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Home My WebLink About198-1831. 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: Pull/Replace ESP 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 8250'feet 7829'feet true vertical 4104' feet None feet Effective Depth measured 7180'feet 6779', 7203'feet true vertical 3581'feet feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 7184' 3583' Packers and SSSV (type, measured and true vertical depth)6779' 7203' 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: West Sak 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: Burst Collapse Gravel Pack Liner 8190' Casing 4094'8231' 7830' 3889' 121'Conductor Production 16"80' measured TVD 7-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 198-183 50-029-22919-00-00 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: ADL0025649, ADL0025650 Kuparuk River Field/ West Sak Oil Pool KRU 1D-112 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 121' Well Shut-In 324-383 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: ESP Feed Thru Packer: Baker SC-1 Gravel SSSV: None Elliot Tuttle elliott.tuttle@conocophillips.com (907) 263-4742Staff RWO/CTD Engineer 7324-7364', 7454-7484', 7532-7560', 7668-7698', 7774-7814' 3647-3666', 3709-3723', 3746-3759', 3811-3825', 3862-3881' 627' 4.59" Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov 3399', 3592' 3399' 3592' By Grace Christianson at 7:47 am, Sep 24, 2024 Digitally signed by Elliott Tuttle DN: OU=CTD/ RWO Senior Engineer, O =Conoco Phillips, CN=Elliott Tuttle, E= elliott.tuttle@conocophillips.com Reason: I am approving this document Location: Date: 2024.09.23 16:27:17-08'00' Foxit PDF Editor Version: 13.0.0 Elliott Tuttle Page 1/5 1D-112 Report Printed: 9/19/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/22/2024 03:30 8/22/2024 04:00 0.50 MIRU, MOVE RURD P Complete rig down check list. 0.0 0.0 8/22/2024 04:00 8/22/2024 08:30 4.50 MIRU, MOVE MOB P Move rig off 1D-42, spot over 1D-112, hang tree in cellar and spot wellhead equipment. Spot kill tank, spot cuttings tank. RU hardline. Rig accept 8:30. 0.0 0.0 8/22/2024 08:30 8/22/2024 12:00 3.50 MIRU, WELCTL RURD P Take on filtered seawater. Process DP in pipe shed. 0.0 0.0 8/22/2024 12:00 8/22/2024 15:00 3.00 MIRU, WELCTL KLWL P PT surface lines. Kill IA pumping 140 bbls down IA and up TBG. Kill TBG by bullheading 100 bbl at 3.5 BPM down TBG 1040 psi. 0.0 0.0 8/22/2024 15:00 8/22/2024 15:30 0.50 MIRU, WELCTL OWFF P Flow check well. Flowing. 0.0 0.0 8/22/2024 15:30 8/22/2024 16:00 0.50 MIRU, WELCTL KLWL P Kill TBG by bullheading 50 bbl at 3.5 BPM down TBG. 0.0 0.0 8/22/2024 16:00 8/22/2024 17:30 1.50 MIRU, WELCTL OWFF P Flow check well. Flowing back, but decreasing slowly. // Charged up formation letting relax, no flow started at 17:00 0.0 0.0 8/22/2024 17:30 8/22/2024 20:00 2.50 MIRU, WELCTL MPSP P Set BPV and test 1000 psi // Trouble getting BPV in hanger, WH personnel retrieve secondary BPV from shop, install test 1000psi @ 2 bpm good test 0.0 0.0 8/22/2024 20:00 8/22/2024 23:00 3.00 MIRU, WHDBOP NUND P Nipple down tubing adapter from well head, dummy penetrator stuck in adapter free from adapter, all bolts seased to nuts backed out of adapter and had to be freed after tubing head off 0.0 0.0 8/22/2024 23:00 8/23/2024 00:00 1.00 MIRU, WHDBOP NUND P Check LDS // Install adapter 0.0 0.0 8/23/2024 00:00 8/23/2024 01:30 1.50 MIRU, WHDBOP NUND P Nipple up BOPs // Install riser // Torque bolts // Perform RKBs 0.0 0.0 8/23/2024 01:30 8/23/2024 02:00 0.50 MIRU, WHDBOP OTHR P Flood lines and grease valves for BOP test 0.0 0.0 8/23/2024 02:00 8/23/2024 05:00 3.00 MIRU, WHDBOP BOPE P Initial BOPE test All tests at 250/2500 PSI for 5 Min each. Tested annular, UVBR's, W/3-1/2" Test joint. Test blinds rams. Choke valves #1 to #16, upper and lower top drive well control valves. Test 3-1/2" HT38 floor valve and IBOP. Tested 2" rig floor Demco kill valves. Tested manual and HCR kill valves and manual and HCR choke valves. Tested hydraulic and manual choke to 1500 PSI and demonstrate bleed off. Performed accumulator draw test. Initial pressure=3100 PSI, after closure=1700 PSI, 200 PSI attained =17 sec, full recovery attained =112 sec. 5 back up nitrogen bottles average =2145 PSI. Function tested. UPR=6 Sec, Annular=25 Sec. Simulated Blinds=6, HCR Kill=1 Sec. HCR Choke=1 Sec. Test gas detectors, P.V.T. and flow show.Test witnessed waived by AOGCC rep Guy Cook 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 8/28/2024 Page 2/5 1D-112 Report Printed: 9/19/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/23/2024 05:00 8/23/2024 08:00 3.00 MIRU, WHDBOP RURD T Penetrator heavily corroded to tree adapter and pulled up out of tubing hanger. Which removed the IA barrier. Fill hole wait 30 minutes, fill hole w/6.8 bbls wait 30 minutes, fill hole w/5 bbls and wait 30 minutes, fill hole w/4.5 bbls to establish a fluid level. 0.0 0.0 8/23/2024 08:00 8/23/2024 10:30 2.50 MIRU, WHDBOP RURD T ND and stand back the BOP stack. Wellhead hand repair penetrator. MU DSA adapter and NU BOP stack. Fill the stack. 0.0 0.0 8/23/2024 10:30 8/23/2024 12:00 1.50 MIRU, WHDBOP BOPE P Finished BOPE test 0.0 0.0 8/23/2024 12:00 8/23/2024 13:00 1.00 MIRU, WHDBOP RURD P Clean and clear rig floor. 0.0 0.0 8/23/2024 13:00 8/23/2024 14:00 1.00 COMPZN, RPCOMP RURD P Bring control lline spooling unit to rig floor. RU spooling unit w/Halliburton. Bring ESP sheeve to floor. RU ESP sheeve. PU landing joint and TQ collar on top. 0.0 0.0 8/23/2024 14:00 8/23/2024 16:00 2.00 COMPZN, RPCOMP OWFF P Flow check well. Flowing but slowing down. Flow check well. No flow. 0.0 0.0 8/23/2024 16:00 8/23/2024 16:30 0.50 COMPZN, RPCOMP MPSP P Pull BPV 0.0 0.0 8/23/2024 16:30 8/23/2024 17:15 0.75 COMPZN, RPCOMP THGR P MU landing joint and MU to tubing hanger. Pull tubing hanger to floor and remove penetrator. Packer release @ 150K PUW 0.0 0.0 8/23/2024 17:15 8/23/2024 20:45 3.50 COMPZN, RPCOMP CIRC P Close annular circulate 400 bbls filtered sea water, 0.0 7,130.0 8/23/2024 20:45 8/23/2024 21:15 0.50 COMPZN, RPCOMP OWFF P Flow check well while taking on seawater // Still showing flow at tiger tank 7,130.0 7,130.0 8/23/2024 21:15 8/23/2024 22:15 1.00 COMPZN, RPCOMP CIRC P Circulate 100 bbls filtered seawater down tubing up IA to tiger tank 7,130.0 7,130.0 8/23/2024 22:15 8/23/2024 22:45 0.50 COMPZN, RPCOMP OWFF P OWFF, still seeing oil swap and slight flow at surface 7,130.0 7,130.0 8/23/2024 22:45 8/23/2024 23:15 0.50 COMPZN, RPCOMP CIRC P Circulate B/U to clean well 5 bbls/ min @ 1050 psi 7,130.0 7,130.0 8/23/2024 23:15 8/24/2024 00:00 0.75 COMPZN, RPCOMP OWFF P OWFF, monitor on pill pit for relaxing formation 22.6 @ 11:12 24.6 @ 11:17 26.2 @ 11:22 27.6 @ 11:27 28.8 @ 11:32 29.8 @ 11:37 30.6 @ 11:42 31.3 @ 11:47 32.0 @ 11:52 32.5 @ 11:57 7,130.0 7,130.0 8/24/2024 00:00 8/24/2024 01:00 1.00 COMPZN, RPCOMP OWFF P Continue with trending well // Well stop flowing 12:40 7,130.0 7,130.0 8/24/2024 01:00 8/24/2024 02:00 1.00 COMPZN, RPCOMP THGR P Remove hanger and esp cable // lay down hanger rig up rope to esp cable 7,130.0 7,115.0 8/24/2024 02:00 8/24/2024 11:30 9.50 COMPZN, RPCOMP PULL P Pull 3.5" ESP completion // Constant hole fill loss Rate 10 bbls/hr Rull F/7115 T/3000' UWT=85K and SOW = 58K 7,115.0 3,000.0 8/24/2024 11:30 8/24/2024 12:00 0.50 COMPZN, RPCOMP SVRG P Service rig. Grease darw works and crown. 3,000.0 3,000.0 Rig: NABORS 7ES RIG RELEASE DATE 8/28/2024 Page 3/5 1D-112 Report Printed: 9/19/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/24/2024 12:00 8/24/2024 16:00 4.00 COMPZN, RPCOMP PULL P Pull 3.5" ESP completion // Constant hole fill loss Rate 10 bbls/hr Pull F/3000' T/surface UWT=50K 3,000.0 0.0 8/24/2024 16:00 8/24/2024 18:00 2.00 COMPZN, RPCOMP RURD P Rig down spooling equipment and clean and clear floor for clean out run 0.0 0.0 8/24/2024 18:00 8/24/2024 19:00 1.00 COMPZN, RPCOMP BHAH P Load BHA in pipe shed // Prep floor for picking up pipe and BHA 0.0 0.0 8/24/2024 19:00 8/24/2024 20:00 1.00 COMPZN, RPCOMP BHAH P Pick up BHA# 1 clean out run BHA // 6.75" junk mill, 2 ea. 5" boot baskets, 6.75" smooth sided string mill, bumper sub, 4.75" fishing jars, 6 ea 4.6875" drill collars 0.0 219.8 8/24/2024 20:00 8/25/2024 00:00 4.00 COMPZN, RPCOMP PULD P Pick up singles of drill pipe T / 4800' 219.8 4,800.0 8/25/2024 00:00 8/25/2024 01:45 1.75 COMPZN, RPCOMP PULD P Continue in hole with cleanout BHA on singles T/ 7180' // Junk mill 6.75" w 6.75" smooth sided string mill and 2 ea. 5" boot baskets 4,800.0 7,000.0 8/25/2024 01:45 8/25/2024 02:30 0.75 COMPZN, RPCOMP REAM P Clean up packer setting depth 6950' to 7020' // Pump 5 bpm @ 840 psi // Rot 62 rpm @ 4200 tq // Complete bottoms up 7,000.0 7,020.0 8/25/2024 02:30 8/25/2024 03:00 0.50 COMPZN, RPCOMP PULD P Continue in hole T/ 7104' // Stack out 8K WOB 7,020.0 7,104.0 8/25/2024 03:00 8/25/2024 03:12 0.20 COMPZN, RPCOMP WASH P Wash/Clean up 7-5/8" casing T/ 7180' // Pump 8 bpm @ 1875 psi 7,104.0 7,180.0 8/25/2024 03:12 8/25/2024 03:45 0.55 COMPZN, RPCOMP CIRC P Circulate SxS // 8 bpm @ 1900 psi 7,180.0 7,180.0 8/25/2024 03:45 8/25/2024 04:00 0.25 COMPZN, RPCOMP OWFF P OWFF // No Flow 7,180.0 7,180.0 8/25/2024 04:00 8/25/2024 07:00 3.00 COMPZN, RPCOMP TRIP P Trip out of hole for test packer F7180' T/225' UWT 110 SOW 70K Loss rate 10 BPH 7,180.0 225.0 8/25/2024 07:00 8/25/2024 08:30 1.50 COMPZN, RPCOMP BHAH P LD CO BHA and clear rig floor. 225.0 0.0 8/25/2024 08:30 8/25/2024 09:00 0.50 COMPZN, RPCOMP BHAH P MU test packer BHA#2 0.0 16.7 8/25/2024 09:00 8/25/2024 11:30 2.50 COMPZN, RPCOMP TRIP P Trip in hole with test packer F/0 T/7180' UWT 89 SOW 66K Loss rate 10 BPH 16.7 6,500.0 8/25/2024 11:30 8/25/2024 12:00 0.50 COMPZN, RPCOMP SVRG P Rig service, grease roughneck and drawworks. 6,500.0 6,500.0 8/25/2024 12:00 8/25/2024 12:30 0.50 COMPZN, RPCOMP TRIP P Trip in hole with test packer 6,500.0 7,015.0 8/25/2024 12:30 8/25/2024 13:30 1.00 COMPZN, RPCOMP PRTS P Set test packer // Test casing 2500 psi 15min 7,015.0 7,015.0 8/25/2024 13:30 8/25/2024 15:00 1.50 COMPZN, RPCOMP SLPC P Cut drilling line 96' 7,015.0 7,015.0 8/25/2024 15:00 8/25/2024 21:00 6.00 COMPZN, RPCOMP PULD P POOH laying down drill line // Lay down packer 7,015.0 0.0 8/25/2024 21:00 8/25/2024 21:30 0.50 COMPZN, RPCOMP CLEN P Clean and clear rig floor 0.0 0.0 8/25/2024 21:30 8/25/2024 23:30 2.00 COMPZN, RPCOMP RURD P Rig up Summit and HES equipment for running ESP completion // Hang sheave in derrick // Bring cannon clamps to rig floor // 0.0 8/26/2024 00:00 8/26/2024 01:30 1.50 COMPZN, RPCOMP RURD P Complete rig up of ESP completion running equipment // confirm running order stage tools in pipe shed 0.0 0.0 8/26/2024 01:30 8/26/2024 02:00 0.50 COMPZN, RPCOMP SFTY P PJSM with all parties for running ESP completion 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 8/28/2024 Page 4/5 1D-112 Report Printed: 9/19/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/26/2024 02:00 8/26/2024 08:00 6.00 COMPZN, RPCOMP PUTB P Pick up and run 3.5" ESP completion per tally // Pick up motor assembly fill with oil. 0.0 410.0 8/26/2024 08:00 8/26/2024 11:30 3.50 COMPZN, RPCOMP PUTB P Per tally MU and RIH to packer. Summit splice pump wire. Haliburton RU packer pass through for gauge. Summit running packer pass through for ESP line. 410.0 410.0 8/26/2024 11:30 8/26/2024 12:00 0.50 COMPZN, RPCOMP SVRG P Service rig. Grease draw works, pipe skate and power tongs. 410.0 410.0 8/26/2024 12:00 8/26/2024 16:00 4.00 COMPZN, RPCOMP PUTB P Continue to MU Summit packer pass through and Halliburton packer pass through. PU ESP Completion. 410.0 410.0 8/26/2024 16:00 8/27/2024 00:00 8.00 COMPZN, RPCOMP PUTB P Pick up and run 3.5" eue pipe for esp completion Stop every 1000' for readings on wire and gauge 410.0 3,100.0 8/27/2024 00:00 8/27/2024 10:00 10.00 COMPZN, RPCOMP PUTB P Continue picking up 3.5" esp completion checking wire and gauge every 1000' to 7136' 3,100.0 7,136.0 8/27/2024 10:00 8/27/2024 13:30 3.50 COMPZN, RPCOMP THGR P MU landing joint to hanger, MU cement hose to landing joint. Summit terminate ESP cable and installing penetrator, Halliburton terminate gauge line and attach to hanger. One motor body clamp, 4 seal body clamps, 1 mle to cable splice clamp, 4 GLM clamps, 4 GLM dual channel half clamps, 4 GLM single channel half clamps and 234 dual channel cross collar clamps. 7,136.0 7,136.0 8/27/2024 13:30 8/27/2024 15:00 1.50 COMPZN, RPCOMP THGR P Seat hanger. RILDS. Test upper and lower void per well head rep to 5000 psi for 10 minutes. 0.0 0.0 8/27/2024 15:00 8/27/2024 17:00 2.00 COMPZN, RPCOMP CIRC P R/U and displace well to CI brine. Pumping @ 4 BBL Min @ 330 PSI 0.0 8/27/2024 17:00 8/27/2024 18:00 1.00 COMPZN, RPCOMP THGR P Remove landing jt, PUll isolation sleeve, install landing jt, drop ball and rod and allow to fall for 30 minutes. 1-5/16 ball, 0.75 rod, 1.375 F/N, 5 rollers, 1.5" stem, 2.0" wheels. 0.0 0.0 8/27/2024 18:00 8/27/2024 19:30 1.50 COMPZN, RPCOMP PACK P Line up on tubing and pressure up 3000 PSI to set packer. Test tubing for 30 min: GOOD TEST. Bleed tubing to 1500 PSI and hold. Line up on IA and test packer to 2500 PSI for 30 min: GOOD TEST. Line up on the tubing, and bleed to 0 PSI, observe SOV shear, and IA pressure bleed to 0 PSI. 0.0 0.0 8/27/2024 19:30 8/27/2024 20:00 0.50 COMPZN, WHDBOP RURD P Blow down lines, and rig down. B/O and L/D landing joint. 0.0 0.0 8/27/2024 20:00 8/27/2024 21:30 1.50 COMPZN, WHDBOP MPSP P Vault Rep set back pressure valve. Line up on IA, and test BPV to 1000 PSI for 10 Min: GOOD TEST. 0.0 0.0 8/27/2024 21:30 8/27/2024 23:30 2.00 COMPZN, WHDBOP NUND P N/D BOP. 0.0 0.0 8/27/2024 23:30 8/28/2024 00:00 0.50 DEMOB, MOVE THGR P Clean and inspect hanger, Vault rep inspect hanger, and fill void with oil. Summit ESP, and HAL completions test lines. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 8/28/2024 Page 5/5 1D-112 Report Printed: 9/19/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/28/2024 00:00 8/28/2024 06:00 6.00 DEMOB, MOVE RURD P NU and TQ flanges to spec. Terminate gauge wire. Split modules. Test ESP motor and line. Test hanger void 5K F/10 min. RU to test tree. PT tree 5000 psi F/5 min Pull BPV. TBG PSI=0, IA PSI=0 Secure cellar F/rig move. Prep floor F/rig move. Warm up moving system. Rig release 06:00 AM 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 8/28/2024 Page 1/5 1D-112 Report Printed: 9/19/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/22/2024 03:30 8/22/2024 04:00 0.50 MIRU, MOVE RURD P Complete rig down check list. 0.0 0.0 8/22/2024 04:00 8/22/2024 08:30 4.50 MIRU, MOVE MOB P Move rig off 1D-42, spot over 1D-112, hang tree in cellar and spot wellhead equipment. Spot kill tank, spot cuttings tank. RU hardline. Rig accept 8:30. 0.0 0.0 8/22/2024 08:30 8/22/2024 12:00 3.50 MIRU, WELCTL RURD P Take on filtered seawater. Process DP in pipe shed. 0.0 0.0 8/22/2024 12:00 8/22/2024 15:00 3.00 MIRU, WELCTL KLWL P PT surface lines. Kill IA pumping 140 bbls down IA and up TBG. Kill TBG by bullheading 100 bbl at 3.5 BPM down TBG 1040 psi. 0.0 0.0 8/22/2024 15:00 8/22/2024 15:30 0.50 MIRU, WELCTL OWFF P Flow check well. Flowing. 0.0 0.0 8/22/2024 15:30 8/22/2024 16:00 0.50 MIRU, WELCTL KLWL P Kill TBG by bullheading 50 bbl at 3.5 BPM down TBG. 0.0 0.0 8/22/2024 16:00 8/22/2024 17:30 1.50 MIRU, WELCTL OWFF P Flow check well. Flowing back, but decreasing slowly. // Charged up formation letting relax, no flow started at 17:00 0.0 0.0 8/22/2024 17:30 8/22/2024 20:00 2.50 MIRU, WELCTL MPSP P Set BPV and test 1000 psi // Trouble getting BPV in hanger, WH personnel retrieve secondary BPV from shop, install test 1000psi @ 2 bpm good test 0.0 0.0 8/22/2024 20:00 8/22/2024 23:00 3.00 MIRU, WHDBOP NUND P Nipple down tubing adapter from well head, dummy penetrator stuck in adapter free from adapter, all bolts seased to nuts backed out of adapter and had to be freed after tubing head off 0.0 0.0 8/22/2024 23:00 8/23/2024 00:00 1.00 MIRU, WHDBOP NUND P Check LDS // Install adapter 0.0 0.0 8/23/2024 00:00 8/23/2024 01:30 1.50 MIRU, WHDBOP NUND P Nipple up BOPs // Install riser // Torque bolts // Perform RKBs 0.0 0.0 8/23/2024 01:30 8/23/2024 02:00 0.50 MIRU, WHDBOP OTHR P Flood lines and grease valves for BOP test 0.0 0.0 8/23/2024 02:00 8/23/2024 05:00 3.00 MIRU, WHDBOP BOPE P Initial BOPE test All tests at 250/2500 PSI for 5 Min each. Tested annular, UVBR's, W/3-1/2" Test joint. Test blinds rams. Choke valves #1 to #16, upper and lower top drive well control valves. Test 3-1/2" HT38 floor valve and IBOP. Tested 2" rig floor Demco kill valves. Tested manual and HCR kill valves and manual and HCR choke valves. Tested hydraulic and manual choke to 1500 PSI and demonstrate bleed off. Performed accumulator draw test. Initial pressure=3100 PSI, after closure=1700 PSI, 200 PSI attained =17 sec, full recovery attained =112 sec. 5 back up nitrogen bottles average =2145 PSI. Function tested. UPR=6 Sec, Annular=25 Sec. Simulated Blinds=6, HCR Kill=1 Sec. HCR Choke=1 Sec. Test gas detectors, P.V.T. and flow show.Test witnessed waived by AOGCC rep Guy Cook 0.0 0.0 Rig: LRS 44 RIG RELEASE DATE 8/29/2024 Page 2/5 1D-112 Report Printed: 9/19/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/23/2024 05:00 8/23/2024 08:00 3.00 MIRU, WHDBOP RURD T Penetrator heavily corroded to tree adapter and pulled up out of tubing hanger. Which removed the IA barrier. Fill hole wait 30 minutes, fill hole w/6.8 bbls wait 30 minutes, fill hole w/5 bbls and wait 30 minutes, fill hole w/4.5 bbls to establish a fluid level. 0.0 0.0 8/23/2024 08:00 8/23/2024 10:30 2.50 MIRU, WHDBOP RURD T ND and stand back the BOP stack. Wellhead hand repair penetrator. MU DSA adapter and NU BOP stack. Fill the stack. 0.0 0.0 8/23/2024 10:30 8/23/2024 12:00 1.50 MIRU, WHDBOP BOPE P Finished BOPE test 0.0 0.0 8/23/2024 12:00 8/23/2024 13:00 1.00 MIRU, WHDBOP RURD P Clean and clear rig floor. 0.0 0.0 8/23/2024 13:00 8/23/2024 14:00 1.00 COMPZN, RPCOMP RURD P Bring control lline spooling unit to rig floor. RU spooling unit w/Halliburton. Bring ESP sheeve to floor. RU ESP sheeve. PU landing joint and TQ collar on top. 0.0 0.0 8/23/2024 14:00 8/23/2024 16:00 2.00 COMPZN, RPCOMP OWFF P Flow check well. Flowing but slowing down. Flow check well. No flow. 0.0 0.0 8/23/2024 16:00 8/23/2024 16:30 0.50 COMPZN, RPCOMP MPSP P Pull BPV 0.0 0.0 8/23/2024 16:30 8/23/2024 17:15 0.75 COMPZN, RPCOMP THGR P MU landing joint and MU to tubing hanger. Pull tubing hanger to floor and remove penetrator. Packer release @ 150K PUW 0.0 0.0 8/23/2024 17:15 8/23/2024 20:45 3.50 COMPZN, RPCOMP CIRC P Close annular circulate 400 bbls filtered sea water, 0.0 7,130.0 8/23/2024 20:45 8/23/2024 21:15 0.50 COMPZN, RPCOMP OWFF P Flow check well while taking on seawater // Still showing flow at tiger tank 7,130.0 7,130.0 8/23/2024 21:15 8/23/2024 22:15 1.00 COMPZN, RPCOMP CIRC P Circulate 100 bbls filtered seawater down tubing up IA to tiger tank 7,130.0 7,130.0 8/23/2024 22:15 8/23/2024 22:45 0.50 COMPZN, RPCOMP OWFF P OWFF, still seeing oil swap and slight flow at surface 7,130.0 7,130.0 8/23/2024 22:45 8/23/2024 23:15 0.50 COMPZN, RPCOMP CIRC P Circulate B/U to clean well 5 bbls/ min @ 1050 psi 7,130.0 7,130.0 8/23/2024 23:15 8/24/2024 00:00 0.75 COMPZN, RPCOMP OWFF P OWFF, monitor on pill pit for relaxing formation 22.6 @ 11:12 24.6 @ 11:17 26.2 @ 11:22 27.6 @ 11:27 28.8 @ 11:32 29.8 @ 11:37 30.6 @ 11:42 31.3 @ 11:47 32.0 @ 11:52 32.5 @ 11:57 7,130.0 7,130.0 8/24/2024 00:00 8/24/2024 01:00 1.00 COMPZN, RPCOMP OWFF P Continue with trending well // Well stop flowing 12:40 7,130.0 7,130.0 8/24/2024 01:00 8/24/2024 02:00 1.00 COMPZN, RPCOMP THGR P Remove hanger and esp cable // lay down hanger rig up rope to esp cable 7,130.0 7,115.0 8/24/2024 02:00 8/24/2024 11:30 9.50 COMPZN, RPCOMP PULL P Pull 3.5" ESP completion // Constant hole fill loss Rate 10 bbls/hr Rull F/7115 T/3000' UWT=85K and SOW = 58K 7,115.0 3,000.0 8/24/2024 11:30 8/24/2024 12:00 0.50 COMPZN, RPCOMP SVRG P Service rig. Grease darw works and crown. 3,000.0 3,000.0 Rig: LRS 44 RIG RELEASE DATE 8/29/2024 Page 3/5 1D-112 Report Printed: 9/19/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/24/2024 12:00 8/24/2024 16:00 4.00 COMPZN, RPCOMP PULL P Pull 3.5" ESP completion // Constant hole fill loss Rate 10 bbls/hr Pull F/3000' T/surface UWT=50K 3,000.0 0.0 8/24/2024 16:00 8/24/2024 18:00 2.00 COMPZN, RPCOMP RURD P Rig down spooling equipment and clean and clear floor for clean out run 0.0 0.0 8/24/2024 18:00 8/24/2024 19:00 1.00 COMPZN, RPCOMP BHAH P Load BHA in pipe shed // Prep floor for picking up pipe and BHA 0.0 0.0 8/24/2024 19:00 8/24/2024 20:00 1.00 COMPZN, RPCOMP BHAH P Pick up BHA# 1 clean out run BHA // 6.75" junk mill, 2 ea. 5" boot baskets, 6.75" smooth sided string mill, bumper sub, 4.75" fishing jars, 6 ea 4.6875" drill collars 0.0 219.8 8/24/2024 20:00 8/25/2024 00:00 4.00 COMPZN, RPCOMP PULD P Pick up singles of drill pipe T / 4800' 219.8 4,800.0 8/25/2024 00:00 8/25/2024 01:45 1.75 COMPZN, RPCOMP PULD P Continue in hole with cleanout BHA on singles T/ 7180' // Junk mill 6.75" w 6.75" smooth sided string mill and 2 ea. 5" boot baskets 4,800.0 7,000.0 8/25/2024 01:45 8/25/2024 02:30 0.75 COMPZN, RPCOMP REAM P Clean up packer setting depth 6950' to 7020' // Pump 5 bpm @ 840 psi // Rot 62 rpm @ 4200 tq // Complete bottoms up 7,000.0 7,020.0 8/25/2024 02:30 8/25/2024 03:00 0.50 COMPZN, RPCOMP PULD P Continue in hole T/ 7104' // Stack out 8K WOB 7,020.0 7,104.0 8/25/2024 03:00 8/25/2024 03:12 0.20 COMPZN, RPCOMP WASH P Wash/Clean up 7-5/8" casing T/ 7180' // Pump 8 bpm @ 1875 psi 7,104.0 7,180.0 8/25/2024 03:12 8/25/2024 03:45 0.55 COMPZN, RPCOMP CIRC P Circulate SxS // 8 bpm @ 1900 psi 7,180.0 7,180.0 8/25/2024 03:45 8/25/2024 04:00 0.25 COMPZN, RPCOMP OWFF P OWFF // No Flow 7,180.0 7,180.0 8/25/2024 04:00 8/25/2024 07:00 3.00 COMPZN, RPCOMP TRIP P Trip out of hole for test packer F7180' T/225' UWT 110 SOW 70K Loss rate 10 BPH 7,180.0 225.0 8/25/2024 07:00 8/25/2024 08:30 1.50 COMPZN, RPCOMP BHAH P LD CO BHA and clear rig floor. 225.0 0.0 8/25/2024 08:30 8/25/2024 09:00 0.50 COMPZN, RPCOMP BHAH P MU test packer BHA#2 0.0 16.7 8/25/2024 09:00 8/25/2024 11:30 2.50 COMPZN, RPCOMP TRIP P Trip in hole with test packer F/0 T/7180' UWT 89 SOW 66K Loss rate 10 BPH 16.7 6,500.0 8/25/2024 11:30 8/25/2024 12:00 0.50 COMPZN, RPCOMP SVRG P Rig service, grease roughneck and drawworks. 6,500.0 6,500.0 8/25/2024 12:00 8/25/2024 12:30 0.50 COMPZN, RPCOMP TRIP P Trip in hole with test packer 6,500.0 7,015.0 8/25/2024 12:30 8/25/2024 13:30 1.00 COMPZN, RPCOMP PRTS P Set test packer // Test casing 2500 psi 15min 7,015.0 7,015.0 8/25/2024 13:30 8/25/2024 15:00 1.50 COMPZN, RPCOMP SLPC P Cut drilling line 96' 7,015.0 7,015.0 8/25/2024 15:00 8/25/2024 21:00 6.00 COMPZN, RPCOMP PULD P POOH laying down drill line // Lay down packer 7,015.0 0.0 8/25/2024 21:00 8/25/2024 21:30 0.50 COMPZN, RPCOMP CLEN P Clean and clear rig floor 0.0 0.0 8/25/2024 21:30 8/25/2024 23:30 2.00 COMPZN, RPCOMP RURD P Rig up Summit and HES equipment for running ESP completion // Hang sheave in derrick // Bring cannon clamps to rig floor // 0.0 8/26/2024 00:00 8/26/2024 01:30 1.50 COMPZN, RPCOMP RURD P Complete rig up of ESP completion running equipment // confirm running order stage tools in pipe shed 0.0 0.0 8/26/2024 01:30 8/26/2024 02:00 0.50 COMPZN, RPCOMP SFTY P PJSM with all parties for running ESP completion 0.0 0.0 Rig: LRS 44 RIG RELEASE DATE 8/29/2024 Page 4/5 1D-112 Report Printed: 9/19/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/26/2024 02:00 8/26/2024 08:00 6.00 COMPZN, RPCOMP PUTB P Pick up and run 3.5" ESP completion per tally // Pick up motor assembly fill with oil. 0.0 410.0 8/26/2024 08:00 8/26/2024 11:30 3.50 COMPZN, RPCOMP PUTB P Per tally MU and RIH to packer. Summit splice pump wire. Haliburton RU packer pass through for gauge. Summit running packer pass through for ESP line. 410.0 410.0 8/26/2024 11:30 8/26/2024 12:00 0.50 COMPZN, RPCOMP SVRG P Service rig. Grease draw works, pipe skate and power tongs. 410.0 410.0 8/26/2024 12:00 8/26/2024 16:00 4.00 COMPZN, RPCOMP PUTB P Continue to MU Summit packer pass through and Halliburton packer pass through. PU ESP Completion. 410.0 410.0 8/26/2024 16:00 8/27/2024 00:00 8.00 COMPZN, RPCOMP PUTB P Pick up and run 3.5" eue pipe for esp completion Stop every 1000' for readings on wire and gauge 410.0 3,100.0 8/27/2024 00:00 8/27/2024 10:00 10.00 COMPZN, RPCOMP PUTB P Continue picking up 3.5" esp completion checking wire and gauge every 1000' to 7136' 3,100.0 7,136.0 8/27/2024 10:00 8/27/2024 13:30 3.50 COMPZN, RPCOMP THGR P MU landing joint to hanger, MU cement hose to landing joint. Summit terminate ESP cable and installing penetrator, Halliburton terminate gauge line and attach to hanger. One motor body clamp, 4 seal body clamps, 1 mle to cable splice clamp, 4 GLM clamps, 4 GLM dual channel half clamps, 4 GLM single channel half clamps and 234 dual channel cross collar clamps. 7,136.0 7,136.0 8/27/2024 13:30 8/27/2024 15:00 1.50 COMPZN, RPCOMP THGR P Seat hanger. RILDS. Test upper and lower void per well head rep to 5000 psi for 10 minutes. 0.0 0.0 8/27/2024 15:00 8/27/2024 17:00 2.00 COMPZN, RPCOMP CIRC P R/U and displace well to CI brine. Pumping @ 4 BBL Min @ 330 PSI 0.0 8/27/2024 17:00 8/27/2024 18:00 1.00 COMPZN, RPCOMP THGR P Remove landing jt, PUll isolation sleeve, install landing jt, drop ball and rod and allow to fall for 30 minutes. 1-5/16 ball, 0.75 rod, 1.375 F/N, 5 rollers, 1.5" stem, 2.0" wheels. 0.0 0.0 8/27/2024 18:00 8/27/2024 19:30 1.50 COMPZN, RPCOMP PACK P Line up on tubing and pressure up 3000 PSI to set packer. Test tubing for 30 min: GOOD TEST. Bleed tubing to 1500 PSI and hold. Line up on IA and test packer to 2500 PSI for 30 min: GOOD TEST. Line up on the tubing, and bleed to 0 PSI, observe SOV shear, and IA pressure bleed to 0 PSI. 0.0 0.0 8/27/2024 19:30 8/27/2024 20:00 0.50 COMPZN, WHDBOP RURD P Blow down lines, and rig down. B/O and L/D landing joint. 0.0 0.0 8/27/2024 20:00 8/27/2024 21:30 1.50 COMPZN, WHDBOP MPSP P Vault Rep set back pressure valve. Line up on IA, and test BPV to 1000 PSI for 10 Min: GOOD TEST. 0.0 0.0 8/27/2024 21:30 8/27/2024 23:30 2.00 COMPZN, WHDBOP NUND P N/D BOP. 0.0 0.0 8/27/2024 23:30 8/28/2024 00:00 0.50 DEMOB, MOVE THGR P Clean and inspect hanger, Vault rep inspect hanger, and fill void with oil. Summit ESP, and HAL completions test lines. 0.0 0.0 Rig: LRS 44 RIG RELEASE DATE 8/29/2024 Page 5/5 1D-112 Report Printed: 9/19/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/28/2024 00:00 8/28/2024 06:00 6.00 DEMOB, MOVE RURD P NU and TQ flanges to spec. Terminate gauge wire. Split modules. Test ESP motor and line. Test hanger void 5K F/10 min. RU to test tree. PT tree 5000 psi F/5 min Pull BPV. TBG PSI=0, IA PSI=0 Secure cellar F/rig move. Prep floor F/rig move. Warm up moving system. Rig release 06:00 AM 0.0 0.0 Rig: LRS 44 RIG RELEASE DATE 8/29/2024 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: ELM 7,180.0 1D-112 4/8/2012 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Post RWO 1D-112 9/8/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By Note: Subsidence CMIT completed 12/29/20 12/29/2020 fergusp NOTE: POSSIBLE TUBING LEAK AT 7053' APPROX 10/25/2015 lehallf NOTE: ESP WORKOVER 10/17/1999 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 41.0 121.0 121.0 62.58 H-40 WELDED PRODUCTION 7 5/8 6.87 40.5 8,230.8 4,094.2 29.70 L-80 ABM-BTC GRAVEL PACK LINER 4.59 3.55 7,203.4 7,830.0 3,888.7 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth 7,183.6 String Max No 3 1/2 Set Depth 3,583.0 Tubing Description Tubing Production 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) 40.5 40.5 0.00 Hanger 10.813 Vault PC TUBING HANGER 4.5" x 3.5" EUE 8rd Bottom Vault CWCT- F6H 4.500 4,738.4 2,496.4 65.33 Mandrel GAS LIFT 5.477 KBMG 3.5" x 1", DV SN# 20953-01 Camco 2.920 6,724.8 3,374.6 63.71 Mandrel GAS LIFT 5.477 KBMG 3.5" x 1", SOV 2000 psig IA to TBG Shear SN#24976-02 Camco KBMG SOV 2000 2.920 6,779.1 3,398.9 63.28 Packer 6.670 3.5" x 7-5/8", ESP FEED-THRU PACKER w/1.900NUE (D&L) TriPoint DLESP 2.940 6,799.7 3,408.1 63.12 Nipple - X 4.495 2.813" X-Nipple SN# 0004890017- 01 HES X-Nipple 2.813 6,882.4 3,445.9 62.52 Mandrel GAS LIFT 5.378 KBMG 3.5" x 1", DV Tubing to IA SOV 2400 psi SN# 24976-01 Camco KBMG Tubing SOV 2400 2.920 6,971.3 3,486.7 62.83 Sleeve - Sliding 5.778 NEXA-2 Sliding Sleeve, SLB, 2.813" X Profile, bypass ports for cable SN: 4793119759-01-002 SLB NEXA-2 2.813 7,025.8 3,511.6 63.01 Sensor - Discharge Gauge 4.851 Gauge Mandrel SN# MXM19710-04 Halliburt on Opsis Gauge 2.932 7,075.9 3,534.2 63.15 Pump - Discharge head 5.650 Discharge Adapter 2.970 7,149.4 3,567.5 63.05 Recieving Base 3.500 Receiving Base Summit 2.970 7,154.0 3,569.5 63.04 Seal Assembly 5.130 Tandem Seal Section Summit 7,172.2 3,577.8 63.01 Motor - Gear Reducing Unit (GRU) 5.380 Gear Reduction Unit Summit 7,174.4 3,578.8 63.01 Motor - Adapter 4.560 ESP Motor and Adapter Summit 7,181.1 3,581.8 63.00 Sensor - Suction Gauge 4.560 2-3/8", 8rd EUE, MOTOR PRESSURE GAUGE Summit 7,182.9 3,582.7 63.00 Centralizer 6.000 2-3/8", 8rd EUE, MOTOR CENTRALIZER Summit 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) 7,109.2 3,549.2 63.10 SLIP STOP 3.5" Slipstop (OAL = 1.5') 90007 2971 9/8/2024 1.500 7,110.7 3,549.9 63.10 PACKOFF 3.5" D&D Packoff Stinger Assembly (OAL = 8.05') 90007 2972 9/8/2024 1.625 7,118.8 3,553.6 63.09 ESP 3.5" 40-1500 TTC ESPCP (OAL = 35.25') 90007 2976 9/8/2024 0.000 7,203.0 3,591.8 62.97 GRAVEL PACK Total of 9,700 lbs of gravel behind screens 10/13/1998 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) 4,738.4 2,496.4 65.33 1 GAS LIFT DMY BK 1 0.0 8/27/2024 KBMG 0.000 6,724.8 3,374.6 63.71 2 GAS LIFT DMY BK 1 0.0 9/7/2024 KMMG 6,882.4 3,445.9 62.52 3 ESP SOV BEK 1 0.0 8/27/2024 #2400 psi KBMG 0.000 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) 7,203.4 3,592.0 62.97 PACKER 6.580 BAKER SC-1 GRAVEL PACKER 4.000 7,208.2 3,594.2 62.96 MILLOUT EXT 6.060 UPPER MILLOUT EXTENSION 4.000 7,212.0 3,595.9 62.96 SLEEVE 6.060 BAKER 80-40 SLIDING SLEEVE 4.000 7,216.1 3,597.8 62.95 MILLOUT EXT 6.060 LOWER MILLOUT EXTENSION 4.000 1D-112, 9/19/2024 10:29:59 AM Vertical schematic (actual) PRODUCTION; 40.5-8,230.8 GRAVEL PACK LINER; 7,203.4- 7,830.0 FRAC; 7,794.0 REFRAC; 7,794.0 IPERF; 7,774.0-7,814.0 IPERF; 7,668.0-7,698.0 REFRAC; 7,668.0 IPERF; 7,532.0-7,560.0 FRAC; 7,532.0 GRAVEL PACK; 7,203.0 FRAC; 7,454.0 IPERF; 7,454.0-7,484.0 IPERF; 7,324.0-7,364.0 FRAC; 7,324.0 Centralizer; 7,182.9 Sensor - Suction Gauge; 7,181.0 Motor - Adapter; 7,174.4 Motor - Gear Reducing Unit (GRU); 7,172.2 Seal Assembly; 7,154.0 Recieving Base; 7,149.4 ESP; 7,118.7 PACKOFF; 7,110.7 SLIP STOP; 7,109.1 Pump - Discharge head; 7,075.9 Sleeve - Sliding; 6,971.3 Mandrel GAS LIFT; 6,882.3 Nipple - X; 6,799.7 Packer; 6,779.1 Mandrel GAS LIFT; 6,724.8 Mandrel GAS LIFT; 4,738.4 CONDUCTOR; 41.0-121.0 Hanger; 40.6 KUP PROD KB-Grd (ft) RR Date 12/13/199 8 Other Elev 1D-112 ... TD Act Btm (ftKB) 8,250.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292291900 Wellbore Status PROD Max Angle & MD Incl (°) 69.56 MD (ftKB) 1,654.86 WELLNAME WELLBORE1D-112 Annotation Last WO: End Date 8/28/2024 H2S (ppm) 0 Date 7/15/2019 Comment SSSV: NONE 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) 7,231.6 3,604.8 62.93 XO Reducing 5.000 CROSSOVER 5"x4.5" 4.500 7,235.5 3,606.6 62.92 XO Reducing 4.500 CROSSOVER 4.5"x4" 4.000 7,829.4 3,888.4 60.94 PLUG 4.590 BULL PLUG 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,324.0 7,364.0 3,647.2 3,665.8 WS D, 1D-112 11/16/1998 4.0 IPERF 2.125" EJ, 0 deg phase 7,454.0 7,484.0 3,708.6 3,722.9 WS B, 1D-112 11/10/1998 4.0 IPERF 2.125" EJ, 0 deg phase 7,532.0 7,560.0 3,745.9 3,759.2 WS A4, 1D-112 11/2/1998 4.0 IPERF 2.125" EJ, 0 deg phase 7,668.0 7,698.0 3,810.7 3,825.0 WS A3, 1D-112 10/15/1998 4.0 IPERF 2.125" EJ, 0 deg phase 7,774.0 7,814.0 3,861.6 3,880.9 WS A2, 1D-112 10/8/1998 4.0 IPERF 2.125" EJ, 0 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) 7,794.0 7,814.0 1 FRAC 10/11/1998 0.0 0.00 0.00 2 FRAC 10/18/1998 0.0 0.00 0.00 7,532.0 7,560.0 3 FRAC 11/3/1998 0.0 0.00 0.00 7,454.0 7,484.0 4 FRAC 11/12/1998 0.0 0.00 0.00 7,324.0 7,364.0 5 FRAC 11/17/1998 0.0 0.00 0.00 7,794.0 7,814.0 1 REFRAC 10/13/1998 0.0 0.00 0.00 7,668.0 7,698.0 2 REFRAC 10/26/1998 0.0 0.00 0.00 1D-112, 9/19/2024 10:29:59 AM Vertical schematic (actual) PRODUCTION; 40.5-8,230.8 GRAVEL PACK LINER; 7,203.4- 7,830.0 FRAC; 7,794.0 REFRAC; 7,794.0 IPERF; 7,774.0-7,814.0 IPERF; 7,668.0-7,698.0 REFRAC; 7,668.0 IPERF; 7,532.0-7,560.0 FRAC; 7,532.0 GRAVEL PACK; 7,203.0 FRAC; 7,454.0 IPERF; 7,454.0-7,484.0 IPERF; 7,324.0-7,364.0 FRAC; 7,324.0 Centralizer; 7,182.9 Sensor - Suction Gauge; 7,181.0 Motor - Adapter; 7,174.4 Motor - Gear Reducing Unit (GRU); 7,172.2 Seal Assembly; 7,154.0 Recieving Base; 7,149.4 ESP; 7,118.7 PACKOFF; 7,110.7 SLIP STOP; 7,109.1 Pump - Discharge head; 7,075.9 Sleeve - Sliding; 6,971.3 Mandrel GAS LIFT; 6,882.3 Nipple - X; 6,799.7 Packer; 6,779.1 Mandrel GAS LIFT; 6,724.8 Mandrel GAS LIFT; 4,738.4 CONDUCTOR; 41.0-121.0 Hanger; 40.6 KUP PROD 1D-112 ... WELLNAME WELLBORE1D-112 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: Pull/Replace ESP 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? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8250'None Casing Collapse Structural Conductor Surface Intermediate Production Gravel Pack Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other 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 (907) 263-4742 Senior RWO/CTD Engineer KRU 1D-112 4104' 7180' 3581' 786 None N/A Subsequent Form Required: Suspension Expiration Date: 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: elliott.tuttle@conocophillips.com AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 3461' MD and 1996' TVD 7203' MD and 3592' TVD N/A Elliott Tuttle STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025649 198-183 P.O. Box 100360, Anchorage, AK 99510 50-029-22919-00-00 Kuparuk River Field West Sak Oil Pool ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY West Sak Oil Pool TVD Burst 7133' MD MD 121'121' 4094'8231' 16"80' 7324-7364', 7454-7484', 7532- 7560', 7668-7698', 7774-7814' 8190' 4.59" 3647-3666', 3709-3723', 3746- 3759', 3811-3825', 3862- 3881' 7-5/8" Perforation Depth TVD (ft): 7/25/2024 7830'627' 3-1/2" 3889' Packer: ESP Feed-Thru Packer Packer: Baker SC-1 Gravel Packer SSSV: None Perforation Depth MD (ft): L-80 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Elliott Tuttle DN: OU=CTD/ RWO Senior Engineer, O=Conoco Phillips, CN=Elliott Tuttle, E=elliott.tuttle@ conocophillips.com Reason: I am approving this document Location: Date: 2024.07.02 13:04:54-08'00' Foxit PDF Editor Version: 13.0.0 Elliott Tuttle 324-383 By Grace Christianson at 1:43 pm, Jul 02, 2024 SFD 7/11/2024 DSR-7/8/24 BOP test to 2500 psig Annular preventer test to 2500 psig VTL 7/18/2024 , ADL0025650 SFD X X 10-404 ($8 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.07.19 09:51:26 -08'00'07/19/24 RBDMS JSB 072324 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 2, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Elliott Tuttle Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Producer 1D-112 (PTD# 198-183). Well 1D-112 is currently shut-in. The well uses a thru-tubing conveyed (TTC) electric submersible progressing cavity pump (ESPCP) for artificial lift. During the last attempted pump changeout, the pump was unable to seat properly. Some slickline diagnostics were run to determine the condition of the receiving base for the pump, which is part of the permanent completion, and it was determined that the guide keys within the receving base have been damaged. The completion is ~12 years old which includes 7 pump changeouts, and has had a tubing leak above the pump intake which has made the pump swaps problematic. A rig workover is recommended since any further non-rig attempts to seat the pump are considered low chance of success. The RWO scope is like-kind replacement of the TTC-ESPCP completion which includes a feed-through packer to provide a barrier to formation as this is a single casing well. If you have any questions or require any further information, please contact me at 907-252-3347 The TTC-ESPCP completion will be pulled and recompleted in like-kind fashion although the production packer will be set deeper so that gas lift is a viable alternative form of artificial lift. Digitally signed by Elliott Tuttle DN: OU=CTD/ RWO Senior Engineer, O=Conoco Phillips, CN =Elliott Tuttle, E=elliott.tuttle@ conocophillips.com Reason: I am the author of this document Location: Date: 2024.07.02 13:05:28 -08'00' Foxit PDF Editor Version: 13.0.0 Elliott Tuttle 1D-112 RWO Procedure West Sak Producer PTD #198-183 Page 1 of 2 Remaining Pre-Rig Work 1. T-PPPOT and T-POT tests. Function LD’s 2. Set plug below 3500’ RKB, CMIT-IA to 2500 psig, pull plug. 3. Set Catcher on top of intake at 7101’ RKB. Pull GLV from Station #1, GLM @ 3336.5’ RKB and install large port OV. 4. Pull OV from station #2 @ 3583’ RKB, let packer gas migrate to surface, 24hrs. 5. Bleed gas, install DV in station #2, pull SOV @ 6991’ RKB 6. Prepare for rig arrival 48-96 hrs before rig arrival. Rig Work MIRU 1. MIRU Nordic 3 on 1D-112. (No BPV set for MIRU due to internal risk assessment for Nordic 3.) 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF down IA as needed through OV. 3. Set HP BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. Retrieve Tubing, Packers, and TTC-ESPCP Completion 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing and release pull-to-release packer. Set Annular and circulate out remaining packer gas. 6. Retrieve completion down through TTC-ESPCP at ~4546’ RKB. a. Drift of casing was noted to be an issue during the RWO in 2012. If drift is a problem on this well, plan is to run swages, staging up in OD. Perform Cleanout and Test Packer run 7. MU Cleanout BHA and TIH down to top of gravel pack liner. Rotate and reciprocate scraper at 6800’ RKB or new packer set depth. 8. MU Test Packer BHA, TIH to 6850’ RKB test backside or packer to surface and confirm casing down past new packer set depth. Install new TTC-ESPCP 3-½” Completion with Feed-through Packer 9. MU 3 ½” completion with TTC-ESPCP, mandrels, packer, and nipples. RIH to depth. 10. Once on depth, space out, land tubing, terminate ESP cable, RILDS. Test void to 5000psi for 5 minutes. 11. Circ in CI down IA to below TTC-ESPCP Assy. 12. Drop ball and Rod, pressure up and set Packer. 13. Pressure test tubing to 1500 psi, 5 minutes bleed to 1000psi. 14. Pressure test inner annulus to 2500 psi for 30 minutes and chart. 15. Dump tubing pressure and shear SOV. ND BOP, NU Tree 16. Install BPV. PT BPV. 17. ND BOPE. NU tree. Test tree. 18. Pull BPV, freeze protect well. 19. RDMO. Post-Rig Work 20. Pull Ball/Rod and any plugs or RHC plugs as needed to set pump. 21. Set Catcher above pump intake. Pull SOV, install DV. Install GLV in station below packer. 22. Set pump. 23. Turn over to operations. 1D-112 RWO Procedure West Sak Producer PTD #198-183 Page 2 of 2 General Well info: Wellhead type/pressure rating: Vetco Gray Horizontal, 5M psi top flange Production Engineer: Will Parker Reservoir Development Engineer: Carolyn Kirchner Estimated Start Date: 7/25/24 Workover Engineer: Elliott Tuttle (907-252-3347, elliott.tuttle@conocophillips.com) Current Operations: This well is currently shut in. Well Type: Producer Scope of Work: Pull the existing 3-1/2” completion with feed through packer and TTC-ESPCP. Replace in-kind with deeper packer set depth. BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: CMIT TxIA to 2500psi Passed, 6/1/23 MIT-OA N/A IC POT &PPPOT PASSED – N/A TBG POT &PPPOT PASSED – 6/4/23 MPSP: 786 psi using 0.1 psi/ft gradient Static BHP: Gauge Reading, 1142psi @ 3558’ RKB 1142psi @ 3558’ RKB 1D-112 Proposed RWO Completion Description Set Depth MD Set Depth TVD OD ID Weight Length Grade Top Conn Run Date Conductor 121 121 16 15.062 62.58 H-40 WELDED 9/22/1998 TUBING WO 7132.92 3560.007 3.5 2.992 9.3 L-80 EUE8rdMO 4/13/2012 Liner 7830 3888.7 4.59 3.548 10/17/1999 Production 8230.8 4094.2 7.625 6.875 29.7 L-80 ABM-BTC 9/22/1998 New Tubing 7140 3560 3.5 2.992 9.3 L-80 EUE8rdMOD PROPOSED COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" x 1" Camco KBMG gas lift mandrel(s) @ TBD X2 3.5" x 7 5/8" D&L Feed Through ESP Packer @ ~6800' RKB 3-½" X landing nipple at xxxx' RKB (2.813" min ID) 3 1/2" NEXA-2 (Up to Open) 5.5" OD with cable bypass - 2.813" X Profile @ xxxx' RKB 3 1/2" HES Gauge Mandrel w/ Dual Opsis Gauge @ xxxx' RKB - How far above TTC-ESPCP Intake? TTC-ESPCP Assembly -Intake - Receiving Base - Tandem Seal Section -Gear Reduction Unit - Summit ESP Motor -Sensor REMAINING COMPLETION LEFT IN HOLE Baker SC-1 Packer @ 7,203' RKB Upper Millout Extension @ 7208' RKB Top of Screens @ 7310.75' RKB Bottom of screens @ 7830' RKB Production Casing Conductor Gravel Pack Screens 7311' - 7830' RKB Gravel Pack Liner #4 Flat ESP Cable 1/4" TEC Wire See Perforations and Slots listed in Wellbore schematic, below. SFD Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: ELM 7,180.0 1D-112 4/8/2012 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Swapped SOV, pulled slipstop, packoff and pump 1D-112 3/26/2024 rogerba Notes: General & Safety Annotation End Date Last Mod By Note: Subsidence CMIT completed 12/29/20 12/29/2020 fergusp NOTE: POSSIBLE TUBING LEAK AT 7053' APPROX 10/25/2015 lehallf NOTE: ESP WORKOVER 10/17/1999 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 41.0 121.0 121.0 62.58 H-40 WELDED PRODUCTION 7 5/8 6.87 40.5 8,230.8 4,094.2 29.70 L-80 ABM-BTC GRAVEL PACK LINER 4.59 3.55 7,203.4 7,830.0 3,888.7 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 36.7 Set Depth … 7,132.9 Set Depth … 3,560.0 String Max No… 3 1/2 Tubing Description TUBING WO Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 36.7 36.7 0.00 HANGER 10.750 VETCO GREY TUBING HANGER Vetco Gray GEN1- ESP- CWCT 3.500 3,336.5 1,945.4 65.69 ESP MANDREL 5.390 GLM, 3 ½" x 1" KBMG S# 007AB03 CAMCO KBMG 2.920 3,460.7 1,995.9 66.33 PACKER 6.670 ESP FEED-THRU PACKER, WEATHERFORD HYDROW II DUAL-STRING PACKER (IA MUST BE BLED DOWN VERY SLOWLY) Weather ford Hydrow- II 3.250 3,583.3 2,044.6 66.82 ESP MANDREL 5.390 GLM, 3 ½" x 1" KBMG S# 15080-08 CAMCO KBMG 2.920 6,991.2 3,495.8 62.89 ESP MANDREL 5.390 GLM, 3 1/2" x 1" KBMG . S# 15080- 03 CAMCO KBMG 2.920 7,043.4 3,519.5 63.07 DISCHARGE 5.310 WELLLIFT DISCHARGE GAUGE UNIT (P/N: PWLE0018) WellLift DGU 2.992 7,100.7 3,545.4 63.11 INTAKE 4.500 TTC RECEIVING XO COUPLING w/ PERFORATED INTAKE (P/N:CSE8442XA) Centrilift TTC 2.992 7,105.2 3,547.5 63.11 SEAL 5.130 TANDEM SEAL SECTION (S/N's: 12013242 / 12013267) Centrilift 7,119.0 3,553.7 63.09 GEAR BOX 5.380 GEAR REDUCTION UNIT (S/N: 120711903) Centrilift GRU 11.42:1 7,120.8 3,554.5 63.09 MOTOR 5.620 ESP MOTOR, 562MSP1 60/1240/29 (S/N: 12057561) Centrilift 562MSP 1 60/1240/ 29 7,129.1 3,558.3 63.07 GAUGE 4.500 WELLLIFT MOTOR GAUGE UNIT (S/N: 192-00787) WellLift MGU 7,131.0 3,559.1 63.07 Centralizer 5.850 MOTOR CENTRALIZER (P/N: C63569) Centrilift 4.000 Top (ftKB)Set Depth … 7,100.0 Set Depth … 3,545.1 String Max No…Tubing Description ESP PUMP Wt (lb/ft) Grade Top Connection ID (in) 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) 7,050.0 3,522.5 63.10 LEAK ESTABLISH LEAK RATE OF .7 BBLS @ 1000 PSI. 10/29/2015 7,203.0 3,591.8 62.97 GRAVEL PACK Total of 9,700 lbs of gravel behind screens 10/13/1998 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) 3,336.5 1,945.4 65.69 1 ESP GLV BK 1 1,300.0 6/18/2023 0.313 3,583.3 2,044.6 66.82 2 ESP OV BK 1 0.0 5/20/2016 To preve nt gas lockin g pump 0.313 6,991.2 3,495.8 62.89 3 ESP SOV BK 1 0.0 3/22/2024 2000 psi tubing shear 0.000 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) 7,203.4 3,592.0 62.97 PACKER 6.580 BAKER SC-1 GRAVEL PACKER 4.000 7,208.2 3,594.2 62.96 MILLOUT EXT 6.060 UPPER MILLOUT EXTENSION 4.000 7,212.0 3,595.9 62.96 SLEEVE 6.060 BAKER 80-40 SLIDING SLEEVE 4.000 7,216.1 3,597.8 62.95 MILLOUT EXT 6.060 LOWER MILLOUT EXTENSION 4.000 7,231.6 3,604.8 62.93 XO Reducing 5.000 CROSSOVER 5"x4.5" 4.500 1D-112, 3/27/2024 8:22:00 AM Vertical schematic (actual) PRODUCTION; 40.5-8,230.8 GRAVEL PACK LINER; 7,203.4- 7,830.0 FRAC; 7,794.0 REFRAC; 7,794.0 IPERF; 7,774.0-7,814.0 IPERF; 7,668.0-7,698.0 REFRAC; 7,668.0 IPERF; 7,532.0-7,560.0 FRAC; 7,532.0 GRAVEL PACK; 7,203.0 FRAC; 7,454.0 IPERF; 7,454.0-7,484.0 IPERF; 7,324.0-7,364.0 FRAC; 7,324.0 GAUGE; 7,129.1 MOTOR; 7,120.8 INTAKE; 7,100.7 LEAK; 7,050.0 DISCHARGE; 7,043.4 ESP MANDREL; 6,991.2 ESP MANDREL; 3,583.3 PACKER; 3,460.7 ESP MANDREL; 3,336.5 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) RR Date 12/13/199 8 Other Elev… 1D-112 ... TD Act Btm (ftKB) 8,250.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292291900 Wellbore Status PROD Max Angle & MD Incl (°) 69.56 MD (ftKB) 1,654.86 WELLNAME WELLBORE1D-112 Annotation Last WO: End Date 4/12/2012 H2S (ppm) 0 Date 7/15/2019 Comment SSSV: NONE 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) 7,235.5 3,606.6 62.92 XO Reducing 4.500 CROSSOVER 4.5"x4" 4.000 7,829.4 3,888.4 60.94 PLUG 4.590 BULL PLUG 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,324.0 7,364.0 3,647.2 3,665.8 WS D, 1D-112 11/16/1998 4.0 IPERF 2.125" EJ, 0 deg phase 7,454.0 7,484.0 3,708.6 3,722.9 WS B, 1D-112 11/10/1998 4.0 IPERF 2.125" EJ, 0 deg phase 7,532.0 7,560.0 3,745.9 3,759.2 WS A4, 1D-112 11/2/1998 4.0 IPERF 2.125" EJ, 0 deg phase 7,668.0 7,698.0 3,810.7 3,825.0 WS A3, 1D-112 10/15/1998 4.0 IPERF 2.125" EJ, 0 deg phase 7,774.0 7,814.0 3,861.6 3,880.9 WS A2, 1D-112 10/8/1998 4.0 IPERF 2.125" EJ, 0 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) 7,794.0 7,814.0 1 FRAC 10/11/1998 0.0 0.00 0.00 2 FRAC 10/18/1998 0.0 0.00 0.00 7,532.0 7,560.0 3 FRAC 11/3/1998 0.0 0.00 0.00 7,454.0 7,484.0 4 FRAC 11/12/1998 0.0 0.00 0.00 7,324.0 7,364.0 5 FRAC 11/17/1998 0.0 0.00 0.00 7,794.0 7,814.0 1 REFRAC 10/13/1998 0.0 0.00 0.00 7,668.0 7,698.0 2 REFRAC 10/26/1998 0.0 0.00 0.00 1D-112, 3/27/2024 8:22:01 AM Vertical schematic (actual) PRODUCTION; 40.5-8,230.8 GRAVEL PACK LINER; 7,203.4- 7,830.0 FRAC; 7,794.0 REFRAC; 7,794.0 IPERF; 7,774.0-7,814.0 IPERF; 7,668.0-7,698.0 REFRAC; 7,668.0 IPERF; 7,532.0-7,560.0 FRAC; 7,532.0 GRAVEL PACK; 7,203.0 FRAC; 7,454.0 IPERF; 7,454.0-7,484.0 IPERF; 7,324.0-7,364.0 FRAC; 7,324.0 GAUGE; 7,129.1 MOTOR; 7,120.8 INTAKE; 7,100.7 LEAK; 7,050.0 DISCHARGE; 7,043.4 ESP MANDREL; 6,991.2 ESP MANDREL; 3,583.3 PACKER; 3,460.7 ESP MANDREL; 3,336.5 CONDUCTOR; 41.0-121.0 KUP PROD 1D-112 ... WELLNAME WELLBORE1D-112 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. //~/-" l~'j~ File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: ~ ,~,~ Poor Quality ' ' ~ Ong~nal- Pages: Other- Pages' DIGITAL DATA Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Beverly Mildred Dareth~owell Date: .~/,,/~ /s//~. [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: ~si STATE OF ALASKA ALP* OIL AND GAS CONSERVATION COM.ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Rug Perforations r Perforate r Other r Alter Casing r Pull Tubing P Stimulate - Frac r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: _ ConocoPhillips Alaska, Inc. Development 17 Exploratory r 198 - 183 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service — 50 - 029 - 22919 - 00- - 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25649 " - 1D 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): e , k L_1 - i cement bond log 1 G fo / �j1-S j C r� S P f Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: , ('J iP. Total Depth measured 8250 feet Plugs (measured) none true vertical 4104 feet Junk (measured) none Effective Depth measured 8075 feet Packer (measured) 3461 true vertical 4012 feet (true vertucal) 1996 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121 121 PRODUCTION 8190 10 8231 4094 5 �NDMe it 8 2 °12 RECEIVED MAY 14 2012 Perforation depth: Measured depth: 7324'- 7364', 7454'- 7484', 7532'- 7560', 7668'- 7698', 7774' -7814' AOGCC Vertical Depth: 3648'- 3666', 3711'- 3724', 3747'- 3760', 3811'- 3825', 3862' -3881' AOGCC Tubing (size, grade, MD, and TVD) 3.5, L - 80, 7133 MD, 3561 TVD Packers & SSSV (type, MD, and TVD) ESP FEED -THRU PACKER, WEATHERFORD HYDROW II DUAL - STRING PACKER @ 3461 MD and 1996 TVD NO SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable 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 98 13 22 -- 189 Subsequent to operation shut - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development 17 , Service r Stratigraphic E 16. Well Status after work: ,.Oil 17 Gas r WDSPL ra Daily Report of Well Operations XXX GSTOR r WINJ 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 Ca 263 -4773 Printed Name Ian Toomey Title Wells Engineer Signature Phone: 263 -4773 Date --7 / S - //- /2. R60MS MAY 14 14 l 00 117 Form 10-404 Revised 11/2011 = /3 �� Z Submit Original Only KUP • 1D-112 ConocoPhillips 0$ Well Attributes Max Angle & MD TD A.ai<a.11 u:: Wellbore API/UW' Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) ; pr y y � 500292291900 WESTSAK PROD 69.56 1,654.86 8,250.0 ' ' Comment H2S (ppm) Date Annotation End Date KB-Grd (R) Rig Release Date "' _ SSSV: NONE 5 9/15/2010 Last WO: 4/12/2012 9/25/1998 Well Conk,' - 1D -112 4/252012 2:1734 PM schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 7,069.0 1/5/2010 Rev Reason: WORKOVER ninam 4/25/2012 HANGER, 37 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String .. String Top Thrd CONDUCTOR 16 15.062 41.0 121.0 121.0 62.58 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 5/8 6.875 40.5 8,230.8 4,094.2 29.70 L -80 ABM -BTC Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 2.992 36.7 7,132.9 3,561.8 9.30 L -80 EUE8RDMOD Completion Details CONDUCTOR, Top Depth 41 -121 (TVD) Top Intl Nomi... Top (ftKB) (ftKB) (•) Item Description Comment ID (in) 36.7 36.7 -1.56 HANGER VETCO GREY TUBING HANGER 3.500 3,460.7 1,995.6 66.33 PACKER ESP FEED -THRU PACKER, WEATHERFORD HYDROW II 3.250 17 DUAL-STRING PACKER 7,043.4 3,519.5 63.07 GAUGE WELLLIFT DISCHARGE GAUGE UNIT (P /N: PWLE0018) 2.992 7,100.8 3,548.3 64.16 INTAKE TTC RECEIVING XO COUPLING w/ PERFORATED INTAKE 2.992 - (P/N:CSE84XA) 7,105.2 3,550.2 64.13 SEAL TANDEM SEAL SECTION (S/N's: 12013242/ 12013267) ESP 7,119.0 3,555.9 64.01 GEAR BOX GEAR REDUC UNIT (S/N: 120711903) MANDREL, ((�� 3337 7,120.8 3,556.7 64.00 MOTOR ESP MOTOR, 5 62MSP1 60/124029 (SM: 12057561) 7,129.1 3,560.2 63.93 GAUGE WELLLIFT MO TOR GAUGE UNIT (S/N: 192-00787) - 7,131.0 3,561.0 63.92 Centralizer MOTOR CENT RALIZER (P /N: C63569) O ther In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) gi■47 V. Top Depth PACKER, 3,461 (TVD) Top lrlcl Top (RKB) (RKB) (°) Description Comment Run Date ID (in) ilk ‘,A) 7,203 3,592.2 63.33 GRAVEL Total of 9700 pounds of gravel placed behind screens 10/13/1999 PACK Perforations & Slots Shot Top (TVD) Btm (TVD) Dens ESP • Top (ftKB) Btm (ftKB) (RKB) (RKB) Zone Date (.h -• Type Comment MANDREL, 7,324 7,364 3,647.5 3,666.3 WS D, 1D - 112 11/16/1998 4.0 IPERF 2.125" EJ, 0 deg phase 3.583 ______ 7,454 7,484 3,710.6 3,724.4 WS B, 1D -112 11/10/1998 4.0 IPERF 2.125" EJ, 0 deg phase 7,532 7,560 3,746.5 ' 3,759.6 WS A4, 1D-112 11/2/1998 4.0 IPERF 2.125" EJ, 0 deg phase 7,668 7,698 3,810.7 3,825.1 WS A3, 1D-112 10/15/1998 4.0 IPERF 2.125" EJ, 0 deg phase 7,774 7,814 3,861.7 3,881.0 WS A2, 1D -112 10/8/1998 4.0 IPERF 2.125" EJ, 0 deg phase ESP MANDREL 1 9 Stimulations & Treatments Bottom Min Top Max Btm Top Depth Depth Depth Depth (ND) (TVD) (RKB) (ftKB) (ftKB) (RKB) Type Date Comment III 7,324.0 7,364.0 3,647.5 3,666.3 Hyd Frac -Other 11/17/1998 7,454.0 7,484.0 3,710.6 3,724.4 Hyd Frac -Other 11/12/1998 GAUGE, 7,043 1 Notes: General & Safety End Dale Annotation 8/18/2010 NOTE: View Schematic w/ Alaska Schematic9.0 INTAKE, 7,101 - ---.- SEAL, 7,105 - - -( 1 GEAR BOX, 7,119 MOTOR, 7,121 GAUGE, 7,129 ' Centralizer, s> <e 7,131 IPERF, ,324 - 7,364 in 11 Hyd 7 ,324.7,364 7,324 IPERF, 7 454.7,484 Hyd Frau 7,� 'i � 1A ^'. 1 GRAVEL PACK, 7200 III II IPERF, 7,532 -7,560 Mandrel Details Top Depth Top Port (TVD) Inc' OD Valve Latch Size TRO Run IPERF, Stn Top(ftKB) (ftKB) (1 Make Model (in) Sery Type Type (In) (psi) Run Date Com... 7,668 - 7,096 ® 1 3,336.5 1,945.3 65.69 CAMCO KBMG 1 ESP DMY BK -5 0.000 0.0 4/12/2012 2 3,583.3 2,037.0 64.99 CAMCO KBMG 1 ESP DMY BK -5 0.000 0.0 4/12/2012 IPERF, II ■ 3 6,991.2 3,495.7 62.89 CAMCO KBMG 1 ESP DMY BK -5 0.000 0.0 4/12/2012 7,774.7,814 PRODUCTION, 41 -8.231 -. • TD, 8,250 • ConocoPhiIIips Time Log & Summary Welview Web Reporting Report Well Name: 1D Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 4/2/2012 10:30:00 PM Rig Release: 4/14/2012 8:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/02/2012 24 hr Summary Move off 1 D -118. Move over well slot 1 D -112. Rig up. 20:00 22:30 2.50 MIRU MOVE MOB P PJSM- Move off 1D -118, shuffle rig mats and Move over 1 D -124 Well (Drill Site Operator on site). Shim and level up Rig. Berm up and secure Cellar. 22:30 00:00 1.50 MIRU WELCTL KLWL P Tie into tree for well kill. MU hard line to Kill tank. Take on Filtered 8.6 lb/gal w /3% KCL fluid in Pits. Spot Rig support equipment. Rig Accepted at 22:30 on 04/02/2012 04/03/2012 Rig UD. Pull BPV, Kill Well, ND Tree. Set blanking plug. NU BOPE. Initial BOPE test 250/3000. Rig up to pull the 3 -1/2" ESP Completion. Pull Tubing Hanger to Floor. Circulate and condition the hole. Single down the 3 -1/2" ESP Completion. 00:00 01:15 1.25 COMPZ WELCTL KLWL P Continue to take on Filtered 8.6 lb/gal w /3% KCL fluid in Pits. Spot Rig support equipment. 01:15 01:30 0.25 COMPZ WELCTL SFTY P PJSM- Discuss hazards with pulling BPV with Vetco Gray reps. 01:30 04:15 2.75 COMPZ WELCTL MPSP P Pull BPV with lubricator Obtain well pressures -10 psi tbg pressure and 10 psi IA pressure, diesel to surface both sides. Pressure Test lines 250/3,000 psi. 04:15 06:00 1.75 COMPZ WELCTL KLWL P PJSM- Make notifications. Reverse t:irrulate 288 bbls of "HOT" sea water w/ 3% KCL at 5 bom at 500 psi ICP, 380 psi FCP.- recovered 250 bbls at kill tank. Reverse another 100 bbls of "HOT" sea water w/ 3% KCL at 5 bpm at 400 psi ICP, 440 FCP- recovered 70 bbls at kill tank for a total 320 bbls. 06:00 07:30 1.50 COMPZ WELCTL OWFF P Tubing / IA both 0 psi, Monitor well for flow, No Flow 07:30 08:00 0.50 COMPZ WHDBO MPSP P Set BPV 08:00 09:00 1.00 COMPZ WHDBO NUND P PJSM, ND Vetco Gray 4 1/16" 5M Tree and install Blanking plug. 09:00 10:30 1.50 COMPZ WHDBOOTHR P PU 11" 5M Class III stack and set over well, Open all ram cavities and cleanout 20/40 sand from previous well. Inspect rams. 10:30 12:30 2.00 COMPZ WHDBO NUND P PJSM, NU 11" 5M Class III stack and connect kill and choke lines. Page 1 of 14 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:30 17:00 4.50 COMPZ WHDBO BOPE P Fill 11" 5M Class III stack and lines with water and RU Test equipment. Held PJSM and Test BOPE at 250 / 3,000 psi in the following order. 1) Kill Line, Blind Rams, Choke Manifold valves 4- 11 -12, and 3 1/2 IF Dart Valve. 2) Kill line HCR, Choke Manifold Valves 3- 7 -9 -10, 3 1/2 IF FOSV, Top Drive Manual Valve. 3) Kill Manual Valve, Choke Manifold Valves 2 -5 -8, and 3 1/2 8rd FOSV 4) Choke Manifold Valve 6 5) Lower Pipe Rams with 3 1/2 Donut Test Joint and Choke Manifold Valve 1 6) Upper Pipe Rams with 31/2 Donut Test Joint and Choke Manual Valve 7) Annular with 3 1/2 Donut Test Joint and Choke side HCR 8) Lower Pipe Rams with 2 7/8 Donut j Test Joint 9) Annular with 2 7/8 Donut Test Joint RD test Equipment . 13" Draw Down- f System pressure 3,000 psi After Close 1,900 psi 200 psi build 15 Seconds System Pressure Build 1,975 Seconds 24 Hr Notice was given at 07:30 hrs on 4 -2 -12 and Right to witness was waived by Lou Grimaldi at 12:45 hrs on 4 -3 -12 17:00 18:00 1.00 7,149 7,149 COMPZ WHDBO MPSP P PJSM. Shoot Fluid Level at 480 -ft. Pull Blanking Plug. Pull BPV. Install Isolation sleeve. Make -up Landing Joint. 18:00 20:30 2.50 7,149 7,125 COMPZ WHDBO THGR P BOLDS. Pull the Tubing Hanger off seat at 100K. Pulled to the Rig Floor at 95K. Centrilift reading on ESP Cable and Heat Trace Cable were all good. Fill Well with 30 bbls. 20:30 22:00 1.50 7,125 7,125 COMPZ RPCOM RURD P PJSM with Rig Crew and Centrilift Service Hands. Centrilift Service Reps remove the ESP and the Heat Trace Penetrator. Lay down Tubing Hanger. 22:00 00:00 2.00 7,125 7,125 COMPZ RPCOM CIRC P Circulate Well at 3.0 bpm /180 psi. with hot 8.6 lb/gal 3% KCL. Total volume circulated = 350 bbls. 04/04/2012 Continue to single down the 3 1/2" ESP /HT Completion. Single in with 2 7/8" x 3 1/2" Clean -out String. Page 2 of 14 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:30 0.50 7,125 7,125 COMPZ RPCOM CIRC P Monitor Well. Observe Fluid Level at 30 -ft and slowly falling. Blow down lines. 00:30 14:00 13.50 7,125 20 COMPZ RPCOM PULD P Up Weight = 95K. Down Weight = 65K. Single down the 3 1/2" ESP /Heat Traced Completion to ESP components. Found light scale on last 10 joints and around ESP components. 14:00 17:00 3.00 20 0 COMPZ RPCOM PULD P Break down and Iav down ESP rnmpnnents in Rnxas Wrap ESP Spool and Heat Trace spool in prep for shipping. OFF load ESP Boxes and Misc equipment. Recovered 475 - 6 ft flat guards 34 - 4 ft flat guards 11 - 3 ft flat guards 1 - End Shoe 69 - 3.5" La Salle Clamps 2 - Protectolizers 2,135 SS Bands Quoted 1,732 Bands on Pipe Tally 17:00 19:00 2.00 0 0 COMPZ WELLPF OTHR P Set wear ring and change over to RIH w/ 2 7/8 Clean out string. Bring Baker Scraper assy to rig floor. Change handling equipment. 19:00 00:00 5.00 0 2,588 COMPZ WELLPF PUTB P PJSM. Single in with 22 Jts of 2 7/8" Hydril 511 Tubing. Make -up the 7 5/8" Casing Scraper BHA. Continue to single in with 111 Jts of 3 1/2" Drill Plpe from the Pipe Shed. 34/05/2012 Continue to single in with the Clean -out String. Clean -out from 7,203 -ft down to 7,829 -ft. Trip out and stand back the Drill Pipe. Single down the 2 7/8" Hydril Tubing. Pick -up and trip in with the Retrievable Bridge Plug and Test Packer. 00:00 04:00 4.00 2,588 7,829 COMPZ WELLPF PUTB P Cnntiniia to cin©IP in the Chan Glut String with 3 1/2" Drill Pipe from the, Pipe Shed. Entered the Sc -1 Packer at 7,203 -ft with no problems. Continue to ease in looking for any Fill. No Fill encountered. Stop at 7,829-ft. 04:00 06:00 2.00 7,829 7,829 COMPZ WELLPF CIRC P Circulate 40 bbls at 3 bpm. ICP 1100 psi, FCP 1310 psi. Rig up to Reverse Circulate. Reverse Ciculate 214 bbls and ceturned 75 bbls to kill tank. (33% returns) 06:00 08:00 2.00 7,829 7,829 COMPZ WELLPF CIRC P Blow down hardline. Circulate bottoms up, down tubing up ia. 265 bbls at 5bpm, 1300 psi ICP, and 1050 FCP. 08:00 09:00 1.00 7,829 7,829 COMPZ WELLPF OWFF P Blow down top drive and monitor. 09:00 12:00 3.00 7,829 1,076 COMPZ WELLPFTRIP P POOH to 1076' 12:00 13:30 1.50 1,076 1,076 COMPZ WELLPFSLPC P Slip and Cut Page 3 of 14 • . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 14:00 0.50 1,076 689 COMPZ WELLPF PULD P Lay down remaining 3 -1/2" DP f/ 1076 -ft to 689 -ft. 14:00 14:30 0.50 689 689 COMPZ WELLPF OTHR P Change over floor equipment to 2 7/8 14:30 16:00 1.50 689 689 COMPZ WELLPF OTHR P Held PJSM with Crane and Rig crew on conducting critical lift of ESP cable spool and Heat trace spool. Off load ESP and Heat Trace spools and re load New ESP Cable spool. 16:00 21:00 5.00 689 0 COMPZ WELLPF PULD P POOH laying down 2 7/8 Hydril 511 clean out string from 689 -ft to surface. Off-load Tubing from Pipe Shed. Finish loading, drifting and tally the 3 1/2" 9.3 lb /ft/ L -80, 8rd EUE Completion Tubing. 21:00 00:00 3.00 0 3,125 COMPZ WELLPF TRIP P PJSM. Pick -up the Baker Model "G" ,,,i /L Lock -Set Retrievable Bridge and a Model "EA" Retrievamatic Packer. Trip in with 3 1/2" Drill Pipe from the Derrick. )4/06/2012 Set RBP. Test Casing. Release RBP. Circ and Cond Well. Trip out with Drill Pipe and stand back in Derrick. Pick up and service ESP Assembly. Single in with 3 1/2" ESP Feedthru Packer Completion. 00:00 02:30 2.50 3,125 7,180 COMPZ WELLPF TRIP P Continue to trip in with 3 1/2" Drill Pipe from the Derrick to 7,180 -ft. 02:30 03:00 0.50 7,180 7,180 COMPZ WELLPF PACK P Set the Baker Retrievable Bridge Plug at 7j80-ft. Lay down one Joint. G 03:00 04:00 1.00 7,180 7,180 COMPZ WELLPF PRTS P Rig up test equipment. Pressure test the 7 5/89" Casing from 7,180 -ft L7 back to surface at 1,500 psi x 30 minutes. Good test. Test recorded on a chart. 04:00 06:00 2.00 7,180 7,165 COMPZ WELLPFCIRC P Plck -up one Joint latch and release the Release RBP. Circulate and condition Well with 333 bbls at 4.0 bpm /560 psi. taking returns to kill tank - recovered 275 bbls. 06:00 07:30 1.50 7,165 7,165 COMPZ WELLPF OWFF P Blow down Top drive and monitor well for flow - fluid level dropping. Held PJSM for tripping out of the hole with drill pipe and splitting in derrick for rig move. 07:30 11:00 3.50 7,165 0 COMPZ WELLPF TRIP P POOH from 7,165 -ft to Test packer and RBP - Release off RBP and Break down Test packer assy. 11:00 12:00 1.00 0 0 COMPZ WELLPF OTHR P Held PJSM on pulling wear ring, setting test plug and washing 11" BOP stack. Wash BOP stack at 12:00 18:30 6.50 0 85 COMPZ RPCOM PULD P Serviced motor and tandem seal assy, verified all shafts rotated. Attach Tech Wire to the Guardian Gauge. Attach and test ESP Cable to the Motor. Page 4 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 23:00 4.50 85 2,145 COMPZ RPCOM PUTB P PJSM. Start to single in with the 3 1/2" ESP w /Freethru Packer Completion from the Pipe Shed as designed. Check ESP Cable at 1,100 -ft. Good. Continue to single in with the Completion to next Cable check. 23:00 00:00 1.00 2,145 2,145 COMPZ RPCOM OTHR T Cable check at 2,145 -ft not good. Re -check with a second meter with same readings. Check with Simpsom Meter. Also with bad results. Centrilift discuss reading with Town. POOH. X4/07/2012 POOH to find the cause of the bad ESP Cable reading. Trouble shoot and correct problem. Start back in with the 3 1/2" ESP w /Feedthru Packer Completion as designed. 00:00 02:30 2.50 2,145 0 COMPZ RPCOM TRIP T Trip out with 3 1/2" Tubing, standing back in the Derrick to trouble shoot poor ESP Cable readings. 02:30 06:00 3.50 0 0 COMPZ RPCOM OTHR T Findings: Inspected the ESP Cable on the way out of the hole. Continued scratches on the ESP Cable after pulling 1,000 -ft out. The next 1,100 -ft+ had 10 minor "dings in the Armor. 5 bad "dings" in the Armor and 1 place in the Armor where the armor was cut. Doing the math and looking at the Directional Survey there is a very bad Dog -Leg section in the casing from - 1,000 -ft (8.9 deg DL) - - 1,100 -ft (6.8 deg DL). After cutting the Cable from the Motor Lead the Cable checked two good legs and one weak leg. The Motor Lead checked good. The Motor checked good. However the Motor has bad scratches along the entire length. Also some of the 3 1/2" Tubing Collars are shined up on one side. Discuss results with Anchorage Engineer. 06:00 07:30 1.50 0 0 COMPZ WELLPF OTHR T Held PJSM for Install shooting flange on BOP stack - Remove Riser and prepare to install shooting flange - Change in Scope, held PJSM and re- nippled up riser to RIH w/ RBP for barrier 07:30 09:00 1.50 0 0 COMPZ WELLPFOTHR T Move completion string in derrick in order to safely RIH w/ DP off Drillers side and keep from damaging equipment and injury to personnel. 09:00 10:30 1.50 0 3,600 COMPZ WELLPF TRIP T Held PJSM with Baker R &S hand on RIH w/ RBP. RIH w/ RBP on 3 1/2 DP to 3,600 -ft. Page 5 of 14 . • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 11:00 0.50 3,600 3,600 COMPZ WELLPF OTHR T Move completion string in derrick in order to safely RIH w/ DP from offDrillers side and keep from damaging equipment and injury to personnel. 11:00 12:00 1.00 3,600 3,600 COMPZ WELLPF OTHR T Held PJSM on making critical lifts - changed out ESP cable spool with replacement from 1 D -118. 12:00 14:00 2.00 3,600 7,181 COMPZ WELLPF TRIP T Recap PJSM with Baker R &S hand on RIH w/ RBP. Continue to RIH w/ RBP on 3 1/2 DP from 3,600 -ft. to 7,180 -ft 117k up wt, 68k do wt. 14:00 15:00 1.00 7,181 7,090 COMPZ WELLPF PACK T Set RBP at 7.180 -ft center of elemant w/ top at 7.178 -ft. Release off and POOH to 7,090 -ft 15:00 16:00 1.00 7,090 7,090 COMPZ WELLPF PRTS T RU and test pressure test RBP at 1,520 psi for 30 minutes. Lost 30 psi / during the 30 minutes. Negative for 1/ 30 minutes on trip tank - static Good test. 16:00 19:00 3.00 7,090 7,171 COMPZ WELLPF OTHR T pump 550 lbs (equivalent to 20 -ft inside 7 5/8 29.6# CSG) of 20 -40 sand down DP at surface to top of RBP at 7,178 -ft. (Calculated Top of sand at 7,158 -ft.). Run to tag TOS. Found Sand strung out due to 63 deg hole angle. Pull back up hole. Roll Charge Pump over while running back in hole. End Charge Pump and pull back up hole. Let Sand settle again. Run back in and tagged TOS at 7,171 -ft. Now have 7 -ft of good Sand on top of RBP. 19:00 23:00 4.00 7,171 0 COMPZ WELLPF OTHR T PJSM. Trip out with the RBP Running Tool on 3 1/' Drill Pipe standing back in the Derrick. (S -Line Unit arrives on Location). 23:00 00:00 1.00 0 0 COMPZ EVALWE ELOG T PJSM. Bring E -Line Toots to the Floor. Rig up E -Line equipment. X4/08/2012 Record Gyro, Caliper, GR/CCL Logs. RD E -Line. After determining the damaged Casing area, 00:00 07:00 7.00 0 0 COMPZ EVALWE ELOG T RIH with Gyro, 40 -Arm Caliper with GR/CCL Tool String. Tool String sat down at 1,380 -ft (60.9 deg incline x 5.06 Dog Leg). Tried many time to pass thru. No -Joy. POOH. Lay down the 40 -Arm Caliper Tool. RIH with Gyro, GR /CCL. Set down at ,1.384 -ft. Tried several times to pass thru. Record Gyro Log from 1,380 -ft back to surface. Lay down Gyro Tool. Pick -up the 40 -Arm Caliper. Test Tool on surface. Motor failed to close the Arms. Replace Motor. Run in with the 40 -Arm Caliper. Set down again at 1,384 -ft. Unable to pass thru. Record Caliper Log from 1,380 -ft back to surface. Page 6 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 09:00 2.00 0 1,389 COMPZ WELLPF TRIP T PU and MU 6 3/4" Tri cone bit and csg scraper assy and RIH on 31/2 DP to 1,389 -ft and tag up . 55k up wt, 55 k do 09:00 09:30 0.50 1,389 1,389 COMPZ WELLPF CIRC T Reverse circulate at 5 bpm at 150 psi - small amount of 20/40 sand in returns. 09:30 10:00 0.50 1,389 1,420 COMPZ WELLPF REAM T Ream down from 1,389 -ft to 1,420 -ft. up wt 55k, 55k do wt and 55k Rot wt. 650 ft/lbs free torque. Circulating with charge pump. 10:00 10:30 0.50 1,420 1,420 COMPZ WELLPF CIRC T Reverse circulate 80 bbls at 8 bpm at 450 psi and recovered 50# of 20/40 sand. 10:30 12:30 2.00 1,420 7,060 COMPZ WELLPF TRIP T RIH from 1.420 -ft to 1.518 -ft slowly with no tag. Continue to RIH from 1,518 - ft to 7,175 - ft - No tag. 120k up wt 67k do wt. PU to 7,060 -ft. 12:30 13:30 1.00 7,060 7,060 COMPZ WELLPF CIRC T Reverse circulated 240 bbls at 8 bpm at 1650 ICP 1650 FCP. - No sand in returns. Blow down Top drive. 13:30 16:00 2.50 7,060 0 COMPZ WELLPFTRIP T POOH from 7,060 -ft to surface, lay down scraper assy. Recovered a few (5 to 8) small metal filings in scraper blades. 16:00 20:15 4.25 0 0 COMPZ EVALWE ELOG T RU Halliburton Eline and RIH w/ 40 , ARM caliper tools from surface to 7,152 -ft. Record 40 -Arm Caliper Log at 50- ft/min back to surface. Lay down Caliper Tool. 20:15 00:00 3.75 0 0 COMPZ EVALWE ELOG T PJSM. Make -up Gyro Tool. Run in with Same to 7,152 -ft. Begin recording Gyro survey. 04/09/2012 Complete Gyro Log. RD E -Line. MU BHA #4, Casing Swedge. Swedge damaged Casing areas and drift Casing to 7,150 -ft. 00:00 04:00 4.00 0 0 COMPZ EVALWE ELOG T Continue recording Gyro Log from 7,152 -ft back to surface. Complete log run. Rig down E -Line equipment. Release E -Line Unit. 04:00 06:00 2.00 0 315 COMPZ WELLPF SWDG T PJSM. Make up BHA #5, 6 3/4" Casing Swedge picking UD from pipe shed to 314 -ft 06:00 17:00 11.00 315 7,150 COMPZ WELLPF SWDG T RIH w/ BHA #5 and tag up at the following intervals: Depth / wt to push thru / wt to pull thru: 408 -ft / 3k / 5k ; 1182 -ft / 15k / 15k ; 1185 -ft / 15k / 15k ; 1643 -ft / 3k / 3k 4106 -ft / 8k / 8k � (I 4816 -ft / 8k / 15k ; 6202 -ft / 9k db / 15k ; 6368 -ft / 15k / 20k ; 6368 -ft / 28k / 25k ; 6837 -ft / 7k / 15k. Continue to RIH to 7,150 -ft. Reverse circulate at 6,368 -ft. 6.0 /bpm /1,300 psi x 240 bbls. 17:00 17:15 0.25 7,150 7,100 COMPZ WELLPF PRTS T PT Casing 1500 psi, 5 minutes, Good Test at 7100'. Page 7 of 14 r ill • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:15 18:00 0.75 7,100 7,100 COMPZ WELLPF SFTY T Safety Awareness Meeting with both Crews. 18:00 21:30 3.50 7,100 0 COMPZ WELLPF SWDG T PJSM. Trip out from 7,100 -ft with BHA #5. Up Weight = 140K. (Note: the tight spot at 6,368 -ft took 25K over pull to pass back through). 21:30 23:00 1.50 0 4,000 COMPZ WELLPF SWDG T Lay down the 6 3/4" Swedge and pick -up the 6 11/16" Swedge. Trip in with BHA #6. At 1,182 -ft Swedge took 4K down weight to drop through. Continue down to 4,000 -ft to drift for the Completion Packer. 23:00 00:00 1.00 4,000 2,539 COMPZ WELLPF SWDG T Begin to trip out with BHA #6, standing back 3 1/2" Drill Pipe in the Derrick from 4,000 -ft. Up Weight = 83K. Down Weight = 60K. 04/10/2012 Continue to investigate Casing damage with Casing Swedge at 1,182 -ft. Discuss options. Perform Weekly BOPE Test. Rig up E -Line. Record CAST -M w /CCL, GR data. 00:00 01:30 1.50 2,539 0 COMPZ WELLPF SWDG T Continue to trip out to 1,182 -ft. (took 4K to drop through on the trip in). Took 8k to pull back through. Attempt to work damage area. However it started to get worse. 12K down, 8 K up. Abort and ponder. Finish trip out with BHA #6. 01:30 01:45 0.25 0 0 COMPZ WELLPF PRTS T Pressure test Casing at 1,500 psi x 5 minutes. Good. 01:45 03:30 1.75 0 1,182 COMPZ WELLPF SWDG T Re- configure BHA to change the depth of the Bumper Sub and Oil Jar (space -out away from a bad dog leg GS)- area). Trip in with BHA #7 to 1,182 -ft. Again it tnnk 12K to rirnp through the damaged spot and 8K 1�� over Dull to come back uo through, (. Discussed results with Anchorage Engineer and the possibilities that rotation might be needed to "wipe out" the bad spot. Decession made to go forward with the scheduled weekly BOPE test and allow more discussion in Anchorage to address the Casing problem. 03:30 05:00 1.50 1,182 0 COMPZ WELLPF SWDG T Give the AOGCC Field Inspector a short- notice call for the Weekly BOPE test. J. Crisp returned call and will witness the test. Trip out with 3 1/2" Drill Pipe and Drill Collars, standing back in the Derrick. Lay down Bumper Sub /Oil Jars, Watermellon Mill, and the Casing Swedge. (Note: the 6 11/16" Casing Swedge had scrape marks on it same as the scrape marks found on the ESP Motor). Pull Wear Bushing. Page 8 of 14 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:00 13:30 8.50 0 0 COMPZ WHDBO PRTS P Fill 11" 5M Class III stack and lines with water and RU Test equipment. Held PJSM and Test BOPE at 250 / 3,000 psi. Perform Accumulator Draw Down Test- System pressure 6° 3,000 psi, After Close 1,950 psi. Function Tested both Chokes. ��" Manual OK. Found Hydraulic Choke unable to build pressure when closed. Find bad choke seat and replace. Function tested after rebuild and OK. 13:30 14:00 0.50 0 0 COMPZ WHDBO PRDT P Pull Test Plug and Install Wear Ring 14:00 16:00 2.00 0 0 COMPZ RISER PULD T PJSM. Nipple Down Flow Riser and Nipple Up Eline 16:00 20:15 4.25 0 0 COMPZ EVALWE RURD T PJSM. RU Eline. Pick -up Lubricator and make -up CAST -M w/ CCL, GR. Attempt pressure test Lubricator (had Shooting Flange leak. Replaced the OTIS connection "O" Ring). Pressure test the Lubricator and the 7 5/8" Casing from the Retrievable Bridge Plug back to surface at 1,500 psi x 15 minutes. Solid test. Record on Chart. 20:15 00:00 3.75 0 0 COMPZ EVALWE ELOG T Run in with CAST -M. CCI. GR Tool String to 7,125 -ft. Begin to log up at 45- ft/min and record data. (Recorded, a High Resolution Pipe Inspection Log from 6,500 -ft - 6,200 -ft with the depth of interest at 6,368 -ft). Continue logging towards surface. X4/11/2012 Continue with E -Line Logging Operations. RD E -Line. Swap Wellbore over to clean filtered Kill Weight Fluid. Release Baker RBP. Circulate Well. Monitor Well. TOOH and LD RBP. 00:00 04:15 4.25 0 0 COMPZ EVALWE ELOG T Continue logging Well towards surface. (Recorded a High Resolution Pipe Inspection Log from 1,300 -ft - 1,000 -ft with the depth of interest at 1,182 -ft). Finish logging to surface. Drop back down to 3,500 -ft. Pressure up on the wellbore to 1,000 psi and log back to surface. (Note: Sticky at 3,100 -ft. Pulled 200 lbs over line tension to free during the pressured pass). 04:15 05:00 0.75 0 0 COMPZ EVALWE RURD T E -Line finish logging. Rig down (release E -Line Unit). 05:00 07:00 2.00 0 0 COMPZ EVALWE NUND T Nipple down Shooting Flange. Nipple up Riser. 07:00 08:30 1.50 0 0 COMPZ EVALWE PULD T Pick -up and lay down Drill Collars. 08:30 08:45 0.25 0 0 COMPZ EVALWE SFTY T PJSM. Discuss hazard for Making up BHA. 08:45 09:15 0.50 0 19 COMPZ EVALWE PULD T MU Baker Retrieving Tool Assembly. (Model " L " Retrieving Head and a 3.5" x 2.875" Rotary Sub. 19.10' OAL Page 9 of 14 • Time Logs • Date From To Dur S, Depth E. Depth Phase Code Subcode T Comment 09:15 12:00 2.75 19 7,173 COMPZ EVALWE TRIP T TIH with Retrieving Head Assembly on Drill Pipe. Wt Ck at 4100', 71 k up & 61k dn, 5067' 83k up & 63k dn, 6129' 99k up & 63 dn, 7094' 110k up & 64k dn and 7173' 120k up & 64k dn. 12:00 13:45 1.75 7,173 7,173 COMPZ EVALWE CIRC T Reverse Circulate sand from top of, RBP at 7 bpm, 1425 psi. Circulated a total of 335 bbls until returns are clean. Had a Un- announced Spill Drill in Cellar during pumping operation. 13:45 15:45 2.00 7,173 7,173 COMPZ EVALWE CIRC T Reverse Circulate wellbore over to clean filtered 8.6 ppg Clean Filtered KWF at 6.0 bpm x 1,430 psi. x 300 bbls. 15:45 16:15 0.50 7,173 7,178 COMPZ EVALWE MPSP T 1 atrh & RP.IAARP RRP at 7 178 -ft , allow element to relax. Verify free travel after RBP released. 16:15 19:00 2.75 7,178 7,175 COMPZ EVALWE CIRC T Circulate Well with 476 bbls of Clean Filtered KWF at 6.0 bpm /960 psi. 19:00 19:30 0.50 7,175 7,175 COMPZ EVALWE OWFF T Observe well for Flow. Lost 7 barrels in 30 minutes. Fluid loss = 14 bph. 19:30 23:00 3.50 7,180 0 COMPZ EVALWE TRIP T PJSM. Start to trip out. Pulled 2 Joints. Retrievable Bridge Plug hung up. Work to free (45 minutes). RBP now free. Run back below setting depth to make sure RBP is still there. Trip out with 3 1/2 Drill Pipe and RBP. Lay down RBP. Lost one RBP Slip Die complete. NOtify Anchorage engineer. 23:00 00:00 1.00 0 0 COMPZ FISH PULD T Call -out Baker Fisherman to build BHA and run Reverse Circulating Junk Basket. (Tools needed for BHA are on Location). Bring Tools to Pipe Shed. 34/12/2012 Left a Slip Die in the Hole from the RBP. Call out Fisherman. Make -up BHA #9, Reverse Circulating Junk Basket. Fish Slip Die. Re -Run 3 1/2" ESP w /Feedthru Packer Completion. 00:00 01:00 1.00 0 0 COMPZ FISH PULD T Baker fisherman arrived on Location. 01:00 01:45 0.75 0 31 COMPZ FISH PULD T Make -up BHA #9, Reverse Circulating Junk Basket (with 7/8" Ball in place). 01:45 04:00 2.25 31 7,090 COMPZ FISH TRIP T Trip in with BHA #9 on 3 1/2" Drill Pipe from the Derrick to 7,090 -ft. Stop for Rig Maintenance. 04:00 05:30 1.50 7,090 7,090 COMPZ RIGMNT RGRP P Scheduled Rig Repair. Cut and Slip Drilling Line (84 -ft). Check Drawworks. 05:30 06:30 1.00 7,090 7,210 COMPZ FISH FISH T Work Reverse Circulating Junk , Basket to recover the lost RBP Slip, Die. Pump rate at 6 bpm, 1660 psi, ROT 80k, 10 RPM, 2k TQ, work up and down from 7,205- 7,210' x 3. Lay down single, BD/TD, monitor well, well drinking at 12.8 BPH. Page 10 of 14 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:30 10:30 4.00 7,210 30 COMPZ FISH FISH T PJSM. TOOH standing back drill pipe to check junk basket. Up Wt 110k. Maintain Proper Hole Fill every 5 stands. 10:30 11:00 0.50 30 0 COMPZ FISH PULD T OOH. Lay down Junk Basket. Recovered Slip Die and One SS Band. 11:00 11:45 0.75 0 0 COMPZ RPCOM PULD T Clean & Clear Floor of Baker Tools. Release Baker Fisherman. 11:45 12:45 1.00 0 0 COMPZ RPCOM CIRC T PJSM. Pull Wear Ring and Set Test Plug. RU BOP washing assembly and Wash BOP stack until clean. 12:45 13:45 1.00 0 0 COMPZ RPCOM PULD T Pull Test Plug. C/O handling equipment and Inspect. Prep to Run ESP Completion. 13:45 14:00 0.25 0 0 COMPZ RPCOM SFTY P Hold PJSM with Nordic Crew, Centrilift Crew. Discuss hazards for running ESP equipment. 14:00 21:15 7.25 0 3,460 COMPZ RPCOM RCST P Make Up and service lower ESP , Completion. Start to run 3 1/2" Completion Tubing from the Derrick. (Note: stopped every 500 -ft to perform a "quick" ESP Cable check. At every 1,000 -ft perform a complete ESP Cable check). Continue running the Completion. Now past the damaged Casing spot at 1,182 -ft. End running in with the 3 1/2" Tubing from the Derrick. Begin to single in with 3 1/2" Tubing from the Pipe Shed. Pick -up Weatherford Hydrow II Dual String Packer. Cut ESP Cable to make Feedthru Connections. Stop for PJSM. 21:15 21:45 0.50 3,460 3,460 COMPZ RPCOM SFTY P PJSM for ESP Cable Spool swap. 21:45 22:30 0.75 3,460 3,460 COMPZ RPCOM OTHR P Spot Crane. Remove empty ESP Spool from Rig Floor. Pick -up ESP Cable Spool and set on Rig Floor. Rig down Crane. Cable swap completed with no problems. 22:30 00:00 1.50 3,460 3,460 COMPZ RPCOM OTHR P Centrilift Service Reps make _ Feedthru Packer ESP able ton and bottom connections. 04/13/2012 Cont to make Feedthru Pkr ESP connections. Cont to run the 3 1/2" Completion as designed. Land Tbg Hanger. Test Packoff. Freeze Protect Well. Rig up S -Line. Discovered that the Side Isolation Sleeve was not pulled before pumping the Diesel. Re- Group. 00:00 03:30 3.50 3,460 3,460 COMPZ RPCOM OTHR P Centrilift Service Reps continue to make Feedthru Packer ESP connections. 03:30 09:00 5.50 3,460 7,094 COMPZ RPCOM RCST P Resume running the 3 1/2" Completion as designed. Continue to single in with 3 1/2" Tubing from the Pipe Shed. Call Out Vetco -Gray Service Rep. Page 11 of 14 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 09:30 0.50 7,094 7,094 COMPZ RPCOM OTHR P On Depth with Completion to Make -up Tubing Hanger. Perform Electrical Integrity Test on Power Cable. ( Tested Good ) 09:30 09:45 0.25 7,094 7,094 COMPZ RPCOM SFTY P PJSM. Discuss Hazard for Handling Tubing Hanger and Making Final Cable Splice. 09:45 12:15 2.50 7,094 7,094 COMPZ RPCOM THGR P MU Tubing Hanger and Make Final Splice on Cable and Test Same. 12:15 12:30 0.25 7,133 7,133 COMPZ RPCOM SFTY P PJSM. Discuss Hazard for Landing Completion. 12:30 14:00 1.50 7,094 7,133 COMPZ RPCOM THGR P MU Landina Joint and Land 3.5" ESP Completion at 7,132.92 ORKB. RILDS and PT hanger Upper and Lower Pack -offs Void to 5000 psi for 10 minutes each. Call Out LRS and SLick -line Crew. 14:00 14:30 0.50 0 0 COMPZ RPCOM SFTY P PJSM. Discuss Hazard for Pumping and S -Line Operations with Rig Crew, S -Line Crew, and Lil Red Crew. 14:30 19:15 4.75 COMPZ RPCOM FRZP P Spot Lil' Red and lay line. Pressure test line at 4,000 psi. Pump Gelled Diesel down the 7 5 /R" x 3 1/7" Annulus at an average of 1.1 bpm /480 psi. Total volume pumped = 125 bbls. Swap to pump Clear Diesel down the 3 1/2" Tubing. Total volume pumped = 32 bls at 1.0 bpm. End Lil Red. Block in and stand -by. 19:15 23:00 3.75 COMPZ RPCOM OTHR T PJSM. Rig up S -Line equipment. Pressure test Lubricator at 500 psi. RIH with a 2.780" Gauge Ring to drift the Tubing. However, Gauge Ring sat down in the Wellhead. Ponder and ask questions. Piarovared that the Side Isolation Sleeve was never pulled before pumping any Diesel. Unable to pull, now that the well has been under balanced with Diesel. Notify the Day Co Man and the Anchorage Engineer. Re- group. Order additional KWF. Order Gel Diesel. Rig back S -Line and send Crew to Camp for bed rest. Rig down Lil' Red and send Unit in to load additional Diesel. Also send Crew to Camp for bed rest. 23:00 00:00 1.00 COMPZ RPCOM CIRC T Wait on additional KWF to arrive on Location. 04/14/2012 Re -Kill Well with KWF. Monitor. Pull Landing Jt. Pull Side Isolation Sleeve. MU Landing Jt. RU S -Line. Set WRP. Set Packer. Test Csg and Pkr. De- pressurize the IA. Page 12 of 14 Time Logs • • Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 00:00 04:00 4.00 0 0 COMPZ WELCTL CIRC T Additional KWF arrived on Location. Off -load into Pits. Reverse in with Clean filtrered 8.6 lb/gal w /3% KCL, taking diesel returns to the Kill Tank. Pumped a total of 350 bbls at 21.0 bpm /160 psi. Call out Vetco Gray. 04:00 04:30 0.50 0 0 COMPZ WELCTL OWFF T Monitor Well. Static. Then observe Well on slow vacuum. 04:30 05:00 0.50 0 0 COMPZ RPCOM OTHR T Lay down Landing Joint. Vetro Gray pulled Side Isolation Sleeve. Make -up Landing Joint. Call out Lil Red. 05:00 08:00 3.00 0 0 COMPZ RPCOM OTHR T Call Out LRS. Hold Weekly Safety meeting. R/U Hoses for Pumping Operation. Prep to swap out ESP spool. 08:00 09:00 1.00 0 0 COMPZ RPCOM PULD P Crane on Location. PJSM. Discuss Hazard for Lifting operation. Swap out ESP Spools. 09:00 09:45 0.75 0 0 COMPZ RPCOM OTHR T LRS On Location. MIRU same. 09:45 10:15 0.50 0 0 COMPZ RPCOM SFTY T Hold PJSM with LRS. Discuss hazard for High Pressure Testing and Pumping Operation. 10:15 12:15 2.00 0 0 COMPZ RPCOM CIRC T PT LRS Pumping Lines to 300/4000 psi. Line up and Circulate 135 bbls of Gelled Diesel down IA Annulus at 1.1 BPM, 480 psi. 12:15 13:00 0.75 0 COMPZ RPCOM CIRC T Swith over to TBG and pump 35 BBL down TBG at 1 BPM at 480 psi. Final Pressures T /IA = 350 / 200 psi. 13:00 19:30 6.50 COMPZ RPCOM SLKL P PJSM. RU HES SL. RIH and drift TBG to 3800'. Second run locate GLM #2 at 3853' and flag Line. Make -up Weatherford WRP. RIH and correlate to "flag ". WRP set at 3,615 -ft RKB. Wait for Setting Tool to set the WRP. Saw good indication WRP set. POOH. Set back S -Line Tools. 19:30 20:00 0.50 COMPZ RPCOM PRTS P Lil' Red pressure up on the Tubing against the WRP to 500 psi x 5 minutes. Good test. 20:00 21:00 1.00 COMPZ RPCOM PACK P Begin the Weatherford Hydrow II Feedthru Packer setting sequence. Increase pressure to 1,000 psi and hold. Slowly increase pressure to 1,500 psi and hold (saw the Packer set at —1,250 psi). Increased pressure to 2,000 psi and begin to pack -off the elements. Increase pressure to 2,500 psi, 3,000 psi and stop at 3,300 psi for a final pressure. Hold pressure for 30 minutes. Final pressure 2,875 psi. Bleed pressure to "0" psi. (Rig down S- Line). Page 13 of 14 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 22:30 1.50 COMPZ RPCOM PRTS P Pressure test the 7 5/8" x 3 1/2" Annulus. Bring pressure to 1,600 psi. Monitor pressure on Chart. Lost 60 psi in 15 minutes. Continue to monitor for the final 15 minutes and lost an additional 30 psi. Test just barley passed. Decided to repeat the test and isolate surface equipment with a second block valve. Initial test pressure was 1,600 psi. After 15 minutes 1,540 psi. Final 15 minutes pressure was 1,530 psi. Test passed. All test were recorded on a Chart. (Rig down Lil' Red) 22:30 00:00 1.50 COMPZ RPCOM PRTS P Begin to bleed the pressure off of the Annulus in steps following the de- pressurize Schedule in the Program. (Install TWCV. Prep to ND BOP Stack). 04/15/2012 Complete de- pressurize schedule. Install TWCV. Nipple Down the BOP Stack. Test the ESP Cable. Nipple Up the Tree. Test Tree to 5,000 psi. Perform the final ESP Cable checks. Pull TWCV. Install BPV. Secure Cellar. RDMO. 00:00 02:30 2.50 0 0 COMPZ RPCOM PRTS P Continue to follow the De- pressurize Schedule to bleed down the pressure from the 7 5/8" x 3 1/2" Annulus. 02:30 03:30 1.00 0 0 COMPZ WHDBO NUND P Nipple down BOP Stack and set back on Stump. Centrilift checked ESP Cable good. 03:30 05:00 1.50 0 0 COMPZ WHDBO NUND P Nipple up Tubing Adaptor and Production Tree. (DSO verified the Tree Orientation). PT tree to 5000 psi. OK. PT Hanger Void/ Packoffs to 5000 psi, OK. 05:00 06:00 1.00 0 0 COMPZ RPCOM OTHR P Make final check of ESP cable/ motor electrical integrety. 06:00 07:00 1.00 0 0 COMPZ WHDBO MPSP P Pull two -way Check and install CIW 3 "'H' BPV. 07:00 08:00 1.00 0 0 COMPZ MOVE MOB P Back off Rig Mats, Clean Tree and Cellar. Release Rig at 8:00 AM. Page 14 of 14 k WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. April 11, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: CAST -M with ACE and CASE Processing: 1D -112 Run Date: 4/10/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1D -112 Data in LAS or DLIS format, Digital Log Image files 1 CD Rom 50- 029 - 22919 -00 ACE Log 1 Color Log 50- 029 - 22919 -00 XAMED MAY 2 3 2012 CAST -M Field print 1 Color Log 50- 029 - 22919 -00 CASE Log 1 Color Log 50- 029 - 22919 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Date: Signed: 1 ')._,P.,114--) �z-v WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. April 10, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 EDMAY 2 3 2022 RE: Multifinger Imaging Tool (MIT) : 1D-112 Run Date: 4/8/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1D -112 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 029 - 22919 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: /11 Signed:�� • ~~~~ ~i ~~~~~~ PROACTIVE DIAGNOSTIC SERVICES INC. 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 Suite C Anchorage, AK 99518 Fax: (907 245-8952 1) MTT Report 2) 22,Jun-10 1x112 1 Report 50-029-22919-00 ~` ~~~ -1~3 ~= Signed : Date Print Name: .O~ntta~is~ic~~s PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (9071245-8951 FAX: (907245-88952 E-MAIL : ~dsanclaorageCc~memorvloa.com WEBSiTE : www.memorvlop.com C:\DocumenLc and Setbngs\Diane Williams~Desktop\Tiansmit_Conoco.docx. • • Memory Magnetic. Thickness Teat Log Results ~urnmary Company: ConocoPhillips Alaska, Inc. Well: 1 D-112 Log Date: June 22, 2010 Field: West Sak Log No.: 10645 State: Alaska Run No.: 1 API No.: 50-029-22919-00 Pipet Desc.: 3.5" 9.3 Ib L-80 EUE 8RD Top Log Intvl.: Surtace Pipet Use: Tubing Bot. Log Intvl.: 198 Ft. (MD) Pipet Desc.: 7.625" 29.7 Ib L-80 ABM-BTC Top Log InNI.: Surface Pipet Use: Production Casing Bot. Log Intvl.: 198 Ft. (MD) Pipe3 Desc.: 16" 62.58 ib. H-40 Welded Top Log Intvl.: Surtace Pipe3 Use: Conductor Pipe Bot. Log Intvl.: 121 Ft. (MD} Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS: This MTT data is tied into the Mandrel Hanger @ 0' Depth_ This is the first time this well has been logged w~h the 12 Arm Magnetic Thickness Tool (MTT). The MTT responds to the total metal thickness of the 3.5" tubing, 7.625" production casing, with some influence from the 16" conductor pipe. Passes at 5Hz, 8Hz and 10Hz were made at 20 fpm. INTERPRETATION OF MTT LOG RESULTS The MTT log results cover the interval from surface to 198'. Changes in meta( volume are relative to the calibration points at 43' and 133', where the readings are assumed to represent undamaged pipe. All other readings are relative to these reference points, which include influences from the 3.5" tubing, 7.625" casing and 16" conductor pipe. A log plot overlay of the average overall metal thickness recorded by the 5Hz, 8Hz and 10Hz passes is included in this report. This plot indicates metal loss features over the intervals 5' -12', 18' - 22', 30' - 38' and 48' - 80', with their maximum metal loss indicated in all three passes list in the table below. Depth 5' - 12' 18' - 22' 30' - 38' 5Hz 6°h 92% 15% Maximum Metal Loss 8Hz 16Hz 4% 0% 6% _ _1% 8% _2°~ 6°to 5°to 48' - 80' _ 5°~ Log plots of the entire 5Hz and 8Hz passes and an expanded log plot of the top 30' of the 5Hz pass are included in this report. Indications of general isolated metal loss are recorded throughout the majority of the interval logged in the 5Hz pass, with indications over the interval (38' - 80') being more prevalent than those below this interval. The 8Hz pass indicates similar isolated metal loss patterns as the 5Hz pass. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which may include influences from the 3.5", 7.625" and 16" pipe. If all of the metal loss is specific to the 7.625" production casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal foss indicated could be from eitherthe 3.5" tubing or 16" conductor. Field Engineer: ~. Etherton Analyst: HY. Yang & J. Burton Witness: B. Boehme ProActive Diagnostic Services, Inc. / P.Q. Box 1369, Stallard, TX 77497 Phone: (2$i) or ($88) 565-9085 Fax: (281) 565-1369 E-mail: PDS~jmemorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ,~~- t ~3 o`E"~ ~E"s 5Hz, ~z and 10Hz Qelta Metal Thi~iess Passes Overlay ~ "" 1 D-112 June 22, 2010 PROACTIVE DIAEIN°STIC SFAYIUS Database File: d:lwarriorldatal1d-1121overlay.db Dataset Pathname: overlay Presentation Format: overlay Dataset Creation: Wed Jun 23 16:41 ~ 18 201 D Charted by: Depth in Feet scaled 1:150 -50 Delta Meta! Thickness 2010 (10Hz) (%) 50 -50 Delta Metal Thickness 2010 (8Hz) (%) 5D -50 Delta Metal Thickness 2010 (5Hz) (%) 50 0 Joi 2a Metal Thickness 5Hz 40 60 10Hz Delta Metal Thickness 80 Bottom of 16" ' o,EM..E"s R~rded Magnetic Thickness ~ Data - 5Hz Pass i 4 A~c''~ ~-t ~ '~ 1 D-112 June 22, 2010 ' P°°AcrivE Diny+wsTic SERYICEs Database File: d:lwarriorldatalld-1121passes.db Dataset Pathname: 5HzPass ' Presentation Format: 18 Dataset Creation: Wed Jun 23 17:27:41 2010 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness (%) 50 1.8 0 Line Speed (ft/min) -200 -7 =-~ ~ - - -- Tree ' Line Speed Ha- s9er- - Pup ~ 5" Collar ~ ' 6% Metal Loss Pups ' .5" Collars 12% Metal Loss 20 - ' 3.5" Collar - - Delta Metal Thickness - ~ - 15°l° Metal Loss - ' Tubing Jt. 1 40 ' 7.625" Collar ' 3.5" Collar ~ ' 60 ' Tubing Jt. 2 ' 5% Metal Loss _~ Bottom of 16" Conducto 1 I I '- 7.625" Collar .5" Collar ~ ~ ~~ ~- MTTP01 (rad) MTTP12 (rad) 11.8 3 i~ o`E`"~E"$ R~rded Magnetic Thickness ~ Data - 8Hz Pass '~1 A Q4 ~c> F ' 1 D-112 June 22, 2010 PnoAcTivc Di.nymsric Scxviccs Database File: d:\warriorldatal1d-1121passes-db Dataset Pathname: 8HzPass ' Presentation Format: 26 Dataset Creation: Thu Jun 2410:00:36 2010 Charted by: Depth in Feet scaled 1:150 ' -50 Delta Metal Thickness (%) 50 2.6 0 Line Speed (ft/min) -200 -6.2 Tree - - - Line Speed Ha_ ~ger_ -~_ _ --- Pup ~ ~ -.>~ .5" Collar ~ - I -- ~ f 4% Metal Loss i Metal Loss Pups - ' .5" Collars ~6% Metal Loss 20 3.5" Collar j ~ i Delta Metal Thickness -,-- 8% Metal Loss ' - Tubing Jt. 1 - 40 ~- ~~- 7.625" Collar--- ~ .5" Collar ~ ' 60 Tubing Jt. 2 i - 6% Metal Loss Bottom of 16" Conductor -- 7.625" Collar 3.5" Collar 1 MTTP01 (rad) 12.6 MTTP12 (rad) 3.8 r-~ 'a'~€lA.;~[2.; R~ . ~~ ~~_„ ~w_..,..,~ ... ~:c~4fil~~~"~ ~3~~~C~4,~~~lpP°1 OF EQ~ft~NC~i~` €~ti~#~.~. ~ ~~~JN ~~.~ t 4 ' g .~,.~. 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[-~X SC~`:+r3 r6 M.-~'p'~k.~~v+~g ~,'8~~ :~' ~., w .~. v .~i # 4 ~n ~ ~ E i<F~.L ~ e.~3t.. ;:fa ~ . . 1 ~~.. ~ (1 ~~' ~ - i f ~v ~~ ~ ~ t f?C~tt3~~~ ft~?tf~ ~4~v "'I 3 ~~ a ~l ~ 7 ~~ 9 >~~w. t ' ~ tg ~ 3 a -Y ; ~,Fi 4.~k~$~'# ifi~~'L.Ii.~i.~ai~ v.~r}:i ~: t a2Ler~ ~L~~`1?~i i~ ~w . g g T ~ ..#L,. f 1^r~..7 ~# r~n9~tEltt i4~lpttx a~ 11~ ~~tM~~~ vMi~ tS.~~ ~~~~~ _ 9 '€_E~~/tti~~ ~1~C~7~f,~t 4.. ~Ft~~~(~`tiTk3~ _. ~ ...o .,. «., „M .,._,_ -~~,,.,,.,~,,...e.:..._..m......,.,. .:. ..........,,,,_.~..-......~.... ._. __ .. Na. `' aaYi~S . ®• ~,~~ M pp ~~ ~ y ~ + 4 g jai # ~+~t~: In~~d~ Tu'~f~~~r~ Llr-e R+~#rl+~y~~1e Pt~r~i~ S~ees ~ ~ ~~ f ' ; ~ ~ .~--.. _ __ _ _ _~._....t.,.~_ Pack tit Asst ~~.~ - .._...~v . «.,... ..... '!gym c4" t~rm~ ~~ ~ ~ ~~°? _._,._._r ...._:.,..,_M,,, _, t~ t E~kcat `C~rcjvrai i'~1C" t'c~cMcr~r ~ ]3~t3° ,..,! ' ~'~fi~at' Hl~~d_t Yta~e ~~x~ 6r~t ~ ~~~~_e~r~ ~~r°~~ ~ d3 = ~,~~ 4n `3t _ C~nt~llf~ _ R~yrh~nn „~. a.~ ~.,~ ~ ~ A` ~lat~}uc~tcl~ - 5l~ :i.:a" La ~ ~~~~ - ...,.,,v ~ ~-__., ~' Fiat w.JC~tc~« ? ~e~~~cit~iGt~~s. ~_. ~ __.. ~~ .... ... ,n„_._, { Vii" ~nt9 Shay _ ~ ~;~ i~.~, ~ ~arad~ to ~+ ~~n~-m ~ ~c~r~rrt~,tt 173 ~~~ca~~...~.,_, ~~~~ ~#ti~ ~ ~K t~~~ ~3K bra ;~~~ ~i:~~. _ _ y} ~y {~ ...r=='s.afew~w.r+~-raw^r~"°r 1~{'4A 1 ~ 1 ii~~ tkw~1 k~P .G.~ d! d i Yv: d~ 5vx.. ~. ~~Cr ~ ~ ~~` ~ ~ ~.~~ `~i., h ~.~."!~" #'(~~~~~t1 tC.3kJl31V C16C9~} ,,,~.,,--~ ,.-~^--M < ~ ~.., r ~4~''i M~C~ ~~ ~d~C~ C?t~ ~a~~ ("f,}f1ff. 1~:1+6~.., s„ ) ) Tom, Here is the well orientation plot for the 1320 requested on 1E-114. Also, included are the cementing reports for each one of these wells. Six wells were seen -to intersect the 1320 plot: 1E-168 v ~).Ö ,-\,.:)0 ¿) 1E-123'/ ;Jù4 -.. 0 '\. ~ ~. \i:.~o\ Oú.:\~ Çj;'1~ ~-O l_~ 1D-116 '''''.\~~5- \. "l.J 1D-113~ '~~'-\'~~ 1 D-112 , ~ ~~_. \ <6;' ~ 1D-I03'¿ ';)'O?>.--Qq(J -<è~\~~\<{~) q/,S'-OL\ All the wells had good cementing operations with the exception of ID-I03. This was the well drilled two years ago and failed to get returns to surface. The bond log was suspect and we went ahead and performed a squeeze. The squeeze only took 9 bbls with fairly high squeeze pressures which told me that the cement was there but I think we may have run the bond log way to soon after the cementing operation (+/-48 hours, SLB recommends 72 hours). If you have any questions give me a call. Steve 263-4620 T~ ~\5 ~ðC~M.c:."\- >.Nû',. \\:'0"--\ û\ -\ ~ (:AL\(Q;\ O-L~SIè.S~~"" .\6\""" \-\1:-\ \£ -~" \ t: - \ \ ~ 1- l1. ~ - L:>. \~£ \ :0-\ ",~~~ ~ \ ~\'- ~..CT¡'\~ \---0-,,-> \")<èE:~' ? \O-L<£.2J\ ~ '\--~, VèS.r«\i~: ~~\ ('..... ~ \, \ v~ \\.~ \J'-J(.~~Q~\-'....(\~ .~ () \'<J-.JL O-cæF\-CLl, \G; \ \'-:~~("'~t ~ ' ßZ1v¿~ ~ ~ ~1 ~C-O :> SCANNEr) FER -~; , , ~ 3538 ,~ lJ 3598 I' Œ I Kuparuk IE Pad, IE-I68, lE-I68 VI I ¡ /" -if 3598 I Kuparuk ID Pad, ID-II2, ID-II2 V2 l " I.~' ", , . I i, I Kuparuk I E Pad, I E- q~, lE-114 l ,,,,, " , b.:~'ð1 , }I!' 't H ' , ....,\'1, ~¡ Ip " ';(,1( U " \"I,:.",<,'¡,',", ~788 ~:l1'ð'ð HJ 3778 ,1\: ~ . U ,(,:1'ð \PAI .../ "J¡"''ð U 3538 ,Ij Kuparuk IE Pad, IE-I68, IE-168L1 ~3 P U 347$:/ i1;¡~:/ ii,i{., ~.¿" )~,ì1 if v' ID Pad, ID-I13, ID-I13 V2 l ') l vt I Ku Kuparuk IE Pad, IE-123, IE-I23 V2 I 7000- YPh'itll* CÇÞnoco I IPS 6000- 5000- 4000- "2 ~ 0 0 0 :::.. 3000- ..-, ::S '€ 0 ~ ~ .£ ::s 0 r:/) 2000- 1000- 0-, "'" , 36 '\:::: ~,'78 .. :::It""''''''' Ir"y-sun *"'JIU. . iN" -~"V''''I''''- " "".L""IIIIU'" .,......"'..." )i ,/ //1 ~ ~ ,/ / I:! ,/ ,/ " / / / / / / ) , , "" ../ I Kuparuk ID Pad, ID-I03, ID-I03 VI I ¡: I. r 11 ANTI-COLLISION SETflNGS Interpolation Method:TVD Interval: 1.000 Depth Range From: 3478.000 To: 3788.250 Maximum Range: 1376.200 Referen.e: Dermitive Survey / / 3718 I KUP~~~ruk I D Pad, I D-116, I D- ~~~i2 l, ,f ~ " , it , l'-. :~ , c ~,¡ 3598 ',"1-~ j 718 t 3538 . ~478 / "- Circles of 1320' Radius . . ",' ,,;,~~~~~~y;::- ,"" Ku aruk IE Pad, l~ Kuparuk IE Pad, IE-33, lE-33 V2 III ~ (d " I Kuparuk l.E .4, IE-24A V1 ", I I ~< -~ I 'ì 4000 5000 6000 7000 W est( - )/East( +) [I OOOftlin] I 8000 ') -) ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-112 1 0-112 ROT - DRILLING Parker Drilling Parker 245 Date From - To Hours Code Sub Phase Code 9/18/1998 00:00 - 12:00 12.00 DRILL DRLG PROD 12:00 - 00:00 12.00 DRILL DRLG PROD 9/19/1998 00:00 - 00:30 0.50 DRILL DRLG PROD 00:30 - 01 :30 1,00 CIRC PROD 01 :30 - 04:30 3.00 TRIP PROD 04:30 - 05:00 0.50 PULD PROD 05:00 - 06:00 1.00 PULD PROD 06:00 - 06:30 0.50 RIGMNT RSRV PROD 06:30 - 10:00 3,50 DRILL REAM PROD 10:00 - 10:30 0.50 CIRC PROD 10:30 - 12:00 1.50 DRILL DRLG PROD 12:00 - 21 :30 9.50 DRILL DRLG PROD 21 :30 - 22:30 1.00 LOG PROD 9/20/1998 22:30 - 23:30 1.00 LOG PROD 23:30 - 00:00 0.50 LOG PROD 00:00 - 01 :00 1.00 CIRC PROD 01 :00 - 12:00 11.00 DRILL DRLG PROD 12:00 - 00:00 12.00 DRILL DRLG PROD 00:00 - 01 :00 1,00 DRILL DRLG PROD 01 :00 - 02:30 1.50 CIRC PROD 02:30 - 07:00 4.50 TRIP PROD 07:00 - 08:00 1.00 PULD PROD 08:00 - 08:30 0.50 PULD PROD 08:30 - 12:00 3.50 TRIP PROD 12:00 - 12:30 0.50 TRIP PROD 12:30 - 17:00 4.50 CIRC PROD 17:00 - 23:00 6.00 TRIP PROD 23:00 - 00:00 1.00 PROD 00:00 - 00:30 0.50 PROD 00:30 - 14:30 14.00 PROD 9/21/1998 9/22/1998 14:30 - 17:30 CIRC PROD 3.00 17:30 - 20:30 3.00 PROD Page 1 of 4 Spud Date: 9/17/1998 End: 9/25/1998 Group: Start: 9/17/1998 Rig Release: 9/25/1998 Rig Number: 245 Description of Operations Hold PJSM= Drill F/267' to 1930' ( TVD 1378')= ADT 8.85 Hold PJSM= Drill F/1030' to 4090' ( TVD 2235')= ADT 8.25= Total Hrs. on Bit 17.10 Hold PJSMDrill F/4090' T/4185' (TVD 2262')= ADT 0.53 Circulate & Clean Hole= Pump Pill TOOH= Pumped out F/3525' T/3336'= Tight Hole F/1174' T/992' Change-Out 9 7/8" Bit= Change Angle on Navidrill Grease & Download Recording Tool Lube Rig Trip In= Ream in Hole tight@ 992' to 1174'= Circ. & Ream F/3145' T/4185' Circulate-Bottoms Up Drill F/4185' T/4468, (TVD 2375')= ADT 0.79 PJSM= Drill F/4468' T/5931'= TVD3012' . Lost Returns @ MD 5931'/ TVD 3012'= Pull 5 Stands Drill Pipe T/ get returns=Returns established Lost Returns, Possibly hole breakdown due to excessive hydraulics Pick up PWD tool where hole conditions may indicate an instability problem Circ. Bottoms/Up @ 5424' See above See above TIH= Wash & Ream Slow See above See above PJSM= Circulate & Condition Mud & Hole Drill F/5931'- T/7226'=(TVD3604')= ADT 7.57 PJSM= Drill F/7226' T/8150'= (TVD 4053')= ADT 9:00 PJSM Drill F/8150' T/8250' TD (TVD 4104') ADT 0.95 Circulate & Condition Mud & Hole= Pumped 30% over Bottoms up strokes TOOH Download Formation Recording tool & Lay down BHA P/U Hole opener & New BHA TIH= Fill every 20 Stands Complete TIH Circulate & Condition Mud & Hole= Pump Low-Vis Sweep= Back @ 42 BBls over Calculations= Monitor= Pump Slug TOOH= Slight swabbing @ 8000' T/5046'= Slight Swabbing @ 5046' & 4854'= UD Hole Opener-Bit Sub- & 2 Stab PJSM W/GBR-ARCO-Parker= Rig-Up to run 7 5/8" casing Held pre-job safety meeting. Run 7-5/8" casing. Land casing on hanger with shoe at 8231' MD & stage tool at 3081' MD. Circulated casing periodically. Used some top drive weight to push casing most of the way in the hole below EOC, up to 20K#. Circulate to condition mud & hole for cementing. Reduce vise from -200 see to -90 sec. Circulated 2200 Bbls, 11.4 BPM, 1150 psi. Reciprocated pipe while circulating, 300K# Up, 11 OK# Down (75K# Blocks). 1 st Stage Cement Job: Dowell prime up & flush line with 5 Bbls water; Test line to 3500 psi; Pump 20 Bbls ARCO wash & 40 Bbls ARCO 10.5 ppg spacer; Mix & pump 204.9 Bbls, 260 sx, 10.5 ppg AS III LW Lead Cement, 7.9 BPM, 350 psi; Load & drop bypass plug; Mix & pump 98 Bbls, 470 sx, 15.8 ppg Tail Cement (Class G + 1% CaCI + Adds.), 5.8 BPM to 6.8 BPM, 350 psi to 100 psi; Load & drop shut-off plug; Chase plug with 25 Bbls wash-up water, 7.6 BPM, 80 psi; Switch to rig pump & finish dispacement with mud, 7.6 BPM, 200 psi to 1200 psi; Bumped Printed: 2f7/2005 9:08:15 AM ) /JJ~//;2 ..~ ~JP ARCO Alaska, Inc. AFC No. I Date AK9573 09/22/98 Well: 1D-112 Contractor: PARKER Rig Name: RIG # 245 Operation At 0600: NU BOPE Upcoming Operations: Clean Out to PBTD, USIT Log MUD DATA MUD TYPE SPUD WEIGHT 9.8ppg VISCOSITY 86sqc PVIYP 36/29 GELS 7/20/ APIWL 3.2 HTHP WL ml/30 min SOLIDS 10.5% HOLE VOLUME 379bbl MBT 15.0 ph 7.9 LGS 9.9% PIT VOL 550 DAILY MUD $525 TOTAL MUD $57439 COMPANY BAROID BHADESCRIPTION BHA NO BHA LENGTH DATE LAST INSPECTED: HOURS ON JARS: TIME I END 00:00 00:30 00:30 14:30 14:30 17;30 Rpt No 6 Depth (MDITVD) Daily Cost $ 159992 Last Csg: 7 5/8" Casing I Rig Accept - hrs 09/17/9812:00:00 8250/4104 Prey Depth MD: 8250 Cum Cost $ 673565 Next Csg: 3.5" Tubing SERVICE PERSONNEL TOTAL I BHA #3: 9-7/8" Hole Opener + BS + NM Stab + NM DC + NM Stab + 2 NM DC + 6 SDC + XO + 4 HWDP + Jars (#04376 UJ) + 40 HWDP DRILLPIPE DATA GRADE CONNECTION 5-135 4" F.H. HWDP 4" F.H. DRILLING DATA BIT DATA DEPTH BIT NO. BIT NO ROTWT SIZE SIZE PUWT MAKE MAKE SOWT TYPE TYPE AVG DRAG SERIAL NO SERIAL NO MAX DRAG DEPTH OUT DEPTH OUT TRO BTM DEPTH IN DEPTH IN TRO OFF FOOTAGE FOOTAGE PUMP PRES ADT/AST ADT/AST III / / PUMP NO WOB2 WOB2 11213\ LINER SZ RPM 1 RPM 1 5.5 I 5.5 \ 5.5 I SPM 1 TFA TFA III GPM2 JETS JETS III III1I 1II1I SPS 1 BIT COST BIT COST III SPP 1 III MUD WT 11\ DULL III GRADE \11 DULL 1\1 GRADE III 3 1649.87 OD 4" 4" ID 3.340" 2,688" 128.28 HOURS 0.50 OPS CODE CASG HOLE SECT PROD 14.00 CASG PROD 3.00 CIRC PROD Daily Drilling Report: 10-112 09/22/98 Days Since AccepUEst: 5.5 / 5.5 EH&S INCIDENT N EMPLOYER SPILL N TYPE VOLUME LAST SAFETY MTG 09/22/98 INJECTION INJECTION WELL 1R-18D SOURCE WELL 1D-112 RATE (bpm) PRESSURE (psi) INJECTION FLUIDS Water Base Muds 290 Cement 290 0 0 0 TOTAL VOL (bbl) 580 TOT FOR WELL (bbl) 7390 WEIGHT 14.00# 29.70# I PHASE OPS Casing and Cementing Casing and Cementing Casing and Cementing ) Daily Drilling Report Rig Relase - hrs: Progress: 0 Est Cost To Date $ 725000 Shoe Test: N/A DRILLS/BOP DATA LAST BOP/DIVERT LAST BOPIDRILL TST 0~21~8 09/17/98 LAST H2S DRILL 06/08/98 LAST CONFINED SPACE 07/15/98 LAST FIRE DRILL 09/14/98 LAST SPILL DRILL 09/08198 FUEL & WATER FUEL USED 1384 DRILL WATER USED - BBLS POTABLE WATER USED - BBLS 1250 100 WEATHER & PERSONNEL DATA TEMP OF 30 WIND SPEED 10 WIND DIRECTION 1350 CHILL FACTOR of 15.94 ARCO PERSONNEL CONTRACTOR PERSONNEL 32 MISC PERSONNEL 5 10 48 CLASS 2 PREM PREM LENGTH 44 I OPERATIONS FROM 0000 - 0000 Held pre-job safety meeting. Run 7-5/8" casing. Land casing on hanger with shoe at 8231' MD & stage tool at 3081' MD. Circulated casing periodically. Used some top drive weight to push casing most of the way in the hole below EOC, up to 20K#. Circulate to condition mud & hole for cementing. Reduce vise from -200 see to -90 sec. Circulated 2200 Bbls, 11.4 BPM, 1150 psi. Reciprocated pipe while circulating, 300K# Up, 110K# Down (75K# Blocks). Page 1 ) ') 17:30 20:30 3.00 CASG PROD Casing and 1st Stage Cement Job: Dowell prime up & flush line with 5 Cementing Bbls water; Test line to 3500 psi; Pump 20 Bbls ARCO wash & 40 Bbls ARCO 10.5 ppg spacer, Mix & pump 204.9 Bbls, 260 sx, 10.5 ppg AS III LW Lead Cement, 7.9 BPM, 350 psi; Load & drop bypass plug; Mix & pump 98 Bbls, 470 sx, 15.8 ppg Tail Cement (Class G + 1% CaCI + Adds.), 5.8 BPM to 6.8 BPM, 350 psi to 100 psi; Load & drop shut-off plug; Chase plug with 25 Bbls wash-up water. 7.6 BPM. 80 psi; Switch to rig pump & finish dispacement with mud, 7.6 BPM, 200 psi to 1200 psi; Bumped plug at 350 Bbls mud, slowed to 5 BPM to bump; Reciprocated pipe until 89 Bbls of Lead cement had rounded the shoe, then landed on hanger; Full returns throughout; Floats held; 1st Stage CIP @ 2010 hrs. 9/22. 20:30 21:30 1.00 CIRC PROD Casing and Pressure up & stage tool at 3081' MD opened at 2650 psi. Cementing Circulated hole clean through stage tool. Had contaminated mud/spacer returns at suñace at start of circulation. Circulated out and dumped a total of 164 Bbls of cement and contaminated mud. Continued circulating & reconditioned mud for 2nd stage cementing, 472 Bbls total, up to 7.2 BPM. 21:30 00:00 2.50 CASG PROD Casing and 2nd Stage Cement Job: Dowell pump 30 Bbls water ahead. Cementing 5.5 BPM. 200 psi; Mix & pump 333 Bbls, 425 sx. 10.5 ppg AS III LW Lead Cement, 5.5 BPM. 50 psi to 275 psi - had contaminated muddy water returns at 245 Bbls, contaminated cement returns at 285 Bbls. 10.5+ ppg cement returns at 325 Bbls Lead pumped. switched to Tail at 333 Bbls; Mix & pump 10 Bbls, 60 sx, 15.7 ppg AS I Tail Cement, 3.9 BPM, 300 psi; Drop closing plug & chase with 25 Bbls wash-up water, 7 BPM, 300 psi; Switch to rig pump & finish displacement with mud, 6.8 BPM. 400 psi to 600 psi; Bumped plug at 118 Bbls mud; Pressured up to 2000 psi. OK - Stage Tool closed at 1150 psi; Floats held; Full returns throughout; Good 10.7 ppg cment returns to suñace; 2nd Stage CIP @ 2330 HRS. 9/22. 24.00 Supervisor: DON E. BREEDEN Daily Drilling Report: 10-112 09/22/98 Page 2 ) ..~ ~" ARCa Alaska, Inc. I Well Name: 1D-112 Rig Name: RIG # 245 Casing Size 7-518" Centralizers Comments: Mud Comments: Wash Comments: 0 Spacer Comments: 2nd Stage = Water Spacer Lead Cement 0 Comments: 0 Tall Cement 0 Comments: 1 st Stage = Class G +; 2nd Stage = AS I Displacement 0 Comments: Calculated top of cement: Cemented to Surface ) Hole Diameter: 9-7/8" Angle thru KRU: 66* Slant, 57,8* at TD Report Date: 09/22/98 AFC No.: AK9573 Shoe Depth: 8231' MD, 4094' TVD Cementing Details Report Number: 6 I Field: West Sak, Kuparuk LC Depth: I % washout: PBTD @ 8104' MD Stage Tool @ 3081' MD State type used, intervals covered and spacing 40 Gemoco 'Splraglider' Rigid Centralizers, 7-518" x 9-518": Installed 2 per joint on Jt #2 &. Jts #4 thru #22, on each side of a stop ring in the middle of each joint, TD to top 01 West Sak. 60 Gemoco Bow Spring Centralizers: Installed 1 on a stop ring on Jts #1 &. #3, 1 in the middle of the Marker Joint, 1 every 3rd Joint Irom there to surface, plus on on a stop ring in the middle 01 joint on each side 01 stage tool. Weight: PV(prior cond): PV(after cond): I YP(prior cond): U~ « ~ ~ Gels before: 9/28 Gels after: 7/20 YP(after cond): 29 Total Volume Circulated: 1st Stage = 2200 Bbls; 2nd Stage = 472 Bbls Volume: Weight: 8.34 ppg Type: ARCO Wash Type: ARCO Type: AS III LW Mix wtr temp: 70. F 1 st Stage = 20 Bbls; 2nd Stage = 0 Volume: 1 st Stage = 40 Bbls; 2nd Stage = 30 Bbls Water Weight: 10.5 ppg 18.34 ppg No. of Sacks: 260 sx 1425 sx Weight: 10.5 ppg Yield: 4.41 cis Type: G Mix wtr temp: 70* F Additives: Class G + 50% D124 + 30% D53 + 3.5% D« + 0.4% 046 + 1.5% d79 + 1.5% S1 Weight: 15.8 ppg 115.7 ppg I Rig Contractor: PARKER No. of Sacks: 470 sx I 60 sx Yield: 1.17 cis I 0.93 cfs Additives: 1st Stage: Class G + 1% S1 + 0.2% D46 + 0.3% D65 + 0.5 % D156 I 2nd Stage: Arctic Set I Rate(before tail at shoe): 7.6 BPM Reciprocation length: 15' Rate(tail around shoe): 7.6 BPM Str.WI.Up: 300 K# Reciprocation speed: 10 FPM Str. WI. Down: 110 K# (75 K# Blocks) Str. WI. in mud: 103 K# Theoretical Displacement: 1st Stage = 372 Bbls 12nd Stage = 141.5 Bbls CP: Date: 9/22/98 Time:23:30 hrs Remarks:1st Stage Cement Job: Dowell prime up &. flush lines with 5 Bbls water: Test line to 3500 psi: Pump 20 Bbls ARCO Wash: Pump 40 Bbls 10.5 ppg ARCO Spacer: Mix &. pump 204.9 Bbls, 260 sx, 10.5 ppg AS III LW Lead Cement, 7.9 BPM, 350 psi: Load &. drop bypass plug: Mix &. pump 98 Bbls, 470 sx, 15.8 ppg Tall Cement (Class G + 1% CaCI + Adds.), 5.8 BPM to 6.8 BPM, 350 psi to 100 psi; Load &. drop shut-off plug: Chase plug with 25 Bbls wash-up water, 7.6 BPY,80 psi: Switch to rig pump &. finish displacement with mud, 7.6 BPM, 200 psi to 1200 psi; Bumped plug at 350 Bbls mud, slowed to 5 BPM to bump: Reciprocated pipe until 89 Bbls of Lead Cement had rounded the shoe, pipe started getting sticky, then landed on hanger: Full returns throughout: Floats held: 1st Stage CIP @ 2010 hrs, 9/22/98. Actual Displacement: 375 Bbls I 143 Bbls Bumped plug: Yes Floats held: Yes Pressure up &. stage tool at 3081' MD opened at 2650 psI. Circulated hole clean through stage tool. Had contaminated mud/spacer returns at surface at start of circulation. Circulated out &. dumped a total of 164 Bbls of cement &. contaminated mud. Continued circulating &. reconditioned mud for 2nd stage cementing, 472 Bbls total, up to 7.2 BPM. 2nd Stage Cement Job: Dowell pump 30 Bbls water ahead, 5.5 BPM, 200 psi: Mix &. pump 333 Bbls, 425 sx, 10.5 ppg AS III LW Lead Cement, 5.5 BPM, 50 psi to 275 psi - had contaminated muddy water returns at 245 Bbls, contaminated cement returns at 285 Bbls, 10.5+ ppg cement returns at 325 Bbls Lead pumped, switched to Tall at 333 Bbls: Mix &. pump 10 Bbls, 60 sx, 15.7 ppg AS I Tall Cement, 3.9 BPM, 300 psi: Drop closing plug &. chase with 25 Bbls wash-up water, 7 BPM, 300 psi: Switch to rig pump &. finish displacement with mud, 6.8 BPM, 400 psi to 600 psi: Bumped plug at 118 Bbls mud; Pressured up to 2000 psi, OK- stage tool closed at 1150 psi: Floats held: Full returnsthroughout: Good 10.7 ppg cement returns to surface: 2nd Stage CIP @ 2330 hrs, 9/22/98. \cement Company: Dowell Approved By: Don E. Breeden Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ') ConocoPhillips Alaska Operations Summary Report 1 D-112 1 D-112 ROT - DRILLING Parker Drilling Parker 245 Date Sub From - To Hours Code Code Phase 9/22/1998 17:30 - 20:30 20:30 - 21 :30 21 :30 - 00:00 9/23/1998 00:00 - 03:00 03:00 - 03:30 03:30 - 06:30 06:30 - 07:00 07:00 - 07:30 07:30 - 10:00 10:00 - 12:30 3.00 PROD 1.00 CIRC PROD 2.50 PROD 3.00 PROD 0.50 NUND CMPL TN 3.00 NUND CMPL TN 0.50 WELCTL BOPE CMPL TN 0.50 2.50 2.50 CMPL TN TRI P CMPL TN CMPL TN 12:30 - 14:30 2.00 TRIP CMPL TN 14:30 - 16:00 1.50 CMPL TN 16:00 - 16:30 0.50 CMPL TN 16:30 - 17:00 0.50 TRIP CMPL TN 17:00 - 18:00 1.00 CMPL TN 18:00 - 21 :30 3.50 TRIP CMPL TN 21 :30 - 22:00 0.50 RIGMNT RSRV CMPL TN 22:00 - 00:00 2.00 TRIP CMPL TN 9/24/1998 00:00 - 01 :00 1.00 CMPL TN 01 :00 - 02:30 1.50 TRIP CMPL TN 02:30 - 04:30 2.00 CIRC CMPL TN 04:30 - 05:30 1.00 CMPL TN Page 2 of 4 Spud Date: 9/17/1998 End: 9/25/1998 Group: Start: 9/17/1998 Rig Release: 9/25/1998 Rig Number: 245 Description of Operations plug at 350 Bbls mud, slowed to 5 BPM to bump; Reciprocated pipe until 89 Bbls of Lead cement had rounded the shoe, then landed on hanger; Full returns throughout; Floats held; 1st Stage CIP @ 2010 hrs, 9/22. Pressure up & stage tool at 3081' MD opened at 2650 psi. Circulated hole clean through stage tool. Had contaminated mud/spacer returns at surface at start of circulation. Circulated out and dumped a total of 164 Bbls of cement and contaminated mud. Continued circulating & reconditioned mud for 2nd stage cementing, 472 Bbls total, up to 7.2 BPM. 2nd Stage Cement Job: Dowell pump 30 Bbls water ahead, 5.5 BPM, 200 psi; Mix & pump 333 Bbls, 425 sx, 10.5 ppg AS III LW Lead Cement, 5.5 BPM, 50 psi to 275 psi - had contaminated muddy water returns at 245 Bbls, contaminated cement returns at 285 Bbls, 10.5+ ppg cement returns at 325 Bbls Lead pumped, switched to Tail at 333 Bbls; Mix & pump 10 Bbls, 60 sx, 15.7 ppg AS I Tail Cement, 3.9 BPM, 300 psi; Drop closing plug & chase with 25 Bbls wash-up water, 7 BPM, 300 psi; Switch to rig pump & finish displacement with mud, 6.8 BPM, 400 psi to 600 psi; Bumped plug at 118 Bbls mud; Pressured up to 2000 psi, OK - Stage Tool closed at 1150 psi; Floats held; Full returns throughout; Good 10.7 ppg cment returns to surface; 2nd Stage CIP @ 2330 HRS, 9/22. LDLJ. Wash cement out of Diverter stack. NU Vetco Gray ESP tubing head, Test to 1000 psi for 5 minutes. NU BOPE. Test blind rams, last 3 valves on choke manifold, & all flanges against casing to 2000 psi for 10 minutes, OK. Testing BOPE by modified procedure approved by AOGCC. Witnessing of test waived by John Spaulding, AOGCC Field Inspector. Set wear bushing. MU BHA #4. RIH to 3071'. Test annular, inside choke & kill line valves against casing to 2000 psi for 10 minutes, OK. Drill out closing plug & stage collar at 3081'. Test lower pipe rams against casing & stage collar to 2000 psi for 10 minutes, OK. RIH, tag cement at 8062'. Drill out cement to plug in baffle collar at 8103' PBTD. Circulate hole clean. Test casing against upper pipe rams; HCR; & outside kill line valve to 3000 psi for 30 minutes; OK. POH. ARCO field wide safety stand-down. Held safety meeting with crew on shift; all service personnel; & camp staff in rig camp to discuss recent fatalities &; re-emphasize everyone's commitment to safe; accident free operations. POH. Service rig. MU casing scraper. RIH. Held safety stand-down with new crew & service company personnel in doghouse. RIH with bit & casing scrapers to PBTD @ 8103'. CBU. Displace mud from well with fresh water & circulate clean. Rig Electrician work on service loop to top drive. Rig Repair Keep up Printed: 217/2005 9:08:15 AM ) ) Page 3 of 4 ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 D-112 Common Well Name: 1 D-112 Event Name: ROT - DRILLING Contractor Name: Parker Drilling Rig Name: Parker 245 Date From - To Hours Code Sub Phase Code 9/24/1998 04:30 - 05:30 1.00 CMPL TN 05:30 - 07:30 2.00 TRIP CMPL TN 07:30 - 09:00 1.50 TRIP CMPL TN 09:00 - 10:00 1.00 CIRC CMPL TN 10:00 - 13:30 3.50 TRIP CMPL TN 13:30 - 14:00 0.50 CMPL TN 14:00 - 17:00 3.00 CMPL TN 17:00 - 18:00 1.00 CMPL TN 18:00 - 18:30 0.50 CMPL TN 18:30 - 19:00 0.50 RIGMNT RSRV CMPL TN 19:00 - 19:30 0.50 CMPL TN RUNT CMPL TN 19:30 - 00:00 4.50 CMPL TN RUNT CMPL TN 9/25/1998 00:00 - 01 :00 1.00 CMPL TN RUNT CMPL TN 01 :00 - 06:00 5.00 CIRC CMPL TN 06:00 - 07:00 07:00 - 09:00 09:00 - 09:30 09:30 - 11 :00 11 :00 - 12:00 12/8/1998 00:00 - 02:00 02:00 - 04:30 04:30 - 09:00 09:00 - 09:30 09:30 - 10:00 10:00 - 11 :30 11 :30 - 18:30 18:30 - 23:00 12/9/1998 23:00 - 00:00 00:00 - 01 :30 01 :30 - 03:00 03:00 - 04:00 04:00 - 05:00 05:00 - 06:00 06:00 - 07:00 07:00 - 14:00 14:00 - 15:00 15:00 - 00:00 1.00 WELLSR CMPL TN 2.00 CIRC CMPLTN 0.50 CMPL TN RUNT CMPL TN 1.50 1.00 NUND CMPL TN NUND CMPL TN NUND CMPL TN NUND CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN 2.00 2.50 4.50 0.50 RIGMNT RSRV 0.50 TRIP 1,50 CIRC 7.00 TRIP 4.50 1.00 1.50 1.50 1.00 1.00 1.00 1.00 7.00 CMPL TN CMPL TN TRIP CMPLTN CIRC CMPLTN TRIP CMPLTN CIRC CMPLTN TRIP CMPLTN CMPL TN 1.00 CMPL TN 9.00 CMPL TN Spud Date: 9/17/1998 End: 9/25/1998 Group: Start: 9/17/1998 Rig Release: 9/25/1998 Rig Number: 245 Description of Operations on PM POH to stage collar. RBIH to bottom. CBU, POH. LD bit & casing scrapers. Pre-job safety meeting with rig crew & SWS. RU SWS e-line. Run USIT Log from 8080' to surface. RD SWS, Slip & cut 131' off drilling line. RU to run tubing. Pull wear bushing. Service rig. Pre-job safety meeting on running tubing. Run 3-1/2" tubing for frac string. Run 3-1/2" tubing to 8103' PBTD, PJSM. RU & displace well to clean 3% KCI/Sea Water: Pump 50 Bbls fresh water spacer, 50 Bbls Caustic (10 ppb) with 'Hogwash', 25 Bbls fresh water, 33 Bbls hi-visc HEC (3 ppb), 50 Bbls fresh water, 290 Bbls clean sea water, 400 Bbls clean 3% KCI/Sea Water. 19 NTU final clarity. POH, LD 29 jts of tubing. RU lines. Reverse circulate 148 Bbls diesel into annulus. Let diesel U-tube into tubing until equalized for freeze protection. Diesel cap to 3470' MD, 2000' TVD. MU Vetco Gray 'frac' tubing hanger with I-wire penetration plugged. MU landing joint. Land tubing with mule-shoe at 7222' MD, (227 jts). NO BOPE. NU Vetco-Gray tree. Test packoff & tree to 5000 psi for 10 minutes. Pull test plug, Release rig. Rig Released @ 1200 hrs, 9/25/98. (moving to 10-110) RID circ. equip.=set bpv=n/d tree, PJSM=n/u 11" bope=pull bpv=install 2 way check. Test bope 250=3500# ok. PJSM=service rig. Bolds=pull hanger to floor=r/u circ. equip. CBU. Poh laying down 3-1/2" tbg. . Drain bop=remove kill & choke lines & riser==reposition rig=level rig & hook up killlines=choke lines & riser.=test lines. Install new piece in rotating head=hang riser. Secure riser above rotating head. Rih to 3011' & pick up kelly. Reverse circ.=clean hole of any debrie possibly left by killing well. Rih to 5459'. Reverse circ.=clean hole. PJSM=rih=tag fill @ 7201'. P/U kelly=make up rotating head rubber & kelly drive bushing=line up bop to accept kelly drive bushing in rotating head=clean out sand fl 7201 to 7379'. Blowed rubber in rotating head=change out same. Rotating Head. Incorrect equipment. Rubbers blowing prematurely. Rig down Rotating Head and locate correct equipment for next well. Cleaning out well fl 7379 to 7575'. ( surface lines plugging off wi iron debrie & large chunks of carbolite) rigged up new reverse line=plugged off existing line. Printed: 2nt2005 9:08:15 AM ) ) Page 4 of 4 ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 D-112 Common Well Name: 1 D-112 Event Name: ROT - DRILLING Contractor Name: Parker Drilling Rig Name: Parker 245 . Date From - To Hours Code Sub Phase Code 12/10/1998 00:00 - 01 :00 1.00 CMPL TN 01 :00 - 02:00 1.00 CMPL TN 02:00 - 22:30 20.50 CMPL TN 22:30 - 00:00 1.50 CIRC CMPL TN 12/11/1998 00:00 - 01 :30 1.50 CIRC CMPL TN 01 :30 - 06:00 4.50 TRIP CMPL TN 06:00 - 06:30 0.50 CMPL TN 06:30 - 08:00 1.50 TRIP CMPL TN 08:00 - 08:30 0.50 CMPL TN 08:30 - 14:30 6.00 TRIP CMPL TN 14:30 - 20:00 5.50 SUN CMPL TN 20:00 - 22:30 2.50 TRIP CMPL TN 22:30 - 23:30 1.00 CMPL TN 23:30 - 00:00 0.50 CMPL TN 12/12/1998 00:00 - 01 :00 1.00 CMPL TN 01 :00 - 06:00 5.00 CMPL TN RUNT CMPL TN 06:00 - 06:30 0.50 CMPL TN 06:30 - 21 :00 14.50 CMPL TN RUNT CMPL TN 21 :00 - 00:00 3.00 CMPL TN 12/13/1998 00:00 - 00:30 0.50 CMPL TN 00:30 - 02:00 1.50 NUND CMPL TN 02:00 - 04:00 2.00 NUND CMPL TN 04:00 - 08:30 4.50 CIRC CMPL TN 08:30 - 10:00 1.50 CMPL TN Spud Date: 9/17/1998 End: 9/25/1998 Group: Start: 9/17/1998 Rig Release: 9/25/1998 Rig Number: 245 Description of Operations Mill & reverse circ,=blew out last rotating head insert Remove insert & install riser. Rotating head. See previous comment See previous comment Clean out fl 7630 to 8075 dpm. (reverse out every jt wI annular preventer closed.) Reverse hole clean. Reverse circ. hole clean for completion. Monitor well=pull to top of perfs=monitor well=poh. PJSM=subject-fall protection. Service rig. Finish poh. Safety méeting on proper ppe useage. Rig up & pick up 228 jts. 3-1/2" 9.3# L-80 eue 8rd mod tbg. to 7170'. R/U slickline & run 2.80" drift=pump down wi 70# pressure to 7170. Poh wI drift & rig down same. Poh wI 3-1/2" tbg, Safety meeting on prper ppe for running completion. Rig down riser & pull insert out of rotating head. Finish changing out riser nipple=pull wear ring. PJSM=string centralift cable=p/u & mlu esp assembly wi sentry gauge=r/u slick line=set & test retrievable pump=set tbg. stop=r/d slick line. PJSM=service rig. Run completion as per program. Space out=hook up heat trace=splice esp cable & baker sentry gauge. Land tbg. hanger=rilds=set bpv, nld 11" bope=final test On esp=heat trace & bot cables. nlu tree=testsame to 5000# ok. Rig up circ. lines=freeze protect well=u-tube same. Clean pits=r/d circ. equip.=prepare fl rig move=release rig @ 10:00 hrs, Printed: 217/2005 9:08:15 AM ~ 0 :f',;tC' ¡¡ ";' ',', ;('J "- MICROFILMED 7/30/02 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAoGE Saved as M:/weepie/microfilm_marker.doc P½ LIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 May 3, 2001 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 1D-112 (198-183) Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the acid treatment operations on the KRU well 1D-112. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney Staff Engineer Phillips Drilling MM/skad RECEIVED ~Y 0 ~ ZOO1 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 15' FNL, 596' FEL, Sec. 23, T11N, R10E, UM 5. Type of Well: Development __X Explorato~___ Stratigraphic__ Service__ (asp's 560491, 5959649) 6. Datum elevation (DF or KB feet) RKB 41 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1D-112 At top of productive interval 682' FNL, 1035' FWL, Sec. 14, T11N, R10E, UM At effective depth At total depth 5227' FNL, 4631' FEL, Sec. 11, T11N, R10E, UM (asp's 556409, 5964964) 9. Permit number / approval number 198-183/ 10. APl number 50-029-22919 11. Field / Pool Kuparuk River Field / West Sak Oil Pool 12. Present well condition summary Total depth: measured true vertical 8250 feet 4104 feet Effective depth: measured 8075 feet true vertical 4012 feet Plugs (measured) Casing Length CONDUCTOR 121' PRODUCTION 8119' Junk (measured) Size Cemented 16" 9 cu yds High Early 7-5/8" 260 sx AS III LW, 470 sx Class G 425 sxAS III LW, 60 sx AS I Measured Depth True vertical Depth 121' 121' 8231' 4094' Perforation depth: measured 7324'-7364', 7454'-7484',7532'-7560',7668'-7698',7774'-7814' true vertical 3648'-3666', 3709'-3723', 3746'-3759', 3811'-3825', 3862'-3881' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tbg @ 7149' MD. Packers & SSSV (type & measured depth) No packer, No SSSV RECEIVED 0'4 Alaska Oil & Gas Cons. Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) see attached description Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Prior to well operation 221 36 5 Subsequent to operation 248 56 12 Casing Pressure Tubing Pressure 168 152 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Michael Mooney Title Staff Engineer Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE Date Comment 1D-112 Event History 05/20/00 PUMP 20 BBL XYLENE PREFLUSH/SOAK FOLLOW WITH 2 STAGES 7 1/2% HCL (TOTAL ACID VOLUME 200 BBLS) OVERFLUSH STAGES WITH TOTAL OF 300 BBLS 3 % KCL AND DISPLACE WITH 100 BLS DIESEL. AVG TREATING PRESSURE 600 PSI AT 3 BPM. NO SIGNIFICANT BREAKS WITH ACID AT PERFS.****READY FOR SOV AND FLOWBACK ..... [OTHER STIM] Page 1 of I 5/2/01 .........................................................................................198-183-0 ~-~tSi~-~"iS"~S'xk"-'iii'~ii~ .......................... ~02'""02922'~9i'9200 P'~iLms ai/As~ mc Roll #1: Start: Stop Roll #2: Start Stop MD 08250 TVD 04104 Completion Date: 12/12/98 Completed Status: 1-OIL Current: T Name Interval Sent Received T/C/D /~D 8758 1,2 SPERRY MPT/GR/EWR4 OH 10/28/98 10/28/98 t/&, DGR/EWR4-MD 1,2 121-8250 OH 11/4/98 11/4/98 O/'L DGR/EWR4-TVD 1,2 1214104 OH 11/4/98 11/4/98 ~'L USIT FINAL BL(C) 0-8080 CH 5 10/12/98 10/15/98 .~,~R SRVY CALC BH 121-8250. OH 2/11/99 2/16/99 ~'~"R SRVYRPT SPERRY 0-8250. OH 11/10/98 11/12/98 Thursday, January 18, 2001 Page 1 of 1 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 17, 1999 Mr. Robert N. Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1D-112 (Permit No. 98-183/399-195) Report of Sundry Well Operations Dear Mr. Commissioner: Enclosed is the Report of Sundry Well Operations for the recent workover operations on KRU 1D-112. If there are any questions, please call 265-6120. Sincerely, G. C. Alvord Drilling Engineering Supervisor Kuparuk Drilling ORIGINAL GCA/skad ' ' © STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Perforate _ Pull tubing Alter casing Repair well Other _X ESP change-out 2, Name of Operator: 5, Type of Well: 6, Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X. RBK 41' 3. Address: Exploratory ~ 7. Unit or Property: P.O. Box 100360 Stratagrapic ~ Anchorage, AK 99510-0360 Service ~ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 16' FNU 596' FEU Sec. 23, T11N, R10E, UN 1D-112 At top of productive interval: 9. Permit number/approval number: 682' FNL, 1035' FWU Sec. 14, T11 N, R10E, Uk 98-183 / 399-195 At effective depth: 10. APl number: 50-029-22919 At total depth: 11. Field/Pool: 50' FSU 650' FWL, Sec. 11, T11 N, R10E, Uk Kuparuk River Field / West Sak Oil Pool 12. Present well condition summary Total Depth: measured 8250' Plugs (measured) bridge plug @ 7830' true vertical 4104' Effective Deptt measured 7830' Junk (measured) true vertical 3899' Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 9 cu yds High Early 121' 121' Surface 8190' 7.625" 260 bbls AS IIILW & 8231' 4094' 470 bbls Class G Production Liner Perforation Depth measured 7324'-7364', 7454'-7484', 7532'-7560', 7668'-7698', 7774'-7&{~J' true vertical 3648'-3666', 3709'-3723', 3746'-3759', 3811'-3825', 3862'-3891' Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 @ 7149' Packers and SSSV (type and measured depth) Baker Gravel Pack SC1 packer @ 7203', No SSSV' ~ ~. ~ ~'~.~i'~..~'. ~!ti~': 13. Stimulation or cement squeeze summary Intervals treated (measured: N/A0RII INAL Intervals treated (measured) 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations __X Oil __X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge, Signed ,~~.~, ~/~'4' Title: ~"~,'~,k~,~ ~. ~,~.~,,~ Date L~{[~(~. Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICA~ Date: 10/22/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:iD-112W0 RIG:NORDIC 3 WELL_ID: 999417 TYPE: STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: WEST SAK BLOCK: SPUD:10/08/99 START COMP:10/08/99 FINAL: WI: 0% SECURITY:0 AP1 NUMBER: 50-029-22919-00 10/08/99 (C1) TD: 0' PB: 8103' 10/09/99 (C2) TD: 0' PB: 6990' 10/10/99 (C3) TD: 0' PB: 6990' 10/11/99 (C4) TD: 0' PB: 6990' 10/12/99 (C5) TD: 0' PB: 7830' 10/13/99 (C6) TD: 0' PB: 7830' 10/14/99 (C7) TD: 0' PB: 7830' NU & TEST BOPS MW: 8 7 3KCLSW SUPV:D GLADDEN / R. OVERSTREET Move off well 1D-108 and move to 1D-112. Accepted rig 0930 hrs. Pump hot diesel and seawater down tubing. CLEAN FLOOR OF CRUDE OIL MW: 8 7 3KCLSW SUPV:D GLADDEN / R. OVERSTREET Pump hi vis pill. ND tree. NU BOPs and test. PJSM. POOH w/tubing, ESP cable and heat trace. TIH W/ BRIDGE PLUG MW: 8 7 3KCLSW SUPV:D GLADDEN / R. 0VERSTREET Finish pulling tubing. Run 6.25" magnet to recover bands. Set test plug. PJSM. Tag ~ 7793'. Cleanout ~ 7793'-7830' PUMPING WELL BORE CLEANUP MW: 8 7 3KCLSW SUPV:D GLADDEN / R. OVERSTREET Continue to cleanout to 7829'. TIH w/bridge plug. Set bridge plug @ 7830'. TIH w/tandem casing scrappers. RUNNING GRAVEL PACK SCREE MW: 8 7 3KCLSW SUPV:P LOCKWOOD / S. GOLDBERG Hold safety meeting. Pump caustic wash. Pump Xanvis, brine and HC1. RIH w/gravel pack screen assembly. RUNNING SLICKLINE ESP MW: 8 7 3KCLSW SUPV:P LOCKWOOD / S. GOLDBERG RIH with gravel pack screens on 3.5" workstring. Set packer at 7203'. PJSM. Start gravel pack procedure. SPLICING ESP POWER CABLE MW: 8.7 3KCLSW SUPV:P LOCKWOOD / S. GOLDBERG PJSM. Run pump. Test packoff to 500 psi. No test. C/O packoff and re-test. Test packoff successfully to 500 psi. Install test plug and test to 3000 psi successfully. RIH with 3.5" tubing. PJSM. Continue running in hole with tubing and test heat trace and sentry gauge. RECEIVED Date: 10/22/99 10/15/99 TD: O' PB: ?830' 10/16/99 TD: O' PB: 7830, ARCO ALASKA INC. WELL SLT~/MARy REPORT Page: 2 RIG RELEASED SUPV:p. LOCKWOOD / S. GOLDBERG Continue running COmpletion ~W: 8.7 3KCLSw trace, ESp and /-Wire. Test' Install Penetrator N/D BOpE. N/U tree and test to 250/5000 ~zY' Land tubing. all SUccessf,~_ s for heat protect. Clean rig. Psi. Freeze RIG RELEASED SUPV:p. LOCKWOOD / S. GOLDBERG MW: 0.0 Clean location. Release rig ~ 0200 hrs. 10/16/99 RECEIVED . . , ! IOV 0 t999 Oil & Gas Cons. Commi,~. AnchomD8 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other _X ESP change-out 2. Name of Operator ARCO Alaska, Inc. 3. Address P. ©. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 16' FNL, 596' FEL, Sec. 23, T11N, R10E, UM At top of productive interval 682' FNL, 1035' FWL, Sec. 14, T11N, R10E, UM At effective depth At total depth 50' FSL, 650' FWL, Sec. 11, T11N, R10E, UM 5. Type of Well: Development __X Exploratory __ Stratigraphic __ Service __ 6. Datum elevation (DF or KB feet) RKB 41 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1D-112 9. Permit number/approval number 98-183 10. APl number 50-029-22919 11. Field / Pool Kuparuk River Field / West Sak Oil Pool 12. Present well condition summary Total depth: measu red true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 8190' Production Perforation depth: measured 825O 4104 8103 4029 Size 16" 7.625" feet Plugs (measured) feet feet Junk (measured) feet Cemented 9 cu yds High Early ~'ISU DDIS/~ IIILW, 4/U OUlS 425 sx AS III LW, 60 sx AS I Measured Depth True vertical Depth 121' 121' 8231' 4094' OR!SlNA L 7324'-7364',7454'-7484',7532'-7560',7668'-7698',7774'-7814' true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 3648'-3666',3709'-3723',3746'-3759',3811'-3825',3862'-3881' 3.5", 9.3#, L-80 @ 7269' MD No packer, No SSSV ~aS~4~ 0ii & Gas Cons, Anchorage 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __X Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic __ 15. Status of well classification as: 14. Estimated date for commencing operation October 6, 1999 16. If proposal was verbally approved Name of approver Date approved Oil __X Gas __ Suspended __ Service __ 17. I hereby cedify that the foregoing is true and correct to the best of my knowledge. Signed ~ Title: Drilling Team Leader Randy Thomas FOR COMMISSION USE ONLY Questions? Call Mark Chambers 265-1319 Date Prepared by Sharon AIIsup-Drake Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test ~ Location clearance Mechanical Integrity Test__ Subsequent form required 10- ORIGINAL SIGNEDBY Approved by order of the Commi~ion Form 10-403 Rev 06/15/88 · Commissioner SUBMIT IN TRIPLICATE PRE-RIG WORK: West Sak 1D-112 GENERAL WORKOVER PROCEDURE 1. RU Slick Line Unit. RIH and pull Shear Valve from GLM @ 7151' leaving an open pocket. 2. Set BPV in tubing. 3. Prepare Location for Nordic Rig 3. 10. 11. 12. 13. 14. 15. GENERAL WORKOVER PROCEDURE: 1. MIRU Nordic Rig 3. Lay hard-line to tree. Pull BPV and VR plug. Load pits with 8.7 ppg filtered 3% KCL kill weight brine. Displace tubing and annulus with kill weight brine. SI well and monitor pressure to ensure well is dead. Set BPV. ND / NU and test BOPE. Screw in landing joint. POOH standing back 3-1/2" tubing and spooling up ESP Cable and Heat Trace. Load, strap and drift 3-1/2" drill pipe. RIH w/cleanout assembly PU 3-1/2" drill pipe off rack. Cleanout fill and POOH standing back 3-1/2" drill pipe. RIH w/bridge plug. Set bridge plug 15' below bottom perforation and POOH standing back 3-1/2" drill pipe. RIH w/muleshoe and dual scrapper assembly. Pump caustic wash and pickle. POOH standing back 3-1/2" drill pipe. PU and RIH w/gravel pack assembly. Set packer @ +/- 7214' and perform gravel pack. POOH laying down 3-1/2" drill pipe. RIH w/3-1/2" tubing and ESP Assembly. Space out heat trace and splice power cable and I-wire to penetrators. Land tubing hanger. RILDS, install two-way check and test tubing hanger. ND/NU/Test Freeze protect with diesel to +/- 2000' TVD. 16. 17. Lower Limit: 6.0 days Expected Case: 7.0 days Upper Limit: 9.0 days No problems encountered. Problems pulling ESP completion, cleaning out to PBTD or Gravel packing MAC 9/27/99 WEST SAK 1D-112 Workovr,'-' Proposed Schematic Standard Frac For Sand Control FFSC to FFSCGP ARCO Alaska, Inc. Depths are based on original RKB Parker 245 7-5/8" Marker Joint (+/- 50' Above Top Perforation) I I f Drillers TD @ 8250' MD 3-1/2" Vetco-Gray Tubing Hanger w/3-1/2" L-80 EUE 8rd Mod Pup Joint, ESP Power Cable Penetrator, Heat Trace Penetrator and TEC Wire Penetrator. 3-1/2" 9.3# L-80 EUE 8rd Mod Spaceout Pups as Required for Heat Trace. 16" 62.5# H-40 @ 120' MD Stage Tool @ 3081' MD Raychem Heat Trace @ +/- 3016' MD Directional KOP = 250' Max Angle = 69.15 Deg @ 4120' Avg Angle Thru W.Sak = +/- 61.50 Deg 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing to Surface. 3-1/2" x 1" Camco 'KBMM' GLM run open 6' handling pups installed on top and bottom. After the rig moves off location, the wells group will install a Shear Circulating Valve (pinned for 3000 psi Tbg / Csg differential). 1 Joint 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing. 1 Joint 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing. Baker Sentry BHP Gauge (attached to 2nd 10' Pup Joint above the Slotted Nipple). 10' Spaceout Pup 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing 10' Handling Pup 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing Centrilift ESPCP (components as listed below) w/bottom set @+/- 7,154' MD (total length = 26.8') Centrilift 3-1/2" Slotted Nipple. Centrilift 'I-I-C Changeover Centrilift Single Seal Section: GSB3 DB ILH6PSF Centrilift PC Pump and Flex Shaft Assembly: KUDU 80TP2000 Centrilift Gear Reduction Unit: 525 Series, 9:1 Centrilift Motor: 57 HP KMH 1315/26 Centrilift Motor Centralizer Baker Model SC-1 Packer @ +/- 7214' D-Sand Perfs: 4 SPF 7324' - 7364' Frac'd w/Carbolite and Prop Lock B / A4-Sand Perfs: 4 SPF 7454' - 7484' / 7532' - 7560' Frac'd w/Carbolite and Prop Lock A3-Sand Perfs: 4 SPF 7668' - 7698' Frac'd w/Carbolite and Prop Lock A2-Sand Perfs: 4 SPF 7774' - 7814' Frac'd w/Carbolite and Prop Lock Top of Sand Plug or Bridge Plug @ +/- 7829' PBTD @ +/- 8103' MD 7-5/8" 29.7# L-80 BTC Mod @ +/- 8231' MD MAC 10/1/99 WEST SAK 1D-112 Current Schematic Standard Frac for Sand Control ARCO Alaska, Inc. Depths are based on original RKB Parker 245 7-5/8" Marker Joint (+/- 50' Above Top Perforation) 3-1/2" Vetco-Gray Tubing Hanger w/3-1/2" L-80 EUE 8rd Mod Pup Joint, ESP Power Cable Penetrator, Heat Trace Penetrator and TEC Wire Penetrator. 3-1/2" 9.3# L-80 EUE 8rd Mod Spaceout Pups as Required for Heat Trace. 16" 62.5# H-40 @ 120' MD Stage Tool @ 3081' MD Raychem Heat Trace @ +/- 3016' MD Directional KOP = 250' Max Angle = 69.15 Deg @ 4120' Avg Angle Thru W.Sak = +/- 61.50 Deg 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing to Surface. 3-1/2" x 1" Camco 'KBMM' GLM run open @ +/-7151' MD. After the rig moved off location, the Wells Group installed a Shear Circulating Valve, pinned for 3000 psi Tbg / Csg differentia. I 1 Joint 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing. 1 Joint 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing. Baker Sentry BHP Gauge (attached to 2nd 10' Pup Joint above the Slotted Nipple). 10' Spaceout Pup 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing 10' Handling Pup 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing Centrilift ESPCP (components as listed below) w/bottom set @ +/- 7269' MD (total length = 26.8') Centrilift 3-1/2" Slotted Nipple. Centrilift -IFC Changeover Centrilift Tandem Seal Section: GSB3 DB IL H6PFS Centrilift PC Pump and Flex Shaft Assembly: KUDU 180ML2000 Centrilift Gear Reduction Unit: 525 Series, 9:1 Centrilift Motor: 57 HP KMH 1315/26 Centrilift Motor Centralizer D-Sand Perfs: 4 SPF 7324' - 7364' Frac'd w/Carbolite and Prop Lock B / A4-Sand Perfs: 4 SPF 7454' - 7484' / 7532' - 7560' Frac'd w/Carbolite and Prop Lock A3-Sand Perfs: 4 SPF 7668' - 7698' Frac'd w/Carbolite and Prop Lock A2-Sand Perfs: 4 SPF 7774' - 7814' Frac'd w/Carbolite and Prop Lock PBTD @ 8103' MD 7-5/8" 29.7# L-80 BTC Mod @ 8231' MD MAC 10/1/99 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL E~ GAS [--] SUSPENDED E~] ABANDONED~] SERVICE 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-183 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22919 4 Location of well at surface 9 Unit or Lease Name 16' FNL, 596' FEL, Sec. 23, T11N, R10E, UM '~' ' ........ ~-~-~-~':;.'-~,~ Kuparuk River Unit AtTop Producing Interval "~.~..)..,~,~,.. , , .... ~ ~~ I 10 Well Number 682' FNL, 1035' I=WL, Sec. 14, TllN, R10E, UM /~__~--//?-~ ._'~; ~b.~ : 1D-112 At Total Depth .. ~~,..~'~i~1~ 11 Field and Pool ...... - ' ..... 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. West Sak Oil Pool RKB 41', Pad 71'I ADL 25649 ALK 467 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. J 15 Water Depth, if offshore 16 No. of Completions 17-Sep-98 21-Sep-98 12-Dec-98I NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 8250' MD & 4104' 'I-VD 8075' MD & 4012' TVD YES xL~ NO U N/A feet MD 1544 APPROX 22 Type Electric or Other Logs Run GR/Res, GR/CCL, USIT 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5# H-10 SURF. 121' 24" 9 cu yds High Eady 7.625" 29.7# L-80 SURF. 8231' 9.875" 1) 260 sx AS III LW, 470 sx Class G 2) 425 sxAS III LW, 60 sxAS I 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 7269' N/A 7794'-7814' MD 3871'-3881' TVD 7668'-7698' MD 3811'-3825' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 7532'-7560' MD 3746'-3759' 'I'VD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7454'-7484' MD 3709'-3723' 'I'VD 7324'-7364', 7454'-7484', see attachments 7324'-7364' MD 3648'-3666' TVD 7532'-7560', 7668'-7698' .. , 4 spf 7794'-7814' 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 2/5/99[ Flowing Date of Test Hours Tested PRODUCTION FOF[OIL-BBL GAS-MCF WATER-BBL cHOKE'~iZE'~I'' GAS-.OIL RATIo I 2/8/99 4.00 TEST PERIOI3 13 0 24 100 I 24 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 0 0 24-HOUR RATE: 72 2 ~40 0 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 9. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top West Sak Sand 7299' 3636' Bottom West Sak Sand 8178' 4066' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Directional Survey :32' I hereby certifY that the f°reg°ing is true and c°rrect t° the best °f mY kn°wledge' ('"~'/~/--/'~"~'~z/"~'l J'~'~'~'~'"~'Signed'~~~'~'~ ~ , ~ Title%~¢~'~¢'~~'''~ ~'~~,,~/,~ DATE ~'~~/~ Prepared by Name/Number Sharon AIIsup-Drake/263-4612 ,- INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 1/14/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:ID-ii2 WELL ID: AK9573 TYPE: -- AFC: AK9573 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:09/17/98 START COMP:12/07/98 RIG:NORDIC % 2 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22919-00 09/17/98 (D1) MW: 9.4 VISC: 305 PV/YP: 42/62 APIWL: 6.4 TD: 267'(267) DRILLING SUPV:CUNNINGHAM/BREEDEN Accept rig @ 1200 hrs. 9/17/98. NU diverter and function test. Spud @ 1700 hrs., drill from 121' to 178' Diskflow pumps and flowline plugged w/gravel. Drill from 178' to 267' 09/18/98 (D2) MW: 9.7 VISC: 219 PV/YP: 42/57 TD: 4090' (3823) TOOH FOR BIT RUN SUPV:CUNNINGHAM/BREEDEN Drill from 267' to 4090' APIWL: 5.2 09/19/98 (D3) MW: 9.6 VISC: 235 PV/YP: 44/52 APIWL: 4.8 TD: 5931'(1841) DRILLING SUPV:CUNNINGHAM/BREEDEN Drill from 4090' to 4185'. Pumped out from 3525' to 3336', tight hole from 1174' to 992' Ream in hole tight from 992' to 1174'. Circ and ream from 3145' to 4185' Drill from 4185' to 5931'. Lost returns @ 5931' MD. Wash and ream slow. 09/20/98 (D4) MW: 9.5 VISC: 217 PV/YP: 46/57 TD: 8150'(2219) T.D. WELL @ 8250'= CBU= RUN 9 7/8" HOLE OPENER SUPV:CUNNINGHAM/BREEDEN Drill from 5931' to 8150' APIWL: 3.6 09/21/98 (D5) MW: 9.6 VISC: 201 PV/YP: 45/43 TD: 8250'(100) RUN 7 5/8" CASING SUPV:CUNNINGHAM/BREEDEN Drill from 8150' to 8250' TD. APIWL: 3.3 09/22/98 (D6} TD: 8250'( 0) SUPV:DON E. BREEDEN NU BOPE MW: 9.8 VISC: 86 PV/YP: 36/29 APIWL: 3.2 Run 7-5/8" casing. Pum 1st and 2nd stage cement. 09/23/98 (D7) TD: 8250' ( 0) SUPV:DON E. BREEDEN MW: 9.4 VISC: 48 PV/YP: 18/ 8 APIWL: 7.5 PULL BIT & CASING SCRAPER BACK TO STAGE COLLAR NU BOPE and test. Drill out closing plug & stage collar at 3081' Drill out cement to plut in baffle collar at 8103' PBTD. Safety stand-down meeting. Date: 1/14/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 09/24/98 (D8) TD: 8250' ( 0) SUPV:DON E. BREEDEN 09/25/98 (D9) TD: 8250' ( 0) SUPV:DON E. BREEDEN MW: 8.3 VISC: 0 PV/YP: 0/ 0 DISPLACING WELL TO CLEAN 3% KCL/SW APIWL: 0.0 Held safety stand-down meeting. Run USIT log. Run 3.5" tubing. MW: 0.0 VISC: RIG RELEASED 0 PV/YP: 0/ 0 APIWL: 0.0 Run 3.5" tubing to 8103' PBTD. Pump Hogwash. Freeze protect well. ND BOPE. NU tree and test to 5000 psi. Release rig @ 1200 hrs. 9/25/98. Date: 1/14/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 REMEDIAL AND COMPLETION OPERATIONS WELL:iD-ii2 WELL ID: AK9573 TYPE: AFC: AK9573 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:09/17/98 START COMP:12/07/98 RIG:NORDIC % 2 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22919-00 12/07/98 (Ci0) TD: 0' PB: 0' 12/08/98 (Cll) TD: 0' PB: 0' 12/09/98 (C12) TD: 8250' PB: 0' 12/10/98 (C13) TD: 8250' PB: 0' 12/11/98 (C14) TD: 8250' PB: 0' 12/12/98 (C15) TD: 8250' PB: 0' 12/13/98 (C16) TD: 8250' PB: 0' SUPV: NU BOPE AND TESTING. MW: 8.7 BRINE Move rig from 1D-113 to 1D-112 and rig up. Accept rig @ 1300 hrs. 12/7/98. RIH @ 5469. MW: 8.7 SUPV:M.C. HEIM N/D tree. N/U BOPE and test to 250/3500%. BRINE CLEANING OUT WELL @ 7780' SUPV:M.C. HEIM Clean hole of sand fro 7201' to 7575' MW: 8.7 BRINE POH TO RUN TBG. MW: 8.7 BRINE SUPV:M.C. HEIM Mill and reverse circ., blew out last rotating head insert. Remove insert and install riser. Clean out from 7630' to 8075'. Reverse hole clean. RUNNING 3-1/2" COMPLETION SUPV:M.C. HEIM Safety meeting. Run 3.5" tubing. MW: 8.7 BRINE PUMPING DIESEL F/ FREEZE MW:15.4 DOILW SUPV:M.C. HEIM Run ESP assembly. Set retrievable pump. Run completion. MW:15.4 DOILW SUPV:M.C. HEIM ND BOPE. NU tree and test to 5000#, OK. Freeze protect well. Release rig @ 1000 hrs. 12/13/98. Date 10/08/98 Upcoming E~ Well Name 1D-112 Job Num 1006981800.8 Service Type ELECTRIC LINE Unit Desc of Work PERFORATE "A2" SANDS Supervisor SCHWENDERMAN Contractor Key Person Complete [~ Successful Accident E~ Initial Tbg Press 0 Injury r-~ Initial Iht Csg Press 0 Spill E~ Initial out csg Press 0 Summary AFC AK9573 0 Prop 18WSTF Uploaded to S SWS-DECKERT FinaITbg Press 0 Final Int Csg Press 0 Final Out Csg Press 0 RAN 2-1/2" ENERJET, BH, 4 SPF, 0 DEG PHASED. RUN # 1 GUN 20' PERFORATED FROM 7814' - 7794' RKB. RUN PERF GUN # 2 PERFO 20' FROM 7794'- 7774' RKB. ALL SHOTS FIRED. [Perf] Date printed: 01/15/99 at: 14:29:26 Date 10/11/98 Upcoming E~ Well Name 1D-112 Job Num 1008981920.10 AFC AK9573 Prop 18WSTF Service Type PUMPING Unit 0 Uploaded to S Desc of Work FRACTURE STIMULATE A2 SAND Supervisor JORDAN Contractor Key Person DS-YOKUM Complete r~ Successful E~ Accident ~ Initial Tbg Press 23 Final Tbg Press 0 Injury E~] Initial Int Csg Press 60 Final Int Csg Press 0 Spill [~ Initial Out Csg Press 0 Final Out Csg Press 0 Summary A2 FRAC SCREENED OUT EARLY WITH 22,687 LBS PROPPANT PLACED IN PERFS, 8927 LBS PROP LEFT IN WELLBORE. WELL CLEA TO TT AT 7222'. [Frac-Refrac] Date printed: 01/15/99 at: 14:29:08 Date 10/13/98 Well Name 1D-112 Service Type PUMPING Desc of Work REFRAC A2 ZONE Supervisor KRALICK Complete [~ Accident ~ Injury ~] Spill [~ Summary Upcoming Job Num Unit 1008981920.10 Contractor Key Person Successful [~ Initial Tbg Press 250 Initial Int Csg Press 450 Initial Out Csg Press 0 DS-YOKUM REFRAC A2 ZONE W/SCREENOUT AT THE 7 PPG FLAT STAGE - 36,900# 16/20 BEHIND PIPE [Frac-Refrac] AFC AK9573 0 Final Tbg Press 800 Final Int Csg Press 500 Final Out Csg Press 0 Prop 18WSTF Uploaded to S Date printed: 01/15/99 at: 14:28:38 Date 10/15/98 Upcoming Well Name 1D-112 Job Num 1006981800.8 Service Type ELECTRIC LINE Unit 8305 Desc of Work PERFORATE A-3 SANDS Supervisor LIGENZA Contractor Key Person SWS-ELMORE Complete [~ Successful Accident I--I Initial Tbg Press 450 Injury I---I Initial Iht Csg Press 0 Spill E~] Initial out csg Press 0 Summary AFC AK9573 0 Final Tbg Press 475 Final Int Csg Press 0 Final Out Csg Press 0 PERFORATED A-3 SANDS FROM 7668' TO 7698'. TWO RUNS W/15' X 2 1/8" EJ GUNS, 4 SPF, O DEGREES PHASE. [Pert'] Prop 18WSTF Uploaded to S Date printed: 01/15/99 at: 14:26:41 Date 10/18/98 Well Name 1D-112 Service Type PUMPING Desc of Work FRAC A3 ZONE Supervisor KRALICK Complete [~ Accident ~ Injury ~ Spill [~ Summary Upcoming Job Num 1008981920.10 Unit AFC AK9573 0 Prop 18WSTF Uploaded to S Contractor Key Person Successful [~ Initial Tbg Press 0 Initial Int Csg Press 344 Initial Out Csg Press 0 DS-YOKUM FinaITbg Press 0 Final Int Csg Press 500 Final Out Csg Press 0 PUMPED A3 ZONE FRAC W/16/20 CARBOLITE - 45,143# TOTAL PUMPED - 29,043# IN PERFS - 19,623# IN PIPE (BEFORE REVERSE OU PRESS 6087 PSI DURING BREAKDOWN - 5.1# IN PERFS - 1258 ISIP (DATAFRAC) - 1794 PSI BHP [Frac-Refrac] Date printed: 01/15/99 at: 14:26:23 Date 10/26/98 Well Name 1D-112 Service Type PUMPING Desc of Work A3 SAND REFRAC Supervisor JORDAN Complete [~ Accident [~] Injury I--I Spill [~ Summary Upcoming Job Num 1008981920.10 Unit AFC AK9573 0 Prop 18WSTF Uploaded to S Contractor Key Person Successful ~] Initial Tbg Press 450 Initial Int Csg Press 370 Initial Out Csg Press 0 DS-GALLEGOS Final Tbg Press 450 Final Int Csg Press 370 Final Out Csg Press 0 A3 SAND REFRAC COMPLETE AS DESIGNED, FINAL TREATING PRESSURE 1843 PSI WITHOUT SCREENOUT OR PRESSURE OUT. 10 LBS TOTAL PROP PUMPED, 102,496 LBS IN FORMATION WITH 10 PPA AT PERFS. 991 LBS / 35' PROPPANT LEFT IN WELLBORE, SAN ESTIMATED AT 7690'. (A3 PERFS 7668' -7698'). MAX TREATING PRESSURE 5751 PSI DURING BREAKDOWN. [Frac-Refrac] Date printed: 01/15/99 at: 14:25:52 Date 11/02/98 Well Name 1D-112 Service Type ELECTRIC LINE Desc of Work Supervisor JOHNS Complete Accident Injury Spill Summary PERF A-4 SANDS Upcoming Job Num Unit 1006981800.8 Contractor Key Person Successful [~ Initial Tbg Press 0 Initial Int Csg Press 0 Initial Out Csg Press 0 PERF'ED A-4 SANDS 7532' TO 7560' WITH 4 SPF [Perf] SWS-JOHNSON AFC AK9573 0 FinaITbg Press 100 Final Int Csg Press 0 Final Out Csg Press 0 Prop 18WSTF Uploaded to S Date printed: 01/15/99 at: 14:25:22 Date 11/03/98 Upcoming E~ Well Name 1D-112 Job Num 1008981920.10 AFC AK9573 Prop 18WSTF Service Type PUMPING Unit 0 Uploaded to S Desc of Work 1D-112 A4 FRAC Supervisor JORDAN Contractor Key Person DS-GALLEGOS Complete [~ Successful [~ Accident [--] Initial Tbg Press 350 FinaI Tbg Press 0 Injury F-] Initial Int Csg Press 350 Final Int Csg Press 350 Spill [~ Initial Out Csg Press 0 Final Out Csg Press 0 Summary A4 SAND FRAC SCREENED OUT EARLY WITH 7 PPA AT PERFS. MAX TREATING PRESSURE 6445 PSI. 39,559 LBS PLACED IN PERFS, 6700 LBS PROPPANT LEFT IN WELLBORE WITH ESTIMATED FILL TOP AT 7300'. A4 PERFS 7532'-7560 Date printed: 01/15/99 at: 14:24:59 Date 11/10/98 Well Name 1D-112 Service Type ELECTRIC LINE Desc of Work PERFORATE B SAND Supervisor LIGENZA Complete Accident Injury Spill Summary Upcoming Job Num 1006981800.8 Unit 2128 Contractor Key Person SWS-JOHNSON Successful [~ Initial Tbg Press 350 Initial Iht Csg Press 0 Initial Out Csg Press 0 PERFORATE B SANDS FROM 7454' TO 7484'. 4 SPF. 0 PHASE. TAG FILL AT 7542'. [Perf] AFC AK9573 0 Final Tbg Press 350 Final Int Csg Press 0 Final Out Csg Press 0 Prop 18WSTF Uploaded to S Date printed: 01/15/99 at: 14:24:24 Date 11/12/98 Upcoming [~ Well Name 1D-112 Job Num Service Type PUMPING Unit Desc of Work 1008981920.10 Supervisor RIGGS Contractor Key Person Complete [~ Successful [~ Accident ~ Initial Tbg Press 500 Injury F-~ Initial Int csg Press 500 Spill E~ Initial out csg Press 0 Summary DS-YOKUM AFC AK9573 0 FinaITbg Press 750 Final Int Csg Press 750 Final Out Csg Press 0 Prop 18WSTF Uploaded to S 1 D 112 B SAND,PUMPED FRAC PER PROCEDURE. PUMPED 96091 # OF PROP WITH 68660 # OF 10 PPG TO PERFS MAX PRESSURE 6958 PSI. SCREENED OUT AS STARTED THE FLUSH. REVERSED OUT TUBING EXPECT TAG @ TT Frac-Refrac] Date printed: 01/15/99 at: 14:23:34 Date 11/16/98 Well Name 1D-112 Service Type ELECTRIC LINE Desc of Work PERFORATE D SAND Supervisor LIGENZA Complete [~ Accident ~ Injury !-I Spill ~ Summary Upcoming Job Num 1006981800.8 Unit 2158 Contractor Key Person Successful [~ Initial Tbg Press 250 Initial Int Csg Press 250 Initial Out Csg Press 0 ROJAS PERFORATE D SANDS FROM 7324' TO 7364' 2-1/2" SAFE E J, 4 SPF. 0 DEG PHASE. [Perf] AFC AK9573 0 Final Tbg Press 250 Final Int Csg Press 250 Final Out Csg Press 0 Prop 18WSTF Uploaded to S Date printed: 01/15/99 at: 14:23:08 Date 11/17/98 Upcoming I~1 Well Name 1D-112 Job Num Service Type PUMPING Unit 1008981920.10 Desc of Work FRAC 'D' SAND Supervisor SCHUROSKY Contractor Key Person DS-YOKUM Complete C~ Successful I~ Accident E~ Initial Tbg Press 444 Injury r-I Initial Int Csg Press 0 Spill I~1 Initial Out Csg Press 0 Summary AFC AK9573 0 Prop 18WSTF Uploaded to S Final Tbg Press 500 Final Int Csg Press 0 Final Out Csg Press 0 PUMPED 'D' SAND FRAC, TOTAL PROP PUMPED 86,383 LBS, WITH 86,050 LBS INTO PERFS. 333 LBS IN PIPE. 10 PPA OF 16/20 WITH PROPLOK COATING AT PERF. WITH MAX TREATMENT PRESSURE OF 4990 PSI.EST TOP OF FILL 13' ABOVE PERF AT 7324'. TIP SCR WAS NOTED. WELL REVERSED OUT WITH DIESEL. [Frac-Refrac] Date printed: 01/15/99 at: 14:22:49 i '1 SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-00853 Sidetrack N°. P&ge 1 of 3 Company ARCO ALASKA, INC. Rig Contractor & No. PARKER 245 Field KUPARUK RIVER UNIT Well Name & No. PAD 1D/1D#112/A2 Survey Section Name SPERRY SUN BHI Rep. WELL DATA Target TVD (F-r) Target Coord. N/S Slot Coord. N/S ' -16.00 Grid Correction 0.000 Depths Measured From: RKB J~ MSL~ ssE] Target Description Target Coord. EAN Slot Coord. ENV -596.00 Magn. Declination 27.390 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: lOOft~ 30m~ lomL-] Vert. Sec. Azim. 322.06 Magn. to Map Corr. 27.390 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Total Coordinate Build Rate Walk Rate Date Tool Vertical Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) . Right (+) Comment Type (Fr) (DO) (DD) (F-T) (ET) (FT) (F'l) (Per 100 ET) Drop (-) Left (-) MWD 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT ~ 17-SEP-98 MWD 121.00 0.00 0.00 121.00 121.00 0.00 0.00 0.00 0.00 0.00 8"MACH 1C-AKO-1.7 DEG. -- 18-SEP-98 MWD 175.00 1.00 263.00 54.00 175.00 0.24 -0.06 -0.47 1.85 1.85 *****GYRO***** 18-SEP-98 MWD 293.81 3.82 274.32 118.81 293.69 3.44 O. 11 -5.44 2.40 2.37 18-S E P-98 MWD 382.31 6.15 301.12 88.50 381.86 9.85 2.79 -12.44 3.66 2.63 30.28 -- 18-SEP-98 MWD 475.87 9.80 310.66 93.56 474.50 22.34 10.57 -22.78 4.14 3.90 10.20 -- 18-SEP-98 MWD 568.52 14.54 311.47 92.65 565.05 41.51 23.42 -37.48 5.12 5.12 0.87 -- 18-S EP-98 MWD 656.78 19.90 313.57 88.26 649.32 67.28 41.12 -56.68 6.11 6.07 2.38 18-SEP'98 MWD 748.15 24.86 314.08 91.37 733.78 101.70 65.21 -81.76 5.43 5.43 0.56 -- 18-SEP-98 MWD 838.78 29.79 314.49 90.63 814.27 142.91 94.26 -111.53 5.44 5.44 0.45 -i 18-SE P-98 MWD 930.13 36.51 314.80 91.35 890.71 192.42 129.35 -147.04 7.36 7.36 0.34 18-SEP-98 MWD 1021.38 44.70 315.35 91.25 959.93 251.32 171.38 -188.92 8.98 8.98 0.60 I8-SEP-98 MWD 1112.21 50.89 315.69 90.83 1020.92 318.13 219.37 -236.04 6.82 6.81 0.37 18-S EP-98 MWD 1203.05 53.19 318.40 90.84 1076.80 389.46 271.80 -284.81 3.46 2.53 2.98 ,- '~'~ 18-S EP-98 MWD 1293.98 56.32 318.46 90.93 1129.27 463.57 327.35 -334.08 3.44 3.44 0.07 18-SEP-98 MWD 1384.43 60.90 318.54 90.45 1176.37 540.61 385.16 -385.23 5.06 5.06 0.09 18-SEP-98 MWD 1474.75 67.54 318.06 90.32 1215.63 621.72 445.84 -439.31 7.37 7.35 -0.53 18-SEP-98 MWD 1654.86 69.56 319.05 180.11 1281.49 789.03 571.50 -550.25 1.23 1.12 0.55 18-SEP-98 MWD 1938.25 67.11 320.87 283.39 1386.11 1052.19 773.09 -719.69 1.05 -0.86 0.64 18-SEP-98 MWD 2129.33 66.81 318.13 191.08 1460.91 1227.83 906.78 -833.87 1.33 -0.16 -1.43 18-SEP-98 MWD 2410.85 66.00 314.25 281.52 1573.63 1484.40 1092.92 -1012.40 1.30 -0.29 -1.38 18-S EP-98 MWD 2695.55 65.68 317.03 284.70 1690.17 1742.49 1278.61 -1193.99 0.90 -0.11 0.98 18-SEP-98 MWD 2982.46 67.78 314.22 286.91 1803.53 2004.35 1466.94 -1378.32 1.16' 0.73 -0.98 18-SEP-98 MWD 3269.68 65.35 316.15 287.22 1917.76 2265.94 1653.82 -1564.07 1.05 -0.85 0.67 · II II I I~ I I SURVEY CALCULATION AND FIELD WORKSHEET Job 0451-00853 Sidetrack No, Page 2 of ! Company ARCO ALASKA, INC. Rig Contractor & No. PARKER- 245 Field KUPARUK RIVER UNIT Well Name & No. PAD 1D/1D#112/A2 Survey Section Name SPERRY SUN BHI Rep. WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -16.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS~ Target Description Target Coord. E/W Slot Coord. E/W -596.00 Magn, Declination 27,390 Calculation Method MINIMUM CURVATURE Target DirectiOn (DB) Build\Walk\DL per: lOOff~ 30mb-j lOm~] Vert, Sec. Azim. 322.06 Magn. to Map Corr. 27.390 Map North to: OTHER I I II I I II ! II SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) /S(-) ] E(+) /W(-) DL t Build (+) 'Right (+) Comment Type (FO (DD)--t (DO) (FO (FT) ....... !.F.._T)_ ............... (F~_~. ............ _(P~e?_~0__0_[_T)_ Drop (-) Left (-) 18-SEP-98 MWD 3552.95 66,80'-1' 316.24 283.27 2032.63 2523,51 1840.69 -1743.29 0.51 0.51 0.03 8"MACH 1C-AKO-1.7 DEGi 18-SEP-98 MWD 3837.25 66.96 319.79 284.30 2144,30 2784.27 2035,01 i -1918,16 1.15 0.06 1,25 19-SEP-98 MWD 4120,19 69.15 320.37 282,94 2250.03 3046.54 2236.27 -2086.55 0.80 0,77 0.20 --. 19-SEP-98 MWD 4406.11 66,19 322.76 285.92 2358,66 3310.95 2443.37 -2250.97 1.29 -1.04 0,84 8"MACH lC-AKO-1.3 DEG. -- 19-SEP-98 MWD 4688,67 64,97 322.59 282.56 2475.48 3568.21 2647.96 -2406.97 0.44 -0.43 -0.06 19-SEP-98 MWD 4977.53 67.06 320.89 288.86 2592,90 3832,10 2855,14 -2570.40 0.90 0.72 -0.59 19-SEP-98 MWD 5261.52 64.15 319.74 283.99 2710.19 4090.58 3054.18 -2735.51 1.09 -1,02 -0.40 __ -- 19-SEP-98 MWD 5357.24 63.1,6 320.50 95.72 2752.66 4176.31 3120.00 -2790.51 1.26 -1,03 0.79 19-SEP-98 MWD 5451.04 62,45 323,28 93.80 2795.54 4259.73 3185.63 -2842,00 2.74 -0,76 2.96 .. 19-sEp-98 MWD 5546.21 62.36 326.65 95.17 2839.63 4343.94 3254.68 -2890.41 3.14 -0.09 3.54 __- 19-SEP-98 MWD 5641.10 61.96 327.06 94.89 2883.95 4427.56 3324.93 -2936.29 0,57 -0.42 0.43 19-S EP-98 MWD 5735,38 63,48 330.05 94,28 2927.17 4510,80 3396.41 -2979.98 3.25 1.61 3,17 20-S EP-98 MWD 5927.46 61.86 330.12 192.08 3015.35 4679.76 3544.31 -3065,08 0.84 -0.84 0.04 jl~. 20-SEP-98 MWD 6115.33 61,81 331.29 187.87 3104.03 4843.50 3688.75 -3146.12 0.55 -0.03 0.62 -- 20-S EP-98 MWD 6307.48 62.64 331.07 192.15 3193.57 5011.36 3837.70 -3228.07 0.44 0.43 -0.11 20-SEP-98 MWD 6497.30 65.34 331.05 189.82 3276.80 5179.84 3986.98 -3310,62 1.42 1.42 -0.01 20-SEP-98 MWD 6686.08 64.01 331.00 188.78 3357.55 5348.39 4136.25 -3393.28 0.70 -0.70 -0.03 20-SEP-98 MWD 6878.55 62.51 331.77 192.47 3444.15 5518.00 4287.14 -3475.60 0.86 -0.78 0.40 20-S EP-98 MWD 7069.00 63.16 332.03 190.45 3531.10 5684.94 4436,61 -3555.41 0.36 0,34 O. 14 20-SEP-98 MWD 7258.01 62.89 331.00 189.01 3616.84 5851.10 4584.66 -3635.74 0.51 -0.14 -0.54 20-S EP-98 MWD 7447.15 61.36 331.38 189.14 3705.27 6016.17 4731.15 -3716.32 0.83 -0.81 0.20 20-S EP-98 MWD 7637.38 61.59 332.11 190.23 3796.11 6180.92 4878.37 -3795.44 0.36 0.12 0.38 20-SEP-98 MWD 7827.90 60.95 332.60 190.52 3887.69 6345.30 5026.36 -3872.95 0.40 -0,34 0.26 20-SEP-98 MWD 8018.26 59.18 333.12 190.36 3982.68 6507.34 5173.16 -3948.21 0.96 -0.93 0.27 I I I I ·"-literati SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-00853 Sidetrack No. Page 3 of 3 Ii=il£~-'l=/r-"~~I Company ARCO ALASKA, INC. Rig Contractor & No. PARKER-245 Field KUPARUK RIVER UNIT ._ Well Name & No. PAD 1D/1D#112/A2 Survey Section Name SPERRYSUN BHI Rep. WELL DATA Target'i-VD (FT) Target Coord. N/S Slot Coord. N/S -16.00 Grid Correction __0,000__ Depths Measured From: RKB ~ MSL ~ SS[- Target Description Target Coord. E/W Slot Coord. EAN -596.00 Magn. Declination 27.390 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: lOOft~ 30m~ lOm~ Vert. Sec. Azim. 322.06 Magn. to Map Corr. 27,390 Map North to: OTHER SURVEY DATA i -- Survey Survey Incl. Hole Course Total Coordinate Build Rate Walk Rate Date Tool Vertical Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (ET) (DD) (DD) (FT) (FT') (FT) (F-F) (Per 100 FT) Drop (-) Left (-) 20-SEP-98 MWD 8184.60 57.83 332.25 166.34 4069.58 6646,73 5299.18 -4013.29 0.93 -0.81 -0.52 PROJECTED TO TD -- 20-SEP-98 MWD 8250.00 57.83 332.25 65.40 4104.40 6701.22 5348.17 -4039.06 0.00 0.00 0.00 CLO.DIST=6702.01 AZ1=322.94 -- I __ _ ___. __ __ __ _ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 11, 1999 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1D-112 (Permit No. 98-183) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 1D-112. If there are any questions, please call 265-6120. Sincerely, T. W. Mc Kay Drilling Team Leader AAI Drilling TWM/skad Kuparuk Unit Kuparuk 1D ID-112 Job No. AKMM80379, Surveyed: 21 September, 1998 SURVEY REPORT 3 November, 1998 Your Ref: API-5002922g1900 Last Survey Date 2f-September-98 Job # AKMMS0379 KBE- 112.1' Surface Coordinates: 5959648.88 N, 560490.65 E (70° 18'01.1604' N, 149° 30'36.2962" W) --D R I L- L,., I N I~i ORIGINAL Survey Ref: svy84 Sperry-Sun Drilling Services Survey Report for 1D-112 Your Ref: API-500292291900 Job No. AKMM80379, Surveyed: 21 September, 1998 Kuparuk Unit Measured Depth (ft) Incl. Sub-Sea Depth (ft) 0.00 0.000 0.000 ~112.10 121.00 0.000 0.000 8.90 175.00 1.000 263.000 62.90 293.81 3.820 274.320 181.59 382.31 6.150 301,120 269.76 475.87 9.800 310.660 362.40 568.52 14.540 311.470 452.95 656.78 19.900 313,570 537.22 748.15 24.860 314.080 621.68 838.78 29.790 314.490 702.17 930.13 36.510 314.800 778.61 1021.38 44.700 315.350 847.83 1112.21 50.890 315,690 908.82 1203.05 53.190 318.400 964.70 1293.98 56.320 318.460 1017.17 1384.43 60.900 318.540 1064.27 1474.75 67.540 318,060 1103.53 1654.86 69.560 319,050 1169.39 1938.25 67.110 320,870 1274.01 2129.33 66.810 318.130 1348.81 2410.85 66.000 314,250 1461.52 2695.55 65,680 317.030 1578.07 2982.46 67.780 314.220 1691.43 3269.68 65.350 316.150 1805.66 3552.95 66.800 316.240 1920.53 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 0.00 0.00 N 0.00 E 5959648.88 N 560490.65 E 121.00 0.00 N 0.00 E 5959648.88 N 560490.65 E 175.00 0.06 S 0.47W 5959648.82 N ' 560490.18 E 293.69 0.11N 5.44W 5959648.95 N 560485.21E 381.86 2.79 N 12.44W 5959651.57 N 560478.18 E 474.50 10.57 N 22.78W 5959659.26 N 560467.79 E 565.05 23.42 N 37.48W 5959671.99 N 560452.98 E 649.32 41.12 N 56.68W 5959689.54 N 560433.64E 733.78 65.21 N 81.76W 5959713.43 N 560408.37 E 814.27 94.26 N 111.53W 5959742.24 N 560378.37 E 890.71 129.35 N 147.04W 5959777.04 N 560342.58 E 959.93 171.38 N 188.92W 5959818.73 N 560300.35 E 1020.92 219.37 N 236.04W 5959866.34 N 560252.86 E 1076.80 271.80 N 284.81W 5959918.37 N 560203.66 E 1129.27 327.35 N 334.08W 5959973.53 N 560153.95 E 1176.37 385.16 N 385.23W 5960030.93 N 560102.34 E 1215.63 445.84 N 439.31W 5960091.17 N 560047.77 E 1281.49 571.50 N 550.25W 5960215.93 N 559935.82 E 1386.11 773.09 N 719.69W 5960416.15 N 559764.76 E 1460.91 906.78 N 833.87W 5960548.92 N 559649.51E 1573.62 1092.92 N 1012.39W 5960733.62 N 559469.49 E 1690.17 1278.61N 1193.99W 5960917.84 N 559286.40 E 1803.53 1466.94 N 1378.32W 5961104.67 N 559100.56 E 1917.76 1653.83 N 1564.07W 5961290.06 N 558913.32 E 2032.63 1840.69 N 1743.29W 5961475.48 N 558732.60 E Dogleg Rate (°~'~OOft) 0.000 1.852 2.396 3.655 4.137 5.119 6.113 5.433 5.444 7.359 8.984 6.821 3.456 3.443 5.064 7.367 1.233 1.051 1.329 1.295 0.898 1.160 1.047 0.513 Vertical Section (ft) 0.00 0.00 0.24 3.44 9.85 22.34 41.51 67.28 101.70 142.91 192.42 251.32 318.13 389.46 463.57 540.61 621.72 789.03 1052.19 1227.83 1484.40 1742.49 2004.35 2265.94 2523.51 Kuparuk 1D Comment Continued,.. 3 November, 1998 - 9:31 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1D-112 Your Ref: API-500292291900 Job No. AKMM80379, Surveyed: 21 September, 1998 Kuparuk Unit Measured Depth (ft) Incl. Sub-Sea Depth (ft) 3837.25 66.960 319.790 2032.20 4120.19 69.150 320.370 2137.93 4406.tl 66.190 322.760 2246.56 4688.67 64.970 322.590 2363.38 4977.53 67.060 320.890 2480.80 5261.52 64.150 319.740 2598.09 5357.24 63.160 320.500 2640.56 5451.04 62.450 323.280 2683.44 5546.21 62.360 326.650 2727.53 5641.10 61.960 327.060 2771.85 5735.38 63.480 330.050 2815.07 5927.46 61.860 330.120 2903.25 6115.33 61.810 331.290 2991.93 6307.48 62.640 331.070 3081.47 6497.30 65.340 331.050 3164.70 6686.08 64.010 331.000 3245.45 6878.55 62.510 331.770 3332.05 7069.00 63.160 332.030 3419.00 7258.01 62.890 331.000 3504.74 7447.15 61.360 331.380 3593.17 7637.38 61.590 332.110 3684.01 7827.90 60.950 332.600 3775.59 8018.26 59.180 333.120 3870.58 8184.60 57.830 332.250 3957.48 8250.00 57.830 332.250 3992.30 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 2144.30 2035.01 N 1918.16W 5961668.38 N 558556.17 E 2250.03 2236.28 N 2086.55W 5961868.29 N 558386.16 E 2358.66 2443.37 N 2250.97W 5962074.05 N ' 558220.08 E 2475.48 2647.96 N 2406.96W 5962277.37 N 558062.45 E 2592.90 2855.15 N 2570.40W 5962483.24 N 557897.35 E 2710.19 3054.18 N 2735.51W 5962680.94 N 557730.64E 2752.66 3120.00 N 2790.51W 5962746.31N 557675.11 E 2795.54 3185.63 N 2842.00W 5962811.53 N 557623.10 E 2839.63 3254.68 N 2890.41W 5962880.18 N 557574.13 E 2883.95 3324.93 N 2936.29W 5962950.07 N 557527.69 E 2927.17 3396.41N 2979.98W 5963021.19 N 557483.43 E 3015.35 3544.31N 3065.08W 5963168.40 N 557397.14 E 3104.03 3688.75 N 3146.12W 5963312.19 N 557314.94 E 3193.57 3837.70 N 3228.07W 5963460.47 N 557231.79 E 3276.80 3986.98 N 3310.61W 5963609.08 N 557148.05 E 3357.55 4136.26 N 3393.27W 5963757.69 N 557064.19 E 3444.15 4287.14 N 3475.60W 5963907.90 N 556980.65 E 3531.10 4436.61N 3555.41W 5964056.72 N 556899.64E 3616.84 4584.66 N 3635.74W 5964204.12 N 556818.12 E 3705.27 4731.15 N 3716.31W 5964349.96 N 556736.37 E 3796.11 4878.38 N 3795.43W 5964496.54 N 556656.07 E 3887.69 5026.37 N 3872.95W 5964643.91 N 556577.36 E 3982.68 5173.16 N 3948.21W 5964790.09 N 556500.93 E 4069.58 5299.18 N 4013.28W 5964915.58 N 556434.84E 4104.40 5348.17 N 4039.06W 5964964.36 N 556408.67 E Dogleg Rate (°/~OOft) 1.150 0.797 1.292 0.435 0.901 1.089 1.255 2.743 3.140 0.569 3.247 0.844 0.550 0.444 1.422 0.705 0.857 0.362 0.506 0.828 0.358 0.405 0.959 0.926 0.000 Vertical Section (ft) 2784.27 3046,54 3310.95 3568.21 3832.10 4090.58 4176.31 4259.73 4343.94 4427.56 4510.80 4679.76 4843.50 5011.36 5179.84 5348.39 5518.00 5684.95 5851,10 6016.17 6180.92 6345.30 6507.34 6646.73 6701.22 Kuparuk 1D Comment Projected Survey Continued... 3 November, '1998 - 9:3'1 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1D-112 Your Ref: API.500292291900 Job No. AKMMS0379, Surveyed: 21 September, ~998 Kuparuk Unit Kuparuk 1 D All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 27.391 o (16-Sep-98) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 322.060° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8250.00ft., The Bottom Hole Displacement is 6702.01 ft., in the Direction of 322.939° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 0.00 0.00 0.00 N 0.00 E Tie-on Survey 8250.00 4104.40 5348.17 N 4039.06 W Projected Survey 3 November, 1998- 9:31 -4- DrillQuest sper r', j-sur ORII--I-IN G SER~./I C ~: S 10-Nov-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-112 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 8,250.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company 0 I:! I I--I--I N G SEI:IL/I C E S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs November 4, 1998 1D-112, AK-MM-80379 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1D-112: 2"x 5" MD Resistivity & Gamma Ray Logs: 50-029-22919-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22919-00 1 Blueline 1 Folded Sepia 1 Blueline ~-" :'-'~ 1 Folded Sepia ~ !'r 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500. Fax (907) 273-3535 A 13ro_q_qo.r Indu~tfi~.~_ Inc_ C~nnnnv 0 t:11 I_1... I I~,11~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs October 28, 1998 1D-112, AK-MM-80379 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of~ Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way,/tG, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22919-00 OCT Alaska Oil & Gas Cons. Commi~ ~orage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 10/12/98 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATrN: Sherrie NO. 11560 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: West Sak (Reservoir Analysis Logs) Well Job # Log Description Date Color RF Sepia Floppy Print Disk 1D-112 (Al) ~, t~ ~ 98512 USlT 980924 1 .... ., ,, SIGNED:~_ Please sign and return onb'copy of this transmittal to Sherrie at the above address. Thank you. DATE: RECEIVED OCT 15 1998 Alaska Oil & Gas Cons. Commission Anchorage TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION September 17. 1998 Tom McKay, Shallow Sands Team Leader ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re; Kuparuk River Unit 1D-112 ARCO Alaska, Inc. Permit No: 98-183 Sur Loc: 16'FNL, 596'FEL, Sec. 23. T11N, R10E, UM Btmhole Loc. 110'FSL, 476'FWL, Sec. 11. T11N, R10E, UM 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Dear Mr. McKav: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Kuparuk River Unit Well No. 1 D-112. 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 Drill Site 1D must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit 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 for a period longer than one year. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 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 mav be given bv contacting the Commission__p__~troleum field inspector on thc North Slope pager at 659-3607. David W. Johns[~n Chairman BY ORDER OF THE COMMISSION dlffEnclosurcs CC~ Department of Fish & Game, Habitat Section w/o cncl. Department of Environmental Conservation w/o cncl. , ~. STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION COMMI'S~ION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Ddll X Reddll lb Type of Well Exploratory Stratigraphic 'f~$~f¢~ Uti ~. "{¢rb~v~e'1'(y[~TT~-~'Oil X Anc~0ragu Re-Entry Deepen Service Development Gas SingleZone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 71' feet Kuparuk River Field 3. Address 6. Property Designation West Sak Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25649, ALE 467 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 16' FN-L, 596' FEL, Sec. 23, TI IN, R]0E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 481' FNL, 930' FWL, Sec. 14, TllN, RIOE, UM 1D-112 #U-630610 At total depth 9. Approximate spud date Amount 110' FSL, 476' FWL, Sec. l 1, TI 1N, R10E, UM 9/17/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1D-03 8331' MD 110' @ TD feet 12.9' @ 378' feet 2560 4119' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 250' feet Maximum hole angle 64.74° Maximum surface 1412 psig At total depth (TVD) 1856 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 77' 41' 41' 118' 118' +_200 CF 9.875" 7.625" 29.7# L-80 BTC MOB 8290' 41' 41' 8331' 4119' 739 Sx Arcticset III L & 625 Sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: truemeasuredvertical ilex-I'~ [~" ¢ [ "t,.? ix 20. Attachments Filing fee X Property plat BOP Sketch X DiverterSketch X Drilling program X Ddlling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct tot~e best of my knowledge '~/~r"_--/" ¢' ~'~ '-"~ ~ ~~, Y~/'.~.-~ ~. ~,f~ Team Date ~:; ' & Title Signed , ' ~/"/ Shallow Sands Leader ~ Commis~on Use Only Pe rmi~¢b?~,l¢,2 I A,I number (/ letter for -- 50- O 2.-~..-" ~.~ ~.,..-~_/,/ ~ IApprovaldatO ¢"~ //V - ~¢ Iseec°verother requirements Conditions of approval Sample's required roes ~_.,¢- Mud Icg required Yes sulfide measures Yes (~ Directional survey required Hydrogen No Required working pressure for BOPE 2M ~ 5M 10M 15M Other: Original Signed johnston David W. by order of ~.~ Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate ARCO Alaska, Inc. Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor Sept 3, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill West Sak 1 D-112 West Sak Phase lB Development Well, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the West Sak interval from 1D pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the West Sak sands in the vicinity of 1 D pad. The well is designated as a monobore production well using a single 7 5/8" casing string, with 3-1/2" tubing. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). Note the 40 acre spacing requirements governed by the West Sak Pool Rules. 4) Directional plots and proximity calculations in'accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). Note that due to the pressures expected in the West Sak sands, ARCO proposes to test the 5000 psi BOP equipment to a maximum of 3000 psi, pending AOGCC approval per this letter and APD. Please note that due to the large number of KRU and West Sak wells which have penetrated the West Sak sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at WS 1D-112, such as shallow gas. There have been ten (10) Kuparuk wells and (22) West Sak wells drilled from KRU 1D pad, and no occurrences of shallow gas or other hazards have been observed. There is a gas sand at approximately 2,100' TVD which is present, but has not caused any past problems in the existing wells which penetrated this sand using a diverter system only. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. 10) Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. Please note that the anticipated spud date for this well is September 17, 1998. If you have any questions or require further information, please contact Scott Goldberg at (907) 263-4622 or Tom McKay at (907) 265-6890. Operations Drilling Engineer CC.' West Sak 1D-112 Well File Tom McKay ATO-1202 Keith Lynch ATO-1228 Cliff Crabtree NSK6 Drill and Case Plan for West Sak 1D-112 (Al) Frac-for-Sand Control Producer General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. 3. Spud and directionally drill 9 7/8" hole to desired target through West Sak interval. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. 5. Run and cement 7 5/8" 29.7# L80 BTC-Mod casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. Displace cement with non freezing completion brine, bump the plug and pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results of pressure test NOTE: Weatherford Gemaco Stage Collar will be placed in the 7 5/8" casing +_1700' TVD below thesufface. ,~4,.~-[~_~ ¢_o0~ /~1,~ (~i"eeO ~o-~'~ e~ 6. Nipple down diverter, nipple up tubing head and BOP's. Test BOP's. l~otify AOGCC 24 hours before test 7. Rig up and run workstring to TD. Circulate the well with seawater and freeze protect the upper +2000' with diesel 8. Nipple down BOP's. Install production tree and pressure test same. 9. Secure well, release rig 1D-112 (Al) Page 1 SG,09/03/98,v1 Completion Plan for West Sak 1 D-112 (Al) Frac-for-Sand Control Producer Four-Stage, Frac-for-Sand Control Completion (Off Rig Fracs) General Procedure: Well Preparation 1. . Staqe 1 3. Rig up frac equipment on well, and pressure test lines and production tree. Pull back pressure valve, and pressure test tubing and annulus. Rig up E-line unit, and make correlation run as required with GR/CCL to correlate logs for perforating. NOTE: The number of stages frac'd may decrease from four (4) to three (3) depending on log results and final completion design strategy. Rig up thru-tubing perf guns for Stage I frac job which includes the West Sak A2 sands. RIH with perf guns, and position guns on depth, 4. Perforate Stage I overbalanced, and POOH with E-line. . . . Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 1 interval. Mix epoxy / resin coated proppant and perform frac-for-sand control frac job on Stage 1 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage I from Stage 2 to follow. Pressure test sand plug as required. RIH with slickline and confirm sand top above Stage 1 perfs. Use CTU as required to jet sand plug top to desired PBTD. Stage 2 8. Rig up thru-tubing perf guns for Stage 2 frac jobwhich includes the West Sak A3 sands. RIH with perf guns, and position guns on depth. 9. Perforate Stage 2 overbalanced, and POOH with E-line. 10. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 2 interval. 11. Mix epoxy / resin coated proppant and perform frac-for-sand control frac job on Stage 2 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage 2 from Stage 3 to follow. Pressure test sand plug as required. 12. RIH with slickline and confirm sand top above Stage 2 perfs. Use CTU as required to jet sand plug top to desired PBTD. Stage 3 13. Rig up thru-tubing perf guns for Stage 3 frac job which includes the West sands. RIH with perf guns, and position guns on depth. 14. Perforate Stage 3 overbalanced, and POOH with E-line. 1D-112 (Al) Page 2 Sak A4 and B SG,09/03/98,v1 15. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 3 interval. 16. Mix epoxy / resin coated proppant and perform frac-for-sand control frac job on Stage 3 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage 3 from Stage 4 to follow. Pressure test sand plug as required. 17. RIH with slickline and confirm sand top above Stage 3 perfs. Use CTU as required to jet sand plug top to desired PBTD. Stage 4 18. Rig up thru-tubing perf guns for Stage 4 frac job which includes the West Sak D sands. RIH with perf guns, and position guns on depth. 19. Perforate Stage 4 overbalanced, and POOH with E-line. 20. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 4 interval. 21. Mix epoxy / resin coated proppant and perform frac-for-sand control frac job on Stage 4 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage 4 from tubing tail. Pressure test sand plug as required. 22. RIH with slickline and confirm sand top below tubing tail. Use CTU as required to jet sand plug top to desired PBTD. 23. Set back pressure valve in tubing hanger, pressure test production tree and secure well. Release frac, E-line, CTU, and slickline equipment as required. Pull Deadstring, Clean Out Well, Run ESP and Production Tubing 24. MIRU completion rig on well. Nipple down production tree and nipple up BOP stack on wellhead. Install 3-1/2" rams unless VBR's are available. Pressure test BOP stack to 3,000 psi. 25. Pull back pressure valve. 26. Pull tubing hanger andcirculate well to clean brine as required. 27. TOH and lay down deadstring. 28. Pick up rock bit and casing scraper and TIH with workstring. 29. Clean out sand plugs, proppant, and perforating debris to PBTD below base of West Sak interval. 30. Circulate well to clean brine. TOH with workstring. 31. Pick up Centrilift ESPCP (progressive cavity ESP) motor, seal assembly, and tubing crossover on 3-1/2" production tubing. 32. Run in well with ESPCP motor assembly with power cable and data gathering information wire attached to tubing. 33. Attach Raychem heat trace cable to tubing at pre-determined depth to position bottom of heat trace below permafrost, and spaced out correctly to avoid surface splicing of heat trace cable. 1D-112 (Al) Page 3 SG,09/03/98,v1 34. Position ESPCP at desired depth, set tubing hanger and run electrical penetrators through same. 35. Make surface electrical connections as required, and set back pressure valve in tubing hanger. 36. Nipple down BOP stack, and nipple up production tree. Pressure test production tree. Secure well. 37. Release rig and turn well over to production. Note: For E-line retrievable ESPCP pumps, the pump components may be run in the well with slickline after the completion rig has released from the well. 1D-112 (Al) Page 4 SG,09/03/98,v1 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS West Sak 1D-112 (Al) Drilling Fluid Type Extended Bentonite Slurry Drilling Fluid Properties: Property Density Plastic Viscosity Yield Point Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to TD Initial 8.8-9.0 ppg 4O 15-45 5-20 10-30 8-15 8.0-10.0 4-6 % Spud to TD Final 9.7-10.0 ppg 35 20-35 5-15 10-35 5-10 8.0-9.5 8-12 % Drilling Fluid System' Tandem Brandt Scalping Shale Shakers Triple Derrick Flow Line Cleaners Solids Processing System to Minimize Drilling Waste Desander, Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Mud Hoppers with Mixing Pumps *Spud mud should be adjusted to a FV between 200 - 250 sec/qt to drill gravel beds. _ Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Only one hole section will be drilled in this well. This single hole section will be drilled using a diverter system only for well control. A 7 5/8" surface / production casing string will be run to total depth (TD). This combination surface / production casing will be cemented to surface. A Weatherford Stage Collar will be placed at approximately 1700' TVD. This will be used as a contingency if cement is not brought to surface as planned. MASP (Maximum Anticipated Surface Pressure): Since a separate string of surface casing is not planned for the West Sak 1D-112 (Al) well, there is no surface casing to be drilled out below requiring a BOP stack to be utilized. The combination surface / production hole to be drilled from surface through the West Sak pay zone can safely be drilled using a diverter system only for well control purposes. 1D-112 (Al) Page I SG,09/03/98,v.1 Based on actual well test data from the nearby WSI-01 well, expected reservoir pressures in the West Sak sands in the 1D pad area vary from 0.43 to 0.46 psi/ft, or 8.2 to 8.8 ppg EMW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.7' ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 3,627" MD/TVD. Experience in the area has proven that these zones can be safely drilled using a diverter system only for well control purposes. The rig diverter system will be filled with water or mud and function tested prior to spudding the well. Since the combination surface / production casing will not be drilled out, leakoff test and MASP calculations are not necessary for drilling ahead. However, MASP calculations for cased hole operations are in order. Calculating MASP based on the highest recorded reservoir pressure from the WS1-01 well, and assuming a gas gradient of 0.11 psi/ft from the West Sak base to surface, the following MASP can be computed: MASP = (4034 ft)(0.46 - 0.11 psi/fi) - 1412 psi Based on this calculation for MASP, it will only be necessary to test the BOP equipment to a maximum of 3,000 psi. Following the cementing of the 7' 5/8" combination surface / production casing in this well, the casing will be pressure tested for 30 minutes at a surface pressure of 3,000 psi. The 7' $/8" 29.7'# 1.80 BTC casing to be used has a burst rating of 6,890 psi; 7'0 % of this burst rating is 4,823 psi. Drilling Area Risks: Drilling risks in the West Sak 1D-112 (Al) area are limited to lost circulation and potential borehole instability in and below the permafrost formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous Drill Site 1D drilling results, 10.0 ppg mud should be more than adequate to control both the Ugnu and West Sak formation pressures without resulting in lost circulation. Well Proximity Risks: The nearest existing well to West Sak 1D-112 (Al) is 1D-03. As designed, the minimum distance between the two wells would be 12.9' at 378' MD. Annular Pumping Activities: Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface / production casing annulus of a permitted existing well on DS-1D. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The West Sak 1D-112 (Al) surface casing will be filled with diesel and/or non-freezing brine after cleaning out the 7 5/8" casing and prior to the drilling rig moving off of the well. 1D-112 (Al) Page 2 SG,09/03/98,v.1 West Sak 1D-112 (Al) Producer Well Four (4) Stage Frac-for-Sand Control Completion 16" Conductor Casing @ 80' 3-1/2' Production Tubing 9.3# L-80 EUE 8RD-Mod Raychem Heat Trace (through permafrost) Weatherford Gemoco 754HO 7-5/8" DV Stage Collar Stnd. Grade BTC Threads (set +/- 200' TVD below permafrost) Power Cable for ESP Centdlift Camco 3-1/2" x 1" 'KBMM' Gas Lift Mandrel Arctic lift 3500 psi Shear circulating valve pre-loaded in GLM (circulate well for freeze protection purposes) ESP Pump Section Centdlift ESP Gearbox Centdlift 7-5/8' Casing Marker Joint 29.7# L-80 BTC-Mod (set +/- 50' above top perforation) ESP Motor Section Centdlift D Sand Frac'd with Resin Coated Proppant B + A4 Sands Frac'd with Resin Coated Proppant A3 Sand Frac'd with Resin Coated Proppant 7-5/8" Combination Surface/Production Casing, 29.7# L-80 BTC-MOD Cemented to Surface (+/- 8331' MD /4119'-I-VD) A2 Sand Frac'd with Resin Coated Proppant ARCO Alaska, Inc. ASG, 09/03/98, v.2 Oeoted by dxse FOR: GOLDBERG Dote ploffed: t-Sep-gfl Plat Reference ;s WS 10-112/A2 Ve~. ~5. ~ardinates ore ~n f~t refer~ sl~ ~112. True V~;cel Depths ore r~erence RKB (Perker 440 880 1320 1760 2200 2640 3080 I V 3520 3960 4400 ARCO Alaska, Inc. Structure : Pad 1D Well : 112 Field : Kuparuk River Unit Location : North Slope, Alaska <- West (feet) 5000 4500 4000 3500 3000 2500 2000 1500 I I I I I I I I I ! I I I I I 1000 I 5O0 0 TD LOCATION: 110' FSL, 476' FWL SEC 11, T11N, RIOE TD - Casing Pt Base Wes[ Sak Sands Base West Sak Sands Top West Sak Sand~. 322.06 AZIMUTH 6106' (TO TARGET) ***Plane of Proposal*** - Wes[ Sok A5 TARGET LOCATION: 481' FNL, 930' FWL I SEC 14, T11N, RIOE TARGET '1-VD=3768 TMD=7507 DEP=6106 NORTH 4815 WEST 3754 Top Ugnu Sonds t RKB ELEVATION 112' KOP TVD=250 TMD=250 DEP=O 8 01 BEGIN TURN / CONTINUE BUILD TVD=333 TMD=335 DER=2 1'3.53 19.3.5 DLS: 6.00 deg per 100 ft 25.22 37.10 49.04 60.99 EOC TVD=1146 TMD=1563 OEP=S49 Base Permafrost EOC AVERAGE ANGLE 64.74 DEG B / PERMAFROST%/D=1656 TMD=2558 DEP=1650 Begin Turn to TarE g?O Az SURFACE LOCATION: 16' FNL. 596' FEL SEC 2.3, T11N, RIOE 6000 5500 h kS000 I4500 t4000 ~ 3500 3000 2500 2000 1500 1000 500 o TARGET ANGLE 64.74 T / UGNU SNDS TVO=3040 TMD=5801 DEP=4563 T / W SAK SNDS TVD=3627 TMD=7177 DEP=5807 TARGET - A3 TVD=3768 TMD=7507 DEP=6i B / W SAK SNDS TVD=4054 TMD=8151 DEP=6670 TD - CSG PT TVD=4119 TMD=8331 DEP=6851 4840 J [ i i i i i I 0 440 880 1320 i i i I I i I i i ii i I i i t i [ 1 760 2200 2640 5080 3520 3960 4400 4840 5280 5720 Vertical Section (feet) -> Azimuth .522.06 with reference 0.00 N, 0.00 E from slot #112 i i i i i : [ i 6160 6600 7040 7480 A I Z C~¢o~ ~ ~.~ FOR: GOLDBERG Dote plotted : I-Sep-fl8 Pio[ Reference is C~/notes om ;n ~e~ ~ference T~e Ve~iCOI Oep~S~~8 (Pork~ ,~ ARCO Alaska, Inc. Structure : Pod 1D Well : 112 Field : Kuparuk River Unit Locofion : North Slope, Alasko <- West (feet) 450 420 590 560 330 300 270 240 I 210 180 _c 150 120 360 530 500 270 240 210 180 150 120 90 60 30 0 ,30 60 90 % 1300 1000 0 ',,, ~ i~oo\ ,,, ' 100 \,\, ~ i %1899.99 ",, ", \ ~ ~18oo · ,,\14o~ \ ! ' \ ", \ 18°° 118°° x k k 900 ~ ~ ~ , k \' ~900\ ~1500 , \ 12oo ',~ 4000 .];. \, \~, 14oo · '~lO00k ~ouu , , ,,~",,,, x ,,,, "~ ~oo k~%%o % ',, ',, \ \ ",,,, lOOO% ",,,, ~ k,, ~ i~, "-, ",, ~oo '~ ~o& ~oo ~ "'"'. '1%o '.~' "',, ' '"',. - 1100 1700 ', ',, ,, · ,, ""~ 1000 1200 '-.. -. -. 1100 "., 900 60 ~ 2100 2000 3O 1800 900 25O0 590 I 1100 [2200¢i q/~ .560 ~ lOOO / ; / 350 2 loo /;~'~ ooo / /¢ oo 9OO [2d'oo / 900/' ,m 270 I ,,"8oo / ," / ;' 8 __~-' boo, ~ov~/ /lOO ' 210 14 !50 ",,,. ~o~',.~oo ,, ~o/loo' __~ "----%'" " ~ ,/;dd-- 17oo 1900 '"', 'qoo ,,~,, ",~ ""'",(8oo ~ ~oo'".,. ~o'~.°..O, ... ~ ooo'--... ~oo x.3o~oo ',. 700 7oo ~ 70o ~ ~700 , 0 1406'~c 100 1300 ~ 6oo F P 9O 1600 l- 6o ! 1500 i i i t i i I i : i ~ i i i i i i i i~ I I i i i i i t i i i 560 350 300 270 240 21 0 ! 80 150 120 90 60 30 0 50 60 90 <- West (feet) C~¢o~ ~ ~,~ FOR: GOLDBERG I Date plotted : 1-Sep-flB I PIot Reference is '~J 1D-112/A2 Vena. ~5. ] Co~[nates o~ in ~e~ ~ference slot ~112. I Tree VeA~ai Oep~e ~B (Parker ~2~5). ARCO Alaska, !nc Structure : Pad 1D Well : 112 Field : Kuparuk River Unit Location : North Slope. Alaska 1300 I 1200 ,4-- 1100 ,-I,-, k_ 1000 0 Z <- West (feet) 1700 1600 1500 1400 1300 1200 1 i O0 1000 900 800 700 600 500 400 300 200 1 O0 '' ' ' ' ' ' ' ' ' ' ' ' ' ' ", '~ 2100 4100 \ · ,, 41 oo ",, '",\,,, 59 00 \\ 1800 " , ~ 1900 1800 '"', ", ~oo "\ ",, · 1700 "'" ",, 5500 " ' ',. 1900 'q 1700 ' C 1700 21 oo '"'\ ,,,, 3900 ",,,, '\ 3300 " 1600 ' ", 650,0 1600 · ,, '~ 1900 "\ 63(~0 1500 '"", '\, '", il ~0 1500 ",,,\\,, 3100 ', ~1700 1400 "",,, " '\,, ?00 1400 ", 2900 ",, 5500 '"' 1900 ',,,, \'.,, 1500 1300 '"',,,, ,,, ,, 5300 -% '~ 1700 '. "',,, ',, 2700 , I "- ', " 5100 120o ", " )0 0 "-,... 2300 ",,, , "" \ ', I ,, ', 2500 ', · ""' "" 1 )0 '"' ',, ~ ", 4-700 i -"" -~-~ '"'""] '~ """~ 1700 f\''' 500 '"" ~'""4' ~ 'P 1°00 (1) ~oot -"-~oo ",.,.. '.,,, ~ ~.,o~',,, ~ ",,:~oo \~oCZ ~oo ~ '""'"'- 2100 "'"'x ~ '"",,, ~ '"",, ~uu~L, ~ 2300 "'" 15"'" '~'' "', ,. \', X ", ;,.1"~00 ~oo ... u~ .~ '.., \ .,,. \~oo, ,,,, \ ~oo ~ "",. "',. x ",.,. \ ,,,, ,,,, ,,,,, 700 600 ~ '"'".. '~ '"",,.X'X~1500 ',1.30~ ", ",. ~-600 ~ -'"'"'"'% 0~~ "'"'"L ''\' '"'~? I00~ ~ ~oo ~?o ',. x ?'oo ~ 500 Q~ ~.L9..o. ~~-~°° "- "~ ~oo .o. '""'"'"- ". ~oo '''''''' %' "-.. "q .590 - ~...... I~C F 300 [ ~ ] i i i i i i i i i i i i i t ~ I I I i ! I I r : ; i i 1700 '.' 500 1500 1400 1500 1200 I 1 O0 1000 900 800 700 500 500 400 500 200 i O0 <- West (feet) C~o,.d w r~x.. FOR: GOLDBERG Oate p~o~ted : I-S~p-98 Plot Reference is WS 10-112/A2 Vers. Coordinates are in feet reference slot ~112. True Vertical Oepths are reference ARCO Alaska, inc. Structure : Pad 10 Well: 112 Field : Kuparuk River Unff Location : North Slope, Alaska 4420 4160 A 3900 '+- 3640 3380 0 '7 3120 2860 2600 2340 2080 1820 <- West (feet) 4680 4420 4160 3900 3640 3380 5120 2860 2600 2340 2080 1820 1560 1300 1040 780 520 5720 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ' i 5720 F 5460 ~ ~ S460 520o 400o'", I- 52o0 · F '""', [~1~ 4200 4~40 ',,, ~ L 4~40 3ilO0 X, '~ 4000 ',,, 3800 4680 '"'", "~l 3600 ",,, 3400 4680 3600~', ~ 3200 "',,,, ' 4420 "' '~ 3000 3400',,, I~ 4200 ,,, ~800[ 4!60 ',,,,. ' ooo ",, .oot 2,,. ",**o ,, ~;~oo ~4oo~-;~oo ;=oo.,, % ,, =,,oo ;,,o~ L '"' '"' 400 ,,, ,000!. ,40 600 '\ 520~'t, 6200~ ..... "- ~ ", 2600 "-. 5800 .,.F ",,., ',,,;200 ",, ", L 3380 '... ~. ,, .,oo',, ~ 280o", ',.,;ooo '\ ", ~4ooi ' 3~20 ~ 4200 ',.. % \ ',, -' ;L . '% 4000 '% ~ 4200 '~ 2400 ; "- .3800 ", -,,. \ ; L ...... '". -~' "- ..... \ 2600'' 5200 '-,, obOU '" % 28~)°uu -- " [ '-,.. 3400 '~nn~", %, '-., 3400 ', '~ i- z860 "-. 3200 ..... '.. k "..5200 \\ J~5000 i "- 'x \ '% 3000 \ t", ". 5000 '% ~ '. '; 2200 \',240C) '"- "'\ %N '%. 2800 ", .,tRnn ~ ~ 2600 ,,.,,,~,~oo ~4o~'.,,, ,q~oo .,,, ~oo ,, ~ ",,,, 2ooo¢ 4000 --. 2 % 24-o0 ", \, i- .%Ooo-~..' ~oo,.,. 'q ., ,. ~o~o ~%o,,.~,..~,,oo ,.,,. \ ,,.~oo ,, 3,oo"~-,',, .... ", \ ",, E--~---,.42oo ', .... .... '"~" .... ~" % " % 4 ~ i uuu ~oo~ ~ooo.,,.. \~oo .,, ~o&%, .....,.',,, '"-,,.x,,,. 2600 ~;'}, X '"x %200'~ h 1560 "~o ~. ~oo-,,_ x. ~ooo,,. V~- 4680 4420 4160 3900 3640 3380 3120 2860 2600 2340 2080 1820 1560 !300 1040 780 520 1560 1500 <- West (feet) ARCO Alaska, Inc. Sfrucfure : Pad 1D Well : 112 Field : Kuparuk River Unif Locafion : Norfh Slope, Alaska WELL PROFILE ..... Paint ..... UD Inc ~e on 0.OO 0.0~ K0P 250.0<] 0.O0 En~ of ~ild~u~n~2.~ 64.7~ Tarot ws 1D-A1 Rvsd 2 7~7.22 64.74 ~d of H~d 61~.5~ 64.7~ ~T.O. · End of H~d 83~.5~ 64.7~ DATA O;r ~ Ncrlh East 270.O00.00 0.00 0.O0 270.0O250.O00.~0 0.O0 270.~ 333.23~.~ -3.63 52~46 11~.82~g.4g -~.13 32~ 3768.~4815.~-375~.~ 322.46~3~,~ 5262-~-4~7.~5 322-464119.35 5~5.82-42~.17 ¥. ~ctDeg/IOD 0.O0 0.O0 O.eQ O.OQ 2-23 6.0Q 54g.286.0(] 6106.09 0.00 666g.79 0.00 6850.66 O.OO 320 330 34O 350 TRUE NORTH 0 10 2O Oe0te~ ~X ~'~,e FOR: GOLDBERG Date I~otted : 1-Se~-g8 Plat Reference is W~ 10-112/A2 Ve~. ~5. J C~rdinotcs are in feet r~ence slot ~112. [rue V~cal Depths are r~r~ce R~ (Parker 3O 40 ..-- ~,, ~oo..-' 50 300 290 280 27O 260 01801 .-500 ~0 1 8O 250 i,,, ,--,, 240 'f~°° 22O 210 200 !90 ~oo ~ ~0o ~oo t30 140 160 180 !70 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference ARCO Alaska, Inc. Pad 1D 112 slot #112 Kuparuk River Unit North Slope, Alaska PROPOSAL L I S T I N~ INCLUDIN~ POSITION UNCERTAINTIES Baker Hughes INTEQ Your ref = WS 1D-112/A2 Vets. #5 Our ref = prop2214 License : Date printed : 1-Sep-98 Date created : 1?-Apr-9? Last revised : 23-Jul-98 Field is centred on n?0 16 18.576,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 30 18.908 Slot location is n?0 18 1.158,w149 30 36.284 Slot Grid coordinates are N 5959648.687, E 560491.090 Slot local coordinates are 16.00 S 596.00 W Projection type: alaska - Zone 4, Spheroids Clarke - 1866 Reference North is True North ARCO Alaska, Inc. Pad 1D,112 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S 0.00 0.00 270.00 0.00 0.00 N 0.00 E 250.00 0.00 270.00 250.00 0.00 N 0.00 E 333.33 5.00 270.00 333.23 0.00 S 3.63 W 400.00 8.01 294.03 399.47 1.89 N 10.79 W 500.00 13.53 307.18 497.68 11.81 N 26.48 W PROPOSAL LISTING Page 1 Your ref : WS 1D-112/A2 Vets. #5 Last revised : 23-Jul-98 Dogleg Vert Deg/100ft Sect 0.00 0.00 0.00 0.00 K0P 6.00 2.23 Begin Turn to Target 6.00 8.12 6.00 25.60 600.00 19.33 312.68 593.57 30.11 N 47.98 W 6.00 53.25 700.00 25.22 315.69 686.07 56.60 N 75.05 W 6.00 90.78 800.00 31.15 317.62 774.17 90.98 N 107.40 W 6.00 137.78 900.00 37.10 318.98 856.92 132.88 N 144.66 W 6.00 193.74 1000.00 43.06 320.01 933.40 181.84 N 186.43 W 6.00 258.04 1100.00 49.04 320.84 1002.77 237.33 N 232.26 W 6.00 329.97 1200.00 55.01 321.53 1064.28 298.73 N 281.63 W 6.00 408.75 1300.00 60.99 322.12 1117.24 365.37 N 334.01 W 6.00 493.51 1362.68 64.74 322.46 1145.82 409.49 N 368.13 W 6.00 549.28 EOC 1500.00 64.74 322.46 1204.43 507.95 N 443.81 W 0.00 673.47 2000.00 64.74 322.46 1417.80 866.48 N 719.36 W 0.00 1125.64 2500.00 64.74 322.46 1631.18 1225.01 N 994.91 W 0.00 1577.82 2558.17 64.74 322.46 1656.00 1266.72 N 1026.97 W 0.00 1630.42 Base Pez-mafrost 3000.00 64.74 322.46 1844.55 1583.53 N 1270.47 W 0.00 2029.99 3500.00 64.74 322.46 2057.92 1942.06 N 1546.02 W 0.00 2482.17 4000.00 64.74 322.46 2271.30 2300.59 N 1821.57 W 0.00 2934.34 4500.00 64.74 322.46 2484.67 2659.11 N 2097.13 W 0.00 3386.52 5000.00 64.74 322.46 2698.05 3017.64 N 2372.68 W 0.00 3838.69 5500.00 64.74 322.46 2911.42 3376.17 N 2648.24 W 0.00 4290.86 5801.30 64.74 322.46 3040.00 3592.21 N 2814.28 W 0.00 4563.34 Top Ugnu Sands 6000.00 64.74 322.46 3124.80 3734.70 N 2923.79 W 0.00 4743.04 6500.00 64.74 322.46 3338.17 4093.22 N 3199.34 W 0.00 5195.21 7000.00 64.74 322.46 3551.55 4451.75 N 3474.90 W 0.00 5647.39 7176.81 64.74 322.46 3627.00 4578.53 N 3572.34 W 0.00 5807.29 Top West Sak Sands 7500.00 64.74 322.46 3764.92 4810.28 N 3750.45 W 0.00 6099.56 7507.20 64.74 322.46 3767.99 4815.43 N 3754.42 W 0.00 6106.07 TARGET - A3 7507.22 64.74 322.46 3768.00 4815.45 N 3754.43 W 0.00 6106.09 WS 1D-A1 Rvsd 22-Jan-98 8000.00 64.74 322.46 3978.29 5168.80 N 4026.01 W 0.00 6551.74 8130.54 64.74 322.46 4034.00 5262.40 N 4097.95 W 0.00 6669.79 Base West Sak Sands 8330.54 64.74 322.46 4119.35 5405.82 N 4208.17 W 0.00 6850.66 TD - Casing Pt All data is in feet unless otherwise stated. Coordinates from slot #112 and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 6850.66 on azimuth 322.10 degrees from wellhead. Total Dogleg for wellpath is 66.76 degrees. Vertical section is from wellhead on azimuth 322.06 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,112 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref = WS 1D-112/A2 Vets. #5 Last revised = 23-Jul-98 Comments in we11path =m=--m===-- = MD TVD Rectangular Coords. Comment 250.00 250.00 0.00 N 333.33 333.23 0.00 S 1362.68 1145.82 409.49 N 2558.17 1656.00 1266.72 N 5801.30 3040.00 3592.21 N 7176.81 3627.00 4578.53 N 7507.20 3767.99 4815.43 N 7507.22 3768.00 4815.45 N 8130.54 4034.00 5262.40 N 8330.54 4119.35 5405.82 N 0.00 E KOP 3.63 W Begin Turn to Target 368.13 W EOC 1026.97 W Base Permafrost 2814.28 W Top Ugnu Sends 3572.34 W Top West Sak Sands 3754.42 W TARGET - A3 3754.43 W WS 1D-A1 Rvsd 22-Jan-98 4097.95 W Base West Sak Sands 4208.17 W TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 8329.93 4119.09 5405.38N 4207.83W 7 5/8" Casing Targets associated with this we11path Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-A1 Rvsd 22-Jan 556698.000,5964433.000,0.0000 3768.00 4815.45N 3754.43W 14-Apr-97 ARCO Alaska, Inc. Pad 1D,112 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S 0.00 0.00 270.00 0.00 16.00 S 596.00 W 250.00 0.00 270.00 250.00 16.00 S 596.00 W 333.33 5.00 270.00 333.23 16.00 S 599.63 W 400.00 8.01 294.03 399.47 14.11 S 606.79 W 500.00 13.53 307.18 497.68 4.19 S 622.48 W 600.00 19.33 312.68 593.57 14.11 N 643.98 W 700.00 25.22 315.69 686.07 40.60 N 671.05 W 800.00 31.15 317.62 774.17 74.98 N 703.40 W 900.00 37.10 318.98 856.92 116.88 N 740.66 W 1000.00 43.06 320.01 933.40 165.84 N 782.43 W 1100.00 49.04 320.84 1002.77 221.33 N 828.26 W 1200.00 55.01 321.53 1064.28 282.73 N 877.63 W 1300.00 60.99 322.12 1117.24 349.37 N 930.01 W 1362.68 64.74 322.46 1145.82 393.49 N 964.13 W 1500.00 64.74 322.46 1204.43 491.95 N 1039.81 W 2000.00 64.74 322.46 1417.80 850.48 N 1315.36 W 2500.00 64.74 322.46 1631.18 1209.01 N 1590.91 W 2558.17 64.74 322.46 1656.00 1250.72 N 1622.97 W 3000.00 64.74 322.46 1844.55 1567.53 N 1866.47 W 3500.00 64.74 322.46 2057.92 1926.06 N 2142.02 W 4000.00 64.74 322.46 2271.30 2284.59 N 2417.57 W 4500.00 64.74 322.46 2484.67 2643.11 N 2693.13 W 5000.00 64.74 322.46 2698.05 3001.64 N 2968.68 W 5500.00 64.74 322.46 2911.42 3360.17 N 3244.24 W 5801.30 64.74 322.46 3040.00 3576.21 N 3410.28 W 6000.00 64.74 322.46 3124.80 3718.70 N 3519.79 W 6500.00 64.74 322.46 3338.17 4077.22 N 3795.34 W 7000.00 64.74 322.46 3551.55 4435.75 N 4070.90 W 7176.81 64.74 322.46 3627.00 4562.53 N 4168.34 W 7500.00 64.74 322.46 3764.92 4794.28 N 4346.45 W 7507.20 64.74 322.46 3767.99 4799.43 N 4350.42 W 7507.22 64.74 322.46 3768.00 4799.45 N 4350.43 W 8000.00 64.74 322.46 3978.29 5152.80 N 4622.01 W 8130.54 64.74 322.46 4034.00 5246.40 N 4693.95 W 8330.54 64.74 322.46 4119.35 5389.82 N 4804.17 W PROPOSAL LISTING Page 1 Your ref : WS 1D-112/A2 Vets. #5 Last revised : 23-Jul-98 Dogleg Vert Deg/100ft Sect 0.00 0.00 6.00 6.00 6.00 0.00 0.00 KOP 2.23 Begin Turn to Target 8.12 25.60 6.00 53.25 6.00 90.78 6.00 137.78 6.00 193.74 6.00 258.04 6.00 329.97 6.00 408.75 6.00 493.51 6.00 549.28 EOC 0.00 673.47 0.00 1125.64 0.00 1577.82 0.00 1630.42 Base Permafrost 0.00 2029.99 0.00 2482.17 0.00 2934.34 0.00 3386.52 0.00 3838.69 0.00 4290.86 0.00 4563.34 Top Ugnu Sands 0.00 4743.04 0.00 5195.21 0.00 5647.39 0.00 5807.29 Top West Sak Sands 0.00 6099.56 0.00 6106.07 TARGET - A3 0.00 6106.09 WS 1D-A1 Rvsd 22-Jan-98 0.00 6551.74 0.00 6669.79 Base West Sak Sands 0.00 6850.66 TD - Casing Pt All data is in feet unless otherwise stated. Coordinates from SE Corner of Sec. 14, T11N, R10E and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 6850.66 on azimuth 322.10 degrees from wellhead. Total Dogleg for wellpath is 66.76 degrees. Vertical section is from wellhead on azimuth 322.06 degrees. Calculation uses the minimum curvature me~hod. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,112 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref = WS 1D-112/42 Vets. #5 Last revised = 23-Jul-98 Comments in wellpath MD TVD Rectangular Coords. Comment 250.00 250.00 16.00 S 333.33 333.23 16.00 S 1362.68 1145.82 393.49 N 2558.17 1656.00 1250.72 N 5801.30 3040.00 3576.21 N 7176.81 3627.00 4562.53 N 7507.20 3767.99 4799.43 N 7507.22 3768.00 4799.45 N 8130.54 4034.00 5246.40 N 8330.54 4119.35 5389.82 N 596.00 W KOP 599.63 W Begin Turn to Target 964.13 W EOC 1622.97 W Base Permafrost 3410.28 W Top Ugnu Sands 4168.34 W Top West Sak Sands 4350.42 W TARGET - 43 4350.43 W WS 1D-A1 Rvsd 22-Jan-98 4693.95 W Base West Sak Sands 4804.17 W TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 16.00S 596.00W 8329.93 4119.09 5389.38N t803.83W 7 5/8" Casing Targets associated with this wellpath Target n~ae Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-A1 Rvsd 22-Jan 556698.000,5964433.000,0.0000 3?68.00 4799.45N 4350.43W 14-Apr-97 ARCO Alaska, Inc. Pad 1D,112 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : WS 1D-112/A2 Vers. #5 Last revised : 23-Jul-98 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Vert Ellipse Semi Axes Minor Depth Degrees Degrees Depth C 0 0 R D I N A T E S Sect Major Minor Vert. Azi. 0.00 0.00 270.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 0.00 N/A 250.00 0.00 270.00 250.00 0.00 N 0.00 E 0.00 0.65 0.65 0.38 N/A 333.33 5.00 270.00 333.23 0.00 S 3.63 W 2.23 0.91 0.87 0.50 270.00 400.00 8.01 294.03 399.47 1.89 N 10.79 W 8.12 1.20 1.06 0.60 283.67 500.00 13.53 307.18 497.68 11.81 N 26.48 W 25.60 1.95 1.36 0.76 298.02 600.00 19.33 312.68 593.57 30.11 N 47.98 W 53.25 3.18 1.72 0.94 305.17 700.00 25.22 315.69 686.07 56.60 N 75.05 W 90.78 4.94 2.14 1.15 309.46 800.00 31.15 317.62 774.17 90.98 N 107.40 W 137.78 7.25 2.61 1.43 312.32 900.00 37.10 318.98 856.92 132.88 N 144.66 W 193.74 10.13 3.12 1.79 314.36 1000.00 43.06 320.01 933.40 181.84 N 186.43 W 258.04 13.59 3.65 2.26 315.90 1100.00 49.04 320.84 1002.77 237.33 N 232.26 W 329.97 17.61 4.19 2.85 317.09 1200.00 55.01 321.53 1064.28 298.73 N 281.63 W 408.75 22.17 4.71 3.54 318.05 1300.00 60.99 322.12 1117.24 365.37 N 334.01 W 493.51 27.21 5.19 4.35 318.84 1362.68 64.74 322.46 1145.82 409.49 N 368.13 W 549.28 30.54 5.47 4.89 319.25 1500.00 64.74 322.46 1204.43 507.95 N 443.81 W 673.47 37.86 6.09 6.09 319.89 2000.00 64.74 322.46 1417.80 866.48 N 719.36 W 1125.64 64.64 8.31 10.51 320.97 2500.00 64.74 322.46 1631.18 1225.01 N 994.91 W 1577.82 91.50 10.52 14.96 321.41 2558.17 64.74 322.46 1656.00 1266.72 N 1026.97 W 1630.42 94.62 10.78 15.47 321.44 3000.00 64.74 322.46 1844.55 1583.53 N 1270.47 W 2029.99 118.37 12.73 19.40 321.65 3500.00 64.74 322.46 2057.92 1942.06 N 1546.02 W 2482.17 145.26 14.93 23.85 321.80 4000.00 64.74 322.46 2271.30 2300.59 N 1821.57 W 2934.34 172.15 17.14 28.30 321.91 4500.00 64.74 322.46 2484.67 2659.11 N 2097.13 W 3386.52 199.04 19.34 32.75 321.98 5000.00 64.74 322.46 2698.05 3017.64 N 2372.68 W 3838.69 225.93 21.55 37.20 322.04 5500.00 64.74 322.46 2911.42 3376.17 N 2648.24 W 4290.86 252.83 23.75 41.65 322.08 5801.30 64.74 322.46 3040.00 3592.21 N 2814.28 W 4563.34 269.04 25.08 44.34 322.10 6000.00 64.74 322.46 3124.80 3734.70 N 2923.79 W 4743.04 279.73 25.96 46.10 322.12 6500.00 64.74 322.46 3338.17 4093.22 N 3199.34 W 5195.21 306.62 28.16 50.56 322.15 7000.00 64.74 322.46 3551.55 4451.75 N 3474.90 W 5647.39 333.52 30.36 55.01 322.17 7176.81 64.74 322.46 3627.00 4578.53 N 3572.34 W 5807.29 343.03 31.14 56.58 322.18 7500.00 64.74 322.46 3764.92 4810.28 N 3750.45 W 6099.56 360.42 32.57 59.46 322.19 7507.20 64.74 322.46 3767.99 4815.43 N 3754.42 W 6106.07 360.81 32.60 59.52 322.19 7507.22 64.74 322.46 3768.00 4815.45 N 3754.43 W 6106.09 360.81 32.60 59.52 322.19 8000.00 64.74 322.46 3978.29 5168.80 N 4026.01 W 6551.74 387.32 34.77 63.91 322.21 8130.54 64.74 322.46 4034.00 5262.40 N 4097.95 W 6669.79 394.34 35.34 65.07 322.22 8330.54 64.74 322.46 4119.35 5405.82 N 4208.17 W 6850.66 405.10 36.23 66.86 322.22 All data is in feet unless otherwise stated. Coordinates from slot #112 and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 6850.66 on azimuth 322.10 degrees from wellhead. Vertical section is from wellhead on azimuth 322.06 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,112 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : WS 1D-112/A2 Vets. #5 Last revised ~ 23-Jul-98 POSITION UNCERTAINTY SUMldARY Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 8331 ARCO (H.A.l.~.g) User specified 405.10 36.23 66.86 1. Ellipse dimensions are half axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak ~-ual. Comments in we11path MD TVD Rectangular Coords. Comment 250.00 250.00 0 333.33 333.23 0 1362.68 1145.82 409 2558.17 1656.00 1266 5801.30 3040.00 3592 7176.81 3627.00 4578 7507.20 3767.99 4815 7507.22 3768.00 4815 8130.54 4034.00 5262 8330.54 4119.35 5405 00 N 00 S 49 N 72 N 21 N 53 N 43 N 45 N 40 N 82 N 0.00 E KOP 3.63 W Begin Turn to Target 368.13 W E0C 1026.97 W Base Permafrost 2814.28 W Top Uguu Sands 3572.34 W Top West Sak Sands 3754.42 W TARGET - A3 3754.43 W WS 1D-A1 Rvsd 22-Jan-98 4097.95 W Base West Sak Sands 4208.17 W TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 8329.93 4119.09 5405.38N 4207.83W 7 5/8" Casing Targets associated with this we11path Target n~ne ~eographic ~ocat£on T.~.~. Rectangular Coordimates ~e~ised WS 1D-A1 Rvsd 22-Jan 556698.000,5964433.000,0.0000 3768.00 4815.45N 3754.43W 14-Apr-9? ARCO Alaska, Inc. Pad 1D,112 Kuparuk River Unit,North Slope, Alaska Measured Inclin Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S PROPOSAL LISTING Page 1 Your ref : WS 1D-112/A2 Vets. #5 Last revised : 23-Jul-98 Dogleg Vert G R i D C O 0 R D S Deg/100ft Sect Easting Northing 0.00 0.00 270.00 0.00 0.00N 0.00E 0.00 0.00 560491.09 5959648.69 250.00 0.00 270.00 250.00 0.00N 0.00E 0.00 0.00 560491.09 5959648.69 333.33 5.00 270.00 333.23 0.00S 3.63W 6.00 2.23 560487.46 5959648.66 400.00 8.01 294.03 399.47 1.89N 10.79W 6.00 8.12 560480.29 5959650.49 500.00 13.53 307.18 497.68 11.81N 26.48W 6.00 25.60 560464.52 5959660.28 600.00 19.33 312.68 593.57 30.11N 47.98W 6.00 53.25 560442.87 5959678.40 700.00 25.22 315.69 686.07 56.60N 75.05W 6.00 90.78 560415.59 5959704.67 800.00 31.15 317.62 774.17 90.98N 107.40W 6.00 137.78 560382.97 5959738.78 900.00 37.10 318.98 856.92 132.88N 144.66W 6.00 193.74 560345.37 5959780.37 1000.00 43.06 320.01 933.40 181.84N 186.43W 6.00 258.04 560303.20 5959828.99 1100.00 49.04 320.84 1002.77 237.33N 232.26W 6.00 329.97 560256.94 5959884.09 1200.00 55.01 321.53 1064.28 298.73N 281.63W 6.00 408.75 560207.07 5959945.08 1300.00 60.99 322.12 1117.24 365.37N 334.01W 6.00 493.51 560154.15 5960011.29 1362.68 64.74 322.46 1145.82 409.49N 368.13W 6.00 549.28 560119.68 5960055.13 1500.00 64.74 322.46 1204.43 507.95N 443.81W 0.00 673.47 560043.21 5960152.97 2000.00 64.74 322.46 1417.80 866.48N 719.36W 0.00 1125.64 559764.78 5960509.21 2500.00 64.74 322.46 1631.18 1225.01N 994.91W 0.00 1577.82 559486.35 5960865.45 2558.17 64.74 322.46 1656.00 1266.72N 1026.97W 0.00 1630.42 559453.95 5960906.90 3000.00 64.74 322.46 1844.55 1583.53N 1270.47W 0.00 2029.99 559207.91 5961221.69 3500.00 64.74 322.46 2057.92 1942.06N 1546.02W 0.00 2482.17 558929.48 5961577.93 4000.00 64.74 322.46 2271.30 2300.59N 1821.57W 0.00 2934.34 558651.05 5961934.17 4500.00 64.74 322.46 2484.67 2659.11N 2097.13W 0.00 3386.52 558372.62 5962290.41 5000.00 64.74 322.46 2698.05 3017.64N 2372.68W 0.00 3838.69 558094.18 5962646.65 5500.00 64.74 322.46 2911.42 3376.17N 2648.24W 0.00 4290.86 557815.75 5963002.89 5801.30 64.74 322.46 3040.00 3592.21N 2814.28W 0.00 4563.34 557647.97 5963217.56 6000.00 64.74 322.46 3124.80 3734.70N 2923.79W 0.00 4743.04 557537.32 5963359.13 6500.00 64.74 322.46 3338.17 4093.22N 3199.34W 0.00 5195.21 557258.89 5963715.38 7000.00 64.74 322.46 3551.55 4451.75N 3474.90W 0.00 5647.39 556980.45 5964071.62 7176.81 64.74 322.46 3627.00 4578.53N 3572.34W 0.00 5807.29 556881.99 5964197.59 7500.00 64.74 322.46 3764.92 4810.28N 3750.45W 0.00 6099.56 556702.02 5964427.86 7507.20 64.74 322.46 3767.99 4815.43N 3754.42W 0.00 6106.07 556698.01 5964432.98 7507.22 64.74 322.46 3768.00 4815.45N 3754.43W 0.00 6106.09 556698.00 5964433.00 8000.00 64.74 322.46 3978.29 5168.80N 4026.01W 0.00 6551.74 556423.59 5964784.10 8130.54 64.74 322.46 4034.00 5262.40N 4097.95W 0.00 6669.79 556350.90 5964877.10 8330.54 64.74 322.46 4119.35 5405.82N 4208.17W 0.00 6850.66 556239.52 5965019.60 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates fr~m slot #112 and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 6850.66 on azimuth 322.10 degrees from wellhead. Total Dogleg for wellpath is 66.76 degrees. Vertical section is from wellhead on azimuth 322.06 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and com~uted using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,112 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref ~ WS 1D-112/A2 Vets. #5 Last revised = 23-Jul-98 Comments in we11path MD TVD Rectangular Coords. Comment ........................................................................................................... 250.00 250.00 0.00N 0.00E KOP 333.33 333.23 0.00S 3.63W Begin Turn to Target 1362.68 1145.82 409.49N 368.13W EOC 2558.17 1656.00 1266.72N 1026.97W Base Permafrost 5801.30 3040.00 3592.21N 2814.28W Top U~nu Sands 7176.81 3627.00 4578.53N 3572.34W Top West Sak Sands 7507.20 3767.99 4815.43N 3754.42W TARGET - A3 7507.22 3768.00 4815.45N 3754.43W WS 1D-A1 Rvsd 22-Jan-98 8130.54 4034.00 5262.40N 4097.95W Base West Sak Sands 8330.54 4119.35 5405.82N 4208.17W TD - Casing Pt Casing positions in string ~A~ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 8329.93 4119.09 5405.38N 4207.83W 7 5/8" Casing Targets associated with this we11path Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-A1 Rvsd 22-Jan 556698.000,5964433.000,0.0000 3?68.00 4815.45N 3754.43W 14-Apr-97 ARCO Alaska, Inc. Pad 1D 112 slot #112 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE Baker Hughes INTEQ REPORT Your ref : WS 1D-112/A2 Vets. #5 Our ref = prop2214 License : Date printed : 1-Sep-98 Date created : 17-Apr-97 Last revised : 23-Jul-98 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on n?0 18 1.316,w149 30 18.908 Slot location is n?0 18 1.158,w149 30 36.284 Slot Grid coordinates are N 5959648.687, E 560491.090 Slot local coordinates are 16.00 S 596.00 W Projection type~ alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <0 - 6270'>,,114,Pad 1D PMSS <377 - 6224'>,,134,Pad 1D PMSS <0 - 6472'>,,131,Pad 1D PMSS <467 - 5802'>,,132,Pad 1D PMSS <0-4414'>,,121,Pad 1D PMSS <0-4530'>,,120,Pad 1D PMSS <0-4515'>,,119,Pad 1D PMSS <O-4590'>,,118,Pad 1D PMSS <0-5205'>,,liT,Pad 1D PMSS <0-4850'>,,109,Pad 1D PMSS <0-5126'>,,106,Pad 1D PMSS <381-6092'>,,105,Pad 1D PMSS <1957-5265'>,,133,Pad 1D PMSS <0-5015'>,,135,Pad 1D PMSS <0-5047'>,,124,Pad 1D TOTCO Sur~rey,,WS-8,Pad 1D PG"MS <0-8365'>,,1,Pad 1D PG~MS <0-8930'>,,5,Pad 1D PGMS <O-8610'>,,6,Pad 1D MSS <3311-8200'>,,7,Pad 1D PMSS <556-7024'>,,9,Pad 1D PMSS <0 - ?340'>,,10,Pad 1D PMSS <0-5462'>,,129,Pad 1D PMSS <0-4778'>,,130,Pad 1D PMSS <0 - 6?16'>,,126,Pad 1D PMSS <0 - 7432'>,,127,Pad 1D PGMS <0-9783'>,,2,Pad 1D PG94S <O-?502'>,,4,Pad 1D Closest approach with 3-D Last revised 27-Aug-98 3 -Aug- 98 23 -Jul- 98 6 -Aug- 98 2-Ju~-98 2-Ju~-98 2-Ju~-98 2-Jun-98 2-Jun-98 2-Jun-98 2-Jun-98 2-Jun- 98 2-Jun-98 2-Jun-98 2-Jun-98 21-May-98 10-Dec- 97 13 -Nov- 97 13 -Nov- 97 6 -Nov- 97 29-Apr- 98 28-Apr- 98 2-Jun- 98 2-Jun-98 1-Jul-98 6-Jul-98 4 -Aug- 92 4 -Aug- 92 Distance 30.0 494.2 405.0 420.0 164.1 149.5 134.1 90.0 73.0 66.2 104 6 149 5 432 1 510 0 253 2 587 0 186 2 227 1 347 0 467.0 119.8 540.0 374.3 389.9 283.8 298.4 115.0 107. I Minimum Distance method 100.0 312.5 100.0 120.0 333.3 333.3 333.3 100.0 355.6 640.0 680.0 500.0 333.3 120.0 355.6 333.3 900 0 20 0 2O 0 333 3 333 3 120 0 312 5 333 3 333 3 312.5 640.0 20.0 Diverging from M.D. 100.0 6680.0 100.0 120.0 333.3 333.3 333.3 100.0 355.6 640.0 680.0 500.0 333.3 312.5 355.6 333.3 900.0 333.3 20.0 333.3 333.3 120.0 312.5 333.3 333.3 312.5 640.0 333.3 PMSS <O-5142~>,,115,Pad 1D PMSS <0 - 6580~>,,128,Pad 1D PMSS <291 - 5795~),,125,Pad 1D PGMS <0-8070'>,,3,Pad 1D PMSS <0 - 5445'>,,122,Pad 1D PMSS<O-7045'>,,111,Pad 1D 2-Jun-98 17-Aug-98 19-Aug-98 13-Aug-98 29-Aug-98 31-Aug-98 37.5 314.4 267.5 12.9 180.0 32.4 333.3 333.3 377.8 100.0 606.8 480.0 333.3 333.3 377.8 100.0 4560.0 5000 psi BOP S. ck Kuparuk River Unit West Sak Operations - Producer Wells 1. 16" Starting Head 2. 11" 5000 psi Horizontal Tubing Head 3. 11" x 13-5/8" 5000 psi Double Studded Adapter/Spacer Spool 4. 13-5/8" 5000 psi x 13-5/8' 5000 psi Spacer Spool 5. 13-5/8" 5000 psi Pipe Rams 6. 13-5/8" 5000 psi Drilling Spool with Choke and Kill Lines 7. 13-5/8" 5000 psi Double Ram with Pipe Rams on Top and Blind Rams on Bottom 8. 13-5/8" 5000 psi Annular Preventer Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. BOP Stack Test 1. Fill BOP stack and manifold with water. 2. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi Iow and 3000 psi high. Test as in step 4. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi and 3000 psi for 3 minutes. 9. -'Open pipe rams. Back off running joint a'nd pull out of hole. Close blind rams and test to 3000 psi for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 3000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with Koomey pump. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. ** VBRS will accomodate 3-1/2" to 6" or 4-1/2" to 7" pipe OD's as appropriate ** TAB, 06/15/98, v.1 DIVERTER SCHEIVi TIC Kuparuk River Unit West Sak Operations L 5 DO NOT SHUT-IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES Maintenance & Operation 1. Upon initial installation: Close valve and fill preventer with water to ensure no leaks - Close preventer to verify operation and that the valve opens immediately 2. Close annular preventer in the event that an influx of wellbore fluids or gas is detected. Open valve to achieve diversion ARCO ALASKA, INC. REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" Conductor 2. Slip-on Weld Starting Head 3. Diverter Assembly With One 2-1/16" 2000 psi Ball Valve 4. 20"- 2000 psi Drilling Spool With One 16" Outlet 5. One 16" HCR Knife Valve With 16" Diverter Line. The Valve Opens Automatically Upon Closure Of Annular Preventer. Diverter Line WilI Be Placed For Optimum Dispersion in Prevailing Wind Conditions 6. 20" - 2000 psi Annular Preventer TAB, 06/12/98, v.2 ARCO Alaska, Inc. - Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor Sept 3, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill West Sak 1D-112 West Sak Phase lB Development Well, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the West Sak interval from 1D pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the West Sak sands in the vicinity of 1 D pad. The well is designated as a monobore production well using a single 7 5/8" casing string, with 3-1/2" tubing. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). Note the 40 acre spacing requirements governed by the West Sak Pool Rules. 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). Note that due to the pressures expected in the West Sak sands, ARCO proposes to test the 5000 psi BOP equipment to a maximum of 3000 psi, pending AOGCC approval per this letter and APD. Please note that due to the large number of KRU and West Sak wells which have penetrated the West Sak sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at WS 1D-112, such as shallow gas. There have been ten (10) Kuparuk wells and (22) West Sak wells drilled from KRU 1D pad, and no occurrences of shallow gas or other hazards have been observed. There is a gas sand at approximately 2,100' TVD which is present, but has not caused any past problems in the existing wells which penetrated this sand using a diverter system only. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. 10) Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. Please note that the anticipated spud date for this well is September 17, 1998. If you have any questions or require further information, please contact Scott Goldberg at (907) 263-4622 or Tom McKay at (907) 265-6890. Operations Drilling Engineer CC: West Sak 1D-112 Well File Tom McKay ATO-1202 Keith Lynch ATQ-1228 Cliff Crabtree NSK6 General Procedure: Drill and Case Plan for West Sak 1D-112 (Al) Frac-for-Sand Control Producer 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. 3. Spud and directionally drill 9 7/8" hole to desired target through West Sak interval. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. 5. Run and cement 7 5/8" 29.7# L80 BTC-Mod casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the' cement job. Displace cement with non freezing completion brine, bump the plug and pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results of pressure test NOTE: Weatherford Gemaco Stage Collar will be placed in the 7 5/8" casing +1700' TVD below thesurface. /,~'-[~-~ ~_oo ~ /~,1,~ ~irecO ~o-~'~ e~ 6. Nipple down diverter, nipple up tubing head and BOP's. Test BOP's. i~iotify AOGCC 24 hours before test 7. Rig up and run workstring to TD. Circulate the well with seawater and freeze protect the upper +2000' with diesel 8. Nipple down BOP's. Install production tree and pressure test same. 9. Secure well, release rig 1D-112 (Al) Page I SG,09/03/98,v1 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS West Sak 1 D-112 (Al) Drilling Fluid Type Extended Bentonite Slurry Drilling Fluid Properties: Property Density Plastic Viscosity Yield Point Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to TD Initial 8.8-9.O ppg 4O 15-45 5-20 10-30 8-15 8.0-10.0 4-6 % Spud to TD Final 9.7-10.0 ppg 35 20-35 5-15 10-35 5-10 8.0-9.5 8-12 % Drilling Fluid System: Tandem Brandt Scalping Shale Shakers Triple Derrick Flow Line Cleaners Solids Processing System to Minimize Drilling Waste Desander, Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Mud Hoppers with Mixing Pumps *Spud mud should be adjusted to a FV between 200 - 250 sec/qt to drill gravel beds. Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Only one hole section will be drilled in this well. This single hole section will be drilled using a diverter system only for well control. A 7 5/8" surface / production casing string will be run to total depth (TD). This combination surface / production casing will be cemented to surface. A Weatherford Stage Collar will be placed at approximately 1700' TVD. This will be used as a contingency if cement is not brought to surface as planned. MASP (Maximum Anticipated Surface Pressure): Since a separate string of surface casing is not planned for the West Sak 1D-112 (Al) well, there is no surface casing to be drilled out below requiring a BOP stack to be utilized. The combination surface / production hole to be drilled from surface through the West Sak pay zone can safely be drilled using a diverter system only for well control purposes. 1D-112 (Al) Page I SG,09/03/98,v.1 Based on actual well test data from the nearby WSI-01 well, expected reservoir pressures in the West Sak sands in the 1D pad area vary from 0.43 to 0.46 psi/fi, or 8.2 to 8.8 ppg F:MW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.7' ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 3,62?' MD/TVD. Experience in the area has proven that these zones can be safely drilled using a diverter system only for well control purposes. The rig diverter system will be filled with water or mud and function tested prior to spudding the well. Since the combination surface / production casing will not be drilled out, leakoff test and MASP calculations are not necessary for drilling ahead. However, MASP calculations for cased hole operations are in order. Calculating MASP based on the highest recorded reservoir pressure from the WS1-01 well, and assuming a gas gradient of 0.11 psi/fi from the West Sak base to surface, the following MASP can be computed: MASP - (4034 ft)(0.46-0.11 psi/fi) - 1412 psi Based on this calculation for MASP, it will only be necessary to test the BOP equipment to a maximum of 3,000 psi. Following the cementing of the ? $/8" combination surface / production casing in this well, the casing will be pressure tested for 30 minutes at a surface pressure of 3,000 psi. The ? 5/8" 29.?# 1.80 BTC casing to be used has a burst rating of 6,890 psi; 70 % of this burst rating is 4,823 psi. Drilling Area Risks: Drilling risks in the West Sak 1D-112 (Al) area are limited to lost circulation and potential borehole instability in and below the permafrost formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous Drill Site 1D drilling results, 10.0 ppg mud should be more than adequate to control both the Ugnu and West Sak formation pressures without resulting in lost circulation. Well Proximity Risks: The nearest existing well to West Sak 1D-112 (Al) is 1D-03. As designed, the minimum distance between the two wells would be 12.9' at 378' MD. Annular Pumping Activities: Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface / production casing annulus of a permitted existig~-w~S-1-D_~, hat annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in ~~-tions. The West Sak 1D-112 (Al) surface casing will be filled with diesel and/or non-freezing brine after cleaning out the 7 5/8" casing and prior to the drilling rig moving off of the well. 1D-112 (Al) Page 2 SG,09/03/98,v.1 Wes Sak 1D-112 (Al) Produder Well Four (4) Stage Frac-for-Sand Control Completion 16" Conductor Casing @ 80' 3-1/2" Production Tubing 9.3# L-80 EUE 8RD-Mod Raychem Heat Trace (through permafrost) Weatherford Gemoco 754HO 7-5/8" DV Stage Collar Stnd. Grade BTC Threads (set +/- 200' TVD below permafrost) Power Cable for ESP Centrilift Camco 3-1/2" x 1" 'KBMM' Gas Lift Mandrel Arctic Lift 3500 psi Shear circulating valve pro-loaded in GLM (circulate well for freeze protection purposes) ESP Pump Section Centrilift ESP Gearbox Centrilift 7-5/8" Casing Marker Joint 29.7# L-80 BTC-Mod (set +/- 50' above top perforation) ESP Motor Section Centrilift D Sand Frac'd with Resin Coated Proppant B + A4 Sands Frac'd with Resin Coated Proppant A3 Sand Frac'd with Resin Coated Proppant 7-5/8" Combination Surface/Production Casing, 29.7# L-80 BTC-MOD Cemented to Surface (+/- 8331' MD / 4119' TVD) A2 Sand Frac'd with Resin Coated Proppant ARCO Alaska, Inc. ASG, 09/03/98, v.2 Completion Plan for West Sak 1D-112 (Al) Frac-for-Sand Control Producer Four-Stage, Frac-for-Sand Control Completion (Off Rig Fracs) General Procedure: Well Preparation 1. Rig up frac equipment on well, and pressure test lines and production tree. Pull back pressure valve, and pressure test tubing and annulus. 2. Rig up E-line unit, and make correlation run as required with GR/CCL to correlate logs for perforating. NOTE: The number of stages frac'd may decrease from four (4) to three (3) depending on log results and final completion design strategy. Stage 1 3. Rig up thru-tubing perf guns for Stage 1 frac job which includes the West Sak A2 sands. RIH with peri guns, and position guns on depth. 4. Perforate Stage 1 overbalanced, and POOH with E-line. . . . Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 1 interval. Mix epoxy / resin coated proppant and perform frac-for-sand control frac job on Stage 1 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage 1 from Stage 2 to follow. Pressure test sand plug as required. RIH with slickline and confirm sand top above Stage 1 peris. Use CTU as required to jet sand plug top to desired PBTD. Stage 2 . Rig up thru-tubing peri guns for Stage 2 frac job which includes the West Sak A3 sands. RIH with peri guns, and position guns on depth. 9. Perforate Stage 2 overbalanced, and POOH with E-line. 10. 11. 12. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 2 interval. Mix epoxy / resin coated proppant and perform frac-for-sand control frac job on Stage 2 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage 2 from Stage 3 to follow. Pressure test sand plug as required. RIH with slickline and confirm sand top above Stage 2 peris. Use CTU as required to jet sand plug top to desired PBTD. Stage 3 13. Rig up thru-tubing peri guns for Stage 3 frac job which includes the West sands. RIH with peri guns, and position guns on depth. 14. Perforate Stage 3 overbalanced, and POOH with E-line. 1 D-112 (Al) Page 2 Sak A4 and B SG,09/03/98,v1 15. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 3 interval. 16. Mix epoxy / resin coated proppant and perform frac-for~sand control frac job on Stage 3 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage 3 from Stage 4 to follow. Pressure test sand plug as required. 17. RIH with slickline and confirm sand top above Stage 3 perfs. Use CTU as required to jet sand plug top to desired PBTD. Stage 4 18. Rig up thru-tubing perf guns for Stage 4 frac job which includes the West Sak D sands. RIH with perf guns, and position guns on depth. 19. Perforate Stage 4 overbalanced, and POOH with E-line. 20. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 4 interval. 21. Mix epoxy / resin coated proppant and perform frac-for-sand control frac job on Stage 4 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage 4 from tubing tail. Pressure test sand plug as required. 22. RIH with slickline and confirm sand top below tubing tail. Use CTU as required to jet sand plug top to desired PBTD. 23. Set back pressure valve in tubing hanger, pressure test production tree and secure well. Release frac, E-line, CTU, and slickline equipment as required. Pull Deadstrinq, Clean Out Well, Run ESP and Production Tubinq 24. MIRU completion rig on well. Nipple down production tree and nipple up BOP stack on wellhead. Install 3-1/2" rams unless VBR's are available. Pressure test BOP stack to 3,000 psi. 25. Pull back pressure valve. Pull tubing hanger and circulate well to clean brine as required. TOH and lay down deadstring. Pick up rock bit and casing scraper and TIH with workstring. Clean out sand plugs, proppant, and perforating debris to PBTD below base of West Sak interval. Circulate well to clean brine. TOH with workstring. Pick up Centrilift ESPCP (progressive cavity ESP) motor, seal assembly, and tubing crossover on 3-1/2" production tubing. Run in well with ESPCP motor assembly with power cable and data gathering information wire attached to tubing. Attach Raychem heat trace cable to tubing at pre-determined depth to position bottom of heat trace below permafrost, and spaced out correctly to avoid surface splicing of heat trace cable. 26. 27. 28. 29. 30. 31. 32. 33. 1D-112 (Al) Page 3 SG,09/03/98,v1 34. Position ESPCP at desired depth, set tubing hanger and run electrical penetrators through same. 35. Make surface electrical connections as required, and set back pressure valve in tubing hanger. 36. Nipple down BOP stack, and nipple up production tree. Pressure test production tree. Secure well. 37. Release rig and turn well over to production. Note: For E-line retrievable ESPCP pumps, the pump components may be run in the well with slickline after the completion rig has released from the well. 1D-112 (Al) Page 4 SG,09/03/98,v1 DIVERTER SCHEM, ]'IC Kuparuk River Unit West Sak Operations 2 DO NOT SHUT-IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES Maintenance & Operation 1. Upon initial installation: - Close valve and fill preventer with water to ensure no leaks - Close preventer to verify operation and that the valve opens immediately 2. Close annular preventer in the event that an influx of wellbore fluids or gas is detected. Open valve to achieve diversion ARCO ALASKA, INC. REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" Conductor 2. Slip-on Weld Starting Head 3. Diverter Assembly With One 2-1/16" 2000 psi Ball Valve 4. 20"- 2000 psi Drilling Spool With One 16" Outlet 5. One 16" HCR Knife Valve With 16" Diverter Line. The Valve Opens Automatically Upon Closure Of Annular Preventer. Diverter Line WilI Be Placed For Optimum Dispersion in Prevailing Wind Conditions 6. 20"- 2000 psi Annular Preventer TAB, 06/12/98, v.2 '-5/8" 5000 psi BOP S =k Kuparuk River Unit West Sak Operations - Producer Wells 4 3 2 I 1. 16" Starting Head 2. 11" 5000 psi Horizontal Tubing Head 3. 11" x 13-5/8" 5000 psi Double Studded Adapter/Spacer Spool 4. 13-5/8" 5000 psi x 13-5/8" 5000 psi Spacer Spool 5. 13-5/8" 5000 psi Pipe Rams 6. 13-5/8" 5000 psi Drilling Spool with Choke and Kill Lines 7. 13-5/8" 5000 psi Double Ram with Pipe Rams on Top and Blind Rams on Bottom 8. 13-5/8" 5000 psi Annular Preventer Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. BOP Stack Test 1. Fill BOP stack and manifold with water. 2. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi Iow and 3000 psi high. Test as in step 4. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi and 3000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 3000 psi for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 3000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with Koomey pump. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. ** VBRS will accomodate 3-1/2" to 6" or 4-1/2" to 7" pipe OD's as appropriate ** TAB, 06/15/98, v.1 Oe0ted by ~',,e FOR: GOLDBERG Dote plotted: 1-Sep-g8 Plot Reference is WS 10-112/A2 Vers. ~5. Coordinates are ;n feet reference stat ~112. True Ver~col Depths ore reference RK8 (Parker 440 880 1320 1760 0 2200 (D 2640 3080 I V .3520 3960 4400 4840 ARCO Alaska, Inc. Structure : Pod 1D Well : 112 Field : Kuporuk River Unit Location : North Slope, Alaska <- West (feet) 5000 4500 4000 5500 3000 2500 2000 1500 1000 I I I I I I I I 1 I I I t I I I I TD LOCATION: [~/ TD - Casing Pt 110' FSL, 476' FWL 4%'k~. Base West Sak Sands Base West Sok Sands I SEC 14, T11N, RIOE I f % TARGET - Wes( Sok A3 __ kx'~- ITARGET LOCATION: ] Top West Sak Sands'.k 481' FNL, 930' FWL ~ ISEC 14, T11N, RIOE J X. TVD=3768 %. TMD=7507 ~ DEP=61 06 NORTH 4815 322.06 AZIMUTH ) WES75754 6106' (TO TARGET To, Ugnu Sands 'RKB ELEVATION 112' KOP TVD=250 TMD=250 DEP=O 8 01 BEGIN TURN / CONTINUE BUILD -PFD=333 TMD=333 DEP=2 X Bose Permafrost 1'3.53 19.33 DLS: 6.00 deg per 100 ft ?5.22 ,37.10 49.04 60.99 ~ OC EOC TVD= 1146 TMD= 1363 0EP=549 'xNNEOC Begin Turn to Target B / PERMAFROST TVD=1656 TMD=2558 DEP=1630 270 Az AVERAGE ANGLE SURFACE LOCATION: 16' FNL, 596' FEL 64.74 DEG sec 23, TllN, RIOE TARGET ANGLE 64.74 T / UGNU SNDS TVD=3040 TMD=5801 DEP=4-563 I / W SAK SNDS TVD=3627 TMD=7177 DEP=5807 TARGET - A3 TVD=3768 TMD=7507 DEP=61 B / W SAK SNDS TVD=4034 TMD=8131 DEP=6670 TD - CSG PT TVD=4119 TMD=8531 DEP=6851 I i I I I I I I I I i I I I I i I I I I i I I I i I i i i 440 880 1320 1760 2200 2640 5080 3520 3960 4400 4840 5280 5720 6160 6600 Vertical Section (feet) -> Azimuth 322.06 with reference 0.00 N, 0.00 E from slot #112 500 0 ~ I I 6000 5500 5000 4500 4000 3500 3000 2500 2000 1500 1000 500 0 A I i i i i 7040 7480 Z 0 Cr~o~eO ~ ~ FOR: GOLDBERG Date platted : I-Sap-§8 Prat Reference is WS 1D-112/A2 Vets. ~5. Ceo~d[notes ere ~n feet reference slot #112. True Vertk:el Depths ore relerence R~KB (Perker 45O 420 390 360 300 270 24O 210 180 150 120 90 6O 9O ARCO Alaska, Inc Structure : Pad 1D Well : 1 12 Field : Kuparuk River Unit Location : North Slope, Alaska '~'0~ 600 1 400 "-~o¢---~: ~, ~ ~__kYo~ ~;oo ~oo~ ~oo ~oo ~ ~2400 ....... ,~.900 I I I { I i i I I I I I I i i i i i i I i I i i i I I I i I I 360 ~50 300 270 240 210 180 150 120 gO 60 30 0 30 60 go <- West (feet) 45O 420 39O 360 330 300 27O 240 A 210 I z o 180 -~ 150 ._]_ 120 9O 9O C~,o~¢~ ~,~,~ FOR: GOLDBERG Oate p~otted : !-Sep-98 [:)lot Reference is ~ 1D-112/~ Vers. ~5. Ca~Motes ore in ~e~ reference s~o[ ~112. r~e ve~l Oepth~ are ref~ence ~B (Park~ ~245 Alaska, Inc. Structure : Pad 1D Well: 1 12 Field : Kuparuk River Unit Location : North Slope, Alaska 1900 1800 1700 1600 1500 1400 1300 1200 1100 '+~ 1000 0 7 900 800 700 600 500 400 300 <- West (feet) 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 600 500 400 300 200 100 II I IIIIIllllllllll_l I I I l I Ill -,, '~ 2100 4100 \ ¢100~ 3900 \ "\,. '\ 3700 \ ,, ",\ \\,, x,,,, 3500 , % 1gO0 ~ 1700 , '",,,, 2100 '"\,,,,, ~ 3900 · 3300 \, '",,,,, ',\ ", 65® \ \ '"", ",,,, ' ~ 1 ~0 ""x,. 3100 \i ~1700 ",~ \,, 2900 ~ 5500 '\ 1900 k,,,,,,, ~ 1500 5300 ',,,,,,,, '~ 1700 " 2700 '\ '"" '"\ 51 O0 ""- 2300 "' ',,, "- \ 2500 ~ "-, ',, 1700 ', '~-.~300 ""'"'"'"'"".., 1500 ~ ~ ' "'"""~:`' '"'\\\~, L ~ "%~7© ~ "".% X ", '~100 '- ..................... ~ '"-. 11C i i i I I I I I I I I i I I I I I I i I i I i I I I I i I 1700 1600 1500 1400 1500 ~200 1100 1000 900 800 700 600 500 400 300 200 100 <- West (feet) 19OO 18o0 1700 1600 1500 140o 1500 1200 I z o 1100 ~ 1000 ---t- 900 800 7OO 600 500 400 5OO C~ot~ ~ ~,~e FOR: GOLDBERG Dote p~otted : I-Sep-gB Plot Reference is WS 1B-112/A2 Vets. CaordMotes or~ in feet reference slot ~112. T~Je Verticol Depths ore reference P~8 (Parker ARCO Alaska, Inc. Structure : Pod 1D Well: 1 12 Field : Kuparuk River Unit Location : North Slope, Alaskc <- West (feet) 4680 4420 4160 3900 3640 3380 3120 2860 2600 2340 2080 1820 1560 1300 1040 780 520 5720 ~ ~ ~ ~ ~ i ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ t ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 5720 5460 5200 4940 4680 4420 4160 A 3900 '+- 3640 3380 0 Z 3120 2860 260O 2340 2080 1820 1560 1300 4000"", 3800~.,, 3600~, [~.4200 ',°.4000 %.3800 '-~ 3600 '-%5400 '-A 3200 "~ 3000 3406"., 4200 ",,,,,,, 4000 3200"".. 5800 \', 3600 · '"'",,, 3400 3000'%, ",,, 3200 2800'~,, 4200 ~ 4000 g 3aoo ,~ 3600 ~ 3400 ~ 3200 '~ 3000 3000 , 1~ 4000 ~ 3800 ",, 3600 ~ 2800 340d \,, 3200~ ~"\ 3ood · '~ 2600 \ 2800~ " 4200 "-~ 3800 28~O-~.3400 2600% '~ 3200 · '~,3000 '",.,\ "-~ 2800 2600 "., ,~ 24oo ',, 2200 4800 5460 ',. 2800 2400",, '~,2600 , ~"- '", '", 2400 _'~-"..~_".~ 2600 ,,, % 2000 4000'%,,.',, 99n~ 2400 \, ' 3800'%",.````- ~ .... " x '\ ' ,...\ 3200'"'"-~.,. '", k '\u...v..~ 800 , .... "%2800 '~, % '", '"'" 2600 'X k 1800 . i ] i I I I t I i I I I I I I i I I II I I i I I i I 4680 4420 4160 3900 3640 3380 3120 2860 2600 2340 2080 1820 1560 1300 1040 780 520 <- West (feet) 5200 4940 4680 4420 4160 39oo A Z 3640 0 ._[._ 3380 --i- 3120 ~ 2860 2600 2340 2080 1820 1560 1300 ARCO Alaska, Inc. Sfrucfure : Pod 1D Well: 112 Field : Kuparuk River Unif Location : North Slope, Alaska WELL PROFILE ..... Point ..... MO '~e an O.00 KOP 250.00 ~,.~'~ Turn to Tcrget 5,3,~.3'~ End ef Build/Turn 1562.88 Target WS lO-A1 Rvsd 2 75O7.22 nd of Hdd 8130.54, .0. & End of Hold 8550.54 DATA Inc Dir TVO Nar~hEast 0.00 270.000.00 ~3.(30 (3.00 o.oa 270.0025Q.00~3.CO0.(~ 5.0(3 270.0O333.250.~O -3.65 64.74-322.46114~.82 ~39.4la -568.13 64,74-322.463768.00 4815.45 --3754-.43 64.74-322.464034.00 5262,40 -4097.95 64.74-322.464119.35 54~5.82 -4208.17 340 330 520 V. Sect Oe~/lo0 O.{3~ 0.00 O.GD 2.23 6.O0 549.286.OO 6106.09 0.O0 6669.79 0.00 6850.66 0.O0 350 TRUE NORTH 0 10 2O 310 C~o~ed ~ ~ FOR: GOLDBERG Dote p~otted : 1-$ep-98 Plot Reference [s WS 10-112/~ Vers. ~5. C~rdinotes crc in feet r~cnce slot ~112. V~c~l Depths ore r~erence RKB (Porker ~2~5). 3O 40 -'~ 100 -"~i/--~ 1 ........... ./ ~oo..-' 50 300 290 '60 70 280 270 8O 9O 260 100 25O 110 240 900 210 200 190 ~oo <~ 300 ~00 150 140 160 180 170 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well ARCO Alaska, Inc. Pad 1D 112 slot #112 Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES Baker Hughes INTEQ Your ref , WS 1D-112/A2 Vets. #5 Our ref : prop221A License : Date printed : 1-Sep-98 Date created : 17-Apr-9? Last revised : 23-Jul-98 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on n?0 18 1.316,w149 30 18.908 Slot location is nT0 18 1.158,w149 30 36.284 Slot Grid coordinates are N 5959648.687, E 560491.090 Slot local coordinates are 16.00 S 596.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. Pad 1D,112 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S 0.00 0.00 270.00 0.00 0.00 N 0.00 E 250.00 0.00 270.00 250.00 0.00 N 0.00 E 333.33 5.00 270.00 333.23 0.00 S 3.63 W 400.00 8.01 294.03 399.47 1.89 N 10.79 W 500.00 13.53 307.18 497.68 11.81 N 26.48 W PROPOSAL LISTING Page 1 Your ref : WS 1D-112/A2 Vets. #5 Last revised : 23-Jul-98 Dogleg Vert Deg/100ft Sect 0.00 0.00 0.00 0.00 KOP 6.00 2.23 Begin Turn to Target 6.00 8.12 6.00 25.60 600.00 19.33 312.68 593.57 30.11 N 47.98 W 6.00 53.25 700.00 25.22 315.69 686.07 56.60 N 75.05 W 6.00 90.78 800.00 31.15 317.62 774.17 90.98 N 107.40 W 6.00 137.78 900.00 37.10 318.98 856.92 132.88 N 144.66 W 6.00 193.74 1000.00 43.06 320.01 933.40 181.84 N 186.43 W 6.00 258.04 1100.00 49.04 320.84 1002.77 237.33 N 232.26 W 6.00 329.97 1200.00 55.01 321.53 1064.28 298.73 N 281.63 W 6.00 408.75 1300.00 60.99 322.12 1117.24 365.37 N 334.01 W 6.00 493.51 1362.68 64.74 322.46 1145.82 409.49 N 368.13 W 6.00 549.28 EOC 1500.00 64.74 322.46 1204.43 507.95 N 443.81 W 0.00 673.47 2000.00 64.74 322.46 1417.80 866.48 N 719.36 W 0.00 1125.64 2500.00 64.74 322.46 1631.18 1225.01 N 994.91 W 0.00 1577.82 2558.17 64.74 322.46 1656.00 1266.72 N 1026.97 W 0.00 1630.42 Base Permafrost 3000.00 64.74 322.46 1844.55 1583.53 N 1270.47 W 0.00 2029.99 3500.00 64.74 322.46 2057.92 1942.06 N 1546.02 W 0.00 2482.17 4000.00 64.74 322.46 2271.30 2300.59 N 1821.57 W 0.00 2934.34 4500.00 64.74 322.46 2484.67 2659.11 N 2097.13 W 0.00 3386.52 5000.00 64.74 322.46 2698.05 3017.64 N 2372.68 W 0.00 3838.69 5500.00 64.74 322.46 2911.42 3376.17 N 2648.24 W 0.00 4290.86 5801.30 64.74 322.46 3040.00 3592.21 N 2814.28 W 0.00 4563.34 Top U~nu Sands 6000.00 64.74 322.46 3124.80 3734.70 N 2923.79 W 0.00 4743.04 6500.00 64.74 322.46 3338.17 4093.22 N 3199.34 W 0.00 5195.21 7000.00 64.74 322.46 3551.55 4451.75 N 3474.90 W 0.00 5647.39 7176.81 64.74 322.46 3627.00 4578.53 N 3572.34 W 0.00 5807.~9 Top West Sak Sands 7500.00 64.74 322.46 3764.92 4810.28 N 3750.45 W 0.00 6099.56 7507.20 64.74 322.46 3767.99 4815.43 N 3754.42 W 0.00 6106.07 TARGET - A3 7507.22 64.74 322.46 3768.00 4815.45 N 3754.43 W 0.00 6106.09 WS 1D-A1 Rvsd 22-Jan-98 8000.00 64.74 322.46 3978.29 5168.80 N 4026.01 W 0.00 6551.74 8130.54 64.74 322.46 4034.00 5262.40 N 4097.95 W 0.00 6669.79 Base West Sak Sands 8330.54 64.74 322.46 4119.35 5405.82 N 4208.17 W 0.00 6850.66 TD - Casing Pt All data is in feet unless otherwise stated. Coordinates from slot #112 and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 6850.66 on azimuth 322.10 degrees from wellhead. Total Dogleg for wellpath is 66.76 degrees. Vertical section is from wellhead on azimuth 322.06 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,112 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : WS 1D-112/A2 Vets. #5 Last revised : 23-Jul-98 Comments in we11path __~============= MD TVD Rectangular Coords. Comment 250 333 1362 2558 5801 7176 7507 7507 8130 8330 00 250 33 333 68 1145 17 1656 30 3040 81 3627 20 3767 22 3768 54 4034 54 4119 00 0.00 N 23 0.00 S 82 409.49 N 00 1266.72 N 00 3592.21 N 00 4578.53 N 99 4815.43 N 00 4815.45 N 00 5262.40 N 35 5405.82 N 0.00 E KOP 3.63 W Begin Turn to Target 368.13 W EOC 1026.97 W Base Permafrost 2814.28 W Top Ugnu Sands 3572.34 W Top West Sak Sands 3754.42 W TARGET - A3 3754.43 W WS 1D-A1 Rvsd 22-Jan-98 4097.95 W Base West Sak Sands 4208.17 W TD - Casing Pt Casing positions in string 'A' ...... Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 8329.93 4119.09 5405.38N 4207.83W 7 5/8" Casing Targets associated with this we11path Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-A1 Rvsd 22-Jan 556698.000,5964433.000,0.0000 3768.00 4815.45N 3754.43W 14-Apr-97 ARCO Alaska, Inc. Pad 1D,112 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 00 R D I N A T E S 0.00 0.00 270.00 0.00 16.00 S 596.00 250.00 0.00 270.00 250.00 16.00 S 596.00 333.33 5.00 270.00 333.23 16.00 S 599.63 400.00 8.01 294.03 399.47 14.11 S 606.79 500.00 13.53 307.18 497.68 4.19 S 622.48 PROPOSAL LISTING Page 1 Your ref : WS 1D-112/A2 Vers. #5 Last revised : 23-Jul-98 Dogleg Vert Deg/100ft Sect W 0.00 0.00 W 0.00 0.00 KOP W 6.00 2.23 Begin Turn to Target W 6.00 8.12 W 6.00 25.60 600.00 19.33 312.68 593.57 14.11 N 643.98 W 6.00 53.25 700.00 25.22 315.69 686.07 40.60 N 671.05 W 6.00 90.78 800.00 31.15 317.62 774.17 74.98 N 703.40 W 6.00 137.78 900.00 37.10 318.98 856.92 116.88 N 740.66 W 6.00 193.74 1000.00 43.06 320.01 933.40 165.84 N 782.43 W 6.00 258.04 1100.00 49.04 320.84 1002.77 221.33 N 828.26 W 6.00 329.97 1200.00 55.01 321.53 1064.28 282.73 N 877.63 W 6.00 408.75 1300.00 60.99 322.12 1117.24 349.37 N 930.01 W 6.00 493.51 1362.68 64.74 322.46 1145.82 393.49 N 964.13 W 6.00 549.28 1500.00 64.74 322.46 1204.43 491.95 N 1039.81 W 0.00 673.47 2000.00 64.74 322.46 1417.80 850.48 N 1315.36 W 0.00 1125.64 2500.00 64.74 322.46 1631.18 1209.01 N 1590.91 W 0.00 1577.82 2558.17 64.74 322.46 1656.00 1250.72 N 1622.97 W 0.00 1630.42 3000.00 64.74 322.46 1844.55 1567.53 N 1866.47 W 0.00 2029.99 3500.00 64.74 322.46 2057.92 1926.06 N 2142.02 W 0.00 2482.17 4000.00 64.74 322.46 2271.30 2284.59 N 2417.57 W 0.00 2934.34 4500.00 64.74 322.46 2484.67 2643.11 N 2693.13 W 0.00 3386.52 5000.00 64.74 322.46 2698.05 3001.64 N 2968.68 W 0.00 3838.69 5500.00 64.74 322.46 2911.42 3360.17 N 3244.24 W 0.00 4290.86 5801.30 64.74 322.46 3040.00 3576.21 N 3410.28 W 0.00 4563.34 6000.00 64.74 322.46 3124.80 3718.70 N 3519.79 W 0.00 4743.04 6500.00 64.74 322.46 3338.17 4077.22 N 3795.34 W 0.00 5195.21 7000.00 64.74 322.46 3551.55 4435.75 N 4070.90 W 0.00 5647.39 7176.81 64.74 322.46 3627.00 4562.53 N 4168.34 W 0.00 5807.29 7500.00 64.74 322.46 3764.92 4794.28 N 4346.45 W 0.00 6099.56 EOC Base Permafrost Top Ugnu Sands Top West Sak Sands 7507.20 64.74 322.46 3767.99 4799.43 N 4350.42 W 0.00 6106.07 TARGET - A3 7507.22 64.74 322.46 3768.00 4799.45 N 4350.43 W 0.00 6106.09 WS 1D-A1 Rvsd 22-Jan-98 8000.00 64.74 322.46 3978.29 5152.80 N 4622.01 W 0.00 6551.74 8130.54 64.74 322.46 4034.00 5246.40 N 4693.95 W 0.00 6669.79 Base West Sak Sands 8330.54 64.74 322.46 4119.35 5389.82 N 4804.17 W 0.00 6850.66 TD - Casing Pt All data is in feet unless otherwise stated. Coordinates from SE Corner of Sec. 14, T11N, R10E and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 6850.66 on azimuth 322.10 degrees from wellhead. Total Dogleg for wellpath is 66.76 degrees. Vertical section is from wellhead on azimuth 322.06 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,112 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTIN0 Page 2 Your ref : WS 1D-112/A2 Vets. #5 Last revised : 23-Jul-98 Comments in wellpath MD TVD Rectangular Coords. Comment 250.00 333.33 1362 68 2558 17 5801 30 7176 81 7507 20 7507 22 8130 54 8330 54 250.00 333.23 1145.82 1656 00 3040 00 3627 00 3767 99 3768 00 4034 O0 4119.35 16.00 S 16.00 S 393.49 N 1250.72 N 3576.21 N 4562.53 N 4799.43 N 4799.45 N 5246.40 N 5389.82 N 596.00 W KOP 599.63 W Begin Turn to Target 964.13 W EOC 1622.97 W Base Permafrost 3410.28 W Top Ugnu Sands 4168.34 W Top West Sak Sands 4350.42 W TARGET - A3 4350.43 W WS 1D-A1 Rvsd 22-Jen-98 4693.95 W Base West Sak Sands 4804.17 W TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 16.00S 596.00W 8329.93 4119.09 5389.38N 4803.83W 7 5/8" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-A1 Rvsd 22-Jan 556698.000,5964433.000,0.0000 3768.00 4799.45N 4350.43W 14-Apr-97 ARCO Alaska, Inc. Pad 1D,112 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTIN~ Page 1 Your ref : WS 1D-112/A2 Vets. #5 Last revised : 23-Jul-98 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Vert Ellipse Semi Axes Minor Depth Degrees Degrees Depth C 0 0 R D I N A T E S Sect Major Minor Vert. Azi. 0.00 0.00 270.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 0.00 N/A 250.00 0.00 270.00 250.00 0.00 N 0.00 E 0.00 0.65 0.65 0.38 N/A 333.33 5.00 270.00 333.23 0.00 S 3.63 W 2.23 0.91 0.87 0.50 270.00 400.00 8.01 294.03 399.4? 1.89 N 10.79 W 8.12 1.20 1.06 0.60 283.67 500.00 13.53 307.18 497.68 11.81 N 26.48 W 25.60 1.95 1.36 0.76 298.02 600.00 19.33 312.68 593.57 30.11 N 47.98 W 53.25 3.18 1.72 0.94 305.17 700.00 25.22 315.69 686.07 56.60 N 75.05 W 90.78 4.94 2.14 1.15 309.46 800.00 31.15 317.62 774.17 90.98 N 107.40 W 137.78 7.25 2.61 1.43 312.32 900.00 37.10 318.98 856.92 132.88 N 144.66 W 193.74 10.13 3.12 1.79 314.36 1000.00 43.06 320.01 933.40 181.84 N 186.43 W 258.04 13.59 3.65 2.26 315.90 1100.00 49.04 320.84 1002.77 237.33 N 232.26 W 329.97 17.61 4.19 2.85 317.09 1200.00 55.01 321.53 1064.28 298.73 N 281.63 W 408.75 22.17 4.71 3.54 318.05 1300.00 60.99 322.12 1117.24 365.37 N 334.01 W 493.51 27.21 5.19 4.35 318.84 1362.68 64.74 322.46 1145.82 409.49 N 368.13 W 549.28 30.54 5.47 4.89 319.25 1500.00 64.74 322.46 1204.43 507.95 N 443.81 W 673.47 37.86 6.09 6.09 319.89 2000.00 64.74 322.46 1417.80 866.48 N 719.36 W 1125.64 64.64 8.31 10.51 320.97 2500.00 64.74 322.46 1631.18 1225.01 N 994.91 W 1577.82 91.50 10.52 14.96 321.41 2558.17 64.74 322.46 1656.00 1266.72 N 1026.97 W 1630.42 94.62 10.78 15.47 321.44 3000.00 64.74 322.46 1844.55 1583.53 N 1270.47 W 2029.99 118.37 12.73 19.40 321.65 3500.00 64.74 322.46 2057.92 1942.06 N 1546.02 W 2482.17 145.26 14.93 23.85 321.80 4000.00 64.74 322.46 2271.30 2300.59 N 1821.57 W 2934.34 172.15 17.14 28.30 321.91 4500.00 64.74 322.46 2484.67 2659.11 N 2097.13 W 3386.52 199.04 19.34 32.75 321.98 5000.00 64.74 322.46 2698.05 3017.64 N 2372.68 W 3838.69 225.93 21.55 37.20 322.04 5500.00 64.74 322.46 2911.42 3376.17 N 2648.24 W 4290.86 252.83 23.75 41.65 322.08 5801.30 64.74 322.46 3040.00 3592.21 N 2814.28 W 4563.34 269.04 25.08 44.34 322.10 6000.00 64.74 322.46 3124.80 3734.?0 N 2923.79 W 4743.04 279.73 25.96 46.10 322.12 6500.00 64.74 322.46 3338.17 4093.22 N 3199.34 W 5195.21 306.62 28.16 50.56 322.15 7000.00 64.74 322.46 3551.55 4451.75 N 3474.90 W 5647.39 333.52 30.36 55.01 322.17 7176.81 64.74 322.46 3627.00 4578.53 N 3572.34 W 5807.29 343.03 31.14 56.58 322.18 7500.00 64.74 322.46 3764.92 4810.28 N 3750.45 W 6099.56 360.42 32.57 59.46 322.19 7507.20 64.74 322.46 3767.99 4815.43 N 3754.42 W 6106.07 360.81 32.60 59.52 322.19 7507.22 64.74 322.46 3768.00 4815.45 N 3754.43 W 6106.09 360.81 32.60 59.52 322.19 8000.00 64.74 322.46 3978.29 5168.80 N 4026.01 W 6551.74 387.32 34.77 63.91 322.21 8130.54 64.74 322.46 4034.00 5262.40 N 4097.95 W 6669.79 394.34 35.34 65.07 322.22 8330.54 64.74 322.46 4119.35 5405.82 N 4208.17 W 6850.66 405.10 36.23 66.86 322.22 All data is in feet unless otherwise stated. Coordinates from slot #112 and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 6850.66 on azimuth 322.10 degrees from wellhead. Vertical section is from wellhead on azimuth 322.06 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,112 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : WS 1D-112/A2 Vets. #5 Last revised : 23-Jul-98 POSITION UNCERTAINTY SUMMARY Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 8331 ARCO (H.A. Mag) User specified 405.10 36.23 66.86 1. Ellipse dimensions are half axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. Comments in wellpath MD TVD Rectangular Coords. Comment 250.00 250.00 0.00 N 333.33 333.23 0.00 S 1362.68 1145.82 409.49 N 2558.17 1656.00 1266.72 N 5801.30 3040.00 3592.21 N 7176.81 3627.00 4578.53 N 7507.20 3767.99 4815.43 N 7507.22 3768.00 4815.45 N 8130.54 4034.00 5262.40 N 8330.54 4119.35 5405.82 N 0.00 E KOP 3.63 W Begin Turn to Target 368.13 W E0C 1026.97 W Base Permafrost 2814.28 W Top Ugnu Sands 35?2.34 W Top West Sak Sands 3754.42 W TARGET - A3 3754.43 W WS 1D-A1 Rvsd 22-Jan-98 4097.95 W Base West Sak Sands 4208.17 W TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 8329.93 4119.09 5405.38N 4207.83W 7 5/8" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-A1 Rvsd 22-Jan 556698.000,5964433.000,0.0000 3768.00 4815.45N 3754.43W 14-Apr-97 ARCO Alaska, Inc. Pad 1D,112 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref = WS 1D-112/A2 Vets. #5 Last revised = 23-Jul-98 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C O O R D S Depth Degrees Degrees Depth C O O R D I N A T E S Deg/100ft Sect Easting Northing 0.00 0.00 270.00 0.00 0.00N 0.00E 0.00 0.00 560491.09 5959648.69 250.00 0.00 2?0.00 250.00 0.00N 0.00E 0.00 0.00 560491.09 5959648.69 333.33 5.00 270.00 333.23 0.00S 3.63W 6.00 2.23 560487.46 5959648.66 400.00 8.01 294.03 399.4? 1.89N 10.79W 6.00 8.12 560480.29 5959650.49 500.00 13.53 307.18 497.68 11.81N 26.48W 6.00 25.60 560464.52 5959660.28 600.00 19.33 312.68 593.57 30.11N 47.98W 6.00 53.25 560442.87 5959678.40 700.00 25.22 315.69 686.07 56.60N 75.05W 6.00 90.78 560415.59 5959704.67 800.00 31.15 317.62 774.17 90.98N 107.40W 6.00 137.78 560382.97 5959738.78 900.00 37.10 318.98 856.92 132.88N 144.66W 6.00 193.74 560345.37 5959780.37 1000.00 43.06 320.01 933.40 181.84N 186.43W 6.00 258.04 560303.20 5959828.99 1100.00 49.04 320.84 1002.77 237.33N 232.26W 6.00 329.97 560256.94 5959884.09 1200.00 55.01 321.53 1064.28 298.73N 281.63W 6.00 408.75 560207.07 5959945.08 1300.00 60.99 322.12 1117.24 365.37N 334.01W 6.00 493.51 560154.15 5960011.29 1362.68 64.74 322.46 1145.82 409.49N 368.13W 6.00 549.28 560119.68 5960055.13 1500.00 64.74 322.46 1204.43 507.95N 443.81W 0.00 673.47 560043.21 5960152.97 2000.00 64.74 322.46 1417.80 866.48N 719.36W 0.00 1125.64 559764.78 5960509.21 2500.00 64.74 322.46 1631.18 1225.01N 994.91W 0.00 1577.82 559486.35 5960865.45 2558.17 64.74 322.46 1656.00 1266.72N 1026.97W 0.00 1630.42 559453.95 5960906.90 3000.00 64.74 322.46 1844.55 1583.53N 1270.47W 0.00 2029.99 559207.91 5961221.69 3500.00 64.74 322.46 2057.92 1942.06N 1546.02W 0.00 2482.17 558929.48 5961577.93 4000.00 64.74 322.46 2271.30 2300.59N 1821.57W 0.00 2934.34 558651.05 5961934.17 4500.00 64.74 322.46 2484.67 2659.11N 2097.13W 0.00 3386.52 558372.62 5962290.41 5000.00 64.74 322.46 2698.05 3017.64N 2372.68W 0.00 3838.69 558094.18 5962646.65 5500.00 64.74 322.46 2911.42 3376.17N 2648.24W 0.00 4290.86 557815.75 5963002.89 5801.30 64.74 322.46 3040.00 3592.21N 2814.28W 0.00 4563.34 557647.97 5963217.56 6000.00 64.74 322.46 3124.80 3734.70N 2923.79W 0.00 4743.04 557537.32 5963359.13 6500.00 64.74 322.46 3338.17 4093.22N 3199.34W 0.00 5195.21 557258.89 5963715.38 7000.00 64.74 322.46 3551.55 4451.75N 3474.90W 0.00 5647.39 556980.45 5964071.62 7176.81 64.74 322.46 3627.00 4578.53N 3572.34W 0.00 5807.29 556881.99 5964197.59 7500.00 64.74 322.46 3764.92 4810.28N 3750.45W 0.00 6099.56 556702.02 5964427.86 7507.20 64.74 322.46 3767.99 4815.43N 3754.42W 0.00 6106.07 556698.01 5964432.98 7507.22 64.74 322.46 3768.00 4815.45N 3754.43W 0.00 6106.09 556698.00 5964433.00 8000.00 64.74 322.46 3978.29 5168.80N 4026.01W 0.00 6551.74 556423.59 5964784.10 8130.54 64.74 322.46 4034.00 5262.40N 4097.95W 0.00 6669.79 556350.90 5964877.10 8330.54 64.74 322.46 4119.35 5405.82N 4208.17W 0.00 6850.66 556239.52 5965019.60 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #112 and TVD from RF~B (Parker %245) (112.00 Ft above mean sea level). Bottom hole distance is 6850.66 on azimuth 322.10 degrees from wellhead. Total Dogleg for wellpath is 66.76 degrees. Vertical section is from wellhead on azimuth 322.06 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,112 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : WS 1D-112/A2 Vets. #5 Last revised : 23-Jul-98 Comments in wellpath MD TVD Rectangular Coords. Comment 250.00 250.00 0.00N 0.00E KOP 333.33 333.23 0.00S 3.63W Begin Turn to Target 1362.68 1145.82 409.49N 368.13W EOC 2558.17 1656.00 1266.72N 1026.97W Base Permafrost 5801.30 3040.00 3592.21N 2814.28W Top Ugnu Sends 7176.81 3627.00 4578.53N 3572.34W Top West Sak Sands 7507.20 3767.99 4815.43N 3754.42W TARGET - A3 7507.22 3768.00 4815.45N 3754.43W WS 1D-A1 Rvsd 22-Jen-98 8130.54 4034.00 5262.40N 4097.95W Base West Sak Sands 8330.54 4119.35 5405.82N 4208.17W TD - Casing Pt Casing positions in string 'A' ============================== Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 8329.93 4119.09 5405.38N 4207.83W 7 5/8" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-A1 Rvsd 22-Jan 556698.000,5964433.000,0.0000 3768.00 4815.45N 3754.43W 14-Apr-97 ARCO Alaska, Inc. Pad 1D 112 slot #112 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : WS 1D-112/A2 Vets. #5 Our ref : prop2214 License : Date printed : 1-Sep-98 Date created : 17-Apr-97 Last revised : 23-Jul-98 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 30 18.908 Slot location is nT0 18 1.158,w149 30 36.284 Slot Grid coordinates are N 5959648.687, E 560491.090 Slot local coordinates are 16.00 S 596.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object we11path PMSS <0 - 6270'>,,114,Pad 1D PMSS <377 - 6224'>,,134,Pad 1D PMSS <0 - 6472'>,,131,Pad 1D PMSS <467 - 5802'>,,132,Pad 1D PMSS <0-4414 PMSS <0-4530 PMSS <0-4515 PMSS <0-4590 PMSS <0-5205 PMSS <0-4850 PMSS <0-5126 >,,121,Pad 1D >,,120,Pad 1D >,,119,Pad 1D >,,118,Pad 1D >,,liT,Pad 1D >,,109,Pad 1D >,,106,Pad 1D PMSS <381-6092'>,,105,Pad 1D PMSS <1957-5265'>,,133,Pad 1D PMSS <0-5015'>,,135,Pad 1D PMSS <0-5047'>,,124,Pad 1D TOTCO Survey,,WS-8,Pad 1D PGMS <0-8365'>,,1,Pad 1D PGMS <0-8930'>,,5,Pad 1D PGMS <0-8610'>,,6,Pad 1D MSS <3311-8200'>,,7,Pad 1D PMSS <556-7024'>,,9,Pad 1D PMSS <0 - 7340'>,,10,Pad 1D PMSS <O-5462'>,,129,Pad 1D PMSS <0-4778'>,,130,Pad 1D PMSS <0 - 6716'>,,126,Pad 1D PMSS <0 - 7432'>,,127,Pad 1D PGMS <O-9783'>,,2,Pad 1D PGMS <O-7502'>,,4,Pad 1D Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 27-Aug-98 30.0 100.0 100.0 3-Aug-98 494.2 312.5 6680.0 23-Jul-98 405.0 100.0 100.0 6-Aug-98 420.0 120.0 120.0 2-Jun-98 164.1 333.3 333.3 2-Jun-98 149.5 333.3 333.3 2-Jun-98 134.1 333,3 333.3 2-Jun-98 90.0 100.0 100.0 2-Jun-98 73.0 355.6 355.6 2-Jtul-98 66.2 640.0 640.0 2-Jun-98 104.6 680.0 680.0 2-Jun-98 149.5 500.0 500.0 2-Jun-98 432.1 333.3 333.3 2-Jun-98 510.0 120.0 312.5 2-Jun-98 253.2 355.6 355.6 21-May-98 587.0 333.3 333.3 10-Dec-97 186.2 900.0 900.0 13-Nov-97 227.1 20.0 333.3 13-Nov-97 347.0 20.0 20.0 6-Nov-97 467.0 333.3 333.3 29-Apr-98 119.8 333.3 333.3 28-Apr-98 540.0 120.0 120.0 2-Jun-98 374.3 312.5 312.5 2-Jun-98 389.9 333.3 333.3 1-Jul-98 283.8 333.3 333.3 6-Jul-98 298.4 312.5 312.5 4-Aug-92 115.0 640.0 640.0 4-Aug-92 107.1 20.0 333.3 PMSS <O-5142~),,115,P~-~'lD PMSS <0 - 6580'>,,128,Pad 1D PMSS <291 - 5795~>,,125,Pad 1D PG~IS <0-8070~,,3,Pa~ 1D PMSS <0 - 5445~>,,122,Pad 1D PMSS<O-?O45~>,,111,Pad 1D 2-jun-98 17-Au~-98 19-Aug-98 13-Au~-98 29-Aug-98 31-Au~-98 3'7.5 314.4 26'7.5 12.9 180.0 32.4 480.0~/ 333.3 333.3 377.8 100.0 606.8 480.0 333.3 333.3 377.8 100.0 4560.0 WELL PERMIT CHECKLIST FIELD & POOL .............. ._.~__.~_.~_..~.~___~' . ADMINISTRATION 1. Permit fee attached ....................... Y 2. Lease number appropriate ................... Y 3. Unique well name and number .................. Y 4. Well located in a defined pool .................. Y 5. Well located proper distance from drilling unit boundary .... Y 6. Well located proper distance from other wells .......... Y 7. Sufficienl acreage available in drilling unit ............ Y 8. If deviated, is wellbore plat included ............... Y 9. Operator only affected party ................... Y 10. Operator has appropriate bond in force ............. Y 11. Permit can be issued without conservation order ........ Y ,~ ,,~2,~/~ 12. Permit can be issued without administrative approval ...... Y 13. Can permit be approved before 15-day wait ........... Y,Y) WELL NAME ,,/~,~.~/" ./2~/~--_/,,,/..2_ PROGRAM: exp [] dev/~/redrll [] serv [] wellbore segll ann. disposal para req,l . AREA ~'"~ ~ UNIT# / //",,,/~"~ ON/OFF SHORE ~,,~ ENGINEERING DATE __ INIT CLASS ,/'~ . //.~o,~.~___ ........ GEOL 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 string to surf csg ........ 18. CMl- will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... ~ N 20. Adequate tankage or reserve pit ................. ~~N'-~ 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. (~ N 23. If diverter required, does it meet regulations .......... ~)O N 24. Drilling fluid program schematic & equip list adequate ..... ,,~N 25. BOPEs, do they meet regulation ................ ~,/'N 26. BOPE press rating appropriate; test to ~O psig. (~ N N 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Is presence of H2S gas probable ................. Y (N___.) Work will occur without operation shutdown ........... 29. ~. ~/~e~ Y N./,? 31. Data presented on potential overpressure zones ....... 32. Seismicanalysisofshallowgaszones ' /~v'~ 33. Seabed condition survey (if off-shore) ............ 34. Contact nam, e/phon,e.for weekly progress reports ...... [exploratory omyj GEOLOGY APPf~, DA E ANNULAR DISPOSAL 35. With proper cementing records, ti"tis plan (A) will contain waste in a suitable receiving zone; ....... APPR [)ATE (B) will not contaminate freshwater; or cause drilling waste... to surface; .......................... (C) will not impair mechanical integrity of the well used for disposal' (D) will not damage producing formation or impair recovery from a ................................ po(fi; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular JDH.-.~ ~ COMMISSION: DW~~,._./ RNC----"~L]~O co _~o '~/L~ .... Comments/Instructions: McheMisl le, v 0512(JIgB Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to, simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. -. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan ~tility Fri Oct 23 13:46:50 1998 Reel Header Service name ............. LISTPE Date ............ - ......... 98/10/23 Origin ................ - .... STS Reel Name ............... '.UNKNOWN Continuation Number ...... 01 Previous Reel~ame. o-~...UNKNoWN Comments ................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/10/23 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Comment Record TAPE HEADER -~ KUPARUK RIVER UNIT, WEST MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 1 AK-MM- 80379 S. BURKHARDT D. LUTRICK 1D-112 500292291900 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 23-0CT-98 MWD RUN 2 A/f-MM- 80379 P. SMITH D. BREEDEN 23 liN 10E 16 596 .00 OPT,.,, o8 Ivvo Alas~-;a Oit & Gas ©~s. Commissio~ Anchorage DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 112.10 70.60 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 8250.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 3. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN ALI TURKER OF SPERRY-SUN DRILLING SERVICES AND MIKE WERNER OF ARCO ALASKA, INC. ON 13 OCTOBER, 1998. 4. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8250'MD 4104'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 FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NLIMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH FET RPD 121.0 8204.0 RPM 121.0 8204.0 RPS 121.0 RPX 121.0 GR 121.0 ROP 121.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: 8204.0 8204.0 8211.5 8249.5 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 121.0 4186.0 2 4186.0 8250.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 RPX MWD OHMM 4 1 68 8 3 RPS MWD OPIMM 4 1 68 12 4 RPM MWD OHMM 4 1 68 16 5 RPD MWD OPIMM 4 1 68 20 6 ROP MWD FT/H 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name Min Max DEPT 121 8249.5 GR 7.4113 134.592 RPX 0.488 2000 RPS 0.4573 2000 RPM 0.1709 2000 RPD 0.1255 2000 . ROP 14.1349 656.25 FET 0.087 10.4041 Mean Nsam 4185.25 16258 65.2484 16182 39.5483 16167 52.6298 16167 69.1009 16167 111.855 16167 246.599 16258 0.44449 16167 First Reading 121 121 121 121 121 121 121 121 Last Reading 8249.5 8211.5 8204 8204 8204 8204 8249.5 8204 First Reading For Entire File .......... 121 Last Reading For Entire File ........... 8249.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/23 Maximum 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 ........... 1.0.0 Date of Generation ....... 98/10/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE N-UMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 121.0 4140.0 RPD 121.0 4140.0 RPM 121.0 4140.0 RPS 121.0 4140.0 RPX 121.0 4140 . 0 GR 121.0 4147.5 ROP 121.0 4186 . 0 $ LOG HEADER DATA DATE LOGGED: 19-SEP-98 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: .0 ISC 5.06 CIM 5.46/EWP4 1.38 MEMORY 4186.0 121.0 4186.0 MAXIMUM ANGLE: 69.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 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 .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER P1063CRG6 P1063CRG6 9.880 9.9 SPUD 9.70 219.0 8.5 300 5.2 4.500 3.670 5.500 3.300 30.6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 API 4 1 68 4 2 RPX MWD 1 OHMM 4 1 68 8 3 RPS MWD 1 OHMM 4 1 68 12 4 RPM MWD 1 OHMM 4 1 68 16 5 RPD MWD 1 OHMM 4 1 68 20 6 ROP MWD 1 FT/H 4 1 68 24 7 FET MWD 1 HOUR 4 1 68 28 8 Name Min Max Mean DEPT 121 4186 2153.5 GR 13.1506 134.592 64.5272 RPX 0.488 2000 67.8009 RPS 0.4573 2000 93.2041 RPM 0.8005 2000 126.633 RPD 0.7003 2000 211.798 ROP 39.0109 656.25 254.167 FET 0.0876 5.3502 0.347098 Nsam 8131 8054 8039 8039 8039 8039 8131 8039 First Reading 121 121 121 121 121 121 121 121 Last Reading 4186 4147.5 4140 4140 4140 4140 4186 4140 First Reading For Entire File .......... 121 Last Reading For Entire File ........... 4186 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/23 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 ....... 98/10/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FET 4141.0 RPX 4141.0 RPD 4141.5 RPM 4141.5 RPS 4141.5 GR 4149.5 STOP DEPTH 8204.0 8204.0 8204.0 8204.0 8204.0 8211.5 ROP 4187.5 $ 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: 8249.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA R3kY EWR4 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: MtTD 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 .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined 21-SEP-98 ISC 5.06 CIM 5.46/EWP4 1.38 MEMORY 8250.0 4186.0 8250.0 57.8 67.1 TOOL NUMBER P1063CGR6 P1063CGR6 9.880 9.9 LSND 9.70 235.0 8.6 300 4.8 3.600 2.564 3.500 3.200 38.4 Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 GR MWD 2 API 4 1 RPX MWD 2 OHMM 4 1 RPS MWD 2 OHMM 4 1 RPM MWD 2 OHMM 4 1 RPD MWD 2 OHMM 4 1 ROP MWD 2 FT/H 4 1 FET MWD 2 HOUR 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 Name Min Max Mean DEPT 4141 8249.5 6195.25 GR 7.4113 129.869 65.9707 RPX 1.771 103.851 11.605 RPS 1.7636 125.397 12.4993 RPM 0.1709 119.081 12.199 RPD 0.1255 119.586 13.0065 ROP 14.1349 650.774 239.031 FET 0.087 10.4041 0.540227 First Last Nsam Reading Reading 8218 4141 8249.5 8125 4149.5 8211.5 8127 4141 8204 8126 4141.5 8204 8126 4141.5 8204 8126 4141.5 8204 8125 4187.5 8249.5 8127 4141 8204 First Reading For Entire File .......... 4141 Last Reading For Entire File ........... 8249.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/10/23 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Reel Trailer Service name ............. LISTPE Date ..................... 98/10/23 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Library. Scientific Physical EOF Physical EOF End Of LIS File