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Home My WebLink About185-246Originated: Delivered to:5-Jul-24 Alaska Oil & Gas Conservation Commiss 05Jul24-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED CD4-586 50-103-20857-00-00 223-046 Colville River WL TTiX-PPROF FINAL FIELD 3-Mar-24 CD4-536 50-103-20863-00-00 223-079 Colville River WL TTiX-PPROF FINAL FIELD 7-Mar-24 2M-12 50-103-20181-00-00 192-090 Kuparuk River WL SCMT FINAL FIELD 8-Mar-24 1B-16A 50-029-22457-01-00 218-155 Kuparuk River WL RST FINAL FIELD 9-Mar-24 CD4-588 50-103-20853-00-00 223-029 Colville River WL TTiX-PPROF FINAL FIELD 22-Mar-24 CD5-23 50-103-20761-00-00 217-155 Colville River WL Packer Setting FINAL FIELD 24-Mar-24 3F-08 50-029-21464-00-00 185-246 Kuparuk River WL SCMT FINAL FIELD 30-Mar-24 2M-03 50-103-20160-00-00 191-141 Kuparuk River WL SCMT FINAL FIELD 31-Mar-24 2B-14 50-029-21143-00-00 184-111 Kuparuk River WL WFL FINAL FIELD 3-Apr-24 2T-41 50-103-20675-00-00 213-146 Kuparuk River WL PPROF FINAL FIELD 7-Apr-24 MT7-03A 50-103-20830-01-00 223-084 Greater Mooses Tooth WL TTiX-Fiber FINAL FIELD 22-May-24 MT7-01 50-103-20832-00-00 221052 Greater Mooses Tooth WL TTiX-Fiber FINAL FIELD 27-May-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private T39122 T39123 T39124 T39125 T39126 T39127 T39128 T39129 T39130 T39131 T39132 T39133 3F-08 50-029-21464-00-00 185-246 Kuparuk River WL SCMT FINAL FIELD 30-Mar-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.05 10:30:21 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 2, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3F-08 KUPARUK RIV UNIT 3F-08 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/02/2024 3F-08 50-029-21464-00-00 185-246-0 W SPT 5937 1852460 1500 2152 2154 2152 2154 0 0 0 0 INITAL P Kam StJohn 5/21/2024 Initial MIT-IA Post RWO per sundry 323-570 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 3F-08 Inspection Date: Tubing OA Packer Depth 610 3020 2900 2860IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS240522122228 BBL Pumped:1.8 BBL Returned:1.6 Tuesday, July 2, 2024 Page 1 of 1 9 9 9 9 9 9 99 9 9 9 9 9 9 9 9 9 9 Post RWO James B. Regg Digitally signed by James B. Regg Date: 2024.07.02 12:59:27 -08'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV UNIT 3F-08 JBR 05/21/2024 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:2 All tests with 3-1/2" Test joint. Bag failed on high psi test, functioned and passed. HCR Choke failed high and low, greased and functioned, passed. Nitrogen: 11@1095 psi. Test Results TEST DATA Rig Rep:Tony Morales, Paul YeaOperator:ConocoPhillips Alaska, Inc.Operator Rep:Mark Adams, Scott Kiser Rig Owner/Rig No.:Nabors 7ES PTD#:1852460 DATE:3/28/2024 Type Operation:WRKOV Annular: 250/3500Type Test:INIT Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopJDH240327092814 Inspector Josh Hunt Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 6 MASP: 3281 Sundry No: 323-570 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 16 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13-5/8" T90 FP #1 Rams 1 3-1/2"x5-1/2"P #2 Rams 1 Blinds P #3 Rams 1 3-1/2"x5-1/2"P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3-1/8"P HCR Valves 2 3-1/8"FP Kill Line Valves 2 3-1/8" & 2"P Check Valve 0 NA BOP Misc 2 2-1/16"P System Pressure P3050 Pressure After Closure P1650 200 PSI Attained P25 Full Pressure Attained P113 Blind Switch Covers:PAll stations Bottle precharge P Nitgn Btls# &psi (avg)P5@2075 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P24 #1 Rams P5 #2 Rams P5 #3 Rams P5 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1       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 7050'feet None feet true vertical 6340' feet None feet Effective Depth measured 6842'feet 6173', 6259', 6534'feet true vertical 6175'feet 5660', 5725', 5937'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" 4-1/2" L-80 L-80 6228' 6558' 5702' 5955' Packers and SSSV (type, measured and true vertical depth)6173' 6259' 6534' 5660' 5725' 5937' 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: 3029' 3029' Burst Collapse Production 1826' 6976' Casing 1850' 6307' 1850' 7009' 2992' 115'Conductor Surface Tie-Back 16" 9-5/8" 77' measured TVD 7" 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 185-246 50-029-21464-00-00 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: ADL0025632, ADL0025643 Kuparuk River Field/ Kuparuk Oil Pool KRU 3F-08 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf MDSize 115' 3600 2200 323-570 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: SLB Blue Max Packer: Baker FHL Retrievable Packer: Baker DB Permanent SSSV: None James Ohlinger james.j.ohlinger@conocophillips.com Staff RWO/CTD Engineer 6385-6435' (squeezed), 6491-6502' (Squeezed), 6610-6647', 6664-6707' 5822-5861'(squeezed), 5904-5913' (Squeezed), 5995-6024', 6037-6070' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov (907) 265-1102 Digitally signed by James J. Ohlinger DN: C=US, OU=ConocoPhillips, O=Wells - Coiled Tubing Drlling, CN=James J. Ohlinger, E= James.J.Ohlinger@cop.com Reason: I am the author of this document Location: Date: 2024.05.02 12:07:29-08'00' Foxit PDF Editor Version: 13.0.0 James J. Ohlinger By Grace Christianson at 12:59 pm, May 02, 2024 DSR-5/8/24 RBDMS JSB 051324 Page 1/9 3F-08 Report Printed: 4/25/2024 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) 3/27/2024 00:00 3/27/2024 05:00 5.00 MIRU, MOVE MOB P Cleaned up cellar. Moved sub off 3F-14 Spotted in sub on 3F-08. 0.0 0.0 3/27/2024 05:00 3/27/2024 07:30 2.50 MIRU, MOVE MOB P Lay out herculite and set mats for pits Spot pits up to sub base, berm around sub and pits Secure stairs and landings 0.0 0.0 3/27/2024 07:30 3/27/2024 12:00 4.50 MIRU, MOVE RURD P Swap power to pits, R/U interconnect, R/U mud lines, B/D F/rig floor tp pits, check lines. Secure rig floor, connect the cement line, Complete pre acceptance checklist. *** Note: Rig on highline power @ 09:15am 0.0 0.0 3/27/2024 12:00 3/27/2024 12:15 0.25 MIRU, WELCTL RURD P Well dispatch sent truck pusher out to walk trucking route and ensure that thier personel are notified of the tight location, Relocate kill and open top tank. *** Rig Accept @ 12:00 pm 0.0 3/27/2024 12:15 3/27/2024 12:45 0.50 MIRU, WELCTL RURD P Spot Vac Truck into rig from access road side of rig. load seawater in pits. Finish installing hard line to kill tank. RU cellar to kill well. 0.0 0.0 3/27/2024 12:45 3/27/2024 16:00 3.25 MIRU, WELCTL RURD P Continue to R/U kill and open top tanks, M/U dike for single wall open top tank, tank manifold froze, R/D and take to pipe shed to steam, re-install manifold, confirm flow path. *** Note: Initial Pressures Tubing100/IA 0/OA 0 0.0 0.0 3/27/2024 16:00 3/27/2024 17:30 1.50 MIRU, WELCTL CIRC P Swap well to 8.5 ppg SW, bring pump online 8.0 bpm/2,100 psi/425 choke psi, ciurculate 30 bbl screen clean pill, followed by 270 bbl of 8.5 ppg SW total of 300 bbls 0.0 0.0 3/27/2024 17:30 3/27/2024 19:30 2.00 MIRU, WHDBOP OWFF P Shut down pump, blow down choke manifold and surface lines. brake off in cellar and monitor well. 0.0 0.0 3/27/2024 19:30 3/27/2024 20:00 0.50 MIRU, WHDBOP MPSP P Set BPV and test under plug to 100 PSI for 10 minutes 0.0 0.0 3/27/2024 20:00 3/28/2024 00:00 4.00 MIRU, WHDBOP NUND P N/D adapter and tree. Function check lift threads in hanger. Obtain RKB measurments. Install Blanking plug. NU BOPE. Install riser torque flanges on BOP stack and DSA. Torque Kill swivel block. 0.0 0.0 3/28/2024 00:00 3/28/2024 01:00 1.00 MIRU, WHDBOP RURD P N/D adapter and tree. Function check lift threads in hanger. Obtain RKB measurements. Install Blanking plug. NU BOPE. Install riser torque flanges on BOP stack and DSA. Torque Kill swivel block. 0.0 0.0 3/28/2024 01:00 3/28/2024 02:30 1.50 MIRU, WHDBOP RURD P Fill stack with water, obtain shell test 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 4/6/2024 Page 2/9 3F-08 Report Printed: 4/25/2024 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) 3/28/2024 02:30 3/28/2024 08:30 6.00 MIRU, WHDBOP BOPE P Start testing BOPE. Initial BOPE test, Tested BOPE at 250/3500 PSI for 5 Min each, Tested annular on 3-1/2" test joint, Fail/Pass on the high, UVBR's, LVBR's w/3-1/2" test joint. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 3 1/2" HT-38 safety valve, FOSV, and IBOP. Tested 3 -1/2" EUE FOSV Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Fail/pass choke HCR, 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=1600 PSI, after closure=1500 PSI, 200 PSI attained =2.5 sec, full recovery attained = 1 min 53 sec. UVBR's= 5 sec, Annular= 30 sec. Simulated blinds= 5 sec. LVBR’s=6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 1095 PSI. Test gas detectors, PVT and flow show. Test Witnessed by AOGCC rep Josh Hunt. 0.0 0.0 3/28/2024 08:30 3/28/2024 09:00 0.50 COMPZN, RPCOMP RURD P Blow down & R/D testing equipment. 0.0 0.0 3/28/2024 09:00 3/28/2024 10:30 1.50 COMPZN, RPCOMP RURD P Blow down surface lines. Empty stack. Pull blanking plug. Pull BPV. PU handling equipment for pulling completion. RU To pull completion. Move rig tongs to rig floor. RU power tongs. 0.0 0.0 3/28/2024 10:30 3/28/2024 11:00 0.50 COMPZN, RPCOMP PULL P MU 3.5" EUE landing joint screw into tubing hanger. BOLDS. Pull hanger off seat at 90K, pull hanger to floor F/6220' T/6,212' - 86K UP 6,220.0 6,212.0 3/28/2024 11:00 3/28/2024 11:45 0.75 COMPZN, RPCOMP CIRC P Circulate BU, 76 spm / 4.7 bpm / 270 psi, 6,212.0 6,212.0 3/28/2024 11:45 3/28/2024 16:00 4.25 COMPZN, RPCOMP PULL P Pull 3.5" completion F/6,220' T/4,500' PUW=86k SOW=35k 6,212.0 1,594.0 3/28/2024 16:00 3/28/2024 17:30 1.50 COMPZN, RPCOMP TRIP P M/U 6.125" Drift to the 3.5" tubing OX to DP, TBIH on DP, set down tight spot @ 655.4', rotate 1/4° increment, unable to drift past. PUW=59 k, SOW= 37 k 1,594.0 655.4 3/28/2024 17:30 3/28/2024 18:00 0.50 COMPZN, RPCOMP TRIP P TOOH, standing DP in derrick F/2,464' (Drift Depth 655.4') T/655.4 655.4 8.5 3/28/2024 18:00 3/28/2024 18:30 0.50 COMPZN, RPCOMP BHAH P LD BHAMU 6" Drift run BHA #2 8.5 8.3 3/28/2024 18:30 3/28/2024 19:00 0.50 COMPZN, RPCOMP TRIP P TIH T/655.4 Sticky Set down 25K PU=25 Pulled 85K to get out of tight spot. 8.5 655.4 3/28/2024 19:00 3/28/2024 19:45 0.75 COMPZN, RPCOMP TRIP P TOOH F/655' T/8.5 655.4 8.5 3/28/2024 19:45 3/28/2024 20:00 0.25 COMPZN, RPCOMP BHAH P LD BHA #2 6" String mill 8.5 0.0 3/28/2024 20:00 3/28/2024 20:30 0.50 COMPZN, RPCOMP SVRG P Service rig 0.0 3/28/2024 20:30 3/28/2024 20:45 0.25 COMPZN, RPCOMP PULL P LD 2 joints for 147 total out of hole. Started pulling 10K over 60K on weight indicator. POOH W/3.5" Tubing F/1695' T/1633' 1,695.0 1,633.0 Rig: NABORS 7ES RIG RELEASE DATE 4/6/2024 Page 3/9 3F-08 Report Printed: 4/25/2024 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) 3/28/2024 20:45 3/28/2024 21:15 0.50 COMPZN, RPCOMP BHAH P PU BHA #3 GS Bait sub and G-Spear On DP. 1,663.0 4.5 3/28/2024 21:15 3/29/2024 00:00 2.75 COMPZN, RPCOMP TRIP P TIH with Tubing crossed over to DP F/1519' T/5527'. 4.5 5,527.0 3/29/2024 00:00 3/29/2024 01:30 1.50 COMPZN, RPCOMP TRIP P TIH F/5527' T/6220' Drop off tubing on tubing cut. Top of bait sub tubing at 4644.45' PUW=115K SOW=100K 5,527.0 6,220.0 3/29/2024 01:30 3/29/2024 02:00 0.50 COMPZN, RPCOMP RURD P Pump off tubing. PUW+100K after. Blow down top drive. POOH with one stand. 6,220.0 6,220.0 3/29/2024 02:00 3/29/2024 02:00 COMPZN, RPCOMP TRIP P TOOH F/6,220' T/4,500' 6,220.0 4,500.0 3/29/2024 02:00 3/29/2024 04:00 2.00 COMPZN, RPCOMP SLPC P 4,500', Slip and cut Drilling line. 4,500.0 4,500.0 3/29/2024 04:00 3/29/2024 06:45 2.75 COMPZN, RPCOMP TRIP P Continue TIH w/DP F/4,500' T/Surface 4,500.0 0.0 3/29/2024 06:45 3/29/2024 07:15 0.50 COMPZN, RPCOMP BHAH P L/D BHA, M/U Baker IBP 0.0 0.0 3/29/2024 07:15 3/29/2024 10:00 2.75 COMPZN, RPCOMP TRIP P TIH on DP w/Baker IBP, filling DP every 5 stands 0.0 2,900.0 3/29/2024 10:00 3/29/2024 11:00 1.00 COMPZN, RPCOMP MPSP P Set IBP COE @ 2,900.4', work pressure up in increments 1,000 psi, 1,500 psi, 1,800 psi, 2,100 psi setting tool sheared. Packer set. P/T packer 1,400 psi for 10 mins charted. 2,900.0 2,900.0 3/29/2024 11:00 3/29/2024 12:45 1.75 COMPZN, RPCOMP TRIP P TOOH, on stands F/2,900' T/Surface 2,900.0 0.0 3/29/2024 12:45 3/29/2024 13:00 0.25 COMPZN, RPCOMP BHAH P L/D baker setting tool, P/U 3.5" Mill Shoe 0.0 0.0 3/29/2024 13:00 3/29/2024 14:00 1.00 COMPZN, RPCOMP TRIP P TIH, on stands 0.0 2,800.0 3/29/2024 14:00 3/29/2024 18:30 4.50 COMPZN, RPCOMP OTHR P Dump 20 sacks of sand on top of IBP 2,800.0 2,800.0 3/29/2024 18:30 3/29/2024 18:45 0.25 COMPZN, RPCOMP TRIP P TOOH 3 stands. 2,500.0 2,500.0 3/29/2024 18:45 3/29/2024 19:00 0.25 COMPZN, RPCOMP CIRC P Circultate DP clean. 2,500.0 2,500.0 3/29/2024 19:00 3/29/2024 20:00 1.00 COMPZN, RPCOMP TRIP P TOOH F/2500 T/surface PUW=69K 2,500.0 2,500.0 3/29/2024 20:00 3/29/2024 22:00 2.00 COMPZN, RPCOMP NUND P ND BOP's and DSA 2,500.0 0.0 3/29/2024 22:00 3/30/2024 00:00 2.00 COMPZN, RPCOMP NUND P RU Hydartight and Grow casing 0.0 0.0 3/30/2024 00:00 3/30/2024 02:30 2.50 COMPZN, RPCOMP NUND P RU Hydartight and Grow casing 31.5" Total growth. Remove tubing head and remove from cellar. 0.0 0.0 3/30/2024 02:30 3/30/2024 04:00 1.50 COMPZN, RPCOMP FISH P Spear casing pull tension set 150K on slips. 31.5" total growth 22.75" stretch total removed from well 54.25" (4.52' OAL) 0.0 0.0 3/30/2024 04:00 3/30/2024 05:00 1.00 COMPZN, RPCOMP RURD P Cut 7" casing install pack off. 0.0 0.0 3/30/2024 05:00 3/30/2024 09:00 4.00 COMPZN, RPCOMP NUND P Install DSA NU BOP's. Change out Lower pipe rams to 7" fixed rams. 0.0 0.0 3/30/2024 09:00 3/30/2024 10:00 1.00 COMPZN, RPCOMP NUND P Install riser pressure test flange break on casing head to 1000 PSI. 0.0 0.0 3/30/2024 10:00 3/30/2024 13:00 3.00 COMPZN, RPCOMP ELNE P SLB E-line on location, PJSM, spot in and R/U, re-head and test E-line. 0.0 0.0 3/30/2024 13:00 3/30/2024 16:15 3.25 COMPZN, RPCOMP ELNE P RIH w/E-line to bottom 2,833', correlation pass up hole, RBIH, main pass 2,830'-surface, showing TOC @ 1,960'. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 4/6/2024 Page 4/9 3F-08 Report Printed: 4/25/2024 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) 3/30/2024 16:15 3/30/2024 17:30 1.25 COMPZN, RPCOMP ELNE P At surface, L/D tools, R/D E-line 0.0 0.0 3/30/2024 17:30 3/30/2024 18:00 0.50 COMPZN, RPCOMP SVRG P Service top drive 0.0 0.0 3/30/2024 18:00 3/30/2024 18:30 0.50 COMPZN, RPCOMP RURD P Clear rig floor rig up to TIH W/DP on BHA 0.0 0.0 3/30/2024 18:30 3/30/2024 19:00 0.50 COMPZN, RPCOMP BHAH P M/U Baker Multi String cutter BHA#6 0.0 8.5 3/30/2024 19:00 3/30/2024 20:15 1.25 COMPZN, RPCOMP TRIP P TIH F/8.5" T/ 1850' establish parameters to cut casing 1850 7ES RKB. PUW=61K 8.5 1,850.0 3/30/2024 20:15 3/30/2024 20:30 0.25 COMPZN, RPCOMP SFTY P Safety meeting W/AES LRS and Nabors discuss plan forward. 1,850.0 1,850.0 3/30/2024 20:30 3/30/2024 21:30 1.00 COMPZN, RPCOMP CPBO P RPM=65 Free Tq.=760 ROT WT=60K PR6BPM @ 1200 PSI Rotating TQ pumps on 1400 Ft/Lbs. Rotated 2 minutes PR=6BPM Torque dropped to 760 Ft.?Lbs 430 PSI Set down 5K on blades.Pulled into cut PU 5K Shut down pump drifted through cut 1' . PU Break out working single. 1,850.0 1,820.0 3/30/2024 21:30 3/30/2024 22:15 0.75 COMPZN, RPCOMP CIRC P Line up to circulate down DP up OA to open top tank. Pressure up down DP to 1000 PSI unable to move Arctic pack. Pressure bled back to 900 PSI. Pressured up -to 1000 PSI. still no circulation. pressure did not fall off. 1,820.0 1,820.0 3/30/2024 22:15 3/30/2024 22:45 0.50 COMPZN, RPCOMP OWFF P OWFF for 30 minutes no flow. 1,820.0 1,820.0 3/30/2024 22:45 3/30/2024 23:45 1.00 COMPZN, RPCOMP TRIP P Blow down top drive TOOH F/1820' T/8.5' LD cutter BHA #6. 1,820.0 8.5 3/30/2024 23:45 3/31/2024 00:00 0.25 COMPZN, RPCOMP BHAH P LD BHA #6 cutter 8.5 0.0 3/31/2024 00:00 3/31/2024 01:00 1.00 COMPZN, RPCOMP BHAH P MU BHA #7 7" Casing spear. 8.5 8.5 3/31/2024 01:00 3/31/2024 01:30 0.50 COMPZN, RPCOMP FISH P Spear casing PU on casing PUW=125K weight broke back to 90K. Pull slips and packoff to floor. 26.0 35.0 3/31/2024 01:30 3/31/2024 02:00 0.50 COMPZN, RPCOMP RURD P LD Slips RIH get spear below table. 35.0 20.0 3/31/2024 02:00 3/31/2024 07:30 5.50 COMPZN, RPCOMP CIRC P Shut in Lower pipe rams. Establish circulation at 3 BPM 600 PSI pressure broke back to 300 PSI. RU LRS and PT Lines to 1500 PSI. LRS circulating at 1.5 BPM 180* Down 7" returns up 7" x 9-5/8" casing to open top tank. Displace OA 20.0 20.0 3/31/2024 07:30 3/31/2024 08:00 0.50 COMPZN, RPCOMP OTHR P R/D cellar, flush out stack, surface lines, etc. 20.0 20.0 3/31/2024 08:00 3/31/2024 08:15 0.25 COMPZN, RPCOMP PULD P Reset spear grapple, spear 7" casing PUW=75K, SOW=74k on hook 1,830.0 1,830.0 3/31/2024 08:15 3/31/2024 11:30 3.25 COMPZN, RPCOMP PULD P L/D spear and cut joint Changeout DP elevators for 7" HYC POOH F/1,850' T/Surface, 42 joints / 2 cut joints 77K UP 63K DN Cut Joint #1=37.46' Cut Joint #2=21.26 1,830.0 0.0 3/31/2024 11:30 3/31/2024 12:30 1.00 COMPZN, RPCOMP BOPE P Set 10.86" test plug, test/chart BOP 7" fixed rams (LPR) 250/3,000 psi. 0.0 0.0 3/31/2024 12:30 3/31/2024 12:45 0.25 COMPZN, RPCOMP PULD P Pull test plug Set 11" wear ring 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 4/6/2024 Page 5/9 3F-08 Report Printed: 4/25/2024 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) 3/31/2024 12:45 3/31/2024 14:45 2.00 COMPZN, RPCOMP OTHR P Unload all 7" casing out of pipe shed, Load DC into pipe shed, and misc. BHA XO's 0.0 3/31/2024 14:45 3/31/2024 16:00 1.25 COMPZN, RPCOMP BHAH P M/U drift assembly w/6 Drill Collars 0.0 241.8 3/31/2024 16:00 3/31/2024 16:45 0.75 COMPZN, RPCOMP TRIP P TIH, w/drift BHA #7 Tag stump at 1849.2' PUW=60K SOW=55K 241.8 1,849.0 3/31/2024 16:45 3/31/2024 17:30 0.75 COMPZN, RPCOMP CIRC P Circulate well 6 BPM sxs 3 times 1,849.0 1,849.0 3/31/2024 17:30 3/31/2024 17:45 0.25 COMPZN, RPCOMP OWFF P OWFF for 15 minutes Blow down top drive. 1,849.0 1,849.0 3/31/2024 17:45 3/31/2024 18:15 0.50 COMPZN, RPCOMP TRIP P TOOH F/1849.2 T/241.8 1,849.0 241.8 3/31/2024 18:15 3/31/2024 19:00 0.75 COMPZN, RPCOMP BHAH P LD BHA #8 MU BHA #9 241.8 254.4 3/31/2024 19:00 3/31/2024 20:30 1.50 COMPZN, RPCOMP TRIP P TIH F/254.35' T/1849 Top of 7" casing. 254.4 1,849.0 3/31/2024 20:30 3/31/2024 22:45 2.25 COMPZN, RPCOMP WASH P Establish parameters. PR=5 BPM 360 PSI PUW=65K SOW=60K Rotate at 65 RPM Free tq=870 FT/Lbs. ROT wt=65K Wash from 1849' to 1853.5' Wash over top of stump. Mill down From 1849' to1849.5' Shut off rotary and drift clean PU=65K wash back over stump clean to tag at 1849.5' 1,849.0 1,849.5 3/31/2024 22:45 3/31/2024 23:30 0.75 COMPZN, RPCOMP CIRC P Circualte 80 Vis sweep SxS. 6 BPM 350 PSI. Blow down top drive. 1,849.5 1,849.5 3/31/2024 23:30 4/1/2024 00:00 0.50 COMPZN, RPCOMP SVRG P Service top drive. 1,849.5 1,849.5 4/1/2024 00:00 4/1/2024 00:30 0.50 COMPZN, RPCOMP TRIP P TOOH F/1849.5 T/ 252.8 PUW=65K 1,849.5 252.8 4/1/2024 00:30 4/1/2024 02:00 1.50 COMPZN, RPCOMP BHAH P LD BHA #9 252.8 0.0 4/1/2024 02:00 4/1/2024 04:30 2.50 COMPZN, RPCOMP RURD P Pull wear ring. RD floor from DP set up floor to run casing C/O to casing bails. RU GBR casing crew. 0.0 0.0 4/1/2024 04:30 4/1/2024 07:30 3.00 COMPZN, RPCOMP PUTB P PU 7" casing RIH F/surface T/1852' PUW=70k SOW=74k M/U Torque=9,400 ft/lbs, Torque turn all connections 0.0 1,852.0 4/1/2024 07:30 4/1/2024 08:00 0.50 COMPZN, RPCOMP PUTB P M/U space out pups, 4.66' and 20.07'=24.73', Slock off F/1,848' T/1,873', Stack out 25k, P/U pull over 30k, Stack out 30k, P/U pull 75k over to confirm casing patch latched up. 1,852.0 1,852.0 4/1/2024 08:00 4/1/2024 08:45 0.75 COMPZN, RPCOMP RURD P R/U to test casing patch and R/D, release GBR 1,852.0 1,852.0 4/1/2024 08:45 4/1/2024 09:45 1.00 COMPZN, RPCOMP PRTS P P/T Casing and casing patch T/1,000 psi as per procedure for 10 mins 1,852.0 1,852.0 4/1/2024 09:45 4/1/2024 11:15 1.50 COMPZN, RPCOMP NUND P N/D BOPE (split stack) 1,852.0 1,852.0 4/1/2024 11:15 4/1/2024 11:45 0.50 COMPZN, RPCOMP HOSO P Set slips on 7" casing, Hang off 65k over string weight, F/PUW=70k-130k set slips 1,852.0 1,852.0 4/1/2024 11:45 4/1/2024 13:00 1.25 COMPZN, RPCOMP NUND P N/U BOPE R/U OA to Kill/Open top tanks 1,852.0 1,852.0 4/1/2024 13:00 4/1/2024 13:45 0.75 COMPZN, RPCOMP RURD P Cementers on location, shut down pumps blow down line to pits, spot cementers and water trucks up to sub 1,852.0 1,852.0 Rig: NABORS 7ES RIG RELEASE DATE 4/6/2024 Page 6/9 3F-08 Report Printed: 4/25/2024 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) 4/1/2024 13:45 4/1/2024 14:15 0.50 COMPZN, RPCOMP RURD P R/U Cement Head, Rig up to circulate down the 7 inch taking returns up the OA in cellar. 1,852.0 1,852.0 4/1/2024 14:15 4/1/2024 14:45 0.50 COMPZN, RPCOMP SFTY P Crew change, replacement crew walkdown job, PJSM w/crew 1,852.0 1,852.0 4/1/2024 14:45 4/1/2024 16:15 1.50 COMPZN, RPCOMP CIRC P Pressure up to open cementer at 3,006 psi continue online @ 3 bpm with 120 bbl of 140° @ 435 psi SW down the 7" casing taking returns up the OA to the pits. 1,852.0 1,852.0 4/1/2024 16:15 4/1/2024 16:30 0.25 COMPZN, RPCOMP PRTS P Shut down pump, flood HES cement line and P/T to 3,000 psi while loading closing dart in cement head. 1,852.0 1,852.0 4/1/2024 16:30 4/1/2024 17:30 1.00 COMPZN, RPCOMP CMNT P Perform cement job - 15.3 ppg Cement wet @ 15:45 hrs. Break circulation w/5 bbl from cementers followed by 10 bbl water spacer/red dye @ 3 bpm, Pump 90 bbl of 15.3 ppg Class G cement, 3.0 bpm @ 490 psi, Opened cementer launch plug. Chase plug with rig pump 6 BPM dropped rate to 3 BPM AT 1000 stks bumped plug at 1137 Stks. FCP 1100 PSI Pressured up to 2600 PSI test float. Cement in place at 5:10 PM. 1,852.0 1,852.0 4/1/2024 17:30 4/1/2024 17:45 0.25 COMPZN, RPCOMP PRTS P Test float. Bleed Pressure off, 7" casing floats not holding. Pressure back up to 3000 PSI. 1,852.0 1,852.0 4/1/2024 17:45 4/1/2024 19:30 1.75 COMPZN, RPCOMP RURD P Clear floor, Move BHA #10 into pipe shed, Wash out stack, Load 3.5" test joint in pipe shed move test plug and wear ring to rig floor, hang tree in cellar. 1,852.0 1,852.0 4/1/2024 19:30 4/1/2024 19:45 0.25 COMPZN, RPCOMP PRTS P Bleed pressure off casing and check cementer closed. Pressure bled to 0PSI. 1,852.0 1,852.0 4/1/2024 19:45 4/1/2024 20:15 0.50 COMPZN, RPCOMP OWFF P OWFF for 30 minutes. 1,852.0 1,852.0 4/1/2024 20:15 4/1/2024 21:00 0.75 COMPZN, RPCOMP RURD P RD cement head flush BOP stack blow down choke and kill lines. Prep to change 7" rams. 1,852.0 1,852.0 4/1/2024 21:00 4/2/2024 00:00 3.00 COMPZN, RPCOMP NUND P Change lower pipe rams. 1,852.0 1,852.0 4/2/2024 00:00 4/2/2024 00:30 0.50 COMPZN, RPCOMP NUND P Split stack 1,852.0 1,852.0 4/2/2024 00:30 4/2/2024 02:00 1.50 COMPZN, RPCOMP WWSP P Cut casing and set intermediate casing pack off. 1,852.0 1,852.0 4/2/2024 02:00 4/2/2024 03:30 1.50 COMPZN, RPCOMP RURD P Install tubing head and test packoff to 3000 PSI. install test plug in tubing head. RD long bails from top drive install short bails. 1,852.0 1,852.0 4/2/2024 03:30 4/2/2024 05:00 1.50 COMPZN, RPCOMP NUND P Install 7-1/16 5k x 13-5/8" 5k DSA and BOP's NU BOP's Install riser and air up boots. 0.0 0.0 4/2/2024 05:00 4/2/2024 05:15 0.25 COMPZN, RPCOMP RURD P RU to test BOP's, PU test joint and screw into test plug. Fill stack with water. 0.0 0.0 4/2/2024 05:15 4/2/2024 07:00 1.75 COMPZN, RPCOMP BOPE P Test BOP' on LPR to 250/3500 PSI. 0.0 0.0 4/2/2024 07:00 4/2/2024 07:30 0.50 COMPZN, RPCOMP RURD P RD from testing BOP's. Blow down pump out stack and refill with seawater. *** Note: Wear ring installed 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 4/6/2024 Page 7/9 3F-08 Report Printed: 4/25/2024 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) 4/2/2024 07:30 4/2/2024 09:45 2.25 COMPZN, RPCOMP BHAH P PU BHA #10 Drill out cement. 0.0 256.8 4/2/2024 09:45 4/2/2024 11:30 1.75 COMPZN, RPCOMP TRIP P TIH, w/BHA #10 with Rock Bit 256.8 1,810.0 4/2/2024 11:30 4/2/2024 11:45 0.25 COMPZN, RPCOMP MILL P Cement stringer, PUW=65k, SOW=65k ROT=65 RPM, ROTW=63, Free weight=pumping 5 bpm/430 psi Ream in hole 1,810.0 1,836.0 4/2/2024 11:45 4/2/2024 13:45 2.00 COMPZN, RPCOMP MILL P Tag cemenet plug, PUW=65k SOW=65k ROT=65 RPM, ROTW=63 Milling ROT TQ= 1,000 ft/lbs 1,836.0 1,839.8 4/2/2024 13:45 4/2/2024 14:15 0.50 COMPZN, RPCOMP MILL P Continue milling through to 1,857' PUW=65k, SOW=65k, ROT=65k ROTW=58k Pumping 5 bpm/440 psi 1,839.8 1,883.0 4/2/2024 14:15 4/2/2024 15:00 0.75 COMPZN, RPCOMP CIRC P 1,883', M/U stand @ 1,959', circulate 45 bbl sweep around. 1,883.0 1,959.0 4/2/2024 15:00 4/2/2024 16:15 1.25 COMPZN, RPCOMP TRIP P Continue IH freely, tag sand top @ 2817' 1,959.0 2,817.0 4/2/2024 16:15 4/2/2024 17:00 0.75 COMPZN, RPCOMP MILL P PUH, bring pump online 5 bpm/430 psi ROT=65 rpm ROTW=63k, ROT TQ=0- 500 ft/lbs Circulate 45 bbl sweep around 2,817.0 2,850.0 4/2/2024 17:00 4/2/2024 19:30 2.50 COMPZN, RPCOMP TRIP P TOOH, for Reverse Junk Basket 2,850.0 257.0 4/2/2024 19:30 4/2/2024 20:30 1.00 COMPZN, RPCOMP BHAH P LD BHA#10 Milling BHA (6.125" rock bit, two boot baskets, 6.151" string mill, two 5.875" string magnets, fishing jars and 6 collars). 257.0 0.0 4/2/2024 20:30 4/2/2024 21:00 0.50 COMPZN, RPCOMP BHAH P MU BHA#11 reverse junk basket BHA (6" cutlip shoe, two wash pipe extensions, 5.75" RCJB, two 4.75 " boot baskets, 6.151" string mill, two 5.875" string magnets and fishing jars). 0.0 278.0 4/2/2024 21:00 4/2/2024 21:30 0.50 COMPZN, RPCOMP SVRG P Grease Black Jack, crown, draw works and roughneck. 278.0 278.0 4/2/2024 21:30 4/2/2024 23:00 1.50 COMPZN, RPCOMP TRIP P TIH to 2833' 278.0 2,833.0 4/2/2024 23:00 4/2/2024 23:30 0.50 COMPZN, RPCOMP WASH P Wash down F/2833'-T/2889' SOW 78K 2,833.0 2,889.0 4/2/2024 23:30 4/3/2024 00:00 0.50 COMPZN, RPCOMP CIRC P Circulate 20 bbl sweep 2,889.0 2,889.0 4/3/2024 00:00 4/3/2024 01:00 1.00 COMPZN, RPCOMP TRIP P TOOH with BHA #11 2,889.0 278.0 4/3/2024 01:00 4/3/2024 03:00 2.00 COMPZN, RPCOMP BHAH P LD BHA #11 Reverse circ junk basket 278.0 0.0 4/3/2024 03:00 4/3/2024 04:00 1.00 COMPZN, RPCOMP BHAH P MU BHA#12 Reverse circ junk basket 0.0 7.5 4/3/2024 04:00 4/3/2024 05:30 1.50 COMPZN, RPCOMP TRIP P TIH with BHA#12 IBP retrieval tool 7.5 2,847.0 4/3/2024 05:30 4/3/2024 06:00 0.50 COMPZN, RPCOMP TRIP P RIH, F/2,847' T/2,937', PUW=76k, SOW=73k, 5k down, latched into plug, equilized and released plug, RIH 15' 2,847.0 2,937.0 4/3/2024 06:00 4/3/2024 06:30 0.50 COMPZN, RPCOMP OWFF P Observed well for flow 30 mins (good test) 2,937.0 2,937.0 4/3/2024 06:30 4/3/2024 08:00 1.50 COMPZN, RPCOMP TRIP P TOOH, F/2,937' T/Surface 2,937.0 0.0 4/3/2024 08:00 4/3/2024 09:00 1.00 COMPZN, RPCOMP BHAH P L/D IBP retrieving tool and G-Lock, M/U G-spear 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 4/6/2024 Page 8/9 3F-08 Report Printed: 4/25/2024 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) 4/3/2024 09:00 4/3/2024 09:30 0.50 COMPZN, RPCOMP PRTS P R/U close blind rams and pressure test casing to 3,000 psi for 10 mins, RD testing equipment and blow down kill Line 0.0 0.0 4/3/2024 09:30 4/3/2024 09:45 0.25 COMPZN, RPCOMP BHAH P M/U BHA 13, G-spear 0.0 0.0 4/3/2024 09:45 4/3/2024 11:15 1.50 COMPZN, RPCOMP TRIP P TIH, w/G-spear 0.0 4,644.4 4/3/2024 11:15 4/3/2024 11:30 0.25 COMPZN, RPCOMP TRIP P PUW=93k, SOW=92k, L/D 3.5" 9.3# L- 80 fish Latch onto fish PUW=105k 4,644.4 4,644.0 4/3/2024 11:30 4/3/2024 15:00 3.50 COMPZN, RPCOMP TRIP P TOOH to BHA. 4,644.0 1,576.0 4/3/2024 15:00 4/3/2024 16:00 1.00 COMPZN, RPCOMP CLEN P At surface with DP Prep RF for L/D 3.5" fish Hang tongs on Driller Side RF 1,576.0 1,576.0 4/3/2024 16:00 4/3/2024 16:30 0.50 COMPZN, RPCOMP SVRG P Service Rig Top Drive, blocks,rough neck and draw works. 1,576.0 1,576.0 4/3/2024 16:30 4/3/2024 20:00 3.50 COMPZN, RPCOMP BHAH P L/D 3.5" 9.3# L-80 tubing 1,576.0 0.0 4/3/2024 20:00 4/3/2024 21:00 1.00 COMPZN, RPCOMP BHAH P M/U Dress off assembly BHA#13 0.0 265.0 4/3/2024 21:00 4/4/2024 00:00 3.00 COMPZN, RPCOMP TRIP P TIH F/265' T/6220' PUW 120K/ SOW110K 265.0 6,220.0 4/4/2024 00:00 4/4/2024 00:30 0.50 COMPZN, RPCOMP WASH P Wash and ream down F/6208' T/6210' 5 BPM/600 PSI, 65 RPM, 3.5K TQ on bottom. TQ off bottom 2.2K Clean out over TBG stump T/6210' - 3.5" tubing stump @ 6210, Dry Drift over Tubing Stump with no rotary and no pumps. 6,208.0 6,210.0 4/4/2024 00:30 4/4/2024 01:30 1.00 COMPZN, RPCOMP CIRC P Pump 40 bbl sweep at 9 BPM/1700 psi 6,210.0 6,210.0 4/4/2024 01:30 4/4/2024 02:00 0.50 COMPZN, RPCOMP SVRG P Service top drive, iron roughneck and draw works. 6,210.0 6,210.0 4/4/2024 02:00 4/4/2024 07:30 5.50 COMPZN, RPCOMP PULD P POOH LD DP F/6218' T/BHA 6,210.0 736.0 4/4/2024 07:30 4/4/2024 10:00 2.50 COMPZN, RPCOMP BHAH P At surface, L/D DC and Dress assembly 736.0 0.0 4/4/2024 10:00 4/4/2024 10:30 0.50 COMPZN, RPCOMP SVRG P Service Rig 0.0 0.0 4/4/2024 10:30 4/4/2024 12:30 2.00 COMPZN, RPCOMP RURD P R/U rig floor for completion operations, RU GBR for running 3.5" HYD 563 tubing. PJSM 0.0 0.0 4/4/2024 12:30 4/4/2024 22:00 9.50 COMPZN, RPCOMP PUTB P Run 3.5" HYD-563 completion with GBR Torque Turn. MU Torque to 2900LBS using BOL 2000 pipe dope. 0.0 6,212.0 4/4/2024 22:00 4/4/2024 23:00 1.00 COMPZN, RPCOMP THGR P Circulate down tubing and witnessed pressure increase as overshot swallowed the tubing stump at 6213'. Shut down pump and RIH. to shear pins at 6215'. At 8K the pins sheared and we set down on the NO GO at 6218'. L\D 3 joints, PU space out pups 7.54' and 8.38' then PU joint 196 and landoing joint, MU head pin to circulate in CI. 6,212.0 6,218.0 4/4/2024 23:00 4/5/2024 00:00 1.00 COMPZN, RPCOMP CRIH P Circulate tubing and IA to CI seawater. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 4/6/2024 Page 9/9 3F-08 Report Printed: 4/25/2024 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) 4/5/2024 00:00 4/5/2024 02:00 2.00 COMPZN, RPCOMP PRTS P Drop B&R and wait 15 minutes for it to fall to RHC plug. PT tubing to 3500 psi for 30 minutes and chart. Reduce tubing pressure to 1500 psi and PT IA to 3000 psi for 30 minutes. Dump pressure on tubing to shear SOV. SOV sheared, 0.0 0.0 4/5/2024 02:00 4/5/2024 03:00 1.00 COMPZN, RPCOMP RURD P Blow down and rig down cement line. Lay down landing joint. Jet the stack clean. Blow down the top drive. 0.0 0.0 4/5/2024 03:00 4/5/2024 03:30 0.50 COMPZN, RPCOMP MPSP P Set the BPV and test to 1000 psi from below for 10 minutes. 0.0 0.0 4/5/2024 03:30 4/5/2024 06:00 2.50 COMPZN, WHDBOP RURD P Blow down surface lines, suck out stack, change out F/3.5" x 5.5" T/7" fixed bore rams, 0.0 0.0 4/5/2024 06:00 4/5/2024 06:30 0.50 COMPZN, WHDBOP SFTY P Both Day and night crews attend Slips/Trips/Falls meeting 0.0 0.0 4/5/2024 06:30 4/5/2024 07:00 0.50 COMPZN, WHDBOP RURD P Tighten up and torque BOPE Doors Continue cleaning pits 0.0 0.0 4/5/2024 07:00 4/5/2024 10:00 3.00 COMPZN, WHDBOP NUND P N/D BOPE, move back to post and secure 0.0 0.0 4/5/2024 10:00 4/5/2024 14:15 4.25 COMPZN, WHDBOP NUND P N/U tree adaptor, and New 3-1/8" 5k tree 0.0 0.0 4/5/2024 14:15 4/5/2024 15:00 0.75 COMPZN, WHDBOP RURD P LRS on location, PJSM spot in and R/U in cellar 0.0 0.0 4/5/2024 15:00 4/5/2024 16:00 1.00 COMPZN, WHDBOP FRZP P Circulate 70 BBL's diesel down the IA taking returns up the tubing 2 BPM at 600 PSI. Vac back hole, R/D LRS 0.0 0.0 4/5/2024 16:00 4/5/2024 18:00 2.00 DEMOB, MOVE RURD P Hook up hole to IA and Tubing Bridle up, lower derrick in preparation to move Work pre-move check list. Tire man found flat on service module 0.0 0.0 4/5/2024 18:00 4/5/2024 21:00 3.00 DEMOB, MOVE RURD P Continue to RD equipment and secure stairs and landings, suck out tiger tank and cuttings box, Prep to change tire. Set top drive in rotory. Unpin top drive. Lower bridle lines to floor. Bridal up blocks. LD cattle shute and prep floor to lower derrick. Move pits away freom sub and change tire. 0.0 0.0 4/5/2024 21:00 4/6/2024 00:00 3.00 DEMOB, MOVE RURD P Prep camp and shop for rig move. Rig release at midnight. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 4/6/2024 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 6,842.0 3F-08 8/4/2017 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Post RWO 3F-08 4/4/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: 6.7 bbls Seal-Tite pumped into OA to repair surface casing leak at 258'. 4/27/2022 jbyrne NOTE: Waivered for water-only injection due to TxIA during gas injection & slow IA x OA. AIO 2B.087 6/29/2020 sheskin 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 38.0 115.0 115.0 62.58 H-40 WELDED SURFACE 9 5/8 8.92 37.0 3,029.4 3,029.3 36.00 J-55 BUTT 7" Tie-Back String workover 2024 7 6.28 24.2 1,850.0 1,849.9 26.00 L-80 HYD 563 PRODUCTION 7 6.28 33.1 7,009.0 6,307.4 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 36.3 Set Depth … 6,228.0 String Max No… 3 1/2 Set Depth … 5,701.7 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) 36.3 36.3 0.09 HANGER 7.000 3.5" FMC Gen 4 tubing hanger - H- BPVT - 3.5" EUE Lift threads FMC GEN IV 2.910 6,113.4 5,614.3 40.70 Mandrel – GAS LIFT 5.955 3.5" SLB MMG mandrel W/SOV SN# 24384-05 SLB MMG RKP latch 2.920 6,173.4 5,659.9 40.31 PACKER 6.276 3.5" x 7" SLB Blue max packer Vam Top x Vam Top SN# C23P-1914 SLB 1030584 59 2.885 6,199.8 5,680.1 40.13 Nipple - X 4.501 3.5" Halliburton 2.81" X nipple SN# 4890017-07 HALLIB URTON 2.81" X 2.810 6,221.1 5,696.4 40.04 OVERSHOT 6.000 Baker 6" OD x 3.58" ID Non sealing overshot Spaced out ~2' off fully located. Baker Non sealing 3.600 Top (ftKB) 6,220.0 Set Depth … 6,557.6 String Max No… 4 1/2 Set Depth … 5,955.2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection ABM-EUE ID (in) 3.00 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) 6,237.2 5,708.7 39.97 NIPPLE 4.540 CAMCO W-1 SELECTIVE NIPPLE 2.812 6,245.3 5,714.9 39.93 PBR 5.875 BAKER PBR w/ 10' STROKE 3.000 6,259.0 5,725.4 39.87 PACKER 6.000 BAKER FHL RETRIEVABLE PACKER 3.000 6,303.7 5,759.8 39.68 INJECTION 6.018 CAMCO MMM 2.920 6,380.6 5,819.0 39.54 BLAST JTS 4.500 STEEL BLAST JOINTS (OAL=129.3') 3.000 6,520.0 5,926.4 39.84 NIPPLE 4.520 AVA BPL NIPPLE 2.750 6,533.0 5,936.4 39.86 XO Reducing 3.500 CROSSOVER 3.5 x 2.875, ID 2.441, #6.5, L-80, ABM-EUE 2.875 6,533.8 5,936.9 39.86 SEAL ASSY 3.437 BAKER LOCATOR SEAL ASSEMBLY 2.406 6,534.4 5,937.4 39.87 PACKER 5.688 BAKER DB PERMANENT PACKER 3.250 6,538.1 5,940.2 39.87 SBE 4.250 BAKER SEAL BORE EXTENSION 3.250 6,549.2 5,948.7 39.89 NIPPLE 3.625 CAMCO D NIPPLE NO GO 2.250 6,556.8 5,954.6 39.90 SOS 3.750 BAKER SHEAR OUT SUB 2.441 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) 6,220.0 5,695.6 40.04 CUT WELLTEC MECHANICAL TUBING CUT @ 6220' RKB. TATTLE-TAIL INDICATED 3.56" BLADE TRAVEL. 12/30/2023 2.992 6,520.0 5,926.4 39.84 2.75" BPI AVA 2.75" x 29" BPI 3/13/2021 2.300 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) 6,113.4 5,614.3 40.70 1 GAS LIFT DMY RK 1 1/2 0.0 4/19/2024 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) 1,835.4 1,835.3 0.50 Collar - Stage 8.240 CMTR,TYPE H ES-II, HYD 563 L- 80 - S/N 5031046 HES II CMTR 6.276 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,385.0 6,435.0 5,822.4 5,861.0 C-4, C-1, C-3, C- 1, UNIT B, 3F-08 2/6/1997 12.0 APERF 4.5" SWS 51B HJII 6,491.0 6,502.0 5,904.1 5,912.5 UNIT B, 3F-08 2/3/1997 12.0 APERF 120 deg. phasing; 5" HJ II Csg Gun 3F-08, 4/29/2024 3:36:28 PM Vertical schematic (actual) PRODUCTION; 1,850.0-7,009.0 IPERF; 6,664.0-6,707.0 IPERF; 6,610.0-6,647.0 PACKER; 6,534.4 2.75" BPI; 6,520.0 CMT SQZ; 6,491.0 ftKB APERF; 6,491.0-6,502.0 SQZ PERFS; 6,435.0 ftKB CMT SQZ; 6,383.0 ftKB CMT SQZ PERFS; 6,385.0 ftKB APERF; 6,385.0-6,435.0 SQZ PERFS; 6,383.0 ftKB INJECTION; 6,303.6 PACKER; 6,259.0 CUT; 6,220.0 Nipple - X; 6,199.8 PACKER; 6,173.4 Mandrel – GAS LIFT; 6,113.4 SURFACE; 37.0-3,029.4 7" Tie-Back String workover 2024; 24.2-1,850.0 Liner Cement; 35.0 ftKB CONDUCTOR; 38.0-115.0 HANGER; 36.3 KUP INJ KB-Grd (ft) 41.00 RR Date 11/11/198 5 Other Elev… 3F-08 ... TD Act Btm (ftKB) 7,050.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292146400 Wellbore Status INJ Max Angle & MD Incl (°) 43.52 MD (ftKB) 5,200.00 WELLNAME WELLBORE3F-08 Annotation Last WO: End Date 2/6/1997 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 6,610.0 6,647.0 5,995.4 6,023.8 A-4, A-3, 3F-08 12/8/1985 4.0 IPERF 90 deg. phasing; 4" HJ II Csg Gun 6,664.0 6,707.0 6,036.8 6,069.8 A-2, 3F-08 12/8/1985 4.0 IPERF 90 deg. phasing; 4" HJ II Csg Gun Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 35.0 1,846.2 35.0 1,846.1 Liner Cement Cement in 7" casing From ES cementer to surface 3/31/2024 6,383.0 6,385.0 5,820.9 5,822.4 SQZ PERFS (SQZ CEMENT); 120 deg. phasing; SWS 4 1/2" Csg Gun 6,383.0 6,467.0 5,820.9 5,885.6 CMT SQZ C Sands 6,435.0 6,467.0 5,861.0 5,885.6 SQZ PERFS (SQZ CEMENT); 120 deg. phasing; SWS 4 1/2" Csg Gun 6,491.0 6,502.0 5,904.1 5,912.5 CMT SQZ B Sands 6,385.0 6,435.0 5,822.4 5,861.0 CMT SQZ PERFS (SQZ CEMENT); 120 deg. phasing; SWS 4 1/2" Csg Gun 3F-08, 4/29/2024 3:36:28 PM Vertical schematic (actual) PRODUCTION; 1,850.0-7,009.0 IPERF; 6,664.0-6,707.0 IPERF; 6,610.0-6,647.0 PACKER; 6,534.4 2.75" BPI; 6,520.0 CMT SQZ; 6,491.0 ftKB APERF; 6,491.0-6,502.0 SQZ PERFS; 6,435.0 ftKB CMT SQZ; 6,383.0 ftKB CMT SQZ PERFS; 6,385.0 ftKB APERF; 6,385.0-6,435.0 SQZ PERFS; 6,383.0 ftKB INJECTION; 6,303.6 PACKER; 6,259.0 CUT; 6,220.0 Nipple - X; 6,199.8 PACKER; 6,173.4 Mandrel – GAS LIFT; 6,113.4 SURFACE; 37.0-3,029.4 7" Tie-Back String workover 2024; 24.2-1,850.0 Liner Cement; 35.0 ftKB CONDUCTOR; 38.0-115.0 HANGER; 36.3 KUP INJ 3F-08 ... WELLNAME WELLBORE3F-08 TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger COPA Wireline Backlog – Batch 2 DATE: 03/01/2024 Transmitted: North Slope, KKuparukk Via SFTP drop - DEVELOPMENT - AOGCC – SCHLUMBERGER 2 of 2 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 192-103/ T38565 188-118/ T38564 192-050/ T38566 184-164/ T38567 185-284/ T38568 185-246/ T38569 203-091/ T38570 202-210/ T38571 202-206/ T38572 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.04 11:44:20 -09'00' 185-246/ Originated: Delivered to:29ͲNovͲ23 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & PerforatingAttn.:Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska99501 Anchorage, Alaska 99518 Office: 907Ͳ275Ͳ2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concernstotheattention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # 12VͲ14 50Ͳ029Ͳ21294Ͳ00 n/a Kuparuk River Packer Setting Record FieldͲFinal 5ͲMarͲ23 0 1 22WͲ01 50Ͳ029Ͳ21273Ͳ00 n/a Kuparuk River Leak Detect Log FieldͲFinal 16ͲNovͲ23 0 1 32WͲ01 50Ͳ029Ͳ21273Ͳ00 908964770 Kuparuk River Multi Finger Caliper Field & Processed 16ͲNovͲ23 0 1 42WͲ01 50Ͳ029Ͳ21273Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 15ͲNovͲ23 0 1 53FͲ08 50Ͳ029Ͳ21464Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 5ͲJunͲ23 0 1 63GͲ09 50Ͳ103Ͳ20129Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 22ͲNovͲ23 0 1 73HͲ13A 50Ͳ103Ͳ20089Ͳ01 n/a Kuparuk River Leak Detect Log FieldͲFinal 17ͲNovͲ23 0 1 83HͲ13A 50Ͳ103Ͳ20089Ͳ01 908964771 Kuparuk River Multi Finger Caliper Field & Processed 18ͲNovͲ23 0 1 93HͲ13A 50Ͳ103Ͳ20089Ͳ01 n/a Kuparuk River Plug Setting Record FieldͲFinal 17ͲNovͲ23 0 1 10 3JͲ15 50Ͳ029Ͳ21497Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 1ͲOctͲ23 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 1. 2V-14 PTD: 185-031 T38189 2. 2W-01 PTD: 185-010 T38190 3. 3F-08 PTD: 185-246 T38191 4. 3G-09 PTD: 190-067 T38192 5. 3H-13A PTD: 196-197 T38193 6. 3J-15 PTD: 185-289 T38194 12/1/2023 53FͲ08 50Ͳ029Ͳ21464Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 5ͲJunͲ23 0 1 Kayla Junke Digitally signed by Kayla Junke Date: 2023.12.01 13:20:08 -09'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: Kuparuk Oil Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7050 3281 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:James Ohlinger Contact Email: Contact Phone: 907-265-6312 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 3F-08 Other: Replace Tubing N/A Kuparuk River Field james.j.ohlinger@conocophillips.com CTD/RWO Drilling Engineer Size Kuparuk Oil Pool 6340' Plugs (MD): Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): 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 AOGCC USE ONLY Tubing Grade: Tubing MD (ft): Packer: 6259'MD/5725'TVD Packer: 6534'MD/5937'TVD N/A Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025632 185-246 P.O. Box 100360, Anchorage, AK 99510 50-029-21464-00-00 ConocoPhillips Alaska, Inc Proposed Pools: L-80 TVD Burst 6558' MD 115' 3029' 115' 3029' 16" 9-5/8" 77' 2992' Perforation Depth MD (ft): 6385-6435' (Squeezed) 6491-6502' (Squeezed) 6610-6647' 6664-6707' 6976' 5822-5861' (Squeezed) 5904-5913' (Squeezed) 5995-6024' 6037'-6070' 6307'7" 6278'6842' 6175' 11/6/2023 3.5"x2-7/8" Packer: Baker FHL Retrievable Packer: Baker DB Permanent SSSV: N/A 7009' 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 3:01 pm, Oct 17, 2023 Digitally signed by James J. Ohlinger DN: C=US, OU=ConocoPhillips, O=Wells - Coiled Tubing Drlling, CN=James J. Ohlinger, E=James.J.Ohlinger@ cop.com Reason: I am the author of this document Location: Date: 2023.10.17 10:38:04-08'00' Foxit PDF Editor Version: 12.1.2 James J. Ohlinger 323-570 SFD 10/19/2023 X X , ADL0025643 SFD DSR-10/19/23VTL 11/9/2023 X BOP test to 3500 psig Annular preventer test to 2500 psig 10-404 *&:JLC 11/14/2023 Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2023.11.14 13:01:33 -09'00'11/14/23 RBDMS JSB 111623 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 4, 2023 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: James J Ohlinger CTD/RWO Staff Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Producer 3F-08 (PTD# 185-246). Well 3F-08 was drilled and completed in November of 1985 by Doyon 9 as a Injector into the C & A-sands. The well was worked over in 1997. If you have any questions or require any further information, please contact me at +1-907-229-3338. The tubing will be replaced above the selective to allow a full subsidence repair of the 7" casing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y Samantha Carlisle at 7:17 am, Apr 28, 2022 'LJLWDOO\VLJQHGE\-DQ%\UQH '1&1 -DQ%\UQH ( MDQE\UQH#FRQRFRSKLOOLSVFRP 5HDVRQ,DPWKHDXWKRURIWKLVGRFXPHQW /RFDWLRQ$QFKRUDJH 'DWH )R[LW3')(GLWRU9HUVLRQ -DQ%\UQH DSR-4/28/22 RBDMS SJC 050322 'DWH (YHQW6XPPDU\ ([HFXWLYH6XPPDU\ )KDGDVXUIDFHFDVLQJOHDNORFDWHGDWa 6XQGU\ DSSURYHGD6HDO7LWHUHSDLURIWKHVXUIDFHFDVLQJOHDN7KHZHOOZDV %2,RQWRZDUPXSIRUWKH6HDO7LWHDSSOLFDWLRQ6HDO7LWHZDV SXPSHGLQWRWKH2$WKHQSUHVVXUHGXSLQVWHSVXQWLOVHDOLQJRIIWKH OHDN$6:0,72$DQG6:0,7,$ERWKSDVVHGSRVW6HDO7LWH LQVWDOODWLRQ3HUWLQHQWZHOOZRUNFRSLHGEHORZ $&(9$/685)$&(&$6,1*6($/7,7(5(3$,5&203/(7( ,QLWLDO7,2 2$)/# )89aEEO 37WRSVL3$66 3XPSEEORI33**HOVHDOLQWR2$ SXPSHGEEO*HOVHDOLQKUV7,2 58WULSOH[ SUHVVXUH2$WRSVLZaEEO7,2 PRQLWRUKU PLQ PLQ PLQ PLQ 3UHVVXUH2$WRSVLZaJDO7,2 PRQLWRUKU PLQ PLQ PLQ PLQ 3UHVVXUH2$WRSVLPRQLWRUZaJDO7,2 PRQLWRU KU PLQ PLQ PLQ PLQ %OHHG2$WRSVLZa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« :W/HQOE« *UDGH + 7RS&RQQHFWLRQ :(/'(' &DVLQJ'HVFULSWLRQ 685)$&( 2'LQ ,'LQ 7RSIW.% 6HW'HSWKIW.% 6HW'HSWK79'« :W/HQOE« *UDGH - 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T-PPPOT and T-POT tests 2. SBHP 3. Open lowest GLM in upper completion 4. CMIT-IA to 2500 psi 5. Cut the tubing at ~6220’ RKB in the middle of the 31’ joint above the W-1 Nipple. Rig Work MIRU 1. MIRU Nabors 7ES on 3F-08 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/3,500 psi. Test annular 250/3,500 psi. Retrieve Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to the cut ~6220’ RKB Cleanout Run 6. Perform a Cleanout run if necessary based on tubing condition and dress off 3.5” tubing stub if necessary. 7” Surface Casing Subsidence Repair 7. RU E-line: Run caliper & RCBL and log from ~6220’ MD back to surface. Confirm top of cement behind 7” casing; Estimated TOC ~ 6000’ MD (SLB CET Log 11/14/85) 8. Set RBP below TOC, pressure test or perform 30 min NFT, dump 50’ of sand on top of RBP. The tubing will be plugged off with cement from the straddle C-sand squeeze. 9. RIH with multistring cutter on DP, cut 7” casing above the TOC, POOH and stand back DP 10. Circulate out the Arctic Pack from 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 3F-08 RWO Procedure Kuparuk Injector RWO PTD #185-246 Page 2 of 4 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. 29. Pull BPV, freeze protect well, and set BPV if necessary. 30. RDMO. Post-Rig Work 31. Swap out SOV with a DV. 32. Pull RBP General Well info: Wellhead type/pressure rating: FMC Gen III (5000 psi) Production Engineer: Brian Lewis Reservoir Development Engineer: Lynn Aleshire Estimated Start Date: 11/06/23 Workover Engineer: James Ohlinger (265-1102/ James.J.Ohlinger@conocophillips.com) Current Operations: This well is currently shut in. Well Type: Injector Scope of Work: Pull the existing 3-1/2” completion down to the pre-rig tubing cut. Perform a full subsidence repair on the 7” casing. Replace 3-1/2” tubing with a poor boy overshot and stack packer. BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: MIT-T Passed 6/23/23 MIT-IA Passed 6/23/23 MIT-OA Failed 5/24/23, OAxForm ~264’ MD IC POT &PPPOT PASSED – 6/23/23 TBG POT & PPPOT PASSED – 6/23/23 MPSP: 3281 psi using 0.1 psi/ft gradient Static BHP: 3855 psi / 5742’ TVD measured on 06/05/23 3F-08 RWO Procedure Kuparuk Injector RWO PTD #185-246 Page 3 of 4 3F-08 Existing RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Conductor 115 115 16 15.06 Surface 3029 3029 9.625 892 Production 7009 6307 7 6.28 3-1/2" Tubing 6533 5936 3.5 2.992 2-7/8" Tubing 6557 5955 2.875 2.441 75" on a high risk pad Exisiting Completion 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface Camco DS Nipple @ 497' RKB (2.812" ID) 3-1/2" Camco MMG GLM @ 6191' RKB Camco W-1 Nipple @ 6237' RKB (2.812" ID) Baker 3-1/2" PBR 6245' RKB (3" ID) Baker FHL Packer @ 6259' RKB (3" ID) Injection Mandrel @ 6304' RKB AVA BPL nipple @ 6520' RKB (2.750" min ID) XO 3.5"x2.875" @ 6533' RKB Baker LTSA @ 6534' RKB (2.046" ID) Baker DB Permanent Packer @ 6534' RKB (3.25" ID) Baker SBE @ 6538' RKB (3.25" ID) Camco D-nipple @ 6549' RKB (2.25" ID) Surface Casing Production Casing Conductor A-sand perfs 6610' - 6707' MD C&B-sand Perfs 6385'-6502' MD RBP ~6279' RKB OAxFORM ~264' 3F-08 RWO Procedure Kuparuk Injector RWO PTD #185-246 Page 4 of 4 3F-08 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Conductor 115 115 16 15.06 Surface 3029 3029 9.625 892 Production 7009 6307 7 6.28 3-1/2" Tubing 6533 5936 3.5 2.992 2-7/8" Tubing 6557 5955 2.875 2.441 Subsidence is 75" on a high risk pad Exisiting Completion 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" GLM @ xxxx' RKB 3-1/2" x 7" Packer @ xxxx' RKB Nipple profile @ xxxx' RKB (2.812" ID) Poorboy Overshot Camco W-1 Nipple Baker 3-1/2" PBR 6245' RKB (3" ID) Baker FHL Packer @ 6259' RKB (3" ID) Injection Mandrel @ 6304' RKB AVA BPL nipple @ 6520' RKB (2.750" min ID) XO 3.5"x2.875" @ 6533' RKB Baker LTSA @ 6534' RKB (2.046" ID) Baker DB Permanent Packer @ 6534' RKB (3.25" ID) Baker SBE @ 6538' RKB (3.25" ID) Camco D-nipple @ 6549' RKB (2.25" ID) Baker SOS @ 6557' RKB (2.441" ID) Surface Casing Production Casing Conductor A-sand perfs 6610' - 6707' MD C&B-sand Perfs 6385'-6502' MD RBP ~6279' RKB OAxFORM ~264' 3029' Tubing Cut ~6220' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 3F-08 (PTD 185-246) Report of failed MITOA Date:Wednesday, May 24, 2023 3:20:57 PM Attachments:3F-08.pdf 3F-08 90 day TIO 5.24.23.png From: Byrne, Jan <Jan.Byrne@conocophillips.com> Sent: Wednesday, May 24, 2023 3:12 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 3F-08 (PTD 185-246) Report of failed MITOA Chris, KRU 3F-08 (PTD 185-246) (AIO 2B.087) Failed a diagnostic MITOA today. The well will be shut in and freeze protected as soon as possible. The plan forward will be to secure the well and perform barrier testing after which diagnostics will determine the source of the MITOA failure. A 90 day TIO trend and wellbore schematic are attached. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-66471 | M: (808) 345-6886 CHOKE FTP F IAP 2W0 1... T11/0 Plot - 3F-08 2000.... ____.d iW m 1W0 a 1000 +... 500 0 2SFeb23 10 -Mar -23 2&Mar-23 0 Ayr -23 MApr-23 01 -May -23 14MW-23 Date Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 6,842.0 8/4/2017 3F-08 pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pulled RBP 2/24/2022 3F-08 fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 38.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (lb… 62.58 Grade H-40 Top Connection WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 37.0 Set Depth (ftKB) 3,029.4 Set Depth (TVD) … 3,029.3 Wt/Len (lb… 36.00 Grade J-55 Top Connection BUTT Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 33.1 Set Depth (ftKB) 7,009.0 Set Depth (TVD) … 6,307.4 Wt/Len (lb… 26.00 Grade J-55 Top Connection BTC Tubing Strings: string max indicates LONGEST segment of string Tubing Description TUBING 3.5"x2.865"@ 6533' String … 3 1/2 ID (in) 2.99 Top (ftKB) 33.1 Set Depth (ft… 6,557.6 Set Depth (TVD… 5,955.2 Wt (lb/ft) 9.30 Grade L-80 Top Connection ABM-EUE Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model 33.1 33.1 0.09 HANGER 3.500 8.000 497.3 497.3 0.37 NIPPLE 2.812 4.540 6,191.4 5,673.7 40.19 GAS LIFT 2.920 6.018 CAMCO MMM 6,237.2 5,708.7 39.97 NIPPLE 2.812 4.540 6,245.2 5,714.9 39.93 PBR 3.000 5.875 6,259.0 5,725.4 39.87 PACKER 3.000 6.000 6,380.5 5,819.0 39.54 BLAST JTS 3.000 4.500 6,520.0 5,926.4 39.84 NIPPLE 2.750 4.520 6,533.0 5,936.3 39.86 XO Reducing 2.875 3.500 6,533.7 5,936.9 39.86 SEAL ASSY 2.406 3.437 6,534.4 5,937.4 39.87 PACKER 3.250 5.688 6,538.0 5,940.2 39.87 SBE 3.250 4.250 6,549.1 5,948.7 39.89 NIPPLE 2.250 3.625 6,556.8 5,954.6 39.90 SOS 2.441 3.750 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 6,520.0 5,926.4 39.84 2.75" BPI AVA 2.75" x 29" BPI 3/13/2021 2.300 Mandrel Inserts : excludes pulled inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 6,191.4 5,673.7 40.19 1 1/2 GAS LIFT DMY RK 0.000 0.0 2/28/2014 2 6,303.6 5,759.8 39.68 1 1/2 INJ DMY RK 0.000 0.0 2/6/1997 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 6,385.0 6,435.0 5,822.4 5,861.0 C-4, C-1, C-3, C -1, UNIT B, 3F- 08 2/6/1997 12.0 APERF 4.5" SWS 51B HJII 6,491.0 6,502.0 5,904.1 5,912.5 UNIT B, 3F-08 2/3/1997 12.0 APERF 120 deg. phasing; 5" HJ II Csg Gun 6,610.0 6,647.0 5,995.4 6,023.8 A-4, A-3, 3F-08 12/8/1985 4.0 IPERF 90 deg. phasing; 4" HJ II Csg Gun 6,664.0 6,707.0 6,036.8 6,069.8 A-2, 3F-08 12/8/1985 4.0 IPERF 90 deg. phasing; 4" HJ II Csg Gun Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,383.0 6,385.0 5,820.9 5,822.4 SQZ PERFS (SQZ CEMENT); 120 deg. phasing; SWS 4 1/2" Csg Gun 6,383.0 6,467.0 5,820.9 5,885.6 CMT SQZ C Sands 6,435.0 6,467.0 5,861.0 5,885.6 SQZ PERFS (SQZ CEMENT); 120 deg. phasing; SWS 4 1/2" Csg Gun 6,491.0 6,502.0 5,904.1 5,912.5 CMT SQZ B Sands 6,385.0 6,435.0 5,822.4 5,861.0 CMT SQZ PERFS (SQZ CEMENT); 120 deg. phasing; SWS 4 1/2" Csg Gun Notes: General & Safety End Date Annotation 4/27/2022 NOTE: 6.7 bbls Seal-Tite pumped into OA to repair surface casing leak at 258'. 6/29/2020 NOTE: Waivered for water-only injection due to TxIA during gas injection & slow IA x OA. AIO 2B.087 3F-08, 4/27/2022 1:58:53 PM Vertical schematic (actual) PRODUCTION; 33.1-7,009.0 IPERF; 6,664.0-6,707.0 IPERF; 6,610.0-6,647.0 SOS; 6,556.8 NIPPLE; 6,549.1 SBE; 6,538.0 PACKER; 6,534.4 SEAL ASSY; 6,533.7 NIPPLE; 6,520.0 2.75" BPI; 6,520.0 APERF; 6,491.0-6,502.0 CMT SQZ; 6,491.0 ftKB SQZ PERFS; 6,435.0 ftKB CMT SQZ; 6,383.0 ftKB CMT SQZ PERFS; 6,385.0 ftKB APERF; 6,385.0-6,435.0 SQZ PERFS; 6,383.0 ftKB INJECTION; 6,303.6 PACKER; 6,259.0 PBR; 6,245.2 NIPPLE; 6,237.2 GAS LIFT; 6,191.4 SURFACE; 37.0-3,029.4 NIPPLE; 497.3 CONDUCTOR; 38.0-115.0 HANGER; 33.1 KUP INJ KB-Grd (ft) 41.00 RR Date 11/11/198 5 Other Elev… 3F-08 ... TD Act Btm (ftKB) 7,050.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292146400 Wellbore Status INJ Max Angle & MD Incl (°) 43.52 MD (ftKB) 5,200.00 WELLNAME WELLBORE3F-08 Annotation Last WO: End Date 2/6/1997 H2S (ppm) DateComment SSSV: NIPPLE CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 3F-08 (PTD 185-246) Plan to BOI Date:Tuesday, April 5, 2022 9:04:02 AM Attachments:3F-08 10-403 Seal-Tite APPRVD.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Tuesday, April 5, 2022 8:58 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 3F-08 (PTD 185-246) Plan to BOI Chris, CPAI plans to bring KRU 3F-08 (PTD 185-246) online in the next few days as Operations resources allow to warm the well up for a SealTite repair of a surface casing leak at 258’. The SealTite work is scheduled for the week starting April 18th. Once the SealTite repair is complete a SW MITIA and SW MITOA will be performed. The approved work sundry is attached. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. 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Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL #1 1A-24 50-029-22984-00 907203651 Kuparuk River Packer Setting Record Field- Final 11-Jun-21 0 12 1E-34 50-029-22805-00 n/a Kuparuk River Leak Detect Log Field- Final 27-Jun-21 0 13 1E-34 50-029-22805-00 n/a Kuparuk River Plug Setting Record Field- Final 27-Jun-21 0 14 1J-168 50-029-23260-00 907188201 Kuparuk River Packer Setting Record Field- Final 3-Jun-21 0 15 2M-33 50-103-20240-00 907209681 Kuparuk River Packer Setting Record Field- Final 17-Jun-21 0 16 2N-347 50-103-20337-00 906961909 Kuparuk River Plug Setting Record Field- Final 14-Jun-21 0 17 2T-207 50-103-20287-00 907201320 Kuparuk River Leak Detect Log Field- Final 9-Jun-21 0 18 2T-207 50-103-20287-00 907199652 Kuparuk River Multi Finger Caliper Field & Processed 9-Jun-21 0 19 2V-03 50-029-21040-00 907177252 Kuparuk River Plug Setting Record Field- Final 27-May-21 0 110 3F-08 50-029-21464-00 907196137 Kuparuk River Plug Setting Record Field- Final 10-Jun-21 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:07/01/2021Wd͗ϭϴϱϮϰϲϬͲ^Ğƚ͗ϯϱϮϯϲBy Abby Bell at 3:53 pm, Jul 01, 2021 Kra _2"t---ce PrN 19s2A_-o Regg, James B (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophi1lips.com> Sent: Thursday, July 16, 2020 5:32 PM > To: Regg, James B (CED) l� ZI(��A Cc: Wallace, Chris D (CED); Brooks, Phoebe L (CED) Subject: RE: [EXTERNAL]RE: KRU 3F-08 (PTD 185-246) MITIA 10-426 Attachments: MIT KRU 3F-08 6-25-20 Revised.xlsx Hi Jim, Yes, that would be appropriate for the situation. Please see the attached copy with the revision. Sincerely, Sara. Ca -141& (He4k4v) /Stepha ei Pack Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n25490cop.com Cell: 907-331-7514 1 sara.e.carlisle@cop.com From: Regg, lames B (CED) <jim.regg@alaska.gov> Sent: Thursday, July 16, 2020 1:35 PM To: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Cc: Wallace, Chris D (CED) <chris.wallace@alaska.gov>; Brooks, Phoebe L (CED) <phoebe.brooks@alaska.gov> Subject: RE: [EXTERNAL]RE: KRU 3F-08 (PTD 185-246) MITIA 10-426 So the MIT remarks could just say "diagnostic test to amend AIC) 26.087'? Jim Regg Supervisor, Inspections AOGCC 333 W.7'h Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907- 793-1236 or ii m.re¢e@alaska.¢ov. From: Well Integrity Compliance Specialist WNS & CPF3 <n25490conocophillips.com> Sent: Thursday, July 16, 2020 1:09 PM To: Regg, James B (CED) <iim.rese@alaska.Rov> Cc: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Subject: RE: [EXTERNAL]RE: KRU 3F-08 (PTD 185-246) MITIA 10-426 Hi Jim, I apologize for the confusing nature of the email below. Here's the backstory: An application for approval to amend AIO 2B.087 (Continued water injection with TxIA on gas) due to the development of IA x OA communication was submitted prematurely to having a recent passing MIT -IA. I discussed this with Chris, and recognized that the application should not have been submitted without that data point. We agreed to perform the MIT -IA so that Chis could progress administrative approval to amend AIO 28.087 (pending a passing MIT - IA). This form is a record of the passing diagnostic MIT that was completed to supplement the request to amend AIO 28.087. Upon receiving documentation of the passing MIT -IA, the amendment to AIO 213-087 was approved. Please let me know if you need any further details regarding the state of the well, or have other questions. I've attached the previous email chains for reference. Sincerely, SarcoCcw141& (He 4rv) /Stepha u&Pach. Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n25490cou com Cell: 907-331-7514 1 sara.e.carlisle@cop.com From: Regg, James B (CED) <lim.regg@alaska.gov> Sent: Thursday, July 16, 2020 9:15 AM To: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Subject: [EXTERNAL]RE: KRU 3F-08 (PTD 185-246) MITIA 10-426 According to our records KRU 3F-08 already has an admin approval —AIO 2B.087—from 2014. The remarks are confusing. Is this indicating further deterioration of the mechanical integrity? Jim Regg Supervisor, Inspections AOGCC 333 W.7'h Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907- 793-1236 or iim.remPalaska.eov. From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Friday, June 26, 2020 3:25 PM To: Regg, James B (CED) <iim.regg@alaska.aov>; DOA AOGCC Prudhoe Bay <doa.aoecc.prudhoe.bay alaska.Qov>; Brooks, Phoebe L (CED) <phoebe.brooks@alaska,gov>; Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: CPA Wells Supt <n1030@conocophillipsxom> Subject: KRU 3F-08 (PTD 185-246) MITIA 10-426 0 Attached is the 10-426 for the non -witnessed MITIA done 6/25/20 to verify IA integrity for a waiver for the well to inject water with known slow IAxOA. Regards, Stephanie Pilch / alt: Sara Carlisle CPF3 & Alpine Well Integrity & Compliance Specialist ConocoPhillips Alaska Office: (907) 659-7126 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: orn.reggAalaska.cov: AOGCC.Insoectorsrolalaska aov' phoebe. brcoks(cbalaska go v chns.wallaceii1alaskaCov OPERATOR: ConocoPhillips Alaska Inc, ��G 17 FIELD / UNIT / PAD: Kuparuk / KRU / 3F Pad i DATE: 06/25/20 OPERATOR REP: Green AOGCC REP: Well 3F-08 INTERVAL Codes Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min, 4=Four Year Cycle F=Fail PTD 185-246 _ Type Inj W _ Tubing 1890 . 1890 1889. 1889 - N = Not Injecting Type Test P Packer TVD 5725 - BBL Pump 4.3 - IA 250 3300 - 3210 - 3190 Interval O Test psi 1500 BBL Return 17 OA 430 440 440 440 - Result P Notes: Diagnostic test to amend AID 28.087 ✓ Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA - Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE W Cotles TYPE TEST Cotles INTERVAL Codes Result Codes W=Water P=Pressure Test 1=Initial Test P=Pass G=Gas O= Other(Uescribe in Notes) 4=Four Year Cycle F=Fail S=Slung V= Required by Variance 1=Inconclusive I = Inausbial Wastewater 0 = Other (describe in nates) N = Not Injecting Form 10-426 (Revised 01/2017) MIT KRU 3F-089-25-20 Revised STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to iim.reggAalaska.gov: AOGCC.Insoeclors(Aalaskagov: phoebe. brooks(@alaska.aov OPERATOR: ConocoPhillips Alaska Inc FIELD / UNIT / PAD: Kuparuk / KRU / 3F Pad DATE: 06/25/20 OPERATOR REP: Green AOGCC REP: Well 3F-08 Pressures: Pretest Initial 15 Min. 30 Min. 45M 60 Min, PTD 185-246 Type Inj W Tubing 1890 1890 1889 1889 Type Test P Packer TVD 5725 BBL Pump 4.3 IA 250 3300 3210 3190 Interval O Test psi 1500 1 BBL Return 1.7 OA 430 440 440 440 Result P Notes: MITIA to verify IA integrity for a waiver Por the well to injection water with slow IAZOA. Before was bled until fluid was to surface prlor to pressuring up IA for MITIA. MITIA, IA id level was at 66', which is a fill up volume of 1.7 bible IA Well Pressures: Pretest Initial 15 Min. 0 Min. 45 Min. 60 Min. PTDType Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pre st Initial 15 Min. 30 Min. 45 Min. 60 Min, PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pr sures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes W = Water G = Gas S = Slurry I = Industrial Wastewater N = Not Injecting TYPE TEST Codes P = Pressure Test O = Other (describe In Notes) INTERVAL Codes Result Codes 1=Initial Test P=Pass 4=Four Year Cycle F=Fail V= Required by Vanance 1=Inconclusive O = Other (describe in notes) Form 10-426 (Revised 01/2017) MIT KRU 3F-066-2520 F Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Wednesday, April 1, 2020 1:03 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: 3F-08 (PTD 185-246) Report of IA Pressure Decrease Attachments: 3F-08 90 -Day TIO.pdf, 3F-08.pdf; MIT KRU 3F PAD PG 1 06-06-19 .xlsx Good Afternoon Chris, KRU injector 3F-08 (PTD 185-246) has recently exhibit unexplained IA pressure decrease. CPAI intends to conduct a 60 - day monitor period for initial diagnostics and to better understand the nature of the depressurization. This well most recently passed an AOGCC witnessed MIT -IA on 6/6/2019. We will plan to shut-in and secure as soon as reasonably possible as per A10 26.087 if communication appears to not be related to injection rate/thermal influences. Depending on the results of the monitor and diagnostics, the proper paperwork for continued injection or repair will be submitted. Please let me know if you have any questions or disagree with the plan forward. Attached is a schematic, 90 -day TIO plot and the most recent MIT -IA test results. Sincerely, Sarco CarUA& (}f "k4 ) / Stephawu,e_, Pilch Well Integrity & Compliance Specialist, WNS & C13173 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n25490cop.com Cell: 907-331-7514 1 sara.e.carlisle@cop.com MEMORANDUM State of Alaska Initial 15 Min 30 Min 45 Min 60 Min Alaska Oil and Gas Conservation Commission T In' I w "TVD DATE: Wednesday, June 12, 2019 TO: Jim Regg Fell qi 4 I1 P.I. Supervisor Fe SUBJECT: Mechanical Integrity Tests ([ CONOCOPHILLIPS ALASKA, INC. - 2457PTD 3MBBL 3F -O8 FROM: Guy Cook KUPARUK RIV UNIT 3F-08 Petroleum Inspector [A Ste: Inspector zzo zzo Reviewed By: P.I. Supry .TSF-- NON -CONFIDENTIAL Comm Well Name. KUPARUK RIV UNIT 3F-08 Insp Num: mitGDC190607180435 Rel Insp Num: API Well Number 50-029-21464-00-00 Inspector Name: Guy Cook 185-246-0 Inspection Date: 6/6/2019 Permit Number: p Wednesday, June 12, 2019 Page I of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3F08 —YPe T In' I w "TVD r 5725 Tubin 2457 600 2457 zas6 - 3280 32lo - 2457PTD 3MBBL 852460 'Type Test SPT Test psi 3000 [A zzo zzo zzo r Pumped: z 3 BBL Returned: s zzo Interval] ReQVAR P/F P Notes: MIT -IA to maximum anticipated injection pressure per AD 26.087. Job was completed with a Little Red Services pump truck and calibrated gauges. Wednesday, June 12, 2019 Page I of I • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Saturday,April 7, 2018 6:40 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: KRU Injector 3F-08 (PTD 185-2461 Monitor Extension Attachments: 3F-08 TIO Plot 90-day 4-7-2018.docx Chris, KRU injector 3F-08(PTD 185-246) has been under a surveillance monitor for the past 60-days to investigate previously suspected OA pressurization. The well passed both a diagnostic MITOA and MITIA, as well as inner casing packoff tests. The OA has appeared stable during the monitor period. The previously communicated monitor period ends today. However,due to temperature fluctuation during the monitor,CPAI intends to extend the monitor another 30- days while the well is on water injection to confirm annular integrity. If integrity is confirmed,we plan to return the well to its original waivered status and continue operation under the existing AA(AIO 26.087). If the pressures appear suspect,we will follow-up with an update and plan forward. Attached is a 90-day TIO plot. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 SCONE° 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Tuesday, February 6, 2018 3:09 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: KRU 3F-08 (PTD# 185-246) Attachments: 3F-08 90day TIO jpg; 3F-08.pdf Chris— KRU injector 3F-08(PTD#185-246,AIO 26.087) has shown a slow pressurization trend in the OA. There's a possibility this is a thermal effect,as the well has had a recent change in injection rate. To further assess the pressure trend CPAI proposes putting the well on a 60-day monitoring period of continuing water injection. During this time,we will perform diagnostics including an MITOA. If any of the diagnostics fail,or if there are continuing anomalies in the pressure trends,we will inform you and begin troubleshooting. Otherwise,we will treat the well per the existing waiver and AA. Attached is a 90-day TIO plot and a wellbore schematic. Please let me know if you have any questions or disagree with the plan. Travis Smith/Rachel Kautz Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 SCANNED 1 • • i_ T ci (� p X f0 orw • > " C.4 11 coo v o -.E 3 (LD o �/ N W to J- (0 > m (� J(`: 07 c0 v- -p c0 J• Y 0 Y OE U " +�+ > p�= V d Q C O La 41o• o v > m Q 0 u ' E a 6 [0p W h n h n n l7 ,- .- ,- � o Q m m j a a a a 0La1 u ti. 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N Q f0 UJ co e� V7 O O) O) i+ E (/) G1• E Z m Y%) Z O N N O 0 0 a+ ` f NEri W M M M M = m m ro Z C1 f0 N11C CD U '� 3 C v ' .--1 0 CA a ub Q I= a` a Q • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg —) DATE: Thursday,June 15,2017 P.I.Supervisor ' e1C1 ('l�I!7 SUBJECT: Mechanical Integrity Tests c l CONOCOPHILLIPS ALASKA INC 3F-08 FROM: Lou Laubenstein KUPARUK RIV UNIT 3F-08 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3F-08 API Well Number 50-029-21464-00-00 Inspector Name: Lou Laubenstein Permit Number: 185-246-0 Inspection Date: 6/6/2017 Insp Num: mitLOL170607162913 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3F-08 - Type Inj W `TVD 5725 ' Tubing 2700 2700 2700 ' 2700 PTD 1852460 Type Test SPT Test psi 3000 IA 670 3400 3300 3260 - BBL Pumped: 2.8 ' BBL Returned: 2.6 - OA 600 860 860 850 Interval REQVAR P/F P Notes: MITIA per AlO 2B.087 to MAIP SCANNED 'SEP 0 52N? f Thursday,June 15,2017 Page I of 1 i • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission j DATE: Wednesday,February 10,2016 TO: Jim Regg Supervisor C l Z1 It I( 0 SUBJECT:Mechanical Integrity Tests P.I.P (9� CONOCOPHILLIPS ALASKA INC 3F-08 FROM: Lou Grimaldi KUPARUK RIV UNIT 3F-08 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry.} NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3F-08 API Well Number 50-029-21464-00-00 Inspector Name: Lou Grimaldi Permit Number: 185-246-0 Inspection Date: 2/4/2016 Insp Num: mitLG160205075534 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3F-08 Type Inj W TVD 7 5725 Tubing 2788 - I 2790 • 2788 - 2787 PTD1852460 • Type Test SPT Test psi 3360 - IA 460 3360 - 3285 - 3255 - Interval1REQVAR P/F P OA j 180 270 • 270 _ 270 - Notes: Test required by A.I.O.2B.087.2.8 bbl's diesel pumped,2.2 returned.Good test.All pertinent documentation provided by Roger Mouser (DHD Lead). , ck I l I x, presS t,nreS. 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Annotation End Fite IFA 0,d IN -916 Pelee..Dale 8F-06.MN0D1694725AM SSW NIPPLE 1 (L !Least WO I 2/6/1997 I 11= 11 /11/1985 1 '4,1.(.1.14,010 UHWI Anaslehlon " I1'pin{1561 I End Dale e,..,I.-, r Last Mod By I End bale 196t riv 5161 ('1.'.Fr 8/30/2019 Rev Rpa3on JAG hi 6hH //515 HANGER m, -•'I_.I Casing Strings Gens Descrlp0wl OD Gni 111 44 Top DAM .9e[f1aWh WOten(I.'Oietle Ino-lamed CONDUCTOR 16 15002 300 115:1 1160 r -.-t40 WELDED Casino Desclpeon 00 51{ 104.1 Top PIKS) set Depth OtKB1 Del Depth(TVD)...1 WALen(I..IGratte Tap Thlead-.-_ SURFACE II 5'0 0)7I 1'"I 3.0294 3,029.3 36!31.55 BUTT ICas,-np0escrpu61 00 ON ', /Top KIKRI Set DepH,DKR1 0,1 Depth(TVD)...MaRen n.,.ltirade Tap'nnod PRODUCTION t -s:,I 7.00911 6.307.4, A0311J'_?a 111C __, Tubing Strings Tieing Oesception ',.'-n 5u. 1 nl lop maw 4,,i D.pih III 141 D+re./WM I.H:1163* Grade Top Connection TUBING � l:1 2992 ss' 955761..... 5,9552 9.331 81:: ABM-EUE 3.512.885'6,6533' 1 Completion Details CONDUCTOR,%6.1150 - m''."'" ._.-.-.•------.__A—. Nominal ID Top von!rvNoint' T Ind1'` Item O ::u- pnl I .. _ 531 3OPpp 3:i 0.99 Ft4NGt11 'FMC GEN i1I'TURING HANGER 3500 _ 4973 .-, .- CAMCODSN PPLE 2917 NIPPLE.4913 623,)" 5,/61T7-3117-triJ4t' `' CAMCO.1.-1'ELECTIVE NIPPLE 2 912 es x,245.2 5,714.6 9993 PDR BAKER PHR wr 10'STROKE 3 mm - 6,259.0 5.7254 9987'PAC4LER RAKER FIJI RE TRIEVABLE PACKER 3.1100' 6.380.5 .-.9819.0 9954 l3UlSt3TS SIEI-I.Bi AST 3:76: r:i.,t_!2i 3; 3.060 5,926.4 3994 NiPPS.E AVA BPI NIPPLE 2750 6,5330 5,936 3 3886 XO Reducing CROSSOVER 3 5 e 2 875,10 2.441,68 6,L-80,ABM- 7.975 /III 8533.7 5936.9 99151;1 6'' i'` BAKER LOCATOR SEAL ASSENEL, --- 7 450 SURFACE,37.090tn 4 - ( 6634.4 5,$2/.4 36.87 &'..!:1, RAKER 11)B PERMANENT PACKER -_-- .1.250 6536.0 5, R SEAL BORE EXTENSION 3 250 9649.1 6.946Y' 39.60 HIPPIE CAMCO U NIPPLE NO GO --. 2.250 DAB V47;6.7044 __ 6550,8 5.6346 3590 SOS —BAKER SHEAR OUT SUB r 2.441' other fnlio1*1GVk Un*rstrLSVebT*plugs.VIIW3,pumps,Rah,etc.' Topp�p((1181 Top Incl 1-"",-.7;%1 P(OKel 4 i NQ 1 pea Com 1n i!20l4 IDIIN , E,:70.039 ,;, 5,4' 3 teVE-0 AVA 2.75'%29e13PC (10/2014 2316 NIPPLE;51312AI Perforations&Slots SMI Dens Top MD) DD.11V13) (ehol416 Paas 02410 TOP(" BOn80Q1 101;01 III 11 70460 01P 6 ltyo Can :kl: I 5,872 5.9010 C-4,C.S.C-s. 2.5=1977 170 Ar'EIIF 4.5'511'5519 Rill 087,.n=t:, . C-1,UNIT 0, 3F-08 6,491.0 6,502.0 5,9041 5,917.5 L.'NIT A 1-Or 2.111997 12.0 APE-111 120 deg phasing;5'11.1 II Cog Gen 0.610,0 6.1470 5B95.4 5.02 . -.A-3.7. TCt�63 46 IPFRE 90 deg phasing;4'FU IUECT10c4 6 303 6 06 Cag Gun _-. :8r',.1 , I ., .. ' I'i" A. 1.I. ,-q ..1 r .F._• TT, .l. C18/0411 I Cement Squeezes I..,,I)s'I: 111n IIV01 'cn r'XC 41m PM!!! WAR; INK=' L\`. 01041 Die Com 6,3930 6,3850 58209 5.8774 CMT 5C7 2(3/1''7 HESITATION DOWN SPEW 7.965 Oa 43.10—. :9.7:14T, , 55$ vie.. f:LW. an-t..-0, 71116/117 is.'Pn":Yi1-RFI' -. _.. .CJ11 7t lIl''l/00' ATIZATIRIWN - B.G + 95020 5.9041+ 4 412 5 0611 SC7 778!1697 HES1TATp41' AP1RF,0,191 097020.. j 060.0 6, I 1 : ,!5 T I CMT SO2 7/5/1997 F£SRATIDN DOWN P. SI Mandrel inerts 31 Tnp(TVD) Valva talon roll SNP TPA 900 6LEEVE-0:6,5670 I� Top INKI3 I''1. 07/9T M5YI OD 04 Sem Trope 7167 p{ r 81,9 Ran Date Coes NppaCi?2011-1+.�.+ ��I: 11 Q19r4 t. :...,1 _.(tdt.t 116 t .3il;"..._.NAY IR bl'100 90-'d36t701•F 6,3036 .. ."I.II.: i t I IAA 1(Y'RK'" D00g ISO 7.5:1597 Nuies:Gent r 11&Salt } End INN AmntatSOn NOTE V'ew SrhemMrtwr Alas'p S11,a1nnlo90 5/3/2074 ':OTE'Weivele3Tx IA Communication,'i 111e1 n(eclwn O0".y - - SEAL ASST 61111 7----._. -....- PACKER, A. PAOKER,4W44o. ODE:6,531.0 ,.. 1 NIPPLE;8.161 N 605.46E69 ti (PERE.6.610060470 'PERE.6,66416707.0,-... .- ,'1,1::,1.^31.13 I 111110--- _._• • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, June 07, 2011 TO: Jim Regg P.I. Supervisor er 6(14(1( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3F-08 FROM: John Crisp KUPARUK RIV UNIT 3F-08 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv, NON-CONFIDENTIAL Comm ---- W N ame: KUPARUK RIV UNIT 3F-08 API Well Number: 50029214640000 Inspector Name: John Crisp Insp N um: mit.ICr110605214118 Permit Number: 185-246-0 Inspection Date: 6/5/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I 3F-08 'Type Inj. G TVD 5725 IA 1160 2080 1980 1970 - p 1852460 TypeTest SPT Test psi 1500 OA 220 250 250 250 _Interval 4YRTST P/F P Tubing 2750 2740 2750 2750 j Notes: 1.9 bbls pumped for test. No problems witnessed. Loe injection pressure with gas due to choked back injection. ? nl` • 'Lu,1 Tuesday, June 07, 2011 Page 1 of 1 05/12/09 ~ ~ ~~~ ., ~ ~~~ ~ ..a- f~ l~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description NO. 5228 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 3A-18 AYS4-00069 PERF/SBHP SURVEY 6 - 04/26/09 1 1 3C-08 B146-00033 GLS S- ! 04/21/09 1 1 2M-25 B14B-00034 GR/TEMP LOG /9!- - 04/22/09 1 1 1R-19A AYS4-00065 _ SBHP SURVEY ~rG ~~ ~fo 04/23/09 1 1 3G-13 AYS4-00067 ` SBHP SURVEY - 04/24/09 1 1 3G-05 AYS4-00066 SBHP SURVEY 04/24/09 1 1 3F-07 8146-00038 SBHP SURVEY - ~ 04/24/09 1 1 F-08 8146-00037 SBHP SURVEY 04/24/09 1 1 3M-25A 6148-00040 SBHP SURVEY 04/25/09 1 1 3K-OS B14B-00039 SBHP SURVEY C./ 04/25/09 1 1 2N-318A AWJI-00026 MEM BHP SURVEY -Q 04/27/09 1 1 2Z-07 B14B-00045 SBHP SURVEY ~. 04/29/09 1 1 2Z-01A 6146-00044 SBHP SURVEY ~-~ ~ 04!29/09 1 1 3K-102 ANHY-00080 GLS 04/30/09 1 1 2W-06 B04C-00036 PRODUCTION PROFILE 05/02/09 1 1 2W-12 B04C-00037 PRODUCTION PROFILE - p 05/03/09 1 1 3C-02 604C-00045 POWERCUTTER W/SBHP SURVEY ~ 05/09/09 1 1 1 J-120 B04C-00043 GLS ~- ~ Q O 05/08/09 1 1 31-11 B04C-00044 SMALL TBG PUNCH W/SBHP 05/08/09 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~~ • l\tlEJ\-10RANDUlVI . TO: Jim Regg 1'.1. Snpuvisor . ; ¿,¡ FRO.'!: John Crisp Petrolcum Inspector Well Name: KLiPARUK RIV LiNIT 3F-08 Insp Num: mltJCr070612111457 ReI Insp Num: Packer -Well! 3F-08~Type Í~j~-W-TVD P.T.D---rts52460 :Typ~Test: SPT Test psi _._-_....._.~-_.._..__.._- -- State of Alaska . \Iaska Oil anù Gas Conservation Commission --ì D \TE: Iuciùal June 12. SL BJECT: \1echanlcallntê:;nt, Töti -\L \\ K-, KUPARUK RIV UNIT 3F·OS S,'C: Inspector NON-CONFIDENTIAL Permit Number: API Well Number: 50-029-21464-00-00 185-246-0 Depth \ <ß5-g..4-b Reviewed By: PJ. Suprv:)ß2-- Comm Inspector Name: John Crisp Inspection Date: 6í8!2007 Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. -------¡ - -~--.._.._.~ ~----·_________¡_---~-------·-~-1·--~-· ---...,....---------.- 660 3020 2980 2970 5726 IA 1500 OA Interval 4YRTST P/F P --_.._--~--- _..._-_.._-~~---~.__.---------- Tubing i Ii, : ------_._-~._---~._.._-----_.__._--~-------_..~._-_._--------~-~~._- Notes: 2.8 bbl's pumped for test Tuesday. June 12, 2007 ---------,-.._~ ;, , ; I ' , _______~_._______._~._____..._...._m.._~ ---i- 2460 -~._- 490 2460 2462 700 __ 7001_~0~~__ sCANNED JUN 2 1 ¡nfll 2461 Page 1 of I . ~ ConocoPhillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 2, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite lQ2,..AWtlCV Sf? 0 3 2006 Anchorage, AK 9950 1 '~~'Hiío ' \'1I~~~'-f(P Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRD) 3F Pad. Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of 2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, RG casing filler, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on August 14, 2006 and is reported as follows. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and sealant were pumped in a similar manner August 21-29,2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Jerry Dethlefs or myself at 907-659-704~,ì{you have any questions. /' ./ Sincerely, ,r? ;f'1 /// ~ h , . :!'¿;/ /" /:7' . ~.. /'jl.·.·/~.../;.· 1'7. "~/~ ;Ý " þ .rVf..ø/ ~V ./ :( M.J . love land ConocoPhillips Well Integrity Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement and Sealant Top-off Kuparuk Field 8/31/2006 Initial Top Cement Final Top Sealant Well Name PTD # of Cement Volume of Cement Cement Volume Sealant Feet Barrels Feet Date Gallons Date , . ·:3F":01~,. . .. ' t&~2~5' . K >: '~.f'..' NA , ','~ '" .', 7:~'" ," ".8/~1!2,nJlð' , ' . , 3F-02 1 85-226 24' 7.0 8/14/2006 7.5 8/21/2006 ·~F~P3: : ", ,'.. " tª$f~21' . , I. '. . J3':if~' , . I·,·· 2.3· ,,' . ,:. :. '. L 8/14.12~lºQ: ,.\ ' . 1,;k~:"" . : ..'.. ·8/~11.(ø:Q~:· -:-'-, 3F-04 185-228 80' 22.7 1 0' 8" 8/14/2006 38.2 8/21/2006 ·3f""~:.,. ~ 1:' 5:1 , ,: . ". '. . : ;·8Jit.f/~{jt16;·:· , .. 7.5 . . :·:;gEtf¡:(Õ06:o 3F-06 185-244 Did not modify 3;.i0>7 " '. "1~~~2~ .' .. " .' A.Qk','· . ,. ·6;6 , I '8'/1:4/20.06 { "..:' 7.5 " .8/2:1J2~106 3F-08 185-246 1 1 '4" 2.6 8/14/2006 6.6 8/21/2006 aF-ŒIt '. I 18~å'IO ,.' Did not modify 3F-1 0 1 85-271 SF NA NA 6.6 8/21/2006 3F,,:"U : '., 't85:"~12 ',: ," ':SF . f. .. ·,.NA, . N:A.· , ., ' .1..7 , .. 8k2a'i4f>JI6 3F-1 2 1 85-273 7'4" 1 .8 8/1 4/2006 6.2 8/23/2006 " · "1:9~f11;;. NA ... '. ' '··'··21í. I . " lJi'E: " ....;a-~2S))~ÔØß;·· I· ~ 1 85-292 Did not "UI AllY ."Co i:.'·, 11l5:!;t~'·,· . 2:4., . ....,' .... '. ' . .8'jf~t20D64': r'., A 7-:." '. ,c- :S:&3í2.ØO~·. . ~ , - c_.' _ >J~.'-' '. ' "' -. _ - ~ê~;'-, .':0,_ ~_"_,,,^,,~,,- _~ _'_d._' 3F-1 6 .di1 51 6" NA NA 2.7 8/23/2006 3f.:1T ,:1't" ' '. .' ..' 3.1 " . , " . " 811:4'/~ØÈl$; < .. t '8. .' . .' 8'i2.ß¡2'O'ttèL . .,.1..., '. 3F-1 8 1 96-1 1 2 4' NA NA 28 8/23/2006 '. ß¡=~J'.9; ~ -. · "2Ø~¡\Ø;1;6 ~:; 'A~' , " ¡ ',.. ..N)X.. ¡ .... ',8" ',' t····, 2, '. . ,.¡8~~t2ÐOfh 3F-20 199-079 36" NA NA 1 7.7 8/23/2006 3F-21 . . . 200120$ . 45" , NA NA . 31 ' '8/Z1)/2Ö06 . , STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us and Bob_Fleckenstein@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. KuparuldKRU/3F 06/05/03 Arend/Brake - APC Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. Well 13F-07 P.T.D. 11852450 Notes: Well 13F-08 P.T,D. 1'1852460 Notes: Type Test Test psil 1500 I Casing I 11001 23001 22751 22751 P/F Type Test Test psiI 1500 I Casing I 8001 22751 22501 22501 P/F P.T.D. I1852720 Type Test TestpsiI 1500 I Casingl 11001 23001 ' 22751 22751 P/F Notes: P.T.D. I1852730 TypeTest Test psiI 1500 I Casing I 11501 22751 22501 22501 P/F Notes: P.T.D. I1852930 Type Test TestpsiI 1500 I Casing I 14001 23001 22801 22801 P/F Notes: P.T.D. I1961510 Type Test Test psiI 1500 I CasingI 01 23001 23001 23001 P/F Notes: Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover O = Other (describe in notes) MIT Report Form Revised: 05/19/02 2003-0605_M IT_K RU_3 F-07_-08_-11_-12_-15._-16A.xls 6/25/2003 ?CRU MIT's Subject: KRU MIT's Date: Fri, 6 Jun 2003 15:28:32 -0800 From: "NSK Problem Well Supv" <rtl 617~conocophillips.com> To: bob_fleckenstein~admin.state.ak.us, tom_rnaunder~admin.state.ak.us, jim_regg~admin.state.ak.us CC: "nl 617" <n1617~conocophillips.com> Attached are the 4 year cycle MIT Results for 3B and 3F. Please call with any questions. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 (See attached file: MIT KRU 3F 06-05-03.xls) (See attached file: MIT KRU 3B 06-05-03.xls) %~_~MIT KRU 3F 06-05-03.xls Name: MIT KRU 3F 06-05-03.xls Type: EXCEL File (application/msexcel) I, Encoding: base64 ~.~MIT KRU 3B 06-05-03.xls MIT KRU 3B 06-05-03.xls ~1~ Name:Type: EXCEL File (application/msexcel) I' Encoding: base64 I of I 6/25/2003 4:37 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us and Bob_Fleckenstein@admin.state.ak.us OPERATOR: FIELD / UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk/KRU/3F 06/05/03 Arend/Brake - APC Chuck Scheve Well 13F-07 P.T.D. I1852450 Notes: Packer Depth Pretest Initial 15 Min. 30 Min. I TypelnjI Gp I T.V.D. I 5850 I Tubing I 25001 25001 25001 25001 Interval Type Test Test psi I 1500 I Casing I 11001 23001 22751 2275J P/F Well 13F-08 P.T.D. I1852450 Notes: Type Test Test psiI 1500 I Casing I 8001 22751 22501 22501 P/F P.T.D. I1852720 Type Test Test psiI 1500 I Casing I 11001 23001 22751 22751 P/F INotes: P.T.D. I1852730 TypeTest Test psiI 1500 I Casing I 11501 22751 22501 22501 P/F Notes: P.T.D. I1852930 TypeTest Test psiI 15oo I, Casing I 14001 23°°1 22801 22801 P/F Notes: Well 13F-I 6A P.T.D. I196J510 Notes: Type Test Test psiI 15oo I Casing I 01 23001 23001 23001 P/F Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey. D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover O = Other (deScribe in notes) MIT Report Form Revised: 05/19/02 MIT KRU 3F 06-05-031 .xls 7/10/2003 't MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich Commissioner FROM: Chuck Scheve Petroleum Inspector DATE: June 5, 2003 SUBJECT: Mechanical Integrity Test Conoco Phillips 3F Pad KRU NON- CONFIDENTIAL Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: P.T.D. Notes: 3F-07 I Type 185-245 Type 3F-08 I Type 185-246 Type 3F-11 I Type 185-272 Type 3F-12 IType 185-273 Type 3F-15 IType 185-293 Type Packer Depth Pretest Initial 15 Min. 30 Min. I ,nj.I G I T.V.D. I 585O I Tubingl~00 I~00 I~00 I~00 I,nterva, I4I testI P ITestpsil 1463 I CasingI 1100I 2300I 2275I 2275I P/F I -PI "~ Inj.I G I T.V.D. I 5726 I Tubing 13650 ] 3650 13650 ] 3650 I,nterv~,l 4I testI P I Testpsil 1432 ICasingI 800 I 2275l 22501 22501 P/F I--P I '" '~i.I s i T.V.D. I~ I T~,~,I~O I1~0 I~o I~0 I,~terv~,I4 I '--~' testI P ITestpsil 1400 I CasingI 1100I 2300I 2275I 2275I P/F I -P I '.i.Is I T.V.~. I~ I Tubing 11300 11300 11300 1~300 I,,te,,,~,l 4 I ~ testIP I Testpsil 1407 I CasingI 1150I 2275I 2250I 2250I P/FI P I '.i.I ~ I T.~.~'. I~"~ I Tu~'"" I~00 I35°° I35°° I3500 I'nter~a'l 4 testI P ITestpsil 1418 ICasingI 1400I 2300I 2280I 2280I P/F I --P 3F-16A 196-151 Type test Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. 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 Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to Conoco Phillips 3F Pad in the Kupamk field and witnessed the routine 4 year MIT's on the above listed 6 wells. The pretest pressures were observed and found to be stable. The standard romulus pressure tests were then performed with all wells demonstrating good mechanical integrity. M.I.T.'s performed: _6 Number of Failures: O Attachments: Total Time during tests: 4 hours cc: MIT report form 5/12/00 L.G. SCANNED jUL O '7 2.003 2003-0605 MIT KRU 3F-16A cs.xls 6/24/2003 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 93 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphk~__ An.c_horage, AK 99510-0360 servi~__x Kuparuk Unit 4. Location of well at cur/ace 8. Well number 15' FNL, 5276' FEL, Sec. 29, T12N, R9E, UM (asp's 5o85oI, 59858o5) 3F-08 ,At top of productive interval 9. Permit number / approval number 1170' FSL, 1197' FWL, Sec. 20, T12N, RgE, UM 185-246 / ,At effective depth 10. APl number 50-029-21464 At total depth 11. Field / Pool 3793' FNL, 3801' FEL, Sec. 20, T12N, R9E, UM (asp's 509969, 59a7511) Kuparuk Oil Pool 12. I~'esent well condition summary 'Total depth: measured 7050 feet Plugs (measured) true vertical 6340 feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 115' 16" 2so sx AS, 115' 115' SUR. CASING 2936' 9-5/8' 865 sx PF E & 350 sx PFC 3029' 3029' PROD. CASING 6916' 7' 300 sx Class G & 175 sx PFC 7009' 6307' [:!:~ :~ :~ :~ :~:K:i:i :i:i ~ :i-": :~ :! :~ :~ :~:::i :~:i :i :~ :i :i:~ :~ :i :;:i :~ :! ~ :i :i :i:! ::' :: :! :: :::::~ :! :! :.: :.: :~ :i:_=:i-'_: :: :i :: :: :! :i :i :~ :~ :~:~ :.'-Si :-; :i :: :.: :~ :~ :i-'.:::' :.:_=:E :.::[:~ :: :: :~ :Z-:~ :.-' :~ :!:! ::' :::::: :: :: :::: :~ :~ ~ :_::i:i:~:: :: :::: :: ::::~:i :i:i:.':::: :5::: :::: :.' :: :~:." :i:i:.= '-!-'.':i-.' ~:~:~:~:~:~:~:~i~i~:~:~:~:~:~:~:~:~:~::~:~:~:~:~:~::~:~:~:~:~:~:~:~::~..~`.~:~..~:~:~::~:~:~:~ 13. Stimulation or cement squeeze summary Treatment description including volumes ...........................................................................................................................................................................................used and final pressure 14. Representative Daily Average Production or Injection Data Oit-Bbl Gas-Mci .W_..a.t.~.-...~..! ...... Casi_n.g.Pressure Tubing Pressure ~5>~5>~:~:`:~:~.~>:~:~~X~>:~:~:~...:~:~:~:~:~:~:~...~:. 15. Attachments Copies of Logs and Surveys run __ Daily Report 17. I hereby certify that the foregoing is true And correct to the best of my knowledge. Questions? Call Jeff Spencer 659-7226 Signed "~-~.~~- Title Production Engineering Supervisor Date,/~~ ,/eft A. ;. S~encer Prepared by Robert Chdstensen 659-7535 Form 10-404 Rev 06/15/88' SUBMIT IN DUPLICATE /, 3F-08 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary ?" : :' .: ". :'i ;'i. ;;:. ~:". ,:. ~if:i'!.!!:~!~ii~i~-::~:i:!?!i'~:'''i!i:~ ;~.~;:!i:'i/:/:~:~!ii~;~'7:!i;:~i:;.-'::~ · ARCO Alaska, Inc. Post Office Box 10036~'-~ Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 5, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3F-08 (Permit No. 85-246) W. el.1 Completion Report Dear Mr. Commissioner: Enclosed is the well completion report to cover any changes made to the completion during the recent workover operations on KRU 3F-08. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Drill Site Development WSI/skad STATE OF ALASKA ~'- ALASK-~' OIL AND GAS CONSERVATION C-~IMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG !1. Status'of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service Water Injection . 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 85-246 31 Address 8~ APl Number P. O. Box 100360, Anchorage, AK 99510 50-029-21464 18' FNL, 1' FWL, Sec. 29, T12N, RgE, UM!~i Kuparuk River Unit At top of productive interval ':1'0. Well Number 1170' FSL, 1197' FWL, Sec. 20, T12N, RgE, UM 3F-08 At total depth ':f 1 Field and PE'ol 1487' FSL, 1470' FWL, Sec. 20, T12N, RgE, UM ........................................... Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. 93' RKBI ADL 25632, ALK 2565 i12. Date Spudded 113. Date T.D. Reached i 14. Date Comp., Susp., or Aband.i15. Water depth, if offshore 116. No. of Completions i 11/4/85 J 11/09/85 J ~ 2/7/97 J N/A MSLJ Two 1¢. T~tal [~ep~'h (M'D+T'v[~i'118~' Plug Back Depth (MD+T~)D)II'9. Directional survey[~2~)~ Depth where SSSV set~211 Thickness Of Permafrosl 7050 6340 ~ 6920 6236 FT~ I~lYes C~No I N/A MD[ 1650' (Approx.) 22. Type Electric or Other Logs Run ,.. 23. CASING, LINER AND CEMENTING RECORD CASi'NG ....... , ..... S_E_---T~--i~IG DEPTH HOLE " SIZE VV]'. PER FT. GRADE TOP Boq-roM SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf. 115' 24" 250 sx AS II 9.625" 36.0# J-55 Surf. 3029' 12.25" 865 sx PF 'E' & 350 sx PF 'C' 7" - 2-6.0~ .... ,J:'55 SMd. 7009' 8.5" 20b--~-x-i2~as~-(~--8;--i75-~--PF'C-; ............................................... 23'i Perf'oratiOns open to Productiok (MD+TVD'Of TOp and BottOm 251 TUBING RECORD " and interval, size and number) ....... SiZE - DEPTH SET (MD) -PACKER SET (MD) 3.5" X 2.875" 6558' 6259' & 6534' MD TVD MD TVD ......................................................................................... 6385'-6435' (reperfed during 26. AC~D', FRACTURE, CEMENT SQUEEZE, ETC. workover) .... 2.5 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED .... ~-~8:~r-6~-6~~- '- cl0w~-~sq~'%z-ed during W0-rk0~-~ ............ 6610'-6647' - 649ir-6502'- ' --80wn~squeezed'during workover .......... 6664'-6707' ~ ........................................................ ........................... 27. PRODUCTION TEST Date First'Production IMethod Of operation (FlOWing, gas lift, etC.) ......... j Water Injection Date of Test II--J(~urs Te~ted PRODUCTION FOR OE"I~-[- ........ GAS-MCF WATER-BBL i CHOKE SIZE ~ GAS-OIL RATIO J TEST PERIOD ' [ iFiS~V T-ubir~gl~Sin~ Pr~ss-~-i;~,LC[ii_A-i:ED -.- .... -OiL:B~i_ ........... G-~,~:-M-si: ....... WA-i:i~i~-i~§-L- ...... "-OJ[-~-~)-i-i~:'A-F~l (-Cs~i~) ............ Press. i 24-Hour RATE . 28. CORE DATA Brief description of'lithol~gy, porosity, fractures, apparent dips and presence of oil, gas or water...Submit core chips¢_ ~/~A~ 0 ." 1997 ORIGINAL AJaska Oii& Gas Cons. Commission Anchorage ~ - Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Marl 30. Formation Tests , Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. 31. List of AttaChments Summary of Daily Drilling Reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed z ~ ~, I~ .................... ~__~ ........ :_._ _~_.~_~_~ ....................... __T_!_tle ___ t~ _~_ [__~l~._t.~_~.~ .... ~H~.-~.4EE~" ............ .D....a.t.e ...... ~-5'c[-~ Prepared By Name/Number: 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 $: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Date: 3/5/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:3F-08 RIG:NORDIC WELL ID: 998712A TYPE: AFC:--998712A AFC EST/UL:$ 775M/ 905M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD: START C0MP:01/31/97 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-21464-00 01/31/97 (Cl) TD: 7050' PB: 6920' SUPV: DLW DAILY:$ 02/01/97 (C2) TD: 7050' PB: 6920' SUPV: DLW DAILY: $ 02/02/97 (C3) TD: 7050' PB: 6920' SUPV:DLW DAILY:$ 02/03/97 (C4) TD: 7050' PB: 6920' SUPV:DLW DAILY:$ 02/04/97 (C5) TD: 7050' PB: 6920' SUPV: DLW DAILY: $ 02/05/97 (C6) TD: 7050' PB: 6920' SUPV:DEB DAILY:$ 02/06/97 (C7) TD: 7050' PB: 6920' SUPV:DEB DAILY:$ PREPARE TO PULL TUBING TO MW:10.0 BRINE Turn key rig move well to well from 3F-03 to 3F-08. Accept rig for operations @ 1130 hrs. 1/30/97. Pump sea water down 3.5" tubing to kill well. Test BOPE and manifold to 250/3500 psi, annular to 300/3000 psi. OK. 36,042 CUM:$ 36,042 ETD:$ 0 EFC:$ 811,042 POOH W/PBR, FHL PKR ASSY MW: 9.2 BRINE Pull 3.5" hanger to rig floor. Pull tubing and 7" packer assemby. 32,500 CUM:$ 68,542 ETD:$ 0 EFC:$ 843,542 RIH W/OPEN ENDED 3.5" DP MW: 9.2 BRINE Continue POOH w/ spear on fishing BHA #1, recovered PBR and packer. RIH with fishing BHA #2. POOH with fish. 59,418 CUM:$ 127,960 ETD:$ 0 EFC:$ 902,960 C/O 'C' SAND SQUEEZE CEME MW: 9.2 BRINE Perform hesitation down squeeze. Clean out from 6232' to 6285' firm cement. 53,404 CUM:$ 181,364 ETD:$ 0 EFC:$ 956,364 RAISE BRINE WEIGHT TO 10. MW: 9.2 BRINE Continue to clean out squeeze cement across 'C' sand perfs from 6285'-6467' Nordic. RIH with BHA #5 to mill on 7" packer. Well started to flow. Raise brine weight to control. 31,200 CUM:$ 212,564 ETD:$ 0 EFC:$ 987,564 CIRCULATE HOLE CLEAN MW:10.5 BRINE Kill well with 10.5 ppg brine. Monitor well - taking fluid slowly. Mill packer free and push to bottom. Packer hung up @ 6646' and 6700', milled and pushed through. POH with fish and milled out packer. Clean out fill from 6814' to PBTD @ 6914' 49,70~ CUM:$ 262,269 ETD:$ 0 EFC:$ 1,037,269 RUNNING 3.5" COMPLETION MW:10.5 BRINE Perforate 'C' sand from 6435' to 6385' Run in hole with packer. Set top of packer @ 6533' Run 3.5" selective single completion assembly. 76,211 CUM:$ 338,480 ETD:$ 0 EFC:$ 1,113,480 Date: 3/5/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 02/07/97 (C8) TD: 7050' PB: 6920' SUPV:DEB DAILY:$ RIG RELEASED MW: 6.8 DOILSW Run 3.5" completion assembly. Set packer. Test tubing and annulus. Secure well. Release rig @ 0330 hrs. 2/7/97. 117,288 CUM:$ 455,768 ETD:$ 0 EFC:$ 1,230,768 End of WellSummary for Well:998712A MEMORANDUM TO: THRU: Blair Wondzell, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: January 8, 1997 FILE NO: ACVJAHEE.DOC FROM: Lou Grimaldi, L.~,~. SUBJECT: Petroleum Inspector BOPE Test Nordic rig #2 Arco well #3F-7 Kuparuk River Field PTD #85-246 Wednesday, January 8, 1997: I witnessed the initial BOPE test on Nordic rig #2 which was working over Arco well #3F-7 in the Kuparuk River Field. The rig was ready to test when I arrived. The test went well until We ~oved from the Blind rams to the Pipe rams. I observed failures on the upper pipe rams and annular preventers. The leakage was observed coming out of the flow line into the possum belly during the tests. The lower pipe rams could not be closed due to the crossover for the landing joint to the tubing hangers O.D. was to large. The H2S and Methane detectors were tested as was the choke manifold and floor safety valves, all passed. The choke and kill valves ot=~e checked out "OK" Shawn McGeehan (Nordic Toolpusher)called the following day to confirm that the failures had been repaired and I allowed for them to unseat the hanger and perform/o I=- the workover. As we were without a extra vehicle I could not witness the retest but informed Shawn we would catch the next test on this rig. SUMMARY:. I witnessed the initial BOPE test on Nordic rig #2. There were three failures. Test time 4 hours. Three failures. Attachments: ACVJAHEE.XLS CC: Mike Zanghi (Kuparuk Drilling Eng.) NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial Workover: X Nordic Rig No. ARCO Alaska Inc. 3F-7 Set @ X Weekly Other 2 PTD # Rep.: Rig Rep.: Location: Sec. DATE: 1/8/97 85-246 Rig Ph.# 659-71 ~ 5 Don Breden Shawn McGeehan 29 T. 12N R. 9E Meridian Umiat TESTDATA= :!~::- , i ~ ~ Test MISC. INSPECTIONS: Location Gen.: P Housekeeping: P (Gen) PTD On Location P Standing Order Posted P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign P Drl. Rig P Hazard Sec. P Quan. Test Press. P/F 25O/300O F 500/3500 F 500/3500 F 500/3500 P 500/3500 P 500/3500 P 500/3500 P 500/3500 P MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Pressure P/F 500/3500 500/3500 500/3500 P 500/3500 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 16 Test Pressure P/F 500/3500 P 38 500/3500 P ~ P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: minutes minutes Remote: Psig. sec. sec. TEST:RESULTS Number of Failures: 3 ,Test Time: 4.0 Hours. Number of valves tested 22 Repair or Replacement of Failed Equipment will be made within N/A days. Notify the Inspector and follow with Written or Faxed verification to he AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: be tested due to interference from landing joint adapter. '" Pipe rams and annular preventers failed repair and call inspector for retest. Lower pipe rams could not Distribution: orig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Louis R. Grimaldi FI-021L (Rev. 12/94) ACVJAH EE.XLS ARCO Alaska, Inc. Date: February 17, 1989 Transmittal #: 7429 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk 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. 3F-11 3H-12 30-07 Kuparuk Well 3F-1 0 Kuparuk Well 3 F- 06 Kuparuk Well 3 F- 02 Kuparuk Well 3 F- 1 6 Kuparuk Well 3 F- 1 6 Kuparuk Well 3 F- 11 Kuparuk Well 3 F- 04 Kuparuk Well 3 F- 05 Kuparuk Well 3F- 1 3 Kuparuk Well 3 N - 1 0 Kuparuk Well 3 N - 1 0 Kuparuk Well 3 N - 04 Kuparuk Well 3 N - 09 Kuapruk Fluid 30-14 Kuparuk Fluid 3 O- 14 Kuparuk Fluid 3 M - 1 8 Kuparuk Fluid 3 F- 1 6 Kuparuk Fluid 3 F- 13 Kuparuk Fluid 3 F- 1 3 Kuparuk Fluid 3 F- 13 Kuparuk Fluid 3 F- 13 Kuparuk Fluid 3 F- 08 Kuparuk Fluid 3 F- 1 6 Kuparuk Fluid 3 F- 1 6 Kuparuk Fluid 3 F- 1 3 Kuparuk Fluid 3 F- 1 6 Kuparuk Fluid 3 F- 1 6 Kuparuk Fluid 3 F- 1 6 Kuparuk Fluid 3 F- 1 4 Kuparuk Fluid Sub-Surface Pressure Survey Kuparuk Well Pressure Re~ort Pressure Re Pressure Re Pressure Re Pressure Re Pressure Re Pressure Re Pressure Re Pressure Re Pressure Re Pressure Re Pressure Re Pressure Re Pressure Re Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level 'Report Level Report Level Report 3Ort )ort 3ort ~ort ~ort ~ort ~ort ~ort ~ort ~ort ~ort 3ort 10-06-88 8-29-88 12-20-88 8-29-87 8-29-87 8-29-89 8-17-87 8-17-87 8-29-87 6-26-87 12-12-88 12-31-88 6-11-87 6-11-87 9-01 -87 5-04-87 2-13-89 2-10-89 2-10-89 6-05-87 6-09-87 6-18-87 6-16-87 6-21 -87 5-08-87 8-18-87 8-24-87 6-05-87 6-2/3-87 8-5-87 6-5-87 9-8-87 #7-889 Amerada , Sand 'A' Amerada Amerada Amerada Sand 'A' Sand 'A' Amerada Sand 'A' Both Sands Both Sands Sand 'A' Casing Casing Casing Casing Tubing Casing Casing Commission Casing Anchorage Tubing Casing Casing 3F-14 3F-06 3F-14 3F-08 3F-14 3F-09 3F-05 3F-09 3F-06 3F-05 3N-10 3N-10 3N-11 3N-10 3N-05 3N-04 3N-13 3N-11 3N-18 3N-17 3N-07 3N-15 3N-05 3N-09 3N-04 3N-14 3N-08 3N-06 3N-02 3N-10 3N-10 3N-10 3N-10 3N-10 3N-10 3N-10 3N-07 3N-01 3N-04 3N-04 3N-09 3N-10 Receipt Ku ~aruk Fluid Ku'3aruk Fluid Ku~3aruk Fluid Ku ~aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Kul)aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku aaruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku aaruk Fluid Ku:)aruk Fluid Ku 2aruk Fluid Ku 3aruk Fluid Ku :)aruk Fluid Ku 2aruk Fluid Ku 2aruk Fluid Ku 2aruk Fluid Ku ~aruk Fluid Ku 2aruk Fluid Ku 2aruk Fluid Ku ~aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku~aruk Fluid Ku:2aruk Fluid Ku~aruk Fluid Acknowledged: Level Level Level Level Level Level Level Leyel Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Report Report Report Report Report Report Report Report Re 2ort Re aort Re 2orr Re 2orr Re 2ort Re sort Re 2orr Re 2ort Re ~ort Re 3orr Re ~ort Re 3orr Re ~ort Re ~ort Re~ort Re~ort Red,orr Re ~ort Re:~ort Re )orr Re )orr Re ~ort Report Report Report Report Report Report Report Report Report Report Report Report 9-11 12-0 9-11 10-1 9-16 4-11 4-08 4-01 3-26 I -30 10-1 10-1 10-2 10-2 10-2 10-2 3-19 9-12 9-10 9-10 9-10 9-12 9-08 9-01 9-01 9-06 9-06 9-06 9-06 6-01 5-31 6-03 6-06 .6-08 6-09 6-25 4-17 4-18 6-17 6-20 5-07 8-24 -87 6-86 -87 I -87 -87 -88 -88 -88 -88 -88 2-87 5-87 8-87 8-87 8-87 8-87 -87 -87 -98 -87 -87 -87 -87 -87 -87 -87 -87 -87 -87 -87 -87 -87 -87 -87 -87 -87 -87 -87 -87 -87 -87 -87 ........................... Date: Casing Tubing Casing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Tub,ng Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Casing Alaska Oil & Gas Cons. ....... ¢b'zci~orag~ DISTRIBUTION; D&M State of Alaska - Mobil Chevron Unocal SAPC ARCO Alaska, Inc. Date: February 23, 1989 Transmittal Ct: 7432 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk 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. 3F-15 3N-18 3F-01 3F-02 3F-09 3F-06 3F-10 3F-11 3F-15 3F-14 3N-10 3N-06 3N-09 31-01 3N-11 3N-14 3F-08 3N-01 3N-14 3F-15 3F-15 3F-13 3F-15 1B-05 1E-25 3B-11 3A-03 3H-01 2Z-19 31-12 1E~08 3M-18 Kupaurk Fluid Level Re~3ort Kupaurk Fluid Level Re,3ort Kupaurk Fluid Level Re3ort Kupaurk Fluid Level Re3ort Kupaurk Fluid Level Re3ort Kupaurk Fluid Level Re3ort Kupaurk Fluid Level Re'3ort Kupaurk Fluid Level Re3ort Kupaurk Fluid Level Re3ort Kupaurk Fluid Level Re3ort Kupaurk Fluid Level Re3ort Kupaurk Fluid Level Re3ort Kupaurk Fluid .Level Re3ort Kupaurk Fluid Level Re3ort Kupaurk Fluid Level Re)ort Kupaurk Fluid Level Re3ort Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kuparuk Well Pressure Report Kuparuk Well Pressure Report Bottom-Hole Pressure Survey Kuapruk Well Pressure Report Kuparuk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report 12-03-87 I 2-1 8-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 5-18-87 5-22-87 5-21-87 4-24-87 4-15-87 4-13-87 4-14-87 4-20-87 12-04-87 2-02-89 8-27-87 8-27-87 8-25-87 2-2O-89 2-19-89 2-20-89 2-21-89 2-21-89 2-20-89 2-20-89 2-19-89 2-15-89 Casing Casing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casing Casing · Casing Casing Casing Casing Casing Casing Casing Tubing Sand 'C' SandBHP 'C' Amerada Casing Casing Casing Tubing Tubin~ C asin~ Casin~ 3H-01 Kupaurk Fluid Level Report 2-15-89 3 B - 1 3 Kupaurk Fluid Level Report 2-17-89 I E- 2 9 Kupaurk Fluid Level Report 2-15-89 1C-05 Kupaurk Fluid Level Report 2-18-89 3M-1 7 Kupaurk Fluid Level Report 2-16-89 2 Z- 2 0 Kupaurk Fluid Level Report 2-18-89 30-1 0 Kupaurk Fluid Level Report 2-16-89 31 - 1 2 Kupaurk Fluid Level Report 2-20-89 3 H - 1 0 BHP Report 2-13-89 Casing Casing Casing Casing/Tubing Casing Tubing Casing Tubing BHP Receipt Acknowledged' - .......................... Date- DISTRIBUTION: D&M ' State of Alaska SAPC Unocal Mobil . . Chevron ARCO Alaska, Inc. Post Office B~.~_,,.00360 Anchorage. Alaska 99510-0360 Telephone 907 276 12!5 November 9, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in duplicate are multiple Reports of Sundry Well Operations on the following Kuparuk wells. Conversions, 3N-11, 3N-10, 3N-05, 3N-04, 3F-12, 3F~03, 3F-08, 3N-03, 13, 1E-21, 1E-19, 1E-23, 1E-lA, 1E-04, 1E-16 and1E-27 · 3K-14, 3C-16, 3K-17, Fractures and Stimulations 1E-14, 3N-17, 3F-16 and 2V-12 Perforations, 3N-11, 3F-11 and 3N-SA 1E-30 Failed MIT If you have any questions, please call me at 265-6840. Sincerely, B. /~~j..? Senior Operations Engineer Attachments cc: J. Gruber M. L. Hagood S. P. Twiggs KOE1.4-9 ATO 1478 ATO 112O ATO 113O 3N-12, 3N- RECEIVED Nov ! 6 1988 0ii & cas co.s. ~~ ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfietdCompany 1. Type of Request: STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown Stimulate __ Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. ©. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 18' FNL, 1' FWL, Sec. 29, T12N, R9E, UM At top of productive interval 1170' FSL, 1197' FWL, Sec. 20, T12N, R9E, UM At effective depth 1425' FSL, 1417' FWL, Sec. 20, T12N, R9E, UM At total depth 1457' FSL, 1470' FWL, Sec. 20, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) RKB 93 7. Unit or Property name Kuparuk River Unit 8. Well number g. Permit number/approval number 7-680 10. APl number 5o-029-21464 11. Field/Pool Kuparuk River Oil Pool 7050' MD feet Plugs (measured) NONE 6340' TVD feet Effective depth: measured 6920' MD feet true vertical 6236' TVD feet Junk (measured) NONE Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 80' 1 6" 250 Sx AS II 115' MD 115' TVD Surface 2994' 9 5/8" 865 Sx PF"E" 3029' MD 3029' TVD Intermediate & 350 Sx PF"C" Production 6974' 7" 300 Sx Class G 7009' MD 6304' TVD Liner & 175 SX PF"C" Perforation depth: measured 6383'-6467', 6491'-6502', 6610-6647', 6664'-6707' MD true vertical 5821'-5886', 5904'-5913',5995'-6024, 6037'-6070' TVD feet Tubing (size, grade, and measured depth) 3-1/2", 9.3#, tubing tail @ 6553' MD Packers and SSSV (type and measured depth) FB-1 Packer ~ 6530', FHL Packer @ 6282', SSSV (TRDP-1A-SSA) @ 1796 13. Stimulation or cement squeeze summary Intervals treated (measured) Ir~'~'~ ~_~ Treatment description including volumes used and final pressure 14. Representative Daily Average Production or In~ection'~am- ~.; ~ch0mge OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 327 93 4156 1 280 350 0 0 5014 800 470 Prior to well operation Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil m Gas Suspended Service Water Injection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404- Rev~(6/ 5/88 ~/ SUBMIT IN DUPLICATE 'ARCO Alaska, In% Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT WELL NIRAClOR REMARKS FIELD - DISTRICT- STATE . ]ZOo - ez_3o - I--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ITemp' ! Chill Fact°r [ Visibility [Wind Vel'Report °F °F miles knots STATE OF ALASKA ALA-~.,.<'A OIL AND GAS CONSERVATION COI',.,.,.~iSSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [~ Plugging [] Stimulate [] Pull tubing [] Amend order Q Perforate [] Other [] 2. Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360: Anchnrage: AK 99510 4. Location of well at surface 18' FNL. 1' FWL. Sec. 29, T12N, R9E, UM At top of productive interv~[I 1170' FSL, 1197' FWL, Sec.20, T12N, RgE, UM At effective depth 1425' FSL, 1417' FWL, Sec 20, T12N, R9E, UN At total depth 1487' FSL: 1470' FWL; S¢.c.20; T12N= RgF= IIM 11. Present well condition summary Total depth: measured 7050' ND feet true vertical 6340' TVD feet 5. Datum elevation (DF or KB) RKB 93 6. Unit or Property name KIjl~artjl< River tlnit i 7. Well number 3F-8 8. Permit number Permit #85-246 9. APl number 50-- 029-21464 10. Pool KIl,naru~ R-ivpr r)~l Pool Plugs (measured) None feet Effective depth: measured true vertical Casing xxx;eX0~x;~kXxXX Conductor 80' Surface 2994' x x x ~¢xt~r4~Cd~te Production xxx - xxxx Perforation depth: measured feet Junk (measured) None 6920' MD feet 6236' TVD Length Size Cemented Measured depth True Vertical depth 16" 250 SX ASII 115' MD 115' TVD 9-5/8" 865 SX PF"E" & 3029' MD 3029' TVD 350 SX PF"C" 6974' 7" 300 SX Class G & 7009' MD 6304' TVD 175 SX PF"C" 6383'-6467' 6491'-6502' 6610'-6647' 6664'-6707' MD true vertica'5821'-5886' 5904'-5913' 5995':6024' Tubing (size, grade and measured depth) 3~", 9.3~, tubing tail e 6553' MD SEP 2 Packers and SSSV (type and measured depth) All--Oil ~, G~ C0n~ Commission FR-1 P~c~p~ ~ RRnA~' FH! P~rb~ ~ ~R?~' ~Xl (TP~D_IA_CCAq--~'~TO~ ~--~ 12.Attachments ---~escr~P{~n' ~~r~o¢~osal-~-' D~'I~ .... .... operations ~-ro~ ~'u'~%ketch ~ Converting ~ producer to a water in~ctinn wpll. 13. Estimated date for commencing operation October 1~ 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the for..egoing is true and correct to the best of my knowledge Signed /:¢j.,'c~ ~? :~/l-~f.C~...~¢Title Sr. Operations Engineer V Commission Use Only Conditions of approval Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearanceI No. Date 9/23/87 Approved by -~' Form 10-403 Rev 12-1-85 Approved (: cy> y by order of Commissioner the commission Date Submit in triplicate ,... ? _ r., STATE OF ALASKA OC./~ ~ ALASKA'OiL AND GAS CONSERVATION C~MISSION ~.5 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~( GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-246 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21464 4. Location of well at surface 9. Unit or Lease Name 18' FNL, 1' FWL, $ec.29, T12N~ R9E~ UM Kuparuk River Unit . At Top Producing Interval 10. Well Number 1170' FSL, 1197' FWL, Sec.20, T12N, R9E, UM 3F-8 At Total Depth 11. Field and Pool 1487' FSL, 1470' FWL, Sec.20, T12N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 93' RKBI ADL 25632 ALK 2565 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 11/04/85 11/09/85 11/11/85*I N/A feet MSLI 1 · 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+FVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 7050 'MD ,6340 'TVD 6920 'MD ,6236 'TVD YES~ NO[] I 1803 feetMD 1500' (Approx) 22. Type Electric or Other Logs Run FDC/CNL/GR/Cal, LSS/GR, GR/CCL/CET/Gauge ring, GCT D I L/SFL/GR/LSS/SP, LDT/CNL/NGT/EPT, LDT/CNL/NGT/EPT/GR, SHDT, D I L/SFL/GR/SP 23. CASING, LINER AND CEMENTING RECORD · SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED . 16" 62.5# H-40 Surf 115' 24" 250 sx AS II 9-5/8" 36.0# J-55 Surf 3029' 12-1/4" 865 sx PF "E" & 350 sx F'F "C" 7" 26.0# J-55 Surf 7009' 8-1/2,, 300 sx Class G & 175 sx PF "C" 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) 6707' - 6664' w/4 spf 3-1/2" 6560' 6289' & 6537' 6647' - 6610' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6491 ' - 6502' w/12 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6467' - 6383' N/A · , 27.N/A PRODUCTION TEST . Date First Production Method of Operation (Flowing, gas lift, etc.) . ~ateofTest Hours Test'ed PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ Flow Tubing Casin'g Pressure CALCULATED..~ OIL-BBL GAS-MCF WATER-DBL 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. NONE ~aska Oil & Gas Cons. Form 10-407 * NOTE: Tubing was run and the well perforated 12/9/85. Rev. 7-1-80 CONTINUED ON REVERSE SIDE WC1/050 Submit in duplicate 29. ( 30. t'- i GEOLOGIC MARK'IER~ -FORMATION TESTS -- NAME - Include interval tested; pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 6383' 5821' N/A Base Kuparuk C 6467' 5882' Top Kuparuk A 6596' 5984' Base Kuparuk A 6761' 6111' · 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed //~~ ~ TitleAssOciate Engineer 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- lng 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 ARCO AIIskI. Post Office ~ 100360 Ancl~orage. Alaska 99510-0360 Telepl~one 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE-_ 04-03-86 TRANSMITTAL # 5622 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints: Schl: CET's or CBL's: One * of each 12-03-85 Run #2 7050-7732 02-21-85 Run #1 6390-6964 02-23-85 Run #2 6400-7000 04-16-85 Run #1 0695-4476 01-28-85 Run #1 5346-7359 01-14-85 Run #1 4710-6500 01-13-85 Run-#1 6050-8250 01-13-85 Run #1 5390-7522 12-06-85 Run #1 6000-8016 02-11-85 Run #2 6488-8062 11-03-85 Run #1 6771-8518 11-03-85 Run #1 6086-7545 11-04-85 Run #1 5186-7006 11-14-85 Run #1 5410-6885 Re ceip~ Ac_k~nowiedged: Vault* fi --D ate: NSK C!erk*b! ADDENDUM WELL: ll/15/S5 11/21/85 3F-8 Log GR/CCL/CET/gage ring f/6991'-5418'. Rn gCT gyro f/PBTD-surf. Arctic Pak w/175 sx PF "C". Drillin~ Superintendent ' Elate ARCO Alaska, Inc. Post Office I~'b'~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 12, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 3F-8 Dear Mr. Chatterton' Enclosed is an addendum to the 3F-8 Well History the Well Completion Report, dated 1/21/86. questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L115 Enclosure to include If you have any wi th ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office B~'~ '100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 11, 1986 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3F-8 Dear Mr. Chatterton' Enclosed is a copy of the 3F-8 Well History to include with the Well Completion Report, dated 1/21/86. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L101 Enclosure ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Oil and Gas Company 'v Well History- Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on lhe first Wednesday after a well is spudded or workover operations are started. DalJy worl~ prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE AK0464 County, parish or borougl3 North Slope Borough I Lease ADL 25632 or Unit I Title Drill State Alaska Well no. 3F-8 Doyon 9 AP1 50-029-21464 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date Hour 11/4/85 I Date and depth as of 8:00 a.m. 11/o5/85 11/06/85 11/07/85 11/08/85 Complete record for each day reported 2130 hrs. IARCO W.I. Prior status if a W.O. 56.24% 16" @ 115' 1189', (1074'), Drlg Wt. 9.6, PV 14, YP 28, PH 9.0, WL 13.6, Sol 9 Accept ri~ @ 1830 hrs, 11/4/85. NU diverter sys. 2130 hrs, 11/4/85. Drl 12¼" hole to 1189'. Spud well @ 16" @ 3029' 3050', (1861'), Logging Wt. 9.6, PV 16, YP 22, PH 9.0, WL 5.6, Sol 9 Fin drlg to 3050', short trip, circ hole cln, TOH. log DIL/SFL/GR/LSS/SP f/3022'-115', LDT/CNL/NGT/EPT f/3022'-1550', high resolution pass f/3022'-2550'. RU Schl, 9-5/8" @ 115' 3050', (0'), Tst 9-5/8" csg Wt. 9.5, PV 14, YP 18, PH 9.0, WL 6.8, Sol 8 Fin rn hi-resolution pass w/LDT/CNL/NGR/EPT/GR. Rn SHDT f/3019'-1550', RD Schl. Make conditioning trip. RU & rn 76 jts, 9-5/8", 36#, J-55 BTC HF/ERW csg w/FC @ 2947', FS @ 3029'. Cmt w/895 sx PF "E" & 350 sx PF "C". Had 155 sx PF "E" cmt rtns to surf. CIP @ 2036 hfs, 11/6/85. ND diverter. NU & tst BOPE. RIH, tst csg. 9-5/8" @ 3029' 5214', (2164'), Navi-Drl Wt. 9.0, PV 5, YP 4, PH 9.5, WL 7.8, Sol 8 DO FC, cmt, FS & CO to 3050'. Drl 10' new hole. Conduct formation tst to 12.0 ppg EMW. Drl 8½" hole to 3200', Navi-Drl to 5214'. 3322', 5.0°, N42.25E, 3321.8 TVD, 5.3 rS, 3.9N, 3.6E 3697', 19.7°, N55.25E, 3687.1TVD, 84.7 VS, 53.8N, 66.1E 4007', 26.4°, N48.25E, 3971.9 TVD, 205.7 rS, 129.0N, 162.2E 4575', 35.4°, N44.25E, 4462.5 T~_., 490.3 rS, 322.1N,.371.TE 4765', 39.8°, N44.25E, 4612.2 TVD, 605.6 rS, 404.7N, 452.1E The above is correct For form preparation a,d-d~-stribu~nl see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date ITitle Drilling Superintendent ARCO Oil and 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 of 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 "Final I~eport" form may be used for reporting the entire operation if space is available. Accounting cost center code State District ICounly or Parish Alaska North Slope Borough Field ILease or Unit Kuparuk River ADL 25632 Auth, or W.O. no, ITM AF~ AK0464 Doyon 9 cost center prior to plugging and [ ARCO Alaska, Inc. 56.24% abandonment of this well Spudded or W,O. begun iOate Hour Prior status if a W.O. Spudded 11/4/85 2130 hrs, Complete record for each day reported Date and deplh as of 8:00 a.m, Old TO 11/09/85 thru 11/12/85 1700 hrs. Released rig Classifications {oil, gas, etc.) Oil Producing method Flowing Drill AP1 50J029-21464 7" @ 7009' 7050' TD, 6920' PBTD, (1836'), RR 9.8 ppg NaC1/NaBr Navi-Drl & surv 8½" hole to 7050' TD, short trip, C&C, POH. Schl, log DIL/SFL/GR/SP f/7040'-3924', log FDC/CNL/GR/CAL f/7015'-6200' & 5000'- 4400'. Log LSS/GR f/7032'-3026'. Rn WST w/shots @ 33 levels, deepest @ 7010'. RD Schl. RIH, rm 6400'-7050', 20 std short trip C&C, POH. RU & rn 162 jts, 7" 26#, J-55 BTC csg w/FC @ 6920', FS @ 7009'. Cmt w/300 sx C1 "G" w/.6% FDP-C344 & .25% HR-7. Bump plug w/3000 psi. ND BOPE, NU & tst tree to 3000 psi. RR @ 1700 hrs, 11/11/85. 4954' 5517' 6272' 6651' 6990' Alaska IWell no. 3¥-8 RU · 40.1°, N43.25E, 4757.9 TVD, 727.6 VS, 492.8N, 536.5E · 42.7°, N43.25E, 5171.1TVD, 1109.8 VS, 768.9N, 800.8E , 39.7°, N42.25E, 5736.5 TVD, 1609.7 VS, 1137.7N, 1138.8E , 39.9°, N40.25E, 6027.7 TVD, 1851.9 VS, 1320.1N, 1298.8E s 39.3°, N44.25E, 6294 TVD, 2060.8 VS, 1474.9N, 1439.4E New TD PB Depth ......... Kind of rig l 1 / 11/85 Rotary Type completion (single, dual, etc.) Sin~la Official rese~oir~ame(s) Date Potential test data ,Well no. Date Reservoir Producing Interval ~ Trest 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 In~*~ ITitle Signature For form preparation and di;tril~'ution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supcrintcndcnt ARCO Alaska, Inc. Post Office B~X'~100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 10, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3F-8 Dear Mr. Chatterton- Enclosed is a copy of the 3F-8 Well History (completion details) to include with the Well Completion Report, dated 01/21/86. if you have any questions, please call me at 263-4944. Sincerely, . Gruber Associate Engineer JG/tw GRU13/L75 Enclosure ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany ARCO Oil and Gas Company Daily- Well~R~story- 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. "Filial Report" shot. lid 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 "Final Report" form may be used for reporting the entire operation if space is available. District ~County or Parish Alaska I North Slope Bor~ough Field ~Lease or Unit Kuparuk River I ADL .25632 Auth. or W.O. no. JTitle ' AFE AK0464 I Completion Nordic 1 API 50-029-21464 Operator I A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O, begun Date Complete 12/8/85 12/o8/85 thru 12/09/85 12/lO/85 Date and depth as of 8:00 a,m. Complete record for each day reported IAccounting cost center code State Alaska Iotal number of wells (active or inactive) on this Dst center prior to plugging and I bandonment of this well I our I Prior statu~ if a W.O. 1945 hrs. I 7" @ 7009' 6920' PBTD, Perf'g 9.8 ppg NaCl/NaBr Accep.t rig @ 1945 hfs, 12/8/85. NU & tst BOPE. RU Schl, perf- w/4" gun, 4 SPF 90° phasing f/6610'-6647' & 6664'-6707'. Perf w/5" gun, 12 SP~, 120° phasing f/6403'-6467' & 6491'-6502'. IWell no. 3F-8 7" @ 7009' 6920' PBTD, RR Diesel Fin perf'g w/5" gun f/6383'-6423'. Make 6-1/8" gage ring/JB rn to 6125'. RIH w/FB-1 pkr, set @ 6530' WLM. RIH w/3½" compl & lnd w/SSSV @ 1803', FHL Pkr @ 6289' MD, FB-1 pkr @ 6537', & TT @ 6560'. Tst tbg, ann, SSSV. Instl BPV. ND BOPE, NU & tst tree. Displ well to diesel. RR @ 2100 hfs, 12/9/85. Old TD I New TD I PB Depth I Released rig rDate IKind of rig 2100 hrs. 12/9/85 Classifications (oil, gas, etc.) Type completion s_.(.~g.gle, dual, etc.) Oil Single Producing method Official reservoir.name(s) Flowing Kuparuk Sands Potenlial test data 6920 ~ ~TD Rotary Well 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 Date i.,-,t,. For form preparation an~ distribution, see Procedures Manual, Section 10, Drilling. Pages 86 and 87. Drilling Superintendent ARCO Alaska, Inc. Post Office Bo~x~'~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 21, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3F-8 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for 3F-8. I have not received the Well History (completion details). When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L13 Enclosures RECEIVED Alaska Oil & Gas Cons. Oo~m~ission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA . ALASKA (:,~ AND GAS CONSERVATION CO~.._.,llSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-246 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21464 4. Location of well at surface · 9. Unit or Lease Name 18' FNL, 1' FWL, Sec.29, T12N, RgE, UN 'LOCATIONS Kuparuk River Unit VERI~N~- At Top Producing Interval 10, Well Number ~ Surf.. 1170' FSL, 1197' FWL, Sec.20, T12N, RgE, UPi 3F-8 At Total Depth~tR' H. ~._ 11. Field and Pool _. _ 1487' FSL, 1470' FWL, Seco20, T12N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 93' RKBI ADL 25632 ALK 2565 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 11/04/85 11/09/85 11/11/85*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7050 'MD ,6340 'TVD 6920 'MD ,6236 'TVD YES l-~X NO []I 1803 feetMD 1500' (Approx) '22. Type Electric or Other Logs Run FDC/CNL/GR/Cal , LSS/GR, GR/CCL/CET/Gauge ri ng, GCT D I L/SFL/GR/LSS/SP, LDT/CNL/NGT/EPT, LDT/CNL/NGT/EPT/GR, SHDT, D I L/SFL/GR/SP 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 115' 24" Conductor report not ¥~;t received. 9-5/8" 36.0# J-55 Surf 3029' 12-1/4" 865 sx PF "E" & 350 sx PF "C" 7" 26.0# 'J-55 Surf 7009' 8-1/2" 300 sx Class G & 175 sD .PF "C" 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) 6707' - 6664' 3-1/2" 6560' 6289' & 6537' 6647' - 6610' w/4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6491 ' - 6502' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED w/1 2 spf 6467' - 6383' N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I " Date of Test Hours Tested PRODUCTION FOR el L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.k, OILoBBL 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. NONE RECEIVED JAN 2 4 1986 Alaska Oil & Gas Cons. Commissio~ Anchorage Form 10407 * NOTE: Tubing was run and the well perforated 12/9/85. TEMP3/WC51 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. "' ... · 30. . . , · ~ · .. ,, , .-,~, :. : . _.. , . : ~ ,~. ~ . , "' GEOLOGIC'MARKEI~S ' ~ "' ".' ~ ~ "F~'O~M~,TiONTE'S'I:~; ', ' , -- · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR,and time of each phase. Top Kuparuk C 6383' 5821' N/A Base Kuparuk C 6467' .5882' Top Kuparuk A 6596' 5984' Base Kuparuk A 6761' 6111' .. ~ . 31. LIST OF ATTACHMENTS Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed..__ ~ ~ 2~-~ Tide Associate Engineer 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 ~njectien, 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". TEMP3/WC40a Form 10407 8UB. SURFA DIRECTIONAL SURVEY [~UIDANCE [~]ONTINUOU$ ['~OOL r, ARCO' ALASKA INCORPORATED Coml~m~Y Well Nil/Il 3~-s (18' FNL, 1' FWL, S29, T12N, R9E, UM) Fleld/I.~&tlon ~A~, ~0~ S~O~E, ~AS~ 71106 LO~Q~ BY; LESNIE / SARBER RECEIVED Alaska Oil & Gas Cons. Commission Anchorage 19-DECEHgEP'-85 CUDNEY :$CT 31R-CTiDNAL SURVEY "USTzDMER LISTING FOR ~RC3 ~LASKA, INS, 3F-'.5 KtJP&R!JK N~3RTH SLOPE~ALASKA SURVEY :DATE: 15-NOV-P~5 ~NGINEER: LESNZ r-/SAR~,ER M':TMO"S._ _, :3,= f. 3~ID"JT,~TI3'~, TJ3L L3CAT£DN: T,ANG:NT"'AL- ,~VER'~GE2. DEVIATION AND AZiMdTH .~'NT ~P;]L~TT~N',,. ~ · LZN~:~R V;_:RTiC4L S":CTIDN' t0R'£7 O£ST '>RGJ~CT::D ONTO ~ TIRG'ET ~Z'IMUTM OF NORT't 4~, DES EAST ~RC3 ALASKA, I'~C. 3~-~ KUPARJK NORTH SLOPE,ALASKA TqUE ~EASURE9 VERTICAL DEPTH DEPTH 0.03 0.03 130.00 lO0.OO 200.03 200.00 300.00 300.30 400.03 400.30 500.00 330.30 500.00 700.03 6'~9.99 300.00 799.99 900.00 899.99 1000.00 9)9.99 1100.00 1099.~3 1200.00 1199.99 1300.00 1£99.~7 1~00.00 13~9.R6 1500.00 1499.95 1000.00 1599.55 1700.0~ 1~99.95 1~00.00 1799.94 1900.00 2OO0.OO 1999.93 2100.30 2099.~3 2200.00 21~9.93 2300.00 22~9.~3 .2400.00 23~9.~3 2500.00 2~9.'~3 2500.00 2599.~3 2700.30 269~.92 2~00.00 2799.93 2900.00 2899.92 3000.00 2999.92 3100.00 3099.91 3200.00 3199.90 3300.00 3299.32 3~00.00 3399.26 3500.00 3497.76 3500.00 3594.36 3700.00 3690.08 3800.00 3782.95 3900.00 3~'7~.~0 iNTERPOLATE2 VALUES FOR SJE-S~ZA CZdRSE VERTICAL DEVIATION 'AZ'!qjTm DEPTH :. D. EG, MIN 2, Eg Mi'~ -93.30' 0 0 N 0 S 7. O0 0 $ N 32 ~ 107.00 0 10 S $8 7 207.30 0 12 N ;~Z 42 307.00 0 13 S 45 47 ~37.33 0 21 ~ ~O 30 ~05 9~ 3 20 ~ 7~ 17 605.99 0 17 ~ 73 17 705.~9 0 15 S 51 32 505.99 0 22 S 50 25 906.99 0 33 1035.93 0 33 1105.93 O 35 1205.97 0 37 1305.96 0 ~0 140 5.96 0 1506.95 0 34 1605.95 0 31 1735.9 I ~06.9~ 0 33 i335.93 O 31 i006.93 0 25 '~!0,5 33 0 13 22.3'$.~3 O 2305.93 0 5 2406.9,t O 19 23 ~6. '~ '~ ', =- 2503.~Z 3 23 270°.92 0 22 ~305 92 0 gO 2906.92 0 31 3005.91 3 ~0 3105.30 0 55 3206.82 3 52 3306.25 7 3~3~.76 11 3501.3~ !5 5597.03 19 36.3'9.35 23 3 3731.40 25 3 19-DFC-35 :V=N lO0 =EET O: V = R T I" S=-~TI . 3. 4. 7. 18. 35. ,D~,. 125. 165. AL DOGLEG ON SEVERITY T '3:3/100 O0 0.00 O6 O. 20 05 iD. 3~, 17 3.11 2'3 3.23 35 0.12 58 0.17 88 0.17 10 3.1~ 21 0.36 24 3.12 28 0.16 16 0.14 85 O.Og 37 0.26 31 0.21 Og 0. ZO 41 0.23 35 0.31 93 0.07 ~,2 0.08 05 0.18 30 0.04 42 0.1~9 54 0.13 81 0.27 22 0.04 60 0.11 96 0.09 28 0.28 gATE OF SURVEY: 15-NOV-85 KELLY BUSHING ELEqATI3N: ENGINEER: LESNIE/SARBER 93.00 M:ASURED RECTANgULaR NORTH/SOUTH DEPTH COORDINATES EAST/WEST FEET 0.00 N 0.01 S 0.07 S 0.18 S 0.32 S 0.70 S 0.94 S 1.02 S 1.18 S 1.48 S 2.02 S 2.58 S 3.45 S 4.39 .S 5'45 S 6.53 S 7.72 S 8.58 S 9.14 S 9.¢0 S 9' 61 S 9.75 S 9.90 S 10.07 S 10..11 S 10.07 S 10.11 S 10.22 S 10.35 S 10.~2 S ~6 0.16 10.32 55 0.13 10.41 34 0.98 10.62 83 4.31 8.84 17 3.94 1.32 29 4.26 10.39 7~ 3.96 24.47 74 4.13 41.89 25 1,30" 63.62 29 3.38 88.14 FEET 0.00 0.0~ 0.00 0.42 0.73 1.22 1.78 2.29 2.77 3.22 3.83 4.55 5.15 5.6~ 6.06 6.29 6.38 6.70 7.35 5,21 9.15 9.97 10.48 10.83 11.02 11.38 12.00 12.66 13.30 13.82 0. O"&? ~ 8 0.07 1 4 O. ~5 · S' 67 3 0.80 S 66 17 1'. 40 S 60 5 2.02 S 62 14 2.51 S 65 57 3.01 S 65 56 3.54 S 65 22 , ', ~:~'0 E P 4, R T UR E ~,~, i~E ,., MIN ,~#% 0 0 E E E E 4.33 S 6'2 7 E 5.28 S 59 31 E 6.19 S 55 11 E 7.16 S 52 14 E 8.15 S ~8 0 E 9.14 S 43 28 E 10.02 S 39 33 E 10.89 S 37 59 E 11.73 S 3~ 50 E 12.48 S 41 9 E 14.56 15.63 16.97 20.13 27.24 39.74 58.93 33.93 113.90 146.06 17.85 S 54 39 E 18.78 S 56 20 E 20.01 S 57 57 E 21.98 S 66 18 E 27.2T S ~7 13 E 41.08 N 75 21 E 6.3.80 N 57 27 E 93.80 N 63 28 E 130.46 N 60 48 E 170.59 N 5~3 53 E 13.27 S 43 36 E 13.95 S 45 38 E 14.42 S 46 36 E 14.79 S 47 3 E 14.96 S 47 28 E I 15.19 S 48 29 EI, 15.6'9 S 49 53 E 16.27 5 51 5 ~ 16.~5 S 52 6 5 17.31 5 52 59 ~ 3F-~ KJP&RU<. NGRTH TqU= ME&SURE3 VERTICAL D;?Td D r-P T -t 4000.00 3964.13 4100.00 4053.40 4200.00 4141.35 4300.00 ~229.31 4400.00 4315.9~ 4500.00 4400.31 4700.00 4553.J~ 4800.0J 4640,39 4900,00 ~716.73 5000,00 ~793.1J 5100.00 4867.57 5!00,33 4939,9'7 5300,00 5012.50 5400,00 5035.~2 5500,00 5158,~7 5500,00 5231,73 5700.00 5305.32 5~00,00 5379,22 5900,00 5~53,57 6000,00 61OD,OD 5603,74 6200,00 5679..~4 6300.00 5756,57 6¢00,00 5333.~7 6500.00 5910.73 6600.00 59~7.46 6700.~0 6064.10 6800.00 514!,29 6900.00 6220.53 7000.00 5300.33 7050.00 5339.78 ~M~UT~TI'~N DATE: I:-DEr-8= .. INT~RPOL&TE] VAI d'-3 F~R ~V=N 100 ~::T 0= SJB-SEA C]JRS2 VERTI'A.L DEV!~TI]'~ AZZMjT~ DE~TM '~EG ~Iq D:G MI"~ 3871.13 26 30 N 48 42 = 3960.40 27 42 N ~7 ~2 '~_ 4048,35 28 B1 q ~7 29 - ~136,31 28 35 'q 47 ~ ~ ~222.94 31 34 N ~7 27 2 4307.31 33 22 N 46 31 ': -- 435~.61 35 25 N 44 35 - ~70.0~ 3,~ 3 N 44 13 4547.]9 39 5,6 N 44 0 ~623.73 40 17 N 43 47 ~_ 4700.10 40 25 N 43 37 ~774.57 43 20 N 43 i0 :._ ~845.97 43 31 N 43 7 : ~919.60 43 22 N ~992.42 43 14 5005,47 42 53 N 42 45 513~.73 521!.32 4! '~2 N 42 14 : 5286,22 5360.57 41 50 5~35.36 ~l JO i,J ~I 27 5 55iJ.7~ '40 '~'7 N 41 7 Y 5563.57 3) ~1 N ~0 4~ ~ 5317.73 39 ~3 N ~C 15 ~ 5.39~.4~ 39 55 N 49 18 ~ 5971,10 39 54 '~ 3'~ 57 2 5127.53 37 20 N 4! ~2 ~ m207.03 37 20 N 41 42 E 5245,78 37 ;ZO N ~1 42 ~ MEASURE V:RTICAL OC,3LEG RESTAN SECTIgN S~V=RITY NgRTH/ F;ET OEG/IOO FEE ~09.21 0.78 116. 254,1~ 2.56 146. 3'31,72 0.3~ 178. 349.23 1.42 210. 399.09 2.63 244. 4:52,70 2.97 281, 50~.47 1,02 320, 568.88 3.~2 363. 632.24 0.71 ~08. 6)5.83 0.2~ ~55. 761.37 1,28 502, ,~27.9.5 1.97 550. ~97.02 0.45 600. ~55.73 0.~5 651. 1034,25 0.23 70!, 1102.52 g.35 751. 1170.54 0,75 301, 1233.20 0,35' 851, 1305,51 0.60 901, 1372.3!3 0.35 951. 143~.59 0,38 1000, 1504.20 0,8~ 1050. 1568,9~ 0,78 1099, 1532.92 0,52 1147. 1696,45 0.25 1195, 1750.02 0.5~ 1244, 1823,97 0.17 1293, 1~B8.02 0,3~ 1342. 1951.39 3,05 1391. 2012.30 0.00 1437. PAGE 2 DATE OF SORVEY: 15-NGV-85 KELLY 5USHING ELEVATION: 93.00' ENGINEER: LESNIE/SA~BER FT '2072.:39 0,00 1482. 2103,19 0,00 1504, GULAR SOUTH T ~6 N 56 N 69 N 85 N 63 N 00 N 9'9 N 47 N 93 N 51 N 14 N :9 N 96 N 2O N 35 ~ 41 N ¢4 N 31 N 93 N 34 N 36 N 94 N 29 N 73 N 67 N 75 N 36 N 0~+ N ,33 N 98 N DEPTH E A S T / W E S T D J~ ~?~:i']A Z I M U T H F:Z ET FE, 258,.91 55 213.4q. E 248.56 E 283.59 E 320.36 E 35).74 E 400.14. E 441.66 E 485,80 E 530.55 E 31 E 306.12' 'N 54 17 E 353,39.*' N 53 22 E 403.08 N 52 38 F ~5'6.53 N 51 59 512.97 N 51 15 E 571,99 N 50 32 E 635,00 N 49 54 E 69'9,27 N 49 21 E 1033.80 E 143~.99 N 45 55 E 1077.19 E 1504.51 N 45 43 E 1119.67 E 1569.16 N 45 31 E 1161.53 E 1533.07 1202,97 ~ 16'96,54 N 1244.38 E 1760,07 N 44 59 1285,83 E 1823,99 N 44 49 ' 1327.Z8 E 1888,02 N 44 40 E 1368.23 E 1951.39 N 4~ 31 E 1408.65 E gO1Z.31 N 44 25 E 1449.01 E 2072.91 N 44 20 E 1469.20 E 2103.21 N 44 18 E 575.18 E 763.53 N 48 52 E 620.89 E ~29.85 N 48 26 E 668.17 E 898.66 N 48 1 E 715,08 E 967,16 N 47 40 E 761.30 E 1035.~9 N 47 21 E 808.26 E 1103.58 ~ 47 5 E 354.39 E 1171.45 N 46 49 E 900.03 E 1238.97 N 46 35 E 945.19 E 1306.14 N 46 21 E 9'8,9..76 E 1372.81 N 45 $ E ARS. O ALASKA, I~C. 3F-~3 KJP&RUK NDRTH SLOPE,ALASKA C ]qPUT&T! 3~ ~EASURED VERTICAL DEPTH DEPTq 0.00 O.OJ 1000.00 999.:)9 2000.00 1,)99.93 3000.00 2)~9.~2 ~000.00 3')$4.13 5]O0.O0 ~793.10 6003.00 5523.35 7OO0.OD 6300.33 7050.00 6339.73 OAT-: 19-DEC-R5 INTERPOL&T=3 ',/..a, LJ=S FOR -VEN 1000 ¢:EET DF SJO-S;A CDjRSE V=RTICAL DOGLEG '¢=RTISAL, DEVI&TiO~ &Zl¢,IdTq SECTION SEVERITY DEPTH.': BEG ~iN DfS 'q!N FEET OES/IOO -93.00 0 0 N S 3 E 0.00 3.00 905.99 0 33 S 49 1 E 1.24 0.12 1905.93 0 ~1 S 77 52 =: -0.42 O.O~ ~905.92 0 31 N ,_:~5 _.,~7 ~- =.° '~,5 0.15 3~71.13 26'30 H 4'~. ~2 { 209.21 0.78 47,JO.lO 40 25 N 4~ 37 :: 751.~7 1.28 5435.3~ 41 20 ~J ~1 27 ~ 143:~.59 0.31{ 5!07.03 37 20 N 41 42 ' 2072.89 0.00 52~5.78 37 20 N 41 ~2 ( 2103.19 0.00 PAGE DATE OF SdRVEY: 15-NDV-85 KELLY BUSHING ELEWATiON: ENGINEER: LESNIE/SARBER 93.00 -2T MEASURED DEPT RECTANGULAR COORDINATES NO~TH/SOUTH EAST/W:ST FEET FEET 0.30 N 0.00 2.02 S 3.83 9.61 S 9.15 10.32 S 14.56 I16.~6 N 179.91 502.14 N 575.18 1000.98 N 1033.80 1482.33 N 1449.01 1504.98 N 1469.20 ..'. o,,;,~0' N o o E 4~'3'3 S 62 7 E 13.27,. S 43 36 E 17.85 S 54 39 E 214.31 763.53 N 48 52 1438.99 N 45 55 2072.91 2103.21 3F-5 KUPARUK NDRTH SLOPE,ALASKA CG'qmGTJTI]"4 JAT=: 19-36C-85 ZNTERPOL4T'3 V~LU=S F~]q -V:N TRUE SuB-SEA ME&SURE2 VLRTICAL VERTI'&L ]EPT~ DEPTt O.O0 0.00 -93.00 93.00 93.00 0.00 193.00 193.00 lO0.O0 293.00 293.00 23~.00 393.03 393.00 30J.00 493.00 493.00 400.00 593.01 593.00 30~.00 593,01 693,00 500,00 793.01 793.00 700,00 993.01 693.00 800.00 ~93.01 993.00 1093.02 1093.00 1000.00 1193.02 1193.00 llOO.OO 12~3.03 1293.00 1200.00 1393,03 1393,00 1300,00 1493,04 1~93.00 1400.00 1593,05 1593,00 1500.00 1693.~5 1693.00 1600.00 1793.06 1793.00 1700.00 1893.06 1893.00 l~O0.O0 19~3.07 1993,00 1900.00 2093.07 2093,00 2000.00 2193,07 2193.00 2100,00 2293.07 2293.00 Z2OO.O0 2393,07 2393,00 2300.00 2~93,07 24~3,00 2400.00 2593,07 25~3,00 2500,00 2593.05 2593.00 2600..00 2793.03 2793.00 2700.00 2893.05 2893.00 2~00.00 2993.9~ 2993.00 £)00.00 3093,09 3093.00 303~.00 3193,10 3193.00 3100.00 3293.17 3293.00 320~.00 3393.63 3393,00 3300,00 3495.1~ 3~93.00 3400,00 3598.06 35~3,00 5500.00 3703,11 3693,00 3310,93 3793.00 3700.00 3920,63 3893,00 3300,00 0 0 N 3 0 ~ 0.30 0 5 N ~3 2 ~ -3.07 0 13 .S 43 23 ~ -0.05 0 12 N ~! 23 ~ 0.15 0 17 S ~6 3 ~ 0.28 0 22 S 5~ 22 ~ 9,34 0 20 5 72 33 5 0.35 0 15 S 53 24 5 1.09 ,3 21 S 51 13 5 1.20 0 33 S 45 23 5 1.2~ 0 33 S 43 48 E 1.29 0 35 S 33 & 5 1.17 0 37 S 25 32 E O.B7 O 39 S 14 3~ E 0,41 O +I S 7 43 : -ID 26 : m O 34 S 5 55 : -0,98 O 32 S 34 ~2 5 -1.40 0 2J 3 64 25 E -1,36 O 33 5 75 51 ~ -0,96 0 3'2 S 77 3~ :£ -0,46 0 25 S ~2 3 ~ -0,02 0 15 S 63 3~ ~ 0.29 S 9 S 55 23 E 0.41 0 6 N '35 23 E 0.52 C i8 N 87 40 E 3,78 0 22 S ~1 52 5 1. 19 ~ 23 5 :~0 41 ~ 1.58 0 ~1 :~ 7~ 25 : 1,94 0 i9 S a'~ ~2 ~ 2.25 0 30 N :~5 ~3 E 2,82 0 %0 .5 :~0 19 ~_ 3,51 0 54 S 87 il E 4.27 3 ~5 N 4:.~ 22 ~ 7.39 7 39 N 43 15 E 17.31 i1 ~0 N 50 55 E 34.30 15 36 N 5~ 37 = !~ 55 N 55 4 ~ 89.80 23 1! N 5~ 5 5 129.5! 25 ~O N 5! 5 E 174.15 PAGE DATE 3F SU2VEY: 15-N3V-85 KELLY BUSHING ELEVATIJN: ENSINEER: LESNIE/SARSER ;E:T O; SUE-SEA DEPTH DOGLEG Rr-CT~NGUL~,R COORDInaTES S:V2RITY NDRTH/SDUTH 5'.1ST/WEST DEG/IO0 F:ET~ FEET 0.00 0.00 N O.O0 0.2) 0.02 S 0.07 3.31 0.05 S 0.02 0.11 0,18 S 0,39 0,33 0,29 S 0,70 o.14 o.6s s 1.18 O.1B 0.93 S 1,74 0,15 1.02 S 2.26 0.15 1.16 S 2.74 0,45 1,45 S 3,.18 0,20 1.9,B S 3,77 0.15 2.63 S ~+.50 0.15 3.39 S 5.11 0.13 4.32 S 5.53 0,32 5,37 S 6.04 0,19 6,55 S 6,28 0,17 7,65 $ 6,37 0.2~ 8.53 S 6.66 0,32 9.11 S 7.31 0,14 9.38 S 8,1.5 0.08 9.60 S 9.09 0.07 9.75 S 9.92 0,08 9,89 S 10,45 0.14 10.06 S 10.31 3.11 10.11 S 11.01 0,32 10.07 S 11.34 0.04 10.10 S 11.95 0.16 10.21 S 12,61 3,14 10,34 S 13,25 0.32 10,42 S 13.78 0.13 10.33 S 1~.50 0.11 10.40 S 15.55 O. 80 10.51 S 16.'!36 4.23 9.12 S 19.80 4.13 1.95 $ 26.65 4.28 9,77 N 3~,95 3.96 24.16 N 58.50 ~,1~ 42.51 N 84.81 1,30 66.21 N 117,34 2.96 93,71 N 153,03 93.00 0'08' -~$ 75 35 W 0.05' "'S 19 21 W 0.43 S 65 20 E 0.76 S 67 18 5 1.36 S 60 6 ~ 1.97 S 61 59 E 2.48 S 65 45 E 2.98 S $6 59 E 3.50 S 65 34 E 4.28 S 62 21 E 5.21 S 59 43 E 6.13 S 56 27 E T.lO S 52 30 E 8.08 S 4~ 20 E 9,07 S 43 46 E 9.96 S 39 47 E 10.82 S 37 59 E 11.68 S 38 43 E 12.43 S ~0 59 E 13.22 S 43 26 13.91 S 45 30 14.39 S 46 34 14.77 S 47 2 14.95 S 47 26 15.16 S ~,8 23 15,65 S 49 47 16,23 S 51 0 15.81 S 5.2 2 17.28 S 52 54 E E E E 17.80 S 54 32 E 18.71 S 56 13 E 19.92 S 57 49 f 21.80 S 65 15 E 26,72 S 85 49 E 40.16 N 75 55 E 63.29 N 67 33 E 94.87 N 53 22 E 134.73 N 60 33 E 179,45 ~ 58 31 E FT 3F-3 KUP~RUK TqUE IE&SURE3 VERTICAL 3EPTH DEPTi 4032.25 3993.00 4144.93 4093.00 4258.73 4193.30 4373,15 4293.00 4491.25 w393.00 4512.75 4~93.J0 473~.40 4855.87 4693.00 4999.86 47~3.00 5135.02 48~3.00 5273.0~ 49~3,00 5~10,41 5093,00 5547,12 5193,00 5683.26 52~3.00 5818.57 53'93.00 5952.84 5493.00 6~85.$i 5593.00 6217.20 3693.00 6347,27 5793.30 6%76.92 5893.00 6507,23 5993.00 5737.65 $093.00 5855.36 51'93.00 6991.13 52~3.00 7050.00 5339.76 OAT~: 1)-O~:C-g5 INTERPOLATED V~LJE5 =3~ EVeN 100 C]JRS5 VERTICAL DEVIATI3~ AZ'~IUT~ S6CTiON SJE-S{.~ VCqTI'&L DEPTH 3900.00 4100.00 4200.00 ,303.00 ~4OO.O0 4:00.3~~ *503.30 ,700.go ~800.00 26 31 t',,t 45 i 5 : '; :,3.57 28 29 ."..J 47 3~ =_ _~75.40 28 22 N 47 25 ~ 329.64 30 45 N 47 2~ m 3~5.15 33 5 N 45 4~ £ ~47.39 35 32 N 44 33 : 516.85 39 10 q 4~ 13 : 592.90 43 20 N ~ 43 E 575 59 40 25 N 43 3.~ = 701.28 43 44 N 43 11 : 352.15 43 24 N 43 0 = 947 13 43 13 N 42 54 : 1041.3~ 42 54 N 42 41 = 1134.55 42 34 N ~2 15 E 1225.88 42 5 ix] 41 53 ~ 1317.95 41 32 N ~1 33 ~ 1407.~3 ~O 52 q 41 1! ~:J 14~4.94 40 1 N ~0 43 5 1579.98 39 32 N 43 3~ - 1552.98 3~ ~2 N 40 2~ ~ 1745.29 w~O0.OO 5300.00 5100.00 5200.00 5300.00 5~OO.OO 5503.00 5600.00 5700.00 5,530.00 35 5a N o,,3 !q = !.~213.6J 39 ~0 N 59 55 ~ 1912.06 37 iO ;q 41 42 5 1991.31 J7 20 N 4! 42 5 2067.54 37 gO N 41 42 ~ 2103,19 5'509.00 5300.30 5103.00 5230.30 6i45.75 P~SE gATE OF SURVEY: 15-N]V-85 KELLY BUSHING ELEVATION: ENGINEER: L:SNZE/SARSER 93.00 FEET O~ SUB-SE& DE~TH DOGLEG RECTANGULAR SEVERITY NgRTH/SgUTH D;G/iO0 FEET 0.5~ 126.01 N 0.59 160.87 N 0.03 197.58 N 3.79 235.20 N 2.69 277.78 N ~.2! 325.25 N 2.32 380.69 N 0.10 440.97 N 1.27 502.07 N 0.61 $68.22 N COOROINATES HSR"rZ.,.:DEP ~,RTUR E E A S T/w E $ T D I g.'][%.,:: ..-..~L' .=&.7,,. I ,,I U T H 190.67 E 228.'5~ ~:,.Nr' 6 32 E 229.13 E 279,97 4 55 E 269.16 E 333,89 N 53 43 E 310.08 E 389,.'18 N 52 49 ~ 356,24 E 451,74 N 52 3 E 405,31 E 520.30 N 51 10 E( 458,40 E 595,~7 ~ 50 17 ~ 516,60 5 679,22 N 49 30 ~ 575,12 E 763,44 ~ 48 52 5 ~37,45 ~ 853,94 N 4g 17 5 0.42 637. 0.27 706. 0.30 774. 0.2:~ 843. 0.47 910, 0.61 977. 0, ?5 1043. 3.65 !107. O, 25 1170, 0.80 1233. 62 N 702.42 E 948.66 N 47 46 E 58 N 766.66 E 1042.50 N 47 20 E 96 N 830,00 E 1135,54 N 46 57 E 08 N 892.41 E 1227,67 N 46 37 ~ 73 N 953,50 E 1318,56 N 46 18 E 51 N 1013,12 E 1~07,88 ~ 46 1 E 35 N 1071,08 E 1495.!6 ~ 45 45 E 76 N 1126.88 E 1580.19 N 45 29 E 79 N 1181,16 E 1663,10 N 45 15 E 46 N 1234,53. E 1745,35 N 45 1 E 0,13 1297. 1.03 1361. O.00 14.21. 0.00 14.78. 0,0O 1504. 21 N 128,6.83 E 1328.62 q 44 48 25 N 1342.75 E 1912.07 ~ 44 36 35 N 1394.57 E 1991.32 N 44 27 33 N 1445.44 E 2067,55 N 44 21 93 N 1469.20 E 2103.21 N 44 18 F? E E E . E 3F-~ KgPARU~ NORTH TOP BASE TOP P6TD KUP~RUK ~ KUPARd~ C KUPARdK A KU~ARUK A INT~RPOL~T:D VILJBS ='3R qEASdRE2 3:~TH ~EL~ ~e, 53~3.00 6a57.00 6596.30 6751.00 6920.00 ?050.00 3&T:: 19-DEC-B5 SHCSEN H3RIZSNS FROM 5320.56 5835.37 5954.40 5111.00 5236.43 5339.78 ORIGIN: TVD lB' SJB-SEA 5727.56 5792.37 5391.40 5018.00 $143.~3 6245.78 D~TE O: SURgEY: l$-N]V-85 KELLY BUSHING ELEV4TION: ENGINEER: LESNIE/SARBER 93.00'DT FNL,i' RE.C T,~NGd AR?COORDINATES NORTH/SDUTH' ,:EA'ST/WEST 1188.07 N 1195.93 E 1228.6~ N 1230.72 E 1291.?1 N 1284.15 E 1372.66 N 1352.31 E 1~46.1D N 1416.72 E 1504.98 N 1459.20 E CGqPOT~TZ]N O.fTE: 1'9-D:C-$5 P~SE 7 ALASKA, INC. 3F-3 KJP&RU,q NORTH SLOPF,ALAS.qA DATE 3F SURVEY: 15-NOV-85 KELLY BUSHING ELEVATION: ENGINEER: LESNIE/SARBER 93.00 TOP KUPARUK C ~ASE KUPAqUK C TOP KUPARUK fi 56SE KU?ARUK A PBTD TD ORIGIN: 18' FNL,I' ~E.~SUR=3 9~PTh TVO 3~LOH q3 FRSM K5 SJB-SEA 5383.00 5820.56 5727.55 5467.00 58B5.37 5792.37 5595.00 5~84.40 5~91.40 6751.00 6111.00 6318.00 6'~20.00 5236.43 6143.43 70~0.00 6339.78 5246.78 FINAL WELL LSCATiOH AT TO: 'FRU~ MEASjRED YE2TZCAL V~RTI~.a.L DEPTH JEDTM 7050.00 5339.75 5245.75 q;D~IZONTAL 3EPA~TUR£ 3I S TA NS E AZ I MUTd F ::' 57 DEG MIN 2103.21 N 44 18 FWL,S REC NO SURFA TANGU RTH/S 188,0 228.6 291.7 372.6 4~5.1 504.9 '1195.93 E 123'0.7Z E 1284.15 E 1 352.31 E 1415.72 E 1469.20 E FT SCHLUMBEROER 0 1RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL 3F-8 FIELD KUPARUK COUNTRY USA RUN ONE DATE LOOOEO REFERENCE 00007]]06 WELL NAME: 3F-8 SURFACE LOCATION: 18' FNL, 1' FWL, S29, T12N, R9E, UM 224. - 1000 -~ 0 0 SO0 1000 1 SOO 2000 · .. ~. i i ~ _." _~ ~ ~ ! ..-' _." ..' f ~_ .~ i ! i i [ ~ ~ ~ ~ ~ ~ ~ :' ; ~.-.,L-~.i--L~._L. 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T-','"T"T"~'-t-f"'~ .......... r"~'-'r"?"f'"?"f'"T"* ...... ?'T";'"~'"~'"f'"r"%'?" -lO00 -SOO 0 SOO lO00 ]SOO 2000 2S00 Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. · . OPERATOR, WEL~ NAME '~ND ~UMBER - Reports and Materials to be received'by: Date Required Date Received Remarks Completion Report . ~_~~ Samples/ Mud Log Core Chips , ~1/ . Registered Survey Plat Inclination Survey Directional .Survey _. / Drill Stem Test Reports I / L.FJ.04 NEW PROJECTS ENGINEERING TRANSMITTAL # 0734 TO: Wm VanAlen State DATE: January 10, 1986 FROM: H. D. White/P. S. Baxter WELL NAME: 3F-8 TRANSMITTED HEREWITH ARE THE FOLLOWING: 3F-8 One copy each Final Blueline and Sepia for each: 2" Dual Induction SFL-GR · 5" Dual Induction SFL-GR 2" Natural Gamma Spectroscopy 5" Natural Gamma Spectroscopy 2" Long Spacing Sonic-GR 5" Long Spacing Sonic-GR 2" LDT-CNL-NGT (Raw) 5" LDT-CNL-NGT (Raw & 25" HI -RES) 2" LDT-CNL-NGT (Porosity) 5" LDT-CNT-NGT (Porosity) 5" & 25" Electromagnetic Propagation 5" Dual Dipmeter-GR Cyberlook 11/6/85 run 1 11/6/85 run 1 11/6/85 run 1 11/6/85 run 1 11/6/85 run 1 11/6/85 run 1 11/6/85 run 1 11/6/85 run 1 11/6/85 run 1 11/6/85 run 1 11/6/85 run 1 11/6/85 run 1 11/6/85 run 1 PLEASE RETURN RECEIPT TO: ARCO ALASKA, INC. ATTN: P. Susanne Baxter, A~~& Sas g0ns. 00mmissJ0n P. O. Box 100360 Anah0rage Anchorage, Alaska 99510 ARCO Alaska, Inc. Post Office B~-~.. f00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC, ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 12-31-85 TRANSMITTAL # -5496 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints/ Open Hole/ Schl/ One * of each 5" DIL/SFL-GR 2" DIL/SFL-GR ~5" DEN/NEU (poro) 2" DEN/NEU (poro) ~5" DEN/NEU ( raw ) ~" DEN/NEU (raw) Cyberlook LSS/WF \ ~ Dual Dipmeter RFT Log 5" DIL/SFL 2" DIL/SFL ~5" DEN/NEU (poro) 2" DEN/NEU (poro) 5" DEN/NEU (raw) 2" DEN/NEU (raw) ~ Cyberlook 5" LSS 2" LSS 11-27-85 Run #1 11-27-85 Run #1 11-27-85 Run #1 11-27-85 Run #1 11-27-85 Run #1 11-27-85 Run #1 11-27~85 Run #1 11-28-85 Run #1 11-28-85 Run #1 11-28-85 Run #1 11-09-85 Run #2 11-09-85 Run #2 11-09-85 Run #2 11-09-85 Run #2 11-09-85 Run #2 11-09-85 Run #2 ~ 11-09-85 Run #2 11-10-85 Run #2 11-10-85 Run #2 1800-6631 1800-6631 6000-6605 6000-6605 6000~6605 6000-6605 6000-6582 6000-6615 3098-6628 6216-6431 3026-7040 3026-7040 4400-7015 4400-7015 4400-7015 4400-7015 6300-6900 3026-7032 3026-7032 3F~9~5'' DIL/SFL~R ~2" DIL/SFL-GR 5" DEN/NEU 2" DEN/NEU 5" DEN/NEU 2" DEN/NEU ~ ~ Cyberl~k ~ RFT Log (poro) (poro) (raw) (raw) 11-17-85 Run #1 11-17-85 Run #1 11-17-85 Run #1 11-17-85 Run #1 11-17-85 Run #1 11-17-85 Run #1. 11-17-85 Run #1 11-16-85 Run.#1 3410-7770 3410-7770 7050-7744 7050=7744 7050_7721F /~ 7260 - ~a ~ 0~ & uas Cons. 6ommiss/og Receipt Acknowledged: State of Ak*bl/se Rathmell*bl NSK Clerk*bl Drilling*bi D & M*bl Vault*films Date: ARCO Alaska, Inc. Post Office B.~..100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC, · ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE12-19-85. TRANSMITTAL # 5473 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Open Hole LIS Tape plus listing/ schl/ One copy of each ~2H-9/w 12-02-85 Run #1 1800.0-8113.0 ref# 71048 ~2H-10~/ 11-23-85 Run #1 2856.0-7960.0 ref# 71002 '~2H-12 x, 11-07-85 Run #1 2743.0-6829.0 ref# 70947 ~'~2V-16/! 06-03-85 Run #1 2973.0-7168.0 ref# 70952-/~c~p~/~ ~3A-10)! 11-09-85 Run #1 3179.0-7014.0 ref# 70960 ~3A-11/, 11-16-85 Run #1 3208.0-7330.0 ref# 70989 ~ 3A-12// 11-23-85 Run #1 3797.0-8006.0 ref# 71003 '~3A-13;/ 12-01-85 Eun #1 1800.0-7597.0 ref# 71047 '~3A-14'/ 12-09-85 Run #1 0144.5-7818.0 ref# 71073 ~.- 3C-9/, II 07-10-85 Run #1 3920.0-8332.5 ref#_ 70996-r~~ ~7'~ 3F-8~! 11-09-85 Run #1&2 0115.0-7040.0 ref# ?0994 ,~3F-9/~ 11-17-85 Run #1 3410.0-7770.0 ref# 70990 3F-10tt 11-27-85 Run #1 1800.0-6631.0 ref# 71037 '~ 3F-11 ~ 12-05-85 Run #1 0148.0-8618.5 ref# 71061 ~J3J-9~/ 11-24-85 Run #1&2 0~91.0-6789.0 ref# 71034 3j-10-~ 12-08-85 Run #1 0096.5-7348.5 ref# 71074 ~ f-~ -lq- ~d~ ~3-~3- ope~ -/~ - VFIF 3~-/~-~0~?~-~-~~ - 3 ~- ~o~ ~ ~_ ,~ ~., ~.. ~ V- ~-~ . - -~ ~n~ ~ ? ?3- ~/~ ( /,~:~ .,',, ~ c~.~ u:~. Receipt Acknowledged: 'STATE OF ALASKA* ~ H-I~ ~I~ ~o ! -.s -dre~-4 ARCO Alaska. Inc. Date: ARCO Alaska, Inc. Post Office Be )0360 Anchorage, Al~'s~a 99510-0360 Telephone 907 276 1215 December 13, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton: Enclosed are the November monthly reports for the following wells: 2H-9 3A-11 3F-8 4-22 16-19 2H-10 3A-12 3F-9 4-29 L2-3 2H-11 3A-13 3F-10 16-7 L2-21 2H-12 3C-6 3J-9 16-15 L3-15 3A-10 3F-7 3J-10 16-18 WSP-12 WSP-20 If you have any questions, please call me at 263-4944. Si ncerely, Gruber Associate Engineer JG/tw GRU12/L129 Enclosures RECEIVED ~l~sk~, 0~ ~, Gas Cons. Commission Anchorage . - ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany. .- STATE OF ALASKA "' " ALASKA C~ AND GAS CONSERVATION CO'~'-411SSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well ~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-246 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 209-21464 9. Unit or Lease Name Kuparuk River Unit 4. Location of Well atsurface 18' FNL, 2' FWL, Sec.29, T12N, R9E, UH 5. Elevation in feet (indicate KB, DF, etc.) 93 ' RKB I6. Lease Designation and Serial No. ADL 25632 ALK 2565 10. Well No. 3F-8 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of. November ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 2130 hfs, 11/4/85. Drld 12-1/4" hole to 3050'. Ran logs. 8-1/2" hole to 7050'TD (11/9/85). Ran logs. Ran, cmtd, & tstd 7" csg. 1700 hfs, 11/11/85. Ran, cmtd & tstd 9-5/8" csg. Drld PBTD = 6920'. Secured well & RR ~ 13. Casing or liner rgn and quantities of cement, results of pressure tests · 16", 62.5#/ft, H-40 weld conductor set 8 115'. Conductor report not yet received. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe @ 3029'. Cmtd w/865 sx PF "E" & 350 sx PF "C". 7" 26.0#/ft J-55, BTC csg w/shoe ~ 7009' Cmtd w/300 sx Class G & 175 sx PF "C". 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SFL/GR/LSS/SP f/3022' - 115' LDT/CNL/NGT/EPT f/3022' - 1550' LDT/CNL/NGT/EPT/GR f/3022' - 2550' SHDT f/3019' - 1550' DIL/SFL/GR/SP f/7040' - 3026' 6. DST data, perforating data, shows of H2S, miscellaneous data None FDC/CNL/GR/Cal f/7015' - 6200' & 5000' - 4400' · LSS/GR f/7032' ~ 3026' GR/CCL/CET/Gauge ring f/6991' - 5418' GCT f/6920' - surface Alaska Oil & Gas Cons. C0r;Im, issi0n Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED (~ _~, ~]--~ TITLE ^ssociate Engineer DATE NOTE--Report/on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 TEMP2/MR73 Submit in duplicate MEMORANDUM TO: THRU: FROM: State of AlaSka ALASKA OIL AJ~q) GAS CONSERVATION COmmISSION C. V ~~erton Chai~a~'--' Lonnie C. Smith Co--is s loner TELEPHONE NO: Bobby D. Foster--'-' Petroleum Inspector DATENovember 12, 1985 F'LE NOD. BDF. 114 SUBJECTBoPE Test ARCO's - K.R.U. - 3F-8 Permit #85-246 Kupa~ak River Field Thursday_, November 7, 1985: The BOPE Test began at 12:00 A~M and was ~°ncl-Ud~8 a~ 1:00 AM.~- As-the attached BOPE test report shows, there were n failures. In summary, I witnessed the BOPE test on ARCO's 3F-8. Attachment 02-001AfRev. 10/79) O&G #4 5184 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Operator . Location, General ~~ Well Sign~ General Housekeeping~Rig ~~ Reserve Pit ~~ Mud Systems Trip Tank ~-~ Pit Gauge Flow Monitor Gas Detectors Visual Audio BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pressure Test Results: Failures ~ Repair or Replacement of failed equipment to be made within --- ACCUMULATOR SYSTEM - Full Charge Pressure~~.~P psiK Pressure After Closure /~D psig. Pump incr. clos. pres. 200 psig --- mi~.~sec. Full Charge Pressure Attained: 3 min-- sec. Controls: Master ~_~ Remote3 Blinds switch cover.~m_ . Kelly and Floor Safe~y Valves' Upper Kelly / Test Pressure Lower Kelly / Test Pressure Ball Type / Test Pressure Inside BOP / Test Pressure Choke Manifold ~~Test Pressure~~'~ No. Valves // No. flanges.. ~_ & Adjustable Chokes Hydrauically operated choke / Test Time J hrs. day~ and Inspector/ Commission office notified. Remarks: Distribution orig. - AO&GCC cc - Operator cc - Supervisor ARCO Alaska, Inc Post Office~....x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 21, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501_ _ SUBJECT' Conductor As-Built Location Plat - 3F Pad Wel 1 s 1-16 Dear Mr. Chatterton- Enclosed is an as-bUilt location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, . . .' · · - ~. Gru~ber~~v~ Associate Engineer JG/tw GRUll/L22 Encl osure If RECEIVED OCT 2 5 ] 85 Alaska Oil & Gas Cons, Commission Anchora~9 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AS I)' T CONDUCTORS I-e IN SECTION 1- ¥=~'~85,734..98 LAT=70°22,20.0858,, X= 508,662.35 LONG=149°55' 46. 549'' 89 FNL, 162 FWL, 52 O.G., 56.1 PAD. 2- ¥=5,985, ?45.10 LAT=?O°22' 20. [856" X= 508,638.99 LONG=149°55' 47. 233'' 78 FNL, 139 FWL, 52 O.G., 56..3 PAD 3- Y=5,985,754.79 LAT=?0o22'20.2812" X= 508,616.29 LONG=149°55' 47. 896'' 69 FNL, 116 FWL, 52 O.G. 56.3 PAD 4- Y=5,985,764.77 LAT=?O°22'20.3796'' ' X= 508,593.66 LONG=149°55' 48. 558" '[ 59 FNL, 93 FWL, 52 O.G. 56.2 pAD 5- Y=5,985,774.87 LAT=70°22 ' 20. 4792'' X= 508,570.4'3 LONG=149°55 ' 49. 237 J~ 49 FNL, 70 FWL, 52 O-.G. 56.2 PAD 6- Y=5,985,784.84 LAT=70°22 ' 20. 5776'' L. X= 508 547.58 LONG=149°55'49.906" 9 NOTES 39 FNL, 48 FWL, 52 O.G. 56.1 PAD I. COORDINATES ARE A.$.R, ZONE4. 7- Y=5,985,794.93 LAT=70°22'20.6771'' 2. SECTION LINE DISTANCES ARE TRUE. X= 508,524.44 LONG. 149°55'50.582" 28 FNL, 24 FWL, 52 O.G.,55.9 PAD :~.HORIZONTAL AND VERTICAL POSITIONS ARE BASED 8- Y=5,985,804.81 LAT=70°22' 20. 7744', ON MONUMENTS SF-MIDDLE & SF-EA~T PER L.H.D&A~OC. X= 508,501.41 LONG=149°55'51.256'' 4. O.G.£LEV*T,ONS ~NTERPOLATED ~O~ S/C ~W~.~O. ~ ~, ~ ~W~, ~ 0.~.,~.~ CED-RIXX-3030 "~~~. ASy~I~T_~ CONDUCTORS 9-16 IN SECTIQN 19 OF ~~.-""~'..-~.o-k X= 508 432 81 LONG=149°55'53 26~" ~.' ~ '.'1 ~. 12 FSL, 67 FEL, 51.20.G., 56.1 PAD , f~/49~~ k~ . ~o- ~=~,~s~,s~.~o ~Az=~o°22'2~.~s,, ~.,,~,,,,,,,, ~. ~...:... ~ . 21~ FSL, 89 FEL, 51.20.G., 56.2 PAD ~..OWA~..~""~- · ~ 11- Y=5 985 855 14 LAT=70°22'21 2708" %. ~eO.S ... ~ X= 508,387.41 LONG= 149o55, 54. 590" "i~?"......":~SL'_~ ~ -- 32 FSL, ~2 FEL, 5~.20.G., 56.3 PAD ~~~'~ 12- Y=5,985,865.19 LAT=70°22'21.3699'' ~~~ X= 508,364.05 LONG= 149°55 ' 55. 273" I HEREBY'CERTIFY THAT I AM P~~Y ~II~D - 42 FSL, 136 FEL, 51.10.G. 56.2 PAD A~ LIC~ED TO PRACTICE LAND I~VEYIM'IN 13- Y=5,985,874.97 LAT=70°22'21.4663'' THE.~TATE OF ALASKA, ~AT ~11 ~AT ~~~NT8 X= 508,341.36 LONG=149°55' 55.937" A ~URVEY ~DE UNDER MY DI~CT~RV~ AND. 52 FSL, 158 FEL,51.10.G., 56.3 PAD THAT CONDUCTOR~ I T~ I A~.C~CT Al ~ '14'.Y=5,985,885.08 LAT=70°22'21.5660'' SEP~ER 19,1~8S A~.C~T~'t ~U 1~ ARE CORRECT A8 ~ ~P~ER ~l, 1~1. X=- 508,318.27 LONG=149°55' 56.612" 62 FSL, 181'FEL, 51.1 O.G.,56.3 PAD 9~~O ~"~' ' 15. Y:5,985,894.96 LAT:70°22 ' 21 . 6635'' ~ 72 FSL, 204 FEL, 51 O.G. 56.1 PAD · X: 508,272.7~ LONG:149°55'57.943'' 2~ ~_, ~ ..... ..~2 FSL, 227 FEL, 51 O.C. 56 P~ ~ - ' Kupmruk ~oject ..~cs ~.--Ii~ DRILL SI~ 3 F 6 < CONDUCTOR AS-BffiLT coc,m CONDUCTORS I THRU8 LOCATED IN PRO,ACTED CONDUCTORS 9 THRU 16 LOCA~D IN P~TR~TED SEC. 19, T. 12N.,R. gE.,U. MER. ~~m~ Dre~ed by:Sydney2 ~. ~. M~85-26 October 15, 1985 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3F-8 ARCO Alaska, Inc. Permit No. 85-246 Sur. Loc. 18'ENL, 2'FWL, Sec. 29, T12N, R?E, UM. Btmhole Loc. 1516'FSL, 1513'F%~, Sec. 20, Tt2N, RgE, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing 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 co~encing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. BY ORDER OF THE COMMISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o enc!. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office Bo~c'-/00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 3, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 3F-8 Dear Mr. Chatterton: Enclosed are: An application for Permit to Drill Kuparuk 3F-8, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plot A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment We estimate spudding this well on November 7, 1985. If you have any questions, please call me at 263-4970. JBK/HRE/lt PD/L08 Enclosures RECEIVED OCT Alaska Oil & Gas Cons. Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION COi~-¢/llSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work, DRILL E~X REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [~(X DEVELOPMENT GAS [] SERVICE [] S~A~-IGRAPHIC L--] SINGLE ZONE [~]XI~' (!' ~/~,/. MULTIPLE ZONE ~ "L.'/ ~.,/~ ~ 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 -%_ ~/O~-.,_ · ~n,,. , 4. Location of well at surface 18' FNL, 2' FWL, Sec.29, T12N, R9E, UN At top of proposed producing interval 1220' FSL, 1222' FWL, Sec.20, T12N, R9E, UH At total depth 1516' FSL, 1513' FWL, Sec.20, T12N, RgE, UH 5. ElevationRl(R 93fin, feetpAD(indicate56, KB, DF etc.) 6. Lease designation and serial no. ADL 25632 ALK 2565 9. Unit or lease name "~e Kuparuk River Unit 10. Well number 3F-8 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse miles 2' ~ surface feet 3F-7 well 25' ~ SURFACE feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 7059' MD, 6290' TVD feet 2560 11/7/85 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures ~ psig@__R~°F' Surface KICK OFF POINT 3200 feet. MAXIMUM HOLE ANGLE 42 oI (see 20 AAC 25.035 (c) (2) 2977 __psig@ 5_R~8 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SETTING DEPTH QUANTITY OF CEMENT SIZE Hole Casing Weight 62.5# 36.0# 26.0# 22. Describe proposed program: CASING AND LINER Grade I Coupling Length H-40 ! Weld MD TOP TVD 80' 35' 35' I 35' I I 35' i 34' I I 34' MD BOTTOM TVD 1151 115' 30531 3053' I 70591 6290' I I (include stage data) ± 200 cf 800 sx PF "E" & 350 sx PF "C" 330 sx Class G neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7059' MD (6290' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. The stack and related equipment will be tested to 3000 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2593 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3000 psi prior to releasing.the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 3F-8 will be 25' away from 3F-7 at the SURFACE. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus wi]] be left with a non-freezing fluid during any interruptions in the disposal process. (continued on attached sheet) 23. I hereby cer,~,i'f~that the foregoing is truce and correct to the best of my knowledge SIGNED //~~~ '.~~~'~/ TITLE Regional Drilling Eh gr. Thespace b~w~ror~fnyssi(~; us; '" CONDITIONS OF APPROVAL Samples required Mud log required I~]YES [lNG [-]YES ~NO Permit number Approval date ,¢%~- %¥C, _-, ~ 10f15/85 APPROVED BY Form ~0401 (HRE) PD/PDO~ / ' ~¢~¢ ~-I-R~ Directional Survey required [~ES []NO APl number SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE October 15, 1985 by order of the Commission Submit in triplicate PERMIT TO DRILL 3F-8 (cont'd) Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 200 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. RECE]VED Alas~ Oit & Gas Cons. Commission Anchorage FIELD, NORTH SLO .PE, ALASKA EAST~. WHIP,$TOCKo ! NC. 4000 _ 5;000 _ 6000 ' ?000 BASE PERHAFROST TVD-t-$23 .- TOP UGNU SNDS TVD-1898 .. TOP W SAK SNDS TVD-2543 K-12 TVD-2853 g 5/8" CSG PT TVD-3053 .... KOP TVD-3200 THD-3200 DEP-O 3 ~L I$ BUILD 3 DE_O ~ ~' EOC TVD-4491 THD-4618 DEP-$02 K-$ TVD-4583 THD-4742 DEP-$8? ~ AVERAGE ANGLE N 42 DEG 32 I"IlN · _ \ T/ZONE C TVD=5838 THD=6445 DEP=I ~ ~%,.' ~TARGET CNTR TVD-5991 THD-6653 DEP-I~7'8 ~- T/ZONE A TVD-6003 THD-6669 DEP-I~9 "% BASE KUP SNDS TVD-61 43 THD-6959 DEP'-2018 TD (LOG PT) TVD-6290 THD-?059 DEP-2153 I ' { I ,ooo~ooo~ooo R E C E ! V E D VERTICAL SECTION Alaska 0il & Gas Cons. Commission Anchorage · SC)~,E-; 1-? IN. - 1000 FEET ~"~ Pi~) ~IF. bELL ldO, 8 PROPOSED : KUPARUK FIELD. NORTH SLOPE, ALASKA EASTIdAN I, H4IPSTOCK. INC. 3000 1000 -- _ .. 1,/E-ST-EAST ........... i' ' o ' ~ ooo .2000 i I I 3OO0 T~'D,,~! DEP-lJ7'~ ' NORTH E'AST ~tRF~ LtiOATltlI~ 1~.' FILL,. 2' Ft~ ~EC. 29. tt~ll. ~ T,'UmET LO~trTTrJll~ 1320' FIL. 13~11t' FIlL SEC. ~0. TI J' N 44 DEB 34 MI N E 1878' (TO TARGET) . , · ' " :~00 2;o0 ,~00 ' D t00 200 ~oo 400 500 600 ~,~:..~ ............. ~._ .--~-.-..~..__....__ ~ ~--.,...~_ ~.~ ~ .... __.~.__., . . .... ...... . ~00 ' ~ r' : ' I ARCO, AL~KA; ~ ,ISC~ ~'.~ ~ ~ ..' ~'~' , '~' '"t' ~" F~9~ , ~ / lqY~ 200 [ I i '~ ' , .... m~' ' . ~ .' ~.. ,~ ' , ~ " I ~/ i NOTE~ ~L PATHS ,EXTEND [BEYOND J ' ' X', ' , /. / { / I TH~S VIEwiNOtWiNDO~ ' ": "''" " ........ : ]: ]~l I ,. : T · ./..,, / :. , I . . , ~ .- .....-. , ,, .,, i , ] " " : ' ~'2255 : i' . .' '~: ~ .... '" :.,'.[. ' K - ~- ~~~~- .100 200 ~00 \ \ \ ~0o 400 - __ I 300 $0o 600 KUPARUK RIVER UNIT '20" OlVERTER SCHEMATIC D, ESCR [PT ION I. 1 6' COe~UCTOR. 2. TAI~O STARTER HEAD. $. TAI~O SAVER SU~. 4. T~O L~R ~I~-C~CT ASSY. 6. ~" ~ ~I ~ILLI~ ~ W/I O" ~TLETS. T. I0" ~ B~L V~~ ~10" ~ DI~RTER LI~S. V~S ~N AUT~TIC~LY ~ ~~ ~ A~~ ~~ER. 8. ~" 2~ ~I ~~ ~~~. MAI NTENANCE & OPERATI ~ i i 3 . I. UPON INITIAL INSTALLATION, CLOSE PREVENTER Alii) VERIFY THAT VALVES HAVE OPEhED PROPERLY. 1 "q/?C/ln bO/'/8. CLOSE ~AR PREVENTER AH BLOW AIR THROUGH DIVERTER LI~S EVERY 12 HOURS. 3. CLOSE AI~LR. AR PREVENTER IN THE EVENT THAT AN I~LUX OF WELLB(31~ FLUII3~ OR GAS IS DETECTED. IF ~CESSARY, MAI~ALLY OVERRIDE AI~ CLOSe: APPR(3aRIATE VALVE TO ACHIEVE DO NOT SHUT IN V~LL ! UNDER ANY CIRCUMSTANCES. i 7 6 5 4 . I~i-5/'8' BCP STACX TEST I. Fll. L ~ Sl'AO( AM3 ~ M¥~FCLD W/TH ARCTIC DIESEL. ~- (]-~C)( l~T ALL LCX]( DO)~I ~ IN WELM~.J~D ARE F1JI. LY RE-~. ~:AT TE~T PtUG IN WITH ~U~IN~ JT ~ ~ IN L~ SCREW. LIt~ YA~¥E3 ~)dAC~q' TO ~ ~'ACX. ~ OT1-ER cREASE ~%~[?~? AN3 HCt. D FOR ~0 MIN. [~ m~n I~ TO LIllE VALVES. CLOSE T(::~ PIPE ~ ~ NCR VALVES 6. TEST 1'0 250 PSI AN3~ AS IN STEP 7. 03qTIl~ TESTING ALL "V~-V~. LII~. AI~ O.iCI(ES WITH A 250 PSI L(:~ AN3 ~ PSI HIGH. TEST AS iN 8. ~ TCI:' PIPE RN~ ~ CL__n~_ 8Ol'T(3a PIPE TEST ~~ PI~ ~ TQ ~ ~I ~ ~ ~I. I0. ~ ~l~ ~ ~ ~ TO ~I ~ ~I. ~F~ ~ LI~ ~ ~ ~ ~UID. ~ ~ v~ IN ~I~I~ ~ITI~ PI~ ~ v~vE, ~ I~I~ TO ~ ~ ~I. 15. ~~ TEST I~~TI~ ~ ~~ ~ ~ST F~, ~I~, ~ ~ TO ~I~I~ ~I~. 14. ~~ ~ ~ ~ ~ NZ~I~ ~Y T~ ~I~Y ~~ ~ ~ILY [<ECEiVED Alaska OiJ & Gas Cons, C. ommissp~. .... ,,uraC~8 CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee (2) Loc thru 8) (n(.~,,4__ (3) Admi / o¢/V.-~.f~ O. (9 thru 12) 10. //,.7"/¢ 11. (10 and 120 v 12, (13 thru 21) (22 tl 26) YES NO · 1. Is the permit fee attached ...................................... 2. Is well to be located in a defined pool ........... 3. Is well located proper distance from property linei!!!!~!~!!!.i!! 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 ..... _........ s. '""'""'"''""'"'"'"' Does operator 'have bond in force a Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... 13. 14. 15. 16. 17. 18. 19, 20. 21. Is conductor string provided ........................................ ~ Is enough cement used to circulate on conductor and surface ......... ,FFF Will cement tie in surface and intermediate or production strings Will cement cover all known productive horizons ~ ....... ,.... ..... Will surface casing protect fresh water zones .... Is this well to b.e kicked off from an existing wellbore ........ . .... ... Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed , , . Is,a diverter system requi.red .. .... ,.. .............. .....,,,.,,.,. ...... ~ . 23. Are necessary diagrams of diVerter and BOP equipment attached ....... ~ 24. Does BOPE have s.ufficient pressure rating - Test to ~[~~._ psig .. ~ 25. Does the choke manifold comply w/API .RP-53 (Feb.78) .................. 26 Is the p of H2S gas probable ~ · resence ................................. 27 Additional requirements REMARKS Additional Remarks: Geo logy: Eng~n~r~ng: HWKjALWVA ~ MTMLCS.~-¢'/" d;¢~_,, HJH"'~?¢ //¢,~" ' ' ¢ rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE , , · 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. TAPE VERIFICATIDN LISTIN~ Alaska Oil & Gas Cons. ' n' · Co~h,fSslOrl LVP 010.~09 VEPIFICATION LISTING PAGE *$ REET, WEAD~R $* ~E~VICE ~A~E DATE :R5/ll/~7 qRIGTN : PR~V!O~S R~EL : ** TAP? HEADRR ** SERVICE wA~E :EDIT mATE ORIGIN :WS~.A mAPE NAME CONTINUATION PREVIOUS T~PE : ********** EOF ********** ** FILE HEADER FILE N~M~ :EDTT ,001 SE~VIC~ NAME DA~E : ~AXIMU~ LENG'rM : 1024 mILE TYPE : PREV]O!IS FILF : ** INF~R~ATIQN REC[}RDS ** qN~M COMTMNT$ PR~$.~ ~ 000 000 OOl 065 ** COMMENTS ** Cons. ************************************************************************************ * S ..H[,UMB~R~ER , LVP OlO,H02 VERIFICATION LISTING PR~E 2 * ALASKA COMPUTING CENTER , ************************************************************************************ CO~P~Y : ADC(~ ~L~SKA INC WELL : 3r-~ (WEST SAK) ~IrbD : KUPARUK COUNTY = NORTH sLOpE BOROUGH ST~TF = ALASK~ ,?OR NUMBER AT ACC: 709.55 RUN #1, DATE LmGGED: 06 NOV 19~5 LDP: H~W~RD RO~,AM C~$ING : 16,O00" @ 115' - RI.T SIZE : 12,25" TO 3044,0' TYPE FI.,U~D = LSN~ D~NS~T¥ : 9.60 r,B/G RM : 5,l~0 e 65.0 Dr VISCOSITY : 58,0 S R~F = 4,830 ~ ~5,0 DF FL!~ID I,OS$ = 5,6 C~ R~ ~T BHT m 4,450 9 76,0 DF ***** ~H?S DaT~ gag NOT BEEN DEPTH SMIFTED - OVERLAYS FIELD PRTNTS $**** ******************************************************************************* , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , * , * SCHbI.MBEDGER L~G$ I,NCbUDED WITH THIS M~GNETIC TAPE~ * * , ^laaka Oil & "~ ,~,,:o cons. Comn~iasion. , i ¢', LVn 010,HO~ VERIFICATION LIS~ING PAOE 3 * nO~b I~IDUCTION SPHERICALLY FOCUSED LOG (D[L) · * DATA aYAILABhE: B016.0' TO ~15.0' * LONG SPACING SONIC (LSS) * * DATA AVAILABLE: 2977.0' * ~,ITHO DENSITY COMPENSATED LOG (LDT) * , , ', , , , , , , , , , , , , , , , * $ , , ************************************************************************************ * SCHLUMBFR~ER * ALASKA COMPUTING C~NTE~ * ************************************************************************************ COmPaNY = ARCO W~LL = FIELD = KUPARUK CO{~NTY = NORTH ST.,OPE BOROUGH ST,ATE = ALASK~ JOB ~U~BER AT ~CC: 70994 ~U~ #2. DATE LOGGE~: 09 NOV ~985 CASI~]G = 9.695" 8 3026.0' - BIT $lZF = B.B" TO 7050.0' TYPE F!,UYD : bSND [,VD 010.W02 VErifICATION LISTING PA~E 4 VI,~CflS.~TY 6 0 LB/G , -' ] ~90 ~ 68 0 DF ~"{ : 9,5 R~C = ~.060 a 68,0 mbUiD LOSS = 4,B C] R~ AT 8~T m ~,679 ~ ~40, ~ATRIX = *~*$* THIS DaT& WA~ NOT BEEN DEPTH SHIWTED - OVERL~Y~ ~I~5D PRINTS * ~C~L~M~ERGER LaGS TNCL~DED W~T~ Wa~S M~GNETIC TAPE~ * * nUAL INDUCTION SPHMRICAhLY FOCUSED LOG (DIL) * * D~T~ AVaILAbLE: 7040,0' TO 3026,0' * bONG S~ACED SONIC LOG (bSS) * D~TA AVAILABLE: 703~.0' TO ~026,0' * * FU~MATIOM DENSITY CO~PMNSATED LOG (FDN) * COMPENSATED NEUTRON. [.~O~ {FDN} *. * D.STA .~V~IbABbE: 7015,0' TO 4400,0' * ****************************** ** DATA FORMAT RECORD ** LVP 010.H0? VEPlFICATIDN LISTING PACE 5 · YPE SIZE 2 1 4 8 4 9 4 16 1 0 1 DATUM SP~CIFTC~TION B60CK$ qN~M S~RVICE SERVICE tJNTT APl I0 OPDFR # L, nG SFLU ~P GR CALl DRHO ~R~T ~N~A ~PgI FD~ FC~L ~T L$S SGR LDT CALI LDT 9HOB LDT DRHO f,F)T gR~T ~g~A f,DT PE? LD gCNL LDT ~C~L LD qb$ [,DT OSS LDT AP! APl TYPE CL~S$ WT 00 000 00 nHM~ 00 220 0! OHmM 00 120 44 ~V O0 010 01 CAUl 00 310 O1 ~AmI O0 310 O1 TN OO ~80 01 ~/C3 O0 ]50 02 ~/C3 O0 ]56 O1 O0 420 O1 O0 000 O0 PU O0 89O O0 CPS O0 330 CPS O0 330 ]0 ~API O0 31o Ol USfF O0 52 0 ~0 US/? O0 520 80 GAPI O0 ]i o IN oO ~80 O1 ~/C3 00 350 02 ~/03 oo 356 O1 O0 42O 01 no 000 OO PU O0 890 O0 O0 ]58 O1 CPS O0 330 CPS o0 ]30 Oo 000 O0 oo 000 O0 REPR CODE 66 66 7] U5 66 66 IPI FIt, E ~OD NO, 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 DEPT' SP 9HOB gPHI 9T PHOB PHi 9EPT 705~ 5000 -19 22~7 4~ 4620 4805 -g99 2500 -099 9500 -999 2500 -ogq ~500 7000.0000 SFLU DRHO DTL SFI,U 1.1,610898 -00068 2043 6875 -999,~500 -990,~500 -999.~500 -O99.2500 ~.8401 OR NR.AT ~CN6 NRAT T sI 2 116 3 544 -~09g -999 -999 0 1 60 ,lin 1 0 REP COD 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 ~8 68 6B 68 68 68 68 68 6292 OBg8 12 O0 ,2500 ,2500 ~.4612 CALI ~NRA CR CALI RNRA PROCESS ¢OC~Ab) 000000000000~0 000000000000 0 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 0o000000000000 00000000000000 onooooo0000000 oooo0ooo0000~0 00o00oo00000 0 0ooooooo000o00 00o0000o000000 oooooooo000oO0 0ooooo00000000 ooo00n~O000000 O000on o000000 oO0OOOOO000000 000o0000000000 00000o00000000 00000000000000 O0000no0000000 8 5020 3 7542, .999 2500 -~9~ 2500 -~9 2500 -~99 ~500 2,4377 Ai~.ska Oil & Gas Cons, LVP 010.H02 VEPiFICATIDN LISTING PAGE 6 WP -27 47~7 ~N RHOB 2[~698 DRHO ~P~I 30.01~7 ~CNL DT 10~.~773 ntb ~HOB -990,2500 DRHO ~P~I -099.9500 DEF Ob.q -99g,~500 OSS 6900.n000 SFLU 72?7 CR ~46~2 DRWO 33.~543 ~CNb 9o~3 n~n -999:2500 DRHO -099,~500 PEW -999.~500 085 DEPT 6900.~000 SFLU SP -37,48~3 RgnB ~,40~4 DRNO MP~4I 40,5762 ~CNL QT 10~,40~3 DTL ~HNB -999.~500 QRMO MPgI -099,~500 PEF O,h~ -g99.2500 DEPT 6700 nO00 SFLU SP -37!0883 ~R ~HOB 2 3538 D~HO gP~{I 31, .591.8 NCNb DT 9~ . 7773 ~. fi., ~HOB -099.~500 DR~4O ~PgI -999,~500 uCF 01,8 '999. ~500 OSS DEUT 6600. ~HOB MPHI 40 DT 97 ~HOB -g9g gPS! -999 045 0000 SFLU 5195 ~R 47~9 DRgO 0879 NCNb 65~3 DTL ~500 nHgO 2500 PEF ~500 0S$ 29 88 -999 -999 0000 ~FLU Slg5 ~R 41~4 ~RHO ~340 NC,L 2773 ntb ~500 DRHO ~500 oE~ 7500 OSS 6400.0000 SFLU 119. O, 1940, 102 m -~99, -999, -ggg, 0 99, O. 2~97, 94, -g~g. -999 -99~ 3~ ~01.. 0 1819~ 10~. -999, -990, -999, 11 79 0 -999 -999 -999 .~I0: 0 9 , 99. -099. 0. 2891, 999, -999, -999, 49, O808 1553 6875 ?5OO ~500 2500 0007 2773 0288 5000 ~773 2500 ~500 2500 1213 0273 0532 6875 5273 ~500 2500 ~500 7508 9648 0059 5000 5273 ~500 ~500 2'5o0 6487 90~3 02~4 6875 1,5~3 2500 2500 ~500 9785 5898 n088 5000 523 .500 2500 2500 9805 ~R WRiT ~CMG MRaT SG~ NRaT IbM gR ~RI.T ~R NCML ~R NRA. T SGR ~R~T NCnb gR WCNL NCWL 110.0898 553 ]125 -999.2500 -090.~500 ].6~84 90.2 73 ~.9631 717 8125 -~99' ,~500 -999,~500 -999,~500 2.88~1 10!.02 3 3 4124 487 3906 -999 2500 -999 2500 -9gg 2500 9 9707 79:9648 2 93!9 671 3125 2soo 99 ~500 -~99 2500 2.7131 110.9023 3.4514 457 -999' .090 '~5 ,~500 -999,2500 9,2285 65.5898 947,8125 -990,2500 :990,7500 34.R242 CALI ~R CALl wCNL CALI RN~A ~R CALl RNRA CALl ~NRA ~R CALl CALI ~R ~NRA CALI RNRA CALI RN~A CALI ~NRA CALI RNRA FCNG 7 61~9 3 5081 106 7148 -g~g 2500 -999 2500 -999 2500 ~ 5745 8 6660 3 1g~5 105 4023 -999 2500 -999 2500 -999 ~500 2 828~ 9 181 3 7327 1,04 0273 -999 2500 -999 2500 -09q ~500 9 g ~994 ~ ~07 80 -099 ,~500 1,14 ~ 27 -099 25~0 -999 25 0 9 ~754 9 254 3 491 500 -999 ~500 -099 500 42.0742 LVP O10.H0~ VE~IWlCATION LIS?ING PA~E 7 NPNI 9T OT ~NOB SP OT DT RHOB DEPT 5P RHOB ~HOB NP~41 2 7695 GR '62:4377 DRHO 35.7910 NCNb 122.~773 -999.2500 DRH(] -999.9500 ~Em -099.~500 05S 6]00.0000 -45,5195 2.]752 42,0410 ~0~,7773 nTL -099,~500 ORRO :999 ~500 999:~500 OSS 6?0O 106 -999 -~99 -999 0000 SFLU 5195 CR ]948 DRMO 0664 NCNb 90~3 DTL ~500 DRanO 2500 PEW ?500 OSS 6100,0000 49,0195 ~R :gg9. 00 999.~00 ~C~b .105,15~3 DTL 999;~500 DR~O ~999.~500 DEW 999.2500 62ooioooo SFLU 6O 5195 -'99q ~500 -999 2500 NCNb ~29,31~5 DTL -999,2500 -999 ~500 ,.E~ -999.~500 OSS 5900 -64 -99g 'g9g 160 -g9g -ggg -090 0000 KFL(J ~695 GR 2500 DRHU ~500 ~CN5 5625 OTb ~500 DRgO ?500 mE~ ~500 OSS 5~00.O000 gFLU 66.0273 -0.0015 1946.6875 59.0117 -o99.7500 :,go. soo ~.~978 135.3125 0.0034 1710.6875 109.7773 -999.~500 -~99.~500 - 99.2soo ],4084 ~26 7148 0 0098 1774 6875 106 0273 -099 2500 -999 ~500 -999,~500 ?11 1875 -999 2500 -999 2500 105 5273 -999 ~500 -999 ~500 -999 3 9592 188 31~5 -9gg ~500 -999 ~500 ~20 81~5 -999 ~500 -999 2500 -999 ~500 ,5320 13 .,-'1875 -099,2500 -999,~500 316.1.406 -999,2500 -o99.~500 -999.2500 NRAT FC~L ~R aT SGR ILM MR~T ~CNL MR~T ~C~L ~R ~R~T FCNL ~R~T ~CNb ~R NR~T FCML S:G~ ~RAT ~CNL MRAT FCNL ~RAT ~CNL 66 0273 ai 7o 582.]125 -999.2500 -999.7500 -999.~500 2,6252 135.3125 447.6406 -o90,2500 -999.~500 -099,2500 ~.9788 126,7148 3.6409 431 6406 . '999,~500 '999.~500 '999,2500 1.6749 '999.2500 '999 2500 -090,~500 Z999. soo 999.~500 -99 ~967 -99 .~500 ~500 -999,2500 -99~,~500 -999,~500 '999, 500 05m5 : 5oo '999~500 '999'~500 ~999~7500 '999~500 -990,~500 ~.]069 RNRA CAt. I RNRA IUD CALl RN~A ~R CALI CALI RNRA CALI PNRA mCNb CAbI RN~A ~R CALI ~NRA ILO CALI ~R CALX RNRA CALI RNRA CALl RNRA TLD 9 9785 3:3420 71o~773 -999. 500 -999,7500 -999,~500 2,6057 9.9863 3 8206 143 ~875 -999 2500 -999 2500 -999 ~500 ~ 8499 0~910 14,1101 140 1875 -999!2500 -q9O ~500 -999 2500 1.~225 '999, 500 '999,2500 257,3906 '999' 500 -999,~500 '999,7500 ~.'~600 -999'2500 217,31~5 'g99.2500 "999,~500 -999,2500. 99,2500 ~29.4375: 999,.~500 999,~500 "999:,.~500 3,2092 Aiaska 0il & Gas Cons. Co LVP 010.~02 VERIFICATION LISTING PAGE 8 ~PHI MPHI DEPT SP OT WP~I OEPT DT DEmT NPWI DT PHOB gPHI DEPT ~PMI SP RH00 ~T wpwI OEnT -56.0195 GR -999.~500 DRNO -999 ~500 MCML 100~152] DTt, -999.9500 DRWO -999.~500 PEF -~99.25~0 OSS 5700.0000 SFLU -57.0508 GR -999.2500 -~99.7500 10~.K273 nTL -999.2500 DR~O -999 ~500 DEF -999~9500 5~00.0000 SFLU 69.0107 -999.9500 -099 ~500 NCNb 94i~77~ -,99 2500 299¢ ~5o0 999:~500 5 , 0~, . -090 -~99 ~00 -.99~ -999 -999 0000 7695 OR ?500 DRHO 2500 2773 nTt ?500 ~RHO 2500 ~E? ~500 qSS 5400, -56 '999 -99~ 99 -999 -999 -999 5 GR 2500 ORHO 2500 ~!CNL ~77~ DTL ?500 DRHO 2500 ~E~ P500 OSS 5300 -999 -999 -999 -999 -999 00 SFLU 95 ~R 2500 DRHO ~00 NCnb '73 DTL 2500 2500 ?500 OSS 5?00.0000 SFLU 124 -g9g -999 99 99 -99~ 5 94 -~99 -99~ -999 -999 -999 78 -999 -999 94 -999 ',999 -999 4 1,10 -999 -999 100 -999 -~99 -999 3 ~,06 -999 -999 100 -999 -'999 -999 1 148 -.999 -999 119 -999 -999 -999 1523 i2500 2500 .7773 .2500 .2500 ,2500 8210 ~7773 .2500 .2500 5273 . .2500 .2500 .7500 .6206 6523 2500 ~500 7773 2500 2500 2500 84 2500 500 773 ?500 2500 2500 26O 023 5O0 ~500 2773 ~500 2500 2500 931.7 8125 2500 ~5~0 5~ 3 2500 2500 ~500 4.0554 GR MRAT rCN6 NRAT IbM GR NRAT FCNL WRiT ~CNh NR&T ~CN6 ~RAT ~R a!RaT FCN6 MR~T ~CWL IbM GR MRAT FCN6 WRAT ~CN6 GR FCMb SGR MR~T ~C~6 -qgq.2500 -999.9500 -999 2500 -999~2500 -999 2500 - :2soo 4.5007 -999.2500 -999.2500 -099.2500 -999.~500 -999.2500 -999.~500 5.2625 -~99.2500 -999.2500 -999.~500 -999 ~500 -999:~500 -999.2500 4.~.179 999.2500 9 .2500 -999 2500 -.999:~500 -~99,2500 3.4905 ~999,~500 999.~500 -~99 ~500 -999!~500 -99o ~500 -999. 500 ! g063 -9 9 500 -g 0 -995 5500 O0 -999 ,~500 -999 2500 3.2698 CALl GR CALX RNRA TbD CAb! RNRA eR CALl RNRA FCN6 CALI RNRA ~R CAbI rCN6 CALI RNRA CALI RNRA FcN6 IbD CALI RNRA gR CALI ~NRA ?CN6 CAbI RNRA GR C~LI RNRA rc~6 ~6D soo -~99 2500 ~20 7~48 -999 2500 -999 2500 -999 ~500 4 4539 -999 2500 -999 ~500 110 398 -999 2500 -999 ~500 -999 2500 4 8796 -999 2500 -999 2500 93 9648 ~999 2500 -999 2500 -999 ~500 -999 25 -999 ~500 ~18 773 -999 ~500 -999 500 -999 2500 3 3967 -999 2500 -999 9500 104 48 -999 500 -999 ~500 ! 8428 :999 2500 - O0 -099 O0 3.1897 bVD Oln. H02 VERIFICA?iON bIS?ING PAGE 9 SP -51.7695 GR 9HOB -999.~500 DRHO gPgI -999.25n0 ~ICgh OT !06.5273 DTL ~i. tOB -999.~500 DR~O NPgI -999.~500 PEw OL~ -099.9500 OSS DEPT 5~00.~000 SFLU SP 6].0195 OR RHOB -999,~500 ~P~I -999.~500 ~C~L DT 105.n273 ~OB -999.~500 NPgI -999.~500 PEW Ob$ -999.2500 OEPT 5000. SP -69 NpHI 47 DT 108 ~HOB -099 ~PHI -999 qbg -o90 0000 ~607 3899 DRHO 3145 9773 DTL ~500 ~500 ~500 D~OT 4900 SP -64 ~PHI 51 DT 116 ~HOB -999 OL$ -999 no00 SFt.,U 5105 GR 3206 DRHO 0254 NCNb 9023 OTL ~500 ~R~[) ~500 PE~ 2500 OSS DE~T 4800 ~P -67 ~P~I 39 DT 1.14 WHOB -999 NP~I -999 OL$ -99~. 0000 8FLU 7695 3752 DRHO 843'7 9500 ~R~O ~500 PEr ~500 120. -990. -999. {06 . '99q, -999. -090. i 129. -q99. -999. 104. -999. ~999. 999. m 14~. 0 1630: 107. -099 -999~ -999. 1 1,51 0 1~77 -99 -999 -999 m 177. O, 183~. .!,14. 999, '999. '999. r)E,'"P".l 4700,0000 .~FLU 1 SP -68'4951 .C,R 1.,25: ~Hn~ ~,.30,8 ~RHC') 0 2 . F 1.09, 273 DTL I R ~HOB -99:9, ~500 OR~O -999 NP~I -999, ~500 PEF -999 OLS -999. ~500 OSS -999 4600.0000 9648 ~500 2500 7773 2500 2500 2500 7542 81~5 2'500 ?500 7773 2500 2500 ~500 1140 4375 0308 6875 7773 2500 ~500 2500 8419 6875 0264 6875 5273 ~500 25no 2500 3850 0:21,5 6875 5273 ~500 25OO 2500 6104 ]398 0049 6875 7773 2500 ~500 2500 5432 NRAT NRaT NRIT uCUL ~R NR~T wCNL ~RAT mCNL NCNL GR WCNL NR~.T ~CN~ ~R NR~T FCgb NRIT ~!CNL ~999.~500 099.2500 90.2500 099.2500 :999.~500 3.8479 -999.9500 -999 ~500 -~99 ~500 -099 2500 -999 2500 -999 2500 4.1609 5 407,6406 -999.~500 -~99.2500 -99~.~500 1,,6260 1.51.6875 4 02.81 386 1.486 -999 ~5 0 -999 ~500 -999 ~500 ~ 3245 I'7'7i~1253 26 474,3~06 5O0 '999',~5 -999, 00 '999.2500 1.5128 414 06 -999 ~4 5OO -999, ~500 -999 500 2.,2932 CALl mNRA CALl ~NRA TLD CALl ~NRA RNRA rCML CALI RNRA GR CALl RNRA ILO CALl GR C,aLI ~NRA CALl ~N~A ~R CALI ~N~A FCNb RNRA ~R CALl FCNL ThD -999,2500 -999,2500 130.0675 -999,2500 -999,2500 -999,~500 3 7405 -999 2500 -999 ?500 146 625 -999 ~500 -999 9 12 4 00O7 143 4375 -999 2500 -999 2500 -999 ~500 1 2969 9 ~ ~9 4 ~98 -999 2500 -999 ~500 2 4 185 716' 25 1 90 isoo 999 500 -999 ,500 ! 4493 143 4375 -999 O0 -999 .~ 00 2.2502 LVP OIO.H0~ VERIFICATION LISTING PAGE 10 SP -74,2607 ~HOB 9.3167 DRHO 0 NPHI 45.5566 WCML 1841 ~T 111,7773 R~OB -q99o~500 OhS -999.~560 085 -g~g SP gPHI RHOB NPHI DE~T SP DT ~HOB 4500.0000 SFt, U -75.6826 2.2424 4~.0957 11~.7773 ~TL -999.2500 ~R~O -~99,7500 -~99'~500 QSS 4~00i0000 SFt. U '77 2451 ~R 2 3362 ~RHO 38.~254 NCnb 10!.9023 DTL -99~,~5o0 DRNO -999,2500 ~EF -990.~500 OSS 101 0 1823 111 -g99 -999 -999 2 777. 10~. 090. -999. -099. ~9~,4951 GR 83 _ ~500 DRNO -999 ~PHI ~99:2500 NCNb -999 OT 106 65~3 ~Tt., 10~ RHOB -qgg 2'500 DRHO -999 MPHI -999 2500 PEF -99~ QLM -999 ~500 QSS -999 RHOB MPMI NPMI 420O -80 -999 -999 999 -999 0000 SFLU 2451 2500 ~500 NCNb ..,093 DTb 500 ..50.0 .9500 -999 -999 l. ln -999 -999 -990 00o0 0107 ?500 DRHO ?500 NCnb 6523 OTb 2500 ORHO 2500 4000. 0000 SFLU DEPT $P RHOB ~T ~P~I 2 108 -99~ -999 ~07 -999 -999 -990 2 ~26 -999 -999 -999 -999 1 .5625 .04~0 .6875 .7773 2500 2500 25O0 .0100 .7148 0811 6875 7773 2500 2500 ~500 2034 4023 0869 6875 273 500 2500 2500 ~389 9648 2500 2500 7773 2500 500 5O0 3928 9648 2500 ~500 027] 2500 2500 2500 7608 9023 2500 2500 0273 2500 2500 2500 3367 FCNL .CWL NRAT FCNL NRAT IbM ~R NRAT FCNb NRAT IbM GR MRAT rcMb NR~T NCNb ~R NR~T FCNb NRRT NCNb ~R MRAT rC~L WRAT ~47 5625 448.140U -999 2500 -99912500 -99n.~500 2,~042 101. 148 3.8186 462.1406 -099.2500 -999.2500 -999,2500 2 1409 80!4023 3 3049 525 3125 '999i~500 -999 500 -999 500 2 1526 -999 ~ -09g 2500 '690 2500 :999 2500 09~ 2500 2,53~3 -999.2500 '999,2580 '999,25 0 '999"2500 '999,2500 -999.2500 2 8577 -099 250:0 -099 2500 -999 2500 -999 2500 -999 2500 -999 2500 4.2625 CA[,I CALI RNRA mCNL IbD CALI RNRA GR CALl DNRA FCNL CAbI GR CALI mNRA CALI RN~A eR CALl RNRA FCNL ILD CALl mNRA CALI C A L I RNRA CAI.,I RNRA FCNL TbD 9 4941 4 ilO1 155 6875 -999 2500 -999 2500 -999 2500 ! 96t0 9 70 llO 1523 -999 500 -999 ~500 -q99 2500 ~ 1526 285 3 3831 78 2148 -999 2500 -999 ~00 -~gg O0 2 1487 -999 2500 -999 25O0 89 ~398 -099 500 -990 2500 -099 ~500 5413 -9~ 2500 -9 ~ 2500 I~ 6523 -9 9 2500 -999 ~500 -999 ~500 2 ~538 -999 :500 -999 500 130 625 -999 500 -999 500 -999 500 4.2000 LVP OlO,HO~ VEPIFICATION LISTING PA~E SP -83.2451 ~R RHO% -999.~500 nRHO ~PHI -999.~500 NCNb OT 99 6523 DTb gPgI -g99.2500 PEF OL$ -999.~500 OSg OEPT 3900.0000 SFI.,U SP -79.9607 GR ~MOB -~9~,7500 ~PHI -999.2500 ~CN~ OT 110.6523 DTL RHOB -999.2500 go~I 099 2500 PEr OgmT 3800.0000 5P -85.5059 R~nB -999.2500 ~PHI -999 5500 DT [16i777~ ~HOB -090 ~500 gPNI -99~ ~500 Obg '999,2500 DBPT 3700. SP RHOB -999. ~PHI -999 DT 114 RHOB -999 ~P~I -099 OhS -990 0000 SFLU 7793 GR 2500 DRgO ?500 ~CN5 0273 DTL ~500 PEW ~500 0S$ DEPT 3600 ~HOB -999 gPNI -~9~ mT 114 ~HOB ~PMI -ggg 0000 SFLU 5215 ~500 DR~O ~500 5273 DT5 ~500 ~500 PEF ~500 OS~ OEPT 3~00 SP -83 ~HOB -999 ~PHI -999 9T 121 ~H00 -099 ~P~I -999 9L8 -999 nO00 gF!.U ~607 ~R ~500 DRHO ~500 8CN5 0273 DTL 2500 DR~O ~500 ~E~ ~500 OSS 3400.0000 SFt. U ~0~.9648 -999°2500 -999 ~500 90~273 -o9o.2500 -999.~500 -999.2500 2.4749 I04.2773 999 ~500 2 99i 5oo lit 5273 -999.2500 -999 2500 -99 : 5oo 3.1741 119.0273 -999.2500 -~99 5500 -999.?500 -999.~S00 -999.~500 105, -999 -999 11,4 -.999 -999 -999 97 -999 -099 -999 -999 94 -999 -999 121 -999 -999 -999 0164 15~3 ~500 ~500 0273 ~500 2500 ~500 6506 ~773 ~500 ~500 2773 ~500 ~500 2500 5354 4648 ~500 ~500 7773 ~5o0 2500 ~500 3772 ~R ~R~T NR~T ~R NRaT FCNL SGR ~;R~T NC~L GR NR~T ~RAT NC.L ~R NRAT NR~T NRAT NR~T ~CNL GR NR~T ~CNL SG~ NRAT ~C~L -999 2500 -999~500 -999 2500 -999~500 -999,~500 2.5510 -999.2500 -999,2500 -999.2500 -099.2500 -~99.~500 -~99.2500 3.0940 -999 2500 -999 ~500 -999 ?500 -999 2500 -999 ~500 -999 ~500 99!9006 .g ~500 -99~ ~500 -999 ~500 -999 500 -999 ~500 2 8342 -999 O0 -999 -999 ~500 -999 2500 '999. O0 -999 ~500 -999 500 -999:~500 -999 500 3.4612 CALX ~N~A CALI ~NRA rCNb RN~A GR CALI CALl RN~A GR ~NRA FCNb · bi RNRA ~R CALl RNRA rCNb CAb! ~R CALI ILO CAb][ mNRA ~R CAbI FCNb -999,~500 -999. 500 105 1523 -999 2500 -999 2500 -999 ~500 2 5667 -999 -099 500 115 65~3 -999 ~500 -999 2500 -o99 2500 3 1252 -999 2500 -999 2500 12~ 65~3 -99 2500 -999 ~500 -999 ~500 3 ~202 -999 500 -99~ 2500 11 3398 -999 ~500 -999 500 -099 ~500 2 8948 -ggg ~500 -999 500 9 ~773 -999 500 -999 O0 g5909 -99 2500 -999 gSO0 -999 ~ -~99 500 -999 ~500 3,3811 bVm 010.H02 VERIFICATION LISTING PA~E 12 SP -84.99~0 ~R 91 ~HO~ -999, 7500 ORMO -999 MPwI -990~500 ~CNL -990 OT 120i0273 OTb 120 ~hOB -090 ?500 ~R~O -999 ~PNI -9992500 mEm -999 OLS -999 ~500 OSK -999 BT 11 .2773 HOB -999. 500 OReO OEPT 3200 SP -87 ~HOB -999 ~PHI -990 QT. 120 qHOB 999 ~I..,$ -q9O 0000 ~FI, U 5059 GR ~500 ~500 NCNb 0273 .7500 DRMO .2500 .~500 OSS OEPT 3100 RHOB -99~ NPHI -99, ~T 12¢ ~HOB -999 NPM1 QLg -999 0000 SFLb 0071 GR ~00 DR.O . O0 MCNb 2500 DRHD ~500 DEF ~500 OSS DEPT 3000 $p -34 RHOB -~99 wPNI -o99 OT 1,23 mHOB ~ ~PHI 48 o000 SFI,U 0883 ~R 2500 DRUO 5n0 wCWB 273 OTb ~002 DRUO 1445 PEF nO~4 OSS OEPT 2900 8'P -37 RHOB -999 UPHI -999 DT 125 ~PHI 54 OLS o :~000 SFLU 883 .2500 OR~;O 1,877 .6875 PEm .001,5 BE..T 2800.0000 SFLU 3 92 990 ;999 117 -999 -999 -999 3 1,01 -990 -099 119 -999 -999 -999 4 83 -99~ -999 -999 -999 -~99 7 81 '999 -999 123 o 2 4 77 -999 -990 124 -0 -0 4648 ~2500 2500 2773 2500 2500 2500 o1057 .6523 .2500 .2500 .5273 .2500 2500 :2500 .9319 .1523 .2500 2500 2773 2500 2500 2500 71 ~500 2500 0273 ~500 2500 2500 .3640 ~148 500 2500 0273 !079 t9 9070 7773 2500 2500 2773 0073 8147 0039 .7585 ~R FCNL NR~T NCNB NR~T NR~T ~CNB GR NR~T FCNL NR~T NC~)L NRAI mCNL MRAT GR NRAT NRAT wC~b -999.2500 -990.2500 -9992500 -999' .2500 -999.2500 -999.2500 3.3713 -~99.2500 -999.2500 =999.2500 -999.2500 -999.2500 -999.2500 4.0164 -999.2500 -999.2500 -~9Q ~500 -999.~500 -999.~500 43757 -999 2500 -9992500 99 250O -999 ~500 -~99 2500 5 6804 -999 2500 -999 ~ 50O -999 500 lO1 3398 3 9709 1606 6875 -999 0 -999 2500 -999 ~500 799648 4 ~60 1531 6871 5.4695 CAb! CALX ~N~A FCNB CALl WNRA ~R CALl RNRA FCNB ILO CALl RNRA ~R CALl FCNL CAb l mNRA GR CAI, I RNRA FCt,'B IbD CALI ~R CALl RNRA FCNB CALI CALl RNRA FCNB ILO -999. o -999.~5'0500 .~05. 525 999,1500 -999.2500 -999.2500 3 5315 -999 2500 103 71 -999 2500 -~99 2500 -999 ~500 4 1570 -999 2500 -9992500 108 0898 -999 2500 -999 2500 -999 2500 4 7000 -990 2500 -099 2500 93 7148 -999 2500 -0992500 -~992500 5 8523 -9 2500 81 2148 1i 4395 383 ~843 906 -g9~ ~960 · 500 -999 ~500 4968 340 3906 5.6218 i~ '"'C .F '- oil c. 7 LVP OIO.HO~ VERIFICATION LISTING PAGE 13 ~P NPHI DT qHOB ~PHI SP RHOB MP~I 9T qH~B NPNI ~HOB NPHI ~P~I 9T ~PHI OhS DEPT SP ~HOB ~PHI DT NPHI E~T ~HOB NPHI DT RHOB NPHI DSPT -43 -~99 -999 ~2~ 5O 9883 OR ?5nO ~C"L 9773 ~092 9930 0132 OSS 2700 -51 -999 -999 125 50 0 0000 SFLU ~9883 .~500 DRHD ~500 NCNL 7773 DTL 1936 DRgO ~441 00~0 OSS 00 0000 SFbU 999.2500 DRHO -999 ~500 ~C~!G 126i2773 DTL 9 ~975 47 7051 DEF -0.0273 2500 -49 -999 -999 2 5O -0 0000 ~FLU 48~3 GR ~500 DRHO 2500 NC~'b 3125 ntt 1702 DRHO ~44 DEF 007~ OSS 2400 -54 -999 -999 130 48 -0 0000 4883 0469 DEF 00~5 2309 -65 -~99 -999 46 -0 O000 ~FLU 7~7 GR ~.,500 DRHO 1 4 DEF 0186 OSS 2200.0000 SFLU 58 '-999 -999 118 0 7 67 -999 -999 129 0 0 57 -999 -999 127 0 0 68 -999 -099 0 0 12 59 -999 -999 417 0 42 -999 -999' 138, 0. 0, 33. .3867 .2500 .~500 .5273 0049 .0161 .9968 .3398 .~500 2500 56?5 0024 7795 0094 72~6 4492 ~500 ~500 0273 0044 8694 ,0151 4004 7148 2500 2500 5625 0000 5879 7305 2500 9500 8906 OOO5 4436 01~7 0430 3555 500 ~500 ~1~5 0122 ?659 ~305 ~R NRaT FCNL NR~T NCNb IbM ~R NRaT FC~L SG~ NR~T NCNL nR NR~T "R~T ~CNL TL~ ~R NR~T FCNL NR~T ~CNL IL~ ~R NR~T FCNL NR~T NCNb GR NRAT FCNL SGR MR~T NCNb IbM -099 2500 -999 2500 -999 2500 59 2617 4 1179 1310 6875 6 77O3 -999 2500 -999 ~500 -999 2500 73 4648 4 1101 1415 6875 12 6426 -999 2500 -999 2500 -999 2500 62 3242 3' 8 g 60 -999 ~100 - gg -og 2500 6R 6523 4 141K.6875 9 0645 -999 2500 -99 nO 56 0 1,7 9~05 2~,I. 299 -99 .2500 -999.9500 -999 2500 56~4805 1573.6875 17.301.8 CALl RNRA CALI ~NRA lED CALl RNRA ~R CALf RNRA FCND CALX RNRA ~R CALI RNRA FCNb I LD CALX CALI ~CNL CAb! RNRA ~R CALl RNRA rCNL I L,D CALX R N R A ~R CAL i DCNL -999 2500 -999 2500 58 3867 12 5566 4 1531 315 ]906 187 6'~50 -999, 0 '999,2500 67,N398 4, 945 345,6406 14 1270 -999 2500 -999 2500 57 4492 12 5566 3 $909 385 3906 9 4551 -999 2500 -999 2500 68 14'8 12 ]848 4 0945 345.6406' , 9.4238 -999.2500 -999.2500 59~7305 12.4473 3'9534 344,8906 .022.i455 .... 99.2500 999,2500 50.3555 13.283 4'000~ 393.3906 17,1611 LVP 0lO.g02 VERIFICATION bTS~ING PAGE -64.9727 GR 51 -999.25n0 DRRO -999 -999.~500 ~IC~G -999 138.56~5 DTL 138 2.1467 %RgO -0 5~.0020 DEF 2 O.nO1.5 035 -0 ~6~0 .~500 .0625 0078 ~56~6 .0098 RH~6 -999.2500 ~RNO -~99. NPHI -999.~0 ~IC~!L -999. DT 1.6~.56~5 DT! 164 R.HOB 1 ~506 Dado o~ ~PHI 5~:5879 mEC 3. OhS -0.0405 OSS O. 0000 SFLU 97~7 ~R 47~ ~500 DRHO -q99 ~500 ~CNL -999 56~5 DTt., 9952 ~R~O 1953 PEF 0049 OS$ -0. DEPT 2000 SP -67 RHOB -q99 gPHI -999 D? 148 ~HOB 1 NPRI 50 0000 SFI..,U g. 9883 GR 74. ~500 DaaO 999 2500 NC~L ~999 ~ 0625 ~TL 156 0217 OReO 0 DEOT 1900 SP -59 gHOB -999 NPHI -999 OT ~57 0000 ~FLU 14 98~3 GR 60 2500 DR~O -999 041.3 DRNO O, 9082 0269 058 O, gEPT 1800. SP -61 %HOB -999 gPHI -999 nT 158 ~P~I 55 OhS -0, 0000 SF~,U 80 4883 qR 41, 2500 DR~O -999 2500 NCnb -999 56~5 DTL ~,44 9766 Dali) 0 5645 PEW ~ 0371 0S8 0 DEOT 1!0~ SP 6 R.HOB '99 ~P~I -99~ DT 135 ~HOB 1 ~P~I 53 OL8 -0 1600.0000 SFLU 78. 9805 ~617 2500 2500 06?5 0947 0784 0586 4492 2500 2500 5625 0063 8206 0029 8457 0273 2500 2.500 06~5 0063 143 ~151 8301 8398 ~500 2500 ~175 0132 1194 0308 '73 2500 3125 0669 87t3 0439 4648 GR SGW ~R NRAT NRAT ~wCNL NR:~T FC~b NRtT ~C~L FCN5 SG~ ~C~b ~R ~R~T FCNL NRAT TGM ~R NRAT ~R~T -o99.~500 -999. 500 -999.2500 56.9805 ~.~078 1529.6875 20.1143 -999,~500 -999,2500 -999 2500 3717930 4.3601 1~0~.6875 16.9111 .99.~500 -999.~500 5~.1992 4.1218 1337.6875 7 7820 - 9922soo 76,902.3 ~,37~6 1372.6875 9,i. 504 -999,~500 -999,~500 -999 ~500 6~ 023 4 4226 12696875 35 6367 -999 2500 -999 2500 -999 ~ O0 46 ~67 4 ~ 93 1.249 ~75 37.4492 CALl ~N~A ~R CAI, I FCNb CALI CALI RNRA CALl RN~A CALl RNRA ALI RNRA RNRA CALl RNRA GR CALI RN~A lb0 CALI RNRA CALl RNRA FCNG .T, bD -999 2500 -099 2500 51 16gO 12 4082 4 3250 353 64O6 22.23~3 :99 ., soo 999,250O 38.2617 17 0361 5:0906 ~75,8906 16.2236 99 ~500 47:~680 12, 770 4,8484 8 ~676 -999 500 -099 ~500 74 0 301 ~51,5906 0 -999 2500 69 8398 1 ~ 4941 6062 ~75 6406 50 8555 -9992500 -999 2500 4t ~242 13 254 4 7390 263,6406 40.5742 tVP 01O,HO~ VEPIFICA$ION L~$TING PAGE 15 SP .54.4893 GR NPHI -999.~500 MC~L DT- 20,2549 DTL ~P~Z 53:0273 p~ ~[,$ -0,n186 085 ospT 1~oo oooo sf~o sP -47:4~3 ~ ~PNI -999.~500 ~CNG ~T -22~ 9373 ntb .HOB -999:~500 DE.O "P~I -g99.~500 PEF DEPT 1400 SP -67: ~HOB -999 NPHI -099 DT 11~ ~HOB -q99 ~PHI -999 0000 SFI, U 47~7 ~500 2500 ~C~L 0273 2500 2500 PEP ?500 SP 59, RHOB g99. ~PHI -999 ~T 81 RHOB -ggg ~PHI -099 48~3 ~500 2500 ~C~L 7773 ~T[., ~500 ~R~O 2500 ~500 DEnT 1~00 SP -7& ~HOB -999 ~P"I -g9g DT 124 ~HOB -999 NPHI -999 ~500 Dr~O 2500 NCNb 0273 ~500 DR~O ~500 PEF DEPT 1J. O0 SP -70 RHOB -999 NPHI -999 DT 50 ~HOB '999 flPHI -999 ~L~ -999 0000 SFI,U 97~7 2500 DRHO 500 NC~L ~617 2500 OReO 2500 ~500 DE.T 1000 0000 ,, 4q -999 o .4492 .2500 .~500 .7549 .0107 .4709 .0098 23. 81. -999. -999. 19. -999. -999. -999. 39. 57. -999 -999 -999 -999 -999 ~57 46 -999 -999 8O -99q -999 -999 62 61 -999 -990 124 -990 368 38 -999 -999 65 -999 -999 -999 179. 5205 1523 ~500 2500 5049 2500 25o0 ~500 4805 2500 ~500 5273 2500 ~500 2500 3906 7305 ~500 500 2500 ~500 ~500 7930 511,7 2500 2500 5273 2500 ,2500 9500 1406 5742 2500 ~500 773 ~500 ~500 2500 9375 NRAT ~RaT ~CNL Ibm ~R NRiT SGm MRIT ~C~h GR FCNL SGR NR~T Ibm ~R ~RAT FC~L NRAT ~C~'L ~R NRAT FCNL ~R!T NC~L Ibm ~R FCNL SG~ NRAT ~C~L -999 2500 · -99 60;7305 4.~625 1697.6875 17.59n6 -999.2500 -999.2500 -999.2500 i999.~500 999.2500 q99.~500 25.8955 -999 ~500 -999!~500 -999 2500 -999 ~500 -999~500 '999 ~500 95.4648 '999.~500 =999.2500 '999.2500 '999.2500 '999,2500 '999.~500 co -999 5oo -999 ~500 -999,~500 ~999 2500 -~99 ~500 "9 . 500 -999.~500 -ggg -9 9: sOO -999 ~500 -999~2500 60.0117 CALl RNRA CALI FCNL CALI ~N~A ~R CALI FCNL CAt, I RNRA GR CALl ~NRA ~CNh IhD CALl DNRA GR CALl RNRA CALI RNRA AL I ~NRA ~'CNI~ C A b I t~N~A ~R CALI RNRA FCNh ~500 49 44q2 4,42~6 383,8906 ,5205-g .2500 -999,~500 81.1523 -999,~500 -999, 500 -999.2500 .9~2.TM ....9,~500 999.2500 .'57.4805 999,2500 ~999,~500 999,~500 674 3125 -999 2500 -999 2500 46 ~305 -999 500 -999 2500 -999 ~500 29,3330 109i.~500 99 ~500 9~ ,5117 .'2500 999,2500 999,~500 1 ~ 8398 -ggg 1500 -990 560 76.7148 r,VP 010.HO? VEPIWlCAVION bTSTING PAGE 16 5P .46.4883 OR DHOB -999°9500 ~IPH1 -~99,~500 NCNb ~T. 95 o273 ~T~, ~H08 q9q:?5~0 ~RHO SP, '46, qHO~ -~99.2500 DR~O ~P~I -999.~500 NCNb 9T 17.~,4~4 9T~., ~HC1B -~99.2500 DRHO NPHI -999 ~500 PEW OL$ -999'~500 Q$S · DEPT 800.0000 ~FbU SP -109.9777 ~R PHOB -999.2500 DRHO MP~I -999.~500 NCNb ~T. 83.5273 Dlb RHOB -99~.~500 DRHO QLS -~99.~500 Q$S OEPT 700 SP -7~ 9HOB -~90 ~PHI -999 OT 89 RHOB -999 ~PHI -999 OOOO 4727 GR 9500 OReO ~500 7773 DTT, ~500 ~RHO ~500 ~E~ 2500 DEPT 600 Bp -101 ~HOB -999 NPWI -~99 RHOB -99e NPWI -999 OhS -999 000 9'7~ ~500 DRMO 2500 ~C~b 7773 DTL 2500 ~500 2500 OSS DEDT KO0 sP -io RHOB "999 OT ~H00 -q99 ~PMI -~99 0000 SFI~U 97~7 ?500 9500 NCNb ~500 DRHO ~500 PEr ?500 400.0000 , ~[,U -999 -999 94 -999 -999 -999 268 48 -999 -999 14 -999 -999 -999 346 38 -999 -q9g 8~ -999 -999 -999 44 -999 -999 91 -999 -999 -999 59 59 -999 -999 96 -999 '999 -999 7 -~99 -999 135 ''qgq -999 -999 .5117 .~LAO .~5~0 .7773 .~500 .9500 .~5no 89~6 :4.180 .2500 .2500 .5645 .2500 .9500 .~500 .8906 .3242 .25no .2500 .0273 ,~5nO .~500 .~500 .6875 .5430 2500 500 273 ~500 ~500 ~:500 6680 6055 ~500 5273 ~5o0 ~500 ~500 ,0359 ,7148 ~500 ~500 1.25 500 500 ~500 5.17~6 NCNb TL~ ~R NRAT FCNb MR~T IbM ~R ~R~T FCNL ~YRAT ~CNb ~R NRAT FCNL SGR NR,AT NCNb NRAT eCNL NRAT IbM ~R NRAT FCNL NR~T NCNb -990.2500 -999.25n0 -99a.2500 -999.2500 -999.~500 -999.~500 -999.2500 =999.2500 -999.2500 :999,~500 99~.2500 -999.2500 1.98.4375 -999.~500 -999.~500 -999 2500 -999}.~500 -999 2500 -999 ~500 98 48 -999 2 O0 -999 ~500 -999:~500 -999 500 -999. 500 -9gq '500 -999 ~500 4,44~1 -999.2500 =999.2500 -999,~500 -999.2500 -999.,~500 -999.~500 5.8250 CAI, I RNRA ~R CALI ~I~A FCNL CAb! ~R CAI, I RNRA ~CNb CALl RNRA ~R I6D CAbI RNRA CALI RNRA ?CN6 TED ~NRA GR RNRA FCNL CALI RNRA ~R CAbI RNRA FCNL -999 2500 -999 ?500 5~ 5117 -999 2500 -999 2500 -999 ~500 167.6875 -999.~500 -999.~500 48.~180 -999..5n0 -999.~500 -999.~500 000 6875 999:~500 999.2500 .~38,3242 ,99.2500 -999.~500 -999.~500 ~2i..~625 "999. ~00 -999 ~ 00 44 -999 ~.500-999-999 ~500 -999 O0 -999 O0 59 6055 -~99 ~500 -999 500 -999 ~500 5 5750 68 71, -999 2500 -999 -999 ~500 7,7742 LVP 010.HO~ VERIFICATION LISTING PAGE 17 SP -119.q727 GR RHOB -999.~500 BRiO qPMI -990.~500 MCNIJ o'r 116.0273 DTL ~Og -990.9500 DRnO MPNI -999.~500 PEF 3oo oo o DP -126:¢727 ~P~l -o99,2500 ~CNL BT 108.2773 BT[. RHOB -999.~500 ~P~I -09°.?500 DEF DEPT 200.0000 SFLU 5P -111.47~7 GR RHOB -999 ~500 DRHO gp~'[ -999:~500 NCNb BT ~1~.7775 DTL %{P~{I -999.~500 OhS -999.~500 DEPT 100 ~HOB -999 ~P~I -999 DT 5~ ~OB -99 0000 SFLU ~,375 GR 2500 nRHO ~500 NCNb o117 DTL ~500 DR~O ~500 PE~ ~500 OLD 9EPT 91 DP -161 RHOB -999 gPHI -o99 DT 55 ~PHI -999 0000 9375 67 ~500 DRHO ~500 PEF ~500 OSS ** FILE TRAILE~ FILE N~F :EOIT DATE ~AXIMU~ LENGTH : wILE TYP~ gEXT FIL~ ~AUE : .001 1024 65.4023 -99q.~500 -999.~500 113.5273 -999.~500 -990.2500 -999.2500 9.8379 4].]555 -999.2500 -990.2500 106.~773 -990.~500 -999,~500 -999.~500 47.~867 6].6055 -999.~500 -999 ~500 -999 ~500 -999!~500 ~999 ~500 20 '999 '990 '999 '999 '099 '99. '099 55 -999 -990 -990 129 893 2500 2500 0273 2500 25n0 2500 7080 1924 2500 2500 {.367 ~500 2500 :2500 CR ~R~T ~CNL GR ~RAT FCNL SGR ~RmT NRAT NRA. T NCNb ~R NRAT NR.~T NCNL ~RAT FCNL :999 ~500 CALI 99~ 500 WN~A -999.2500 ~R '999,2500 CALl -999 2500 ~NRA -999:2500',, FCNh 8.5957 -999.~500' CALX -999.~500 RNRA -999,~500 GR -999.2500,CALI -099.2500 -099,2500 FCNL -999 2500 C, ALI -999 ~500 RNRA -999 ~500 GR -999 2500 C~LX -990,2500 P RA -999,~500 FC'N~ 2000 -999 -099 -999 -999 -990 -q99 6875 IhB soo ca z 2500 ~NR'A ~500 ~R ~ ~500 FCNL 2000 6875 -999 1500 -999 ~00 ~099 ~ O0 'gDg 500 -999 2500 " 99: 5oo CALI RNRA ~R CALI -999 2500 -999:2500 65,40?3 -999,¢500 -999,2500 -999,2500 1~,00o8 -99 ,2500 -999,2500 43,3555 -999,2500 -999,2500 -999,~500 30,~330 999, 500 -999,~500 63, 5 999.~0 5 500 -999, 500 -999,~500 12 ~770 -999 500 -999 ~500 20 893 -999 ~500 -999 25OO -999 9500 12 3848 .9~ 2500 -9 ~500 -9 2500 -999 2500 -999 ,2500 LVP 010.~09. VERIFICATION LISTING PAGE ** TAPF TR&ILE~ ** SE~VTCF MA~E :EDIT DATE :~5/1~./~7 ORIGIN :~S1A CONTINIIATION # :01 NEXT TAPM,MA~E : COmMeNTS : ** RFEL WR&ILE~ ** 5ERV?C? NAME :MDIT DATE :85/11/~7 OR?G~'N : C(I~T~NI!ATION # :01 NEXT REEL WA~E : CO~MEN~S : ********** EOF ********~* **$******* EOF ********** A~aska Oil & Gas Cons.