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Home My WebLink About195-1401. 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 9514'feet 9210'feet true vertical 6949' feet None feet Effective Depth measured 9210'feet 8241', 8349'feet true vertical 6693'feet 5943', 6023'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth)2-7/8" 3-1/2" L-80 L-80 8317' 8349' 5998' 6023' Packers and SSSV (type, measured and true vertical depth)8241' 8349' 5943' 6023' 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: 8925-8960', 9180-9205' 6466-6492', 6667-6689' 4957'3873' 16" 7-5/8" Burst Collapse Production Liner 2290' 8534' Casing 2203' 6195' 2325' 8569' 9514'6949' 4916' 121'Conductor Surface Tie Back String 79' measured TVD 5-1/2" 5-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 195-140 50-029-225950-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0025634, ADL0025641 Kuparuk River Field/ Kuparuk Oil Pool KRU 1Q-22 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) N/A Gas-Mcf MDSize 121' Well Shut-In 325-292 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: DLH TriPoint Retrievable Packer: Baker SABL-3 Permanent SSSV: None Cy Eller cy.eller@conocophillips.com (907) 265-6049CTD/RWO Engineer 1165'3-1/2" Fra O s 6. A PG , C g Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 9:26 am, Jul 11, 2025 DSR-7/21/25JJL 7/21/25 RBDMS JSB 071725 Page 1/10 1Q-22 Report Printed: 7/10/2025 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) 6/2/2025 03:00 6/2/2025 04:00 1.00 MIRU, MOVE MOB P Rig down U-tube equipment // Prep to pull off well. 0.0 0.0 6/2/2025 04:00 6/2/2025 09:30 5.50 MIRU, MOVE MOB P Pull rig off well spot on pad // clean cellar. Call out roads & pads to level pad in front of well. Set up mats on 1Q- 22. 0.0 0.0 6/2/2025 09:30 6/2/2025 11:00 1.50 MIRU, MOVE MOB P Pull sub over well. Shim & level rig. Berm in rig. 0.0 0.0 6/2/2025 11:00 6/2/2025 12:00 1.00 MIRU, MOVE MOB P Spot auxillary equipment. Berm in rig. Complete acceptance checklist. RIg accepted @ 12:00 Hrs. 0.0 0.0 6/2/2025 12:00 6/2/2025 14:30 2.50 MIRU, WELCTL RURD P Take on seawater. Build heated deep clean pill. R/U circ equipment. 0.0 0.0 6/2/2025 14:30 6/2/2025 15:00 0.50 MIRU, WELCTL PRTS P PT circ equipment & hard line T/ 2500 PSI. 0.0 0.0 6/2/2025 15:00 6/2/2025 15:30 0.50 MIRU, WELCTL SFTY P PJSM on well kill. 0.0 0.0 6/2/2025 15:30 6/2/2025 17:30 2.00 MIRU, WELCTL KLWL P Bleed free gas off TBG & IA. Kill well w/ 32 Bbls heated deep clean pill followed by 228 Bbls seawater @ 3 BPM, 1160 PSI. 0.0 0.0 6/2/2025 17:30 6/2/2025 18:00 0.50 MIRU, WELCTL OWFF P OWFF at well head no flow observed 0.0 0.0 6/2/2025 18:00 6/2/2025 20:00 2.00 MIRU, WHDBOP NUND P Set BPV, PT from below to 1000 PSI for 10 min. Good test, ND production tree, inspect hanger threads 7.75 turns 0.0 0.0 6/2/2025 20:00 6/2/2025 22:30 2.50 MIRU, WHDBOP NUND P Install blanking plug and nipple up BOPs // install flow riser 0.0 0.0 6/2/2025 22:30 6/3/2025 00:00 1.50 MIRU, WHDBOP RURD P Rig up test equipment // Grease valves for BOP test 0.0 0.0 6/3/2025 00:00 6/3/2025 01:00 1.00 MIRU, WHDBOP RURD P Flood stack, get RKBs, shell test stack 250/3000 0.0 0.0 6/3/2025 01:00 6/3/2025 05:30 4.50 MIRU, WHDBOP BOPE P Initial BOPE test to 250/3000 PSI for 5 Min each, Tested UVBR's & annular on 2-7/8" X 5 1/2 test joints. Test blind rams, .Choke valves #1 to #13, upper and lower top drive well control valves. Test 3 1/2" IF & 2-7/8" HT-PAC FOSV & IBOP. Test 3 1/2" EUE FOSV. Test rig floor Demco kill valve MM #13. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure = 3000 PSI, after closure = 1750 PSI, 200 PSI attained = 25 sec, full recovery attained = 107 sec. UVBR's = 5 sec,. Annular = 17 sec. Simulated blinds = 5 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average = 2000 PSI. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Adam Earl. 0.0 0.0 6/3/2025 05:30 6/3/2025 06:30 1.00 MIRU, WHDBOP RURD P B/D, R/D testing equipment. Install mouse hole. 0.0 0.0 6/3/2025 06:30 6/3/2025 07:00 0.50 MIRU, WHDBOP MPSP P Pull blanking plug & BPV. 0.0 0.0 6/3/2025 07:00 6/3/2025 08:15 1.25 COMPZN, RPCOMP RURD P Shuffle 18 stand of 3 1/2" DP from ODS T/ DS. Change elevators. M/U landing joint. K/U, set 10K down. BOLDS. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 6/14/2025 Page 2/10 1Q-22 Report Printed: 7/10/2025 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) 6/3/2025 08:15 6/3/2025 08:30 0.25 COMPZN, RPCOMP PULL P Pull hanger T/ RF. Hanger of seat @ 75K. Pipe free @ 105K. PUW=101. Pull cut F/ 8310' T/ 8277' 8,310.0 8,277.0 6/3/2025 08:30 6/3/2025 09:15 0.75 COMPZN, RPCOMP CIRC P Circ STS @ 5 BPM, 2000 PSI. Over boarding contaminated fluid. 8,277.0 8,277.0 6/3/2025 09:15 6/3/2025 09:30 0.25 COMPZN, RPCOMP OWFF P OWFF 8,277.0 8,277.0 6/3/2025 09:30 6/3/2025 10:00 0.50 COMPZN, RPCOMP PULD P L/D landing joint & hanger. 8,277.0 8,277.0 6/3/2025 10:00 6/3/2025 12:00 2.00 COMPZN, RPCOMP PUTB P Pull 3 1/2" completion racking back in derrick F/ 8277' T/ 4987'. PUW=101K 8,277.0 4,987.0 6/3/2025 12:00 6/3/2025 15:30 3.50 COMPZN, RPCOMP PULL P L/D 3 1/2" completion F/ 4987' T/ surface. PUW=73K. L/D 258 joints & clean cut. 14.28' OAL. 4,987.0 0.0 6/3/2025 15:30 6/3/2025 16:00 0.50 COMPZN, RPCOMP CLEN P Clean & clear RF & pipe shed. 0.0 0.0 6/3/2025 16:00 6/3/2025 16:30 0.50 COMPZN, RPCOMP RURD P Install wear bushing. 6 9/16" ID 0.0 0.0 6/3/2025 16:30 6/3/2025 18:30 2.00 COMPZN, RPCOMP RURD P Mobilize 2 7/8" handling equipment & BHA #1 T/ RF & pipe shed. 0.0 0.0 6/3/2025 18:30 6/3/2025 20:00 1.50 COMPZN, RPCOMP BHAH P Pick up BHA# 1 ----5.5" drift assembly 0.0 260.0 6/3/2025 20:00 6/4/2025 00:00 4.00 COMPZN, RPCOMP PUTB P RIH w/ BHA# 1 on singles 2-7/8" HT- Pac drill pipe 260.0 2,900.0 6/4/2025 00:00 6/4/2025 05:15 5.25 COMPZN, RPCOMP PUTB P RIH w/ BHA# 1 on singles 2-7/8" HT- Pac drill pipe T/ 8300'. PUW=113K, SOW=80K. 2,900.0 8,300.0 6/4/2025 05:15 6/4/2025 05:30 0.25 COMPZN, RPCOMP WASH P Obtaned parameters, pump @ 1 BPM, 252 PSI. Rot @ 20 RPM, 2K Free Tq. ROT=95K. Wash & ream down. Saw PSI increase as bull nose stacke out on stump. P/U kill rotarty. Wash down PSI increase set 5K down @ 8305'. P/U off stump T/ 8301' 8,300.0 8,301.0 6/4/2025 05:30 6/4/2025 06:45 1.25 COMPZN, RPCOMP CIRC P Circ hi-vis pill around @ 4 BPM, 2450 PSI. 8,301.0 8,301.0 6/4/2025 06:45 6/4/2025 07:15 0.50 COMPZN, RPCOMP OWFF P OWFF. B/D TD. 8,301.0 8,301.0 6/4/2025 07:15 6/4/2025 11:00 3.75 COMPZN, RPCOMP TRIP P TOOH F/ 8301' T/ 207'. PUW=113K. 8,301.0 207.0 6/4/2025 11:00 6/4/2025 12:00 1.00 COMPZN, RPCOMP BHAH P L/D BHA #1 F/ 207'. PUW=39K. 207.0 0.0 6/4/2025 12:00 6/4/2025 12:15 0.25 COMPZN, RPCOMP CLEN P Clean & clear RF. 0.0 0.0 6/4/2025 12:15 6/4/2025 12:30 0.25 COMPZN, RPCOMP SFTY P PJSM w/ AK E-Line & rig crew on R/U run E-Line. 0.0 0.0 6/4/2025 12:30 6/4/2025 13:00 0.50 COMPZN, RPCOMP ELNE P R/U E-Line & CBL tool string 0.0 0.0 6/4/2025 13:00 6/4/2025 14:15 1.25 COMPZN, RPCOMP ELOG P RIH w/ CCL, CBL, GR tool sting T/ 2600'. Stabilizer collapsed. POOH. 0.0 0.0 6/4/2025 14:15 6/4/2025 14:30 0.25 COMPZN, RPCOMP ELNE P Tighten up centralizer & add 1 more centralizer to tool string. 0.0 0.0 6/4/2025 14:30 6/4/2025 18:00 3.50 COMPZN, RPCOMP ELOG P TIH w/ CCL, CBD & GR tool sting T/ 5000'. Log to surface. // Rig down E- line 0.0 0.0 6/4/2025 18:00 6/4/2025 18:30 0.50 COMPZN, RPCOMP CLEN P Clean and clear rig floor for picking up BHA 0.0 0.0 6/4/2025 18:30 6/4/2025 19:30 1.00 COMPZN, RPCOMP BHAH T Pick up BHA# 2 G-lock 0.0 45.0 6/4/2025 19:30 6/4/2025 21:30 2.00 COMPZN, RPCOMP TRIP P TIH on stands 3.5" EUE tubing 45.0 3,250.0 Rig: NORDIC 3 RIG RELEASE DATE 6/14/2025 Page 3/10 1Q-22 Report Printed: 7/10/2025 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) 6/4/2025 21:30 6/4/2025 22:30 1.00 COMPZN, RPCOMP MPSP T Attempt to set plug @ 3300' and 3280' unable to set plug, TOOH to inspect 3,250.0 3,250.0 6/4/2025 22:30 6/5/2025 00:00 1.50 COMPZN, RPCOMP TRIP T TOOH to inspect G-plug 3,250.0 2,900.0 6/5/2025 00:00 6/5/2025 01:00 1.00 COMPZN, RPCOMP TRIP T TOOH to inspect BHA# 2 2,900.0 45.0 6/5/2025 01:00 6/5/2025 02:00 1.00 COMPZN, RPCOMP BHAH T Inspect BHA found key way in top of tool not engaged, reconfigure tool and test set and tool not spinning freely 45.0 0.0 6/5/2025 02:00 6/5/2025 04:00 2.00 COMPZN, RPCOMP WAIT T Wait for plug to mobilize from Baker Deadhorse 0.0 0.0 6/5/2025 04:00 6/5/2025 04:45 0.75 COMPZN, RPCOMP BHAH T Pick up BHA# 3, WRBP ( ball set w/ 1- 1/8" ) 0.0 46.0 6/5/2025 04:45 6/5/2025 07:00 2.25 COMPZN, RPCOMP TRIP T TIH w/ BHA# 3 T/ 2484'. PUW=53K, SOW=53K. 46.0 2,484.0 6/5/2025 07:00 6/5/2025 07:30 0.50 COMPZN, RPCOMP CIRC P Circ STB @ 1 BPM, 80 PSI, 2 BPM, 220 PSI. 2,484.0 2,484.0 6/5/2025 07:30 6/5/2025 08:15 0.75 COMPZN, RPCOMP MPSP P P/UI / 2882'. Drop 1 7/16" setting ball. Pump ball on seat @ 2 BPM, 120 PSI. Caught PSI @ 10 Bbls. Pressure up set WRBP @ 2480' COE. Top @ 2478'.. Shear off @ 3130 PSI. P/U T/ 2470' S/O set 5K down tag on depth. P/T T/ 2475' verify circ @ 1 BPM, 80 PSI. K/D B/D TD. 2,484.0 2,482.0 6/5/2025 08:15 6/5/2025 09:15 1.00 COMPZN, RPCOMP TRIP P TOOH F/ 2478' T/ 41'. PUW=53K. 2,482.0 41.0 6/5/2025 09:15 6/5/2025 09:45 0.50 COMPZN, RPCOMP BHAH P L/D BHA #3. 41.0 0.0 6/5/2025 09:45 6/5/2025 10:00 0.25 COMPZN, RPCOMP RURD P R/U testing equipment. 0.0 0.0 6/5/2025 10:00 6/5/2025 10:15 0.25 COMPZN, RPCOMP PRTS P PT WRBP T/ 1000 PSI, for 10 Min. 0.0 0.0 6/5/2025 10:15 6/5/2025 10:30 0.25 COMPZN, RPCOMP RURD P B/D, R/D testing equipment. 0.0 0.0 6/5/2025 10:30 6/5/2025 10:45 0.25 COMPZN, RPCOMP BHAH P M/U BHA #4 mule shoe T/ 38'. 0.0 38.0 6/5/2025 10:45 6/5/2025 11:45 1.00 COMPZN, RPCOMP TRIP P TIH F/ 38' T/ 2381'. PUW=53K, SOW=53K 38.0 2,381.0 6/5/2025 11:45 6/5/2025 12:00 0.25 COMPZN, RPCOMP RURD P R/U circ equipment to feed sand hopper and pull fluid from IA. 2,381.0 2,381.0 6/5/2025 12:00 6/5/2025 18:00 6.00 COMPZN, RPCOMP CIRC P Dump 12 sacks of sand down 3 1/2" EUE tubing. Tag sand 2433' 2,381.0 2,381.0 6/5/2025 18:00 6/5/2025 22:30 4.50 COMPZN, RPCOMP PULL P Lay down 35 stands 3.5" EUE completion tubing 2,381.0 0.0 6/5/2025 22:30 6/6/2025 00:00 1.50 COMPZN, WELLPR NUND P Nipple down BOPs 0.0 0.0 6/6/2025 00:00 6/6/2025 03:30 3.50 COMPZN, WELLPR CUTP P Grow and stretch casing No grow spear casing pull 140K, CSG free. Total grow and stretch 16.25". Re-land in emergency slips. Cut of excess CSG & pack off w/ saw-zaw. 0.0 0.0 6/6/2025 03:30 6/6/2025 05:30 2.00 COMPZN, WELLPR NUND P Nipple up DSA to casing head, nipple up BOPs 0.0 0.0 6/6/2025 05:30 6/6/2025 06:00 0.50 COMPZN, WELLPR PRTS P PT ring groves through external port on DSA. 3000 PSI lower flange. 5000 PSI upper flange for 10 Min each. 0.0 0.0 6/6/2025 06:00 6/6/2025 06:45 0.75 COMPZN, WELLPR NUND P Install flow nipple. R/U trip hose. 0.0 0.0 6/6/2025 06:45 6/6/2025 07:15 0.50 COMPZN, RPCOMP BHAH T M/U BHA #6 MSC T/ 9' 0.0 9.0 Rig: NORDIC 3 RIG RELEASE DATE 6/14/2025 Page 4/10 1Q-22 Report Printed: 7/10/2025 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) 6/6/2025 07:15 6/6/2025 09:30 2.25 COMPZN, RPCOMP TRIP T TIH on 2 7/8" HT Pac DP T/ 2328'. PUW=56K, SOW=55K. 9.0 2,328.0 6/6/2025 09:30 6/6/2025 10:30 1.00 COMPZN, RPCOMP CIRC T Obtain parameters pumping 100 PSI @ 1 BPM, 200 PSI @ 1.5 BPM, 300 PSI @ 2 BPM. 450 PSI @ 2.5 BPM. 600 PSI @ 3 BPM. Wash in hole 2320' T/ 2380' @ 1.5 BPM - 3 BPM. Attempting to locate collar. Unsuccessful in locating collar. 2,380.0 2,380.0 6/6/2025 10:30 6/6/2025 11:00 0.50 COMPZN, RPCOMP PULD T Rack back a stand, P/U working single. RIH T/ 2325'. 2,380.0 2,325.0 6/6/2025 11:00 6/6/2025 12:00 1.00 COMPZN, RPCOMP CPBO T Attempt to cut 5 1/2": CSG @ 5 BPM, 1530 PSI. Rotate @ 80 RPM, .8K Free Tq. ROT=55K. Never saw any torque increase. Cutter is not responding correctly. Call out new cutter from Deadhorse. 2,325.0 2,325.0 6/6/2025 12:00 6/6/2025 12:30 0.50 COMPZN, RPCOMP OWFF T L/D working single T/ 2294'. B/D TD. OWFF. Crew change out. 2,325.0 2,294.0 6/6/2025 12:30 6/6/2025 13:30 1.00 COMPZN, RPCOMP TRIP T TOOU F/ 2294' T/ 9'. PUW=56K, 2,294.0 9.0 6/6/2025 13:30 6/6/2025 14:00 0.50 COMPZN, RPCOMP BHAH T L/D BHA #6. Inspect MSC. Flow tail stuck inside piston. 9.0 0.0 6/6/2025 14:00 6/6/2025 15:00 1.00 COMPZN, RPCOMP WAIT T Mobilize new MSC from Deadhorse. 0.0 0.0 6/6/2025 15:00 6/6/2025 15:30 0.50 COMPZN, RPCOMP BHAH P M/U BHA #7 MSC T/ 41'. Function MSC in BOP stack. Good function. 0.0 41.0 6/6/2025 15:30 6/6/2025 17:30 2.00 COMPZN, RPCOMP TRIP P TIH on 2 7/8" HT Pac DP T/ 2,200' 41.0 2,200.0 6/6/2025 17:30 6/6/2025 18:30 1.00 COMPZN, RPCOMP CPBO P Pump 500 psi down drill pipe, locate collar @ 2,241', rack back stand of drill pipe, pick up working single, perform cut @ 2,221' Pump 3.5 bpm @ 950 psi, TQ 950 ft/lbs Posative indicator of cut flow our OA 2,200.0 2,320.0 6/6/2025 18:30 6/6/2025 20:00 1.50 COMPZN, RPCOMP CIRC P Circulate 120 bbls 140° water followed by seawater // Pump 4 bpm @ 1229 psi 2,320.0 2,320.0 6/6/2025 20:00 6/6/2025 21:30 1.50 COMPZN, RPCOMP TRIP P TOOH with MSC BHA# 7 2,320.0 0.0 6/6/2025 21:30 6/6/2025 22:00 0.50 COMPZN, RPCOMP OWFF P Flow check well at OA 0.0 0.0 6/6/2025 22:00 6/6/2025 22:30 0.50 COMPZN, RPCOMP FISH P Pick up BHA# 8 5.5" fishing spear, spear 5.5" casing, pick up 5' ensure pipe free 2,320.0 2,315.0 6/6/2025 22:30 6/7/2025 00:00 1.50 COMPZN, RPCOMP NUND P Nipple down DSA to pull slips from 5.5" casing 2,315.0 2,315.0 6/7/2025 00:00 6/7/2025 01:00 1.00 COMPZN, RPCOMP NUND P Nipple up BOPs DSA test 3000 psi 10 min 2,320.0 2,320.0 6/7/2025 01:00 6/7/2025 04:45 3.75 COMPZN, RPCOMP PULL P Pull 5.5" casing from cut @ 2,321' // Initial pick up wt 69k // 52 Jts pulled 22.06' Cut Jt // 12 Centralizers recovered 2,320.0 0.0 6/7/2025 04:45 6/7/2025 06:45 2.00 COMPZN, RPCOMP CLEN P Clean and clear rig floor // Rig down tubing equipment rig up to run drill pipe 0.0 0.0 6/7/2025 06:45 6/7/2025 07:15 0.50 COMPZN, RPCOMP MPSP P Set test plug. 0.0 0.0 6/7/2025 07:15 6/7/2025 07:45 0.50 COMPZN, RPCOMP RURD P R/U testing equipment. FIll stack w/ fresh water. 0.0 0.0 6/7/2025 07:45 6/7/2025 08:15 0.50 COMPZN, RPCOMP PRTS P PT stack breaks 250/2500 PSI. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 6/14/2025 Page 5/10 1Q-22 Report Printed: 7/10/2025 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) 6/7/2025 08:15 6/7/2025 10:00 1.75 COMPZN, RPCOMP RURD P B/D, R/D testing equipment. Install wear bushing. C/O LDS. Mobilize BHA #9 to pipe shed. 0.0 0.0 6/7/2025 10:00 6/7/2025 11:30 1.50 COMPZN, RPCOMP BHAH P M/U BHA #9 clean out run w/ tandem 6.75" sting mill T/ 132', SOW=40K 0.0 132.0 6/7/2025 11:30 6/7/2025 12:45 1.25 COMPZN, RPCOMP TRIP P TIH F/ 132' T/ 2265'. PUW=70K, SOW=65K. 132.0 2,265.0 6/7/2025 12:45 6/7/2025 13:00 0.25 COMPZN, RPCOMP WASH P Wash in hole F/ 2265' @ 3 BPM, 160 PSI. inside CSG stub @ 2321'. 2,265.0 2,321.0 6/7/2025 13:00 6/7/2025 13:30 0.50 COMPZN, RPCOMP DISP P Displace well to vis seawater @ 4 BPM, 230 PSI. 2,321.0 2,320.0 6/7/2025 13:30 6/7/2025 14:00 0.50 COMPZN, RPCOMP RURD P Drain trip tank. Refill w/ vis seawater. 2,320.0 2,320.0 6/7/2025 14:00 6/7/2025 14:15 0.25 COMPZN, RPCOMP OWFF P P/U T/ 2262'. B/D TD. OWFF. 2,320.0 2,262.0 6/7/2025 14:15 6/7/2025 15:00 0.75 COMPZN, RPCOMP TRIP P TOOH F/ 2262' T/ 132'. PUW=70K. 2,262.0 132.0 6/7/2025 15:00 6/7/2025 15:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA #9, PUW=40K. 132.0 0.0 6/7/2025 15:30 6/7/2025 16:00 0.50 COMPZN, RPCOMP BHAH P M/U BHA #10 Dress off shoe T/ 143' SOW=40K. 0.0 143.0 6/7/2025 16:00 6/7/2025 17:30 1.50 COMPZN, RPCOMP TRIP P TIH w/ BHA# 10 to top of cut @ 2,321' 143.0 2,321.0 6/7/2025 17:30 6/7/2025 18:30 1.00 COMPZN, RPCOMP MILL P Mill top of casing to 2,322' 2,321.0 2,322.0 6/7/2025 18:30 6/7/2025 20:30 2.00 COMPZN, RPCOMP SLPC P Slip and cut drill line 2,322.0 2,320.0 6/7/2025 20:30 6/8/2025 00:00 3.50 COMPZN, RPCOMP PULD P TOOH laying down drill pipe 2,320.0 700.0 6/8/2025 00:00 6/8/2025 00:45 0.75 COMPZN, RPCOMP PULD P Complete laying down drill pipe 700.0 0.0 6/8/2025 00:45 6/8/2025 02:00 1.25 COMPZN, RPCOMP CLEN P Clean and clear rig floor, clear pipe shed of tools and drill pipe 0.0 0.0 6/8/2025 02:00 6/8/2025 02:30 0.50 COMPZN, RPCOMP OTHR P Pull wear ring 0.0 0.0 6/8/2025 02:30 6/8/2025 03:00 0.50 COMPZN, RPCOMP SFTY P PJSM for running 5.5" HYD 563 casing 0.0 0.0 6/8/2025 03:00 6/8/2025 06:30 3.50 COMPZN, RPCOMP PUTB P Run 5 1/2", 15.5#, L-80, Hyd 563 Tie back string T/ 2313', PUW=68K, SOW=64K. 0.0 2,313.0 6/8/2025 06:30 6/8/2025 07:00 0.50 COMPZN, RPCOMP WASH P Wash casing patch in hole F/ 2313 T/ 2322' @ 2.5 BPM, 140 PSI. Pressure increase T/ 500 PSI @ 2322'. Kill pump swallow CSG stub T/ 2325'. Set down 25K. Pull test 50K over string weight. 2,313.0 2,325.0 6/8/2025 07:00 6/8/2025 07:30 0.50 COMPZN, RPCOMP RURD P B/D TD. R/U testing equipment on 5 1/2" CSG. 2,325.0 2,325.0 6/8/2025 07:30 6/8/2025 08:45 1.25 COMPZN, RPCOMP PRTS P PT 5 1/2" CSG patch T/ 1000 PSI for 10 Min. T/ 1500 PSI for 10 Min. T/ 2000 PSI for 10 Min. 2,325.0 2,325.0 6/8/2025 08:45 6/8/2025 09:15 0.50 COMPZN, RPCOMP RURD P R/D testing equipment. Suck stack out. 2,325.0 2,325.0 6/8/2025 09:15 6/8/2025 10:30 1.25 COMPZN, RPCOMP NUND P Split BOP stack. Lift stack up. Set emergency slips w/ 50 tension. N/U BOP stack. 2,325.0 2,325.0 6/8/2025 10:30 6/8/2025 10:45 0.25 COMPZN, RPCOMP PRTS P PT 11" 3K flange break externally through DSA port T/ 3000 PSI. 2,325.0 2,325.0 6/8/2025 10:45 6/8/2025 11:45 1.00 COMPZN, RPCOMP RURD P Spot & R/U HES cement van. Stage vac trucks & super sucker. Load closing plug in cement head. R/U cement head & hose. R/U hard iron to cement line. 2,325.0 2,325.0 Rig: NORDIC 3 RIG RELEASE DATE 6/14/2025 Page 6/10 1Q-22 Report Printed: 7/10/2025 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) 6/8/2025 11:45 6/8/2025 12:00 0.25 COMPZN, RPCOMP SFTY P PJSM w/ HES & rig crew on cementing tie back CSG T/ surface. 2,325.0 2,325.0 6/8/2025 12:00 6/8/2025 12:15 0.25 COMPZN, RPCOMP PRTS P Flood lines. PT cement equipment T/ 500/3500 PSI. Blow back to cement van. 2,325.0 2,325.0 6/8/2025 12:15 6/8/2025 13:15 1.00 COMPZN, RPCOMP CIRC P R/U hot water to mud pumps. Pressure up pop cementer open @ 2600 PSI. Circ 100 Bbls 140* fresh water @ 4 BPM, 520 PSI. 2,325.0 2,325.0 6/8/2025 13:15 6/8/2025 14:45 1.50 COMPZN, RPCOMP CMNT P HES pump 10 Bbls fresh water w/ red die @ 3 BPM, 350 PSI. Cement wet @ 13:22 Hrs. Pump 108 Bbls 15.8 PPG cement @ 3 BPM, 600 PSI. Pump 10 Bbls fresh water. Drop closing plug. Rig displace w/ 8.5 PPG vis seawater @ 3 BPM, ICP=1475. @ 40 Bbls reduced rate T/ 1.5 BPM. Plug bumped on time 771 strokes. FCP=750. Pressure up T/ 2700 PSI shift cementer closed. Hold 2600 PSI for 5 Min. Open up verify cementer is holding in closed position. Cement in place @14:33 Hrs. 35 Bbls 15.8 PPG returned T/ surface. 2,325.0 2,325.0 6/8/2025 14:45 6/8/2025 16:45 2.00 COMPZN, RPCOMP RURD P B/D R/D cement line. Flush return line w/ contam pill out to cuttings tank, open top tank & tiger tank. R/D cement head. Suck out stack. Rinse stack w/ contam pill. Clean all dead legs on cement line & return lines. 2,325.0 0.0 6/8/2025 16:45 6/8/2025 19:45 3.00 COMPZN, RPCOMP WOC P Wait on cement 100 psi compressive strength 0.0 0.0 6/8/2025 19:45 6/8/2025 21:30 1.75 COMPZN, RPCOMP NUND P Nipple down stack from casing head for cutting casing 0.0 0.0 6/8/2025 21:30 6/9/2025 00:00 2.50 COMPZN, RPCOMP CUTP P Cut casing and bevel , install pack off , instal 11 3k adaper , Cut 17.26' of joint 55 0.0 0.0 6/9/2025 00:00 6/9/2025 01:00 1.00 COMPZN, RPCOMP NUND P Install tubing head and test 3000 psi on void 0.0 0.0 6/9/2025 01:00 6/9/2025 04:00 3.00 COMPZN, RPCOMP NUND P Nipple up BOPs // Check lower pipe rams // get RKBs // Make up all lines in cellar 0.0 0.0 6/9/2025 04:00 6/9/2025 05:00 1.00 COMPZN, RPCOMP CLEN P Check lower ram cavities for cement 0.0 0.0 6/9/2025 05:00 6/9/2025 05:30 0.50 COMPZN, RPCOMP RURD P R/U testing equipment. Fill stack w/ fresh water. 0.0 0.0 6/9/2025 05:30 6/9/2025 06:00 0.50 COMPZN, RPCOMP PRTS P PT stack breaks & lower door seals T/ 250/3000 PSI. 0.0 0.0 6/9/2025 06:00 6/9/2025 06:30 0.50 COMPZN, RPCOMP RURD P B/D, R/D testing equipment. 0.0 0.0 6/9/2025 06:30 6/9/2025 07:00 0.50 COMPZN, RPCOMP RURD P Pull test plug. Install wear bushing. 0.0 0.0 6/9/2025 07:00 6/9/2025 08:15 1.25 COMPZN, RPCOMP BHAH P M/U BHA #11 mill out T/ 213'. SOW=35K 0.0 213.0 6/9/2025 08:15 6/9/2025 08:45 0.50 COMPZN, RPCOMP TRIP P TIH F/ 213' T/ 677'. SOW=40K. 213.0 677.0 6/9/2025 08:45 6/9/2025 09:00 0.25 COMPZN, RPCOMP SFTY P Clear ice from derrick. 677.0 677.0 6/9/2025 09:00 6/9/2025 10:00 1.00 COMPZN, RPCOMP TRIP P TIH F/ 677' T/ 2253', Took 3K string weight. PUW=57K, SOW=55K. 677.0 2,248.0 Rig: NORDIC 3 RIG RELEASE DATE 6/14/2025 Page 7/10 1Q-22 Report Printed: 7/10/2025 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) 6/9/2025 10:00 6/9/2025 18:00 8.00 COMPZN, RPCOMP MILL P Obtain parameters pump @ 3.5 BPM, 590 PSI. Rot @ 80 RPM, .8K free Tq. ROT=56K. Wash & ream through green cement. Mill plug @ 2301', Tq= 1.2- 1.6K. WOB= 2-5K. Mill up hard cement F/ 2336' T/2,419' at 100 RPM 6- 8K WOB Dry drill on sand 20 min 2,248.0 2,419.0 6/9/2025 18:00 6/9/2025 19:30 1.50 COMPZN, RPCOMP CIRC P Pump 35 bble sweep circulate well clean 2,419.0 2,409.0 6/9/2025 19:30 6/9/2025 21:00 1.50 COMPZN, RPCOMP TRIP P TOOH for RCJB 2,409.0 240.0 6/9/2025 21:00 6/9/2025 22:00 1.00 COMPZN, RPCOMP BHAH P Lay down BHA# 11, Mill out assembly // Mill OD 4.75" small chunks of metal debris recovered in boot basket 240.0 0.0 6/9/2025 22:00 6/9/2025 23:00 1.00 COMPZN, RPCOMP BHAH P Pick up BHA# 12 RCJB 0.0 205.0 6/9/2025 23:00 6/10/2025 00:00 1.00 COMPZN, RPCOMP TRIP P TIH w/ RCJB TIH T/ 1700 Up wt 58 Dn Wt 55 205.0 1,700.0 6/10/2025 00:00 6/10/2025 01:00 1.00 COMPZN, RPCOMP TRIP P TIH w/ RCJB TIH T/ 2415 Up wt 58 Dn Wt 55 1,700.0 2,415.0 6/10/2025 01:00 6/10/2025 02:00 1.00 COMPZN, RPCOMP WASH P Circulate 3.5 bpm @ 2000 psi // Rot 55 rpm @ 1061 ft/lbs // Tag sand @ 2421' // Wash down T/ 2428' 2,415.0 2,428.0 6/10/2025 02:00 6/10/2025 03:30 1.50 COMPZN, RPCOMP TRIP P OWFF // Blow down TD // Trip out of hole to inspect RCJB 2,428.0 204.0 6/10/2025 03:30 6/10/2025 04:15 0.75 COMPZN, RPCOMP BHAH P Rack collars, break down RCJB, two small cunks of aluminum and cement in basket Function test BOP 204.0 0.0 6/10/2025 04:15 6/10/2025 05:00 0.75 COMPZN, RPCOMP BHAH P Make up BHA #13 0.0 0.0 6/10/2025 05:00 6/10/2025 07:00 2.00 COMPZN, RPCOMP TRIP P Trip in hole to 2,424' 60K UP 55K DN 0.0 2,424.0 6/10/2025 07:00 6/10/2025 09:00 2.00 COMPZN, RPCOMP WASH P Wash down F/2,424' T/2,479' at 5 BPM 1311 PSI Tag up with 3K down on WRBP Pump 20 BBLS Hi Vis sweep, circulate until casing clean 2,424.0 2,479.0 6/10/2025 09:00 6/10/2025 09:30 0.50 COMPZN, RPCOMP OWFF P Flow check, blow down top drive 2,479.0 2,479.0 6/10/2025 09:30 6/10/2025 11:00 1.50 COMPZN, RPCOMP TRIP P Trip out of hole F/2,479' T/208' 2,479.0 208.0 6/10/2025 11:00 6/10/2025 12:15 1.25 COMPZN, RPCOMP BHAH P Lay down BHA #13, inspect RCJB 208.0 0.0 6/10/2025 12:15 6/10/2025 12:45 0.50 COMPZN, RPCOMP BHAH P Make up BHA #14 WRBP retrieving tool to 36' 0.0 36.0 6/10/2025 12:45 6/10/2025 14:30 1.75 COMPZN, RPCOMP TRIP P Trip in hole F/36' T/2,474' 57K UP 52K DN 36.0 2,474.0 6/10/2025 14:30 6/10/2025 15:15 0.75 COMPZN, RPCOMP DISP P Dispalce well to neat seawater at 4 BPM 640 PSI 2,474.0 2,474.0 6/10/2025 15:15 6/10/2025 15:30 0.25 COMPZN, RPCOMP MPSP P Retrieve WRBP as per Baker Set down 5K at 2,480' Pick up release WRBP, slack off to 2,483' 2,474.0 2,483.0 6/10/2025 15:30 6/10/2025 16:15 0.75 COMPZN, RPCOMP CIRC P Circulate casing clean, pump 20 BBL Hi vis sweep at 4 BPM 2,483.0 2,483.0 6/10/2025 16:15 6/10/2025 16:45 0.50 COMPZN, RPCOMP OWFF P Flow check, blow down top drive, let elements on WRBP relax 2,483.0 2,483.0 Rig: NORDIC 3 RIG RELEASE DATE 6/14/2025 Page 8/10 1Q-22 Report Printed: 7/10/2025 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) 6/10/2025 16:45 6/10/2025 18:30 1.75 COMPZN, RPCOMP TRIP P Trip out F/2,483' T/ 40' 2,483.0 40.0 6/10/2025 18:30 6/10/2025 19:00 0.50 COMPZN, RPCOMP BHAH P Lay down BHA #15 RBP from 2477" 40.0 0.0 6/10/2025 19:00 6/10/2025 20:00 1.00 COMPZN, RPCOMP MPSP P PT 5 1/2" casing to HEX plug @ 8368'. 2500 PSI/30 min. Good test 0.0 0.0 6/10/2025 20:00 6/10/2025 21:30 1.50 COMPZN, RPCOMP BHAH P P/U BHA #15. Dummy overshot, tandum string mills, magnets, and boot baskets 0.0 231.4 6/10/2025 21:30 6/10/2025 23:00 1.50 COMPZN, RPCOMP TRIP P Trip in well, 231 to 2312'. Set down. PUW=60K. SOW=55KTry to work through, PUH KU 231.4 2,312.0 6/10/2025 23:00 6/11/2025 00:00 1.00 COMPZN, RPCOMP REAM P Ream out cement 2300 to 2305, Mill depths, 4 BPM @ 1070 PSI, 60 RPM @ 745 Lb/Ft free torque. Pump high vis sweep 2,312.0 2,312.0 6/11/2025 00:00 6/11/2025 00:30 0.50 COMPZN, RPCOMP CIRC P Circulate hi vis sweep to surface. 2,312.0 2,312.0 6/11/2025 00:30 6/11/2025 04:30 4.00 COMPZN, RPCOMP TRIP P Dry drift through interval clean. Continue in with BHA # 15, Recip packer setting area 8175 to 8240' 2,312.0 8,313.0 6/11/2025 04:30 6/11/2025 05:00 0.50 COMPZN, RPCOMP TRIP P Tag stump @ 8305. No pressure increase. Rotate 20 RPM. See pressure increase and no go @ 8313' 8,313.0 8,313.0 6/11/2025 05:00 6/11/2025 06:15 1.25 COMPZN, RPCOMP CIRC P Circulate Hi vis sweep and casing clean 8,313.0 8,313.0 6/11/2025 06:15 6/11/2025 06:45 0.50 COMPZN, RPCOMP OWFF P Flow check, blow down top drive 8,313.0 8,313.0 6/11/2025 06:45 6/11/2025 12:00 5.25 COMPZN, RPCOMP TRIP P POOH F/8,313' to 208' Laying down 2 7/8" drill pipe 8,313.0 208.0 6/11/2025 12:00 6/11/2025 12:45 0.75 COMPZN, RPCOMP BHAH P Lay down BHA #14 208.0 0.0 6/11/2025 12:45 6/11/2025 13:45 1.00 COMPZN, RPCOMP PRTS P Test 5 1/2" casing to 2500 PSI for 10 min, good test 0.0 0.0 6/11/2025 13:45 6/11/2025 15:15 1.50 COMPZN, RPCOMP RURD P Clean and clear rig floor of BHA components and 2 7/8" equipment 0.0 0.0 6/11/2025 15:15 6/11/2025 16:30 1.25 COMPZN, RPCOMP RURD P Pull wear ring Load completion equipment into pipe shed and rig up to run 2 7/8" tubing 0.0 0.0 6/11/2025 16:30 6/12/2025 00:00 7.50 COMPZN, RPCOMP PUTB P PJSM, Run 2 7/8" 6.4 PPF, L-80, EUE- M liner per program to midnight depth of 3153 0.0 3,153.0 6/12/2025 00:00 6/12/2025 07:45 7.75 COMPZN, RPCOMP PUTB P Continue running 2 7/8" 6.4 PPF, L-80, EUE-M completion per detail F/3,153' T/8,287' 80K UP 60K DN 3,153.0 8,287.0 6/12/2025 07:45 6/12/2025 08:30 0.75 COMPZN, RPCOMP PUTB P Locate 3 1/2" TBG stump at 8,314' with 1 BPM 105 PSI, shut down pump Set down 8K see shear pins at 28' in on JT #262, locate stump at 8320.18' with 10K down Pick up off TBG stump to 8,309'' 8,287.0 8,309.0 6/12/2025 08:30 6/12/2025 09:45 1.25 COMPZN, RPCOMP DISP P PJSM, Circulate in CI brine at 3 BPM 575 PSI, pump 134 BBLS 8,309.0 8,309.0 6/12/2025 09:45 6/12/2025 10:15 0.50 COMPZN, RPCOMP PACK P Drop 1 5/16" ball and rod Slack off to 8,314' set down 5K, pick up to neutral weight Pressure up to 3500 to set DLH Tri Point packer, hold PSI for 10 min Bleed off pressure pull 15K over to 95K to make sure packer set 8,309.0 8,320.0 Rig: NORDIC 3 RIG RELEASE DATE 6/14/2025 Page 9/10 1Q-22 Report Printed: 7/10/2025 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) 6/12/2025 10:15 6/12/2025 11:45 1.50 COMPZN, RPCOMP HOSO P Pick up to 100k = 20K over, apply 2500 PSI did not shear out PBR, pressure up to 3500 still did not shear out PBR Slack off to 80K, Pull 25K over to 103K shear out seal assembly from PBR Slack off locate no go, figure space out Lay down JT #262 T/8,199' PBR top at 8,219' from Nordic 3 RKB 8,320.0 8,199.0 6/12/2025 11:45 6/12/2025 12:15 0.50 COMPZN, RPCOMP THGR P Make up FMC hanger, drain BOP stack Land out in well head, RILDS 85K UP 58K DN Locater 2.08' off no go 8,199.0 8,203.0 6/12/2025 12:15 6/12/2025 13:45 1.50 COMPZN, RPCOMP RURD P Rig up testing equipment on tubing and IA Flood lines 8,203.0 8,203.0 6/12/2025 13:45 6/12/2025 15:00 1.25 COMPZN, RPCOMP PRTS P Test tubing to 3000 PSI for 30 min PSI at start TBG 3240, IA 10, OA 0 15 min PSI TBG 3230, IA 10, OA 0 30 min PSI TBG 3225, IA 10, OA 0 Bleed TBG to 1500 PSI, line up pump down IA Pressure up to 1900 PSI on IA, observe a shear and TBG/IA pressures reading the same Bleed off to zero, pump down IA to 2500 tubing pressure reading same Consult town, contact slick line and mobilize slick line unit to location Test TBG and IA to 2500 PSI for 30 min Starting PSI 2675, 15 min 2660, 30 min 2650 8,203.0 8,203.0 6/12/2025 15:00 6/12/2025 15:45 0.75 COMPZN, RPCOMP CIRC P Rig up to circulate down tubing out IA at 2 BPM 630 PSI Pump 5 BBLS 8,203.0 8,203.0 6/12/2025 15:45 6/12/2025 16:45 1.00 COMPZN, RPCOMP RURD T Rig down circulating and testing equipment Clean and clear rig floor and pipe shed Swap out landing joint for 3 1/2" Mobilize slick line to location 8,203.0 8,203.0 6/12/2025 16:45 6/12/2025 21:45 5.00 COMPZN, RPCOMP RURD T Slick line on location Spot up and rig up slick line, Set catcher. Pull SOV. Valve is sherared. Rerun SOV. Stand back slick line 8,203.0 8,203.0 6/12/2025 21:45 6/12/2025 23:00 1.25 COMPZN, RPCOMP RURD P R/U to PT completion. Bring tubing up 3000 PSI. Not in communication with annulas. Bleed off to 1500 PSI and hold. Test IA to 2500 PSI for 30 min. Good test. Dump tubing pressure, shear SOV 8,203.0 8,203.0 6/12/2025 23:00 6/13/2025 00:00 1.00 COMPZN, RPCOMP RURD P Complete rigging down HES slickline. Rig down testing plumbing. Pull landing joint, Prep to set BPV, Set BPV. Test 1000PSI for 10 min. 8,203.0 0.0 6/13/2025 00:00 6/13/2025 00:30 0.50 COMPZN, RPCOMP RURD P Complete rig down PT equipment. 0.0 0.0 6/13/2025 00:30 6/13/2025 06:00 5.50 COMPZN, RPCOMP CLEN P Flush pits, pumps, surface lines, and BOPE with hot deep clean pill followed with fresh water flush. Pressure wash rig floor and mats 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 6/14/2025 Page 10/10 1Q-22 Report Printed: 7/10/2025 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) 6/13/2025 06:00 6/13/2025 11:00 5.00 COMPZN, RPCOMP CLEN P Open ram doors, remove ram blocks, clean out BOP ram cavities, top wash pits and shaker room, clear pipe shed and rig floor of rental equipment, blow down lines 0.0 0.0 6/13/2025 11:00 6/13/2025 12:00 1.00 COMPZN, RPCOMP NUND P Nipple down BOP and rack back 0.0 0.0 6/13/2025 12:00 6/13/2025 13:30 1.50 COMPZN, RPCOMP NUND P Clean well head and back pressure valve, install TBG head adaptor, nipple up FMC tree, test tubing head adaptor to 5000 PSI for 10 min 0.0 0.0 6/13/2025 13:30 6/13/2025 15:00 1.50 COMPZN, RPCOMP RURD P Rig up lines and equipment for testing tree and freeze protecting well 0.0 0.0 6/13/2025 15:00 6/13/2025 15:45 0.75 COMPZN, RPCOMP SEQP P Flood lines and test tree to 250 for 5 min and 5000 PSI for 5 min each 0.0 0.0 6/13/2025 15:45 6/13/2025 16:15 0.50 COMPZN, RPCOMP MPSP P Pull BPV 0.0 0.0 6/13/2025 16:15 6/13/2025 18:00 1.75 COMPZN, RPCOMP FRZP P Freeze protect well with 45 BBLS diesel at 2 BPM 900 PSI Utube diesel from annulus to tubing, blow down lines 0.0 0.0 6/13/2025 18:00 6/13/2025 20:00 2.00 COMPZN, RPCOMP RURD P Rig down freeze protect lines Secure well obtian final pressure reading Warm up moving system. Prep area to move rig off well 0.0 0.0 6/13/2025 20:00 6/13/2025 21:00 1.00 COMPZN, WHDBOP MOB P Move off 1Q-22. Set rig down. Place mat in cellar for BOPe work 0.0 0.0 6/13/2025 21:00 6/14/2025 00:00 3.00 COMPZN, WHDBOP RURD P R/D BOP stack 0.0 0.0 6/14/2025 00:00 6/14/2025 01:00 1.00 COMPZN, WHDBOP RURD P Break down BOPE 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 6/14/2025 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 9,210.0 1Q-22 7/1/2025 praffer Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled HEX plug @ 8368' RKB 1Q-22 7/1/2025 rmoore22 Notes: General & Safety Annotation End Date Last Mod By Note: Placed 195,000# of 20/40 frac sand into the perfs. 9/27/2018 fergusp NOTE: Tagged obstuction in 3.5" Liner @ 8948' RKB 4/19/2018 fergusp NOTE: Pumped 26.5 bbl of 15.8 class G cement down the O/A. TOC approx 3600' 1/19/2015 lehallf Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.03 42.0 121.0 121.0 62.58 H-40 WELDED SURFACE 7 5/8 6.87 41.0 4,957.1 3,872.9 29.70 L-80 BTC-MOD Tie-Back String 5 1/2 4.95 34.7 2,325.0 2,202.6 15.50 L-80 Hyd 563 Production 5 1/2 4.95 2,322.0 8,569.0 6,194.5 15.50 L-80 LTC-MOD LINER 3 1/2 2.99 8,348.6 9,514.0 9.20 L-80 ABM-BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 22.6 Set Depth … 8,316.5 String Max No… 2 7/8 Set Depth … 5,998.3 Tubing Description Tubing – Completion Upper Wt (lb/ft) 6.50 Grade L80 Top Connection EUE-M ID (in) 2.44 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) 22.6 22.6 0.16 Hanger 6.982 ORKB to ULDS Nordic 1 22.58' (Nordic 3 RKB to ULDS 26.05') FMC TC-1A ENS 2.952 3,066.3 2,685.0 53.04 Mandrel – GAS LIFT 4.741 2-7/8" X 1" KBMG, GLM SLB KBGM 2.371 6,537.1 4,897.7 54.14 Mandrel – GAS LIFT 4.730 2-7/8" X 1" KBMG, GLM SLB KBGM 2.371 8,159.6 5,885.0 46.68 Mandrel – GAS LIFT 4.730 2-7/8" X 1" KBMG, GLM SLB KBGM 2.371 8,213.6 5,922.7 44.25 Locator 4.180 Baker locaor - locater 2.08' off no go 2.980 8,215.9 5,924.4 44.13 Seal Assembly 3.980 Baker 80-40 PBR W/4" ID - Seal assy 11.78' 3.98" OD Baker 80-40 2.980 8,241.3 5,942.8 43.15 Packer 4.950 2-7/8" x 5 1/2" 14-20 DLH TriPoint DLH Retrievable Packer Tri Point DLH 2.380 8,288.6 5,977.6 42.17 Nipple - X 3.770 2.313 X Nipple HES X 2.313 8,309.5 5,993.1 41.86 Overshot 4.810 3.5" x 7.625" Poor Boy Overshot (To no go 6.49') PBOS 3.620 Top (ftKB) 8,310.0 Set Depth … 8,349.1 String Max No… 3 1/2 Set Depth … 6,022.7 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection ABM-EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,327.3 6,006.3 41.68 NIPPLE 4.540 CAMCO D NIPPLE NO GO 2.750 8,334.4 6,011.7 41.61 PBR 4.000 BAKER 80-40 PBR SHEAR OUT w/ 10' SEALS 2.992 8,348.4 6,022.1 41.41 ANCHOR 4.500 BAKER ANCHOR 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) 35.2 35.2 0.25 EMERGENCY SLIPS C-21 11" x 5 1/2" emergency slips - In 5-1/2" Tie Back String 6/8/2025 11.00 0 9,210.0 Bridge Plug - Permanent Milled Weatherford FracGuard plug, pushed to hard tag at 9210' CTMD 9/30/2018 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) 3,066.3 2,685.0 53.04 1 GAS LIFT GLV BK 1 1,226.0 6/19/2025 SLB KBMG 0.188 6,537.1 4,897.7 54.14 2 GAS LIFT GLV BK 1 1,249.0 6/19/2025 SLB KBMG 0.250 8,159.6 5,885.0 46.68 3 GAS LIFT OV BK 1 6/20/2025 SLB KBMG 0.188 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) 2,302.5 2,185.9 42.05 Collar - Stage 6.625 5 1/2" H-ES II Cementer HES H-ES II Cementer 4.750 8,348.6 6,022.3 41.41 PACKER 4.625 BAKER SABL-3 PERMANENT PACKER 2.812 8,352.8 6,025.4 41.33 NIPPLE 3.750 BAKER XO NIPPLE 3.000 8,353.1 6,025.7 41.32 XO THREAD 3.500 2.992 9,416.2 LANDING COLLAR 3.500 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,925.0 8,942.0 6,466.0 6,478.7 C-1, 1Q-22 6/29/2018 6.0 APERF 2.5" HYPERJET, 6 SPF, 60 DEG PHASING 8,942.0 8,950.0 6,478.7 6,484.7 C-1, 1Q-22 2/3/1998 4.0 APERF 2 1/8" EJ DP; Oriented (+/-) 90 deg 1Q-22, 7/7/2025 10:47:29 AM Vertical schematic (actual) LINER; 8,348.6-9,514.0 Bridge Plug - Permanent; 9,210.0 IPERF; 9,180.0-9,205.0 APERF; 8,950.0-8,960.0 RPERF; 8,942.0-8,950.0 APERF; 8,942.0-8,950.0 Mini frac; 8,925.0 APERF; 8,925.0-8,942.0 Primary – Full Bore; 8,340.0 ftKB Production; 2,322.0-8,569.0 Nipple - X; 8,288.6 Packer; 8,241.3 Seal Assembly; 8,215.8 Mandrel – GAS LIFT; 8,159.6 Primary – Full Bore; 7,680.0 ftKB Mandrel – GAS LIFT; 6,537.1 SURFACE; 41.0-4,957.1 Mandrel – GAS LIFT; 3,066.3 Primary – Full Bore; 361.0 ftKB Tie-Back String; 34.7-2,325.0 Production String 1 Cement; 41.0 ftKB CONDUCTOR; 42.0-121.0 Hanger; 22.6 KUP PROD KB-Grd (ft) RR Date 2/24/1996 Other Elev… 1Q-22 ... TD Act Btm (ftKB) 9,514.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292259500 Wellbore Status PROD Max Angle & MD Incl (°) 58.65 MD (ftKB) 6,920.01 WELLNAME WELLBORE1Q-22 Annotation Last WO: End Date 6/13/2025 H2S (ppm) 25 Date 8/22/2017 Comment SSSV: NIPPLE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,942.0 8,950.0 6,478.7 6,484.7 C-1, 1Q-22 6/29/2018 6.0 RPERF 2.5" HYPERJET, 6 SPF, 60 DEG PHASING 8,950.0 8,960.0 6,484.7 6,492.3 C-1, 1Q-22 6/29/2018 6.0 APERF 2.5" HYPERJET, 6 SPF, 60 DEG PHASING 9,180.0 9,205.0 6,667.8 A-4, A-3, 1Q-22 4/18/1996 4.0 IPERF 180 deg. ph; 2.5" Hollow Carrier 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) 8,925.0 8,960.0 1 Mini frac 9/27/2018 200,000.0 0.0 2,621.00 2,823.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 41.0 2,322.0 41.0 2,200.4 Production String 1 Cement HES pump 10 Bbls fresh water w/ red die @ 3 BPM, 350 PSI. Pump 108 Bbls 15.8 PPG cement @ 3 BPM, 900 PSI. Drop closing plug. Pump 10 Bbls fresh water. Rig displace w/ vis seawater @ 3 BPM. Slowed pump T/ 1,5 BPM. Plug bumped on time 771 strokes. Pressure up T/ 2600 PSI held for 5 Min. Open up verify tool shifted closed no returns through 5 1/2". 6/8/2025 1Q-22, 7/7/2025 10:47:29 AM Vertical schematic (actual) LINER; 8,348.6-9,514.0 Bridge Plug - Permanent; 9,210.0 IPERF; 9,180.0-9,205.0 APERF; 8,950.0-8,960.0 RPERF; 8,942.0-8,950.0 APERF; 8,942.0-8,950.0 Mini frac; 8,925.0 APERF; 8,925.0-8,942.0 Primary – Full Bore; 8,340.0 ftKB Production; 2,322.0-8,569.0 Nipple - X; 8,288.6 Packer; 8,241.3 Seal Assembly; 8,215.8 Mandrel – GAS LIFT; 8,159.6 Primary – Full Bore; 7,680.0 ftKB Mandrel – GAS LIFT; 6,537.1 SURFACE; 41.0-4,957.1 Mandrel – GAS LIFT; 3,066.3 Primary – Full Bore; 361.0 ftKB Tie-Back String; 34.7-2,325.0 Production String 1 Cement; 41.0 ftKB CONDUCTOR; 42.0-121.0 Hanger; 22.6 KUP PROD 1Q-22 ... WELLNAME WELLBORE1Q-22 Originated: Delivered to:18-Jun-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 1B-20 50-029-23164-00 910026681 Kuparuk River Packer Setting Record Field- Final 7-May-25 0 12 1D-117 50-029-22844-00 910027101 Kuparuk River Plug Setting Record Field- Final 8-May-25 0 13 1D-133 50-029-22827-00 910010225 Kuparuk River Multi Finger Caliper Field & Processed 25-May-25 0 14 1G-02 50-029-20813-00 910036496 Kuparuk River Multi Finger Caliper Field & Processed 21-May-25 0 15 1H-08 50-029-20763-00 910080713 Kuparuk River Multi Finger Caliper Field & Processed 22-May-25 0 16 1H-08 50-029-20763-00 910080713 Kuparuk River Plug Setting Record Field- Final 22-May-25 0 17 1Q-04 50-029-21250-00 910027200 Kuparuk River Tubing Cut Record Field- Final 14-May-25 0 18 1Q-04 50-029-21250-00 910027200 Kuparuk River Tubing Cut Record Field- Final 15-May-25 0 19 1Q-22 50-029-22595-00 910027102 Kuparuk River Plug Setting Record Field- Final 16-May-25 0 110 2B-02A 50-029-21154-01 910106459 Kuparuk River Leak Detect Log Field- Final 14-Jun-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:203-115197-237197-206182-138182-093184-234195-140216-087T40582T40583T40584T40585T40586T40586T40587T40587T40588T405896/20/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.06.20 08:37:34 -08'00'1Q-2250-029-22595-00 910027102Kuparuk RiverPlug Setting RecordField- Final16-May-2501195-140 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number):10. Field: Kuparuk Oil Pool Kuparuk Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9514'1784'None Casing Collapse Conductor Surface Production Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. 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:GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: 907-265-6049 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 121' 6949' 8327', 9210' 7-5/8" 79'121' Baker SABL-3 Permanent SSSV: None 6949'8915'6459' 5-1/2" 16" 9514'1165' 3-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025634, ADL0025641 195-140 P.O. Box 100360, Anchorage, AK 99510 50-029-225950-00-00 ConocoPhillips Alaska, Inc KRU 1Q-22 Will perfs require a spacing exception due to property boundaries? AOGCC USE ONLY Tubing Grade:Tubing MD (ft): 8349'MD/6022'TVD Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Proposed Pools: 3873' Burst 4957' Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size 8349'8925-8960' 9180-9205' 8534' 3-1/2" 6466-6492' 6668-6689' Kuparuk River Field TVD Perforation Depth TVD (ft): MD 6195' Cy Eller 6/9/2025 Date: 4916' 8569' Perforation Depth MD (ft): cy.eller@conocophillips.com CTD/RWO Engineer Subsequent Form Required: Suspension Expiration Date: L-80 m n P s 1 6 5 6 t g 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 10:59 am, May 09, 2025 325-292 10-404 JJL 5/12/25 A.Dewhurst 15MAY25 AOGCC witnessed BOP and Annular test to 2500 psi. DSR-5/9/25 X *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.02 09:46:20 -08'00'06/02/25 RBDMS JSB 060225 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 8, 2025 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KRU 1Q-22 (PTD# 195-140). Well 1Q-22 was drilled and 5-1/2” production casing was topset above the Kuparuk sands by Parker 245 in October of 1995. In February of 1996, Nordic 1 drilled to TD and installed a 3-1/2” liner and 3-1/2” upper completion leaving the well as a Producer in the Kuparuk A sands. The Kuparuk C sands were later perforated in 1998. The well failed a proactive TIFL in 2024, and subsequent diagnostics revealed tubing leaks in gas lift mandrels at 7,373’ and 8,282’ RKB. Since the well has a history of scale buildup, patches are not a viable option to bring the well back online. During pre-rig diagnostics, the well failed an MIT-OA to 1,800 psi with fluid flow up the SC x conductor annulus. Prior to the 2015 OA cement job, the well had a known shallow surface casing leak. The OA cement job was pumped to allow the surface casing leak depth to be identified, since the well had an open OA shoe. The OA cement job temporarily fixed the surface casing leak, indicated by a passing MIT-OA in 2015, but is no longer providing pressure integrity, indicated by the recent failing MIT-OA. To return the well to production, we are requesting approval to proceed with a rig workover. We plan to pull the 3-1/2” completion from a pre-rig cut above the packer, then cut and pull the 5-1/2” production casing from above the TOC and run new 5-1/2” production casing and cement the OA, then perform a casing cleanout run, and a tubing dress off run as needed based on tubing condition. A new 2-7/8” gas lifted completion with a non- sealing overshot and stacked packer will be installed. If you have any questions or require any further information, please contact me at 907-265-6049. Cy Eller Rig Workover Engineer CPAI Drilling and Wells 1Q-22 Kuparuk Producer Pull and Replace Tubing Procedure PTD: 195-140 Page 1 of 3 PPre-Rig Work Remaining 1. Pull CA-2 plug from nipple profile at 8,327’ RKB. 2. Obtain updated SBHP. 3. Pull DMY valve from GLM at 7,368’ RKB for circulation point. 4. Set HEX plug at ~8,368’ RKB. 5. Cut tubing at ~8,310’ RKB. 6. CMIT-TxIA to 2,500 psi. 7. DDT-TxIA. 8. MIT-OA to 1,800 psi. Failed 5/4/2025 9. T-POT, T-PPPOT, IC-POT, IC-PPPOT. FT LDS. Passed 5/3/2025 10. Prepare well for rig arrival. Rig Work MIRU 1. MIRU Nordic 3 on 1Q-22. No BPV will be set for MIRU due to Nordic 3 internal risk assessment. 2. Circulate seawater. Record shut in pressures on the T & IA. Circulate KWF as needed and complete 30-minute NFT. Verify well is dead. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. Retrieve 3-1/2” Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing and jewelry from pre-rig cut at ~8,310’ RKB. 5-1/2” Casing “Subsidence-Style” Repair 6. RU E-Line and pull CBL from SC shoe to surface. 7. Set plug in 5-1/2” casing below TOC identified by CBL. PT plug to confirm set, dump sand on top of plug. 8. ND BOPE, ND tubing head and grow casing as needed using de-tensioning system, pull casing in tension and set slips, NU BOPE to casing head. a. BOPE flange break unable to be tested at this point. Flange break to be tested as soon as practical once test plug can be installed. 9. RIH and cut 5-1/2” casing. Circulate freeze protect out of OA. 10. Spear 5-1/2” casing, split BOPE stack and remove casing slips. NU BOPE to casing head. 11. Pull 5-1/2” casing from cut. a. Make additional cuts in 5-1/2” casing to remove in sections as necessary. b. Test BOPE breaks once 5-1/2” casing is pulled. 12. RIH with mills to ensure drift for overshot casing patch and cementer. Bore out 7-5/8” casing to create drift as necessary. 13. MU and RIH with overshot casing patch, cementer, and new 5-1/2” casing. Engage overshot and PT casing against plug to 2,500 psi. 14. Cement 5-1/2” x 7-5/8” annulus to surface. 1Q-22 Kuparuk Producer Pull and Replace Tubing Procedure PTD: 195-140 Page 2 of 3 15. ND BOPE, set casing slips, cut excess 5-1/2” casing and install packoffs, NU tubing head and BOPE. Test breaks to 250/2,500 psi. 16. RIH and mill up cement and cementer plugs. Perform additional cleanout runs as necessary. 17. RIH and wash sand and debris from top of plug. Retrieve plug. Casing Cleanout Run 18. RIH on DP and perform casing cleanout and tubing dress off runs if necessary, based on tubing condition. Install new 2-7/8” Gas Lift Completion with Stacked Packer 19. MU new 2-7/8” completion with non-sealing overshot, nipple profile, 2-7/8” x 5-1/2” packer, and GLMs. RIH to tubing stub. 20. Once on depth, space out as needed. Circulate corrosion inhibited fluid. 21. Land tubing hanger, RILDS, drop ball and rod and set packer. 22. Pressure test tubing to 3,000 PSI for 30 minutes. 23. Pressure test IA to 2,500 PSI for 30 minutes. ND BOP, NU Tree 24. Confirm pressure tests, then shear out SOV. 25. Install BPV and test. ND BOPE. NU tree and PT packoffs. 26. Pull BPV and freeze protect well. 27. RDMO. PPost-Rig Work 1. Pull SOV and DVs 2. Pull ball and rod used for setting packer. 3. Install new GLD. 4. Pull pre-rig HEX plug from liner. General Well Information: Estimated Start Date: 5/27/2025 6/9/2025 Current Operations: Shut in Well Type: Producer Wellhead Type: FMC Gen IV. 11” 3M casing head top flange. 7-1/16” 5M tubing head top flange. Scope of Work: Pull the existing 3-1/2” completion from pre-rig cut. Cut, pull, and replace 5- 1/2” casing and cement up OA. Perform tubing cleanout/dress off run, install a new 2-7/8” gas lift completion with stacked packer. BOP Configuration: Annular / Pipe Rams / Blind Rams / Pipe Rams 1Q-22 Kuparuk Producer Pull and Replace Tubing Procedure PTD: 195-140 Page 3 of 3 FFollowing subject to change with Pre-Rig Work: MIT Results: CMIT-TxIA: Passed (2,500 psi, 7/19/2024) MIT-OA: Passed (1,800 psi, 1/29/2015) Failed (1,800 psi, 5/4/2025) Tubing POT: Passed (4/12/2024) (No record of T-PPPOT) Passed (5/3/2025) IC POT & PPPOT: Passed (1/14/2014) Passed (5/3/2025) Static BHP: 2,453 psi / 6,693’ TVD measured on 5/4/2018 MPSP: 1,784 psi using 0.1 psi/ft gradient Personnel: Workover Engineer: Cy Eller (907-265-6049 / Cy.Eller@conocophillips.com) Production Engineer: Jennifer McLeod Last Tag Last Mod ByEnd DateWellboreDepth (ftKB)Annotation zembaej7/28/20221Q-228,915.0Last Tag: RKB (Est. 10' above top Perf) Last Rev Reason Last Mod ByEnd DateWellboreAnnotation rmoore228/2/20241Q-22Rev Reason: Ran LDL and Caliper. Notes: General & Safety Last Mod ByEnd DateAnnotation fergusp9/27/2018Note: Placed 195,000# of 20/40 frac sand into the perfs. fergusp4/19/2018NOTE: Tagged obstuction in 3.5" Liner @ 8948' RKB lehallf1/19/2015NOTE: Pumped 26.5 bbl of 15.8 class G cement down the O/A. TOC approx 3600' Casing Strings Top (ftKB)ID (in)OD (in)Csg Des Set Depth (ftKB) Set Depth Top ThreadGradeWt/Len (lb/ft)(TVD) (ftKB) WELDEDH-4062.58121.0121.042.015.0316CONDUCTOR BTC-MODL-8029.703,872.94,957.141.06.877 5/8SURFACE LTC-MODL-8015.506,194.58,569.034.74.955 1/2PRODUCTION ABM-BTCL-809.209,514.08,348.62.993 1/2LINER Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 22.6 Set Depth … 8,349.1 String Max No… 3 1/2 Set Depth … 6,022.7 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection ABM-EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl Item Des(°) OD Nominal (in)ModelMakeCom Nominal ID (in) 3.500FMC GEN IV TUBING HANGER8.000HANGER0.1622.622.6 2.812CAMCO DS LANDING NIPPLE3.800NIPPLE0.83522.8522.8 2.900ATXBST4.750GAS LIFT51.892,393.72,603.5 2.900ATXBST4.750GAS LIFT48.523,588.04,514.1 2.900ATXBST4.750GAS LIFT52.954,581.86,020.3 2.900ATXBST4.750GAS LIFT49.815,380.27,368.4 2.900ATXBST4.750GAS LIFT42.405,969.08,277.1 2.750CAMCO D NIPPLE NO GO4.540NIPPLE41.686,006.38,327.2 BAKER 80-40 PBR SHEAR OUT w/4.000PBR41.616,011.68,334.3 10' SEALS 2.992 2.992BAKER ANCHOR4.500ANCHOR41.416,022.18,348.3 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)ID (in)Run DateSNModelMakeComDes LEAK -49.805,383.27,373.0 TUBING LDL FOUND TUBING LEAK @ 7373' RKB 0.0008/1/2024 LEAK -42.295,972.78,282.0 TUBING LDL FOUND TUBING LEAK @ 8282' RKB 0.0008/1/2024 TUBING41.686,006.18,327.0 PLUG 0.0007/7/2024Set 2.75" CA2 plug. Bridge Plug -9,210.0 Permanent Milled Weatherford FracGuard plug, pushed to hard tag at 9210' CTMD 0.0009/30/2018 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 ModelMakeComRun Date(psi) Port Size (in) 51.892,393.72,603.5 1 T-1DMYGAS LIFT 1 0.0007/9/20240.0 48.523,588.04,514.1 2 T-1DMYGAS LIFT 1 0.0007/8/20240.0 52.954,581.86,020.3 3 T-1DMYGAS LIFT 1 0.0007/11/20240.0 49.815,380.27,368.4 4 T-1DMYGAS LIFT 1 7/24/2024 42.405,969.08,277.1 5 T-1DMYGAS LIFT 1 0.0009/5/20180.0 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl Item Des(°) OD Nominal (in)ModelMakeCom Nominal ID (in) BAKER SABL-3 PERMANENT4.625PACKER41.416,022.38,348.6 PACKER 2.812 3.000BAKER XO NIPPLE3.750NIPPLE41.336,025.48,352.8 2.9923.500XO THREAD41.326,025.78,353.1 LANDING9,416.2 COLLAR 2.9923.500 Perforations & Slots Btm (ftKB)Top (ftKB) Top (TVD) (ftKB) Btm (TVD) DateLinked Zone(ftKB) Shot Dens (shots/ft)ComType 2.5" HYPERJET, 6 SPF, 60APERF6.06/29/2018C-1, 1Q-226,478.76,466.08,942.08,925.0 DEG PHASING 2 1/8" EJ DP; Oriented (+/-)APERF4.02/3/1998C-1, 1Q-226,484.76,478.78,950.08,942.0 90 deg 2.5" HYPERJET, 6 SPF, 60RPERF6.06/29/2018C-1, 1Q-226,484.76,478.78,950.08,942.0 DEG PHASING 2.5" HYPERJET, 6 SPF, 60APERF6.06/29/2018C-1, 1Q-226,492.36,484.78,960.08,950.0 DEG PHASING 180 deg. ph; 2.5" HollowIPERF4.04/18/1996A-4, A-3, 1Q-226,667.89,205.09,180.0 Carrier Stimulation Intervals Btm (ftKB)Top (ftKB) Inter val Num ber Start DateSubtypeType Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 8,960.08,925.0 1 2,823.002,621.000.0200,000.09/27/2018Mini frac 1Q-22, 4/25/2025 10:36:51 AM Vertical schematic (actual) LINER; 8,348.6-9,514.0 FLOAT SHOE; 9,512.4-9,514.0 FLOAT COLLAR; 9,448.0- 9,448.9 LANDING COLLAR; 9,416.2- 9,417.1 Bridge Plug - Permanent; 9,210.0 IPERF; 9,180.0-9,205.0 APERF; 8,950.0-8,960.0 APERF; 8,942.0-8,950.0 RPERF; 8,942.0-8,950.0 Mini frac; 8,925.0 APERF; 8,925.0-8,942.0 PRODUCTION; 34.7-8,569.0 FLOAT SHOE; 8,567.8-8,569.0 FLOAT COLLAR; 8,481.7- 8,482.8 NIPPLE; 8,352.8-8,353.1 PACKER; 8,348.6-8,352.8 ANCHOR; 8,348.3 PBR; 8,334.3 TUBING PLUG; 8,327.0 NIPPLE; 8,327.2 LEAK - TUBING; 8,282.0 GAS LIFT; 8,277.1 LEAK - TUBING; 7,373.0 GAS LIFT; 7,368.4 GAS LIFT; 6,020.3 SURFACE; 41.0-4,957.1 FLOAT SHOE; 4,955.6-4,957.1 FLOAT COLLAR; 4,874.5- 4,875.8 GAS LIFT; 4,514.1 GAS LIFT; 2,603.5 NIPPLE; 522.8 CONDUCTOR; 42.0-121.0 HANGER; 41.0-45.5 HANGER; 22.6 KUP PROD RR DateKB-Grd (ft) 2/24/1996 Other Elev… 1Q-22 ... TD Act Btm (ftKB) 9,514.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292259500 Wellbore Status PROD Max Angle & MD ncl (°)I 8.655 MD (ftKB) 6,920.01 WELLBOREWELLNAME 1Q-22 Annotation Last WO: End DateH2S (ppm) 25 Date 8/22/2017 Comment SSSV: NIPPLE Shallow SC Leak ORIGINATED TRANSMITTAL DATE: 5/30/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5455 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 5455 1Q-22 50029225950000 Tubing Cut Record 17-May-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 lorna.c.collins@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 195-140 T40509 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.30 13:14:46 -08'00' 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 From:Lau, Jack J (OGC) To:Eller, Cy Cc:Hobbs, Greg S Subject:(195-140] RE: CPAI_KRU_1Q-22_2025_Update Date:Wednesday, May 14, 2025 11:20:51 AM Good plan. Thanks Jack From: Eller, Cy <Cy.Eller@conocophillips.com> Sent: Wednesday, May 14, 2025 10:13 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: RE: [EXTERNAL]RE: CPAI_KRU_1Q-22_2025_Update Hi Jack, After I submitted the revised Sundry on 5/9/2025, we got an updated SBHP survey on 1Q-22. The new SBHP is 3,338 psi at 6,480’ TVD. The MPSP with a 0.1 psi/ft gas gradient is 2,690 psi. We plan to test BOPs to 3,000 psi. 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 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Monday, May 12, 2025 2:06 PM To: Eller, Cy <Cy.Eller@conocophillips.com> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: RE: [EXTERNAL]RE: CPAI_KRU_1Q-22_2025_Update Thanks From: Eller, Cy <Cy.Eller@conocophillips.com> Sent: Monday, May 12, 2025 2:03 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: RE: [EXTERNAL]RE: CPAI_KRU_1Q-22_2025_Update Hi Jack, The most recent CMIT on 1Q-22 passed on 7/19/2024. We plan to get the HEX plug set this week and will get another CMIT to confirm PC integrity and plug set. The cement volumes for the OA cement job will be dependent on final 5-1/2” casing cut depth based on the CBL pulled on-rig. We plan to pump the annulus volume to the cut + 50% excess of cement. A ~10 bbl freshwater spacer will be used followed by seawater for displacement. Thank you, Cy Eller RWO/CTD Engineer ConocoPhillips Alaska Office: 907-265-6049 Cell: 907-232-4090 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Monday, May 12, 2025 11:20 AM To: Eller, Cy <Cy.Eller@conocophillips.com> Subject: RE: [EXTERNAL]RE: CPAI_KRU_1Q-22_2025_Update Thanks Cy reviewing the updated sundry application. Few questions Did the pre-rig CMIT pass? Does the PC of integrity. Please send your cementing calcs including displacement. Thanks Jack From: Eller, Cy <Cy.Eller@conocophillips.com> Sent: Friday, May 9, 2025 11:43 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: RE: [EXTERNAL]RE: CPAI_KRU_1Q-22_2025_Update Thank you, Jack. The revised Sundry has been submitted. We have moved KRU 1Q-04 in front of 1Q-22 on the rig schedule. I updated the anticipated start date on the revised Sundry. Thanks, Cy Eller RWO/CTD Engineer ConocoPhillips Alaska Office: 907-265-6049 Cell: 907-232-4090 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Thursday, May 8, 2025 1:26 PM To: Eller, Cy <Cy.Eller@conocophillips.com> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: [EXTERNAL]RE: CPAI_KRU_1Q-22_2025_Update Thanks for the update Cy. With this level of change please resubmit the revised sundry application via official channel. We will make sure it is reviewed timely. Jack From: Eller, Cy <Cy.Eller@conocophillips.com> Sent: Thursday, May 8, 2025 1:15 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: CPAI_KRU_1Q-22_2025_Update Hi Jack, As noted in my Sundry Application to workover KRU 1Q-22, we planned to perform an MIT-OA to 1,800 psi to verify the surface casing integrity. Unfortunately, the MIT-OA failed with fluid flow up the SC x conductor annulus on 5/4/2025. The OA pressure was bled to 0 psi and the test was aborted. Our revised plan is to complete a “subsidence style” repair and cut, pull, and replace the 5- 1/2” production casing. The original Sundry Application is submitted, but still under AOGCC review for approval. Please advise on a path forward to document the change. Thank you, Cy Eller RWO/CTD Engineer ConocoPhillips Alaska 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. Office: 907-265-6049 Cell: 907-232-4090 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Monday, April 28, 2025 1:41 PM To: Eller, Cy <Cy.Eller@conocophillips.com> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: RE: [EXTERNAL]CPAI_KRU_1Q-22_2025_received_042525_review.pdf Thanks Cy. Jack From: Eller, Cy <Cy.Eller@conocophillips.com> Sent: Monday, April 28, 2025 1:08 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: RE: [EXTERNAL]CPAI_KRU_1Q-22_2025_received_042525_review.pdf Hi Jack, It looks like I updated the date from the original cement detail but not the TOC when making the proposed schematic. The correct calculated TOC from the cement detail is 6,896’ MD. Attached is an updated schematic with the correct depth. I apologize for the confusion. Thank you, Cy Eller RWO/CTD Engineer ConocoPhillips Alaska Office: 907-265-6049 Cell: 907-232-4090 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Monday, April 28, 2025 12:36 PM To: Eller, Cy <Cy.Eller@conocophillips.com> Subject: [EXTERNAL]CPAI_KRU_1Q-22_2025_received_042525_review.pdf CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Good afternoon Cy, I noticed the proposed diagram doesn’t accurately reflect the location of the proposed new packer in respect to TOC. Please edit and shoot me an accurate diagram. Thanks Jack Originated: Delivered to:13-Aug-24 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET# 1 1Q-22 50-029-22595-00 909470221 Kuparuk River Leak Detect Log Field- Final 1-Aug-24 0 1 2 1Q-22 50-029-22595-00 909470221 Kuparuk River Multi Finger Caliper Field & Processed 1-Aug-24 0 1 3 2A-11 50-103-20057-00 909443804 Kuparuk River Multi Finger Caliper Field & Processed 13-Jul-24 0 1 4 2C-12 50-029-21222-00 909469468 Kuparuk River Packer Setting Record Field- Final 23-Jul-24 0 1 5 2M-25 50-103-20152-00 909509189 Kuparuk River Multi Finger Caliper Field & Processed 10-Aug-24 0 1 6 2X-05 50-029-20985-00 909469473 Kuparuk River Leak Detect Log Field- Final 26-Jul-24 0 1 7 2X-05 50-029-20985-00 909469473 Kuparuk River Packer Setting Record Field- Final 28-Jul-24 0 1 8 2Z-06 50-029-20957-00 909460858 Kuparuk River Multi Finger Caliper Field & Processed 15-Jul-24 0 1 9 WSW-05 50-029-20838-00 909490893 Kuparuk River Multi Finger Caliper Field & Processed 2-Aug-24 0 1 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: T39442 T39442 T39443 T39444 T39445 T39446 T39446 T39447 T39448 195-140 186-003 184-206 191-021 183-107 183-077 182-164 8-14-2024 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.14 08:42:09 -08'00' 1 1Q-22 50-029-22595-00 909470221 Kuparuk River Leak Detect Log Field- Final 1-Aug-24 0 1 2 1Q-22 50-029-22595-00 909470221 Kuparuk River Multi Finger Caliper Field & Processed 1-Aug-24 0 195-140 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed Abandon r Repair well r Rug Perforations r Perforate r Other F OA CMT Shoe Alter Casing r Pull Tubing r Stimulate- Frac r Waiver r Time Extension r Change Approved R-ogram rOperat Shutdow n r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 195-140 _ 3.Address: 6.API Number. P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-029-22595-00 7.Property Designation(Lease Number): 8 Well Name and Number: ADL0025634 KRU 1Q-22 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 9514 feet Plugs(measured) None true vertical 6995 feet Junk(measured) None Effective Depth measured 9414 feet Packer(measured) 8348 true vertical 6913 feet (true vertical) 6022 Casing Length Size MD ND Burst Collapse CONDUCTOR 79 16 121 121 SURFACE 4916 7.625 4957 3875 PRODUCTION 8534 5.5 8569 6199 RECEIVED LINER 1165 4.625 9514 6993 FEB 0 3 2015 Perforation depth: Measured depth: 8942 8950,9180 9205 AOGCG P P Sat* 1 r " i I::`_� True Vertical Depth: 6369-6368,6608-6634 Tubing(size,grade,MD,and TVD) 3.5, L-80, 8349 MD,6012 TVD Packers&SSSV(type,MD,and TVD) ANCHOR-BAKER ANCHOR @ 8348 MD and 6022 TVD NIPPLE-CAMCO DS LANDING NIPPLE, 2.856"NO GO w/2.812" ID @ 523 MD and 523 TVD 12.Stimulation or cement squeeze summary: NA 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 NA Subsequent to operation NA 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development pr Service r Stratigraphic r 16.Well Status after work Oil r Gas r WDSPL r Daily Report of Well Operations x GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C.O Exempt. 314-647 Contact MJ Loveland/Martin Walters Email n1878@conocophillips.com Printed Name MJ Loveland Title WI Proj Supvisor Signature 24r, �/ Phone:659-7403 Date i/ _.....-- ./7 A C-42 c.....,-------- 34-) Jg1 V71- z/4./i5- RBDMS FEB - 4 2015 Form 10-404 Revised 10/2012 Submit Original Only RECEIVED ConocoPhillips FEB 0 3 2015 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 January 30, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-404 Report of Sundry Well Operations ConocoPhillips Alaska, Inc. KRU well 1Q-22, PTD 195-140 surface casing cement shoe. Please call MJ Loveland or Martin Walters at 659-7043 if you have any questions. Sincerely, 7/14-ri MJ veland ConocoPhillips Well Integrity Projects Supervisor 1Q-22 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 1Q-22 PTD 195-140 Sundry 314-647 01/19/15 PUMPED 26.5 BBLS CLASS G CEMENT TO SHOE ON 0/A followed by 35 bbls diesel 01/29/15 MITOA passed to 1800 psi. Pressured OA in increments to 1800 psi w/0.7 bbls diesel. Starting T/I/O = 560/590/1800. 15 min T/I/O = 560/590/1735. (-65). 30 min T/I/0 = 560/590/1720. (-15). (Passed). • KUP PROD 1Q-22 Conoco.Phillips "" Well Attributes Max Angle&MD TD Alaska,411. Welmore APuuWI Field Name Wellbore Status Inci I") MD(ftKB) Act Btm(ftKB) crm..R lhp, 500292259500 KUPARUK RIVER UNIT PROD a 58.65 6,920.01 9,514.0 " ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) .7 Rig Release Date 10-22.1/25201510:52:26 AM SSSV:NIPPLE 135 12/16/2013 _Last WO: 2/24/1996 Vertical schematic(actual) Annotation Depth(0KB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,817.0 10/25/2014 Rev Reason:CEMENT NOTE lehallf 1252015 HANGER;226 Casing Strings Casing Description OD(in) r ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WULen(I...Grade Top Thread CONDUCTOR 16 15.026 42.0 121.0 121.0 62.58 H-40 WELDED Casing Description OD(in) 'ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I.,.Grade Top Thread lk SURFACE 7 5/8 6.875 41.0 4,957.1 3,872.9 29.70 L-80 BTC-MOD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION 512 4.950 347 8,569.0 6,194.5 15.50 L-80 LTC-MOD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread LINER 312 2.992 8,348.6 9,514.0 9.20 L-80 ABM-BIC A,...." ,,,,Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top not C) Item Des Com (in) CONDUCTOR:42.0421.0-e -- 8,348.6 6,022.3 41.41 PACKER BAKER SABL-3 PERMANENT PACKER 2.812 11 8,352.8 Tubing Strings 6,025.4 41.33 NIPPLE 'BAKER XO NIPPLE 3.000 NIPPLE;522.8 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 31/2 2.992 22.6 8,349.1 6,022.7 9.30 L-80 ABM-EUE Completion Details GAS LIFT;2,603.5 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl CI Item Des I Com (in) 22.6 22.6 0.16 HANGER FMC GEN IV TUBING HANGER 3.500 522.8 522.8 0.83 NIPPLE CAMCO DS LANDING NIPPLE,2.856"NO GO w/2.812" 2.812 I ', ID 8,327.2 6,006.3 41.68 NIPPLE CAMCO D NIPPLE NO GO 2.750 8,334.3 6,011.6 41.61 PBR BAKER 80-40 PBR SHEAR OUT w/10'SEALS 2.992 GAS LIFT,4,514.1 8,348.3 6,022.1 41.41 ANCHOR BAKER ANCHOR 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) f Top(ND) Top Incl Top(ftKB) (ftKB) 0 Des Corn Run Date ID(in) 8,3272 6,006.3 41.68 PLUG 2.75"CA-2 PLUG 10/25/2014 0.000 Perforations&Slots Shot Dens Top(TVD) Btm(ND) (shotstt SURFACE;41.0-4,957.1 Top(ftKB)KB) Btm(ftKB) (ftKB) (ftKB) Zone Date 9 Type Co 8,942.0 8,950.0 6,478.7 6,484.7 C-1,1Q-22 2/3/1998 4.0 APERF 2 1/S"EJ DP;Oriented (+/-)90 deg 9,180.0 9,205.0 6,667.8 A-4,A-3,1Q- 4/18/1996 4.0 IPERF 180 deg.ph;2.5"Hollow GAS LIFT;6,020.3 22- Carrier Mandrel Inserts --- St a8 0. Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make _ Model OD(In) Sent _ Type Type (in) _ (psi) Run Date Corn 2,603.5 2,393.7 BST ATX 1 GAS LIFT GLV T-1 0.156 1,387.0 10/20/2012 GAS LIFT;7,368.4 2 4,514.1 3,588.0 BST -ATX 1 GAS LIFT GLV T-1 0.156 1,359.0 10/20/2012 3 6,020.3 4,581.8 BST ATX 1 GAS LIFT GLV T-1 0.188 1,378.0 10/19/2012 4 7,368.4 5,380.2 BST ATX 1 GAS LIFT GLV T-1 0. 1,357.0 10/1912012 GAS LIFT;8,277.1 5 8,277.1 5,969.0 BST ATX 1-GAS LIFT �0V T-1 0.188188 0.0 10/18/2012 es:General&Safety NIPPLE;8,327.2 End Date Annotation PLUG;0,327.z 10/13/2010 NOTE:View Schematic w/Alaska Schematic9.0 1/19/2015 NOTE: Pumped 26.5 bbl of 15.8 class G cement down the 0/A.TOC approx 3600' PBR;8,334.3 ANCHOR;8,348.3 M PRODUCTION;347-8,569.0 APERF:8,942.0-8,9500 1 _ IPERF,9,180.0.9.205.0 LINER;8,348.6-9,614.0 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: scanned by: Bevedy Dia~~;~athan Lowell Date:~//~7 Is~ [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Isl • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 February 14, 2011 ri FED z Z U 1; RECEIVED Commissioner Dan Seamount FEB 17 f ` Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 IA &Gas Con Cr11" 4ssmi Anchorage, AK 99501 n: ar= 1-1- .∎ �- Commissioner Dan Seamount: ' Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement 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 corrosion inhibitor /sealant was pumped February 10 -12, 2011.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 Perry Klein at 907 - 659 -7043, if you have any questions. Sincerely, MJ Loveland 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 2/15/2011 1B,1D,1E,1Q,1Y /3F,3G,3J PAD Corrosion Initial td at '`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 gal 1B -01 50029204650000 1800400 SF N/A 19" N/A 1.4 2/11/2011 1D -119 50029228360000 1972220 2" 'NIA 23" N/A 4.2 2/10/2011 1E -117 50029232510000 2050260 12" N/A _ 12" N/A 4.2 2/12/2011 1E-121 50029232380000 2042460 6" N/A 18" N/A 4.4 2/12/2011 1Q-21 50029225910000 1951330 5" N/A 5" N/A 5.2 2/12/2011 r> 1Q-22 50029225950000 1951400 5" N/A 5" N/A 3.2 2/12/2011 1Y -06A 50029209580100 1971340 6" N/A 6" N/A 5.2 2/12/2011 1Y -08 50029209440000 1830620 6" N/A 6" N/A 3.3 2/12/2011 3F -19A 50029226800100 2040160 8" N/A - 8" N/A 3.4 2/11/2011 3G -16 50103201350000 1901040 16" 1 N/A 1 8" N/A 3 2/11/2011 3J -17 50029227000000 1961460 SF 1 N/A 1 9" N/A 3.3 2/11/2011 1 I ~.. ConocoPhiliips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 23, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ,- ,_ ~ - , % i7 rr: ~ ~S~ ~'~° r Enclosed please fmd a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped August 29, 2008 and the corrosion inhibitor/sealant was pumped October 17, 2008. 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 Perry Klein at 907-659-7043, if you have any questions. Sincerely, ~,;-~ , ~~$'~~~~ NGIf ~ ~ ~~~a .~ -- ,~~~ , ~. ,~ ~-,~ MJ Loveland 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 n~+e 10/22/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-18 190-153 21' 2.80 27" 8/29/2008 6.80 10/17/2008 1 Q-21 195-133 5" NA 5" NA 1.00 10/17/2008 1Q-22 195-140 5" NA 5" NA 1.00 10!17/2008 1 Q-26 195-132 8" NA 8" NA 1.00 10/17/2008 Schlumberger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well 3M-07 1 E-18 .->þ1 Q-22 1 G-08A 1G-10A 2C-04 2D-05 2P-429 2N-306 1 D-122 1 C-111 1D-114 2V -08A 3M-01 (REDO) 31-04 1 E-1 05 Job# 11015737 11015745 11015744 11072911 11072910 11072907 11072909 11056695 11056696 11015730 11015732 11015728 11072913 11015736 10092325 11015726 ~t\raNEtJ NO\! 022005 Log Description INJECTION PROFILE GLS SURVEY PRODUCTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE PRODUCTION PROFILE TEMPERATURE SURVEY :IL,} a1U SIGNED: 10/07/05 NO. 3492 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk --- Date BL Color CD 09/26/05 1 10/02/05 1 10/01/05 1 10/01/05 1 09/30/05 1 09/27/05 1 09/29/05 1 09/18/05 1 09/19/05 1 09/06/05 1 09/22/05 1 09/04105 1 10/03/05 1 09/25/05 1 10/02/05 1 09/02/05 1 ~__7' DATE: / 7 (\)~JvN-- r Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Cf f" -I i:Ð ~;l___ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, Commissioner THRU: Tom Maunder, P. i. Supervisor DATE: May 17, 2001 FROM: John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests Kuparuk River Unit lQ Pad May 17,2001- i traveled to Phillips Alaska's Kuparuk River Field to witness Safety Valve System tests. Ernie Barndt was PhillipS Rep. in charge of SVS testing. Testing was conducted in a safe & efficient manner. I witnessed one failure, 'the SSV on 1Q-05 would not pass the DP test. The valve was serviced & would not pass the re-test. Well 1Q-05 is shut in until repaired & re-tested. The AOGCC test report is attached for reference. I inspected 20 well houses on lQ Pad w! no problems witnessed. SUMMARY: ! witnessed SVS testing in Kuparuk River Field. 15 wells, 30 components tested. 1 failure witnessed. 3.33% failure rate. 20 well houses inspected. ,.A. ttachments: SVS KRU lQ 5-17-01jc Cc; NON-CONFIDENTIAL SVS KRU lQ 5-17-01jc Alas~,a Oil and Gas Conservation Commis~.oa Safety Valve System Test Report Operator: Phi!!ip...s. Alaska Operator Rep: Emie Barndt AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: K,uparuk,,,Riv~'r Unit lQ Pad .. Separator psi: LPS ..... 85, HPS. , , 5/17/01 ............ t $SSE 'WeII Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE iQ-02A 1~J51940' · lQ-03 1842330 ~5 70: "65 ' 'P P .... OIL 1Q-04 1842340 85 60! 55 P P OIL ,lQ-05 1842170 85 76 . 54 e .,'" '4 ., ' .... OIL lQ-.06 184208,,0 85i 60 . 55 P , e , , OIL lQ-09 1841920 3750 20001 1900 P P WAG lQ-10... 1841980 85 70 62 P , e ....... OIL 1Q-Il 184~990 " lQ-12 1841930 ..... 1 Q715 , 1850460 ,lQ-!6 185o47o , 85., ~ 70 64 P .... e ..... OIL 1Q-20A 1951560 85 70 60 P P OIL !Q-21 1951330 1Q-22 1951400 85 " 76 .... 55i 'P e ..... 0IL 1Q-23 1951410 85! , 70 50'. P P , OIL 1Q-26 1951320 85: 70 52i P' p OIL1 lQ-08' "1970930 37~0' '2000 1850i ' P" ' e ....... WAG lQ-13 ' 1850440 3750! 2000 1850 P e ' WAG lQ-14 1850450 3750 2000 1850 P P WAG 1Q-24 1951210 3750 2000 2100 P P wAG , , Wells: 15 Components: 30 Failures: 1 Failure Rate: 3.33% Remarks: 1Q-05 was serviced & re-tested, re-test failed & well was shut in for repairs. RJF 1/16/01 Page 1 ofl SVS KRU lQ 5-17-01jc ....-, THE MATERIAL UNDER TI-llS COVER HAS BEEN MICROFILMED - ON OR BEFORE JANL ARY 03, 200~- ~ C:LORl\MFu..M.DOC STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Pull tubing _ 2. Name of Operator: 15. ARCO Alaska, Inc. I 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface: 1210' FNL, 1161' FEL, Sec 26, T12N, R9E, UM At top of productive interval: 2505' FSL, 2517' FEU Sec 24, T12N, R9E, UM At effective depth: 2553' FNL, 2286' FEL, Sec 24, T12N, R9E, UM At total depth: 2513' FNL, 2245' FEL, Sec 24, T12N, R9E, UM Stimulate__ Plugging _ Perforate _X Alter casing _ Repair well _ Other _ Type of Well: Development X. Exploratory ~ Stratagrapic ~. Service _~. 6. Datum of elavation (DF or KB feet): 25' RKE 7. Unit or Property: Kuparuk River Unit 8. Well number: 1 Q-22 9. Permit number/approval number: 95-0140 10. APl number: 50-029-22595-00 11. Field/Pool: Kuparuk River Field/Pool 12. Present well condition summary Total Depth: measured 9514 feet true vertical 6995 feet Effective Depfl measured 9414 feet true vertical 6913 feet Casing Length Conductor 80' Surface 4916' Production 8531' Liner 1163' Size 16" 7-5/8" 5.5" 3.5" Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth 224 Sx ASI 121' 121' 820 Sx AS III & 4957' 3875' 410 Sx Class G 149 Sx Class G 8569' 6199' 127 Sx Class G 9512' 6993' Perforation Depth measured true vertical 7330' TO 7340', 7614'-76zk 6359'-6368', 6608'-663z Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80, @ 8349' M£ Packers and SSSV (type and measured depth) Baker sabl-3 Packer @ 8349 MD; NO SSSV 13. Stimulation or cement squeeze summary PERFORATED C1 SAND FROM 8932'-9852' Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 504 288 62 990 221 Subsequent to operation 638 362 72 15. Attachments 116. Status of well classification as: Copies of Logs and Surveys run _ I Daily Report of Well Operations ~X Oil _~X Gas _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed F~~ Title: ~~ ~"~(_~ Form 10-404-Eev06/15/~8 ~ / 1046 227 Suspended _ Service _ Date SUBMIT IN DUPLICA Inc. KUPARUK RIVER UNIT , 'ELL SERVICE REPORT 1Q-22(4-1)) WELL JOB SCOPE JOB NUMBER 1Q-22 PERFORATE, PERF SUPPORT 1104980511.1 DATE DAILY WORK UNIT NUMBER 11/06/98 PERFORATE C1 SAND 2128 -DAY 1 FIELD ESTIMATE OPERATION COMPLETE SUCCESSFUL I KEY PERSON (~ Yes O No ~ Yes O NoI SWS-JOHNSON AFC# CC# I DAILY COST ACCUM COST KAWWRK 230DS10QLI $9,328 $11,183 InitialTbg IFinalTbg IlnitiallA IFinallA IlnitialOA IFinalOA IIILSize 650PSII 650PSII 1250PSl 1250PSl 100PSI 100PSI 0.000 " SUPERVISOR HAUGHT Signed IMin ID I Depth 0.000" 0 FI- DALLY SUMMARY PERFORATE C1 SAND FROM 8932' TO 8952'. USED 2 1/2" HOLLOW CARRIER GUNS, 4 SPF, 180 DEGREE PHASE, ORIENTATED +/- 90 DEGREES FROM THE LOW SIDE. [Peal] TIME LOG ENTRY 11:00 MIRU SWS. TGSM-DISCUSS SAFE PERFORATING SYSTEM. MU SAFE GUN ASSEMBLY. 13:00 P/T LUBRICATOR/BOP TO 3000#. OK. 13:10 RIH W/MH, CCL, MPD HEAD, SAFE GUN (20'- 2 1/2" HOLLOW CARRIER, 180 PHASE, 4 SPF, 90 ORIENTATION) 14:00 AT 9150' ELM. TIE IN WITH COLLARS ON 2/2/98 COMPLETION RECORD LOG. FLOW WELL TO DECREASE TUBING PRESSURE. SI WELL, PULL UP TO DEPTH, FIRE PERF GUN AT 8932'-8952'. WELL SLIGHTLY UNDERBALANCED. APPEARS TO HAVE FIRED. 14:40 PUH WHILE LOGGING TO 8850'. 14:45 POOH 15:45 OOH. ALL SHOTS FIRED. RDMO. INFORM DSO OF WELL STATUS. ASK FOR WELL TO BE BROUGHT ON AND PUT IN TEST. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $o.oo $8o.oo APC $300.00 $300.00 HALLIBURTON $0.00 $1,115.00 LITTLE RED $0.00 $660.00 SCHLUMBERGER $9,028.00 $9,028.00 TOTAL FIELD ESTIMATE $9,328.00 $11,183.00 96/0~/S0 96/L0/S0 96/L0/S0 96/80/~0 T 96/9~/~0 T 96/0~/S0 / X~ojua~uI SIeT~a~PM IPOTBOlOaD IIaM TPnpTATpuI DDDO~ OTzT-S6 O~T-S6 O~T-S6 OTzT-S6 OTzT-S6 OfT-S6 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Stimulatem Plugging__ Perforate~ Alter casing Repair well Other 2. Name of Operator 5. Type of Well: Development X__ ARCO Alaska, Inc. I Exploratory _ 3. Address ~ Stratigraphic _ P. O. Box 100360, Anchorage, AK 99510 Sqrvice _ 4. Location of well at surface 1210' FNL, 1161' FEL, Sec 26, T12N, R9E, UM At top of productive interval 2505' FSL, 2517' FEL, Sec 24, T12N, R9E, UM At effective depth 2553' FNL, 2286' FEL, Sec 24, T12N, R9E, UM At total depth 2513' FNL, 2245' FEL, Sec 24, T12N, R9E, UM 12. Present well condition summary Total Depth: measured 9514 feet true vertical 6995 feet Datum elevation (DF or KB) KB 25 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1 Q-22 9. Permit number/approval number 95-140 10. APl number 50-029-22595-00 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None Effective depth: measured 9414 feet true vertical 6913 feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 4916' 7.625" 8531' 5.5" 1163' 3.5" measured 8942'-8950',9180'-9205' true vertical 6513'-6519',6713'-6734' TUbing (size, grade, and measured depth) 3.5", 9.3#/ft. L-80 @ 8349' Packers and SSSV (type and measured depth) Cemented 224 Sx AS I 820 Sx AS III & 410 Sx Class G 149 Sx Class G 127 Sx Class G Measured depth True vertical depth 121' 121' 4957' 3875' 8569' 6199' 9512' 6993' ORIGINAL Packer: Baker SABL-3 @ 8349; SSSV: None, nipple @ 523' 13. Stimulation or cement squeeze summary Perforate 'C' sand interval on 2/3/98. Intervals treated (measured) 8942'-8958' Treatment description including volumes used and final pressure Perforated using 2-1/8" EJ guns w/DP charges @ 4 SPF, fp = 1900 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation (A only) Subsequent to operation (A+C) 52 78 0 1025 206 646 294 38 1028 217 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil X__ Gas 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed FO Title Wells Superintendent Form 10-404 R~ Suspended Service Date "-~/,2 '~/¢'~''~ SUBMIT IN DUPLICATE RECEIVED 27 1998 Alaska 0il & Gas C~s, Co~,~ Alaska, Inc. KUPARUK RIVER UNIT '~' WELL SERVICE REPORT '~ KI(1Q-22(W4-6)) -'WELL JOB SCOPE JOB NUMBER 1 Q-22 PERFORATE, PERF SUPPORT 0130981840.5 DATE DAILY WORK UNIT NUMBER 02/03/98 PERFORATE, PERF SUPPORT DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR I (~) Yes (~ NoI (~) Yes O No SWS-DALEBOUT ~ FIELD AFC# CC# DALLY COST ACCUM COST ESTIMATE KAWWRK 230DS10QL $1 3,1 99 $15,307 Initial Tbq Press . Final Tb.q Press Initial Inner Ann Final Inner Ann I Initial Outer AnI~ I Final Outer Ann 1 900 PSI 1 900 PSI 1450 PSI 1 450 PSII I1 50 PSI 1 50 PSI DALLY SUMMARY PERFORATE F/8942 - 8958' ELM W/2-1/8" EJ DP @ 2 SPF, +/- 90 DEG (4 SPF TOTAL). TIME 20:00 21:45 01:00 03:00 04:00 06:45 LOG ENTRY MIRU SWS (DALEBOUT & CREW). TGSM & JOB OVERVIEW. MU GUN ASSEMBLY #1 (16' 2-1/8" EJ DP/CCL/GR/WT) TL - 25'. PT BOPE TO 3000 PSL RIH TO 9150' ELM. TIE IN 2/17/96 SWS PHASOR DUAL INDUCTION - GR. CONFIRMED THAT GUNS WERE LOADED INCORRECTLY (4 SPF VS 2 SPF). POOH TO CHANG,E GUNS. AT SURFACE. REMOVE GR & MU CORRECT GUN ASSEMBLY (16' 2-1/8" EJ DP/CCL/WTI TL-20'. PT & RIH. TIE IN W/COLLARS. PERFORATE F/8942 - 8958' ELM W/2-1/8" EJ DP @ 2 SPF, +90 DEG F/LOW SIDE OF HOLE. GOOD SURFACE INDICATIONS. POOH. AT SU~r~Uh_. ALL o~iOTS FIRED. MU GUN ASSEMBLY #3 (16' 2-1/8" EJ DP/CCL/WT) TL -20'. PT & RIH. TIE IN & PERFORATE F/8942 - 8958' ELM W/2-1/8" EJ DP @ 2 SPF, -90 DEG F/LOW SIDE OF HOLE (SHOT TOTAL OF 4 SPF 180 DEG PHASED). GOOD SURFACE INDICATIONS. POOH. 07:30 AT SURFACE. BEGIN RD. '-SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $210.00 APC $500.00 $500.00 HALLIBURTON $0.00 $1,058.00 LI-I-FLE RED $440.00 $1,280.00 SCHLUMBERGER $12,259.00 $12,259.00 TOTAL FIELD ESTIMATE $1 3,1 99.00 $1 5,307.00 ARCO Alaska, Inc. Post Office Box 1003~u Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 22, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1Q-22 (Permit No. 95-140) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 1Q-22. This well was top set above the Kuparuk formation by Parker rig 245 because of high reservoir pressure. The well was later drilled out by Nordic rig #1 and a 3.5" liner run to T.D. If there are any questions, please call 263-4622. Sincerely, W. Isaacson Drilling Engineer Kuparuk Drill Site Development WSI/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION ,., .)MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL ~] GAS [---I SUSPENDED I---I ABANDONED [] SERVICE r---I 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 95-140 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22595 4 Location of well at surface 9 Unit or Lease Name At Top Producing Interval ~ ~- · '/~,'~'~,~ ~ I ~ 10 Well Number At Total Depth ~~~ .... ~ 2513' FNL, 2245' FEL, Sec. 24, T12N, RgE, U~~'~¢'~' ....... ~.-,: :. - KUPARUK RIVER 5 Elevation in feet (indi~te KB, DF, etc.) 6 Lease Designation and Serial No. Nordic ~1 Rig RKB 25', Pad 53' ADL 25634 ALK 2567 12 Date Spudded 13 ~te T.D. Reached 14 Date ~mp., Susp. or A~nd. 15 Water Depth, if offshore I16 No. of Completions 10-3-95 02-11-96 (drillout) 18-Apr-96 (pe~d) NA feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Su~ey 20 Depth where SSSV sel I 21 Thickness of ~rmafrost 9514' MD & 6995' TVD 9414'MD&6913'~D YES ~ NO ~ NA feelMDI = 1380'ss APPROX 22 Ty~ Electric or Other Logs Run ARC5/GR, G~CC~CBT 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE ~ GRADE TOP B~ HOLE SIZE CEM~ RECO~ 16" 62.58~ H-40 SURF. 121' 24" 224 sx AS I 7.625" 29.7~ L-80 SURF. 4957' 9.875" 820 sx AS III Lead, 410 sx Class G Tail 5.5" 15.5~ L-80 SURF. 8569' 6.75" 149 sx Class G 3.5" 9.2~ L-80 8348' 9514' 4.75" 127 sx Class G 24 Pedorations o~n to Production (MD+TVD of Top and Bo,om and 25 TUBING RECORD inte~al, size and numar) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 8349' 8349' 9180'-9205'MD 4 spf 6721'-6742'TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9180'-9205' 1660 bbls fluid and 13860~ 20/40 and 139191~ 1~18 LDC proppant from 2 to 10 ppa. Placed 123418~ at 10 ppa in formation. 25000~ left in wellbore. 27 PRODUCTION TEST Date First Production IMethod of O~ralion (Flowing, gas li~, etc.) 5/10/96~ Gas Li~ Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 7/25/96 12 TEST PERIOD ~ 6 6 127 0 0~ 1919 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press 204 767 24-HOUR RATE~ 132 254 0 ~24° 28 CORE DATA Brief description of lithology, ~rosity, ~actures, apparent dips and presen~ of oil, gas or water. Submit core chips. RECEIVED Nas~a 0il & 6as Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ;'9. ' 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 8812' 6403' Bottom Kuparuk C 8959' 6527' Top Kuparuk A 9162' 6698' Bottom Kuparuk A 9308' 6821' RECEIVED AUG 2 3 1996 Alaska 011 & Gas Oon~, Cornmi~sior~ A~ch0rage Freeze protect annulus. 31. LIST OF A'I-I-ACHMENTS Daily Drilling History, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. 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, a~r injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 5/22/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 1 WELL:lQ-22 RIG:PARKER 245 WELL ID: AK8293 AFC: AK8293 TYPE: -- STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:10/03/95 START COMP: BLOCK: FINAL' WI: 0% SECURITY:0 AFC EST/UL:$ 1240M/ API NUMBER' 50-029-22595-00 OM 10/03/95 (1) TD- 600' (600) SUPV: RLM DAILY: 10/04/95 (2) TD: 4970' (4370) SUPV'JT DAILY' 10/05/95 (3) TD: 4970' ( 0) SUPV:JT DAILY: 10/06/95 ( 4) TD' 5065' ( 95) SUPV: JT DAILY: 10/07/95 ( 5) TD' 6433' (1368) SUPV: JT DAILY: 10/08/95 (6) TD: 8108' (1675) SUPV:JT DAILY: 10/09/95 (7) TD: 8822' (714) SUPV: JT DAILY: 10/10/95 (8) TD' 8822' ( 0) SUPV'JT DAILY: MW: 9.2 PV/YP: 33/19 APIWL: 8.8 DRILLING Move rig from 1Q-23 to 1Q-22. Accept rig at 1930 hfs 10/2/95. Nipple up diverter. Function test diverter. Clean out conductor from 95' to 121' Spud at 0030 10/3/95. Drill from 121' to 600' $125,824 CUM: $125,824 ETD: $0 EFC: $1,365,824 MW: 10.0 CIRC Drill from 600' to 4970' $79,914 CUM: $205,738 ETD' PV/YP: 21/19 APIWL: 8.0 $0 EFC' $1,445,738 MW- 10.1 PV/YP: 18/ 7 APIWL: 7.8 NU BOPE Run surface casing. Cement casing. $171,165 CUM' $376,903 ETD: $0 EFC' $1,616,903 MW: 8.5 PV/YP: 4/ 3 APIWL: 17.5 NU BOPE Test annular preventer. Tag cement @ 4735' & drill to cement plug @ 4842' Test casing. Drill cement, plugs and 10' new formation. Perform EMW test. Drilled from 4980' to 5065'. $72,228 CUM: $449,131 ETD: $0 EFC: $1,689,131 MW: 8.7 TRIPPING TO REPLACE MWD Drilled from 5065' to 6433' $90,503 CUM' $539,634 ETD' PV/YP: 6/ 8 APIWL: 14.6 $0 EFC' $1,779,634 MW' 9.1 TRIPPING TO UNPLUG MWD Drilled from 6434' to 8107' $76,298 CUM' $615,932 ETD: PV/YP: 13/ 7 AP IWL' 7.2 $0 EFC: $1,855,932 MW: 11.0 PV/YP: 20/ 8 APIWL: 4.4 CIRC AND RAISING MW Drillstring plugged off. Bit plugged with steel. Drilled from 8108' to 8822' Splintered shale on screens. $89,177 CUM: $705,109 ETD: $0 EFC: $1,945,109 MW' 12.4 PV/YP' 30/14 APIWL: 4.2 RIH TO CEMENT HIGH PRESSURE ZO Raised mud weight to 12.4 ppg until well dead. RU to run 3-1/3" tubing stinger. RIH with DP to cement off high pressure zone. $96,030 CUM: $801,139 ETD: $0 EFC' $2,041,139 Date: 5/22/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 2 10/11/95 ( 9) TD: 8822' ( 0) SUPV:RLM DAILY: 10/12/95 (10) TD: 8822'( 0) SUPV:RLM DALLY: 10/13/95 ( 11} TD: 8575' ( 0) S UP V: RLM DAILY: 10/14/95 (12) TD: 8575' ( 0) SUPV:RLM DAILY: 02/06/96 { 13) TD: 8569' ( 0) SUPV: DLW DAILY: 02/07/96 (14) TD: 8577' ( 8) SUPV:DLW DAILY: 02/08/96 (15) TD: 8746' ( 169} SUPV:DEB DAILY: 02/09/96 ( 16} TD: 8746' ( 0} SUPV: DEB MW: 12.3 PV/YP: 31/16 APIWL: 6.4 REDUCE MUD WT. Lay cement plug from 8822' to 8325'. Preceeded cement with 30 bbls 11.5 ppg spacer, pumped 22 bbls G cement. CIP at 1214 hfs 10/10/95. Wait on cement. $93,658 CUM: $894,797 ETD: $0 EFC: $2,134,797 MW: 11.3 PV/YP: 22/14 APIWL: 7.2 POOH TO RUN CASING Circulate and reduce mud weight to 11.3 ppg. Run in hole to wash and ream. Hit hard cement. POOH. $68,923 CUM: $963,720 ETD: $0 EFC: $2,203,720 MW: 11.3 PV/YP: 20/14 APIWL: 7.2 INJECTING MUD Run 5.5" casing. Cement casing. CIP at 0008 hfs 10/13/95. Freeze protect 7-5/8" x 5.5" annulus. $140,855 CUM: $1,104,575 ETD: $0 EFC: $2,344,575 MW: 0.0 RIG RELEASED Released rig @ 0700 10/13/95. $21,759 CUM: $1,126,334 ETD: PV/YP: 0/ 0 AP IWL: 0.0 $0 EFC: $2,366,334 MW: 8.4 PV/YP: 0/ 0 APIWL: 0.0 P/U 2-7/8" DP BREAK IN Move rig to 1Q-22. Accept rig @ 1600 hrs 2/5/96. N/D tree. N/U BOP's. Test BOP's and choke manifold 300-5000 psi, test Hydril ato 3000 psi. RIH open ended drill pipe to pump out diesel. Freeze protect well. $23,649 CUM: $1,149,983 ETD: $0 EFC: $2,389,983 MW: 11.9 PV/YP: 24/ 7 APIWL: 6.0 DRILL 4-3/4" @ 8577' RIH w/2-7/8" drillpipe to 3317' RIH with BHA %1. Fill pipe every 2000' to 8415' Tag cement. Wash and clean out fill and cement from 8415 to 8503'. Test 5-1/2" casing @ 8503' to 3500 psi for 30 min. OK. Continue to clean out cement and shoe @ 8558' cement to 8575' $44,567 CUM: $1,194,550 ETD: $0 EFC: $2,434,550 MW: 11.9 PV/YP: 25/ 9 APIWL: 4.0 CIRC SLOW @ 8716' CHECK PUMP , Drill formation from 8575' to 8597' Test formation to 700 psi, 14.1 ppg EMW, no leak off. Drill to 8746' Repack plunger in pump. Work on mud pump. RIH 3 stands and PU kelly. Circulate @ 8716' Stuffing box still leaking, try to tighten. $36,658 CUM: $1,231,208 ETD: $0 EFC: $2,471,208 MW: 11.9 PV/YP: 24/ 9 APIWL: 4.0 WASH & REAM BACK TO BOTTOM Work on mud pump. Remove %1 stuffing box & replace O-ring. Still leaks, believe leak to be around sleeve in stuffing box & around O-ring. Remove %1 fluid end and stuffing box. Remove other 2 fluid ends and stuffing goxes. Prepare fluid ends. Install 3 new stuffing boxes on fluid ends & re-install on mud pump. Reassemble mud pump and test. OK. Attempt to circulate, hole frozen up. Work pipe holding 5/22/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 3 DAILY: 02/10/96 (17) TD: 9081' (335) SUPV:DEB DAILY: 02/11/96 (18) TD: 9404' (323) SUPV: DEB DAILY: 02/12/96 (19) TD: 9514' (110) SUPV:DEB DAILY: 02/13/96 (20) TD: 9514' ( 0) SUPV:DEB DAILY: 02/14/96 (21) TD: 9514' ( 0} SUPV:DEB DAILY: 2000 psi, worked free and established circulation. Circulate out slushy mud & warm up hole. Break circulation. Hole packing off & sticking. Rotate pipe & circulate until pipe washed free. Wash & ream 5 singles back into hole to 8716' Hole sticky in old rathole just below casing shoe, cleaned up OK. Got lots of shale cavings over shaker at bottoms up. Hole cleaning up, still getting some cavings. $22,173 CUM: $1,253,381 ETD: $0 EFC: $2,493,381 MW: 11.9 DRILLING @ 9081' MD Drill 8746' to 9081' $38,619 CUM: $1,292,600 ETD: PV/YP: 25/17 AP IWL: 3.8 $0 EFC: $2,532,000 MW: 11.9 PV/YP: 21/16 APIWL: 4.2 DRILLING @ 9404' Drill 9081' to 9134'. Make 9 stand precautionary short trip to condition hole. Worked thru tight spots at bit depths of 8780',8715' & 8655' Worked thru tight spots, pulled into casing shoe, & ran back to bottom, no fill. Drill 9134' to 9404' $34,828 CUM: $1,326,828 ETD: $0 EFC: $2,566,828 MW: 11.9 PV/YP: 21/18 APIWL: 4.2 CIRC & WU TO 12.1 PPG FOR TRIP Drill 9404' to 9419'. Blowdown & standback kelly. Precautionary short trip 14 stands into casing shoe & back to bottom. No tight spots. Changed out swivel packing while inside casing. Wash & ream 30' to bottom. Drill 9419' to 9514' Standback kelly. POH, tight spot @ 9474' Short trip into casing shoe. Monitor hole, no flow. Wash & ream 3 singles to bottom, 9379' to 9514' OK. Circulate hole clean, gas cut to 11.0 ppg with some oil at bottoms up. Weight up. $35,275 CUM: $1,362,103 ETD: $0 EFC: $2,602,103 MW: 11.8 PV/YP: 21/16 APIWL: 3.8 SOAK & WORK STUCK PIPE Start POH, pulled into tight spot @ 9474'. Try to free pipe down, no go. Work pipe up, down & rotate, all no go - pipe stuck with bit @ +/- 9474' Recovered some chips of shale, but no significant amount. Continued working pipe. Spot SFT pill. Continue working stuck pipe. $47,129 CUM: $1,409,232 ETD: $0 EFC: $2,649,232 MW: 11.8 PV/YP: 24/17 APIWL: 3.8 PREPARE TO FIRE BACK-OFF SHOT Continue working stuck pipe. RIH with APRS Free Point Tool. Tools slowed to a stop, unable to run below 6870', area of maximum hole angle. POOH. RIH with Free Point tool. DP free to top of DCs. Top of 1st DC appears free. POOH. RIH with FP tool. Top DC free. Bottom of 5th DC/top of 6th DC stuck. Intermittent movement at top of 5th DC. 4th & 3rd DC mostly stuck. 2nd DC mostly free. Top of DCs @ =/- 9004' MD. POH. RIH with String Shot & tie into 1st DC. Set string shot at bottom of first (top) DC. $33,745 CUM: $1,442,977 ETD: $0 EFC: $2,682,977 .: 5/22/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page' 4 02/15/96 (22) TD' 9514' ( 0) SUPV:DEB DAILY' 02/16/96 ( 23) TD: 9514' ( 0) SUPV:DEB DAILY: 02/17/96 ( 24} TD: 9514' ( 0} SUPV: DEB DAILY: 02/18/96 ( 25) TD' 9514' ( 0) SUPV:DEB DAILY' 02/19/96 ( 26) TD' 9514' ( 0) SUPV:DEB DAILY' MW: 11.8 PV/YP: 22/18 APIWL: 3.8 WORKING DP TO FREE FISH Work 7 rounds LH torque into DP. Fire string shot at bottom of first (top) DC. Pipe free, got back-off. POH. Lost shot rod in hole, +/-6' piece of 1/4" steel rod. POH 142 stands DP + XO +1, 3-1/2" DC. Test BOPE. RIH with FTA %1. Tag top of fish @ 9034' Screw into fish. Work pipe, jar down on bumper sub, jar up occasionally, torque up and work pipe. $91,160 CUM: $1,534,137 ETD: $0 EFC: $2,774,137 MW: 11.9 PV/YP:. 21/21 APIWL: 3.8 POH W/FTA %1 & FISH Work pipe to free stuck BHA. Jar down and work pipe. NO movement of fish. Pump SFT pill. Continue working pipe. Pipe broke free jarring down. Work pipe free. Circulate out remaining SFT pill. POH with FTA %1 fish. $45,617 CUM: $1,579,754 ETD: $0 EFC: $2,819,754 MW: 11.8 PV/YP: 26/20 APIWL: 3.8 WASH & REAM BACK TO BOTTOM POH with FTA %1 & fish. LD top Spiral Drill Collar. RIH w/BHA. Drop 1-1/4" drift with slickline pigtail in BHA to float looking for APRS 1/4" x 6' long String Shot Rod. POH to float, recovered drift, but no shot rod RIH to 8528' · , just above 5-1/2" casing shoe. Add "Liquid Casing" LCM to system. Wash and ream down singles, no ledges or tight spots. $69,833 CUM: $1,649,587 ETD: $0 EFC: $2,889,587 MW: 11.9 PV/YP: 24/20 APIWL: 3.8 POH WITH SWS LOGGING TOOLS Wash & ream singles to bottom @ 9514' Ream thru tight spots @ 9340', 9381', & 9414'. Motor drilled and reamed last 3 singles to bottom, hole tight & sticky. After drilling down, washed & reamed each of last 3 singles 2 or 3 times until hole cleaned up & worked freely. RIH with 3-5/8" SGT/DITE, log down & tag bottom @ 9512' Start logging up fro 9504', tool stuck @ 9450' Work wire, pull maximum line pull to free tool. Tool finally pulled free. POH logging into casing, tools malfunctioning. POH with logging tools. $34,723 CUM: $1,684,310 ETD: $0 EFC: $2,924,310 MW: 11.9 PV/YP: 24/20 APIWL: 3.8 START RIH W/3-1/2" LINER ON DP Wash & ream kelly to bottom. No bridges, last 2' on bottom sticky. Circulate hole clean. Work pipe 70' & rotate down last 40' with kelly while circulating. Pipe rotates OK. POH 15 stands into casing. Pulled tight at 9317', packing off, circulated & worked pipe, pulled sticky spot up hole 30' & pulled through. Worked back thru, OK. Had another small tight spot @ 8605', worked through OK. RBIH 15 stands. PU kelly, ream to bottom. NO ledges, no fill. POH 16 stands into casing. Pulled through two small tight spots @ 8749' & 8605'. Run 3-1/2" liner on DP. $34,443 CUM' $1,718,753 ETD' AUG 2 1996 Alaska 011 & Gas Cons. Commission Anchorage 5/22/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 5 02/20/96 ( 27} TD: 9514' ( 0) SUPV:DEB DAILY: 02/21/96 ( 28) TD: 9514' ( 0) SUPV:DEB DAILY: 02/22/96 (29) TD: 9514' ( 0} SUPV:DLW DAILY: 02/23/96 (30) TD' 9514' ( 0) SUPV: DLW DAILY: 02/24/96 ( 31) TD: 9514' ( 0) SUPV.DLW DAILY: MW: 11.9 PV/YP: 26/24 APIWL: 4.0 POH WITH DP & LINER RIH with 3-1/2" liner on 2-7/8" DP to 5-1/2" casing shoe. Pump cement. $88,273 CUM: $1,807,026 ETD: $0 EFC: $3,047,026 MW: 11.8 PV/YP: 30/22 APIWL: 5.2 PUMP CEMENT Continue POOH w/3-1/2" liner looking for wiper plug. Drift 2-7/8" DP found plug in the 5th joint of 3-1/2" liner. POOH. Rerun 3-1/2" liner with New Baker liner hanger PKR. Run 3-1/2" liner thru open hole for 5.5" csg shoe @ 8553' Nordic RKB to 9514' Pump cement. CIP @ 0610 hrs. 2/21/96. $57,557 CUM: $1,864,583 ETD: $0 EFC: $3,104,583 MW: 11.8 PV/YP: 28/17 APIWL: 4.2 RUN 3-1/2" COMPLETION Release from 5.5" x 3.5" Baker liner hanger packer. POOH. Run 3.5" completion assembly. $49,589 CUM: $1,914,172 ETD: $0 EFC: $3,154,172 MW: 8.5 PV/YP: 0/ 0 APIWL: 0.0 ND BOPS & NU TREE Continue running 3-1/2" completion w/jewelry to 100' of 5.5" x 3.5" liner top Pkr @ 8348' Test casing to 3500 psi/30 min. OK. Continue running tubing. Freeze protect well. Test annulus to 3500 psi/15 min., OK. Test tubing to 3500 psi/15 min., OK. $120,805 CUM: $2,034,977 ETD: $0 EFC: $3,274,977 MW: 8.5 PV/YP: 0/ 0 APIWL: 0.0 RELEASE RIG N/D BOP's. N/U tree and test packoff to 250/5000 psi for 15 min. OK. Test tree to 250/5000 psi. OK. Release rig @ 1200 hrs. 2/23//96. $18,998 CUM: $2,053,975 ETD: $0 EFC: $3,293,975 End of WellSummary for Well'AK8293 ,.;O Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT '~' K1(1Q-22(W4-6)) WELL JOB SCOPE JOB NUMBER 1 Q-22 PERFORATE, PERF SUPPORT 1 228951620.4 UNIT NUMBER DATE 04/18/96 DAY 3 DALLY WORK PERFORATE A SAND OPERATION COMPLETE I SUCCESSFUL I KEYPERSON YES YES SWS-BAILEY InitialTbcjPress-iFinalTbgPress IlnitiallnnerAnn IFinallnnerAnn10PSI 900 PSI OPSl 0PSI SUPERVISOR GOLDEN Initial Outer Ann I 200 PSI I Final Outer Ann 200 PSI DALLY SUMMARY PERFORATED A SAND F/9180'-9205' WITH 2-1/2" HOLLOW CARRIER (BIG HOLE CHARGES, 4 SPF, 180 DEG PHASING, 24 DEG CCW F/HIGH SIDE OF HOLE). HAD TO PULL 4100# TO FREE GUN#2 AFTER FIRING. TIME LOG ENTRY 18:00 MIRU SWS. TGSM-SNOW BERM AROUND WELLHEAD. 18:45 21:30 23:45 01:00 PT LUBRICATOR TO 3500 PSI - GOOD.RIH W/CCL, GR, MPD,5'-2 1/2" HOLLOW CARRIER (4 SPF, 180 DEG PHASING, 24 DEG CCW F/HIGH SIDE OF HOLE, BIG HOLE CHARGES).TIED INTO GR FROM OPEN HOLE LOG DATED 2/17/96.PRESSURED WELLBORE TO 1200 PSI. PERFORATED 9200'-9205'. WHP DROPPED TO 1050 PSI.POOH, SLIGHT PULL RIGHT AFTER FIRING, LET GO AT 800# ABOVE NORMAL. NO FURTHER PROBLEMS POOH. ALL SHOTS FIRED. PT LUBRICATOR TO 3500 PSI - GOOD.RIH W/CCL, MPD, 20' 2-1/2" HOLLOW CARRIER (4 SPF, 180 DEG PHASING, 24 DEG CCW F/HIG SIDE OF HOLE, BIG HOLE CARGES). TIED INTO PREVIOUS GUN RUN.WHP (BEFORE) = 1500 PSI, PERFORATED 9180'-9200', WHP (AFTER) = 1370 PSI.GUN STUCK. PULLED FREE AT 4100# (2600# ABOVE THE NORMAL WEIGH'I-).POOH. ALL SHOTS FIRED. NO GUN ABNORMALITIES NOTED (MEASURED OD 2.6-2.7"). RD SWS. MIRU APC DHP.UNABLE TO PUMP INTO WELL AT 3000 PSI.BLED WHP TO 300 PSI, WHP BUILT TO 600 PSI IN 5 MINUTES. RD APC DHP. RECE ',/ED AUG 7) 1996 'Nast~a Oil & Gas Cons. commiSSiOn At~chorage :'~':-4,fid :"': ':' ~'}?? ,77 5?5,35 "" ....... "-- 44':~...':..':..:'..5: ! ~'':7< ,-~ ~=L;:_~zl..~ .'~ · ~ ;--'.'~,,= , -. ........ ~:Z:i 7£ ....... :%.' .~'~ -" J .-' , i :; 2 ,. '-2 C.- ; .' '-.5.~:', 15 '.71 ~ ¢ 53}0,50 .....'P~-~, ~ ~;,. q: ~.., ~.,, ~:~, ,., .... ' ......::-::.vt ' ..... ' .... '. :';5,?: ARCO Alaska, Inc. Date' May 1 3, 1996 Transmittal #: 9688 RETURN TO' ARCO Alaska, Inc. Attn.: Julie Nash Kuparuk Operations File Clerk ATO-1119 B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. receipt and return one signed copy of this transmittal. qJ'"'~"f~ 1 Q-22 q&--~Z-1F-19 ,Ir&-/S" 3H-24 ¢3H-28 Acknowledged: ARC 5 10/O9/95 ARC 5 03/22/96 CDR O2/O4/96 CDR 02/13/96 ~ ~0~6 Please acknowledge 4957-8790 4568-9457 50-103-20235-00 50-103-20236-00 50- i 03-20236-00 · ., Date: "..,-,,, 2 (.~ i99G DISTRIBUTION' Mr. Vernon E. Pringle Jr. DeGIoyler and MacNaughton One Energy Square Dallas, TX 75206 Sharon AIIsup-Drake DS Development ATO- 1205 Clifton Posey Geology ATO - 1251 ChapmanZuspan NSK Wells Group NSK 69 Larry Grant AOGCC 3001 Porcupine Drive Anchorage, AK 99501 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 A'FI'N: Sherrie NO. 10173 Company: Alaska Oil & Gas Cons Comm Attn' Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 5/6/96 Field: Kuparuk (Open Hole) LIS Well Job # Log Description Date BL RF Sepia DIR MWD Tape 1Q-22 ~-- ! ~[0 95340 ARC5 951 009 1 1F-19 ~'(~.- 0 ~-;~- 96099 ARC5 960322 1 3H-24 q~,-~ ~- 96073 ~ 960204 I I 1 3H-28 %{% 0 ~ 96087 ~ 960213 1,, 1 3H-28 96087 ~CON 960213 I 1 3H-28 ~ 96087 CD~CDN 96021 3 1,~ SIGNED' ___ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. ARCO Alaska, inc. Date: April 23, 1996 Transmittal #: 9673 RETURN TO: ARCO Alaska, Inc. Attn.: Julie Nash Kuparuk Operations File Clerk ATOo1119B P.O. Box 100360 Anchorage. AK 99510-0360 Transmitted below are the following Cased Hole items. receipt and return one signed copy of this transmittal. %-07;L 1F-19 Cement Bond Log SLTJ-GR/CCL 04/12/96 ~l"-I ~'~ 1Q-21 Cement Bond Log SLTJ--GR/CCL 04/14/96 t~"'-.-l,-f, o1Q-22A Cement Bond Log SLTJ-GR/CCL 04/14/96 q4-'-/.r/'~ 2X-17 Cement Bond Log SLTJ-GR/CCL 04/11/96 ~.~¢ 3H-24 Cement Bond Log SLTJ-GR/CCL 04/14/96 Receipt ~~ Acknowledge: Date' DISTRIBUTION' Sharon Allsup-Drake DS Development ATO-1205 Larry Grant (+sepia) AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Please acknowledge 6682-9356 9155-10318 8172-9383 6000-7644 10910-11912 Chapman/Zuspan NSK Wells Group NSK69 ARCO Alaska, Inc. Date: April 3, 1996 Transmittal If: 9357 RETURN TO: ARCO Alaska, Inc. Attn.: Julie Nash Kuparuk Operations File Clerk ATO-111 9 B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. Please acknowledge ,receipt and return one signed copy of this transmittal. 1 Q-21 1Q-22A ..,./3 H-28A r-,I (~- ~.~ J",,3 H_ 28 A 1Q-20A Acknowledged: Dual Induction-SFL 02/29/96 Phasor Dual INduction-GR 02/1 7/96 CDR 02/17/96 CDN 02/27/96 P ha~~cl~ctio~~/~ 02/02/96Date' 9434-10412 8342-95O4 50-103-20236-01 50-103-20236-01 6950-7915 DISTRIBUTION: Mr. Vernon E. Pringle Jr. DeGIoyler and MacNaughton One Energy Square Dallas, TX 75206 Sharon Allsup-Drake DS Development ATO - 1205 Clifton Posey Geology ATO - 1251 ChapmanZuspan -"SK.~ Wells G:oup, NSK 69 Larry Grant AOGCC 3001 Porcupine Drive Anchorage, AK 99501 March 18, 1996 William S. Isaacson Drilling Engineer Kupan~ Drill Site Development ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 TONY KNO WLES, G 0 VERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re: Requested annular disposal of cement washdown water from coiled tubing cement squeezes Dear Mr. Isaacson: The Commission has received your request for authorization for disposal of cement washdown water from cement squeeze operations in the annuli of wells currently being utilized by Parker Rig #245. The washdown water would be generated by cement squeeze operations on the following wells: 1Q-02A, 1Q-20A, 1 Q-22, and 2M-09. Disposal would take place into the annuli of wells being used by Parker Rig #245 on drill sites IF, 2A, or 2M, for which annular disposal has already been authorized. ARCO Alaska, Inc. (ARCO) must demonstrate that complying with the limitation of disposal through the annular space of a well on the same pad is imprudent. There are annuli available for disposal on the lQ pad. The cement squeeze operations w/ii each generate an estimated 30-50 bbls of water and 1 bbl of cement. Grind and inject facilities are not required for disposal of the cement washdown water generated during these squeeze operations. Pending submittal of information that it is imprudent not to do so, the Commission denies the request by ARCO Alaska, Inc. to dispose of cement washdown water from the 1Q-02A, 1Q-20A and 1 Q-22 wells in the annuli of wells not located on 1Q pad. The cement washdown water from these wells mav be either injected iv, to annuii on the iQ pad, or disposed of in a Class I well. The Commission also suggests the cement washdown water from the 2M-09 well be temporarily stored and disposed of when Parker Rig #245 is conducting annular inject/on operations on the 2M pad. As an alternative to storage, the cement washdown water from the 2M-09 well may also be disposed of in a Class I well. J. David Norton, P.E. Commissioner Tuckerman Babcock Commissioner 0 (.) n '- "'"r 0 Z o ARCO AlasV, a, Inc. Post Office Box 100360 Anchorage, Alaska 99SI0,-03,60 Telephone 907 276 1215 q-z - '~',.,,. David W. '"~--*-~' r~.,~. AI~Ra Oil And Gas Conservation Commission 300t Porcupine Ddve Anchorage, AK 99501 907) 279-1433 @07) 276-7542 (fax) Annuiar Disposal of 'Drilling Wa.~ts-~' ~cr Cement Squeeze Operations on KRU Wells 1Q-02A, 1Q.20A, 1Q-22, and 2~M-09 Gentlemen: ARCO hereby requests a waiver to the AOGCC ReguIations coverfng Annular Disposal of Bdlling Waste recently adopted by the Commission on January 31, 1996. This waiver is requested to cover ARCO's cement squeeze operations on wells 1Q-02A, 1Q-20A, 1Q-22, and 2M-09. Each of the lQ wells were recently ddlled and completed. Due to difficulties in the cementing portion of the drilling operations, cement squeezes will be necessary prier to bringing the wells on service. Well 2M-09 is currently planned for sidetrack operations and a cement squeeze is necessary in order to plug and abandon the existing wellbore. The waiver being requested is to Section (d), Part (4) of 20 AAC 25.080., which limits the annular disposal of drilling waste, to drilling operations on the same drill pad as the annulus being injected into. ARCO requests the AOGCO grant permission to allow cement wash-water generated from cement squeeze operations on the aforementioned wells, be injected into the annulus being used at that t~me by Parker ¢245 on drill site 1F, 2A, or 2M. We appreciate your consideration of this request. If you have any questions or require any additional information on this ma~er, please contact me at 263-4622. William S. Isaacson Ddlling Engineer Kuparuk Ddll Site Development ;: r:.::' :':.' ARCO Ai~ka, Inc. is a Subsidiary of At, laaticR{cbJlel(ICom~aay ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 ~ Telephone 907-276-1215 :" November 6, 1995 Mr. Bob Crandall Alaska Oil & Gas Conservation Commission . 3001 Porcupine Dr. ^ '" '"~-^ rag e, ^ ~' 99501 :-' '"" ")~. ,. /""",l I~,.~i i~.,~ /'"ti \ ...., . .. ~,,~..,t'-J,~_ Subject' '- Waiver of Continuous Directional Surveys. on KR~J 10 Pad Driil-Outs"~?.J,'/'''~,,. . Dear Mr. Crandall' As per our telephone conversation of October 27, i995, the following letter is to confirm the waiver of continuous directional surveys on KRU wells 1Q-20A, 21, and 22. Each of these wells was originally planned to be drilled to total depth and 5-1/2" casing run through the Kuparuk. Unexpectedly, the 5-1/2" casing had to be set above the Kuparuk due to extreme fluid loss in shallow formations or high pressures encountered within the Kuparuk interval. Currently, each of the wells has continuous directional surveys from the surface to within 190' TVD of the top of the Kuparuk Formation. Standard practices in the Kuparuk field are to drop magnetic single shot surveys at TD when the Kuparuk is top set or when the MWD is left out of the drilling assembly used to TD the well. Due to the reduced size of the hole to be drilled-out below the 5-1/2" casing, equipment needed to acquire a single shot survey at TD is currently not available, or what is available substantially reduces the dependability of the drill string bottom hole assembly. As well, standard cased hole gyro survey tools can not be run due to internal diameter constraints of the 3-1/2" liner to be run in each of the lQ drill-outs. Plans are to drill-out each well with a drilling assembly designed to hold the final angle at which the 5 1/2" casing was set and drill to the predicted TD. Future wells .. ,_.,e drilled-nut_ . _..._h~lnw F-1/2". . casing..- will.,,. ,r'"-n"ir=, th,-, ~mr~, ,ieltlr~n~ ....., ,-'¢.., th".., app,.,..,.~,.. m~~=,i*l~,..,,..,,,..,,.. .*.'~,~- =,"'~F,!e.., ,~...,, single shot surveys to be taken at TD, Included with this letter is a plot of actual directional data from drilling operations to date with the estimated 3-1/2" liner setting depth for each drill-out. Thank you, and please feel free to call if you have any questions or comments. I can be reached at 263-4622. Sincerely, William S. isaacson Drilling Engineer ARC'0 ALAS*~-, ,~, mA, inc. ..t ....... j,a : ,O Well : 20A Field : Ku~aruk River UniJ Location : Norih Slope, Alaska ~,. ~: ~.00 East : 50 3 ! 50 500 ~50 600 --> 750 , 9OO 3200_ 3600_' .. c 39002 ,-- ~ .,.60 C .4 ,,~,.800 .' (],,) - J I v -.; 6000.~ 5OOO.J 9OO : 200 1500 Scale 1 : 150.00 Point Vertical Section on 0.14 azimuth with reference 0.00 N, 0.00 £ from slot 1050 5900 _~750 _5600 _$450 -- _3500 _5150 _ _27OO _2550 -- L2400 _2250 !-- _2100 _ _1950 -- _1800 ~1650 1350 A i Z ARCu .LAS s_n, Structure : Pod 10 Well : 21 ~ Field : KuDaruk River Unit Location : Nor"ih Slope, Alaska l 500 0 500 1000 1500 2000 2500 3000 3500 I I ,,I ! I ' ~ ' ' I I I I I I I _7000 10-21(0) Rvsd 22-A~q-95 ,~ 5500 500 CO . e'" 2000~ _ 65~_ I 6000 5500 f5000 _4500 //~ -- _4000 J _ i _~500 _~ooo 0 _2500 ~" L _2000 _1500 _1000 U~ 500 -- I '' GO'lO' ~vo 7O0O_ 0 500 1000 1500 2000 2500 3000 3500 4000 1500 5000 5500 6000 6500 7000 7500 Scale 1 - 250.00 Vertical Section on 2,5.69 azimuth with reference 0.00 N, 0.00 E from slot #21 ARCO ..'4LASKA, Inc. P!ot ,~eterenc. ~ 22 '..'e,~n #5. $1ructure : Pad lQ Well : 22 : Fieid : Kuoaruk River Unit Location : North Slope, Alaska l 500 0 500 I000 1500 2000 2500 5000 3500 4000 ~500 ~00 .~ o 800 J --~ ,~<ick Off Poir~t ~2oo4 ..c Ch_ 20004 ~J 28oo_1 ~ 32com ~. 3600D CD ~ooo_~ '-'t --. V 10-22([) Rvsd 25-Seo-95 ( ./~; - 5200J ot Hold 54-O0 ~ 5800i ~ '[[ Lr~ ER 72~ 0 tO0 8~ 1200 I ~00 2000 24~ 2800 52~ ~6~ 4000 t4~ ~00 5200 56~ 6000 _JO00 _2500 '2000 _,zoo -- _1ooo GLO0'-rvO ~% 18',r'vg Scale 1 · 200.00 Vertical Section on 46.57 azimuth with reference 0.00 N, 0.00 E from slot #22 TONY KNOWLE$, GOVERNOR ALASIT~L OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 17, 1995 Mike Zanghi, Drill Site Develop. Supv. ARCO Alaska Inc. P O Box 100360 Anchorage, AK g'§510-0360 Re: Kuparuk River Unit 1Q-22 ARCO Alaska Inc.. - Permit No 95-140 Surf Loc 1210'FNL, 1161'FEL, Sec. 26, T12N, R09E, UM Btmhole Loc 2296'FNL, 2184'FEL, Sec. 24, T12N, R09E, UM Dear Mr. Zanghi: The AOGCC staff has reviewed recent occurrences of abnormal formation pressure encountered while ddlling 1Q-20 and 1Q-22. In both cases casing had to be set above the Kuparuk formation in order to complete the well. Based on the information available, the Commission is revising the BOPE test pressure to 5000 psi on well 1Q-22 and 1Q-20A when the wells are completed and future 1Q Pad wells. This will entail using a 5000 psi rated BOP stack equipped according to 20 AAC 25.035 (d). 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. If there are any questions about this change, please contact our staff at 279-1433. · c: Dept of Fish & Game, Habitat Section Dept of Environmental Conservation ¢:ETA FF'~AOGCC~, 1 QWELL. DOC ii'35AM ARCO ALASF[A INC No, 3885 FACSIMILE ONLY October 10, 1995 0CT 'i 1 1995 Jack Har~ A~ .Oil .& Gas Cons. Commission Reservoir Engineer ~ch0rage Alaska Oil and Gas Conservation Commission ~,,-/ 3001 Porcupine Drive ~ Anchorage, AK 99S01 Subie~ KRU Well 1Q-22 Changes to Permit to Drill Permit No. 95-140 API No. 50-029-22595 Dear Mr. Hartz: Per our conversation on 10/9/95, I am providing the following information for your files on KRU Well 1Q-22. 1Q-22 was drilled to the permitted target location as planned under the approved Permit to Drill. We drilled through the D shales below the top of the Kuparuk and 20' into the C Sand reservoir at 8822' MD. At that time we began taking small influxes of gas and eventually oil into the reservoir. The mud was weighted up in several stages from 10.7 ppg to 12_.4 ~before the influxes were stopped. Our recent experience on lQ-20 indicate~e formations above the Kuparuk would be likely to break down at that high of a mud weight if we continued drilling. Not wanting to risk dealing with the lost circulation we decided to cement over the high pressure formation(s) at TD, and topset the Kuparuk with 5-1/2" casing. Parker 245 will leave the well at that point. Nordic 1 will move onto the well later this year, drill to TD, and set a 3-1/2" liner. Our final well completion will look very similar to the current plans in the Permit to Drill. 5-1/2" casing will be set and cemented with 50 sx Class G at -+8600' MD. Nordic 1 will drill a 4-3/4" hole to the planned target and run a 3-1/2" liner from _+8300' to TD. The contingency for the Nordic drfllout is discussed in the "Drilling Area Risks" section of the permit. We discussed these issues on 10/9/95 and derided that no amendments or additional forms were required for cementing over the high-pressured zones or the Nordic drillout. Please let me know if this changes. If there are any questions on the above please contact me at 2634183. ..;/ ; ,--7 ,., r - . _._.., '>.,:.:.,: ?,-' Denise Petrash Drilling Engineer ' '"' ..... '-'- , ALASKA OIL ANrD GAS CONSERVATION CO~LVII$8ION Se.p_._tember 7, ~" TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 .: -o Mike Zanghi, Ddg Engr Supv ARCO Alaska Inc. P O Box 100360 Anchorage, AK 99519-6612 Re: Kuparuk River Unit 1Q-22 ARCO'Alaska Inc. ' ............. Permit No 95-140 Surf Loc 1210'FNL, 1161'FEL, Sec. 26, T12N, R09E, UM Btmhole Loc 2296'FNL, 2184'FEL, Sec. 24, T12N, R09E, UM Dear Mr. Zanghi: ~ Eng[osed is the approved application for permit to ddll the above referenced well. ~T~h~'Perr~....if~o drill dOe~ not exempt you from pbiaining additional permits.requir, e~by law from'other i.¢gbve~mental agencies, and d/ees not authoriZe co0ducting ddiling..opefations Until all other required /Tperr~,itting deter(flirtations are'made. ?' .. ...... '~ 'L~-,~''' .-~- 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 ddiling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be oleum field inspector 659-3607. _ _ · · . '. . . .. " David W.N(0hnston \ . - '~' Chairman ' ' BY ORDER OF THE COMMISSION /encl c:' Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - wlo encl ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 September 7, 1995 Mike Zanghi, Ddg Engr Supv ARCO Alaska Inc. P O Box 100360 Anchorage, AK 99519-6612 Re: Kuparuk River Unit 1Q-22 ARCO-Alaska Inc. Permit No 95-140 Surf Loc 1210'FNL, 1161'FEL, Sec. 26, T12N, R09E, UM Btmhole Loc 2296'FNL, 2184'FEL, Sec. 24, T12N, R09E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to ddil 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. oleum field inspector 659-3607. · David W.%Jxohnston \ ' - Chairman BY ORDER OF THE COMMISSION 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 lencl c:' Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA AL~,.,,~, OIL AND GAS CONSERVATION COMMI~,.. PERMIT TO DRILL 2O AAC 25.OO5 1 a. Type of Work Drill X Redrill D I b Type of Well Exploratory J'"l Stratigraphic Test D Development OII X Re-Entry D Deepen r'J Service r'l Development Gas r'] Single Zone X Multiple Zone J-J 2. Name of Operator 5. Datum Elevation (DF or KB) 1 0. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 53' feet Kuparuk River Field 3. Address 6. Property Designal~on Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25634, ALK 2567 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 20 AAC 25.025) 1210' FNL, 1161' FEL, Sec. 26, T12N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 2604' FSL, 2570' FEL, Sec. 24, T.12N, RgE, UM 1Q-22 #U-630610 At total depth 9. Approximate spud date Amount 2296' FNL, 2184' FEL, Sec. 24, T12N, R9E, UM 9/1 8/95 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1Q-02 9614' MD 2184 ~ TD feet 14.4' @ 720' MD feet 2560 6934'. TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 1000' feet Maximum holeangle 51.73° Maximumsurlace 2293 peig At total depth (TVD) 3500 pslg 18. Casing program Setting Depth size Specifications Top Bottom Quantit7 of cement Hole Casinc, i Weight Grade Couplin~l Len~lth MD 'rVD MD 3'VD (include sta~le data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 9.875" 7.625" 29.7# L-80 LTC 4903' 41' 41' 4944' 3874' 720 Sx Arcticset III & HF-ERW 410 Sx Class G 6.75" 5.5" 15.5# L-80 LTCMOD 8730' 41' 41' 8771' 6289' HF-ERW 6.75" 3.5" 9.3# L-80 EUE8rdM 843' 8771' 6289' 9614' 6934' 290 SxClassG Top 500' above Kuparuk 1 9. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Co, ,,c or "[: Surface . ., ~ ii Intermediate Production LinerS EP 0 1.995 Perforation depth: measured true vertical At~tSt~a~ L~t[ & Gas Cons, Commission '. ~ch0rage 20. Attachments Filing fee X Property plat D BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot D Refraction analysis D Seabed report r'~ 20 AAC 25.050 requirements X 21. I hereby certify that .'[he foregoingj's true and correct to the best of my knowledge ~l.~ ( Title Drill Site Develop. Supv. Signed v ~. [ ~. "~)~"~ Commission Use Only Permit Number 1~331.~ bet [ Approval ~2.~te_. I See cover letter for . --" other requirements Conditions of approval Samples required [-] Yes ,,~ No Mud Icg required D Yes ~ No Hydrogen sulfide measures ~'Yes ~ No Directionalsurveyrequired Ji;~J" Yes r-J No Required working pressure for DOPE r~ 2M J~ 3M r-J 5M J-J 10M J--J 15M Other: OrigJrlalSJgnea By by order of Approved by David W, J0hrJst0rJ Commissioner the commission Date Form 10-401 Rev. 7-24-89 ' fit in triplicate GENERAL DRIllING PROCEDURE KUPARUK RIVER FIELD 1Q-22 , , , , 1 , . . , 10. 11. 12. 13. 14. 15. 16. 17. Move in and rig up Parker #245. Install diverter system. Drill 9-7/8" hole to 7-5/8" surface casing point (4,944')according to directional plan. -- · Run and cement 7-5/8" casing. Install and test BOPE to 3000 psi. Test casing to 2000 psi. -- Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 6-3/4" hole to total depth (9,614') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement tapered 5-1/2" x 3-1/2" casing string. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) ND BOPE. NU tubinghead & either full opening valve (if logging planned) or master valve and upper tree assembly (if no logging planned). Note: As a dedicated producer, no cased hole cement bond logs will be run unless there are problems with the cement job. Secure well and release rig. Move in and rig up Nordic #1. Install and test BOPE. Pressure test tapered 5-1/2" x 3-1/2" casing to 3500 psi. Run completion assembly. Pressure test SBE/XO. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig in preparation for perforating. DRILLING FLUID PROGRAM Well 1Q-22 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 50-80* 5-15 15-40 10-12 9.5-10 _+10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes' Weight up to TD 11.0 10-18 8-12 35-5O 2-4 4-8 4-5 through Kuparuk 9.5-10 <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/ff. This shows that formation breakdown would occur before a surface pressure of 2,293 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 1Q-22 is 1Q-02. As designed, the minimum distance between the two wells would be 14.4' @ 720' MD. Annular Pumping Activities: Incidental fluids developed from ddlling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 1Q-22 surface/production casing annulus will be filled with diesel after setting the 5-1/2" x 3-1/2" tapered casing and prior to th~ drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface, if the surface shoe is within 200' TVD of the top of the hydrocarbons. Alternatively, if the hydrocarbons are far below the shoe then sufficient cement volume will be. pumped during the production cement job to cover the formation. -~ It is requested that 1Q-22 be permitted for annular pumping occurring as a result of the ddlling project on DS lQ, per proposed regulations 20 AAC 25.005 (k). Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Surface casing will be set in the Creatceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. Generally, the surface casing shoe is set 200' vertical below the base of the West Sak into the heart of the shales. Drilling Area Risks- Risks in the 1Q-22 ddlling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation matedal (LCM) and reduced circulating rates as needed. 5-1/2" casing will be topset above the Kuparuk and either Nordic Rig #1 or a coiled tubing unit will drill out a 4-3/4" hole, and run a 3-1/2" liner to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the.target location and careful analysis of pressure data from offset wells show that a mud weight of 11.0 ppg will provide sufficient overpressure to safely drill, trip pip~, and cement. The 7-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. Them will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Surface casing will be set in the Creatceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. Generally, the sudace casing shoe is set 200' vertical below the base of the West Sak into the heart of the shales. Drilling Area Risks: Risks in the 1Q-22 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. 5-1/2" casing will be topset above the Kuparuk and either Nordic Rig #1 or a coiled tubing unit will drill out a 4-3/4" hole, and run a 3-1/2" liner to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 11.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 7-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. EP 0 5 1995 & Gas Cons. Commission .Anchorage ARCO ALASKA, Inc. Structure : Pad lQ Well : 22 Field : Kup~ruk River Unif Lo¢ot|on : North Slopo, ~lo~k~i Creoted by : jones Dote plotted : 18-^ug-95 For: D PETRASH TD LOCATION: 2296' FNL, 2184' FEL o.oo East > 500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 TARGET LOCATION: 4500 iPIot Reference is 22 Version #4. 2604' FSL, 2570' FEL iCoordinotee ere ,n feet ret ....... lot ~22. ! SEC 24 T12N RSE :~/~ ~ / 4000 !True Vertical Depths ore reference RKB (Parker ~z245).i TARGET ~ I ~ I ~ TMD=8771 ~ ~ } DEP=5454 ~- 5500 ! ~~ ~ ~ST 3871 ~ '~ "'%o.. - 5434' (TO TARGET) ~,. -I I o soo_ - :CN ~ - q ., * '~,d ~ _=o~o ~ o _ . RK~o.:~' " ~ ~ ~ - -. I -'~ ,~ ~5 .~ ~% _,,oo 0 · ~ ; _ 500 ~ ~ ' B/ PERMAFROST ~D=1594 TMD=~04 DEP=95 ~ =~o. % - ~ ~ 21.oo ~ 'o~_ 0 ~ ~ 27.00 % ~ ~ooo~ X ~oo ~ - ~ - ~ 45'g~ooT/ UGNU SNDS ~D=2419 TMD:2600 DEP=632 z ~ - 2500_ .~[OC WD=24~ TMD=2724 DEP=727 - 3000_ ~ W SAK SNDS ~D=3069 TMD=3644 DEP=1449 · ~soo_ > ~ ~/w s,~ s.~s mo=a~4 ~,==4~z~ =~p=~:~ ~ ~000_ ~ MAXIMUM ANGLE ~5oo_ 5ooo~ K-10 W~=5024 IMD=6801 DEP=3927 V ~oo~ BEGIN ANGLE DROP ~D 5881 TMD 8185 DEP 5014 HRZ Midpoint ~D-5929 TMD-8261 BEP=5073 5ooo = = = _ HRZ Midpoint ~D=5929 TMD=8261 BEP=5073 6000 - - '46.~ DROP 2 BEG / 100' _ ~ 42.00 6500 ~ Z ~ ~ '~ ~U Y~ 't'AKUNt' A 7000 B/ KUP SNDS ~D=6781 TMD=9414 DEP=5847 - 7500 I I I I I I I I I I I I I I I I I I I I I I I I I I I I 500 0 500 1000 1500 2000 2500 5000 5500 4000 4500 5000 5500 6000 6500 Scole 1 : 250.00 Vertical Section on 45.42 ~zimufh with reference 0.00 N, 0.00 E from slot ~22 ARCO ALASKA, Inc. iCreoted by : jones l~Or.' CD PETtb~SH Structure : Pod 10 Well : 22 IDote plotted : 18-Aug-95 ! lPIot Reference is 22 Version #4. Field : Kuporuk River Unit Lo¢ofion : North Slope, Alosko ICoordlnotes ore in feet. reference slot ¢22, i [True Verticol Depths ore reference RKB (Parker ¢245).i ~oo,~. ~o.ooEast =-> 100 80 60 40 20 0 20 40 60 80 100 120 140 160 180 200 220 240 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 520 ~40 I I 80¸ 11oo 160 I 140 20 0 100 ~=~ 8o 6o · -- 20_ 7OO % % % I I I I I I I [ I I I I I I I I I I I I I I I I I I I I I I I I I 100 80 60 40 20 0 20 40 60 80 1 O0 120 140 160 180 200 220 240 ~co,~ ~. ~0.oo E o s t o _ 0 0 iCreoted by : jon~ For: D PETRASHi ':date plotted : 18-Aug-g5 iPlot Reference is 22 Version #4. , . iCoordinotes are in feet reference slot ~[22. '~True Vertical Depths are referer~e RKB (Porker $cole 1 : 50.00 1900 18aa. 1700_ _ 1600_ _ 1500_ 1400 1200_ _ 1100_ 1000_ I ~. 90o ~ © Z 800 700 _ _ 600 _ s°°i 400 ARCO ALASKA, Inc. Structure : Pad 10 Well : 22 Field : Kuparuk River Unit Location : North Slope, Alaskai Easf --> 200 500 400 500 600 700 800 900 1000 1100 1200 1500 1400 1500 1600 1700 1800 I I I I i I I I I I I I I I J I I I I I I I I I I I I I I [ I I I Jl900 -- ~00 .~700 257 / 230[ 1700 1600 2100 ~500 23OO 7O0 % % % % % % % 1500 1400 SOO 100 I )00 900 0 700 6OO 500 4OO 0 0 200 100 -L 200 300 400 .500 600 700 800 900 1000 11 oo 1200. 1 .%00 1400 1500 1600 1700 1800 Scale 1 ' ,50.00 E{~ sf > 300 o 200 · · 0 100 0 KUPARUK RIVER UN, ! 20" DIVERTER SCHEMATIC 6 4 3 DO NOT SHUT IN DIVERTER -AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. . . MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) . 2. 3. 4. 5. 6. 20" - 2000 PSI ANNULAR PREVENTER. S EP 0 ',¢ i99.5 ^l~s~ Oil & Gas Cons. CorrjmJssion 16" CONDUCTOR. Aritho. rage SLIP-ON WELD STARTING HEAD, DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. _ _ DKP 11/9/94 ~ m~oo< WELL PERMIT CHECKLIST k~iN~s~,~b,ff ....................... 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number ............... 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary. 6. Well located proper distance from other wells ...... · 7. Sufficient acreage available in drilling unit ...... 8. If deviated, is wellbore plat included ......... 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order ..... ENGINEERING WELL NAM~ GEOL AREA 14. Conductor string provided ............... Y~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg. N 17. CMT vol adequate to tie-in long string to surf csg . . 18. CM~ will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit.. ........... 21. If a re-drill, has a 10-403 for abndnmnt been approved..Y N 22. Adequate wellbore separation proposed ......... .~ N 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... ~/ N BOPE press rating adequate; test to~------~d~ psig. Y~ N 26. 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ .Y~ 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis 9f shallow gas zones .......... 33. Seabed condition survey (if off-shore) ........ /Y N ' 34. Contact name/phone for weekly progress reports . . . [exploratory only] GEOL0~Y: ENGINEERING: " C6M~SSION: ......................' ..... TAB~ C~mments/Ins tructions: Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * . . . ............................ . ....... SCHLUMBERGER ....... . ............................ * COMPANY NAME : ARCO ALASKA, INC. WELL NAME '. 1Q-22 FIELD NAME : KUPARUK BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22595-00 REFERENCE NO : 96074 M C OF LM o~ I I.~ /~)! LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1996 12:13 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/05/14 ORIGIN : FLIC REEL NAME : 96074 CONTINUATION # : PREVIOUS REEL : COf~4FITT : ARCO ALASKA INC, 1Q-22, KUPARUK, API #50-029-22595-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/05/14 ORIGIN : FLIC TAPE NAME : 96074 CONTINUATION # : 1 PREVIOUS TAPE : COf~4ENT : ARCO ALASKA INC, 1Q-22, KUPARUK, API #50-029-22595-00 TAPE HEADER KUPARUK OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION RUN 1 96074 G. BAILEY D. BREEDON SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 1Q-22 500292259500 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 27-MAR-96 RUN 2 RUN 3 26 12N 9E 1210 1161 78. O0 77.00 52.40 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 5.500 8569.0 4.750 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1996 12:13 3RD STRING PRODUCTION STRING No depth adjustments were made to this data because it has been requested by Dave Shafer of ARCO through Floyd Bettis of Schlumberger to establish this DITE/GR data as the depth control GR for all subsequent logging. Primary depth control, including the use of magnetic marks, was used by the field logging crew. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/05/14 MAX REC SIZE : 4096 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLEMAIN PASS Ail tool strings; Clipped curves; No cased hole data. DEPTH INCREMENT: 0.5000 FILE SU~E4ARY LDWG TOOL CODE START DEPTH STOP DEPTH DITE 9500.0 8552.0 GRCH 9475.0 8552.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MF~ASUREDDEPTH) BASELINE DEPTH MERGED DATA SOURCE LDWG TOOL CODE $ REM_ARKS: No depth shifting as per Dave Shafer of ARCO. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... RUN NO. PASS NO. MERGE TOP MERGE BASE LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1996 12:13 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 85 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SDx~P ELEM CODE (HEX) DEPT FT 100313 O0 000 O0 0 1 1 1 4 68 0000000000 IDPH DTE 0HP~4100313 O0 000 O0 0 1 1 1 4 68 0000000000 IMPH DTE 0H~1~100313 O0 000 O0 0 1 1 1 4 68 0000000000 ILD DTE OH~4 100313 O0 000 O0 0 1 1 1 4 68 0000000000 ILM DTE 0HT4~100313 O0 000 O0 0 1 1 1 4 68 0000000000 SFL DTE 0H~4100313 O0 000 O0 0 1 1 1 4 68 0000000000 GR DTE GAPI 100313 O0 000 O0 0 1 1 1 4 68 0000000000 TEND DTE LB 100313 O0 000 O0 0 1 1 1 4 68 0000000000 TENS DTE LB 100313 O0 000 O0 0 1 1 1 4 68 0000000000 FIRES DTE OH~k4100313 O0 000 O0 0 1 1 1 4 68 0000000000 MTEMDTE DEGF 100313 O0 000 O0 0 1 1 1 4 68 0000000000 SP DTE MV 100313 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 9500. 000 IDPH. DTE 3. 027 IMPH.DTE 3. 477 ILD.DTE ILM. DTE 3 . 430 SFL.DTE 3 . 594 GR.DTE -999.250 TEND.DTE TENS.DTE 5115. 000 MRES.DTE O. 825 MTEM. DTE 156. 625 SP.DTE 2.990 537.500 -16.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center DEPT. 8552. 000 IDPH. DTE ILM. DTE 1.331 SFL . DTE TENS.DTE 790. 000 MiRES.DTE 14-MAY-1996 12:13 1.518 IMPH.DTE 2.125 GR.DTE 0.959 MTEM. DTE 1.158 79.938 138.250 I LD . DTE TEND. DTE SP. DTE PAGE: 1.541 121.000 -40.750 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION . O01CO1 DATE : 96/05/14 MAX REC SIZE : 4096 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/05/14 MAX REC SIZE : 4096 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Clipped curves for open hole logs run into casing. PASS NUMBER: 2 DEPTH INCREM~FJFT: 0.5000 FILE SUM~Jh~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 8552.0 8292.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... REM_ARKS: No depth shifting as per Dave Shafer of ARCO. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1996 12:13 PAGE: 5 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 0 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAi~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB S~.~P ELEM CODE (HEX) DEPT FT 100313 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH DTE GAPI 100313 O0 000 O0 0 2 1 1 4 68 0000000000 TEND DTE LB 100313 O0 000 O0 0 2 1 1 4 68 0000000000 TENS DTE LB 100313 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 8552. 000 GRCH.DTE 88. 938 TEND.DTE 588. 000 TENS.DTE DEPT. 8298.000 GRCH.DTE 205.375 TEND.DTE 589.500 TENS.DTE 4100. 000 3955. 000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1996 12:13 PAGE: **** FILE TRAILER **** FILE NAME : EDIT . 002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/05/14 MAX REC SIZE : 4096 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE ·FLIC VERSION ·O01CO1 DATE : 96/05/14 MAX REC SIZE : 4096 FILE TYPE : LO LAST FILE : RUN ~ER : TOOL STRING NUMBER: PASS ~ER : DEPTH INCREMENT: FILE SU~ff4ARY FILE HEADER FILE NUMBER 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files. 1 1 2 0.5000 VENDOR TOOL CODE START DEPTH STOP DEPTH DITE 9500.0 8552.0 GR 9475.0 8552.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... DITE PHASOR INDUCTION DITE PHASOR INDUCTION DITE AUX.MEASURE~ENT 18-FEB-96 CP42.2 1800 18-FEB-96 252 18-FEB-96 9514.0 9511.0 8342.0 9504.0 TOOL NUMBER DIS-270 DIC- 163 AI~-AA-950 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1996 12:13 PAGE: GR TCC TCC $ GA2~CA RAY TELEMETRY CARTRIDGE TELEMETRY CARTRIDGE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) .. MUD CAKE AT (MT): MUD CAKE AT (BHT) : SGC-SA-271 TCC-B-290 TCM-AB-19 4.750 8569.0 8552.0 DISP WEIGHTED CLAY/POLY 11.80 50.0 9.5 157.0 1.970 68.0 1.270 68.0 4. 140 68.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: USED NORDIC RKB FOR DEPTH REFERENCE. PRIMARY DEPTH CONTROL USED INCLUDING THE USE OF MAGNETIC MARKS. THIS LOG IS A COMPOSITE OF BOTH UP AND DOWN LOG PASSES. THE MAJOR PORTION OF THE LOG IS DOWN LOG WHICH IS DEPTH SHIFTED AS UP LOG. AFTER LOGGING DOWN, THE TOOLS STUCK AT 9450' FOR 3 1/2 HOURS AND TOOL PROBLEMS WERE PRESENT ONCE THE TOOLS CAME FREE. NO ADDITION OH LOGGING DONE $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1996 12:13 PAGE: TYPE REPR CODE VALUE 73 66 66 73 65 48 1 0.5 FT 85 3 4 5 6 7 8 68 9 65 11 66 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100313 O0 000 O0 0 3 1 1 4 68 0000000000 IDPH LOG 0P~4~100313 O0 000 O0 0 3 1 1 4 68 0000000000 IMPH LOG 0P~4~1003t3 O0 000 O0 0 3 1 1 4 68 0000000000 ILD LOG OPHvi~iO0313 O0 000 O0 0 3 1 1 4 68 0000000000 ILM LOG 0H~100313 O0 000 O0 0 3 1 1 4 68 0000000000 SFLU LOG 0H~4~100313 O0 000 O0 0 3 1 1 4 68 0000000000 GR LOG GAPI 100313 O0 000 O0 0 3 1 1 4 68 0000000000 HTENLOG LB 100313 O0 000 O0 0 3 1 1 4 68 0000000000 TENS LOG LB 100313 O0 000 O0 0 3 1 1 4 68 0000000000 MP~ES LOG 0H~4~100313 O0 000 O0 0 3 1 1 4 68 0000000000 MTEMLOG DEGF 100313 O0 000 O0 0 3 1 1 4 68 0000000000 SP LOG MV 100313 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 9576.000 IDPH.LOG 3.031 IMPH.LOG 3.734 ILD.LOG ILM. LOG 3.709 SFLU. LOG 3.441 GR.LOG 106.938 HTEN. LOG TENS.LOG 1840.000 f~RES.LOG 0.825 MTEM. LOG 156.625 SP.LOG DEPT. 8545.500 IDPH. LOG 1950.000 IMPH.LOG 1950.000 ILD.LOG ILM. LOG 1950.000 SFLU. LOG 1.201 GR.LOG 94.688 HTEN.LOG TENS.LOG 790.000 fqRES.LOG 0.962 MTEM. LOG 138.250 SP.LOG 3.004 87.438 -15.719 1950. 000 107. 563 -40.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1996 12:13 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION · O01CO1 DATE · 96/05/14 MAX REC SIZE : 4096 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 96/05/14 MAX REC SIZE : 4096 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUFiBER: PASS NUFfl~ER : DEPTH INCREMENT: FILE SURff~ARY FILE HEADER FILE NUMBER 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 1 0.5000 VENDOR TOOL CODE START DEPTH STOP DEPTH DITE 8750.0 8552.0 GR 8725.0 8552.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DITE PHASOR INDUCTION DITE PHASOR INDUCTION D I TE AUX. MEASUREMENT 18-FEB-96 CP42.2 1800 18-FEB-96 220 18-FEB-96 9514.0 9511.0 8342.0 9504.0 TOOL NUMBER ........... DIS-270 DIC-163 21_lv~vY-2~-950 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1996 12:13 PAGE: 10 GR TCC TCC $ GAM~A RAY TELEMETRY CARTRIDGE TELEMETRY CARTRIDGE SGC-SA-271 TCC-B-290 TCM- AB -19 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 4. 750 8569.0 8552.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATTrRE (MT): MUD AT BOTTOM HOLE TEMPERATtrRE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : DISP WEIGHTED CLAY/POLY 11.80 50.0 9.5 157.0 1.970 68.0 1.270 68.0 4. 140 68.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: USED NORDIC RKB FOR DEPTH REFERENCE. PRIMARY DEPTH CONTROL USED INCLUDING THE USE OF MAGArETICMARKS. THIS LOG IS A COMPOSITE OF BOTH UP AND DOWN LOG PASSES. THE MAJOR PORTION OF THE LOG IS DOWN LOG WHICH IS DEPTH SHIFTED AS UP LOG. AFTER LOGGING DOWN, THE TOOLS STUCK AT 9450' FOR 3 1/2 HOURS AND TOOL PROBLEMS WERE PRESENT ONCE THE TOOLS CAME FREE. NO ADDITION OH LOGGING USED $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1996 12:13 PAGE: 11 TYPE REPR CODE VALUE 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 85 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 4 1 1 4 68 0000000000 DEPT FT 100313 IDPH RPT OH~4MlO0313 O0 000 O0 0 4 1 1 4 68 0000000000 IMPH RPT OH~ff~lO0313 O0 000 O0 0 4 1 1 4 68 0000000000 ILD RPT OH~ff4 100313 O0 000 O0 0 4 1 1 4 68 0000000000 ILM RPT OH~ff4 100313 O0 000 O0 0 4 1 1 4 68 0000000000 SFLU RPT 0tff4~100313 O0 000 O0 0 4 1 1 4 68 0000000000 GR RPT GAPI 100313 O0 000 O0 0 4 1 1 4 68 0000000000 HTENRPT LB 100313 O0 000 O0 0 4 1 1 4 68 0000000000 TENS RPT LB 100313 O0 000 O0 0 4 1 1 4 68 0000000000 ~iRES RPT OH~ff4100313 O0 000 O0 0 4 1 1 4 68 0000000000 MTEMRPT DEGF 100313 O0 000 O0 0 4 1 1 4 68 0000000000 SP RPT MV 100313 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 8812.000 ILM. RPT 4.020 TENS.RPT 2250.000 DEPT. 8337.500 ILM. RPT 1950.000 TENS.RPT 3930.000 IDPH. RPT 3.803 IMPH.RPT 4.055 ILD.RPT SFLU. RPT 3.670 GR.RPT 126.188 HTEN. RPT I~ES.RPT 0.968 MTEM. RPT 138.875 SP.RPT IDPH.RPT 47.688 IMPH.RPT 1950.000 ILD.RPT SFLU. RPT 0.661 GR.RPT 165.000 HTEN.RPT MRES.RPT 0.959 MTEM. RPT 137.000 SP.RPT 3.770 266.250 18.031 45.188 575.000 -93.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1996 12:13 PAGE: 12 **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 96/05/14 MAX REC SIZE : 4096 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE · FLIC VERSION · O01CO1 DATE : 96/05/14 MAX REC SIZE : 4096 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER 5 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into casing. PASS ~ER : 2 DEPTH INCREMENT: 0.5000 FILE SU~ff~ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 8552.0 8292.0 GR LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) .. TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DITE DITE DITE GR TCC TCC PHASOR INDUCTION PHASOR INDUCTION AUX. MEASUREMENT GA~ViA RAY TELEMETRY CARTRIDGE TELEMETRY CARTRIDGE 18-FEB-96 CP42.2 1800 18-FEB-96 220 18-FEB-96 9514.0 9511.0 8342.0 9504.0 TOOL NUMBER ........... DIS-270 DIC-163 A~-AA-950 SGC-SA-271 TCC-B-290 TCM-AB-19 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1996 12:13 PAGE .. 13 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 4.750 8569.0 8552.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~4~I) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) .. DISP WEIGHTED CLA~POLY 11.80 50.0 9.5 157.0 1. 970 68.0 1. 270 68.0 4. 140 68.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: USED NORDIC RKB FOR DEPTH REFERENCE. PRIMARY DEPTH CONTRO INCLUDING THE USE OF MANGETIC MARKS. THIS LOG IS A COMPOSITE OF BOTH UP AND DOWN LOG PASSES. THE MAJOR PORTION OF THE LOG IS DOWN LOG WHICH IS DEPTH SHIFTED AS UP LOG. AFTER LOGGING DOWN, THE TOOLS STUCK AT 9450' FOR 3 1/2 HOURS AND TOOL PROBLEMS WERE PRESENT ONCE THE TOOLS CAME FREE. NO ADDITION O.H. LOGGING WAS WA $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1996 12:13 PAGE: 14 TYPE REPR CODE VALUE 6 73 7 65 8 68 0.5 9 65 FT 11 66 0 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100313 O0 000 O0 0 5 1 1 4 68 0000000000 GR CSG GAPI 100313 O0 000 O0 0 5 1 1 4 68 0000000000 HTEN CSG LB 100313 O0 000 O0 0 5 1 1 4 68 0000000000 TENS CSG LB 100313 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 8552.000 GR.CSG 88.938 HTEN. CSG 588.000 TENS.CSG DEPT. 8298.000 GR.CSG 205.375 HTEN. CSG 589.500 TENS.CSG 4100.000 3955.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE · 96/05/14 MAX REC SIZE : 4096 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1996 12:13 PAGE: 15 **** TAPE TRAILER **** SERVICE NA~E : EDIT DATE : 96/05/14 ORIGIN · FLIC TAPE NAME : 96074 CONTINUATION # : 1 PREVIOUS TAPE : COM~4ENT : ARCO ALASKA INC, 1Q-22, KUPARUK, API #50-029-22595-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE . 96/05/14 ORIGIN : FLIC REEL NABIE : 96074 CONTINUATION # : PREVIOUS REEL : COM~4FJFr : ARCO ALASKA INC, 1Q-22, KUPARUK, API #50-029-22595-00 * ALASKA COMPUTING CENTER * ****************************** . * ....... SCHLUMBERGER ....... . ****************************** COMPANY NAME : ARCO ALASKA, INC. WELL NAME : 1Q-22 FIELD NAME : KUPARUK RIVER BOROUGH : NORTH SLOPE STATE · ALASKA APiATLfMBER : 50-029-22595-00 REFERENCE NO : 95340 _. ~'~:::~",.' O -~ 1996 M Cf OF]LMED Date LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-APR-1996 10:40 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/04/25 ORIGIN : FLIC REEL NAME : 95340 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., KUPARUK 1Q-22, API #50-029-22595-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/04/25 ORIGIN : FLIC TAPE NAME : 95340 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA INC., KUPARUK 1Q-22, API #50-029-22595-00 TAPE HEADER KUPARUK RIVER MWD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION 1Q-22 500292259500 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 25-APR-96 BIT RUN1 BIT RUN2 BIT RUN3 95340 95340 95340 NICOLS NICOLS NICOLS TRANTHAM TRANTHAM TRANTHAM SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 26 12N 9E 1210 1161 94. O0 94. O0 52.40 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (F~ 6.750 7.625 4957.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-APR-1996 10:40 3RD STRING PRODUCTION STRING REMARKS: Well drilled 06-OCT through 09-0CT-95 with ARC5 only. All data was collected in three bit runs. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION · O01CO1 DATE : 96/04/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: O. 5000 FILE SUM~UkRY LDWG TOOL CODE $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 4910.0 8820.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH MWD 88888.0 88887.5 8765.0 8764.5 8759.0 8757.0 8742.0 8733.5 8727.0 8719.5 8701.5 8692.0 8684.5 8670.0 8670.0 8654.5 8645.5 8629.0 8602.5 8583.5 8598.5 8579.5 8578.0 8561.0 8569.0 8552.5 8564.5 8545.5 8554.5 8537.5 8475.5 8453.5 8460.0 8440.0 8429.0 8409.5 8421.5 8401.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-APR-1996 10:40 PAGE: 83 62.0 8360 8322 8312 8299 8279 8252 8229 8202 4957 8341.0 0 8339.0 0 8302.0 5 8292.5 0 8278.5 0 8258.5 5 8232.0 0 8209.5 0 8179.5 0 4957.0 MERGED DATA SOURCE LDWG TOOL CODE $ REN~fl~KS: BIT RUN NO. f4~RGE TOP MERGE BASE 1 4910.0 6434.0 2 6434.0 8108.0 3 8108.0 8820.5 The depth adjustments shown above reflect the MWD GR to the CBT GR on 1Q-22A logged by SWS. Ail other l4WD curves were carried with the GR. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 25 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-APR-1996 10:40 PAGE: ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~I~ CODE (HEX) O0 000 O0 0 1 1 1 4 68 0000000000 DEPT FT ROP MWD F/HR O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI O0 000 O0 0 1 1 1 4 68 0000000000 RPXXMWD OIq~I O0 000 O0 0 1 1 1 4 68 0000000000 RPX f4WD OHM~I O0 000 O0 0 1 1 1 4 68 0000000000 RPS MWD OH~4 O0 000 O0 0 1 1 1 4 68 0000000000 RPM MWD OH~I O0 000 O0 0 1 1 1 4 68 0000000000 RPD MWD OH~ O0 000 O0 0 I 1 1 4 68 0000000000 GRCH CBT GAPI O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 8830.000 ROP.MWD -999.250 FET.MWD -999.250 GR.MWD RPXX.MWD -999.250 RPX.MWD -999.250 RPS.14WD -999.250 RPM. MWD RPD.MWD -999.250 GRCH. CBT 59.063 DEPT. 8000.000 ROP.MWD 172.609 FET.MWD 0.468 GR.MWD RPXX.MWD 2.154 RPX.MWD 2.174 RPS.MWD 2.171 RPM. MWD RPD.MWD 2.195 GRCH. CBT -999.250 DEPT. 7000.000 ROP.MWD 180.000 FET.MWD 0.747 GR.MWD RPXX.MWD 2.591 RPX.MWD 2.598 RPS.MWD 2.631 RPM.MWD RPD.MWD 2.719 GRCH. CBT -999.250 DEPT. 6000. 000 ROP.MWD 128. 414 FET.MWD O. 335 GR.MWD RPXX.MWD 3. 421 RPX.MWD 3.506 RPS.MWD 3.572 RPM. MWD RPD.MWD 3. 630 GRCH. CBT -999. 250 DEPT. 5000.000 ROP.MWD 180.000 FET.MWD 0.031 GR.MWD RPXX.MWD 3.471 RPX.MWD 3.478 RPS.MWD 3.534 RPM. MWD RPD.MWD 3.537 GRCH. CBT -999.250 DEPT. 4883.000 ROP.MWD -999.250 FET.MWD -999.250 GR.MWD RPXX.MWD ~999.250 RPX. MWD -999.250 RPS.MWD -999.250 RPM. MWD RPD.MWD -999.250 GRCH. CBT -999.250 -999.250 -999.250 92.672 2.172 89.330 2.680 105.719 3.609 84.494 3.570 -999.250 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-APR-1996 10:40 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/04/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/04/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NTJMBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUR~IARY VENDOR TOOL CODE START DEPTH STOP DEPTH M~rD 4910.0 6434.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ARC5 RESIST./GR $ 07-0CT-95 IDEAL 4. OB09 f~IOR Y 8822.0 4910.0 6434.0 75 49.9 51.7 TOOL NUMBER ARC5 ENP1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-APR-1996 10:40 PAGE: BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) 6. 750 4957.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 12.20 MUD VISCOSITY (S) : 41.0 MUD PH: 10.0 MUD CHLORIDES (PPM) : FLUID LOSS (C3): 8.0 RESISTIVITY (OHFfl~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 2.290 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 1. 930 MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 REMARKS: ************ RUN1 ************* DRILLED INTERVAL 4978' - 6434' RES TO BIT: 42.40'; GR TO BIT: 46.50' ************ RUN2 ************* DRILLED INTERVAL 6434' - 8108' RES TO BIT: 42.40'; GR TO BIT: 46.50' *** RUN 3 INTERVAL 8108' - 8822'**** RES TO BIT: 32.20'; GR TO BIT: 36.30' $ LIS FORMAT DATA 84.0 85.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-APR-1996 10:40 PAGE: TYPE REPR CODE VALUE 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOC TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 2 1 1 4 68 0000000000 ROP LW1 F/HR O0 000 O0 0 2 1 1 4 68 0000000000 FET LW1 HR O0 000 O0 0 2 1 1 4 68 0000000000 GR LW1 GAPI O0 000 O0 0 2 1 1 4 68 0000000000 RPXX LW1 OPi~ O0 000 O0 0 2 1 1 4 68 0000000000 RPX LW1 OH~M O0 000 O0 0 2 1 1 4 68 0000000000 RPS LW1 OH~M O0 000 O0 0 2 1 1 4 68 0000000000 RPM LW1 OPiMM O0 000 O0 0 2 1 1 4 68 0000000000 RPD LW1 Otfl~M O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 6434. 500 ROP. LW1 123. 750 FET. LW1 O. 386 GR. LW1 RPJ~X. LW1 3.546 RPX.LW1 3. 689 RPS.LW1 3. 775 RPM. LW1 RPD . LW1 3 . 930 DEPT. 6000. 000 ROP. LW1 180. 000 FET. LW1 O. 325 GR. LW1 RPXX. LW1 2. 566 RPX. LW1 2. 633 RPS. LW1 2. 680 RPM. LW1 RPD. LW1 2. 842 DEPT. 5000. 000 ROP.LW1 180. 000 FET.LW1 O. 031 GR.LW1 RPXX. LW1 3 . 471 RPX. LW1 3. 478 RPS. LW1 3 . 534 RPM. LW1 RPD . LW1 3 . 537 DEPT. 4882.500 ROP.LW1 180. 000 FET.LW1 O. 000 GR.LW1 RPXX. LW1 1000. 000 RPX.LW1 1000. 000 RPS.LW1 1000. 000 RPM. LW1 RPD. LW1 1000. 000 97. 607 3. 840 91. 012 2. 743 85.511 3.570 6.501 1000.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-APR-1996 10:40 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/04/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/04/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUF~ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 6360.0 8108.0 LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ARC5 RESIST./GR $ 08-0CT-95 IDEAL 4.0B09 MEMORY 8822.0 6380.0 8108.0 70 51.7 51.1 TOOL NUMBER ARC5 ENP1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-APR-1996 10:40 PAGE: BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 6. 750 4957.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 12.20 MUD VISCOSITY (S) : 41.0 MUD PH: 10.0 MUD CHLORIDES (PPM) : FLUID LOSS (C3): 8.0 RESISTIVITY (OH~4~) AT TE~IPERATURE (DEGF) : MUD AT MEASURED TE~IPERATURE (MT): 2. 290 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 1. 930 MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): RE,lARKS: ************ RUN 1 ************* DRILLED INTERVAL 4978' - 6434' RES TO BIT: 42.40'; GR TO BIT: 46.50' ************ RUN 2 ************* DRILLED INTERVAL 6434' - 8108' RES TO BIT: 42.40'; GR TO BIT: 46.50' *** RUN 3 INTERVAL 8108' - 8822'**** RES TO BIT: 32.20'; GR TO BIT: 36.30' $ LIS FORMAT DATA 20000 84.0 85.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-APR-1996 10:40 PAGE: 10 TYPE REPR CODE VALUE 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 3 1 1 4 68 0000000000 ROP LW2 F/HR O0 000 O0 0 3 1 1 4 68 0000000000 FET LW2 HR O0 000 O0 0 3 1 1 4 68 0000000000 GR LW2 GAPI O0 000 O0 0 3 1 1 4 68 0000000000 RPXX LW2 0t~4~ O0 000 O0 0 3 1 1 4 68 0000000000 RPX LW2 OPk4M O0 000 O0 0 3 1 1 4 68 0000000000 RPS LW2 OHF24 O0 000 O0 0 3 1 1 4 68 0000000000 RPM LW2 OH~M O0 000 O0 0 3 1 1 4 68 0000000000 RPD LW2 OHFff~ O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 8107. 500 ROP. LW2 141 . 429 FET. LW2 1 . 053 GR. LW2 RPXX. LW2 1 . 916 RPX. LW2 1. 952 RPS. LW2 1 . 998 RPM. LW2 RPD . LW2 2. 081 DEPT. 8000. 000 ROP. LW2 180. 000 FET. LW2 O. 447 GR. LW2 RPXX. LW2 2.078 RPX. LW2 2.104 RPS. LW2 2.118 RPM. LW2 RPD. LW2 2. 085 DEPT. 7000. 000 ROP.LW2 165. 000 FET. LW2 O. 575 GR.LW2 RPXX. LW2 2. 457 RPX. LW2 2. 493 RPS.LW2 2. 610 RPM. LW2 RPD . LW2 2. 803 DEPT. 6357. 500 ROP. LW2 180. 000 FET. LW2 O. 000 GR. LW2 RPXX. LW2 666. 825 RPX. LW2 1000. 000 RPS. LW2 1000. 000 RPM. LW2 RPD. LW2 1000. 000 92. 949 2. 045 83.333 2.108 90.087 2.744 3.728 lO00.O00 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-APRil996 10:40 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/04/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION : O01CO1 DATE : 96/04/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUM~ER 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREM_ENT: 0.5000 FILE SUA~E~RY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 8005.0 8822.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (~ORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ARC5 RESIST./GR $ 09-0CT-95 IDEAL 4. OB09 MEMORY 8822.0 8005.0 8822.0 70 51.1 32.5 TOOL NUMBER ARC5 ENP1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-APR-1996 10:40 PAGE: 12 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 6. 750 4957.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 12.20 MUD VISCOSITY (S) : 41.0 MUD PH : 10.0 MUD CHLORIDES (PPM) : FLUID LOSS (C3): 8.0 RESISTIVITY (0I~4~) AT TEMPERATURE (DEGF): MUD AT MEASURED TE~IPERATURE (MT): 2. 290 MUD AT MAX CIRCULATIONG TE~IPERATURE : MUD FILTRATE AT (MT): 1.930 MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): R~S: ************ RUN1 ************* DRILLED INTERVAL 4978' - 6434' RES TO BIT: 42.40'; GR TO BIT: 46.50' ************ RUN2 ************* DRILLED INTERVAL 6434' - 8108' RES TO BIT: 42.40'; GR TO BIT: 46.50' *** RUN 3 INTERVAL 8108' - 8822'**** RES TO BIT: 32.20'; GR TO BIT: 36.30' $ LIS FORMAT DATA 20000 84.0 85.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-APR-1996 10:40 PAGE: 13 TYPE REPR CODE VALUE 1! 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE APIAPI API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ArU~B SAMP ELEM CODE (HEX) O0 000 O0 0 4 1 1 4 68 0000000000 DEPT FT ROP LW3 F/HR O0 000 O0 0 4 1 1 4 68 0000000000 FET LW3 HR O0 000 O0 0 4 1 1 4 68 0000000000 GR LW3 GAPI O0 000 O0 0 4 1 1 4 68 0000000000 RPXX LW3 OI~Vk4 O0 000 O0 0 4 1 1 4 68 0000000000 RPX LW3 OHT4~ O0 000 O0 0 4 1 1 4 68 0000000000 RPS LW3 OPi~k4 O0 000 O0 0 4 1 1 4 68 0000000000 RPM LW3 OPiN~I O0 000 O0 0 4 1 1 4 68 0000000000 RPD LW3 OHN~ O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 8821 . 000 ROP. LW3 94 . 286 FET. LW3 1 . 942 GR. LW3 RPXX. LW3 2. 253 RPX. LW3 2. 279 RPS. LW3 2. 290 RPM. LW3 RPD . LW3 2. 340 DEPT. 8004. 000 ROP. LW3 180. 000 FET. LW3 O. 000 GR. LW3 RPX3i. LW3 1000. 000 RPX. LW3 1000. 000 RPS.LW3 1000. 000 RPM. LW3 RPD. LW3 1000. 000 99.866 2.306 6.058 1000.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 96/04/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-APR-1996 10:40 PAGE: 14 **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 96/04/25 ORIGIN : FLIC TAPE NAME : 95340 CONTINUATION # .. 1 PREVIOUS TAPE COR94ENT : ARCO ALASKA INC., KUPARUK 1Q-22, API #50-029-22595-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 96/04/25 ORIGIN : FLIC REEL NAME : 95340 CONTINUATION # : PREVIOUS REEL : COf4~IENT : ARCO ALASKA INC., KUPARUK 1Q-22, API #50-029-22595-00 * ALASKA COMPUTING CENTER * . . ****************************** * ............................ * ....... SCHLUMBERGER ....... . ............................ . ****************************** COMPANY NAME : ARCO ALASKA, INC. WELL NAME : 1Q-22A FIELD NAME : KUPARUK BOROUGH : NORTH SLOPE STATE : ALASKA API NLrMBER : 50-029-22595-01 REFERENCE NO : 96074 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-MAR-1996 15:47 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/03/27 ORIGIN · FLIC REEL NA~IE : 96074 CONTINUATION # : PREVIOUS REEL : COI~ENT : ARCO ALASKA INC, 1Q-22A, KUPARUK, API #50-029-22595-01 **** TAPE H~ER **** SERVICE NAME : EDIT DATE : 96/03/27 ORIGIN : FLIC TAPE NAME : 96074 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC, 1Q-22A, KUPARUK, API #50-029-22595-01 TAPE HEADER KUPARUK OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL : ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: R~'~ 1 96074 G.BAILEY D.BREEDON WELL CASING RECORD 1 ST STRING 2h~ STRING 1Q-22A 500292259501 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 27-MAR-96 RUN 2 RUN 3 26 12N 9E 1210 1161 78.00 77.00 52.40 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN)DEPTH (FT) 5.500 8569.0 4.750 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-MAR-1996 15:47 3RD STRING PRODUCTION REMARKS: STRING No depth adjustments were made to this data because it has been requested by Dave Shafer of ARCO through Floyd Bettis of Schlumberger to establish this DITE/GR data as the depth control GR for all subsequent logging. Primar~ depth control, including the use of magnetic marks, was used by the field logging crew. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/03/27 MAX REC SIZE : 4096 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS Ail tool strings; Clipped curves; No cased hole data. DEPTH INCREMENT: O . 5000 FILE SU~flVARY LDWG TOOL CODE START DEPTH STOP DEPTH DITE 9500.0 8552.0 GRCH 9475.0 8552.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: No depth shifting as per Dave Shafer of ARCO. .......... EQUIVALENT UNSHIFTED DEPTH RUN NO. PASS NO. MERGE TOP MERGE BASE LIS FORMAT DATA LIS Tape Verification LisTing Schlumberger Alaska Computing Cenrer 27-MAR-1996 15:47 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 85 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 1 1 1 4 68 0000000000 DEPT FT 100313 IDPH DTE OH~flO0313 O0 000 O0 0 1 1 1 4 68 0000000000 IMPH DTE OH~g4100313 O0 000 O0 0 1 1 1 4 68 0000000000 ILD DTE 0H~4~100313 O0 000 O0 0 1 1 1 4 68 0000000000 ILM DTE OH~4~ 100313 O0 000 O0 0 1 1 1 4 68 0000000000 SFL DTE OH~MlO0313 O0 000 O0 0 1 1 1 4 68 0000000000 GR DTE GAPI 100313 O0 000 O0 0 1 1 1 4 68 0000000000 TEND DTE LB 100313 O0 000 O0 0 1 1 1 4 68 0000000000 TENS DTE LB 100313 O0 000 O0 0 1 1 1 4 68 0000000000 MRES DTE OH~PIiO0313 O0 000 O0 0 1 1 1 4 68 0000000000 MTEMDTE DEGF 100313 O0 000 O0 0 1 1 1 4 68 0000000000 SP DTE MV 100313 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 9500. 000 IDPH.DTE 3. 027 IMPH. DTE 3. 477 ILD.DTE iLM. DTE 3. 430 SFL.DTE 3. 594 GR.DTE -999. 250 TEND.DTE TENS.DTE 5115. 000 MRES.DTE O. 825 MTEM. DTE 156. 625 SP.DTE 2.990 537.500 -16.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-MA~-1996 15:47 PAGE: DEPT. 8552. 000 IDPH. DTE ILM. DTE 1. 331 SFL . DTE TENS.DTE 790. 000 MRES.DTE 1.518 IMPH.DTE 2.125 GR.DTE 0.959 MTE~.DTE 1.158 79.938 138.250 I LD . DTE TEND. DTE SP.DTE 1.541 121.000 -40.750 ** END OF DATA ** **** FILE TRAILER **** FiLE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/03/27 MAX REC SIZE : 4096 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/03/27 MAX REC SIZE : 4096 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Clipped curves for open hole logs run into casing. PASS NUMBER: 2 DEPTH INCREM~¥T: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 8552.0 8292.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ EQUIVALENT UNSHIFTED DEPTH REMARKS: No depth shifting as per Dave Shafer of ARCO. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-MAR-1996 15:47 PAGE: * * DATA FORMAT SPECIFICATION RECORD * * ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 0 12 68 13 66 0 ! 4 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN * * NAME SERV UNIT SERVICE API API API API FILE NOWB NUMB SIZE REPR PROCESS ID ORDER #LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100313 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH DTE GAPI 100313 O0 000 O0 0 2 1 1 4 68 0000000000 TEND DTE LB 100313 O0 000 O0 0 2 1 1 4 68 0000000000 TENS DTE LB 100313 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 8552.000 GRCH.DTE 88.938 TEND.DTE 588.000 TENS.DTE DEPT. 8298. 000 GRCH.DTE 205. 375 TEND.DTE 589. 500 TENS.DTE 4100.000 3955.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-MAR-1996 15:47 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01COI DATE : 96/03/27 MAX REC SIZE : 4096 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/03/27 MAX REC SIZE : 4096 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 3 RAW OPEN HOLE MAIN PASS Curves and log header dara for each run and ~ool string in separate files. RUN NUMBER: 1 TOOL STRING NUMBER .. 1 PASS NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH DITE 9500.0 GR 9475.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL {FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH 8552.0 8552.0 18-FEB-96 CP42.2 1800 18-FEB-96 252 18-FEB-96 9514.0 9511.0 8342.0 9504.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DITE PHASOR INDUCTION DITE PHASOR INDUCTION DITE AUX.MEASUREMENT TOOL NUMBER DIS-270 DIC- 163 A~ff4-AA-950 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-MAR-1996 15:47 PAGE: GR TCC TCC $ GA~gViA RAY TELEMETRY CARTRIDGE TELEMETRY CARTRIDGE SGC-SA-271 TCC-B-290 TCM-AB- 19 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : 4. 750 8569.0 8552.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OI~Vff4) AT TEMPERATURE (DEGF) : ~ AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT): DISP WEIGHTED CLAY/POLY 11.80 50.0 9.5 157.0 1. 970 68.0 1. 270 68.0 4. 140 68.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: USED NORDIC RKB FOR DEPTH REFERENCE. PRIMARY DEPTH CONTROL USED INCLUDING THE USE OF MAGNETIC MARKS. THIS LOG IS A COMPOSITE OF BOTH UP AND DOWN LOG PASSES. THE MAJOR PORTION OF THE LOG IS DOWN LOG WHICH IS DEPTH SHIFTED AS UP LOG. AFTER LOGGING DOWN, THE TOOLS STUCK AT 9450' FOR 3 1/2 HOURS AND TOOL PROBLEMS WERE PRESENT ONCE THE TOOLS CAME FREE. NO ADDITION OH LOGGING DONE $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Cen~er 27-MAR-1996 15:47 PAGE: TYPE REPR CODE VALUE 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 85 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILENUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100313 O0 000 O0 0 3 1 1 4 68 0000000000 IDPH LOG OP2~flO0313 O0 000 O0 0 3 1 1 4 68 0000000000 IMPH LOG OH2V~4100313 O0 000 O0 0 3 1 1 4 68 0000000000 ILD LOG OH~ 100313 O0 000 O0 0 3 1 1 4 68 0000000000 ILM LOG OH~f 100313 O0 000 O0 0 3 1 1 4 68 0000000000 SFLU LOG OHMMIO0313 O0 000 O0 0 3 1 1 4 68 0000000000 GR LOG GAPI 100313 O0 000 O0 0 3 1 1 4 68 0000000000 HTENLOG LB 100313 O0 000 O0 0 3 1 1 4 68 0000000000 TENS LOG LB 100313 O0 000 O0 0 3 1 1 4 68 0000000000 MRES LOG OH~ 100313 O0 000 O0 0 3 1 1 4 68 0000000000 MTE~ILOG DEGF 100313 O0 000 O0 0 3 1 1 4 68 0000000000 SP LOG MV 100313 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 9576.000 IDPH. LOG 3.031 IMPH.LOG 3.734 ILD.LOG ILM. LOG 3.709 SFLU. LOG 3.441 GR.LOG 106.938 HTEN. LOG TENS.LOG 1840.000 MRES.LOG 0.825 MTE~.LOG 156.625 SP. LOG DEPT. 8545.500 IDPH.LOG 1950.000 IMPH. LOG 1950.000 ILD.LOG ILM. LOG 1950.000 SFLU. LOG 1.201 GR.LOG 94.688 HTEN. LOG TENS.LOG 790.000 MRES.LOG 0.962 MTE~.LOG 138.250 SP.LOG 3. 004 87. 438 -15. 719 1950.000 107.563 -40.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-MAR-1996 15:47 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/03/27 MAX REC SIZE : 4096 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE · 96/03/27 MAX REC SIZE : 4096 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 1 0.5000 VENDOR TOOL CODE START DEPTH STOP DEPTH DITE 8750.0 8552.0 GR 8725.0 8552.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VE~VDOR TOOL CODE TOOL TYPE DITE PHASOR INDUCTION DITE PHASOR INDUCTION D I TE AUX. MEASUREMENT 18-FEB-96 CP42.2 1800 18-FEB-96 220 18-FEB-96 9514.0 9511.0 8342.0 9504.0 TOOL NUMBER DIS-270 DIC-163 AI~WI-AA-950 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-MAR-1996 15:47 PAGE: 10 GR TCC TCC $ GA~IA RAY TELE~ETRY CARTRIDGE TELEMETRY CARTRIDGE SGC-SA-271 TCC-B-290 TCM-AB - 19 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 4. 750 8569.0 8552.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : DISP WEIGHTED CLAY/POLY 11.80 50.0 9.5 157.0 1.970 68.0 1. 270 68.0 4.140 68.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: USED NORDIC RKB FOR DEPTH REFERENCE. PRIMARY DEPTH CONTROL USED INCLUDING THE USE OF MAGNETIC MARKS. THIS LOG IS A COMPOSITE OF BOTH UP AND DOWN LOG PASSES. THE MAJOR PORTION OF THE LOG IS DOWN LOG WHICH IS DEPTH SHIFTED AS UP LOG. AFTER LOGGING DOWN, THE TOOLS STUCK AT 9450' FOR 3 1/2 HOURS AND TOOL PROBLEMS WERE PRESENT ONCE THE TOOLS CAME FREE. NO ADDITION OH LOGGING USED $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-MAR-1996 15:47 PAGE: i1 TYPE REPR CODE VALUE 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 85 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUmB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 100313 O0 000 O0 0 4 1 1 4 68 0000000000 IDPH RPT 0H~100313 O0 000 O0 0 4 1 1 4 68 0000000000 IMPH RPT OHIV2~lO0313 O0 000 O0 0 4 1 1 4 68 0000000000 ILD RPT 0P24~ 100313 O0 000 O0 0 4 1 1 4 68 0000000000 ILM RPT OP2zI~ 100313 O0 000 O0 0 4 1 1 4 68 0000000000 SFLU RPT OH~MlO0313 O0 000 O0 0 4 1 1 4 68 0000000000 GR RPT GAPI 100313 O0 000 O0 0 4 1 1 4 68 0000000000 HTENRPT LB 100313 O0 000 O0 0 4 1 1 4 68 0000000000 TENS RPT LB 100313 O0 000 O0 0 4 1 1 4 68 0000000000 M~RES RPT 0H~100313 O0 000 O0 0 4 1 1 4 68 0000000000 MTE~RPT DEGF 100313 O0 000 O0 0 4 1 1 4 68 0000000000 SP RPT MV 100313 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 8812.000 IDPH. RPT 3.803 IMPH.RPT 4.055 ILD.RPT ILM. RPT 4.020 SFLU. RPT 3.670 GR.RPT 126.188 HTEN. RPT TENS.RPT 2250.000 MRES.RPT 0.968 MTE~.RPT 138.875 SP.RPT DEPT. 8337.500 IDPH. RPT 47.688 IMPH.RPT 1950.000 ILD.RPT ILM. RPT 1950.000 SFLU. RPT 0.661 GR.RPT 165.000 HTEN. RPT TENS.RPT 3930.000 MRES.RPT 0.959 MTEM. RPT 137.000 SP.RPT 3.770 266.250 18.031 45.188 575.000 -93.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing CenZer 27-MAR-1996 15:47 PAGE: 12 **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE : 96/03/27 MAX REC SIZE : 4096 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 96/03/27 MAX REC SIZE : 4096 FILE TYPE : LO LAST FILE : GR LOG HEADER DATA FILE HEADER FILE NUMBER 5 RAW CASED HOLE MAIN PASS Curves and log header da~a for open hole logs run into casing. PASS NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE SUN~VlARY VENDOR TOOL CODE START DEPTH STOP DEPTH 8552.0 8292.0 DA TE LOGGED: 18 - FEB q 96 SOFTWARE VERSION: CP42.2 TIME CIRCULATION ENDED: 1800 18-FEB-96 TIME LOGGER ON BOTTOM: 220 18-FEB-96 TD DRILLER (FT) : 9514.0 TD LOGGER (FT) : 9511.0 TOP LOG INTERVAL (FT) : 8342.0 BOTTOM LOG INTERVAL (FT) : 9504.0 LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DITE PHASOR INDUCTION DIS- 270 DITE PHASOR INDUCTION DIC-163 D I TE AUX. MEASUREMENT A~M- AA - 950 GR GAFflViA RAY SGC-SA-271 TCC TELEMETRY CAR TR IDGE TCC- B ~ 290 TCC TELEMETRY CARTRIDGE TCM-AB - 19 LIS Tape Verlficarion Listing Schlumberger Alaska Computing Center 27-MAR-1996 15:47 PAGE: 13 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 4.750 8569.0 8552.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OHNff~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : ~RID CAKE AT (MT): MUD CAKE AT (BHT) : DISP WEIGHTED CLA~POLY 11.80 50.0 9.5 157.0 1. 970 68.0 1.270 68.0 4. 140 68.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): RE~La2~KS: USED NORDIC RKB FOR DEPTH REFERENCE. PRIMARY DEPTH CONTRO INCLUDING THE USE OF MANGETIC MARKS. THIS LOG IS A COMPOSITE OF BOTH UP AND DOWN LOG PASSES. THE MAJOR PORTION OF THE LOG IS DOWN LOG WHICH IS DEPTH SHIFTED AS UP LOG. AFTER LOGGING DOWN, THE TOOLS STUCK AT 9450' FOR 3 1/2 HOURS AIVD TOOL PROBLEMS WERE PRESENT ONCE THE TOOLS CAME FREE. NO ADDITION O.H. LOGGING WAS WA LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE i 66 0 2 66 0 3 73 16 4 66 1 5 66 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-MAR-1996 15:47 PAGE: 14 TYPE REPR CODE VALUE 6 73 7 65 8 68 0.5 9 65 FT 11 66 0 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 100313 O0 000 O0 0 5 1 I 4 68 0000000000 GR CSG GAPI 100313 O0 000 O0 0 5 1 1 4 68 0000000000 HTEN CSG LB 100313 O0 000 O0 0 5 1 1 4 68 0000000000 TENS CSG LB 100313 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 8552.000 GR.CSG 88.938 HTEN. CSG 588.000 TENS. CSG DEPT. 8298.000 GR.CSG 205.375 HTEN. CSG 589.500 TENS. CSG 4100.000 3955.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 96/03/27 MAX REC SIZE : 4096 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Cen~er 27-MAR-1996 15:~7 PAGE: 15 **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 96/03/27 ORIGIN : FLIC TAPE NAME : 96074 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA INC, 1Q-22A, KUPARUK, API #50-029-22595-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE · 96/03/27 ORIGIN · FLIC REEL NAME · 96074 CONTINUATION # : PREVIOUS REEL : CO~4~ENT : ARCO ALASKA INC, 1Q-22A, KUPARUK, API #50-029-22595-01