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Home My WebLink About192-0971. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Replace Tubing Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 13015'feet None feet true vertical 6146'feet 12911'feet Effective Depth measured 10400'feet 9672', 9891', 9991', 10963' feet true vertical 6048'feet 5740', 5847', 5893', 6144' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth)3-1/2" 3-1/2" L-80 L-80 9848' 9992' 5826' 5893' Packers and SSSV (type, measured and true vertical depth)9672' 9891' 9991' 10963' 5740' 5847' 5893' 6144' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Kuparuk Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Contact Phone: 325-337 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Tripoint DLH Packer: Baker FHL Retrievable Packer: Baker FH Retrievable Baker FB-1 SSSV: None James Ohlinger james.j.ohlinger@conocophillips.com (907) 265-1102CTD Engineer 10760-10900', 11430-11550', 11720-12180', 12300-12550', 12650-12850' 6118-6136', 6147-6145', 6142-6137', 6136-6141', 6145-6147' 2906'7" measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) N/A Gas-Mcf MDSize 121' N/A measured TVD 9-5/8" 9-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 192-097 50-103-20183-00-00 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: ADL0025585, ADL0025586, ADL0025590 Kuparuk River Field/ Kuparuk Oil Pool KRU 2M-29 Plugs Junk measured Length Production Liner 1985 8394' Casing 1876' 6049' 2012' 10405' 13002'6146' 3626' 121'Conductor Surface Production 16" 13-3/8" 77' 3669'2776' Burst Collapse Fra O s 6. A PG , g Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 11:33 am, Aug 22, 2025 Digitally signed by James J. Ohlinger DN: CN=James J. Ohlinger, E= James.J.Ohlinger@cop.com Reason: I am the author of this document Location: Date: 2025.08.22 08:03:48-08'00' Foxit PDF Editor Version: 13.1.6 James J. Ohlinger J.Lau 11/4/25 DSR-9/11/25 RBDMS SJB 082825 Page 1/14 2M-29 Report Printed: 8/13/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/7/2025 00:00 7/7/2025 02:00 2.00 MIRU, MOVE DMOB P Mobilize F/2M-25 to 2M-29. PJSM to pull pits off sub at 1230 Pulled Sub off 2M-25 at 0200 0.0 0.0 7/7/2025 02:00 7/7/2025 06:00 4.00 MIRU, MOVE MOB P Mobilize sub to 2M-29 Spot in sub base. Pick up mats on pad and stack. Spread pit liner under front of rig. Spot in pits. Start working pre-acceptance checklist. 0.0 0.0 7/7/2025 06:00 7/7/2025 08:30 2.50 MIRU, MOVE MOB P Set mats under pit mod, safe out walkways and berming.RU interconnect betweensub and pit modules. Rig accepted at 8:30. 0.0 0.0 7/7/2025 08:30 7/7/2025 14:00 5.50 MIRU, WELCTL KLWL P Take on 10.9 ppg brine to pits. RU to kill the well.Install 1502 flange on IA Valve. Have pad operator open SSSV. Inial Pressures T/IA/OA = 650/700/60 psi. Processing 3.5" 9.3# EUEM tubing in pipeshed. 0.0 0.0 7/7/2025 14:00 7/7/2025 14:30 0.50 MIRU, WELCTL SFTY P Safety/PJSM meeting to kill well. 0.0 0.0 7/7/2025 14:30 7/7/2025 16:30 2.00 MIRU, WELCTL DISP P Pump a 35 bbl high vis deep clean sweep at 3 BPM /400 psi.Followed by 10.9 ppg NaCl/NaBr. Tubing and IA volume is 690 bbls to pre-rig cut at 9845'. Continue process tubing in pipe shed 0.0 0.0 7/7/2025 16:30 7/7/2025 17:30 1.00 MIRU, WELCTL OWFF P RD circulateing equipment and OWFF for 30 minutes Continue process tubing in pipe shed 0.0 7/7/2025 17:30 7/7/2025 18:00 0.50 MIRU, WELCTL MPSP P Set BPV and test to 1000 PSI for 10 minutes. Continue process tubing in pipe shed 7/7/2025 18:00 7/7/2025 21:00 3.00 MIRU, WHDBOP NUND P ND tree and adapter. Set blanking plug in hanger neck, Function test LDS. Continue process tubing in pipe shed 7/7/2025 21:00 7/8/2025 00:00 3.00 MIRU, WHDBOP NUND P NU DSA and BOP's. Continue process tubing in pipe shed 7/8/2025 00:00 7/8/2025 01:00 1.00 MIRU, WHDBOP NUND P Flood BOP stack function rams and annular. Perform shell test on BOP stack. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/27/2025 Page 2/14 2M-29 Report Printed: 8/13/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/8/2025 01:00 7/8/2025 07:00 6.00 MIRU, WHDBOP BOPE P Start testing BOPE. Initial BOPE test, Tested BOPE at 250/3000 PSI for 5 Min each, Tested annular on 3-1/2" test joint, UVBR's, w/3 -1/2" test joint. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 3 1/2" HT-38 safety valve, FOSV, and IBOP. Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=3050 PSI, after closure=1600 PSI, 200 PSI attained =15 sec, full recovery attained = 184 sec. UVBR's= 6 sec, Annular= 19 sec. Simulated blinds= 6 sec. LVBR’s=6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2100 PSI. Test gas detectors, PVT and flow show. Test Witness Waived by AOGCC rep Sean Sullivan, Annular preventer fail pass. Would not hold closing pressure. Observed and replace leaking hydraulic hose. 0.0 0.0 7/8/2025 07:00 7/8/2025 08:00 1.00 COMPZN, RPCOMP RURD P RD from testing and RU floor to lay down 3-1/2" completion. 0.0 0.0 7/8/2025 08:00 7/8/2025 08:30 0.50 COMPZN, RPCOMP PULL P M/U YJ spear assy to top drive. Enguage spear to completion. Set down 10K, BOLDS. Hanger unseated @ 50K over. Bring hanger to floor. PUW=95K ,Lay down spear and hanger 9,845.0 9,825.0 7/8/2025 08:30 7/8/2025 17:30 9.00 COMPZN, RPCOMP PULL P Pull 3 1/2" completion from pre rig cut @ 9845. PUW=95K. Cut section 4.39' 9,825.0 7/8/2025 17:30 7/8/2025 18:00 0.50 COMPZN, RPCOMP SVRG P Service rig tongs. rough neck and draw works. 7/8/2025 18:00 7/8/2025 18:30 0.50 COMPZN, RPCOMP PULL P Pull 3 1/2" completion from pre rig cut @ 9845. PUW=95K. Cut section 4.39' 7/8/2025 18:30 7/8/2025 19:00 0.50 COMPZN, RPCOMP OWFF P OWFF for 30 minutes clena and clear rig floor. 7/8/2025 19:00 7/8/2025 20:30 1.50 COMPZN, RPCOMP RURD P Suck out stack RU to test BOP's set test plug and fill stack W/FW. Purge system 7/8/2025 20:30 7/8/2025 21:00 0.50 COMPZN, RPCOMP BOPE P Tested LPR's on 9-5/8" Test joint to 250/3000 PSI for 5MIN ea. 7/8/2025 21:00 7/8/2025 22:00 1.00 COMPZN, RPCOMP RURD P RD from testing blown surface lines. LD test oint and pull test plug. Set wear ring in tubing head. 7/8/2025 22:00 7/8/2025 22:30 0.50 COMPZN, RPCOMP SVRG P Service top drive greased black jack. 7/8/2025 22:30 7/9/2025 00:00 1.50 COMPZN, RPCOMP RURD T E-Line on previous job. Process DP while waiting for E-Line to arrive. 7/9/2025 00:00 7/9/2025 00:45 0.75 COMPZN, RPCOMP RURD T Wait on E-Line to complete job to arrive on location. Continue to process DP 0.0 0.0 7/9/2025 00:45 7/9/2025 02:15 1.50 COMPZN, RPCOMP ELNE P AK eline on location. Walk down job with operator while crew started spotting in equipment. Spot in logger, move equipment to floor RU to RIH 0.0 0.0 7/9/2025 02:15 7/9/2025 07:00 4.75 COMPZN, RPCOMP ELNE P Log CBL in 9-5/8" casing F/3700' T/surface 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/27/2025 Page 3/14 2M-29 Report Printed: 8/13/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/9/2025 07:00 7/9/2025 07:30 0.50 COMPZN, RPCOMP BHAH P M/U BHA #2 \9 5/8" RBP 0.0 24.1 7/9/2025 07:30 7/9/2025 09:30 2.00 COMPZN, RPCOMP PULD P Single in 3 1/2" DP 24.1 2,425.0 7/9/2025 09:30 7/9/2025 10:00 0.50 COMPZN, RPCOMP MPSP P Attempt to set RBP @ 2400'. PUW=67, SOW=60K. Unable to get plug to set down. P/U single. Plug set down @ 2425. Able to set and release from plug 2,425.0 2,425.0 7/9/2025 10:00 7/9/2025 10:30 0.50 COMPZN, RPCOMP MPSP P Pressure test RPB 1000 PSI / 10 min. Good test 2,425.0 2,388.0 7/9/2025 10:30 7/9/2025 16:00 5.50 COMPZN, RPCOMP OTHR P Pull two stands of DP, PUW=67K. Dump 36, 60Lb sacks sand on top of RBP, R/D sand dump equipment. RIH to TOS @ 2379 2,388.0 2,186.0 7/9/2025 16:00 7/9/2025 17:30 1.50 COMPZN, RPCOMP DISP P PUH to 2180. Pump 20 BBl spacer, Displace well 10.9PPG Brine to fresh water 4 BPM @ 180 PSI 2,186.0 2,180.0 7/9/2025 17:30 7/9/2025 18:15 0.75 COMPZN, RPCOMP TRIP P TOOH F/2180' T/24.1 2,180.0 24.1 7/9/2025 18:15 7/9/2025 18:30 0.25 COMPZN, RPCOMP BHAH P LD BHA retrieving head 24.1 0.0 7/9/2025 18:30 7/9/2025 19:00 0.50 COMPZN, RPCOMP RURD P Pull wear ring 0.0 0.0 7/9/2025 19:00 7/10/2025 00:00 5.00 COMPZN, RPCOMP NUND P Pull riser, remove turn buckles from stack N/D BOP's. ND tubing head. RU the cameron detensioning tool. 0.0 0.0 7/10/2025 00:00 7/10/2025 01:30 1.50 COMPZN, RPCOMP CUTP P RU cameron compression tool. Attempted to De-tension casing at the wellhead. LDS and gland nuts seized. 0.0 0.0 7/10/2025 01:30 7/10/2025 08:00 6.50 COMPZN, RPCOMP WAIT P Confered with town discussed plan forward. FMC working with materials to aquire LDS to replace seized LDS. Contaced DHD to confirm drill is availalbe and complete for drill out. 0.0 0.0 7/10/2025 08:00 7/10/2025 14:00 6.00 COMPZN, RPCOMP OTHR P DHD team on location. Holod PJSM - planning meeting with rig crew. Call back FMC well head hand. Call out Cameron for decompression tool. Start working lock down screw gland nut issues on casing head. Able to get gland nuts backed off. Able to pull lock down screws. Tap threads in casing head flange. Install lock down screw - gland nuts 0.0 0.0 7/10/2025 14:00 7/10/2025 15:30 1.50 COMPZN, RPCOMP OTHR P Start growing 9 5/8" casing. Initial force 470K. Total growth 35. Rig down Cameron tools 0.0 0.0 7/10/2025 15:30 7/10/2025 16:00 0.50 COMPZN, RPCOMP CUTP P Spear 9 5/8" casing. Pull to 170K. Pull slips. Go to neutral weight. Casing in good position. Disengage spear 0.0 0.0 7/10/2025 16:00 7/10/2025 17:00 1.00 COMPZN, RPCOMP CUTP P Rig up FMC WACHS saw to cut casing head off. Remove pack-off. Removed 3.291' 0.0 0.0 7/10/2025 17:00 7/10/2025 20:00 3.00 COMPZN, RPCOMP NUND P NU BOP's top casing head 0.0 0.0 7/10/2025 20:00 7/10/2025 21:00 1.00 COMPZN, RPCOMP BHAH P MU External casing cutter BHA. 0.0 23.6 7/10/2025 21:00 7/10/2025 23:30 2.50 COMPZN, RPCOMP TRIP P TIH F/23.62' T/108' Knife blades catching collars. POOH to secure knife blades. TIH F/23.62' T/2382 Tag sand W/10K down PUW=65K SOW=62K 23.6 2,382.0 Rig: NABORS 7ES RIG RELEASE DATE 7/27/2025 Page 4/14 2M-29 Report Printed: 8/13/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/10/2025 23:30 7/11/2025 00:00 0.50 COMPZN, RPCOMP CPBO P Establish parameters to cut casing PUW=65K SOW=62K 1.5 BPM 130 PSI, 4BPM @1200 PSI, 4.5BPM @ 2000 PSI Rot 90 RPM ROT WT= 62K Tq-1.2K Located collar at 2034' 7ES RKB. 2037' ELMD. Racked back stand 22 MU working single. Moved fluid in pits 2,382.0 2,010.0 7/11/2025 00:00 7/11/2025 01:00 1.00 COMPZN, RPCOMP CPBO P Rotate at 90 RPM Engage pump work up to 35 SPM TQ=2.1K-2.5K Tq built to 9K and broke back to 1.2K Tq built back to 2.5K Set down 5K on DP, knives engaged casing cut. Shut off rotary set down 10K on knives PU to 70K Shut off pumps and LD working single. 2,010.0 2,010.0 7/11/2025 01:00 7/11/2025 02:15 1.25 COMPZN, RPCOMP CIRC P Circulate DP x 9-5/8" to cuttings tank at 4 BPM Started getting gas in returns. Shut down pump. Closed in annular. Lined up to take returns through gas buster to cuttings tank at 2.5 BPM. 2,010.0 2,010.0 7/11/2025 02:15 7/11/2025 02:30 0.25 COMPZN, RPCOMP OWFF P OWFF for 15 minutes 0 Flow 2,010.0 2,010.0 7/11/2025 02:30 7/11/2025 04:00 1.50 COMPZN, RPCOMP TRIP P TOOH F/2010' T/23.6' LD cutter inspect knife blades. Wear on top of blades chipped carbides 1.5" from tips. Metal filings in knife cavaties. 2,010.0 23.6 7/11/2025 04:00 7/11/2025 04:15 0.25 COMPZN, RPCOMP BHAH P LD cutter MU spear. 23.6 12.0 7/11/2025 04:15 7/11/2025 04:30 0.25 COMPZN, RPCOMP PULD P PU single joint and spear casing at wellhead. 12.0 28.0 7/11/2025 04:30 7/11/2025 08:00 3.50 COMPZN, RPCOMP CIRC P Pull 150K on casing. No movement. Line up to pump down drill pipe up 13- 5/8" casing. Close annular Break circulation 1 BPM at 175 PSI. Pump 300 BBls, FCP=940 PSI @ 4 BPM 28.0 28.0 7/11/2025 08:00 7/11/2025 08:30 0.50 COMPZN, RPCOMP FISH P Pull on 9-5/8" casing to 150K. Get top of spear to floor. Over pulling. Observe collar 5' down in stack. Makle multiple attemps to come up. Go to neutral 28.0 28.0 7/11/2025 08:30 7/11/2025 09:00 0.50 COMPZN, RPCOMP CIRC P Circulate, Work pipe up through stack. Appears to be hanging up on collars 28.0 40.0 7/11/2025 09:00 7/11/2025 10:00 1.00 COMPZN, RPCOMP BHAH P Set slips, Release spear and lay down. P/U FOSV & XO 40.0 40.0 7/11/2025 10:00 7/11/2025 11:30 1.50 COMPZN, RPCOMP CIRC P Make second circulation 270 BBls. 4 BPM @ 920 PSI OWFF 40.0 40.0 7/11/2025 11:30 7/11/2025 12:00 0.50 COMPZN, RPCOMP PULL P Pull 9 5/8" completion. PUw= 125K 40.0 120.0 7/11/2025 12:00 7/11/2025 19:00 7.00 COMPZN, RPCOMP RGRP T Chain attaching point on skate buggy broke. RR buggy to repair and reinstall. 120.0 120.0 7/11/2025 19:00 7/11/2025 23:15 4.25 COMPZN, RPCOMP PULL P LD 9-5/8" casing to 2010'. Cut joint measured 20.37'. Recovered 14 centralizers. 0.0 7/11/2025 23:15 7/12/2025 00:00 0.75 COMPZN, RPCOMP RURD P Clear floor after laying down 9-5/8" casing. RD GBR casing crew. RU safety valve to test BOP to casing head break 0.0 7/12/2025 00:00 7/12/2025 01:00 1.00 COMPZN, RPCOMP RURD P PU 9-5/8" test joint MU test plug to test joint. Set test plug. RU to test break and bag. Fill stack with fresh water. Rig: NABORS 7ES RIG RELEASE DATE 7/27/2025 Page 5/14 2M-29 Report Printed: 8/13/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/12/2025 01:00 7/12/2025 04:30 3.50 COMPZN, RPCOMP BOPE P Test casing head to BOP stack break , and annular to 250/3000 PSI. 7/12/2025 04:30 7/12/2025 05:00 0.50 COMPZN, RPCOMP RURD P Pull test plug and test joint. LD test joint. Set wear ring. Wear ring not seating in casing head. Jet profile. Try again. Locate one at ware house 7/12/2025 05:00 7/12/2025 11:00 6.00 COMPZN, RPCOMP WAIT T Wear rings at warehouse 13.45". we need 13.1. Locate one at Hillcorp. Hot shot it to rig 7/12/2025 11:00 7/12/2025 12:00 1.00 COMPZN, RPCOMP OTHR P Install wear ring in 9 5/8" casing head, 12.250 ID 0.0 0.0 7/12/2025 12:00 7/12/2025 13:00 1.00 COMPZN, RPCOMP BHAH P MU 13-5/8" Clean out/dress off BHA. T/75.07'. Planned to run 12.250" string reamer to aid in 13 3/8 clean up. ID of wear bushing 12.250. Going without reamer 0.0 69.0 7/12/2025 13:00 7/12/2025 14:30 1.50 COMPZN, RPCOMP TRIP P Trip in hole, BHA #5 Dress off mill. Set down @ 529'. PUH attempt to work through. Unable to work past, POOH. Drag marks on dress off shoe 69.0 0.0 7/12/2025 14:30 7/12/2025 18:30 4.00 COMPZN, RPCOMP WAIT T Gather up milling BHA, DC's, Jars, Bumper sub 0.0 0.0 7/12/2025 18:30 7/12/2025 20:30 2.00 COMPZN, RPCOMP BHAH T MU 10.875" OD String mill BHA. 0.0 139.7 7/12/2025 20:30 7/12/2025 21:30 1.00 COMPZN, RPCOMP TRIP T TIH to tag PUW=50K SOW=50K Tag at 623.5' Set down 17K' W/String mill. PUH to 608' KU. Establish milling parameters. PR=5 BPM at 90 PSI 65 RPM 715 free Tq. 139.7 623.5 7/12/2025 21:30 7/12/2025 23:15 1.75 COMPZN, RPCOMP MILL T Work through restriction at 623.5' T/624.5'. 2K drag rotation off. Work area till clean, Continue TIH Set down at 797.1' Set down Rot 86 RPM 1.2K Tq. PR=5 BPM 100 PSI ROTWT=53K Work down T/797.4' Tq on= Work through area till drifted clean. 623.5 797.4 7/12/2025 23:15 7/13/2025 00:00 0.75 COMPZN, RPCOMP TRIP T TIH to 1663', 797.4 1,663.0 7/13/2025 00:00 7/13/2025 00:30 0.50 COMPZN, RPCOMP TRIP T Continue to TIH to tag at 2021' Mill depth (7ES RKB) 1,663.0 2,021.0 7/13/2025 00:30 7/13/2025 01:15 0.75 COMPZN, RPCOMP TRIP T TOOH F/2021 PUW=70K T/797' 2,021.0 797.0 7/13/2025 01:15 7/13/2025 02:30 1.25 COMPZN, RPCOMP REAM T Ream through 797' and 623' 4 times 2K drag max. PU clean and TOOH. 797.0 623.0 7/13/2025 02:30 7/13/2025 03:00 0.50 COMPZN, RPCOMP TRIP T TOOH F/620' T/139.7' 623.0 139.7 7/13/2025 03:00 7/13/2025 05:00 2.00 COMPZN, RPCOMP BHAH T Rack back collars and change out string mill W/12.25" slick OD string mill. 139.7 139.2 7/13/2025 05:00 7/13/2025 13:15 8.25 COMPZN, RPCOMP TRIP T TIH F/139.2' T/ First tight area @ 233, 330, 539, 624, and 797'. Reaming performed @ 5 BPM @ 65 PSI, 75 RPM, FT=950 Lb/Ft. SOW=45K. Clear down to 1990', 139.2 1,990.0 7/13/2025 13:15 7/13/2025 14:45 1.50 COMPZN, RPCOMP TRIP T PUW=79K off bottom. Over pull @ 797 & 233 coming up 1,990.0 139.0 7/13/2025 14:45 7/13/2025 15:15 0.50 COMPZN, RPCOMP BHAH T Lay down BHA # 7 single 12.25 string reamer 139.0 0.0 7/13/2025 15:15 7/13/2025 16:00 0.75 COMPZN, RPCOMP BHAH T M/U BHA #8, 11 7/8" & 12 1/4" tandum string reamer 0.0 145.6 Rig: NABORS 7ES RIG RELEASE DATE 7/27/2025 Page 6/14 2M-29 Report Printed: 8/13/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/13/2025 16:00 7/13/2025 16:30 0.50 COMPZN, RPCOMP TRIP T RIH to 234'. KU Ream down @ 5 BPM @ 65 PSI, 75 RPM, FT=950 Lb/Ft. PUW=45K SOW=45K Mill through restrictions at 529' Tq on 1.5 PR 5BPM RPM 80 ROTW=45K 145.6 234.0 7/13/2025 16:30 7/13/2025 19:00 2.50 COMPZN, RPCOMP MILL T KU Ream down @ 5 BPM @ 65 PSI, 75 RPM, FT=950 Lb/Ft. PUW=45K SOW=45K Mill through restrictions at 236' and 529' Tq on=7.5 PR 5BPM=35 PSI RPM 80 ROTW=45K Drifted 797' 10K down passed through restriction. 234.0 797.0 7/13/2025 19:00 7/13/2025 20:00 1.00 COMPZN, RPCOMP TRIP T TIH to top of casing cut at 2010' 797.0 2,010.0 7/13/2025 20:00 7/13/2025 21:00 1.00 COMPZN, RPCOMP CIRC T Circulate 30 BBL 250 vis sweep, chase sweep SxS at 12 BPM. 2,010.0 797.0 7/13/2025 21:00 7/13/2025 21:30 0.50 COMPZN, RPCOMP TRIP T F/2010' T/797' 797.0 797.0 7/13/2025 21:30 7/14/2025 00:00 2.50 COMPZN, RPCOMP MILL T Back ream through restriction 2 times F/797-707' 90 RPM. freeTq. 900K Tq on -6-8K PR-5BPM 45 PSI. Shut down rotary drifted clean 529' Continue to PUH to restriction at 398' Work mills through restriction free Tq=1K Ft/Lbs 70 RPM ROT WT 50K pr 5BPM 30 PSI. Work through restriction multiple times torque spiked to 15K Ft/Lbs. 797.0 398.0 7/14/2025 00:00 7/14/2025 03:00 3.00 COMPZN, RPCOMP MILL T Work mills through restriction at 398' free Tq=1K Ft/Lbs 70 RPM ROT WT 50K pr 5BPM 30 PSI. Work through restriction multiple times. Observed torque spike to 15K Ft/Lbs. 80 RPM Rot wt=50K Torque on 5K-6K Ft/Lbs 5BPM 30 PSI Continue to work area till able to drift clean. PUH to 389K over pulled 10K PR=5 BPM 30 PSI 80 RPM worked area 398.0 398.0 7/14/2025 03:00 7/14/2025 03:15 0.25 COMPZN, RPCOMP TRIP T TOOH to BHA 398.0 145.7 7/14/2025 03:15 7/14/2025 03:30 0.25 COMPZN, RPCOMP OWFF T OWFF for 10 minutes 145.7 145.7 7/14/2025 03:30 7/14/2025 04:00 0.50 COMPZN, RPCOMP BHAH T Rack back collars and LD BHA to Bit sub. Recovered all of BHA to bit sub. Double pin , flex joint and bullnose LIH. 145.7 0.0 7/14/2025 04:00 7/14/2025 06:00 2.00 COMPZN, RPCOMP BHAH T MU Screw in BHA to fish Double pin from bottom of BHA. 0.0 127.0 7/14/2025 06:00 7/14/2025 09:00 3.00 COMPZN, RPCOMP FISH T RIH T/2402' tag, PUW=70K, SOW=65K 1/2 BPM @ 65 PSI, 15 RPM, FTQ=1000 See TQ up to 1300 on fish 127.0 2,402.0 7/14/2025 09:00 7/14/2025 11:00 2.00 COMPZN, RPCOMP TRIP T Trip out F//2402 T//122. PUW=70K 2,402.0 122.0 7/14/2025 11:00 7/14/2025 12:00 1.00 COMPZN, RPCOMP BHAH T Lay down screw in BHA. Recover bullnose, flex joint, and double pin. All LIH items recovered 122.0 0.0 7/14/2025 12:00 7/14/2025 13:00 1.00 COMPZN, RPCOMP BHAH T M/U BHA #9 Dress off mill 0.0 152.0 7/14/2025 13:00 7/14/2025 14:00 1.00 COMPZN, RPCOMP TRIP T Trip in well. Set down @ 524, PUW=50K, 20 RPM, FTQ=520. Little to know headway 152.0 523.0 Rig: NABORS 7ES RIG RELEASE DATE 7/27/2025 Page 7/14 2M-29 Report Printed: 8/13/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/14/2025 14:00 7/14/2025 14:30 0.50 COMPZN, RPCOMP TRIP T Trip out, PUW=50K 523.0 152.0 7/14/2025 14:30 7/14/2025 16:00 1.50 COMPZN, RPCOMP BHAH T Lay down BHA #9 Dress off mill. M/U tandum mills with increased spacing between mills. Call out XO's from tool house 152.0 0.0 7/14/2025 16:00 7/14/2025 19:00 3.00 COMPZN, RPCOMP BHAH T M/U tandem mills with increased spacing between mills. Call out XO's from tool house. 0.0 152.0 7/14/2025 19:00 7/14/2025 19:30 0.50 COMPZN, RPCOMP TRIP T TIH to tag at 522' PU Establish parameters 5 BPM 45 PSI, 85 RPM Free Tq.=1000 Ft/Lbs 152.0 522.0 7/14/2025 19:30 7/14/2025 21:00 1.50 COMPZN, RPCOMP MILL T Mill/hone restriction at 522'-559' Tq. on=2.5K-6K mill through area. Drift clean 522.0 569.0 7/14/2025 21:00 7/14/2025 21:15 0.25 COMPZN, RPCOMP TRIP T TIH to 860' TOOH F/860' T/152' 569.0 152.0 7/14/2025 21:15 7/15/2025 00:00 2.75 COMPZN, RPCOMP BHAH T LD String mill BHA MU reconfigured burn shoe BHA. 152.0 7/15/2025 00:00 7/15/2025 00:45 0.75 COMPZN, RPCOMP BHAH T Compete MU 9-5/8" Dress off BHA T/149.06' 0.0 149.1 7/15/2025 00:45 7/15/2025 02:00 1.25 COMPZN, RPCOMP TRIP T TIH to 218 set down rotated 1/4 rotation fell through PU clean. 317 set down 10K rotated string fell through. 350' set down 9-12K fell through 527' set down 10K rotated 5 RPM unable to pass through. Torque spiked to 7K. Pulled 10K over to get out of restriction. 149.1 529.0 7/15/2025 02:00 7/15/2025 03:00 1.00 COMPZN, RPCOMP TRIP T TOOH F/527' PUW=50K 529.0 149.0 7/15/2025 03:00 7/15/2025 05:00 2.00 COMPZN, RPCOMP BHAH T LD dress off BHA. MU reconfigured Stiff tandem string mill BHA. 13 149.0 171.0 7/15/2025 05:00 7/15/2025 09:30 4.50 COMPZN, RPCOMP TRIP T TIH F/171.19' T/ 575', Reaming 5 BPM @ 45 PSI, 80 RPM, FTQ=1.1K, 560' to 575'. 171.0 575.0 7/15/2025 09:30 7/15/2025 10:00 0.50 COMPZN, RPCOMP TRIP T Continue in to 927' 575.0 927.0 7/15/2025 10:00 7/15/2025 11:00 1.00 COMPZN, RPCOMP SLPC P Slip and cut 88' Drilling line 927.0 927.0 7/15/2025 11:00 7/15/2025 12:00 1.00 COMPZN, RPCOMP TRIP T Trip out of well 927.0 171.0 7/15/2025 12:00 7/15/2025 13:00 1.00 COMPZN, RPCOMP BHAH T Lay down BHA 13 171.0 0.0 7/15/2025 13:00 7/15/2025 14:00 1.00 COMPZN, RPCOMP BHAH T M/U BHA #14 Dress off mill 0.0 171.0 7/15/2025 14:00 7/15/2025 15:30 1.50 COMPZN, RPCOMP TRIP T Trip in well. Set down 527. Attempt to work through. Multiple RPM, pipe speed, and pump rates. No Go. Have shorter dress off mill coming 171.0 171.0 7/15/2025 15:30 7/15/2025 20:00 4.50 COMPZN, RPCOMP BHAH T Lay down BHA #14 and M/U BHA # 15 171.0 0.0 7/15/2025 20:00 7/15/2025 21:00 1.00 COMPZN, RPCOMP TRIP T RIH Tag up @ 365' W/ no issue Cont RIH t/ 1350' w/ no 2 small tag up @ 258' 365' 365.0 1,350.0 7/15/2025 21:00 7/15/2025 22:00 1.00 COMPZN, RPCOMP TRIP T POOH @ 360' 4k over pulled RIH T/ 435' B.R. 1,350.0 435.0 7/15/2025 22:00 7/15/2025 23:00 1.00 COMPZN, RPCOMP WASH T M/U Top drive Back ream @/ 435' String mill @ 359' Tq 4500 ib 80 rpm Lost 5K on string wt. w/ tq jumped 2/3K and lost wt 435.0 200.0 Rig: NABORS 7ES RIG RELEASE DATE 7/27/2025 Page 8/14 2M-29 Report Printed: 8/13/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/15/2025 23:00 7/16/2025 00:00 1.00 COMPZN, RPCOMP BHAH T POOH Stand Back BHA #15 Lost in hole 55.88 BHA # 15 Tot BHA in Hole Bull Nose,1- 6 1/2" D.C. XO ,String Mill, XO,XO.SOD String mill, XO,2.31' Bumper Sub left in hole. 200.0 0.0 7/16/2025 00:00 7/16/2025 06:00 6.00 COMPZN, RPCOMP WAIT T Wait on Fishing Tools F/ YJOS F/Dead Horse / Due to twisted off tools down hole 0.0 0.0 7/16/2025 06:00 7/16/2025 07:30 1.50 COMPZN, RPCOMP BHAH T Over shot on location, M/U BHA #16 9.5" overshot 0.0 197.6 7/16/2025 07:30 7/16/2025 08:30 1.00 COMPZN, RPCOMP TRIP T Trip in hole BHA #16,T//1900', KU, PUW=70K, SOW=65, Pump 2 BPM @ 45 PSI, 20 RPM FT= 1K 197.6 1,900.0 7/16/2025 08:30 7/16/2025 09:00 0.50 COMPZN, RPCOMP FISH T RBIH toward fish, Set down 1989 . Startede taking seigh @ 1986. shut down pump & rotation. PU. see additional weight ~1.5K. Set back down. depths are the same 1,900.0 1,989.0 7/16/2025 09:00 7/16/2025 10:00 1.00 COMPZN, RPCOMP TRIP T Trip out of well, PUW=76.5K 1,989.0 197.0 7/16/2025 10:00 7/16/2025 11:00 1.00 COMPZN, RPCOMP BHAH T At overshot to fish 197.0 0.0 7/16/2025 11:00 7/16/2025 12:30 1.50 COMPZN, RPCOMP BHAH T Release over shot from fish. recover all items left in hole. 55.8' 0.0 0.0 7/16/2025 12:30 7/16/2025 14:30 2.00 COMPZN, RPCOMP BHAH T Lay down fish. Clear and clean rig floor. 0.0 0.0 7/16/2025 14:30 7/16/2025 15:30 1.00 COMPZN, RPCOMP BHAH T M/U BHA #17. 9 5/16 dress off mill. Shorter version 0.0 111.0 7/16/2025 15:30 7/16/2025 17:30 2.00 COMPZN, RPCOMP TRIP P Trip in well to dress off 9 5/8" stump 111.0 2,013.5 7/16/2025 17:30 7/16/2025 19:30 2.00 COMPZN, RPCOMP MILL P Tag up @ 2010' P/U and Polish top of 9 5/8" casing WOB 4/6 K Tq 2000/3800 lb Polish F/ 2010't/2013.5' All Good 2,013.5 7/16/2025 19:30 7/16/2025 20:30 1.00 COMPZN, RPCOMP CIRC P Circ 50 BBls Hi-Vis Sweep Around @ 8 bbls min w/ 191 PSI 2,013.5 7/16/2025 20:30 7/16/2025 23:00 2.50 COMPZN, RPCOMP TRIP P POOH Stand Back 3 1/2" D.P 0.0 7/16/2025 23:00 7/17/2025 00:00 1.00 COMPZN, RPCOMP BHAH P L/D YJOS BHA and Pulled W.R. W/ FMC Hand 0.0 7/17/2025 00:00 7/17/2025 02:00 2.00 COMPZN, RPCOMP PUTB T Load Pipe Shed and R/U GBR Casing Equip F/ 9 5/8" 563 casing 0.0 0.0 7/17/2025 02:00 7/17/2025 02:30 0.50 COMPZN, RPCOMP PUTB T Hold PJSM w/ Rig crew and GBR casing crew 0.0 0.0 7/17/2025 02:30 7/17/2025 06:30 4.00 COMPZN, RPCOMP PUTB T P/U 9 5/8" casing 563 M/U TQ 16000K running cementeralizer every other joint 0.0 2,013.4 7/17/2025 06:30 7/17/2025 07:30 1.00 COMPZN, RPCOMP PUTB P Land casing splice @ 2013.4. Pull up to confirm latch 180 2,014.0 2,014.0 7/17/2025 07:30 7/17/2025 10:00 2.50 COMPZN, RPCOMP RURD P Drain stack - RU for pressure test, Load out GBR equipment 2,014.0 2,014.0 7/17/2025 10:00 7/17/2025 10:30 0.50 COMPZN, RPCOMP PRTS P Pressure test 9 5/8" casing 1000 PSI / 10 minutes - Good 2,014.0 2,014.0 7/17/2025 10:30 7/17/2025 11:00 0.50 COMPZN, RPCOMP RURD P R/D pressure test equipment - TIW valve 2,014.0 2,014.0 7/17/2025 11:00 7/17/2025 13:30 2.50 COMPZN, RPCOMP NUND P ND Stack to install 9 5/8" casing slips, NU BOPE Stack 2,014.0 2,014.0 7/17/2025 13:30 7/17/2025 15:00 1.50 COMPZN, RPCOMP RURD P Load up cement head & XO. Load Wiper dart, M/U Cement head 2,014.0 2,014.0 7/17/2025 15:00 7/17/2025 15:30 0.50 COMPZN, RPCOMP SFTY P Hold pre job safety - planning meeting with HES and rig crew 2,014.0 2,014.0 7/17/2025 15:30 7/17/2025 15:45 0.25 COMPZN, RPCOMP MPSP P .HES charge customer line with air 2,014.0 2,014.0 Rig: NABORS 7ES RIG RELEASE DATE 7/27/2025 Page 9/14 2M-29 Report Printed: 8/13/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/17/2025 15:45 7/17/2025 16:15 0.50 COMPZN, RPCOMP CIRC P Line up down 9 5/8' casing. Pump ES cement valve open @ 2640 PSI. Circulate 3 BPM @ 90 PSI. Shut down rig pump. Turn over to HES cementers 2,014.0 2,014.0 7/17/2025 16:15 7/17/2025 16:30 0.25 COMPZN, RPCOMP CMNT P Cementers flood lines. Perform 500 low 4000PSI high prsure test. Chasing leak 2,014.0 2,014.0 7/17/2025 16:30 7/17/2025 18:30 2.00 COMPZN, RPCOMP CIRC P Circulate 395 BBls 5 BPM 265 PSI 2,014.0 2,014.0 7/17/2025 18:30 7/17/2025 19:00 0.50 COMPZN, RPCOMP CMNT P Hold PJSM W/ cement crew and Mix and batch spacer 2,014.0 2,014.0 7/17/2025 19:00 7/17/2025 22:00 3.00 COMPZN, RPCOMP CMNT P Pump 5 bbls Fresh water and test line t/ 3500 psi All good All good and pump 20 bbls red Dye spacer and chase w/ 182 bbls 15.8 cement drop Plug and chase w/ 10 bbls water spacer .chase w/ rig pump displace w/ S/W @ 4.4 bbls min Bump plug @ 133.5 bbls Hold pres 2400 psi 10 mins All good Check plug Bleed off t/ 0 with no Flow All Good ( CIP @ 2040 Time) Calculated 45 bbls good cement returnes OA 2,014.0 2,014.0 7/17/2025 22:00 7/18/2025 00:00 2.00 COMPZN, RPCOMP CLEN P Wash up All surf Euip And R/D Halliburton Cement Head Prep f/ ND BOP 2,014.0 2,014.0 7/18/2025 00:00 7/18/2025 02:00 2.00 COMPZN, RPCOMP WWSP P N/D BOP , Deenergize Koomey. Raise stack 2,014.0 7/18/2025 02:00 7/18/2025 03:00 1.00 COMPZN, RPCOMP WWSP P Cut 9 5/8" Casing W/ FMC Wachs Saw cutter and L/D cut jt 35.09' 9 5/8" 7/18/2025 03:00 7/18/2025 05:30 2.50 COMPZN, RPCOMP WWSP P Polish up 9 5/8"Stub. Install Packoffs. ,Install,Tubing spool test Packoffs 3000 PSI / 10 minutes 7/18/2025 05:30 7/18/2025 06:00 0.50 COMPZN, RPCOMP SVRG P Service Rig, Lube draw works 7/18/2025 06:00 7/18/2025 08:30 2.50 COMPZN, RPCOMP NUND P Install DSA onto tubing spool, NU BOPE 7/18/2025 08:30 7/18/2025 09:00 0.50 COMPZN, RPCOMP SEQP P Test BOPE at flange breaks, 250/3000 7/18/2025 09:00 7/18/2025 10:00 1.00 COMPZN, RPCOMP RURD P Lay down test tool, Pull test plug, R/D test hoses 7/18/2025 10:00 7/18/2025 10:30 0.50 COMPZN, RPCOMP RURD P Install wear ring 9" ID 7/18/2025 10:30 7/18/2025 12:30 2.00 COMPZN, RPCOMP BHAH P M/U BHA #18, Mill cement, wiper dart, cement to top of sand 0.0 195.4 7/18/2025 12:30 7/18/2025 13:30 1.00 COMPZN, RPCOMP TRIP P Trip in hole to 1897 195.4 1,897.0 7/18/2025 13:30 7/18/2025 14:00 0.50 COMPZN, RPCOMP MILL P KU stand 19, PUW 75K, SOW=65K, RPM=25, FT 1,897.0 1,897.0 7/18/2025 14:00 7/19/2025 00:00 10.00 COMPZN, RPCOMP MILL P RIH, tag @ 1963 start milling. See rubber on shaker from 1991. Avg. ROP 5 FPM UW 75 DW 65 Rot 70 WOB 6-15 Pumping @ 10 bbls min w/600 PSI Cont to wash down F/ 2010'T/2402' Flow Check All Good 1,897.0 2,403.0 7/19/2025 00:00 7/19/2025 02:00 2.00 COMPZN, RPCOMP CIRC P P/U and pump 50 bbls sweep around @ 2403' / Flow check 10 mins All Good 2,403.0 2,403.0 7/19/2025 02:00 7/19/2025 03:30 1.50 COMPZN, RPCOMP TRIP P POOH 2,403.0 195.0 7/19/2025 03:30 7/19/2025 05:00 1.50 COMPZN, RPCOMP BHAH P L/D BHA # 18 / M/U BHA # 19 W/ RCJB 195.0 137.4 7/19/2025 05:00 7/19/2025 06:00 1.00 COMPZN, RPCOMP BHAH P RIH w/ BHA #19 137.4 2,405.0 7/19/2025 06:00 7/19/2025 07:00 1.00 COMPZN, RPCOMP TRIP P RIH T/ Dry rag @ 2405, 2,405.0 2,405.0 Rig: NABORS 7ES RIG RELEASE DATE 7/27/2025 Page 10/14 2M-29 Report Printed: 8/13/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/19/2025 07:00 7/19/2025 09:00 2.00 COMPZN, RPCOMP OTHR P P/U Circ. 12 BPM @670 PSI. Jet down to hard bottom @ 2405 X3. Rotate 10 RPM FT 1300Ft/Lb. . Unable to make progress, 2,405.0 2,405.0 7/19/2025 09:00 7/19/2025 10:00 1.00 COMPZN, RPCOMP TRIP P Trip out of well 2,405.0 137.0 7/19/2025 10:00 7/19/2025 11:00 1.00 COMPZN, RPCOMP BHAH P Break down BHA #19 RCJB, No recovery. Cage is gutted Signs of junk in hole, 137.0 0.0 7/19/2025 11:00 7/19/2025 11:30 0.50 COMPZN, RPCOMP BHAH P M/U BHA #20 8.5"" junk mill 0.0 45.7 7/19/2025 11:30 7/19/2025 13:00 1.50 COMPZN, RPCOMP TRIP P Trip in hole to dry tag @ 2405 45.7 2,405.0 7/19/2025 13:00 7/19/2025 14:30 1.50 COMPZN, RPCOMP MILL P PUH, Rotate 30 RPM, FT=1.5, Start dry milline @2405 to 2408 7 to 10 K WOB 2,405.0 2,408.0 7/19/2025 14:30 7/19/2025 16:00 1.50 COMPZN, RPCOMP TRIP P POOH L/D Mill 2,408.0 45.0 7/19/2025 16:00 7/19/2025 16:30 0.50 COMPZN, RPCOMP BHAH P M/U BHA 21 w/ RCJB 45.0 7/19/2025 16:30 7/19/2025 17:30 1.00 COMPZN, RPCOMP TRIP P RIH W/ Tag 2408' 30.0 2,408.0 7/19/2025 17:30 7/19/2025 18:00 0.50 COMPZN, RPCOMP CIRC P Wash and Rot 6" no go @2405 to 2408 7 to 10 K WOB 2,405.0 2,408.0 7/19/2025 18:00 7/19/2025 19:00 1.00 COMPZN, RPCOMP TRIP P POOH 2,408.0 7/19/2025 19:00 7/19/2025 19:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA # 21 W/ cage w/ no Fingers 0.0 7/19/2025 19:30 7/19/2025 20:00 0.50 COMPZN, RPCOMP BHAH P M/U BHA # 22 RCJB 0.0 7/19/2025 20:00 7/19/2025 21:00 1.00 COMPZN, RPCOMP TRIP P RIH No Rot Tag @ 2408' 2,408.0 7/19/2025 21:00 7/20/2025 00:00 3.00 COMPZN, RPCOMP CIRC P C/O Fuild F/ 8.5 S/W T/ 10.9 Brine Attempt To Fill RCJB W/ RCJB Fingers or Junk 2,408.0 7/20/2025 00:00 7/20/2025 01:00 1.00 COMPZN, RPCOMP CIRC P Continue Swap out Fluids f/ 8.6 T/10.9 Brine 2,408.0 7/20/2025 01:00 7/20/2025 02:00 1.00 COMPZN, RPCOMP TRIP P POOH 2,408.0 0.0 7/20/2025 02:00 7/20/2025 02:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA # 22 W/ 10 RCJB Fingers Missing Tot Left in Hole 34 Small fingers 0.0 0.0 7/20/2025 02:30 7/20/2025 03:00 0.50 COMPZN, RPCOMP BHAH P M/U BHA #23 w/ 4.1' extension W/ RCJB T/ the Fingers 0.0 0.0 7/20/2025 03:00 7/20/2025 03:30 0.50 COMPZN, RPCOMP TRIP P RIH and Tag up @ 2406' PUW=65K, SOW=60K 0.0 2,408.0 7/20/2025 03:30 7/20/2025 04:00 0.50 COMPZN, RPCOMP MILL P Wash and Mill F/ 2406 T/ 2406, 10 BPM @ 790 PSI Recip area 2,408.0 2,408.0 7/20/2025 04:00 7/20/2025 05:00 1.00 COMPZN, RPCOMP TRIP P Trip out, PUW=65K 2,408.0 137.0 7/20/2025 05:00 7/20/2025 05:30 0.50 COMPZN, RPCOMP BHAH P Lay down BHa #23.Inspect reverse flow junk basket. . Very little recovered 137.0 0.0 7/20/2025 05:30 7/20/2025 06:30 1.00 COMPZN, RPCOMP BHAH P P/U RCJB & single. RIH. Kick on pumpe. Inspect jetting action. Looks good. M/U BHA #24 RCJB 0.0 45.8 7/20/2025 06:30 7/20/2025 07:30 1.00 COMPZN, RPCOMP TRIP P Trip in hole,, 45 to 2404. KU. 45.8 2,403.0 7/20/2025 07:30 7/20/2025 09:00 1.50 COMPZN, RPCOMP WASH P KU, Online with pumps 10 BPM @ 900 PSI, Rotate 20 to r50 RPM, Washed - ream in small steps to 2409 2,403.0 2,409.0 7/20/2025 09:00 7/20/2025 09:30 0.50 COMPZN, RPCOMP TRIP P Trip out F2403 to 45 2,409.0 45.0 Rig: NABORS 7ES RIG RELEASE DATE 7/27/2025 Page 11/14 2M-29 Report Printed: 8/13/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/20/2025 09:30 7/20/2025 11:00 1.50 COMPZN, RPCOMP BHAH P Lay down BHA #24 45.0 0.0 7/20/2025 11:00 7/20/2025 11:30 0.50 COMPZN, RPCOMP BHAH P M/U BHA #25 to jet - circulate long way Wavey bottom shoe 0.0 53.8 7/20/2025 11:30 7/20/2025 12:00 0.50 COMPZN, RPCOMP TRIP P Trip in hole to 2386' KU 53.8 2,386.0 7/20/2025 12:00 7/20/2025 14:30 2.50 COMPZN, RPCOMP CIRC P Establish circulation 10 BPM @ 900 PSI. Wash down to 2408. Pump 40 BBL 10.9 PPG Hi Vis Sweep. circulate around. Recip around bottom. Get sweep at surface Minimal naterial in sweep 2,386.0 2,408.0 7/20/2025 14:30 7/20/2025 15:00 0.50 COMPZN, RPCOMP TRIP P POOH, PUW=60 K 2,408.0 53.0 7/20/2025 15:00 7/20/2025 15:30 0.50 COMPZN, RPCOMP BHAH P Lay down BHA #25 53.0 0.0 7/20/2025 15:30 7/20/2025 16:30 1.00 COMPZN, RPCOMP BHAH P M/U BHA #26. RBP retrival tool 0.0 25.0 7/20/2025 16:30 7/20/2025 18:00 1.50 COMPZN, RPCOMP TRIP P RIH and Tag @ 2408' 25.0 2,408.0 7/20/2025 18:00 7/20/2025 18:30 0.50 COMPZN, RPCOMP FISH P Attempt To Latch up No Go 0.0 2,408.0 7/20/2025 18:30 7/20/2025 19:30 1.00 COMPZN, RPCOMP TRIP P POOH 2,408.0 0.0 7/20/2025 19:30 7/20/2025 20:00 0.50 COMPZN, RPCOMP BHAH P L/D BHA # 26 0.0 0.0 7/20/2025 20:00 7/20/2025 20:30 0.50 COMPZN, RPCOMP PRTS P Test Casing 2500 PSI 10 Mins All Good 0.0 0.0 7/20/2025 20:30 7/20/2025 23:30 3.00 COMPZN, RPCOMP DSL T R/U Slick Line T/ Run in Hole W/ Impression Block RIH W/ 7"LIB Tag up @ 2017' No Go POH L/D LIB W/ No Bottom Marks and scratches on the side. We think due to angle of holeR/D Slickline Unit 0.0 2,017.0 7/20/2025 23:30 7/21/2025 00:00 0.50 COMPZN, RPCOMP BHAH T Discuss w/ town engineer to go in with burning shoe M/U BHA #27 W/ 8,5 Burn over shoe 0.0 0.0 7/21/2025 00:00 7/21/2025 00:30 0.50 COMPZN, RPCOMP BHAH P Continue t/ M/U BHA # 27 W/ 8 1/2" Shoe 0.0 2,408.0 7/21/2025 00:30 7/21/2025 01:30 1.00 COMPZN, RPCOMP TRIP P RIH w/D.P Tag up @ 2407' 2,407.0 7/21/2025 01:30 7/21/2025 07:30 6.00 COMPZN, RPCOMP MILL P Start Milling on Junk W/ shoe @ 2407' UW 75 DW 62 Rot Wt 70 25 - 60 RPM Tq 2-3 Pumping @ 3-6 bbls w/ 350 PSI T/ 550 PSI cut 2.5 ' of Junk 2,407.0 2,408.0 7/21/2025 07:30 7/21/2025 09:00 1.50 COMPZN, RPCOMP TRIP P POOH 2,408.0 0.0 7/21/2025 09:00 7/21/2025 10:00 1.00 COMPZN, RPCOMP BHAH P L/D BHA # 27 M/U BHA #28 0.0 0.0 7/21/2025 10:00 7/21/2025 11:00 1.00 COMPZN, RPCOMP FISH P Tag Up @ 2406'Start Milling on Junk W/ shoe @ 2407' UW 75 DW 62 Rot Wt 70 25 - 60 RPM Tq 2-3 Pumping @ 3-6 bbls w/ 350 PSI T/ 550 PSI cut 1.2 ' of Junk 2,406.0 2,407.0 7/21/2025 11:00 7/21/2025 13:00 2.00 COMPZN, RPCOMP TRIP P POOH L/D BHA # 28 M/U BHA #29 7/21/2025 13:00 7/21/2025 15:00 2.00 COMPZN, RPCOMP TRIP T RIH W/ Retrieval tool assy No Go Attempt To Latch up unsuccessful 0.0 2,408.0 7/21/2025 15:00 7/21/2025 17:00 2.00 COMPZN, RPCOMP TRIP T POOH L/D Retrieval and M/U 5" Grapple Over Shot RIH BHA #30 0.0 2,408.0 7/21/2025 17:00 7/21/2025 18:00 1.00 COMPZN, RPCOMP TRIP T RIH and Latch on RBP Rig: NABORS 7ES RIG RELEASE DATE 7/27/2025 Page 12/14 2M-29 Report Printed: 8/13/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/21/2025 18:00 7/21/2025 22:00 4.00 COMPZN, RPCOMP FISH T Pull RBP free Move up hole 20' No go Move RBP Down Work RBP down T/ 2515' Stop Moveing Attempt to move RBP down and up w/ no success 2,408.0 2,408.0 7/21/2025 22:00 7/22/2025 00:00 2.00 COMPZN, RPCOMP TRIP T Release F/ RBP @ 2515' POOH T/ P/U Drilling Jars and 9-6 1/4" D.C 0.0 2,515.0 7/22/2025 00:00 7/22/2025 02:00 2.00 COMPZN, RPCOMP OTHR T Continue t/ wait on the Drilling Jars F/ Dead Horse SLB Jars 2,515.0 0.0 7/22/2025 02:00 7/22/2025 04:00 2.00 COMPZN, RPCOMP BHAH T M/U BHA # 31 0.0 393.0 7/22/2025 04:00 7/22/2025 06:00 2.00 COMPZN, RPCOMP TRIP T RIH and Latch up @ 2515' 393.0 2,500.0 7/22/2025 06:00 7/22/2025 07:00 1.00 COMPZN, RPCOMP FISH T Continue Attempt to pull 9 5/8" PKR Free Jarred Down 12 Time W/ 35K w/ no success Jarred up 3 time Grapple pulled free or something broke 2,500.0 2,500.0 7/22/2025 07:00 7/22/2025 08:00 1.00 COMPZN, RPCOMP TRIP T POOH 2,500.0 393.0 7/22/2025 08:00 7/22/2025 09:30 1.50 COMPZN, RPCOMP BHAH T Stand Back BHA # 31 // Recovered 4' of plug and mandrle 393.0 0.0 7/22/2025 09:30 7/22/2025 10:30 1.00 COMPZN, RPCOMP CLEN T Clean and clear rig floor // send BHA down to pipe shed 0.0 0.0 7/22/2025 10:30 7/22/2025 11:30 1.00 COMPZN, RPCOMP RURD T Rig up test equipment // bring in test joints 0.0 0.0 7/22/2025 11:30 7/22/2025 13:00 1.50 COMPZN, RPCOMP OTHR T Flood surface lines // Grease Valves // Shell test BOPs 0.0 0.0 7/22/2025 13:00 7/22/2025 17:30 4.50 COMPZN, RPCOMP BOPE P Start testing BOPE. Initial BOPE test, Tested BOPE at 250/3000 PSI for 5 Min each, Tested annular on 3-1/2" test joint, UVBR's, w/3 -1/2" test joint. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 3 1/2" HT-38 safety valve, FOSV, and IBOP. Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=3050 PSI, after closure=1600 PSI, 200 PSI attained =15 sec, full recovery attained = 184 sec. UVBR's= 6 sec, Annular= 19 sec. Simulated blinds= 6 sec. LVBR’s=6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2100 PSI. Test gas detectors, PVT and flow show. Test Witness Waived by AOGCC rep Guy Cook, Annular preventer fail pass. Would not hold closing pressure. Observed and replace leaking hydraulic hose. 0.0 0.0 7/22/2025 17:30 7/22/2025 18:30 1.00 COMPZN, RPCOMP CLEN T R/D Test Euip and Blow All Equip Down and Install W.R W/ FMC Hand 0.0 7/22/2025 18:30 7/22/2025 19:30 1.00 COMPZN, RPCOMP BHAH T M/U BHA # 32 W/ RCJB 7/22/2025 19:30 7/22/2025 20:30 1.00 COMPZN, RPCOMP TRIP T RIH and Tag @ 2517' 7/22/2025 20:30 7/22/2025 21:30 1.00 COMPZN, RPCOMP MILL T Mill on Top of PKR @ 2517 W/ RCJB UW 68 DW 62 Rot 65 about 45 mins 7/22/2025 21:30 7/22/2025 22:30 1.00 COMPZN, RPCOMP TRIP T POOH Rig: NABORS 7ES RIG RELEASE DATE 7/27/2025 Page 13/14 2M-29 Report Printed: 8/13/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/22/2025 22:30 7/22/2025 23:30 1.00 COMPZN, RPCOMP BHAH T L/D RCJB and Shoe W/ no Junk in RCJB Clean M/U BHA # 33 W/ Burning shoe 7/22/2025 23:30 7/23/2025 00:00 0.50 COMPZN, RPCOMP TRIP T RIH 7/23/2025 00:00 7/23/2025 00:30 0.50 COMPZN, RPCOMP TRIP T Continue t/ RIH W/shoe T/ 2516' 0.0 2,517.0 7/23/2025 00:30 7/23/2025 03:30 3.00 COMPZN, RPCOMP MILL T Tag top RPB @ 2517' Start Milling @ 2517' UW 75 DW 55 Rot wt 70 @ 3 bbls min w/ 110 PSI w/60 RPM Free Tq 1900 -4500 Cut 2517.6 Pump 40 bbls Sweep around. 2,517.0 2,517.6 7/23/2025 03:30 7/23/2025 04:30 1.00 COMPZN, RPCOMP TRIP T POOH 2,517.6 337.0 7/23/2025 04:30 7/23/2025 05:30 1.00 COMPZN, RPCOMP BHAH T Rack collars, inspect mill shoe found lttle wear and slips in boot basket 337.0 0.0 7/23/2025 05:30 7/23/2025 06:00 0.50 COMPZN, RPCOMP CLEN T Clean and clear rig floor 0.0 0.0 7/23/2025 06:00 7/23/2025 07:00 1.00 COMPZN, RPCOMP BHAH T Pick up Taper Tap BHA# 34 0.0 228.0 7/23/2025 07:00 7/23/2025 08:30 1.50 COMPZN, RPCOMP TRIP T TIH to top of fish @ 2,517' 228.0 2,517.0 7/23/2025 08:30 7/23/2025 09:00 0.50 COMPZN, RPCOMP FISH T Work down T/ 2600' no indication of fish 2,517.0 2,600.0 7/23/2025 09:00 7/23/2025 11:45 2.75 COMPZN, RPCOMP PULD T Continue in hole with singles drill pipe T/ 5026' 2,600.0 5,026.0 7/23/2025 11:45 7/23/2025 13:00 1.25 COMPZN, RPCOMP CIRC T Circulate well to get well in balance 5,026.0 5,026.0 7/23/2025 13:00 7/23/2025 17:30 4.50 COMPZN, RPCOMP PULD T Continue in hole F/ 5,026' picking up singles T/ 9800' 5,026.0 9,800.0 7/23/2025 17:30 7/23/2025 19:00 1.50 COMPZN, RPCOMP CIRC T Circ B/U @ 8 bbls min w/ 2300 PSI 5,056.0 9,800.0 7/23/2025 19:00 7/23/2025 20:00 1.00 COMPZN, RPCOMP TRIP T RIH Tag fish 9816 ' 9,816.0 9,818.0 7/23/2025 20:00 7/23/2025 21:00 1.00 COMPZN, RPCOMP FISH T Fishing F/ 9816 / to T/ 9819' Screwed in taper tap about 8/10 " Small pres increase 40/50 PSI P/U W/ 3/6 K over String wt 9,819.0 5,000.0 7/23/2025 21:00 7/24/2025 00:00 3.00 COMPZN, RPCOMP TRIP T POOH and Stand Back 3 1/2" D.P. 5,000.0 2,000.0 7/24/2025 00:00 7/24/2025 01:00 1.00 COMPZN, RPCOMP TRIP P Continue POOH 2,000.0 0.0 7/24/2025 01:00 7/24/2025 03:15 2.25 COMPZN, RPCOMP BHAH P L/D Fish BHA # 34 W/ 9 5/8" PKR w/ Bull nose and C/U Floor M/U BHA # 35 0.0 250.0 7/24/2025 03:15 7/24/2025 06:00 2.75 COMPZN, RPCOMP TRIP P RIH W/ D.P 250.0 9,750.0 7/24/2025 06:00 7/24/2025 07:30 1.50 COMPZN, RPCOMP SLPC P Slip and cut drill line 9,750.0 9,750.0 7/24/2025 07:30 7/24/2025 09:30 2.00 COMPZN, RPCOMP FISH P Obtain perameters // Pu Wt 175 Dn Wt 90K // Tag stump @ 9,822', work overshot over pipe T/ 9,825.9', Pu 50K over confirm latch // Straight pull 50K allow jars to bleed, not to exceed 60K shear on packer // Work seals up to 50K 12 times 9,750.0 9,825.9 7/24/2025 09:30 7/24/2025 13:00 3.50 COMPZN, RPCOMP TRIP P Release from fish, OWFF, TOOH to BHA 9,825.9 346.0 7/24/2025 13:00 7/24/2025 14:00 1.00 COMPZN, RPCOMP BHAH P Lay down BHA# 35 and inspect 346.0 0.0 7/24/2025 14:00 7/24/2025 15:00 1.00 COMPZN, RPCOMP PRTS P Rig up test equipment, test casing aginst blinds and rbp @ 9,912' unable to get passing test 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/27/2025 Page 14/14 2M-29 Report Printed: 8/13/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/24/2025 15:00 7/24/2025 17:00 2.00 COMPZN, RPCOMP BHAH P Pick up 9 5/8" Test packer BHA# 36 0.0 7/24/2025 17:00 7/24/2025 19:30 2.50 COMPZN, RPCOMP TRIP P RIH T/ 3000' 0.0 3,000.0 7/24/2025 19:30 7/24/2025 20:00 0.50 COMPZN, RPCOMP PRTS P Set PKR and Test 9 5/8" T/ Surf T/ 2500 PSI IA 15 mis all good Pres up down Tubing No Good 7/24/2025 20:00 7/24/2025 23:00 3.00 COMPZN, RPCOMP TRIP P Release PKR and Continue RIH T/ 9750' 3,000.0 9,750.0 7/24/2025 23:00 7/24/2025 23:30 0.50 COMPZN, RPCOMP PRTS P Set PKR @ 9750' Retest IA T/ 2500 PSI All Good Attempt to Tested Down D.P No Go 7/24/2025 23:30 7/25/2025 00:00 0.50 COMPZN, RPCOMP TRIP P Release PKR POOH 9,750.0 6,000.0 7/25/2025 00:00 7/25/2025 04:30 4.50 COMPZN, RPCOMP TRIP P POOH F/ 9782' T/ 344' 6,000.0 7/25/2025 04:30 7/25/2025 05:30 1.00 COMPZN, RPCOMP BHAH P L/D BHA # 36 Test PKR Assy 7/25/2025 05:30 7/25/2025 06:00 0.50 COMPZN, RPCOMP SVRG P Serivce Rig 7/25/2025 06:00 7/25/2025 07:30 1.50 COMPZN, RPCOMP BHAH P M/U BHA # 37 7/25/2025 07:30 7/25/2025 10:00 2.50 COMPZN, RPCOMP TRIP P RIH F/ 334' T/ 9680' 334.0 9,680.0 7/25/2025 10:00 7/25/2025 14:30 4.50 COMPZN, RPCOMP WASH P Reaming / washing over Stump until Clean F/ 9815' T/ 9829' All Good and CBU High rate All Good 7/25/2025 14:30 7/25/2025 22:30 8.00 COMPZN, RPCOMP TRIP P POOH and L/D 3 1/2" D.P. 334.0 0.0 7/25/2025 22:30 7/26/2025 00:00 1.50 COMPZN, RPCOMP BHAH P L/D BHA and Clean up Floor 0.0 0.0 7/26/2025 00:00 7/26/2025 02:30 2.50 COMPZN, RPCOMP RURD P Continue R/U To Run 3 1/2" Completion W/ Poor Boy Overshot W/ Stack PKR Load Pipe Shed W/ 3 1/2" Completion Assembly. 0.0 0.0 7/26/2025 02:30 7/26/2025 16:00 13.50 COMPZN, RPCOMP PULD P Hold PJSM M/U 3 1/2" Completion Assy W/ Poor Boy over shot and P/U 3 1/2" EUE-M 9.3 # Tubing w/ 9 5/8" Stack Packer Assy 0.0 9,820.0 7/26/2025 16:00 7/26/2025 16:45 0.75 COMPZN, RPCOMP HOSO P Obtain up and dn wts // Up wt 95 Dn wt 59 // Tag top of stump 9826.5' // Shear screws @ 9830.5' // NG @ 9833.5' // Calculate space out pick up pup jts 4.22 and 2.08 install below JT 309, make up hanger space out for CI 9,820.0 9,833.0 7/26/2025 16:45 7/26/2025 21:45 5.00 COMPZN, RPCOMP DISP P Displace IA to 10.9# CI Brine // Pump 3 bpm @ 450 psi 9,833.0 9,820.0 7/26/2025 21:45 7/26/2025 23:15 1.50 COMPZN, WHDBOP THGR P M/U Hanger and Land Tubing Hanger RILDS, Drop Rod and Ball Test Tubing T/ 3500 PSI set PKR Bleed Down T/1600 PSI Test IA T/ 2500 PSI 30 mins All Good Bleed Down Tubing Shear out SOV All Good Final Sring WT UW95 Land the Hanger DN60K 9,820.0 9,820.0 7/26/2025 23:15 7/27/2025 00:00 0.75 COMPZN, WHDBOP SEQP P L/D Land Jt Ck SOV and Circ 2 BBLs Around All Good Test BPV and Test T/ 1000 PSI All Good 0.0 0.0 7/27/2025 00:00 7/27/2025 08:00 8.00 DEMOB, MOVE RURD P RDMO of 2M-29. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/27/2025 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 10,400.0 2M-29 2/3/2025 pottej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled RBP 2M-29 8/18/2025 zembaej 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 20 18.94 44.0 121.0 121.0 91.50 H-40 WELDED SURFACE 13 3/8 12.41 42.7 3,669.3 2,776.2 68.00 L-80 BTC Production Upper 9 5/8 8.68 27.2 2,012.0 1,876.4 47.00 T-95 563 Production 9 5/8 8.68 2,010.7 10,405.0 6,049.1 47.00 L-80 BTC LINER 7 6.28 10,096.0 13,001.7 6,146.4 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth … 9,848.0 String Max No… 3 1/2 Set Depth … 5,826.1 Tubing Description Tubing – Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RD 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) 25.8 25.8 0.03 Hanger 6.980 FMC 3-1/2" Tubing Hanger w/ 3.5 EUE 8rd Top & Bottom FMC GEN 4 2.960 3,386.9 2,636.5 61.39 Mandrel – GAS LIFT 5.680 3.5" X 1" MMG, GLM w/DV & BK Latch, SN# 24758-10 SLB MMG 2.900 7,011.9 4,437.6 62.23 Mandrel – GAS LIFT 5.681 3.5" X 1" MMG, GLM w/DV & BK Latch, SN# 25489-10 SLB MMG 2.900 9,615.5 5,712.5 60.17 Mandrel – GAS LIFT 5.682 3.5" X 1" KBMG, GLM w/SOV 2000 psi & BEK Latch, SN# 25489-01 SLB MMG 2.900 9,672.0 5,740.4 60.78 Packer 8.218 Tripoint DLH Packer 3 1/2 X 9-5/8" Tri-Point 9.625 x 3.5 2.813 9,757.3 5,782.0 60.81 Nipple - X 4.514 3.5" x 2.813" X-Landing SN#0004993357 HES X Nipple 2.813 9,841.1 5,822.8 61.08 Overshot 6.000 3.5" x 8.25" Poorboy Overshot (6.2' of swallow) 2' From fully located Baker Poorboy Oversho t 3.610 Top (ftKB) 9,845.0 Set Depth … 9,991.7 String Max No… 3 1/2 Set Depth … 5,893.3 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection 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) 9,877.4 5,840.3 61.42 SBE 5.000 BAKER 80-40 SEAL BORE EXTENSION Baker 80-48 3.000 9,890.8 5,846.7 61.54 PACKER 8.460 BAKER FHL RETRIEVABLE PACKER Baker T&C Upset 2.930 9,936.5 5,868.2 62.42 NIPPLE 5.390 CAMCO DS NIPPLE T&C Upset 2.812 9,975.0 5,885.8 63.03 LOCATOR 4.000 BAKER LOCATOR SUB T&C Upset 3.000 9,975.8 5,886.1 63.04 SEAL ASSY 4.000 BAKER GBH 80-40 SEAL ASSY T&C Upset 3.000 9,987.7 5,891.5 63.24 STINGER 2.992 STINGER STABBED INTO ORIGINAL 'FH' FAILED PACKER T&C Upset 2.812 Top (ftKB) 9,991.2 Set Depth … 11,356.1 String Max No… 3 1/2 Set Depth … 6,149.4 Tubing Description TUBING Original Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-ABM 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) 9,991.2 5,893.1 63.30 PACKER 8.218 BAKER FH RETRIEVABLE PACKER (PACKER FAILED, REASON FOR 2007 WORKOVER) BAKER FH 3.000 10,030.8 5,910.6 64.34 NIPPLE 4.540 CAMCO DS NIPPLE w/NO GO PROFILE CAMCO DS 2.812 10,037.9 5,913.6 64.57 GAS LIFT 6.018 CAMCO MMM CAMCO MMM 2.920 10,121.7 5,948.0 66.90 SLEEVE-C 4.500 BAKER CMU SLIDING SLEEVE (CLOSED) BAKER CMU 2.812 10,760.0 6,117.8 85.08 BLAST JT 4.500 STEEL BLAST JOINTS (OAL - 158') SBJ 3.476 10,924.6 6,139.6 82.74 SLEEVE-C 4.500 BAKER CMU SLIDING SLEEVE (CLOSED 3/6/1997) BAKER CMU 2.812 10,961.1 6,143.8 83.98 SEAL ASSY 4.500 BAKER GBH-22 LOCATOR/SEAL ASEMBLY, 4" SEAL BORE BAKER GBH-22 3.000 10,962.9 6,144.0 84.05 PACKER 5.875 BAKER FB-1 PACKER BAKER FB-1 4.000 10,966.2 6,144.4 84.18 SBE 5.000 BAKER SEAL BORE EXTENSION BAKER 4.000 11,010.1 6,148.3 85.45 NIPPLE 4.540 CAMCO D NIPPLE w/NO GO PROFILE CAMCO D 2.750 11,355.3 6,149.4 91.42 SOS 4.000 CAMCO Muleshoe WLEG w/seat removed CAMCO 2.992 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) 27.2 27.2 0.03 EMERGENCY SLIPS 7/22/2025 9.875 9,845.0 5,824.7 61.13 CUT WELLTEC MECHANICAL TBG CUT AT 9845' RKB 2/25/2025 2.992 2M-29, 8/21/2025 11:34:29 AM Vertical schematic (actual) LINER; 10,096.0-13,001.7 FISH; 12,911.0 IPERF; 12,650.0-12,850.0 FRAC; 12,650.0 IPERF; 12,300.0-12,550.0 IPERF; 11,720.0-12,180.0 Liner Cement; 10,395.0 ftKB IPERF; 11,430.0-11,550.0 PACKER; 10,962.9 IPERF; 10,850.0-10,900.0 FRAC; 10,760.0 IPERF; 10,760.0-10,850.0 Production; 2,010.7-10,405.0 TIGHT SPOT; 10,378.0 Primary – Full Bore; 9,850.0 ftKB GAS LIFT; 10,037.9 PACKER; 9,991.2 LEAK; 9,923.0 PACKER; 9,890.8 SBE; 9,877.4 LEAK; 9,850.0 CUT; 9,845.0 Nipple - X; 9,757.2 Packer; 9,672.0 Mandrel – GAS LIFT; 9,615.5 Mandrel – GAS LIFT; 7,011.9 SURFACE; 42.7-3,669.3 Mandrel – GAS LIFT; 3,386.9 Production Upper; 27.3-2,012.0 Primary – Full Bore; 46.0 ftKB Liner Cement; 27.2 ftKB CONDUCTOR; 44.0-121.0 EMERGENCY SLIPS; 27.2 Hanger; 25.8 KUP PROD KB-Grd (ft) -54.00 RR Date 10/21/199 2 Other Elev… 2M-29 ... TD Act Btm (ftKB) 13,015.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032018300 Wellbore Status PROD Max Angle & MD Incl (°) 91.55 MD (ftKB) 11,416.90 WELLNAME WELLBORE2M-29 Annotation Last WO: End Date 1/9/2007 H2S (ppm) 20 Date 12/20/2012 Comment SSSV: NIPPLE Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 9,850.0 5,827.1 61.18 LEAK TBG LEAK AT 9850' RKB IDENTIFIED BY EL ON 5/3/18 5/3/2018 2.992 9,923.0 5,861.9 62.12 LEAK TBG LEAK AT 9923' RKB IDENTIFIED BY EL ACOUSTIC LDL 11/18/2022 2.992 10,378.0 6,040.0 70.30 TIGHT SPOT Known Tight Spot in Tbg 1/14/2007 0.000 12,911.0 6,147.0 90.05 FISH 1 1/2" OV Lost in Wellbore 8/31/1997 8/31/1997 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,386.9 2,636.5 61.39 1 GAS LIFT GLV RK 1 1/2 1,254.0 8/6/2025 slb MMG 0.313 7,011.9 4,437.6 62.23 2 GAS LIFT GLV RK 1 1/2 1,214.0 8/6/2025 slb MMG 0.313 9,615.5 5,712.5 60.17 3 GAS LIFT OV RK 1 1/2 0.0 8/6/2025 slb MMG 0.313 10,037.9 5,913.6 64.57 7 PROD DMY BKO- 3 1 0.0 4/11/1996 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 12,911.1 6,147.0 90.05 LANDING COLLAR 7.000 TIW TYPE L LANDING COLLAR TIW TYPE L 6.151 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,760.0 10,850.0 6,117.8 6,128.7 A-3, 2M-29 3/21/1996 4.0 IPERF SWS 4.5" TCP gun; 180 deg phase 10,850.0 10,900.0 6,128.7 6,136.3 A-3, 2M-29 10/1/1993 4.0 IPERF SWS 4.5" TCP gun; 180 deg phase 11,430.0 11,550.0 6,147.4 6,145.4 A-3, 2M-29 9/30/1993 4.0 IPERF SWS 4.5" TCP gun; 90 deg phase 11,720.0 12,180.0 6,142.4 6,136.8 A-3, 2M-29 9/30/1993 4.0 IPERF SWS 4.5" TCP gun; 90 deg phase 12,300.0 12,550.0 6,136.2 6,141.4 A-3, 2M-29 9/30/1993 4.0 IPERF SWS 4.5" TCP gun; 90 deg phase 12,650.0 12,850.0 6,144.8 6,147.0 A-3, 2M-29 9/21/1993 4.0 IPERF SWS 4.5" TCP gun; 180 deg phase Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 12,650.0 12,850.0 1 FRAC 9/24/1993 0.0 0.00 0.00 10,760.0 10,900.0 2 FRAC 4/1/1996 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 46.0 3,664.0 46.0 2,773.5 Primary – Full Bore Lead 820 sx 12 ppg Permafrost E + Tail 900 sx 15.8 ppg Class G... Circ & cond mud prior to cmt job - Pump 1091 bbl mud @ 9.6 ppg, 10 BPM, Full returns. Pump 100 bbl FW Spacer. Mix & pump 820 sxs PF 'E', followed by 900 sxs Class G Tail. Displ w/543.5 bbl, 10 BPM - Slowed to 2.5 BPM after 530 bbl displ - Did NOT bump plug - Floats held. Had 28 bbl 11.1 ppg cmt returns to surface. CIP @ 23:00 9/30/92. Recip csg until 400 bbl displ had been pumped. ^^Csg OD=13.375 27.2 2,160.0 27.2 1,980.3 Liner Cement Cement 9 5/8 Tie back X 13 3/8 Conductor. 15.8 PPG from ES Cementer @ 1991.5 to surface 7/17/2025 9,850.0 10,401.0 5,827.1 6,047.7 Primary – Full Bore Single Stage 66 bbl 15.6 ppg Class G ... Circ & cond mud prior to cmt job - Pump total of 948 bbl (9380 strks) 9.9 ppg mud, initial pump rate 5 BPM - increase to 6 .5 BPM. Pump 5 bbl H2O, PT lines to 3000 psi. Drop btm plug #1, Pump 50 bbl Spacer @ 11.0 ppg, drop btm plug #2. Mix & pump 310 sxs Class G @ 5 BPM. Drop top plug, flush lines w/10 bbl H2O & displ w/744 bbl mud @ 9.9 ppg, 12 BPM. Had full returns throughout job. Bump plug w/2000 psi - Held press 15 min - Floats held. CIP @ 19:10 10/7/92. Recip'd csg during job. ^^Csg OD=9.625 0.0 0.0 0.0 0.0 Squeeze – Behind Casing Squeeze Top Job + Tail Arctic Pack... ArcticPack Test Report 12/4/92 exists, but unable to locate ArcticPack report. **TOC calculated from annulus volume based on hole diameter + 20% enlargement ^^Csg OD=9.625 10,395.0 13,002.0 6,045.7 6,146.4 Liner Cement Lead 45 sx 8.93 ppg Class G + Tail 460 sx 15.6 ppg Class G... Circ & cond mud prior to cmt job - Circ total 1212 bbl mud @ 10.8 ppg, 6.5 - 7.5 BPM w/Full returns. Pump 50 bbl ARCO Spacer @ 11.0 ppg. Mix & pump 45 sxs Class G Lead, followed by 460 sxs Class G Tail. Displ w/279 bbl mud @ 10.8 ppg. Bump plug 7.3 bbl early - Floats held. Recip'd liner until plug was pumped. Had full returns throughout cmt job. Set liner hanger and released from same. Pull 4' above liner and reverse out 55 bbl Spacer and Preflush and 20 bbl Spacer contaminated mud - No cmt was reversed out. Tested liner top packer to 150 psi for 30 min. CIP @ 17:19 10/19/92. ^^Csg OD=7 2M-29, 8/21/2025 11:34:30 AM Vertical schematic (actual) LINER; 10,096.0-13,001.7 FISH; 12,911.0 IPERF; 12,650.0-12,850.0 FRAC; 12,650.0 IPERF; 12,300.0-12,550.0 IPERF; 11,720.0-12,180.0 Liner Cement; 10,395.0 ftKB IPERF; 11,430.0-11,550.0 PACKER; 10,962.9 IPERF; 10,850.0-10,900.0 FRAC; 10,760.0 IPERF; 10,760.0-10,850.0 Production; 2,010.7-10,405.0 TIGHT SPOT; 10,378.0 Primary – Full Bore; 9,850.0 ftKB GAS LIFT; 10,037.9 PACKER; 9,991.2 LEAK; 9,923.0 PACKER; 9,890.8 SBE; 9,877.4 LEAK; 9,850.0 CUT; 9,845.0 Nipple - X; 9,757.2 Packer; 9,672.0 Mandrel – GAS LIFT; 9,615.5 Mandrel – GAS LIFT; 7,011.9 SURFACE; 42.7-3,669.3 Mandrel – GAS LIFT; 3,386.9 Production Upper; 27.3-2,012.0 Primary – Full Bore; 46.0 ftKB Liner Cement; 27.2 ftKB CONDUCTOR; 44.0-121.0 EMERGENCY SLIPS; 27.2 Hanger; 25.8 KUP PROD 2M-29 ... WELLNAME WELLBORE2M-29 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Lau, Jack J (OGC) To:Eller, Cy Cc:Coberly, Jonathan; Dodson, Kate; AOGCC Records (CED sponsored) Subject:RE: 2M-29 RWO Plan Forward (Sundry #325-337) Date:Thursday, July 24, 2025 9:23:56 AM Good morning Cy, I have reviewed your proposed changes. You have approval to move forward with the plan outlined below. Jack From: Eller, Cy <Cy.Eller@conocophillips.com> Sent: Thursday, July 24, 2025 9:07 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Coberly, Jonathan <Jonathan.Coberly@conocophillips.com>; Dodson, Kate <Kate.Dodson@conocophillips.com> Subject: 2M-29 RWO Plan Forward (Sundry #325-337) Hi Jack, I am on-call for RWO operations for this week and wanted to give you an update and seek approval of plan forward on 2M-29. We were able to complete the subsidence repair work, but were unable to remove the tubing stub and seal assembly from the PBR. We are currently tripping out of hole with our fishing BHA. To return this well to production, we are requesting your approval to proceed with running a non-sealing overshot and stacked packer for the new completion. Please see below for the proposed plan forward. 1. Continue to TOOH LD fishing BHA.2. Pressure test 9-5/8” casing to 2500 psi for 15 minutes.3. RIH with dress off/cleanout BHA. Dress off tubing stub as needed. TOOH LD drillpipe.4. MU 3 ½” completion with poor boy overshot, packer, and GLMs. RIH with completion.5. Circulate CI brine, space out as needed, land hanger, RILDS, drop B&R, and set packer.6. Pressure test tubing to 3000 psi for 30 minutes on chart.7. Pressure test inner annulus to 2500 psi for 30 minutes on chart. 8. Confirm pressure tests, then shear out SOV with pressure differential.9. Install BPV.10. ND BOPE. NU tree. PT tree.11. Pull BPV, freeze protect well at opportune time, and set BPV if necessary.12. RDMO. Attached are the current working schematic and a proposed schematic. Please let me know if you have any questions or concerns with this plan. Thank you, Cy Eller RWO/CTD Engineer ConocoPhillips Alaska Office: 907-265-6049 Cell: 907-232-4090 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 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: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 13015'2572'12911' Casing Collapse Conductor Surface Production Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. 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: 907-265-1102 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 3626'13-3/8"3669'2776' 6146'10400'6048'9912' KRU 2M-29 10760-10900' 11430-11550' 11720-12180' 12300-12550' 12650-12850' 6118-6136' 6147-6145' 6142-6137' 6136-6141' 6145-6147' 2906' 7/24/2025 3-1/2" 3-1/2" Packer: Baker FHL Retrievable Packer: Baker FHL Retrievable Packer: Baker FB-1 SSSV: None Perforation Depth MD (ft):Perforation Depth TVD (ft): 77' Proposed Pools: Burst Current Pools: MPSP (psi):Plugs (MD): 121'121' TVD 10405' 20" 7" 6049' 6146'13002' P.O. Box 100360, Anchorage, AK 99510 50-103-20183-00-00 ConocoPhillips Alaska, Inc Will perfs require a spacing exception due to property boundaries? 9992' 11356' MD AOGCC USE ONLY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025590 Other: Pull Tubing Kuparuk River Field Kuparuk River Oil Pool Kuparuk River Oil Pool Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size 192-097 L-80 L-80 10365'9-5/8" 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Tubing Grade:Tubing MD (ft): 9891'MD/5847'TVD 9991'MD/5893'TVD 10963'MD/6144'TVD James Ohlinger james.j.ohlinger@conocophillips.com CTD Engineer Subsequent Form Required: Suspension Expiration Date: m n P 1 6 5 6 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 2:27 pm, Jun 02, 2025 Digitally signed by James J. Ohlinger DN: C=US, OU=ConocoPhillips, O=Wells - Coiled Tubing Drlling, CN=James J. Ohlinger, E=James.J.Ohlinger@ cop.com Reason: I am the author of this document Location: Date: 2025.06.02 14:16:11-08'00'Foxit PDF Editor Version: 13.1.6 James J. Ohlinger 325-337 JJL 6/3/25 AOGCC witnessed BOP and annular test to 3000 psi. DSR-6/3/25 Replace tubing 10-404 X SFD 7/03/2025 , ADL0025585, ADL0025586 SFD JLC 7/3/2025 Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.07.03 11:56:51 -08'00'07/03/25 RBDMS JSB 070925 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 27, 2025 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: James Ohlinger Staff CTD/RWO Engineer ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Producer 2M-29 (PTD# 192-097). Well 2M-29 was originally drilled in 1992. The well has primarily been a Kuparuk A-sand Producer. A rig work-over was performed in 2007 to address a leaking packer @ 9991' RKB. Since then the well has developed AnnComm issues that moved it to being a RWO candidate due to leaks. The leak at 9850' was patched in 2023, it has been removed for the RWO. The Arctic Pack passed MIT-OA in 2005 and 2007, but a casing leak is expected ~500' MD. A MIT-OA failed on 2/2/25, but a recent Surface Casling Leak Detect (SCLD) passed on 2/10/25. Diagnostic testing is showing that we have competent production casing. If you have any questions or require any further information, please contact me at . To address the Surface Casing leak a subsidence style repair will be conducted, at the same time it will remove some of the 58" of subsidence strain that is causing tight spots in the tubing; 5230'-5538' MD. The tubing will be pulled from the seals out of the upper packer. The 9-5/8" casing will be cut and removed down to Arctic Pack cement. Drift in the 13-3/8" will be re-established. Then a new 9-5/8" casing and patch will be installed and cemented to surface. A new 3.5" completion will be installed to recomplete the well. General Well info Wellhead type/pressure rating: FMC Gen IV, 5K psi top flange on Tubing head, 5K psi top flange on Casing head Production Engineer: Will Parker Reservoir Development Engineer: Grace Knock Estimated Start Date: 07/24/25 Workover Engineer: James J Ohlinger (+1-907-265-1102/ James.J.Ohlinger@conocophillips.com) Current Operations: This well is currently shut in; 1/31/25 Well Type: Producer Scope of Work: Pull the existing 3-1/2” completion down to the seals in the PBR/FHL Packer ~9877’. Install a new 3-1/2” completion w/ new seals stabbed into existing packer. Subsidence like repair on the Production Casing to cement the annulus for the surface casing leak at ~500’. BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Ram / Drilling Spools Following subject to change/be updated with pre-rig work: MIT results: MIT-T Tubing leak ~9850’ MD DDT-TxIA Passed 500psi 2/15/25 MIT-OA Failed 2/2/25 IC-POT Passed 2/01/25 IC-PPPOT Failed – 2/01/25 TBG POT & PPPOT PASSED – 2/01/25 SCLD Passed 2/10/25 MPSP: 2572 psi using 0.1 psi/ft gradient Static BHP: 3152 psi / 5802’ TVD measured on 01/24/25 FIT: Drilling the 12-1/4” hole out the 13-3/8” casing was 12.5 ppg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ast Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 10,400.0 2M-29 2/3/2025 pottej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Cut Tbg 2M-29 2/25/2025 bworthi1 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 20 18.94 44.0 121.0 121.0 91.50 H-40 WELDED SURFACE 13 3/8 12.41 42.7 3,669.3 2,776.2 68.00 L-80 BTC PRODUCTION 9 5/8 8.68 39.7 10,405.0 6,049.1 47.00 L-80 BTC LINER 7 6.28 10,096.0 13,001.7 6,146.4 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 37.6 Set Depth … 9,991.7 Set Depth … 5,893.3 String Max No… 3 1/2 Tubing Description TUBING WO Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rdABM OD 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) 37.6 37.6 0.04 HANGER 11.000 FMC TUBING HANGER w.4.5" PUP FMC 3.958 505.9 505.9 1.89 NIPPLE 4.520 CAMCO DS NIPPLE CAMCO 2.875 3,518.5 2,700.5 60.32 GAS LIFT 5.390 CAMCO KBMG 2.920 5,954.9 3,905.9 61.63 GAS LIFT 5.390 CAMCO KBMG 2.920 6,922.7 4,394.6 59.94 GAS LIFT 5.390 CAMCO KBMG 2.920 7,699.8 4,750.3 63.65 GAS LIFT 5.390 CAMCO KBMG 2.920 8,917.7 5,347.4 57.87 GAS LIFT 5.390 CAMCO KBMG 2.920 9,822.8 5,813.9 60.89 GAS LIFT 5.390 CAMCO KBMG 2.920 9,877.4 5,840.3 61.42 SBE 5.000 BAKER 80-40 SEAL BORE EXTENSION Baker 80-48 3.000 9,890.8 5,846.7 61.54 PACKER 8.460 BAKER FHL RETRIEVABLE PACKER Baker T&C Upset 2.930 9,936.5 5,868.2 62.42 NIPPLE 5.390 CAMCO DS NIPPLE T&C Upset 2.812 9,975.0 5,885.8 63.03 LOCATOR 4.000 BAKER LOCATOR SUB T&C Upset 3.000 9,975.8 5,886.1 63.04 SEAL ASSY 4.000 BAKER GBH 80-40 SEAL ASSY T&C Upset 3.000 9,987.7 5,891.5 63.24 STINGER 2.992 STINGER STABBED INTO ORIGINAL 'FH' FAILED PACKER T&C Upset 2.812 Top (ftKB) 9,991.2 Set Depth … 11,356.1 Set Depth … 6,149.4 String Max No… 3 1/2 Tubing Description TUBING Original Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-ABM 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) 9,991.2 5,893.1 63.30 PACKER 8.218 BAKER FH RETRIEVABLE PACKER (PACKER FAILED, REASON FOR 2007 WORKOVER) BAKER FH 3.000 10,030.8 5,910.6 64.34 NIPPLE 4.540 CAMCO DS NIPPLE w/NO GO PROFILE CAMCO DS 2.812 10,037.9 5,913.6 64.57 GAS LIFT 6.018 CAMCO MMM CAMCO MMM 2.920 10,121.7 5,948.0 66.90 SLEEVE-C 4.500 BAKER CMU SLIDING SLEEVE (CLOSED) BAKER CMU 2.812 10,760.0 6,117.8 85.08 BLAST JT 4.500 STEEL BLAST JOINTS (OAL - 158') SBJ 3.476 10,924.6 6,139.6 82.74 SLEEVE-C 4.500 BAKER CMU SLIDING SLEEVE (CLOSED 3/6/1997) BAKER CMU 2.812 10,961.1 6,143.8 83.98 SEAL ASSY 4.500 BAKER GBH-22 LOCATOR/SEAL ASEMBLY, 4" SEAL BORE BAKER GBH-22 3.000 10,962.9 6,144.0 84.05 PACKER 5.875 BAKER FB-1 PACKER BAKER FB-1 4.000 10,966.2 6,144.4 84.18 SBE 5.000 BAKER SEAL BORE EXTENSION BAKER 4.000 11,010.1 6,148.3 85.45 NIPPLE 4.540 CAMCO D NIPPLE w/NO GO PROFILE CAMCO D 2.750 11,355.3 6,149.4 91.42 SOS 4.000 CAMCO Muleshoe WLEG w/seat removed CAMCO 2.992 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) 5,230.0 3,559.4 61.16 TIGHT SPOT Sat down @ 5230' SLM with DMY patch drift during subsidence surveillance. This was after B&F. Suspect corkscrew tubing. 2/15/2024 2.650 5,538.0 3,707.8 61.40 TIGHT SPOT Sat down @ 5538' SLM with DMY RBP drift during subsidence surveillance. This was after B&F. Suspect corkscrew tubing. Erratic weight swings while POOH. 2/15/2024 2.650 9,845.0 5,824.7 61.13 CUT WELLTEC MECHANICAL TBG CUT AT 9845' RKB 2/25/2025 2.992 9,850.0 5,827.1 61.18 LEAK TBG LEAK AT 9850' RKB IDENTIFIED BY EL ON 5/3/18 5/3/2018 2.992 2M-29, 2/26/2025 10:24:07 AM Vertical schematic (actual) LINER; 10,096.0-13,001.7 FLOAT SHOE; 12,998.5- 13,001.7 FLOAT COLLAR; 12,954.5- 12,956.4 FISH; 12,911.0 LANDING COLLAR; 12,911.0- 12,911.9 IPERF; 12,650.0-12,850.0 FRAC; 12,650.0 IPERF; 12,300.0-12,550.0 IPERF; 11,720.0-12,180.0 IPERF; 11,430.0-11,550.0 SOS; 11,355.3 NIPPLE; 11,010.1 SBE; 10,966.2 PACKER; 10,962.9 SEAL ASSY; 10,961.1 SLEEVE-C; 10,924.6 IPERF; 10,850.0-10,900.0 FRAC; 10,760.0 IPERF; 10,760.0-10,850.0 PRODUCTION; 39.7-10,405.0 FLOAT SHOE; 10,403.4- 10,405.0 OBSTRUCTION; 10,400.0 FLOAT COLLAR; 10,317.8- 10,319.1 SLEEVE-C; 10,121.7 HANGER; 10,096.0-10,110.1 GAS LIFT; 10,037.9 NIPPLE; 10,030.8 PACKER; 9,991.2 STINGER; 9,987.7 SEAL ASSY; 9,975.8 LOCATOR; 9,975.0 NIPPLE; 9,936.5 LEAK; 9,923.0 RBP; 9,911.6 PACKER; 9,890.8 SBE; 9,877.4 LEAK; 9,850.0 CUT; 9,845.0 GAS LIFT; 9,822.8 GAS LIFT; 8,917.7 GAS LIFT; 7,699.7 GAS LIFT; 6,922.7 GAS LIFT; 5,954.9 TIGHT SPOT; 5,538.0 TIGHT SPOT; 5,230.0 SURFACE; 42.7-3,669.3 FLOAT SHOE; 3,667.3-3,669.3 FLOAT COLLAR; 3,576.0- 3,577.4 GAS LIFT; 3,518.5 NIPPLE; 505.9 CONDUCTOR; 44.0-121.0 KUP PROD KB-Grd (ft) RR Date 10/21/199 2 Other Elev… 2M-29 ... TD Act Btm (ftKB) 13,015.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032018300 Wellbore Status PROD Max Angle & MD Incl (°) 91.55 MD (ftKB) 11,416.90 WELLNAME WELLBORE2M-29 Annotation Last WO: End Date 1/9/2007 H2S (ppm) 20 Date 12/20/2012 Comment SSSV: NIPPLE Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 9,911.6 5,856.5 61.84 RBP 2.72" PIIP RBP W/ DEBRIS EXTENSION. MOE = 9914' RKB, OAL = 7.2' TTS PIIP CPP3 5151, CPEQ 35040 2/12/2025 0.000 9,923.0 5,861.9 62.12 LEAK TBG LEAK AT 9923' RKB IDENTIFIED BY EL ACOUSTIC LDL 11/18/2022 2.992 10,400.0 6,047.4 70.43 OBSTRUCTI ON SLICKLINE TAG HARD OBSTRUCTION @ 10400' RKB (10372' SLM) 2/3/2025 0.000 12,911.0 6,147.0 90.05 FISH 1 1/2" OV Lost in Wellbore 8/31/1997 8/31/1997 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,518.5 2,700.5 60.32 1 GAS LIFT DMY BK 1 2/7/2025 5,954.9 3,905.9 61.63 2 GAS LIFT DMY BK 1 2/6/2025 6,922.7 4,394.6 59.94 3 GAS LIFT DMY BK 1 0.0 8/20/2009 0.000 7,699.8 4,750.3 63.65 4 GAS LIFT DMY BK 1 0.0 4/16/2021 0.000 8,917.7 5,347.4 57.87 5 GAS LIFT DMY BK 1 0.0 4/16/2021 0.000 9,822.8 5,813.9 60.89 6 GAS LIFT DMY BK 1 0.0 4/30/2018 0.000 10,037.9 5,913.6 64.57 7 GAS LIFT DMY BKO- 3 1 0.0 4/11/1996 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 12,911.1 6,147.0 90.05 LANDING COLLAR 7.000 TIW TYPE L LANDING COLLAR TIW TYPE L 6.151 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,760.0 10,850.0 6,117.8 6,128.7 A-3, 2M-29 3/21/1996 4.0 IPERF SWS 4.5" TCP gun; 180 deg phase 10,850.0 10,900.0 6,128.7 6,136.3 A-3, 2M-29 10/1/1993 4.0 IPERF SWS 4.5" TCP gun; 180 deg phase 11,430.0 11,550.0 6,147.4 6,145.4 A-3, 2M-29 9/30/1993 4.0 IPERF SWS 4.5" TCP gun; 90 deg phase 11,720.0 12,180.0 6,142.4 6,136.8 A-3, 2M-29 9/30/1993 4.0 IPERF SWS 4.5" TCP gun; 90 deg phase 12,300.0 12,550.0 6,136.2 6,141.4 A-3, 2M-29 9/30/1993 4.0 IPERF SWS 4.5" TCP gun; 90 deg phase 12,650.0 12,850.0 6,144.8 6,147.0 A-3, 2M-29 9/21/1993 4.0 IPERF SWS 4.5" TCP gun; 180 deg phase Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 12,650.0 12,850.0 1 FRAC 9/24/1993 0.0 0.00 0.00 10,760.0 10,900.0 2 FRAC 4/1/1996 0.0 0.00 0.00 2M-29, 2/26/2025 10:24:07 AM Vertical schematic (actual) LINER; 10,096.0-13,001.7 FLOAT SHOE; 12,998.5- 13,001.7 FLOAT COLLAR; 12,954.5- 12,956.4 FISH; 12,911.0 LANDING COLLAR; 12,911.0- 12,911.9 IPERF; 12,650.0-12,850.0 FRAC; 12,650.0 IPERF; 12,300.0-12,550.0 IPERF; 11,720.0-12,180.0 IPERF; 11,430.0-11,550.0 SOS; 11,355.3 NIPPLE; 11,010.1 SBE; 10,966.2 PACKER; 10,962.9 SEAL ASSY; 10,961.1 SLEEVE-C; 10,924.6 IPERF; 10,850.0-10,900.0 FRAC; 10,760.0 IPERF; 10,760.0-10,850.0 PRODUCTION; 39.7-10,405.0 FLOAT SHOE; 10,403.4- 10,405.0 OBSTRUCTION; 10,400.0 FLOAT COLLAR; 10,317.8- 10,319.1 SLEEVE-C; 10,121.7 HANGER; 10,096.0-10,110.1 GAS LIFT; 10,037.9 NIPPLE; 10,030.8 PACKER; 9,991.2 STINGER; 9,987.7 SEAL ASSY; 9,975.8 LOCATOR; 9,975.0 NIPPLE; 9,936.5 LEAK; 9,923.0 RBP; 9,911.6 PACKER; 9,890.8 SBE; 9,877.4 LEAK; 9,850.0 CUT; 9,845.0 GAS LIFT; 9,822.8 GAS LIFT; 8,917.7 GAS LIFT; 7,699.7 GAS LIFT; 6,922.7 GAS LIFT; 5,954.9 TIGHT SPOT; 5,538.0 TIGHT SPOT; 5,230.0 SURFACE; 42.7-3,669.3 FLOAT SHOE; 3,667.3-3,669.3 FLOAT COLLAR; 3,576.0- 3,577.4 GAS LIFT; 3,518.5 NIPPLE; 505.9 CONDUCTOR; 44.0-121.0 KUP PROD 2M-29 ... WELLNAME WELLBORE2M-29 3 2M-29 Existing Completion Producer COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Conductor 121 121 20 18.936 91.5 H-40 Welded Surface 3669 2776 13-3/8 12.415 68 L-80 BTC Production 10405 6049 9-5/8 8.681 47 L-80 BTC Tubing 11355 3-1/2 2.992 9.3 L-80 EUE-M Arctic Cement Diesel Pack BBLS BBLS 58" Subsidence 11/30/92 109 112 bbl/ft 0.0597 footage 1825 1875 3700 0 0 J,B#K COMPLETION FMC PBU Gen IV wellhead 3-1/2" 9.3# L-80 EUE-M 8rd Tubing to surface Camco DS Nipple @ 506' MD (2.875" ID) KBMG GLM @ 3516', 5955', 6923', 7700', 8918', 9823' Baker 80-40 SBE @ 9877' MD Baker FHL Retrievable Packer @ 9891' MD Camco DS Nipple @ 9937' MD ( 2.812" ID) Baker GBH 80-40 Seal Assembly Baker FH Retrievable Packer (failed) @ 9991' MD Camco DS Nipple @ 10,030' MD ( 2.812" ID) Camco MMM GLM @ 10,038' MD Baker CMU Sliding Sleeve @ 10,122' MD ( 2.812" ID) Baker Steel Blast joints 10,760-10,919' MD Baker CMU Sliding Sleeve @ 10,923' MD ( 2.812" ID) Baker GBH-22 LSA @ 10,961' MD Baker FB-1 Packer @ 10,963' MD Baker SBE @ 10,966' MD Camco D Nipple @ 11,010' MD (2.75" ID) Camco WLEG @ 11,355' MD Surface Casing Production Casing Conductor .17C1,,,K -%) 3 #'! !$234 !6!"$K .17C1,$,K -%) 3 #$5 , 2.4 - 24 #$5 , 2)4 #$+!2)34 6!&1!'.4,$.)4 .17.+1!6,B"K +,'$5 , 74 2M-29 Proposed Completion Producer COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 121 121 20 18.936 91.5 H-40 Welded Surface 3669 2776 13.375 12.415 68 L-80 BTC BTC Production 10405 6049 9.625 8.681 47 L-80 BTC BTC Tubing 9891 3.5 2.992 9.3 L-80 EUE-M EUE-M Arctic Cement Diesel Pack BBLS BBLS 11/30/92 109 112 bbl/ft 0.0597 footage 1825 1875 3700 0 0 J ,B#K COMPLETION FMC PBU Gen IV wellhead 3-1/2" 9.3# L-80 EUE-M 8rd Tubing to surface 1.5" GLM @ 3375', 7035', 9600' COMPLETION Baker 80-40 SBE @ 9877' MD Baker FHL Retrievable Packer @ 9891' MD Camco DS Nipple @ 9937' MD ( 2.812" ID) Baker GBH 80-40 Seal Assembly Baker FH Retrievable Packer (failed) @ 9991' MD Camco DS Nipple @ 10,030' MD ( 2.812" ID) Camco MMM GLM @ 10,038' MD Baker CMU Sliding Sleeve @ 10,122' MD ( 2.812" ID) Baker Steel Blast joints 10,760-10,919' MD Baker CMU Sliding Sleeve @ 10,923' MD ( 2.812" ID) Baker GBH-22 LSA @ 10,961' MD Baker FB-1 Packer @ 10,963' MD Baker SBE @ 10,966' MD Camco D Nipple @ 11,010' MD (2.75" ID) Camco WLEG @ 11,355' MD Surface Casing Production Casing Conductor .17C1,,,K -%) 3 #'! !$234 !6!"$K .17C1,$,K -%) 3 #$5 , 2.4 - 24 .17.+1!6,B"K +,'$5 , 74 ORIGINATED TRANSMITTAL DATE: 3/4/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5315 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5315 2M-29 50103201830000 Tubing Cut Record 25-Feb-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 192-097 T40182 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.03.05 10:25:46 -09'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Originated: Delivered to:19-Feb-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 2C-03 50-029-20968-00 909817733 Kuparuk River Multi Finger Caliper Field & Processed 17-Jan-25 0 12 2M-22 50-103-20170-00 909865523 Kuparuk River Multi Finger Caliper Field & Processed 12-Feb-25 0 13 2M-29 50-103-20183-00 909817744 Kuparuk River Plug Setting Record Field- Final 12-Feb-25 0 14 2W-01 50-029-21273-00 9097400015 Kuparuk River Leak Detect Log Field- Final 1-Feb-25 0 15 2X-05 50-029-20985-00 909816964 Kuparuk River Plug Setting Record Field- Final 20-Jan-25 0 16 3C-10A 50-029-21356-01 909817450 Kuparuk River Leak Detect Log Field- Final 18-Jan-25 0 17 3C-10A 50-029-21356-01 909817450 Kuparuk River Multi Finger Caliper Field & Processed 18-Jan-25 0 18 3H-33A 50-103-20578-01 909817452 Kuparuk River Leak Detect Log Field- Final 27-Jan-25 0 19 3H-33A 50-103-20578-01 909817452 Kuparuk River Multi Finger Caliper Field & Processed 26-Jan-25 0 110 3Q-10 50-029-21675-00 909817087 Kuparuk River Multi Finger Caliper Field & Processed 28-Jan-25 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T40117T40118T40119T40120T40121T40122T40122T40123T40123T40124183-089192-049192-097185-010183-107213-083209-103186-1872/20/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.02.20 11:45:36 -09'00'92-0972M-2950-103-20183-00 909817744Kuparuk RiverPlug Setting RecordField- Final12-Feb-2501 C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2024-02-04_24002_KRU_2M-29_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 24002 KRU 2M-29 50-103-20183-00 Caliper Survey w/ Log Data 04-Feb-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 192-097 T40098 2/19/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.02.19 08:24:20 -09'00' TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 2H-11 50-103-20052-00 185261_2H-11_SCMT Post-BiSN_22Aug2023 185261_2H-11_SCMT Pre-BiSN_27Jul2023 2H-12 50-103-20053-00 185262_2H-12_PPROF_01Jun2023 2H-17 50-103-20329-00 200019_2H-17_IPROF_01Jul2023 2K-07 50-103-20107-00 189071_2K-07_RBP_17Apr2023 2M-20 50-103-20169-00 192048_2M-20_LDL_30Mar2022 2M-29 50-103-20183-00 192097_2M-29_Patch_30Dec2022 2N-310 50-103-20549-00 207090_2N-310_CIBP_16Jul2023 2N-316 50-103-20342-00 200090_2N-316_EVO RPB_23Mar2023 200090_2N-316_LDL Caliper_02Sept2022 2N-329 50-103-20257-00 198067_2N-329_PLUG-LDL_03Mar2023 198067_2N-329_RST_31Dec2022 2T-14 50-103-20061-00 186044_2T-14_Patch_11Jun2022 2U-12 50-029-21304-00 185041_2U-12_LDL_06Aug2023 7of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38372 T38373 T38374 T38375 T38376 T38377 T38378 T38379 T383780 T38381 T38382 2/29/2024 2M-29 50-103-20183-00 192097_2M-29_Patch_30Dec2022 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:56:50 -09'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Tubing Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 13015'feet None feet true vertical 6146' feet 12911' feet Effective Depth measured 10319'feet 9839', 9873', 9891', 9991' feet true vertical 6020'feet 5822', 5838', 5847', 5893' feet Perforation depth Measured depth: True Vertical depth: Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 11356' MD 6149' TVD Packers and SSSV (type, measured and true vertical depth) 9839' MD 9873' MD 9891' MD 9991' MD 506' MD 5822' TVD 5838' TVD 5847' TVD 5893' TVD 506' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 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: N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 159 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: P2P Patch Packer Packer: P2P Patch Packer Packer: Baker FHL Retrvbl Packer Packer: Baker FH Retrvbl Packer (failed) SSSV: Camco DS Nipple Dusty Freeborn dusty.freeborn@conocophillips.com (907) 659-7224Senior Well Integrity Specialist 10760-10900', 11430-11550', 11720-12180', 12300-12550', 12650-12850' 6118-6136', 6147-6145', 6142-6137', 6136-6141', 6145-6147' 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) 186 Gas-Mcf MD 1334 Size 121' 2423 11751177 214 2212200 219 measured TVD 9-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 192-097 50-103-20183-00-00 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: ADL0025590 Kuparuk River Field/ Kuparuk River Oil Pool KRU 2M-29 Plugs Junk measured Length Production Liner 10365' 2906' Casing 6049' 7" 10405' 13002' 6146' 3627' 121'Conductor Surface Intermediate 20" 13-3/8" 77' 3669' 2776' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Meredith Guhl at 3:00 pm, Feb 08, 2023 Digitally signed by Dusty Freeborn DN: OU=AK WELLS, O=ConocoPhillips, CN=Dusty Freeborn, E=dusty.freeborn@conocophillips.com Reason: I am the author of this document Location: Eagle River, Alaska Date: 2023.02.08 14:49:09-09'00' Foxit PDF Editor Version: 12.0.1 Dusty Freeborn P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 8, 2023 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the retrievable tubing patch set across a known tubing leak in producer KRU 2M-29 (PTD 192-097). Please contact me at 659-7224 if you have any questions. Sincerely, Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Digitally signed by Dusty Freeborn DN: OU=AK WELLS, O=ConocoPhillips, CN=Dusty Freeborn, E=dusty.freeborn@ conocophillips.com Reason: I am the author of this document Location: Eagle River, Alaska Date: 2023.02.08 14:48:05-09'00' Foxit PDF Editor Version: 12.0.1 Dusty Freeborn DTTMSTART JOBTYP SUMMARYOPS 12/18/2022 ACQUIRE DATA PULLED 2.812" CSA-2 PLUG @ 9936' RKB; BRUSH n' FLUSH PATCH INTERVAL FROM 9798'-9928' RKB; DRIFT W/ 2.74" X 35' DMY PATCH ASSEMBLY DOWN TO 9928' RKB (NO ANOMALIES) 12/19/2022 ACQUIRE DATA RAN 24 ARM READ CALIPER W/ CCL FROM 9990' RKB TO SURFACE; RAN 3 1/2" SLIP STOP HOLEFINDER & SET @ 9875' RKB (OBTAIN GOOD COMBO TBG X IA TEST) ALSO SET @ 9841' RKB & OBTAIN GOOD TBG TEST. READY FOR E-LINE/RELAY TO SET PATCH. 12/30/2022 ACQUIRE DATA SET QUADCO PARAGON II LOWER PACKER FOR PATCH AT 9875'. SIT DOWN AT 9842' AND WORK TOOLS UP AND DOWN MAKING SLOW PROGRESS TO REQUIRED DEPTH. SET LOWER PACKER AT 9875'. CCL TO MID ELEMENT = 9.75', CCL STOP DEPTH = 9865.25'. READY FOR SLICKLINE. SERIAL #: CPP35203 1/9/2023 ACQUIRE DATA LOAD TBG W/ 85 BBLS OF DIESEL, LAND 3 1/2" TTS TEST TOOL IN LOWER P2P @ 9872' RKB, & CMIT TBG X IA TO 2500 PSI (PASS) SET UPPER 2.725" P2P (MID ELEMENT CPP35321 @ 9841' RKB), SPACER PIPE, & ANCHOR LATCH (CPAL35196) @ 9839' RKB RAN 3 1/2" TTS TEST TOOL TO UPPER P2P @ 9839' RKB & MITT TO 2500 PSI (PASS) CMIT TBG x IA TO 2500 PSI (PASS). JOB COMPLETE. 2M-29 Tubing Patch Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: Slickline corrected to RKB 10,319.0 2M-29 8/18/2022 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Patch 2M-29 1/9/2023 zembaej 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 20 18.94 44.0 121.0 121.0 91.50 H-40 WELDED SURFACE 13 3/8 12.41 42.7 3,669.3 2,776.2 68.00 L-80 BTC PRODUCTION 9 5/8 8.68 39.7 10,405.0 6,049.1 47.00 L-80 BTC LINER 7 6.28 10,096.0 13,001.7 6,146.4 26.00 J-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 37.6 Set Depth 9,991.7 Set Depth 5,893.3 String Ma 3 1/2 Tubing Description TUBING WO Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rdABMO D 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) 37.6 37.6 0.04 HANGER 11.000 FMC TUBING HANGER w.4.5" PUP FMC 3.958 505.9 505.9 1.89 NIPPLE 4.520 CAMCO DS NIPPLE CAMCO 2.875 3,518.5 2,700.5 60.32 GAS LIFT 5.390 CAMCO KBMG 2.920 5,954.9 3,905.9 61.63 GAS LIFT 5.390 CAMCO KBMG 2.920 6,922.7 4,394.6 59.94 GAS LIFT 5.390 CAMCO KBMG 2.920 7,699.8 4,750.3 63.65 GAS LIFT 5.390 CAMCO KBMG 2.920 8,917.7 5,347.4 57.87 GAS LIFT 5.390 CAMCO KBMG 2.920 9,822.8 5,813.9 60.89 GAS LIFT 5.390 CAMCO KBMG 2.920 9,877.4 5,840.3 61.42 SBE 5.000 BAKER 80-40 SEAL BORE EXTENSION Baker 80-48 3.000 9,890.8 5,846.7 61.54 PACKER 8.460 BAKER FHL RETRIEVABLE PACKER Baker T&C Upset 2.930 9,936.5 5,868.2 62.42 NIPPLE 5.390 CAMCO DS NIPPLE T&C Upset 2.812 9,975.0 5,885.8 63.03 LOCATOR 4.000 BAKER LOCATOR SUB T&C Upset 3.000 9,975.8 5,886.1 63.04 SEAL ASSY 4.000 BAKER GBH 80-40 SEAL ASSY T&C Upset 3.000 9,987.7 5,891.5 63.24 STINGER 2.992 STINGER STABBED INTO ORIGINAL 'FH' FAILED PACKER T&C Upset 2.812 Top (ftKB) 9,991.2 Set Depth 11,356.1 Set Depth 6,149.4 String Ma 3 1/2 Tubing Description TUBING Original Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-ABM 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) 9,991.2 5,893.1 63.30 PACKER 8.218 BAKER FH RETRIEVABLE PACKER (PACKER FAILED, REASON FOR 2007 WORKOVER) BAKER FH 3.000 10,030.8 5,910.6 64.34 NIPPLE 4.540 CAMCO DS NIPPLE w/NO GO PROFILE CAMCO DS 2.812 10,037.9 5,913.6 64.57 GAS LIFT 6.018 CAMCO MMM CAMCO MMM 2.920 10,121.7 5,948.0 66.90 SLEEVE-C 4.500 BAKER CMU SLIDING SLEEVE (CLOSED) BAKER CMU 2.812 10,760.0 6,117.8 85.08 BLAST JT 4.500 STEEL BLAST JOINTS (OAL - 158') SBJ 3.476 10,924.6 6,139.6 82.74 SLEEVE-C 4.500 BAKER CMU SLIDING SLEEVE (CLOSED 3/6/1997) BAKER CMU 2.812 10,961.1 6,143.8 83.98 SEAL ASSY 4.500 BAKER GBH-22 LOCATOR/SEAL ASEMBLY, 4" SEAL BORE BAKER GBH-22 3.000 10,962.9 6,144.0 84.05 PACKER 5.875 BAKER FB-1 PACKER BAKER FB-1 4.000 10,966.2 6,144.4 84.18 SBE 5.000 BAKER SEAL BORE EXTENSION BAKER 4.000 11,010.1 6,148.3 85.45 NIPPLE 4.540 CAMCO D NIPPLE w/NO GO PROFILE CAMCO D 2.750 11,355.3 6,149.4 91.42 SOS 4.000 CAMCO Muleshoe WLEG w/seat removed CAMCO 2.992 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) 9,839.0 5,821.8 61.06 PACKER - PATCH - UPR 2.72" P2P (MID ELEMENT @ 9841), SPACER PIPE, & ANCHOR LATCH (33.8' OAL) TTS P2P CPP3 5321 1/9/2023 1.625 9,842.6 5,823.5 61.10 ANCHOR LATCH ON SPACER PIPE SPACER PIPE & ANCHOR LATCH CONNECTED TO UPPER P2P TTS ANCHO R LATCH CPAL 35196 1/9/2023 1.600 9,850.0 5,827.1 61.18 LEAK TBG LEAK AT 9850' RKB IDENTIFIED BY EL ON 5/13/18 5/13/2018 2.992 9,872.6 5,837.9 61.39 PACKER - PATCH - LWR PARAGON II LOWER PACKER W/ MOE @ 9875' RKB, OAL = 4.01' TTS PARAG ON II PACKER CPP3 5203 12/30/2022 1.625 2M-29, 2/3/2023 7:07:26 AM Vertical schematic (actual) LINER; 10,096.0-13,001.7 FISH; 12,911.0 IPERF; 12,650.0-12,850.0 FRAC; 12,650.0 IPERF; 12,300.0-12,550.0 IPERF; 11,720.0-12,180.0 IPERF; 11,430.0-11,550.0 PACKER; 10,962.9 IPERF; 10,850.0-10,900.0 FRAC; 10,760.0 IPERF; 10,760.0-10,850.0 PRODUCTION; 39.7-10,405.0 GAS LIFT; 10,037.9 PACKER; 9,991.2 LEAK; 9,923.0 PACKER; 9,890.8 SBE; 9,877.4 PACKER - PATCH - LWR; 9,872.6 ANCHOR LATCH ON SPACER PIPE; 9,842.6 LEAK; 9,850.0 PACKER - PATCH - UPR; 9,839.0 GAS LIFT; 9,822.8 GAS LIFT; 8,917.7 GAS LIFT; 7,699.7 GAS LIFT; 6,922.7 GAS LIFT; 5,954.9 SURFACE; 42.7-3,669.3 GAS LIFT; 3,518.5 CONDUCTOR; 44.0-121.0 KUP PROD KB-Grd (ft) RR Date 10/21/199 2 Other Elev 2M-29 ... TD Act Btm (ftKB) 13,015.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032018300 Wellbore Status PROD Max Angle & MD Incl (°) 91.55 MD (ftKB) 11,416.90 WELLNAME WELLBORE2M-29 Annotation Last WO: End Date 1/9/2007 H2S (ppm) 20 Date 12/20/2012 Comment SSSV: NIPPLE Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 9,923.0 5,861.9 62.12 LEAK TBG LEAK AT 9923' RKB IDENTIFIED BY EL ACOUSTIC LDL 11/18/2022 2.992 12,911.0 6,147.0 90.05 FISH 1 1/2" OV Lost in Wellbore 8/31/1997 8/31/1997 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,518.5 2,700.5 60.32 1 GAS LIFT GLV BK 1 1,262.0 6/18/2021 0.188 5,954.9 3,905.9 61.63 2 GAS LIFT OV BK 1 0.0 6/18/2021 0.188 6,922.7 4,394.6 59.94 3 GAS LIFT DMY BK 1 0.0 8/20/2009 0.000 7,699.8 4,750.3 63.65 4 GAS LIFT DMY BK 1 0.0 4/16/2021 0.000 8,917.7 5,347.4 57.87 5 GAS LIFT DMY BK 1 0.0 4/16/2021 0.000 9,822.8 5,813.9 60.89 6 GAS LIFT DMY BK 1 0.0 4/30/2018 0.000 10,037.9 5,913.6 64.57 7 GAS LIFT DMY BKO- 3 1 0.0 4/11/1996 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 12,911.1 6,147.0 90.05 LANDING COLLAR 7.000 TIW TYPE L LANDING COLLAR TIW TYPE L 6.151 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,760.0 10,850.0 6,117.8 6,128.7 A-3, 2M-29 3/21/1996 4.0 IPERF SWS 4.5" TCP gun; 180 deg phase 10,850.0 10,900.0 6,128.7 6,136.3 A-3, 2M-29 10/1/1993 4.0 IPERF SWS 4.5" TCP gun; 180 deg phase 11,430.0 11,550.0 6,147.4 6,145.4 A-3, 2M-29 9/30/1993 4.0 IPERF SWS 4.5" TCP gun; 90 deg phase 11,720.0 12,180.0 6,142.4 6,136.8 A-3, 2M-29 9/30/1993 4.0 IPERF SWS 4.5" TCP gun; 90 deg phase 12,300.0 12,550.0 6,136.2 6,141.4 A-3, 2M-29 9/30/1993 4.0 IPERF SWS 4.5" TCP gun; 90 deg phase 12,650.0 12,850.0 6,144.8 6,147.0 A-3, 2M-29 9/21/1993 4.0 IPERF SWS 4.5" TCP gun; 180 deg phase Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 12,650.0 12,850.0 1 FRAC 9/24/1993 0.0 0.00 0.00 10,760.0 10,900.0 2 FRAC 4/1/1996 0.0 0.00 0.00 2M-29, 2/3/2023 7:07:26 AM Vertical schematic (actual) LINER; 10,096.0-13,001.7 FISH; 12,911.0 IPERF; 12,650.0-12,850.0 FRAC; 12,650.0 IPERF; 12,300.0-12,550.0 IPERF; 11,720.0-12,180.0 IPERF; 11,430.0-11,550.0 PACKER; 10,962.9 IPERF; 10,850.0-10,900.0 FRAC; 10,760.0 IPERF; 10,760.0-10,850.0 PRODUCTION; 39.7-10,405.0 GAS LIFT; 10,037.9 PACKER; 9,991.2 LEAK; 9,923.0 PACKER; 9,890.8 SBE; 9,877.4 PACKER - PATCH - LWR; 9,872.6 ANCHOR LATCH ON SPACER PIPE; 9,842.6 LEAK; 9,850.0 PACKER - PATCH - UPR; 9,839.0 GAS LIFT; 9,822.8 GAS LIFT; 8,917.7 GAS LIFT; 7,699.7 GAS LIFT; 6,922.7 GAS LIFT; 5,954.9 SURFACE; 42.7-3,669.3 GAS LIFT; 3,518.5 CONDUCTOR; 44.0-121.0 KUP PROD 2M-29 ... WELLNAME WELLBORE2M-29 C:\Users\mdguhl\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\LCF4WGUY\2022-12-19_15895_2M-29_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 15895 KRU 2M-29 50-103-20183-00 Caliper Survey w/ Log Data 19-Dec-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE,INC., 4141 B STREET,SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM By Meredith Guhl at 8:53 am, Dec 29, 2022 192-097 T37398 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.12.29 08:53:33 -09'00' C:\Users\mdguhl\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\LCF4WGUY\2022-11-18_22510_KRU_2M-29_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 22510 KRU 2M-29 50-103-20183-00 LeakPoint Survey 18-Nov-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE,INC., 4141 B STREET,SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM By Meredith Guhl at 12:56 pm, Nov 22, 2022 192-097 T37287 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.22 12:56:35 -09'00' STATE OF ALASKA AIL OIL AND GAS CONSERVATION COMION REPORT OF SUNDRY WELL OPERATIONS JUN 0 t 2013 1.Operations Abandon Li Plug Perforations Li Fracture Stimulate LI Pull Tubing U A060-6 wn LI Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well Q Re-enter Susp Well❑ Other: Tubing Patch ❑✓ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development Q Exploratory ❑ 192-097 3.Address: PO Box 100360 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99510 50-103-20183-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025590 KRU 2M-29 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): j N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 13002 feet Plugs measured N/A feet true vertical 6146 feet Junk measured N/A feet Effective Depth measured 13002 feet Packer measured 9891 feet true vertical 6146 feet true vertical 5847 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 20" 121' 121' Surface 3626' 13 3/8" 3669' 2776' Intermediate 10365' 9 5/8" 10405' 6049' Production Liner 2906' 7" 13002' 6146' SCANNED JUN 1 1 ?018 Perforation depth Measured depth 10760'-12850' feet True Vertical depth 6118'-6147' feet Tubing(size,grade,measured and true vertical depth) 3-1/2" L-80 11356' 6149' Packers and SSSV(type,measured and true vertical depth) Packer Baker FHL Retrievable 9891' 5847' Nipple Camco DS 506' 506' Upper Patch Packer Weatherford Widepak 9837' 5821' Lower Patch Packer Weatherford Widepak 9867' 5835' 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): 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: N/A N/A N/A N/A N/A Subsequent to operation: N/A N/A N/A N/A N/A 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations III Exploratory ❑ Development E Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 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: N/A Authorized Name: Travis Smith Contact Name: Kelly Lyons/Jan Byrne Authorized Title: Well I G,eggrriitty Superv':'op Contact Email: N1617Ca�conocophillips,,com Authorized Signature: i J` 41 Date: 5.047 /O Contact Phone: 659-7224 Form 10-404 Revised 4/2017V`TL (i`-//` RBDMS�\JUN 0 4 2016 Submit Original Only A‘ l� ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 May 29, 2018 Commissioner Hollis French Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner French: Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the retrievable tubing patch set in producer KRU 2M-29 (PTD# 192-097). Please contact Kelly Lyons or Jan Byrne at 659-7224 if you have any questions. Sincerely, 07,/,,,,6 r Travis Smit Well Integrity Supervisor ConocoPhillips Alaska, Inc. • 0 • i •� Well History I 0W 2M-29 Conoco hillips Aixkn API/UWI Legal WeIlName Field Name 5010320183 2M-29 KUPARUK RIVER UNIT Well Type Original KB/RT Elevation(ft) Well Status Development 146.00 PROD Daily Operations Legal Start Date WeIlName Last 24hr Sum AFE/RFE Rig Supervisor 5/27/2018 2M-29 SET ER TEST TOOL IN TOP OF PATCH AT 9837'RKB.PERFORMED PASSING MIT-IA TO 10408760 MCLAUGHLIN, 2500#.READY FOR PRODUCTION. RYAN,Wells Supervisor 5/26/2018 2M-29 PERFORM PASSING CMIT-TxIA TO 2500#ON WFD LOWER ANCHOR &TEST TOOL. SET 10408760 CONDIO, UPPER WFD PATCH AT 9837'RKB. PERFORM PASSING MIT-T 2500#WITH TEST TOOL. IN JOHN,Wells PROGRESS. Supervisor 5/24/2018 2M-29 SET 2.72"WFD WIDEPACK SLE(CP35086)LOWER ANCHOR AT 9867'RKB. 10408760 CONDIO, JOHN,Wells Supervisor 5/23/2018 2M-29 B&F TBG FROM 9789'RKB TO 9889'RKB WHILE PUMPING 1OBBLS DSL. DRIFT w/ 10408760 FERGUSON, 2.72"x18'-8"DUMMY PATCH TO 9909'RKB. READY FOR E-LINE. SID,WeIIs Supervisor 5/22/2018 2M-29 PULL CATCHER @ 9936'RKB. EQ&PULL CA-2 PLUG @ SAME. TAG OBSTRUCTION @ 10408760 FERGUSON, 10436'RKB. MEASURED BHP @ 10429'RKB w/GRADIENT STOP @ 10060'RKB. SBHP OF SID,Wells 3,670 PSI MEASURED. IN PROGRESS... Supervisor 5/4/2018 2M-29 PERFORMED CALIPER SURVEY FROM TOP OF PLUG AT 9936'UP TO SURFACE AT 30 10408760 FAMA, FPM. JAKE,Wells Supervisor 5/3/2018 2M-29 PERFORM LDL FROM TOP OF PLUG AT 9936'UP TO SURFACE. LEAK IDENTIFIED AT 10408760 FAMA, 9850'. LLR ESTABLISHED AT 1.5 BBL/MIN AT 210OPSI. JAKE,Wells Supervisor Page 1/1 Report Printed: 5/2/2018 KUP POD 2M-29 ConocoPhillips Well Attrib Max Angl ) TD Field Name Wellhore APPUWI Wellbore Status Incl p) MD Act Btm(ftKB) Alaska,Inc. KUPARUK RIVER UNIT 501032018300 PROD 91.55 11,41 . U 13.015,0 .on000Ralwps Comment H2S(ppm) Date Annotation End Date I KB-Grd(ft) 1 Rig Release Date ••• SSSV:NIPPLE 20 12/20/2012 Last WO: 1/9/2007 10/21/1992 2M-29,5/29/2018 8:07:21 PM Last Tag M Annotation End Date Depth(ftKB) Last Mod By D Last Tag:Slickline corrected to RKB 4/1412018 10,393.0 fergusp (ft Vertical schematic(actual) Last Rev Reason KB Annotation End Date Last Mod By ) Rev Reason:Pulled Plug 5/28/2018 - rmclaug „ .................. ..... 101 Casing Strings • . . Casing Oescnptloe OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WELen(I.,.Grade Top Thread `" -'- CONDUCTOR 20 18.94 44.0 121.0 121.0 91.50 H-40 WELDED '- - -- Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread " :•__„^-•_ SURFACE 133/8 12.41 42.7 3,669.3 2,776.2 68.00 L-80 BTC ' 1 - Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(IVO)...Wt/Len(I.,.Grade Top Thread "-'--"'••_'- PRODUCTION 95/8 8,68 39.7 10,405.0 6,049.1 47.00 L-80 BTC - �•». -•• Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WE/Len II.,.Grade Top Thread • • • LINER 7 6.28 10,096.0 13,001.7 6,146.4 26.00 J-55 BTC ., a J- Liner Details Nominal ID ,. - UE - �~ Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) v- 1 ----- • - 10,096.0 5,937.7 66.26 HANGER TIW 476 PBR w/S6 PACKER 8 DTH-S LINER 7.000 HANGER -"'-•-`-' Tubing Strings '-" """ """"""'"""""" Tubing Description String Me...ID(in) Top(ftKB) Set Depth(ft.. Set Depth(TVD)(...WI(Ib/ft) Grade Top Connection -CAMP ... ^-'-'-^�°•^•-- TUBING WO 31/2 2.99 37.6 9,991.7 5,893.3 9.30 L-80 EUEBrdABMOD - Completion Details Top I ND) Top Incl Nominal . Top(ftKB) (ftKB) (°) Item Des Corn ID(in) 37.6 0.04 HANGER FMC TUBING HANGER w.4.5"PUP 3.958 - -- •••-- 505.9 505.9 1.89 NIPPLE CAMCO DS NIPPLE 2.875 • -..,-_.-...._._ 9,877.4 5,840.3 61.42 SBE BAKER 80-40 SEAL BORE EXTENSION 3.000 "•• - - -•• -- --- 9,890.8 5,846.7 61.54 PACKER BAKER FHL RETRIEVABLE PACKER 2.930 77777 9,936.5 5,868.2 62.42 NIPPLE CAMCO D5 NIPPLE 2.812 -•---•--•-- 9,975.0 5,885,6 63.03 LOCATOR BAKER LOCATOR SUB 3.000 .. 9,975.8 5,886,1 63.04 SEAL ASSY BAKER GBH 80-40 SEAL ASSY 3.000 _,-„_,-_-_ 9,987.7 5,891.5 63.24 STINGER STINGER STABBED INTO ORIGINAL'FH'FAILED PACKER 2.812 ' ------ Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft.,rset Depth(TVD)(...Wt(113/ft) Grade Top Connection 77.,-----772"."--- TUBING Original 31/2 2.99 9,991.2 11,356.1 6,149,4 9.30 L-80 EUE-ABM w _•....,_._ Completion Details ' '--"""'- Top(TVD) Top Incl Nominal ,. .......................................-_:. ......-.......,......... Top(ftKB) (ftKB) J (°) Item Des Com ID(in) 9,991.2 5,893.1 63.30 PACKER BAKER FH RETRIEVABLE PACKER(PACKER FAILED, 3.000 •"'• -_..._.....'...... REASON FOR 2007 WORKOVER) "•' -"...""""""'•"' ------- 10,030.8 5,910.6 64.34 NIPPLE CAMCO DS NIPPLE w/NO GO PROFILE 2.812 '. -- ----7-7.7]77- 10,121.7 5,948.0 66.90 SLEEVE-C BAKER CMU SLIDING SLEEVE(CLOSED) 2.812 _.,. a 10,760.0 6,117.8 85.08 BLAST JT STEEL BLAST JOINTS(OAL-158') 3.476 -------- 10,924.6 6,139.6 82.74 SLEEVE-C BAKER CMU SLIDING SLEEVE(CLOSED 3/6/1997) 2.812 ..-,•� 10,961.1 6,143.8 83.98 SEAL ASSY BAKER GBH-22 LOCATOR/SEALASEMBLY,4"SEAL BORE 3.000 ,,i� •�- 10,962.9 6,144.0 84.05 PACKER BAKER FB-1 PACKER 4.000 • -cry '-"'-'"- 10,966.2 6,144.4 84.18 SBE BAKER SEAL BORE EXTENSION 4,000 ,.m ?' (1,010.1 6,148.3 85.45 NIPPLE CAMCO D NIPPLE w/NO GO PROFILE 2.750 ' """"" 11,355.3 6,149.4 91.42'SOS CAMCO Muleshoe WLEG w/seat removed 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,-UPPER... - fish,etc.) II _ -"" ` Top(TVD) Top Incl i '•""-"°-- Top(ftKB) (ftKB) (°I Des Com Run Date ID(in) 1 - .„...... 9,837.0 5,820.8 61.04 Packer 2.72"WFD Widepack SLE Upper Packer 512612018 1.810 lel A�- 9,867.0 5,835.3 61.35 Packer 2.72"WFD Widepack SLE Lower Anchor. 5/24/2018 1.750 .................. ••..-LOWER...- I. 12,911.0 6,147.0 90.05 FISH 1 1/2"OV Lost In Wellbore 8/31/1997 8/31/1997 Perforations&Slots ... ,-................. Shot Dens 7.7'..................................... - -- ............. Top(TVD) Btm(TVD) (shots/ft ..._..--�_ Top(ftKB) Btm(ftKB) (SOB) (ftKB) Linked Zone Date I Type Corn '•--•--- 10,760.0 10,850.0 6,117.8 6,128.7 A-3,2M-29 3/21/1996 4.0 IPERF SWS 4.5"TCP gun;180 �'��-•-'" deg phase ... -C-4A SU,.. ' 10,850.0 10,900.0 6,128.7 6,136.3 A-3,2M-29 10/1/1993 4.0 IPERF SWS 4.5"TCP gun;180 deg phase -A-3 INT... 11,430.0 11,550.0 6,147,4 6,145.4 A-3,2M-29 9/30/1993 4.0 IPERF SWS 4,5"TCP gun;90 deg phase ^---- 11,720.0 12,180.0 6,142.4 6,136.6 A-3,2M-29 9/30/1993 4.0 IPERF SWS 4.5"TCP gun;90 deg __ phase :I •----- 12,300.0 12,550.0 6,136,2 6,141.4 A-3,2M-29 9/30/1993 4.0 IPERF SWS4.5"TCP gun;90 deg phase 1 - "'= 12,650.0 12,850.0 6,144.8 6,147.0 A-3,2M-29 9/21/1993 4.0 IPERF SWS 4.5"TCP gun;180 ..._.,--.._ deg phase -, j - -� Frac Summary Start Date Proppant Designed(Ib) Proppant In Formation(lb) I� ..._..........-.-- ... 9/24/1993 Stg n Start Date Top Depth(ftKB) Stm(ftKB) Link to Fluid System Vol Clean(bbl) Vol Slurry(hbl) .� 9/24/1993 12,650.0 12,850.0 """ "-i - Start Date Proppant Designed(lb) Proppant In Formation(lb) -,_ 9/24/1993 Stg# Start Date Top Depth(ftKB) Btm(ftKB) Link to Fluid System Vol Clean(bbQ Vol Slurry(bbI) -= - Mandrel Inserts , _ St ati I r__.- on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (MB) Make Model OD(in) Sent Type Type (in) (psi) Run Date Com ...".,_•...,^ 1 3,518.5 2,700.5 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,246.0 4/16/2018 `-"'-•'"-"" 2 5,954.9 3,905.9 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,250.0 4/16/2018 . "'"' ................-'""""'" _._"' .._. - 3 6,922.7 4,394.6 CAMCO KBMG 1 GAS LIFT OMY BK 0.000 0.0 8/20/2009 .....-.MILUVE... • a FCIJP ®® 2M-29 ConocoPhillips Alaska,Inc. �' Canocoph •Bfips 2M-29,5/29/2018 8:07:22 PM M D (ft Vertical schematic(actual) KB ,ii ' Mandrel Inserts St ati a•- •^^-•^^-•• ' . °n Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1 251 0 4/17/2018 GAS LIFT OV BK 0 250 0 0 4/16/20 8 ' ••••• 9,822.8 5,813.9 CAMCO KBMG ®GAS LIFT DMY BK 0.000 ^' 0.0 4/30/2018 7 10,037.9 5,913.6 CAMCO MMM 1 GAS LIFT DMY BKO-3 0.000 0.0 4/11/1996 : 1 .....�._.... "r _ Notes:General&Safety •• - c - _e..._ End Date Annotation ■ 1 ___.._......_,_ 1/7/2007 NOTE:WORKOVER INCLUDED WELLHEAD CHANGEOUT L ._.._.._ 3/2/2007 NOTE:TAG OBSTRUCTION aQ 10399 --'""'•'"� 8!9!2008 NOTE:View Schematic w/Alaska Schematic9.0 -'•""'-"•^•-•- 10/6/2013 NOTE:TAG OBSTRUCTION @a 10,367 RKB ,_,._CAMP . __ _ _ ...._._ ■ C .. ■ — . ■ .__---.....-- .. .. 1 ri .., M.. .................._., _ r..».. • _ . ,. ,v, 1 I _... _ I ..... 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LL LL > C CIS > ate 6 4 , CU + N _c O O Z 0 o a1 u > _ N c O C E O (00 a) Y u E. roR. T I- > u a 4. � O .. c co a O O E u a) H Q N ❑ n c a -. LL . 3 2 01 LL LL ano d O ❑ d ❑ .a ❑ O y a '- C W O 0 a O O F- J a J �o J a d R rn r- a a a • g co 0 a -, O Cl- 0 0 I- d d = Nu al H CC N m U La `u tco) � III N +.,cc v. ❑ � ruC3 GI Y 0` > `Jo• y.+ m a t T '° Z v 6. ZONE o 1 0 Z N 13 1 3 t u d J J J J J J J J J J J J J J J C o < < a m a` w U3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 ` RLLI S VI .0 m W W W W W W W W W W W W W W Ill \ 7 S t+' > > > > > > > > > > > > > > > 1 ZY Y Y Y Y Y Y Y Y Y Y Y Y Y Y � O _> > > > > > > > > > > > > > > i0 cz CYCLCLCGCLY fXCeCCIXCLYIXCLrv s T owa a a a a aa a a a a a a a a ILI a a a a a a a a a a a a a a a > > > > > 7 > > > ❑ > > > > > c= - O 00® ' pqc u o 03 u CIXERRI (N.' 0 re w a- N M t} tt) N M R 7 LC) VI t0 r CO to X N .as . LL1fl® ❑ r r• r` r- h N N N N N N N N N N C tr 0 00 00 0 0 a- r -- r r C �r o O Co O O Co O O O O O O O O O O 5) @ ilW�d Y ?., ® � '# aCLC CO wtnthtntntnti 00 v e , ■ m CO CO m COm o O 0 O 0 0 0 Co O O C 9W7 , Q > F- I- I- I- I- fn U) to CO CO fn fn fn U) 0) n w ❑ O ❑ CI GI In CI C) ❑ C1 ❑ ❑ ❑ C O fr x N to E Lot w H 0 0 0 0 0 00 0 0 0 0 0 <- O 0 0 C tO 0 0 0 0 0 0 0 0 o O o O o 0 0 - pq V C) M M N - N O O O N N 1` N N r` 'Vr E T CO CO N r N O) 0) O 0 N 0 tr) rB - L. 0 N 0 N N CO 0 M M tD t0 to-0 t0 N e u N 0 0 O 0 N O 0 M M O M N N O N N N N N N N N N N N N N N N N y� 4 M M M M to to M W to T to Of W a) to ' G1 in Si O O O O N N O N N N N N N N N 'L 4- x 4- e- 0 0 0 0 0 0 0 0 0 0 0 i O O O O O O O O O O O O O O O fl. Ill O a) w C t() to an N to 1.0 to N to to .41 en to V) U) ` cc C13C CO cLo z m E co v �� OD �+ cc c c =It L. r_ -a to a .-r Q .- rn rn o ', r, rn CO CO n n do e` V C0 ate+ aCU .• a CU Z Y OO M Z N N N M 7 0 0 0 O r r 7 r +' _ E al N I- 44 o_ N 0 N J x N N J U o. x U U x x x x m m ro a C a <( O N M N N N N M M r C Z a) r0 W CO Y .� a� t"r R. ''1� r6 c G! r6 O a tD Q �. _ I- a` a < • pro l9Z-05' #- • Loepp, Victoria T (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Wednesday,April 25, 2018 12:17 PM To: Loepp,Victoria T(DOA) Cc: Senden, R.Tyler Subject: Report of sustained IA pressure above DNE KRU producer 2M-29 (PTD 192-097) 4-25-18 Attachments: 2M-29 schematic.pdf;2M-29 90 day TIO 4-25-18.JPG Follow Up Flag: Follow up Flag Status: Flagged Victoria, KRU gas-lifted producer 2M-29 (PTD 192-097) has a sustained IA pressure that is currently at 2100psi and was initially observed to be above the 2000psi DNE on 4-22-18. It appears to be stabilizing out at 2100psi. An attempt to bleed the pressure off was unsuccessful.The 9-5/8" 1-80 47#production casing has an internal yield pressure rating of 4720psi; therefore the 2100psi represents 44%of burst. The well was shut in on 4-14-18 to perform well intervention wellworl to address a failed TIFL. When work with slickline indicated the leak could not be identified and repaired, a retrievable tubing plug was set on 4/21/18 in preparation for a leak detect log with Eline. It is not clear whether the plug set was bad or if this is an indication of a packer leak. CPAI intends to have slickline rig up on the well tomorrow to troubleshot the plug and pull and replace as necessary so that the pressure on the casing can be relieved with the ultimate aim at repairing the leak so that the well can be returned to production. Please let us know if there are any questions. Attached is the schematic and 90 day TIO plot. Kelly Lyons/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907) SCANNED JuN 2(118 1 W U aCD w • 0 En C7 w N Q v - u7 w a 0 LL 0 GL7 W N O. o 6 CJ N = N W Ea' , N Jy o N co W c, N h- ni .p 0 —I °i .J (7 J ? c� 0 o 0 030 6aP 0 0 0 d M CO i f I t I t 4 a LI (.1%. I 1 a Q co co, co __,, o ._ _ ,,,, CO .__ , ,„ s_ .. „... V L..„.. s ,, r, C , , '� is, - co CO 1 :_, C .__ _ „ 0 co co (Y y, C 07 c0 f1 a`s - L. V9 l6 ` ca _ oC $ u_ Z C Q 1 m w U_ N OD P N O C) NC3 N co o ! co zi. - F cN 5d a N -)I1 � III 1 I CN r C E ate+ ) d d d d d o d C7-Tj P P. y n d 71 a d d d d ICS 03 O O d 41 .. �. Z 0 N .�-� d 0 (tdl8Jf '03� CU 05 032 isd �y cn C w e ----,\ KUP PROD • 2M-29 Conoco Phillips g", Well Attributes Max Angle&MD TD Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Alaska,Inc. 501032018300 KUPARUK RIVER UNIT PROD 91.55 11,416.90 13,015.0 c'''''.4"""Cf. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Dale ..- SSSV:NIPPLE 20 12/20/2012 Last WO: 1/9/2007 10/21/1992 2M-29,4118/2018 9:13 05 AM Last Tag Vertical schematic(actual/ Annotation Depth(ftKB) End Date Last Mod By w. Last Tag:Slickline corrected to RKB 10,393.0 4/14/2018 fergusp Last Rev Reason Annotation End Date Last Mod By Rev Reason_Tag,GLV's,AnnCom 4/17/2018 fergusp , Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(MKS) Set Depth(TVD)...Wt/Len g...Grade Top Thread CONDUCTOR 20 18.936 44.0 121.0 121.0 91.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread -A.A./CONDUCTOR;44.0-1210.a.alAJ..._" SURFACE 133/8 12.415 42.7 3,669.3 2,776.2 68.00 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WULen(I...Grade Top Thread NIPPLE,505.9 f 1 PRODUCTION 9 5/8 8.681 39.7 10,405.0 6,049.1 47.00 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth OMB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread LINER 7 6.276 10,096.0 13,001.7 6,146.4 26.00 J-55 BTC GAS LIFT;3,518.5 - Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl I') Item Des Com (in) 10,096.0 5,937.7 66.26 HANGER TIW 47#PBR w/S6 PACKER 8 DTHLINER 7.000 HANGER SURFACE;42.7-3,669.3--/ Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth)TVD)(...Wt(lb/ft) Grade Top Connection TUBING WO 3 1/2 2.992 37.6 9,991.7 5,893.3 9.30 L-80 EUE8rdABMOD Completion Details GAS LIFT;5,954.9 Top)TVD) Top Incl Nominal Top(ftKB) (ftKB) (") Item Des Com ID(In) _ 37.6 37.6 0.04 HANGER FMC TUBING HANGER w.4.5"PUP 3.958 GAS LIFT;8,922.7 505.9 505.9 1.89 NIPPLE CAMCO DS NIPPLE 2.875 __ 9,877.4 5,840.3 61.42 SBE BAKER 80-40 SEAL BORE EXTENSION 3.000 - 9,890.8 5,846.7 61.54 PACKER BAKER FHL RETRIEVABLE PACKER 2.930 GAS LIFT;7,899.7 9,936.5 5,868.2 62.42 NIPPLE CAMCO DS NIPPLE 2.812 - 9,975.0 5,885.8 63.03 LOCATOR BAKER LOCATOR SUB 3.000 9,975.8 5,886.1 63.04 SEAL ASSY BAKER GBH 80-40 SEAL ASSY 3.000 GAS LIFT;8,9177-lir 8987.7 5,891.5 63.24 STINGER STINGER STABBED INTO ORIGINAL'FH'FAILED PACKER 2.812 Tubing Description String Ma...ID(in) Top(RKB) Set Depth(ft..°Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection _ TUBING Original 31/2 2.992 9,991.2 11,356.1 6,149.4 9.30 L-80 EUE-ABM GAS LIFT;9,822.8-1 Completion Details !� Top(TVD) Top Ind Nominal Top(ftKB) (ftl(B) C) Herr.Des Com ID(In) 9,991.2 5,893.1 63.30 PACKER BAKER FH RETRIEVABLE PACKER(PACKER FAILED,REASON 3.000 SBE;9,877.4 FOR 2007 WORKOVER) PACKER;9,890.8 _ ' 10,030.8 5,910.6 64.34 NIPPLE CAMCO DS NIPPLE w/NO GO PROFILE 2.812 10,121.7 5,948.0 66.90 SLEEVE-C BAKER CMU SLIDING SLEEVE(CLOSED) 2.812 NIPPLE;9,936.5 10,760.0 6,117.8 85.08 BLAST JT STEEL BLAST JOINTS(OAL-158') 3.476 • 10,924.6 6,139.6 82.74 SLEEVE-C BAKER CMU SLIDING SLEEVE(CLOSED 3/6(1997) 2.812 LOCATOR;9,975.0 - SEAL ASSY;9,9758 10,961.1 6,143.8 83.98 SEAL ASSY BAKER GBH-22 LOCATOR/SEAL ASEMBLY,4'SEAL BORE 3.000 STINGER;9,987.7 it 10,962.9 6,144.0 84.05 PACKER BAKER FB-1 PACKER 4.000 PACKER;9,991.2 1_1 10,966.2 6,144.4 84.18 SBE BAKER SEAL BORE EXTENSION 4.000 a 11,010.1 6,148.3 85.45 NIPPLE CAMCO D NIPPLE wINO GO PROFILE 2.750 NIPPLE;10,030.0 $ 11,355.3 6,149.4 91.42 SOS CAMCO Muleshoe WLEG w/seat removed 2.992 GAS LIFT;10,037.9If Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl pr Top(ftKB) (ftKB) (°) Des Com Run Date ID(In) ® 9,937.0 5,868 4 62.43 Tubing Plug 2.81"CA2 Plug 4/17/2018 12,911.0 6,147.0 90.05 FISH 1 1/2"OV Lost in Wellbore 8/31/1997 8/31/1997 SLEEVE-C;10,121.7 - • Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shots/ft Top(ftKB) glee(ftKB) (ftKB) (RKB) Zone Date ) Type Corn 10,760.0 10,850.0 6,117.8 6,128.7 A-3,2M-29 3/21/1996 4.0 IPERF SWS 4.5'TCP gun;180 deg phase PRODUCTION;3/.7-10,4050 ` 10,850.0 10,900.0 6,128.7 6,136.3 A-3,2M-29 10/1/1993 4.0 IPERF SWS 4.5"TCP gun;180 deg phase (PERF;10,780.0-10,850.0 , -y 11,430.0 11,550.0 6,147.4 6,145.4 A-3,2M-29 9/30/1993 40 IPERF SWS 4.5'TCP gun;90 deg FRAC;10,760.0 1phase IPERF;10,850.0-10,900.0 I 11,720.0 12,180.0 6,142.4 6,136.8 A-3,2M-29 9/30/1993 4.0 IPERF SWS 4.5'TCP gun;90 deg phase SLEEVE-C;10,924.6 1.1 111 12,300.0 12,550.0 6,136.2 6,141.4 A-3,2M-29 9/30/1993 4 0 IPERF SWS 4.5"TCP gun;90 deg SEAL ASSY;10,981.1 phase I 12,650.0 12,850.0 6,144.8 6,147.0 A-3,2M-29 9/21/1993 4.0 IPERF SWS 4.5"TCP gun;180 deg PACKER;10,962.9 phase SBE;10,988.2 $ Stimulations&Treatments A , Proppant Designed(Ib) Proppant In Formation(lb) Date 9/24/1993 NIPPLE;11,010.1 Stimulations&Treatments W ' Vol Clean Pump SOS:11,355.3 Ill Stg# Top(ftKB) Btm(ftKB) Date Stim/Treat Fluid (bbl) Vol Slurry(bbl) IPERF;11,4300-11,550.0--• 12,650.0 12,850.0 9/24/1993 Proppant Designed(Ib) Proppant In Formation(Ib) Date IPERF;11 720.0-12,180.0 4/1/1996 Stimulations&Treatments IPERF;12,300.0-12,550.0 Vol Clean Pump FRAC;12,650.0 Stg# Top(ftKB) Btm(ftKB) Date Stim/Treat Fluid (bbl) Vol Slurry(bbl) IPERF;12,650.0-12,850.0 I I I 10,760.0 10,9000 4/1/1996 FISH:12,911.0 I LINER,10,096.0-13,0011 ` KUP PROD • 2M-29 ConocoPhillips A Alaska,Inc. �! OlnoaaiteNpe: 2M-29,4/182018 9'1309 AM Vertical schematic(actual) Mandrel Inserts St aB on Top(TVD) Valve Latch Poet Sine TRO Run -M/CONDUCTOR;44.0-1210- Top(81KB) (8K8) Make Model OD(in) SereType Type (in) (psi) Run Dale Corn 1 3,518.5 2,700.5 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,246.0 4/16/2018 NIPPLE;505.9 S; 2 5,954.9 3,905.9 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,250.0 4/16/2018 3 6,922.7 4,394.6 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 8/20/2009 GAS LIFT;3,5185 4 7,699.8 4,750.3 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,251.0 4/17/2018 5 8,917.7 5,347.4 CAMCO KBMG 1 GAS LIFT OV BK 0.250 0.0 4/16/2018 69,822.8 5,813.9 CAMCO KBMG 1 GAS LIFT DMY BKO-3 0.000 0.0 8/19/2009 7 10,037.9 5,913.6 CAMCO MMM 1 GAS LIFT DMY BKO-3 0.000 0.0 4/11/1996 SURFACE;427-36693 Notes:General&Safety End Date Annotation 1/7/2007 NOTE:WORKOVER INCLUDED WELLHEAD CI-IANGEOUT 3/2/2007 NOTE:TAG OBSTRUCTION @ 10399 8/9/2008 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT;5,954.9 : 10/6/2013 NOTE:TAG OBSTRUCTION @ 10,367 RKB GAS LIFT;6,922.7 GAS LIFT;7,699.7 GAS LIFT;8,9177 GAS LIFT;9,822.8 SBE;9,877.4 PACKER;9,890.8 NIPPLE;9,936.5 1/ LOCATOR;9,975.0 SEAL ASSY 9,9758 STINGER;9,987.7 PACKER;9,991.2 NIPPLE;10,030.6 GAS UFT;10,037.9 F SLEEVE-C;10,121.7 I■I PRODUCTION;39.7-10,405.0 (PERF;10,760.0-10,850.0 FRAC; FRAC;10,760.0 IPERF;10,850.0-10,9000 SLEEVE-C;10,924.8 ' I SEAL ASSY;10,961_1 _ PACKER;10,9629 SUE;10,9661 I NIPPLE;11,010.1 1 SOS;11,355.3 1e IPERF;11,4302-11,550.0 IPERF;11,720.0-12,180.0 IPERF;12,300.0-12,550.0 _ FRAC;12,850.0 IPERF;12,650.0-12,850.0 FISH;12,911.0 LINER:10,098.0-13.001 7 • • C s oPhillips Alaska P.O. SOX 100360 ANCHORAGE, ALASKA 99510 -0360 ' ..s' NNED MA[R 0 LULL March 9, 2012 Commissioner Dan Seamount P r _. � U Alaska Oil & Gas Commission � �i _ _ trt:2 I � 333 West 7 Avenue, Suite 100 �`- --- _, Anchorage, AK 99501 l ea -- 17 Commissioner Dan Seamount: - Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells were found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped in the fall of 2011. The corrosion inhibitor /sealant was pumped on various days in January and February 2012. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907- 659 -7043, if you have any questions. Sincerel , MJ oveland ConocoPhillips Well Integrity Projects Supervisor • • • ConocoPhillips Alaska Inc" Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 3-09 -2012 2A,M,T,X PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft pal 2A-19A 50103201970100 2010830 12" NA 39" NA 15.3 2/11/2012 2M -02 50103201790000 1920830 10'5" 1.62 19" 11/22/11 5.1 2/11/2012 2M-29 50103201830000 1920970 SF NA 24" NA 3.4 , 2/11/2012 2T-18 50103202130000 1950170 4'2" 0.50 9" 11/22/11 2.55 2/12/2012 2T-28 50103202250000 1950920 9" NA 16" NA 2T- 207 50103202780000 1982310 22'3" 3.70 7" 11/21/11 2.98 2/122012 2T-215 50103202800000 , 1982420 18'6" • 2.40 10" 1122/11 4.25 2/122012 2X-06 50029209880000 1831100 SF NA 21" NA 2.13 2/12/2012 • Schlumbergel' Jq9-0'ì~ scANI'lEO J\J\,\ ~ 11.0\)7 06/14/07 NO. 4300 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Compàny: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~; 0 2007 Field: Kuparuk Well Job# CD Log Description Date BL Color 2M-16 11629024 SBHP SURVEY 06/06/07 1 2N-306 11629025 SBHP SURVEY 06/06/07 1 2H-07 11638870 PRODUCTION PROFILE 06/07/07 1 2N-323 11629027 SBHP SURVEY 06/08/07 1 2N-313 11629027 SBHP SURVEY 06/08/07 1 2M-29 11638871 SBHP SURVEY 06/08/07 1 1C-104 11638872 LDL 06/08/07 1 1G-08A 11629026 PRODUCTION PROFILE 06/09/07 1 2N-308 11638874 SBHP SURVEY 06/09/07 1 2M-10 11629031 SBHP SURVEY 06/10/07 1 1A-27 11638876 PRODUCTION PROFILE 06/10'07 1 2M-12 11629030 SBHP SURVEY 06/10'07 1 2L-311 11638881 SBHP SURVEY 06'11/07 1 2N-317 11638878 SBHP SURVEY 06/11/07 1 2B-08 11629032 INJECTION PROFILE 06'11/07 1 1H-08 11638882 INJECTION PROFILE 06'12/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . . . RECEIVED STATE OF ALASKA k MAR ALASKA Oil AND GAS CONSERVATION COMMISSION ., J ~ I) 1 2007 REPORT OF SUNDRY WELL OPERA TIOHSa Oil & Gas C.ns. Commilsíon 1. Operations Performed: Abandon 0 Repair Well 0 . Plug Perforations 0 Stimulate 0 oltuJm;horm Alter Casing 0 Pull Tubing 0 . Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Opera!. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. 0 Exploratory 0 192-097/ . Development 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20183-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 146', Pad 105' 2M-29 - 8. Property Designation: 10. Field/Pool(s): ADL 25590,' ALK 2676 Kuparuk River Field / Kuparuk Oil Pool . 11. Present Well Condition Summary: Total Depth measured 13015' feet true vertical 6146' feet Plugs (measured) Effective Depth measured 10710' feet Junk (measured) 12911 ' true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 20" 121' 121' SUR. CASING 3518' 13-3/8" 3664' 2774' PROD. CASING 10255' 9-5/8" 10401 ' 6048' LINER 2906' 7" 13002' 6146' Perforation depth: Measured depth: 10760'-10900',11430'-11550', 11720'-12180', 12300'-12550', 12650'-12850' true vertical depth: 6118'-6136',6147'-6145',6142'-6137', 6136'-6141', 6145'-6147' Tubing (size, grade, and measured depth) 3-1/2", L-80, 11356' MD. Packers & SSSV (type & measured depth) pkr=Baker FHL retriev. Pkr, Baker 'FH' retriev. Pkr, BAKER 'FB-1' pkr= 9891',9991',10962' Cameo 'OS' landing nipple @ 506' 12. Stimulation or cement squeeze summary: §;i(~~NEf) MAR 0 6 ZOOI Intervals treated (measured) none \,V\,.;! Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casinn Pressure Tubino Pressure Prior to well operation SI -- Subsequent to operation 69 . 1023 1604 . -- 235 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: OilO GasD WAG 0 GINJD WINJD WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: N/A Contact Howard Gober @ 263-4220 Printed Name Howard Gober Title Wells Group Engineer . I Signature -rÌ? .A~ Phone Date 2/1.-1 Oi- l ~""7 "'''''1 Pre~red b""hamn AI/sun-Drake 263-4612 I Form 1 0-404 Revised 04/2004 0·. D. I 1". ¡ I·~' A. L RBDMS 8Ft MAR (I {) ZOU7 A.. ~ S b 't 0" I 0 I ''"'\ I -¡ 'I' . 'v zt.. 7 u mf ngtna n y I V , .,.....-;r~ AP ' .'Z..ø'7 . . ConocoPhmips Alaska, Inc. KRU 2M-29 ~ SSSV TVDe: Nioole Orig Completion: 10/21/1992 Angle @ TO: 91 dea a'ì) 13015 Annular Fluid: Last W/O: 1/9/2007 Rev Reason: WORKOVER Reference Loa: Ref Loa Date: Last UPdate: 1/23/2007 Last Taa: 10710 TO: 13015 ftKB Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 20.000 0 121 121 91.50 H-40 SUR. CASING 13.375 0 3664 2774 68.00 K -55/L -8C PROD. CASING 9.625 0 10401 6048 47.00 L-80 Size TOD Bottom TVD Wt Grade Thread I 3.500 I 0 I 9971 I 5884 I 9.30 I L-80 I EUE8rdABM I ~356 I 6149 I 9.30 I L-80. ABM EUE I Interval TVD Zone Status Ft SPF Date TVDe Comment 10760 -10900 6118-6136 A-3 140 4 10/5/1993 IPERF SWS 4.5" TCP gun; 180 dea phase 11430 -11550 6147 - 6145 A-3 120 4 10/5/1993 IPERF SWS 4.5" TCP gun; 180 dea phase 11720 -12180 6142 - 6137 A-3 460 4 10/5/1993 IPERF SWS 4.5" TCP gun; 180 dea phase 12300 - 12550 6136 - 6141 A-3 250 4 10/5/1993 IPERF SWS 4.5" TCP gun; 180 deg phase 12650 - 12850 6145 - 6147 A-3 200 4 10/5/1993 IPERF SWS 4.5" TCP gun: 180 d phase St MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Run Vlv Mfr Cmnt 1 3519 2701 CAMCO KBMG DMY 1.0 BK-5 0.000 0 1/6/2007 2 5955 3906 CAMCO KBMG DMY 1.0 BK-5 0.000 0 1/612007 3 6923 4395 CAMCO KBMG SOV 1.0 BK-5 0.000 0 1/612007 4 7700 4750 CAMCO KBMG DMY 1.0 BK-5 0.000 0 1/612007 5 8819 5295 CAMCO KBMG DMY 1.0 BK-5 0.000 0 1/612007 6 9823 5814 CAMCO KBMG DMY 1.0 BEK 0.000 0 1/612007 Deoth TVD TVDe Description ID 38 38 HANGER FMC TUBING HANGER 3.958 506 506 NIP CAMCO 'OS' LANDING NIPPLE 2.875 TUBING 9875 5839 SEAL BAKER 80-40 PBR w/SEAL ASSEMBLY 3.000 (9971-11356, 9891 5847 PACKER BAKER FHL RETRIEVABLE PACKER 2,930 OD:3,500, - - 9937 5868 NIP CAMCO OS NIPPLE 2,812 ID:2,992) - - 9976 5886 SEAL BAKER 80-40 SEAL ASSEMBLY w/LOCA TOR SUB 3.000 - - 9991 5893 PACKER Baker 'FH' Baker Retrievable Packer 3.000 10031 5911 NIP Cameo 'OS' Landina NiDDle NO GO 2.812 10122 5948 SLEEVE-C Baker 'CMU' Slidina; CLOSED 2.812 10925 6140 SLEEVE-C Baker 'CMU' Slidina; CLOSED (3/6/97) 2.812 10961 6144 PBR Baker 'GBH-22' 3.000 10962 6144 PKR Baker 'FB-1' 4.000 10966 6144 SBE Baker 4.000 11010 6148 NIP Cameo '0' Nioole NO GO 2.750 11355 6149 SOS Cameo Muleshoe WEG 2.992 11356 6149 TTL 2.992 DeDth I 12911 11 1/2" OV I Lost in Well bore 8/31/1997 - - - - - - - - - - - - - - - - - - . · ......../ ConocoPhillips We/Mew Web Reporting Time Log Summary 12/30/2006 15:00 20:00 5.00 MIRU MOVE MOB P Move Rig from 2T-208 to 2M-29 20:00 20:30 0.50 MIRU MOVE OTHR P Set wellhead in Cellar 20:30 21:00 0.50 MIRU MOVE PSIT P Spot up rig over well. Accept Rig 21:00 22:00 1.00 MIRU MOVE OTHR P Cont to RU equipment and berm around ri . 22:00 00:00 2,00 MIRU MOVE OTHR P Crane on location to remove Centrilift ESP S ooler from ri floor. 12/31/2006 00:00 05:00 5.00 MIRU MOVE OTHR P Continue to spot equipment. Berm up rig. RU kill tanks. Load pits with 14.0# LSND mud, 05:00 08:00 3.00 MIRU MOVE OTHR P Test lines to kill tanks. Continue to load its with 14.0 # mud. 08:00 11 :00 3.00 MIRU WELCT EQRP P PU lubricator, Having problems with McEvoy Master valve, will not open fully. continue to work valve and finally et full o ened. Pull BPV 11:00 11:30 0.50 MIRU WELCT OTHR P Valve crew on location to service master valve. 11:30 12:00 0.50 MIRU WELCT OTHR P MU hoses to tree, line up kill manifold. Initial wellhead pressures T/I/O 1960/2030/325 12:00 14:00 2.00 MIRU WELCT KLWL P Bleed tubing thru choke to Tiger Tank. Pum a 30 bbl HiVisc ill down tubin , 14:00 17:00 3.00 MIRU WELCT CIRC P Start pumping 14,0# mud down tubing, taking returns thru choke out to tiger tank. Pump 150 bbls of 14.0# mud, then bullhead (1481 stks) 70 bbls of mud down IA to to erf. 17:00 20:00 3.00 MIRU WELCT CIRC P Continue circulating 14.0# mud down tubing at 64 spm taking returns thru choke out to ti er tank. 20:00 21:30 1.50 MIRU WELCT CIRC P Getting 13.4# mud back to surface after 18,819 strks (892 bbls). Blow down lines to tiger tank and start taking returns back to pits. Pump all 14.0# mud available at surface, still getting light returns of 13.3# heavy. No si ns of h drocarbons in returns. 21:30 23:00 1.50 MIRU WELCT COND P Shut down circulation and wt up pits to 14.0# mud. 200 bbls of mud in pits. Pressures during shutdown, tubing = 10 si,IA=10 si. 23:00 00:00 1.00 MIRU WELCT CIRC P Continue circulation at 64 spm with 14.0# mud. Pump 200 bbls, getting returns of 13.5#heav . WI up 180 bbls of mud in pits from 13.5# to 14.0# 01:00 02:30 1.50 P Pump 180 bbls of 14.0# mud down tubing, taking returns up IA and thru choke. Pump rate = 41 spm, tubing pressure = 510 psi, IA pressure = 90 psi. Shut down to monitor well and build up wt of mud in pits, Tubing ressure = 90 si,IA ressure = 0 si. 02:30 03:30 1.00 P WI up mud in pits to 14.0#. Funnel Viscosity = 46. Will increase viscosi while wei htin u . 03:30 04:30 1.00 P Pump 180 bbls of 14.0# mud down tubing at 87 spm taking returns up IA. Tb ress = 750 si, IA = 50 si. 04:30 06:30 2.00 P Shut down pumping and monitor well. After 30 min, tbg = 20 psi, IA = 0 psi. wtu mud in its to 14.0#. 06:30 12:00 5.50 P Circulate down tubing taking returns from IA thru choke to pits, maintaining weight at 14.0 ppg going in, 2 BPM, 570 psi, hold -30 psi on choke, returns slowl increased to 13.8+ 12:00 14:30 2.50 P Load of 14.0 ppg mud arrived from mud plant, load into pits. Increase circulation rate to 3 BPM, then 4 BPM, 850 psi, 100 psi on choke. Got 14.0 returns last hour. 14:30 16:00 1.50 P Shut-in and monitor well. SITP 100 psi in 30 min, 110 psi at 60 min. IA on slight vacuum, until slight flow at 60 min. 16:00 17:00 1.00 P Swap lines and reverse circulate 1.5 bottoms up from tubing, 3 BPM. Got heavy returns at bottoms up, up to 14.7 , no formation fluids. 17:00 17:30 0.50 P Monitor well. IA built to 100 psi in 5 min, 135 psi at 20 min. Tubing on Ii ht vacuum. 17:30 19:30 2.00 P Swap lines and resume circulating 14.0 ppg mud down tubing, 4 BPM, 800 psi, returns from IA thru choke and poor-boy, 50 psi on choke. Reloaded tubing with 14.0 ppg. 13.8 ppg returns increased to 14.0+ ppg after 350 Bbls; 14.3 ppg at 425 Bbls; 14.1 ppg at 600 Bbls, Gas slowly increased to 300 Units at 425 Bbls, then fell back to 100 Units at 500 Bbls, 75 Units at 535 Bbls (bottoms up), 50 Units at 600 Bbls and 650 Bbls. 19:30 20:00 0.50 COMPZ WELCT CIRC P Getting 14.0# mud at pits with surface to surface volume urn ed. 20:00 20:30 0.50 COMPZ WELCT KLWL P Shut down and monitor pressure. SIDP ressure = 100 si. IA=O si. 01/01/200720:30 00:00 3.50 COMPZr WELCT CIRC P Circulating mud at 5 bpm and weigting up to 14.5# mud. CP = 845 psi, IA = 50 psi. 01/02/2007 00:00 01:30 1.50 COMPZr WELCT CIRC P Continue Circulating 14.5# Mud at 5 bpm. Preparinq for BOP instalation 01:30 03:30 2.00 COMPZr WELCT CIRC P Get good 14.5# mud throughout system. Increase pump rate to 7 bpm and continue circulating. Pump total of 20,000 strks with 14.5# mud at 7 bpm, 03:30 05:30 2.00 COMPZr WELCT OWFF P Shut down circulation and monitor pressures. T = 0 psi, IA = 0 psi. RD & blowdown circulating hoses while monitoring well. 05:30 07:00 1.50 COMPZr WELCT OWFF P RU to set BPV while monitoring well. Annulus on very light vacuum. Some diesel breaking out in tree, no flow. Well dead. 07:00 07:30 0.50 COMPZr WELCT OTHR P Set BPV. 07:30 10:00 2.50 COMPZr WELCT NUND P PJSM. ND 4-1/16" 5 Ksi tree and adapter. 10:00 16:30 6.50 COMPZr WELCT NUND P Install blanking plug. Check retrieving tool make-up on blanking plug & remove retieving tool. NU BOPE. 16:30 16:45 0.25 COMPZr WELCT BOPE P Test BOPE. Witnessing of test waived by Chuck Scheve, AOGCC Field Inspector. 16:45 19:00 2.25 COMPZI WELCT BOPE T Problems with Gray lock holding on kill line during first pressure test. Tried numerous solutions without success. Replaced gray lock fitting and test was successful I. Continue with BOPE I pressure test procedure. 19:00 21:30 2,50 COMPZI WELCT BOPE P Pressure test Blind rams, Pipe rams, kill lines, choke manifold, HCR, Upper and Lower KC, 250psi/10 min. low & 4000psi/10 min, high. 21:30 22:00 0.50 COMPZ' WELCT BOPE P Pressure test Annular 400 low and 2500/10 hiqh as per procedures. 22:00 22:15 0.25 COMPZr WELCT SFTY P Hold safety meeting with Rig crew for removal of blanking plug and BPV 22:15 22:45 0.50 COMPZr WELCT OTHR P Check well for pressure, "0" on tubing and IA. Pull test plug and BPV. 22 :45 23:00 0.25 COMPZr RPCm. PULD P P/U joint of 4", XT-39 DP & X-over to 4-1/2" IBT, MU into tubing hanger. Back out Lock down screws. 23:00 23:30 0.50 COMPZr RPCOI\ PULD P P/U on tubing string to 100k, P/U to 120K wait 5 min., worked string back down, P/U 135K wait 5 min. Jarred string back down P/U to 150K wait 5 min. Jarred back down saw weight loss, P/U to 155K completion string came free. 23:30 00:00 0.50 COMPZr RPCOI\ PULD P P/U tubing hanger to rig floor and set up to circulate 1-1/2 X well volume. 01:00 02:30 1.50 02:30 03:00 0.50 03:00 16:00 13.00 P Start pulling and laying down 4" - completion string. Initial P/U weight 115K. Flow check completed after first 15 stands. Looked good, continue to POOH while monitoring well. Pump slug @ 5673'. Continue POOH LD 4" tubing & jewelry. Calculated hole fill 37.8 Bbls, Actual fill 44.8 Bbls. Recovered entire string thru Baker seal assembl . 16:00 17:00 1.00 COMPZ RPCOI\ OWFF P Monitor well, static. Clear last of tubing and jewelry out of pipe shed & oft rig floor, Drain stack. Set test plug on 3-1/2" test ·oint. 17:00 20:30 3.50 COMPZ WELCT BOPE P RILDS on test plug & test same to 2500 psi, OK, Change upper & lower pipe rams to 3-1/2". Test both sets of rams 250/10 min. & 4000 /10 min, Tests are good, Changed out elevators and sli dies from 4" to 3.5", 20:30 21:30 1.00 COMPZ RPCOI\ CIRC BOLDS, pull test plug and install wear-ring. Hold safety meeting to review well plan, Well Control, Pit montoring, and BHA assembly and land in de tho 21:30 00:00 2.50 COMPZ RPCOI\ RIH with 3.5" DS, BOT 9-5/8" Test Packer with 5" No-go ring and 9.6' of 2-7/8" Mule Shoe stinger on the bottom. RPCOI\ 01/04/2007 00:00 03:00 3.00 RPCOI\ TRIP P Continue to RIH with 3.5" DS, 9-5/8" test packer with 2-7/8" MS stinger. Stopping every hour to monitor well activi 03:00 03:30 0.50 RIGMN SVRG P Service rig. 03:30 07:00 3.50 RPCOI\ TRIP P Continue RIH PU 3-1/2" DP. Tag no-go on top of PBR @ 9962' MD, muleshoe to 9971'. Circulated down with M/S and saw pressure increase when No Go landed in to of PBR. 07:00 08:00 1.00 COMPZ RPCOI\ OTHR P PU & set Baker Retrieve-a-Matic at 9935' MD, center of rubber. Took 2 tries with 6 to 8 LH turns in DP to un-jay and set test packer (would have been very tricky to do with tubing). 145K# PU, 80K# SO, 35K# Blocks, Set 30K# down on acker. Blow down top drive. RU to test casing. Close pipe rams and test 9-5/8" casing above Retrieve-a-Matic at 9935' MD to 1020 psi, lost 50 psi in 30 minutes (10 psi loss last 20 minutes), good test. Blowdown kill line. 09:00 09:30 0.50 COMPZ RPCOI\ OTHR P MU top drive on string. PU & release test packer. Rotate to Jay-up packer. Circulate 10 minutes, wash down into PBR with stin er, 3 BPM. 09:30 12:00 2.50 COMPZ RPCOI\ CIRC P Swap around and reverse circulate to clean out any debris, with stinger in PBR and no-go just off seat. Started getting heavy mud at bottoms up, but no debris or produced fluids. Had 16.0 ppg returns shortly after bottoms up, continued reversing and watering back return mud until weight was 14,7 ppg. 3 BPM to 4 BPM, 1300 psi to 2000 si, 4BPM 1700 si final. 12:00 15:30 3.50 COMPZ RPCOI\ CIRC P Open preventer and circulate to condition mud, reciprocate pipe periodically. 6 BPM, 1880 psi. Continue circulating until 14.5 ppg mud in & out. 1-3/4 circulations total. 15:30 16:00 0.50 COMPZ RPCOI\ OWFF P Monitor well - static. Fill trip tank while monitoring well. Blowdown lines. 16:00 17:30 1.50 9,970 9,000 COMPZ RPCOI\ TRIP P POOH LD 30 joints of DP to 9000', using mud bucket. Hole taking proper fill, 6 Bbls Actual, 5.2 Bbls Calculated, 0.8 Bbls over-fill. 17:30 18:30 1.00 9,000 9,000 RPCOI\ OWFF P Monitor well while mixing dry job. Pum d 'ob and let it even out. 18:30 00:00 5.50 9,000 RPCOI\ TRIP P Continue POOH LD DP. Stopping every hour and monitor well in case of swabbin with BHA. 01/05/2007 00:00 05:00 5.00 COMPZ RPCOI\ TRIP T During crew change Drillers where adjusting the drawworks Brakeband and it broke right above the adjustment bracket. Blocks & pipe where secured while adjusting so no movement took place. Shut down to repair and inspected other side which also had a crack right above the adjustment bracket. Current depth is 2740' MD. While waiting for welding and repairs continue with pipe tally of 3.5" com letion strin , 05:00 10:00 5.00 COMPZ RPCOI\ OTHR T Both Brake Bands on draw-works have been repaired by welding, no replacement parts on the slope. Called Tubescope to MPI welds. Welds passed, test brake drum. Completed JSNRA form and safet meetin . Continue to POOH sideways with 3.5" DS from 2780'MD. Complete string and 9-5/8 Test acker surface 12:30 14:30 2.00 P Clear pipe deck and set up to run 3.5" completion string, Measure BHA components and review tally prior to ickin u tools and CS. 14:30 15:00 0.50 P Pull wear ring 15:00 16:30 1.50 P Begin picking up 3.5" completion string and BHA components as per rocedure & dia ram. 16:30 23:30 7.00 P Start to RIH, Depth at 23:45 8800'MD. 01/06/2007 00:00 02:00 2.00 P Complete RIH with 3.5" Completion String, drifted last 500' of CS to 2,91". Landed on Joint 312 estimated depth 9955' MD. P/U and set up to circulate down the strin to see seals locatin . 02:00 03:00 1.00 P RIH slowly and noticed seals catching in PBR and slight pressure increase from 300 psi to 380 psi. Stop pumping. Took around 4000# downweight to set inside. RIH 12' total set depth is 9967'MD. P/U string weight and slowly pressure up to 3000psi. Indication of Packer setting @ 1180psi, continue increasing pressure to 3000 psi and hold for 10 min, Slight drop oft to 2900 psi, looks good. No gains or losses noticed in its. Bleed down slowl . 03:00 03:24 OAO COMPZ RPCOI\ PACK P Set up to pressure test the casing. OA readings are 290 psi. Close annular and pressure test to 1000 psi. 15 psi leak oft detected over 15 min. Good test. Bleed down slowl . 03:24 04:24 1.00 COMPZ RPCOI\ PACK P Rig up to pressure up on PBR down the CS. Pressure up to 3000 psi, P/U to 120 K and felt PBR shear. Bleed down pressure and pull 3 stands. Total from setting depth 88' No excess drag detected. 04:24 05:42 1.30 COMPZ RPCOI\ PULD P Rig up and tally Baker Storm packer measurements. Configurations consists of: Storm packer (14.8') Storm valve (2.75'), twin valve(2.72'), 3.5" DP (38.18'), Totallenght set 5' Below casing spool. Pressure test to 400 si, no leak oft detected, 05:42 07:42 2.00 WELCT NUND P Bleed down OA current pressure 290 si. ND BOP's 07:42 09:42 2.00 RPCOI\ NUND Continue Bleeding down OA to "0" ressure. 04:00 04:30 0.50 COMPZ RPCOJl. SFTY Pull casing head, studs & cut oft 9-5/8" Stump. Install 9-5/8" X 13-3/8" Pack oft. RILDS, Needed to pre-heat TBG head and install. Pressure test flange and pack oft to 3800psi /15 min. 80% of collapse ress. of 9-5/8" no leaks. NU BOP's, install test plug and test any broken flange connections to 4000 si. Finish NU BOP stack. Test breaks. Pull test plug. Set up to pull Storm packer. Circulate 10 bbl to ensure fluid acked. P P/U on Storm packer released @ 110K P/U slowly and lay down pups & Packer. Checked OA, IA no pressure chan es, no flow. P RIH with (3) 3-1/2" 9.3# EUE 8 round pup joints, (1 jt) 3-1/2" tubing, 4-1/2" IBT X 3-1/2" EU crossover, 4-1/2" pup & FMC tubing Hanger. Locator to be landed @ 9966MD (Nordic 3 RKB), M/S at 9977' MD. P Safety Meeting with fluidlMud engineers, and transport crew to discuss pumping operations & offloading procedures. Begin offloading Mud pits and set up to circulate sea water down the IA. P Unload mud from pits & prepare to displace 14.5 ppg mud from well with Sea Water. Vac trucks having a hard time pulling off heavy mud, clear 550 bbl of it s ace before urn in . P Reverse circulate clean 8.5+ ppg SW into well, displacing 14.5 ppg mud. 3 BPM, 900 psi to 2000 psi - slowed to 2.6 BPM, 2000 psi for 165 Bbls until SW rounded bottom - increased to 4.5 BPM, 2000 psi to 450 psi as SW returned to surface. Continued reverse circulating SWan extra 200 Bbls, 4.5 BPM, 450 psi until SW returns were clean. LRS pumped 21.9 Bbls of Diesel into OA, filled up at 21 Bbls, then pressured up to 900 psi at shut down, 875 psi after 15 minutes, monitored then bled OA down to 500 psi & SI (OA done while displacing well w/ S 20:42 21 :42 1.00 P 21:42 23:42 2.00 P 01/07/2007 00:00 01:30 1.50 P 01 :30 03:00 1.50 03:00 04:00 1.00 04:30 06:30 2.00 COMPZ RPCOJl. RURD 06:30 11 :30 5.00 COMPZ RPCOJl. CIRC Switched lines and circulated 200 Bbls of SWwith 1% CRW-132 corrosion inhibitor into well, chased with 86 Bbls SW to spot in IA from seal assembly to above GLM wI SOV at 6913' MD, 4.9 BPM, 500 psi. (200 Bbls Inhibited SW reaches to approx. 6600' MD . 13:00 14:30 1.50 COMPZ RPCOII. HOSO P Land Tubing Hanger. 110K# PU, 72K# SO, 35K# Block WI. RILDS. RU lines to test tubin & casin . 14:30 19:00 4.50 COMPZ RPCOII. DHEQ P Test Tubing to 2500 psi, 15 min. lost 30 psi, IA open, OK. Bleed tubing. Test IA to 2500 psi for 30 minutes, holding 1700 psi on tubing, lost 30 psi on lA, no change on tubing, OK. Had to fix leak on line prior to test on casing. Bled down tubing side to shear open SOV, had light bump indicating shear after tubing bled to -100 psi, with 2500 psi on lA, but SOV not fully open. Repressured tubing & IA to 2500 psi and bled oft tubing to get SOV fully open,OK. RD & blowdown lines. 19:00 19:30 0.50 RPCOII. RURD P LDU. Set BPV. 19:30 23:00 3,50 RPCOII. RURD P ND BOPE, N/U adapter flange & tree. 23:00 00:00 1.00 RPCOII. RURD P Pull BPV & Install Test Plug. Test tree & pack oft 250/5000 15 min. Prepare to pull test plug and freeze protect well. 01108/2007 00:00 03:30 3.50 COMPZ RPCOII. FRZP P Rig up and Freeze protect, Pump down IA up tubing. Total 175 bbls, 80 F. Pum rate 2 bbl/min. 03:30 05:00 1.50 COMPZ RPCOII. FRZP P Connect tubing & IA & let diesel U-tube until equalized. 175 Bbls is 2500' MD in tubing & IA. Rig down Little Red. RD circulatin lines. 05:00 05:30 0.50 COMPZ RPCOII. FRZP P Set BPV. Secure well for hand-over. Final pressures: 0 psi Tubing, 0 psi IA,20 si OA. 05:30 07:00 1.50 COMPZ RPCOII. Secure well. Finish cleaning pits & prepare rig for move. Rig Released @ 0700, 1/8/07, THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER 13, 2000 E E P~L E M A T E R IA L U N D TH IS M. A R K ER C:LO~LM.DOC W E R ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 9, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2M-29 (Permit No. 92-97) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the workover on KRU 2M-29. The original 4" x 3.5" selective single completion was pulled and the wellbore was cleaned out. Additional perfs were added and the well was fractured stimulated for a second time. The 4" x 3.5" selective single completion was then re-run: If there are any questions, please call 263-4622. Sincerely, W. Isaacson Drilling Engineer Kuparuk Drill Site Development WSI/skad RECEIVED AUG ? 3 1996 Alaska Oil & Gas Cons. Commission Anchorage 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 [~] ABANDONE[[~ SERVICE 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 92-97 3 Address P.O. Box 100360, Anchorage, AK 99510-0360 4 Location of well at surface 114' FSL, 51 'FEL, Sec. 28, T11 N, RSE, UM At Top Producing Interval 980' FSL, 1393' FEL, Sec 32, T11 N, R8E, UM At Total Depth 789' FNL, 2196' FWL, Sec. 5, T10N, R8E, UM 5 Elevation in feet (indicate KB, DF, etc.) RKB 146', Pad 105' GL 6 Lease Designation and Serial No. ADL25590 ALK2676 12 Date Spudded 13 Date T.D. Reached J14 Date Comp., Susp. or Aband. 28-Sep-92 18-Oct-92 I 11 ~Apr-96 (recom pleted) 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 13015'MD &6146'TVD 12911'MD & 6147'TVD YES E~ NO ~ 8 APl Number 50-103-20183 9 Unit or Lease Name Kuparuk River Unit 10 Well Number 2M-29 11 Field and Pool KUPARUK RIVER 15 Water Depth, if offshore 116 No. of Completions NA feet MSLI 2 Depth where SSSV set I 21 Thickness of permafrost N/A feet MDI = 1380' ss APPROX 22 Type Electric or Other Logs Run CDR, CDN, HLDT, CBT, CET, GCT 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECOF~ 20" 62.58# H-40 SURF. 121' 26" 210 sx AS II cml 13.375" 68# K-55/L-80 SURF. 3664' 16" 820 sx Perm E, 900 sx Class G cmt 9.625" 47# L-80 SURF. 10401' 12.25" 310 sx Class G cml 7" 26# J-55 10096' 13002' 8.5" 505 sx Class G cmt 25 24 Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 10760' - 10850' MD 4spf 6118' - 6129'TVD 10850' - 10900' MD 4 spf 6129'- 6136' TVD 11430'-11550'MD 4spf 6147'-6145'TVD 11720'-12180'MD 4spf 6142'-6136'TVD 12300' - 12550' MD 4 spf 6136' - 6141' TVD 12650'- 12850' MD 4spf 6144' - 6146' TVD SIZE 4" x 3.5" 26 TUBING RECORD JPACKER SET (MD) DEPTH11356' SET (MD) 19991 ', 10963' I ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) A' sands PRODUCTIONTEST AMOUNT & KIND OF MATERIAL USED ITotal proppant 280559#. Put 277359# behind pipe with 3200# left in wellbore w/12# pp~ at perfs (39600# of #20/40, 214879# of #12/18, 26080# of #10/14) Date First Production Date of Test JHours Tested JPRODUCTION F..OR I I TEST PERIOD E Flow Tubing ICasing Pressure ICALCULATED Press. I J24-HOUR RATE I~ I Method of Operation (Flowing, gas lift, etc.) Flowing OIL-BBL OIL-BBL 28 CORE GAS-MCF GAS-MCF DATA WATER-BBL WATER-BBL CHOKE SIZE I GAS-OIL RATIO OIL GRAVITY-APl (corr) =24° Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 10561' 6088' Bottom Kuparuk C 10638' 6106' Top Kuparuk A 10638' 6106' Bottom Kuparuk A 11196' 6116' Freeze protect annulus with diesel 31. LIST OF ATTACHMENTS Daily Drilling History ~2. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,,~'~' ~, ~'~,..~,,,.,.....~,.._..._- Title O~,T.L~.I:~r~ F.N~,,,~.~.~ DATE S'1'~-~(-' 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 I~'((? jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". .~. %~ Form 10-407 Date: 7/23/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page' 1 REMEDIAL AND COMPLETION OPERATIONS WELL:2M-29 RIG'NORDIC WELL ID: 998399 AFC' 998399 TYPE' -- STATE'ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD:09/28/92 START OOMP' BLOCK' FINAL' WI- 0% SECURITY-0 AFC EST/UL'$ 1203M/ 1408M API NUMBER. 50-103-20183-00 03/09/96 (1) TD:13015' PB:12911' SUPV:DEB DAILY: 03/10/96 (2) TD:13015' PB:12911' SUPV:DEB DAILY: 03/11/96 (3) TD: 13015' PB: 12911' SUPV: DEB DAILY: 03/12/96 ( 4) TD: 13015' PB: 12911' SUPV: DEB DAILY: 03/13/96 (5) TD: 13015' PB: 12911' SUPV: DEB DAILY: 03/14/96 ( 6) TD:13015' PB: 0' SUPV: DEB DAILY: ACCEPT RIG MW' 0.0 Move rig & camp from 2X-19 to 2M pad. Accept rig @ 0600 hrs. 3/9/96. $26,021 CUM: $52,042 ETD' $0 EFC- $1,255,042 S/L RIH TO SET SLEEVE IN MW: 0.0 Accept rig @ 0600, 3/9/96. Line up to kill well, with returns down production flowline. Hold pre-job safety meeting. Load tubing with seawater, annulus open thru choke to production flowline. Tubing perfs didn't penetrate or are plugged. Secure well. Pump diesel down flowline to freeze protect. Test lubricator to 2000 psi. RIH with 1.5" flow sleeve to set in GLM %1. $31,200 CUM: $114,442 ETD: $0 EFC: $1,317,442 CIRC 10.7 PPG BRINE TO KI MW: 0.0 Load well with 9.3 ppg "kill" weight viscous brine. Monitor well, still have pressure and good flow. Freeze protect production flowline with diesel. Monitor well, strong flow, shut-in. Weight up brine to 10.7 ppg. Circulate brine into well. $36,262 CUM: $186,966 ETD: $0 EFC: $1,389,966 CIRC 10.7 PPG BRINE TO KI MW:10.7 Finish circulating 10.7 ppg viscous brine into well, taking returns thru choke & degasser into pits. Continue to de-gas returned brine and weight up to 10.7 ppg and circulate, returns thru choke & degasser into pits. $182,258 CUM: $551,482 ETD: $0 EFC: $1,754,482 TEST BOPE, EXTEND FLOW RI MW:10.7 Continue to de-gas & weight up returned brine to 10.7 ppg. Circulate 10.7 ppg viscous brine, returns thru choke & poor-boy degasser to pits. Shut down & monitor well. No flow, well dead. NU BOPE. Test BOPE to 300/3500 psi. $56,715 CUM: $664,912 ETD: $0 EFC: $1,867,912 CIRCULATE 10.9 PPG BRINE MW:10.9 Finish testing BOPE: variable pipe rams to 300/3500 psi; annular to 250/2500 psi, OK. Circulate, getting gas cut brine at +/- 1/2 bottoms up. Closed annular, open annular and monitor well, gas boiling at flow nipple. Very slow flow. Weight up brine. Circulate and load well with brine. Date: 7/23/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 2 03/15/96 ( 7) TD: 13015' PB: 12911' SUPV: DEB DAILY: 03/16/96 ( TD:13015' PB:12911' SUPV:DEB 8) DAILY: 03/17/96 (9) TD: 13015' PB: 12911' SUPV: DEB DAILY: 03/18/96 (10) TD: 13015' PB: 12911' SUPV: DEB DAILY: 03/19/96 (11) TD: 13015' PB: 12911' SUPV: DEB DAILY: 03/20/96 ( 12} TD:13015' PB:12911' SUPV:DLW DAILY: 03/21/96 (13) TD:13015' PB: 0' SUPV:DLW DAILY: LOAD PIPE SHED WITH 3.5" MW:10.9 Finish circulating bottoms up. Monitor well. Some bubbling, no flow. Pump visc pill. Displace and spot as a balanced plug/"kill" pill. Monitor well. POH 4" tubing. $70,140 CUM: $931,642 ETD: $0 EFC: $2,134,642 CIRCULATE BOTTOMS UP MW:10.9 RIH w/3.5" DP to 9924' Gas boiling at surface, trip volume OK, no gain, no flow. Circulate out gas & oil migrating up hole. Closed annular & continued circulating through open choke. Opened annular and continued circulating. Hole stable, gas circulated out. Tag top of PBR @ 9961' Work fish up & down hole, working freely with light drag. CBU, some gas cut at bottoms up, circulated out. $32,199 CUM: $996,040 ETD: $0 EFC: $2,199,040 RIH WITH FTA %2 MW: 0.0 POH with 3-1/2" DP, slow to prevent swabbing. LD fish. RIH with FTA %2 on 3.5" DP, using vent plug in stands to prevent flowback. $38,667 CUM: $1,073,374 ETD: $0 EFC: $2,276,374 RIH WITH BIT & SCRAPER MW:10.9 RIH with FTA %2. Tagged TOL @ 10085' Work overshot over stub & latch onto fish. Circulate out gas cut brine, returns very gassy from gas migrating up hole. Closed annular and circulated at reduced rate thru choke. Circulated out relatively small amount of gas cut from behind fish. Monitor well, stable. Pump slug. POH with FTA %2. Recovered all tubing and jewelry from cut off stub thru seal assembly. RIH with bit and BHA %1. $41,193 CUM: $1,155,760 ETD: $0 EFC: $2,358,760 RIH W/BAKER RBP ON DP MW:10.9 Safety shutdown meeting. RIH with BHA %1. Tag packer @ 10938' MD, no fill. Circulate out gas cut brine. Minimal gas cut at bottoms up. Monitor well, stable. POH. RIH with Baker retrievable bridge plug. $59,671 CUM: $1,275,102 ETD: $0 EFC: $2,478,102 RIH W/SWS 4.5" TCP GUNS MW:10.8 Run 7" wireline set retrievable bridge plug, set @ 10918' Monitor well. Pre-job safety meeting on picking up DP conveyed perforating guns. RIH w/DP. Run subs @ 10024' & 9709' $43,789 CUM: $1,362,680 ETD: $0 EFC: $2,565,680 CIRC & KILL WELL AFTER PE MW: 0.0 Continue RIH w/Schlumberger 4.5" DP conveyed perforating guns on 3.5" DP to 10880' Log perforating guns on depth for top shot to be @ 10760' to 10850' POOH. Pressured up to 3000 psi, well started taking fluid @ 2500 psi. Guns fired @ 1058 hfs 13 min after pressured up. Well started to flow. Put well on choke and hold 300 psi on casing annulus. Mud foaming through poor boy degasser. Well not flowing but gas bubbling in annulus. Shut well in at 1700 hrs. Monitor well. Continue to have well control problems. ~L~glV i..i./ Ai~mka 011 & (3a~ Cong. Commission Date: 7/23/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page' 3 03/22/96 (14) TD:13015' PB:12911' SUPV:DLW DAILY' 03/23/96 (15) TD:13015' PB:t2911' SUPV:DLW DAILY: 03/24/96 { 16) TD: 13015 ' PB: 0' SUPV: DLW DAILY: 03/25/96 (17) TD:13015' PB: 0' SUPV:DLW DAILY: 03/26/96 (18) TD:13015' PB: 0' SUPV:DLW DAILY: 03/27/96 (19) TD' 13015' PB: 0' SUPV: DLW DALLY · CIRC & KILL WELL W/12 PPG HW:12.0 Continue killing well after perforating 10760' to 10850' Held 450-500 psi on annulus, 850 psi en DP while circulating @ 2 bpm. Returns going to ARCO flew tiger tank. Hud still foaming bad. Shut well in @ total circulation ef well bore. 0 psi en Dp and annulus. Heniter for 30 minutes. OK. Shut in for pressure build-up. Start pumping kill weight mud 12 ppg @ 0400 hrs., holding 400 psi on annulus and 1000 psi on DP @ 2 bpm. $79,775 CUH: $1,591,292 ETD: $0 EFC: $2,794,292 POOH W/SWS TCP GUNS MW:ll.9 Continue killing well w/12 ppg mud weight. Taking returns to ARCO tiger flow tank. Shut in well. Move foamed up mud back to rig pits thru degasser and condition 10.6+ load. Continue killing well until hole completely changed over to 12 ppg mud. Open well and monitor. Well dead. $39,532 CUM: $1,670,356 ETD: $0 EFC: $2,873,356 L/D DP TO RUN FRAC TBG MW:ll.5 L/D perforating guns. All shots fired. Wash down to 10918' Monitor well, dead. $206,982 CUM' $2,084,320 ETD: $0 EFC' $3,287,320 RUN 4" & 3.5" FRAC TBG HW'll.5 Stand back 3.5" DP. Run 4" and 3.5" frac completion. $31,200 CUM- $2,146,720 ETD: $0 EFC' $3,349,720 TRYING TO PULL FMC TEST P MW:ll.5 Continue running 4" x 3.5" frac string, EOT @ 10683', retrievable packer @ 10190' N/D BOPs. N/U tbg head adapter. Run FMC tree test plug. Test tree 250-5000 psi for 15 min., OK. Made 3 runs to pull plug damaged FMC pulling tool. $54,501 CUM: $2,255,722 ETD: $0 EFC: $3,458,722 N/U TREE HW:ll.6 Continue to try pulling FHC 4" tree plug. Keep shearing pins in pulling tool. Run impressuien block shows valve stim bent and off center. Bleed tbg pressure to "0", suck tree out. Prong leos and setting ef top ef test plug. Fish out prong and run FHC pulling tool sheared 2 pins. Plug stuck. Continue sucking fluid from tree, R/U safety valves and N/D tree install safety valve. N/U 13-5/8" BOP's ever tbg safety valve. Test HCR and annulus valves. PUll tbg hanger te rig fleer. Bleed off pressure en tbg, break out PHC tbg hanger. Install tbg safety valve. H/U FHC 11" x 4.5" tbg hanger w/NSCT 4.5 threads top & bottom & CIW profile. Land tbg hanger w/BPV in place. N/D BOP's. H/U tree. Change 11" adapter flange and test to 250-5000 psi OK., N/U tree. Bleed annulus from 250 psi te 0 psi, bleed tbg te "0" psi pull BPV @0600 hrs. $31,200 CUH: $2,318,122 ETD: $0 EFC: $3,521,122 t!C lVED Date: 7/23/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 03/28/96 (20) TD: 13015' PB: 0' SUPV: DLW DAILY: 04/03/96 (21) TD:13015' PB: 0' SUPV:DEB DAILY: 04/04/96 (22) TD:13015' PB: 0' SUPV:DEB DAILY: 04/05/96 TD:130t5' PB:12911' SUPV:DEB (23) DAILY: 04/06/96 (24) TD:13015' PB:12911' SUPV:DEB DAILY: 04/07/96 (25) TD: 13015' PB: 12911' SUPV: DEB DAILY: 04/08/96 (26) TD:13015' PB:12911' SUPV:DEB DAILY: 04/09/96 TD:13015' PB:12911' SUPV:DEB (27) DAILY: 04/10/96 (28) TD: 13015' PB:12911' SUPV: DEB DAILY: RELEASE RIG Test FMC tree 250-5000 psi. Set packer. Release rig @ 2100 hrs. 3/27/96. MW: 0.0 Secure well. $52,818 CUM: $2,423,758 ETD: $0 EFC: $3,626,758 MOVING RIG MW: 0.0 Move rig off 2M-09. Prepare to move onto 2M-29. $13,308 CUM: $2,450,374 ETD: $0 EFC: $3,653,374 KILLING WELL MW:ll.6 Accept rig @ 0600 4/3/96. Circulate kill fluid. Monitor well. Circulate more viscous brine and weight up to 11.6 PPg. $52,518 CUM: $2,555,410 ETD: $0 EFC: $3,758,410 KILL & MONITOR WELL MW:ll.6 Circulate brine to pits. Lost 73 bbls. Monitor well & attempt to bleed off trapped pressure. Strong flow of light fluid from tubing. Shut in tubing. Bled off annulus, annulus dying. Reverse out light fluid from tubing. Tubing dead. Reverse circulate brine. Lost 35 bbls. SI well. Tubing dead. $60,611 CUM: $2,676,632 ETD: $0 EFC: $3,879,632 NU 13-5/8" KSI BOPE MW:ll.6 Continue to circulate mud and monitoring well. Well dead. NU 13-3/8" 5000 psi BOPE. $49, 854 CUM: $2, 776,340 ETD: $0 EFC: $3,979,340 POH WITH FRAC STRING MW:ll.7 Function test BOPE. Test BOPE 250/3500 psi. OK. brine. Monitor well, well dead. Circulate $41,859 CUM: $2,860,058 ETD: $0 EFC: $4,063,058 RIH W/RBP RETRIEVING TOOL MW:i Continue to pull tubing. RIH with fishing as of liner @ 10,090' Work retrieving tool iht continue RIH. $36,530 CUM: $2,933,118 ETD: $0 EFC: $4,136,118 1.7 sembly, tag top o liner & REPAIRING RIG HYDRAULIC L MW:ll.7 RIH to 10,916', no fill. Reverse circulate, losing fluid. Minimal gas cut, hole clean. Tag RBP @ 10,926' Tag packer @ 10,945' . POH 15 stands to pull RBP above 7" liner, no drag. RIH w/muleshoed joint of 2-3/8" tubing on 3.5" DP. $37,045 CUM' $3,007,208 ETD' $0 EFC' $4,210,208 POH LDDP MW:ll.8 Continue RIH with 2-3/8" stinger and spaced out 9-5/8" scraper. Tag packer @ 10,945' puts 2-3/8" muleshoe @ 10, 978', & 9-5/8" scraper to 10,~60' POH LDDP. $53,906 CUM: $3,115,020 ETD: $0 EFC: $4,318,020 Date: 7/23/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 5 04/11/96 (29) TD:13015' PB:12911' SUPV:DEB DAILY: RIH W/CRX PLUG ON SLICKLI MW:12.0 Run 4" x 3.5" selective single completion. Stab into FB-1 packer & locate out. Mark pipe for space out. Space out. Install 10' pup, 1 joint below hanger. Land hanger. $31,200 CUM: $3,177,420 ETD: $0 EFC: $4,380,420 04/12/96 (30) TD:13015' PB:12911' SUPV:DEB DAILY: NU TREE MW:ll.9 RIH with 2.812" CRX plug on slickline. Attempt to set in DS nipple @ 10016' MD. Very weak slickline action due to thick, heavy brine and hole angle. Pressure up to 500 psi, leaking by plug. POH, plug came out with setting tools. RIH with 2.812" standing valve and try to set in DS nipple. Pressure up to 500 psi & held, but unable to shear down to release plug, due to weak tool action. POH, standing valve came out with tools. Pressure tubing to 2500 psi & set packer. Held 2500 psi for 15 minutes, OK. Land hanger. Test tubing to 3500 psi, 15 minutes, OK. Test annulus to 3500 psi, 15 minutes, OK. Set BPV. NU tree. $119,330 CUM: $3,416,080 ETD: $0 EFC: $4,619,080 04/13/96 { 31) TD:13015' PB:12911' SUPV:DEB DAILY: RIG RELEASED MW: 6.8 SW NU tree. Pull BPV, set test plug. Test packoff to 5000 psi, OK. Test tree to 250 psi & 5000 psi, OK. Reverse circulate diesel into annulus for freeze protection. Secure well. Release rig @ 2100 hrs. 4/12/96. $25,720 CUM: $3,467,520 ETD: $0 EFC: $4,670,520 End of WellSummary for We11:998399 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: David J~ Chairman.--~-' Blair Wondzel~2'~~ P. !. Supervisor~7~u FROM: Doug Amo~,~ ~~. SUBJECT: Petroleum Inspector DATE: April 7, 1996 FILE NO: abuhdfdd.doc BOPE Test Nordic 1 Arco KRU 2M-29 Kuparuk Rv. Field PTD No. 92-0097 Saturday, April 6, 1996: I traveled to Arco's KRU 2M-29 well to witness the BOPE Test on Nordic Rig No. 1. As the attached AOGCC B©PE Test Form indicates, this was a long test due to a hard to locate leak. The leak was finally isolated a the Stand Pipe Valve, the valve was rebuilt and the testing resumed. Ail equipment tested good after the valve repair. SUMMARY: ! witnessed the successful BOPE Test at Arco's KRU 2M-29 well on Nordic Rig No. 1. Attachment: ABUHDFDD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Workover: X DATE: Drlg Contractor: Nordic Rig No. I PTD # 92-0097 Rig Ph.# Operator: ARCO Rep.: Well Name: KRU 2M-29 Rig Rep.: Casing Size: 9 5/8" Set @ 13,002 Location: Sec. Test: Initial X Weekly Other Ron 4/6/96 659-7115 Don Breeden 28 T. 11N R. 8 E Meridian Umiat TESTDATA MISC. INSPECTIONS: Location Gen.: OK Housekeeping:. OK (Gen) PTD On Location Yes Standing Order Posted Yes Well Sign OK Drl. Rig OK Hazard Sec. Yes BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F 250/3,500 P N/A 250/3,500 P 250/3,500 P 250/3,500 P/P 250/3,500 P 250/3,500 P/P N/A MUD SYSTEM: Visual Trip Tank OK Pit Level Indicators OK Flow Indicator OK Meth Gas Detector OK H2S Gas Detector OK FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F N/A N/A 1 250/3, 500 P 1 250/3, 500 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 12 Test Pressure P/F 250/3,500 P 26 250/3,500 P I P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure 3,000 P Pressure After Closure 1,500 P Alarm 200 psi Attained After Closure minutes 30 OK System Pressure Attained 4 minutes 56 OK Blind Switch Covers: Master: Yes Remote: OK Nitgn. Btl's: 3 @ 2,000 Avg. OK Psig. OK sec. sec. Yes Number of Failures: I ,Test Time: 8.0 Hours. Number of valves tested 16 Repair or Replacement of Failed Equipment will be made within 0 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 REMARKS: The long test time was due to a slow and hard to find leak during the test. The leakoff was caused by the Kelly or Stand Pipe valve. The valve was rebuilt and the testing resumed afl equipment then tested good. Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: FI-021L (Rev. 12/94) ABUHDFDD.XLS AOGCC Individual Well Geological Materials Inventory Page' 1 Date' 09/29/95 PERMIT DATA T DATA_PLUS RUN DATE_RECVD 92-097 5723 ~CDR CORRECTED HLDT 07/26/1993 92-097 SURVEY 92-097 CBT ~/R~UB-SURFACE DIRECT. 02/22/1993 01/19/1993 92-097 CDR 92-097 CDR 10/8-10/92 ~I~i0/2-18/92 11/02/1992 11/02/1992 92-097 CDR LWD/DC ~,'~H,3669-13018 08/17/1993 92-097 CET 92-097 HLDT _o ~ _ 0917 HL[1T ~J~- CH 01/19/1993 L--C'~ U'~ 993 448-12014 06/07/1993 Are dry'dl-~amples required? Was the well cored? yes Are well tests Well is in compliance COMMENTS yes ~ And received? Q_.Analysis & description received? ~__~ce ived? required? yes I~±tial STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM~,.,,~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL ~] GAS E~] SUSPENDED [~ ABANDONED E~ SERVICE E~ ~,~ . 2 Name of Operator 7 Permit Number ... ARCO Alaska, Inc 92-97 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 ,.. 50-103-20183 · 4 Location of well at surface ~..!. ~ iii i;!~; 9 Unit or Lease Name 114' FSL, 51' FEL, SEC 28, T 11N, R 8E, UM ,/'O/~_?~.. ~[ KUPARUK At Top Producing lnterval '~;:'~; :!i:z :~ ,I~i lO WellNumber 789' FNL, 2196' FWL, SEC 5, T 10N, R 8E, UM " ' ' KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. RKB 146', PAD 105' GL ADL 25590 ALK 2676 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. ! 15 Water Depth, if offshore 116 No. of Completions 28-Sep-92 18-Oct-92 ~(Comp & Perf)/~,,,2~,/'_~-~-- NA feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey ' 12~ Depth where SSSV set 21 Thickness of permafrost 13015' MD, 6146' TVD 12911' MD, 6147' TVD YES x~J NO L._]] 1797' feet MD 1400' APPROX 22 Type Electric or Other Logs Run CDR, CDN, HLDT,CBT, CET, GCT 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5# H-40 SURF 121' 24" 210 SX AS II CMT 13.375" 68# K-55/L-80 SURF 3664' 17.5" 820 SX PERM E, 900 SX CLASS G CMT 9.625" 47# L-80 SURF 10401' 12.25" 310 SX CLASS G CMT 7" 26# J-55 10096' 13002' 8.5" 505 SX CLASS G CMT 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) 4.5" TCP GUN @ 4SPF 10850'-10900' MD 6129'-6136' TVD 4" x 3.5" J-55/L-80 10.9#/9.3# 11347' * 10954'* 4.5" TCP GUN @ 4 SPF 11430'-11550' MD 6147'-6145' TVD *Tied into Final CDR Icg of 05/27/93 4.5" TCP GUN @ 4 SPF 11720'-12180' MD 6142'-6136' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 4.5" TCP GUN @ 4 SPF 12300'-12550' MD 6136'-6141' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4.5" TCP GUN @ 4 SPF 12650'-12850' MD 6142'-6146' TVD *See attached report 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS~MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ¢ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A RECEIVED NOV 1 7 Ataska 0d & Gas Cons. C0mmissiop Anchorage 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 OF KUPARUK C 10561' 6088' BASE OF KUPARUK C 10640' 6102' TOP OF KUPARUK A 10640' 6102' BASE OF KUPARUK A N/A N/A 31. LIST OF A'i-DACHMENTS REPORT OF OPERATIONS, 2 COPIES OF DIRECTIONAL SURVEYS, FRAC/STIM REPORTS 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. Signed ~/'/~~~'~ Title ,~,-~'~-¢., ~"~-~/' DATE ~¢/'(,,~_~' INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 09/23/93 2M-29 PERFS: Stage 1. Stage 2. Stage 3. Stage 4. Stage 5. Stage 6. Pmp Stage 7. Pmp Stage 8. Pmp Stage 9. Pmp Stage 10. Pmp Stage 11. Pmp Stage 12. Pmp 12650"- 12850' Pmp 50 bbl Slk H20 @ 25 bpm 8500-8400 psi Pmp 500 bbls Pre Pad Delay XL SW @ 25 bpm 8400-7050 psi Flush 157 bbls Non XL SW @ 15 bpm 7050-4620 psi ISIP: 1648 psi, FG=0.70 Pmp 500 bbl DF XL SW @ 25 bpm 5850-7275 psi Flush 157 bbls Non XL @ 25 bpm 7275-5978 psi 1020 bbl XL SW @ 25 bpm 5650-7100 psi 525 bbls XL SW 2 PPG16/20 @ 23 bpm 7100-6180 psi 230 bbls XL SW 4 PPG 12/18 @ 23 bpm 6180-6477 psi 150 bbls XL SW 6 PPG 12/18 @ 23 bpm 6477-6400 psi 215 bbls XL SW 8 PPG 12/18 @ 20 bpm 6400-5830 psi 250 bbls XL SW 10 PPG 12/18 @ 18 bpm 5830-5680 psi 50 bbls XL SW 12 PPG 12/18 @ 15 bpm 5680-8000 psi Screen out 50 bbls into 12 PPA stage w/10.3 ppg concentration @ perfs Fluid to recover: 3389 bbls Sand in zone: 1 91000# Sand in casing: 48810# Average Press: 6500 psi RECEIVED F~OV 1 7 Gas Cons. 1_,014'IITIJS$i0n Anchorage ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 2M-29 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER 50-103-20183 ACCEPT: 09/28/92 08:30 SPUD: 09/28/92 04:00 RELEASE: 10/05/93 07:30 OPERATION: DRLG RIG: PARKER 245 WO/C RIG: NORDIC 1 09/29/92 (1) PARKER 245 TD: 1571'( o) 09/30/92 (2) PARKER 245 TD: 3686' (2115) o) 10/01/92 (3) PARKER 245 TD: 3686'( o) 10/02/92 (4) PARKER 245 TD: 3686'( 10/03/92 (5) PARKER 245 TD: 6383'(2697) DRILL & SURVEY MW: 9.6 VIS:104 MVE RIG F/2M-04 TO 2M-29. ACCEPTED RIG @ 08:30 HRS 09/28/92. NU DIVERTER SYSTEM-CHANGE F/16" SPOOL TO 20". FUNCTION TST DIVERTER BAG & VALVES. FILL STACK & CHECK FOR LEAKS. TIGHTEN GRAY LOCK CLAMP-HOOK UP DIVERTER LINES. DIVERTER & BOP TESTS WAIVED BY AOGCC. PU BHA-CHANGE STAB BLADES, ADJUST NAVI-DRILL-ORIENT TOOLS-CLEAN OUT CONDUCTOR F/110'-121'. SPUD @ 16:00 HRS 09/28/92. DRILL 16" HOLE F/121'-470'. CLEAN OUT MJYNO'S-PACKED W/CLAY. DRILL 16" HOLE F/470'-1571' POOH TO RUN 13-3/8" CSG 13-3/8"@ 3663' MW: 9.7 VIS: 74 DRILL 16" HOLE F/157'-3686' SURVEY W/MWD. CBU. WIPE HOLE TO HWDP. HOLE FREE, N6 FILL. CIRC & COND MUD FOR 13-3/8" CSG. POOH. WELD ON CSG HEAD 13-3/8"@ 3663' MW: 9.7 VIS: 64 POOH. LD DN BHA. RU GBR TONGS. RAN 13-3/8" CSG TO 1410'-HIT BRIDGE. CIRC & WASH THROUGH BRIDGE. RAN CSG TO 1552'-HIT BRIDGE. CIRC & WASH THROUGH BRIDGE. RAN 13-3/8" CSG TO 3663'. RU HOWCO. CIRC 1091 BBLS @ 10 BPM WITH FULL RETURNS. CMT CSG W/SHOE @ 3664', FC @ 3575'. CMT W/820 SX PF "E" CMT & 900 SX CLASS G TAIL CMT. NN DIVERTER SYSTEM. WASH OUT DIVERTER VALVES. MAKE ROUGH CUT ON 13-3/8" CSG. SET OUT LANDING JT. CHANGE OUT ADAPTOR SPOOLS ON 20" ANNULUR. WASH CMT OUT OF ANNULUR. SET SPOOL AND LONG RISER OUT OF CELLAR. MAKE FINAL CUT ON 13-3/8" CSG & SET IN 13-5/8", 5M X 13-3/8" SOW CSG HEAD. RIH 13-3/8"@ 3663' MW: 8.6 VIS: 31 PRE-HEAT & WELD ON 13-5/8" X 13-3/8" SOW CSG HEAD. POST HEAT AND COOL PER FMC PROCEDURES. TEST WELD W/NITROGEN. INSTALL DRILLING SPOOL. NU BOPE. TEST ALL BOPE TO 300 & 3000 PSI. LOWER IBOP FAILED, REPLACED VALVE AND RETESTED-OK. ALL AUDIO & VISUAL ALARMS WORKING. INSTALL WEAR BUSHING. MU BHA. ORIENT TOOLS & RIH. DRILLING 13-3/8"@ 3663' MW: 8.9 VIS: 36 RIH TO 3569' DRILL PLUGS & FC @ 3570' CMT TO 3643' · , · CBU. TEST CSG TO 2000 PSI. DRILL REMAINING CMT & FS @ 3663', C/O TO 3686'. DRILL 10' NEW HOLE TO 3696' CIRC HOLE CLEAN. PERFORM PIT TO 12.5 PG. EMW. DRILL ~2.25" HOLE F/3696'-6383'. SURVEY W/MWD, LOG W/LWD. RECEIVED I OV 1 ? i995 A!aska Oil & Gas Cons. Commission Anchorage, WELL: 2M-29 API: 50-103-20183 PERMIT: PAGE: 2 10/04/92 (6) PARKER 245 TD: 7485' ( 1102) 10/05/92 (7) PARKER 245 TD: 9910' (2425) 10/06/92 (8) PARKER 245 TD:10421' ( 511) 10/07/92 (9) PARKER 245 TD:10421' ( o) 10/08/92 (10) PARKER 245 TD:10421' ( o) DRILLING 13-3/8"@ 3663' MW: 9.1 VIS: 39 DRILL 12.25" HOLE F/6383'-6756'. SURVEY W/MWD. LOG W/LWD. CBU. POOH. HOLE GREE. DN LOAD LWD INFO. SERVICE MWD. BREAK BIT & RE-JET. LD TURBINE. PU MACH 1 AKO @ 1.2 DEGREES. MU BIT & RIH TO 6726' WASH F/6756' FOR ANADRILL. NO FILL. DRILL 12.2~" HOLE F/6756'-7485' SURVEY W/MWD. LOG W/LWD. DRILLING 13-3/8"@ 3663' MW: 9.2 VIS: 36 DRILL 12/25" HOLE F/7485'-9910'. SURVEY W/MWD. LOG W/LWD. STARTED SECOND KICK OFF @ 9885'. REAMING TO BTM 9-5/8"@10401' MW: 9.3 VIS: 37 DRILL 12.25" HOLE F/9910'-10421'. SURVEY W/MWD. LOG W/LWD. CBU. WIPE HOLE F/10421' TO 13-3/8" SHOE. TIGHT HOLE F/10334'-9508'. WORK PIPE, PULL SLOW AND WASH OUT. TOOK 4.5 HRS TO PULL FIRST 10 STDS. REMAINDER OF TRIP FREE. SLIP AND CUT DRILL LINE 120'. RIH TO 9513'. WASH AND REAM F/9513'-10406'. TORQUE 15-17K. BTM 35' TIGHT AND PACKING OFF. WILL INCREASE MUD WT. TO 10.4 PPG WHILE CIRC. 9-5/8"@10401' MW: 9.8 VIS: 43 CIRC & RAISE MUD WT. TO 9.8 PPG. SHORT TRIP TO 9148'. HOLE TIGHT F/10339'-9872'. RIH TO 10421', NO FILL. PMP 50 BBLS HIGH VIS SWEEP, CIRC & COND HOLE FOR 9-5/8" CSG. POOH, PULL 40 TO 50K OVER WT F/10339'-9877' AND FROM 5921'-5733'. DOWNLOAD LWD INFO, LD BHA. PULL WEAR RING, SET TEST PLUG, CHANGE TOP PIPE RAMS TO 9-5/8", TEST BONNET SEALS TO 300 PSI AND 3000 PSI-GOOD TEST. PULL TEST PLUG. FUNCTION TEST 9-5/8" RAMS-OK. RIG TO RUN 9-5/8" CSG. HOLD PRE-SAFETY MEETING. RUNNING 9-5/8" CSG. CHNG OUT 9-5/8" PIPE RAMS 9-5/8"@10401' MW:10.1 VIS: 41 RIH W/9-5/8" CSG TO 3628' CBU. NO MUD LOSS. RIH W/9-5/8" CSG TO 10,401' (~HOE DEPTH). CIRC & RECIP 9-5/8" CSG F/CMT JOB. CMT 9-5/8" CSG W/310 SX CLASS G CMT. BMP PLUG & HELD 2000 PSI FOR 15 MIN, RELEASED-FLOATS HELD. ND. SET 9-5/8" SLIPS W/353 DN/WT-ROUGH CUT CSG @ 12" LD LANDING JT-ELEVATORS-CMT HEAD-BALES. MAKE FINAL CUT-INSTALL 13-5/8" 5K X 11" 5K ADAPTER SPOOL. NU BOPE, HOOK UP KILL LINE, CHOKE LINE, FLOW LINE. CHANGE RAMS F/9-5/8" TO VARIABLES . RECEIVED U~i & Gas Cons. Commission A~chora~e WELL: 2M-29 API: 50-103-20183 PERMIT: PAGE: 3 10/09/92 (11) PARKER 245 TD:10580' ( 159) 10/10/92 (12) PARKER 245 TD:ll153' ( 573) DRILL & SURVEY 8.5" HOLE 9-5/8"@10401' MW:10.2 VIS: 41 RU TEST EQUIP. TEST ALL RAMS, CHOKE, & KILL LINES & VALVES, CHOKE MANIFOLD, HYDRIL, FLOOR SAFETY VALVES, ETC TO 3000 PSI-ALL TESTS GOOD. BOP TEST WAIVED BY AOGCC. PULL TEST PLUG, RUN WEAR BUSHING. PU BHA, ORIENT MWD TOODS. SERV RIG. RIH, FILL PIPE @ 6000'. CUT DRILLING LINE 70' DRILL PLUGS, FC, & CMT TO 10357'. CIRC. TEST 9-5/8" CSG TO 2000 PSI-NO PRESS LOSSS. DRILL CMT, & FS, CLEAN OUT RAT HOLE, CIRC PACKING OFF & DP TORQUING. CIRC & WORK PIPE. PERFORM EMW. DRILL, LOG, & SURVEY. DRILL & SURVEY 8.5" HOLE 9-5/8"@10401' MW:10.2 VIS: 45 DRILL, LOG, & SURVEY. 10/11/92 (13) PARKER 245 TD:l1241' ( 88) 10/12/92 (14) PARKER 245 TD:l1241' ( o) 10/13/92 (15) PARKER 245 TD:10784' ( o) 10/14/92 (16) PARKER 245 TD:10868' ( 84) POH FOR NEW BHA 9-5/8"@10401' MW:10.3 VIS: 46 DRIL F/11153'-11241'. LOST 500 PSI PMP PRESS-CHECK SURF EQUIP-MIX & PMP SLUG POOH-TIGHT F/10482'-10460'. DN/LOAD ANADRILL TOOLS-BIT MISSING F/BHA. SHAFT ON NAVIDRILL SHEARED, LEAVING BIT & BIT BOX F/NAVIDRILL IN HOLE, TOP OF FISH @ 11239'. LD NAVIDRILL. CK CHANGE OUST SCREW'S ON LWD & MWD. PICK UP 3 STEEL DC 6-1/4". WAIT ON TRI-STATE. SERV RIG & TOP DRIVE. CLEAN & GREASE-0-MATIC STRIP. PU OVERSHOT & TRI-STATE TOOLS-MU SAME. TIH W/OVERSHOT-TIGHT @ 11050'. WASH & REAM W/OVERSHOT F/11050'-11222', STOPPED @ 11222'. PMP SLUG & POH-TIGHT @ 10488, 10432'. RIH W/OVERSHOT 9-5/8"@10401' MW:10.3 VIS: 45 FIN POOH. PU NAVI-DRIL, ADJUST ANGLE, CHANGE STAB BLADE. CHANGE OF ORDERS, LD NAVI-DRIL. MU BIT #5, RUN BHA, RIH TO 10288', FILL PIPE @ 4000' & 7200'. CUT DRLG LINE 82', SET & CHECK CROW-OMATIC. SERV RIG & TOP DRIVE. CHANGE DIES ON GRABS. RIH, WASH & REAM F/10500'-11239'. CIRC & COND MUD. POH W/ll STDS, PMP SLUG, CONT POOH, LD NB STAB. MU 8-1/8" OVERSHOT. RIH. SIDE TRACK WELL 9-5/8"@10401' MW:10.2 VIS: 45 FIN RIH W/OVERSHOT TO 11239' WASH 41' TO FISH-ATTEMPT TO CATCH FISH @ 11239'. PMP SLUG & POH. SERV RIG & TOP DRIVE. FIN TOH-NO FISH. LD FISHING TOOLS & STEEL DC'S. PU NEW BHA-MOTOR-MWD-LWD-ORIENT TOOLS-PROGRAM-SURF TEST. TIH-FILL PIPE @ 5460' & 10361'. SIDE TRACK WELL @ 10750'-10784'. DRILLING 9-5/8"@10401' MW:10.4 VIS: 53 SIDE TRACK WELL F/10784'-10810' PMP PILL. POOH, BREAK BIT, LD NAVIDRILL. PU DYNA DRILL. MU NEW BIT. DOWN LOADED MWD. THE BIT WAS IN GAUGE AT THE CONES, OUT 1/8" AT TOP OF WEAR PADS, OUT 1/4" AT BTM OF WEAR PAD. RIH, FILL PIPE @ 5460' RIH TO 10362'. SLIP & CUT DRILL LINE. WASH & REAM F/107~9'-10810'. CONTINUE SIDETRACK F/10810' 10868' RECEIVED [',iOV t 7 & Gas Cons. Commission Anchorage WELL: 2M-29 API: 50-103-20183 PERMIT: PAGE: 4 10/15/92 (17) PARKER 245 TD:llll4' ( 246) 10/16/92 (18) PARKER 245 TD:12076' ( 962) 10/17/92 (19) PARKER 245 TD:12500' ( 424) .10/18/92 ( 20) PARKER 245 TD:13015' ( 515) 10/19/92 (21) PARKER 245 TD:13015' ( o) DRILLING 9-5/8"@10401' MW:10.3 VIS: 49 DRIL 8.5" HOLE F/10868' T/10904'. SURVEY W/MWD LOG W/LWD. HAVING PROBLEMS SLIDING & CONTROLING BENT HOUSING MOTOR. CBU. POOH, TIGHT HOLE F/BTM TO SHOE 25-65 K EXCESS DRAG. DN LOAD LWD, BREAK BIT. LD BENT HOUSING MOTOR. PU MACH 1 AKO & NEW BIT. ORIENT TOOLS. RIH TO 10401'. FILLED PIPE @ 5000'. SERVICE TOP DRIVE. REAM & WASH F/10401'-10904'. SLIDE IN W/O PMP F/10749'-10812'. DRILL 8.5" HOLE F/10904'-11114'. SURVEY W/MWD, LOG W/LWD. DRILLING 9-5/8"@10401' MW:10.4 VIS: 47 DRIL 8.5" HOLE F/11114'-11815'. SURVEY W/MWD. LOG W/LWD. CIRC PMP PILL. WIPE HOLE TO SHOE @ 10401'. INTERMITTENT PULLS 25-50K OVER NORMAL F/11071'-10792'. MUD GAS CUT F/10.4 TO 9.7 PPG ON BTMS UP. DRILL 8.5" HOLE F/11114'-12076'. SURVEY W/MWD. LOG W/LWD. RIH 9-5/8"@10401' MW:10.4 VIS: 42 DRILL 8.5" HOLE F/12076'-12500'. SURVEY W/MWD. LOG W/LWD. DEEP RESISTIVITY ON LWD FAILED & MWD FAILED. CBU. PMP PILL. POOH. ND LOAD LWD. LD LWD & MWD. CHECK BIT. PU FRESH LWD & MWD. RERUN BIT #8. ORIENT TOOLS & LAOD LWD. RIH TO 10400'. FILL PIPE @ 5000'_ SLIP & CUT DRLG LINE. BREAK CIRC @ 10400'. RIH TO 11091' TAKING WT. REAM & WASH F/11091'-11181' RUNNING IN HOLE @ 600 HRS. RIH 9-5/8"@10401' MW:10.6 VIS: 47 CONT TO RIH. REAM TIGHT SPOTS F/11600'-11638', 12094'-12185'. WASH F/12460'-12500' NO FILL. MUD GAS CUT F/10.6 TO 7.1 PPG ON BTMS UP. D~ILL 8.5" HOLE F/12500'-13015'. SURVEY W/MWD. LOG W/LWD. CBU. WIPE HOLE F/13015'-10400'. TIGHT HOLE @ 10831' REAM & WASH OUT F/10769'-10684' PULLED BALL INTO SHO~ & HAD TO REAM BTM 20' OF CSG TO G~T INTO OPEN HOLE. REAM F/10401'-10938'. RIH TO 11743' RIH W/LINER ON DP 7"@13001' MW:10.8 VIS: 48 RIH TO 12340'. WASH & REAM TO GET RESISTIVITY LOG F/12340'-12510'_ RIH TO 13015'. NO FILL_ CIRC & COND MUD. PMP HI-VIS SWEEP & INCREASE MUD WT TO 10.8 PPG. MUD GAS CUT TO 8.3 PPG ON BTMS UP. WIPE HOLE TO SHOE, NO TIGHT SPOTS, NO FILL. CIRC & COND MUD. PMP HI-VIS SWEEP. MUD CUT TO 7.1 PPG ON BTMS UP. POOH, HOLE FREE. DN LOAD LWD & LD BHA. NOSE OF BIT WORN DN TO A CONCAVE SHAPE. SLM NO CHANGE. RU GBR CSG TONGS. RUN 7" LINER W/TIW HGR, LINER TOP PKR & PBR. RUN LINER IN HOLE ON DP TO 5200' CBU @ 8 BPM, NO MUD LOSS. RUN LINER IN HOLE ON DP. CURRENTLY @ 7100' WELL: API: PERMIT: 2M-29 50-103-20183 PAGE: 5 10/20/92 (22) PARKER 245 TD:13015' ( 10/21/92 (23) PARKER 245 TD:13015' ( 10/22/92 (24) PARKER 245 TD:13015' ( 01/03/93 (25) TD:13015 PB:12911 01/04/93 (26) TD:13015 PB:12911 o) o) o) POOH 7"@13001' MW:10.8 VIS: 51 RUN LINER IN HOLE ON DP TO 10400'. CIRC @ SHOE & RU TIW CMT MANIFOLD ON SINGLE_ RIH W/LINER ON DP TO 13002'. TOOK 2 HRS TO GET LAST 5 STDS IN HOLE. CIRC @ TD @ 6-5-7 5 BPM WITH FULL RETURNS & NO PACKING OFF PROBLEMS. CMT CSG PER PROCEDURE. (TOTAL OF 505 SX CLASS G CMT). SET LINER HANGER & SET LINER TOP PACKER. TOP OF LINER @ 10096' AND BTM OF SHOE @ 13002' PBTD IS 12911'. PMP 70 BBLS PRE-FLUSH & SPACER AHEAD 6F CMT. REVERSED OUT 55 BBLS PREFLUSH AND SPACER & 20 BBLS PRE-FLUSH CONTAMINATED MUD, CUT F/10.8 TO 10.1 PPG. TESTED LINER TOP PKR TO 1500 PSI FOR 30 MIN. PMP PILL. POOH. LD LINER RUNNING TOOL. MU BIT & SCRAPER. RIH & TAG LINER TOP @ 10096' CIRC CLEAN. POOH. POOH 7"@13001' MW:10.4 VIS: 0 POOH. LD BIT & SCRAPER. CUT DRILLING LINE. PULL WEAR BUSHING, SET TEST PLUG, CHANGE BTM RAMS TO 3-1/2, TEST TO 3000 PSI-GOOD. SET WEAR BUSHING. PU BHA FOR CLEAN OUT RUN IN 7" LINER. SERV RIG & TOP DRIVE. PU 90 JTS 3-1/2" DP, RIH, TAG LANDING COLLAR @ 12911'. CBU. PMP 50 BBLS WATER, 50 BBLS HI-VIS SWEEP, & DISPLACE WELL W/10.4 PPG BRINE. MONITOR WELL. LD ALL S-135 DP. PULL & STD 65 STANDS "G" DP. RIG RELEASED 7"@13001' MW:10.4 VIS: 0 POOH. LD EXCESS "G" DP & 45 JTS 3-1/2" DP. MONITOR WELL. POOH. LD REMAINING 3-1/2" DP, 4-3/4" DC'S, SCRAPER, BIT. PULL WEAR BUSHING, CLEAR 3-1/2" EQUIPMENT OFF FLOOR. PULL 3-1/2" RAMS, INSTALL 5" RAMS. MD 13-5/8" BOP STACK-LD RISER. ND WELL HEAD & SWAB VALVE. FREEZE PROTECT WELL-150 BBLS H20 & 120 BBLS DIESEL @ 3 BPM, 500 PSI. RD INJECTION LINE. RIG RELEASED @ 17:30 HRS 10/21/92. CIRC @ TOL 7"@13001' MW:ll.5 NaC1/Br MOVE RIG F/2M-28 TO 2M-29. ND DRY HOLE TREE. NU 11" X 7" DSA & BOP. TEST BOP & CSG TO 1500 PSI. WT UP BRINE IN PITS TO 10.4 WHILE LOAD PIPE SHED W/3-1/2" DP. RIH W/BIT & 7" CSG SCRAPER ON 120 STDS 3-1/2" DP. RU 3-1/2" DP, TAG TOL @ 10075', NORDIC RKB. CBU @ TOL @ 4.5 BPM @ 1500 PSI WHILE RECIP DP. CIRC & FILTER BRINE 7"@13001' MW:ll.5 NaC1/Br FIN CBU @ TOL. RIH W/3-1/2" DP TO 12889' PBTD. RU KELLY BREAK CIRC. CIRC HI-VIS SWEEP AROUND @ 4.5 BPM. RECIPROCATE & ROTATE PIPE WHILE CIRC. SLIP & CUT DRLG LINE WHILE CIRC. POH TO TOL @ 10075'. CBU. RIH TO PBTD. CIRC HI-VIS SWEEP AROUND @ 4.5 BPM WHILE RECIP PIPE. CONT TO CIRC CLEANING PIT #3. FILTER BRINE INTO PIT #3. CIRC & FILTER BRINE @ 2-3 BPM. RECEIVED A ' *, ' is, Anchorage WELL: API: PERMIT: 2M-29 50-103-20183 PAGE: 6 01/05/93 (27) TD:13015 PB:12911 09/18/93 (28) TD:13015 PB:12911 09/19/93 (29) TD:13015 PB:12911 09/20/93 (30) TD:13015 PB:12911 RIG RELEASED 7"@13001' MW:ll.5 NaCl/Br CIRC & FILTER BTINE @ 2-3 BPM UNTIL RETURNS ARE CLEAN. POH. LD 167 JTS 3-1/2" DP. CONT POH W/120 STDS DP. DISPLACE WELL W/DIESEL @ 450'. BLOW DN LINES. POH. ND BOP. NU DRY HOLE TREE. MOVING RIG 7"@13001' MW:10.4 NaC1/Br FIN CLEANING PITS. MOVE RIG TO 1Y ACCESS TO SPINE ROAD & WAIT FOR ARCO CREW CHANGE. MOVE RIG F/1Y PAD TO 2M PAD. BROKE THRU ROAD COMING ONTO 2B PAD. CRIBBED UP W/PLYWOOD & CONT MOVING. RIG ARRIVED @ 2M PAD @ 0500 HRS. REMOVE REAR AUX WHEELS. REPLACE LANDING & STAIRS IN CELLAR AREA. RIH W/SWS TCP GUNS, PU DP 7"@13001' MW:10.4 NaCl/Br MOVE RIG OVER WELL 2M-29. ACCEPTED RIG @ 0630 HRS 09/18/93. LEVEL RIG. ND FMC DRY HOLE TREE; 11" X 4-1/16" TBG HEAD ADAPTER & MASTER VALVE. LOAD 134 BBLS 10.4 PPG BRINE INTO PITS. SET TEST PLUG. NU 11" 5 KSI BOP STACK. LOAD 3-1/2" DP INTO SHED. TEST BOPE. WITNESSING OF TEST WAIVED BY LOU GRIMALDI, AOGCC FIELD INSPECTOR. PULL TEST PLUG. TEST CSG & LINER TO 3500 PSI FOR 15 MIN, OK. LOAD SWS TCP GUNS. MU & RIH 200' OF SWS 4-1/2" TCP GUNS; 4 SPF, 180 DEG PHASING, 34B DP SHOTS ALIGNED W/CLAPPER TO HI SIDE, 43C BH SHOTS TO LOW SIDE OF HOLE. MU ABSOLUTE PRESS FIRING HEAD, 2 DEBRIS/CIRC SUBS, XO TO DP. RIH W/GUNS, PU DP. CIRC OUT DIESEL CAP @ 570'. INSERTED RA MARKER SUBS TO BE @ + 9200' WHEN GUNS ARE ON DEPTH. 320 JTS DP @ 0600, 80 JTS LEFT TO PU. POH W/DP & PERF GUNS 7"@13001' MW:10.4 NaCl/Br FIN RIH W/TCP GUNS. PU DP. LD 1 SINGLE. RU SWS. MU & RIH W/GR/CCL/NOISE TOOL. TIE INTO CDR LOG OF 10/2-18/92. PU 4' & PUT GUNS ON DEPTH. START LISTENING FOR CLAPPER W/NOISE TOOL, NOT HEARING ANY SOUND. POH. CHANGE OUT NOISE TOOL. TURN PIPE IN VARIOUS COMBINATIONS OF TURNS & LISTEN FOR CLAPPER TO CONFIRM ORIENTATION OF SHOTS TO TOP & BTM OF HOLE. FINALLY GOT GUNS ORIENTED @ 1800 HRS. POH & RD SWS E-LINE. MU CIRC HEAED. BREAK CIRC W/CHARGE PMP. CLOSE PIPE RAMS. PRESS UP ON DP & ANN TO 3000 PSI TO ACTIVATE FIRING HEAD, HOLD 5 MIN. BLEED OFF PRESS & WAIT FOR GUNS TO FIRE. FUNS FIRED +20 MIN LATER. WAIT EXTRA 25 MIN FOR SAFETY. PERF A SAND F/12650'-12850'. OPENED PIPE RAMS & FILLED HOLE W/6 BBLS. MONITOR WELL-STABLE. CBU, 4 BPM, 1400 PSI. NO GAS OR TRASH ON BU. LOST 7 BBLS. SWITCH OVER & DISPLACE WELL W/VISC BRINE, 4 BPM, 1100 PSI. HAD CLEAN BREAKOVER TO VISC RETURNS @ EXPECTED VOL. CONT CIRC VISC BRINE F/OUTSIDE TANKS TO PITS. TRANSFERRED REMAINING CLEAR BRINE F/PITS TO TIGER TANKS. BREAK OFF CIRC HEAD. PULL 1 JTS DP, WET. MIX & PMP SLUG. POH W/DP & PERF GUNS. RECEIVE WELL: API: PERMIT: 2M-29 50-103-20183 PAGE: 7 09/21/93 (31) TD:13015 PB:12911 09/22/93 (32) TD:13015 PB:12911 09/23/93 (33) TD:13015 PB:12911 09/24/93 (34) TD:13015 PB:12911 CIRC HOLE CLEAN 7"813001' MW:10.5 NaC1/Br POH W/3-1/2" DP. LD SWS 4-1/2" TCP PERF GUN ASSY. ASF. CHECKED TATTLE TALES; ONE SHOWED SHOTS FIRED ORIENTED TO TOP & BOTTOM OF HOLE AS PLANNED, OTHER SHOWED ORIENTATION WITH 5 DEG OF PLAN. CLEAR TOOLS. CHANGE SHAKER SCREENS. NU BIT & BIT SUB. RIH W/199 STDS DP. POH-LD 50 JTS DP FOR REAMING. KELLY UP. WASH & DOUBLE REAM SINGLES F/11014'-12898' PBTD. CBU 8 4-3/4 BPM, 1200 PSI. RECIP & ROTATE DOWN W/KELLY WHILE CIRC. RIH W/3-1/2" WORK STRING 7"813001' MW:10.4 NaCl/Br CONT CIRC HOLE CLEAN 8 4-3/4 BPM, 1200 PSI. RECIP & ROTATE DOWN W/KELLY WHILE CIRC. RECOVERED PIPE DOPE & PERF DEBRIS, CIRC CLEAN. BREAK OFF KELLY. TEST UPPER & LOWER KELLY COCKS. BLOWDOWN & STANDBACK KELLY. MIX SLUG. SLIP & CUT 50' OF DRILL LINE. PMP SLUG. POOH-LD 170 JTS DP. MOVE PIPE OUT OF SHED. RD LD LINE. CONT POH W/DP STANDS. LD BIT & BIT SUB. PULL WEAR RING. RD DP EQUIP. RU TBG EQUIP. RACK & TALLY 3-1/2" TBG. RIH W/3-1/2" WORKSTRING FOR FRAC JOB. RIG ON STANDBY FOR FRAC 7"813001' MW:10.4 NaCl/Br SERV RIG. FIN RUNNING 3-1/2" FRAC STRING. MU FMC 4" TBG HGR USING CROSSOVER COUPLING ON TOP JT OF 3-1/2". MU 3-1/2" LJT W/2 XO TO 4-1/2" BTC LANDING THREAD. LAND HGR. RILDS. RU LINES. CIRC 110 BBLS CLEAR BRINE INTO TBG, DISPLACING VISC BRINE 8 2 BPM, 500 PSI. RU OTIS SL. TEST LUB TO 3500 PSI. RIH & SET CAT STANDING VALVE IN D-NIPPLE 8 10145' SLM. PRESS TBG/ANN TO SET PKR. POOH W/SL LEAVING TOOL STRING IN HOLE. WIRE KINKED & PARTED APPROX 12' ABOVE TOOL STRING. MU RET TOOL. RIH & LATCH FISH. POOH W/FISH. RD WL. BACK OUT LJT, XO LEFT IN HGR. MU LJT W/SAFETY VALVE. RAISE STACK & LOOSEN XO. RESET STACK & BACK OUT LJT. SET BPV. ND BOPE. NU FMC TREE, PULL BPV, SET PLUG & TEST TREE TO 5000 PSI. SECURE WELL & MOVE RIG OFF WELL. RIG ON STANDBY FOR FRAC W/DOWELL. RIH W/OTIS SL TO PULL DV 7"813001' MW:10.4 NaC1/Br RIG ON STANDBY FOR FRAC W/DOWELL & CTU C/O OF WORKSTRING. SET BPV & REMOVE SCAFFOLDING F/WELL. MOVE RIG OVER WELL. PULL BPV. RU OTIS SL & RIH TO PULL DUMMY VALVE F/GLM @ 10093' RECEIVED WELL: API: PERMIT: 2M-29 50-103-20183 PAGE: 8 09/25/93 (35) TD:13015 PB:12911 09/26/93 (36) TD:13015 PB:12911 09/27/93 (37) TD:13015 PB:12911 POOH & LD 3-1/2" TBG WS 7"@13001' MW:10.4 NaCl/Br RIH W/SL TOOLS TO RETRIEVE DUMMY F/GLM @ 10093' TAGGED BRIDGE. PMP 10 BBLS BRINE INTO TBG. WORK TOOLS & RIH TO 9856' TAGGED ANOTHER BRIDGE-WOULD NOT GO DEEPER. CALLED OUT S~S. RAN OTIS 2-1/2" DRIVE-DOWN BAILER. TAGGED BRIDGE, DROVE DOWN TO 9864'. POH, NO RECOVERY. RD OTIS. WO SWS. MU KILL LINE & TEST FLLOR VALVES & CHOKE MANIFOLD. RU SWS. TEST LUB TO 1500 PSI. RIH W/TWO 1-11/16" TBG PUNCH GUNS. TIE INTO TBG & SHOOT FIRST GUN-NO HOLES. TIE IN & FIRE SECOND GUN @ SAME SPOT. VERIFY HOLES W/PMP. POH. RD SWS. REVERSE CIRC TBG VOL, DISPLACE CLEAR BRINE W/VISC BRINE. MONITOR WELL, WELL DEAD. RD CIRC JT & LINES. TRANSFER BRINE. SET BPV. ND TREE, NU 13-5/8" BOP STACK. TEST BOPE. BOLDS & PU TBG W/140K LBS IN ATTEMPT TO FREE PKR. WORK PIPE SEVERAL TIMES WITHOUT SUCCESS. PMP W/5 BPM, 900 PSI, & UP WT OF 145K LBS. UNABLE TO SHEAR PKR FREE. RU SWS & MU JET CUTTER. PU ON TBG W/80K LBS & SET SLIPS. RIH TO 9840' & CUT TBG. POOH & RD SWS. PU ll0K LBS & PART TBG. PULL HGR TO FLOOR, BACK OUT & LD SAME. POOH & LD 3-1/2" TBG WORKSTRING. WAIT ON DART 7"@13001' MW:10.4 NaCl/Br SERV RIG. POOH W/3-1/2" TBG WS. PIPE PULLING WET. RU TO PMP DRY JOB. MIX & PMP 35 BBL SLUG. POOH W/TBG. REMOVE SEAL RINGS & LD. RD TBG EQUIP. BRING FISHING TOOLS TO FLOOR. MU FISHING BHA. WAIT ON NEW BUMPER JARS. RIH W/FISHING BHA ON 3-1/2" DP. KELLY UP & BREAK CIRC, TAG FISH @ 9834' (NORDIC RKB). MILL OVER TBG STUMP & ROTATE PKR FREE. WASH OVER TBG & PU FISH. STAND BACK KELLY & PULL 1 STD DP. ATTEMPT TO CIRC THRU FISH-NO SUCCESS. PRESS TO 2500 PSI. BLEED PRESS OFF. DROP DART TO PMP OUT SUB. C/O FRAC SAND IN WELL 7"@13001' MW:10.4 NaC1/Br SERV RIG. WAIT ON DART. POOH. CIRC EVERY 20 STDS IN ATTEMPT TO SHEAR PMP OUT SUB. PRESS PIPE TO 2500 PSI W/OUT SHEARING SUB. DART FINALLY REACHED SUB W/120 OF 150 STDS OF DP OOH. PRESS UP 1500 PSI & SHEARED SUB. CBU. MIX & PMP DRY JOB. POOH W/3-1/2" DP. POOH W/FISHING BHA. LD DC'S, JARS, & BUMPER SUB. BREAK OUT O/S W/15' TBG STUB. CLEAR FLOOR OF DP EQUIP & RU TO POOH W/3-1/2" TBG. POOH W/FISH. CLEAN FRAC SAND F/PLUGGED JTS & CLEAN FLOOR FREE OF FRAC SAND. RU DP EQUIP. RIH W/6-1/8" BIT & BHA #2 TO C/O FRAC SAND F/WELL. RIH. BREAK CIRC. REAM DOWN TO 11175' @ RPT TIME. RECEIVED liOV, 1 7 'i'~93~ 6,as Cons. Commission Anchorage WELL: API: PERMIT: 2M-29 50-103-20183 PAGE: 9 09/28/93 (38) TD:13015 PB:12911 09/29/93 (39) TD:13015 PB:12911 09/30/93 (40) TD:13015 PB:12911 10/01/93 (41) TD:13015 PB:12911 10/02/93 (42) TD:13015 PB:12911 CIRC FRAC SAND F/WELL 7"@13001' MW:10.5 NaCl/Br SERV RIG. REAM DOWN SINGLES F/11000' TO 12899' TO C/O FRAC SAND F/WELL. REAM EACH JT W/RATE @ 4.5 BPM. CIRC. ROTATE & RECIP PIPE WHILE CIRC. RU MI SOLIDS CONTROL VAN TO AID IN CLEANING SOLIDS F/FLUID. BREAK & STAND BACK KELLY. POOH. CIRC, ROTATE & RECIP PIPE. LARGE AMT OF FRAC SAND OVER SHAKERS & F/SOLID CONTROLS VAN. REPLACE SCREEN ON RIG SHAKER. CONT TO CIRC @ 4.5 BPM, ROTATE & RECIP PIPE. RU SWS E-LINE 7"@13001' MW:10.5 NaCl/Br CIRC @ 4.5 BPM, ROTATE, & RECIP PIPE UNTIL FLUID CLEANED UP. BLOW DOWN & STAND BACK KELLY. SLIP & CUT 50' OF DRILL LINE. PMP DRY JOB. POH W/3-1/2" DP. LOAD SWS PERF GUNS IN PIPE SHED. LOAD SWS EQUIPMENT. HOLD SAFETY MEETING. MU & RUN 54 SWS 4-1/2" TCP GUNS. RIH W/3-1/2" DP. SPACE OUT W/DP FOR GUN PLACEMENT. RU SWS E-LINE. RIH W/PERF GUNS 7"@13001' MW:10.5 NaCl/Br RIH W/GR/CCL. CORRELATE & POSITION GUNS ON DEPTH. POH. RD SWS. FILL DP. HOLD SAFETY MEETING. PRESS DP TO 2500 PSI, INCREASE GRAD TO 4400 PSI, SHEARED TPPV. FIRE GUNS. PERF F/11430'-11550', 11720'-12180', 12300'-12550' W/SWS 4.5" TCP GUNS, 4 SPF, 90 DEG PHASING, 34B DEEP PENETRATING CHARGES. CORRELATED TO CDR LOG. MONITOR WELL. REPAIR GLAND NUT ON MUD PMP. CIRC. POH W/3-1/2" DP. LD SWS PERF GUNS IN PIPE SHED. LOAD SWS EQUIP. HOLD SAFETY MEETING. MU & RUN 3 SWS 4-1/2" TCP GUNS. RIH W/3-1/2" DP. FILL DP EVERY 10 STDS. MU BHA 7"@13001' MW:10.5 NaC1/Br RIH W/3-1/2" DP. SPACE OUT. RU SWS. RIH W/GR/CCL/NOISE TOOL. CORRELATE & POSITION GUNS ON DEPTH. ORIENT GUNS. POH. RD SWS. FILL DP. CLEAN PMP SCREEN. HOLD SAFETY MEETING. PRESS DP TO 2500 PSI, INCREASE TO 4500 PSI AFTER 2 MIN, SHEARED TPPV. PERF F/10850'-10900' W/SWS 4.5" TCP GUNS, 4 SPF, 180 DEG PHASING, ORIENTED 0 DEG CCW FROM TOP OF HOLE, 34B DEEP PENETRATING CHARGES TO TOP OF HOLE & 43C BH CHARGE TO BTM OF HOLE. CORRELATED TO CDR LOG. MONITOR WELL. CIRC. POOH W/3-1/2" DP. LD SWS PERF GUNS. ASF. MU BIT & BHA. PREP TO RIH. POH 7"@13001' MW:10.5 NaC1/Br SERV RIG. RIH W/3-1/2" DP. TAGGED PBTD @ 12899'. PU KELLY. CBU WHILE ROTATE & RECIP DP. TRANSFER VISC BRINE VOL TO PITS. DISPLACE WELL W/10.4 PPG CLEAR BRINE FLUID. FLUSH LINES, TRANSFER REMAINING VISC FLUID TO OUTSIDE TANK & CLEAN PITS. STAND BACK KELLY. FIN TRANSFER OF CLEAR BRINE TO PITS. CHECK FLUID LOSES-APPROX 3 BPH. POOH W/3-1/2" DP. RECEIVEC gas 6ons. Anchorage WELL: API: PERMIT: 2M-29 50-103-20183 PAGE: 10 10/03/93 (43) TD:13015 PB:12911 POH 7"@13001' MW:10.5 NaCl/Br SERV RIG. FIN POH. LD DC, JAR & BIT. PULL WEAR RING. SET TEST PLUG. CONDUCT FULL BOP TEST. RU TO RUN PKR & TAILPIPE ASSY. MU SOS, 11 JTS OF 3-1/2" L-80 TBG, CAMCO D NIPPLE, JT OF TBG, & BAKER FB-1 PERM PKR. RIH W/PKR. SPACE OUT. RU SWS. RIH & TIE IN PKR ON DEPTH. POH. RD SWS. DROP BALL. RU CIRC HOSE. CIRC BALL DN. SET PKR. SHEAR OFF PKR. COULD NOT CIRC. ATTEMPT TO GAIN CIRC W/O SUCCESS. POH 2 STDS & PIPE PULLED DRY. TOP OF FB-1 PKR SET @ 10954' & TAIL @ 11347' MD. POH & LD 3-1/2" DP. SHUT DN & MONITOR WELL. FLUID LOSS @ 32 BPH. RIH TO 10850'. MIX XANVIS PILL & PMP. MONITOR WELL, NO LOSSES AFTER PUMPING PILL. POH & LD 3-1/2" DP. 10/04/93 (44) TD:13015 PB:12911 10/05/93 (45) TD:13015 PB:12911 RUNNING COMPLETION 7"@13001' MW:10.5 NaCl/Br TRANSFER BRINE. MIX & PMP DRY JOB. SERV RIG. POH & LD DP. LD BAKER PKR SETTING TOOL. RIH DP STANDS IN DERRICK. POH & LD SAME. PULL WEAR RING. FIN UNLOADING DP/F PIPE SHED. LOAD PIPE SHED W/3-1/2" & 4" TBG. DRIFT, STRAP, & CHECK SEAL RINGS. MU BAKER SEAL ASSY, CAMCO SLIDING SLEEVE, BLAST JTS, & GLM. RIH W/3-1/2" TBG. RIH W/BLANKING PLUG 7"@13001' MW:10.5 NaCl/Br SERV RIG. RIH W/3-1/2" , L-80, 9.3# EUE 8RD MOD TBG, & 4", J-55, 11#, BTC MOD TBG. SPACE OUT TBG. PU FMC HGR & ATTACH SSSV CONTROL LINE & TEST. LAND TBG. RILDS. RU OTIS SL. DISCOVERED OTIS LUB CONNECTION NOT AS EXPECTED. COULD NOT MAKE UP TO TIW VALVE & PMP IN SUB. WAIT ON CROSSOVER F/OTIS SHOP IN DEADHORSE. RU LUB & TEST TO 3500 PSI. RIH W/PLUG @ 50 FPM. 10/06/93 (46) TD:13015 PB:12911 RIG RELEASED 7"@13001' MW:10.5 NaC1/Br POH W/RUNNING TOOL ON SL. PRESS TBG TO 2500 PSI TO SET PKR. BOLDS. PU & SHEARED PBR W/92K#. RELANDED HGR & RILDS. PRESS ANN & TBG TO 1000 PSI. BLED OFF TBG TO 500 PSI TO TEST SSSV. OK. OPENED SSSV. PRESS TBG TO 3000 PSI & ANN TO 2500 PSI. NO COMMUNICATION. RU OTIS. RETRIEVE TEST TOOL F/D NIPPLE @ 10032' CLOSED SSSV. BO LANDING JT. SET BPV. ND BOP. NU TREE. RETRIEVE BPV. SET TEST PLUG. TEST TREE TO 250/5000 PSI. RETRIEVE TEST PLUG. OPENED SSSV. OPENED SSSV. FREEZE PROTECTED ANN BY PUMPING 29 BBLS DIESEL. PMP 6 BBLS DIESEL DN TBG @ 1 BPM @ 1400 PSI FOR FREEZE PROTECTION. SITP=800 PSI. SICP=800 PSI. CV IN GLM @ 9930' NOT HOLDING. RETRIEVING TOOL NOT AVAILABLE FOR CV. PREP RIG FOR MOVE & MOVED OFF 2M-29 WELL. RELEASE RIG @ 1930 HRS 10/05/93. SIGNATURE: (drilling ~e ~in-tende~ DATE: r-~ UIDANCE ~'] ONTINUOUS ~-J OOL SUB - S URFA CE DIRECTIONAL SURVEY RECEIVED Oil & G~s Cons. Col~imission Anchorage Company Well Name Field/Location ARCO ALASKA, INC. 2N-29 (114' FSL, 51' FEL, SEC 28, TllN, R8E, UN) KUPARUK, NORTH SLOPE, ALASKA Job Reference No. 93017 Loqqed By: dOHNSON Date lO-dAN-93 Computed By: KRUldELL SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA INC 2M-29 KUPARUK RIVER NORTH SLOPE, ALASKA SURVEY DATE: lO-JAN-93 ENGINEER' G. JOHNSON MEll-IODS OF COMPUTATION TOOL LOCATION' TANGENTIAL- Averaged deviation and azimuth INTERPOLATION- LINEAR RECEIVED .. :~ ~;',2 OH & Gas Cons. Commission Anchorage VERTICAL SECTION' HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 56 DEG 26 MIN WEST COMPUTATION DATE' 7-FEB-93 PAGE ARCO ALASKA INC 2M-29 KUPARL~{ RIVER NORTH SLOPE, ALASKA DATE OF SURVEY- lO-JAN-93 KELLY BUSHING ELEVATION' 146.00 FT ENGINEER' G. JOHNSON INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IOO FEET FEET FEET DEG 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 900 O0 0 O0 -146 O0 100 200 299 399 499 599 698 797 895 0 0 O0 -46 O0 0 16 O0 54 O0 0 23 99 153 99 0 33 99 253 99 0 37 97 353 97 I 44 76 453 76 5 47 82 552.82 9 24 29 651.29 10 42 16 749.16 12 47 N 0 0 E S 27 46 W S 22 17 W S 26 7 W S 25 36 W S 35 44 W S 53 33 W S 56 32 W S 58 16 W S 58 49 W 0 O0 0 06 0 59 I 26 2 14 3 69 9 84 23 34 40 75 61 23 0 O0 0 91 0 O0 0 O0 0 38 2 71 3 73 2 10 2 53 I 77 0 O0 N 0 05 S 0 64 S 1 35 S 2 27 S 3 81 S 7 87 S 15 61 S 25 O1 S 35 58 S 0 O0 E 0 03 W 0 28 W 0 61W 106 W I 90 W 6 58 W 17 65 W 32 31 W 49 88 W 0 O0 N 0 0 E 0 0 1 2 4 10 23 40 61 06 S 31 53 W 70 S 23 43 W 48 S 24 18 W 51 S 24 57 W 26 S 26 29 W 26 S 39 54 W 56 S 48 31W 85 S 52 15 W 27 S 54 30 W 1000.00 1100.00 1088 1200.00 1183 1300.00 1276 1400.00 1368 1500.00 1457 1600.00 1545 1700.00 1631 1800.00 1713 1900.00 1791 992 14 14 942 13 1037 57 1130 04 1222 52 1311 62 1399 27 1485 25 1567 91 1645 846 14 15 17 14 17 12 13 19 26 57 22 17 04 25 17 52 27 21 62 29 33 27 32 54 25 36 46 91 39 21 S 55 54 W S 56 14 W S 57 11W S 57 37 W S 58 29 W S 59 2O W S 60 6 W S 60 58 W S 59 51 W S 60 12 W 85 57 113 56 144 79 180 39 220 76 265 34 312 56 364 O1 421 09 482 72 2 32 1 53 3 27 3 77 2 56 1 17 3 13 4 75 3 34 2 12 48 75 S 64 81 100 122 145 169 194 222 253 46 S 93 57 S 119 84 S 149 15 S 183 18 S 222 07 S 262 38 S 307 55 S 357 51S 411 51W 113 64 W 144 58 W 180 88 W 220 11W 265 93 W 312 87 W 364 69 W 421 10 W 482 70 35 W 85 59 S 55 17 W 58 S 55 25 W 80 S 55 43 W 40 S 56 1W 76 S 56 24 W 35 S 56 50 W 59 S 57 15 W 10 S 57 44 W 27 S 58 7 W 98 S 58 20 W 2000 O0 1867 55 1721 55 42 34 2100 2200 2300 2400 2500 2600 2700 2800 2900 O0 1939 O0 2006 O0 2070 O0 2129 O0 2184 O0 2237 O0 2290 O0 2342 O0 2393 23 1793 90 1860 74 1924 88 1983 78 2038 78 2091 61 2144 19 2196 49 2247 23 46 0 90 48 40 74 51 59 88 55 19 78 57 50 78 57 59 61 58 34 19 59 3 49 59 27 S 59 31W 547 98 S 58 11W 617 61 S 57 35 W 691 21 S 56 37 W 768 15 S 56 55 W 848 76 S 57 34 W 932 32 S 57 28 W 1017 11 S 57 41W 1102 O0 S 58 3 W 1187 64 S 58 1W 1273.44 3 04 3 28 2 67 3 14 2 60 1 07 0 31 1 66 0 24 1 24 286 21 S 467 73 W 548.35 S 58 32 W 322 361 403 447 492 538 583 629 674 30 S 527 48 S 589 31S 654 63 S 721 73 S 791 30 S 863 89 S 935 49 S 1007 88 S 1080 34 W 618.04 S 58 34 W 67 W 691.65 S 58 29 W 25 W 768.57 S 58 21 W 59 W 849.15 S 58 11 W 95 W 932.72 S 58 7 W 46 W 1017.51 S 58 4 W 09 W 1102.42 S 58 1 W 62 W 1188.09 S 58 0 W 47 W 1273.92 S 58 1 W 3000 O0 2444 05 2298 05 59 30 3100 O0 2494 77 2348 3200 O0 2545 30 2399 3300 O0 2595 03 2449 3400 O0 2642 76 2496 3500 O0 2691 40 2545 3600 O0 2741 13 2595 3700 O0 2792 03 2646 3800.00 2843 35 2697 3900.00 2894.22 2748 77 59 41 30 59 32 03 61 18 76 61 17 40 60 27 13 59 52 03 58 56 35 59 19 22 59 30 S 57 58 W 1359 69 S 58 2 W 1445 S 58 5 W 1532 S 57 46 W 1618 S 57 49 W 1706 S 58 23 W 1794 S 58 50 W 1880 S 58 46 W 1966 S 58 42 W 2052 S 58 54 W 2138 84 11 82 68 O2 71 70 47 49 0 68 0 39 0 3O 1 9O 0 88 1 24 0 92 0 73 0 13 0 38 720 72 S 1153 56 W 1360 20 S 58 0 W 766 36 S 1226 812 04 S 1299 858 06 S 1373 905 O0 S 1447 951 20 S 1521 996 40 S 1595 1040 79 S 1669 1085 41 S 1742 1130.05 S 1816 67 W 1446 38 S 58 0 W 88 W 1532 68 S 58 0 W 42 W 1619 43 S 58 0 W 71W 1707 30 S 57 59 W ow w VED w ECE! 60 W 2139.40 S 58 7 W .......... ~ u:~s Cons. Commisslo. ~chorage ARCO ALASKA INC 2M-29 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE' 7-FEB-93 PAGE 2 DATE OF SURVEY: lO-JAN-93 KELLY BUSHING ELEVATION: 146.00 FT ENGINEER: G. JOHNSON INTERPOLATED VALUES FOR EVEN iO0 FEET OF MEASURED DEPTH TRUE SL~-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION A~IMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 4000 O0 2944 79 2798.79 59 37 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 2995 O0 3045 O0 3096 O0 3146 O0 3197 O0 3247 O0 3297 O0 3347 O0 3397 35 2849.35 59 39 86 2899.86 59 36 49 2950.49 59 32 87 3000:87 59 59 O1 3051.01 59 47 37 3101.37 59 46 79 3151.79 59 40 99 3201.99 60 3 73 3251.73 60 16 S 58 58 W 2224 67 S 58 52 W 2310 S 58 27 W 2397 S 58 2 W 2483 S 58 4 W 2569 S 57 54 W 2656 S 57 45 W 2742 S 57 26 W 2828 S 57 20 W 2915 S 57 6 W 3002 87 11 31 66 14 51 86 33 O7 0 21 0 49 0 41 0 33 0 17 0 33 0 2O 0 41 0 46 0 36 1174 54 S 1890 51 W 2225.66 S 58 9 W 1219 1263 1309 1355 1400 1446 1493 1539 1586 07 S 1964 94 S 2038 37 S 2111 10 S 2184 95 S 2258 98 S 2331 24 S 2404 86 S 2476 87 S 2549 41 W 2311.93 S 58 11 W 13 W 2398.23 S 58 12 W 43 W 2484.47 S 58 12 W 72 W 2570 86 S 58 11W og W 2657 37 S 58 11 W 20 W 2743 76 S 58 10 W 13 W 2830 12 S 58 9 W 97 W 2916 60 S 58 8 W 88 W 3003 34 S 58 6 W 5000.00 3447.24 3301.24 60 23 5100.00 3496.36 3350 36 60 46 5200.00 3544.90 3398 5300.00 3593.22 3447 5400.00 3641.58 3495 5500.00 3689.59 3543 5600.00 3737.40 3591 5700.00 3784.93 3638 5800.00 3832.38 3686 5900.00 3879.76 3733 90 61 5 22 61 3 58 61 10 59 61 21 40 61 33 93 61 39 38 61 44 76 61 42 6000 OO 3927 25 3781 25 61 39 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 3975 O0 4023 O0 4072 O0 4122 O0 4173 O0 4225 O0 4278 O0 4331 O0 4383 11 3829 11 61 4 62 3877 62 60 51 70 3926 70 60 21 60 3976 60 59 48 42 4027 42 59 8 24 4079.24 58 26 19 4132.19 57 41 37 4185.37 58 25 13 4237.13 59 27 S 57 2 W 3088 95 S 56 53 W 3176 S 56 53 W 3263 S 56 37 W 3351 S 56 20 W 3438 S 55 58 W 3526 S 55 49 W 3614 S 55 23 W 3702 S 54 52 W 3790 S 54 24 W 3878 05 48 03 56 28 10 08 08 10 S 53 49 W 3966 03 S 53 28 W 4O53 S 53 8 W 4141 S 53 15 W 4228 S 53 11W 4314 S 53 12 W 4400 S 53 27 W 4485 S 53 55 W 4570 S 53 8 W 4655 S 53 18 W 4740 72 O3 O2 54 52 92 65 23 65 0 24 0 59 0 39 0 37 0 49 0 41 0 25 0 65 0 31 0 57 O. 63 0.41 O. 38 0 44 0 51 0 84 0 63 1 10 1 43 2 16 1634 12 S 2622 79 W 3090 21 S 58 5 W 1681 1729 1777 1825 1874 1923 1973 2023 2074 59 S 2695 36 S 2769 35 S 2842 74 S 2915 58 S 2988 92 S 3060 58 S 3133 97 S 3205 93 S 3277 82 W 3177 05 W 3264 28 W 3352 21W 3439 O8 W 3527 74 W 3615 37 W 3703 55 W 3791 37 W 3878 30 S 58 3 W 71 S 58 1W 24 S 57 59 W 74 S 57 57 W 42 S 57 54 W 19 S 57 51W 11 S 57 48 W 04 S 57 44 W 98 S 57 40 W 2126 52 S 3348 66 W 3966 82 S 57 35 W 2178 2230 2283 2335 2386 2437 2488 2538 2589 64 S 3419 94 S 3489 12 S 3559 03 S 3628 68 S 3697 87 S 3766 09 S 3834 43 S 3902 74 S 3970 33 W 4054 41 S 57 30 W 40 W 4141 62 S 57 24 W 18 W 4228 52 S 57 19 W 57 W 4314 96 S 57 14 W 49 W 4400 87 S 57 9 W O0 W 4486 20 S 57 5 W 37 W 4570 89 S 57 1W 47 W 4655.42 S 56 57 W 93 W 4740.79 S 56 53 W 7000 O0 4432 03 4286 03 62 3 7100 7200 7300 7400 7500 7600 7700 7800 O0 4478 O0 4523 O0 4569 O0 4615 O0 4661 O0 4706 O0 4750 oo 4794 33 4332 65 4377 24 4423 19 4469 26 4515 05 4560 42 4604 16 4648 33 62 42 65 63 12 24 62 40 19 62 34 26 62 48 05 63 40 42 63 39 16 64 23 7900 O0 4837 13 4691 13 64 35 S 54 30 W 4827 76 S 55 18 W 4916 37 S 56 12 W 5005 50 S 55 52 W 5094 50 S 55 43 W 5183 31 S 56 7 W 5272 06 S 57 14 W 5361 47 S 57 11W 5451 08 S 58 42 W 5540 97 S 58 44 W 5631 20 2 48 1 34 0 47 0 39 0 16 2 53 0 22 1 08 1 05 0 76 2641 32 S 4041 27 W 4827.88 S 56 50 W 2692 2742 2791 2841 2891 2940 2989 3036 20 S 4113 18 S 4187 94 S 4261 89 S 4334 85 S 4408 67 S 4483 28 S 4558 97 S 4634 84 W 4916 46 S 56 48 W 65 W 5005 59 S 56 47 W 45 W 5094 59 S 56 46 W 88 W 5183 39 S 56 45 W 24 W 5272 13 S 56 44 W 14 W 5361 54 S 56 44 W 43 W 5451 15 S 56 45 W 66 W 5541 05 S 56 46 W 3083 95 S 4711 78 W 5631 31 S 56 48 W ECEIVED ConS. Col)t~l ARCO ALASKA INC 2M-29 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: 7-FEB-93 PAGE 3 DATE OF SURVEY: lO-JAN-93 KELLY BUSHING ELEVATION: 146.00 FI ENGINEER: G. JOHNSON INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN 8000 O0 4880.77 4734 77 63 6 8100 8200 8300 8400 8500 8600 8700 8800 8900 O0 4927.48 4781 O0 4976.62 4830 O0 5028 05 4882 O0 5078 72 4932 O0 5128 16 4982 O0 5178 64 5032 O0 5231 54 5085 O0 5284 84 5138 O0 5338 O0 5192 48 61 19 62 59 35 05 59 72 60 9 16 60 28 64 58 32 54 57 41 84 57 51 O0 57 53 9000 O0 5391 13 5245 13 57 58 9100 9200 9300 9400 9500 9600 9700 9800 9900 O0 5444 O0 5498 O0 5551 O0 5603 O0 5654 O0 5704 O0 5754 O0 5802 O0 5851 40 5298 14 5352 54 5405 48 5457 90 5508 80 5558 04 5608 81 5656 02 5705 40 57 35 14 57 23 54 58 20 48 58 42 90 59 55 80 60 6 04 60 53 81 60 47 02 61 39 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEG MIN FEET S 58 34 W 5721 10 S 58 49 W 5809 44 S 59 20 W 5896 45 S 59 33 W 5982 09 S 60 3 W 6068 15 S 60 9 W 6154 89 S 59 51W 6241 04 S 58 37 W 6325 79 S 58 31W 6410 35 S 58 30 W 6495 O0 S 58 27 W '"6579 66 S 58 9 W 6664 S 58 0 W 6748 S 57 2O W 6833 S 56 39 W 6918 S 55 49 W 7004 S 55 14 W 7090 S 54 44 W 7177 S 54 42 W 7265 S 53 59 W 7352 24 54 06 51 28 92 93 19 74 DEG/IO0 FEET FEET FEET DEG MIN 3.37 2 2O 3 19 0 39 0 68 0 52 1 69 0 91 0 32 0 63 0 15 0 45 0 25 1 88 0 71 1 77 0 45 0 52 0 41 1 71 3130 74 S 4788 63 W 5721 23 S 56 49 W 3176 3221 3264 3308 3351 3394 3438 3482 3526 63 $ 4864 43 S 4938 98 S 5012 38 S 5087 68 S 5162 83 S 5237 12 S 5310 30 S 5382 57 S 5454 20 W 5809 88 W 5896 76 W 5982 25 W 6068 62 W 6155 38 W 6241 36 W 6326 52 W 6410 74 W 6495 60 S 56 51W 62 S 56 53 W 30 S 56 55 W 40 S 56 58 W 19 S 57 0 W 39 S 57 3 W 19 S 57 5 W 77 S 57 6 W 45 S 57 7 W 3570 90 S 5526 93 W 6580 14 S 57 8 W 3615 3659 3704 3751 3799 3848 3898 3948 3999 32 S 5598 95 S 5670 99 S 5742 59 S 5813 11S 5885 24 S 5956 20 S 6O27 64 S 6099 76 S 6170 97 W 6664 52 W 6749 07 W 6833 70 W 6919 09 W 7004 48 W 7091 75 W 7178 O0 W 7265 15 W 7353 75 S 57 9 W 07 S 57 10 W 61 S 57 10 W 07 S 57 10 W 82 S 57 9 W 45 S 57 8 W 42 S 57 7 W 65 S 57 5 W 15 S 57 3 W 10000 O0 5897.03 5751 03 63 28 10100 10200 10300 10400 10500 10600 10700 10800 10900 O0 5939.33 5793 O0 5977.35 5831 O0 6013.46 5867 O0 6047.40 5901 O0 6076.33 5930 O0 6095.01 5949 O0 6112.65 5966 O0 6121.77 5975 O0 6136.27 5990 33 66 21 35 68 42 46 69 30 40 70 26 33 74 33 O1 79 55 65 84 52 77 83 14 27 81 44 11000 O0 6147 38 6001 38 85 15 11100 11200 11300 11400 11500 11600 11700 11800 11900 O0 6152 O0 6152 O0 6150 O0 6148 O0 6146 O0 6144 O0 6142 O0 6140 O0 6138 80 6006 44 6006 61 6004 19 6002 06 6000 81 5998 90 5996 53 5994 86 5992 80 88 57 44 90 57 61 91 9 19 91 33 06 90 58 81 90 45 90 91 20 53 91 5 86 91 5 S 54 0 W 7441 45 S 50 28 W 7531 S 47 49 W 7623 S 46 31W 7715 S 44 54 W 7807 S 40 9 W 7900 S 39 44 W 7994 S 40 5 W 8088 S 39 51W 8184 S 42 28 W 8279 81 43 55 94 53 52 69 32 57 S 43 42 W 8376 42 S 45 4 W 8474 S 45 15 W 8572 S 45 30 W 8670 S 46 8 W 8768 S 44 25 W 8866 S 45 17 W 8964 S 44 3 W 9062 S 43 59 W 9160 S 44 19 W 9258 04 21 47 63 73 57 54 27 06 3 09 5 02 1 03 3 77 2 62 7 21 6 57 6 28 5 71 4 76 94 O1 39 35 49 68 45 .80 .01 .29 4051 74 S 6242 12 W 7441 82 S 57 1 W 4107 4168 4231 4296 4367 4443 4518 4594 4669 O0 S 6313 10 S 6383 07 S 6452 83 S 6519 66 S 6583 06 S 6646 50 S 6709 48 S 6773 39 S 6838 90 W 7532 31W 7623 09 W 7715 34 W 7807 45 W 7900 23 W 7994 19 W 8088 55 W 8184 16 W 8280 12 S 56 57 W 63 S 56 51W 66 S 56 45 W 98 S 56 37 W 53 S 56 26 W 57 S 56 14 W 89 S 56 2 W 75 S 55 51W 31 S 55 40 W 4741 42 S 6906 60 W 837~ 48 S 55 32 W 4812 4882 4952 5022 5092 5164 5234 5306 5377 76 S 6976 86 S 7047 58 S 7119 61S 7190 86 S 7261 14 S 7331 89 S 7402 45 S 7472 87 S 7542 42 W 8475 72 W 8573 38 W 8672 72 W 8771 84 W 8869 96 W 8968 59 W 9066 40 W 9164 38 W 9263 44 S 55 24 W 95 S 55 17 W 58 S 55 11W 15 S 55 4 W 7O S 54 57 W 05 S 54 51W 56 S 54 44 W 89 S 54 37 W 31 S 54 31W RECEIVED COMPUTATION DATE: 7-FEB-93 PAGE 4 ARCO ALASKA INC 2M-29 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: lO-JAN-93 KELLY BUSHING ELEVATION: 146.00 FT ENGINEER: G. JOHNSON INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURB VBTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DE8 MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DE8/iO0 FEET FEET FEET DEG MIN 12000 O0 6137 62 5991 62 90 17 12100 12200 12300 12400 12500 12600 12700 12800 12900 O0 6137 O0 6136 O0 6136 O0 6136 O0 6139 O0 6143 O0 6145 O0 6146 O0 6146 13 5991 67 5990 15 5990 62 5990 21 5993 30 5997 72 5999 74 6000 94 6000 13 90 17 67 90 18 15 90 12 62 89 16 21 87 36 30 88 6 72 88 58 74 89 42 94 90 2 S 44 5 W 9355.85 S 43 12 W 9453.50 S 43 54 W 9550.87 S 43 42 W 9648.39 S 42 39 W 9745.69 S 43 28 W 9842.89 S 43 31 W 9940.25 S 44 11W 10037.72 S 44 14 W 10135.45 S 44 9 W 10233.17 1 53 3 4O 1 66 0 72 1 49 2 13 1 51 1 82 0 74 0 35 5449.31S 7612 34 W 9361 77 S 54 24 W 5521.24 S 7681 5594 03 S 7750 5666 38 S 7819 5739 38 S 7887 5812 54 S 7955 5885 07 S 8024 5957 44 S 8093 6029 09 S 8163 6100 81S 8232 81W 9460 37 W 9558 39 W 9656 73 W 9754 84 W 9852 56 W 9951 52 W10049 27 W10148 96 W10247 14 S 54 18 W 31 S 54 11W 64 S 54 4 W 83 S 53 58 W 97 S 53 51W 26 S 53 45 W 69 S 53 39 W 35 S 53 33 W 02 S 53 28 W 13000.00 6146.31 6000.31 90 54 13015.00 6146.15 6000.15 91 6 S 44 8 W 10330.87 S 44 8 W 10345.53 1 .11 0.00 6172.58 S 8302.59 W10345.71 S 53 22 W 6183.34 S 8313.03 W10360.51 S 53 21 W RECEIVED I 7 O:i & 8as Cons, Commission Anchorage COMPUTATION DATE: 7-FEB-93 PAGE 5 ARCO ALASKA INC 2M-29 KUPARUK RIVER NORTH SLOPE, ALASKA DATE DF SURVEY: lO-JAN-93 KELLY BUSHING ELEVATION: 146.00 FT INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 0 14 846 55 1721 05 2298 79 2798 24 3301 25 3781 03 4286 77 4734 13 5245 14 15 17 55 42 34 05 59 30 79 59 37 24 60 23 25 61 39 03 62 3 77 63 6 13 57 58 ENGINEER: G. JOHNSON VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 -146 O0 O0 992 O0 1867 O0 2444 O0 2944 O0 3447 O0 3927 O0 4432 O0 4880 O0 5391 0 O0 57 98 69 67 95 03 76 10 66 0 O0 1000 2000 3000 4000 5000 6000 7000 8000 9000 N 0 0 E S 55 54 W 85 S 59 31W 547 S 57 58 W 1359 S 58 58 W 2224 S 57 2 W 3088 S 53 49 W 3966 S 54 30 W 4827 S 58 34 W 5721 S 58 27 W 6579 10000.00 5897.03 5751.03 63 28 11000.00 6147.38 6001.38 85 15 12000.00 6137.62 5991.62 90 17 13000.00 6146.31 6000.31 90 54 13015.00 6146.15 6000.15 91 6 S 54 0 W 7441.45 S 43 42 W 8376.42 S 44 S W 9355.85 S 44 8 W 10330.87 S 44 8 W 10345.53 0 O0 2 32 3 04 0 68 0 21 0 24 0 63 2 48 3 37 0 15 0 O0 N 48 286 720 1174 1634 2126 2641 3130 3570 0 O0 E 75 S 70 21S 467 72 S 1153 54 S 1890 12 S 2622 52 S 3348 32 S 4041 35 W 85 73 W 548 56 W 1360 51W 2225 79 W 3090 66 W 3966 27 W 4827 74 S 4788 63 W 5721 90 S 5526 93 W 6580 0 O0 N 0 0 E 59 S 55 17 W 35 S 58 32 W 20 S 58 0 W 66 S 58 9 W 21 S 58 5 W 82 S 57 35 W 88 S 56 50 W 23 S 56 49 W 14 S 57 8 W 3.09 5.94 I. 53 1.11 O. O0 4051.74 S 6242 12 W 7441.82 S 57 1 W 4741.42 S 6906 60 W 8377.48 S 55 32 W 5449.31S 7612 34 W 9361.77 S 54 24 W 6172.58 $ 8302.59 W10345,71 S 53 22 W 6183.34 S 8313.03 W10360.51 S 53 21 W RECEIVED ,,-..~::. }:xa (,:~ & Gas Cons. Caaimission Anchorage COMPUTATION DATE' 7-FEB-93 PAGE 6 ARCO ALASKa INC 2M-29 KUPARUK RIVER NORTH SLOPE, ALASKa DATE OF SURVEY. lO-JAN-93 KELLY BUSHING ELEVATION- 146.00 FT ENGINEER' G. JOHNSON INTERP0~TED VALUES FOR EVEN 1OO FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMLFFH DEPTH DEPTH DEPTH DEG MIN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEQ/100 FEET FEET FEET DEQ MIN 000 146 OO 246 OO 346 O1 446 O1 546 07 646 $7 747 87 849 68 952 28 0 O0 -146.00 146 O0 246 O0 346 O0 446 O0 546 O0 646 O0 746 O0 846 O0 946 O0 0 0 0.00 0 23 100.00 0 26 200 O0 0 36 300 O0 0 51 400 O0 3 22 500 O0 7 43 600 O0 10 1 700 O0 11 50 800 O0 14 16 N 0 0 E S 21 54 W S 24 28 W S 26 19 W S 24 30 W S 48 5 W S 54 54 W S 57 19 W S 59 13 W S 57 8 W 0 O0 0 29 0 86 1 65 2 65 $ 56 15 35 31 43 50 49 73 42 0 O0 0 O0 0 O0 0 O0 0 50 5 84 2 95 1 23 1 30 2 76 0 O0 N 0 31S 0 94 S 1 77 S 2 82 S 5 21S 11 09 S 20 O1S 30 05 S 42 03 S 0 O0 E 0 15 W 0 41 W 0 81 W 1 31 W 3 21 W 11 06 W 24 44 W 40 66 W 60 23 W 0 O0 N 0 0 E 0 34 S 25 10 W 1 02 S 23 30 W 1 95 S 24 40 W 3 11 S 24 51W 6 12 S 31 39 W 15 66 S 44 54 W 31 59 S 50 41W 50 56 S 53 32 W 73.44 S 55 6 W 1055 97 1046 O0 1160 75 1146 1267 08 1246 1375 69 1346 1487 04 1446 1600 43 1546 1717 61 1646 1841.20 1746 1970.95 1846 2109.77 1946 900.00 16 24 O0 1000.00 18 21 O0 1100.00 21 20 O0 1200 O0 24 35 O0 1300 O0 27 12 O0 1400 O0 29 33 O0 1500 O0 33 41 O0 1600 O0 37 56 O0 1700 O0 41 36 O0 1800 O0 46 18 S 55 50 W S 56 58 W S 57 12 W S 58 19 W S 59 17 W S 60 6 W S 60 56 W S 59 46 W S 59 52 W S 58 6 W 100 79 132 09 168 18 210 50 259 42 312 78 373 64 446 05 528 52 624 66 2 49 2 63 2 02 3 50 1 04 3 12 4 13 2 68 4 03 2 89 57 32 S 74 94 116 142 169 199 235 276 326 82 92 W 100 81 S 55 21 W 67 S 108 25 S 139 77 S 175 15 S 217 17 S 263 07 S 316 14 S 379 37 S 450 02 S 533 98 W 132 30 W 168 15 W 210 O1W 259 11W 312 32 W 373 29 W 446 91W 528 33 W 625 11 S 55 35 W 19 S 55 55 W 50 S 56 19 W 42 S 56 46 W 81 S 57 16 W 75 S 57 49 W 26 S 58 12 W 86 S 58 30 W 08 S 58 34 W 2260 37 2046 O0 1900 O0 50 42 2428 2615 2807 3003 3201 3406 3609 3805 4002 60 2146 50 2246 41 2346 84 2446 39 2546 73 2646 70 2746 20 2846 38 2946 O0 2OOO O0 2100 O0 2200 O0 2300 O0 2400 O0 2500 O0 2600 O0 2700 O0 2800 O0 56 8 O0 57 57 O0 59 2 O0 59 29 O0 59 33 O0 61 14 O0 59 48 O0 59 20 O0 59 37 S 56 56 W S 57 13 W 872 S 57 29 W 1030 S 58 4 W 1194 S 57 59 W 1363 S 58 6 W 1533 S 57 51W 1712 S 58 54 W 1889 S 58 42 W 2056 S 58 58 W 2226 737 19 39 24 O0 O0 3O 58 09 93 73 3 86 3 46 0 25 0 20 0 59 0 31 0 8O 1 02 0 10 0 23 386 33 S 628 36 W 737 62 S 58 25 W 460 545 632 722 812 908 1000 1087 1175 48 S 741 37 S 874 85 S 1013 47 S 1156 67 S 1300 14 S 1452 73 S 1603 74 S 1746 60 S 1892 42 W 872 54 W 1030 O1W 1194 36 W 1363 90 W 1533 71W 1713 10 W 1889 80 W 2057 27 W 2227 78 S 58 9 W 65 S 58 3 W 44 S 58 0 W 50 S 58 0 W 87 S 58 0 W 21 S 57 59 W 81 S 58 2 W 79 S 58 5 W 72 S 58 9 W 4200 27 3046 O0 2900.00 59 36 4398 4597 4796 4997 5202 5409 5618 5828 6039 27 3146 27 3246 O1 3346 48 3446 26 3546 16 3646 06 3746 76 3846 43 3946 O0 3000.00 59 59 O0 3100 O0 59 46 O0 3200 O0 60 2 O0 3300 O0 60 23 O0 3400 O0 61 5 O0 3500 O0 61 13 O0 3600 O0 61 35 O0 3700 O0 61 44 O0 3800 O0 61 32 S 58 27 W 2397 34 S 58 4 W 2568 S 57 45 W 2740 S 57 21W 2911 S 57 2 W 3086 S 56 53 W 3265 S 56 20 W 3446 S 55 47 W 3629 S 54 45 W 3815 S 53 37 W 4000 16 16 88 76 46 58 98 39 68 0 41 0 19 0 18 0 43 0 20 0 43 0 59 0 19 0 38 0 85 1264 06 S 2038 33 W 2398 47 S 58 12 W 1354 1445 1538 1632 1730 1830 1932 2038 2147 31S 2183 72 S 2329 O0 S 2474 92 S 2620 45 S 2770 19 S 2921 85 $ 3073 57 S 3226 06 S 3376 44 W 2569 21W 2741 06 W 2913 96 W 3088 71W 3266 89 W 3447 88 W 3631 25 W 3816 62 W 4001 36 S 58 11W 41 S 58 10 W 15 S 58 8 W 02 S 58 5 W 69 S 58 1W 76 S 57 56 W O7 S 57 5O W 34 S 57 43 W 43 S 57 33 W rCEIVED,. COMPUTATION DATE: 7-FEB-93 PAGE 7 ARCO ALASKA INC 2M-29 KUPARU~ RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: lO-JAN-93 KELLY BUSHING ELEVATION: 146.00 FT ENGINEER: G. JOHNSON INTERPOLATED VALUES FOR EVEN lO0 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 6245 8~ 4046 O0 '3900.00 60 39 6446 6639 6828 7029 7249 7466 7690 7920 8138 29 4i46 45 4246 04 4346 98 4446 27 4546 82 4646 04 4746 67 4846 20 4946 O0 4000.00 59 28 O0 4100.00 58 5 O0 4200.00 58 39 O0 4300'.00 62 2i O0 4400.00 62 51 O0 4500.00 62 30 O0 4600.00 63 39 O0 4700.00 64 35 O0 4800.00 60 47 S 53 13 W 4i80 95 S 53 7 W 4354 S 53 39 W 4519 S 53 6 W 4679 S 54 55 W 4854 S 56 0 W 5049 S 55 44 W 5242 S 57 7 W 5442 S 58 46 W 5649 S 58 58 W 5842 42 42 11 28 4i 60 15 86 83 1 04 0 85 1 08 0 39 0 78 0 50 0 88 0 73 0 66 0 97 2254 91 S 3521 40 W 4181 49 S 57 22 W 2359 2457 2552 2656 2766 2875 2984 3093 3193 O0 S 3660 81S 3792 79 S 3921 64 S 4062 67 S 4224 32 S 4383 44 S 4550 64 S 4727 90 S 4892 53 W 4354 99 W 4519 60 W 4679 92 W 4854 09 W 5049 86 W 5242 93 W 5442 74 W 5649 80 W 5842 80 S 57 12 W 69 S 57 3 W 28 S 56 56 W 38 S 56 49 W 49 S 56 47 W 68 S 56 44 W 22 S 56 45 W 97 S 56 48 W 99 S 56 52 W 8334 99 5046 O0 4900 O0 59 19 8536 8727 8915 9102 9289 9482 9683 9889 10116 03 5i46 06 5246 05 5346 99 5446 45 5546 35 5646 48 5746 45 5846 72 5946 O0 5000 O0 5100 O0 5200 O0 5300 O0 5400 O0 5500 O0 5600 O0 5700 O0 5800 O0 60 7 O0 57 43 O0 57 52 O0 57 34 O0 58 11 O0 59 36 O0 60 52 O0 61 31 O0 66 45 S 59 42 W 6012 08 S 60 4 W 6i86 S 58 31W 6348 S 58 30 W 6507 S 58 8 W 6666 S 57 29 W 6824 S 56 4 W 6989 S 54 46 W 7163 S 53 58 W 7343 S 49 39 W 7547 13 65 73 76 09 O4 51 46 05 1 91 1 90 0 36 0 61 0 42 2 32 2 63 0 73 0 98 5 34 3280 18 S 5038 67 W 6012 30 S 56 56 W 3367 3450 3533 3616 3700 3790 3889 3994 4116 28 S 5189 05 S 5329 23 S 5465 65 S 5601 14 S 5734 58 S 5872 87 S 6015 30 S 6162 82 S 6325 75 W 6186 87 W 6349 60 W 65O8 11W 6667 51W 6824 46 W 6989 97 W 7164 65 W 7343 67 W 7547 45 S 57 1W 05 S 57 5 W 19 S 57 7 W 27 S 57 9 W 64 S 57 10 W 59 S 57 10 W oi s 57 7 W 88 S 57 3 W 34 S 56 57 W 10395.81 6046.00 5900.00 70 20 10983.79 6146.00 6000.00 84 51 13015.00 6146.15 6000.15 91 6 S 45 0 W 7804.07 S 44 9 W 8360.68 S 44 8 W 10345.53 1.16 5.99 O. O0 4294.03 S 6516.55 W 7804.11 S 56 37 W 4729.70 S 6895.48 W 8361.69 S 55 33 W 6183.34 S 8313.03 W10360.5i S 53 21 W ARCO ALASKA INC 2M-2g KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 13 3/8" CASINO 9 $/8" INTER CSG LAST READING GCT TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A PBTD 7" PROD CSG COMPUTATION DATE' 7-FF__B-93 PAGE 8 DATE OF SURVEY: IO-JAN-93 KELLY BUSHING ELEVATION: I46.00 FT ENGINEER: G, JOHNSON INTERPOLATED VALUES FOR CHOSEN HoRIZONs SURFACE LOCATION = 114' FSL ~ 51' FEL, SEC28 T11N R8E UM MEASURED DEPTH 'I-VD BELOW KB FROM KB SUB-SEA 3664 O0 10401 O0 10484 20 10561 O0 10640 O0 10640 O0 12911 .00 13002.00 13015.00 2773 51 6047 74 6073 38 6087 72 6102 48 6102 48 6146 94 6146 29 6146 15 2627 51 5901 74 5927 38 5941 72 5956 48 5956 48 6000 94 6000 29 6000 15 RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 1024 84 S 4297 50 S 4355 75 S 4413 66 S 4473 22 S 4473 22 S 6108 7O S 6174 O1S 6183 34 S 1643 23 W 6520 O0 W 6573 53 W 6621 74 W 6671 34 W 6671 34 W 824O 62 W 8303 98 W 8313 03 W RECEIVED ARCO ALASKA INC 2M-29 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 13 3/8" CASING g 5/8" INTER CSG LAST READING GCT TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A PBTD 7" PROD CSG COMPUTATION DATE: 7-FEB-g3 PAGE 9 DATE OF SURVEY: lO-JAN-93 KELLY BUSHING ELEVATION: 146.00 FT ENGINEER: G. JOHNSON STRATIGRAPHIC SUMMARY SURFACE LOCATION = 114' FSL & 51' FEL, SEC28 T11N RSE UM MEASURED DEPTH TVD BELOW .KB FROM KB SUB-SEA 3664 O0 10401 O0 10484 20 10561 O0 10640 O0 10640 O0 12911 O0 13002 O0 13015 O0 2773 51 6047 74 6073 38 6087 72 6102 48 6102 48 6146 94 6146 29 6146 15 2627 51 5901 74 5927 38 5941 72 5956 48 5956 48 6000 94 6000 29 6000 15 RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 1024 84 S 4297 50 S 4355 75 S 4413 66 S 4473 22 S 4473 22 S 6108 70 S 6174 O1S 6183 34 S 1643.23 W 6520 O0 W 6573 53 W 6621 74 W 6671 34 W 6671 34 W 8240 62 W 8303 98 W 8313 03 W FINAL WELL LOCATION AT TO: -I'RUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 13015.00 6146.15 6000.15 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 10360.51 S 53 21 W RECEIVED DIRECTIONAL SURVEY COMPANY FIELO COUNTRY RUN DATE LOQOED DI;PTH UNIT ARCO ALASKA INC KUPARUK RIVER 2M-29 USA 1 10 - JAN FEET 93 93017 RECEIVED ~!~r~ka Oil & Gas Cons. Commission Anchorage NELL: (114' 2H-29 FSL, 5].' FEL, SEC 28, T11N, R8E, tlR) HORIZONTAL PROJECTION ~)00 RECEIVEE A~'~chorage WELL' ZH-Z9 (114' FSL, 51' FEL, SEC 28, T11N, R8E, UR) 1C000 VERTICAL PROJECTIOH 12CX:: 0 RECEIVED Oil & C.'as u .)ns. ~ol41missJon ~ncflor'age ---- q ARCO Alaska, Inc. Date: August 13, 1993 Transmittal #: 8836 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. receipt and return one signed copy of this transmittal. 1Y.24~/5--?Z. ct'5-'-¢(o 1 H-21 R~--- m5 2M-32 9'¥~, ~ H-21 H-21 Wz,-~o 2 M-07 cl'c-ci'~ ~ 2M-29 ~3~..-7o <,,I Y-22 Y-22 HLDT/CNTG CDR Enhancement LWD/Depth Corrected CDR LWD/Depth Corrected CDR LWD/Depth Corrected CDN LWD/Depth Corrected CDR LWD/Depth Corrected CDR LWD/Depth Corrected CDR LWD/Depth Corrected CDN LWD/Depth Corrected 8-06-93 5-25-93 5-25-93 5-25-93 1-19-92 5-27-93 7-14-93 7-14-93 Please acknowledge 7543-8232 4674-8317 4~r~= ~ 2995 4665-8319 4665-8319 3180-10345 3669-13018 3508-6036 3508-6036 Receipt Acknowledged: DISTRIBUTION' D&M NSK Date: RECEIVED Drilling Catherine Worley(Geology) AUG 1 7 199~) Alaska 0il & Gas Cons. Commission Anchorage State of Alaska, (+Sepia) ARCO Alaska, Inc. Date: July 23, 1993 Transmittal #: 8812 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. and return one signed copy of this transmittal. '0t~29 ~"'{ 3"'~LIs Tape and Listing: 10-18-92 92622 L,~_,$'~ ~ ~...,,~ft,"7Bit Runs of CDR. Corrected HLDT ,~_.~-07 b '[''' LIS Tape and Listing: 9-18-93 92563 ~,.~? ,.~,?,,,\ 3 Bit Runs of CDR. Corrected HLDT ~'~t'1~-21 S'! ,,,, LI.S Tape and Listing: 3-27-93 93132 ~ ~o~. ./q '3-"" CDR/CDN & QRO Enhanced Resistivity 43.~V1-32 :)' .o, LIS Tape and Listing: 11-17-92 92686 ~,~"'.~\'\CDR Runs 1 & 2, Averaged Cased Hole HLDT ?Z -.-.' LIS Tape and Listing: 6-26-93 93292 . ~.,~ DTE/SDN & CNTH ~r~x ~/ LIS Tape and Listing: 6-9-93 93263 ~0 J..,,,~ CDR/CDN & GR CBT in LDWG Format ~!"~-22 '~'1'- LIS Tape and Listing: 5-29-93 93244 ~~,~ _. .[.,,~ \~CDR/CDN in 1 Bit Run, GR from CBT ¢~'~....I-Y:17 ~ '~ /,LIS Tape and Listing: 5-23-93 93241 L/" ,_,~ I .,./-.CDR Runs 1 & 2, CDN Run 2, QRO Processed ~'~/.~EF12 ~'"~ \ ~' LIS Tape and Listing: 5-18-93 93239 t.~-- 1 CNTG/HLDT & Arithmetic Average ___ R ece,pt Ac kn // ~/ Anchd'rage DISTRIBUTION: Please acknowledge receipt Bob Ocanas State of Alaska ARCO Alaska, Inc. / Date: June 04, 1993 Transmittal #: 8¢55 RETURN TO: ARCO Alaska, Inc. Attn: Nikki Stiller Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following ~ items. receipt and return one signed copy of ~mittal. ~¢~fD '1' _.~1H-10 _ _, '"'4H-10 ff~"~ f~ /1H-12 - ,,,,,~. "N1H-12 ~¢~ - 2M-07 ~~( -- 1B-12 2M-29 Receipt Acknowledged: DISTRIBUTION: D&M NSK Please acknowledge CDN-LWD/Depth Corrected CDR-LWD/Depth Corrected CDN-LWD/Depth Corrected CDR-LWD/Depth Corrected HLDT, Corrected CH Density HLDT'Corrected CH Density HLDT-Corrected CH Density 3/2-5/93 4414-7561 3/2-5/93 4414-7561 3/17-20/93 5317-11034 3/! 7-20/93 5317-11 034 1/9/93 8000-9336 5/18/93 8030-8682 1/8/93 10448-12014 Drilling St.ate of Alaska(.+Sepia) Date: VendorPackage(Johnsto~/~? Kathy Worley(Geologyi¢° ARCO Alaska, Inc. Date: February 19, 1993 Transmittal #: 8667 RETURN TO: ARCO Alaska, Inc. Attn: Nikki Stiller Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Sub-Surface Directional 01-10-93 93016 Survey Sub-Surface Directional 0 1 - 3 1 - 93 93052 Survey Sub-Surface Directional 0 1 - 1.0-93 9301 7 Survey Receipt Acknowledg e~-~~~ DISTRIBUTION: D&M State of Alaska (2 copies) Date: .............. RECEIVED Alaska 0il & {~as Cons. Commission Anchorage ARCO Alaska, Inc. Date: January 15, 1993 Transmittal #: 8644 RETURN TO: ARCO Alaska, Inc. ATTN: Nikki Stiller Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Cased Hole items. Please acknowledge receipt and return one signed copy of this transmittal. 1H-20 H-20 I-!-19 2~-07 -20 Cement Bond Log Cement Evaluation Log Cement Evaluation Log Cement Bond Log Cement Bond Log Cement BOnd Log Cement Evaluation Log Cement Evaluation Log 01 -08-93 3950-10145 01-08-93 3950-10164 01 -07-93 6950-8882 01 -07-93 6950-8863 01 -09-93 7000-9308 01 -08-93 9900-11979 01 -09-93 7000-9350 01 -08-93 9900-12027 Receipt Drilling Acknowledge: State of Alaska(+sepia) Date: RECEIVED NSK JAN 1 9 1995 Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: October 30, 1992 Transmittal #: 8587 RETURN TO: ARCO Alaska, Inc. Attn: Nikki Stiller Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. Please acknowledge receipt and return one signed copy of this transmittal. M-29 &"5'"'~"~ 3J-1 2 Receipt CDR 10/8-10/92 10401-11241 CDR 10/2-18/92 10401-13015 Injection Profile Continuous 1 0 - 2 0 - 9 2 7 6 5 0 - 7 9 5 0 Spinner GR-CCL-Temp. Acknowledged' -- Date: N~'~)'~" 1992 DISTRIBUTION: Alaska 0il & Gas Cons. Commission Anchorage D&M Drilling Vendor Package(Johnston) NSK State of Alaska(+Sepia) L S AOILANDGAS CONSERVATION COMMISSION September 25, 1992 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 A W McBride Drilling Engineer Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 2M-29 ARCO Alaska, Inc. Permit No: 92-97 Sur. Loc. ll4'FSL, 51'FEL, Sec. 28, TllN, R8E, UM Btmhole Loc. 754'FNL, 2165'FWL, Sec. 5, T10N, R8E, UM Dear Mr. McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ,.~TA-I-E OF ~ ALASKA OIL AND GAS CONSERVATION COMMIbolON PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill D i b Type of Well Exploratory D Stratigraphic Test I-'1 Development Oil X Re-Ent~ E] Deepen D Service E] Development Gas E] SinclleZone X Multiple Zone 2.. Name of Operator 5. Datum Elevation (DF or KB) 1 0. Field and Pool ARCO Alaska, Inc. RKB 146', Pad 105' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25590, ALK 2676 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 20 A.AC 25.025) 114' FSL, 51' FEL, Sec. 28, T11N, R8E, UM Kuparuk River Unit Statewide At top of productive interval (O TARGET ) 8. Well number Number 735' FSL, 1794' FEL, Sec. 32, T11N, RSE, UM 2M-29 #UG630610 At total depth 9. Approximate spud date Amount 754' FNL, 2165' FWL~ Sec. 5~ T10N~ R8E~ UM 9/28/92 $200r000 1 2. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and '[VD) property line 2M-30 13005' MD 754 @ TD feet 15' @ 200' MD feet 2560 6162' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.03.6(e)(2)) Kickoff depth 500 feet Maximum hole angle 88.94° Maximumsufface 1629 Dsla At total depth (TVD) 3117 18. Casing program Settin~l Depth size Specifications Top Boltom Quantity of cement Hole Casing Weight Grade Coupling Length MD ..)TVD MD TVD {include sta~le dataI 24' 20 91.5 H-40 Weld 80' 41' 41' 121' 121' +150 CF 16" 13.375 68.0 L-80 BTC 3663' 41' 41' 3704' 2751' 380 Sx Permafrost E & 900 Sx Class G 12.25" 9.625 47.0 L-80 BTCMOl' 4721' 41' 41' 4762' 3275' 180 Sx Class G 12.25' 9.625 47.0 L-80 BTC 5661' 4762' 3275' 10423' 6033' 8.5" 7 26.0 J-55 BTC 2882' 10123' 5925' 13005' 6162' 45 Sx Class G Light Weight 360 Sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True-Vertical depth ' R E¢ E IV E D Surface Intermediate Production LinerS E P 1 1992 Perforation depth: measured Alaska 0il & Gas Cons, C0mraissi0n true vertical;Anchorage 20. Attachments Filing fee X Property plat E] BOP Sketch X Diverter Sketch X Ddlling program X Ddlling fluid program X Time vs depth plot [-~ Refraction analysis D Seabed report D 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Si¢lned Z~/,/~. ~-/~.~.,,~ Title Area Drilling Engineer Date ~/21/~... Commission Use Onl~ Permit Number I AP, number I Approva, date~,_ ~._~_ ~.(;~ I See cover letter for C'~.. - ~,~ ~, 5 O-/~_-~ -- ~ ~/~:>,~ other rec]uiremonts Conditicns of approva~ SamCes required I--I Yes ~' No Mud io. required I--! Yes /I~1' No Hydrogen sulfide measures 0 Yes .J~ No Directional survey required .J~ Yes 0 No Required workin.q pressure for BOPE O 2M ,~ 3M 0 5M O 10M O 15M Other: OriginatDavid Signed By by order of Approved ,, dohiqstoF! Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 2M-29 I . . . , . , . , 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. Move in and rig up Parker #245. Install diverter system. Drill 16" hole to 13-3/8" surface casing point (3704')according to directional plan. Run and cement 13-3/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 12-1/4" hole to 9-5/8" casing depth (10,423') according to directional plan. Run LWD tools as needed. Run and cement 9-5/8" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) Pressure test to 3500 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to TD (13,005') as per directional plan. Run LWD tools as needed. Run 7" liner from 10,123' to TD (300' liner lap). Cement liner and set liner hanger and liner top packer. ND BOPE and install lower production tree assembly. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate, stimulate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. RECIEIVED S E P 2 1 1992 Alaska Oil & Gas Cons, O0rfl~'tSSi0B Anchorage DRILLING FLUID PROGRAM Well 2M-29 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-100' 5-15 15-40 10-12 9-10 10% +_ Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9-10 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Weight up to TD 10.1-10.6 16-22 12-20 40-50 2-4 4-8 4-6 9-10 9-12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1629 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 2M-29 is 2M-30. As designed, the minimum distance between the two wells would be 15' @ 200' MD. The wells would diverge from that point. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of a previously drilled well on 2M pad. That annulus will be left with a non-freezing fluid during any extended shut down (>4hr) in pumping operations. The annulus will be sealed with 175+ sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 80-100 sec/qt to drill gravel beds. Adjust FV to 50-60 sec/qt below gravel beds. RECEIVED S E P ?_ 1 1992 Alaska 0il & Gas Cons. Commission ;Anchorage Casing Design ! Cement Calculations 18-Sep-92 Well Number: Surface Csg MD: Surface Csg TVD: Production Csg A MD: Production Csg A TVD: Liner MD: Liner TVD: Top of West Sak, TM D: Top of Target, TMD: Top of Target, TVD: Estimated Mud Weight: Surface Casing Choice (1, 2, 3, or 4): Intermediate Casing Choice (1 or 2): Production Liner Choice (1 or 2): Max. Csg. Surface Press. During Frac 2M-29 3,7O4 ft 2,751 ft 10,423 ft 6,033 ft 13,005 ft 6,162 ft 2,219 ft 11,014 ft 6,125 ft 10.0 ppg ~** See Page 5 I~ ' Casing 3,500 psi Maximum anticipated surface pressure TVD surface shoe = 2,751 ft {(13.5'0.052)-0.11}*TVDshoe =L 1,629 psiJ Estimated BH pressure at top of target zone Anticipated Mud Weight = Top of Target Zone, TVD = 100 psi Overbalance = =[ 10.1 ppg 6,125 ft 3,217 psi 3117 psiI Surface lead: Top West Sak, TMD = 2,219 fi Design lead bottom 500 ft above the Top of West Sak = 1,719 ft Annular area = 0.4206 cf/If Lead length * Annulus area = 723 cf Excess factor = 15% Cement volume required = 831 cf Yield for Permafrost Cmt = 2.17 Cement volume required =[ 380 sxJ Surface tail: TM D shoe (surface TD - 500' above West Sak) * (Annulus area) Length of cmt inside csg Internal csg volume Cmt required in casing Total cmt Excess factor R~(~lV~D Cement volume required = Yield for Class G cmt S E P ~ 1 I~99~ Cement volume required Alaska Oil & Gas Cons. Go~'tss~o~ Anchorage 3,704 ft 835 cf 80 ft 0.8406 cf/If 67 cf 902 cf 15% 1,037 cf 1.15 900 sxJ Casing Design ! Cement Calculations 18-Sep-92 Intermediate tail: TM D = 10,423 ft Want TOC 500' above shoe = 9,923 ft Annulus area (12.25" Hole) = 0.3132 (TD-TOC)*Annulus area = 157 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.411 Cmt required in casing = 33 cf Total cmt = 189 cf Excess factor = 15% Cement volume required = 218 cf Yield for Class G cmt = 1.23 Cement volume required =1 180 sxI Production liner lead' Annulus volume = 388 cf 50% Annulus volume = 194 cf Yield for Class G w/spherelite 4.33 Cement volume required =1 45 sx Production liner tail: TMD = 2,582 ft Liner lap = 300 ft Annulus area (8.5" Hole) = 0.1268 Annulus area (cased hole) = 0.1438 Lengths*Annulus areas = 371 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.2148 Cmt required in casing = 17 cf Total cmt = 388 cf Excess factor = 15% Cement volume required = 446 cf Yield for Class G cmt = 1.23 Cement volume required =1 360 sxI TENSION - Minimum Desi_~n Factors are: T(_ob)=l.5 and T(_is)=l.8 Surface Casing (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyancy Dead Wt in Air = Length * (WEft) Buoyancy = Weight of fluid displaced Mud Weight = 9.6 ppg Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =! 1069000 lb 3,704 ft 68.0O Ib/ft 251872.0 lb 35916.5 lb 215955.5 lb 5.0J Surface Casing (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyancy Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of fluid displaced Mud weight = 9.6 ppg R E~: E IV E b s E P 2 1 1992 AIaska Oil & Gas Cons. C0mmissi~ Anchorage Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ 1140000 lb 3,704 ft 68.00 Ib/ft 251872.0 lb 35916.5 lb 215955.5 lb Casing Design ! Cement Calculations Intermediate Casing (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyancy Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of fluid displaced Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =! Intermediate Casing (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyancy Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of fluid displaced Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ Production Liner (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyancy Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of fluid displaced Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =! Production Liner (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyancy Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of fluid displaced Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 BURST-Minimum Design Factor = ~I_F (~ E IV E D Surface Casing: Burst = Maximum surface pressure S E P 1 1992 Casing Rated For: Max Shut-in Pres = Alaska 0il & Gas Cons. CommiSsion Intermediate Casing Anchorage 1. Design Case - Tubing leak while well is $1 Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Design Factor Casing Rated For: Inside pressure Outside Pressure Net Pressure Design Factor Production Liner: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure Outside Pressure Net Pressure Design Factor 18-Sep-92 1086000 lb 10,423 ft 47.00 Ib/ft 489881.0 lb 73483.1 lb 416397.9 lb 2.6J 1161000 lb 10,423 ft 47.00 Ib/ft 489881.0 lb 73483.1 lb 416397.9 lb 2.81 415000 lb 2,882 ft 26.00 Ib/ft 74932.0 lb 11301.3 lb 63630.7 lb 6.5J 490000 lb 2,882 ft 26.00 Ib/ft 74932.0 lb 11301.3 lb 63630.7 lb 7.71 3450 psi 1628.6 psi 2.11 6870 psi 6637 psi 2792 psi 3845 psi 1.81 4980 psi 6704 psi 2852 psi 3852 psi 1.31 Casing Design / Cement Calculations 18-Sep-92 COLLAPSE - Minimum Design Factor = 1.0 Surface Casing 1. Worst Case - Lost circulation and casing pressure = 0 2. External pressure =Mud Wt * 0.052 * TVD Intermediate Casing 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Production Liner 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =[ Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 1950 psi 0.520 Ib/ft 1431 psi 1.4J 4750 psi 0.520 Ib/ft 3137 psi 1.5J 4320 psi 0.52O Ib/ft 3204 psi 1.3] RE'EEIVED S E P 2 1 1992 Alaska 0il & Gas Cons. Commission Anchorage Casing Design ! Cement Calculations 18-Sep-92 Surface Casing Choices OD ID I b/ft Grade Metal X-Section Jt Strength Body Strength Collapse Burst I 9.625 8.681 47 L-80 13.5724 sq. in. 1161000 lb 1086000 lb 4750 psi 6870 psi 2 9.625 8.835 40 L-80 11.4538 sq. in. 979000 lb 916000 lb 3090 psi 5750 psi 3 9.625 8.921 36 J-55 10.2545 sq. in. 639000 lb 564000 lb 2020 psi 3520 psi 4 13.375 12.415 68 J-55 19.4452 sq. in. 1140000 lb 1069000 lb 1950 psi 3450 psi Production Casing Choices OD ID I blft Grade Metal X-Section Jt Strength Body Strength Collapse Burst 1 9.625 8.681 47 L-80 13.5724 sq. in. 1161000 lb 1086000 lb 4750 psi 6870 psi 2 7.000 6.276 26 J-55 7.5491 sq. in. 490000 lb 415000 lb 4320 psi 4980 psi i E' 'EIVED Alaska 0il & Gas Cons. Oommission Anchorage CREATED BY : JONES For: B. MATHEWS :.DATE PLOTTED : 4-SEP-g2 ",PLOT REFERENCE IS 2g VERSION #5. [COORDINATES ARE IN FEET REFERENCE SLOT #2g. !TRUE VERTICAL DEPTHS ARE REFERENCE WELLHEAD. b..E. _q.9 500 - o .. 500 100~ 1500- - 2000_ - ~ 2500_ · --_ '-t--- ~" 3000_ - 3500- · ~ _ ~ 4000_ 4500_ - 5000- - 5500_ - 5000_ 6500- ARCO ALASKA, Inc. Structure : Pad 2M Well : 29 Field : Kuparuk River Unit Location : North Slope, Alaska S 56.44 DEG W 8428' (TO TARGET) ***PLANE OF PROPOSAL*** ~000 8400 I I 7800 I <-- West 7200 6600 6000 5400 4.~00 4200 3600 3000 24,00 1800 ! 200 I I I I I { I I I I I I I I I I t I I I I I SURFACE LOCATION: 114' FSL, 51' FEL SEC. 28, T11N, RBE TOP KUPARUK LOCATION: I 01 O' FSL, I 527' FEL SEC. 32, T11N, RSE TARGET LOCATION: 735' FSL, 1794.' FEL SEC. 32, T11N, RBE RKB ELEVATION: 14-6' TD LOCATION: KOP TVD=500 TMD:500 DEP:O 754-' FNL, 2165' FWL SEC. 5, TI ON, RBE 6.00 1 2.00 BUILD 3 DEG / 100' 18.00 24..00 B/ PERMAFROST TVD--1396 TMD=14-33 DEP=223 30.00 T/ UGNU SNDS TVD=14-26 TMD=14-67 DEP=239 36.00 4-2.00 4'8.00 T/W SAK SNDS TVD=lg96 TMD=221g DEP=723 ~4.00 60.00EOC TVD=2159 TMD=2509 DEP=963 SCALE 1 : 300.00 600 0 600 I I I I 600 m 0 -- .. 600 o · .! 200 .1800 - 0 .~400 3000 3600I I ' ~200V B/ W SAK SNDS TVD=2551 TMD=3301 DEP=1650 13 3/8"CSG PT TVD=2751 TMD=3704 DEP=2000 K-lO TVD=2806 TMD=3015 DEP=2096 K-5 TVD=4-286 TMD=6800 DEP=4689 AVERAGE ANGLE 60.28 DEG KOP #2 TVD=584-0 TMD=9934 DEP=74-10 g 5/8"CSG PT TVD=6033 TMD=104-23 DEP=7857 T/ KUP SNDS (C) TVD=6083 TMD=10628 DEP=0053 T/ ZONE A TVD=6093 TMD=10682 DEP=8105 A3 INTERVAL TVD=6116 TMB=10854 DEP=8272 TARGET - Mid A3 - FINAL EOC TVD=6125 TMD=II014 DEP=8428 TI)/ LOGGING PT TVD=6162 TMD=I3005 DEP=I0352 i i i i i i i i i t i I i i I i i i I i i i i i i i i I I i 500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 &SOO 7000 SCALE 1 : 250.00 Verfic(31 Soction on 236.44 azimuth wHh roforence 0.00 N, 0.00 E from slot #29 i 7500 I 1 8000 ~4o0 - _6000 R'ECEIVED Alaska Oil & Gas Cons. Commission Anchorage TARGET ANGLE 88.94 DEG 3 OEO / 10~' DOGLI:O 8500 9000 9500 10000 10500 2~0 I I ARCO ALASKA, I13. O. Structure : Pod 2M Well : 29 PLOT INCLUDES· 1F/4U/7/SV/12 Field : Kuparuk River Unit Location : North Slope, Alaska 200 160 120 WoestSCALE 1 : 4-0.00 40 4-0 80 1 20 160 · 80 1700 l'~Oo ~00 ~oo 1 500 3o lO0 11oo 1500 700 1300 4-0 m ·,, · o 0 o ~o 0 80 60 _200 L2¢0 KUPARUK RIVER UNI~' 20" DIVERTER SCHEMATIC 6 I I 3 DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 20" CONDUCTOR 2. SLIP~)N WELD STARTING HEAD 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND o,v .s,o. ECEIVED 6. 20" - 2000 PSI ANNULAR PREVENTER SEP 2 1 1992 Alaska Oil & Gas Cons. (;ommission Anchorage EDF 3~10~2 7 , 6 5 4 3 13 5/8" 5000 ;-'SI BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2- ASSURE THAT ACCUMULATOR PRESSURE IS 3(XX) PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. ~ OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 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. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE ENES. 7. TEST TO 250 PSI AND 3(X)O PSI AS IN STEP 4. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A250 PSI LOW AND 3(X)O PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTrOM 9. RAMS TO 250 PSI AND 3000 PSI. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. 10 CLOSE BLIND RAMS AND TESTTO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD 11. AND 12_ ENES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE 13. DRILLING POSITION. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3(x:x) PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 20' - 2000 PSI STARTING HEAD 13~3/8' SOW CASING HEAD 3. 13-5/8' 5(x:x) PSI X 13-5/8' - 5(xx) PSI DRILLING SPOOL 4. 13-5/8' -5000 PSI PIPE RAMS 5. 13-5/8' - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8' - 50(X) PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 1,~5/8' - 5000 PSI ANNULAR RECEIVED S E P 2 1 1992 ^iaska Oil & 6as Cons. comrnissior ;Anchorage SRE 8Z22/89 Al .~ska 2M...?..,,9. I~up ~ruk Fti~er 9/'2.'219~ M. Minder Casing Int. Imf Dmso Dmso t'.]~z.~s o 'T'~:..~n sion ,.,k...6. Bottom 'T'op Length Lbs Grade 'T'hre. ad I....bs lA 13,876 2761 4.1 3663 68 [..=80 D"'r'c; () 2A 9.6~6 6033 4,1 10382 4:7 I,..,,.80 BTC 0 3A '7 6162 & 1 ~88 ~ 26 J... 56 B" f' C 0 4A 0 0 0 0 0 0 0 0 6A 0 0 0 0 0 0 (] 0 6A 0 0 0 0 0 0 O 0 7A 0 0 0 0 0 0 0 0 8A 0 0 0 0 0 0 0 9A 0 0 0 0 0 0 0 0 10A 0 0 0 0 0 0 0 1B 213 3B 4,B 5B 6B 10E.~ Mud Wie.ght PPg 10,0 9.6 10,6 0.0 0,0 0.0 0,0 0.0 0,0 0.0 Hyd Grr..~dient psi/ft 0.52O 0.4,99 0,65'1 0.OOO 0.000 0.000 0,000 0.000 0.000 0.000 Max psi Yield e~- 687o 4.,98o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1C 2.,.(:; 3C 5C 6C 8C 9C 'f Tension K/L.bs 24.9.084. 4-8,'7.954. '74.93~ 0 0 0 0 0 0 Strength '? 554. 'f 086 415 0 0 0 0 0. 0 0 I::>r'es s ur'e Collapse Bot...P$1 I:::tesist. '14.31 2',2,..6(:) 30'f 2... 4.750 $396 4,320 0 0 0 0 0 0 0 0 0 0 0 0 0 0 P ~.ge I ('7'. I. ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE F2 thru 8] (3) Admin [~,$]~_ ~//~//~_ 9. [9 thru lr3] ' 10. ~ ~,~l~- ~'~--. 11. [ t0 g 13] 12. (4) Casg ~,,-~/'/. ~)' [14 thru 22] 13. 14. 15.' 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. (5) BOPE ~-~.~.~, 9- ~-- -? ~---. [23 thru 28] Company YES 1. Is permit fee attached ............................................... 4 ...... 2. Is well to be located in a defined pool... 3. Is well located proper distance from property iine ........... : ....... ... 4. Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6 Is well to be deviated & is wellbore plat included ................... 7 Is operator the only affected party .................................. 8 Can permit be approved before 15-day wait .. Lease & Well ,~. ~z~2~ NO Does operator have a bond in force ................................... Is a com~ervation order needed ....................................... Is administrative approval needed .................................... Is lease nLmber appropriate .......................................... Does well have a unique name & nLrnber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~4). psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... REMARKS (6) Other ~'/~__ .?/~.///~ ['29 thru 31] (7) Contact (8) Addl 29. 30. 31. 32. 33. geology' engineering' DWJ~.~ MTM ~ RAD~ RPC ..,~ BEW rev 08/18/92 jo/6.011 FOR EXPLORATORY g STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone ncrnber of contact to supply weekly progress data ...... Additional requirements eeeeleeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Additional INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE remarks' 0 ,.-I 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 simp!ify 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. STAT~ UK R/VEE~U~IT: NORTH SLOPE BOROUGH IS Tape verification Listing chlum~erger Alaska ComDutinO Center 24-MAY-1993 15:53 SERVICE NaME : EDIT ~T~ : 93/05/24 O~!cIN : FLIC CONTINUATIOZ # : PREVIOUS RE~L ~ C9~"ENT : ARCO ALASKA, INC,,KUP~RUK RIVER UNIT,2M-~9,50-103-20183-O0 D~T~ : 93105/24 ORIGIN : FL!C COgTI~UATIO~ # ~ ~ P~Ev!ou~ TAPE : C~ENT : ARCO ALASKA, TNC',KUPA~UK ~IVER UN!T,2H-29,50-103-20~83.00 KUP&RUK RIVER UNIT A~i NUMBER: ODEDATOR: T'apw CDE~TION DAT~: ~ . 008 DATA JOB NUgBER: OP~RATDR MTTN~S$: SURFAC~ LOCATION TOWgS~IP: ~WL: ~L.,V~TION(~ ~ROM ~SL O) K~LLY BUSHINg: GROUND 5EVIL: BIT ~ RUN 1 g2~22 ISON CASING R .F..cORD I, ST STRING ND STR!N~ ARCO NC. SC~[:['M~ERGER ElL SEnVIcE$ 24'-~Ay g3 ' ST MO · .SON BIT RUN 3 :ST. AMOUR MOR~ISON lIN 8E 114 14~,00 !!4 ,00 05.00 ODEN HOI~E C~$ING DRI. sLER$ ~IT SIZE fIN)'SIZE fiN) DEPTH~.(FT) 8,:500 9,625 ~663,0 chlumber..qer AlasKa Computing Center 3~D STRING PRODUCTION STRTNG REgAPKS~ FIEI~D ENGINEER'S REMARKS: UH 1I DUli, L 3663' TO 6757'° ~ TO ~T: 110'3', ~E$. TO BTT: 99,9' ~lg 2 DRILL ~757'. ~O 104~' . ~ASHDOWH 6727' TO 6757;, GR TO BIT= 85 4' RES TO BIT: 75,0' 6 i . . G~ T£) ~IT: 43.7', RES. TO ~IT! 33,3'. SIDeTrACK STARTS AT ~0750', ~UN"'5: DRILL 10809' TO 10905'. G~ TO BIT: 44.7', ~ES. TO BIT: RU~"6~ D~ILL 10905' TO ~2500'. G~ Tfl B~T: 44.0', RES. TO B~T: ]3,6'. RU~ 7. ~;~IL5 ~2500 TO 13015 , ' ' : WA~HDOWN G~ 12276' T0_12468', GR TO BIT': 44.4'. RES,.TO BIT: DAT~ SAMPLED EVERY ~6 ~CONDS, SOFTWARE: $ V2.3D /4.0C F[L~ NANE : EDIT .O0l VERSION ~ OO!A07 DAT~ : 93/05/24 ~× RFC $~ZE : 1024 FILE TYPE : I.,O PAGE~ FILF HEADER neath shifted and cl~pped curves; all bit runs merged, DEPTH IgCR~ENT 0°5000 ~RU TOOL ~OD£ ST~R? D~PTH STOP ~PTH CD~ 3663,0 120!~0,0 SB~S~LINE CURVE FOR SHIFTS~ CURVE SHIFT DaT~ (MSASURED DEPTH) BAS~LI~E DEPTH ...... ----E~.UtVALEMT [!NSHIFTED DEPTH----,------ ~4WD IS Ta~e Yer~c~tlon Listlnq chlumberqer AlasKa Comp~ltInO Center 24-~iAY-~ og3 15:53 PAGE: 1104~,5 1!941,5 I~g24 5 1,o~2,0 !1746,5 11747.0 11549 0 11549.0 !1454.5 11463,0 11444.0 i1457.5 ~09U~,5 !0978.0 __ 897.5 10~89,5 1084~:0 10944,0 ..063 5 I0634,5 ,o5~9.o io566.s ,053o.0 ~0400 5 0400. {0357i5 !0359.~ 100 0 101,5 .RGED DATA SOURCE ~RU,TOOL CODE BIT,mUM MO, ~ERGE TOP ~wn ! 3663,0 MWD 2 6757,0 ~WO 3 10421,0 ~WD 4 !0750,0 uWO 5 10809,0 ~WO 6 10905.0 uwD 7 12500,0 $ 6757.0 I042~.0 11~41.0 10809.0 10905.0 !2500.,0 13015,0 ?HE DEPTH.ADJUSTMENTS SHOWN ABUVE REFLECT MWD GR: TO WIRELINE CBT GR OF 08,JA~-93, ALL OT,ER CURVES wERE CARRIED WITH THE:~R SHIFT-~THE CBT/HLDT W~$ LOGGE~ . WITH TOOLS ON'END"OF COl'LED TUBING ~ND WAS TIE'D: ~NTO LWD CD~ LOG, L{S FOR.~.T DATA T~BLE TYPE : CONS TUMI VALU DEFI TYPE.i . . CN ~RCO Ab~A. ! Comoanv Name WN 2~:29 Welts-Name ApI~ 50 103-20183 AP! Serial Number FL ~14' FSL & 51' FEL Field Location ' SFCT 28 sect~ n ¥0~' lin Town ~Ip IS Ta~e Vert. f~.¢atXon Listing chlumberger AlasKa Computlnq Center 24-MAY-1993 ~5:53 PAGE.I 4 COU~ N~T! WXT~ SON pD~T DFPN ~V ~T R~CA ~CST B~ ~ORTH SLOPE AL.~SK~ Ii4' F~b & 5~' F~L FT MORRISON 618976 0 146, 146, ~46o 105. 13015, 130.15, ~.30~5' 3663, ~0'6 County State or Prov~nce Nation Latitude Longitude Witness Name Service Order Number Permanent datum ~levation of Permanen Log ~easured From ~bove Permanent Datum Elevation of Kellv Bu ~T FT Elevation Of Derrick ~T Elevation of Ground L FT Total DePth - Driller WT Total Depth - Log~r FT Bottom Log Interva~ FT Top LOg Interval ~ DrilliLg Fluid Type G/C3 ~rtlllng Fluid ~nstt $ Dril~in~ FlUid Ph ZONE Drll lng Fluid Viscos ZONE ~3 Drillin~ Fluid LOSS ZONE OHMM ! 81 ~eslst~itV of Mud Sa ~KGF 6~ Mud. Sample Temperatur OHM~ !,~8 Resistivity of'~ud Fi DE~w 65. ~'udiFiltrate Sample T OHM~ Resistivity of Mud Ca ZONE DEaF ~Ud Ca~e Sa~ple Tempe ZONE DEGF -999,25 Surface Temperature DEaF 140, Bottom Hole Temoeratu TYPE : ZONE TABLE TYPE : CURV D~PT Oeoth ATR ~G$ BHC AT.:EN[.]ATION' T" R_~SIS~IVITY~ ' P~ ~GS ~HC PH~SF SHIFT~..ESISTIVITY IS Tame verification Listing chltlmberger AlasKa Computing Center .. 24-MAY-~,g93 15:53 Gamma Ray ** ~AT~ FORVAT SPECIFICATION RECORD ** ** SET TYPE o 64EB ** TYPE R~PR CODE VALUE I 66 0 2 66 0 3 73 24 4 66 5 66 7 65 11 S6 4-2 1) 66 14 65 FT 15 66 68 16 6~ 0 66 0 ** SET TYPE - CMAN ** ID ORDER # bOG TYPE CHASM ~OD NU~B SA~P MbEM CODE (HEX) DMP? Em 6~8976 O0 000 O0 0 1 ! ~ 4 68 0000000000 RA MWD OHMM 618976 O0 000 O0 0 ~ ! 1 4 68 0000000000 R~ ~WD 0~ 618976 O0 000 O0 0 ! 1 i 4 68 0000000000 ~Op ~WD F/HR 618976 O0 000 O0 0 ~ 1 1 4 68 0000000000 R$I ~WD 61~976 O0 000 O0 0 ~ 1 ~, 4 68 0000000000 G~ ~W~ GAPI 6~8976 O0 000 O0 0 1 I. 1 4 68 0000000000 ** D~.TA ** DEPT. 1 O14'000 RA,!,~WD '999.2 0 RP.~WD ~SX.MWD 999,250 GR.~wD -q99.~ "0 -999.~50 ROP.MWD 'i-999.250 IS ?ape Yeriflcation [. st nc~ cblumberger AlasKa Com ut ng DEPT. 1]000.000 ~$Y.MWD 999.250 DEP?. 12800.000 ~$I.~WD 0.000 D~PT. 12600.000 ~SI.~WO 0.000 wp? 12400.000 D~sI:.~¢ 0.00o D~P?. ~200.000 ~$I.~WD 0.000 D~PT, 12000.000 R$~.~WD 0.000 DEPT. 11800.000 ~T.MWD 0.000 DEPT. {!600.000 ~S~.~WO 0.000 D~?. 11400,000 ~SI.~wD 0'000 D~P? 11200'000 ~s~:~ ..... o.ooo ~. ~iooo.Ooo ~$Y.~D 0.000 ~T. 10800.000 ~,'~.~WD !,000 U~T ~o600 00O ~s~: "t.ooo D~uT. ~0200,000 ~S~,.wu ~.ooo D~. 9800.000 DEPT, 9600.000 Center RA.MWD GR.~WD ~A.~WD ~R.~WD ~A,~WD RA.MWD ~R.MW~ GR,~WD ~,~WD .~WD RA,~WD ~R,~WD GR.{WD GR. - , · Rg.'MWD ~R.~WD ~ ~WD R~.~WD ~R,:MWD RA.NWD 24-~AY-~993 -999.250 -999.250 38.~30 55. 95 44.~40 64.325 41.742 55.032 40.I36 31.109 43.411 16.387 16.038 60.]24 ! 0 966 59'124 3o.669 45 · 3.34 53.$5~ 47.924 -999.250 2:4,227 ~. 868 l I0-555 239. , 15:53 RP~-MWD RP.HWD ~P.~WD RP.MWD RP.~WD RP,MWD RP., MWD RP.MWD RP.MWD: ~P. MWD ~P.m~WD ~P.MWD RP,~WD R P. M: W D -999.250 66.565 42.286 64.099 43.052 5~.004 47.102 lP.sg2 1 e' :3 s 6 13.392 44' 445 77.81 ] -999.250 ~,s~o 5.403 4'662 ROP .MWD RDP.MND DOP.~WD ROp. MWD ROP.MWD ROP..WD ROP.MWD ROP.MWD ROP.MWD ROP.MWD ROP'MWD ROP.MWD ROP.MWD ROP.MWD ROP.MWD ROp. M~D ROP. MWD PAGE: 52.175 40.805 3B,4~7 72.289 67.166 45.110 61.609 38.~80 76.924 87.808 60'377 8'896 :28,03B 139'557 200'486 102'272 2 ] I, 636 129.495 IS TaPe Verification Listing chlt~mberger Alaska Comput~no Center D~PT q400.000 ~. ~SZ'..~WD 1.000 GR.~WD D~PT 9200. 000 ~A. ~WP ~SI~"~ !.000 ~.~W~ ~pT g000.000 D~t:MWD 0.000 GR.~WD o~PT. .~oo.oo0 ~_.~wD ~S~ .NWD O, 000 GR. ~WD D~PT. ~600. 000 R~. ~WD ~. ~WD 0.000 ~R, ~WD D~T. 8400. 000 R~. MWD ~I. NWD 0.000 G~'MWD D~PT ,200.000 0~0~ 8000.000 R~. ~s~:,4w~ o.oo0 o~ 7~oo. ooo ~]PT 7600, OOO D~P~ 7400,000 D~PT. 7200,000 ~I' ~'WO 0,000 ~R,MWD ooo D~PT. 6400'000 RSI,~WD 0'000 '~R'MWD D~PT. 0.0o0 .RSI,~D 6200-000 24-MAY-1993 4 66 4,342 3 47n ~o~24~ 12 598 ].568 126.6~9 3 3 3 3.!14 10~.059 3 757 3 567 4 3.083 !1~-424 .06~ 1:5, 39 3.3~3 88,6 5 3'964 15:53 RP.MWD PP,~WD RP.~WD RP,MWD RP.MwD RP,MWD RP.MWD RP.MWD RP.~WD RP,MWD RP.~WD RP.MWD RP.MWD RP.MwD 4.877 3.980 3.154 4.202 3.614 3.842 2.966 3.152 3.648 3.620 4.689 4',154 2'600 1'821 3~i909 4~043 ROP.MwD ROP.MWD ROP.MwD ROP.MWD ROP.MWD ~Op. MWD ROp,MWD ROp,MWD ROP'MWD ROp,MWD ROP'.MW9 PAGEI 174.856 153.027 156,518 213.485 197.768 60,201 306.904 ~53,461 268.460 324.007 .260,727 260.3~6 131,53B 163,289 3I?.961 IS Tape Verification Listinq chXumberqer AlasKa ComDutinq Cemter D~PT. 6000.000 RA.MWD RS!.MWD 0.000 GR.~WD D~PT. 5800.000 R&.MWD R$I.~WD 0,000 ~R.~WD DEPT. 5600.000 RSI.~WD 0.000 D~PT. 5400.000 RA,MWD ~T,~W~ 0,000 ~R.~WD DEPT. 5200.000 RA.~WD RST.~D 0,000 G~.MWD DEP?. 5000,000 ~A.MWD ~SI.MWD 1,000 ~R.MWD ~S?.)~WD 0.000 ~R.~WD D~PT. 4600 000 RS!,~'WD 0:000 GR.~WD D~PT. 4400,000 ~A.MWD D~, 4200,000 RaoMWD ~SI.MWD 0,000 DEPT. 4008 000 RSI.MWD :000 ~R,MWD D~P~, 3800,000 ~ MWD . S!.MWD 1,000 GR:~WD . DEPT. 3663,000 ~A,MWD ~ERVICE D~TF LAST FILE TRAILER **** C EDIT .00~ : FLIC : O0~.A07 : ~$/05/24 : 1024 : hO 24-gAY-1993 15:53 3,462 ~P.~W;j 3 463 106.248 ' 3.757 RP.~WD 3.480 105.910 3.32~ RP.MWD 3.077 90.537 3.)14 RP.~WD 3 131 106,875 " ' 3,729 RP.MWD 3.538 90,993 3,770 RP,MWD 3 467 83,535 ' 3 WD 3 · 5,044 ~P,MWD 0 215 71,906 ' -' 4.62 B6,477 ' '.wo -gg so ROP.MWD ROP*MWD ROP.MWO ROP.~WD ROp. MWD ROP,MWD ROP.~WD ROP.MWD Rop,.w ROp. MWD RO~MWD RO~M~D PA~E: 290.178 295.529 · 126,736 140.332 i60.305 423,863 254.320 538.594 222.016 354,234 334,3'75 264.576 -999,250 lade Yert~lcation Listing chlUmberger ~!a$~a ComputinQ Center 24-MAY-1993 15:53 PAGE: FILE NAME : EDIT .002 V~RSION : O01A07 DATE { 03/05/24 ~AX RFC SIZE : 10~4 FYLE TYP~ ! LO LAST FI[,~ ~ FILF HE~DER FIL~ NU~B~ 2 RAW MWD Curves and log h~ader data for each hit run l.n separate files, ~T RUN NUMBE~: D~PTg INC~E~E~T: 0.5000 # FILE SUMMARY VENDOR TOOL CODE START.DEPTH CD~ 366].0 ~OG,HEADER DATA DATE LOGGED: SOFTWARE: DOWNHOL~ SOFTWAR~ DAT,~ TYP~ (MEMORY OR TOO[, ST~ING (TOP !O BOTTOM) $ D~ILL~RS CASING D~PTH(FTi): RO~ENOLE CONDITIONS M!)D TYPE: ~UD D~NSITY MUD VISCOSITY ~UD ~UD CHLORIDES (PP~): STOp DEPT~ 6757,0 4.0C 67570 6757,0 3663,0 1:0,60 IS Tape Verification Listing ch!umber~er AlasKa ComputlmG Center 24-MAy-1993 t5:53 PAGE: FLUID DOSS RESISTIVITY (OHM~ AT TE~DERATUR~ DEGF) MUD AT ~ASURED ~UD AT ~A× C~CULATING TEMPERATURE: ~UD FILTRATE AT ~T~ ~U5 CA~ AT ~E[!?RON TOOL ~ATRIX~ ~AT~IX DENSITY: HOL~ CORRECTION (IN): TOOL STANDOFF WR~OU~NCY ~EMARK$~ FIELD ENGINEER'S REMARKS: RUN ~: DRILL 3663' TO 6757', $ 1,~10 65.0 ~,4~0 65.0 8,500 TUN! YALU DEF! TYPE CN A~CO ALASKA. INC Comoanv Name F~ KUPARUK RIVER UNiT Field Name W~ FL $~C? TOWN ST~T LONG WITN PDAT TDD TQL TLI FT MT ~T FT FT FT 2,-29 5o-I03-20183 1!4' ~SL & 51' FEL 2~ lin NORTH SLOPE BOROUGH t~4' FSL & 5~' FED 618976 !46. I46. 146. 105, 13015, 13015, 13015. 3663. well Name &PI Serial Numbe~ Field Location Sectiom Township Range county State.or Province Nation Latitude Longitude Witness Name Service Order Number ~ermanent 8arum Etevattom o~ Permanen Lo~ ~easu~ed From Above ~ermanent Datum E!evat on of Kel!¥ Bu Elevation of Derric~ Elevation of Ground L Total Depth - Drill. er Total DePth -..bogoer Bottom Log Interval TOD LOg Interval IS TaPe Verification L~$t~ng chlu~berger AlasKa Computi~O Center PAGE: 11 TUfT VALU DE DFD G/C3 10.6 Dri O~p~ Dri DFV S Dri D~L F3 R{S OH~M I 8! Res ~ST DE~F 6~. BUd ~FST DEGF 65.' P¥CS OH~M Res ~CST OE~F ~Ud STEM g~GF '999.25 Sur BHT 9EGF 140, 80t FI TYPE mm~mmmmmmmmmm.~m~mmmmmmm.mm~m~m.m~mmmm~m~mm fling Fluid Type_ lll~o Fluid D4n$1t lllno Fluid Ph ZONE fling Fluid V{$Cos lli.g Fluid bOSS ZONE iStivltF of Mud Sa .Sample Temperatur lsttvtt¥ of Mud Fi ,.Filtrate SamPle T istlvtty of gud Ca ZONE ~Cake Sample Tempe ZONE face Temperature tom Hole Temperato T~BLE TYP~ : ZONE TUN! BDEP TDEP DFPH DFV DF[, : R~CS ~CST 1 FT O. 0.' O, o. o. ,,, o2., o.., . TABLE TYPE : CURV DEpT ATR PSR Oe~th R~TE OF DRILLING PENETRATIO~ ~a~a ~ole Deviation True Vertlca! DePth as channel <TVTCPI> FORMAT SPEC!FYC~TION RECORD ** SET TYPg -~64gB **· TYPE ..... REPR~:.CODK VALUE I ~6 o 2 66 0 ~ 7,3 32 4 66 1 ,IS Ta~e Verification tistina chlUmberaer .~lasKa Computlnq Center 24-MAY-1993 15:53 PAGEI 12 ~ . 6 73 7 65 9 65 I1 66 14 65 !5 66 16 66 0 66 ;mmmmmmm~mmmmmmmmmmmm~mmmsm E R~PR COD~ VhbUE 0,5 FT 32 1 N~Y ~R~V UM!T 8E~VIC~ ~PI ID ORDER # bOG DEPT FT A18976 O0 000 ~TR LW1 OM~M 618976 O0 000 P$~ LW! OMMM 618976 OO 000 ROP~ LW! F/HR 618976 O0 OOO G~ LWl GAPI 61~976 O0 000 $~R LWI DB 618976 O0 000 DE¥I 5WI DEG 618976 O0 000 VDEP 5Wl ~T 61~976 00~ 000 mmmmmm~mmmmmmmmNmmmmm~.m~mm~#mmmmmmm.~m~m#mm#mmm~m#mm ~PI ~PI APT FTI,E NUMB NUM~ SI~E R~PR PROCESS TYPE CheSS MOD NUMB S~P E[,~ CODE (HEX) ~m~.mmmmmmmmemmmm~m~m~m~~mMmmm.~Mmmmmmmmmmmmmm~mm O0 0 ~ ~ I 4 68 0000000000 O0 0 2 i 1 4 6~ 0000000000 O0 0 2 ! i 4 6~ 0000000000 O0 0 ~ ! 1 4 68 0000000000 O0 0 2 1 I 4 68 go00000000 O0 0 2 1 !, 4 6~ 0000000000 O0 0 ~ 1 1 4 68 0000000000 O0 0 2 I 1 4 68 0000000000 ¢~. .... i56.5~7 SNR'bWi O~ 6600,000 AT~.bW! DM~T. 6.400 000 GR'LWI 96~3~9 ~NR.LWl s oo. Ooo GR,LWt 98.803 SNR.LW1 4-3~4 551.4 0 3971 5:100 O0 '°oo · 3.740 530.500 PSR.bWi . 5'51i DEV'I.bWl 99g.250 PSR.Lw! . ).841 :ROpE.LW~ DEVI.LWI 999,250 V~EP.LW! PSR bWl . 3'430 ROPE.LW1 DEV'I~Wt 999'~50 VDEP.LW1 DEVI.bWI 'g9 ~50 VOKP.I.,W1 PsR, w't 3' 51 DEVI,bWl -999.250 vDEP:LWi. PSR,bW~ 3.511 ROPE.LW1 D~VI.LW! -999.750 VDEP.LWl 435-332 :-999,250 ~49.682 -999,250 179 q7 :"909:~0 -999 50 ~94.,552 :-999,250 309,043 -999,250 IS Tane Veri~lcatton ListJng chlumherqer AlasKa Comp,{tlng Center D~PT, 5600,000 ATR,LW{. G~.LWI B7,819 SNR.LWl DE~. 5400.000 ATR.LW! ,Lw! 97,109 SNU.LW! D~P'. 5200,000 AT~,L~I D~PT. 4800,000 ATR.LWl GP,L~ ! ! 0 !. 8 i 0 SNR. Lw i D~PT. 4600.000 AT~.LWl G~.LWI 72,095 SNR.LWl DEPT, 4400,000 ATR,LW1 GP.L~I 77,952 SNR,LW1 4200,000 ATR,LW1 D~PT'L~1 99,403 SNR LW1 D~PT, 4000,000 ATR,LWl G~,LW1 ~1.457 SNR,LW1 D~PT' )800,000 ATR.LWl G~,LW1 89,769 SNR.LW! G~,~WI 41,575 SNR.LW~ SERVICE ) FbXC D.{TE { 9)/05/24 ~X R~C SIZE ~ 10~4 FILE TYP~ : LO LAST FibE ~ 24-MA¥-199] 15153 3.328 PSR.LWl 505.P00 D~VI.LW1 3,~40 pSR.LW1 4~.000 D~V!.Lwl 3,656 PSR,LW1 482.000 D~VI,LW! 3.7~9 PSR,Lw1 -8.~00 DEVI.LWI 3.344 PSR.LW1 -8.300 DEVI.LW1 4 99~ PSR,LWI 4381~oo n~Vi.bwi 4,625 PSR'LW! 466,200 DEVI,hW1 3,64~ PSR,bWl 447,30 D~V],LWl 6.oo9 psR.uw 52 o 3.079 -999.250 3.033 -999.250 ].516 -999.250 3.452 -999.250 3 172 '999~250 8 769 -999~50 4.213: =999.750 3,084 -999.250 7.782 '999'~50 5,300 -9992250 0.~ 6 1 250 ROPE.LWI VDEP.LWl ROPF.LW1 VDFP.LW! ROPE.LWI VDFP,LW! ROPE.LW1 VDEP.I. W1 ROPE..LW1 VDEP.LW1 ROP~,LW! VDEP.LW! VDFP,LW! ROP~'LW1 VDEP,LWl VDEP,LWt · ROP .... VDEP,LW! ROPE,LWI VDEP.LW! PAGE: 123.429 -999.250 135.275 -999.250 168.455 -999.250 448.7!~ -999.250 -999. 554.414 -99~,250 208,4~9 '999,~50 404.4~1 "999,250 328',2~5 '9~9,250 26~667 -99 ~250 -9991,250 -999,250 13 IS Ta~e Verification Listlnq chlumherqer AlasKa Computtnq Center 24-~AY-1993 15153 PAGEt 14 SERVICE : ~bIC VE~IO~ : 001~07 D~T~ : 9]/05/~4 ~a× REC $~Z~ : ~024 FIL~ TYPE ~ LO !.~S? FrLE : F~LE HEADER Curves and log header data for eaeh bit run ,in seoarate files. B~T RUN NUMBER: 2 DEPTH II~CREUENT~ 0.5000 # V£NDO~ TOOL CODE START DEPTH 6757.0 'LOG HEADER DAT~ DATE $OFTWAREt SURFACE $OFT.'_ARE VERSION~ DAT~ TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT)I TOP LOG INTERVAL (FT ~OTTO~ bOG INTERVAL FT BIT ~OTATING SPEED gOLg INCLINATION (DEG) ~INI~U~ ANGLE~ ~hXIMUM A~GLE~ ~OOb STRIMG (TOP TO BOTTOm) V£NDOR TOOL CODE TOOL T S ~O~EHObE AND C~$ING DATA OP~ ~OLE BIT S!Z~ fiN): D~ILL~RS CASING DEPTH (FT)'~ ~O~O~g' ~UD TYP~ · ~UO vISCOSITY ~UD .UD C~I, OR!DES (PPM)! STOP DEPTH m~m~mmmmmm ~04~o0 .OC 0421.0 t042i,0 , EGg830 8,500 ES Tape VerifYcat{.on I, ist{Do chlumberqer AlasKa Computl. nq Center .. 24-MA¥-1993 15153 PAGE{ 15 FLUID I, OS$ RESISTIVITY (OH~ AT TEMPERATURE DEGF) MUD AT MEASURED TEMPER~TURK ~UD AT MAX CIRCULATING TF~P~RATURF: MUD FI[,Ta~TE AT MT: ~U9 CAKE AT PT: ~EUTRO~ TOOL ~T~I×: ~ATR!X DENSITY: HnI,~ CORRECTIO~ (IN){ TOOL STANDOFF (IN): EWR FREOU~NCY (HZ): ~.EMARKSI FIELD ENGINEgR'S REMARKS: ~UN 2{'D~ISL 6757'' TO {042{' : WASHDOWN 6727' TO 67~7$, G~ TO BIT: 85.4', RES, TO ~IT: 75,0' D~TA F~OM DOWNHOL~ DA~A $~qPLED EVERY 2~ S~CONDS' SOFTWARE: $ ],8~0 65,0 ~,480 65.0 V2.3D /4.0C TABLE TYPE : CONS TUN! VALU PEri TYPE CN AIaCO Ab~KA'-RY{'~CR-" Comoany · Name FN KUPARUK .IvE UNiT w~ FL SECT TOWN R~Ng COU~ LON~ WlT~ S~N PDAT TOD TQL BSI rT FT ~T WT 2{-29 50-],0.3-20183 lt4' FS[, & 51' F~L NORTH SLOPE BOROUGH ALASKA 1~' FSI, & 51' FEb 6)8976 0. ~46, ~46. {46o ~0~5o Field Name WellName RPI Serial Number Field Location SeCtion Township Ranoe .Cou~tg State or Province Nation batitude Longitude Witness game :Service~order Number Permanent datum Elevation of Permanen LOg ~easured From Above Permanent Datum ~Elevation of Kellv BU Elevatfon of Derrick Elevation of Ground L Total DePth -Drll{er Total Depth - Logger Bottom Log Interval IS Tape Verification hlsting chlumherger AlasKa Computing Center PAGE: 16 TLI DFT D~D ~CST STE~ BRINE 10.6 S qHMM 1.81 DEGF 65. DEGF 6~." Mud-Filtrate Sample T OHMM ~e$titivity Of MUd Ca 0ES? Mud Cake Sample Temoe 0~GF Surface DEFI TYPE oD Lo~ ~nterval Dril!in~ Fluid Type. Orilli~ Fluid Densit rlllng~luid Ph ZONE rillln~ Wluid Vtseos ZONE Drillin~ Fluid boss ZONE ResistivitF o~ Mud Sa ~ud Sample Temperatur ZONE ZONE -999.25 Temperature 140. Bottom Hole Temperatu T~BL~ TYP~ = ZONE T~BLE TYPE = CU~V DEFI ~TR RGS BHC ~TTENU~T!ON ~ESIiT!¥ITY P~ ~GS ~HC PHASE 8H~FT RESISTIVITY ROPE RATE OF D~ILLI~ PEN~TRATIO~ G~ ~a~ma Pay V~EP True Vertical DePth as channel <TVTCPI> D~VI Mole Dev!ation ** DATA SET,TYPE - 64EB ** TYP~ RED~ CODE ~VALUE ! 66 0 2 66: 0 3 .73 32 IS TaPe Verification Listing chlumbe.rger A!as~a COmDUtl. ng Center 24-~AY-1993 15:53 PAGE: 5 66 7 65 11 66 t2 12 68 11 66 0 14 65 FT !5 66 68 16 66 0 66 1 ** SET TYPE - CH~N ** .. NiM~ SE~V [INIT SERVICE APl APl AP1 AP! FILE NUMB NUMB SIZE REPR PROCESS ID ORDER ~ bOG TYPE C~aSS NOD NUMB $~P ELE~ CODE (H~X) D~PT ~T 618976 O0 000 O0 0 ] I I 4 68 0000000000 R.T~ L~2 OH~M 618976 O0 000 O0 0 ] 1 I 4 68 0000000000 Ps~ ~ 0~ 618976 oo 000 oo 0 ~ 1 i 4 68 0000000000 ROP~ LW2 F/H~ 618976 O0 000 O0 0 3 1 I 4 68 0000000000 ~ LW~ GAPI 618976 O0 000 O0 0 ) I ! 4 68 0000000000 SM~ 5W2 OB 618976 O0 000 O0 0 ] 1 1 4 68 0000000000 VD~P bW2 FT 618976 O0 000 O0 0 3 ! 1 4 68 0000000000 D/V!E LW2 DEG 6 .8976i O0 000 O0 0 { I , I 4. 681. 0000000000 17 DEP?. o~PT, ~'Ooo I04~.695 ~o4~o'ooo 10200.000 1t8,I86 ooo'g:ooo 16 065 9800 :~00 241 93 9600,000 114.168 ~NR.f '2 760.]00 VD~ID, LW2 6028'371 DEVI.LW2 ATR.LW2 -999' 250 P~R'LW2 '9991' ~50 ROPE'LW2 SNR...:~W2 -10~500 VDEP LW2 6021'864 DEVI , ATR,L~ 2 2-7 4 P~R,Lw2 3"983 SNR.LW~ .16,4 0 VDEP, 5W2 -999,~50 DEVI,LW2 . . AT~,r, W2 3 757 PSR'LW .... 5,086 SN~,LW~ -lO~.~O0 VDEP,LW -999-:~50 D~VI,LW~ s,~w~ 69o.~oo VD~P.~w~ ,9~'" .250 DEVI.LW2 SN~-.5~W2 66t.400 .vDEP,:bW{ '999~250 DEVI.bW2 '557 1~ '404 , 199.843 '999,250 8 234 "999, 999,.250 c~lum~erger Alas~ COmOU~[vq Center D~PT. 9400,O00 AT~,L~2 G~oLW2 I04,298 SNR,LW2 DFPT. 9~00,000 AT~,LW2 G~.~W2 96,5~5 SNR.LW2 DKP?. 9000.000 ATR.DW2 G~.LW2 101,984 SNR.LW2 D~PT, 8800,000 ~T~.LW2 G~.LW~ 1~$,695 SNR.LW2 DEPT. 9600,000 ATR.LW2 GP'LW2 124.961 SNRoLW2 DEPT, 8400.000 ATRoLW2 G~.LW2 126.150 S~R.LW2 DEPT. 8200,000 ATE LW2 Gg,LW~ 8],496 DEPT. 8000 000 ATR.bW2 ~.sw~ !oo:~o4 ~PT. 78oo.ooo D~T. 7600,000 ATR~LW2 D~PT. 7400'000 ATR.~W2 G~,LW2 125'970 SN:R.SW~ DEPT 7200.000 · .. bW2 G~.b~~ 144'446 DFPT. 7000'.000 ATR:.L~2 a~'~w~ 9o: 43 24-HAY-lg93 15:5] 4.433 PSR.bW2 -12,$00 VDEP.bW2 4.324 PS~.bW2 -10.000 V~EP.LW2 3.491 673.~00 VDEP,~W2 3.~71 PSR.LW2 666.~00 3,544 66~.600 VDEP,SW2 3 8i.] PS~.LW2 667]300 3 ]4 PSR. 3 64 ~W2 3. ~5 3 609. ~00 560 i 800 1. 764 -9.600 4.589 -999,250 4.002 -999.250 3.230 -999.250 -99g.~50 3.525 -999,250 3 824 -999:~50 . 2.768 -999.~50 '999.~50 -999.,25O , 3804 -9992250 4. 66 -999.50 -999 50 -999.250 .~50 ROPE,LW2 DEVI,[.W2 ROPE.LW2 DEVI.LW2 ROPE.LW2 DEVI.LW2 ROPE.LW2 DEVI.Lw2 ROPE.LW2 DEVI.LW~ POPE,LW2 DEVY,LW2 ROpE.LW2 DFVI.LW2 DEVI,LW2 DEVI.LW~ DEV!'LW~ ROPE'LW2 DEVY.LW2 ROPE.LW2 DEVI.LW2 RoPE'LW~ DEVI'.SW2 DEVI'LN2 DEVI.BW2 PAGE: -999,250 158.415 -999.250 182.456 -999.250 153.771 -999,250 2~5 874 -999:250 188.349 -999,250 8~.376 -99 ,~50 317,289 "999,250 13~,399 '999,250 .270,499 '999.250 318.031 -999,250 248,610 '-999,250 is 'oo -999.250 259,704 '999.250 ~"999. 50 18 IS Tape Ver..iftcation ~,i~iuq chlUmb.~rqer ~las~a Co~putin~ Center PAGE~ 1.9 **** FILM TRAILEP **** F!LF H~E : EDIT .OO~ SERVICE : WL!C VERSION : 00i~07 u~X ~EC SIZE ~ 10~4 F~LE ~YPE : LO **** FILE ~ADER **** FIL~ ~A~ : EDIT ,004 SERVIC~ ~ V~RSI~N ~ 00lA07 ~X ~C SIZE : 10~4 FIL~ TYPE : LO L~ST F~LE F!bF gEnDER RAW ~WD curves and log header data for each bit run in separate files, BIT ~UN DEPTH IMCRE~ENT: 0.5000 # VENDOR TOOL CODE START DEPT~ CD~ t042~,O LOG HEADER DATA D~TE LOGGED: SOFTWARE: SURW~CE SOFTWAR~ VERSION: DOWNHObE $OFTMAR~ VERSION: DATA TYPE (~EMORY OR RE~L-TIME)~ TOP LOG INTERVAL (FT): ~OTTOM bOG BIT ~OTATING DOLE INCLINATION (PEG) MAXI~U~ ANGLE~ STOp DEPTH 1,1241,,0 02-0CT-9~ FAST tl~4l.O 3663*0 39,/022/058 IS Tape Verification Listino chlumberger .AlasKa Computln~. Center 24-MAY-iq93 15:53 PAGE: 2O ~OREHObE AND CASING DtT~ OPEN HOLE MIT SIZE DRILLERS C~SING DEPTH (ET): ~ORE~OLE CONDITIONS ~UD TYPE: ~UD DEnSiTY (LB/G): .IJD VISCOSITY MUD DH: ~SISTIVITy (OH~ AT TEMPERATUNE DEGF) MUD AT MEASURED TEMPERATURE (~T): ~U~ AT MAX CIPCUbATING TEmPErATURE: ~UD FILTRATE AT ~T) MUD CAKE AT ~EUTRON TO05 ~TRIX DENSITY: ~ObK C~RECTI~N TO~L STANDOFF KWR FREQUENCY 3 3.0 10,60 1,810 65.0 1,480 8,500 RUN 3~ DRILL lOJ21:' TO 11241' GR TO .BIT~ 44 1 , RES, TD BITj D~T~ FRO~ DO~HOLE ~EMORY. DAT~ S.A~Pb~D ~V~RY ~6 $~COND$. SOFTWARe: V2.3D /4.0C LIs FORMAT DATA CONS ..TUNI VAbU DEFI TYPE CM ARCO ILnSKA TNC. Company ~ame FN KUP&RUK RIVER UN . J..IT Field Name S~CT WYTN PD~T 2M-29 50-103~20183 1!4' FSI. & 51' FEI, ~ORTH SLOPE BOROUGH ALASKA ~14' FSL& 51' FEb ~ORRISON 6{8976 ~ell Name AP1 Serial Number i.ld Location Section Township Range County State or Province Matlon Latitude Longitude witness Name Service Order Number PermaneDt datum ES TaPe verification List~no chlt{mberqer AlasKa Computing Center 24-NAY-iD93 15:53 PAGE: 21 TUNt VA!JU DKFI TYPE ~ rT O, Elevation of . Permanen L~F PKB Log ~easured From ~PD FT 146. tbove Permanent Datum EKB ~T 146. glevation oi Kelly Bu EOF rT 146, flevation of Derrick E~L FT 105. ~levation of Ground L TOD wT 13015. Total Deptb. Driller TDL FT 13015. Total DePth - Log~er 8ti ~T 130!5, Bottoz Log Interval TLI FT 3663. T t LDO Interval DWD G/C3 10.6 Drillin~ Fluid Densit DFP~ Drilling Fluid Ph ZONE DFV S Drillln~ Fluid Viscos ZONE DrL F3 Drillin~ Fluid Loss ZONE RMS OHM~ ! ~ ~esistl~ity Of Mud Sa ~ST DEGF 6~~ ~u~-Sample'TemPeratur RMFS OH~ 1 ~8 ~esistivit¥ of'~ud Fi ~ST O£GF 6~ ~ud_Filtrate Sample T RMC~ OH.H ~esistiVitV of ~ud Ca ZONE MCST DEGF ~ud.Cake SamPle Tempe STE~ DEaF -999.25 Surface Temperature BHT- DEaF 140. Botto~ Hole Temperatu TUN! BDEP TDEP DFPH DFV DFL RMCS ~CST I Fr O, O. O, O. O, O. O. : · . DEPT ~nemth ATR RGS ~HC ATTENUAT!(}N RESISTIVITY PSR RGS :BBC PHA$~ SHIFT RESISTIVITY :G~ Gamma Ray DEVY Hole Dev{ation V~gP True VertiCal DePth as channel <TVTCPi> Tape Verification Listing chlumberger Alaska Computi~o Center 24-MAY-1993 15:53 PAGE: ** SET TIP: - 64CB ** TYPE R~P~ CODE VALUE ! 66 0 2 66 0 ] 7] 32 4 66 1 5 66 6 7] 7 65 9 65 11 66 32 12 68 13 66 0 14 65 FT 15 66 68 16 66 ~ 0 66 1 ** SMT TYPE - CHAN,,** ..:....:.. ......... . ......... ...... ...... . ....... :.....:....... .... .................... N~~M~ RRV ......[INIT SERVICE API APl AP1 AP1 FIL~BNUM NUMB.. SIZE REPR PROCESS ID ORDER # LOG TYPE ChA$S ~OD NUMB SimP ELEM CODE (HEX) D~PT F~ 6~8976 4 ! ! 4 68 0000000000 OHMS 6 8976 O0 000 O0 0 4 1 I 4 68 0000000000 O0 000 O0 0 ATR .o~ ~ ~,.~ ~~ OD ooo OD o 4 ~ ~ 4 ~ oooooooooo ~ ~ ~ 4 ~ oooooooooo ~ ~ , ~ ~ oooooooooo ~ ~ ~ ~ ~ oooooooooo ~ ~ ~ ~ ~. oooooooooo 4 I 1. 4 68 ~000~00 ** DATA ** DEPT'. 11241 000 ATR.LW3 1~ 103 PSR,b~3 12 900 ROPE,LW3 G~.LW3 65:333 D~VI.LW] 9:027 VDEP,LW3 6124:743 SN'R.LW3 DEPT 11200,000 ATR.LW3 I! 928 DSR LW3 13 9~ ROPE LW3 GD~LW] 65,115 DEVI.LW3 90:94] V~P:~W3 6~25:4 SNR:LW3 DEPT. !I000,000 ATR.LW3 13,596 PSR.LW] 16.28~ ROPE.LW3 G~.LW] $7.836 D~VI.LW3 85.254 VD~P.LW3 6120.407 SNR.LW3 D~PT. 10gO0.000 ATR.LW3 30,630 PSR,~.3 38 225 ROPE,LW3 GR.LW~ 45.634 DEVI.LW~ 83,~31 VDEP. 3 6094:790 SNR.LW3 120,000 744.300 -9.300 6 - :lgo 22 IS Ta~e Verification Listinq chltlmberqer ~lasKa Comput!n~ Center' 24-~AY-!993 15:53 23 DEp~. tn600,000 AT~.bw3 G~,LW3 49.880 DEVI.Lw3 D~PT. 104~I.000 ATR.LW3 Gm,L~3 72,695 DEVI.bW3 ** END OF DATA ** 62 990 PSR.bW3 79.'720 VDEP.LW3 ~.61~ .~SR.bw3 72.881 VDEP. R~..161 ROPE.LW3 6072.812 SNR.LW3 4.]92 ROPE.LW3 6028.371 SNR.LW] 30.100 770.600 55.728 760.300 **** FILF TRAILER **** FILE NA~E : EDIT .004 SERVICE ~ FLIC V~R$ION : 00lA0? ~X REC S!Z~ : ~024 FI[,F TYPE : LO LAsT FILE : **** FILE HEADER **** FILM NA~E : EDIT ,005 SE~v!cE : FbIC VFR~ION : O01~AO7 D~TM ~ 9]/0~/~4 ~X REC SIZE : !024 FILE TY~E ~ LO bAST FILM ~ Curve~ and log header data ~or each bit r~n ~n separate files. BIT RUN NUMBER: 4. D~PTH IMCRM~T~ 0.5000 # FIL~ SU~M~RY VENDOR TOOL CODE 8TART DEPTH '10750,0 LOG H~ADER O~TA DATE LOGGED~ SURF,ACE SOFTWARE VERSION:. OOWNHOL~ ~SOFTWA~E DATA TYP~ (MEMORY OR TD DRILLER (FI): TOP LO~ INTERVAL 1.0809.0 4.0C O IS T~°e Verification Llstino chlumberqer AlasKa Computing Center 24-~AY-1993 15:53 PAGE: 24 ~OTTOW bOG INTMRVA[, (FT): BIT 90TATING SPEED HOL~ INCLINATION TOOL ST~ING (TOP TO V~NDO~ TOOL COD~ TOOL TYPE .... .... ........ cn~ .TY $ 10809.0 TOOL ~G8~]9/022/058 ~ORE~OLE AND CASING DATA OPEN HOI,~ 8~T SIZE (IN): , 8.500 D~ILL~g$ CASING D~PTH (FI): 3663.0 80RENOSE CONDITIONS ~UO TYPE~ ~UD DENSITY (LB/G): ~o,$0 ~UD VISCOSITY (S): ~UD FLUID LOSS !S?IVITY (OM~ AT TEMPERATURE DE~F) RE$~u6'AT ~EASURED TEMP~ATURE~ (~T): 1.810 ~UD AT ~AX CIRCULATING TEMPE~ATL!~E ~U~ FILTRATE AT MT: t.4~0 ~E[JTRO~ TOOL MaTRiX: HOnK CO~ECTION tIN): 8,500 TOOL STANDOFF FREQUENCY (HZ): ~EMARKS: FIE[:,D.:ENG~NEER~S REMARKS: RUN 4:DRI[,5 IQ750' TO 10809'' GR TO B~T:.43 ', DAT~ ':FRO~ DOWNHOLf OAT.~ SA"PLED EVERY 20 S~CONDS. SOFTWARE: V2,3D $ FORMAT DATA 65.0 65.0 / TABLE TYPM : COL~!S T ~ N ! VA bi) DEF I TYPE CN ARCO ~I,~$KA. INC ComDan~ Name FN KUP~RII~: ~IV~R"'UN~T Field-~ame W'~ ~-~9 Well Name IS Tape VerIficatfon Listinq chlUmberoer Alaska Computing Center 24-MAY-1993 15:53 PAGE: 25 TUM? V~I,U DE aDI 50-103-20i83 . ~p! FL 114' FSL & 51' FEL Fie 28 Sec lin Tow 8E Ran NORTH SLOPE BOROUGH Cou ALASKA Sta 114' FSL & 51' FEL gat COUN STAT N~TI ~IT~ SON 618976 PDaT EPD FT 0 ADD PT 146, EKB wT I46. EDP mT ~46. E~L FT I05, TDD FT Tnb FT Th! FT 3663. DFT BRINE DFD G/C3 DFPH DFV S R~S OH~ 1,81 ~$? D~GF 65~ R~FS OH~M I 8 ~rST O~Or 6~~ ~CS OH~M ~CST DEGF STE~ D~GF -g99.25 B~T D~F FI TYPE m~m~~m~~mm~~m~mmm~m~m~ serial Number Id Location tton nshtp ge ntv te or Province ion Latitude Longitude wit~ess Name Service Order Number Permanent datum. Elevation o~ Permanen Log Measured From ~bove Permanent Datum Elevation of Kelly Bu Elevation o~ Derrlc~ Elevation of Ground b Total DePth - Driller Total Depth -Logoer Botto~ 60~ Interval TOD [,Og Interval Drilling Fluid O~Ill.g Fluid DrIbrtilInonO Flu Fluid viseos - . ty of MUd Sa ~ d Sam !e T~mpe~atur ZONE ZONE ZONE Mud Filtrate Sample T Resistivity of Mud Ca ZONE Surfaekee Sample Temp~ ZONE Temperature ' ~ottsm Nole T~mperatu TABLE TYPE ~ ZONE TUN! BDEP TDEP DFPH DFV - - nFL R~C$ ~CST 0 O' O' O, IS Ta~e Verification bi. sting chlumberoer Alaska Computing Center 24-MAY-1993 15:53 PSR G~ gGS ~HC ATTENUATION RESIST!VITY ~GS BHC PHASE SHIFT RESISTIVITY RATE OF DRILLING P~N~TRATIO~ Gamma Rav NO1e ~ev~ation True Vertical Depth as channel cTYTCPI) PAGE: 26 ** DATA FOR~AT SPECIFICATION RECORD ** ** SET TYPE - 64EM ** TYPE R~PR.:CODE ! 66 0 2 66 0 3 73 32 4 66 5 66 6 73 7 65 8 68 05 ~I 66 32 12 6~ 1] 66 0 14 65 FT 15 66 68 16 66 0 66 N~ S~V [INIT SE~VIC~ API apt APT ~PI FIL~ N[JM8 N~MR S!~E ~EPR P~CES~ ID ORDER ~ bOG TYPE CLASS MOD NUM:B SAMP E[~EM ..... CODE. (HEX) AT~ bW4 ~H~ 618976 O0 000 O0 0 5 1 I 4 68 O000000OO0 PS~ ~w4 o~.. et~76 oo ooo oo o s ~ ~ 4 se ooooooooo0 ~Op~ LW4 P/HR 618976 O0 000 O0 0 5 ! 1 4 Se 0000000000 a~ ~,w4 ~A.~ 6~976 oo ooo oo o s 1 ~ 4 se oooooooooo D~V! bW4 DEG 61~976 O0 000 O0 0 5 ! 1 4 68 0000000000 Vn~P tW4 FT 6i8976 O0 000 O0 0 5 1 i 4 6" 0000000000 SNR bW4 OB 618976 OO 000 O0 0 5 ! 1 4 68 0000000000 I$ Tape verification [,istinq Chlumberger Alaska Comp'.ltinq Center 15:5] PAGE: 27 ~m~mm~m~mm~m~mm~mm~mmmmmmmm~mmmm~mm~mmmm~mm~m~mm~~~m~mmm~m~mmmm~mmm~mmm! DEPT. 10809.000 ATR.LW4 25.272 PSR.bW4 GR.L~4 41,803 DEVI,LW4 82.603 VDEP.bW4 DEPT, lO~O0,OOO ATP,LW4 30.630 PSR.LW4 G~.LWa ~5,614 DEVI.LW4 83,231 VDEP.LW4 D~PT 1075n 000 ATR.LW4 10 212 PSR.tW4 51.994 RGPE.LW4 6095.812 SNR.LW4 225 ROPW. LW4 ~.117 ROPE.LW4 60 ..926 SN~.LW4 END OF DATA 11.409 206.200 7.246 'g.300 115.380 665.900 FII.,F NAME : EDTT ,005 V~RSION : 001A07 DATE : 9]/05/24 ~A× REC SIZE : F~LE TYPE **** FILE HEADER FILe, NAME , gDIT .006 VMR~!O~ : O01A07 D~. · : g~/~/~4 'FILM TYPE ~ LO LAST F~LE FIL~ H~DER FILE NUMbeR RAW , _ Curves and 1o~ .eader ~at, a ~or each blt run in SeOarate.[~les g~T RUN NUMBE~: - 5 ' DEPTH INCREMENT: 0,5000 ~II,~ SUMMIRY VENDOR ?O£]L CODE START DEPTH sTOP DEPTH CD 10809,0 10905,0 $ · ~OG H~ADgR DATA IS Tape Verification List. inq chlumberaer Alaska Computlno Center 24.,.~4AY=1993 15:53 PAGE: 28 $OFTWARE~ SURFACE SOFTWARE VERSION: ~AT~ TYPE (~MORY TD D~IbLER TOP LOG ~NTE~V&b mOTTO~ bOG INT~RVA[. (FT)~ mit ~OTATING SPEED (RPM)~ ~OLE INCLINATION CDEG) v~XI.U~ ANGLE: BOREHOLE AN[) CASING DATA OPEN HOLE BIT SIZE DRILLERS CASING DEPTH (FT): BORENObE CONQITIOMS MUD TYPE: ~UD DENSITY (LB/G): MUD VISCOSITY ~UD MUD AT SEAS .UD AT ~X ~iR~ULATiNG TEMPERATURE~ ~UD FILTRATE AT ~UD CA~E AT 0~-0CT-92 FAST 2.3D 4.0C HE~ORY 10905.0 10809.0 !0905.0 TOOL NUMBER R~$Slg/O~2/058 B 500 10,60 1,810 $5.0 ~.4~0 65.o NEUTRON ?OOb ~AT~IX DENSITY: HObE CORRMCTION 8,500 ~W~ FREQUENCY FIELD ENGINEER'S 8E~ARKS: RU~ 5: D~IbL ~0809' GR TO ~IT: 44 7 , RES,.'T_~ BIT. DATA SAMPLED EVERY ~ SECOND$"'$OFTwARE~ V2,3D /4,0C IS ?aue verification Listinq 24-MAY-Igg3 15~53 PAGE: 29 chlumberqer AlasKa Comp-utin~ Center ' TUM! VALU DEFI TYPE ''~'''''''''''''''''''C ..... ''''~';~S~,'''''''''''''''''~''''~''''''''''''''''T~C Comma y Na e ..... ''''''''''''''' F~ KI. IP~RUK RIVER ~N~T Field Name W~ 2~-29 Well Na~e APX~ 50-~0~-20~8~ A~I Serial Number FL 1t4' FSL & 51' FEL Field Location S~CT 28 .... Section TOW~ lin Township R~N~ ~E Range COUN NORTH SLOPE BOROUGH Cou tF ST~T A[,~SKA State or Province N~T! ~4' FSL & 51; FEL Nation LaT! 5atltude LON~ Longitude WITS ~0R~ISON Witnes~ Name SON 618976 Service Order Number PD{T ~b Pe.~ma~ent datum EPD WT 0. Elevat{on of Permanen L~F RKB Lo~ ~easured F~O~ A~O FT 146. AbOve Permanent Datum E~'B ~T 146. Elevation of Kelly Bu KD~ ~T 146, Klevat~on o~ Derrick E~5 FT 105.= ~ievation of Ground L TDD ~T ~]01.~ Total Oe~th - Drille~ TDL FT I]Oi : Total DePth - Loq~er BL! FT 1]015, Bottom LOg Interval TL! FT 36~3. TOp ~o glnterval DFT BR ~E Prllli~ Flui~ Type DFD G/C] ~0'6 Dr~llin~ Flu Densit DFC, .... Driltin~ Fluid P~ ZONE DFV $ 9r[Ilino Fluid Viscos ZONE Dr[, F3 Ortllinq~..~Flu d LOSS- ZOME ~S nH~ ~B1 ~esis~i~i~TO~ ~ud Sa ~ST DECF '8 Mtld.~S mD/ e Peratur ~FS 0'~ ~ PesistiVitV of ~u~ Fi ~FST DEGF 6~ Mud Filtrate Sample T RMC8 ON~ Resl~ lvi f ~ud Ca ZONE ~C~m DE~F Mu~ ~ tY o .......... ~ .... ke sample Tempe ZONE ST~ ~E~F -99.9.25 $~[face TemDeratu~e .BHT. , DEGF I40, B tO~ Hole Temperatu ~TIBLE TYP~ : ZON~ TUN! BOEP TDEP DFPH DFV DFL R~C$ ~CST O, O. O, 0, 0, O. O. Cblt)mber~er A)aska ComD~Iting Center 24-MAY-1993 !5:53 RnDF VDEP neath qGS BHC ATTENUATION RESISTIV!TY RGS BHC DHA$~ SHIFT R~SI$TIV!T¥ ~ATF OF D~IL[,I~G DENETRAT!O~ Gamma ~lole Deviation True reft(ca! Depth a~ channel <TVTCPI> 3O ** DATA FORMAT SPECIFyCaTION RECORD ** ** SET TYPE - 64~B ** ! 66 0 2 66 .0 3 73 32 4 .66 5 $6 6 73 7 65 8 68 0 5 9 65 F~ I! 66 32 12 68 !3 66 I4 65 FT 15 66 68 t6 66 0 66 ** SET TYPE D~PT rT 618976 O0 000 O0 0 6 I i 4 68 ~TR LW5 OH~ 618976 O0 000 O0 0 6 1, I 4 68 PSR bW5 OH~ 610976 O0 000 O0 0 6 I ! 4 68 ROP~ bW5 F/~R 610976 O0 000 O0 0 6 1 i 4 68 G~ LW5 GAPI 618976 O0 000 O0 0 6 I 1 4 68 D~VI LW5 9EG 618976 O0 000 O0 0 6 t I 4 68 V~EP LW5 FT 618976 O0 000 O0 0 6 ~ 1 4 68 S~R LW5 DB 618976 O0 000 O0 0 6 ~ 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 IS TeDe Verifi. cetion !,,istino chlumberqer ~lasKa ComputiD~ Center 24-MA¥-1993 PAGE: 31 ** DATA ** DEDT 10905,000 AT~,LW5 27,393 PSR,LW5 39,1985 ROPE,LW5 GR:I, W5 52,27~ DEV ,bW5 8~,944 VDED.LW5 6~09, 64 SNR,LW5 DEPT, 10809,000 ATR,LW5 25,272 PSR,LW5 51,~94 ROPF,LW5 GR,LW5 4{,803 DEVI,LW5 8~,603 VD~P.LW5 6095,8%2 S~R,LW5 END OF DA?A ~ -999,250 745,300 1~,409 206,~00 F~LE NAME : EDIT ,006 S~VICE : FLIC V~R$ION : 001~07 DAT~ : g3/05/~4 ~X R~C SIZE : 1024 FIL~ TYPE : LO FILE NA~E : EDIT ,007 S~RvICE : FLIC VERSION : O01A07 DATE : 9]/05./24 ~AX R~C SIZE : 10~4 FILF TYPE L~ST FILE RAW MWD C%~rves and io0 2cadet :data BIT RUN NUdgER: 6 DFPTH INCREMENT: 0,5000 VEMDOR TOOL CODE ~DR # .... ~R DA~A LO~ DA~ 5OG~ED~ SOFTWARE~ SUR~CE $OFTWAR~ for START DEPTH 10905 VSRS~ON: each bit run: in'separate STOP DEPTH 12500.0 02-OCT-g2 ~iies. IS TaDe verfftcation Llstln~ ChlUmber~er Alas<e Computin~ CeDter 24-MA¥-1993 15:53 PAGE: DQWNHObE SOFTWARE VER$ION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER ~OTTO, LOG INTERVAL ~OLE INCLIN&TtON (DEL) ~AXI~U~ A~GLE: TOOL STPING (TO~ TO YENDO~ TOOL CODE TOOL TYPE ~ . REglSTI¥ITY 80REHOLE AND CASING DATA OPEN HOLE ~IT SIZE (IN): DRILLERS CASING DEPTH ~OREHOLE CONDITIONS ~UD TYPE~ MUD DEMSiTY (LB/G): VISCOSITY CSLORIDES FLUID LOSS (C3 : R~$ISTiVITY (OH~ AT TEMPERATURE DEGF) MUD AT MEASURED TEMP~R~TUR~ (~T)~ ~UD AT ~X CIRCULATING TEmPErATURE: gUD FILTRATE AT ~UD CAKE AT gE!JTRON TOOL MATRIX: ~TRIX D~N'SI?Y~ HOLE CORRECTION {IN): TOOL STANDOFF (IN): MW~ FReQUEnCY 4.0C MEMORY 12500.0 10905.0 12500.O TOOL ;~UMB~R 8.500 ~663,0 10,60 1,810 65,0 1,480 65.0 8,500 RUN 6: DRILL 10~05' TO 12500' GR TO BIT: 44.0', R~S..:TO BIT: 33,6' DATA SA L NDS, SOFTWARE; .V2,::]D /4,0C $ ' . ~!S FORMAT DATA IS TaUe Verification Listino 24-MAY-1993 !5:53 PAGE: Chlumberqer Alaska Comuut!~ Center TABLE TYPE : CONS T~! VALU DEFI TYPE ............ .... .......................-..............,,.,,...... ..... .. .... ..................... .... CN ARCO ALASKA, INC. m ny Name F4 KUPARUK RIVERU IN T Field Name WN 2~-~9 Well Name APIN 50-103-2018] Ap! Serial Number Fi. 114' FSi, & 51' FEb Field Location SECT 2~ Section TO~ I1N Township ~'G 8~ Ranqe COUN NORTH SLOPE BOROUGH County STAT A~SKA State or Prov~nce N~TI 114' FSL & 5!' FEL Nation L~T! Latitude LON~ ~onqitude SON 618976 Service Order Number PDAT MSL Per~anent datum ~PD FT O. Elevation of Permanen L~F ~K.B Lo~ ~easured From APb ~T ~46, Above Permanent Datum E~ FT ~,46, Elevation of ~ellV Bu ELF FT ~46, Elevation of Derrick EGL FT 105 ~levatlon of Ground TDO ZT 1.~0{5, Total Depth , Dtl. ller T~L WT 11~, Total Depth - boqaer B~.I mT 1 , Bottom 5o~ Interval TLI FT 3663, Top Log Interval D~T B~iNE Drtlli~ Fluid Type DFD G/C3 10,6 Drillin Fluid Oenslt DFP. ' Dri~ln~ Fluid ph ZONE D~V S nri~ii "rlula vlscos ~t, r~ Orli~ riulo ~oss ZON~ ~$ O~M 1 81 ~esistlvtty of ~tld Sa ~$T OEGF 6~, Ud Sammle Temperatur ~FST ~KGF 65. ~ud..,Filtr e Sample T R~CS OH,M Resistivity of Mud Ca ZONE ~CST DEGF ~ud~.Cake sample Tempe ZOnE ST~ ~EGF -999,~5 Surface Temperature B~T Q~F . ~40, Bottom Hole Temperatu TABLE T'¥P~ : ZONE TUN! BDEP TDEP DFPH I FT O. O. O, 0., O, ~: O. O, IS Tare Yerification Listing 24-MAY-I, 993 15:5] chlumberger Alaska ComPutin~ Center DEPT VOEP Oemth QG$ ~HC ~TTEMUATION RESISTIVITY RGS ~HC PHASE SH%FT RESISTIVITY ~TE OF DRILLING PENeTRATiON Gamma gav go!e Deviation True Vertical Depth as cbanne~ <TYTCPI> mmmmmmm~mmm~mmmm~mmmmmmmmmmmmmmmmmmmmm~mmmmmmmmmmmm~mmm~m PAGE: 34 ** DATA FORMAT SPEC)F!C~TTON RECORD ** ** SET TYPE - 64EB ** 1 66 ~ 66 0 3 7~ 32 4 66 '5 66 ? 65 8 68 0,5 9 ~5 FT 11 66 32 12 1~ 66 0 i4 65 15 66 68 !6 66 0 66 I TYPE - CHAN ** . ~IO. o~PT FT AT~ bW6 OHMM ROPE hW6 F/HR ~ hW6 GAPI ORDE .... ~ LOG TYPE CLASS MOD NUMB S~.~P EbEM CODE 618976 O0 000 O0 0 7 1 1 4 68 0000000000 618976 O0 000 O0 0 7 i 1 4 68 0000000000 61~976 O0 000 O0 0 7 1 1 4 6~ 0000000000 618976 O0 000 O0 0 7 1 I 4 68 0000000000 6i8976 O0 000 O0 0 7 ! I 4 6B 0000000000 618976 O0 0'00 O0 0 7 1 1 4 68 0000000000 61~976 O0 000 O0 0 7 ! ! 4 68 0000000000 61~976 O0 000 O0 0 ? ~ I 4 68 0000000000 Tape verification Listlno 24'~AY-~.o93 t5:53 chlumberoer Alaska ComputlmO Center PAGE~ 35 ~m~mmmmm-mmmmmmmmmmmm~mmmmmm~m#mmm#mmmmmmmmmmmmmmm~m~mmm~mmmmmmmmmmmmmmmmmmmmmmmmmmm D~pT. 12500.000 ATP.LW6 32 654 G~.LN6 '34.933 DEVI.LW6 87:606 VDEP.LW6 D~PT. {2400.000 ATR.LW6 29.025 PSR.LW6 oo.ooo G~,LW6 57,684 DEVI.LW6 90. 5 DEPT. 12000.000 ATR,LW6 34.793 P$~,LW6 G~.LW6 40.4~3 DEVI.LW6 90.289 VD~P.Lw6 DEP?. 11800.000 ATR.LW6 33 67 PSR,L~6 ~,LW6 43,129 DEVI.LW6 91~91_ VD~P,bW6 D~PT 11600.000 ATR.LW6 16.4]9 PSR,LW6 G~LW6 6~,896 DEVI.LW6 90.756 VDEP,LW6 DEPT. 11400.000 A~P,LW6 16.018 P$~.Lw6 G~.LW6 63,334 DE i,LW6 91.544 VDEP'LW6 D~PT. i~.200,000 ~TR.LW6 11.9~8 PSR.bW6 G~'LW6 66.115 DEVI.LW6 90.943 · DEPT, II000,000 AT~.LW6 1].596 PSR,5W6 G~,LW6 ~7'8~6 DEVI,LW6 85,~54 VDE~,LW6 D~PT 1090~ 271 DEVi,LW6 8t,944 VDEP.LW6 6!.761 6112.436 63.739 6109.845 44 ~74 6109~683 58.004 6110,613 48,566 6113.537 6117.8~0 612 !.90 13.920 6125.458 6 09.964 ROPE.LW6 SN~.I. W6 ROPE.LW6 SNR.LW6 ROPE.LW6 SNR.LW6 ROP£.LW6 SNR.LW6 ROPE.LW6 ROpE.LW6 ROP~'LW6 SNR.LW6 MOpE'[,W6 SNR,LW6 ROpE'LW6 SNR-LW6 ROP~'LW6 SN~.LW6 -999.250 750.600 64.748 798,400 71,713 802,900 49,219 783,700 6 o 0 39,046 154,800 80,000 746,900 747,500 ,oo8 -9.300 ~-999.250 745,300 END OF DATA ** · **** FILM TRAILER **** FILE NA~E : EDIT ,007 S~VICE : FL!C VERSION ~ 00iA07 ~AX REC SIZM : 1024 FIL~ TYPE : hO L~ST FILE IS Ta~e Verlf.,1¢at~.on Listi~q ¢~lumberger Alaska Computin~ Center PAG£~ 36 FILE MAMg : EDIT .008 $~vIcE VERSION : 00~A07 ~AX REC SIZE : ~0~4 F~LE TYPE LAST FILE FIL~ NU~BER 8 RAW MWD BITCurvesRUN NUMBER:and log. header7 data for each bit. run in separate files, DEPT~ INC~E~E~Ti 0.5000 # FTL~ SUmmARY VENDOR T~OL CODE START DEPTH 12500.0 LOG HEADER DATA DATE bOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (~E~ORY OR ~EAL-TI~E}: TD DRILL~g TOP LOG INTERVAL (FT){ BOTTOM: bOG INTERVAL (FT)~ ~IT WOTATING SPEED "OLE INCLINATION (DEC) ~IN!MUM ANGLE: wAXIMU~ ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOh CODE TOOL TYPE ~O~EMOE, E AND CASING DATA D~ILLMR8 CASING DEPTH # BO~EMOLE CONDITIONS VUD TYPE: ~UD DENSITY (LB/G): ~UD VISCOSITY (S): ~UD STOP DEPTH 13015.0 02'0CT-92 FAST 2,]D 4.0C. ~E~O~Y I30t~.0 1250 '0 i30I$,0 RGS839/022/058 1:0,60 IS Tape verification Listinq chlumberger AlasKa Computin~ Center 24-~AY-1993 15:53 PAGES 37 RESISTIVITY (OHMM AT TEMPERATURE ~UD AT MEASUgED TEMPEraTURE (~T)I ~UD AT gal CIrCULATInG TEMPERATURE: ~UO FILTRATE AT ~T~ ~UD CAKE AT MT: NEUTRO~ TO05 ~ATRIX DENSITY: ~OLE CO~ECTION TOOL STAgDOFF (IN): 1,480 8,500 FIELD ~NGIN~ER"S RUN 71 DRILL 12500' TO 13015'! . ~"ASHDOWN GR ~2~76' TO 246 ' GR TO BIT~ 44,4', RES. TO BIT. DAT~ F~ DOWNHOLE ~E~RY, ..... DATA S.A~DL~D EVERY ~6 $~CONDS SOFTWARE: $ # LIS FORMAT DAT~ 65.0 65.0 V2,3D /4,OC TYPE : CONS ~CO a.t.,~SK'~ TNC_, Company Name FN KUI~ARUK RIVER UNIT Field Name AD!N Fb 'S~CT TOWN N~TX L~T! SON F~D L~F ?OD 2~-29 50-103-20i83 NORTH SLOPE BOROUGH ALASKA. 1!4' ~SL & 51' FEI, MORRISON 618976 ~B F'T 146. ?T 146. ~T 146, Well Name APl Serial Number Field Location Section Townshi~ Range County State or Prov~nce Nation Latitude Longitude Witness Name S~vice Order NumDer Permanent datum Elevation of Permanen 5DC ~easured~ From Above= Per~anent Datum =~Elevation of Ke'llv BU ElevatiOn of Derrick Elevation of Ground TOtal Depth -~ Drtt!er Total Depth -LoGger Bottom Log Interval IS Tape Verification Listing 24-NAY-lgg3 15:53 PAGE: 38 chl%~mberger Alaska Computing Center ' · TUNI VALU DEFI TYPE . ,I WT 3663. TOp Lop Interval DFT BRINE Drillino Fluid Type_ DFD G/C3 10.6 Drillino Fluid Densit DFPH Drltlino Fluid Ph ZONE DVV S Drilling Fluid Vlscos ZONE DF[, ~3 Drilling Fluid Loss ZONE R~$ OH~M 1.81 Desistlvity of MUd Sa ~ST D~GF ' ~FST D~GF 6_. ~esistl lty of Mud Fi .~d-.Fi. ltrafe sample T R~CR OH~ Resistivity of MUd Ca ZONE NCST DKGF Nud.Ca~e Sample Tempe STE~ DEGF -999 25 Surface Temperature BHT ' - DK~F 140. Botto~ Hole Temperatu TA~!,K TYP~ C ZONE DEFI D~P? Be~t ATR ~G~ BHC RTTENUATION RESISTIVITY PSR RGS BNC PHRSE SHIFT RESISTIVITY ROPE_ RATE OF DRILLING PE.~T~ATIOMN G~ ~amma Ra D~VT Hole DevYation V~EP True vertical ~epth as channel (TVTCPI) ** DATA ** SET TYPE - 64EB ** TYPE REPR~ ~' . ',,ODE .. VA[~:UE ! 66 0 :IS Tape Verification bistin.q chlumber~er AlasKa Computtna Center 24-MAY-1993 !5153 PAGEI 39 4 5 7 8 9 11 0 ~lJ.m ** SET TYPE - CHAN ** -.........,,..,-.......-...-................-.........,,,...,.,........,........,....... TD ORDER ~ 50~ TYPM CLASS MOD NUmB 8~MP ELEM CODE D~PT FT 618976 O0 000 O0 0 8 1 I 4 68 0000000000 ATR LW7 OHEM 618976 O0 000 O0 0 ~ ! I 4 68 0000000000 PSR LW7 OH~M 618976 O0 000 O0 0 8 ~ I 4 68 O0000000OO R~P~ LW7 F/HR 618976 O0 000 O0 0 ~ ! 1 4 68 0000000000 G~ 5W7 GAP! 61~976 O0 000 O0 0 8 I I 4 68 0000000000 D~¥! bW7 DEG 618976 O0 000 O0 0 8 ! ! 4 68 O000OO0000 VDEP LW7 FT 618976 O0 000 O0 0 ~ 1 I 4 68 0000000000 SNR bW7 . .DB 618976 O0 , 000 O0 0 8 1 1 4 68 0000000000 ** D~T~. ** DEPT,L!~7 1301.5,000 ~TR,LW7 -999,250 PSR.LW7 999 250 ROPE LW7 G~, -999,250 DEV'I,LW7 91,100 VDEP.LW7 ~19:351 SNR~LW7 · ~P,LW? 250 DEVI:bW7 90:899 VDE~..LW7 ~119:506 SMR:LW7 DE'PT. 12800,000 A?R,LW7 35 375 PSR,LW7 6~791 ROPE LW7 GP.bW7 56.183 DEVI,LW7 89~70~ VDEP,LW7 611 951 SNR:LW7 '~R,LW7 65,0'69 DEV'I,LW7 88, VDEP,~LW7 61.!6.528 SNR:LW7 D~PT i~500.000 ATR.LW'7 32,654 PSR,,LW7 61-,~61 ROPE LW7 G~LW7 34,933 DEVt',LW7 87.606 VDFP.LW7 6~12. ~6 SNR~LW7 -999 250 51 872 -999:~50 40.6~4 783.100 43.689 779:300 -999~250 750,600 ** E,..D OF DATA ** IS TaPe Yertftcation Listln~ cblumberger alas~a Computino Center 24-MAY-1993 ~153 PAGEI 4O **** FIbF TRAILE~ FILE NAME : EDIT ,008 V~R~ION ~ 00!~07 DAT~ : 93/05/24 ~X R~C SIZE ~ 1024 FI~ TYP~ LAST **** FILE NEADMR **** FILE NA~E ~ MDIT ,009 SERVICE t FblC V~RMIOM ~ O0!A07 D~T~ ~ 93/05/~4 ~IX REC SIZ~ : 102i FILM TYPE baST FILE CURVES Curves and lo~ header data for each pass in separate files; raw bacK,round pass in. last file DRPTH INCREMENT~ -,5000 VENDOR,,TOOL CODE START DEPTH ~b~ 10349.0 S bOG HEADER ~ATA STOP DEPTH 12037,0 DATE TI'~E bOG~R OM BOTTOM~ DEPTH CONTROL USED (YES/NO): ?oo ST ZN (TOP TO VENDOR TOOL CODE XOO5 ?YPE gLDT AUXILT,!~RY MEASUR~EM MLDT COLLAR LOCATO~ MLDT TEL~aET~Y CARTRIDGE ~LDT GAMMA RRY SONDE ~LDT COMP. FOR~AT!ON ~LDT C~MFNT BOND CARTRIDGE 08-JAM-g3 CP32,6 !2033.0 g900,0 900,0 R~$-aa-95o TCC-B-278 AH-I07, Tape verif],catlon bist~.ng ChlUmber~er AlasKa ComPuting Center 24-~AY-1993 15~5~ PAGE: 4! HbDT CEMENT BOND HbDT HLDT HI VOLTAGE HLDT HbDT CARTRIDGE HLDT ~LDT SONDE gLDT HLDT $ DRILLERS CASING DEPT~ (FT): LO~G~ CASING D~PT~ ~ORENOLE CONDITIONS FLUID TYPE: FLU!~ DENSITY SURFAC~ TFHPER~TURE (DEGF): BOTTO~ HOLE TEMPERATURE (DEGF): FLUID SALINITY (PP~): FLUID LEVEL (FT)~ FLUID ~AT~ AT WELLHEAD fBPM]: WATER CUTS (PCT)~ ~EUT~ON TOO[, TOOL TYPg (EPITHER~L O~ THERMAL): MATRIX: VATR1X DENSITY~ HOLE CORRECTION BLU~hINE COUNT RATE NORMALIZATION IM OIL ZONE TOP NOR~bIZIM~ WINDOW BA~E NORMALIZING WINDOW (FT): BLU~LINE COUNT RATE SCALES SET BY F!ELD ENGINEER FA~ COUNT RATE bOW SCALE (CPS) WAR COUNT RATE HIGM SCALE {CD8): NEAR COUNT RATE bOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE TOOL STA ~DDFF tIN): CBS-DA-160 HLDV-AA-t9 HLDC-AA-20 MLDS-BA-20 CE~C-B-756 CESS-A-763 12.250 104o1.0 i0.40 160,0 HORIZONTAL W~bb bOGGED WITH TOOI, S ON THE END OF COI~O TUBING. TIeD INTO LWD CDR UNABb~ TO REACH D~Ib[,ER$ P.BTD DUE TO cOI[~ED TUBING 8TACKING OUT 878' BEFORE TD. LI'NABbE TO DO ~FTER SU~'VEY TOOL CHECK BECAU$~ TOOL LENGTHS MADE IT I~PRACTICAL TO REMOVE LOGGING SOURCE 'WITH TOO[,, STILL COMPLECTED TO COIL HEAD. $ LIS FORMAT DATA IS Tape verification Listlnq 24-MAY-l. 993 15:5.3 PAGE! 42 cbtumberqer Al. as~a Computing Center T~BLE TYPE : CONS TUN! VALU DEr! TYPE · '''--mmmmmmm.mmm~mmmmm~m.mmm~emmmm.mmm.mmmmmm.~mmmm~m~mmmmmmm.mmmmm~mmmmmmmm ~.RC~ ~b~$~RI~C. Com~an~ Name KUP~RUK RI .. UNIT Field ame 2"-~9 Well Name FT WT ~T rT ~T ~T WT 50-103-20183 APl Serial Number ]14' rs[, & 51' FEb Field Location 28 Section 11N Township 8E Range NORTH SLOPE BOROUGH County ALASKA State or Prov~nce 1t4' FSL & 51' FEL Nation Latitude Longitude MORRI$ON Witness Name ~18976 Service Order Number MSL Permanent datum O, Elevation of Permanen ~KB Loq ~easured From 146. Above Permanent Datum 146. Elevation of Kelly 146. Elevation of Der 105 Elevatio~ of Ground D 130{5, Total Depth - Drlller 1~1~, Total Depth - 5ogqer 1-~ ~!, Bottom Log Interval 3663. TO B~I~E Dr~ 10.6 Lo 'Interval G/C3 lli~o Fluid Type_ lllno Fluid Densit nO Fluld P. ZONE S Ortlllno Fluid Vlscos ZON~ F3 ~rl nO Fluid 5Dss' ZONE OHM~ U£GF {81 Resistivity of Mu~ Sa OHM. ~ ! "ud~.Sample Temperatur DEaF ~ 8 ResiStivltv o~'~Ud Fi ......... Mud..Filt'rate Sample:~ O~ Resi. stivlt'~ o~ .ud Ca ZONE D~GF MUd...Cake 8a. mple Tempe ZONE DEaF -999.25 OEUw 140, Bottom,Hole*TemDe~atu WN APlN FL SECT TOwN Rlg~ COUN STAT NaT) bAT) LON~ WITW PDAT EGL. TOL DFT DFP~ MST R~CS MCST TABL~ TYPE TUNT BDEP TDEP DFPH DFV DFL R~CS ~CST .... 0 0 0 I ~T 0' ' ' IS Ta~'e Verification blstlnq chlumberC;er AlasKa ComputinO Center 15:53 D~FI D~PT Depth ~OP Bulk Density D~H~ Delta L$~ Lono $Dacin~ Bulk DensltV $$~u Short $~acino Bulk DemsltV CCL CCL ~mplitude ~ ~amma PAGE: 4] DATA FORMAT SPECIFICATION RECORD 0 4 66 5 66 6 73 7 65 9 65 F 36 1] 66 0 15 66 68 16 66 0 66 I ** SET TYPE - CHAM ** ...,,................................,,..-,,,-,..--.--....-....--------..---------- .... N~ , S~RV UNIT ~ERVYCE ~PI .~Pl Y II,E ~}JMB N{}~B SIZE REPR P~OCESS ID ORDER # bOG TYPE CLASS MOD NUMB SiMP EbEM CODE (HEX) D~PT FT 618976 O0 000 O0 0 9 1 I 4 68 0000000000 RHOB ~LDT G/C~ 618976 O0 000 O0 0 9 I 1 4 68 0000000000 D~HO WLDT G/C) 61R976 O0 000 O0 0 9 1 I 4 6~ 0000000000 LSR~ ~bDT G/C] 61:8976 O0 000 O0 0 9 ! I 4 68 0000000000 S~R~ ~LDT ~/C] 61~976 O0 000 O0 0 9 ~ i 4 6R 0000000000 CCh ~LDT V 61~976 O0 000 O0 0 9 ~ 1 4 68 0000000000 G~ ~UDT G~P! 61~976 O0 000 O0 0 9 ! I 4 68 0000000000 .IS ?a~e veri. f. lcation Listtn.q ;chlumberoer Rlas.~a Com..mutin0 Center DEPT. 12036,500 RHOB.HLDT $$~W.HLDT -999.250 CCL.HLDT D~PT 12000.000 $SRU~HbDT 3'969 CCL.HbOT DEPT 11800.000 SSDH;HL~T 3.569 CCL.~LDT D~T. 11000.000 RHDB.HLDT S~H.HLDT 3.876 CC5,HLDT D~PT I080~ 000 RHOB.HLDT D °T 1.0.400.000 SS~:HLD? 4,650 CCL.HLDT D~PT 10349,500 RH08.HLDT . . 24-~AY-1993 15:~3 -999.250 DRHO.HLDT -999.250 2.319 DRHOeWLDT -0 518 -0.096 G~.HLD~ 31:813 2.386 DRH0.HLDT -0.324 -o. 33 ]8.875 2.429 D~HO.HLDT -0.370 -0.144 ~.HLDT 48.500 2.429 D~HO,HLDT -0.365 -0,11] GR,HLDT 48.875 2.36{ DPHO,HLDT 0,387 2.396 DRH0 HLDT -0.340 2,606 DR~O,HLDT -0,264 -0,11] OR,~LDT 46..81] -999.250 DRH0,HLDT -999'~250 -0.1SO ~.HLST 44,000 LSRH.HLDT LSRH.HLDT L$~H.HLDT LSRH.HLDT LSPH.H/.DT LSRH.HLDT LSRH.HLDT LSRH,HLDT LSRH.HbDT LS~H,HLDT LSRH,HLDT PAGE: 44 -999.250 2.837 2.710 2,799 2.794 2.748 2,860 2,736 2.871 3,335 ~'999,250 NA~E I EDIT ,009 $~VICE { 'FI, lC V~SIO~ ~ OOIA07 D. T'F { 93/05/24 ~AX ~EC~$IZ~ { !.024 I8 ?a~e Verification bistinq chlumberoer A!asKa Comput.~_nq Center PAGEI 45 **** TAPE TRAIb5~ **** S~RVICE NA~E DAT~ T~PF NAME : g2~62 CONTINUATIO~ # : 1 PREVIOUS TAPE CO~MEWT **** RMEb TRAI[,E~ **** $~RV!CF N~MM : EDIT D~TF : 9]/05/24 O~IGIN ~ R~EL NA~E : 9~662 CONTINUAT[OM # ~ P~EVIOUS REMb COMMENT ~ ~RCO AbASKA, INC,,~UPARUK RIVER