0.06 27 2.40 Line of Pits. 1550.05 0.08 35 5 2.40 Line Corrosion. 1560.04 0.06 28 .1 2.39 Line of Pits. 1570.05 0.06 29 5 2.41 Line Corrosion. 158 5016 0.04 0.06 29 5 2.40 Line of Pits. 159 1 5048 0.05 0.06 29 4 1 2.39 Line of Pits. 160 5080 0.05 0.06 26 2.40 Line of Pits. 161 5110 0.07 0.06 28 5 2.40 Line Corrosion. 162 5141 0.04 0.06 28 :5 2.40 Line Corrosion. 163 5173 0 0.07 30 2.40 Line of its. 164 5204 0.03 0.06 29 2.39 Line of Pits. 165 5236 0.04 0.06 29 5 2.38 Line of Pits. 166 5267 0 0.06 27 2.39 Line Corrosion. 167 5298 0.05 0.07 34 2.40 Line of Pits. 168 5330 0.05 0.07 32 5 2.41 Line of Pits. 169 5361 0.06 0.06 29 d 2.39 Line of Pits. 1705393 0.04 0.08 35 1, 2.39 Line of Pits. 171_r5486 5424 0.06 0.07 31 2.39 Line of Pits. 1725456 0 0.07 32 4 2.40 Line of Pits. 173 0 0.06 29 2.39 Line of Pits. 174 5518 0.05 0.07 33 - 2.38 Line Corrosion. Lt. Deposits. 175 5549 0.05 0.08 35 4 2.38 Line of Pits. Lt. Deposits. 176 5581 0.04 0.08 35 2.36 Line Corrosio,. it De osits. 177 5612 0.06 0.07 321 2.40 Line of Pits. 178 1 5643 0.05 0.08 36 6 2.36 Line Corrosion. Lt. Deposits. 179 5674 0 0.09 39 - 2.37 Line Corrosion. Lt. Deposits. 180 5705 0.05 0.08 37 2.38 Line Corrosion. Lt. De osits. 181 5737 0.06 0.08 35 2.39 Line Corrosion. - 182 5769 O.nS 0.07 32 ^ 2.35 Line Corrosion. Lt. Deposits. 183 5800 0.(t 0.07 30 2.37 Line of Pits. Lt. Deposits. 184 5832 0 0.07 34 2.37 Line of Pits. Lt. Deposits. 185 5863 0.05 0.07 32 6 2.39 Line of Pits. 186 5895 0 0.08 36 2.38 Line Corrosion. 187 5926 0.05 0.06 29 2.37 Line of Pits. Lt. Deposits. 188 5958 0.06 0.07 33 4 2.37 Line of Pits. Lt. Deposits. 189 5989 0 0.08 36 2.37 Line Corrosion. Lt. Deposits. 190 6020 0.04 0.07 30 2.37 Line Corrosion. Lt. Deoosits Penetration Body Metal Loss Body Page 4 C _£ f CASED - wL Well: 1 R-35 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Joint Tabulation Sheet Survey Date: June 6, 2019 Analyst: Waldrop Pipe Descdpfion 3.5 in. 9.3 ppf L-80 EUE-M Tubing 2.875 in. 6.5 ppf L-80 EUE-M Tubing Nom. ID Body Wall 2.992 in. 0.254 in. 2.441 in. 0.217 in. Top Depth Bottom Depth 26 ft 59 ft 59 ft 11,720 ft Joint Jt. Depth Pen. No. (Ft.) Upset (in.) Pen. Body (in.) Pen. % �Metai Loss ,� Min. 1. D. (in.) Commentswall) Profile 50 100 191 6052 0.05 1 0.08 37 5 2.35 Line Corrosion. Lt. De osits. jDam,ge 192 6083 0.03 0.07 32 4 2.37 Line of Pits. Lt. Deposits. 193 6114 0.07 0.09 41 6 2.38 Line Corrosion. Lt. Deposits. 194 6146 0.08 0.08 38 4 2.37 Line of Pits. It Deposits. 195 6177 0.05 0.10 44 3 2.37 Line Corrosion. Lt. Deposits. 196 6209 0.07 0.09 42 6 2.37 Line of Pits. Lt. Deposits. 197 6240 0.07 0.08 36 1 2.38 Line Corrosion. Lt. De osits. 198 6272 0.05 0.10 45 6 2.37 Line Corrosion. Lt. Deposits. 199 6304 0.06 0.09 39 4 2.40 Line Corrosion. 200 6335 0.0' 0.11 49 - 2.36 Line Corrosion. Lt. De osits. _ 201 6366 0.05 0.09 43 2.38 Line of Pits. Lt. De osits. 202 6397 0.07 0.10 44 5 2.38 Line Corrosion. Lt. Deposits. 203 6428 0,07 0.10 46 - 2.37 Line Corrosion. Lt. Deposits _ 204 6459 0.09 0.09 43 6 2.38 Line Corrosion. 205 6490 0.05 0.10 46 6 2.36 Line of Pits. Lt. Deposits. 206 6522 0.10 0.11 50 2.38 Line Corrosion. Lt. Deposits _ 207 6553 0.06 .11 50 6 2.38 _ Line Corrosion. Lt. Deposits. 208 6585 0-12 0.11 50 8 2.38 Line Corrosion. 209 6616 0.03 0.10 44 9 2.36 Line Corrosion. Lt. De osits. 210 6648 0.09 0.12 53 6 2.39 Line Corrosion. 211 6680 0.06 0.11 52 7 2.36 Line Corrosion. Lt. Deposits. 212 6711 0.11 0.09 43 7 2.39 Line Corrosion. 213 6743 0.04 0.10 48 2.36 Line Corrosion. Lt. Deposits. 214 6775 0.05 0.11 52 2.36 Line Corrosion. Lt. Deposits. 215 6806 0.05 0.10 44 7 2.35 Line Corrosion. Lt. Deposits 216 6837 0.07 0.09 39 2.37 Line Corrosion. LL Deposits. _ 217 6869 0.05 0.10 44 5' 2.37 Line Corrosion. Lt. Deposits. 217.1 6900 0.03 0.03 12 3 2.38 Pu 217.2 6908 0 0 0 0 2.34 GLM 2 Latch @ 12:00 217.3 6915 0 0.02 10 2 2.39 Pup__ 218 6924 0.07 0.16 71 14 2.35 Line Corrosion. Lt. Deposits. 219 6955 0.04 0.14 66 12 2.35 Line Corrosion. Lt. De osits. 220 6986 0.0i 0.15 70 i 0 2.35 Line Corrosion. Lt. Deposits. 221 7018 0.05 0.15 68 i= 2.35 Corrosion. Lt. Deposits. 222 7050 13 58 11 2.36 Line Corrosion. Lt. De osits. 223 7081 15 70 iG 2.40 Line Corrosion. 224 7113 13 59 2.35 Line Corrosion. Lt. De osits. 225 7145 16 71 12 2.40 Line Corrosion. 226 7176 12 55 2.39 Line Corrosion. 227 7208 J3O. 12 55 2.36 Line Corrosion. Lt. De osits. 228 7238 14 63 12 2.38 Line Corrosion. Lt. De osits. 229 7269 10 44 2.36 Line of Pits. Lt. De osits.230 7301 13 62 16 235 Corrosio231 7333 13 62 8 2.36 Line Corrosion. Lt. Deposits, 232 7362 0.07 0.16 74 9 2.37 Deposits. Line Corrosion. LtjDeposEjts._ 233 7394 U.O� 0.15 70 - 2.36 Line Corrosion. 234 7426 0.07 0.08 39 .1 2.39 Line of Pits. 235 7458 0.04 0.11 52 2.35 Line Corrosion. ZV 236 7490 0.00 0.10 47 2.36 Line Corrosion. 237 7521 0.07 0.09 43 :; 2.37 Line Corrosion. Penetration Body - Metal Loss Body Page 5 _=_g0% CASED LL Joint Tabulation Sheet Well: IR -35 Survey Date: June 6, 2019 Field: Kuparuk Analyst: Waldrop Company: ConocoPhillips Alaska, Inc. Pipe Description 3.5 in. 2.875 9.3 ppf L-80 EUE-M Tubing in. 6.5 ppf L-80 EUE-M Tubing Nom. ID Body Wall Top Depth 2.992 in. 0.254 in. 26 ft 2.441 in. 0.217 in. 59 ft Bottom Depth 59 ft 11 720 ft. Joint No. Jt. Depth Pcn. (Ft.) Upset (in.) Pen. Body (in.) Pen. % nle,ai Lu Ss Min. 1. D. (in.) Comments Damage Profile (% wall) 0 50 100 238 7553 O.n6 0.14 1 65 1 9 2.37 Line Corrosion. Lt. Deposits. 239 7585 0.0,' 0.12 56 8 2.35 Line Corrosion. Lt. Deposits. 240 7616 0.08 0.12 55 1 9 2.36 Line Corrosion. Lt. Deposits. 241 7647 0.08 0.13 58 6 2.37 Line Corrosion. Lt. Deposits. 242 7678 0.05 0.11 52 1 6 2.36 Line Corrosion. Lt. Deposits. 243 771 0 0.06 0.10 45 1 6 2.35 Line Corrosion. Lt. De osits. 244 7742 U.05 0.08 35 1 2.37 Line of Pits. Lt. Deposits. 245 7774 0.06 0.14 65 1 .40 Line Corrosion. 246 7805 0.05 0.08 38 4 2.37 _ Line of Pits. Lt. Deposits. 247 7837 0.05 0.10 46 - 2.35 _ Line of Pits. Lt. Deposits. _ 248 7868 0 0.15 68 6 2.35 Line Corrosion. Lt. Deposits. 249 7900 0.10 0.12 56 6 2.34 _ Line Corrosion. Lt. Deposits. _ 250 7932 0.10 0.10 44 - 2.37 Line of Pits. Lt. Deposits. 251 7964 O.Of, 0.12 57 2.39 Line of Pits. 252 7996 0 0.10 48 5 2.34 Line of Pits. Lt. Deposits. 253 8028 0.0.1 0.12 57 s 2.38 Line of Pits. 254 8058 U 0.13 60 5 2.34 Line Corrosion. Lt. Deposits. 255 8090 0.10 0.16 72 8 2.38 Line Corrosion. Lt. Deposits. 256 8122 0.08 0.12 53 5 2.35 Line of Pits. Lt. Deposits. 257 8154 0.08 0.13 61 u 2.40 Line of Pits. 258 8185 0 0.12 53 6 2.35 Line of Pits. Lt. Deposits. 259 8217 0.05 0.11 51 6 2.35 Line of Pits. Lt. Deposits. 260 8249 G.13 0.11 52 2.39 Line of Pits. 261 8281 0 0.10 48 = 2.35 Line of Pits. Lt. Deposits. 262 8312 0.04 0.14 63 6 2.35 Line Corrosion. Lt. Deposits. 263 8344 0.06 0.16 73 2.37 Line Corrosion. Lt. De osits. 264 8376 0.05 0.12 55 1 2.35 Line Corrosion. Lt. Deposits. 265 8407 0 0.11 52 3 2.35 Line of Pits. Lt. Deposits 266 8439 0 0.12 57 2.34 Line Corrosion. Lt. Deposits. 267 8471 0.07 0.10 47 2.39 Line of Pits. 268 8502 0.10 0.13 61 0 2.35 Line Corrosion. Lt. Deposits. _ 269 8532 0.04 0.11 49 6 2.36 Line Corrosion. Lt. Deposits, 270 8564 0 0.07 30 i, 2.34 Line of Pits. Lt. De osits. 271 8595 0.03 0.08 36 2.37 Gne of Pits. Lt De osits. 272 8626 0.06 0.13 58 7 2.35 Line Corrosion. Lt. Deposits. 273 8656 0 0.10 47 2.37 Line of Pits. Lt. De osits. 274 8687 0 0.12 54 2.34 Line Corrosion. Lt Deposits. 275 8719 0.09 0.11 49 6 237 Line Corrosion. Lt De osits. 276 8750 G 0.15 71 2.34 Line Corrosion. Lt. Deposits. 277 8782 0.05 0.14 65 - 2.38 Line Corrosion. Lt. Deposits. 278 8813 0.01 0.11 52 7, 2.35 Line Corrosion. Lt. Deposits. 279 8845 0.06 0.1464 7 2.38 Line Corrosion. Lt. Deposits. 280 8877 a 0.10 45 4 2.35 Line Corrosion. Lt. Deposits. 281 8909 0.04 0.13 60 8 2.34 Line Corrosion. Lt. Deposit 282 8940 0 0.09 42 4 2.35 Line Corrosion. Lt. Deposits. 283 8971 0.05 0.16 74 6 2.35 Line Corrosion. Lt. De osi6. 284 9002 0.05 0.11 49 6 2.36 Line of Pits. Lt. De osits. 285 9034 0.04 0.09 42 6 2.40 _ Line of Pits. 286 9065 0 0.10 48 a 2.35 Line Corrosion. Lt Deposits. 287 1 9097 1 0 1 0.11 48 <i 2.37 LineCorrosion- Lt. De osits. Penetration Body --_ Metal Loss Body Page 6 CASED „Qt.L Well: IR -35 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Joint Tabulation Sheet Survey Date: June 6, 2019 Analyst: Waldrop Pipe Description 3.5 in. 9.3 ppf L-80 EUE-M Tubing 2.875 in. 6.5 ppf L-80 EUE-M Tubing Nom. ID Body Wall 2.992 in. 0.254 in. 2.441 in. 0.217 in Top Depth Bottom Depth 26 ft 59 ft 59 ft 11,720 ft Joint No. Jt. Depth Pen. (Ft.) Upset (in.) Pen. Body (in.) Pen. % Mewl Loss % Min. LID. (in.) Comments Damage Profile (%wall) 0 50 100 287.1 1 9127 0 0.02 92 2.38 Pu Lt. Deposits. 287.2 9135 0 0 0 0 1 2.30 GLM 3 Latch @ 4:00 287.3 9143 0 0.02 11 1 2.36 Pup Lt. Deposits. 288 9151 0.04 0.15 68 6 2.36 Line Corrosion. Lt. Deposits. 289 9183 0.12 0.14 65 6 2.36 Line Corrosion. Lt. Deposits. 290 9213 0 0.06 25 5 2.36 Line of Pits. Lt. Deposits. 291 9245 0 0.12 55 D 2.37 Line of Pits. Lt. Deposits. 94 292 9275 0 0.05 24 4 2.36 Line of Pits. It De osits. 293 9307 0 0.14 66 6 2.35 Line Corrosion. Lt. Deposits, 294 9338 0.03 0.14 63 2.39 Line Corrosion. 295 9366 0 0.13 61 2.36 Line Corrosion. Lt. Deposits. 296 9398 0 0.14 64 6 2.35 Line Corrosion. Lt. Deposits. 297 9430 0.05 0.13 59 - 2.35 Line Corrosion. Lt. Deposits. 298 9462 0,06 0.07 32 -! 2.39 Isolated Pitting 299 9493 0.03 0.15 69 7 2.35 Line Corrosion. Lt. Deposits. 300 9525 0.03 0.05 24 2.38 Line of Pits. 301 9557 0 0.11 53 6 2.34 Line Corrosion. Lt. De osits. 302 9589 0 0.11 52 6 2.35 Line of Pits. Lt. Deposits. 303 9621 W)1 0.11 48 4 2.35 Line of Pits. Lt. Deposits. 304 9651 0 0.12 53 j 2.36 Line Corrosion. Lt. De osits. 305 9683 0.10 0.12 54 2.34 Line Corrosion. Lt. Deposits. 306 9714 0.04 0.07 30 li 2.36 Line of Pits. Lt. Deposits. 307 9746 0 0.11 50 2.39 Line Corrosion. 308 9777 0 0.05 24 2.36 Line of Pits. Lt. De osits 309 9808 0.03 0.11 48 2.39 Line Corrosion. 310 9840 0 0.14 63 2.35 Line Corrosion. Lt. Der)osits. 311 9871 0.06 0.10 48 -! 2.35 Line of Pits. Lt. Deposits. 312 9902 1 0.04 0.10 45 5 2.39 Line Corrosion. 313 9934 0 0.11 50 1 2.36 Line of Pits. Lt. Deposits. 314 9965 0 0.05 24 4 2.34 Line of Pits. Lt. Deposits. , 315 9996 0.04 0.09 42 2 2.38 Line of Pits. 316 10028 0 0.10 47 5 2.35 Line of Pits. Lt. Deposits. 317 10059 0.03 0.11 48 3 2.38 Line of Pits. 318 10091 0 0.10 47 4 2.35 Line of Pits. Lt. De p osits. 319 10123 0 0.11 53 5 2.36 Line Corrosion. Lt. Deposits. 320 10154 0 0.11 51- 2.35 Line of Pits. Lt. Deposit 321 10186 0 0.12 57 6 2.34 Line Corrosion. Lt. De osits. 322 10217 0 0.11 52 5 2.39 Line Corrosion. 323 10248 0 0.11 51 2.36 Line Corrosion. Lt. Deposits. 324 10279 0 0.12 54 2.34 Line of Pits. Lt. De osits. - 325 10310 0 0.04 19 2.35 Shallow Line of Pits. Lt. Deposits. 326 10341 0 0.04 77 J. 2.34 Shallow Pitting. Lt. Deposits. 327 10372 0 0.04 18 2 2.34 Shallow Line of Pits. Lt. Deposits. 328 10401 0 0.05 24 3 2.37 Line of Pits. Lt. Deposits. -. 329 10432 0 0.04 19 4 2.37 Shallow Line of Pits. Lt. Deposits. 330 10464 0 0.05 22 3 2.40 Line of Pits. 331 10496 0 0.06 1 28 2 2.35 Line of Pits.. Lt. Deposits 332 10526 0 0.05 1 21 2 2.35. Line of Pits. Lt. Deposits.. 333 10556 0 0.05 24 -i 2.38 Line of Pits. Lt. Deposits. 334 10588 0 0.03 1 16 1 3 1 2.34 Shallow Pitting. Lt. Deposits. Penetration Body ,. Metal Loss Body Page 7 _ CASED ASE = CnVLm Well: IR -35 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. joint Tabulation Sheet Survey Date: June 6, 2019 Analyst: Waldrop Pipe Description 3.5 in. 9.3 ppf L-80 EUE-M Tubing 6.5 ppf L-80 EUE-M Tubing Nom. ID Body Wall Top Depth 2.992 in. 0.254 in. 26 ft 2.441 in. 0.217 in. 59 ft Bottom Depth 59 ft 11 720 ft. Joint No. Jt. Depth Pen. (Ft.) Upset (in.) Pen. Body (in.) Pen. Mccil % Loss .� in. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 335 10619 0 0.04 20 2.39 Line of Pits. 335.1 10651 0 0.03 15 3 2.35 Pu Shallow Pitting. Lt. Denosits. 335.2 10659 0 0 0 0 2.28 GLM 4 Latch @ 6:00 335.3 10666 0 0.02 11 1 2.36 Pu Lt. Deposits. 336 10674 0 0.05 23 i 2.37 Line of Pits. Lt. De osits. 337 10705 0 0.06 25 3 2.35 Line of Pits. Lt. Deposits. 338 10736 0 0.05 25 2.35 Line of Pits. Lt. Deposits. 339 10768 0 0.05 22 2.35 Line of Pits. Lt. Deposits. 340 10800 0 0.05 24 3 2.35 Line of Pits. Lt. Deposits. - 341 10831 0 1 0.03 152.35 Shallow Pitting. Lt. Deposits 342 10863 0 0.03 12 2.34 Lt- Deposits. 343 10895 0 0.03 14 3 2.37 Lt. Deposits. 344 10927 0 0.02 8 2.35 Lt. Deposits. 345 10955 0 0.02 10 2.39 346 10987 0 0.04 17 2 2.38 Shallow Line of Pits. Lt De osits. 347 11017 0 0.04 20 39 2WGLM5JLatch Line of Pits. 348 11048 0 0.02 10 3 t. Deposits. 349 11080 0 0.02 8 i t. Deposits. 350 11112 0 0.03 12 5 t. Deposits. 351 11144 U 0.02 7 2 t. Deposits. 352 11175 0 0.03 12 <d t. Deposits. 353 11207 0 0.02 7 2 . Deposits. 354 11236 0 0.03 12 . De osits. 355 11267 0 0.02 9 - . Deposits. 355.1 11299 0 0.03 12 5 u Lt. De osits. 355.2 11307 0 0 0 LM SLatch @ 7:00 355.3 11313 0 0.03 13 2.36 Pun Lt. Deposits 356 11322 0 0.02 11 2 2.35 Lt. Deposits. 357 11353 0 0.02 9 3 2.38 Lt. Deposits. 358 11385 0 0.01 6 3 2.36 Lt. Deposits. 359 11416 0 0.02 7 3 2.35 Lt. Deposits. 360 11448 1 0 0.02 8 1 2.39 361 11479 0 0.03 15 .3 2.34 Shallow Pitting . Lt. DEU. 362 11510 0 0.02 11 2.37 Lt. Deposits. 363 11540 0 0.02 10 3 2.36 Lt. Deposits. 364 11571 0 0.02 11 - 2.36 Lt. Deposits. 365 11603 0 0.02 11 2.36 Lt. Deposits. 366 11634 0 0.03 12 5 2.35 Lt. De -it,. 366.1 11666 0.03 0,03 15 2.35 Pu Shallow Line of osits. 366.2 11674 0 0 00 2.30 GLM 6 Latch 11 6:00 366.3 11681 0 0.02 11 2 2.38 Pu Lt. De osits. 367 116891 0 0.03 12 ' 2.35 Lt. Deposits. 367.1 11719 1 0 0 0 0 2.34 11 Pun It De osits. . Penetration Body w Metal Loss Body Page 8 CASED HOLE Cross-sectional Illustration Survey Date: June 6, 2019 Tool Type: UW MFC 24 No. 218527 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Tubing: 2.875 in. 6.5 ppf LL80 EUE-M Analyst _ Waldrop Cross Section for Joint 232 at depth 7,374.040 ft. Tool speed = 51 Nominal ID = 2.441 Nominal OD = 2.875 Remaining wall area = 91 % Tool deviation = 65° Finger= 19 Penetration = 0.161 in. Line Corrosion 0.16 in. = 74% Wall Penetration HIGH SIDE = UP _ CASED -= HOLE Company: ConocoPhillips Alaska, Inc. Country: USA EUE-M Cross-sectional Illustration Survey Date: Tool Type: Tool Size: No. of Fingers: Cross Section for Joint 283 at depth 8,978.406 ft. Tool speed = 49 Nominal ID = 2.441 Nominal OD = 2.875 Remaining wall area = 94% Tool deviation = 72° June 6, 2019 UW MFC 24 No. 218527 1.69 inches 24 Waldrop Finger = 18 Penetration = 0.160 in. Line Corrosion 0.16 in. = 74% Wall Penetration HIGH SIDE = UP CASED HOLE Company: ConocoPhillips Alaska, Inc. Country: USA Tubing: 2.875 in. 6.5 oof L-80 EL Cross-sectional Illustration Survey Date: June 6, 2019 Tool Type: UW MFC 24 No. 218527 Tool Size: 1.69 inches No. of Fingers: 24 Analyst: Waldrop Cross Section for Joint 230 at depth 7,301.740 ft. Tool speed = 49 Nominal ID = 2.441 Nominal OD = 2.875 Remaining wall area = 84% Tool deviation = 74° Finger= 18 Penetration = 0.081 in. Corrosion 16% Cross -Sectional Wall Loss HIGH SIDE= UP 20 12 10 • ' " TRANSMITTAL DATE TRANSMITTAL # 1 ' SERVICE ORDER SERVICE Color WELL NAME API # # FIELD NAME DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED Prints CD's 50-029-23050-00 nt Signature Please return via courier or sign/scan and email a A Transmittal Receipt signature confirms that a package (box / r�/ envelope, etc.) has been received and the contents of the ` / package have been verified to match the media noted above. The Date specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this Schlumberger and CPAI. point. Schlumberger -Private Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. j 0 1 - ~ 1 Q 'Well History File Identifier Organizing (dOI\(~) RESCAN III "1'11/111111111 DIGITAL DATA r./ Diskettes, No.3 0 Two-Sided 0 Color items: 0 Grayscale items: 0 Poor Quality Originals: 0 Other: 0 Other, Norrype NOTES: BY: _K{~~ Project Proofing BY: ,--.., -,,~RYLe\ Scanning Preparation :~ x 30 = c¡ ~ "- 'L~A~~ BY: ,--,,- '" '-- 0 Rescan Needed 1111111111111111111 0 OVERSIZED (Scannable) 0 Maps: Other items scannable by large scanner 0 OVERSIZED (Non-Scannable) Logs of variQus kinds ,0 Other DATe6 ~!i'{ b<f Is! mP 1111111111111111111 V11P DATEs(d5jtllf Is! + I = TOTAL PAGES q! 0",,1 ~ oIflSI Production Scanning Q Stage 1 PAGE COUNT FROM SCANNED FILE: ,/1 // V Î I~~.G~ COUNT MATCHES NUMBER IN SCANNING PREPARATION: -;-- YES ,,: f.Jõ' ,^,,?ftJ/ð1 ,~ Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: - YES BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) ReScanned (ì/ldividuallu,r (&pCci,JI ,Jllo!HíOIJ.I ,~c;¡lJniHg cpmplniOd) RES CANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: ISI 1111111111111111111 DATE: Isl Y\1P _NO _NO 111/11/11111/111111 Quality Checked (donç\ 1111111111111111111 12/1 OIO2Rev3NOTScanned. wpd STATE OF ALASKA RECEIVED ALA.OIL AND GAS CONSERVATION COM ION NOV 13 2013 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r.i's Plug Perforations r Perforate r Othe GCC Alter Casing r Pull Tubing lam;. Stimulate- Frac r Waiver fl Time Extension fl Change Approved Program rOperat. Shutdown r Stimulate-Other fl Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Fr, Exploratory r 201-210 ' 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-029-23050-00 ' 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25627,25635 • 1R-35 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool " 11.Present Well Condition Summary: Total Depth measured 12642 feet Plugs(measured) 12297' true vertical 7009 feet Junk(measured) none Effective Depth measured 12541 feet Packer(measured) 11769 true vertical 6922 feet (true vertical) 6198 Casing Length Size MD TVD Burst Collapse CONDUCTOR 117 16" 158 158 SURFACE 7882 9.625" 7923 4225 PRODUCTION 11935 7" 11974 6385 LINER 868 3.5" 12637 7008 Perforation depth: Measured depth: 12194'-12208', 12352'-12392' NNE j � ' r �`.!� True Vertical Depth: 6590'-6603',6740'-6779' Tubing(size,grade,MD,and ND) 2.875, L-80, 11814 MD,6238 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER ZXP TOP PACKER @ 11769'MD and 6198'TVD NIPPLE-CAMCO DS NIPPLE @ 531'MD and 530'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory ("w Development • Service r Stratigraphic r 16.Well Status after work: Oil ... - Gas r WDSPL r Daily Report of Well Operations XXX GSTOR WIND r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: none Contact Ian Toomey a 263-4773 Email Ian.A.Toomeyaconocophillips.com Printed Name Ian Toomey Title Wells Engineer Signature ,____-.--- Phone:263-4773 Date 4,___,.. //- /. -/3 t RBENS NOV 2 1 2 1. VZ.f . ..'ez7,4/Pp' 12//8//3 Form 10-404 Revised 10/2012 Submit Original Only ' KUP PROD • 1R-35 Conoco Phillips ` ,,. Well Attributes Max Angle&MO Alaska.Inc ,, Wellbore APIIUWI [Field Name 'Wellbore Status Inc/(3 MD(ftKB) Act Btm(ftKB) �rw„x-twrea4,x l 500292305000 [Field RIVER UNIT PROD 68.76 6,523.29 12,630.0 ..Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1R-35,10/30/20138z1:43 AM SSSV:NIPPLE I 40 8/6/2009 Last WO: I 10/29/2013 42.30 12/10/2001 V n schemer ( tua0 Annotation Depth(ftKB) End Date Annotation Last Mod By I End Date __.__ ___ .............. ,_.. _._....Last Tag:SLM 12,451.0 10/16/2013 Rev Reason:WORKOVER osborl 10/30/2013 HANGER',36.2-- VLI.1 I / posing Strings , ■ I ■ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread III,! A CONDUCTOR 16 15.062 41.0 158.0 158.0 62.58 AB PI5LGr PEB 10 I • Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I_Grade Top Thread SURFACE 95/8 8.835 40.5 7,922.6 4,2249 40.00 L-80 BTC Casing Description OD(in) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread I I�` �I PRODUCTION 7 6.276 38.4 11,973.8 6,384.7 26.00 L-80 BTC-MOD Casing Description OD(m) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread j LINER 3 1/2 2.992 11,769 1 12,637.0 9.30 L-80 SLHT Liner Details CONDUCTOR 41.0.158.0 I a Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Inc/(3 Item Des Corn (in) :15 11,769.1 6,198.1 27.24 PACKER BAKER ZXP TOP PACKER w/HR PROFILE 4.400 NIPPLE,531.t z 11,787.0 6,214.1 26.75 NIPPLE BAKER RS NIPPLE IN/COLLAR 4.250 11,789.7 6,216.5 26.67 HANGER BAKER FLEX LOCK II HYD ROTATING HANGER 4.440 I . F 11,799.8 6,225.5 26.40 SBE BAKER SEAL BORE EXTENSION wl COLLARS 4.000 12,296.8 6,6873 1367 NIPPLE HBAOLRE B=2R7T5O N N IX LNI PRPELDE U WCE/2R.7w 5"2 N2O"GO;S 2E13" 2.250 ill 10/16/2013 GAS LIFT,3,911.5 Tubing Strings y Tubing Description I String Ma.IID(in) I Top(ftKB) )Set Depth(ft..I Set Depth(TVD)(..[Wt(Ib/ft) 'Grade I Top Connection • TUBING WO 2 7/8 2.441 36.2 11,814.01 6,238.3 6.50 L-80 EUE-m I ompletlon Details GAS LIFT;6910.5 Nominal ID Top(ft613) Top(TVD)(ftKB) Top feel(°) Item Des Com (in) 36.2 36.2 0.11 HANGER FMC TUBING HANGER 2.992 I 70.9 70.9 0.22 XO Reducing 3-1/2"9.30 L-80 EUE-m box x 2-7/8"6.58 EUE pin 2.441 crossover 531.1 529.8 8.50 NIPPLE CAMCO'OS'NIPPLE 2.312 SURFACE;405-7922.6 11,729.5 6,163.0 28.28 NIPPLE HALLIBURTON'X'NIPPLE w/RHC-M plug body installed 2.313 ® 11,776.2 6,204.4 27.04 LOCATOR BAKER LOCATOR(above locate) 2.980 GAS LIFT,9,134.a a 11,777.0 6,205.2 27.02 LOCATOR BAKER LOCATOR(below locate) 2.980 11,802.5 6,228.0 26.32 SEAL ASSY BAKER 80-40 BONDED SEAL ASSEMBLY 2.980 ii Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT,10657.4 ii Top(ND) Top Inc/ Top(ftKB) (ftKB) 13 Des Com Run Date ID(in) 4 12,296.8 6,6873 16.67 NIPPLE 2.75"NIPPLE REDUCER SET IN LINER NIPPLE 10/16/2013 2.250 4 REDUCER li 12,296.8 6,687.3 16.67 PLUG 2.25"CA-2 PLUG SET IN NIPPLE REDUCER 10/18/2013 0.000 GAS LIFT;11306.6 It I Perforations&Slots I Shot Dens Top(ND) Btet(ND) (shotslt GAS LIFT;11 674.3- _ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 12,194.0 12,208.0 6,589.7 6,602.9 C-1,1R-35 4/21/2002 6.0 IPERF 2.5"Poweriet 12,352.0 12,392.0 6,740.2 6,778.6 A-5,A-4,A-3, 4/3/2004 6.0 APERF 2"HSD,60 deg phase i 1R-35 NIPPLE;11 729.5 1'fti>Erlulatictne Br Treatments w Min Top Max Btm Depth Depth Top(ND) Btm(ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 12,194.0 12,208.0 6,589.7 6,602.9 FRAC 11/8/2002 Lost 60%of treesaver rubber in Wellbore,screened out w/7.5 PPA on PERFS I Mandrel Inserts LOCATOR,11.776.2 i 1111 St ati C LOCATOR,11 777 0 pi f� on Top(ND) Valve Latch Port Size TRO Ron 1 No Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (ie) (psi) Run Date m I1 1 3,911.5 2,597.9 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 10/27/2013 SPACE OUTS2.96"Ill 2 6,910.5 3,799.6 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 10/27/2013 11,777.5 I-: ;I 3 9,134.4 4,705.1 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 10/27/2013 SEAL ASST,tt,8025 . 4 10,657.4 5,351.7 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 10/27/2013 '- 5 11,306.6 5,806.1 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 10/27/2013 .. 6 11,674.3 6,1143 Camco KBMG 1 GAS LIFT SOV DBEK CK-2 0.000 0.0 10/27/2013 ;Motes'General&Safety , End Date Annotation 10/21/2010 NOTE:View Schematic w/Alaska Schematic9.0 10/18/2013 NOTE: Dump Bail 4'CaCO3 on Plug PRODUCTION;384-11,973.8 - IPERF;12.1 .0.12,208 FRA94C;12,194 0 O-\ i I NIPPLE REDUCER;12,296.8 PLUG;12,296.81 1 ''' APERF,12,352.0-12.392.0 1 ) I :I LINER;11,769.1-12.637.0 ConocoPhillips Time Log & Summary Weltview Web Reporting Report Well Name: 1R-35 Rig Name: NABORS 7ES Job Type: RECOMPLETION Rig Accept: 10/20/2013 1:30:00 AM Rig Release: 10/28/2013 11:59:00 PM Time Logs Date From To Dur S. De•th E. De.th Phase Code Subcode T Comment 10/19/2013 24 hr Summary Rig released form 1E-09 at 23:59 HRS 10/18/2013. Jack up and move rig down pad so pits could move to 1R. Move pit module to 1R. Move Sub to 1R and start berming and placing mats for rig placement.Move rig over 1 R-35, raise derrick, center over well and complete beming and placing tanks. 00:00 01:30 1.50 MIRU MOVE MOB P Jack up rig and remove herculite, then move to middle of pad to allow pits to move around rig. 01:30 02:30 1.00 MIRU MOVE MOB P Hook up pits with truck and haul off pad to 1R pad. 02:30 04:30 2.00 MIRU MOVE MOB P Prep rig for derrick down; Bridal up. 04:30 05:00 0.50 MIRU MOVE MOB P Lay over derrrick. 05:00 12:00 7.00 MIRU MOVE MOB P Move rig from 1E to 1R pad. 12:00 16:00 4.00 MIRU MOVE MOB P Hang tree in cellar and adjust and set mats for rig. 16:00 18:30 2.50 MIRU MOVE MOB P Lay Herculite and set rig over 1R-35. 18:30 19:30 1.00 MIRU MOVE MOB P Berm up rig. 19:30 20:30 1.00 MIRU MOVE MOB P Raise derrick and scure. 20:30 22:30 2.00 MIRU MOVE MOB P Spot pits, lay mats and Herculite. Set cuttings tank and steps. set pit module. 22:30 00:00 1.50 MIRU MOVE MOB P Set mud shack,tool house and berm tanks and pits. 10/20/2013 Berm up and RU tanks and pit module. Take on brine of the pits and Accept rig at 01:30 10/20/2013. Continue to put rig together and RU to wellhead to pump KWF. PT all rig lines, Clear and check all lines to Tiger Tank then PT same. Lubricate out BPV. Initial pressures on well: Tbg= 12 psi, IA= 1700 psi, OA=250 psi. Bleed off IA and Tubing to vent gas off. Reverse circ 11.3 KWF around well. Shut in; SITP=70, SIIA= 110. Weight up active system from 11.2 to 11.4 ppg. 00:00 00:30 0.50 MIRU MOVE RURD P Finish berming pits and sub module. 00:30 01:30 1.00 MIRU MOVE RURD P turn on steam and hook up electricalon inter-tie. raise cattle shoot and complete pit RU. Accept Rig at 01:30 10/20/2013. Bring brine into the pits. 01:30 03:00 1.50 MIRU MOVE RURD P Clean rig, mezzanine, pipe shed, while taking on fluids to the pits. 03:00 04:30 1.50 MIRU MOVE RURD P RU and Bridle down, hang Bridle lines in derrick. 04:30 06:30 2.00 MIRU MOVE RURD P Prep cellar, RU manifold for well kill operations. install secondary valves on annulus, air test lines to Tiger Tank. 06:30 07:00 0.50 MIRU MOVE PRTS P PT stand pipe and surface to 3700 psi. Page 1 of 10 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 09:00 2.00 MIRU WHDBO PRTS P RU and pick up lubricator, PT to 2500 psi-Good. Pull BPV. Tbg= 1200 psi, IA= 1700 psi, OA=250 psi 09:00 12:00 3.00 MIRU WELCTI KLWL P RU all lines in cellar to Tiger tanks and PT to 2000 psi-Good. Rig up to bleed off well pressure and bleed to Tbg= 1050 psi, return fluid immediately, continued to bleed fuild. Crew change. 12:00 15:30 3.50 MIRU WELCTI KLWL P Reverse circulate 425 BBL of 11.3 ppg Brine to Tiger Tank. Stage pumps to 3 BPM; IA=570 psi, Choke=470 psi 15:30 16:00 0.50 MIRU WELCTI KLWL P Shut in well and pump off Tiger Tank while taking on fluids to the pits. 16:00 17:00 1.00 MIRU WELCTI KLWL P Bleed tubing to Tiger TankSITP=430 psi, SICP=390 psi. Bleed IA to TT, bleed tubing to TT. 17:00 20:00 3.00 MIRU WELCTI KLWL P Circulate 11.2 brine down tubing and take returns from the IA through the choke manifold. Stage pumps to 4 BPM;Tbg=520 psi, IA=60 psi;432 BBL pumped. 20:00 20:30 0.50 MIRU WELCTI KLWL P Shut in well; Initial SITP=60 psi, SIIA=80 psi. At 15 minutes SITP= 70 psi, SIIA= 110 psi. Bleed off 5.5 BBL, Shit in. 20:30 22:00 1.50 MIRU WELCTI KLWL P Monitor well shut in. Discuss with town the shut-in pressures and the displacement, Calculations made for kill weight and discussion of bullheading fluid to the perfs from the open GLM. The decision was made to bullhead 6 BBL to the"C"sand, weight up and circulate 11.4 around. Monitoring while shut-in; Initial SITP= 50 psi, SIIA=90 psi,At 15 minutes SITP=70 psi, SIIA= 110 psi. Weight up system to 11.4 ppg. 22:00 23:00 1.00 MIRU WELCTI KLWL P Bullhead 6 BBL down tubing with choke shut in at 1 BPM with Tbg= 140 psi, IA= 160 psi. Tubing pressured to 160 psi then settled to 140 psi for injecting. Shut-in at 23:00 SITP=50 psi, SIIA=90 psi. 23:00 00:00 1.00 MIRU WELCTI KLWL P Circulate 11.4 brine through Choke at 2 BPM with Tbg=200 psi, IA= 100 psi. At 23"59 with 2 BPM Tbg= 150, IA= 100 psi. 82 BBLS of 11.4 ppg pumped with 6 BBL loss. Crew change. 10/21/2013 Pump KWF of 11.4 ppg initially at 2 BPM slowing to 1 BPM to minimize losses and keep up with building 11.4 from 11.2 ppg brine. Hole could not take the 11.4 ppg so the weight was cut back to 11.2 ppg and circulated around. Hole monitored for 30 minutes and started on a slight vaccum then went static. BPV was installed and the tree was nippled down. Page 2 of 10 Time Logs • Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 00:00 03:00 3.00 MIRU WELCTL KLWL P Continue to pump 11.4 ppg brine down tubing at 1.1 BPM with Tbg= 30 psi, IA=20. Shut in; SITP=0, SIIA=40 psi. 03:00 04:00 1.00 MIRU WELCTL KLWL P Build mud volume;weight up to 11.4 ppg. 04:00 05:00 1.00 MIRU WELCTL KLWL P Resume pumping at 1 BPM with Tbg=30 psi, IA=20 psi. Total losses 53 BBLs with 398 BBL pumped. 05:00 05:30 0.50 MIRU WELCTL KLWL P Build volume;weight up to 11.4 pg. 05:30 07:30 2.00 MIRU WELCTL KLWL P Resume pumping 11.4 ppg at 3 BPM with unacceptable losses;Tbg=260 psi, IA= 10 psi. Shut in;Tbg=0 psi, IA=0-10 psi. Slow trickle on return during monitoring. Total losses 87 BBLS with 438 BBL pumped. 07:30 12:00 4.50 MIRU WELCTL KLWL P Change mud system to 11.2 ppg. Skim pits of contaminated mud and dispose. Monitor returns with continued slow stream from annulus. Crew change. 12:00 13:00 1.00 MIRU WELCTL KLWL P Blend all pits to 11.2 uniform and continue to skim off contamination. 13:00 17:00 4.00 MIRU WELCTL KLWL P Reverse Circulate 11.2 ppg brine through full open choke; reverse circ 212 BBL at 1.5 BBL, Tbg=0 psi, IA= 70 psi. Reverse circ 207 BBL at 2 BPM ;Tbg=0 psi, IA= 110 psi. 419 BBL pumped total with 87 BBL lost to well. 17:00 18:30 1.50 MIRU WELCTL OWFF P Monitor well, shut in; Initial Tbg= 10 psi, IA=0 psi. Final at 18:30 Tbg=0 psi, IA=0 psi. 18:30 19:00 0.50 MIRU WELCTL KLWL P Blow down all lines. 19:00 19:30 0.50 MIRU WELCTL OWFF P Monitor well open to atmosphere with no flow for 30 minutes. RD circ lines and manifold. 19:30 20:00 0.50 MIRU WHDBO NUND P RD all lines to tree and rig. 20:00 20:30 0.50 MIRU WHDBO NUND P Install BPV per FMC rep. 20:30 22:30 2.00 MIRU WHDBO NUND P ND tree and adapter. Inspect hanger threads-good. Install blanking plug with 13 1/4 RH turns. Check LH ACME threads on top with 9 3/4 LH turns. 22:30 00:00 1.50 MIRU WHDBO NUND P NU BOP, Install DSA on tubing head, set stack on DSA. _Crew change. 10/22/2013 NU BOPE and test. Tests Witnessed by Chuck Sheeve of AOGCC. RD test equipment and MU tubing pups for landing joint. Engage tubing hanger and pull 200K indicated weight to attempt to free string. String would not release. Repeated attempts to pull free without success. Call out E-line to cut tubing. E-line crews could not come out because they were houred out. Worked pipe, pulling maximum weight attempting to work free while waiting. 00:00 03:00 3.00 MIRU WHDBO NUND P NU BOP, riser and RU flow lines. Page 3of10 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 04:00 1.00 MIRU WHDBO BOPE P PU test joint and fill stand with water for testing. Testing witnessed by Chuck Sheeve of AOGCC. 04:00 06:30 2.50 MIRU WHDBO BOPE P Test BOPE; Upper and lower VBR, annular with 3.5"test joint, Kill, stand pipe, HCR and manula Kill, HT-38 FOSV and IBOP. and valves to 250/3000 psi for 5 minutes each. Tests witnessed by AOGCC rep. 06:30 07:00 0.50 MIRU WHDBO BOPE P LD 3.5"test joint and PU 2 7/8"test joint. 07:00 08:00 1.00 MIRU WHDBO BOPE P Test stack elements with 2 7/8"test joint 250/3000 psi for 10 minutes- good. Witnessed by AOGCC rep. 08:00 08:15 0.25 MIRU WHDBO BOPE P Perform Koomey drawdown tests. 08:15 08:30 0.25 MIRU WHDBO BOPE P Test BOP components closing times; Good. 08:30 09:00 0.50 MIRU WHDBO BOPE P LD 2 7/8"test joint and RD FOSV 09:00 10:30 1.50 MIRU WHDBO BOPE P Test blinds and inner and outer testing valves: Good. 10:30 11:30 1.00 MIRU WHDBO PULD P LD test tools and blow down alll lines and clear rigfloor. 11:30 12:00 0.50 MIRU RPCOM RURD P RU and pull blanking plug. Crew change. 12:00 13:00 1.00 COMPZ RPCOM RURD P RU FMC and pull BPV per FMC rep. 13:00 15:30 2.50 COMPZ RPCOM RURD P RU GBR tubing handling equipment and MU landing joint from 3 1/2" EUE 8rd tubing pups. 15:30 16:30 1.00 COMPZ RPCOM RURD P FMC rep BOLDS. 16:30 18:00 1.50 COMPZ RPCOM PULL P Engage tubing hanger and pull 170K indicated with 10.6'stretch. Continue to pull up to 200K indicated weight without movement. 18:00 22:00 4.00 COMPZ RPCOM PULL T Call out Halliburton E-line at 18:00, crew not rested and would be at 01:00. Continue to pull while waiting. 22:00 22:15 0.25 COMPZ WELCTI.SFTY T BOP drill with well secure 45 sec, CRT= 115 sec. AAR and drill good. 22:15 00:00 1.75 COMPZ RPCOM PULL T Continue to pull to 200K indicated with 10.6'stretch. Total loss to well 63 BBLs with hole fill on. 10/23/2013 Continue attempts to pull tubing free without success. RU wireline on rig. Set tubing is slips with 160K indicated up weight. Rig up E-line. RIH with locator and 5'of 160 grain string shot. Locate and fire shot at 11755'WLM. POOH and MU 2.5"RCT, RIH and fire cutter at 11755'WLM,time 16:44. Tension release felt at the surface. Pull 140K and free tubing, PU= 130K, SO=46K. RD HES E-line equipment and RU GBR tubing handling equipment. Pull tubing hanger and LD 3.5"tubing. Total loss to well 24 hour was 151 BBLs. 00:00 02:00 2.00 COMPZ RPCOM PULL T Continue to pull on tubing string to 200K while waiting on E-line crew and equipment. 02:00 06:00 4.00 COMPZ RPCOM RURD P Move in E-line truck and equipment to rig. RU equipment. 06:00 08:45 2.75 COMPZ RPCOM RURD P Continue to rig up crossovers to screw onto 3-1/2"EUE tubing sitting in slips w/130k total tension. Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:45 09:15 0.50 MIRU RPCOM ELNE P HES arm string shot w/160 grain/ft charge. Note: Tool string: 1-7/16"cable head, swivel, 7' 1.688"weight bar, 2" roller w/2-1/2"wheels, (2)5' 1.688" weight bars, 2"roller w/2-1/2" wheels, 5' 1.688"weight bar, CCL, 5' string shot w/160 gr/ft=total length of 35.02'. 09:15 12:00 2.75 COMPZ RPCOM ELNE P RIH w/160 grain/ft, 5' long string shot. 65 BBLs loss to hole 00:00 to 12:00. Crew change. 12:00 12:15 0.25 COMPZ RPCOM ELNE P Correlate string shot center @ 11755'. Fire shot. 12:15 13:30 1.25 COMPZ RPCOM ELNE P Trip out w/string shot assembly. Confirmed fired. 13:30 14:45 1.25 COMPZ RPCOM ELNE P Lay down tools string. Rig up tool string to cut tubing w/2.5"radial cutting torch. Note:Toolstring: 1-7/17"cable head w/1.375"fishing neck, swivel, 7' 1.688"weight bar, 2"roller w/2-1/2" wheels, (2)5' 1.688"weight bars, 2" roller w/2-1/2"wheels, mono conductor electric jars, (2) 1-11/16" knuckle jts, 1-11/16"Tekco adjustable centralizer,2"CCL, EMA 1.5", 1-11/16"Tecko adj centralizer, 2.5"radial cutting torch, 1-11/16" Tekco adj centralizer=total length of 47.58'. 14:45 15:00 0.25 COMPZ RPCOM ELNE P Make up crossovers to 3-1/2"EUE. 15:00 16:30 1.50 COMPZ RPCOM ELNE P RIH w/toolstring to cut 3-1/2"tubing @ 11755'(midjoint of joint above seal assembly). Indication of cut. 16:30 16:45 0.25 COMPZ RPCOM ELNE P Correlate w/CCL @ 11745.7'WLM to cut pipe @ 11755'WLM. Indication of cut @ 1644hrs. 16:45 17:45 1.00 COMPZ RPCOM ELNE P POOH w/RCT toolstring. 17:45 18:15 0.50 COMPZ RPCOM ELNE P Rig down HES tool string. Rig packoff assembly to the side. Bring sheave down. LD CCL, EMA, RTC, sheave. 18:15 18:30 0.25 11,755 11,755 COMPZ RPCOM PULL P Pick up on string to confirm free. Set back in slips. Pull tubing free with 140K. PU= 130K, SO=46K. 18:30 19:30 1.00 11,755 11,755 COMPZ RPCOM RURD P Continue to rig down HES E-line equipment from rig floor and off rig. 19:30 21:30 2.00 11,755 11,755 COMPZ RPCOM CIRC P Reverse circulate and condition hole with 11.2 brine; 40 BBL Deep clean sweep and chase with 120 BBL 11.2 ppg brine,40 BBL Deep clean sweep, 10 BBL 11.2 brine at 2 BPm with 125 psi. 34 BBL lose to well during circulation. 21:30 22:00 0.50 11,755 11,755 COMPZ RPCOM PULD P RU GBR to LD tubing. a. Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 00:00 2.00 11,755 10,862 COMPZ RPCOM PULL P LD landing joints and hanger with pup mesured at 3.26'. PU= 120K, SO=50K. LD 28 joints of 3.5"9.3# L-80 EUE 8rd and DS nipple. PU= 100K, SO=48K. 86 BBL lost to well 12:00 to 23:59. Crew change. 10/24/2013 Continue to pull 3.5"tubing, LD and strap same. Pull total 371 joints, hanger and pup, 5 GLM, 2 DS nipples. MU Baker BHA#1 Over shot with jars, bumper sub and 9-4 3/4 drill collars. Strap pipe, pick up 3.5"drill pipe and single in the hole. 00:00 12:00 12.00 10,862 45 COMPZ RPCOM PULL P Pull, LD and strap 3.5"tubing. LD total of 329 joints, 3 GLM out of the hole. PU=42K, S0=42K. Crew change. Note:A lot of holes in pipe f/jt 202 to 226 out of hole. 12:00 14:30 2.50 45 0 COMPZ RPCOM PULL P Pull, LD and strap 3.5"tubing. LD from joint 330 to 16.16'cut joint. Total tubing laid down; hanger and tubing pup, 371 joints of 3.5", 5 GLM and 2 DS nipples. Calculated fill on trip 39.7 BBL, actual fill 100.1 BBL; 60.4 BBL loss to well. 14:30 16:30 2.00 0 0 COMPZ RPCOM PULD P RD tubing handling equipment, change elevators, hang rig tongs, clean and clear floor. 16:30 18:00 1.50 0 0 COMPZ RPCOM PULD P Strap and tally pulled completion string. Remove from pipe shed. Break out DS nipples. 18:00 19:00 1.00 0 0 COMPZ FISH PULD P Stage Baker equipment to pipeshed and rigfloor. 19:00 21:00 2.00 0 311 COMPZ FISH PULD P MU BHA#1 as per Baker rep; Overshot and Extension, bumper sub and jars. PU=40K, SO=40K. Crew change. 21:00 00:00 3.00 311 1,413 COMPZ FISH TRIP P Pick up 3 1/2"drill pipe from 311'to 1413'. PU=57K, SO=53K. 10/25/2013 Continue to trip in hole with fishing assembly to 11730'. Circulate 1.7 BPM with 150 psi and 25 RPM with 9K torque. Stop pumps and rotation. Slack down and observed 5K down weight at 11749'. Continue to slack down to 11751'observed 20K down weight. PU to 240K indicated with a sudden loss of weight to 185Kwhile picking up to 11700'. Slack down to 11751'and set 20 down weight. PU and pull free at 270K indicated weight with a slow loss of weight to 185K as seals pulled free. Circulate 581 BBLs around until well in balance, monitor Static for 15 minutes. POOH. 00:00 00:30 0.50 1,413 1,413 COMPZ RPCOM SVRG P Service top drive and roughneck. 00:30 02:00 1.50 1,413 2,160 COMPZ FISH TRIP P Trip in the hole with 3.5"drill pipe singles from 1413'to 2160'. PU wt 60k, SO wt 54k. 02:00 02:30 0.50 2,160 2,160 COMPZ FISH TRIP P Move pipe into the shed and strap. 02:30 02:45 0.25 2,160 2,160 COMPZ RPCOM SFTY P BOP drill with well secure in 20 sec. and CRT=55 sec. 02:45 04:15 1.50 2,160 3,430 COMPZ FISH TRIP P Trip in the hole with 3.5"drill pipe from 2160'to 3430'. 04:15 05:00 0.75 3,430 3,430 COMPZ FISH TRIP P Move pipe into the shed and strap. Page 6of10 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:00 06:00 1.00 3,430 4,245 COMPZ FISH TRIP P Trip in hole with 3.5"drill pipe from the pipe shed to 4245'. PU=85K, S0=65K. 06:00 12:00 6.00 4,245 8,350 COMPZ FISH TRIP P PU and single in with drill pipe to 8350'; PU= 103, S0=70K. Crew change at 09:00. 12:00 14:30 2.50 8,350 10,887 COMPZ FISH TRIP P Trip in hole with 3.5"drill pipe from the pipe shed to 10887'. PU= 155K, SO=75K. 14:30 15:30 1.00 10,887 10,887 COMPZ RPCOM SLPC P Slip and cut drill line; 61'. 15:30 16:00 0.50 10,887 10,887 COMPZ RPCOM SVRG P Service drawworks and top drive, inspect brakes. 16:00 18:30 2.50 10,887 11,730 COMPZ FISH TRIP P Trip in hole with 3.5"drill pipe from the pipe shed to 11730'. PU= 185K, SO=85K. 18:30 19:00 0.50 11,730 11,667 COMPZ FISH FISH P Circulate 1.7 BPM with 150 psi and 25 RPM with 9K torque. Stop pumps and rotation. Slack down and observed 5K down weight at 11749'. Continue to slack down to 11751' observed 20K down weight. PU to 240K indicated with a sudden loss of weight to 185Kwhile picking up to 11700'. Slack down to 11751'and set 20 down weight. PU and pull free at 270K indicated weight with a slow loss of weight to 185K as seals pulled free. Pull up to 11667'to circulate. 19:00 20:00 1.00 11,667 11,667 COMPZ FISH SVRG P Service rig;grease washpipe to stop leakage. Blow down top drive. 20:00 23:30 3.50 11,667 11,667 COMPZ FISH CIRC P Circulate and condition at 11667';4 BPM with 1200 psi. Circulated 477 BBL and well flowing up drill pipe. Circulate 75 BBL and well flowing up drill pipe slowly. Circulate 29 BBL check with no flow. SPR taken at 20:30: Pump#1; 34 strk=320 psi, 51 strk=720 psi, Pump#2'34 strk=350 psi, 51 strk= 700 psi. 23:30 00:00 0.50 11,667 11,667 COMPZ FISH OWFF P Monitor well for 15 minutes for flow; Static. Blow down lines and install stripping rubber. Total losses last 24 hours at 118 BBL. 10/26/2013 POOH with seal assembly. Skate down for repairs. Pull seal assembly to surface and LD. Clear and clear floor, RU for handling tubing. Verify tubing staging and MU seal assembly. PU and run in with completion string. 00:00 06:00 6.00 11,667 3,625 COMPZ FISH TRIP P POOH laying down 3-1/2"dp with Baker fishing assembly from 11667' to 3625'. PU wt 165k @ 11667'. PU wt @ 3625'=75k. Time Logs • S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 11:30 5.50 3,625 3,625 COMPZ RIGMN7 RGRP T Columbia pipe handling machine malfunction-bolt backed out locking up machine travel of buggy/backstop of machine. Held PJSM w/all personal involved. Lock out/Tagout. Repair/replace bolt. Function test machine. 11:30 12:00 0.50 3,625 3,151 COMPZ FISH PULD P Continue to POOH laying down 3-1/2"dp with Baker fishing assembly from 3625'to 3151'. PU wt 70k @ 3151'. 12:00 15:00 3.00 3,151 311 COMPZ FISH PULD P Continue to POOH laying down 3-1/2"dp with Baker fishing assembly from 3151'to 311'. 15:00 16:00 1.00 311 60 COMPZ FISH PULD P Lay down Baker BHA#1 f/311'to fish.A total of 23.75 bbl fluid loss while tripping. 16:00 17:00 1.00 60 0 COMPZ FISH PULD P Lay down fish: cut jt(15.25')(Jt 372), 3-1/2"9.3 ppf L-80 pup jt(6.17'), Baker seal assembly(38.9'). Total fish layed down=60.32'. 17:00 18:00 1.00 0 0 COMPZ FISH PULD P Latch on to stand in derrick. Lay down 3 jts of 3-1/2"HT38 drill pipe. Pull wear bushing 18:00 20:30 2.50 0 COMPZ RPCOM RURD P Clean and clear floor of Baker BHA components. Stage completion components to rigfloor. RU tubing handling equipment for 2 7/8"tubing. 20:30 21:30 1.00 COMPZ RPCOM RURD P MU completion seal assembly. 21:30 22:30 1.00 COMPZ RPCOM RCST P Verify tubing and completion equipment to be run. PJSM for running completion. 22:30 00:00 1.50 COMPZ RPCOM RCST P Run 2 7/8"6.5#L-80 8rd EUE-mod tubing completion per running order to 987'. PU=36K, SO=33K 37 BBL loss to well last 24 hours. 10/27/2013 Continue to run 2 7/8"completion to 11767'confirm seal engagement with pump pressure and land to No-Go. Mark and space out. Pick up and reverse circulate in 1%corrosion inhibited brine. PU space out joints, make up tubing hanger and land; RILDS. Drop Ball&Rod, PT tubing and IA 250/3500, charted for 30 minutes; Good tests. Monitor well static for 30 minutes. Install TWC and test to 1000 psi for 10 minutes; Good. Prep to ND BOP. 00:00 09:00 9.00 COMPZ RPCOM RCST P Continue running 2 7/8"6.5#L-80 8rd EUE-mod tubing completion per running order to 11767'; PU=75K, SO=50K. 09:00 10:00 1.00 COMPZ RPCOM RCST P Make up tools, change out to long bales. RU head pin and circulating hose. 10:00 11:30 1.50 COMPZ RPCOM CIRC P PUmp 1 BPM with 125 psi and slack off and locate seal bore assembly with a 200 psi increase at 11797'. SHut down pump and open bleeder. Continue to slack off and tag No-Go @ 11812'. Pick up 3'for space out and mark. Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T 'Comment 11:30 12:00 0.50 COMPZ RPCOM RCST P LD joint 367 and replace with joint 373. Crew change. 12:00 14:30 2.50 COMPZ RPCOM RCST P MU XO to 3.5"tubing, hanger, landing joint. RU circulating lines and pump 1 BPM to verify seals engaged; Good. Pick up 6'. 14:30 18:00 3.50 COMPZ RPCOM CIRC P Circulate 400 BBL of 1%corrosion inhibited 11.2 ppg brine.at 4 BPM with 1000 psi. Followed by 40 BBL brine to clear surface lines. 18:00 19:30 1.50 COMPZ RPCOM RCST P Land tubing and RILDS per FMC rep. RD circulating lines. Drop Ball& Rod with rollers. 19:30 23:00 3.50 COMPZ RPCOM PRTS P Pressure test tubing 250/3500 psi for 30 minutes; Good. Bleed to 2500 on tubing side and hold. PT IA, 250/ 3500 psi for 30 minutes; Good. Tests charted. Bleed down all pressure and pump down the IA to shear SOV at 2225 psi. Pump 4 BBL both directions with 800 psi at 2 BPM. 23:00 23:30 0.50 COMPZ WHDBO PRTS P Install TWC as per FMC rerp and test to 1000 psi for 10 minutes; Good. 23:30 00:00 0.50 COMPZ WHDBO OWFF P Observe well for flow; No flow. RD circ lines and blow down lines, choke and standpipe. Crew change. 33 BBLs lost to well in last 24 hours. 10/28/2013 ND BOPS and NU tree. Tested tree packoff 250/5000 for 10 minutes; Good. Tested tree to 250/5000 psi for 30 minutes; Good. Pump 93 BBLs of diesel for freeze protect on well. U-tube for 2 hour to equalize. Rig down from tree and dress tree with valves. Orientation verified by DSO. FMC installed BPV and moved off well to 1 R-34. Rig release at 23:59. 00:00 02:30 2.50 COMPZ WHDBO NUND P ND BOPE, blow down all lines and RD same. Move BOP to pedestal. 02:30 05:00 2.50 COMPZ WHDBO NUND P NU Tree; orientation verified by DSO; Ducker, and installed per FMC rep. 05:00 07:30 2.50 COMPZ WHDBO PRTS P Test tree pack-off with FMC rep. 250/5000 psi for 10 minutes; Good test. Test tree to 250/5000 psi charted for 30 minutes; Good test. 07:30 08:00 0.50 COMPZ WHDBO RURD P MU tools to pull TWC, pull TWC. 08:00 10:00 2.00 COMPZ WHDBO FRZP P RU to tree to circulate diesel. PJSM with LRS. RU LRS to pump down IA with returns to cuttings tank from tubing. PT lines to 3000 psi. Pump 93 BBLs diesel with 2 BPM AT ICP=1400 psi, FCP= 1750 psi. Shut down and shut in. RD LRS. • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 12:00 2.00 COMPZ WHDBO FRZP P Open tubing and IA and allow to U-tube. IA=400 psi,Tbg=400 psi. After 1 hour bleed down to zero on both sides. Blow down lines and RD. At 12:00 Tbg=0 psi, IA= 100 psi, OA=220 psi. Crew change. 12:00 13:30 1.50 COMPZ WHDBO PRTS P Ru and PT lubricator for 5 minutes at 1000 psi; Good. 13:30 15:00 1.50 COMPZ WHDBO RURD P Per FMC rep install BPV with Lubricator. RD lubricator, close master valve and SSV valves on tree. Tbg=225 psi, IA=210 psi, OA=220 psi. 15:00 16:00 1.00 COMPZ WHDBO RURD P Remove Aux. IA valve; install flange and gauge; change bales, Inspect tires for move. 16:00 22:30 6.50 DEMOB MOVE RURD P Change out cement hose. Install Blak Jak washpipe on top drive. Change out SRL devices; cellar, A-legs, derrick ladder, and change out restraints on sheaves in derrick. 22:30 00:00 1.50 DEMOB MOVE RURD P RD and remove berming around pits and rig. RD interconnect hoses and power. Remove cuttings tank. Rig Released 10/28/2013 23:59 1 R-35 to 1 R-34 Page 10 of 10 Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, November 12, 2010 3:00 PM To: 'NSK Problem Well Supv' Subject: RE: 1 R -35 (PTD #201 -210) Approval Request Martin, As per the phone conversation it looks like you can flow the well as long as it meets your internal criteria. Guy Schwartz Senior Petroleum Engineer �R 20)D AOGCC ► NOV 16 793 -1226 (office) 444 -3433 (cell) From: NSK Problem Well Supv [ mai Ito: n1617 @conocophillips.com] Sent: Thursday, November 11, 2010 10:53 AM To: Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; CPF1 Prod Engr; Glessner, Dana Subject: RE: iR -35 (PTD #201 -210) Approval Request Guy, In response to your request for more information regarding the 30 producing day test on Kuparuk gaslifted producer 1R -35, I provide the following: In the course of evaluating the well for a patch or a rig workover to replace the production tubing, the most recent test data before the well failure indicated a test of 99% WC and 14751 GOR. This makes it difficult to justify any further work on the well. This test was uncharacteristic for the well which typically produces —75 bopd @ 70 -80% WC & <1000 GOR. Considering that the well failed a TIFL on 4/15/10 and was unable to be repaired prior to 5/13/10, we were prevented from obtaining any more tests to confirm the production. It is possible that the pattern is mature & watered out, but the evidence cannot be considered conclusive based upon the last test. To rely on that questionable data would make any further well work uneconomic. The request for further production testing with known TxIA (but a passing CMIT) is to determine if this well is capable of making oil at economic rates to justify a rig workover to replace the tubing. The primary data needed is 2 to 3 well tests once non - transient production begins to confirm the BLPD, WC, & GOR. Possible wellwork will include plug removal, tag TD, gaslift installation, and FSBHP. Please let me know if you need additional information. Martin From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com] Sent: Tuesday, November 09, 2010 2:04 PM To: Schwartz, Guy L (DOA) Subject: FW: 111-35 (PTD #201 -210) Approval Request 11/12/2010 Page 2 of 2 Guy, Can you give me an update on the status of this request? Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 -659 -7224 Cell 907- 943 -1720 / 1999 Pager 907 - 659 -7000 #909 i Well Supv 25, 2010 9:05 AM L(DOA) irity Proj; NSK Problem Well Supv; Glessner, Dana; CPH Prod Engr; CPH DS Lead Techs ,PTD #201 -210) Approval Request Guy, Kuparuk gaslifted producer 1 R -35 (PTD#201 -210) was reported to AOGCC as having sustained casing pressure on 04/16/10. Since that time we have completed a passing TAA Combo MIT and a caliper survey. Results of the caliper indicate that the well is incapable of being repaired without a rig worker. CPA[ requests permission to flow the 1 R -35 for a cumulative of 30 producing days with known TAA communication to collect data to justify a rig workover. Attached is a 90 day TIO plot, wellbore schematic and MIT form. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 - 659 -7224 Cell 907 - 943 -1720 / 1999 Pager 907 - 659 -7000 #909 11/12/2010 PaoAclivE D'u-gNOSriC SertvicES, INC. ~~~~ L Ti~AflfSn/I/1T.4L To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road SuiteC ,~, ~~=; ~ i=;i ~; w `` `1~~1~ Anchorage, AK 99518 ~ ~~~~° `''`~~"""'" Fax: (907) 245-6952 1) Caliper Report 2} 14-May-10 1 R-05 ~bl-al~ ~S~-bps Signed Print Name: Oate PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245.88952 E~NAII: fTM.~saf?~1'9~s~q~~sr*,aa~;~y~;l;r~.r;~se- WEBStTE: =A1+nl~td.~ea'~C33"/I~p.y3tT~ 1 Report / EDE 50-029-23050-QO ~ ~ - ~~'\ ~~; - ...=~ ~e v~- . - _ - ~~~ , C:\Documerris and Settings\Diane Williazns\Desktop\Transmit_Conoco.dopt l • • Memory Mult~Fnger Caliper ,~ Log Results Summary Company: ConocoPhillipsAlaska, Inc. Well: 1R~5 Log Date: May 14, 2010 Field: Kuparuk Log No.: 10632 State: Alaska Run No.: 1 API No.: 50-029-23050-00 Pipet Desc.: 3.5" 9.3 Ib. L-80 EUE 8RD MOD Top Log Intvl1.: Surface Pipet Use: Tubing Bot: Log Intvl1.: 11,717 Ft. (MD) Inspection Type : Corrosive 8 Mechanical Damage Inspection COMMENTS This caliper data is tied into the top of GLM 5 @ 11,693' (Driller's Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage. The caliper recordings indicate the 3.5" tubing logged appears to be in good to poor condition, with multiple holes /holes /possible hole recorded in 21 of the 382 joints logged. Most of the holes are recorded between joints 202 and 225 (6,350' - _7,080'). Other recorded damage appears as line corrosion, sometimes ' broadening into corrosion, recorded on the low side of the tubing from the bottom of GLM 1 to 8,750', as well as shallow line of pits and shallow pitting. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded. MAXIMUM RECORDED WALL PENETRATIONS Multiple Holes (100%) Jt. 205 @ 6,425 Ft. (MD) Multiple Holes (100%) Jt. 212 @ 6,662 Ft. (MD) Multiple Holes (100%) Jt. 211 @ 6,629 Ft. (MD) Multiple Holes (100%) Jt. 221 @ 6,935 Ft. (MD) Multiple Holes (100%) Jt. 220 @ 6,904 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas of cross-sectional wall loss (> 14%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS No significant I.D. restrictions are recorded. Field Engineer G. Elberton Analyst: HY. Yang Witness: 8. Boehme PraActive Diagnostic Services, Inc, % P.O, Box 1369, Stafford, Tx, 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS:_<memorylog.com Prudhoe Say Fieid Office Phone: (907) 659-2307 Fax: (907) 659-2314 ~p~~~l~ ~~~~~ • s Correlation of Recorded Damage to Borehole Profile ~ Pipe 1 3.5 in (-14.4' - 11705.1') Well: 1 R-35 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: May 14, 2010 A pprox. Tool De viation . A pprox. Borehol e Profil e 1 -9 50 -~ `~ 1535 100 ~, 3105 GLM 1 ,, s 150 a` ~- 4697 v ~ ~ ,- - -" u. I Z 200 6264 ~ ~ n. v o D GLM 2 250 ~ I, ~', 7858 300 , ~ 9428 GLM 3 ~f". 35U 11013 GLM 4 GLM 5 371 11705 0 5 0 1 00 Da mage Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 371 • • PDS Report Overview --~,.~~~,. Body Region Analysis Well: 1 R-35 Survey Date: May 14, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. 218527 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Analyst: HY. Yan Tubing: Nom.OD Weight Grade & Thread Norn.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f L-80 EUE 8RD MOD 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (%wall) ~ penetration body metal loss body 400 300 200 100 0 0 to 1 to 10 to 1% 10% 20% 20 to 40 to over 40% 85% 85% Number of ~oints anal sed total = 382 pene loss . 0 162 76 37 338 7 64 59 21 0 0 0 Damage Configuration (body ) 150 100 50 0 Isola?eci general lir.~~ ring hole J pons pitting corrosion corrosion corrosion ible hole Number of'oints dama ed total = 194 26 30 117 0 21 Damage Profile (% wall) ~ penetration body _, , rnetal loss body 0 50 100 n GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 Bottom of Survey = 371 Analysis Overview page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 FUF 8RD MOD Well: 1 R-35 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: May 14, 2010 Joint No. Jt. Depth (Ft.) Pc~n. Uls~•i (Ins.) Pen. Body (Ins.) Pen. °l~ McG~I liss °~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 -14 c) 0.01 4 ! 2.97 PUP 1 -9 U 0.02 7 3 2.94 2 23 a 0.02 ? 2.93 3 55 U 0.02 7 > 2.95 4 86 U 0.02 (~ 2.93 5 118 O 0.02 2.94 6 149 0 0.02 i ? 2.95 7 181 t ~ 0.02 t; _' 2.94 8 212 t i 0.02 t; _' 2.92 9 244 i) 0.02 > 2.92 10 275 i~ 0.02 tf ? 2.94 11 306 tl 0.02 ~ ? 2.95 12 338 O 0.02 7 ~' 2.94 13 369 U 0.02 ~~ _' 2.94 14 401 U 0.02 2.94 ~ 15 433 U 0.02 7 1 2.96 15.1 464 it 0 U t1 2.88 Camco DS Landin Ni le 16 466 O 0.02 7 2 2.93 17 496 U 0.02 9 3 2.93 18 527 i? 0.02 7 I 2.95 19 559 U 0.02 7 ~' 2.96 20 591 i. 0.02 7 2.94 21 622 i) 0.02 7 I 2.93 22 654 ! ~ 0.02 7 2.93 2' 685 l~ 0.02 7 ? 2.95 24 717 rj 0.02 7 2.93 25 748 t~ 0.02 i 2.96 26 779 ~. ~ 0.02 2.92 27 811 ~! 0.02 2.94 ~ 28 843 ~' 0.02 ~ ~ I 2.92 29 874 ~ I 0.02 ti 2.94 30 906 U 0.02 ti 1 2.94 31 937 U 0.02 7 2.94 32 968 a 0.02 7 ? 2.93 33 1001 n 0.02 7 ~> 2.95 -' 34 1032 ~ ~ 0.02 7 ' 2.94 35 1063 ~ ~ 0.02 2.94 36 1095 U 0.02 I 2.95 37 1126 , ~ 0.02 t. 2.93 38 1158 ~' 0.02 7 I 2.93 39 1188 i ~ 0.02 - 2.95 40 1220 ~~ 0.02 ~ ~' 2.93 41 1251 i~ 0.02 7 2.93 42 1283 a 0.02 2.94 43 1314 O 0.02 - 1 2.96 44 1345 ~ 1 0.02 ? 2.93 45 1377 0.02 ~ 2.94 46 1408 . ~ 0.02 i' 2.94 47 1440 i ~ 0.02 f3 _' 2.94 48 1472 i! 0.02 f3 2.93 __ Penetration Body Metal Loss Body Page 1 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD MOD Well: 1 R-35 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocvPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: May 14, 2010 Joint No. Jt. Depth (Ft) I'~•n. t)hsc•t (Ins.! Pen. Body (Ins.) Pc~n. % ti1ct,al loss °~„ Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 49 1503 O 0.02 i' 2.93 50 1535 (t 0.02 ~~ I 2.95 51 1566 O 0.01 (i ~' 2.95 52 1598 +? 0.02 7 1 2.93 53 1629 ! t 0.02 2.94 ~ 54 1661 U Q02 7 2.92 55 1692 t} 0.02 tt 2.96 56 1724 t~ 0.02 ' 2.95 57 1754 a 0.02 ~~ ~ 2.94 58 1785 U 0.03 12 2.93 59 1817 U 0.02 7 1 2.90 60 1849 11 0.02 1 2.93 61 1880 tl 0.02 ~? 2 2.94 62 191 1 r ~ 0.02 ~ 2.95 63 1943 i~ 0.02 ~ 2.93 ~ 64 1974 i) 0.02 9 I 2.94 65 2006 c? 0.02 ~ 2.95 66 2037 U 0.02 7 ~ 2.93 67 2069 U 0.02 9 ~ 2.91 68 2100 ~) 0.03 1 I 5 2.93 69 2132 a 0.02 6 ? 2.95 70 2163 U 0.02 9 ? 2.95 71 2195 U 0.03 11 i 2.94 72 2226 U 0.03 10 ? 2.95 73 2259 (> 0.02 7 ? 2.93 74 2290 U 0.02 ~) I 2.94 75 2321 ~ t 0.02 7 2.94 76 2353 t t 0.03 10 2.91 77 2385 i? 0.02 ~) _' 2.93 78 2416 a 0.03 11 4 2.93 79 2447 It 0.02 ti 2.93 80 2479 U 0.02 t3 -t 2.93 81 2510 U 0.02 tS I 2.97 82 2541 U 0.03 1~) ' 290 83 2573 U 0.02 ~ 2.96 ~ 84 2604 O 0.02 7 ? 2.94 85 263.5 U 0.03 1 U 5 2.92 86 2666 (t 0.03 1O 4 2.90 87 2697 t~ 0.02 - I 2.93 88 2729 tr 0.02 3 ~' 2.94 ~ 89 2 760 (t 0.01 i I 2.96 90 2791 a 0.01 F> ' 2.94 ~ 91 2823 t? 0.02 _' 2.93 92 2854 tt 0.02 6 2 2.95 93 2886 a 0.02 ' 2.95 94 2917 ~~! 0.02 (3 _' 2.96 95 2948 ~t 0.02 7 i 2.96 96 2980 it 0.03 11 i 2.94 97 3011 ~.? 0.03 I2 2.92 98 3042 ! t 0.03 1 1 _' 2.93 Penetration Body Metal Loss Body Page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD MOD Well: 1 R-35 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: May 14, 2010 Joint No. )t. Depth (Ft) I'~~n. Utxet (lns.} Pen. Body (Ins.) Pc°n. `~~~ Metal I oss °~~~ Min. LD. (Ins.) Damage Profile Comments (%wall) 0 50 100 99 3074 U 0.03 1 U Z 2.92 100 3105 O 0.02 9 2.94 101 3137 t) 0.03 1 ~' 2.92 Shallow line of its. 102 3168 ~ ~ 0.02 ~) 2.93 103 3199 i l 0.03 I 1 2.91 104 3231 U 0.03 t 3 2.94 Shallow line of its. 105 3262 t) 0.03 i ~! 2.96 Shallow line of its. 106 3294 U 0.02 £3 2.94 107 3325 )) 0.04 I -~ 2.93 Shallow line of its. 108 3356 t) 0.02 ~) 2.93 109 3388 n 0.03 11 2.93 110 3419 U 0.03 i "> ~ 2.94 Shallow line of its. 111 3451 U 0.03 l 5 2.94 Shallow line of its. 112 3482 U 0.03 12 I 2.96 113 3514 O 0.04 1 i 2.94 Shallow line of its. 1 14 3546 U 0.03 13 2 2.94 Shallow line of its. 115 3576 U 0.04 14 2 2.92 Shallow line of its. 116 3608 t) 0.04 14 z 2.96 Shallow line of its. 117 3639 +) 0.04 17 2.95 Shallow line of its. 118 3670 t) 0.04 17 r. 2.94 Shallow line of its. 119 3702 t) 0.03 1 ; 2.92 Shallow line of its. 120 3733 U 0.05 1 ~3 2.92 Shallow line of its. 121 3765 U 0.05 1 £3 -s 2.93 Shallow line of its. 122 3796 O 0.02 ri I 2.96 123 3828 t) 0.04 ? £i 2.95 Shallow line of its. 123.1 3859 t) 0.03 1 Z 1 2.93 PUP 123.2 3866 t} 0 0 U N A GLM 1 Latch @ 2:00 123.3 3873 a 0.05 20 2.93 PUP Shallow line corrosion. 124 3878 ~~ 0.10 3£3 t, 2.91 Line corrosion. 125 3910 l) 0.07 <'£9 2.93 Corrosion. - 126 3941 i) 0.08 30 i 2.93 Corrosion. 127 3973 tt 0.04 1 i ? 2.96 Shallow line corrosion. 128 4004 t) 0.06 24 ~ 2.93 Line corrosion. 129 4035 t) 0.08 32 -~ 2.93 Corrosion. - 130 4067 O 0.03 13 I 2.96 Shallow line corrosion. 131 4099 O 0.05 ~ 1 2.93 Line corrosion. 132 4130 U 0.06 24 ~ 2.94 Line corrosion. 133 4161 0 0.08 31 ~ 2.95 Corrosion. 134 4193 O 0.07 ~6 2.92 Line corrosion. 135 4224 t) 0.07 ~7 i 2.94 Corrosion. 136 4256 t) 0.10 ~1 4 2.91 Line corrosion. 137 4287 t) 0.09 >_; ~ 2.92 Corrosion. 138 4319 t) 0.08 ~ 1 2.93 Corrosion. 139 4350 ~~ 0.06 24 ~ 2.93 Corrosion. - 140 4381 i) 0.10 39 ~ 2.94 Corrosion. 141 4413 U.t)5 0.09 ;~ 4 .93 Corrosion. 142 4445 O 0.13 ~9 2.92 Corrosion. - 143 4476 t) 0.13 51 a 2.91 Line corrosion. 144 4508 I) 0.11 42 4 2.93 Corrosion. - 145 4539 U 0.09 36 i 2.93 Corrosion. - _ Penetration Body Metal Loss Body Page 3 • PDS REPORT JOINT TABI, ' Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD MOD Well: Body Wall: 0.254 in Field: ' Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • iLATION SHEET 1 R-3 5 Kuparuk ConocoPhillips Alaska, Inc USA May 14, 2010 Joint No. Jt. Depth (Ft.) Pcu. Ul~sci tln~.) Pen. Body (Ins.) Pen. % :Mrlal I~~ss "~, Min. LD• (Ins.) Comments Damage Profile {%wall) 0 50 100 146 4571 (? 0.08 iU 2.94 Line corrosion. 147 4602 O 0.09 )'i 2.93 Line corrosion. - 148 4634 O 0.12 46 i 2.93 Line corrosion. - 149 4666 (? 0.07 i 2.93 Line corrosion. 150 4697 (? 0.14 ~5 -1 2.96 Line corrosion. - 151 4728 (1 0.09 (5 2 2.92 Line corrosion. - 152 4760 t).t) ; 0.10 -1 i 2.94 Line corrosion. - 153 4792 U 0.07 ~£; 2.94 Line corrosion. - 154 4823 ~.U3 0.12 47 -£ 2.90 Corrosion. - 155 4854 O 0.26 lUU - 2.93 HOLE! 156 4885 t) 0.07 Zvi (, 2.92 Corrosion. 157 4917 u.tt5 0.09 i5 ~ 2.93 Corrosion. - 158 4948 O 0.11 42 2.92 Line corrosion. 159 4980 t1 0.08 tJ t~ 2.90 Line corrosion. 160 5008 (? 0.07 ~ i 2.93 Line corrosion. 161 5039 U.t1,- 0.09 ~ ~S 2.92 Line corrosion. 162 5070 O.tr; 0.08 30 i 2.94 Line corrosion. 163 5101 (1 0.09 36 ~ 2.94 Line corrosion. 164 5133 U 0.14 54 t 2.91 Line corrosion. 165 5164 !~.U~ 0.07 >7 3 2.92 Linecorr Sion. 166 5196 U 0.08 31 3 2.93 Line corrosion. 167 5227 U 0.09 i5 ~ 2.92 Line corrosion. 168 5258 t) 0.07 28 3 2.93 Line corrosion. 169 5289 U.U6 0.08 33 4 2.92 Corrosion. 170 5321 i) 0.08 31 3 2.94 Line corrosion. 171 5352 t) 0.08 33 4 2.93 Line corrosion. 172 5384 t).ti£S 0.16 65 5 2.93 Corrosion. 173 5415 U 0.10 39 3 2.93 Line corrosion. 174 5446 U.U_i 0.15 58 4 2.91 Corrosion. 175 5476 U 0.18 70 5 2.93 Line corrosion. 176 5508 t).t)7 0.17 65 -t 2.95 Line corrosion. 177 5540 U 0.17 65 r~ 2.93 Corrosion. 178 5571 t) 0.18 7U -# 2.92 Line corrosion. 179 5603 0.06 0.17 67 t, 2.93 Corrosion. 180 5634 U.07 0.17 (~„ t> 2.92 Line corrosion. 181 56Fi6 U 0.20 i 9 (~ 2.92 Corrosion. 182 5698 i?.l)8 0.18 7(1 2.93 Corrosion. 183 5728 ~).Ui 0.20 ~ 8 5 2.95 Line corrosion. 184 5760 U 0.12 ~tb 5 2.92 Line corrosion. - 185 5792 U.US 0.16 (~1 ~1 2.92 Line corrosion. 186 5823 U.O; 0.18 ~2 6 2.92 Line corrosion. 187 5855 U 0.16 t~4 ~ 2.95 Line corrosion. 188 5886 U.U:i 0.16 (> b 2.93 Line corrosion. 189 5918 U.U~ 0.14 56 b 2.93 Line corrosion. 190 5949 U.(15 0.16 b4 b 2.94 Corrosion. 191 5981 U.Uti 0.18 72 2.93 Line corrosion. 192 6012 U 0.17 67 i, 2.93 Line corrosion. - 193 6044 (~ 0.18 70 7 2.92 Corrosion. - 194 6075 ,) r)5 0.14 56 (~ 2.92 Line corrosion. 195 6107 O.tit, 0.15 59 ~ 2.92 Line corrosion. __ Penetration Body Metal Loss Body Page 4 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD MOD Well: 1 R-35 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: May 14, 2010 Joint No. Jt. Depth (Ft.) N~_~n. Ul~x~i (Ins.) Pen. Body (Ins.) Pen. "/~ Mct,rl I oss `;4~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 196 6138 O 0.11 44 4 2.91 Line corrosion. - 197 6170 U 0.15 59 t~ 2.94 Line corrosion. - 198 6201 ~ ~.n5 0.12 49 -1 2.92 Corrosion. - 199 6233 U.i~ 0.15 5? - 2.90 Line corrosion. - 200 6264 t~.10 0.17 (>~ !~ 2.93 Line corrosion. - 201 6296 ~l 0.13 50 -l 2.93 Line corrosion. - 202 6327 ~! 0.42 100 14 2.91 Multi le HOLLS ! 203 6359 ~~ 0.35 100 ~~ 2.93 HOLE ! 204 6391 ~~ 0.49 100 2.93 HOLE ! 205 6422 ' ~.! ~~ 0.72 100 i ~ 2.93 Multi le HOLES ! 206 6454 i Lt u, 0.52 100 1 ~1 2.89 Multi le HOLES ! 207 6485 ~ ~_«(~ 0.50 100 E~ 2.93 HOLE ! 208 6517 U.ZZ 0.46 1 UO 11 2.92 Multi le HOLES ! 209 6548 t~.~a; 0.26 l0i) 6 2.93 HOLE ! 210 6580 1.06 0.33 100 ~~ 2.93 HOLE ! - 21 1 661 1 t ~.t i~ 0.58 100 1 "> 2.92 Multi le HOLES ! 212 6643 ~~.Uf3 0.64 1 OU 13 2.93 Multi le HOLES ! 213 6674 U.11~ 0.49 l U0 11 2.91 HOLE 1 214 6706 ~~.i~(> 0.21 83 i 2.93 Line corrosion. 215 6737 i).IU 0.31 100 (~ 2.91 HOLE! r 216 6769 i1 0.45 100 '~ 2.92 Multi le HOLES 217 6800 t?.0? 0.43 100 ~~ 2.92 Multi le HOLES ! 218 6832 t)_Ub 0.22 B7 i 2.94 Possible HOLE ! 219 6863 x_).15 0.32 100 ~ 2.92 Multi IeHOLES! ~~~~ 220 6894 (7.U(, 0.53 100 '? 2.90 Multi le HOLES ! 221 6926 U.U ~ 0.57 100 ~~ 2.92 Multi le HOLES ! 222 6957 U.l)~ 0.19 73 -1 2.93 Corrosion. 223 6989 O 0.21 £>i ~, 2.94 Line corrosion. 224 7020 !).U(? 0.17 E,H ~~ 2.93 Line corrosion. 225 7052 !).~?6 0.41 7 iri) ~, 2.94 HOLE ! 226 7083 it 0.11 4; 2.93 Line corrosion. 227 7115 !~ 0.14 ~5 5 2.94 Line corrosion. -- 228 7146 t~ 0.13 5~ 3 2.91 Line corrosion. - 229 7179 t~ 0.07 Zfi ? 2.93 Line corrosion. 230 7210 U 0.13 51 -1 2.91 Line corrosion. 231 7241 i~ 0.12 4' 2.93 Line corrosion. 232 7273 (~ 0.11 •1 ~ ? 2.95 Line corrosion. 233 7305 ~1 0.12 47 ~ 2.93 Line corrosion. 234 7336 ~~.~>5 0.11 4> 2.92 Line corrosion. - 235 7368 U 0.05 Ltd 2.94 Line corrosion. 236 7398 i} 0.10 41 ~ 2.91 Line corrosion. 237 7430 (f.~1' 0.12 48 ~~ 2.96 Line corrosion. - 238 7461 ~~ 0.18 ~ 2 ~i 2.93 Corrosion. 238.1 7491 i~ 0.13 51 ~~ 2.91 PUP Corrosion. 238.2 7498 U 0 t1 i ~ N A GLM 2 Latch @ 11:00 238.3 7505 U.09 0.10 t'~ 2.95 PUP Line corrosion. 239 7511 !L~U 0.18 i~`) 2.92 Line corrosion. 240 7543 ~~ 0.09 ~~ 2.94 Line corrosion. 241 7574 i? 0.11 41 4 2.92 Line corrosion. 242 7606 U 0.08 33 ~ 2.92 Line corrosion. _ Penetration Body Metal Loss Body Page 5 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE SRD MOD Well: 1 R-35 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: May 14, 2010 Joint No. Jt. Depth (Ft) I'en. Upset (Ins.) Pen. Body (Ins.) Pen. °i~ Metal I oss ~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 243 7637 U.US 0.11 ~iZ 2.93 Line corrosion. 244 7668 t) 0.07 Zb 2.92 Line corrosion. 245 7700 U.t) 5 0.11 44 a 2.91 Line corrosion. - 246 7732 t).1)(~ 0.07 28 _' 2.92 Line corrosion. - 247 7763 t! 0.08 a 2.92 Line corrosion. - 248 7795 t! 0.04 1 ~ 2.93 Shallow line of its. - 249 7826 ~! 0.07 Zip 2.93 Line corrosion. 250 7858 ~; 0.05 ZU 2.94 Shallow line of its. 251 7888 U 0.07 Zt) 2.93 Line corrosion. 252 7920 n 0.07 2~~ ? 2.90 Line corrosion. - _ 253 7951 +! 0.05 X11 2 2.92 Line corrosion. - 254 7982 !! 0.07 Zia Z 2.91 Corrosion. 255 8014 i! 0.07 30 ? 2.92 Line corrosion. - 256 8045 i! 0.07 26 ~' 2.92 Line corrosion. 257 8077 (? 0.05 Z 1 4 2.93 Line corrosion. - 258 8109 t) 0.07 Z(> 2.92 Line corrosion. 259 8141 0 0.09 ,.. 2.93 Line corrosion. 260 8172 c) 0.07 ~U ~ 2.91 Line corrosion. 261 8202 i! 0.04 1 ~ ~' 2.93 Shallow line corrosion. ' 262 8232 U 0.06 24 3 2.91 _ Line corrosion. 263 8264 l! 0.08 33 b 2.93 Line corrosion. 264 8295 U 0.05 ZO ? 2.91 Shallow line corrosion. 265 8327 ~! 0.06 Z4 ~' 2.91 Line corrosion. 266 8358 U 0.04 16 _' 2.93 Shallow line corrosion. 267 8390 U 0.04 15 ~' 2.90 Shallow line corrosion. 268 8422 t! 0.05 Z I ~' 2.93 Line corrosion. 269 8453 l! 0.08 3l) 2.91 Line corrosion. 270 8485 0 0.05 2U 2.93 Line corrosion. ' 271 8516 +! 0.06 2.92 Line corrosion. - 272 8548 t! 0.06 '_' 292 Line corrosion. 273 8580 ~! 0.04 i 2.90 Shallow line corrosion. - 274 8611 i) 0.03 1.S 2.92 Shallow line corrosion. - 275 8643 t! 0.03 13 L 2.93 Shallow line corrosion. 276 8673 t! 0.05 18 Z 2.92 Shallow line corrosion. 277 8705 +) 0.06 25 2 2.93 Line corrosion. ~ 278 8737 +) 0.06 Z> 2.89 _ Line corrosion. 279 8768 t! 0.04 I ; ~' 2.92 Shallow line corrosion. 280 8800 t1 0.05 ? `? _' 2.93 Shallow line corrosion. 281 8831 U 0.04 2.93 Shallow line corrosion. 282 8862 t! 0.04 15 2.90 Shallow line corrosion. 283 8894 U 0.03 ? I 4 2.92 284 8925 t) 0.03 i _> ? 2.91 Shallow line corrosion. 285 8956 U 0.04 16 _' 2.91 Shallow line corrosion. 286 8987 t) 0.03 12 ~' 2.90 287 9019 t) 0.04 1 S i 2.92 Shallow line corrosion. 288 9050 t! 0.03 1(i ? 2.93 289 9082 t) 0.04 14 i 2.93 Shallow line corrosion. 290 9113 i! 0.04 15 _' 2.91 Shallow line corrosion. 291 9145 t! 0.03 I s 2.90 Shallow line corrosion. 292 9176 ! ~ 0.03 I ~' 2.93 _ Penetration Body IVtetal Loss Body Page 6 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 LUE 8KU MOD Well: 1 R-35 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal LD.: 2.992 in Country: USA Survey Date: May 14, 2010 Joint No. Jt. Depth (Ft) Pc~n. UIxE~! {In,.i Pen. Body (Ins.) Pen. °4> Me)~il I o5s "4, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 293 9208 '! 0.04 I4 2.90 Shallow line corrosion. 294 9239 ~? 0.02 ~) 2.92 295 9271 ~! 0.02 9 2.93 296 9302 a 0.02 ~) ; 2.90 297 9334 ~! 0.02 9 2.92 298 9365 (i 0.02 - .' 2.91 299 9397 ~) 0.02 ~3 2.91 300 942 8 + 1 0.02 7 I 2.93 301 9458 t! 0.06 _' ~.~ 2. 1 Shallow ittin . 302 9490 ~) 0.03 12 2.91 303 9522 a 0.03 11 ~ 2.89 304 9553 t) 0.02 ~) ~ 2.92 305 9585 t 1 0.02 - _' 2.93 ` 306 9617 i.) 0.02 - I 2.92 307 9647 ti 0.02 ~) 1 2.92 308 9679 !) 0,02 ti 2.92 309 9710 zi 0.03 I1 _' 2.91 310 9742 ~ 1 0.02 7 2.91 311 9773 U 0.02 2.92 312 9804 !? 0.03 11 ' 2.93 313 9836 !! 0.02 7 _' 2.94 314 9867 !! 0.02 7 _' 2.93 315 9898 ~ i 0.02 ~) ._ 2.91 316 9929 U 0.06 25 2.93 Line corrosion. 316.1 9961 U 0.04 1 t3 2.93 PUP Shallow line corrosion. 316.2 9967 u 0 U !) N A GLM 3 Latch ~ 11:30 316.3 9973 U 0.02 ~3 I 2.93 PUP 317 99$0 !1 0.04 (I 2.92 Shallow line of its. ~ 318 1001 1 t) 0.02 ~i 2.89 319 10043 !) 0.02 » 2.92 '~ 320 10073 i! 0.03 12 4 2.91 321 10105 ~ ! 0.03 1 1 ~' 2.92 322 10136 !_! 0.02 ~) 2.93 323 10168 U 0.02 _' 2.93 ~ 324 10198 0.03 0.02 ~) _' 2.91 325 10230 n 0.02 8 ! 2.94 .326 10262 l) 0.03 1 "3 2.93 Shallow line of its. 327 10294 ~) 0.02 rs 2.94 328 10324 ~ 1 0.02 ') 2.93 329 10356 ~! 0.02 2.94 330 10386 i) 0.03 lt) _' 2.93 331 10417 ~l 0.02 ~ 2.93 332 10448 U 0.02 ~1 1 2.94 333 10479 ~) 0.03 12 ~ 2.94 334 10509 ~! 0.03 1 ; 2.93 Shallow ittin . 335 10541 !? 0.02 2.93 336 10574 !) 0.01 0 ! 2.90 337 10606 U 0.02 9 ? 2.93 338 10635 U 0.04 17 - 2.93 Shallow ittin . 339 10667 ~) 0.02 ? -1 2.93 _ Penetration Body Metal Loss Body Page 7 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD MOD Well: 1 R-35 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: May 14, 2010 Joint No. Jt. Depth (Ft) I'e°n. t JF~sE~~ rln5.) Pen. Body (Ins.) Pen. % Metal I c,ss °'~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 340 10698 a 0.02 ~; 2.91 341 10730 U 0.02 9 -1 2.92 342 10763 (a 0.02 ~) 2.91 343 10792 ~ ~ 0.03 1 { > 2.92 344 10823 i 1 0.03 1 1 2.93 345 10856 a 0.03 1 i? _' 2.92 346 10887 i ~ 0.03 ! i ~ _' 2.9 347 10918 ~i 0.02 2.93 348 10 48 a 0.03 I ri ~, 2.93 -~ 349 10979 U 0.02 ~? b 2.91 350 11013 ~ ~ 0.02 E~ (~ 2.93 351 11045 ! ~ 0.02 c 2 2.94 352 11074 U 0.02 t3 2 2.92 353 11105 i' 0.02 ~ _' 293 354 11137 t~ 0.02 2.92 355 11168 !~ 0.01 (, i~ 2.91 355.1 11200 t~ 0.02 i I 2.94 PUP 355.2 11205 u 0 U tl N A GLM 4 Latch @ 6:30 355.3 11211 c, 0.03 12 ; 2.92 PUP 356 112 9 U 0.02 ~ ? 2.92 357 11248 i~ 0.04 14 1 2.91 Shallow ittin . 358 11280 U 0.02 9 _' 2.93 359 11313 ~) 0.02 9 ? 2.93 360 11341 ! ~ 0.02 ~ 2.92 361 11373 a 0.02 kt ~ 2.91 "' 362 11403 (! 0.03 E 1 2.93 363 11435 t~ 0.02 ~~ 2.93 ~~ 364 11465 ~ ~ 0.03 I U 2.91 365 11494 !? 0.03 13 '~ 2.90 Shallow ittin . 366 11530 ~_~ 0.02 8 2.91 367 11560 (! 0.02 ~> 2.90 368 11589 U 0.02 i3 2.90 369 1 1622 ~> 0.02 % ! ~ 2.89 370 11654 ~! 0.03 11 I 2.92 370.1 11684 ~~ 0.02 ~ ~: 2.93 PUP 370.2 11693 u 0 l; a N A GLM 5 Latch @ 2:00 370.3 11695 i ~ 0.03 12 4 2.92 PUP 371 1 1705 ! ~ 0.02 ti U 2.92 _ Penetration Body Metal Loss Body Page 8 ~ ~ ~ ~ ~ r ~ ~ i ! r ~ ~ ~ ~ ~ ~ ~ ~ PDS Report Cross Sections Well: 1 R-35 Survey Date: May 14, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. 218527 Company: Conoco Phillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf L-80 EUE 8RD MOD Analyst: HY. Yang, Cross Section for Joint 205 at depth 6425.38 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 94 Tool deviation = 70 ° Finger 7 Penetration = 0.72 im Multiple Holes 0.72 ins = 100% Wall Penetration HIGH SIDE = UP • Cross Sections page 1 PDS Report Cross Sections ~.-.- - S „ Well: 1R-35 Survey Date: May 14, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. 218527 Company: Conoco Phillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf L-80 EUE 8RD MOD Analyst: HY. Yang Cross Section for Joint 212 at depth 6662.18 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 90 Tool deviation = 75 ° Finger 8 Penetration = 0.642 i Multiple Holes 0.64 ins = 100% Wall Penetration HIGH SIDE = UP Cross Sections page 2 ~`-`\ ~ KUP ~ 1 R-35 ConoeoPllillips II Att ributes An le s MD TD al~r.,., In ~ W ellbore AHNWI 500292305000 FlNtl Name Well Status Ind (°) MD (mcBl KU PARUK RIVER UNIT PROD 6876 6,523.29 Ad Btm (RIB) 12,637.0 Comment X25lppm) Date Arrmtatlon Entl Dale KB-Drtl pt) Rig Relea se Dffie w u cro n -tR-ss atarzo l6 I s34a cni SSSV: NIPPLE 40 8/6/2009 Last WO: 42.30 12/10/2001 c-A ai Amotatlon Dep tli lltlB) Ontl Dale Amotatlon Last By Ertl Die Last Tag: SLM 12.508.0 2!7!2010 Rev Reason SET PLUG. GLV C/O Imosbor 4/18/2010 Casin Strin s A Stdllg a D Slnng ID Set Depth Se[ Depm (ND) Sttllg WI Sldn g Casing l ksalptlon M) fn) Top (NCe) ImcB) (KKel (IhslR) Qatl e SttlngT Thrtl '} CONDUC TOR 1 6 15.062 0.0 158.0 158.0 62.58 API5L... PEB CDNCll (TOR. SURFACE 95 /8 8.697 0.0 7,992.0 4.252.9 40.00 L-80 BTC tss PRODUC TION 7 6.151 0.0 11.974.0 6.384.8 26.00 L-80 BTC-MOD LINER 31 /2 2.992 11,769.0 12,637.0 9.30 L-80 SLHT NIPPLE 509 Tubin Strln s , Sttlrg O D String ID Se[ De Set Depth (ND) Stnng Wt Stnn g Tublrg l) esatpaon Ilnl PM Top (111(8) I~BI (PoCB) (lbslR) Gatl e stnng Ta p Thrd TUBING 3 1 /2 2.992 0.0 11,778.0 6,206.8 9.30 L-80 EUEBrdM OD GAS uEr, Other I n Hole A ll Jewel .Tubin Run 8 Retrievabl Fish etc. 3 &9] Top Depm (ND) Top Ind Top (RtCB) IRKBI !% Desg1 on Comment Rrn Date ID gn) cAS uFT 509 508.0 7.84 N IPPLE CAMCO LANDING'DS' LANDING NIPPLE 12/20/2001 2.875 ]512 3,897 2,592.3 67.07 G AS UFT CAMCO/KBUG/1/GLV/BK/.125/1338/Comment: STA 1 11/8/2008 2.920 7,512 4,D50.0 64.12 G AS LIFT CAMCO/KBUG/1/GLV/BK1.156/1352/Comment: STA 2 11!9/2008 2.920 9.984 5,041.3 66.58 G AS LIFT CAMCOIKBUG/1/GLVBK-5/.156/1335/Comment STA 3 11!9/2008 2.920 ~ 11,215 5,733.9 38.38 G AS LIFT CAMCO/KBUG/1lGLV/BK-5/.188/1357/Comment: STA4 ttll/2008 2.920 suRFADE,~ 7 9z 11,693 6,131.2 29.22 G AS LIFT CAMCO/MMGr1.5/OV/RK/.25//Comment STA5 4/17/2010 2.920 s 11.739 6,171.5 28.04 N IPPLE CAMCO'DS' NIPPLE 12/20!2001 2.818 11,739 6,171.5 28.04 P LUG 2.81"CA-2 PLUG 4/14/2010 0.000 cAS UEr, 11,769 6,199.0 27.93 P ACKER LINER-BAKER ZXP LINER TOP PACKER WITH HR 12/20/20111 4.4017 9.984 PROFILE 11,800 6,226.0 26.79 S BE LINER -BAKER SEALBORE EXTENSION W/COLLARS 12/20/2001 4.000 11,805 6,230.4 26.61 S EAL BAKER GBH-22 SEAL ASSEMBLY 12/20!2001 3.000 GP'j~1125 12,272 6,663.5 16.79 C ATCHER 2.71"CATCHER (OAL~8") 3/4/2010 0.000 12,297 6,687.5 16.67 N IPPLE LINER - HES'XN' NIPPLE WffH NO GO PROFILE W/ 12/2012001 2.750 2.812" BORE (BELOW PERFS) cos LIFT. 12,297 6,6875 16.67 P LUG 2.81"XN PLUG 3!4!2010 0.000 --- 12,541 6,922.2 14.68 C OLLAR BAKER LANDING COLLAR 12!20/2001 2.960 12,572 6,952.2 14.44 C OLLAR BAKER SINGLE VALVE FLOAT COLLAR 12/20!2001 2.960 NIPPLE, i,,]39 Perfora tions 8 Slots (LUG. 11.739 ~~ Top ITVD) etm ITVD) Dens Top Blm IpBI IRKBI I~BI Zone Date Ish~- l:orrmert 12,194 12,208 6,589.7 6,602.4 C -1, 1R-35 4/21/2002 6.0 IPERF 2.5"POwerjet PACKER. 12,352 12,392 6,740.2 6,778.7 A -5, A-4, A-3, 4/3/2004 6.0 APERF 2" HSD, 60 deg phase 11,76° 1 R-36 Stimula tions & Treatments Min Top Max Btm Top Depth Bosom Deptl1 Deptl1 Deptl1 (7VD) (ND) I~BI ~Bl ryncBl IRKB1 type Date CommM 12,194.0 12,208.0 6,589.7 6,602.4 F RAC 11!8/2002 Lost 60%oFtreesaver rubber inwellbore,saeened sae,ll.eoo t I7 5 PPA PERFS ou w . on sEA,L. tt eos PRODUCTION 11 974 IPERF, 12;194-12,208 FRAC, 12.194 I CATCHER, 12?72 NIPPLE t" J9] PLUG, 12,297 I~YEP.F 12 352-12 392 CGLLM, 12541 CDLLAR, 12572 LINER, 12,837 TD, 12,631 • • Page 1 of 1 Regg, James B (DOA) ~n ?~I-ZCo From: NSK Problem Well Supv [n1617@conocophillips.com] I Sent: Friday, April 16, 2010 6:09 PM ~~"~ ~` (~'t~ To: Schwartz, Guy L (DOA); Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: 1 R-35 (PTD 201-210) Report of SCP on IA Attachments: 1 R-35 schematic.pdf Guy, Tom, Jim Kuparuk gas lifted producer 1 R-35 (PTD 201-210) was reported with SCP on the IA. The TIO was 3250/3225/40. The immediate action .was to have slickline set a plug in the tubing to secure the well and bleed the tubing an A down. A leaking GLV is suspected. slickline will continue with further diagnos ics and repair if possible. Attached is a 90 day TIO plot and a schematic. Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 ~tiJ~~f P = ~ z~a~Ps`, SCE - 3 zzS~,s ~ ~~~~~, ~_.~ ~ 4~ 4 J~~u4 ~s ti1.c~c~ ~'„^mCa~1;v~ 0.C-~-w; ~~ ~~~~ ~~ C~ `'~ 4/19/2010 KRU 1 R-35 PTD 201-210 4/16/2010 Tln Pressures Plot TRN ANNL ANNULUS PRESSUR E TRENDS ~, ri n . 4000. sc ~~~.I.I. F???!~'`: WLKRU 1R-35 2DD. 4000 , .. _ - 4000. 3000. 3600 3000. r 4~+!'r. 900D. 3200 _1-~- - 2800 ~ n ~~ ~ .~ 2400 - V 2000 _ - ~ "~ 1600 _ __ _~ - - - - -- - -, t . , ,. _ _ - _ ~1 _ _ - - - i I 1200 i tisw J i D . I ----- - !!! - ~~ LL '~ ~~~,----" ~ - -~4s ~, , _ {~~~~ ~ - 0 . 800 ~._ ~ ~ i ~ ' y ~ •., -. 0. 400 ! t . I; - D, _ 0. 0 -- -------- --- ----~ _-- --------- - -- ----_ --- --- -- ------ --- - -- - ------ -_------- -------- -- -------------------------- ----------------------------------------------------------- ----- -------------- - --- ------ D. PLOT STAR"T TIME MINOR TIME P~~p"I' d?UI2A7`ION FL0'[' T:h[? "I'I~iV? 16-JAN-10 14:38 MASQR TIME WEEK +02160:00:00 HRS 16-APR-10 14:38 ~~~~ ~~~ PICK TI3iE ~rJ-+~~~~~s06t 4g SC TAG HAISE WL1R-35-CHOKE DESCRIPTION FLOW TUBING CHOKE P-VALIIE ??????? LATEST DRILLSITE WELL ~ PREY WELL SCRATCH 69 FLOW TUBING PRESSURE 7799972 lr 35 SCRATCH_69 FLOW TUBING TEMF ??????? ~ NEXT WELL ~' AI-P1R5002-35 GL CASING PRESSURE ??????? ~ ??????? ~-:f ° ~ `~~ OPERATOR 7?????? ~ OPERATOR VERIFIED SCRATCH 69 INNER ANNULUS PRES ~ ??7???? ~ SYSTEM AUTO ENTRY _ SCRATCH_69 OUTER ANNULUS PRES C~/k ??????? ~ HOTH U.A- • • ~~" ~~ KUP ~ ~ 1 R-35 . l Well Attributes Cdi1©COPI'lilllp5 __ _ Max Anyle & MD _. _ TD i "" ~' ' .. ... iit .~a~I;U'::t ~ -:!305000 ____ Fieltl Name KUPARUK RIVER UNIT _.__ Well Status lir~ll) PROD 68.76 t.:U tttK-8) 6,523.29 Act Btm (RKB) 12,637.0 ment H25 (ppm) Date Annotation End Date KB-Grd (ft) Rig Raleaae Dab _ waif e R ^]r Om2z~ 3~ 5h'r -V: NIPPLE 40 8/6/2009 LastWO: 42.30 12/10/2001 g_ J . , ~ t _ $ hemalk Actual ,~I~i~„~ Depth (ttKB) End Date Annotation Last Mod By End Date _ _ '.' I -~~.~ iLM 12.508.0 2!1/2010 Rev Reason: SET PLUG 8 CATCHER Imosbor 3/27/2010 Casin Strin s String OD Strang IG ~ _ Se[ Uep[h xt Deptn (ND} _ String Wt String -using Deacrl lion (in) (in) Top (RKB). (ftK8) (RKB) (Iba/R) Grade String Top Thr< k ~ CONDUCTOR 16 15.062 0.0 158.0 158.0 62.58 API5L... PEB coNDUCroR h. SURFACE 95/8 8.697 0.0 7,992.0 4,252.9 40.00 L-80 BTC 158 i i i NIPPLE 509 7E~ I I , { , _ l GAS LIFT, ~ r__'. 3,997 ~`_ _ GAS LIFT, -Jf L 7,512 ~ - '~ F C~ I SURFACE, i I 7,992 I GAS LIFT, L -- r: -- 9,964 T I ri GAS LIFT 11.215 ~ t-f+ ~ i ' I rr --1. GAS LIFT, I_ ._ 11,693 I 1 NIPP 11 7 ' ' , LE, 39 , ,,~ G F~ I ~__-d. PACKER. ' 11,769 - _._. __ ____._ ___._ ____. __ ___..__ ,_.. . 6BE, 11,800 SEAL. 11.805 ' PRODUCTION, I 11,974 IPERF, 12,184-12,208 FRAC, 12,194 CATCHER, 12,272 PLUG, 12,297 APERF, 12,352-12,392 Slring OD St ing ID Set Depth Set Depth (ND) String Wt String Tubing Descrlpnon 1~^( (~^) Top IRKS) (RKB) (ttKB) (lbslh) Grade Slrlng TOp Thrd TUBING '~ 3 1/2 2.992 0.0 11 778.0 6,206.8 9.30 L 80 EUE8rdMOD Other In Hole All_Jewelry: Tubin Run 8 Retrievable, Fish, etc.) _ ~__ _ Top Dapth (ND) Top Intl Too IRKBI (RKB) I°1 I Deserlotion ~ Comment I Run Oata ID Iinl 1 IX Slot$ Top (ND) Btm PROFILE 2.812" BORE (BELOW PERFS) Oena (ah... Comment 1R-3~~--- .~ Stimulations & Treatments ' euiw~n - -- - -- Min Top Max Btm Top Depth Depth Depth Depth (ND) IND) (ttKB) (RKB) (ftK8) (RKB) Type Date Comment 12,194.0 12,208.0 6,589.7 6,602.4 FRAC 11/8/2002 Lost 60% of treesaver rubber in wellbore, screened out wl1.5 PPA on PERFS COLLAR, 12,572 LINER. 12,637 TD, 12,fi37 i Con ~ " ocoPhiilips Alaska R.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 31, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 x', 6~,~,n ' ~ "'" ,:. `?ifi.i`', ~ _~;:.F _ Dear Mr. Maunder: ~b ~, a` 1C~ ~~3~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped August 15~' and 23`a 2009, and the corrosion inhibitor/sealant was pumped August 27~', 28;~ and 29~' 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions, Sincerely, / ~~ MJ Loveland ~ ~~~~~~~~~. ~~~ ~ ~ 2oos ~I~;~~~ p~d ~ Ge~ C~n~e.~a~n€ni~~i~r~ ~~~~,~6~~ ConocoPhillips Well Integrity Projects Supervisor ~ . \ 1 . . .'t . . - ' ~ • ' ~ ~ ~ -~'.. ~ t ~ 't ~ ~ ,~ LG~.~ J .. _ P, •' . " . _ . . , . . , .~, f, ~.... ~ ConocoPhiliips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/29/09 ~ Q ae n Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitod sealant date ft bbls ft al 1 R-01 B 50029214040200 . 2001560 13'7" 2.0 26" 8/15/2U09 5.1 8/27/2009 1 R-02 50029214050000 1851760 80' 13.30 23" 8/23/2009 4.7 8/28f2009 1 R-03A 50029214060100 2000210 15' 3.00 27" 8/15/2009 5.3 8/28/2009 1R-04 50029214070000 1851780 15'2" 3.00 26" 8/15/2009 5.1 8/28/2009 1 R-05 50029213300000 1850700 20'9" 2.20 23" 8/15/2009 3.8 8/28/2009 1 R-06 50029213310000 1850710 14' 2.00 23" 8/15/2009 3.8 8/28/2009 1 R-07 50029213320000 1850720 44' 5.00 24" 8l15/2009 4 8i2812009 1R-OS 50029213330000 1850730 8' 1.00 21" 8/15/2009 13.7 S/28/2009 1 R-09 50029213500000 1850950 9' 1.20 25" 8/15/2009 4.3 8/28/2009 1 R-10 50029213510000 1850960 32' 5.40 22" 8/15/2009 3.4 8l28l20Q9 1 R-11 50029213520000 1850970 47' 6.00 38" 8/15/2009 13.9 8/28/2009 1R-12 50029213530000 1850980 38' 6.00 24" 8/15/2009 4 8/28/2009 1 R-13 50029213850000 1851500 10' 0.50 25" 8/15/2009 4.3 8/29/2009 1 R-15 50029213870000 1851520 21'4" 4.00 35" 8/15/2009 12 8/29/2009 1R-16 50029213880000 1851530 12'6" 9.00 21" 8/23/2009 3.8 8/29/2009 1 R-17 50029222120000 1911140 20" N/A 20" N/A 4.4 S/28/2009 1R-18 50029221880000 1910870 9'4" 1.20 21" 8/1512009 3.7 SI28/2009 1 R-19A 50029221850100 1910850 18" N/A 18" N/A 10.2 8/29/2009 1 R-20 50029222070000 1911080 8'4" 2.00 19" 8/15/2009 11.3 8/29/2009 1R-22A 50029222060100 1990490 16" N/A 16" N/A 9 8/29/2009 1 R-23 50029222000000 1911010 18'8" 2.30 39" 8/15/2009 13.9 8/29/2009 1 R-25 50029221530000 1910470 7'4" 1.50 26" 8/15/2009 5.1 8l27/2009 1 R-26 50029221930000 1910920 7' 3.50 38" 8/23/2009 13.9 8/28/2009 1R-27 50029222010000 1911020 18" N/A 18" N/A 5.1 S/28/2009 1 R-29 50029221950000 1910940 18" N/A 18" N!A 4.1 8/28/2009 1 R-35 50029230500000 2012100 18" N/A 18" N/A 5.3 8/29/2009 1 R-36 50Q29230570000 2012270 19" N!A 19" N/A 5.3 8/29J2009 ~~rN~~~~~t~~i Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 , ~ - ATTN: Beth ~ ,.~ ~ ''',,~,... NO.4914 1 !"', ~. ,~ Well Job # Log Description ~~-- - Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 10/14/08 1L-23 12097405 SBHP SURVEY j 07/17/08 1 1 2A-17 11975793 PRODUCTION PROFILE 9 - JL O pC 09/10/08 1 1 3G-25X 12080437 LDL ~ - 3 C.((o 09/21/08 1 1 2C-04 12100444 INJECTION PROFILE C L / 09/14/08 1 1 3M-13 12096541 LDL - (~L( ( C~ 09/10/08 1 1 2Z-13A 12100446 LDL Q(o- ('}O ~U 09!15/08 1 1 1 F-06 12096510 PRODUCTION PROFILE 07/17/08 1 1 3C-14A 12080436 SCMT - ~' S-'a. 09/22/08 1 1 iC-111 12100451 INJECTION PROFILE -t p - 09/20/08 1 1 30-15 12100452 LDL - ~ SQ 09/21/08 1 1 1C-117 12100453 INJECTION PROFILE o 09/23/08 1 1 f R-11 11966277 SBHP SURVEY S- (~ 09/25/08 1 1 1R-35 11966279 SBHP SURVEY _ ~ 09/25/08 1 1 1 R-14 11966286 LDL ( 09/29/08 1 1 2X-18 12080443 PRODUCTION PROFILE 09/30!08 1 1 iR-34 12080444 _ GLS ~jL .- 10/01/08 1 1 2A-13 12096547 PRODUCTION PRO ILE .= L %~'dSCj 10/02/08 1 1 1D-01 12097422 GLS 10/03/08 1 1 1 R-07 12097425 PRODUCTION PROFILE ter: -~ ( 10/06/08 1 1 1H-19 12096548 INJECTION PROFILE L 10/03/08 1 1 1 B-16 12097426 GLS Cj - =' 10/07/08 1 1 3B-09 12100442 PRODUCTION PROFILE - 09/12/08 1 1 3K-103 12096550 USIT - 10/06/08 1 1 2X-05 12096551 INJECTION PROFILE - ('~ 10/07/08 1 1 1B-04 12096552 INJECTION PROFILE -- ~ 10/08/08 1 1 1A-02 12096553 INJECTION PROFILE ~ 10/09/08 1 i 16-16 12096554 PRODUCTION PROFILE G)C~ .r G 10/10/08 1 1 2D-15 12096555 PRODUCTION PROFILE ~'L~C :, 10/11/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • 11/21/06 Sc~lIIDbepgel' NO. 4049 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 9 (DOn Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 i'lO) Q l ~f,j,\"~h),~;:;;n & l - U' ~Vð~,'~"": \:oš...--J ( L Field: Kuparuk Well Job# Log Description Date BL Color CD 2U-09 11416231 SBHP SURVEY 10/29/06 1 3J-18 11483494 GLS 11/13/06 1 3J-13 11483495 INJECTION PROFILE 11/14/06 1 1R-07 11486070 SBHP SURVEY 11/11/06 1 2X-17· 11486068 PRODUCTION PROFILE 11/09/06 1 1 0-36 . 11486077 SBHP SURVEY 11/19/06 1 10-120 - 11486073 INJECTION PROFilE 11/14/06 1 1 R-35 - 11486074 PROD PROFilE-INCOMPLETE OPERATION 11/15/06 1 t Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. r /.1t--- . . . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_ Inserts\Microfilm _ Marker. doc ~ / M~ ~~~t.1 DATA SUBMITTAL COMPLIANCE REPORT 4/29/2004 Permitto Drill 2012100 Well Name/No. KUPARUK RIV UNIT 1R-35 Operator CONOCOPHILLIPS ALASKA INC ~. '-'td. i Y. Ilhv À~~} '{!pI No. 50-029-23050-00-00 MD 12630 lVO 7008 --- Completion Date 4/21/2002 --,- Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey (~.[...--/ \ -./ '- --- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) Log/ Data Type ¡¿:'og CGg [,ßD C Pdf ~.D Electr Digital Dataset Med/Frmt Number Name Log Log Run Scale Media No 5 BS 1 5 BS 1 Interval Start Stop 11500 12470 11500 12470 123 12630 123 12582 OH/ CH Received Case 5/17/2002 Case 5/17/2002 Case 11/6/2002 Open 4/19/2002 ') 11350 10763 Comments Digital Well Log Data ~ Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? Y {J¡) Daily History Received? ~/N Œ>N ) Chips Received? ( Y'"f-N- ~ Formation Tops Analysis Received? Comments: Compliance Reviewed By: ~ Date: ~v! ~ ~~Y' J ,-......, ..-... Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 ConocÓPhillips May 13, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 1 R-35 (APD # 201-210) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operations on the Kuparuk well 1 R-35. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, t{ . Jltv~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad RECEIVED MAY 14 2004 Alaska Oil & Gas Cons. Commission Anchorage ./ ~ "...... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RepairWeli 0 Pull Tubing 0 Operat. ShutdownD Abandon 0 Alter Casing 0 Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 36' 1. Operations Performed: Stimulate 0 Other 0 Waiver 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 201-2101 6. API Number: 50-029-23050-00 Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development - 0 Stratigraphic 0 Exploratory 0 Service D 9. Well Name and Number: 1 R-35 8. Property Designation: ADL 25627 & 256351 ALK 2560 11. Present Well Condition Summary: 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION LINER Perforation depth: measured 12642' feet true vertical 7009' feet measured 125M' feet true vertical 6896' feet Length Size MD 122' 16" 158' 7883' 9-5/8" 7923' 11936' 7" 11974' 868' 3-1/2" 12637' Plugs (measured) Junk (measured) TVD Burst Collapse 158' 4225' 6385' 7008' Measured depth: 12194'-12208',12352'-12392' RECEIVED MAY 1 4 2004 true vertical depth: 6590'-6603',6740'-6779' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 11778' MD. Packers & SSSV (type & measured depth) pkr= BAKER ZXP LINER TOP PACKER WITH HR PROFILE pkr= 11769' sssv= NIP sssv= 509' 12. Stimulation or cement squeeze summary: Alaska Oil & Gas Cons. Commission Anchorage Intervals treated (measured) N/A 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Me! Water.Bbl 827 480 849 1314 15. Well Class after proposed work: Exploratory D Development 0 Service 0 16. Well Status after proposed work: oil0 GasD WAGD GINJD WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations_X Form 10-404 Revised 04/2004 Contact Printed Name Signature Oil.Bbl 322 487 Casinq Pressure Tubinq Pressure 369 224 WDSPLD Mike Mooney @ 263-4574 Mike Mooney 4J.- I{ -j Title Phone Wells Group Team Leader Date </13!¡¡f Preoared bY shar:IA~suo-Drake 263-4612 MAY 1 A. 1nft4 RØOMS 8FL Submit Original Only ,"-""" .- ConocoPhillips Alaska, Inc. TUBING (0-11778. 00:3.500. 10:2.992) SURFACE - (0-7992. 00:9,625. Wt:40.00) ~RODUCTION (0-11974, 00:7.000, Wt:26.00) NIP :11739-11740. 00:3.750) PKR :11769-11770, 00:5.980) LINER :11769-12637, 00:3.500, Wt:9.30) Perf :12194-12208) FRAC :12194-12208) NIP :12297-12298, 00:4.280) Perf :12352-12392) SHOE ;12635--12636, 00:4,280\ 7- ~ , z: " I I ] J ~ API: 500292305000 SSSV Type: Nipple Well Type: PROD Orig 12/10/2001 Completion: Last W/O: Ref Log Date: TD: 12642 ftKB 69 6523 Annular Fluid: Reference Log: Last Tag: 12514 Last Date: KRU Angle @ TS: 21 deg @ 12143 Angle @ TD: 14 deg @ 12642 Rev Reason: GLV design Last Update: 4/27/2004 Description BAKER ZXP LINER TOP PACKER WITH HR PROFILE BAKER SEALBORE EXTENSION W/COLLARS HES 'XN' NIPPLE WITH NO GO PROFILE W/ 2.812" BORE (BELOW PERFS) BAKER LANDING COLLAR BAKER SINGLE VALVE FLOAT COLLAR BAKER 'V' SET SHOE Description CONDUCTOR SURFACE PRODUCTION LINER Size 16.000 9.625 7.000 3.500 Top 0 0 0 11769 Bottom 158 7992 11974 12637 Interval 12194 - 12208 12352 - 12392 Interval 12194 - 12208 MD TVD Man Man Type V Mfr V Type VOD Latch Mfr 1 3897 2592 CAMCO KBUG GLV 1.0 BK-5 2 7512 4050 CAMCO KBUG OV 1.0 BK-5 3 9984 5041 CAMCO KBUG DMY 1.0 BK-5 4 11215 5734 CAMCO KBUG DMY 1.0 BK-5 5 11693 6131 CAMCO MMG DMY 1.5 RKP Description CAMCO LANDING 'DS' LANDING NIPPLE CAMCO 'DS' NIPPLE BAKER GBH-22 SEAL ASSEMBLY PKR SBE NIP 12541 6922 12572 6952 12635 7013 COLLAR COLLAR SHOE TVD 158 4253 6385 7015 Wt Grade Thread 62.58 API5LGrB PEB 40.00 L-80 BTC 26.00 L-80 BTC-MOD 9.30 L-80 SLHT Grade L-80 Thread Port TRO Date Run 0.188 1383 4/12/2004 0.250 0 4/12/2004 0.000 0 4/12/2004 0.000 0 10/29/2002 0.000 0 11/5/2002 1 R-35 Vlv Cmnt ID 2.875 2.818 3,000 ID 4.400 4.000 2.750 2.960 2.960 2.960 r--.., ~ 1R-35 Well Events Summary D~ &m~ry 04/03/04 PERFORATED: 12352'-12392',6 SPF POWERJET -- DID NOT TAG 0 0 [Perf] 04/12/04 NEW GAS LIFT DESIGN, GLV @ 3897', OV @ 7512' & DV @ 9984' RKBDD[GLV, Scale] ~ ...-.. Mike Mooney Wells Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 Conoc~iIIi pS December 11 , 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 1 R-35 (201-210) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the Kuparuk well 1 R-35. It has also come to our attention that the total depth is actually 12' deeper than previously reported. The total depth has been corrected on the attached report. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, )//,fiI/~ M. Mooney Wells Team Leader CPAI Drilling MM/skad RECEIVED DEC 11 2002 Alaska Oil & Gas Gons. Commission Anchorage .~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS '- 1. Operations performed: Operation shutdown- Pull tubing - 2. Name of Operator ConocoPhillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 4732' FNL, 5134' FEL, Sec. 17, T12N, R1OE, UM At top of productive interval 2105' FNL, 58' FWL, Sec. 9, T12N, R1OE, UM At effective depth At total depth 1996' FNL, 5157' FEL, Sec. 9, T12N, R10E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing CONDUCTOR SURFACE PRODUCTION LINER LINER Size 16" Length 122' 7883' 11936' 868' 9-5/8" 7" 3-1/2" Perforation depth: measured 12194' - 12208' true vertical 6590' - 6603' Tubing (size, grade, and measured depth) Stimulate _XX Alter easing- 5. Type of Well: Development - X Exploratory - Stratigraphic - Serviee- (asp's 539830,5991750) (asp's 544952, 5999688) (asp's 545015, 5999794) 12642 feet 7009 feet Plugs (measured) 12496 feet 6879 feet Junk (measured) Cemented 320 sx AS I 494.5 bbl AS Lite, 399 bbls LiteCrE 1BO sx Class G 42.9 bbls Class G 3-1/2",9.3#, L-BO Tbg @ 11819' MD. Packers & SSSV (type & measured depth) BAKER ZXP LINER TOP PACKER WITH HR PROFILE @ 11769' MD. CAMCO LANDING 'OS' LANDING @ 509' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) 12194' - 12208' MD Treatment description including volumes used and final pressure PLACED 60214# OF 16/20 CERAMIC PROPPANT BEHIND PIPE 14. Representative Daily Averaae Production or Injection Data Oil-Bbl Gas-Me! Water-Bbl 929 1349 Subsequent to operation 15. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations _X Oil - X Gas - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,j I.J / Michael Mooney ~ ~ Prior to well operation 1854 "90MS BFL Form 10-404 Rev 06/15/88. ~,--- 747 Title: Wells Team Leader Plugging - Perforate - Repairwell- Other- 6. Datum elevation (DF or KB feet) RKB 36 feet 7. Unit or Property name Kuparuk Unit 8. Well number 1 R-35 9. Permit number / approval number 201-210/ 10. API number 50-029-23050 11. Field / Pool Kuparuk Oil Pool Measured Depth 158' 7923' 11974' 12637' True vertical Depth 158' 4225' 6385' 7008' RECEIVED DEC 1 1 2002 Alaska Oil & Gas Cons. Commission Anchorage Casing Pressure Tubing Pressure 188 284 31 Suspended - Service - Questions? Call Mike Mooney 263-4574 Date /72/¡c;It> Z prepare:;b7s;~ron Allsup-Drake 263-4612 Db C / / 'fì¡. ,"".',. '-uu,-' ~ SUBMIT IN DUPLICATE Date 11/08/02 11/09/02 ..~ ~ 1 R-35 Event History Comment PUMP FRACTURE TREATMENT. PLACED 60,214# OF 16/20 CERAMIC PROPPANT BEHIND PIPE, THEN SCREENED OUT WITH 7.5 PPA ON PERFS. PUMPED A TOTAL OF 89,763# OF PROP, LEFT 29,549# OF PROP IN WELLBORE. LOST 60% OF TREESA VER RUBBER IN WELLBORE. [FRAC-REFRAC] POST FRAC CLEANOUT USING 640 BBLS SLICK WATER AND 290 BBLS DIESEL TO PBTD @ 12507' CTM WITH 110% TO 125% RETURNS - FLOWED WELL TO TANK AND TURNED OVER TO OPERATIONS [FCO] ,- Page 1 of 1 11/25/2002 ,--'- --.., ~D /~ ~/O } 1359 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 01,2002 RE: MWD Fonnation Evaluation Logs lR-35, AK-MM-11190 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Rob Kalish, Speny-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 lR-35: Digital Log Images 50-029-23050-00 1 CD Rom RECEIVED NoV °6 2002 Alaska Oit & G as CO/jf: f'- 11- v. 1JillT1111i00. I"IIIChOfage ....JlOn ~ /', PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 R. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 May 24, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for lR-35 (201-210) Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Kuparuk welllR-35. If you have any questions regarding this matter, please contact Scott Lowry at 265-6869. Sincerely, ~~ R. Thomas Kuparuk Drilling Team Leader PAl Drilling RT/skad RECEIVED JUN 0 5 2002 Alaska Oil & Gas Cons. commission Anchorage ORIGIN/~L ~ .~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil [2] Gas 0 Suspended 0 Abandoned 0 Service 0 2. Name of Operator ~"~i.<XiÄ--i¡> 7. Permit Number PhillipsAlaska,lnc. t,<~¡ 201-2101 3. Address ;' ! "":1 8. API Number P. O. Box 100360, Anchorage, AK 99510-0360 \",~»., ' . ',,', .~.\ 50-029-23050-00 4. Location of well at surface -- ',', ,:"t...,,~:~.:~.~. 9. Unit or Lease Name 546' FSL, 145' FWL, Sec. 17, T12N, R1OE, UM f GOMPLr:~i;orJl (ASP: 539830, 5991750) Kuparuk River Unit ~~~; ::~~~;~ :~,a~ec. 9, T12N, R10E, UM : J/}21 Dt: (ASP: 544952, 5999688) 10. W~I~~~;ber At Total Depth J -VER~O ~ 11. Field and Pool 1999' FNL, 121' FWL, Sec. 9, T12N, R1OE, UM l:::-~ (ASP: 545015, 5999794) Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk River Pool RKB 36 feet ADL 25627 & 25635, ALK 2560 12. Date Spudded 13. Date T.D. Reached 11 D~!e,c:z7.Pb~' Or Aba~1.. 115. Water Depth, if offshore 16. No. of Completions November 14, 2001 December 4,2001 ¡tr.'becP,(,1:)9r ~ rP° N/A feet MSL 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 12630' MD 1 7008' TVD 12541' MD 1 6922' TVD YES [2] No 0 Camco Nipple @ 509' 22. Type Electric or Other Logs Run GR/Res/Dens/Neutron,PWD, CCL 23. 21. Thickness of Permafrost 1812' CASING SIZE WT. PER FT. 16" 62.6# 9.625" 40# 7" 26# 3.5" 9.3# GRADE H-40 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 158' Surface 7923' Surface 11974' 11769' 12637' HOLE SIZE 24" 12.25" 8.5" CEMENTING RECORD 320 sx AS 1 494.5 bbl sx AS Lite, 399 bbls LiteCrete 180 sx Class G AMOUNT PULLED 6.125" 42.9 bbls Class G 3.5" TUBING RECORD DEPTH SET (MD) 11819' PACKER SET (MD) 11769' 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 25. SIZE 12194' - 12208' MD 6590' - 6603' TVD 6 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A N/A 5/18/2002 6 hours Flow Tubing Casing Pressure press. 185 psi 1284 28. Test Period> Calculated 24-Hour Rate> PRODUCTION TEST Method of Operation (Flowing, gas lilt, etc.) Gas Lift Oil Production for OIL-BBL GAS-MCF 374 144 OIL-BBL GAS-MCF 1397 905 CORE DATA WATER-BBL 0 WATER-BBL 0 CHOKE SIZE GAS-OIL RATIO 176 648 OIL GRAVITY - API (corr) not available 27. Date First Production May 16, 2002 Date of Test Hours Tested Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIVED N/A JUN 0 5 2002 Alaska Oil & Gas Gons. GommISSIO[¡ Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SpE r', 1 r'" !\ 1'\ I tJ ! t"} ¡ ¡ \J !-'\ L Submit in duplicate RBDMS 8FL JJN 6 2002 \~ ~ .""'-""', ~ 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A 12143' 12212' 12341 ' 12459' 6542' 6607' 6730' 6843' Annulus left open - freeze protected with diesel. RECEIVED ,IUi'j 0 !) ?OO? 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Alaska on & Gas Cons. Commission <AooIaÐlapll Scott Lowry 265-6869 Signe~ ~ - R. Thomas --"¡¡tle Kuparuk Drillina Team Leader Date !) (2. V (ð l- Prepared by Sharon Allsup-Drake 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 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 cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ,"", ¡ ~ V ¡ L .~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 R-35 1 R-35 ROT - DRILLING Nabors Nabors 245 Start: 11/12/2001 Rig Release: 12/9/2001 Rig Number: 245 Spud Date: 11/14/2001 End: Group: 11110/2001 20:30 - 00:00 11/11/2001 00:00 - 02:00 02:00.03:30 03:30 - 07:30 07:30.11 :30 11:30 -14:00 14:00 - 18:00 18:00 - 18:30 18:30 - 21 :30 21 :30 - 22:00 22:00 - 00:00 11/12/2001 00:00 - 01 :30 01 :30 - 04:30 04:30 - 06:30 06:30 - 07:30 07:30 - 12:00 12:00 - 13:00 13:00 - 14:00 14:00 - 16:00 16:00 - 18:00 18:00 - 19:00 19:00 - 21:00 21:00 - 21:30 21:30 - 23:00 3.50 MOVE 2.00 MOVE 1.50 MOVE 4.00 MOVE 4.00 MOVE 2.50 MOVE 4.00 MOVE 0.50 MOVE 3.00 MOVE 0.50 MOVE 2.00 MOVE 1.50 MOVE 3.00 MOVE 2.00 MOVE 1.00 MOVE 4.50 MOVE 1.00 MOVE 1.00 MOVE 2.00 MOVE 2.00 MOVE 1.00 MOVE 2.00 MOVE 0.50 MOVE 1.50 MOVE MOVE MOVE MOVE MOVE OTHR MOVE MOVE MOVE MOVE MOVE OTHR MOVE MOVE MOVE OTHR MOVE MOVE MOVE OTHR MOVE MOVE MOVE MOVE MOVE OTHR MOVE MOVE MOVE OTHR MOVE MOVE MOVE OTHR MOVE POSN MOVE POSN MOVE POSN MOVE OTHR MOVE POSN MOVE POSN MOVE POSN MOVE PJSM on skid floor, raising cellar,jacking up on crib blocks. Skid floor 36' to center P U cellar and hang off. Jacking pressure to skid 2300 psi to break free-- 1800 to contin ue moving. Cellar lift @ 1700 psi. Seperate modules. Jack up utility module. Repair throttle on # 1 Lampson, right hand s ide. Maneuver modules to travel down road. Exit pad with both module. Drill module in t he lead. Travel 1.8 miles. Chain broke on # 2 Lampson left hand side. Repair chain on # 2 Lampson, left hand side Moving both modules from 1.8 miles to 2.8 miles from 1C-109. Replace "T" bolt on left rear track tumbler 0 f #2 Lampson. Moving both modules from 2.8 miles to 3.8 miles (1A pad access area). Let traffic get around both modules while in "V" area of 1A pad access. Continue moving both modules from 1A acce ss area to 4.4 miles from 1C pad. Both modu les off Spine road traveling towards 1 G/1 R P ad @ 2300 hrs. Moving both modules f/ 4.4 miles away fl 1 C pad to 4.8 miles. Secondary chain on # 2 L ampson, left track, broke. Repair secondary chain # 2 Lampson, left tr ac k. Move both moduless fl 4.8 miles away fl 1C pad towards 1R, to 5.4 miles. Chain broke 0 n # 2 Lampson, left track. Repair broken secondary chain on # 2 Lamps on, left track. Continue to move both modules FI 5.4 miles away f/ 1 C pad to 1 R pad. On Pad @ 1200 hr s with both modules. Drill module in lead th e whole move. Total to pad = 7.8 miles. Tot al to well will be 8.0 Clean snow off pad to set rig and camp. Build berm fl cellar. Align drill module wi w e II Ii n e. Skid floor to drill position. Finish turning drill module and spot over hol e. Lower stomper and cellar box. Turn utility module and line up wi drill modu Ie. Jack drill module up, remove crib blocks an d set on ground. Mate utility module to drill module. Jack up, Printed: 1/17/2002 2:29:20 PM -'~-- .~. ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 R-35 1 R-35 ROT - DRILLING Nabors Nabors 245 Start: 11/12/2001 Rig Release: 12/9/2001 Rig Number: 245 Spud Date: 11/14/2001 End: Group: 11112/2001 21:30 - 23:00 23:00 - 00:00 11/13/2001 00:00 - 02:00 02:00 - 03:30 03:30-11:00 11:00-19:00 19:00 - 20:00 20:00 - 22:30 22:30 - 00:00 11/14/2001 00:00 - 08:30 08:30-11:00 11 :00 - 11 :30 11:30 -12:30 12:30 - 13:00 13:00 - 16:00 16:00-16:30 16:30-17:30 17:30 - 18:00 18:00 - 19:00 19:00 - 20:00 20:00 - 21 :00 21:00 - 22:00 22:00 - 23:00 23:00 - 00:00 11/15/2001 00:00 - 00:00 11/16/2001 00:00 - 08:30 1.50 MOVE 1.00 MOVE 2.00 MOVE 1.50 MOVE 7.50 MOVE POSN MOVE OTHR MOVE POSN MOVE RURD MOVE RURD MOVE 1.00 DRILL 8.00 WELCTL NUND SURFAC OTHR SURFAC 2.50 DRILL 1.50 DRILL 8.50 DRILL 2.50 DRILL PULD SURFAC PULD SURFAC PULD SURFAC PULD SURFAC 1.00 DRILL 0.50 WELCTL BOPE SURFAC SFTY SURFAC 0.50 DRILL 3.00 DRILL 0.50 DRILL 1.00 DRILL 0.50 DRILL 1.00 DRILL 1.00 DRILL 1.00 DRILL 1.00 DRILL 1.00 DRILL 1.00 DRILL 24.00 DRILL 8.50 DRILL PULD SURFAC OTHR SURFAC OTHR SURFAC OTHR SURFAC DRLG SURFAC SURV SURFAC DRLG SURFAC SURV SURFAC DRLG SURFAC SURV SURFAC DRLG SURFAC DRLG SURFAC DRLG SURFAC remove crib blocks, set on ground. Load 219 joints of 5" drill pipe, jars, and 2 9 joints of 5" HWDP in pipe shed to be warm in g up. Skid rig 2 1/2" towards pipe shed while riggi n g up. Re build cellar support for cellar box while r igging up. Camp arrived on 1 R pad @ 033 O. Camp set @ 0800. Rigging up, connecting lines, adjust v door, adjust skate, mix mud. Rig accepted @ 040 0 hrs 11/13/2001 NU Diverter. Change from Vetco/Gray quick connect to FMC 16" quick connect. Move equipment off the top of HWDP in pipe shed. Prep rig floor to PU DP. PU 29 joints of 5" HWDP and jars. MU and t orque, stand back in derrick. PU 5" 19.5 # dp. MU and torque up to stand back in derrick. Will plan to PU 219 joints ( 73 stands)derrick. Continue PU 5",19.5 #/ft G-105, DP. MU, to rque up and stand back in derrick. Total of 73 stands PU in derrick. Remove smaller tools from rig floor. PU 5" a nd 8" tools to rig floor. Function test diverter. Witness of test waive d by AOGCC insp. Jeff Jones. Pre spud meeting held wI both crews and te am members on location. PU, MU, stand back in derrick 8" flex collar s. PU bit # 1, MU & orient BHA # 1. Program MWD tools. Fill hole, check for leaks, circ surface syste m. Drill 12 1/4" surface hole fl 158' to 179'. AR T=.3hrs Run gyro @ 175' bit depth. Survey depth @ 79' . Drill 12 1/4" hole fl 175' to 268'. ART= .75 hr. Run gyro survey @ 268' bit depth. Survey @ 172' . Drill 12 1/4" hole fl 268' to 354'. ART =.25 hr. AST= .75 hr. Survey wI MWD @ 354' bit depth. Drill 12 1/4" hole fl 354' to 445'. AST= .75 hrs. Directional drill 12 1/4" hole fl 445' to 1643 '(1198') 1643' MD = TVD 1536' ART = 2.4 2 hrs. AST = 15.08 hrs. Drill 12 1/4" surface hole f/ 1643' to 2390' ( Printed: 1/17/2002 2:29:20 PM /.-..... '--', Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 R-35 1 R-35 ROT - DRILLING Nabors Nabors 245 Start: 11/12/2001 Rig Release: 12/9/2001 Rig Number: 245 Spud Date: 11/14/2001 End: Group: 11/16/2001 00:00 - 08:30 8.50 DRILL DRLG SURFAC 08:30 - 09:30 1.00 DRILL OTHR SURFAC 09:30 - 10:30 1.00 DRILL DRLG SURFAC 10:30-12:00 1.50 DRILL DRLG SURFAC 12:00 - 15:00 3.00 DRILL TRIP SURFAC 15:00 - 16:00 1.00 DRILL TRIP SURFAC 16:00 - 16:30 0.50 DRILL TRIP SURFAC 16:30 - 17:30 1.00 RIGMNT RSRV SURFAC 17:30 - 00:00 6.50 RIGMNT RGRP SURFAC 11/17/2001 00:00 - 01 :30 1.50 RIGMNT RGRP SURFAC 01 :30 - 02:30 1.00 RIGMNT RSRV SURFAC 02:30 - 05:30 3.00 DRILL PULD SURFAC 05:30 - 06:00 0.50 DRILL OTHR SURFAC 06:00 - 07:30 1.50 DRILL TRIP SURFAC 07:30 - 12:00 4.50 DRILL DRLG SURFAC 12:00 - 00:00 12.00 DRILL DRLG SURFAC 11/18/2001 00:00 - 09:30 9.50 DRILL DRLG SURFAC 09:30 - 11 :30 2.00 RIGMNT RGRP SURFAC 11:30-12:00 0.50 DRILL DRLG SURFAC 12:00 - 00:00 12.00 DRILL DRLG SURFAC 11/19/2001 00:00 - 04:00 4.00 DRILL DRLG SURFAC 04:00 - 04:30 0.50 RIGMNT RGRP SURFAC 747') AST = 5.5 hrs ART = .5 hrs Dropped stand of drill pipe across derrick w hi Ie making a connection. Retrieve stand an d make a connection. Drill 12 1/4" surface hole from 2390' to 248 4' (94'). ART = .5 hrs. AST = .5 hrs. Whil e drilling this stand it was noticed that the standpipe pressure was higher than before h and. Appears that the upper IBOP valve did not fully open. Circ hole, monitor hole, pump dry job for tri p. POOH. Reset motor from 1.5deg bend to 1.15 deg b end. Download MWD. Drain motor, break off bit, clean floor. Service rig and top drive. Replace upper IBOP on top drive. Tuboscope inspect all breaks on top drive connections . Inspected spare saver subs- one needs ref aced, 2 cracked pin threads. Replace upper IBOP valve on top drive. This includes removing accuators, clamps, and other subs and valves. Test valve to 3500 p s i. Service top drive. MU BHA # 2, bit # 2. Upload MWD and orient same. Shallow hole test MWD @ 1st stand of HWD P. Blow down top drive. Trip in hole w/ BHA # 2. Precautionary ream f/ 2394 to 2484'. Survey @ 2484', Directional drill 12 1/4" hole f/ 2484' to 304 3' (559') TVD = 2250' ART =.75 hrs. AST = 1.75 hrs. Directional drill 12 1/4" hole f/ 3043' to 453 l' (1488') TVD = 2877' ART = 6.75 hrs, A ST = 1. 75 hrs. Directional drill 12 1/4" surf hole f/ 4531' to 5744' (1213') (TVD = 3345') ART = 3.75 hrs. AST = 2.00 hrs. Trouble shoot problem of power swivel and r otary table not being able to engage in reve rse direction. Contactor was stuck in pan el (RT/PS) in choke manifold room. Work pipe and make connection. Orient to m ake slide. Directional drill 12 1/4" hole f/ 5744' to 700 0' (1256') (TVD = 3834'). ART = 6.25 hrs. AST = 3.00 hrs. Directional drill 12 1/4" surface hole f/ 70 00' to 7435' ART =3.0 hrs. (435') Lost power to CPM as well as DISCFLOW pu Printed: 1/17/2002 2:29:20 PM ~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 R-35 1 R-35 ROT - DRILLING Nabors Nabors 245 Start: 11/12/2001 Rig Release: 12/9/2001 Rig Number: 245 Spud Date: 11/14/2001 End: Group: 11/19/2001 04:00 - 04:30 04:30 - 10:00 10:00 - 12:30 12:30 - 17:00 17:00- 17:30 17:30 - 22:30 22:30.00:00 11/20/2001 00:00 - 03:00 03:00 - 03:30 03:30 - 04:00 04:00 - 12:00 12:00 - 13:00 13:00 - 14:30 14:30 - 15:00 15:00 - 16:00 16:00-16:30 16:30 - 17:00 17:00 - 18:30 11/21/2001 18:30 - 21 :30 21 :30 - 22:30 22:30 - 00:00 00:00 - 02:30 02:30 - 03:30 03:30 - 09:00 09:00 - 14:00 14:00 - 14:15 14:15 - 20:00 5.50 DRILL 0.50 RIGMNT RGRP SURFAC DRLG SURFAC 2.50 DRILL 4.50 DRILL 0.50 DRILL 5.00 DRILL 1.50 DRILL 3.00 DRILL 0.50 DRILL 0.50 DRILL 8.00 DRILL 1.00 DRILL 1.50 DRILL 0.50 CASE 1.00 CASE 0.50 CASE 0.50 CASE 1.50 CASE 3.00 CASE 1.00 CASE 1.50 CASE 2.50 CASE 1.00 CASE 5.50 CASE CIRC SURFAC WIPR SURFAC OBSV SURFAC WIPR SURFAC CIRC SURFAC CIRC SURFAC OBSV SURFAC TRIP SURFAC TRIP SURFAC SURV SURFAC PULD SURFAC SFTY SURFAC RURD SURFAC SFTY SURFAC RUNC SURFAC RURD SURFAC RUNC SURFAC CIRC SURFAC RUNC SURFAC RUNC SURFAC CIRC SURFAC RUNC SURFAC 5.00 CEMENTCIRC SURFAC 0.25 CEMENTSFTY SURFAC 5.75 CEMENT PUMP SURFAC mps in utility module. Trouble shoot and fix problem. Directional drill 12 1/4" surf. hole f/ 7435' t 0 7945' (510') TVD = 4234' ART = 2.5 hrs. AST = .5 hrs. Circulate and condition mud and hole. Pump dry job, POOH to 1800'. Monitor well, clean rig floor. RIH, fill pipe and break circ @ 4598' & 6186 , Fill pipe and precaautionary ream last 75' to bottom @ 7945'. Circulate and condition mud and hole f/ 9 5/ a" casing. Circulate and conditiion mud and hole f/ 9 5 /8" casing. Pull a stand every 45 min. w/ ci rc. Monitor well. Pump dry job. RIH to bottom. POOH f/ 9 5/8" casing. Monitor well @ 10 s tandsout, monitor @ 20 stands out, monitor @ 25 stands out. Hole is static. Download MWD. LD BHA. Clean up rig floor. PJSM. Review procedures for rigging up ca sing tools. RU GBR casing tools and Frank's Fill-Up To 01. PJSM. Discuss casing running procedures. Run 2 jts casing. Hydraulic fitting broke on casing tongs. Change out casing tongs. Clean up rig floor Run 9-5/8" casing to 2500'. Circulate bottoms up. Continue to run 9-5/a" casing. Run 9-5/8" casing to 5015'. Circulate bottoms up. Continue running 9-5/8" casing. Hit tight sp ot at 5500'. Circ and work casing through ti ght spot. Run total 191 jts 9-5/8" casing to 7881'. PU hanger, landing jt, & cmt head. Circulate and condition mud for cement job. PJSM - Discuss cement job. Pump 5 bbls CW100. PT to 3800 psi. Pump 15 bbls CW100. Drop btm plug. Pump 50 b bls mud push. Pump 494.5 bbls lead and 39 8.7 bbls tail. Shut down drop top plug. Pu mp 10 bbls water. Rig displace with 575 bbl s mud. Shut down 9 bbls early due to high pressure. Recovered 1ao bbls of 11.1-11.4# cement at surface. Some lost returns duri ng cement job. See cement report for detail s. CIP@1952 hrs. Check floats - holding g Printed: 1/1712002 2:29:20 PM ,~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 R-35 1 R-35 ROT - DRILLING Nabors Nabors 245 Start: 11/12/2001 Rig Release: 12/9/2001 Rig Number: 245 Spud Date: 11/14/2001 End: Group: 11/21/2001 14:15 - 20:00 5.75 CEMENT PUMP SURFAC 20:00 - 21:00 1.00 CEMENTOTHR SURFAC 21 :00 - 22:30 1.50 CEMENTPULD SURFAC 22:30 - 22:45 0.25 WELCTL SFTY SURFAC 22:45 - 00:00 1.25 WELCTL NUND SURFAC 00:00 - 03:00 3.00 WELCTL NUND SURFAC 03:00 - 12:00 9.00 WELCTL NUND INTRM1 12:00 - 14:00 2.00 WELCTL OTHR INTRM1 14:00 - 00:00 10.00 WELCTL BOPE INTRM1 11/22/2001 11/23/2001 00:00 - 06:00 6.00 WELCTL EQRP INTRM1 06:00 - 07:00 1.00 WELCTL EQRP INTRM1 07:00 - 10:00 3.00 WELCTL EQRP INTRM1 10:00 -11:30 1.50 WELCTL BOPE INTRM1 11:30-13:00 1.50 WELCTL EQRP INTRM1 13:00 - 14:30 1.50 RIGMNT RSRV INTRM1 14:30 - 15:30 1.00 RIGMNT RSRV INTRM1 15:30 - 21 :30 6.00 DRILL PULD INTRM1 21 :30 - 23:30 2.00 DRILL CIRC INTRM1 23:30 - 00:00 0.50 WELCTL SFTY INTRM1 11/24/2001 00:00 - 01 :30 1.50 WELCTL 8FTY INTRM1 01:30 - 01:45 0.25 DRILL SFTY INTRM1 01:45 - 03:30 1.75 DRILL PULD INTRM1 03:30 - 03:45 0.25 DRILL 8FTY INTRM1 03:45 - 05:00 1.25 DRILL PULD INTRM1 05:00 - 05:30 0.50 DRILL OTHR INTRM1 05:30 - 07:00 1.50 DRILL PULD INTRM1 07:00 - 07:30 0.50 DRILL DEQT INTRM1 07:30 - 09:30 2.00 DRILL PULD INTRM1 09:30 - 10:30 1.00 DRILL PULD INTRM1 ood. Flush stack. LD cement equipment and landing it. RD ca sing equipment & RU for 5". PJSM - Discuss procedures for ND of BOP st ac k. ND Diverter Stack. ND diverter stack. Clean cement from flow Ii ne, bag element, and knife valve. NU 13-5/8" 5M BOP RU BOP test equipment. Perform BOP test. Witnessing waived by Lo u Grimmaldi AOGCC Inspector. Test to 250 psi low and 5000 psi high. Failure on choke valves 4,6,7, & 9. Cycle and retest same Test hose and bleeder failure. Replace s ame. Retighten bottom flange on DSA. Cha nge out ring gasket on kill line un i-bolt. Te st annular to 3500 psi - Failed. Retest ann ular - Failed. RD and blowdown test equipment. RU equip ment to replace element in annular prevente r. Pull cap off annular. LD element. Clean and prep preventer for new element. Wait on new element. Caught behind rig mo ve at PRB. Heat and prep new element. Install element and annular preventer cap. AD cellar equip ment. NU bell nipple and flowline. RU BOP test equipment. Function test annu lar. Initial sealing pressure=800 psi. Test annular to 250 psi low and 3500 psi high. R D test equipment. Set wear bushing. Run in lock down screws. LD setting tools. Slip and cut 120' of drilling line. Lubricate rig and service top drive. PU and RIH w/ 45 stands 5" drill pipe. Circulate and rotate drill pipe to cleanup. Perform BOP drill and stripping drill. Perform stripping drill. PJ8M - Discuss procedures for pulling out 0 f h 0 Ie. POOH w/ 56 stands 5" drill pipe. Discuss procedures for PU BHA. Clean up rig floor. PU equipment out of pip e shed. PU 8.5" Smith PDC bit and BHA. Load MWD. Continue PU BHA. Surface test MWD. Tools not reading proper Iy. POOH to MWD. Download data. LD MWD. PU new MWD. Orient to motor. Load MWD. Printed: 1/17/2002 2:29:20 PM ,~ ~, Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 R-35 1 R-35 ROT - DRILLING Nabors Nabors 245 Start: 11/12/2001 Rig Release: 12/9/2001 Rig Number: 245 Spud Date: 11/14/2001 End: Group: 11/24/2001 10:30-11:00 11:00-16:00 16:00 - 18:30 18:30.19:00 19:00.20:30 20:30 . 21 :30 21 :30 - 22:00 22:00 - 23:30 23:30 - 00:00 11/25/2001 00:00 - 01:00 01 :00 - 02:00 02:00 - 04:30 04:30 - 04:45 04:45 - 05:30 05:30.13:30 13:30.15:00 15:00 - 16:00 16:00 - 17:00 17:00 - 20:30 20:30 - 21 :00 21 :00 - 00:00 11/26/2001 00:00 - 18:00 18:00 - 20:30 20:30 - 21:15 21:15 - 21:30 21 :30 - 22:00 0.50 DRILL 5.00 DRILL DEQT INTRM1 TRIP INTRM1 2.50 WELCTL SFTY INTRM1 0.50 DRILL 1.50 DRILL 1.00 DRILL 0.50 DRILL 1.50 DRILL 0.50 DRILL 1.00 DRILL 1.00 DRILL 2.50 DRILL 0.25 DRILL 0.75 DRILL 8.00 DRILL 1.50 DRILL 1.00 DRILL 1.00 DRILL 3.50 DRILL 0.50 DRILL 3.00 DRILL 18.00 DRILL 2.50 DRILL TRIP INTRM1 DRLG INTRM1 CIRC INTRM1 DRLG INTRM1 CIRC INTRM1 OTHR INTRM1 DEQT INTRM1 DRLG INTRM1 CIRC INTRM1 SFTY INTRM1 LOT INTRM1 DRLG INTRM1 DRLG INTRM1 WIPR INTRM1 CIRC INTRM1 REAM INTRM1 CIRC INTRM1 DRLG INTRM1 DRLG INTRM1 CIRC INTRM1 0.75 DRILL WIPR INTRM1 0.25 WELCTL SFTY INTRM1 0.50 RIGMNT RSRV INTRM1 Surface test MWD. Good test. RIH to 1090. MU top drive. Rotate past por t collar. Continue RIH. Fill pipe @3523'. Check MWD. RIH to 6884'. BOP drill while drilling. PJSM. Discuss wel I kill procedures. Perform kill drill. RIH. Tag cement at 7668'. Drill out cement from 7668' to 7762'. Circ and condition mud. Circulate out thick, contaminated mud. Drill out cement from 7762' to 7855'. Went 15' past float collar. Circ and condition mud for casing pressure t est. RU equipment for casing pressure test. Beg in test at 2357 hrs. Pressure test 9-5/8" casing to 2600 psi. Pr essure bled off to 2550 psi in 30 min. Reco rded test on chart. Drill cement from 7855' to shoe at 7922'. D rill 20' new hole to 7965'. Circ bottoms up. Pump 25 bbls spacer @ 6 BPM. Change hole over to 8.4# LSND mud @ 11 BPM. PJSM - Discuss LOT procedures. RU for LOT. Perform LOT. Mud wt 8.4 ppg. Pressure broke back at 1550 psi (15.4 ppg EMW). Pump 3 bbls extra and shut in. Pre ssure stabilized at 905 psi. RD and blowdo wn test equipment. Perform PWD baseline test. Drill 7965' to 8 741'. AST=0.75 ART=4.9 Hole packed off. Rotate and reciprocate. U nable to regain circulation. POOH w/ 5 stan ds. 30M-50M overpull. Short trip to shoe at 7922'. Unable to regai n circulation until upper stabilizer was abov e casing shoe. No fluid lost to hole. Condition mud. Circ bottoms up. Wash and ream to bottom as a precautionary measure. No tight spots encountered. Condition mud. Circ high vis sweep. Recov ered good amount cuttings with sweep. ECD dropping. Drill ahead to 9021' MD (4659' TVD). ART= 2 AST=O Drill ahead from 9021' to 10329'. ART=11.2 5 AST=1.75 Condition mud. Circ weighted high vis swee p. Short trip to shoe. Kick while tripping drill. Lubricate rig. Service top drive. Printed; 1/17/2002 2:29:20 PM ,~ "'-"\ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 R-35 1 R-35 ROT - DRILLING Nabors Nabors 245 Start: 11/12/2001 Rig Release: 12/9/2001 Rig Number: 245 Spud Date: 11/14/2001 End: Group: 11/26/2001 22:00.23:30 23:30.00:00 00:00.01:30 11/27/2001 01 :30.12:00 12:00.00:00 11/28/2001 00:00 - 04:30 04:30 - 08:00 08:00 - 08:15 08:15 - 10:00 10:00.10:15 10:15 -11:00 11:00-14:30 14:30 - 17:00 17:00 - 18:30 18:30 - 19:30 19:30 - 00:00 11/29/2001 00:00 - 00:30 00:30 - 01 :30 01 :30 - 02:30 02:30.03:30 03:30.04:00 04:00 -10:00 10:00-10:30 11/30/2001 10:30 - 17:00 17:00 - 19:00 19:00 - 00:00 00:00 - 02:00 02:00 - 09:00 09:00 - 09:15 -,-~- 1.50 DRILL 0.50 DRILL 1.50 DRILL 10.50 DRILL 12.00 DRILL 4.50 DRILL 3.50 DRILL 0.25 DRILL 1.75 DRILL 0.25 DRILL 0.75 DRILL 3.50 DRILL 2.50 DRILL 1.50 DRILL 1.00 DRILL 4.50 DRILL 0.50 DRILL 1.00 DRILL 1.00 DRILL 1.00 CASE 0.50 CASE 6.00 CASE 0.50 CASE 6.50 CASE 2.00 CASE 5.00 CASE 2.00 CASE WIPR INTRM1 CIRC INTRM1 CIRC INTRM1 DRLG INTRM1 DRLG INTRM1 DRLG INTRM1 CIRC INTRM1 SFTY INTRM1 WIPR INTRM1 SFTY INTRM1 WIPR INTRM1 CIRC INTRM1 TRIP INTRM1 CIRC INTRM1 LOT INTRM1 TRIP INTRM1 TRIP INTRM1 OTHR INTRM1 PULD INTRM1 RURD INTRM1 SFTY INTRM1 RUNC INTRM1 CIRC INTRM1 RUNC INTRM1 CIRC INTRM1 RUNC INTRM1 RUNC INTRM1 7.00 CEMENTCIRC INTRM1 0.25 CEMENTSFTY INTRM1 Trip in hole Condition mud. Circ bottoms up. Circ bottoms up. Watch for ECD to drop per PWD tool. Drill ahead 10329'.10983' (TVD=5558'). Pu mp 25 bbl weighted high vis sweep @ 10889' Returned to surface 450 stks late. Starte d to weight up mud @ 10983'. ART=4.2 AS T=3.0 Drill ahead 10983'.11732' (TVD=6165'). Pu mp weighted high vis sweep @ 11639'. ART =4.25 AST=4.0 Drill from 11732' to 8.5" TD @ 11983' (TVD= 6395'). ART=1 AST=1.6 Pump 25 bbl weighted high vis sweep plus 2 bottoms up (20000 stks). Sweep hit 550 st ks late. PJSM. Discuss short trip. Monitor well - no flow. Pump dry job. POO H to 10229'. Monitor well. no flow. PJSM - Discuss RIH procedure. RIH to 11983'. Pump 25 bbls weighted high vis sweep. Con dition mud and circulate hole clean. Monito r well - no flow. Pump dry job. POOH to 9-5/8' casing shoe. Condition mud and circulate for LOT. Perform open hole LOT. MW=10.6 ppg. LOT at shoe=15.15 ppg. LOT at 11983'=13.6 pp g. 1/2 bbl bled back after test. Monitor well - no flow. Pump dry job. POO H to drill collars. POOH w/ BHA. Drain motor & MWD. BO Bit. Orient motor to 0 deg. RIH to MWD Download MWD Data LD MWD and BHA. Pull wear bushing. Clean up rig floor. RU casing running equip ment. PJSM - Discuss casing running procedures. RIH w/ 7" casing to 4000'. Pump casing vol (1512 stks) @ 5 BPM and 4 00 ps i. Continue Circulate Continue Continue up tool. t 11973' Break circulation slowly at 2 BPM. Recip pi pe. Getting some returns. Back off to 1/2 BPM. Work pipe at varying pump speeds. V ery slow returns. Pump 6200 stks. PJSM - Discuss cementing procedures. RIH w/ 7" casing to 7886'. and condition mud. RIH w/ 7" casing to 11575'. RIH w/ 7" casing to 11933'. LD fill Blowdown top drive. Land casing a Printed: 1/17/2002 2:29:20 PM ~ ~, Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 R-35 1 R-35 ROT - DRILLING Nabors Nabors 245 Start: 11/12/2001 Rig Release: 12/9/2001 Rig Number: 245 Spud Date: 11/14/2001 End: Group: 11130/2001 09:15.10:00 0.75 CEMENT PUMP INTRM1 10:00-11:00 1.00 CEMENT DISP INTRM1 11:00 - 12:30 1.50 CEMENT RURD INTRM1 12:30.12:45 0.25 CASE SFTY INTRM1 12:45 - 13:30 0.75 CASE DEaT INTRM1 13:30 - 21 :00 7.50 WELCTL EaRP PROD 21 :00 - 00:00 3.00 WELCTL BOPE PROD 12/1/2001 2.50 WELCTL BOPE PROD 00:00 - 02:30 02:30 - 02:45 0.25 DRILL SFTY PROD 02:45 - 07:30 4.75 DRILL PULD PROD 07:30 - 07:45 0.25 DRILL SFTY PROD 07:45 -11:00 3.25 DRILL PULD PROD 11 :00 - 11 :30 0.50 DRILL PULD PROD 11:30 - 13:30 2.00 RIGMNT RGRP PROD 13:30 - 14:00 0.50 DRILL PULD PROD 14:00 - 18:30 4.50 DRILL PULD PROD 18:30 - 20:30 2.00 DRILL TRIP PROD 20:30 - 23:00 2.50 WELCTL SFTY PROD 23:00 - 00:00 1.00 RIGMNT RGRP PROD 12/2/2001 00:00 - 00:15 0.25 RIGMNT SFTY PROD 00:15 - 04:00 3.75 RIGMNT RGRP PROD 04:00 - 04:15 0.25 DRILL SFTY PROD RU Dowell. Pump 5 bbls CW100. P test lin es to 3500 psi. Pump 15 bbl CW100 and 30 bbl 12# Mud Push. Drop bottom plug. Pump 38.5 bbls 15.7# cement. Drop top plug. P ump 11 bbl water. Displace cement wi rig pumps at 6 BPM and 1100 psi. Drop to 3 BPM for last 20 bbls. R ecip pipe while displacing. Bumped top plu g at 4412 stks (4405 calculated). Pressure up to 1700 psi. Held for 5 min. Bleed pres sure off and check floats. Holding good. L ost 950 bbls mud while circulating and ceme nti n g. RD casing running equipment. PJSM - Discuss packoff setting procedures. Set 7" packoff and test to 5000 psi for 10 m in. Change upper and lower pipe rams to 3.5 x 6 variable bore rams. Change saver sub on top drive. Replace die keepers on grabber head. RU BOP test equipment. BOP test in progress. Test annular to 250 p si low and 3500 psi high. Test being witnes sed by John Spaulding - AOGCC. Continue with BOP test. Witnessed by John Spaulding - AOGCC. Test all equipment ex cept annular to 250 psi low and 5000 psi hig h. Blowdown and RD test equipment. Set w ear bushing. Clean up rig floor. PJSM - Discuss procedures for laying down DP. LD 48 stands 5" DP. Clean up rig floor. PJSM - Discuss procedures for picking up a nd standing back DP. PU 4" DP and stand back in derrick. PU BHA components out of pipe shed. Repair cracked hydraulic fitting on iron roug hneck. PU remaining 4" DP and stand in derrick. 0 stands total stood back. MU BHA. Orient motor. Program MWD and f unction test. Load sources. LD 6-3/4" flex collars. RIH wi BHA, HWDP. and jars. Single in hol e with 18 jts 4" DP. Conduct BOP drill and stripping drill. Blowd own choke manifòld. Change out drilling line. PJSM - Discuss procedures for finishing cha ngeout of drilling line. Change out drilling line. PSJM - Discuss procedures for picking up D P. Printed: 1/17/2002 2:29:20 PM ~ ""'-"", Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 R-35 1 R-35 ROT - DRILLING Nabors Nabors 245 Start: 11/12/2001 Rig Release: 12/9/2001 Rig Number: 245 Spud Date: 11/14/2001 End: Group: 12/2/2001 04:15 - 09:30 5.25 DRILL TRIP PROD 09:30 - 10:00 0,50 RIGMNT RSRV PROD 10:00 - 17:30 7.50 DRILL TRIP PROD 17:30 - 19:00 1.50 DRILL CIRC PROD 19:00 - 21 :00 2.00 DRILL DEQT PROD 21:00 - 00:00 3.00 DRILL DRLG PROD 12/3/2001 00:00 - 02:30 2.50 DRILL CIRC PROD 02:30 - 04:00 1.50 DRILL DRLG PROD 04:00 - 05:30 1.50 DRILL CIRC PROD 05:30 - 06:30 1.00 DRILL FIT PROD 06:30 - 12:00 5.50 DRILL DRLG PROD 12:00 - 16:00 4.00 DRILL DRLG PROD 16:00 - 18:00 2.00 DRILL CIRC PROD 18:00 - 22:30 4.50 DRILL DRLG PROD 22:30 - 23:30 1.00 DRILL CIRC PROD 23:30 - 00:00 0.50 DRILL DRLG PROD 12/4/2001 00:00 - 00:30 0.50 DRILL DRLG PROD 00:30 . 02:00 1.50 DRILL CIRC PROD 02:00 - 04:30 2.50 DRILL DRLG PROD 04:30 - 06:30 2.00 DRILL CIRC PROD 06:30 - 08:00 1.50 DRILL WIPR PROD 08:00 - 08:30 0.50 RIGMNT RSRV PROD 08:30 - 09:30 1.00 DRILL WIPR PROD 09:30 - 14:30 5.00 DRILL CIRC PROD 14:30 - 15:00 0.50 DRILL oasv PROD 15:00 - 16:30 1.50 DRILL WIPR PROD 16:30 - 18:00 1.50 DRILL CIRC PROD 18:00 - 18:30 0.50 DRILL OBSV PROD PU and RIH wi 4" DP out of pipe shed. Pum p pipe volume after 100 its picked up. Lubricate rig. Continue PU and RIH wI 4" DP to TOC at 11 865' . Circ and condition mud. Pressure test 7" casing to 3550 psi. Pressu re dropped to 3480 psi in 30 min. RD test e quipment. Drill out cement, plugs, and float collar to 1 1968' . Pump 30 bbl spacer. Change hole over to n ew mud. Get slow pump rates. Drill float shoe, rathole, and 20' new hole. Circulate bottoms up. Monitor well. Perform FIT test. Pressure up to 1870 psi. Bled down to 1820 psi in 10 min. FIT EMW =16 ppg. RD test equipment. Perform PWD baseline test. Drill from 1200 3' to 12038'. Pump 30 bbl nutplug sweep fol lowed by another 25 bbl nutplug sweep. Try ing to get bit to drill. Spud bit down to get it to drill. Continue drilling to 12066'. Tot al for tour: ART=4.3 AST=O Drill ahead to 12225'. Pump sweep and check for flow. Well is sta tic. Drill ahead from 12225' to 12430'. Pump sweep and check for flow. Well is sta tic. Drill ahead from 12430' to 12449' (TVD=683 5') Total for tour: ART=6 AST=1.5 Drill 6 1/8" hole fl 12449' to 12499' (50') PU, monitor well- static, SPR. Cut MW back to 10.3+ ppg. Drill 6 1/8" hole fl 12499' to 12630' (131') ( TVD= 7009') ADT=1.4 hrs ART=1.4 hrs AST =0.0 hrs. Circ. & Cond mud. Pump 22 bbls weighted Hi -Vis sweep. Survey, monitor well. POOH to 7" shoe (8 stands). Monitor well. B OP drill. Service rig and top drive. RIH to 12243', fill pipe, wash to 12630'. No fill. Circ and condition mud and hole. Bottoms u p gas cut to 8.3 ppg. Increase MW to 10.6 P pg. SPA wI 10.6 ppg MW. Monitor well. OK. Short trip to 7" shoe. Monitor well. RIH. No fill. Circ bottomsw up. Check for gas. OK. Monitor well- static. Pump dry job for trip 0 Printed: 1/17/2002 2:29:20 PM ~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 R-35 1 R-35 ROT - DRILLING Nabors Nabors 245 Start: 11/12/2001 Rig Release: 12/9/2001 Rig Number: 245 Spud Date: 11/14/2001 End: Group: 12/4/2001 18:00-18:30 0.50 DRILL OBSV PROD 18:30 - 00:00 5.50 DRILL TRIP PROD 12/5/2001 00:00 - 01:00 1.00 DRILL TRIP PROD 01:00 - 02:00 1.00 DRILL PULD PROD 02:00- 03:30 1.50 DRILL OTHR PROD 03:30 - 04:30 1.00 DRILL PULD PROD 04:30 - 05:30 1.00 CASE RURD PROD 05:30 - 06:00 0.50 CASE SFTY PROD 06:00 - 08:00 2.00 CASE PULR PROD 08:00 - 09:00 1.00 CASE PULR PROD 09:00 - 14:00 5.00 CASE RUNL PROD 14:00 - 14:30 0.50 CASE CIRC PROD 14:30-18:30 4.00 CASE RUNL PROD 18:30 - 20:00 1.50 CASE CIRC PROD 20:00 - 00:00 4.00 CASE RUNL PROD 12/6/2001 00:00 - 02:00 2.00 CASE CIRC PROD 02:00 - 02:30 0.50 CASE RUNL PROD 02:30 - 03:00 03:00 - 07:30 0.50 CASE RUNL PROD 4.50 CEMENTCIRC PROD 07:30 - 08:00 O.SO CEMENT SFTY PROD 08:00 - 09:00 1.00 CEMENT PUMP PROD 09:00 - 10:00 1.00 CEMENT DISP PROD 10:00 - 10:30 0.50 CEMENTOTHR PROD 10:30 - 12:00 1.50 CEMENTOTHR PROD 12:00 - 13:00 13:00 - 13:30 1.00 CEMENT RURD PROD 0.50 CEMENTCIRC PROD ut. POOH for 3 1/2" liner. POOH to 4" HWDP, monitor well, PJSM on L/ D HWDP. LID 18 joints 4" HWDP, jars,Flex DC's. Clean up floor, PJSM wI Sperry Sun. Downlo ad MWD tools. LID MWD tools, drain motor, break bit" Re- orient motor, Finish LID BHA. RU to run 3 1/2" casing as liner. PJSM. Running 3 1/2" liner PU/MU 26 joints 3 1/2" 9.3 # L-80 SLHT tubi n g. PU/MU SBE, X-O and Hanger wI running tool RU & circ liner capacity @ 3BPM 2S0 psi. up wt 7S k, down 75 k. blocks 75 k. Run liner on 4" DP to 4000'. Circ liner & DP capacity @ 4000'. Run 3 1/2" liner on 4" DP to 8000'. Circulate and condition mud. Circ capacity 0 fliner&DP. RIH wI 3 1/2" liner on 4" DP to 11,900'. Continue circulating & condition mud @ 11,9 00'. While circulating, prepare Baker cern en t head wI S' pup joint, valves and washup Ii ne. LID 2 singles, blow down top drive. Continue running in hole with 3 1/2" liner on 4" drill pipe. MU single and cement head. Establish circ and slack off to tag bottom. Add 10' pup below cement head. Break circ @ 2.0 bpm wI 700 psi. Tag botto m, pu, rotate @ 20 rpm wI 6500 ftllb torque. Circ and conditon mud and hole prior to ce ment job on 3 1/2" liner. PJSM wI team members on cement job while circulating liner, recip and rotating. Cement liner. Pump 10 bbls CW 100, test lin as to 4S00 psi, 10 bbls CW100, 27.2 bbls M udpush XL, 42.9 bbls 1S.8 ppg cement, shut in cement head. Flush line with rig pumps to finish cleaning out cement from lines. Drop plug and follow with mud wI rig pump. Bump plug @ calculated strokes to 1400 psi. CIP @ 0950 hrs. Set hanger wI 2900 psi. Release liner with 4 SOO psi. Set packer wI SO,OOO# weight. Circ 17.S bbls. Line up to reverse circ. Reverse circ 12 bbl s cement to surface. Continue to reverse tot al of 4000 strokes (400 bbls). RID cement head and pups, LID same. Pump dry job to POOH wI 4" drill pipe. Printed: 1/17/2002 2:29:20 PM ,~ .~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 R-35 1 R-35 ROT - DRILLING Nabors Nabors 245 Start: 11/12/2001 Rig Release: 12/9/2001 Rig Number: 245 Spud Date: 11/14/2001 End: Group: 12/6/2001 13:30 - 23:00 9.50 CEMENTTRIP PROD 12/7/2001 00:00.01 :00 1.00 CMPL TN OTHR CMPL TN 01 :00 - 01:30 0.50 CMPL TN RURD CMPLTN 01 :30 - 02:00 0.50 CMPL TN SFTY CMPL TN 02:00 - 14:00 12.00 CMPLTN RUNT CMPL TN 14:00 - 16:00 2.00 CMPL TN SOHO CMPLTN 16:00 - 17:00 1.00 CMPL TN OTHR CMPL TN 17:00 - 20:00 3.00 CMPLTNCIRC CMPLTN 20:00 - 23:00 3.00 CMPL TN OTHR CMPL TN 23:00 - 00:00 1.00 CMPL TN CMPL TN 12/8/2001 00:00 - 00:30 0.50 CMPL TN OTHR CMPL TN 00:30 - 03:00 2.50 WELCTL OTHR CMPLTN 03:00 - 05:00 2.00 WELCTL OTHR CMPL TN 05:00 - 09:30 4.50 WELCTL NUND CMPL TN 09:30 - 15:30 6.00 WELCTL NUND CMPL TN 15:30 - 17:00 1.50 WELCTL OTHR CMPL TN 17:00 - 20:00 3.00 CMPL TN FRZP CMPL TN 20:00 - 00:00 4.00 CMPL TN FRZP CMPL TN 12/9/2001 00:00 - 00:30 0.50 CMPL TN FRZP CMPL TN 00:30 - 01 :30 1.00 CMPLTN FAZP CMPL TN 01 :30 . 03:00 1.50 CMPL TN FRZP CMPL TN POOH, LID 4" drill pipe. PJSM. Pull wear bushing prior to running co mpletion. RU to run 3 1/2" completion. PJSM on completion program wI team membe rs. PU and run 3 1/2" completion per program. While circ slow, verify and locate. PU & Spa ce out. AU test equip. Test casing to 3500 psi & ch art test for 30 min. Lost 40 psi. RU and reverse circ mud out of well with fre sh water till clean. Circ 8200 strokes (826 b bls) @ 5 bpm with 700 psi. Land tubing, run in lock down screws. PU w t 145 k, SO wt 110 k RU & test 3 1/2" tubin g to 3500 psi for 15 min, chart same. Lost 5 psi. Ble tubing to 1500 psi. Test 7" x 3 1/2" annulus to 3500 psi for 15 min, chart same. Lost 6 psi. Bleed off pressure on tubing to shear RP valve. Sheared on second attempt. AID test equipment. Lay down landing joint. LID power tongs, slips and elevators for 3 1 12" completion. Modify "T" bar to run FMC's BPV prior to nip piing down. Working on kill and choke line f langes while modifing "T" bar. Set BPV. Change upper and lower pipe rams to 4 1/2" VB A's. NID BOPE. LID 14' riser out of cellar area. NU FMC tree. Orient valves according to dia gram. Pull BPV. Set two way check. RU & test tree to 250 psi low and 5000 psi h igh. Chart test. Pull two way check. Freeze protect 3 1/2" x 7" annulus wI 95 bbl s diesel. "U" tube diesel to 3 12" tubing. P ress before "U tubing" = 275 psi. Final pres s = 0 psi. Estimate diesel in ann & tbg @ 2 514' MD = 2009' TVD. Set BPV. AU to freeze protect 9 5/8" x 7" annulus. Do a LOT, chart same prior to 300 bbfs water fl ush and then pump 75 bbls diesel into annul us. Final press after freeze protect = 1170 psi. Finish pumping 300 bbl water flush ahead of diesel for freeze protection of 9 5/8" x 7" annulus. Freeze protect 9 5/8" x 7" annulus with 75 b bs diesel @ 2.5 BPM and 1300 psi. Final c ire pressure = Final shut in pressure = Blow down diesel from lines. RID equip from freeze protection. Secure well. Printed: 1/17/2002 2:29:20 PM ,'--"'" I~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 R-35 1 R-35 ROT - DRILLING Nabors Nabors 245 Start: 11/12/2001 Rig Release: 12/9/2001 Rig Number: 245 Spud Date: 11/14/2001 End: Group: 12/9/2001 03:00 - CMPL TN CMPL TN Rig r a I a a sad fro m 1 R - 3 5 for 6 0 I m 0 v a a way f rom CPM to wall 1R-36 @ 0300 hrs 12/9/01. Printed: 1/17/2002 2:29:20 PM Date 03/16/02 04/21/02 05/10102 05/11/02 05/12/02 05/13/02 --'----- ,~ ,p--." 1 R-35 Event History Comment CLEANED TO 12,515' CTM WI SLICK SEAWATER, SLICK DIESEL, AND DIESEL GEL USING A 1.75" VORTECH JETSWIRL NOZZLE. WELL FREEZE PROTECTED TO 2500'+. COIL BLOWN DOWN WI N2 FOR REEL SWAP. [FCO, VORTECH] RIG UP RUN 14 FT 2.5 POWERJET @ 6 SPF-- PERF INTERVAL 12194 TO 12208-- CCL TO TOP SHOT - 12.0P FT--STOP DEPTH 12182 RAN STATIC SURVEYS @ 12201 & 11901 [PERF] TAGGED FILL @ 12,524' RKB, IN PROGRESS [TAG] PULLED DV'S @ 3897',7512',9984',11,215' RKB, SET GLV @ 11,215' RKB, IN PROGRESS [GLV] SET GLV'S @ 3897', 7512', 9984' RKB, IN PROGRESS [GLV] REPLACED SOY WI OV @ 11,693' RKB [GLV] Page 1 of 1 5/20/2002 ~ ,--... ;)01- diD 28-Dec-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Re: Distribution of Survey Data for Well 1 R-35 GYRO Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 'MD 'MD 'MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED IN'I 0 3 2002 Alaska Oil & Gas Cons. Commission Ancl:..orage ;20,-.;lID t, :, " ~, .( Kuparuk River Unit North Slope, Alaska Kuparuk 1 R, Slot 1 R-35 1 R-35 Gyro Job No. AKFO11190, Surveyed: 4 December, 2001 DEFINITIVE SURVEY REPORT 28 December, 2001 Your Ref: API 500292305000 Surface Coordinates: 5991750.23 N, 539829.69 E (70° 23' 18.2569- N, 149040'33.7012- W) Kelly Bushing: 83.80ft above Mean Sea Level ,( RECEIVED JAN 0 3 2002 Alaska Oil 8: Gas Cons. Commission Ancoorage !5 pE!1"'"'1"'"' Y - !5 U., DRILLING SEÄVIc;es; A Halliburton Company Survey Ref: svy9699 Sperry-Sun Drilling Services Survey Report for 1R-35 Gyro Your Ref: API 500292305000 Job No. AKFO11190, Surveyed: 4 December, 2001 f'" " II Kuparuk River Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 0.00 0,000 0.000 -83.80 0,00 '( 79,00 0250 340,000 -4.80 79.00 17UO OAOO 30.000 87.20 171.00 Local Coordinates Northlngs Eastlngs (ft) (ft) O.OON 0.16 N 0.63N O,OOE 0.06W 0.03E Global Coordinates Northlngs Eastlngs (ft) (ft) 5991750.23 N 5991750.39 N 5991750.86 N 539829.69 E 539829,63 E 539829.72 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 83.8' (MSL). Northings and Eastings are relative to 546' FSL & 147' FWL. Magnetic Declination at Surface is 26.011 ° (11-Nov-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 546' FSL & 147' FWL and calculated along an Azimuth of 33.110° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 171.00ft., The Bottom Hole Displacement is 0.63ft., in the Direction of 3.002° (True). Survey tool program for 1R-35 Gyro ( From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0,00 0.00 171.00 171.00 Tolerable Gyro 28 December, 2001 - 14:21 Page 2 of 2 Dogleg Vertical Rate Section (0/100ft) 0,316 0.333 0,00 0.10 0.54 I) North Slope, Alaska Kuparuk 1 R Comment Tolerable Gyro DriliQuest 2.00.08.005 ...-..., -\ 28-Dec-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Re: Distribution of Survey Data for Well 1 R-35 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: ' MD Window / Kickoff Survey , MD Projected Survey: 12,630.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED j¡\J. 0 3 2002 Alaska Oil & Gas Cons. Commission Anc~i)rage ~O" ;1,10 , . \...... Kuparuk River Unit North Slope, Alaska Kuparuk 1 R, Slot 1 R-35 1 R.35 Job No. AKZZ11190, Surveyed: 4 December, 2001 SURVEY REPORT 28 December, 2001 DEF'N'T'VE ) Your Ref: API 500292305000 Surface Coordinates: 5991750.23 N, 539829.69 E (70023'18.2569" N, 149040'33.7012" W) Kelly Bushing: 83.80ft above Mean Sea Level Sl::Il!!r'r'Y- SUI! DRILLING seRVices A H8111burton Comp8ny ) Survey Ref: svy9748 Sperry-Sun Drilling Services I) Survey Report for 1R-35 Your Ref: API 500292305000 Job No. AKZZ11190, Surveyed: 4 December, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 R Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 171.00 0.400 30.000 87.20 171.00 0.63N 0.03E 5991750.86 N 539829.72 E 0.54 AK-6 BP _IFR-AK ) 300.24 2.620 83.960 216.39 300.19 1.33N 3.20E 5991751.58 N 539832.88 E 1.862 2.86 394.04 5.300 80.710 309.96 393.76 2.26N 9.61 E 5991752.54 N 539839.28 E 2.866 7.14 485.51 7.140 83.460 400.88 484.68 3.58N 19.42 E 5991753.92 N 539849.09 E 2.037 13.61 576.34 9.850 84.840 490.71 574.51 4.93N 32.77 E 5991755.33 N 539862.43 E 2.992 22.03 664.57 14.220 78.870 576.98 660.78 7.70N 50.93 E 5991758.20 N 539880.58 E 5.144 34.27 752.26 18.260 72.310 661.16 744.96 13.96 N 74.60 E 5991764.58 N 539904.21 E 5.053 52.44 842.57 20.370 64.630 746.40 830.20 24.99 N 102.29 E 5991775.77 N 539931.84 E 3.652 76.81 933.26 25.170 50.660 830.06 913.86 44.01 N 131.50 E 5991794.94 N 539960.96 E 7.939 108.69 1023.40 23.760 40.640 912.14 995.94 69.95 N 158.17 E 5991821.02 N 539987.48 E 4.856 144.99 1117.49 24.870 35.640 997.89 1081.69 100.42 N 182.04 E 5991851.61 N 540011.20 E 2.485 183.55 1211.29 24.550 32.950 1083.10 1166.90 132.80 N 204.14 E 5991884.11 N 540033.12 E 1.246 222.74 1304.07 26.770 33.080 1166.73 1250.53 166.48 N 226.03 E 5991917.92 N 540054.83 E 2.394 262.92 1395.63 30.320 34.170 1247.15 1330.95 202.90 N 250.27 E 5991954.46 N 540078.88 E 3.919 306.66 1487.74 31.700 34.750 1326.09 1409.89 242.02 N 277.12 E 5991993.72 N 540105.52 E 1.533 354.10 1579.84 36.190 33.960 1402.47 1486.27 284.48 N 306.12E 5992036.33 N 540134.29 E 4.899 405.50 1676.10 41.570 33.220 1477.38 1561.18 334.80 N 339.52 E 5992086.83 N 540167.42 E 5.610 465.90 1769.10 45.210 33.360 1544.95 1628.75 388.19N 374.58 E 5992140.41 N 540202.20 E 3.915 529.77 1863.17 46.800 33.620 1610.29 1694.09 444.63 N 411.92E 5992197.05 N 540239.24 E 1.702 597.44 ) 1955.27 53.310 34.140 1669.39 1753.19 503.21 N 451.27 E 5992255.84 N 540278.28 E 7.082 668.01 2047.91 60.570 34.480 1719.90 1803.70 567.29 N 495.02 E 5992320.15 N 540321.68 E 7.843 745.58 2141.46 65.930 32.590 1761.99 1845.79 636.91 N 541.12 E 5992390.02 N 540367.41 E 6.007 829.08 2235.40 63.690 32.370 1801.97 1885.77 708.62 N 586.77 E 5992461.96 N 540412.68 E 2.394 914.08 2328.49 63.490 33.330 1843.38 1927.18 778.66 N 631.99 E 5992532.25 N 540457.53 E 0.948 997.45 2424.48 64.290 30.770 1885.63 1969.43 851.71 N 677.72 E 5992605.54 N 540502.87 E 2.536 1083.62 2514.57 63.420 31.030 1925.32 2009.12 921.10 N 719.25 E 5992675.15 N 540544.03 E 1.000 1164.43 2608.65 61.200 30.680 1969.04 2052.84 992.61 N 761.98 E 5992746.89 N 540586.37 E 2.383 1247.66 2702.58 63.140 31.230 2012.89 2096.69 1063.84 N 804.70 E 5992818.34 N 540628.71 E 2.129 1330.67 2795.11 61.730 31.390 2055.71 2139.51 1133.92 N 847.33 E 5992888.65 N 540670.97 E 1.532 1412.65 2887.09 64.120 32.380 2097.57 2181.37 1203.45 N 890.59 E 5992958.41 N 540713.86 E 2.769 1494.53 ""--- ....... 28 December, 2001 - 14:21 Page2of7 Dri/lQuest 2.00.08.005 Sperry-Sun Drilling Services f) Survey Report for 1R-35 Your Ref: API 500292305000 Job No. AKZZ11190, Surveyed: 4 December, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 R Measured Sub-5ea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate SectIon Comment eft) eft) (ft) eft) eft) eft) eft) (o/100ft) 2981.45 66.160 33.250 2137.24 2221.04 1275.40 N 936.99 E 5993030.60 N 540759.87 E 2.318 1580.13 ) 3073.41 65.860 33.340 2174.63 2258.43 1345.63 N 983.11 E 5993101.07 N 540805.62 E 0.338 1664.15 "'-- 3166.50 66.910 32.500 2211.92 2295.72 1417.22 N 1029.46 E 5993172.92 N 540851.59 E 1.398 1749.44 3258.80 67.850 32.190 2247.42 2331.22 1489.20 N 1075.04 E 5993245.14 N 540896.79 E 1.065 1834.63 3351.19 67.430 31.530 2282.57 2366.37 1561.77 N 1120.15E 5993317.95 N 540941.50 E 0.802 1920.06 3439.78 67.160 30.150 2316.76 2400.56 1631.94 N 1162.04 E 5993388.34 N 540983.02 E 1.469 2001.71 3537.61 65.190 28.560 2356.28 2440.08 1709.93 N 1205.92 E 5993466.56 N 541026.48 E 2.503 2091.01 3630.33 63.690 28.540 2396.28 2480.08 1783.40 N 1245.89 E 5993540.24 N 541066.06 E 1.618 2174.39 3723.15 63.970 29.720 2437.22 2521.02 1856.17 N 1286.44 E 5993613.22 N 541106.23 E 1.180 2257.49 3816.03 66.160 29.890 2476.38 2560.18 1929.25 N 1328.30 E 5993686.52 N 541147.70 E 2.364 2341.57 3908.60 67.200 30.320 2513.02 2596.82 2002.78 N 1370.94 E 5993760.29 N 541189.95 E 1.202 2426.45 4002.43 65.330 31.290 2550.79 2634.59 2076.56 N 1414.92 E 5993834.30 N 541233.53 E 2.206 2512.27 4092.87 64.740 30.330 2588.96 2672.76 2146.97 N 1456.92 E 5993904.93 N 541275.15 E 1.163 2594.20 4186.58 65.050 30.550 2628.72 2712.52 2220.14 N 1499.91 E 5993978.32 N 541317.75 E 0.393 2678.96 4282.77 64.980 31.620 2669.35 2753.15 2294.80 N 1544.93 E 5994053.23 N 541362.37 E 1.011 2766.09 43I4.54 66.270 31.720 2707.22 2791.02 2365.94 N 1588.81 E 5994124.60 N 541405.88 E 1.409 2849.65 44 9.63 67.730 32.670 2744.38 2828.18 2440.01 N 1635.45 E 5994198.92 N 541452.12 E 1.790 2937.17 4560.78 67.360 33.080 2779.19 2862.99 2510.76 N 1681.18 E 5994269.91 N 541497.47 E 0.581 3021.41 4655.79 68.260 34.150 2815.07 2898.87 2584.02 N 1729.88 E 5994343.42 N 541545.78 E 1.409 3109.38 ) 4749.14 68.480 32.990 2849.49 2933.29 2656.32 N 1777.86 E 5994415.98 N 541593.38 E 1.179 3196.15 4844.16 68.080 34.150 2884.65 2968.45 2729.87 N 1826.67 E 5994489.79 N 541641.79 E 1.210 3284.42 4938.22 66.840 34.460 2920.71 3004.51 2801.63 N 1875.63 E 5994561.81 N 541690.37 E 1.353 3371.27 5031.88 68.400 33.790 2956.37 3040.17 2873.32 N 1924.21 E 5994633.76 N 541738.57 E 1.792 3457.86 5124.73 66.940 33.080 2991.64 3075.44 2944.99 N 1971.54 E 5994705.68 N 541785.51 E 1.724 3543.74 5216.51 64.190 33.430 3029.61 3113.41 3014.86 N 2017.35 E 5994775.79 N 541830.95 E 3.016 3627.29 5309.83 63.850 34.430 3070.49 3154.29 3084.47 N 2064.17 E 5994845.65 N 541877.41 E 1.030 3711.17 5403.13 63.630 34.220 3111.77 3195.57 3153.57 N 2111.36 E 5994915.00 N 541924.22 E 0.310 3794.82 5497.13 62.920 33.330 3154.04 3237.84 3223.35 N 2158.03 E 5994985.03 N 541970.52 E 1.134 3878.78 5591.78 65.050 34.000 3195.55 3279.35 3294.14 N 2205.18 E 5995056.07 N 542017.30 E 2.339 3963.83 5683.27 64.480 34.550 3234.56 3318.36 3362.53 N 2251.79 E 5995124.70 N 542063.54 E 0.827 4046.57 28 December, 2001 - 14:21 Page 3 of7 Drí/lQuest 2.00.08.005 Sperry-Sun Drilling Services 8 Survey Report for 1 R-35 Your Ref: API 500292305000 Job No. AKZZ11190, Surveyed: 4 December, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 R Measured Sub-Sea Vertical Local CoordInates Global Coordinates Dogleg VertIcal Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 5777.34 66.940 34.230 3273.25 3357.05 3433.28 N 2300.21 E 5995195.71 N 542111.58 E 2.633 4132.28 ) 5869.54 66.330 34.440 3309.81 3393.61 3503.17 N 2347.95 E 5995265.86 N 542158.95 E 0.694 4216.90 5963.85 64.810 35.390 3348.82 3432.62 3573.58 N 2397.09 E 5995336.53 N 542207.71 E 1.854 4302.72 6057.92 65.970 34.360 3387.99 3471.79 3643.74 N 2445.99 E 5995406.95 N 542256.24 E 1.585 4388.20 6152.21 65.730 35.110 3426.57 3510.37 3714.45 N 2495.01 E 5995477.92 N 542304.88 E 0.769 4474.20 6246.23 65.870 34.160 3465.11 3548.91 3785.01 N 2543.75 E 5995548.73 N 542353.24 E 0.934 4559.93 6337.85 67.300 34.560 3501.52 3585.32 3854.41 N 2591.20 E 5995618.39 N 542400.33 E 1.611 4643.98 6431.22 67.300 34.300 3537.55 3621.35 3925.46 N 2639.90 E 5995689.69 N 542448.65 E 0.257 4730.10 6523.31 68.760 32.350 3572.01 3655.81 3996.81 N 2686.81 E 5995761.30 N 542495.18 E 2.524 4815.49 6618.05 67.960 32.490 3606.94 3690.74 4071.15 N 2734.02 E 5995835.89 N 542541.99 E 0.856 4903.55 6711.63 68.390 30.850 3641.74 3725.54 4145.09 N 2779.63 E 5995910.06 N 542587.20 E 1.691 4990.39 6805.56 68.040 31.500 3676.60 3760.40 4219.71 N 2824.78 E 5995984.93 N 542631.95 E 0.743 5077.56 6897.65 68.100 31.080 3710.99 3794.79 4292.71 N 2869.15 E 5996058.16 N 542675.93 E 0.428 5162.94 6991.43 65.860 30.390 3747.66 3831.46 4366.89 N 2913.26 E 5996132.58 N 542719.65.E 2.483 5249.17 7085.62 66.030 30.270 3786.05 3869.85 4441.13 N 2956.69 E 5996207.05 N 542762.69 E 0.215 5335.08 7180.17 64.950 31.470 3825.28 3909.08 4514.97 N 3000.83 E 5996281.12N 542806.43 E 1.624 5421.04 7273.57 64.220 30.830 3865.36 3949.16 4587.17 N 3044.47 E 5996353.55 N 542849.68 E 0.997 5505.35 7366.54 65.150 31.270 3905.12 3988.92 4659.17 N 3087.82 E 5996425.78 N 542892.65 E 1.088 5589.34 7461.18 65.140 31.040 3944.90 4028.70 4732.66 N 3132.24 E 5996499.50 N 542936.68 E 0.221 5675.17 ) 7553.91 64.370 31.290 3984.44 4068.24 4804.42 N 3175.65 E 5996571.50 N 542979.70 E 0.865 5758.99 7646.89 64.920 31.960 4024.26 4108.06 4875.97 N 3219.71 E 5996643.28 N 543023.38 E 0.880 5842.98 7739.25 64.000 31.570 4064.08 4147.88 4946.82 N 3263.58 E 5996714.36 N 543066.87 E 1.066 5926.30 78:33.03 65.370 33.110 4104.18 4187.98 5018.44 N 3308.93 E 5996786.22 N 543111.84 E 2.083 6011.06 7881.40 65.610 33.270 4124.25 4208.05 5055.27 N 3333.02 E 5996823.18 N 543135.74 E 0.580 6055.07 80'10.63 66.730 29.420 4176.48 4260.28 5156.21 N 3394.48 E 5996924.45 N 543196.66 E 2.860 6173.19 8103.46 66.260 28.540 4213.50 4297.30 5230.68 N 3435.73 E 5996999.13 N 543237.51 E 1.006 6258.10 8197.47 65.650 29.090 4251.80 4335.60 5305.90 N 3477.11 E 5997074.57 N 543278.49 E 0.841 6343.71 8291.10 66.730 31.960 4289.61 4373.41 5379.67 N 3520.62 E 5997148.58 N 543321.60 E 3.032 6429.27 8385.45 66.920 33.020 4326.74 4410.54 5452.83 N 3567.21 E 5997221.98 N 543367.80 E 1.052 6516.00 8477.84 67.400 33.330 4362.60 4446.40 5524.10 N 3613.80 E 5997293.50 N 543414.01 E 0.605 6601.14 ...-., ....-., 28 December, 2001 . 14:21 Page4of7 DrillQuest 2.00.08.005 , . Sperry-Sun Drilling Services I) Survey Report for 1 R-35 Your Ref: API 500292305000 Job No. AKZZ11190, Surveyed: 4 December, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 R Measured Sub-5ea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth locI. Azim. Depth Depth Northings Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8571.27 66.980 32.990 4398.82 4482.62 5596.20 N 3660.91 E 5997365.85 N 543460.74 E 0.561 6687.27 ) 8664.40 66.850 32.720 4435.34 4519.14 5668.16 N 3707.39 E 5997438.06 N 543506.83 E 0.301 6772.94 '"-, 8758.05 67.190 33.650 4471.90 4555.70 5740.32 N 3754.58 E 5997510.47 N 543553.64 E 0.984 6859.16 8851.69 67.260 33.110 4508.15 4591.95 5812.42 N 3802.08 E 5997582.81 N 543600.76 E 0.537 6945.49 8945.49 66.650 32.800 4544.87 4628.67 5884.84 N 3849.03 E 5997655.49 N 543647.32 E 0.718 7031.81 9040.91 66.050 32.370 4583.15 4666.95 5958.49 N 3896.11 E 5997729.38 N 543694.00 E 0.752 7119.21 9135.19 65.780 31.550 4621.62 4705.42 6031.51 N 3941.67 E 5997802.65 N 543739.17 E 0.844 7205.26 9226.25 66.640 33.420 4658.36 4742.16 6101.79 N 3986.42 E 5997873.17 N 543783.55 E 2.103 7288.57 9319.49 66.770 33.050 4695.23 4779.03 6173.42 N 4033.35 E 5997945.05 N 543830.10 E 0.390 7374.21 9411.70 66.580 32.300 4731.74 4815.54 6244.69 N 4079.07 E 5998016.56 N 543875.44 E 0.775 7458.88 9504.32 66.660 33.840 4768.50 4852.30 6315.93 N 4125.45 E 5998088.05 N 543921.45 E 1.529 7543.90 9598.30 67.050 34.460 4805.44 4889.24 6387.45 N 4173.97 E 5998159.82 N 543969.57 E 0.735 7630.30 9691.78 67.120 33.950 4841.84 4925.64 6458.66 N 4222.37 E 5998231.29 N 544017.60 E 0.508 7716.38 9786.67 66.850 33.590 4878.93 4962.73 6531.26 N 4270.92 E 5998304.14 N 544065.76 E 0.450 7803.71 9879.64 66.390 32.450 4915.83 4999.63 6602.81 N 4317.42 E 5998375.94 N 544111.88 E 1.229 7889.05 9970.12 66.520 33.180 4951.97 5035.77 6672.52 N 4362.37 E 5998445.89 N 544156.46 E 0.753 7971.99 10064.10 66.930 34.580 4989.11 5072.91 6744.19 N 4410.50 E 5998517.81 N 544204.20 E 1.436 8058.32 10158.50 66.720 34.250 5026.26 5110.06 6815.78 N 4459.54 E 5998589,67 N 544252.87 E 0.391 8145.08 10252.00 65.090 34.250 5064.43 5148.23 6886.33 N 4507.58 E 5998660.47 N 544300.53 E 1.743 8230.41 ) 10346.00 62.370 33.180 5106.03 5189.83 6956.43 N 4554.37 E 5998730.82 N 544346.94 E 3.068 8314.69 10440.80 60.390 33.380 5151.44 5235.24 7026.00 N 4600.03 E 5998800.63 N 544392.23 E 2.097 8397.90 1 05:J3.80 58.030 33.640 5199.04 5282.84 7092.61 N 4644.13 E 5998867.47 N 544435.98 E 2.549 8477.78 10626.30 55.160 34.080 5249.96 5333.76 7156.73 N 4687.15 E 5998931.82 N 544478.65 E 3.128 8554.99 10720.80 52.640 33.640 5305.64 5389.44 7220.12 N 4729.69 E 5998995.44 N 544520.85 E 2.693 8631.33 10812.90 50.530 32.220 5362.86 5446.66 7280.68 N 4768.92 E 5999056,21 N 544559.77 E 2.590 8703.48 10906.10 47.520 30.960 5423.97 5507.77 7340.60 N 4805.79 E 5999116.32 N 544596.32 E 3.387 8773.81 11001.00 44.460 31.740 5489.90 5573.70 7398.89 N 4841.29 E 5999174.80 N 544631.50 E 3.278 8842.03 110!}2.90 42.080 32.170 5556.81 5640.61 7452.33 N 4874.62 E 5999228.42 N 544664.55 E 2.610 8905.00 11186.30 39.610 32.810 5627.46 5711.26 7503.86 N 4907.42 E 5999280.12 N 544697.07 E 2.682 8966.08 11280.70 36.910 32.840 5701.58 5785.38 7552.97 N 4939.11 E 5999329.40 N 544728.50 E 2.860 9024.53 28 December, 2001 . 14:21 Page50f7 Dri/lQuest 2.00.08.005 .' . Sperry-Sun Drilling Services Survey Report for 1 R-35 Your Ref: API 500292305000 Job No. AKZZ11190, Surveyed: 4 December, 2001 f) North Slope, Alaska Kuparuk River Unit Kuparuk 1 R Measured Sub-5ea Vertical Local CoordInates Global CoordInates Dogleg Vertical Depth locI. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate SectIon Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11375.50 34.790 32.570 5778.41 5862.21 7599.69 N 4969.11 E 5999376.28 N 544758.25 E 2.242 9080.04 ) 11469.20 33.330 33.030 5856.04 5939.84 7643.80 N 4997.53 E 5999420.54 N 544786.43 E 1.582 9132.52 ',-., 11563.60 31.410 33.430 5935.76 6019.56 7686.08 N 5025.22 E 5999462.96 N 544813.90 E 2.047 9183.05 11655.50 30.180 33.640 6014.71 6098.51 7725.29 N 5051.21 E 5999502.32 N 544839.68 E 1.344 9230.10 11748.30 27.800 33.930 6095.87 6179.67 7762.68 N 5076.22 E 5999539.83 N 544864.49 E 2.569 9275.07 11841.30 25.270 32.240 6179.07 6262.87 7797.47 N 5098.91 E 5999574.74 N 544887.00 E 2.839 9316.61 11890.50 23.460 31.270 6223.89 6307.69 7814.72 N 5109.60 E 5999592.05 N 544897.59 E 3.768 9336.90 11979.50 21.380 29.940 6306.16 6389.96 7843.92 N 5126.90 E 5999621.35 N 544914.73 E 2.405 9370.81 12004.50 21.510 30.110 6329.42 6413.22 7851.84 N 5131.47 E 5999629.29 N 544919.26 E 0.576 9379.94 12101.60 21.920 30.040 6419.63 6503.43 7882.93 N 5149.47 E 5999660.47 N 544937.10 E 0.423 9415.81 12196.80 20.030 29.900 6508.52 6592.32 7912.45 N 5166.50 E 5999690.08 N 544953.97 E 1.986 9449.84 12292.60 16.690 30.390 6599.43 6683.23 7938.54 N 5181.64 E 5999716.26 N 544968.97 E 3.490 9479.97 12389.30 16.200 30.930 6692.18 6775.98 7962.09 N 5195.60 E 5999739.88 N 544982.80 E 0.531 9507.32 12483.40 15.200 31.220 6782.76 6866.56 7983.90 N 5208.74 E 5999761.76 N 544995.83 E 1.066 9532.77 12568.20 14.440 31.620 6864.74 6948.54 8002.41 N 5220.04 E 5999780.33 N 545007.04 E 0.904 9554.45 12630.00 14.440 31.620 6924.59 7008.39 8015.53 N 5228.12 E 5999793.50 N 545015.05 E 0.000 9569.85 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. ) Vertical depths are relative to RKB = 83.8' (MSL). Northings and Eastings are relative to 546' FSL & 141' FWL. Magnetic Declination at Surface is 26.011° (11-Nov-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 546" FSL & 141' FWL and calculated along an Azimuth of 33.110° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12630.00ft., The Bottom Hole Displacement is 9569.85ft., in the Direction of 33.114° (True). _.---' --...-... 28 December, 2001 - 14:21 Page6of7 DrillQuest 2.00.08.005 .. ~ I . Kuparuk River Unit Comments ',,--. Measured Depth (ft) 12630.00 7008.39 Sperry-Sun Drilling Services Survey Report for 1 R.35 Your Ref: API 500292305000 Job No. AKZZ11190, Surveyed: 4 December, 2001 6) North Slope, Alaska Kuparuk 1 R StatIon Coordinates TVD Northlngs Eastlngs (ft) (ft) (ft) Comment ') ./ 8015.53 N 5228.12 E Projected Survey Survey tool program for 1 R.35 From Measured Vertical Depth Depth (ft) (ft) 0.00 171.00 ~, ---" ------ 28 December, 2001 . 14:21 0.00 171.00 To Measured VertIcal Depth Depth Survey Tool Description (ft) (ft) 171.00 12630.00 171.00 Tolerable Gyro (1R-35 Gyro) 7008.39 AK-6 BP _'FR-AK (1R-35) ) Page7of7 DrillQuest 2.00.08.005 r". . ..--.... 201-2/0 28-Dec-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 R-35 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: ' MD Window / Kickoff Survey MD Projected Survey: 12,630.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED IN'l 0 3 2002 Alaska Oil & Gas Cons. CommiS3ion Ancoorage at "-- rp ....... ~ .( ( ;20 I, ;lID " Kuparuk Rivør Unit North Slope, ,it/aska Kuparuk 1 R, Slbt 1 R-35 1 R-35 MWD Job No. AKMM11190, Surveyed: 4 December, 2001 SURVEY REPORT 28 December, 2001 Your Ref: API 500292305000 Surface Coordinates: 5991750.23 N, 539829.69 E (70° 23' 18.2569" N, 149040'33.7012" W) Kelly Bushing: 83.80ft above Mean Sea Level RECEI\/ED JAN 03 2002 Alaska Oil & Gas Cons. Commìssion Anct"orage Spe!"""""" Y - !!5 UI'1 DAII.-L..ING SEAVIces A Halliburton Company Survey Ref: svy9749 Sperry-Sun Drilling Services I) Survey Report for 1 R-35 MWD Your Ref: API 500292305000 Job No. AKMM11190, Surveyed: 4 December, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 R Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) ( 171.00 0.400 30.000 87.20 171.00 0.63N 0.O3E 5991750.86 N 539829.72 E 0.54 MWD Magnetic 300.24 2.620 84.550 216.39 300.19 1.30 N 3.20 E 5991751.55 N 539832.88 E 1.865 2.84 394.04 5.300 81.280 309.96 393.76 2.16 N 9.62E 5991752.44 N 539839.30 E 2.866 7.06 485.51 7.140 83.790 400.88 484.68 3.42 N 19.44 E 5991753.75 N 539849.12 E 2.033 13.48 576.34 9.850 85.220 490.71 574.51 4.67N 32.80 E 5991755.08 N 539862.47 E 2.992 21.83 664.57 14.220 79.230 576.98 660.78 7.33N 50.98 E 5991757.83 N 539880.63 E 5.145 33.99 752.26 18,260 72.600 661.16 744.96 13.45 N 74.68 E 5991764.08 N 539904.30 E 5.062 52.06 842.57 20.370 64,610 746.40 830.20 24.43 N 102.39 E 5991775.20 N 539931.95 E 3.740 76,39 933.26 25.170 50.980 830.06 913.86 43.36 N 131.67 E 5991794.29 N 539961.12 E 7.833 108.24 1023.40 23.760 40.990 912.14 995.94 69.15 N 158.48 E 5991820.22 N 539987.80 E 4.843 144.49 1117.49 24.870 36.050 997.89 1081.69 99.46 N 182.56 E 5991850.66 N 540011.72 E 2.462 183.03 1211.29 24.550 33.280 1083.10 1166.90 131.70 N 204.86 E 5991883.01 N 540033.85 E 1.281 222.22 1304.07 26.770 33.510 1166.73 1250.53 165.23 N 226.98 E 5991916.67 N 540055.79 E 2.395 262.39 1395.63 30.320 34.810 1247.14 1330.94 201.41 N 251.56 E 5991952.98 N 540080.18 E 3.936 306.13 1487.74 31.700 35.310 1326.09 1409.89 240.25 N 278.83 E 5991991.97 N 540107.23 E 1.524 353.55 1579.84 36.190 34.640 1402.47 1486.27 282.39 N 308.28 E 5992034.26 N 540136.46 E 4.892 404.94 1676.10 41.570 33.680 1477.38 1561.18 332.39 N 342.17 E 5992084.44 N 540170.09 E 5.624 465.33 1769.10 45.210 33.500 1544.95 1628.75 385.60 N 377.51 E 5992137.84 N 540205.14 E 3.916 529.20 ( 1863.17 46.800 33.940 1610.29 1694.09 441.88 N 415.08 E 5992194.32 N 540242.41 E 1,723 596.87 1955.27 53.310 34.280 1669.39 1753.19 500.31 N 454.66 E 5992252.95 N 540281.68 E 7.074 667.43 2047.91 60.570 34.330 1719.89 1803.69 564.40 N 498.39 E 5992317.28 N 540325.07 E 7.837 745.00 2141.46 65.930 32.760 1761.99 1845.79 634.01 N 544.51 E 5992387.13 N 540370.82 E 5.922 828.50 2235.40 63.690 32.570 1801.97 1885.77 705.57 N 590.39 E 5992458.93 N 540416.32 E 2.392 913.50 2328.49 63.490 33.560 1843.38 1927.18 775.44 N 635.88 E 5992529.05 N 540461.43 E 0.976 996.88 2424.48 64.290 31.030 1885.63 1969.43 848.30 N 681.92 E 5992602.15 N 540507.08 E 2.509 1083.05 2514.57 63.420 30.140 1925.32 2009.12 917.91 N 723.07 E 5992671.98 N 540547.86 E 1.311 1163.84 2608.65 61.200 30.850 1969.04 2052.84 989.69 N 765.34 E 5992743.99 N 540589.74 E 2.452 1247.05 2702.58 63.140 31.540 2012.89 2096.69 1060.74 N 808.36 E 5992815.26 N 540632.39 E 2.165 1330.07 2795.11 61.730 33.960 2055.71 2139.51 1129.73N 852.72 E 5992884.48 N 540676.38 E 2.774 1412.08 2887,09 64.120 31.260 2097.58 2181.38 1198.71 N 896.83 E 5992953.70 N 540720.13 E 3.685 1493.96 28 December, 2001 - 14:20 Page2of7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services I) Survey Report for 1 R.35 MWD Your Ref: API 500292305000 Job No. AKMM11190, Surveyed:.4 December, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 R Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment eft) (ft) (ft) (ft) (ft) (ft) (ft) eo/100ft) 2981.45 66.160 32.610 2137.25 2221.05 1271.36 N 942.12 E 5993026.59 N 540765.03 E 2.522 1579.56 ¡' 3073.41 65.860 33.870 2174.64 2258.44 1341.63 N 988.17 E 5993097.10 N 540810.70 E 1.294 1663.57 1 3166.50 66.910 31.690 2211.93 2295.73 1413.34 N 1034.34 E 5993169.06 N 540856.49 E 2.424 1748.85 3258.80 67.850 32.940 2247.43 2331.23 1485.34 N 1079.89 E 5993241.30 N 540901.65 E 1.612 1834.04 3351.19 67.430 31.510 2282.58 2366.38 ' 1557.62 N 1125.45 E 5993313.82 N 540946.83 E 1.502 1919.47 3439.78 67.160 32.410 2316.78 2400.58 1626.95 N 1168.71 E 5993383.38 N 540989.72 E 0.985 2001.18 3537.61 65.190 31.600 2356.29 2440.09 1702.84 N 1216.14 E 5993459.52 N 541036.75 E 2.151 2090.65 3630.33 63.690 29.810 2396.30 2480.10 1774.74 N 1258.86 E 5993531.65 N 541079.08 E 2,377 2174.22 3723.15 63.970 28.920 2437.24 2521.04 1847.35 N 1299.71 E 5993604.47 N 541119.54 E 0.912 2257.34 3816.03 66.160 32.420 2476.40 2560.20 1919.76 N 1342.68 E 5993677.11 N 541162.12 E 4.151 2341.47 3908.60 67.200 32,960 2513.05 2596.85 1991.30 N 1388.59 E 5993748.89 N 541207.65 E 1.245 2426.47 4002.43 65.330 29.760 2550.82 2634.62 2064.62 N 1433.29 E 5993822.45 N 541251.97 E 3.704 2512.31 4092.87 64.740 32.370 2589.00 2672.80 2134.84 N 1475.59 E 5993892.90 N 541293.89 E 2.696 2594.23 4186,58 65,050 33.800 2628.76 2712.56 2205.94 N 1521.91 E 5993964.24 N 541339.83 E 1.421 2679.09 4282.77 64.980 32.810 2669.39 2753.19 2278.80 N 1569.79 E 5994037.36 N 541387.32 E 0.936 2766.27 4374.54 66.270 35.060 2707.27 2791.07 2348.14 N 1616.45 E 5994106.95 N 541433.61 E 2.639 2849.85 4469.63 67.730 32.720 2744.42 2828.22 2420.80 N 1665.25 E 5994179.87 N 541482.02 E 2.736 2937.36 4560.78 67.360 33.270 2779.24 2863.04 2491.45 N 1711.12 E 5994250.76 N 541527.52 E 0.690 3021.60 ( 4655.79 68.260 33.050 2815.12 2898.92 2565.10 N 1759.24 E 5994324.66 N 541575.24 E 0.971 3109.57 4749.14 68.480 33.540 2849.53 2933.33 2637.63 N 1806.88 E 5994397.45 N 541622.49 E 0.542 3196.34 4844.16 68.080 34.390 2884.70 2968.50 2710.84 N 1856.19 E 5994470.92 N 541671.42 E 0.932 3284.61 4938.22 66.840 32.400 2920.75 3004.55 2783.37 N 1904.01 E 5994543.70 N 541718.85 E 2.357 3371.47 5031.88 68.400 36.270 2956.43 3040.23 2854.85 N 1952.86 E 5994615.44 N 541767.31 E 4.168 3458.04 5124.73 66.940 34.150 2991.71 3075.51 2925.01 N 2002.38 E 5994685.87 N 541816.46 E 2.633 3543.86 5216.51 64.190 32.030 3029.67 3113.47 2995.00 N 2048.01 E 5994756.10 N 541861.71 E 3.660 3627.40 5309.83 63.850 34.030 3070.55 3154.35 3065.33 N 2093.73 E 5994826.67 N 541907.06 E 1.961 3711.28 5403.13 63.630 33.020 3111.84 3195.64 3135.08 N 2139.94 E 5994896.66 N 541952.90 E 0.999 3794.95 5497.13 62.920 35.460 3154.11 3237.91 3204.48 N 2187.17 E 5994966.31 N 541999.76 E 2.438 3878,88 5591.78 65.050 35.400 3195.62 3279.42 3273.79 N 2236.48 E 5995035.88 N 542048.70 E 2.251 3963.87 5683.27 64.480 32.700 3234.64 3318.44 3342.34 N 2282.81 E 5995104.69 N 542094.67 E 2.741 4046.61 28 December, 2001. 14:20 Page 3 of7 DrillQllest 2.00.08.005 Sperry-Sun Drilling Services f) Survey Report for 1 R.35 MWD Your Ref: API 500292305000 Job No. AKMM11190, Surveyed: 4 December, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 R Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) CO/100ft) ,f 5777.34 66.940 36.310 3273.34 3357.14 3412.97 N 2331.39 E 5995175.57 N 542142.87 E 4.367 4132.30 5869.54 66.330 36.650 3309.90 3393.70 3481.02 N 2381.71 E 5995243.89 N 542192.83 E 0.743 4216.79 5963.85 64.810 34.200 3348.91 3432.71 3550.98 N 2431.48 E 5995314.11 N 542242.23 E 2.862 4302.57 6057.92 65.970 32.610 3388.09 3471.89 3622.37 N 2478.56 E 5995385.75 N 542288.92 E 1.970 4388.09 6152.21 65.730 37.350 3426.68 3510.48 3692.84 N 2527.87 E 5995456.48 N 542337.85 E 4.594 4474.05 6246.23 65.870 33.200 3465.24 3549.04 3762.83 N 2577.37 E 5995526.74 N 542386.99 E 4.029 4559.72 6337.85 67.300 36.780 3501.66 3585.46 3831.69 N 2625.59 E 5995595.85 N 542434.83 E 3.910 4643.73 6431.22 67.300 32.920 3537.70 3621.50 3902.36 N 2674.80 E 5995666.78 N 542483.66 E 3.814 4729.81 6523.31 68.760 34.630 3572.15 3655.95 3973.34 N 2722.28 E 5995738.01 N 542530.76 E 2.341 4815.20 6618.05 67.960 31.000 3607.10 3690.90 4047.33 N 2770.00 E 5995812.26 N 542578.09 E 3.660 4903.24 6711.63 68.390 30.910 3641.89 3725.69 4121.83 N 2814.68 E 5995886.99 N 542622.38 E 0.468 4990.05 6805.56 68.040 29.870 3676.75 3760.55 4197.06 N 2858.80 E 5995962.46 N 542666.10 E 1.094 5077.17 6897.65 68.100 33.530 3711.16 3794.96 4269.73 N 2903.68 E 5996035.36 N 542710.59 E 3.687 5162.56 6991.43 65.860 29.220 3747.84 3831.64 4343.38 N 2948.63 E 5996109.25 N 542755.14 E 4.857 5248.80 7085.62 66.030 32.450 3786.24 3870.04 4417.22 N 2992.71 E 5996183.33 N 542798.83 E 3.137 5334.73 7180.17 64.950 29.880 3825.47 3909.27 4490.82 N 3037.23 E 5996257.16 N 542842.96 E 2.724 5420.69 7273.57 64.220 32.230 3865.56 3949.36 4563.08 N 3080.74 E 5996329.66 N 542886.08 E 2.403 5504.99 7366.54 65.150 32.740 3905.31 3989.11 4633.97 N 3125.88 E 5996400.79 N 542930.84 E 1.116 5589.03 ( 7461.18 65.140 32.770 3945.09 4028.89 4706.19 N 3172.34 E 5996473.25 N 542976.92 E 0.031 5674.90 7553.91 64.370 29.060 3984.65 4068.45 4778.13 N 3215.43 E 5996545.42 N 543019.62 E 3.713 5758.69 7646.89 64.920 33.180 4024.48 4108.28 4850.03 N 3258.85 E 5996617.55 N 543062.66 E 4.047 5842.64 7739.25 64.000 33.190 4064.30 4148.10 4919.78 N 3304.46 E 5996687.54 N 543107.90 E 0.996 5925.97 7833.03 65.370 32.040 4104.40 4188.20 4991.18N 3350.14 E 5996759.19 N 543153.20 E 1.834 6010.74 7881.40 65.610 31.400 4124.47 4208.27 5028.62 N 3373.28 E 5996796.75 N 543176.14 E 1.302 6054,74 8010.63 66.730 29.700 4176.68 4260.48 5130.42 N 3433.36 E 5996898.87 N 543235.67 E 1.483 6172.83 8103.46 66.260 28.710 4213.71 4297.51 5204.72 N 3474.90 E 5996973.39 N 543276.82 E 1.101 6257.76 8197.47 65.650 29.370 4252.01 4335.81 5279.78 N 3516.57 E 5997048.67 N 543318.09 E 0.912 6343.39 8291.10 66,730 32.280 4289.82 4373.62 5353.33 N 3560.46 E 5997122.45 N 543361.59 E 3,068 6428.97 8385.45 66.920 33.310 4326.95 4410.75 5426.24 N 3607.44 E 5997195.61 N 543408.18 E 1.024 6515.70 8477.84 67.400 33.590 4362.81 4446.61 5497.28 N 3654.38 E 5997266.90 N 543454.73 E 0.590 6600.85 28 December, 2001 - 14:20 Page 4 of 7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services I) Survey Report for 1 R-35 MWD Your Ref: API 500292305000 Job No. AKMM11190, Surveyed: 4 December, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1R Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°11 OOft) ( 8571.27 66.980 33.240 4399.03 4482.83 5569.17 N 3701.81 E 5997339.04 N 543501.78 E 0.567 6686.97 8664.40 66.850 33.090 4435.55 4519.35 5640.88 N 3748.67 E 5997411.00N 543548.26 E 0.204 6772.64 8758.05 67.190 34.030 4472.11 4555.91 5712.73 N 3796.33 E 5997483.10 N 543595.54 E 0.993 6858.86 8851.69 67.260 33.840 4508.36 4592.16 5784.36 N 3844.53 E 5997554.99 N 543643.36 E 0.201 6945.19 8945.49 66.650 33.030 4545.08 4628.88 5856.39 N 3892.09 E 5997627.27 N 543690.53 E 1.027 7031.50 9040.91 66.050 32.770 4583.36 4667.16 5929.78 N 3939.57 E 5997700.91 N 543737.62 E 0.677 7118.90 9135.19 65.780 31.940 4621.83 4705.63 6002.49 N 3985.63 E 5997773.86 N 543783.29 E 0.853 7204.97 9226.25 66.640 33.790 4658.57 4742.37 6072.46 N 4030.85 E 5997844.08 N 543828.14 E 2.085 7288.28 9319.49 66.770 33.370 4695.44 4779.24 6143.81 N 4078.22 E 5997915.68 N 543875.12 E 0.437 7373.92 9411.70 66.580 32.430 4731.95 4815.75 6214.90 N 4124.21 E 5997987.01 N 543920.74 E 0.959 7458,59 9504.32 66.660 34.190 4768.71 4852.51 6285.95 N 4170.89 E 5998058.31 N 543967.04 E 1.746 7543.60 9598.30 67.050 34.660 4805.65 4889.45 6357.23 N 4219.75 E 5998129.85 N 544015.52 E 0.619 7629.99 9691.78 67.120 34.170 4842.04 4925.84 6428.26 N 4268.41 E 5998201.14 N 544063.80 E 0.489 7716.07 9786.67 66.850 33.940 4879.14 4962.94 6500.62 N 4317.32 E 5998273.75 N 544112.32E 0.362 7803.40 9879.64 66.390 32.720 4916.04 4999.84 6571.92 N 4364.21 E 5998345.30 N 544158.83 E 1.302 7888.73 9970.12 66.520 33.550 4952.18 5035.98 6641.38 N 4409.55 E 5998415.00 N 544203.80 E 0.853 7971.68 10064.10 66.930 34.840 4989.32 5073.12 6712.78 N 4458.07 E 5998486.66 N 544251.94 E 1.334 8057.99 10158.50 66.720 34.620 5026.47 5110.27 6784.10 N 4507.51 E 5998558.24 N 544301.00 E 0.309 8144.74 ( 10252.00 65.090 34.640 5064.64 5148.44 6854.33 N 4556.01 E 5998628.73 N 544349.13 E 1.743 8230.06 10346.00 62.370 33.540 5106.24 5190.04 6924.12 N 4603.26 E 5998698.78 N 544396.00 E 3.078 8314.33 10440.80 60.390 33.830 5151.65 5235.45 6993.37 N 4649.41 E 5998768.26 N 544441.78 E 2.106 8397.54 10533.80 58.030 33.940 5199.25 5283.05 7059.69 N 4693.95 E 5998834.82 N 544485.97 E 2.540 8477.42 10626.30 55.160 34.370 5250.17 5333.97 7123.58 N 4737.29 E 5998898.94 N 544528.97 E 3.127 8554.61 10720.80 52.640 33.980 5305.85 5389.65 7186.74 N 4780.18 E 5998962.33 N 544571.52 E 2.687 8630.95 10812.90 50.530 32.480 5363.07 5446.87 7247.09 N 4819.73 E 5999022.89 N 544610.75 E 2.622 8703.11 10906.10 47.520 31.460 5424.18 5507.98 7306.77 N 4857.00 E 5999082.77 N 544647.70 E 3.334 8773.45 11001.00 44.460 32.140 5490.11 5573.91 7364.78 N 4892.95 E 5999140.96 N 544683.34 E 3.265 8841.67 11092.90 42.080 32.540 5557.02 5640.82 7418.00 N 4926.64 E 5999194.36 N 544716.75 E 2.607 8904.66 11186.30 39.610 33.200 5627.67 5711.47 7469.30 N 4959.78 E 5999245.84 N 544749.62 E 2.685 8965,73 11280.70 36.910 33.270 5701.79 5785.59 7518.19 N 4991.82 E 5999294.90 N 544781.39 E 2.861 9024.18 28 December, 2001 . 14:20 Page 5 of7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services f) " , Survey Report for 1 R.35 MWD Your Ref: AP/500292305000 Job No. AKMM11190, Surveyed: 4 December, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 R Measured Sub.Sea Vertical Local CoordInates Global Coordinates Dogleg Vertical Depth Incl. Azim, Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) ,{ 11375,50 34.790 32.950 5778.62 5862.42 7564.69 N 5022.15 E 5999341.57 N 544811.47 E 2-245 9079,70 1146920 33.330 33.460 5856.25 5940,05 7608.60 N 5050.88 E 5999385.63 N 544839,97 E 1.588 9132.18 11563,60 31.410 33.850 5935,97 6019,77 7650.67 N 5078.88 E 5999427.85 N 544867,75 E 2.046 9182.71 11655.50 30,180 34.120 6014,91 6098.71 7689.69 N 5105.18 E 5999467.00 N 544893.84 E 1,347 9229,76 11748,30 27.800 33,930 6096.08 6179,88 7726.96 N 5130.35 E 5999504.40 N 544918.81 E 2.567 9274.72 11841.30 25.270 32.680 6179.28 6263.08 7761.66 N 5153.18 E 5999539.23 N 544941.45 E 2.786 9316.27 11890.50 23.460 31.660 6224.09 6307.89 7778.84 N 5163.99 E 5999556.47 N 544952.17 E 3.777 9336.56 11979.50 21.380 29.750 6306.36 6390.16 7808.01 N 5181.34 E 5999585.73 N 544969.37 E 2.476 9370.47 12004.50 21.510 29.930 6329.63 6413.43 7815.94 N 5185.89 E 5999593.68 N 544973.87 E 0.583 9379.59 12101.60 21,920 30.410 6419.84 6503.64 7847.00 N 5203.94 E 5999624.83 N 544991.76 E 0.460 9415.47 12196.80 20.030 30.330 6508.73 6592.53 7876.40 N 5221.17 E 5999654.32 N 545008.84 E 1.986 9449.51 12292.60 16.690 30.830 6599.64 6683.44 7902.38 N 5236.51 E 5999680.39 N 545024.04 E 3.490 9479.65 12389.30 16.200 31.320 6692.38 6776.18 7925.82 N 5250.64 E 5999703.91 N 545038.04 E 0.527 9507.01 12483.40 15-200 31.890 6782.97 6866.77 7947.51 N 5263.98 E 5999725.67 N 545051.26 E 1.075 9532.46 12568.20 14.440 31.800 6864.95 6948.75 7965.94 N 5275.42 E 5999744.15 N 545062.61 E 0.897 9554.15 12630.00 14.440 31.800 6924.80 7008.60 7979.03 N 5283.55 E 5999757.29 N 545070.66 E 0.000 9569.55 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. ( fertical depths are relative to RKB = 83.8' (MSL). Northings and Eastings are relative to 546' FSL & 141' FWL. Magnetic Declination at Surface is 26.011° (11-Nov-01) The Dogleg Severity is in Degrees per 100 feet (US), Vertical Section is from 546' FSL & 141' FWL and calculated along an Azimuth of 33.110° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12630.00ft., The Bottom Hole Displacement is 9569.79ft., in the Direction of 33.512° (True). 28 December, 2001 - 14:20 Page 6 of 7 DrillQuest 2.00.08.005 Kuparuk River Unit Comments { Measured Depth (ft) 12630.00 Sperry-Sun Drilling Services Survey Report for 1 R-35 MWD Your Ref: API 500292305000 Job No. AKMM11190, Surveyed:4 December, 2001 f) 7979.03 N Survey tool program for 1 R-35 MWD North Slope, Alaska Kuparuk 1 R Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 7008.60 From Measured Vertical Depth Depth (ft) (ft) 0.00 171.00 ( 0.00 171.00 To Measured Vertical Depth Depth (ft) (ft) 171.00 12630.00 Comment 5283.55 E Projected Survey Survey Tool Description 171.00 Tolerable Gyro (1R-35 Gyro) 7008.60 MWD Magnetic (1R-35 MWD) 28 December, 2001 - 14:20 ,,""..". '..-'" Page 70f7 DrillQuest 2.00.08.005 05/16/02 Sc~..epg8P Well NO. 2082 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Sepia CD Color 04/14/02 1 1 04/14/02 1 1 04/14/02 1 1 04/11/02 1 1 04/11/02 1 1 04/18/02 1 1 04/18/02 1 1 04/21/02 1 1 04/16/02 1 1 04/19/02 1 1 04/23/02 1 1 04/15/02 1 1 04/13/02 1 1 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth ( lC-119 1C-133 1 C-133 1 D-1O9 1 D-119 lD-132 1 D-132 lR-35 2D-02 2P-431 2T-39 3B-14 3C-15 ( Job # Log Description ñDJ-/Rq DRIFT&TAG ¡:JDI-O 7 1 PRESSURE/TEMP LOG .j, INJECTION PROFILE Jq7-~~S STATIC BOTTOM HOLE PRESSURE aD-1~9 STATIC BOTTOM HOLE PRESSURE Jq?- ~ I TEMPERATURE WARM BACKS ~ INJECTION PROFILE aD) - rl'O PRESSURE TEMPERATURE Ic¡(lf - I s::J PRESSURE-TEMP STATIONS aDd -Of-¡ ~ PERF RECORD/STATIC SURVEY ~J-JC¡(3 PRODUCTION PROFILE j9S-oa4 PRESSURE/TEMP LOG / cg'5-cSOQ PRESSURE/TEMP DATE: R[~t:IVED t'1.~f 1 7 2002 Alaska Oil & Gas Cons. Comn1isSon AncbOrØge SIGN~ {-L (1gp':'J Please sign and return one copy of this transmittal to Sherrie at th~ åbove address or fax to (907) 561.8317. Thank you. ~ ,.-, WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn. : Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska April 12, 2002 RE: MWD Fonnation Evaluation Logs lR-35, AK-MM-11190 1 LDWG fonnatted Disc with verification listing. ilPI#: 50-029-23050-00 aat-dlD PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 ~CEIVED Signed: ~~ ~'P D /-,. r':J .j () r\:1Q? :--':- /¡, I .. ,\ : ") L.. - Alaska Oil & Gas Cons. Commission Anchorage clr3s." ~ .---- L ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7"'Street Suite # 700 Anchorage, Alaska 99501 RE: Distribution - Fina/ Print( s J The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal/etter to the attention of: Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration (Alaska], Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 WELL DATE LOG TYPE DIGITAL OR CD-ROM 1 MYLAR / SEPIA FILM 1 BLUE LINE PRINT[S] REPORT OR COLOR Open Hole 1 Res. Eva!. CH 1 1 1 dO/-/4S S-178 2/7/02 Mech. CH 1 (oj Caliper Survey Signed: ~ c.Jhp~ ) Date: Print Name: RECEIVED FEB 1 9 2002 Alaska Oil & Gas Cons. Commi88ion PRoACTivE DiAGNOSTic SERvicES, INc., ~ 10 K STREET SuiTE 200, ANC~ORAGE, AK 995~chorage Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: pdsanchorage@memorylog.com Website: www.merl19rylog.com ,--..., I ."'-\ ~~!Æ~E IT F Á,~]~~~!Æ A I#.\.. c¡ IiA 0 IL AND GAS CONSERVATI ON COMMISSION TONY KNOWLES, GOVERNOR 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501.3539 PHONE (907) 279.1433 FAX (907) 276-7542 Chuck Mallary Drilling Engineering Supervisor Phillips Alaska,mc PO Box 100360 Anchorage AK 9951 Re: Kuparuk River Unit 1R-35 Phillips Alaska, mc. Pennit No: 201-210 Sur Loc: 546' FSL, 141' FWL, Sec 17, T12N, RlOE, UM Btmhole Loc. 2001' FNL, 118' FWL, Sec. 9, T12N, RlOE, UM Dear Mr. Mallary: Enclosed is the approved application for permit to drill the above referenced well. The pennit to drill does not exempt you from. obtaining additional pennits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting detenninations are made. Annular disposal has not been requested as part of the Pennit to Drill application for Kuparuk River Unit 1R-35. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on KRU lR pad must comply with the requirements and limitations of 20 MC 25.080. Approval of this pennit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. Blowout prevention equipment (HOPE) must be tested in accordance with 20 MC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ~~'~ Chair BY ORDER OF THE COMMISSION DATED this 7th day of November, 2001 jjcÆnclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ..--- ------. PHilliP", Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 Chuck Mallary Phone (907) 265-6434 Fax: (907) 265-1535 Email: crmalla@ppco.com October 29, 2001 Cammy Oechsli Taylor, Chair Alaska Oil and Gas Conservation Commission 333 West th Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, producer 1 R-35 Dear Commissioner Taylor: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore producer well, KRU 1 R-35, a development well. Please find attached for the review of the Commission the information required by 20 ACC 25.005 (c). If you have any questions or require any further information, please contact Scott Lowry at 265-6869. Sincerely, ~~ Drilling Engineering Supervisor RECEIVED OCT 2 9 2001 Alaska Oil & Gas Cons. Commission Anchorage ORIGINAL .r . "'---' ".--. , " ~ kt l/~ STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1a. Type of work: Drill ø Redrill 0 Re-entry 0 Deepen 0 2. Name of Operator Phillips Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 546' FSL, 147' FWL, Sec. 17, T12N, RWE, UM At top of productive Interval 2105' FNL, 56' FWL, Sec. 9, T12N, R10E, UM At total depth 2007' FNL, 118' FWL, Sec. 9, T12N, R10E, UM 12. Distance to nearest property line I 13. Distance to nearest well 56' @ Target feet 1R-1224' @ 600' 16. To be completed for deviated wells Kickoff depth: 300 MD 18. Casing program size 1 b. Type of well. Exploratory 0 Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone 0 5. Datum elevation (OF or KB) RKB 41 feet 6. Property Designation 02$"(,. 3Ç ~ ADL 25627 ALK 2560 1.1> 7. Unit or property Name Kuparuk River Unit 8. Well number 1 R-35 9. Approximate spud date November 9, 2001 14. Number of acres in property 2560 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 3105 psig At total depth (TVD) 3833 psig Seltlng Depth Maximum hole angle 66° Hole Casing Weight 24" 16' 62.5# 12.25' 9.625" 40# 8.5' 7' 26# 6.125' 3.5" 9.3# Specnlcations Grade Coupling H-40 Weld L-80 BTC-Mod L-80 BTCM L-80 SLHT Length 120' 7904' 11949' 792' 19. To be completed for Redrlll, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured true vertical feet feet Effective Depth: measured true vertical feet feet Casing Conductor Surface Length Cemented Size Production Perforation depth: measured true vertical Development Oil 0 Multiple Zone 0 10. Field and Pool feet Kuparuk River Field Kuparuk River Pool 11. Type Bond (see 20 AAC 25.0251) Statewide Number #5952 180 Amount $200,000 15. Proposed depth (MD and TVD) 12632' MD I 7023' TVD Top Boltom Quantity of Cement MD TVD MD TVD (include stage data) 41' 41' 161' 161' 420sxAS1 41' 41' 7945' 4229' 860 sx AS Lite, 900 sx LiteCrete 41' 41' 11990' 6408' 170 sx Class G 11840' 6269' 12632' 7023' 180 sx Class G wI GasBlok Plugs (measured) Junk (measured) Measured depth True Vertical depth RECEIVED OCT 2 9 ZO01 Alaska Oil & Gas Cons. Commission Anchorage 20. Attachments Filing fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program 0 Drilling fluid program 0 Time vs depth plot DRefraction analysis 0 Seabed report 0 20 MC 25.050 requirements 0 21. I hereby certi~atph 0 going is true and IT to the best of my knowledge Questions? Call Scott Lowry 265-686~ Signed Title: Drilling Engineering Supervisor Date ól q t!J d ).f:l:) l C. 8// PreDarerl bv Sharon Allsuo-fJ ak~ Commission Use Onl} I API number I Approval date 50- 0 z..Cj - 2305O-Cx::) Conditions of approval Samples required 0 Yes iii No Mud log required Hydrogen sulfide measures ~ Yes 0 No Directional survey required Required working pressure for BOPE D2M; 0 3M; 0 5M; 0 10M; 0 Other. SSOO\>'>\ 'M\"'\~~M. ~~~....~ Original Signed By Approved by Cammy Oechali Permit Number 2LJ f-2-1ð Form 10-401 Rev. 12/1/85' ŒJ Yes I See cover lelter for other requirements 0 Yes ŒJ' No 0 No Commissioner 0 by order of [A //J / the commission r Date / ~ "1;' V I 0 11 í ~ ì , V ri Submit in triplicate ,r---. . App}4on for Permit to Drill, Well 1 R-35 Revision No.O Saved: 29-0ct-O1 Permit It - Kuparuk Well 1 R-35 Application for Permit to Drill Document Table of Contents 1. Well Name .................................................................................................................2 Requirements of 20 AAC 25.005 (f)........................................................................................................2 2. Location Summary ...................................................................................................2 Requirements of 20 AAC 25.005(c)(2) ......................................................,............................................2 Requirements of 20 AAC 25.050(b)........................................................................................................2 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ..........................................................................,........................3 4. Drilling Hazards Information ...................................................................................3 Requirements of 20 AAC 25.005 (c)(4) ............................................................"....................................3 5. Procedure for Conducting Formation Integrity Tests ...........................................3 Requirements of 20AAC 25.005 (c)(5) ...................................................................,..................".......... 3 6. Casing and Cementing Program.............................................................................3 Requirements of 20 AAC 25. 005(c)(6) """"""""""""""""""""""""""""""""""""""'"....................3 7. Diverter System Information ...................................................................................4 Requirements of 20 AAC 25. 005(c)(7) ..........................................,........................................................4 8. Drilling Fluid Program .............................................................................................4 Requirements of 20 AAC 25. 005(c)(B) ...........................................................................,.................."... 4 9. Abnormally Pressured Formation Information ..............................l....................... 5 Requirements of 20 AAC 25.005 (c)(9) ............................................................."..............................,.... 5 10. Seismic Analysis .......................................................................................................5 Requirements of 20 AAC 25.005 (c)(10) ........................................................................,.......................5 11. Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ........................................................................,.......................5 12. Evidence of Bonding................................................................................................5 Requirements of 20 AAC 25.005 (c)(12) .....................................................,..........................................5 13. Proposed Drilling Program......................................................................................5 1R-35 PERMIT IT. DOC 0 R I G1irf¡f~C~~~ r"-- App~on for Permit to Drill, Well 1 R-35 Revision No.O Saved: 29-0ct-O1 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 6 Requirements of 20 AAC 25.005 (c)(14) """""""".....................................,..........................................6 15. Attachments ............................................................................................................. 6 Attachment 1 Directional Plan......................................................."""""""""""""""""""""""""""'" 6 Attachment 2 Drilling Hazards.............................................................................................6 Attachment 3 Well Schematic..............................................................................................6 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identitied by a unique name designated by the operator and a unique API number assigned by the commission under 20 MC 25.040(b). For a well with multiple well brancheSr each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commiS5ion The well for which this application is submitted will be designated as 1R-35. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the lollowlng itemSr except for an item already on tile wIth the commission and identitied in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation and at total depth referenced to governmental section lines. (8) the coordinates of the proposed location of the well at the surfac~ referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth' Location at Surface NGS Coordinates Northings: 5,991,750 1546' FSL, 147' FWL, Sec 17, T12N, R10E, UM I RKB Elevation I Eastings: 539,832 Pad Elevation 85.3' AMSL 44.1' AMSL Location at Top of Productive Interval (Kuparuk "Cl" Sand) NGS Coordinates Northings: 5,999,689 2105' FNL, 56' FWL, Sec 9, T12N, R10E, UM Eastings: 544,951 Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 12,210' 6617' 6532' Location at Total Depth I 2007' FNL, 118' FWL, NGS Coordinates Northings: 5,999,786 Eastings: 545,012 Sec 9, T12N, R10E, UM Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 12,632' 7024' 6938' and (D) other information required by 20 AAC 25.050(b/" Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Foro¡ 10-401) mllst (1) include a plat drawn to a 511Ítable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan 1R-35 PERMIT IT DOC am~tM A L ~, App~on for Permit to Drill, Wel/1 R-35 Revision No.O Saved: 29-0ct-O1 and (2) for all wells within ZOO feet of the proposed wellbore (A) list the names of the operators of those wells~ to the extent that those names are known or discoverable in public records¡ and show that each named operator has been furnished a copy of the application by certified mai/; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Pelmlt to Drill must be accompanied by each of the following Items¡ except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC Z5.03!i 20 AAC 25.036r or 20 AAC 25.037" as applicable/ Please reference BOP schematics on file for Nabors 245E. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Driil must be accompanied by each of the following item5~ except for an item already on fiie with the commission and identified in the application: (4) information on drilling hazardS¡ including (A) the maximum downhole pressure that may be encountereet criteria used to determine it and maximum potential surface pressure based on a methane gradient; Based on offset well data, the expected reservoir pressure in the C-l Kuparuk sand for lR-35 is -3000 psi at 6600' tvd, 0.45 psi/ft or 8.7 ppg EMW (equivalent mud weight). The C-l sand could have a maximum reservoir pressure of -3800 psi at 6600' tvd, 0.58 psi/ft or 11.1 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) while drilling lR-35 is calculated using above maximum reservoir pressure, a gas gradient of 0.11 psi/ft, and the C-l Kuparuk sand target at 6608' tvd: MPSP =(6608 ft)*(0.58 - 0.11 psi/ft) = 3105 psi (B) data on potential gas zones,' The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones~ and zones that Imve a propensity for differentl~71 sticking/ Please see Attachment 2 - Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests¡ as required under 20 MC 25.030(f)/ Drill out surface and intermediate casing shoes and perform LOT test or FIT (maximum of 16 ppg EMW) in accordance with the Kuparuk LOT / FIT procedure, that Phillips Alaska has on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a PermIt to Dnll must be accompanied by each of the following Items¡ except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cement/ì¡g program as required by 20 AAC 25,030; and a description of any slotted Ilìler, pre- perforated liner, or screen to be installeet. 1R-35 PERMIT IT. DOC amGtÑ A L r-, App~on for Permit to Drill, Well 1 R-3S Revision No.O Saved: 29-0ct-O1 Casing and Cementing Program Hole Top Btm CsgfTbg Size Weigh Length MOfTVO MOfTVO 00 (in) (in) t (Iblft) Grade Connection (ft) (ft) (ft) Cement Program 16 24 62.5 H-40 Welded 120' 41'/41' 161'/161' 420 sx 15.8 ppg ASl 9-5/8 12-1/4 40 L-80 BTC-Mod 7904' 41'/41' 7945'/4229' Lead: 860 sx 10.7 ppg AS Lite Tail: 900 sx 12.0 ppg 'LiteCRETE'. (Yield=2.40 cuft/sk) Planned TOC=Surface 7 8-1/2 26 L-80 BTC-Mod 11,949' 41'/41' 11,990'/6408' 170 sx 15.8 ppg \G' w/ add. Planned TOC=l1,190' 3-1/2 6-1/8 9.3 L-80 SLHT 792' 11,840'/6269' 12,632'/7023' 180 sx 15.8 ppg 'G' w/ Gasblok Planned TOC=l1,640' 3-1/2 9.3 L-80 EUE 8rd 11,799' 41' /41' 11,840'/6269' Mod 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of tI1e following items, except for an item already on file with the commission and identified in the application: (7) a diagram and descliption of the diverter system as required by 20 MC 25. 035" unle5s this requirement is waived by the commi","5ion under 20 MC 25.035(h)(2); Please reference diverter schematic on file for Nabors 245E. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already 017 file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25. 033; Drilling will be done using mud systems having the following properties: Spud to surface Intermediate Drill out casing point Hole to TD Extended bentonite slurry Freshwater LSND Freshwater LSND Density (ppg) 8.5-9.4 85-9.8 9.5 Funnel Viscosity(sec) 60-300* 35-55 50-65 Yield Point (cP) 25-50 8-25 15-25 Plastic Viscosity (lb/100 sf) 20-40 5-25 12-24 10 see. Gel (lb/100 sf) 15-40 3-10 3-10 API Filtrate (cc) 4-15 5-15 HTHP < 10 PH 8.5-9.5 9-9.5 9-9.5 Solids (%) 3-8 3-10 3-9 *Spud mud should be adjusted to a FV between 200-300 sec/qt to drill gravel beds 1R-35 PERMIT IT. DOC 0 FlTGt¡jji /"'"'- . App~on for Permit to Drill, Well 1 R-35 Revision No.O Saved: 29-0ct-O1 Diagram of Nabors 245E Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An applIcatIon far a Permit to Drill must be accompanIed by each of the following items., except for an item already on file wIth the commIssion and Identified in the applIcation: (9) for an exploratory or stratigraphic test wel¿ a tabulatiOl7 setting out the depths of predicted abnOfmally geo-pressured strata as required by 20 AAC 25. 033{f}; N/ A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the fryllowing items., except for an item already on tile with the cammL'>-sion and Identified in the application: (10) for an exploratOfY or stratigraphic test wel¿ a seIsmic refractIon or reflection analysIs as required by 20 MC 25.061(3); N/ A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a PermIt to Dn!1 must be accompanIed by each of the following items, except for an Item already on file with the commissIon and identified In the application: (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up ngf or floatJilg drIllIng vesse¿ an analysis of seabed conditions as requIred by 20 MC 25.061(b); N/ A - Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An applIcation for a PermIt to Dn!1 must be accompanied by each of the following items., except for an Item already on file with the commissIon and identified in the application: (12) evidence showing that the reqUfi-ements of 20 MC 25.025 (Bonding}have been met. Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items., except for an Item already on file with the commi..""'7on and identified in the application: The proposed drilling program is listed below. Please refer as well to Attachment 3, Well Schematic. 1. MIRU Nabors 245E. 2. Install diverter system. 3. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" 40#, L-80 BTC-Mod casing string to surface. Employ lightweight permafrost cement lead slurry and LiteCRETE tail slurry. Pump adequate excess to ensure cement reaches the surface. If cement does not circulate to surface, perform stage or top job. Install and test BOPE to 5000 psi. Test casing to 2500 psi. 5. Drill out cement and 20' of new hole. Perform LOT/FIT, but do not exceed 16.0 ppg EMW. 6. Drill 8-1/2" hole to intermediate casing point according to directional plan. Run LWD logging equipment with GR and resistivity. 7. Run and cement 7" 26#, L-80 BTC-Mod intermediate casing string. Pressure test casing to 3500 psi. Note: If significant hydrocarbon zones are present above the intermediate casing point, sufficient cement will be pumped for isolation in accordance with 20 MC 25.030(d)(3)(C). 1R-35 PERMIT IT. DOC oRfffmÄ L "'---" ApplJ--tjon for Permit to Drill, Well 1 R-35 Revision No.O Saved: 29-0ct-O1 8. Drill out cement and 20' of new hole. Perform LOT/FIT, but do not exceed 16.0 ppg EMW. 9. Drill 6-1/8" hole to TD according to directional plan. Run LWD logging equipment with GR, resistivity, and density-neutron tools. 10. Run 3-1/2" 9.3#, L-80 SLHT liner on drill pipe with Baker liner top packer and hanger and cement liner. 11. Pressure test liner to 3500 psi. 12. Run 3-1/2" 9.3#, L-80 8rd EUE 8rd-Mod gaslift completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3500 psi. 13. Set TWC and ND BOPE. Install and pressure test production tree. 14. Secure well. Rig down and move out. 15. Handover well to Operations Personnel. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to On!1 mustc b(~ accompanied by each of the following Items¡ except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 MC 25.080 for an annular disposal operation ¡j] the wel£/ Waste fluids generated during the drilling process will be disposed of down a permitted annulus on lR pad or hauled to a KRU Class II disposal well. All cuttings will be disposed of either down a permitted annulus on lR pad or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. At the end of drilling operations, an application may be submitted to permit lR-35 for annular pumping of fluids occurring as a result of future drilling operations on lR pad. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic. 0 RIG I NXf::¡iiic!: c::= ::xJ -- ~~ -- :ë::: :J:::=.. r-- 0- 1200 - 2400 - 1ñ ~ ~ .s:: õ.. 3600- Q) 0 (¡j (.) :¡::; (¡¡ > 4800 - 6000 - 7200 - DrlllQues! 2.00.09.006 SliL: Y,"5991749.93' è, & X~5:39ß31.66' i: reSt. &. !iT FWL., :3ec. 17.T12N.R1 Dir @ 3.00/100ft (12-1/4" Hole): 300.00ft MD, 300.00ft TVD in Dir Rate @ 3.5°/100ft: 1800.001t MD, 1650.47ft TVD End Dir, Start Sail @ 66.21°: 2430.56ft MD, 2004.98ft TVD ~ I 0 I 2400 1 3600 I 1200 9,51B' Casing 7944.BII MD 4229.3ft TVD I 4800 I 6000 Scale: 1 inch = 1200ft ",' Phillips Alaska, Inc. North Slope, Alaska Kuparuk River Unit 1 R...35 (wpO1) Current Well Properties 1R-35 Well: Horizontal Coordinates: Ref. Global Coordinates: 5991749.93 N, 539831.66 E Ref. Structure: 699,82 N, 5.63 E Ref. Geographical Coordinates :70' 23' 18.2538" N, 149' 40' 33.6436" W 546' FSL & 147' FWL, Sec. 17-T12N-RtOE RKB Elevation: North Reference: Units: 85.30ft above Mean Sea Level True North Feet (US) ) 5pe! rarry-5 U1 ~lífr&:~t;J"rlr:=:""I~~'r~jl:' A I'Þ\HWiçn ;¡;"m¡:qIlY 9-5/8" Csg PI. ... Drill out 8-1/2" Hole ) 7" Csg Pt.., Drill 6-1/8" HoletoTD End Dir, Start Sail @ 15.70°: 12200.811t MD, 6608,OOIt TVD :1 ;,63i244ft MD, 702:3,531: TVD &118' FWL, Sec.9-T12tH')jOF) 3-112' Line' 12632.4ft MD 7023.5tt TVD I 7200 I 8400 I 9600 C) ::0 --- ~ --- ~ r-- 7500 - 6000 - 4500 - 3000 - 1500 - -3000 -1500 I 0 I Eastings 4500 I Scale: 1 inch = 150Oft Well: 1500 I 3000 I 6000 I 7500 I 9000 I Phillips Alaska, Inc. North Slope, Alaska Kuparuk River Unit 1 R..35 (wpO1) 3,112' Uner 12632.4" MD 7023.5ft TVD : 12EJ:32.44ft MD, 7023,53ft & 118'FWL, SeG,9-T 7' Casing 11BBO,Oft MD 640B.Oft TVD Current Well Properties 1R.35 Begin Dir @ 2.5°/1001t: 10180.3811 MD, 5131.061t TVD Horizontal Coordinates: Ref. Global Coordinates: 5991749,93 N, 539831,66 E Ref. Structure: 699,82 N, 5,63 E Ref. Geographical Coordinates :70' 23' 18,2538" N, 1490 40' 33,64360 W 546' FSL & 147' FWL, Sec, 17-T12N-R10E RKB Eievation : North Reference: Units: 85,30ft above Mean Sea Level True North Feet (US) Reference is TRUE North ~I'I' sun <, ì5Ãï'r::-LíÑ'ij' ',iJiFfvTc.:"Ifs A HilimlMirtoo C,¡)!ììpålÌ:V End Dir, Start Sail @ 66.21 ° : 2430.561t MD, 2004.98ft TVD Increase in Dir Rate @ 3.5°/1O0ft: 1800.00lt MD, 1650.47ft TVD 10500 I - 7500 - 6000 ) - 4500 en OJ c :E 1::: 0 Z - 3000 - 1500 ) ð 0 '" ~ II £:. U .S: 0 - ,- ----~ -- ,--~ -- ----- -- - Begin Dir @ 3.0o/100ft (12-1/4" Hole): 300.001t MD, 300.00ft TVD -- ~ -- ~ -- ~ --, - -- - -- -- -- - -- ~ -- - ,-- --- 0 DrlllQues! 2.00.09.006 -3000 I -1500 Scale: 1 inch = 1500ft '(,05991749,93' N & X",S39831.66' E F:St. &1.iT FI¿VL, S¡)Ç.17-T12N-H1OL:) I 0 I 4500 Eastings I 6000 I 7500 I 9000 I 1500 I 3000 íri -¡¡¡ U C/) I 10500 <:::) ::t:J --- G") -- ~ r-- ) PROPOSAL REPORT 26 October, 2001 ) Your Ref: Per 'Prelim' Plan ver #1.B Surface Coordinates: 5991749.93 N, 539831.66 E (70023' 18.2538" N, 149040' 33.6436" W) Surface Coordinates relative to Project H Reference: 991749.93 N, 39831.66 E (Grid) Surface Coordinates relative to Structure: 699.82 N, 5.63 E (True) Kelly Bushing: 85.30ft above Mean Sea Level ~1~"""V-SUl1 rim¡;¡¡;;:[cHa:::::\I:.:Œ~J::a:. ¡a. twilbwrtm Ö>ri""""r Proposal Ref: pro9660 Sperry-Sun Drilling Services Proposal Report for 1R-35 (wp01) Your Ref: Per 'Prelim' Plan ver#1.B Revised: 26 October, 2001 Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Section Comment (ft) (ft) (ft) (ft) (ft) 0.00 0.000 0.000 -85.30 0.00 0.00 N O.OOE 0.00 SHL: Y=5991749.93' N & X=539831.E E (546' FSL & 147' FWL, Sec. 17-T12 R10E) 100.00 0.000 0.000 14.70 100.00 0.00 N 539831.66 E 0.000 0.00 200.00 0.000 0.000 114.70 200.00 0.00 N 539831.66 E 0.000 0.00 1: 300.00 0.000 0.000 214.70 300.00 0.00 N 539831.66 E 0.000 0.00 Begin Dir @ 3.00/1 OOft (12-1/4" 300.00ft MD, 300.00ft TVD 400.00 3.000 40.000 314.65 399.95 5991751.94 N 539833.33 E 3.000 2.60 500.00 6.000 40.000 5991757.98 N 539838.34 E 3.000 10.39 600.00 9.000 40.000 5991768.02 N 539846.68 E 3.000 23.34 700.00 12.000 40.000 5991782.04 N 539858.32 E 3.000 41.43 800.00 15.000 40.000 5991800.00 N 539873.22 E 3,000 64.61 900.00 18.000 40.000 5991821.86 N 539891.36 E 3.000 92.80 1000.00 97.17 N 81.54 E 5991847.54 N 539912.68 E 3.000 125.94 1100.00 126.49 N 106.13 E 5991876.98 N 539937.12 E 3.000 163.92 1200.00 159.46 N 133.80 E 5991910.10 N 539964.61 E 3.000 206.66 1300.00 196.01 N 164.47 E 5991946.81 N 539995.09 E 3.000 254.03 1400.00 236.03 N 198.05 E 5991987.01 N 540028.45 E 3.000 305.89 1337.29 1422.59 279.42 N 234.46 E 5992030.59 N 540064.63 E 3.000 362.12 1416.61 1501.91 326.04 N 273.58 E 5992077.43 N 540103.50 E 3.000 422.55 1492.65 1577.95 375.79 N 315.32 E 5992127.39 N 540144.98 E 3.000 487.02 <::,) 1565.17 1650.47 428.51 N 359.57 E 5992180.35 N 540188.94 E 3.000 555.35 Increase in Dir Rate @ 3.5°/100ft : 1800.00ft MD, 1650.47ft TVD ) ::t::J 39.628 1582.00 1667.30 441.62 N 370.49 E 5992193.51 N 540199.79 E 3.500 572.29 Base Permafrost --. 1900.00 48.329 38.512 1633.79 1719.09 484.84 N 405.56 E 5992236.92 N 540234.63 E 3.500 627.65 ~ 2000.00 51.675 37.172 1698.06 1783.36 545.34 N 452.53 E 5992297.67 N 540281.28 E 3.500 703.99 --. 2100.00 55.035 35.949 1757.74 1843.04 609.78 N 500.30 E 5992362.37 N 540328.71 E 3.500 784.06 ~ 2200.00 58.406 34.824 1812.61 1897.91 677.94 N 548.69 E 5992430.78 N 540376.74 E 3.500 867.58 2300.00 61.786 33.777 1862.46 1947.76 749.55 N 597.53 E 5992502.65 N 540425.18 E 3.500 954.24 r-- 26 October, 2001 - 14:24 Page 2 of 9 DrillQuesf 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for 1R-35 (wp01) Your Ref: Per 'Prelim' Plan ver#1.B Revised: 26 October, 2001 Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Section Comment (ft) (ft) (ft) (ft) (ft) 2400.00 65.174 32,795 1907.10 1992.40 824.34 N 646.61 E 3.500 1043.70 2430.56 66.211 32.505 1919.68 2004.98 847.79 N 661.64 E 3.500 1071.55 End Dir, Start Sail @ 66.210 : 2430.56 MD, 2004.98ft TVD 2500.00 66.211 32.505 1947.69 2032.99 901.37 N 0.000 1135.09 2600.00 66.211 32.505 1988.03 2073.33 978.54 N 0.000 1226.58 ) 2700.00 66.211 32.505 2028.37 2113.67 1055.71 N 0.000 1318.08 2800.00 66.211 32.505 2068.70 5992887.29 N 540668.91 E 0.000 1409.58 2900.00 66.211 32.505 2109.04 5992964.72 N 540717.67 E 0.000 1501.08 3000.00 66.211 32.505 2149.38 5993042.14 N 540766.43 E 0.000 1592.58 3100.00 66.211 32.505 2189.72 5993119.57 N 540815.19 E 0.000 1684.08 3200.00 66.211 32.505 2230.05 5993197.00 N 540863.95 E 0.000 1775.57 3300.00 66.211 1518.72 N 1089.16 E 5993274.43 N 540912.71 E 0.000 1867.07 3400.00 66.211 1595.89 N 1138.33E 5993351.86 N 540961.47 E 0.000 1958.57 3500.00 66.211 1673.06 N 1187.50 E 5993429.29 N 541010.24 E 0.000 2050.07 3600.00 66.211 1750.23 N 1236.68 E 5993506.72 N 541059.00 E 0.000 2141.57 3700.00 66.211 1827.40 N 1285.85 E 5993584.15 N 541107.76 E 0.000 2233.07 2557.38 1904.57 N 1335.02 E 5993661.58 N 541156.52 E 0.000 2324.56 2597.72 1981.74N 1384.19E 5993739.01 N 541205.28 E 0.000 2416.06 2638.05 2058.90 N 1433.36 E 5993816.44 N 541254.04 E 0.000 2507.56 2678.39 2136.07 N 1482.54 E 5993893.87 N 541302.80 E 0.000 2599.06 2718.73 2213.24 N 1531.71 E 5993971.30 N 541351.56E 0.000 2690.56 <:::') 32.505 2650.00 2735.30 2244.94 N 1551.91 E 5994003.11 N 541371.59E 0.000 2728.15 Top Ugnu ) ::c 32.505 2673.77 2759.07 2290.41 N 1580.88 E 5994048.73 N 541400.32 E 0.000 2782.06 -- 32.505 2714.10 2799.40 2367.58 N 1630.05 E 5994126.16 N 541449.08 E 0.000 2873.55 ~ 32.505 2754.44 2839.74 2444.75 N 1679.22 E 5994203.59 N 541497.84 E 0.000 2965.05 32.505 2794.78 2880.08 2521.92 N 1728.39 E 5994281.02 N 541546.60 E 0.000 3056.55 -- :ë:: 4700.00 66.211 32.505 2835.12 2920.42 2599.09 N 1777.57 E 5994358.45 N 541595.36 E 0.000 3148.05 ):::::... 4800.00 66.211 32,505 2875.45 2960.75 2676.25 N 1826.74 E 5994435.88 N 541644.12 E 0.000 3239.55 4900.00 66.211 32.505 2915.79 3001.09 2753.42 N 1875.91 E 5994513.31 N 541692.88 E 0.000 3331 .05 r-- 5000.00 66.211 32.505 2956.13 3041.43 2830.59 N 1925.08 E 5994590.74 N 541741.64 E 0.000 3422.54 5100.00 66.211 32.505 2996.47 3081.77 2907.76 N 1974.25 E 5994668.17 N 541790.40 E 0.000 3514.04 26 October, 2001 - 14:24 Page30f9 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for 1R-35 (wp01) Your Ref: Per 'Prelim' Plan ver#1.B Revised: 26 October, 2001 Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Section Comment (ft) (ft) (ft) (ft) (ft) 5200.00 66.211 32.505 3036.80 3122.10 2984.93 N 0.000 3605.54 5300.00 66.211 32.505 3077.14 3162.44 3062.10 N 0.000 3697.04 5400.00 66.211 32.505 3117.48 3202.78 3139.27 N 0.000 3788.54 5500.00 66.211 32.505 3157.82 3243.12 3216.44 N 0.000 3880.04 5600.00 66.211 32.505 3198.15 3283.45 3293.60 N 0.000 3971 .53 ) 5604.58 66.211 32.505 3200.00 3285.30 5995058.86 N 542036.43 E 0.000 3975.72 Base Ugnu 5700.00 66.211 32.505 3238.49 3323.79 5995132.74 N 542082.96 E 0.000 4063.03 5800.00 66.211 32.505 3278.83 3364.13 5995210.17 N 542131.72 E 0.000 4154.53 5900.00 66.211 32.505 3319.17 3404.47 5995287.60 N 542180.48 E 0.000 4246.03 5996.27 66.211 32.505 3358.00 3443.30 5995362.14 N 542227.42 E 0.000 4334.12 Top West Sak 6000.00 66.211 2416.80 E 5995365.03 N 542229.24 E 0.000 4337.53 6100,00 66.211 2465.97 E 5995442.46 N 542278.00 E 0.000 4429.03 6200.00 66.211 2515.14E 5995519.89 N 542326.76 E 0.000 4520.52 6300.00 66.211 2564.32 E 5995597.32 N 542375.52 E 0.000 4612.02 6400.00 66.211 2613.49 E 5995674.75 N 542424.28 E 0.000 4703.52 3646.49 3988.12 N 2662.66 E 5995752.18 N 542473.04 E 0.000 4795.02 3686.83 4065.29 N 2711.83 E 5995829.61 N 542521.80 E 0.000 4886.52 3727.17 4142.46 N 2761.00 E 5995907.04 N 542570.56 E 0.000 4978.02 3767.50 4219.63 N 2810.18E 5995984.47 N 542619.32 E 0.000 5069.51 3807.84 4296.80 N 2859.35 E 5996061.90 N 542668.08 E 0.000 5161.01 c::> 32.505 3762.88 3848.18 4373.97 N 2908.52 E 5996139.33 N 542716.84 E 0.000 5252.51 32.505 3803.22 3888.52 4451.13 N 2957.69 E 5996216.76 N 542765,60 E 0.000 5344.01 ) ::0 32.505 3843.55 3928.85 4528.30 N 3006.86 E 5996294.19 N 542814.36 E 0.000 5435.51 --- 32.505 3883.89 3969.19 4605.47 N 3056.04 E 5996371,61 N 542863.12 E 0.000 5527.01 (;") 32.505 3924.23 4009.53 4682.64 N 3105.21 E 5996449.04 N 542911 .88 E 0.000 5618.50 -- 7449.01 66.211 32.505 3944,00 4029.30 4720.46 N 3129.31 E 5996487.00 N 542935.78 E 0.000 5663.35 Base West Sak ~ 7500.00 66.211 32.505 3964.57 4049.87 4759.81 N 3154.38 E 5996526.47 N 542960.64 E 0.000 5710.00 7600.00 66.211 32.505 4004.90 4090.20 4836.98 N 3203.55 E 5996603.90 N 543009.40 E 0.000 5801.50 7700.00 66.211 32.505 4045.24 4130.54 4914.15 N 3252.72 E 5996681.33 N 543058.16 E 0.000 5893.00 r-- 7800.00 66.211 32.505 4085.58 4170.88 4991.32 N 3301 .90 E 5996758.76 N 543106.92 E 0.000 5984.50 26 October, 2001 - 14:24 Page 4 of 9 Dri/lQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for 1R-35 (wp01) Your Ref: Per 'Prelim' Plan ver #1.8 Revised: 26 October, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 R Measured Sub-Sea Vertical Local Coordinates Depth Incl, Azim. Depth Depth Northings Eastings Section Comment (ft) (ft) (ft) (ft) (ft) 7900.00 66.211 32.505 4125.92 4211 .22 5068.48 N 3351.07 E 0.000 6076.00 7944.83 66.211 32.505 4144.00 4229.30 5103.08 N 3373.11 E 0.000 6117.02 9-5/8" Csg Pt. ... Drill out 8-1/2" Hole 9 5/8" Casing 8000.00 66.211 32.505 4166.25 4251.55 5145.65 N 0.000 6167.49 8100.00 66.211 32.505 4206.59 4291.89 5222.82 N 0.000 6258.99 ) 8200.00 66.211 32.505 4246.93 4332.23 5299.99 N 0.000 6350.49 8300.00 66.211 32.505 4287.27 5997145.91 N 543350.72 E 0.000 6441.99 8400.00 66.211 32.505 4327.60 5997223.34 N 543399.48 E 0.000 6533.49 8500.00 66.211 32.505 4367.94 5997300.77 N 543448.24 E 0.000 6624.99 8600.00 66.211 32.505 4408.28 5997378.20 N 543497.00 E 0.000 6716.48 8700.00 66.211 32.505 4448.62 5997455.63 N 543545.76 E 0.000 6807.98 8800.00 66.211 5763.00 N 3793.61 E 5997533.06 N 543594.52 E 0.000 6899.48 8900.00 66.211 5840.17 N 3842.79 E 5997610.49 N 543643.28 E 0.000 6990.98 9000.00 66.211 5917.34 N 3891.96 E 5997687.92 N 543692.04 E 0.000 7082.48 9100.00 66.211 5994.51 N 3941.13 E 5997765.35 N 543740.80 E 0.000 7173.98 9200.00 66.211 6071.68 N 3990.30 E 5997842.78 N 543789.56 E 0.000 7265.47 4775.94 6148.85 N 4039.47 E 5997920.21 N 543838.32 E 0.000 7356.97 4816.28 6226.02 N 4088.65 E 5997997.64 N 543887.08 E 0.000 7448.47 4856.62 6303.18 N 4137.82 E 5998075.06 N 543935.84 E 0.000 7539.97 4896.95 6380.35 N 4186.99 E 5998152.49 N 543984.60 E 0.000 7631.47 4937.29 6457.52 N 4236.16 E 5998229.92 N 544033.36 E 0.000 7722.97 C) 9800.00i::!I; 66.211 32.505 4892.33 4977.63 6534.69 N 4285.33 E 5998307.35 N 544082.12 E 0.000 7814.47 ) :J::" 9900.00 66.211 32.505 4932.67 5017.97 6611.86 N 4334.50 E 5998384.78 N 544130.88 E 0.000 7905.96 10000.00 66.211 32.505 4973.00 5058.30 6689.03 N 4383.68 E 5998462.21 N 544179.64 E 0.000 7997.46 -. 10100.00 66.211 32.505 5013.34 5098.64 6766.20 N 4432.85 E 5998539.64 N 544228.40 E 0.000 8088.96 C'~'. 10180.38 66.211 32.505 5045.76 5131.06 6828.22 N 4472.37 E 5998601.88 N 544267.60 E 0.000 8162.50 Begin Dir @ 2.5°/100ft: 10180.38ft -..", MD, 5131.06ft TVD - C::~~. 10200.00 65.720 32.505 5053.76 5139.06 6843.34 N 4482.00 E 5998617.04 N 544277.15 E 2.500 8180.42 ~;~ 10300.00 63.220 32.502 5096.85 5182.15 6919.43 N 4530.49 E 5998693.40 N 544325.23 E 2.500 8270.65 r--- 10400.00 60.720 32.499 5143.84 5229.14 6993.87 N 4577.91 E 5998768.09 N 544372.25 E 2.500 8358.91 10500.00 58.220 32.496 5194.63 5279.93 7066.51 N 4624.19 E 5998840.97 N 544418.14 E 2.500 8445.03 10600.00 55.720 32.493 5249.14 5334.44 7137.22 N 4669.22 E 5998911.92 N 544462.80 E 2.500 8528.86 26 October, 2001 - 14:24 Page 50f9 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for 1R-35 (wp01) Your Ref: Per 'Prelim' Plan ver#1.B Revised: 26 October, 2001 Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Section Comment {ft} (ft) (ft) (ft) (ft) 10700.00 53.220 32.490 5307.25 5392.55 7205.86 N .15 E 2.500 8610.23 10800.00 50.720 32.486 5368.85 5454.15 7272.29 N 8.10E 2.500 8688.99 10900.00 48.220 32.483 5433.83 5519.13 7336.40 N 54 8.57 E 2.500 8764.98 11000.00 45.720 32.479 5502.06 5587.36 7398.06 N 544627.50 E 2.500 8838.07 11100.00 43.220 32.474 5573.42 5658.72 7457.16 N 544664.79 E 2.500 8908.12 ) 11200.00 40.720 32.469 5647.76 5999289.54 N 544700.39 E 2.500 8974.98 11300.00 38.220 32.464 5724.95 5999343.35 N 544734.23 E 2.500 9038.54 11400.00 35.720 32.458 5804.84 5999394.26 N 544766.23 E 2.500 9098.67 11500.00 33.220 32.451 5887.27 5999442.18 N 544796.35 E 2.500 9155.26 11537.72 32.277 32.448 5919.00 5999459.45 N 544807.21 E 2.500 9175.66 C70 11600.00 30.720 5034.00 E 5999487.01 N 544824.52 E 2.500 9208.20 11675.92 28.822 5054.22 E 5999518.93 N 544844.57 E 2.500 9245.89 Top HAZ 11700.00 28.220 5060.38 E 5999528.66 N 544850.68 E 2.500 9257.39 11768.51 26.507 5077.27 E 5999555.33 N 544867.43 E 2.500 9288.88 Base HAZrrop Kalubik 11800.00 25.720 5084.70 E 5999567.07 N 544874.80 E 2.500 9302.73 6324.58 7825.13 N 5106.91 E 5999602.15 N 544896.81 E 2.500 9344.15 6335.30 7828.98 N 5109.35 E 5999606.02 N 544899.24 E 2.500 9348.72 K1 fLower Kalubik 6408.00 7853.72 N 5125.06 E 5999630.84 N 544914.81 E 2.500 9378.01 7" Csg Pt ... Orill6-1f8" Hole to TO 7" Casing 6332.01 6417.31 7856.71 N 5126.95 E 5999633.84 N 544916.69 E 2.500 9381.56 6368.00 6453.30 7867.92 N 5134.06 E 5999645.08 N 544923.74 E 2.500 9394.83 Top Kuparuk 32.376 6426.29 6511.59 7884.86 N 5144.81 E 5999662.08 N 544934.39 E 2.500 9414.88 ) C) 32.350 6521.92 6607.22 7909.51 N 5160.43 E 5999686.82 N 544949.88 E 2.500 9444.06 ::0 32.350 6522.70 6608.00 7909.69 N 5160.55 E 5999687.00 N 544950.00 E 2.500 9444.28 End Oir, Start Sail @ 15.700 : 12200.81ft MO, 6608.00ft TVO --- 12210.47 15.700 32.350 6532.00 6617.30 7911.90 N 5161.94E 5999689.22 N 544951.39 E 0.000 9446.90 Top C1 Target eJ) 12236.43 15.700 32.350 6557.00 6642.30 7917.84 N 5165.70 E 5999695.17 N 544955.12 E 0.000 9453.92 TopB --- 12300.00 15.700 32.350 6618.19 5999709.75 N ~,. 6703.49 7932.37 N 5174.91 E 544964.24 E 0.000 9471.12 ~ 12317.46 15.700 32.350 6635.00 6720.30 7936.36 N 5177.44 E 5999713.76 N 544966.75 E 0.000 9475.85 Top A4 12328.88 15.700 32.350 6646.00 6731 .30 7938.97 N 5179.09 E 5999716.38 N 544968.39 E 0.000 9478.94 Top A3 r-- 12379.78 15.700 32.350 6695.00 6780.30 7950.61 N 5186.46 E 5999728.05 N 544975.70 E 0.000 9492.71 Top A2 12400.00 15.700 32.350 6714.46 6799.76 7955.23 N 5189.39 E 5999732.69 N 544978.60 E 0.000 9498.18 26 October, 2001- 14:24 Page 6 of9 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for 1 R-35 (wp01) Your Ref: Per 'Prelim' Plan ver #1.B Revised: 26 October, 2001 M Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinat< Depth Incl. Azim. Depth Depth Northings Eastings Northings (ft) (ft) (ft) (ft) (ft) (ft) 12429.64 15.700 32.350 6743.00 6828.30 7962.01 N 12500.00 15.700 32.350 6810.73 6896.03 7978.09 N 12600.00 15.700 32.350 6907.00 6992.30 8000.95 N - 12632.44 15.700 32.350 6938.23 7023.53 8008.37 N 0.000 0.000 0.000 0.000 9506.20 9525.24 9552.30 9561.07 All data is in Feet (US) unless otherwise stated. Directions and coordinates ar< Vertical depths are relative to RKB = 85.3' (MSL). Northings and Eastings Magnetic Declination at Surface is 26.035° (15-0ct-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 546' FSL & 147' FWL and cal Based upon Minimum Curvature type calcu' " The Bottom Hole Displacement is 9561. Comments 'on Coordinates Northings Eastings (ft) (ft) Comment C) 0.00 0.00 N 0.00 E ::0 300.00 300.00 0.00 N 0.00 E 1800.00 1650.47 428.51 N 359.57 E --. 2430.56 2004.98 847.79 N 661.64 E C":) 7944.83 4229.30 5103.08 N 3373.11 E --- <: 10180.38 5131.06 6828.22 N 4472.37 E 11990.04 6408.00 7853.72 N 5125.06 E ::r:::.. 12200.81 6608.00 7909.70 N 5160.55 E r-- 12632.44 7023.53 8008.37 N 5223.04 E SHL: Y=5991749.93' N & X=539831.66' E (546' FSL & 147' FWL, Sec. 17-T12N-R10E) Begin Dir @ 3.00/100ft (12-1/4" Hole): 300.00ft MD, 300.00ft TVD Increase in Dir Rate @ 3.5°/1O0ft: 1800.00ft MD, 1650.47ft TVD End Dir, Start Sail @ 66.21 ° : 2430.56ft MD, 2004.98ft TVD 9-5/8" Csg PI. ... Drill out 8-1/2" Hole Begin Dir @ 2.5°/1O0ft : 1 0180.38ft MD, 5131.06ft TVD 7" Csg Pt ... Drill 6-1/8" Hole to TD End Dir, Start Sail @ 15.70° : 12200.81ft MD, 6608.00ft TVD Total Depth: 12632.44ft MD, 7023.53ft TVD 26 October, 2001 - 14:24 Page 7 of 9 North Slope, Alaska Kuparuk 1R Comment Base Kuparuk Total Depth: 12632.44ft MD, 7023.53- TVD ) 31/2" Liner ) DrillQuest 2.00.09.006 C) ::x:J --- G'"') -- <~ ~ r-- Kuparuk River Unit Formation Tops Formati on Plane (Below Well Origin) Sub-Sea Dip Dip Dir. (ft) Deg. Deg. 1582.00 0.000 0.305 2650.00 0.000 0.305 3200.00 0.000 0.305 3358.00 0.000 0.305 3944.00 0.000 0.305 5919.00 0.000 0.305 6038.00 0.000 0.305 6120.00 0.000 0.305 6250.00 0.000 0.305 6368.00 0.000 0.305 6532.00 6557.00 6635.00 6646.00 6695. 6743. 26 October, 2001 - 14:24 Profile Measured Vertical Depth Depth (ft) (ft) 1823.96 4241.08 5604.58 5996.27 7449.01 1667.30 2735.30 3285.30 3443.30 4029.30 12429.64 6828.30 Sperry-Sun Drilling Services Proposal Report for 1R-35 (wp01) Your Ref: Per 'Prelim' Plan ver #1.8 Revised: 26 October, 2001 Penetration Point Sub-Sea Depth Northings (ft) (ft) 6532.00 6557.00 6635.00 6646.00 6695.00 Base Permafrost Top Ugnu Base Ugnu Top West Sak Base West Sak 7682.91 N 5016.54 E C70 7742.19 N 5054.22 E Top HRZ 7778.47 N 5077.27 E Base HRZffop Kalubik 7828.98 N 5109.35 E K1/Lower Kalubik 7867.92 N 5134.06 E Top Kuparuk 7911.90 N 5161.94 E Top C1 Target 7917.84 N 5165.70 E TopB 7936.36 N 5177.44 E TopM 7938.97 N 5179.09 E Top A3 7950.61 N 5186.46 E Top A2 7962.01 N 5193.68 E Base Kuparuk 6743.00 Page 8 of 9 North Slope, Alaska Kuparuk 1R ) ) DrillQuest 2.00.09.006 C) ::0 --- C") --- ~ r-- Kuparuk River Unit Casing details From Measured Vertical Depth Depth (ft) (ft) <Surface> <Surface> <Surface> <Surface> <Surface> <Surface> Targets associated with this wellpath Target Name 1 R-35 A3 Sand 26 October, 2001 - 14:24 Sperry-Sun Drilling Services Proposal Report for 1R-35 (wp01) Your Ref: Per 'Prelim' Plan ver#1.B Revised: 26 October, 2001 North Slope, Alaska Kuparuk 1A To Measured Vertical Depth Depth (ft) (ft) Casing Detail 7944.83 11990.04 12632.44 95/8" Casing 7" Casing 3 1/2" liner ) 4229.30 6408.00 7023.53 Target Entry Coordinates TVD Northings Eastings Target Target (ft) (ft) (ft) Shape Type 6731.30 7942.59 N 5180.72 E Point Current Target Mean Sea LeveIJGlobal Coordinates: 6646.00 5999720.00 N 544970.00 E Geographical Coordinates: 700 24' 36.3578" N 149038' 01.7805" W 6617.30 7909.69 N 5160.55 E Point Current Target Mean Sea Level/Global Coordinates: 6532.00 5999687.00 N 544950.00 E Geographical Coordinates: 700 24' 36.0344" N 1490 38' 02.3726" W 6205.30 7793.07 N 5089.92 E Point Current Target Mean Sea Level/Global Coordinates: 6120.00 5999570.00 N 544880.00 E Geographical Coordinates: 700 24' 34.8878" N 1490 38' 04.4451" W ) Page90f9 DrillQuest 2.00.09.006 Phillips Alaska, Inc. 1 (wpO1) MD Inc Azim. SSTVD TVD N/S E/W Y X DLS V.S. Comment (ft) (Deg) (Deg) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) (ft) 0,00 0.00 0.00 -85.30 0.00 0.00 N 0.00 E 5991749.93 N 539831.66 E 0.00 0.00 SHL 300.00 0.00 0.00 214.70 300.00 0.00 N 0.00 E 5991749.93 N 539831.66 E 0.00 0.00 Begin Dir (12-1/4" Hole) 1800.00 45.00 40.00 1565.17 1650.47 428.51 N 359.57 E 5992180.35 N 540188,94 E 3.00 555.35 Increase in DLS ) 1823.96 45.80 39.63 1582.00 1667.30 441 .62 N 370.49 E 5992193.52 N 540199.79 E 3.50 572.29 Base Permafrost 2430.56 66.21 32.51 1919.68 2004.98 847.79 N 661.64 E 5992601.23 N 540488.77 E 3.50 1071 .55 End Dìr; Start Sail 4241.08 66.21 32.51 2650.00 2735.30 2244.94 N 1551.91 E 5994003.11 N 541371.59 E 0,00 2728.15 Top Ugnu 5604,58 66.21 3251 3200.00 3285.30 3297,14 N 2222,36 E 5995058,86 N 542036.43 E 0.00 3975.72 Base 5996.27 66.21 32.51 3358.00 3443,30 3599.40 N 2414.97 E 5995362.14 N 542227.42 E 0,00 4334,12 Top West Sak 7449,02 66.21 32.51 3944.00 4029.30 4720.47 N ~'I 29,31 E 5996487.00 N 542935,78 E 0.00 5663,35 Base West Sak 7944.83 66.21 32.51 4144.00 4229.30 5103.08 N 3373.11 E 5996870.90 N 543177.54 E 0.00 6117.02 9-5/8" Csg Pt, Drill out 8-1/2" Hole 10180.38 66.21 32.51 5045,76 5131.06 6828.22 N 4472.37 E 5998601.88 N 544267.60 E 0.00 8162.50 Begin Dir 11537.72 32.28 32.45 5919.00 6004,30 7682,91 N 5016.54 E 5999459.46 N 544807.21 E 2,50 9175,66 C 70 1 Î 675.92 28,82 32.44 6038.00 6123,30 7742.19 N 5054.22 E 5999518,93 N 544844.57 E 2.50 9245,89 Top HnZ 11768,51 26,51 32,43 6120,00 6205,30 7778.47 N 5077.27 E 5999555.33 N 544867.43 E 2,50 9288.88 Base HRZ / Top Ka!ubik 11911.65 22,93 32.41 6250.00 6335,30 7828.98 N 5109.35 E 5999(306.02 N 544899.24 E 2.50 9348.72 Kif Lower Ka!ubìk 11990.04 20.97 32.40 6322.70 6408.00 7853.72 N 5125.06 E 5999630.84 N 544914.81 E 2.50 9378.01 7" Csg Pt '" Drill 6-1/8" Hole 12038.36 19.76 32.39 6368.00 6453.30 7867.92 N 5134.06 E 5999645,08 N 544923.74 E 2.50 9394.83 Top Kuparuk 12200.81 15.70 32.35 6522.70 6608.00 7909.69 N 5160.55 E 5999687.00 N 544950.00 E 2.50 9444.28 End Dir; Start Sail 12210.47 15.70 32.35 6532.00 6617.30 7911.90 N 5161.94 E 5999689.22 N 544951.39 E 0.00 9446.90 Top CI Target 12236.44 15.70 32.35 6557.00 6642.30 7917.84 N 5165.70 E 5999695,17 N 544955.12 E 0.00 9453.92 Top B 12317.46 15.70 32.35 6635,00 6720.30 7936.36 N 5177.44 E 5999713.76 N 544966.75 E 0.00 9475.85 Top A4 ) 12328.88 15.70 :32,35 6646.00 6n1.30 7938.97 N 5179,09 E 5999716,38 N 544968.39 E 0.00 9478.94 Top A3 C)2379.78 15.70 32,35 6695.00 6780.30 7950.61 N 5186.46 E 5999728.05 N 544975.70 E 0.00 9492.71 Top A2 :X. 12429.64 15,70 32.35 6743,00 6828,30 7962.01 N 5193.68 E 5999739.49 N 544982.86 E 0.00 9506,20 Base -:J2632.44 15.70 32.35 6938.23 7023.53 8008.37 N 5223.04 E 5999786,00 N 545011.97 E 0.00 9561.07 Total Depth ~" -"'.." ~ ~ r-- Company: Field: Referenee Site: Reference Well: Reference Wellpath: ,/"', ,~ Sperry-Sun Anticollision Report Phillips Alaska Inc. Kuparuk River Unit Kuparuk 1 R Pad Plan: 1R-35 1R-35 10/26/2001 Time: 15:00:00 Page: 1 Date: Well: Plan: 1 R-35, True North 1 R-35 @ 85.3' 85.3 Co-ordinate(NE) Reference: Vertical (TVD) Reference: Dh: Oracle Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing GLOBAL SCAN APPLIED: All wellpaths \\ithin 200'+ 100/1000 of reference Interpolation Method: MD Interval: 100.00 It Depth Range: 41.20 to 12632.40 It Maximnm Radius: 1459.12 It Reference: Error Model: Scan Method: Error Surface: Survey Program for Definitive Wellpath Date: 10/15/2001 Validated: No Planned "'rom To Survey It It 41.20 1000.00 1000.00 12630.30 Casing Points Version: Toolcode 3 Tool Name Planned: 1 R-35 (wp01) V1 Planned: 1R-35 (wp01) V1 CB-GYRO-SS MWD Camera based gyro single shots MWD - Standard MD TVD Diameter Hole Size It It in in 7944.83 4229.35 9.625 12.250 11990.04 6408.08 7.000 8.500 12632.40 7023.57 3.500 6.125 Name 9-5/8" 7" 3-1/2" Summary <___nom.--__m_---- Offset Wellpath m--m____-_m___._> Site Well Wellpath Kuparuk 1 R Pad Kuparuk 1 R Pad Kuparuk 1 R Pad Kuparuk 1 R Pad Kuparuk 1 R Pad Kuparuk 1 R Pad Kuparuk 1 R Pad Kuparuk 1 R Pad Kuparuk 1 R Pad Kuparuk 1 R Pad Kuparuk 1 R Pad Kuparuk 1 R Pad Kuparuk 1 R Pad Kuparuk 1 R Pad 1R-13 1R-14 1R-15 1R-16 1R-19 1R-19 1R-20 1 R-21 1 R-22 1R-22 1 R-23 1R-32 1R-33 1R-34 1R-13V1 1R-14 V1 1R-15 V1 1R-16 V1 1R-19VO 1R-19AV1 1 R-20 VO 1R-21 VO 1 R-22 VO 1R-22A VO 1 R-23 VO 1 R-32 VO 1 R-33 VO 1 R-34 V1 Reference Offset Ctr-Ctr No-Go Allowable MD MD Distance Area Deviation Warning It It It It It 600.96 600.00 21.57 11.15 10.42 Pass: Major Risk 300.00 300.00 29.86 5.82 24.04 Pass: Major Risk 300.00 300.00 89.21 7.09 82.12 Pass: Major Risk 394.09 400.00 151.56 7.94 143.62 Pass: Major Risk 932.37 900.00 158.13 24.31 134.27 Pass: Major Risk 932.37 900.00 158.13 24.31 134.27 Pass: Major Risk 1750.50 1700.00 129.28 51.28 79.04 Pass: Major Risk 804.91 800.00 58.61 14.04 44.57 Pass: Major Risk 494.95 500.00 62.46 9.14 53.34 Pass: Major Risk 300.00 300.00 60.49 5.66 54.83 Pass: Major Risk 300.00 300.00 119.66 5.44 114.22 Pass: Major Risk 299.97 300.00 137.76 5.75 132.02 Pass: Major Risk 815.80 800.00 107.03 15.82 91.60 Pass: Major Risk 805.98 800.00 53.10 14.58 38.53 Pass: Major Risk ORIGINAL . /,--" ~ 1 R-35 Drillina Hazards Summary 12-1/411 Hole /9-5/8" Casina Interval Event Conductor Broach Well Collision Hydrate gas Gravel and sand sloughing Shoe Fracture/Lost Returns during cement job Risk Level Low Low Low Low Moderate 8-1/2" Hole /7" Casina Interval Event Shale stability in HRZ and K-1 intervals High ECO and swabbing if higher MW is required Hole cleaning in long, high angle tangent Drilling too deep into possibly elevated pressure of Kuparuk sands. Risk Level Moderate Low Moderate Moderate 6-1/8" Hole /3 1/2" Liner Interval Event Drill into higher than anticipated reservoir pressure. Hole cleaning in long, high angle tangent Barite sag if higher mud weight are required. Risk Level Moderate Low Low I Mitigation Strategy Set 120' of conductor (instead of 80') and monitor cellar continuously during interval. Careful well planning and surveying, adherence to anti-collision policy. Use coldest water available to mix in mud to keep it cool. Elevated mud viscosity from spud; Hi dens sweeps. Reduced pump rates, and lightweight tail cement Mitigation Strategy Control with higher MW and proper drilling practices. Control mud rheology closely, and monitor surge/swab pressures with PWO tool. Pump out on trips as necessary. Good drilling practices. Monitor GR/Res logs closely and work closely with geologist to ensure casing point is placed as planned. Mitigation Strategy Set 7" casing shoe in good shale to provide adequate kick tolerance. Hold kick drill with crews immediately prior to drilling into Kuparuk sands. Good drilling practices. Most of high angle hole will be cased. Watch mud properties closely. Control mud chemical additions (lubes) to prevent barite settling. Follow guidelines provided. 1R-35 Dril/íng Hazards Summary. doc prepared by Scott Lowry 10/16/01 ORIGIN~Lof1 .. /"-", KRU 1 R-35 Produc\... Proposed Completion Schematic T opset Base Case 16" 62.6# @ +1-120' MD . ..; t I Depths are based on Nabors 245E RKB Surface csg. 9-S/8" 40.0# L-80 BTC (+1- 794S' MD I 4229' TVD) Intermediate csg. 7" 26.0# L-80 BTCM (+1- 11,990' MD I 6408' TVD) Future Perforations Production Liner 3-1/2" 9.3# L-80 SLHT (+1-12,632' MD I 7023' TVD) I 1. j ~ -..- - I r I ~ i ... .. ,~, PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 3-1/2" FMC Gen V Tubing Hanger, 3-1/2" L-80 EUE8RD pin down 3-1/2" 9.3# L-80 EUE8RD Spaceout Pups as Required 3-1/2" 9,3# L-80 EUE8RD Tubing to Surface l 3-1/2" Cameo 'OS' nipple wi 2.813" No-Go Profile. Set at +1- SOO' MD 3-1/2" 9.3# L-BO EUE8RD tubing to landing nipple 3-1/2" x 1" Cameo 'KBUG' Mandrels wi DV's and RK latch's (Max, OD S.390", ID 2,92"), 6' L-80 handling pups installed above and below on GLM. Spaced out wi 3-1/2" 9,3# L-80 EUE8RD tubing as follows: GLM 1 2 3 4 S TVD (RKB) 2600' 40S0' SOSO' S750' 6206' (As noted below) 3-1/2" x 1-1/2" Cameo 'MMG' mandrel wi shear valve and latch (Max. OD S.96B", ID 2.92"), pinned for 3000 psi shear (casing to tubing differential), 6' L-80 handling pups installed above and below. 1 it 3-1/2" 9,3# L-80 EUE8RD tubing 3-1/2" Cameo 'OS' nipple wi 2.7S" No-Go profile, 1 it 3-1/2" 9.3# L-80 EUE8RD tubing S.12S" x 3" Baker locator sub 4-1/2" Baker GBH-22 casing seal assembly wi 1S' stroke, 3-1/2" L-80 EUE8RD box up - Liner Assembly (run on drillpipe), set @ +1- 11,840' MD Baker 7" x S" 'ZXP' Liner Top Isolation Packer with HR profile Baker 7" x S" 'Flexlock' Liner Hanger Baker 17' Seal Bore Extension XO Sub,S" Stub Acme box x 3-1/2" SLHT pin 1 it 3-1/2" 9.3# L-80 SLHT tubing 3-1/2" 9.3# L-80 SLHT liner as needed 3-1/2" Baker Landing Collar 1 it 3-1/2" 9.3# L-80 SLHT tubing 3-1/2" Baker Float Collar 1 it 3-1/2" 9.3# L-80 SLHT tubing 3-1/2" Baker Float Shoe 0 RIG I NA L SLL,10/22/01,v1 ~ ~. 1 R-35 Drilling Hazards Summary 12-1/4" Hole /9-5/8" Casing Interval Event Conductor Broach Well Collision Hydrate gas Gravel and sand sloughing Shoe Fracture/Lost Returns during cement job Risk Level Low Low Low Low Moderate 8..1/2" Hole / 7" Casing Interval Event Shale stability in HRZ and K-1 intervals High ECD and swabbing if higher MW is required Hole cleaning in long, high angle tangent Drilling too deep into possibly elevated pressure of Kuparuk sands. Risk Level Moderate Low Moderate Moderate 6-1/8" Hole / 3 1/2" Liner Interval Event Drill into higher than anticipated reservoir pressure. Hole cleaning in long, high angle tangent Barite sag if higher mud weight are required. Risk Level Moderate Low Low Mitigation Strategy Set 120' of conductor (instead of 80') and monitor cellar continuously during interval. Careful well planning and surveying, ~dherence to anti~collision policy. Use coldest water available to mix in mud to keep it cool. Elevated mud viscosity from spud; Hi dens sweeps. Reduced pump rates, and lightweight tail cement Mitiqation StrateQY Control with higher MW and proper drilling practices. Control mud rheology closely, and monitor surge/swab pressures with PWD tool. Pump out on trips as necessary. Good drilling practices. Monitor GR/Res logs closely and work closely with geologist to ensure casing point is placed as planned. Mitiqation Strateqy Set 7" casing shoe in good shale to provide adequate kick tolerance. Hold kick drill with crews immediately prior to drilling into Kuparuk sands. Good drilling practices. Most of high angle hole will be cased. Watch mud properties closely. Control mud chemical additions (lubes) to prevent barite settling. Follow guidelines provided. 1R-35 Dril/ing Hazards Summary 11-D7-D11.doc revised by T. Brockway 11/07/01 Page 1 of 2 ~ Pad and Surroundina Area Event H2S encountered while drilling. Produced levels of H2S in the range of 160 ppm have been noted in well 1 R-20. Risk Level Low ~, Mitigation Strategy Approved Hydrogen Sulfide contingency measures will remain in effect during the drilling of 1 R-35. if it becomes necessary to notify the AOGCC of an H2S encounter. drillina will be suspended and will resume only after the development of detailed remedial and continaency procedures. full compliance with 20 MC 25.065 and the applicable referenced sections of API RP49. and approval of the AOGCC. 1R-35 Drilling Hazards Summary 11"()7..()11.doc revised by T. Brockway 11/07101 Page 2 of 2 ~ ~", American Expresse 172 DATE ~1 o~~ ~ /m-40IIO?I ~';"D;~ ~~E c,.b.-k.¡ ~ / IloGCc. I sl/oo. Q:) 1 ~ ~ LLíJ-I(~ ---:j Jc-. I/o. , ( DOLLARS Cash Advance Draft Issued by Integrated Payment System, Inc. Englewood. Colorado I: .0 2 .00 ~001: ~ 5 CHECK 1 STANDARD LETTER DEVELOPMENT ¡ DEVELOPMENT REDRILL EXPLORATION INJECTION WELL INJECTION WELL REDRILL ~ ~ TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSNUTTAL LETTER WELL NAME ¡(It Ii, / ~- 3S CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTILATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR DIif'OSAL ù¿) NO ANNULAR DISPOSAL cfJ YES ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new wellbore segment of existing well ----' Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . . ~ / e<-&n,1 Hßt¿¡uI-?f~ -(1M ,/-;x/( r tPL/~ t:l--rt/'lv (~ ~=s«. fib Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated.. . ANNUL~S ;;YES + M'!;J ~~.' ~ t iiuJs 4- C-u I¡;~ ~ ~ tLt1t1ulu:s ~ /Rr«:/- SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved . subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. WEll PERMIT CHECKLIST FIELD & POOL t/c¡O If)/) ADMINISTRATION 1.permitfeeattached.........~............. 2. Lease number appropriate1". ». . . : '~~ J- (C? :'iù/. . 3. Uniquewellnameandnumber..... .......... .. . 4. Weillocatedinadefinedpool................. . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbóre plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . IN 10. Operator has appropriate bond in force. . . . . . . . . . . ., . N 11. Permit can be issued without conservation order. . . . . . . . . N 12. Permit can.be issued without administrative approval.. . . . . .. N 13. Can permit be approved before 15-day wait.. . . . . . . . . . Y N 14. Conductor string provided ., . . . . . . .. . . . . . . . . . ~ N 15. Surface casing protects all known USDWs. . . . . . . . . .. . . N 16. CMT vol adequate to circulate on conductor & surf csg. . . . . Y N. ~ 17. CMT vol adequate to tie-in long sm 'ng to surf csg. . . . . . . . ~ \t!) (.1. .(\ 1;\~.'O'~,?~",>c:;:.. \ ~~ ~~ \'t~ ~'"'>~~ 18. CMT will cover all known productive horizons. . . . . . . . . . N 19. Casing designs adequate for C~ T, B & permafrost. . . . . . . . N .' " 20. Adequatetankageorreservepit.. . . . . . . . . . . . . . . . . Y N ý"",..:,:~,~~~\ ""~ ~'"::k~~ Ç>\~ . 21. If a re-drill, has a 10-403 for abandonment been approved. . . .-¥---N- ~ ~ . 22. Adequate well bore separation proposed.. . . . . . . . . . . . N 23. If diverter required, does it meet regulations. . . . . . . . . . N 24. Drilling fluid program schematic & equip list adequate. . . . . N 25. BOPEs, do they meet regulation. . . . . . . . D . " . . . . N \ n l:"o.Æ'\ '!'"?I"'.þ .. . \ I , i~.- RÞ,TE ,26. BOPE press rating appropriate; test to 3>5'0' ~">\ psig. . N \Å~~~~~"'t-'" ~\'ÐS~C;í SO'-"-.)'f~\ \,::>V\ ~\--\(\C@IJ...!' ~I' TV\ [-ç- 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N . 28. Work will occur without operation shutdbwn. . . . . . . . . . . Y Â "r.."\\. -_\ - ~ ~; eo .. :-. \ '~'VV(.. ~ ~ r< 29. Is presence of H;zS gas probable.. . . . . . . . . . . . . . . . Y @~I"J(I ~'\O~'<J ~\~0f '\(}~~ ""',:>.. 'I...\~ l;. ~'-.J \ ~~ . ~~~~ Ì'" <\ 't::>\\->-~ 30. Permit can beissuedw/ohydrogen sulfide measures. .... ß!N 6fJS<J rz...,..lUè.RI- /K(-ZLJ ýÞ\U,~~:re..d 1Ç;,3é():;'¡,Ir'5 ih-1. 1{/¿¥6D~ 31. Da~a ~resented. on potential overpressure zones. . . . . . . Y c:xr-<-c:..1c..d HL-:S-€...rVO/Y' t'~urL '-<I 8.7 ?<f'õ Erru::ù (D,<J5:r~VtI j~;......t).~. ! 32. Seismic anal~~ls of shallow gas zones. . . . . . . . . ;;¿. .. Ii N , " , APPR DATE 33. Seabed condition survey (If off-shore). . . . . . . . . . . . . Y N . ßD 10. SDoi 34, Contact nameJphone lor weekly progress reports [""p/ora only} Y N 1-'\<..:> iJ "'> '" W """'So \.-. ,,>¡:>\;)~ß."~ ; ANNULAR DISPOSAl35. With proper cementing records, this plan . ~~ù\~t;¡-ð~'S.~~Q\ ~'i \ocz~~~ . C~\cs.;"\S;:~",' (A) will contain waste in a suitable receiving zone; . . . . . . . Y N (B) will not contaminate freshwater; or cause drilling waste. .. Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GE~OlOGY: ENGIN EE.RING: UIC/Annular COMMISSION: R~ ./ ~crw WM--8~ S TE~ ~7Yn H{ç JM~ ¿'(¡b (fi J",I oJ A~~R DATE ~ /0-30<61 , ENGINEERING GEOLOGY APPR DATE a /1 /¿/Cd . . COMPANY -rtu 1/ ~$ WELL NAME /£35 PROGRAM: exp - dev ./' redrll- serv - wellbore seg _ann. disposal para req - INIT CLASSJ ~V f Oil ~ GEOL AREA f3èfb UNIT# () / I/~f) ON/OFF SHORE C/1 N N :' N ~' N N y¿N N .sti-r'~ /bC4'¡'~ ¿,M.. I71:>L DZS-b:3~' -10 ~c..'¡~ ~Þu:z.l o.-r-d .--/DI-a-( ¿r,/d VJ-t. TJÞLOz.S"h7.'7o Com ments/l nstructions: c:\msoffice\wordian\diana\checklist (rev. 11/011100) c 0 Z 0 -I :E ::0 )- -I m Z -I :I: - en » ::0 m » ) ,r-, ~ 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 specialeffort has been made to chronologically organize this category of information. ~ ~ Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Apr 11 10:51:27 2002 Reel Header Service name.............LISTPE Date.....................02/04/l1 Origin...................STS Reel Name................UNKNOWN Continuation Number......Ol Previous Reel Name.......UNKNOWN Comments.................STS LIS Tape Header Service name.............LISTPE Date.....................02/04/11 Origin...................STS Tape Name................UNKNOWN Continuation Number......Ol Previous Tape Name.......UNKNOWN Comments.................STS LIS Physical EOF Comment Record TAPE HEADER KLiparuk River Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: MWD RUN 1 AK-MM-11190 S. HUIBAN D. WESTER MWD RUN 5 AK-MM-11190 A. WEAVER F. HERBERT MSL 0) OPEN HOLE BIT SIZE (IN) 12.250 8.500 6.125 Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services lR-35 500292305000 Phillips Alaska, Inc. Sperry-Sun Drilling Services ll-APR-02 MWD RUN 2 AK-MM-11190 S. HUIBAN D. WESTER MWD RUN 4 AK-MM-11 1 90 A. WEAVER F. HERBERT MWD RUN 99 AK-MM-11190 S. HUIBAN D. WESTER 17 12N 10E 546 147 83.80 42.90 CASING SIZE (IN) 20.000 9.625 7.000 DRILLERS DEPTH (FT) 161. 0 7922.0 11973.0 dol-a J 0 IOÎfo3 ~ ~ 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1, 2, AND 4 WERE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUN 4 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD). 3. THE TOOL STRING FAILED THE SHALLOW PULSE TEST ON MWD RUN 3 - NO FOOTAGE WAS MADE/NO DATA WERE ACQUIRED. 4. MWD RUN 5 COMPRISED DIRECTIONAL WITH DGR, EWR4, COMPENSATED THERMAL NEUTRON POROSITY (CTN), STABILIZED LITHO-DENSITY (SLD), AND PWD. 5. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM D. SCHWARTZ, PHILLIPS ALASKA, DATED 12/06/01, QUOTING AUTHORIZATION FROM M. LONGDEN. 6. VERTICAL RESISTIVITY INVERSION (VRI) DATA ARE PRESENTED AS A DEEP PHASE ENHANCED (RDVR) CURVE IN MWD MERGED DATA, AND AS 4 ENHANCED CURVES AND 4 MODELED CURVES IN THE FINAL RAW MWD FILE. THIS FINAL FILE COMPRISES A PORTION OF MWD RUN 2. 7. MWD RUNS 1, 2, 4, & 5 REPRESENT WELL lR-35 WITH API#:50-029-23050-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12630'MD / 7008'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP ~ SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP ~ SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED TNPS = SMOOTHED MATRIX, FIXED CTFA = SMOOTHED CTNA = SMOOTHED SBD2 = SMOOTHED BIN) . SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLD SLIDE ~ NON-ROTATED INTERVALS ACCOUNTING FOR BIT-TO-SENSOR DISTANCE MEXP = FORWARD-MODELED EXTRA SHALLOW PHASE RESISTIVITY. FORMATION EXPOSURE TIME. THERMAL NEUTRON POROSITY (SANDSTONE HOLE SIZE). AVERAGE OF FAR DETECTOR'S COUNT RATE. AVERAGE OF NEAR DETECTOR'S COUNT RATE. BULK DENSITY-COMPENSATED (LOW-COUNT MESP = FORWARD-MODELED SHALLOW PHASE RESISTIVITY. MEMP = FORWARD-MODELED MEDIUM PHASE RESISTIVITY. MEDP ~ FORWARD-MODELED DEEP PHASE RESISTIVITY. VEXP = INVERSION-DERIVED EXTRA SHALLOW PHASE RESISTIVITY (ENHANCED) . VESP = INVERSION-DERIVED SHALLOW PHASE RESISTIVITY (ENHANCED) . VEMP = INVERSION-DERIVED MEDIUM PHASE RESISTIVITY (ENHANCED) . VEDP = INVERSION-DERIVED DEEP PHASE RESISTIVITY (ENHANCED) . r----. ~ PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" MUD WEIGHT: 10.4 PPG MUD SALINITY: 300 PPM CHLORIDES FORMATION WATER SALINITY: 16000 FLUID DENSITY: 1.0 G!CC MATRIX DENSITY: 2.65 G!CC LITHOLOGY: SANDSTONE $ File Header Service name.............STSLIB.001 Service Sub Level Name... Version NLimber...........1.0.0 Date of Generation.......02!04!11 Maximum Physical Record..65535 File Type................LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPX RPS RPM RPD FET ROP RDVR FCNT NCNT NPHI PEF RHOB DRHO $ 1 PPM CHLORIDES clipped curves; all bit runs merged. .5000 START DEPTH 123.5 123.5 123.5 123.5 123.5 123.5 161. 5 5980.5 11856.5 11857.0 11857.0 11872.5 11957.5 11957.5 STOP DEPTH 12582.0 12589.0 12589.0 12589.0 12589.0 12589.0 12630.0 7319.5 12521.5 12522.0 12521. 5 12537.5 12537.5 12537.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 123.5 2485.5 MWD 2 2485.5 7944.5 MWD 4 7944.5 11983.0 MWD 5 11983.0 12630.0 MWD 99 5980.5 7319.5 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.. ...................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O ~ /~ Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 RDVR MWD OHMM 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 123.5 12630 6376.75 25014 123.5 12630 ROP MWD FT/H 0.58 10965.3 170.919 24938 161. 5 12630 GR MWD API 11.31 437.37 91.8012 24918 123.5 12582 RPX MWD OHMM 0.31 2000 15.1464 24932 123.5 12589 RPS MWD OHMM 0.18 2000 18.382 24932 123.5 12589 RPN NHD OHMM 0.11 2000 26.0849 24932 123.5 12589 RPD MWD OHMM 0.12 2000 33.2036 24932 123.5 12589 FET MWD HOUR 0.08 140.38 1. 84366 24932 123.5 12589 NPHI MWD PU-S 16.42 65.18 38.7173 1330 11857 12521. 5 FCNT MWD CNTS 91 1023 270.471 1331 11856.5 12521.5 NCNT MHD CNTS 12114 36673 19830 1331 11857 12522 RHOB NHD G/C~j 1. 84 3.26 2.40651 1161 11957.5 12537.5 DRHO MHD G/CM -0.23 0.68 0.0548148 1161 11957.5 12537.5 PEF MI'm BARN 2.45 17.72 6.32011 1331 11872.5 12537.5 RDVR MWD OHMM 0.377 175.123 8.64199 2679 5980.5 7319.5 First Reading For Entire File..........123.5 Last Reading For Entire File...........12630 File Trailer Service name........ .....STSLIB.OOI Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......02/04/11 MaximLim Physical Record..65535 File Type................LO Next File Name...... ... ..STSLIB.002 Physical EOF File Header Service name........ ... ..STSLIB.002 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......02/04/11 Maximum Physical Record..65535 File Type............... .LO PrevioLis File Name.......STSLIB.OOI Comment Record FILE HEADER FILE NUMBER: RAH MHD CLirves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE 2 header data for each bit run in separate files. 1 .5000 START DEPTH STOP DEPTH .~ GR RPX RPS RPD FET RPM ROP $ 123.5 123.5 123.5 123.5 123.5 123.5 161. 5 2449.0 2441.0 2441. 0 2441.0 2441.0 2441.0 2485.5 # 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: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................. Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-t1~e...0 ~ 16-NOV-01 Insite 66.16 Memory 2486.0 123.0 2486.0 .0 65.9 TOOL NUMBER PB02280HRG8 PB02280HRG8 12.250 Water 9.00 280.0 10.0 1000 .0 Based 5.000 3.901 7.100 3.000 60.0 78.8 60.0 60.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWDOIO FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 ,~ ~ RPM RPD FET MWD010 MWD010 MWD010 OHMM OHMM HOUR 4 4 4 1 1 1 68 68 68 20 24 28 6 7 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 123.5 2485.5 1304.5 4725 123.5 2485.5 ROP MWD010 FT/H 0.58 10965.3 113.301 4649 161. 5 2485.5 GR MWD010 API 11.31 133.81 68.9644 4652 123.5 2449 RPX MWD010 OHMM 1.23 2000 48.1525 4636 123.5 2441 RPS MWD010 OHMM 1.11 2000 59.2083 4636 123.5 2441 RPM MWD010 OH~I 1.16 2000 83.8606 4636 123.5 2441 RPD MWD010 OHMM 0.91 2000 116.88 4636 123.5 2441 FET MWD010 HOUR 0.08 2.04 0.770017 4636 123.5 2441 First Reading For Entire File..........123.5 Last Reading For Entire File...........2485.5 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......02/04/11 Maximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/04/11 Maximum Physical Record..65535 File Type................LO PrevioLis File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SU~IARY VENDOR TOOL CODE FET RPM RPS RPX RPO GR ROP $ 3 header data for each bit rLin in separate files. 2 .5000 START DEPTH 2441.5 2441.5 2441.5 2441.5 2441.5 2449.5 2486.0 STOP DEPTH 7900.5 7900.5 7900.5 7900.5 7900.5 7908.0 7944 . 5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 19-NOV-01 Insite 66.16 Memory 7945.0 2486.0 7945.0 61. 2 ~ MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record....... ......Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sLlb-type...O ~ 68.8 TOOL NUMBER PB02280HRG8 PB02280HRG8 12.250 7922.0 Water 9.20 68.0 9.4 400 .0 Based 5.000 3.772 7.100 3.000 70.0 95.0 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR M¡.m020 API 4 1 68 8 3 RPX MWD020 OHIvIM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2441.5 7944.5 5193 11007 2441.5 7944.5 ROP MWD020 FT/H 2.62 675.98 233.919 10918 2486 7944.5 GR MWD020 API 27.94 142.86 80.3024 10918 2449.5 7908 RPX MWD020 OHMM 1.17 82.99 11.2173 10919 2441.5 7900.5 RPS MWD020 OHMM 1. 08 134.78 12.819 10919 2441.5 7900.5 RPM MWD020 OHMM 0.9 1563.35 13.4844 10919 2441. 5 7900.5 RPD MWD020 OHMM 0.96 1567.94 14.0718 10919 2441. 5 7900.5 FET MWD020 HOUR 0.11 21.72 0.583967 10919 2441.5 7900.5 First Reading For Entire File..........2441.5 Last Reading For Entire File...........7944.5 /"""",, ~ File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......02/04/ll Maximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name.............STSLIB.004 Service SLib Level Name... Version Number.......... .1.0.0 Date of Generation.......02/04/ll Maximum Physical Record..65535 File Type................LO Previous File Name.......STSLIB.003 Comment Recol-d FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 4 header data for each bit run in separate files. 4 .5000 START DEPTH 7901. 0 ì 901. 0 7901. 0 ì 901. 0 ì 901. 0 ì90B.5 ì945.0 STOP DEPTH 1192ì.5 1192ì.5 1192ì.5 1192ì.5 1192ì.5 11935.5 11983.0 # 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: MAXIMUM ANGLE: 28-NOV-Ol Insite 66.16 Memory 11983.0 ì945.0 11983.0 23.5 6ì.4 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR E\AiR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER PB023l2HWRG6 PB023l2HWRG6 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 119ì3.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): HUD PH: HUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): Based Water 9.20 4ì.0 9.0 300 3.4 1. 800 ìO.O ~ ~ MUD AT ~X CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 1. 065 2.000 2.200 123.0 70.0 70.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth Llnits...........Feet Data Reference Point........ .... ..Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7901 11983 9942 8165 7901 11983 ROP MWD040 FT/H 1. 37 485.43 136.05 8077 7945 11983 GR MWD040 API 40.82 437.37 117.483 8055 7908.5 11935.5 RPX MWD040 OHMM 0.31 1157.78 3.37246 8054 7901 11927.5 RPS MWD040 OHMM 0.18 1821. 84 4.7156 8054 7901 11927.5 RPM MWD040 OHMM 0.11 1867.02 5.34188 8054 7901 11927.5 RPD MWD040 OHMM 0.12 2000 7.90443 8054 7901 11927.5 FET MWD040 HOUR 0.23 140.38 2.55765 8054 7901 11927.5 First Reading For Entire Fi1e..........7901 Last Reading For Entire File...........11983 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......02/04/11 Maximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name.............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/04/11 Maximum Physical Record..65535 File Type................ LO ~ Previous File Name.......STSLIB.004 Comment Record FILE HE}\DER FILE NUMBER: RAW MWD CLirves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FCNT NPHI NCNT PEF RPX RPX RP~1 RPD FET GR RHOB DRHO ROP $ 5 ,~ header data for each bit run in separate files. 5 .5000 START DEPTH 11856.5 11857.0 11857.0 11872.5 11928.0 11928.0 11928.0 11928.0 11928.0 11936.0 11957.5 11957.5 11983.5 # 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: M}\XIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 SLD CTN $ STOP DEPTH 12521. 5 12521.5 12522.0 12537.5 12589.0 12589.0 12589.0 12589.0 12589.0 12582.0 12537.5 12537.5 12630.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPEPATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: 04-DEC-01 Insite 66.16 Memory 12630.0 11983.0 12630.0 14.4 21. 9 TOOL NUMBER PB02317FGRV4 PB02317FGRV4 PB02317FGRV4 PB02317FGRV4 6.125 Water 10.40 52.0 9.7 300 2.7 Based 1.900 1.137 1.750 1.400 68.0 118.2 68.0 68.0 .~ ~. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value................ ..... .-999 Depth Units....................... DatLim Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 NPHI MWD050 PU-S 4 1 68 32 9 FCNT MWD050 CNTS 4 1 68 36 10 NCNT MWD050 CNTS 4 1 68 40 11 RHOB MWD050 G/CM 4 1 68 44 12 DRHO MWD050 G/CM 4 1 68 48 13 PEF MWD050 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11856.5 12630 12243.3 1548 11856.5 12630 ROP MWD050 FT/H 0.74 161. 24 64.0111 1294 11983.5 12630 GR MWD050 API 38.5 172.66 111.07 1293 11936 12582 RPX MWD050 OHMM 1.02 450.91 3.59195 1323 11928 12589 RPS MWD050 OHMM 0.48 1000.76 4.42989 1323 11928 12589 RPM MWD050 OHMM 0.53 2000 53.9021 1323 11928 12589 RPD MWDO50 OHMM 1. 04 2000 51.9011 1323 11928 12589 FET MWD050 HOUR 0.42 123.32 11.6558 1323 11928 12589 NPHI MWD050 PU-S 16.42 65.18 38.7173 1330 11857 12521.5 FCNT MWD050 CNTS 91 1023 270.471 1331 11856.5 12521. 5 NCNT MWD050 CNTS 12114 36673 19830 1331 11857 12522 RHOB MWD050 G/CM 1. 84 3.26 2.40651 1161 11957.5 12537.5 DRHO MWD050 G/CM -0.23 0.68 0.0548148 1161 11957.5 12537.5 PEF MWD050 BARN 2.45 17.72 6.32011 1331 11872.5 12537.5 First Reading For Entire File..........11856.5 Last Reading For Entire File...........12630 File Trailer Service name.............STSLIB.005 Service Sub Level Name... Version Number... ........1.0.0 Date of Generation...... .02/04/11 MaximLim Physical Record..65535 File Type................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 Service SLib Level Name... Version Number.. ...... ...1.0.0 Date of Generation.......O2/04/11 Maximum Physical Record..65535 File Type................LO Previous File Name.......STSLIB.005 .~ Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE VEMP VESP VEXP MEDP MEMP MESP MEXP VEDP $ 6 ..--.., header data for each bit run in separate files. 99 .5000 START DEPTH 5980.5 5980.5 5980.5 5980.5 5980.5 5980.5 5980.5 5980.5 STOP DEPTH 7319.5 7319.5 7319.5 7319.5 7319.5 7319.5 7319.5 7319.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO 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 VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTRO~~G. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILT~~TE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point............. .Undefined 19-NOV-01 Insite Processed 5980.0 7320.0 61.2 68.8 TOOL NUMBER PB02280HRG8 PB02280HRG8 12.250 Water 9.20 68.0 9.4 400 .0 Based 5.000 3.772 7.100 3.000 70.0 95.0 70.0 70.0 ~ ~, Frame Spacing.....................60 .lIN Max frames per record.............Undefined Absent valLle......................-999 Depth Units....................... Datum specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 MEXP MWD099 OHMM 4 1 68 4 2 MESP MWD099 OHMM 4 1 68 8 3 MEMP MWD099 OHMM 4 1 68 12 4 MEDP MI;¡D099 OHMl--1 4 1 68 16 5 VEXP MWD099 OHMM 4 1 68 20 6 VESP MWD099 OHMM 4 1 68 24 7 VEMP MWD099 OHMM 4 1 68 28 8 VEDP MWD099 OHMM 4 1 68 32 9 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5980.5 7319.5 6650 2679 5980.5 7319.5 MEXP MWD099 OHMM 1.7 35.832 6.64896 2679 5980.5 7319.5 MESP MWD099 OHMM 1.613 62.227 7.0945 2679 5980.5 7319.5 MEMP MWD099 OHMM 0.985 2000 12.7554 2679 5980.5 7319.5 MEDP MWD099 OHMM 0.879 2000 15.0152 2679 5980.5 7319.5 VEXP MWD099 OHMM 1. 305 71.071 6. 9297 2679 5980.5 7319.5 VESP MWD099 OHMM 0.968 264.477 7.65357 2679 5980.5 7319.5 VEMP MWD099 OHMM 0.301 179.099 8.12279 2679 5980.5 7319.5 VEDP MWD099 OHMM 0.377 175.123 8.64199 2679 5980.5 7319.5 First Reading For Entire Fi1e..........5980.5 Last Reading For Entire File.......... .7319.5 File Trailer Service name........... ..STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/04/11 Maximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.007 Physical EOF Tape Trailer Service name..... ........LISTPE Date.....................02/04/11 Origin.. .................STS Tape Name................UNKNOWN Continuation NLimber......01 Next Tape Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name...... .......LISTPE Date.....................02/04/11 Origin...................STS Reel Name................UNKNOWN ContinLiation NLimber......01 Next Reel Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File ~ .~