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190-035
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, December 19, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1L-10 KUPARUK RIV UNIT 1L-10 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/19/2024 1L-10 50-029-22026-00-00 190-035-0 W SPT 5832 1900350 1500 1200 1200 1200 1200 88 88 87 87 INITAL P Austin McLeod 10/31/2024 Post RWO. Sundry 324-471. 30 MinPretest Initial 15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name: KUPARUK RIV UNIT 1L-10 Inspection Date: Tubing OA Packer Depth 420 2000 1915 1890IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM241031181221 BBL Pumped:1.6 BBL Returned:1.4 Thursday, December 19, 2024 Page 1 of 1 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Replace Tubing Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9241'feet None feet true vertical 6385' feet None feet Effective Depth measured 8371'feet 8350', 8532', 8879'feet true vertical 6700'feet 5707', 5831', 6089'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" 4-1/2" 3-1/2" L-80 L-80 L-80 8493' 8882' 8903' 5804' 6092' 6107' Packers and SSSV (type, measured and true vertical depth)8350' 8532' 8879' 5707' 5831' 6089' 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: 324-471 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: Blue Pack Max Packer: BAKER FHL Packer: BAKER FB-1 SSSV: None Adam Klem adam.klem@conocophillips.com (907) 263-4529Staff RWO/CTD Engineer 8713-8790', 8800-8806', 8811-8819', 8924-8956', 9016-9024' 5964-6021', 6029-6033', 6037-6043', 6124-6149', 6197-6204' 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 115' N/A Well Shut-In measured TVD 7" 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 191-035 50-029-22026-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025659, ADL0025660 Kuparuk River Field/ Kuparuk Oil Pool KRU 1L-10 Plugs Junk measured Length Production 2121' 9191' Casing 1908' 6370' 2153' 9224' 5101' 115'Conductor Surface Tie Back String 16" 9-5/8" 79' 5137' 3681' Burst Collapse 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 9:57 am, Oct 11, 2024 Digitally signed by Adam Klem DN: CN=Adam Klem, E=adam.klem@ conocophillips.com, C=US Reason: I am approving this document Location: Date: 2024.10.11 09:30:53-08'00' Foxit PDF Editor Version: 13.0.0 Adam Klem Page 1/10 1L-10 Report Printed: 10/10/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/2/2024 16:00 9/3/2024 00:00 8.00 MIRU, MOVE MOB P Back rig off 1B-07. Prep for rig move to 1L. PU mats around cellar area. Clean up around well in prep for Pad Op Environmental inspection. Cont. to haul support equipment to 1L. Finsih rig prep for move to 1L. Call Security. Rig move to start @ 19:00 after field change out. 0.0 0.0 9/3/2024 00:00 9/3/2024 18:00 18.00 MIRU, MOVE MOB P Continue moving toward 1F staging area. Start moving mats from spine to 1F to 1FC to 1L 0.0 0.0 9/3/2024 18:00 9/4/2024 00:00 6.00 MIRU, MOVE WAIT P Continue to wait for matts to be shuffled for rig move. Lay down herculite and mats on 1L-10. Open 7" rams for BWM inspection 0.0 0.0 9/4/2024 00:00 9/4/2024 06:00 6.00 MIRU, MOVE WAIT P Continue to wait for matts to be shuffled for rig move. Lay down herculite and mats on 1L-10 0.0 0.0 9/4/2024 06:00 9/4/2024 08:00 2.00 MIRU, MOVE MOB P Start moving rig towards 1L pad // TH start matt shuffle 0.0 0.0 9/4/2024 08:00 9/4/2024 11:00 3.00 MIRU, MOVE WAIT P Wait for mats to be shuffled behind rig Perform balence of BWM on BOPE 0.0 0.0 9/4/2024 11:00 9/4/2024 12:00 1.00 MIRU, MOVE MOB P Continue moving toward 1L-10 0.0 0.0 9/4/2024 12:00 9/4/2024 15:00 3.00 MIRU, MOVE WAIT P Wait for mats to be shuffled 0.0 0.0 9/4/2024 15:00 9/4/2024 18:00 3.00 MIRU, MOVE MOB P On 1L pad. Maps to well, Start spotting rig on 1L-10 0.0 0.0 9/4/2024 18:00 9/5/2024 00:00 6.00 MIRU, MOVE RURD P Spotted on well, Safe out rig, Work rig accept check list. Spot tanks, cutiings box. Rig up well kill hoses. Rig up hardline to tanks, Take on 10.9 PPG to pits. RIG ACCEPT 23:00 0.0 0.0 9/5/2024 00:00 9/5/2024 01:30 1.50 MIRU, WELCTL RURD P Continue to rig up KWF circulation equipment 0.0 0.0 9/5/2024 01:30 9/5/2024 02:00 0.50 MIRU, WELCTL SEQP P PT line to tank manifold, 2500 PSI 0.0 0.0 9/5/2024 02:00 9/5/2024 03:00 1.00 MIRU, WELCTL OTHR P Bleed off well, Initial tubing pressure 580, Bleed down in steps to 145 PSI. Mix of fluid and gas. Initial IA 184. Bleed down to 60 PSI. Went to zero bleeding off tubing 0.0 0.0 9/5/2024 03:00 9/5/2024 05:00 2.00 MIRU, WELCTL KLWL P Start well kill. Work pump up to 4 BPM holding 300 PSI casing pressure. 0.0 0.0 9/5/2024 05:00 9/5/2024 05:45 0.75 MIRU, WELCTL OWFF P Pump 450 BBls 10.9, Last three samples all 10.9, FCP=955. IA=308 0.0 0.0 9/5/2024 05:45 9/5/2024 06:45 1.00 MIRU, WHDBOP RURD P Rig down circulating equipment // Set BPV, test 1000 psi 10 min 0.0 0.0 9/5/2024 06:45 9/5/2024 08:45 2.00 MIRU, WHDBOP NUND P Nipple down production tree, inspect hanger threads, install test dart 0.0 0.0 9/5/2024 08:45 9/5/2024 12:30 3.75 MIRU, WHDBOP NUND P Nipple up BOPs // WH leaning straightnen up stack // Install riser and trip tank lines 0.0 0.0 9/5/2024 12:30 9/5/2024 13:30 1.00 MIRU, WHDBOP RURD P Grease valves rig up for testing flood stack for shell test, Blind ram door seal leaking 0.0 0.0 9/5/2024 13:30 9/5/2024 15:00 1.50 MIRU, WHDBOP RGRP T Replace door seal on blind rams 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 9/15/2024 Page 2/10 1L-10 Report Printed: 10/10/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/5/2024 15:00 9/5/2024 21:00 6.00 MIRU, WHDBOP BOPE P Fill stack, Purge air. Shell test BOPE, Initial BOPE test, Tested BOPE at 250/3000 PSI for 5 Min each, Tested annular w/ 3 1/2 & 7" test joint. , UVBR's W/ 3 ½ test joint. Test LPR w/7" test joint. Test blinds rams. Choke valves #1 to #13, upper and lower top drive well control valves. Test 3 1/2" IF FOSV and IBOP. Test 3 ½ & 4 ½ EUE FOSV. Test 2" 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=3050 PSI, after closure=1600 PSI, 200 PSI attained =23 sec, full recovery attained =134 sec. UVBR's= 5 sec, Simulated LVBRs= 5 sec. Annular= 17 sec. Simulated blinds= 5 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average =2050 PSI. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Kam St.John 0.0 0.0 9/5/2024 21:00 9/5/2024 22:00 1.00 MIRU, WHDBOP RURD P R/D testing equipment. Blow down lines, R/U pull BPV, Make up landing joint to hanger. M/U to top drive. Set down 10K 0.0 0.0 9/5/2024 22:00 9/5/2024 22:30 0.50 COMPZN, RPCOMP PULL P Back out LDS, See hanger pull free @ 115K, Dragging 105K. Pull hanger to floor 0.0 0.0 9/5/2024 22:30 9/6/2024 00:00 1.50 COMPZN, RPCOMP CIRC P Circulate BU 5 BPM @ 640 PSI, 250 BBls, OWFF, blow down top drive 0.0 0.0 9/6/2024 00:00 9/6/2024 00:30 0.50 COMPZN, RPCOMP PULL P Pull one joint 3 1/2" completion. Well on slow simmer. R/U headpin to circ another BU 0.0 0.0 9/6/2024 00:30 9/6/2024 01:30 1.00 COMPZN, RPCOMP CIRC P Circulate 221 BBls 10.9PPG @ 4 BPM @460 PSI OWFF 0.0 0.0 9/6/2024 01:30 9/6/2024 09:00 7.50 COMPZN, RPCOMP PULL P Well static, Continue pull 3 1/2" completion from 8414', PUW=98K Cut Jt 14.35' 8,414.0 0.0 9/6/2024 09:00 9/6/2024 09:30 0.50 COMPZN, RPCOMP OTHR P Set wear ring 0.0 0.0 9/6/2024 09:30 9/6/2024 10:00 0.50 COMPZN, RPCOMP RURD P Rig up E-line 0.0 0.0 9/6/2024 10:00 9/6/2024 14:45 4.75 COMPZN, RPCOMP ELNE P E-line F/ 5150' to surface // CBL and CCL 0.0 0.0 9/6/2024 14:45 9/6/2024 15:45 1.00 COMPZN, RPCOMP RURD P Rig down e-line unit 0.0 0.0 9/6/2024 15:45 9/6/2024 16:00 0.25 COMPZN, RPCOMP BHAH P Pick up BHA#1 G-plug 0.0 16.0 9/6/2024 16:00 9/6/2024 19:30 3.50 COMPZN, RPCOMP PULD P RIH on singles of drill pipe to 2242' 16.0 2,242.0 9/6/2024 19:30 9/6/2024 20:00 0.50 COMPZN, RPCOMP MPSP P Kelly up, PUW=69K, SOW=55K, RIH to 2255', Set RPB @ 2255, COE=2247, Top of plug @ 2244 2,242.0 2,255.0 9/6/2024 20:00 9/6/2024 20:30 0.50 COMPZN, RPCOMP MPSP P PUH to 2242. PT RBB 2000PSI for 10 min. Good test 2,255.0 2,242.0 9/6/2024 20:30 9/6/2024 22:00 1.50 COMPZN, RPCOMP DISP P Displace 10.9 PPG fluid above RBP to seawater. 2,242.0 2,242.0 Rig: NORDIC 3 RIG RELEASE DATE 9/15/2024 Page 3/10 1L-10 Report Printed: 10/10/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/6/2024 22:00 9/7/2024 00:00 2.00 COMPZN, RPCOMP RURD P Lay down single, Rack back one stand. Blow down top drive and choke line. Rig up to dump 23 bags of sand, 7 bags in @ midnight 2,242.0 2,150.0 9/7/2024 00:00 9/7/2024 03:30 3.50 COMPZN, RPCOMP OTHR P Continue to dump sand. 23 sacks in Shut down circulation 2,150.0 2,150.0 9/7/2024 03:30 9/7/2024 04:30 1.00 COMPZN, RPCOMP OTHR P Let sand settle one hour 2,150.0 2,150.0 9/7/2024 04:30 9/7/2024 04:42 0.20 COMPZN, RPCOMP OWFF P P/U stand, Tag top of sand @ 2189' // Pu Wt off bottom 63K So Wt on bottom 53K 2,150.0 2,189.0 9/7/2024 04:42 9/7/2024 08:00 3.30 COMPZN, RPCOMP TRIP P Trip out of well, PUW=69K // Upone trip out found 1 jt short in string // Adjusted Plug depth 2218' COE 2214' Top of plug // Top of sand adjusted 2158' 2,189.0 0.0 9/7/2024 08:00 9/7/2024 08:30 0.50 COMPZN, RPCOMP OWFF P MT stack observe well for flow at well head // No flow 0.0 0.0 9/7/2024 08:30 9/7/2024 10:00 1.50 COMPZN, RPCOMP NUND P Remove trip tank hose // Remove riser from stack // Nipple down stack // 0.0 0.0 9/7/2024 10:00 9/7/2024 13:00 3.00 COMPZN, RPCOMP CUTP P Rig up cameron CGT to tubing head // Relieve stress in casing // Total growth 4" // Wait 30 min for complete growth 0.0 0.0 9/7/2024 13:00 9/7/2024 14:30 1.50 COMPZN, RPCOMP CUTP P Spear 7" casing // Pull 50K over string wt ( 95K ) // set slips total stretch 24" // Total Grow and Stretch = 28" // Cut excess off for stabbing DSA 0.0 0.0 9/7/2024 14:30 9/7/2024 16:30 2.00 COMPZN, RPCOMP NUND P Nipple up stream flow DSA and BOPs // Install riser 0.0 0.0 9/7/2024 16:30 9/7/2024 17:00 0.50 COMPZN, RPCOMP SVRG P Service draw works, Inspect top drive 0.0 0.0 9/7/2024 17:00 9/7/2024 17:30 0.50 COMPZN, RPCOMP BHAH P Make up casing collar BHA #3 0.0 4.0 9/7/2024 17:30 9/7/2024 19:00 1.50 COMPZN, RPCOMP TRIP P Trip in hole to 2104 4.0 2,104.0 9/7/2024 19:00 9/7/2024 20:30 1.50 COMPZN, RPCOMP SLPC P PJSM, Slip and cut drilling line 2,104.0 2,104.0 9/7/2024 20:30 9/7/2024 21:00 0.50 COMPZN, RPCOMP SVRG P Lubricate crown, Shieves, top drive 2,104.0 2,104.0 9/7/2024 21:00 9/7/2024 21:30 0.50 COMPZN, RPCOMP TRIP P RIH, Dry tag top of sand 2158. PUH to 2136. Pumps online @ 2 BPM 220 PSI, Locate lower collar @ 2175'. Shut down pump. PUH to 2130. Pumps online @ 2 BPM @ 220 PSI. Locate casing collar @ 2134'. 2,104.0 2,134.0 9/7/2024 21:30 9/7/2024 22:00 0.50 COMPZN, RPCOMP CPBO P RIH to 2151.2. Cutter blades @ 2150'. Rotate 65 RPM. Free torque @ 1295 Lb/Ft. Bring pumps online 3 BPM @ 1215 PSI. Observe torque increase to 5- 7K then drop of to free torque. 2,151.2 2,151.2 9/7/2024 22:00 9/7/2024 23:30 1.50 COMPZN, RPCOMP CIRC P Circ 40 BBl deep clean pill followed with 80 BBls seawater 2,151.2 2,151.2 9/7/2024 23:30 9/8/2024 00:00 0.50 COMPZN, RPCOMP OWFF P OWFF - Good 2,151.2 2,151.0 9/8/2024 00:00 9/8/2024 01:00 1.00 COMPZN, RPCOMP TRIP P POOH, PUW=65 2,151.0 0.0 9/8/2024 01:00 9/8/2024 01:30 0.50 COMPZN, RPCOMP OWFF P Drain stack, OWFF 0.0 0.0 9/8/2024 01:30 9/8/2024 02:00 0.50 COMPZN, RPCOMP BHAH P Lay down cutter, P/U 7" casing spear. Engauge 7" casing. Set down 10K. 0.0 0.0 9/8/2024 02:00 9/8/2024 02:18 0.30 COMPZN, RPCOMP FISH P Engauge 7" casing spear. Set down 10K. Back out LDS. Came free from casing head @ 90K 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 9/15/2024 Page 4/10 1L-10 Report Printed: 10/10/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/8/2024 02:18 9/8/2024 03:00 0.70 COMPZN, RPCOMP NUND P Air down boots, Nipple down stack Lift stack 0.0 0.0 9/8/2024 03:00 9/8/2024 04:00 1.00 COMPZN, RPCOMP OTHR P Pull caasing, Pull casing e slips. Pull pack off to rig floor 0.0 0.0 9/8/2024 04:00 9/8/2024 06:00 2.00 COMPZN, RPCOMP NUND P Stab stack, M/U and torgue bolts. Install chain falls on stack, Air up boots. 2,150.0 2,150.0 9/8/2024 06:00 9/8/2024 07:00 1.00 COMPZN, RPCOMP RURD P Rig up GBR remove packoffs and slips from pipe 2,150.0 2,130.0 9/8/2024 07:00 9/8/2024 11:15 4.25 COMPZN, RPCOMP PULL P Pull and lay down 7" casing from Cut @ 2150' // Cut Jt 17.56' , 51 full jts and 1 landing jt @ 36.52' 2,130.0 0.0 9/8/2024 11:15 9/8/2024 12:00 0.75 COMPZN, RPCOMP RURD P Rig down casing crew, clean floor prep to pick up BHA 0.0 0.0 9/8/2024 12:00 9/8/2024 12:30 0.50 COMPZN, RPCOMP SVRG P Service rig and inspect derrick 0.0 0.0 9/8/2024 12:30 9/8/2024 15:00 2.50 COMPZN, RPCOMP PRTS P Install test plug in casing head // Charted 250/3000 test on DSA Breaks 0.0 0.0 9/8/2024 15:00 9/8/2024 15:30 0.50 COMPZN, RPCOMP OTHR P Install wear bushing in casing head 0.0 0.0 9/8/2024 15:30 9/8/2024 17:00 1.50 COMPZN, RPCOMP BHAH P Strap and pick up drift BHA 0.0 0.0 9/8/2024 17:00 9/8/2024 18:00 1.00 COMPZN, RPCOMP BHAH P P/U BHA #5, Drift run w/8.25 junk mill, dog boned 8.5" reamers and drill collars 0.0 157.8 9/8/2024 18:00 9/8/2024 18:30 0.50 COMPZN, RPCOMP SFTY P Crew change, PJSM to trip in hole 157.8 157.8 9/8/2024 18:30 9/8/2024 19:00 0.50 COMPZN, RPCOMP TRIP P Trip in hole to 448' set down. 157.8 448.0 9/8/2024 19:00 9/8/2024 20:00 1.00 COMPZN, RPCOMP REAM P KU, Try to wash through . No go. PUH ROT=65 RPM, 4 BPM @ 120 PSI. Obseve torque up @ 448 - Mill and 460 - string reamer. Clean @ 463. Cycle through area then dry drift good. 448.0 530.0 9/8/2024 20:00 9/8/2024 21:30 1.50 COMPZN, RPCOMP TRIP P Continue tripping in F/530 to light tag @ 2150 no issues 530.0 2,150.0 9/8/2024 21:30 9/8/2024 22:30 1.00 COMPZN, RPCOMP TRIP P POOH, No overpulls 480 to 430', PUW=60K 2,150.0 157.0 9/8/2024 22:30 9/9/2024 00:00 1.50 COMPZN, RPCOMP BHAH P Rack back stand of collars. Lay down bit sub and Junk mill 157.0 0.0 9/9/2024 00:00 9/9/2024 00:30 0.50 COMPZN, RPCOMP BHAH P P/U 7" dress off shoe 0.0 159.4 9/9/2024 00:30 9/9/2024 02:00 1.50 COMPZN, RPCOMP TRIP P Trip in hole, to 2155 159.4 2,155.0 9/9/2024 02:00 9/9/2024 02:30 0.50 COMPZN, RPCOMP MILL P Polish 7" casing stub, 4 BPM @ 215 PSI, 45 RPM // Dress down to 2155' , leaving top of stump @ 2150.2' 2,155.0 2,155.0 9/9/2024 02:30 9/9/2024 03:00 0.50 COMPZN, RPCOMP CIRC P Pump 35 BBl hi vis sweep, 5 BPM @ 300 PSI 2,155.0 2,155.0 9/9/2024 03:00 9/9/2024 04:00 1.00 COMPZN, RPCOMP OWFF P Flow check well, Blow down top drive, Choke and kill lines 2,155.0 2,155.0 9/9/2024 04:00 9/9/2024 05:30 1.50 COMPZN, RPCOMP TRIP P Trip out of well, PUW=66K 2,155.0 160.0 9/9/2024 05:30 9/9/2024 06:30 1.00 COMPZN, RPCOMP BHAH P Lay down BHA // Inspect mills 160.0 0.0 9/9/2024 06:30 9/9/2024 07:00 0.50 COMPZN, RPCOMP OTHR P Remove wear bushing from stack 0.0 0.0 9/9/2024 07:00 9/9/2024 08:30 1.50 COMPZN, RPCOMP RURD P Rig up GBR torque turn for 7" casing 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 9/15/2024 Page 5/10 1L-10 Report Printed: 10/10/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/9/2024 08:30 9/9/2024 13:30 5.00 COMPZN, RPCOMP PUTB P Confirm running order, pick up and run 7" Hyd 563 Casing // Up wt 85K Dn Wt 75K Latch casing @ 2150.2 Full locate 2153' // Pull up to 150K confirm latch 7" x 8 1/4"Bladed Summit Centralizers ran every other joing F/ #1 T/ #49 & #50. Total of 26 Ran 0.0 2,153.0 9/9/2024 13:30 9/9/2024 14:00 0.50 COMPZN, RPCOMP PRTS P PT Casing patch 1000 psi 10 min good test // Pressure up open ES Cementer 3200 psi 2,153.0 2,153.0 9/9/2024 14:00 9/9/2024 14:30 0.50 COMPZN, RPCOMP OWFF P OWFF @ well head no flow 2,153.0 2,153.0 9/9/2024 14:30 9/9/2024 16:30 2.00 COMPZN, RPCOMP HOSO P Break stack set E-slips and packoff w/ 66K over. // PT break with stream flow flange 3000 psi good test 2,153.0 2,153.0 9/9/2024 16:30 9/9/2024 18:00 1.50 COMPZN, RPCOMP CIRC P Circulate 140° water down 7" up OA warm up annulus for cement 2,153.0 2,153.0 9/9/2024 18:00 9/9/2024 19:15 1.25 COMPZN, RPCOMP RURD P Rig up cement lines // Load closing plug // PT lines 4000 psi 2,153.0 2,153.0 9/9/2024 19:15 9/9/2024 21:15 2.00 COMPZN, RPCOMP CMNT P Pump cement 10 bbls lead with dye 120 bbls 11# 30 bbls 15.3# 10 bbls 8.3 tail flush 70 bbls bump plug Batched up 19:40 Dropped plug @ 20:44 Bumped plug @ 2,153.0 2,153.0 9/9/2024 21:15 9/9/2024 21:27 0.20 COMPZN, RPCOMP CMNT P Dart landed 82 BBls, FCP=700 PSI. Hold dart pressure 2150 for 5 minutes. 11PPG final sample at tank. 80 BBls excess cement in cuttings box. Calculated 86 BBls excess pumped 2,153.0 2,153.0 9/9/2024 21:27 9/9/2024 22:00 0.55 COMPZN, RPCOMP CMNT P Open up cement head no flow, Blow down lines. Line up to pump contam pill through rig. 2,153.0 2,153.0 9/9/2024 22:00 9/10/2024 00:00 2.00 COMPZN, RPCOMP RURD P R/D cement head and cross over, R/D OA valves, Lay down excess 7" tubulars 2,153.0 2,153.0 9/10/2024 00:00 9/10/2024 01:00 1.00 COMPZN, RPCOMP WOC P R/D cellar iron. 0.0 0.0 9/10/2024 01:00 9/10/2024 06:00 5.00 COMPZN, RPCOMP WOC P Clear and clean rig floor, Continue to load / process 3 1/2" drill pipe 0.0 0.0 9/10/2024 06:00 9/10/2024 12:00 6.00 COMPZN, RPCOMP WOC P Inspect Derrick, Service crown and draw works. Clean suction and discharge screens on mud pump. Clean and organize pits, cellar, rig floor 0.0 0.0 9/10/2024 12:00 9/10/2024 12:30 0.50 COMPZN, RPCOMP SFTY P PJSM Deflate air boots on riser, ND stack, and lift stack for 7" casing cut 0.0 0.0 9/10/2024 12:30 9/10/2024 13:30 1.00 COMPZN, RPCOMP NUND P ND BOPE, R/U WHACKS cutter. Cut 7" casing. P/U cut joint to rig floor. Cut joint 29.84' 0.0 0.0 9/10/2024 13:30 9/10/2024 16:00 2.50 COMPZN, RPCOMP NUND P NU Stack. Pull riser, ND DSA. Rack back BOPE. M/U new tubing head. M/U DSA. 0.0 0.0 9/10/2024 16:00 9/10/2024 16:30 0.50 COMPZN, RPCOMP PRTS P PT casing pack off 3000 PSI 15 minutes. 0.0 0.0 9/10/2024 16:30 9/10/2024 17:30 1.00 COMPZN, RPCOMP NUND P M/U upper DSA flange, Secure stack. Install riser. Fill stack w/ fresh water. 0.0 0.0 9/10/2024 17:30 9/10/2024 18:00 0.50 COMPZN, RPCOMP MPSP P Install test plug. Fill stack w/ fresh water. 0.0 0.0 9/10/2024 18:00 9/10/2024 18:30 0.50 COMPZN, RPCOMP PRTS P P/U BOP stack breaks 250/3000 PSI. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 9/15/2024 Page 6/10 1L-10 Report Printed: 10/10/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/10/2024 18:30 9/10/2024 19:30 1.00 COMPZN, RPCOMP MPSP P Drain stack., Pull Test plug. Install wear bushing. Take new RKB's. 0.0 0.0 9/10/2024 19:30 9/10/2024 20:30 1.00 COMPZN, RPCOMP RURD P Mobilize BHA #7 to RF & Pipe shed. 0.0 0.0 9/10/2024 20:30 9/10/2024 22:15 1.75 COMPZN, RPCOMP BHAH P M/U BHA #7 roller cone bit, 6 1/8" string mill, boot baskets, magnets & collars T/ 189'. SOW=40K. 0.0 189.0 9/10/2024 22:15 9/11/2024 00:00 1.75 COMPZN, RPCOMP PULD P PUDP F/ 189' T/ 1547', SOW=50 189.0 9/11/2024 00:00 9/11/2024 00:30 0.50 COMPZN, RPCOMP PULD P PUDP F/ 1547' T/ 2076', Set down 5 K. 1,547.0 2,076.0 9/11/2024 00:30 9/11/2024 01:30 1.00 COMPZN, RPCOMP DISP P Obtain parameters circ @ 4 BPM, 240 PSI. Rot @ 30 RPM, 1.7K Free Tq. Displace well T/ vis seawater. Work single F/ 2076' T/ 2105' through stringer. 2,076.0 2,105.0 9/11/2024 01:30 9/11/2024 04:30 3.00 COMPZN, RPCOMP DRLG P Drill cement string to plug @ 2140' @ 4 BPM, 240 PSI. Rot @ 30-50 RPM, 1.7- 10K Tq. 2-10K WOB. Drill through plug & retainer T/ sand top @ 2256'. Dry drill on sand top for 15 min. 2,105.0 2,156.0 9/11/2024 04:30 9/11/2024 05:30 1.00 COMPZN, RPCOMP CIRC P P/U T/ 2127'. Circ 15 Bbls hi vis pill around @ 8 BPM. 760 PSI. B/D TD. 2,156.0 2,127.0 9/11/2024 05:30 9/11/2024 07:00 1.50 COMPZN, RPCOMP TRIP P Trip out, 2127 to 188' 2,127.0 188.0 9/11/2024 07:00 9/11/2024 08:00 1.00 COMPZN, RPCOMP BHAH P L/D intensifier, Rack back collars, Clean magnets, Check - clean boot baskets, Lay down string reamers 188.0 0.0 9/11/2024 08:00 9/11/2024 09:00 1.00 COMPZN, RPCOMP BHAH P M/U BHA #8. 5 3/4' RFJB, Boot baskets and magnets 0.0 177.0 9/11/2024 09:00 9/11/2024 12:12 3.20 COMPZN, RPCOMP PULD P RIH w/ BHA #8 to 2152 set down. Hard bottom. PUH PUW=62K, RIW=60K. Pumps online. Drill string plugged. Bleed off pressure. Work pipe above set down. Bring pumps online drill pipe cleared. 3.8 BPM @ 2180 PSI. Tag bottom. Not acting like sand bottom. PUH. Rotate 20 RPM @ 1380 free torque. RIH. making footage from 2152 to 2157 177.0 2,157.0 9/11/2024 12:12 9/11/2024 12:48 0.60 COMPZN, RPCOMP CIRC P Circ BU @ @ 3.8 BPM @ 2165' PSI. Need to make connection. Light sand, cement, and rubber on shaker at BU. 2,157.0 2,165.0 9/11/2024 12:48 9/11/2024 13:30 0.70 COMPZN, RPCOMP MILL P Make connection, 3.8 BPM @ 2180 PSI, 20 RPM FT=1380. Working down taking small bites to 2170' 2,165.0 2,170.0 9/11/2024 13:30 9/11/2024 14:00 0.50 COMPZN, RPCOMP CIRC P At 2170' Circ on bottom then PUH to 2165. Circ BU 3.8 BPM @ 2180 PSI 2,170.0 2,170.0 9/11/2024 14:00 9/11/2024 15:30 1.50 COMPZN, RPCOMP TRIP P Trip out, BHA #8, PUW=60k 2,170.0 177.0 9/11/2024 15:30 9/11/2024 16:30 1.00 COMPZN, RPCOMP BHAH P At BHA, Stand back collars, RCJB large chunks of cement w/ some metal. Two jets on basket plugged. Cleaned boot baskets - empty. minimal material on magnets. M/U BHA to re-run 177.0 0.0 9/11/2024 16:30 9/11/2024 17:30 1.00 COMPZN, RPCOMP BHAH P Run in hole BHA #9 RCJB #2 T/ 177'. M/U single T/ 207' 0.0 207.0 9/11/2024 17:30 9/11/2024 18:00 0.50 COMPZN, RPCOMP CLEN P Clean & clear RF. 207.0 207.0 9/11/2024 18:00 9/11/2024 18:30 0.50 COMPZN, RPCOMP SVRG P Service rig. Grease draw works & TD. 207.0 207.0 9/11/2024 18:30 9/11/2024 20:45 2.25 COMPZN, RPCOMP PULD P PUDP F/ 207', dry tag top of sand @ 2175'. PUW=68K, SOW=60K. 207.0 2,175.0 Rig: NORDIC 3 RIG RELEASE DATE 9/15/2024 Page 7/10 1L-10 Report Printed: 10/10/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/11/2024 20:45 9/11/2024 21:00 0.25 COMPZN, RPCOMP CIRC P P/U T/ 2146'. Circ STB @ 8 BPM, 880 PSI. RIH T/ 2156'. Drop RCJB activation ball. Pump ball on seat @ 1 BPM, 83 PSI. 2,175.0 2,156.0 9/11/2024 21:00 9/11/2024 21:15 0.25 COMPZN, RPCOMP WASH P Circ @ 5.5 BPM, 1725 PSI. Rot @ 20 RPM, Free Tq =1.5. ROT=63K. Wash sand down T/ 2185'. 2,156.0 2,185.0 9/11/2024 21:15 9/11/2024 22:00 0.75 COMPZN, RPCOMP CIRC P P/U T/ 2158'. Circ STS @ 7 BPM, 2910 PSI. Sand at shakers. 2,185.0 2,158.0 9/11/2024 22:00 9/11/2024 22:15 0.25 COMPZN, RPCOMP OWFF P OWFF, B/D TD. 2,158.0 2,158.0 9/11/2024 22:15 9/11/2024 23:30 1.25 COMPZN, RPCOMP TRIP P POOH F/ 2158' T/ 177' PUW=68K. 2,158.0 177.0 9/11/2024 23:30 9/12/2024 00:00 0.50 COMPZN, RPCOMP BHAH P L/D BHA #9. Inspect RCJB, large chunks of cement in RCJB. 177.0 0.0 9/12/2024 00:00 9/12/2024 00:45 0.75 COMPZN, RPCOMP BHAH P M/U BHA #10, RCJB #3 T/ 177'. SOW=40K. 0.0 177.0 9/12/2024 00:45 9/12/2024 02:00 1.25 COMPZN, RPCOMP PULD P PUDP F/ 177' T/ 731'. SOW=50K. 177.0 731.0 9/12/2024 02:00 9/12/2024 02:45 0.75 COMPZN, RPCOMP TRIP P RIH F/ 731', dry tag sand 2190'. 731.0 2,190.0 9/12/2024 02:45 9/12/2024 03:00 0.25 COMPZN, RPCOMP CIRC P P/U T/ 2158'. Circ STB @ 8 BPM, 770 PSI. Drop RCJB activation ball and circ on seat @ 1 BPM. 2,190.0 2,158.0 9/12/2024 03:00 9/12/2024 03:15 0.25 COMPZN, RPCOMP WASH P Circ @ 5.5 BPM, 1850 PSI. Rot @ 25 RPM, Free Tq =1.5. ROT=63K. Wash sand down T/ 2198'. 2,158.0 2,198.0 9/12/2024 03:15 9/12/2024 03:45 0.50 COMPZN, RPCOMP CIRC P P/U T 2149'. Circ STS @ 7 BPM, 2980 PSI. Sand at shakers. 2,198.0 2,149.0 9/12/2024 03:45 9/12/2024 04:00 0.25 COMPZN, RPCOMP OWFF P OWFF. B/D TD. 2,149.0 2,149.0 9/12/2024 04:00 9/12/2024 05:00 1.00 COMPZN, RPCOMP TRIP P POOH F/ 2194' T/ 177'. PUW=70K. 2,149.0 177.0 9/12/2024 05:00 9/12/2024 07:00 2.00 COMPZN, RPCOMP BHAH P Lay down intensifier, Rack back stand of DC, Break off and clean out wash over mill and RFJB. Enough material to re run RCJB. 177.0 117.0 9/12/2024 07:00 9/12/2024 08:00 1.00 COMPZN, RPCOMP TRIP P Trip in hole, BHA #11 RCJB to 2122' 117.0 2,122.0 9/12/2024 08:00 9/12/2024 08:30 0.50 COMPZN, RPCOMP WASH P Kelly up. Break circulation 7 BPM @ 760 PSI, Shut down. Drop ball. Circ to tool, New pressures 7 BPM @ 3100 PSI, PUW=75K, SOW=62K. wash down to 2205 2,122.0 2,205.0 9/12/2024 08:30 9/12/2024 09:00 0.50 COMPZN, RPCOMP CIRC P PUH to 2181 CBU 7 BPM @ 3100 PSI 2,205.0 2,181.0 9/12/2024 09:00 9/12/2024 09:30 0.50 COMPZN, RPCOMP OWFF P Shut down pump, OWFF, Blow down top drive 2,181.0 2,181.0 9/12/2024 09:30 9/12/2024 10:30 1.00 COMPZN, RPCOMP TRIP P Trip out of well T 177' 2,181.0 177.0 9/12/2024 10:30 9/12/2024 11:00 0.50 COMPZN, RPCOMP BHAH P At surface, Lay down intensifier, DC's. Break down RCJB. Minimal material inside. 177.0 0.0 9/12/2024 11:00 9/12/2024 12:00 1.00 COMPZN, RPCOMP PRTS P Pressure test 7" casing down to RBP @ 2218. 3000 PSI 30 Min. - Good test 0.0 0.0 9/12/2024 12:00 9/12/2024 12:30 0.50 COMPZN, RPCOMP BOPE P Perform Bi Weekly BOPE function test. Tagged out 7" rams out of service 0.0 0.0 9/12/2024 12:30 9/12/2024 13:00 0.50 COMPZN, RPCOMP CLEN P Clean & clear RF. B/D surface lines. 0.0 9/12/2024 13:00 9/12/2024 13:30 0.50 COMPZN, RPCOMP BHAH P M/U BHA #12 retrieval tool for BOT RBP 0.0 12.7 Rig: NORDIC 3 RIG RELEASE DATE 9/15/2024 Page 8/10 1L-10 Report Printed: 10/10/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/12/2024 13:30 9/12/2024 15:00 1.50 COMPZN, RPCOMP TRIP P Trip in hole T //2142', PUW=65K, SOW=57K. 12.7 2,212.0 9/12/2024 15:00 9/12/2024 15:30 0.50 COMPZN, RPCOMP DISP P KU. Wash down to 2212'@ 7 BPM @ 416 PSI. Send 25 BBl 60 LSRV pill followed by 20 BBls Vis up seawater. Displace well to 10.9 PPG brine. 2,212.0 2,215.0 9/12/2024 15:30 9/12/2024 16:00 0.50 COMPZN, RPCOMP MPSP P Slow rate to 1BPM. RIH to 2215, Engage RBP, equalize & release RBP. Pull 15K break over drag @ 5K over. RIH to 2220 2,215.0 2,120.0 9/12/2024 16:00 9/12/2024 17:00 1.00 COMPZN, RPCOMP OWFF P OWFF, Refill trip tank with 10.9PPG. Pull stand, KB, Blow down top drive 2,220.0 2,142.0 9/12/2024 17:00 9/12/2024 18:00 1.00 COMPZN, RPCOMP TRIP P POOH F/ 2142' T/ 6'. 2,215.0 6.0 9/12/2024 18:00 9/12/2024 18:30 0.50 COMPZN, RPCOMP BHAH P L/D RBP & retrieval tool. 6.0 0.0 9/12/2024 18:30 9/12/2024 19:00 0.50 COMPZN, RPCOMP CLEN P Clean & clear RF. 0.0 0.0 9/12/2024 19:00 9/12/2024 20:15 1.25 COMPZN, RPCOMP BHAH P M/U BHA #13 sizing shoe & 6 1/8" string mills T/ 184', SOW=40K. 0.0 184.0 9/12/2024 20:15 9/13/2024 00:00 3.75 COMPZN, RPCOMP TRIP P RIH F/ 184' T/ 8284', PUW165K, SOW=85K 184.0 8,284.0 9/13/2024 00:00 9/13/2024 01:15 1.25 COMPZN, RPCOMP REAM P Obtain parameters. Pump @ 5 BPM, 1720 PSI. Rot @ 40 RPM, 8K Free Tq. Wash & ream F/ 8284' T/ 8470'. ROT=110K. 8-8.5K Tq. 8,284.0 8,470.0 9/13/2024 01:15 9/13/2024 01:45 0.50 COMPZN, RPCOMP MILL P Obtain parameters. Pump @ 5 BPM, 1720 PSI. Rot @ 20 RPM. 7K Free Tq. Wash & ream F/ 8470' over tubing stub @ 8485', PSI increase T/ 1820. Swallow stub T/ 8495' shoe depth, PSI increase T/ 2135. P/U T/ 8480' repeate without ROT. Same pressure signiture. Top of stub @ 8485'. 8,470.0 8,485.0 9/13/2024 01:45 9/13/2024 03:30 1.75 COMPZN, RPCOMP DISP P P/U T/ 8470'. L/D single. Circ 30 Blls hi -vis pill. Displace well w/ seawater @ 5 BPM, 1800 PSI. 8,485.0 8,470.0 9/13/2024 03:30 9/13/2024 03:45 0.25 COMPZN, RPCOMP OWFF P OWFF. 8,470.0 8,470.0 9/13/2024 03:45 9/13/2024 04:00 0.25 COMPZN, RPCOMP RURD P R/U testing equipment. 8,470.0 8,470.0 9/13/2024 04:00 9/13/2024 04:30 0.50 COMPZN, RPCOMP PRTS P Close UPR. PT 7" CSG to lower RBP T/ 2500 PSI for 15 MIn. 8,470.0 8,470.0 9/13/2024 04:30 9/13/2024 05:00 0.50 COMPZN, RPCOMP RURD P R/D testing equipment. B/D TD. 8,470.0 8,470.0 9/13/2024 05:00 9/13/2024 08:30 3.50 COMPZN, RPCOMP TRIP P Trip out of well, PUW=190K. Dragging off bottom. Rack back 70 stands in derrick 8,470.0 2,314.0 9/13/2024 08:30 9/13/2024 11:15 2.75 COMPZN, RPCOMP PULD P Lay down singles to BHA #13 2,314.0 184.0 9/13/2024 11:15 9/13/2024 13:00 1.75 COMPZN, RPCOMP BHAH P Lay down BHA # 13, Break down 184.0 0.0 9/13/2024 13:00 9/13/2024 17:00 4.00 COMPZN, RPCOMP RURD P Load out balence of fishing tools. Load GBR tongs, R/U Torque turn, Work overshot discrepancy. Pull wear bushing. 0.0 0.0 9/13/2024 17:00 9/13/2024 17:15 0.25 COMPZN, RPCOMP SFTY P PJSM W/ GBR & SLB completions to run completion 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 9/15/2024 Page 9/10 1L-10 Report Printed: 10/10/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/13/2024 17:15 9/14/2024 00:00 6.75 COMPZN, RPCOMP PUTB P Run 3 1/2", 9.3#, L-80 HYD 563 completion T/ 4970', PUW=75K, SOW=55K. Hyd 563 torque turned T/ 2900 Ft/lbs. Best'O'Life 2000 arctic grade dope used. 0.0 4,970.0 9/14/2024 00:00 9/14/2024 05:00 5.00 COMPZN, RPCOMP PUTB P Cont run 3 1/2" completion F/ 4970', T/ 8475' PUW=106K, SOW=67K. Kelly up wash down over TBG stub @ 3 BPM, 250 PSI. Saw PSI increase T/ 280 @ 8488'. Reduce pump rate. Continue in shear pins popped @ 8493'. Continue in PSI increase F/ 200 T/ 450, Fully locate @ 8499' Nordic 3 RKB. . 4,970.0 8,499.0 9/14/2024 05:00 9/14/2024 05:30 0.50 COMPZN, RPCOMP HOSO P L/D #274, #273 & 272. M/U space out pups 9.75', 9.73', 1.99'. M/U joint 272, T/ 8459'. 8,499.0 8,480.0 9/14/2024 05:30 9/14/2024 07:00 1.50 COMPZN, RPCOMP CRIH P Close UPR. Reverse circ 250 Bbls CI seawater @ 3 BPM. 306 PSI. Followed by 10 Bbls neat seawater. FCP=389 PSI 8,480.0 8,480.0 9/14/2024 07:00 9/14/2024 08:00 1.00 COMPZN, RPCOMP THGR P Shut down pump. Break off top drive. P/U Hanger and landing joint, Land hanger w/ bottom of PBOS @ 8493.43 ORKB. Run in LDS's, Lay down landing joint 8,480.0 8,493.0 9/14/2024 08:00 9/14/2024 08:15 0.25 COMPZN, RPCOMP OTHR P DROP BALL AND ROD WITH ROLLER STEM 8,493.0 8,493.0 9/14/2024 08:15 9/14/2024 09:15 1.00 COMPZN, RPCOMP RURD P Rig up manifolds to set packer. PT tubing, Casing 8,493.0 8,493.0 9/14/2024 09:15 9/14/2024 09:30 0.25 COMPZN, RPCOMP SEQP P PT surface lines and manifolds 3700 PSI - Good test 8,493.0 8,493.0 9/14/2024 09:30 9/14/2024 09:45 0.25 COMPZN, RPCOMP PACK P Line up down tubing. Pressure up tubing in 500 PSI increments per SLB rep T/ 3700 PSI. 8,493.0 8,493.0 9/14/2024 09:45 9/14/2024 10:15 0.50 COMPZN, RPCOMP PRTS P Start 3 1/2" pressure test, 3700 PSI / 30 min - Good test 8,493.0 8,493.0 9/14/2024 10:15 9/14/2024 11:00 0.75 COMPZN, RPCOMP PRTS P Bleed tubing down to 2000 PSI, Pressure up IA 2500 PSI 5 min. Start 3000 PSI / 30 Min test 8,493.0 8,493.0 9/14/2024 11:00 9/14/2024 11:15 0.25 COMPZN, RPCOMP PRTS P Line up to bleed down tubing, Bleed down tubing. Observe SOV shear as IA bled to zero with tubing 8,493.0 8,493.0 9/14/2024 11:15 9/14/2024 11:30 0.25 COMPZN, RPCOMP CIRC P Line up, pump down IA taking returns up tubing. 2 BPM @ 230 PSI 8,493.0 8,493.0 9/14/2024 11:30 9/14/2024 12:00 0.50 COMPZN, RPCOMP RURD P R/D test equipment. Pull landing joint 8,493.0 8,493.0 9/14/2024 12:00 9/14/2024 12:15 0.25 COMPZN, RPCOMP MPSP P Set BPV, 8,493.0 8,493.0 9/14/2024 12:15 9/14/2024 12:30 0.25 COMPZN, RPCOMP PRTS P PT BPV from below T/ 1000 PSI for 10 Min 8,493.0 8,493.0 9/14/2024 12:30 9/14/2024 13:15 0.75 COMPZN, WHDBOP RURD P R/U to blow rig down 0.0 0.0 9/14/2024 13:15 9/14/2024 15:15 2.00 COMPZN, WHDBOP NUND P Nipple down BOPE 0.0 0.0 9/14/2024 15:15 9/14/2024 16:15 1.00 COMPZN, WHDBOP NUND P Install tree test dart, Nipple up adaptor & tree. 0.0 0.0 9/14/2024 16:15 9/14/2024 16:45 0.50 COMPZN, WHDBOP PRTS P Test hanger void T/ 5000 PSI for 15 Min. 0.0 0.0 9/14/2024 16:45 9/14/2024 17:45 1.00 COMPZN, WHDBOP RURD P PJSM Rig up LRS, R/U U tube 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 9/15/2024 Page 10/10 1L-10 Report Printed: 10/10/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/14/2024 17:45 9/14/2024 18:15 0.50 COMPZN, WHDBOP PRTS P PT tree T/ 5000 PSI for 10 Min. 0.0 0.0 9/14/2024 18:15 9/14/2024 19:00 0.75 COMPZN, WHDBOP MPSP P Pull test dart & BPV. 0.0 0.0 9/14/2024 19:00 9/14/2024 21:00 2.00 COMPZN, WHDBOP FRZP P LRS pump 85 Bbls diesel freeze protect down IA, ICP=700 FCP=950.. Release LRS. U-tube well for 1 Hr. 0.0 0.0 9/14/2024 21:00 9/14/2024 22:00 1.00 COMPZN, WHDBOP RURD P B/D circ lines. Secure tree & cellar. Obtain final pressures. T/I/O = 75/150/0 0.0 0.0 9/14/2024 22:00 9/15/2024 00:00 2.00 DEMOB, MOVE DMOB P Suck out cellar box. Move auxiliary equipment away from rig. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 9/15/2024 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,903.0 1L-10 8/17/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Replace SOV w/ DV. Pull B&R, RHC, catcher & RBP. 1L-10 10/1/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL OA x FORMATION, WATER INJECTION ONLY 1/29/2014 hipshkf NOTE: View Schematic w/ Alaska Schematic9.0 9/30/2010 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 36.0 115.0 115.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 35.8 5,136.5 3,680.7 36.00 J-55 BTC Tie-Back String 7 6.28 32.3 2,153.0 1,907.9 26.00 L-80 HYD 563 Production 7 6.28 2,150.0 9,223.7 6,370.3 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 30.4 Set Depth 8,493.4 String Max No 3 1/2 Set Depth 5,804.1 Tubing Description Tubing Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection HYD 563 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) 30.4 30.4 0.05 Hanger 7.010 Cameron 7 1/16" x 3 1/2" CXS Tubing Hanger. EUE top thread. Camero n CXS 2.950 8,291.2 5,667.9 47.71 Mandrel GAS LIFT 5.942 3 1/2" x 1 1/2" MMG, GLM SLB MMG 2.920 8,349.7 5,707.2 47.95 Packer 6.280 3 1/2" x 7" Bluepack Max RH Packer, VamTop, SLB Bluepac k Mas RH 2.894 8,434.2 5,763.7 47.52 Nipple - X 4.502 3 1/2" x 2.813" X Nipple SLB X Nipple 2.813 8,481.6 5,796.0 46.62 Overshot 6.100 7 x 3 1/2" PBOS (11.43' swallow) 4 1/2", 12.6#, L-80, w/ 3 1/2"EUE Box (Shear pins @ 5.9') Inno Poorboy Oversho t 3.630 Top (ftKB) 8,485.0 Set Depth 8,882.3 String Max No 4 1/2 Set Depth 6,091.7 Tubing Description Tubing Completion Lower Wt (lb/ft) Grade Top Connection EUE 8rnd 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) 8,501.9 5,810.0 46.21 SEAL ASSY 5.000 BAKER SEAL ASSY - Space out BAKER 2.990 8,508.3 5,814.4 46.00 PBR 3.980 BAKER PBR 80-40 BAKER 80-4O 2.990 8,531.7 5,830.8 45.25 PACKER 5.970 BAKER FHL PACKER ASSEMBLY BAKER FHL 2.970 8,614.6 5,890.5 42.83 GAS LIFT 5.968 CAMCO 3 1/2" X 1 1/2" MMG GLM w/ DV CAMCO MMG 2.920 8,698.7 5,952.8 41.54 Blast Joint 4.500 BLAST JOINT 3 1/2" EUE 8rd 2.992 8,861.0 6,075.3 39.86 SLEEVE 4.550 BAKER CMU SLIDING SLEEVE - OPENED 1/4/14 BAKER CMU 2.812 8,875.3 6,086.2 39.57 LOCATOR 3.980 BAKER NO-GO LOCATOR BAKER 80-40 2.990 8,876.1 6,086.9 39.55 SEAL ASSY 4.000 BAKER SEAL ASSY BAKER 2.980 Top (ftKB) 8,879.0 Set Depth 8,902.6 String Max No 3 1/2 Set Depth 6,107.4 Tubing Description TUBING WO - 2001 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,879.0 6,089.1 39.49 PACKER 5.872 BAKER FB-1 PACKER 4.000 8,882.3 6,091.7 39.42 MILL 5.000 BAKER MILL OUT EXTENSION 4.000 8,894.4 6,101.0 39.17 NIPPLE 4.250 OTIS XN NIPPLE 2.813" w/ 2.75" NO GO 2.750 8,901.7 6,106.7 39.00 WLEG 4.500 BAKER 3.5" WIRELINE ENTRY GUIDE 3.000 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) 32.3 32.3 0.05 EMERGENCY SLIPS McEvoy Type SB-3 Pack-Off Assy for slips McEvoy SB-3 9/9/2024 7.000 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) 8,291.2 5,667.9 47.71 1 GAS LIFT DMY RK 1 1/2 0.0 9/29/2024 SLB MMG 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 2,137.6 1,899.2 55.16 Collar - Stage 8.255 CMTR,TYPE H ES-II, HYD 563 L- 80 (S/N#: B5031046-01) Halliburto n HES II CMTR 6.125 2,149.1 1,905.7 55.36 Patch 8.375 7" Sealing Overshot Casing Patch, (2.97' swallow, SN# Z7011- 001) Bowen 1002902 7.125 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,713.0 8,790.0 5,963.5 6,021.4 C-4, UNIT B, 1L- 10 8/19/1990 6.0 APERF 2 1/8" Dyna Strip; Zero deg. phasing 1L-10, 10/10/2024 10:38:45 AM Vertical schematic (actual) Production; 2,150.0-9,223.7 IPERF; 9,016.0-9,024.0 IPERF; 8,938.0-8,956.0 APERF; 8,934.0-8,939.0 APERF; 8,929.0-8,934.0 APERF; 8,924.0-8,929.0 PACKER; 8,879.0 SLEEVE; 8,861.0 APERF; 8,811.0-8,819.0 APERF; 8,800.0-8,806.0 APERF; 8,713.0-8,790.0 GAS LIFT; 8,614.6 PACKER; 8,531.7 Nipple - X; 8,434.2 Packer; 8,349.7 Mandrel GAS LIFT; 8,291.2 SURFACE; 35.8-5,136.5 Tie-Back String; 32.2-2,153.0 Intermediate String 1 Cement; 33.3 ftKB CONDUCTOR; 36.0-115.0 EMERGENCY SLIPS; 32.3 Hanger; 30.4 KUP INJ KB-Grd (ft) 40.01 RR Date 3/25/1990 Other Elev 1L-10 ... TD Act Btm (ftKB) 9,241.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292202600 Wellbore Status INJ Max Angle & MD Incl (°) 57.36 MD (ftKB) 2,400.00 WELLNAME WELLBORE1L-10 Annotation Last WO: End Date 9/14/2024 H2S (ppm) DateComment SSSV: NIPPLE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,800.0 8,806.0 6,028.9 6,033.4 UNIT B, 1L-10 8/19/1990 6.0 APERF 2 1/8" Dyna Strip; Zero deg. phasing 8,811.0 8,819.0 6,037.2 6,043.2 UNIT B, 1L-10 8/19/1990 6.0 APERF 2 1/8" Dyna Strip; Zero deg. phasing 8,924.0 8,929.0 6,124.1 6,128.0 A-5, 1L-10 9/17/2010 4.0 APERF 2 1/8" Millenium Deepstar Strip guns, +/- 45° phase 8,929.0 8,934.0 6,128.0 6,132.0 A-5, 1L-10 9/16/2010 4.0 APERF 2 1/8" Millenium Deepstar Strip guns, +/- 45° phase 8,934.0 8,939.0 6,132.0 6,135.9 A-5, 1L-10 9/11/2010 4.0 APERF 2 1/8" Millenium Deepstar Strip guns, +/- 45° phase 8,938.0 8,956.0 6,135.1 6,149.3 A-5, A-4, 1L-10 7/6/1990 4.0 IPERF 4 1/2" Csg Gun; Oriented 70 deg. CCW 9,016.0 9,024.0 6,197.4 6,203.9 A-4, 1L-10 7/6/1990 40.0 IPERF 4 1/2" Csg Gun; Oriented 50 deg. CCW Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 33.3 2,153.0 33.3 1,907.9 Intermediate String 1 Cement Pump cement 10 bbls lead with dye 120 bbls 11# 30 bbls 15.3# 10 bbls 8.3 tail flush 70 bbls bump plug Batched up 20.44 Dropped plug @ 20:44 Bumped plug @ 21.27 9/9/2024 1L-10, 10/10/2024 10:38:46 AM Vertical schematic (actual) Production; 2,150.0-9,223.7 IPERF; 9,016.0-9,024.0 IPERF; 8,938.0-8,956.0 APERF; 8,934.0-8,939.0 APERF; 8,929.0-8,934.0 APERF; 8,924.0-8,929.0 PACKER; 8,879.0 SLEEVE; 8,861.0 APERF; 8,811.0-8,819.0 APERF; 8,800.0-8,806.0 APERF; 8,713.0-8,790.0 GAS LIFT; 8,614.6 PACKER; 8,531.7 Nipple - X; 8,434.2 Packer; 8,349.7 Mandrel GAS LIFT; 8,291.2 SURFACE; 35.8-5,136.5 Tie-Back String; 32.2-2,153.0 Intermediate String 1 Cement; 33.3 ftKB CONDUCTOR; 36.0-115.0 EMERGENCY SLIPS; 32.3 Hanger; 30.4 KUP INJ 1L-10 ... WELLNAME WELLBORE1L-10 ORIGINATED TRANSMITTAL DATE: 9/10/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5041 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk River PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5041 1L-10 50029220260000 Cement Bond Log 6-Sep-2024 RECIPIENTS ConocoPhillips Alaska, Inc. DIGITAL FILES PRINTS CD'S 1 0 0 0 USPS 0 0 0 0 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 190-035 T39537 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.10 11:28:39 -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 ORIGINATED TRANSMITTAL DATE: 8/26/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5016 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 5016 1L-10 50029220260000 Hoist (no Logs) 22-Aug-2024 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 tom.osterkamp@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 190-035 T39486 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.26 10:34:56 -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 tom.osterkamp@conocophillips.com ORIGINATED TRANSMITTAL DATE: 8/20/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5009 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 5009 1L-10 50029220260000 Plug Setting Record 19-Aug-2024 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 tom.osterkamp@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 190-035 T39464 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.20 15:07:17 -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 tom.osterkamp@conocophillips.com 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number): 10. Field: Kuparuk Oil Pool Kuparuk Oil Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9241' 6385' 8371' 6700'2717 None None Casing Collapse Conductor Surface Production Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: 907-263-4529 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 KRU 1L-10 8713-8790' 8800-8806' 8811-8819' 8924'-8956' 9016-9024' 9191' 5964'-6021' 6029-6033' 6037'-6043' 6124'-6149' 6197'-6204' 9/8/2024 3-1/2" 3-1/2" Baker FHL Baker FB-1 SSSV: None 5101' 9224' Perforation Depth MD (ft): 115' 5137' 6370'7" 16" 9.625" 79' Burst 8884' 8903' MD 115' 3681' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025659, ADL0025660 190-035 P.O. Box 100360, Anchorage, AK 99510 50-029-22026-00-00 ConocoPhillips Alaska, Inc Proposed Pools: AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 8534'MD/5832'TVD 8879'MD/6089'TVD Perforation Depth TVD (ft): Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size Kuparuk River Field Adam Klem adam.klem@conocophillips.com CTD/RWO Engineer Subsequent Form Required: Suspension Expiration Date: L-80 L-80 TVD Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 11:27 am, Aug 15, 2024 Digitally signed by Adam Klem DN: CN=Adam Klem, E=adam.klem@ conocophillips.com, C=US Reason: Location: Date: 2024.08.13 12:57:13-08'00' Foxit PDF Editor Version: 13.0.0 Adam Klem A.Dewhurst 22AUG24 DSR-8/21/24 10-404 Victoria Loepp X BOP test pressure to 3000 psig Annular preventer test to 2500 psig VTL 8/23/2024 XX SFD for GCW 8/23/2024 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.08.23 10:42:12 -08'00'08/23/24 RBDMS JSB 082324 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 12, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Adam Klem Staff RWO/CTD Engineer ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Producer 1L-10 (PTD# 190-035). 1L-10 is an injector drilled in 1990 completed with 3.5" tubing and 7" casing. A surface casing leak was identified at 402'MD. The well has been waivered for WI only, however the ability to restore WAG injection is desired. Therefore, a RWO is needed to pull the tubing and isolate the leak. The plan is to pre rig cut the tubing and pull the tubing on rig. The the 7" will be cut below the known leak and a subsidence style repair of running new 7" with a sealing overshot onto the 7" stub and cementing the 7" to surface will be performed. Then a non sealing overshot will be run with a stacked packer on the new 3.5" tubing. If you have any questions or require any further information, please contact me at 907-263-4529 Digitally signed by Adam Klem DN: CN=Adam Klem, E= adam.klem@conocophillips.com, C=US Reason: Location: Date: 2024.08.13 12:57:26-08'00' Foxit PDF Editor Version: 13.0.0 Adam Klem 1L-10 RWO Procedure Kuparuk Producer PTD #190-035 Page 1 of 2 Remaining Pre-Rig Work 1. Get updated SBHP 2. Dummy off all GLMs 3. Set WL set RBP below upper packer at ~8650’ MD. Pressure test tubing and IA. 4. Pull DV from GLM at 8447’ MD 5. Cut the tubing in the first full joint above the packer, ~8550’ MD 6. Install BPV within 48 hrs of rig arrival and prep well for rig. Rig Work MIRU 1. MIRU Nordic 3 on 1L-10. Pull BPV if need to circulate. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate ~10.9 KW brine. 3. Set BPV and confirm as barrier, ND Tree, NU BOPE and test to 250/3,000 psi. Test annular 250/3,000 psi. Retrieve 3.5” Tubing Section 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to pre-rig cut (~8550’ MD). Cut and Pull 7” 6. RU E-line. Run caliper and CBL from surface casing shoe at 5137’ MD to surface. (no arctic pack-just looking for debris or other indicators for casing cut) 7. Set RBP below planned cut. PT RBP. Dump sand on RBP. 8. Circulate out brine with SW for subsidence operations. Monitor well for flow. 9. RIH with multistring cutter on DP, cut 7” casing at location determined by CBL, POOH and stand back DP 10. Circulate the OA 11. ND BOPEs, ND tubing head using Hydratight, NU BOP to the casing head a. Can not retest the BOPE at this point. Retest flange break once casing is recovered 12. Spear the 7” casing. POOH and lay down the 7” casing 13. RIH w/ tandem string mills to gauge the 9-5/8” casing for the ES cementer & Sealing Overshot 14. RU casing crew and RIH w/ new 7” casing, ES Cementer, and Sealing Overshot, PT casing to 2500 psi 15. RU cementer and cement 7” x 9-5/8” annulus to surface 16. ND BOPE, pull 7” casing in tension and land in the slips. Cut excess 7” casing with Wachs cutter. 17. NU new tubing head and BOP stock. PT BOPs 18. RIH w/ 6-1/8” bit/mill to TOC, mill through cement. POOH standing back drillpipe. 19. Pressure test the casing to 2500 psi, chart for 30 minutes 20. RIH w/ wash string assembly and circulate out sand on top of RBP. POOH standing back drillpipe. 21. Pull RBP Install 3-½” Tubing Injection String 22. MU 3 ½” completion with poorboy overshot, packer, nipples, and GLMs. RIH to tubing stub 23. Once on depth, circulate CI brine, space out as needed, land hanger, RILDS, drop B&R, and set packer. 24. Pressure test tubing to 3,000 psig for 5 minutes. 25. Pressure test inner annulus to 2,500 psig for 30 minutes on chart. ND BOP, NU Tree 26. Confirm pressure tests, then shear out SOV with pressure differential. 27. Install BPV. 28. ND BOPE. NU tree. PT tree. 1L-10 RWO Procedure Kuparuk Producer PTD #190-035 Page 2 of 2 29. Pull BPV, freeze protect well, and set BPV if necessary. 30. RDMO. Post-Rig Work 31. Pull BPV 32. Install GLD General Well info: Wellhead type/pressure rating: McEvoy Gen 4 Production Engineer: Banabas (Barny) Dogah Reservoir Development Engineer: Cody Keith Estimated Start Date: 9/8/2024 Workover Engineer: Adam Klem (263-4529/ adam.klem@conocophillips.com) Current Operations: This well is currently injecting water only Well Type: Injector Scope of Work: Pull the existing 3-1/2” completion down to the pre-rig tubing cut. Install a new 7” casing to regain all OA needed for WAG injection. BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross/ Pipe Ram / Mud Cross MIT results: Tbg: MITT to 3000psi planned pre rig after plug is set IA: MITIA to 3300psi: passed 6/1/24 IC POT & PPPOT: passed 7/24/24 TBG PPOT: passed 7/25/24 TBG POT: failed 7/25/24 MPSP: 2,717 psi using 0.1 psi/ft gradient Static BHP: 3,327 psi / 6100’ TVD measured on 3/18/23 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Est. 14' above Top A-Sand Perf) 8,910.0 1L-10 3/7/2022 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled plug w/ gauges. 1L-10 3/18/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL OA x FORMATION, WATER INJECTION ONLY 1/29/2014 hipshkf NOTE: View Schematic w/ Alaska Schematic9.0 9/30/2010 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 36.0 115.0 115.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 35.8 5,136.5 3,680.7 36.00 J-55 BTC PRODUCTION 7 6.28 32.3 9,223.7 6,370.3 26.00 J-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 25.9 Set Depth … 8,884.2 Set Depth … 6,093.1 String Ma… 3 1/2 Tubing Description TUBING W0 - 2013 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rnd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 25.9 25.9 0.04 HANGER 8.000 McEVOY TUBING HANGER McEVO Y SB-3-NL 2.992 504.5 504.4 3.89 NIPPLE 4.550 CAMCO "DS" NIPPLE (2.875") CAMCO DS, 2.875" 2.875 2,301.0 1,990.3 56.39 GAS LIFT 5.968 CAMCO 3 1/2" X 1 1/2" MMG GLM CAMCO MMG 2.920 8,447.8 5,772.9 47.26 GAS LIFT 5.968 CAMCO 3 1/2" X 1 1/2" MMG GLM w/ DV CAMCO MMG 2.920 8,503.8 5,811.3 46.15 SEAL ASSY 5.000 BAKER SEAL ASSY - Space out BAKER 2.990 8,510.2 5,815.8 45.94 PBR 3.980 BAKER PBR 80-40 BAKER 80-4O 2.990 8,533.6 5,832.1 45.19 PACKER 5.970 BAKER FHL PACKER ASSEMBLY BAKER FHL 2.970 8,616.5 5,891.9 42.80 GAS LIFT 5.968 CAMCO 3 1/2" X 1 1/2" MMG GLM w/ DV CAMCO MMG 2.920 8,700.6 5,954.2 41.52 Blast Joint 4.500 BLAST JOINT 3 1/2" EUE 8rd 2.992 8,862.9 6,076.7 39.82 SLEEVE 4.550 BAKER CMU SLIDING SLEEVE - OPENED 1/4/14 BAKER CMU 2.812 8,877.2 6,087.7 39.53 LOCATOR 3.980 BAKER NO-GO LOCATOR BAKER 80-40 2.990 8,878.0 6,088.4 39.51 SEAL ASSY 4.000 BAKER SEAL ASSY BAKER 2.980 Top (ftKB) 8,879.0 Set Depth … 8,902.6 Set Depth … 6,107.4 String Ma… 3 1/2 Tubing Description TUBING WO - 2001 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,879.0 6,089.1 39.49 PACKER 5.872 BAKER FB-1 PACKER 4.000 8,882.3 6,091.7 39.42 MILL 5.000 BAKER MILL OUT EXTENSION 4.000 8,894.4 6,101.0 39.17 NIPPLE 4.250 OTIS XN NIPPLE 2.813" w/ 2.75" NO GO 2.750 8,901.7 6,106.7 39.00 WLEG 4.500 BAKER 3.5" WIRELINE ENTRY GUIDE 3.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,301.0 1,990.3 56.39 1 GAS LIFT DMY RK 1 1/2 0.0 1/4/2014 CAMCO MMG 0.000 8,447.8 5,772.9 47.26 2 GAS LIFT DMY RK 1 1/2 0.0 12/16/2013 CAMCO MMG 0.000 8,616.5 5,891.9 42.80 3 GAS LIFT DMY RK 1 1/2 0.0 12/16/2013 CAMCO MMG 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,713.0 8,790.0 5,963.5 6,021.4 C-4, UNIT B, 1L- 10 8/19/1990 6.0 APERF 2 1/8" Dyna Strip; Zero deg. phasing 8,800.0 8,806.0 6,028.9 6,033.4 UNIT B, 1L-10 8/19/1990 6.0 APERF 2 1/8" Dyna Strip; Zero deg. phasing 8,811.0 8,819.0 6,037.2 6,043.2 UNIT B, 1L-10 8/19/1990 6.0 APERF 2 1/8" Dyna Strip; Zero deg. phasing 8,924.0 8,929.0 6,124.1 6,128.0 A-5, 1L-10 9/17/2010 4.0 APERF 2 1/8" Millenium Deepstar Strip guns, +/- 45° phase 8,929.0 8,934.0 6,128.0 6,132.0 A-5, 1L-10 9/16/2010 4.0 APERF 2 1/8" Millenium Deepstar Strip guns, +/- 45° phase 8,934.0 8,939.0 6,132.0 6,135.9 A-5, 1L-10 9/11/2010 4.0 APERF 2 1/8" Millenium Deepstar Strip guns, +/- 45° phase 8,938.0 8,956.0 6,135.1 6,149.3 A-5, A-4, 1L-10 7/6/1990 4.0 IPERF 4 1/2" Csg Gun; Oriented 70 deg. CCW 9,016.0 9,024.0 6,197.4 6,203.9 A-4, 1L-10 7/6/1990 40.0 IPERF 4 1/2" Csg Gun; Oriented 50 deg. CCW 1L-10, 3/19/2023 8:36:29 AM Vertical schematic (actual) PRODUCTION; 32.3-9,223.7 FLOAT SHOE; 9,222.1-9,223.7 FLOAT COLLAR; 9,144.0- 9,146.0 IPERF; 9,016.0-9,024.0 IPERF; 8,938.0-8,956.0 APERF; 8,934.0-8,939.0 APERF; 8,929.0-8,934.0 APERF; 8,924.0-8,929.0 WLEG; 8,901.7 NIPPLE; 8,894.4 MILL; 8,882.3 SEAL ASSY; 8,878.0 PACKER; 8,879.0 LOCATOR; 8,877.2 SLEEVE; 8,862.9 APERF; 8,811.0-8,819.0 APERF; 8,800.0-8,806.0 APERF; 8,713.0-8,790.0 GAS LIFT; 8,616.5 PACKER; 8,533.6 PBR; 8,510.2 SEAL ASSY; 8,503.8 GAS LIFT; 8,447.7 SURFACE; 35.8-5,136.5 FLOAT SHOE; 5,134.8-5,136.5 FLOAT COLLAR; 5,057.6- 5,059.0 GAS LIFT; 2,300.9 NIPPLE; 504.5 CONDUCTOR; 36.0-115.0 HANGER; 35.8-40.3 HANGER; 25.9 KUP INJ KB-Grd (ft) 40.01 RR Date 3/25/1990 Other Elev… 1L-10 ... TD Act Btm (ftKB) 9,241.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292202600 Wellbore Status INJ Max Angle & MD Incl (°) 57.36 MD (ftKB) 2,400.00 WELLNAME WELLBORE1L-10 Annotation Last WO: End Date 12/6/2013 H2S (ppm) DateComment SSSV: NIPPLE 1L-10 Proposed RWO Completion PROPOSED COMPLETION 3-1/2", 9.3#, L-80 HYD563Tubing to surface 3-1/2" Camco MMG gas lift mandrels @ TBD 3-1/2" by 7" Packer w/ PBR and SBE 3-1/2" X landing nipple at xxxx' RKB (2.813" min ID) 3-1/2" PBO PROPOSED 7" Tieback 7" Hyd563 Casing cemented to surface HES Stage Cement Tool Sealing Overshot Patch REMAINING COMPLETION LEFT IN HOLE 3-1/2" x 7" Baker FHL Retrievable packer. (8534' RKB) 3.5" x 1.5" MMG Production Mandrel Baker CMU 3-1/2" x 7" Baker FB-1 Retrievable packer. (8879' RKB) 2.813" XN Nipple (2.75" No-GO) (8895' RKB) Surface Casing Production/Intermediate Casing Conductor A-Sand C-Sand MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, July 8, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1L-10 KUPARUK RIV UNIT 1L-10 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/08/2024 1L-10 50-029-22026-00-00 190-035-0 W SPT 5832 1900350 3000 1848 1849 1850 1850 230 230 235 235 REQVAR P Guy Cook 6/1/2024 MITIA to maximum anticipated injection pressure per AIO 2B.083. Testing completed with a Little Red Services pump truck and calibrated gauges. Water header pressure at 2750 psi. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1L-10 Inspection Date: Tubing OA Packer Depth 520 3300 3210 3200IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC240601184008 BBL Pumped:2.6 BBL Returned:2.8 Monday, July 8, 2024 Page 1 of 1 9 9 9 9 9 9 99 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.07.08 12:09:40 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 20, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1L-10 KUPARUK RIV UNIT 1L-10 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/20/2022 1L-10 50-029-22026-00-00 190-035-0 W SPT 5832 1900350 3000 1392 1394 1394 1391 153 157 157 157 REQVAR P Adam Earl 6/18/2022 MIT-IA tested as per AIO 2B.083 to max ant.inj.psi 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1L-10 Inspection Date: Tubing OA Packer Depth 320 3300 3210 3200IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220622101152 BBL Pumped:3 BBL Returned:3 Wednesday, July 20, 2022 Page 1 of 1 MEMORANDUM To: Jim Regg P.I. Supervisor I\ FROM: Austin McLeod Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 8, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 1410 KUPARUK RIV UNrl' 1410 Src: Inspector Reviewed By: P.I. Supry Comm Well Name KUPARUK RIV UNIT 1410 API Well Number 50-029-22026-OMO Inspector Name: Austin McLeod Permit Number: 190-035-0 Inspection Date: 6/42020 Insp Num: mitSAM200605092428 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 11,110 Type Inj I w `TVD 1 5832 Tubing 2139 2134. 2132 " 2112 PTD 1900350 Type Test SPT Test psi 3000 " IA 750 3320 - 3230 3220 ' BBL Pumped: 19 ' BBL Returned: 2.9 OA 130 135 135 135 ' Interval REQVAR P/F P Notes: 2 year to MAID as per AIO 28.083 v Monday, June 8, 2020 Page I of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,June 08,2016 TO: Jim ( P.I.Supervisor �(t "V 7!Ido SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1L-10 FROM: Matt Herrera KUPARUK RIV UNIT 1L-10 Petroleum Inspector Sre: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1L-10 API Well Number 50-029-22026-00-00 Inspector Name: Matt Herrera Permit Number: 190-035-0 Inspection Date: 6/1/2016 Insp Num: mitMFH160603150116 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1L-10 Type Inj W TVD 5832 Tubing 1318 . 1318 1324 - 1322 . PTD 1900350 - IType Test SPT Test psi 3300 IA 587 3350 3280 - 3270 Interval REQVAR P/F P / OA 125 128 - 128 128 • Notes: A1O 213.083 NE® DEC 2 9 2016 Wednesday,June 08,2016 Page 1 of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Friday,February 26,2016 Supervisor q 3 SUBJECT: Mechanical Integrity Tests P.I. CONOCOPHILLIPS ALASKA INC 1L-10 FROM: Jeff Jones KUPARUK RIV UNIT 1L-10 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv�A--- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1L-10 API Well Number 50-029-22026-00-00 Inspector Name: Jeff Jones Permit Number: 190-035-0 Inspection Date: 2/20/2016 Insp Num: mitJJ160221073618 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IL-10 Type Inj W'TVD 5832 - Tubing 1807 - 1807 - 1808 - 1806 _ PTD 1900350 - Type Test SPT Test psi 3000 . IA 482 3278 3230 - 3212 - Interval REQVAR P/F P 'r' OA 118 121 _ 121 - 121 - Notes: MIT-IA to maximum anticipated injection pressure per AIO 2B.083. % pno SEP 2 6 2016 Friday,February 26,2016 Page 1 of 1 F • T wP THE STATE \�I� s Alaska Oil and Gas 44'" �' °f tl° n lssl C s t GOVERNOR SEAN PARNELL 333 West Seventh Avenue ALAS'" Anchorage, Alaska 99501-3572 ALAS ��'®���� Main: 907.279.1433 Fax: 907.276.7542 Paul Chan Wells Engineer ConocoPhillips Alaska, Inc. Q _ P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Meltwater Oil Pool, 1L-10 Sundry Number: 313-581 Dear Mr. Chan: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, r . Cathy P!Foerster Chair, Commissioner DATED this )6 d y of November, 2013. Encl. STATE OF ALASKA Ap I ` `�' �� ALI.OIL AND GAS CONSERVATION COMM ION ��� NOV 2013 • APPLICATION FOR SUNDRY APPROVALS �\4 20 AAC 25.280 iCC 1.Type of Request: Abandon r Plug for Redrill f. Perforate New Pool fl Repair well 17, Change pprove Program r Suspend r Plug Perforations l Perforate r Rill Tubing Time Extension E Operational Shutdown r° Re-enter Susp.Well r Stimulate r Alter casing fl Other: ; 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory Development 190-035 • 3.Address: 6.API Number: Stratigraphic r Service �;. P.O. Box 100360,Anchorage,Alaska 99510 50-029-22026-00• 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No 1 1 L-10 • . 9.Property Designation(Lease Number): PO 10.Field/Pool(s): ADL 25660• / S4S� Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9241 • 6385 • 9144' • 6303'- 8867' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115' 115' SURFACE 5101 9.625 5137' 3681' PRODUCTION 9191 7 9224' 6370' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8713-8790,8800-8806,8811-8819,8924-8956,9016-9024 5964-6021,6029-6035,6039-6045,6124-6150,6198-6204 3.5 L-80 8903 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER FHL PACKER MD=8582 TVD=5866 • PACKER-BAKER FB-1 PACKER MD=8879 TVD=6089 - NIPPLE-CAMCO DS NIPPLE MD=494 TVD=494 • 12.Attachments: Description Summary of Proposal 17 13. Well Class after proposed work: Detailed Operations Program r.. BOP Sketch r Exploratory l Stratigraphic fl Development r Service 17' 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 11/27/2013 Oil r Gas r WDSPL r Suspended 16.Verbal Approval: Date: WINJ I- GINJ r WAG Abandoned r Commission Representative: GSTOR r SPLUG 17. I hereby certify that the foregoing is true and correct t e best of my knowledge. Contact: Paul Chan @ 263-4759 Email: Paul.Chanacontractor.cop.com Printed Name Paul Chan Title: Wells Engineer Signature Phone:263-4759 Date `l1 13 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3V2 —'S SI' s Plug Integrity r BOP Test Mechanical Integrity Test f Location Clearance r /� / 7 d ,e Other: /d'v P tr,S ! d-!J cc p S L J L,/<d1°'1�d"` fL JAI// J •"'t SS�d Spacing Exception Required? Yes ❑ No V( Subsequent Form Required: it C— `-T U g-' APPROVED BY Approved by: 01,,,,, / 2241 /^— COMMISSIONER THE COMMISSION Date: if / ; '�/ Approved ap ['cation is valid tor 12 months trom the date of approval. Form 10-403(Revised 10/2012) RIGINAL slI�I i3 Submit Form and Attachments in Duplicate A� /f / % «/7(‘, RBDMS NOV 21 • • RECEIVED ConocoPhillips NOV 0 7 2013 Alaska P.O. BOX 100360 AoGCC ANCHORAGE,ALASKA 99510-0360 November 5,2013 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 workover Kuparuk Injection Well 1L-10(PTD# 190-035). 1L-10 was drilled in March 1990 and completed with a simple completion in July 1990. In March 2001 the simple completion was replaced with a single selective completion. The well is currently shut-in due to a leak in the tubing at 8519' MD and secured with a plug in the sliding sleeve at 8867'MD. The scope of work is to pull&replace the 3-Y2"tubing string with a new 3-'/2"9.3#L-80 tubing string. If you have any questions or require any further information,please contact me at 263-4759. Sincerely, Paul Chan Workover Engineer CPAI Drilling and Wells • • 1 L-10 Rig Workover Pull and Run Tubing (PTD #: 190-035) Current Status: This well has been SI since 3/14/13 due to a tubing leak at 8519' MD. Scope of Work: Pull 3 '/2"tubing and run new 3-'/2"tubing string. General Well info: Well Type: Injector MPSP: 1,850 psi using max SITP on 3/14/13 Reservoir Pressure/TVD: 2,688 psi/6,162' TVD(8.2 ppg)from Panex gauges on 5/08/13. Wellhead type/pressure rating: McEvoy Gen 4,7-'/16" 5M psi top flange BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: CMIT passed on 8/2/13,MIT-OA failed on 7/22/13. Earliest Estimated Start Date: November 27,2013 Production Engineer: David Lagerlef/Dana Glessner Workover Engineer: Paul Chan(263-4759/pchan4 @conocophillips.com) Pre-Rig Work 1. Pull dummy valve from GLM and leave pocket open for circulation point. 2. Set BPV w/i 24 hrs of rig arrival. Proposed Procedure 1. MIRU. 2. Pull BPV. Circulate 9.6 ppg KWF. Verify well is dead. 3. Set BPV and ND tree. NU BOPE&test BOP's to 250/3000 psi. 4. Pull BPV. MU landing joint,BOLDS,and pull tubing hanger to rig floor. a. If the seals cannot be pulled from the Baker FHL packer at 8582'MD,the tubing will be cut with e-line and an attempt will be made to fish the seals. If the seals cannot be fished,the well will then be completed with a stacker packer completion with the new packer 8514'MD or deeper. 5. POOH and laydown 3 'h"tubing. 6. RIH w/3 '/2"tubing completion and sting into PBR,space out,mark the pipe and pull out of PBR. 7. Space out w/pups,MU hanger. Circulate well full of corrosion inhibited brine. Land the hanger,RILDS. 8. PT the IA,ramp up pressure to shear the SOV. P r tv b► 9. Install BPV,ND BOPE,NU tree. Pull BPV,install tree test plug&test tree. Pull tree test plug. 10. Freeze protect through the SOV,set BPV. 11. RDMO. Post-Rig Work 1. Reset well house(s)and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline: Pull SOV from GLM and replace w/DV. Pull catcher sub and CSA-2 plug in CMU sliding sleeve. 4. Turn well over to operations. • • Conoco Phillips Well: KRU 1L-10 Current Completion �l os Id • DS 2.875"Profile @ 494'MD 16"62.5#H-40 to 115'MD • 3-'/2"9.3#/ft L-80 EUE 8rd-mod tubing 9-5/8"36#J-55 to 5,137' MD • 3-1/2"MMG GLM @ 8520'MD 4 Baker PBR @ 8568'MD ! - • Baker FHL packer @ 8582'MD • MP • 3-1/2"MMG GLM @ 8629'MD s_( • Baker CMU Sliding Sleeve @ 8867'IV, Baker FB-1 packer @ 8879'MD ' )lx" Ca Otis 31"XN @8894'MD • 3-'/2"WLEG @ 8902'MD 7"26#J-55 shoe at 9,224' MD e , • ConocoPhillips Well: KRU 1L-10 Proposed Completion bI os is • 3-1/2"DS 2.875"Profile @-500'MD 16"62.5#H-40to115'MD • 3-1/2"9.3#/ft L-80 EUE 8rd-mod tubing 9-5/8"36#J-55 to 5,137' MD — _ 4 3-1/2"MMG GLM @-8500'MD • Baker PBR @ 8568'MD • Baker FHL packer @ 8582'MD EEO • 3-1/2"MMG GLM @ 8629'MD IFF1 Baker CMU Sliding Sleeve @ 8867'MD f Baker FB-1 packer @ 8879'MD ) xN t 4 Otis 31/='XN @8894'MD • 3-1/2"WLEG @ 8902'MD 7"26#J-55 shoe at 9,224'MD • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. December 8, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 1L -10 Run Date: 11/27/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Wireline & Perforating, 6900 Arctic Blvd., Anchorage, Klinton Wood, Halliburton Wi g , AK 99518 g 1L -10 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50- 029 - 22026 -00 Injection Profile Log 1 Color Log 50- 029 - 22026 -00 StAKINFX FEB 0 1 ZU1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. ' b _ 5 Anchorage, Alaska 99518 _ Office: 907 - 273 -3527 0 *l Fax: 907- 273 -3535 klinton.wo • . latig . 1 Date: Signed: (). 4 : i:: c. WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 1L-10 Run Date: 7/25/2009 October 13, 2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1 L-10 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-22026-00 Injection Profile Log 1 Color Log 50-029-22026-OC~t ~~~ ~~~° ~ ~ 2nag PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto@halliburton.com Date: ~~~ !~d -035 ~ ~ ~ ~ r Signed: • MEM®RANDLTM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday, June 11, 2008 Jim Regg P.I. Supervisor ` ~j°~i bl (7((i~ SUBJECT: Mechanical Integrity Tests ~ G CONOCOPHILLIPS ALASKA INC 1L-10 FROM: Jeff Jones KUPARUK RIV UNIT 1L-10 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~,~2- Comm Well Name: KUPARUK RN UNIT 1L-10 API Well Number 50-029-22026-00-00 Inspector Name• Jeff Jones Insp Num: mitJJ08061 0 1 1 2936 Permit Number: 190-035-0 Inspection Date: 6~1~2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 1L-lo Well (T a In'. ~ G TVD 5866 IA 1 t60 2860 I 2840 I 2830 -- - - -- p ' ~ 1900350 SPT ' Test SI P.T. TypeTest , lsoo ~ ~ OA 120 ' zso ~----_ -__ .- _ _ _ - --~_ zso zso Interval 4YRTST p~F P / Tubing zzoo ' 2200 ~ 2zos zzos Notes• 2.4 BBLS diesel pumped; no exceptions noted. . ~~~b~`3 JUL Jti ~` p Z008 Wednesday, June I I, 2008 Page 1 of 1 09/15/06 Scblumbel'gel' RECEIVEC) NO. 3959 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth SEP 1 5 2006 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~ Oil & Gas Coos. Ccmœ~Jçn ,4.nd1crage / ðo "3 (:;- . .... Cr:'Q - I _0 .' :\~ì:t.D ,}\..... ~C~~~'e (" "\"S~ ,¡I:, (, ¿LV1.~. 1. "I Field: u:rC- Kuparuk Well Log Description Date CD BL Color Job # 2A-18 11213804 LDL 09/09/06 1 1A-20 11213802 PROD PROFILE WIDEFT 09/07/06 1 3A-17 11213803 PROD PROFILE W/DEFT 09/08/06 1 1 J-156 11415621 PRODUCTION PROFILE 09/06/06 1 2A-13 11415619 PRODUCTION PROFILE 09/04/06 1 1L·28 11213805 PROD PROFILE W/DEFT 09/10/06 1 1 L-1 0 1142164 INJECTION PROFILE 09/09/06 1 1 J-1 02 11421625 USIT 09/11/06 1 2E-05 N/A INJECTION PROFILE 09/07/06 1 2E-05 11216326 SBHP 09/06/06 1 2U-03 11213007 INJECTION PROFILE 09/12/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test !jþ(2.. 6l \h{oA Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us; and Jim_Regg@admin.state.a OPERATOR: ConocoPhillips Alaska Inc. FIELD I UNIT I PAD: KRU1L DATE: 06/14/04 OPERATOR REP: Brake 1 Rogers AOGCC REP: Waived Packer Depth Pretest Initial 15 Min. 30 Min. Well 11 L-01 I Type Inj 1 N 1 T.V.D. I 5762 I Tubing 1 801 801 801 8°llnterval 4 P.TD. 1841730 Type Test P Test psi 1500 Casing 240 1740 1720 1720 P/F P Notes: well11L-03A I Type Inj I S 1 TV.D. I 4456 I Tubing I 25501 25501 25501 255°I,nterva, 4 P.T.D. 1990370 Type Test P Test psi 1500 Casing 450 1800 1760 1760 P/F P Notes: well11L-05 1 Type Inj I G 1 TV.D. 1 58261 Tubing I 35401 35401 35401 354°I,nterva, 4 P.TD. 1841230 Type Test P Test psi 1500 Casing 700 1740 1710 1700 P/F P Notes: well11L-07 I Type Inj I S I TV.D. 1 57381 Tubing 1 25501 25501 25501 25501 Interval 1 4 P.TD. 1841450 Type Test P Test psi 1500 Casing 560 1740 1740 1740 P/F P Notes: we1l11L-1O I Type Inj 1 S I TV.D. I 5866 1 Tubing 1 17901 17901 17901 1790 lnterval 4 P.T.D. 1900350 Type Test P Test psi 1500 Casing 1240 2500 2450 2450 P/F P Notes: we1l11L-14 1 Type Inj I G 1 TV.D. 1 5768 1 Tubing I 28001 28001 28001 28001 Interval 1 4 P.T.D. 1910100 Type Test P Test psi 1500 Casing 650 1700 1680 1680 P/F P Notes: we1l11L-16 1 Type Inj 1 N 1 TV.D. I 5794 I Tubing I 901 901 901 9°llnterval 4 P.T.D. 1841810 Type Test P Test psi 1500 Casing 125 1625 1620 1620 P/F P Notes: we1l11L-17 1 Type Inj G 1 T.V.D. 5868 I Tubing 1 32601 32601 33001 33001,nterva, 4 P.T.D. 1910430 Type Test P Test psi 1500 Casing 725 1725 1720 1720 P/F P Notes: well 1L-18 1 Type Inj I P.TD. 1910350 Type Test Notes: well11 L-21 DPNI Type Inj I P.TD. 1910060 Type Test Notes: Well 11 L-22 1 Type Inj I P.TD. 1901640 Type Test Notes: we1l11L-25 I Type Inj I P.TD. 1910700 Type Test Notes: MIT Report Form Revised: 05/19/02 s 1 TV.D. 1 5859 1 Tubing 1 18901 18901 18901 189°I,nterva, 4 P Test psi 1500 Casing 470 2600 2550 2540 P/F P S 1 TV.D. 1 5769 I Tubing I 22901 22901 22901 229011nterval 4 P Test psi 1500 Casing 60 1760 1760 1760 P/F P S I TV.D. 1 5909 1 Tubing I 23001 23001 23001 230011nterval 4 P Test psi 1500 Casing 60 1760 1750 1750 P/F P N 1 TV.D. 1 5884 1 Tubing 1 12501 12501 12501 125011nterval 4 P Test psi 1500 Casing 410 1760 1720 1720 P/F P MIT KRU 1L 06-14-04.xls 6/15/2004 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Alter casing ' r'"] Repaii"Well r~ Plug Perf0ra~ions r'-] . Stimulate r'~ Time'Extension ... .. . Change Approved Program [~] ··Puli.Tubing r-']' Perlomte New pool r-l.. Re-enter Suspended Well .. 2. Operator Name: 4. Current Well Status: · ' : 5. Permit to Ddll Number: ConocoPhillips Alaska, Inc. Development r-] . Exploratory F-] 190_035 / .., ' 3. Address: Stratigraphic r-'] Service r'~ 6. APl Number: P. O. Box 100360 ., 50-029-22026-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 122' 1L-10 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 9241' feet true vertical 6385' feet Plugs (measured) Effective Depth measured 9144 feet Junk (measured) true vertical 8738 feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 115' 16" 115' 115' SURFACE 5015' 9-5/8" 5137' 3681' PRODUCTION 9102' 7" 9224' 6370' "., .':,1 ~/~;I ,,.?' ,:':' ti .~.: ~, ,, ~ ~ ~ ~,.,t, . Perforation depth: Measured depth: 8713 - 9024J,.'~"~','~, ,~. /~UG J 5 true vertical depth: 5963 - 6204 ....... ~,;,.: ~,,,/~"i'~'~i ,- ~"~ '?'i:'~ '!;¥:?'.i;' '~-',t !' i'!i'i'...it ;.;; .... " Tubing (size, grade, and measured depth) 3-1/2", L-80, 8903' MD. · .......... Packers & SSSV (type & measured depth) pkr= BAKER FHL; BAKER "FB-I" PACKER pkr=- 8581'; 8879' SSSV= NIP SSSV=493' '12. 'stim~latidn or'ce'mbnt $'qubeze'.summary: ' · · · . · · · . ..' ' .. · . · . ..' .' .. . · . · '..:' · .. · ... .... : · Intervals treated (measured). · N/A .. ' "' · Treatment descril~fiShs including volumes USed and final pressure: . . ... · . .. . · . · · . . 1'3. .:. · .. Representative Daily',~verage. Production or InjectiOn' Da~a .. '...' OiI-Bbl'.'.. "· .Ga's-Mcf · · " Water-BIsI .' Casin.q Pressure · 'r~bin.q Pre'ssore. Pdor. towell operation ., '" · .. 4846 ". .1300 18,.39 · Subsequent to operation . ". · 6585: ' ' .' .':' 13.0.0 " '. 2699 14. AttachmentS' ". : . . ~ 5.'Weli .Ola~s a~t~r proposed wbrk: :... . . . Copies of Lo~s and surveys run _~_ .Exploratory D.. Development ..r~. Service r~ · : Daily Repor~ Of Well Operations __X' 16. Well Status' aftei'prop0sed work: · oilr-] Gas r--~ 'WAG r'~ GINJ[~ WINJ r-~ WDSPLr-'] 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.C. Exempt: I !:?':::.:C°ntact Jeff Spencer @ 659-7226 :i::; !'.~.ii!ii=:i~!i:i; ':.i'.'i;Printed Name/,/,,) ~)be/~ C,,~'i~J]ensen ::.i: Title :::::::::::::::::::::: ProductiOn Engineering Technician ure : O te Form 10-404 Revised 2/2003 · SUBMIT IN DUPLICATE 1L-10 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 081011031CommenCed WAG ::EOB. Injection PI-,.,.LIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 May 22, 2001 Commissioner Camille Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 1 L- 10 (190-035) Dear Ms. Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation treatment on KRU well 1L-10. If there are any questions, please contact me at 263-4574. Sincerely, Staff Engineer Phillips Drilling MM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ RKB 122 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 service__x Kuparuk Unit 4. Location of well at surface 8. Well number 5113' FNL, 5062' FEL, Sec. 29, T11 N, R10E, UM (asp's 540277, 5949135) 1L-10 At top of productive interval 9. Permit number / approval number 1356' FSL, 619' FWI, Sec. 28, T11 N, R10E, UM ~ 190-035 / At effective depth 10. APl number " ,~ 50-029-22026 At total depth 11. Field / Pool 3864' FNL, 4335' FEL, Sec. 28, T11 N, R10E, UM (asp's 546272, 5950418) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 9241 feet Plugs (measured) true vertical 6385 feet ~:~:~:~:~:~:~:~:~:~.:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~ Effective depth: measured?~iiiiiii::ii?!i~iiiiiii?ii~iii~i!i:~i?~iiii~ii~i~:iiiiii89~i3ii feet Junk (measured) Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 115' 16" 235 sx cs, 115' 115' SURFACE 5015' 9-5/8" 110o sx AS III, 460 sx Class G 5137' 3681' PRODUCTION 9102' 7" 250 sx Class G 9224' 6369' Perforation depth: m asured!~!~ta:!~8~?.8~!I~06. :?1881:.:?~88:~!¢i!89~8:::8956~:90~1~.::;9024:..:.· i::..:..i-i-:..i:i-:..:: ,.............................................................. true verticalilm~!~2!::!iii~9!!:6~4' 6038'-6044', 6135'-6150', 6198'-6204' ~ '~ ~_~, , Tubing (size, grade, and measured depth) 3-1/2", 9.3~, L-80 Tbg ~ 8903' MD. ~ ~'~/ ~' ..... ~ Packers & SSSV (~pe & measured depth) BAKER FHL ~ 8581' MD; BAKER "FB-I" PACKER ~ 8879' MD; ....... ~" '~" '~'; (-;;;:~:: ~;~ :~;- ¢'( CAMCO DS ~ 493' MD. 13. Stimulation or cement squeeze summa~ Intewals treated (measured) See A~achment Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pre~ure Prior to well operation ~ ~ ~ ~ ~~~~ :.:.: .: .:.: :. :.:.:.:.:: .:.:.: :,:. :::::::::::::::::::::::::::::::::::::: .: ::.:.:.:: 1 $. ~achmonts Gopios of ko~s and Su~ogs run ~ ~aily ~oport of Woll Oporafions ~ Oil ~ Oas ~ 8uspondod ~ So~co ~Wator X 17. I horoby corti~ that tho foro~oin~ is truo and corroct to tho host of my knowlod~o. Ouos#ons7 Call MiRo Moonoy2G~-4574 Signed ~~~ Title Staff Engineer Michael Moo~ey ~. Prepared by Sharon A//su~Drake Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE Date Comment 1L-10 Event History 04/09/01 ATTEMPTED HPBD. SAW GOOD DIVERSION IN ALL DIVERSION STAGES. PUMPED FIRST TWO HPBD STAGES TO COMPLETION. IN THIRD SCOUR STAGE, WELLHEAD PRESSURE INCREASED TO MAXIMUM ALLOWABLE, TREATMENT STOPPED DUE TO HIGH PRESSURE. ATTEMPTED TO BACKFLOW TO CLEAR SAN Page 1 of 1 5/22/01 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY TUBING -- (0-8903, OD:3.500, ID:2.992) Per[ (8713-879O) Perf (8800-8806) Perf (8811-8819) PKR (8879-8880, 0D:5.872) Per[ (8938-8§56) Per[ (901~9024) I RU 1L-10 APl: 1500292202600 I Well TYpe: i lNJ j Angle @ TS: j'~2'~J~g'@-;8-?0~ SSSV Type:l NIPPLE Odg Completion: ._3/2_~/_9_0 ......... i -ii~ AngI'e @ TD;i33 deg Annular Fluid:t Last W/O: 3/5/01 1. Rev Reason: Set DMY by ImO Reference Log:I . Ref Log Date: I --~. -~--"--_~-~._~i ~i~i. Lasi UPdateij 3/23!01 Last Tag: I TD: _9_ _2 41_ . [t_ _K B~ ........ L Last Tag Date: I Max Hole Angle:/57 de~q_~ 2400 .__J_ .................... J :ca~ing String; ALL STRINGS Description I Size I Top [ Bottom [--~D I"" Wt ..... I-'Grade"I";i;J~'~;~-a-~i'- CONDUCTOR 16.000 0 I- 115 ~--- 1i5 -~-62:50' [ H-40'[ .......... SURFACE 9.625 0 _5137__ i--~368~- 1-'36:00 I J-55 T ........... PRODUCTION 7.000 I 0 r 9224 ~-- 6371'-- [-2__.6.09_~j J:55l:- ............ Size Top Bottom 3.500 0 8903 PerfOrations summa~ : : Interval TVD 8713 - 8790 5964 - 6021 8800 - 8806 6029 - 6033 8811 - 8819 6037 - 6043 8938-8956 9016-9024 TVD 6108 Zone I StatusI Ft C-4,UNIT B 7~ UNIT B / 6 UNIT B A-5,A-4 18 A-4 6135-6150 6198-6204 Gas Uff Mandrels/Valves;;; : : St' MD ~D Man Man V Mfr V Type ~/~-O'-"-£'a~h-l-'P0rt-['TRo ...... Date .......~i'~'- iff Type / I Run /Cmnt 1 / 8519 5822 CAMCO I MMG CAMCO D___M:~-__~-::~-:~-'~J__ RK __ 0.000 [- 0 i 3122101 I- Produ~t~n Mandrels/Valves St MD ~D Man Man I vMfr I ~~-vo-D-l-LatCh ['port I TROI Date 'I ~1~" I I I ifr I Type I ] ~ j / I J Run ~Cmnt 2 I 86281 5901 CAMCO MMG CAMCO D_M_Y___~ _-_I_.0-1__.~_:-RK' 0.000I 0 i 315101 .:.L...i...:_: ..... Other (plUgs, equip.~ etcl i - JEWELRY Type Description '.i ...... ID"-- NIP Camco DS nipple i. s-P~--~D~-~'-' [--T~'pe' .............. com'me'r~t 2 1/8~' DYna striP; ze~o'c~eg~' 6_~_ §i~9)90- l' ApER phasing ........... ~6--~--~1-9)9(~ '-J APERF 2 1/8" Dyna Strip; Zero deg. ----] - -I . phasing 6 [ 8/19/90 r APERF 2 1/8" Dyna Strip; Zero deg. __ j ....... J ..... phasing ........ 4 i 716190 / IPERF i4 l/2"CsgGun; Oriented 70 -J~- ...... l-- I deg. CCW 40 ~7/6/90 / IPERF J4 1/2" Csg Gun; Oriented 50 ...... ~ ........... ~ ............ Ideg~.CCW Depth I TVDI 493 I 493 I 8568 /5857I 8581 158661 8867 160801 8877 /6088I 8879 16089I 8879 /6089 [ 8894 /6101j 8901/6106/ PBR Baker PBR w/5.875 guide . PKR Baker FHL SLEEVE BAKER CMU sliding sleeve w/CAMCO DS~profiiel NIP BAKER NO GO NIPPLE PKR BAKER "FB-1" PACKER SEAL BAKER SEAL ASSEMBLY NIP OTIS XN NIPPLE WIRELIKE BAKER WLEG 3.5" GUIDE 4.000 21938 "2:8i'3- '3.000.: 4.000 _ _ 3.000 2.750 '3.o00' MEMORANDUM State of Alaska Alaska 011 and Gas Conservation Commission TO: THRU: FROM: Julie Heusser ~" ~\~ DATE: May 21, 2001 Commissioner ~SUBJECT: Mechanical Integrity Tests Tom Maunder ~/.~~~ Phillips Alaska P.I. Supervisor/~/" ' ~"-' / 1D & 1L Pads John Crisp Kuparuk River Unit Petroleum Inspector Kuparuk River Field NO, N- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. ,, .We"I '1D:38 I Type~nj.I ' S '"I"T.v.D'.'I ~2~ lfu~hgl 2100I 2~00I 2~00I 2~00 I~nt~a~'! '1' ,P.T.D.I'2000'770 TYpetestI P' 'lTestpsiI' 1561 I Casing.I. 1700, I.'2700 I 2670' I 2660, I' P,/F Notes: ' W'elli 1L-10 I T~pe,.j.i "s' I T.v.D. 15866 i Tubingl 2570 12570 12570 12576 I,nterva, I I .... P.,T;D.I 190035(~ Type't',e~tl' P ITesi'Psil 146~ '1CaSingi o ",'1'" 20'00, ! 19~0' I,, 1950 Notes: · , 'we, i , P.T,.D,.I Notes: Notes: Type test I ! I I .. I . . I 'I' .'. l'nterva'l ! Type testI I Test psiI Casing I I I I P/F I ......... I . ,I . . Notes: Type test Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Tests Details I witnessed 2 MIT's in Phillips KRU. No failures witnesed. Interval I= Inilial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) M.I.T.'s performed: _2 AttaChments: nPne Number of Failures: 0_. Total Time during tests: 3 ,bm. ¢¢: MIT report form 5/12/00 L.G. MIT KRU 1D & 1L 5-21-01jc 5123/01 PH -'LIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 J. Trantham Phone (907) 265-6434 Fax: (907) 265-6224 March 16, 2001 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 1L-10 (90-35 / 300-320) Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operations on KRU well 1L-10. If there are any questions, please contact me at 265-6434 or Pat Reilly at 265-6048. Sincerely, J. Trantham Drilling Engineering Supervisor Phillips Drilling JT/skad ORIGINAL RECEIVED Alaska Oil & Gas Cons. Commission', Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Perforate _ Pull tubing _X Alter casing _ Repair well _ Other 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): Phillips Alaska, Inc. Development _. RKB 96 3. Address: Exploratory ~ 7. Unit or Property: P.O. Box 100360 Stratagrapic ~ Anchorage, AK 99510-0360 Service X. Kuparuk River Unit 4. Location of well at surface: 8. Well number: 164' FSL, 216' FWL, Sec. 29, T11N, R10E, UN 1L-10 At top of productive interval: 9. Permit number/approval number: 1356' FSL, 619' FWL, Sec. 28, T11N, R10E, UN 90-35 / 300-320 At effective depth: 10. APl number: 50-029-22026-00 At total depth: 1 I. Field/Pool: 1414' FSL, 938' FWL, Sec. 28, T11 N, R10E, Uk Kuparuk River Field / Kuparuk River Pool 12. Present well condition summary Total Depth: measured 9241' Plugs (measured) true vertical 6384' Effective Deptl measured 8923' Junk (measured) true vertical 6123' Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 235 sx CS II 115' 115' Surface 5015' 9.625" 1100 sx ASIII & 460 sx Class G 5137' 3681' Production 9101' 7" 250 sx Class G 9223' 6369' Liner Perforation Depth measured 8713'-8790', 8800'-8806', 8811 '-8819', 8938'-8956', 9016'-9024' true vertical 5963'-6021 ', 6029'-6034', 6038'-6044', 6013'-6028', 6075'-6081' Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 @ 8903' Packers and SSSV (type and measured depth) Baker 'FHL' packer @ 8581' Baker FB-1 packer @ 8879', No SSSV 13. Stimulation or cement squeeze summary Intervals treated (measured~ N/A Intervals treated (measured) 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Rel~ort of Well Operations _~X Oil Gas Suspended Service _X 17. I herebylcertify that the foregoing is true and correct to the best of my knowledge. Questions? Call Pat Reilly 265-6048 Signed f,,~,,_~,~ Title: Drilling Engineering Supervisor Date ·-,,,z - Jam~¥Trantharn Form 10-404 Rev 06/15/88 Prepared by Sharon AIIsup-Drake SUBMITIN DUPLICATE ~. MAR 1 9 Alaska Oi~ & Gas Cons. Anchorage Operations Summary 1L-10 Rpt Date 02/27/01 02/27/01 02/27/01 02/27/01 02/27/01 02/27/01 02/28/01 02/28/01 02/28/01 02/28/01 02/28/01 02/28/01 02/28/01 02/28/01 02/28/01 02/28/01 03/01/01 03/01/01 03/01/01 03/01/01 O3/O 1/01 03/01/01 03/01/01 03/01/01 03/02/01 03/02/01 03/02/01 03/02/01 03/02/01 03/02/01 03/02/01 03/03/01 03/03/01 03/03/01 03/03/01 03/03/01 03/03/01 03/03/01 03/03/01 03/03/01 03/04/01 03/04/01 03/04/01 03/04/01 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 12:00 12:00 12:00 AM AM AM AM Begin 07:30 14:30 17:00 19:30 21:00 22:00 00:00 00:30 01:30 02:30 04:30 06:00 09:00 12:30 15:30 21:00 00:00 02:30 04:00 06:00 07:00 13:00 14:30 16:00 00:00 02:30 07:30 10:30 11:30 16:30 19:30 00:00 00:30 01:30 08:30 11:00 14:30 15:30 16:30 18:00 00:00 00:30 06:00 07:00 Time End Time 14:30 17:00 19:30 21:00 22:00 00:00 00:30 01:30 02:30 04:30 06:00 09:00 12:30 15:30 21:00 00:00 02:30 04:00 06:00 07:00 13:00 14:30 16:00 00:00 02:30 07:30 10:30 11:30 16:30 19:30 00:00 00:30 01:30 08:30 11:00 14:30 15:30 16:30 18:00 00:00 00:30 06:00 07:00 12:00 Comments Move rig 8 miles from I H to I L pad w/1 hr. stop waiting to cross end of runway after plane landed. Spot over well. Level rig & berm-spot rig equipment. Pull VR plug-pull bpv-rig up circ. lines. Rig up hot oil-test hard lines w/air. PJSM w/DSO-rig crew-toolpusher-mud man-truck drivers & co. man. Security notified. (tbg. 620#-annulus Circ. well w/120 deg. seawater. Finish displacing & circ. 120 deg. seawater. Pump 60 bbls. hot diesel down annulus. Build hi-vis spacer & Icad mud in mud tanks. Displace diesel & seawater w/11.2# drlg. mud @ 3 bpm. Monitor well-freeze protect hard line-rig down circ. lines. PJSM-set bpv-nipple down tree & set out. Set in new Nipple up bope-pull bpv-set test plug-function bope. Test bope-250-4000# ok-lay down test plug-(witness test BOLDS-attempt to pull hanger to floor-work tbgo while waiting on sws to chemical cut tbg. PJSM-Rig up sws & rih w/chemical cutter. Finish making chemical cut-poh & rig down sws. (cut @ Lay down landing jt. & hanger-circ, bottoms up while Poh laying down 3.5" tbg. & jewellry. Crew change-PJSM-service rig & top drive. Finish laying 3.5" tbg. & jewellry-recovered everything down to cut-left 2 ss bands in hole. Load 2 jts. screens in shed & pick up same for screen Change out handling equipment-load bha in pipe shed & Make up bha #1-rih while picking up 14 4 3/4" dc,s & 3.5" Finish RIH picking up 3.5" dp. Record parameters-Tag & engage fish @ 8492' dpm-Jar loose-packer came loose w/seal assembly-work up hole Drop ball-shear pump out sub-circ. & work pipe to free up element on packer & circ. out gas. Circ. finish conditioning mud to 10.4#. POH w/fish. Lay down fish-recovered cut off jt.-pbr-packer & tail pipe. Make up bha #2 & rih slow w/cleanout assembly. Finish rih-tag sand @ 8674' dpm. CBU-condition mud for cleaning out sand. Cleaning out sand from 8674 to 8923'. Circ. hole clean pump hi-vis sweep & dry job. POH for running completion. Lay down 14 dc,s & bha, Pull wear ring. Slip & cut drlg. line. Haliburton wire line working on well # 1L-09-standby till PJSM-w/sws-rig up sws & run 5.9" gauge ring & junk basket & rih w/baker FB-1 packer & set on E-Line @ Finish setting packer on wireline @ 8879'-poh & rig down PJSM-rig up & run completion as per program. Crew change-service rig. PJSM-run completion-275 jts. 3.5" tbg. & jew~E CE t-"~ MAR 1 9 Alaska Oil & Gas Cons. Commission 03/04/01 03/04/01 03/04/01 03/04/01 03/04/01 03/04/01 03/04/01 03/05/01 03/05/01 03/05/01 03/05/01 12:00 12:00 12:00 AM AM AM 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 14:00 15:00 16:00 18:00 21:00 22:00 00:00 00:30 02:00 02:30 14:00 15:00 16:00 18:00 21:00 22:00 00:00 00:30 02:00 02:30 04:00 Operations Summary 1L-10 Rig up circ. lines-make up hanger-land tbg.-drop bar- pressure to 2500#-set packer & hold 30 mins. BOLDS-pick up-shear pbr @ 125k-space out & land Pressure to 2500# on tbg.-hold 15 mins.--bleed to 560#- pressure annukus 2500#-hold 15 mins.-increase to Pull landing jt.-set bpv-n/d bope. N/U tree & test packoff 5000#-pull bpv set 2 way check. Test tree 5000#-pull 2 way check & rig up circ. lines. Displace well to seawater @ 3.5 bpm. Finish displacing well to seawater. Freeze protect well w/85 bbls. diesel. Rig down circ. lines-pressures (tbg. 550=annulus 550) Set bpv-secure well & cellar-rig down berm & prep rig for move NOTE (Release rig @ 04:00 3/5/2001) Alaska 0il & Gas Cons. Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate Other _ Change approved program _ Pull tubing _X Variance _ Perforate 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ RKB 122 feet 3. Address Exploratory _ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__X Kuparuk River Unit 4. Location of well at surface 8. Well number 164' FSL, 216' FWL, Sec. 29, T11N, RIOE, UM 1L-10 At top of productive interval 9. Permit number / approval number 1356' FSLi 619' FWL, Sec. 28, T11 N, R10E, UM 90-35 At effective depth 10. APl number 50-029-22026-00 At total depth 11. Field / Pool 1414' FSL, 2938' FEL, Sec. 28, T11 N, R10E, UM Kuparuk River Field / Kuparuk River Pool 12. Present well condition summary Total depth: measured 9241 feet Plugs (measured) true vertical 6384 feet Effective depth: measured 9144 feet Junk (measured) true vertical 6303 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 80' 16" 235 sx cs, 115' 115' Surface 5015' 9.625" 1 lOO sx ASIII & 460 sx Class G 5137' 3681' Production 9101' 7" 250 sx Class G 9223' 6369' Liner Perforation depth: measured 8713'-8790', 8800'-8806', 8811'-8819', 8938'-8956', 9016'-9024'RECEIVED true vertical 5963'-6043', 6135'-6203' DEC 2 ? 2000 Tubing (size, grade, and measured depth 3.5", 9.3#, J-55 @ 8569' MD Alaska Oil & Gas Cons. Commission Anchorage Packers & SSSV (type & measured depth) Baker HB packer @ 8524' ,Otis series 10 SSSV @ 1812' 13. Attachments Description summary of proposal __X Detailed operations program _ BOP sketch __ Schematic __X Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic 14. Estimated date for commencing operation 15. Status of well classification as: January 9, 2001 16. If proposal was verbally approved Oil__ Gas __ Suspended __ Name of approver Date approved Service __X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Pat Reilly 265-6048 Signed ~ "~~-~ Title: Drilling Engineering Supervisor Date James Trantharn Prepared b)/ Sharon AIIsup-Drake FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness J Approval no. Plug integrity __ BOP Test __~ Location clearance --I ~(:~O - Mecha,ical Integrity Test ~ Subsequent form required 10- ..... _A__pprove_~ by order of the Commission [;) Taylor Seamount Commissioner Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE PRE-RIG WORK: KRU IL-10 GENERAL WORKOVER PROCEDURE 1. RU Slick Line Unit. RIH and tag bottom. Dummy off all GLM's. 2. RU CTU and RIH and set sand plug across A sand perfs 3. RU Slick Line, RIH pull bottom GLM valve and leave open. 4. RU E-LINE, RIH and chemical cut the tubing in the middle of the 1st full joint above the seals. 5. Set BPV in tubing. Install VR plug in annulus valve. Prepare Location for Nordic 3. GENERAL WORKOVER PROCEDURE: 1. MIRU Nordic Rig. Lay hard-line to tree. Pull BPV and VR plug. 2. Load pits with seawater. Displace tubing and annulus with seawater. SI well and monitor pressure to determine kill weight. Load pits with kill weight mud. Displace tubing and annulus with kill weight mud through open bottom GLM. SI well and monitor pressure to ensure well is dead. Set BPV. o 4. ND / NU and test BOPE. ~ 5. Screw in landing joint. POOH laying down completion. 6. Load, strap and drift 3-1/2" drill pipe. 7. RIH with overshot, engage fish, POOH with seals. 8. PU packer milling assembly and RIH picking up 3-1/2" drill pipe off the rack. 9. Mill up Baker permanent packer and push it to bottom. 10. RIH and fish packer. 11. RIH with cleanout assembly. 12. Cleanout to below bottom of C sand perforation, and POOH laying down 3-1/2" drill pipe. 13. RIH with bottom packer assembly on E-line and set packer. 14. Load, strap and drift 3.5" tubing. 15. RIH with 3.5" selective completion assembly as per schematic. 16. Spaceout with tubing pups and land tubing hanger. 17. Pressure test tubing and annulus. 1~ 18. ND / NU and test tree. 19. Displace well to seawater and freeze protect with diesel to +\- 2000' TVD. RECEIVED Alaska Oil & Gas Cons. Commission Anchorage PJR 11/20/00 1L-10 INJECTOR Workover Schematic 9-5/8" 36# J-55 @ 5,137' C4, Sand Perfs 8,713'- 8,819' MD A4 Sand Perfs 8,938'- 9,024' MD 7" ZC~ d-35 9,224' 3-1/2" 5M Cameron Gen IV tubing hanger with 3.5" L-80 9.3# EUE 8rd Mod pin down. 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing to the tubing hanger. 3-1/2" Camco DS Landing Nipple with 2.875" ID No-Go profile set @ +/- 500' MD. 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing to the 'DS' Nipple with 3-1/2" x 1" Camco 'KBUG' GLM's w/DV's spaced out as follows. RECEIVED Alaska 0il & Gas Cons. Commission Anchorage 3-1/2" x 1-1/2" 'MMG' GLM w/DCR Dump Kill Valve (3000 psi casing to tubing shear). 6' L-80 handling pups installed on top and bottom of mandrel. I Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 6' Handling Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. Baker '80-40' PBR. Baker 7" x 3-1/2" 'FHL' Retrievable Packer @ 8,563'. Minimum ID through the packer 3.00". 3ol/2", L-80, 9.3# EUE 8rd Mod Tubing to Packer. 3-1/2" x 1-1/2" 'MMG' GLM w/ 6' L-80 handling pups installed on top and bottom of mandrel. 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing to GLM. 3-1/2, L-80, Special Clearance BTC Mod Tubing w/Ricked Blast Rings. XO coupling to 3-1/2" EUE 8rd on top joint. Enough Blast Rings to cover all C-Sand Perfs w/at least 5' overlap above & below perfs. 3-1/2", Lo80, 9.3# EUE 8rd Mod Pup Joints as required to begin blast rings 5' below bottom C-Sand Perforations (XO coupling to 3-1/2" BTC Mod on top). Baker Sliding Sleeve with Camco 2.81" DS Profile @ 8,869' ( Lock has 2.856" NO-GO ring). 6' Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. Baker 'GBH-22' Locator Seal Assembly (5' seals w/Iocator). Baker 'FB-I' Hydraulic Set Permanent Packer w/5' Seal Bore Extension @ 8,879' (4" ID through SBE - 2.985" min bore through seals). 6' Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 3-1/2" Camco D Nipple @ 8,899' w/2.75" No-Go Profile 6' Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. Baker 3-1/2" Shear Out Sub w/ WL Re-entry Guide. Tubing tail @ 8,913' MD. PBTD @ 8,776' - Fill tagged on 8/25/97 PBTD @ 9,144' (EFFECTIVE DEPTH)- Actual 7" casing PBTD to FC. TD @ 9,241' 12/26/00 P JR MEMORANDUM TO: Dan Seam°unt'~ CommissiOner THRU: Blair Wondzell P.I. Supervisor FROM: John Crisp J' ~'~ Petroleum InspectOr State of Alaska Alaska Oil and Gas Conservation Commission DATE: September 11,2000 SUBJECT: Mechanical Integrity Tests Phillips Alaska Inc. 1 L Pad 03,05,07,10,14 Kuparuk River Unit Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. We,,I 1L-03 I Typelnj.I S I T.V.D. 14546 I Tubin.gl 2300 12300 I 23~)0 12300 I,ntervall 4 ~.¥.D.I 1841580 ITypetestl P ITestpsil 1137 I Casin~l 450 I 1825 I 18p0 I 1800 I P/F I _P' Notes: WellI 1L-05 I Typelnj. I S I*.~.~.'1 ~ I Tubing 12525 12525 12525 I~ I lntervall 4 P.T.D.I 1841230 ITypetestI P ITestpsil 1457 I Casingl 640 117O011660116501 P/FIE' Notes: WellI 1L-07 I Typelnj. I S ] T.V.D. I 5745 ]Tubing I 2550 I 2550 I 2550 I 2550 J lntervalJ 4 P.T.D.I 1841450 ITypetestI P ITestpsil 1436 J CasingI 690 I 1600 I 1540 l"1540 I PIE Notes: WeliI 1L~10 I Typelnj.I S ] T.V.D. 16043 I Tubing 11810 11810 11810 11810 I lntervall 4 'P.T.D.I 1900350 ITypetestI P I TestPsil 1511 I Casingl 575 I 2450 I 2440 I 2430 I PIE I Notes: ... We!!.l 1L-14 I Typelnj.! S I T.V.D. I*~ I Tubing I 2350 I 2350 12350 12350 I lntervall 4 P.T.D.l.1910100 TypetestI P ITestpsil 1442 I Casingl 5.00 1.1500. 1149011490I P/FIE- Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N -- NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Vadance W-'- Test during Workover O= Other (describe in notes) Test's Details I traveled to Phillips KRU to witness MITs. Phillips Rep. Peter Nezaticky was in charge of performing MITs. Testing was conducted in safe & efficient manner. .I.T.'s performed: Attachments: Number of Failures: 0 Total Time during tests: 2 hrs. cc: MIT report form 5/12/00 L.G. MIT KRU 1 La 9-11-00jc.xls 9/13/00 Well Name i'.oE Type Run Date ri,,er U'.it tA.-~l ,~/"/7 ~ River Unit 1 !.--.~0~ o- ~ ~ River Unit 11.--14 ~/~ff~ River Unit 1L-.I 7 ~1 ~ ~ Rive,' [.Jiii't II.-"22 ~o - I~ ~ l~vcr Unit IR 04 ~-/~ River Unit 1Y-10 ~) - ~/ River Unit 1Y---12 ~fl ~d River Unit 1Y..-15 g34 3 liiver Unit 2H-08~q~ ~ River Unit 2C.-02~fl --ff 3 riv,, u,it 2c-o4 dS-Y~ [<.t, pan,k River Unit 2(2 05 ~.?- ~ ff Kuparuk .River Uni! 2C 06 ,dP~--'/~::> Kuparuk River Unit 2V.-13 ~-- ~ ~ Kuparuk River Unit 3(3~12 ~O~ ~ Kt, paruk River Unit 3ttO2 gY~ / ~ Y Kuparuk River Unit 3(;.--20 ~/2 ~ Water Flow l.og (TiYI'..P) Injection Profile Injection Profile Injection Profile Injection Profile Injection Profile Injection Profile Injection Profile inj~x:iion Profile Injection Profile lnjedion Profile Injection Profile Injection Profile h)jectio, Profile Survey Inj~tion Profile Suwcy Injection ProEle Production i.og Production Log Injection Profile Injection Profile Survc~ [njl~iion Profile 07.IA N 199 i 10-I..91 03 NOVEMBER1991 4 N()VEMBt£I~. 1991 4 NOVEiMBER 1991 11-.06..-1991 6/30/91 12-13..-1991 11--19-91 11.-17-1991 12..2-91 12-..27-.1991 26 .DE(; 1991 10-27..-1991 11125191 11.-16-1991 ~.-.I [JNt(.-.1991 31 .-.JULY-. 1991 I 1 N()V 1991 1 iR 119/91 11..29-1991 RECEIVED MAR 2 6 1992 Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Post Office B~,,_ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 20, 1992 Mr. Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Wondzell' In response to your questions concerning the cement integrity in Wells 1L- I0 and 2K-23, ! have researched our drilling records to verify that a cement squeeze was performed across the Kuparuk interval in these wells. As you noted, based on the initial cement bond log, the primary cement job in Wells 1L-10 and 2K-23 did not appear to be adequate for these wells to be operated as Class II UIC wells. However, both of these wells had subsequent cement squeezes performed by a completion rig after the cement bond log but prior to injection of any fluids into the well. Well 1L-10 was squeezed on June 2, 1990, with 43.2 BBLS of cement to a squeeze pressure of 2840 psi. Well 2K-23 was squeezed on May 13, 1990, with 29.6 BBLS of cement to a squeeze pressure of 3020 psi. It is not standard operating procedure to perform follow-up cement bond logs on every squeeze, however we do run them on an occasional basis to evaluate the effectiveness of our squeeze operations. To date, these follow-up cement bond logs indicate that we have had excellent success with our cement placement. If additional data is needed, please contact me at 263-4281. Sincerely, C. W. Strickland Operations Engineer CWS/kz CC: J. D. Bolling A. W. McBride G. W. Targac P. S. White KOE 1.5-5 ATO- 1196 ~ ATO- 1448 ATO-1186 ATO- 1128 RECEIVED JAN 2 2 t992 (;iii & llas Co~s, Comml~slen ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany /\l/?,!i ~;()0;~ {; ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 5, 1991 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in duplicate are multiple Report of Sundry Well Operations notices in the Kuparuk field. The wells are listed below. WELL ACTION 1 L-1 0 Conversion 1 L - 2 2 Conversion 3Mol 3 Perforate 3M- 1 7 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer CC: KOE Manager ATe 1120 KeEl .4-9 w/o attachments RECEIVED SEP 1 2 1991 Alaska 0il & Gas Cons. 6or~m'tss't¢ Anchorage ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ALASKA OIL AND C~S CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS , 1. Operations Performed: Operation Shutdown __ Pull tubing Alter casing Stimulate m Plugging Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 5. Type of Well: Development Exploratory Stratigraphic 99510 Service Location of well at surface 64' FSL, 216' FWL, Sec. 29, T11N, R10E, UM At top of productive interval 356' FSL, 619' FWL, Sec. 28, T11N, R10E, UM At effective depth 380' FSL, 886' FWL, Sec. 28, T11N, R10E, UM At total depth 414' FSL, 2938' FEL, Sec. 28, T11N, R10E, UM 4. 1 1 1 1 12. Present well condition summary Total Depth' measured true vertical 9241 ' feet 6384' feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 1 2 2 7. Unit or Property name Kuparuk River Unit feet 8. Well number 11.-10 9. Permit number/approval number 90-35 / ¢/~. 10. APl number 50-0~)-22026 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 91 44' true vertical 6303' feet Junk (measured) feet Casing Len g t h Structural Conductor 1 1 5' Surface 51 3 7' Intermediate Production 9 2 2 3' Liner Perforation depth: measured 8713'-8790', 8938'-8956', true vertical 5963'-6043', Size 16" 9 5/8" 7" Cemented Measured depth True vertical depth 235 Sx CS II 1 15' I 15' 1100 Sx AS III & 51 37' 3681' 460 Sx Class G 250 Sx Class G 9223' 6369' 8800'-8806', 9016'-9024' 6135'-6203' Tubing (size, grade, and measured depth) 3 1/2" J-55 set at 8601' Packers and SSSV (type and measured depth) Baker HB @ 8524', Otis Series 10 @ 1812' 8811'-8819' 6 SPF 0 degree phasing 4 SPF 180 degree phasing RECEIVED 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure S E P 1 2 1991 Alaska Oil & Gas Cons. 6ommiSSiOr~ Anchorage 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 4535 10419 46 50 370 Subsequent to operation 0 - - 0 - 5900 600 2300 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector X Oil _ Gas Suspended Service 17. I her~,by certify that the foregoing is true and correct to the best of my knowledge. ,Si,necl f ~'~.~' ~ Title~~ ~~~'''''~ Form 10-404 Rev 09/12/90 Date 7-- --~ - ~ I SUBMIT IN DUPLICATE APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other ~ 2. Name of Operator 15. Type of Well: 6. Datum elevation (DF or KB) I Development ~- _ feet ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchora~]e, AK 99510 4. Location of well at surface 164' FSL, 216' FWL, S29, T11N, R10E, UM, At top of productive interval 1356' FSL, 619' FWL, Sec. 28' T11N, R10E, UM At effective depth 1380' FSL, 886' FWL, Sec.28, T11N, R10E, UM At total depth 1414' FSL~ 2938' FWL~ Sec. 28~ T11N~ R10Er UM Exploratory Stratigraphic BKB 122 7. Unit or Property name Kuparuk River Unit 8. Well number 1L-10 9. Permit number 90-35 10, APl number so-22026 11. F~d/Poo~ Kuparuk River Field Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 9 2 4 1 ' feet Plugs (measured) true vertical 6 3 8 4' feet Non~ Effective depth: measured 91 4 4' feet Junk (measured) true vertical 6 3 0 3' feet Nor~ Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 1 1 5' 1 6" 235 Sx CSII 1 1 5' 1 1 5' Surface 5137' 9 5/8" 1100 Sx AS III & 5137' 3681' Intermediate 460 Sx Class G Production 9 2 2 3' 7" 250 Sx Class G 9 2 2 3' 6 3 6 9' Uner Perforation depth: measured 8713'-8790' 6 SPF 0' degree phasing 8800'-8806' 6 SPF 0' degree phasing 8811-8819' 6 SPF 0' degree phasing 8938-8956 4 SPF 180 degree phasing ~. 9016-9024 4 SPF 180 degree phasing true vertical 5963'-6043', 6135'-6203', TVD Tubing (size, grade, and measured depth) ;-~i~ 3 1/2" J-55 set at 8601' Packers and SSSV (type and measured depth) Baker HB ~ 8524' Otis Series 10:1812' 13, Attachments Description summary of proposal _ Detailed operation program ~ BOP sketch _ Convert well from oil producer to water injector. (Wellbore schematic attached). 14. Estimated date for commencing operation 115, Status of well classification as: August. 1991 I Oil ~ Gas _.. Suspended _ 16. If proposal was verbally approved Name of approve~~' Date approved Service Water Injector 17. I here.l.~ certify.tha,t, the foregoing is true and correct to the best of my knowledge. Signed'~~ ~L~ · ~ Title Senior Operations Encjineer Date FOR COMM~K3N USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test__ Location clearance_.. Mechanical Integrity Test/~. Subsequent form require Approved by order of the Commission Form 10-403 Rev 09/12/90 Originat Signed By David W. Johnston IApprovaLNp. Commissioner Approved Co~~ TRIPLICATE / ,~1 AR~'-~- ALASKA INC.- KUPARUK r~'~LD Spud Date: 03-14-90 Completion Date: 0 7 - 0 6 - 9 0 Maximum Hole Angle: 55.7 Original Rig RKB: 33.1' All depth are RKB MD to top APl# 50-029-22000-00 C Sand: NOT PERFED A Sand: CPEN deg. @ 3308' MD 4 5,6 I Comments: of equipment. Well Type: OIL Tree Type: CAMERON GEN IV Tree Cap Type: Tree Cap Size: Tree Cap O-ring ASN: Last Workover Date: 0 7 - 0 7 - 9 0 Jewelry 1 SSSV: OTIS "SERIES 10" 2.812" ID @ 1812' 2 PBR: BAKER 3.5" ID @ 8518' 3 PKR: BAKER HB 3.5 ID @ 8524' 4 NOGO: CAMCO 'D' NIPPLE 2.750" ID @ 8569' 5 SHEAR OUT: BAKER @ 8601' 6 TUBING TAIL: @ 8602' Minimum ID:2.750" NOGO Casing end Tubing ~lze Welu_ht Grade TLAi~ ~ 9.625" 36# J-55 0 5137' 7' 26# J-55 0 9224' 3.5' 9.3# J-55 0 8600' Description CASING CAS~IG TUBING Gas aft Information ~ Stn~ Valve ~ Sz. 2158' I DIV 1 ' 8475' 2 D/V 1.5' AID# Date Run Perforation Data Interval SPF 8713-8790 6 8"800-8806 6 8811-8819 6 8938-8956 4 9016-9024 40 Date Phase FI' Zone 08-19-90 0 77 C 08-19-90 0 6 C 08-19-90 0 8 C 07-06-90 180 18 A 07-06-90 180 8 A Comments LAST TAG: 9029' ON 08-03-90 PBTD: 9144' LAST REVISION: 7-25-91 a^s WELL COMPLETION OR RECOMPLETION REPORT AND , ~. I Status of Well Classification of Service Well OIL ~ GAS r"-] SUSPENDED r"-] ABANDONED r-] SERVICE I-~ 2 Name of Operator 7 Permit Number ARCO Alaska~ Inc 90-35 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22026 4 Location of well at surface 9 Unit or Lease Name 164' FSL, 216' FWL, Sec. 29, T11 N, R10E, UM . YFP, IFIF. D lO Well Number At Top Producing Interval i~__~..~. 7 / S~rf 5.~ 1356' FSL, 619' FWL, Sec. 28, T11N, R10E, UM t "~"~ 1L-10 At Total Depth~--~--~. '~~'-~J~:~"I~'~~ ',~1 Field and Pool 1414' FSL, 938' FWL, Sec. 28, T11N, R10E, UM i KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designa~d Serial No. KUPARUK RIVER OIL POOL RKB 122' ADL: 25660 ALK: 470 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Ak)and. ' i 15 Water Depth, if offshore 116 No. of Completions 3/14/90. 3/21/90. "wefeJoT'I NA feet M SLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where ,~SSV set 21 Thickness of permafrost 9241' MD & 6384' TVD & 6303'TVD YES ~ NO D 1812' feetMD 1600' APPROX 9144' MD 22 Type Electric or Other Logs Run DIL/FDL/CN L/GR/P ET/GR/CCL 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SITF' CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24" 235 SX CS II 95~8" 36# J-55 SURF 5137' 12-1/4" 1100 SXAS III, 460 SX CLASS G 7" 26# L-80 SURF 9223' 8-1/2" 250 SX CLASS G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 8602' 8532' 8938'-8956' MD W/4-1/2" CSG GUN @ 4 SPF 6013'-6028' TVD 9016'-9024' MD W/4-1/2" CSG GUN @ 4 SPF 6075'-6081' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED i8713'-8790' MD W/2-1/8" DYNA STRIP GUN @ 6 SPF 5963'-6021' TVD SEE A'g'ACHED 8800'-8806' MD W/2-1/8" DYNA STRIP GUN @ 6 SPF 6029'-6034' TVD 8811'-8819' MD W/2-1/8" DYNA STRIP GUN @ 6 SPF 6038'-6044' TVD 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE J GAs-OIL RATIO I TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ . 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED OCT o 1.990 '' Anchora FRACTURED 7/:31/90 REPERFED 8/19/90 Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS FORMATION TESTS NAIVE Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 8702' 5955' NA KUPARUK C Be'I-rOM 8777' 6011' KUPARUK A TOP 8908' 6111' KUPARUK A BOTTOM 9020' 6201' ,. 31. LIST OF ATTACHMENTS GYRO, SUMMARY OF OPERATIONS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Sig ned ~,~ ~,,{~;~{.-~. t~.. ~~~~e AR~ DRILLING E~INEER Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL iL-10 7/31/90 Frac Kuparuk "A" sand perfs 8938'-8956' & 9016'-9024' @ 180 deg phase. Stage 1: Pmp 150 bbls Gel H20 prepad @ 20 bpm 6613-4494 psi Stage 2:700 bbls YF240 pad @ 20 bpm 47804790 psi Stage 3:138 bbls YF240 w/2# 16/20 LWP @ 20 bbls 4790-4740 psi Stage 4:115 bbls YF240 w/4# 16/20 LWP @ 20-18 bpm 4740-4988-5084 psi 20 bbls YF240 Flush 66 bbls Slick Diesel flush @ 18 bpm 4650-4670 psi Went to flush when pressure & Nolte started rapid increase, cutting 2 bbls rate had very little effect on press. Substituted LWP for Carbolite. Fluid to recover: 1,180 bbls Sand in zone: 30,890 lbs Sand in csg: 568 lbs Avg pressure: 4780 psi ~Drilling Date ARCO Alaska, Inc. Date: September 14, 1990 Transmittal #: 7883 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1 L- 1 0 Core Analysis 5 - 2 9 - 9 0 B P - 3 - 1 3 81 Receipt Acknowledged' D ri Iii ng Franzen D&M Kup. Reservoir Eng. Chevron Date: State of Alaska BP RECEIVED ..... _,S_EP 1 ? 1990 Alas~.Oli & Gas Cons. Commission Anchorage Unocal Mobil D ARCO ALASKA, INC. CORE ANALYSIS REPORT KRU iL-10 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA CL FILE NO. BP-3-1381 Performed by: Core Laboratories 8005 Schoon St. Anchorage, AK 99518 (907) 349-3541 Final Report Presented May 29, 1990 REEEIVED S E P 1 ? 1990 .Oil & Gas Cons. comm'tssiOn 't~chorage These ana]ysis, opinions or interpretations are based on observations and materials supplied by the c]ient to whom, and for whose exc]usive and confidentia] use, this report is made. The interpretations or opinions expressed represent the best judgement of Core Laboratories (a]] errors and omissions excepted); but Core Laboratories and it's officers and emp]oyees assume no responsibi]ity and make no warranty of representation as to the productivity, proper operations, profitability of any oi], gas or other minera] we1] or formation in connection with which such report is used or relied upon. INTRODUCTION Core Laboratories was requested to perform a sidewall core analysis study on behalf of Arco Alaska, Inc. for samples recovered from the KRU iL-10, North Slope, Alaska. Presented herein are the results of this study. Rotary sidewall cores were submitted. A service description with methodology is presented in section 1. The sidewall core analysis results are presented in section 2. Section 3 contains shipping transmittals. We sincerely appreciate this opportunity to be of service and hope these data prove beneficial in your development efforts. TABLE OF CONTENTS Section SIDEWALL CORE ANALYSIS, SERVICE DESCRIPTION AND METHODOLOGY SIDEWALL CORE ANALYSIS, TABULAR RESULTS TRANSMITTALS SECTION 1 SIDEWALL CORE Field Procedures Core Laboratories was not represented at the wellsite. Forty-one rotary sidewall samples arrived at Core Laboratories' Anchorage facility in April, 1990. The rotary sidewalls were preserved in ProtectCore pouches. All samples were shipped air freight. Core Processing Sample Preparation Dean-Stark Sidewall Samples Forty samples were selected for Dean-Stark analysis. They were first cleaned of drilling mud and cut into shapes approximating right cylinders. The samples were then weighed, placed in thimbles, and loaded into the Dean Stark. The remaining sample was too small for analysis. Analysis Techniques Dean-Stark Fluid Saturation Measurements Water was extracted from the sidewall samples by Dean-Stark technique using toluene. Samples were left in Dean-Stark for 24 hours. Recovered waters were measured and the samples were placed in the Soxlet for hydrocarbon extraction at least five days. Extracted samples were dried in a convection oven at 220 degrees F. for a minimum of 24 hours, and cooled in a desiccator to room temperature before porosity and permeability were measured. Saturations by Dean-Stark methods were calculated using Equations 1 and 2. So = [((W1 - W2 - H20)/Do)/Vp] x 100 (i) Sw = [H20/Vp] x 100 (2) Where: So = Oil Saturations, Percent Sw = Water Saturation, Percent Wi = Natural Weight W2 = Extracted and Dried Weight H20 = Extracted Water, Density Assumed 1.0 gm/cc Do = Density of Oil Vp = Pore Volume Grain Density Grain volume determinations were performed according to Boyle's Law utilizing the Helium Porosimeter. Grain density was calculated using Equation 3. Dg = Mg/Vg (3) Where: Dg = Grain Density Vg = Grain Volume Mg = Grain Mass Atmospheric Porosity The samples were measured for bulk volume by mercury displacement at ambient conditions. Porosity was calculated using Equation 4. P = [(Vb-Vg) / Vb) ] x 100 (4) Where-. P = Porosity, Percent Vb = Bulk Volume Vg = Grain Volume Atmospheric Permeability to Air Samples were loaded into a Hassler type core holder at a confining pressure of 200 psig. Permeability calculations were performed as defined by Darcy's Equation for compressible fluids, Equation 6. Pa x v x 1000 Qa x L x L K = x (6) (P1 - P2) (P1 +P2) Vb Where: K = Permeability v = Gas Viscosity P1 - P2 = Differential Pressure P1 + P2 = Mean Pressure Pa = Atmospheric Pressure Qa = Flow Rate L = Length Vb = Bulk Volume Special Conditions And Interpretations One of the samples was comprised largely of drilling mud, and therefore unusable for any analysis. Eleven additional samples were badly broken and thus unsuitable for permeability measurements. Other measurements were, however, not affected by the breaks. The table below identifies the above mentioned samples. Sample # Depth Excluded Analysis 3 8744.0 Permeability 4 8745.0 Permeability 7 8748.0 Permeability 9 8749.5 All 10 8752.0 Permeability 11 8756.0 Permeability 12 8760.0 Permeability 16 8768.0 Permeability 22 8778.0 Permeability 29 8792.0 Permeability 39 9018.0 Permeability 41 9024.0 Permeability Sample Disposition Upon completion of the analysis all sidewall samples were air freighted to ARCO's Shin Sakurai in Plano. See appendix for disposition of all samples shipped. DEAN-STARK ANALYSIS RESULTS j J J J I I t J ! J J J J J J i J J J Company Well : ARCO ALASKA, INC. : KRU 1L- 10 ANALYTICAL P R 0 C CORE E D U R LABORATORIES Field : KUPARUK RIVER UNIT Formation : KUPARUK ES AND QUALITY AS File No.: BP-3-1381 Date : 28-Apr- lggo SURANCE HANDLING & CLEANING ANALYSIS Core Transportation Solvent Extraction Equipment Extraction Time Drying Equipment Drying Time Drying Tent~erature : AIR FREIGHT : TOLUENE : DEAN STARK : 24 HOURS : CONVECTION OVEN : 24 HOURS : 220 DEG. F. Grain volume measured by Boyle's Law in a matrix cup using He Bulk volume by Archimedes Principle Water saturations by Dean Stark Oil saturations by weight difference in Dean Stark Dean Stark grain densities clean, dry solid mineral phase are measured REMARKS Mercury was used as displaced fluid for bulk volume measurement. j j j J I i i J J i J i i J J J J . J J Company Wel 1 : ARCO ALASKA, INC. : KRU 1L-10 CORE LABORATORIES Field : KUPARUK RIVER UNIT Formation : KUPARUK File No.: BP-3-1381 Date : 28-Apr- 1990 TABLE I S U # #A, RY O F CORE DATA ZONE AND CUTOFF DATA ZONE: Identification NOT SPECIFIED Top Depth 8739.0 ft Bottom Depth 9025.0 ft Number of Samples 41 DATA TYPE: Porosity (HELIUM) Permeability (HORIZONTAL) Kair CUTOFFS: Porosity (Minimum) Porosity (Maximum) Permeability (Minimum) --- Permeability {Maximum) --- Water Saturation (Maximum) Oil Saturation (Minimum) - Grain Density (Minimum) -- Grain Density {Maximum) -- Lithology Excluded 0.0 100.0 0.0000 100000. 100.0 0.0 2.00 3.50 NONE % % md md % % gm/cc gm/cc CHARACTERISTICS REMAINING AFTER CUTOFFS ZONE: Number of Samples Thickness Represented - POROSITY: Storage Capacity Arithmetic Average Minimum Maximum Median Standard Deviation .... GRAIN DENSITY: Arithmetic Average Minimum Maximum Median Standard Deviation .... 40 40.0 ft 664.2 ~-ft 16.6 % 3.7% 30.5 % 17.0 % +7.1% 2.94 gm/cc 2.61 gm/cc 3.30 gm/cc 3.00 gm/cc ±0.24 gm/cc PERMEABILITY: Flow Capacity Arithmetic Average .... Geometric Average Harmonic Average Minimum Maximum Median Standard Dev. (Geom) -- 597.6 md-ft 20.6 2.54 0.09 0.01 147. 5.16 K.10±1.272 md md md md md md md HETEROGENEITY (Permeability): Dykstra-Parsons Var. -- Lorenz Coefficient 0.952 0.589 AVERAGE SATURATIONS (Pore Volume): Oil Water 23.0 % 62.0 % Stat 1 - 1 i J J J j j I J J J J J i i ~ J J J J CORE LABORATORIES Company : ARCO ALASKA, INC. Wel 1 : KRU 1L- 10 Location : 28-11N-10E,Fr HE cot 3964'S 4195'W (BHL) Co,State : NORTH SLOPE, ALASKA Field : KUPARUK RIVER UNIT Formation : KUPARUK Coring Fluid : Elevation : CORE ANALYSIS RESULTS File No.: BP-3-1381 Date : 28-Apr- 1990 API No. : Analysts: PLB SATURATION SAMPLE DEPTH PERMEABILITY POROSITY GRAIN DESCRIPTION NUMBER (HORIZONTAL) (HELIUM) (PORE VOLUME) DENSITY Kair OIL WATER ft md % % % gm/cc I 8740.0 1.33 11.0 20.5 45.0 3.13 SS-ltgy,mgr,vwsrtd,sbang-rnd,vwcmt,qtz,glau,sid 2 8742.0 6.20 18.4 29.1 47.4 3.06 SS-ltgy,mgr,vwsrtd,sbang-rnd,sli fri,qtz,glau,dol 3 8744.0 16.0 24.2 70.1 3.11 SS-mgy,fgr,vwsrtd,sbrnd-wrnd,wcmt,glau,qtz,sid,tr dol 4 8745.0 14.5 23.1 72.8 3.24 SS-mgy,vf-mgr,wsrtd,sbrnd-wrnd,vwcmt,glau,qtz,sid 5 8746.0 0.01 8.5 29.7 60.5 3.30 SS-mltgy,f-mgr,pred fgr,wsrtd,sbrnd-wrnd,vwcmt,qtz,glau,sid 6 8747.0 <.01 7.2 28.7 69.4 3.28 SS-mltgy,f-mgr,pred fgr,wsrtd,$brnd-wrnd,vwcmt,qtz,glau,sid 7 8748.0 7.6 29.8 69.0 3.22 SS-mltgy,f-mgr,pred fgr,wsrtd,sbrnd-wrnd,vwcmt,qtz,glau,sid,frac 8 8749.0 18.2 12.0 23.4 67.8 3.27 SS-mgy,vfgr,vwsrtd,sbang-rnd,vwcmt,qtz,glau,sid 9 8749.5 Insufficient Sample 10 8752.0 10.1 29.0 70.8 3.15 SS-mltgy,fgr,vwsrtd,sbrnd-rnd,vwcmt,qtz,glau,sid 11 8756.0 10.9 25.3 60.9 3.14 SS-mltgy,fgr,vwsrtd,sbrnd-rnd,vwcmt,qtz,glau,sid 12 8760.0 21.5 23.5 73.2 2.65 SLTST-mltgy,aren,calc,dol,tr carb lam 13 8761.5 66.8 25.0 25.7 57.5 3.01 SS-mltgy,f-mgr,pred fgr,wsrtd,sb-wrnd,sli fri,qtz,glau,sid 14 8764.0 43.7 30.5 28.3 70.2 2.88 SS-mltgy,f-mgr,pred fgr,wsrtd,sbang-rnd,mod fri,qtz,glau,sid 15 8766.0 35.6 26.7 24.0 63.9 3.00 SS-ltgy,f-cgr,pred fgr,wsrtd,sbrdn-rnd sli fri,qtz,glau,sid 16 8768.0 26.4 27.8 62.1 2.98 SS-ltbrngy,f-nxjr,pred fgr,vwsrtd,sbang-rnd,mod fri,qtz,glau,sid,broken 17 8770.0 0.07 6.8 17.3 82.4 3.13 SS-ltgy,f-mgr,pred fgr,vwsrtd,sbang-rnd,wcmt,qtz,glau,sid,tr calc 18 8772.0 6.16 24.0 30.6 56.0 3.03 SS-mltgy,f-mgr,pred fgr,vwsrtd,sbang-rnd,sli fri,qtz,glau,sid 19 8773.0 0.03 10.8 12.7 74.9 3.13 SS-mltgy,f-mgr,pred fgr,vwsrtd,sbrnd-rnd,wcmt,qtz,glau,sid 20 8774.0 0.05 14.0 20.3 64.3 3.08 SS-ltbrngy,fgr,vwsrtd,sb-wrnd,vwcmt,qtz,glau,sid,frac 21 8776.0 1.30 4.8 19.3 66.0 3.09 SS-mltgy,f-cgr,pred fgr,wsrtd,sbang-rnd,vwcmt,qtz,glau,wt cmt 22 8778.0 7.5 17.1 81.0 3.11 SS-mltgy,fgr,r cgr,wsrtd,sbang-rnd,vwcmt,qtz,alt glau,ltbrn cmt,pt cmt frac 23 8780.0 30.7 27.1 29.5 57.5 2.99 SS-mgy,fgr,r cgr,wsrtd,sbang-rnd,mod fri,qtz,alt glau,carb cmt 24 8782.0 62.7 24.1 32.6 56.9 2.94 SS-mgy,fgr,r cgr,wsrtd,sbang-rnd,sli fri, atz,alt glau,dol,tr calc cmt,frac 25 8784.0 2.72 6.4 24.8 86.6 3.22 SS-mgy,fgr,r cgr,wsrtd,sbang-rnd,vwcmt,qtz,glau,sid,frac 26 8786.0 0.08 3.7 23.3 63.8 3.11 SS-ltgy,f-cgr,pred fgr,sbang-rnd,vwcmt,qtz,dol cmt 27 8787.5 3.36 19.3 22.7 50.9 2.80 SS-mgy,f-cgr,pred mgr,sbang-rnd,wcmt,qtz,glau,carb cmt 1 - 1 TRANSMITTALS Western Atlas International CORE LABORATORIES TRANSMITTAL AND ACKNOWLEDGEMENT OF RECEIPT TO: SHIN SAKURAI AR CO PR OD UCTION RESEAR CH CTR. 2300 W. PLANO PARKWAY PLANO, TX. 7.507.5 MATERIALS RECEIVED VIA: FEDERAL EXPRESS ITEMS RECEIVED: ONE PACKAGE CONTAINING FORTY-ONE ROTARY SIDEWALL SAMPLES FROM KR U 1L-lO (SEE A TTA CHED INVENTOR Y) - PLEASE RETURN ONE COPY SHIPPED BY: MIL TON CARNEY FOR CORE LAB DATE: 30-APRIL-90 RECEIVED BY: FOR ARCO DATE: Please note that the items listed above are inventoried, shipped and recieved in good faith, but are subject to minor adjustments because of possible human error. In such case both shipper and receiver agree to make a timely and bona fide effort to correct an, y observed discrepancies. 8005 Schooe Street. Anchorage. Alaska 99518-3045, (907) 349-3541. Fax (907) 344-2823 PLUG INVENTORY COMPANY ARCO ALASKA, INC. WELL KRU IL-10 DATE 30-APR-90 FILE NO. BP-3-1381~ BOX DEPTH 8740.0 8742.0 8744.0 8745.0 8746.0 8747.0 8748.0 8749.0 8749.5 8752.0 8756.0 8760.0 8761.5 8764.0 8766.0 8768.0 8770.0 8772.0 8773.0 BOX DEPTH 8774.0 8776.0 8778.0 8780.0 8782.0 8784.0 8786.0 8787.5 8790.0 8792.0 8794.0 8796.0 8802.5 8806.0 8942.0 8944.0 8945.0 8946.0 8948.0 BOX DEPTH 9018.0 9022.0 9024.0 CORE LABORATORIES. Company : ARCO ALASKA, iNC. Well : KRU 1L-10 Locatton: 28-11N-lOE,Fr NE CDr 3964'S 4195'W (BHL) Co,State : NORTH SLOPE, ALASKA Fteld : KUPARUK RIVER UN!T Formation : KUPARUK Cortng Flutd: Elevation : CORE ANALYSIS RESULTS File No.: BP-3-138! Date : 28-Apr-1990 AP! No. : Analysts: PLB SATURATION SAMPLE DEPTH PERMEABILITY POROSITY GRAIN DESCRIPTION NUMBER (HORIZONTAL) (HELIUM) (PORE VOLUHE) DENSITY Kmir OIL WATER ft md % % % gm/cc , I 8740.0 1.33 11.0 ZO.S 45.0 3.13 SS- ltgy, mgr,vwsrtd, sbmng-rnd, vwcmt, qtz, glmu, s t d Z 874Z.0 6.ZO 18.4 zg.I 47,4 3.06 SS-ltgy,mgr,vwsrtd,sbang-rnd,slt fri,qtz,gl&u,dol 3 8744.0 16.0 Z4.Z 70.1 3.11 $$-mgy,fgr,vwsrtd,sbrnd-wrnd,wcmt,gl&u,qtz,std,tr do1 4 8745.0 14.5 Z3.1 7Z.8 3.Z4 SS-toMy, vt'-mgr, wsrtd, sbrnd-wrnd, vwcmt, g 1au, qtz, atd 5 8746.0 0.01 8.5 Z9.7 60.5 3.30 $$-mltgy,f-mgr,pred fgr,wsrtd,sbrnd-wrnd,vwcit,qtz,glau,atd 6 8747.0 <.01 7.Z Z8.7 69.4 3.Z8 S$-mltgy, f-mgr,pred fgr,wsrtd,$brnd-wrnd,vwcmt,qtz,glau,std 7 8748.0 7.6 ~'g.8 69.0 3.ZZ $S-mltgy,f-mgr,pred fgr,wsrtd,abrnd-wrnd, vwcit,qtz,glau,std,fr&¢ 8 8749.0 18.Z 12.0 23.4 67.8 3.27 SS-may, vfgr, vwsrtd, sbmng-rnd, vwcmt, qtz, glau, atd 9 8749.5 Insufficient Smmple 10 875Z.0 10.1 29.0 70.8 3.15 $$-mltgy, fgr, vwsrtd,sbrnd-rnd, vwcmt,qtz, glmu, s td 11 8756.0 10.9 25.3 60.9 3.14 SS-mltgy, fgr,vwsrtd,sbrnd-rnd,vwcmt,qtz,glau, s Jd 12 8760.0 Z1.5 ~3.5 73.2 2.$5 $LTST-mltgy,mren,calc,dol,tr carb lam 13 8761.5 66.8 Z5.O 25.7 57.5 3.01 $S-mltgy,f-mgr,pred fgr,wsrtd,sb-wrnd,slt fri,qtz,glmu,$~d 14 8764.0 43.7 30.5 28.3 70.2 Z.88 SS-mltgy,f-mgr,pred fgr,wsrtd,$bang-rnd,mod frt,qtz,glau,$td 15 8766.0 35.6 Z6.7 24.0 63.9 3.00 $S-ltgy,f-cgr,pred fgr,w~rtd,sbrdn-rnd slt fri,qtz,gliu,sid 16 8768.0 26.4 Z7.8' 6Z.1 Z.98 S$-ltb~ngy,r-mgr, pred fgr,vwsrtd,sbmng-rnd,md frt,qt:z,glau,~td,broken 17 8770.0 0.07 6.8 17.3 8Z'.4 3.13 $$-ltgy,f-mgr,pred fgr,vwsrtd,$bing-rnd,wcmt,qtz,gl&u,~td,tr ¢&1¢ 18 877~.0 6.16 Z4.0 30.6 56.0 3.03 $S-mltgy, f-mgr,pred fgr,vwsrtd,sbmng-rnd,slt frt,qtz,gliu,std 19 8773.0 0.03 10.8 lZ.7 74.9 3.13 $S-mltgy,f-mgr,pred fgr,vwsrtd,abrnd-rnd,wcat,qtz,glau,sJd ZO 8774.0 0.05 14.0 ZO.3 64.3 3.08 5S- ltbrngy, fgr, vw~rtd, sb-wrnd, vwcmt, qtz, glau, s td, fraG ~1 8776.0 1.30 4.8 19.3 66.0 3.09 SS-mltgy,f-cgr,pred fgr,wsrtd,sbang-rnd,vwcat,qtz,glau,~l: Git 2Z 8778.0 7.5 17.1 81.0 3.11 $S-mltgy,fgr,r ¢gr,w~rtd,sbang-rnd,vwcmt,qtz,alt glau, ltbrn Git,pt rumt frae Z3 8780.0 30.7 Z7.1 Z9.5 57.5 2.99 S$-mgy,fgr,r ¢gr,wsrtd,$bang-rnd,mod fri,qtz,< glau,earb 24 8782.0 62.7 24.1 32.6 56.9 2.94 S$-mgy,fgr,r cgr,wsrtd,sbang-rnd,slt frt, atz,alt glau,dol,tr talc cit,frac Z5 8784.0 2.72 6.4 24.8 86.6 3.~2 $S-mgy,fgr,r ¢gr,wsrtd,sbmng-rnd,vwcmt,qtz,glmu,$td,frm¢ Z6 8786.0 0.08 3.7 Z3.3 63.8 3.11 SS-ltgy,f-cgr,pred fgr,$bang-rnd,vwcmt,qtz,dol cmt Z7 8787.5 3.36 19.3 ZZ.7 50.9 Z.80 SS-mgy,f-cgr,pred mgr,sbmng-rnd,wcmt,qtz,glau,cmrb 1- ! Company #ell : ARCO ALASI~, INC. : KRU 1L=10 CORE CORE LABORATORZES Fteld' : KUPARUK RIVER UNIT Formation : KUPARUK ANALYSTS RESULTS Ftle No.: BP-3-1381 Date : 28-Apr-1990 SATURATION SA#PLE DEPTH PERHEABZLITY POROS%TY GRAIN DESCRIPT%ON NU#BER (HORZZONTAL) (NELZUH) (PORE VOLUHE) DENSZTY Katr OIL VATER ft md Z X Z gm/cc 28 8790.0 5.16 18.2 12.5 65.5 2.63 PBL SS-dkgy,fsd-fbpl,pred md,mod s~td,sb-wsrnd,mod frt,qtz,tr glau,btt 29 8792.0 18.5 19.3 71.6 2.66 SLTST-mdkgy,slt frac on lam, carb cmt '30 8794.0 0.57 15.9 17.8 70.9 2.66 SLTST-mltgy,aren carb cmt,dk gy calc cmt bnd 31 8796.0 1.66 16.4 17.7 58.8 2.64 SS-mltgy,vf-fgr,r cgr,pred fgr,$bang-sbrnd,~cmt,qtz,calc cn~ lam 32 8802.5 0.03 17.6 1.1 97.7 3.05 HDST-ltgy,mss,dol 33 8806.0 48.5 20.4 22.8 47.4 2.65 SS-mltgy,fgr,vwsrtd,tr lam,$b&ng-sbrnd,wcn~,qtz,carb cmt 34 8942.0 55.4 22.8 1.0 68.3 2.61 SS-mltgy, fgr,vwsrtd,tr lam, sbang-sbrnd,wcmt,qtz,carb cn~ 35 8944.0 19.2 23.2 34.2 43.2 2.64 SS-ltgy,vf-fgr,pred vfgr,wsrtd,$bang-sbrnd,wcng,qtz,carb cmt 36 8945.0 0.64 15.0 11.6 80.6 2.72 SS-mdkgy, vfgr,abd dkgy celc cmt lem, vwcmt,qtz 37 8946.0 26.6 23.3 26.3 48.1 2.65 SS-mltgy, vfgr,wsrtd,dk lam, s11 frt,sb&ng,qtz 38 8948.0 14.0 21.4 28.8 55.1 2.64 SS-mltgy,vfgr,wsrtd,dk l&m, slt frt,sbang,qtz,calc cmt: fric 39 9018.0 18.5 24.6 68.1 2.65 SS-bndltgy vt'gr,wsrtd sd,dk gy do1 cmt sltst 40 9022.0 147. 23.5 30.3 15.3 2.64 SS-ltgy,vfgr,vwsrtd,sbang-sbrnd,wcmt,qtz,carb cmt 41 9024.0 14.5 4.1 94.0 2.67 HDST-dkgy,calc cmt,lam sdy 1-2 ,~RCO Alaska, Inc~ ~ Subsidiary of Atlantic Richfield Compaq. i<. ~ t,_ \ L--I© )~,~ ~-t_,,, WELL SERVICE REPOR'I ,VELL//.. /~ IOPERATION AT..~LEPOR~ TIME I-'1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ARCO Oil a,,d Gas Company Well History - Initial Report- Daily Instructions: Prepare and submit the "lnltlel Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to Spudding should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC. Field KUPARUK RIVER UNIT ICounty, parish or borough NORTH SLOPE Lease or Unit ADL: 25660 ALK: 470 Title COMPLETIONS IState AK IWell no. KRU iL-i' Auth. or W.O. no, AK4176 Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 07/01/90 (12) TD: 0 PB: 9144 SUPV:CD 07/02/90 (13) TD: 0 PB: 9144 SUPV:CD 07/03/90 (14) TD: 0 PB: 9144 SUPV:CD 07/04/90 (15) TD: 0 PB: 9144 SUPV:CD 07/05/90 (16) TD: 0 PB: 9144 SUPV:CD 07/06/90 (17) TD: 0 PB: 9144 SUPV:CD Date [ Hour 03/14/90 Complete record for each day reported NORDIC 1 17:30 ARCO W I 55. 8533 IPrior eta us if a W,O. RIH W/ DBP ON HLS WL 7"@ 8860' MW:ll.0 NaC1/Br MOVE RIG F/ 1L-9 TO IL-10, ND TREE, NU BOPE AND TST, RU HLS E-LINE, RIH TO 9000' W/ 6.125" GR/JB, POH AND LD GR/JB, MU DBP AND RIH DAILY:S21,037 CUM:$1,333,147 ETD:S1,333,147 EFC:$1,740,000 WOC 7"@ 8860' MW:ll.0 NaCl/Br FINISH RIH W/ DBP, SET AT 8900' POH, MU SPZ PERF GUN, RIH AND PERF 8862'-8864' POH, PRES CSG TO VERIFY HOLES, PU EZSV, RIH OH HLS E-LINE, SET AT 8672' POH, RU HLS SQZ PERF GUN#2 RIH AND PERF 8640'-8642', POH, PRES UP ON CSG TO VERIFY HOLES IN CSG, UNABLE TO GET INJECTION RATE WITH RIG PUMP, PRES CSG TO 3500 PSI BLEEDS TO 3000 PSI IN 3.5 MIN, RD HLS E-LINE, MU HOWCO EZSV STINGER AND TIH TO HOWCO EZSV AT 8672, RU DOWELL LINES, STING EZSV, CMT SQZ W/ 150 SX CMT, PO EZSV, SQZ 75 SX CMT, CIP AT 03:35, RD DOWELL, WOC DAILY:S72,576 CUM:$1,405,723 ETD:S1,405,723 EFC:$1,740,000 DRILLING CMT 7"@ 8860' MW:ll.0 NaC1/Br WOC, POH USING MUD BUCKET, LOAD OUT HOWCO TOOLS, RU FLOOR TO PU DRILL STRING AND KELLY, TIH, DRILL CMT F/ 8515'-8672' (EZSV), TST 7", DRILL EZSV, DRILL CMT DAILY:S40,825 CUM:$1,446,548 ETD:S1,446,548 EFC:$1,740,000 PREP TO FILTER BRINE 7"@ 8860' MW:ll.0 NaC1/Br DRILL CMT TO 8884', CIRC/TST CSG FOR 30 MIN AT 1350 PSI, DRILL CMT 8884' TO DBP, WASH FROM 8900 TO PBTD, AT 9127', CIRC HOLE CLEAN, SET BACK KELLY, CUT AND SLIP DRILL LINE, POH, RU CSG SCRAPER (7") AND TIH DAILY:S28,147 CUM:$1,474,695 ETD:S1,474,695 EFC:$1,740,000 RIH W/ GR/JB ON HLS E-LINE 7"@ 8860' MW:ll.0 NaCl/Br FILTER BRINE, BLOW DOWN LINEW/KELLY, LD KELLY, LD 3.5" DP AND 4-3/4" DS'S AND 7" CASING SCRAPER AND BIT, RD FLOW NIPPLE AND FLOW LINE, RU HLS LUBR AND WL, START DOWN HOLE W/ GR/JB ON HLS WL DAILY:S32,943 CUM:$1,507,638 ETD:S1,507,638 EFC:$1,740,000 LAND 3-1/2" TBG ON HNGR 7"@ 8860' MW:ll.0 NaCl/Br RIH W GR/JB TO 9100', POH W/ JUNK, RIH W/ GR/JB, POH W/ JUNK, RIH W/ GR/JB, POH W/ 1 PINT CMT, LD GR/JB, MU PERF GUN #1, RIH WITH PERF GUN #1 AND PERF 9016'-9024' (ASF), MU PERF GUN #2, RIH W/ PERF GUN #2 AND PERF 8938'-8956' (ASF), PREP TO RUN TBG, RUN 3-1/2" COMP, TBG LANDED ON HNGR AT 0600 HRS DAILY:S183,873 CUM:$1,691,511 ETD:S1,691,511 EFC:$1,740,000 The above is correct Signature/) I ~ For form preparation ~1~ distribution, see Procedures Man[{alJ Section 10, Drilling, Pages 86 an~W~7. AR3B-459-1-D INumber all daily well history forms es they are prepared for each well. consecutively iPage no. ARCO O,..,nd Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon compietion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ARCO ALASKA INC. Field KUPARUK RIVER UNIT Auth. or W.O. no. AK4176 County or Parish NORTH SLOPE ILease or Unit ADL: 25660 ALK: 470 ITitle COMPLETION IAccounting cost center code State AK IWell no, KPU I L- i Operator ARCO Spudded or W.O. begun SPUD Date and depth Complete record for each day reported as of 8:00 a,m. NORDIC 1 07/07/90 ( 18] TD: 0 PB: 9144 SUPV:GB A'R'C°'W'I'55.8533 Date 03/14/90 I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our 17:30 Prior status if a W,O. RIG RELEASED 7"@ 8860' MW:ll.0 NaC1/Br FINISH LAND TBG, SET PKR, SHEAR PBR, TST SSSV, PULL LDG JT, ND BOP, NU TREE, OPEN SSSV, PRES TST 3-1/2" X 7" ANNULUS, SHEAR SOS, DISPLACE ANNULUS W/ 6 BBLS DIESEL, BULLHEAD 2 BBLS DIESEL DOWN TBG, CV HOLDING RD AND BLOW DOWN LINES, RELEASE RIG DAILY:S12,985 CUM:$1,704,496 ETD:S1,704,496 EFC:$1,740,000 Old TD Released rig New TD I PB Depth Date IKind of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data ~/etl no. Date Reservoir Producing Interval :Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct F;r form prT~aration d;trib ' ' / -- ' ' 0 see P .... %;7~rgiZZu~Soction ~n, Drilling, Pages 86 and 87. ~%'*"~ lNumber all dally well hislo~ fopm~"%%~ I Page no. Jas they are prepared f ..... h well. I 1 AR3B-459-3-C Gyrodata Incorporated P.O. Box 79389 Houston, Texas 77224 713/461-3146 Fax: 713/461-0920 June 27. 1990 Mr. Steve Edwards ARCO Alaska, Inc. P.O. Box 100560 Anchorage, Alaska 99510 Re: Kuparuk River Unit 1L-lO (29-11-10) North Slope Borough, Alaska Dear Mr. Edwards: Enclosed please find one (1) original and nine (9) copies of the survey addendum to KRU 1L-10 (29-11-10). Please let me know if I can provide further assistance. Sincerely, A1 Kudrle Rep resen tat i ye Enclosures Gyrodata Services, Inc. Houston, TX / Lafayette, LA / New Odeans, LANentura, CA / Aberdeen, U.K. / Calgary, Alberta Anchorage, AK / Kuantan, Malaysia / Buenos Aires, Argentina / Bergen, Norway 06/26/90. GREAT LAND DIRECTIONAL DRILLING, INC. Client .... : ARCO ALASKA, INC. Field ..... : KUPARUK RIVER UNIT Well ...... : KRU 1L-10 (29-11-10) Section at: N,79.38,E Surveyor..: AL KUDRLE Computation...: RADIUS OF CURVATURE- Survey Date...: 06/06/90 RKB Elevation.: 122.00 ft Reference ..... : AK0690G230 RECORD OF SURVEY MEAS INCLN VERTICAL-DEPTHS DEPTH ANGLE BKB SUB-SEA DISTNCE 100 0.17 100.0 -22.0 200 0.21 200.0 78.0 300 0.34 300.0 178.0 400 0.81 400.0 278.0 500 3.84 499.9 377.9 BEARING 0.1 N 82.89 E 0.1 N 0.1 E 0.4 N 72.05 E 0.2 N 0.4 E 0.9 S 75.46 E 0.2 N 0.9 E 1.7 S 52.60 E 0.2 S 1.8 E 3.5 S 21.50 E 3.4 S 4.2 E SECTION DIRECTION RELATIVE-COORDINATES FROM-WELL-HEAD CLOSURE D I STNCE BEARING / 100 0.1 N 41.45 E 0.17 0.4 N 67.21 E 0.04 0.9 N 78.05 E 0.13 1.8 S 82.05 E 0.47 5.4 S 50.60 E 3.03 7 600 5.01 599.6 477.6 7 700 5.29 699.2 577.2 7 800~ 5.86 798.7 676.7 7 900 7.63 898.0 776.0 7 1000 10.17 996.8 874.8 5.2 S 25.05 E 8.0 S 32.54 E 12.4 S 42.43 E 19.8 S 58.33 E 32.1 S 67.86 E 10.5 S 7.2 E 18.4 S 11.6 E 26.1 S 17.5 E 33.6 S 26.5 E 40.6 S 40.3 E 12.8 S 34.52 E 1.17 21.7 S 32.16 E 0.29 31.4 S 33.80 E 0.58 42.8 S 38.28 E 1.79 57.1 S 44.80 E 2.56 7 1100 14.88 1094.4 972.4 7 1200 20.01 1189.8 1067.8 7 1300 22.21 1283.1 1161.1 7 1400 27.04 1373.9 1251.9 7 1500 34.20 1459.9 1337.9 51.3 S 77.70 E 79.4 S 83.83 E 114.3 S 89.10 E 155.5 N 84.81 E 206.3 N 82.59 E 47.0 S 61.0 E 51.8 S 90.5 E 54.0 S 126.4 E 52.4 S 168.1 E 46.8 S 218.6 E 76.9 S 52.39 E 4.75 104.3 S 60.23 E 5.18 137.5 S 66.88 E 2.33 176.0 S 72.67 E 4.99 223.6 S 77.91 E 7.19 7 1600 41.66 1538.8 1416.8 7 1700 43.69 1612.3 1490.3 7 1800 44.84 1683.9 1561.9 7 1900 48.12 1752.7 1630.7 7 2000 51.50 1817.3 1695.3 267.6 N 81.46 E 335.4 N 80.61 E 405.2 N 79.42 E 477.7 N 78.22 E 554.0 N 78.01 E 38.3 S 279.5 E 27.8 S 346.4 E 15.7 S 415.2 E 1.6 S 486.3 E 14.1 N 561.0 E 282.1 S 82.19 E 7.48 347.5 S 85.42 E 2.07 415.5 S 87.84 E 1.29 486.3 S 89.81 E 3.35 561.2 N 88.56 E 3.38 7 2100 54.52 1877.4 1755.4 7 2200 56.23 1934.2 1812.2 633.8 N 74.33 E 715.6 N 72.12 E 33.2 N 638.6 E 57.0 N 717.4 E 639.4 N 87.02 E 3.88 719.6 N 85.46 E 2.29 'Survey Codes: 7/GYRO ( KRU1LiO ) KRU 1L-10 (29-11-10) Page 2 06/26/90- RECORD OF SURVEY S MEAS INCLN VERTICAL-DEPTHS C DEPTH ANGLE 7 2300 56.38 1989.7 1867.7 7 2400 57.36 2044.4 1922.4 7 2500 53.97 2100.8 1978.8 7 2600 53.02 2160.3 2038.3 7 2700 53.58 2220.0 2098.0 BKB SUB-SEA DISTNCE BEARING SECTION DIRECTION RELATIVE-COORDINATES FROM-WELL-HEAD 82.5 N 796.6 E 107.2 N 876.5 E 131.0 N 955.6 E 154.1 N 1032.6 E 176.5 N 1109.6 E 798.1 N 72.20 E 881.3 N 73.38 E 963.4 N 73.16 E 1043.3 N 73.41E 1123.1 N 74.21 E 7 2800 53.86 2279.2 2157.2 7 2900 54.91 2337.4 2215.4 7 3000 55.85 2394.2 2272.2 7 3100 54.23 2451.5 2329.5 7 3200 54.79 2509.6 2387.6 1203.4 N 74.34 E 1284.5 N 76.59 E 1366.7 N 75.49 E 1448.5 N 77.42 E 1529.9 N 78.23 E 198.3 N 1187.2 E 218.7 N 1265.9 E 238.6 N 1345.7 E 257.8 N 1425.4 E 274.9 N 1505.0 E 7 3300 55.39 2566.8 2444.8 7 3400 53.92 2624.7 2502.7 7 3500 52.15 2684.8 2562.8 7 3600 52.58 2745.9 2623.9 7 3700 52.51 2806.7 2684.7 1611.9 N 78.96 E 1693.4 N 79.91 E 1773.3 N 77.62 E 1852.5 N 78.42 E 1931.9 N 78.68 E 291.2 N 1585.4 E 306.1 N 1665.6 E 321.7 N 1743.9 E 338.1 N 1821.4 E 353.9 N 1899.2 E 7 ,3800 53.16 2867.1 2745.1 7 3900 53.83 2926.6 2804.6 7 4000 54.11 2985.4 2863.4 7 4100 54.08 3044.0 2922.0 7 4200 50.84 3105.0 2983.0 2011.6 N 79.62 E 2091.9 N 79.43 E 2172.8 N 80.01 E 2253.8 N 80.00 E 2333.1 N 79.01 E 368.9 N 1977.5 E 383.5 N 2056.5 E 397.9 N 2136.1 E 412.0 N 2215.8 E 426.4 N .2293.8 E 7 4300 51,25 3167.8 3045,8 2410.9 N 79.18 E 441.1 N 2370.2 E 7 4400 51.90 3230.0 3108.0 2489.2 N 80.23 E 455.1 N 2447.2 E 7 4500 52.63 3291.2 3169.2 2568.3 N 80.93 E 468.1 N 2525.3 E 7 4600 52.58 3351.9 3229.9 2647.7 N 81.68 E 480.1 N 2603.8 E 7 4700 52.58 3412.7 3290.7 2727.0 N 83.23 E 490.5 N 2682.5 E 7 4800 52.82 3473.3 3351.3 2806.3 N 83.41 E 499.8 N 2761.5 E CLOSURE DL DISTNCE BEARING /100 800.8 N 84.09 E 0.16 883.1 N 83.03 E 1.29 964.5 N 82.19 E 3.39 1044.0 N 81.51 E 0.96"-~ 1123.5 N 80.96 E 0.76 ) 1203.6 N 80.52 E 0.29 1284.6 N 80.20 E 1.84 1366.7 N 79.95 E 1.20 1448.5 N 79.75 E 2.06 1529.9 N 79.65 E 0.78 1611.9 N 79.59 E 0.78 1693.5 N 79.59 E 1.60 1773.3 N 79.55 E 2.27 1852.5 N 79.48 E 0.66 1931.9 N 79.45 E 0.18 2011,6 N 79.43 E 0.89 2091.9 N 79.44 E 0.68,.>, 2172.8 N 79.45 E 0,47~''~ 2253.8 N 79.47 E 0.03 ) 2333.1 N 79.47 E 3.29 2410.9 N 79.46 E 0.42 2489.2 N 79.46 E 0.92 2568.3 N 79.50 E 0.85 2647.7 N 79.55 E 0.48 2727.0 N 79.64 E 0.98 2806.4 N 79.74 E 0.27 'Survey Codes: 7/GYR0 KRU 1L-10 (29-11-10) RECORD OF SURVEY S MEAS INCLN VERTICAL-DEPTHS C DEPTH ANGLE BKB SUB-SEA DISTNCE SECTION DIRECTION RELATIVE-COORDINATES BEARING FROM-WELL-HEAD ---- 7 4900 51.67 3534.5 3412.5 2885.3 N 80.41 E 510.9 N 2839.8 E 7 5000 51.86 3596.4 3474.4 2963.8 N 79.97 E 524.3 N 2917.2 E 7 5100 51.99 3658.1 3536.1 3042.5 N 81.59 E 536.9 N 2994.9 E 7 5200 52.19 3719.5 3597.5 3121.4 N 81.11 E 548.7 N 3072.9 E 7 5300 52.19 3780.8 3658.8 3200.4 N 80.76 E 561.2 N 3150.9 E 7 5400 52.58 3841.8 3719.8 3279.5 N 80.93 E 573.8 N 3229.1 E 7 5500 52.81 3902.4 3780.4 3359.1 N 80.81 E 586.4 N 3307.6 E 7 5600 52.55 3963.1 3841.1 3438.6 N 80.47 E 599.4 N 3386.1 E 7 5700 51.76 4024.4 3902.4 3517.5 N 79.47 E 613.1 N 3463.9 E 7 5800 51.33 4086.6 3964.6 3595.8 N 78.37 E 628.2 N 3540.7 E 7 5900 51.70 4148.8 4026.8 3674.1 N 77.93 E 644.2 N 3617.3 E 7 6000 51.89 4210.7 4088.7 3752.6 N 77.72 E 660.8 N 3694.1 E 7 6100 52.42 4272.0 4150.0 3831.6 N 77.47 E 677.8 N 3771.3 E 7 6200 52.59 4332.9 4210.9 3910.9 N 77.21 E 695.2 N 3848.7 E 7 6300 50.50 4395.1 4273.1 3989.1 N 77.27 E 712.5 N 3925.0 E 7 6400 50.95 4458.4 4336.4 4066.5 N 76.94 E 729.7 N 4000.5 E 7 6500 51.23 4521.2 4399.2 4144.2 N 76.56 E 747.6 N 4076.2 E 7 6600 51.60 4583.6 4461.6 4222.3 N 76.34 E 765.9 N 4152.2 E 7 6700 51.85 4645.5 4523.5 4300.6 N 76.09 E 784.6 N 4228.5 E 7 6800 52.20 4707.1 4585.1 4379.3 N 75.88 E 803.7 N 4305.0 E 7 6900 52.51 4768.1 4646.1 4458.4 N 75.94 E 822.9 N 4381.8 E 7 7000 52.77 4828.8 4706.8 4537.7 N 75.66 E 842,4 N 4458.8 E 7 7100 50.86 4890.6 4768.6 4616.1 N 75.29 E 862.2 N 4534.9 E 7 7200 50.16 4954.2 4832.2 4693.1 N 76.25 E 881.1 N 4609.7 E 7 7300 50.57 5018.0 4896.0 4770.0 N 76.02 E 899.6 N 4684.5 E 7 7400 50.75 5081.4 4959.4 4847.2 N 75.86 E 918.4 N 4759.5 E 'Survey Codes: 7/GYRO Page 3 06/26/90. CLOSURE DL DISTNCE BEARING /100 2885.4 N 79.80 E 2.17 2963.9 N 79.81 E 0.33 3042.6 N 79.84 E 1.01 3121.5 N 79.87 E 0.36~ 3200.5 N 79.90 E 0.22 3279.7 N 79.92 E 0.40 3359.2 N 79.95 E 0.24 3438.7 N 79.96 E 0.34 3517.7 N 79.96 E 1.00 3596.0 N 79.94 E 0.80 3674.2 N 79.90 E 0.46 3752.8 N 79.86 E 0.23 3831.7 N 79.81 E 0.55 3911.0 N 79.76 E 0.24 3989.2 N 79.71 E 2.09 4066.5 N 79.66 E 0.49 4144.2 N 79.61 E 0.36 4222.3 N 79.55 E 0.39'. 4300.7 N 79.49 E 0.29 4379.3 N 79.43 E 0.37 4458.4 N 79.36 E 0.31 4537.7 N 79.30 E 0.31 4616.1 N 79.24 E 1.92 4693.2 N 79.18 E 0.90 4770.1 N 79.13 E 0.43 4847.3 N 79.08 E 0.20 KRU 1L-10 (29-11-10) Page 4 06/26/9(~ RECORD OF SURVEY MEAS INCLN VERTICAL-DEPTHS DEPTH ANGLE 7500 51.15 5144.4 5022.4 7600 49.72 5208.1 5086.1 7700 47.98 5273.9 5151.9 7800 48.34 5340.6 5218.6 7900 48.78 5406.8 5284.8 BKB SUB-SEA DISTNCE BEARING 4924.7 N 75.43 E 5001.6 N 74.20 E 5076.5 N 74.02 E 5150.7 N 73.91 E 5225.3 N 73.63 E SECTION DIRECTION RELATIVE-COORDINATES FROM-WELL-HEAD 937.6 N 4834.7 E 957.8 N 4909.1 E 978.4 N 4981.5 E 999.0 N 5053.1 E 1020.0 N 5125.1 E 7 8000 49.18 5472.4 5350.4 7 8100 47.73 5538.7 5416.7 7 8200 47.43 5606.2 5484.2 7 8300 47.74 5673.7 5551.7 7 8400 48.17 5740.6 5618.6 5300.4 N 73.54 E 5374.7 N 72.41 E 5448.0 N 71.64 E 5521.1 N 71.25 E 5594.6 N 71.27 E 1041.3 N 5197.5 E 1063.2 N 5269.1 E 1086.0 N 5339.3 E 1109.5 N 5409.3 E 1133.3 N 5479.6 E CLOSURE DL DISTNCE BEARING /100 4924.8 N 79.02 E 0.48 5001.7 N 78.96 E 1.60 5076.7 N 78.89 E 1.74 5151.0 N 78.82 E 0.37 5225.6 N 78.74 E 0.47 5300.8 N 78.67 E 0.40 5375.3 N 78.59 E 1.58 5448.6 N 78.50 E 0.51 5521.9 N 78.41 E 0.38 5595.6 N 78.31 E 0.43 7 8500 46.27 5808.5 5686.5 7 8600 43.05 5879.7 5757.7 7 8700 41.52 5953.6 5831.6 7 8800 41,14 6028.7 5906.7 7 8900 39.05 6105.2 5983.2 5667.3 N 72.06 E 5737.2 N 74.82 E 5804.4 N 78.42 E 5870.4 N 78.54 E 5934.8 N 78.08 E 1156.4 N 1176.4 N 1192.0 N 1205.2 N 1218.3 N 5549.3 E 5616.6 E 5682.1 E 5746.8 E 5809.8 E 5668.5 N 78.23 E 1.94 5738.5 N 78.17 E 3.47 5805.7 N 78.15 E 2.20 5871.8 N 78.16 E 0.38 5936.2 N 78.16 E 2.10 7 9000 36.30 6184.4 6062.4 7 9100 33.45 6266.4 6144.4 7 9126 32.98 6288.1 6166.1 X 9240 32.98 6383.8 6261.8 5995.9 N 78.60 E 6053.1 N 81.65 E 6067.3 N 82.75 E 6129.3 N 82.75 E 1230.6 N 1240.4 N 1242.3 N 1250.2 N 5869.7 E 5926.0 E 5940.1 E 6001.7 E 5997.3 N 78.16 E 2.76 6054.4 N 78.18 E 3.00 6068.6 N 78.19 E 2.20'-''' i 6130.5 N 78.23 E 0.00 'Survey Codes: 7/GYRO X/EXTRAPOLATED KRU 1L-10 (29-11-10) Page 5 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL o6/26/9o 8UBSEA MEAS BKB MD-TVD VERT DEPTH DEPTH DEPTH DIFF CORRECT 0 122 122 0 0 100 222 222 0 0 200 322 322 0 0 300 422 422 0 0 400 522 522 0 0 RELATIVE COORDINATES FROM WELL HEAD 0.11 N 0.16 E 0.13 N 0.47 E 0.14 N 1.03 E 0.54 S 2.11 E 4.87 S 4.77 E 500 622 622 0 0 600 723 722 1 0 700 823 822 1 1 800 924 922 2 1 900 1026 1022 4 1 12.31 S 8.11 E 20.17 S 12.75 E 27.87 S 19.19 E 35.26 S 29.36 E 42.27 S 44.74 E 1000 1129 1122 7 3 1100 1234 1222 12 6 1200 1342 1322 20 8 1300 1455 1422 33 13 1400 1578 1522 56 23 48.52 S 68.50 E 52.93 S 102.44 E 42.78 S 135.79 E 49.91 S 194.59 E 40.69 S 265.19 E 1500 1713 1622 91 36 1600 1855 1722 133 41 1700 2008 1822 186 53 1800 2178 1922 256 70 1900 2359 2022 337 81 26.31 S 355.63 E 8.79 S 453.67 E 15.04 N 566.95 E 48.40 N 700.85 E 98.79 N 842.83 E 2000 2536 2122 414 77 2100 2703 2222 481 67 2200 2873 2322 551 70 2300 3049 2422 627 76 2400 3222 2522 700 73 139.63 N 177.22 N 219.63 N 252.40 N 279.27 N 983.31 E 1112.18 E 1242.60 E 1383.55 E 1522.08 E 2500 3395 2622 773 74 310.33 N 1660.84 E KRU 1L-lO (29-11-10) Page 6 06/26/90 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL SUBSEA MEAS BKB MD-TVD VERT DEPTH DEPTH DEPTH DIFF CORRECT 2600 3561 2722 839 65 2700 3725 2822 903 64 2800 3892 2922 970 67 2900 4062 3022 1040 70 3000 4227 3122 1105 65 RELATIVE COORDINATES FROM WELL HEAD 334.52 N 359.20 N 381.16 N 406.65 N 430.74 N 1790.26 E 1918.49 E 2050.56 E 2185.88 E 2314.31 E 3100 3200 3300 3400 3500 4387 3222 1165 60 4551 3322 1229 64 4715 3422 1293 65 4880 3522 1358 64 5041 3622 1419 62 460.44 N 477.47 N 492.19 N 486.26 N 536.00 N 2435.43 E 2564.43 E 2694.59 E 2822.04 E 2947.43 E 3600 3700 3800 3900 4000 5204 3722 1482 63 5367 3822 1545 63 5532 3922 1610 65 5696 4022 1674 64 5857 4122 1735 61 549.10 N 570.91N 589.34 N 601.52 N 634.28 N 3076.08 E 3203.35 E 3333.20 E 3461.73 E 3584.64 E 4100 4200 4300 4400 4500 6018 4222 1796 62 6182 4322 1860 64 6342 4422 1920 60 6501 4522 1979 59 6662 4622 2040 61 663.32 N 689.31 N 717.93 N 747.75 N 775.30 N 3708.35 E 3835.29 E 3957.31 E 4077.20 E 4199.90 E 4600 4700 4800 4900 5000 6824 4722 2102 62 6989 4822 2167 64 7150 4922 2228 61 7306 5022 2284 57 7464 5122 2342 58 808.58 N 836.58 N 878.35 N 900.60 N 926.38 N 4323.61 E 4450.92 E 4569.38 E 4689.21 E 4808.70 E 5100 7621 5222 2399 57 961.66 N 4924.95 E KRU 1L-10 (29-11-10) Page 7 06/26/90 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL SUBSEA MEAS BKB MD-TVD DEPTH DEPTH DEPTH DIFF 5200 7772 5322 2450 5300 7923 5422 2501 5400 8075 5522 2553 5500 8223 5622 2601 5600 8372 5722 2650 VERT CORRECT 51 51 52 48 49 RELATIVE COORDINATES FROM WELL HEAD 992.01 N 1024.54 N 1043.68 N 1089.95 N 1126.90 N 5033.41 E 5141.90 E 5253.19 E 5356.01 E 5459.85 E 5700 8519 5822 2697 5800 8658 5922 2736 5900 8791 6022 2769 6000 8922 6122 2800 6100 9046 6222 2824 47 38 34 30 25 1167.03 N 1207.30 N 1205.74 N 1222.66 N 1250.44 N 5556.72 E 5632.08 E 574O.63 E 5822.53 E 5884.23 E 6200 9166 6322 2844 2O 1245.11 N 5961.91 E 3~U 1L-10 (29-11-10) Page 8 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL 06/26/90 MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES CLOSURE DL/ DEPTH g. lqOLE BKB 8UB-S DIST BEARING FROM-WELI.~IEiI~ DIST BEhR. ING 100 1000 10.17 997 875 32 S 67.86 E 41 S 2000 51.50 1817 1695 554 N 78.01 E 14 N 3000 55.85 2394 2272 1367 N 75.49 E 239 N 4000 54.11 2985 2863 2173 N 80.01 E 398 N 5000 51.86 3596 3474 2964 N 79.97 E 524 N 40 E 57 S 44.80 E 2.6 561 E 561 N 88.56 E 3.4 1346 E 1367 N 79.95 E 1.2 2136 E 2173 N 79.45 E 0.5 2917 E 2964 N 79.81 E 0.3 6000 51.89 4211 4089 3753 N 77.72 E 661 N 7000 52.77 4829 4707 4538 N 75.66 E 842 N 8000 49.18 5472 5350 5300 N 73.54 E 1041 N 9000 36.30 6184 6062 5996 N 78.60 E 1231 N 3694 E 3753 N 79.86 E 0.2 4459 E 4538 N 79.30 E 0.3 5197 E 5301 N 78.67 E 0.4 5870 E 5997 N 78.16 E 2.8 by GREAT LAND DIRECTIONAL DRILLING, INC. for Gyrodata Services, Inc. 06/26/90 Client .... : ARCO ALASKA, INC. Field ..... : KUPARUK RIVER UNIT Well ...... : KRU 1L-10 (29-11-10) Section at: N,79.38,E Surveyor..: AL KUDRLE Computation...: RADIUS OF CURVATURE Survey Date...: 06/06/90 RKB Elevation.: 122.00 ft Job Number .... : AK0690G230 INTERPOLATED MARKERS REPORT Surface Location: 164 NSL 216 EWL S29 TllN R10E MARKER MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES IDENTIFICATION DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD KB 0 0.00 0 -122 0 N 0.00 E 0 N 0 E 9-5/8" CASING 5137 52.06 3681 3559 3072 N 81.41 E 541 N 3024 E TOP KUPARUK C 8702 41.51 5955 5833 5806 N 78.42 E 1192 N 5683 E BASE KUPARUK C 8777 41.23 6011 5889 5855 N 78.51 E 1202 N 5732 E TOP KUPARUK A 8908 38.83 6111 5989 5940 N 78.12 E 1219 N 5815 E BASE KUPARUK A 9020 35.73 6201 6079 6008 N 79.21 E 1233 N 5881 E PBTD 9144 32.98 6303 6181 6077 N 82.75 E 1244 N 5950 E 7" CASING 9224 32.98 6370 6248 6121 N 82.75 E 1249 N 5993 E TD 9240 32.98 6384 6262 6129 N 82.75 E 1250 N 6002 E <Y,t~>o .-- A T 600 1200 · - Gp ak L,nY Bjpe£kional DpY ?'ng £nc. '/ERTICAL SECTION VIEW &~co ALASKA. INC. T'/D Scale.' I inch : 1200 feet Dap Scale.: I inch = 1200 feet ?awn ..... : 06/26/90 . HD TVD SECTN INCLN 0 0 0 0.00 5137 368! 3072 52.06 8702 5955 5806 41.5t 8777 601! 5855 41.23 BgOB 61t! 5940 38.83 9020 620t 6008 35.73 9i44 6303 6077 32.98 9224 6370 6t2t 32.98 9240 63B4 !6129 ~2.gB Marker Identification A} KB B} 9-5/8" CASIN~ ~ TOP KUPARUK C D) BASE KUPARUK C ~ TOP KUPARUK A F) BASE KUPARUK A m PBTD ~ 7' CASIN~ :SO0 -- 2400 .- 3000 - 3600 . 4200 .-- 4800 5400 -- 6000 "- 6600 ; .... ~ ............... ~ ...................................... ; 600 o 600 i2oo ieO0 2400 3000 3600 4200 4eO0 ~400 6000 Section DepartuPe 3,.~' WELL NAME ............................................................. ~:6'~--~-E-o~-6~c.~.L- MATE RIALS I NVE NT'0 R-Y [ ~heck off or li~ data as it is re}eived 407"i / o///~ ...... [,, ,ddll~n9 hist.~ .... s~eY'"! ~ well eared i,,t~,,~a,~s , ,, ,,, ,, ~;,~ ~ , ,,, ,, ,,,,,, , .... ,,,,~ , , ,,, ,, , , ,, i, I I ....... ~ .............. I , , , I,,, , ,, I ....... LOG TYPE ' ' RuN ' INTERVALS ' SCALE z~ ~,,~/~. ~/F~. ./ - ~ I ~/~ ' - ?~ . ~/ ' ~ " v ~ " U -i 7} ARCO Alaska, Inc. Date: June 22, 1990 oil ..aas Cons Commi--.- ~nchorage' ~ion Transmittal ~: 7793 RETURN TO: ARCO Alaska, Inc. ATTN: Jenny Gamage Kuparuk Operations File Clerk ATO-111 9 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. signed copy of this transmittal. 1 Y-30 Pulse Echo Cement Evaluation 1 L-1 0 Pulse Echo Cement Evaluation 2 K- 1 0 Tracer Chek 2 C- 1 3 Experimental NORM Tracerscan Please acknowledge receipt and return one 6-5-90 8345-9164 5-31 -90 7087-9122 6-2-90 6350-6555 5-24-90 6895-7075 Receipt Acknowledged: Date: DISTRIBUTION: Drilling NSK ,of Alaska(+sepia) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 0 APPLICATION FOR SUNDRY APPROVALS Operation Shutdown .~ Re-enter suspended well _ Plugging _ Time extension _ Stimulate _ Variance Perforate Other 6. Datum elevation (DF or KB) 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well _ Change approved program _ Pull tubing _ 99510 5. Type of Well: Development Exploratory Stratigraphic Service 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 4. Location of well at surface 164' FSL, 216' FWL, Sec. 29, T11N, R10E, UM At top of productive interval 1219' FSL, 621' FEL, Sec. 28, T11N, R10E, UM (approx) At effective depth 1292' FSL, 907 FWL, Sec.28, T11N, R10E, UM (approx) At total depth 1243' FSL, 3856' FEL, Sec. 28,T11N, R10E, UM (approx) 9241' feet Plugs (measured) 6389' feet None RKB 122' 7. Unit or Property name Kuparuk River Unit 8. Well number 1L-10 9. Permit number 90-35 feet 12. Present well condition summary Total Depth: measured (approx) true vertical 91 44' feet Junk (measured) 63 09' feet None 13. Effective depth: measured (approx) true vertical Casing Length Size Cemented Structural 8 0' 1 6" Conductor Surface 5014' 9 5/8" 1100 Sx AS III & Intermediate 460 Sx Class G Production 8738' 7" 250 Sx Class G Liner Perforation depth: measured true vertical None 10. APl number 50-029-22026 11. Field/Pool Kupurak River Field/ Kuparuk River Oil Pool Measured depth True vertical depth 115' 115' 5136' 3676' (approx) 8860' 6089' (approx) Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None Attachments Description summary of proposal _ 14. Estimated date for commencing operation June, 1990 16. If proposal was verbally approved Date approved 15. Detailed operation program ;~ BOP sketch Status of well classification as: Oil X Gas m Suspended Name of approver Service IIAppr°val No?~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ?~ ~-~~ Title Area Drilling Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require 1 Commissioner Approved Copy Date ~,~'/~0 SUBMIT ~N TF~PLICATE Approved by the order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED 6¥ LONNIE C. SMITH ARCO Oil and Gas Company Well History - Initial Report - Daily Inatructions: Prepare and submit the "lnitill RIl~orl" on the first Wednesday alto; a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive datea only. Dist riot I County. parish or borough ARCO ALASKA INC_. _ - ' ~ t NORTH SLOPE - Field - - ILease or Unit KUPARUK RIVER I ADL: 25660 ALK: 470 JTitle DRILL/NG Auth. or W.O. no. . _ State I Weil no. KR~ 1L-10 Operator ARCO W.I. ARCO 55.8533 Spudded or W.O. begun IDate IHour Pr or status if a W.O. SPUD I 03/14/90 I 17:30 Date and depth as of 8:00 a.m. 03/15/90 (1) TI): 1230' ( 123 SUPV: JP 03/16/90 (2) TD: 4180' ( 295 SUPV: JP 03/17/90 (3) TD: 5155'( 97 SUPV:JP 03/18/90 (4) TD: 5155'( SUPV:JP 03/19/90 (5) TD: 7300'( 214 SLT~V:JP 03/20/90 (6) TD: 8405' ( 110 SUPV: JP 03/21/90 { 7) TD: 9188'{ 78 SUPV:~T~ 03/22/90 (8) TD: 9241' ( 5: SUPS/: CD 03/23/90 (9) TD: 9241'( SUPV:CD iComplete record for each day reposed DOYON 14 DRLG MW: 9.8 VIS: 63 MOVE FROM KRU STATE 2, NU DIVERTER, TIH, DRLG, POOH TO CHECK MWD, RIH, DRLG. ~ DAILY:S188,249 CUM:$188,249 ETD:S188,249 EFC:$0 DRLG MW:10.1 ViS: 57 DRLG, CIRC. OUT GAS AT 1380 AND 1703, INCREASE MUD WT FROM 9.8 TO 10.0. DAILY:S68,371 CUM:$256,620 ETD:S256,620 EFC:$0 CIRC MW:10.2 VIS: 51 DRILL FROM 4180 TO 4584,DROP SURVEY, POOH,TIP OF NOSE CONE GONE, RIH, WORK BY JUNK, CIRC. OUT THICK MUD,DRILL FROM 4584 TO 5155,CIRC BU, SHORT T~IP,POOH, CIRC DAILY:S56,434 CUM:$3i3,054 ETD~$313,054 EFC:$0 MU BHA#2 9-5/8"@ 5136' MW:10.1 VIS: 43 POOH, RUN CSG AND CMt W/1100 SX AS III & 460 SX CLASS G, ND DIVERTER, RUBOPE, TEST SAME, PU BHA#2. DAILY:S196,078 CUM:$509,132 ETD:S509,132 EFC:$0 DRLG 9-5/8"@ 5136' MW: 9.1 VIS: 36 MU BHA, TIH, TEST CSG, CUT DRILL LINE,DRILL FLOAT, TEST FORMATION, DRLG 5165-7300. DAIL~:$~9,138 . CUM:$568,270 ETD:S568,270 EFC:$0 MU BHA 9-5/8"@ 5136' MW: 9.5 VIS: 38 DRILL F/7300-8405, CBU, POH TO CSG SHOE, PERFORM LOT TO 11.1 EMW - OK, POH, MU BHA, DROPPED BIT WHILE MU BHA, RECOVERED BIT IN RISER, CONT. MU BHA DAILY:S66,947 CUM:$635,217 ETD:S635,217 EFC:$0 DRLG AT 9188 9-5/8"@ 5136' MW:10.8 VIS: 44 CONT. TIH, REAM F/8356-8405, DRILL F/8405-9188 DAILY:S79,752 CUM:$714,969 ETD:S714,969 EFC:$0 RIH FOR WIPER TRIP 9-5/8"@ 5136' MW:10.9 VIS: 41 DRLG, SHORT TRIP,SWAB WELL, CIRC OUT GAS,SHORT TRIP, CIRC, POOH, LOG, RIH FOR WIPER TRIP DAILY:S112,520 CUM:$827,489 ETD:S877,496 EFC:$-50,007 LOGGING 9-5/8"@ 5136' MW:10.9 VIS: 40 CUT DRLG LINE, RIH TO CIRC.,POOH, RUN LOGS WITH HLS. DAILY:S114,167 CUM:$941,656 ETD:S991,663 EFC:$0 The above is correct Drilling, Pages 86 and 87. they are prepared for each well. iPage no. AR3B-459-1 -ID ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on 'Final" form. 1) Submit "lnlerlm' sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting ol oil strin; until completion. District Field J County or Parish State Lease or Unit IWe~l no. - ' ADL: 25660 ALK: 470 KRU ~L-10 Complete record for each day while drilling or workover in progress DOYON 14 Date and depth as of 8:00 a.m. 03/24/90 { 10 TI): 9241' { SUPV-- CD RUN CASING 9-5/8"@ 5136' MW:10.9 VIS: 42 CONTINUE LOGGING, TIH FOR WIPER TRIP,REAM, POOH LDDP,RUN 7" CSG. DAILY:S166,713 COM:$1,108,369 ETD:S1,158,376 EFC:$0 The above is correct For form preparati{;~and distribution see Procedures Ma~al Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B Number all daily well hislory forms consecutively as hey are prepared Ior each well. IPage no. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Rel3~rt" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "FInsl Report" form may be used for reporting the entire operation if space is available. District AI~CO ALASKA INC. ! NORTH SLOPE KUPARUK RI _VER ............. I..._ ADL: 25660 ALK: 470 fAccounting State AK cost center code IWell no. AK4176 I ..... DRILLING Iotal number of wells (active or inactive) on this est center prior to plugging and [ bandonment of this well I our I Prlor status if a W.O, I 17:30 Operator A.R.Co. W.I. ~CO 55. 8533 Spudded or W.O. begun Date SP~D 03/14/90 Date and depth Complete record for each day reported as of 8:00 a.m. DOYON 14 03/25/90 (11) TD: 9241 PB: 9144 SUPV: CD Old TD New TD Released rig RIG RELEASED 7"@ 8860' MW: 0.0 RUN CASING, CIRC, CEMENT CASING W/250 SX CLASS G,ND BOPE, RELEASED RIG ON 25-HAY-90 @ 01:30. DAILY:S203,741 CUM:$1,312,110 ETD:S1,362,117 EFC:$0 Date PB Depth K nd of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc,) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P, Water % GOR Gravity Allowable Effective date corrected The abov~,~s correct Date Drilling, Pages 86 and 87. AR3B-459-3-C Number all dally well history forms consecutively no. they are prepared for each well. j Page as Division of Allantlcl~lchfleldC~mpaa¥ ARCO Alaska, Inc. Date: April 12, 1990 Transmittal #: 7724 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK Transmitted herewith are the following items. one signed copy of this transmittal. · ,., . 1 L-e-9' High Resolution Induction DFL 2"-Corrected · , .. Please acknowledge receipt and return 3-22-90 8470-9228 Receipt Acknowledged: DISTRIBUTION: D&M Drilling Franzen RECEIVED ..... ~i:;/~ ~ z ~9~o Alaska Oil & Gas Cons. Commission Anchorage Vendor Package(Johnston) NSK ~ iState of Alaska(+Sepia) Halliburton Logging Services An hor'age, AK 417/90 RE: Corrected copies of 1L-10 High Resolution Induction An advance copy of the corrected High Resolution Induction (HRI) from ARCO Kuparuk 1L-10 is enclosed. Final prinls of this version marked "CORRECTEIT' as well as LIS tapes of the HRI data only will be distributed via normal channels. The High Resolution Induction measures two inductance components, the traditional ~f' signal and the ~' signal, which conl~ains the bulk of the high resolution information. The X signal is many times smaller than the R and the measurement process difficult in high resistivity environments. On 1 L-1 O, errors of 2 mmhos on the medium and 6 mmhos on the deep were uncoYered using a new processing technique called'AUTO X Corr~n. This program will soon be available on the truck for use in real time. Results from this algorithm will match the log you now see. We apologize for any inconven~nce this may have caused and look forward to offering the AUTO X correction program in the very near future. Until a point of confidence is reached with the High Resolution tool, we will continue to offer the normal Dual Induction instead. Regards, Mike Walker Alast(a Oil 8, e~as Co~s. C, ommisston Anchorage ARCO Alaska, Inc. Date: April 12, 1990 Transmittal #: 7725 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1 L- 1 0 LIS Tapes and Listing 3 - 2 2 - 9 0 HRI Corrected ~ ~/¢~ .~ Receipt Acknowledged: ............................. Date: APR 17 1990 Nas[~Ott &-Sas Cons. commisston Anchorage DISTRIBUTION: Lynn Goettinger ~ State of Alaska ARCO Alaska, Inc. Date: April 4, 1990 Transmittal #: 7713 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1 L- 1 0 LIS Tape and Listing 3-22- 90 SDL/DSN/ML Receipt Acknowledged: DISTRIBUTION: Lynn Goettinger State of Alaska ARCO Alaska, Inc. Date: April 4, 1990 Transmittal #: 7714 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1 L-1 0 Microlog Caliper 3-22-90 8370-91 98 1 L- 1 0 Spectral Density-Gamma Ray 3 - 2 2 - 9 0 8 3 70 - 92 00 1 L - 1 0 Rotary Sidewall Core 3 - 2 3 - 9 0 8 6 89 - 91 50 1 L- 1 0 Spectral Density-Raw Data 3 - 2 2 - 9 0 8 3 70 - 92 0 0 1L-10 Spectral Density-Porosities 3-22-90 8370-9200 1 L - 1 0 High Resolution Induction 5" 3 - 2 2 - 9 0 8 3 70 - 92 2 8 1 L-1 0 High Resolution Induction 2" 3-22-90 8370-9228 RECEIVED Receipt Acknowledged: APR - ~ 1990 Date' '~' ,~aska 0il & 6as Cons. C0mmissi¢~: Anchorage DISTRIBUTION: D&M Drilling Franzen Vendor Package(Johnson) NSK State of Aiaska(+Sepia) ARCO Alaska, Inc. Date: March 28, 1990 Transmittal #: 7706 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. I L-10 2" Dual Induction- SFL 3-22-90 876-9230 I L- 1 0 5" Dual Induction- SFL 3 - 2 2 - 9 0 876 - 9230 1L-10 2" and 5" Raw FDC 3-22-90 5136-9206 1 L- 1 0 5" Cyberlook 3 - 22 - 9 0 8590 - 911 0 I L- 1 0 2" and 5" Porosity FDC 3 - 2 2 - 9 0 5136 - 9206 1 L- 1 0 Dual Gamma Ray Electromagnetic 3 - 2 - 9 0 51 55 - 9241 Wave Resistivity Receipt Acknowledged: DISTRIBUTION: ............................. Date: D&M Drilling Franzen RECEIVED Alaska 0il & Gas Cons. C0mmissi0.[~ Ar~chorag~ Vendor Package(Johnson) NSK State of Alaska(+Sepia) ARCO Alaska, Inc. Date: March 28, 1990 Transmittal #: 7707 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1 L - 1 0 LIS Tape and Listing 3 - 2 7 - 9 0 5 1 3 6 - 9 2 4 1 Receipt Acknowledged: ............................. Date OISTRIBUTION: Lynn Goettinger State of Alaska $'I'^TE OF AL^~KA ALASKA OIL AND GAS CONSE'RVATION COI~I$$10N BOP[ Intpec~ton Report Clinoril housekeeptng Reserve pit: .. ~ ~UD~ SYSTENs[ Vt sual ..Audio Trip tank ___._ _. Z,.-.-- J ~ P~t gauge ....... _7..-,'-- I ~ ~. _ ,.i ~.~ de~.:~r, ~ I -~ --_ ..... Pipe rmml ~lind rems ~hOke line valves HCR valve Kill line valve~ Cheek velvl .T, ~ST P~.3ULTS, Rlmlrkm/ _ -l Pull charge presmure _..~_.(~q~O ., pmig Pra~s after :losure ,, ~7OC) .... p~tg pump tncr clem press 200 piig :_ mtn_~L~see Full ohorge pre~s attained .--...~.~mtn ~ P_! _c~_: Z~_o; ~oo(8.iSn p,~ __ Control~ Has~°r Blind ewi:~h cover Upper Kelly llmb prflsurt .... Bell typ. J tilt premium IMidm BOP Tilt geemmurI. Choke man4fold J' Tilt prllturm Number vllvel ,, I ~' . ,- Numbmr flanges ~(~ ...... _ ^dJ~ltable ohokee , J . C)~.l ....... Repair or replaeemenl; of fm(led equipment to be mmda within /th.zsA-a Oil g (Jas Cons. Commission Anchorag~ Or(g - AOGCC Operator Supervisor Inm~lc~orl C.OO~ (r.v March 5, 1990 Telecopy No. (907) 276-7542 P J Archey Area Drilling Engineer AR. CO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 1L-10 ARCO Alaska In¢ Permit # 90-35 Surf Loc 164'FSL, 216'FWL, Sec 29, TllN, R10E, UM Btmhole Loc 3964'FNL, 4195'FEL, Sec 28, TllN, R10E, UM Dear Mr Archey: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. To aid us in scheduling field work, please notify this office 24 C' hours prior to commen lng installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. C V Chatterton Chairman Alaska Oil and Gas Conservation Commission BY O~ER OF THE COMMISSION jo Enclosure Department of Fish & Game, Habitat Section - w/o encl Department of Environmental Conservation - w/o encl STATE OF ALASKA ALA,.,,,A OIL AND GAS CONSERVATION COMMISo~ON PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill -- I lb. Type of Well Exploralory__ Stratigraphic Test _ Development Oil .~X Re-Entry _ Deepen --I Service _ Development Gas __ Single Zone .2L Multiple Zone _ ?_. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 122. Pad 86' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25660 ALK 470 4. Location of well at sudace 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 164' FSL, 216' FWL, Sec. 29, T11N, R10E, UM Kuparuk River Unit At top of productive interval (TARGET) 8. Well number Number 4004' FNL, 4410' FEL, Sec. 28 , T11N, R10E, UM 1L-10 #U630610 At total depth 9. Approximale spud date Amount 3964' FNL, 4195' FEL, Sec 28, T11N, R10E, UM 03-05-90 $2O0,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1L-08 9209 MD 925' @ TD feet 60' at SURFACE feet 2560 6330TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 400 feet Maximum hole angle 51 o Maximum surface 2180slg At total depth (TVD) 6287' 3490 psig 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length IVD 'I'VD IVD TVD (include stage dataI 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' ±200 CF 12.25 9.625 36.0# J-55 BTC 4972' 35' 35' 4972 3680' 1100 Sx AS III & ~-~.Rw 460 Sx Class G 8.5 7" 26.0# J-55 BTC 9209' 35' 35' 9209' 6330' 200SxClassG ~-~.l~W Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured true vertical feet Casing Length Size Cemented Measured depth True Vertical depth (~t°rnUdC::[°al R ECE iV E D Surface Intermediate ProductionMAR - 2 1990 Liner Alaska 011 & Gas Cons. Perforation depth: measured true vertical 20. Attachments Filing fee X Property plat __ BOP Sketch ~ Diverter Sketch ~ Drilling program ~ Drilling fluid program ~ Time vs depth plot __ Refraction analysis _ Seabed report _20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~,/~c~ ~ ~-~'~-C~-/ Title Area Drillincj Encjine;r Date / Commission Use Only Permit Number I APInumber I Approval ~)a~e/ I See cover letter for ~:~(~ ,- ~,-~,~ 50- (~ 2.- ~?- ~ Z C/Z ~" 0 5 / 9 0 other recluirements Conditions of approval Samples required wY e s ,~ N o Mud log required m Y e s ~ N o Hydrogen sulfide measures m Yes ~ N o Directional survey required .,z~'Yes m N o Required working pressure for BOPE .__2M- _~ 3 M' 5 M' 1~ M' 1 5 M by order of Approved by ~. ~ ,. ~' , ~ . ~?'~,/~/_~//~ Commissioner the commission Dale Form 10-401 Rev. 7-24-89 /,' in triplicate / GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 1L PAD o . , . . , , . , 10. 11 12 13 14 15 16 17 18 19 20 Move in and rig up Doyon 14. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. note: The surface casing for all wells will be set deeper than the field rules of 3000' to cover the West Sak formation. ¢O'"~ .~,,,-~o,'~,,~ ,~',. ~,?,;~ Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test. Drill 8-1/2" hole to logging point according to directional plan. Run open hole evaluation logs or RLL as needed. Run and cement 7" casing. Pressure test to 3500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Change over to diesel Shut in and secure well. Clean location and release rig. Fracture stimulate well. Naska 0ii & G~S Co~s. 21 Reperforate and add additional perfs. DRILLING FLUID PROGRAM (1L-10) Spud to 9-5/8" Drill out to Weight up surface casing weight up to TD Density 9.0-9.6 8.6-9.4 10.6 PV 15-30 8-10 10-16 YP 20-40 5-8 7-1 2 Viscosity 70-80* 35-40 35-50 Initial Gel 5-15 2-4 4-8 10 Minute Gel 1 5- 30 4 - 8 5-1 2 APl Filtrate 10-15 7-9 4-5 pH 9- 1 0 8.5-9 8.5-9.5 % Solids 10 +/- 4- 7 <12 Drilling Fluid System: - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators RECEIVED MAR - 2 1990 Alaska 0il & Gas Cons. Commisst~ltl Anchorage Notes: - Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. - Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2180 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 1L-10 is 1L-08. As designed, the minimum distance between the two wells would be 60' at surface. The wells would diverge from that point. Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. * Spud mud should be adjusted to a funnel viscosity between 100-120 to drill gravel beds. 400 _ 350 _ 3uO _ 250 _ 200 _ 150 _ 100 150 200 I , ,, 250 300 350 400 450 ,500 5.50 I I I I I I / 1300 ~'~00 2500 -'"900 - ~ '~700 - ~oo ~/...~~ ~ _ _ _ _ - ~ noo I ~ ~ ~00 ,'Xo~-w°° I , , 150 200 2 50 300 350 400 450 500 550 400 350 300 250 200 15C 100 · . . ARCO ALASKA. Inc. Pad .1L. Wal I No, 10 Kuparuk Field,. North ~,opoaed .ope, Alaaka 1 000 _ 2000_ 3000 _ 4000 _ 5000_ 6000_ 7000 RKB ELEVATION, 125' RECEIVED KOP 3 g 15 21 TVD=400 THD-,400 DEP'=O BUILD 3 DE~O PER 100 FT MAR - 2 1990 Oil & Gas .Cons. Commissio~ ~cfiorage 27 ,3,3 B/ PERMAFROST TVD=I 525 TMD=I 603 DEP=367 39 ~'551 EOC TVD=1890 TMD=2110 DEP=?16 T/ UONU SNDS TVD-2425 TMD=2965 DEP=1383 T/ W SAK SNDS TVD=3015 TMD-3g08 DEP=2119 AVERAGE ANOLE 51 DEG 18 HIN B/ 14 SAK SNDS TVD=3480 TMD-4652 DEP=2699 g 5/8' CSO PT TVD-3680 THD=4972 DEP-2949 K-lO TVD-3875 TMD=5283 DEP-3192 K-5 TVD=5Og5 TMD=7234 DEP=4715 T/ ZONE C TVD=5955 TMD=8610 DEP=S?88 T/ ZONE A TVD=6t05 TMD=8849 DEP=5975 TAROET CNTR TVD=6155 TMD=Sg2g DEP=6037 B/ KUP SNDS TVD=6205 THD=9009 DEP=6100 TD (LOC PT) TVD=6330 THD=9209 DEP=6256 I [ [ i 1000 2000 3000 4000 VERTICAL SECT[ON I 5000 I 60OO I 7000 HORIZONTAL PROJECTION SCALE 1 IN. = 1000 FEET z o ~000 2000 1 000 I 000 ARCO ALASKA, Inc. Pad lt. Well No' 10 Kuparuk FI eld. North Proposed Slope. Alaska ~ ooo 0 SURFACE WEST-EAST 1 000 2000 3000 4000 5000 6000 t I I I I I 7000 ,I TAROET CENTER TVD=6155 TMD=8929 ~ DEP=6037 ~, '~ NORTH 1112 EAST 5934 TD LOCAT I ON, 3964' FNL. 4195' FEL SEC. 28. TIlN. RIOE SURFACE LOCAT [ ON, 164' FSL. 216' FWL SEC. 29. TI1N. R IOE TARGET LOCATION, ,~004' FNL. ,4.,4.10' FEL SEC. 28. T11N. R1OE N 7'9 DEC 2~3 HINE 60JT' (TO TARGET) 7 , 6 5 4 13 5/8" 5000 F,.,I BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECKAND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TESTALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTORAND MANUAL KILLAND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMSAND CLOSE Bo'FrOM PIPE RAMS. TEST BOq-I'OM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMSAND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8"- 5000 PSI SPACER SPOOL 4. 13-5/8"-5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR SRE 8/22/89 DOYON 14 KUPARUK RIVER UNIT __ 20" DIVERTER SCHEMATIC .I L DESCRIPTION 1. 16' CONDUCTOR 2. FMC SLIP~3N WELD STARTING HEAD 3. FMC D IVERTER ASSEMBLY wrrH TWO 2-1/16' 2000 PSI BALL VALVES 4. 20' 2000 PSI DRILLING SPOOL W/10" OUTLETS 5. 10' HCR BALL VALVES W/10' DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTF. I~ VALVES CAN BE REMOTELY CONTR~ i I=n TO ACHIEVE DOWNWIND DIVERSION. 6. 20' 2000 PSI ANNULAR PREVENTER ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS D~VERTER SYSTEM AS A VARIANCE FROM 20AAC2S.0aS(b) MAINTENANCE & OPERATION 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES REC£iVED MAR - 2 1990 0il & Gas Cons. (,,ommiss~¢-' JG 4/26/88 CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE Fe----~ '~/C ~ (2) Loc (2 thru (8) (3) Admin ~dr f/p//~ o -(9 ~thru -1-3~-' ' (10 and 13) . (4) (14 thru 22) Company/~_~ 1. Is the permit fee attached .......................................... 2. Is well td be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... e 10. 11. 12. 13. (5) BOPE (23 thru 28) 14. 15. 16.¸ " 17. 18. 19. 20. 21. 22. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... Lease & Well No. ,z~ YES NO Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... ,~ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. ,~ Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ 23. 24. 25. 26. 27. 28. Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~OO~> psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (6) Z'Zc '(29 thru 3'1~ (6) Add: ~.~. 3-2-9o Geology: Engineering: rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. , INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE , Additional Remarks: 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. * HHHH *HHHH HHHH HHHH HHHH HHHH H H A L HHHH HHHH H H A~ L L HHHHHHHHHHH HHHH A A L L HHHHHHHHHHH H H AAAA L L HHHH HHHH H H A A LL LL HHHH HHHH L 0 G G I N G L I BBB U U RRRR TTTTT 0 N N I B B U U R R T 0 0 NN N I BBBB U U RRRR T O 0 N N N I B B U U R R T O 0 N NN I BBBB U R R T O N N S E R V I C E S , I N C . * . ******************************************************************************** * * * * * L.I.S. TAPE VERIFICATION LISTING * ******************************************************************************** ** REEL HEADER ** SERVICE: NAME; GO/DDL D A T E 9 ',"; 10411 ~") OR I G I N DENV REEL NAME ARCOR1 CONTINUATI[tI"4 NUMBER _1. PREVIOUS REEL COMMENTS ** TAPE HEADER ** SERVICE NAME COMCEN DATE 00 / OO/0(} OR I G i N DENV TAPE NAME O CONT II'.tUAT i ON NUMBER 1 PREVI , :o O u,...:, TAPE ~'% ('"[ ~¢1 t¥1 ~:' ~, ! ~F ~:' *********************************************************************************** *** TAPE END OF FILE MARK ********************************************************************************** ** F:ILE HEADER F:'ILE NAME SERVICE NAME )])ATE M A X I M U M L E NG T I-.I FILE T'YPE PREVIOUS F'ILE ** INFORMATION RECORDS EET ~A'T'E · - i 0- 9 0 :N 'RU 1L- t ('i ~F-..'CO ALASKA INC. UPARUK RIVER UNIT 64FT FSL 216FT FWL ONG .0 0 0 0 ATI . ("),.'") 0 0 ECT i N OE OUN ORTH c" Fl~="- TAT .: U I'",1 :F:'IN i -:.']:, - 0 2 9 - 2 2 0 2 6 - 0 0 MCKAY RUGEN LAB '7!9 .__, ..... ("~ 0 ()('-~ :*T' .0'.:":, '.:';:, () O. 9 C, 00 i , 0,:"),:":,,:'.;:, -FF'H . -':":'. C', 00 . ,::::, 000 iE iFST '. 5400 iCST ~MC .99 (') 0 'MFB . (')00 (".~ 0000 0000 ~S 5000 6250 DATA FORMAT' RECORD - ENTRY B/_OCKS 0 DATA RECORD TYPE 0 DATUM SPEC I F:' I CAT I ON BLOCK TYPE 28 DATA FRAME SIZEi i i_ O G G I N ~_ D I R E C T I 0 N I = U P , ~:."' ,..~ ~'::' '=,.~, -- _n 0 W t',1 I 0 F"T t .... ~-.~L.. L. 0 G o E F:' T H U I',11 ]" S 0.2500 FRAME SPACING F' + UN I T S .... ! ..'. . ~.. 3A MAv.-, NO I- R~4PIE. c,/RECORT") ******** NULL. T')ATA VALUE F + !Jl',l I T S 68 + REP r'tn.OE .~ ; . ............ 1 P'.~ P, SU~-~-TYPIE C'. T El R M I N A- T 0 R DATA FORMAT RECORD DATUM ~_FECIFICATION BLOCK 5--- -- MNEM TOOL SERVIC:E UNIT AP1 APl API API I=IL SI Z SPL REF' I::'I~(")CFSS C. ODES DEPT 9216. 000 HDCN - 123."1-5. ()0(':, D E F' 'l" 9000. C:, C) 0 H D CN ~L '? 9 =' · , ,, ~.J-..) '7 + G R 86.7 ~. 1 H D F?. S 5 ,, 570 H M F:'. S 5 ,, 59'7 HMCN 1 ~ c".., ,:,, 668 ,_r')F- L ~,' . .,':~ ..... o,:" D E F'T 86 C;C,. 00 () G R HDCN 529. 862 HMCN __~ D E F' T 8400.000 G R HDCN 267 o~'~o . ~,-: ~, H M C N ............ ~. H D R S t.). ()01 :L'74. 846 DFL ,_,*'::. 983 i 17 62C' H,][. F;.'.c, 1 887 t-II'"IF~S 537 /I. 22 DFL '"'" 1 ':'":"= 258. 924 267. 744 H I'1R S ,..., .... :1. ,, 861. H D R S 3. '734 H M R S 3 ,, '735 DFrL 4. 693 END OF:' TAPE: FrILE FINAL DEPTH LEVEL ON FII._E= 8367.750 F"T' ** FILE: TRAILER ** F i L..E NAME COMCEN. 00 :t. S E R V i C E N A M E: () VERSI(]N NUMBER DATE COMCEN MAXIMUM LENGTH i024 FiL. E TYF'E L.D NEXT F:[LE ************************************************************************* *** 'T'AF'E END [DF' FiLE MARK ** TAF'E TRAIL_ER ** SERVICE: NAME DATE 0 R i G I N TAF'E NAME C'. 0 t',.I T I .r,.I LJ A T I 0 I'4 1'.I U M B E R NEXT TA.F'E i"" £'t ~¢1 b,: r.'" h J "t' C:: ,.--.,-.,J ~! /F':.~"-. ! ..=, COMCEN 00 / (] 0 / 00- DENV C) 1 * * TAPE , .,...,-~.,. c.,, SERV]:CE NAME DATE OF(IGIN TAPE NAME · CONT I NUAT I ON I'~d, t~..,c.R PREVIOUS T'APE ~"'~"lv v'-' ~ '1'~_.~ .... .h I1 I~.t:I: ~.,: COMCEN 00 / 00 / 00 DENV I *~* TAPE ~:~'~ OF F'r~ c MARK ************************************* ,,, ~ ~,'~' "~'.r. F i LE HEADER * * F i LE NAME: '-:r'OMCEt"I SERVICE NAME '"' VERSION NUMBER 0 DATIE COMCEN MAX IMUM L=~t~TM~...,,_. ,,, 1(]24 FILE TYPE LO pc,~;'rOUS FILE ; ~ %~... ¥ .i. ~.,= ~.~,THOUT PREDECESSOR FLAG ~'"I It"" "-C2C"" ", ,.:: _.,,_.. C ~ ..... -~ 0 R 0 C K F' 0 U N D j T [Error has occured DATA FORMAT RECORD - ENTRY BLOCKS I 1 66 3 2 7o · 4 1 5 1 66 8 4 68 9 4. z. =; .i. 1 ~ ~. 79 14 ~ ].5 I 66 16 I 66 0 1 66 0 D A T'A R E C 0 Fi: D '1' Y P El; 0 IL) A T U M S F:'E C'. I F' I .., ~..t I I 0 N BI 0 C ~:: T Y P lie 36 D A "1' A F R A M F.:E,_,c:' I Z E i ~ q I'-] r_~ t N G D I R E C'T' I 0 N 1 .-:-~ I F" 25 F: ::' D 0 kll',l 1 C.iP T I CA L L [] G I} E P T'H U N I 'T'Si l"i '"'~"=' ('""~ , ~:: --~ .~.., F R A M E c, P A C I IxlG F + UN I T S 28 MAX NO FI:%]MES/RECORD * * * ;,*'; * * * * NULL ]DA'FA ',,;AL. LIE F + LINIT'S 68 + FIEF'. CODE 1 DSB SUB--TYF:'E ("l TERM I NATOR DATA FORMAl' REC(]RD - DATUM SF'ECIFICA]'ION BLOCK MNEM TOOL DEPT G R I 0 G A P i 0 H D R S 0 0 H P'I M C.', HMRS 0 OHMM 0 HDCN 0 MI;'IIqO 0 HMCN 0 MMHO 0 DF'L.. i 0 OHMM ("; TENS 0 0 D L []ii D (") L_ B O SERVI{SE UNI'F APt APt API API FIL · .., ,.':.FI_ REP F-I'lL. CE,::.,:=, CODI!Ec'',..., 0 F 0 0 4 .t. 68 0 ()() 00 () 00 () 00000 () 0 0 0 0 0 0 0 0 0 DATA Bt_..OCKS f .... '~- 927'?_; ~ E F . . ('; 00 H D C N - _i. 2345. (')00 GR 1 144. 298 DLOD 886. 356 D E P T 9000. ("~ 00 G R 1 DLOD 9:~.~5 ~ ii. 28 D F L 1 20 () 00.00 () END OF TAPE FILE F'INAL DEF:'T'H LEVEL ON FILE= 89(}5.500 FT ** FIt_E TRAIl_ER ** FILE: NAME COMCEN.001 SERVICE NAME () VERS I ON ~,:: im:c,=R 0 MAXIMUM LENGTH 1024 FII...E 'TYPE LO NEXT FILE: *** TAPE END OF FILE MARK ** TAPE TRAILER ** SEF:<VICE: NAME COMCEN D A T E () 0 / 00 / 00 r",R ':'R ~' [",1 DENV TAF'E NAME O CONTINUATION NUMBER 1 NEXT TAI='E COMMENTS * * TAPE HEADIER ::k. ,-:,'~; SERVICE NAME COMCEN D A ]' E 00 / 00 / 00 OR I G I N DENV TAPE NAME 0 C rE) l,,I T I N U A T I 0 f',l N U M B E R 1 PF,'E~., ~.~:[ 01.1.=; TAPE COMMENTS: *** 'FAI='E END OF FILE MAR[::: · , ********************************************************************************** ** FILE HEADER ** i'"' I L E N A M E C O M C E N. (':, O .1. ~=r---":-':'""I._,,_,., -,, CE NAME ,:"3 ,..,~,c:~ ,_, .~., I ON NL.IMBER (':'. DA'T'E COMCEN ,"'lAX I MUM ,.._ ,_ , .., ~,~ r':'~"'R"'""~, -, I ':":'24 F I LE TYPE ,..-u' R PREVIOUS FILE h [.,...,r'-4D W I T'HOUT , , .,_,,... ,__.,_ ....... :RR F'L AG Error has occured , ORP,A,~ .~.=.~,,,~ - ENTRY BL[ .... ~ ..... 0 DATA REiCOF1D TYPE 0 DATUM SPECIFICATION BL. OCK "tYPE' 36 DATA FRAME SIZE' I LOGGING DIREC'T'ION iI=UP,255=DOWN i OPTICAL. LOG DEF'"I"H UNITS 0.2500 FRAME SPACING F' + UN I T S 28 MAX NC] FR~.'ffflES/F(ECORD * * * * * * * * NULL.. DA]"A VALUE F + UNITS 68 + REF'. CO. DE I DSB SUB-TYF'E. £) ]"ERM I NATOR DATA FORMAT -,-r'n,' RE..~,RD - DATUM SPECIFICATION BLOCK MNEM TOOL DEPT 0 F 0 GR2 0 GAP I 0 HDRS 0 OHMM 0 HMRS 0 OHMM 0 HDCN 0 MMHO 0 HMCN ('~ MMHO 0 D F L 2 C, 0 H P'I M 0 TENS 0 0 D L 0 D 0 L. B 0 SERVICE UNIT AP1 AP1 AP1 AF'I FIL '-'3IZ SPL REP I::'ROCESS CODES DATA BLOCKS D E PT 92 !.50. ()00 H D C N - 1 ~._'. 4 ~. 000 DLOD 958. 145 GR'~..~ 98 . 793 HMCN -12345.000 HDRS - 1 ]73'4.5.0(:)0 DF l_..~ 5. 969 D E P T 9000.000 ~ R ~ 8 (] . ~ '~' ._. ~ ~:..° HDCN 18('~ .... . ...,,.~';')9~ HMCN 1 ~, _ , .)~.~, DLOD 969. 104 DEPT 8800.000 GR2 83.425 HDCN 162.978 HMCN 171.279 DLOD 864.984 HDRS ~. p~. o 6 '~" 1 HMRS 5 TENS 55:76 D E P T 860 ('3.00 (} HDCN 529. 181 DLOD '~ 8'""" HDRS 6.136 DFL2 6.991 HMRS '5. 838 ]"EN°,., 5('~4:"]. .. ,, 476 GR2 1'~'~'-.~.. 277 HMCN 537. 606 HDRS 1 . 890 DFL2. 2.140 I-IMR,.. .1. 86(;3 'T'ENS 4739.128 END OF TAPE FILE F I NAL DEPTH._~..~ ::~'~-~. ON F I LE= 84~._'" - ....... ".~50 FT ** FILE TRAILER ** F'ILE NAME COMCEN.001 SERVICE NAME 0 VERSION NLiMBER 0 DATE COMCEN MAXIPIUM LENG]"H 1024 FILE TYPE LO NEXT FILE *********************************************************************************** *** TAPE END OF FIt_E MARK *********************************************************************************** ** TAPE TRAIL. ER ** SERVICE NAME DATE ORIGIN TAPE NAME CONTINUATION NUMBER NEXT TAPE COMMENTS COMCEN o., o., ,,' 00 / 00 DENV 0 1 ** REEL TRAILER ** SERVICE NAME DATE ORIGIN REEL NAME CONTINUATION NUMBER GO/DDL 90/04/10 DENV ARCOR1 .1. *** TAPE END OF FILE MARK MAXIMUM LI~,_, BYTE. ~r-n/l~'~,~., ~, ~^C._E,.E[,r- v '".= -.~) .' "-, (, BY]"ES ) Error has occured LOGICAL BYTE COUNT EXCEEDS PHYSICAL BYTE COUNT PHYSICAL COUNT= * LOGICAL COUNT= Error has occ:ured *** TAPE END OF FILE MARK 32768 ******************************************************************************** *** END OF TAPE DETECTED *** NORMAL F'ROGRAM TERMINATION ** FILE HEADER ** FILE SEQUENCE # 1 FILE NAME: 1L-10.MWD SERVICE NAME: SSDS VERSION #: V 2.40 DATE: 90/03/26 MAX. RECORD LENGTH: 1024 FILE TYPE: EO PREVIOUS FILE NAME: ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# DEPT ROP MWD EWR MWD FXE MWD NXE MWD NFO MWD NFl MWD NN0 MWD NN1 MWD GRC MWD CAL MWD RHOB MWD NPSC MWD LOG TYP CLS MOD NO. LVL CODE FT 0 0 0 0 1 4 0 1 68 FT/H 0 0 0 0 1 4 0 1 68 OHMM 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 API 0 0 0 0 1 4 0 1 68 INCH 0 0 0 0 1 4 0 1 68 G/C3 0 0 0 0 1 4 0 1 68 P.U. 0 0 0 0 1 4 0 1 68 ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS ':? tC OFILMED TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# DEPT ROP MWD EWR MWD FXE MWD NXE MWD NFO MWD NFl MWD NN0 MWD NN1 MWD GRC MWD CAL MWD RHOB MWD NPSC MWD LOG TYP CLS MOD NO. LVL CODE FT 0 0 0 0 1 4 0 1 68 FT/H 0 0 0 0 1 4 0 1 68 OHMM 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 API 0 0 0 0 1 4 0 1 68 INCH 0 0 0 0 1 4 0 1 68 G/C3 0 0 0 0 1 4 0 1 68 P.U. 0 0 0 0 1 4 0 1 68 (NOTE'. **** LIS READ **** MAXIMUM RECORD LENGTH - 8192 BYTES) ** REEL HEADER ** REEL SEQUENCE # 1 SERVICE NAME: SSDS DATE: 90/03/26 ORIGIN OF DATA: RLL REEL NAME: ARCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER ** SERVICE NAME: SSDS DATE: 90/03/26 ORIGIN OF DATA: 1L10 TAPE NAME: KUPARUK CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** END OF FILE (EOF # 1) ********** ** DATA VERIFICATION (every 250 FT) ** DEPT ROP EWR FXE NXE NF0 NN 0 NN 1 GRC CAL RHOB NPS C 5000.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 5250.000 518.335 4.123 2520.000 2632.000 85.452 5500.000 292.203 2.999 2568.000 2456.000 113.862 .297 8.670 .460 8.400 5750.000 247.352 3.493 .673 2584.000 2680.000 97.289 8.400 6000.000 257.104 3.160 2744.000 2744.000 105.141 6250.000 224.121 2.823 2722.574 2744.000 106.899 .523 8.410 .480 8. 570 .311 2.258 .474 2.303 .697 2.329 .566 2.334 .507 2.421 6500.000 208.594 2.759 .616 .639 2856.000 2728.000 120.997 8.400 2.380 6750.000 250.312 3.164 .434 .508 2968.000 2888.000 95.524 8.450 2.332 599.000 41.603 631.000 41.002 655.000 39.300 663.000 35.652 694.860 35.620 679.000 35.413 663.000 33.319 7000.000 234.668 3.783 .733 .852 735.000 2824.000 2840.000 90.166 8.630 2.350 31.993 7250.000 240.938 2.731 .587 .609 671.000 2808.000 2872.000 94.591 8.430 2.340 35.138 7500.000 256.055 2.131 .637 .730 791.685 2475.530 2494.054 174.348 8.560 2.197 41.053 7750.000 186.143 3.185 .624 .647 759.000 2616.000 2568.000 178.798 8.800 2.553 40.574 8000.000 149.063 3.754 .838 .961 2572.166 2490.083 120.237 8.720 2.126 2.036 2.413 8250.000 110.305 3.081 1.934 2648.127 2580.012 167.946 8.590 643.876 38.284 820.932 36.189 8500.000 46.662 2.942 1.202 1.392 891.092 2583.948 2484.035 220.861 8.690 2.402 41.802 1.209 2.297 8750.000 179.648 57.095 .984 2745.722 2776.683 71.108 8.410 600.392 38.129 9000.000 47.906 4.919 1.242 1.405 674.977 2751.295 2716.274 97.948 8.590 2.305 35.752 9250.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** 453 DATA RECORDS ** 5000.00 TO ** FILE TRAILER** FILE NAME: 1L-10.MWD SERVICE NAME: SSDS FROM 9300.00 FT NFl -999.250 583.000 639.000 631.000 663.000 680.576 663.000 647.000 711.000 631.000 754.221 711.000 709.959 805.573 862.917 627.184 706.852 -999.250 VERSION #: V 2.40 DATE: 90/03/26 MAX. RECORD LENGTH: FILE TYPE: EO NEXT FILE NAME: 1024 ********** END OF FILE (EOF # 2) ********** * L L I BBB U U RRRR TTTTT O N N * * L L I B B U U R R T 0 0 NN N * * L L I BBBB U U RRRR T O O N N N * * L L I B B U U R R T O O N NN * * A LL LL I BBBB U R R T O N N * * *HHHH HHHH L O G G I N G S E R V I C E S , I N C . * * * . * * * * * * * . * * * * * L.I.S. TAPE VERIFICATION LISTING * * * * HHHH HHHH HHHH HHHH H H A HHHH HHHH H H AA HHHHHHHHHHH HHHH A A HHHHHHHHHHH H H AAAA HHHH HHHH H H A HHHH HHHH RECEIVED ** RI!EEL. HEADER ** SERVICE NAME GO/DDL. D A'T' E 9 C: 10 3131 0 R i G i N D E N V REEt.. NAMIE ARC02 C 0 N"i" i N U A"t" I 0 N N U M B E R 1 PREVIOUS RIEEI... C 0 M M IE N 'T' S ** TAPiE HEADER ** S E IR V I C E N A I"!E ,-, ..,-, !]' A T E 0 0 / 0 0 / 0 0 OR T R 'r j,, DE. NV .... r .... t.. ,I T' A t::' [.:' NAMtE 0 CONT'INUA'T'ZON NUMBER 1 PREVIOUS TAF'E. C:, O M M E N T' S: ******************************************************************************** *** 'TAPE END OF:" FIi..E MARK ******************************************************************************** ** FILE"' HEADER ** F: .11 L E NAME SERVICE NAME V E R S I O N N U M B E R DATE ..... I .... '-I '~ .... M A X ti M ! JM ,.... E:, I'~ G I .la F I LIi.:"' T YP PR E V I OUS F' I L El C 0 M C E N. () 0 :L 0 0 COMCEN 10 2 4 LO ** IIqF,_,-,~,,.-,TION RECOI::;..'DS ** D B U r,.t FEE'T' WN K R U 1 L.- 10 F:' I'..I KI._IF'A!:~UK R ir. VER UN ir. T F L 164 FT F'St .... !.... OI',IG O. ()0()0 SECT 29 10E C[]LJN NORTH. S L.O F'I!.:.': S'T'A T AK 519 3 j 'T'Y P I-IF;..' I E t'4 G I M C K A Y / B O I... 0 T W I "Fig .-,1 i .-,r.-I, I"', _ (:.:~ ,:.'.., 4 ? S A !< U 1 '7.1. 9 BH'T' ! 5 8. () 0 0 0 MF:;,'T () O ,, O 0 00 DF'T' NDF:' .'OF'D 1 (). 90()0 DFV 41. ('.'. () () () DF'PH 9 ,, () 000 DF:'I .... 7 0.0 () 0 0 MF:'SS FI[.:: MFST RMI:::' 2.54 ::} () MCSS MtE M i '''~ 62 'T' ~..~ ~...~ . 65. () () 0,'"~ RMC ":'.,:.. 01 ()0 RMF::'B 0 0 12:1.. C: ()00 E: D t::' (). 0 () 00 EDP (). () 000 8 ,, 5 (),:".~ C:, DD ..... L ::5 . C:,O O0 0.0 0 0 0 L..MF' I:R ~::: B 'T'L I C'~. 0 0 O0 .L~-.~ t ~.~ FL.l..dq~-~ I RECORD ENTRY '" rl ...... c., 3 ~'.' '7 o, 4 :L 66 5 !. 66 8 4 68 9 4 65 i i 2 '79 12 4 68 .. ~-, ! 66 16 1 66 () 1 66 () D A"i" A R E C O Fi'. D 'T' Y P E 0 DA]"UM SPECI F:' I CA'T' 101',1 BI....OCK 'T'YF::'IE 80 DATA F:'RAME SIZIE I I...(]GG I NG I} I REC'T 101',1 'L =UF=' .. 2 ........ i'""DOWN I OP'TI[3AI... LOG DEF:"T'H UixtI'T'S c'). ?.5OO FRAME SPAC I NG F '+' U N -'[ 'T' S 12 MAX NC) F:'RAMES/RECOF;:D (~..) .., ~, '+' R E P C C) D E 1 D~B ~'' q .... " ~.~ U.L - F ¥ F E () T E R M I N A'T' (] R MNEM '1"OC)L.. D E F::' ]" () F G R 0 ,...q ~.,, .''"' ~:'' I 0 r.::' :r) c::- t, I 0 .... ' ...... ,, ,, (.., F' :=. 0 NDSN () .... · · L,~' ~, (:) N L... I M () D E C P () t'-.1P H I () DIE C P 0 N Fi: A T 0 C: / C 0 D F=' H I 0 D E C P () D F"':,' H 0 0 G / C:: 3 0 F S D L 0 C: P S 0 I¥c:. r,, ~ () F: t::' .~ 0 · i ....I .;..-' ~ .... _ ...... PIE 0 0 R H 0 :(-':,' 0 (3 / C:: 3 0 M I N V () 0 H M M 0 v '.. f~' I I1,1 d l: () O !-'ti'IM O C A t.,. :[ () :!: N 0 DCAI .... 0 I N O TENS C, 0 BS '"' I N ,:":, DL. CiD (', L_B C; S, tERV I CE Ut',I I 'T AP1 Al::' I AP I AP I F' I I... S I Z SF:'I .... REP ::::::::::::::::::::::::::: CODIES '0 0 () 0 () ,-..".~ 0 0 0 () 0 0 0 () 0 0 0 D A"il" A Bt.... O C K S · '1 ...........................................................I' ....................................................... 1 ......................................................... I- ........................................................................ I",11.... I M (), 4. t S I"--.IF:' H I (). 481 .I',IR A T 1 (), .1. () 0 D F::'I"-! 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