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Home My WebLink About197-2131. 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: ESP/PCP/Replace Tubing Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 5462'feet 4457', 5290'feet true vertical 4003' feet None feet Effective Depth measured 4457'feet 4405', 4880'feet true vertical 3034'feet 2986', 3451'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 4865' 3436' Packers and SSSV (type, measured and true vertical depth)4405' 4880' 2986' 3451' 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: 4984-4999' (slots), 5009-5024' (slots), 5010-5038', 5039-5049' (slots), 5070-5090', 5079-5089' (slots), 5116-5133', 5119-5129' (slots), 5156- 5166', 5159-5169' (slots), 5183-5193', 5199-5209' (slots), 5239-5249' (slots), 5252-5283', 5279-5289' (slots) 3555-3570', 3580-3595', 3581-3609', 3610-3620', 3641-3661', 3650-3660', 3687-3704', 3690-3700', 3727-3737', 3730-3740', 3754-3764', 3770-3780', 3810-3820', 3823-3853', 3850-3860' 324-421 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. Packer: ESP Feed Thru Packer: Baker SC-1 Gravel Pack SSSV: None Shane Germann shane.germann@conocophillips.com (907) 263-4597CTD Engineer 410' 4-1/2" 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 MDSize 121' Well Shut-In measured TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 197-213 50-029-22830-00-00 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: ADL0025650 Kuparuk River Field/ West Sak Oil Pool KRU 1D-129 Plugs Junk measured Length Gravel Pack Liner Casing 5290' 3861' 5412' 121'Conductor Surface 16" 7-5/8" 80' 5453' 4023' Burst Collapse Fra O s 6. A PG , C g Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Gas-Mcf By Grace Christianson at 8:51 am, Oct 02, 2024 Digitally signed by Shane Germann DN: O=ConocoPhillips, CN=Shane Germann , E=shane.germann@conocophillips.com Reason: I am the author of this document Location: Date: 2024.10.01 15:56:51-08'00' Foxit PDF Editor Version: 13.0.0 Page 1/7 1D-129 Report Printed: 9/30/2024 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 06:00 8/28/2024 12:00 6.00 MIRU, MOVE MOB P Moving pits and rig from 1D-112 to 1D- 129 0.0 0.0 8/28/2024 12:00 8/28/2024 13:30 1.50 MIRU, WELCTL MOB P Back rig sub over 1D-129. Back pits up to rig sub. Spot the kill tank and cutting tank and MU hardline. 0.0 0.0 8/28/2024 13:30 8/28/2024 17:00 3.50 MIRU, WELCTL MOB P Taking on filtered 10.2 ppg brine. and rig accept at 13:00. 0.0 0.0 8/28/2024 17:00 8/28/2024 17:30 0.50 MIRU, WELCTL KLWL P Reverse circulate 100 BBLS of 10.2 brine until clean returns at surface. Pump @ 2.5 BBL/min @ 1905 PSI. 0.0 0.0 8/28/2024 17:30 8/28/2024 18:00 0.50 MIRU, WELCTL KLWL P Bull head 85 BBLS down tubing @ 4 BBL/MIN @ 953 PSI. 0.0 8/28/2024 18:00 8/28/2024 20:00 2.00 MIRU, WELCTL KLWL P Montior well, observe flow, and trend only slightly decreasing. Shut in well and observe pressure build from 90 PSI to 120 PSI on gage. Consult town for plan forward. 8/28/2024 20:00 8/28/2024 20:30 0.50 MIRU, WELCTL KLWL P Line up and bull head 80 more barrels down tubing. 4 BBL/ Min @ 950 PSI. 8/28/2024 20:30 8/28/2024 22:00 1.50 MIRU, WELCTL OWFF P Relax well. 8/29/2024 00:00 8/29/2024 00:15 0.25 MIRU, WELCTL KLWL P Continue to monitor well. Trend stabalized @ 1-2 BBL/ every 5 min. 0.0 0.0 8/29/2024 00:15 8/29/2024 01:30 1.25 MIRU, WELCTL KLWL P Shut in tubing, and IA. PJSM to circulate and kill well. Suck out tiger tank. Spot, and prepare trucks. 0.0 0.0 8/29/2024 01:30 8/29/2024 02:30 1.00 MIRU, WELCTL KLWL P Reverse circulate 120 BBLS of 10.2 Brine, until good returns to surface. Shut in to tiger tank and bleed IA to 0. IA on slight Vac. 0.0 0.0 8/29/2024 02:30 8/29/2024 03:30 1.00 MIRU, WELCTL KLWL P Line up on tubing and bullhead 180 BBLS of 10.2 Brine. FCP 1000 PSI. Shut in and monitor pressures for 10 min. Observe tubing pressure drop. 0.0 0.0 8/29/2024 03:30 8/29/2024 04:30 1.00 MIRU, WELCTL KLWL P Line IA to tiger tank and bleed pressure from bull heading. Shut in IA. Line up tubing to tiger tank, and bleed to tiger tank. IA bled back 11.5 BBLS Tubing bleed back 0.0 0.0 8/29/2024 04:30 8/29/2024 05:00 0.50 MIRU, WELCTL OWFF P Flow check 30 min: Static. 0.0 0.0 8/29/2024 05:00 8/29/2024 06:00 1.00 MIRU, WELCTL OWFF P RU to install BPV. Open tubing back up to run BPV and slight pressure again, bleed it off. Decide to perform another 30 flow check. 0.0 0.0 8/29/2024 06:00 8/29/2024 07:00 1.00 MIRU, WELCTL MPSP P Set BPV and perform a rolling test from below to 1000 psi. Let IA bleed off and stop flowing. 0.0 0.0 8/29/2024 07:00 8/29/2024 08:00 1.00 MIRU, WHDBOP RURD P BD lines to tiger tank. RD lines in cellar. Prep for nipple down tree. MU sling to top drive for pulling tree. 0.0 0.0 8/29/2024 08:00 8/29/2024 09:30 1.50 MIRU, WHDBOP NUND P ND Tree and hang in corner of cellar. 0.0 0.0 8/29/2024 09:30 8/29/2024 11:30 2.00 MIRU, WHDBOP NUND P NU BOPE to wellhead. 0.0 0.0 8/29/2024 11:30 8/29/2024 13:00 1.50 MIRU, WHDBOP RURD P RU test charts, MU XO to donut test joints. MU blank sub to top drive. Flood stack.Grease valves on stack. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 9/4/2024 Page 2/7 1D-129 Report Printed: 9/30/2024 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) 8/29/2024 13:00 8/29/2024 17:30 4.50 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" & 4-1/2"Test joint. Did not test LPR. 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=3050 PSI, after closure=1635 PSI, 200 PSI attained =20 sec, full recovery attained =140 sec. 5 back up nitrogen bottles average =2150 PSI. Function tested. UPR=5 Sec, LPR=5 Sec Annular=24 Sec. Simulated Blinds=5, HCR Kill=1 Sec. HCR Choke=1 Sec. Test gas detectors, P.V.T. and flow show. Test witnessed waived by AOGCC rep Josh Hunt. 0.0 0.0 8/29/2024 17:30 8/29/2024 19:00 1.50 COMPZN, RPCOMP RURD P R/D test equipment, blow down and clear lines. 0.0 0.0 8/29/2024 19:00 8/29/2024 19:30 0.50 COMPZN, RPCOMP THGR P BOLDS. R/U HAL spooler, and Summit ESP cable spooler. P/U landing joint and M/U to hanger. 0.0 0.0 8/29/2024 19:30 8/29/2024 21:30 2.00 COMPZN, RPCOMP THGR T Repair stripped gland nut. 0.0 0.0 8/29/2024 21:30 8/29/2024 21:45 0.25 COMPZN, RPCOMP OTHR P Unseat hanger, P/U to 110K see weight release. P/U again to 165K Again observe 0.0 0.0 8/29/2024 21:45 8/29/2024 23:15 1.50 COMPZN, RPCOMP CIRC P Attempt to Circ around 10.2 brine. @ 4 BBL/Min @ 700 PSI, no returns. 0.0 0.0 8/29/2024 23:15 8/30/2024 00:00 0.75 COMPZN, RPCOMP CIRC P Relax tubing and IA. 0.0 0.0 8/30/2024 00:00 8/30/2024 00:30 0.50 COMPZN, RPCOMP OWFF P Relax Tubing and IA. 0.0 0.0 8/30/2024 00:30 8/30/2024 01:00 0.50 COMPZN, RPCOMP OTHR P Open annular, and fill backside w/ approx 8 bbls. Work string up and down 5' to verify packer released, and relax element or remove debris. Line up and pump dumping returns to the cuttings box to verify circ path. SOWT: 70 K, PUWT 90 K 2 BBL/Min @ 210 PSI. 0.0 4,868.0 8/30/2024 01:00 8/30/2024 01:15 0.25 COMPZN, RPCOMP CIRC P R/U lines to test spool. Monitor well at rotary table. Well on slight vac. 4,868.0 4,868.0 8/30/2024 01:15 8/30/2024 02:30 1.25 COMPZN, RPCOMP CIRC P Close annular. Line up to pump down tubing taking returns out the test spool valve to the tiger tank 10.2 returned to surface. Pump @ 3.5 BBL/Min @ 650 PSI 4,868.0 4,868.0 8/30/2024 02:30 8/30/2024 03:30 1.00 COMPZN, RPCOMP CIRC P Open annular break circulation and finish surface to surface strokes taking returns back to the pits 4,868.0 4,868.0 8/30/2024 03:30 8/30/2024 04:00 0.50 COMPZN, RPCOMP OWFF P Observe bleed back with pumps off. Diminishing trend from 4 BBL/5 min to 1.2 BBL/5 min in first 15 min. Rate remained at 1.2 BBL/ 5 min for second 15 min. 4,868.0 4,868.0 Rig: NABORS 7ES RIG RELEASE DATE 9/4/2024 Page 3/7 1D-129 Report Printed: 9/30/2024 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) 8/30/2024 04:00 8/30/2024 06:30 2.50 COMPZN, RPCOMP CIRC P Circulate bottoms up @ 590 PSI/ 2.5 BPM 4,868.0 4,868.0 8/30/2024 06:30 8/30/2024 09:30 3.00 COMPZN, RPCOMP OWFF P Flow checked the well. Taking returns to the trip tank in 10 minutes intervals. Trended down to a stop. 4,868.0 4,868.0 8/30/2024 09:30 8/30/2024 10:30 1.00 COMPZN, RPCOMP THGR P Pull hanger to the floor, terminate wires and control line. RU third party spooling units and their equipment. Breakout of hanger and LD landing joint. 4,868.0 4,851.0 8/30/2024 10:30 8/30/2024 11:00 0.50 COMPZN, RPCOMP SVRG P Replaced damaged hardware in slips 4,851.0 4,851.0 8/30/2024 11:00 8/30/2024 20:00 9.00 COMPZN, RPCOMP PUTB P LD 4-1/2" completion F/ 4851' T/91.92' 4,851.0 92.0 8/30/2024 20:00 8/30/2024 21:30 1.50 COMPZN, RPCOMP PUTB P B/D and L/D ESP assy F/ 92' to surface. ALC pump Can connection to pup joint bellow loose. 92.0 0.0 8/30/2024 21:30 8/30/2024 23:00 1.50 COMPZN, RPCOMP OTHR P R/D HAL Tech wire spooler, and other equipment, R/D Summit ESP, and spool remaining cable. Clean and clear rig floor. Recovdered 15 SS Bands, and 155 clamps. 0.0 0.0 8/30/2024 23:00 8/31/2024 00:00 1.00 COMPZN, RPCOMP OTHR P M/U wear ring running tool. Set wear bushing. 0.0 0.0 8/31/2024 00:00 8/31/2024 00:30 0.50 COMPZN, RPCOMP OTHR P Change out elavators, and prepare equipment. 0.0 0.0 8/31/2024 00:30 8/31/2024 01:00 0.50 COMPZN, RPCOMP BHAH P P/U BHA #1 (Clean out BHA) F/ surface to 37.38 Static losses while not tripping in of out. 0.0 37.4 8/31/2024 01:00 8/31/2024 02:30 1.50 COMPZN, RPCOMP PULD P RIH F/ 37.38' to 1046' P/U drill pipe. 37.4 1,046.0 8/31/2024 02:30 8/31/2024 02:45 0.25 COMPZN, RPCOMP OTHR P Unnanounced kick while tripping drill. Drill performed with motor man running the rig. Well secure in 1 min 20 seconds. AAR held with crew. 1,046.0 1,046.0 8/31/2024 02:45 8/31/2024 08:30 5.75 COMPZN, RPCOMP PULD P Cont. RIH w/ BHA # 1 F/ 1,046' to 4870'. PUWT 99K SOWT 70K 1,046.0 4,870.0 8/31/2024 08:30 8/31/2024 09:00 0.50 COMPZN, RPCOMP CIRC P Circulate and rotate F/4430' T/4520' 4 BPM at 400 psi. TQ2900, ROT 76K /PUW 90K / SOW 68K Pumped a bottoms up. 4,870.0 4,870.0 8/31/2024 09:00 8/31/2024 11:00 2.00 COMPZN, RPCOMP TRIP P TOOH F/4870' T/37'. PUW 99K Losses 7 bph while tripping out of hole 4,870.0 37.0 8/31/2024 11:00 8/31/2024 11:30 0.50 COMPZN, RPCOMP BHAH P LD clean out BHA. Static losses while not tripping in of out. 37.0 0.0 8/31/2024 11:30 8/31/2024 12:00 0.50 COMPZN, RPCOMP SVRG P Insepect and grease crown, blocks and washpipe. 0.0 0.0 8/31/2024 12:00 8/31/2024 13:00 1.00 COMPZN, RPCOMP BHAH P PU test packer BHA. 0.0 16.5 8/31/2024 13:00 8/31/2024 14:30 1.50 COMPZN, RPCOMP TRIP P TIH with test packer to 4553' PUW 89K SOW 65K Losses 5 BPH while RIH. 16.5 4,553.0 8/31/2024 14:30 8/31/2024 15:00 0.50 COMPZN, RPCOMP MPSP P Set packer at 4548' COE and PT casing to 2500 psi for 5 min and chart. Good test. 4,553.0 4,553.0 8/31/2024 15:00 8/31/2024 21:00 6.00 COMPZN, RPCOMP PULD P POOH LD drillpipe to pipe shed F4853' T/16.5' Losses 7 bph while POOH. 4,553.0 16.5 Rig: NABORS 7ES RIG RELEASE DATE 9/4/2024 Page 4/7 1D-129 Report Printed: 9/30/2024 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) 8/31/2024 21:00 8/31/2024 21:30 0.50 COMPZN, RPCOMP BHAH P L/D test packer. 16.5 0.0 8/31/2024 21:30 8/31/2024 22:00 0.50 COMPZN, RPCOMP OTHR P Pull wear ring. 0.0 0.0 8/31/2024 22:00 9/1/2024 00:00 2.00 COMPZN, RPCOMP RURD P R/U spooler, and Summit ESP lines, and sheaves. R/U equipment to run 3.5" 9.3# ESP completion. Load completions equipment into the pipe shed. PJSM w/ Service providers, and crew. Lost 106 BBL total for day. 0.0 0.0 9/1/2024 00:00 9/1/2024 01:15 1.25 COMPZN, RPCOMP ALFT P P/U motor guide with centralizer, intake sensor and motor. Install cap tube on sensor, and purge Dielectric oil through motor assy. 0.0 31.0 9/1/2024 01:15 9/1/2024 03:30 2.25 COMPZN, RPCOMP ALFT P PU Tandem seal sections align splines, stab onto motor, and torque flange bolts. come down to ESP cable connection on Motor, and attach cable lead. purge Dielectric oil through tandem seal assy. RIH. 31.0 52.4 9/1/2024 03:30 9/1/2024 04:00 0.50 COMPZN, RPCOMP ALFT P P/U and M/U Recieving base, spacer pups two joints of 3.5" 9.3# EUE tubing, and discharge adaptor w/ spacer pup. 52.4 134.8 9/1/2024 04:00 9/1/2024 07:00 3.00 COMPZN, RPCOMP ALFT P Connect cap tube to discharge adaptor. P/U 1 full joint of tubing. Summit ESP cut ESP Cable lead and make splice. 134.8 134.8 9/1/2024 07:00 9/1/2024 13:00 6.00 COMPZN, RPCOMP ALFT P PU to packer, splice ESP and tec wire through packer. 134.8 460.0 9/1/2024 13:00 9/1/2024 19:00 6.00 COMPZN, RPCOMP ALFT P MU and RIH from packer at 460' to tubing hanger at 2817'. Average losses of 6 bph 460.0 2,817.0 9/1/2024 19:00 9/1/2024 21:30 2.50 COMPZN, RPCOMP ALFT T Crew set slips on ESP cable. Cut and splice cable. 2,817.0 2,817.0 9/1/2024 21:30 9/1/2024 23:30 2.00 COMPZN, RPCOMP ALFT T Test ESP cable. Intake sensor not reading during test. Summit ESP trouble shoot gauge reading. 2,817.0 2,817.0 9/1/2024 23:30 9/2/2024 00:00 0.50 COMPZN, RPCOMP ALFT T P/U to splice. Cut splice to verify no communication to intake sensor. 0 Reading from intake sensor, Discharge sensor reading 1371 PSI. 2,817.0 2,817.0 9/2/2024 00:00 9/2/2024 01:30 1.50 COMPZN, RPCOMP ALFT T Cut splice, connect to ESP cable and trouble shoot. 2,817.0 2,817.0 9/2/2024 01:30 9/2/2024 06:00 4.50 COMPZN, RPCOMP ALFT T POOH racking back 3.5" tubing F/2880' T/ESP UWT 55K / DWT 48K 2,817.0 0.0 9/2/2024 06:00 9/2/2024 14:00 8.00 COMPZN, RPCOMP ALFT T Terminate ESP cabke F/packer feed through to ESP sheave. LD ESP completion. Disassemble ESP pump as per Summit. CO ESP reels. Purge ESPMotor w/oil. Swap ESP reel. 0.0 0.0 9/2/2024 14:00 9/2/2024 17:00 3.00 COMPZN, RPCOMP ALFT T Install ESP clamps on ESP motor. Tie into ESP motor. Service motor. Check cable voltage. Low voltage reading on cable. 0.0 90.0 Rig: NABORS 7ES RIG RELEASE DATE 9/4/2024 Page 5/7 1D-129 Report Printed: 9/30/2024 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) 9/2/2024 17:00 9/2/2024 19:30 2.50 COMPZN, RPCOMP ALFT T POOH F/ 90' to 70'. Test lead cable, poor voltage. Remove from motor, check voltage through cable. 650 mega ohms. Check voltage on motor itself 703 mega ohms. Connect cable to motor, and check voltage at surface 703 mega ohms. Suspected water ingress to head of cable, or connection to motor. Change out lead cable. Check voltage 703 mega ohms. 90.0 70.0 9/2/2024 19:30 9/2/2024 22:00 2.50 COMPZN, RPCOMP ALFT T Refill motor assy, and seal assy w/ oil. Check voltage 653 Mega ohms. P/U discharge adapter and 2 joints of 3.5" EUE tubing. Check voltage 460 Mega ohms. 70.0 150.0 9/2/2024 22:00 9/3/2024 00:00 2.00 COMPZN, RPCOMP ALFT T Summit splice flat wire from spool to lead cable. Check voltage from spool to cable. 420 Mega ohms (8000' of cable added). 150.0 150.0 9/3/2024 00:00 9/3/2024 00:30 0.50 COMPZN, RPCOMP ALFT T Summit ESP finish splice from lead cable to ESP cable spool. 150.0 150.0 9/3/2024 00:30 9/3/2024 01:15 0.75 COMPZN, RPCOMP ALFT T P/U HAL gauge mandrel, and M/U. HAL reps attach gauge, and pressure test to 10K for 5 min. Summit ESP test cable. 590 mega ohms. 150.0 180.0 9/3/2024 01:15 9/3/2024 03:00 1.75 COMPZN, RPCOMP ALFT T Cont. to RIH picking up 3.5" ESP completion. 180.0 453.0 9/3/2024 03:00 9/3/2024 09:00 6.00 COMPZN, RPCOMP ALFT T Summit ESP make splice at top and bottom of the packer. HAL make tech wire splice at packer. Test ESP cable before splice: 1.61 giga watts. Test ESP cable after splice: 453.0 453.0 9/3/2024 09:00 9/3/2024 15:15 6.25 COMPZN, RPCOMP ALFT T RIH F/ 453' to 2817' W/ 3.5" 9.3# L-80 EUE completion. Test ESP cable every 500'. HAL constantly monitoring TECH wire, and gauge. 453.0 2,817.0 9/3/2024 15:15 9/3/2024 20:30 5.25 COMPZN, RPCOMP ALFT P Cont. RIH RIH F/ 453' to 2817' W/ 3.5" 9.3# L-80 EUE completion. Test ESP cable every 500'. HAL constantly monitoring TECH wire, and gauge. SOWT: 55K PUWT: 75K Cannon clamps: 162 Half Clamps: 6 Seal Clamps: 4 Motor clamps: 4 Splice clamp: 1 GLM clamps: 4 2,817.0 4,865.0 Rig: NABORS 7ES RIG RELEASE DATE 9/4/2024 Page 6/7 1D-129 Report Printed: 9/30/2024 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) 9/3/2024 20:30 9/4/2024 00:00 3.50 COMPZN, RPCOMP THGR P P/U hanger, and landing joint. Install side port isolation sleeve. Terminate Summit ESP cable, and HAL TECH wire at hanger. HAL final readings before termination at hanger. Tubing: 1677 PSI Temp: 56.7° F IA: 1679 PSI Temp 56.83° F Summit final readings after termination @ hanger Intake PSI: Discharg PSI: Temp: Resistance: 1.71 Giga Ohms 4,865.0 4,865.0 9/4/2024 00:00 9/4/2024 00:30 0.50 COMPZN, RPCOMP THGR P Terminate Summit ESP cable, and HAL TECH wire at hanger. HAL final readings before termination at hanger. Tubing: 1677 PSI Temp: 56.7° F IA: 1679 PSI Temp 56.83° F Summit final readings after termination @ hanger Intake PSI: 1797 PSI Intake temp: 61° F Discharg PSI: 1796 PSI Discharge temp: 61 ° F Resistance: 2.41 Giga Ohms Vibrations X: 0.062 Y: 0.066 4,845.0 4,845.0 9/4/2024 00:30 9/4/2024 03:00 2.50 COMPZN, RPCOMP OTHR T CI fluid brought to location was 10.4 instead of 10.2 PPG. Leak was discovered on truck. Repair truck. R/D ESP sheave. R/D Summit ESP, and HAL equipment on the rig floor. 4,845.0 4,845.0 Rig: NABORS 7ES RIG RELEASE DATE 9/4/2024 Page 7/7 1D-129 Report Printed: 9/30/2024 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) 9/4/2024 03:00 9/4/2024 03:30 0.50 COMPZN, RPCOMP THGR P Land hanger. Vault Rep RILDS. R/U Lines in the cellar. and circulating lines on the rig floor to circulate in CI. Final Summit readings before removing umbilical from hanger. Intake PSI: 1794 PSI Intake temp: 61° F Discharg PSI: 1790 PSI Motor temp: 61 ° F Resistance: 2.38 Giga Ohms Vibrations X: 0.082 Y: 0.070 Final HAL gauge readings Tubing: 1639 PSI Tubing temp 62° F IA: 1640 PSI IA temp: 62° 4,865.0 0.0 9/4/2024 03:30 9/4/2024 04:00 0.50 COMPZN, RPCOMP RURD P R/U Lines in the cellar, and circulating lines on the rig floor to circulate in CI. 0.0 0.0 9/4/2024 04:00 9/4/2024 07:00 3.00 COMPZN, RPCOMP CIRC P Circulate around 10.2 CI brine. 126 GPM GPM @ 200 PSI. 0.0 0.0 9/4/2024 07:00 9/4/2024 07:30 0.50 COMPZN, RPCOMP PACK P Pull isolation sleeve out of hanger. Drop ball and rod 1-5/16" 83" long. Allow to fall for 30 min. 0.0 0.0 9/4/2024 07:30 9/4/2024 08:30 1.00 COMPZN, RPCOMP PRTS P Pressure test tubing to 2500 PSI 30 min: GOOD test. Bleed tubing to 1500 PSI, and hold on tubing. Line up on IA and test IA to 2500 PSI for 30 min: GOOD test. Line up on tubing, and bleed tubing to 0 PSI. Observe SOV shear, and IA bleed to 0 PSI. 0.0 0.0 9/4/2024 08:30 9/4/2024 09:00 0.50 COMPZN, RPCOMP MPSP P Set BPV. Line up and test to 1000 PSI for 10 min: GOOD TEST. 0.0 0.0 9/4/2024 09:00 9/4/2024 16:00 7.00 COMPZN, WHDBOP OTHR P Rig crew perform between wells maintenance of the BOP. 0.0 0.0 9/4/2024 16:00 9/4/2024 17:00 1.00 COMPZN, WHDBOP NUND P N/D BOP, and rack back. 0.0 0.0 9/4/2024 17:00 9/4/2024 17:30 0.50 COMPZN, WHDBOP THGR P Terminate lines at the well head, and test Summit, and HAL lines: GOOD. 0.0 0.0 9/4/2024 17:30 9/4/2024 19:00 1.50 COMPZN, WHDBOP NUND P N/U tree and adaptor flange. 0.0 0.0 9/4/2024 19:00 9/4/2024 20:00 1.00 COMPZN, WHDBOP OTHR P Hal Rep finish termination of line. Vault Rep test upper and lower hanger seals to 5000 PSI for 10 min each: GOOD. 0.0 0.0 9/4/2024 20:00 9/4/2024 20:30 0.50 COMPZN, WHDBOP PRTS P Rig up and test tree to 5000 PSI for 10 min: GOOD. 0.0 0.0 9/4/2024 20:30 9/4/2024 21:30 1.00 DEMOB, MOVE MPSP P Pull test dart, and BPV. Secure cellar. RIG RELEASED @ 2130. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 9/4/2024 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 1D-129 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Post RWO 1D-129 9/8/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: 1D-129 Scale is acid soluable w/ HCl. Used 10% HCl to pull packoff and pump. 5/4/2020 rwocoman NOTE: Repair SC from bottom of starter head to 70" w/ 10" x 65 x .500 wall pipe, OAL=70" 12/9/2012 ninam NOTE: View Schematic w/ Alaska Schematic9.0 1/12/2011 ninam NOTE: ESP WORKOVER 11/13/2003 osborl NOTE: ESP WORKOVER, ADD GRAVEL PACK 9/19/1999 osborl NOTE: ESP WORKOVER 11/22/1997 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 SURFACE 7 5/8 6.87 40.7 5,452.6 4,023.4 29.70 L-80 BTCM Gravel Pack Liner 4 1/2 4.00 4,879.6 5,290.3 3,861.2 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) -0.1 Set Depth 4,865.2 String Max No 4 1/2 Set Depth 3,436.2 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) 38.8 38.8 0.00 Hanger 10.750 Vault PC TUBING HANGER 4.5" x 3.5" EUE 8rd Bottom Vault PC CWCT- F6H 2.950 2,087.2 1,568.3 57.60 Mandrel GAS LIFT 5.430 KBMG 3.5" x 1" DV SN#24982-03 Camco KBMG 2.920 4,350.3 2,935.5 26.05 Mandrel GAS LIFT 5.454 KBMG 3.5" x 1", SOV 2000 psig IA to TBG Shear SN#24982-02 Camco KBMG 2.920 4,405.2 2,985.6 22.29 Packer - Liner 6.670 3.5" x 7-5/8", ESP FEED-THRU PACKER (40K shear to release) Tripoint DLESP 2.940 4,457.1 3,034.2 19.03 Nipple - X 4.495 2.813" X-Nipple w/ RHC SN# 0005011991-11 HES X-Nipple 2.813 4,540.9 3,114.5 14.25 Mandrel GAS LIFT 5.435 KBMG 3.5" x 1", SOV 2400 psig TBG to IA Shear SN#24982-01 Camco KBMG 2.920 4,629.2 3,200.8 9.51 Sleeve - Sliding 5.800 NEXA-2 Sliding Sleeve, SLB, 2.813" X Profile, bypass ports for cable SN:4793119759-01-001 SLB NEXA-2 2.813 4,685.3 3,256.5 5.38 Sensor - Discharge Gauge 4.516 Gauge Mandrel SN# MXM 19710-02 Halliburt on Opsis gauge 2.813 4,735.4 3,306.4 2.33 Discharge Adapter 4.500 Discharge Adapter Summit Discharg e adpator 2.992 4,808.2 3,379.2 1.42 Recieving Base 4.500 Receiving Base &Coupling S/N 4517080004-2 Summit Recievin g base 4,812.7 3,383.7 1.42 Seal Assembly 5.130 Tandem Seal Sections (513BSBS,INC,SB,HD,AFLADS BAG) Summit Tandem seal assy 4,830.6 3,401.6 1.40 Motor 5.130 Adapter 450 motor to 513 Summit Motor adaptor 4,831.1 3,402.1 1.40 Motor 5.620 Motor 450, PPM, LS, 42HP, 948V, 40A, ALIFT S/N 14096448 Summit Perman ent magnet motor 4,862.4 3,433.4 1.37 Motor - Adapter 4.560 Sensor adapter to Motor Summit Motor adaptor 4,862.7 3,433.7 1.37 Sensor - Suction Gauge 4.560 Sensor S/N 14098197 Summit Intake sensor 4,864.5 3,435.5 1.36 Centralizer 6.000 Centrilizer/Motor Guide Summit Centraliz er 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) 4,450.0 3,027.5 19.45 BALL & ROD Ball and rod on seat in X- nipple @ 4457 9/4/2024 0.000 4,457.1 3,034.2 19.03 TUBING PLUG RHC plug body 9/4/2024 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,087.2 1,568.3 57.60 1 GAS LIFT DMY BK 5.43 9/3/2024 2000 PSI shear out valve. Shear ed out 9/4/20 24 CAMCO KBMG 4,350.3 2,935.5 26.05 2 GAS LIFT SOV BEK 5.43 0.0 9/3/2024 0.000 1D-129, 9/30/2024 1:20:00 PM Vertical schematic (actual) SURFACE; 40.7-5,452.6 Gravel Pack Liner; 4,879.6- 5,290.3 SLOTS; 5,279.0-5,289.0 IPERF; 5,252.0-5,282.0 FRAC; 5,252.0 SLOTS; 5,239.0-5,249.0 SLOTS; 5,199.0-5,209.0 APERF; 5,183.0-5,193.0 SLOTS; 5,159.0-5,169.0 APERF; 5,156.0-5,166.0 APERF; 5,116.0-5,133.0 SLOTS; 5,119.0-5,129.0 SLOTS; 5,079.0-5,089.0 FRAC; 5,070.0 FRAC; 5,070.0 IPERF; 5,070.0-5,090.0 SLOTS; 5,039.0-5,049.0 IPERF; 5,010.0-5,038.0 FRAC; 5,010.0 SLOTS; 5,009.0-5,024.0 SLOTS; 4,984.0-4,999.0 Centralizer; 4,864.5 Sensor - Suction Gauge; 4,862.7 Motor - Adapter; 4,862.4 Motor; 4,831.1 Motor; 4,830.6 Seal Assembly; 4,812.7 Recieving Base; 4,808.2 Sleeve - Sliding; 4,629.2 Mandrel GAS LIFT; 4,540.9 TUBING PLUG; 4,457.1 Nipple - X; 4,457.1 BALL & ROD; 4,450.0 Packer - Liner; 4,405.2 Mandrel GAS LIFT; 4,350.3 Mandrel GAS LIFT; 2,087.2 CONDUCTOR; 41.0-121.0 Hanger; 38.8 KUP PROD KB-Grd (ft) 41.00 RR Date 11/29/199 7 Other Elev 1D-129 ... TD Act Btm (ftKB) 5,462.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292283000 Wellbore Status PROD Max Angle & MD Incl (°) 58.37 MD (ftKB) 2,146.26 WELLNAME WELLBORE1D-129 Annotation Last WO: End Date 5/1/2012 H2S (ppm) 0 Date 12/29/2015 Comment SSSV: NONE Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 4,540.9 3,114.5 14.25 3 ESP SOV BEK 5.43 5 9/3/2024 2400 PSI SOV, Not shear ed CAMCO KBMG 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) 4,879.6 3,450.6 1.35 PACKER 6.700 BAKER SC-1 GRAVEL PACKER 4.000 4,884.4 3,455.4 1.34 EXTENSION 5.500 UPPER MILLOUT EXTENSION 4.892 4,888.3 3,459.2 1.34 SLEEVE 5.800 SLIDING SLEEVE 4.892 4,892.3 3,463.3 1.33 EXTENSION 5.500 LOWER MILLOUT EXTENSION 4.000 4,907.7 3,478.7 1.33 XO Reducing 5.000 CROSSOVER 5"x4.5" 4.500 5,289.6 3,860.5 1.09 PLUG 5.540 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 4,984.0 4,999.0 3,555.0 3,570.0 NF, 1D-129 9/19/1999 50.0 SLOTS 4.5" HT .020 Gauge Screen 13.5# 5,009.0 5,024.0 3,580.0 3,595.0 WS D, 1D-129 9/19/1999 50.0 SLOTS 4.5" HT .020 Gauge Screen 13.5# 5,010.0 5,038.0 3,581.0 3,609.0 WS D, 1D-129 12/6/1997 4.0 IPERF 0 deg ph/low side; 2 1/8"EJ 5,039.0 5,049.0 3,610.0 3,620.0 WS C, 1D-129 9/19/1999 50.0 SLOTS 4.5" HT .020 Gauge Screen 13.5# 5,070.0 5,090.0 3,640.9 3,660.9 WS B, 1D-129 12/4/1997 4.0 IPERF 0 deg ph/low side; 2 1/8"EJ 5,079.0 5,089.0 3,649.9 3,659.9 WS B, 1D-129 9/19/1999 50.0 SLOTS 5,116.0 5,133.0 3,686.9 3,703.9 WS A4, 1D-129 9/15/1999 12.0 APERF HSD-BH 4 1/2" 5,119.0 5,129.0 3,689.9 3,699.9 WS B, WS A4, 1D-129 9/19/1999 50.0 SLOTS 4.5" HT .020 Gauge Screen 13.5# 5,156.0 5,166.0 3,726.9 3,736.9 WS A4, WS A3, 1D-129 9/15/1999 12.0 APERF HSD-BH 4 1/2" 5,159.0 5,169.0 3,729.9 3,739.9 WS A3, 1D-129 9/19/1999 50.0 SLOTS 4.5" HT .020 Gauge Screen 13.5# 5,183.0 5,193.0 3,753.9 3,763.9 WS A3, 1D-129 9/15/1999 12.0 APERF HSD-BH 4 1/2" 5,199.0 5,209.0 3,769.9 3,779.9 WS A3, WS A2, 1D-129 9/19/1999 50.0 SLOTS 4.5" HT .020 Gauge Screen 13.5# 5,239.0 5,249.0 3,809.9 3,819.9 WS A2, 1D-129 9/19/1999 50.0 SLOTS 4.5" HT .020 Gauge Screen 13.5# 5,252.0 5,282.0 3,822.9 3,852.9 WS A2, 1D-129 11/30/1997 4.0 IPERF 0 deg ph/low side; BH EJ 5,279.0 5,289.0 3,849.9 3,859.9 WS A2, 1D-129 9/19/1999 50.0 SLOTS 4.5" HT .020 Gauge Screen 13.5# 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) 5,252.0 5,282.0 1 FRAC 12/2/1997 0.0 0.00 0.00 5,070.0 5,090.0 2 FRAC 12/4/1997 0.0 0.00 0.00 5,070.0 5,090.0 3 FRAC 12/5/1997 0.0 0.00 0.00 5,010.0 5,038.0 4 FRAC 12/6/1997 0.0 0.00 0.00 1D-129, 9/30/2024 1:20:01 PM Vertical schematic (actual) SURFACE; 40.7-5,452.6 Gravel Pack Liner; 4,879.6- 5,290.3 SLOTS; 5,279.0-5,289.0 IPERF; 5,252.0-5,282.0 FRAC; 5,252.0 SLOTS; 5,239.0-5,249.0 SLOTS; 5,199.0-5,209.0 APERF; 5,183.0-5,193.0 SLOTS; 5,159.0-5,169.0 APERF; 5,156.0-5,166.0 APERF; 5,116.0-5,133.0 SLOTS; 5,119.0-5,129.0 SLOTS; 5,079.0-5,089.0 FRAC; 5,070.0 FRAC; 5,070.0 IPERF; 5,070.0-5,090.0 SLOTS; 5,039.0-5,049.0 IPERF; 5,010.0-5,038.0 FRAC; 5,010.0 SLOTS; 5,009.0-5,024.0 SLOTS; 4,984.0-4,999.0 Centralizer; 4,864.5 Sensor - Suction Gauge; 4,862.7 Motor - Adapter; 4,862.4 Motor; 4,831.1 Motor; 4,830.6 Seal Assembly; 4,812.7 Recieving Base; 4,808.2 Sleeve - Sliding; 4,629.2 Mandrel GAS LIFT; 4,540.9 TUBING PLUG; 4,457.1 Nipple - X; 4,457.1 BALL & ROD; 4,450.0 Packer - Liner; 4,405.2 Mandrel GAS LIFT; 4,350.3 Mandrel GAS LIFT; 2,087.2 CONDUCTOR; 41.0-121.0 Hanger; 38.8 KUP PROD 1D-129 ... WELLNAME WELLBORE1D-129 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number): 10. Field: West Sak Oil Pool West Sak Oil Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 5462 1434 None Casing Collapse Conductor Surface 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: 907-263-4597 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 Shane Germann shane.germann@conocophillips.com CTD/RWO Engineer Subsequent Form Required: Suspension Expiration Date: L-80 Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size Kuparuk River Field TVD Perforation Depth TVD (ft): MD 3861' 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. Proposed Pools: 4023' Burst AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 2115'MD/1583'TVD 4880'MD/3451'TVD 4870' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025650 197-213 P.O. Box 100360, Anchorage, AK 99510 50-029-22830-00-00 ConocoPhillips Alaska, Inc Will perfs require a spacing exception due to property boundaries? 8/19/2024 4-1/2" 121' 5453' KRU 1D-129 4984-4999' (Slots) 5009-5024' (Slots) 5010-5038' 5039-5049' (Slots) 5070-5090' 5079-5089' (Slots) 5116-5113' 5119-5129' (Slots) 5156-5166' 5159-5169' (Slots) 5183-5193' 5199-5209' (Slots) 5239-5249' (Slots) 5252-5282' 5279-5289' (Slots) 410' 3555-3570' 3580-3595' 3581-3609' 3610-3620' 3641-3661' 3650-3660' 3687-3704' 3690-3700' 3727-3737' 3730-3740' 3754-3764' 3770-3780' 3810-3820' 3823-3853' 3850-3860' 5412' 5290' Perforation Depth MD (ft): Viking ESP Baker SC-1 Gravel SSSV: None 4033' 5453 4024' 4-1/2" 16" None 7-5/8" 80' 121' 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 Shane Germann DN: O=ConocoPhillips, CN=Shane Germann, E= shane.germann@conocophillips.com Reason: I have reviewed this document Location: Date: 2024.07.19 08:58:05-08'00' Foxit PDF Editor Version: 13.0.0 324-421 By Grace Christianson at 10:38 am, Jul 19, 2024 DSR-7/19/24SFD 7/29/2024VTL 8/5/2024 Run ESP/PCP X X BOP test to 2500 psig Annular test to 2500 psig 10-404 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.08.05 15:22:48 -08'00'08/05/24 RBDMS JSB 080624 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 15, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Shane Germann Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Producer 1D-129 (PTD# 197-213). Well 1D-129 is currently shut-in. The well uses a thru-tubing conveyed (TTC) electric submersible pump (ESP) for artificial lift. During the last attempted pump & motor changeout, the motor for the ESP was dropped and fell to the no- go at the end of the tubing string. Attempts to fish the motor resulted in parting the motor. The completion is ~10 years old which includes 6 pump changeouts. A rig workover is recommended since non-rig recovery efforts of the parted motor have been unsuccessful. The RWO scope is replacement of the TTC-ESP completion with a tubing-conveyed motor compatible with a thru-tubing conveyed ESP/PCP. The completion 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 406-670-1939. The TTC-ESP completion will be pulled and recompleted with a tubing-conveyed motor set up for TTC ESP/PCP. The production packer will be set deeper so that gas lift is a viable alternative form of artificial lift. Digitally signed by Shane Germann DN: O=ConocoPhillips, CN=Shane Germann, E=shane.germann@ conocophillips.com Reason: I have reviewed this document Location: Date: 2024.07.19 08:57:23-08'00' Foxit PDF Editor Version: 13.0.0 1D-129 RWO Procedure West Sak Producer PTD #197-213 Page 1 of 2 Pre-Rig Work 1. T-PPPOT and T-POT tests. Function LD’s 2. Set plug below 2200’ RKB, CMIT-IA to 2500 psig, pull plug. 3. Set Catcher on top of ESP at 4868’ RKB. Pull GLV from Station #1, GLM @ 1994’ RKB and install large port OV. 4. Pull DV from station #2 @ 2229’ RKB, let packer gas migrate to surface, 24hrs. 5. Bleed gas, install DV in station #2, pull SOV @ 4621’ RKB 6. Measure SBHP 7. Prepare for rig arrival 48-96 hrs before rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 1D-129. (No BPV set for MIRU due to internal risk assessment for Nabors 7ES) 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-ESP Completion 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 4-1/2” tubing and release pull-to-release packer. Close annular and circulate out remaining packer gas. 6. Retrieve completion down through TTC-ESP at ~4870’ RKB. Perform Cleanout and Test Packer run 7. MU Cleanout BHA and TIH down to top of gravel pack liner. Rotate and reciprocate scraper at 4700’ RKB or new packer set depth. 8. MU Test Packer BHA, TIH to 4800’ 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 1000 psi. 14. Pressure test inner annulus to 1500 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-129 RWO Procedure West Sak Producer PTD #197-213 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: 8/19/24 Workover Engineer: Shane Germann (406-670-1939, shane.germann@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-ESP. Replace with TTC- ESPCP and deeper packer set depth. BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Rams Following subject to change/be updated with pre-rig work: MIT results: CMIT TxIA to 2500psi Passed, 8/12/23 MIT-OA N/A IC POT & PPPOT– N/A TBG POT & PPPOT – TBD during pre-rig work MPSP: 1434 psi using 0.1 psi/ft gradient Static BHP: 1774psi @ 4826’ RKB (3397’ TVD) on 8/10/2023 Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:1D-129 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: PRE RWO MIT- IA pulled sta 1 pocket left open 1D-129 scolem Notes: General & Safety Annotation End Date Last Mod By NOTE: 1D-129 Scale is acid soluable w/ HCl. Used 10% HCl to pull packoff and pump. 5/4/2020 rwocoman NOTE: Repair SC from bottom of starter head to 70" w/ 10" x 65 x .500 wall pipe, OAL=70"12/9/2012 ninam NOTE: View Schematic w/ Alaska Schematic9.01/12/2011 ninam NOTE: ESP WORKOVER 11/13/2003 osborl NOTE: ESP WORKOVER, ADD GRAVEL PACK 9/19/1999 osborl NOTE: ESP WORKOVER 11/22/1997 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 41.0121.0121.062.58 H-40 WELDED SURFACE7 5/86.8740.7 5,452.6 4,023.4 29.70 L-80 BTCM Gravel Pack Liner 4 1/2 4.00 4,879.6 5,290.3 3,861.2 Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 37.0 Set Depth … 4,870.0 Set Depth… 3,441.0 String Ma… 4 1/2 Tubing Description Tubing – Production Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT-M ID (in) 3.96 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) 37.037.00.00 HANGER 10.750 VETCO GREY TUBING HANGER 10 3/4" X 4 1/2" Vetco- Gray 3.958 1,994.3 1,517.6 56.38 GAS LIFT 6.437 GLM 4 1/2" X 1" KBMG DV # 13175- 39 CAMCO KBGM 3.860 2,114.6 1,582.8 57.95 PACKER 6.700 VIKING 7 5/8" HYD. ESP PACKER VIKING 3.900 2,229.5 1,643.7 57.54 GAS LIFT 6.437 GLM 4 1/2" X 1" KBMG DV #13175- 10 CAMCO KBGM 3.860 4,621.0 3,192.8 10.12 GAS LIFT 6.437 GLM 4 1/2" X 1" KBMG DV #13175- 05 CAMCO KBGM 3.860 4,674.5 3,245.7 6.18 GUAGE 6.460 BAKER GUARDIAN GUAGE Centrilift 3.958 4,778.1 3,349.1 1.58 ALC MOTOR 5.500 ALC MOTOR SHROUD W/ XO (SHTX14A0010) ALCSHTX14 A0010 3.890 4,792.6 3,363.6 1.49 ALC MOTOR 5.500 ALC MOTOR SHROUD (SHTX14A0011) ALCSHTX14 A0011 3.890 4,806.3 3,377.3 1.43 ALC MOTOR 5.500 ALC MOTOR SHROUD (SHTX14A0012) ALCSHTX14 A0012 3.890 4,820.0 3,391.0 1.41 ALC PUMP CAN 5.500 ALC PUMP CAN (PCTXM004)ALC PCTXM 004 3.956 4,858.8 3,429.8 1.37 NIPPLE 5.500 B PROFILE 4.5" BUTRESS B X B ALC 3.956 4,868.1 3,439.1 1.36 NIPPLE 5.500 N0 G0 3.80 STOP (BPNGTX14B005) ALC BPNGT X14B00 5 3.800 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) 4,827.03,398.01.40 ACCESS MOTOR 4.5" ACCESSS MOTOR (43' 1" OAL). Parted Lower Mating Unit from top of Access Motor (12/07/20) while fishing with CTU. Bottom of motor is stuck in the No-Go located @ 4868' RKB. 11/7/2020 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) 1,994.3 1,517.6 56.38 1 GAS LIFT OPEN BK 1 8/12/2023Schlumb erger Camco KMBG 2,229.5 1,643.7 57.54 2 GAS LIFT DMY BK 1 0.0 5/8/2018 Schlumb erger Camco KMBG0.000 4,621.03,192.810.12 3 GAS LIFT SOVBK 1 0.012/15/2019 2000# STS Schlumb erger Camco KMBG1.000 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) 4,879.6 3,450.6 1.35 PACKER 6.700 BAKER SC-1 GRAVEL PACKER 4.000 4,884.4 3,455.4 1.34 EXTENSION5.500UPPER MILLOUT EXTENSION4.892 4,888.3 3,459.2 1.34 SLEEVE 5.800 SLIDING SLEEVE 4.892 4,892.3 3,463.3 1.33 EXTENSION 5.500 LOWER MILLOUT EXTENSION 4.000 4,907.7 3,478.7 1.33 XO Reducing 5.000 CROSSOVER 5"x4.5" 4.500 5,289.63,860.5 1.09 PLUG 5.540 BULL PLUG0.000 1D-129, 8/13/2023 4:51:59 AM Vertical schematic (actual) SURFACE; 40.7-5,452.6 FLOAT SHOE; 5,451.1-5,452.6 FLOAT COLLAR; 5,368.3- 5,369.6 Gravel Pack Liner; 4,879.6- 5,290.3 PLUG; 5,289.6-5,290.3 SLOTS; 5,279.0-5,289.0 IPERF; 5,252.0-5,282.0 FRAC; 5,252.0 SLOTS; 5,239.0-5,249.0 SLOTS; 5,199.0-5,209.0 APERF; 5,183.0-5,193.0 SLOTS; 5,159.0-5,169.0 APERF; 5,156.0-5,166.0 APERF; 5,116.0-5,133.0 SLOTS; 5,119.0-5,129.0 SLOTS; 5,079.0-5,089.0 FRAC; 5,070.0 FRAC; 5,070.0 IPERF; 5,070.0-5,090.0 SLOTS; 5,039.0-5,049.0 IPERF; 5,010.0-5,038.0 FRAC; 5,010.0 SLOTS; 5,009.0-5,024.0 SLOTS; 4,984.0-4,999.0 EXTENSION; 4,892.3-4,907.7 SBE; 4,890.8-4,892.3 SLEEVE; 4,888.3-4,890.8 EXTENSION; 4,884.4-4,888.3 PACKER; 4,879.6-4,884.4 NIPPLE; 4,868.1 NIPPLE; 4,858.8 ACCESS MOTOR; 4,827.0 ALC PUMP CAN; 4,820.0 ALC MOTOR; 4,806.3 ALC MOTOR; 4,792.6 ALC MOTOR; 4,778.1 GUAGE; 4,674.5 GAS LIFT; 4,621.0 STAGE COLLAR; 2,498.3- 2,501.1 GAS LIFT; 2,229.5 PACKER; 2,114.5 GAS LIFT; 1,994.3 CONDUCTOR; 41.0-121.0 HANGER; 40.7-43.7 HANGER; 37.0 KUP PROD KB-Grd (ft) 41.00 RR Date 11/29/199 7 Other Elev… 1D-129 ... TD Act Btm (ftKB) 5,462.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292283000 Wellbore Status PROD Max Angle & MD Incl (°) 58.37 MD (ftKB) 2,146.26 WELLNAME WELLBORE Annotation Last WO: End Date 5/1/2012 H2S (ppm) 0 Date 12/29/2015 Comment SSSV: NONE Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 4,984.0 4,999.0 3,555.0 3,570.0 NF, 1D-129 9/19/1999 50.0 SLOTS 4.5" HT .020 Gauge Screen 13.5# 5,009.0 5,024.0 3,580.0 3,595.0 WS D, 1D-129 9/19/1999 50.0 SLOTS 4.5" HT .020 Gauge Screen 13.5# 5,010.0 5,038.0 3,581.0 3,609.0 WS D, 1D-129 12/6/1997 4.0 IPERF 0 deg ph/low side; 2 1/8"EJ 5,039.0 5,049.0 3,610.0 3,620.0 WS C, 1D-129 9/19/1999 50.0 SLOTS 4.5" HT .020 Gauge Screen 13.5# 5,070.0 5,090.0 3,640.9 3,660.9 WS B, 1D-129 12/4/1997 4.0 IPERF 0 deg ph/low side; 2 1/8"EJ 5,079.0 5,089.03,649.93,659.9 WS B, 1D-129 9/19/1999 50.0SLOTS 5,116.0 5,133.03,686.93,703.9 WS A4, 1D-129 9/15/1999 12.0 APERF HSD-BH 4 1/2" 5,119.0 5,129.03,689.93,699.9 WS B, WS A4, 1D-129 9/19/1999 50.0SLOTS 4.5" HT .020 Gauge Screen 13.5# 5,156.0 5,166.03,726.93,736.9 WS A4, WS A3, 1D-129 9/15/1999 12.0 APERF HSD-BH 4 1/2" 5,159.0 5,169.03,729.93,739.9 WS A3, 1D-129 9/19/1999 50.0SLOTS 4.5" HT .020 Gauge Screen 13.5# 5,183.0 5,193.03,753.93,763.9 WS A3, 1D-129 9/15/1999 12.0 APERF HSD-BH 4 1/2" 5,199.0 5,209.03,769.93,779.9 WS A3, WS A2, 1D-129 9/19/1999 50.0SLOTS 4.5" HT .020 Gauge Screen 13.5# 5,239.0 5,249.0 3,809.9 3,819.9 WS A2, 1D-129 9/19/1999 50.0 SLOTS 4.5" HT .020 Gauge Screen 13.5# 5,252.0 5,282.03,822.93,852.9 WS A2, 1D-129 11/30/19974.0 IPERF 0 deg ph/low side; BH EJ 5,279.0 5,289.0 3,849.9 3,859.9 WS A2, 1D-129 9/19/1999 50.0 SLOTS 4.5" HT .020 Gauge Screen 13.5# 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) 5,252.0 5,282.0 1 FRAC 12/2/1997 0.00.00 0.00 5,070.0 5,090.0 2 FRAC 12/4/1997 0.00.00 0.00 5,070.0 5,090.0 3 FRAC 12/5/1997 0.00.00 0.00 5,010.0 5,038.0 4 FRAC 12/6/1997 0.00.00 0.00 1D-129, 8/13/2023 4:52:01 AM Vertical schematic (actual) SURFACE; 40.7-5,452.6 FLOAT SHOE; 5,451.1-5,452.6 FLOAT COLLAR; 5,368.3- 5,369.6 Gravel Pack Liner; 4,879.6- 5,290.3 PLUG; 5,289.6-5,290.3 SLOTS; 5,279.0-5,289.0 IPERF; 5,252.0-5,282.0 FRAC; 5,252.0 SLOTS; 5,239.0-5,249.0 SLOTS; 5,199.0-5,209.0 APERF; 5,183.0-5,193.0 SLOTS; 5,159.0-5,169.0 APERF; 5,156.0-5,166.0 APERF; 5,116.0-5,133.0 SLOTS; 5,119.0-5,129.0 SLOTS; 5,079.0-5,089.0 FRAC; 5,070.0 FRAC; 5,070.0 IPERF; 5,070.0-5,090.0 SLOTS; 5,039.0-5,049.0 IPERF; 5,010.0-5,038.0 FRAC; 5,010.0 SLOTS; 5,009.0-5,024.0 SLOTS; 4,984.0-4,999.0 EXTENSION; 4,892.3-4,907.7 SBE; 4,890.8-4,892.3 SLEEVE; 4,888.3-4,890.8 EXTENSION; 4,884.4-4,888.3 PACKER; 4,879.6-4,884.4 NIPPLE; 4,868.1 NIPPLE; 4,858.8 ACCESS MOTOR; 4,827.0 ALC PUMP CAN; 4,820.0 ALC MOTOR; 4,806.3 ALC MOTOR; 4,792.6 ALC MOTOR; 4,778.1 GUAGE; 4,674.5 GAS LIFT; 4,621.0 STAGE COLLAR; 2,498.3- 2,501.1 GAS LIFT; 2,229.5 PACKER; 2,114.5 GAS LIFT; 1,994.3 CONDUCTOR; 41.0-121.0 HANGER; 40.7-43.7 HANGER; 37.0 KUP PROD 1D-129 ... WELLNAME WELLBORE 1D-129 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 121 121 16 15.06 62.58 H-40 Welded Welded Surface 5453 4023 7-5/8 6.87 29.7 L-80 BTCM BTCM Production/ Intermediate N/A Liner 5290 3861 4-1/2 4 13.5 Tubing 4870 3441 4-1/2 3.96 12.6 L-80 IBTM IBTM PROPOSED COMPLETION 3-1/2" 12.6# L-80 EUEM Tubing to surface 3-1/2" x 1" GLMs @ 2096' & as deep as possible 3-1/2" x 7-5/8" Feedthrough Packer @ ~deep as possible 3-1/2" X landing nipple @ TBD (2.813" min ID) 3-1/2" CMU Sliding sleeve (2.813" X profile) Downhole gauge @ TBD TTC Crossover for TTC ESPCP @ deep as possible Seal Assembly Torque Shaft Assembly Motor Gauge Sensor Centrilizer w/ chem injection (unused) REMAINING COMPLETION LEFT IN HOLE Baker SC-1 Gravel Packer @ 4879' RKB (4" ID) Gravel pack liner w/ screens Surface Casing Conductor Perfs for West Sak A2, A3, A4, B, and D sands STATE OF ALASKA I 1 E D • ALA�...A OIL AND GAS CONSERVATION COMM11 SION APR 0 2 2014 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Rug Perforations r Perforate r Other QGCC Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well Co E5 P 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p- Exploratory r 197-213 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-029-22830-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25650 \ • ' 1D-129 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured . 5462 feet Plugs(measured) 5290 true vertical 4033 feet Junk(measured) none Effective Depth measured . 5433 feet Packer(measured) 2115,4880 true vertical 4004 feet (true vertical) 1583, 3451 Casing Length Size MD TVD Burst Collapse r CONDUCTOR 80 16 121 121 SURFACE 5412 7.625 5453 4023 GRAVEL PACK 410 4.5 5290 3861 ry Li} LINER SCANNED JUL_ 1 b U Perforation depth: Measured depth: 4984-4999,5009-5049,5070-5090,5116-5133,5156-5169,5183-5193,5199-5209,5239-5249,5252-5289 True Vertical Depth: 3555-3570,3580-3620,3641-3661,3686-3704,3727-3740,3754-3764,3770-3780,3810-3820,3823-3860 Tubing(size,grade,MD,and TVD) 4.5, L-80,4870 MD, 3441 ND RBDMS MAY 14 2014 Packers&SSSV(type,MD,and ND) PACKER -VIKING 7 5/8"HYD. ESP PACKER @ 2115 MD and 1583 ND PACKER -BAKER SC-1 GRAVEL PACKER @ 4880 MD and 3451 ND no SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: • Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r 16.Well Status after work: i Oil I✓ Gas r WDSPL r 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 Brett Packer C ,265-6845 Email J.Brett.Packer(a�conocophillips.com Printed Name Brett Packer Title Supervising Workover Engineer Signaturer �� 79vc Phone:265 6845 Date ,//0/('tt 171-F 5 /24111— Form 10-404 Revised 10/2012 407 /7 %% Submit Original Only • KUP PROD 1D-129 Conoc i hi liIn " Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APUUWI Field Name Wellbore Status ncl(") MD(ftKB) Act Btm(0KB) N44 500292283000 WEST SAK PROD 58.37 2,146.26 5,462.0 °.- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1D-129,4/220149:2401 AM SSSV:NONE 10 8/14/2012 Last WO: 5/1/2012 41.00 11/29/1997 Vertical schematic(actual Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER.3�o � • Last Tag: Rev Reason:WORKOVER postojl 4/1/2014 • ySCasing Strings ' "' • • tC r. w CasingDescription OD ID To (DAB) Set Depth ftKB Set Depth TVD... Wt/Len I...Grade To Thread P (in) lin) PP 1 1 P 1 1 l P CONDUCTOR 16 15.063 41.0 121.0 121.0 6258 H-40 WELDED • • • 1 Casing Description OD(in) ID(in) Top OMB) Set Depth(ftKB) Set Depth(TVD)... WULen(I...Grade Top Thread • • SURFACE 7 5/8 6.875 40.7 5,452.6 4,023.4 29.70 L-80 BTCM • • • s Casing Description OD(in) ID(in) Top(DAB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR;41.0.121.0 1 Gravel Pack Liner 4 1/2 4.000 4,879.6 5,290.3 3,861.2 - Liner Details GAS LIFT;1,9943 Nominal ID Top(flK8) Top(TVD)(ftKB) Top not(°) Item Des Com (in) 4,879.6 3,450.6 1.35 PACKER BAKER SC-1 GRAVEL PACKER 4.000 • 4,884.4 3,455.4 1.34 EXTENSION UPPER MILLOUT EXTENSION 4.892 PACKER;2,114.5 4,888.3 3,459.2 1.34 SLEEVE SLIDING SLEEVE 4.892 4,890.8 3,461.8 1.34 SBE BAKER SEAL BORE 4.000 t 4,892.3 3,463.3 1.33 EXTENSION LOWER MILLOUT EXTENSION 4.000 GAS LIFT;2,229.5 L r 4,907.7 3,478.7 1.33 XO Reducing CROSSOVER 5"x4.5" 4.500 4,983.5 3,554.5 1.30 SCREEN BAKER 0.20 GAUGE SCREEN 4.000 5,008.6 3,579.6 1.29 SCREEN BAKER 0.20 GAUGE SCREEN 4.000 5,038.7 3,609.7 1.28 SCREEN BAKER 0.20 GAUGE SCREEN 4.000 5,078.8 3,649.8 1.27 SCREEN BAKER 0.20 GAUGE SCREEN 4.000 GAS LIFT;3,621.0. 5,119.0 3,689.9 124 SCREEN BAKER 0.20 GAUGE SCREEN 4.000 5,159.1 3,730.0 120 SCREEN BAKER 0.20 GAUGE SCREEN 4.000 5,199.2 3,770.1 1.17 SCREEN BAKER 0.20 GAUGE SCREEN 4.000 GUAGE;4,6705 5,239.4 3,810.3 1.13 SCREEN BAKER 0.20 GAUGE SCREEN 4.000 [ 5,279.5 3,850.4 1.10 SCREEN BAKER 0.20 GAUGE SCREEN 4.000 1.. 5,289.6 3.860.5 1.09 PLUG BULL PLUG 0.000 ALC MOTOR;4,778.1 i:. I Tubing Strings ALC MOTOR;4.7926 I ;=_j.6'I Tubing Description String Ma...ID(in) Top)ftKB) Set Depth dt.,Set Depth(ND)(...Wt(Iblft) Grade Top Connection ALC MOTOR.4,8063 , ESP TUBING WO 4 1/2 3.958 37.0 4,870.0 3.441.0 12.60 L-80 IBT-M ALC PUMP CAN:4.8200 owe., Completion Details I Nominal ID I Top(ftKB) Top(ND)(ftKB) Top not(°) Item Des Coin (in) NIPPLE;4,858.e 37.0 37.0 0.00 HANGER VETCO GREY TUBING HANGER 10 3/4"X 4 1/2" 3.958 NIPPLE;4,868.1 2,114.6 1,582.8 57.95 PACKER VIKING 7 5/8"HYD.ESP PACKER 3.900 4,674.5 3,245.7 6.18 GUAGE BAKER GUARDIAN GUAGE 3.958 _a 4,778.1 3,349.1 1.58 ALC MOTOR ALC MOTOR SHROUD W/X0(SHTX14A0010) 3.890 . � i=i- 4,792.6 3,363.6 1.49 ALC MOTOR ALC MOTOR SHROUD(SHTX14A0011) 3.890 4,806.3 3,377.3 1.43 ALC MOTOR ALC MOTOR SHROUD(SHTX14A0012) 3.890 !Wilt 4,820.0 3,391.0 1.41 ALC PUMP ALC PUMP CAN(PCTXM004) 3.956 CAN •slime 111 4,858.8 3,429.8 1.37 NIPPLE B PROFILE 4.5"BUTRESS B X B 3.956 ■ 4,868.1 3,439.1 1.36 NIPPLE NO GO 3.80 STOP(BPNGTX14B005) 3.800 Perforations&Slots SLOTS:4,984.0-4,999.0- ' Shot ■I Dens ■ Top(ND) Bter(ND) (snots'( i■ Top(ftKB) Btm(ftKB) (15KB) (ftKB) Zone Date t) Type Com 4,984.0 4,999.0 3,555.0 3,570.0 NF,1D-129 9/19/1999 50.0 SLOTS 4.5"HT.020 Gauge Screen 13.5# SLOTS;5.009.05,024.0 J-Alin FRAC;5,010.0 5,009.0 5,024.0 3,580.0 3,595.0 WS D,1D-129 9/19/1999 50.0 SLOTS 4.5"HT.020 Gauge IPERF:5.010.0.5.038.0 Screen 13.58 5,010.0 5,038.0 3,581.0 3,609.0 WS D,1D-129 12/6/1997 4.0 IPERF 0 deg ph/low side;2 1/8"EJ SLOTS;5,039.05,049.0- III 5,039.0 5,049.0 3,610.0 3,620.0 WS C,1D-129 9/19/1999 50.0 SLOTS 4.5"HT.020 Gauge Screen 13.5# FRAC;5,070.0 FRAC;5,070.0 5,070.0 5,090.0 3,640.9 3,660.9 WS B,1D-129 12/4/1997 4.0 (PERF 0 deg ph/low side;2 IPERF;5,070.05,090.0 "7. ,, I 1/8"EJ SLOTS;5,079.05,089.0 -- 5,079.0 5,089.0 3,649.9 3,659.9 WS B,10-129 9/19/1999 50.0 SLOTS SLOTS;5,119.55,129.0 i . J'��t 5,116.0 5,133.0 3,686.9 3,703.9 WS A4,10- 9/15/1999 12.0 APERF HSD-BH 4 1/2" APERF;5,116.05,133.0 .' "'" 129 II 1 5,119.0 5,129.0 3,689.9 3,699.9 WS B,WS 9/19/1999 50.0 SLOTS 4.5"HT.020 Gauge A4,10-129 Screen 13.58 APERF;5,156.05,166.0, 1 5,156.0 5,166.0 3,726.9 3,736.9 WS A4,WS 9/15/1999 12.0 APERF HSD-BH 4 1/2" SLOTS;5,159.05,169.0- !+ljt mil A3,1D-129 11 5,159.0 5,169.0 3,729.9 3,739.9 WS A3,10- 9/19/1999 50.0 SLOTS 4.5"HT.020 Gauge 129 Screen 13.5# APERF;5.183.05.1930-- 1 5,183.0 5,193.0 3,753.9 3,763.9 WS A3,1D- 9/15/1999 ' 12.0 APERF HSD-BH41/2' 1 129 SLOTS;5,199.0.5,209.0- , :,i4-_iii 5,199.0 5,209.0 3,769.9 3,779.9 WS A3,WS 9/19/1999 50.0 SLOTS 4.5"HT.020 Gauge A2,1D-129 Screen 13.58 5,239.0 5,249.0 3,809.9 3,819.9 WS A2,10- 9/19/1999 50.0 SLOTS -4.5"HT.020 Gauge SLOTS;5,238.05,249.0- f, _ 129 Screen 13.58 5,252.0 5,282.0 3,822.9 3,852.9 WS A2,10- 11/30/1997 4.0 IPERF 0 deg ph/low side;BH FRAC;5.252.0 129 EJ IPERF;5,252.05282.0 5,279.0 5,289.0 3,849.9 3,859.9 WS A2,10- 9/19/1999 50.0 SLOTS 4.5"HT.020 Gauge _ 1 129 Screen 13.54 SLOTS;5.279.05,289.0- Stimulations&Treatments Min Top Max elm Gravel Pack Liner;4,879.6- ' Depth Depth Top(TVD) Bier(TVD) 5,290.3 )ftKB) (ftKB) (ftKB) (ftKB) Type Date _ Com 5,252.0 5,282.0' 3,822.9 3,852.9 FRAC 12/2/1997 A2 SAND FRAC-1891208 w/9#16/20 proppant 5,070.0 5,090.0 3,640.9 3,660.9 FRAC 12/4/1997 B-SAND FRAC-737598,w/10#PPA OF 16/208 SURFACE;40.75,452.6-. KUP PROD 1 D-129 ConoccPhiiiips - Alaska,Inc. • 10-129,4/2/2014 9:24:02 AM Vnrtcal schematic(actual) , ..........................................GER37....__ _._... ._. HANGER;37.0-- Ra &� Stimulations&Treatments Min Top Max Btm Depth Depth Top(ND) Btm(ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 5,070.0 5,090.0 3,640.9 3,660.9 FRAC 12/5/1997 B-SAND FRAC part 2-109044#w/18#PPA 16/20# 5,010.0 5,038.0 3,581.0 3,609.0 FRAC 12/6/1997 WS D-SAND FRAC-102651#Proppant treated CONDUCTOR.41.0-121.0 .� w/Propiok w/10#PPA 16/20# Mandrel Inserts GAS LIFT;1,994.3 a. St 1111 of Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(In) Sery Type Type (In) (psi) Run Date Com 1,994.3 1,517.6 CAMCO KBGM 1 GAS LIFT DMY BK-5 1.000 3/2/2014 PACKER,2,114.5 - 2 2229.5 1,643.7 CAMCO KBGM 1 GAS LIFT DMY BK-5 1.000 3/2/2014 lat UM 3 4,621.0 3,192.8 CAMCO KBGM 1 GAS LIFT DMY BK-5 1.000 3/2/2014 AD Notes:General&Safety GAS LIFT;2,229.5 End Date Annotation 11/22/1997 NOTE:ESP WORKOVER is 9/19/1999 NOTE:ESP WORKOVER,ADD GRAVEL PACK ;. 11/13/2003 NOTE:ESP WORKOVER 1/12/2011 NOTE:View Schematic w/Alaska Schematic9.0 �.. 12/92012 NOTE:Repair SC from bottom of starter head to 70"w/10"x 65 x.500 wall pipe,OAL=70" GAS UFT;4,621.0 GUAGE;4,674.5 ' It ALC MOTOR;4,778.1 II_: i ALC MOTOR;4,792.6 _ '_ ALC MOTOR;4,806.3 g,1p ALC PUMP CAN;4,0200 ',►1i4m I NIPPLE;4,858 8 IIN- NIPPLE;4,868.1 IlE f Cr'P II 'l/41 a, MB . SLOTS.4,964.0-4,9990- la=s I 1111 � 1 SLOTS;5.009.05.024.0 i11iliMr FRAC;505,038.0 ��I! (PERF;5,010.0-5,0380 SLOTS;5,039.05.049.0- - I FRAC;5,070.0 FRAC;5,070.0 !PERF;5,070.0-5,090.0 SLOTS;5.079.05989.0 -- II SLOTS;5.119.05.129.0 ',- APERF;5.116.05.133.01 rr._ 1I I APERF;5,156.05,166.0. U SLOTS;5,159.05,169.0- t- tl APERF;5,183.05,193.0- I I I SLOTS;5,199.05,209.0- later r. SLOTS;5,239.05,249.0- \-: - FRAC:5,282.0 !PERF;5,252.05,282 0 i=i I SLOTS;5.279.0-5,289.0- ji Gravel Pack liner;4,879.6- 5,290.3 I SURFACE;40.75,452.6- 1D-120 DRE-RIG WELL WORK DATE SUMMARY 10/5/2013 (PRE RWO) : POT-T PASSED, UPPER POT-T PASSED, LOWER POT-T PASSED, PPPOT- T FAILED (DUE TO EXTERNAL LEAK AROUND ESP CABLE IN TOP OF THA), UPPER PPPOT-T PASSED, LOWER PPPOT-T PASSED, FT T LDS (ALL GOOD). 2/5/2014 PULLED DV @ 2743' RKB. JOB COMPLETE (READY FOR BPV). Conoco hiIIips Time Log & Summary We/Mew Web Reporting Report Well Name: 1D-129 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 2/21/2014 12:00:00 PM Rig Release: 3/2/2014 10:30:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/14/2014 24 hr Summary Rig down for repairs. Rig Not accepted 00:00 00:00 24.00 MIRU RIGMNT RGRP T Rig down for repairs. Continue repair auger box. Welders from 06:00 to -21:00 02/15/2014 00:00 00:00 24.00 MIRU RIGMNT RGRP T Rig down for repairs. Continue repair auger box. Welders from 06:00 to —19:00 02/16/2014 00:00 00:00 24.00 MIRU RIGMNT RGRP T Rig down for repairs. Continue repair auger box. GBR welders from 06:00 to 18:00 02/17/2014 00:00 00:00 24.00 MIRU RIGMNT RGRP T Rig down for repairs. Continue repair auger box. Welders from 06:00 to —21:00 32/18/2014 00:00 06:00 6.00 MIRU RIGMNT RGRP T Rig down for repairs. Continue repair auger box. 06:00 00:00 18.00 MIRU RIGMNT RGRP T Rig down for repairs. continue to repair auger box 02/19/2014 Rig down for repairs, rig not accepted. Continue with auger box repairs.Welders completed @ 20:00 hrs. Additional flange,downspout and installation of auger required. 00:00 00:00 24.00 MIRU RIGMNT RGRP T Continue working on Auger box repairs. 02/20/2014 Complete Auger repairs, clean pits. Accept rig @ 14:00 hrs, Set up rig mats, liner, and berm around wellhead. Start warming up moving system. Moving system ready @ 19:30 hrs, ambient temp-41 degrees,wind chill-57.Wait on Weather. 00:00 14:00 14.00 MIRU RIGMNT RGRP T Continue working on auger repairs. 14:00 19:30 5.50 MIRU MOVE MOB T wait on weather Current Temp.42 below.set hurkilite and T matts for rig. Loader operating in cold weather variance 19:30 00:00 4.50 MIRU MOVE MOB T Rig warming procedure completed, current ambient temperature is-41 with a wind chill of-57.Wait on Weather. Page 1 of 9 Time Logs Date i From To Dur S.Depth E. Depth Phase Code Subcode T Comment 02/21/2014 24 hr Summary WOW until 09:00 hrs, MIRU over well. Rig Accepted @ 12:00 hrs. Spot support equipment, rig up hard lines, take on first load of KWF. P/U lubricator, pull BPV.WHP=600 psi. *3.5 hrs of NPT waiting on filtered&heated KWF due to vac truck delays* 00:00 07:00 7.00 MIRU MOVE MOB T Current ambient temp-44,wind chill -69.wait on weather prior to moving rig over well. 07:00 09:00 2.00 MIRU MOVE MOB T Continue to wait on the weather. 09:00 12:00 3.00 MIRU MOVE MOB P Moved rig in on well under CW Variance. Rig accepted @ 12:00 hrs 12:00 15:30 3.50 MIRU MOVE MOB P Spot aux.equipment. Ru kill tank and lines.Take of filtered 9.6#KCL brine. Ru lines in cellar. 15:30 17:30 2.00 MIRU MOVE RURD P PJSM with crane crew. Uploaded ESP cable spooler&spool. install spooler gaurds. 17:30 20:30 3.00 MIRU WHDBO MPSP P Warm up lubicator hold PJSM with Vetco Gray service hand. Put steam blanket around tree and warm it ip _prior to pulling BPV. 20:30 00:00 3.50 MIRU WELCTL KLWL T Second load of 9.6#KWF was ordered+24hours out. Two trucks broke down while P/U Brine from MI. Arrived on location© 17:30 hrs,fluid temp 96 degrees, had to filter+heat KWF to 130 degrees prior to killing well. **Pre-spud with Cody Crew& performed Black gold Hazard hunt. Loaded test joints and prepared handling equipment. ** 02/22/2014 Load heated&filtered 9.6#Brine,test surface lines. First well kill attempt, Tubing 600 psi/IA 310 psi. reverse circulate ICP 520 psi @ 3bpm, choke 390 psi, 252 bbls,240 bbls returns. Shut down and clean out Kill tank. SITP 130 psi/IA 160 psi.Attempt well kill with 9.6#conventional, Pumped 240 bbls,230 bbls returned. SITP 75 psi. Clean out Kill tank.Weight up new KWF to 10.1#.Third attempt to kill well, ICP 900 psi @ 5 bpm, circulate 170 bbls until good mud weight returns,SI and bullheaded 47 bbls down tubing @ 700 psi. Let well stabilize, bleed down slowly at surface to zero pressure.Well began flowing following 15 minute flow check due to injector activity on the pad. SI injector, new pressure indicate&order 12#KWF. 00:00 01:30 1.50 MIRU WELCTL PRTS P Complete loading KWF,test hard line to 2500 psi. 01:30 03:30 2.00 MIRU WELCTL KLWL P PJSM-Well Kill operations. Bleed down gas head SITP=600 psi/IA 310 psi. Bleed down to 50 psi. Strap tank 81 bbls to start.(72 bbls frozen) Start pumping 3 bpm 9.6#Brine, ICP 520 psi, choke 390 psi. Pumped 252 bbls, returned 240 bbls. Kill tank strap 370 bbls,due to foamed up oily returns+81 bbls. 03:30 05:30 2.00 MIRU WELCTL KLWL P Shut down to suck out Kill tank. Monitor pressures. FCP 250 psi/90 psi on choke. Tubing 130/IA 160 psi. Page 2 of 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 07:00 1.50 MIRU WELCTL KLWL P Set up to pump long way. Gas/oil head on IA. Tubing 200 psi/IA 150 psi. ICP 610 psi ©3 bpm with 400 psi on choke.Total of 25 bbls away to get dirty 9.6#back. Pump 75 bbls/ Returns 66 bbls returned. Oily/gas pockets still coming back. Continue pumping long way until clean 9.6#to surface. 07:00 08:00 1.00 MIRU WELCTL OWFF P Monitor well. let well stabilize,Tubing pressure @ 75 psi. new KWF 10.1 heavy. 08:00 13:30 5.50 MIRU WELCTL KLWL T Bled current KWF to new KWF. 13:30 15:00 1.50 MIRU WELCTL KLWL T Est. circulation conventional. ICP 900 psi @ 5 BPM. Circulated 170 BBLs of 10.1#filtered 3percent KCL/Brine. 10#heavy to surface. Shut in the IA bull headed 47 bbls down tubing©700 psi. 1.5 bpm. 15:00 16:30 1.50 MIRU WELCTL OWFF T SITP 700 psi. let well stabilize for 15 min.s Tubing pressure= 200 psi IA 200 psi. Slow bleed off of pressure. well laid stagnet for 15 min's be gan flowing. SWI & monitor. Tbg. 300 psi IA 200 psi. 16:30 00:00 7.50 MIRU WELCTL KLWL T Wait on 12#KWF due to injector communication. Uploaded completion on rig, strap and tally. 02/23/2014 Load 12#KWF, Kill well-circulate around @ 5 bpm ICP 520 psi, Choke 300 psi, FCP 590 psi, Choke 190 psi. Pumped 212 bbls, lost 24 bbls to formation. Monitor well-on vac. Prior to setting BPV, bullhead additional 65 bbls-monitor well-on vac. Set BPV, ND tree, NUBOPE. AOGCC waived witness by Chuck Scheve, Complete BOPE test with 3 1/2"&4 1/2"test joints. Pull plug, pull BPV, M/U landing joint pump 30 bbls to fill well. BOLDS- P/U 150K to break over, string weight 85K, P/U 10 ft&Circulate B/U. 00:00 04:00 4.00 COMPZ WELCTL KLWL T First load arrived, filter prior to taking on the rig. 321 bbls in pits. Second load enroute to location. 04:00 06:00 2.00 COMPZ WELCTL KLWL T Start killing the well conventional. Pumping 5 bpm @ 520 psi/300 psi on choke, slowly open choke while pumping down tubing. FCP 590 psi, 150 psi on choke. 11.9#heavy back at the choke. Total 212 bbls pumped, 178 bbls returned. Lost 34 bbls to formation. 06:00 07:00 1.00 COMPZ WELCTL OWFF P 30 minute no-flow, crew change. 07:00 08:00 1.00 COMPZ WELCTL OPNW T Began braking down lines and well began to blow. riggged back up lines & PT to 2300 psi. SH tubing pressue =60 psi. IA 0 Psi 08:00 09:30 1.50 COMPZ WELCTL KLWL T Bull headed 47 bbls down tubing. and circulated 67 bbls up IA 12#in/ out SD for to monitor 09:30 10:00 0.50 COMPZ WELCTL OWFF T monitor well for flow. Page 3 of 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T ` Comment 10:00 10:30 0.50 COMPZ WHDBO MPSP P Install BPV 10:30 12:30 2.00 COMPZ WHDBO NUND P ND tree. Install blanking plug. Adding 7 bbls of KWF per hour down IA 12:30 16:30 4.00 COMPZ WHDBO NUND P NU BOPE and change top rams to VBR's. Body test BOPE 250/3000 psi 16:30 18:30 2.00 COMPZ WHDBO BOPE P Test BOPE equipment to 250/3000 psi(1)Blinds,killl stand pipe,HCR TD, 3.5"dart, choke 4,11,12. pass. (2) Kill HCR, TD man, 3.5 IF FOSV, choke 3,7,9,10. pass. (3)3.5"8rd FOSV,Lwr PR 3.5"TJ, Choke 2,5,8. Pass. (4)Ann,3.5"TJ,4.5"8rd FOSV, Man kill, choke 6. 18:30 21:00 2.50 COMPZ WHDBO BOPE P Test 5-UPR 3.5", Choke, HCR Test 6-Lwr 4.5" Test 7-Ann 4.5" Test 8-Upr 4.5"Choke#1. Draw down test complete. Start 3K, end 1850psi, 18 secs/200 psi, 90 secs/3K. Continue to top up 7 bbls/hour. 21:00 22:30 1.50 COMPZ WHDBO MPSP P Blow down stack, Pull test plug& BPV. Set ISO sleeve. M/U Landing joint. 22:30 00:00 1.50 COMPZ RPCOM PULL P PJSM-BOLDS, P/U on tubing. Hanger broke over @ 150K,string weight 85K. P/U 20ft. Stop& circulate B/U. Took 42 bbls to get returns. Oily/gas returns for first 25 bbls took outside. 02/24/2014 Circulate B/U prior to POOH with 3 1/2"decompletion.TOOH laying down tubing while spooling ESP cable. Pump was free of debris and in good working order. Swap out ESP spools, load new drilling line spool. Begin P/U new ESP completion assembly. Recovered all protectolizers, SS bands and Clamps that were ran in hole. 24 hour losses=288 bbls. 00:00 01:00 1.00 COMPZ RPCOM CIRC P Complete circulating B/U, light gas returns to surface.Total losses during circulation 42 bbls to bbls to fill the hole+31 during circulation= 73 bbls. 01:00 02:00 1.00 COMPZ RPCOM SFTY P 30 minute no-flow check, blow down top drive, lay down tubing hanger. Test cable to Pump. good. PJSM for POOH. 02:00 10:00 8.00 COMPZ RPCOM PULL P Pull 3 joints, set up spooler and cable. Hole fill with 10bbls/hour. Continue POOH with decompletion. 10:00 11:30 1.50 COMPZ RPCOM PULD P Cut ESP cable with 2 ft+lay down ESP. checking fluid and rotation. Oil is still new and shaft is free. 11:30 12:00 0.50 COMPZ RPCOM OTHR P remove cable from sheave and prep spool for unloading. Page 4 of 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 COMPZ RPCOM OTHR P Unload old cable spool, up load new ESP, Tech wire and drilling line on to rig with crane. Rig back up ESP equipment. 18:00 19:30 1.50 COMPZ RPCOM PULD P Tally new completion equipment& organize equipment. Set up rig floor handling equipment. Double check tally vs procedure. Continue to fill hole 7 bbls/hour. 19:30 22:00 2.50 COMPZ RPCOM PUTB P PJSM-P/U ESP completion&M/U assembly up to to the top shroud& X-over pup. Total of 99.50' 22:00 00:00 2.00 COMPZ RPCOM OTHR P M/U Fixed end wet connection up to splice. 02/25/2014 P/U ESP completion strings and M/U splice to motor lead&Tech wire to Gardian Guage. P/U 1000'of 4.5" completion. R/U Eline and RIH with 3.80"drift down to 972', POOH and P/U ESP motor. RIH and line parted @ 572', RIH with LIB to 916'. R/D SL, POOH with completion string standing back 9 stands, cut splice above motor shrouds, break off below Pump Can, retrieve SL tools and ESP pump. M/U splice above motor shroud. 24 hour losses=86 bbls. 00:00 02:00 2.00 COMPZ RPCOM OTHR P Continue M/U splice from motor lead to spool. Mig cable-good. 02:00 06:30 4.50 210 COMPZ RPCOM OTHR P P/U 3 joints then Gardian Guage. M/U splice to tech wire spool. 06:30 08:30 2.00 COMPZ RPCOM PULD P Continue to pick up 4.5 IBT-M tubing. Drifting with 3.833 drift @ floor 08:30 10:30 2.00 COMPZ RPCOM PULD P PU ALC/Centrilift pump asssembly and service. 10:30 18:00 7.50 COMPZ RPCOM SLKL T PJSM RU HES slick line unit. RIH with 3.80 with centerlizer 3.83 X 8.4' . to 992 ft. Pu motor assembly RIH to 700 ft- hit oil pad pick up and lost tool string. Un string 1.6 wire and string 1.25 wire. Run 3.8" IB. Tagged @ 528 ft. POOH. No markings. RIH with same tagged 916 ft. POOH wire indicated on IB. RD slick line. 18:00 20:00 2.00 COMPZ RPCOM PULL T POOH with ESP equipment 8 Stands. Break down gaurdian gauge and keep techwire connection together. POOH 1 stand, Cut ESP cable on splice connection above the top motor shroud. POOH and make break at botttom of ALC pump can. 20:00 21:00 1.00 COMPZ RPCOM FISH T Retrieve SL tools, break down on rig floor. 5 ft of wire attached to the rope socket. Pull 30ft retrievable pump from No-go, set pump in mousehole. M/U ALC pump Can to bottom section. RIH&set up rig floor to re-splice ESP cable. 21:00 23:30 2.50 COMPZ RPCOM FISH T Re-splice connection. Test ESP pump in mousehole. P/U and stand back in the derrick. Page 5 of 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:30 00:00 0.50 COMPZ RPCOM PUTB T PJSM-P/U completion-total of 9 stands.. 02/26/2014 Complete Splice above motor shroud, RIH 1000'. R/U SL and continue with attempting to set ESP motor/pump.Attempts© 1000', motor stuck @ 888', move string in hole down to 1430',fish motor, move completion string up to 639', attempt to set motor numerous times, tool shearing but not locating, move completion string up to 232'. 24 hour losses= 178 bbls, Change KWF to 10.6#. 00:00 01:00 1.00 195 COMPZ RPCOM OTHR T Continue making splice above motor shroud. 01:00 02:00 1.00 195 1,020 COMPZ RPCOM PUTB T TIH 1000'installing cannon clamps. Clean up rig floor and prep for slick line operations. 02:00 03:00 1.00 1,020 COMPZ RPCOM SLKL T Wait on Slickline to arrive, 02:30=8 hours off. 03:00 08:30 5.50 COMPZ RPCOM SLKL P R/U slickline, fill hole pumping 35 bbls down the tubing, RIH with drft run to 973 ft. POOH. Picked up motor assembly hung up @ 841' pumped down to 880ft unable to get past. BHA in 7°dogleg. Sheared off motor&POOH. 08:30 09:30 1.00 COMPZ RPCOM PUTB T Continue to pick up completion& RIH to 1430'to clear dog leg with ESP BHA. 09:30 13:30 4.00 COMPZ RPCOM SLKL T Pick slick line back up. RIH with catch assembly pullled motor free. pooh to 1203 ft motor hung up. worked with Hyd.jars. 16 hits pull free. continue out. sat back motor, RD slick line. Start pumping 10.6#KWF. 13:30 15:00 1.50 COMPZ RPCOM PULL T POOH with esp bbl to 600 ft. 15:00 16:30 1.50 COMPZ RPCOM OTHR T Service motor seals. Seals bad. lay down seals. Check motor. Ok. 16:30 23:30 7.00 COMPZ RPCOM SLKL T Pick slick line up. RIH with3.80 drift to 639 ft. pumped 18 bbls of 10.7 KWF down tubing. let fluid balance out. Check fluid level with drift. Fluid @ 400 ft. Try to work motor and try to engage wet connect. No luck, make 3 seperate attempts, along with motor inspections. 23:30 00:00 0.50 COMPZ RPCOM SLKL T Lay down SL equipment, POOH with completion string to 232'to a vertical part of the well. Pump 34 bbls to fill well. 32/27/2014 Attemp to troubleshoot ESP motor/pump complications @ 232'. TOOH with completion, found the motor drifted past the wet connect due to the Pump Can assembly being out of alignment by 15 degrees. Break down assembly, adjusted back to correct alignment and tach welded the housing into place. Replaced the fixed wet connect, make up new completion assembly,splice the ESp connection. TIH to 289', run motor, pump then pack off, all tests passed. P-test pack offs to 1500 psi/5 minutes. Pass. Continue to TIH with 4.5" completion string. Stop every 1000'to drift and perform surface tests on cable. 24 hour losses=212 bbls Page 6 of 9 —Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 COMPZ RPCOM PULL T POOH to 232', R/U Slick line, pump 25 bbls down tubing. R/U motor pump and seals. 02:00 04:00 2.00 COMPZ RPCOM SLKL T Attempt to engage motor assembly, tag up, 196'over pull weights& depth change slightly each attempt. Tap down, slid down 2ft to enaging position @ 198', no readings on ESP, P/U overpull @ 196', set back down to 202'. Tap down on tool in no-go position, bad(short)in the cable readings. Possible 4ft deeper than should be, decision to POOH with SL. RD Slickline&prepare to stand back completion string. 04:00 05:00 1.00 COMPZ RPCOM PULL T POOH with completion string. Inspect motor shrouds, and pump can with motor still inside the shrouds. Motor has gone past engaging position&the top part of the pump can has rotated about 15 degrees. Decision to P/U 5 stands and RIH to fish out the pump. 05:00 06:30 1.50 COMPZ RPCOM SLKL T R/U SI and fish motor assembly. 06:30 08:00 1.50 COMPZ RPCOM PULL T POOH with outer ESP equipment. Pump can off center+/- 15° . Most likely the reason for failed connection attempts. 08:00 10:30 2.50 COMPZ RPCOM OTHR T Adjusted can back in line&replaced the fixed end wet connection. Tack welded bottom of can. 10:30 16:00 5.50 COMPZ RPCOM OTHR T Install motor lead to motor can, Splice on motor lead to cable. 16:00 17:30 1.50 283 COMPZ RPCOM TRIP P RIH with ESP outer assembly to 289 ft. 17:30 21:00 3.50 283 283 COMPZ RPCOM SLKL P R/U SL and run motor assembly. Tag No-go @ 289'. Pump 25 bbls to fill hole, P/U dogs sheared @ 285' 1800#, RIH slowly, tap down and engage wet connect. Test ESP cable at surface. Good Meg readings but the Zenith guage is fluctuating. Guardian Guage is reading good. P/U pump RIH and set @ 218'. P/U and RIH with Pack Offs, tagged @ 188'. Set with spangs. P/U pressure test tool to test pack offs. 21:00 22:30 1.50 283 283 COMPZ RPCOM SLKL P Pressure test pack offs 1500 psi/5 minutes. -good test, good DH readings. POOH with SL. P/U and install tubing stop. Set SL aside. Page 7 of 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 00:00 1.50 283 1,250 COMPZ RPCOM PUTB P PJSM-P/U 1000'of completion. Drift tubing with 3.83", check surface connections. P/U 1000' 02/28/2014 RIH with new 4 1.2"completion string drifting to 3.83"every 1000'. Difficult time drifting through GLM#1 &2 had to install KS to make clean drift through GLM. Complete packer splice,TIH with ESP completion down to 4860', P/U tubing hanger and drift with 3.83". Successful. Total numbers ran 156 cannon clamps, 15 SS bands. 24 hour losses= 114 bbls. 00:00 01:30 1.50 1,250 1,250 COMPZ RPCOM SLKL P R/U Slick line RIH to 1270'to drift tubing to 3.83". POOH and set back SL. 01:30 04:00 2.50 1,250 2,740 COMPZ RPCOM PUTB P P/U 4 1/2"completion to Viking packer @ 2740'as per program. 04:00 09:30 5.50 2,740 2,610 COMPZ RPCOM SLKL T R/U SLick line and drift tubing with 3.83"drift. RIH 110'tagged up. POOH with SL. Pull 3 joints to inspect GLM. Cannot drift at surface with 3.83". P/U GLM #3 and attempt to drift, no luck. Change drift to 3.80"and drift both GLM's. Laid down GLM ran rig 3.833 drift thru it ok. Picked GLM back up. Ran 4 ft 3.8 drift thru it. Had to tap thru with spank jar.Added second 4 ft section with knuckle jt. dropped it thru GLM. DG sheared and dropped drift. Repinned DG tool RIH to 2550 ft retrieved drift assembly. pooh. laid down slick line. 09:30 10:30 1.00 2,610 2,741 COMPZ RPCOM TRIP P RIH with 1 std of 4.5" 12.6#L-80 IBT-M and packer. 1 jt IF DP. Hung packer above slips. 10:30 19:30 9.00 2,741 2,741 COMPZ RPCOM OTHR P Spliced ESP&tech wire thru packer. Mig connections and test tech wire readings. Good. 19:30 21:30 2.00 2,741 2,891 COMPZ RPCOM SLKL P P/U 4.5"completion&final GLM. P/U weight 70K. R/U SL and drift 3.83"down 300'past packer&GLM. RD SL. 21:30 00:00 2.50 2,891 4,431 COMPZ RPCOM PUTB P Continue TIH with 4.5"completion string. Stop 1000'and test cables. 03/01/2014 RIH with completion down to 4870', P/U weight 98K, down 75K. R/U SL and drift tubing&hanger to 3.833". M/U final splice and test connections, land tubing hanger&tet pack off 250/5000 psi. Reverse circ 50 bbls of 1%corrossion inhibited fluid spot around packer. R/U SL and set WRP @ 2250',test, POOH. Set Viking packer 4200 psi, center of element @ 2117'ORKB,test IA 1500 psi for 30 minutes, perform slow pressure bleed. R/U SL and set catcher sub @ 2248', pull dummy valve from GLM#1 @ 1993'. R/D Slick line, pull landing joint, set TWC, NDBOPE. Test ESP cable and connections. 24 hour losses= 168 bbls. 00:00 01:00 1.00 4,431 4,856 COMPZ RPCOM PUTB P P/U 4 1/2"completion down to 4850' 01:00 03:30 2.50 4,856 4,870 COMPZ RPCOM SLKL P R/U SL and drift from surface down 1945'with 3.83"including the tubing hanger at surface. Install ISO sleeve following the drift. RD SL. Page 8 of 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 07:00 3.50 4,870 4,870 COMPZ RPCOM THGR P M/U landing joint and tubing hanger. Start splicing ESP cable to tubing hanger. Test connections. Land tubing hanger-P/U weight 98K , Down 75K. RILDS. Test 250/5000 psi/ 07:00 08:30 1.50 4,870 COMPZ RPCOM CRIH P Pumped 50 bbls of 5%CRW treated 10.7 KCL/Brine followed with 15 bbls untreated brine. @ 3 BPM @ 90 psi. 08:30 13:00 4.50 COMPZ RPCOM SLKL P PJSM Ru HES slick Ine. RIH withGLM locator. locate GLM @ 2230' . RIH with weatherford WRP set plug @ 2250'. POOH with setting tool assembly. Laid down slick line. 13:00 19:00 6.00 COMPZ RPCOM PACK P RU lines to set Viking packer @ 2116'. Pressure up to 4150 psi. sheared packer. continue to pressure up to 5K. Missed shear. held for 5 mins. bled off pressure. re pressured up to 4200 psi for 5 mins. bled off pressured up to 4200 psi for 10 mins. bled down to 1000 psi for 10 min's. bled off tubing. Pressured up on IA to 1500 psi for 30 min's. completed slow bleed off as per program. 19:00 22:30 3.50 COMPZ RPCOM SLKL P PJSM- R/U SL first run to set catcher sub @ 2248' SLMD. Second run Pull DV @ 1993'. RD Slickine&set TWC. 22:30 00:00 1.50 DEMOB WHDBO NUND P ND BOPE. Empty pits on rig. Start hauling off tank farm and filtration skid. 03/02/2014 Freeze protected well. RD equipment. Clean pits Rig released @ 10:30 hrs 00:00 01:00 1.00 COMPZ WHDBO NUND P Complete ND BOPE, test ESP cable through penetrators prior to NU tree. Good test. 01:00 04:00 3.00 COMPZ WHDBO NUND P NU tree. Pressure test 250/5000 psi. 04:00 07:30 3.50 COMPZ WHDBO FRZP P R/U LRS to freeze protect well. Pull TWC and line up valves. 07:30 08:30 1.00 COMPZ WHDBO MPSP P Set BPV&secured well. 08:30 10:30 2.00 COMPZ MOVE DMOB P Clean pits RD lines. Rig Released @ 10:30 hrs Page 9 of 9 1D-12^ COST-RIG WELL WORK DATE SUMMARY 3/19/2014 PROVIDED CRANE ASSIST TO PULL BPV. GAUGED TBG TO 3.81"TO CATCHER @ 2219' SLM. IN PROGRESS. 3/20/2014 PULLED DV © 2229' RKB. SET OVs © 1994'AND 2229' RKB. PULLED CATCHER AND WRP @ 2259' RKB. GAUGED TBG TO 3.81"TO TBG STOP @ 4723' SLM; SET CATCHER @ SAME. REPLACED DV©4621' RKB WITH SOV. PULLED CATCHER. COMPLETE. STATE OF ALASKA ALP. OIL AND GAS CONSERVATION COMOION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well r Rug Perforations r Perforate r Other SC sleeve repair Alter Casing r Pull Tubing r Stimulate - Frac r Waiver f 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 , 1 97 - 213 3. Address: Stratigraphic r Service r 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 22830 - 00 e 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025650 10 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): Kuparuk River Field / We Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 5462 feet Plugs (measured) 5290 true vertical 4033 feet Junk (measured) None Effective Depth measured 5433 feet Packer sured) 2863 true vertical 4004 feet ....rr/ " ' ^ (true vertucal) 1998 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121 121 GRAVEL PACK L 411 6.7 5290 4023 � � � � �r SURFACE 5412 10 5453 g� 0't3 V ED Sleeve 4' 11.5" 10" SCONE- MAR 1 DEC 18 2012 AOGCC Perforation depth: Measured depth: 4984 -4999, 5009 -5049, 5070 -5090, 5116 -5133, 5156 -5169, 5183 -5193, 9199 -5209, 5239 -5249, 5252 -52. True Vertical Depth: 3555 -3570, 3580 -3620, 3641 -3661, 3687 -Q704,. 3727 -3740, 3753 -3764, 3770 -3780, 3810 -3820, 3823 -381 Tubing (size, grade, MD, and TVD) 3.5, L -80, 4808 MD, 3379 TVD Packers & SSSV (type, MD, and TVD) PACKER - ESP FEED -THRU PACKER, SLB -MZ PACKER @ 2863 MD and 1998 TVD NONE - Type Not Found (Manual Entry Required) @ 0 MD and 0 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): NA 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 NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development I; - Service r Stratigraphic r 16. Well Status after work: r Oil I✓ Gas r WDSPL r Daily Report of Well Operations X 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: 312 -408 Contact MJ Loveland /Martin Walters Printed Name MJ Loveland Title WI Projects Supervisor Signature / Phone: 659 -7043 Date 12/14/12 ,..„.7 7 A P, "_,:-,, .4i-- r-yi C, 1 0 2C 2 // f /2 •Z'J' 1 Form 10 -404 Revised 11/2011 / Submit Original Only • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 December 14, 2012 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Commissioner Seamount: Enclosed please find the 10 -404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 1D -129, PTD 197 -213, Sundry 312 -408 surface casing repair. Please call MJ Loveland or Martin Walters at 659 -7043 if you have any questions. Sincerely, MJ Lovel ConocoPhillips Well Integrity Projects Supervisor • 1D-129 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 07/08/12 Cut two 5" X 15" windows in conductor for sealant prep. 07/18/12 Kakivik inspected SC thru windows and found external corrosion thru out inspected area and 2 spots with > 50% wall loss. 11/30/12ICut 8' of conductor and the starter head off wellhead. 12/01/12 E- mailed AOGCC and inform them that they have opportunity to witness damage to SC, Jeff Jones waived. 12/07/121E- mailed AOGCC to inform them of opportunity to witness repair to SC - no response. 12/09/121 Welded 4' 11.5" of 10" x65 X.500 wall pipe sleeve onto SC 12 /11 /12IKakivik NDE inspected Sleeve 12 /12 /12IWelded a 7' 5" X 16" 62# .375 conductor around SC. I 1 t � Mk k„..''',-,41 . . ' :t. I : i • .. ...,. -',„--,,, , . �:,' , ' 7 , .y a �' F4 , f e. . , .. ,i.4,.. ,‘,,*:%;:, (a i i; :. ; .):. ,, . . 4 -,,i1, . , . , : s ,,„„, ‘ ` fir, _ 1, fy F' •4t k f y .. �. . /ti �f. - .. ��` I _i~ I • � / ' `. ice „7611 . r:r -; -..'i.". ::*: ' 1..- ' '‘. - : .°...-.:..9i''''.:1'''.' r . vg, .. >S _ • j .r. s . A UConocoPhillips Alaska. Inc This photo is copyright by ConocoPhillips Alaska, Inc. and cannot be released or published without express P _; written consent of ConocoPhillips Alaska 5 Xr t r Al- Y S.f 6 +4: ' liv, } f.P r a`b xen ,y, w «3 ,r� t' R" ,rt'S,C �' J°, 4 ,, - 1 f 3! ML .. x i , I " d : be. release ,or, 11r I : pr bush 'without express ,A,', • ►�q,�erl rprl auto; ' GmvllPs Alas. ¢ r.- ! f MS J . at . 7 r j r ti F� - 1 _ r 1 ,4 4-:&,.. 6 f ,,, a.k r , ...r a t F a� a ^ ,a r Y 1 ! ++ "� S, f +�" I i7 " F''' 73 t • VI %dr - 3 f ` C•�� } 3 fi e! : , �! }t - 5 ^ Y .. l C,� F ? "s ":', 5 �S: 0 0 ., - �, 2rr , 'nj ",y'•'` • . g `�+ Y .. R : a a '9t.r : C3 F5 X t} .� it j7 + .3r VI . t r;s� S3 �k a�k br t> T . . -'"' t , u .':.", ". T'y cy n l Y tt + -} . +� '�pp : ,' Y r ti , • jc 1 ` ""�.. 1 .� .7 ,. 'rF ; r ethr•,rk�, ,. ^!� !} vr'f'9s x t s 1..',:::,.%-...:2,4:-k,,,-,-,,1"',''.. -- s w • h " r °' i e t 3 a +x v. i . t ^ i 1 r ` r , .. $ • 1 r 1 I j u,+ '4 1 � ��tsg5w� "fi} � •� � �� . tin rk .. - 1w�. �� "+ �t � �� r'^a 1 M � � h',. : 1 ,:'S•+ t T",) t ; +' Ni �, _ .- - . ��(: + - t ''' , P ;� - '"? lyS 7 i'& �r . • s 4 �i ''''''04,.. x ,. E t c r � ,.+ I } 9 t. � � t!� i t �, d f j£ � - r }�J e NN z lb v ..' k" 3 + F S e y F • I' v. T ' f x k 5 v. ev 1 F' wit itry 5 r r Y � s 't Y i y t, a r 3 { . • i r tz w uhf s ., 2 " .� d: t . ,,,, , ,,..,,,, .. . ,3,..,,,*..,,,, ,A.,.S. ..!' ',:„. ,,' - ( . •(° . w{taRR t,{h+ 1 vac' . 1 • • ` - cn r r `v r ti y r � ' t ' h7'tA Y ,+ 4 i A t .' r I . t az X y r x ' Y ! r a r w t -i p + 10 t r l h' ' �` r a • 1 • 3 } ..+ . `, +f B r ! 7j 7-!,, a F �.''': - ; _ pv. - ) S • i Y 0.x r 1 jr'£ 1: j 1 { 4 ',''...'' f Y J , w ;r • , r ,7 h �a. .a.,..y 4 + 3 .. � +ice.. "' •:,a �.# d5j,� '•Mfr k � ♦' .#� '�• u� .a A tl 5 x is A ' . Jr a ,( w + .ks„ 4,..,,,.: . . ? 0 s ..v+.. r� : 2� k �s��..�t� !." *,�� i/7,:" 6 . THE STATE Alaska Oil and Gas °fALASKA Conservation Commission c ittitAt t GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF ALA91°.' Anchora 9 e Main: 907 2 Fax: 907.276.7542 MJ Loveland SCANNED JAN 10 2013 WI Projects Supervisor ConocoPhillips Alaska, Inc. 1 3 P.O. Box 100360 � ! -' :- ------- Anchorage, AK 99510 --- Re: Kuparuk River Field, West Sak Oil Pool, 1D -129 Sundry Number: 312 -408 Dear Ms. Loveland: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. 4 erel , Wit f K. ■ or Com 'ssioner DATED this / day of November, 2012. Encl. • • loPv RECEIVED ConocoPhillips ?AI? Alaska P.O. BOX 100360 A . ANCHORAGE, ALASKA 99510 -0360 '' 4`' ra October 20, 2012 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Commissioner Seamount: Enclosed please find the 10 -403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 1D -129, PTD 197 -213 surface casing inspection and repair. Please call MJ Loveland or Martin Walters at 659 -7043 if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor STATE OF ALASKA • A SKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon r . Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Hug Perforations r Perforate �j, 9p��Il Tubi d 4 v Time Extension r a !' rt g r 1 z tia1 Operational Shutdow n r Re -enter Susp. Well [ Stimulate I` After casin g r" d Other:SC sleeve repair rq• 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development rpl • Exploratory [ 197 -213 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 22830 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes [ No r 1D -129 • 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0025650 • Kuparuk River Field / West Sak Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 5462 , 4033 ' 5433' 4004' 5290' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121' 121' �� -�y,qC l'''''' � ' GRAVEL PACK LINER 411 6.7 5290' 4023' �'+ ,. SURFACE 5412 10 5453' 3861' OCT (li,l 3 �,.„:y §,_ailCC 1 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4984 -4999, 5009 -5049, 5070 -5090, 5116- 3555 -3570, 3580 -3620, 3641 -3661, 3687- 5133, 5156 -5169, 5183 -5193, 9199 -5209, 3704, 3727 -3740, 3753 -3764, 3770 -3780, 5239 -5249, 5252 -5289 3810 -3820, 3823 -3860' 3.5 L - 4808 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - ESP FEED -THRU PACKER, SLB -MZ PACKER MD= 2863 TVD= 1998 NONE - Type Not Found (Manual Entry Required) MD= TVD= 12. Attachments: Description Summary of Proposal pi 13. Well Class after proposed work: Detailed Operations Program [ BOP Sketch [ Exploratory Development • r Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 1/1/2013 Oil r • Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ C GINJ r WAG r Abandoned r Commission Representative: GSTOR [ SPLUG [ 17. I hereby certify that the foregoing is true and correct to th est of my knowledge. Contact: MJ Loveland /Martin Walters Printed Name MJ Loveland Title: WI Projects Supervisor Signature ,07///Tr.'" Phone: Date /ay if - 7 7 i , Commission Use Only (1� Sundry Number: 312_ (O r (� y` Conditions of approval: Notify Commission so that a representative may witness Plug Integrity BOP Test r Mechanical Integrity Test Location Clearance ° 9 9 tY � r� 9 tY � _; Other: , p),/0 G!!2 6 (/!'>/Z rzp Q)rs Subsequent Form Required: 1 4 _ 4 a 4 0 i 3 APPROVED BY f jr��_ 'C) k 4 OCT 31 COMMISSIONER THE COMMISSION Date: Z/ 1' • Form 10 -403 Revised 1/20 11 " / - , • GINAL � � P Submit in Duplicate t ��13t11 1�� 12 _ iiozu • ' S ConocoPhillips Alaska, Inc. Kuparuk Well 1D -129 (PTD 197 -213) SUNDRY NOTICE 10 -403 APPROVAL REQUEST 10 -19 -12 This application for Sundry approval for Kuparuk (WestSak) well 1D -129 is for the proactive inspection pP rY pp P ( ) p p and repair of the casing packer - ESP well that was p f t e surface casing near surface. This well was a single cas g pac drilled and completed in 1998. During proactive casing inspection work the production casing was discovered to have several areas with localized near surface corrosion and significant wall loss. ConocoPhillips intends to excavate around the well head approximately 10' deep, remove the conductor, and patch the suspected areas on the surface casing. With approval, inspection and possible repair of the production casing will require the following general steps: 1. Ensure the well is Secure with a tubing plug. 2. Remove the floor grate, well house, flow lines, and other equipment from around the wellhead. 3. Remove gravel from around well head to an approximate depth of 10' 4. Install nitrogen purge equipment for the conductor (and OA if needed) so that hot work may be conducted in a safe manner. 5. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Remove all of then exposed of conductor if needed. Notify AOGCC Inspector for opportunity to inspect. 6. CPAI Mechanical Engineers will determine if patch or repair is needed to return the casing to operational integrity. 7. If a patch is required, QA/QC will verify the repair for a final integrity check. 8. Install anti - corrosion coating as specified by CPAI Corrosion Engineer. 9. Replace the conductor and fill the void with cement and top off with sealant. 10. Backfill as needed with gravel around the wellhead. 11. Remove plugs and return the well to production. 12. File 10 -404 with the AOGCC post repair. Well Integrity Project Supervisor 10/19/2012 1p, t '` . x }> 4 . STATE OF ALASKA AL, OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1 1. Operations Performed: Abandon r Repair w ell r Plug Perforations r flb rforate [ Other r Alter Casing r Pull Tubing Pr 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 ry" Exploratory r ^ 197 - 213 3. Address: 6. API Number: Stratigraphic - Service P. O. Box 100360, Anchorage, Alaska 99510 '° 50 - 029 - 22830 - 7. Property Designation (Lease Number): • 8. Well Name and Number: ADL 25650 - ' 1D 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 5462 feet Plugs (measured) 3007', 5290' true vertical 4033 feet Junk (measured) None Effective Depth measured 5433 feet Packer (measured) 2863 true vertical 4004 feet (true vertucal) 1998 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121 121 RECEIVED SURFACE 5412 7.625 5453 4023 GRAVEL PACK LINER 411 4.5 5290 3861 JUN 0 1 7 012 AOGCC Perforation depth: Measured depth: 4984 -4999, 5009 -5049, 5070 -5090, 5116 -5133, 5156 -5169, 5183 -5193, 5199 -5209, 5239 -5249, 5252 -5289 True Vertical Depth: 3555 -3570, 3580 -3620, 3641 -3661, 3687 -3704, 3727 -3740, 3753 -3764, 3770 -3780, 3810 -3820, 3823 -3860 Tubing (size, grade, MD, and TVD) 3.5, L -80, 4840 MD, 3411 TVD Packers & SSSV (type, MD, and TVD) PACKER - ESP FEED -THRU PACKER, SLB -MZ PACKER @ 2863'M and 1MB ND PACKER - BAKER SC -1 GRAVEL PACKER @ 4880 MD and 3451 TVD NO SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: " JUL 0 a zoi 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 81 35 69 -- 216 Subsequent to operation shut - in 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development 17 . Service r Stratigraphic r 16. Well Status after work: • Oil P Gas r WDSPL r 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 Brett Packer (7a. 265 -6845 Printed Name Brett Packer Title Sr. Wells Engineer - Signature 7 /?mot Phone: 265 -6845 Date / f7rz Form 10-404 Revised 11/2011 R eDAAS JUN 0 1 co Submit Original Only Y ,'' KUP 1D -129 CIonoc illips o Well Attributes Max Angle & MD TD Alaska Inc 3a. Wellbore API/UWI Field Name Well Status Intl ( °) MD (ftKB) Act Btm (ftKB) - corocor+vtGps 500292283000 WEST SAK PROD 58.37 2,146.26 5,462.0 ' Comment H2S (ppm) Date Annotation End Date KB-Ord (ft) Rig Release Date ' - -' SSSV: NONE 0 9/26/2011 Last WO: 5/1/2012 41.00 11/29/1997 Well Conan: -1 0-129, 5/16/2012 2'.06'.07 PM Schematic- Actual Annotation Depth (ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason: WELL REVIEW osborl 5/16/2012 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 15063 41.0 121.0 121.0 62.58 H - 40 WELDED r -` Casing Description String 0... 'String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd CONDUCTOR, SURFACE 75/8 6.875 40.7 5,452.6 4,023.4 29.70 L -80 BTCM 41-121 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd Gravel Pack Liner 4 1/2 4.000 4,879.6 5,290.3 3,861.2 Liner Details Top Depth (TVD) Top Inc! Nomi... Top (ftKB) (RKB) r) Item Description Comment ID (in) MIMI MANDREL P.. 4,879.6 3,450.6 1.35 PACKER BAKER SC -1 GRAVEL PACKER 4.000 2.744 M 4,884.4 3,455.4 1.34 EXTENSION UPPER MILLOUT EXTENSION 4.892 4,888.3 3,4592 1.34 SLEEVE SLIDING SLEEVE 4.892 PACKER, 2,863 4,890.8 3,461.8 1.34 SBE BAKER SEAL BORE 4.000 I AM 4,892.3 3,463.3 1.33 EXTENSION LOWER MILLOUT EXTENSION 4.000 ... 4,907.7 3,478.7 1.43 X0 Reducing CROSSOVER 5 "x4.5" 4.500 ESP MANDREL, ,. 4,983.5 3,554.5 1.36 SCREEN BAKER 0.20 GAUGE SCREEN 4.000 , 2,982 5,008.6 3,579.6 1.34 SCREEN BAKER 0.20 GAUGE SCREEN 4.000 III ii 5,038.7 3,609.7 1.31 SCREEN BAKER 0.20 GAUGE SCREEN 4.000 PLUG, 3,007 CATCHER, 5,078.8 3,649.8 128 SCREEN BAKER 0.20 GAUGE SCREEN 4.000 3,009 5,119.0 3,689.9 124 SCREEN BAKER 0.20 GAUGE SCREEN 4.000 ESP 5,159.1 3,730.0 1.20 SCREEN BAKER 0.20 GAUGE SCREEN 4.000 1 MAN 46E9L8, 5,199.2 3,770.1 1.17 SCREEN BAKER 0.20 GAUGE SCREEN 4.000 5,239.4 3,810.3 1.13 SCREEN ' BAKER 0.20 GAUGE SCREEN 4.000 IMF DISCHARGE, 5279.5 3,850.4 1.04 SCREEN BAKER 0.20 GAUGE SCREEN 4.000 Mir 4'750 . , 5,289.6 3,860.5 1.04 PLUG BULL PLUG 0.000 On Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd INTAKE, 4,808 : TUBING WO 3 1/2 2.992 37.0 4,840.1 3.411.1 9.30 L - 80 EUE SEAL, 4,812 GEAR, 4,828 Completion Details Top Depth MOTOR, 4.828 L (TVD) Top Inc! Nomi... GAUGE. 4,836 `�" Top (ftKB) (ftKB) E) Item Description Comment ID (in) CeMr, 4,838 r ` 37.0 37.0 -0.57 HANGER VETCO GRAY TUBING HANGER 2.950 2,863.3 1,998.3 55.48 PACKER ESP Feed -Thru Packer, SLB -MZ packer 2.920 4,750.2 3,321.2 1.48 DISCHARGE WeIILift Discharge Gauge Unit. S/N# 12129923 2.992 4,807.6 3,378.6 1.42 INTAKE TTC Receiving X0 Coupling w/ perforated intake 2.992 WIN 4,812.4 3,383.4 1.42 SEAL Tandem Seal Section. S /N# 12064502 / 12064738 gni_ 4,826.1 3,397.2 1.40 GEAR Gear Reduction Unit 4,828.0 3,399.0 1.40 MOTOR ESP Motor, 562MSP1, 60 hp/1240V/29 S/N# 12059549 4,836.3 3,407.3 1.39 GAUGE WellLift Motor Gauge Unit. S /N# 192 -00828 4,838.1 3,409.1 1.39 Centralizer Motor Centralizer. (P/N# C63569) 4.000 SLOTS, + Other In Hole (rIVireline retrievable plugs, valves, pumps, fish, etc.) 4,984-4,999 - •+-® Top Depth (TVD) Top Intl 1 1 Top (ftKB) (ftKB) (e) Description Comment Run Date ID (in) 3,007.0 2,078.8 56.14 PLUG PLUG SET ON TOP OF CATCHER. 4/30/2012 0.000 SLOTS, - - - 3,009.0 2,080.0 56.15 CATCHER WEATHERFORD WRP 4/30/2012 0.000 !' 5,009-5,024 PERF, 074 I 5,010-5,038 I P erfor ations & Slots FRAC, 5,010 Shot Top (TVD Btm (TVD) Dens ��° Top (ftKB) Bin (RKB) (ftKB) (ftKB) Zone Date (. Type Comment SLOTS, ,, -'- -- - - - 4,984.0 4,999.0 3,555.0 3,570.0 NF, 1D-129 9/19/1999 50.0 SLOTS 4.5" HT .020 Gauge Screen 13.5# 5,039-5,049 IPERF, 5,009.0 5,024.0 3,580.0 3,595.0 WS D, 1D -129 9/19/1999 50.0 SLOTS 4.5" HT .020 Gauge Screen 13.5# 5,070.5,0901 \ FRAC, 5,070 \ 5,010.0 5,038.0 3,581.0 3,609.0 WS D, 1D-129 12/6/1997 4.0 IPERF O deg ph/ow side; 2 1/8 "EJ M . FRAC, 5,070 III SLOTS, I 5,039.0 5,049.0 3,610.0 3,620.0 WS C, 1D -129 9/19/1999 50.0 SLOTS 4.5" HT .020 Gauge Screen 13.5# 5,079-5.089 L 5,070.0 5,090.0 3,641.0 3,660.9 WS B, 1D -129 12/4/1997 4.0 IPERF 0 deg ph/low side; 2 1/8 "EJ 91079. ■ 5,079.0 5,089.0 3,649.9 3,659.9 WS B, 10-129 9/19/1999 50.0 SLOTS 5,119 -5,129 APERF,\ 5,116.0 5,133.0 3,686.9 3,703.9 WS A4, 10.129 9/15/1999 12.0 APERF HSD - BH 41/2" 5,116-5,133 I 5,1190 5,129.0 3,689.9 3,699.9 WS B, WS A4, 9/19/1999 50.0 SLOTS 4.5" HT .020 Gauge Screen 13.5# #, 10.129 APERF, 5,15fi5,166Ns 5,156.0 5,166.0 3,726.9 3,736.9 WS A4, WS A3, 9/15/1999 12.0 APERF HSD -BH 4 1/2" SLOTS, 1D-129 5,159 -5,169 ' ' 5,159.0 5,169.0 3,729.9 3,739.9 WS A3, 10.129 9/19/1999 50.0 SLOTS 4.5" HT .020 Gauge Screen 13.5# 5,183.0 5,193.0 3,753.9 3,763.9 WS A3, 10.129 9/15/1999 12.0 APERF HSD- BH 41/2" 5,1835E7 3 5,199.0 5,209.0 3,769.9 3,779.9 WS A3, WS A2, 9/19/1999 50.0 SLOTS 4.5" HT .020 Gauge Screen 13.5# 1D -129 SLOTS, _ -- - __- 5,1995,209 ' 1 5,239.0 5,249.0 3,809.9 3,819.9 WS A2, 10.129 9/19/1999 50.0 SLOTS 4.5" HT .020 Gauge Screen 13.5# 5252.0 5,282.0 3,822.9 3,852.9 WS A2, 1D -129 11/30/1997 4.0 IPERF 0 deg ph/low side; BH EJ SLOTS, 5,279.0 5,289.0 3,849.9 3,859.9 WS A2, 1D -129 9/19/1999 50.0 SLOTS 4.5" HT .020 Gauge Screen 13.5# 5,239-5,249 IPERF, 5,252-5,282 -- IuI FRAC, C,5,252 SLOTS, 5,279-5,289 Mandrel Details Gravel Pack Top Depth Top Port Liner, (TVD) Intl OD Valve Latch Size TRO Run 4,680 -5,290 Stn Top (ftKB) (ftKB) (°) Make Model (in) Sew Type Type fn) (psi) Run Date Com... ! 1 2,743.7 1,929.2 54.93 Camco KBMG 1 ESP DMY BK -5 0.000 0.0 4/29/2012 SURFACE, 2 2,981.5 2,064.7 56.03 Camco KBMG 1 ESP DMY BK -5 0.000 0.0 4/29/2012 41 -5,453 TD, 5,462 3 4,698.1 3,269.2 4.21 Camco KBMG 1 ESP DMY BK -5 0.000 0.0 4/29/2012 KU P • 1D-129 ConocoPhiHips owes- Alaska, trv. KB (R) Rig Release Date "' 41.00 11/29/1997 Well Confl9: -10 -129, 5/16/2012 2:06.07 PM Schema tic- Actual HANGER, 37 „ Stimulations & Treatments .. _ Bottom Min Top Max Btm Top Depth Depth Depth Depth (TVD) (TVD) (MB) (RKB) (RKB) MB) Type Date Comment CONDUCTOR. 41 5,010.0 5,038.0 3,581.0 3,609.0 FRAC 12/6/1997 WS D-SAND FRAC - 102651# Proppant treated w /Proplok w /10# PPA 16/20# 1 5,070.0 5,090.0 3,641.0 3,660.9 FRAC 12/4/1997 B-SAND FRAC - 73759#, w /10# PPA OF 16/20# i 5,070.0 5,090.0 3,641.0 3,660.9 FRAC 12/5/1997 B -SAND FRAC part 2- 109044 #w /18# PPA 16/20# 5,252.0 5,282.0 3,822.9 3,852.9 FRAC 12/2/1997 A2 SAND FRAC - 189120# w/9# 16/20 proppant ESP IMF Notes: General & Safet8, MANDREL, arm End Date Annotation 2,744 l♦ 11/22/1997 NOTE: ESP WORKOVER 9/19/1999 NOTE: ESP WORKOVER, ADD GRAVEL PACK ”" 11/13/2003 NOTE: ESP WORKOVER PACKER. 2,863 INF 1/12/2011 NOTE: View Schematic w/ Alaska Schematic9.0 Mr ESP MANDREL, 2,982 I [ Ng PLUG, 3,007 CATCHER. 3,009 ill ESP MANDREL, MC 4,698 at IMF ME DISCHARGE. 4.750 IL IN ME INTAKE, 4,808 SEAL. 4,812 GEAR, 4,828 g � - MOTOR, 4,828 Air`-FF GAUGE, 4,836 - c. I Centralizer, 4,838 Mil 1111B I 1 .10.-",.... SLOTS, � Fi 4,984 -0,999 Mi in SLOTS. -- ± ® -- 5,0095,024 - - I IPERF. ' ►T FRAC, 5,0 F 10 RAC, 5,070 III S II LOTS, - - _ -- 5,0395,049 • IPERF, 5,07115,090 I I FRAC. 5,070 FRAC, 5,070 SLOTS, 5.0785,088 SLOTS, 5,1195.129 APERF, 5116 -5,133 APERF, , 5,1565,168 SLOTS, 5,159-5,169 APERF, III 5,1835,193 SLOTS, 5,199-5,209 1 1111 1 I SLOTS, 5,239-5,249 -. IPERF. 5,2525,282 I FRAC. 5,252 SLOTS. 5,279 -5,289 Gravel Pack Liner, , 4,880 -5,290 SURFACE, 41- 5,453 . TD, 5,462 1D-129 Well Work Summary DATE SUMMARY 4/4/12 SET CATCHER AND GR @4!t' SLM. PULLED SOV FROM 4720' RKB, EPLACED W/ DV. PULLED CATCHER AND SLIPSTOP FROM 4734' SLM. IN PROGRESS. 4/5/12 PULLED 3 1/2" D &D PACKOFF FROM 4738' SLM. PULLED 35' 9" x 3 1/2" PCESP FROM 4746' SLM. MEASURED BHP @ 4800' RKB= 1106 psi. RETURNED ON 4/5, PUMPED 42 HOT DIESEL DOWN TUBING AND 185 HOT DIESEL DOWN I /A. SHOT FLUID LEVEL NEXT DAY, 60 FT ON TUBING AND 30 FT ON I /A. PRESSURES ARE 60 PSI TUB AND 20 PSI I /A. BPV INSTALLED ON 4/7. COMPLETE. 4/8/12 PRE RWO TESTING, TOP VOID PPPOT (PASSED), UPPER HANGER BODY PPPOT (PASSED), LOWER HANGER BODY POT (PASSED), LOWER HANGER BODY PPPOT (FAILED), FUNCTION TEST LDS'S • • Conoc Phillips Time Log & Summary We //view Web Reporting Report Well Name: 1D Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 4/26/2012 1:00:00 AM Rig Release: 5/1/2012 5:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/26/2012 24 hr Summary Move over well slot 1 D -129. Rig up. Pull BPV. Kill Well. Set BPV. ND Tree. Set blanking plug. NU Weatherford Safety Tensioning Adapter and BOPE. Initial BOPE test 250/3000. Pull Blanking plug and BPV. Circulate and rnnditinn the hole 00:00 01:00 1.00 MIRU MOVE MOB P Move Rig From 1D-134 to 1D-129, RU Hoses in Cellar, Spot Cutting Box, Spot Kill Tank. 01:00 04:00 3.00 COMPZ WELCTL MOB P PJSM- RU Treating Iron to kill tank, Load Pits with KWF. Accept Rig at 01:00 hours. Spot high line trailer. Spot MI Shack. Change out #10 choke valve. Spot remaining support equipment. Held Pre Spud with Night crews. 04:00 05:00 1.00 COMPZ WELCTL MPSP P PJSM. Load Lubricator to Rig Floor and Install same on Wellhead and Pull BPV, ITP= 5 psi. IAP= 100 psi 05:00 06:00 1.00 COMPZ WELCTL PRTS P Fluid Pack and PT Kill Lines and choke to 250/3500 psi. 06:00 07:00 1.00 COMPZ WELCTL SFTY P Safety Stand Up with Nordic Rig 3 day and night crews, Weatherford well head rep. and ASRC Truck Drivers, Climber Alert, review resent hand injury(s) and fatality, where are we in our own personal commitments to safety? Held changeout with crews. 07:00. 08:00 1.00 COMPZ WELCTL SFTY P Held Pre Spud with Daylight crews - MI, Nordic and ASRC. Held PJSM with PJSM on Killing well with same. Reviewed volumes with Driller as crews were hazard checking work areas in preparation for well kill. 08:00 09:00 1.00 COMPZ WELCTL CIRC P Reverse Circulate 280 bbls of 150° F 3% KCL kill weight fluid off vac truck, taking returns to kill tank at 2 to 3 bpm displacing well of diesel until recovering KWF at surface. Recovered 235 bbls. Well originally took 28 bbls to catch circulation - original fluid level calculates to 650 -ft Static. 09:00 09:30 0.50 COMPZ WELCTL OWFF P Monitor well for flow - TBG and IA on slight vacuum. 09:30 10:00 0.50 COMPZ WELCTLMPSP P Install BPV with dry rod 10:00 11:30 1.50 COMPZ WHDBO NUND P ND Tree. Hang in cellar. Page 1 of7 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:30 12:30 1.00 COMPZ WHDBO NUND P Install blanking plug. NU Bop using Weatherford Safety Tension Adapter. 12:30 20:00 7.50 COMPZ WHDBO BOPE P RU Test equipment and conduct Initial BOP Test at 250 / 3,000 psi. Shoot IA static fluid level at 372 -ft at 18:00 hrs. 20:00 22:30 2.50 COMPZ WELCTL OTHR P Test breaks on choke ( #10 valve changeout). 250/5000 psi against valves 4, 5, 9 and 12 to 5000 psi, leak of rate of 250 psi in 5 min. w/ ni visible leaks, grease valves 4, 5, 9, 12 and add 2nd block valve to test pump hose, leak slowed down to 15 psi in 5 min. still no visible leaks on choke manfold. Test kill line 250/3000 psi. RD test equipment. 22:30 23:30 1.00 COMPZ WELCTL MPSP P Pull blanking plug and BPV, monitor, well static. Install Side Port Isolation Sleeve. 23:30 00:00 0.50 COMPZ WELCTLCIRC P RU circulating equipment, circulate 300 bbls filtered KWF long way, ICP= 70 psi, caught pressure to 230 psi and getting returns at 15 bbls away. 04/27/2012 Circulate and condition the hole. Pull Tubin• Hanger to Floor. Ri• u. to •ull the 3 -1/2" ESP Com•letion. Single down the 3 -1/2" ESP Completion. MU and TIH with 7 -5/8" Cleanout BHA. Unable to enter top of SC -1 Packer at 4,892 -ft. TOOH with BHA #1. MU and TIH with RCJB BHA, 00:00 01:00 1.00 COMPZ WELCTL CIR P Continue to circulate 360 bbls filtered KWF long way at 4 bpm, ICP= 70 psi, caught pressure to 230 psi and getting returns at 15 bbls away, 360 bbls pumped w/ 270 bbls returns (75% returns) 01:00 01:30 0.50 COMPZ WELCTL OWFF P Well on slight vac, monitor well while RD circulating equipment, well static in 20 minutes. 01:30 02:00 0.50 COMPZ WHDBO PULL P PJSM- MU to landing joint, BOLDS. 02:00 03:30 1.50 4,842 4,720 COMPZ RPCOM THGR P Un -land and pull hanger to rig floor. Took 105k to Un -land. Up wt was 95k. 27.7 -ft from mark at rig floor to hanger. Hanger was in good condition, lower o -ring was damaged. LID Hanger and Prep ESP cable and heat trace to spool onto reel. Page 2 of 7 Time Logs • • Date From To Dur S. Depth E. Deoth Phase Code Subcode T Comment 03:30 11:00 7.50 4,720 0 COMPZ RPCOM PULL P TOOH sideways with 3-1/2" Completion while spooling up ESP cable and Heat trace and keeping hole full from trip tank. Recovered 404 - 5 -ft DC clamps 24 - 4 -ft DC clamps 29 - 3 -ft DC clamps 34 - 2 -ft DC clamps 34 - X cplg clamps 1 - SS Band 2 - Flat guards 11:00 13:00 2.00 0 0 COMPZ RPCOM OTHR P Clean and clear rig of decompletion equipment 13:00 14:00 1.00 0 481 COMPZ WELLPF PULD P Held PJSM on picking up BHA #1. PU and MU mule shoe to 2 7/8 511 hydril TBG and RIH to 444 -ft. PU, MU and RIH w/ CSG Scraper assy to 481 -ft. 14:00 17:30 3.50 481 4,893 COMPZ WELLPF TRIP T RIH from derrick w/ BHA #1 on 3 1/2 DP from 481 -ft, Tag up at 4,893 -ft, Attempt of Wash down 3 bpm at 190 psi, ROT 5 rpm, not pressureing up when taking weight, getting 97% returns, make several attempts but still unable to enter SC -1 Packer at 4,393-ft. 17:30 18:30 1.00 4,893 4,893 COMPZ WELLPF OTHR P PJSM with Crane crew, Change out ESP spool, off load Heat aTrace spool. 18:30 21:00 2.50 4,893 481 COMPZ WELLPF TRIP T PJSM TOOH from 4,824 -ft (Up wt 95k, Dn wt 68k) with Clean out / casing scraper BHA. 21:00 22:30 1.50 481 0 COMPZ WELLPF PULD T Lay down Clean out BHA, 1" of tip of Hydril 511 muleshoe folded over, body slightly egged, appears to have been pinched inside of packer top. 22:30 22:45 0.25 0 0 COMPZ WELLPF SFTY T PJSM- discuss hazards of MU of RCJB with Bumper sub and jars. 22:45 23:15 0.50 0 32 COMPZ WELLPF PULD T MU Reverse Circulateing Junk Basket, Bumper Sub, Oil Jar BHA 23:15 00:00 0.75 32 515 COMPZ WELLPF TRIP T TIH with RCJB BHA on 3 -1/2" DP to 515 -ft (Up wt 45k, Dn wt 74k) X4/28/2012 Pick up and RIH with RCJB. Reverse circulate at 4,892 -ft. Trip out. Lay down BHA #2 & #3. Pick up and RIH with 7 -5/8" Cleanout BHA #4. Circulate Hole clean. Trip ou. Pick up and RIH with RBP and Test Packer BHA #5. Test Casino. Trip out. 00:00 01:30 1.50 515 4,878 COMPZ WELLPF TRIP T Continue to TIH with RCJB BHA on 3 -1/2" DP from 515 -ft to 4,878 -ft. 01:30 02:00 0.50 4,878 4,893 COMPZ WELLPF CIRC T Reverse circ 8 bpm ICP 2000 psi, reciprocate down to 4,891 -ft 1 time, RIH to 4,893 -ft and set down 1k for 5 min. FCP 2000 psi. BDTD 02:00 04:00 2.00 4,893 32 COMPZ WELLPF TRIP T PJSM- TOOH from 4,893 -ft (Up wt 105k, Dn wt 70k) with RCJB BHA. 04:00 05:00 1.00 32 0 COMPZ WELLPF PULD T Lay Down BHA #2, recovered 2 complete and 1 partial steel 1 -1/4" bands. Page 3 of 7 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subc ode T Comment 05:00 07:00 2.00 0 0 COMPZ WELLPF SLPC P PJSM- Slip -n -Cut 84 -ft Drill line. 07:00 08:30 1.50 0 4,895 COMPZ WELLPF TRIP T RIH w/ RCJB - 2nd Run to 4,895 -ft. 08:30 10:00 1.50 4,895 4,895 COMPZ WELLPF FISH T Cycle reverse basket w/ slow rotation - showed slight torque. 10:00 12:00 2.00 4,895 0 COMPZ WELLPF TRIP T POOH from 4,895 -ft to surface. Tear down tool and recovered nothing - basket was empty. 12:00 12:30 0.50 0 0 COMPZ WELLPF OTHR T Remove BHA from rig floor and change over to RIH w/ 2 7/8 511 hydril tbg. 12:30 13:00 0.50 0 471 COMPZ WELLPF PULD T PU and RIH w/ 2 7/8 511 hydril TBG and CSG scraper assy to 471 -ft. 13:00 15:00 2.00 471 4,893 COMPZ WELLPF TRIP T RIH w/ BHA #4 on 3 1/2 DP to 4,893 -ft. 15:00 16:30 1.50 4,893 4,893 COMPZ WELLPF FISH T Attempt to work into liner top. unable to enter liner top at 4,893 -ft. BDTD. 16:30 18:00 1.50 4,893 471 COMPZ WELLPF TRIP T PJSM - TOOH w/ BHA #4 from 4,893 -ft, Up wt 95k, Dn wt 70k. 18:00 19:00 1.00 471 0 COMPZ WELLPF PULD T Lay Down BHA, 511 Hydril Muleshoe bottom appears to have been sitting on possible lost balled up Clamp from previous re- completion, confer with town engineer, pics put in folder. 19:00 19:30 0.50 0 36 COMPZ WELLPF PULD P PJSM- PU Baker Model "G" RBP, "L" Retrieving Head, XO Sub, Handling Pup, "EA" Retrievamatic Test Packer and Handling Pup 19:30 22:00 2.50 36 4,806 COMPZ WELLPF MPSP P TIH with BHA #5 on 3 -1/2" DP, Set RBP element at 4,799 -ft, release off RBP, pick up and lay down single joint. Up wt 98k, Dn wt 70k. 22:00 22:45 0.75 4,806 4,806 COMPZ WELLPF PRTS P RU test equipment and pressure test 7 -5/8" casing against RBP to 1500 psi 30 minutes on chart, initial pressure= 1615 psi, 15 minutes= 1595 psi and 30 minute pressure reading 1590 psi, Good. 22:45 23:30 0.75 4,806 4,806 COMPZ WELLPF MPSP P PJSM- TIH and release RBP at 4,806 -ft. 23:30 00:00 0.50 4,806 3,720 COMPZ WELLPF TRIP P PJSM- TOOH w/ BHA #5 from 4,806 -ft, Up wt 95k, Dn wt 70k. to 3720 -ft, Up wt 83k 04/29/2012 Continue to TOOH and Lay down RBP and Test Packer. Pull Wear Bushing. Set Test Plug. Wash BOP Stack. Pull Test Plug. Prep to run ESP completion. Pick up, service and RIH with 3 -1/2" ESP completion. Make Splice at Packer. TIH with remainder of completion. MU Tubing Hanger. Make Final Splice. Land Hanger. RILDS.Test Pack -off. 00:00 01:30 1.50 3,619 0 COMPZ WELLPF TRIP P PJSM - TOOH w/ BHA #5 from 3,619 -ft, Lay down and off load test packer BHA #5 01:30 02:30 1.00 0 0 COMPZ WELLPF OTHR P PJSM- Pull Wear Bushing and Set Test Plug, Wash BOP stack, Pull Test Plug. Page 4 of 7 • Time Logs Date From To Our S. Depth E. Depth Phase Code Subcode T Comment 02:30 04:00 1.50 0 0 COMPZ WELLPF CIRC P Bullhead 160 bbls corrosion inhibited (CRW -123, 1% by volume) filtered seawater down 7 -5/8" casing 2 bpm, ICP 120 psi, FCP 400 psi, pressure down to 115 psi and bleeding down slowly. Change over floors. Prep to run completion 04:00 05:15 1.25 0 0 COMPZ WELLPF OWFF P Monitor well for flow while continuing to prep to run completion, well on slight vac for 30 min. 05:15 05:30 0.25 0 0 COMPZ RPCOM SFTY P PJSM- discuss hazards of make up and running of ESP completion. 05:30 09:00 3.50 0 152 COMPZ RPCOM PULD P PU MU and service lower ESP completion. RIH to GLM #1 to 152 -ft. 09:00 09:30 0.50 152 275 COMPZ RPCOM PUTB P Begin RIH, picking up 3 1/2 TBG to 275 -ft and damaged armor with tbg safety plate and cannon clamp. 09:30 10:30 1.00 275 275 COMPZ RPCOM OTHR T Meg cable - good test. Repair armor damage. 10:30 12:30 2.00 275 1,976 COMPZ RPCOM PUTB P Continue to RIH picking up 3 1/2 TBG from 275 -ft to 1,042 -ft. Meg cable- good test. Continue to RIH picking up 3 1/2 TBG to Camco MZ Packer at 1,976 -ft. 12:30 16:00 3.50 1,976 1,976 COMPZ RPCOM OTHR P Splice ESP cable and tie into feed thru lines on Packer. Meg ESP cable - good test. 16:00 19:30 3.50 1,976 4,798 COMPZ RPCOM PUTB P Continue to RIH picking up 3 1/2 TBG from 1,976 -ft to 4,798 -ft. Meg cable- good test. Pick up TBG Hanger on Landing jt with poor boy swivel attached. 19:30 23:00 3.50 4,798 4,798 COMPZ RPCOM OTHR P Install penetrators and make final splice. Meg cable, good. Filling IA off of trip tank, 34 bbls to fill, 2 bph average losses. 23:00 23:30 0.50 4,798 4,840 COMPZ RPCOM THGR P Land completion, Up wt 85k, Dn wt 65k, RILDS. Installed Clamp Count; 3 ea. Protectolizers 3 ea. 3500 -A -05P Connon clamps 4 ea. 5150- AF -12P Cannon Clamps 86 ea. 3500 -A05 Cannon Clamps 23:30 00:00 0.50 4,840 4,840 COMPZ RPCOM PRTS P Pressure test hanger upper and lower pack -offs to 5000 psi for 15 minutes while monitoring well for flow 30 minutes. well static at 24:00 04/30/2012 Set TWC. ND BOP. Check ESP cable. NU Tree. Test tree and voids. Check ESP cable. RU Slickline. Make Drift and Correlation runs. Set WRP and Catcher. Load IA with Gelled Diesel, TBG with Diesel. Set Dummy Valves in GLM's #1 and #2. Test Tubing. MIT -IA. RD Slickline. Bleed IA per Decompression schedule. 00:00 00:30 0.50 0 0 COMPZ WHDBO MPSP P Lay down landing joint. Pull side port isolation sleeve. Set Two Way Check Page 5 of7 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 01:45 1.25 0 0 COMPZ WHDBO NUND P PJSM- Nipple Down BOP w/ Weatherford Safety Tension Adapter. Make electrical integrity checks. 01:45 02:45 1.00 0 0 COMPZ WHDBO NUND P PJSM- Nipple up tree. 02:45 03:30 0.75 0 0 COMPZ WHDBO PRTS P Pressure test Tree pack -off / voids 5000 psi for 15 minutes. RU test equipment and pressure test Tree 250/5000 psi on chart. RD test equipment 03:30 04:00 0.50 0 0 COMPZ WHDBO MPSP P Pull Two Way Check. 04:00 04:30 0.50 0 0 COMPZ RPEQP1SLKL P Spot Slickline and LRS units 04:30 04:45 0.25 0 0 COMPZ RPEQPI SFTY P PJSM with Halliburton, Weatherford, LRS and N3 crews, discuss plan forward and hazards associated with Pumping and Slickline operations. 04:45 08:15 3.50 0 0 COMPZ RPEQP1 RURD P RU Slickline, bring in Slickline equipment. 08:15 09:00 0.75 0 0 COMPZ RPEQP1SLKL P PT lubricator at 500 psi. Good test. MU and RIH w/ 2.79" OD drift to 3,100 - ft. POOH. SI swab valve. 09:00 10:00 1.00 0 0 COMPZ RPEQP1SLKL P Change over to kick over tool, RIH to 2,968 -ft, locate pocket, mark wire. POOH. SI Swab valve. 10:00 12:30 2.50 0 0 COMPZ RPEQP1SLKL P Bring WFT Slick pump to rig floor and setup. MU 2.78" WRP RIH to 3,013 -ft, set Slick pump and stroke 35 times and set WRP w/ top at 3,007 -ft. POOH SI Swab valve. 12:30 13:30 1.00 0 0 COMPZ RPEQP1SLKL P PU catcher sub and RIH to 3,007 -ft, set catcher - POOH 13:30 15:00 1.50 0 0 COMPZ RPEQP1SLKL P Change over to kick over tool, RIH to 2,650 -ft while LRS bullheading 81 bbls gelled diesel and 12 bbls neat diesel down IA 2 bpm, ICP 300 psi, FPC 800 psi, Set DV in upper GLM at 2,744 -ft, POOH. 15:00 16:30 1.50 0 0 COMPZ RPEQP1SLKL P Change over to kick over tool, RIH while bullheading 30 bbls neat diesel down tubing 1 bpm, ICP 100 psi, FCP 375 psi, set DV in lower GLM at 2,981 -ft, POOH 16:30 21:00 4.50 0 0 COMPZ RPEQP1PRTS P Pressure test tubing to 3000 psi, not holding, Stand back Slickline equipment, tie in direct to top of tree, Pressure test tubing 3000 psi, IA holding 40 psi, good. bleed tubing to 1000 psi. 21:00 22:30 1.50 0 0 COMPZ RPEQPI PRTS P Switch over to IA, Pressure test IA to 1600 psi, steady loss, bump pressure back up to 1655 psi, 15 minutes 1625 psi, 30 minutes 1610 psi. 22:30 00:00 1.50 0 0 COMPZ RPEQP1OTHR P Bleed IA per decompression schedule. RD Slicklie and LRS. Page 6 of 7 t • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/01/2012 24 hr Summary Continue to Bleed IA per Decompression schedule. Set BPV. Make Final Cable checks. Secure cellar. RDMO. Nordic Riq 3 released at 05:00 hrs on May 1, 2012 00:00 02:00 2.00 0 0 COMPZ RPEQP1 OTHR P Bleed IA per decompression schedule. During bleed down split DP in derrick and tie off. Install new E -line top entry Gooseneck on TD. Start rig warm up for move. 02:00 02:30 0.50 0 0 COMPZ RPEQP1 OWFF P Bleed tubing to 0 psi, monitor tubing and casing for 30 minutes. No flow observed. 02:30 03:00 0.50 0 0 COMPZ RPEQPI OTHR P Make final cable / motor electrical checks, Good. 03:00 04:00 1.00 0 0 COMPZ RPEQP1OTHR P Continue rig warm up. Finish install of new E -line top entry Gooseneck on TD. RD test equipment. Load BPV lubricator to floor. 04:00 04:30 0.50 0 0 COMPZ RPEQPI MPSP P Set BPV. 04:30 05:00 0.50 0 0 COMPZ MOVE MOB P Secure cellar, dress tree. Back off 1D-129 Nordic Rig 3, clean tree and cellar. Release Rig at 05:00 hrs on 5 -1 -12 Page 7 of 7 • • ~~~L ~~~~~~~ I~. PROACTIVE DIAyNOSi1C SERVICES INC. To: AOGCC Christine AAa 5~~~'zer 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907] 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTTj 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 , , r~ :; ZJ1Sj Suite C ~~'+~'~~ ~i~ `'~ ~~ Anchorage, AK 99518 Fax: (907j 245-8952 1) MTT Report 25-Jun-10 1 D-129 1 Report 50-029-22830-00 2J MTT Report 25-Jan-10 1 D-133 1 Report 50-029-22827-00 /~~ -a~~ ~ ga-aa~ Signed ; Dat rage Print Name; PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : pdsancharage@memarvloa.com WEBSITE : wtir/w.memoryloa.t:om C:\Documents and Settings\Diane Williams\Desktop\Trans¢ut_Conoco.docx r~ u Memory Magnetic Thickness Tool Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1D-129 Log Date: June 25, 2010 Field: West Sak Log No.: 7416 State: Alaska Run No.: 1 API No.: 50-029-22830-00 Pipet Desc.: 3.5° 9.3 Ib L-80 EUE 8RD Top Log Intvl.: Surface Pipet Use: Tubing Bot. Log Intvl.: 222 Ft. (MD) Pipet Desc.: 7.625° 29.7 Ib L-80 BTC-MOD Top Log Intvl.: Surface Pipet Use: Surface Casing Bot. Log Intvl.: 222 Ft. (MD) Pipe3 Desc.: 16" 62.58 Ib. H-40 Welded Top Log Intvl.: Surface 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 with the 12 Arm Magnetic Thickness Tool (MTT). The MTT responds to the total metal thickness of the 3.5" tubing, 7.625" surface 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 222'. Changes in metal volume are relative to the calibration points at 63' and 150', 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 an area of up to 6% relative metal loss over the interval (68' - 72') in the 10Hz pass. Over the same interval, the SHz pass indicates up to 5% relative metal loss and the 5Hz pass indicates up to 3% relative metal loss. A log plot of the entire 5Hz pass and an expanded log plot of top 30' of the 5Hz pass are included in this report. Indications of general isolated metal loss are recorded throughout the interval logged in the 5Hz pass. A maximum ~6% circumferential metal loss is indicated in the interval between 68' and 72' in the 10Hz pass, and a maximum ^'3% circumferential metal loss is indicated in the same interval in 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" surface casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 3.5~ tubing or 16° conductor. ~- ' (Field Engineer: Wm. McCrossan Analyst: HY. Yang & J. Burton Witness: J. Condio ~ ~~'roAcf~ive ?;agnostic Service, I~~c. ~ P~.~; Eiox 1.369, StUfford, TX 7749 Phone: (281; or (888? 565-9085 Fax: (281) 565-1369 E-mail: PC~SC~memorylag.com Prudhoe Bay Field Office Phone. X90;) 659-2307 Fax; 0907 659-231.4 19~ -ar3 1 ' o`~MwEusp~~ 5Hz, and 10Hz Delta Metal Thi ess Passes Overlay Qa ~9G 1 D-129 June 25, 2010 Pw°Ac rivF ~inyn°sric SERVICES Database File: d:\warrior\data\1d-1291overlay.db Dataset Pathname: overlay Presentation Format: overlay Dataset Creation: Tue Jun 29 16:53:48 2010 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness 2010 (10Hz) (%) 50 -50 Delta Metal Thickness 2010 (8Hz} (%} 50 -50 Delta Metal Thickness 2010 {5Hz) {%) 50 0 Delta Metal 20 ~ ~10HZ Delta Metal 60 Bottom of 16" 80 Delta Metal Thickness 100 120 OHz Delta Metal Thickness Delta Metal Thickness 140 160 180 200 220 Delta Metal Thickn -50 Delta Metal Thickness 2010 (10Hz) (%} 50 -50 Delta Metal Thickness 2010 {8Hz) {%) 50 -50 Delta Metal Thickness 2010 (5Hz) {%) 50 o`~"'WE~`sA~ R rded Magnetic Thickness L Data - 5Hz Pass a°' `~' c ~ "' 1 D-129 June 25, 2010 PR°A[T1YE ~IM1{',IE°S11C SERyI[ES ' Database File: d:\warrior\data\1d-129\5hzpass.db Dataset Pathname: SHzPass Presentation Format : 18 ' Dataset Creation: Tue Jun 29 17:24:53 2010 Charted by: Depth in Feet scaled 1:150 ' -50 Delta Metal Thickness (°!°) 50 1.8 0 Line Speed (fUmin) -200 -7 ' ~r~ 3.5" Collar ' .5" Colla Pups ' .5" Colla Line S pee 20 ' Delta Meta l Thickness Tubing Jt. 1 7.6 25" Collar 40 ' .5" Collar Tubing Jt. 2 ' 60 3% Metal Loss ' 3 5 " C llar - . o _ " - - Bottom of 16 Conductor - 80 ' 7.625" Co llar Tubing Jt. 3 100 ~. MTTP01 (rad) 11.8 MTTP12 (rad) 3 " ' 3.5 Col la ~ , 120 ' I Tubing Jt. 4 7. 625" Collar 3 5" C ll ' . o ar 140 ~, _ UP ConocoPhillips ~ att-~bl,teg - -_- 11,1,.5„ o APIIUWIField Name - 500292283000 I WEST SAK . ...~ .~ Comment - - ~ -- --H2S lPl ... - _.._.__-__.__._..____.. ,SSSV: NONE 5 HANGER, ESP MANDREL,... -.--.__ 3,646 ESP MANDREL, 4,721 16 15.063 '~, 41.0 in9 0... SMn91D ._ Top ((tK8' 7 5I8 6.750 39 0 ing O.. String ID ... Top (kK8 31/2 2.992 37.0 Top Inel (") Run Date RKB TESTED TO 11 PSI (GOOD TEST) SLIP STOP, 4,7]2 PACKOFF. 4,773 PUMP, 4,781 GAUGE, 4,800 NIPPLE, 4,615 - SEP,L, 4,820 MOTOR, 4,8.'S PACKER, 4,891 MILLOUT, 4,895 SLEEVE, 4,900 SBE, 4,903 JOINT, 4,92f1 Blank Pipe, IPERF, 5.0165.038 IPERF, 5,070.5,090 APERF, 5,1165,133 REEN. 4 984 APERF 5.1565.166 APERF, 5,1835,193 IPERF, 5.2525 282 Top (ND) Btm (ND) Dens (ftK8) ~ (RKB) Zone Date (sh.° Type Comment 1 D-129 58.37 2,146.26 5,462.0 Date KB6rd (R) Rig Release Date _71/13_/20_03 41_.00 11/29/1997 - Last Mod ... End Date Imosbor _~ 112 512 01 0 epth (ND) ... String WL.. ~ String ... I Skiing Top Thrd 121.0 ~'~ 62.58 I H-40 11 Welded eplh (TVD)._~IiShing WC.. '~, String ... String Top Thrd 1.023.9 I 29.70 ! L-80 BTC-MOD BULL PLUG, 5,290 SURFACE, 3.45,453 '~ TD, 5,462 n ~,....J ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Comnanv TUBING DETAIL 3.5"ESP Completion 1 D 129 DATE: 2/6/2000 A AC A Aw/~rn # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH r.v DEPTH TOPS Nordic RKB to LDS 26.30 26.30 Han er Vetco Gra Tubin Han er w/ 3.62' u 3.94 26.30 3.5" 9.3# L-80 EUE 8rd u .36 30.96 3.5" 9.3# L-80 EUE 8rd Mod Pu Jt. 2.27 30.60 3.5" 9.3# L-80 EUE 8rd Mod Pu Jt. 10.07 32.87 3.5" 9.3# L-80 EUE 8rd Mod Pu Jt. 10.09 42.94 3-152 Jts. 3.5" 9.3# L-80 EUE 8rd Mod 4659.20 53.03 GLM Camco KBMM GLM 3.5" x 1" w/ u s 6.09 & 5.59 No GLV 18.50 4712.23 1-2 Jts. 3.5" 9.3# L-80 EUE 8rd Mod 61.88 4730.73 3.5" 9.3# L-80 EUE 8rd Mod Pup Jt. 10.05 4792.61 3.5" 9.3# L-80 EUE 8rd Mod Pu Jt. 10.20 4802.66 Slotted ni le 2.992" ID 3.11 4812.86 3.5" Tubin TTC Crossover 2.992" ID 1.42 4815.97 Centrilift Seal Section GSB3 DB IL H6 PFS 13.80 4817.39 Centrilift Gear Reduction Unit 9:1 525 Series 1.32 4831.19 Centrilift Motor 50 HP 1170/27 KMH 6.78 4832.51 Centrilift Motor Centralizer .42 4839.29 Bottom Of Centrilift E u ment 4839.71 Ra chem 351 6' Flat Guards 28 4' Flat Guards 12 3' Flat Guards 1141 Bands Centrilift 160 Bands 45 LaSalle Clam s 3 Flat Guards 6' 1 Flat Guards 4' Rema-1~s: String Weights with Blocks: 62K# Up, 46K# Dn 6K# Blocks Ran 152 joi nts of tubing n~~~aa .uu~ny, v~~wa, « IId11l~C1 Wllfl L.80/ piasnc raonit. uses Arctic Grade API Modified No Lead thread compound on all connections. Tubing is non-coated Nordic Rig #3 Drilling Supervisor. M.C. Heim . . ~ ConocoPhillips Alaska RECEIVED .JUL 1 0 Z007 P.O. BOX 100360 ANCHORAGE, AlASKA 99510-0360 .!\Iaska Oil & Gas Cons. Commission Anchorage July 6, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK. 99501 ~CANNfD JUL 11 2007 \q1,ð-\3 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please M.J. Loveland at 907-659-7043, if you have any questions. ;;~ M.~ ConocoPhillips Well Integrity Project Supervisor . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft Qal 1 0-09 198-065 23" na 5 6/9/2007 10-101 200-183 2" na 3.2 6/9/2007 10-102 200-075 2" na 3.2 6/912007 10-103 202-096 5" na 8 6/912007 1O-105a 201-202 25" na 38 619/2007 10-106 197-240 2" na 3.2 6/912007 10-107 200-177 2" na 3.2 6/912007 10-108 198-187 8" na 12.8 6/912007 10-113 198-178 2" na 1 6/912007 10-114 198-159 2" na 1 6/9/2007 10-115 197-232 2" na 1 6/912007 10-116 198-172 2" na 1 6/912007 10-117 197-237 2" na 1 6/912007 10-118 197-229 2" na 1 6/912007 10-119 197-222 2" na 1 6/9/2007 10-122 198-149 2" na 1 6/9/2007 10-123 198-170 2" na 1 6/9/2007 1O-125a 200-044 2" na 1 6/9/2007 10-126 198-108 2" na 1 6/9/2007 10-127 198-109 8" na 2.5 61912007 10-128 198-133 2" na 1 6/9/2007 10-129 197-213 2" na 1 6/912007 10-130 197-183 23" na 5 6/9/2007 Kuparuk Field June 9,2007 . , Mike Mooney ( ,~' Wells Group Team Leader Drilling & Wells P. O. Box 100360 Y Anchorage, AK 99510-0360 ConocoPhiiii pS Phone: 907-2634574 December 10, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 10-129 (APD # 197-213/303-194) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operations on the Kuparuk well 1 0-129. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, #-d~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad RECEIVED DEC 1 6 2003 II 0., & Gas Cons commission A\as,,8 , . Anch(jfage StANNErJ JA~ 2 «I 2004 0 RIG I N A L ( ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Suspend 0 Operation Shutdown 0 Perforate 0 Variance 0 Annular Disp. 0 Alter Casing 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Other 0 Change Approved Program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 197-213/303-194 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, AnchoraQe, Alaska 99510 50-029-22830-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 41', Pad 70' 1 D-129 8. Property Designation: 10. Field/Pool(s): ADL 25660, ALK 468 Kuparuk River Field 1 West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 5462' feet true vertical 4033' feet Plugs (measured) 52901 Effective Depth measured 5300' feet Junk (measured) true vertical 3871' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 1211 121' SUR. CASING 5412' 7-5/8" 5453' 4024' Perforation depth: Measured depth: 5010'-5038',5070'-5090',5116'-5133', 5156'-5166', 5183'-5193', 5252'-5282' true vertical depth: 3581'-3609',3641'-3661',3687'-3704', 3727'-3737', 3754'-3764', 3823'-385RE CE IVE D Tubing (size, grade, and measured depth) 3-1/2" , L-80, 4815' MD. DEC 1 6 2003 Packers & SSSV (type & measured depth) packerless ESP completion 0., & Gas Cons. Commission no sssv Alaska I . I ,- 12. Stimulation or cement squeeze summary: ",III"IIUI QH'" Intervals treated (measured) N/ A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casina Pressure Tubina Pressure Prior to well operation 334 594 61 - 226 Subsequent to operation 298 43 138 - 215 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run - Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: Oil 0 GasD WAG 0 GINJD WINJ 0 WDSPLD --;:: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry ~mber~..N/A if.::.O. EJ<e~t: J I .~. _-.f() "5 I (,1 ~ Contact Guy Schwartz @ 265-6958 ' I I Printed Name Mike Mooney Title Wells Group Team Leader Signature .A d ,A P~~e.¡;,\rkJ1IMrëG'\ Jíi\~~ eï) Ifì\ (')fHH Date rZ);tø/65 }If?;!¡;- }JI~ \ì~"~ßIt'\\tl~ j'tIl:JLi . ¡'U'1!J ((.y \L\I LlJ! u4 PreDared bv Sharon AI/suo-Drake 263-4612 V J FOrm10-404_1R . 2.. . .' ' ^ L SUBMIT IN DUPLICATE V.\~ I l-\ ( I~I ConocoPhillips Alaska, Inc. KRU 1D-129 1D.129 500292283000 PROD NONE 11/29/1997 11/13/2003 41' RKB TUBING Thread (0-4815, Welded 00:3.500, - BTC-MOD 10:2.992) Thread EUE 8rd Zone Status Ft SPF Date Comment WSD 28 4 12/6/1997 0 de h/low side' 2 1/8"EJ WSB 20 4 12/4/1997 0 de h/low side' 2 1/8"EJ WSA4 17 12 9/15/1999 HSD-BH 4 1/2" WS 10 12 9/15/1999 HSD-BH 4 1/2" A4 WS A3 WSA3 10 12 9/15/1999 APERF HSD-BH 4 1/2" SEAL WSA2 30 4 11/30/1997 IPERF 0 de h/low side' BH EJ (4820-4834, Man Type V Mfr V Type VOD Latch Port TRO Date Vlv 00:5.130) Run Cmnt CAMCO DMY 1.0 BK 0.000 0 3/18/2003 CAMCO DMY 1.0 BK 0.000 0 11/13/2003 ID 3.958 4780' WLM 0.000 4.500 2.992 0.000 0.000 0.000 0.000 Descri tion ID Baker SC1 4.000 Baker 4.892 Baker Slidin Sleeve 4.892 Baker 4.400 Baker 4.000 Baker 4.000 Baker 0.20 Gau e 4.000 Baker 4.000 ( ( ConocoPhillips Alaska Päge1 of2 Operations Summary Report Legal Well Name: 10-129 Common Well Name: 10-129 Spud Date: 11/22/1997 Event Name: WORKOVER/RECOMP Start: 11/9/2003 End: 11/13/2003 Contractor Name: Rig Release: 11/13/2003 Group: Rig Name: Nabors 3S Rig Number: From- To Hours. Code ~~dbe Phase Description of Operations 11/9/2003 00:00 -10:00 10.00 MOVE MOVE MOVE Scope down derrick and lay down. Blow down steam lines etc. Move rig from 1 D-1 02 to 1 D-129 10:00 - 10:30 0.50 MOVE RURD MOVE Lay mats and Herculite under the sub, spot BOP behind well. 10:30 - 14:00 3.50 MOVE RURD MOVE Spot and level sub over well. Spot pipe shed in place laying over steps and installing handrails. Spot Pits, lay matts and jack down. R/U steam lines, water lines, mud lines and choke lines. 14:00 - 15:00 1.00 MOVE RURD MOVE Raise derrick & scope up mast, install ESP sheave. Hook up electric lines. R/U load lines and flow line. 15:00 - 00:00 9.00 WELLS NUND RIGUP Check pressure on annulus - 0 tbg - 0 (small vac.). Accepted rig @ 1500 hrs (11/09/03). N/U BOP stack. NU is taking extra time because stack had to be broken into 3 pieces. BOP cradle will not fit behind West Sak wells. AOGCC (John Crisp) waived the BOP test witness @ 6:20 pm (11/9/03).. Pulled tree above BPV. Installed test dart in hanger profile above BPV. NU stack. Discovered well building pressure in annulus. Prep to rekill well after stack completed. Loaded and heated up brine in pits to 140 degrees in prep for circulation. MU stack in prep for blind and choke manifold test. 00:00 - WELLS RIGUP 11/10/2003 00:00 - 03:00 3.00 WELCT BOPE WRKOVR Continue to NU BOP stack. Test blind rams and HCR's to 3500 psi in prep to pull test dart and circulate another well kill. Ran lines to open top tank and back to MI tanks. Finished heating fluid in pits to 140 degrees. Annulus pressure @ 65 psi and slowly climbing. 03:00 - 07:00 4.00 WELCT CIRC WRKOVR Pulled test dart - finished weighing up brine to 10.2#. Rigged up lines to circulate well. Started circulating well kill w/ heated 10.2# brine through BPV and tubing @ 2 bpm max taking returns to an open top tank. Losing fluids (62% returns). Switched back to pits to attempt to reduce backpressure during circulation. Returns 10.2 ppg. Shut in to monitor well. 07:00 - 08:30 1.50 WELCT OBSV WRKOVR Test safty valves while monitoring well. SI press = tubing on vac. IA 28 psi. Bled off IA to O. Shut in. after 5 min. 5 psi. Bled off. Press on both sides O. 08:30 - 10:00 1.50 WELCT BOPE WRKOVR Pull BPV. RIH with landing jt. Installed floor safety valve. Close rams and test BOPE (pipe rams, annular) 250 and 3500 psi, annular to 3000 psi. 10:00 - 11 :00 1.00 WELLS PULD WRKOVR B.O.L.D.S, Pull tubing hanger to rig floor, remove penetrators. 65K to move hanger. Up wt. 54K Dwn wt 36K 11 :00 - 11 :30 0.50 WELCT WRKOVR Monitor well, losing 20 BPH. R/U hose to sheave to catch and contain oil from cables. Cut Brine wt. back to 10.1 ppg. 11 :30 - 18:00 6.50 WELLS PULD WRKOVR POOH with 3.5" tubing standing back and strapping, spooling up ESP cable, heat trace, and removing bands and channels. Wiping oil with absorb. Tubing and cables were not as clean as last well after pumping hot brine. Fluid losses 11-12 BPH. Cut Brine wt. back to 10.0ppg. Continue to POOH. 18:00 - 00:00 6.00 WELLS PULD WRKOVR ESP equipment on surface at midnight. Lay down individual pieces and prep for Baker Retrievamatic run to pressure test casing. Transferring fluids from MI and weighting up to 10.0#. Motor megger and hi-pot looked good. Coupling appeared to be locked up. No seals appeared to be compromised. 11/11/2003 00:00 - 07:00 7.00 WELLS TRIP WRKOVR Rig down Centrilift equipment and PU Baker Retrievamatic packer in prep to RIH to test casing. RIH with Baker packer to test casing. 07:00 - 08:00 1.00 WELLS DEQT WRKOVR Picked up two jts to get packer to 7841'. Set packer, press up to 2500 psi on Chart Recorder. Held for 30 min. Bled pressure off. 08:00 - 09:30 1.50 WELLS CIRC WRKOVR Released Baker Retrievamatic Packer. Circulate bottoms up with 10.1 Printed: 12/8/2003 11: 11: 18 AM ( ( ConocoPhillips Alaska Page 2 of 2 Operations Summary Report Legal Well Name: 1 0-129 Common Well Name: 10-129 Spud Date: 11/22/1997 Event Name: WORKOVER/RECOMP Start: 11/9/2003 End: 11/13/2003 Contractor Name: Rig Release: 11/13/2003 Group: Rig Name: Nabors 3S Rig Number: Date ..,. From-To Hours Code... ¿'~dbe Phase Description of Operations .... ... . .. ... .... . ..'... . 11/11/2003 08:00 - 09:30 1.50 WELLSR CIRC WRKOVR ppg Brine. Getting 10.2 ppg brine back. Fluid losses 14 bbls during circulation. 09:30 - 16:00 6.50 WELLSR TRIP WRKOVR Drop 2.867" rabbit. POOH with tubing. Rabbit stopped in pin end of joint on stand #2, #3, & #11. Stopped in box end of stand #17 and #21. Lay down bad joints and replace with new joints in string. POOH to packer. Found rabbit in x-over above packer. 16:00 - 16:30 0.50 WELLSF PULD WRKOVR LD Baker packer. Remove packer from floor. 16:30 - 18:30 2.00 CMPL TN RURD WRKOVR PU Raychem heat trace spool and set on rig floor. Pull Motor lead extension and cable through elephant trunk and thread through sheave. Pull cable to rig floor. RU air hose connections for Centrilift. Strap GLM's and rabbit to 2.85". 18:30 - 18:45 0.25 CMPL TN SFTY WRKOVR Pre-job safety meeting for picking up Centrilift equipment and running in hole. Losses to well down to 6 bph... brine weight at 10 ppg. 18:45 - 20:20 1.58 CMPL TN PULD WRKOVR PU Centrilift Motor. Flush motor/seal assembly with PC-92 oil. 20:20 - 21 :00 0.67 CMPL TN PULD WRKOVR Attach MLE to motor. PU second pup and begin rigging up Baker Guardian guage. 21 :00 - 23:30 2.50 CMPL TN PULD WRKOVR Attach Baker Guardian Gauge. Sensor is 3' from bottom of first pup jt. above intake ports. 23:30 - 00:00 0.50 CMPL TN RUNT WRKOVR Continue to RIH with ESP completion. 11/12/2003 00:00 - 03:00 3.00 CMPL TN RUNT WRKOVR RIH with ESP completion. Used Cannon single channel cross couple clamps on every other collar. 03:00 - 14:00 11.00 CMPL TN RUNT WRKOVR RU Heat Trace (Raychem), Heat Trace sheave, bring extra Cannon Clamps to rig floor. RIH clamping Heat Trace and power cable to tubing. Started Heat Trace 22.5' from bottom of stand number 28. Use Cannon dual channel clamps on pipe body. No clamps across collars. 14:00 - 18:30 4.50 CMPL TN SOHO WRKOVR RIH with stand #76. Mark distance to end of heat trace cable on top joint. LD top joint. PU 1-8' and 2-2' pup joints. PU landing joint. MU hanger with 1-3.5', 1-0.5', and 1-2' pup attached. RIH to hanger. Space out too long. Remove 2-2' pups (4.6' total). Add 1-4' pup to string. Load heat trace penetrator in wellhead. MU heat trace connector. Perform electrical checks. OK. Load power cable penetrator in wellhead. Cut cable and splice on connector plug. MU cable plug to penetrator. Perform electrical checks. OK. Load Baker Tech wire penetrator in wellhead. Splice plug on to Tech wire. MU Tech wire plug to penetrator. Good temp and pressure readings on Tech wire. Clamp cables to tubing below hanger. RIH with hanger and land in wellhead. Up weight 52K. Down weight 32K. RILDS. 18:30 - 00:00 5.50 CMPL TN NUND WRKOVR Nip dwn BOP's and install ABB 5K tree. PT all wellhead equip with chart recorder. Re-test Baker, and Raychem's penitraters after tree set, passed. Rig down BOP's and stack back in prep. for brine recovery. 11/13/2003 00:00 - 05:00 5.00 CMPL TN NUND WRKOVR Continue to separate BOP's. Rig up for brine swap with freeze protect. Wash pits. 05:00 - 09:00 4.00 CMPL TN FRZP WRKOVR Continue to freeze protect well recovering brine. 140 BBLS diesel pumped down IA for freeze protect. Put IA and tubing in communication to u-tube diesel. Rig crew prepping rig for move to 1C-170. 09:00 - 10:00 1.00 WELLSF PLGM WRKOVR RU APC lubricator to run BPV. Set BPV in hanger. RD APC. Released rig at 1000. Printed: 12/8/2003 11: 11: 18 AM Re: West Sak Workovers Subject: Re: West Sak Workovers Date: Tue, 04 Nov 2003 07:11:50 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Schwartz, Guy L" <Guy. L.Schwartz@conocophillips.com> CC: "Mooney, M" <M.Mooney@conocophillips.com>, "Worthington, Aras J" <Aras.J.Worthington@conocophillips.com> Guy, et al: ~ ~ ~(~)t~).-\ '~ ~ Thanks for bringing over the USIT log on 1 D-140. I concur with your assessment of the log. It did not appear that there was any wall loss and a pattern suggestive of the original mill marks was evident. You also provided the report sheets for the boroscope inspections and the Schlumberger engineer's assessment of the log. You emailed me the log for 1D-110A. I agree with ConocoPhillips' proposal to eliminate the casing inspection logs in 1D-102 and 1 D-129, subject to the assessment of the condition of the tubing and any other factors that would lead one to believe that conditions in one of these wellbores is different than the initial wells surveyed. Based on choosing what you believed were the worst case wells based on annular production time and the flow rates should have given ConocoPhillips the most conservative inspection. I will place a copy of this message in the respective well files. Please call me with any questions. Tom Maunder, PE AOGCC ~"~ - \[~ ~ ~ "Schwartz, Guy L" wrote: \~) - ~ ~ ~ ~ > Tom, > As per our conversation today regarding the ongoing West Sak ESP workovers I wanted formally state the results and discuss further diagnostic procedures. > The wells we have completed are first 1D-140 and 1D-110A. These two wells were chosen to be the first in our set of four workovers due to the longer duration of annular flow with these > wells. It was felt that if the casing and wellhead diagnostics looked favorable that further work on the following two wells ('1D-102 and 1D-129) could be re-addressed and possibly reduced in scope. > > Results to date: > 1D-'140: Borescope of the wellhead showed no wear or erosion. Inside of the wellhead and VR threads looked to be in "like new" condition. > The 7 5/8" casing was pressure tested to 2500 psi and held solid. > A USIT corrosion log was run over the entire 7 5/8" casing and showed that it was in very good condition. Milling marks were still very visible on the inside of the tubing and virtually no wall loss was seen. > 1D-110A The borescope of the wellhead also showed the wellhead and 2" valve and VR to be in like new condition. > The 7 5/8" casing tested to 2500 psi. > USIT corrosion log showed the 7 5/8" casing to be in great shape. > As a prudent operator we are proposing we continue to pressure test the 7 5/8" casing on the remaining workover wells but discontinue the borescope and USIT log. If conditions warrant change such as corroded tubing being pulled out the remaining two wells we would of course re-look at running the USIT log. > > Thanks foryour consideration, > Guy Schwartz > > Drilling and Wells Engineer > office: 907-265-6958 > AT0-1548 I of 2 11/4/2003 7:12 AM tJuarLurly lluwline mspecuon reports Subject: Quarterly flowline inspection reports Date: Mon, 6 Oct 2003 13:02:53 -0800 From: "NSK Problem Well Supv" <n1617@conocophillips.com> To: tom_maunder@admin.state.ak.us, bob_fleckenstein@admin.state.ak.us CC: "rtl 617" <n1617@conocophillips.com> Tom, Here is a copy of the quarterly flowline inspection reports required to fulfill the Sundry requirements for the following wells. 1 D-102: PTD 2000750, Sundry #302-101 1D-105A: PTD 2012020, Sundry #302-294 1 Do110A: PTD 2000390, Sundry #302-227 1 D-121: PTD 1971810, Sundry #302-304 1 D-127: PTD 1981090, Sundry #353-057 1 D-129: PTD 1972.130, Sundry #303-092 1Do140: PTD 2001360, Sundry #302-376 3H-05: PTD 1870770, Sundry #302-102 Please let me know if you have any questions. Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 (See attached file: 3H-05 Quarterly Inspection Log.xls)(See attached file: 1 D-102 Insp Log.xls)(See attached file: 1 D-105 Inspection Log.xls)(See attached file: 1D-110 Insp Log.xls)(See attached file: 1D-121 Inspection Log.xls)(See attached file: 1D-127 Inspection Log.xls)(See attached file: 1D-129 Inspection Log.xls)(See attached file: 1 D-140 Inspection Log.xls) Name: 3H-05 Quarterly Inspection Log.xls Type: EXCEL File (application/msexcel) Encoding: base64 Type: EXCEL File (application/msexcel) I Encoding: base64 ,/ B1 Inspection Log.xls D-1 05 Name: 1D-105 Inspection Log.xls ~t Type: EXCEL File (application/msexcel)iI=. Encoding: base64 !~1D-110 Insp Log xls,_, lEncoding; base64Type' EXCEL File (application/msexcel) ~: 1 D-t21 Inspection Lo.q.. xls~ Type-. EXCEL File (application/msexcel)~,I I !Enc°ding: base64 t i B 1 D-127 Inspection Lo.q.xls Name: 1D-127 Inspection Log.xls Type: EXCEL File (application/msexcel)! Encoding- base64 1 of 2 10/6/2003 3:17 PM L4uarterly llowline inspection reports I Name: 1D-129 Inspection Log.xls 't 1 D-129 Inspection Loq.xlsI Type: EXCEL File (application/msexcel)l I Encoding: base64 ' Name: 1D-140 Inspection Log.xls 't 1 D-140 Inspection Loq.xls. I Type: EXCEL File (application/msexcel)t I Encoding: base64 I 2 of 2 10/6/2003 3:17 PM 1D-129 Special Inspection Request Log DS1D 1D-129 - Flowback inspection - Weekly inspections for 1 month - Monthly inspections for 2 months then quarterly inspections until further notice B, I, N - (B - baseline inspection, I - Increase in % wall loss, N - No change from previous inspection) # of Worst Date of Inspection B, I, N Case Wall Damage Comments Inspection Locations Loss % Grade 04/13/03 6 B 0% A Base Line Frac Inspection 04/22/03 6 N 0% A 1-Week follow-up Inspection 05/13/03 6 N .~ 0°o_0~ ~ A 3-Week follow-up Inspection 06/17/03 6,, ~ 0% , ;¢ A Operations Request 09/17/03 6 // N 0°/2..-'''' A Quarterly Inspection Interval 12/17/03L ~ '" ' ~ ,~[ ,f'V".. Quarterly Inspection Interval ~ ,, ,,, ConoCOPhillips Guy Schwartz Senior Wells Engineer Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6958 July 17, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval, West Sak 1D-129 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the West Sak well 1 D-129. 1 D-129 was drilled as part of theWSAK phase lA drilling program. The well was completed with the Frae for sand control resin coated proppant. The resin coating failed to hold the proppant in place and the proppant flowback damaged the PCP equipment. The well was worked over in the 3rd qtr of 1999 to install a gravel pack assembly and replace the broken PCP equipment. The well experienced an electrical failure within 7 days of the startup after the workover to install the gravel pack screens. A second workover to changeout the TTC-PCP was completed in February of 2000. The well started to experience pump problems again in early 2003. After several pump changeouts and other diagnostics, it was determined that the motor is locked up. The well was brought-on-line with gas lift in April of 2003. This workover will pull the broken TTC-PCP completion and run a new TTC-PCP completion in the well. The procedure for this workover also includes a casing pressure test and a USIT log to evaluate casing integrity after 6 months of annulus production. The data from this and the other 3 West Sak workovers is critical in determining how West Sak workovers and motor failures are handled in the future. If the casing fails to pressure test or if the USlT indicates serious casing damage, then the workover will be suspended. If you have any questions or require any further information, please contact me at 265-6958. G. Schwartz Senior Wells Engineer CPAI Drilling and Wells GLS/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon Alter casing Change approved program Suspend [~ Operation Shutdown ~] Repair well [~] Plug Perforations [] Pull Tubing [~ Perforate New Pool ["-[ Perforate D Variance [~ Stimulate E~ Time Extension r-~ Re-enter Suspended Well [~ Annular Disp. Other 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 41' Pad 70' 8. Property Designation: ADL 25660, ALK 468 4. Current Well Class: Development [~ Exploratory Stratigraphic [] Service 5. Permit to Drill Nu,~ber: . / 197-213 v' 6. APl Number: 50-029-22830-00 V'~ 9. Well Name and Number: 1D-129 10. Field/Pool(s): Kuparuk River Field / West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): 5462' Casing CONDUCTOR SUR. CASING Perforation Depth MD (ft): Total Depth TVD (ft): 4033' Length 121' 5412' Effective Depth MD (ft): 5433' Size 16" 7-5/8" Effective Depth TVD (fi): 4004' MD 121' 5453' Perforation Depth TVD (ft): 5010'-5038',5070'-5090', 5116'-5133', 5156'~5166', 5183'-5193', 5252'-5282' Plugs (measured): 5290' TVD 121' 4024' Tubing Size: 3-1/2" Junk (measured): Burst Collapse Tubing Grade: Tubing MD (ft): L-80 4816' Packers and SSSV Type: pkr= BAKER SC1 no SSSV 12. Attachments: Description Summary of Proposal ['~ Detailed Operations Program ~ BOP Sketch 14. Estimated Date for Commencing Operations: August 11, 2003 16. Verbal Approval: Date: Packers and SSSV MD (ft) pkr= 4891' no SSSV 13. Well Class after proposed work: Exploratory [] Development [] 15. Well Status after proposed work: oil [] Sas I--I WAS I--1 G NJ I--I Plugged [~] WINJ [--] Service Abandoned BI WDSPL ~-1 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Guy Schwa~ . Signature ~~ Commission Use Only Contact: Title: Phone Guy Schwartz @ 265-6958 Senior Wells Engineer Date 7- / ~'- ~,.~ SundryNumb · __~~lq~ Conditions of approval: Notify Commission so that a representative may witness Plug Integrity E~ BOP Test,~ Mechanical Integrity Test [~] Subsequent Form Required: ~~ Form 10-403 Revised 2/2003 · ORIGINAL Location Clearance [-"] BY ORDER OF THE COMMISSION SUBMIT IN DUPLICATE PRE-RIG WORK: West Sak 1D-129 GENERAL WORKOVER PROCEDURE 5-7 days before RWO, RU Slick Line Unit. RIH and pull OV fi.om GLM @ 4711' leaving an open pocket. Pull Packoff and KOBE Knockout. 2. Kill well by pumping down tubing, taking returns up the annulus. 10.7 ppg KWF is expected. 3. Set BPV in tubing. Prepare Location for Nabors 3S: Remove well house(s), check tubing hanger LDS's, test tubing and casing packoffs. GENERAL WORKOVER PROCEDURE: 1. MIRU Nabors 3S. Lay hard-line to tree. 2. Verify if well is dead. If not circulate well with appropriate KWF based on surface pressure. Install BPV. 3. ND tree/NU BOPE. Function test BOPE. Pull BPV. Install test plug. 4. Test BOPE to 5000 psi. Pull test plug. 5. Screw in landing joint ( 4.909 MCA thread connection ). POOH standing back 3-1/2" tubing and spooling up ESP Cable and Heat Trace (BOT gauge wire is embedded in the power cable). o · RIH with retrievable bridge plug on 3 ¥2" tubing. Set at 4840 ft and release from plug. Test casing to 2500 psi for 30 min. POOH standing back 3 ¥2 tubing. 7. Inspect wellhead and annular valve for erosion. 8. RIH w/RBP latch and casing scraper assembly. 9. Cleanout (reserving out) to 4840', relatch packer and release. POOH with plug. 10. PU and RIH w/Eline USIT casing inspection log and log entire 7 5/8" casing from 4840' to surface. 11. RIH w/3-1/2" tubing and TTC ESP Assembly. Space out heat trace and splice power cable. 12. Land tubing hanger. RILDS, install two-way check and test tubing hanger. 13. ND BOPE/NU Tree/Test. 14. Freeze protect with diesel to +/- 2000' TVD. Set BPV. RDMO workover rig. Lower Limit: 4.0 days Expected Case: 5.0 days Upper Limit: 7.0 days No problems encountered. Problems pulling ESP completion, Space out problems and control line issues. GLS 6/30/03 ConocoPhillips Alaska, Inc. (4776-4781, 0D:3.500) SEAL (4817-4831, 0D:3,500) (4831-4833, OD:3.500) MOTOR (4833.4839, OD:3.500) (4891-4895, OD:6.800) (4895-4900, 0D:5,500) SLEEVE (49004903, 0D:5,800) SEAL BORE (4903-4920, OD:5.500) BINK PIPE (4923-4984, 0D:4,550) KRU 1D-129 1D-129 APl: 500292283000 SSSV Type: NONE Annular Fluid: Reference LastTa ALL STRINGS SUR. CASING CONDUCTOR TUBING Size 3,500 0 PeHorations Summary Interval TVD 5010-5038 3581-3609 5070-5090 3641-3661 5116-5133 3687-3704 5156-5166 3727-3737 5183-5193 3754-3764 5252-5282 3823-3853 Well Type: Orig Completion: Last W/O: Ref Log Date: TD: Max Hole Angle: PROD 11/29/1997 2/6/2000 5462 ftKB 58 deg(~2146 Boffom TVD 0 5453 4024 0 121 121 Angle (~ TS: Angle @ TD: Rev Reason: Last Update: deg(~ deg@5462 Pull pump, reset slipstop, set ~ackoff, GLV 3/26J2003 Wt Grade Thread 29.70 L-80 I BTC-MOD 62.58 H-40 I Welded Bottom I TVD Wt Grade 4816I 3387 9.30 L-80 I Zone I StatuslEt Is. FI Date wso I ]=~ i ~ i~=~ w~I i~01 ~ i~=~c WSA4 I 147112 19/15/~ w~;,w~I i ~o i ~ i~,~,~ WSA3 I 11°112 19/15/1~ ws,~I i~o i ~ i~,~o,~, Thread EUE 8rd I Type I Comment 971 IPERF IZero deg. phasing/Iow side; 12 1/8" EJ 971 IPERF IZero deg. phasing/Iow side; 12 1/8" EJ 991APERF IHSD-BH 4 1/2" 991APERF IHSD-BH 41/2" 991APERF IHSD-BH 4 1/2" )97~ IPERF IZero deg. phasing/Iow side; / I BH EJ Vlv Cmnt -JEWELRY .. : Description Set 3/8/2003 NEW PACKOFF ASSEMBLY INCLUDES PACKOFF, KOBE KNOCKOUT, PUP TOTAL LENGTH APPROX. 98"~ set 3/18/2003 Centrilift Slotted Nipple Centrilift TTC Crossover ID 0.000 0.000 0,000 2.992 2.992 Centrilift GSB3 2,992 Centrilift 525 9.1 2.992 Centrilift 1127/27 2,992 Centrilift 2,992 Baker SCl 4,000 Baker 4,892 ~ Sleeve 4,892 Baker 4,400 Baker 4.000 Baker 4,000 4.000 Baker 0.20 Gauge Baker 4.000 Note DEAD PUMP, WELL NOW ON GAS LIFT SCREEN OD:5.100) .. Qdarterly Flowline line inspections Subject: Quarterly Flowline line inspections Date: Mon, 7 Jul 2003 16:08:20 -0800 From: "NSK Problem Well Supv" <n1617@conocophillips.com> To: tom_maunder@admin.state.ak.us CC: bob_fleckenstein @admin.state.ak.us, "n 1617" <n 1617@conocophillips.com> Tom, Here is a copy of the quarterly flowline inspection reports required to fulfill the Sundry requirements for the following wells. 1D-102: PTD 2000750, Sundry #302-101 1D-105A: PTD 2012020, Sundry #302-294 1D-110A: PTD 2000390, Sundry #302-227 1D-121: PTD 1971810, Sundry #302-304 1D-127: PTD 1981090, Sundry #353-057 1D-129: PTD 1972130, Sundry #303-092 1 D-140: PTD 2001360, Sundry #302-376 3H-05: PTD 1870770, Sundry #302-102 Please let me know if you have any questions. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 (See attached file: 3H-05 Quarterly Inspection Log.xls)(See attached file: 1 D-102 Insp Log.xls)(See attached file: 1 D-105 Inspection Log.xls)(See attached file: 1D-110 Insp Log.xls)(See attached file: 1 D-121 Inspection Log.xls)(See attached file: 1D-127 Inspection Log.xls)(See attached file: 1 D-129 Inspection Log.xls)(See attached file: 1D-140 Inspection Log.xls) ¢~3H-05 Quarterly Inspection Lo,q.xls Name: 3H-05 Quarterly Inspection Log.xls Type: EXCEL File (application/msexcel) Encoding: base64 ~1D-102 Insp Lo.q.xls Name: 1D-102 Insp Log.xls Type: EXCEL File (application/msexcel) Encoding: base64 Name: 1D-105 Inspection Log.xls r~l Inspection Lo,q.xls Type: (application/msexcel) D-1 05 EXCEL File Encoding: base64 ¢~_.~ 1D-110 Insp Log.xls Type: EXCEL File (application/msexcel) Encoding: base64 ~1D-121 Inspection Loq.xls Name: 1D-121 Inspection Log.xls Type: EXCEL File (application/msexcel) Encoding: base64 J 1 of ~C~NN~'"JUL _1_ 6 21303 ?/~4/2003 10:39 Ab · Quarterly Flowline line inspections ! Name: 1 D-127 Inspection Log.xls ~1D-127 Inspection Log.xlsi Type: EXCEL File (application/msexcel) !Encoding: base64 "1D-129 Inspection Loq.xls I Type: EXCEL File (application/msexcel) Name: 1D-129 Inspection Log.xls i Encoding: base64 I I Name: 1D-140 Inspection Log.xls i~'~ 1D-140 Inspection Log.xls Type: EXCEL File (application/msexcel) !Encoding: base64 2 of 2 7/14/2003 10:39 AM 1D-129 Special Inspection Request Log - Flowback inspection - Weekly inspections for 1 month - Monthly inspections for 2 months then quarterly inspections until further notice B, I, N - (B - baseline inspection, I - Increase in % wall loss, N - No change from previous inspection) # of Worst Date of Inspection B, I, N CaseWall Damage! Comments Inspection Locations Loss % Grade 04/13/03 6 B 0% A Base Line Frac Inspection 04/22/03 6 N 0% A 1-Week follow-up Inspection 05/13/03 6 N 0% A 3-Week follow-up Inspection 06/17/03 6 N 0% A Operations Request 09/17/03 Quarterly Inspection Interval STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Pull tubing _ 2. Name of Operator: 15. ARCO Alaska, Inc. I 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface: 391' FNL, 600' FEL Sec. 23, T11N, R10E, UM At top of productive interval: 2629' FSL, 2603' FEL, Sec. 23, T11 N, R10E, UM At effective depth: At total depth: 2629' FSL, 2603' FEL, Sec. 23, T11 N, R10E, UM 12. Present well condition summary Stimulate__ Alter casing _ Type of Well: Development X. Exploratory ~ Stratagrapic ~ Service __~ Plugging _ Perforate _ Repair well _ Other_X ESP Change-out 6. Datum of elavation (DF or KB feet): 41' RKI~ 7. Unit or Property: Kuparuk River Unit 8. Well number: 1D-129 9. Permit number/approval number: 97-213 / 399-166 / 300-006 10. APl number: 50-029-22830 11. Field/Pool: Kuparuk River Field / West Sak Oil Pool Total Depth: measured true vertical 5462' Plugs (measured) bridge plug @ 5300' WLM / 5290' DC; 4033' Effective Deptt measured 5299' WLM/5289' DP Junk (measured) true vertical 3870' Casing Length Size Cemented Conductor 80' 16" 9 cu yds High Early Surface 5412' 7.625" 580 sx AS III 460 sx Class G Production Measured depth True vertical depth 121' 121' 5453' 4024' Liner Perforation Depth measured true vertical 5010'-5038',5070'-5090', 5252'-5282',5183'-5193', 5156'-5166',5116'-5L~" 3581'-3609',3641'-3661' 3823'-3853',3754'-3764,3727'-3737',3687'-37D4' Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 @ 4832' Packers and SSSV (type and measured depth) Baker SC-1 Gravel pack packer @ 4901' WLM / 4891' DP, No SSS¥ 13. Stimulation or cement squeeze summary Intervals treated (measured~ N/A Intervals treated (measured) 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 116. Status of well classification as: Copies of Logs and Surveys run _ I Daily Report of Well Operations _Z Oil _~ Gas _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~,~,,~ ~'. ~,,~ Title: Drilling Engineering Supervisor Chip Alvorct' Suspended _ Service Questions ? Call Mark Ch ambers 265-1319 Date ~('~7 (Zc~, ¢' Form 10-404 Rev 06/15/88 Prepared by Sharon AIIsup-Drake SUBMIT IN DUPLI~,, Date: 02/16/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:lD-129W02 RIG:NORDIC 3 STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: WEST SAK BLOCK: SPUD:01/31/00 START COMP:01/30/00 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22830-00 01/30/00 (C1 TD: 0' PB: 0' 01/31/00 (C2 TD: 0' PB: 0' 02/01/00 (C3 TD: 0' PB: 0' 02/02/00 (C4 TD: 0 ' PB: 0 ' 02/03/00 (C5 TD: 0' PB: 0' 02/04/00 (C6 TD: 0' PB: 0' MOVE RIG SUPV:M. C. HEIM Move rig from Milne Point to iD pad. MW: 0.0 CONTINUE RIG MOVE. MW: 0.0 SUPV:M. C. HEIM Complete rig move to iD pad. Spot rig over 1D-129. Accept rig @ 11:30 pm. Rig up. TESTING BOPE. MW: 9.6 BRINE SUPV:M. C. HEIM Pull VR plug & BPV. Displace well with brine. Circ, well shut in. Monitor well, well dead. CLEANING UP FLOOR & RIGGI MW: 9.6 BRINE SUPV:M. C. HEIM Set BPV. N/D tree, N/U BOPE and function test BOPE. Safety shut down. PJSM. POH with 3.5" tubing, spooling ESP and heat trace cables. SOAKING FORMATION W/ ACID MW: 9.6 BRINE SUPV:M. C. HEIM RIH w/slickline. Pull packoff, pull pump. POH w/3.5" tubing. RIH with new 3.5" tubing. Safety meeting. Pump pickle acid. RIH w/3.5" tubing. Tag packer @ 4891' WAIT ON NEW ESP CABLE. MW: 9.6 BRINE SUPV:M. C. HEIM Circ. heated brine, land seal assembly and test annulus 2000#, OK. Pump down tubing and squeeze away heated diesel. Shut down, let acid soak. Pump down tubing and squeeze heated fresh water w/HC1. Shut down let acid soak. Pump down tubing and squeeze away heated brine and cool brine w/KC1. Unseat seal assembly, well flowing, circ hole volume thru choke. Well flow slowing. Pump pill, well stopped flowing POH w/completion string. P/U and M/U completion equipment. Date: 02/16/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 02/05/00 (C7 TD: 0' PB: 0' 02/06/00 C8 TD: 0' PB: 0' 02/07/00 C9 TD: 0' PB: 0' 02/08/00 TD: O' PB: O' Cl0) CIRC. HOLE CLEAN MW: 9.6 BRINE SUPV:M. C. HEIM Install baker sentry gauge. Running ESP completion to 1512', tested ESP cable ~ 1000'+, weak reading. Tested esp cable 6 1512', weak reading. POH w/esp completion. Testing motor and cable while waiting on new spool and crane. Spot crane, change out esp cables, wrap cable and heat. M/U esp cable to motor, make up baker sentry gauge, RIH w/1 std. completion assy, not testing correctly, POH w/same. Cut off motor lead and splice on new one. SETTING PACKOFF W/ WIRE L MW: 9.6 BRINE SUPV:M. C. HEIM M/U motor lead splice, make up on motor, not testing correctly, lay down motor. Run in hole w/3.5" tubing to 4650'. Circ hole clean, recovered 20 bbls crude. Pull out of hole w/3.5" tubing installing new rings ~ each break. Make up new motor and test, motor not testing, did not test after filling w/oil. Wait on new motor. Make up new motor and baker sentry gauge, test motor, OK, continue running in hole w/completion, testing cable frequently, tested every time. CLEANING MUD PITS. PREPAR MW: 9.6 BRINE SUPV:M. C. HEIM Run 3.5" esp completion assembly. Run & set pump-packoff & GLV, test to 1500~, OK. Pull GLV, Run tubing stop. Hook up heat trace cable. Set BPV. ND BOP stack. NU tree and test baker sentry gauge[ MW: 9.6 BRINE SUPV:DON WESTER NU tree. Test heat trace and ESP cable. OK. Test tubing hanger void to 5000 psi OK 300 psi on tubing & annulus. Circulated down tubing. Pull BPV, set two way check, test tree to 500/5000 psi. OK. Pump diesel down annulus. Set BPV Move rig off well. Release rig @ 1000 hrs. 2/8/2000. 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. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 391' FNL, 600' FEL, Sec. 23, T11N, R10E, UM At top of productive interval 2629' FSL, 2603' FEL, Sec. 23, T11 N, R10E, UM At effective depth At total depth 2629' FSL, 2603' FEL, Sec. 23, 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 1 D-129 9. Permit number / approval number 97-213 10. APl number 50-029-22830 11. Field / Pool Kuparuk River Field / West Sak Oil Pool 12. Present well condition summary Total depth: measured 5462 feet true vertical 4033 feet Effective depth: measured~299' WLM/5289' DF feet true vertical 3870' feet Casing Length Size Conductor 80' 16" Surface 5412' 7.625" Production Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) Plugs (measured) Junk (measured) bridge plug @ 5300' WLM/5290' DP Cemented Measured Depth True vertical Depth 9 cu yds High Early 121' 121' 580 AS III & 460 sx Class G 5453' 4024' ORIGINAL 5010'-5038', 5070'-5090', 5252'-5282', 5183'-5193', 5156'-5166', 5116'-5133' 3581'-3609',3641'-3661' 3823'-3853',3754'-3764,3727'-3737',3687'-3704' 3.5", 9.3#, L-80 @ 4832' Baker SC-1 Gravel pack packer @ 4901' WLM / 4891' DP, No SSSV 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 __ 14. Estimated date for commencing operation January 25, 2000 Date approved 15. Status of well classification as: Oil __X Service 16. If proposal was verbally approved Name of approver Gas __ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signedc/~~ ~ ~ Title: Drilling Team Leader Questions? Call Mark Chambers 265-1319 Date 'll'(~''~' Prepared by Sharon Al/sup-Drake FOR COMMISSION USE ONLY ~1~ 6¢:~roval: Co_rlj;J,i~ Noti.fy Co.mmission so representative may witness JCN~~ ~. PMl;~:~cg;l,~:_ BOPTest ~ Location clearance _ I~~'O. tegrity Test~_.~U~_.. __ Subsequent form required 10-__~l'~(~)f~ ORIGINAL SIGNED' BY Approved by order of the Commission RO~ N. Ghfis~nson Commissioner Form 10-403 Rev 06/15/88. SUBMIT IR:TRIPLICATE West Sak 1D-129 GENERAL WORKOVER PROCEDURE PRE-RIG WORK: 1. RU Slick Line Unit. RIH and pull Shear Valve from GLM @ 4718' leaving an open pocket. 2. Set BPV in tubing. Install VR plug in annulus valve. Prepare Location for Nordic Rig 3. GENERAL WORKOVER PROCEDURE: 1. MIRU Nordic Rig 3. Lay hard-line to tree. Pull BPV and VR plug. 2. 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. 3. ND / NU and test B OPE. 4. Screw in landing joint. POOH standing back 3-1/2" tubing and spooling up ESP Cable and Heat Trace. 5. Load, strap and drift 3-1/2" drill pipe. 6. RIH w/cleanout assembly PU 3-1/2" drill pipe off rack. 7. Cleanout to PBTD. 8. POOH laying down 3-1/2" drill pipe. 9. RIH w/3-1/2" tubing and ESP Assembly. Space out heat trace and splice power cable and 1-wire to penetrators. 10. Land tubing hanger. RILDS, install two-way check and test tubing hanger. 11. ND/NU/Test 12. Freeze protect with diesel to +/- 2000' TVD. Lower Limit: 5.0 days Expected Case: 6.0 days Upper Limit: 8.0 days No problems encountered. Problems pulling ESP completion or cleaning out to PBTD MAC 1/10/00 ¢; EIVED WEST SAK 1 D-129 Workover Frac for Sand Control w/Gravel Pack ARCO Alaska, Inc. J 7-5/8" Marker Joint (+/- 50' Above Top Perforation) TD @ 5462' ,[ 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 @ 121' MD DV Stage Collar @ 2498' MD Raychem Heat Trace @ +/- 2303' MD 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing to Surface. Directional Information KOP = 470' Max Angle = 58 Deg @ 2146' 3-1/2" x 1" Camco 'KBMM' GLM run open @+/- 4,718' MD. After the rig moves off location, the Wells Group will install a Shear Circulating Valve, pinned for 3000 psi Tbg / Csg differentia. I. GLM to be run w/6' handling pups on top and bottom. 2 Joints 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 @+/- 4,832' MD (total length = 26.8') Centrilift 3-1/2" Slotted Nipple. Centrilift 'IFC Changeover Centrilift Seal Section: GSB3 DB IL H6PFS Centrilift PC Pump and Flex Shaft Assembly: KUDU 80TP2000 Centrilift Gear Reduction Unit: 525 Series, 9:1 Centrilift Motor Centralizer Baker Model SC-1 Packer @ +/-4,891' MO D-Sand ~e~fs: ~ ~F ~,0~ O' - ~,0~8' Fmo'~ ~/~ ~-~0 ~r~olite ~n~ ~ro~Loo~ B-Sand Perfs: 4 SPF 5,070' - 5,090' Frac'd w/16-20 Carbolite and PropLock A4-Sand Perfs: 12SPF 5,116'-5,133' A3-Sand Perfs: 12 SPF 5,156' - 5,166' / 5,183' - 5,193' A2-Sand Perfs: 4 SPF 5,252' - 5,282' Frac'd w/16-20 Carbolite and PropLock Top of bridge plug @ +/- 5285' MD Top of fill @ +/- 5,357' MD 7-5/8" 29.7# L-80 BTC Mod @ +/- 5453' MD MAC 1/10/00 ARCO Alaska, Inc. GKA 1D-129 ==~= 1D-129 §L= APl: 500292283000 Well Type: PROD Angle @ TS: dog (~ SSSV Type: NONE Orig Completion: 11/29/97 Angle @ TD: 1 dog @ 5462 Annular Fluid: Last W/O: 9/19/99 Rev Reason: Workover new TUBING schematic by ImO (0-4817, Reference Log: Ref Log Date: Last Update: 10/24/99 0D:3.500,.. Last Tag: 5430 TD: 5462 ftKB ID:2.992) I Last Tag Date: Max Hole Angle: 58 dog @ 2146 Casin~l Strin~l - CONDUCTOR 16.000 0 121 121 62.58 H-40 Welded Casing String - SUR. CASING !iiii~' Size I Top I Bottom TVD I Wt I Grade I Thread 7.625 0 5453 4024 29.70 L-80 BTC-MOD ESP Pump Tubing Strin~l - TUBING (4790-4812. Size I Top Bottom TVD I Wt IGradeI Thread 0D:4.719) 3.500 0 4817 3388 9.30 L-80 EUE 8rd-MOD Perforations Summary Interval TVD Zone Status Feet SPF Date Type Comment 5010 - 5038 3581 - 3609 28 4 12/6/97 IPERF Zero deg. phasing/Iow side; 2 1/8" EJ 5070 - 5090 3641 - 3661 20 4 12/4/97 IPERF Zero deg. phasing/Iow side; 2 1/8" EJ 5116 - 5133 3687 - 3704 17 12 9/15/99 APERF HSD-BH 4 1/2" 5156- 5166 3727 - 3737 10 12 9/15/99 APERF HSD-BH 4 1/2" 5183 - 5193 3754 - 3764 10 12 9/15/99 APERF HSD-BH 4 1/2" 5252 - 5282 3823 - 3853 30 4 11/30/97 IPERF Zero deg. phasing/Iow side; BH EJ Gas Lift MandrelsNalves SeaISection Stn MD TVD Man Man V Mfr V Type V OD Latch Port TRO Date VIv (4817-4824, Mfr Type Run ;omment OD:5.125) 1 47181 3289 Camco KBMM CAMCO SOV 1.0 BK 0.000 3000 10/23/99 Other .'plu~ls, equip, otc;). JEWELRY Depth TVD Type Description ID 4783 3354 Packoff 0.000 Assy 4790 3361 ESP Pump w/Flex Shaft and Intake (180TP2000) 0.000 4812 3383 NIP Centrilift slotted nipple 2.992 4817 3388 Seal Section GSB3 DB 1L H6 PFS 0.000 Motor 4824 3395 Gearbox 9:1 525 Series 0.000 (4825-4832, 4825 3396 Motor PC ESP 57 HP 1315/26 KMH 0.000 OD:5.625) 4891 3462 PKR SC1 Gravel Pack Packer 4.000 4900 3471 SLEEVE BAKER sliding sleeve 4.992 4984 3555 SCREEN BAKER .2 Gauge screen 4.000 5290 3861 PLUG BAKER bull plug 0.000 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 10, 1999 Mr. Robert N. Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1D-129 (Permit No. 97-213/399-166) Report of Sundry Well Operations Dear Mr. Commissioner: Enclosed is the Report of Sundry Well Operations for the recent workover operations on KRU 1D-129. 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 _ Pull tubing _ 2. Name of Operator: 15. ARCO Alaska, Inc. I 3. Address: P.O. Box 100360 Anchora,qe, AK 99510-0360 4. Location of well at surface: 391' FNL, 600' FEL, Sec. 23, T11 N, R10E, ur,, At top of productive interval: 2629' FSL, 2603' FEL, Sec. 23, T11 N, R10E, UN At effective depth: At total depth: 2629' FSL, 2603' FEL, Sec. 23, T11 N, R10E, UN 12. Present well condition summary Total Depth: measured 5462' true vertical 4033' Effective Deptt measured 5299' WLM/5289' DP true vertical 3870' Stimulate__ Alter casing _ Type of Well: Development X. Exploratory ~ Stratagrapic ~ Service ~ Plugging _ Perforate _ Repair well _ Other_X ESP Change-out 6. Datum of elavation (DF or KB feet): 41' RKE 7. Unit or Property: Kuparuk River Unit 8. Well number: 1D-129 9. Permit number/approval number: 97-213 / 399-166 10. APl number: 50-029-22830 11. Field/Pool: Kuparuk River Field / West Sak Oil Pool Plugs (measured) bridge plug @ 5300' WLM / 5290' DP Junk (measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 9 cu yds High Early 121~ 121' Surface 5412' 7,625" 580 sx AS III 5453' 4024' 460 sx Class G Production Liner Perforation Depth measured 5010'-5038', 5070'-5090', 5252'-5282', 5183'-5193', 5156'-5166', 5116'-51:,~' true vertical 3581 '-3609', 3641'-3661' 3823'-3853' 3754'-3764, 3727'-3737', 3687'-370,f' Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 @ 4832' Packers and SSSV (type and measured depth) Baker SC-1 Gravel pack packer @ 4901' WLM / 4891' DP, No SSS~/ 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Intervals treated (measured) 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil __X Gas _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~/~ ~j.., Form 10-~,04 Rev 06/15/88 Suspended _ Service Date SUBMIT IN DUPLICATE .~ Date: 10/20/99 REMEDIAL AND COMPLETION OPERATIONS WELL:lD-129WO WELL_ID: 999406 TYPE: STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: WEST SAK SPUD:09/12/99 START COMP:09/07/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 RIG:NORDIC 3 WI: 0% SECURITY:0 API NIIMBER: 50-029-22830-00 BLOCK: FINAL: 09/07/99 (C1) TD: 0' PB: 0' TURNKEY RIG MOVE FROM 3F SUPV:RICK OVERSTREET Turnkey rig move from 3F to iD. MW: 0.0 09/08/99 (C2) TD: 0' PB: 5433' MOVING RIG FROM 3F TO iD. MW: 0.0 SUPV:RICK OVERSTREET Moving rig & mats from 3F to 1D-129. Accepted rig ~ 1100 am. 09/09/99 (C3) TD: 0' PB: 5433' CONTINUE TO MOVE RIG FROM SUPV:RICK OVERSTREET Continue to move rig & mats to 1D pad. MW: 0.0 09/10/99 (C4) TD: 0' PB: 5433' MOVING RIG & MATS FROM 3F MW: 0.0 SUPV:RICK OVERSTREET Continue moving mats and rig from 3F to iD. 09/11/99 (C5) TD: 0' PB: 5433' RU HARDLINE AND PREPARING MW: 0.0 SUPV:RICK OVERSTREET Completed moving rig from 3B to iD. Spot rig over well. 09/12/99 (C6) TD: 0' PB: 5433' CHANGING OUT ELEMENT IN B MW: 8.7 SUPV:RICK OVERSTREET Spot rig & level. Held PJSM. ND tree, NU BOP. BRINE 09/13/99 (C7) TD: 0' PB: 5433' LOADING PIPE SHED, DRIFTI MW: 8.7 3KCL SUPV:RICK OVERSTREET Function test BOPE, OK. Circulate bottoms up, monitor well to ensure well dead. PJSM. POOH laying down 2-7/8" tubing. 09/14/99 (C8) TD: 0' PB: 5433' RIGGING UP TO RUN GR/JB 0 MW: 8.7 KCL SUPV:P. LOCKWOOD/S. GOLDBERG Pull out of hole with tubing and ESP equipment. RIH w/mill and x-over. Lost 9 bbls while circulating. PJSM. 09/15/99 (C9) TD: 0' PB: 5300' POOH WITH SCRAPERS MW: 8.7 KCL SUPV:P. LOCKWOOD/S. GOLDBERG Perforate interval 5183' to 5193', 5156'-5166', 5116' to 5133' RIH w/Baker bridge plug and set at 5300' PJSM. Pump caustic wash. Pump risc. pill, and HC1 acid. Date: 10/20/99 ARCO ALASKA INC. WELL SEIMMARY REPORT Page: 2 09/16/99 (C10 TD: 0' PB: 5300' 09/17/99 (Cll TD: 0' PB: 5300' 09/18/99 (C12 TD: 0' PB: 5300' 09/19/99 (C13 TD: 0' PB: 5300' POOH WITH SETTING TOOLS MW: 8.7 KCL SUPV:P. LOCKWOOD/S. GOLDBERG Continue to circulate the well clean. Load Baker Gravel Pack screens. Monitoring well and saw that it was flowing. Shut in well. Open well to trip tank and monitor flow. Flowrate decreasing to zero. RIH w/gravel pack screens. Set gravel pack packer at 4891' Hold safety meeting. Start gravel pack procedures. RUNNING 3 1/2" COMPLETION MW: 8.7 KCL SUPV:P. LOCKWOOD/S. GOLDBERG Circulate B/U through choke. Monitor well. Well flowing back slightly. Monitor well. Pull 15 stands. Hole not taking correct fill. Run seal section assembly. Set wireline retrievable pump. RIGGING UP ON 1D-113 MW: 8.7 KCL SUPV:P. LOCKWOOD/S. GOLDBERG RIH w/3.5" tubing and ESP assembly. N/U tree and test to 250/5000 psi. Freeze protect well. RIG RELEASED TO 1D-113 MW: 8.7 SUPV:P. LOCKWOOD/S. GOLDBERG Rig down. Release rig at 0200 hrs. 9/19/99 KCL MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission Robert Christenson~~') DATE: 9/13/99 Chairman THRU: Blair Wondzell, P. I. Supervisor FROM' Lawrence M'Wade SUBJECT: Petroleum Inspector FILE NO: aa2gimgf. DOC BOP Test Nordic 3 KRU 1 D-129 PTD 97-213 September 13,1999: I traveled to Kupurak to witness an initial BOP test on Nordic 3 which is doing a workover on a ESP West Sak completion. The test was going very well till we got to the annular which would not pass the pressure test. We tested everything else and the crew started to drain the stack and replace the element in the annular. SUMMARY: Witnessed the BOP test on Nordic3, 3 hours, I failure. Attachments: aa2gimgf, xIs cc; NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Workover: X Drlg Contractor: Nordic Rig No. Operator: ARCO Well Name: 1D-12g Casing Size: 7 5/8' Set @ 5412' Test: Initial X Weekly Other 3 PTD # Rep.: Rig Rep.: Location: Sec. 97-213 DATE: 3/1/9g Rig Ph.# 659-7563 Rick Overstreet Shane McGheehan 23 T. 11N R. 10E Meridian Urniat Te~ MISC. INSPECTIONS: FLOOR SAFETY VALVES: Quan. Pressure P/F Location Gen.' ok Well Sign X Upper Kelly / IBOP 1 300/3500 ! ...P Housekeeping: ok (Gert) Drl. Rig X Lower Kelly /IBOP 1 300/3500 I P PTD On Location ~ Hazard Sec. X ~ Ball Type I 300/3500 'p Standing Order Posted X ~' Inside BOP I 300/3500 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. Test I 250/3,000 Pressure 350/3500 1 300/3500 1 300/3500 I 300/3500 I 300/3500 1 300/3500 3 o/35o0 ,. ,, P/F F P , P P P P MUD SYSTEM: Visual Alarm Trip Tank X X Pit Level Indicators X X Flow Indicator X '~ "' Meth Gas Detector X X H2S Gas Detector X X CHOKE MANIFOLD: No. Valves 12 No. Flanges 36 Manual Chokes 1 Hydraulic Chokes 1 350/3500 Functioned Functioned P/F P , , P p, , P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure ~ System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 2150-2200 3,000 I' 2,100 minutes 20 sec. minutes 5 sec. X Remote: X 2200-2200 Psig. Number of Failures: f ,Test Time: 3,0 Hours. Number of valves tested 19 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 I I REMARKS: / Annular would not pass pressure test. Chan~ed element. I I I Distribution: odg-Well File c - Oper./Rig c - Database c - Tdp Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO , II Waived By: Witnessed By: Larry Wade F1-021L (Rev. 12/94) aa2girngf, xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request Abandon _ Suspend _ Operational shutdown _ Alter casing _ Repair well _ Plugging _ Change approved program _ Pull tubing _ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: Development _X Exploratory _ Stratigraphic __ Service _ Re-enter suspended well _ Time extension _ Stimulate _ Other _X Variance _ Perforate _ ESP change-out 6. Datum elevation (DF or KB feet) RKB 41 feet 7. Unit or Property name Kuparuk River Unit 4. Location of well at surface 391' FNL, 600' FEL, Sec. 23, T11N, R10E, UM At top of productive interval 2629' FSL, 2603' FEL, Sec. 23, T11 N, R10E, UM At effective depth At total depth 2629' FSL, 2603' FEL, Sec. 23, T11 N, R10E, UM 12. Present well condition summar Total depth: Effective depth: measured 5462 true vertical 4033 measured 5433 true vertical 4004 feet Plugs (measured) feet feet Junk (measured) feet 8. Well number 1 D-129 9. Permit number / approval number 97-213 10. APl number 50-029-22830 11. Field / Pool Kuparuk River Field / West Sak Oil Pool ORIGINAL Casing Length Conductor 80' Surface 5412' Size Cemented 16" 9 cu yds High Early 7.625" ss0 AS III 460 & sx Class G Measured Depth True vertical Depth 121' 121' 5453' 4024' Production Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 5010'-5038',5070'-5090',5252'-5282' 3581'-3609',3641'-3661',3823'-3853' 2.875",6.5#, L-80 @ 4878' MD No packer, No SSSV Alaska 0ii & Gas Cons. O0rm~fissio~', 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 September 6, 1999 16. If proposal was verbally approved Name of approver Date approved Oil __X Gas __ Suspended __ Service 17. I hereby certify 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 Prepared b~' 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- ~r ~ I Appr°va' n°'~=)O/- Approved by order of the Commission ORIGINAL SIGNED, ElY Rob~,~ hi. (Jhdstenson , C,O~ommissioner Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE West Sak 1D-129 GENERAL WORKOVER PROCEDURE PRE-RIG WORK: 1. RU Slick Line Unit. RIH and pull Shear Valve from GLM @ 4826' leaving an open pocket. 2. Set BPV in tubing. Install VR plug in annulus valve. Prepare Location for Nordic Rig 3. GENERAL WORKOVER PROCEDURE: 1. MIRU Nordic Rig 3. Lay hard-line to tree. Pull BPV and VR plug. 2. 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. 3. ND / NU and test BOPE. 4. Screw in landing joint. POOH laying down 2-7/8" tubing and spooling up ESP Cable and Heat Trace. 5. Load, strap and drift 3-1/2" drill pipe. 6. RIH w/cleanout assembly PU 3-1/2" drill pipe off rack. 7. Cleanout to PBTD and POOH standing back 3-1/2" drill pipe. 8. RIH w/muleshoe and dual scrapper assembly. Spot sand plug and pump caustic wash and pickle. 9. POOH standing back 3-1/2" drill pipe. 10. PU and RIH w/gravel pack assembly. 11. Set packer @ +/- 4900' and perform gravel pack. 12. POOH laying down 3-1/2" drill pipe. 13. RIH w/3-1/2" tubing and ESP Assembly. Space out heat trace and splice power cable and I-wire to penetrators. 14. Land tubing hanger. RILDS, install two-way check and test tubing hanger. 15. ND/NU/Test 16. Freeze protect with diesel to +/- 2000' TVD. 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 8/20/99 WEST SAK 1 D-129 Workover Proposed Schematic Standard Frac For Sand Control FFSC to FFSCGP ARCO Alaska, Inc. J !__ Depths are based on original RKB Parker 245 37' RKB to LDS 7-5/8" Marker Joint (+/- 50' Above Top Perforation) TD @ 5462' 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 @ 121' MD DV Stage Collar @ 2498' MD Raychem Heat Trace @ +/- 2265' MD 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing to Surface. Directional KOP = 470' Max Angle = 58 Deg @ 2146' 3-1/2" x 1" Camco 'KBMM' GLM run open @+/- 4,761' MD. After the rig moves off location, the Wells Group will install a Shear Circulating Valve, pinned for 3000 psi Tbg / Csg differentia. I 2 Joints 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 @+/- 4,840' MD (total length = 26.8') Centrilift 3-1/2" Slotted Nipple. Centrilift -IFC Changeover Centrilift Seal Section: GSB3 DB IL H6PFS 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 @ +/- 4900' MD D-Sand Perfs: 4 SPF 5010' - 5038' Frac'd w/16-20 Carbolite and PropLock B-Sand Perfs: 4 SPF 5070' - 5090' Frac'd w/16-20 Carbolite and PropLock A2-Sand Perfs: 4 SPF 5252' - 5282' Frac'd w/16-20 Carbolite and PropLock Top of sand plug @ +/- 5297' MD PBTD @ +/- 5433' MD 7-5/8" 29.7# L-80 BTC Mod @ +/- 5453' MD MAC 8/2O/99 ARCO Alaska, TUBING (0-4878, OD:2.875. ID:2.438) SUP,. CASING (0-5453, -- 0D:7.625, Wt:29.70) Gas Lift Mandrel/Dummy Valve 1 (4826-4827, OD:4.742) Handling Pup -- (4870-4878, 0D:2.875) ESP Pump (4878-4907, -- OD:4.719) Seal Section (4907-4921, -- 0D:5.125) Gearbox (4921-4922, OD:5.250) Motor (4922-4929, -- OD:5.625) Perf (5010-5038) Perf (5070-5090) Peri (5252-5282) Inc. KRU 1D-129 1D-129 APl:1500292283000 SSSV Type: NONE Annular Fluid: Last Tag: 5430 Rev Reason: New Schem BY ez Casing String - CONDUCTOR size I Top 1 16.000 0 Casing String - SUR. CASING Size Top 7.625 0 Tubing String - TUBING Size Top 2.875 0 Perforations IntervalI TVD I Zone 5010 - 5038 3581 - 3609 5070- 5090 3641 - 3661 5252- 5282 3823- 3853 Gas Lift Mandrels/Valves Well Type: Orig Completion: Last W/O: Last Tag Date: PROD 11/29/97 12/21/97 Last Update: 8/23/98 Boffom TVD PBTD: 15462 ftKB TD: 5462 ftKB Max Hole 58 deg @ 2146 Anq e: 121 121 Boffom TVD 5453 4024 Boffom TVD 4878 3449 Angle @ TS: I deg @ Angle @ TD:I 1 deg ~ 5462 Wt GradeI Thread 62.58 H-40 Wt GradeI Thread 29.70 L-80 Wt Grade Thread 6.50 L-80 EUE 8rd Mod Feet SPF Date Type 28 4 12/6/97 2 1/8" EJ 20 4 12/4/97 2 1/8" EJ 30 4 11/30/97 BH EJ Zero Comment deg. phasing/Iow side Zero deg. phasing/Iow side Zero deg, phasing/Iow side Stn MD TVD Man Mfr Man Type Vlv Mfr Vlv Type Vlv OD Latch PortI TRO Date Rut I 4826 3397 Camco KBMM CAMCO DCR 1.0 BK 0.000 3000 12/24/97 Other (PlUgS,:equiP, etC,) - JEWELRY Depth I TVDI Type I Description ID 48701 34411 Handling Pup 2 7/8" 6.5" EUE 8rd Mod 2.441 48781 34491 ESP Pump w/Flex Shaft and Intake (180TP2000) 0.000 49071 3478 Seal Section GSFT DB HL PFS 0.000 4921 3492 Gearbox 19:1 525 Series 0.000 4922 3493 Motor PC ESP 57 HP 1315/26 KMH 0.000 General Notes: Date 4/5/98 Note Encoutered FILL in TBG (Frac Sand) (~ 3492' (WLM) ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 5, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1D-129 (Permit No. 97-213) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on West Sak 1D-129. If there are any questions, please call 265-6890. Sincerely, T. W. Mc Kay Senior Drilling Engineer Kupamk Development TWM/skad RECEIVED FEB ~G 1998 Alaska Oil & ~as Cons. Commission Anchorag~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL ~] GAS [~ SUSPENDED ['~ ABANDONED~ SERVICE [] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 97-213 3 Address 8 APl Number P.O. Box 100360, Anchora~le, AK 99510-0360 50-029-22830 ,,~.¢.- ' 9 Unit or Lease Name 4 Location of well at surface ?":- ,. '.'~' ,. i~' ~'~'*~''''~'~=~1~~'' 391' FNL, 600' FEL, Sec. 23, T11N, R10E, UM ~' :i ~! Kuparuk River Unit At Top Producing Interval i .~._~_~_~--(..//~,,~ i i~~ ,10 Well Number' 2629' FSL, 2603' FEL, Sec. 23, T11N, R10E, UM ~i,~ West Sak 1D-129 At Total Depth , i' 11 Field and Pool 2629' FSL, 2603' FEL, Sec. 23, T11 N, R10E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. West Sak Oil Pool RKB 41', Pad 70'I ADL 25650 ALK 468 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 16 No. of Completions 22-Nov-97 25-Nov-97 24-Dec-97 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 5462' MD & 4033' TVD 5433' MD & 4004' TVD YES JxJ NO U NA feet MD 2198' APPROX 22 Type Electdc or Other Logs Run GR/Res 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.58# H-40 SURF. 121' 24,, 9 cu yds High Early 7.625" 29.7# L-80 SURF. 5453' 9.875" 680 sx AS III & 460 sx Class G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2.875" 4929' 5010'-5038' MD 3581'-3609' TVD 5070'-5090' MD 3641'-3661' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 5252'-5282' MD 3823'-3853' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4 spf 5070'-5090' MD & ~njected 109044# of prop w/10# ppa of #16/20 5252'-5282' MD at perfs. 5010'-5038' MD ~njected 102651# of prop wi10# ppa of #16/20 @perfs 27 PRODUCTION TEST Date First Production 12/26/97 Method of Operation Gas (Flowing, Lift gas lift, etc.) Date of Test Hours Tested PRODUCTION FO OIL-BBL GAS-MCF WATER-BBI CHOKE SIZE I GAS-OIL RATIO 1/15/98 4 TEST PERIOI: 73 36 3 0J 505 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBI OIL GRAVITY-APl (corr) Press. 167 -15 24-HOUR RATE: 439 221 23 20° . 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev, 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top West Sak Sand 5006' 3577' Base West Sak Sand 5426' 3997' Annulus left open - freeze protected with diesel. 31. LIST OF A'FFACHMENTS Summary of Daily Drilling Reports, Directional Survey 132. I hereby certify that the foregoing is true and correct to the best of my knowledge. 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 4~'c~/orage C~t~rfl/,~ton Date: 1/15/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iD-129 RIG:NORDIC WELL_ID: AK9045 TYPE: AFC: AK9045 AFC EST/UL:$ 1606M/ 1928M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:il/22/97 START COMP:12/18/97 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22830-00 11/22/97 (D1) TD: 985' (985) SUPV:DEB MW: 9.0 VISC: 330 PV/YP: 30/55 APIWL: 7.8 SHORT TRIP AT 1449' MD Pre-move safety meeting. Move from 1D-133 to 1D-129. Accept rig ~ 0530 hrs. 11/22/97. NU diverter system. Function test diverter. Spud in at 121' and drill to 985' MD. Drilling ahead. 11/23/97 (D2) TD: 3825' (2840) SUPV:DEB MW: 9.2 VISC: 285 PV/YP: 40/53 RIH Drill from 985' to 3825' MD. APIWL: 7.8 11/24/97 (D3) TD: 4300' (475) SUPV:DEB MW: 9.3 VISC: 266 PV/YP: 37/47 APIWL: 6.8 DRILLING AT 4722' MD RIH, hit bridge at 530'. Would not work thru easily, did not try pump due to risk of side tracking. Wash thru bridge to 630', saw nothing. Drill from 3825' to 4300' MD. 11/25/97 (D4) TD: 5462' (1162) SUPV:GRW MW: 9.2 VISC: 285 PV/YP: 36/50 POOH FOR CASING Drill from 4300' to 5462' APIWL: 6.2 11/26/97 (D5) TD: 5462'( SUPV:GRW 0) MW: 9.4 VISC: 110 PV/YP: 30/38 APIWL: 7.4 CLEANING OUT DIVERTER Safety meeting. Run 7-5/8" casing to 5453' TVD. Pump cement. 11/27/97 (D6) TD: 5462'( SUPV:GRW 0) MW: 8.8 VISC: 39 PV/YP: 9/15 APIWL: 18.0 POOH TO CHECK BIT Finish cementing first stage. Cement 2nd stage. N/D diverter, NU BOPE, test BOPE to 300/3000 psi. Drill stage collar and 5' of cement. Drill cement from 5050' to 5200' 11/28/97 (D7) TD: 5462'( SUPV:GRW 0) MW: 8.9 VISC: 43 PV/YP: 5/33 POOH W/DP Drill cement to 5433' APIWL: 20.0 Date: 1/15/98 11/29/97 (DS) TD: 5462'( SUPV:GRW 0) ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 MW: 8.5 VISC: 28 PV/YP: 1/ 0 APIWL: 0.0 RIG RELEASED Safety meeting. Run 3.5" tubing to 5432'. Freeze protect well. N/D BOPE. N/U tree. Test to 5000 psi. Release rig @ 2400 hrs. 11/29/97. REMEDIAL AND COMPLETION OPERATIONS WELL:iD-129 RIG:NORDIC WELL_ID: AK9045 TYPE: AFC: AK9045 AFC EST/UL:$ 1606M/ 1928M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:il/22/97 START COMP:12/18/97 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22830-00 12/18/97 (C9) TD: 0' PB: 5433' SUPV:MC DISPLACING FREEZE PROTECT MW: 0.0 Spot rig and level. Repair riser. R/U to kill well. 12/19/97 (C10) TD: 0' PB: 0' SUPV:MC RIH W/3.5" DP AND MILL MW: 8.7 KCL N/D tree. N/U BOPE. Test BOPE. RIH w/spear, latch into tubing hanger. Pull tubing hanger to floor. 12/20/97 (Cll) TD: 5423' PB: 5423' SUPV:MC POOH W/3.5" DP MW: 8.7 KCL Clean out 7-5/8" casing from 4929' - 5126' and then to PBTD of 5423' 12/21/97 (C12) TD: 5423' PB: 5423' SUPV:MC PREPARING TO POOH TO LOG MW: 8.7 RIH with mule shoe. Wash down to PBTD @ 5423' KCL 12/22/97 (C13) TD: 5423' PB: 5423' SUPV:MC RIH W/2-7/8" COMPLETION S MW: 8.7 KCL Continue to reverse circ and clean well bore. Safety meeting. Pump caustic w/Hogwash sweep followed by Xanvis hi vis sweep. Circulate out residual polymer. R/U Protechnics Radioactive trace log on slick line. Wait on Protechnics, wait on Halliburton, logging unit down (problems - cold). 12/23/97 (C14) TD: 5423' WORK ON ESP CABLE MW: 8.7 KCL Safety meeting. RIH with 2-7/8" tubing w/ESP cable w/heat PB: 5423' SUPV:DW trace from 2265' to surface. 12/24/97 (C15) TD: 5423' PB: 5423' SUPV:DW RIG RELEASED AT 1800 HRS MW: 8.7 KCL Continue running completion tubing. ND BOPE and NU tree and test to 250/5000 psi, OK. Freeze protect well. Release rig @ 1800 hrs. 12/24/97. End of WellSummary for Well:AK9045 ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-129(W4-6)) WELL 1 D-129 JOB SCOPE FRAC, FRAC SUPPORT JOB NUMBER 1129972015.4 DATE DALLY WORK UNIT NUMBER 11/30/97 PERFORATE 8337 OPERATION COMPLETE I SUCCESSFUL IKEY PERSON YES [ YES I SWS-BAILEY Initial Tbg Press Fin~-i~ ~-ress Initial Inner Ann I Final Inner Ann 0 PSI 0 PSI 0 PSII 0 PSI DAILY SUMMARY DAY 1 SUPERVISOR SCHUROSKY Initial Outer Ann I Final Outer Ann 0 PSII 0 PSI PERFORATE WELL WITH 30' ENERJET, 5252' TO 5282' I TIME LOG ENTRY 16:00 RIG UP APC, PULL BACKPRESSURE VALVE. 17:30 MIRU SWS E-LINE, HOLD TGSM, PT BOP AND STACK TO 2500 PSI. 18:45 RIH WITH CPLC(CCL), CGRS (GAMMA RAY), 6' WT. BAR, TO LOG COLLARS AND GAMARAY FOR DEPTH TIE IN LOG FOR PERF GUNS. POOH. 21:00 RIH WITH 30' BIGHOLE ENERJET GUN, 4 SPF, 0 DEG PHASE. TO 5252'. TIE IN ON DEPTH TO GAMA/CCL, SHOOT GUN WITH CCL AT 5247.5', 4.5' TO TOP SHOT. 22:30 POOH WITH SPENT GUNS. 22:45 AT SURFACE WITH TOOLS, CHECK FOR DISCHARGE OF GUNS. RDMO. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-129(W4-6)) WELL JOB SCOPE 1 D-129 FRAC, FRAC SUPPORT DATE DALLY WORK 12/04/97 FRAC, FRAC SUPPORT DAY OPERATION COMPLETE ISUCCESSFUL IKEYPERSON 3 YES YES SWS-DECKERT InitialTbgPress JFinalTbgPress IlnitiallnnerAnn IFinallnnerAnn I Initial Outer Ann IFinaIOuterAnn 250 PSI 250 PSI 250 PSI 250 PSI 0 PSI 0 PSI DAILY SUMMARY JOB NUMBER 1129972015.4 UNIT NUMBER SUPERVISOR BLACK PERFORATED "B" SAND F/5070 - 5090' ELM W/2-1/8" EJ BH @ 4 SPF & 0 DEG PHASING / ORIENTATION I TIME LOG ENTRY 02:00 MIRU SWS (DECKERT & CREW) & LRS. APC VALVE CREW SERVICE TREE VALVES. TGSM & PAD NOTIFICATION OF UPCOMING PERF WORK. MU GUN ASSEMBLY (20' EJ/CCL/HD) TL-33'. PT BOPE TO 2000 PSI. 05:00 RIH TO 5100' ELM. TIE IN W/11/30/97 SWS PERF RECORD. LOG INTO POSITION & PERFORATE F/5070 - 5090' ELM W/2-1/8" EJ BH @ 4 SPF & 0 DEG PHASING / ORIENTATION. GOOD SURFACE INDICATION BUT NO PRESSURE INCREASE. LOG UP INTO TUBING & POOH. 06:15 AT SURFACE. ALL SHOTS FIRED. RELEASE F/RADIO SILENCE. BEGIN RD. 07:45 OFF LOCATION & RELEASE TO FRAC CREW F/UPCOMING FRAC. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-129(W4-6)) WELL 1D-129 DATE 12/O4/97 DAY 3 JOB SCOPE FRAC, FRAC SUPPORT DAILY WORK WEST SAK INITIAL "B" SAND FRAC OPERATION COMPLETE SUCCESSFUL YES NO Initial Tbg Press I Final Tbg Press I Initial Inner Ann1320 PSI 1150 PSI 320 PSI DAILY SUMMARY IKEY PERSON DS-GALLEGOS JOB NUMBER 1129972015.4 UNIT NUMBER SUPERVISOR CHANEY Final Inner Ann I Initial Outer Ann Final Outer Ann 1050 PSII 0 PSI 0 PSI INITIAL WEST SAK "B" SAND FRAC COMPLETED THRU FLUSH. INJECTED 73759 LBS OF PROP IN THE FORM. W/10# PPA OF #16/20 @ PERF'S. PROPLOCK SERVICES EQUIPMENT FAILED AND WAS UNABLE TO COAT THE LAST 60 BBLS OF THE JOB. MAXIMUM PRESSURE 3000 PSI & F.G. (.66). TIME 08:00 LOG ENTRY MIRU DOWELL FRAC EQUIP, HES PROPLOK EQUIP, PROTECHNICS EQUIP, LRS HOT OIL UNIT, AND APC VAC TRKS. HELD SAFETY MEETING 10:30 PT'D BACKSIDE LINES TO 4000 PSI. PT'D HIGH PRESSURE LINES TO 4100 PSI. 11:30 12:30 13:45 PUMP IMPLUSE TEST W/DIESEL @ 18 BPM. VOLUME PUMPED 20 BBLS. MAXIMUM AND ENDING PRESSURE 3000 PSI. S/D AND OBTAINED ISIP 998 PSI W/F.G. @ (.66). STOOD-BY AND MONITORED WHTP. PUMP BREAKDOWN W/50% HEC - 3% KCL GW @ 20 TO 15 BPM. VOLUME PUMPED 220 BBLS. USED 2088 LBS OF #16/20 PROP. MAXIMUM PRESSURE 3000 PSI AND ENDING PRESSURE 1760 PSI. STEPPED DOWN RATE @ END OF STAGE AND S/D. OBTAINED ISIP OF 1103 PSI W/F.G. @ (.66). PULSED FOR CLOSURE AND MONITORED WHTP. PUMP DATAFRAC W/50% HEC - 3% KCL GW @ 5 TO 15 BPM. CIRCULATED 49 BBLS OF GEL UP THE CSG AND INTO OPEN TOP.. VOLUME PUMPED 157 BBLS. MAXIMUM AND ENDING PRESSURE 1875 PSI. S/D AND OBTAINED ISIP OF 1085 PSI W/F.G. @ (.68). STOOD-BY AND MONITORED WHTP FOR CLOSURE. CLOSURE TIME +-25 MINS AND PAD VOLUME 10 BBLS. 18:45 FREEZE PROTECTED THE TBG W/23 BBLS DIESEL DOWN TO 2600' WHILE CIRCULATING RETURNS UP THE CSG. LEFT CSG WITH 144 BBLS OF DIESEL AND 23 BBLS OF GW. 19:30 RDFN ALL EQUIP AND SECURED WELL. TURNED OVER TO S/LINE FOR CONFIRMATION TAG. 15:00 CIRCULATED DIESEL DOWN THE CSG AND OUT TBG TO OPEN TOP. PUMPED 150 BBLS OF SLICK DIESEL. CSG AND TBG COMPLETELY DISPLACED W/DIESEL. 16:45 PUMP FRAC W/50% HEC - 3% KCL GW @ 5 TO 15 BPM. CIRCULATED 49 BBLS OF DIESEL UP THE CSG AND TO OPEN TOP. COMPLETED THRU FLUSH. SLURRY VOLUME PUMPED 483 BBLS. MAXIMUM AND ENDING PRESSURE 2000 PSI. PUMPED 74342 LBS OF #16/20 PROP. INJECTED 73759 LBS OF PROP IN THE FORM. W/ 10# PPA OF #16/20 @ PERF'S. PROPLOCK SERVICES EQUIPMENT FAILED AND WAS UNABLE TO COAT THE LAST 60 BBLS OF THE JOB. LEFT APP: 583 LBS OF PROP IN THE WELLBORE. S/D AND ALLOWED THE FRAC TO CLOSE. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-129(W4-6)) WELL 1 D-129 DATE 12/05/97 JOBSCOPE FRAC, FRAC SUPPORT DAILY WORK FRAC, FRAC SUPPORT DAY OPERATION COMPLy- I E SUCCESSFUL 4 YES YES Initial Tbg Press Final Tbg Press I Initial Inner Ann 900 PSI 800 PSII 0 PSI DAILY SUMMARY DUMP 2' SLUGGIT PILL; EST. TOP OF PLUG @ 5039' RKB. KEY PERSON HES-OBER Final Inner Ann 0 PSI JOB NUMBER 1129972015.4 UNIT NUMBER 7O175 SUPERVISOR FITZPATRICK Initial Outer Ann I Final Outer Ann 0 PSII 0 PSi TIME 15:00 16:45 LOG ENTRY UNABLE TO RIG UP ON 2T-12 DUE TO CHOKE HOUSE DIRECTLY IN FRONT OF WELL HOUSE, MO TO 1D-129 AS PER CWG SUPV. MI/TGSM- SLIPS, TRIPS & FALLS. MUSTER AREA. TIGHT RIG UP PARKER RIG & FRAC EQUIP. FOOTING ON TEMP SCAFFOLDING, WIDE W/L HOLE. 17:00 RU- HES & APC PUMP. 1.875" TS: RS,QC,5',KJ,5',KJ,LSS,QC. P/T LINES & EQUIP 2500 PSI. 17:30 RIH W/TEL ASSEM TO LOC TT @ 4874' SLM (4910' ELM-- 36' CF) TAG @ 5000' SLM (5036' RKB) EST. 2' ABOVE TARGET OF 5040' RKB, APC PUMP 2 BBLS (TBG 900 PSI < 2600 PSI) TAG @ 5003' SLM (5039' RKB) EST. 1' ABOVE TARGET- POOH, STANDBY AS PER STEVE BRADLY. 19:05 DIRECTED TO SET 1' SLUGGIT ON TOP OF SAND AS PER STEVE BRADLEY. 19:25 RIH W/FULL 11' X 2.5" DUMP BLR TO 5005' SLM (5041' RKB) RELEASE SLUGGIT-POOH BLR EMPTY. NOTE: VERY VERY SLOW RIH AFTER 2700' SLM. 20:30 RIH W/FULL 11' X 2.5" DUMP BLR TO 5004' SLM (5040' RKB) RELEASE SLUGGIT-POOH BLR EMPTY, EST. TOP OF SLUGGIT PILL @ 5039' RKB. 22:00 RDFN- TURN WELL OVER TO DSO, NOTIFY RANDY BLACK SLUGGIT PILL IN PLACE. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-129(W4-6)) WELL 1D-129 DATE 12/05/97 JOB SCOPE FRAC, FRAC SUPPORT DALLY WORK WEST SAK "B" SAND FRAC - 2ND A'FFEMPT DAY OPERATION COMPLETE I SUCCESSFUL I KEY PERSON 4 YES YES DS-GALLEGOS InitialTbgPress IFinalTbgPress IlnitiallnnerAnn IFinallnnerAnn 250 PSI 900 PSI 350 PSI 900 PSI DAILY SUMMARY JOB NUMBER 1129972015.4 UNIT NUMBER SUPERVISOR CHANEY Initial Outer Ann I Final Outer Ann 0 PSII 0 PSI "B" SAND FRAC COMPLETED THRU FLUSH. INJECTED 109044 LBS OF PROP (TREATED W/PROPLOK)IN THE FORM W/10# PPA OF #16/20 @ THE PERF'S. FREEZE PROTECTED WELL W/24 BBLS OF DIESEL DOWN TO 2700'.MAXIMUM PRESSURE 2700 PSI & F.G. (.69). TIME 07:00 10:00 10:45 11:50 LOG ENTRY MIRU DOWELL FRAC EQUIP, HES PROPLOK SKID, LRS HOT OIL UNIT, PROTECHNICS EQUIP, AND APC VAC TRUCKS. HELD SAFETY MEETING (21 PEOPLE ON LOCATION). PT'D BACKSIDE LINES TO 4000 PSI. PT'D HIGH PRESSURE LINES TO 4500 PSI. PUMP BREAKDOWN W/50% HEC - 3% KCL GW @ 20 TO 15 BPM. VOLUME PUMPED 215 BBLS. USED 2120 LBS OF #16/20 FOR SCOURING. MAXIMUM PRESSURE 2700 PSI AND ENDING PRESSURE 1750 PSI. STEPPED DOWN RATE @ LAST 10 BBLS OF STAGE. S/D AND OBTAINED ISIP OF 1143 PSI W/F.G. @ (.69). PULSED FOR CLOSURE AND MONITORED WHTP. PUMP DATAFRAC W/50% HEC - 3% KCL GW @ 5 TO 20 BPM. CIRCULATED 49 BBLS OF GW DOWN TBG AND UP CSG TO OPEN TOP. VOLUME PUMPED 157 BBLS. MAXIMUM AND ENDING PRESSURE 1750 PSI. S/D AND OBTAINED ISIP OF 1075 PSI W/F.G. @ (.69). STOOD-BY ND MONITORED WHTP FOR CLOSURE. CLOSURE TIME +-20 MINS, PAD VOLUME 10 BBLS. 12:30 CIRCULATED 120 BBLS OF DIESEL DOWN THE CSG AND TOOK RETURNS UP THE TBG AND TO OPEN TOP. TBG AND CSG FULLY DISPLACED W/DIESEL. 14:30 PUMP FRAC W/50% HEC - 3 % KCL GW @ 10 TO 15 BPM. CIRCULATED 48 BBLS OUT OF CSG AND INTO OPEN TOP. 2#PPA ->15 BBLS ->WHTP 1800 PSI ->CSG 1240 PSI ->15 BPM ->1100 LBS 16/20 W/PROPLOKRAMP ->354 BBLS ->WHTP 1875 PSI->CSG 1265 PSI ->15 BPM ->60000 LBS " W/PROPLOK8#PPA ->150 BBLS->WHTP 1800 PSI ->CSG 1275 PSI ->15 BPM ->36000 LBS" W/PROPLOK9#PPA -> 19 BBLS-> WHTP 1800 PSI ->CSG 1285 PSI ->15 BPM -> 5000 LBS" W/PROPLOK10#PPA ->19 BBLS->WHTP 1800 PSI ->CSG 1285 PSI -> 15 BPM-> 5000 LBS" W/PROPLOKFLUSH -> 23 BBLS OF GW & 24 BBLS OF DIESELPUMPED A TOTAL OF 109627 LBS OF #16/20 PROP. INJECTED 109044 LBS OF PROP IN THE FORMATION W/10# PPA OF #16/20 @ THE PERF'S. ADDED SB-124 RA TRACER INTO PROP. LEFT 583 LBS OF PROP IN THE WELLBORE. FREEZE PROTECTED WELL W/24 BBLS OF DIESEL DOWN TO 2700'. TIME LOG ENTRY 15:30 STARTED R/D. 16:30 R/D COMPLP_.. ~ E ALL EQUIPMENT LAYED DOWN UNTIL NEXT STAGE. WELL SECURED. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-129(W4-6)) WELL 1D-129 DATE 12/06/97 DAY 5 JOB SCOPE FRAC, FRAC SUPPORT DALLY WORK WEST SAK INITIAL "D" SAND FRAC OPERATION COMPLETE I SUCCESSFUL YES I YES Initial Tbg Press I Final Tbg Press Initial Inner Ann 400 PSII 650 PSI 500 PSI DALLY SUMMARY JOB NUMBER 1129972015.4 UNIT NUMBER KEY PERSON DS-GALLEGOS Final Inner Ann I Initial Outer Ann]1050 PSI O PSI SUPERVISOR CHANEY Final Outer Ann 0 PSI WEST SAK "D" SAND FRAC COMPLETED THRU FLUSH. SLURRY VOLUME 689 BBLS. INJECTED 102651 LBS OF PROP (TREATED W/PROPLOK) IN THE FORM W/10# PPA OF #16/20 @ THE PERF'S. FREEZE PROTECTED W/21 BBLS OF DIESEL DOWN TO 2400'. TIME LOG ENTRY 12:00 13:30 14:15 15:25 16:15 17:20 18:00 MIRU DOWELL FRAC EQUIP, HES PROPLOK EQUIP, PROTECHNICS EQUIP, LRS HOT OIL UNIT, & APC VAC TRUCKS. HELD SAFETY MEETING (22 ON LOCATION). PT'D BACKSIDE LINES TO 4000 PSI. PT'D HIGH PRESSURE LINES TO 4300 PSI. PUMP IMPULSE TEST W/DIESEL @ 20 BPM. VOLUME PUMPED 20 BBLS. MAX AND ENDING PRESSURE 3000 PSI. S/D AND OBTAINED ISIP OF 1208 PSI W/F.G. @ (.69). STOOD-BY AND MONITORED WHTP. PUMP BREAKDOWN W/50# HEC - 3% KCL @ 20 TO 15 BPM. VOLUME PUMPED 215 BBLS. USED 2011 LBS OF #16/20 FOR SCOURING. MAX PRESSURE 2900 PSI AND ENDING PRESSURE 1900 PSI. STEPPED DOWN RATE @END OF STAGE. S/D AND OBTAINED ISIP OF 1189 PSI W/F.G. @ (.69). PULSED FOR CLOSURE AND MONITORED WHTP. PUMP DATAFRAC W/50# HEC - 3% KCL @ 10 TO 15 BPM. CIRCULATED 49 BBLS OUT OF CSG. VOLUME PUMPED 129 BBLS. MAX AND ENDING PRESSURE 1950 PSI. S/D AND OBTAINED ISIP OF 1130 PSI W/F.G. @ (.70). STOOD-BY AND MONITORED WHTP FOR CLOSURE. +-28 MINS @ 880 PSI. PAD VOLUME 10 BBLS. CIRCULATED DOWN CSG AND UP TBG W/120 BBLS OF DIESEL. TBG AND CSG FULL OF DIESEL. PUMP FRAC W/50# HEC - 3% KCL @ 10 TO 15 BPM. CIRCULATED 46 BBLS OUT OF CSG. WEST SAK "D" SAND FRAC COMPLETED THRU FLUSH. SLURRY VOLUME 689 BBLS. PUMPED 103234 LBS OF #16/20 PROP. INJECTED 102651 LBS OF PROP (TREATED W/PROPLOK) IN THE FORM W/10# PPA OF #16/20 @ THE PERF'S. LEFT 583 LBS IN WELLBORE. ADDED SC-46 RA TRACER TO PROP. FREEZE PROTECTED W/21 BBLS OF DIESEL DOWN TO 2400'. 19:15 STARTED RD. 21:00 RDMO ALL FRAC EQUIP. WELL SECURED. ARCO Alaska, Inc. WELL JOB SCOPE 1 D-129 FRAC, FRAC SUPPORT DATE 12/06/97 DAY 5 KUPARUK RIVER UNIT WELL SERVICE REPORT K1 (1D-129(W4-6)) JOB NUMBER 1129972015.4 UNIT NUMBER SUPERVISOR BLACK DALLY WORK FRAC, FRAC SUPPORT OPERATION COMPLETE ISUCCESSFUL IKEYPERSON YES YES SWS-DECKERT InitialTbgPress IFinalTbgPress IlnitiallnnerAnn IFinallnnerAnn IlnitialOuterAnn I Final Outer Ann 800 PSI 500 PSI 800 PSI 500 PSI 0 PSI 0 PSI DAILY SUMMARY PERFORATED "D" SAND F/5010 - 5038' ELM W/2-1/8" EJ BH @ 4 SPF & 0 DEG PHASING / ORIENTATION TIME LOG ENTRY 21:45 MIRU SWS (DECKERT & CREW). MU TAG ASSEMBLY (CCL/WT/WT) TL-10'. PT BOPE TO 2000 PSI & RIH TO 4980' ELM. TIE IN W/11-30-97 SWS PERF RECORD. TAGGED BOTTOM @ 5038' ELM. WILL BE ABLE TO PERFORATE. POOH F/1ST GUN RUN. 00:00 AT SURFACE. OBTAIN RADIO SILENCE. MU GUN ASSEMBLY #1 (15'- 2-1/8" EJ/CCL/HD) TL-25'. PT & RIH TO 4980' ELM. TIE IN & PERFORATE F/5023 - 5038' ELM W/2-1/8" EJ BH @ 4 SPF & O DEG PHASED / ORIENTED. GOOD SHOT INDICATION. LOG OFF & POOH. 02:30 AT SURFACE. ALL SHOTS FIRED. MU GUN ASSEMBLY #2 (13' - 2-1/8" EJ/CCL/HD) TL -23'. PT & RIH. TIE IN & PERFORATE F/5010 - 5023' ELM W/SAME GUNS AS ABOVE. LOG OFF & POOH. 04:45 AT SURFACE. ALL SHOTS FIRED. BEGIN RD & RELEASE APC. 06:00 RD COMPLETE. TURN OVER TO PRODUCTION F/UPCOMING FRAC. ARCO ALASKA, 1D129 (J3) MEASURED DEPTH 0.00 121.00 201.73 291.78 380.44 471.96 563.72 653.33 745.02 836.55 925.50 1015.61 1106.60 1197.70 1292.87 1383.32 1576.45 1768.30 1958.62 2146.26 2338,47 2526.93 2718.72 2908.35 3099.44 3287.87 3574.40 3761.34 3856.60 3950.51 4046.37 4141.29 4234.77 4330.10 4424.39 4519.48 4613.53 4707.80 4746.20 4801.92 INC. SPERRY-SUN DRILLING SERVICES ANGLE DIRECTION VERTICAL LATITUDE DEPARTURE DEG DEG DEPTH FEET FEET 0.00 O.0O 0.55 1.75 6.82 11.90 17.83 22.57 27.85 33.57 40.26 45.12 49.37 51.65 54.06 55.48 55.41 55.23 55.91 58.37 56.46 56.16 55.01 55.69 56.57 54.81 55.21 55.09 50.84 49.86 44.78 39.12 33.94 27.43 .20.98 15.31 10.67 3.72 1.78 1.43 0.00 0.00 38.38 273.68 264.86 255.67 244.24 231.31 224.78 221.06 217.49 218.42 216.27 218.77 219.55 221.00 221.35 221.89 221.55 221.09 220.22 220.95 220.81 220.80 221.01 220.44 221.22 220.69 219.48 220.55 220.72 220.10 219.65 220.62 221.18 217.04 218.48 223.47 245.26 251.07 0.00 0.00 121.00 0.00 201.73 0.30 N 291..77 0.73 N 380.15 0.35 N 470.43 2.48 S 559.09 10.93 S 643.21 27,66 S 726.15 53.89 S 804.82 88.18 S 875.91 129.58 S 942.12 '177.72 S 1003.88 230.85 S 1061.82 286.58 S 1119.28 345.39 S 1171.46 401.75 S 1281.00 521.48 S 1390.16 639.42 S 1497.77 756.59 S 1599.57 874.96 S 1703.09 997.81 S 1807.63 1116.90 S 1916.02 1236.52 S 2023.84 1354.60 S 2130.33 1474.52 S 2236.54 1592.46 S 2400.85 1770.07 S 2507.67 1885.93 S 2565.03 1944.08 S 2624.96 1999.46 S 2689.92 2052.92 S 2760.49 2101.21 S 2835.58 2143.89 S 2917.52 2181.08 S 3003.47 2210.30 S 3093.80 2233.16 S 3185.42 2249.89 S 3278.89 2258.95 S 3317.24 2260.11 S 3372.94 2260.70 S Page 1 0.00 0.00 0.24 E 0.86 W 7.46 W 11/22/97 AK-MM-80020 VERTICAL DOG SECTION LEG 0.00 0.00 0.00 0.00 -0.39 0.68 0.00 2.35 4.56 5.75 22.03 W 16.14 5.77 43.87 W 36.71 7.18 69.67 W 66.16 7.24 98.52 W 104.82 6.50 130.23 W 151.48 6.58 163.92 W 204.85 7.90 201.50 W 265.88 5.44 241.98 W 332.57 4.98 284.81 W 402.78 3.28 332.72 W 478.62 2.62 380.49 W 485.20 W 589.99 W 694.46 W 798.51 W 904.03 W 1006.04 W 1109.59 W 1211.53 W 1315.43 W 1416.97 W 1570.45 W 1671.01 W 1719.98 W 1766.46 W 1812.34 W 1853.47 W 1889.14 W 1920.45 W 1945.73 W 1964.52 W 1977.42 W 1984.97 W 1986.37 W 1987.81 W 552.50 2.04 711.54 0.15 869.26 0.25 1026.19 0.39 1183.77 1.33 1345.71 1.06 1502.52 0.36 1660.73 0.60 1816.72 0.36 1975.37 0.47 2131.00 0.97 2365.73 0.26 2519.13 0.24 2595.15 4.58 2667.46 1.36 2737.90 5.30 2801.33 5.98 2856.95 5.55 2905.57 6.85 2944.21 6.84 2973.79 6.11 2994.90 4.95 3006.69 7.40 3008.47 5.65 3009.86 0.69 SPERRY-SUN DRILLING'SERVICES Page 2 ARCO ALASKA, INC. 1D129 (J3) 11/22/97 AK-MM-80020 MEASURED ANGLE DIRECTION DEPTH DEG DEG VERTICAL LATITUDE DEPTH FEET DEPARTURE VERTICAL DOG FEET SECTION LEG 4896.16 1.33 257.44 3467.15 2261.31 S 5085.44 1.27 276.83 3656.39 2261.54 S 5275.44 1.10 284.68 3846.35 2260.83 S 5398.58 1.04 284.61 3969..46 2260.25 S 5462.00 1.04 284.61 4032.87 2259.96 S 1989.99 W 3011.74 0.19 1994.22 W 3014.65 0.23 1998.07 W 3016.60 0.12 2000.30 W 3017.59 0.05 2001.41 W 3018.09 0.00 THE DOGLEG SEVERITY IS IN DEGREES PER 100.00 FEET THE VERTICAL SECTION WAS COMPUTED ALONG 220.30° (TRUE) BASED UPON MINIMUM CURVATURE TYPE CALCULATIONS. THE BOTTOM HOLE DISPLACEMENT IS 3018.78 FEET, IN THE DIRECTION OF 221.53° (TRUE) SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 ARCO ALASKA, INC WS / !D-129 500292283000 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/18/97 DATE OF SURVEY: 112297 MWD SURVEY JOB NUMBER: AKMM80020 KELLY BUSHING ELEV. = 111.50 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. .00 .00 -111.50 0 0 N .00 E .00 .00N 121.00 121.00 9.50 0 0 N .00 E .00 .0ON 201.73 201.73 90.23 0 33 N 38.38 E .68 .30N 291.78 291.76 180.26 1 45 N 86.32 W 2.35 .73N 380.44 380.14 268.64 6 49 S 84.86 W 5..75 .35N .00E .00 .00E .00 .24E -.39 .86W .00 7.46W 4.56 471.96 470.42 358.92 11 53 S 75.67 W 5.77 563.72 559.08 447.58 17 49 S 64.24 W 7.18 653.33 643.20 531.70 22 34 S 51.31 W 7.24 745.02 726.14 614.64 27 51 S 44.78 W 6.50 836.55 804.81 693.31 33 34 S 41.06 W 6.58 2.48S 22.03W 16.14 10.93S 43.87W 36.71 27.66S 69.67W 66.16 53.89S 98.52W 104.82 88.18S 130.23W 151.48 925.50 875.90 764.40 40 15 S 37.49 W 7.90 1015.61 942.11 830.61 45 7 S 38.42 W 5.44 1106.60 1003.87 892.37 49 22 S 36.27 W 4.98 1197.70 1061.81 950.31 51 39 S 38.77 W 3.28 1292.87 1119.26 1007.76 54 3 S 39.55 W 2.62 129.58S 163.92W 204.85 177.72S 201.50W 265.88 230.85S 241.98W 332.57 286.58S 284.81W 402.78 345.38S 332.71W 478.61 1383.32 1171.44 1059.94 55 28 S 41.00 W 2.04 1576.45 1280.98 1169.48 55 24 S 41.35 W .15 1768.30 1390.14 1278.64 55 13 S 41.'89 W .25 1958.62 1497.74 1386.24 55 54 S 41.55 W .39 2146.26 1599.53 1488.03 58 22 S 41.09 W 1.33 401.74S 380.47W 552.48 521.46S 485.19W 711.52 639.40S 589.98W 869.24 756.57S 694.44W 1026.17 874.92S 798.48W 1183.73 2338.47 1703.03 1591.53 56 27 S 40.22 W 1.06 997.76S 903.98W 1345.65 2526.93 1807.57 1696.07 56 9 S 40.95 W .36 1116.85S 1006.00W 1502.45 2718.72 1915.96 1804.46 55 0 S 40.81 W .60 1236.47S 1109.54W 1660.66 2908.35 2023.78 1912.28 55 41 S 40.80 W .36 1354.55S 1211.48W 1816.65 3099.44 2130.27 2018.77 56 34 S 41.01 W .47 1474.46S 1315.38W 1975.29 3287.87 2236.47 2124.97 54 48 S 40.44 W .97 1592.39S 1416.91W 2130.91 3574.40 2400.77 2289.27 55 12 S 41.22 W .26 1770.00S 1570.39W 2365.64 3761.34 2507.60 2396.10 55 5 S 40.69 W .24 1885.86S 1670.95W 2519.04 3856.60 2564.96 2453.46 50 50 S 39.48 W 4.58 1944.01S 1719.92W 2595.06 3950.51 2624.88 2513.38 49 51 S 40.55 W 1.36 1999.39S 1766.40W 2667.36 4046.37 2689.84 2578.34 44 46 S 40.72 W 5.30 2052.85S 1812.28W 2737.81 4141.29 2760.41 2648.91 39 7 S 40.10 W 5.98 2101.13S 1853.41W 2801.23 4234.77 2835.50 2724.00 33 56 S 39.65 W 5.55 2143.81S 1889.08W 2856.85 4330.10 2917.44 2805.94 27 25 S 40.62 W 6.85 2181.01S 1920.39W 2905.48 4424.39 3003.40 2891.90 20 58 S 41.18 W 6.84 2210.23S 1945.67W 2944.11 ORIOlNAL SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA, INC WS / 1D-129 500292283000 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/18/97 DATE OF SURVEY: 112297 MWD SURVEY JOB NUMBER: AKMM80020 KELLY BUSHING ELEV. = 111.50 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 4519.48 3093.72 2982.22 15 18 S 37.04 W 6.11 2233.08S 1964.46W 2973.69 4613.53 3185.34 3073.84 10 40 S 38.48 W 4.95 2249.82S 1977.36W' 2994.80 4707.80 3278.81 3167.31 3 43 S 43.47 W 7.40 2258.88S 1984.90W 3006.59 4746.20 3317.16 3205.66 1 46 S 65.26 W 5.65 2260.04S 1986.30W 3008.38 4801.92 3372.86 3261.36 1 25 S 71.07 W .69 2260.62S 1987.75W 3009.76 4896.16 3467.07 3355.57 1 19 S 77.44 W .19 2261.24S 19'89.93W 3011.64 5085.44 3656.30 3544.80 1 16 N 83.17 W .23 2261.47S 1994.15W 3014.55 5275.44 3846.26 3734.76 1 6 N 75.'32 W .12 2260.76S 1998.01W 3016.50 5398.58 3969.38 3857.88 1 2 N 75.39 W .05 2260.18S 2000.23W 3017.49 5462.00 4032.79 3921.29 1 2 N 75.39 W .00 2259.89S 2001.35W 3017.99 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 3018.69 FEET AT SOUTH 41 DEG. 31 MIN. WEST AT MD = 5462 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 220.30 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 5,462.00' MD SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA, INC WS / 1D-129 500292283000 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/18/97 DATE OF SURVEY: 112297 JOB NUMBER: AKMM80020 KELLY BUSHING ELEV. = 111.50 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .00 .00 -111.50 1000.00 931.02 819.52 2000.00 1520.94 1409.44 3000.00 2075.44 1963.94 4000.00 2657.64 2546.14 .00 N .00 E 169.11 S 194.69 W 782.22 S 717.17 W 1411.85 S 1260.95 W 2027.55 S 1790.53 W .00 68.98 68.98 479.06 410.08 924.56 445.50 1342.36 417.80 5000.00 3570.89 3459.39 5462.00 4032.79 3921.29 2261.70 S 1992.27 W 2259.89 S 2001.35 W 1429.11 86.76 1429.21 .09 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC WS / 1D-129 500292283000 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/18/97 DATE OF SURVEY: 112297 JOB NUMBER: AKMM80020 KELLY BUSHING ELEV. = 111.50 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 111.50 211.50 311.54 412 09 514 18 619 24 728 56 844 64 973 11 .00 -111.50 111.50 .00 211.50 100.00 311.50 200.00 411.50 300.00 511.50 400.00 611.50 500.00 711.50 600.00 811.50 700.00 911.50 800.00 5 20 48 91 154 00 N .00 E .00 00 N .00 E .00 .00 38 N .30 E .00 .00 73 N 1.71 W .04 .04 23 S 11.70 W .59 .55 47 S 31.24 W 2.68 2.08 18 S 59.61 W 7.74 5.06 61 S 93.16 W 17.06 9.32 63 S' 133.19 W 33.14 16.08 56 S 183.27 W 61.61 28.47 1118.36 1279.64 1454.02 1630.21 1805.76 1011.50 900.00 1111.50 1000.00 1211.50 1100.00 1311.50 1200.00 1411.50 1300.00 238.04 S 247.30 W 337.13 S 325.90 W 445.70 S 418.69 W 554.69 S 514.43 W 662.31 S 610.52 W 106.86 45.25 168.14 61.29 242.52 74.37 318.71 76.20 394.26 75.54 1983.16 2169.08 2353.80 2533.99 2710.94 1511.50 1400.00 1611.50 1500.00 1711.50 1600.00 1811.50 1700.00 1911.50 1800.00 771.78 S 707.92 W 889.57 S 811.25 W 1007.52 S 912.23 W 1121.27 S 1009.84 W 1231.64 S 1105.38 W 471.66 77.40 557.58 85.92 642.30 84.71 722.49 80.19 799.44 76.95 2886.57 3065.37 3244.54 3418.07 3593.20 2011.50 1900.00 2111.50 2000.00 2211.50 2100.00 2311.50 2200.00 2411.50 2300.00 1340.93 S 1199.73 W 1453.00 S 1296.72 W 1565.44 S 1393.95 W 1673.37 S 1485.93 W 1781.61 S 1580.56 W 875.07 75.63 953.87 78.80 1033.04 79.17 1106.57 73.52 1181.70 75.13 3768.08 3929.75 4076.39 4205.53 4323.38 2511.50 2400.00 2611.50 2500.00 2711.50 2600.00 2811.50 2700.00 2911.50 2800.00 1890.04 S 1674.52 W 1987.33 S 1756.08 W 2068.63 S 1825.81 W 2130.97 S 1878.40 W 2178.62 S 1918.34 W 1256.58 74.88 1318.25 61.67 1364.89 46.64 1394.03 29.14 1411.88 17.85 4433.04 4537.87 4640.07 4740.53 3011.50 2900.00 3111.50 3000.00 3211.50 3100.00 3311.50 3200.00 2212.51 S 1947.64 W 2236.83 S 1967.29 W 2253.30 S 1980.16 W 2259.96 S 1986.14 W 1421.54 9.66 1426.37 4.83 1428.57 2.20 1429.03 .47 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC WS / 1D-129 500292283000 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/18/97 DATE OF SURVEY: 112297 JOB NUMBER: AKMM80020 KELLY BUSHING ELEV. = 111.50 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 840.57 3411.50 3300.00 2260.93 S 1988.66 W 1429.07 .04 940.60 3511.50 3400.00 2261.47 S 1990.93 W 1429.10 .03 040.62 3611.50 3500.00 2261.59 S 1993.17 W 1429.12 .03 140.65 3711.50 3600.00 2261.33 S 1995.37 W 1429.15 .02 240.67 3811.50 3700.00 2260.93 S 1997.36 W 1429.17 .02 340.69 3911.50 3800.00 2260.44 S 1999.22 W 1429.19 .02 440.71 4011.50 3900.00 2259.98 S 2000.97 W 1429.21 .02 462.00 4032.79 3921.29 2259.89 S 2001.35 W 1429.21 .00 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS ,, 0 Ft I I--I--I I~ G SI~:: FI~I C E S 19-Dec-97 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-129 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD n/a' MD 5,462.00' 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 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.' Loft Taylor 3001 Porcupine· Dr. Anchorage, Alaska 99501 December 23, 1997 RE: MWD Formation Evaluation Logs 1D-129, AK-MM-80020 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1D-129: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22830-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22830-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries. Inc. Company 0 F! I I_ll IM CS SEll:lUll--ES WELL LOG TRANSMYFTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs December 23, 1997 1D-129, AK-MM-80020 The technical data listed below is being submitted herewith. Please address any problems or concems to the attention of~ Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. APl#: 50-029-22830-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company AOGCC Geological Materials Inventory 97-213 PERMIT ARCO Log Data Sent 8212 ,j SPERRY MPT/GR/EWR4 12/23/1997 DGR/EWR4-MD ~ 121-5462 12/23/1997 DGR/EWR4-TVD j 1212,033 12/23/1997 MWD SRVY tq~SPERRY 0-5462. 2/5/1998 MWD SRVY ~~SPERRY 0-5462. 12/19/1997 ~7 Completion Date.__!_~"/~_~/_~_~ .... Daily wellops ]j~..~&/~_~_ Are dry ditch samples required? ~ yes ~ And received? ~o Was the well cored? C~Z~ yes ~ no Are tests required? Well is in compliance Comments Received 12/24/1997 12/24/1997 12/24/1997 2/6/1998 12/24/1997 Box Analysis description recei~v.e 9..f[2~ Received? [~-~ ~o-- Wednesday, October 13, 1999 Page l ofl t" STATE OF ALASKA i ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown __ Pull tubing Alter casing Stimulate Plugging Perforate X Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 391' FNL, 600' FEL, Sec. 23, T11N, R10E, UM At top of productive interval 2132' FSL, 2145' FWL, Sec. 23, T11N, R10E, UM At effective depth 2629' FSL, 2601' FWL, Sec. 23, T11N, R10E, UM At total depth 2629' FSL, 2601' FEL, Sec. 23, T11N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 5462 feet 4033 feet 6. Datum elevation (DF or KB) RKB 112 7. Unit or Property name Kuparuk River Unit 8. Well number 1 D-129 feet 9. Permit number/approval number 97-213 10. APl number 50-029-22830-00 11. Field/Pool Kuparuk River Field/West Sak Pool Plugs (measured) None Effective depth: measured 5 4 3 2 true vertical 4003 feet feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 5412' 7-5/8" measured 5010'-5038' true vertical 3541 '-3569' Cemented 200 cu ft -Approx 580 Sx AS III & 460 Sx Class G Tubing (size, grade, and measured depth) 2-7/8", 6.5#/ft., L-80 @ 4929' Packers and SSSV (type and measured depth) Pkr: None, ESP seal section @ 4907'; SSSV: None 13. Stimulation or cement squeeze summary Perforate 'D' sand on 12/6/97. Intervals treated (measured) 5010'-5038' Treatment description including volumes used and final pressure 14. Measured depth 121' 5453' True vertical depth 121' 4024' RECEIVED Alaska Oil & Gas Cons. Comm[ssio~ Anchorage Perforated using 2-1/8" EJ guns w/BH charges @ 4 SPF, fp was 800 psi. Representative Daily Average production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 800 800 Subsequent to operation 319 188 10 130 126 15. Attachments Morning Report X 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 ~ Form 10-4~,/Re'~6/15/88 , ~ J&K. Title Wells Superintendent Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(D-129(W4-6)) WELL JOB SCOPE JOB NUMBER 1D-129 FRAC, FRAC SUPPORT 1129972015.4 DATE DAILY WORK ' 'UNIT NUMBER 12/06/97 FRAC, FRAC SUPPORT DAY OPERATION cOMPLETE I SUCCESSFUL KEY PERSON 'SUPERVISOR 5 (~ Yes O NoI (~) Yes O No SWS-DECKERT BLACK FIELD AFC~ CC.,fl DAILY COST ACCUM ~OST Signed ESTIMATE AK9045 18WSTFTSC $1 3,465 $731,909 Initial Tb.a Press Final Tb.q Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 800 PSI 500 PSI 800 PSI 50.0 PSII 0 PSII 0 PSI DALLY SUMMARY PERFORATED "D" SAND F/5010 - 5038' ELM W/2-1/8" EJ BH @ 4 SPF & 0 DEG PHASING / ORIENTATION TIME LOG ENTRY 21:45 MIRU SWS (DECKERT & CREW). MU TAG ASSEMBLY (CCL/WT/WT) TL-10'. PT BOPE TO 2000 PSI & RIH TO 4980' ELM. TIE IN W/11-30-97 SWS PERF RECORD. TAGGED BOq-rOM @ 5038' ELM. WILL BE ABLE TO PERFORATE. POOH F/1ST GUN RUN. 00:00 AT SURFACE. OBTAIN RADIO SILENCE. MU GUN ASSEMBLY #1 (15' - 2-1/8" EJ/CCL/HD) TL-25'. PT & RIH TO 4980' ELM. TIE IN & PERFORATE F/5023 - 5038' ELM W/2-1/8" EJ BH @ 4 SPF & O DEG PHASED / ORIENTED. GOOD SHOT INDICATION. LOG OFF & POOH. 02:30 AT SURFACE. ALL SHOTS FIRED. MU GUN ASSEMBLY #2 (13' - 2-1/8" EJ/CCL/HD) TL -23'. PT & RIH. TIE IN & PERFORATE F/5010 - 5023' ELM W/SAME GUNS AS ABOVE. LOG OFF & POOH. 04:45 AT SURFACE. ALL SHOTS FIRED. BEGIN RD & RELEASE APC. 06:00 RD COMPLETE. TURN OVER TO PRODUCTION F/UPCOMING FRAC. SERVICE CEMPANY - SERVICE DAILY COST ACCUM TOTAL $0..00 $15.00 APC $8,300.00 $40,700.00 DIESEL $750.00 .$6,215.00 , ,, , DOWELL $88,523.65 $369,260.70 HALLIBURTON .. $58,700.25 ...... $208,709.09 LITTLE RED $2,580.00 $12,735.00 MI $! 1,655.57 $11,655.57 MI FLUIDS $0.00 . $.30,529.46 P ROTECHNICS $5,120.00 $24,120.00 SCHLUMBERGER $12,165.00 $27,970.00 TOTAL FIELD ESTIMATE $187,794.47 $731,909.81 STATE OF ALASKA ~"' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown __ Stimulate X Pull tubing Alter casing Repair well 2. Name of Operator 15. Type of Well: Development X ARCO Alaska, Inc. Exploratory _ 3. Address Stratigraphic _ P. O. Box 100360, Anchorage, AK 99510 Service i4. Location of well at surface 391' FNL, 600' FEL, Sec. 23, T11N, R10E, UM At top of productive interval 2132' FSL, 2145' FWL, Sec. 23, T11N, R10E, UM At effective depth 2629' FSL, 2601' FWL, Sec. 23, T11N, R10E, UM At total depth 2629' FSL, 2601' FEL, Sec. 23, T11N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 5462 feet 4033 feet Plugging Perforate Other 6. Datum elevation (DF or KB) RKB 112 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1 D-129 9. Permit number/approval number 97-213 10. APl number 50-029-22830-00 11. Field/Pool Kuparuk River Field/West Sak Pool Plugs (measured) None Effective depth: measured 5 4 3 2 true vertical 4 0 0 3 feet feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 5412' 7-5/8" measured 5010'-5038' true vertical 3541 '-3569' Cemented 200 cu ft -Approx 580 Sx AS III & 460 Sx Class G Tubing (size, grade, and measured depth) 2-7/8", 6.5#/ft., L-80 @ 4929' Packers and SSSV (type and measured depth) Pkr: None, ESP seal section @ 4907'; SSSV: None Measured depth 121' 5453' RECEIVED JAN 29 1998 True vertical depth 121' 4024' ORIGINAL 13. Stimulation or cement squeeze summary Fracture stimulate 'D' sand on 12/6/97. Alaska0il & Gas Cons. ComlllJssJ0.11 Intervals treated (measured) Anchorage 5010'-5038' Treatment description including volumes used and final pressure Pumped 102.7 MIbs of 16/20 ceramic proppant into the formation, fp was 2165 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 800 800 Subsequent to operation 319 188 10 130 126 15. Attachments Morning Report X 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. .~igned Title Wells Superintendent Date Form 10- 0,~...4/R(~,J 06/15/88 SUBMIT IN DUPLICATE TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 19. 1997 Mike Zanghi Drilling Superintendent ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: West Sak 1 D-129(J3) ARCO Alaska. Inc. Permit No: 97-213 Sur. Loc.: 391'FNL. 600'FEL, Sec. 23, TI 1N, RIOE, UM Btmhole Loc: 2597'FSL. 2544'FEL. Sec. 23, TI IN, R10E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced xveil. The permit to drill does not exempt you from obtaining additional permits required bv law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North r David W. Johnston Chairman BY ORDER OF THE COMMISSION dlf/enclosures cc; Department of Fish & Game. Habitat Section w/o encl. Department of Envinornment Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill I lb Type of Well Exploratory E] Stratigraphic Test D Development Oil X Re-Entry DeepenI Service D Development Gas D single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 70' feet Kuparuk River Field 3. Address 6. Property Designation West Sak Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25650, ALK 468 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 391' FNL, 600' FEL, Sec. 23, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 2597' FSL, 2544' FEL, Sec. 23, T11 N, R10E, UM West Sak 1 D-129 (J3) #U-630610 At total depth 9. Approximate spud date Amount 2597' FSL, 2544' FEL, Sec. 23, T11 N, R10E, UM 11/18/97 $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-06 5574' MD 2597' @ TD feet 27.1' @ 360' feet 2560 4137' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 56.1 ° Maximum surface 1378 psig At total depth 1811 psig (TVD) 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casin9 Wei~lht Grade Couplin~l Length MD TVD MD TVD (include sta~le data) 24" 16" 62.5# H-40 Weld 77' 41' 41' 118' 118' +200 CF 9.875" 7.625" 29.7# L-80 BTC MOD 5533' 41' 41' 5574' 4137' 580 Sx Arcticset III & 325 Sx Class G & 60 sx ASI 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 Intermediate Production Liner i ..... ", "~ ,~'~ :..., i,i ~ ~, Perforation depth: measured true vertical ,!~,~!as~'a, Oil & ~'iss, ~}o?,s 20. Attachments Filing fee X Property plat [] BOP Sketch [] Diverter Sketch X Drilling program X Drilling 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 to the best of my knowledge Signed~-~_.,~~ F'~f., //~,~.,~' Z,R/,,tGI. I...T Title Drill Site Develop. Supv. Date Commission Use Only Number I APl number I Approval date F71 See cover letter for Permi/ ,~ ~--,//~.~ 50- ~ 2..~ ~ ~_ ~:',~<:~ /,/' · -- --" .-- other requirements Conditions of approval Samples required [-1 Yes r'~ No Mud log required r~ Yes J~ No Hydrogen sulfidemeasures ~Yos [~No Directional survey required ~::~¥es [~ No Required workingpressureforBOPE [~M r-13M E~ 5M E~ 1OM E~ 15M Other: 0riginal Sig, neci By' ' by order of //.._,/~,.,. ~,7~ Approved by David W. Johnston Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate ARCO Alaska, Inc. KUPARUK RIVER UNIT ,4. WELL SERVICE REPORT ~' K1(D-129(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-129 FRAC, FRAC SUPPORT 1129972015.4 DATE DAILY WORK UNIT NUMBER 12/06/97 WEST SAK INITIAL "D" SAND FRAC DAY 'bPERATION COMPLETE I ~UCCESSFLJL KEY PERSON SUPERVISOR 5 (~) Yes O NoI (~ Yes (~ No DS-GALLEGOS CHANEY FIELD AFC~ ~ DALLY COST ACCUM COST Signed ESTIMATE AK9045 18WSTF7SC $1 73,021 $731,909 _ Initial Tb.q Press Final Tb.q Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 400 PSI 650 PSI I 500 PSI 1050 PSII 0 PSII 0 PSI DALLY SUMMARY IWEST SAK "D" SAND FRAC COMPLETED THRU FLUSH. SLURRY VOLUME 689 BBLS. INJECTED 102651 LBS OF PROP (TREATED W/ PROPLOK) IN THE FORM W/10# PPA OF #16/20 @ THE PERF'S. FREEZE PROTECTED W/21 BBLS OF DIESEL DOWN TO 2400'. TIME 12:00 13:30 14:15 15:25 LOG ENTRY MIRU DOWELL FRAC EQUIP, HES PROPLOK EQUIP, PROTECHNICS EQUIP, LRS HOT OIL UNIT, & APC VAC TRUCKS. HELD SAFETY MEETING (22 ON LOCATION). PT'D BACKSIDE LINES TO 4000 PSI. PT'D HIGH PRESSURE LINES TO 4300 PSI. PUMP IMPULSE TEST W/DIESEL @ 20 BPM. VOLUME PUMPED 20 BBLS. MAX AND ENDING PRESSURE 3000 PSI. S/D AND OBTAINED ISIP OF 1208 PSI W/F.G. @ (.69). STOOD-BY AND MONITORED WHTP. PUMP BREAKDOWN W/50# HEC - 3% KCL @ 20 TO 15 BPM. VOLUME PUMPED 215 BBLS. USED 2011 LBS OF #16/20 FOR SCOURING. MAX PRESSURE 2900 PSI AND ENDING PRESSURE 1900 PSI. STEPPED DOWN RATE @END OF STAGE. S/D AND OBTAINED ISIP OF 1189 PSI W/F.G. @ (.69). PULSED FOR CLOSURE AND MONITORED WHTP. 16:15 PUMP DATAFRAC W/50# HEC - 3% KCL @ 10 TO 15 BPM. CIRCULATED 49 BBLS OUT OF CSG. VOLUME PUMPED 129 BBLS. MAX AND ENDING PRESSURE 1950 PSI. S/D AND OBTAINED ISIP OF 1130 PSI W/F.G. @ (.70). STOOD-BY AND MONITORED WHTP FOR CLOSURE. +-28 MINS @ 880 PSI. PAD VOLUME 10 BBLS. 17:20 CIRCULATED DOWN CSG AND UP TBG W/120 BBLS OF DIESEL. TBG AND CSG FULL OF DIESEL. 18:00 19:15 21:00 PUMP FRAC W/50# HEC - 3% KCL @ 10 TO 15 BPM. CIRCULATED 46 BBLS OUT OF CSG. WEST SAK "D" SAND FRAC COMPLETED THRU FLUSH. SLURRY VOLUME 689 BBLS. PUMPED 103234 LBS OF #16/20 PROP. INJECTED 102651 LBS OF PROP (TREATED W/PROPLOK) IN THE FORM W/10# PPA OF #16/20 @ THE PERF'S. LEFT 583 LBS IN WELLBORE. ADDED SC-46 RA TRACER TO PROP. FREEZE PROTECTED W/21 BBLS OF DIESEL DOWN TO 2400'. STARTED RD. RDMO ALL FRAC EQUIP. WELL SECURED. SERVICE cOMPANY. SERVICE DAILY ~6ST ACCUM TOTAL ' ' ' $0.00 $15.0C APC $8,300.00 $40,700.0C , , DIESEL $750.00 $6,215.0C DOWELL $88,523.65 $369,260.7C ,, HALLIBURTON $58,700.25 $208,709.0c. LITTLE RED ~ ,-., , .-~, ~ · · · $2,580.00 .... $12,735.0C.. MI ! ~ ~'~ I [~ i ~\1 L~ ! $11,655.57 $.1.1,655.57 ..... MI FLUIDS "~ ' ~" '~ I I ~11 t I,, $0.00 $30,529.4(~ ,,, PROTECHNICS $5,120.00 $24,120.0C SCHLUMBERGER $12,165.00 $27,970.0£ TOTAL FIELD ESTIMATE $1 87,794.47 $731,909.81 Drill and Case Plan for West Sak 1D-129 (J3) Frac-for-Sand Control Producer General Procedure: o 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. . 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. . Run and cement 7-5/8" 29.7# L80 BTC casing to surface, displace cement with mud. Perform stage job and top job as required. NOTE: Stage (DV) tool to be installed +/- 200 ft TVD below the base of permafrost interval. . Nipple down diverter and install wellhead. Nipple up BOP stack and pressure test same to 3,000 psi. . Pick up 6-3/4" mill tooth bit with 3-1/2" drill pipe and collars. Trip in and drill out stage collar. Clean out to PBTD. ! Shut in BOP's and pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results. . Swap well over to non-freezing completion brine. Filter brine to desired level. Trip out. 10. Pick up 3-1/2" tubing deadstring and TIH. Circulate filtered brine to desired level. 11. Hang tubing in wellhead, install back pressure valve, and nipple down BOP stack. Nipple up and pressure test production tree. Secure well. 12. Release rig. TAB, 11/10/97, Rev.3 Page 1 Completion Plan for West Sak 1D-129 (J3) Frac-for-Sand Control Producer Four-Stage, Frac-for-Sand Control Completion (Off Rig Fracs) General Procedure: Well Preparation , 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. Stage 1 , Rig up thru-tubing perf guns for Stage 1 frac job which includes the West Sak A2 sands. RIH with perf 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 perfs. Use CTU as required to jet sand plug top to desired PBTD. Stage 2 , Rig up thru-tubing perf guns for Stage 2 frac job which 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. i Page 2 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 Sak A4 and B sands. RIH with perf guns, and position guns on depth. 14. Perforate Stage 3 overbalanced, and POOH with E-line. 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. Page 3 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. 26. Pull tubing hanger and circulate 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. Change rams to 2- 7/8" and pressure test same unless VBR's are available. 31. Pick up Centrilift PCP-ESP (progressive cavity ESP) on 2-7/8" production tubing. 32. Run in well with PCP-ESP pump 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. 34. 35. Position PCP-ESP at desired depth, set tubing hanger and run electrical penetrators through same. 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. TAB, 11/10/97, Rev.3 Page 4 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS West Sak 1D-129 (J3) Drillinq Fluid Type Extended Bentonite Slurry Drillinq 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 9.6-10.0 ppg 35 20-35 5-15 10-35 5-10 8.0-9.5 8-12% Drillinq 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 150-200 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 combination surface / production casing string will be run at total depth (TD). This combination surface / production casing will be cemented to surface using a stage (DV) collar. The stage collar will be placed approximately 200 feet TVD below the base of the permafrost interval. Page 1 MASP (Maximum Anticipated Surface Pressure): Since a separate string of surface casing is not planned for the West Sak 1D-129 (J3) 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. Based on actual well test data from the nearby WS1-01 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 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 3,527' 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 WSI-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 = (3,937 fi)(0.46 - 0.11 psi/fi) = 1378 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 BOP stack will be installed and tested to 3,000 psi. The stage collar will then be drilled out and the well cleaned out to PBTD. At that time, the casing will be pressure tested for 30 minutes at a surface pressure of 3,000 psi as well. The 7-5/8" 29.7# LB0 BTC-MOD casing to be used has a burst rating of 6,890 psi; 70 % of this burst rating is 4,823 psi. A deadstring will then be run in the well in preparation for off-rig perforating and fracture stimulation treatments. A completion rig would then return to the well following fracture stimulation work to remove the deadstring, and to install the ESP pump, power cable, heat trace, and production tubing. Page 2 Drillinc~ Area Risks: Drilling risks in the West Sak 1D-129 (J3) 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. ARCO has drilled through the West Sak formation many times in nearby Kuparuk wells. For this reason, AAI requests that the requirements listed in 20 AAC 25.033 (e) and 20 AAC 25.061 (a) (pertaining to predicted overpressured strata and seismic refraction / reflection analysis, respectively) be waived for the drilling of West Sak 1D-129 (J3). Well Proximity Risks: The nearest existing well to West Sak 1D-129 (J3) is KRU 1D-06. As designed, the minimum distance between the two wells would be 27' @ 360' 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 an 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-129 (J3) surface casing / production tubing annulus will be filled with diesel and/or non-freezing brine after setting the 7-5/8" combination surface / production casing and prior to the drilling rig moving off of the well. TAB, 11/06/97 Page 3 3OO 3OO 600 900 1200 1500 1800 2100 2400 2700 3000 3300 3600 3900 4200 cr.otoo W ri.c, For: T McKAY Dote pla~.ed : 23-0ct-97 Plot Reference ia WS 1D-12g/J5 Vernon Cao~inotes om ;n fe~-t reference sl~t ~129. r~c Vcrfical ~ptha ~rc r~encc ~D (Pork~ 300 Structure : Pad lB Well : J3 Field : Kuparuk River Unit Location : Nodh Slope, AlaskaI <- West (feet) 2100 1800 1500 1200 go0 600 300 0 _. I t I I I I I I I f I I I I I SURFACE LOCATION: ] 391' FNL, 600' FEL 270 Az SEC. 23, T11N, RIOE Begin Turn to Torget 220.3 AZIMUTH 3006' (TO TARGET) ***Plone of Proposol*** Permofrost RKB ELEVATION: 1 11' K0P TVD=300 TMD=300 DEP=0 6,00 BEGIN TURN TO TARGET TVD=416 TMD=417 DEP=5 10.69 16.08 21.79 . BLS: 6.00 deg per 100 ft 27.81 Angle Drop 33.49 9f~1.34'~ Top Ugnu Sends 51 29 TARGET West Sok A3 136 TMD=1281 DEP=427 - TARGET/TD LOCATION: '~MAFROST TVD=1628 TMD=2163 DEP=1159 2597' FSL, 2544' FEL SEC. 23, T11N, RIOE TARG ET MAXIMUM ANGLE ~. ~vD=3669 TMD=5106 56.12 DE G ~ DEP=~OO6 SOUTH 2292 WEST 1944 ~D=2584 TMD=3879 DEP=2583~,~.85 42.85 v ~24.85 BLS: 6.00 deg per 100 ft 18.85 END ANGLE DROP TVD=3377 TMD=4814 DEP=3006 T/ W SAK SNDS TVD=3527 TMD=4964 OEP=3006 TARGET W SAK A3 TVD=3669 TMD-5106 DEP=3006~ B/ W SAK SNDS TVD=3937 TMD=5374 DEP=3006 TD - CSG PT TVD=4137 TMD=5574 DEP=3006_.~ I I I I I I I I I I I I I I I I I I I I I I 0 300 600 900 1200 1500 1800 21 O0 2400 2700 3000 Verticol Section (feet) -> Azimuth 220.30 with reference 0.00 N, 0.00 E from slot #129 12.85 6.85 0.85 I 3300 300 300 600 900 1200 15oo 1800 2100 2400 TARGET ANGLE VERTICAL :~o~ ~ ~;.~. For: T McKAY Date platted: 25-Oct-g? Plot Reference ia WS 1D-129/J'~ Version Coard;notes am ~n fe~t ~ference sic)[ ~'129. true Vcrt~:al Dcpl. hs~RKB (Parker Structure : Pad 1D Well : J5 Field : Kuparuk River Unit Location : North' Slope, AlaskaI 4O 0 '%O 8O 12O 16O 2OO --I.-- (D 240 ~- 280 .-I-- 0 O0 32o I v 3~0 4O0 440 48t3 520 ~40 <- West (feet) 560 520 480 440 400 ,360 ;S20 280 240 200 160 120 80 40 0 40 80 .................. ,,,"/ 40 .......... j..~.o..o.. 2500 ,.,' ¢' ..... / ~°?',/%oo / ,,,' ,,' ~~ 6oo / ,," ,/'~ :700 / / / / / / / ,,~;~ /' ~oo/ /'/ ,/' 900~900 ~500 1200 ~20 "?~o "'"' /~ooo ' 6o ,oo? / / / ¢,ooo ,,,' /;9oo /~=oo / :oo // ,,' ./1500 / ~ ~200 ,,'/ ," ~ ,,',~oo oo ~oo ~4oo / /, ~ 2~0 0 /' ¢?~200 / ,/' // /1700 [ 1400 440 / //' 1900// / ,,// ,// __ 520 [ I I i I I t I I I I I I I I I I i I I I i60 520 480 440 400 360 320 280 240 200 160 120 80 40 0 40 80 ~ <- West (feet) C,eo~ed by ~.ch For: T McKAY Dote plotted: 23-0ct-97 Plot Reference ;~ WS tO-12g/d5 Version C~rdinotes ore in f~t reference slot ~129. True Ve~[¢ol D~thB ore reference R~ IARCO Alaska, Inc. Structure: Pad 1D Well : J5 Field : Kuporuk River' Unlf Location : Norfh Slope. AlaskaI 500 600 700 800 900 1000 1100 12O0 1500 1400 1500 I v 16oo 1700 1800 1900 2OOO 21 O0 2200 2300 2400 <- West (feet) 2000 1900 1800 1700 1600 1500 1400 1500 1200 1100 1000 900 800 700 600 500 I I I I 14°,0,.,/ ,,/'2000/~-/ /," ,/'2200 1500/ 2100/,' ,,'" _ ,//%300 1 600/// 220,,~/,'~¢00 170/0// 2Z,/'~ 600 // 257///2700 180,/0/s/2600 /';800 1900.,' // // ,,,,"~oo/" .,,,,"~ooo // / ,/31 O0 onnn ,,"~900 ;"3200 // / / 3400 ,"30on/ /3600 ,," '~7 ,/~- 21 00/" / r-~--]/ /// /3100 2200///3200 //' /'3300 2300 ,// , //' /3400 2500/'/ /3600 ///' 2600 2700,/'/'// /3800 · 2800 .,' 2900 .///-~,~4000 3000 #'/ / i I I I I i i i I I I i I i I I I I I i i i I I I I I I i I i 2000 1900 1800 1700 1600 1500 1400 1500 1200 1100 1000 900 800 700 600 500 (- West (feet) 500 600 700 800 900 L IOOO 1100 1200 1300 bO 0 ,-i- 1400 1500 ._+. I 16oo V 1700 1800 1900 2000 2100 2200 2300 2400 ARCO Alaska, Inc. Pad 1D J3 slot #129 Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE by Baker Hughes INTEQ REPORT Your ref = WS 1D-129/J3 Version #3 Our ref = prop2193 License = Date printed ~ 23-0ct-97 Date created = 16-Apr-97 Last revised = 22-0ct-97 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 17 57.470,w149 30 36.399 Slot Grid coordinates are N 5959273.703, E 560490.139 Slot local coordinates are 391.00 S 600.00 W Projection ty~e: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object we11path PGMS <O-8365'),,1,Pad 1D TOTCO Survey,,WS-8,Pad 1D PGMS <0-8930'>,,5,Pad 1D PGMS <O-7502~>,,4,Pad 1D PGMS ¢O-8070~,,3,Pad 1D MSS <3311-8200~>,,7,Pad 1D PGMS ~O-8610~,,6,Pad 1D PGMS <0-9783'>,,2,Pad 1D WS 1D-133/J5 Version #4,,JS,Pad 1D WS 1D-124/G3 Version #3,,G3,Pad 1D WS 1D-130/H4 Version #4,,H4,Pad 1D WS 1D-121/G5 Version #3,,GS,Pad 1D WS 1D-135/G7 Version #4,,GT,Pad 1D WS 1D-106/D6 Vers.#3,,D6,Pad 1D WS 1D-109/D4 Vets. #2,,D4,Pad 1D WS 1D-119/F4 Vers.#3,,F4,Pad 1D WS 1D-120/F6 Vets. #3,,F6,Pad 1D WS 1D-118/E5 Version #4,,E5,Pad 1D WS 1D-105/C7 Version #4,,CT,Pad 1D WS 1D-115/E3 Version #4,,E3,Pad 1D WS 1D-117/E7 Version #4,,ET,Pad 1D Closest approach with 3-D Minimum Distance method Last revised Distance 4-Aug-92 16-0ct-96 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 22-Oct-97 22-0ct-97 9-0ct-97 22-Oct-97 22-0ct-97 8-Oct-97 8-Oct-97 6-Oct-97 6-0ct-97 22-Oct-97 22-0ct-97 22-Oct-97 22-Oct-97 627.9 173.8 147.5 267.6 388 0 83 6 27 1 507 8 59 4 120 0 15.0 210.0 118.3 495.0 450.0 240.0 225.0 285.0 525.0 330.0 300.0 M.D. Diverging from M.D. 416.7 416.7 880.0 880.0 300.0 300.0 416.7 416.7 20.0 4860.0 5574.1 5574.1 360.0 360.0 380.0 380.0 660.0 660.0 300.0 5574.1 300.0 5574.1 300.0 5574.1 760.0 760.0 300.0 300.0 300.0 300.0 300.0 5574.1 300.0 300.0 300.0 3OO.O 300.0 300.0 280.0 5574.1 300.0 300.0 West ;ak 1D-129 (J3) Stimula tion Diagram Four (4) Stage Frac-for-Sand Control with 3-1/2" Deadstring m m m m m m m m m m m m m m m m m mm m mm m, m mm m m mm m m m m m mm m mm mm mm m mm mm m m m m m mm m m m 16" Conductor Casing @ 80' 7-5/8" DV Stage Collar set approx. 200' TVD below permafrost 3-1/2" Deadstring to Frac Through Off-Rig m m m m D Sand Frac'd with Resin Coated Proppant m m m m B + A4 Sands Frac'd with Resin Coated Proppant mm m m mm A3 Sand Frac'd with Resin Coated Proppant m m mm mm A2 Sand Frac'd with Resin Coated Proppant 7-5/8" Combination Surface / Production Casing, Cemented to Surface ARCO Alaska, Inc. TAB, 11/06/97, Rev. 1 West Sak 1D-129 (J3) Proposed Completion Diagram Four (4) Stage Frac-for-Sand Control Completion 2-7/8" Production Tubing Power Cable for ESP Centrilift m m m m m m m m m m m m 7-5/8" Combination Surface/Production Casing, 29.7# L-80 BTC-MOD (Cemented to Surface) mm m mm mm m m m m m m m m m m mm mm m m m m mm mm mm 16" Conductor Casing @ 80' Raychem Heat Trace (through permafrost) Weatherford Gemoco 754HO 7-5/8" DV Stage Collar Stnd. Grade BTC Threads (set +/- 200' TVD below permafrost) Camco 2-7/8" Gas Lift Mandrel with 1" side pocket Arctic Lift 3500 psi Shear circulating valve pre-loaded in GLM (circulate well for freeze protection purposes) ESP Pump Section Centrilift ESP Gearbox Centrilift ESP Motor Section Oentrilift D Sand Frac'd with Resin Coated Proppant m -- B + A4 Sands Frac'd with __-- Resin Caoted Proppant m -- A3 Sand Frac'd with ~ Resin Coated Proppant A2 Sand Frac'd with Resin Caoted Proppant ARCO Alaska, Inc. TAB, 11/10/97, Rev.1 KUPARUK RIVER UNIT- WEST SAK OPERATIONS 20" DIVERTER SCHEMATIC 6 I4 5 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. , MAINTENANCE ~ OPERATION 'UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT 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 WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20"- 2000 PSI ANNULAR PREVENTER. TWM, 9/15/97 l, , 1 8 , 7 13 West 5/8" 5000 PSI BOP STACK Sak Operations - Producer Wells ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2_ ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. I 6 ..... ...... / I I L__ I £ J I I . , 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 AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6, CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TESTAS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOTA 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. BACKOFF RUNNING JT AND PULL OUTOF 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 SETIN THE DRILLING POSITION. , 11,TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12.TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13,RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14.PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL ACCOMODATE 3-1/2" TO 6" OR 4-1/2" TO 7" PIPE ODS AS APPROPRIATE. 1. 16"- STARTING HEAD 2. 11"- 5000 PSI HORIZONTAL TUBING HEAD 3. 11" 5000 PSI 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 DRLG SPOOL W/ CHOKE AND KILL LINES 7. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 8. 13-5/8" - 5000 PSI ANNULAR TWM, 9/22/97 PC 9ESCRiPT1ON AS-BUILT PER KSB~ Kg7082ACS /?ood C D.S. 105~ 2 106 ~ 'O3 $ 115 I 117 118 ~4 119 ; 120 · 121 I 124 1-D 6 129 150 133 135 i , 6 8 50 . 13 9/17/97 AJR I PC D.S.1B ,DESCRIPTION AS-BUILT PER KSB~ Kg7082ACS '. \ · · WEST SAK-1 THIS SURVEY VICINITY MAP SCALE: 1" = I MILE NO SCALE LEGEND 0 EX/STING CONDUCTORS · NEW CONDUCTOR LOCATION ARCO Alaska, Inc. CADD FILE NO. DRAWING NO: LK610410 SEE SHEET I~ 2 FOR NOTES AND LOCATION INFORMATION .~ LOUNSBURY & ASSOCIATES, INC. E~NEERs PLANNERS SURVEYO~ AREA' 1D WOOULE XX UNIT' D1 DRILL SITE 1-D WEST SAK PHASE I - WELL CONDUCTORS AS-BUILT SHEET: REV: CEA-D1DX-6104-D10 ~ o¢ 2 , ..,; ,: ..a ~ ~" ', ~ · '.' ,,,, .'."~' .,~.'.. 2 ,, N 0 TES . CDORDINATES SHOWN ARE A.S.P. ZONE 4, N.A.D. 2Z ELEVATIONS $H014~i ARE BRITISH PE77?OLEUM MEAN SEA LEVEL, ALL DISTANCES SHOWN ARE TRUE. 2. BASIS OF LOCATIONS AND ELEVATIONS ARE D.S. i-D MONUMENTS PER LHD AND ASSOCIATES. 3. CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTIONS ~4 & 23, TOWNSHIP 11 NORTH, RANGE 10 EAST, U.M, 4. DATE OF SURVEYS: 8/25, 29 & 30/97, FIELD 8K L97-24, pp. 32 - 45, 68 - 7J. 5. DRILL SITE 1-0 GRID NORTH IS ROTATED 00' 01' 05" WEST FROM A.S.P. ZONE 4 GRID NORTH. 6. SEE DRAWING NSK-3.5-1 FOR AS-BUILT LOCATIONS OF CONDUCTORS till THROUGH 9ESCRIPllON AS-BUILT PER KSB~ K97082ACS ,/ \ \, ~CINITY MAP SCALE: I" = I MILE Well SEC, SEC. PAD No. ,y, A.S.P.s 'X' LA TITUDE LONGITUDE ~ ~ ELEV. EL£V. S,~.c. 14, T. 11 N., R. IO E. F,S.L.F.E.L. 105 5,959,798.99 560,490,57 70' 18' 02.657' 149' 30' 36.263' 154' 595' 70.5' 62,0' 106 5,959,768.95 560,490,67 70' 18' 02.$41" 149' 30' 36.268' 104' 595' 70.4' 62.3' 109 5,959,723.89 560,490.60 70' 18' 01.898' 149' 30' 36.280' 59' 596' 70.4' 62.7' S, ;c. 23, T. 11 N., R. I O E. F.N.L.F.E.L. 115 5,959,605.95 560,490.68 70' 18' .00.718° 149' $0' 36.$06" 61' 597' 70,4' 65.4' 117 5,959,575.95 560,490.65 70' 18' 00.425' I49' $0' $6,314' 9I' 597' 70.4' 63.4' 118 5,959,558.95 560,490.68 70' 18' 00.276" 149' $0' 36.,716' 106' 597' 70.4' 6[4' 119 5,959,513,86 560,490.72 70' I7' 59.852' I49' .70' 36.$26" I5I' 598' 70.6' 66.0' 120 5,959,499.01 560,490,77 70' 17' 59.686" 149' 30' 36.$27' 166' 598' 70.6' 68.0' 121 5,959,485.89 560,490.67 70' 17' 59.558" I49' 30' 36.335' 181' 598' 70.5' 66.0 124 5,959,393,96 560,490.70 70' 17' 58.653' I49' $0' 36.355' 271' 599' 70.3' 65.0' 129 5,959,273.92 560,490.79 70' 17' 5Z472" 149' 30' 36.380' $91' 600' 70.3' 6&2' 130 5,959,259.09 560,490.81 70' 17' 5Z$26' 149' 30' 36.383' 406' 600' 70.5' 68.2' 135 5,959,213.89 560,490.68 70' I7' 56.882' I49' 30' 36,397' 45I' 600' 70.4' 135 5,959,139.02 560,490.80 70' 17' 56. I46° 149' 30' 36.412' 526' 601' 70.5' 69.4' , SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE 8Y ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF AUGUST 30, 1997. ARCO Alaska, Inc.' ,, LK610410 9//'02 97 ii . .,~,~..,.~ ~~',...~.,,~. ,.~,,,,,~.~, .. LOUNSBURY & ASSOCIATES, INC. E,~NEERS PLANNERS SURVEYORS AREA' 10 MODULE' XX DRILL SITE 1-D WEST SAK PHASE I - WELL CONDUCTORS AS-BUILT CEA-D1DX-S104D10 ISHEET:201[2 i'R~:v: ·, ,.. ,., , , ,.:, ,,;.:;.~. ..... :,:,.~*,?~j~ :;~,.,.. U~iT' D, 2 ARCO Alaska, Inc. Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor November 10, 1997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill West Sak 1D-129 (J3) West Sak Phase lA 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 1D pad. The well is designed including hydraulic fracturing stimulation treatments using resin coated type proppant material. The stimulation procedure is designed to control sand production expected in these unconsolidated formations. The well is planned as a producer well using a progressive cavity ESP ("PCESP") to artificially lift the well. 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 detailed in ARCO's testimony for West Sak Pool Rules governing the West Sak development project. 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 5) 6) 7) 8) 9) 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 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-129 (J3), such as shallow gas. There have been eight (8) Kuparuk 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. An exception to the requirements set out by 20 AAC 25.033 (e) and 25.061 (a) are hereby requested for this APD because of this regional experience. A prediction of the maximum downhole and surface pressures which may be encountered however are included in this APD per 20 AAC 25.035 (d) (2). 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. The drilling fluid program, in addition to the requirements set for[h in 20' AAC 25.033 are attached in this APD package. A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached 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. An exception to the requirements detailed in 20 AAC 25.005 (c) (8) is thus requested. Please note that the anticipated spud date for this well is November 18, 1997. If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or Tom McKay at (907) 265-6890. Thomas A. Brockway ~' Operations Drilling Engineer Attachments CC: West Sak 1D-129 (J3) Well File Tom McKay ATO-1202 Keith Lynch ATO- 1228 Ike Bellaci ATO-1260 Cliff Crabtree NSK-6 · WELL PERMIT CHECKLIST COMPANY FIELD & POOL ~'~¢>,//,d"~> INIT CLASS ~ //-'~'/ WELL NAME ./~d..,/ GEOL AREA PROGRAM: exp [] dev. v~redrll [] serv [] wellbore seg C ann. disposal para req D ~?',,,~ UNIT# /,/,/~ ~ ON/OFF SHORE ~,~'1~,.,.) ADMINISTRATION ENGINEERING GEOLOGY R DATE 1. Permit fee attached ....................... N 2. Lease number appropriate ................... N 3. Unique well name and number .................. N 4. Well located in a defined pool .................. N 5. Well located proper distance from drilling unit boundary .... N 6. Well located proper distance from other wells .......... N 7. Sufficient acreage available in drilling unit ............ N 8. If deviated, is wellbore plat included ............... N 9. Operator only affected party ................... N 10. Operator has appropriate bond in force ............. N 11. Permit can be issued without conservation order ........ N 12. Permit can be issued without administrative approval ...... N 13. Can permit be approved before 15-day wait ........... N 15. Surface casing protects all known USDWs ........... N 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved.. ·~-~ iN 22. Adequate wellbore separation proposed ............. N 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ..... ,4 .......... 26. BOPE press rating appropriate; test to ~t.,~c.,~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ (_~N 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. Y 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. 34. Contact name/phone for weekly,progress repo, rts ...... ///Y N Y N lexp~oramry omyj REMARKS GEOLOGY: ENGINEERING: COMMISSION: ' - JDH ~ RNC CO ~ Comments/Instructions: HOW/lit - A:\FORMS\cheklist rev 09197 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 Utility Wed Dec 17 10:32:12 1997 Reel Header Service name ............. LISTPE Date ..................... 97/12/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/12/17 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 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: MWD RUN 1 AK-MM-80020 P. SMITH D. BREEDEN ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 1D-129 500292283000 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 17-DEC-97 MWD RUN 3 AK-MM-80020 P. SMITH D. BREEDEN 23 liN 10E 391 600 .00 111.30 70.30 RECEiVt:: DEC 2 4 Oil &Gas Cons. WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9. 875 5462.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 AND 3 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 3. MWD RUN 2 MADE NO FOOTAGE AND IS NOT PRESENTED. 4. DEPTH SHIFT/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN MIKE WERNER OF ARCO ALASKA, INC. AND MARSHALL MUNYAK OF SPERRY-SUN DRILLING SERVICES ON 12/12/97. 5. THIS WELL REACHED A TOTAL DEPTH OF 5462'MD, 4033'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 ....... 97/12/17 Maximum Physical Record..~5535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH FET 121.0 RPD 121.0 RPM 121.0 RPS 121.0 RPX 121.0 GR 121.0 ROP 123.5 $ STOP DEPTH 5417.5 5417.5 5417.5 5417.5 5417.5 5425.0 5462.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 1 121.0 3824.0 3 3824.0 5462.0 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 DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD AAPI 4 1 68 RPX MWD OHM- 4 1 68 RPS MWD OHM- 4 1~ 68 RPM MWD OHM- 4 1 68 RPD MWD OHM- 4 1 68 FET MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max DEPT 121 5462 ROP 6.2432 4130.42 GR 9.6722 109.804 RPX 0.3105 2000 RPS 0.1827 2000 RPM 0.4778 2000 RPD 0.4116 2000 FET 0.09 21.393 Mean Nsam 2791.5 10683 247.53 10678 55.0375 10609 46.5323 10594 54.0204 10594 86.7801 10594 161.539 10594 0.607074 10594 First Reading 121 123.5 121 121 121 121 121 121 Last Reading 5462 5462 5425 5417.5 5417.5 5417.5 5417.5 5417.5 First Reading For Entire File .......... 121 Last Reading For Entire File ........... 5462 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/17 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 ....... 97/12/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 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 3779.5 R?D 121.0 3779.5 RPM 121.0 3779.5 R?S 121.0 3779.5 RPX 121.0 3779.5 GR 121.0 3787.0 ROP 123.5 3824'.0 $ LOG HEADER DATA DATE LOGGED: 23-NOV-97 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.06 DOWNHOLE SOFTWARE VERSION: CIM 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 3824.0 TOP LOG INTERVAL (FT): 121.0 BOTTOM LOG INTERVAL (FT): 3824.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: 58.4 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): TOOL NUMBER P0863CRG6 P0863CRG6 9.880 9.9 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 SPUD MUD 176.90 285.0 9.0 400 7.8 6.000 4.960 6.900 5.000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 AAPI 4 1 68 4 2 RPX MWD 1 OHM~ 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 26.7 First Name Min Max Mean Nsam Reading DEPT 121 3824 1972.5 7407 121 GR 9.6722 109.804 53.5505 7333 121 RPX 0.3105 2000 62.71 7318 121 RPS 0.1827 2000 73.2985 7318 121 RPM 0.4778 2000 120.743 7318 121 RPD 0.4116 2000 228.604 7318 121 ROP 11.3372 4130.42 273.653 7402 123.5 FET 0.09 3.1202 0.371121 7318 121 Last Reading 3824 3787 3779.5 3779.5 3779.5 3779.5 3824 3779.5 First Reading For Entire File .......... 121 Last Reading For Entire File ........... 3824 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/17 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 ....... 97/12/17 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: 3 DEPTH INCREMENT: .5000 FILE SUMFuARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 3780.5 5417.5 RPD 3780.5 5417.5 RPM~ 3780.5 5417.5 RPS 3780.5 5417.5 RPX 3780.5 5417.5 GR 3788.0 5425.0 ROP 3826.0 5462.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 25-NOV-97 ISC 5.06 CIM 5.46 MEMORY 5462.0 3824.0 5462.0 1.0 50.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL ~ 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 P0863CRG6 P0863CRG6 9.880 9.9 S PUD MUD 178.80 310.0 9.0 450 7.2 4.800 3.540 6.200 3.600 34.5 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 7kAPI 4 1 68 4 2 RPX MWD 3 OHMM 4 1 68 8 3 RPS MWD 3 OHMM 4 1 68 12 4 RPM MWD 3 OHMM 4 1 68 16 5 RPD MWD 3 OHMM 4 1 68 20 6 ROP MWD 3 FT/H 4 1 68 24 7 FET MWD 3 HOUR 4 1 68 28 8 First Name Min Max Mean Nsam Reading Last Reading DEPT 3780.5 5462 4621.25 3364 GR 14.8793 104.229 58.3685 3275 RPX 0.9521 141.424 10.3937 3275 RPS 1.0447 112.684 10.9558 3275 RPM 1.1229 153.065 10.9135 3275 RPD 1.3076 159.948 11.7275 3275 ROP 6.2432 1824.61 188.495 3273 FET 0.1411 21.393 1.13122 3275 3780.5 3788 3780.5 3780.5 3780.5 3780.5 3826 3780.5 5462 5425 5417.5 5417.5 5417.5 5417.5 5462 5417.5 First Reading For Entire File .......... 3780.5 Last Reading For Entire File ........... 5462 File Trailer Service name ............. STSLIB. 003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/12/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 97/12/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File