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194-162
STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:7ES DATE:3/22/23 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #1941620 Sundry #322-339 Operation:Drilling:Workover:X Explor.: Test:Initial:X Weekly:Bi-Weekly:Other: Rams:250/4500 Annular:250/4500 Valves:250/4500 MASP:4003 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 2 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13 5/8" T90 P Pit Level Indicators P P #1 Rams 1 2 7/8' x 5"P Flow Indicator P P #2 Rams 1 Blinds P Meth Gas Detector P P #3 Rams 1 3 1/2" x 5 1/2"P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8" Gate P Time/Pressure Test Result HCR Valves 2 3 1/8" Gate P System Pressure (psi)3000 P Kill Line Valves 2 3 1/8" & 2"P Pressure After Closure (psi)1550 P Check Valve 0 NA 200 psi Attained (sec)17 P BOP Misc 2 2 1/16" Gate P Full Pressure Attained (sec)144 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:1050 P Quantity Test Result Nitgn. Bottles # & psi (Avg.):5 @ 1950 P No. Valves 16 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 29 P #1 Rams 6 P Coiled Tubing Only:#2 Rams 5 P Inside Reel valves 0 NA #3 Rams 6 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:6.5 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 3/20/23 16:24 Waived By Test Start Date/Time:3/22/2023 7:30 (date)(time)Witness Test Finish Date/Time:3/22/2023 14:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Sully Sullivan Nabors All Tests with 3 1/2"Test joint. Kelly Cozby / Paul Yearout ConocoPhillips Mark Adams / Chase Erdman KRU 1R-34 Test Pressure (psi): kelly.cozby@nabors.com nskrwo.cm@conocophillips.com Form 10-424 (Revised 08/2022)2023-0322_BOP_Nabors7ES_KRU_1R-34 J. Regg; 8/24/2023 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 Coiled Tubing Ops Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 13570'feet 13033'feet true vertical 6998' feet 13168', 13180' feet Effective Depth measured 13033'feet 9401', 12899', 13007', 13056' feet true vertical 6597'feet 4881', 6502', 6579', 6614' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 13075' MD 6627' TVD Packers and SSSV (type, measured and true vertical depth) 9401' MD 12899' MD 13007' MD 13056' MD N/A 4881' TVD 6502' TVD 6579' TVD 6614' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 322-339 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: HLB TNT TechHold Packer Packer: Baker Premier Prod Packer Packer: Baker F-1 Prod Packer Packer: Baker FB-1 Prod Packer SSSV: None Adam Klem adam.klem@conocophillips.com (907) 263-4529Staff RWO/CTD Engineer 13181-13216' 6704-6730' measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 121' ~ ~~ Well Remains Shut-In ~~ ~ measured TVD 7"x5" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 194-162 50-029-22534-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025635, ADL0025628 Kuparuk River Field/ Kuparuk River Oil Pool KRU 1R-34 Plugs Junk measured Length Production Liner 13520' Casing 6990'13560' 7093' 121'Conductor Surface Intermediate 16" 9-5/8" 80' 7133' 4070' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Kayla Junke at 9:28 am, Apr 27, 2023 Page 1/5 1R-34 Report Printed: 4/26/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/20/2023 00:00 3/20/2023 02:30 2.50 MIRU, MOVE MOB P RDMO. Pull sub from well and stage at entrance of pad. 3/20/2023 02:30 3/20/2023 11:00 8.50 MIRU, MOVE RGRP T Nabors changing out bridal lines. Pull and make repaires to flow line to pits. 3/20/2023 11:00 3/20/2023 15:30 4.50 MIRU, MOVE MOB P Trucks on location @ 11:00. Load shop, office and pits. Move to 1R. Set shop and office. Stage pits on location. 3/20/2023 15:30 3/21/2023 00:00 8.50 MIRU, MOVE MOB P Move sub F/ 1H T/ 1R. On Location at 2330 hrs. Stage equipment in cellar. Wellhead and Tubing Adaptor. 3/21/2023 00:00 3/21/2023 04:00 4.00 MIRU, MOVE RURD P Spread herculite. Spot sub over well. Install rig mats. Spot Pits, Beam up camp, cellar and front of Rig. 0.0 0.0 3/21/2023 04:00 3/21/2023 06:00 2.00 MIRU, MOVE RURD P Safe out Derrick. Raise derrick. RU Inner Connect. Spot cuttings tank. R/U tiger tank line & Choke House. 0.0 0.0 3/21/2023 06:00 3/21/2023 12:00 6.00 MIRU, WELCTL RURD P Complete rig up checklist *** Rig Accepted 3/21/23 @ 11:00 *** Bring on 12.0 PPG KWF into pits. 0.0 0.0 3/21/2023 12:00 3/21/2023 14:30 2.50 MIRU, WELCTL PRTS P Initial TBG PSI= 200 Initial IA= 360 Initial OA= 60 Fluid pack and PT Flow back iron and choke to tiger tank to 4500 psi. bled pressure off tubing and IA. 0.0 0.0 3/21/2023 14:30 3/21/2023 16:30 2.00 MIRU, WELCTL KLWL P Circulate well over to 12.0 ppg NaCl @ 6 bpm, 1000 psi. Pumped total of 520 BBL's. 0.0 0.0 3/21/2023 16:30 3/21/2023 17:00 0.50 MIRU, WELCTL RURD P Blow down lines 0.0 0.0 3/21/2023 17:00 3/21/2023 17:30 0.50 MIRU, WELCTL OWFF P Monitor well for flow. 0.0 0.0 3/21/2023 17:30 3/21/2023 18:00 0.50 MIRU, WELCTL MPSP P RU to and set ISA BPV. 0.0 0.0 3/21/2023 18:00 3/21/2023 18:30 0.50 MIRU, WELCTL PRTS P Pressure test under BPV to 1000 PSI for 10 minutes. Bled pressure off IA and adapter void. 0.0 0.0 3/21/2023 18:30 3/21/2023 23:30 5.00 MIRU, WELCTL NUND P ND adapter and tree. NU BOP's 0.0 0.0 3/21/2023 23:30 3/22/2023 00:00 0.50 MIRU, WELCTL OTHR P Perform between wells maintenance 3/22/2023 00:00 3/22/2023 05:00 5.00 MIRU, WHDBOP OTHR P Performing between wells maintenance 0.0 0.0 3/22/2023 05:00 3/22/2023 07:30 2.50 MIRU, WHDBOP RURD P Pick up test tools, grease valves prep for bop test 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 3/28/2023 Page 2/5 1R-34 Report Printed: 4/26/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/22/2023 07:30 3/22/2023 14:00 6.50 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/4500 PSI for 5 Min each, Test annular 250/4500 on 3-1/2"" test joint. Tested, UVBR's and LVBR's on 3-1/2"" test joints. Test blinds rams. Choke valves #1 to #16, upper and lower top drive well control valves. Test 3 1/2" HT- 38 FOSV and IBOP. Test 3 ½ 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 pressure=3000 PSI, after closure=1550 PSI, 200 PSI attained =17 sec, full recovery attained =144 sec. UVBR's= 6 sec, LVBR's= 6 sec. Annular= 28 sec. Simulated blinds= 6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average =1950 PSI. Witnessed waived by AOGCC rep Sean Sullivan 0.0 0.0 3/22/2023 14:00 3/22/2023 16:30 2.50 COMPZN, RPCOMP RURD P Rig down testing equipment and pull blanking plug // Pull BPV 0.0 0.0 3/22/2023 16:30 3/22/2023 17:30 1.00 COMPZN, RPCOMP THGR P Pick up landing jt make up to hanger // Back out LDS // Pull hanger off seat and to floor 100K PUW 12,960.0 12,940.0 3/22/2023 17:30 3/22/2023 18:00 0.50 COMPZN, RPCOMP RGRP T Tubing tongs not set up for pulling pipe waited on crew to configure tools 12,940.0 12,940.0 3/22/2023 18:00 3/22/2023 23:30 5.50 COMPZN, RPCOMP PULL P Pick up landing jt install in hanger // back out LDS // Pull hanger off seat 100k Up wt. // Lay down hanger and completion 12,940.0 7,500.0 3/22/2023 23:30 3/23/2023 00:00 0.50 COMPZN, RPCOMP SVRG P Service TD and Drawworks // Service Tubing tongs 7,500.0 7,500.0 3/23/2023 00:00 3/23/2023 10:00 10.00 COMPZN, RPCOMP PULL P Lay down completion, 3.5" Rd tubing, pull 412 full joints, 14.35' cut joint, 5 GL mandrels, and 1 DS landing nipple. 75K upweight @ 7500' 7,500.0 0.0 3/23/2023 10:00 3/23/2023 11:30 1.50 COMPZN, RPCOMP OTHR P L<oad out decompletion. Complete loading 3.5" drill pipe, 84 Jts and 6, 3.75" collars 6,000.0 0.0 3/23/2023 11:30 3/23/2023 12:00 0.50 COMPZN, RPCOMP SVRG P Service rig tongs 0.0 0.0 3/23/2023 12:00 3/23/2023 14:30 2.50 COMPZN, RPCOMP OTHR P L<oad out decompletion. Complete loading 3.5" drill pipe, 84 Jts and 6, 3.75" collars 0.0 0.0 3/23/2023 14:30 3/23/2023 15:00 0.50 COMPZN, RPCOMP SFTY P PJSM to make up BHA #1 and 3 1/2" drill pipe 0.0 0.0 3/23/2023 15:00 3/23/2023 16:30 1.50 COMPZN, RPCOMP BHAH P Make up BHA #1 Scraper dress stump run 0.0 71.0 3/23/2023 16:30 3/23/2023 18:00 1.50 COMPZN, RPCOMP BHAH P P/U 6 drill collars and X-O on top of collars 71.0 257.1 3/23/2023 18:00 3/23/2023 23:30 5.50 COMPZN, RPCOMP PULD P M/U 3 1/2" DP 257.1 7,000.0 3/23/2023 23:30 3/24/2023 00:00 0.50 COMPZN, RPCOMP SVRG P Service blocks and topdrive 7,000.0 7,000.0 3/24/2023 00:00 3/24/2023 01:00 1.00 COMPZN, RPCOMP PULD P RIH with clean out assembly picking up singles drill pipe 7,000.0 8,800.0 3/24/2023 01:00 3/24/2023 03:45 2.75 COMPZN, RPCOMP SLPC P Cut and slip drill line 8,800.0 8,800.0 Rig: NABORS 7ES RIG RELEASE DATE 3/28/2023 Page 3/5 1R-34 Report Printed: 4/26/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/24/2023 03:45 3/24/2023 04:15 0.50 COMPZN, RPCOMP PULD P RIH picking up singles 8,800.0 9,300.0 3/24/2023 04:15 3/24/2023 04:45 0.50 COMPZN, RPCOMP REAM P Ream setting area for upper packer pump B/U 9,300.0 9,400.0 3/24/2023 04:45 3/24/2023 09:45 5.00 COMPZN, RPCOMP PULD P RIH picking up singles to top of stump @ 12975' 9,400.0 12,900.0 3/24/2023 09:45 3/24/2023 09:51 0.10 COMPZN, RPCOMP PULD P 12,900' parameters, upweight 175K, SOW=125K 12,900.0 12,900.0 3/24/2023 09:51 3/24/2023 10:00 0.15 COMPZN, RPCOMP PULD P Continue in, Set down 4K @ Jt 403, - 5.6', 12,962'. Upweight 175K 12,900.0 12,962.0 3/24/2023 10:00 3/24/2023 10:18 0.30 COMPZN, RPCOMP RURD P Lay down one joint. R/U blower hose, Kelly up 12,930 12,962.0 12,930.0 3/24/2023 10:18 3/24/2023 10:42 0.40 COMPZN, RPCOMP MILL P Bring pumps online 2 BPM @ 510 PSI, 35 RPM, 8.5K tourque, 175K up, SOW=125K, RIH, See torque up @ 12964, Low, 25 PSI pressure increase.Top of stump 12,659' 12,930.0 12,964.0 3/24/2023 10:42 3/24/2023 10:48 0.10 COMPZN, RPCOMP MILL P PUH, Bring pump up to 3 BPM / 56 Stks, 895 PSI Pump pressure, RIH looking for PSI increase. See presure increase to 1200PSI and torque to 10K 12,964, Dress stump to 12,966 12,964.0 12,964.0 3/24/2023 10:48 3/24/2023 11:00 0.20 COMPZN, RPCOMP MILL P Pick up off stump, PUW=175K, Pressure drop[ @ 5.6' up to 900PSI 12,964.0 12,966.0 3/24/2023 11:00 3/24/2023 11:42 0.70 COMPZN, RPCOMP CIRC P Mix / pump 20BBl hi vis swwep. Recip pipe above 12,960'. Sweep down pipe @ 11:10. circ sweep 12,966.0 12,950.0 3/24/2023 11:42 3/24/2023 11:54 0.20 COMPZN, RPCOMP TRIP P Trip out 2 jts, Recip lower packer setting depth 12,895. Circ sweep out of hole 12,950.0 12,890.0 3/24/2023 11:54 3/24/2023 13:24 1.50 COMPZN, RPCOMP CIRC P Clean lower packer setting depth, circ sweep to surface 12,890.0 12,800.0 3/24/2023 13:24 3/24/2023 18:00 4.60 COMPZN, RPCOMP TRIP P Start tripping out of hole, PUW=199K 12,800.0 275.0 3/24/2023 18:00 3/24/2023 19:45 1.75 COMPZN, RPCOMP BHAH P Rack 3 stands collars // Lay down scraper BHA // Inspect boot baskets for abnormal contents // 275.0 0.0 3/24/2023 19:45 3/24/2023 20:30 0.75 COMPZN, RPCOMP CLEN P Clean floor and prep for trip in with packer assembly 0.0 0.0 3/24/2023 20:30 3/24/2023 21:00 0.50 COMPZN, RPCOMP SVRG P Service rig Blocks and TD, Service drawworks 0.0 0.0 3/24/2023 21:00 3/24/2023 22:30 1.50 COMPZN, RPCOMP BHAH P Pick up packer BHA 0.0 328.0 3/24/2023 22:30 3/25/2023 00:00 1.50 COMPZN, RPCOMP TRIP P Trip in hole with packer assembly // 70'/min running speed 328.0 2,750.0 3/25/2023 00:00 3/25/2023 05:00 5.00 COMPZN, RPCOMP TRIP P Trip in hole with packer on stands of DP 2,750.0 12,960.0 3/25/2023 05:00 3/25/2023 06:30 1.50 COMPZN, RPCOMP HOSO P Pu wt 170 K SO wt 95K // NG overshot @ 12963' // Pu and drop single for space out and rod drop // prep to circ in CI 12,960.0 12,963.0 3/25/2023 06:30 3/25/2023 07:30 1.00 COMPZN, RPCOMP CIRC P Circulate in 30 bbls CI // Spot 20 bbls out side of pipe 10 bbls inside pipe 2 BBls min, 400 PSI 12,963.0 12,963.0 3/25/2023 07:30 3/25/2023 10:12 2.70 COMPZN, RPCOMP PRTS P Drop ball and rod set packer at 3200PSI. Continue to pressure up to 3500 PSI . Unable to get good test. Rig off Kelly. Hook uo cement line to DP. Obtian good test 3600 PSI/30Min 12,963.0 12,963.0 Rig: NABORS 7ES RIG RELEASE DATE 3/28/2023 Page 4/5 1R-34 Report Printed: 4/26/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/25/2023 10:12 3/25/2023 13:00 2.80 COMPZN, RPCOMP PRTS P Rig down test equipment, Lay down two singles. PUW=170K. Set test packer, rotate left up to 10 revolutions on third atempt. Test packer set SOW=125K, PUW=175 12772'. PT down DP. 3500 PSI for 30 Min.Pass. Bleed off 12,963.0 12,772.0 3/25/2023 13:00 3/25/2023 13:30 0.50 COMPZN, RPCOMP SVRG P Service rig digital counters, top drive, Iron rough neck 12,772.0 12,772.0 3/25/2023 13:30 3/25/2023 14:12 0.70 COMPZN, RPCOMP PULD P Pull 50 joints 3.5 DP. Lay down. PUW=170K 12,772.0 11,180.0 3/25/2023 14:12 3/25/2023 16:00 1.80 COMPZN, RPCOMP PRTS P Kelly up, Circ DP to purge. PT to 3000PSI. Good test, Release packer 11,180.0 11,180.0 3/25/2023 16:00 3/25/2023 18:00 2.00 COMPZN, RPCOMP PULD P Pull 50 more joints of DP - lay down, PUW=155K 11,180.0 9,604.0 3/25/2023 18:00 3/25/2023 21:30 3.50 COMPZN, RPCOMP PRTS P Kelly up, Circ DP, Set test packer // Pipe test good from 9600' to top of packer // Pull 2 jts get element to 9422' test down tubing leak found // close BOP's pressure up and test casing 3000psi for 30 min 9417' Center of element good test // bad pipe count pick up 2 jts re-test good test // 9,604.0 9,422.0 3/25/2023 21:30 3/26/2023 00:00 2.50 COMPZN, RPCOMP PULD P Lay down drill pipe 9,422.0 6,700.0 3/26/2023 00:00 3/26/2023 00:30 0.50 COMPZN, RPCOMP PULD P Lay down drill pipe 6,700.0 6,550.0 3/26/2023 00:30 3/26/2023 01:00 0.50 COMPZN, RPCOMP SVRG P Change roller pin for spinners 6,550.0 6,550.0 3/26/2023 01:00 3/26/2023 05:00 4.00 COMPZN, RPCOMP PULD P Lay down drill pipe 6,550.0 273.0 3/26/2023 05:00 3/26/2023 06:30 1.50 COMPZN, RPCOMP BHAH P Lay down DC's, Test Packer and seals, running tools 273.0 0.0 3/26/2023 06:30 3/26/2023 07:30 1.00 COMPZN, RPCOMP RURD P Remove wear bushing - Clean rig floor 0.0 0.0 3/26/2023 07:30 3/26/2023 13:00 5.50 COMPZN, RPCOMP OTHR P Process remainder of 3.5" tubing for completion // clean floor and prep for picking up completion 0.0 0.0 3/26/2023 13:00 3/26/2023 13:30 0.50 COMPZN, RPCOMP SVRG P Service rig test fit new blower // service td and tongs 0.0 0.0 3/26/2023 13:30 3/27/2023 00:00 10.50 COMPZN, RPCOMP PUTB P Pick up and run 1R-34 completion 0.0 8,400.0 3/27/2023 00:00 3/27/2023 05:30 5.50 COMPZN, RPCOMP PUTB P Pick up upper completion 8,400.0 11,853.0 3/27/2023 05:30 3/27/2023 05:42 0.20 COMPZN, RPCOMP HOSO P Joint 407 Kelly up, PUW=100K, SOW=65K. Pumps online 1 BPM @ 90 PSI RIH. Observed pressure increase to 125 PSI @ 4' in on jt 407. 11,853.0 11,857.0 3/27/2023 05:42 3/27/2023 06:42 1.00 COMPZN, RPCOMP HOSO P Measured in 21' to 11,874 1K down. PUH to string weight. RBIH to confirm locate. Pull joint 407,406, and 405. 11,857.0 11,800.0 3/27/2023 06:42 3/27/2023 07:12 0.50 COMPZN, RPCOMP HOSO P Compute space out, 4 pups, OAL=26.93' 11,826.0 11,826.0 3/27/2023 07:12 3/27/2023 08:42 1.50 COMPZN, RPCOMP PUTB P Make up joint 405 above space out pups. Hook up circulation line to tubine, Make up tubing haner & hanger pup 11,826.0 11,859.1 3/27/2023 08:42 3/27/2023 11:36 2.90 COMPZN, RPCOMP CIRC P Pump 12.0 inhibited brine, 2.5 BPM @ 300 psi 11,859.1 11,859.1 3/27/2023 11:36 3/27/2023 11:54 0.30 COMPZN, RPCOMP PUTB P Shut down pump, PUH to lubricate hanger seals. Confirm LDS retracted 11,859.1 11,850.0 3/27/2023 11:54 3/27/2023 12:18 0.40 COMPZN, RPCOMP PUTB P RIH to land competion, bottom seal @ 11,872 11,850.0 11,872.0 3/27/2023 12:18 3/27/2023 12:48 0.50 COMPZN, RPCOMP PRTS P Line up down tubing pressure up 3850 PSI. Hold for 30 minutes - Good test 11,872.0 11,872.0 Rig: NABORS 7ES RIG RELEASE DATE 3/28/2023 Page 5/5 1R-34 Report Printed: 4/26/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/27/2023 12:48 3/27/2023 13:48 1.00 COMPZN, RPCOMP PRTS P Bleed tubing down to 1500PSI. Line up down IA. Pressure up to 2750. Hold for 30 minutes - Good test 11,872.0 11,872.0 3/27/2023 13:48 3/27/2023 14:00 0.20 COMPZN, RPCOMP OTHR P Bleed off tubing observe SOV release 11,872.0 11,872.0 3/27/2023 14:00 3/27/2023 15:00 1.00 COMPZN, WHDBOP OTHR P Lay down landing jt flush stack for nipple down Set BPV 11,872.0 0.0 3/27/2023 15:00 3/27/2023 17:30 2.50 COMPZN, WHDBOP NUND P Rig on Gen pwr 15:15, Nipple down stack 0.0 0.0 3/27/2023 17:30 3/27/2023 18:00 0.50 COMPZN, WHDBOP SVRG P Service squeeze manifold 0.0 0.0 3/27/2023 18:00 3/27/2023 23:00 5.00 DEMOB, MOVE OTHR P nipple up tree // Test void on well head 5000psi 10 min good test // Test tree 5000psi good test // pull BPV 0.0 0.0 3/27/2023 23:00 3/28/2023 00:00 1.00 DEMOB, MOVE FRZP P Rig up Little red pressure test lines // Pump 75 bbls diesel down IA taking returns up tubing Rig released 00:00 3/28/23 Final Pressures Tubing 400psi IA 475psi OA 80psi 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 3/28/2023 DTTMSTART JOBTYP SUMMARYOPS 3/7/2023 ACQUIRE DATA RIH W/ HEX PLUG, SIT DOWN AT 13038.5' WITH BOTTOM OF PLUG, UNABLE TO GET DEEPER. SET 1.80" HEX PLUG AT 13,035.8' (MID-ELEMENT), CCL TO ME, 14.3', CCL STOP DEPTH = 13021.5'. JOB COMPLETE, READY FOR DHD 3/8/2023 ACQUIRE DATA (PRE RWO) T DDT (COMPLETE), IA DDT (COMPLETE) 3/9/2023 ACQUIRE DATA W/ 10' x 2" DUMP BAILER LAY IN 1.3 GALLONS OF CaCO3 ON TOP OF HEX PLUG @ 13,032' RKB. IN PROGRESS. 3/10/2023 ACQUIRE DATA MAKE MULTIPLE RUNS W/ 10' X 2" DUMP BAILER LAYING IN 5 GALLONS OF CaCO3 ON TOP OF HEX PLUG (TOP OF CaCO3 @ 13,022' RKB). READY FOR E-LINE. 3/11/2023 ACQUIRE DATA STRING SHOT INTERVAL FROM 12,966' - 12,975' CUT 3-1/2" TUBING WITH 2" RCT AT 12,975' (MID-JOINT) JOB COMPLETE, READY FOR RWO 3/20/2023 RECOMPLETION Move off Well 101 and Stage Sub on 1H pad. Nabors change out bridal lines. Change flow line to pits. Moving auxiliary to 1R-Pad. Move Pits, Shop and Camp. Prep and move Sub F/1H-Pad T/1R-pad. 3/21/2023 RECOMPLETION Complete move in and rig up over 1R-34, Rig accepted 11:00 on 3/21/23, bring on KWF perform well kill ops, remove tree and nipple up stack, start between wells maintenance 3/22/2023 RECOMPLETION Finished between wells maintenance, rigged up for and completed initial 250/4500 witness waived Sean Sullivan test, rig down test equipment pick up landing jt., back out LDS pull hanger off seat 100K, lay down completion to 7500' 3/23/2023 RECOMPLETION Continued to lay down completion, finish processing drill pipe and collars, pick up BHA# 1 clean out assembly, RIH picking up drill pipe 3/24/2023 RECOMPLETION Continued picking up pipe to stump @ 12,962 , clean packer setting area, TOOH for packer run, lay down bha and inspect boot baskets no abnormal debris, pick up packer and trip in hole on stands 3/25/2023 RECOMPLETION Continued in hole washing over stump @ 12963 NG, pick up circulate 30 bbls CI into well, spot 20 bbls out side of pipe, NG @ 12963 pick up to string wt 170K drop ball and rod set packer per baker rep, test packer 3000psi 30 min good test, move up hole looking for leak 50 jts at a time, Found leak below 9417' packer setting area, test casing 3000psi 30 min good test, lay down drill pipe 3/26/2023 RECOMPLETION Finish laying down drill pipe and BHA, Tally tubing and start picking up upper completion 3/27/2023 RECOMPLETION Complete running upper completion, land on depth setting hanger, MIT tubing and IA passed, Nipple down stack nipple up tree, freeze protect Rig released 00:00 3/28/23 4/5/2023 ACQUIRE DATA (DELAYED START DUE TO INCORRECT TREE CAP FLANGE) SHOOK OFF BAITED 2'' BALL n' ROD PULLING TOOL @ 9800' RKB; PULLED SOV & SET OV @ 9343' RKB; PULLED DMY'S @ 7844', 2994' RKB & SET GLV'S (OBTAIN GOOD TBG TEST TO 2000). IN PROGRESS. 4/6/2023 ACQUIRE DATA PULLED BAITED PULLING TOOL @ 12,932' RKB; BAIL FILL & PULLED BALL n' ROD @ 12,948' RKB; PULLED RHC PLUG BODY @ 12,957' RKB. IN PROGRESS. 4/7/2023 ACQUIRE DATA BAIL FILL FROM 12,979'-13,033' RKB; LATCH & ATTEMPTED TO PULL 1.81" HEX PLUG. IN PROGRESS. 4/8/2023 ACQUIRE DATA ATTEMPT TO LATCH 1.81'' HEX PLUG @ 13033' RKB (UNABLE TO LATCH); BAILED FILL FROM HEX PLUG & ATTMEPT TO LATCH W/ NO SUCCESS; RAN BARBELL 2.58'' LIB TO 13033' RKB (INCONCLUSIVE). IN PROGRESS. 4/9/2023 ACQUIRE DATA RAN 2.5" HYDROSTATIC BAILERS DOWN TO HEX PLUG @ 13,033' RKB (MINIMAL AMOUNT OF RETURNS); ATTEMPT TO LATCH HEX PLUG (NO SUCCESS); RAN 2.5" PUMP BAILER W/ FLAPPER BOTTOM DOWN TO 13,033' RKB (NO RETURNS). IN PROGRESS. 4/10/2023 ACQUIRE DATA RAN VARIOUS BAILERS TO 13,033' RKB RECOVERING SMALL AMOUNTS OF FILL; ATTEMPT TO LATCH W/ 1.5'' GR (NO SUCCESS); RAN BARBELL 2'' IMPRESSION BLOCK DOWN TO 13,033' RKB (INCONCLUSIVE). IN PROGRESS. 4/13/2023 ACQUIRE DATA RAN 2-1/2" PUMP BAILER TO 13,033' RKB, RECOVERED ~1/2 GAL OF SAND. MADE SEVERAL UNSUCCESSFUL ATTEMPTS TO PULL HEX PLUG @ 13,033' RKB, IN PROGRESS 4/14/2023 ACQUIRE DATA BAILED ~1 GAL OF SAND FROM HEX PLUG @ 13,033' RKB, RAN 2.62" LIB, IMPRESSION OF FILL, BAILED ~1/2 GAL OF SAND FROM HEX PLUG @ 13,033' RKB, IN PROGRESS 4/15/2023 ACQUIRE DATA BAILED ~1 GAL OF SAND/RIG DEBREE FROM HEX PLUG @ 13,033' RKB. ATTEMPTED TO PULL HEX PLUG @ 13,033' RKB (UNSUCCESSFUL), IN PROGRESS 4/16/2023 ACQUIRE DATA BAILED ~1/4 GAL OF SAND FROM HEX PLUG @ 13,033' RKB, ATTEMPTED TO PULL HEX PLUG @ 13,033' RKB (UNSUCCESSFUL), IN PROGRESS 4/17/2023 ACQUIRE DATA RAN 2.62" LIB TO HEX PLUG @ 13,033' RKB (IMPRESSION OF FN FILLED W/ SAND), RAN 1" POCKET POKER TO BREAK UP SAND. RAN 2-1/2" HYDROSTATIC BAILER TO HEX PLUG @ 13,033' RKB, RECOVERED 2 CUPS OF SAND. ATTEMPTED TO PULL HEX PLUG @ 13,033' RKB, UNABLE TO LATCH. RIG DOWN, COIL NEEDED TO WASH HEX PLUG. 1R-34 RWO Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 13,176.0 1R-34 11/18/2013 hipshkf Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Installed GLD, Pulled RHC Plug, & Bailed CaC03 1R-34 4/7/2023 zembaej General Notes: Last 3 entries Com Date Last Mod By One 2.5"" roller from roller stem missing in well. 8/14/1999 Admin 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 41.0 121.0 121.0 62.58 H-40 WELDED SURFACE 9 5/8 8.83 40.6 7,133.2 4,069.8 40.00 L-80 BTC PRODUCTION 7x5 7 6.28 39.5 13,560.0 6,989.7 26.00 L-80 BTC-MOD Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 0.1 Set Depth 12,884.8 Set Depth 6,491.4 String Ma 3 1/2 Tubing Description Tubing Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8r ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 36.7 36.6 0.08 Hanger 6.990 3.5" x 11" FMC Tubing Hanger Gen 4 FMC TC-1A- EN # P100022 0888 2.960 515.4 515.4 1.00 Nipple - X 4.545 2.813" X-Nipple Halliburt on LN,2.81 3,X,41X X LAS,3 1/2-9.30 API,B-P 2.813 2,944.4 2,618.2 61.19 Mandrel GAS LIFT 5.390 3.5" x 1" KBMG SLB KBMG 2.920 7,843.9 4,320.7 68.19 Mandrel GAS LIFT 5.390 3.5" x 1" KBMG SLB KBMG 2.920 9,342.6 4,859.6 68.37 Mandrel GAS LIFT 5.390 3.5" x 1" KBMG SLB KBMG 2.920 9,401.2 4,881.0 68.77 Halliburton TNT Packer 6.280 TECHHOLD PKR,7,26-29,3 1/2- 9.30 VAMTOP,B-P Halliburt on TECHH OLD PKR,7,2 6-29,3 1/2-9.30 VAMTO P,B-P 2.902 12,840.7 6,458.9 42.45 Nipple - X 4.545 2.813" X-Nipple Halliburt on LN,2.81 3,X,41X X LAS,3 1/2-9.30 API,B-P 2.813 12,862.1 6,474.7 42.61 Locator 4.170 3.5" locator BOT 2.992 12,863.1 6,475.4 42.63 Seal Assembly 3.970 "PBR" Seal Assembly spaced out 2.14' off tag BOT 2.992 Top (ftKB) 12,864.3 Set Depth 12,979.8 Set Depth 6,559.8 String Ma 3 1/2 Tubing Description Tubing Completion Lower Wt (lb/ft) 9.30 Grade L80 Top Connection EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 12,864.3 6,476.3 42.66 PBR 5.880 20 ft "PBR" Polish Bore Receptacle Baker 80-40 2.992 12,899.1 6,501.8 43.36 Packer 6.280 Baker Premier Production Packer Baker Premier 2.970 12,957.1 6,543.6 44.35 Nipple - X 3.760 Nipple - X HES 2.813 12,973.5 6,555.3 44.41 Overshot 5.990 Overshot BOT 3.620 Top (ftKB) 12,964.3 Set Depth 13,023.1 Set Depth 6,590.7 String Ma 3 1/2 Tubing Description Tubing Production Wt (lb/ft) 9.30 Grade L-80 Top Connection N/A 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) 13,001.5 6,575.3 44.52 LOCATOR 5.000 BAKER LOCATOR BAKER 2.990 13,002.6 6,576.0 44.52 Seal Assembly 3.980 Seal Assembly BAKER 2.990 Top (ftKB) 13,006.9 Set Depth 13,075.0 Set Depth 6,627.7 String Ma 5.87 Tubing Description STACKER PACKER Wt (lb/ft) Grade Top Connection Acme ID (in) 2.98 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) 13,006.9 6,579.1 44.54 PACKER 5.870 BAKER F-1 PRODUCTION PACKER 4.000 13,010.2 6,581.5 44.55 SBE 5.870 BAKER SEAL BORE EXTENSION 2.980 13,044.6 6,606.0 44.56 NIPPLE 4.520 CAMCO "D" NIPPLE WITH 2.75" X 1.81" NIPPLE REDUCER SET, ID IS REDUCED TO 1.81" CAMCO "D" 1.810 13,056.0 6,614.1 44.44 SEAL ASSY 4.000 BAKER SEAL ASSY 2.920 13,071.0 6,624.8 44.29 MULE SHOE 3.500 BAKER MULE SHOE 2.920 1R-34, 4/26/2023 7:51:12 AM Vertical schematic (actual) PRODUCTION 7x5; 39.5- 13,560.0 FISH; 13,168.0 IPERF; 13,181.0-13,216.0 FISH; 13,180.0 PACKER; 13,056.0 NIPPLE; 13,044.6 NIPPLE REDUCER; 13,044.0 PLUG; 13,032.7 PACKER; 13,006.9 CUT; 12,975.0 Nipple - X; 12,957.1 Packer; 12,899.0 Nipple - X; 12,840.7 LEAK - CASING; 9,538.0 Halliburton TNT Packer; 9,401.1 Mandrel GAS LIFT; 9,342.6 Mandrel GAS LIFT; 7,843.9 SURFACE; 40.6-7,133.2 Mandrel GAS LIFT; 2,944.4 Nipple - X; 515.4 CONDUCTOR; 41.0-121.0 Hanger; 36.6 KUP PROD KB-Grd (ft) RR Date 1/14/1995 Other Elev 1R-34 ... TD Act Btm (ftKB) 13,570.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292253400 Wellbore Status PROD Max Angle & MD Incl (°) 71.98 MD (ftKB) 5,416.11 WELLNAME WELLBORE1R-34 Annotation Last WO: End Date 3/27/2023 H2S (ppm) 200 Date 9/4/2011 Comment SSSV: NIPPLE Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 13,056.0 Set Depth 13,074.1 Set Depth 6,627.1 String Ma 5 7/8 Tubing Description TUBING Original Wt (lb/ft) 9.30 Grade p-110 Top Connection ID (in) 4.00 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) 13,056.0 6,614.1 44.44 PACKER 5.875 BAKER FB-1 PACKER 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) 9,538.0 4,929.8 69.30 LEAK - CASING Casing leak found at 9538', using RST WFL, 0.5 BPM AT 2500 PSI. Likely additional leak at 9570' 8/30/2019 6.260 12,975.0 6,556.4 44.41 CUT 2" RCT TBG CUT AT 12,975' (MID-JT) 3/11/2023 2.992 13,032.7 6,597.5 44.64 PLUG 1.80" HEX PLUG MID- ELEMENT AT 13,035.8', FISHNECK 1.5" GS, OAL 5.85' INTERW ELL 180-288 HEX 40386 8 3/7/2023 0.000 13,044.0 6,605.5 44.57 NIPPLE REDUCER 2.75" X 1.81" CAMCO NIPPLE REDUCER. NOTE: NIPPLE REDUCDER IS NO LONGER USABLE. THE REDUCER UNSEATED WITH DP. IT WAS PUSHED BACK DOWN TO THE 2.75" D NIPPLE. SEE WSR DATED 07/11/20 11/30/2019 1.810 13,168.0 6,694.9 43.26 FISH 73' SPENT TBG PERF GUN Perfed 3/19/95 (SWS 3 3/8" HSD) Tagged 4/13/95 3/20/1995 0.000 13,180.0 6,703.6 43.13 FISH ROLLER One 2.5" roller from roller stem missing in well. 8/14/1999 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,944.4 2,618.2 61.19 1 GLV BK 1 1,287.0 4/5/2023 Schlumb erger BK 0.250 7,843.9 4,320.7 68.19 2 GLV BK 1 1,202.0 4/5/2023 Schlumb erger BK 0.250 9,342.6 4,859.6 68.37 3 OV BEK 1 0.0 4/5/2023 Schlumb erger BK 0.313 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 13,181.0 13,216.0 6,704.3 6,730.0 A-3, 1R-34 3/19/1995 4.0 IPERF 180 deg. phasing; 3 3/8" HSD TBG Conveyed 1R-34, 4/26/2023 7:51:12 AM Vertical schematic (actual) PRODUCTION 7x5; 39.5- 13,560.0 FISH; 13,168.0 IPERF; 13,181.0-13,216.0 FISH; 13,180.0 PACKER; 13,056.0 NIPPLE; 13,044.6 NIPPLE REDUCER; 13,044.0 PLUG; 13,032.7 PACKER; 13,006.9 CUT; 12,975.0 Nipple - X; 12,957.1 Packer; 12,899.0 Nipple - X; 12,840.7 LEAK - CASING; 9,538.0 Halliburton TNT Packer; 9,401.1 Mandrel GAS LIFT; 9,342.6 Mandrel GAS LIFT; 7,843.9 SURFACE; 40.6-7,133.2 Mandrel GAS LIFT; 2,944.4 Nipple - X; 515.4 CONDUCTOR; 41.0-121.0 Hanger; 36.6 KUP PROD 1R-34 ... WELLNAME WELLBORE1R-34 1 Regg, James B (OGC) From:Yearout, Paul <Paul.Yearout@nabors.com> Sent:Saturday, March 25, 2023 7:41 AM To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); NSK RWO CM Cc:greg.s.hobbs@conocophillips.com; Kneale, Michael L; Henson, James; Morales, Tony; Cozby, Kelly; Medina, Johnny Subject:7ES BOP Test report 3-22-23 1R-34 Attachments:Nabors 7ES 3-22-23.xlsx Thank you Paul Yearout 7ES Toolpusher Nabors Alaska Drilling Inc. Office 907‐670‐ 6132 Cell 907‐244‐6322 paul.yearout@nabors.com ******************************* NABORS EMAIL NOTICE - This transmission may be strictly proprietary and confidential. If you are not the intended recipient, reading, disclosing, copying, distributing or using the contents of this transmission is prohibited. If you have received this in error, please reply and notify the sender (only) and delete the message. Unauthorized interception of this e-mail is a violation of federal criminal law. This communication does not reflect an intention by the sender or the sender's principal to conduct a transaction or make any agreement by electronic means. Nothing contained in this message or in any attachment shall satisfy the requirements for a writing, and nothing contained herein shall constitute a contract or electronic signature under the Electronic Signatures in Global and National Commerce Act, any version of the Uniform Electronic Transactions Act, or any other statute governing electronic transactions. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. KRU 1R-34PTD 1941620 C:\Users\mdguhl\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\LCF4WGUY\2022-11-28_22062_KRU_1R-34_LeakPoint Survey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 22062 KRU 1R-34 50-029-22534-00 LeakPoint Survey 28-Nov-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE,INC., 4141 B STREET,SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM By Meredith Guhl at 8:06 am, Dec 14, 2022 194-162 T37371 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.12.14 08:07:37 -09'00' ! 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Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #CD # 1 2T-08 50-103-20070-00 906569204 Kuparuk River Multi Finger Caliper Field & Processed 25-Jun-20 0 1 2 3H-20 50-103-20093-00 906581746 Kuparuk River Multi Finger Caliper Field & Processed 30-Jun-20 0 1 3 1F-19 50-029-22660-00 906611163 Kuparuk River Multi Finger Caliper Field & Processed 20-Jul-20 0 1 4 1G-05 50-029-20908-00 906614905 Kuparuk River Packer Setting Record Field- Final 27-Jul-20 0 1 5 1R-34 50-029-22534-00 906617820 Kuparuk River Plug Setting Record Field- Final 22-Jul-20 0 1 6 2C-15 50-029-21219-00 906631899 Kuparuk River Multi Finger Caliper Field & Processed 31-Jul-20 7 2C-15 50-029-21219-00 906631899 Kuparuk River Plug Setting Record Field- Final 30-Jul-20 8 2T-08 50-103-20070-00 906595629 Kuparuk River Packer Setting Record Field- Final 13-Jul-20 0 1 9 2U-02 50-029-21268-00 906629021 Kuparuk River Multi Finger Caliper Field & Processed 29-Jul-20 10 2U-02 50-029-21268-00 906629020 Kuparuk River Leak Detect Log Field- Final 29-Jul-20 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 0 1 0 1 Received by the AOGCC 10/05/2020 PTD: 1941620 E-Set: 34055 10/07/2020 Abby Bell WELL LOG TRANSMITTAL #906120358 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 1R-34 Run Date: 11/30/2019 3, 94 4 January 16, 2020 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of- Fanny f Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1R-34 Digital Data in LAS format, Digital Log Image file f b!z': 1 CD Rom 50-029-22534-00 <# ✓ V222pa0 400 cc 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 FRS_ANC@hailiburton.com Date: C ��� Signed: Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: n n sj AOGCC -yt ATM: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 ---o&j Anchorage, AK 99501 194162 31474 TRANSMfTTALDATE15-Nov-19 15Nov19-1W 03 WELL NAME 1D -125A 1R-34 API # 50-029.22904-01 50-029-22534-00 ORDERSERVICE # DWUJ-00138 DWUJ-00142 FIELD NAME KUPARUK RIVER KUPARUK RIVER SERVICE DESCRIPTION WL WL1 DELIVERABLE DESCRIPTION Caliper, CBL Caliper DATA TYPE FINAL FIELD FINAL FIELD Color DATELOGGED Prints 15.Oct-19 20 -Oct -19 r 1 3G-18 3N-15 3N-09 1F-12 1A-01 11-1-109 1H-113 1H-117 50-103-20142-00 50-029-21592-00 50-029-21541-00 50-029-21012-00 50-029-20590-00 50-029.23595-00 50-029.23588-00 50-029-23602-00 E5C2-00012 EOSH-00109 EOSH-00111 DWUJ-00146 DWUJ-00147 DWUJ-00149 E5C2-00013 E5C2-00014 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL WL WL1 WL WL WL LDL LDL Caliper P PPROF PPROF (PROF IPROF (PROF FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 29 -Oct -19 30 -Oct -19 5 -Nov -19 8 -Nov -19 9 -Nov -19 12 -Nov -19 13 -Nov -19 14 -Nov -19 1 1 1 1 1 1 1 10 me return via courier or sign/scan and email a copy to Date and CPA]. Schlumberger -Private A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. WELL LOG TRANSMITTAL #905904903 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log: 1R-34 Run Date: 8/14/2019 194162 39355 October 16, 2019 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 1R-34 Digital Data in LAS format, Digital Log file RECEIVED 1 CD Rom 50-029-22534-00 OCT 2 3 2019 A®GCC 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 FRS—ANC@halliburton.com Date:51! Signed: Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax Delivered to: n AOGCC � ATTN: Natural Resources Technician It Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 "'fes Anchorage, AK 99501 TRANSMITTAL DATE TRANSMITTAL# 1C-20 1H-04 2A-25 1H-105 1R-34 2A -27A U-1561-2 1H-115 50.029-23273.00 50-029-20770-00 50.103-20239-00 50-029-20727-01 50-029-22534-00 50-103.20604-01 50-029.23311-61 50.029-23605-00 ••r EDEA•00011 E118-00096 EOSH-00086 EOSH-00087 EOSH-00088 EOSH-00090 EDEA -00019 EOSH-00094 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER Memory WL WL WL WL WL Memory WL W (PROF IPROF Caliper P IPROF LDL-WFL IPROF IPROF IPROF IPROF FINAL FIFINAL FIELD ELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 2 -Aug -19 27 -Aug -19 28 -Aug -19 29 -Aug -19 30 -Aug -19 2 -Sep -19 5 -Sep -19 5 -Sep -19 r 1 1 1 1 1 1 1 1 8 Na Signature Please return via courier or sign/scan and email a copy to A Transmittal Receipt signature confirms that a package (box, nvelope, etc.) has been received and the contents of the package have been verified to match the media noted above. Date The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this and CPAI. point. Schlumberger -Private SLB Originated: Schlumberger PTS- PRINT CENTER 6411 A Street Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax Delivered to: AOGCC � \ ATTN: Natural Resources Technician II J Alaska Oil & Gas Conservation Commision is 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 TRANSMITTAL DATE TRANSMITTAL It r. i WELL NAME API p SERVICE ORDER N SERVICE FIELD NAME DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE Color DDAATTEE�LIO�GG�ED Prints CD's ® r r r l a rrr • �® r ��-0 /A Transmittal Receipt signature confirms that a package. (box, "'•`III Gj envelope, etc.) has been received and the contents of the X 1, l package have been verified to match the media noted above. Skatu Date The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this return via courier or sign/scan and email a copy to Sch umberger and CPAI. point. 'TSPrintCenterC�slb com ohil p cam _ SLB Auditor - .TW Schlumberger -Private XHVZE Pages NOT Scanned in this Well History File 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:~Dianna Vincent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is/ 1 STATE OF ALASKA RECEIVED ALA A OIL AND GAS CONSERVATION COMMIoSION �l REPORT OF SUNDRY WELL OPERATIONS DEC 112013 1.Operations Performed: Abandon r Repair w ell [ • Plug Perforations r Perforate r Other Alter Casing r Pull Tubing Fil• Stimulate-Frac r Waiver r Time ExtensioAloGGC Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory r 194-162 • 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-22534-00• 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25628 • 1 R-34 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool • 11.Present Well Condition Summary: Total Depth measured 13570 feet Plugs(measured) none true vertical 6997 feet Junk(measured) 13180' Effective Depth measured 13465 feet Packer(measured) 13007, 13056 true vertical 6917 feet (true vertical) 6579,6614 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121 121 SURFACE 7093 9.625 7133 4070 PRODUCTION 13521 7"x 5" 13560 6990 Perforation depth: Measured depth: 13181-13216 True Vertical Depth: 6704-6730 SCANNED :IAN 2 7 21,114 Tubing(size,grade,MD,and ND) 3.5, L-80, 13163 MD,6691 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER FB-1 PACKER @ 13007 MD and 6579 TVD PACKER-BAKER FB-1 PACKER @ 13056 MD and 6614 TVD LANDING NIPPLE-CAMCO DS @ 538 TVD and 538 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this workover 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 shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run _ Exploratory r Development r • Service r Stratigraphic r 16.Well Status after work: Oil r . Gas r VVDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: none Contact Jake Voss Cad 265-6935 Email Jake.Vossconocophillips.com Printed Name ake Voss ' Title Drilling Engineer Signature 1/ Phone:265-6935 Date I i/te/t 3 V1-J RSr:\ E DEC 1621k, /// O / / - Form 10-404 Revised 10/2012 " •vp Submit Original Only f KUP PROD 1R-34 Cono i hillips Øg Well Attributes (Max Angle&MD TD Alaska Inc. Wellbore API/UW Field Name Wellbore Status ncl(°) MD OMB) Act Btm(ftKB) txrriciosis 500292253400 KUPARUK RIVER UNIT PROD 71.98 5416.11 13,570.0 ... Comment Date Annotation End Date KBGrd(ft) Rig Release Date 1R-34,12/10/2013 1:37.26 PM SSSV:NIPPLE 1 H2S(ppm)200 9/4/2011 Last WO: I 11/12/2013 1 1/14/1995 Vertical schematic(actual) _ Annotation I Depth(ftKB) !End Date Annotation 'Last Mod By End Date Last Tag:SLM 13,176.0 11/18/2013 Rev Reason:WORKOVER,PULL PLUG,GLV haggea 12/10/2013 .. _.._. I"�I _..__.. C/O HANGER;35.6 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.063 41.0 121.0 121.0 62.58 H-40 WELDED Casing Description OD(in) -ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread SURFACE 95/8 8.835 40.6 7,133.2 4,069.8 40.00 L-80 BTC 1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WI/Len(I...Grade Top Thread PRODUCTION 7x5 7 6.2761 39.5 13,560.0 6,989.7 26.00 L-80 BTC-MOD Tubing Strings Tubing Description (String Ma,,.1ID(in) (Top(111)8) (Set Depth 111..1 1 Set Depth(ND)(...Wt(lb/ft) (Grade I Top Connection U .,,TUBING WO 3 1/2 2.992 36.6 13,023 1 6.590.7 9 30 L-80 EUE 8rnd Completion Details • CONDUCTOR;41.0121.0 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Inc'(°) Item Des Corn (in) 36.6 36.6� 0.08 HANGER FMC TUBING HANGER 2.992 538.2 538.2 1.00 NIPPLE CAMCO"DS"NIPPLE 2.812 NIPPLE;539.2 13,001.5 6,575.2' 44.52 LOCATOR BAKER LOCATOR 2.990 13,002.6 6,576.0' 44.52 SEAL ASSY BAKER SEAL ASSY 2.990 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection STACKER PACKER I 5.871 2.9801 13,006.9 13,075.01 6,627.7 I I Acme GAS LIFT,2,929.1 Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Inc)(°) Item Des Com (in) 13,006.9 6,579.1 44.54 PACKER BAKER F-1 PRODUCTION PACKER 4.000 13,010.2 6,581.5 44.55 SBE BAKER SEAL BORE EXTENSION 2.980 in 13,044.6 6,606.0 44.56 NIPPLE CAMCO"D"NIPPLE 2.750 GAS LIFT;6,340.7 13,056.0 6,614.1 44.44 SEAL ASSY BAKER SEAL ASSY 2.920 13,071.0 6,624.8 44.29 MULE SHOE BAKER MULE SHOE 2.920 Tubing Description IString Ma,..I1D(in) (Top(ftKB) Set Depth(ft..1Set Depth(ND)(...IWt pbkt) [Grade 'Top Connection TUBING Original 57/8 4.000 13,056.0 13,074.1 6,627.1 9.301p-110 Completion Details •• Nominal ID Top(ftKB) Top(ND)(ftKB) Top loci(°) Item Des Com (in) SURFACE;40.6-7,133.2- 13,056.0 6,614.1 44.44 PACKER BAKER FB-1 PACKER 4.000 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Inc! GAS UFT;9076.7 ,. Top(111)8) (ftKB) (°) Des Com Run Date ID(in) 13,168.0 6,694.9 43.26 FISH 73'SPENT TBG PERF GUN Perfed 3/19/95(SWS 3 3/20/1995 0.000 3/8"HSD) Tagged 4/13/95 13.180.0 6,703.6 43.13 FISH ROLLER One 2.5"roller from roller stem missing in 8/14/1999 0.000 well. GAS UFT;11,103.4 a I Perforations&Slots a Shot Dens Top(ND) Stm(ND) (shotsk • MITop(ftKB) Btm(ft(B) (ftKB) (ftKB) Zone Date t) Type Com GAS LIFT;12,330.0 • 13,181.0 13,216.0 6,704.3 6,730.0 A-3,1R-34 3/19/1995 4.0 IPERF 180 deg.phasing;33/8" HSD TBG Conveyed Mandrel Inserts St ati C GAS LIFT:12.943.3 GI on Top(TVD) Valve Latch Port Size TRO Run m Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date I 1 2,929.1' 2,610.8'CAMCO KBMG 1 GAS LIFT GLV BK 0.156 0.0 12/4/2013 2 6,340.7 3,790.9 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,339.0 12/52013 al 3 9,076.7 4,760.5 CAMCO KBMG 1 GAS LIFT OV BK 0.250 0.0 11/28/2013 4 11,103.4 5,510.3 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 11/92013 LOCATOR;13,0015 1.1 5 12,330.0- 6,112.4 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 11/9/2013 •p• 6 12,943.3 6,533.7 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 11/92013 latr PACKER;13,006.9 I • Notes:General&Safety SEAL ASSY;13,002.5 End Date Annotation SBE;13,010.2 10/21/2010 NOTE:View Schematic w/Alaska Schematic9.0 et rNIPPLE:13.0446 ASSY;13,056.0 �I 1- SEAL :�_ PACKER;13,0560 Z l MULE SHOE;13,071.0 )°il, IS FISH;13,180.0 (PERF;13,181 A13216..\ FISH;13,188.0 PRODUCTION 705;39.5- 13,580.0 1 R-34 Well Work Summary • DATE SUMMARY 9/23/2013 PULLED PRONG FROM CA-2 PLUG BODY @ 13050' RKB. MADE 2 ATTEMT3S TO PULL 2.75"CA- 2 PLUG BODY FROM 13050' RKB. RAN 2.50"x 10' P.BAILER AND RECOVERED—1/2 GALL OF SCALE FROM CA-2 PLUG BODY. MADE ANOTHER ATTEMPT TO PULL CA-2 PLUG BODY FROM 13050' RKB. 9/24/2013 MADE 5 BAILER RUNS WITH 2.50"x 10' P.BAILER. BAILED FROM 12987'SLM TO 12993' SLM. RECOVERED 2-1/4 GALLONS OF SCALE...JOB IN PROGRESS. 9/29/2013 MADE 4 BAILER RUNS FROM 12986'SLM TO 10987' SLM AND RECOVERED 1/4 GALLON OF SCALE. MADE 1 ATTEMPT TO PULL CA-2 PLUG BODY FROM 13050' RKB. 9/30/2013 MADE 5 BAILER RUNS FROM 12986'SLM TO 12992'SLM AND RECOVERED 1/4 CUP OF SCALE. METAL MARK ON BTM OF BAILER ON LAST RUN. 10/1/2013 MADE 2 ATTEMPTS TO PULL CA-2 PLUG FROM D-NIPPLE @ 13050' RKB. RAN 2.50" HYDROSTATIC BAILER AND RECOVERED 1 CUP OF FINE SCALE FROM 13050' RKB. PULLED CA-2 PLUG BODY FROM 13050' RKB...JOB IN PROGRESS 10/2/2013 PERFORMED A-SAND SBHPS WITH DSL TOOLS. GOOD DATA. BRUSH & FLUSH LOGGING INTERVALS FROM 13170' RKB TO 12950' RKB. LRS USED 83 BBLS. RAN 2.69"WFD WRP, UNABLE TO PASS D-NIPPLE @ 13050' RKB. UNABLE TO GET TOOLS FREE. DISCONNECTED FROM DIGITAL CONTROL RELEASE. 25' FISH LEFT IN HOLE, 1.75" F.N. LOOKING UP...JOB IN PROGRESS 10/7/2013 ATTEMPTED TO FISH TOOLSTRING @ 12975' SLM, UNABLE TO LATCH FISHING NECK POSSIBLE DUE TO FILL ON TOP OF THE TOOLSTRING 10/8/2013 RAN 2.5"x 10' PUMP BAILER TO FISH @ 12975' SLM, RECOVERED —2 CUPS OF SAND, METAL MARKS ON BAILER BOTTOM, IN PROGRESS 10/10/2013 RAN 2.50"x 10' PUMP BAILER TO TOOLSTRING @ 12975' SLM, RECOVERED 2 CUPS OF SAND, JARRED ON TOOLSTRING FOR 1 hr, NO MOVEMENT, LOST SPANGS AFTER 45min OF JARRING ***REQUIRES"S"CORE TO LATCH FISHING NECK, JDC OR SB WILL NOT LATCH*** 10/13/2013 BAILED 1 CUP SCALE @ 12997'SLM. RIH WITH P/T TO 12994' SLM, UNABLE TO LATCH FISH. IN PROGRESS. 10/17/2013 SLB CTU#6: ATTEMPT TO FISH DIGITAL SLICKLINE TOOSTRING (WRP SETTING ASSEMBLY) FROM NIPPLE 13050'. STACKED OUT ON FISH MULTIPLE TIMES WITH BOWEN SERIES 10 OVERSHOT WITH 1.688 GRAPPLE. OBSERVED OVERPULL WITH —2K#INCREASE IN UP WEIGHT. NO FISH-METAL MARKS ON BOTTOM OF GRAPPLE. RESTART IN MORNING. 10/18/2013 SLB CTU#6: ATTEMPT TO FISH DIGITAL SLICKLINE TOOSTRING (WRP SETTING ASSEMBLY) FROM NIPPLE 13050'. LATCH FISH WITH SL 2-1/2"JUS WITH 3" 'GS' BAIT SUB. HIT 43 UP JAR HITS (G FORCE JARS) BEFORE THEY QUIT. PUMP OFF GS SPEAR LEAVING FISH BAITED. RIG BACK AND CUT PIPE. RESTART IN MORNING. 10/19/2013 SLB CTU#6:ATTEMPT TO FISH DIGITAL SLICKLINE TOOSTRING (WRP SETTING ASSEMBLY) FROM NIPPLE 13050'. LATCH FISH WITH SL 2-1/2"JUS WITH 3"'GS' BAIT SUB. HIT 11 UP JAR HITS (BOWEN OIL JARS) BEFORE THEY QUIT. PUMP OFF GS SPEAR LEAVING FISH BAITED. RIG BACK AND CUT PIPE. RESTART IN MORNING. 10/20/2013 SLB CTU#6:ATTEMPT TO FISH DIGITAL SLICKLINE TOOSTRING (WRP SETTING ASSEMBLY) FROM NIPPLE 13050'. SPOT 150 BBLS DIESEL WITH 0.9 PERCENT 776 FRICTION REDUCER IN TUBING. LATCH BAITED FISH WITH 3"'GS'SPEAR. APPEAR TO BE GETTING GOOD WEIGHT TRANSFER DOWNHOLE. GET 55 GOOD UP JAR HITS WITH 20K#OVERPULL(CTT OIL JARS). PUMP OFF GS SPEAR LEAVING FISH BAITED AND POOH TO CUT PIPE FOR COIL MANAGEMENT. WHILE POOH NOTICE RUB SPOTS ON COIL TUBING BETWEEN 11,100'-11,400'. MEASURED THICKNESS WITH ULTRASONIC TESTER AND FIND SPOTS BETWEEN 0.09"-0.10" THICK(MINIMUM FOR 0.134"WALL IS 0.121"). RDMO CTU#6 TO SPOOL PIPE IN PRUDHOE. 10/24/2013 PERFORMED A TUBING PUNCH WITH A 6 FT, 4 SPF, 0 DEGREE PHASING, 1 9/16 IN HSC WITH BH 3.2 GM MILLENIUM HMX CHARGES. PERF DEPTH = 12974'-12980', CCL TO TOP SHOT=3.9 FT, CCL STOP DEPTH = 12070.1'. JOB IN PROGRESS. 10/25/2013 TAG FISH AT 13025.8', FIRE 160 GR/FT STRING SHOT FROM 13017.5'- 13022.5', CUT TUBING AT 13022'W/RCT 2500-200, LOG CORRELATED TO TUBING DETAIL RECORD DATED 19 MAR 1996. UNABLE TO COME FREE AFTER CUTTING TUBING, RELEASED FROM WEAK POINT AFTER ACTIVATING JARS 28 TIMES. TOOLSTRING LEFT IN HOLE, OAL:47.6'x2.5". TOP OF FISH AT 12989'. READY FOR SLICKLINE. 10/26/2013 RECOVERED E-LINE TOnL_STRING @ 12,934' SLM (ALL PARTS RF"OVERED). READY FOR BPV. Conoc�hillups Time Log & Summary We/Niew Web Reporting Report Well Name: 1R-34 Rig Name: NABORS 7ES Job Type: RECOMPLETION Rig Accept: 10/29/2013 4:00:00 PM Rig Release: 11/11/2013 11:59:00 PM Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 10/29/2013 24 hr Summary Move Rig from 1 R-35 to 1 R-34 on the other side of the pad. Spot rig over hole.Set down. Set mats and herculite for pits. Spot pits. Rig up service lines. Berm rig.Test gas monitors. Pull BPV. Filling pits with 13.6 ppg mud. Rig LID kill tank and hard line.Test mud lines and lines to tank. 00:00 01:00 1.00 MIRU MOVE MOB P Pull pits away from rig on 1R-35, stage on other side of pad by 1R-34. Warm up tires and prepare sub for moving. 01:00 01:30 0.50 MIRU MOVE MOB P Jack up sub, pull off well 1R-35, stage on pad. 01:30 04:30 3.00 MIRU MOVE OTHR P Change out gas buster line in the interconnect. Change out choke hose in the cellar. Both items bring rig into compliance of the commissioning criteria for the hoses. Pick up berming and matting. 04:30 07:00 2.50 MIRU MOVE MOB P Move sub around the pad to well 1 R-34.Walk rig over well checking the clearance of the well along side of well 1R-34(1R-17).Pull rig back off well. 07:00 09:30 2.50 MIRU MOVE MOB P Spot matting boards and berming around 1R-34. Spot rig over well 1 R-34. Install mats and set the sub down. 09:30 11:00 1.50 MIRU MOVE MOB P Spot pits,set matting boards and herculite. Spot cuttings tank for discharge fluids f/the pits. 11:00 12:00 1.00 MIRU MOVE MOB P Berrm around rig w/Handy berm materials. 12:00 16:00 4.00 MIRU MOVE MOB P Continue to berm rig and pits w/ Handy berm materials. Connecting service lines(Sub to pits,and pits to interconnect). Electrician tested the Sierra gas monitoring systems. Rig accepted @ 1600 hrs 10-29-2013. 16:00 17:30 1.50 MIRU WELCTL RURD P Rig up lubricator to pull the Back PressureValve. Pressure test lubricator to 1500 psi f/5 min. FMC rep Dave pulled the BPV. Pressures:Tbg 10 psi, IA 300 psi, OA 330 psi. Rig down lubricator. Filling pits w/13.6 ppg mud @ 1640 hrs. Page 1 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 20:30 3.00 MIRU MOVE RURD P Rig up lines to circulate from the tree to the kill tank. Hardline crew rigging up lines from the cellar to the tiger tank. Load and strap 3.5"drill pipe in the pipe shed. 20:30 00:00 3.50 MIRU MOVE PRTS P Pressure test surface Mud Lines, Stand Pipe, Kelly Hose, Cement Hose, Second Kill Line, Cellar Manifold, and the 2"Line from the cellar to the Tiger Tank at 250/3,500 psi. Good test. (Continue to off-load 13.6 lb/gal mud into the rig Pits. continue to load 3 1/2"Drill Pipe in the Plpe Shed). 10/30/2013 Circulate and condition Well to 13.6 lb/gal Mud. Nipple down Production Tree. Nipple up 13 5/8"x 5,000 BOP Stack. Perform the initial BOPE test at 250/3,500 psi. 00:00 00:30 0.50 COMPZ WELCTL SFTY P PJSM. Discuss sand environmental concerns associated with circulating the Well. 00:30 03:30 3.00 COMPZ WELCTL KLWL P Circulate the Well with 13.6 lb/gal Mud down the Tubing taking returns from the 7"x 3 1/2"Annulus through the choke to the Tiger Tank. Initial circulation rate 6.0 bpm/800 psi. Observe returns into the Tiger Tank after circulating 14 bbls. Saw Mud returns after pumping 432 bbls. at '6.0 bpm/1.400 psi. continue pumping 13.6 lbs/gal Mud in. Weight returns out at 13.1 lbs/gals. 03:30 04:30 1.00 COMPZ WELCTL KLWL P Had to shut down due to Tiger Tank 'getting full. Off-load and and haul returns to Disposal Well on 1-R Pad. Unable to move in next available empty Vac Truck on location to continue to suck out Tiger Tank due to two flat tires. Wait on dirty Vac to finish off loading. 04:30 06:15 1.75 COMPZ WELCTL KLWL P Resume circulating with 13.6 lb/gal Mud at 2.0 bpm/670 psi. Hole staying full...observe 1:1 returns. MW in 13.6 ppg, MW out 13.2 ppg. 06:15 07:00 0.75 COMPZ WELCTL RURD P Shut down pumping to tiger tank. Line up to circulate back to the mud pits. 07:00 09:30 2.50 COMPZ WELCTL CIRC P Continue to circulate down the 3-1/2" tubing taking returns to the mud pits. Stage pumps up to 7 bpm w/3500 psi(IA pressure was 420 psi). Adding barite to maintain 13.6 ppg MW in. Circulated until MW out was 13.6 ppg. Increase viscosity of mud to 55. Circulated 842 bbls to the pits. 09:30 10:00 0.50 COMPZ WELCTL DHEQ P Shut down pups. Monitor tubing and IA to atmoshere for 30 minutes. No Flow. Page 2 of 18 • Time Logs Date From To Dur S. Depth E.Depth'Phase Code Subcode T Comment 10:00 11:00 1.00 COMPZ WELCTL RURD P Blow down/rig down lines. 11:00 11:30 0.50 COMPZ WHDBO MPSP P FMC rep Dave set the 3"ISA back pressure valve. Note: Rig floor to upper lockdown screws=24.28'. Rig floor to lower lockdown screws= 26.23'.The previous tally shows Parker 245 RKB to upper @ 36.60'or 36.72'and lower @ 38.45'. So either a 12.44' difference or a 12.22'difference in rig height. 11:30 13:30 2.00 COMPZ WHDBO NUND P Nipple down the 3-1/8"5m FMC tree and 7-1/16"x 3-1/8"tree adapter. Check hanger threads-good. Note: Pictures of hanger threads and blanking plug posted to the"S" drive folder. Install FMC blanking plug with 103/4" Right hand turns.Then screwed the retieval tool onto the blanking plug, requiring 9-3/4 turns of LH to tighten. Removed retrieval tool. 13:30 16:30 3.00 COMPZ WHDBO NUND P Nipple up the 13-5/8"Hydril BOPE with 2-7/8"x 5"rams installed in both top and bottom pipe rams. Install riser and flow line. 16:30 00:00 7.50 COMPZ WHDBO BOPE P Begin the initial BOPE test as per ConocoPhillips/AOGCC requirements at 250/3,500 psi.The State's right to witness the test was waived by B. Noble. Pick-up 3 1/2" Test Joint. Fill lines with water. Test BOP body,and choke manifold valves. Number 16 valve failed. Isolate Valve#16. Continue testing remaining BOPE at 250/3,500 psi. 10/31/2013 Complete the initial BOPE test.Attempt to pull the Completion Tubing.Tubing appears to not be cut. Rig up E-line for second tubing cut attempt. Run string shot to prep tubing for second cut. 00:00 02:00 2.00 COMPZ WHDBO BOPE P Continue with the initial BOPE test. Perform Koomey draw test as follows: Start at 3,000 psi. Close at 1,700 psi 200 psi in 14 seconds, Final in 95 seconds. Bag in 13 seconds. UPR/Blinds/LPR in 65 seconds. Choke/Kill HCR in 1 Second. Pump recovery time, Electric=42 seconds. Air-95 seconds. 5 back-up Bottles average 1,950 psi each. Repair manifold Valve#16 and test at 250/3,500 psi. Good. All test good and recorded on chart. 02:00 02:30 0.50 COMPZ WHDBO BOPE P Rig down test equipment. Blow down lines. Page 3 of 18 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T' Comment 02:30 03:30 1.00 COMPZ WHDBO RURD P Check IA pressure at 0 psi. Check tubing pressure under the BPV at 0 psi. Pull the BPV with"T"bar and lay down same. 03:30 04:30 1.00 0 13,074 COMPZ WHDBO RURD P Rig up GBR tubing handling equipment. Make-up Landing Joint. Check IA pressure again at 0 psi. BOLDS. 04:30 06:30 2.00 13,074 13,074 COMPZ RPCOM PULL P Un-seat Tubing Hanger. Attempt to pull the tubing free at the tubing cut made at 13,022-ft. Work tubing up to the limit of 195K(80%)several times. Bring pump on line at 2.0 bpm/700 psi continue to work tubing. Increase pump rate to 8.0 bpm/3,500 psi. continue to attempt to free tubing. No joy. 06:30 07:30 1.00 13,074 0 COMPZ RPCOM RURD P Abort any further attempt to pull tubing free. Set in the slips with 180K hook load.Lay down three Pup Joints from the Landing Joint. Rig down GBR tubing handling equipment. 07:30 08:30 1.00 COMPZ RPEQP1 ELNE T Monitor Well while waiting on Halliburton E-Line Unit to arrive on location. 08:30 08:45 0.25 COMPZ RPEQP1 ELNE T Halliburton on locaton. Have discussion w/1R-18 injection pump operator Chuck Harris and mechanic Steve as to needs to spot up and exchange telephone contact numbers. Rig up spot was located and no conflict with 1R operations were observed. 08:45 09:45 1.00 COMPZ RPEQP1 ELNE T Spot Halliburton E-Line Unit, and tool trailer(Whale). 09:45 12:00 2.25 COMPZ RPEQP1 ELNE T Rig up E-Line equipment from Unit to rig floor. Make-up Tool String. Toolstring: 1-7/16"OD cable head,1.69"OD swivel, 1.688"OD 7' weight bar, 1-11/16"OD roller w/2" wheel, 1.688"OD 5'weight bar, 1-11/16"OD roller w/2"wheel, 1.688"OD 5'weight bar, 2"OD roller w/2-1/2"OD wheel, 1.688"OD 5' weight bar,2"OD roller w/2-1/2"OD wheel,2"OD collar locator(CCL), 5' shot rod(160 gr/ft)=38.35'total length.Weight of BHA=294 pounds. 12:00 15:30 3.50 0 7,700 COMPZ RPEQP1ELNE T Stab onto stump w/a line equipment. Run in with Tool String and a 5-ft String Shot(160 gr/ft)to '7700'WLM. Page 4 of 18 Time Logs Date From To Dur S.Depth E. Depth Phase ! Code Subcode T Comment 15:30 17:30 2.00 7,700 13,014 COMPZ RPEQPI ELNE T Had to pump the tool string down as needed from'7700'WLM,started w/ .5 bpm,then pumping 1.0 bpm through the tangent section. Ran in to 13014'. 17:30 18:30 1.00 13,014 12,984 COMPZ RPEQPI ELNE T Make two correlation passes f/ 13014'WLM up the hole to locate pups and GLM in area of interest. Record a tie-in pass and log String Shot in place with the center of the String Shot at the proposed depth of the second tubing cut attempt at 12,984-ft WLM. Fire String Shot @ 1825 hrs. 18:30 21:00 2.50 12,984 0 COMPZ RPEQPI ELNE T Pull out of the hole w/string shot assembly f/12984'WLM and lay down the Tool String. String Shot fired. 21:00 00:00 3.00 COMPZ RPEQPI ELNE T Temporary suspend the Radical Cutting Torch run due to present E-Line rig up and sheave location. Re-position the Logging Unit and Crane Unit. Note:Footprint area to rig up in is very tight with 1 R-18 injection 1 operations close by on the drillers side of rig. 11/01/2013 Re-position E-Line Unit and rig back up. RIH w/RCT. Log cutter into place and cut the 3 1/2"Tubing at 11,565-ft. POOH and RD.Tbg pulled free from cut depth. 00:00 02:30 2.50 COMPZ RPEQPI ELNE T Continue to re-position the crane and sheaves to allow for proper angle to the Rig floor to prevent line rubbing. Temporary suspend rig up(present crew houred out). 02:30 05:00 2.50 COMPZ RPEQPI ELNE T Waiting for the relief crew to arrive on location so as to continue the rig up. (Note:Circulate and condition Well while waiting). 05:00 09:15 4.25 COMPZ RPEQPI ELNE T PJSM with Crew and their supervisor. Resume rig-up 09:15 09:30 0.25 COMPZ RPEQP1ELNE T Pre job safety meeting with Halliburton e line and rig crew. Page 5 of 18 Time Logs Date From To Dur S. Death E.Depth Phase '•Code Subcode T Comment 09:30 10:45 1.25 COMPZ RPEQP1 ELNE T Rig up tool string for the 2"radial cutting torch. Toolstring: 1-7/16"OD cable head,1.69"OD swivel, 1.688"OD 7' weight bar, 1-11/16"OD roller w/2" wheel, 1.688"OD 5'weight bar, 1-11/16"OD roller w/2"wheel, 1.688"OD 5'weight bar,1.68"OD Electric jars, 1-11/16"knuckle jts, 1-11/16"adjustable centralizer,2" OD collar locator(CCL), 1.5"OD EMA, 1=11/16"adjustable centralizer,2"roller w/2-1/2"wheels, 2"OD EXT,2"OD radial cutting torch,2"OD PBA,2"roller w/2-1/2" wheels, 1-11/16"adjustable centralizer=52.81'total length. Weight of BHA=335.5 pounds. 10:45 20:00 9.25 COMPZ RPEQP1 ELNE T Stab e line onto the 3-1/2"9.3 ppf L-80 EUE stump in rotary table. Pipe is sitting w/180k on wt indicator. Block wt 30k of this wt. Start in the hole w/2"radial cutting torch tool string. Had to work and pump Tool String down at 2-3 bpm. After several attempts were unable to get below 11,582-ft. Discuss plan forward with Anchorage Engineer and fishing options with Baker Fishing Tools. Decision made to cut tubing near present depth. Log cutter in place at 11,565-ft(CCL depth= 11,552.2-ft)in the middle of Joint# 46. Set Anchor Arms. Fire RCT. Good surface indication. Log off and the collars now log 10-ft shift up hole. Good. 20:00 00:00 4.00 COMPZ RPEQP1 ELNE T POOH with E-Line Tool String. Lay down Tool String. Pull Tubing free with 98K up weight and 55K down weight. Finish E-Line rig down. Release Unit. 11/02/2013 Cicrulate and condition Well with 13.6 lb/gal Mud. Single down 3 1/2"Completion Tbg from 11,565-ft. MU BHA#1. Begin to single in on 3 1/2"Drill Pipe. 00:00 01:30 1.50 0 28 COMPZ RPCOM CIRC P Pull Tubing Hanger to the Floor. Circulate and condition Well with 13.6 lb/gal Mud. Total bbls pumped =417. MW in 13.6 lb/gal, MW out 13.6 lb/gal. Monitor Well static. 01:30 12:00 10.50 28 2,615 COMPZ RPCOM PULD P Up Weight=97K. Down Weight= 55K. Single down the 3 1/2" Completion from the cut depth (11,565-ft). Number and tally Joints. Off load Pipe Shed as needed. Page 6 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase "'Code Subcode T Comment 12:00 17:00 5.00 2,615 0 COMPZ RPCOM PULD P Crew Change. Up Weight=47K. Down weight=42K. Continue to single down the 3 1/2"Completion to surface. 17:00 18:30 1.50 0 0 COMPZ RPCOM RURD P Rig down GBR tubing handling equipment. Clear and clean Rig Floor. 18:30 19:00 0.50 0 0 COMPZ RPCOM RURD P Install 6 3/8"ID Wear Bushing. 19:00 22:00 3.00 0 225 COMPZ RPCOM PULD P Make-up BHA#1...5 3/4"Overshot w/3 1/2"Basket Grapple. (Note: All six Drill Collars were drifted with a 2 1/4"Drift). 22:00 00:00 2.00 225 1,329 COMPZ RPCOM PULD P Single in BHA#1 with 3 1/2"Drill Plpe from the Pipe Shed to 1,329-ft 11/03/2013 Finish in with BHA#1 on 3 1/2"Drill Pipe. Circulate. Latch Fish. Circulate and Jar the remaining 3 1/2" Completion,free. Circulate and condition Well until 13.6 lb/gal returned. Monitor Well static. 00:00 05:30 5.50 1,329 8,252 COMPZ RPCOM PULD P Continue to run in hole with BHA#1 with 3 1/2"Drill Pipe from the Pipe Shed to 8,252-ft. PU wt 115k, SO wt 62k. 05:30 06:45 1.25 8,252 8,252 COMPZ RPCOM CIRC P Well out of balance. Stop to circulate and condition Well from 8,252-ft with 13.6 lb/gal Mud. Pumping 189 gpm w/2240 psi. Circulate until MVWV in and out= 13.6 ppg. Circulated 336 bbls. 06:45 07:00 0.25 8,252 8,252 COMPZ RPCOM OWFF P Monitor well-static. Blow down the top drive. 07:00 10:00 3.00 8,252 11,543 COMPZ RPCOM PULD P Continue to run in with BHA#1 f/ 8252'to 11543'with 3 1/2"Drill Pipe from the Pipe Shed. PU wt 175k,SO wt 72k. 10:00 11:30 1.50 11,543 11,543 COMPZ RPCOM CIRC P Circulate and condition mud to 13.6 ppg in and out. Circulated surface to surface. Pumping 210 gpm w/3500 psi. Obtain slow pump rates: Pump#1 35 spm=870 psi, 52 spm= 1120 psi. Pump#2 35 spm= 870 psi.52 spm= 1120 psi. Obtain parameters. 10 rpm=8.5k ft lbs of torque. Rot wt 95k.While pumping Rot wt=95k, PU wt =150k, SO wt=60k. With out pumps PU wt= 175k, SO wt=77k. Page 7 of 18 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 11:30 12:00 0.50 11,543 13,074 COMPZ RPCOM FISH P Slack off to tag top of fish @ 11569.5. PU then rotate over the top w/9.5k ft lbs of torque. Shut down rotary, let torque out of pipe, continue to slack off over fish(4.75' of swallow) to 11577'fishing assembly depth w/15k on fish. Pick up to 200k-fish on(length of fish 1513.91'). Break circulation, pumping 84 gpm w/935 psi,then increase pump rate to 126 gpm w/1195 psi. 12:00 13:30 1.50 13,074 13,074 COMPZ RPCOM JAR P Work fish attempting to get the jars to work. Working string up to 325k. Picked up a 5'pup jt to allow more weight to cock jars.Jars started working w/50k overpull(Jars Fired @ 225k on weight indicator). Pumping 42 gpm w/750 psi to 208 gpm w/ 3400 psi. 13:30 15:30 2.00 13,074 13,069 COMPZ RPCOM JAR P Jarring on fish w/110k overpull(285 on weight indicator,then pulling to 325k for a while. Increased pull after jars fired to 335k.Appear to be moving fish up hole. Estimated 5'of movement since 1400 hrs. 15:30 15:45 0.25 13,069 13,069 COMPZ RPCOM PULD P Slacked off to 111576'fishing assembly depth'. Removed 5'pup on top of string(on top of jt 360 in the hole). 15:45 17:45 2.00 13,069 12,996 COMPZ RPCOM JAR P Continue to jar fish w/110k overpull (285k on weight indicator),then picking up to 335k on the weight indicator. Pumping 206 gpm w/ 3200-3300 psi. Continuing to make progress working fish up the hole. Once seals appeared to pull free, PU wt dropped to 180 k dragging to 200k. Pulled stand out of the hole to 11486'fishing assembly depth (potential fish length= 1513.91').Set back a stand. 17:45 00:00 6.25 12,996 12,996 COMPZ RPCOM CIRC P Make a top drive connection. Close the top pipe rams, line up to circulate to the pits through the choke manifold and Gas Buster as planned. No gas observed in the returns. Circulate and condition until 13.6 lb/gal observed in the returns. Total Volume pumped=747 bbls. Monitor Well static. 11/04/2013 Trip out with BHA#1. Lay down BHA#1...Overshot Assembly. Lay down recovered 3 1/2"Completion. Make-up BHA#2...5 3/4"Washpipe Assembly.Trip in on 3 1/2"Drill Pipe. Page 8 of 18 • Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 12,996 11,556 COMPZ RPCOM TRIP P Up Weight= 160K. Trip out with 3 1/2"Drill Pipe, BHA#1,and the remaining 3 1/2"Gas Lift completion. Observing a 15-25K drag. Pumping out of the hole at 5.0 blp/3,300 psi to 11,556-ft(end of Fish depth)...10,065-ft(BHA depth). 02:00 03:00 1.00 0 0 COMPZ RPCOM CIRC P End pumping out of the hole. Monitor Well static. Pump a 25 bbl "dry job", Blow down Top-Drive. 03:00 06:30 3.50 0 2,662 COMPZ RPCOM TRIP P Up Weight 175K. Continue tripping out standing back 3 1/2"Drill Pipe from 11,556-ft to 2,662-ft. 06:30 07:00 0.50 2,662 2,662 COMPZ RPCOM CIRC P Circulate and condition Well at 6.5 bpm/680 psi. Mud weight in= 13.6. Mud weight out= 13.6. No gas. Monitor Well static. 07:00 07:30 0.50 2,662 2,662 COMPZ RPCOM PULD P Service Top Drive and Blocks. 07:30 08:00 0.50 2,662 1,747 COMPZ RPCOM TRIP P Trip out from 2,662-ft to BHA#1. 08:00 08:30 0.50 1,747 1,522 COMPZ RPCOM PULD P Stand back 4 3/4"Drill Collars. Lay down BHA#1. Lay down the 3 1/2" Cut-off Stump from the second RCT cut. OAL=22.99-ft. Good cut. 08:30 09:30 1.00 1,522 1,522 COMPZ RPCOM RURD P PJSM. Rig up GBR 3 1/2"tubing handling equipment. 09:30 12:00 2.50 1,522 0 COMPZ RPCOM PULD P Single down the recovered 3 1/2" Completion. Recovered 43 Joints of Tubing,2 GLMs, and the 3 1/2" Cut-off Stub from the orginal E-Line RCT cut at 13,022-ft elmd. OAL of the Stub=9.58-ft. 12:00 14:30 2.50 0 0 COMPZ RPCOM RURD P Rig down GBR equipment. Remove Overshot from Fish. Clear and clean Rig Floor. 14:30 15:00 0.50 0 0 COMPZ RPCOM SVRG P Service Draw works and handling equipments. 15:00 19:00 4.00 0 291 COMPZ RPCOM PULD P Make-up BHA#2...Wash Pipe Assembly. 19:00 00:00 5.00 291 8,998 COMPZ RPCOM TRIP P Trip in BHA#2 on 3 1/2"Drill Pipe from the Pipe Shed to 8,998-ft. 11/05/2013 Washover the 3 1/2"Tbg Stub down to the Baker Locator Sub. Circulate and condition Well.Trip out with BHA#2. Make-up BHA#3.Trip in with BHA#3. 00:00 02:00 2.00 8,998 11,648 COMPZ RPCOM TRIP P Crew change. Continue to trip in with BHA#2 from 8,998-ft to 11,648-ft with Drill Pipe from the Derrick. (Service Rig). 02:00 03:30 1.50 11,648 12,960 COMPZ RPCOM TRIP P Continue to trip in with BHA#2 from 11,648-ft with Drill Pipe singles from the Pipe Shed to 12,960-ft(fill). Up Weight=225K. Down weight= 65K. Page 9 of 18 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 03:30 05:00 1.50 12,960 13,036 COMPZ RPCOM FISH P Bring Pump on line at 5.0 bpm/3,900 psi. Up weight= 175K. Down weight=70K. RPMs=20. Torque = 11,500 ft/lbs. Set down on fill at 12,960-ft. Wash down to the top of the 3 1/2"Cut-off Tubing Stump at 13,000-ft dpmd. Work to get over top of Stump. Continue washing/rotating down over the Fish. Bottom returns across the Shaker=very heavy thick Mud and some formation sand. Tagged up solid on the Baker Locator at 13,036-ft. 05:00 09:00 4.00 13,036 13,026 COMPZ RPCOM CIRC P Pull up hole to 13,026-ft. Pump a hi-Vis Sweep at 3.0 bpm/2,100 psi. Chase Sweep back to surface at 5.25 bpm/3,780 psi. Rotate and reciprocate Pipe. RPMs= 10. Torque= 10-12K ft/lbs. Continue to circulate and condition 13.6 lb/gal in 13.9 lb/gal out. Also recovered small amount of Carb-o-lite Frac Sand. Well finally cleaned up. 13.6 lb/gal in. 13.6 lb/gal out. Total bbls pumped 1,059. Blow down Top Drive. 09:00 12:00 3.00 13,026 7,200 COMPZ RPCOM TRIP P Pump a 20 bbl"dry-job". Up weight =218K. Trip out with BHA#2 standing back 3 1/2"Drill Pipe in the Derrick to 7,200-ft. Up weight= 150K. 12:00 15:00 3.00 7,200 291 COMPZ RPCOM TRIP P Crew change. Continue to trip out with BHA#2 from 7,200-ft,standing the 3 1/2"Drill Pipe in the Derrick to BHA#2 at 291-ft. Calculated displacement=????,Actual displacement=????. 15:00 17:00 2.00 291 0 COMPZ RPCOM PULD P UD washover BHA#2 F/291'T/ surface. 17:00 18:00 1.00 0 227 COMPZ RPCOM PULD P M/U Overshot BHA#3 F/surface T/ 227'MD. 18:00 22:00 4.00 227 8,081 COMPZ RPCOM TRIP P RIH F 227'MD T/8081'MD, Calculated displacement=43.9 bbls, Actual displacement=48.9 bbls. 22:00 22:30 0.50 8,081 8,081 COMPZ RPCOM CIRC P While RIH pipe became wet, pump 20 bbl 14.3 ppg slug @ 5 bpm 2300 psi. 22:30 00:00 1.50 8,081 11,014 COMPZ RPCOM TRIP P Continue RIH with BHA#3, F/8081' T/11014'MD, Calculated diplacement=29.5 bbls,Actual dispalcement=35.1bbls. Page 10of18 • Time Logs Date From To Dur S.Depth E. Depth Phase !Code Subcode T Comment 11/06/2013 24 hr Summary Continue RIH to 12,935'MD, Clean rig floor and slip&cut drlg line,Verified circulation before engaging fish, latch onto fish at 13,000'MD, Open POS with 3800 psi,Took SPR's, Pulled 260K to free seal assembly, Pulled up 30'and went back downl9'and saw indication of btm seals entering into the packer assembly @ 13,036'MD, Circ to check for gas,Well took total of 87 bbl's and no gas back to surface, Monitor well for 30 min's, POOH with fish and L/D same. Digital S-Line tool still stuck up inside joint packed with formation sand, L/D same,Make up cleanout BHA with 7"scraper and RIH down to 7427'MD at midnight. 00:00 01:30 1.50 11,014 12,935 COMPZ RPCOM TRIP P RIH F/11,04'T/12,935'MD PUW= 218K, SOW=78K. 01:30 02:00 0.50 12,935 12,935 COMPZ RPCOM OTHR P Remove air slips,Clean mud off rig floor, PJSM on cutting drlg line. 02:00 03:00 1.00 12,935 12,935 COMPZ RPCOM SLPC P Slip and cut 108'of drlg line. 03:00 04:00 1.00 12,935 13,000 COMPZ RPCOM FISH P Fish as per-Baker hand @ 13,000' MD, Set down 15K, P/U to 230K and confirm latch, PUW=218K, SOW= 82K, Open POS with 3800 psi,take SPRs,#1 MP with 20 spm= 1310 psi,30 spm= 1970 psi,#2 MP with 20 spm= 1320 psi,30 spm= 1980 psi, Pull seals with 260K, P/U 30' and slack off 19'and saw bobble on wt indicator indicating the seals were entering back into the packer, monitor well, Had 12 BPH losses static rate. 04:00 07:00 3.00 13,000 12,960 COMPZ RPCOM CIRC P Circulate with 3.5 bpm and 2790 psi, Had 80 bph loss,then slow down to 21.6 bph losses. (Total loss to well while circ=87 bbls) 07:00 08:30 1.50 12,960 12,960 COMPZ RPCOM OWFF P Shut down Pumps. Blow down the Top Drive. Monitor Well x 30 minutes. Observed an 8"drop in Mud level. Put Well on the Trip Tank and monitor for an additional 15 minutes. Observed No Loss/No Gain for 15 minutes. Pump a 24 bbl"dry job". 08:30 12:00 3.50 12,960 5,241 COMPZ RPCOM TRIP P Up Weight=220K.Trip out from 12.956-ft standing 3 1/2"Drill Pipe back in the Derrick to 5,241-ft. Up weight= 100K. Down weight=60K. Calculated DP displacement=46.4 bbls. Actual displacement=51.9 bbls. 12:00 15:00 3.00 5,241 227 COMPZ RPCOM TRIP P Crew change. Continue to trip out from 5,241-ft standing 3 1/2"Drill Pipe in the Derrick to 320-ft. Monitor Well x 10 minutes. Observerd a slow drop in Mud level. Stand back the last Stand of Drill Plpe. Page 11 of 18 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 15:00 19:00 4.00 227 0 COMPZ RPCOM PULD P BHA to surface. Lay down Accelator. Stand back Drill Collars. Pull"D"Nipple to Rig Floor. Hold PJSM and discuss the tubing punch and retrieving Schlumberger Digital Tool String. Clear Rig floor and perform tubing punch in the Pup Joint below the Nipple with Iron Roughneck. Small amount of trapped gas under the stuck plug in the Nipple was safely released. Break down remainder of the Fish. Total Fish recovered=3 1/2"Cut-off Tbg Stump, Baker Locator Seal Assembly,2 Joints of 3 1/2"9.3 lb/ft, L-80 FL4S Tbg, 1 ea 3 1/2"9.3 lb/ft, L-80, FL4S Pup Joint, Mule Shoe Entry Guide. Slick Line tools stuck in sand inside Joint. Unable to retrieve tool string on Location. Will NORM recovered pieces. Waiting for direction from Schlumberger as to when and where to ship. 19:00 20:00 1.00 0 235 COMPZ RPCOM PULD P M/U BHA#4 with 7"casing scraper F/surface T/235'MD 20:00 00:00 4.00 235 7,427 COMPZ RPCOM TRIP P RIH with BHA#4 F/235'T/7427' MD, PUW= 120K,SOW=68K, Calculated displacement with float= 93.0 bbls,Actual displacement= 59.0 bbls. 11/07/2013 RIH to 12,915'MD,Wash down to to top of packer @ 13,036'MD, No problems,Continue down to No Go at 13,058'MD, Pull back above packer, Circ&cond. Mud 5 bpm 3700 psi, Monitor well 30 min,service rig, POOH, UD BHA#4, Clear floor off, P/U and remove SLB digitial tool from cut joint, Clear floor, Pull wear bushing,Wash out stack,M/U test joint and x-over,TIW, set test plug and fill stack with water,Test BOP with 250 low and 3500 high for 5 min each. (AOGCC Rep. Jeff Jones waived witness of test) 00:00 02:30 2.50 7,427 12,915 COMPZ RPCOM TRIP P RIH F/7427'T/12,915'MD. PUW= 220K, SOW=80K. 02:30 03:30 1.00 12,915 13,058 COMPZ RPCOM REAM P Wash&Ream F/12,915'T/13,036' top of packer with no problems, continue washing down to No Go at 13,058'MD with 5 bpm 3700 psi. Pulled back above the packer.Observed no issues or junk. Page 12 of 18 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 03:30 06:00 2.50 13,058 12,915 COMPZ RPCOM CIRC P Circulate and Condition mud at 5bpm 3700 psi, reciprocated pipe F/ 13,009'T/12,915'MD while circulating. Up weight= 185K. Down weight=74K. Continue to circulate and condition to increase gel properties minimizing barite sag issues, until Mud Engineer satisfied with Mud properties. Mud weight= 13.6 lb/gal in, 13.6 lb/gal out. Take slow pump rates as follows: MP#1 =at 2.0 bpm/3.0 bpm, 1,185/1,750 psi. MP#2=at 2 bpm/3 bpm, 1,190/1,171 psi. 06:00 06:30 0.50 12,915 12,915 COMPZ RPCOM OWFF P Monitor Well static. 06:30 07:00 0.50 12,915 12,915 COMPZ RPCOM SVRG P Service Top Drive, Blocks,and Washpipe. Pump a 25 bbl dry job. 07:00 12:00 5.00 12,915 5,344 COMPZ RPCOM TRIP P Up weight=225K. Down weight= 80K. Trip out from 12,915-ft with 3 1/2"Drill Pipe standing back in the Derrick to 5,344-ft. Up weight= 105K. Down weight=65K. Calculated displacement=46.4 bbls. Actual displacement=51.5 bbls. 12:00 15:00 3.00 5,344 328 COMPZ RPCOM TRIP P Crew Change. Continue to trip out with 3 1.2"Drill Pipe standing back in the Derrick from 5,344-ft. Stop with one stand of Drill Pipe left in the hole. Monitor Well x 10 minutes...static. 15:00 16:00 1.00 328 0 COMPZ RPCOM PULD P BHA#4 at surface. Lay down Drill Collars and the remainder of the BHA. Calculated displacement= 35.1 bbls. Actual displacement 37.1 bbls. Clear and clean Rig Floor. 16:00 17:00 1.00 COMPZ RPCOM OTHR P Clear and clean rig floor. 17:00 19:00 2.00 COMPZ RPCOM OTHR P PJSM with Rig Crew and Schlumberger personnel to discuss safety and operational issues to remove the"sand stuck" Schlumberger Tool String in a joint of tubing. The Schlumberger S Digital tool String was recovered without any issues. 19:00 19:30 0.50 COMPZ RPCOM BOPE P PJSM. Pull Wear Bushing. Wash BOP Stack. Set Test Plug. 19:30 20:30 1.00 COMPZ RPCOM OTHR P Pick up swizzle stick and flush out stack and L/D same. 20:30 21:00 0.50 COMPZ RPCOM BOPE P P/U test joint-M/U test plug, Dart, TIW valve and x-overs,set test plug and fill stack and choke manifold with water. Page 13 of 18 r Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 21:00 23:30 2.50 COMPZ RPCOM BOPE P Test BOPs with 3.5"test joint,Test VBRs, Kill stand pipe, Manuel and HCR Kill,CH 1-11, and 14-16,250 low 3500 high for 5 min each, (Jeff Jones with AOGCC waived witness of test). 23:30 00:00 0.50 COMPZ RPCOM BOPE P Draw Down Test: Start=3000 psi, After closing= 1700 psi, Initial 200= 17 sec, Full recovery=96 sec, Bag= 12 sec, UPR/Blinds/LPR=63 sec, Choke/Kill= 15 sec,5 bottles= 1925 psi, Pump recovery times=Electric= 44 sec,Air=96 sec. 11/08/2013 Complete weekly BOPE test. Make-up Lower Completion per program. Run in hole on Drill Pipe.Space out. Set Packer.Test Casing, Packer,and CA-2 Plug. Spot Corrosion Inhibited Mud on bottom. Pull up hole and reverse in 30 bbl spacer followed by 30 bbls 9.6 lb/gal Brine and saw pressure increase to 3900 psi with only 9 spm, Bled off pressure and open well to pump conventionally with 7 bbls 15 spm with 2500 psi, R/U to reverse again and had more than 7 bbls of brine coming back, investigate valves on mud manifold, R/U to bypass manifold and start to reversing again but could not, had 3300 psi with no returns, Call town and discuss plan forward. 00:00 00:30 0.50 COMPZ RPCOM BOPE P Test Blind rams, Choke valves 12& 13, Inner&outer spool valves,250 low 3500 high for 5 min each. (Good Test)Witness of test waived by AOGCC Jeff Jones. 00:30 01:00 0.50 COMPZ RPCOM BOPE P Pull test plug&test joint, set wear bushing, blow down all lines. 01:00 02:00 1.00 COMPZ RPCOM PULD P P/U UD tools and P/U GBR tongs. 02:00 02:45 0.75 0 82 COMPZ RPCOM PUTB P Make up lower completion as per-Baker rep and running order. 02:45 03:15 0.50 COMPZ RPCOM OTHR P Power down hydraulic tongs and rig down same. 03:15 06:00 2.75 82 4,816 COMPZ RPCOM TRIP P RIH with lower completion at 90-ft/min on 3.5"dp from derrick F/ 82'T/4,816-fy. Up weight=80K. Down weight=65K. 06:00 14:30 8.50 4,816 12,987 COMPZ RPCOM TRIP P Crew change. Continue running the Lower Completion section on 3 1/2" Drill Pipe from the Derrick to 13,057.83 Mule Shoe depth. Pick up 2-ft off the Lower Baker F-1 Packer at 13,038-ft. Top of the Upper Baker F-1 at 12,987.76-ft. Drop 1 7/16".9 sp gravity Packer Setting Ball. Bring Pump on line at 1/0 bpm/1,050 psi. Observe Ball on seat after pumping 69.2 bbls/1,150 psi. Bump pressure up to 1,500 psi x 15 min,2,000 psi x 10 minutes,2,500 psi x 5 minutes, 3,000 psi x 5 minutes. Pull Drill Pipe and observe Setting Tool releasing from the Packer at 190K. Close Pipe Rams and pressure test the 7" Casing, Packer and the Ca-2 Plug at 2,500 psi x 15 minutes. Good test. Record tests on a chart. Page 14 of 18 Time Logs Date From To Dur S.Depth :E. Depth Phase Code Subcode T Comment 14:30 15:15 0.75 12,987 12,987 COMPZ RPCOM CIRC P Pump15 bbls of Corrosion Inhibited 13.6 lb/gal Mud down the Drill Pipe. Displace with 82 bbls of 13.6 lb/gal Mud. 15:15 15:45 0.50 12,987 12,608 COMPZ RPCOM TRIP P Pull 5 stands of 3 1/2"Drill Pipe. Blow down Top Drive. 15:45 21:30 5.75 12,608 12,608 COMPZ RPCOM CIRC P PJSM,Clean shakers,troughs and pits#1 and trip tank with power washer for 9.6 ppg brine returns 21:30 00:00 2.50 12,608 12,608 COMPZ RPCOM CIRC T PJSM with new crew, Reverse in,35 bbl Spacer Pill with 3.5 bpm 1800 psi followed by 30 bbls of 9.6 ppg brine, but pressure started increasing from 2100 psi and then slowly up to 3900 with only 9 spm. Stopped pumping, bled pressure down,open well and pump down dp to see if we could un-plug for 7 bbls with 15 spm 2500 psi,stopped and rig back up to reverse circ and had more then 7 bbls brine coming back, investigate possible valve leaking by on mud manifold. R/U and bypass mud manifold and tried to reverse but plugged off, Call town and discuss plan forward. 11/09/2013 Displace 13.6 lb/gal Mud from wellbore with 9.6 lb/gal Brine. Monitor Well. Single down 3 1/2"Drill Pipe. Lay down Baker Setting Tool. L/D 15 joints via mouse hole from derrick, Pull wear bushing, Bring up GBR equipment and rig up same, PJSM with crew on running TBG, Run 3.5"9.3#L-80 eue 8rd upper completion as per detail F/surface T/887'MD. Optimum make u?=2240 ft/lbs. 00:00 02:30 2.50 12,608 12,608 COMPZ RPCOM CIRC P R/U to circulate conventionally down dp,taking returns to cuttings box from Mud pump#2 with two vac trucks piggy back to each other. Brk circ with 2 bpm and stage rate up to 5.8 bpm, ICP= 1550 psi, FCP=2150 psi. 02:30 03:00 0.50 12,608 12,608 COMPZ RPCOM CIRC P Flow check well,out of balance, circ 50 more bbls @ 5.8 bpm 2150 psi. SPR#2 Mud pump with 9.6 ppg brine:35 SPM=370 psi, 52 SPM= 780 psi.Take weight checks 9.6 ppg in and out. 03:00 04:30 1.50 12,608 12,608 COMPZ RPCOM OWFF P Monitor well for 30 min, (Static) SIM-OPS: Blow down all lines. Clean possum bellies,trough and rinse under shakers to take on 9.6 ppg brine into pit#1 and trip tank. Flush out trip tank line to cuttings tank. 04:30 06:00 1.50 12,608 COMPZ RPCOM TRIP P POOH laying down 3.5"dp F/ 12,608'T/11'MD. PUW= 150K, SOW=75K. 06:00 12:00 6.00 11,364 7,120 COMPZ RPCOM TRIP P Continue to single down 3 1/2"Drill Pipe to the Pipe Shed from 11,364-ft to 7,120-ft. Up weight= 140K. Down weight=72K. Page 15 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 19:30 7.50 7,120 0 COMPZ RPCOM TRIP P Crew change. Continue to single down 3 1/2"Drill Pipe to the Pipe Shed from 7,120-ft to Surface. L/D packer running tool, Calciulated displacement=44.8 bbls,Actual displacement=48.9 bbls. 19:30 20:30 1.00 0 0 COMPZ RPCOM TRIP P UD 15 joints of 3.5"dp via mousehole. 20:30 21:00 0.50 0 0 COMPZ RPCOM OTHR P Pull wear bushing. 21:00 22:00 1.00 0 0 COMPZ RPCOM RURD P Bring up GBR tbg equipment and rig up same. 22:00 22:30 0.50 0 0 COMPZ RPCOM SFTY P PJSM with crew on running 3.5"tbg and running order. 22:30 00:00 1.50 0 887 COMPZ RPCOM RCST P RIH with upper completion 3.5"9.3# L-80 EUE 8rd string as per running detail and Baker rep. F/Surface T/ 887'MD, Make up torque=2240 fUlbs. 11/10/2013 Continue running upper 3.5"upper completion, Brk circ and sting into SBR and saw pressure increase @ 12,992'MD Bleed off, Slack off to No Go @ 13,013'MD with 15K, Space out, Spot trucks&mix corrosion inhibitor, pumped 340 bbls and chase with 112 bbls brine, Land hanger&RILDS, PT tbg to 3000 psi for 15 min, bleed down tol 500 psi, PT IA to 2500 psi for 30 min, Bleed off IA&tbg to zero, Ramp up on IA and shear out valve, pump both ways good, LID landing joint,and blow down all rig lines. 00:00 06:00 6.00 887 5,889 COMPZ RPCOM RCST P PJSM,Continue running 3.5"9.3# L-80 EUE 8rd Mod upper completion string F/887'T/5989'MD 06:00 12:00 6.00 5,889 12,291 COMPZ RPCOM RCST P PJSM,Continue running 3.5"9.3# L-80 EUE 8rd Mod upper completion string F/5,989-ft to 12,291-ft Up weight= 105K. Down weight=53K. 12:00 15:30 3.50 12,291 12,987 COMPZ RPCOM RCST P Crew change. Continue running the 3 1/2"Gas Lift Completion as designed. Pick-up the Landing Joint (#416). Up weight= 120K. Down weight=55K Bring pump on line at 1.0 bpm/155 psi. Ease in hole and start to enter the SBE with the Seal Assembly. Saw pressure increase to 195 psi. End pump. Locate on the Baker F-1 Packer at 12,987-ft with 28-ft of Joint#416 in the hole. 15:30 16:30 1.00 12,987 12,967 COMPZ RPCOM RCST P Lay down Joints#416,#415,and #414. Pick-up 2 ea 10-ft Pup Joints and 1 ea 6-ft Pup Joint. Pick up Joint#414. Make-up the Tubing Hanger w/2.68-ft Pup Joint. 16:30 19:30 3.00 12,967 12,967 COMPZ RPCOM CIRC P Rig up to circulate 9.6 lb/gal Brine with Corrosion Inhibitor added. Pump 325 bbls of 9.6 lb/gal Corrosion Inhibited Brine at 5.0 bpm/1,050 psi followed by 112 bbls of 9.6 lb/gal at 5.0 bpm/990 psi to displace the Tubing. Page 16 of 18 Time Logs Date - From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 20:00 0.50 12,967 13,009 COMPZ RPCOM RCST P Land Tubing with 4.75-ft of"stick-up" from locate on top of the Baker FB-1 Packer. End of the Seal Assembly Mule Shoe inside of the SBE is at 13,008.72. RILDS. 20:00 21:30 1.50 COMPZ RPCOM PRTS P Pressure test TBG to 3000 psi for 15 min, Bleed down to 1500 psi, Pressure test IA to 2500 psi for 30 min, Bleed IA&TBG to zero, Pressure up IA and shear SOV, Pump down IA 3 bpm 850 psi, Pump down TBG 3 bpm 930 psi. 21:30 22:00 0.50 COMPZ RPCOM OWFF P Monitor well for 30 min. 22:00 22:30 0.50 COMPZ RPCOM OTHR P R/D circulating equipment and lay down landing joint. 22:30 23:00 0.50 COMPZ RPCOM OTHR P Install BPV as per FMC and rig up and test in direction of flow to 1000 psi good. 23:00 00:00 1.00 COMPZ RPCOM OTHR P Blow down hole fill,choke manifold, secondary kill, Choke/kill and mud line back to pumps, R/D circulating equipment to secondary kill line. Begin removing BOP bolts. 11/11/2013 Nipple down, Start breaking BOP bolts, Pull rotary table cover&clean drip pans,continue cleaning pits, Pull riser,Turnbuckles, Pick up and set stack back and secure,At 05:00 hrs Phase 3 weather conditions announced through out Greater Kuparuk area and work was suspended until 17:30 hrs when Phase 2 conditions announced. Coordinate Crew change out at the rig and resumed N/U operations of adapter flange and tree,Test adapter void 250 low/5000 psi high for 10 min, Pulled BPV and install tree test plug, Fill tree with diesel and test 250 low/5000 psi and chart, Pull tree test plug and rig up Little Red and pump 75 bbls of diesel, (Release rig @ 24:00 hrs 11/11/2013) 00:00 01:00 1.00 COMPZ WHDBO NUND P Begain breaking bolts to nipple down stack. 01:00 03:30 2.50 COMPZ WHDBO OTHR P Pull rotary table cover and clean under rotary table and drip pans, reinstall cover. SIM-OPS continue and finish cleaning pit tanks out. 03:30 05:00 1.50 COMPZ WHDBO NUND P Pull riser,Turnbuckles and pick up stack and set back and secure. 05:00 12:00 7.00 COMPZ WHDBO NUND T Phase 3 conditions announced throughout Kuparuk area,suspend all work and wait out storm. 12:00 18:00 6.00 COMPZ WHDBO NUND T Phase 3 conditions announced throughout Kuparuk area, suspend all work and wait out storm. 18:00 20:30 2.50 COMPZ WHDBO NUND P N/U adapter flange and tree as per FMC Rep.(SIM-OPS: Loader diggin out around Pad after blow). 20:30 21:00 0.50 COMPZ WHDBO PRTS P FMC filled and R/U and test void on adapter flange,250 low and 5000 psi high for 10 min each. Night Co. Rep. witness test(Good). (SIM-OPS: Start rigging down floor for move.) 21:00 21:30 0.50 COMPZ WHDBO SEQP P FMC pulled BPV and install tree test plug. (SIM-OPS:continue digging out and getting ready to move rig.) Page 17 of 18 Time Logs, Date From To Dur S.Death E.Death Phase Code Subcode T Comment 21:30 22:30 1.00 COMPZ WHDBO PRTS P Fill tree with diesel, R/U and test tree 250 low,5000 psi high for 5 min each. (Good). (SIM-OPS: Continue rigging floor down.) 22:30 23:00 0.50 COMPZ WHDBO SEQP P FMC pulled Tree test Plug. (SIM-OPS: Blow down water in pits.) 23:00 00:00 1.00 COMPZ WHDBO FRZP P PJSM, R/U Little Red to freeze protect well with 75 bbl diesel and pressure test line to 3000 psi. Pumped 75 bbls 2 bpm ICP=900 psi FCP=750 psi, OA had 320 psi. (SIM-OPS suck off returning brine from displacing with diesel out pits and cutting tank)Release Vac trucks.Secure tree valves and cellar area. Release rig @ 24:00 Hrs, 11/11/2013 Page 18 of 18 1R-34 POST RIG WELL WORK SUMMARY DATE SUMMARY 11/18/2013 REPLACED SOV W/DV @ 9,063' RKB; MIT TBG. TO 2500 PSI (PASS), MIT-IA TO 2500 PSI (PASS); PULLED 2,75"CA-2 PLUG @ 13,025' RKB &TAG FILL @ 13,176' RKB (EST.40' FILL). READY FOR CTU. 11/20/2013 RIH TO A HARD TAG @ 13180'CTMD, DO A BOTTOMS UP, CHASE OUT OF HOLE JOB COMPLETE TURNED OVER TO DSO 11/28/2013 SET 2.78"CATCHER @ 13025' RKB. PULLED DVs @ 9063' &6328' RKB. SET 1/4" OV @ 9063', GLV @ 6328' RKB. IN PROGRESS. 11/29/2013 PULLED DV FROM 2917' RKB. ATTEMPTED SET GLV @ 2917' RKB. CHECK SET, GLV APPARENTLY NOT IN GLM. PULLED EMPTY CATCHER FROM 13025' RKB. IN PROGRESS. 11/30/2013 ATTEMPTED LOCATE MISSING GLV;ATTEMPTED LIB GLM POCKET @ 2917' RKB. IN PROGRESS. 12/3/2013 PULLED DAMAGED GLV FROM 2917' RKB. IN PROGRESS. 12/4/2013 SET GLV @ 2917' RKB. WITH HOLEFINDER IDENTIFIED POSSIBLE TBG LEAK @ GLM @ 6328' RKB. IN PROGRESS. 12/5/2013 PULLED, REPLACED GLV @ 6328' RKB. BLED IA TO CONFIRM SET. PULLED CATCHER. COMPLETE. ~ ~ • • ConocoPh~llips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 3, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~~4~-~~ X ~~ ~~~ ~ Q ~dng ~llas~a ~il ~i Gas Corrs. Commission Anchorac~e ~°`r. ! _ ~. ~'~~~~~~ ~~ ~~ ~ ~~~~ (.~ ~ -~ ~ 6 ~- ( 1 .~ - 3 ~" Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRin. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped November 2"d, 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. ConocoPhillips Well Integrity Projects Supervisor • ~ ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 17/3/09 ~ R -,a~ Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corzosion inhibitod sealant date ft bbls ft al 1 R-34 50029225340000 1941620 9" NA 9" NA 1.7 11 ~2J2009 NO.4914 .~' `: ~.- c_i Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth .,, xN la/ ~ ~n17 W a0 e'~ ~ 1- 6' V li Well Job # Log Description Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 10/14/08 1 L-23 12097405 SBHP SURVEY 07/17/08 1 1 2A-17 11975793 PRODUC710N PROFILE 9 .- JL p L 09/10/08 1 1 3G-25X 12080437 LDL ~ - '3 C.((o 09/21/08 1 1 2C-04 12100444 INJECTION PROFILE ~ / 09/14/08 1 1 3M-13 12096541 LDL - (~C( j ~ 09/10/08 1 1 2Z-13A 12100446 LDL b(o- ! O ~3U 3 09/15/08 1 1 i F-O6 12096510 PRODUCTION PROFILE 07/17/08 1 1 3C-14A 12080436 SCMT - ~ 5-~ 09!22/08 1 1 1C-111 12100451 INJECTION PROFILE -t p .r 09/20/08 1 1 30-15 12100452 LDL - ~ 5a 09/21/08 1 1 iC-117 12100453 INJECTION PROFILE o 09/23/08 1 1 1 R-11 11966277 SBHP SURVEY S- (~ 09/25/08 1 1 1 R-35 11966279 SBHP SURVEY ~ ~ ` 09/25/08 1 1 1 R-14 11966286 LDL _ ( 09/29/08 1 1 2X-18 12080443 PRODUCTION PROFILE 09/30/08 1 1 iR-34 12080444 GLS C>jL ,,., 10/01/08 1 1 2A-13 12096547 PRODUCTION PRO ILE .~: C ~~CJ 10/02/08 1 1 1D-01 12097422 GLS 10/03/08 1 1 1 R-07 12097425 PRODUCTION PROFILE ~'~': ( 10/06/08 1 1 1H-19 12096548 INJECTION PROFILE L~ 10/03/08 1 1 1 B-16 12097426 GLS C~ _ =' 10/07/08 1 1 38-09 12100442 PRODUCTION PROFILE = 09/12/08 1 1 3K-103 12096550 USIT 10/06/08 1 1 2X-05 12096551 INJECTION PROFILE ~~ 10/07/08 i 1 1 B-04 12096552 INJECTION PROFILE 10/08/08 1 1 1A-02 12096553 INJECTION PROFILE U 10/09/08 1 1 1 B-16 12096554 PRODUCTION PROFILE q C' .- G 10/10/08 1 1 2D-15 12096555 PRODUCTION PROFILE ,j~C . 10/11/08 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. • • THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03,2001 M AT E IA L U N D ER TH IS M ARK ER C :LORBIVlFILlVtDOC :?.4 -- i 6 2. C D IR/," F I i',l A L. ~ I O0 ...... / 3500 0 3 / 3 0/9 5 Ar'e dr'y d-'['tcch samples r'equ'ir'ed? ye:. Was the wo'ii eot'ed? yes I~;;~_._.A4~' ~iysi':: Ar"e we'i'i -tests r"equ'i'r"ed? ~,,te ii -'i's i' n comp'l -~anco i n 'i' 1: i' a 'i C 0 N ki E N T S ~Rece :i: red ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 5, 1995 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1R-34(Permit No. 94-162) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the recent 34. Sincerely, M. Zanghi Kuparuk Drillsite Development Supervisor MZ/skad operations on KRU 1R- Cons. Commission Anch0r,r ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMb,... '.ION WELL COMPLETION OR RECOMPLETION REPORT'-AND LOG 1 Status of Well Classif'icati~)n/of?SCvice Well .~ ~ ? ,v . OIL r-~ GAS r~ SUSPENDED ['--] ABANDONED [] SERVICE , i.~..,..';,; .. 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 94-162 3 Address 8 APl Number P.O. Box 100360, Anchora~ie, AK 99510-0360 50-029-22534 4 Location of well at surface :. ...... ~, 9 Unit or Lease Name 623' FSL, 214' FEL, Sec. 18, T12N, R10E, UM i-~. ~ .,... i Kuparuk River Unit At Top Producing Interval ! ~/~'~_. _ : ~"~~[~:?~a 10 WollNumber At Total Depth! ~~___-- ;; ..... ; ~Y 11 Field and Pool 519' FSL, 261' FWL, Soc. 5, T12N, R10E, UM c-.,-~..:,:: ;~ ..... :~-.¢. ~ KUPARUK RIVER 5 Elevation in foot (indicate KB, DF, otc.) 6 Lease Designation and Serial No. KUPARUK RIVER 86' RKB 45' Pad ADL 25628, ALK 2561 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. [ 15 Water Depth, if offshore [16 No. of Completions 30- Doc-94 12-Jan-95 19-Mar-95[ NA foot MSk[ 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey [20 Depth whore SSSV set 21 Thickness of permafrost I 1 3570' M D & 6998' TVD 13465'MD & 6917'/VD YES X~ NO L~ NA foot MD 1570' APPROX 22 Typo Electric or Other Logs Run GR/CDR/DWOB(MEL) 23 CASING, klNER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP B'I'M HOLE SIZE CEMENT R~CORD 16" 62.5# H-40 Surf 121' 24" 205 sxs AS I 9.625" 40# L-80 Surf 7133' 12.25" 1450 sxs ASIII Lead, 790 sxs Class G Tail 7" x 5" 26#/18# L-80 Surf 13560' 8.5" 480 sxs Class G Tail 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 34/2", 9.3#, L-80 13144' 13056' 4 spf 13181' - 13216' M D 6705' - 6730' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 13181'- 13216' 8.0MIbs 20/40 & 100.0MIbs 12/18 Mesh ceramic proppant 27 PRODUCTION TEST Date First Production [Method of Operation (Flowing, gas lifl, etc.) I Date of Test Hours Tested PRODUCTION FOR OIk-BBL GAS-MCF WATER-BBL CHOKE SIZE [ GAS-OIL RATIO I TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBk OIk GRAVITY-APl (corr) Press. 24-HOUR RATE E 28 GORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RI C£1VI D JUN -7 1995 & 6as 0ohs. Anchor.:' Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MAFI~SRS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 12962' 6547' Base Kuparuk C 13019' 6588' Top Kuparuk A 13156' 6686' Base Kuparuk A 13301' 6793' RECEIVED JUN -.-7 1995 Aj~$ka~ Oil & Gas C0nsi Commission Anch0r~- ,', 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. S p"" ,'~ ~ ~~, Title'-~,~(J~.~,~. ~.,~J ~t'~,. ~/b/~~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALASKA INC. DAILY OPERATIONS PAGE 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 1R-34 NORTH SLOPE BOROUGH KUPARUK RIVER KUPARUK RIVER ADL 25628 ALK 2561 50-029-22534 94-162 ACCEPT: 12-30-94 15:00 SPUD: 12-30-94 20:30 RELEASE: OPERATION: DRLG RIG: PARKER 245 WO/C RIG: 12-31-94 (1) PARKER 245 TD: 1600 (1479) 1-1-95 (2) PARKER TD: 5700 ( 4100) 1-2-95 (3) PARKER TD: 6780 ( 1080) 1-3-95 (4) PARKER TD: 7150' (370') 1-4-95(5) PARKER TD: 7491' (341') DRILLING SURFACE HOLE 16"@121 MW: 9.2 VIS:76 CUM:$93,809 MOVE RIG 30' F/1R-33 T/1R-34. NU DIVERTER. MIX SPUD MUD. PU & ORIENT BHA. DRLG F/121' T/558'. RUN GYRO SURVEY. DRLG F/558' T/1600'. DRLG SURFACE HOLE 16" @121 MW:10.1 VIS: 53 CUM:$169,602 DRLG F/1600' T/5700' DRLG SURFACE HOLE 16"@121' MW:10.1 VIS:53 CUM:$246,732 DRLG F/5700' T/6063'. CBU. POOH F/BlT CHANGE. HOLE TIGHT F/2450' T/2360' & F/1720' T/1540'. MU BlT & ORIENT MOTOR. SERVICE RIG & TOP DRIVE. RIH W/BIT #2 REAM F/1729' T/1900'. DRLG F/6063' T/6355'. DRLG F/6355' T/6780'. CIRCULATING W/CASING ON BOTTOM 16"@ 121' MW:10.1 VIS: 46 CUM:$444,995 DRLG F/6780' T/7150'. CBU. SHORT TRIP TO 5800'. CIRC & COND. MUD. POOH. LD BHA. RU & RUN 9-5/8", 40#,L-80, BTC CASING. HELD SAFETY MEETING. CIRC @ 3140 RUN 9-5/8", 40#, L-80 , BTC CASING. CIRC @ 5100'. RUN %5/8", 40 #, L-80, BTC CASING TO BO"IWOM. NO PROBLEMS. MAKE UP MANDREL HANGER AND FINISH RII-I. (HAD TROUBLE WITH THREADS). POOH FOR MWD 9.625" @7133' MW: 8.6 VIS: 30 CUM: $628,111 CIRC. AND COND. MUD FOR CEMENT JOB. CEMENT 9.625" CASING AT 7133'. SEE CASE AND CEMENTING DETAILS FOR MORE INFO. CHECK FLOATS AND LAY DOWN LANDIN( JOINT. NIPPLE DOWN DIVERTER AND RIG UP FOR TOP JOB. PERFORM TOP JOB WITH 250 SACKS ARCTIC SET 3, HAD 12.1 PPG RETURNS TO SURFACE. MAKE UP 9.625" SPEED HEAD. NIPPLE UP BOPE. TEST BOPE TO 300/3000 PSI. WITNESS OF TEST WAIVED BY AOGCC. SET WEAR BUSHING. SLIP AND CUT DRILL LINE 145'. MAKE UP BHA AND RIH TO 7025'. CALIBRATE AND TEST H2S AND COMBUSTIBLE GAS ALARMS, ALL OK. TEST CASING TO 2000 PSI FOR 30 MIN. DRILL FLOAT COLLAR AT 7055', CIVIl AND FLOAT SHOE AT 7133' AND 10 FEET NEW HOLE TO 7160'. CIRCULATE HOLE CLEAN. PERFORM PIT TO 12.5 PPG EMW. DIRECTIONAL DRILL 8.5" HOLE FROM 7160' TO 7491'. ACCELEROMETER FAILED ON MWD. CIRCULATE BoTroMs UP. POOH FOR NEW' MWD. RECEIYED WELL: 1R-34 API: 50-02%22534 PERMIT: 94-162 PAGE 2 1-5-95 (6) PARKER TI3: 9925'(2434') 1-6-95 (7) PARKER TD: 10765' (840') 1-7-95 (8) PARKER TD: 12006' ( 1241') 1-8-95 (9) PARKER TD: 12606' (600') 1-9-95 (10) PARKER TD: 12840' (234') DRIIJ.R~TG 9.625" @7133' MW: 9.0 VIS: 33 CUM:$684,804 POOH, CHANGE OUT MWD, LAY DOWN STAB. SERVICE TOP DRIVE. RIH TO 7491'. DIRECTIONAL DRILL 8.5" HOLE FROM 7491' TO 7915'. DIRECTIONAL DRILL 8.5" HOLE FROM 7915' TO 8857'. REPAIR 4" OTECO VALVE ON #1 MUD PUMP (DOWN TIME). DIRECTIONAL DRILL 8.5" HOLE FROM 8857' TO 9170'. DIRECTIONAL DRILL 8.5" HOLE FROM 9170' TO 9925'. MWD FAILED, POSS. POWER SUPPLY PROBLEM. CIRCULATE BOTTOMS UP. DRILLING 9.625" @ 7133' MW: 9.0 VIS: 36 CUM: $760,578 CIRCULATE BOTTOMS UP. POOH, LAY DOWN MWD AND TURBINE, INSPECT BIT, PICK UP NEW TURBINE AND MWD. RIH WITH HWDP. SHALLOW TEST MWD. SERVICE RIG AND TOP DRIVE. RIH TO 7109'. SLIP AND CUT DRILL LINE 75'. HELD H2S DRILL. RIH. CHECK SHOT SURVEYS AT 7566', 8877', 9065', 9250', 9436', 9624', 9810'. DIRECTIONAL DRILL 8.5" HOLE FROM 9925' TO 10170'. DIRECTIONAL DRILL 8.5" HOLE FROM 10170' TO 10765'. DRILLING 9.625"@ 7133' MW: 9.0 VIS: 43 CUM:$859,419 DIRECTIONAL DRILL 8.5" HOLE FROM 10765' TO 11186'. SERVICE TOP DRIVE. DIRECTIONAL DRILL 8.5" HOLE FROM 11186' TO 11820'. DIRECTIONAL DRILL 8.5" HOLE FROM 11820' TO 12006'. DRILLING 9.625" @ 7133' MW: 10.5 VIS: 48 CUM:$958,893 DIRECTIONAL DRILL 8.5" HOLE F/12006' TO 12,182'. P-RATE DOWN, DIFFICULT TO SLIDE. CIRCULATE FOR TRIP. TRIP FOR BIT. WASH AND REAM FROM 11954' TO 12,1~ (PRECAUTIONARY). DIRECTIONAL DRILL 8.5" HOLE FROM 12182' TO 12606'. SLIP AND CUT DRILL LINE 9.625" @7133' MW: 11.5 VIS: 48 CUM:$1071,365 DIRECTIONAL DRILL 8.5" HOLE FROM 12606' TO 12817'. WEIGHT UP COMPLETE TO 11.5 PPG, HOLE TAKING FLUID AT +/- 30 BPH. CIRC. AT REDUCED PRESSURE, MONITOR WELL FOR LOSS/GAIN. LOST 18 BBLS. WHILE CIRC. GAINED 32 BBLS. AFTER SHUTTING DOWN PUMP. DIRECTIONAL DRILL 8.5" HOLE F/12817' TO 12840', DRILLING RATrY. ADDED 5 PPB BARA FIBER. ATI'EMFF TO MAKE HOLE, WOULD NOT DRILL. MIX AND PUMP SLUG. POOH TO SHOE AT 7133'. SERVICE RIG AND TOP DRIVE. MONITOR WELL, STATIC. POOH, DOWN LOAD MWD, CHECK TURBINE. FOUND FEMALE SPLINED HOUSING ON LOWER END OF TURBINE BROKEN OFF AND STUCK ON SHAFF IN BEARING PACKAGE. LAY DOWN TURBINE. PICK UP MACH 1 AKO SET AT 1°, ORIENT, SHALLOW TEST MWD. RIH SLOW TO SHOE, STAGE IN TO PREVENT BREAKING DOWN FORMATION. CEI'VE.D ,,, .-.k,' r~ii & Gas Cons. Cnmmission ~,r)chora Date: 05/31/95 Page: 3 ARCO Alaska Inc. DAILY DRILLING REPORT WELL:iR-34 RIG:PARKER 245 WI: 55% SECURITY:2 WELLID: AK8063 AFE: AK8063 TYPE:DEV AFE EST:$ 1939M/ 2620M AREA/CNTY:NORTH SLOPE BOROUGH STATE:AK API NUMBER:50-029-22534 FIELD: KAPARUK RIVER SPUD:12/30/94 START COMP: FINAL: 01/10/95 (11) PARKER 245 TD: 12994' (154') POOH 9.625" @ 7133' MW: 11.5 VIS: 47 CUM:$1,146,657 Drill 8.5" hole from 12840 to 12994'. 01/11/95 ( 12) PARKER 245 TD: 13155' (161') DRILLING 9.625" @ 7133' MW: 11.5 VIS: 48 CUM:$1,231,014 Drill 8.5" hole from 12994' to 13155'. 01/12/95 ( 13) PARKER 245 TD: 13570' (415') POOH FOR SHORT TRIP 9.625" @ 7133' MW: 11.4 VIS: 43 CUM:$1,303,445 Drill 8.5" hole from 13155' to 13570'. 01/13/95 ( 14) PARKER 245 TD: 13570' (0') RUNNING 7"x5" CASING 9.625" @ 7133' MW: 11.4 VIS: 45 CUM: $1,375,136 Run 7" x 5" production casing.. 01/14/95 ( 15) PARKER 245 TD: 13570' (0') INJECTING DIESEL DOWN ANNULUS 7x5" @ 13560' MW: 0 VIS: 0 CUM:$1,618,515 Run 7" x 5" production casing to 13560'. Cement casing. 01/15/95 ( 16) PARKER 245 TD: 13570' (0') RIG RELEASE 7x5" @ 13560' MW: 0 VIS: 0 CUM:$1,641,550 Freeze protect annulus. Release rig 0900 hfs 1/14/95. REMEDIAL AND COMPLETION OPERATIONS WELL: 1R-34 WELLID: AK8063 AREA/CNTY: FIELD: SPUD: AFE: AK8063' START COMP: RIG:NORDIC WI: 0% SECURITY:0 TYPE:DEV AFE EST:$ OM/ OM STATE: API NUMBER: FINAL: 03/09/95 (17) TD:13570' PB:13465' SUPV:DB 03/10/95 (18) TD:13570' PB:13465' SUPV:DB RIH - PICKING UP DRILLPIP MW: 8.6 SW & DIESEL Accept rig @900 hfs, 3/9/95. Test BOPE. RIH 145 stds DDP. Rack and tally 210 joints drillpipe. DAILY:S39,463 CUM:$39,463 ETD:SO EFC:$39,463 DRILLING ON RUBBER PLUG @ MW: 8.6 sEAWATER Drill cement from 12851 to 13052'. Drill & spin on rubber plug @ 13052' DAILY: $33,426 CUM: $72,889 ETD:SO Gas Cons. Cornmis~io~ Anchor[" Date: 05/31/95 Page 4 ARCO Alaska Inc. DAILY DRILLING REPORT 03/11/95 (19) TD:13570' PB:13465' SUPV:DB 03/12/95 (20) TD:13570' PB:13465' SUPV:DB 03/13/95 (21) TD:13570' PB:13465' SUPV:DB 03/14/95 (22) TD:13570' PB:13465' SUPV:DB 03/15/95 (23) TD:13570' PB:13465' SUPV:DB 03/16/95 (24) TD:13570' PB:13465' SUPV:DB 03/17/95 (25) TD:13570' PB:13465' SUPV:CJF 03/18/95 (26) TD:13570' PB:13465' SUPV:CCFF RIH W/MILL & MOTOR MW: 8.6 SEAWATER LD 17 jts DP. MU 3-15/16" Mill %1 & 3-1/2" Drilex Motor/BHA %2. RIH. (approx. 60 stds DP in hole @ 0600) DAILY:S31,868 CUM:$104,757 ETD:SO EFC:$104,757 MW: 8.6 SEAWATER Drill cement from 13056 to 13181 with slow rotary & Drilex motor. DAILY:S31,479 CUM:$136,236 ETD:SO EFC:$136,236 CIRCULATE HI-VISC SWEEP, MW: 8.6 SEAWATER Drill out cement with mill on Drilex mud motor from 13181' to PBTD @ 13450' Nordic RKB. DAILY:SO CUM:$136,236 ETD:SO EFC:$136,236 PREPARE TO LD 3-1/8" DC MW: 8.6 SEAWATER Test 7"x5' production casing. POH-LDDP(212 its). Prepare to LD 3-1/8" DC. DAILY:S35,511 CUM:$171,747 ETD:SO EFC:$171,747 LOAD PIPE SHED WITH TBG MW: 8.6 SEAWATER Continue POH with mill & motor, laying down fourteen 3-1/8 DAILY: $42,174 CUM: $213,921 ETD:SO EFC: $213,921 POH W/TBG & SEAL ASS'Y MW: 8.6 SEAWATER Continue RIH w/seal assy. Tag 7x5 crossover @ 13058' w/ seal ass'y. Work pipe. Unable to stab into seal bore. RIH with logging tools. Log. POH w/seal ass'y and tbg. DAILY:S43,024 CUM:$289,203 ETD:SO EFC:$213,921 LAYING DOWN BAKER SEAL AS MW: 8.6 SEAWATER Test BOPE to 3000 psi. OK. PU Baker bull nosed stinger on locator seal ass'y & RIH w/3-1/2" tbg. Tag SBE @ 13061' Work tbg, unable to penetrate SBE w/seals. POH w/tbg & locator seal ass'y, changing seal rings. Lay down seal ass'y. DAILY:S9,749 CUM:$266,694 ETD:SO EFC:$266,694 POH W/PACKER SETTING TOOL RIH ON 3-1/2" TBG. Set packer. MW: 8.6 DAILY:S32,401 CUM:$352,304 ETD:SO EFC: $474,063 RECEIVED dUN -Y !995 Oii& Gas Cons. Gommissior: Anchon ,~ Date: 05/31/95 Page 5 ARCO Alaska Inc. DAILY DRILLING REPORT 03/19/95 (27) TD:13570' PB:13465' SUPV:CJF SETTING BACK PRESSURE VAL MW: 0.0 Finish POH w/pkr setting tool on 3-1/2" tbg changing out seal rings. PU 3-3/8" perf guns. Guns & seal ass'y run on 3-1/2" tbg, spacing out nipples and GLMs as per design. Guns fired. Set BPV. DAILY:S174,968 CUM:$474,063 ETD:S0 EFC:$474,063 03/20/95 (28) SET BPV. SECURE RIG FOR MOVE TD:13570' Release rig @ 0730 hrs. 3/19/95. PB:13465' SUPV:CJF DAILY:S9,749 CUM:$537,021 ETD:SO End of WellSummary for Well:AK8063 MW: 0.0 EFC:$474,063 Gas Cons. Commission Ar~chort ~ ?'742,32 9728,17 PROGRAM *w**~***** COMPAHY ARCO ALASKA ~ELL NA~ -!R-3A LOCA?IO~ t XUPARU~ LOCA~ECN 2 ALAS[A MA~N£T!C ~£CLINATION 28,79 GRID C~N~RG~NC£ ANGLE 0.00 ~AT£: 09-JAN-?5 W££L HL~8~R 0 ~LL HEAO LOCATIOH: LAT(N/-S) 0.00 AZIMUTH ?~0~ ROTARY TA~L£ TO TAR~£T tS TIE IH P)ENT(TIP) : MEASURE~ ~£PTH 121.PO TRUE UER~ ~£PTH 12!,00 INCLI~ATICN ~.00 AZIH~TP 0,00 LAT!TUD£(~/-S) 0.00 ~PA~TLR~(E/-W) ~£P(£/-W) 3,15 '0,00 I( OFILME Date~ I _ ORIGINAL MEaSUReD IMT£RVAL VERTICAL ~PTH DEPTH I21,00 0.0 12!,00 44~.00 321.0 441.98 622,00 180,0 621.96 741.12 1!9.1 741.05 831.85 90,7 831.67 923.52 1013.71 llOE.lO 1197.50 129C.31 1353.46 1475,06 1570,56 1664,3) 1758,86 1852,72 1943,74 203~,11 2133,34 2227,67 23!9.52 2412.6) 2504.36 2599.06 2689.74 278~,56 2~78,05 2971,43 3066,10 315~,05 3251,36 343~,82 3625,56 3811,80 4002,88 418~,88 4~77.02 456~,74 4756,20 4944,15 91.7 922,)8 90,2 1012,11 89,4 1100,!0 94,4 1192,58 92,) 12~3,tI 93,1 i373,70 91.6 1462.76 95,5 1555,51 93.8 1646,12 94.5 1736.02 93.9 1823.19 91,0 1905,75 94,4 1989,37 95,2 2070.98 94.3 2148.47 91,9 2221,04 93,2 2291.77 91,7 2357,48 94,7 2420,H 90.7 2477,80 93.8 2533.19 94.5 25H.87 93.4 2631.04 94.7 2672.15 91.9 2707+02 93,3 2739,~4 185,5 2800.30 188,7 2862,00 186,2 2924.83 191,1 2988.14 186,0 3051,98 188,1 3117.92 189,7 3183,64 189,6 3251,23 187,9 3315.99 ~,~,~******** ANADRILL ************** SURU£¥ CALCULATIONS ~*~o~******** CIRCULAR ARC ~ETHOD******** TARGET STATION AZIMUTH LATITUD~ SECTIOH INCIN. N/-S ft deo deg ft ~.00 0,00 0.00 0.00 2.7~ 1,00 !0,00 2,76 ~,80 1,00 25.00 5,73 $,35 1,66 26,27 8.22 !1.98 3,75 38.55 11.72 19,09 7,42 41,20 18,52 2~,!2 9,40 45,49 28,06 40,41 10,92 49,00 38,74 53,40 12,14 50,25 50,95 63.34 13.36 42,44 65.!1 8~,97 13.61 35.15 82,01 !~,49 13,44 31,34 99,92 12~,26 14,15 22,94 120,15 14~,57 15,92 16.53 143.05 i7~,88 19,86 15,09 170,97 21i.!4 23.64 10.93 204.86 249+24 26,15 7,23 242.68 292,86 29.05 6.49 286,09 341.85 32,95 5,11 334.88 395.62 36.59 2.95 388.53 451,89 39.01 1.05 444,77 512.46 42,I7 1.25 505,36 575.36 46.25 2.42 569.24 646,74 49,79 2.74 639,56 7!7,26 52.33 2,84 710,00 ,,~,97 55.30 3,30 795,60 879,07 58.38 3,01 864.57 953:,20 62,33 2,49 945,62 1039,47 66,19 3,65 1030,76 1!23.53 69.24 3.92 11!5,65 ;;~,98 69,97 3,39 1202,93 I386,09 71+80 359,42 1378,06 I564.08 70,04 359,54 1556.41 1739,26 70,54 2,39 1731,69 I~!?,54 70,75 2.91 1911.78 309~,22 69.10 3.96 2096.17 2273,42 69.86 3,11' 2262,04 :~o,o; 69,60 4,07 2439,67 2~2~,48 68,62 2,40 2616;47 28D],78 71,05 4,79 2792,43 D~FA~TURE DISPLAC£~£NT ~t AZIMUTH ~/-~ ft ft deg 0.00 0,00 ~,49 2.S0 10.00 ~,-~ 5,90 13.95 ~,~3 8,63 17,72 5.06 12,77 23,34 DLS deg/ lOOft 0,00 0.31 0,15 0.56 2,37 I),83 21.45 30.31 4,01 19.91 34.41 35.36 2.30 31.51 49.93 39,13 1,84 45,39 68,57 42,01 1,32 60,~3 8S,97 42,96 2,27 74,21 110,60 42,14 1,84 85,~5 131,79 40.70 0.99 ~6,27 153,96 38,70 2,22 104,40 177,09 36,12 2,58 I12,26 204,54 33,29 4,20 119,98 237,41 30.36 4,35 125,97 273,43 27,43 3,24 131,18 314.73 24.63 3.10 t36,11 361,48 22,12 4,16 13?.84 412,92 19.79 4,08 14!,78 466,82 17,68 2,92 143,60 525.20 15,80 3.40 145,07 587,44 14.30 4,54 14~.25 656,51 13,05 3.75 15'1.69 726,02 12,06 2,80 155,75 800,99 I1,21 i(O,[O 879,27 10,49 163,98 959.73 9.84 1(8,55 1044,45 9,29 174,17 1129,16 9,87 179,74 1216,2~ 8.50 184.00 1390,29 7,61 I82,38 1567.06 6.68 185,33 1741,58 6.11 t~3,67 1921,57 5.78 203,19 2096,12 5.58 214,70 2272.2l 5,42 ~25.~5 2450,10 5.29 25,85 2627.08 5.15 24~,~3 2803.33 5,05 3,19 3.27 4,26 4.22 3,33 0,95 2.25 0.93 1.47 0,28 0,55 0.49. 0,97 1,76 H£ASURSD INTERVAL VERTICAL f~ ft ft 5132.97 I8B,3 3377.41 5416.11 283.1 3467.35 5602.37 186.3 3527.12 5789,36 187.0 3590,44 5972.87 183.5 3656.04 6253.54 6441,45 6625,45 6815,04 7000.72 7062.01 7387,25 756~.34 7758,66 7944,18 8130,94 9317,90 8503,32 8877.89 9065.97 9250.15 943~.26 9624,25 981C,12 9906.82 10093,70 10277.43 1046~.40 10656.64 10844.70 1103!.71 11215.40 11206.32 I139~.56 11490.20 11581.53 11672.67 11962.10 11856.08 280,7 3759,32 187.9 3826.48 184,0 3892.15 189,6 3958.59 185,7 4022,47 61,3 4044,30 325,2 4158,82 179,1 4220,00 192,3 4288,81 185,5 4357,65 186,8 4425,03 187,0 4491,76 185,4 4557,41 186.2 4621,51 188,4 4687.97 18B,1 4756,68 184,2 4825,05 186,1 4893.64 188,0 4960.17 185.9 5025.84 96,7 5059,87 186,9 5124,34 183,7 5189,28 189,0 5258.78 190,2 5329,91 188,1 5404,02 187,0 5480.77 183,7 5557,60 90,9 5596,55 93,2 5635,82 90,6 5673,18 91,3 5711,60 91.1 5751.54 89.4 5792,94 94,0 5839.41 *~********* AHADRILL SURU£Y CALCULATIOHS *~,~********* CIRCUCAR ARC TARGET STATIOH AZIMUTH LATITUO£ 9£CTIOH IHCLH, H/-S ft de§ deo ft 2990,14' 70,99 6,77 2970,07 3249,44 71,98 3,00 3237.52 3424,78 70,59 0,55 3413,83 ~03,~4 69,82 0,55 3589,75 3771.78 68.29 1,19 3761.12 ~03t,63 68,53 1,52 4022,02 4233.10 69.60 4,74 4197,23 -~,,..~ 68.58 2,80 4368,72 4557,50 70.39 4.58 4545,90 ~731,83 69.37 2,81 4719.88 4789.10 68,91 1,30 4777,12 5~93.42 69.86 2,58 5081,34 5251,73 70.I9 2.52 5249,49 5441,20 67.88 4,13 5428.76 5613,56 68,56 3,55 5600,65 5787,73 69,15 3,88 5774,46 59~2,37 69,03 3,91 5948,72 ~13~.77 69.50 3.69 6121.75 ~310,53 70,22 3,06 6296,22 &485.82 68,47 3,85 6472,19 ~6~1,89 68,69 4,20 6646,84 683Z,qO 67.74 2,97 6817,52 70~5.83 69,01 0,50 6990.43 7181,55 69,54 1,85 7166,21 7355.35 69,08 1,06 7340,04 7445,80 69.71 1,00 7430.54 7621,14 69.94 2,19 7605,87 779~,98 68.66 2,09 ~ 77,,.62 79~,61 68,18 0,46 7953,30 8144,57 67.91 357,52 8129.69 ~316,99 65,68 1,24 8302,48 8487,42 65.86 1,06 8472,98 865~.23 64,70 3,06 8639,72 ~735,39 64.57 2,53 8721,77 88~0,93 65.61 1.75 8806,2~ 8903,50 65.70 3J3 8888,77 ~9~6.36 64,54 3,~9 8971,46 9069.27 63.47 1.66 9053.27 ~147.51 61.38 1.67 9132.51 932~,17 59,34 2,18 9214,13 1R-34 DEPARTURE ~ISPLACEM~HT at AZIMUTH E/'W ft ft deq 264,91 2981,B6 5,10 287,75 3250,23 5.08 293.22 3426,40 4,91 2~4,?0 3601,85 4,70 297.49 3772,86 4,52 3¢3.64 4033,47 4,32 323,34 4209,90 4,27 324,:.:~ 438.0,76 4,25 335,~0 4558,30 4,23 347,24 4732,64 4,21 349,30 4789,87 4,18 329,6I 5094,05 4,05 367,10 5262,31 4.00 377.~9 5441,87 3.98 389,C2 5614,14 3,97 ~¢0,30 5788,32 3,97 4~2,00 5962.97 3,96 423,33 6136.37 3,96 433,~2 6311.13 3,94 ~44,24 6487,42 3,93 455,53 6662,50 3,93 ~E7.23 6833,5t 3,92 472,45 7006,38 3,87 ~76,06 7182,0t 3,80 489,48 7355,75 3,75 582,t0 7446.16 3.71 48~.~8 7621.45 3,66 ~3,39 7793.26 3.63 497,31 796~.83 3,58 4V4,22 8144,70 3,48 492,31 8317;07 3,39 4~5,73 8487,47 3,35 501,72 8654,27 3,32 5C5.73 8736,42 3,32 50~,~8 8820,97 3,31 512,62 8903,53 3,30 5:7,H 8986,39 3,30 52!.89 9068,30 3,30 524.19 9147,54 3.29 526.93 9229.19 3.27 deo/ lOOft 0.99 1.31 1,45 0,41 0.90 0.14 1,70 1,13 1,30 1.05 2.43 0,47 0,19 1,44 0,47 0.35 0.07 0,26 0,50 1,01 0,21 0,80 1.41 0,73 0,47 0,65 0,61 0,69 0,84 1,44 2.17 0,13 1,17 0,55 1,35 1.69 1.35 2,.49 2.35 2,22 H£P~URED INTERVAL VERTICAL D£PTH D£PTH ft ft ft !1946,86 90,8 5587,07 12038,42 91,6 5937.80 L2127.70 89.3 5989.84 12218.83 91,I 6044,83 [23!0,99 92.2 6100.91 12401,95 [2491,56 125B3,27 [2674,00 £2856.53 12945.00 [3036.38 13127.99 [3219,27 91,0 6156.!7 89,6 621.1.94 91.7 6272,29 90,7 6336,16 91,8 6403.61 90,7 6470,63 88,5 6534,92 91,4 6600.13 91,6 6665,85 91,3 6732~39 1331C,10 90,8 6799.61 L3400,89 90,8 6867,83 13493,73 92,B 6938,68 [3509,27 15,5 6950.64 ~ LAST SURU£Y IS PROJ£CT£D [3570,00 60.7 6997,46 **~*~******** AHA~RILL ************** SURVEY CALCULATIONS ~*~°~******** CIRCULAR ARC M£?HO~******** ?ARK£T STATION AZI)UTH LATITUO£ SE3TIOH INCLH. ft deg deg ft 930~,21 57.34 358.!~ 9291.38 93B2,18 55.36 357,25 9367,53 9454,46 53,34 359,25 9440,04 ~527,02 52,42 1,07 9512.70 9~03,12 52,62 2,04 9585,80 ~672.33 52.56 0,41 9658,03 7747,32 50,48 358,49 9728,17 ~811.09 47,19 357.72 9797,17 9875,14 43,30 356,43 9861,50 9937,03 42,I9 355,99 9923.69 9997,59 42,50 355,59 9984,60 J0057,59 44.30 352,49 10045,05 1012).I1 44,65 349,13 10108,22 1C!~],85 43,69 347.80 10170.76 1024~,17 42,71 348.I6 10231,88 ]C3DI.51 41,82 350,77 10291,93 10S6),14 40,77 351,88 10351,15 3~419,13 39,75 353,56 10410.65 I042~,88 39,57 351,32 10420.48 10465,75 39,57 35!,32 10458,73 1R-3~ .... D~FA~TUR£ DISPLACEH£NT at AZIMUTH DLS ~/-~ de9/ f~ ft deg lOOft ~'7,21 9~06,3~ ;~ 3,25 4,35 524,18 9382,18 3,20 2,32 52!,95 9454,46 3,16 2,90 522,14 9527.02 3,14 1,B? 524,[3 9600,12 3,13 0,86 525,~8 9672,33 3,12 1,43 525,02 9742,33 3,09 2,87 522,74 9811,10 3,05 3.63 519.:8 9875,17 3.02 4.41 5!5.30 9937,06 2.97 1,27 510.77 9997,6& 2.93 0,42 504,43 10057.71 2,87 3,15 494,21 10120,30 2,80 2.60 481,~6 10182,15 2,71 1.45. ~8,~5 10242.60 2,62 I,I1 457,27 10302,08 2.54 2.17 ~48,22 10360,85 2,48 1.41 44~,~1 10419.97 2,42 1,60 ~39,31 10429.74 2,41 9,24 10467.71 2,37 0,00 ARCO Alaska, Inc. Date: March 29, 1995 Transmittal #: 9219 RETURN TO: ARCO Alaska, Inc. Attn: Brian Hebert Kuparuk Operations File Clerk ATO- 1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. and return one signed copy of this transmittal. LIS Tape and Listing LWD Open Hole Edit LIS Tape and Listing LWD Open Hole Edit LIS Tape and Listing LWD Open Hole Edit Please acknowledge receipt 3/13/95 95009 3/13/95 95060 3/09/95 95061 Receipt Acknowledged: Date' .p. E £ E!V DISTRIBUTION: Larry Grant AOGCC 3001 Porcupine Drive Anchorage, AK 99501 ED MAR ;5 0 1995 Alaska Oil & Gas Cons. 6ommisslor~ Anchorage ARCO Alaska, Inc. Date: March 24, 1995 Transmittal Cf: 9216 RETURN TO: ARCO Alaska, Inc. Attn: Bdan Hebert Kuparuk Operations File Clerk ATO-1119 B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. Please acknowledge receipt and return one signed copy of this transmittal. ~ ~-'/5'~1R-33 1R-34 2T-21 2T-21 ,z./--~l R-32 ... 2Z-23 2Z-23 /_~2.Z-22 · CDR Depth Shifted 2Z-22 CDN Depth Shifted Acknowledged CDR Final Pdnt CDR Final Pdnt CDR Depth Corrected CDN Depth Corrected Slim GR MWD Depth Corrected CDR Depth Shifted CDN Depth Shifted . 12/28/94 1/13/95 Feb16-21/95 Feb16-21/95 Dec11-14/94 Feb7-10/95 Feb7-10/95 Feb1-4/95 Feb1-4/95 Date: RefCf95009 RefCf95060 RefCf95077 RefCf95077 RefCf95024 RefCf50-029-22544 Ref#50-029-22544 Refcf50-029-22524 Refcf50-029-22524 DISTRIBUTION: Mr. Vernon E Pringle, Jr. (Geology) DeGIoyer and MacNaughton One Energy Square Dallas, TX 75206 Sharon AIIsup-Drake DS Development ATO-1205 RECEIVED Clifton Posey GeAla~ 0il & Gas Cons. Commission ATe 1251 Anchorage Erickson/Zuspan NSK Central Files NSK 69 %arry Grant (+Sepia) AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Sandy Lemke ATe 1336 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO' David Jo~ ,R~ DATE: Chairmaa_...k.~ January 9, 1995 THRU: Blair Wondzeil, ~ FILE NO: P. I. Supervisor FROM: Lou Grimaldi, ,¢~,~ SUBJECT: Petroleum Inspector QAXJAICD.DOC Rig/BOPE Inspection Parker rig # 245 Arco well# 1 R-34 Prudhoe Bay Field PTD # 94-162 Monday, January 9, 1995: I made a Rig/BOPE inspection on Parker rig # 245 which was working over Arco's well 1 R-34 The rig was in top shape with evidence of regular maintenance of the BOPE and cleaning of the rig. Granville Rizek and John Crisp (Parker Toolpushers) do a outstanding job of keeping this rig in top shape. I found all BOPE to be in compliance. The area surrounding the rig was clean and orderly. Special attention is paid to keeping the area surrounding the camp clean. Good access around the rig was provided. SUMMARY: i made a Rig/BOPE inspection on Parker rig # 245, All BOPE equipment was in compliance. Attachments: QAXJAICD.XLS . o /, rl-oaa (~v. QAXJAICD.XLS ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 28, 1994 Michael Zanghi Drill Site Develop. Supv. ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 1R-34 ARCO Alaska, Inc. Permit No: 94-162 Sur. Loc. 623'FSL, 214'FEL, Sec. 18, T12N, RiOE, UM Btmhole Loc. 505'FSL, 360'FWL, Sec. 5, T12N, RiOE, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. ~~a~r~~ S~$ iON dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAbr~ OIL AND ~ CONSERVATION COMMIS,5,,JN PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill [] lb Type of Well Exploratory [] Stratigraphic Test [] Development Oil X Re-Entry r~ Deepen ~] Service r'~ Development Gas r~ Single Zone X aultipleZone 2.. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 45' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25628, ALK 2561 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 2o AAC 25.025) 623' FSL, 214' FEL, Sec. 18, T12N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 300' FSL, 350' FWL, Sec. 5, T12N, R10E, UM 1 R-34 #U-63061 0 At total depth 9. Approximate spud date Amount 505' FSL, 360' FWL, Sec. 5, T12N, R10E, UM 12/29/94 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'I'VD) property line 1R-1 7 13470' MD 360' ~ TD feet 14.7' ~ 400' MD feet 2560 6967' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035(e)(2)) Kickoff depth 800' feet Maximum hole angle 68.7° Maxirnurnsurface 2413 psig At total depth (TVD) 3650 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casin~l Weight Grade Couplin(~ Length MD TVD MD TVD {include sta~le dataI 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' _+200 CF 12.25" 9.625" 40.0# L-80 BTC 7072' 41' 41' 7113' 4076' 1450 Sx Arcticset III & HF-ERW 790 Sx Class 8.5" 7" 26.0# L-80 BTCMOC 13035 41' 41' 13076' 6666' (XO to 5") HF-ERW 8.5" 5" 18.0# L-80 LTC 394' 13076' 6666' 13470' 6967' 390SxClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural sCu°rr;dacUect°rR E C E iV E D Intermediate Production LinerDEC 1 5 1994 Perforation depth: measured Alsska 0ii & Gas Cons. Commission true vertical Anchorage 20. Attachments Filing fee X Property plat [] BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot r~ Refraction analysis r-] Seabed report ~] 20 AAC 25.050 requirements X 21. I hereby certify ~ ~~x.,,~ that e foregoing is ue and correct to the best of my knowledge Signed .~ Title Drill Site Develop. Supv. Date (~"~ 1 5~01~o'~ C°mmiZn Use On'y Permit Number Approval date See cover letter for -- rec{uirements Conditions of approval Samples required ri Yes ,~ No Mud Icg required L.J Yes [~ No Hydrogen sulfidemeasures [] Yes [~ No Directional survey required [] Yes [~ No Required working pressure for BOPE r'~ 2M r~ 3M ~] 5M [] 1OM [~ 15M Other: Original Signed By David W. Johnston by order of/ -'-) ....~,,~ ~_~ Approved by Commissioner the commission Date /o'", c,, Form 10-401 Rev. 7-24-89 Submit in triplicate I , . , 10 11 12 13 14 15 16. 17. 18. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 1R-34 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (7,113')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (13,470') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" x 5" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) ND BOPE. NU tubinghead & full opening valve for cased hole logging. Secure well and release rig. Run cased hole cement evaluation. ND full opening valve and NU master valve and cap. Move in and rig up Nordic #1. Install and test BOPE. Pressure test 7" x 5" casing to 3500 psi. Perforate and run completion assembly. This is a "packerless" completion that utilizes a 4" seal bore extension (SBE) run in the 7" x 5" casing string. The seal assembly is run on the end of the completion string, stung into the SBE, and tested to ensure tubing x casing annular integrity. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. RECEIVED DE(; 'l 5 1994 Alaska 0il & Gas Cons. Commission Anchora~ DRILLING FLUID PROGRAM Well 1 R-34 Spud to 9-5/8" surface casing Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 9.0-10.0 15-25 15-35 50-80' 5-15 15-40 10-12 9.5-10 _+10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 10.8 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2,413 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 1 R-34 is 1 R-17. As designed, the minimum distance between the two wells would be 14.7'@ 400' MD. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The annulus will be sealed with 225 sx of cement followed by Arctic pack upon completion of fluid pumping. Risks in the 1 R-34 drilling area include possible lost circulation and high pressures in the Kuparuk. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. The 7" casing will be topset above the Kuparuk and a 5" liner run to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 10.8 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 9-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. RECEIVED DE(; 1 5 i994 Alaska 0il & Gas Cons. Commission Anchora~..?, iCreated by : jones For: D PETRASH iDate plotted : 6-Nov-94 Plot Reference is .34 Version #5. iCoordinates are in feet reference slot #54.i iTrue Vertical Depths are reference RKB. Baker Hughes INTEQ 50O t"q 0 .. 500 1000 1500_ -I~ _ (D 2000_ - 2500_ _ 0 · --3000_ --,1.-- _ 5500_ _ 4000_ _ ¢500_ - J 5000_ V - 5500_ 6000_ 6500_ - 7000_ ARCO ALASKA, Structure : Pad 1R Well: ,34 Field : Kuparuk River Unit Location : North Slope, Alaska ....... East --> 1200 600 0 600 1200 1800 I I I t I I I II II TD LOCATION: 505' FSL, 360' PC/L SEC. 5, T12N, RIOE N 3.15 DEG E 10;353' (TO TARGET) ***PLANE OF PROPOSAL*~* J TARGET LOCATION: J 500' FSL, 350' F~L SEC. 5, T12N, R10E TARGET - A3 SANDS r~D:6723 TMD=13151 DEP=10253 NORTH 10237 EAST 564 ESllMATEO RKB ELEVATION: 86' RECEIVED 19.67 25 58 B/ PERMAFROST TVD=1656 TMD=1683 DEP=t79 ...... ~.~ . . _ k, 3'i.~2 Alask~ 011 & f~a$ I,;Orl$. uommlsSlOn X,,,3~.s4s Anchora~:¢- %. 4-9.42 %., 55.40 B/ W SAK SNDS r,.tD=3876 TMD=6553 0EP=4403 "~ ~ 5/8" CS(; PT 1VD=4076 1MD=7113 DEP=4gl4 AVERAGE ANGLE DEG BEGIN ANGLE DROP WD=5622 TMD=l1360 DEP=8871 '""~ 600o K-10 1VD=5806 T1~D=11786 DEP=9254~- --'= -- "'~-.. ~-2'~c~80O "~-' 5~.oo DROP K-5 1VD=6096 TMD=12293 DEP=9670 %5o.~c~.00 6600 6000 J I 5400 Z 4800 0 4200 3600 3000 2400 1800 1200 600 o 0 600 g 2 DEG / ~00' _10800 - _10200 _ _ 9600 _ _ 9000 8400 78OO END ANGLE DROP - T/ ZONE D 1'VD=6449 TMD=12795 OEP=10023 ~ 42.00 T/ ZONE C 1VD=6553 TMD=12929 DEP=10110 T/ ZONE A 1'VD=6704 TMD=15126 DEP=10237 TARGET ANGLE TARGET - A3 SNDS TVD=6793 TMD--lalSI DEP=I0253 8/ KUP SNDS 1¥D=6814 THD=13270 DEP=10329 40 DEG ~ / ?" CSG PT TYD=6967 TMD=13470 DEP=10457 I I I I I I t I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 500 0 500 1000 1500 2000 2500 3000 5500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 Scale 1 : 250.00 Verficat Section on 3.15 azimuth wHh reference 0.00 N, 0.00 E from slot #34 1700 ~ocation : North 21Ope, Alaska ' West SCale I : 50.00 7oo J7oo ,330o 3100 RECEIVED DEC '! 5 I99~ Anchora? West STOO 4~OO ,~)OO 30O SCale 1 : 50,00 '~soo .3goo -5700 'S~o0 -5200 I I ,~TOO ARCO ALASKA, IYIO. Structure : Pad 1R Field : Kuparuk River Unit Location : North Slope, Alaska < - -- We s f ScaPe 1 : $0.00 1+00 1,1001200 11(~ lOO0 900 600 700 600 ~ ~ 500 200 I00 0 I00 200 500 4~0 54:10600 3700 36O0 2200_ 2600 2100_ 25O0 2000_ 2400 1800_ ~.~ 1400_ 1.100_ CO 1200 RECEIVED DEC ] 5 1994 ,,*A.!~sk~ Oil & Gas Oons. Anchor~, 14.001300 1200 11 001000 gO0 800 700 600 500 400 300 200 1 00 0 1 O0 200 300 400 500 600 < - -- W e s t sco,~,: so.oo Z 0 ARCO ALASKA, Inc. Sfrucfure : Pod 1R Field : Kuporuk River Unif Locofion : North Slope, Alosko <-- Wesf Scale 1:20.00 ~60 520 ~80 4.40 'H:)O360 520 280 2'1~0200 160 120 80 40 0 ~0 80 120 160 200 12001 11601 11201 1080[ 1040~ 10001 960 ~ 920 ~ I 1900 1800 ~1240 1200 ~1160 1120 920 I I 84O ~ 0 760 '~ 270 560 560 44O RECEIVED DEC 1 5 199q ,~o A~aska Oil & Gas C0ns. Commission Anchom ~ 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 i I I I I 560 520 ~ ~ 4~ 3~ 320 2~ 2~ 200 1 ~ 120 ~ ~ 0 ~ ~ 120 1 ~ 200 2~ <-- Wesf ~,~. ~o.oo 64.0 720 72O Casing Design / Cement Calculations 13-Dec-94 Well Number: Surface Csg MD: Surface Csg TVD: Production Csg MD: Production Csg TVD: Top of West Sak, TMD: Top of Kuparuk, TMD: Top of Target, A3 Sands, TVD: Estimated Pressure: Surface Casing Choice: Production Csg Choice: Production Casing Frac. Pressure 1 R-34 7,113 ft 4,O76 ft 13,470 ft 6,967 ft 5,189 ft 12,793 ft 6,723 ft 3650 psi 3,500 psi Maximum anticipated surface pressure Estimated BH pressure at top of target zone TVD surface shoe {(13.5'0.052)-0.11}*TVDshoe Estimated Pressure= Top of Target, TVD = Overbalance, psi= Anticipated Mud Weight =1 4,076 ft 2,413 psi[ 3,65O.O ppg 6,723 ft 130 psi 10.8 PPgl Surface lead' Top West Sak, TMD = 5,189 ft Design lead bottom 500 ft above the Top of West Sak = 4,689 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 1,518 cf Excess factor = 85% Cement volume required = 2,809 cf Yield for Permafrost Cmt = 1.94 Cement volume required =1 1,450 sxI Surface tail: TM D shoe = 7,113 ft (surface TD - 500' above West Sak) * (Annulus area) = 759 cf Length of cmt inside csg = 80 ft Internal csg volume = 0.4257 cf/If Cmt required in casing = 34 cf Total cmt = 793 cf Excess factor = 15% Cement volume required = 912 cf Yield for Class G cmt - 1.15 Cement volume required =[ 790 sxJ RECEIVED DEC 1,5 ]99'~ 0il & Gas CODS. Commission Anch0ra." Casing Design/Cement Calculations 13-Dec-94 Production tail: TMD = 13,470 ft Top of Target, TMD = 12,793 ft Want TOC 500' above top of target = 12,293 ft 5" casing tail top (50' above A sand) =[ 13,076 ftJ 5" Annulus area (9" Hole) = 0.3054 7" Annulus area (9" Hole) = 0.1745 (5" Casing Top-TOC)*7" Annulus area + (5" to TD)* 5" Annulus area = 257 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.0997 Cmt required in casing = 8 cf Total cmt = 265 cf Excess factor = 75% Cement volume required = 464 cf Yield for Class G cmt = 1.19 Cement volume required =[ 390 sxJ TENSION - Minimum Design Factors are: T(pb)=1.5 and T(js)=1.8 Surface (Pipe Body): Casing Rated For: Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Length Casing Wt (Ib/ft) Dead Wt in Air Buoyancy = Tension (Pipe Body) Design Factor Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 Production (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body)= Design Factor =[ Production (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud RECEIVED DEC ~. 5 1994. Casing Rated For: Length = Casing Wt (lb/R) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =! Gas Cons. Commission Anchor~ ; 9160O0 lb 7,113 ft 40.00 Ib/ft 284520.0 lb 45757.9 lb 238762.1 lb 979000 lb 7,113 ft 40.00 Ib/ft 284520.0 lb 45757.9 lb 238762.1 lb 604000 lb 13,470 ft 26.00 Ib/ft 350220.0 lb 57112.0 lb 293108.0 lb 667000 lb 13,470 ft 26.00 Ib/ft 350220.0 lb 57112.0 lb 2931 O8.0 lb 2.31 Casing Design/Cement Calculations BURST- Minimum Design FactQr = 1.1 Surface Casing: Burst = Maximum surface pressure Casing Rated For: Max Shut-in Pres = Design Factor =[ Production Csg: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres (3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure = Outside Pressure = Net Pressure = Design Factor =! COLLAPSE- Minimum Design Factor = 1.0 Surface Casing 1. Design Case - Lost circulation and Fluid level drops to 2000' TVD with 9.0 # Mud 2. Ext. Pres=Mud Wt*0.052*TVD-(2000'TVD of 9# Mud) Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =[ Production Csg 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 13-Dec-94 5750 psi 2413.0 psi 2.4J 7240 psi 7417 psi 3224 psi 4193 psi 1.71 3090 psi 0.562 Ib/ft 1356 psi 2.3J 5410 psi 0.562 Ib/ft 3917 psi 1.41 DEC ~ ,5 1994 ,~iaska 0il & Gas Cons. Cot~lrnissJon Anchor~ Casing Design / Cement Calculations 13-Dec-94 Surface Casing Choices OD ID I b/ft Grade Metal X-Section Jt Strength Body Strength I 9.625 8.681 47 L-80 13.5724 sq. in. 1161000 lb 1086000 lb 2 9.625 8.835 40 L-80 11.4538 sq. in. 979000 lb 916000 lb 3 9.625 8.921 36 J-55 10.2545 sq. in. 639000 lb 564000 lb 4 10.750 9.950 45.5 J-55 13.0062 sq. in. 931000 lb 715000 lb Collapse Burst 4750 psi 6870 psi 3090 psi 5750 psi 2020 psi 3520 psi 2090 psi 3580 psi Production Casing Choices OD ID I b/ft Grade Metal X-Section Jt Strength Body Strength I 7.000 6.276 26 L-80 7.5491 sq. in. 667000 lb 604000 lb I 5.000 4.276 18 L-80 5.2746 sq. in. 376000 lb 422000 lb 2 7.000 6.276 26 J-55 7.5491 sq. in. 490000 lb 415000 lb Collapse Burst 5410 psi 7240 psi 10490 psi 10140 psi 4320 psi 4980 psi RECEIVED DEC 1 $1994 AJ~sk~ {iii & I~as Cons. O0mmission Anchor~. -. r~UPARUK RIVER UNI', 20" DIVERTER SCHEMATIC 6 I4 3 2 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. . MAINTENAN(~E & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) RECEIVED 1. 16" CONDUCTOR. ~'~$k~- 0il & Gas Cons. Commission 2. SLIP-ON WELD STARTING HEAD. Anchor~ : 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20"- 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE, THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OFANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. DKP 1 l~J/CJ4 < < 7 , 6 > > 13 5/8" 5000 PS, BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1,.-5~ PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH 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 AND 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 TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR 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 LOW AND 3000 PSI HIGH. TESTAS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOTA 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. BACKOFF RUNNING JT AND PULL OUTOF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI 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 KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5(:X)O PSI ANNULAR RECEIVED DEC l 0il & Gas Cons. Commission Anchor;. WELL PERMIT CHECKLIST COMPANY /~f'~ ~_~ c5 INIT CLASS /~..~/ /--~/ UNIT# PROGRAM: exp [] dev~ redrll [] aery [] ADMINISTRATION 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 drlg unit boundary. 6. Well located proper distance from other wells ..... '7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party ............. 10. Operator has appropriate bond in force ........ 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval. 13. Can permit be approved before 15-day wait ....... APPR DAT~ 14. Conductor string provided ............... 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 horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ..................... 26. BOPE press rating adequate; ~est to~ ~(>~t) psig.~ 27. Choke manifold complies w/API ~-53 (May 84) ...... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............ GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures .... 31. Data presented on potential overpressure zones ..... Y / N 32. Seismic analysis of shallow gas zones .......... / · 33. Seabed condition survey (if off-shore) ........ / Y N ' 34. Contact name/phone for weekly progress reports~.,../.. Y N [exploratory only] / GEOLOGY: ENGINEERING: COMMISSION: B '" '~ "~/'/'~ '~' DW~ Comments/Instructions: '-~OW~o - A:~FORMS~,cheklist rev 03~94 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. RECEIVED MAR 50 I995 Alask~ Oil & ~as Oonso Ooramis$[o~ Anchorage ,I$ Tar, e Ver l f Scat ,i on I,Ist, ina chlumberger AlasKa Comp,t,'.ino Center 13-~A¢-1. q9b 13:53 SFRVICE N~F,, : E[;TT D~'rF : 951(;3/13 TAPF NAuE : 95060 C~NTINU,~TION ~ : Cg~';~EMT : ~RC() At.,ASKa IBC., FUPA~dW RIVEP UNIT, 1. R-34, 50-020-22534 Ku~oruk ~iver Umit OPEPATO~: .bOGCI NG COMPANY: T~PE' CREATION DATE: d 0 g D A T a ENGINEER: BIT RIII,,~ 1. 950 ~ 0 St. git RUN 4 95060 St, Amour ~,'; t.:~[~ P i S80~~ !.¢ - 34, 5O02922534 Arco Alaska !nc. SC}41,,U~IRERGE~ ¢iEb[, SERVICES 13-~iA~-95 P, IT RUN 2 9 0 0 St, At't'lOklr BIT RUN 5 95060 S'L. A~OLIF MURRI6$Ob~ 1 2 ,N 1, 0 E; 6 23 2:14 45.6' 0 PAGE: .IS Tame verification List~ ~chlumherqer Alaska COmptltinq CeDter 13-u.A.R-19O5 13:53 ~.500 9.875 7133.0 1ST ST~£:,IG 3RP ST~]jNG LIS F'OR~AT DATA LIS FORe, AT nATA PAGE~ **** F [ [: .F.., FILF NA,~.~Ei : EiOIT .00! $~RVIC~: : FLTC VERSIClN : O01COI NaX REC SIZ~ .F..T. !.,, F TYPE : L/~ST FILE] : FILE FILE NUi,~gER: Depth shifted and clipped curves; 81! bit runs merged. FII.~E LDWG TO()!,,, COPE B,AS L,[NE CU~V~ F(] C[.IRv2 SHIFT DATA - ......... ECSUIVALE;~,IT U~qSHIFTED DEPTH .... - ..... ..........l, ~ '~'~;~. ,., ..... 0 7X~;~;''' ~ 749!,0 9925.0 3 9925,0 12182°0 4 12~,82,0 12840.0 5 ~.2840,0 12994,0 6 1.2994.0 13570.0 IS ~ap.e ver.Ificat;ion l.,ist, lnq chlumberq~r :{!as~.a Comp~]t~.n~ Center 13-~,4AP-19q5 1.3:53 PAGE: THE .~T~R A~.~D PSVR CURVk;S P~AY ~!OT f) qERI, AY T~iE FIEIj[) ** DATA [.,.' .O R ;,4 h, T gP~CTF'TCAi/T,]N r~ECOPP ** TYPE REJPR Ci,)i)H ~ALI}rl 1, 66 . 2 66 0 3 73 3° 4 6b 1 5 66 6 73 7 66 8 68 0.5 1,! 66 28 1.2 68 13 66 0 14 65 FT 15 6b 68 16 66 ] 0 66 0 Tare ¥ er j. f,i..cat.i on icMlumbeToer AlasKa COmPuti.~o 13PP?'. ! 356, 9. 500 Ra.. ~ ,,~ B -90.9.25(> VR~'. Ut,~l'~ -999.25C, DF'PT. 1 ~SC 0. bOO VRP..,v'*'~ 2.6P4 DFpT. 13000. OOC VRP.~v;D 2.51 DFPT. 127r~ru. UC;0 VR?. ~1igD 1.461 DF??. 12500. 000 iq5. ~WD 2. 957 VRP. ~WD 3.3(:3 DI~TpT. 12250. VRP. MWD 2.29b, D E F ti'. 1200 (). 0 r, 0 R~. MWD 2. ! C 0 V a P. !~ !,v D 2.058 DB,,~- t. 11500. i,,{/~. MWD 3. 522 VRP. MWD 3,629 D F~ p T. I !. 250.000 R~,. M~D 3. 226 VR~. M,,b 2. 839 il) 00 g 20 920 D ~.~ P T , I 0 ? 50 , 000 R.~ , MW[) 2 . 7 ] 3 VRP,MWD 3.!72 Center 13-MAP-1995 13:53 GR. MW!,.) -999.250 R[)P. :t~WD 19.1{)8 FET.MbD ~P. . .,'<'WI.;, -qqg... .'250 DEi~.'4WD -99a.250. VRA.~WD P t-) . F' W O C~ R o !-t bt i,) P P. Yi W D G R. M k: D · f; L,. G R. ¢i W D P P. ,~ kO G R. M W R ?. h b D G R. :~,'i W [) R P. )4 !,~! D g R..!'4 W t) a P. M W D 9 5.3 ~i 1 R [3 P. ?',;, W 9 2. g 90 D E R. ;,'l ~'~ 0 76.231 RD[:'. 4.8 J, 2 DER. 98.4 ~5 ROP. 2.624. DER o :qWD 118. R~5 aOP. MWO 1.490 DER.NWD 163.719 ROP. ~v~W!) 3,233 DER. M~D 1. 06.432 ~ 0 P, ~',,'i w [) ~ ~'. ~ , , 2.303 2.. 008 D E R. ~!, W D 1.32 271. ' 2.6 8 125.8e5 R, OP..MWD 3.623 DE:R. MWD 8 ~. 777 R 0 P. M V,,i D 2. [~92 DER. MWO G R. M 1,; 1.) !, 00.606 R 0 P. N W 9 R P . ~i, W t:) 6 .001 D E,'R. M 'w O 16.730 2.~92 34.951 4.~44 20.753 2.686 79.946 1.4fl7 156.51,8 3.124 !,04.653 2.10~ 22 059 57.508 2.395 114.645 3.SSS 70.868 2.994 98 356 si s2o PET. M w D VRA ,M'~D F E T. ~, W D VRA.~WD FET. M WD VRA.MwD F E T. N W D VR A .. ~,~ wD PET. M wO VRA.~WD PET.MwD v R A. M Wl D PET. ~ WD VRA.M~D FET. M WD VRA.~WD F'ET, MWD V R A . M W D FET. MWD VR A. ~ WD R, .:P . F,4 ,w [,) 3 .264 D E: R . ,,,~4 W O 3.019 V R. h: ~'l :~, O PAGE: -999,250 -999.250 1.450 2.926 0.807 5.053 1.6!4 2.541 0.B85 1.417 1.076 3.065 0.465 2.0!5 1'2~6 2.063 1.156 2.275 1.1,88 3.655 0.578 2.983 0.676 8.044 I 1,96 ,Is Tape Yeriilcation !,~iSti. ns ;chlumberger A..!..asKa Computiinq 0.000 2.653 3.137 DFpT. 10250.00,0 VRP. ~D 3. 345 I)FpT. ! 0000. O0,0 VRP.,uWD 3.052 [)~iPT. 0750.000 Ra.~WP 2.879 VRP.~WD 3.494 DFPT. 9500. 000 aa.~WO 3.153 DEPT. g250.000 Ra.~WD 4.456 VRV.~WD 6.453 DEPT. 9000.00© RA.MWD 3.395 VRP.MWD 3.381 DFPT. R5.~WD 3.597 VRP.~WD 3.6e3 24.7 DEPT. Ra.~,qWD 3.450 VRP.NWD 3.536 DEPT, 8000,000 R~.MWO 13,426 V~P,~WD 3,390 DEPT. 7750,000 RI.MWD 3.~6~ YRP.~D 3.4~6 {) E ? T. 7500.000 V R P..."~ w D 3.157 Center R P. r~: W D C R. ~i w D 13-k~AR-:1995 ,[3:53 ! 06. 541 kOp. ,~,;a,D l. (.,.P.. 74,8 ~f]P. y, wD ! 07. 699 I;~i').P. 3. 393 DER. 97.1 ~,1. ROP. 3.5,52 DER. 96.114 5 · 150 [)ER . 94.556 k 0 3.39 !. [)ER 3.028 144.000 3.284 73,469 2.920 ~5.937 3.172 166.664 3.39i 260.869 4.972 318.719 3.392 FET.~D FET.M~D FET.~WD VCa.~WD VRA.MWD FET.NWD VRA.gWD GR,.NWD 101.9u5 [~OP.~WD 27:2 557 ~ET.!~D R P. i~,'~ w [) 3.6 o o P [: ~. t"t w O 3; 59 o v ~ ~.. ,~a w D 224.469 3.33] 312.841 3.501 C, R, H W D ~ P. ~; W D 91.576 3.382 D E R..~ h~ O 93.2-40 3.529 3 . 449 i) E R . .~ W D G R. f~4 W RP.gWD 329.9~0 :3.441 VRA,~WD FET.MWD VRA.M%,iD FET.N~D G R, ~4. ¢; [) 103.7 O 9 R O P. ~4. W .') 340 735 F E T. tU W D (.; JR, lq b D 92.726 I? 0 P, i)! h.! D 224,995 F' E T, N W D PAGE: 0.]68 2.832 0.486 3.096 1.015 2.692 0.479 2.95~ U. 509 3.173 0.414 6,005 0.257 3. 389 1,.254 3'562 0.381 3.225 0.342 3.492 0.41.4 3.310 0.278 3.207 0.224 3,031 Tape Vet 1. f fcat.ion ',chlumberger Alaska Com~,utino Cent:er 13-~AP-1995 13:53 104.0 e,.' 6 POP. 3.815 254.391 3.~69 DFPT. 7058.500 GR. ~'~ D 34.0,90 NOP. ;q %~ [) -q99.2.,50 [~ ,~D -999.250 R P. ;',~ ~,, [) -099.250 )1) 5 ~. ,~. ~c [) -999.250 V~.P, ~..'i ~.' D -999. 250 EET,~D FET,~D PAGE: 0.291 3,977 -999,250 -999.250 FIL, F ~A~iE : EO!'!' .OO1 SF~VIC~: : WLIC VERSION : 00!C01 DA?w : O51071!. ~',~X ~KC $'!Z~: : 1024 FT[,,,~: TYPE : I.,O F!'L~ ,~4A~E : EOT'I . S~R¥ICE : FLIC VI{RS IOt,~ : 001C0! DA'T~ : 95103/13 ~4hX ,R~;C SIZE : F 1' b~t TYPE : LaST F.I' Lg : Fl LF,, [!E~DER F!LF NUgBER 2 RA~ Curves and loq, l header data for each bit. ru!n t.n separate BIT RUN '~t'U~BEP: 1, DEPTH INCRE~qE~T: 0,5000 "'"'""" ..... ';;;l; .... "';iT;'" CDR 7 70 DATE LOGGED: 1,3-dA~-95 SOFTWARE: SURE'ACE SOFT~o~t.AI~.E VERSIO~:~: FAST 2.5[{ DATA TYPE *[3 I) RILLE~R CF~!,'): 13570.0 files. made Verilication Listino ~Chlumberqer AlasKa Computinq Center 13-~AR-!995 !3:53 PAGg: T(]P LOG 'TiqTgPVA.& (FT): BOTTOM [.~G INTERVAb ~IT ROTATILIG SPE;~iI') (~PF): HOT,E INC[.,I NATI 0~ MTNIr~i~M ANGLE: TOOT, STPlNG (mop VE.Nr)GR TOOL COl)~7 TOOb mYPE ............... . .... . , .... oT CDR hU~[., R~]S] ~ 'IVIT P(]PEHOL~' AND C.aSTNG DATA OPEN HOI,.E ~.~tI' $!Z~ (IN)'. D~'T. ULE~S CASTNG D~;PT,U (FT): 7140.0 !3545.f) 6~.9 69.9 .... ~;I.JD ~ YPF: DFNSITY (Lg~/G): PH: CHLORIDES (PPt~): Fl.,u!g' LOSS (C3): MAXIF~I~M RECt3.RDE!.~ TE~BERAI."~IR~.~ (DEGF): RESISTIVITY' (OHMN) AT TE~IPERATURE, (DEGff"): ~[..~D AT aEASOR~.',D TE;~'PF, RATIJRE MOD AT MAX CIRCUI..,AT!NG TEi~PERATURE : '~UD FILTRATE: AT (freT): ~l?O CAKE AT (aT): ~EI. ITRO~ TOOL MATRI× DENSITY: H(3[,iE CORRECTION (liN'): RE~;.a RKS TOOb STANDOFF (IN): 8.500 7133.0 LSMD 8.50 29.0 SANDSTONE 2.65 8,500 500 ****************** RGB RU.~ 1 & 2***:************ l. sta~ce: F,i't to C;A.: 75 93 ft. ~i. stance: ~?itt,. t,o R[JP: Oi. stance: [~'3it to Res: ~5 51 DriIl, ed Interval 7150- 0491 ft, (RU~', i) Ori],.led .Interval. 74Ol - gg. 25 ********************* RG8 Ru~;~' 3 & Olstance: bit to g'R~ 66.42 ft. Of, stance; Sit to Res: 56,00 (;,rill. e~ Interval 9925 - j, 2182 ft, Orille~ .I.~t, ervol 12~2 - 12~:40 it, (RIJhi ) *******:*********.** RGS Ut, iN 5 *~'**************** [)istence: ;~;it to ¢;P~: 59.04 ft. Distance: ,6Jr t.o ROP: 51.79 Distamce: 6Jr tO Res: 48,62 ,IS. ~ape VerItitcatJo~ .Listi. ns ;chl. Ug, berqer ~k.laska ComputJnci Cemt. er 13153 l~ri].le~ I~t. erval 12~40 - 1209a ft. [)ista~ce: b~,t to GR: 3~.96 ft. Oista~ce: ~it to gOP: 27.71 Oista~ce: ~it to Res: 24,5~ ft. i)ri].led Interval 12994 - 1357o ft. '~ell TO'd on 1-12-95 at ~nc~le at :rl.~: 39.57 E, ec~. ~lax. LIS F'OR~A~ PAGE: ** DATA F'ORf,~;AT SPEC)FICA'I"TOIx; RE(!OR!,~ ** ** SET TYP< - 64b:[:~ ** · :~F ..... E E API &PI API API FILE N(J~B NU~B SIZE REP[:{ PROCES ID Oal:,i~,;R ~ [~OG '.I]YP~I CL,ASS 1~[,.![) N(.j~,![:~ S,ANP gbE,a Ct)D~; (HEX) p T F T 61. o 1. a (..~ 0 ~ ,7) o 0 00 0 2 I 1 4 68 00000000 , , ..~ , . G~ !.., W' 1 GAPI 6191a0 O0 000 Ok; 0 2 J.. 1 4 6~ 0000000000 ROPE I.!~] F/M~~ 6191~0 O0 000 O0 0 2 1 1 4 68 0000000000 T ~ B !., ~: 1 :~t R 61. 91. 90 00 000 00 0 2 i i 4 68 00000000 ATR I,,,W 1 0 H tv~ ~,, 6!91~0 O0 000 O0 0 2 1 1 4 68 0000000000 ,IS Ta¢e Verlf~icatI. or, l,ist!n~ ;chlun',berger Al. asks Co,'.;'.)uti.ho Center DE.pT o 7490. ()0!.; Z~TP o Lk; ..l -999 · 25(., DPPT. 7250 · 0oO ATP · I.,wl 3. 989 L) F'pT. 7058. 500 aT~. I,k; 1 -909,25C' 422.637 -999.250 254.391 3.~69 -999.250 -99g.250 TAB.!,wl TAB.!.wl TAB.I.,w ! -999.250 0.291 -999.250 **** FILE TkAII,ER **** Fib;' t~at~E : SERVICE V~RSION : o01C0! L)~TF : 95/031!3 ~X REC 5!Z~] : 1024 FI'L~" TYPE : 1..~O L~ST FILE **** FILE 19' I !.., F ~,J A ~ E SFRVI'CE : FLiC V ERS IO;)~' : O01. COI DATE : 95/U3/1 ~,i!X REC SIZE : 1024 FILF TYPE : 1.,() LAST FIfE : FILE FILF NUMBER 3 RA~ Ctirves and log aeader data BIT RUN NI.I~BER: 2 DF, PTa I~CRE~E~T: 0.5000 FILF SI.I~ A RY V ~1N I') 0 R T 0 0 I,.., C C,) f) E S '~I." h R T t) E: L, OG }'iE.APF, P DATg b A T 'E; !., 0 G g E [): S i' ~ F T w .A R g: for each bit: r'dn i.h separate 13 - d FAST files, Tape verlf:icatien l'.,istt, nCt .cblu,,beroer .Alaska Com, put:Jnq Center ,[ 3-t,,AR-.1 q95 13:53 PAGE: 10 PA!'.& TYPE 'lP D,~ !LLER .'tOp L©G T.;',ITE:PVA[.., B/OT T~q a l~j fi G ~[)I.,E INC[, TOtJ!., ,e,T~[NG (TOP VFt'~I.)OR T(Tif').l.., CODk: TflOI, "I'YP~: Cr)R $ AND C~6Ii',.!G PATA DRIL~I.,[,.;R,S C,,'~,~.! ,,,G lJlt;P!IJH 13570.0 7110.0 13545,0 95 67.7 70.2 R[]RE,'.-1OLE CO?,~P I:tl ~ [.I [.) TYPE.-,'. ;ii/i) DENSITY (I.,6/t':;): aIlD 'qI$C()SiTY (,%): ~![!f] PH: FLUID L~S 1RF;8IST IVI ~4UD :v~uD C~ (FT): NEIITR[]q TOOl., M ~,.T R.I' X: 'a 0 t.., E C f') R R 8.500 7133.0 ~,90 33.0 2.310 2,970 0.000 74.0 60,0 0,0 ShNDSTOI~E 2.65 8,500 E~R FREOUE~,ICV' (HZ): *********.******.*** RGS RUN !, & 2******,********* Distance: .i.)t't to c,;R: 75,93 ft. Distance: Bit to ROI:): 68,6~ it. [)istance: 13it to Res: 65.51 ft..., Drilled It~terval. 7150 - 7491 ft, (RUN 1) Drilled Interval 7491- 9925 f~, (90N 2) *****************~ R(;S R[tN' 3 Distance: .~:)it to GR: 66,42 Dist. ance: ~.it to ~OP: 59,17 Distance: ~it to Res: 56,00 [)rilled Inte.rval 9925 - 121~2 Orilied Interval :121.8~ -12840 ft, (aOq 4) *****************~ RGS R'UN' 5 *~*************:*** ~I~ Tape verification l.,istin~ .chlumberqer AlaSK+~ Co,mmt.]ti~](~ Center i3-.~!AR-1.995 13:53 PAGE: 11 [)i s t.e.~,~ce: Bit: Distance: bit Distance: i~it Drilled Interv **~****~**** DistaqCe: Distance: Distance: Drilled Interv ~ell TD'd ADql. e ~t TO: tO GA: 59.(.'4 to PF]D: 5~,79 ~t. to Pes: 48.62 al ~2840 - 12994 ft, to CA: 34.96 ft. to ROP: 27.71. to ~e$: 24.54 tr, al 12994 - 13570 ~t. -12-95 st 01:00, 9.57 DeG. Hax, Dev.= 7~.~2 I~ 8689.5 Cji P D *' ~ 000 00 0 3 1, 1, 4 6 B 0000000000 000 00 0 3 1 1, 4 68 000 O 000000 000 O0 0 3 1 1 4 ~8 0000000000 000 00 0 3 1 1 4, 68 000000000 O 000 00 0 3 1 IL 4 68 0000000000 000 O0 0 3 1 1 4 68 0000000000 000 O0 0 3 I I 4 68 0000000000 ,IS Ta~e Verification I,istin~ 13-~'!AP-1995 13:53 ~chlumherqer Al. asKa Computinq-. Centc, r PAGE: 1.2 o 925. U -999. 250 DVPT. q 750. 000 .... ATR.L'W2 2.~79 0500.000 3.153 DMPT. 9250.00[! ATP.I..,W2 4.456 D~PT. O0n0. 000 DEPT. 8750 . 000 hqlP. [.,W2 3. 597 DEPT. 8500.000 AT~.L~2 3.247 DF, PT. 8250. O00 aTP.[,W2 3.450 DEPT. 8000. 000 ATP. I,,W2 3. 426 DEPT. 7750. uO0 hTR. l,.,w2 3. 268. DEPT. 7500. 000 a T P . L ~ 2 3 . 0 ] 8 D~PT. 7412.00U ATP,,. t,.W2 -999. 250 ** END OF' DATA GR. L,t.,; 2 -Q9Q.250 PO~E. [,w2 306.904 TAB.L~2 PSR. LW2 -c~99. 250 I)ER. bW2 -999. 250 G R. 1_,',~' 2 !.07.699 ~f]P~.i~w2 65.937 TAB.D~2 PSR.LW2 3.393 DER.bW2 3.172 GR./,~'~2 97.101 ~OPE.L~'~2 166 664 TAB.DW2 PS~.LW2 3.552 DER. !.,w2 3~391 GR.bW2 96.!14 P{]Pf2. L~2 260.869 TAB.LW2 FSR. LW2 5.150 I')ER. [.,,w2 4. q72 G~.LW2 94.556 ~OPE.LW2 318.719 TAB.Lw2 PSq.LW2 3.391 DEM.LW2 3.392 CR.LW2 !01 .g05 ROPE.LW2 272.557 TAB.L~2 PSR. L{';'2 3.600 DER.LW2 3.599 GR.LW2 91.576 ~OPE;. LW2 224.469 TAB.IJ~2 PSR.l, W2 3.3~2 DF, R. LW2 3.333 GR.L~2 93.240 ROP~.Lw2 312 841 TAB.LW2 ~,' 5 a. L 'w 2 3.529 [) E R. b W 2 3 [ 501 GR.LW2 90.159 ROPE.LW2 329.980 PSR. L;,~2 3.449 DER.DW2 3.441 (:;k. LW 2 103.709 ROPE.LW2 340 735 ~SR.'g~2 ' 3.3~0 DER.aW2 3.339 CB. !,,,W 2 92,726 POPE;, LW2 224 995 TAB.L~'2 P S ~. L f~ 2 3. ~.. 21. f) E.R. L W 2 3: 091 GR.LW2 93.440 ~OPE. I~W2 -999 250 TAB. 1.,~2 PSR.LW2 -999'250 DER.LW2 -999:250 -999.250 0.479 0.599 0.414 0.257 1.254 0.381 0.342 0.414 0. 278 0.22~ -999.250 **** FILE Tk A 1, !.,EP, FiL~ NA~,~E : FDI'I .003 ~ERV,ICE : FL,, I C VERSION : O0t, CO1 DATE : 9510311.3 a~X ~,:C 5IZF : !0~4 FILE TYPE : I..,C~ ['., A ST FILE : .IS ~aDe Verification [,..istlnz icblumberger AlasKa Co,,~;utino Center' .1. 3-t'~AP-1995 13:53 PAGE: I¸3 F'ILV N A .u, g : ~SFRV i CE : FbTC VERSION : o01C01 D~TF : 05/0 ~,'~X R~.(_" S~ZF~ : 1(32'i. FIbF TYPE : LO LAST FILE : FILF H E A OE'.R FILF N U~,JE:R 4 RAW M. WD Curves and log header data for each bit run i~ separate BTT RI.IN i"~II~RER: 3 DFPTM INCPEVEN'I': 0.5000 # FILE SUNM.ARY VENDOR TOO[, CODE STbRT PED'.[N CDR''''''' ........... 12T~;T[ .... bOG HEADER DATE LOGGED: SOFTWARE: SURFA~F, ~OFTW~RE VERSION I)OWNHOLE 80FTWARE V~RgI('}ht DATA TYPE (MEMORY or REAL-T.i.~,~E): 'ri) DRILLER (FT) TOP LOG IN'7'f]RVAL (FT): BOTTO~ bOG INTERVAL (FT): BIT ROTATING HOLE INCL, INATION (DE:C;) M!NIaUM ANGLE ~'~ A X I'. M U t,'{ ANGLE;: STOP £:~EPTH :.POOL STRING (TOP VENDOR TOO.[., CODE TOO[, TYPE CDR CO!~P Di,,IA,b RESISTIVITY' $ BOREHOLE AND C.h$IhiG DATA OPEN [,,,IDLE B'[I' ,S!ZE etD!): DR.IDI..,ERS CASING DEPTH MI,)D TYPE: MUD DENSITY M tJ D V ! $ C {.,~ $ M U () P N; ~, T..T D CHbORI'DES FAS'I' 2.5 P,. UE~ORY 1.:3570.0 7140.0 1,3545.0 90 53.3 6g,g T 0 (] I., N !,I M B g R 8 . 500 7133.0 L 8 N [) 43.0 files. ,IS Tape Verification Listinq ;cblun, berqer AlasKa Co,p;:,utins Center 13:53 PAGS: qOLE ¢:iJRRECTIC~!'.~ (!~,i~: 3.45O 66.0 64.0 # SANI)S'I'~E 2.65 8.500 T00!, STA,NO,.')FW (I~J): ~dR FRF~i'~U6HCY (~Z): 1,500 ****************** ~(;S ROu 1. & 2*************** oista~ce: f~it to CR: 75.93 ft, D~stamce: ~it to NdP: 68,68 it. Distance: bit ED Pes: o5,51 it. Drilled Interval 7150 - 74.9~ ft. DrilleO interval '7491 - 9925 ft. (R[!N 2) ****~************* R(;S RO~ 3 & 4*********'****** Distance: bit to G~: 66,42 Distance: ~.~it to RUP: 59,17 it, DJ. stance: Bit to Res: 56,00 ~t, [)ri].led Interval g925 - 1.2182 ft, (RUN 3) Dril. l~d Interval 1.21~2 - 12ggO ft, (RUN ****~*********%*** RGS RUN 5 D~.stance: Bit to GR: 59.0a ~t. Dlstamce: ~itt to ROP: b~,79 it,. Oistance: ~!t to ~es: 48,62 Drilled I~terva]. 128,q0 ~ ~2994 ft **************************~{IN 6 ****~************* Oistance: ~i~t to GR: 34.96 ~t, D~sta~ce: ~it to t.~OP: 27,71, it. O!stance: 61t to Pes: 24.54 Dri],ied Interval 12994- 13570 ~el] TD'd on ~-]2-95 at 01:00, AnGle ~t TD: 39,57 De~, ~ax. Dev.= 70,22 ~ 8689.5 $ bls FOR~:~AT DATA ,I~ ma~e Veri(!.cat. iom ListInq ;chl. Umberger AlasKa Con, p~ti.n(~ Center 13:53 PAGE: 15 6 73 9 ~5 FT 15 60 6~ 0 6~ 1 ** SET TYPE - CF4ANi ~D ('!A'DE~ ~ LOG TYPE CI.~5S ~OD NUNB SAMP ELEM CODE (HEX) DEPT FT . lr*18(i ()O OOu OO 0 4 1 68 000000 0 GP t,¥;3 (;.~ g I ~ 1 9I, f3C' O0 OOO O0 0 4 I I 4 68 0000000000 ROPE I:,'~3 FI~ 61ql~O 0() 000 O0 0 4 1 1 4 68 0000000000 TIB 1,~3 ~P 619180 0() 000 O0 0 4 ! I 4 68 0000000000 ATR LW3 OH~",~,~ 619180 O0 000 OO 0 4 1 1 4 b8 0000000000 PSR LW3 O~a~ 6191.~0 O0 ()00 O0 0 4 1 1 4 68 0000000000 OF~ L~3 [~[tg~ 61~1~o O0 000 O0 0 4 ! 1 4 68 0000000000 ** DgTh ** i') E P'r. 1 P 1 ~t 1..50 (,) G P,. L w 3 - 999.2 b 0 R C') P E. b W 3 2 O 08 ~ T A B. I., W 3 .... ,..~ " , ';' ~"~ LW3 -999~250 ~ '['P, I., W 3 - 9 ~ ~ z 5 O ~,, $ R. L W 3 . o 99.25 O b E, a.. DEPT 1200o OoO GP LW3 9B 309 P[:Pf:.hW3 22 Os9 TAB.LW3 ATP. I,W3 2.106 PSP.,I.,w 3 2. 008 DER' bw3 2: 0,43 b E p'r. 1175 (.). 000 C a. b W 3 132.271, R (':! P'~';. :b w 3 57.508 T.A B. L W 3 atp. [,W3 2. 095 PSk, hw3 2.6~9 DER. I~w3 2. 395 DE:PT, ll, bO0.O00 GR.LW3 1,25.865 RUPE.bW3 114 645 TAB.I,~3 ~, T P. [., W 3 3.5 ~ 2 P $ ~:{. l,, w 3 3.623 D E R. ~. W 3 3 ~ 588 [')FPT. 11250.000 (;R.LW3 68.777 ~OP.E. I~W3 70.868 TAB.LW3 ATP.LN3 3.226 Psa.bw3 2.~92 r~Ea.hw3 2.994 OEPT. I ! 000. 000 GE. Lw 3 100. 606 ~OP~;. bW3 9~. 356 TAB. I.,,~'3 .~ T P. I',, W 3 4.4, 20 P S ~'. [,, w .3 6. O 6 I. D E a. L, ~,~ 3 5.620 -999.250 1.296 1..156 1.188 0.578 0.676 Tame Verif.tcatJon l,i. st. ino chlumberger Alaska Coml:utinq Center 13-~AP-1.905 13:53 PAGE: 16 D~'PT. 10750. 000 G~. I.,~~ 3 A TI~. [.,%~; 3 2.71 $ PSR. L,~:3 [3FPT. 1 ('i) 500.00{~ CF:. LI'43 A'F~. LW 3 2 · 853 PSR. L~,~ 3 DFPT. 10250.0O0 GR. I.:~'~ 3 ~TP. [,W.3 3. ] 63 P$~. LI,q3 D ? P T. .10000.0 C u G R. L. I,.: 3 DFpT. 9837. o00 GR. h~; 3 /~ TP. [,~ 3 -999. 250 PSR. L,t" 3 !22.10g P(.JPE. Lw 3 3.2¢~4 i)ER. Lw3 98.760 3.J45 DER.LW3 1{)6.541 ~OPE,LW3 3. 357 D~.F. L~3 1.08.74~ 134.339 3.019 ]49.99~ 3.02~ 144.000 3.284 73.469 ?.920 jU7.2u0 ~OPE.LW3 -999.~50 -Q90.250 DER.LW3 -999.250 T~B.[,~3 TAS.LW3 TAB.I, w3 'rAg. LW 3 TA8.[.,~3 1.196 0.368 0.48b 1.0!5 -999.250 F'IL~ ~,iA~IE; : EDIT .on4 SERVICE : FLIC VFRSIO~ : O0!COl D.a, TE : 95/03/13 ~.~X RF~C SIZE : 1024. FTLF TYPE : LO I,,, ~ ST FILE : **** FILE N A ~E'; SERVICE V g R 810 0,~ T ~' ~: a X R E C F'I LE: T Y LAST 5 header data 4 o. 5000 for each bit run .In separate $'['~RT DEPTH $ ~l:' 0 P b E P T H files. Verification l,,,ist ina ;chlumberger AlasKs Compotinq center 13-mAP-1995 13:53 PAGE: 7 LOG HFAD~.)P DATK [,r!GGED: $(')F'['W ARE: SU~WACE DATA TYP~ ( TOP LOG BiT WCTATIN NOLF' INC?,IN TOOL STP mmmmmm C [) R BO~EHOLE AND C OPEN HOL~: MUD TY~E NUD DENSITY MUD ~ISCOSI CIiLORID FLU ID LOSS RESISTIVIT M U N E!..ITRDN M A T R I ~ATRIX T 0 ~F~M~RKS: lNG ('r()P Tf; BO'FTO~) TOOL CODE I00I., TYPE Ct)MP DU/~.L, RESISTIVITY' 13-JA,W-95 13570.0 7140.0 13545.n 7~ 42,2 57,3 TO0!~ N[]4~:~ER t,) i,, s Ois Dis Ori Dr i **.,, i) i, s TT SIZE (IN): CASING D~PT}4 (LSlG): TY (S): (FT): 8.500 7133.o LSNI) 1.1.50 45,0 560 ,470 000 SANDSTONE '[TY: 2.65 TION (I~',i): 8.500 73.0 82,0 0.0 ~.! [) 0 F ~," ( I t,,! ): I. 500 U E ?',! C Y ( i.t Z ): *************** RGS Pt,.i~l 1 g 2*************** tance: l~,~,it to GR,, 75,93 ft, ta.ce: 8it to ~Op: 68,68 ft. tance: ~sit to Pes: 65.5! lied Interval. 7150 - '1.491. ft., (RUN 1) ll.e'J Interval 7.4~1 - 9925 it, (~f.!N 2) **"************* RGS [~(..iN 3 & 4**************,* tance: ~3it to Gl:{: 66.42 ft. ,IS Ta~e v~r!~i, catio,~ L, istint~ ,chlumMerger alaska Computin~ Center 13:53 PAGE: 18 Distance: 6it 50 ROD: 59,17 f-t. Drilled IDterva! q9~5 - 1~182 It. (RUN 3) Drilleo interval 1218~ ~ 12~40 ft (RUN 4) O~staDce: ~t 5o GR: 59.04 ft. D~StaDce: 3it to R~]P: 5~..79 f:t:. Oistance: r$i5 to ~es: ~8.62 tr. Drilled IDterval ~.2S40 - 1~994 ft. D~stance: ~t to GR: 34 96 ft. Distance: D~.St~nce: ~it to ~es: 24.54 iff. Drilled [Dterval ~2q94- 13570 ~t. ,,~ell TD'd on !-12-95 at 01:60. Anqle at I'[): 39.57 De~. ~ax. bev.= 70.22 fa 8689.5 S l'.~,.~S F'OR)~.~T DATA ** DATA FnR,"4AT SP~CIFICATI!3f',t P'ECOPD ** ,,;7 ............. '"'"'"'"'"'""" E ~ (., ..4. r~ U ~ 15 $ ..t Z k,, R E P R p Ii) ORDER ~ LOG ";{~YPE Cl.,ASS MOD ~,ll,j~f:~ SAMP EL, EM CODE D E P T ~";!' 6 10 1 8 0 0 0 0 0 0 0 0 0 5 1. 1 4 6 8 0 0 0 0 0 0 0 0 0 0 G~ Lw4 GAPI 6:1,91 ~0 O0 000 O0 0 5 1 1 4 68 0000000000 ROPE bw,4 F/HR 619180 O0 000 ('}0 0 5 !, I 4 68 0000000000 I$ '~'a.oe VerlflcatioD bisttnc~ 13-.~AP-1995 1.3:53 chlumberqer A]..~ska Comput!.r)a Center AGE: 1.9 i,.~A ..... U ,IT ,~i~;ICV ~PI ~PI APl P It.,L k,h;M~ NUMB SiZE REPR PROC~;SS IO ~DY~ ~ [..,P'~; TYPE CL~S ~OD ~ S~:,~P ELE~'~ CODE (HEX) I III I II IIII~IIIIIIIIII III iIIIliitiI i t iIIiIII iI~liiiIiI iliiiI iiiiiiiliiIiiiliiIIIiiiiIii T~ L~4 ~ 6191~c O0 000 O0 0 5 1 I 4 6~ 0000000000 ATN LW4 0 H ,v~ ,~ 6191~(, O0 000 O0 0 5 1 t 4 68 0000000000 PSR Lw4 O R ~: ~ 6191~0 00 O0O 0() 0 5 1 I 4 6~ 0000000000 DFR 1., ;~ 4 O ~ Y~ ~.~ 6191a0 O0 O00 06 0 5 1 1 4 68 0000000000 pEPT. 12839.500 Ga. I.,W4 -gg¢.2b0 ROPE. b;~;4 33.457 TAB.I.,~4 ATP. I,,w4 -999.250 PSR. 1,,~;4 -999.250 DF, R. !.,w~ -999.250 DEPT. 12750.000 C; R. I..~b; 4 118.845 ~OP~.LW4 78.946 TAB.L~4 ATP. 1.,~,}4 l. 4:~, 2 PSR. t,,~;q 1. 490 DER. I.,w4 1. 487 DEPT. 19500.000 GR. LW.4 1~3.719 ROP:6.:. bW4 156.518 TAB.LW4 aT~.L~4 2,95-1 PS ~, . t~t,,,' 4 3.233 I;'ER. 6~4 3.124 DFPT, 12250,000 ~';'. . . ,,. . t.,~, LW4 !06 4:32 ~0P~; L,;~4 !04 653 TAB [.:W4 aTP. 1,.,;~ 4 1.891 PSR. LW~ 2. 303 DE~. L;,~4 2. ! 06 - · o g ''~ . o . I ,.. ~. o o D~PW. 12000 0(;0 ~,.~ L~Y4 105 513 RGPE LW4 090 250 TAB AT~. T,,¥~ 4 2.223 PSR.LW4 2.188 DER. I,,'~ ~ 2.201 DEPT. 11976,500 GR. [,,w4 94.~48 ROP~,;. b;~ 4 999 250 .~TP. L'N4 -999.250 PSP,. I~i~ 4 -~99.250 DER./,~4 ~99g:250 **: EI~;D OF DATA ** -999.250 0.885 1.076 0.465 -999.250 '999.250 **** FILE TR.A ILER **** FILE N.At~E ,' EDIT ,005 SERVI, CE : F,bIC VERSION : 001C01 D,ATF : 95/03/13 ;~,',~.X REC SIZE : !024 F'lbv q"ypE ~ L **** FILE SERVICE NIX R[;:C SIZE FI'LF TYPE LAST FILE: HEADER **** : EDJT ,006 : rblC : 00lC01 : 95/U3/1 3 : !, 02,4 : 1,, 0 : .IS ']'ape Verfficst. io~ !..istJr'~g .cblumberger AlasKa ComputJna center 13-~-,AR-1995 13:53 PAGE: 2O Curves and lo9 header dsta for each hit run in separate BIT RUN ~!U~'.~ER; 5 VENbDR T.D(]!_, COPE START DEPTE ~KADER DATA DAT~: LOGGED: SUFTWARE: Bn~'~ObF SOFTWARE ~]RSiON: DATA 'l'YPE (~V~,~OkY iL) bRI!,bER (FT): TOP [,OG INTERVAL (FT): P[)T3>~:,t I,.,[]G INTERVAL ( BIT ROTATING HOLE IUCLI~AT!ON aAX I Nll~,,~ ANGLE: S T [1 P L! F: !-' T ! i 1272 .. S'.r F~ I N G (mOP T 0 0 l,., C O D ...... , ..... AND CAS!t~i(; Pt~.TA OI, g [?,1! 8!ZF (I~,,~): C[,]N DI TIONS VISCOSITY (8): b (! R I !,,) E ~3 ( LOSS (C3): P~AXIaI,!a RECORDED TE~':PERATUF;E (DEC;F) ~4A~:RIX: fiORRECTiO!"; ( 1.3-jAN-95 1.3570.0 7~40.e 1.3545.0 42.2 44.3 022 8,50 () 7133.0 I,.~SND 1!.50 1.610 0.0 0 0 '$ A N D 2.65 8. 500 files. 75.0 73.0 !S 'rave YerI. ficat, i. on I,j. st.~..nc] 13-~,)AR-1995 .[.~:53 chlumherc..,er AlasKa Co~put.J. no Center 21 T£)r~b S]'A,Hi)[~FV (I.q]: l .500 ****************** R(;~ PUN ,1 l)ista~ce: !'!,i.t ~o (;R: 75,93 Distance: ~iE t.o ~'OP: 6~,68 Oistar. ce: ~it to Res: 65,~1 it, Dril. led ].interval 71~0- 749~ ft, (RUN 1) Drilled 'I~terval ~49~ - ~925 ft., {RUL 2) Oi. st. ar, ce: ~it. to CR: 66.42 ft. Dist{~nce: bit to P{]P: 59.17 Distance: bit to Fes: 56,0o Orilled IDterval 9925 - 121B2 Ori]l~d ipterval ~2~.~2 - 12~40 Distance: ~..~i.t to GN: 59.04 {t. Oistance: [Itt ~o RgP: 5~..79 OjstanC~: bit to 'Res: 48,62 it. Drilled Interval ~2~40 ~ 12994 Distance: }~It to (;R: 34.96 Distance: ~tt Eo ROP: 27,71 [')istance: bit to Res: 24,54 Drilled Interval. 12994' 13570 ft. .An~]le at. TD: 39.57 De~. }!ax. Dev.= 70.22 ia S689.5 LIS FOR~!.AT DATA ** [')ATA }.:'ORa.AT SPgC].FIL .... ,.'z(',llq RECURL.'i ** IS Taoe Ver~.f.~csti. on l',istinq CblUmberqer A1MSI<~ Comput,~nq Center PAGE: 22 , mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm.mmmmmmm., . 6 1 I 4 68 GO00000000 6 1 1 4 68 0000000000 6 1 I 4 68 0000000000 6 1 l 4 68 0000000000 6 1 1 4 68 0000000000 6 l 1 4 68 O000OO0000 6 1, 1 4: 68 0000000000 m~mmmmmmmmmmmmmmmmmmmmmmmm#mMmmmmmmmmmmmmmmmmmmmmmm~mmmm ** E!~![) (IF DATA ** -99q 250 Pt)PE.6W5 18 405 TAB.I..,W5 -O9~: 250 [)ER, 1.,,:W5 -999: 250 1, 28.017 ~ (') P E. b ',,q 5 - 99 9.250 T A ~. L ~ 5 I. 5~g bF, R. bW5 1.5,32 11V,6,30 R[,iPE, bW5 =999,250 -999.250 [)ER:. Lw5 -999.250 -999.250 -999.250 -999.250 **** FILE FILE 8ERr ICE DATE MAX REC F 1 i,, E "r Y P I,, ~,$'r TRh I!,,,EP **** EDIT .006 FI,,, I C 001C01 1.024 L U ,I.a 7'ape veriflcatlon {,istinq ChlUmbergor Al. asEa Co,nputino Center 13-~qP-1995 13:33 PAGE: 23 Curves and loq header ,~ata ~or each bit run in separate DFpTH I NC P'.g.N ENT: 0o5000 FILF SU~,~ A RY VEN/)I2}R T~C][, C{30F', START C t) !..~ 5 6 q. 5 bOG H'~]ADER DATA r~ATE bOGGED: 8{,.INFACg 80~T~AI'{E VERSIL.IN~ DATA TYPE (~iE~,:~OR.Y or }'iEAL-TIt,~E;): TD DRILLER (FT} TOP ,[,,OG TNTERVAb BOTTO~ LOG INTERVAL BIT ROTATING S'.!'O P DEPTH TOOt., STRING {TOP CDR C[]~v~P [')UAl.., RESISTIVITY S OPF~M F']Ol,~] BIT 8.'[Z~7 DR!bT~;~.8 CASI~<iG I.}EPTN fFT)~ BOPEHOI, E COt, iD!TI06~$ ~4 t.,l D TYPE: .~!UI,) DENSITY (Lf~/G) !, 3-dAN-95 !~'AST 2.5B 13570.0 7140.0 13545.0 9~ 39.6 44.7 ~G8 22 8,500 7133.0 !58 bi D 1, 1.50 44.0 files. Tare Ver].fIcation [.,istinq ~chlumberc~er ~].asKa Com~:utinq Center 13:53 1.b40 1.fllO 0,000 '15.0 73. O 0.0 STANDOFF (IN]: F'RF(~UeNCY (?,Z): ~,500 1 · 50{; ****************** ~GS [~U,~,~ 1 & 2*************** Olstance: [.'.4it to C~: 75 9.~ Distance: }3it to RtJP~ Q~. 68 Distance: bit t.o Rest 65,51 Drilled Interval. 7150 - 749~. ft, Orilled Interval. 74qJ - 9925 ft, (RUN 2) ****************** RGS Rb~'~ 3 & 4*************** Distance: B~t to GN: 66,42 D~.Sta¢ce: [gJ.t to ROP: 59,17 ft, Oistance: ~;it to Res: 56,00 Ori]leO Interval. 9925 - 12192 ft., .[)rille~ Interval 12182 - 12840 ft, B.~.star, ce: B~t to (;R: 59 04 ft. Distance: [~t to ~{]P: 5{,79 ft, ~.stance: Bit to Res: 48,62 OrilleO. Interval ~2840 - 12994 ********************** PGS ~t.]N' 6 ****************** D.~stance: Bit to Gk: 34.96 ft, o~stance: t~It:, to pop: 27.71 Drilled Interval 12994 - 1.3570 ,~ell TD'd on 1-~..2-95 at 01100. An~l..e at TP: 39.57 De,. ~ax. Dev.= 7O.22 ~ 8689.5 T A PAGE: 4 SET TYPE' - 64E;¢ ** 7'¥Pg REPR CODE ,[ 6 6 2 66 ,IS Tape vert. flcat~on ~,]!$t.~n~ ;CblUmberger R].asKa C. om~,utir,,q Center ].3-~'~AP,-!995 13:53 PAGE: 25 mmmmmm m mm mmmmm mm~m~m TYPE ~FipR C[)t)E v 3 73 2 4 66 5 66 0 73 7 65 9 65 Fl 11 66 30 17 15 66 6~ !6 6~ 0 66 ',i A ~ ~ S ltl R v U ,', ,I, T SERIC;gAP'v . ID ORD!!;R # bO OKPq' FT 619180 O0 GR LW6 GAPT 6101~0 oo Rr.'lpF', LW6 F/HR 619180 O0 T~B I, W6 HR 619180 00 ATR [,W6 0 H >~ ~' 619180 O0 ,PSR LW6 OHMM 6191~0 00 D~R L~6 OHT~ Y~ 619180 O0 00 0 7 1 1 4 68 0000000000 00 0 7 I 1 4 68 0000000000 00 0 7 .1. 1. 4 68 0000000000 O0 0 7 1 1 4 6@ 0000000000 O0 0 7 1 I 4 68 0000()00000 O0 0 7 1 1 4 68 0000000000 O0 0 7 1 1 4 68 O0000000OO ** D~TA ** D K P'l'. I 3569.50 0 G R. L, W 6 A. TR. L~'! 6 -999.25(i) PSR, DF, PT. i 3500. 000 GR. LW6 ~T~, !,.,~6 2. 895 PSR,.bW6 D E P T. I 3250.000 G R. 1:,, ~ 6 ATP. b[~6 4.9 16 PSR. L'~6 DFPT. 13000.00;) GR.LW6 ~TP.I,,W6 2.811 PS:R.LW6 ATP. LW 6 -999,250 PSR., LW6 -999.250 ROPE. bt~!6 19. ! 08 TAB,LW6 -999.250 DER.LW6 -999.250 95.3~1 PC)Pg. LW6 16.739 2.890 [,)E]R. LW6 2.892 76.231, P 0 P ~;, b W 6 3,4 951 T A. B. I,., ~ 6 98.4~5 R[:)P~, LW 6 20.753 TA, B.LW6 2.624 D~R.bW6 2.6~6 ~20.528 R[')PE. L~6 -999.250 TAB.LW6 '999.250 DE,R. bW6 -999.250 -999.250 t.450 0.807 1.61.4 -999.250 ** E;ND t,}F~ DATA ** 'rape Veriflcatiop~ l.,istinq cblumberc]er AlasKa Com~Jt,~tlnq Center 13:53 PAGE: 26 5FR~ IC~] : WL!C VFRS ] 0:'~ : 00]C01. DATF : 95/0]/13 .vAx~ REC SIZe. : ~ 024
