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Home My WebLink About199-075STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV UNIT 3G-26 JBR 04/04/2023 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:0 3-1/2" JT used good test accumulator bottles 11 @ 1027 avg prechage Test Results TEST DATA Rig Rep:Kelly Cozby / Paul YearOperator:ConocoPhillips Alaska, Inc.Operator Rep:Dale Rowell / Chase Erdma Rig Owner/Rig No.:Nabors 7ES PTD#:1990750 DATE:2/18/2023 Type Operation:WRKOV Annular: 250/3500Type Test:INIT Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopKPS230219092436 Inspector Kam StJohn Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 4.5 MASP: 3215 Sundry No: 323-043 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"P #1 Rams 1 2-7/8" x 5"P #2 Rams 1 Blinds P #3 Rams 1 3-1/2" x 5-1/2 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"P Kill Line Valves 2 3-1/8"P Check Valve 0 NA BOP Misc 2 2-1/16"P System Pressure P3000 Pressure After Closure P1500 200 PSI Attained P10 Full Pressure Attained P147 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P5 @ 2010 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 P29 #1 Rams P5 #2 Rams P6 #3 Rams P6 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1       STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED By Kayla Junks at 10:05 am, Mar 22, 2023 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 E Coiled Tubing Ops ❑ Other: Replace Tubing Q 2. Operator Name 4. Well Class Before Work: 5. Permit to Drill Number: ConoeoPhillips Alaska, Inc. Development Q Exploratory ❑ Stratigraphic ❑ Service ❑ 199-075 3. Address: P.O. Box 100360 6. API Number: Anchorage, AK 99510 50-103-20303-00-00 7. Property Designation (Lease Number): 8. Well Name and Number. ADL0026647 KRU 313-26 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): NIA Kuparuk River Field/ Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 9850' feet Plugs measured None feel true vertical 6388' feet Junk measured None feet Effective Depth measured 9850' feet Packer measured 60841, 8532', 9161' feet true vertical 6388' feet true vertical 3949'. 5274'. 5764' feet Casing Length Sim MD TVD Burst Collapse Conductor 79' 16" 110, 110, Surface 46314' 7-5/8" 4344' 3051' Intermediate Production 9299' 5-1/2" 9332' 5909' Liner 687' 3-1/2" 9848' 6386' Perforation depth Measured depth 9362-9377', 9502-9516', 9530-9545' True Vertical depth 5935-5947', 6057-6070', 6083-6096' Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 9161' MD 5764' TVD Packers and SSSV (type, measured and true vertical depth) Packer: Baker FA-1 Packer 6084' MD 3949' TVD Packer: FAB Packer 8532' MD 5274' TVD Packer: Baker SABL-3 Peru Packer 9161' MD 5764' TVD SSSV: None N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13a. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Well Remains Shut -In Subsequent to operation: - - - - - 13b. Pools active after work: Kuparuk River Oil Pool 14. Attachments (required per 20 AAc 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations ❑° Exploratory ❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: oy 101nenMsl.nec«nonn 323.043 eN:GUSA=ecmwPNIIIgN ,eNSWe /�Jklu�' eem.nn Fnl,aeye,,,,,"newnW,Pnonra.wm Authorized Name and Fewm: I lew roAwveE IMa Oocu,renl i_ r: Digital Signature with Date: oen:zozsMwVe lm 12 1 Contact Name: Shane Germann g g Fo}X PeF EUnW VersIM: 1301 Contact Email: shane.aermannik0conocoohillios.com Authorized Title: Senior CTD Engineer Contact Phone: (907) 263-4597 Sr Pet Eng: Isr Pet Geo: I I Sr Res Eng: RBDMS JSB 032323 Form 10404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Operations Summary (with Timelog Depths) 3G-26 RIG RELEASE DATE 2/25/2023 cor�anerps Rig: NABORS 7ES Job: RECOMPLETION Time Log Stim Time Erid Time our (hr) Phase Activity Code Time P-T-X Operation Stan Depth (ftKB) End Depth (ftKB) 2/16/2023 2/16/2023 4.00 DMOB P Bridal up. Lay over derrick. RID tiger 0.0 0.0 12:00 16:00 tank line. Move cuttings tank and mud shack. Disconnect electrical in interconnect. Trucks on location @ 12:00 Noon. Load shop and office. 2/16/2023 2/16/2023 2.00 MOB P Move Pits, Office, and shop f/3N-Pad to 0.0 0.0 16:00 18:00 3G-Pad. Spot Office complex and Shop. 2/16/2023 2/17/2023 6.00 MOB P Move Sub f/3N-Pad to 3G-Pad. Rig on 0.0 0.0 18:00 00:00 1location @ 00:00 2/17/2023 2/17/2023 3.50 MIRU, MOVE MOB P Hang tree in cellar. Spot wellhead 00:00 03:30 equipment behind well. Spot sub over well, lay mats and herculite. 2/17/2023 2/17/2023 1.00 MIRU, MOVE MOB P Trucks on location @ 0300 Hrs. Spot 03:30 04:30 pits to sub, lay mats and herculite. Sent Notification to AOGCC. 2/17/2023 2/17/2023 6.00 MIRU, WELCTL MOB P Berming in rig. Spot cuttings tank. R/U 0.0 0.0 04:30 10:30 tiger tank line & Choke House. RU Circulating Manifold in Cellar. RU Inner Connect. Berm in Open Top Tank 2/17/2023 2/17/2023 3.50 MIRU, WELCTL COND P Accept Rig. Take on Fluid to pits, start 0.0 0.0 10:30 14:00 Conditioning fluid from 10.4 PPG to 10.0 PPG. 2/17/2023 2/17/2023 1.75 MIRU, WELCTL KLWL P Fluid Pack out to Kill Tank. PT Lines to 0.0 0.0 14:00 15:45 3500 psi. Open Well to Choke. lintial TBG:75 / Initial IA 75 / Initial CA 20 psi. Stage Rig pump from 1 BPM to 5 BPM, 1100 psi. Circulated 220 bbls of 10.4 KWF. Blow Circulating Lines and Choke. 2/17/2023 2/17/2023 1.00 MIRU, WELCTL OWFF P Observe Well For Flow. 0.0 0.0 15:45 16:45 2/17/2023 2/17/2023 0.50 MIRU, WELCTL MPSP P Install BPV. 0.0 C.0 16:45 17:15 2/17/2023 2/17/2023 0.50 MIRU, WELCTL PRTS P Pressure test BPV for 15 mins @ 1000 0.0 0.0 17:15 17:45 psi. // Good test // 2/17/2023 2/17/2023 1.25 MIRU, WELCTL RURD P Rig down tree for nipple up 0.0 0.0 17:45 19:00 2/17/2023 2/17/2023 3.00 MIRU, WHDBOP NUND P Nipple up stack get RKB's 0.0 0.0 19:00 22:00 2/17/2023 2/17/2023 0.50 MIRU, WHDBOP SVRG P Service rig 0.0 0.0 22:00 22:30 2/17/2023 2/18/2023 1.50 MIRU, WHDBOP OTHR P Perform between wells maintenance 0.0 0.0 22:30 00:00 2/18/2023 2/18/2023 6.00 MIRU, WHDBOP OTHR P Perform between wells maintenance 0.0 0.0 00:00 06:00 2/18/2023 2/18/2023 0.50 MIRU, WHDBOP SVRG P Service Drawworks 06:00 06:30 2/18/2023 2/18/2023 2.00 MIRU, WHDBOP RURD P Make up test jt and shale test stack and 0.0 0.0 06:30 08:30 test plug. Page 115 Report Printed: 2/27/2023 Operations Summary (with Timelog Depths) 3G-26 RIG RELEASE DATE 2/25/2023 cor�anerps Rig: NABORS 7ES Job: RECOMPLETION Time Log Stim Time ErM Time Dur (hr) Phase Activity Code Time P-T-X Operation Stan Depth (ftKB) End Depth (ftKB) 2/18/2023 2/18/2023 4.50 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 0.0 0.0 08:30 13:00 250/3500 PSI for 5 Min each, Test annular 250/2500 on 3-1/2"" test joint. Tested, UVBR's and LPR on 3-1/2"" test joints. Test blinds rams. Choke valves #1 to #11, upper and lower top drive well control valves. Test 3 1/2" HT-38 FOSV and IBOP. Test 3 %" EUE FOSV Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressureiiii PSI, after closure=1500 PSI, 200 PSI attained =XX sec, full recovery attained =10 sec. UVBR's= 5 sec, LVBR's= 5 sec. Annular- 29 sec. Simulated blinds= 6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average =2025 PSI. Witnessed by AOGCC rep Kam StJohn. 2/18/2023 2/18/2023 1.00 COMPZN, RPCOMP RURD P B/D, RID testing equipment. Drain 0.0 0.0 13:00 14:00 Stack. 2/18/2023 2/18/2023 1.25 COMPZN, RPCOMP MPSP P Pull tree test dart & BPV. 0.0 0.0 14:00 15:15 2/18/2023 2/18/2023 0.50 COMPZN, RPCOMP PULD P M/U landing joint T/ hanger. M/U TD. 0.0 0.0 15:15 15:45 Set down 10 block weight. BOLDS. 2/18/2023 2/18/2023 1.75 COMPZN, RPCOMP PULL P Pull hanger free at 100K, weight broke 8,486.0 7,700.0 15:45 17:30 over to 88K with no drag. Pull Hanger to Rig Floor and LID same. Continue OOH laying down 3.5" Completion. 2/18/2023 2/18/2023 0.50 COMPZN, RPCOMP SVRG P Change out power tongs 7,700.0 7,700.0 17:30 18:00 2/18/2023 2/19/2023 6.00 COMPZN, RPCOMP PULL P Continue OOH laying down 3.5" 7,700.0 5,800.0 18:00 00:00 Completion. 2/19/2023 2/19/2023 3.00 COMPZN, RPCOMP PULL P Continue OOH laying down 3.5" 5,800.0 0.0 00:00 03:00 Completion. From Jt 177 down to top of No -Go had multiple holes in 3-1/2" tubing // Bad cut seals pulled out of lower completion 2/19/2023 2/19/2023 1.00 COMPZN, RPCOMP CLEN P Cleaned floor prep pick up pipe 0.0 0.0 03:00 04:00 2/19/2023 2/19/2023 5.00 COMPZN, RPCOMP PULD P Install Wear Bushing. Pick up 3-1/2" 0.0 0.0 04:00 09:00 worksting stand in derrick 2/19/2023 2/19/2023 0.50 COMPZN, RPCOMP SVRG P Rig Service. 0.0 0.0 09:00 09:30 2/19/2023 2/19/2023 1.50 COMPZN, RPCOMP BHAH P PU/MU BHA#1. Scraper Assembly 0.0 42.4 09:30 11:00 2/19/2023 2/19/2023 10.00 COMPZN, RPCOMP TRIP P TIH with BHA #1 on 3.5" Hydril PH6 // 42.4 8,400.0 11:00 21:00 RIH to 8400 2/19/2023 2/19/2023 1.75 COMPZN, RPCOMP WASH P Wash 8400 - 8440 test packer setting 8,400.0 8,440.0 21:00 22:45 area // Pu Wt. 105K So Wt. 75K // Pump 2 bpm @ 360 psi // Wash and scrape area for perm packer 2/19/2023 2/19/2023 0.25 COMPZN, RPCOMP TRIP P TIH with BHA #1 on 3.5" Hydril PH6 // 8,440.0 8,520.0 22:45 23:00 RIH to 8520 2/19/2023 2/20/2023 1.00 COMPZN, RPCOMP WASH P Wash seal bore ext T/ 8530' // 8,520.0 8,530.0 23:00 00:00 Encounter fill from 8520' to 8541' // Tag out on XO with bit depth 8541' // Top of seal bore 8528' 2/20/2023 2/20/2023 2.00 COMPZN, RPCOMP CIRC P Pump surface to surface volume ensure 8,530.0 8,500.0 00:00 02:00 dean hole // Pump dry job for tooh Page 215 Report Printed: 2/27/2023 Operations Summary (with Timelog Depths) 3G-26 9.6 RIG RELEASE DATE 2/25/2023 co.i Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time ErM Time Dur (hr) Phase Activity Code Time P-T-X Operation Stan Depth (WB) End Depth (ftKB) 2/20/2023 2/20/2023 3.50 COMPZN, RPCOMP TRIP P Trip out on stands for test packer 8,500.0 35.0 02:00 05:30 2/20/2023 2/20/2023 1.50 COMPZN, RPCOMP BHAH P Lay down scraper bha 35.0 0.0 05:30 07:00 2/20/2023 2/20/2023 0.50 COMPZN, RPCOMP BHAH P Pick up test packer bha # 2 0.0 26.0 07:00 07:30 2/20/2023 2/20/2023 0.50 COMPZN, RPCOMP SVRG P Rig Service. 26.0 26.0 07:30 08:00 2/20/2023 2/20/2023 6.00 COMPZN, RPCOMP TRIP P Trip in hole on stands T/ 8490' 26.0 8,490.0 08:00 14:00 2/20/2023 2/20/2023 9.25 COMPZN, RPCOMP PRTS P Up Wt 105K / Din Wt 70K @ 8450'. Set 8,490.0 6,700.0 14:00 23:15 Test Packer @ 8490' .Test casing @ 8490' (Failed) Test casing @ 8440' (Failed)Test casing @ 8430' (Failed) Test Casing @ 8420' (Failed) Test Casing @ 841 0'(Failed) Test Casing @ 8390' (Fail) Test Casing @ 8197' ( Fail ) Test @ 8140' ( Fail) Test @ 8120' ( Failed ) Test @ 7620' ( Failed ) Test @ 7550' ( Failed ) Test @ 6700' ( Failed ) Test between packer and plug ( Failed ) Pump 1150 psi ( 2.5 bbls ) in 5 min leaked off 870 psi static fluid level on annulus 2/20/2023 2/21/2023 0.75 COMPZN, RPCOMP TRIP P Trip out of hole Standing Back 3-1/2" 6,700.0 5,000.0 23:15 00:00 work string 2/21/2023 2/21/2023 1.25 COMPZN, RPCOMP TRIP P Trip out to 3000' 5,000.0 3,000.0 00:00 01:15 2/21/2023 2/21/2023 5.75 COMPZN, RPCOMP PRTS P Test casing @ 3000' ( Pass) ,Work 3,000.0 6,150.0 01:15 07:00 back in well performing casing test to locate leak Test Casing @ 4050' ( Pass ) Test Casing @ 5082' ( Pass ) Test Casing 6050' ( Pass ) Test Casing @ 6180' ( Fail ) Test Casing @ 6150' marginal results looks to be area where leak is 2/21/2023 2/21/2023 2.00 COMPZN, RPCOMP SLPC P Cut and slip drill line 6,150.0 6,150.0 07:00 09:00 2/21/2023 2/21/2023 2.25 COMPZN, RPCOMP TRIP P Trip in to top of PBR to pump Cl 6,150.0 8,500.0 09:00 11:15 2/21/2023 2/21/2023 1.25 COMPZN, RPCOMP CIRC P Pump 57 bbls Cl followed by 20 BBLS 8,500.0 8,500.0 11:15 12:30 2/21/2023 2/21/2023 5.00 COMPZN, RPCOMP TRIP P Check flow// Blow down TD and Stand 8,500.0 23.0 12:30 17:30 pipe // TOOH 2/21/2023 2/21/2023 0.50 COMPZN, RPCOMP BHAH P At surface with test packer, Service 23.0 0.0 17:30 18:00 break packer, lay down packer 2/21/2023 2/21/2023 1.00 COMPZN, RPCOMP RURD P Crew change, R/U floor to run lower 0.0 0.0 18:00 19:00 completion, C/O rig tongs 2/21/2023 2/21/2023 0.50 COMPZN, RPCOMP SVRG P Service/ Inspect top drive 0.0 0.0 19:00 19:30 2/21/2023 2/21/2023 4.00 COMPZN, RPCOMP RGRP T Unable to get casing hydraulic circut to 0.0 0.0 19:30 23:30 run tongs - Trouble shoot circut 2/21/2023 2/21/2023 0.20 COMPZN, RPCOMP BHAH P P/U Baker seal assembly 0.0 19.1 23:30 23:42 2/21/2023 2/22/2023 0.30 COMPZN, RPCOMP PUTB P P/U lower 3 1/2' completion, 77 Jts 19.1 109.0 23:42 00:00 2/22/2023 2/22/2023 6.00 COMPZN, RPCOMP PUTB P Continue picking up lower completion 109.0 2,500.0 00:00 06:00 Page 315 Report Printed: 2/27/2023 Operations Summary (with Timelog Depths) 3G-26 RIG RELEASE DATE 2/25/2023 cor�anerps Rig: NABORS 7ES Job: RECOMPLETION Time Log Statl Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Stan Depth (flKB) Eno Depr (flKB) 2/22/2023 2/22/2023 5.00 COMPZN, RPCOMP RUNL P Run lower completion tubing and hanger 2,500.0 8,500.0 06:00 11:00 on PH-6 work string // NG with top of PBR @ 8508' 2/22/2023 2/22/2023 4.00 COMPZN, RPCOMP HOSO P Confirm NG tag Pump pressure 8,500.0 8,518.0 11:00 15:00 increase re -tag @ 8508' top of PBR // break jt drop 1" ball for setting tool // Set packer top @ 6078' w/ 2000psi pick up 130K packer set // blow down TD for freezing protection // test packer 1960psi 2/22/2023 2/22/2023 8.00 COMPZN, RPCOMP PULD P Lay down drill pipe 8,518.0 30.0 15:00 23:00 2/22/2023 2/23/2023 1.00 COMPZN, RPCOMP BHAH P All work PH-6 workstring OOH, Lay 30.0 0.0 23:00 00:00 down bumper sub, B-2 setting tool - Prep floor for running completion. Pull wear ring 2/23/2023 2/23/2023 0.50 COMPZN, RPCOMP BHAH P Prep floor for running completion. Pull 0.0 0.0 00:00 00:30 wear ring, (Cont) 2/23/2023 2/23/2023 0.50 COMPZN, RPCOMP SVRG P Service top drive and tongs 0.0 0.0 00:30 01:00 2/23/2023 2/23/2023 1.00 COMPZN, RPCOMP CLEN P Clean and dear rig floor for liner run cps 0.0 0.0 01:00 02:00 2/23/2023 2/23/2023 10.00 COMPZN, RPCOMP PUTB P PJSM - Make up upper 3 1/5" 0.0 5,866.0 02:00 12:00 completion 2/23/2023 2/23/2023 0.50 COMPZN, RPCOMP PRTS P Pressure test lower seals 2000psi 10 5,866.0 5,866.0 12:00 12:30 min good test 2/23/2023 2/23/2023 0.50 COMPZN, RPCOMP PUTB P Pickup and run upper completion 5,866.0 6,050.0 12:30 13:00 2/23/2023 2/23/2023 1.00 COMPZN, RPCOMP CIRC P Circulate in Cl 6,050.0 6,050.0 13:00 14:00 2/23/2023 2/23/2023 0.25 COMPZN, RPCOMP PRTS P Test K-latch seals and upper seals 1500 6,079.0 6,079.0 14:00 14:15 for 10 min good test // Shear out pbr leave 1600 psi on pipe pull 30K over posative shear // blead off for space out 2/23/2023 2/23/2023 2.00 COMPZN, RPCOMP PACK P Space out land hanger // Pick out of 6,079.0 6,079.0 14:15 16:15 PBR re -tag mark pipe for space out // Pull tag jt+ 2 to install pup below full jt Pick up jt 267 and hanger land on depth 2/23/2023 2/23/2023 0.50 COMPZN, RPCOMP PRTS P Pressure test tubing and IA // Pressure 6,079.0 6,079.0 16:15 16:45 up pressure on IA and Tubing moving together trouble shoot line up // 2/23/2023 2/23/2023 2.75 COMPZN, RPCOMP PRTS P P/U completion, Lay down hanger, P/U 6,079.0 6,097.0 16:45 19:30 joint & 10' pup, set down on no go. Attemp PT. Getting returns. Pump PSI 750 PSISeals or SOV sheared, Call out slick line 2/23/2023 2/23/2023 2.00 COMPZN, RPCOMP WAIT T Call out Slick line to diagnose SOV 6,097.0 6,097.0 19:30 21:30 Valve 2/23/2023 2/23/2023 1.50 COMPZN, RPCOMP SLKL P Slick line on location. MIRU. Set catcher 6,097.0 6,097.0 21:30 23:00 sub@ 6085'. Pull SOV from bottom GLM. 6014 SLM. Valve is sheared. 2/23/2023 2/24/2023 1.00 COMPZN, RPCOMP SLKL P Slick line rigged up, RIH with catcher 6,097.0 6,097.0 23:00 00:00 sub to 6085 SLM 2/24/2023 2/24/2023 3.00 COMPZN, RPCOMP SLKL T RIH with catcher sub to 6085 SLM, 6,097.0 6,097.0 00:00 03:00 POOH. Pull SOV from bottom GLM. 6014 SLM. Valve is sheared 2/24/2023 2/24/2023 3.00 COMPZN, RPCOMP SLKL T Bottom latch DGLV on location, S/L 6,097.0 6,097.0 03:00 06:00 crew change out. RIH with dummy 2/24/2023 2/24/2023 1.00 COMPZN, RPCOMP HOSO P Land hanger and space out 6,097.0 6,097.0 06:00 07:00 2/24/2023 2/24/2023 1.75 COMPZN, RPCOMP PRTS P Pressure test tubing 3000 30 min 6,097.0 6,097.0 07:00 08:45 ( Pass ) Test IA 2500 30 min ( Pass) // Rig down test equipment Page 415 Report Printed: 2/27/2023 Operations Summary (with Timelog Depths) 9.6 3G-26 RIG RELEASE DATE 2/25/2023 CorwcoPh➢rips Rig: NABORS 7ES Job: RECOMPLETION Time Log Statl Time End Time Cur (hr) Phase Activity Code Time P-T-X Operation Stan Depth (ftKB) End Depth (ftKB) 2/24/2023 2/24/2023 5.25 COMPZN, WHDBOP SLKL P Rig up slick line pull dummy valve 6,097.0 0.0 08:45 14:00 2/24/2023 2/24/2023 0.50 COMPZN, WHDBOP OTHR P Install BPV, PT 1000 PSI / 5 Min - Good 0.0 0.0 14:00 14:30 2/24/2023 2/24/2023 1.00 COMPZN, WHDBOP NUND P Nipple down SOP's / DSA 0.0 0.0 14:30 15:30 2/24/2023 2/24/2023 1.50 COMPZN, WHDBOP NUND P Nipple up adapter and production tree 0.0 0.0 15:30 17:00 2/24/2023 2/24/2023 4.00 COMPZN, WHDBOP CIRC P MIRU LRS, PT 250 Low- 5000 PSI 0.0 0.0 17:00 21:00 high. Online down annulas returns up tubing. Pump 50 BBIs LEPD freeze protect. S/D pump. Rig up U tube diesel tubing X IA 2/24/2023 2/24/2023 1.00 DEMOB, MOVE RURD P Rig down circulation equipment 0.0 0.0 21:00 22:00 2/24/2023 2/25/2023 2.00 DEMOB, MOVE RURD R/D cellar, Fluids out of pits. Work RID 0.0 0.0 22:00 00:00 lists Rig Release Midnight Page 515 Report Printed: 2/27/2023 3G-26 RWO Summary of Operations DTTMSTARTJOBTYP SUMMARYOPS 1/8/2023 ACQUIRE DATA (PRE RWO) FT LDS/GNS (COMPLETE), T POT (PASS), T PPPOT (PASS), IC POT (PASS), IC PPPOT (PASS), MITOA (PASS) @ 1800 PSI. 1/20/2023 ACQUIRE DATA PULLED GLV'S @ 7624', 5789', 3313' RKB & SET DMY'S; PULLED 2.78" CATCHER @ 8580' RKB; EQUALIZED & PULLED 3.5" WRP @ 8584' RKB; MEASURE BHP @ 9365' RKB. BHP = 3808 PSI. IN PROGRESS. 1/21/2023 ACQUIRE DATA BRUSH n' FLUSH & GAUGE TBG W/ 2.84" TO TAG DS NIP @ 9140' RKB; (UTILIZING 1.69" DPU) SET 2.72" QUADCO RBP @ 8616' RKB ME (#CPP35352 / #CPEQ35019); SET 2.79" CATCHER W/ TTS STINGER @ 8612' RKB. READY FOR DHD. 1/22/2023 ACQUIRE DATA (PRE-RWO) : CDDT-T/IA IN -PROGRESS. 1/23/2023 ACQUIRE DATA (PRE-RWO) : CDDT-T/IA IN -PROGRESS. 1/24/2023 ACQUIRE DATA (PRE-RWO) : CDDT-T/IA FAILED. 1/28/2023 REPAIR WELL CIRC-OUT WELL, PUMPED 200 BBLS SEAWATER CONTAIINING 84 GALLONS CRW-132, FOLLOWED BY 53 BBLS DIESEL. ALLOW TBG & IA TO U-TUBE FOR FREEZE PROTECT. READY FOR DHD 1/29/2023 ACQUIRE DATA (PRE-RWO) CDDT T X IA TO 0 PSI IN PROGRESS. 1/30/2023 ACQUIRE DATA (Pre RWO) CDDT T X IA FAILED 2/8/2023 ACQUIRE DATA PULLED 3 1/2" CATCHER & RBP @ 8612' RKB. READY FOR E-LINE. 2/9/2023 ACQUIRE DATA SET QUADCO 3.5" MEDIUM EXPANSION RBP AT 8552.0' RKB (MID ELEMENT), CCL TO ME = 12.1', CCL STOP DEPTH = 8539.9' DROP 2.70" CATCHER AND CHASE TO BOTTOM. TAG TOP OF CATCHER AT 8546' RKB (TOP OF RBP AT 8549') JOB IN PROGRESS 2/9/2023 REPAIR WELL CIRC-OUT PUMPED 200 BBLS SW W/ 84 GALS CRW-132 DWN TBG TAKING RETURNS UP IA PUMPED 53 BBLS DSL OWN TBG U-TUBED FOR FREEZE PROTECT READY FOR DHD 2/10/2023 ACQUIRE DATA JOB CONTINUED FROM 09-FEB-2023 PERFORM STRING SHOT OVER INTERVAL 8477' - 8487' RKB CUT 3-1/2" TUBING WITH 2-5/8" CHEMICAL CUTTER AT 8486.0' RKB, CCL TO CUTTER = 11.4', CCL STOP DEPTH = 8474.6' JOB COMPLETE, READY FOR RWO 2/12/2023 ACQUIRE DATA (PRE RWO) BLEED T/I/O TO 0 PSI (COMPLETE) T/I/O DDT (COMPLETE) 2/16/2023 RECOMPLETION Completed rigging down off 3N-07, lay over derrick, office and shop to 3G pad and spot, start moving rig from 3N to 3G 2/17/2023 RECOMPLETION Complete rigging up over 3G-26, take on fluid and accept rig @ 10:00, kill well with 10ppg fluid, set BPV, nipple down tree and nipple up stack, start performing between wells maint. 2/18/2023 RECOMPLETION Completed between wells maintenance, rig up and perform initial 250/3500 state witnessed test Kam StJohn, pull test dart and BPV, unseat hanger 100K PU wt, lay down lower completion to jt 177 2/19/2023 RECOMPLETION Complete laying down upper completion, pick up baker scraper run tools, trip in hole with scraper on singles 3-12" work string, wash seal bore ext. T/ 8530' 2/20/2023 RECOMPLETION Completed washing seal bore ext, pump surface to surface, TOOH for test packer run, trip in on stands set packer @ - 8490' test casing, Unable to get good test work up hole T/ 6700' still not able to get test, start tripping out of hole to 3000' half way up well bore to test casing 2/21/2023 RECOMPLETION Test casing @ 3000'- Good, Trip in to casing test failure @ 6180. Deepest good test @ 6150'. Trip into top of PBR @ 8100', Pump 57 BBIs Cl. Trip out with test packer H Start picking up lower completion 2/22/2023 RECOMPLETION Complete lower completion P/U with Baker seal asembelly, 77 As 3 1/2" 8rd EUE IPC tubing, D nipple W/RHC plug installed, and 3 112 X 51/2' Baker Packer. Trip in well, Land top seals in PBR @ 8537. Set packer. PT 30 min. Trip out laying down string. Lay down string in derrick. Prep to run upper completion 2/23/2023 RECOMPLETION Run upper completion to 6050, Circ in Cl brine. Continue in to No Go @ 6079. PT K Latch and upper seals 1500 PSI for 10 minutes. Pull up see shear screws shear. PUH. Pick up space out pups / Hanger. Land hanger. NO PT. Have T X IA Pull hanger. Set back down on no go 6097' . Still have circulation T X IA. Call out HES Skick line 2/23/2023 REPAIR WELL SET 3" CATCHER @ 6084' SLM; PULLED SOV @ 6004' SLM (SOV SHEARED); SET INTEGRAL BTM LATCH DV @ 6004' SLM; PULLED DV @ 6004' SLM; PULLED CATCHER @ 6084' SLM. JOB COMPLETE 2/24/2023 RECOMPLETION MIRU HES Slick line. Set catcher, Change out SOV in lower mandrel. Valve was sheared. Make up space out pups w/ hanger. Land hahger. RI LDS's. PT Tubing 3000 PSI/30Min. PT IA 2500130 Min. Good test. Go to RDMO Rig Release Midnight 3/8/2023 OPTIMIZE WELL SET CATCHER ON TOP OF RHC @ 6101' RKB; PULLED DV & SET GLV @ 3627' RKB; SET OV @ 6002' RKB; OBTAIN GOOD TBG TEST & IA DDT; PULLED CATCHER @ 6101' RKB. IN PROGRESS. 3/9/2023 OPTIMIZE WELL PULLED RHC PLUG BODY @ 6101' RKB; BAIL FILL & PULL CATCHER @ 8545' RKB; PULLED CATCHER & 2.60" ME RBP @ 8545' RKB; TAG SLIP STOP ON ISO SLEEVE W/ 2.5" GAUGE RING @ 9347' RKB. (NOTE: LARGER TOOLS CONSISTENTLY OVER PULL COMING THRU PACKER @ 6084' RKB). JOB COMPLETE. 3110/2023 MAINTAIN WELL FL PRESSURE TEST PUMPED 12 BBLS DSL DWN FL PRESSURE TESTED FL TO 3000 PSI BLED FL TO 300 PSI KUP PROD WELLNAME 3G-26 WELLBORE 3G-26 'a" A111IMMIL 1013nocoPhillip5 Alaska, Inc. in TAM CONDUCTOR; FLOAT ANCHOR FLOAT APERF, 9,aa2'atP 0- LANDING FLOAT Well Attributes I Max Angle&MD TO TOM!Name WNfinsw APWWI Wellhore Sralua Id(°) K PAR KRIVER NIT 1 2 PR D o.]4 Mn(IIKBI 5,3d4.d6 Aci arm Treat 9,850.0 Camment pp, 12S Ippm) pate MmrNian Last WO: Entl ONe 2242023 KBGN III 34.99 RR Date 12011999 OIM1er EkO... Amwtalion Depth IftKBI 1 WNlbore End Data Last Mod By Last Tag: RKB e541.0 "'a 2I42009 ep, Last Rev Reason Annotation WeIINrt 1 End Data Last Mod! By Rev Reason: Installed OLD B Pulled Plug's I "'a 3I92023 2emba, Notes: General & Safety Annotation Ena Date Lut Moo Br NOTE. VIEW SCHEMATIC WAlaska SOCrrmts,9.0 lIZ412000 tripa, Casing Strings Cag pea Doing to lint 1,(IINS) set Depth set PNTN nIP)PIKB) Deem WLLen (ih.)RH�0� . Top TMeatl CONDUCTOR 16 15.06 31.0 110.0 110.0 62.58 WELDED SURFACE ]5I8 6.8] 30.1 4,344.3 3,051.4 29.70 BTC-MOD PRODUCTION 51I2 4.95 33.0 9,332.0 5,909.3 1B50 BTC-MOD LINER 31I2 2.99 9,161.4 9,S48.01 6,386.4 9.30 I L-80 JBIG Tubing Strings: string max Indicates LONGEST segment of string Top IRKB) BN pepth... Set Depth... String Me... Tubing Description W[donim do Top Lo 11- lo(II) 26.5 8,527.0 5,270.1 312 Tubing - Production 9.30 L-80 EUE 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top(M(B) Top ITVD) (flKB) Toptoal F) ftem Des 0o Consul pn) Com Make model Nominal ID (in) 26.5 26.5 0.03 Hanger 6.990 Tubing Hanger, FMC Gen 3 wl 3.5 FMC EUE Brd Bottom SAW 2.960 516.3 515.0 9.50 Nipple-X 4.506 2.813' X-landing Nipple HES X Nipple 2.813 3,627.4 2,672.0 57.86 Mandrel - GAS LIFT 3.500 3.5"X1"KBG-25 wIDV&BK Latch SLB KEG 24) 2.820 6,002.6 3,906.9 59.25 Mandrel - GAS LIFT 3.500 3.5"X1"KBG-25 SLB NBC 24) 2.820 6,065.4 3,939.2 59.07 Seal Assembly 3.500 Baker seal assembly Met 1.83' stroke Baker w/Locator I20' From fully located) Baker Seal Amy 2.992 6,067.4 3,940.2 59.07 PBR 4780 80-40"PBR" Polish Bore Receptacle w1l 1.83'Seal Assy. Installed 4.000 6,082.4 3,947.9 59.05 Anchor 3.500 KBH-22 Anchor Seal Assy. 2.992 6,084.2 3,948.8 59.05 Packer 3.500 Baker 3-12"x5-12"FA-1 Packer A-1 3.000 6,101.7 3,957.9 59.02 Nipple - No Go 3.500 3.5" No GO Landing Nipple, 2]5" D- Profile, Nipple 2750 9,515.1 5,262.3 49.53 Locator 4.170 Baker 312" 80.40 GBH-22 Locator sub, EUE-Brd-Mod has 040 aker 80 2.970 9,515.2 5,262A 49.52 SealAssembly 3.500 Baker seal assembly, wl Mub Shoe (2.0' From fully located) aker eal ssy 2.992 TOp (IIKB) Set pep[h... 8,51 d.2 8,533.E Set pepm... Skiing Me... Tuhing oe6011ptlOn 5,2]d.5 d.]] Tubing -Completion W[(IhX1) G,atlettMn M(In) Lower 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top(M(B) TopTVD) (flKB) Toptoal (•) ftem Des 0o Nammm (Id earn Make Made' Nominal ID (in) 8,514.2 5,261.8 49.55 PBR 4.]]0 Baker BO-00'FBR"wl 40K Shear r 80-40 2.990 9,531.9 5,273.3 48.99 ANCHOR 4.490 KBH-22 Anchor Seal Assembly 40 ;Baker FA"-36 KBH-22 3.010 TapMKB) BerDepth... 9,166.0 SO Depth...Mrig Ma...Tubing Deaarlptlon WI(4M) Dade p Connectlan lD 7)8,532.3 5,'68.0 3112 FABSTRADDLEPACKER 9.30 L-80 T-MOD 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top(Itl(B) Top RVD) MKB) Tap lncl V) ftem Des pp Nominal (in) Earn Maka MoMI Nominal to (in) 8,532.3 5,273.6 48.98 PACKER 4.550 45 'FAB" Packer cal XO Pup 3.000 9,140.3 5746.1 31.]8 NIPPLE 4.500 Camco 2812"DS Nipple 2.812 9,153.2 5,757.1 3174 SEALASSY 4.500 12.80' Seal Assembly cal 2'spaceoul 3.000 Top (RISEN Set pep[h... 9,147.3 9,161.4 Srtpeptb... Skiing Ma... Tubing De¢crilNion W[(IbM) OnM Tap Connedim ID (in) 57fi4.0 412 TUBING Original 3.00 Completion Details: excludes tubing, pup, space out, thread, RKB... Top(M(B) TopTVD) (flKB) Toptoal I I•) ftem Rs OD Nominal (in) CoreMake Model Dominion to(in) 9,147.3 5752.0 3176 PER 4.500 BAKER 45 05PECKL CLEARANCE PER 3.000 9,160.7 5,763.5 3171 ANCHOR SEAL 4750 SEAL BORE MODEL KBH ANCHOR SEAL ASSEMBLY 4.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top NIKB) Top ITVD) (flKB) Toplml C) Des Co. Make Model SN Run Date to 9,356.0 5,929.8 31.00 SLIP STOP SLIP STOP SET ON TOP OF ISO SLEEVE. 2I4I2009 1.500 9,359.7 5,933.0 30.92 SLEEVE-C G and ISO sleeve, ID 2.31"(DAL 22'9") Top seal @ 9360', Stun seal @ 9380' 3/19120M 1.470 Mandrel Inserts : excludes pulled inserts Top OWED (M(B) st atl Top on Ind I-) No Serr Vave Type LahM1k.DH-.�un TypeRun Dab Com Make MOtlM pMTOp(ftK) a (in) r62].4 2,6] .0 5].8fi GLV INT3I82023 SLB KBGF -9 0.125 8,002.6 3,906.9 59.25 2 OV INTNW2023 SLB 113G2d 1 0.125 ® KUP PROD WELLNAME 3G-26 WELLBORE 3G-26 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9850' None Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: 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: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior writt en approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Shane Germann shane.germann@conocophillips.com (907) 263-4597 Senior CTD Engineer Tubing Grade: Tubing MD (ft): 8532' MD and 5274' TVD 9161' MD and 5764' TVD 513' MD and 512' TVD Perforation Depth TVD (ft): Tubing Size: L-80 9166' 2/9/2023 Packer: 45 FAB Packer w/ XO Pup Packer: Baker SABL-3 Perm Liner Packer SSSV: Camco DS Nipple STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025547 199-075 P.O. Box 100360, Anchorage, AK 99510 50-103-20303-00-00 ConocoPhillips Alaska, Inc. KRU 3G-26 Kuparuk River Oil Pool Kuparuk River Oil Pool Kuparuk River Field N/A Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 6388' 8612' 5327' 3215 8612' MD 110' 3051' 110' 4344' 5909'9332' 16" 7-5/8" 79' 4314' Perforation Depth MD (ft): 9362-9377', 9502-9516', 9530-9545' 9299' 3-1/2" 5935-5948', 6057-6070', 6083-6096' 9848'687' 3-1/2" 6386' 5-1/2" Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Samantha Carlisle at 3:24 pm, Jan 26, 2023 323-043 Digitally signed by Shane Germann DN: C=US, O=ConocoPhillips Alaska, CN=Shane Germann, E=shane.germann@conocophillips.com Reason: I have reviewed this document Location: Date: 2023.01.26 14:16:36-09'00' Foxit PDF Editor Version: 12.0.1 X DLB 02/01/2023 DSR-1/26/23VTL 2/7/2023 10-404X X BOP test to 3500 psig Annular preventer test to 2500 psig GCW 02/07/23 JLC 2/7/2023 2/7/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.02.07 15:15:05 -09'00' RBDMS JSB 020823 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 26, 2023 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Kuparuk Producer 3G-26 (PTD# 199-075). Well 3G-26 was drilled and completed in 1999 as a Kuparuk A/C sand producer. The well was worked over in 2009 to install straddle packer and C-sands were closed for production via sleeve. In 2014, there became tubing to IA communication and multiple tubing leaks were discovered. In 2015, a leak detect log identified a suspected PC leak from 8450'-8470'. The well then became a RWO candidate. The scope of the RWO is to pull the existing 3-1/2” completion down through pre-rig cut, install a new 3-1/2” completion with a stacked packer. If you have any questions or require any further information, please contact me at 406-670-1939. Shane Germann Senior Wells Engineer CPAI Drilling and Wells Digitally signed by Shane Germann DN: C=US, O=ConocoPhillips Alaska, CN=Shane Germann, E= shane.germann@conocophillips.com Reason: I am the author of this document Location: Date: 2023.01.26 14:17:02-09'00' Foxit PDF Editor Version: 12.0.1 3G-26 RWO Procedure Kuparuk Producer PTD #199-075 Page 1 of 2 Remaining Pre-Rig Work 1. T-PPPOT and T-POT tests. 2. SBHP. 3. Open lowest GLM in upper completion. Dummy off all other GLMs. 4. Set RBP. Perform C-DDT. 5. Cut the tubing nominally at ~8490 RKB in the middle of the first full joint above the PBR. 6. Prepare well within 48-72 hrs of rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 3G-26. No BPV set for MIRU due to N7ES internal risk assessment. 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. Circulate KWF as needed. Verify well is dead with 30 minute NFT with KWF in the well. 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 Section 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to tubing cut (~8490’ RKB). Cleanout Run and Casing Test 6. Perform a Cleanout run as necessary based on tubing condition and dress off 3.5” tubing stub if necessary. 7. RIH with test packer and confirm production casing integrity. TOOH. Install 3-½” Tubing with Stacked Packer 8. MU 3 ½” completion with overshot, packer, GLMs, and nipples. RIH with completion. 9. Once on depth, space out as needed. Land tubing hanger. RILDS. PT packoffs. ND BOP, NU Tree, Set Packer and Test Completion 10. Install BPV and test to confirm as barrier. ND BOPE and NU tree. Test tree. Pull BPV 11. Circulate in corrosion inhibited fluid. 12. Set packer. 13. Pressure test tubing to 3000 psi for 30 minutes. 14. Pressure test inner annulus to 2500 psi for 30 minutes on chart. 15. Confirm pressure tests, then shear out SOV with pressure differential. 16. Freeze protect well if necessary. 17. RDMO. Post-Rig Work 18. Install GLD. 19. Pull any plugs or ball/rod used for setting packer. 3G-26 RWO Procedure Kuparuk Producer PTD #199-075 Page 2 of 2 General Well info: Wellhead type/pressure rating: FMC Gen IV. 7-1/16” 5k psi top flange. 11” 3K psi bottom flange Production Engineer: Brian Lewis Reservoir Development Engineer: Lynn Aleshire Estimated Start Date: 2/9/2023 Workover Engineer: Shane Germann (406-670-1939/ shane.germann@conocophillips.com) Current Operations: This well is currently shut in. Well Type: Producer Scope of Work: Pull the existing 3-1/2” completion down through pre-rig cut, install a new 3-1/2” completion with a stacked packer. BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: MIT-T N/A (holes, leaks in tubing) CMIT-TxIA N/A (PC leaks identified) MIT-OA Passed- 1/8/2023 IC POT & PPPOT PASSED – 1/8/2023 TBG POT & PPPOT PASSED – 1/8/2023 MPSP: 3215 psi using 0.1 psi/ft gradient Static BHP: 3808 psi / 5930’ TVD measured on 1/20/2023 3G-26 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 110 110 16 15.062 62.5 H-40 Welded Welded Surface 4344 3051 7.625 6.875 29.7 L-80 BTC-MOD BTC-MOD Production/ Intermediate 9332 5909 5.5 4.95 15.5 L-80 BTC-MOD BTC-MOD Liner 9848 6386 3.5 2.992 9.3 L-80 BTC BTC Tubing 8532 5275 3.5 2.992 9.3 L-80 IBT-MOD IBT-MOD PROPOSED COMPLETION 3-½" X nipple at 518' RKB (2.813" min ID) 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco MMG gas lift mandrels @ 3500', 7600', 8350' RKB Baker 3-1/2" 80-40 PBR @ 8407' RKB (3" ID) Baker 40-36 Anchor @ 8414' RKB Baker 3-1/2" x 5-1/2" FA Packer @ 8421' RKB (4" ID) 3-½" D landing nipple at 8469' RKB (2.75" min ID) 3-1/2" x 4.75" OD Non-sealing overshot @ 8490' RKB REMAINING COMPLETION LEFT IN HOLE Pre-rig tubing cut @ 8490' RKB Baker 80-40 PBR w/40k Shear @ 8514' RKB KBH-22 Anchor Seal Assembly @ 8531' RKB (2.99" ID) 45 "FAB" Packer @ 8532' RKB (3.00" ID) Camco DS nipple @ 9140' RKB (2.812" ID) Surface Casing Production/Intermediate Casing Conductor A-sand perfs 9502' - 9545' RKB C-sand perfs 9362' - 9377' RKB Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 9,541.0 3G-26 2/4/2009 triplwj Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: GLV C/O, SET DMY, PULL CATCHER & PLUG 3G-26 1/20/2023 praffer Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 1/24/2009 triplwj 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 31.0 110.0 110.0 62.58 H-40 WELDED SURFACE 7 5/8 6.87 30.1 4,344.3 3,051.4 29.70 L-80 BTC-MOD PRODUCTION 5 1/2 4.95 33.0 9,332.0 5,909.3 15.50 L-80 BTC-MOD LINER 3 1/2 2.99 9,161.4 9,848.0 6,386.4 9.30 L-80 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 26.1 Set Depth … 8,533.6 Set Depth … 5,274.5 String Ma… 3 1/2 Tubing Description TUBING WO Wt (lb/ft) 9.30 Grade L-80 Top Connection IBT-Mod 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) 26.1 26.1 0.03 HANGER 6.995 FMC Tbg Hanger, G4, 3 1/2" x 6", EUE 8R top, IBT pin, 1 port FMC G4 2.992 512.9 511.6 9.42 NIPPLE 4.520 Camco 3 1/2" "DS" Nipple w/ 2.875" Profile Camco DS Nipple 2.875 3,312.9 2,506.3 58.50 GAS LIFT 4.725 Camco 3 1/2" x 1" KBG-2-9 w/ DK- 1A Dummy w/Integral Latch Camco KBG-2-9 2.900 5,789.0 3,799.1 59.56 GAS LIFT 4.725 Camco 3 1/2" x 1" KBG-2-9 w/ DK- 1A Dummy w/Integral Latch Camco KBG-2-9 2.900 7,624.6 4,751.4 58.96 GAS LIFT 4.725 Camco 3 1/2" x 1" KBG-2-9 w/ DK- 1A Dummy w/Integral Latch Camco KBG-2-9 2.900 8,462.1 5,228.4 50.74 GAS LIFT 4.725 Camco 3 1/2" x 1" KBG-2-9 w/DCK- 3 Shear Valve, Integral Latch Camco KBG-2-9 2.900 8,511.7 5,260.2 49.63 LOCATOR 4.000 Seal Assembly Locator w/ 2.11' Spaceout Baker 2.990 8,514.2 5,261.8 49.55 PBR 4.770 Baker 80-40 "PBR" w/ 40K Shear Baker 80-40 2.990 8,531.9 5,273.3 48.99 ANCHOR 4.490 KBH-22 Anchor Seal Assembly 40 "FA" - 36 Baker KBH-22 3.010 Top (ftKB) 8,532.3 Set Depth … 9,166.0 Set Depth … 5,768.0 String Ma… 3 1/2 Tubing Description FAB STRADDLE PACKER Wt (lb/ft) 9.30 Grade L-80 Top Connection IBT-MOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,532.3 5,273.6 48.98 PACKER 4.550 45 "FAB" Packer w/ XO Pup 3.000 9,140.3 5,746.1 31.78 NIPPLE 4.500 Camco 2.812" DS Nipple 2.812 9,153.2 5,757.1 31.74 SEAL ASSY 4.500 12.80' Seal Assembly w/ 2' spaceout 3.000 Top (ftKB) 9,147.3 Set Depth … 9,161.4 Set Depth … 5,764.0 String Ma… 4 1/2 Tubing Description TUBING Original Wt (lb/ft) Grade Top Connection 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) 9,147.3 5,752.0 31.76 PBR 4.500 BAKER 45-40 SPECIAL CLEARANCE PBR 3.000 9,160.7 5,763.5 31.71 ANCHOR SEAL 4.750 SEAL BORE MODEL KBH ANCHOR SEAL ASSEMBLY 4.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 8,608.0 5,324.5 46.57 CATCHER 3-1/2" CATCHER. OAL = 63". 45" DEEP. 1/21/2023 0.000 8,612.0 5,327.2 46.42 PLUG 2.725" PIIP RBP, CE = 8615', W/ 2.84" NOGO BULLNOSE. 4800# RELEASE. 4.01' TOP OF PIIP TO EQ. VLV. PISTON (CPEQ35019). CPP3 5352 1/20/2023 0.000 9,356.0 5,929.8 31.00 SLIP STOP SLIP STOP SET ON TOP OF ISO SLEEVE. 2/4/2009 1.500 9,359.7 5,933.0 30.92 SLEEVE-C C-Sand ISO sleeve, ID 2.31" (OAL 22'9") Top seal @ 9360', Btm seal @ 9380' 3/19/2000 1.470 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,312.9 2,506.3 58.50 1 Gas Lift DMY BTM 1 0.0 1/20/2023 0.000 5,789.0 3,799.1 59.56 2 Gas Lift DMY BTM 1 0.0 1/20/2023 0.000 7,624.6 4,751.4 58.96 3 Gas Lift DMY BTM 1 0.0 1/20/2023 0.000 8,462.1 5,228.4 50.74 4 Gas Lift OPEN BTM 1 0.0 3/23/2015 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) 9,161.4 5,764.0 31.71 PACKER 5.500 BAKER SABL-3 PERMANENT LINER PACKER 2.780 9,359.7 5,933.1 30.92 NIPPLE 3.750 HES SEATING NIPPLE w/POLISH BORE 2.750 3G-26, 1/22/2023 8:32:28 AM Vertical schematic (actual) LINER; 9,161.4-9,848.0 FLOAT SHOE; 9,846.4-9,848.0 FLOAT COLLAR; 9,781.4- 9,782.3 LANDING COLLAR; 9,749.6- 9,750.6 IPERF; 9,530.0-9,545.0 IPERF; 9,502.0-9,516.0 NIPPLE; 9,380.5-9,382.0 SLEEVE-C; 9,359.7 APERF; 9,362.0-9,377.0 NIPPLE; 9,359.7-9,360.5 SLIP STOP; 9,356.0 PRODUCTION; 33.0-9,332.0 FLOAT SHOE; 9,330.6-9,332.0 FLOAT COLLAR; 9,244.7- 9,246.0 PACKER; 9,161.4-9,165.9 ANCHOR SEAL; 9,160.7 SEAL ASSY; 9,153.2 PBR; 9,147.3 NIPPLE; 9,140.3 PLUG; 8,612.0 CATCHER; 8,608.0 PACKER; 8,532.3 ANCHOR; 8,531.9 PBR; 8,514.2 LOCATOR; 8,511.7 GAS LIFT; 8,462.1 GAS LIFT; 7,624.6 GAS LIFT; 5,789.0 SURFACE; 30.1-4,344.3 SHOE; 4,342.8-4,344.3 FLOAT COLLAR; 4,257.0- 4,258.4 GAS LIFT; 3,312.9 TAM COLLAR; 1,031.0-1,033.5 NIPPLE; 512.9 CONDUCTOR; 31.0-110.0 HANGER; 30.1-31.7 HANGER; 26.1 KUP PROD KB-Grd (ft) 34.99 RR Date 8/20/1999 Other Elev… 3G-26 ... TD Act Btm (ftKB) 9,850.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032030300 Wellbore Status PROD Max Angle & MD Incl (°) 60.74 MD (ftKB) 5,344.46 WELLNAME WELLBORE3G-26 Annotation Last WO: End Date 1/10/2009 H2S (ppm) 170 Date 12/23/2013 Comment SSSV: NIPPLE 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) 9,380.5 5,950.9 30.47 NIPPLE 3.940 HES 'XN' LANDING NIPPLE NO GO PROFILE 2.635 9,749.6 6,290.2 13.00 LANDING COLLAR 4.250 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,362.0 9,377.0 5,935.0 5,947.9 C-4, 3G-26 1/30/2000 4.0 APERF 2.5" hollow carrier, 180 deg. ph 9,502.0 9,516.0 6,057.4 6,070.0 A-3, A-4, A-5, 3G-26 9/12/1999 4.0 IPERF 2 1/8" ENERJET 0 deg ph 9,530.0 9,545.0 6,082.6 6,096.3 A-2, 3G-26 9/6/1999 4.0 IPERF 2 1/8" ENERJET 180 deg ph 3G-26, 1/22/2023 8:32:28 AM Vertical schematic (actual) LINER; 9,161.4-9,848.0 FLOAT SHOE; 9,846.4-9,848.0 FLOAT COLLAR; 9,781.4- 9,782.3 LANDING COLLAR; 9,749.6- 9,750.6 IPERF; 9,530.0-9,545.0 IPERF; 9,502.0-9,516.0 NIPPLE; 9,380.5-9,382.0 SLEEVE-C; 9,359.7 APERF; 9,362.0-9,377.0 NIPPLE; 9,359.7-9,360.5 SLIP STOP; 9,356.0 PRODUCTION; 33.0-9,332.0 FLOAT SHOE; 9,330.6-9,332.0 FLOAT COLLAR; 9,244.7- 9,246.0 PACKER; 9,161.4-9,165.9 ANCHOR SEAL; 9,160.7 SEAL ASSY; 9,153.2 PBR; 9,147.3 NIPPLE; 9,140.3 PLUG; 8,612.0 CATCHER; 8,608.0 PACKER; 8,532.3 ANCHOR; 8,531.9 PBR; 8,514.2 LOCATOR; 8,511.7 GAS LIFT; 8,462.1 GAS LIFT; 7,624.6 GAS LIFT; 5,789.0 SURFACE; 30.1-4,344.3 SHOE; 4,342.8-4,344.3 FLOAT COLLAR; 4,257.0- 4,258.4 GAS LIFT; 3,312.9 TAM COLLAR; 1,031.0-1,033.5 NIPPLE; 512.9 CONDUCTOR; 31.0-110.0 HANGER; 30.1-31.7 HANGER; 26.1 KUP PROD 3G-26 ... WELLNAME WELLBORE3G-26 ISSUED AS:PRELIMINARYDATE:ISSUED BY:AS BUILTFOR:APPROVALMARK-UPQUOTEREVIEW07-JUN-21PKMXX17'-314"[5261]3'-912"[1156]4'-734"[1418]2'-0"[610]2'-934"[859]2'-0"[610]2'-0"[610]BY NABORSBY OPERATORPIPE RAMCL WELLCHOKE LINE7BILL OF MATERIALS413121NOQTY DESCRIPTIONBOP, RAM 1358" 5M CAMERON "U" (DOUBLE)1DRILL SPOOL 1358" 5M w/ (2) 318" 5M OUTLETS.BOP, RAM 1358" 5M CAMERON "U" (SINGLE)36GATE VALVE, MANUAL 318" 5MGATE VALVE, HYDRAULIC 318" 5M22BOP, ANNULAR 1358" 5M CAMERON T-9012434455556724" HEIGHT.678KILL LINE5API TARGET BLIND FLANGE 318" 5M48DSA 318"5M x 2116" 5M1FF-TICKET #:THIS DRAWING IS SHOWN TRUE SCALE ONLY WHEN PRINTED ON THIS SIZE PAPERTHIS DOCUMENT AND THE INFORMATION CONTAINED HEREIN IS A CONFIDENTIAL DISCLOSURE. IT IS SHOWN TO YOUR COMPANY WITH THE UNDERSTANDING IT IS NOT TO BEREVEALED TO OTHERS OR USED FOR ANY PURPOSE WITHOUT THE WRITTEN CONSENT OF NABORS INDUSTRIES.REV.XREFDESCRIPTION APP.DATEBYTITLE COPYRIGHTED©DATE:DRN BY:ER:BDWG:APP:RIG:SCALE:NABORSSHT NO. OFNABORS RIG 7ES13 5/8" 5M BOP STACK LAYOUT14002 7ESPKM NTS27-MAY-21 SMB7ES-0008-01B REVISED AND ISSUED FOR INFORMATION 07-JUN-21 PKM3470945 01 01DRILLER SIDEOFF DRILLER SIDE • 24,8'9,0 WELL LOG TRANSMITTAL# To: Alaska Oil and Gas Conservation Comm. February 26, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 RECEIVED M K BENDER MAR`0 8 2015 RE: Multi Finger Caliper: 3G-26 AOGCC Run Date: 1/19/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3G-26 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20303-00 Multi Finger Caliper(Field Log) 1 color log 50-103-20303-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNINGAND RETURNIN.0,A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari SCANNED 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: , / , Ai ' ,� • 16t9 - a7€ 3 ConocoPhillips RECEIVED Alaska NOV 10 2015 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC .A®UCC November 7, 2015 Commissioner Cathy Foerster 5 � AU 1 9 2016 Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field(KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call MJ Loveland at 907-659-7043, if you have any questions. Sincerely, ,,/ej) s f Gam` MJ Loveland ConocoPhillips Well Integrity Projects Supervisor 0 • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 1117/2015 3G,3M&3S PAD Corrosion Initial top Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# of cement pumped cement date inhibitor sealant date ft bbls ft gal 3G-26 50029216960100 1990750 22" 0.4 26" 11/3/2015 2 11/6/2015 3M-03 50029216960100 2081790 SF NA 9" NA 2.6 11/6/2015 3M-04 50029216970000 1870150 12" NA 8" NA 3.7 11/6/2015 3M-25 50029224330100 1940060 12" NA 9" NA 3.2 11/6/2015 3S-14 50103204390000 2022210 64" 0.10 12" 11/3/2015 6 11/6/2015 STATE OF ALASKA • ALADA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool rRepair Well Re-enter Susp Well r' Other:Cond Ext Ivy 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r.7 Exploratory r 199-075 3.Address: 6.API Number: • Stratigraphic r Service r 50-103-20303-00 P. O. Box 100360,Anchorage,Alaska 99510 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025547 • KRU 3G-26 ° 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Kuparuk River Field/Kuparuk River Oil Pool ' 11.Present Well Condition Summary: Total Depth measured 9850 ► feet Plugs(measured) None true vertical 6388 • feet Junk(measured) None Effective Depth measured 9541 feet Packer(measured) 8532 true vertical 6093 feet (true vertical) 5274 Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 16 110 110 1640 630 SURFACE 4314 12 4344 3051 6890 4790 PRODUCTION 9299 5.5 9332 5909 7000 4990 LINER 687 5.5 9848 6386 10159 10533 Perforation depth: Measured depth: 9362'-9545' SCANNED 9/K / 2 20if, , True Vertical Depth: 5935-6096' ErLI Nov 10 20115 Tubing(size,grade,MD,and ND) 3.5, L-80, 9156 MD, 5759 TVD AOG CC Packers&SSSV(type,MD,and TVD) PACKER-45"FAB"PACKER W/ XO PUP @ 8532 MD and 5274 TVD NIPPLE-Camco 3 1/2""DS"Nipple w/2.875"Profile @ 513 MD and 512 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): NA Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: • Daily Report of Well Operations p Exploratory r Development ' Service r Stratigraphic !- Copies of Logs and Surveys Run r 16.Well Status after work: Oil r • Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r VVINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-625 Contact Email n 1878(' cop.com Printed Name MJ Loveland Title Well Integrity Supervisor Signature /f�� Phone:659-7043/ Date 11/7/2015 YTL 1lG/14 'rn r/ ` ;� �nv 132015 Form 10-404 Revised 5/2015 RBDM " Submit Original Only 0 0 I ConocoPhillips RECEIVED Alaska NOV 10 2015 P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC November 7, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well 3G-26, PTD 199-075, Sundry 315-625, conductor extension. Please contact me at 659-7043 if yo have any questions. r i` Sincerely, ,,/77 — MJ Loveland ConocoPhillips Well Integrity Projects Supervisor 3G-26 DESCRIPTION OF WORK COMPLETED SUMMARY 11/07/15 Event Summary 11/01/15 Cut 1'off top of conductor to create a clean welding surface. Welded a 26" conductor extension onto existing conductor due to rising wellhea 5 • io\ ®F TSF �� s9 THE STATE Alaska Oil and Gas ,, 1,4of/� j\ J(j\ Conservation Commission T Js KA - 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS ' `a 6- Fax: 907.276.7542 www.aogcc.alaska.gov � Martin Walters Well Integrity Supervisor I3±-:-P-7-31- ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3G-26 Sundry Number: 315-625 Dear Mr. Walters: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P-7R1 - Cathy P. oerster Chair DATED this /3 day of October, 2015 Encl. RBDMS OCT 14 2015 STATE OF ALASKA AOKA OIL AND GAS CONSERVATION COM SION OCT 0 6 Z015 APPLICATION FOR SUNDRY APPROVALS 17r-S 1003`1S 20 AAC 25.280 AOGCC 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well p Re-enter Susp Well r Other:Cond Ext P ' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. • Exploratory r Development r. 199-075 r 3.Address: Stratigraphic r Service r 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-103-20303-00 . 7. If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No F / KRU 3G-26 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025547 , Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth Mo(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9850' • 6388' ' 9541' - 6093' • Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 110' 110' 1640 630 SURFACE 4314 7-5/8 4344' 3051' 6890 4790 PRODUCTION 9299 5-1/2 9332' 5909' 7000 4990 LINER 687 3-1/2 9848' 6386' 10159 10533 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9362'-9545' , 5935-6096' 3.5 L-80 9156 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER=45"FAB"PACKER W/ XO PUP MD=8532 TVD=5274 , SSSV=Cameo 3 1/2""DS"Nipple MD=513 TVD=512 12.Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development 17 • Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 11/15/2015WINJ r WDSPL r Suspended r OIL Fi, 16.Verbal Approval: Date: GAS r WAG r GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Martin Walters/MJ Loveland Email: n1878(cilcop.com Printed Name Martin Walters �I Title: Well Integrity Supervisor Signature /rj/,{Z ULieZ `c Phone:659-7043 Date: 10-04-15 Commission Use Only Sundry Number: 26 Conditions of approval: Notify Commission so that a representative may witness �j 15— 4. Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No [ Subsequent Form Required: /Q —/d//. APPROVED BY �T V-417 Approved by: ��oved application is valid Tor IL months from tRt aiC oT a Roval. Date: /O—/. ' /3 -,z04.45.----, 2,4- Submit Form and Form 10-403 vise5/2 �o� //� )�RBDhrterDIq0� 177-7_ i0� � � ORIGINAL � 1' ConocoPhillips ,,r ;, 62015 Alaska P.O. BOX 100360 AOGGG ANCHORAGE,ALASKA 99510-0360 October 4, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 3G-26, PTD 199-075 conductor extension. i Please contact Martin Walters or MJ Loveland at 659-7043 if you have any questions. Sincerely, 076!"1:47/(kkig Martin Walters ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska,Inc. Kuparuk Well 3G-26 (PTD 199-075) SUNDRY NOTICE 10-403 APPROVAL REQUEST October 4, 2015 This application for Sundry approval for Kuparuk well 3G-26 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to the surface casing. At some point during normal operations the conductor subsided about 26". With approval, the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Examine surface casing for any corrosion damage. 3. Extend the conductor to starter head and fill the void with cement and top off with sealant. 4. File 10-404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor `, a 3 KUP PROD • 3G-26 ' Con�Orl p�1�lliP S Well Attributes Max Angle&MD TD Alaska.Inc. Wellbore APIIUWI Field Name Wellbore Status ncl(`) MD(ftKB) Act Btm(ftKB) ( iNlhp), 501032030300 KUPARUK RIVER UNIT PROD 60.74 5,344.46 9,850.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 3G-26,3/31/20154:37.38 PM SSSV:NIPPLE 170 12/23/2013 Last WO. 1)10/2009 34.99 8/20/1999 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date _ . Last Tag.RKB 9,541.0 2/4/2009 Rev Reason:SET PLUG,CATCHER,GLV CIO lehallf 3/31/2015 HANGER;20.1 Csing Strings nk T Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread [�'J� CONDUCTOR 16 15.062 31.0 110.0 110.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(RKB) Set Depth(ND)...'Wt/Len(I.. Grade Top Thread SURFACE 75/8 6.875 30.1 4,344.3 3,051.4 29.70 L-80 BTC-MOD Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...'Wt/Len(I...Grade Top Thread PRODUCTION 51/2 4.950 33.0 9,332.0 5,909.3 15.50 L-80 BTC-MOD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(1...Grade Top Thread ''''''"''''LINER 31/2 2.992 9.161.4 9,848.0 6,386.4 9.30 L-80 BTC CONDUCTOR;31,0-110.0 Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(3 Item Des Corn (in) NIPPLE;512.9 Vi 9,161.4 5,764.0 31.71 PACKER BAKER SABL-3 PERMANENT LINER PACKER 2.780 9,359.7' 5,933.1 30.92 NIPPLE HES SEATING NIPPLE w/POLISH BORE 2.750 9,380.5 5,950.9 30.47 NIPPLE HES'XN'LANDING NIPPLE NO GO PROFILE 2.635 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...ISot Depth(ND)(...WI(lb/ft) Grade Top Connection - TUBING WO 31/2 2.992 26.1 8.533611 5,274.5 9.30 L-80 IBT-Mod GAS LIFT;3,312.9Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB( Top Incl(°) Item Des Com (in) 26.1 26.1 0.03 HANGER FMC Tbg Hanger,G4,3 1/2"x 6",EUE 8R top,IBT pin,1 2.992 poll 512.9 511.6 9.42 NIPPLE Camco 3 1/2""DS"Nipple w/2.875"Profile 2.875 SURFACE;30.14,344.3- 4 4 8,511.7 5,260.2 49.63 LOCATOR Seal Assembly Locator w/2.11'Spaceout 2.990 8,514.2 5,261.8 49.55 PBR Baker 80-40"PBR"w/40K Shear 2.990 11H 8,531.9 5,2733 48.99 ANCHOR KBH-22 Anchor Seal Assembly 40"FA"-36 3.010 GAS LIFT;5,789.0 ��il Tubing Description String Ma...ID(in) -Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Iblft) Grade Top Connection FAB STRADDLE 31/2 2.992 8,532.3 9,166.0 5,768.0 9.30 L-80 IBT-MOD PACKER Completion Details GAS LIFT;7,624 6 Nominal ID HTop(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 8,532.3 5,273.6 48.98 PACKER 45"FAB"Packer w/XO Pup 3.000 9,140.3' 5,746.1 31.78 NIPPLE Camco 2.812"DS Nipple 2.812 9,1532 5,757.1 31.74 SEAL ASSY 12.80'Seal Assembly w/2'spaceout 3.000 GAS LIFT,8,482.2 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING Original 41/2 3.000 9.147.3 9,161.4 5,764.0 Completion Details Nominal ID 1----- Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) LOCATOR;8,511.7 [ 1 9,147.3 5,752.0 31.76 PBR BAKER 45-40 SPECIAL CLEARANCE PBR 3.000 PBR;8,514.2 5 t 9.160.7 5,763.5 31.71 ANCHOR SEAL BORE MODEL KBH ANCHOR SEAL ASSEMBLY 4.000 SEAL Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) ANCHOR;8,531.9 0Top Top(ND) Top Incl PACKER;8,5323 (ftKB) (ftKB) (1 Des Com Run Date ID(in) 8,584.0 5,308.1 47.33 PLUG 2.77"WRP 3/22/2015 PLUG;8,584.01I;y;, 8,584.0 5,308.1 47.33 CATCHER CATCHER DEPLOYED ONTO WRP 3/23/2015 III CATCHER;8,584.0 9,356.0 5,929.8 31.00 SLIP STOP SLIP STOP SET ON TOP OF ISO SLEEVE. 2/4/2009 1.500 ill, 9,359.7 5,933.0 30.92 SLEEVE-C C-Sand ISO sleeve,ID 2.31"(OAL 229")Top seal 3/19/2000 1.470 - @ 9360',Bim seal @ 9380' NIPPLE;9,140.3 Perforations&Slots Shot Dens 1 ; Top(ND) Btm(ND) (shotslf Top(ftKB) Bhe(ftKB) (ftKB) (ftKB) Zone Date t) Type Com PBR;9,147.3 9,362.0 9,377.0 5,935.0 5,947.9'C-4,3G-26 1/30/2000 4.0 APERF 2.5"hollow carrier,180 SEAL ASSY;9,153.2 I�• deg.ph ANCHOR SEAL;9,160.7 t . 9,502.0 9,516.0 6,057.4 6,070.0 A-3,A-4,A-5, 9/12/1999 4.0 (PERF 21/8"ENERJET 0 deg 3G-26 ph 9,530.0 9,545.0 6,082.6 6,096.3 A-2,3G-26 9/6/1999 4.0 (PERF 2 1/8"ENERJET 180 deg ph Mandrel Inserts St au Top(ND) Valve Latch Port Size TRO Run PRODUCTION;33.0-9,332.0 N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com i'' 3,312.9 2,506.3 Camco KBG-2- 1 Gas Lift GLV BTM 0.156 1,311.0 1/17/2009 SLIP STOP;9,350.0 9 SLEEVE-C;0,369.7 A 2 5,789.0 3,799.1 Camco KBG-2- 1 Gas Lift GLV BTM 0.188 1,334.0 1/17/2009 9 APERF;9,382.o-g.377.0 3' 7,624.6 4,751.4 Camco KBG-2- 1 Gas Lift GLV BTM 0.188 1,317.0 1/17/2009 9 4 8,462.2 5.228.4 Camco KBG-2- 1 Gas Lift OPEN BTM 0.0 3/23/2015 Ill 9 Notes:General&Safety End Dale Annotation IPERF;9.502.0-0.516A 1'2'1/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 1 IPERF;9,530 -9,545.0 0 r[ 11 L 1 LINER;9,101.4-9,848.0 1 • Bettis, Patricia K (DOA) From: NSK Well Integrity Proj <N1878@conocophillips.com> Sent: Friday, October 09, 2015 8:12 AM To: Bettis, Patricia K (DOA) Subject: RE: KRU 3G-26 (PTD 199-075): Sundry Application Attachments: 3G-26.pdf Patricia Attached is the 3G-26 Schematic Apologies for the oversite error. MJ MJ Loveland /Martin Walters Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 MJ's Cell (907) 943-1687 From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Wednesday, October 07, 2015 1:19 PM To: NSK Well Integrity Proj<N1878@conocophillips.com> Subject: [EXTERNAL]KRU 3G-26 (PTD 199-075): Sundry Application Good afternoon Martin, Please submit a current wellbore schematic for KRU 3G-26. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Wednesday, October 07, 2015 1:19 PM To: NSK Well Integrity Proj (N1878@conocophillips.com) Subject: KRU 3G-26 (PTD 199-075): Sundry Application Good afternoon Martin, Please submit a current wellbore schematic for KRU 3G-26. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 Z5'6%1 WELL LOG TRANSMITTAL DATA LOGGED c.itrr2oi5 K BENDER To: Alaska Oil and Gas Conservation Comm. May 27, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 TR ECE!VED ILJii 04 2015 RE: Leak Detect Log with TMD3D: 3G-26 Run Date: 5/19/2015 OGCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3G-26 Digital Data in LAS format, Digital Log file 1 CD Rom 50-103-20303-00 Leak Detect Log with TMD3D (Field print) SNE© 4 20)L, 1 Color Log 50-103-20303-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Beverly Mildred Daretha a~ Lowell Date: ~7/7 /si ~ [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: Is/ ~~ ~ ~~~ ~ 2 2009 STATE OF ALASKA Aie~t~a ~11~ ,~ Gas LQf1S, C®t11f1lIS~lQq ALASKA OIL AND GAS CONSERVATION COMMISSION At1t:~101'a:]~8 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ^ Repair Well ~ Plug Perforations ^ Stimulate ^ Other ^ Alter Casing ^~ Pull Tubing Q Perforate New Pool ^ .Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnocoPhilllps Alaska, InC. Development 0 Exploratory ^ 199-075 / 3. Address: Strati ra hic g p ^ Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20303-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 30' 3G-26 8. Property Designation: 10. Field/Pool(s): ADL 25547 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 9850' ~ feet true vertical 6388' feet Plugs (measured) 9180' Effective Depth measured 9754' feet Junk (measured) true vertical 6295' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 110' 110' SURFACE 4314' 7-5/8" 4344' 3051' PRODUCTION 9295' S-1/2" 9325' 5903' PRODUCTION 687' 3-1/2" 9848' 6386' Perforation depth: Measured depth: 9362'-9377', 9502'-9516', 9530'-9545' true vertical depth: 5935'-5948', 6058'-6070', 6083'-6066' ~ •~ ~ `~~ ~~~ ~ ~ .. ~ Tubing (size, grade, and measured depth) 3-1/2" , L-80, 9161' MD. Packers & SSSV (type & measured depth) Baker 45-FAB, Baker SABL-3 pkr @ 8532', 9161' Camco DS nipple @ 512' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI -- Subsequent to operation 88 477 580 -- 219 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development 0 ' Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.o. Exempt: 309-002 contact Howard Gober @ 263-4220 Printed Name Howard Gober Title Wells Engineer Signature Phone: 263-4220 Date ~ ! j C ~~ Pre aced b Sha n A11 u -Drake 263-4612 ~p Z • r2,,.ov Form 10-404 Revised 04/2006 ~ ~ ~ ~ ~l;i~ ~ ~ ~~D9 ~ ~~ Submit Ori I~O,nly .. f//i/~ 3G-26 Pre and Post Rig Well Summary DATE SUMMARY 12/13/08 PRE-RWO, T-POT (PASSED), T~POT (PASSED), IC-POT (PASSED), IC- PPPOT (PASSED), FUNCTION TEST LDS'S 12/19/08 RECORD SBHP SURVEY AND SET WEATHERFORD WRP. RESULTS: SURVEY STOP AT 9257' (3315.6 PSI/152.4 DEG F) GRADIENT STOP AT 9139' (3271.8 PSI/149.6 DEG SET WFT SPECIAL CLEARANCE WRP MID-ELEMENT AT 9180' RKB. CCL TO MID-ELEMENT=14.3'.. CCL STOP DEPTH=9165.7'. 12/22/08 SET CATCHER ON WRP (cil 9158' WLM,, PULLED GLV'S @ 7693', 6176' & 3936 RKB, SET DV @ 7693' RKB, IN PROGRESS 12/23/08 PULLED DV @ 9055' RKB (OPEN POCKET) SET DV'S @ 3936', 6176', 8641' RKB. LOADED WELL W/ 9.6 BRINE (0.6% SAFE LUBE) W/ 2000' DIESEL CAP. CMIT TO 2500 PSI, GOOD. BPV INSTALL ORDERED., JOB COMPLETE. TBG & IA WERE BLED DOWN BY THE DSO. T/I/0= 0/0/0 e~~ ~ T 1/16/09 SET 1" DV @ 3312' RKB. MITT TO 2500#- PASS, MITIA TO 2500#- PASS. PULLED DV'S @ 3312', 5787', 7624', 8461' RKB. DRIFTED TBG W/ 2.75" LIB & TAGGED FILL IN TBG aC~ 9151' WLM. IN PROGRESS 1/17/09 SET AVA CATCHER @ 9151' WLM, SET NEW GAS LIFT DESIGN @ 3312, 5788', 7624' & OV @ 8461' RKB, PULLED AVA CATCHER. BAILING SOLIDS @ 9151' WLM. IN PROGRESS 1/19/09 BAILED FILL, PULLED CATCHER @ 9155' WLM, BAILING ON WRP, IN PROGRESS 1/20/09 BAILED ON WRP, IN PROGRESS 1/22/09 BAILED FILL OFF WRP 9180' RKB.EQUILIZED WRP AND MOVED UPHOL_E _~ .....~~.... ,...,~ „ "sir, /1 AA/~A~ rwo *+nnio~ DI II I IAI('_ Tr1lll I FFT INHnI F** 1/23/09 MOVED WRP UPHOLE APPROX 650' TO 8477' SLM.IN PROGRESS 1/24/09 PULLED 3 1/2" WRP. LOST ALL 3 ELEMENTS FROM PLUG ATTEMPT TO FISH W/O SUCCESS. 1/28/09 PULLED 3 1/2" SLIP STOP (a~ 9360' RKB RECOVERED CHUNK OF RUBBER FROM WRP. READY FOR CTU. 2/1/09 RIH WITH VENTURI BASKET AND RECIPROCATED ACROSS ISO SLEEVE @ 9360' CTMD. HAD A LARGE AMOUNT WRP ELEMENTS IN JUNK BASKET AFTER POOH. RETURN IN AM FOR ANOTHER RUN WITH BASKET AND PERFORM CLEAN OUT BELOW ISO SLEEVE. 2/2/09 CLEAN DOWN TO 9579' CTMD, 34 FEET BELOW LOWER SET PERF @ 9545' MD AND 219 FEET BELOW ISO SLEEVE @ 9360' MD.HAD BETTER THAN 1 FOR 1 RETURN UNTIL WE UNCOVERED THE LOWER PERF AND THE WELL WHEN ON A VAC AND STUCK COIL FOR TWO HOURS. ABLE TO MOVE PIPE AFTER USING PRESSURE TO SURGE WELL.LEFT WELL SHUT AND FREEZE PROTECTED FOR SLICK-LINE TAG. 2/4/09 TAGGED EST. 9541' RKB, 4' FILL. SET 3-1/2" SLIP STOP ON C SAND IS SLEEVE @ 9345' RKB. COMPLETE. s~~~ ~~ conoco`Pnillips ~~' ~' A 1 A1aSka. Iru; . ... HANGER, 26 NIPPLE, GAS LIFT, 3,313 SURFACE. 30-4.344 GAS LIFT, 5.]69 GAS LIFT, ],625 GAS LIFT, 8.462 LOCATOR. 8,512 PBR, 8,514 ANCHOR, 8,532 PBR. 9.14] ANCHOR SEAL, 9,161 PRODUCTION, 2]-9,325 SLIP STOP, 8.359 APERF, 9,362-8,31] SLEEVE-C. 9,360 IPERF. 9,502-9,516 IPERF, 9.530-8,545 LINER, 8,161-9,846 TD, 9,850 .T KUP ~ 3G-26 ~ellbore APIIUWI Field Name - Well Status Prod/lnJ Type Inel (°) MD (ftK8) Act Btm (ftK8) 501032030300 KUPARUK RIVER UNIT PROD 60.74 5,344 9,850 ment H2S (ppm) Date Annota tion End Date KB-Grd (it) Rlg Release Dat SSV: NIPPLE 1D0 7/21/2007 Last WO: i/10/2009 34.99 8/20/1999 nnotation Depth (ftK8) Entl Date Annotation Entl Date ast Tag: RKB 9,541 2/4/2009 Rev Reason: UPDATE WORKOVER DETAILS 2/10/2009 :asin Strin s asing Description String 0.. . String ID ... Top (kKB) Sel Depth (f... Se[ Depth (ND) ... String Wt... String ... String Top Thrd ~ONDUCTOR 16 15.062 30 110 110.0 62.58 H-40 WELDED asing Description String 0.. . String ID ... Top (ftK8) Set Depth ((... Set Depth (ND) ... String WL.. String ... String Top Thrd URFACE 7 5/B 6.750 30 4,344 3,051.2 45.50 L-80 BTC-MOD asing Description String 0.. . String ID ... Top (ftK8) Set Depth (T... Sat Depth (ND) ... String Wt... String ._ String Top Thrd PRODUCTION 51/2 4.950 27 9,325 5,903.4 23.00 L-80 BTC-MOD asing Deseripton String 0.. . String ID ... Top (ftK8) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd INER 31/2 2.992 9,161 9,848 6,386.4 9.30 L-80 BTC .finer Details Top Depth (ND) Top Incl eo fkKBl (kKB) (°) I tem Descriotlon Comment ID (li , uu,„y uea~„yuun .,.,,,,y v... u.,,,,y ,u ... ,..y 1,.....1 ..e. °.ev.,, 1,... ..o. ..oy... 1....r ... .......y ...... .......y ... .-.....y ...~ ....~ TUBING 31/2 2.992 26 6,534 5,276 9.30 L-80 IBT-Mod Com letion Details Top Depth (ND) Top Incl Top (ftK8) (ftK8) (°) Item Description Comment ID (In) 26 26.1 -5.15 HANGER FMC Tbg Hanger, G4, 3 1/2" x 6", EUE BR top, IBT pin, t port 2.992 Tubing Description Slring 0... String ID ... Top (ftK8) Set Depth (i... Set Depth (ND) ... String Wt... String ... String Top Thrtl FAB Packer Run 3 112 2.992 8,532 9,166 5,768 9.30 L-80 IBT-MOD Com letion Details Top Depth (ND) Top Incl Top (ftK8) (ftK8) (°) Item Description Comment ID (in) 8,532 5,275.5 49.60 PACKER 45 "FAB" Packer wl XO Pup 3.000 TUBING Original 41/2 3.000 9,147 9,161 5,764 Com letion Details Top Depth (ND) Top Incl Too (ftK8) (ftK8) (°) Item Description Comment ID (In) TOO IHKBI ( K ) To(°)ncl Descriotlon Run Date ID (In) Comment Btm seal @ 9380' Perforations 8 Slots snot Top (ND) Btm (ND) Dens Too (itKe1 etm fftK81 (ftK8) (ftK8) Zone Date (sh... Type Comment - (ND) Incl OD Valve Latch Slze TRO tool Stn Too !(tKBI (ftK8) (°) Make Model (In) Serv Typa Type (In) (pgl Run Date Lomm... Time Log & Summary ConocoPhiilips ~y~,r„;~w w~b ~e~o~,~Q Report - - -- - -- _ Well Name: 3G-26 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 12/30/2008 1:00:00 PM Rig Release: 1/10/2009 11:59:00 PM Time LocJs _ . _. _ Date From To Dur S. Deoth E Depth Phase Code Subcode T Comment __ _ 12/29/2008 2a hr summary Move Nordic 3 from 2K-22 to CPF 2 11:00 17:30 6.50 COMPZ MOVE MOB P Move Nordic 3 from 2K-22 to CPF 2 . 17:30 19:00 1.50 COMPZ MOVE WOCC NP Standby w/ rig crew for CPAI Feild Crew chan e 19:00 00:00 5.00 COMPZ RIGMN7 RGRP NP Change tire on boggles 12/30/2008 Continue to move Nordic 3 from CPF 2 to 3G-26, spotted rig and equipment, loaded pits with 9.6 ppg brine, circulated out diesel, ND tree, started NU of BOP. 00:00 04:00 4.00 COMPZ MOVE MOB P Move rig from CPF 2 to 1Q Pad. 04:00 07:00 3.00 COMPZ MOVE WOCC NP Standby w/ rig crew for CPAI Feild Crew chan e. 07:00 13:00 6.00 COMPZ MOVE MOB P Move rig from 1Q Pad to 3G Pad. 13:00 20:00 7.00 COMPZ MOVE PSIT P Spot rig over well, set up handy-berm, spot tanks and mud shack, Ru hardline to kill tank, Ru circ hoses, load pits with 9.6 brine, ull BPV tb ressure = 300 si IA = 300 si OA = 0 psi. Nordic Rig 3 acre ted at 13:00 hrs. 20:00 21:30 1.50 COMPZ RPCOM CIRC P PJSM, pressure test hardline, pumped 50 bbls 9.6 brine down IA taking returns up tbg to clear diesel, pumped 100 bbls down tbg until good 9.6 ppg returns at 3 bpm - 660 psi, shut down and checked for flow,.well~ 21:30 22:00 0.50 COMPZ RPCOM RURD P Blew down all circ and hardlines, set BPV. 22:00 23:00 1.00 COMPZ RPCOM NUND P ND tree. 23:00 00:00 1.00 COMPZ RPCOM NUND P NU 13 5/8" BOP. 12/31 /2008 NU BOP, test BOPE. Test witnessed by Jeff Jones - AOGCC Inspector. Ru and attempt to pull hanger to floor, call out and RU SWS a-line, RIH and fire strin shot at 9,141', POOH and MU them cutter, start RIH. 00:00 02:00 2.00 COMPZ RPCOM NUND P Cont NU 13 5/8" BOP stack. 02:00 05:00 3.00 COMPZ WELCTL BOPE P RU test equipment, tested BOPE at 250/3,850 psi. Tested annular at 250/3,500 si. 05:00 06:00 1.00 COMPZ WELCTL BOPE T Pull blanking plug, Change out ball. 06:00 08:00 2.00 COMPZ WELCTL BOPE P Continue BOP test. 08:00 11:00 3.00 COMPZ WELCTL BOPE T Repair leak in choke manifold. Chan a out seal rin . ~ ~~ ParJ~ 1 s~f ~~7 a Time__Logs _ Date From To Dur S. De th E. De t_h_ Phase Code Subcode T Comment 11:00 13:00 2.00 COMPZ WELCTI BOPE P BOP test complete. Pull blanking & BPV. Pressure under BPV. Rig up to circulate hole volume. Test witnessed by AOGCC (Jeff Jones 13:00 14:30 1.50 COMPZ WELCTL CIRC P Circulate hole volume, monitor well. 14:30 15:00 0.50 COMPZ RPCOM PULD P Make up landing joint and circulating hose. 15:00 18:30 3.50 COMPZ RPCOM PULD P Attem t to ull seal assembl from PBR work up to max pull weight of 200k, continue to work pipe till SLB E-Line arrival. 18:30 22:30 4.00 COMPZ FISH ELNE P RU SWS a-line, PJSM, RIH with strin shot to to of 6' u 'nt at 9 141'. Corelate de th and fir rin OOH LD tool. 22:30 00:00 1.50 COMPZ FISH ELNE P MU chemical cutter, RIH. 1 /01 /2009 Cut tubing, POOH RD SWS, attempt to pull hanger to floor, RU SWS and find free point, POOH, MU and RIH with strip shot and set off at 6,215', POOH, MU chem cutter, wait on wireline ~ars. 00:00 03:30 3.50 COMPZ FISH ELNE P Cont RIH with chemical cutter on e-line, could not get below 6,950', attempted to pump tool down at 2 1/2 bpm - 230 psi with no success, POOH to add weight bar and remove one centralizer. Rig crew racking and tall in PH6 workstrin . 03:30 05:30 2.00 COMPZ FISH ELNE T RIH with chemical cutter on a-line to 5,000', had indication of electrical short to the tool assembly, POOH to troubleshoot electrical problem. Firing head had fluid in it, cleaned up and CO dam ex losive. 05:30 06:30 1.00 COMPZ FISH ELNE P RIH with chemical cutter on a-line, correlate depths and make cut in 6' tb u at 9 144' WLM, 6' pup located on to of seal assembl . 06:30 08:30 2.00 COMPZ FISH ELNE P Release cutting tool anchors, POOH, RD SWS and um in sub. 08:30 09:30 1.00 COMPZ FISH WOEQ T Wait on arrival of free point tools. Recieved call for AOGCC inspector about BOP test. Decision made to retest annular and lower kill choke. 09:30 11:30 2.00 COMPZ WELCTL BOPE T Retest annular 250!3500 psi and LKC's 3,7,9,10. Good test. .... ~ ®~ _ ~~~ ~ ~f 1~ r~ Time Logs _ _ Date From To Dur S Depth E_ De th Phase Cade Subcode T Comment I 11:30 19:00 7.50 COMPZ FISH ELNE T PJSM. Rig up SLB E-Line for free point. First stop 997'MD 100 % pipe movement, 2300'MD 98% pipe movement, 4498'MD 87% pipe movement, 4527'MD 75% pipe movement, 4637'MD 73% pipe movement, 4777'MD 62% pipe movement, 5072'MD 55% pipe movement, 5666'MD 53% pipe movement, 6797'MD 35% pipe movement, and one at cut depth of +/- 6200'MD 51 % i e movement. POOH free oint tools. 19:00 22:30 3.50 COMPZ FISH ELNE T RU and RIH with string shot to 6,300' WLM. Correlate depths and perform strin shot in first full 'oint at 6 215'. POOH LD string shot tool. POOH LD strin shot. 22:30 00:00 1.50 COMPZ FISH ELNE T MU chemical cutter assembly and wait on wire-ine 'ars to be delivered. 1 /02/2009 RIH with cutter and cut string at 6,215', POOH RD SWS, pull hanger to rig floor, CBU, decomplete well, PU sin le in hole with overshot on PH6 and en a e fish at 6,220', CBU and um ed 15 bbl hi-vis swee . 00:00 02:00 2.00 COMPZ FISH ELNE T RIH with chemical cutter, correlate depths and cut tubing at 6,215', POOH and RD SWS. 02:00 03:00 1.00 COMPZ RPCOM CIRC P RD pump in sub, MU circ head, pull hanger to rig floor 67K up weight, CBU 5 b m - 700 si. 03:00 11:30 8.50 6,215 0 COMPZ RPCOM PULD P LD landing jnt and hanger, POOH LD 3 1/2" completion, strapping tbg and jewelry before off-loading from rig. On surface with 6,215' tubing, clean chemical cut. 11:30 13:00 1.50 0 0 COMPZ RPCOM RURD P Install wear ring. PJSM. Cut and Slip drill line. Change handling e ui ment. 13:00 15:00 2.00 0 382 COMPZ FISH PULD T Make up Baker fishin BHA. 4 11/16" overshot, bumper sub, super jar, pump out sub, crossover, 12 3 1/8" DC's, crossover to PH-6. 15:00 22:00 7.00 0 6,200 COMPZ FISH TRIP T PU and single in hole with fishing BHA on 3.5" PH-6 to 6,200' and obtain parameters. Break circ at 2 b m - 400 si. 22:00 00:00 2.00 6,200 6,190 COMPZ FISH FISH T Up weight 85K, down weight 71 K, ease in hole and engage fish at 6,220'. PU to 200K and jar one time, PU to 200K and hold, string weight dropped to 100K, cont PU to 200K and hold, cont to work string and jar on fish one more time. String moving but dragging, pulled one full joint above table and up pump rate to 5 bpm - 2600 psi, mix and pump 15 bbl hi h vis swee . .~ m °~ E~~a~ ~ s~f ~D ~~ Time Logs I Date From __To Dur____ S Depth E._~th Phase Code Subcode T Comment I 1 /03/2009 2a hr summary POOH standing back PH6, RU and cont POOH LD 3 1/2" tubing to original chemical cut, re-dress overshot and RIH to 9,144', CBU, engaged fish and pulled seals out of PBR, CBU, POOH standing back 3 1/2" PH6 from 9,132'to 1,321'. 00:00 01:00 1.00 6,190 6,190 COMPZ FISH CIRC T Circ out sweep while reciprocating strin . 01:00 06:00 5.00 6,190 2,929 COMPZ FISH TRIP T LD 1 joint PH6, blow down top drive, POOH standing back 3 1/2" PH6 and DC's, LD jars, bumper sub and overshot. 06:00 11:00 5.00 2,929 0 COMPZ FISH PULL P CO elevators, cont POOH LD 3 1/2" EUE tubing and jewelry. Started noticing some pitting on tubing and collars from 8,650'MD and below. On surface with cut tubing, tubing cut clean. 11:00 13:00 2.00 0 0 COMPZ FISH RURD P Kick out tubing. Clean rig floor. Redress overshot. Make up second BHA, same as revious run. 13:00 19:30 6.50 0 9,144 COMPZ FISH TRIP P RIH in hole with second fishing BHA on 3.5" PH-6 from derrick to 6,275', cont RIH with singles from pipeshed to 9,121', break circ at 2 bpm - 350 psi, up weight 112K, down weight 83K, increase pump rate to 5 bpm - 2,100 si d wash down to 9,144'. 19:30 20:00 0.50 9,144 9,144 COMPZ FISH CIRC P Pump hi-vis sweep at 6 bpm - 2,800 psi and had good amount of sand at bottoms u . 20:00 20:30 0.50 9,144 9,144 COMPZ FISH FISH P Reduce pump rate to 2 bpm - 350 psi, wash down over tubing stub, shut down pump, and engage fish. PU to 150K and fish ulled free,. break circ at 2 bpm - 350 psi and slacked off until pump pressure increased, shut down pump and pressure holding, PU approximately 2' and ressure bled off. 20:30 21:00 0.50 9,132 9,132 COMPZ FISH CIRC P CBU at 6 bpm - 2,800 psi. 21:00 00:00 3.00 9,132 1,321 COMPZ FISH TRIP P POOH standing back 3 1/2" PH6 from 9,132'to 1,321'. 1 /04/2009 Cont POOH and LD seal assembly, MU cleanout BHA, RIH and reverse circ last 3 stands in hole to 9,147', reverse circ 2 tubing volumes, POOH stand back 3 1/2" PH6, finish rack and tally 3 1/2" IBT completion strin , RU and PU RIH with com letion strin to 2,900'. 00:00 01:30 1.50 1,321 0 COMPZ FISH TRIP P Cont POOH from 1,321' and LD overshot assembly, seal assembly and tubin stub. 01:30 02:00 0.50 0 392 COMPZ RPCOM OTHR P MU cleanout assembly. ~~ t'a~;~ '~ ~~ 1 fl r~ Time Logs - _ Date From To Dur S. Dew E. Depth Phase Code Subcode T Comment __ _ ___ 02:00 12:00 10.00 392 9,147 COMPZ RPCOM TRIP P RIH with cleanout assembly on 3 1/2" PH6 from derrick and simop rack and tally 3 1/2" IBT completion string. Continue in hole to 8,905' MD, Kelly up and reverse circulate @ 5 BPM 1,740' psi, RIH to 8984'MD, Kelly up, and reverse circulate @ 5 BPM 1,900 psi, RIH to 9,093'MD, Kelly up and reverse circulate @ 5.5 BPM 1,870 psi. RIH, tag up at 9 147', P/U 6" and reverse circulate , pump sweep, minimum sand return. Monitor well. 12:00 19:00 7.00 9,147 0 COMPZ RPCOM TRIP P POOH LD first 69 joints PH6, rack back remaining 71 stands in derrick for next well, LD DC's and cleanuot BHA. 19:00 21:00 2.00 0 0 COMPZ RPCOM RURD P Load Baker tools, RU floor to run 3 1/2"IBT com letion ull wear rin . 21:00 00:00 3.00 0 2,900 COMPZ RPCOM RCST P PJSM, MU seal assembly, PU and single in hole with 3 1/2" IBT-Mod tubin to 2,900'. 1 /05/2009 Cont PU RIH with 3 1/2"IBT completion from 2,900' to 9,147', attempt to no-go locator, could only get 6' of down stroke after pressure increase indicated seal assembly entering seal bore, started POOH then ran back to bottom to test casing, casing leaking off, POOH stand back 3 1/2" tubing, MU 2 7/8" 12' muleshoe on 5 1/2" test acker and start RIH on PH6 from derrick. 00:00 05:00 5.00 2,900 9,135 COMPZ RPCOM RCST P Cont PU and single in hole with 3 1/2" IBT Mod tubing from 2,900' to 9,135'. 05:00 08:00 3.00 9,135 9,147 COMPZ RPCOM HOSO T MU circ hose, pump at 1/2 bpm and ensured seals enterin PBR, shut down pump, opened bleeder and tagged with only 6' of down stroke, appears to be fill in PBR, repeated process with same results, applied 200 psi on tubing, PU to string weight of 90K plus 6' and lost pressure, rolled pump at 1 bpm and stung into seal bore, obtained pressure increase and tagged with 6' down stroke, called Well Engineer and decision made to test IA to 2,500 psi, pressure fell off 900 psi in 15 mins. Sheared 1" SOV when PT the IA. 08:00 11:30 3.50 9,147 9,125 COMPZ RPCOM DHEO T POOH with 3.5" completion to 8,500'MD. Decision made to retest IA from town. RIH to 9,125'MD. 11:30 13:00 1.50 9,125 9,125 COMPZ RPCOM CIRC T Circulate hole volume, 9.6 ppg in & out. 13:00 14:30 1.50 9,125 9,125 COMPZ RPCOM DHEO T Attempt to test WRP/Packer to 2,500 psi. Unable to get pressure to 2,500 psi. 2,100 psi @ .75 BPM leak rate, shut down pump, pressure bleeding off. Bleed off pressure. Shuffle PH-6 in derrick. Payrt a rsi 1~ !• Time Logs Date From To Dur S De th E De th Phase Code Subcode T_ _Comment 14:30 22:30 8.00 9,125 0 COMPZ RPCOM TRIP T POOH racking back 3.5" completion. Pulling slow as rig is on one gen set due to fuel conservation. 22:30 23:00 0.50 0 0 COMPZ RPCOM OTHR T Cut a 2 7/8" 'oint to 12' for mule shoe, set wear rin . 23:00 00:00 1.00 0 22 COMPZ RPCOM TRIP T PJSM, MU 2 7/8" 12' mule shoe joint on bottom of "45-A4" 5 1/2" Model EA retrievamatic test acker. 1 /06/2009 RIH on PH6 with test packer. Pressure test casing below 9082' to 2500 psi. Held good. Pressure test casing above 8630' to 2500 psi. Held good. Determined bad 5 1/2" casing between 8630' & 9082'. Leak taking 1 bpm @ 2200 psi. Reverse circulated and washed down to 9,165' to clean out PBR, POOH LD 15 jnts PH6, slipped and cut drill line at 8,725', cont POOH rack back stands to 2,270'. 00:00 07:30 7.50 22 6,554 COMPZ RPCOM TRIP T Cont RIH with retrievamatic on PH6 from derrick 70 stands to 6,554'. 07:30 08:00 0.50 6,554 6,554 COMPZ RPCOM DHEQ T Set test acker and tested 5 1/2;' casin to 2,500 si from surface to 6,554', ood test. 08:00 10:00 2.00 6,554 8,586 COMPZ RPCOM TRIP T Cont PU and single in hole from 6,556' to 8,586'. 10:00 10:30 0.50 8,586 8,586 COMPZ RPCOM DHEQ T Set test Hacker and tested 5 1/2" casin to 2.500 psi, from surface to 8 586' ood tesf. 10:30 12:00 1.50 8,586 8,894 COMPZ RPCOM DHEQ T Cont PU and single in hole from 8,586' to 8.894' leaked. Pumped into hole 2,200 psi @ 1 BPM. Switch and pumped down drillpipe, tested to 2,500 si leaked at same rate. 12:00 13:30 1.50 8,894 9,082 COMPZ RPCOM DHEQ T Bled off pressure. Circulated 5 bbls around to keep top drive from freezing. Released test packer, RIH to 9,114' to center element and stinger 5' above PBR. Pressure test below test packer to 2,500 psi. ood test. Bled off pressure. PU to 9.082'. Tested below to 2 500 si ood test. PU to 9,051' attempted to test below, leaked off. Pumped into leak @ 2 200 si w/1 BPM. Bottom interval of hole between 9 082' & 9 051'. 13:30 15:00 1.50 9,082 9,082 COMPZ RPCOM DHEQ T Bled off all pressure. POOH to 8,630' ressure test to 2,500 psi good test. Bled off pressure, lowered test packer to 8,670', pressured to 2,500 leaked off 500 si in less than 1 min. Determined bad 5 1!2" casing between 8,630' & 9,082'. 15:00 17:00 2.00 9,082 9,165 COMPZ RPCOM CIRC T RIH to top of PBR, lowered stinger into PBR tagged @ 9,159' washed down to 9 165'. Pumped 15 bbl Hi-Vis swee ,circulated hole clean. 17:00 18:00 1.00 9,165 8,725 COMPZ RPCOM TRIP T POOH, laid down 15 jts 3-1/2' PH6 drill i e. 18:00 20:00 2.00 8,725 8,725 COMPZ RIGMNT SVRG T Slip & Cut drill line, clear floor and re to POOH. ~~ ~~® ~ ~ F~ar~~ ~ of ifl Time Logs ___ _ Date From To Dur S. Depth E. De th Phase Code Subcode T Comment __ i 20:00 00:00 4.00 8,725 2,270 COMPZ RPCOM TRIP T Cont POOH with retrievamatic test packer and mule shoe joint on 3 1/2" PH6, racking back in derrick. From 8,725' to 2,270'. Up weight 50K, down wei ht 48K. 1!07/2009 Cont POOH LD test packer, CO element in annular, RU and test BOPE at 250/3,850 psi and annular at 250/3,500 psi. Test witnessed by Lou Grimaldi - AOGCC Inspector. PU RIH with FAB packer assembly to 4, 952'. 00:00 01:30 1.50 2,270 0 COMPZ RPCOM TRIP T Cont POOH with test packer from 2,270', LD mule shoe 'nt and acker. 01:30 02:00 0.50 0 0 COMPZ RIGMNT SFTY T PJSM with crew on change out of annular element. 02:00 08:00 6.00 0 0 COMPZ RIGMNT RGRP P Drain BOP stack, ND riser, RU and,- break cap on annular, CO element, MU cap and function test annular. NU riser. 08:00 16:30 8.50 0 0 COMPZ WELCTL BOPE P Test BOPE 250/3850 psi and Annular 250/3500 psi. Some trouble with annular test. New element hard to seal off. BOP test witnessed by AOGCC Rep Lou Grimaldi. RD test e ui ment. Clear ri floor. 16:30 17:00 0.50 0 0 COMPZ RPCOM OTHR T Set wear ring. RU tools for RIH with acker. 17:00 00:00 7.00 0 4,952 COMPZ RPCOM RCST T MU seal assembl 2.812" DS nipple, RIH on 19 joints 3 1/2" IBT, MU FAB acker and settin to I, RIH on 3 1/2" PH6 drill pipe from derrick to 4,952', up weight 73K, down wei ht 65K. 1 /08/2009 Cont RIH with FAB packer assembly, locate and no-go seal assembly, attempted to test tubing to 500 psi but getting returns, decision made to POOH, tested setting tool on surface and found source of leak, CO runnin tool and tested on surface, PU and RIH with FAB acker assembl to 4,960'. 00:00 03:30 3.50 4,952 9,125 COMPZ RPCOM RCST T Cont RIH with FAB packer assembly on 3 1/2" PH6 from 4,952' to 9,125'. 03:30 04:00 0.50 9,125 9,125 COMPZ RPCOM CIRC T Apply steam to topdrive to warm up wash-pipe before circulating, grease wash-pipe and circ through topdrive with charge pump to ensure wash-pipe does not leak, kelly upon jnt # 273, up weight 106K, down wei ht 80K. ~~____.~ ~~ _ ~ F'ag~: 7 of 1b ~~ Time Logs _ _ _ _ _ _ Date From To Dur S De th E._De th Phase Code Subcode T Comment 04:00 07:00 3.00 9,125 9,168 COMPZ RPCOM HOSO T Roll pump at 1/2 bpm, ease down into seal bore and verify seals entering PBR, open bleeder, PU joint #274, no-go'd with MS guide at 9,168', PU to neutral +2', attempt to test tb at 500 si, ettin returns and pressure bleeding off, bleed off eased down and no-go's seal assembly, attempt to pressure test to 500 psi, still getting returns and bleedin o PU and attempt test with 5' of seals in bore, getting returns, PU and attempt test with 2' of seals in bore, still getting returns, PU out of PBR and circ at low rate while discussing op's with wells en ineer. 07:00 12:30 5.50 9,168 0 COMPZ RPCOM PULD T POOH standing back work string'. LD packer and running tool. Pull and stand back 3 1/2" IBT tubing and LD seal ass .for ressure testin . 12:30 13:30 1.00 0 0 COMPZ RPCOM OTHR T Plu ed end of acker and running tool, NU test pump. Attempt to pressure test. Turned water on with no pump and water flowed freely thru "Ada for Nut" on the settin tool. Broke down setting tool and found that the setting tool adaptor is for a smaller bore packer than the 5 1/2" FA acker. 13:30 18:30 5.00 0 0 COMPZ RPCOM WOEQ T Wait on Baker running tool with ro er adaptor. Redress running tool. MU test plug and test pump, test running tool assembly at 250/500 si, ood test, RD test a ui ment. 18:30 00:00 5.50 0 4,960 COMPZ RPCOM RCST T MU seal assembly, XO's and DS nipple, RIN with 19 jnts 3 1/2" IBT to 628', MU FAB packer, running tool and bumper sub, XO and cont RIH on PH6 drill pipe from derrick to 4,960', u wei ht 73K, down wei ht 65K. 1 /09/2009 Cont RIH with FAB packer assembly, locate and no-go seal assembly, test tbg to 500 psi, spot corrosion inhibitor, drop ball and set packer, test IA to 3,000 psi, shear ball seat and POOH LD 69 jnts PH6 and stand back 70 stands PH6. 00:00 03:30 3.50 4,960 9,134 COMPZ RPCOM RCST T Cont RIH with FAB packer assembly on PH6 from 4,960' to 9,134'. 03:30 04:15 0.75 9,134 9,134 COMPZ RPCOM CIRC T Apply steam to topdrive to warm up wash-pipe before circulating, grease wash-pipe and circ through topdrive with charge pump to ensure wash-pipe does not leak, kelly up on jnt # 273, up weight 106K, down wei ht 80K. I~~cd~ ~ rsf 1t~ Time Logs ___ Date_ _ From To Dur S. Depth E. Depth Phase Code Subcode__T Comment __ _ _ 04:15 04:30 0.25 9,134 9,165 COMPZ RPCOM HOSO T Roll pump at 1/2 bpm, ease down into seal bore and verify seals enterin PBR, open bleeder, no-go'd with MS guide at 9,167', locator at 9,156', PU to neutral +2', test tbg at 500 si, no returns and ood test. 04:30 05:30 1.00 9,165 9,153 COMPZ RPCOM CIRC T Test tbg at 500 psi for 5 minutes, PU out of PBR, spot 25 bbls corrosion inhibitor with 5 bbls left in workstring at 2 b m - 260 si, bleed off. 05:30 06:30 1.00 9,153 9,153 COMPZ RPCOM PACK T Break off joint, drop 1 7/16" ball and allow to dro , 06:30 08:30 2.00 9,153 9,132 COMPZ RPCOM PACK T With charge pump,attempted put ball on seat, ball would not seat. RIH and tag up with seal assembly. PU to 2' mark. Applied 3,000 psi against the WRP to set acker .pulled 22K over string wt. Packer set @ 8,532'. Slacked back off to neutral and bled pressure to 0. Set down 5K wt on packer. Pressured IA to 3,000 psi and held solid for 15 min. Bled pressure off. PU and opened Bumper Sub, rotated 15 turns to right to release settin tool from acker. 08:30 10:00 1.50 9,132 7,400 COMPZ RPCOM PULD T POOH laying down first 69 jts of PH6 workstring. Stopped at 7,400' due to ball finally getting on seat. RU head pin and hose to open ball seat. Pressured up to 4,000 psi opened ball seat. RD hose and head in. 10:00 15:00 5.00 7,400 0 COMPZ RPCOM PULD T Continue POOH standing back workstrin for next welt. 15:00 16:00 1.00 0 0 COMPZ RPCOM PULD T Brake out and LD running tool. Kick out beaver slide to truck. Remove wear ring. RU rig floor for running com letion. 16:00 00:00 8.00 0 8,520 COMPZ RPCOM RCST T PJSM. RIH with completion assembl from derrick consisting of Baker KBH-22 anchor seal assembly, PBR, 4 GLM and 2.875" 'DS' Nipple. MU joint #271 at 8,520', up weight 82K, down wei ht 67K. 1/10/2009 Latch anchor assembly into FAB packer, shear out PBR, space out, spot corrosion inhibited seawater, RU slickline and install dummy valve in lower GLM, test tbg and csg, install BPV, ND tree, NU BOP, test tree, freeze rotect well, RDMO well. 00:00 01:00 1.00 8,528 8,480 COMPZ RPCOM HOSO P Locate and latch anchor assembly into top of FAB packer 5 1/2' in on joint #271= 8,528', pulled 10K to verify latch, pulled to 126K (44K over) and sheared out of PBR, rolled pump at 1/2 bpm and ensured seals entering PBR, bled off, no-go'd with seals at 8,520', obtained space out, MU hanger, landing joint and 6' pup, installed circ hose. Page ~f 1 t} r~ Time Logs _ - - Date From To Dur S. De th E Depth Phase Code Subcode T Comment __ ~ 01:00 02:00 1.00 8,480 8,480 COMPZ RPCOM CIRC P Pumped 10 bbls 8.6 ppg, 155 bbls corrosion inhibited seawater off vac t ruck then chased with 10 bbls 8.6 to clear pump and lines at 5 bpm - 1,180 si. 02:00 02:30 0.50 8,480 8,519 COMPZ RPCOM HOSO T Drain stack, land hanger, up weight 82K, down weight 67K, seal assembly mule shoe guide set at 8,518.93', RILD's. 02:30 07:00 4.50 8,519 8,519 COMPZ RPCOM HOSO T RU and attempt to test 3 1/2" IBT tubing at 3,000 psi for 15 minutes, ettin communication to IA, pull hanger to floor and LD, PU 1 joint and pup, MU head pin and circ hose, roll pump at 1/2 bpm and had~c~ood indication of seals entering PBR, no-go seal assembly, RU and attempt to pressure up on IA, had immediate communication u the tubin ,called Well Engineer and decision made to re-land han er and call out slickline, MU hanger, pup, and landing joint, drained stack, land han er. 07:00 12:00 5.00 8,519 COMPZ RPCOM SLKL T PJSM. RU slickline. RIH and pull sheared SOV from bottom GLM @ 8461'. RIH and set dummy valve in same GLM 8461'. 12:00 13:30 1.50 COMPZ RPCOM DHEO P RU test equipment. Test tubing to 3000 si for 15 min. Good test. Test IA to 3000 psi for 30 min. Good test. Chart both. RD test a ui ment. 13:30 14:30 1.00 COMPZ RPCOM SLKL T RIH with slickline and pull dummy valve from #1 GLM @ 3311'. RD slickline. 14:30 15:30 1.00 COMPZ RPCOM NUND P Set BPV. 15:30 19:30 4.00 COMPZ RPCOM NUND P ND BOP, oriented tree same as tree that came off. NU tree. (DS Facility Eng. Brandon Locke declined to witness . 19:30 21:30 2.00 COMPZ RPCOM FRZP P RU LRS, tested lines and tree to 5,000 psi for 10 minutes, tested hardline to kill tank, pulled t_ est plug, pumped 70 bbls 50 degree diesel down IA, taking returns up tbg to kill tank at 2 bpm - 600 psi. Shut down, RD and blew down circ lines and hardline. 21:30 00:00 2.50 COMPZ RPCOM RURD P Installed BPV, cleaned cellar, removed hardline from rig, moved mudshack and tanks for rig move, installed tree hardware, RDMO well 3G-26, removed T mats and liner, cleaned cellar box. Released Nordic Ri 3 at 23:59 hrs 1/10/2009. SITP=O si, IA=O si, OA=O si. ~~ ~ ~'aqe 1 ~ of 10 • • ~_..', ~'. ; A t,.~.,..~ dl ~'~ '' ~..a a df +d A1~1 €-;._ ~ A~;~ ~~' i ~; ~ ~ ~\\ trj~ ,,,~A 1;° SARAH PAL1N, GOVERNOR ALASSA OIL A1~TD GAS ~' 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQATI011T COMI1i15SIO1~T ,'~~~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Howard Gober Wells Engineer ConocoPhillips Alaska Inc. ~~~~ 4iA~ ~Q~ PO Box 100360 Anchorage, AK 99510 ~~' Re: Kuparuk River Field, Kuparuk Oil Pool, 3G-26 ~`~~ Sundry Number: 309-002 Dear Mr. Gober: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~ day of January, 2009 Encl. ~ ~g-~ ~11fE~ q ~ STATE OF ALASKA • t 1 ALASKA OIL AND GAS CONSERVATION COMMISSION JAN Q 7 200 ~- ~~ APPLICATION FOR SUNDRY APPROV~;~~ . ~ ~a 0i1 ~ Gas Cons. COmmiSSlOfi?! 20 AAC 25.280 „ _ _L _ __ _ _ 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver Other ^ Alter casing ^ Repair well ^/ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing Q Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilllps Alaska, InC. Development Q • Exploratory ^ 199-075 • 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20303-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? Y@S ^ NO ^~ 3G-26 - 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25547 RKB 30' Kuparuk River Field /Kuparuk Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9850' 6388' 9754' 6295' 9180' Casing Length Size MD TVD Burst Collapse CONDUCTOR g0' 16" 110' 110' SURFACE 4314' 7-5/8" 4344' 3051' PRODUCTION 9295' 5-1/2" 9325' 5903' PRODUCTION 687' 3-1/2" 9848' 6386' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9362'-9377', 9502'-9516', 9530'-9545' 5935'-5948', 6058'-6070', 6083'-6066' 3-1/2" L-80 9161' Packers and SSSV Type: Packers and SSSV MD (ft) Baker SABL-3 pkr @ 9161' Camco DS nipple @ 532' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat January 7, 2009 Oil ^~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: ~~'""~C~ WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: ~~ 18. I hereby certify that the foregoing is true an correct to the best of my knowledge. Contact: Howard Gober @ 263-4220 Printed Name HOWard Gober Title: Wells Engineer Signature Phone 263-4220 Date (l Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~~ (' ~ ~ ' Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~. ,I~~ 2 1 2009 Subsequent Form Required: ~ t--~ ~\ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 10-453 Revised 06/2006/ 'Submit in,(Duplicate 4 ~ • ConocoPhillips ~~~ P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 6, 2009 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7t" Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Producing Well 3G-26 (PTD 199-075). 3G-26 had a tubing leak that could not be repaired with a patch. It was decided to work the well over. During pre-rig diagnostics a combo MIT to 2500 psi was performed on 12/23/08 to check the casing integrity. Since the test was good, the workover was planned without submitting a 10- 403. The rig was moved in on 12/29/08 to begin the workover. The work was progressing toward the planned objective of replacing the tubing until the casing was pressure tested on 1/5/09. Unfortunately, the casing did not hold pressure. A test packer was run, and on 1/6/09, and the casing leak was isolated to 8630'-9082' RKB. Above and below this interval the casing will hold a 2500 psi pressure test. As outlined in the attachments, CPAI would like to isolate the casing leak with a straddle packer assembly. Prior to landing the straddle packer assembly, corrosion inhibited fluid will be spotted in the annulus between the packers. Since the rig is currently on the well, CPAI requests approval to proceed at your earliest convenience. If you have any questions or require any further information, please contact me at 263-4220. Sincerely, Howard B. Go er Wells Engineer CPAI Drilling and Wells • Kuparuk 3G-26 General Workover Procedure Current Status The workover is currently underway. Since the casing had passed a pressure test during .pre- rig diagnostics, the workover was begun without applying fora 10-403. To date, work that has been accomplished is: 1. MIRU 2. Pull BPV. Circulate diesel out of well with 9.6# brine. Set BPV. 3. ND tree. NU 13-5/8" BOP. Test BOPE to 250/3850 psi and annular to 250/3500 psi. Test witnessed by Jeff Jones - AOGCC 4. Attempt to pull tubing, but it would not come free. 5. RU Schlumberger. Chemical cut tubing at 9144' RKB. Tubing would not pull free. 6. Run free point tool. Chemical cut tubing at 6215' RKB. 7. POOH with tubing and lay down. 8. RIH with overshot on 3-1/2" PH6 workstring. Engage fish and POOH with tubing down to first chemical cut. 9. RIH with overshot on workstring. Engage pup joint above seal assembly. POOH with pup joint and seal assembly. 10. RIH with scraper and circulate hole clean. 11. RIH with new 3-1/2" completion. Seal assembly would not travel to the bottom of the seal assembly. 12. Pressure test IA. Able to pump 3/ bpm at 2100 psi. Notify AOGCC of casing leak. 13. RIH with test packer and 2-7/8" stinger below. Casing tests good to 2500 psi above 8630' and below 9082' RKB. Plan Forward Major steps: 1. POOH with work string and test packer. 2. Perform weekly BOP test to 250/3850 psi and the annular to 250/3500 psi. 3. RIH with straddle packer completion consisting of seal assembly to stab in to original PBR, 3-1/2" tubing, and Baker FAB packer. Run assembly on work string. Stab in to PBR. Pick up and spot corrosion inhibited brine. Space out and set packer @ +/- 8530' RKB. Release setting tool and POOH. 4. RIH with Baker K anchor and PBR on new 3-1/2" gas lift completion 5. Locate FAB packer. Latch anchor into packer. Pressure test annulus to 3000 psi. Bleed off and shear PBR. Space out and make up hanger. Load tubing and IA with corrosion inhibited fluid. 6. Land hanger and run in lock down screws. Bleed down pressure in tubing to 2000 psi on chart recorder. Pressure test tubing to 3000 psi for 15 minutes. Pressure test annulus to 3000 psi and record 7. Shear SOV. Set BPV. ND BOP Stack. 8. NU tree. Pull BPV. Set tree test plug. Pressure test tree to 250\5000 psi. Test packoff to 250\5000 psi. Pull tree test plug. Freeze protect well. Set BPV. 9. RDMO Nordic 3. • • Post-Rig Work: Pull BPV. 2. RU slickline. Pull SOV and install new gas lift design. Pull catcher sub. Pull WRP. 3. Return to production. -~~ r- KUP a 3G-26 ~ f~1,. `i C~~lmi l~ll~p5 to Well Attribut es ___ Max Angle 8 MD TD ° A~ t,N i Wellbore APVUWI Fieltl Nama Well Status ProNlnj Type ) MD (ftKB) Acl Btm (fiK8) Inc! ( I ` ' 501032030300 KUPARUK RIVER UNIT (PROD 5,34446 9.8500 60.74 Comment H25 (ppm) Annotation End Date Date Rig Release Dati KB-Grtl (ft) ?7/8ar2~uu xsaa ,v -- ~ G26 ° 6 SSSV~NIPPLE 100 ( ( ( ( 7/1/2008 Last WO: ( 34.99 8/20/1999 ®II. snb . ~,- _. Schema4ic Act .H Annotaton ( Depth (ftKB) End Data ( Annotation (End Date Last Tao SLM 9.521.0 10/29!2008 Rev Reason: GLV C/O SET PLUG 12/25/2008 CONDUCTOR. no NIPPLE. 532 SURFACE, a.3se GAS LIFT. 6.1]6 GAS LIFT, 1,693 GAS LIFT, 8.661 GAS LIFT, 9,055 NIPPLE, 9,107 SEAL, 9,16] PACKER. 9.161 PL UG. 9,180 PRODUCTION, 9.325 NIPPLE. 9.360 SLEEVE-C, _~ 9,360 APERF, 9,362-9,3J7 -- NIPPLE.9.380- (CONDUCTOR 16 15.062 0.0 110.0 110.0 62.58 H-40 WELDED SURFACE 7 5/8 6.750 0.0 4,344.0 3,051.2 ! .b(t t$0 BTC-MOD ~~PRODUCTION S 1721 4.950 ~ 0.0 9,325.0 5,903.4 .~'rL2Y.90'L-80 7 BTC-MOD PRODUCTION 3 1/7 2.992 6,386.4 9.20 L-80 9,161.0 9,848 0 BTC-MOD Tubing Strings _ String OD String ID _ _ Sat Depth Set Depth (ND) String Wt String Tubing Descnp[ion (in) (in) Top (ftKB) (ftKB) (ftKB (Ibs/ft) Grede J Slnn To p ) Thrd TUBING 3 1/2' 2.992 0.0 9,161.0 5 763.7 9.301E-80 111 IEUE 8rd ~ Other In Hole All Jewel : Tubin g Run & Retrievable, Fish etc. Top Depth - ~ (TVD) Top Inc! ~ I T~(ftK8) (ftKB) (°) '' Description Comment Run Data ~. ID (in) 532.0 5304 10.10~ NIPPLE ~CAMCO DS NIPPLE 8/19/1999 2812 3,936.0 2,836.0' 57.22 GAS LIFT CAMCO/KBG-2-9/1lOMY/INTlO Comment STA 1 12/23/2008 ~ 2.900 6,176 0 3,996.1 ~ 59.01 GAS LIFT ;CAMCO/KBG-2-9/1/DMY/INT///Comment: STA 2 12/23/2008 1 2.900 7,693.0 4,786.61 59.07 GAS LIFT ~CAMCO/KBG-2-9/1lDMY/INT///Comment STA 3 12/22/2008 2900 8,641.0 5,347.7 1 45.26 GAS LIFT CAMCO/KBG-2-9/1/DMY/INT/// Comment: STA 4 12/23/2008 2.900 9,0550 5,673J ~ 32.14 GAS LIFT ~,CAMCO/KBG-2-9/1/OPENlINT//1 Comment STAS 12/23/2008 2.900 5,933.3 30.97 NIPPLE Halliburton polished bore nipple 8/19/1999 Z. /5~ 5,933.3 30.91 SLEEVE-C Set ISO sleeve, ID 2.31" w/slip stop above ID 1.47" set 3/19/2000 1.47 10/292008 1,950.6 30 481 NIPPLE Halliburton XN nipple 8/19!1999 2.63 ms --I ---- - - -- snot I Top (TVD) Bim (fVD) i Dens i m (ftKB) (ftKB) (fiK8) Zone Date (sh-~ Type Comment _ 9,377.0 5 935.0 5948.0 C-0, 3G-26 ' 1/302000 4.0 APERF 25" hollow carrier, 180 deg. ph 9,516.0 ~, 6,057.8 6,070.1 A-3, A-0, A-5, ', 9/121999 4.0 IPERF 2 1!8" ENERJET 0 deg ph '~ 3G-26 ~ i. 9,545.01, 6 082.7 6 096.3A-2, 3G-26 X916/1999 I 4.0', IPERF ~,2 1/8" ENERJET 180 deg ph IPERF, 9.602-9,516 Well: 3G-36 API: 501032030300 ~-~" ~Cfl'IOCQ~~'11~~1~5 Field: Kuparuk PTD: 199-075 2009 RWO PROPOSED COMPLETION EXISTING COMPLETION NEW COMPLETION WELLHEAD ~ Lift threads: 3'/" 8rd EUE BPV: 3" FMC ISA BPV Model: FMC Gen IVA Slimhole CONDUCTOR 16", 62.58 ppf, H-40 ,welded TUBING 3-1/2", 9.3 ppf, L-80, IBT-Mod A: Nipple: 2.875" DS SURFACE CASING 75/8', 29.7 ppf, L-80, BTC-MOD PRODUCTION TUBING 3-1/2", 9.3 ppf, L-80, EUE 8rd-Mod PRODUCTION CASING 5%2', 15.5 ppf, L-80, BTC-MOD LINER 3'/2', 9.3 ppf, L-80, IBT-Mod Liner top Packer and PBR -Baker SABL-3 @ 9161' RKB PLUG 3-1/2" Weatherford WRP Set at 11,540' RKB C SAND STRADDLE Across Csand Perfs - 2.75" seal bore above and 2.635" XN nipple below. 2.31" iso sleeve in between with slip stop above PERFS 9362'-9377' MD C sand 9502'-9516' MD A sand 9530'-9545' MD A sand B: Gas Lift Mandrels C: Packer/PBR: Baker 3-1/2" FA D: Nipple: 2.813" DS E: Seal Assembly: Baker 3-1/2" stabbed in to existing PBR above SABL• 3 packer Casing Leaks: 8630'-9082' RKB Last Tag: 10/29/08 Tag Depth: 9534' RKB Fill: 11' fill above btm pert TD: 9850' RKB Last Updated: 6-Jan-09 Updated by: HBG From: Maunder, Thomas E (DOA) Sent: Monday, January 05, 2009 4:20 PM To: 'Gober, Howard' Cc: Poletzky, Isabel C; Burd, James A; Cawvey, Von; CPF3 Prod Engrs; Seitz, Brian; Ennis, J J; Packer, Brett B; Nelson, Erik Q; Long, Jill W Subject: RE: 3G-26 (PTD 199-075) Casing Leak Howard, Thanks for the information. Proceeding as you plan to conduct diagnostics doesn't require a new approval. As you note, once you have determined the repair plan an approval may be required. Keep us informed. Tom Maunder, PE AOGCC From: Gober, Howard [mailto:Howard.Gober@conocophillips.com] Sent: Monday, January 05, 2009 2:55 PM To: Maunder, Thomas E (DOA) Cc: Poletzky, Isabel C; Burd, James A; Cawvey, Von; CPF3 Prod Engrs; Seitz, Brian; Ennis, J J; Packer, Brett B; Nelson, Erik Q; Long, Jill W Subject: 3G-26 (PTD 199-075) Casing Leak Tom, Nordic 3 is currently on 3G-26 (PTD 199-075} at Kuparuk. This well is a producer and it had a tubing leak. Prior to the workover, we set a WRP in the liner at 9180' RKB. A CMIT to 2500 psi passed on 12/23/08 and a negative test to 0 psi passed on the same date. The tests were done with 9.6 ppg brine and a 2000' diesel cap in the hole. This is below the reservoir pressure which was 11.3 ppg. With the passing CMIT, the workover was planned as a tubing changeout only. Therefore, a Sundry application was not submitted to the AOGCC. This morning, we ran the new 3-1/2" gas lift completion in the ground. We appear to have some fill in the seal bore, so we will have to pull out and make a cleanout run through the PBR. While on bottom, we pressure tested the casing to ensure everything was still good. Unfortunately, we cannot get the casing to hold a 2500 psi pressure test. In fact, we cannot get above 2100 psi. At this pressure we are pumping approximately 0.75 bpm. When we shut down, the pressure bleeds off. Therefore, it appears we now have a casing leak. We will run a test packer to find the casing leak. At this time we will develop a repair plan and discuss it with you for approval. Please let me know if you have any questions. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907-263-4220 Office 907-240-5515 Cell Howard.Gober@conocophillips.com vviJ 1 /5/2009 12/30/08 --~ ~.. ~. ~ 9 I ~® ~~~ ~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description 2U-03 12080460 INJECTION PROFILE '~' aj 11/17/08 1 1 1Y-03 12096583 INJECTION PROFILE - 12/07/08 1 1 iC-11 12114998 PRODUCTION PROFILE a 12/14/08 1 1 1 D-07 12114999 USIT 'T ~ a 12/15/08 1 1 1 B-09 12115001 INJECTION PROFILE L ~ 12!18/08 1 1 3G-26 12115002 WEATHERFORD WRP/SBHP I 12/19/08 1 1 1C-18 12100472 INJECTION PROFILE (' r 12/21/08 1 1 1 E-21 12115005 INJECTION PROFILE Q 12/22/08 1 1 2C-02 12100475 INJECTION PROFILE () 3 12/24/08 1 1 ~„ ,/ NO. 5024 Company: Alaska'Oii &'Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD J Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 17, 2008 • 0~~;11~~~3~~ ~ ~~~~~. Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ~~~~ AUK ~ ~ 20G8 Dear Mr. Maunder: Enclosed please find 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. wells 3G-26 (PTDr1990750 . The report records the successful Tubing POGLM patch set to repair the TxIA communication. Please call myself or Martin Walters at 659-7224 or MJ Loveland/Perry Klein at 659- 7043 if you have any questions. Sincerely, i ` rent Rogers Problem Well Supervisor STATE OF ALASKA ~~~ ~ ~ Za0$ ALASKA OIL AND GAS CONSERVATION COMMISSION ~;~;t ~~ ~~~~ BOOS ~;01111'6'113Si~ REPORT OF SUNDRY WELL OPERATIONS ~.,n~..~..n..~ 1. Operations Pertormed: Abandon ^ Repair Well ~ Plug Perforations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ~ Exploratory ^ 199-075 - 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20303-00 7. KB Elevation (ft); 9. Well Name and Number: RKB 82' 3G-26 ' 8. Property Designation: 10. Field/Pool(s): .~ ADL 25547 ALK 2661 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 9850' ~ feet true vertical 6388' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 110' 16" 110' 110' SURFACE 4262' 7 5/8 4344' 3051' PRODUCTION 9243' 51/2" 9325' 5903' PRODUCTION 687' 3-1/2" 9848' 6386' Perforation depth: Measured depth: 9362-9377, 9502-9516, 9530-9545 true vertical depth: 5935-5948, 6058-6070, 6083-6096 Tubing (size, grade, and measured depth) 3 1/2", L-80, 9161' MD Packers &SSSV (type & measured depth) Pkr= Baker SABL-3 Packer, 9161' MD SSSV= Camco DS Nipple, 532' 12. Stimulation or cement squeeze summary: ~ Q~~c` ~ 5 Intervals treated (measured) N~q ~ ~ J Treatment descri tions includin volume s used and final ressure: c~~~ ~P,j~-~ `~ - A ~ p g p j ~ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development 0 Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: contact Brent Rogers/Martin Walters Printed Name Brent Rogers Title Problem Wells Supervisor Signature Phone: 659-7224 Date 0617/08 >!~ Form 10-404 Revised 04/2006 ~ 1 \ ~ ~ ~ ~ r~ ~ Submit Original Only/`~~ S ~~, ~U~ ~ ~ ZOOS 3G-26 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 5/21/2008 SET WEATHERFORD 3.5" ECLIPSE PACKER MID-ELEMENT AT 8652' (LOWER ER PACKER FOR POGLM PATCH). 5/22/2008 6/10/2008 Summary TESTED LOWER PKR @ 8652' RKB TO 2500 PSI. SET 18.25' POGLM ASSEMBLY, STABBING INTO LOWER PKR @ 8652' RKB; UPPER PKR @ 8633' RKB. TESTED PKR TO 2500 PSI. COMPLETE. TIFL;(Passed) Initial T/I/0=175/1200/0; Shut in WH and LG; Shot initial FL@ 4350 Stacked out TBG with LG; Shot 2nd FL @ same location; Final T/I/0=900/275/0 Set 19' Weatherford retrievable POGLM patch @ 8633' - 8652'. The TIFL passed following the patch set. • • ~~LL T%4.4N~1[/1/1`~~4L ~~. ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907] 859-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTTJ The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn; Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fa~c (907j 245-8952 1) Caliper Report 26-Feb-08 3G26 2j 1 Report / EDE 50-103-20303-00 ~~~f~NE~ ~iAR ~ ~ ~DO~ i~9-~~-S~t~g~5 Signed : I Print Name: ~`~ i i5~-;t.t..e {~/1 ~ (,~ ~e,(~o~. .. _ __~ . ~~~ ~ ~ - ~, ~° .. ~.. ~ 9 ~ `~ ~ :~~ Date : ~"~~~ ~,nG~)~; PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245$8952 E-MAIL : pdsanehoraae(a~memoretlo~.com WEB5ITE : www.memo~loa.com C:\Documentis and Settings\Owner\Deslctop\Transmit_Conoco.doc ~ ~ Memory Multi-Finger Caliper S Log Results Summary Company: ConocoPhiilips Alaska, Inc. Well: 3G-26 Log Date: February 26, 2008 Field: Kuparuk Log No.: 8664 State: Alaska Run No.: 1 API No.: 50-103-20303-00 Pipet Desc.: 3.5" 9.3 Ib. L-80 EUE 8rd Top Log Intvll.: Surface Pipet Use: Tubing Bot. Log (ntv11.: 9,178 Ft. (MD) Inspection Type : Corrosive b Mechanical Damage Inspection COMMENTS This caliper data is tied into the CAMCO W NIPPLE @ 9,907'. This log was run to assess the condition of the 3.5" tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate that the 3.5" tubing is in good condition, with the exception of a 24%wall penetration in joint 96 (3,065'). The damage recorded appears mostly in the form of Isolated Pitting and some General Corrosion. No areas of significant cross-sectional wall loss (> 10%) or I.D. restrictions are recorded. MAXIMUM RECORDED WALL PENETRATIONS: Isolated Pitting (24°i6) Jt. 96 ~ 3,065 Ft. (MD) No other sign cant wall penetrations (>19°~) are recorded. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No areas of significant cross-sectional wa11 loss (> 10%) are recorded. MAXIMUM REGORDED lD RESTRICTIONS No significant I.D. restrictions are recorded. Field Engineer: K. Miller Analyst: HY. Yang Witness: C. Fitzpatrick ?raActive Diagnostic Services, Inc. ; P.O. Box 1369, Stafford, TX 77497 Phone: (2811 or (888) 565-9085 Fax: (281} 565-1369 E-mail: PDS~a;memorylog.carn ?rudhoe Bay f=ield Office Phone: (907, 659-2307 Fax: (9071 659-2314 ~~~ ~5 ~I s~~s5, • • Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (-1.6' - 9170.1') Well: 3G26 Field: Kuparuk Company: ConocoPhilips Alaska, Inc. Country: USA Survey Date: February 26, 2008 Approx. Tool Deviation ^ Approx. Borehole Profile 2 799 1590 2381 3173 GLM 1 4001 4791 ~ 5583 LL c GLM 2 .c 6410 a v 7200 GLM 3 802 7 GLM 4 8852 GLM 5 283 9170 0 50 100 Damage Profile (% wall) /Tool Deviation (degrees) Bottorn of Su rvey = 283 1 25 ' 50 75 100 125 150 ~ 175 - E 200 ~ 0 225 ' 2 50 275 • • PDS Report Overview ~~ s. Body Region Analysis Well: 3G-26 Survey Date: February 26, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Analyst: ___ _ HY. Yan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f L-80 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) i~ penetration body metal loss body 250 200 150 100 50 0 0 to 1 to 10 to 1% 10% 20% 20 ro 40 ro over 40% 85% 85% Number of'oints anal se d rotal = 301 pene. 0 149 151 loss 62 237 2 1 0 0 0 0 0 Damage Configuration (body ) 80 60 40 20 0 isolated general line ring hole/poss pitting corrosion corrosion corrosion ible hole Number of 'oints darna ed total = 75 65 10 0 0 0 Damage Profile (% wall) ~ penetration body ;;~;,~,~, metal loss body 0 50 100 0 95 GLM 1 GLM 2 GLM 3 GLM 4 CLM 5 282 Bottom of Survey = 283 Analysis Overview page 2 ~ ~ PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Body Wall: 0.254 in Upset Wall: 0.254 in Nominal I.D.: 2.992 in Well: 3G-26 Field: Kuparuk Company: ConocoPhi6ips Alaska, Inc. Country: USA Survey Date: February 26, 2008 Joint No. Jt. Depth (Ft.) I'c~n. U(~s~~t (Ins.) Pen. Body (Ins.) {'en. %~ M~~t.il I os~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 .1 U 0.01 (> 2.87 PUP 1 2 U 0.03 1 Z (, 2.93 1.1 35 t~ 0.02 tf _' .95 PUP 12 41 i1 0.02 ~) ~ 2.92 PUP 1.3 47 ~~ 0.02 tf I 2.89 PUP 57 (~ 0.03 1 Z (, 2.93 3 89 t) .02 ~~ ~ 2.92 4 120 i ~ 0.0 -! 2.94 5 152 O 0.03 1 t ~ t, 2.9 6 184 t t 0.03 1 Z ~ 2.94 7 216 t ~ 0.01 5 a 2.93 8 247 t ~ 0.03 12 (~ 2.92 9 279 a 0.01 4 (~ 2.93 10 310 a 0.02 ~~ 1 2.90 11 342 a 0.03 1 i 2.92 Shallow itlin . 12 74 tt .0 11 t, 2.93 13 405 (1 0.02 ~ ~ i ~ 2.92 14 437 U 0.02 t3 a 2 9 15 469 It 0.02 9 ~ ~ 2.92 15.1 500 U 0.01 4 I 2.87 PUP 15. 506 l) 0 U u 2.81 Camco S Ni le 15.3 508 l) 0.01 5 ' 2.90 PUP 16 513 U 0.02 ~~ (~ 2.93 17 545 U 0.02 ~~ 6 2.93 18 577 a .0 > (, 3 19 608 t t 0.03 I ~ 7 2.92 0 640 a 0.04 1 tt 2 .93 Shallow itUn . 21 671 (~ 0.02 ~ 4 2.94 2 703 U 0.02 ~~ (~ 2. 2 23 736 O 0.03 Itl ? 2.90 24 76 U 0.02 `~ - 2.92 25 799 t1 0.04 I (~ t, 2.93 Shallow ittin . 26 830 t) 0.03 1 u (~ 2.92 27 862 (1 0.03 I ; 5 2.93 Shallow 'ttin . 28 894 U 0.03 I t) 4 2.92 29 925 t~ 0.01 6 5 2.93 30 957 t ~ 0.01 ~ 4 2.93 31 989 U 0.02 ~~ 5 2.91 32 1020 t i 0.02 7 2 2.88 33 1052 U 0.03 I i 2.91 Shallow 'ttin . 34 1083 t ~ 0.03 12 5 2.93 35 1115 ~ 1 0.03 I 1 v 2.93 36 1147 t~ 0.0 ~~ 2.91 37 1178 U 0.03 I c 6 2.92 Shallow corrosion. 38 1210 cl 0.02 7 2 2.91 39 1241 t> 0.03 13 4 2.93 Shallow itUn . 40 1273 t) 0.02 ~~ t~ 2.92 41 1305 U 0.01 > -1 2.93 4 1336 U 0.03 11 (~ .94 43 1368 a 0.01 (~ c, 2.91 Penetration Body Metal Loss Body Page 1 ~ ~ PDS REPORT JOINT TABULATION SHEEP Pipe: 3.5 in 9.3 ppf L-80 Well: 3G-26 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: February 26, 2008 Joint No. Jt. Depth (Ft.) I'frn. UL~set (Ins.) Pen. Body (Ins.) 1'c~n. `% ~~~).~I I~~,~ °~, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 44 1400 0 0.03 12 !~ 2.91 45 1431 U 0.02 ~ .91 46 1463 t) 0.0 1:; 1 I 2.92 ha low c rro ion. 7 1495 l) 0.03 12 a 2.92 48 1526 ~ 0.02 ~) (~ 2.93 4 1558 t) 0.01 4 ~~ 2.93 0 1590 U 0.01 (~ !~ 2.94 51 1621 c) 0.03 1 I 91 52 1653 U 0.03 1 Z a 2 92 53 1684 U .03 11 ~ 2.91 54 1716 U 0. 2 8 _' 2 92 55 1747 U .03 13 a .93 Shallow ittin . 56 1779 U 0.02 ~) 2.93 57 1811 t) 0.02 ~> 2.92 58 1843 t) 0.02 7 2.93 5 1874 U 0.02 ~~ a 2.92 60 1905 U 0.03 11 2.90 61 1938 U 0.03 10 ~; .91 62 19 9 l) 0.0 7 ' .94 63 2001 O 0.02 9 ~ 2.93 64 2033 O 0.03 12 2.91 hallow it9n Lt. a sits. 65 2064 t) 0.02 t9 2.93 66 2096 U 0 1 ? ~ 2.92 67 2128 (1 0.01 ~~ 2.94 6 2159 O 0 0 ~) ~ 2.92 69 2191 ~? 0.03 I ~ ? 2.91 70 2223 ~) 0.01 5 I 2.93 71 2254 ~) 0.02 t9 I 2.94 72 2286 I) 0.02 7 F, 2. 3 73 2318 O 0.03 13 ~ 2.92 Shallow 'ttin . 74 2349 0 0.03 1 ~~ - 2.91 75 2381 t) 0.02 ~' 2.94 76 2413 O 0.03 1~' i) 2.90 77 2445 U 0.03 l l i 2.93 78 477 ! } 0.04 I -i (, 2.91 Shallow 'tGn . 79 508 U 0.01 4 4 2.90 80 2540 l~ 0.01 6 4 2.92 81 2571 O 0.04 I (~ t3 2.94 Shallow it6 82 2603 U 0.02 7 ~~ 2.92 83 2635 a 0.02 7 2.92 84 2667 i? 0.04 I i I 2.9 ow 'tU 85 2698 U 0.03 I t) t, 2.91 86 2 7 0 ~) 0.02 ~ 2.91 87 2761 It 0.02 ~> 2.93 88 2793 U 0.03 1 U (~ 2.91 89 2825 t) 0.04 I t9 ti 2.91 Shallow it6 90 2856 li 0.03 I > 4 .92 Shallow itU 91 2888 t) 0.03 13 ') 2.95 Shallow corrosion. 9 2920 0.0 I Z 2.9 93 2952 0.02 `~ 2.93 _ Penetration Body Metal Loss Body Page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Wefl: 36-26 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhiNips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: February 26, 2008 Joint No. Jt. Depth (Ft.) I'c~n. t )I~sc~t Uns.) Pen. Body (Ins.) Pen. % 'vtc~t,il l_vss `i~~ Min. LD. (Ins.) Damage Profile Comments (% wall) 0 50 100 94 2983 t) 0.02 i 2.91 95 3015 t) 0.04 14 ~~ 2.91 Shallow ittin . 96 047 t) 0.06 _>~1 ~~ .91 Isol ted i tin 97 3078 U 0.03 11 t, 2.92 98 3110 U 0.02 7 i ~ 2.91 99 3142 11 0.02 7 ? 2.93 100 3173 t) 0.03 11 I 2.92 101 3205 t) 0.02 7 ~' 2.93 102 3237 U 0.04 17 t, 2.93 Shallow ~ttin . 103 3269 U 0.05 1 ~) 2.93 Shallow ittin . 04 3300 U 0.03 1 z ~ .92 Shallow ittin . 105 33 2 U 0.01 ~ - 2.93 106 3364 U 0.02 `1 2.93 107 3396 t) 0.02 a 2.93 108 427 U 0.04 I b (~ 2.9 Sh Ilow ittin . 109 3459 U 0.02 t3 t, 2.93 110 3490 U 0.01 6 _' 2.92 111 3522 U 0.01 U t) 2.91 112 3554 ~) 0.02 9 1 2,91 113 3586 U 0.02 7 1 2.94 114 3617 U 0.02 8 F1 2.94 115 3649 U 0.03 11 I 2.91 116 3681 a .02 9 ~~ 2.92 117 3713 0 0.02 9 l 2.93 118 3744 U 0.03 11 ~ .90 119 3776 O 0.03 11 F3 2.91 120 3808 t1 0.03 10 ~1 2.91 121 3839 t) 0.03 11 ~~ 2.90 122 3871 a 0.02 9 ~', .92 122.1 3903 0 0.03 I1 ,' 2.93 PUP 1 2.2 3917 ~1 0 0 t) N A GLM 1 Latch~9:00 122.3 3926 ~) 0.02 ~) _' 2.92 PUP 123 3938 t~ 0.01 ~ h 2.94 124 3970 U 0.03 1 z (~ 2.91 125 4001 U 0.03 1 Z 7 .92 126 4033 U 0.03 11 (~ 2.92 127 4065 l1 0.02 % _' 2.93 128 4096 c) 0.02 t3 ~ 2.93 129 4128 t) 0.0 9 2.92 130 4160 t 1 0.01 ~ ~ 2.91 131 4191 U 0.01 5 (, 2.92 132 4223 U 0.04 14 Z 2.90 Shallow ittin . 133 42 t) 0.03 12 (, 2.92 134 4286 ~) 0.02 9 / 2.91 135 4318 U 0.03 12 ~ 2.92 136 4350 U 0.03 12 _' 2.88 137 4381 t1 0.03 13 2.90 138 4412 U 0.03 11 i 2.91 139 4444 U 0.03 11 (i 2.92 140 4475 i> 0.02 V i 2.94 Penetration Body Metal Loss Body Page 3 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 3G-26 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: February 26, 2008 Joint No. Jt. Depth (Ft.) I'~~n. lll„~~t !In,.l Pen. Body (lns.) I'~~n. `;4, ~ti1c~t.~l Lu "~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 141 4508 t t 0.02 t3 2.93 142 4539 tt 0.02 ~t 2.92 143 4570 U 0.03 1l) ~ 2.93 144 4601 t) 0.02 ~t -1 2.92 145 4633 t~ 0.03 1 _' S 2.92 146 4665 ~ t 0.02 ~~ 2.93 147 4696 U 0.03 Il ~1 2.93 148 4728 t) 0.03 1 U 1 2.93 149 4759 U 0.02 `) 5 .92 150 4791 ~ t 0.02 `) -t 2.91 151 4823 It 0.01 ~ ~ 2.94 152 4855 tl 0.02 t3 I 2.93 153 4887 ~ t 0.03 1 ~' 2.92 154 4918 ~ t 0.03 I ~ l -! 2.89 155 4950 U 0.03 12 ~' 2 90 Shallow itlin . 156 4981 c) 0.04 16 5 2.93 Shallow itUn . 157 5012 t> 0.03 11 7 2.93 158 044 t t 0.02 9 ? 2.88 159 5076 t) 0.03 10 2.93 160 5107 tt 0.04 17 2.91 Shallo i ti 161 5139 U 0.04 1 t, 2.88 Shallow corrosion. 162 5171 ~) 0.01 t> ! t 2.90 16 5203 ~ t 0.03 I ~ t 2.92 164 5234 t) 0.03 I > !~ 2.92 Shallow itUn . 1 5 26 U 0.04 14 5 2.91 Shal ow itUn . 166 5298 U 0.03 I u 5 2.93 167 5329 t1 0.03 I ~ 3 2.91 168 5361 It 0.02 7 ~l 2.91 169 5393 t) 0.03 11 1 2.92 170 5424 it 0.02 ~~ 2.90 171 5456 t t 0.03 1 I -i 2.92 172 5488 ~ t 0.02 ~) 2.93 173 5518 U 0.03 11 6 2.91 174 5550 U 0.03 11 (, 2.92 175 5583 0 0.04 17 2 .91 Shallow ittin . 176 5614 ~) 0.03 1 1 ~' 2.91 177 5645 U 0.04 14 E~ 2.93 Shallow 'tlin . 178 5677 1 1 0.03 1 U 1 2.89 179 5708 t t 0.03 12 ~~ 2.93 180 5740 U 0.03 I U (~ 2.92 181 5772 U 0.0 10 _' 2.92 182 5804 t) 0.02 7 ~ 2.91 183 5835 ~ t 0.03 1 1 2 2. 1 184 5867 (t 0.03 11 6 2.92 185 5898 tt 0.03 12 2.91 186 5930 U 0.03 13 ? 2.92 Shallow itUn . 187 5961 ~ t 0.03 1 1 ~ 2.90 188 5994 t t 0.02 9 t ~ 2.91 189 6025 t t 0.04 15 (~ 2.90 Shallow itlin . 190 6057 tl 0.03 1~ 2.90 Penetration Body Metal Loss Body Page 4 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 3G-26 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: February 26, 2008 Joint No. Jt. Depth (Ft.) I'~~n. Ul~.r~t Ilns.) Pen. Body (Ins.) Pev~. °4, ~1~~1.~1 Irs~ °~~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 191 6089 a 0.0 9 -1 2.9 19 6120 a 0.02 9 ~~ 2.92 192.1 6152 O 0.02 ~3 _' 2.93 PUP 192.2 6160 t) 0 0 (: N GLM 2 Latch ~ 10:30 192.2 6176 O 0.01 5 1 2.90 PUP 193 6188 U 0.03 1 t) I 2.93 194 6219 U 0.04 14 I 2.92 Shallow itUn . 195 6251 t) 0.03 1 Z ? 2.88 196 6283 U 0.03 11 2.89 197 6314 U 0.03 13 ~ 2.89 Shallow itUn . 198 6346 U 0.03 I1 1 2.90 199 6378 t) 0.03 1 1 - 2.91 200 6410 a 0.03 11 t ~ 2.90 201 6441 U 0.03 13 Z 2.91 Shall w rrosion. 202 6473 U 0.03 1 t) O 2.90 203 6505 U 0.04 14 t i 2.91 hallow ittin . 204 6536 U 0.05 2U 7 2.91 Shallow corrosion. 205 6568 U 0.03 11 -1 2 92 206 6600 t) 0.03 12 t~ 2.90 Shallow i tin . 207 6631 U 0.04 14 (, 2.91 Shallow ittin . 208 6662 t) 0.04 17 1 2.91 Shallow ittin . 209 6695 U 0.03 1 3 (~ 2.91 Sha low itUn . 210 6726 U 0.04 17 0 2.90 Shallow corrosion. 211 6758 t) 0.03 1.3 t) 2.91 Shallow ittin . 21 6790 U 0.03 11 ~ 1 213 6820 t) 0.03 12 t) 2.91 214 6853 t) 0.02 9 O 2.89 215 6884 t) 0.03 12 (~ 2.90 Shallow itUn . 216 6916 U 0.03 12 I 2.91 Shallow ittin . 217 6948 t) 0.02 ~~ 2.90 218 6979 U 0.03 1.3 t) 2.90 Shallow itfin . 219 7011 U 0.05 I') O 2.91 Shallow ittin . 220 7042 U 0.04 15 I 2.90 Shallow corrosion. 221 7074 U 0.03 I 1 ~) 2.91 222 7106 U 0.04 1 ~ U 2.91 Shallow itUn . 223 7138 U 0.03 13 t) 2.91 Shallow itUn . 224 7169 a 0.03 13 ~ 2.91 Shallow it6n . 225 7200 O 0.03 13 l) 2.90 Shallow ittin . 226 7232 U 0.03 1 tl 2.9 227 7264 U 0.03 13 i) 2.90 Shallow itUn . 228 7296 t) 0.04 15 t) 2.92 Shallow ittin . 229 7328 O 0.03 I I _' 2.91 230 7358 O 0.03 I U I 2.89 231 7390 +) 0.03 I! O 2.90 232 7422 O 0.03 1l a 2.89 233 7453 n 0.04 14 t) 2.90 Shallow ittin . 234 7486 i ~ 0.03 1 1 2.91 235 7517 t) 0.04 14 _' 2.91 Shallow itUn . 236 7549 a .03 13 U 2.89 Shallow itUn . 237 7581 ~~ 0.03 l O 2.90 Shallow itUn . Penetration Body Metal Loss Body Page 5 • • PDS REPORT JOIN T TABU LATION SHEET Pipe: Body Wall: 3.5 in 9.3 0.254 in PPf L ~ Well: Upset Wall: Nominal I D 0.254 in Field: 3G-26 KuParuk . .: Com an 2992 ~n P y~ Country: ConocoPhipips Alaska Inc Survey Date: , . USA February ~~ ~nno Penetration Body Page 6 Metal Loss Body • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 3G-26 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: February 26, 2008 Joint No. Jt. Depth (Ft.) I'f~n. Ul~sc~I Ilns.l Pen. Body (Ins.) I'c'n. %, Metal loss `;<, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 280.2 9048 t) 0 U U N A GLM 5 Latch ~ 8:30 280.3 9055 O 0.04 16 2 2.93 PUP Shallow ittin . 281 9073 l) 0.03 1 3 i 2.92 Shallow i tin . 281.1 9107 U 0 O U 2.81 Camco W Ni !e 28 9108 ~~ 0.03 1U 7 .92 282.1 9140 ~) 0.03 IZ 2.88 PUP Shallow ittin 282.2 9147 t~ 0 l) t) 2.99 Baker Seal 282.3 9157 U 0 U c~ 2.75 Packer Han U 282.4 9165 U 0.01 4 Z 2.92 PUP 283 9170 ti 0.01 4 1 2.93 First oint of 3.5" Ca in Penetration Body Metal Loss Body Page 7 PDS Report Cross Sections ~1 ~~ ,. 4 Well: 3G-26 Survey Date: February 26, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers; 24 Tubing: 3.5 ins 9.3 oof L-80 Analyst: HY. Yang Cross Section for Joint 96 at depth 3065.383 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 100 Tool deviation = 65 ° Finger 14 Penetration = 0.056 ins Isolated Pitting 0.06 ins = 24% Wall Penetration HIGH SIDE = UP ~ ~ i ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ • • Cross Sections page 1 • °;"~ PHILLIPS Alaska, Inc. KRU 3~-2s Scblullbepger (J, NO. 4384 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 2, '7 Z007 B!, ()~~S comrflissiQ\l n 1 LUISi ANIt.\~D ~Ub ,¡) c.r. 11'::.0- 'fIiJ'iJ Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job# Log Description Date BL 1 R-27 11850425 FPIT Ie¡ / -It:);) 08/18/07 1 31-08 11839638 LDL )"'lr{", -rI-h-. 07/28/07 1 2M-19 11813070 INJECTION PROFILE /1.1' .CI I-~-::l 07/29/07 1 3G-26 11813071 LDL Io,O¡-/"")-:}~ 07/30/07 1 1R-18 11837482 SBHP/DDL Ie:; / -' ^'ff9- 07/31/07 1 1Y-01 11813072 INJECTION PROFILE U~ - /'1f3-cf'\Ó 07/31107 1 2C-08 11813073 INJECTION PROFILE' íJTI" )1r.7. -(~.< 08/01/07 1 3H-32 11837483 LDL ...:-~-":"..I 08/01/07 1 1Y-10 11837485 INJECTION PROFILE ·U~ I ''If'2.. - t"'E)'"' ) 08/03/07 1 3G-08 11813075 PRODUCTION PROFILE' 1~() - () C"S- 08/04/07 1 1A-06 11837486 INJECTION PROFILE ¡yTC' 1'Íf1~11(.". 08/04/07 1 2N-337B 11837489 PRODUCTION PROFILE . ~N ~ - If A", 08/06/07 1 2U-08 11813076 LDL W17t ,~ -/')81 08/06/07 1 1G-12 11837490 PRODUCTION PROFILE 115'3 - J.~;l 08/07/07 1 2N-343 11745232 MEM INJECTION PROFILE . ()Tf' IC1~ -I"'A:J 08/08/07 1 2N-327 11837491 SONIC SCANNER &:> ":t --O<O~ 08/08/07 2N-327 11837491 SONIC SCANNER-FMI ................ J"" 08/08/07 3K-01 11632749 PRODUCTION PROFILE . 1*(0 - 1";/ 08/12/07 1 2X-04 11846430 INJECTION PROFILE ()'I.(' )-x~ -II*' 08/13/07 1 2Z-29 11850419 SBHP SURVEY /1r7f ';'):::A 08/13/07 1 2X-19 11850420 SBHP SURVEY J ') C - ¡~'-'S- 08/13/07 1 1A-20 11850421 SBHPSURVEY I~()-J~~ 08/14/07 1 1F-13 11850422 SBHP SURVEY U 'L '\ 1S.:3. -J¿¡/.J 08/14/07 1 1H-10 11846432 SBHP SURVEY ¡OJ-:< -~~ 08/14/07 1 1Q-10 11846431 SBHP SURVEY l"íf¿ - 1C1'$r 08/14/07 1 2U-05 11846433 INJECTION PROFILE U~_ lIrf)-(Jl~ 08/15/07 1 2D-12 11846434 PRODUCTION PROFILE 1 *1../ -1"A4 08/16/07 1 2H-06 11846435 LDL J7r~ -¡¿PI 08/17/07 1 Kuparuk Color CD 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. 'd7( 08/22/07 . . .! 199-075-0 KUPARUI( RIV UNIT 3G-26 50- 103-20303-00 PHILLIPS ALASKA [NC Roll #1: Start: Stop Roll #2: Start__ Stop MD 09850'. TVD 06388 ~Completion Date: ~9 ~Completed Status: 1-OIL Current: T Name Interval c 9341 -~--~-~ I SCHLUM AIT/GPIT C 9457 1 SCHLUM RST 12/13/99 D 9050/~' 1-3 SPERRY MPT/GR/EWR4 L AIT-GR/CCI~::j~' FINAL 8530-9842 L CONTSRVY/GPIT/~~ FINAL 8530-9842 L DGR/EWR-MD~-- FINAL 11215-13247 PB2 L DGR/EWR-TVD~~'~'' FINAL 110-5905 L PROD/~. FINAL 9300-9595 L STAT PRES/TEIv~ L WTR FLOW}( R SRVY CALC J R SRVY RPT:~ / ~r-' FINAL 8987-9509 9/12/99 FINAL 9300-9595 BHI 110-9850. SPERRY 0-9327 Sent Received T/C/D . OH 10/6/99 10/13/99 CH 2/29/00 3/14/00 OH 11/11/99 11/12/99 OH 10/6/99 10/13/99 CH 10/6/99 10/13/99 OH 2/5 11/23/99 11/22/99 OH 2/5 11/23/99 11/22/99 CH 5 2/2/00 2/15/00 CH 5 9/30/99 9/30/99 CH 5 2/2/00 2/15/00 OH 11/1/99 11/2/99 OH 8/19/99 8/31/99 Wednesday, June 20,2001 Page 1 of 1 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 18, 2001 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a 10-404 Report Of Sundry Well Operations for Phillips Alaska, Inc., well 3G-26. Attached is a service report detailing the pumping of cement for a surface casing shoe. Please call Pete Nezaticky or me at 907-659-7224 if you have any questions. Sincerely, Jerry Dethlefs Phillips Problem Well Supervisor Attachment STATE OF ALASKA -- ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other_X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Developrnent__X RKB 82 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 service__ Kuparuk Unit 4. Location of well at surface 8. Well number 2536' FNL, 4909' FEL, Sec. 24, T12N, R8E, UM (asp's 498750, 5988560) 3G-26 At top of productive interval 9. Permit number / approval number 2867' FNL, 365' FEL, Sec. 13, T12N, R8E, UM (asp's 503292, 5993513) 199-075 1990750 At effective depth 10. APl number 50-103-20303 At total depth 11. Field / Pool 2734' FNL, 244' FEL, Sec. 13, T12N, R8E, UM (asp's 503412, 5993642) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 9850 feet Plugs (measured) Tagged Fill (3/19/2000) @ 9584' MD. true vertical 6388 feet Effective depth: measured 9584 feet Junk (measured) true vertical 6132 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 110' 16" 265 Sx AS I 110' 110' SURFACE 4262' 7-5/8" 350 Sx AS III LW, 500 G 4344' 3051' PRODUCTION 9243' 5-1/2" 150 Sx Class G 9325' 5903' PRODUCTION 687' 3-1/2" 61 Sx Class G 9848' 6386' Perforation depth: measured 9362 - 9377'; 9502 - 9516'; 9530 - 9545' true vertical 5935 - 5948'; 6058 - 6070'; 6083 - 6096' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tbg @ 9161' MD. !Packers & SSSV (type & measured depth) BAKER SABL-3 PACKER @ 9161' MD. CAMCO DS @ 532' MD. 13. Stimulation or cement squeeze summary Pumped 18 bbls 15.8 ppg cement down CA for shoe Intervals treated (measured) Estimate 500' cement column, top of cement in CA @ 3844' Treatment description including volumes used and final pressure (see attached Well Service Report) 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 463 277 336 - 193 Subsequent to operation 540 230 441 - 192 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __X Gas __ Suspended __ Service 17.1hereby certify that the foregoing is tr e and correct to the best of my knowledge.,~ s_~.._..~ ~ R~CEIV~F$ Signed ~'"'~-~¢ ~------E----~~--¢--~-~ Title: Phillips Problem Well Supervisor Date: 03/18/01 / Jerry Ioethlet.~ J~...~ ~A/~[~) ~el~are~l(¥1~n Peirce 265-6471 Form 10-404 Rev 06/15/88 · Alaska 0il &Anch0rageGaSSUBMiTC0ns' iNC°mrnissi° rDUPLiCATE PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(3G-26(W4-6)) WELL JOB SCOPE JOB NUMBER ' " 3G-26 AN N-COM M 0314011406.1 DATE DAILY WORK UNIT NUMBER 03/18/01 PUMP CA CEMENT SHOE DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 1 YES YES DS-DOUGHTEN DETHLEFS FI ELD AFC# CC# DAILY COST ACCUM COSTer ,~'n ~ d-~Fi ~ Signed. z,"'-~n a~ ESTIMATE K85329 230D S36G L $10,897.00 $10,897.00 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Out I NA NA 200 PSI 200 PSII 0 PSII 800 PSI DALLY SUMMARY IPUMPED CA CEMENT SHOE; 18 BBLS 15.8 PPG "TAIL" CEMENT (STATE WITNESSED)[Cement-Poly Squeeze, Maintenance, WH Maintenance] TIME LOG ENTRY 10:00 MIRU DOWEL CEMENTERS. INSTALL HL TO CA. 11:20 SAFETY MEETING; DOWELL 4, APC 3, PAl 3, AOGCC 1 (JOHN CRISP) 11:45 PRIME AND PT @ 3000 PSI 11:50 PUMP 80 DEG FRESH WATER PRE-FLUSH, 100 BBLS. AVE RATE 3.1 BPM, AVE PRESSURE 1400 PSI. 12:25 PUMP 15.8 PPG "TAIL" CEMENT, 18 BBLS, 2.3 BPM, 900 PSI. 12:35 PUMP 5 BBLS FRESH WATER SPACER, 1.5 BPM, 600 PSI 12:40 PUMP DIESEL DISPLACEMENT, 59 EELS, 3.1 BPM, 1200 PSI. 13:00 13:10 14:00 SHUT DOWN PUMPS. 800 PSI ISIP. ESTIMATED CEMENT TOP IN CA 3844' (500' CEMENT COLUMN ABOVE SHOE). CLEAN PUMPS, RIG DOWN RELEASE WELL TO PRODUCTION. CAN BE ECL IN 24 HOURS. CA TO BE BLED TO ZERO PSI IN 24 HOURS TO PREVENT WELLHEAD LEAK. MITOA WILL BE DONE IN A FEW DAYS. FLUID SUMMARY 18 BBLS 15.8 PPG "TAIL" CEMENT 200 BBLS 80 DEG FRESH WATER 59 BBLS DIESEL SERVICE COMPANY - SERVICE DAILY COS'~ ~ ,.Ac-C,I.[M,T_O,T~AL APC DOWELL ~D o ~ 9(~tli Gas Cons. Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other__ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 82 feet 3. Address Explorato~ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk Unit 4. Location of well at surface 8. Well number 2536' FNL, 4909' FEL, Sec. 24, T12N, R8E, UM (asp's 498750, 5988560) 3G-26 At top of productive interval 9. Permit number / approval number 2867' FNL, 365' FEL, Sec. 13, T12N, R8E, UM (asp's 503292, 5993513) 199-075 At effective depth 10. APl number 50-103-20303 At total depth 11. Field / Pool 2734' FNL, 244' FEL, Sec. 13, T12N, R8E, UM (asp's 503412, 5993642) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 9850 feet Plugs (measured) Tagged Fill (3/19/2000) @ 9584' MD. true vertical 6388 feet Effective depth: measured 9584 feet Junk (measured) true vertical 6132 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 110' 16" 265 Sx AS I 110' 110' SURFACE 4262' 7-5/8" 350 Sx AS III LW, 500 G 4344' 3051' PRODUCTION 9243' 5-1/2" 150 Sx Class G 9325' 5903' PRODUCTION 687' 3-1/2" 61 Sx Class G 9848' 6386' Perforation depth: measured 9362 - 9377'; 9502 - 9516'; 9530 - 9545' true vertical 5935 - 5948'; 6058 - 6070'; 6083 - 6096' ' '- "' ~ ~ Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tbg @ 9161' MD. R ~ 6 E IV E B Packers & SSSV (type & measured depth) BAKER SABL-3 PACKER @ 9161' MD. CAMCO DS @ 532' MD. FI.~ '~ 3 200'J 13. Stimulation or cement squeeze summary -~laska 0il & Gas Cons. Comn'~Jssjor~ Intervals treated (measured) (see attached) Anchorage Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 463 277 336 193 Subsequent to operation 540 230 441 192 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations ._X Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed //~ /~~,,~ Title: Date ~'/7/~),? · . Prepared by John Peirce 265-6471 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 3G-26 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 1/30/00: MIRU & PT equipment. RIH w/perforating guns & tagged PBTD @ 9587' MD, then PU & shot 15' of perforations as follows: Added perforations: 9367 - 9382' MD Used 2-1/2" HSD carriers & shot perfs at 4 spf at 180 degree phasing. POOH w/guns. RD. 3/19/00: RIH & tagged fill @ 9584' MD. Returned the well to production w/gas lift & obtained a valid well test. 2/2/OO Schlumberger NO. 121149 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print 1A-22 PRODUCTION PROFILE 000111 I 1 2M-02 Ct ! ~ INJECTION PROFILE 000113 I 1 2M-03 ,,J-- INJECTION PROFILE 000113 I 1 3G-26 PRODUCTION PROFILE 000116 I 1 3G-26 WATER FLOW LOG 000116 I 1 1 D-132 INJECTION PROFILE 000112 I I ,,, ...... Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. _ ,...] Anchorage, Alaska 99501 MWD Formation Evaluation Logs 3G-26, AK-MM-90142 November 23, 1999 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of~ Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 3G-26: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-103-20303-00 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20303-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia ~" 2;: i999 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 A Halliburton Company WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs November 11, 1999 3G-26, AK-MM-90142 1 LDWG formatted Disc with verification listing. API#: 50-103-20303-00 PLEASE ACKNOWLEDGE RECEIFr BY SIGNING AND RETURNING THE ATTACHED COPY OF THE TRANSM1TrAL LETrER TO TH~ ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 Date: :',t i~ 1999 ,'2dasim Oil & Gas Cons. Commission ,~c~ora~ 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 A Halliburton Company ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 1, 1999 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3G-26 (Perinit No. 99-75) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 3G-26. If there are any questions, please call 265-6890. Sincerely, G. C. Alvord Drilling Engineering Supervisor AAI Drilling GCA/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMmiSSIoN WELL COMPLETION OR RECOMPLETION REPORT ANDi: Gi V 1. Status of well Classification of Service Well Oil D Gas E] Suspended D Abandoned D Service D 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 99-75 ~SS~ 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-103-20303 4. Location of well at surface ,~~1~/I 9. Unit or Lease Name 2538'FNL, 370'FWL, Sec. 24, T12N, RSE, UM , :il ~'~ .'1~_ ~ :! Kuparuk River Unit At Top Producing Interval "~./i~t¢ ~i 10. Well Number 2412' FSL, 370' FEL, Sec. 13, T12N, RSE, UM , .~, .. · 3G-26 AtTotalDepth /.~, ,.~ 11.FieldandPool 2542' FSL, 245' FEL, Sec. 13, T12N, R8E, UM ' -- Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk River Pool RBK 30' feetI ADL 25547 ALK 2661 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 15. Water Depth, if offshore 16. No. of Completions July 30, 1999 August 16, 1999 August 19, 1999 N/A feetMSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 9850' MD/6388'TVD 9754' MD/6295'TVD YES [~] No E~ N/A feetMD 1802' 22. Type Electric or Other Logs Run GR, CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 110' 24" 265 sx AS I 7.625" 29.7# L-80 Surface 4344' ' 9.875" 350 sx AS III LW, 500 sx Class G 5.5" 15.5# L-80 Surface 9325' 6.75" 150 sx Class (3 3.5" 9.2# L-80 9161' 9850' 4.75" 61 sx Class G 24. Perforations open Io Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 9161' 9161' 9530'-9545' MD 6083'-6096' TVD 4 SPF 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9502'-9516' MD 6058'-6070' TVD 4 SPF DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9530'-9545', 9502'-9516' 1) 19000# sand on formation, 12000# in wellbore 2)128,000# in formation r n ikiAI Date First Production method of operation (Flowing, gas lift, etc.) U I~ I U i I '~ ~ L,, September 18, 1999 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL R/~TIO 10/17/1999 8.0 Test Period > 260 501 184 161I 2183 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) press. 194 psi 1194 24-Hour Rate > 780 1503 552 N/A 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A Form lO-4O7 Rev. 7-1-80 CONTINU ED ON REVERSE SIDE Submit in duplicate 29. NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A GEOLOGIC MARKERS MEAS. DEPTH 9351' 9435' 9486' 9621' TRUE VERT. DEPTH 5926' 5998' 6044' 6167' 30. FO RMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that lhe following is true and correct to the best of my knowledge. Questions? Call Mark Chambers 265-1319 Signed/~_,~,,~ (~. ~*~ Title Drillinq Engineerinq Supervisor Date Chip Alvord INSTRUCTIONS Prepared by Sharon AIIsup-Drake 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 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 Date: 09/21/99 ARCO ALASKA INC. WELL SIIMMARY REPORT Page: 1 WELL:3G-26 WELL_ID: AK0035 TYPE: STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD:07/30/99 START COMP: RIG:NORDIC 3 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20303-00 07/24/99 (D1) MW: 0.0 VISC: 0 PV/YP: 0/ 0 TD/TVD: 110/110 (110) TURNKEY RIG MOVE SUPV:D. WESTER/S. GOLDBERG Turnkey rig move from 1G to 3G. UPCOMING OPERATIONS:TURNKEY RIG MOVE APIWL: 0.0 07/25/99 (D2) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 110/110 ( 0) CONINUE TURN KEY RIG MOVE, AT '3B' PAD LAYING PLYWOOD SUPV:D. WESTER/S. GOLDBERG Continue turn key rig move from 1G pad. Accept rig for operations due to road conditions ~ 0800 hrs. Continue rig move to 3G pad. UPCOMING OPERATIONS:MOVE TO '3G' PAD 07/26/99 (D3) MW: 0.0 VISC: 0 PV/YP: 0/ 0 TD/TVD: 110/110 ( 0) MOVING RIG MATS AND PLYWOOD AROUND RIG SUPV:D. WESTER/S. GOLDBERG Move rig from CPF3 to Drillsite 3B. UPCOMING OPERATIONS:MAT ROAD FROM 3F TO 3G APIWL: 0.0 07/27/99 (D4) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 110/110 ( 0) FINISH LAYING MATTING BOARDS TO 3G SUPV:DEARL W. GLADDEN Move all matts and plywood around rig, lay plywood and matts from 3F pad to 3G pad. UPCOMING OPERATIONS:FINISH LAYING MATTS - MOVE RIG FROM 3F TO 3G 07/28/99 (D5) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 110/110 ( 0) FINISH N/U DIVERTER - LOAD D/P IN SHED & STRAP - MIX S SUPV:DEARL W. GLADDEN Continue to move rig. MIRU. N/U diverter. UPCOMING OPERATIONS:FINISH N/U DIVERTER - P/U & STANDBACK D/P IN DERRICK -P/ U BHA 07/29/99 (D6) MW: 8.6 VISC: 100 PV/YP: 20/40 APIWL: 15.0 TD/TVD: 110/110 ( 0) REPAIR BENT DERRICK BOARD SUPV:DEARL W. GLADDEN N/U diverter system and function test. UPCOMING OPERATIONS:P/U BHA - SPUD WELL - DRILL TO SURFACE TD Date: 09/21/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 07/30/99 (D7) MW: 9.0 VISC: 126 PV/YP: 0/ 0 APIWL: 10.6 TD/TVD: 940/110 (830) DRLG 9 7/8" HOLE ~ 1292' SUPV:DEARL W. GLADDEN Pre spud and safety meeting. Spud well, drilling 110' to 994' UPCOMING OPERATIONS:DRLG TO CSG PT - CONDITION MUD & HOLE - TOH L/D BHA - RUN 7 5/8" CSG 07/31/99 (D8) MW: 9.3 VISC: 73 PV/YP: 33/28 APIWL: 6.0 TD/TVD: 2606/2103 (1666) DRLG 9 7/8'' HOLE ~ 3474' SUPV:DEARL W. GLADDEN Drilling from 994' to 1076' Clay blinding screens, clean shaker screens, coat w/drill and slide - jet flowline. Drilling from 1076' to 2073' Tight hole and swab. Tight 1740' wash & ream. Wash and ream to bttm 2043' to 2073' Drilling 2073' to 2606' UPCOMING OPERATIONS:TD SURFACE HOLE - CIRCU & CONDITION MUD - SHORT TRIP - CIRCU & CONDITION - TOH 08/01/99 (D9) MW: 9.5 VISC: 71 PV/YP: 30/33 APIWL: 5.2 TD/TVD: 4350/3054 (1744) TIH W/HO SUPV:DEARL W. GLADDEN Drilling from 2606' to 4350', TD 7-5/8" casing point. Circ and condition for short trip. TOH. Swabbing and tight. UPCOMING OPERATIONS:MAKE C/O RUN W/HO - CIRCU & COND HOLE F/ CSG - T0H L/D HO - RUN 7 5/8" CSG 08/02/99 (D10) MW: 9.5 VISC: 70 PV/YP: 33/36 APIWL: 5.0 TD/TVD: 4350/3054 ( 0) CIRCU & CONDITION TO CMT 7 5/8" CSG SUPV:DEARL W. GLADDEN RIH w/hole opener. Wash 75' to bttm. Pump low/high sweep. PJSM. Run 7-5/8" casing. UPCOMING OPERATIONS:CMT CSG - N/D DIVERTER - M/U SPEED HEAD - N/U BOP'S - TEST BOPS 08/03/99 (Dll) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 4350/3054 ( 0) REPAIRING CASING HEAD SUPV:D. WESTER/S. GOLDBERG Continue to run 7-5/8" casing. Cement 7-5/8" casing. Plug bumped. Attempt to make up FMC casing head assembly. Torqued up without engaging seal. Connection failure between casing head and mandrel hanger. Attempt to back off casing head without success. UPCOMING OPERATIONS:FINISH CASING HEAD WORK. N/U BOPE AND TEST. Date: 09/21/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 08/04/99 (D12) MW: 8.5 VISC: 38 PV/YP: 8/10 APIWL: 7.6 TD/TVD: 4350/3054 ( 0) RUNNING IN HOLE WITH 6 3/4" BIT AND BHA SUPV:D. WESTER/S. GOLDBERG Continue to attempt to remove FMC casing head. Mandrel hanger is unusable due to damaged threads. Remove mandrel hanger. A new mandrel hanger with a pup was made up to the 7-5/8" casing. A new FMC casing head was successfully made up to this mandrel hanger. N/U BOPE and test to 250/3000 psi. OK. UPCOMING OPERATIONS:PRESSURE TEST CASING, DRILLOUT SHOE JOINTS AND 20' OF NEW HOLE, PERFORM LOT 08/05/99 (D13) MW: 8.8 VISC: 43 PV/YP: 10/13 APIWL: 6.4 TD/TVD: 5285/3543 (935) POOH TO CHECK TOOLS SUPV:D. WESTER/S. GOLDBERG Continue to test BOPE to 250/3000 psi. RIH and tag cement at 4126' MD. Clean out cement from inside casing. Drill float collar at 4258' and shoe at 4344' Drill 16' additional feet outside shoe (10' of new hole). Perform FIT to 16.1 ppg. No leak off. Drill 20' additional feet. CBU. Perform second test to 16.3 ppg. No leak off. Continue drilling from 4380' to 5284' UPCOMING OPERATIONS:RUN BACK IN HOLE AND CONTINUE DRILLING 08/06/99 (D14) MW: 9.1 VISC: 45 PV/YP: 13/18 APIWL: 6.0 TD/TVD: 6187/4001 (902) DRILLING AHEAD AT 6661' MD SUPV:D. WESTER/S. GOLDBERG Drilling from 5284' to 5428' Penetration rate slowing and unusual standpipe pressure fluctuations. Circulate well clean with reciprocation and rotation. POOH to 7-5/8" shoe. Check pump pressure there. Still high. Pump dry job. POOH. Bit balled with cement and clay. Two nozzles plugged. RIH w/HWDP and jars. drilling ahead from 5428' to 6187' UPCOMING OPERATIONS:CONTINUE DRILLING TO APPROX 9000' PERFORM 3RD LOT. 08/07/99 (D15) MW: 9.2 VISC: 50 PV/YP: 16/20 APIWL: 5.2 TD/TVD: 7333/4561 (1146) DRILLING AHEAD AT 7770' SUPV:D. WESTER/S. GOLDBERG Drilling ahead from 6181' to 6757'. Minimal slides for angle. Circulate to clean up well. ECD steadily climbing. Hole packed off. Working pipe. Circulate low viscosity sweep around. Continue circulating well clean until ECD dropped back to approx. 10.7 ppg. Continue drilling ahead from 6757' to 7141' Pump low viscosity sweep around. Some success with cuttings over shakers. Hole packed off and ECD spiked to 14.0 ppg. Cleaned up quickly with circulation and off bottom rotation. Short trip 19 stands to 5320' Drilling ahead from 7141' to 7333' UPCOMING OPERATIONS:CONTINUE DRILLING TO APPROX. 9000' FOR LOT Date: 09/21/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 08/08/99 (D16) MW: 10.4 VISC: 46 PV/YP: 18/21 APIWL: 2.8 TD/TVD: 8583/5260 (1250) DRILLING AHEAD AT APPROX. 8800' MD SUPV:D. WESTER/S. GOLDBERG Drilling from 7333' to 8293' Change liners in pumps from 5.5" to 4.5". Continue drilling ahead from 8293' to 8583' UPCOMING OPERATIONS:DRILL TO APPROX. 9000' MD. PERFORM LOT. 08/09/99 (D17) MW: 11.0 VISC: 48 PV/YP: 19/21 APIWL: 2.8 TD/TVD: 9251/5841 ( 668) TD'D HOLE SECTION AT 9327' MD, 5854 TVD. (K-1 MARKER) SUPV:D. WESTER/S. GOLDBERG Drilling ahead from 8583' to 8773' Successful sliding to drop angle. Pump sweep around with little success. Continue drilling from 8773' to 8908' Perform LOT. Broke down at 12.9 ppg at shoe. Continue drilling from 8908' to 9225' Losing 10-15 bph of fluid while drilling. ECD 11.8 ppg. Circulating and conditioning mud. Blending in high weight fluid to increase mud weight to 11.0 ppg. Continue to lose fluid. Perform LOT with LCM pill placed in annulus. Leaked off with 13.7 ppg at shoe. Circulate LCM pill out of hole. Continue drilling ahead from 9225' to 9251' UPCOMING OPERATIONS:TRIP BACK TO BOTTOM, C&C MUD, POOH LDDP 08/10/99 (D18) MW: 11.0 VISC: 43 PV/YP: 16/14 APIWL: 3.0 TD/TVD: 9327/5846 ( 76) L/D 4" DP SUPV:DEARL W. GLADDEN Drilling 9251' to 9327' TOH, slight tight spot ~ 8725' 08/11/99 (D19) MW: 11.0 VISC: 50 PV/YP: 22/18 TD/TVD: 9327/5846 ( 0) CEMENT 5 1/2'' CSG SUPV:DEARL W. GLADDEN PJSM. Run 5.5" casing. APIWL: 2.8 08/12/99 (D20) MW: 11.0 VISC: 37 PV/YP: 12/15 APIWL: 4.0 TD/TVD: 9327/5846 ( 0) N/U BOPS SUPV:DEARL W. GLADDEN Continue TIH w/5.5" casing. Lost total 105 bbls mud. Install cement head, attempt to break circ. Lost 100 bbls, no returns. PJSM. Cement 5.5" casing. N/D BOPs. After BOPs N/D it was observed that 7-5/8" well head was loose. Wait on cement. Remove and re-install wellhead. 08/13/99 (D21) MW: 11.5 VISC: 41 PV/YP: 15/25 APIWL: 3.4 TD/TVD: 9327/5846 ( 0) P/U BHA SUPV:DEARL W. GLADDEN M/U wellhead on fluted hanger. Attempt to set tubing head packoff, will not test. Freeze protect well. P/U BOP stack so inside of tbg spool can be inspected for leak. Attempt several more test, still bleeding off, pressure loss seems to be slowing down. N/U BOPs and test. Kill line conn leaking. Date: 09/21/99 ARCO ALASKA INC. WELL SIRVfMARY REPORT Page: 5 08/14/99 (D22) MW: 11.5 VISC: 42 PV/YP: 17/21 TD/TVD: 9327/5846 ( 0) CIRCU & CONDITION TO PERFORM FIT SUPV:DEARL W. GLADDEN Test BOPs to 250/3000 psi. PJSM. APIWL: 2.5 08/15/99 (D23) MW: 11.6 VISC: 45 PV/YP: 23/30 APIWL: 2.2 TD/TVD: 9811/6329 ( 484) CIRCU & CONDITION AFTER SHORT TRIP SUPV:DEARL W. GLADDEN Wash and ream CMT stringers 9196'-9227' Drilling plugs, CMT, float & shoe =10' new hole 9277' to 9337' Perform FIT to 13.5 ppg EMW. PJSM. Drill blind from 9337' to 9811' 08/16/99 (D24) MW: 11.7 VISC: 48 PV/YP: 17/31 APIWL: 2.2 TD/TVD: 9850/6350 ( 39) RUN 3 1/2" LINER SUPV:DEARL W. GLADDEN Drilling 9811' to 9850'. TOH slow to shoe (9325') no swab, no tight hole. Monitor well for flow, BOP drill, safety meeting. TIH slow to bttm 9850', no fill. Monitor well, static. TOH slow, hole will swab if pulled faster than 30/min. Pulling wet. TOH, slow, pulling wet. Run #1, GR/CCL and continuous survey. 08/17/99 (D25) MW: 8.5 VISC: 28 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 9850/6350 ( 0) SUPV:D. WESTER/S. GOLDBERG Continue wireline logging well. Test BOPE to 300/3000 psi. Run liner assembly. Pump cement. 08/18/99 (D26) MW: 8.5 VISC: 28 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 9850/6350 ( 0) LOADING PIPE SHED WITH 3 1/2" SUPV:D. WESTER/S. GOLDBERG Continue displacing well to seawater. Clean out surface equipment. Safety meeting. POOH laying down 2-7/8" drillpipe. R/U 4" handling equipment. Unable to breakout 4" drillpipe due to excessive torque. 08/19/99 (D27) MW: 8.5 VISC: 28 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 9850/6350 ( 0) CLEANING LOCATION IN PREPARATION TO MOVE RIG SUPV:D. WESTER/S. GOLDBERG Run 3.5" tubing completion. N/D BOP stack, N/U tree. 08/20/99 (D28) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 9850/6350 ( 0) RIG RELEASED AT 09:00 8/20/99 SUPV:D. WESTER/S. GOLDBERG Continue to N/U tree. Test packoff to 5000 psi. test tree to 250/5000 psi. Freeze protect to 3100'. Set BPV. Back rig off well. Rig released at 0900 hrs 8/20/99 SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-07023 Sidetrack No._ ...... Page I of _5... Company ARCO ALASKA, INC. Rig Contractor & No. NORDIC- 3 Field _KUp~_RLJ. KRIV~R- UNIT Well Name & No. PAD 3G/26 Survey Section Name Definitive Survey BHI Rep. LYNN HENSLEY Jl'Jllilrr~~ WELL DATA Target'l-VD (F'r) Target Coord. N/S Slot Coord. N/S -2537.70 Grid Correction 0.000 Depths Measured From: RKB Target Description Target Coord. E/W Slot Coord. EAN 371.37 Magn. Declination 26.638 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft~ 30m~ 10mil'j Vert. Sec. Azim..___4_2._6_.4_ .......... Magn. to Map Corr. __.__26:~3.8' ..... Map North to: OTHER .... SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (F-T) (Fl') (FT) (FT) (Per ~00 F'r) Drop (-) Left (-) MWD 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT 30-JUL-99 MWD 110.00 0.00 0.00 110.00 110.00 0.00 0.00 0,00 0.00 0.00 8' MACH 1C - 1.4 DEG AKO 30-JU L-99 MWD 202.50 0.23 54.51 92.50 202.50 0.18 0.11 0.15 0.25 0.25 30-JUL-99 MWD 292.92 2.99 28.77 90.42 292.88 2.65 2.28 1.43 3.08 3.05 30-JUL-99 MWD 383.30 4.72 33,74 90.38 383.05 8.61 7.44 4.63 1.95 1.91 30-J U L-99 MWD 474.74 8.44 39.00 91.44 473.87 19.03 15.79 10.95 4.12 4.07 5.75 30-JUL-99 MWD 565.28 10.76 38.66 90.54 563.14 34.09 27.55 20.41 2.56 2.56 -0.38 30-JUL-99 MWD 655.28 12.53 38.76 90.00 651.28 52.22 41.73 31.77 1.97 1.97 0.11 __ 30-JUL-99 MWD 746.90 13.52 38.83 91.62 740.54 72.82 57.82 44.71 1.08 1.08 0.08 30-JUL-99 MWD 837.98 15,07 40.33 91.08 828.80 95.27 75.14 59.05 1.75 1.70 1.65 ., 30-J U L-99 MWD 928.79 18.22 41.61 90.81 915.79 121.27 94.76 76.12 3.49 3.47 1.41 31 -JUL-99 MWD 1022.85 20.58 43.77 94,06 1004.51 152.51 117.69 97.33 2,62 2.51 2.30 -- __ 31 -JUL-99 MWD 1111.61 25.09 43.10 88.76 1086.29 186.94 142.71 120.99 5.09 5.08 -0.75 31 -JUL-99 MWD 1209.76 26.83 42.73 98.15 1174.53 229.90 174.18 150.24 1.78 1.77 -0.38 31 -JU L-99 MWD 1305.17 28.87 41.21 95.41 1258.89 274.46 207.33 180.03 2.26 2.14 -1.59 31 -JUL-99 MWD 1401.35 32.03 41.17 96.18 1341.79 323.19 244.00 212.12 3.29 3.29 . -0.04 31 -JUL-Dg MWD 1497.26 33.07 39.50 95.91 1422.64 374.74 283.34 245.51 1.43 1.08 -1.74 31 -JUL-99 MWD 1591.64 35.27 38.90 94.38 1500.72 427.65 324,42 279.01 2.36 2.33 -0,64 31 -JUL-99 MWD 1688.10 38,48 40.96 96.46 1577.88 485,46 368.77 316,18 3,57 3,33 2.14 31-JUL-99 MWD 1783.61 ' 42.35 41.37 95,51 1650.58 547.34 415.37 356.94 4.06 4.05 0.43 3i -JUL-99 MWD 1879.58 46.61 41.22 95.97 1719.04 614.55 465.89 401.30 4.44 4.44 -0.16 31 -JU L-99 MWD 1975.69 51.26 42,52 96,11 1782,16 686.99 519,81 449.67 4.94 4.84 1.35 31 -JUL-99 MWD 2069,53 54.02 42.77 93.84 1839.10 761.57 574.67 500.20 2,95 2.94 0,27 31 -JU L-99 MWD 2167,26 56.55 42.95 97,73 1894,75 841,89 633.55 554.84 2,59 2.59 0.18 SURVEY CALCULATION AND FIELD WORKSHEET Job.o. 'age _2_ .... of . 5 = |1[~ =-I:~t Company ARCO ALASKA, INC. Rig Contractor & No. __N_O_R__D!_C._-_3 ..................... Field _K U_ . .P. .A_ _R UK RIVER UNIT ....... Well Name & No. PAD 3G/26 Survey Section Name Definitive Survey BHI Rep. LYNN HENSLEY ~r~~ WELL DATA Target'I-VD (FT) Target Coord. N/S Slot Coord. N/S -2537.70 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS~ Target Description Target Coord. E/VV Slot Coord. ENV 371.37 Magn. Declination 26.638 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft~ 30mL_-] 10m~_] Vert. Sec. Azim. 42.64 Magn, to Map Corr. __._ 2_6.~3.8____ Map North to: OTHER ..... SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length 'I-VD Section N(+) / S(-) Ei~i-)-W'(-~-- DE Build (+) Right (+) Comment Type (FT) (DD) (OD) (F-T) (FT) (FT) (FT) (Per 700 F-r) Drop (-) Left (-) 31 -JUL-99 MWD 2263,18 56,00 43,34 95,92 1948,01 921.67 691,75 609.39 0,67 -0.57 0.41 31-JUL-99 MWD 2359,29 57,06 43.08 96.11 2001,01 1001.83 750.19 664.28 1,13 1,10 -0,27 31 -J UL-99 MWD 2455.80 58,02 42.77 96.51 2052.81 1083.26 809,82 719.74 1,03 0,99 -0,32 31 -J UL-99 MWD 2549,94 57.04 42,70 94.14 2103,35 1162.69 868.15 773.64 1.04 -1,04 -0.07 __ 31 -J U L-99 MWD 2642.66 58,65 41,23 92,72 2152,69 1241,17 926,52 826,12 2,19 1,74 -1.59 31 -J U L-99 MWD 2735.84 57,80 41.49 93.18 2201,76 1320,37 985,98 878,46 0,94 -0,91 0,28 01 -AUG-99 MWD 2838,50 57.70 39,89 102,66 2256,54 1407,13 1051,81 935,06 1.32 -0,10 -1,56 ..... 01-AUG-99 MWD 2933,31 58.51 40,91 94.81 2306.64 1487.57 1113.10 987.23 1,25 0,85 1.08 01 -AUG-99 MWD 3031,10 57,74 40,72 97,79 2358,28 1570,57 1175.95 1041.51 0.80 -0,79 -0.19 __. 01 -AUG-99 MWD 3126,82 58.83 41.54 95.72 2408,60 1651,96 1237~28 1095.07 1,35 1,14 0.86 , 01 -AUG-99 MWD 3224,60 57,95 41,00 97.78 2459,85 1735,21 1299,87 1150,00 1,02 -0,90 -0.55 01 -AUG-99 MWD 3319,53 58,54 41,78 94,93 2509.81 1815.91 1360.42 1203.37 0,94 0.62 0.82 01 -AUG-99 MWD 3417,50 57,86 41.51 97.97 2561,43 1899,16 1422.64 1258.70 0.73 -0,69 -0.28 ..................................... 01 -AUG-99 MWD 3513,93 58.76 43.14 96.43 2612.09 1981.21 1483,30 1313,95 1,71 0,93 1,69 01 -AUG-99 MWD 3609,56 57,65 43,14 95,63 2662,48 2062,48 1542,61 1369,53 1,16 -1,16 0.00 01 -AUG-99 MWD 3705,05 58,79 41,90 95.49 2712,77 2143,65 1602,44 1424,38 1,63 1,19 -1,30 01-AUG-99 MWD 3801,11 57.81 41,38 96,06 2763,25 2225,37 1663,51 1478,69 1.12 -1,02 -0.54 01 -AUG-99 MWD 3897,38 56,76 41,77 96.27 2815,28 2306.35 1724,11 1532,44 1,14 -1,09 0,41 01 ,AUG-99 MWD 3993,82 57,88 ,43,08 96,44 2867,35 2387.52 1784,02 1587,20 1,63 1,16 1,36 01 -AUG-99 MWD 4087,98 58,96 43.76 94.16 2916,66 2467.73 1842,28 1642,34 1,30 1.15 0,72 01 -AUG-99 MWD 4184,29 57,69 43,19 96.31 2967,23 2549.68 1901,75 1698,73 1,41 -1.32 -0.59 01 -AUG-99 MWD 4279,50 58,70 44.08 95.21 3017,41 2630,58 1960,31 1754,57 1,33 1,06 0,93 05-AUG-99 MWD 4385.61 57.61 43.92 106.11 3073.39 2720.69 2025.15 1817:18 1.04 -1.03 -0.15 4-3/4" Mach 1XL- 1.2 Deg AKO 05-AUG-99 MWD 4480.87 57.40 43.77 95.26 3124.57 2801.02 2083.10 1872.84 0.26 -0.22 -0.16 SURVEY CALCULATION AND FIELD WORKSHEET ~,o_ _0~__~_~... s~-,,~,o.. ........ ~age __3 Company ARCO ALASKA, INC. _ ........ Rig Contractor & No. _N _ORD_IC.-__;3 ...................................... Field KUPARUK_ RIVER_ UNI_T- ..................... Well Name & No. PAD 3G/26 __ Survey Section Name Definitive Survey BHI Rep. LYNN HENSLEY ~lrrEi~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S ....... .-25_37_.__7.0. ...... Grid Correction .... _0._0_~.0- ............ Depths Measured From: EKE ~1 MSL~-_i SS!.'i Target Description Target Coord. E/W Slot Coord. E/W 371.37 Magn. Declination 26.638 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft~ 30ml~ 10m~_.l Vert. Sec. Azim. 42.64 Magn. to Map Corr. 26.638 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length 'I-VD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (F'I') (FT) (FT) (FT) (Per ~00 ET) Drop (-) Left (-) 05-AU G-99 MWD 4575.19 57.16 43,81 94.32 3175.55 2880.35 2140.38 1927.75 0.26 -0.25 0.04 , 05-AUG-99 MWD 4674.49 57.84 44.63 99.30 3228.91 2964.07 .... -;~);i'~0-' 1986.16 0.98 0.68 0.83 05-AUG-99 MWD 4769.59 58.68 44.95 95.10 3278.94 3044.89 2257.79 2043.14 0.93 0.88 0.34 05-AUG-99 MWD 4866.58 58.33 44.96 96.99 3329.61 3127.52 2316.32 2101.57 0.36 -0.36 0.01 05-AUG-99 MWD 4962.24 58.24 44.04 95.66 3379.90 3208.85 2374.36 2158.61 0.82 -0.09 -0.96 05-AU G-99 MWD 5058.39 57.98 43.88 96.15 3430.69 3290.47 2433.12 2215.28 0.31 -0.27 -0.17 . , 05-AUG-99 MWD 5152.56 59.90 43.96 94.17 3479.27 3371.11 2491.23 2271.23 2.04 2.04 0.08 06-AUG-99 MWD 5248.35 60.10 43.68 95.79 3527.17 3454.05 2551.08 2328.67 0.33 0.21 -0.29 06-AUG-99 MWD 5344.44 60.74 43.89 96.09 3574.60 3537.60 2611.41 2386.49 0.69 0.67 0.22 , 06-AUG-99 MWD 5438.98 60.15 43.74 94.54 3621.23 3619.82 2670.75 2443.43 0.64 -0.62 '-0.16 06-AUG-99 MWD 5536.17 59.54 43.55 97.19 3670.06 3703.85 2731.56 2501.43 0.65 -0.63 -0.20 06-AUG-99 MWD 5632.68 59.12 43.20 96.51 3719.29 3786.85 2791.90 2558.44 0.54 -0.44 -0.36 06-AUG-99 MWD 5728.85 59.31 43.17 96.17 3768.50 3869.47 2852.14 2614.98 0.20 0.20 -0.03 06-AUG-99 MWD 5823.83 59:70 43.10 94.98 3816.70 3951.31 2911.87 2670.94 0.41 0.41 -0.07 06-AUG-99 MWD 5920.90 59.87 43.14 97.07 3865.55 4035.19 2973.10 2728.28 0.18 0.18 0.04 .___ 06-^UG-99 MWD 6016.53 59.14 43.1'8 95.63 3914.08 4117.58 3033.20 2784.64 0.76 -0.76 0.04 07-AUG-99 MWD 6112.54 59.01 43.20 96.01 3963.42 4199.94 3093.25 2841.01 0.14 -0.14 0.02 07-AUG-99 MWD 6208.09 59.01 44.09 95.55 4012.62 4281.84 3152.52 2897:54 0.80 0.00 0.93 07-AUG-99 MWD 6304.26 58.90 43.17 96.17 4062.21 4364.22 3212.16 2954.40 0.83 -0.11 -0.96 07-AUG-99 MWD 6400.65 59.13 43.32 96.39 4111.84 4446.85 3272.36 3011.01 0.27 0.24 0.16 07-AUG-99 MWD 6495.80 59.66 43.01 95.15 4160.28 4528.74 3332.09 3067.03 0.62 0.56 -0.33 07-AUG-99 MWD 6591.63 59.36 43.44 95.83 4208.90 4611.32 3392.26 3123.59 0.50 -0.31 0.45 07-AUG-99 MWD 6688.04 59.97 43.55 96.41 4257.60 4694.52 3452.62 3180.86 0.64 0.63 0.11 07-AUG-99 MWD 6784.78 59.33 43.18 ~i-~'~ ....... ~4'3'~6148 ...... ~ ~'-~-.-9'~ .................. : "~'i'~i'~i- ...... ~2-3~ii'~ ........... 01~4 -0.66 -0.38 SURVEY CALCULATION AND FIELD WORKSHEET . No. ~__O~,_._I_-07 _(~., Sidetrack No. Page _=[,i~_=l ::~._..~ Company ARCO ALASKA, ,_N_C_ ...... Rig Cont~acto~ & No...~K~. _:.3 .............. Field _K.U__PARUK. RIVER_UN__~- Well Name & No, PAD 3G/26 Survey Section Name Definitive Survey BHI Rep. LYNN HENSLEY J~ii~r~ WELL DATA .. Target TVD (FT) Target Coord. N/S Slot Coord, N/S -2537.70 ..... Grid Correction 0.000 Depths Measured From: RKB i Target Description ............. Target Coord. E/W Slot Coord. E/W 371.37 Magn. Declination 26.638 Calculation Method MINIMUM CURVATURE I I Target Direction (DP) Build\Walk\DL per: 100ft~ 30m[~_~ 10ml~ Vert. Sec. Azim. 42.64 Uagn. to Map Corr. 26.638 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical--.T°tal Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (IT) (F-'T) (FT) (Per ~00 F~ Drop (-) Left (-) 07-AUG-99 MWD 6880.47 59,49 44.22 95.69 4355.17 4860.35 3572.87 3295.09 0.95 0.17 1.09 --, 07-AUG-99 MWD 6977.55 57.32 44.11 97.08 4406.03 4943.01 3632.18 3352.70 2.24 -2.24 -0.11 ' 07-AUG-99 MWD 7074.13 57,20 44.33 96.58 4458,26 5024.21 3690.40 3409.36 0.23 -0.12 0.23 09-AUG-99 MWD 7169.81 57,28 42.70 95.68 4510.04 5104.66 3748.75 3464.76 1.44 0,08 -1.70 07-AUG-99 MWD 7265.77 57.53 42.88 95.96 4561.73 5185,51 3808.07 3519.68 0.30 0.26 0.19 __ 08-AUG-99 MWD 7362.41 57,61 42.58 96.64 4613,56 5267.07 3867.99 3575.03 0.27 0.08 -0.31 -- 08-AUG-99 MWD 7457.23 57,86 41.83 94.82 4664.18 5347.25 3927.38 3628.89 0.72 0.26 -0.79 ' " .............. -..__. . ................................. 08-AUG-99 MWD 7554.10 58.87 41.66 96.87 4714.99 5429.71 3988.92 3683.80 1,05 1.04 -0.18 08-AUG-99 MWD 7648.56 58.99 41.88 94.46 4763.74 5510.61 4049.26 3737.70 0.24 0,13 0.23 ................................................ ~ ................................ : ..........................................................................................._. 08-AUG-99 MWD 7744.32 59.17 41.60 95,76 4812.94 5592.75 4110.56 3792.39 0.31 0,19 -0.29 .,. .. 08-AUG-99 MWD 7840.71 57,87 41.10 96.39 4863.28 5674.93 4172.27 3846.70 1.42 -1,35 -0.52 ......................................... .......................................................... 08-AUG-99 MWD 7936.93 55.82 41.07 96.22 4915.90 5755.46 4232.98 3899.63 2.13 -2.13 -0.03 ...................... 08-AUG-99 MWD 8033,01 54.99 40.02 96.08 4970.45 5834.49 4293.08 3951.05 1.25 -0.86 -1.09 · ,.. ._ 08-AUG-99 MWD 8129.59 54,22 39.40 96,58 5026.39 5913.12 4353.64 4001.35 0.95 -0.80 -0.64 ......................... ..................... 08-AUG-99 MWD 8225.05 52.67 41.59 95.46 5083.25 5989.73 4411.96 4051.13 2.46 -1.62 2.29 -- -- ................................................ 08-AUG-99 MWD 8320.78 52.73 39.71 95.73 5141.26 6065,83 4469.73 4100.73 1.56 0.06 . -1.96 ........ ___ 08-AUG-99 MWD 8416,49 51.77. 41.73 95.71 5199.86 6141.46 4527.09 4150.09 1.95 -1.00 2,11 -- 08-AU G-99 MWD 8512.41 49.61 41.88 95.92 5260.62 6215.66 4582,40 4199.55 2.26 -2.25 0,16 -- ................. 09-AUG-99 MWD 8609,27 46.53 . 42.56 96.86 5325.34 6287.71 4635.77 4247.96 3.22 -3,18 0.70 .......... . ............................................ ~ .................................. 09-AUG-99 MWD 8705,16 42.70 42.50 95.89 5393.58 6355.05 4685.39 4293.48 3.99 -3.99 -0.06 ................ 09-AUG-99 MWD 8801.40 39.34 42.40 96.24 5466.19 6418.20 4731.99 4336.11 3.49 -3.49 -0,10 -~_ ~ .............................. ~ ..................... ~ ..... ~ ............ 09-AUG-99 MWD 8895.37 35.96 42.54 93.97 5540.58 6475,59 4774.33 4374.86 3.60 -3.60 0.15 .......................................................... ~ ........................................................................................ 09-AUG-99 MWD 8992.69 32,50 43.42 97.32 5621.03 6530.33 4814.38 4412.16 3.59 -3.56 0,90 .................................................................................................. ......................................................................................................................... 09-AUG-99 MWD 9088.57 31.95 43.22 95.88 5702.14 6581.45 4851.58 ..... i"~'~4'~4'~'i ~ ..... 0.58 -0.57 -0.21 · i j"jjjm, j(j3j,~) SURVEY CALCULATION AND FIELD WORKSHEET Job No. 045_?.-0_7_O2_3 .... Sidetrack No,_ ........ Page 5 of I =¢~--~· == [l_r~_=l Company ARCO ALASKA, INC. _ ....... Rig Contractor & No. __NORDIC.:._3 ............................ Field Kup_ARUK RIV.ER UNIT ............ Well Name & No. PAD 3G/26 Survey Section Name Definitive Survey BHI Rep. LYNN HENSLEY WELL DATA ..................................................................................................................................... Target'I-VD (Fr) Target Coord. N/S Slot Coord. N/S -2537.70 Grid Correction 0.000 ...... Depths Measured From: RKB HI MSL~I ss~ Target Description Target Coord. E/VV Slot Coord. E/W 371.37 Magn. Declination 26.638 Calculation Method MINIMUM CURVATURE ........................... Target Direction (DD) Build\Walk\DL per: 100ft~ 30ml--_l 10m~ Vert. Sec. Azim. 42.64 Magn. to Map Corr. 26.638 Map North to: OTHER ........................................... SURVEY DATA Survey i ....... Total Coordinate Build Rate Walk Rate Date Tool Survey Incl. Hole Course Vertical _ Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (FT) (FT) (FT) (Per ~00 FT) Drop (-) Left (-) ___ ...... ....................................... 09-AUG-99 MWD 9184.94 31.63 43.18 96.37 5784.05 6632.22 4888.59 4481.99 0.33 -0.33 -0.04 ........................................................... J-L 09-AUG-99 MWD 9257.71 31.68 43.11 72.77 5845.99 6670.41 4916.45 4508.11 0.09 0,07 -0.10 ___ ......................... 17-AUG-99 MMS 9340.00 31.34 41.85 82.29 5916.15 6713,41 4948.17 4537.15 0.90 -0.41 -1.53 -S-~'~-~--(~ ~l'~ ~'U ~ ~ S'"i~'~/~ -~y-~- , .:. __ .......................................................................................... 17-AUG-99 MMS 9440.00 29.19 41.19 100.00 6002.52 6763.80 4985.89 4570.57 2.18 -2.15 -0.66 ..................... , ............................................................ 17-AUG-99 MMS 9540.00 24.54 41.62 100.00 6091.70 6808.96 5019.79 4600.43 4.65 -4.65 0.43 17-AUG-99 MMS 9640.00 18.54 43.07 100.00 6184.67 6845.66 5046.95 4625.11 6.02 -6.00 1.45 -- .......... ................... ~..____ 17-AUG-99 MMS 9740,00 13.19 46.35 100.00 6280.83 6872.96 5066.45 4644.23 5.42 -5,35 3,28 17-AUG-99 MMS 9820.00 11.62 46.33 80.00 6358.96 6890.11 5078.32 4656.66 1.96 -1,96 -0.02 -- 17-AUG-99 MMS 9850.00 11.62 46.33 30.00 6388.35 6896,14 5082.49 4661.04 0.00 0.00 0.00 PROJECTED DATA - No Survey ' ;.' _ ____ , /, __ __ ........... ..... __ _ ............. .......... .... ................ _. ___ __ .............................................................................................................................. ................................................................................. . ................... ........... Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 3G, Slot 3g-26 3G-26 Job No. AKMM90142, Surveyed: 10 August, 1999 SURVEY REPORT 19 August, 1999, ORIGINAL Your Reft 500292030300 Surface Coordinates: 5988560.51 N, 498749.57 E (70° 22' 47.9256" N, 150° 00' 36.6000" W) Kelly Bushing: 82.0Oft above Mean Sea Level sper',r', -sun D, R I L L, I N I~,, , S, E R V.,I ,r" Ei 5 Survey Ref: svy8729 A tlALI,IBURT~N COIV[PAN~ D Ft I I_/I ~ I:S 19-Aug-99 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 3G-26 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 9,327.O0' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company Sperry-Sun Drilling Services Survey Report for 3G-26 Your Ref: 500292030300 Job No. AKMM90142, Surveyed: 10 August, 1999 Prudhoe Bay Unit Measured Depth (ft) Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 0.00 0.000 0.000 -82.00 0.00 202.50 0.230 54.510 120.50 202.50 292.91 2.990 28.770 210.87 292.87 383.30 4.720 33.740 301.05 383.05 474.74 8.440 39.000 391.87 473.87 565.37 10.760 38.660 481.22 563.22 655.28 12.530 38.760 569.28 ' 651,28 746.90 13.520 38,830 658.54 740.54 837.98 15.070 40.330 746.80 828.80 928.79 18.220 41.610 833.79 915.79 1022.85 20.580 43.770 922.51 1004.51 1111.61 25.090 43.100 1004.29 1086.29 1209.76 26.830 42.730 1092.53 1174.53 1305.17 28.870 41.210 1176.89 1258.89 1401.35 32.030 41.170 1259.79 1341.79 1497.26 33.070 39.500 1340.64 1422.64 1591.64 35.270 38.900 1418.72 1500.72 1688.10 38.480 40.960 1495.88 1577.88 1783.61 42.350 41.370 1568.58 1650.58 1879.58 46.610 41.220 1637.04 1719.04 1975.69 51.260 42.520 1700.16 1782.16 2069.53 54.020 42.770 1757.10 1839.10 2167.26 56.550 42.950 1812.75 1894.75 2263.18 56.000 43.340 1866.01 1948.01 2359.29 57.060 43.080 1919.01 2001.01 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 0.00 N 0.00 E 5988560.51 N 498749.57 E 0.24 N 0.33 E 5988560.75 N 498749.90 E 2.41 N 1.61 E 5988562.92 N 498751.18 E 7:57 N 4.81 E 5988568.08 N 498754.39 E 15.91 N 11.13 E 5988576.42 N 498760.70 E 27.69 N 20.60 E 5988588.20 N 498770.18 E 41.85 N 31.95 E 5988602.36 N 498781.53 E 57.94 N 44.89 E 5988618.45 N 498794.47 E 75.27 N 59.23 E 5988635.77 N 498808.81 E 94.88 N 76.30 E 5988655.38 N 498825.89 E 117.82 N 97.50 E 5988678.31 N 498847.09 E 142,84 N 121.17 E 5988703.33 N 498870.76 E 174,31 N 150.42 E 5988734.79 N 498900,02 E 207.45 N 180.21 E 5988767.93 N 498929.81 E 244.13 N 212.30 E 5988804.61 N 498961.91 E 283.47 N 245.69 E 5988843.94 N 498995.31 E 324.55 N 279.18 E 5988885.01 N 499028.81 E 368.90 N 316.36 E 5988929.36 N 499065.99 E 415.50 N 357.11 E 5988975.95 N 499106.75 E 466.01 N 401.48 E 5989026.45 N 499151,12 E 519,94 N 449.85 E 5989080.37 N 499199.50 E 574.79 N 500.37 E 5989135.22 N 499250.04 E 633.67 N 555.02 E 5989194.09 N 499304.69 E 691.88 N 609.57 E 5989252.29 N 499359,26 E 750.31 N 664.46 E 5989310.71 N 499414.16 E Alaska State Plane Zone 4 Kuparuk 3G Dogleg Vertical Rate Section (°/100ft) (ft) Comment 0.00 0.114 0.40 3.080 2.87 1.948 8.83 4.117 19.25 2.561 34.33 1.969 52.44 1.081 73.04 1.750 95.50 3.492 121.50 2.622 152.74 5.089 187.17 1.780 230.13 2.264 274.69 3.286 323.42 1.433 374.98 2.358 427,89 3.566 485.7o 4.061 547.59 4.440 614.81 4.944 687.24 2.949 761.82 2.593 842.15 0.666 921.92 1.126 1002.09 Continued... 19 August, 1999 - 8:32 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for 3G-26 Your Ref: 500292030300 Job No. AKMM90142, Surveyed: 10 August, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 2455.93 58.020 42.770 1970.88 2052.88 2549.94 57.040 42.700 2021.35 2103.35 2642.66 58.650 41.230 2070.69 2152.69 2735.84 57.800 41.490 2119.76 2201.76 2838.50 57.700 39.890 2174.55 2256.55 2933.31 58.510 40.910 2224.64 2306.64 3031.10 57.740 40.720 2276.28 ' 2358.28 3126.82 58.830 41.540 2326.60 2408.60 3224.60 57.950 41.000 2377.85 2459.85 3319.53 58.540 41.780 2427.81 2509.81 3417.50 57.860 41.510 2479.43 2561.43 3513.93 58.760 43.140 2530.09 2612.09 3609.56 57.650 43.140 2580.48 2662.48 3705.05 58.790 41.900 2630.77 2712.77 3801.11 57.810 41.380 2681.25 2763.25 3897.38 56.760 41.770 2733,28 2815.28 3993.82 57.880 43.080 2785.35 2867.35 4087.98 58.960 43.760 2834,66 2916.66 4184.29 57.690 43.190 2885.23 2967.23 4279.50 58.700 44.080 2935.41 3017.41 4385,61 57.610 43.920 2991.39 3073.39 4480.87 57.400 43.770 3042.57 3124.57 4575.19 57.160 43.810 3093.55 3175.55 4674.49 57.840 44.630 3146.91 3228.91 4769.59 58.680 44.950 3196.94 3278.94 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 810.02 N 719.99 E 5989370.41N 499469.70 E 868.28 N 773.81 E 5989428.66 N 499523.53 E 926.65 N 826.29 E 5989487.02 N 499576.02 E 986.10 N 878.64 E 5989546.47 N 499628.37 E 1051.93 N 935.24 E 5989612.29 N 499684,99 E 1113.23 N 987.41E 5989673.57 N 499737.17 E 1176.08 N 1041.69 E 5989736.41N 499791.46 E 1237.40 N 1095,25 E 5989797.73 N 499845.03 E 1299.99 N 1150.18 E 5989860.31N 499899.97 E 1360.55 N 1203.55 E 5989920.86 N 499953.35 E 1422.77 N 1258.88 E 5989983.07 N 500008.69 E 1483.42 N 1314.13 E 5990043.71 N 500063.95 E 1542.73 N 1369.71 E 5990103.01 N 500119.53 E 1602.56 N 1424.56 E 5990162.83 N 500174.40 E 1663.64 N 1478.87 E 5990223.90 N 500228.71 E 1724.23 N 1532.61 E 5990284.49 N 500282.47 E 1784.14 N 1587.38 E 5990344.39 N 500337.25 E 1842.40 N 1642.51 E 5990402.64 N 500392.39 E 1901.88 N 1698.91E 5990462.11N 500448.80 E 1960.44 N 1754.74 E 5990520.65 N 500504.64 E 2025.28 N 1817.36 E 5990585.48 N 500567.27 E 2083.22 N 1873.02 E 5990643.42 N 500622.93 E 2140,51 N 1927.93 E 5990700.69 N 500677.86 E 2200.52 N 1986.34 E 5990760.70 N 500736.28 E 2257.92 N 2043.32 E 5990818.09 N 500793.26 E Alaska State Plane Zone 4 Kuparuk 3G Dogleg Vertical Rate Section (°/100fi) (ft) Comment 1.030 1083.62 1.044 1162.94 2.195 1241.42 0.943 1320.62 1.322 1407,40 1.251 1487.83 0.805 1570.84 1.352 1652.24 1.015 1735,49 0.935 1816.19 0.733 1899.45 1.715 1981.49 1.161 2062.77 1.626 2143.94 1.119 2225.66 1.143 2306.64 1.630 2387.81 1.302 2468.02 1.412 2549.97 1.325 2630.86 1.035 2720.97 0.257 2801.29 0.257 2880.63 0.977 2964.34 0.928 3045.15 Continued... 19 August, 1999 - 8:32 - 3 - DrlllQuest Sperry-Sun Drilling Services Survey Report for 3G-26 Your Ref: 500292030300 Job No. AKMM90142, Surveyed: 10 August, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 4866.58 58.330 44.960 3247.61 3329.61 4962.24 58.240 44.040 3297.90 3379.90 5058.39 57.980 43.880 3348.69 3430.69 5152.56 59.900 43.960 3397.27 3479.27 5248.35 60.100 43.680 3445.17 3527.17 5344.44 60.740 43.890 3492.60 3574.60 5438.98 60.150 43.740 3539.23 '3621.23 5536.17 59.540 43.550 3588.06 3670.06 5632.68 59.120 43.210 3637.29 3719.29 5728.85 59.310 43.170 3686.51 3768.51 5823.83 59.700 43.100 3734.71 3816.71 5920.90 59.870 43.140 3783.56 3865.56 6016.53 59.140 43.180 3832.08 3914.08 6112.54 59.010 43.200 3881.43 3963.43 6208.09 59.010 44.090 3930.62 4012.62 6304.26 58.900 43.170 3980.22 4062.22 6400.65 59.130 43.320 4029.84 4111.84 6495.80 59.660 43.010 4078.29 4160.29 6591.63 59.360 43.440 4126.91 4208.91 6688.04 59.970 43.550 4175.60 4257.60 6784.78 59.330 43.180 4224.48 4306.48 6880.47 59.490 44.220 4273.18 4355.18 6977.55 57.320 44.110 4324.04 4406.04 7074.13 57.200 44.330 4376.27 4458.27 7169.81 57.280 42.700 4428.05 4510.05 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 2316.44 N 2101.75 E 5990876.60 N 500851.71E 2374.48 N 2158.79 E 5990934.63 N 500908.75 E 2433.25 N 2215.46 E 5990993.39 N 500965.43 E 2491.35 N 2271.41 E 5991051.48 N 501021.40 E 2551.21 N 2328.85 E 5991111.33 N 501078.84 E 2611.54 N 2386.67 E 5991171.65 N 501136.68 E 2670.88 N 2443.61 E 5991230.98 N 501193.62 E 2731.69 N 2501.61E 5991291.78 N 501251.64 E 2792.02 N 2558.62 E 5991352.10 N 501308.66 E 2852.26 N 2615.17 E 5991412.33 N 501365.22 E 2911.98 N 2671.13 E 5991472.04 N 501421.18 E 2973.21 N 2728.46 E 5991533.26 N 501478.53 E 3033.32 N 2784.83 E 5991593.36 N 501534.91 E 3093.37 N 2841.20 E 5991653.40 N 501591.28 E 3152.64 N 2897.73 E 5991712.66 N 501647.83 E 3212.27 N 2954.58 E 5991772.29 N 501704.69 E 3272.47 N 3011.20 E 5991832.48 N 501761.31E 3332.20 N 3067.22 E 5991892.20 N 501817.35 E 3392.37 N 3123.78 E 5991952.36 N 501873.91 E 3452.74 N 3181.05 E 5992012.72 N 501931.20 E 3513.43 N 3238.37 E 5992073.40 N 501988.53 E 3572.98 N 3295.28 E 5992132.94 N 502045.45 E 3632.29 N 3352.89 E 5992192.24 N 502103.07 E 3690.51N 3409.55 E 5992250.45 N 502159.73 E 3748.86 N 3464.94 E 5992308.79 N 502215.14 E Alaska State Plane Zone 4 Kuparuk 3G Dogleg Vertical Rate Section (°/100ft) (ft) Comment 0.361 3127.78 0.824 3209.10 0.305 3290.72 2.040 3371.36 0.328 3454.29 0.693 3537.84 0.639 3620.05 0.650 3704.07 0.530 3787.08 0.201 3869.69 0.415 3951.53 0.179 4035.40 0.764 4117.80 0.137 4200.16 0,798 4282.05 0.828 4364.43 0.273 4447.06 0.624 4528.95 0.498 4611.52 0,640 4694.72 0.739 4778.19 0.950 4860.54 2,237 4943.19 0.228 5024.39 1.435 5104.84 Continued... 19 August, 1999 - 8:32 - 4 - DrillQuest Sperry-Sun Drilling Services Survey Report for 3G-26 Your Reh 500292030300 Job No. AKMMg0142, Surveyed: 10 August, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 7265.77 57.530 42.880 4479.74 4561.74 7362.41 57.610 42.580 4531.57 4613.57 7457.23 57.860 41.830 4582.18 4664.18 7554.10 58.870 41.660 4632.99 4714.99 7648.56 58.990 41.880 4681.74 4763.74 7744.32 59.170 41.600 4730.95 4812.95 7840.71 57.870 41.100 4781.28 '4863.28 7936.93 55.820 41.070 4833.90 4915.90 8033.01 54.990 40.020 4888.45 4970.45 8129.59 54.220 39.400 4944.39 5026.39 8225.05 52.670 41.590 5001.25 5083.25 8320.78 52.730 39.710 5059.27 5141.27 8416.49 51.770 41.730 5117.87 5199.87 8512.41 49.610 41.880 5178.63 5260.63 8609.27 46.530 42.560 5243.35 5325.35 8705.16 42.700 42.500 5311.59 5393.59 8801.40 39.340 42.400 5384.19 5466.19 8895.37 35.960 42.540 5458.58 5540.58 8992.69 32.500 43,420 5539.03 5621.03 9088.57 31.950 43.220 5620.14 5702.14 9184.94 31.630 43.180 5702.06 5784.06 9257.71 31.680 43.110 5764.00 5846.00 9327.00 31.680 43.110 5822.97 5904.97 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 3808.19 N 3519.86 E 5992368.11 N 502270.07 E 3868.10 N 3575.21 E 5992428.02 N 502325.43 E 3927.50 N 3629.07 E 5992487.40 N 502379.30 E 3989.03 N 3683.99 E 5992548.93 N 502434.22 E 4049.38 N 3737.88 E 5992609.26 N 502488.13 E 4110.67 N 3792.57 E 5992670.55 N 502542.83 E 4172.38 N 3846.88 E 5992732.25 N 502597.15 E 4233.09 N 3899.82 E 5992792.95 N 502650.10 E 4293.19 N 3951.23 E 5992853.04 N 502701.52 E 4353.75 N 4001.54 E 5992913.60 N 502751.83 E 4412.07 N 4051.31 E 5992971.90 N 502801.62 E 4469.84 N 4100.92 E 5993029.67 N 502851.23 E, 4527.20 N 4150.27 E 5993087.01 N 502900.60 E 4582.52 N 4199.74 E 5993142.33 N 502950.08 E 4635.88 N 4248.15 E 5993195.68 N 502998.50 E 4685.50 N 4293.67 E 5993245.29 N 503044.02 E 4732.10 N 4336.30 E 5993291.89 N 503086.66 E 4774.44 N 4375.05 E 5993334.22 N 503125.41 E 4814.49 N 4412.35 E 5993374.27 N 503162.72 E 4851.69 N 4447.42 E 5993411.46 N 503197.81 E 4888.70 N 4482.18 E 5993448.46 N 503232.56 E 4916.56 N 4508.29 E 5993476.32 N 503258.69 E 4943.13 N 4533.16 E 5993502.88 N 503283.56 E Alaska State Plane Zone 4 Kuparuk 3G Dogleg Rate (°/100fi) Vertical Section (ft) Comment 0.305 0.275 0.719 1.053 0.237 0.313 1.419 2.131 1.247 0.954 2.456 1.563 1.947 2.255 3.222 3.994 3.492 3.598 3.591 0.584 0.333 0.085 0.000 5185.68 5267.25 5347.43 5429.90 5510.80 5592.94 5675.12 5755.65 5834.69 5913.33 5989.95 6066.05 6141.68 6215.89 6287.94 6355.27 6418.43 6475.82 6530.55 6581.68 6632.44 6670.63 6707.02 PROJECTED SURVEY Continued... 19 August, 1999 - 8:32 - 5 - DrillQuest Sperry-Sun Drilling Services Survey Report for 3G-26 Your Reh 500292030300 Job No. AKMM90142, Surveyed: 10 August, 1999 Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 3G All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 42.523° (True). Based upon Minimum Curvature type calculations,' at a Measured Depth of 9327.00ft., The Bottom Hole Displacement is 6707.02ft., id the Direction of 42.523° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 9327.00 5904.97 4943.13 N 4533.16 E PROJECTED SURVEY 19 August, 1999 - 8:32 - 6 - DrillQuest Date 09/06/99 Well Na 3G-26 Service Type ELECTRIC LINE Upcoming JobNum 0905991711,1 Unit 2128 Desc of Work 2 1/8" ENERJET BH PERFORATE Supervisor KRALICK Complet F' Accident F- Injury ~- spill I- Summary Contractor Key Perso SWS-JOHNSON Successful F- Initial Tbg Press 100 Initial Int Csg Press 0 Initial Out Csg Press 0 AFC K85225 0 Prop 230D$36C- Uploaded to Se~ Final Tbg Press 700 Final Int Csg Press 0 Final Out Csg Press 0 PERFORATED 9530-9545 4 SPF, BH, 180 PHASED W 2 1/8" ENERJETS FROM 9530' -9545' IN TWO RUNS - DEBRIS OR BURR CUT PI CORD ON THIRD RUN - NEED SLICKLINE SWEEP TO BOTTOM Date printed: 09/28/99 at: 16:13:53 Date 09/12/99 Upcoming I-- Well Na 3G-26 Job Num 0905991711,1 Service Type ELECTRIC LINE Unit 2128 Desc of Work 2 1/8" ENERJET PERF AND STATIC PRESS/TEMP Supervisor FERGUSON Complet r~ Accident r- Injury I-- Spill i-- Summary PERFORATED: 9502'-95'18', 4 SPF '0' PHASE RANDOM ORIENTATION.SBHP AT 9509'= 3540 PSlA Contractor Key Perso SWS-JOHNSON Successful r~ Initial Tbg Press 1200 Initial Int Csg Press 0 initial Out Csg Press 0 AFC K85225 0 Final Tbg Press 1200 Final Int Csg Press 0 Final Out Csg Press 0 Prop 230DS36E Uploaded to Sen Date printed: 09/28/99 at: 16:14:22 Date Well Na Service Type Desc of Work Supervisor ODELL Complet r~ Accident F- injury ~ Spill F- Summary 09/15/99 upcOming F- 3G-26 Job Num 0830990527.1 PUMPING Unit FRACTU RE TREATM E NT Contractor Key Perso DS-YOAKUM AFC K85225 Prop 230D$36C- 0 Uploaded to Sen Successful F- Initial Tbg Press 1176 Final Tbg Press 200 Initial Iht Csg Press 160 Final Iht Csg Press 100 Initial Out Csg Press 0 Final Out Csg Press 0 PUMPED HYDRAULIC FRACTURE, SCREENED OUT WITH 4.1 PPG ON PERFS, 19000# SAND ON FORMATION. 12000 # IN WELLB( [Frac-Refrac] Date printed: 09/28/99 at: 16:14:41 Date 09/20/99 Well Na 3G-26 Service Type PUMPING Desc of Work FRACTURE TREATMENT Supervisor ODELL Complet [~ Accident I-- Injury I-- Spill F- summary Upcoming Job Num 0830990527.1 Unit AFC K85225 0 Prop 230DS36C- Uploaded to Sen Contractor Key Perso Successful I~ Initial Tbg Press 1080 Initial Iht Csg Press 430 Initial Out Csg Press 0 DS-YOAKUM Final Tbg Press 0 Final Int Csg Press 500 Final Out Csg Press 0 PUMPED FRACTURE TREATMENT AS DESIGNED, 128,000# IN FORMATION, 12 PPA ON PERFS. [Frac-Refrac] Date printed: 09/28/99 at: 16:14:57 - fi'q .o-; %- Schhanberger NO. 12843 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print CD 2L-307 FBHP/TEMP SURVEY 990919 I 1 2N-321A ~% ~ RSTWATER FLOW LOG 990925 I 1 2N-325 t,~.l <.- EST WATER FLOW LOG 990924 I 1 2N-343 Ct. I ~ RST WATER FLOW LOG 990923 I 1 3G-26 ._~>L{ ~ 99346 AIT/GPIT 990816 1 3G-26 99346 AIT/GR/CCL 990816 I 1 3G-26 99346 CONTINUOUS SURVEY W/GPIT 990816 I 1 ,,,, SIGNED: ~_~_~~/~~'~'0 0 DATE: ~,,"T 13 1999 Naska 0il & Gas Cons. C0mmisei0n Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. TJI~~ '10/6/99 9/30/99 Schiumberger NO. 12823 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk,West Sak,Tarn Color Well Job # Log Description Date BL Sepia Print 2N-321A L,~(.-. INJECTION & STATIC PROFILE 990917 I 1 3G-26 STATIC PRESSURE SURVEY 990912 I 1 31-12 DEPTH DETERMINATION LOG 990914 I 1 30-07 (.,~1 r..L_ INJECTION PROFILE 990922 1 1 2T-210 99367 CBUSCMT 990918 1 ~ t::i!i"::'~" ' ;~ ~'~~"'":'::~'"'.~ SIGNED: ~ DATE: ' ' ,&lit~l~ Oi! & Gas (i;0~'~s. Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank'~(~ TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION July 23. 1999 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Chip Alvord Drilling Engineering Supervisor ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 Rc' Kuparuk River Unit 3G-26 ARCO Alaska. Inc. Permit No: 99-75 Sur Loc: 2538'FNL. 370'FWL. Sec. 24. T12N, R8E. UM Btmhole Loc. 2574'FSL. 198'FEL. Sec. 13. T12N. R8E. UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed bv a valid Formation Integrit-5., Test (FIT). Cementing records. FIT data. and any CQLs must be submitted to the Commission on form 10-403 prior to the start of disposal operations. Please note that anv disposal of fluids generated from this drilling operation which are pumped down thc surface/production casing annulus of a well approved for annular disposal on Drill Site 3G must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35..000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one vear. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given bv contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christenson. P.E. Chairman BY ORDER OF THE COMMISSION dltTEnclosures CC: Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. To: Robert Chfistenson From: Tom Brockway ... Fax; Pages: I (including this page) Phone: Date: 07/20/99 Re: KRU 3G-26 Permit [] Urgent X For Review [] Please Comment [] Please Reply [] Please Recycle, Dear Mr. Christenson, Thank you for making tile lime to expedite the review of the Permit to Drill for well KRU 3G-26. I apologize for the short notice. It is the standard policy of AAI Ddlling to have permit packages submitted to the AQGCC 2 to 3 weeks prior to the well spud date. In this case however, the preparation of the permit package was delayed due to last minute changes in the geologic prognosis and a severe case of stomach flu which kept the wellplanner, who prepares the directional portion of the package, sidelined for all of last week. In addition, a change in the rig schedule ddven by pressure reduction concerns on a planned sidetrack, resulted in the spud date of this well being moved up from it's original early August time frame. Thanks again for your help in approving this permit. If can be of any assistance or answer any questions p~..ase feel free to contact me at (90'7) 263-4135. Thomas A. Brrx~.kway .~ Operations Drilling Engineer AAI Drilling RECEIVED JUI 1999 Alaska Oil & Gas Cons. 00rnmis~n ~ch0ra~e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la, Type ofwork: Drill [] Redrill [] I lb. Type ofwell. Exploratory [] StratigraphicTestJ--J Development Oilj'~l Re-entry [] Deepen []J Service [] Development Gas [] Single Zone [] Multiple Zone[] 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 82 feet 3. Address 6. Property Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-036l ADL 25547 ALK 2661 Kuparuk River Pool 4. Location of well al surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 2538' FNL, 370' FWL, Sec. 24, T12N, R8E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 2401' FSL, 357' FEL, Sec. 13, T12N, R8E, UM 3G-26 #U-630610 At total depth 9. Approximate spud date Amount 2574' FSL, 198' FEL, Sec. 13, T12N, R8E, UM July 24, 1999 $200,000 12. Distance to nearest property line J 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 198 @ TD feetJ 3G-02 26.1' @ 261' MD feet 2560 9791 ' MD / 6320 ' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 250 MD Maximum hole angle 57.7° Maximum surface 1793 psig At total depth (TVD) 3500 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Lenglh MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 28' 82' 82' 110' 110' 265 sx ASl 9.875" 7.625" 29.7# L-80 BTCM 4292' 82' 82' 4374' 3039' 480 sx Class G, 357 sx AS 111,60 AS 6.75" 5.5" 15.5# L-80 BTCM 9153' 82' 82' 9235' 5838' 181 sx Class G 6.75" 3.5" 9.3# L-80 EUE8rd 556' 9235' 5838' 9791' 6320' same as above 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feet Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface Production ~ ."~ . ~. .... Linerr'd b 0 0 R ! G / &lA L Perforationdepth:measured AJaStm 0il & Gas 00ns. ^nchorag8 true vertical 20. ^ttaehments Filing fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Timers depth plot [] Refraction analysis [] Seabed report [] 20,~0 25.050 requirements [] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call Tom Brockway 263-4134 Signed ~ ~'. ~"~¢..~ Title: OdllingEngineedngSupervisor Date Chip Alvo, Pr~.l?~rp. rY I~ Commission Use Onl~ Perm~;;~bj~ I APl5~'umber'/O' date See coverletter ~-.- ~-. O ,.~'O,_~ J Approval V ,~C~, ~/,~, for other requ rements Conditions of approval Samples required [] Yes ~ No Mud Icg required [] Yes "~ No Hydrogen sulfide measures [] Yes [] No Directional survey required [] Yes [] No for BOPE [] 2M; [],(~ [] 5M; [] 10M;[] [] Required working pressure Qther: ORIGINAL SIGNED-BY by order of . ^,,rowd Rob. t U. Ch,sten o. oomr. i.,o.e. ,,e oomm, io. ,.,. Fnrrn 10-401 Rev. 12/1/85 · Submit in triplicate GENERAL DRILL AND COMPLETE PROCEDURE KUPARUK RIVER UNIT- PRODUCER KRU 3G-26 General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up Nordic Rig 3. Install diverter & function test same. 3. Spud and directionally drill 9-7/8" hole to 7-5/8" surface casing point (+/4374') according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering 4. Run and cement 7-5/8" 29.7# L-80 BTCM casing to surface using lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. Displace cement with mud. Note: TAM Port Collar will be placed in the 7-5/8" casing 1000' TVD below the surface. Port collar will only be opened and used if cement does not circulate to surface. As an alternative, if observations at surface indicate cement top is above the Port Collar, a top job may be performed in lieu of utilizing the port collar. A Top Job may only be performed after consulting with the AOGCC. This is based on the cement thickening time and time required to trip in the hole and open the Port Collar to perform the second stage cement job. See attached TAM Port Collar Utilization Decision Tree. Nipple down diverter and install wellhead. Nipple up BOPE and test to 3000 psi. Record results. Shut in BOP's and pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results. Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 14.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). Drill 6-3/4" hole to well total depth (+/- 9791') according to directional plan, running LWD logging equipment as needed. Run and cement 5-1/2" 15.5# L-80 BTCM x 3-1/2" 9.3# L-80 EUE8RD tapered casing string with polished seal bore as part of XO. Adequate cement will be pumped to place cement top +\- 500' above the casing shoe. Displace cement with mud. Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Pressure test casing to 3,500 psi for 30 minutes per AOGCC regulations. Record results. Run completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus. Freeze protect well. Pull landing joint. Install BPV. Nipple down BOP stack and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. Release rig. Clean location and RDMO in preparation for coiled tubing cleanout and perforating. . , . , 10. 11. 12. 13. 14. 3G-26 TAB, 6/19/99, vl DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, & DRILLING AREA RISKS KRU 3G-26 Drillinq Fluid Properties: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 7-5/8" surface casing 8.5-10.0 16-26 25-50 150-250* 10-20 10-30 8-15 8-10 4-6% Drill out to TD 8.5-11.8 5-15 5-12 30-40 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drillinq Fluid System: Nordic Rig 3 Tandem Geolograph/Swaco Shale Shakers Mud Cleaner, Degassers Pit Level Indicator (Visual / Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Flow Line Cleaner *Spud mud should be adjusted to a FV between 100-150 sec/qt to drill gravel beds Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure is calculated using an expected surface casing leak-off of 13.5 ppg EMW (0.70 psi/fi) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 1793 psi. Therefore, Arco Alaska, Inc. will test the BOP equipment to 3000 psi. MASP = (3039 ft)(0.70 -0.11) = 1793 psi Based on offset well data, reservoir pressures in the Kuparuk sands in the vicinity of the 3G-26 target location are expected to be ~3500 psi (0.59 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 11.8 ppg would be predicted as the maximum mud weight needed to safely drill in this formation using conventional drilling methods, assuming a TVD of 5912'. Well Proximity Risks: The nearest existing well to 3G-26 is 3G-02. As designed, the minimum distance between the two wells would be 26.1' at 261' MD. 3G-26 TAB, 7/19/99, v2 Drilling Area Risks: Risks in the 3G-26 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. If lost circulation cannot be controlled with LCM and a reduction of circulating pressure, 5-1/2" casing will be topset above the Kuparuk and either Nordic Rig #3 or a coiled tubing unit will drill out 4-3/4" hole and run a 3-1/2" liner to TD. Careful analysis of pressure data from offset wells shows that a mud weight of 11.8 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 7-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Annular Pumpin.q Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on 1G pad or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 3G-26 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. We request that 3G-26 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure Max Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (3039') + 1,500 psi -- 3396 psi This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 7-5/8" 29.7 L-80 3 BTCM 4,790 psi NA 6,890 psi 5,856 psi 5-1/2" 15.5 L-80 3 BTCM 4,990 psi 4,242 psi 7,000 psi 5,950 psi 3-1/2" * 9.3 L-80 2 8rd EUE Mod 10,530 psi 8,951 psi i10,160 psi 8,636 psi *ifneeded Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). 3G-26 TAB, 7/19/99, v2 Created by: AndrewsFor: BROCKWAY Dot~ plotted : 13~u1-1999 Plot Refe~nc~ Is 28 Veml~n ~6. I Coo~fno~ ore in feet reference slot tl, I ARCO Alaska, }nc.t F;eld : Kuporuk River Unlf Looaflon : North Slope, AIo=koJ 500 PROFILE COMMENT DATA ..... Point .....I~ In¢ O'r ~ North F_J3~ V. ~ Dea~l 0(3 KOP 2~.~ 0,~ 42`~ 2~.~ 0`~ 0,~ 0,~ 0.~ ~e P~t 1729.~ ~ 4~ t~ ~ 369~ ~ ~ ~C 2t 7~.7257,74 4~ I~07 ~07 ~1 ~ ~ Top ~ ~k 31~ 57.74 4~ ~ ~%9t t 1~ ~ 674.~~ ~ W~ Sak ~,~ 57.7~ ~ ~.~ 1~19 1~ 2~7 ~ ~mp SS 4~Z~ 57,74 4Z~ 31~ 2189.96201~ 2g~.oI ~ ~0 (KIO) 4761.~ 57,74 42.~ 52~ ~.~ 2~ ~7~41 ~ o3 2000 2500 5000 0 0 e~ -~ 5500 o3 4000 I 45oo ¥ o · RKB Elevation: 82' ~oc 9120.~2 30,00 4954- 5735.804~57.374-4~2,07 6616.57 ~,00 / / KOP K-1 id~ rker 9254`.8'/ 50,00 42.6~ 58~6.004g09.504-520.87 6675.94- 0.00 3G-26 Top C4 7/t2/99 9520.32 50~00 4;7-6~- 5912`00494~95 4~g,81 6716.66 0.00 5.00 ~, top C5 9351.1~3 30`00 4~-54`5~4E.004-936224GBE~896737.4~ 0,00 500 -- ~ 9.00 rap c2 937,5.74 30,00 42.54. 595(3,00 49§l.35 4~56.,58 6744.3~ 0.00 ~ 15.00 DLS: 3.00 dee per 100 ft ropcl 9576.90 543,00 42.64 5esl.00 4¢JSl.74 4~558.cJ~ $744.95 boo ~ 2 1.00 rap B S~tole 95,~2.67 30.00 42`6~ 5956.00 4sr~86 4,570.93 674-7.8~- 1 000 ~. 27 oo rap A C S ) g4F=2.~ ,3CLOg 4~.r~. 6035.00 4-995`17 4~q~7.92 6787.58 ~ ' fop A C 2 ) 9494-.~ 3(LO0 42.54 60~.~.00 5005,064-608.87 680~4 CLO0 3.~.00 ~au~ech 9590.52 50,00 ~-2.64` 614~00 5040,514-6~1.55 6851,76 0.00 'e~ 39.00 ~ne~= P~,rmnfrne{' TO - (MUtual:ed) 9790,~5250~00 4-2.64- 6319.2t5t 15.88 4709,07695t.76 0.00 1500 ~. 45 aa '-~ '51 .oo 00 EOC '~ ~o~ West So~ MAXIMUM ANGLE: ~ 57.74 DEG ~ Bose West Sok 7 5/8 '"~'~'"'~ ' Camp SS C50 42 64 AZIMUTH ~ ?~igin Angle Drop 6 T) DLS: .3.00 deg per 100 ft O0 RZzMiO Point) 5500 ~9.00 EOC K-1 Morker Top C5 Top C2 TARGET ANGLE: 3G-26 lop C4 7/~2/~ 5,~ ropc~ ooo T g ¢sc , , ... ~/('est;mate4~ ~)~x~- Top A ( 2 ) TD Miluveach 6500 7000 I I I I I ~ I ~ I ~ ~ I I i ~ i ~ ~ I ~ ~ ~ ~ ~ ~ ~ I ~ I I I I ~ 500 0 500 1000 1500 2000 2500 3000 5500 4000 4500 5000 5500 6000 6500 7000 7500 BO00 Verticol SecHon (feel) -> Azlmufh 42.§4 with r~f~r,n¢~ 0.00 Iq. 0.00 F from $1o~ #1 Oreo[ed by: Andrews For: Dote plotted: 15--,Jut-lggg Plot R~ferlnce la 25 Versl'on ARCO Alaska, Inc. ~fruafure : Pad ~G Well -' 26 Fteld: Kul~ruk River Unit Lo~f[on: North Slope, Alaska East (feet) -> 800 400 0 400 800 1200 1600 2000 2400 2800 5200 5600 4000 4400 4800 5200 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I A 51 O0 I 4900 0 Z 4800 East (feet) -> 4500 4400 4500 4600 4700 4800 5500 I I I i I I I I I I I 5200 5000 4700 TD LOCATION: 2574' FSI_, 198' FEL SEC. 15, T12N, RSE % TARGET LOCATION: 2401' FSL, 357' FEL SEC. 15, T12N, RSE 42.64 AZIMUTH (TO TA C T) ***Plane OF Proposal*** Surface Location: 2538' FNL, 370' FWL SEC. 24, T12N, RSE 6400 6000 5600 5200 4800 4400 400O 5600 3200 Z 2800 0 24O0 2000 ~.~ 1600 1200 800 400 400 8OO 1200 ARCO Alaska, Inc. Sfruoture: Pad Z~G Well : 26 Field: Kuparuk River Unit Loaaflon: North Slope, Alaska East (feet) 80 40 0 40 80 120 160 200 240 280 520 560 400 440 480 520 560 640 i I I I I I I I I I I I I I I I I I I I I I I I 640 i i i 600 0 560 520 ,/ 1600 480 440 400 560 A 520 -~- 280 2~0 0 Z 2OO 160 120 80 120 40 ?00 1600 / / / / / / / / oo / / / / / / / / / / / / / / 600 560 520 480 440 400 360 320 A I Z 280 0 --i- 240 --i- 200 v 160 120 80 40 120 i [ i s i i ~o ~o ~ ' ;o ' ~'o ' ,~o ,~o ~o ~o ~o Eosf (feel) -~ i 440 i 480 5½0 560 40 120 Creoted by: Andrews Fei':. I]HOCKWAY~ Dote plotted: 14-Jul-1999 PIol: Reference ii 2~t Version I ~ln~ ~ [n feet mf~ slot ARCO Alaska, Inc. Struature : Pad ,!lG Well : 26 FIeld: Kuparuk River Unlt Laaaf[on: North Slope, Alaska East (feet) 300 400 500 600 700 800 900 1000 11 O0 1200 1500 1400 1500 1600 1700 1800 1900 21 O0 I I I I I I I I I I I I I I I I I I I I I I I I 2000 1900 % 1800 1700 % 1600 ~'..~00 % 1500 1400 o~ - 1 400 1300 ~0o ~/0o 1000 aoo ~ ~~7o° 700 P~o° /~°o ~~Oo 600 500 300 I ~- ~/00 500 200 , ] [ [ [ [ [ [ , [ [ ] , , [ [ [ [ , , , ] , [ , s [ , [ , , 200 ~00 ~00 500 800 700 800 900 ~ 000 ~ ~ O0 ~ 200 ~ $00 ~ ~00 ~ 500 ~ 800 ~ 700 ~ 800 ~ 900 Eosf (feet) -> 2100 2000 1900 1800 1700 1600 1500 1~oo A I Z 1200 --4- 1100 ,,-i- 1000 v 900 800 700 600 5OO Creoted by: Andrews For: BHOCKW&Y~ Dote I~otted: 14-Ju1-1~9 ] ~ot Re~nce ;~ 26 Ve~on ~6, / ARCO Alaska, l. nc.[ Sfrualure: Pad 30 Well: Field: Kuparuk River Unit Laoqflon: North Slope, Ma.ka East (feet) -> 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 5200 3400 3600 5800 4000 4200 4400 I I I I I I I I I I I I I I I I I I I I ! I I I I I I I I I I 4800 /~00 4600 /5900 4400 /700 4200 /500 4000 /500 ~800 /100 3600 3400 5200 ,+_ 3000 "~ 2800 0 Z % % 2800 2400 2200 2000 1800 1600 1400 1200 % % ~00 4600 44OO 4200 4000 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 Easf (feel) -> 3800 3600 340O 3200 3000 2800 2600 2400 2200 1200 1400 1600 1800 2000 Created by: A~drews i~or: e~c~,yI Dote piotted: t4-Jul-19g9 ~ ~lna~s are fn feat ~fe~ slot ~1. ~ T,, V~l ~, o~, ~O (No~[c Ill).I 7000 6BO0 6600 6400 6200 6000 5800 5600 5400 '+- 5200 5000 Z 4800 4600 4400 4200 4000 3800 3600 3400 3200 ARCO Alaska, Inc. Slruofure: Pad ~ Well : 26 F~eld: Kup~ruk Rl~er Unlf Le~rt[on: North Slope, AJaska East (feet) -> 3600 3800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 6200 6400 6600 I I I I I I I I I I I I f I I I I I I I I I I I I I I I I I I O //d,oo° o // ~'oo ? ? 6000 j6200 i i i i i i ! i i i i i i i i i i i i i i i i i i i i i i i i 3600 3800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 6200 6400 6600 East (feet) -> 7000 6800 6600 6400 6200 6000 5800 5600 5400 Z 5200 0 5000 ~ --I- 4800 ~ 4600 440O 4200 4000 5800 3600 3400 3200 ARCO Alaska, Inc. Pad 3G 26 slot #1 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 26 Version~6 Our ref : prop3202 License : Date printed : 14-Ju1-1999 Date created : 19-Nov-1998 Last revised : 13-Ju1-1999 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 23 12.884,w150 0 47.469 Slot location is n70 22 47.926,w150 0 36.600 Slot Grid coordinates are N 5988560.552, E 498749.571 Slot local coordinates are 2537.70 S 371,37 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <549 - 14940'>,,28,Pad 3H PMSS <5706 - 8867'>,,28A,Pad 3H PMSS <7395 - 12575'>,,28A,Pad 3H PGMS <0-12410'>,,25,Pad 3H PMSS <1506-3878'>,,20,Pad 3H PMSS <1622-4449'>,,20,Pad 3H PGMS <O-9050'>,,20,Pad 3H PMSS <1506-2076'>,,20,Pad 3H PGMS <0-11346'>,,21,Pad 3H PGMS <O-10234'>,,22,Pad 3H PGMS <O-7298'>,,12,Pad 3H PGMS <0-8250'>,,14,Pad 3H PGMS <0-8614'>, 17,Pad 3H PGMS <0-9770'>, PGMS <0-6785'>, PGMS <0-8350'> PGMS <0-7310 > PGMS <0-6881 > PGMS <0-8620 > PGMS <0-9555 > PGMS <0-8167 > PGMS <0-10293 > PGMS <0-8650'>, PGMS <0-10730'> 16,Pad 3H lO,Pad 3H ,2 Pad 3H 9 Pad 3H 8 Pad 3H 7 Pad 3H 3 Pad 3H i Pad 3H 18,Pad 3H 19,Pad 3H ,31,Pad 3H PMSS <461-12044'>,,24,Pad 3H PGMS <O-7155'>,,5,Pad 3H PGMS <O-7750'>,,11,Pad 3H Closest approach with 3-D Minimum Distance method Last revised Distance 18-Feb-1996 9624.0 28-Feb-1996 9624.0 28-Feb-1996 9624.0 17-Feb-1999 9524.8 13-Nov-1991 9623.9 13-Nov-1991 9602.7 13-Nov-1991 9601.5 13-Nov-1991 9624.3 13-Nov-1991 9713.3 13-Nov-1991 9780.9 13-Nov-1991 9008.0 13-Nov-1991 8957.9 13-Nov-1991 9515.6 13-Nov-1991 9567.1 13-Nov-1991 7351.6 13-Nov-1991 3515.8 13-Nov-1991 5330.5 13-Nov-1991 8858.2 13-Nov-1991 8845.5 13-Nov-1991 1365.8 13-Nov-1991 6168.3 13-Nov-1991 9714.9 14-Feb-1996 g629.6 14-Feb-1996 9798.7 14-Feb-1996 9685.0 13-Nov-1991 7497.5 13-Nov-1991 6712.4 M.D. 8250 0 8250 0 8250 0 8287 0 8420 3 8575 9 8587 0 8431 4 8398.1 8320.3 8598.1 9085.6 8331.4 8242.5 9790.5 9150.0 9790.5 8498.1 8150.0 9790.5 7100.0 8298.1 8398.1 8300.0 8442.5 8200.0 9790.5 Diverging from M.D. 8342.5 8342.5 8342.5 8287.0 9462.3 9376.9 9462,3 9700 0 9750 9760 9462 9234 9460 9120 9790 9150 9790 9560 8150 9790 7100 9020 9590 8650 9250 8200 9790 PGMS <0-7987'>, 'ad 3H PGMS <0-8095'>,,~.~Pad 3H PGMS <O-8460'>,,15,Pad 3H PMSS <1743-6660'>,,26,Pad 3H PMSS <7640 - 9875'~,,23A,Pad 3H PGMS <O-9360'>,,23,Pad 3H PGMS <0-7370'>,,13,Pad 3H PMSS <6133 - 7755'>,,13A,Pad 3H PMSS <12259 - 13247'>,,25APB2,Pad 3H PMSS <11231' - 14458'>,,25APB1,Pad 3H PMSS <12256 - 15240'>,,25A,Pad 3H PGMS <0-8390'>,,3,Pad 3A PGMS <O-7630'>,,13,Pad 3A PGMS <O-8024'>,,12,Pad 3A PGMS <0-7350'>,,11,Pad 3A PGMS <O-7000'>,,lO,Pad 3A MMS <O-6400'>,,WS-23,Pad 3A PGMS <O-7120'>,,8,Pad 3A PMSS <0-7275'>,,7,Pad 3A PGMS <0-7680'>,,6,Pad 3A PGMS <O-8660'>,,5,Pad 3A PGMS <O-8690'>,,2,Pad 3A PGMS <0-9155'>,,16,Pad 3A PGMS <O-8160'>,,15,Pad 3A PGMS <O-7855'>,,14,Pad 3A PMSS <0 - 8795'>,,18,Pad 3A PMSS <0 - 7785'>,,17,Pad 3A PGMS <O-8475'>,,4,Pad 3A PGMS <0-9600'>,,1,Pad 3A PMSS <644 - 7165'>,,17,Pad 3F PGMS <0-8730'> PGMS <0-7455'>, PGMS <0-6975'>, PGMS <0-7570'>, PGMS <0-8600'>, PGMS <0-6650'>, PGMS <0-8070 > PGMS <0-7717 > PGMS <0-6913 > PGMS <0-7966 > PGMS <0-7864 > PGMS <0-7785 > PGMS <0-8600'>, PGMS <0-7050'> PGMS <0-8875'> PMSS <7121-8580'> ,1 Pad 3F 15 Pad 3F 14 Pad 3F 12 Pad 3F 11 Pad 3F 10 Pad 3F 7 Pad 3F 6 Pad 3F 4 Pad 3F 3 Pad 3F 2 Pad 3F 9 Pad 3F 16 Pad 3F ,8 Pad 3F ,5 Pad 3F ,16A,Pad 3F PMSS <475 - 6868'>,,18,Pad 3F PMSS <550 - 8132'>,,19,Pad 3F PGMS <0-8108'>,,13,Pad 3F PGMS <0-11694'><Depth Shifted>,,21,Pad 3G PMSS <9795 - 12960'>,,2IA,Pad 3G PGMS <0-6659'>, 2,Pad 3G PMSS <0 - 7501'> ,3,Pad 3G PGMS <0-8089'> 4,Pad 3G PGMS <0-8219'> PGMS <0-7910'> PGMS <0-8759'> PGMS <0-10322'> PGMS <0-6900 >, PGMS <0-6749 >, PMSS <0-9320 >, PGMS <0-9653 >, PGMS <0-9650 >, PGMS <0-8200 >, PGMS <0-10100'> PGMS <0-9782 > PGMS <0-7420 > PGMS <0-9940 > PMSS <0-3640 > PMSS <0-7990 > PGMS <0-8250 > 5 Pad 3G 6 Pad 3G 8 Pad 3G 9 Pad 3G 11 Pad 3G 12 Pad 3G 13 Pad 3G 16 Pad 3G 18 Pad 3G 19 Pad 3G ,20,Pad 3G 22 Pad 3G 23 Pad 3G 24 Pad 3G 25 Pad 3G 15 Pad 3G 10 Pad 3G PMSS <456 - 3803 >,,25X,Pad 3G PMSS <3874 - 7675'>,,25X,Pad 3G PMSS <5700-8767'>,,7,Pad 3G PGMS <O-8767'>,,7A,Pad 3G PGMS <0-7795'>,,17,Pad 3G PGMS <0-7035'><Depth Shifted>,,14,Pad 3G PMSS <5956-7470'>,,14A,Pad 3G 13-Nov-1991 13-Nov-1991 13-Nov-1991 7-$an-1999 7-Jan-1999 7-Nov-1996 13-Nov-1991 7-Jan-1999 16-2un-1999 16-~un-1999 1-$u1-1999 17-Mar-1998 2-Jan-1992 2-~an-1992 2-Jan-1992 2-~an-1992 2-~an-1992 2-2an-1992 2-~an-1992 2-~an-1992 2-Jan-1992 2-Jan-1992 2-Jan-1992 2-~an-1992 2-Jan-1992 17-Sep-1996 19-Mar-1997 30-Apr-1996 2-2an-1992 5-Mar-1999 21-Nov-1991 21-Nov-1991 21-Nov-1991 21-Nov-1991 21-Nov-1991 21-Nov-1991 21-Nov-1991 21-Nov-1991 21-Nov-1991 21-Nov-1991 21-Nov-1991 21-Nov-1991 21-Nov-1991 21-Nov-1991 5-Mar-1999 5-Mar-1999 5-Mar-1999 5-Mar-1999 8-Apr-1999 19-Nov-1998 19-Nov-1998 19-Nov-1998 19-Nov-1998 19-Nov-1998 19-Nov-1998 19-Nov-1998 19-Nov-1998 19-Nov-1998 19-Nov-1998 19-Nov-1998 19-Nov-1998 19-Nov-1998 19-Nov-1998 19-Nov-1998 19-Nov-1998 19-Nov-1998 19-Nov-1998 19-Nov-1998 19-Nov-1998 19-Nov-1998 19-Nov-1998 19-Nov-1998 19-Nov-1998 19-Nov-1998 19-Nov-1998 19-Nov-1998 19-Nov-1998 19-Nov-1998 9209.1 4219.9 9424.4 7358.3 13619.2 9638.4 9129.0 10738.1 9524.8 9524.8 9524 8 4159 2 6611 0 7328 3 4127 6 6554 4 5455 4 3992 4 6156 3 1778 9 7154 9 2158 7 7430 6 6465 6 7311 7 7441 3 6924 7 6086 8 6989 6 6153 0 9751.4 5956.1 7169.0 8002.6 9068.7 9100.1 7341.9 9416.7 9259.7 9535.2 9597.3 9287.7 3839.5 9138.6 9614.1 4094.3 9575.9 5600.0 4963.8 566.4 566.4 26.1 51.1 76.4 100.8 125.4 174.9 199.6 251.4 276.4 365.7 440.4 491.4 516.4 541.4 591.4 616.4 641.4 351 3 415 8 225 6 377 2 377 2 151 4 151 4 466 4 391 2 391 2 ~ 7 97~ 5 8431 4 9790 5 9790 5 8342 5 8387 0 9790 5 8287 0 8287 0 8287.0 9790.5 9760.0 9096,5 9790.5 9780.0 9790.5 9790.5 9790.5 9790.5 9050.0 9462.3 9031.2 9790.5 9050.0 9042.1 9790.5 9790.5 9063.8 8000.0 4860.0 6240.0 7850.0 4740.0 4220.0 5640.0 9790.5 5280.0 6120.0 5160.0 5060.0 5140.0 7880.0 6280.0 5480.0 9042.1 4700.0 9790.5 974O. 0 0.0 0.0 261.1 261.1 0.0 261.1 272.2 272.2 300.0 0.0 0.0 261.1 272.2 0.0 0.0 0.0 0.0 0.0 0.0 250.0 261.1 261.1 100.0 100.0 0.0 0.0 0.0 140.0 140.0 9540.0 9790.5 9580.0 9790.5 9790.5 9790.5 8920.3 9790.5 8287.0 8287.0 8287.0 9790.5 9760.0 9750.0 9790.5 9780.0 9790.5 9790.5 9790.5 9790.5 9160.0 9462.3 9650.0 9790.5 9320.0 9042.1 9790.5 9790.5 9063.8 8000.0 6760.0 6240.0 7850.0 4740.0 4220.0 5640.0 9790.5 6500.0 9640.0 9160.0 9017.3 5140.0 7880.0 9680.0 9750.0 9042.1 4700.0 9790.5 9740.0 8509.2 8509.2 261.1 261.1 0.0 261.1 272.2 272.2 9720.0 0.0 0.0 261.1 272.2 0.0 0.0 200.0 0.0 9074.7 0.0 250.0 261.1 261.1 100.0 100.0 0.0 0.0 0.0 9240.0 9240.0 TAM 7-5/8" Port Collar Stnd. Grade BTC Threads (+/- 1000' MD / 1000'-I-VD) Surface csg. 7 5/8" 29.7# L-80 BTCM (+/- 4374' MD / 3039' TVD) All Depths Reference Nordic 3 RKB Production csg. 5-1/2" 15.5# L-80 LTCM run XO/SBE to surface (+/- 9235' MD / 5838' TVD) Production csg. 3-1/2" 9.3# L-80 EUEM run TD to XO/SBE (+/- 9791' MD / 6320' TVD) K, U 3G-26 Proposed Completion K. 3-1/2" Gen IV tubing hanger with 3-1/2" L-80 EUE 8RD-Mod pin down J. 3-1/2" L-80 9.3# EUE 8RD-Mod tubing to surface I. 3-1/2" Camco 'DS' nipple w/2.812" No-Go Profile. 3-1/2" x 6' L-80 pup installed above. 3-1/2" x 6' L-80 flow coupling installed below, EUE 8RD-Mod set at +/- 500' MD H. 3-1/2" L-80 9.3# EUE 8RD-Mod tubing to nipple G. 3-1/2" x 1" Camco 'KBG-2-9' Mandrels w/DK valve (Max OD 4.725", ID 2.90"). 15' L-80 crossover handling pups (BTC x Special Clearance EUESRD ) installed. Spaced out with 3-1/2" L-80 EUE8RD Mod tubing. F. 3-1/2" L-80 9.3# EUE 8RD-Mod tubing to mandrel E. 3-1/2" x 1" Camco 'KBG-2-9' Mandrel w/DCK-2 valve and latch (Max. OD 4.725", ID 2.90"). 15' L-80 crossover handling pups (BTC x Special Clearence EUE 8rd) installed on GLM. D. Ijt 3-1/2" L-80 9.3# EUE 8RD-Mod tubing C. 3-1/2" Camco 'W' landing nipple with 2.813" ID and Selective profile B. 1 jt 3-1/2" L-80 9.3# EUE 8RD-Mod tubing A. Baker 4-1/2" 'GBH-22' Locator Seal Assembly w/15' of seals & Iocator 3-1/2" x 6' handling pup installed on top. EUE 8RD-Mod box up I!aker XO Coupling aker 5" OD x 4" ID Seal Bore Extension aker XO, SBE x 3-1/2" EUE et at +/- 9235' MD / 5838' TVD 3-1/2" Camco 'D' landing nipple with 2.75" ID and No-Go profile (Max OD 4.50") Future Thru-Tubing Perforations 3-1/2" 'Isolation PBR' w/8" of effective stroke. (Max OD 4.25", Seal Bore ID 2.75") 3-1/2" EUEM landing collar/FS/FC TAB, 7/19/99, vl '~ 5/29/991 MRT JB ~: K99069ACS i<~ DS.-3G 23 -~'~ 26 25n-'~Ld03 VICINITY MAP Scale 1" = 1 Mile I 25-X 24 22 20 18 16 14 25 12 10 8 6 LEGEND ,. EXISTING CONDUCTORS o NEW CONDUCTOR LOCATION SEE SHEET #2 FOR NOTES AND LOCATION INFORMATION. ,. & ASSOCIATES, INC. ENGINEERS PLANNERS SURVEYORS AREA: 3G MODULE: XXXX UNIT: D3 ARCO Alaska, Inc. ~' WELL CONDUCTOR #26 Subsidiary of Atlantic Richfield Company AS-BUILT LOCATION CADD FILE NO.I IDRAWiNG NO: I$HEET: IREV: LK650719 6/4/99 CEA-D3GX-6307D19 1 15/29/991 UrT J8 . K99069AC$ NOTES ~11~ ~~ S_~~A ~c~~ 9 1. BASIS OF LOCATION AND ELEVATION ARE DRILLSITE 3-G MONUMENTS PER LHD ~ ASSOCIATES. - 2. ELEVATIONS SHO~ ARE B.P.M.S.L 3. COORDINATESSHO~ ARE A.S.P. ZONE 4, N.A.D. 27. 1~ 4. ~LL LOCATED WlmlN PROTRAC~D SECTION 24, T. 12 N., R.8 E., UMIAT MERIDIAN, ALASKA. 5. SEE DWGS. CEA-DSGX-65e798, CEA-DSGX-65e7D11, CEA-D3GX-63e7D14, AND CEA-D3GX-63~7D16 FOR DS.-3G ~G[S. 28-20. 2~ 25 mCI~I~ Scale 1" = 1 Mile LOCA~D ~]N PRO~AC~D SEC. 24, T 12 N, R 8 E. A.S.P.'s NO. Y X LATITUDE LONGITUDE F.N.L. F.W.L. O.G. PAD 26 5,988,56~.51 498,749.57 7~'22'47.926" 15~'~'~6.6~" 2,538' 37~' 47.~' 52.2' ~ ~ ~ ~ ~ ~ '- ! HEREBY CERTIFY ~AT ! AM PROPERLY REGISTERED AND ~ ~ 49th ~. ~ , ..... ~...~ .... y~ .... ~ .... ~ ..... ~ LICENSED TO PRACTICE LAND SUR~YING IN ~E STATE OF ~ //~,/~ ~/~_ ~ ALASKA AND THAT THIS PLA T REPRESENTS A SURLY ~ ...... ~~"~ ..... ~ DONE BY ME OR UNDER MY DIRECT SUPERVISION AND ~ ~ ~~~-.~ / ~, ~AT ALL DIMENSIONS AND O~ER DETAILS ARE CORRECT -~ e.', . LS~eOa~ /~-~ AS OF JUNE 4, 1999. ~ LOUNSBURY C/15 assoc a, s. ARCO Alaska, Inc. DS3G ~ ~ CONDUCTOR ~26 Subsidiory of Atlontic Richfield Compony AS-BUILT LOCA~ON LK63~719 6/4/99 .CEA-D3GX-63~7D19 2 or 2 16" ~,VERTER SCHEMATIC-~ Nordic Rig 3 Kuparuk River Unit Operations 3 Open I Closed .~' '~ '~ _ Closed ___~ · To Accumulator I ~. .... From Accumulator Open Maintenance & Operation 1. Upon initial installation: - Close valve and fill preventer with water to ensure no leaks - Close preventer to verify operation and that the valve opens immediately 2. Close annular preventer in the event that an influx of wellbore fluids or gas is detected. Open valve to achieve diversion DO NOT SHUT-IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES 1. 16" Conductor 2. 16-3/4" 2000 psi Slip-on Weld Starting Head (Quick Connect) 3. 16-3/4" x 21-1/4" 2000 psi, Double-Studded Adapter Flange 4. 16" Diverter Spool with APl 21-1/4" 2000 psi Flanges 5. 21-1/4" Schaefer 2000 psi Annular Preventer 6. 16" Knife Valve. The valve opens automatically upon closure of annular preventer. 7. 16" Diverter Line TAB, 07/19/99, v2 7-1/1 . 5000 psi BOP Stack .... Nordic Rig 3 Kuparuk River Unit Operations Kill Line 3 I Choke Line Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. BOP Stack Test 1. Fill BOP stack and manifold with water. 2. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi Iow and 3000 psi high. Test as in step 4. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi and 3000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 250 psi Iow and 3000 psi high for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 3000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with BOP test pump. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. 1. 16" Starting Head 2. 7-1/16" 5000 psi Tubing Head 3. 7-1/16" 5000 psi Hydril Single Pipe Rams, 3-1/8" 5000 psi Side Outlets w/ Manual Locks 4. 7-1/16" 5000 psi Drilling Spool with Choke and Kill Lines, 2 Choke valves - one 3" 5000 psi Hydraulic gate and one 3" 5000 psi Manual gate, 2 Kill valves - each are 3" 5000 psi gate 5. 7-1/16" 5000 psi Hydril Double Ram with Pipe Rams on Top and Blind Rams on Bottom, 3-1/8" Side Outlets w/Manual Locks 6. 7-1/16" 5000 psi Hydril Annular Preventer, Hub Bottom Connection TAB, 10/01/98, v.2 I Uparuk River Unit Operations TAM Port Collar Utilization Decision Tree Cement above Port Collar (1000' TVD) / Perform Top Job as per requirements of AOGCC Nipple Up and Test BOP's Continue with Completion Begin Primary One Stage Cement Job / No Cement / to Surface / Cement below Port Collar (1000' TVD)~ If Top Job is ineffective or unacceptable to AOGCC Open Port Collar using drillpipe Circulate Cement to Surface and close Port Collar Cement to Surface Nipple Up and Test BOP's Continue with Completion Indicators of Cement Top 1. Observation of Tracers in Spacer ahead of lead cement 2. Calculated Displacement 3. Displacement Pressures during Primary Cement Job 4. Other indications that cement is near surface Nipple Up and Test BOP's Continue with Completion ARCO Alaska, Inc. Post Office Box 1~0360 Anchorage, Alaska 99510 July 19, 1999 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill: Surface Location: Target Location: Bottom Hole Location: KRU 3G-26 2538' FNL, 370' FWL, Sec 24, T12N, R8E, UM 2401' FSL, 357' FEL, Sec. 13, T12N, R8E, UM 2574' FSL, 198' FEL, Sec. 13, T12N, R8E, UM Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the Kuparuk interval from 3G pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and further develop the production potential of the Kuparuk sands in the vicinity of 3G pad. The well is designated as a producer and is planned to penetrate the Kuparuk C and A sands using a 7-5/8" surface casing string and a 5-1/2" x 3-1/2" tapered production casing string with a crossover seal bore. The well will be drilled and completed using Nordic Rig 3. Completion plans call for running 3-1/2" production tubing with gas lift mandrels as a tieback string. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. ?' F~ i ~ ~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Alaska 0ii & Gas Cons. C.,o.m.mi,~sior~ 9) 10) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S and combustible gas monitoring equipment functioning on the rig as is the standard operating procedure in the Kuparuk River Unit drilling operation. Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. The following are ARCO's designated contacts for reporting responsibilities to the Commission: A) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 B) Geologic Data and Logs William Raatz, Geologist (20 AAC 25.071) 263-4952 Please note that the anticipated spud date for this well is July 24, 1999 If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or Chip Alvord at (907) 265-6120. Since r.e.~/' 'Fhomas A. Brockwa'~ Operations Drilling Engineer Attachments: CC: KRU 1G-17 Well File Chip AIvord Mark Chambers Randy Kanady ATe-1030 ATe- 1 O32 ATO-1290 ARCO Alaska, Inc. ALPINE DISBURSEMENT ACCOUNT P.O. Box 103240 Anchorage, AK 99510-3240 PAY TO THE ORDER OF: ALASKA OEPT oF'REVENUE ALASKA OIL'& ~GAS CONSERVATION COMMI 3001 ,~ PORCUPINE "DRIVE" ~,.c. ~u~... 249004454 73-426 839 0990337 JUNE 22, 1999 ~,~ :::,:VOID AFTER 90 DAYS *** : ' ::, . ::':: EXACTLY ***.***i;~:**~:IO0::DOLLARS AND O0 CENTs ~:'$*********** 100.00 The First National Bank of Chicago-0710 . Payable Through Republic Bank Shelbyville, Kentucky TRACE NUMBER: 249004454 cio t, ii F= 2~,' 0 q qO ~, ~ ?," WELL PERMIT CHECKLIST COMPANY ,~ ~ WELL NAME/,~,~z:.-/' ..~ ~ - Z~PROGRAM: exp __ dev ~ redrll __ serv ~ wellbore seg ann. disposal para req ~ FIELD & POOL INIT CLASS ~/~z/ ,,2 -,~/ ADMINISTRATION A R D TE, ENGINEERING 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from ddlling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in ddlling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... APP~R.. DATE 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive hodzons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diveder required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to .'~ ©C)-~'~"~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. AREA GEOLOGY 30. 31. 32. "APPR DATE UNIT# /¢,//~ ON/OFF SHORE Permit can be issued w/o hydrogen sulfide measures ..... ~YY N ~'/~ .~. ~ Data presented on potential overpressure zones ....... Y N Seismic analysis of shallow gas zones ............. Seabed condition survey (if off-shore) ............. / N Contact name/phone for weekly progress reports [exploratory o~] Y N With proper cementing records, this plan /~ ' C%"~ ~. (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; I~e..¢..¢ F,~uu.~,.s i'"'-,~u~,~ '3"~,~ ~=..~-. I~-r~, p¢o-/I-~=.~.., t~e~c.c)ve..,c, /%v,~u..~.5 . (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N ,, G E.~_~ ENGINEERING:. UlC/Annular JDH~ COMMISSION: DWJ ~ RNC ~ , co £,o Comments/Instructions: c:\msoffice\wordian\diana\checklist Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Thu Nov 04 16:31:45 1999 Reel Header Service name ............. LISTPE Date ..................... 99/11/04 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 99/11/04 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 1 AK-MM-90142 TOM MCGUIRE DEARL GLADDE RECEIVED ~'a',! 1 2. 1999 Aja~{aO~ & Gas Cons. Comm~on 3 G- 2 6 A~O~ 501032030300 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 04-NOV-99 MWD RUN 2 AK-MM-90142 MARK HANIK DON WESTER MWD RUN 3 AK-MM-90142 MARK HANIK DON WESTER 24 12N OO8 2538 370 82.00 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 82.00 52.20 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 110.0 9.875 7.625 4344.0 6.750 9327.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL, PRESSURE WHILE DRILLING (PWD), AND DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS. 3. MWD RUNS 2-3 ARE DIRECTIONAL, PRESSURE WHILE DRILLING (PWD , DRILLSTRING DYNAMICS SENSOR (DDS), ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4 , AND DUAL GAMMA RAY DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS. 4. DIGITAL DATA IS CORRRECTED TO THE PDC GR OF 08/20/99 (AIT GR) WITH KBE = 82'AMSL. 5. MWD RUNS 1-3 REPRESENT WELL 3G-26 WITH API%: 50-029-20303-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9327'MD, 5905'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/11/04 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 125 0 ROP 164 5 FET 4329 5 RPD 4329 5 RPM 4329 5 R?S 4329 5 RPX 4329 5 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 125 0 8538 8541 8543 8546 8550 8552 8555 8557 8559 8561 8568 8570 8572 8580 8604 8606 8619 8624 8625 8627 8645 8647 8660 8663 8665 8667 8669 8672 8675 8678 8682 8690 8693 8695 8698 8706 8715 8717 8719 8720 0 0 0 5 5 5 0 5 0 0 0 5 0 0 0 5 5 5 5 5 0 5 5 0 5 0 0 5 0 0 0 5 0 5 5 5 0 0 0 5 GR 129 5 8542 5 8546 0 8548 0 8551 5 8555 5 8558 0 8560 0 8562 5 8564 5 8566 5 8574 5 8576 5 8579 0 8586 5 8609 5 8612 5 8625 0 8628 0 8630 0 8632 5 8649 5 8652 0 8662 5 8666 0 8669 0 8670 0 8672 0 8676 0 8678 5 8682 0 8685 5 8694 5 8696 5 8698 0 8700 5 8709 0 8718 0 8720 5 8723 0 8724 5 STOP DEPTH 9268 5 9324 0 9275 5 9275 5 9275 5 9275 5 9275 5 EQUIVALENT UNSHIFTED DEPTH 8722 8725 8727 8728 8729 8733 8735 8743 8746 8749 8754 8756 8757 8759 8760 8763 8766 8770 8772 8774 8780 8781 8783 8787 8788 8791 8796 8796 8802 8806 8808 8810 8814 8815 8818 8819 8822 8824 8829 8831 8833 8836 8837 8841 8847 8854 8856 8860 8864 8869 8872 8876 8885 8886 8887 8892 8893 725 728 730 732 733 736 738 745 750 752 757 759 760 762 764 767 770 773 775 777 784 786 790 792 792 794 798 799 806 810 811 813 820 821 823 824 825 828 833 836 838 840 841 844 850 856 859 863 867 871 875 879 887 889 891 894 896 8902 8904 8911 8913 8915 8919 8923 8927 8932 8934 8936 8940 8942 8943 8946 8955 8959 8960 8962 8979 8982 8985 8987 8993 8999 9006 9010 9012 9013 9019 9021 9024 9026 9028 9032 9035 9039 9045 9047 9055 9057 9060 9062 9064 9069 9074 9078 9080 9089 9108 9110 9112 9114 9115 9117 9118 9127 8903 8905 8914 8916 8918 8922 8926 8930 8936 8937 8939 8942 8945 8946 8948 8958 8962 8963 8965 8982 8985 8986 8989 8996 9002 9009 9014 9015 9017 9022 9025 9027 9029 9031 9036 9039 9042 9049 9051 9059 9061 9063 9065 9067 9072 9078 9081 9083 9092 9111 9113 9115 9117 9119 9120 9121 9131 9131 5 9136 9142 9154 9157 9159 9164 9198 9226 9228 9232 9263 9264 9266 9324 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: 9135 0 9139 0 9144 0 9157 5 9160 5 9162 5 9167 5 9201 5 9229 5 9231 5 9236 0 9266 5 9268 0 9270 0 9327 5 BIT RUN NO MERGE TOP MERGE BASE 1 129.0 4350.0 2 4350.0 5428.0 3 5428.0 9327.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 - 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Name Min Max Mean Nsam Reading DEPT 125 9324 4724.5 18399 125 ROP 0 4763 188.608 18281 164.5 GR 9.09 524.18 102.825 18288 125 RPX 1.03 2000 4.00764 9893 4329.5 Last Reading 9324 9324 9268.5 9275.5 RPS 0.07 547.55 3.83005 9893 RPM 0.06 2000 7.73902 9893 RPD 0.3 2000 5.47469 9893 FET 0.1003 93.6923 1.39966 9893 4329.5 9275.5 4329.5 9275.5 4329.5 9275.5 4329.5 9275.5 First Reading For Entire File .......... 125 Last Reading For Entire File ........... 9324 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/11/04 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/11/04 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 129.5 4310.5 ROP 169.0 4351.5 $ LOG HEADER DATA DATE LOGGED: 01-AUG-99 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG INSITE 4.02 1.42/1.15/2.41/5.15/5.41 MEMORY 4350.0 110.0 4350.0 MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .1 59.0 TOOL NUMBER 91334HWG6 9.880 9.9 SPUD MUD 9.30 73.0 9.4 250 6.0 .000 .000 .000 .000 40.4 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 API 4 1 68 4 2 ROP MWD 1 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading Last Reading DEFT 129.5 4351.5 2240.5 8445 GR 9.09 130.45 68.6162 8363 ROP 0 1689.88 246.043 8327 129.5 129.5 169 4351.5 4310.5 4351.5 First Reading For Entire File .......... 129.5 Last Reading For Entire File ........... 4351.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/11/04 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/11/04 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FET RPD RPM RPS RPX GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 4334 0 4334 0 4334 0 4334 0 4334 0 5375 0 5429 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : STOP DEPTH 5380.0 5380 0 5380 0 5380 0 5380 0 9272 0 9327 5 06-AUG-99 INSITE 4.02 1.42/1.15/2.41/5.15/5.41 MEMORY 5428.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 4350.0 5428.0 57.2 60.7 TOOL NUMBER P1331GRV4 P1331GRV4 6.750 6.8 LSND 8.80 43.0 10.6 150 6.4 5.200 3. 600 3. 900 7.800 36.1 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 RPX MWD 2 OHMM 4 1 68 8 3 RPS MWD 2 OHMM 4 1 68 RPM MWD 2 OHMM 4 1 68 RPD MWD 2 OHMM 4 1 68 ROP MWD 2 FT/H 4 1 68 FET MWD 2 HOUR 4 1 68 12 16 2O 24 28 Name Min Max Mean Nsam DEPT 4311 5428.5 4869.75 2236 GR 45.27 174.43 111.704 2125 RPX 1.98 2000 6.46605 2093 RPS 0.07 547.55 5.34814 2093 RPM 0.06 2000 23.1154 2093 RPD 0.3 2000 12.0403 2093 ROP 0 569.05 170.392 2154 FET 0.1481 93.6923 2.26514 2093 First Reading 4311 4311 4334 4334 4334 4334 4352 4334 Last Reading 5428.5 5373 5380 5380 5380 5380 5428.5 5380 First Reading For Entire File .......... 4311 Last Reading For Entire File ........... 5428.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/11/04 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/11/04 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 5375.0 9272.0 FET 5380 5 RPD 5380 5 RPM 5380 5 RPS 5380 5 RPX 5380 5 ROP 5429 0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 9279 0 927 9 0 9279 0 9279 0 9279 0 9327 5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH {FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S) : MUD PH: MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record 10-AUG-99 INSITE 4.02 1.42/1.15/2.41/5.15/5.41 MEMORY 9327.0 5428.0 9327.0 31'.6 60.0 TOOL NUMBER P1331GRV4 P1331GRV4 6.750 6.8 LSND 11.00 48.0 9.5 250 2.8 2.700 1.500 2.600 3.000 55.0 .0 Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 GR MWD 3 API 4 1 RPX MWD 3 OHMM 4 1 RPS MWD 3 OHMM 4 1 RPM MWD 3 OHMM 4 1 RPD MWD 3 OHMM 4 1 ROP MWD 3 FT/H 4 1 FET MWD 3 HOUR 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 Name Min Max Mean DEPT 5375 9327.5 7351.25 GR 62.54 524.18 137.162 RPX 1.02 10.95 3.34793 RPS 1.03 10.58 3.42265 RPM 1.03 10.18 3.61311 RPD 1.12 8.93 3.71288 ROP 0 4763 132.359 FET 0.1003 13.9131 1.16723 First Last Nsam Reading Reading 7906 5375 9327.5 7795 5375 9272 7798 5380.5 9279 7798 5380.5 9279 7798 5380.5 9279 7798 5380.5 9279 7798 5429 9327.5 7798 5380.5 9279 First Reading For Entire File .......... 5375 Last Reading For Entire File ........... 9327.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/11/04 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/11/04 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Services Writing Reel Trailer Service name ............. LISTPE Date ..................... 99/11/04 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Services Library. Library. Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File