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Home My WebLink About207-107 TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard Drive data drop 1H-111 50-029-23581-00 217133_1H-111_IPROFWFL_03JUL2023 1H-114 50-029-23584-00 217136_1H-114_IPROF_17Oct23 1H-115 50-029-23605-00 218053_1H-115_IPROF RSTWFL_09May2022 1H-116 50-029-23594-00 218012_1H-116_IPROFWFL_05Jul2023 1H-117 50-029-23602-00 218032_1H-117_PPROF-WFL_06July23 218032_1H-117_WFL_18Oct23 1H-119 50-029-23591-00 217178_1H-119_WFL_07Jul2023 1J-102 50-029-23317-00 206110_1J-102_RPPG_18Jul2023 1J-107 50-029-23366-00 207107_1J-107_PPROF_10May2022 1J-162 50-029-23360-00 207080_1J-162_LDL_03May2022 1J-170 50-029-23310-00 206062_1J-170_Temp-Pres_11Jul2023 1J-176 50-029-23364-00 207099_1J-176_LDL_11May2022 4of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38340 T38341 T38342 T38344 T38343 T38345 T38346 T38347 T38348 T38349 T38350 2/29/2024 1J-107 50-029-23366-00 207107_1J-107_PPROF_10May2022 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:34:11 -09'00' Originated: Delivered to:29ͲNovͲ23 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & PerforatingAttn.:Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska99501 Anchorage, Alaska 99518 Office: 907Ͳ275Ͳ2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concernstotheattention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # 11CͲ22 50Ͳ029Ͳ23127Ͳ00 908965028 Kuparuk River Multi Finger Caliper Field & Processed 20ͲNovͲ23 0 1 21DͲ38 50Ͳ029Ͳ22961Ͳ00 908965029 Kuparuk River Multi Finger Caliper Field & Processed 21ͲNovͲ23 0 1 31JͲ107 50Ͳ029Ͳ23366Ͳ00 n/a Kuparuk River Packer Setting Record FieldͲFinal 9ͲOctͲ23 0 1 41LͲ03A 50Ͳ029Ͳ21182Ͳ01 908347301 Kuparuk River Multi Finger Caliper Field & Processed 7ͲJanͲ23 0 1 52LͲ313 50Ͳ103Ͳ20277Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 26ͲNovͲ23 0 1 62MͲ24 50Ͳ103Ͳ20171Ͳ00 n/a Kuparuk River Patch Setting Record FieldͲFinal 21ͲDecͲ22 0 1 72PͲ415A 50Ͳ103Ͳ20383Ͳ01 n/a Kuparuk River Plug Setting Record FieldͲFinal 7ͲOctͲ23 0 1 82PͲ417 50Ͳ103Ͳ20375Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 6ͲOctͲ23 0 1 92PͲ420 50Ͳ103Ͳ20391Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 5ͲOctͲ23 0 1 10 2VͲ05 50Ͳ029Ͳ21051Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 19ͲJulͲ23 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 1. 1C-22 PTD:202-222 T38179 2.1D-38 PTD: 200-077 T38180 3. 1J-107 PTD: 207-107 T38181 4. 1L-03A PTD: 199-037 T38182 5. 2L-313 PTD: 198-219 T38183 6. 2M-24 PTD: 192-050 T38184 7. 2P-415A PTD: 201-226 T38185 8. 2P-417 PTD: 201-069 T38186 9. 2P-420 PTD: 201-182 T38187 10. 2V-05 PTD: 183-176 T38188 12/1/2023 31JͲ107 50Ͳ029Ͳ23366Ͳ00 n/a Kuparuk River Packer Setting Record FieldͲFinal 9ͲOctͲ23 0 1 Kayla Junke Digitally signed by Kayla Junke Date: 2023.12.01 12:25:47 -09'00' C:\Users\mdguhl\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\OLDB5O34\2022-02-01_22522_KRU_1J-107_LeakDetectLog_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 22522 KRU 1J-107 50-029-23366-00 Leak Detect Log 01-Feb-23 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 7:12 am, Feb 13, 2023 207-107 T37497 Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.02.13 07:12:46 -09'00' 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: Scab Liner 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 12073 feet None feet true vertical 3656 feet None feet Effective Depth measured 12073 feet 7973', 8169'feet true vertical 3656 feet 3646', 3669' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 7980' MD 3647' TVD Packers and SSSV (type, measured and true vertical depth) 7973' MD 8169' MD N/A 3646' TVD 3669' 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: 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: 3468' 2275' Burst Collapse B Liner Scab Liner (solid/ screens) 8696' 3622' 3603' Casing 3717' 3661' 2-3/8" 8721' 11792' 11792' 3661' 3437' 108'Conductor Surface Intermediate 20" 13-3/8" 77' measured TVD 9-5/8" 5-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 207-107 50-029-23366-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL25661, ADL25662 Kuparuk River Field/ West Sak Oil Pool KRU 1J-107 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 108' ~ ~~ Well remains Shut-In ~~ ~ 322-700 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: LEM TorqueMaster Packer Packer: Baker ML ZXP Liner Top Packer SSSV: None Elliott Tuttle elliott.tuttle@conocophillips.com (907) 263-4742Senior RWO/CTD Engineer 9778-11712' Slotted Liner 3663-3660' Slotted Liner Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Meredith Guhl at 8:23 am, Feb 03, 2023 Digitally signed by Elliott Tuttle DN: C=US, OU=CTD/ RWO Drilling Engineer, O=" Conoco Phillips, Inc", CN=Elliott Tuttle, E=elliott.tuttle@ conocophillips.com Reason: I am approving this document Location: Date: 2023.02.02 15:03:38-09'00' Foxit PDF Editor Version: 12.0.1 Elliott Tuttle Page 1/8 1J-107 Report Printed: 2/1/2023 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) 12/30/2022 06:00 12/30/2022 11:30 5.50 MIRU, MOVE RURD P Rig move checklists and prep for move 0.0 0.0 12/30/2022 11:30 12/30/2022 14:00 2.50 MIRU, MOVE RURD T Trucks on location @ 11:30 , still working on rig down checklists 0.0 0.0 12/30/2022 14:00 12/30/2022 14:30 0.50 MIRU, MOVE SFTY P PJSM moving rig 0.0 0.0 12/30/2022 14:30 12/30/2022 16:12 1.70 MIRU, MOVE DMOB P Jack up pits, Pull mats, Pull pits forward / Stage on pad 0.0 0.0 12/30/2022 16:12 12/30/2022 17:42 1.50 MIRU, MOVE DMOB P Jack up sub. Pull mats. Pull off well. Stage on pad 0.0 0.0 12/30/2022 17:42 12/30/2022 18:42 1.00 MIRU, MOVE DMOB P Install Jeeps on modules. Rig down cellar containment 0.0 0.0 12/30/2022 18:42 12/30/2022 21:00 2.30 MIRU, MOVE MOB P Leave DS 1E bound for 1J. Security holds us up momentarily for departing aircraft 0.0 0.0 12/30/2022 21:00 12/30/2022 22:30 1.50 MIRU, MOVE MOB P Crew change out at 1 D pad, Continue to 1J 0.0 0.0 12/30/2022 22:30 12/31/2022 00:00 1.50 MIRU, MOVE P On 1J, Pull Jeeps foof modules. Status well. R/U cellar containment 0.0 12/31/2022 00:00 12/31/2022 01:30 1.50 MIRU, MOVE MOB P Continie setting mats spotting modules 0.0 0.0 12/31/2022 01:30 12/31/2022 05:30 4.00 MIRU, MOVE RURD P Safe out rig / Stairs landings, and emergency exits. Rig up PUTZ, Get steam around rig. 0.0 0.0 12/31/2022 05:30 12/31/2022 06:00 0.50 MIRU, MOVE SFTY P PJSM Reel Swap 0.0 0.0 12/31/2022 06:00 12/31/2022 08:00 2.00 SLOT, WELLPR CTOP P Swap 2-3/8" reel for 2-5/8" reel 0.0 0.0 12/31/2022 08:00 12/31/2022 10:00 2.00 SLOT, WELLPR CTOP P Secure reel , shim hubs, torque down saddle clamps 0.0 0.0 12/31/2022 10:00 12/31/2022 12:00 2.00 SLOT, WELLPR NUND P Nipple up bops and change out riser 0.0 0.0 12/31/2022 12:00 12/31/2022 18:00 6.00 SLOT, WELLPR CTOP P Change out horse head rollers, remove stripper and replace brass w/ 2.625" brass, pull gripper blocks, 0.0 0.0 12/31/2022 18:00 1/1/2023 00:00 6.00 SLOT, WELLPR CTOP P Reconfigure CTES counter for 2 5/8" CT. Install stripper on injector. Change out guide arch roller for 2 5/8" CT. Chain and secure inner reel iron. 0.0 0.0 1/1/2023 00:00 1/1/2023 02:30 2.50 SLOT, WELLPR CTOP P Get CT in correct position / orientation to stab CT. Remove banding and shipping cover off reel. 0.0 0.0 1/1/2023 02:30 1/1/2023 03:00 0.50 SLOT, WELLPR SFTY P Review CT stabbing procedure, Discuss additiional hazards with larger coil. 0.0 0.0 1/1/2023 03:00 1/1/2023 06:00 3.00 SLOT, WELLPR CTOP P Stab CT Into injector // rig down stabbing equipment 0.0 0.0 1/1/2023 06:00 1/1/2023 10:30 4.50 SLOT, WELLPR CTOP P Install coil tubing connector // ream out coil 0.0 0.0 1/1/2023 10:30 1/1/2023 12:30 2.00 SLOT, WELLPR CTOP P Baker install upper quick and pressure test // check cont. good test 0.0 0.0 1/1/2023 12:30 1/1/2023 13:30 1.00 SLOT, WELLPR CTOP P Flood reel with water // pressure test upper quick and coil connector to 4,000psi no leaks bleed off good test // 0.0 0.0 1/1/2023 13:30 1/1/2023 15:00 1.50 MIRU, WHDBOP CIRC P Flood up BOPs and surface lines // Valve checklist for BOP test // Grease up valves on stack and for BOP test 0.0 0.0 1/1/2023 15:00 1/2/2023 00:00 9.00 MIRU, WHDBOP BOPE P Test BOPs , Witness waived AOGCC Adam Earl 250 / 2500 all rams and annular 0.0 0.0 1/2/2023 00:00 1/2/2023 01:00 1.00 MIRU, WHDBOP BOPE P Continue with full BOPE test. Witness waived by Adam Earl AOGCC 0.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 1/9/2023 Page 2/8 1J-107 Report Printed: 2/1/2023 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) 1/2/2023 01:00 1/2/2023 02:00 1.00 MIRU, WHDBOP BOPE P Pull test joint, Skid injector to floor. Make up riser. stab on injector. Test packing, Inner reel iron, and pressure bulkhead, TT Line End of test Fail / Pass on R-3, B-06 On test 7 segment of test joint was marred. Replace segment on joint. Retest good 0.0 0.0 1/2/2023 02:00 1/2/2023 04:00 2.00 MIRU, WHDBOP RGRP T Swab two was a fail, Try serviceing it and retest. Get good test 0.0 0.0 1/2/2023 04:00 1/2/2023 06:00 2.00 MIRU, WHDBOP CIRC P Install floats in UQCMake up Nozzle, circulate fresh water out of coil // Pump 3 bbls per min pump wire forward // 0.0 0.0 1/2/2023 06:00 1/2/2023 07:15 1.25 PROD1, RPEQPT KLWL P Open well under swab 2 well on a vac // Pump 128 bbls 8.6ppg filtered seawater to L1 Lateral entry module diverter @ 3 bbl/min @ 0 psi into well, was never able to catch fluid // Fluid volume 200' / min pump rate 0.0 0.0 1/2/2023 07:15 1/2/2023 08:00 0.75 PROD1, RPEQPT PULD P Flow check well for 30min // build BHA# 1 tag assembly // no pressure build pump 20 more bbls @ 5 bpm 0.0 0.0 1/2/2023 08:00 1/2/2023 08:30 0.50 PROD1, RPEQPT PULD P Put bha in hole and cart on well // Total BHA length 34.74' // Nozzle open ended 0.0 0.0 1/2/2023 08:30 1/2/2023 09:18 0.80 PROD1, RPEQPT TRIP P Tag up set depth tracking equipment // RIH w/ BHA# 1 tag assembly // Adjust gooseneck for 2.625" pipe 0.0 250.0 1/2/2023 09:18 1/2/2023 09:30 0.20 PROD1, RPEQPT TRIP T Lost coms with tools 200' from surface // POOH 250.0 0.0 1/2/2023 09:30 1/2/2023 09:36 0.10 PROD1, RPEQPT CTOP T Flow check well // PJSM testing tools // 0.0 0.0 1/2/2023 09:36 1/2/2023 17:36 8.00 PROD1, RPEQPT CTOP T Remove cart and troubleshoot BHA // While troubleshooting e-line well build 50psi pump second tubing volume 5 bpm @ 90psi pump pressure shut down monitor pressure // Found short in wire in upper quick 0.0 0.0 1/2/2023 17:36 1/2/2023 20:36 3.00 PROD1, RPEQPT CTOP T Cut coil to find good wire and install coil tubing connector // Pull test to 50K good test 0.0 0.0 1/2/2023 20:36 1/2/2023 22:06 1.50 PROD1, RPEQPT CTOP T Install Baker Upper Quick 0.0 0.0 1/2/2023 22:06 1/2/2023 22:42 0.60 PROD1, RPEQPT PULD T Pick up BHA# 2 nozzle run // No coms on the tools 30.0 30.0 1/2/2023 22:42 1/2/2023 23:06 0.40 PROD1, RPEQPT PULD T Take tool out of hole to test connections 30.0 0.0 1/2/2023 23:06 1/3/2023 00:00 0.90 PROD1, RPEQPT PULD T Swap out BHA 0.0 1/3/2023 00:00 1/3/2023 00:18 0.30 PROD1, RPEQPT PULD P M/U Injector to BHA #3, Surfacew test tool - Good. Tag up and set counters 0.0 34.7 1/3/2023 00:18 1/3/2023 01:18 1.00 PROD1, RPEQPT TRIP P RIH BHA #3. At 350' PUH checking pipe for any marks from gripper blocks. Continue in hole 34.7 1,178.0 1/3/2023 01:18 1/3/2023 01:30 0.20 PROD1, RPEQPT TRIP P Stop to inspect saddle clamps. Lost comms with tool 1,178.0 1,178.0 1/3/2023 01:30 1/3/2023 02:06 0.60 PROD1, RPEQPT TRIP T POOH to investigate comm issues 1,178.0 40.0 1/3/2023 02:06 1/3/2023 02:36 0.50 PROD1, RPEQPT PULD T At surface, Well on vac. Unstab Injector. Test wire. Indicates short. Pull flow sub from UQC. Wire there. Still no test. Pull BHA. Send down to shed. Bench test tool good. Go back to wire on rig floor 40.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 1/9/2023 Page 3/8 1J-107 Report Printed: 2/1/2023 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) 1/3/2023 02:36 1/3/2023 04:42 2.10 PROD1, RPEQPT CTOP T Cut off connector. Trim E-Line. Install boot. Stab back on well. Line up and reverse circulate CT. Hear wiire move first ramp up. 0.0 0.0 1/3/2023 04:42 1/3/2023 05:00 0.30 PROD1, RPEQPT CTOP T Unstab, Cut off CTC. Start cutting CT to find wire, 16' to find wire. Cut total of 25' 0.0 0.0 1/3/2023 05:00 1/3/2023 09:18 4.30 PROD1, RPEQPT CTOP T Trouble shoot E-line. Pull pressure bulkhead apart. Meg all 7 wires. Looks like we have correct configuration 0.0 0.0 1/3/2023 09:18 1/3/2023 13:18 4.00 PROD1, RPEQPT CTOP T Prep CT for CTC. Install CTC, Pull test CTC to 50K 0.0 0.0 1/3/2023 13:18 1/3/2023 14:54 1.60 PROD1, RPEQPT CTOP T Test wires, Head up e-line to UQC 0.0 0.0 1/3/2023 14:54 1/3/2023 16:06 1.20 PROD1, RPEQPT CTOP T PT CTC, Pressure bulkhead. Is leaking in inner real. LOTO reel. fix leak. Got leak repaired. Re pressure test bulkhead - Good 0.0 0.0 1/3/2023 16:06 1/3/2023 17:06 1.00 PROD1, RPEQPT CTOP T Stab on well. Circulate CT @ 3 BPM post slack mgmt 0.0 0.0 1/3/2023 17:06 1/3/2023 19:06 2.00 PROD1, RPEQPT CTOP T Test e-line, bad test., troubleshoot e- line, confer with team, agree to cut off bulkhead and re-install. Call out CDR2 electrician to assist. 0.0 0.0 1/3/2023 19:06 1/3/2023 21:06 2.00 PROD1, RPEQPT CTOP T Break off inner reel bulkhead and iron, re-dress bulkhead and replace 1502 rubbers 0.0 0.0 1/3/2023 21:06 1/3/2023 23:06 2.00 PROD1, RPEQPT CTOP T Install re-dressed bulkhead, test e-line, (good test). 0.0 0.0 1/3/2023 23:06 1/4/2023 00:00 0.90 PROD1, RPEQPT CTOP T Head up BHI Upper Quick, test e-line, (good test) 0.0 0.0 1/4/2023 00:00 1/4/2023 00:45 0.75 PROD1, RPEQPT CTOP T Test e-line (good test), PT re-head, high pressure bulkhead, and flowsub. 0.0 0.0 1/4/2023 00:45 1/4/2023 01:21 0.60 PROD1, RPEQPT PULD P MU Cleanout/Drift assembly BHA #4, surface test tools (good test), tag up & re-set counters, 0.0 34.7 1/4/2023 01:21 1/4/2023 03:21 2.00 PROD1, RPEQPT TRIP P RIH Weight Check @ 2,732' PUW 16k CTSW 34.7 7,900.0 1/4/2023 03:21 1/4/2023 03:39 0.30 PROD1, RPEQPT TRIP P PUW 35 k CTSW, continue IH to 8,300' to confirm clean before switching tools to CCL mode. 7,900.0 8,300.0 1/4/2023 03:39 1/4/2023 03:57 0.30 PROD1, RPEQPT TRIP P PUH to logging depth, switch over to logging mode 8,300.0 7,900.0 1/4/2023 03:57 1/4/2023 04:33 0.60 PROD1, RPEQPT DLOG P Log CCL, correct depth to log - 10' 7,900.0 8,300.0 1/4/2023 04:33 1/4/2023 05:42 1.15 PROD1, RPEQPT TRIP P Continue IH 9,300' 40k CTSW 10,300' 44k CTSW' 11315 44K PUW 11902 set down 8,300.0 11,904.0 1/4/2023 05:42 1/4/2023 06:00 0.30 PROD1, RPEQPT TRIP P PUH at increase pump rate, PUW=60K 11,904.0 11,000.0 1/4/2023 06:00 1/4/2023 06:54 0.90 PROD1, RPEQPT TRIP P RBIH Start taking 25' bites from 11904. Did have to jet through this area then fairly clean to 12,015'. Low on coil 11,000.0 12,015.0 1/4/2023 06:54 1/4/2023 07:00 0.10 PROD1, RPEQPT TRIP P PUH to 11850 2.5 BPM 12,015.0 11,850.0 1/4/2023 07:00 1/4/2023 07:12 0.20 PROD1, RPEQPT TRIP P Dry drift to 12,015 clear. 11,850.0 12,015.0 1/4/2023 07:12 1/4/2023 10:42 3.50 PROD1, RPEQPT TRIP P POOH, Paint flag @ 10014.88, Continue out. 12,015.0 48.0 1/4/2023 10:42 1/4/2023 11:12 0.50 PROD1, RPEQPT OWFF P At surface Flow check well, .5 48.0 48.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 1/9/2023 Page 4/8 1J-107 Report Printed: 2/1/2023 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) 1/4/2023 11:12 1/4/2023 11:24 0.20 PROD1, RPEQPT PULD P Lay down BHA #4 48.0 0.0 1/4/2023 11:24 1/4/2023 11:54 0.50 PROD1, RPEQPT RURD P Rig floor for screen ops 0.0 0.0 1/4/2023 11:54 1/4/2023 12:54 1.00 PROD1, RPEQPT PULD P Ready to pick up downhole screens. Screen wrapping is problematic 0.0 0.0 1/4/2023 12:54 1/4/2023 15:42 2.80 PROD1, RPEQPT PULD P Fill well, Get air buble back. Shut swab and monitor. Unwrap screens while waiting for welll to stabilize. Open well and flow check - Good 0.0 0.0 1/4/2023 15:42 1/4/2023 19:12 3.50 PROD1, RPEQPT PUTB P Screens ready to run. Start making up liner 0.0 1,706.4 1/4/2023 19:12 1/4/2023 19:24 0.20 PROD1, RPEQPT SFTY P Kick While Tripping Drill, place safety joint on skate, bring to rig floor via skate operator, stab and MU to screen (511 xo installed), all hands on deck and thrid party individuals radio in. Drill complete 4 min 33 seconds AAR, TIW valve was confirmed open before picking up, pipe slip rams confirmed closed, H2S monitor brought to cellar and in working condition (charged). Lay down safety joint and remove last three screen packaging. 1,706.4 1,706.4 1/4/2023 19:24 1/4/2023 19:42 0.30 PROD1, RPEQPT PUTB P Continue PU screens 1,706.4 1,796.3 1/4/2023 19:42 1/4/2023 20:18 0.60 PROD1, RPEQPT PULD P MU BHI CoilTrak tools, stab injector head, surface test tools (good test), tag up reset counter depths 1,796.3 1,836.5 1/4/2023 20:18 1/4/2023 21:42 1.40 PROD1, RPEQPT TRIP P RIH, pumping min rate 0.4 bpm/41 psi pump pressure 1,836.5 7,906.0 1/4/2023 21:42 1/4/2023 21:54 0.20 PROD1, RPEQPT DLOG P Correct to EOP flag minus 1.2', PUW 46 k CTSW, minus 6.0 k DHWOB 7,906.0 7,906.0 1/4/2023 21:54 1/4/2023 22:24 0.50 PROD1, RPEQPT TRIP P Continue IH, RIW 8 k CTSW 7,906.0 9,723.0 1/4/2023 22:24 1/4/2023 22:42 0.30 PROD1, RPEQPT DLOG P Log CCL at 15 fpm, correction of minus 12' 9,723.0 9,923.0 1/4/2023 22:42 1/4/2023 23:12 0.50 PROD1, RPEQPT TRIP P Continue IH 9,923.0 10,756.0 1/4/2023 23:12 1/4/2023 23:24 0.20 PROD1, RPEQPT TRIP P Stack out -40 k CTSW, Break over @ 70 k CTSW, - 11 k DHWOB, level out at 50 k CTSW, - 7.5 k DHWOB 10,756.0 10,710.0 1/4/2023 23:24 1/5/2023 00:00 0.60 PROD1, RPEQPT TRIP P RBIH, pumping down the back side with charge pump 2.8 bpm 10,710.0 10,750.0 1/5/2023 00:00 1/5/2023 00:54 0.90 PROD1, RPEQPT TRIP P Continue working pipe IH PUW's 65-70 k CTSW 10,750.0 10,827.0 1/5/2023 00:54 1/5/2023 01:24 0.50 PROD1, RPEQPT TRIP P PUH to 9,683' PUW 50 k CTSW 10,827.0 9,683.0 1/5/2023 01:24 1/5/2023 11:24 10.00 PROD1, RPEQPT TRIP P RBIH , Work screens to bottom, 60 to 80 FPH pumping 2.7 BBL /Min. 9,683.0 12,000.0 1/5/2023 11:24 1/5/2023 12:24 1.00 PROD1, RPEQPT TRIP P Release from liner PUH remove screen length left in hole 1801.15 Continue up hole 12,000.0 10,174.9 1/5/2023 12:24 1/5/2023 13:42 1.30 PROD1, RPEQPT DLOG P Make CCL pass, -50' correction, Clean wheel was covered. 10,174.9 8,325.0 1/5/2023 13:42 1/5/2023 14:24 0.70 PROD1, RPEQPT TRIP P RBIH to confirm top of screens 8,325.0 10,190.0 1/5/2023 14:24 1/5/2023 15:09 0.75 PROD1, RPEQPT TRIP P Tag screens @ 10,190, S/B 10198. Push down 8 feet. Top of screens @ 10198'. Pump off screens 10,190.0 10,198.0 1/5/2023 15:09 1/5/2023 17:39 2.50 PROD1, RPEQPT TRIP P POOH 10,198.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 1/9/2023 Page 5/8 1J-107 Report Printed: 2/1/2023 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) 1/5/2023 17:39 1/5/2023 18:15 0.60 PROD1, RPEQPT PULD P At surface, check well for flow, LD Setting tools 10,198.0 35.0 1/5/2023 18:15 1/5/2023 19:45 1.50 PROD1, RPEQPT PUTB P Prep RF for tubing ops Stage drillers side PDL out of drillers view, RU Little Jerks inplace of tongs, stand for dog collar, load joint #1 onto skate Check pipe tally PJSM for pickup pipe 35.0 0.0 1/5/2023 19:45 1/5/2023 21:30 1.75 PROD1, RPEQPT PUTB P Start pickup L1 upper screen assembly BHA #6 Joint #36 in hole 0.0 1,078.4 1/5/2023 21:30 1/5/2023 21:42 0.20 PROD1, RPEQPT SFTY P Drill: Kick while tripping, all hand on location accounted for and commnicated either going to their stations, or going to safe briefing area. Total time 2 min 13 sec's. AAR: All went well, safety joint in position/spaced out without issues, TIW valve open when picked up, and closed after rams and annular closed, Great Drill 1,078.4 1,078.4 1/5/2023 21:42 1/5/2023 23:12 1.50 PROD1, RPEQPT PUTB P Unwrap/Prep second row of screens, remove all packaging and discard into C&D dumpster. check tally, PJSM 1,078.4 1,078.0 1/5/2023 23:12 1/6/2023 00:00 0.80 PROD1, RPEQPT PUTB P Pickup remaining screens 34 of 70 total joints 1,078.0 1,676.4 1/6/2023 00:00 1/6/2023 00:45 0.75 PROD1, RPEQPT PUTB P Continue Picking up Screens 56 of 70 1,676.4 2,096.2 1/6/2023 00:45 1/6/2023 00:57 0.20 PROD1, RPEQPT PUTB P MU Swell pack, XO, and SBR 2,096.2 2,114.4 1/6/2023 00:57 1/6/2023 01:21 0.40 PROD1, RPEQPT PULD P MU BHI CoilTrak tools, stab INJH, surface test tools (good test), tag up reset counters 2,114.4 2,149.7 1/6/2023 01:21 1/6/2023 03:21 2.00 PROD1, RPEQPT TRIP P RIH 2,149.7 10,030.0 1/6/2023 03:21 1/6/2023 03:45 0.40 PROD1, RPEQPT DLOG P Log CCL with no correction PUW 46 k CTSW, -4 k DHWOB 10,030.0 10,150.0 1/6/2023 03:45 1/6/2023 03:57 0.20 PROD1, RPEQPT TRIP P Continue IH 10,150.0 10,198.0 1/6/2023 03:57 1/6/2023 04:09 0.20 PROD1, RPEQPT TRIP P Tag TOL @ 10,198', PUH to 55 k CTSW, confirmed liner latch, set back on TOL 10,199', bring pump online 2.5 bpm/Diff 1,546 psi, PUH 39 k breakover CTSW 10,198.0 8,084.0 1/6/2023 04:09 1/6/2023 06:15 2.10 PROD1, RPEQPT TRIP P Park Coil and remove liner length from counters, continue POOH 8,084.0 40.0 1/6/2023 06:15 1/6/2023 06:45 0.50 PROD1, RPEQPT OWFF P At surface, Perform 30 min flow check - Good, Lay down BHA #6 40.0 40.0 1/6/2023 06:45 1/6/2023 07:00 0.25 PROD1, RPEQPT PULD P Unstab injector. Lay down BHA #6, Screen running BHA 40.0 0.0 1/6/2023 07:00 1/6/2023 08:00 1.00 PROD1, RPEQPT PULD P Make up BHA #7 to fish down hole ramp. Make up to coil, surface test tool, Stab on injector, Tag up set counters 0.0 59.9 1/6/2023 08:00 1/6/2023 09:30 1.50 PROD1, RPEQPT TRIP P RIH BHA #7 59.9 5,921.0 1/6/2023 09:30 1/6/2023 10:30 1.00 PROD1, RPEQPT RGRP P Stop, Replace injector counter assembly 5,921.0 5,921.0 1/6/2023 10:30 1/6/2023 11:00 0.50 PROD1, RPEQPT TRIP P Continue in 5,921.0 7,926.0 1/6/2023 11:00 1/6/2023 11:06 0.10 PROD1, RPEQPT TRIP P PUH for CCL pass 7,926.0 7,700.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 1/9/2023 Page 6/8 1J-107 Report Printed: 2/1/2023 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) 1/6/2023 11:06 1/6/2023 11:30 0.40 PROD1, RPEQPT DLOG P Log down CCL pass, +3' correction 7,700.0 7,912.0 1/6/2023 11:30 1/6/2023 11:36 0.10 PROD1, RPEQPT TRIP P Trip in to fish diver. 7,912.0 8,000.0 1/6/2023 11:36 1/6/2023 12:36 1.00 PROD1, RPEQPT FISH P 8000' go to 10 FPM. Go past diverter. Set down 8084. PUH to 8010, RBIH, Set down @ 8056. PUH. to 50K, Normal PUW=38K. Jars fires. Weight went to 38 K. Drift down to 8090. Open EDC, Trip out of hole 8,000.0 8,090.0 1/6/2023 12:36 1/6/2023 15:06 2.50 PROD1, RPEQPT TRIP P POOH 8,090.0 43.0 1/6/2023 15:06 1/6/2023 15:54 0.80 PROD1, RPEQPT PULD P At surface, well on vac, Unsrab injector, Rack back Coiltrak. Have recovered diverter ramp 43.0 0.0 1/6/2023 15:54 1/6/2023 16:54 1.00 PROD1, RPEQPT PULD P PU Cleanout/drift assembly BHA #8 0.0 34.8 1/6/2023 16:54 1/6/2023 18:54 2.00 PROD1, RPEQPT TRIP P Tag up, reset counters, RIH 34.8 7,900.0 1/6/2023 18:54 1/6/2023 19:30 0.60 PROD1, RPEQPT DLOG P Log CCL, + 100' Inspect counters, PUW 46 k CTSW, RIW 8 k 7,900.0 8,155.0 1/6/2023 19:30 1/6/2023 20:24 0.90 PROD1, RPEQPT TRIP P RIH, set down @ 11,792', + 5 k DHWOB, - 15 k CTSW PUW 57 k CTSW 8,155.0 11,792.0 1/6/2023 20:24 1/6/2023 22:54 2.50 PROD1, RPEQPT TRIP P POOH, pumping displacing down the back side 11,792.0 35.5 1/6/2023 22:54 1/6/2023 23:24 0.50 PROD1, RPEQPT OWFF P At surface, check well for flow, PJSM 35.5 35.5 1/6/2023 23:24 1/7/2023 00:00 0.60 PROD1, RPEQPT PULD P LD Cleanout/Drift Assembly BHA #8 35.5 0.0 1/7/2023 00:00 1/7/2023 02:00 2.00 PROD1, RPEQPT PUTB P Prep RF for Liner OPS. Prep pipe shed, check tally Finish removing all packaging from screens 0.0 0.0 1/7/2023 02:00 1/7/2023 04:00 2.00 PROD1, RPEQPT PUTB P PJSM PU 107 screen assembly w/65 screened joints, 56 solid joints, ported bullnose, swell packer, and SBR. Joint #28 0.0 831.6 1/7/2023 04:00 1/7/2023 04:15 0.25 PROD1, RPEQPT SFTY P Kick while tripping drill - 3 mins 22 seconds Safety joint in place, TIW open position, 511 crossover installed Lower to simulate functioning close pipeslip rams and annular. montior well. Third party reported to muster area, Tool hand sleeping in PU, Discuss Derrick hand having to notify to muster. 831.6 831.6 1/7/2023 04:15 1/7/2023 07:00 2.75 PROD1, RPEQPT PUTB P Unwrap next row of screens 831.6 831.6 1/7/2023 07:00 1/7/2023 11:48 4.80 PROD1, RPEQPT PUTB P Continue pickup up screens, Swell packer, andseal bore deployment sleeve 831.6 3,617.0 1/7/2023 11:48 1/7/2023 12:48 1.00 PROD1, RPEQPT PULD P Make up coiltrak, Stab GS into seal bore deployment sleeve. Lower down, set in slips. Make up injector. Surface test tool. Stab on well. Tag up set counters 3,617.0 3,652.8 1/7/2023 12:48 1/7/2023 14:48 2.00 PROD1, RPEQPT TRIP P RIH BHA #9 3,652.8 11,390.0 1/7/2023 14:48 1/7/2023 15:06 0.30 PROD1, RPEQPT DLOG P Log CCl pass for +37'' correction 11,390.0 11,650.0 1/7/2023 15:06 1/7/2023 15:30 0.40 PROD1, RPEQPT TRIP P Continue in coil, Set down @ 11792', Release from liner, PUH 11,650.0 11,792.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 1/9/2023 Page 7/8 1J-107 Report Printed: 2/1/2023 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) 1/7/2023 15:30 1/7/2023 15:54 0.40 DEMOB, WHDBOP PRTS P PUH, Remove length of BHA left in hole. Perform 15 Minute static BHP test 1252 PSI @ 3663.88 TVD, 3554.89 SSTVD 11,792.0 8,156.0 1/7/2023 15:54 1/7/2023 18:24 2.50 DEMOB, WHDBOP TRIP P POOH 8,156.0 1,027.0 1/7/2023 18:24 1/7/2023 18:54 0.50 DEMOB, WHDBOP TRIP P Measure Fluid Level, bad read Continue POOH, pressure washing injector chains, skates, and stuffing box 1,027.0 35.5 1/7/2023 18:54 1/7/2023 19:24 0.50 DEMOB, WHDBOP OWFF P At surface, check well for flow, PJSM 35.5 35.5 1/7/2023 19:24 1/7/2023 20:30 1.10 DEMOB, WHDBOP PULD P LD Setting tools BHA #9 35.5 0.0 1/7/2023 20:30 1/7/2023 22:30 2.00 DEMOB, WHDBOP CTOP P MU Nozzle, stab injector head, shoot fluid level ( 868' ) Bring pump online flushing surface lines 0.0 0.0 1/7/2023 22:30 1/8/2023 00:00 1.50 DEMOB, WHDBOP FRZP P LRS on location Pump 38 bbl freeze protect down tubing Displace with seawater Shut well in 0.0 0.0 1/8/2023 00:00 1/8/2023 02:30 2.50 DEMOB, WHDBOP CTOP P Load corrosion inhibitor into pits, flush all surface lines, stack, high pressure screens, with 100 bbls. Taking returns to Tiger Tank 0.0 0.0 1/8/2023 02:30 1/8/2023 04:00 1.50 DEMOB, WHDBOP CTOP P Remove checks from upper quick Stabbed INJH Haliburton on location, move in unit and rig up, Cool Down Unit PT N2 line to 5,000 psi 0.0 0.0 1/8/2023 04:00 1/8/2023 04:42 0.70 DEMOB, WHDBOP CTOP P Load out tiger tank fluids PJSM with Rig Crew and Haliburton for blowing N2 0.0 0.0 1/8/2023 04:42 1/8/2023 05:00 0.30 DEMOB, WHDBOP CTOP P Function open SR 3, SR 4, R7 to tiger tank, come online with N2, 2,000 SCF 18 mins. shut down unit, continue to bleed coil down to tiger tank 0.0 0.0 1/8/2023 05:00 1/8/2023 06:00 1.00 DEMOB, WHDBOP CTOP P Shut down N2 and rig off. Bleed N@ pressure from rig 0.0 0.0 1/8/2023 06:00 1/8/2023 07:00 1.00 DEMOB, WHDBOP CTOP P Unstab injector. Pull Upper quick connect 0.0 0.0 1/8/2023 07:00 1/8/2023 08:00 1.00 DEMOB, WHDBOP CTOP P Prep CT / Rig to unstab 2 5/8" from injector and secure to spool 0.0 0.0 1/8/2023 08:00 1/8/2023 09:00 1.00 DEMOB, WHDBOP CTOP P PJSM, Remove inner reel iron / Pressure bulkhead, Wash pipe 0.0 0.0 1/8/2023 09:00 1/8/2023 11:00 2.00 DEMOB, WHDBOP CTOP P Rig up to unstab CT 0.0 0.0 1/8/2023 11:00 1/8/2023 15:00 4.00 DEMOB, WHDBOP CTOP P Unstab CT from injector. Pull to spool. Remove CT from horse head. secure to spool. Cut tail off CT. Rig to bridge crane 0.0 0.0 1/8/2023 15:00 1/8/2023 18:00 3.00 DEMOB, WHDBOP CTOP P Remove King pin and bolster from bombay door. Prep to download CT to truck 0.0 0.0 1/8/2023 18:00 1/8/2023 23:00 5.00 DEMOB, WHDBOP CTOP P Remove horse head rollers, and gooseneck rollers, clean and put in storage box Brake down wellhead risers and dress for storage 0.0 1/8/2023 23:00 1/9/2023 00:00 1.00 DEMOB, WHDBOP CTOP P Install 2" gooseneck rollers into arch. clean and clear rig floor Rig: NABORS CDR3-AC RIG RELEASE DATE 1/9/2023 Page 8/8 1J-107 Report Printed: 2/1/2023 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) 1/9/2023 00:00 1/9/2023 03:00 3.00 DEMOB, WHDBOP CTOP P Continue to install 2" gooseneck rollers, dissasemble both mud pumps 1 & 2 clean all machined surfaces, dress with TPS protectant, store all pump parts into cabinets with grease, 0.0 0.0 1/9/2023 03:00 1/9/2023 06:00 3.00 DEMOB, WHDBOP CTOP P Remove and clean all 2-5/8" giripper blocks, break down lubricators, remove all crossovers, rollers, grapple, dimpler from box and lube up for storage, load baker boxes into the pipe shed, put hydraulic oil tote into shop to warm up, C/O horses head rollers back to 2". 0.0 0.0 1/9/2023 06:00 1/9/2023 12:00 6.00 DEMOB, WHDBOP CTOP P Break down PDL's for storage, Break off slick line tools clean and dress for storate. In COP box, Adding 529 to HPU's. Mud pumps pickled pull centrifuges down for cleaning and pickleing. Rig Release 12:00 Noon 0.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 1/9/2023 DTTMSTART JOBTYP SUMMARYOPS 12/30/2022 RECOMPLETION RDMO 1E-21 Mob to 1J-107 12/31/2022 RECOMPLETION Spot Modules. Safe out rig, MIRU, Work MIRU check lists. C/O CT string. C/O gripper blocks on injector, Change out brass in stuffing box. C/T Guide arch rollers. Nipple up BOPE. Make up inner reel iron - Pressure bulkhead. Rig on Hi-Line 9AM 1/1/2023 RECOMPLETION Rig up and stab CT in injector. Prep CT install connector. Head uo e-line into upper quick connect. Statr full BOPE test. Witness waive by Adam Earl, AOGCC. 1/2/2023 RECOMPLETION Completed bop test, open up well 0 psi under master, pump tubing volume , pick up bha# 1 nozzle run, RIH to 290', adjust gooseneck, wire shorted out pooh re-head coil test good pick up BHA# 2 nozzle run 1/3/2023 RECOMPLETION RIH to 1,100', PUH, lost coms with DHT, POOH, trouble shoot e-line issues, replace inner reel high pressure bulkhead, obtain good e-line test 1/4/2023 RECOMPLETION PU Cleanout/drift assembly BHA #4, RIH, logged CCL for depth control, inital set down 11,904', cleanout past bridge to TD 12,015', POOH, PU lower screen section w/60 joints, RIH, logged CCL, stack out @ 10,757' work pipe 1/5/2023 RECOMPLETION Work lower screens to bottom 12,000', TOL @ 10,198', POOH, LD setting tools, PU upper screen segment with 70 jts, QCLL, Sealed Dissolvable Bullnose, swell packer, and SBR 1/6/2023 RECOMPLETION Run upper screen segment to depth 10,198' TOL=8,181', POOH, LD seting tools over a dead well, PU fishing assembly BHA #7, fish diverter OOH, PU Cleanout/Drift Assembly BHA #8, RIH, log CCL + 100', clean counters (shmoo), continue IH setting down on depth 11,792', POOH, LD drift assembly BHA #8 1/7/2023 RECOMPLETION PU screen assembly BHA #9 w/SRB with centrilizer, 3 solid joints, 65 screen joints, 53 solid joints, and non-ported bullnose, RIH, release on depth 11,792', TOP @ 8,173', obtain SBHP 6.3 ppg, POOH, pressure wash INJH whjle POOH 1,100' to surface 1/8/2023 RECOMPLETION Load & blend inhibitor into pits, circulate and flush all surface lines and coiled tubing reel, blow down reel with Haliburton N2, bleed down, remove inner reel iron and bulkhead, cut off BHI upper quick and CTC, install 2-5/8" grapple cable, unstab coil from INJH, secure coil to spool, trim tail for shipping, WellWorc rigged off all equipment, and shipped out, Clean pits and drag chain. 1/9/2023 RECOMPLETION Continue prepping rig for cold stack. Break down PDL for storage. Pickle mud pumps 1J-107 Scab Liner Summary of Operations 1J-107 RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 108' 108' 20" 19.124" 94# H-40 Welded Welded Surface 3467.8' 2275.4' 13 3/8" 12.415" 68# L-80 BTC BTC Intermediate 8721' 3716.8' 9 5/8" 8.835" 40# L-80 BTC-M BTC-M B Liner (Main)11792' 3661' 5 1/2" 4.95" 15.5# L-80 IBT-M IBT-M D Liner (L1 Lat)12015.3' 3588.9' 4 1/2" 4.00" 11.6# L-80 IBT-M IBT-M Tubing 7979.8' 3647' 4 1/2" 3.958" 12.6# L-80 IBT-M IBT-M Surface Casing Conductor Perfs 4-1/2" DB-6 Landing Nipple @ 492.4' RKB (3.875" ID) 4-1/2" x 1" Camco KBMG GLM @ 2751.6', 6144.2' RKB 4-1/2" x 1" Camco KBMG GLM @ 7779.8' RKB 4-1/2" Gauge Carrier, BH SureSENS Gauge @ 7848.1' RKB 4-1/2" Locator/ Seal Assembly @ 7909.7' RKB 18' Lng 80-47 Seal Bore Extension @ 7915.7' RKB 4-1/2" DB Landing Nipple @ 7955.4' RKB (3.813" min ID) 4-1/2" x 8" Fluted Centralizer @ 7966.8' RKB (4.00" ID) 81FA47 ML Production Anchor @ 7977.67' RKB -Latched into: 4-1/2" x 9 5/8" Torque Master Packer @ 7973.39' RKB 4-1/2" DB Nipple @ 8005.98' RKB (3.75" ID) B-1 Baker LEM (Lateral Entry Module) @ 8033.65' RKB (8.27' above L-1 Lateral Hook Hanger, Latched) (3.688" ID) 4 1/2" DB Nipple @ 8124.2' RKB (3.562 ID) Modified by EDT 2/1/2023 B Liner (Mainbore): 7" x 9 5/8" Baker ML ZXP Packer and Flex Lock LH @ 8169.5' RKB 190-47 Seal Bore Extension @ 8197.4' RKB (4.75" ID) 5 1/2" Swell Packer @ 9649.7' RKB Scab Liner: 2.25" Seal Bore Deployment Sleeve @ 8174.55' RKB 3.25" OD x 2 3/8" Swell Packer @ 8181.39' RKB 2 3/8" Solid Liner from 8189' to 9762.85' RKB 2 3/8" 107 Micron Screen From 9762.85' to 11707.74' RKB 2 3/8" Solid Liner then Solid Bullnose @ 11792' RKB (TD) 5 1/2" Solid Liner to: 5 1/2" Slotted Liner from 9778.5' to 11720.9' RKB Shoe Depth @ 11792' RKB LEM Latched into L1 B Hook Hanger Intermediate Casing D Liner (L1 Liner): 7" x 9 5/8" Baker B-1 Flanged Hook Hanger @ 8041.82' RKB (21.2' inside Casing) Crossover Bushing 7" x 5.5" @ 8069.2' Crossover Bushing 5.5" x 4.5" @ 8070.6' Scab Liner (2 sections): 2.25" Seal Bore Deployment Sleeve @ 8084.77' RKB 3.25" OD x 2 3/8" Swell Packer @ 8092' RKB 2 3/8" 107 Micron Screen From 8100.77' to 11,997.74' RKB Shrouded (3.25 "OD) QCLL latched w/ dissolvable bullnose @ 10,198.55' RKB Solid Bullnose @ 12,000' RKB (TD) 4-1/2" Slotted Liner from 8099.4' to 11970.29' Guide Shoe/ Btm of Liner @ 12015.3' L1 Lateral: 3892' of Screen Jnts Mainbore Lateral: 1945' of Screen Jnts 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Scab Liner 2. Operator Name:4. Current Well Class:5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: N/A 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 12073 11792 440 N/A N/A Casing Collapse Conductor Surface Intermediate Slotted Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: 907-263-4742 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 13.375 9.625 3437 1. LEM Torque Master Packer 2. ZXP Liner Top Packer 3656 Perforation Depth MD (ft): 5 1/23623 8696 Length Size 77 9778-11712 3663-3660 MD 2275 3717 3661 3468 8721 11792 108 108 TVD Burst Kuparuk River Field/West Sak Oil Pool PRESENT WELL CONDITION SUMMARY 20 3661 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL25661, ADL25662 207-107 P.O. Box 100360 Anchorage, AK 99510-0360 50-029-23366-00 ConocoPhillips Alaska, Inc N/A KRU 1J-107 Proposed Pools: Tubing Grade:Tubing MD (ft): 7973'MD/3646'TVD 8170'MD/3639'TVD Perforation Depth TVD (ft):Tubing Size: L-80 7980 12/28/2022 4.5 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY RWO/CTD Engineer Elliott Tuttle elliott.tuttle@conocophillips.com P s 20 6. 50 6 t y t n r Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Anne Prysunka at 1:19 pm, Dec 14, 2022 322-700 Digitally signed by Elliott Tuttle DN: C=US, OU=CTD/ RWO Drilling Engineer, O="Conoco Phillips , Inc", CN=Elliott Tuttle, E=elliott.tuttle@conocophillips.com Reason: I am the author of this document Location: Date: 2022.12.14 12:01:17-09'00' Foxit PDF Editor Version: 12.0.1 Elliott Tuttle BOP test to 2500 psig SFD 12/15/2022 10-404 DSR-12/14/22 -00 SFD 12/15/2022 X X VTL 12/16/2022 GCW GCW 12/16/22 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2022.12.16 09:38:49 -09'00' P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 14, 2022 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Elliott Tuttle Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Kuparuk Producer 1J- 107(PTD# 207-107) and 1J-107L1 (PTD# 207-108). Well 1J-107 was drilled and completed in September of 2007 by Doyon 141 as a dual lateral West Sak Producer. The well was then worked over in February 2009, where a LEM (Lateral Entry Module) was landed in the L1 Hook hanger and a 4 1/2" ESP completion was installed. lastly in 2016, the well was worked over again swapping the upper completion to gas lift with 4 1/2" tubing landing a seal assembly in the upper most packer. the well has a history of making sand and it is known that if sand production can be limited, it reduces the risk of MBE's (Matrix Bypass Events) from occuring. This RWO request is to land screen scab liners in both laterals made possible by a newly designed bottom set diverter in the LEM of the L1 Liner. If you have any questions or require any further information, please contact me at 907-252-3347. Scab liners will be run into both laterals by way of new diverter followed by pulling diverter and running liner into mainbore lateral. Digitally signed by Elliott Tuttle DN: C=US, OU=CTD/ RWO Drilling Engineer, O="Conoco Phillips, Inc", CN=Elliott Tuttle, E=elliott.tuttle@ conocophillips.com Reason: I am the author of this document Location: Date: 2022.12.14 12:02:20-09'00' Foxit PDF Editor Version: 12.0.1 Elliott Tuttle 1J-107 RWO Procedure Kuparuk Producer Screen Scab Liner Install PTD #’s 207-107, 207-108 Page 1 of 3 Pre-Rig Work Completed: 1. Set position 1 Diverter into D Lat LEM @ 8047’ RKB 2. Perform D Lateral fluff and stuff cleanout down to 11,910’ CTMD – shy of TD 3. Pull position 1 Diverter from D Lat LEM 4. Set position 1 Isolation sleeve (isolates D Lateral from mainbore) @ 8047’ RKB 5. Perform B Lateral fluff and stuff cleanout down to 11796’ CTMD – shy of TD 6. Pull position 1 Isolations sleeve from D Lat LEM 7. Set IALD (Increased Access Lateral Diverter) into D LEM at 8047’ a. Diverter uses a running tool to locate and orient in the LEM, then sets an anchor below the window of the LEM maximizing the drift of the junction 8. Run 3.25” OD x 30’ Drift through junction and down to 8500’ successfully. Confirmed drift wit GR/CCL on memory Rig Work , Estimated Start Date: 12/28/2022 MIRU 1. MIRU Nabors CDR-3AC rig using 2” coiled tubing on 1J-107. NU 7-1/16” BOPE, test. D Lateral Operations (1J-107L1) 2. RIH on 2” Coiled Tubing and confirm TD, POOH laying in 8.6ppg slick seawater. 3. PU Screen Scab Liner while pumping across the top with same fluid a. 3” Bullnose b. 3930’ of 2 3/8” Basepipe 107 Micron Mesh Screen w/ 3.25” OD Carbon Fiber Centralizers installed c. 3.25” OD Water Swell Packer d. 2.25” ID Seal Bore Deployment Sleeve (3.25” OD) 4. RIH on 2” Coiled Tubing and land on bottom, pump off and POOH 5. RIH and Fish IALD Diverter on 2” Coiled Tubing B Lateral Operations (1J-107) 6. RIH on 2” Coiled Tubing and confirm TD, POOH laying in 8.6 slick seawater. 7. PU Screen Scab Liner while pumping across the top with same fluid a. 2 3/8” Bullnose b. ~2014’ of 2 3/8” Basepipe 107 Micron Mesh Screen w/ 3.25” OD Carbon Fiber Centralizers installed c. ~1582’ of 2 3/8” Solid Liner d. 3.25” OD Water Swell Packer e. 2.25” ID Seal Bore Deployment Sleeve (3.25” OD) 8. RIH on 2” Coiled Tubing and land on bottom, pump off and POOH RDMO 9. Freeze protect well 10. ND BOPE. 11. RDMO. Post-Rig Work 12. Wait on Swell Packers to seal 13. Return to production 1J-107 RWO Procedure Kuparuk Producer Screen Scab Liner Install PTD #’s 207-107, 207-108 Page 2 of 3 General Well info: Production Engineer: Marina Krysinski Workover Engineer: Elliott Tuttle (907-252-3347/ Elliott.tuttle@conocophillips.com) Current Operations: This well is currently shut in since the IALD was set in the D Lat LEM Well Type: Producer Scope of Work: Confirm TD in D Lat then deploy screen scab liner. Fish the IALD, then confirm TD in B Lat followed by deploying screen scab liner. RDMO BOP configuration: Attached below MPSP: 440 psi using 0.1 psi/ft gradient Static BHP: 1103 psi / 6631.2’ TVD measured on 1/8/21 (3.20ppg) 1J-107 RWO Procedure Kuparuk Producer Screen Scab Liner Install PTD #’s 207-107, 207-108 Page 3 of 3 Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 19.124 Top (ftKB) 31.0 Set Depth (ftKB) 108.0 Set Depth (TVD) … 108.0 Wt/Len (l… 94.00 Grade H-40 Top Thread Casing Description SURFACE OD (in) 13 3/8 ID (in) 12.415 Top (ftKB) 30.4 Set Depth (ftKB) 3,467.8 Set Depth (TVD) … 2,275.4 Wt/Len (l… 68.00 Grade L-80 Top Thread BTC Casing Description INTERMEDIATE OD (in) 9 5/8 ID (in) 8.835 Top (ftKB) 24.8 Set Depth (ftKB) 8,721.0 Set Depth (TVD) … 3,716.8 Wt/Len (l… 40.00 Grade L-80 Top Thread BTCM Casing Description B LINER SLOTTED OD (in) 5 1/2 ID (in) 4.950 Top (ftKB) 8,169.5 Set Depth (ftKB) 11,792.0 Set Depth (TVD) … 3,661.0 Wt/Len (l… 15.50 Grade L-80 Top Thread IBT-M Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 8,169.5 3,669.3 83.27 PACKER BAKER 'ML' ZXP LINER TOP PACKER 6.320 8,190.7 3,671.8 83.24 HANGER FLEX LOCK LINER HANGER 6.200 8,196.0 3,672.4 83.24 XO BUSHING CROSSOVER BUSHING 4.910 8,197.4 3,672.6 83.24 SBE 190-47 SEAL BORE EXTENSION 4.750 9,649.7 3,658.2 88.52 Swell Packer EASYWELL SWELL PACKER 4.950 11,720.9 3,659.7 89.09 Swell Packer EASYWELL SWELL PACKER 4.950 Casing Description D LINER LEM OD (in) 4 1/2 ID (in) 3.958 Top (ftKB) 7,973.4 Set Depth (ftKB) 8,207.8 Set Depth (TVD) … 3,673.8 Wt/Len (l… 12.60 Grade L-80 Top Thread IBTM Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,973.4 3,646.3 83.18 PACKER LEM TorqueMaster Packer 3.950 8,006.0 3,650.1 83.22 NIPPLE LEM 3.75" 'DB' Nipple 3.750 8,124.2 3,664.0 83.32 NIPPLE LEM 3.562" 'DB' Nipple 3.562 8,204.6 3,673.4 83.23 SEAL ASSY LEM SEAL ASSEMBLY 3.870 Tubing Strings Tubing Description TUBING WO 2016 String Ma… 4 1/2 ID (in) 3.958 Top (ftKB) 23.7 Set Depth (ft… 7,979.8 Set Depth (TVD) (… 3,647.0 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 23.7 23.7 0.00 HANGER Vetco Gray MB-222 Tubing Hanger(drifted 3.895") w/ 4- ½'' IBT-M Pup Joint 3.04' 3.958 492.4 491.6 7.86 NIPPLE Camco 4-½" x 3.875" DB-6 Landing Nipple (IBT-M BxP) 3.875 7,848.1 3,631.2 83.30 GAUGE Unique Gauge Carrier (4-½'' IBT-M Coupling) (BH SureSENS 125LP Gauge w/ TEC wire) 3.958 7,909.7 3,638.7 83.03 LOCATOR Baker Locator Sub 3.950 7,910.9 3,638.8 83.03 SEAL ASSY Baker 17' 80-47 Seal Assembly. 4.79 feet up from fully located. 3.900 7,915.7 3,639.4 83.05 SBE Baker 18' 80-47 PBR SHEARED 4.750 7,955.4 3,644.1 83.16 NIPPLE Camco 4-½" 3.813" DB Landing Nipple (IBT-M BxP) 3.813 7,966.8 3,645.5 83.17 CENTRALIZE R 4½" x 8" fluted centralizer 4.000 7,977.7 3,646.8 83.18 ANCHOR Baker ML Production Anchor 81FA47, 4-½" IBT-M Box) 3.880 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Zone Date Shot Dens (shots/f t)Type Com 9,778.0 11,712.0 3,663.1 3,659.6 WS B, 1J-107 9/3/2007 32.0 SLOTS 100% slotted liner, 2.5"x .125", 4 circumferential rows/ft, 3" centers staggered 18 deg Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,751.6 2,002.3 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,478.0 5/10/2016 2 6,144.2 3,216.3 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 5/6/2016 3 7,779.8 3,623.3 Camco KBMG 1 GAS LIFT OV BK 0.313 0.0 10/11/2017 Notes: General & Safety End Date Annotation 9/15/2007 NOTE: MULTI-LATERAL WELL - 1J-107 (B-SAND), 1J-107L1 (D-SAND) 8/23/2008 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 5/14/2010 NOTE: WELL CONVERTED FROM ESP TO GAS LIFT PRODUCTION Comment SSSV: NIPPLE1J-107, 11/2/2017 3:48:38 PM Vertical schematic (actual) B LINER SLOTTED; 8,169.5- 11,792.0 SLOTS; 9,778.0-11,712.0 INTERMEDIATE; 24.8-8,721.0 D LINER LEM; 7,973.4-8,207.8 D LINER SLOTTED; 8,041.8- 12,015.3 ANCHOR; 7,977.7 XO Threads; 7,968.1 CENTRALIZER; 7,966.8 NIPPLE; 7,955.4 SBE; 7,915.7 SEAL ASSY; 7,910.9 LOCATOR; 7,909.7 GAUGE; 7,848.1 GAS LIFT; 7,779.8 GAS LIFT; 6,144.1 SURFACE; 30.4-3,467.8 GAS LIFT; 2,751.6 NIPPLE; 492.4 CONDUCTOR; 31.0-108.0 HANGER; 23.7 Annotation Last Tag: Depth (ftKB) End Date Annotation Rev Reason: GLV C/O #3 Last Mod By pproven End Date 11/2/2017 KUP PROD KB-Grd (ft) 32.29 Rig Release Date 9/15/2007 Annotation Last WO: End Date 5/7/2016 1J-107 H2S (ppm) 75 Date 8/11/2015 ... TD Act Btm (ftKB) 12,073.0 Well Attributes Wellbore API/UWI 500292336600 Field Name WEST SAK Wellbore Status PROD Max Angle & MD Incl (°) 96.49 MD (ftKB) 9,103.81 1J-107 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 108' 108' 20" 19.124" 94# H-40 Welded Welded Surface 3467.8' 2275.4' 13 3/8" 12.415" 68# L-80 BTC BTC Intermediate 8721' 3716.8' 9 5/8" 8.835" 40# L-80 BTC-M BTC-M B Liner (Main)11792' 3661' 5 1/2" 4.95" 15.5# L-80 IBT-M IBT-M D Liner (L1 Lat)12015.3' 3588.9' 4 1/2" 4.00" 11.6# L-80 IBT-M IBT-M Tubing 7979.8' 3647' 4 1/2" 3.958" 12.6# L-80 IBT-M IBT-M Surface Casing Conductor Perfs 4-1/2" DB-6 Landing Nipple @ 492.4' RKB (3.875" ID) 4-1/2" x 1" Camco KBMG GLM @ 2751.6', 6144.2' RKB 4-1/2" Gauge Carrier, BH SureSENS Gauge @ 7848.1' RKB 4-1/2" x 1" Camco KBMG GLM @ 7779.8' RKB 4-1/2" Locator/ Seal Assembly @ 7909.7' RKB 18' Lng 80-47 Seal Bore Extension @ 7915.7' RKB 4-1/2" DB Landing Nipple @ 7955.4' RKB (3.813" min ID) 4-1/2" x 8" Fluted Centralizer @ 7966.8' RKB (4.00" ID) 81FA47 ML Production Anchor @ 7977.67' RKB -Latched into: 4-1/2" x 9 5/8" Torque Master Packer @ 7973.39' RKB 4-1/2" DB Nipple @ 8005.98' RKB (3.75" ID) B-1 Baker LEM (Lateral Entry Module) @ 8033.65' RKB (8.27' above L-1 Lateral Hook Hanger, Latched) (3.688" ID) 4 1/2" DB Nipple @ 8124.2' RKB (3.562 ID) Seal Assembly @ 8204.6' RKB (Landed in B Liner, Mainbore) Modified by EDT 12/12/2022 B sand Liner Detail (Mainbore Lateral): 7" x 9 5/8" Baker ML ZXP Packer and Flex Lock LH @ 8169.5' RKB 190-47 Seal Bore Extension @ 8197.4' RKB (4.75" ID) 5 1/2" Swell Packer @ 9649.7' RKB Scab Liner: 2.25" Seal Bore Deployment Sleeve @ 8180' RKB 3.25" OD x 2 3/8" Swell Packer @ 8186' RKB 2 3/8" Solid Liner from 8196' to 9778' RKB 2 3/8" 107 Micron Screen From 9778' to 11792' RKB 5 1/2" Solid Liner to: 5 1/2" Slotted Liner from 9778.5' to 11720.9' RKB Shoe Depth @ 11792' RKB (Casing orange peeled and welded) LEM Latched into L1 B Hook Hanger Intermediate Casing D sand Liner Detail (L1 Lateral): 7" x 9 5/8" Baker B-1 Flanged Hook Hanger @ 8041.82' RKB (21.2' inside Casing) Crossover Bushing 7" x 5.5" @ 8069.2' Crossover Bushing 5.5" x 4.5" @ 8070.6' Scab Liner: 2.25" Seal Bore Deployment Sleeve @ 8074' RKB 3.25" OD x 2 3/8" Swell Packer @ 8078' RKB 2 3/8" 107 Micron Screen From 8088' to 12015' RKB 4-1/2" Slotted Liner from 8099.4' to 11970.29' Guide Shoe/ Btm of Liner @ 12015.3' L1 Lateral: ~3927' of Screen Jnts Mainbore Lateral: ~2014' of Screen Jnts C:\Users\mdguhl\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\LCF4WGUY\2022-12-08_22513_KRU_1J-107_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 22513 KRU 1J-107 50-029-23366-00 Caliper Survey W/ Log Data 08-Dec-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 10:04 am, Dec 13, 2022 207-107 T37370 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.12.13 10:05:22 -09'00' C:\Users\aebell\Desktop\September 2021 Data Drop\Halliburton Data Drop 09292021\2021-09-22_20178_KRU_1J-107_CaliperSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 20178 KRU 1J-107 50-029-23366-00 Caliper Survey 22-Sep-21 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 FTP ______________________________ ______________________________________ Print Name 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 Abby Bell ___________________________________ ignaturrrrrrrrrrrrrrrrrrrrrrrrrrrrrrrrreeeeeeeeeeeeeeeeeeeeeeee 37' (6HW By Abby Bell at 11:33 am, Sep 29, 2021 ! " # " $%&' # ( ') * +,! - *( ./ !0 1"!! 2/ ./ 34354-04 6. 0 " * ( ' ( % 7 . 899 0 : 7. *9 0 3 ;8 * , . 0 < ; 5" : ( * " ') * ( / * +" : $ "(/ ' ( $ $,!= > />$ *!!6 ') 8! ! 8 " ' ' = ' ' !""#$ %&$' (') 8 < *&#&+,- ., "/0 $'1,"" , *+23 -,* * *: / : ? .; 34354-49354-9@3531<0 )&'4 $ #% =: ,5 !$, ( :9, '/A /A,/!($!' 7,!%%,,! +61+1.2+70616+ 41 5 ( !3 ! ! ?" &": )&'4 ( * ,B ( " #& = =" C .24-03+5#+?- &)44<+4 9A2254 #& ",!="$ 4#?4? <63434 " <4* By Samantha Carlisle at 8:52 am, Nov 24, 2020 John W Peirce Digitally signed by John W Peirce Date: 2020.11.24 07:51:44 -09'00' SD 11/24/2020RBDMS HEW 11/25/2020 DSR-11/24/2020VTL 02/18/2021 !"#$$%&'!()'!*)!+)",- $*.,+/)%,+/0,)1 2 %%$- &#34#&$$&0!"%567%%$-340289&#(: *;/.&+.!+)'*),&+8 /"',+/)'!*)!+),- $*.!" )'!*)!+)0 %%$-34*+"7",!-!$ < 2 )& < = !)'!*)!+) *'5&# !'*),&+- Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:1J-107 triplwj Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: GLV C/O #3 11/2/2017 1J-107 pproven Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 19.12 Top (ftKB) 31.0 Set Depth (ftKB) 108.0 Set Depth (TVD) … 108.0 Wt/Len (l… 94.00 Grade H-40 Top Thread Casing Description SURFACE OD (in) 13 3/8 ID (in) 12.41 Top (ftKB) 30.4 Set Depth (ftKB) 3,467.8 Set Depth (TVD) … 2,275.4 Wt/Len (l… 68.00 Grade L-80 Top Thread BTC Casing Description INTERMEDIATE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 24.8 Set Depth (ftKB) 8,721.0 Set Depth (TVD) … 3,716.8 Wt/Len (l… 40.00 Grade L-80 Top Thread BTCM Casing Description B LINER SLOTTED OD (in) 5 1/2 ID (in) 4.95 Top (ftKB) 8,169.5 Set Depth (ftKB) 11,792.0 Set Depth (TVD) … 3,661.0 Wt/Len (l… 15.50 Grade L-80 Top Thread IBT-M Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 8,169.5 3,669.3 83.27 PACKER BAKER 'ML' ZXP LINER TOP PACKER 6.320 8,190.7 3,671.8 83.24 HANGER FLEX LOCK LINER HANGER 6.200 8,196.0 3,672.4 83.24 XO BUSHING CROSSOVER BUSHING 4.910 8,197.4 3,672.6 83.24 SBE 190-47 SEAL BORE EXTENSION 4.750 9,649.7 3,658.2 88.52 Swell Packer EASYWELL SWELL PACKER 4.950 11,720.9 3,659.7 89.09 Swell Packer EASYWELL SWELL PACKER 4.950 Casing Description D LINER LEM OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 7,973.4 Set Depth (ftKB) 8,207.8 Set Depth (TVD) … 3,673.8 Wt/Len (l… 12.60 Grade L-80 Top Thread IBTM Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,973.4 3,646.3 83.18 PACKER LEM TorqueMaster Packer 3.950 8,006.0 3,650.1 83.22 NIPPLE LEM 3.75" 'DB' Nipple 3.750 8,124.2 3,664.0 83.32 NIPPLE LEM 3.562" 'DB' Nipple 3.562 8,204.6 3,673.4 83.23 SEAL ASSY LEM SEAL ASSEMBLY 3.870 Tubing Strings Tubing Description TUBING WO 2016 String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 23.7 Set Depth (ft… 7,979.8 Set Depth (TVD) (… 3,647.0 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 23.7 23.7 0.00 HANGER Vetco Gray MB-222 Tubing Hanger(drifted 3.895") w/ 4-½'' IBT-M Pup Joint 3.04' 3.958 492.4 491.6 7.86 NIPPLE Camco 4-½" x 3.875" DB-6 Landing Nipple (IBT-M BxP) 3.875 7,848.1 3,631.2 83.30 GAUGE Unique Gauge Carrier (4-½'' IBT-M Coupling) (BH SureSENS 125LP Gauge w/ TEC wire) 3.958 7,909.7 3,638.7 83.03 LOCATOR Baker Locator Sub 3.950 7,910.9 3,638.8 83.03 SEAL ASSY Baker 17' 80-47 Seal Assembly. 4.79 feet up from fully located. 3.900 7,915.7 3,639.4 83.05 SBE Baker 18' 80-47 PBR SHEARED 4.750 7,955.4 3,644.1 83.16 NIPPLE Camco 4-½" 3.813" DB Landing Nipple (IBT-M BxP) 3.813 7,966.8 3,645.5 83.17 CENTRALIZER 4½" x 8" fluted centralizer 4.000 7,977.7 3,646.8 83.18 ANCHOR Baker ML Production Anchor 81FA47, 4-½" IBT-M Box) 3.880 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 9,778.0 11,712.0 3,663.1 3,659.6 WS B, 1J-107 9/3/2007 32.0 SLOTS 100% slotted liner, 2.5"x .125", 4 circumferential rows/ft, 3" centers staggered 18 deg Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,751.6 2,002.3 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,478.0 5/10/2016 2 6,144.2 3,216.3 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 5/6/2016 3 7,779.8 3,623.3 Camco KBMG 1 GAS LIFT OV BK 0.313 0.0 10/11/2017 Notes: General & Safety End Date Annotation 5/14/2010 NOTE: WELL CONVERTED FROM ESP TO GAS LIFT PRODUCTION 8/23/2008 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 9/15/2007 NOTE: MULTI-LATERAL WELL - 1J-107 (B-SAND), 1J-107L1 (D-SAND) 1J-107, 11/19/2020 8:41:55 AM Vertical schematic (actual) B LINER SLOTTED; 8,169.5- 11,792.0 SLOTS; 9,778.0-11,712.0 INTERMEDIATE; 24.8-8,721.0 D LINER LEM; 7,973.4-8,207.8 D LINER SLOTTED; 8,041.8- 12,015.3 ANCHOR; 7,977.7 XO Threads; 7,968.1 CENTRALIZER; 7,966.8 NIPPLE; 7,955.4 SBE; 7,915.7 SEAL ASSY; 7,910.9 LOCATOR; 7,909.7 GAUGE; 7,848.1 GAS LIFT; 7,779.8 GAS LIFT; 6,144.1 SURFACE; 30.4-3,467.8 GAS LIFT; 2,751.6 NIPPLE; 492.4 CONDUCTOR; 31.0-108.0 HANGER; 23.7 KUP PROD KB-Grd (ft) 32.29 Rig Release Date 9/15/2007 1J-107 ... TD Act Btm (ftKB) 12,073.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292336600 Wellbore Status PROD Max Angle & MD Incl (°) 96.49 MD (ftKB) 9,103.81 WELLNAME WELLBORE1J-107 Annotation Last WO: End Date 5/7/2016 H2S (ppm) 75 Date 8/11/2015 Comment SSSV: NIPPLE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS JAN U 3 2020 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ OpeF n Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: RPPG MBE TRTMTEI 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development p Exploratory ❑ 207-107 3. Address: P. 0. Box 100360, Anchorage, Stmtigmphic❑ Service ❑ 6. API Number: Alaska 99510 50-029-23366-00 7. Property Designation (Lease Number): 6. Well Name and Number: ADL 25661, ADL 25662 KRU 1 J-107 9. Logs (List logs and submit electronic and panted data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field / West Sak Oil Pool 11. Present Well Contlition Summary: Total Depth measured 12,073 feet Plugs measured None feet true vertical 3,656 feet Junk measured None feet Effective Depth measured 11,792 feet Packer measured 7937, 8170 feet true vertical 3,661 feet true vertical 3646, 3669 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 feet 20 108' MD 108' TVD SURFACE 3,437 feet 13 3/8 " 3,468' MD 2275' TVD INTERMEDIATE 8,696 feet 95/8" 8,721' MD 3717' TVD B LINER SLOTTED 3,623 feet 51/2" 11,792'MD 3661'TVD Perforation depth: Measured depth: 9778-11712 feet True Vertical depth: 3663-3660 feet Tubing (size, grade, measured and true vertical depth) 4.5" L-80 7,980' MD 3,647' TVD Packers and SSSV (type, measured and true vertical depth) PACKER- LEM TRQUE MASTER PKR 7,973' MD 3,646' TVD PACKER - ZXP LINER TOP PACKER 8,170' MD 3,669' TVD MD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Diked Gas -Mu I Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: SHUT-IN - _ Subsequent to operation: a 1448 1 1195 - 211 14. Attachments (repuired per 20 n C 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations 10 Exploratory ❑ Development p Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil O Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-520 Authorized Name: John Peirce Contact Name: John Peirce Authorized Title: Sr. Wells Contact Email: John.W.Peirce@cop.com ,Ennginfeer� Authorized Si nature: u� W ' Contact Phone: (907) 265-6471 1 rzr 2 Date: o Form 10-404 Revised 4/2017 V77- ,4 71,y1090 3BDMS i JAN 0 3 2020 Submit Original Only 1 J-107 OFFSET PRODUCER TO 1 J-1 05L1 RPPG MBE TREATMENT DTTM JOBTYP SUMMARYOPS START 11/28/19 MISC. CAPACITY RIH WITH 2.0" OD HSD GUNS, 6 SPF, 60 DEGREE PHASE, SHOOT SUSTAINMENT HOLES IN B LATERAL LINER FROM 9925' TO 9930' CTMD, F/P TBG TO 3000', VERIFIED ALL SHOTS FIRED, READY FOR FULLBORE RPPG, JOB IN PROGRESS. RDMO CT UNIT. 12/5/19 MISC. CAPACITY PUMPED FULLBORE RPPG TREATMENT TO OPEN B LAT MBE AT SUSTAINMENT -9930' RKB. FRESH 5' PERF INTERVAL SHOT OVER MBE AT 9925-9930' RKB (SEE WSR 11/28/19). PUMPED 496 -BBL TREATMENT INCLUDING 100 -BBL 2% KCL PRE -FLUSH, FOLLOWED BY 241 -BBL SLURRY CONTAINING 2% KCL PLUS 5940# RPPG PRODUCT. DISPLACED SLURRY TO MBE WITH 21 -BBL 2% KCL AND 134 -BBL DIESEL FP (155 - BBL TOTAL DISPLACEMENT, SWAPPED TO DIESEL EARLY DUE TO WHP PRESSURE INCREASE). GAINED APPROXIMATELY 1930 -PSI NET PRESSURE DURING TREATMENT PUMPING 2.0-3.6 BPM. SHUT IN SUPPORTED PRODUCER 1J-107 SIMULTANEOUSLY AT START OF PUMPING AND REQUESTED IT BE FREEZE PROTECTED SLOWLY AND BOL ONLY AFTER 48 -HOURS. 12/9/19 PUMPING PUMPED 141 BBLS DIESEL DOWN TBG TO ESTABLISH INJECTIVITY TRACKING ONLY JOB COMPLETE KUP PROD WELLNAME 1J-107 WELLBORE 1J-107 ConocoPhillip$ h.— Well Attributes Max Angle 8 MD ro �a�°� MDeS. SURFACE: Ma .a a— Lx:F ,U SEAL ASSM. EEE: NIP%E: & Slots D LINER SLORED: D LINER LEM: E LINER &IpMD: 41W S 1,.MS- Bim Lom Com Run IN. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY John Peirce Sr. Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J-107 Permit to Drill Number: 207-107 Sundry Number: 320-018 Dear Mr. Peirce: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage,. Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, m . Price Chair DATED this day of January, 2020. 3BDMS�uIAN 3 12020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED JAN420 AO 2' ?JC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Re air Well Elp Operations shuttlown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: RPPG MBE RE-TRTMNTD 2. Operator Name: 4. Current Well Class: 1 5. Permit to Drill Number: ConocoPhilll s Alaska Inc. Exploratory ❑ Development El Stratigmphic ❑ Service ❑ 207-107 4 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23366-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No D KRU 1J-107 ' 9. Property Designation (Lease; umber): 10. Field/Pool(s): ADL 25661, ADL 25662 I Kuparuk River Field /West Sak Oil Pool " 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 12,073' 3,656' 11792 3661 1500PSI NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 77' 20" 108' 108' Surface 3,437' 133/8 3,468' 2,275' Intermediate 8,696' 95/8 8,721' 3,717' Slotted Liner 3,623' 51/2 1 11,792' 3,661' Perforation Depth MD (it): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (it): 9778-11712 3663-3660 4.500" L-80 7,980' Packers and SSSV Type: Packers and SSSV MD (H) and TVD ft: PACKER = LEM TORQUE MASTER PACKER 7973 MD and 3646 TVD PACKER = ZXP LINER TOP PACKER 8170 MD and 3639 TVD 12. Attachments: Proposal Summary El Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ DevelopmentEl Service ❑ 14. Estimated Date for 1/2712020 . 15. Well Status after proposed work: Commencing Operations: OIL ❑+ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: John Peirce John Peirce Contact Name: Authorized Title: Sr. Wells Engineer Contact Email: Jahn.W.Peirce@cop.com A Contact Phone: (907) 265-6471 Authorized Signature: % Wr `• ' Date: 1114/202e> - - —'� COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. ZU- Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: .,_/ IMS 1 q Post Initial Injection MIT Req'd? Yes ❑ No L7 -" D"-"�""- r�N 312020 Spacing Exception Required? Yes ❑ No Subsequent Form Required: / 0 — -Ib 4 v APPROVED BY Approved by: ,1 COMMISSIONER THE COMMISSION Date: (J V7'L y/yy120 C �4?00 dQ 111 G I N A L Submit Form and Form 10- Revised 4/2017pt� Approved application I@ /I� for 12 months from the date O O chments in Dupliate IIJd.g OIP?3�2.0 .e'Av/ r4 Conoco✓Phillips Kaska, Inc. 11-1mnnarzo2oa0ns2 PM Last Tag Vwb�sch-.-lsrnul) Annotation DegM1(XKIN I End Oate wellbore lx[Moa By ............................................................... .............. Farm :E.7� Last Tag: 1J-10] IIIDIwj Last Rev Reason Annadtbn End Deb Wellbore last Mad By Rev Reason: GLV C/O #3 11J-10] pproven c;rrgscrr ea ,_ - CONDUCTOR; 91619.0 NIPPLE: M 4 Order LIFT; 27516 suRPAca: xiaa,46Te- GAS UPr; e.la4.t Gds UT. 7,M8 cqu6Q 7ar41 LGCATOR7.89.7 6EPLg66Y: 7.8108 .8E;7.815.T NIPPLE: 7real cEMRAuzER'. T.94a xo tlwwa: [s9.1 ANCNOR;7,677 D LINER SLOTTED: 404111. 12.015.9 0 LINER LEM', 7,99.46,2076 INTERMEDIATE;M.9A,72f 0 SLOTS; 9,MG-11.7120-a a LINER SLOTTED; 9,169.8 T.Ai a L - easme0eanapron Do(in) ID(in) 1(UK.) set Dean UIKBI set paptn lrvDL.. wuLan (L.. craaa To, Th CONDUCTOR 20 19.12 31.0 1080 1080 94.00 H40 Casing Deomptlan OD(inl 109n) Top(NNB) get Depnd (RKB) set Oeptn frvD)_. wtlten l... Grine Top Tnredl SURFACE 13318 12.41 394 3,46).6 2,,05 .4 88.00 L40 BTC eaalnp permit Do (in) ID(M) Top(Real 9M D101hutNBI BN Depth(TVD)... wagon k Gmde Tap Thread INTERMEDIATE gON 8.83 24.8 $]210 3)168 40.00 L-80 BTCM Casing Description OD (in) ID(n) iop IRKS) Set Dep"NIRB) setDeMh(TVD)...WdLen 11...Gam Top Thread B LINER SLOTTED 5112 4.95 8,169.5 11,792,0 3,661.0 15 Led IDT-M Liner Details. W. lNomina110 Top(RKS) "piO (RI(9) top met P) Item Des Com (1n) 6,169.5 3,669.3 832] PACKER BAKER '.1-ZXPLIHER TOP PACKER 6.320 8,19 97 3,6)18 8324 HANGER FLEX LOCK LINER HANGER 6.200 8,1960 3,6]2.4 83.24 XO BUSHING CROSSOVER BUSHING 4.910 6,1974 3,672.6 83.24 SBE 190.47 SEAL BORE EXTENSION 4.750 9,649] 3,6562 88.52 Swell Pecker EASYWELLSWELLPACKER 4950 11,]209 3,6593 8909 Swell Packer EASYWELLSWELL PACKER 4.950 osing Descaptlon OD QnI ID (im Top (ttKBI Set -soNINE) fief Daptr jND)._ WI/L¢n 6...611, Top TM1reaO YL DLNER LEM 4112 396 ),973.4 8,2078 3,6738 12.60 L-80 IBTM Liner Details iop111K9) Tap (NDI (RKB) Top Incl r) I.minmlD tem ties Cam (In) 7,973.4 3,fi48.363,18 PACKER LEM TOMUNMeater Packer 3.950 8,006.0 3,650.1 83.22 NIPPLE LEM 3.]5"'DB'Nipple 3750 8,124.2 3,864.083.2 NIPPLE LEM 3.562"'DB'NipplR 3562 8,204.6 3,6)3.4 8323 SEALASSV LEM SEAL ASSEMBLY 3.870 Tubing Strings Tubma Description so-mB Ma... m(m) Top RUE) set Depth lR„set D-On(TVD)(... Wt9b/ttI Grade Top.nmmFnn TUBING W02016 41/2 396 23.] >,979.8 3,6470 12.60 L-80 IBTM Cm opletion Details To, (ID) Tarried Nominal TnP (XH9l (Rea) C) Ile. Daa Com to (in) 231 23.7 0,00 HANGER Vetco Gay - Tubing H.eg.,(dnttd 3. 5')w14-%/ IBT-M 3.958 Pup Joint 3.04' 4924 491.6 7.86 NIPPLm E Caco4-'G"x3.875"DB-6Landing NipDle(IBT-MBxP) 3.875 7,84B.1 3,6312 83.30 GAUGE Unique GaugeCamer (4a. IBT-M Coupling) BH SureSENS 3.958 125LP Gauge wl TEC wire) 7,9093 3,6387 8303 LOCATOR lesager Locator Sub 3950 7,910.9 3,6368 83.03 SEALASSV 13aker178047Seal Aasembly.4.79 feet up from fully located. 3,900 ],915.] 3,639.4 83.05 SBE Baker 18'8047 PER SHEARED 4.750 ],955.4 3,644.1 83.16 NIPPLE Camco 4-X"3.813" DB Landing Nippla(IBT-MBxP) 3813 ),966.8 3,645.5 83.1] CENTRALIZER 4X".8" fluted centralizer 4,000 J,W77 3,646.8 NJ III JANLJHUX Baker ML Production Anchor 81FA47,4-X"IBI -MBox) 3.88p Perforations & Slots Tap(f KIN t.(MB) Top (TAS (Real Ban (rv0) (reel LmkM Zone new snot Dens pnoWN ) Tyce Com 9)78.0 11,)120 3,663.1 3,659.6 WS B, iJ-10) 9/ 007 32.0 SLOTS 100 slotted liner, 2.5"x.125',4 Circumferential novel Y centers staggered 18 deg Mandrel Inserts fit aI N Tap (fIX9 Top mD) VaNe LatcM1 Port Size TRO Run I ME) Meke Madel OO pnl sery Type Type listeS (pall Run Dah Com "Ano 2,0023 Camco KBMG 1 GASLIFT GLV BK 0.186 1,4)8.0 511042018 2 6,144.2 ]216.3 Carom KBMG 1 GAS LIFT DMY BK -5 O.ULU 0.0 5162016 3 7,7798 3,623.3 Camco KBMG 1 GAS LIFT OV BK 0313 0.0 10/11201) Notes: General Is Safety E Dead Annotation 5114/2010 NOTE. WELL CONVERTED FRDM ESP TO GAS LIFT PRODUCTION 82312008 NOTE: VIEW SCHEMATIC w/Alaska Schematicfl0 W152007 INCITE: MULTI -LATERAL WELL -1J-10) (BSAND), 1J-10711 (O -SAND) Proposal for 1J -105L1 to 1J-107 RPPG B MBE Retreatment U-105 Tri-Lat injector was drilled & completed in 2007 with West Sak A, B, & D Sd laterals. 1J-1051-1 B Lat has a 4.5", L-80 slotted liner. The first B MBE occurred 4/5/12 from 1J-1051-1 to 1J-1031-1 producer. A 5/26/12 IPROF found B MBE at -9550' RKB taking all PWI. On 9/24/12, a Crystal Seal job sealed the MBE for -3 months, then 3/24/13 (PROF verified the B MBE at 9550' had reopened. An 8/10/13 Crystal Seal retreatment was pumped, and treatment -3 years until the next MBE occurred 3/9/16. A 5/25/16 ]PROF in 1J-1051-1 found new MBE at 9750' RKB. On 4/30/17, an RPPG treatment sealed MBE at 9750' RKB and the treatment lasted until 10/20/19 when a new MBE occurred from 1J-1051-1 to 1J-107. This is the first MBE from 1J-1051-1 to 1J-107. An 11/8/19 ]PROF in 1J-1051-1 found the new B MBE at 9900' RKB to 1J-107 B Lat. A fullbore RPPG job on 12/5/19 treated the MBE with 5940 lbs of RPPG, but post -job SWI response shows 1J-1051-1 not regaining positive WHIP yet with over -30 days at 500 - 1000 BWPD. It's assumed the MBE treatment may have failed, but it's also possible the MBE is sealed, and low BHP matrix is taking SWI with WHIP on vacuum. Thus, CT F&S and [PROF will be performed (per separate procedure). If new IPROF shows B MBE at 9900' RKB is still open, this procedure will be ready to fullbore pump an RPPG retreatment to the MBE ASAP. Post-RPPG retreatment, 1J-1051-1 will be returned to SWI to evaluate retreatment results before restoring SWI to all 3 laterals. U-1051-1 is currently configured for B MBE treatment. The 'A' Lat was isolated by a Plug set at 7809' RKB on 10/29/19. A 'B' Diverter was set 11/7/19 at 7696' RKB, and a 'D' Iso-Slv was set 11/7/19 at 7332' RKB to isolate D Lat. A perf interval was shot 11/28/19 at 9925 - 9930' RKB near B MBE at 6 spf, 60 deg ph, using 'big hole' charges. ASF. No additional perforating is needed. It is proposed that the B MBE at 9900' RKB be retreated with RPPG (Reformed Polymer Particle Gel) to return 1J-1051-1 to SWI service. Procedure: Pumping: Verify that a post-RPPG job IPROF (of early 2020) on 1J -105L1 was performed and evaluated as indicating that an open B MBE still exists at +/- 9900' RKB before proceeding to step 1. 1) At -12 hours before the RPPG job, put 1J-1051-1 on SWI at 1000 BPD to displace Diesel FP and gas head from tubing to open B MBE to 1J-107. RU pumping equipment at 1J-105 the next morning. SI 1J-107 and 1J-1051-1, then immediately fullbore pump into 1J-1051-1 with 151 bbls (volume to MBE) of 2% KCL Brine at some steady rate between 1.5 to 4.0 bpm (rate TBD based on rate needed to let pump keep up with vac rate acting on well), followed by XX bbls of RPPG slurry mixed with 2% KCL Brine while adding 0.5 - 0.75 lbs/gal RPPG on -the -fly. Continue pumping 0.5 - 0.75 ppg slurry at steady rate until WHIP reaches 200 psi, then determine when to Flush by swap to 108 bbls of 2% KCL Brine displacement, followed by 41 bbls Diesel FP to 2000' TVD (2684' RKB), followed by Shutdown to trap WHP leaving RPPG treatment -1 bbl underdisplaced to B MBE. RD equipment. Wait 48 hrs for RPPG to cure in MBE to crosslinked non -flowing RPPG before returning 1J-1051-1 to injection or 1J-107 to production. Return 1J-1051-1 to SWI. Evaluate results of RPPG MBE treatment. THE STATE OfALASKA GOVERNOR MIKE DUNLEAVY John Peirce Sr. Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J-107 Permit to Drill Number: 207-107 Sundry Number: 319-520 Dear Mr. Peirce: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.aloslka.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, \-- - 'u— J Price Chair DATED this L5 day of November, 2019. RBDIws fF NOV 18 2019 RECEIVE' STATE OF ALASKA NOV 13 2019 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ,A®GCG 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: RPPG MBE TRTM'E1 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilli sAlaska Inc. Exploratory ❑ Development p • Stratigraphic El Service ❑ 207-107 ' 3. Address: 6. API Number: yb.o�y_,�3366-�-tD P. 0. Box 100360, Anchorage, Alaska 99510 500292336600 7. If perforating: 8. Well Name and Number: L i r-10 What Regulation or Conservation Order governs well spacing in this pool? N/A M �E jrw- 1 KRU 1J-107 ' Will planned perforations require a spacing exception? Yes ❑ No 21 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25661, ADL 25662 1 Kuparuk River Field /West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 12,073' • 3,656' 11792 3661 1500psi NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 77' 20" 108' 108' Surface 3,437' 13318 3,468' 2,275' Intermediate 8,696' 95/8 8,721' 3,717' Slotted Liner 3,623' 51/2 11,792' 3,661' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9778-11712 3663-3660 4.500" L-80 7,980' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): LEM Torque Master Packer 7973 MD and 3646 TVD ZXP Liner Top Packer 8170 MD and 3669 TVD 12. Attachments: Proposal Summary 0 Wellbore schematic 0 13, Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Strati ra hic ❑ Development[2] ment g p p ❑ Service ❑ 14. Estimated Date for 12/4/2019 15. Well Status after proposed work: Commencing Operations: OIL 71 • WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: O Shutdown GINJ ❑ P ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: John Peirce John Peirce Contact Name: Authorized Title: Sr. Wells Engineer Contact Email: John.W.Peirce@cop.com r Contact Phone: (907) 265.6471 Authorized Signature: W ,G Date: a)j2, 19 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: -Sao Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMSZ Nloy 1 g 2019 Post Initial Injection MIT Req'd? Yes ❑ No ❑ pi,I Spacing Exception Required? Yes ❑ No Subsequent Form Required: APPROVED BY '�� Approved by: COMMISSIONER THE COMMISSION Date: �� JN iP� �� 1 1 1 % ��yY�i ,sand Sub mi[ Form and rm 1-403 Re d 4 2ov Approved application i li r to of approval. Attachments in Duplicate . l� �pDrJ" �'j k' Syl Proposal for 1J-1051-1 to 1J-107 RPPG B MBE Treatment 1J-105 Tri -lateral injector was drilled & completed in 2007 with laterals in West Sak A, B, & D sands. 1J -105L1 B Lat has a 4.5", L-80 slotted liner. Multiple B MBE's have occurred in 1J -105L1. The first B MBE occurred 4/5/12 from 1J -105L1 to 1J-1031-1 producer. A 5/26/12 IPROF found a B MBE at 9550' RKB taking all PWI. On 9/24/12, a 1J-1051-1 Crystal Seal job sealed the MBE for —3 months. A 3/24/13 IPROF verified the B MBE at —9550' had reopened, then an 8/10/13 Crystal Seal retreatment was pumped. This retreatment lasted —3 years until another MBE occurred on 3/9/16. A 5/25/16 IPROF in 1J-1051-1 found a new MBE at 9750' RKB. On 4/30/17, an RPPG treatment sealed the MBE at 9750' RKB and this treatment lasted until 10/20/19 when a new MBE occurred from 1J -105L1 to 1J-107. This is the first MBE from 1J -105L1 to 1J-107 11/8/19 IPROF in 1J-1051-1 found the new B MBE exists at 9900' RKB to 1 J-107 B Lat. 1J-1051-1 is currently configured for a B MBE treatment. The 'A' lateral was isolated by a Plug set at 7809' RKB on 10/29/19. A 'B' Diverter was set at 7696' RKB on 11/7/19 (for B Lat (PROF of 11/8/19), and a 'D' Iso-Slv was set 11/7/19 at 7332' RKB to isolate the D Lat. It is proposed that the new B MBE at 9900' RKB be sealed with RPPG (Reformed Polymer Particle Gel) to return 1J -105L1 to SWI service. Procedure: Coil Tubing: 1) RIH with pert gun & shoot 5' OAL large hole perfs in 4.5" OD blank liner at +/- 9895' RKB in D Lat near the 'B' MBE. POOH with gun. Verify all shots fired. RD CTU. Pumping: 2) At —12 hours before planned RPPG job, put 1J -105L1 on SWI at 1000 BPD to displace Diesel FP and gas head from tubing to open B MBE to 1J-107. RU pumping equipment at 1J-105 next morning. i SI 1J-107 and 1J-1051-1, and then immediately fullbore pump into 1J-1051-1 with 150 bbls (= tubing + liner volume to MBE) of 2% KCL Brine at steady rate between 1.5 to 4.0 bpm (pump rate will depend on what rate is needed to let the pump keep up with the vacuum rate seen acting on the well), followed by XX bbls of RPPG slurry mixed with 2% KCL Brine while adding 0.5 - 0.75 lbs/gal RPPG on -the -fly. Continue pumping 0.5 - 0.75 ppg slurry at a steady rate until WHIP reaches 500 to 800 psi, then swap to 108 bbls of 2% KCL Brine displacement, followed by 41 bbls Diesel FP to 2000' TVD (2684' RKB), followed by shutdown to leave the RPPG treatment —1 bbl underdisplaced to B MBE. RD pumping equipment. Wait 48 hrs for RPPG to cure in MBE to crosslinked non -flowing RPPG before returning 1J -105L1 to injection or 1J-107 to production. Return 1J-1051-1 to SWI to evaluate results of the RPPG B MBE treatment. After sufficient evaluation time to verify that B MBE is sealed, 1J-105 will be reconfigured to restore SWI to all three laterals. KUP PROD WELLNAME U-107 WELLBORE 1J-107 Conoco Well Attributes Max Angle & MD TD WeIIWre APINWI W¢I,-AGrems IltPcl^o) IMOnX aR) Aq Bim DUKE) Alaska, INC. IWFCT CGN I5(Ip]9J3 u. PRiVt, d oA n se 1J-101, 11 /1LID1911:16W PM Last Tag Vervnletlwretic (ecmtll Ametatbn Cepm MIN all DAN Wines- Last MW By ............................... _..._................ ..._......._._.................._ MANGER; A7� Last Tag: 1J-iW tripfwj Last Rev Reason AnnoNlion EAtl "i AIIWra Ry Rev Reason: GLV CIO #3 111220ll 1J-10]Wpprav"Ie"'l dn Casing Strings CONDUCTOR: 31.0-10Vd NIPPLE; Gt9 GAS UFT P.dN6--. SURPAGE:2D43b°]JI t. A L, D,tat Gns urrn.]i8.e GAucE, Tara) LOCATOR; ),603.] sEALAsaY;7,91Ge SlSsjsa] NIPPLE 7.gj5.4 CENTRAUZER7,9ea.a XXOT.. ISo ANCHOR i9T].] D LINER SLOTTED 8.041.8- izolss D LINER LEM', ],g]368,A18 51142010 INTERMEDIATE', YG.88.TU.G yII1S SLOTS, 9,2]9GI1.112.D— I E LINER SLOTTED: &1®S 11.]93.0— CONDU eniR 20 1 (i12 Top mKel 108.0 mmrce) 10 Depm (rvD1... 94.00 p... H4" Top TM1reea CONDUCTOR 20 19.12 108.0 94.00 H<0 T31 op Casing Dexrlp4an OD 6n) ID (in) 30,4 ) Set 7.8 (XHBI set 01 FIVE) wlnzn p... GnOe iop Threetl a" Do SURFACE 13318 12 d1 304 3,4828 2,215.4 68.00 L-80 BTC Casing Deeclllllion OD (in) ID (in) Top DUKE) eH Depth DUKE) Sol a (rvDl... WUIen O... Grade Tap T'No' INTERMEDIATE 9518 8.83 24B 8,]21.0 3,7'aR 4000 LA0 BTCM caem9 Dazcripnon ED (in) IS (in) Top mica) Set Death mind Set Depth (Np)... w11Lm p... GmEe roprnreait B LINER SLOTTED 5112 4.95 8,169.5 11,7920 3,6610 15.58 L-80 IBT-M Liner Details xaminAl lD Top mKe) Top(rvD)(RKa) Top Incl (') I Item De: Com (in) 8,1695 3,8693 83.27 PACKER BAKER'ML' ZXP LINER TOP PACKER 6.320 8,190.7 3,671.8 83.24 HANGER FLEX LOCK LINER HANGER 6200 8,1960 3,6]24 83.24 XO BUSHING CROSSOVERBUSHINO 4910 8,19]4 3,6]26 83.24 SBE 19047 SEAL BORE EXTENSION 4750 %6497 3,658.2 8852 Swell Packer EASYWELL SWELL PACKER 4.950 11,7209 3,6597 89 OB Swell Packer EASYWELL SWELL PACKER 4.950 Caving Deacriptlan ODpn) ID (in) Toppli Set DepMmKp Btl Depth(rVO)._INDIA'a Goee Top Thread DLINER LF M 4112 39fi 7,973.4 8207.8 30738 12.68 L-80 IBTM Liner Details Tap mica) rop(NDI ME) Top Incl M nem Des Com nominal lOpp 7,973.4 3fi,4631 83.16 PACKER LEMTmeeeMom (Packer 3.950 8,006.0 3,650.1 83.22 NIPPLE LEM DO pippin3750 8,124.2 3,6640 BT32 NIPPLE LEIM 3.562"'De'Nipple 3.562 8,204.6 3,673.4 8323 SEALASSY LEM SEALABSEMBLY 3.870 Tubing Strings Tubing Oesaaptio n shmg Ma...ID pn) Top (XHB) sal Oepin m., setDepm OVID f.. w[{mry) Grade Tap Connection TUBING WO 2016 4112 396 23.7 7,979.8 3,fi47.0 12.60 L -So IBTM Completion Details "Re') Top Incl Nominal Top IRKR 1 (UNID (°) 11em Des Cam ID(in) 23.7 233 0.00HANGER Wine —Gray Tubing Hanger(dlifted3895"Mol 4-%"IBT-M 3.958 Pup Joint 3INI, 492.4 491.6 7.86 NIPPLE Camm4=h"x3.8]5" DBA Lending Nipple(IBT-M BxP) 3.875 7,848.1 3,631.2 83.30 GAUGE Unique Gouge Carrier (4-/," e) IBT-M Coupling BH Sures NS 3.958 125P Gauge w/TEC cr ],8097 3,838.] 63.03 LOCATOR Baker Loceter Sub 3.950 7,9109 3,638.8 83.03 SEALASSY Baker 17'8047 Seal Assembly. 4.79 feet up from hilly located 3.900 7,9153 3,6394 83.05 SBE Baker 18' 8047 PBR SHEARED 4350 7,955.4 3,644.1 83.16 NIPPLE Cameo 4-%"3.813" DB Landing Nipple(IBT-M BxP) 3.813 7,966.8 3,645.5 83.1]CENTRALIZER 4%'x8" fluted centralizer 4.000 J,9A.J 3,646.6 83.18 ANCHOR Baker ML Production Anchor 81FA47,4=h"IBT-M Box) 3.880 Perforations & Slots TaP DUKE/ EIm IXKB1 Top(ND) DUKE) at. RV IXKB) LInkN Zone paN snot Dens (sn ob" 1 TYce Com 9,778.0 11712.0 3,663.1 ,659.6 WS B, 1J-107 98/2007 M05LOTS 100%slotted liner, 25"x.125'.4 circumferential raves", W centers Staggered 18 deg Mandrel Inserts m N Top(1VD) Valve latah Parl9ix T... Top DUKE) DUKE) Make Matlel OD(in) sary Type Type (Ind sell Run Date Com 1 2,7515 2,002.3Camce KBMG 1 GAS LIFT GLV BK 0.188 1,478.0 SIt012016 2 6,144.2 3,216.3 Cemcb KBMG 1 GAS LIFT DMY BKS 0.000 0.0 5/fi201fi 3 7,779.8 31823.3 Camco KBMG 1 GAB LIFT OV BK 0.313 0.0 10I1120D Notes: General & Safety End DUN AnnabXan 9/152007 NOTE: MULTI-IATERAL WELL- 17107(BSAND). 1J-10A1(DSAND) WN2008 NOTE: VIEW SCHEMATIC whMaska SChemai0 NOTE: WELL CONVERTED FROM ESP TO GAS LIFT PRODUCTION • { STATE OF ALASKA A KA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E Plug Perforations r Fracture Stimulate r Pull Tubing F Operations Shutdown Performed: Suspend E Perforate E Other Stimulate pr Alter Casing Change Approved Program Plug for Redrill E Perforate New Pool E Repair Well E Re-enter Susp Well E Other. Install Gas Lift F 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory r 207-107 _ 3.Address: 6.API Number: Stratigraphic E Service P.O. Box 100360,Anchorage,Alaska 99510 50-029-23366-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25661,ADL 25662 KRU 1J-107 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NONE Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 12073 feet Plugs(measured) None true vertical 3656 feet Junk(measured) None Effective Depth measured 11792 feet Packer(measured) 7973,8169 true vertical 3661 feet (true vertical) 3646,3669 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 20 108 108 SURFACE 3437 13 3/8 3468 2275 INTERMEDIATE 8696 9 5/8 8721 3717 B LINER SLOTTE 3623 5 1/2 11792 3661 FIVEPerforation depth: Measured depth: 9778-11712 -E _ �� True Vertical Depth: 3663-3660 JUN n 1 2016 Tubing(size,grade,MD,and TVD) 4.5, L-80,7980 MD,3647 TVD AOGCO Packers&SSSV(type,MD,and ND) PACKER-LEM TorqueMaster Packer @ 7973 MD and 3646 TVD PACKER-BAKER ML ZXP Liner Top @ 8169 MD and 3669 ND SSSV: NONE 12.Stimulation or cement squeeze summary: WOMB ,, I- i o r f11j Intervals treated(measured): none 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 236 447 120 645 175 Subsequent to operation Shut-in 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory E Development F Service 1Stratigraphic E Copies of Logs and Surveys Run r 16.Well Status after work: Oil F Gas E WDSPL E Printed and Electronic Fracture Stimulation Data I- GSTOR r' WINJ E WAG f' GINJ E SUSP E SPLUG i,.:... 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: N/A Contact Danny Kane a 265-6048 Email Danny.Kaneaconocophillips.com Printed Name Danny Kane Title Sr. Wells Engineer SignaturePhone:265-6048 Date —N•P.y—Z05 I Co Irrc. 7/0/1 Form 10-404 Revised 5/2015 `��% RBDMS Lk, RAI 0 Z 2016 L Submit Original Only Operations Summary (with Timelog Depths) Of 1J-107 ConocoPhiffips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End lime Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/1/2016 5/1/2016 4.50 MIRU MOVE MOB P Moved Rig from 1J-182 to 1J-107. 00:00 04:30 Sub over the Well @ 0430. 5/1/2016 5/1/2016 3.50 MIRU MOVE MOB P Positioned remaining Modules. 04:30 08:00 5/1/2016 5/1/2016 4.00 MIRU MOVE RURD P Rigged up and connected lines to Pits 08:00 12:00 and work Rig accept list. Rig accepted at 1200 Hrs. 5/1/2016 5/1/2016 1.50 MIRU MOVE RURD P Rigged up lines to the Tree and Flow 12:00 13:30 back tank. 5/1/2016 5/1/2016 0.50 MIRU MOVE SEQP P Pressure test line to Choke House 13:30 14:00 250/2500 psi.Test Good. 5/1/2016 5/1/2016 1.25 MIRU WELCTL OWFF P IA had 800 psi.bled down to FB Tank 14:00 15:15 to 580 psi. 5/1/2016 5/1/2016 1.00 MIRU WELCTL MPSP P PU and Tested Lubractor.Pulled BPV. 15:15 16:15 5/1/2016 5/1/2016 1.00 MIRU WELCTL OWFF P IA had 580 psi.Tbg 300 psi.bled 16:15 17:15 down IA to FB Tank to 560 psi. 5/1/2016 5/1/2016 3.00 MIRU WELCTL KLWL P Pumped 720 Bbls 8.6 PPG 3%KCL 17:15 20:15 Brine down Tubing @ 4 BPM 130 psi returns lined up to FB Tank.Only Gas returns.No Fluid. 5/1/2016 5/1/2016 0.50 MIRU WELCTL OWFF P Observed Well on Vacum then had 20:15 20:45 small amount of gas coming from IA. 5/1/2016 5/1/2016 1.00 MIRU WELCTL KLWL P Pumped 150 Bbls 8.6 PPG 3%KCL 20:45 21:45 Brine down IA @ 5 BPM 130 psi returns lined up to FB Tank Via Tubing.No returns.No Fluid. 5/1/2016 5/1/2016 0.25 MIRU WELCTL OWFF P Observed Well on Vacum then had 21:45 22:00 small amount of gas coming from IA. 5/1/2016 5/1/2016 0.75 MIRU WELCTL KLWL P Pumped 59 Bbls 8.6 PPG 3%KCL 22:00 22:45 Viscostified Brine down IA @ 5 BPM 130 psi retums lined up to FB Tank Via Tubing.No returns. 5/1/2016 5/2/2016 1.25 MIRU WELCTL OWFF P Observed Well on Vacum then had 22:45 00:00 small amount of gas coming from IA. Installed gauge and monitered for pressure. 1.5 psi.Opened back and Well died. 5/2/2016 5/2/2016 0.75 MIRU WHDBOP MPSP P Checked Pressure on IA 1.5 PSI.Bled 00:00 00:45 off.Installed BPV. 5/2/2016 5/2/2016 1.50 MIRU WHDBOP NUND P Nippled down Tree and installed 00:45 02:15 Blanking Plug. 5/2/2016 5/2/2016 2.50 MIRU WHDBOP NUND P Nipple up BOP. 02:15 04:45 5/2/2016 5/2/2016 1.00 MIRU WHDBOP RURD .P Set Test Joint and RU to test. 04:45 05:45 Page 1/6 Report Printed: 5/10/2016 0 Operations Summary (with Timelog Depths) 1J-107 ConocoPhillips AP.xks Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/2/2016 5/2/2016 4.50 MIRU WHDBOP BOPE P PJSM-Test BOPE w/4 1/2"test joint to 05:45 10:15 250/2500 psi for 5 min each.#1:Top pipe rams,CV 1,12,13, 14&manual kill valve.#2:Upper IBOP,HCR kill, CV 9,&11.#3:Lower IBOP,CV 5,8& 10. #4:Dart„CV 4,6&7. #5:FOSV and CV 2. #6:HCR choke&4"kill line Demco valve, #7:Manual choke valve&HCR kill. #8:Annular preventer.#9:Lower pipe rams.#10: Blind rams and CV 3.Accumulator test:system pressure=2950 psi,After closing=1300 psi,200 psi attained after 44 sec,full pressure attained after 174 sec,Five bottle nitrogen avg=2020 psi.Performed drawdown test on manual and hydraulic chokes. PVT and gas alarms tested. BOPE test witness waived by AOGCC Rep. Chuck Schieve.. 5/2/2016 5/2/2016 0.50 MIRU WHDBOP RURD P Rig down BOP test Equipment. 10:15 10:45 5/2/2016 5/2/2016 0.25 COMPZN RPCOMP MPSP P Pulled BPV and Blanking plug. 10:45 11:00 5/2/2016 5/2/2016 0.50 COMPZN RPCOMP RURD P Rigged up to Pull tubing.Made up 11:00 11:30 Landing Jt and backed out lock down screws. 5/2/2016 5/2/2016 0.50 COMPZN RPCOMP PULL P Picked up Tubing Hanger Free with 7,900.0 7,878.0 11:30 12:00 250K.Picked up to Rig Floor. 5/2/2016 5/2/2016 1.00 COMPZN RPCOMP RURD P Picked up ESP cable spooler tools to 7,878.0 7,878.0 12:00 13:00 rig floor. 5/2/2016 5/2/2016 0.50 COMPZN RPCOMP PULL P Laid down Tubing Hanger. 7,878.0 7,878.0 13:00 13:30 5/2/2016 5/2/2016 1.00 COMPZN RPCOMP RURD P Rigged up to Spool ESP cable. 7,878.0 7,878.0 13:30 14:30 5/2/2016 5/2/2016 8.00 COMPZN RPCOMP PULL P POOH standing back tubing SLM 7,878.0 102.0 14:30 22:30 while spooling ESP cable.Laid down 3 GLM's,Discharge Sub,and 1 Bad joint of tubing(bad theads). Recovered 147 Clamps and 10 SS Bands. 5/2/2016 5/3/2016 1.50 COMPZN RPCOMP PULL P Break down and lay down ESP and 102.0 0.0 22:30 00:00 Screens. 5/3/2016 5/3/2016 0.50 COMPZN RPCOMP SFTY P Pre job safety meeting on rigging 0.0 0.0 00:00 00:30 down Centrilift equipment 5/3/2016 5/3/2016 1.00 COMPZN RPCOMP RURD P -Rig down Centrilift sheaves and 0.0 0.0 00:30 01:30 spoolers 5/3/2016 5/3/2016 0.50 COMPZN RPCOMP OTHR "P Mobilize wearing ring and fishing tools 0.0 0.0 01:30 02:00 to rig floor 5/3/2016 5/3/2016 0.50 COMPZN RPCOMP SVRG P Service rig 0.0 0.0 02:00 02:30 5/3/2016 5/3/2016 0.50 COMPZN RPCOMP OTHR P Clear rig floor 0.0 0.0 02:30 03:00 5/3/2016 5/3/2016 0.50 COMPZN WHDBOP OTHR P Set wear ring(9"I.D.) 0.0 0.0 03:00 03:30 5/3/2016 5/3/2016 1.00 COMPZN RPCOMP SFTY P Safety meeting on picking up casing 0.0 7,456.0 03:30 04:30 scraper and jetted nozzle Page 2/6 Report Printed: 5/10/2016 • • 0 tz Operations Summary (with Timelog Depths) 0 1J-107 Conocciehilliip rs tis Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/3/2016 5/3/2016 6.75 COMPZN RPCOMP TRIP P RIH with scraper and jetted nozzle on 7,456.0 7,717.0 04:30 11:15 4-1/2"tubing out of the derrick to 7456'. Work pipe to 7717'. Pump 5 bbl from trip tank every 1/2 hour. Fluid level at 1278'via echometer. 5/3/2016 5/3/2016 0.25 COMPZN RPCOMP CIRC P Pump 2 bpm at 500 psi. Pressure 7,717.0 7,717.0 11:15 11:30 decreased to 300 psi 5/3/2016 5/3/2016 0.50 COMPZN RPCOMP CIRC P Bullhead 53 bbl seawater down tubing 7,717.0 7,717.0 11:30 12:00 and IA @ 7 bpm @ 0-38 psi 5/3/2016 5/3/2016 0.50 COMPZN RPCOMP TRIP P Continue to single in the hole from 7,717.0 7,790.0 12:00 12:30 7717'to 7790'. 5/3/2016 5/3/2016 0.75 COMPZN RPCOMP WASH P Wash from 7790'to 7905'. pumping at 7,790.0 7,905.0 12:30 13:15 2 bpm© 1000 psi. Bullhead 20 bbl down IA at 6 bpm at 50 psi 5/3/2016 5/3/2016 1.75 COMPZN RPCOMP WASH P Continue washing down at 2 bpm @ 7,906.0 7,986.0 13:15 15:00 850 psi from 7906'to 7986'. Tag on No-go @ 7986' Set down 10k and close annular. Pressure up on IA to 400 psi to confirm tag on No-go. Bleed pressure and open annnular. Pick up 15'and close annular. Bullhead 200 bbl down IA clean seal assembly @ 500 gpm @ 150 psi 5/3/2016 5/3/2016 0.50 COMPZN RPCOMP OWFF P -Observe well for flow while rigging up 7,986.0 7,986.0 15:00 15:30 to L/D 4-1/2"tubing 5/3/2016 5/3/2016 3.00 COMPZN RPCOMP PULD 'P Lay down 4-1/2"tubing from 7986'to 7,986.0 5,990.0 15:30 18:30 5990' 5/3/2016 5/3/2016 0.50 COMPZN RPCOMP SFTY T GBR hydraulic unit developed leak in 5,990.0 5,990.0 18:30 19:00 high pressure hose. Change out unit. Spill confined to secondary containment. Kuparuk security notfied. 5/3/2016 5/3/2016 4.50 COMPZN RPCOMP PULD Continue laying down tubing from 5,990.0 740.0 19:00 23:30 5990'to 740'. Started pulling wet. 5/3/2016 5/3/2016 0.25 COMPZN RPCOMP CIRC Attempt to circulate down tubing. 740.0 740.0 23:30 23:45 Pressured up to 1350 psi without success 5/3/2016 5/4/2016 0.25 COMPZN RPCOMP TRIP Continue POOH racking back tubing 740.0 730.0 23:45 00:00 5/4/2016 5/4/2016 1.25 COMPZN WELLPR TRIP P POOH from 730'racking back 8 730.0 0.0 00:00 01:15 stands of tubing. 5/4/2016 5/4/2016 1.00 COMPZN WELLPR BHAH P Lay down scraper and jetted nozzle 0.0 0.0 01:15 02:15 5/4/2016 5/4/2016 0.50'COMPZN WELLPR TRIP P RIH with 8 stands of tubing out of 0.0 730.0 02:15 02:45 derrick 5/4/2016 5/4/2016 0.50-COMPZN WELLPR PULD P Lay down 24 joints of 4-1/2"tubing 730.0 0.0 02:45 03:15 5/4/2016 5/4/2016 1.00 COMPZN WELLPR RURD P Clean and clear rig floor 0.0 0.0 03:15 04:15 5/4/2016 5/4/2016 0.25 COMPZN WELLPR RURD P Pull wear ring 0.0 0.0 04:15 04:30 5/4/2016 5/4/2016 0.50 COMPZN RPCOMP RURD P Mobilize Centrilift equipment to the rig 0.0 0.0 04:30 05:00 floor 5/4/2016 5/4/2016 1.75 COMPZN RPCOMP RURD P Rig up spooler 0.0 0.0 05:00 06:45 5/4/2016 5/4/2016 0.25 COMPZN RPCOMP SFTY P Safety meeting on running 4-1/2" 0.0 0.0 06:45 07:00 tubing 5/4/2016 5/4/2016 0.25 COMPZN RPCOMP OTHR P Connect Tech wire to probe 0.0 0.0 07:00 07:15 Page 3/6 Report Printed: 5/10/2016 Ill s Operations Summary (with Timelog Depths) 0 a 1J-107 1101 cPm(lips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth ' Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/4/2016 5/4/2016 0.25 COMPZN RPCOMP PUTB P Pickup Baker anchor/seal assembly,1 0.0 0.0 07:15 07:30 joint of tubing and gauge carrier 5/4/2016 5/4/2016 0.25 COMPZN RPCOMP OTHR P Connect Tech wire to gauge carrier 0.0 0.0 07:30 07:45 and test continuity 5/4/2016 5/4/2016 0.50 COMPZN RPCOMP PUTB P Pick up landing nipple,one joint of 0.0 234.0 07:45 08:15 tubing and 1 GLM 5/4/2016 5/4/2016 10.50 COMPZN RPCOMP `PUTB P Continue RIH with 4-1/2"completion 234.0 7,979.0 08:15 18:45 from 234'to 7979' 5/4/2016 5/4/2016 4.00 COMPZN RPCOMP PACK T Tag top of packer with anchor at 7,979.0 7,979.0 18:45 22:45 7979'. P/U=94k,5/0=59k. Set down 5-15k. Unable to latch anchor. Put 1/4 turn in string and continue to work pipe w/o success. Pump down tubing at 8 bpm to clean out top of packer. Continue to rotate string in 1/4 turn increments and work pipe until a full turn was applied to the tubing. Set down and fill annulus with inhibitted brine and fluid level dropped. 5/4/2016 5/5/2016 1.25 COMPZN RPCOMP -PULL T POOH laying down 4-1/2"tubing string 7,979.0 7,500.0 22:45 00:00 from 7979'to 7500' 5/5/2016 5/5/2016 7.50 COMPZN RPCOMP PULL T POOH laying down 4-1/2"completion 7,500.0 104.0 00:00 07:30 from 7500'to 104'. Pump 4 bbl every 10 joints. 5/5/2016 5/5/2016 0.50 COMPZN RPCOMP PULL T Disconnect Tec Wire from Gauge 104.0 104.0 07:30 08:00 Carrier 5/5/2016 5/5/2016 0.25 COMPZN RPCOMP PULL T Lay down completion jewelry 104.0 0.0 08:00 08:15 5/5/2016 5/5/2016 1.00 COMPZN RPCOMP RURD T Clean and clear rig floor 0.0 0.0 08:15 09:15 5/5/2016 5/5/2016 1.25 COMPZN RPCOMP SLPC T Slip and cut drilling line. Note: 0.0 0.0 09:15 10:30 Concurrent operation-load pipe shed with 4"drillpipe 5/5/2016 5/5/2016 - 0.50 COMPZN 'RPCOMP SVRG T Service rig and top drive 0.0 0.0 10:30 11:00 5/5/2016 5/5/2016 0.50 COMPZN RPCOMP RURD T Mobilize Baker tools to the rig floor 0.0 0.0 11:00 11:30 5/5/2016 5/5/2016 0.50 COMPZN RPCOMP BOPE T Rig up to test BOPE with 4"test joint. 0.0 0.0 11:30 12:00 Fill hole with 30 bbl sea water. 5/5/2016 5/5/2016 0.50 COMPZN RPCOMP OTHR T Continue to load pipe shed with 4" 0.0 0.0 12:00 12:30 drillpipe 5/5/2016 5/5/2016 1.50 COMPZN RPCOMP BOPE T Test UPR's,LPR's and annular to 0.0 0.0 12:30 14:00 250/3000 psi with 4"test joint. 5/5/2016 5/5/2016 0.75 COMPZN RPCOMP BOPE T Rig down test equipment and st wear 0.0 0.0 14:00 14:45 bushing(9"I.D.) 5/5/2016 5/5/2016 0.25 COMPZN RPCOMP RURD T Change elevators to 4" 0.0 0.0 14:45 15:00 5/5/2016 5/5/2016 • 0.50 COMPZN RPCOMP BHAH T Pick up BHA#2 0.0 35.0 15:00 15:30 5/5/2016 5/5/2016 4.50 COMPZN 'RPCOMP .PULD T RIH picking up singles out of the 35.0 7,943.0 15:30 20:00 pipeshed from 35'to 7943' 5/5/2016 5/5/2016 0.50 COMPZN RPCOMP WASH T Wash down from 7943'to 7986'with 7,943.0 7,986.0 20:00 20:30 nozzle. Locate on top of packer at 7979'. Set down 10k. Pick up and circulate down drillpipe at 8 bpm while rotating 15 rpm. Pump a total of 200 bbl. P/U=114k,S/O=68k. Rot= 86k. Page 4/6 Report Printed: 5/10/2016 • • _z Operations Summary (with Timelog Depths) a s 1J-107 ConocoPhitliips Al. Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(EKE) 5/5/2016 5/5/2016 0.75 COMPZN RPCOMP CIRC T Close pipe rams and bullhead 515 7,986.0 7,986.0 20:30 21:15 bbls seawater at 780 gpm. Open pipe rams and tag top of packer at 7979' with nozzle at 7986' 5/5/2016 5/5/2016 2.25 COMPZN RPCOMP TRIP T POOH racking drillpipe in derrick 7,986.0 65.0 21:15 23:30 5/5/2016 5/6/2016 0.50 COMPZN RPCOMP BHAH T Lay down BHA and clean magnets. 65.0 0.0 23:30 00:00 Minor amount of filings on magnets 5/6/2016 5/6/2016 0.25 COMPZN RPCOMP BHAH T Lay down clean out BHA 0.0 0.0 00:00 00:15 5/6/2016 5/6/2016 0.50 COMPZN RPCOMP RURD T Clear rig floor 0.0 0.0 00:15 00:45 5/6/2016 5/6/2016 0.25 COMPZN WHDBOP OTHR T Pull wear bushing 0.0 0.0 00:45 01:00 5/6/2016 5/6/2016 0.50 COMPZN RPCOMP -RURD T Mobilize tongs and spooler to the rig 0.0 0.0 01:00 01:30 floor 5/6/2016 5/6/2016 0.75 COMPZN RPCOMP -RURD T Rig up tubing tongs and spooler 0.0 0.0 01:30 02:15 5/6/2016 5/6/2016 0.75 COMPZN RPCOMP PUTB T Make up anchor and PBR 0.0 250.0 02:15 03:00 5/6/2016 5/6/2016 0.75 COMPZN RPCOMP OTHR T Connect Tec Wire to gauge carrier 250.0 250.0 03:00 03:45 5/6/2016 5/6/2016 8.25 COMPZN RPCOMP RCST T Pick up 4-1/2"completion string from 250.0 6,570.0 03:45 12:00 250'to 6570' 5/6/2016 5/6/2016 1.50 COMPZN RPCOMP RCST T Continue to RIH with 4-1/2" 6,570.0 7,979.0 12:00 13:30 completion from 6570'to 7979' 5/6/2016 5/6/2016 1.25 COMPZN RPCOMP PACK T Tag up on no-go at 7979.76'. Set 7,979.0 7,979.0 13:30 14:45 down 10K to set anchor. Pick up and saw 10K overpull indicating anchor set. Pull up to neutral weight and fill IA with 450 bbl of corrosion inhibitted brine. P/U=93K,S/O=63K 5/6/2016 5/6/2016 0.25 COMPZN RPCOMP PACK P Pull up to 137K(44K overpull)and 7,979.0 7,915.0 14:45 15:00 shear out of PBR. Set down on no-go of PBR at 7915'- 5/6/2016 5/6/2016 1.00 COMPZN RPCOMP HOSO P Pull out of PBR. L/D 3 joints of tubing 7,915.0 7,915.0 15:00 16:00 and pick up space out pups(3.41', 7.82',9.80',9.81')and one joint of tubing. 5/6/2016 5/6/2016 1.50 COMPZN RPCOMP THGR P Make up hanger and terminate TEC 7,915.0 7,915.0 16:00 17:30 Wire through hanger 5/6/2016 5/6/2016 1.25 COMPZN RPCOMP CRIH P Sting into PBR with seals and fill IA 7,915.0 7,915.0 17:30 18:45 with corrosion inhibitted brine 5/6/2016 5/6/2016 1.00 COMPZN RPCOMP THGR P Land hanger and RILDS. Test upper 7,915.0 7,915.0 18:45 19:45 and lower seals on tubing hanger to 5000 psi 5/6/2016 5/6/2016 0.50 COMPZN WHDBOP RURD P Lay down landing joint and set BPV 7,915.0 7,915.0 19:45 20:15 5/6/2016 5/6/2016 0.75 COMPZN WHDBOP NUND P Nipple down BOPE 7,915.0 7,915.0 20:15 21:00 5/6/2016 5/6/2016 0.50 COMPZN WHDBOP NUND P Change tubing head adapter on Xmas 7,915.0 7,915.0 21:00 21:30 tree 5/6/2016 5/6/2016 1.25 COMPZN WHDBOP -NUND P Nipple up Xmas tree 7,915.0 7,915.0 21:30 22:45 5/6/2016 5/6/2016 0.50 COMPZN WHDBOP NUND P Terminate Tec Wire 7,915.0 7,915.0 22:45 23:15 5/6/2016 5/7/2016 0.75 COMPZN WHDBOP NUND T Trouble shoot threads on penetrator 7,915.0 7,915.0 23:15 00:00 Page 5/6 Report Printed: 5/10/2016 • ! y Operations Summary (with Timelog Depths) 1J-107 'C€nocoPhtllbps Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/7/2016 5/7/2016 0.50 COMPZN WHDBOP PRTS P Terminate and test TEC wire. 7,915.0 7,915.0 00:00 00:30 Guardian gauge functioning. BHP= 1190 psi BHT=66.94 F 5/7/2016 5/7/2016 0.25 COMPZN WHDBOP PRTS P Test tubing hanger void to 5000 psi for 7,915.0 7,915.0 00:30 00:45 10 minutes 5/7/2016 5/7/2016 1.00 COMPZN WHDBOP THGR P Pull BPV and install 2-way check. Fill 7,915.0 7,915.0 00:45 01:45 tree with diesel 5/7/2016 5/7/2016 1.25 COMPZN WHDBOP PRTS P Test tree to 250 psi for 5 minutes and 7,915.0 7,915.0 01:45 03:00 to 5000 psi for 10 minutes 5/7/2016 5/7/2016 0.25 COMPZN WHDBOP THGR P Pull 2-way check 7,915.0 7,915.0 03:00 03:15 5/7/2016 5/7/2016 0.50 COMPZN WHDBOP PRTS P Test IA to 2500 psi for 30 minutes. 7,915.0 7,915.0 03:15 03:45 Record test on chart 5/7/2016 5/7/2016 0.25 COMPZN WHDBOP OTHR P Pressure up on IA to 3025 psi to shear 7,915.0 7,915.0 03:45 04:00 SOV 5/7/2016 5/7/2016 0.75 COMPZN WHDBOP FRZP P Rig up LRS and test lines to 2500 psi 7,915.0 7,915.0 04:00 04:45 5/7/2016 5/7/2016 3.75 COMPZN WHDBOP 'FRZP P Freeze protect well by pumping 154 7,915.0 7,915.0 04:45 08:30 bbl diesel down IA followed by 39 bbl diesel down tubing. 5/7/2016 5/7/2016 0.25 COMPZN WHDBOP 'FRZP P Rig down LRS 7,915.0 7,915.0 08:30 08:45 5/7/2016 5/7/2016 3.25 COMPZN RPCOMP PULD P Lay down 4"drillpipe out of the derrick 7,915.0 7,915.0 08:45 12:00 5/7/2016 5/7/2016 2.00 COMPZN RPCOMP PULD P Continue to lay down 4"drillpipe out of 7,915.0 7,915.0 12:00 14:00 the derrick 5/7/2016 5/8/2016 10.00 DEMOB MOVE DMOB P Pre rig to move to 2G-03. De-ice 7,915.0 7,915.0 14:00 00:00 derrick. Work on drag chains in pits and rockwasher. Change oil in top drive. Repair skate. Change oil in drawworks.Clean suction screens and manifolds on mud pumps. Release rig at 24:00 hours 5/7/2016 Page 616 Report Printed: 5/10/2016 • r„ • KUP PD 1J-107 ConocoPhillips rs a+t wt Well Attribute Max Angle TD Alaska Inc Wellbore APUUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Lonocoimahps 500292336600 WEST SAK PROD 96.49 9,103.81 12,073.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date 1J-107,5/20/2016:22220 PM SSSV:NIPPLE 75 8/11/2015 Last WO: 5/7/2016 32.29 9/15/2007 verscal nchompl(E OVA* "Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:WORKOVER lehallf 5/10/2016 HANGER,23.7 iI 4ul'- Casing Strings Casing Description ` OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 20 19.124 31.0 108.0 108.0 94.00 H-40 I`u Casing Description (in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 13 3/8 12.415 30.4 3,467.8 2,275.4 68.00 L-80 BTC Casing Description OD(in) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wtllen p...Grade Top Thread INTERMEDIATE 95/8 8.835 24.8 8,721.0 3,716.8 40.00 L-80 BTCM CONDUCTOR;31.0-108.0-a s Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread B LINER SLOTTED 5 1/2 4.950 8,169.5 11,792.0 3,661.0 15.50 L-80 IBT-M Liner Details Nominal ID NIPPLE;492.4 Top(ftKB) Top(ND)(ftKB) Top Incl r) Item Des Com (in) 8,169.5 3,669.3 83.27 PACKER BAKER'MU ZXP LINER TOP PACKER 6.320 I8,190.7 3,671.8 83.24 HANGER FLEX LOCK LINER HANGER 6.200 GAS LIFT;2,751.8 I. 8,196.0 3,672.4 83.24 XO BUSHING CROSSOVER BUSHING 4.910 8,197.4 3,672.6 83.24 SBE 190-47 SEAL BORE EXTENSION 4.750 9,649.7 3,658.2 88.52 Swell Packer EASYWELL SWELL PACKER 4.950 il 11,720.9 3,659.7 89.09 Swell Packer EASYWELL SWELL PACKER 4.950 l Casing Description 100(in) IID(in) 'Top(ftKB) ISet Depth(ftKB) ISet Depth(TVD(...IWtlLen)I...IGrade Tap Thread SURFACE,30.4-3,467.8-. - D LINER LEM 4 1/2 3.958 7,973 4 8,207 8 3,673.8 12 601L-80 IBTM 11 Liner Details GAS LIFT,6,144.1 . Nominal ID it Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des 7,973.4 3,646.3 83.18 PACKER LEM TorqueMaster PackerCom (in)3.950 8,006.0 3,650.1 83.22 NIPPLE LEM 3.75"'DB'Nipple 3.750 GAS LIFT,7,779.0 1E. 8,124.2' 3,664.0' 83.32 NIPPLE 'LEM 3.562"'DB'Nipple 3.562 8,204.6 3,673.4 83.23 SEAL ASSY LEM SEAL ASSEMBLY 3.870 11 Tubing Strings it GAUGE;7,848.1Tubing Description String Ma...ID(in) Top(ftKB( Set Depth(ft..,Set Depth(ND)L..Wt(Ibfrt( Grade Top Connection HTUBING WO 2016 41/2 3.958 23.7 7,979.8 3,647.0 12.60 L-80 IBTM Completion Details Nominal ID Top(MB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) LOCATOR;7,909.723.7 23.7 0.00 HANGER Vetco Gray MB-222 Tubing Hanger(drifted 3.895")w/4- 3.958 SEAL ASSY;7,910.9 %"IBT-M Pup Joint 3.04' SBE;7,915.7 492.4 491.6 7.86 NIPPLE Camco 4-%"x 3.875"DB-6 Landing Nipple(IBT-M BxP) 3.875 Ill NIPPLE;7,955.4 - 7,848.1 3,631.2 83.30 GAUGE Unique Gauge Carrier(4-11/A"IBT-M Coupling)(BH 3.958 SureSENS 125LP Gauge w/TEC wire) CENTRALIZER;7,988.8 4 7,909.7 3,638.7 83.03 LOCATOR Baker Locator Sub 3.950 XO Threads;7,868.1 7,910.9 3,638.8 83.03 SEAL ASSY Baker 17'80-47 Seal Assembly.4.79 feet up from fully 3.900 ANCHOR;7,977.7CV located. i'i i_i tT 7,915.7 3,639.4 83.05 SBE Baker 18'80-47 PBR SHEARED 4.750 7,955.4 3,644.1 83.16 NIPPLE Camco 4-K"3.813"DB Landing Nipple(IBT-M BxP) 3.813 7,966.8 3,645.5 83.17 CENTRALIZE 414"x 8"fluted centralizer 4.000 R E2 7,977.7 3,646.8 83.18 ANCHOR Baker ML Production Anchor 81FA47,4-14"IBT-M Box) 3.880 1 i Perforations&Slots I Shot 0 LINER SLOTTED;8,041.8- r Top(ND) Btm NO Dens 12,015.3 Top/RKB) Btm(ftKB) (ftKB) (ftKB) ) Zone Date (s ft) Type Com 9,778.0 11,712.0 3,663.1 3,659.6 WS B,1J-107 9/3/2007 32.0 SLOTS 100%slotted liner, 2.5"x.125",4 circumferential rows/ft, 3"centers staggered 18 deg Mandrel Inserts St ab N Top(TVG) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1 2,751.6 2,002.3 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,478.0 5/10/2016 j----t �- 2 6,144.2 3,216.3 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 5/6/2016 j_i- 3 7,779.8 3,623.3 Camco KBMG 1 GAS LIFT OV BK I 0,313 0.0 5/11/2016 Notes:General&Safety End Date Annotation D LINER LEM,7,973.4-8,2078 9/15/2007 NOTE:MULTI-LATERAL WELL-1J-107(B-SAND),1J-107L1(D-SAND) in 8/23/2008 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 5/14/2010 NOTE:WELL CONVERTED FROM ESP TO GAS LIFT PRODUCTION INTERMEDIATE;24.8-8,721 0 l lir SLOTS;9,778.0-11,712.0 Uri 1 B LINER SLOTTED;8,160.5all - 11,792.0 Image Projecfi Well Hisfiory File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. - 1 Q ~ Well History File Identifier Organizing (aone> RE AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: „~ o,aed iuuiuiuuiiuii DIGITAL DATA Diskettes, No.1 ^ Other, No/Type: o Ae,v~~„a~ iiiuiiiiiumiii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: BY: Maria Date: ~ ^ Other:: Js/ Project Proofing II I II II II ~ ~ III ~ I III BY: Maria Date: ~-. 1 ~ ~ ~ /s/ Scanning Preparation ~_ x 30 = ~ + ~ ~ =TOTAL PAGES 1 c~a (Count does not include cover sheet) BY: Maria Date: I /s! ~~ - ~ ~ l - Production Scanning II I II ~I II I I I!I I I III Stage 7 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Pre aration: _~YES NO BY: Maria Date: +~„ ' ~ ~ S /s/ Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s! Scanning is complete at this point unless rescanning is required. II I II II II I II II IIIII ReScanned BY: Maria Date: /s/ Comments about this fife: Quality Checked III II'lll III IIII III 10/6/2005 Well History File Cover Page.doc • ~.°~ e ~~~ ~y~ ~~ ,S ~ ~.. ~ 4. _ ~ ~ ..~ :SAsr '~ .a <;~. t ~^ ~ ~ ~ ~:~ ~:,.~ . ~ _ ,~ ; ~,~ ~~~ ~`~C r. ~ ~ MICROFILMED 6/30/2010 '~~~~~ D O NOT PLACE ~~ ANY N EW MATE RIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc • • WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1J-107+L1 May 15, 2009 AK-MW-5154790 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Bryan Burinda, Sperry Drilling, Arctic Blvd., Anchorage, AK 99518 1J-107+L1 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23366-00,60 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23366-00,60 Digital Log Images 2 CD Rom 50-029-23366-00,60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 F ~~ 5~~: ' ' ~iton. com ~ ~ ~o~s Date: -~ a Q~~9~. D ~61f~Sflt~~ 6ch®~ BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: ~ ~o~ -~o~- «~~ ~' ~~~-~o~ ~~ruU • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION ~~ V ~1.~ /~P~ 2 ~ 2Q09 REPORT OF SUNDRY WELL OPERATI01.~>~ca Qii & Gas Cons. Comumission 1. Operations Performed: Abandon ^ Repair Well ^~ ~ Plug Perforations ^ Stimulate ^ Other 8~-~ - Alter Casing ^ Pull Tubing ^~ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnOCOPhillips Alaska, InC. Development ^~ ~ Exploratory ^ 207-107 / 3. Address: Stratigraphic ^ Service ^ 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510 50-029-23366-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 81' 1 J-107 8. Property Designation: 10. Field/Pool(s): ADL 25661, 25662 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 12073' feet true vertical 3656' feet Plugs (measured) Effective Depth measured 11792' feet Junk (measured) true vertical 3661' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 20"x34" 108' 108' SURFACE 3440' 13-3/8" 3468' 2275' INTERMEDIATE 8693' 9.625" 8721' 3716' PRODUCTION 3623' 5.5" 11792' 3661' Perforation depth: Measured depth: slotted liner from 9778'-1 1712' true vertical depth: 3663'-3660' Tubing (size, grade, and measured depth) 4.5", L-80, 7898' MD. ~~~~~ ~~ /~~ ~ ~ +-s`' ~~ `~' Packers &SSSV (type & measured depth) Pkr @ 7s73' no SSSV 12. Stimulation or cement squeeze summary: LJttt~ S ~ ~ ~ t~ _01 Intervals treated measured ( ) not applicable Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 428 1415 23 -- 215 Subsequent to operation 416 79 458 -- 222 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development 0 Service ^ Daily Report of Well Operations _X 16. Well Status after work: OiIO Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none contact Brett Packer @ 263-6845 Printed Name Brett Packer Title Wells Engineer `/ 2 ~ /~~ / Signature ~`~ ~ Phone: 265-6845 Date Pre aced b Sharon Allsu -Dr ke 263-4612 Form 10-404 Revised 04/2006 ,v Submit Original Only iJ-174 (PTD #207-143), 1J-13~PTD#206-108) Multi-lat drawings ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Packer, Brett B [J.Brett.Packer@conocophillips.com] Sent: Wednesday, April 29, 2009 3:40 PM To: Maunder, Thomas E (DOA) Subject: RE: 1J-107 (PTD#207-107) Multi-lat drawing Attachments: Visio-1J-107 HBB DLP_ESP As Completed WO 09.pdf Here you go! ,~ Brett ~Pacfgr ~Drill"ing aC'Wells `Workover Engineer `Work# (907) 265-6845 Cell# (907) 230-8377 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, April 29, 2009 1:50 PM To: Packer, Brett B Subject: RE: 1J-174 (PTD #207-143), iJ-137 (PTD#206-108) Multi-lat drawings Thanks much Brett. Do you have one for 1J-107 (207-107) as well? Tom Maunder, PE AOGCC From: Packer, Brett B [mailto:J.Brett.Packer@conocophiilips.com] Sent: Wednesday, April 29, 2009 1:48 PM To: Maunder, Thomas E (DOA) Subject: iJ-174 (PTD #207-143), 1J-137 (PTD#206-108) Multi-lat drawings Tom, Attached are the updated profile views for these two wells. «Visio-1J-137 HB DLP As-Completed-WO 09 .pdf» «Visio-1J-174 RAM HB DLP as completed_WO-09.pdf» ,~ Brett hacker ~DrilCing a2 `Wells 'Workover~Engineer 'Work# (907) 265-6845 Cell# (907) 230-8377 4/30/2009 Insulated Conductor, 20" 94# K-55 x 34" 0.312 WT+I- 80' Wellhead I Tubing I Tree: 13.316" x 4-112", 5,000 psi • • Ph l C As Comple#~c! 6AKKER MIJ6MES Tubing String i ips ono~o 4-112" 12.6#, L-8Q IBLM 3.958" ID, 3.890" Drift West Sak Hybrid Producer M d l E Rakrr (lit "1'nnls (LEMI l 1 J-~ U7 o Latera ntrv e u With Diverters an d Isolation Dual Lateral Completion Lakrd Access Dlverter Lateral lsolatbn Divener Wn I d 2775' MD-GLM, Camco, 4-112" x 1" KBMG W O 09 GS Running Tool Strang Instened Is.ta° Lmeral Drml. ns a 12. so° ID Mainbore DnRI 'GS' Pro}ile for i 6691' MD-GLM, Camco, 4-112" x 1" KBMG C~ coil connacmr ~ - ` RvnninglRetneving ~` { i e h.oo' Length) 1 1 Snap InlSnap Out j !, u I ~ Back Pressure Valve a' I -Positive locating ~ I~.ll) I 3467 MD - 13-318" Casing ° ~ (7.80' Length) ~ Golkt y r r~ Shoe, 68#, LAO, BTC set, '~ ' I I .- rlpw-rnru swivel ` Lateral Isolation ' - seals 2275'TVD (1.25'Lengthl ',-' lateral Dtveder _ r Hydraulic \ w Ramp 7900' MD -Bottom of Motor Centralizer, Centralift TTC-ESP _ _ Dlsep^nect ~ Isdatlonr Mainhorr _-I / /T It. W' Length) ~ Divener Sleeve " ~ " - ~ ' ~t o' i~gml I Lateral leolation _ 6.85 R Approa. - ~-~ ' seal: OAL - ~ 'Jan may ba requoetl in highly tletnalld 79' Diverkr Length 19' Skeve LenlNt t 7973' MD -TorqueMaster Packer Asmb 9-S/a" TorqueMaster Packer ~` ~- 7.562" DB Nipple _ - Orienting Prolik Automatic Alignment of LEM --- Positive Latching Colkt Indicates Correct Location - Seal Bore for Lateral Isolation - 3.66a" ID Access Window Positive Lateral Access Vk Thru-Tubing Divener 8042' MD- T' x 9-SIB" Model B HOOK Hanger 8006' MD - 3.750" DB Nipple •D' Sand Lateral - 8034' MD -Lateral Entry Module (LEM) Orienting Profile 8047' MD - D Sand Window, 3655' TVD (83 deq) / 4-1/2" 11.6#, BTC, LAO Slotted Liner ~~'~`e~~,~,~~^e..~ ` ~ 4-112" Guide Shoe 8169' MD - 7" X 9-SIB" ML ZXP Liner Top Packer with integrated RS profile and Flexlock slips 8124' MD - 3.562" DB Nipple MD - 4112" Casing Shoe. 11.6#, L-80 BTCM, 3588' TVD 8208' MD -Bottom of Seal Assembly 'B' Sand Lateral 4.75" Seal OD, 3.875" ID 5-112" 15.5 #, BTC, L-80 Slotted Liner 5.1/2" Eccentric ~. `,. ~ .Guide Shoe 8197 MD-Casing Sealbore ~ - - - Seal Bore for Lateral Receptacle 20' x 4.75" ID Isoktion - 3.6aa" ID Isoktion Seal Asemby 8721 MD -80 BTCC3716' TVDe, 40.0#, 4,75" Seel OD 1.675" Seal ID 2' LengtA (89 deg inc) (D Baknr Hughes 200E TM1is tlom,ment may not be reprotlucetl or tlizlribuled, in wM1Ok or in pan, in any lorm or by any means ekclronk or mechanics , pl,orocepying, recortling, or by any information storage antl relrieyal ayslem rww known or M1ereaner invenletl, wilM1OUI wrinen permission Irom 9aker NugM1ea Inc. 7" X 9-5/8" HOOK Hanger Mainbore Draft: 7.00" Mainbore Daft, wdh divener 6.25" .ateral Dri/t. no divener or LEM: 6.28" etenl Drift. wr divener, no LEM: 5.12" LatenUMainbore Divener OD: a.50" 41/2" Lateral Entry Module Mainbore Drill: J.6a" inbpre Drill, w/ isolation sleeve: 3.50" Lateral Drm. w/ coil divener: 7.00" OD of Divener and Sleeve: +/- ~.6i Divener and Skeve Length: +/- 19' i~eJ 11792' MD - 5-112" Casing Shoe, 15.5 #, L-80 BTCM, 3661' TVD ~~'- `O~ . ~ -.,k opal Lakral compkuon-vroau~er Z^^,.- .,w ev Ian TOOmeY vi.ian ao.. 2 • • ConotoPhillips 1 HANGER. 23 CONDUCTOR. 28108 ESP MANDREL. z.ns SURFACE, 30-3 468 ESP MANDREL, 6,886 Discharge (ESP), ],175 ESP INTAKE. ],856 ESP MOTOR, 7,679 '' ESP GAUGE,_ ],896 ~~~- CBnVa4xer, ],858 t.-- D~SAN:] t[ M, 1.97]-tl./O6 (TERMED WTE. 25 8 ]21 SLOTS, 9,]78-11 112 8-SAND LINER SLOTTED, 8,169-11 ]92 D-SAND LINER SLOTTED. 8,062-12.015 i r KUP • 1J-107 ~ Well Attributes Wellbore APW WI Field Name _ Well Status Prodlinj Type Max Angle & MD Inc! (°) 'MD (ftKB) ',TD Act Blm (ftKB) 500292336600 (WEST SAK (PRODUCING 9649 9,103.81 12,073.0 Comment H2S (ppm) Date .Annotation End Date KB-Grd (Hj Rig Release Dat SSSV~ NONE 0 ( 1/1/2009 Last WO: 3!4!2009 3229 9/15/2007 -' Annotation Depth (HKB) End Date Annotation End Date Last Tag: I ( Rev Reason: WORKOVER 4/16/2009 Casin Strin s Casing Description ,String 0... 'String ID ... Top (ftKB) Set Dopth (f... Set Depih (ND) ... String Wt... String ... String Top Thrd CONDUCTOR 20 19.124 28.0 108.0 108.0 94.00 H-00 Casing Description String 0... String ID ... Top (NKB) Set Dap[h (f... Sat Depih (ND) ... String Wt... String ... String Top ThM ,SURFACE 13 3/8 12 415 30.4 3.467.8 2,275 0 65.00 L-80 I BTC , Casing Description iString 0... String ID ... Top (HKB) Set Depth (f... Sat Depth (ND) ... String Wt... (String ... String Top Thrd INTERMEDIATE 95/8 8.835 24.8 5,721.0 3,710) 40.00 L-80 ~ BTCM Casing Description ~ String 0... ~, String ID ... Top (ftKB) Set Depth (f... I Set Depth (ND) ... Strmg Wt... ~iString .. ~~ String Top Thrd D-SAND WINDOW 9 ~, 8.500 8,047-0 8,057.0 40.00 L-80 ' Casing Description String 0... 'i String ID ... Top (HKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd D-SAND LEM 4.55 '. 3.910 7,973.4 8,207.8 3,6738 12.60 L-80 IBTM Casing Description String 0... 'String ID ._ Top (HKB) Set Depth (f... Se[ Depih (ND) ... String Wt... String... (String Top Thrd B-SAND LINER 1 4112 I 3.992 8,169.5 11,792.0 3660.5 11.60 L-80 ~ IBT-M SLOTTED ~ Liner Details Top Depth, _ (ND) Top Inc! Top (HKB) (HKB) (°) Item Descriptio n I Comment ID (ir 8,169.5 3,669.3114 83.271 PACKER .Baker "ML" ZXP Liner Top Pkr 7.00" X 9 625" (SF 44K) 6.3: 8,190.7 3,671.81 83.24 HANGER ~7.0" X 9.625"'Flex-Lock" Liner Hgr, 8.32" OD/ 6.20" ID 6.1( 8,196.0 3,672.4 83.24 XO BUSHING Cross Over Bushing 7"X 5.5" Hyd 563 OD 7.67" ID 4.91" 4.91 8,197.4 3,672.6 83.24 SBE 190-47 Seal Bore EM, Hyd 563 box X pin 4.7. 9,649.7 3,658.3 88.52 PACKER 'Swell Packer ~ 4.9: 11,720.9 3,659.7 89.09 PACKER (Swell Packer ~ 4.9` Tubing Strings Tubing Description .. .String O._ String ID ._ Top (HKB) Set Depth (f... Sat Depth (ND) ... String Wt... String ... String Top Thrd ESP COMPLETION I q7/2 3-958 I 22.6 I 7,900.1 I 3637.5 12.60 I L-80 I IBTM- C_ ompletion Det ails . _ ___. __. --_ To th i (NDi ToP Inc1, Top (HKB) (ftKB) (°I 'i (tam Desniptio n ! Command ID (in 22.6 ~. 22.6 -0.03 I HANGER ~ Vetco Gray 4-1/2" Hgr (2.08") w/ full 4-1/2" Jt (28.15"). 3.9( 7,774.71 3,622.8' 83.65 Discharge (Unique Pressure Discharge Sub 3.Sf (ESP) 7,855.9 3,632.0 82.82 ESP INTAKE '. TTC Crossover w/ Screen Intake (5.13" O.D.) 3.9`. 7,865.5 3,633.2 82.86 ESP SEAL 1Upper Tandem Seal Section 1.0( 7,872.4 3,634.1 82 881 ESP SEAL 7900.14 1.0( 7,879.3 3,634.9 82.91 ESP MOTOR Motor 190 HP KMH 1.0( --7,896-1 3,637.0 83.08 ESP GAUGE -- _- -- A-Well I pump guage (4.5" O.D.) 1.0( - -- - 7,898.2I 3,637.31 83.08,ICentralizer Motor Centralizer (5.85" O.D.) _- 1.0( Perforations & Slots snot Top (TVD) Btm (ND) i~ Dens Top (ftKB) I Btm (ftKB) (ftKB) (HKB) Zone Dale (sh-~ Type ~ CommeM 9,778 11,712 3,663.7 3,659.7 WS B, iJ-107 19/3/2007 32.0 SLOTS 1100%slotted liner, 2.5"x .125", 4 !circumferential rows/ft, 3" centers I ~staggeretl l8 deg -- Notes: General & Safety End Date Annotation _. __- 9/15/2001 NOTE MULTI-LATERAL WELL-1J-107(8-SAND), iJ-107L1 (D-SAND) 8/23/2008 NOTE VIEW SCHEMATIC w/Alaska Schematic9.0 _. _._ Top ~ Port Inc! OD Valve Latch Size TRO Run (°) Make Model (in) Sarv TYPe Type (iN (psl) Run Data Com i4.58iCamco KBMG 1~ESP 1SOV IBK-6 0.000 2,000.03/10/2009 r3.601Camco KBMG 1IESP DMY iBK-5 O.000I 0.0 3/4/2009 TD (uao]). 12,0]3 Cona-ccaPhitlips Time Log & Summary ive!lview Web ReA°Krng Report Well Name: 1J-107 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 2/26/2009 12:30:00 PM Rig Release: 3/5/2009 4:00:00 AM ---- ', Time L~ -- ----- _ Date __From To Dur S Depth E, Depth Phase__Code Subcode T Comment 2/25/2009 24 hr Summary Moved rig from 30 Pad to CPF 3. 21:00 00:00 3.00 COMPZ MOVE MOB P Move Nordic Rig 3 off 30 Pad, onto s ine road to CPF 3. 2/26/2009 Cont moving Nordic Rig 3 from CPF 3 to 1A Pad access roads, hold for CPAI field wide change out, cont moving rig to 1J Pad, MIRU over 1J-107, spotted rig on well, spotted equip and bermed up, RU circ liines, MU hardline and tested, pulled BPV, loaded spooler, bled off gas cap, performed initial circulation as per plan and monitored well. 00:00 05:00 5.00 COMPZ MOVE MOB P Road Nordic Rig 3 from CPF 3 to 1A Pad access roads. 05:00 07:00 2.00 COMPZ MOVE MOB X Standby w/ rig crew waiting for CPAI Field Chan eout. 07:00 12:30 5.50 0 0 COMPZ MOVE MOB P Road Nordic Rig 3 from 1A Pad access roads to 1 J Pad. Spot rig over well. Acce t Nordic Ri 3 onto 1J-107 on 2/26/2009 12:30 m. 12:30 14:30 2.00 0 0 COMPZ RPCOM RURD P Spot rig equipment: cutting box, spill van, mud shack, hi-line trailer, etc. 14:30 17:30 3.00 0 0 COMPZ RPCOM RURD P Berm kill tank. RU hardline to kill tank. Load lubricator. 17:30 18:30 1.00 0 0 COMPZ WELCTI KLWL P pull BPV with lubricator, tbg press = 380 si, IA = 780 si, OA = 950 si. 18:30 19:30 1.00 0 0 COMPZ RPCOM OTHR P Load ESP spooler into rig floor with crane. 19:30 23:30 4.00 0 0 COMPZ WELCTI KLWL P Test hard line at 250/2,500 psi, good test, bleed gas cap off IA from 780 to 10 psi and tbg from 380 to 260 psi, pump 150 bbls hot seawater w/ 6% KCL down tbg at 5 bpm - ICP 270 psi FCP 80 psi, line up and pump 500 bbls down IA at 5 b m - 150 si. 23:30 00:00 0.50 0 0 COMPZ WELCTI OWFF P Shut in and monitor well for 30 min. IA built to 20 si, tb built to 10 si. 2/27/2009 Cont pump and kill well with seawater and 6% KCL, install BPV, ND tree, install test dart, NU BOP, perform initial BOP test, pull test dart and BPV, MU landing jnU isolation sleeve, unseat hanger, pumped 550 bbls, POOH stand back tb usin tri le dis lacement and/or 50 b h, from 7,849' to 7,556'. P~c~ ~ er ~ r~ Time Logs Date From To Dur S De th E De th Phase Code Subcode T Comment 00:00 02:00 2.00 0 0 COMPZ WELCTL KLWL P Bled off tbg and IA to zero psi and shut in, pressures built to 10 psi on IA and 20 psi on tbg. Pumped 50 bbls down tbg at 5 bpm - 80 psi, followed by 75 bbls hot seawater down IA at 5 bpm - 120 psi. Shut in well and monitored 30 min, both IA and tbg increased to 10 psi. Pumped 100 bbls down tbg 5 bpm - 80 psi then 100 bbls down IA at 5 bpm - 120 psi. Shut in well and monitored for 30 min, had no increase in pressures, both IA and tb on vaccume. 02:00 03:00 1.00 0 0 COMPZ WELCTL OTHR P RD circ lines and installed BPV, OA gauge still showing 950 psi, RU OA on hardline to kill tank to bleed off pressure. RU circ line to IA to add 50 b h to hole throw h BOP testin . 03:00 04:30 1.50 0 0 COMPZ WELCTL NUND P ND tree and installed test dart. 04:30 09:30 5.00 0 0 COMPZ WELCTL NUND P NU 13 5/8" BOPE. 09:30 20:00 10.50 0 0 COMPZ WELCTL BOPE P Testin BOPE 250/2500 si. Test annular and variables with 3-1/2" and 4-1 /2". Testing witnessed by John Crisp AOGCC. Camp on highline at 11:00 hrs, rig on hi hline at 15:00 hrs. 20:00 21:00 1.00 0 0 COMPZ RPCOM OTHR P Pulled test dart and BPV, MU landin ~nt. 21:00 23:00 2.00 0 7,874 COMPZ RPCOM CIRC P BOLD's, RU and pumped 100 bbls down tb ,unseated han~C er 165K up weight, pulled hanger above mud cross and pumped 450 bbls hot seawater down IA through kill line at 5 b m, never had returns. 23:00 23:30 0.50 7,874 7,821 COMPZ RPCOM PULD P Pulled hanger to rig floor, up weight 105K, tested ESP cable, LD hanger and landing jnt, string ESP cable over sheave and onto s ool. 23:30 00:00 0.50 7,821 7,556 COMPZ RPCOM PULL P POOH stnd back 4 1/2" tbg and drifting same at 3.833", from 7,849' to 7,556'. 2/28/2009 Cont POOH standing back 4 1/2" tbg, install wear ring, PU and RIH with wash tool assembly on 3 1/2" DP to 7,270'. 00:00 10:00 10.00 7,556 450 COMPZ RPCOM PULL P Cont POOH, up weight 105K, racking back 4 1/2" tbg drifting in derrick to 3.833". 10:00 11:00 1.00 450 450 COMPZ RPCOM CIRC P Gas coming up through thetubing even after pumping 100 bl / hr down the IA. Viscosify 150 bbl of SW w/6% KCL with Flo-Visc. Pump 100 bbl down the IA. Observed well, gas sto ed comin to surface _ m .® _ __ F~age ~ s~t~ 6 n r~ Time Logs Date From_ To Dur S D~th E. De th Phase Code Subcod_e T Comment _ ~ _ 11:00 15:00 4.00 450 0 COMPZ RPCOM PULD P POOH with tubing to ESP completion. RD and LD ESP com letion. Observed the bottom of the retrievable gas separator through the intake ports on TTC. Retrieved 221 Cannon clamps, 16 SS bands, 2 flat guards, 3 protectolizers. (MISSING 3 x SS BANDS FROM RUN TALLY 15:00 16:00 1.00 0 0 COMPZ RPCOM RURD P Set wear ring. Prepare floor to run wash strin on 3-1/2" DP. 16:00 17:30 1.50 0 478 COMPZ RPCOM PULD P PJSM. PU amd MU bull nose and lateral wash nozzle wash assembly strip . 17:30 00:00 6.50 478 7,270 COMPZ RPCOM PULD P PU and single in hole on 3 1/2" DP from pipeshed to 7,270', up weight 105K, down weight 60K, and cont adding 100 bph hi-vis seawater to well. 3/01 /2009 Copt PU and single in hole to 7,982', cleanout down through D-lat hook hanger, B-lat ZXP to bottom of B-lat csg SBR at 8,220', POOH stand back 3 1/2" DP, LD DC's and washtool assembly, RIH with 3 1/2" DP and mule shoe for well control while waitin on weaather conditions to im rove. 00:00 01:30 1.50 7,270 7,982 COMPZ RPCOM PULD P Cont PU and single in hole from 7,270' to 7,982'. Load pits with seawater/6% KCL. Had to wait on vac truck due to J Pad access road drifting in. Entire field at Phase 2 weather conditions at 01:00 hrs. 01:30 03:30 2.00 7,982 8,220 COMPZ RPCOM WASH P With 500 bbls in pits started washing down from 7,982' cont single in hole, could not excede a pump rate of 5 bpm due to dumping pump pop-offs, pumping 5 bpm down IA, pumping 5 bpm - 3,150 psi down 3 1/2" DP. Washed down to a maximumn depth of 8,220' with no problem. Reciprocated string 50' slowly, a total of 3 times, and did get some returns at surface. Pumped low-vis seawater washin down. 03:30 06:00 2.50 8,220 490 COMPZ RPCOM TRIP P Blew down top drive, observed well, fluid column dro in ,off-loaded vac truck into pits, ensured vac trucks could continue making round trips for fluid, POOH standing back 3 1/2" DP. 06:00 08:30 2.50 490 0 COMPZ RPCOM PULD P Lay down drill collars, Baker e ui ment and wash strip . 08:30 09:00 0.50 0 0 COMPZ RPCOM RURD T KUPARUK IN PHASE 3 CONDITIONS. Pre are floor to run DP in hole as a kill strip . ~~~ ~ ~~a~~ 3 of ~ ~~ Time Logs _ _ Date From To Dur S De th E. De th Phase Code Subcode T _ Comment 09:00 12:30 3.50 0 7,758 COMPZ RPCOM TRIP T RIH with stands of drill pipe down to 7758'. Install floor valve and sting in top drive. Close upper pipe rams. Up wt = 110 K#, down wt = 66 K#. 12:30 00:00 11.50 7,758 7,758 COMPZ RPCOM OTHR T WAITING ON WEATHER. 3/02/2009 Cont waiting on weather and road conditions, POOH with 3 1/2" DP, MU LEM assemblies, shallow test MWD, RIH in 3 1/2" DP to 2,081'. 00:00 10:30 10.50 7,758 7,758 COMPZ RPCOM OTHR T Cont waiting on weather and road conditions to allow vac trucks or emer enc vehicles access to ad. 10:30 12:00 1.50 7,758 7,758 COMPZ RPCOM CIRC T PHASE 3 WEATHER AND ROAD CONDITIONS LIFTED. PJSM. Well is on a vacuum. Unsting top drive from floor valve, open upper pipe rams. Pump 150 bbl of viscous SW w/6% KC- L dower the IA and 60 bbl down the tubin 12:00 13:30 1.50 7,758 7,758 COMPZ RPCOM RURD P Off load spool of used ESP cable, load news ool. 13:30 17:30 4.00 7,758 0 COMPZ RPCOM TRIP T POOH stand back 3 1/2" DP. 17:30 18:30 1.00 0 0 COMPZ RPCOM RURD P Pull wear ring, CO floor equipment. 18:30 20:30 2.00 0 246 COMPZ RPCOM PULD P PU and MU outer LEM assembly, acker and inner strip . 20:30 22:00 1.50 246 338 COMPZ RPCOM DHEO P RIH 1 stand 3 1/2" DP, MU top drive, pump at 3.5 bpm - 800 psi, obtain shallow test on MWD, blow down top drive. 22:00 00:00 2.00 338 2,081 COMPZ RPCOM TRIP P Install wear ring, cont RIH 30 fpm, on 3 1/2" DP from derrick to 2,081', up wei ht 60K, down wei ht 55K. 3/03/2009 Copt RIH with LEM assembly to 8,207', orient and set LEM, POOH LD running tools and inner string, RIH with 4 1/2" ESP com letion to 855'. 00:00 06:00 6.00 2,081 7,990 COMPZ RPCOM TRIP P Cont RIH with LEM assembly on 3 1/2" DP at 30 fpm, from 2,081' to 7 990' up weight 110K, down weight 66K. 06:00 07:30 1.50 7,990 8,207 COMPZ RPCOM HOSO P MU top drive, break circ at 3 bpm - 950 psi to orient LEM with MWD, washed down to 8,187' mule shoe depth, passing through hook hanger with no problem, up weight 120K, down weight 61 K, LEM at 81 degrees right, reciprocate string and re-orient to 6 degrees right, latched in with mule shoe at 8,207', verified with 15K over pull to 135K, latched in again at 6 degrees right. Seal assembly mule shoe at 8,207' Top of Torquemaster Packer at 7,973' ~ _ ~~ e F'~g=~ ~ of~ 6 • Time Logs Date From To Dur S. Depth E Depth Phase Code Subcode_ T Comment____ 07:30 08:30 1.00 8,207 8,207 COMPZ RPCOM PACK P Set string in slips, dropped a 29/32" ball and pumped down string at 1bpm, seated ball, pressured uo on workstring to 2,800 psi to activate and set Tor ueMaster Packer, bleed to 1,500 psi and pull 25K over, slack off and compress 5K, bump pressure u to 2,800 si then bleed off to zero. 08:30 09:00 0.50 8,207 8,207 COMPZ RPCOM PRTS P Filled lA with char a um ,close rams RU and test IA x Tor ueMaster at 2,500 si for 5 mi u e on chart. Good test. Bled off IA, ulled settin tools from acker. 09:00 10:00 1.00 8,207 8,175 COMPZ RPCOM OWFF P Monitor well, fluid dropping in IA, blow down top drive, LD one jnt, RU test pump on workstring, pressure up to 4,050 psi and shear ball seat, RD test hose. 10:00 14:30 4.50 8,175 0 COMPZ RPCOM TRIP P POOH 82 stands 3 1/2" DP standing back, using 50 bph for hole fill, pull wear ring, LD inner string, MWD, and settin tools. 14:30 18:00 3.50 0 85 COMPZ RPCOM RCST P Set up tools for running 4 1/2" ESP com letion. PU/MU motor centralizer, A-well I-Pump sensor and motor and service same. PU/MU the tandem seal section and service same. MU TTC xover/itake to top of seal section. Feed motor lead extension cable thru sheave in derrick and connect to pump rece tacle assembl . 18:00 20:00 2.00 85 255 COMPZ RPCOM RCST P RIH with 4 1/2" completion tbg from derrick to 255'. 20:00 23:00 3.00 255 255 COMPZ RPCOM SLKL P RU slickline, PU and MU TTC ESP, set pum ,test ackoff to 1,000 si for 15 minutes, good test, set slip sto , RD slickline. 23:00 00:00 1.00 255 876 COMPZ RPCOM RCST P Cont RIH with 4 1/2" completion tbg from derrick, from 255' to 876', up wei ht 47K, down wei ht 47K. 3/04/2009 Cont RIH with ESP completion to 7,900', MU hanger and final splice to penetrator, land tbg, RILD's, LD landing jnt, install 2 way check, ND BOP, NU tree and test, pull 2 way check, bull head diesel down tbg and IA to freeze rotect well, install BPV, re to move ri . 00:00 09:00 9.00 876 7,847 COMPZ RPCOM RCST P Cont RIH with 4 1/2" completion tbg from derrick, from 876' to 7,847', performing electrical tests on the ESP cable eve 1,000'. 09:00 12:00 3.00 7,847 7,900 COMPZ RPCOM HOSO P MU hanger and landing jnt, make final splice of ESP cable to enetrator. Land tubin and RILDS. 12:00 13:00 1.00 7,900 COMPZ RPCOM THGR P Back out landing jt. and wash out BOP stack. LD landing jt. Test hanger void/packoff to 5,000 psi. Remove side port isolation sleeve from han er. Install two-wa check. ~.. ~ ~ i arcs ~ cet ~ ~~ Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 13:00 17:30 4.50 COMPZ RPCOM NUND P ND BOPE. Test ESP electrical cable/motor integrity. NU tubing head adapter and tree. Test tree to 5,000 si. Pulltwo-wa check. 17:30 18:00 0.50 COMPZ RPCOM RURD P Seperate drill pipe in derrick for rig move. 18:00 21:30 3.50 COMPZ RPCOM FRZP P RU circ lines on tree, test lines at 250/1,500 psi, with LRS pumped 42 bbls diesel down t an s diesel down IA at 2 bpm, shut down and shut in well, SITP = 50 psi, IA = 50 si, OA = 450 si. 21:30 23:30 2.00 COMPZ RPCOM OTHR P RU lubricator and install BPV, RD lubricator. 23:30 00:00 0.50 COMPZ RPCOM DMOB P Blow down all circ lines, move tanks, hi hline trailer and shacks from ri . 3/05/2009 Secure well, dress tree, move tanks, highline trailer, shacks from rig, back rig off well 1J-107, move rig mats to well 1J-137, clean cellar box, move ri onto 1J-137. 00:00 04:00 4.00 COMPZ MOVE DMOB P Dressed tree, moved tanks, shacks and highline trailer clear of rig, worked on bogey tire, backed rig off well, removed double stack rig mats from well site, cleaned out cellar box. Nordic Ri 3 released from well 1 J-107, at 04:00 hrs 3/5/2009 DATA SUBMITTAL COMPLIANCE REPORT 11 /21 /2008 Permit to Drill 2079070 Well Name/No. KUPARUK RIV U WSAK 1J-107 Operator CONOCOPHILLIPS ALASKA INC MD 12073 TVD 3656 Completion Date 9/14/2007 Completion Status 1-OIL Current Status 1-OIL API No. 50-029-23366-00-00 UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: GR/Res Well Log Information: Log/ Electr Data Digital Dataset Ty~ Med/Frmt Number Name (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / • Scale Media No Start Stop CH Received Comments '~D D Asc Directional Survey 28 12'073 Open 12/3/2007 ~pt Directional Survey 28 12073 Open 12/3/2007 15804 LIS Verification 3439 12073 Open 12!28/2007 LIS Veri, GR, FET, RPS, ', RPM, ROP C Lis 15804 Induction/Resistivity 3439 12073 Open 12/28/2007 LIS Veri, GR, FET, RPS, j RPM, ROP Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y f~ Chips Received? l~Y1G"' Analysis ~l`-f'IV" Received? Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? ~/ N Formation Tops ~ N Comments: Compliance Reviewed By: Date: October 31, 2008 Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. 7~' Ave. Ste. 100 Anchorage, AK 99501 Robert Christensen Production Engineering Tech. Greater Kuparuk Unit , NSK-69 PO Box 196105 Anchorage, AK 99519-6105 Phone: (907)659-7535 Fax: 659-7314 Dear Mr. Maunder, ConocoPhillips Alaska, Inc. has changed the artificial lift method in the West Sak 1J-107 and 1 J-107L 1 multilateral oil production wells. Enclosed you will find 10-404 Reports of Sundry Well Operation recording the change in artificial lift method to Gas Lifted due to a failed Electrical Submersible Pump. If you have any questions regarding this matter, please contact me at 659-7535. Sincerely, %C~~- Robert D. Christensen Attachments Y - w "'° J • , ~ ~ .. ~~ STATE OF ALASKA - ~ ~'~P ALASKA OIL AND GAS CONSERVATION COMMISSION _ REPORT OF SUNDRY WELL OPERATIOS~ ' `Y 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ^ Failed ESP ~ Alter Casing ^ Pull Tubing ^ Pertorate New Pool ^ to Waiver ^ Time Extension ^ Gaslift Change Approved Program ^ Operat. Shutdown^ Pertorate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: COnocoPhllllps Alaska, InC. Development ~ Exploratory ^ 207-107 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23366-00 , 7. KB Elevation (ft): 9. Well Name and Number: RKB 109' ~ 1J-107 ' 8. Property Designation: 10. Field/Pool(s): , ADL 25661, 25662 Kurpark River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 12073' ~ feet true vertical 3656' ~ feet Plugs (measured) Effective Depth measured 11792 feet Junk (measured) true vertical 3661 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 20" 108' 108' SURFACE 3440' 13-318" 3468 2275' INTERMEDIATE 8693' 9-5/8" 8721 3716' L1-WINDOW 10' 9-5/8" 8057' 3656' SLOTTED LINER 3623' S-1/2" 11792 3661' Perforation depth: Measured depth: 9778' - 11712' true vertical depth: 3663' - 3660' Tubing (size, grade, and measured depth) 4-1/2", L-80, 7875' MD. Packers &SSSV (type & measured depth) Packer =None SSSV =None 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 643 133 475 167 169 Subsequent to operation 646 264 382 852 181 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ ,Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: N/A contact Bob Christensen/Vacant Printed Name:" o ert D. C istensen Title Production Engineering Specialist Signature s ~ Phone: 659-7535 Date !~/3l ~t-~ Form 10-404 Revised 04/2004 ~ ~"~ ~ ~ ~ ~ ~ ~~ ~ ~JQb Submit Original Only ~ ~~ ~Z~. i ~/r.1/~ ConocoPhillips ni.~,R~, Inr:. KUP • 1 J-107 Well Attributes Wellbore APW WI Field Name Well Status Prod/InJ Well Type Inc! (°) MD (RKB) TD (max) (R.. 500292336600 WEST SAK PROD 96.49 9,103.81 12,073.0 Comment H23 (ppm) Date Mn«ation SSSV: NONE 0 7/tY1008 Last WO: End Date KB[ird (R) Rig Release Date 32.29 9/15/2007 Mnotatlon Last Tag: Depth (RKB) E M Dale Mnotatlon Rev Reason: FORMAT UPDATE End Date 10!4/2008 Casin Stria s Casing Descriptlon INTERMEDIATE String 0... 95J8 Stang ID .. 8.835 . Top (RKB) S 24.8 et Depth (f... 8,721.0 Set Depth (ND) ... 3,710.7 String Wt... 40.00 String Gr... L-80 String Top Thrd BTCM Casing Descriptlon CONDUCTOR String 0... 20 String ID .. 19.124 . Top (RKB) S 28.0 et Depth (r... 108.0 Set Depth (ND) ... 108.0 String Wt... 94.00 String Gr... H-40 String lop Thrd Casing Descriptlon SURFACE Casing Descriptlon D-SAND WINDOW String 0... 133/8 String 0... 9 Slring ID .. 12.415 String ID .. 8.500 . Top (RKB) S 30.4 . Top (RKB) S 8,047.0 et Depth (/... 3,467.8 et Depth (/... 8,057.0 Set Depth (ND) ... 2,275.0 Set Depth (ND) ... 3,656.3 String Wt... 68.00 Strng Wt... 40.00 String Gr... L-80 String 6r... L-80 String Top Thrd BTC String Top Thrd Caaing Descriptlon BSAND LINER SLOTTED String 0... 4 1/2 String ID .. 3.992 . Top (RKB) S 8,169.5 et DepN (r... 11,792.0 Set Depth (ND) ... 3,660.5 String Wt... 11.60 String Or... L-80 String Top Thrd IBT-M Liner Details Top (RNB) Top Depth (ND) (RKB) Top Inc! (°) Item Descriptlo n Comment ID (In) 8,169.5 3,669.3 83.27 PACKER Baker "ML" ZXP Liner Top Pkr 7.00" X 9.625" (SF 44K) 6.320 8,190.7 3,671.8 83.24 HANGER 7.0" X 9.625" "Flex-Lock" Liner Hgr, 8.32" OD/ 6.20" ID 6.100 8,196.0 3,672.4 83.24 XO BUSHING Cross Over Bushing 7"X 5.5" Hyd 563 OD 7.67" ID 4.91' 4.910 8,197.4 3,672.6 83.24 SBE 190-07 Seal Bore Ext, Hyd 563 box X pin 4.750 9,649.7 3,658.3 88.52 PACKER Swell Packer 4.950 11,720.9 3,659.7 89.09 PACKER Swell Packer 4.950 Tubin Stria s Tubing Descriptlon String 0... String ID ... Top (RKB) Set Depth (/... Set Depth (ND) ... String Wt... String Gr... String Top Thrd TUBING 41/2 3.958 22.6 7,874.5 3,634.3 12.60 L-80 IBT-m Com le tion Det ails Top (RKB) Top Depth (ND) (RKB) Top Inc! (°) Ikm Descriptlo n Comment ID (In) 22.6 22.6 -0.03 HANGER Vetco Gray 11"x 4-1/2" Hgr w/ 4.909" MCA Top Conn. 3.860 7,752.0 3,620.3 84.06 ESP DISHCARGE Unique Pressure Discharge Sub 3.860 7,829.2 3,629.1 83.46 ESP INTAKE TTC Crossover wl Screen Intake (5.13" O.D.) 0.000 7,839.8 3,630.3 83.37 SEAL ASSY Lower Tandem Seal Section GS83D8 FER HL SSCV SB/SB PFSA CLS 0.000 7,853.6 3,631.7 82.81 ESP MOTOR Motor 190 HP KMH 0.000 7,870.3 3,633.8 82.88 ESP GAUGE A-Well I pump guage (4.5" O.D.) 0.000 7,872.4 3,634.1 82.88 CENTRALIZE R Motor Centralizer(5.875"O.D.) 0.000 Other In Hole (reline retrieva ble lu s valves um s fish etc. Top (RKB) Top Depth (ND) t~B) Top Inc! (°) Descriptlon Comment Run Date ID (in) 7,754.0 3,620.5 84.02 PUMP TTC ESP PUMP ASSEMBLY w/PACKOFF 8 SLIPSTOP (OAL ??) set 9/12/2007 9/13/2007 0.000 Perforatlons Top (RKB) Btm (RKB) Top (ND) (RKB) Btm (ND) (RKB) Zone Date sn« Dens (eh~° Type Comment 9,778.0 11,712.0 3,663.1 3,659.7 WS B, 1J-107 9/3/2007 32.0 SLOTS 100% slotted liner, 2.5'k .125", 4 dreumferential rowdR, 3" centers staggered 18 deg Notes: General 8 Safe End Date Mnotatlon 9/15/2007 NOTE: MULTI-LATERAL WELL- 1J-107 (B-SAND), 1J-107L1 (D-SAND) &23/2008 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 Mandrel Details Stn To RKB Top Depth (ND) (ftK8) Top Inel (°) Make Model OD (in) $erv Valve Type Latch Type Port Size Iln) TRO Run (psi) Comment Run Date 1 2,190.0 1,791.6 66.83 CAMCO K BMG 1 Gas Lift SOV BKS 0 2,000.0 7/22/2008 1 J-107 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/26/08 09/27 09/29/0 10/04/08 PERFORM FILL CLEANOUT ON FIRST RUN, PULLED PACKOFF FROM 7801 CTMD, TOOK SEVERAL HOURS TO WORK THROUGH COLLAR @ 7662 CTMD. WILL RTN IN A.M. TO PULL ESP. PULLED ESP FROM 7811 CTMD, PUMP IS IN DEPLOYMENT FLANGE IN TREE FOR S/L. WELL IS FREEZE PROTECTED. 3 PULLED 4.5" TTC-ESP PUMP FROM TREE. PUMP MISSING ~1/4 OF GAS SEPARATOR HOUSING WITH SOME INTERNAL PARTS & PUMP EYE/ ~3'. RAN 3.70" LIB TO 7345' SLM, STOPPED DUE TO 79 DEG DEVIATION. NO IMPRESSION, FISH IS SUSPECTED TO BE ON THE MOTOR SHAFT. SET SLIP STOP CATCHER @ 2270' SLM. PULLED 1" SHEARED SOV @ 2190' RKB, IN PROGRESS. 10/05/08 SET 1" X 5/32" GLV (1281 TRO) @ 2190' RKB. PULLED CATCHER, JOB COMPLETE. 10/07/08 10/08/08 10/14/0 10/16/08 10/23/08 10/24/08 MU AND RIH WITH BAKER VENTURI BASKET DOWN TO 7843' CTMD AND RECOVERED A SMALL AMOUNT METAL AND RUBBER PIECES. RUN#2.RIH WITH A 2.5" SLIP CATCH SPEAR DOWN TO 7852' CTMD AND MADE ONE ATTEMPT TO FISH OUT BOTTOM SECTION OF GAS SEPARATOR. JOB INCOMPLETE FISHED OUT TWO SMALL PIECES OF METAL USING VENTURI JUNK BASKET. DISCONTINUE FISHING OPERATION UNTIL ANOTHER SPEAR CAN BE BUILD THAT (WILL ENGAGED LOWER SECTION OF GAS SEPARATOR OF ESP. I MADE TWO ATTEMPTS AT FISHING LOWER SECTION OF ESP PUMP_ BOTH RUNS UNSUCCESSFULb FIRST RUN WITH 2.961" ITCO SPEAR APPEARED TO ENGAGE FISH WITH 7K OVER PULL, SECOND RUN WITH 3.023" ITCO SPEAR DID NOT APPEAR TO ENGAGE FISH AND HAD NO OVER PULLS, SUSPEND JOB, ATTEMPTED TO FISH LOWER SECTION OF ESP PUMP, FIRST RUN WITH VENTURI RESULTED IN RETRIEVING 1/2 CUP SAND, SECOND RUN MADE WITH 2.961" ITCO SPEAR AND WAS UNABLE TO LATCH FISH, WELL LEFT SHUT IN AND FREEZE PROTECTED, TURN OVER TO DSO, (SUGGEST VIDEO/CAMERA RIG UP ELINE, WELLTEC TRACTOR, AND EXPRO CAMERA. TOOLS FALL TO 6440 FT, TRACTOR TO 7812 FT. RECORD IMAGES, CAMERA STOPS FUNCTIONING, POOH, WILL MAKE ANOTHER ATTEMPT TOMORROW. ELINE WELTEC TRACTOR W/ EXPRO VIDEO. SECOND ATTEMPT AT CAPTURING IMAGES OF FISH UTILIZING GAS LIFT GAS. TOOLS FELL TO 6650 FT, TRACTORED TO FISH AT 7840 FT, RECORDED IMAGES, POOH 10/24/08 Well Returned to production as a gas lifted oil producer ` West Sak 1J-107 (PTD 207-107,ZConversion To Gaslift . Regg, James B (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, October 22, 2008 3:20 PM To: Regg, James B (DOA); 'NSK Problem Well Supv' Cc: 'NSK Well Integrity Proj ; 'NSK West Sak Prod Engr'; 'CPF1 DS Lead Techs' Subject: RE: West Sak 1J-107 (PTD 207-107) Conversion To Gaslift Thanks Jim. Martin, et al please be sure to file the 404 noting the first day of production on gas lift. Tom Maunder, PE AOGCC Page 1 of 2 From: Regg, James B (DOA) Sent: Wednesday, October 22, 2008 3:18 PM To: NSK Problem Well Supv Cc: NSK Well Integrity Proj; NSK West Sak Prod Engr; Maunder, Thomas E (DOA); CPF1 DS Lead Techs Subject: RE: West Sak 1J-107 (PTD 207-107) Conversion To Gaslift We concur with your request to convert KRU 1 J-107 from ESP to gas lift while you assess aptions and plan well work. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Wednesday, October 22, 2008 9:09 AM To: Maunder, Thomas E (DOA) Cc: NSK Well Integrity Proj; NSK West Sak Prod Engr; NSK Problem Well Supv; CPFi DS Lead Techs; Regg, James B (DOA) Subject: West Sak 1J-107 (PTD 207-107) Conversion To Gaslift Tom, As per our conversation, West Sak producer 1J-107 (PTD 207-107) ESP went down on high suction temperature on 9/7/08 after what appeared to be a dead heading event. The ESP was restarted on 9/7/08 but went down again on 9/9/08 because of high motor temperature. After some troubleshooting, ConocoPhillips decided to pull and replace the pump. On 9/27/08 coiled tubing was used to pull the wireline retrievable pump to the deployment flange. Slickline rigged up on 9/30/08, pulled the pump from the deployment flange, and discovered that the pump had failed at the rotary gas separator and the lower 1/4 of the rotary gas separator and the pump eye had been left in hole. The initial assessment hints that sand/erosion/flow cutting caused the pump to come apart. Coiled tubing attempted to fish the pump remnants from 10/7-16/08 but was unsuccessful. The well has been shut in for ±40 days so while we evaluate the options and plan for additional wellwork, ConocoPhillips would like to get the well back on production using gas lift. Slickline installed gas lift valves on 10/5 and the well is ready to produce pending AOGCC approval. This well is an ESP well and does not have a 10/22/2008 West Sak 1J-107 (PTD 207-10~Conversion To Gaslift • Page 2 of 2 packer so as a result, we will have TxIA communication. Please reply with your approval to gaslift the well until it can be repaired. Attached is a 90 day TIO plot and a wellbore schematic. «1J-107 TIO Plot.ppt» «1J-107 Wellbore Schematic.pdf» Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 10/22/2008 ~D 20?-- ~c; 7 T/I10 Plot -1 J-107 900 Boa 700 600 N 500 a 400 300 200 100 0 r~.~:. r ,. L' ~ , -, ;' /~. ~5 ~ A ... ... ..... ......................... ............. .......ti~~. } .. .. - -- ---- ~_-- - - _. --- - -_ ._ __ _ _~t, _ ----- . - ~-- <<-J 01-Aug-08 01-Sep-08 Date 01-Oct-08 00 150 a E as 100 Y O r v 50 0 -r~~-- ~ KUP _ _ ___- _ . _ _ 1J-107 Cor~occ~PhiNips ; '~ Well Attributes ~ _ 'Wellbore nPVUWI F~altl Name W 11 St t s ProdllnT WeH Type -- Inel (') _ MD (ftK6) ,U (maxi tt[... ' i 500292336600 WEST SAK PROD 96.49 9.103.81 12,073.0 Comment H2S (ppm) Dale Annotation Entl Date KB-Grd (ft) Rig Release Date SSSV. NONE 0 7/1/2008 Last WO: 32.29 9/15/2007 ^ien co r ~ ion io goo ~.~w_ss.Fnn_ Schamale -A,:iu.~l -_. .. _-__- - _. _- _ - __ Annotation Depth (ftK6) End Dale Annotation End Date Last Ta 9 Rev Reason: FORMAT U PDATE 10/4/2008 Casin Strin s __ Casing Description String 0... String ID .. . Top (ftK6) Sat Depth (T. .. Set Depth (ND) ... String Wt... String Gr... Skiing Top Thrtl HANGER, 23 `. ~ ® INTERMEDIATE 95/8 8.835 24.8 8,721.0 3,710.7 40.00 L-80 BTCM -- _ ~ "' Casing Description String 0... String ID .. . Top (ftK6) Set Depth (f. .. Set Depth (ND) ... String WL.. String Gr... String Top Thrd CONDUCTOR 20 19.124 28.0 108.0 tOS.O 94.00 H-40 Casing Description String 0... String ID .. . Top (ftK8) Set Depth (f. .. Set Depth (ND) ... Suing Wt... String Gr... String Top Thrd SURFACE 133/8 12.415 30.4 3,467.8 2,275.0 68.00 L-80 BTC , Casing Description String 0... String ID .. . Top (flK8) Set Depth (f. .. Sef Depth (ND)... String WL.. String Gr... String Top Thrtl D-SAND WINDOW 9 8.500 8,047.0 8,057.0 3,656.3 40.00 L-80 ' Casing Description String O._ String ID .. . Top (ftK6) Set Depth (f. .. Sat Depth (ND) ... String Wt... String Gr... String Top Thrd ' ?-~4ND LINER 4 1/2 3.992 8,169.5 11,792.0 3,660.5 11.60 L-80 IBT-M - -. I ~~~ 1TTED ~L~irdiQibaaa, , 28-108 GAS LIFr, 2,190 SURFACE, 30-3 468 ESP DISHCARGE, ],]52 PUMP. ].]54 ESP INTAKE. ],829 SEAL ASSY, ].6aa ESP MOTOR, ],854 ESP GAUGE, 25-8,]21 SLOTS, 9,]]8-11,]12 B-SAND LINER SLOTTED, 8,16&11,792 0-SAND LINER sLOrreo, 8,042-12,015 ~. -. , 1 ( ti: 1 Top (ftKB) Top Depth (ND) (ftK6) Top Incl (°) Item Description Comment ID (in) 22.6 22.6 -0.03 HANGER Vetco Gray 11"x 4-1/2" Hgr w/ 4.909" MCA Top Conn. 3.860 7,752.0 3,620.3 84.06 ESP DISHCARGE Unique Pressure Discharge Sub 3.860 7,829.2 3,629.1 83.46 ESP INTAKE TTC Crossover w/ Screen Intake (5.13" O.D.) 0.000 7,839.8 3,630.3 83.37 SEAL ASSY Lower Tandem Seal Section GSB3DB FER HL SSCV SB/SB PFSA CLS 0.000 7,853.6 3,631.7 82.81 ESP MOTOR Motor 190 HP KMH 0.000 7,870.3 3,633.8 82.88 ESP GAUGE A-Well I pump guage (4.5" O.D.) 0.000 7,872.4 3,634.1 82.88 CENTRALIZER Motor Centralizer (5.875" O.D.) 0.000 Other In Hole (Wireline retrievable. ploys, valves, pumps, Tish, e_tc:.) Top Depth (ND) Top Top (ftK6) (ftK6) Incl (°) Description Comment Run Data ID 7,754.0 3,620.5 84.02 PUMP TTC ESP PUMP ASSEMBLY w/PAC KOFF & SLIPSTOP 9/13/2007 0. (DAL ??) set 9/12/2007 I PerfcTrations snot Top (ND) Btm (ND) Dans Top (ftK6) Btm (ftK6) (ftK6) (ftKB) Zone Date (sh~- Type Comment 9,778.0 11,712.0 3,663.1 3,659.7 WS B, 1J-107 9/3/2007 32.0 SLOTS t00q slotted liner, 2.5"x .125", 4 circumferential rows/ft, 3" centers staggered 18 deg Notes: General & Safety - ____ G,.., r._,_ Annn~al,nn TD (1J-107), 12,073 it _ ~~ ii ,) 9/15/2007 NOTE: MULTI-LATERAL WELL- 1J-107 (BSAND), 7J-107Lt (D-SAND) 8/23/2008 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 I Mandrel Details -~ ---- lop Depth Top - - Port -~ (ND) Incl OD Valve Latch Size TRO Run Stn Top (ftKB) (ftK6) (°) Make Motlel lin) Serv Type Typo (i^) (psi) Comment Run Date 1 2,190.0 1,791.6 66.83 CAMCO KBMG 1 Gas Lift SOV BK-5 0 2,000.0 7/22/2008 ~Tubiny Strings _ _ L.c~^y ~eb.,~wr„-.o ardo9 ~.. s„ yw... ,..P,TrKSI sar Depth (t... sat Daptn (rvo).. sr ny :. r... oa o,... sa~„y I,.R U,~a (TUBING 4 1/2 3 958 ,. 22 6 ~. 7,874.5 ~ 3.634 3 ~ 12 60 L-80 IBT-m ConlDletion Details -a ConocoPhillips _ Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Sept 6, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission ~~ 333 West 7~' Avenue, Suite 100 ~. Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped August 28th, 2008. The corrosion inhibitor/sealant was pumped August 29th, Sept 5-6th,2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry Klei 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 9/6/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-17 190-151 SF NA SF NA 2.55 8/29/2008 1A-18 190-153 21' 2.80 27" 8/28/2008 1A-20 190-162 21' 2.80 25" 8/28/2008 7.65 8/29/2008 1A-25 190-167 14' 1.90 25" 8/28/2008 7.65 8/29/2008 1J-101 205-182 6" NA 6" NA 1.28 9/5/2008 1J-102 206-110 7" NA 7" NA 1.70 9/5/2008 1J-103 206-114 7" NA 7" NA 1.28 9/5/2008 1J-105 207-027 8" NA 8" NA 1.28 9/5/2008 1J-107 207-107 7" NA 7" NA 1.28 9/5/2008 1J-109 206-050 14" NA 14" NA 8.08 9/5/2008 1J-115 206-122 10" NA 10" NA 2.55 9/5/2008 1J-118 206-176 5" NA 5" NA 6.80 9/5/2008 1J-120 207-045 4" NA 4" NA 2.55 9/5/2008 1J-127 206-047 6" NA 6" NA 1.70 9/5/2008 1J-135 207-038 8" NA 8" NA 1.70 9/6/2008 1J-136 206-154 9" NA 9" NA 1.70 9/6/2008 1J-137 206-108 12" NA 12" NA 5.10 9/6/2008 1J-154 205-035 4" NA 4" NA 4.67 9/6/2008 1 J-156 206-067 8" NA 8" NA 5.95 9/6/2008 1J-159 206-005 20" NA 20" NA 14.87 9/6/2008 1J-160 207-015 20" NA 20" NA 7.23 9/6/2008 1J-164 205-144 20" NA 20" NA 11.90 9/6/2008 1 J-176 207-099 6" NA 6" NA 1.28 9/6/2008 1 J-184 206-044 8" NA 8" NA 1.28 9!6/2008 ConocoPhillips January 29, 2008 T. Maunder State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7t" Avenue Suite 100 Anchorage, Alaska 99501 Subject: Additional Well Summaries Dear Mr. Maunder: . J. Eggemeyer Engineering Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6049 ~. ~~ ~ ~ ~ ~a ~~~~~~~ ConocoPhillips Alaska, Inc. submits the attached well summaries for wells 3~@=44-, -~-"-~;--;~ "",~€ =9-TJ "'G " ' "'G' ", 1J-107 and ~ ' you requested. These summaries will replace the shorter summaries already submitted with the completion reports for these wells. If you have any questions regarding this matter, please contact me at 265-6049. Sincerely, ~~r-~- Eggemeyer Engineering Team Leader CPAI Drilling JE/skad Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA} Sent: Thursday, December 13, 2007 2:33 PM To: 'Eggemeyer, Jerome C.' Subject: 1J-107 (207-107}, 1J-107L1 (207-108) and CD4-07 (207-118} Jerome, Further to our discussions, would you please provide the detailed operations reports for the following well (s}/operations. 1J-147 (207-147) One copy of the full summary (-107 & -107L1} 1J-107L1 (207-108) Summary for lateral (-107L1) only CD4-07 (207-118) One copy of the summary Thanks in advance. Cali or message with any questions. Tam Maunder, PE AOGCC 12/13/2007 n ~J ConocoPhillips December 12, 2007 Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Corrected Well Completion Reports for 1J-107 and 1J-107L1 Dear Commissioner. ConocoPhillips Alaska, Inc. submits the attached corrected Well Completion Reports for the Kuparuk West Sak multi-lateral 1J-107 and 1J-107L1. We have corrected the RKB, permafrost depth and geologic markers. If you have any questions regarding this matter, please contact me at 265-6830 or Pat Reilly at 265-6048. Sincerely, --°~t`~- R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad Alaska .iii ~ ~~s L~n~. ~ommissiot~ Anchorage ~v rr,ec-~Gd STATE OF ALASKA nn ~,~ ~2.~q,n~ ALASKA OIL AND GAS CONSERVATION COMMISSION .REC~~~~ V WELL COMPLETION OR RECOMPLETION REPO G 1a. Well Status: Oil O Gas Plugged Abandoned ^ Suspended 20AAC 25.105 20AAC 25.110 Alaska GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: ~"~P`C . ~rq(~'i1't16bt&jp(1 ry ^ S ~ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., ~ orAband.: September 14, 2007 12. Perms tuber: 207-107 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: August 22, 2007 13. API Number: 50-029-23366-00 4a. Location of Well (Governmental Section): Surface: 3132' FNL,~2422' FEL, Sec. 35, T11N, R10E, UM 7. Date TD Reached: September 4, 2007 14. Well Name and Number: 1J-107 Top of Productive Horizon: 1442' FSL, 2009' FEL, Sec. 36, T11 N, R10E, UM 8. KB (ft above MSL): 109' ~ Ground (ft MSL): 81' ~ 15. Field/Pool(s): Kuparuk River Field Total Depth: 2136' FNL, 1987' FEL, Sec. 1, T10N, R10E, UM 9. Plug Back Depth (MD+ND): ~ 11792' MD / 3661' TVD West Sak Oil Pool - 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558785 ` y- 5945960 ' Zone- 4 10. Total Depth (MD + ND): , 12073' MD ! 3656' ND ` 16. Property Designation: ADL 25661, 25662 TPI: x- 564485 y- 5945301 Zone- 4 Total Depth: x-564538 - 5941723 Zone-4 11. SSSV Depth (MD + ND): none 17. Land Use Permit: 471,2177 18. Directional Survey: Yes Q No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (ND): not available 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/Res 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE ING CORD AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENT RE PULLED 20" x 34" 78.6# H-40 28' 108' 28' 108' 42" 35o sx AS 1 13,375" 68# L-80 28' 3468' 28' 2275' 13.375" 701 sx AS Lite, 227 sx LiteCRETE 9.625" 40# L-80 28' 8721' 28' 3716' 9.625" 660 sx DeepCRETE 5.5" 15.5# L-80 8169' 11792' 3669' 3661' 6.75" slotted liner 23. Open to production or injection? Yes ^ No If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Pertoration Size and Number): SIZE DEPTH SET (MD) PACKER SET 4.5" 7875' none slotted liner from 9778'-11712' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production November 12, 2007 Method of Operation (Flowing, gas lift, etc.) ESP oil -shares production with 1J-107L1 Date of Test 11/12/2007 Hours Tested 4 hours Production for Test Period --> OIL-BBL 190 GAS-MCF 42 WATER-BBL 105 CHOKE SIZE 15% GAS-OIL RATIO 264 Flow Tubing press. 393 psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL 1073 GAS-MCF 284 WATER-BBL 620 OIL GRAVITY -API (corr) not available 27. CORE DATA Conventional Core(s) Acquired? Yes No Q Sidewall Cores Acquired? Yes ^ No If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. ) .: NONE _ ~j. !~, r,~ ~~; Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE ff ~.~~~ ~ ~~ /~/O~ 1-'+x~~` (_ i)F~I.: ~ ~~~~ 1C/ ~ 1, 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ~ Yes ~ No If yes, list intervals and formations tested, Permafrost -Top surface SUrfaCe briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom not available not available needed, and submit detailed test information per 20 AAC 25.071. Ugnu C 5535' 3010' Ugnu B 6195' 3234' Ugnu A 6364' 3293' K13 6853' 3443' West Sak D 7430' 3576' West Sak C 8316' 3667' West Sak B 8491' 3707' N/A Formation at total depth: West Sak B sand 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, slotted liner detail sheet, cement summary 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Pat Reilly @ 265-6048 Printed Nam Rand Thomas Title: Drillino Team Leader ~ Z~f ~6~ ' Signature Phone ~~- ~ ~ ~ Date INSTRUCTIONS Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 ConocoPhillips November 28, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Reports for 1 J-107 and 1 J-107L1 ___-~ Dear Commissioner: P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations of the Kuparuk West Sak multi-lateral 1J-107 and 1J- - 107L1. If you have any questions regarding this matter, please contact me at 265-6830 or Pat Reilly at 265-6048. Sincerely, ~ ~~ R. Thom s Kuparuk Drilling Team Leader CPAI Drilling RT/skad N~1~ ~ ~~ ~rt~T .G,~ ` 5di z~ s,:v rk~'SfJJs~~y ;~i11~ri~~ t'~~~. Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells EK.~t,~C~~~1 STATE OF ALASKA ~~~~ ~' ~ Z~a~ ALASKA OIL AND GAS CONSERVATION C~MI~ WELL COMPLETION OR RECOMPLETI ~~~,Q-NDSSLOG 1a. Well Status: Oil ^/ Gas Plugged Abandoned ^ Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: Development Q Exploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: September 14, 2007 12. Permit to Drill Number: 207-107 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: August 22, 2007 ~ 13. API Number: 50-029-23366-00 4a. Location of Well (Governmental Section): Surface: 3132' FNL, 2422' FEL, Sec. 35, T11 N, R10E, UM 7. Date TD Reached: September 4, 2007 .- 14. Well Name and Number: 1 J-107 ' Top of Productive Horizon: 1442' FSL, 2009' FEL, Sec. 36, T11 N, R10E, UM 8. KB (ft above MSL): 28' RKB Ground (ft MSL): 109' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 2136' FNL, 1987' FEL, Sec. 1, T10N, R10E, UM 9. Plug Back Depth (MD + TVD): 11792' MD / 3661' TVD West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558785 R y- 5945960 ' Zone- 4 10. Total Depth (MD + TVD): ~ 12073' MD / 3656' TVD ` 16. Property Designation: ADL 25661, 25662 TPI: x- 564485 y- 5945301 Zone- 4 Total Depth: x- 564538 ~ - 5941723 - Zone- 4 11. SSSV Depth (MD + TVD): none 17. Land Use Permit: 471, 2177 18. Directional Survey: Yes ^/ No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): 22so' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/Res 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE D O AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING REC R PULLED 20" x 34" 78.6# H-40 28' 108' 28' 108' 42" 35o sx AS 1 13.375" 68# L-80 28' 3468' 28' 2275' 5" 701 sx AS Lite, 227 sx LiteCRETE 9.625" 40# L-80 28' 8721' 28' 3716' ~9r82~" 660 sx DeepCRETE ~ 5.5" 15.5# L-80 8169' 11792' 3669' 3661' 6.75" slotted liner 23. Open to production or injection? Yes ^/ No If Yes, list each 24. TUBING RECORD Interval open (MD+TVD of Top & Bottom; Pertoration Size and Number): SIZE DEPTH SET (MD) PACKER SET 4.5" 7875' none slotted liner from 9778'-11712' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production November 12, 2007 Method of Operation (Flowing, gas lift, etc.) ESP oil -shares production with 1J-107L1 Date of Test 11/12/2007 Hours Tested 4 hours Production for Test Period --> OIL-BBL 190 GAS-MCF 42 WATER-BBL 105 CHOKE SIZE 15% GAS-OIL RATIO 264 Flow Tubing press. 393 psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL 1073 ~ GAS-MCF 284 WATER-BBL 620 OIL GRAVITY -API (corr) not available 27. CORE DATA Conventional Core(s) Acquired? Yes No / Sidewall Cores Acquired? Yes No / If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. rv I~i~f.'it ~ ~ii~i14 ~~ NONE ~ ~j-'a~r VER Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE ~~ ~~ ~)~~1.~ ~ ~7~~r 0 R I G I NA L 12•~f'•o ~~ 28. GEOLOGIC MARKERS (List all formations and mare encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ~/ No If yes, list intervals and formations tested, Permafrost -Top surface surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 3431' 2260' ~ needed, and submit detailed test information per 20 AAC 25.071. T3 3431' 2260' K15 3431' 2260' Ugnu C 5535' 3010' Ugnu B 6195' 3234' Ugnu A 6364' 3293' K13 6853' 3443' West Sak D 7430' 3576' West Sak C 8316' 3667 West Sak B 8491' 3707' West Sak A4 12073' 3656' N/A West Sak A3 12073' 3656' West Sak A2 12073' 3656' Formation at total depth: Kuparuk B sand 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, slotted liner detail sheet, cement summary 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Pat Reilly @ 265-6048 Printed Na Ra Th mas Title: Drillino Team Leader `( ~~ (~' 7 ~ Signature Phone ZG S-~~ ~ ~ Date INSTRUCTIONS Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersibie, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 Halliburton Company Survey Report • Company: ConocoPhillips Alaska Inc . Date: 9/25/2007 Time: '12:03_~F3 Pa;;c: 1 Pirld: Kuparuk River Unit Co -ordin:~~c(~~E~kefcrcncc: WelI:1J-107, Tr ue North site: Kuparuk 1J Pad Vertical (I~ ll) Re ference: 1J107: 109.01- ~~ell: 1J-107 Sectiont~~sjRete rencc: Well (O.OON,I).OOE,180.OOAzi) Wellpath: 1J-107 Sung (~lcularion McUio~[: Minimum Curva ture Db: Oracle Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordin ate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: 1 J-107 Slot Name: API 50-029-23366-00 Well Position: +N/-S 40.55 ft Northing: 5945960.16 ft Latitude: 70 15 46.657 N +E/-W -3.73 ft Easting : 558785.90 ft Longitude: 149 31 29.115 W Position Uncertainty: 0.00 ft Wellpath: 1J-107 Drilled From: Well Ref. Point j API 50-029-23366-00 Tie-on Depth: 28.00 ft ' ' Current Datum: 1J107: Height 109.00 ft ~ Above System Datum: Mean Sea Level Magnetic Data: 8/27/2007 Declination: 23.21 deg Field Strength: 57618 nT Mag Dip Angle: 80.79 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.00 0.00 0.00 180.00 Survey Program for Definitive Wellpath Date: 9/4/2007 Validated: Yes Version: 2 j Actual From To Survey Toolcade Toal Name ft ft 50.00 728.00 1J-107 Gy ro (50.00-728.00) CB-GYRO-SS Camera based gyro single shot 811.33 12042.44 1J-107 /IFR+MS+Sag (811.33-120 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey ylI) Intl ,Mini TVD Sys T~'I) A!ti t:/W ~lapA 114apt: (~ool ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5945960.16 - 558785.90 ~ TIE LINE 50.00 0.13 344.12 50.00 -59.00 0.02 -0.01 5945960.18 558785.89 CB-GYRO-SS 100.00 0.20 198.41 100.00 -9.00 0.00 -0.05 5945960.16 558785.85 CB-GYRO-SS 181.00 0.02 355.46 181.00 72.00 -0.12 -0.10 5945960.03 558785.81 CB-GYRO-SS 264.00 0.76 68.78 264.00 155.00 0.09 0.42 5945960.25 558786.32 CB-GYRO-SS 355.00 3.07 72.90 354.94 245.94 1.02 3.31 5945961.21 558789.20 CB-GYRO-SS 447.00 6.59 75.62 446.60 337.60 3.06 10.78 5945963.30 558796.65 CB-GYRO-SS 541.00 9.22 72.30 539.70 430.70 6.69 23.18 5945967.03 558809.03 CB-GYRO-SS 633.00 12.36 72.36 630.06 521.06 11.92 39.59 5945972.38 558825.39 CB-GYRO-SS 728.00 14.80 71.52 722.40 613.40 18.84 60.79 5945979.48 558846.54 CB-GYRO-SS 811.33 16.50 71.33 802.64 693.64 26.01 82.10 5945986.80 558867.78 MWD+IFR-AK-CAZ-SC 860.56 17.18 71.11 849.75 740.75 30.60 95.60 5945991.50 558881.25 MWD+IFR-AK-CAZ-SC 905.55 17.81 71.53 892.66 783.66 34.93 108.41 5945995.93 558894.03 MWD+IFR-AK-CAZ-SC ~ 955.07 20.62 73.15 939.42 830.42 39.86 123.94 5946000.98 558909.52 MWD+IFR-AK-CAZ-SC i 1001.41 23.35 74.40 982.39 873.39 44.69 140.60 5946005.95 558926.13 MWD+IFR-AK-CAZ-SC j 1047.22 25.44 74.99 1024.10 915.10 49.68 158.85 5946011.08 558944.34 MWD+IFR-AK-CAZ-SC 1092.29 27.68 74.14 1064.42 955.42 55.05 178.27 5946016.60 558963.72 MWD+IFR-AK-CAZ-SC 1140.12 28.20 72.80 1106.67 997.67 61.43 199.76 5946023.14 558985.15 MWD+IFR-AK-CAZ-SC 1186.80 29.58 71.87 1147.54 1038.54 68.28 221.24 5946030.16 559006.58 MWD+IFR-AK-CAZ-SC 1230.99 30.86 72.54 1185.72 1076.72 75.07 242.42 5946037.11 559027.70 MWD+IFR-AK-CAZ-SC 1279.22 30.98 73.49 1227.10 1118.10 82.31 266.12 5946044.54 559051.34 MWD+IFR-AK-CAZ-SC 1324.14 33.54 73.76 1265.08 1156.08 89.07 289.12 5946051.47 559074.29 MWD+IFR-AK-CAZ-SC 1371.33 37.21 73.11 1303.55 1194.55 96.86 315.30 5946059.47 559100.41 MWD+IFR-AK-CAZ-SC j 1415.80 37.77 73.27 1338.84 1229.84 104.69 341.21 5946067.50 559126.25 MWD+IFR-AK-CAZ-SC 1464.52 38.79 72.99 1377.08 1268.08 113.45 370.09 5946076.48 559155.06 MWD+IFR-AK-CAZ-SC 1510.18 39.87 72.16 1412.40 1303.40 122.12 397.70 5946085.37 559182.60 MWD+IFR-AK-CAZ-SC 1552.04 42.44 72.89 1443.92 1334.92 130.38 423.98 5946093.84 559208.81 MWD+IFR-AK-CAZ-SC 1600.37 44.12 74.23 1479.10 1370.10 139.75 455.76 5946103.45 559240.51 MWD+IFR-AK-CAZ-SC 1656.33 45.01 73.99 1518.97 1409.97 150.51 493.52 5946114.50 559278.19 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConacoPhillips Alaska !nc. Bate:. 9/25/2007 Time: 12:03:43 - Pa~~c: 3 Field: Kuparu k River Uni t Co-or dinate(NE} Refercncc: bNell: 1J-10 7, True North ~itc Ku p2rti k 1J Pad Verticat(TVD}RcFcrcncc 1J107' G09. 0 ~~ell: 1J- 107 Sec6on(YS)lteCerencc Well (O.OON,0 00G,180.OOr'~i) y1cIIFa1h: 1J- 107 Survey Calculati on ~te(hod: Minimum C uNature Db: Oracle __ tiunc~ --- ~iD fue l ~i~im TVD SysT~ D \1S Fl~~ ~~1upA ~1apE "Cool ft deg de g ft ft ft ft ft ft 1694. 82 46 .89 73 .80 1545. 73 1436 .73 158. 18 520.10 5946122. 38 559304. 70 MWD+IFR-AK-CAZ-SC 1738. 51 50. 05 72 .81 1574. 69 1465 .69 167. 58 551.42 5946132. 02 559335. 94 MWD+IFR-AK-CAZ-SC 1786. 49 54. 27 72 .30 1604. 12 1495 .12 178. 94 587.56 5946143. 67 559371. 99 MWD+IFR-AK-CAZ-SC 1825. 71 56. 03 72 .61 1626. 53 1517 .53 188. 64 618.25 5946153. 61 559402. 60 MWD+IFR-AK-CAZ-SC 1879. 72 57. 77 73 .04 1656. 03 1547 .03 202. 00 661.47 5946167. 30 559445. 71 MWD+IFR-AK-CAZ-SC 1927. 91 61. 65 74 .00 1680. 33 1571 .33 213. 80 701.37 5946179. 41 559485. 51 MWD+IFR-AK-CAZ-SC 1972. 51 64. 69 75 .15 1700. 46 1591 .46 224. 38 739.73 5946190. 28 559523. 79 MWD+IFR-AK-CAZ-SC 2020. 78 65. 30 74 .77 1720. 86 1611 .86 235. 73 781.98 5946201. 96 559565. 94 MWD+IFR-AK-CAZ-SC 2065. 00 64. 31 74 .96 1739. 68 1630 .68 246. 18 820.60 5946212. 71 559604. 48 MWD+IFR-AK-CAZ-SC 2110. 95 65. 70 74 .70 1759. 10 1650 .10 257. 07 860.80 5946223. 92 559644. 58 MWD+IFR-AK-CAZ-SC 2157. 50 65. 30 74 .17 1778. 40 1669 .40 268. 44 901.60 5946235. 60 559685. 29 MWD+IFR-AK-CAZ-SC 2205. 20 67 .35 73 .01 1797. 56 1688 .56 280. 78 943.50 5946248. 27 559727. 09 MWD+IFR-AK-CAZ-SC 2250. 04 68 .90 72 .52 1814. 26 1705 .26 293. 11 983.24 5946260. 91 559766. 73 MWD+IFR-AK-CAZ-SC 2297. 60 69 .02 72 .55 1831. 34 1722 .34 306. 44 1025.59 5946274. 56 559808. 96 MWD+IFR-AK-CAZ-SC 2342. 90 67. 43 72 .87 1848. 14 1739 .14 318. 94 1065.75 5946287. 38 559849. 03 MWD+IFR-AK-CAZ-SC 2389. 76 66. 74 72 .85 1866. 39 1757 .39 331. 66 1107.00 5946300. 42 559890. 17 MWD+IFR-AK-CAZ-SC 2435. 71 66. 75 72 .28 1884. 53 1775 .53 344. 31 1147.27 5946313. 38 559930. 34 MWD+IFR-AK-CAZ-SC '; 2484. 00 68. 18 72 .21 1903. 04 1794 .04 357. 91 1189.75 5946327. 31 559972. 71 MWD+IFR-AK-CAZ-SC 2529. 28 69. 33 71 .82 1919. 44 1810 .44 370. 94 1229.89 5946340. 65 560012. 74 MWD+IFR-AK-CAZ-SC 2577. 19 69. 55 71 .66 1936. 27 1827 .27 385. 00 1272.49 5946355. 04 560055. 22 MWD+IFR-AK-CAZ-SC 2622. 20 68. 25 71 .90 1952. 47 1843 .47 398. 13 1312.38 5946368. 48 560095. 00 MWD+IFR-AK-CAZ-SC ~ 2668. 72 67. 82 71 .83 1969. 87 1860 .87 411. 55 1353.38 5946382. 23 560135. 89 MWD+IFR-AK-CAZ-SC 2713. 89 66 .59 72 .22 1987. 37 1878 .37 424. 41 1392.98 5946395. 39 560175. 40 MWD+IFR-AK-CAZ-SC 2763. 92 66 .73 72 .18 2007. 19 1898 .19 438. 45 1436.72 5946409. 77 560219. 02 MWD+IFR-AK-CAZ-SC 2806. 82 66 .48 73 .10 2024. 23 1915 .23 450. 20 1474.30 5946421. 81 560256. 50 MWD+IFR-AK-CAZ-SC 2854. 72 69 .37 74 .53 2042. 23 1933 .23 462. 56 1516.93 5946434. 51 560299. 02 MWD+IFR-AK-CAZ-SC 2900. 12 70 .46 74 .39 2057. 82 1948 .82 473. 99 1558.01 5946446. 25 560340. 01 MWD+IFR-AK-CAZ-SC ~ 2948. 44 70. 26 74 .29 2074. 06 1965 .06 486. 27 1601.83 5946458. 87 560383. 73 MWD+IFR-AK-CAZ-SC 2992. 76 69. 56 74 .26 2089. 28 1980 .28 497. 55 1641.89 5946470. 46 560423. 70 MWD+IFR-AK-CAZ-SC 3085. 57 67. 57 74 .63 2123. 20 2014 .20 520. 72 1725.11 5946494. 28 560506. 73 MWD+IFR-AK-CAZ-SC 3132. 09 66. 05 74 .73 2141. 52 2032 .52 532. 02 1766.35 5946505. 90 560547. 88 MWD+IFR-AK-CAZ-SC 3181. 18 66. 40 74 .73 2161. 31 2052 .31 543. 85 1809.69 5946518. 07 560591. 12 MWD+IFR-AK-CAZ-SC 3228. 51 66. 48 74 .40 2180. 23 2071 .23 555. 39 1851.51 5946529. 94 560632. 84 MWD+IFR-AK-CAZ-SC 3275. 61 67. 37 74 .38 2198. 69 2089 .69 567. 05 1893.24 5946541. 92 560674. 48 MWD+IFR-AK-CAZ-SC 3313. 39 67. 91 73 .99 2213. 06 2104 .06 576. 58 1926.86 5946551. 70 560708. 01 MWD+IFR-AK-CAZ-SC 3370. 86 66. 77 74 .05 2235. 20 2126 .20 591. 18 1977.84 5946566. 70 560758. 88 MWD+IFR-AK-CAZ-SC 3428. 39 64 .80 73 .90 2258. 79 2149 .79 605. 66 2028.27 5946581. 58 560809. 19 MWD+IFR-AK-CAZ-SC 3508. 45 65 .65 73 .86 2292. 34 2183 .34 625. 84 2098.10 5946602. 30 560878. 85 MWD+IFR-AK-CAZ-SC 3553. 78 66 .56 73 .77 2310. 71 2201 .71 637. 39 2137.90 5946614. 16 560918. 56 MWD+IFR-AK-CAZ-SC 3648. 62 67 .33 73 .79 2347. 85 2238 .85 661. 77 2221.70 5946639. 19 561002. 15 MWD+IFR-AK-CAZ-SC i 3741. 00 68. 96 73 .90 2382. 23 2273 .23 685. 62 2304.05 5946663. 68 561084. 30 MWD+IFR-AK-CAZ-SC I i 3834. 00 70. 09 73 .84 2414. 76 2305 .76 709. 83 2387.74 5946688. 54 561167. 80 MWD+IFR-AK-CAZ-SC ~ 3925. 88 69. 25 72 .93 2446. 69 2337 .69 734. 46 2470.30 5946713. 81 561250. 15 MWD+IFR-AK-CAZ-SC ' 4019. 42 69. 05 72 .50 2479. 98 2370 .98 760. 43 2553.77 5946740. 43 561333. 41 MWD+IFR-AK-CAZ-SC 4112. 00 69. 97 72 .22 2512. 39 2403 .39 786. 71 2636.41 5946767. 36 561415. 83 MWD+IFR-AK-CAZ-SC 4204. 66 70. 83 72 .12 2543. 47 2434 .47 813. 44 2719.51 5946794. 73 561498. 71 MWD+IFR-AK-CAZ-SC 4296. 95 71. 22 72 .72 2573. 48 2464 .48 839. 80 2802.71 5946821. 74 561581. 69 MWD+IFR-AK-CAZ-SC 4389. 72 69. 76 72 .91 2604. 46 2495 .46 865. 64 2886.24 5946848. 22 561665. 02 MWD+IFR-AK-CAZ-SC 4482. 88 70. 08 73 .18 2636. 44 2527 .44 891. 15 2969.94 5946874. 39 561748. 50 MWD+IFR-AK-CAZ-SC 4574. 50 69 .70 73 .78 2667. 95 2558 .95 915. 62 3052.42 5946899. 49 561830. 78 MWD+IFR-AK-CAZ-SC 4666. 79 69 .30 74 .05 2700. 27 2591 .27 939. 57 3135.48 5946924. 09 561913. 65 MWD+IFR-AK-CAZ-SC 4759. 92 69 .32 74 .51 2733. 17 2624 .17 963. 17 3219.34 5946948. 34 561997. 32 MWD+IFR-AK-CAZ-SC ~ Halliburton Company Survey Report ('ompsmc: ConocoPhillips Alaska Inc. Date: 9/25/20D7 Time: 12:03:43 Page: 3 Fidel: Kuparuk Rlver Urtit Co-ordinaCe(NF) Reference: Well: 1J-107, True North Site Kuparuk 1J Pad VerCicat(TVD) Reference: 1.1107: 109.0 ~~rll: 1J-107 Section (VS~Reference_ Well (0.00N,O.OOE,130.OOAzi) Wellpath: 1J-107 Survey Calculation ~~Ictlwd: Minimum Curvature I>h: Oracle Survey vii) Lrcl ~iim TVD SysTVD ~/S E/W Jlap~ MapF Tool ft deg deg ft ft ft ft ft ft 4851.96 69.12 74.42 2765.82 2656.82 986.22 3302.25 5946972.04 562080.04 MWD+IFR-AK-CAZ-SC 4944.21 69.24 73.71 2798.61 2689.61 1009.89 3385.17 5946996.35 562162.75 MWD+IFR-AK-CAZ-SC 5037.10 69.57 72.13 2831.29 2722.29 1035.43 3468.28 5947022.54 562245.66 MWD+IFR-AK-CAZ-SC 5129.66 69.31 71.68 2863.80 2754.80 1062.35 3550.66 5947050.09 562327.82 MWD+IFR-AK-CAZ-SC 5219.39 68.38 72.17 2896.18 2787.18 1088.31 3630.21 5947076.68 562407.15 MWD+IFR-AK-CAZ-SC 5314.81 68.32 74.53 2931.39 2822.39 1113.72 3715.17 5947102.75 562491.91 MWD+IFR-AK-CAZ-SC 5408.89 69.24 79.77 2965.46 2856.46 1133.21 3800.64 5947122.89 562577.21 MWD+IFR-AK-CAZ-SC 5498.47 69.58 84.14 2996.98 2887.98 1144.94 3883.65 5947135.27 562660.12 MWD+IFR-AK-CAZ-SC 5593.48 69.83 88.67 3029.95 2920.95 1150.52 3972.56 5947141.55 562748.97 MWD+IFR-AK-CAZ-SC 5686.03 70.17 92.04 3061.61 2952.61 1149.98 4059.51 5947141.68 562835.92 MWD+IFR-AK-CAZ-SC 5779.39 70.30 95.30 3093.19 2984.19 1144.35 4147.17 5947136.74 562923.61 MWD+IFR-AK-CAZ-SC 5873.62 70.42 98.27 3124.86 3015.86 1133.87 4235.29 5947126.95 563011.80 MWD+IFR-AK-CAZ-SC 5968.23 69.90 101.75 3156.98 3047.98 1118.41 4322.91 5947112.17 563099.53 MWD+IFR-AK-CAZ-SC 6062.25 70.57 103.76 3188.78 3079.78 1098.87 4409.20 5947093.31 563185.97 MWD+IFR-AK-CAZ-SC 6155.01 70.03 104.41 3220.05 3111.05 1077.62 4493.91 5947072.72 563270.82 MWD+IFR-AK-CAZ-SC 6252.62 68.84 107.35 3254.34 3145.34 1052.63 4581.80 5947048.42 563358.90 MWD+IFR-AK-CAZ-SC 6347.97 70.22 111.93 3287.70 3178.70 1022.60 4665.89 5947019.05 563443.22 MWD+IFR-AK-CAZ-SC 6442.90 71.42 118.05 3318.92 3209.92 984.73 4747.10 5946981.82 563524.72 MWD+IFR-AK-CAZ-SC 6537.38 71.59 122.16 3348.90 3239.90 939.79 4824.60 5946937.50 563602.55 MWD+IFR-AK-CAZ-SC 6633.10 71.92 125.38 3378.87 3269.87 889.27 4900.15 5946887.57 563678.49 MWD+IFR-AK-CAZ-SC 6728.37 73.03 129.59 3407.57 3298.57 833.99 4972.22 5946832.86 563750.98 MWD+IFR-AK-CAZ-SC I ~ 6820.74 73.42 133.95 3434.24 3325.24 775.09 5038.16 5946774.48 563817.37 MWD+IFR-AK-CAZ-SC ~ 6915.02 73.68 136.47 3460.95 3351.95 710.92 5101.85 5946710.82 563881.56 MWD+IFR-AK-CAZ-SC 7008.89 75.88 140.52 3485.60 3376.60 643.10 5161.85 5946643.47 563942.07 MWD+IFR-AK-CAZ-SC 7101.33 75.91 142.79 3508.13 3399.13 572.79 5217.46 5946573.61 563998.23 MWD+IFR-AK-CAZ-SC 7193.75 77.06 146.35 3529.73 3420.73 499.58 5269.54 5946500.81 564050.87 MWD+IFR-AK-CAZ-SC 7285.72 78.20 150.85 3549.44 3440.44 422.92 5316.32 5946424.53 564098.25 MWD+IFR-AK-CAZ-SC 7378.30 79.57 153.64 3567.29 3458.29 342.54 5358.62 5946344.49 564141.17 MWD+IFR-AK-CAZ-SC 7473.98 81.08 156.27 3583.38 3474.38 257.09 5398.54 5946259.37 564181.75 MWD+IFR-AK-CAZ-SC 7567.18 81.96 157.32 3597.12 3488.12 172.37 5434.86 5946174.94 564218.72 MWD+IFR-AK-CAZ-SC 7658.79 82.45 158.14 3609.55 3500.55 88.38 5469.25 5946091.23 564253.77 MWD+IFR-AK-CAZ-SC 7745.84 84.17 159.20 3619.69 3510.69 7.85 5500.70 5946010.95 564285.84 MWD+IFR-AK-CAZ-SC 7793.88 83.31 158.18 3624.93 3515.93 -36.64 5518.05 5945966.60 564303.54 MWD+IFR-AK-CAZ-SC 7845.90 83.32 158.54 3630.98 3521.98 -84.66 5537.10 5945918.73 564322.96 MWD+IFR-AK-CAZ-SC 7889.41 82.95 158.63 3636.18 3527.18 -124.88 5552.88 5945878.65 564339.05 MWD+IFR-AK-CAZ-SC 7935.43 83.13 159.91 3641.76 3532.76 -167.60 5569.05 5945836.05 564355.55 MWD+IFR-AK-CAZ-SC 8035.65 83.26 163.56 3653.64 3544.64 -262.09 5600.23 5945741.83 564387.47 MWD+IFR-AK-CAZ-SC 8131.42 83.32 164.73 3664.83 3555.83 -353.58 5626.21 5945650.55 564414.16 MWD+IFR-AK-CAZ-SC 8225.53 83.20 165.56 3675.87 3566.87 -443.91 5650.17 5945560.41 564438.82 MWD+IFR-AK-CAZ-SC I 8278.10 83.20 167.27 3682.10 3573.10 -494.65 5662.43 5945509.77 564451.48 MWD+IFR-AK-CAZ-SC ~ 8320.83 82.88 169.24 3687.28 3578.28 -536.18 5671.07 5945468.32 564460.44 MWD+IFR-AK-CAZ-SC ~ 8416.56 83.14 172.70 3698.93 3589.93 -630.00 5685.98 5945374.62 564476.08 MWD+IFR-AK-CAZ-SC ~ 8511.06 85.70 176.07 3708.12 3599.12 -723.58 5695.17 5945281.13 564486.00 MWD+IFR-AK-CAZ-SC 8605.14 87.34 177.47 3713.83 3604.83 -817.34 5700.46 5945187.43 564492.02 MWD+IFR-AK-CAZ-SC 8699.58 89.36 179.62 3716.55 3607.55 -911.70 5702.86 5945093.10 564495.15 MWD+IFR-AK-CAZ-SC ~ 8816.40 90.31 181.13 3716.89 3607.89 -1028.51 5702.09 5944976.30 564495.30 MWD+IFR-AK-CAZ-SC 8913.79 94.40 180.90 3712.89 3603.89 -1125.78 5700.37 5944879.02 564494.34 MWD+IFR-AK-CAZ-SC 9008.00 96.45 180.65 3703.98 3594.98 -1219.55 5699.10 5944785.25 564493.80 MWD+IFR-AK-CAZ-SC 9103.79 96.49 179.82 3693.19 3584.19 -1314.73 5698.71 5944690.08 564494.15 MWD+IFR-AK-CAZ-SC 9197.69 95.00 178.63 3683.79 3574.79 -1408.15 5699.98 5944596.69 564496.15 MWD+IFR-AK-CAZ-SC 9292.12 94.94 179.24 3675.61 3566.61 -1502.21 5701.72 5944502.66 564498.63 MWD+IFR-AK-CAZ-SC 9387.08 95.07 179.42 3667.32 3558.32 -1596.80 5702.83 5944408.08 564500.47 MWD+IFR-AK-CAZ-SC 9480.55 92.51 178.60 3661.14 3552.14 -1690.04 5704.44 5944314.87 564502.81 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report r Company: ConoCOPhillips Alaska Inc. Date 9!25!2007 I imc? 12:03:43 Pagc: -1 Field: Kuparuk River Unit (~o-urdiuatelNE)Referencc: WeH: 1J-107, True North Site: Kuparuk 1'J Pad ~'crtiail If'~ D) Reference: 1 J 107' 103.0 Welh 1 J-107 Scctiun i ~~5) Refereuce: Well (O OON.O.OOE,180.OOAzi) ~1'ellpaCh: 1J-107 tiuncy~ Calcidadonblethod: Minimum Curvature Ub: Oracle __ _ _ __ SUn'Pc >tU Inc! ~iiin TVD S~ti'I ~'D niti Fa~~ MapN MapE Tool ft deg deg ft ft ft ft ft ft ~ 9576.01 91.23 178.44 3658.03 3549.03 -1785.42 5706.91 5944219.52 564506.02 MWD+IFR-AK-CAZ-SC 9670.43 87.76 177.91 3658.86 3549.86 -1879.77 5709.91 5944125.20 564509.77 MWD+IFR-AK-CAZ-SC 9766.65 87.71 178.24 3662.66 3553.66 -1975.86 5713.14 5944029.15 564513.74 MWD+IFR-AK-CAZ-SC 9860.82 90.13 179.16 3664.44 3555.44 -2069.98 5715.28 5943935.06 564516.62 MWD+IFR-AK-CAZ-SC ~ 9956.63 90.43 179.28 3663.97 3554.97 -2165.78 5716.58 5943839.28 564518.67 MWD+IFR-AK-CAZ-SC 10051.08 90.99 180.10 3662.80 3553.80 -2260.22 5717.09 5943744.86 564519.92 MWD+IFR-AK-CAZ-SC 10142.79 90.61 181.57 3661.52 3552.52 -2351.91 5715.76 5943653.17 564519.29 MWD+IFR-AK-CAZ-SC 10237.61 90.80 182.34 3660.35 3551.35 -2446.67 5712.52 5943558.40 564516.80 MWD+IFR-AK-CAZ-SC 10331.27 89.25 181.47 3660.31 3551.31 -2540.27 5709.41 5943464.78 564514.42 MWD+IFR-AK-CAZ-SC 10422.87 89.38 180.93 3661.41 3552.41 -2631.84 5707.49 5943373.21 564513.22 MWD+IFR-AK-CAZ-SC 10517.22 89.81 180.04 3662.07 3553.07 -2726.19 5706.69 5943278.87 564513.15 MWD+IFR-AK-CAZ-SC 10609.90 90.99 179.80 3661.43 3552.43 -2818.86 5706.82 5943186.20 564514.01 MWD+IFR-AK-CAZ-SC 10702.30 89.62 179.00 3660.93 3551.93 -2911.25 5707.79 5943093.83 564515.69 MWD+IFR-AK-CAZ-SC 10795.92 90.68 179.59 3660.69 3551.69 -3004.86 5708.94 5943000.24 564517.58 MWD+IFR-AK-CAZ-SC 10890.63 92.48 179.93 3658.08 3549.08 -3099.53 5709.34 5942905.59 564518.71 MWD+IFR-AK-CAZ-SC 10983.05 90.29 180.00 3655.84 3546.84 -3191.92 5709.40 5942813.21 564519.49 MWD+IFR-AK-CAZ-SC 11075.91 90.06 179.13 3655.56 3546.56 -3284.78 5710.10 5942720.38 564520.92 MWD+IFR-AK-CAZ-SC I 11170.73 89.75 178.81 3655.72 3546.72 -3379.58 5711.80 5942625.60 564523.36 MWD+IFR-AK-CAZ-SC ' 11265.97 89.63 178.11 3656.23 3547.23 -3474.78 5714.36 5942530.42 564526.67 MWD+IFR-AK-CAZ-SC 11359.14 90.19 178.22 3656.38 3547.38 -3567.91 5717.35 5942437.34 564530.38 MWD+IFR-AK-CAZ-SC 11454.32 89.25 178.64 3656.84 3547.84 -3663.05 5719.96 5942342.23 564533.73 MWD+IFR-AK-CAZ-SC i 11548.66 89.01 179.02 3658.28 3549.28 -3757.36 5721.88 5942247.95 564536.39 MWD+IFR-AK-CAZ-SC 11643.67 90.00 179.44 3659.10 3550.10 -3852.35 5723.16 5942152.97 564538.41 MWD+IFR-AK-CAZ-SC 11738.69 88.88 179.78 3660.03 3551.03 -3947.37 5723.80 5942057.98 564539.80 MWD+IFR-AK-CAZ-SC I 11832.97 89.32 180.43 3661.51 3552.51 -4041.63 5723.63 5941963.72 564540.36 MWD+IFR-AK-CAZ-SC 11927.60 90.93 181.45 3661.30 3552.30 -4136.25 5722.08 5941869.11 564539.55 MWD+IFR-AK-CAZ-SC I ~ 12020.13 92.47 181.05 3658.56 3549.56 -4228.71 5720.06 5941776.64 564538.25 MWD+IFR-AK-CAZ-SC ~ 12042.44 92.40 181.10 3657.61 3548.61 -4251.00 5719.64 5941754.35 564538.01 MWD+IFR-AK-CAZ-SC -12073.00 92.40 181.10 3656.33 ~ 3547.33 -4281.52 5719.06 5941723.82 - 564537.66 -PROJECTED to TD i ~-~ 1J-107 S/oited and Blank Liner Detail Well : 1J-107 ConocoPh~ll~ps °e" Sand Liner detail Date: si5~2oo7 Alaska;anc, Rig• Doyon 141 DEPTH Jt Number . ;: Num of Jts COMPLETE DESCRIPTION OF UlPllp~lJT RUN Pa 1: }~~ S ' i~ . 3 ~ '~ ~ : ti,, ,'~~ . %~:~+ '',,~,-~~ rah ~. :'(}k~•i:ice ::~y'k •. 4 .y !s{r ' ~ '~ ' ~¢ ^^` ~ ;~ "R \' .. . .. ~ OD(in) nominal [reserved] ff {rESeNedj jCe~gNedj Max OD(in) actual [reserved] ifeSe Ned] iYESeNedj.. ID(in) actual (reseeedj [fese Nedj jfeseNedj LENGTH - TOPS : : .: : >:.'...:;;..,iY ice' + ..i: :4ii . 4}"':?.:?.::Y:::?i:: iii: ?:.:: »iiii: iiiiiiJiiiJ::::::::i::::::i::::i::::::i::: [~~''~'~k~(~l:.f..csr.::.~(~ :.....:...:.....:.:::...:::.::..:::<;.;;;:.;:.:;.;;;;;:.;:<;,:,:.;:,:.;;;;;>;......... ' 8158.37 5" Drill Pi a to Surtace =___> 8158.37 8158.37 8158.37 Baker Liner setting tool( Does not stay in hole) 6.65 8.15 3.06 11.10 8158.37 Baker "ML" ZXP Liner Top Pkr 7.00" X 9.625" (SF 44K) 8.31 8.43 6.32 21.22 8169.47 7.0" X 9.625" "Flex-Lock" Liner Hgr, 8.32" OD/ 6.20" ID 8.3 8.3 6.1 5.29 8190.69 Cross Over Bushing 7"X 5.5" Hyd 563 OD 7.67" ID 4.91" 765 765 4.91 1.40 8195.98 190-47 Seal Bore Ext, Hyd 563 box X pin 6.26 6.26 4.75 19.25 8197.38 5.5" XO Pup Jt 5.5 Hyd 563 b X 5.5" BTCM p 5.56 6.05 4.98 1.55 8216.63 Jts 48 to 80 33 Jts 5.5" 15.5 f L80 BTCM Blank cs w/ TR 5.5 6.05 4.95 1422.33 8218.18 pup}t-!5.5'`'15.5# L80 BTCM blankrr,esg w/TR 5.5 6.05 4.95 9.22 9640.51 Swell Packer ' '' 5.53 7.94 4.95 18.96 9649.73 ipu 't -' S.5" ' 15.5#' L80 BTCM blankcsg end w/TR< 5.5 6.05 4.95 9.19 9668.69 Jts 46 to 47 2 Jts 5.5" 15.5 f L80 BTCM Blank csg w/TR 5.5 6.05 4.95 87.12 9677.88 2:.: fS`'.~~s~`:`:?'(~L8i3~')`~)UC3i%Ff~~~~Ot<~>~2~3```' 5.5 6.05 4.95 3 50 1 9765.00 Jts 1 to 45 45 Jts 5.5" 15.5 f L80 BTCM Slotted csg w/ TR 5.5 6.05 4.95 1933.40 9778.50 pu jt = 5.5" ,15.5# L8b BTGM blank>~esg w/,TR '` 5.5 6.05 4.95 9.01 11711.90 .Swell Packer > '! 5.5 7.9T 4.95 18.90 11720.91 pup jt -45.5" 15.5# L80 BTC'N1 blank!csg w /TR 5.5 6.05 4.95 9.19 11739.81 5.5" 15.5 f L80 BTCM Blank cs shoe 'oint w/ TR 5.5 6.05 4.95 43.00 11749.00 End is orange peeled and welded closed =__> 11792.00 11792.00 52 Trq Rings installed on Jts #80 thru # 28 11792.00 Torq to 10,990K when ring installed. 11792.00 Liner was ran to bottom without rotating. On bttm weigh t 71K 11792.00 11792.00 At Window - Up wt 135K, Dn wt 77K, Rot wt 95K 11792.00 Torq 5-7K , 20 RPMs 11792.00 After liner released - Up wt 155K, Dn wt 83, Rot wt 107K 11792.00 Torq 7-8K 20 RPMs 11792.00 11792.00 11792.00 11792.00 11792.00 Ran total of 35 Jts, BT CM Blanks =1509.45' and 45 'ts BTCM Slots = 1933.40' Ran 2 Swell Packer - To s 11,721' and 9, 650' Slots are 0.125" wide x 2.5" Ion x 32 slo/ft. w/ 32 2.5" Ion x .125" 4 U Wt 160k Circumferential ad'acent rows, 3" Centers sta ered 18de . 3' non-slotted ends. Rot Wt 71 k Ran total of 77 -Ran 1 er 't h droform 5.5' X 8" 3 rib from 'oint #2 thru 78 Block Wt 34k Torqued BTC liner w/o torque rings to 5500+/- ft-Ibs, w/torque rings to 10,900 ft-Ibs Used Run-N-Seal thread com ound on all connections. All drifted w/ 3.875" rabbit. Supervisors: Dearl Gladden/ Nina Woods r ~ Daily Operations Summary Report 1J-107 .~`~~~R~~®~ ~~~~ Field Name WEST SAK ~ Primary Job Type !!Secondary Job Type /API / UWI DRILLING ORIGINAL I 5002923366 Contractor Rlg Name/No Rig Accept Date Rlg Release Date DOYON 9/15/2007 141 8/22/2007 Marl Ddle _ _ EnrJ Dale Laet 2Jnr Sum 18/1/20 18/2/2007 I Moved rig onto 1J-107 3/22/200 5'23/2007 From 312 to 3/22107 rig was on summer maintenance. Accepted riy @ 00:01 hrs, PU 8 stood back 65 sb9s of 5" DP, fin NU Diverter & function tested same. MU 16" Bit #1 & spudded well @ 19'50 hrs. drilled from 108'to 224`, ', POOH & cont. to fotU BHA #1 X8/23/2007 .8/24/2007 Fin. MU BHA #1 & cont. to drill 16" hole from 224' to 1.650' ,~ 8/24/2007 ~ 8/25/2007 Directionally drilled 16" hole from 1,650' to 3.361' 8/25/2007 '26/2007 Drilled from 3,361' to 3,475' (Csg Pt). BROOH to 207' wino problems, POOH & LD BHA #1 . RU &RIH w113 318" csg and landed same 2i 3.468' w/no problems- Began to circ and cond mud for cementing. 3/2E.~2007 18!?_ 07 Circ hole while W.O. vac trucks then cemented 13 318" csg, bumped plug ~C had 70 bbls of good cmt back to '~ surface. ND Diverter & MU Vetco Gray MB 222 welhead, Began NU BOP stack i 8/27/2007 8/28/200 Fin. NU BOP stack and lines, tested BOPE 250/3,000 psi, blind rams failed, changed out and retested OK. Installed wear bushing, MU Geopilot BHA #2 & RIH to 3,370', (FC @ 3,385') RU & began testing csg to 3,000 psi 8/28/2007 9;29/2007 ~ Fin. testing csg for 30 min. OK Drill Shoe track + 25' new hole -Displace to 9.0 ppg LSND mud -Perform LOT to !12.6 ppg EMVi' -Drilled 12-114" Int. hole with GP front 3500'to 6244' MD. 18/29/2007 8/30/2007 Drilled 12-1 /4" Int. Hole with GP from 6244' to 7749' MD. POOH to inspect BHA due to slow drilling. .8/30/2007 8/31/2007 OOH from 7,597'-7.226', hole swabbing. BROOH 7,041' to 3,~~T then POOH to BHA. Change out 12-114" Bit ' damaged teeth and cutters TIH -Drill 1Z-1!4' Intermediate hole with GP from 7,749'to 8,152' MD. 8/31/2007 9!1/2007 Drill 12-1 /4" Intermediate with GP from 8.152' to 8,723' MD / 3,718' TVD. POOH. LD BHA_ RU and RIH with 9-5/8" g to 2.20'?' MD. 9l1/2007 9!7_,12007 Continue RIH with 9-5/8" Csg -Circ & Condition mud -Pump 12.5 ppg cement & Displace with OBM - G1P @ t715 hrs Csg at 8.721' MD with Est TOC (w 5,035' MD. Cut pipe - PU 8 set csg slips -install PO & test. Set Wear Ring. P orm LCT on OA to 12.1 ppg EMW. Cut & Slip DL. 9/2/2007 X113;2007 TIH with BHA#4 rill out shoe track + 23' new hole -Perform LOT to 13.1 ppa EMW - Dril 8-1 /2" B Lateral with GeoPilot from 875 9840' MD. 9/3/2007 ' 9/4/2007 'Drilled 8-112" B Latera ith GP From 9,840' MD to 10,376' MD r 3.659' TVD. Drilled through 22 concretions for a total of 252'. 9/4/2007 9.`5 2007 Drilled 8-1/2" B Lateral with P from 10.876' MD to 12.073' MD / 3,656' TVD. Drilled through 8 concretions for a total of 42'. BROOH to 8.662 irc Hi-Vis Sweep -TIH -Circ 2x BU -Displace open hole to SFOBM Cont POOH. 9/5/2007 9/612007 !DISPLACE CSG FROM 7.913' TO SFOBM W/776 LUBE, POOH & LD BHA# 4. RU ~ R1H WITH 'B' SAND '5.5" LINER TO 11.792' MD TOP LINER SET AT 8.169' MD. POOH WITH RUNNING TOOL PREP FOR '.WHIPSTOCK RUN. 19/6/2007 9/7/2007 RIH with Whipstoeklfutilling Assembly, D Pass across K13. Orient 14 deg Left Hi-Side, and shaar off I whipstock. Displace to MOBOM. Set TO t 8,047' MD -BOW at 8,064' MD. Milled 'D' sand window from 8,047' I to 8,108' MD. 25' of gauge hole to 8,089' M irc & dress window -POOH. Pull Wear Ring, Flush Stack, Install wear ring. MU BHA #6. 9/7/20Q7 .:9/8/2007 TIH WITH BHA#6 -SLIP & CUT DL -DRILLED 8- " D LATERAL FROf~1 8.108' TO 9,541' MD. 9/8/2007 9/9/2007 Drilled 8-1/2" D Lateral from 9,541' to 12,02'1' MD. B OH to 10,830' MD. 9/9/2007 9/10/2007 BROOH to TOW -POOH & LD BHA #6 BOPE Test t 00 psi Iow13,000 psi high, AOGCC waived witnessing of ' the lest- PU Hcle opener BHA #7 - RIH to 12,021' MD - p Hi-Vis Sweep and Circ.. 9i 10/2607 ~i9/11/2007 /DISPLACE'D' LATERAL WITH SFOBM TO TOW - DISPLA FROM TOW TO SURFACE WITH 176 LUBE ISFOBM. POOH. RIH WITH FISHING ASSEMBLY & RETRIE WHIPSTOCK. CBU, MONITOR WELL. LD j WHIPSTOCK BHA AND CLEAR FLOOR. 9!11;2007 ~+It?J2007 I PJSM on "D" lateral liner, Run "D" lateral liner, shallow test MWD, to 5021', repair hydraulic leak on the top drive,continue RIH to 10932', circ and orient to Hook window. Hook wr ow, unhook orient and go past window and tag bottom, PU, orent to hook, Hook more 3 times, set down 25k of ook. drop 29/32" ball pump to seat, sheared early (2400 psi), drop 1-3/4" hall, pump to seat. pressure to 3500 and release liner, PU then L/D .single dp, monitor evell. POOH wet, LID running tools, clean floor. 9/121"2007 9/13/2007 Clean floor, PJSM, Slip and oul drilling line, PJSM, L/D 5" dp f/ the derrick, puff w r bushing, PU completion equipment, RU/ run 4-1/2" completion, install pump w/ Halliburton slick line, install koff, service motor w/ Centralift. Depth @ midnight 126'. ..9/13/2007 ',9/14/2(107 PAake capilllary line connection and motor wire connection, run 4-1/2" 12.6 ppf L-80 IBT- ESP completion, testing the 1.39" OD round wire every 25 jts run, instatlithe GLM afterjt # 181, then contin nnirx to jt #250. then PI_I/MtJ hanger w/ full jt (4-112" IBT PxPI. MU landing joint, install penetrator, measure a cuf then splice 1..9" OD cable to pigtail. MU to penetrator, test ,land. RILDS, test lower hanger body seals to 0 and 5000 psi fl 10 min each. f Page 1/2 Report Printed: 1'I/12/2007~i Daily Operations Summary Report 1 J-107 Start Datn End Dale La: ~ 5/14/2007 9/15/2007 Test upper hanger body seals to 250 c ,pull landing ~omt, set BPV, change lower pipe rams to 4", N/D BOP ra ift test ESP penetrator, NU tree, test hanger void to 250 and 5000 psi V, install TWC, test tree to 250 psi and 5000 psi,PJSM, perform final ESP cable ec s- OK, freeze protect well w/diesel, pumped 565 bbls, returned 500 bbls. Blow down lines, PU lubricator, install BPV, secure well, clean cellar. Rig released @ midnight 2359 hrs 9/14/2007 for 11 mile move to 2Z-01 A. SIJP~RS~~~i~ Page 2l2 Report Printed: 11/12/2007', Cementing Detail for AGOCC L~q~l ;.eilName Cc r r Su;n~ i9J-907 ~Gonductor.108.OftKB 1J-107 Surface.3,467.8ftKB 12/6/2006 12/6/2006 8/26/2007 8126/2007 Dowell pumped 5 bblsof CW 100 then pressure tested lines to 3.000 psi, coat to pump 70 add. 8bls of CW 100 at 8.3 ppg. Pumped 55 bbls of 10.5 ppg mudpush with red dye at 4.9 bpm at 260 psi. Dropped bottom plug. Mixed and pumped 570 bbls, 701 sx of Arctic set lite cement at 10.7 ppg and 4.45 cu fL'sk yield with additives at 6.0 bpm at 555 psi. Continued mixing and pumping 99 bbls. 227 sx of Litecrete cement at 120 ppg and 2.49 cu ft/sk yield with additives at 6.0 bpm at 400 psi- Shut down and dropped top plug. Dowell chased plug with 20 hbls of water then turned it over to the rig and rig cont. to displace cement with 9.1 ppg mud at 6.0 bpm, initial pressure was 550 psi, max pressure at 3.5 bpm was 680 psi, lost all returns with 102.6 t;b! left into displacement- Bumped plug on calc displacement of 487 bbls, pressured up to 1,350 psi and held for three minutes, bled off and checked 'Floats-OK. CIP at 13:30 hrs, Had 70 bbls of good 10.7 ppy cement back at surface. 1J-107 Intermediate, 8,721.OftKB 9/112007 91112007 Dement Program as folbws: Dowell pumped 2 bbls water and PT lines to 3200 - 50 bbls of 8.4 ppg CW-100 at 4 bpm, 120 psi - 50 bbls of 11.4 ppg Mud Push @ 4 bpm, 240 psi -Dropped Btm Plug -Batch up and pumped 264 bbls of 12.5 ppg DeepCRETE cement, 660 sks, 2.25 yield with additives -Ave 6.5 bpm at 900 psi. Reciprocated csg while pumping. Flush lines with 3 bbls water and Dropped Top Plug. Swap over to mud pumps and displace with 8.4 ppg OBM @ 7 bpm, 780 psi. Stopped reciprocating pipe 510 bbls into displacement. Reduced rate to 3 bpm, 580 psi @ 630 bbls into displacement. Bumped plug @ 646 bbls (calculated displacement 651 bbls) -Pressured up to 1100 psi for 5 mins - Bled off and checked floats which held. Good retums throughout job with talc TOC @ 5,035' MD. Dwn wt 105k, PU and set slips at 185k for st wt of 80k. ** ICIP @ 17:15 hrs ** www.peloton.com Page 1/1 Report Printed: ConoCOPhillips Time Log Summary WeINIer+ VYeb R- sorFing Well Name: 1J-107 Job Type: DRILLING ORIGINAL Time Logs Date From To Dur S. De th E. De~th _ Phase Code Subcode T COM ___ _ 08/01/2007 18:00 20:00 2.00 _ MIRU MOVE DMOB _ P Prep rig to move from 1J-122 -Pull apart complexes starting with pipe shed #1 & #2 & Rockwasher -Pull apart power pack (Boilers, Motors, Pum s, Pits and set aside. 20:00 21:00 1.00 MIRU MOVE MOB P Pull Sub base off 1J-122. Spot Sub over 1J-107. 21:00 00:00 3.00 MIRU MOVE MOB P Set all complex's *" NOTE"' Starting @ 0001 hrs 8-2-2007 Doyon 141 will be working the Summer Maintenance ro ram scheduled for 2 weeks +/- 08/22/2007 00:00 01:00 1.00 0 0 MIRU MOVE RURD P RU stabbing board winch and mud bucket, tested pipe skate and prep. pipe shed for drill pipe, ACCEPTED RIG 00:01 hrs, 8/22/07 01:00 06:00 5.00 0 0 MIRU MOVE OTHR P Loaded pipe shed with 195 jts of 5" DP and strapped same, Sim-op: NU 20" riser and diverter and line, took on water in mud pits and began mixing s ud mud. 06:00 14:00 8.00 0 0 MIRU MOVE OTHR P PU and stood back 35 stds of 5" slick DP then PU and stood back 30 stds of 5" DP with super sliders. Then PU and stood back 5 stds of HWDP. (Note: Installed super sliders in pipe shed 14:00 15:45 1.75 0 0 MIRU MOVE OTHR P PU BHA to rig floor then PU and stood back 1 std of 8" NMFDC's 15:45 16:15 0.50 0 0 MIRU WELC BOPE P Function tested Diverter and knife valve then performed a Koomey test. Note: John Crisp with AOGCC waived witnessin of the test. 16:15 17:00 0.75 0 0 SURFA DRILL PULD P MU 16" bit #1 on 8" motor with 1.83" deg. bend and RIH tagging fill inside conductor at 93'. 17:00 17:45 0.75 0 0 SURFA DRILL OTHR P Flooded conductor and pressure tested surface lines to 3,000 si. 17:45 19:15 1.50 0 0 SURFA RIGMN RGRP T Repaired leak on standpipe master valve and repaired lower IBOP on top drive, retested line to 3,000 psi and ck'd ok. 19:15 19:45 0.50 0 0 SURFA DRILL CIRC P Cleaned out fill inside conductor from 93' to 108'. 19:45 23:00 3.25 0 224 SURFA DRILL DRLG P Spudded well at 19:50 hrs and drilled 16" hole from 0' to 224', ADT 2.75 hrs. 23:00 23:30 0.50 224 42 SURFA DRILL TRIP P POOH from 224' to motor at 42'. Time Logs Date ____Fro TTo Dur S Depth E_ Depth Phase Code Subcode T COM _ 08/22/2007 23:30 00:00 0.50 42 42 SURFA DRILL RURD P RU Gyro scheave and wireline. 08/23/2007 00:00 01:30 1.50 42 224 SURFA DRILL PULD P MU BHA #1 RIH to 224', MU MWD and oriented and uploaded same, MU UBHO sub and oriented same then RIH with NMFDC's and HWDP to 224'. 01:30 12:00 10.50 224 813 SURFA DRILL DDRL P Directionally drilled 16" hole and took G ro surve s from 224' to 813' MD/804' TVD (589') ART 3.14 hrs, AST 3.07 hrs. 12:00 00:00 12.00 813 1,650 SURFA DRILL DDRL P Directionally drilled 16" hole from 813' to 1,650' MD/ 1,510' TVD, (837'), ART 2.15 hrs, AST 5.82 hrs. Note ran 10 gyro surveys up to 825' and RD Gvro at 1 000' 08/24/2007 00:00 01:30 1.50 1,650 1,650 SURFA DRILL REAM NP Reamed dogleg out at base of the permafrost from 9 deg's down to 5 de 's, reamed from 1,595'to 1,650'. 01:30 12:00 10.50 1,650 2,514 SURFA DRILL DDRL P Directionally drilled 16" hole from 1,650' to 2,514' MD/ 1,914' TVD, (864' , ART 2.98 hrs, AST 3.20 hrs. 12:00 00:00 12.00 2,514 3,361 SURFA DRILL DDRL P Directionally drilled 16" hole from 2,514' to 3,361' MD/ 2,231' TVD, 847' , ART 4.11 hrs, AST 3.97 hrs. 08/25/2007 00:00 00:45 0.75 3,361 3,475 SURFA DRILL DDRL P Directionally drilled 16" hole from 3,361' to 3,475' MD/2,278' TVD, (114'), (13 3/8" csg pt.) ART 0.46 hrs, AST 0.16 hrs. 00:45 08:00 7.25 3,475 207 SURFA DRILL REAM P Monitored well-static, backreamed out of hole from 3,475' to 207', BROOH at 60 rpm's and 5-10K ft-Ibs torque and at 630 gpm at 1,840 psi and slowed to 500 gpm at 1,000 psi at 620', and cunt to BROOH to 207'. No problems BROOH. 08:00 10:00 2.00 207 0 SURFA DRILL PULD P Downloaded MWD and LD BHA #1, LD MWD, motor and bit, cleared and cleaned ri floor. 10:00 12:15 2.25 0 0 SURFA CASIN RURD P RU to run 13 3/8" csg, changed out elevator bales and MU Franks tool. 12:15 12;30 0.25 0 0 SURFA CASIN( SFTY P Held PJSM with rig crew and tong operator on running of csg and the associated hazards. 12:30 20:30 8.00 0 3,468 SURFA CASIN RNCS P MU 3 jts 13 3/8" 68#, L-80 BTC csg and shoe track and thread locked same RIH to 80' then checked floats. Cont. RIH with 13 3/8", 68#, L-80, BTC csg, broke circ every 20 jts while RIH and getting up and down wts, MU Vetco Gray hanger and landed csg at 3,468', no problems .RIH, ran 82 jts total of csg ,total flt equip and csg ran including hanger 3,437.41'. Initial P/U wt = 300K, S/O =90k, Ran 22 bowspring centralizers and 2 stop rin s er well Ian. ~~ ~~ Time Lo s !Date From Tn four S neoth F Denth Phase CndP SubcodP T COM 08/25/2007 20:30 00:00 3.50 3,468 3,468 SURFA CEME~ CIRC P Began to circ hole thru Franks fill up tool while conditioning mud for. cementing, staged pump rate up to 40 spm, 4 bpm at 350 psi and after circ 300 bbls lost all slack off wt while attempting to increase pump rate to 5 bpm, slowed pump rate to 3 bpm at 300 psi and began reciprocating pipe 2X every 10 min's and landing in han er while conditionin mud. 08/26/2007 00:00 02:00 2.00 3,468 3,468 SURFA CEME~ CIRC P Cont. to circ and cond mud reciprocating pipe 2-3X every 10 min's and with conditioned mud around the shoe staged pump rate up from 3 bpm to 5 bpm at 800 psi, then reciprocated pipe continuous for 15 min and hole looked good reci rocatin i e at 290K up wt and 65K do wt, shut down to LD fill up tool, circ a total of 1,200 bbls since landin cs . 02:00 03:00 1.00 3,468 3,468 SURFA CEME~ RURD P RD Franks fill up tool, blew down top drive and MU Dowell cement head. 03:00 04:45 1.75 3,468 3,468 SURFA CEME~ CIRC P Cont to circ and condition mud for cementing and waiting on additional vac trucks for cement job, staged pump rate up to 6 bpm at 250 psi and after reciprocating csg for 30 min, lost all slack off wt., set on han er fin circ btms up after MU cmt head, slowed pump rate to 4 bpm then attempted to reciprocate pipe, took 330K to break over then RIH with cs sto in 1' off the hanger, increased pump rate to 6 bpm then PU on csg, took 375K to move csg then after several attempts was able to work csq down into the , hanger. Finished conditioning mud for cementing, Initial mud was 9.1 ppg, 193 vis, PV 20 and YP of 35, conditioned mud to 9.1 ppg, 40 vis, PV 11 and YP 6. 04:45 08:30 3.75 3,468 3,468 SURFA CEME~ CIRC NP Cont to circ hole at 5 bpm while waiting on vac trucks. Held PJSM with crew, Dowell and ASRC truck drivers on cement job while circ. (no i e movement &'~;~s~ ~ ref ~2 • Time Logs _ _ _ ___ From To Dur S De th E De th Phase Code Subcode T COh~4 Date _ 08/26!2007 08:30 12:00 3.50 3,468 3,468 SURFA CEME~ DISP _ P _ Dowell pumped 5 bbls of CW 100 then pressure tested lines to 3,000 psi, cont to pump 70 add. Bbls of CW 100 at 8.3 ppg. Pumped 55 bbls of 10.5 ppg mudpush with red dye at 4.9 bpm at 260 psi. Dropped bottom plug. Mixed and pumped 570 bbls, 701 sx of Arctic set lite cement at 10.7 ppg and 4.45 cu ft/sk yield with additives at 6.0 bpm at 555 psi. Continued mixing and pumping 99 bbls, 227 sx of Litecrete cement at 12.0 ppg and 2.49 cu ft/sk yield with additives at 6.0 bpm at 400 psi.. Shut down and dropped to lu . 12:00 13:45 1.75 3,468 3,468 SURFA CEME~ DISP P Dowell chased plug with 20 bbls of water then turned it over to the rig and rig cont. to displace cement with 9.1 ppg mud at 6.0 bpm, initial pressure was 550 psi, max pressure at 3.5 bpm was 680 psi, lost all returns with 102.6 bbl left into displacement. Bumped plug on calc displacement of 487 bbls, pressured up to 1,350 psi and held for three minutes, bled off and checked floats-OK. CIP at 13:30 hrs, Had 70 bbls of good 10.7 ppg cement back at surface. 13:45 15:15 1.50 3,468 3,468 SURFA CEME~ RURD P RD cement head, LD landing jt and csg tools, cleaned out cmt valve, cleared and cleaned ri floor. 15:15 18:00 2.75 3,468 3,468 SURFA WELCT NUND P ND Diverter and line and removed from cellar. 18:00 19:45 1.75 3,468 3,468 SURFA WELCT NUND P Mu Vetco Gray MB-222 wellhead and oriented same, tested seal to 5,000 si for 10 min. 19:45 00:00 4.25 3,468 3,468 SURFA WELCT NUND P Began NU BOP stack after rig maintenance, NU Annular to VBR's, installed VBR's ram bod 08/27/2007 00:00 06:30 6.50 0 0 SURFA WELC NUND P Fin. NU BOP stack, choke and kill lines, installed blind rams, riser and turnbuckles. 06:30 13:00 6.50 0 0 SURFA WELCT BOPE P RU and tested BOPE, tested rams, valves and manifold fo 250 psi low and 3,000 psi high, blind rams failed, changed out and retested same testing ok. tested rams with 5" and 9 5/8" test jts. NOTE: Bob Noble with AOGCC witnessed the test. 13:00 13:30 0.50 0 0 SURFA DRILL OTHR P Installed long wear bushing. (12 5/16" ID 13:30 14:15 0.75 0 0 SURFA DRILL PULD P PU BHA #2 to rig floor. 14:15 14:30 0.25 0 0 SURFA DRILL SFTY P Held PJSM with Sperry Sun and crew on MU BHA. Time Logs _ __ _ Date From To Dur S De th E. De th Ph se Code Subcod e T COM _ __ 08/27/2007 14:30 18:00 3.50 0 540 SURFA DRILL _ _ PULD P MU 12 1/4" Geopilot BHA #2 RIH to 540', MU new 12 1/4" bit on 9600 Geopilot and MWD then uploaded same, cont. RIH with 1 std of 8" NMFDC's, HWDP and jars to 449', then PU 3 jts of 5" DP from pipe shed RIH to 540'. 18:00 18:30 0.50 540 540 SURFA DRILL OTHR P Est. circ and broke in Geopilot 18:30 19:45 1.25 540 1,399 SURFA DRILL TRIP P Cont. RIH with BHA #2 PU 5" DP out of the pipe shed RIH from 540' to 1,399'. 19:45 20:00 0.25 1,399 1,399 SURFA DRILL DHEQ P Shallow tested MWD at 1,399' at 600 m at 900 si and ck'd ok. 20:00 22:45 2.75 1,399 3,370 SURFA DRILL TRIP P Cont. RIH from 1,399' PU 5" DP from the pipe shed, PU 90 jts total RIH to 3,300', est circ at 2.5 bpm at 20 rpm's and washed down from 3,300' to 3,370' when it started to take wt. (FC set @ 3,385' 22:45 23:15 0.50 3,370 3,370 SURFA DRILL CIRC P Circ hole clean at 3,370' for csg test, circ at 620 gpm at 1,400 psi, 60 rpm's, 9.0 ppg MW in and out, rot wt 83K, up wt 88K, do wt 80K 23:15 00:00 0.75 3,370 3,370 SURFA CASIN( DHEQ P RU and be an testin 13 3/8" cs to 3 000 i f 08/28/2007 00:00 00:30 0.50 3,370 3,370 SURFA CASINC DHEQ P Continue testing 13-3/8" Csg to 3000 psi for 30 mins -Good Test -Rig down e ui ment. 00:30 02:30 2.00 3,370 3,475 SURFA CEME~ DRLG P Drilled out plugs, flt collar, shoe track, & shoe from 3,370' to 3475' MD. 02:30 03:00 0.50 3,475 3,500 SURFA DRILL DDRL P Drilled 25' of new hole to 3500' MD. 602 GPM @ 1400 psi, 70 rpm. ECD 9.66 ADT = 0.29 hrs TRO = 5-10 ft'Ibs PU WT = 118K, SP wt = 62K, Rot Wt = 84K 03:00 03:45 0.75 3,500 3,468 SURFA DRILL CIRC P Pull up into casing -Circulate BU's at same rates. 03:45 04:30 0.75 3,468 3,468 SURFA DRILL CIRC P Displaced hole over to reconditioned 9.0 ppg LSND mud -Circ @ 602 GPM, 1250 psi, 70 rpm - Trq 5-10k ft'Ibs. 04:30 05:00 0.50 3,468 3,468 SURFA DRILL LOT P RU equipment and perform LOT to 0 psi with 9.0 ppg mud 3,468' MD. RD. 05:00 12:00 7.00 3,500 4,520 INTRM1 DRILL DDRL P Record SPR's -Drill 12-1/4" Intermediate with GP from 3500' to 4520' MD, 2652' TVD (1,020'). ADT 4.47 hrs. Max Gas 575 units. 12:00 00:00 12.00 4,520 6,244 INTRMI DRILL DDRL P Dril 12-1 /4" Intermediate with GP from 4520' to 6244' MD, 3250' TVD. (1,724') Max Gas = 690 units. ADT 7.72 hrs. ECD 9.70 PU a total of 13 Su er sliders. --~-- ® - a~~e >= t~# 22 _ Time Logs __ _ Date From To Dur S Depth E Depth Phase Code Subcode T COM 08/29/2007 00:00 12:00 12.00 6,244 7,567 INTRM1 DRILL DDRL P Drill 12-1/4" Intermediate with GP from 6,244' to 7,567' MD ! 3,597' TVD. (1,323') Max Gas = 640 units. Slow drilling through 93' of concretions from 9:40 to 15:40 hrs. ADT 7.48 hrs. ECD 9.80 12:00 23:15 11.25 7,567 7,749 INTRM1 DRILL DDRL P Drill 12-1/4" Intermediate with GP from 7,567 to 7,749' MD / 3,621' TVD. (182') Max Gas = 51 units. Slow drilling through 62' of concretion/hard section from 16:20 - 23:15 hrs. ADT 4.12 hrs. ECD 9.87 23:15 23:30 0.25 7,749 7,749 INTRM1 DRILL CIRC T Decision made to pull out of hole & inspect bit -Unable to make hole drilling with minimal WOB and deflection without working in low torsional effeciency -Concern over possible damage to GP. Attempted to drill with zero deflection on bit and drilling continued to be slow (made 30') with concern over not being able to hold angle -kicked up to 85 deg. Circulated to obtain zero tool face and discuss o tions. 23:30 00:00 0.50 7,749 7,597 INTRM1 DRILL REAM T Monitor well -Static -POOH on elevators 5 stands. 08/30/2007 00:00 06:00 6.00 7,597 3,397 INTRM1 DRILL REAM T POOH from 7597' to 7226' MD -Pipe swabbing with an over pull of 25-55k - Hook up TD and pump out from 7226' to 7041' MD @ 3 bpm, 250 psi -Hole appears to be packing off, erratic SPP and Trq with 25-40k over pull - BROOH from 7041' to 3397' MD @ 700 GPM, 2150 si, 150 r m, Tr 8-12k ft*Ibs. 06:00 07:00 1.00 3,397 3,397 INTRM1 DRILL CIRC T Circulate above casing shoe until clean returns across shakers - 700 m, 1650 si, 120 r m, Tr 6k ft*Ibs 07:00 07:45 0.75 3,397 450 INTRM1 DRILL TRIP T Cont POOH from 3397' to 450' MD 07:45 08:15 0.50 450 150 INTRM1 DRILL PULD T Rack back 3 Stands of HWDP, Jars, 1 Std NM FC's - PU to MWD tools and Plu -in. 08:15 09:15 1.00 150 150 INTRM1 DRILL OTHR T Download MWD and check oil in GeoPilot -Good: 09:15 09:45 0.50 0 0 INTRM1 DRILL PULD T Change out Bit -Bit graded low with heavy wear and damage to outer teeth, worn teeth and cutters, dull, slightly undergauge -Damage to Top Stabilizer. 09:45 10:30 0.75 0 532 INTRM1 DRILL TRIP T TIH with BHA #3 to 532' MD 10:30 10:45 0.25 532 532 INTRM1 DRILL OTHR T Shallow Hole Test MWD 10:45 12:00 1.25 532 2,735 INTRM1 DRILL TRIP T Continue to TIH from 532' to 2735' MD. 12:00 13:30 1.50 2,735 7,692 INTRM1 DRILL TRIP T Continue to TIH from 2735' to 7692' M D. ~ ~~ ~~~ ~. s Time Logs _ _ ___ Date Fro_m___ To Dur S _D th E. De th Phase_ Code Subcode T COM _ 08/30/2007 13:30 14:15 0.75 7,692 7,749 INTRM 1 DRILL CIRC T Wash and ream from 7692' to deepest depth drilled - 7749' MD @ 700 GPM, 2200 si, 100 r m, Tr 7k ft*Ibs. 14:15 00:00 9.75 7,749 8,152 INTRM1 DRILL DDRL P Continue Drilling 12-1/4" Intermediate with GP from 7749' to 8152' MD / 3668' TVD (403' Total). ADT = 6.18 hrs, .Max Gas = 201 units. 08/31/2007 00:00 05:30 5.50 8,152 8,728 INTRM1 DRILL DDRL P Continue Drilling 12-1/4" Intermediate with GP from 8,152' to 8,728' MD / 3,718' TVD (576' Total). ADT = 4.41 hrs, Max Gas = 219 units. 05:30 07:30 2.00 8,728 8,728 INTRM1 DRILL CIRC NP Waiting on decision for plan forward from Town Engineers and Geologists. Recipricate pipe circulating at reduced rates. 07:30 12:00 4.50 8,728 3,959 iNTRM1 DRILL REAM P BROOH from 8728' MD to 3959' MD at 120 RPM, 764 GPM, 2650 psi, Trq 10k Ft'Ibs. 12:00 12:30 0.50 3,959 3,394 INTRM1 DRILL REAM P Continue to BROOH from 3959' to 3394' MD 120 m, 760 m. 12:30 13:15 0.75 3,394 3,300 INTRM1 DRILL CIRC P Pull above shoe @ 3468' MD -Pump 30 BBL Hi Vis Sweep -Circulate & Reci i e from 3394' to 3300' MD. 13:15 13:30 0.25 3,300 3,300 INTRM1 DRILL OWFF P Monitor well and pump slug. 13:30 14:30 1.00 3,300 296 INTRM1 DRILL TRIP P POOH on elevators and Std Back HWDP and Jars. 14:30 15:15 0.75 296 60 INTRM1 DRILL PULD P LD 8" Flex DC's, Stabilizers, and float sub -Clear Ri floor. 15:15 16:00 0.75 60 60 INTRM1 DRILL OTHR P Download MWD Data 16:00 17:00 1.00 60 0 INTRMI DRILL PULD P LD MWD tools, Geo-Pilot, and Bit. 17:00 18:00 1.00 INTRM1 DRILL OTHR P Pull wear ring & Clear rig floor of drillin a ui ment. 18:00 20:00 2.00 INTRM1 CASINC RURD P RU equipment to run 9-5/8" Csg - Scaffolding, Slips, Elevators, Bails, Franks Fill-U tool, Cs Ton s. 20:00 20:30 0.50 INTRM1 CASINC SFTY P PJSM to discuss hazards and review rocedures for runnin casin . 20:30 00:00 3.50 0 2,202 INTRM1 CASINC RNCS P Run 9-5/8" Csg, 40# L-80 BTCM as follows to 2202' MD :Weatherford 303 Sure Seal Float Shoe - 2 Jts - Weatherford 402 Sure Seal Float Clr - 1 Jt -1 Pup Jt - 13 Jts -Window Jt - 2 Pup Jts - 34 Jts. BakerLoc First 3 Jts. Checked Floats. 09/01/2007 00:00 01:00 1.00 2,202 3,439 INTRM1 CASIN RNCS P Continue to RIH with 9-5/8" 40# L-80 BTCM Cs from 2,202' to 3,439' MD. 01:00 02:00 1.00 3,439 3,439 INTRM1 CASINC CIRC P Circulate BU just above surface csg shoe at 3,468' MD - 5 BPM, 250 si. _. _ ~_~ f~~qe ? ref • L Times _ _ _ __ Date From To Dur S Depth E Depth Phase Code Subcode T COM 09/01/2007 02:00 09:00 7.00 3,439 8,721 INTRM1 CASIN RNCS P Continue RIH with 9-5/8" 40# L-80 BTCM Csg from 3,439' to 8,721' MD. (RIH 14 stands and wash down 2). No Problems encountered RIH. Ran 216 total jts of csg with 3 pup jts to put window jt on depth at 8,036' MD. FC @ 8,631' MD and btm of shoe @ 8,721' MD. Total of 216 jts of csg run. Jt #216 cut off with 11' in hole. Ran tandem rise bowspring centralizer with stop ring on Jt #1 and Jt #3 10' above FC and FS and 4 on jts #200, 204, 208, and 213 for a total of 6. Ran 89 Brunel BOS21 polymer cents on Jts #2 and #4 - 92. Ran 61 Roller Cent from jt# 135 - 195. Run 3 Turbolators with fins floating on Jt # 7 and 3 floating on Jt# 18. ** No centralizer on window 't**. 09:00 11:15 2.25 8,721 8,721 INTRMI CEME CIRC P Circulate & condition mud for cementing - Recip pipe pumpina throu h Franks fill-u to I. Staged pumps up to 6 BPM, 400 psi. PU Wt = 215K, SO Wt = 100k. 11:15 12:00 0.75 8,721 8,721 INTRM1 CEMEf+ RURD P RD Franks fill up tool -Blow Down Top Drive - MU Dowell Cement head. 12:00 13:45 1.75 8,721 8,721 INTRM1 CEME CIRC P Continue to circulate and condition mud for cementing. Initial mud 9.6 ppg, 48 vis, PV 13, and YP 21. Conditioned mud to 9.1 ppg, 34 vis, PV 8, and YP 11. Up Wt 220k & Dwn Wt105k. 13:45 14:00 0.25 8,721 8,721 INTRM1 CEME SFTY P PJSM with Crew and Dowell pumping supervisor. Review hazards and Conti enc tans. 14:00 15:30 1.50 8,721 8,721 INTRM1 CEME DISP P Pump Cement Program as follows: Dowell pumped 2 bbls water and PT tines to 3200 psi - 50 bbls of 8.4 ppg CW-100 at 4 bpm, 120 psi - 50 bbls of 11.4 ppg Mud Push @ 4 bpm, 240 psi - Dropped Btm Plug -Batch up and pumped 264 bbls of 12.5 ppg DeepCRETE cement, 660 sks, 2.25 yield with additives -Ave 6.5 bpm at 900 psi. Reciprocated csg while pumping. Flush lines with 3 bbls water and Dro ed To Plu . ~. _ - _ ®®- Paga 3 ~~ Z~~ Time Logs ~ __ __ _ D e From To Dur S Depth E. Depth Phase Code Subcode T COM 09/01/2007 15:30 17:15 1.75 8,721 8,721 INTRM1 CEME DISP P Swap over to mud pumps and displace with 8.4 ppg OBM @ 7 bpm, 780 psi. Stopped reciprocating csg 510 bbls ~ ~ into displacement. Reduced rate to 3 bpm, 580 psi @ 630 bbls into ~~ displacement. Bumped plug @ 646 ~a ~ " bbls (calculated displacement 651 v ~ bbls) -Pressured up to 1100 psi for 5 mins -Bled off and checked floats which held. Good returns throughout job with talc TOC @ 5,035' MD. Dwn wt 105k, PU and set slips at 185k for st wt of 80k. ** ICIP 17:15 hrs 17:15 18:00 0.75 8,721 8,721 INTRM1 CEME~ RURD P RD Cement head and blow down lines - Pum out fluids into 't to be cut. 18:00 18:45 0.75 8,721 8,721 INTRM1 WELCT EQRP P PU BOP stack - Vetco gray reps set cs sli s & SO with 80k on sli s. 18:45 21:30 2.75 8,721 8,721 INTRM1 WELCT EQRP P Cut off 9-5/8" csg with pneumatic cutter and LD remaining jt stub (31.90'). Dress stub and install pack off. 21:30 22:30 1.00 8,721 8,721 INTRMI WELC NUND P NU BOPE -Reset riser -Test Pack-Off and O-Rings to 2400 psi for 10 mins -Good test. Set wear rin . 22:30 23:00 0.50 8,721 8,721 INTRM1 DRILL LOT P RU on 13-3/8" x 9-5/8" outer annulus and erformed LOT to 12.1 ppg EMW~ 360 psi with 9.1 ppg mud @ 2,275' TVD. 23:00 00:00 1.00 INTRM1 RIGMN SVRG P PJSM to slip & cut 77' of drill line. Sim Ops - Began to flush OA with 228 bbls of water -pumping 3 bpm at 700 psi. ICP = 500 si. 09/02/2007 00:00 00:30 0.50 INTRM1 RIGMN SVRG P Continue to slip & cut dril & line - 84.5' - SimOps Continue pumping water flush down the OA - Pumped a total of 228 BBLS water. 00:30 01:00 0.50 INTRM1 RIGMN SVRG P Service top drive & Draw works. 01:00 02:00 1.00 0 60 INTRMI DRILL PULD P PU and MU BHA #4 with 8-1/2" bit, Geo-Pilot, NM Flex DC's -Smart Stab - MWD w/DGR, EWR, PWD, Smart Stab, MWD HCIM, MWD TM HOC. 02:00 02:45 0.75 60 60 INTRM1 DRILL OTHR P Plug in and upload MWD. 02:45 03:15 0.50 60 450 INTRM1 DRILL PULD P Cont MU BHA -Flt sub, 3 NMDC's, 1 HWDP, Jars, 3 HWDP, and 3 jts of 5" DP. 03:15 03:45 0.50 450 450 INTRM1 DRILL DHEO P SHT MWD tools @ 600 gpm, 1400 psi -Test Good. 03:45 05:00 1.25 450 3,108 INTRM1 DRILL TRIP P PU and single in 81 jts of 5" DP from shed + 1 std 5" DP to 3108' MD. 05:00 05:15 0.25 3,108 3,108 INTRM1 DRILL OTHR P Break in bearing Geo-Pilot & fill pipe. 05:15 05:30 0.25 3,108 3,773 INTRM1 DRILL TRIP P Cont to TIH from 3108' to 3773' MD. 05:30 05:45 0.25 3,773 3,773 INTRMI DRILL OTHR P Test Geo-Pilot and Geo-Span manifold. ~_ ~~. ~ _ ~~v~~ ~ of 2 ~ ~ Time Logs _ _ _ Hate From To f)ur S Depth E Denth Phase Code Subcode T COM 09/02/2007 05:45 07:15 1.50 3,773 8,657 INTRM1 DRILL TRIP P Continue TIH from 3,773' to 8,567' MD. Little Red pumping freeze protect the OA -Total of 133 BBLS diesel at 2 b m, 1050 si. 07:15 07:30 0.25 8,567 8,635 INTRM1 DRILL CIRC P Wash down and tag up on plug @ 8635' MD. Pumping 3 bpm, 250 psi with no rotation. 07:30 07:45 0.25 8,635 8,635 INTRM1 DRILL CIRC P Circulate air out of string at 600 gpm - um i e volume. 07:45 08:45 1.00 8,635 8,635 INTRM1 DRILL DHEQ P RU and test 9-5/8" Cs to 3000 si for 30 mins -Record test on chart -Good Test. 08:45 11:15 2.50 8,635 8,728 INTRM1 CEME~ DRLG P Drill out Float collar, shoe track. 11:15 11:45 0.50 8,728 8,751 INTRM1 DRILL DDRL P Drill 23' of new hole to 8751' MD at 5454 gpm, 2350 psi, 100 rpm, trq 9500 11:45 12:30 0.75 8,751 8,751 INTRM1 DRILL CIRC P Circulate & condition mud for LOT- PU Wt 140k, Rot Wt 95k, SO Wt 76k. Pump 600 gpm @ 2600 psi, 50 rpm, Tr 9k ft'Ibs. 12:30 13:15 0.75 8,751 8,751 INTRM1 CEME~ LOT P , Perform LOT to 13.1 EMW -Blow Down TD & Wash/ream to btm. 13:15 00:30 11.25 8,751 9,840 PROD1 DRILL DDRL P Dril18-1/2" B Lat with GP from 8,751' to 9,840' MD / 3,665' TVD. ADT 7.51 Hrs. Max Gas 221 units. Drilled throu h 4 concretions for a total of 33'. 09/03/2007 00:00 12:00 12.00 9,840 10,464 PROD1 DRILL DDRL P Drill 8-1/2" B Lat with GP from 9,840' to 10,464' MD ! 3,662' TVD. ADT 8.96 Hrs. Max Gas 299 units. Drilled through 11 concretions for a total of 84'. 12:00 00:00 12.00 10,464 10,876 PROD1 DRILL DDRL P Drill 8-1/2" B Lat with GP from 10,464' to 10,876 MD / 3,659' TVD. ADT 10.1 Hrs. Max Gas 131 units. Drilled through 11 concretions for a total of 252' - 42% of total footage drilled last 12 hrs. 09/04/2007 00:00 11:30 11.50 10,876 12,073 PROD1 DRILL DDRL P Drill 8-1/2" B Lat with GP from 10,876' to 12,073' MD / 3,656' TVD. ADT 8.91 Hrs. ECD 10.74. Max Gas 340 units. Drilled through 8 concretions for a total of 42'. 11:30 12:00 0.50 12,073 11,962 PROD1 DRILL REAM P Flow check -Static. Record SPR's. BROOH from 12,073' MD to 11,962' MD, 630 gpm, 3100 psi, 140 rpm, Trq 10k. 12:00 16:15 4.25 11,962 8,662 PROD1 DRILL REAM P PJSM -Continue BROOH from 11,962' MD to 8,785' MD, 650 gpm, 140 rpm. Pump out from 8,785' to 8,662' and 650 m. 16:15 17:45 1.50 8,662 8,567 PROD1 DRILL CIRC P Circulate and recip pipe from 8,662' - 8,567'. Pump 30 bbls Hi-Vis sweep at 650 gpm, 2200 psi, 100 rpm. Returned 15% excess to shakers. Continue circulatin BU's. Monitor well -Static. Time_Logs _ __ _ _ I~atp Frnm Tn flur ~ rlanth F ~lanth Phaca r:n~1a ~nhrnriP T (C~~~ 09/04/2007 17:45 18:30 0.75 8,567 12,073 PROD1 DRILL TRIP P RIH to 12,054' MD - PU a single & wash/ream back to btm @ 12,073' MD clean . 18:30 21:00 2.50 12,073 11,993 PROD1 DRILL CIRC P Circulate 2x BU and recip pipe from 12,073' to 11,993' MD at 640 gpm, 3200 si, 130 r m. 21:00 22:00 1.00 11,993 11,960 PROD1 DRILL CIRC P Pumped 298 bbls of 8.4 ppg 50/50 VersaPro SFOBM. Monitor well - Static - LD Sing-e. Mud Engineer held PJSM with truck crew prir to dis lacement. 22:00 23:00 1.00 11,960 10,639 PROD1 DRILL TRIP P POOH 15 stands on elevators to 10,639' MD. Check well -Static. Wanted to verify that well was not swabbing before continuing with dis lacement of o en hole. 23:00 23:30 0.50 10,639 10,639 PROD1 DRILL CIRC P Pump remaining 50 bbls of SFOBM and chase with 100 bbls OBM. Monitor well -Static. 23:30 00:00 0.50 10,639 9,885 PROD1 DRILL TRIP P Continue to POOH on elevators to 9,885' MD. Hole is takin ro er fill. 09/05/2007 00:00 01:00 1.00 9,885 7,913 PROD1 DRILL TRIP P CONTINUE POOH FROM 10,639' TO 7,913' MD. PU WT 170K, SO WT 55K. 01:00 02:00 1.00 7,913 7,913 PROD1 DRILL CIRC P DISPLACE HOLE WITH SFOBM W/ 776 LOBE TO SURFACE. INITIAL CIRCULATION AT 636 GPM @ 2700 PSI -REDUCED RATE DOWN TO 424 GPM @ 1400 PSI (TO KEEP UP WITH VAC TRUCKS) PUMPED A TOTAL OF 560 BBLS. 02:00 04:30 2.50 9,713 354 PROD1 DRILL TRIP P CONT TO POOH FROM 7,913' TO 354' MD. 04:30 05:00 0.50 354 35 PROD1 DRILL PULD P STAND BACK 2 STDS OF HWDP & JARS, 1 STD N FLEX DC'S, AND UD FLT SUB. 05:00 05:45 0.75 35 35 PROD1 DRILL PULD P PLUG IN + DOWN LOAD MWD. 05:45 06:45 1.00 354 0 PROD1 DRILL PULD P CONT UD BHA#4: TM HOC, HCIM, SMART STAB, MWD W/DGR+EWR+PWD, SMART STAB, NM GEO-FLEX, GEO-PILOT+BIT. 06:45 07:00 0.25 0 0 COMPZ DRILL OTHR P CLEAN & CLEAR RIG FLR. 07:00 07:30 0.50 0 0 COMPZ CASINC RURD P R/U FOR 5.5" LINER RUN. 07:30 07:45 0.25 0 0 COMPZ CASIN( SFTY P PJSM ON HAZARD RECOGNITION ON M/U LINER. ~~cx~ 1 ~ ~f ~~ Time Logs _ _ _ Date From To Dur S Depth E. De th Phase Code Subcode T COM __ _. 09/05/2007 07:45 11:30 3.75 0 3,633 COMPZ CASIN( PUTB P P/U + M/U 5.5" 15.5 PPF L-80 BTCM LINER PER DETAIL: BLANK CSG SHOE JT WITH ORANGE PEELED END - PUP JT -SWELL PKR -PUP JT - 45 JTS OF SLOTS - 2 PUP JTS - BLANKJTS - PUP JT -SWELL PKR - PUP JT - 33 JTS BLANK - HYD 563 XO BTCM PUP -SEAL BORE EXTENSION - XO BUSHING WITH 4.91" ID -FLEX-LOCK LINER HANGER - ZXP LINE TOP PKR. TOTAL OF 45 JTS OF SLOTTED CSG AND 35 JTS OF BLANK CSG. 77 HYDROFORM CENTRALIZERS RUN ON JT #2 - 78. INSTALLED 52 TRO RINGS ON JTS #28 - 80. 11:30 12:00 0.50 3,633 3,633 COMPZ CASIN( RURD P CLEAR RIG FLOOR - UD CSG TOOLS THROUGH THE BEAVERSLIDE AND PU SLIPS, ELEVATORS TO RUN DP. 12:00 16:00 4.00 3,633 11,792 COMPZ CASIN( RUNL P PJSM. CONTINUE TO RIH W/LINER ON 5" DP TO MD 11769' - P/U SINGLE. PU WT 160K, SO WT 70K. 16:00 18:00 2.00 11,792 11,792 COMPZ CASIN CIRC P BREAK CIRCULATION & RIH TO 11796' -DROP BALL & P/U TO SETTING DETH OF 11,792' MD - PUMP BALL ON SEAT AND PRESSURE UP TO 1800# TO HANGER. PRESSURE UP TO 2550 PSI TO SET PACKER. HELD FOR 5 MIN. BLEED OFF -PRESSURE UP BACK SIDE TO 3000PSI TO TEST ZXP PACKER. HOLD FOR 10 MIN - GOODTEST. BLEED OFF. PRESSURE UP TO 4000 PSI ON DP AND RELEASE RUNNING TOOL. BLEED OFF PRESSURE. PICKUP 10' (UP WT 160K) S/O & CONFIRM T.O.L. @ 8,169' MD. UD SINGLE. LINER SHOE JT SET AT 11,792' MD, XO BUSHING WITH 4.91" MIN ID SET AT 8,196' MD. SWELL PKRS SETAT 11,721' MD AND 9,650' MD. 18:00 19:00 1.00 8,169 8,121 COMPZ CASIN CIRC NP CIRC @ 8,121' - DP FLOWING BACK DUE TO FLUID EMBALANCE AND FLUID ON THE BACK SIDE A LITTLE HEAVY. 19:00 22:15 3.25 8,121 11 COMPZ DRILL TRIP P POOH WITH RUNNING TOOL - (DISP 8 BBLS LONG). MONITOR WELL - STATIC. 22:15 23:00 0.75 11 0 COMPZ DRILL PULD P BREAK & UD BAKER RUNNING TOOL. 23:00 00:00 1.00 0 0 COMPZ DRILL OTHR P CLEAR & CLEAN RIG FLR -HOIST MILLING TOOLS TO FLOOR AND PREP FOR WHIPSTOCK RUN. 09/06/2007 00:00 00:15 0.25 0 PROD2 STK OTHR P PJSM to MU Baker Whipstock/Milling Assembl with Baker, S er ,Crew. i Time Logs h ~' Date From To Dur S De th E De th Phase Code Subcode T COM i 09/06/2007 00:15 01:45 1.50 0 183 PROD2 STK PULD P MU "D" sand whipstock and milling assembly: Bull nose, Seal Assembly, Stop sub, Unloader sub, 2 Jts HWDP, Blanks Sbu, Btm Trip Anchor, Safety disconnect, Drain sub, String Magnet, Debris Sub, 9-5/8" Window Master Whipstock Slide (17' length), 6-3/16" Window Mill, 8-3/8" Lower String Mill, Flex Jt, 8-1/2" Upper mill, 1 Jt HWDP, Float Sub. Top of Upper mill is 19' back. 01:45 04:00 2.25 183 183 PROD2 STK PULD P PU 6-3/4" MWD with DGR, EWR, PWD, Smart Stab, HCIM, TM HOC - Orient - Plu in and u load. 04:00 04:15 0.25 183 519 PROD2 STK PULD P MU Bumper sub and stands of HWDP. 04:15 04:30 0.25 519 519 PROD2 STK OTHR P Shallow hole test MWD -Pump at 500 GPM, 800 si -Check OK. 04:30 07:30 3.00 519 6,955 PROD2 STK TRIP P TIH with Whipstock/Milling Assembly from 519' to 6,955' MD -Filling pipe @ 2895' and 5246' MD. 07:30 08:00 0.50 6,955. 7,145 PROD2 STK OTHR P Made MADD pass across K-13 sand from 6,955' to 7,145' MD. Pumped 487 m, 1480 si. 08:00 08:45 0.75 7,145 8,132 PROD2 STK TRIP P Continue TIH from 7,145' to 8,132' MD. 08:45 09:15 0.50 8,132 8,047 PROD2 STK OTHR P RIH and Orient 14 deg Left Hi-Side- Tagged up on "B" Lateral ZXP PKR @ 8169' MD. Set trip anchor with 28K dwn wt. (Before set PU Wt = 140, SO Wt = 68k). Worked string to shear bolt with 10k over pull and 35k dwn wt block wt. 09:15 09:45 0.50 8,047 8,047 PROD2 STK CIRC P Begin to displace well from SFOBM over to MOBM at 10 b m, 1160 si. 09:45 12:00 2.25 8,047 8,051 PROD2 STK WPST P Milled from 8,047' to 8,051' MD @ 297 GPM, 700 si, 90 r m, Tr 7-8k ft*Ibs. 12:00 14:15 2.25 8,051 8,064 PROD2 STK WPST P PJSM and continue milling window ~ from 8,051' MD to 8,064' MD. Pumped ~ a 30 bbl Hi-Vis weighted sweep at A ` ~ (~ 8,056' MD -Returned 50% excess. ' ~ l MD. TOW is Pumped sweep at 8,064 at 8,047' MD, BOW at 8,064' MD. 14:15 16:15 2.00 8,064 8,108 PROD2 STK WPST P Drill from 8,064' MD to 8,108' MD to provide 25' of Gauge Hole for upcoming GP run from 8,064' to 8,089' MD. Pum hi-vis swee at 8,096' MD. 16:15 17:00 0.75 8,108 8,108 PROD2 STK CIRC P Circulate hole clean while ream/dress mills throu h the window. 17:00 17:30 0.50 8,108 8,046 PROD2 STK OTHR P Monitor Well -Static. Pump slug and la dwn 2 sin les to shed. 17:30 20:30 3.00 8,046 183 PROD2 STK TRIP P POOH -Stand back HWDP - LD Bumper Sub. Displacement 5 bbls Ion .Monitor well -Static. 20:30 21:30 1.00 183 183 PROD2 STK OTHR P Down Load MWD. ~~qe ' ~ cif ~2 ' Time Logs f)atp Frnm Tn fli it ~ f)anth F f7anth Phaca ('nria Si ihrnriP T f CAM 09/06/2007 21:30 22:00 0.50 183 0 PROD2 STK PULD P Continue POOH with Milling Assembly and LD -Upper Mill Full Gauge, all mills looked ood. 22:00 22:30 0.50 0 PROD2 STK PULD P Clean milling assembly - LD via beaver slide. 22:30 23:15 0.75 PROD2 STK OTHR P Pull wear ring -Flush Stack -Function test Bag, Top and Btm Rams, and Blinds -Install Wear Rin . 23:15 00:00 0.75 0 76 PROD2 DRILL PULD P PU and MU BHA #6 with Bit, Geo-Pilot, NM Geo-Flex, MWD, Flt Sub. 09/07/2007 00:00 00:45 0.75 76 76 PROD2 DRILL PULD P PLUG IN & UP LOAD MWD. 00:45 01:15 0.50 76 354 PROD2 DRILL PULD P P/U 1 STD NM FLEX DC'S. 1 STD HWDP W/JAR L/D JAR #15061082, P/U JAR #15061081, 1 STD HWDP. 01:15 01:45 0.50 354 354 PROD2 DRILL DHEO P BREAK IN BEARINGS ON GEO-PILOT & SHT MWD 530 GPM , 1000 PSI. 01:45 04:00 2.25 354 7,910 PROD2 DRILL TRIP P TIH F/ 354' T/ 7910' FILLING PIPE @ 2729' & 5108'. 04:00 04:45 0.75 7,910 7,910 PROD2 RIGMN SVRG P PJSM, SLIP & CUT DRILL LINE 71' 04:45 05:15 0.50 7,910 7,910 PROD2 RIGMN' SVRG P SERVICE TOP DRIVE 05:15 05:45 0.50 7,910 8,108 PROD2 DRILL REAM P WASH F/ 7910' T/ 8089' & REAM F/ 8089' T/ 8108' (CLEAN HOLE, ECD 9.6 05:45 12:00 6.25 8,108 8,468 PROD2 DRILL DDRL P DRILL 8-1/" D-LATERAL WITH GP FROM 8,108' MD TO 8,468' - TVD 3668'. ECD 9.83, MAX GAS 350 UNITS. TOTAL OF 6 CONCRETIONS DRILLED FOR 55'. 12:00 00:00 12.00 8,468 9,541 PROD2 DRILL DDRL P DRILL 8-1P' D-LATERAL WITH GP FROM 8,468' MD TO 9,541' - TVD 3,616'. ECD 9.79, MAX GAS 364 UNITS. TOTAL OF 14 CONCRETIONS DRILLED FOR 105'. 09/08/2007 00:00 12:00 12.00 9,541 10,680 PROD2 DRILL DDRL P PJSM -Drill 8-1 /2" D-Lateral with GP from 9,541' to 10,680' MD / 3,616' TVD. ECD 10.31 -Max Gas 395 Units Total of 3 concretions for 32'. 12:00 21:15 9.25 10,680 12,021 PROD2 DRILL DDRL P PJSM -Drill 8-1 /2" D-Lateral with GP from 10,680' to 12,021' MD / 3,588' TVD. ECD 10.71 -Max Gas 513 Units. 21:15 21:30 0.25 12,021 12,021 PROD2 DRILL CIRC P Circulate -Survey for DD -Record Kill rates -Monitor well -Static. 21:30 00:00 2.50 12,021 10,830 PROD2 DRILL REAM P BROOH from 12, 021' to 10,830' MD. Pum at 640 m, 140 r m. 09/09/2007 00:00 03:45 3.75 10,830 8,098 PROD2 DRILL REAM P PJSM -Continue to BROOH from 10,830' to 8,098' MD. Pump @ 640 gpm, 2800 psi, 140 rpm, Trq 10 - 15k ft*Ibs. Time Logs --- - _Date From To Dur __ 5 Depth _E_._D~th -- Phase Code Subcode__T COM___ 09/09/2007 03:45 05:00 1.25 8,098 8,006 PROD2 DRILL TRIP P Monitor well -static -Pull out on elevators from 8,089' to 8,006' MD. 05:00 09:00 4.00 8,006 170 PROD2 DRILL TRIP P Pump dry job -POOH on elevators from 8,006' to 170' MD. 09:00 09:30 0.50 170 60 PROD2 DRILL PULD P LD 3 NMFDCS's and 1 NMFC 09:30 10:00 0.50 60 60 PROD2 DRILL OTHR P Download MWD 10:00 11:00 1.00 60 0 PROD2 DRILL PULD P Continue to LD BHA 11:00 12:00 1.00 0 PROD2 DRILL OTHR P Clean and Clear Rig Floor- Pull Wear Bushin . 12:00 12:30 0.50 PROD2 WELC BOPE P PJSM -Test BOPE -Set Test Plug - Fill stack & choke - RU equipment to test. 12:30 17:30 5.00 PROD2 WELCT BOPE P Test BOPE -Test with 4-1/2" test JT: Upper rams, all choke valves, upper & lower IBOP, Dart & Flor valves, Man & HCR Kill and choke line vlvs, and Annuluar. Test blinds with 5" test Jt - Tested Annular & Top pipe rams. All test 300 psi low and 3000 psi high. Tested Koomey Recovery. Pull test plug & set wear ring. AOGCC rep Chuck Scheve waived witnessing the test. 17:30 18:00 0.50 0 294 PROD2 DRILL PULD P PU Hole opener BHA: apt Bull nose Hole opener, Bit sub, 1 jt HWDP, NM float sub, Int blade stabilizer, 2 jts HWDP, Jars, 4 jst HWDP. Monitor well -Static. 18:00 22:30 4.50 294 12,021 PROD2 DRILL TRIP P RIH -Fill DP at 2,668' - 5,521' - 8,035' MD. Break Circ and wash down 2 stnds in tight spots from 9,643' to 9,789'. Cont to RIH -Lost SO wt @ 11,901' MD -Break Circ and wash/ream from 11,901' to 12, 021' MD. Picked u sin le . 22:30 00:00 1.50 12,021 11,928 PROD2 DRILL CIRC P Pump 25 bbls Hi-Vis sweep & circulate BU's until clean. Recip pipe from 12,021' to 11,928' MD @ 730 m, 3200 si, 140 r m. 09/10/2007 00:00 00:30 0.50 11,928 11,928 PROD2 DRILL CIRC P PJSM -CIRC BU UNTIL SHAKERS CLEAN 730 GPM. 3100 PSI. 00:30 00:45 0.25 11,928 11,928 PROD2 DRILL SFTY P PJSM WITH MUD ENG, CREW, & TRUCK DRIVERS TO REVIEW DISPLACEMENT. ASSIGN SPILL CHAMPION & REVIEW PROCEDURE 00:45 01:30 0.75 11,928 12,021 PROD2 DRILL CIRC P DISPLACED OPEN HOLE OVER TO SFOBM -STAGING PUMPS FROM 12 BPM @ 1800 PSI TO 5 BPM @ 500 PSI - PUMPED A TOTAL OF 450 BBLS. ~_~~_._...~..._..._.. __.. --._._ ~ ~..~ .._~.~_~.- F'r~ 15 ~~ 2 ~ ~ Time Logs - -- ------- -- - Date From To Dur S Denth E Depth Phase Cnde SuhcndP T COM 09/10/2007 01:30 05:30 4.00 12,021 8,047 PROD2 DRILL TRIP P POOH FROM 12,021' TO 8,047' MD. POOH ON ELEVATORS, PULL SLOW FIRST 10 STANDS & OBSERVE HOLE FOR SWABBING - TAKING PROPER FILL. FLOW CHECK WELL -STATIC. PU WT = 175K, SO WT = 43K. TOW (8047' MD) PUMP 66 BBLS OF SFOBM WITH 776 LUBE 5 BPM 400 PSI. 05:30 06:45 1.25 8,047 7,853 PROD2 DRILL CIRC P POOH FROM 8,047' TO 7,853' MD. START PUMPING SECOND DISPLACEMENT TO SURFACE WITH 60-40 3% 776 LUBE VERSAPRO SFOBM. 06:45 10:00 3.25 7,853 293 PROD2 DRILL TRIP P MONITOR WELL -STATIC. POOH FROM 7,853' TO 293' MD. 10:00 11:15 1.25 293 0 PROD2 DRILL PULD P RACK BACK HWDP & JARS - UD BHA. 11:15 12:00 0.75 0 0 PROD2 DRILL OTHR P CLEAR & CLEAN RIG FLR 12:00 12:30 0.50 0 293 COMPZ FISH PULD P PJSM & P/U BAKER WHIPSTOCK RETRIEVING ASSEMBLY - MONITOR WELL STATIC. 12:30 15:00 2.50 293 8,010 COMPZ FISH TRIP P RIH W/FISHING ASSEMBLY HOOK (FILL DP @ 3,274' - 5,627' MD. BRK CIRC @ 8,010' MD. PU WT = 145K, SO WT = 74K. 15:00 16:00 1.00 8,010 8,057 COMPZ FISH FISH P WASH ORIENT & HOOK WHIPSTOCKfcil 8.07' MD. WORK & JAR 80-105K OVER & CAME FREE. PU WT = 155K. (WELL TOOK APPROX 2 BBLS 16:00 17:00 1.00 8,057 8,006 COMPZ FISH CIRC P CBU @ 8,006' MD @ 590 GPM AND 1800 PSI. (MAX GAS 62 UNITS). MONITOR WELL -STATIC. 17:00 21:00 4.00 8,006 200 COMPZ FISH TRIP P POOH (DISP 5 BBL LONG) MONITOR WELL -STATIC. 21:00 23:00 2.00 200 0 COMPZ FISH PULD P UD JARS, BUMPER SUB & UD WHIPSTOCK ASSEMBLY. MAGNET CONTAINED LARGE AMOUNTS OF METAL SHAVINGS. 23:00 00:00 1.00 0 0 COMPZ FISH OTHR P CLEAR FLR OF WHIP STOCK TOOLS & CLEAN FLR. PU TOOLS FOR RUNNING LINER. 09/11/2007 00:00 00:15 0.25 0 0 COMPZ CASINC SFTY P Pre job safety meeting on PU tools f/ beaver slide. 00:15 01:00 0.75 0 0 COMPZ CASINC OTHR P PU tools f/ beaver slide. 01:00 01:15 0.25 0 0 COMPZ CASIN SFTY P PJSM on running the "D" lateral slotted liner. 01:15 04:00 2.75 0 3,946 COMPZ CASINC RNCS P Run "D" lateral 4.5" 11.6 ppf L-80 BTC-m slotted liner. 04:00 05:30 1.50 3,946 3,980 COMPZ CASIN RNCS P MU Baker Hook Hanger assembly. PU wt 62k, SO wt 55k, blocks 34k. 05:30 05:45 0.25 3,980 3,980 COMPZ CASINC CIRC P Shallow test Sperry Sun MWD tools, um in 110 m w/ 500 si. OK. Time Lois _ __ Subcode T COM _ Date From To Dur S. De th E. Depth Phase Code 09/11/2007 05:45 06:30 0.75 3,980 5,021 COMPZ . CASINC RUNL __ P _ ___ RIH w/ liner on 5" drill pipe. 06:30 11:00 4.50 5,021 5,021 COMPZ RIGMN RGRP T Hydraulic leak on top drive. Work on top drive accumulator reservoir tank, bladder ruptured. Spilled 20 gals of hydraulic fluid to secondary containment. Cleaned u sill. 11:00 12:15 1.25 5,021 8,047 COMPZ CASINC RUNL P Continue to RIH w/the "D" lateral liner to TOW @ 8047'. PU wt 115k, SO wt 72k, Blocks 34k. 12:15 12:30 0.25 8,047 8,230 COMPZ CASINC RUNL P Went into the open hole w/the liner to 8230' on first t 12:30 13:45 1.25 8,230 11,930 COMPZ CASIN RUNL P Continue to RIH w/ "D" lateral liner. 13:45 15:00 1.25 11,930 12,021 COMPZ CASIN( RUNL P Make a top drive connection on stand # 85 (11932'). Pumping 3bpm w/ 800 psi. PU wt 160k, SO wt 67k w/pumps on. Oriented 27 left, slack off and went past window 3', PU, reoriented to 16 Left, slacked off and hooked window w/ 90' in on stand # 85. Set 10k on hook, toolface went to 8 right. PU 45' and oriented 180 degrees. RIH, pick up a single and tag bottom of the hole 12021'. 15:00 16:00 1.00 12,021 12,015 COMPZ CASIN OTHR P PU to above the TOW w/the hook hanger. Rotate 180 degrees and work string up and down. Rehook window 3 more times. While oriented 13 left, final orientation was 8 right when hooked.Hooked in the same spot. Set 25k on hook. 16:00 17:15 1.25 12,015 12,015 COMPZ CASIN CIRC P Drop a 29/32" ball. Circulate down pumping 3bpm w/ 800 psi. Pumped a total of 140 bbls for ball to reach seat. Ball seat blew early @ 2400 psi (should have been 4000 psi). PU to 165-170k on pipe with no indication of liner release. Set down 25k a ain. 17:15 17:45 0.50 12,015 12,015 COMPZ CASINC CIRC NP Drop a 1-3/4" ball, pumped down @ 3bpm w/ 250 psi. Ball on seat @ 1745 hrs. Pressure up f/ 1000 psi to 3500 psi. Released running tool. PU to 155k 10-15k li hter PU wt . 17:45 18:15 0.50 12,015 8,042 COMPZ CASINC OTHR P Flow check. Lay down a single. POOH w/ Baker running tools. Wet tri since we dro ed the bi er ball. 18:15 22:30 4.25 8,042 30 COMPZ CASIN OTHR P POOH wet. Dispalcement 15 bbls over calculated. Monitor well, static. 22:30 00:00 1.50 30 0 COMPZ CASINC OTHR P Break and lay down Sperry Sun MWD. Make service breaks on Baker inner string tools and running tools. La down same. Clean floor. 09/12/2007 00:00 01:00 1.00 0 0 COMPZ CASINC OTHR P Clear and clean floor. 01:00 02:00 1.00 0 0 COMPZ RIGMN SVRG P Slip and cut drilling. v~ ~-. ~ m. ~~~~ 4'~ of 22~ Time Logs _ _ Date Fmm Tn flat S I~eoth F I~enth Phase Cn~ie Suhc~de T CC~M 09/12/2007 02:00 02:15 0.25 0 0 COMPZ DRILL SFTY P Pre job safety meeting on laying down drill i e. 02:15 12:00 9.75 0 0 COMPZ DRILL PULD P Lay down drill pipe from the derrick. 12:00 12:15 0.25 0 0 COMPZ DRILL SFTY P Pre job safety meeting on laying down drill i e. 12:15 13:00 0.75 0 0 COMPZ DRILL PULD P Lay down drill pipe from the derrick. 13:00 13:30 0.50 0 0 COMPZ DRILL OTHR P Pull Vetco Gray wear bushing. 13:30 15:00 1.50 0 0 COMPZ DRILL PULD P Blow down the top drive. Clear floor of 5" tools. 15:00 16:00 1.00 0 0 COMPZ RPCOti RURD P PU completion equipment to the floor. RU r h 4-12" 16:00 16:15 0.25 82 COMPZ RPCO SFTY P PJSM on picking up pump assembly. 16:15 16:45 0.50 0 0 COMPZ RPCOti RCST P PU/MU TTC crossover w/ Screen Intake assembly, MU (2) joints of 4-1/2" 12.6 ppf L-80 IBT-m tubing. PU and install first section of pump in the hole (TTC x-o/Pump Eye, gas seperator, charge pump, then the lower pump. Total length of this pump assembl 27.11'. 16:45 17:00 0.25 0 82 COMPZ RPCOh SLKL P RU Halliburton sllickline. PU second pump section (Upper pump, swage, bow spring, hanger receptacle, polishbore/fishing neck) Total length of this assembly 18.94'. Connect the two pump sections together. Total of 46.05' for both assembl 's. 17:00 17:30 0.50 82 82 COMPZ RPCOh SLKL P RIH on .125" wire, RS, OC 11' of 2-1/8" stem, OC, LSS. RIH w/ 46.05' TTCESP pump. Hit 15 times, sheared. POOH w/wireline. 17:30 18:00 0.50 82 82 COMPZ RPCOh SLKL P RIH w/ 4-1/2" 8.34' long D & D Packoff assembly (D& D stinger, 2-7/8" Dart type check valve, spacer pipe 2-7/8" EUE 8rd, Kobe Knock out, D & D Packoff assembly), set on top of ESP pump. Beat down 15 times. Set. POOH. 18:00 18:45 0.75 82 82 COMPZ RPCOh SLKL P RIH w/ 3" SS, D & D test tool. Set. POOH. Rig pressure test packoff to 1000 si f/ 5 min. Good test. 18:45 19:00 0.25 82 82 COMPZ RPCOb SLKL P RIH w! 3" SS. Pull Test tool. 19:00 20:00 1.00 82 82 COMPZ RPCOti SLKL P RIH 4-1/2" GS, D&D slip stop (1.5' overall .Set sli sto . 20:00 20:15 0.25 82 82 COMPZ RPCO SLKL P Rig down wireline sheaves and tools. 20:15 20:30 0.25 82 0 COMPZ RPCOA PULD P MU 4-1 /2" 12.6 ppf L-80 pup jt and discharge sub and 4-1 /2" 12.6 ppf L-80 u 't. then stand back in the derrick. i~<re~ 1 ~ ~t ?2 i ~ Time Logs __ _ _ _ _ _ _ _ Date From To Dur S_ Depth F f]Pnth Phase Code Suhcnde T CnM 09/12/2007 20:30 21:30 1.00 0 35 COMPZ RPCOb PULD P PU/MU motor centralizer, A-Well I pump guage, 190 hp KMHG centralift motor and tandem seals. Bolt to ether, check cou lin s. Fill with oil. 21:30 22:00 0.50 35 35 COMPZ RPCO OTHR P RU spooling unit. Hang sheave on air hoist line. 22:00 22:30 0.50 35 35 COMPZ RPCOh OTHR P Connect capillary tube to A-well ua e, connect motor lead to motor. 22:30 22:45 0.25 35 35 COMPZ RPCOh OTHR P Check cable continuity, good. 22:45 00:00 1.25 35 126 COMPZ RPCOh RCST P MU TTC crossover, pup jt, 2 jts of 4-1 /2" 12.6 ppg L-80 IBT-m tubing, pup jt, Unique discharge sub and 4-1/2" 12.6 f u ~t. Fill with oil. 09/13/2007 00:00 00:15 0.25 126 126 COMPZ RPCOI~ SFTY P Pre job saafety meeting on running 4-1/2" 12.6 ppf L-80 IBT-m ESP com letion. 00:15 01:00 0.75 126 126 COMPZ RPCO OTHR P Connect 1/4" capillary line from A Well guage to Unique discharge sub, Install protectolizers and bands and connect ESP motor lead. Test the 1.39" round cable s oolin unit. 01:00 02:45 1.75 126 838 COMPZ RPCO RCST P Run 4-/2" 12.6 ppf L-80 IBT-m tubing, jts # 3 - # 25. Installing Cannon clam s, one er 't across the collars. 02:45 03:00 0.25 838 838 COMPZ RPCOh DHEQ P Test ESP cable: megger test- 1 giga ohm, test all 3 phases each time. Test A- Well Pressure sub: Temperature and pressure readings, as well as vibration alon x and axis. 03:00 04:30 1.50 838 1,614 COMPZ RPCOb RCST P Run 4-/2" 12.6 ppf L-80 IBT-m tubing, jts # 26- # 50. Installing Cannon clamps, one per jt across the collars. Record SO wt 't # 50. 04:30 04:45 0.25 1,614 1,614 COMPZ RPCOM1 DHEQ P Test ESP cable: megger test- 1 giga ohm, test all 3 phases each time. Test A- Well Pressure sub: Temperature and pressure readings, as well as vibration alon x and axis. 04:45 06:15 1.50. 1,614 2,392 COMPZ RPCO RCST P Run 4-/2" 12.6 ppf L-80 IBT-m tubing, jts # 51- # 75. Installing Cannon clamps, one per jt across the collars. Record SO wt eve 10 ~ts. 06:15 06:45 0.50 2,392 2,392 COMPZ RPCOM1 DHEQ P Test ESP cable: megger test- 1 giga ohm, test all 3 phases each time. Test A- Well Pressure sub: Temperature and pressure readings, as well as vibration alon x and axis. 06:45 08:00 1.25 2,392 3,163 COMPZ RPCOti RCST P Run 4-/2" 12.6 ppf L-80 IBT-m tubing, jts # 76- # 100. Installing Cannon clamps, one per jt across the collars. Record SO wt eve 10 'ts. 08:00 08:15 0.25 3,163 3,163 COMPZ RPCO DHEO P Test ESP cable: megger test- 1 giga ohm, test all 3 phases each time. Test A- Well Pressure sub: Temperature and pressure readings, as well as vibration alon x and axis. • Time Logs ~ Date From To Dur S De th E. De th Phase Code Subcode T COM I 09/13/2007 08:15 09:30 1.25 3,163 3,932 COMPZ RPCO[v RCST P Run 4-/2" 12.6 ppf L-80 IBT-m tubing, jts # 101- # 125. Installing Cannon clamps, one perjt across the collars. Record SO wt's eve 10 'ts. 09:30 09:45 0.25 3,932 3,932 COMPZ RPCOti DHEQ P Test ESP cable: megger test- 1 giga ohm, test all 3 phases each time. Test A- Well Pressure sub: Temperature and pressure readings, as well as vibration alon x and axis. 09:45 11:30 1.75 3,932 4,706 COMPZ RPCOh RCST P Run 4-/2" 12.6 ppf L-80 IBT-m tubing, jts # 126- # 150. Installing Cannon clamps, one per jt across the collars. Record SO wt's eve 10 'ts. 11:30 12:00 0.50 4,706 4,706 COMPZ RPCOf~ DHEQ P Crew Change. Test ESP cable: megger test- 1 giga ohm, test all 3 phases each time. Test A- Well Pressure sub: Temperature and pressure readings, as well as vibration alon x and axis. 12:00 13:00 1.00 4,706 5,483 COMPZ RPCOh RCST P Run 4-/2" 12.6 ppf L-80 IBT-m tubing, jts # 151- # 175. Installing Cannon clamps, one perjt across the collars. Record SO wt's eve 10 'ts. 13:00 13:15 0.25 5,483 5,483 COMPZ RPCOh DHEQ P Test ESP cable: megger test- 1 giga ohm, test all 3 phases each time. Test A- Well Pressure sub: Temperature and pressure readings, as well as vibration alon x and axis. 13:15 13:45 0.50 5,483 5,667 COMPZ RPCOh RCST P Run 4-/2" 12.6 ppf L-80 IBT-m tubing, jts # 175- # 181. Installing Cannon clamps, one perjt across the collars. Record SO wt's eve 10 'ts. 13:45 14:00 0.25 5,667 5,694 COMPZ RPCO RCST P PU/MU Schlumberger/Camco KBMG 4-1/2" x 1"GLM with a 2000 psi tubing to annulus shear valve installed, a 10' 4-1/2" pup above and below. Installing Cannon clamps, one perjt across the collars of the pups. Run cable alon side minor of GLM side . 14:00 14:30 0.50 5,694 6,278 COMPZ RPCOh RCST P Run 4-/2" 12.6 ppf L-80 IBT-m tubing, jts # 182- # 200. Installing Cannon clamps, one perjt across the collars to 't # 186, then eve other one. 14:30 14:45 0.25 6,278 6,278 COMPZ RPCOh DHEQ P Test ESP cable: megger test- 1 giga ohm, test all 3 phases each time. Test A- Well Pressure sub: Temperature and pressure readings, as well as vibration alon x and axis. 14:45 15:45 1.00 6,278 7,049 COMPZ RPCOti RCST P Run 4-/2" 12.6 ppf L-80 IBT-m tubing, jts # 201- # 225. Installing Cannon clamps every other joint. Record SO wt's eve 10 'ts. 15:45 16:15 0.50 7,049 7,049 COMPZ RPCOh DHEQ P Test ESP cable: megger test- 1 giga ohm, test all 3 phases each time. Test A- Well Pressure sub: Temperature and pressure readings, as well as vibration alon x and axis. _~ _.m _ ®~m~- _~~ _ ~ ~~ • _ Time Lois - ----- -- --_ __ Date From To Dur S. De th E. De th Phase Code Sub code T COM 09/13/2007 16:15 17:00 0.75 7,049 7,821 COMPZ RPCOh _ RCST P Run 4-/2" 12.6 ppf L-80 IBT-m tubing, jts # 226- # 250. _Installing Cannon clamps every other joint. Record SO wt's eve 10 'ts. 17:00 18:00 1.00 7,821 7,852 COMPZ RPCOh RCST P M Vetco/ Grav MB 222A Hanger w/ 4-1/2" Pin x Pin joint (28.13') and landing joint w/ 4.909" MCA threads in the han er. Lower han er to the floor 18:00 21:30 3.50 7,852 7,837 COMPZ RPCO OTHR P Install penetrator in the hanger, measure cable, then PU 15' and cut the 1.39" round ESP cable. Splice cable to penetrator pigtail. PU wt 102 k, SO wt 59 k, Blocks 35k. 21:30 22:00 0.50 7,837 7,852 COMPZ RPCOh OTHR P Lower hanger to the floor, clean and connect ESP cable. Attatch (3) stainless steel 1-1/4" bands. 22:00 22:30 0.50 7,852 7,852 COMPZ RPCO DHEQ P Test ESP cable: megger test- 1 gigs ohm, test all 3 phases each time. Test A- Well Pressure sub: Temperature and pressure readings, as well as vibration alon x and axis. 22:30 22:45 0.25 7,852 7,875 COMPZ RPCOh HOSO P Drain stack, RIH and land hanger into Vetco Gray Multibowl. Hanger OD w/ bushing 13-1/2". Note: A total of 221 Cannon over the coupling clamps w/ a channel f/ 1.39: ESP cable (P/N 4500-A-24) were run, with a total of 442 taper pins (OD 6-3/4" f/ collar to belly of clamp). A total of 3 Protectolizers (1 motor and 2 pump) were run (OD 5-7l8"). A total of 2 flat guards were run. A total of 19 Stainless bands 1-1l4" were run. MU for ue on tubin 2600 ft lbs. 22:45 23:15 0.50 7,875 7,875 COMPZ WELCT OTHR P RILDS, torque to 600 ft lbs. 23:15 00:00 0.75 7,875 7,875 COMPZ WELC7 OTHR P Test lower hanger body seals to 250 psi f/ 10 min. then to 5000 psi f/ 10 minutes. OK.. 09/14/2007 00:00 01:00 1.00 7,875 7,854 COMPZ RPCOh DHEQ P Test upper hanger body seals to 250 psi and 5000 psi f/ 10 min each. OK. Clearing rig floor and lay down Sperry Sun Geos an. 01:00 01:30 0.50 7,854 0 COMPZ RPCOb PULD P Lay down landing joint (4.909" MCA x 4-1/2" ,install BPV. 01:30 01:45 0.25 0 0 COMPZ RPCOh SFTY P Pre job safety meeting on changing lower i e rams to 4". 01:45 02:45 1.00 0 0 COMPZ RPCO OTHR P Change lower pipe rams f/ 9-5/8" to 4". 02:45 03:45 1.00 0 0 COMPZ RPCOti NUND P Nipple down BOP 03:45 04:30 0.75 0 0 COMPZ RPCOh DHEQ P Test ESP cable: megger test- 1 giga ohm, test all 3 phases. Test A- Well Pressure sub: Temperature and pressure readings, as well as vibration alon x and axis. ~aq~ ~ erf 2~~ • • Time Logs _ _ D~Ie____ From To Dur 5 Deyth E. Depth Phase Code Subcode T COM ___ 09/14/2007 04:30 05:30 1.00 0 0 COMPZ RPCOh NUND P NU Vetco Gray 4-1/8" horizontal tree. 05:30 08:00 2.50 0 0 COMPZ RPCOh DHEQ P Test hanger void/ packoff to 250 psi, then 5000 psi. Was not holding 5000 psi, neck seal leaking, tightened the tree flan a and tested ok. 08:00 09:00 1.00 0 0 COMPZ RPCOh DHEQ P RU scaffolding on the tree. Pull the BPV, set the test plug. Test the tree to 250 psi low f/ 10 min. Then test to 5000 psi f/ 10 min. OK. After tree test: Performed final check on the ESP cable/penetrator A Well: Pi= 1571, Pd= 1569, Ti- 25.4c, Tmwt=25c, Vx= 0.071, Vy= 0.102. Centralift: Phase to phase = 3.1 ohms, me er = 1 i ohm. 09:00 09:15 0.25 0 0 COMPZ RPCOh SFTY P Pre job safety meeting on displacing/freeze protecting the well with Little Red Hot Oil. 09:15 21:00 11.75 0 0 COMPZ RPCOh FRZP P Little Red pumped and displaced the 8.4 ppg SFOBM from the well with diesel by pumping into the 9-5/8" x 4-1/2"annulus, taking returns from the tubing.. Pumped 565 bbls, with 500 bbls returned to the pits. Pumped mostly 1 to .75 bpm. Initial 1 bpm w/ 400 psi, final rate 1 bpm w/ 750 psi. Shut in annulus pressure= 250 psi,Tubing =120 psi. Returned 493 bbls of solids free oil base mud, and took 7 bbls of diesel to the rockwasher pit. Note: The camp moved this afternoon to 2Z pad while displacing and freeze protecting. Left approx 1500 hrs, on 2Z ad 1820 hrs. 21:00 22:00 1.00 0 0 COMPZ RPCOh FRZP P Blow down freeze protecting lines. Rig down same. Loaded i e sheds. 22:00 22:45 0.75 0 0 COMPZ RPCOti RURD P PU lubricator to set BPV. Install flanges on the wellhead. Remove double valves. Install the BPV. Note: Final tubing pressure 250 psi. Final IA (9-5/8" x 4-1/2") 290 psi, OA 13-3/8" x 9-5/8" 275 si. 22:45 23:15 0.50 0 0 COMPZ RPCO RURD P Secure well. 23:15 00:00 0.75 0 0 COMPZ RPCOh RURD P Wipe down tree, cleaning cellar w/ super sucker. Rig released for 11 mile move to 2Z-01A. ' .7.x~q~ f.d ~, ~.. ~~~' KRU 1 J-107 Conc~~pPhiliips Alaska, 1nC. 1 J-107'_ - _ __ _ - _ API: 500292336600 Well T e: PRpD An le ~ TS: de a) TUBING SSSV Type: NONE Orig 9/15/2007 Angle @ TD: 92 deg @ 12073 (o-7e7s, oD:a.SOO, Com letion: ID:3.958) ' Annular Fluid: Last W/O: Rev Reason: NEW WELL PUMP (77547854, OD:3.800) XOINTAKE (7829-7840, OD:5.130) SEAL (7840-7854, OD:5.130) MOTOR (78547870, OD:5.620) GAUGE (7870.7872, OD:4.500) TERMEDIATE (o-x721, OD:9.625, wt:ao.ao) PACKER (8169-8170, OD:8.430) Reference Lo : 28' RKB Ref Lo Date: Last U date: 11/1/2007 Last Ta TD: 12073 ftKB Last Tag Date• Max Hole Angle: 96 deg r7 9104 _ __ Casing String -ALL STRI NGS Descri lion Size To Bottom ND Wt Grade Thread CONDUCTOR 20.000 0 80 80 94.00 K-55 WELDED SURFACE 13.375 0 3468 2275 68.00 L-80 BTC INTERMEDIATE 9.625 0 8721 3717 40.00 L-80 BTCM WINDOW 9.000 8047 8048 3655 0.00 B-SAND SLOTTED LINER 5.500 8169 11792 3661 15.50 L-80 BTCM Tubing String _ TUBING Size To _ _ Bottom ND Vi/t Grade Thread 4.500 0 -_...._ 7875 3634 12.60 L-80 IBTM _ Perforations Summary Interval TVD Zone Status Ft SPF Date T Comment 9778 - 11712 3663 - 3660 WS B 1934 32 9/3/2007 SLOTS 100% slotted finer, 2.5"x .125", 4 circumferential rows/ft, 3" centers sfannarerl 1 R clan Gas Lift MandrelsNalves f "" _ _ _ _. -- St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 T 2190 1791 CAMCO RBMG SOV 1 0 EK-5 0.000 0 9113%2007 ~ _. -- Other plugs, equip., etc.) -COMPLETION _ De h TVD T e Descri lion ID 23 23 HANGER VETCO GRAY TUBING HANGER 3.860 7752 3620 PRES SUB UNIQUE PRESSURE DISCHARGE SUB 0.000 7754 3621 PUMP TTC ESP PUMP ASSEMBLY w/PACKOFF & SLIPSTOP (OAL ??) set 0.000 0.000 7840 3630 SEAL UPPER & LOWER TANDEM SEAL SECTION GSB3DB FER HL SSCV SB/SB 0.000 7854 3632 MOTOR CENTRILIFT 190 HP KMHG 0.000 7870 3634 GAUGE A-WELL 1 PUMP GAUGE 0.000 7872 3634 Centralizer MOTOR CENTRALIZER 0.000 8042 -. Other ~ De ih 3654 pl~, ND HANGER equip., etc T e D-SAND BAKER 'B' FLANGED HOOK HANGER __ .) - B-SAND LINER DETAIL Descri lion 7.510 ID 8169 3669 PACKER B-SAND BAKER'ML' ZXP LINER TOP PACKER 6.320 8190 3672 HANGER B-SAND FLEXLOCK LINER HANGER 6.100 8195 3672 XO Bush~tg B-SAND CROSSOVER BUSHING 4.910 8197 3673 SBE B-SAND 190-47 SEAL BORE EXTENSION 4.750 9650 3659 PACKER B-SAND SWELL PACKER 4.950 11721 'Safety I Date 3660 Notes Note PACKER B-SAND SWELL PACKER _ 4.950 _ i X9/15/2007 NOTE: MULTI-LATERAL WELL - 1J-107 (B-SAND). 1J-107L1 (D-SAND) • 12-Oct-07 AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-107 Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 28.00' MD Window /Kickoff Survey 0.00' MD (if applicable) Projected Survey: 12,073.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ~' Si ned ~ ~ ~~~J' C ~ , ~ Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~~ 7 ~ ~ ~~ WELL LOG TRANSMITTAL To: State of Alaska September 17, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 1J-107 AK-MW-5154790 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23 3 66-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. ~ 9~ =. ~, ~;, ~~~= ~~~ D~ ~. s _ :i'.5~ ~~' '~~~' Signed: ,y ~30~'" ~° ~ • l~ SARAH PALIN, GOVERNOR L>~I[s-7~ Ouj 01st ~ 333 W. 7th AVENUE, SUITE 100 C011T5ERQ~7`I011T COMl~II55IO1Q ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, 1J-107 ConocoPhillips Alaska, Inc. Permit No: 207-107 Surface Location: 3132' FNL, 2422' FEL, SEC. 35, T 11 N, R l OE, UM Bottomhole Location: 2135' FNL, 1982' FEL, SEC. 1, T10N, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness required test, contact the Commission's petroleum field inspector at (90~~9-3607 (pager). ,~ ... DATED this day of August, 2007 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Conoco~hillips ~ Alaska Post OfFce Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907)265-6830 Email: Randy.L.Thomas@conocophillips.com July 31, 2007 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permit to Drill, West Sak Producer, 1J-107, iJ-107 L1 Dear Commissioners: 1 2007 ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore producer well, a horizontal well in the West Sak ~~B" and ~~D" sands. The main bore of the well will be designated 1J-107, and the lateral bore of the well will be designated 1J-107L1. ` Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date of 1J-107 is August 15, 2007. J If you have any questions or require any further information, please contact Pat Reilly at 265-6048. Sincere) Ran homa Greater Kupar Area Drilling Team Leader ~~~ ~S STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1~~~l~ ~ ~ 2~~7 ? . ~ ~~ t'~ ~ < `; (s01i~, 'W lrR1IfC1i~"IO?1 et.'.,.. 1 a. Type of Work: Drill Q Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory Development Oil ^/ Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone^ Single Zone ^ 1 c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 - 11. Well Name and Number: 1J-107 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 12100' ~ ND: 3689' ° 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 3132' FNL, 2422' FEL, Sec. 35, T11N, R10E, UM ~ 7. Property Designation: ADL 25661,E25662 < West Sak Oil Pool Top of Productive Horizon: 3866' FNL, 1995' FEL, Sec. 36, T11 N, R10E, UM 8. Land Use Permit: ALK 471, 2177 13. Approximate Spud Date: 8/15/2007 Total Depth: 2135' FNL, 1982' FEL, Sec. 1, T10N, R10E, UM , 9. Acres in Property: 2560 14. Distance to Nearest Property: < 1 mile 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558785 - y- 5945960 ' Zone- 4 10. KB Elevation (Height above GL): 109' AMSL ~ feet 15. Distance to Nearest Well within Pool: 1J-105 , 1189' @ 11401 16. Deviated wells: Kickoff depth: 400 ft. Maximum Hole Angle: g3° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1600 psig - Surface: 1191 psig - 18. Casing Program if ti S Setting Depth Quantity of Cement Size ons pec ica Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 40" 20" 62.5# H-40 Welded 80' 40' 40' 108' ~ 108' 260 cf ArcticCrete 16" 13-3/8" 68# L-80 BTC 3503' 40' 40' 3543' ~ 2275 ~ 690 sx AS Lite, 220 sx DeepCRETE 12.25" 9-5/8" 40# L-80 BTCM 8510' 40' 40' 8550' - 3715' , 630 sx DeepCRETE 8.5" 5.5" 15.5# L-80 BTCM 3945' 8155' 3671' 12100' : 3689' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ff): Total Depth ND (ff): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): 20. Attachments: Filing Fee ^ BOP Sketch Drilling Program ~ Time v. Depth Plot Shallow Hazard Analysis 0 Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements ^~ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Pat Reilly @ 265-6048 Printed Name Randy Thomas~~~/// Title Drilling Team Leader /jj Signature / ~ r / ~~~ Phone ~~~L Date G/~ ~ ha n All k a j'~ /~ Commission Use Only Permit to Drill ~7 ~f Number: ~,~ (~" ~ I API Number: 50-0~~ ~33~~j'" Permit A proval Date: ~ ~ See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce Coalbed m have, gas hydrates, or gas contained in shales: 11 Samples req'd: Yes ^ No ~ Mud log req'd: Yes ^ No [~ Other: ~30~ ~S~ ~~~5~ ~S ~VU~H2S measures: Yes [] No it n I svy req'd: Yes [~ No ^ APPROVED BY THE COMMISSION DATE: ~ ~0 ,COMMISSIONER Form 10-401 Revised 12/2005 ~~ ~~~;, ~ ~~ ~ ~ ~ ` l~ ~ ~ g ~• +Q7 Submit in Duplicate • Permit It -West Sak Well #1J-107 Application for Permit to Drill Document tion for Permit to Drill, Well 1J-107 Revision No.O Saved: 1-Aug-07 Table of Contents 1. Well Name .................................................................................................................. 2 Re uirements o 20 AAC 25.005 .............................. 2 R' .f ~ ............................................................................... 2. Location Summary ..................................................................................................... 2 Requirements of 20 AAC 25.OOS(c)(2) ......................................................................................................... 2 Requirements of 20 AAC 2S.OS0(b) ............................................................................................................. 3 3. Blowout Prevention Equipment Information ............................................................... 3 Requirements of 20 AAC 25.005(c)(3) ......................................................................................................... 3 4. Drilling Hazards Information ..................................................................................... 3 Requirements of 20 AAC 25.005 (c) (4) ............................................................................. . .......................... 3 5. Procedure for Conducting Formation Integrity Tests .................................................. 3 Requirements of 20 AAC 25.005 (c)(S) ........................................................................................................ 3 6. Casing and Cementing Program ................................................................................. 4 Requirements of 20 AAC 25.005(c)(6) ......................................................................................................... 4 7. Diverter System Information ...................................................................................... 4 Requirements of 20 AAC 25.OOS(c)(7) ......................................................................................................... 4 8. Drilling Fluid Program ............................................................................................... 4 Requirements of 20 AAC 25.OOS(c)(8) ......................................................................................................... 4 Surface Hole Mud Program (extended bentonite) ......................................................................................... 4 Intermediate Hole Mud Program (LSND) .................................................................................................... 5 Lateral Mud Program (MI VersaPro Mineral Oil Base) B, D sand laterals .................................................... 5 9. Abnormally Pressured Formation Information ........................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ........................................................................................................ 5 10. Seismic Analysis ......................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ...................................................................................................... 5 11. Seabed Condition Analysis .......................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ...................................................................................................... 5 1J-107 PERMIT IT Page 1 of 7 Printed: 1-Aug-07 • A~tion for Permit to Drill, Well 1 J-107 Revision No.O Saved: 1-Aug-07 12. Evidence of Bonding ................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ...................................................................................................... 5 13. Proposed Drilling Program ......................................................................................... 6 Requirements of 20 AAC 25.005 (c)(13) ...................................................................................................... 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal .................................. 7 Requirements of 20 AAC 25.005 (c)(14) ...................................................................................................... 7 15. Attachments ............................................................................................................... 7 Attachment 2 Directional Plan .................................................................................................................. 7 Attachment 3 Drilling Hazards Summary ................................................................................................... 7 Attachment 4 CemCADE Summary ............................................................................................................. 7 Attachment 5 Well Schematic .................................................................................................................... 7 1. Well Name Requirements of 20 AAC 25.005 (fl Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a ia~ell with multiple ti~~ell branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the ia~ell by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1J-107. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Dri71 mz~rst be accompanied by ead7 of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's o~a~ners and showing (A)the coordinates of ~"he proposed Location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the i~~ell at tlae surface, referenced to die state plane coordinate system for this state as maintained by the National Geodetic Survey in the 1~'ational Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 3,132' FNL, 2,422' FEL, Section 35, T11N, R10E ASP Zone 4 NAD 27 Coordinates RKB Elevation 109' AMSL Northings: 5,945,960 Eastings: 558,785 Pad Elevation 81' AMSL Location at Top of Productive Interval (West 3,866' FNL, 1,995' FEL, Section 36, T11N, R10E Sak `B" Sand ASP Z NAD 2 d Measured Depth, RKB: 8,550 one 4 7 Coor inates Northin 272 Eastin s: 5 945 s: 564 498 Total Vertical Depth, RKB: 3,715 g , , g , Total Vertical Depth, SS: 3,606 Location at Total Depth 2,135' FNL, 1,982' FEL, Section 1, T10N, R10E ASP z 4 NAD 27 C d Measured Depth, RKB: 12,100 one oor inates Northin 724 Eastin s: 5 941 s: 565 543 Total Vertical Depth, RKB: 3,689 g , , g , Total Vertical Depth, SS: 3,580 and (D) other information required by 20 AAC 25.050(b); 1J-107 PERMIT IT t Page 2 of 7 Printed: 1-Aug-07 ~RlGI • ~ation for Permit to Drill, Well 1J-107 Revision No.O Saved: 1-Aug-07 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-A01) must (I) include a plat. drawn to a suitable scale, shoe+~ing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of arry portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by terrified mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already ova file with the commission and idenrified in the application: (3j a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J-107. For all operations the stack will be equipped with 3-1/2" to 6" variable bore rams in the uppermost ram cavity, blind rams in the middle cavity, and 9-5/8" rams in the lowermost cavity. Upon initial nipple up, and at intervals of no more than 14 days thereafter, a test plug will be set below the lowermost rams, the annular preventer will be tested to 1,500 psi and the blind rams and upper rams will be tested to 3,000 psi. (This test will test the shell and end connections of the lowermost ram). The lowermost rams will be closed and tested to 3,000 psi on a 9-5/8" OD. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, exceptfor ma item already on file with the commission and identified in the application: (4J information on drilling ha zards, including (A) the maximum doi~,nhole pressure that maybe encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; f The expected reservoir pressure in the West Sak sands in the 1J-107 area is 0.43 psi/ft, or 8.3 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) is 1,165 psi. Based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak B sand formation is 3,721'. The MPSP is: MPSP = (3,721 ft)(0.43 - 0.11 psi/ft) =1,191 psi (B) data on potential gas=ones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured sb~ata, lost circulation =ones, and pones that hcrne a propensfty for d~erential sticking; Please see Attachment 2: 1J-107 Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application far a Permit to Drill must be accompanied Gy each of the follait~ing items, except for an item already on file with the commission .and identified in.the application: (S) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.0300; 1J-107 PERMIT IT Page 3 of 7 Printed: 1-Aug-07 ORIGINAL • A~tion for Permit to Crill, Well 1J-107 Revision No.O Saved: 1-Aug-07 1J-107 will be completed with 9-5/8" casing landed at the top of the West Sak "B" sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c) (6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item ah•eady on file with the commission and identified in the application: (6) a complete proposed casing mid cementing program as required by 20 AAC 25.030, mid a descriptia~ of any slotted liner, pre perforated liner, or screen to be installed; See also Attachment 3: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD (In) (in) (lb/ft) Grade Connection (ft) (ft) t) Cement Pro am 20" 40" 62 5 H-40 Welded 80 40' / 40' 80' / 80' Cemented to surface with 260 cf . ArcticCRETE Cemented to Surface with 13-3/8" 16" 68 L-80 BTC 3,503 40' / 40' 3,543' 12,275' 690 sz ArcticSet Lite Lead, 220 sx DeepCRETE Tail Cement Top planned @ 5,024' 9-5/8" 12-1/4" 40 L-80 BTCM 8,510 40' / 40' 8,550' / 3,715' MD / 2,821' TVD. Cemented w/ 630 sx DeepCRETE 5-1/2 8-1/2" B Sand Lateral 15.5 L-80 BTCM 3 945 8 155' / 3 671' 12 100' / 3 689' Slotted-no cement slotted (tJ-lo7) , , , , , 4-1/2 8-1/2" D Sand Lateral 11.6 L-80 BTCM 3 996 055' / 3 658' 8 051' / 3 620' 12 Slotted- no cement slotted (1J-107 L1) , , , , , 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following'items, except for an item ah~eady on file is=ith the commission ' and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.03.5, unless this requirement is »~aived by the commission wader 20 A.~c 2s. o3s~a~~z~; A 21-1/4", 2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of 1J- 107. Please see diagrams of the Doyon 15 diverter system on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, exceptfor an item already on file with the commission and identified in the application: (8) a drilling flzud program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Base of Permafrost to Surface Casing Point Initial Value Final Value Initial Value Final Value Density (ppg) 8.5 9.2 9.2 9.6 Funnel Viscosity 150 250 200 300 (seconds Yield Point 50-70 50-70 30-50 30-50 (cP) Plastic Viscostty 20-45 20-45 15-20 15-20 (lb/100 s pM 8.5-9.0 8.5-9.0 8.5-9.0 8.5-9.0 1J-107 PERMIT IT Page 4 of 7 Printed: 1-Aug-07 pR1GfNt~L • tion for Permit to Drill, Well 1J-107 Revision No.O Saved: 1-Aug-07 API Filtrate NC-8.0 NC-8.0 5.0-7.0 5.0-7.0 (cc / 30 min)) *9.6 ppg if hydrates aze encountered ` Intermediate Hole Mud Program (LSND) 13-3/8"Casing Shoe to Intermediate Casing Point Initial Value Density ( g) 9.0-9.4 Funnel Viscosity 45-60 (seconds Plastic Viscostiy 12-18 (Ib/100 s Yield Point 26-35 (cP) API Filtrate 4-6 (cc / 30 min)) Chlorides (mg/Z) <500 pH 9.0-9.5 MBT <20.0 Lateral Mud Program (MI VersaPro Mineral Oil Base) B, D sand laterals Value Densi ( ~ 8.4 - 8.6 Plastic Viscostiy 15-25 (lb/100 s Yield Point 18-28 (cP) HTHP Fluid loss (ml/30 min @ <4.0 200 si & 1 SO° Oil /Water Ratio 80:20 Electrical >600 Stability Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 15. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the follrn+~ing items, except for an item already o» file with tlve commission and identified in fhe application: (9) for my exploratory or stratigraphic test hell, a tabulation setting out the depths ofpredicfed abnornuxlly geo pressured strata as required by 20 AAC 25.0330; Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of20-AAC 25.005 (c)(10) Ara application for a Permit to Drill must be accompanied by each of the follo~+~ing items, except for an item already on file with the commission and identified in the application: (10) for m~ exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is trot for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items. except for an item already on file with the commission and ident0ed irz the application: (11) for a x~ell drilled from an offshore platform, mobile bottom founded sUzrcture, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as reguned by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, exceptfor an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 iiBonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 1J-107 PERMIT /T Page 5 of 7 Printed: 9-Aug-07 oR~~rn~a~ A~tion for Permit to Drill, Well 1J-107 Revision No.O Saved: 1-Aug-07 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of dae following items, except for an item already on file tivith the commission. and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematics. f 1. Excavate cellar, install cellar box, set and cement 20" x 34" insulated conductor to +/- 108' RKB. Install landing ring on conductor. 2. Move in /rig up Doyon Rig 15. Insta1121-1/4" Annular with 16" diverter line and function test. 3. Spud and directionally drill 16" hole to casing point at +/- 3,543' MD / 2,275' TVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 13-3/8", 68#, L80, BTC casing to surface. Displace cement with mud and, pressure test casing to 2500 si for 30 minutes and record results. Perform to 'ob if re uired. p pJ q 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's as described above in Section 3 above and test to 3,000 psi (annular preventer to 1500 psi). Notify AOGCC 24 hrs before test. 6. PU 12-1/4" drilling assembly, with MWD, LWD & PWD. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. 7. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. , 8. Directionally drill to 9-5/8" casing point at 8,550' MD / 3,715 TVD, the prognosed top of the B sand. 9. Run 9-5/8", 40# L80, BTC Mod casing to surface. Pump cement and displace with mud (top of cement to be 5,024' MD / 2,284' TVD (500' above Ugnu formation). 10. Install wellhead x 9-5/8" packoff and test to 5000 psi. 11. Flush 13-3/8" x 9-5/8" annulus with water, followed by diesel. 12. PU 8-1/2" drilling'assembly, with MWD, and LWD logging tools. RIH to top of cement. Pressure test casing to 3,000 psi for 30 minutes and record results. Clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar 13. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling mud. Perform formation ~ ~ 14 integrity test to leak off, recording results. Directionally dri118-1/2" hole to TD at +/- 12 100' MD / 3 689' TVD as per directional plan . , . , 15. POOH, back reaming out of lateral. POOH. 16. PU and run 5-1/2" slotted liner. 17. Land liner, set liner hanger @ +/- 8,155' MD / 3,671' TVD. POOH. Note: Remaining operations are covered under the IJ--107 LI Application for Permit to Drill, and are provided here for information only. 18. Run and set Baker WindowMaster whipstock system, at window point of 8,055' MD / 3,658' TVD, the top of the "D" sand. 19. Mi118-1/2" window. POOH. 20. Pick up $-1/2" drilling assembly with LWD and MWD and PWD. RIH. 21. Drill to TD of "D" sand lateral at 12,051' MD / 3,620' TVD, as per directional plan. 22. POOH, back reaming out of lateral. POOH. 23. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 24. PU and run 4-1/2" slotted liner. 1J-107 PERMIT IT Page 6 of 7 Printed: 1-Aug-07 JRIGhNAL • tion for Permit to Drill, Well 1J-107 Revision No.0 Saved: 1-Aug-07 25. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 26. Release hanger running tool, POOH, laying down drill pipe as required. 27. PU ESP completion as required and RIH to depth. Land tubing. Set BPV. 28. Nipple down BOPE, nipple up tree and test. Pull BPV. 29. Freeze protect well with diesel by pumping into 4-1/2" x 9-5/8" annulus, taking returns from tubing and allowing to equalize. 30. Set BPV and move rig off. 31. Rig up wire line unit. Pull BPV. 32. Set gas lift valves in mandrels. Use ESP to clean up well. 33. Place well on production. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items, exceptfor an item already or1 file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statemenl of whether the operator intends to request authorisation under 20 AAC 25.080 for an annular disposal operation in the »~ell.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1J Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on lE Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 CemCADE Summary Attachment 4 Well Schematic 1J-107 PERMIT IT Page 7 of 7 Printed: 1-Aug-07 ORIGINAL • • ConocoPhillips Alaska Plan: 1 J-107 (wp05) Sperry Drilling Services Proposal Report -Geographic 16 July, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-107 Plan 1J-107 Local Coordinate Origin: Viewing Datum: TVDs to System: North Reference: Unit System: Centered on Well Plan 1J-107 Plan RKB @ 109.OOft (Doyon 141 (28+81)) N True API - US Survey Feet L' I~"1' Sperry Drilling Services OR161NAL 0 c~ z n r Sp®rry Orlllln~ Sarvlce6 -300 0 300 600 900 1200 lsoo 0 n L 1800 n a~ v 2100 r ~ 2400 H 2700- 3000 3300 3600 3900 4200 Site: Kuparuk 1 J Pad Well: Plan 1J-107 Wellbore: Plan 1J-107 Plan: 1J-107 (wp05) SHL @ 28' MD, 28' TVD: FNL 3132' FEL 2422'-Sec ~ t ~ j 0° ~~ WELL DETAIIS: Plan 17-107 Cn~ound Level: 81.00 +N/-S +FJ-W Northing Easting La[ittude Longitude Slot 0.00 0.00 5945960.16 558785.90 70°I5'46.657N 149°31'29.1 ISW FORMATION TOP DETAILS No.TVDPath TVDSS MDPath Formation 1 1511.08 1402.08 1672.03 Pfrost 2 1660.23 1551.23 1926.04 T3 3 1971.90 1862.9 2722.65 K75 4 2275.34 2166.34 3543.47 T3+550 5 3003.95 2894.95 5524.62 Ugnu C 6 3245.79 3136.79 6233.22 Ugnu B 7 3325.81 3216.81 6481.72 Ugnu A 8 3434.04 3325.04 6851.05 K 13 9 3658.30 3549.3 8055.55 W Sak D 10 3698.42 3589.42 8359.72 W Sak C 11 3715.11 3606.11 8550.06 W Sak B ~00 10= CASING DETAILS 15° No MD TVD TVDss Name Size 3 8 3 8 20° 9 5/8 8 2 8550.1 I 3715.1 l 3606.1 19 5 }Q00 3 12100.24 3689.50 3580.5 51/2" 5-1/2 3p° 35° 40° d§0p ----------------------------- --- soa----- -- --------------- ----- \Pfrost -------- ----- - -SS°------ ----- ------------------------------------------------------ . ~~~0 T3 - - - - - - - - - - - - ` - - - - - - - - - 'rip - - - - - - - - ----------------- ------------------------------------- - - - - - - K 15 13 3/8" Sapp ----------- ------ ------------- O -6gs0 ---------------- T3+550 Begin Pump Tangen1 9p 82° @ 7670' MD, 3605' TVD ~O ASpO ~ End Pump Tangent @ 7870' MD, 3632' ND Ugnu C " S~~o i~ ,' ' ,' 9 5!8" Casing @ 8550' MD, 3715' TVD: FNL 3866' FEL 1995'-Sec 36-T11N_R10E ' +~Bp„ .~ - - ~ - - - - - - - - - - - - - 1 - - - - - - _ -_ - - - - - - - - - - -~- - - _. 1 Ugnu B 600" ,~ BHL @ 12100' MD, 3689' ND: FNL 2135' FEL 1982'-Sec 1-T10N_R10E o ~ / ------ -- ~ - ° - ---Ugnu A o ~ ~, ------------- -----------------g----- o o----------- - - ----------- -- ----- o - --- -~ - ~-~ N ----------- ~ o ~ mc°v N 1J-107 L1(wp05) ~ -K 13 ~ ,o m ° u~ eo .~ r-_-- ~ o = - o - o ~_____-~ ====o-====rn i 1J-107(wp05~ ~~\~ WSakD ~ ~ ` o ° 0 0 0 , 9 Sl8" 5 1/2" ` W Sak C W Sak B -1800 -1500 -1200 -900 -600 -300 0 300 600 900 1200 1500 1800 2100 2400 2700 3000 3300 3600 3900 4200 4500 4800 5100 Vertical Section at 180.00° (750 ft/in) ~ ColnocoPhillips Alaska HA!_ L{~URTCEN Project: Kuparuk River Unit wELLDETA1LS Planu-]o7 $perey Grilling $erwiel0$ Site: Kuparuk 1J Pad Ground Level: 81.00 Well: Plan 1 J-107 +N/-S +F1-W Northing Easung Latittude Longitude Slot Wellbore: Plan 1J-107 0.00 0.00 5945960.16 558785.90 70°I5'46.657N 149°31'29.115W Plan: 1J-107 (wp05) REFERENCE INFORMATION 3000 Co-ordinate (N/E) Reference: Well Plan iJ-107, True North Vertical (ND) Reference: Plan RKB ~ 109.OOft (Doyon 741 (28+81)) Measuretl Depth Reference: Plan RKB ~ 109.OOft (Doyon 141 (28+81)) 2750 Calculation Method: Minimum Curvature 2500 CASING DETAILS 2250 No MD TVD TVDss Name Size ~ 1 3543.47 227534 2166.34 13 3/8" 13-3/8 ~/ \ 2 8550.1 l 3715. 11 3606.11 9 5/8" 9-5/8 2000 ~,y=~ / r / `-'~ 3 12100.24 3689.50 3580.5 5 1/2" 5-1/2 1750 . ~ (J I ~,, ~`~' 1~~J "V 1500 1250 a . o h° „yN 1000 13 3/8" ° °o 0 ~~ i ~ i o ~o ~ 750 ~ o S~ J 500 N ~ `gu 250 ° ~ G0, 0 0 ~ ' ' 161° -250 _ ~ - / SHL @ 28' MD, 28' TV D: FNL 3132' FEL 2422'-Sec 35-TI IN-RI OE , - ' 165° / -500 - ' -750 - ' ~ ~ 9 5/8" _ Begin Pump Tangent 82° @ 7670' MD, 3605' TVD ,1.- ° o -1000 0 180 0 -1250 End Pump Tangent @ 7870' MD, 3632' TVD 130° C -1500 0 -1750 o -2000 130° -2250 -2500 -2750 180° -3000 -3250 -3500 130° -3750 BHL @ 12100' MD, 3689' TVD: FNL 2135' FEL 1982'-Sec 1-TI ON-RIOE -4000 ' - - ` _ _ 130° ' - - -4250 _ ~ - - - _ 5 1/2"" - 690 -4500 i 11-107 (wp05) -4750 -5000 T M Azimuths to True North Magnetic North: 24.54° -5250- Magnetic Field Strength: 57578.1 nT -5500- Dip Angle: 80.72° - Date: 11/18/2004 -5750 Model: BGGM2004 -250 0 250 500 750 1000 1250 1500 1750 2000 2250 2500 2750 3000 3250 3500 3750 4000 4250 4500 4750 5000 5250 5500 5750 G000 6250 6500 G750 7000 West(-)/East(+) (1000 fT/in) ~-' ConocoPhillips ~~ ORIGINAL • ConocoPhillips Alaska Halliburton Company Compass Proposal Report -Geographic C~ HALILIBUTON Sperry Drilling Services Database: .Sperry EDM .11 Local Co-ordinate Reference: Well Plan 1J-107 Company: ' ConocoPhillips Alaska, Inc. TVD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-107 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-107 Design: 1 J-107 (wp05) Project Kuparuk River Unit. North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Plan 1J-107 Well Position +N/-S 0.00 ft Northing: 5,945,960.16 ft Latitude: 70° 15' 46.657" N +E/-W 0.00 ft Easting: 558,785.90 ft Longitude: 149° 31' 29.115" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.OOft Wellbore Plan 1J-107 Magnetics Date Model Name Sample Declination Dip Angle Field Strength bggm2004 11/18/2004 24.54 80.72 57,578 Design 1J-107 (wp05) Audit Notes: Version: Phase: PLAN Tie On Depth: 28.00 I Vertical Section: Depth Frorn (TV D) +N/-S +EI-W Direction I (ft) (ft) (ft)' (~) 28.00 0.00 0.00 180.00 7/16/2007 5:25:07PM Page 2 of 9 COMPASS 2003.11 Build 48 OR161NAL Halliburton Company HALLI URTQN COIIOCO~1~~Ip5 Compass Proposal Report -Geographic Alaska Sperry Drilling 8®rvices Database: .Sperry EDM .11 Local Co-ordinate Reference: ~^dell Plan 1J-107 Company: ConocoPhillips Alaska, Inc. ND Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-107 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-107 Design: 1J-107 (wp05) Plan Summary Measured Dogleg Build Turn Depth Inclination Azimuth TVD NDSS +N/-S +E/-W Rate Rate Rate TFO (ft) (~) (~) (ft) (ft) (ft) (ft) (°I100ft) (°I100ft) (°/100ft) (°) 28.00 0.00 0.00 28.u0 -81.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 191.00 0.00 0.00 0.00 0.00 0.00 0.00 702.98 12.09 70.00 700.00 591.00 14.49 39.80 3.00 3.00 0.00 70.00 1,654.75 50.14 73.21 1,500.00 _ 1,391.00 159.45 500.23 4.00 4.00 0.34 4.00 1,704.75 50.14 73,21 1,532.05 1,423.05 170.53 536.98 0.00 0.00 0.00 0.00 2,158.95 68.30 73.02 1,763.51 1,654.51 283.45 908.81 4.00 4.00 -0.04 -0.57 5,219.67 68.30 73.02 2,895.00 2,786.00 1,113.88 3,628.75 0.00 0.00 0.00 0.00 5,558.86 70.00 85.54 3,015.71 2,906.71 1,172.66 3,939.58 3.48 0.50 3.69 81.75 7,654.85 82.00 160.67 3,602.51 3,493.51 122.43 5,481.51 3.50 0.57 3.58 92.63 8,055.55 82.00 160.67 3,658.30 3,549.30 -252.01 5,612.84 0.00 0.00 0.00 0.00 8,255.55 82.00 167.75 3,686.15 3,577.15 -442.47 5,666.70 3.51 0.00 3.54 90.00 8,381.79 85.00 171.01 3,700.44 3,591.44 -565.72 5,689.79 3.50 2.38 2.58 47.37 8,520.11 85.00 175.87 3,712.50 3,603.50 -702.57 5,705.52 3.50 0.00 3.51 90.00 8,550.11 85.00 176.92 3,715.11 3,606.11 -732.40 5,707.40 3.50 0.00 3.51 90.00 8,780.01 93.37 180.74 3,718.39 3,609.39 -961.98 5,712.08 4.00 3.64 1.66 24.59 8,950.68 93.37 180.74 3,708.36 3,599.36 -1,132.34 5,709.88 0.00 0.00 0.00 0.00 8,992.52 92.06 179.69 3,706.38 3,597.38 -1,174.13 5,709.72 4.00 -3.12 -2.50 -141.33 9,292.52 92.06 179.69 3,695.60 3,586.60 -1,473.93 5,711.32 0.00 0.00 0.00 0.00 9,386.11 91.12 179.69 3,693.00 3,584.00 -1,567.48 5,711.82 1.00 -1.00 0.00 180.00 10,053.82 91.12 179.69 3,679.90 3,570.90 -2,235.06 5,715.37 0.00 0.00 0.00 0.00 10,162.62 90.04 179.76 3,678.80 3,569.80 -2,343.85 5,715.89 1.00 -1.00 0.06 176.40 11,053.00 90.04 179.76 3,678.20 3,569.20 -3,234.22 5,719.58 0.00 0.00 0.00 0.00 11,099.74 89.57 179.78 3,678.36 3,569.36 -3,280.96 5,719.76 1.00 -1.00 0.04 177.95 11,653.11 89.57 179.78 3,682.50 3,573.50 -3,834.31 5,721.89 0.00 0.00 0.00 0.00 11,703.91 89.07 179.67 3,683.10 3,574.10 -3,885.10 5,722.13 1.00 -0.98 -0.21 -167.80 12,100.25 89.07 179.67 3,689.50 3,580.50 -4,281.39 5,724.40 0.00 0.00 0.00 0.00 7/16/2007 5:25:07PM Page 3 of 9 COMPASS 2003.11 Build 48 4RIG~~AL • ~ ~-' Halliburton Company HALLIBURTN ~UI'l000~1~ ~ s Compass Proposal Report -Geographic gp®rry Drilling S®rvices A -c a Database: .Sperry EDM .11 Local Co-ordinate Reference: Well Plan 1J-107 Company: ConocoPhillips Alaska, Inc. ND Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Plan RKB (a~ 109.00ft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-107 Survey Calculation Method: Minimum Curvature , Wellbore: Plan 1J-107 Design: 1J-107 (wp05) Planned Survey 1J-107 (vvp05) Map Map MD Incl Azimuth ND (ft) TVDSS +N/-S +E/_yy Northing Easting DLSEV Vert Section (ft) (~) (") Iftl (ft) (ft) (ft) (ftl (°/100ft) (ftl 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5,945,960.16 558,785.90 0.00 0.00 SFiL @ 28' MD, 28' TV D: FNL 3132' FEL 2422'-Sec 35-T71 N-R10E 100.00 0.00 0.00 100.00 -9.00 0.00 0.00 5,945,960.16 558,785.90 0.00 0.00 200.00 0.00 0.00 200.00 91.00 0.00 0.00 5,945,960.16 558,785.90 0.00 0.00 300.00 0.00 0.00 300.00 191.00 0.00 0.00 5,945,960.16 558,785.90 0.00 0.00 400.00 3.00 70.00 399.95 290.95 0.90 2.46 5,945,961.07 558,788.35 3.00 -0.90 500.00 6.00 70.00 499.63 390.63 3.58 9.83 5,945,963.81 558,795.70 3.00 -3.58 600.00 9.00 70.00 598.77 489.77 8.04 22.10 5,945,968.37 558,807.93 3.00 -8.04 700.00 12.00 70.00 697.08 588.08 14.27 39.22 5,945,974.74 558,825.00 3.00 -14.27 702.98 12.09 70.00 700.00 591.00 14.49 39.80 5,945,974.96 558,825.59 3.00 -14.49 800.00 15.96 70.98 794.11 685.11 22.31 61.97 5,945,982.95 558,847.69 4.00 -22.31 900.00 19.96 71.61 889.21 780.21 32.18 91.18 5,945,993.05 558,876.82 4.00 -32.18 1 000.00 23.96 72.03 981.94 872.94 43.84 126.70 5,946,004.98 558,912.24 4.00 -43.84 , 1,100.00 27.95 72.33 1,071.84 962.84 57.22 168.36 5,946,018.69 558,953.79 4.00 -57.22 1,200.00 31.95 72.57 1,158.46 1049.46 72.26 215.95 5,946,034.10 559,001.26 4.00 -72.26 1 300.00 35.95 72.76 1,241.40 1132.40 88.90 269.26 5,946,051.15 559,054.43 4.00 -88.90 , 1,400.00 39.95 72.91 1,320.24 1211.24 107.04 328.00 5,946,069.75 559,113.02 4.00 -107.04 1,500.00 43.95 73.04 1,394.60 1285.60 126.60 391.91 5,946,089.81 559,176.77 4.00 -126.60 600.00 1 47.95 73.16 1,464.12 1355.12 147.49 460.66 5,946,111.23 559,245.35 4.00 -147.49 , 1,654.75 50.14 73.21 1,500.00 1391.00 159.45 500.23 5,946,123.49 559,284.83 4.00 -159.45 1,672.03 50.14 73.21 1,511.08 1402.08 163.28 512.94 5,946,127.42 559,297.50 0.00 -163.28 Pfrost 700.00 1 50.14 73.21 1,529.01 1420.01 169.48 533.49 5,946,133.78 559,318.00 0.00 -169.48 , 704.75 1 50.14 73.21 1,532.05 1423.05 170.53 536.98 5,946,134.86 559,321.48 0.00 -170.53 , 800.00 1 53.95 73.17 1,590.63 1481.63 192.25 608.86 5,946,157.14 559,393.18 4.00 -192.25 , 1,900.00 57.95 73.12 1,646.61 1537.61 216.27 688.13 5,946,181.78 559,472.26 4.00 -216.27 1,926.04 58.99 73.11 1,660.23 1551.23 222.72 709.37 5,946,188.39 559,493.44 4.00 -222.72 T3 2 000.00 61.95 73.08 1,696.68 1587.68 241.43 770.93 5,946,207.58 559,554.85 4.00 -241.43 , 2 100.00 65.95 73.04 1,740.60 1631.60 267.60 856.86 5,946,234.41 559,640.56 4.00 -267.60 , 158.95 2 68.30 73.02 1,763.51 1654.51 283.45 908.81 5,946,250.66 559,692.38 4.00 -283.45 , 2,200.00 68.30 73.02 1,778.69 1669.69 294.58 945.28 5,946,262.08 559,728.76 0.00 -294.58 300.00 2 68.30 73.02 1,815.65 1706.65 321.71 1,034.15 5,946,289.91 559,817.41 0.00 -321.71 , 2,400.00 68.30 73.02 1,852.62 1743.62 348.85 1,123.02 5,946,317.73 559,906.05 0.00 -348.85 2,500.00 68.30 73.02 1,889.59 1780.59 375.98 1,211.88 5,946,345.55 559,994.69 0.00 -375.98 2 600.00 68.30 73.02 1,926.56 1817.56 403.11 1,300.75 5,946,373.37 560,083.34 0.00 -403.11 , 2,700.00 68.30 73.02 1,963.53 1854.53 430.24 1,389.61 5,946,401.20 560,171.98 0.00 -430.24 2,722.65 68.30 73.02 1,971.90 1862.90 436.39 1,409.74 5,946,407.50 560,192.06 0.00 -436.39 K15 2 800.00 68.30 73.02 2,000.49 1891.49 457.37 1,478.48 5,946,429.02 560,260.62 0.00 -457.37 , 2,900.00 68.30 73.02 2,037.46 1928.46 484.51 1,567.35 5,946,456.84 560,349.27 0.00 -484.51 3,000.00 68.30 73.02 2,074.43 1965.43 511.64 1,656.21 5,946,484.66 560,437.91 0.00 -511.64 100.00 3 68.30 73.02 2,111.40 2002.40 538.77 1,745.08 5,946,512.49 560,526.55 0.00 -538.77 , 3,200.00 68:30 73.02 2,148.37 2039.37 565.90 1,833.95 5,946,540.31 560,615.20 0.00 -565.90 3,300.00 68.30 73.02 2,185.33 2076.33 593.03 1,922.81 5,946,568.13 560,703.84 0.00 -593.03 3,400.00 68.30 73.02 2,222.30 2113.30 620.17 2,011.68 5,946,595.95 560,792.48 0.00 -620.17 7/16/2007 5:25:07PM Page 4 of 9 COMPASS 2003.11 Build 48 ~~ ~'' Halliburton Company ConoeoPhillips Compass Proposal Report -Geographic Alaska HALLi URTON Sperry Drilling Services Database: .Sperry EDM .11 Local Co-ordinate Reference: V'lell Plan 1J-107 Company: ConocoPhillips Alaska, Inc. TVD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: 1 lan RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-107 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-107 Design: iJ-107 (wp05) Planned Survey 1J-1071wp05) Map Map MD Incl Azimuth ND (ft) TVDSS +N/-S +E/_yy Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) lft) 1ft) lft) ('/100ft) (ft) 3,500.00 68.30 73.02 2,259.27 2150.27 647.30 2,100.54 5,946,623.78 560,881.12 0.00 -647.30 3,543.47 68.30 73.02 2,275.34 2166.34 659.09 2,139.17 5,946,635.87 560,919.66 0.00 -659.09 T3+550 - 13 318" 3,600.00 68.30 73.02 2,296.24 2187.24 674.43 2,189.41. 5,946,651.60 560,969.77 0.00 -674.43 3,700.00 68.30 73.02 2,333.21 2224.21 701.56 2,278.28 5,946,679.42 561,058.41 0.00 -701.56 3,800.00 68.30 73.02 2,370.18 2261.18 728.70 2,367.14 5,946,707.24 561,147.05 0.00 -728.70 3,900.00 68.30 73.02 2,407.14 2298.14 755.83 2,456.01 5,946,735.06 561,235.70 0.00 -755.83 4,000.00 68.30 73.02 2,444.11 2335.11 782.96 2,544.88 5,946,762.89 561,324.34 0.00 -782.96 4,100.00 68.30 73.02 2,481.08 2372.08 810.09 2,633.74 5,946,790.71 561,412.98 0.00 -810.09 4,200.00 68,30 73.02 2,518.05 2409.05 837.22 2,722.61 5,946,818.53 561,501.63 0.00 -837.22 4,300.00 68.30 73.02 2,555.02 2446.02 864.36 2,811.47 5,946,846.35 561,590.27 0.00 -864.36 4,400.00 68.30 73.02 2,591.98 2482.98 891.49 2,900.34 5,946,874.18 561,678.91 0.00 -891.49 4,500.00 68,30 73.02 2,628.95 2519.95 918.62 2,989.21 5,946,902.00 561,767.56 0.00 -918.62 4,600.00 68.30 73.02 2,665.92 2556.92 945.75 3,078.07 5,946,929.82 561,856.20 0.00 -945.75 4,700.00 68.30 73.02 2,702.89 2593.89 972.88 3,166.94 5,946,957.64 561,944.84 0.00 -972.88 4,800.00 68.30 73.02 2,739.86 2630.86 1,000.02 3,255.81 5,946,985.47 562,033.49 0.00 -1,000.02 4,900.00 68.30 73.02 2,776.82 2667.82 1,027.15 3,344.67 5,947,013.29 562,122.13 0.00 -1,027.15 5,000.00 68.30 73.02 2,813.79 2704.79 1,054.28 3,433.54 5,947,041.11 562,210.77 0.00 -1,054.28 5,100.00 68.30 73.02 2,850.76 2741.76 1,081.41 3,522.40 5,947,068.93 562,299.42 0.00 -1,081.41 5,200.00 68.30 73.02 2,887.73 2778.73 1,108.54 3,611.27 5,947,096.75 562,388.06 0.00 -1,108.54 5,219.67 68.30 73.02 2,895.00 2786.00 1,113.88 3,628.75 5,947,102.23 562,405.50 0.00 -1,113.88 5,300.00 68.71 75.99 2,924.43 2815.43 1,133.85 3,700.77 5,947,122.75 562,477.35 3.47 -1,133.85 5,400.00 69.21 79.68 2,960.34 2851.34 1,153.51 3,791.99 5,947,143.13 562,568.40 3.48 -1,153.51 5,500.00 69.71 83.37 2,995.44 2886.44 1,167.32 3,884.59 5,947,157.66 562,660.88 3.49 -1,167.32 5,524.62 69.83 84.27 3,003.95 2894.95 1,169.80 3,907.55 5,947,160.32 562,683.82 3.50 -1,169.80 Ugnu C 5,558.86 70.00 85.54 3,015.71 2906.71 1,172.66 3,939.58 5,947,163.43 562,715.83 3.50 -1,172.66 5,600.00 69.94 87.07 3,029.80 2920.80 1,175.15 3,978.15 5,947,166.22 562,754.38 3.50 -1,175.15 5,700.00 69.85 90.79 3,064.18 2955.18 1,176.90 4,072.02 5,947,168.70 562,848.22 3.50 -1,176.90 5,800.00 69.84 94.52 3, 098.65 2989.65 1,172.55 4,165.78 5,947,165.08 562,942.00 3.50 -1,172.55 5,900.00 69.91 98.25 3,133.07 3024.07 1,162.10 4,259.07 5,947,155.36 563,035.36 3.50 -1,162.10 6,000.00 70.05 101.97 3,167.32 3058.32 1,145.61 4,351.55 5,947,139.60 563,127.95 3.50 -1,145.61 6,100.00 70.28 105.68 3,201.26 3092.26 1,123.13 4,442.87 5,947,117.83 563,219.44 3.50 -1,123.13 6,200.00 70.57 109.39 3,234.77 3125.77 1,094.74 4,532.69 5,947,090.15 563,309.47 3.50 -1,094.74 6,233.22 70.69 110.61 3,245.79 3136.79 1,084.02 4,562.14 5,947,079.66 563,339.00 3.50 -1,084.02 Ugnu B 6,300.00 70.95 113.07 3,267.73 3158.73 1,060.56 4,620.68 5,947,056.65 563,397.71 3.50 -1,060.56 6,400.00 71.40 116.74 3,300.01 3191.01 1,020.70 4,706.50 5,947,017.47 563,483.84 3.50 -1,020.70 6,481.72 71.81 119.72 3,325.81 3216.81 984.02 4,774.81 5,946,981.33 563,552.43 3.50 -984.02 Ugnu A 6,500.00 71.91 120.39 3,331.50 3222.50 975.32 4,789.85 5,946,972.75 563,567.53 3.50 -975.32 6,600.00 72.50 124.01 3,362.07 3253.07 924.59 4,870.40 5,946,922.65 563,648.46 3.50 -924.59 6,700.00 73.15 127.61 3,391.61 3282.61 868.69 4,947.86 5,946,867.37 563,726.35 3.50 -868.69 6,800.00 73.86 131.18 3,420.02 3311.02 807.84 5,021.93 5,946,807.10 563,800.89 3.50 -807.84 6,851.05 74.25 133.00 3,434.04 3325.04 774.94 5,058.35 5,946,774.49 563,837.56 3.50 -774.94 K13 7/162007 5:25:07PM Page 5 of 9 COMPASS 2003.11 Build 48 QRIG-~~!~_. • ~ ~' Halliburton Company CO11000~'1i~~fp5 Compass Proposal Report -Geographic Alaska HALL~BURT N Sperry Drilling Servlcee Database: .Sperry EDM .11 Local Co-ordinate Reference: Well Plan 1J-107 Company: ConocoPhillips Alaska, Inc. TVD Reference: Plan RKB Q 109.OOft (Doyon 141 (28+81)) Project: K~.aparuk River Unit MD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-107 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-107 Design: 1J-107 (wp05) J Planned Survey 1J-107 (v~p05) MD lncl Azimuth TVD (ft) TVDSS (ft) (°) (°) (ft) 6,900.00 74.63 134.73 3,447.17 3338.17 7,000.00 75.46 138.25 3,472.98 3363.98 7,100.00 76.34 141.74 3,497.35 3388.35 7,200.00 77.27 145.21 3,520.19 3411.19 7,300.00 78.24 148.65 3,541.40 3432.40 7,400.00 79.25 152.07 3,560.92 3451.92 7,500.00 80.30 155.46 3,578.67 3469.67 7,600.00 81.39 158.83 3,594.58 3485.58 7,654.85 82.00 160.67 3,602.51 3493.51 7,670.00 82.00 160.67 3,604.62 3495.62 Begin Pum p Tangent 82° @ 7670' MD, 3605' TVD 7,700.00 82.00 160.67 3,608.79 3499.79 7,800.00 82.00 160.67 3,622.72 3513.72 7,870.00 82.00 160.67 3,632.46 3523.46 End Pump Tangent @ 7870' MD, 3632' TVD 7,900.00 82.00 160.67 3,636.64 3527.64 8,000.00 82.00 160.67 3,650.57 3541.57 8,055.55 82.00 160.67 3,658.30 3549.30 W Sak D -1J-109a Dtop (wp05) 05/16/07 8,100.00 82.00 162.24 3,664.49 3555.49 8,200.00 82.00 165.78 3,678.41 3569.41 8,255.55 82.00 167.75 3,686.15 3577.15 8,300.00 83.05 168.90 3,691.93 3582.93 8,359.72 84.47 170.45 3,698.42 3589.42 W Sak C Map Map +NI-S +E/-W Northing Easting DLSEV Vert Section (ft) (ft) 1ft) (ft) (°/100ft) (ft) 742.26 5,092.35 5,946,742.08 563,871.81 3.50 -742.26 672.20 5,158.85 5,946,672.55 563,938.85 3.50 -672.20 597.91 5,221.18 5,946,598.76 564,001.75 3.50 -597.91 519.68 5,279.10 5,946,520.99 564,060.28 3.50 -519.68 437.80 5,332.41 5,946,439.53 564,114.22 3.50 -437.80 352.57 5,380.90 5,946,354.69 564,163.37 3.50 -352.57 264.31 5,424.40 5,946,266.78 564,207.55 3.50 -264.31 173.34 5,462.73 5,946,176.13 564,246.58 3.50 -173.34 122.43 5,481.51 5,946,125.36 564,265.76 3.50 -122.43 108.27 5,486.48 5,946,111.24 564,270.84 0.00 -108.27 80.23 5,496.31 5,946,083.29 564,280.89 0.00 -80.23 -13.21 5,529.08 5,945,990.11 564,314.39 0.00 13.21 -78.62 5,552.03 5,945,924.89 564,337.84 0.00 78.62 -106.66 5,561.86 5,945,896.94 564,347.89 0.00 106.66 -200.10 5,594.64 5,945,803.76 564,381.39 0.00 200.10 -252.01 5,612.84 5,945,752.00 564,400.00 0.00 252.01 -293.74 5,626.84 5,945,710.38 564,414.32 3.50 293.74 -388.92 5,654.10 5,945,615.43 564,442.33 3.51 388.92 -442.47 5,666.70 5,945,561.99 564,455.33 3.51 442.47 -485.63 5,675.61 5,945,518.90 564,464.58 3.50 485.63 -544.03 5,686.25 5,945,460.59 564,475.68 3.50 544.03 8,381.79 85.00 171.01 3,700.44 3591.44 -565.72 5,689.79 5,945,438.93 564,479.39 3.50 565.72 8,400.00 85.00 171.65 3,702.03 3593.03 -583.65 5,692.52 5,945,421.02 564,482.26 3.49 583.65 8,500.00 85.00 175.16 3,710.75 3601.75 -682.60 5,703.96 5,945,322.18 564,494.46 3.50 682.60 8,520.11 85.00 175.87 3,712.50 3603.50 -702.57 5,705.52 5,945,302.22 564,496.19 3.50 702.57 8,550.11 85.00 176.92 3,715.11 3606.11 -732.40 5,707.40 5,945,272.41 564,498.30 3.50 732.40 9 518" Casing @ 8550' MD, 3715' TVD: FNL 3866' FEL 1995'-Sec 36-T11 N-R10E - W Sak B - 9 5/8" 8,600.00 86.81 177.75 3,718.67 3609.67 -782.10 5,709.71 5,945,222.73 564,501.00 4.00 782.10 8,700.00 90.45 179.41 3,721.06 3612.06 -882.02 5,712.18 5,945,122.84 564,504.25 4.00 882.02 8,780.01 93.37 180.74 3,718.39 3609.39 -961.98 5,712.08 5,945,042.89 564,504.77 4.00 961.98 8,800.00 93.37 180.74 3,717.21 3608.21 -981.93 5,711.82 5,945,022.94 564,504.66 0.00 981.93 8,900.00 93.37 180.74 3,711.34 3602.34 -1,081.75 5,710.53 5,944,923.13 564,504.15 0.00 1,081.75 8,950.68 93.37 180.74 3,708.36 3599.36 -1,132.34 5,709.88 5,944,872.54 564,503.89 0.00 1,132.34 8,992.52 92.06 179.69 3,706.38 3597.38 -1,174.13 5,709.72 5,944,830.75 564,504.06 4.00 1,174.13 9,000.00 92.06 179.69 3,706.11 3597.11 -1,181.61 5,709.76 5,944,823.28 564,504.16 0.00 1,181.61 9,100.00 92.06 179.69 3,702.52 3593.52 -1,281.54 5,710.29 5,944,723.36 564,505.47 0.00 1,281.54 9,200.00 92.06 179.69 3,698.93 3589.93 -1,381.47 5,710.82 5,944,623.44 564,506.79 0.00 1,381.47 9,292.52 92.06 179.69 3,695.60 3586.60 -1,473.93 5,711.32 5,944,531.00 564,508.00 0.00 1,473.93 1J-107 MB B CP1 05!16107 9,300.00 91.99 179.69 3,695.34 3586.34 -1,481.41 5,711.36 5,944,523.53 564,508.10 1.00 1,481.41 9,386.11 91.12 179.69 3,693.00 3584.00 -1,567.48 5,711.82 5,944,437.47 564,509.23 1.00 1,567.48 7/16/2007 5:25:07PM Page 6 of 9 COMPASS 2003.11 Build 48 C011000~'11~~IpS Halliburton Company HALLiBURTON Alaska Compass Proposal Report -Geographic gperry Drilling S®rvice~ Database: .Sperry EDM .11 Local Co-ordinate Reference: =- Well Plan 1J-107 Company: ConocoPhillips Alaska, Inc. ND Reference: ' Plan RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-107 Survey Calculation Method: '' Minimum Curvature Wellbore: Plan 1J-107 Design: 1J-107 (wp05) Planned Survey 1 J~107 (~~/p05~ Map Map MD Inc! Azimuth TVD (ft) TVDSS +N(-S +E/-W Northing Fasting DLSEV Vert Section (ft) (°) (°) (ftl (ft) (ft) (ft) Ift) (°/100ft) (ftl 9,400.00 91.12 179.69 3,692.73 3583.73 -1,581.37 5,711.89 5,944,423.58 564,509.41 0.00 1,581.37 9,500.00 91.12 179.69 3,690.77 3581.77 -1,681.35 5,712.42 5,944,323.62 564,510.73 0.00 1,681.35 9,600.00 91.12 179.69 3,688.80 3579.80 -1,781.33 5,712.96 5,944,223.65 564,512.04 0.00 1,781.33 9,700.00 91.12 179.69 3,686.84 3577.84 -1,881.31 5,713.49 5,944,123.69 564,513.35 0.00 1,881.31 9,800.00 91.12 179.69 3,684.88 3575.88 -1,981.29 5,714.02 5,944,023.73 564,514.67 0.00 1,981.29 9,900.00 91.12 179.69 3,682.92 3573.92 -2,081.27 5,714.55 5,943,923.77 564,515.98 0.00 2,081.27 10,000.00 91.12 179.69 3,680.96 3571.96 -2,181.25 5,715.09 5,943,823.80 564,517.29 0.00 2,181.25 10,053.82 91.12 179.69 3,679.90 3570.90 -2,235.06 5,715.37 5,943,770.00 564,518.00 0.00 2,235.06 1J-107 MB B CP2 05/16/O7 10,100.00 90.66 179.72 3,679.18 3570.18 -2,281.23 5,715.61 5,943,723.84 564,518.59 1.00 2,281.23 10,162.62 90.04 179.76 3,678.80 3569.80 -2,343.85 5,715.89 5,943,661.23 564,519.36 1.00 2,343.85 10,200.00 90.04 179.76 3,678.77 3569.77 -2,381.23 5,716.04 5,943,623.86 564,519.81 0.00 2,381.23 10,300.00 90.04 179.76 3,678.70 3569.70 -2,481.23 5,716.46 5,943,523.87 564,521.01 0.00 2,481.23 10,400.00 90.04 179.76 3,678.64 3569.64 -2,581.23 5,716.87 5,943,423.89 564,522.20 0.00 2,581.23 10,500.00 90.04 179.76 3,678.57 3569.57 -2,681.22 5,717.29 5,943,323.91 564,523.39 0.00 2,681.22 10,600.00 90.04 179.76 3,678.50 3569.50 -2,781.22 5,717.70 5,943,223.92 564,524.59 0.00 2,781.22 10,700.00 90.04 179.76 3,678.44 3569.44 -2,881.22 5,718.11 5,943,123.94 564,525.78 0.00 2,881.22 10,800.00 90.04 179.76 3,678.37 3569.37 -2,981.22 5,718.53 5,943,023.96 564,526.98 0.00 2,981.22 10,900.00 90.04 179.76 3,678.30 3569.30 -3,081.22 5,718.94 5,942,923.97 564,528.17 0.00 3,081.22 11,000.00 90.04 179.76 3,678.24 3569.24 -3,181.22 5,719.36 5,942,823.99 564,529.37 0.00 3,181.22 11,053.00 90.04 179.76 3,678.20 3569.20 -3,234.22 5,719.58 5,942,771.00 564,530.00 0.00 3,234.22 1J-107 MB B CP3 05116/07 11,099.74 89.57 179.78 3,678.36 3569.36 -3,280.96 5,719.76 5,942,724.27 564,530.55 1.00 3,280.96 11,100.00 89.57 179.78 3,678.36 3569.36 -3,281.22 5,719.76 5,942,724.01 564,530.55 0.00 3,281.22 11,200.00 89.57 179.78 3,679.11 3570.11 -3,381.22 5,720.15 5,942,624.03 564,531.72 0.00 3,381.22 11,300.00 89.57 179.78 3,679.86 3570.86 -3,481.21 5,720.53 5,942,524.05 564,532.89 0.00 3,481.21 11,400.00 89.57 179.78 3,680.61 3571.61 -3,581.21 5,720.92 5,942,424.07 564,534.05 0.00 3,581.21 11,500.00 89.57 179.78 3,681.35 3572.35 -3,681.20 5,721.30 5,942,324.09 564,535.22 0.00 3,681.20 11,600.00 89.57 179.78 3,682.10 3573.10 -3,781.20 5,721.69 5,942,224.10 564,536.38 0.00 3,781.20 11,653.11 89.57 179.78 3,682.50 3573.50 -3,834.31 5,721.89 5,942,171.00 564,537.00 0.00 3,834.31 1J-107 MB B CP4 05/16!07 11,700.00 89.11 179.68 3,683.04 3574.04 -3,881.20 5,722.11 5,942,124.13 564,537.59 1.00 3,881.20 11,703.91 89.07 179.67 3,683.10 3574.10 -3,885.10 5,722.13 5,942,120.22 564,537.64 1.00 3,885.10 11,800.00 89.07 179.67 3,684.65 3575.65 -3,981.18 5,722.68 5,942,024.16 564,538.94 0.00 3,981.18 11,900.00 89.07 179.67 3,686.27 3577.27 -4,081.17 5,723.26 5,941,924.19 564,540.29 0.00 4,081.17 12,000.00 89.07 179.67 3,687.88 3578.88 -4,181.15 5,723.83 5,941,824.22 564,541.64 0.00 4,181.15 12,100.00 89.07 179.67 3,689.50 3580.50 -4,281.14 5,724.40 5,941,724.25 564,543.00 0.00 4,281.14 12,100.25 ~ 89.07 179.67 3,689.50 ~ 3580.50 -4,281.39 5,724.40 5,941,724.00 564,543.00 0.00 4,281.39 BHL @ 12100' MD, 3689' TVD: FN L 2135' FEL 1 982'-Sec 1-T10N-R10E - 5 1/2" - 1J-1 07 MB B Toe 05! 16/07 7/16/2007 5:25:07PM Page 7 of 9 COMPASS 2003.11 Build 48 ORIGINAL • ConocoPhillips Alaska Halliburton Company Compass Proposal Report -Geographic HALLIBURTON Sperry Dritiing Services Database: .Sperry EDM .11 Local Co-ordinate Reference: Well Plan 1J-107 Company: G~nocoPhillips Alaska, Inc. TVD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Project: k:uparuk River Unit MD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-107 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-107 Design: 1 J-107 (wp05) Geologic Targets Plan 1J-107 TVD TVDSS Target Nartte +Nl.g +EI-W Northing Easting (ft) (ft) - Shapo ft ft (ft) (ft) 3,695.60 1J-107 MB_B_CP1 05/16/07 -1,473.93 5,711.32 5,944,531.00 564,508.00 - Polygon Point 1 0.00 0.00 5,944,531.00 564,508.00 Point 2 -761.44 4.07 5,943,770.00 564,518.00 3,682.50 1J-107 MB_B_CP4 05/16/07 -3,834.31 5,721.89 5,942,171.00 564,537.00 - Polygon Point 1 0.00 0.00 5,942,171.00 564,537.00 Point 2 -447.13 2.51 5,941,724.00 564,543.00 3,739.60 1J-107 MB_B_Heel 05/16/07 -252.01 5,612.84 5,945,752.00 564,400.00 - Polygon Point 1 0.00 0.00 5,945,752.00 564,400.00 Point 2 -1,222.92 98.53 5,944,531.00 564,508.00 3,689.50 1J-107 MB_B_Toe 05/16/07 -4,281.39 5,724.40 5,941,724.00 564,543.00. - Point 3,658.30 1J-109a Dtop (wp05) 05/16/07 -252.01 5,612.84 5,945,752.00 564,400.00 - Point 3,679.90 1J-107 MB_B_CP2 05/16/07 -2,235.06 5,715.37 5,943,770.00 564,518.00 - Polygon Point 1 0.00 0.00 5,943,770.00 564,518.00 Point 2 -999.22 4.20 5,942,771.00 564,530.00 3,678.20 1J-107 MB_B_CP3 05/16/07 -3,234.22 5,719.58 5,942,771.00 564,530.00 - Polygon Point 1 0.00 0.00 5,942,771.00 564,530.00 Point 2 -600.10 2.32 5,942,171.00 564,537.00 Prognosed Casing Points Measured Vertical Casing Holo Depth Depth Diameter Diameter (ft) (ft) O ( ) 3,543.47 2,275.34 13-3/8 16 8,550.11 3,715.11 9-518 12-1 /4 12,100.24 3,689.50 5-112 8-112 7/16/2007 5:25:07PM Page 8 of 9 COMPASS 2003.11 Build 48 aRI~1NAL ~O~OCO~i"i~ Halliburton Company HALLiBURTO ~~ Compass Proposal Report -Geographic gperry Driiiing Services Database: Sperry EDM .11 Local Co-ordinate Reference: Well Plan 1J-107 Company: ConocoPhillips Alaska, Inc. TVD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-107 Survey Calculation Method: tv~inimum Curvature Wellbore: Plan 1J-107 Design: 1J-107 (wp05) Prognosed Formation Intersection Points Measured Depth Inclination Azimuth TVD TVDSS +N/-E (ft) +E/-W (ft) (ft) 1°) (') (ftl (ft) Namc 1,672.03 50.14 73.21 1,511.08 163.28 512.94 Pfrost 1,926.04 58.99 73.11 1,660.23 222.72 709.37 T3 2,722.65 68.30 73.02 1,971.90 436.39 1,409.74 K15 3,543.47 68.30 73.02 2,275.34 659.09 2,139.17 T3+550 5,524.62 69.83 84.27 3,003.95 1,169.80 3,907.55 Ugnu C 6,233.22 70.69 110.61 3,245.79 1,084.02 4,562.14 Ugnu B 6,481.72 71.81 119.72 3,325.81 984.02 4,774.81 Ugnu A 6,851.05 74.25 133.00 3,434.04 774.94 5,058.35 K 13 8,055.55 82.00 160.67 3,658.30 -252.01 5,612.84 W Sak D 8,359.72 84.47 170.45 3,698.42 -544.03 5,686.25 W Sak C 8,550.06 85.00 176.92 3,715.11 -732.35 5,707.40 W Sak B i Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/$ +E!-W Comment (ft) lft) (ft} (ft) 28.00 28.00 0.00 0.00 SHL @ 28' MD, 28' TVD: FNL 3132' FEL 2422'-Sec 35-T11N-R10E 7,670.00 3,604.62 108.27 5,486.48 Begin Pump Tangent 82° @ 7670' MD, 3605' TVD 7,870.00 3,632.46 -78.62 5,552.03 End Pump Tangent @ 7870' MD, 3632' TVD 8,550.11 3,715.11 -732.40 5,707.40 9 5/8" Casing @ 8550' MD, 3715' TVD: FNL 3866' FEL 1995'-Sec 36-T11 N-R' 12,100.24 3,689.50 -4,281.38 5,724.40 BHL @ 12100' MD, 3689' TVD: FNL 2135' FEL 1982'-Sec 1-T10N-R10E 7/16/2007 5:25:07PM Page 9 of 9 COMPASS 2003.11 Build 48 ORIGINAL • ~ ConocoPhillips Alaska Plan: 1J-107 (wp05) Sperry Drilling Services Anticollision Summary 17 July, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-107 Plan 1J-107 Local Coordinate Origin: Centered on Well Plan 1J-107 Viewing Datum: Plan RKB (a~ 109.OOft (Doyon 141 (28+81)) TVDs to System: N North Reference: True Unit System: API - US Survey Feet H L.fIJTON Sperry Drilling Services ORIGINAL SURVEY PROGRAM Date: 2007-06-15700:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 0.00 1000.00 IJ-107 (wp05) CSG1'RO-SS 1000.00 12100.20 1J-107 (wp05) MWD+IFR-AK-CAZSC 1~~ 09 ^~. ,~o° 1, \~ ~\ 5a , ~)1 ] 166 ~~~ 1 1 ~~ 1y. COMPANY DETAILS: ConocoPhillips Alaska, Inc. Engineering Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surtace: Elliptical Conic Warning Method: Rules Based ,,~.~o so 10~ \ \ O~ 1 ~ ~=Q~ O ~ 1~•J \~Q 1'v ` ^I1 b \ \ O~\ v ~ Y Travelling Cylintler Azimuth (TFO+ALI) ~°~ vs Centre to Centre Separation X200 ft/ink ~ REFERENCE INFORMATION ~ Co-ordinate (N/E) Reference: Well Plan 1J-107, True North VeRical (TVD) Reference: Plan RKB ~ 109.OOft (Doyon 141 (28+81)) Section (VS) Reference: Slot - (O.OON, O.OOE) Measured Depth Reference: Plan RKB ~ 109.OOft (Doyon 141 (28+81)) Calculation Method: Minimum Curvature From Colour To MD I 0 250 250 500 500 750 750 - _. ...__ 1000 1000 1250 1250 1500 1500 1750 1750 2000 2000 2250 2250 2500 2500 3000 3000 4000 4000 5000 5000 6000 6000 7000 7000 8000 8000 9000 9000 10000 10000 0 ANTI-COLLISION SETTINGS Interpolation Method: MD Interval: 50Stations Depth Range From: 0.00 To 12100.89 Maximum Range: 1410.09 Reference: Plan: 1J-107 (wp05) 1J-105 ' 180 1 J-D 3 90 Traveging Cylinder Atimu[h (rFO+AZI) ~°~ vs Centre to Centre Separation (30 ft/in( ~ NAD 27 ASP Zone 4 : WELL DETAILS: Plan 1J-107 ~ Ground Level: 81.00 +N/-S +EI-W Northing Easting Latittude Longitude Slot 0.00 0.00 5945960.16 558785.90 70°15'46.657N 149°31'29.115W Svc MD IM bu NO •WS •EI-W OLe9 TFxe Vaec Tegel 1 900 960 0.00 o.ao 0.00 Sao 000 Sao 900 z 300.00 900 0.00 Sao ao o.oo Sao 900 0.00 900 3 ]02.99 12.09 ]0.00 ]OO.GO 14.49 39.80 308 4 1fi54.]5 50.14 ]321 1500.00 159.45 500.23 d.00 ]0.00 -1449 4.0015945 5 1]04.]5 50.14 ]3.21 1532.05 1N.53 536.98 0.00 0.00 -1]0.53 6 2158.85 68.30 ]J.02 1]fi3.51 28J.45 908.81 4.00 -0.51 -28345 ] 5219.6] 66.30 ]302 2695.00 111386 3626]5 90D 000 111368 6 5558.88 ]0.00 85.51 3015.]1 11]2.66 3938.56 348 8 1651.Ya 62.00 160.61 3603.51 1n.43 518151 3.50 61.]5 -11]2.66 82.63 -1 n.43 to sosa 55 ea0o 36se 30 <sz 91 sbu34 o 00 16 1 006 z5z o1 .,.1o9a o:aa 1+.v93, as l9 0. 1 11 ezs5ss e2ao ]. 5 3666.15 w424] ssbs.]a 351 s0.oo uzn tz 9391 ]9 6500 1]t Ot J]00.44 565.]2 5669.]9 350 0]3] SfiS.]2 13 8520.11 65.00 1]5.81 311 Z.50 -]02.5] 5]05.52 350 90.00 ]028] 14 8550.11 85.OD 116.82 3]15.11 -]32.40 5]0]40 350 15 8]!0.01 93.3] 160.]4 3]18.39 -98198 5]12.08 4.00 90.00 73340 24.59 96198 16 695986 939] 180.]4 3]06.36 -t 132.31 5]09.08 000 900 113234 1] 8992.52 93.Ofi 1]9fi9 ]]06.38 ~11]4.1J 5]09.n 900 141.33 11]4.13 18 9192.52 9206 11969 169560 -14]J93 5]I I.]2 000 19 8368.11 91.12 1'!8.88 3893.OJ -156].48 5111.82 1.60 000 14]3.93 1J-10]MBB CPI GS 160] 180.00 1561.48 - - 20 10053.82 112 119.69 36]990 ~Z23506 8115.31 000 000 223506 1J-10]MB B CP205I160] -- 21 10182.62 8001 1]8.]6 38]8.80 -230.1.85 5]15.89 tOD 1]640 2343.85 22 1105300 9004 1]9)6 36]810 -J13422 811958 000 23 11098]1 88.5] 118.]6 3618.36 J280.% 5119.]6 1.00 900 J23422 1J-t0]MH_B CP3OS'16/0] 111.95 3280.86 24 11fi5311 895] 1]9 >8 3fi8250 38J4 JI 5]2169 000 000 JBJ4.31 1J-10]MH H CP405I1N0] - - 25 11]03.81 89.0] 119.8] 3863.10 x88.5.10 5122.13 1.00 26 12100.25 090] 1J86] 3609.50 438139 5]24,40 000 -181.80 3885.10 0.00 4281.39 IJ-10]MB H Tae 05116'01 ~~3 ~~~ ` ~ U Halliburton Co m an P Y Antico llision Report Company: ConocoPhillips Alaska Inc. Date: 7/17/2007 1'imc: 14:31:42 Yage: 1 Field: Kuparuk River Unit Rcfcrence Site: Kuparuk 1J Pad Co-ordinate( NE) Reference: Well: Plan 1J-107, True North Reference a~'ell: Plan 1J-107 Vertical (TVD) Rcfcren ce: Doyon 14 1 (28+81) 1 09.0 Reference ~1'cllpafh: Plan 1J-107 Db: Orade GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Plan: 1J-107 (wp05) & NOT PLANNED PR Interpolation Method: MD Interval: 25.00 ff Error Model: ISCWSA Ellipse Depth Range: 28.00 to 12100.27 ff Scan Method: Trav Cylinder North Maximum Radius: 1407.23 ft Error Surface: Ellipse + Casing Casing Points Dlll TVD lliamcter Hole Sizc Name ft ft in in 3543.47 2275.34 13.375 16.000 13 3/8" 8552.76 3715.34 9.625 12.250 9 5/8" 12100.27 3689.50 5.500 8.500 51/2" Plan: 1J-107 (wp05) Date Composed: 7/3/2007 Version: 3 Principal: Yes Tied-to: From Well Ref. Point Summary __ _ _ _ _ _ _ - ~ <-- ---------------- O ffset~Vcllpath ---- -------------> Reference Offset Ctr-Ctr No-Go Allowable Site ~~'ell Wcllpath ~1D MD Distance .area Deviation Warning ft ft ft ft ft Kuparuk 1J Pad 1J-03 1J-03 V11 666.96 675.00 40.30 10.83 29.47 Pass: Major Risk Kuparuk 1J Pad 1J-03 1J-03L1 V3 667.08 675.00 40.30 11.17 29.14 Pass: Major Risk Kuparuk 1J Pad 1J-03 1J-03L2 V2 667.08 675.00 40.30 11.17 29.14 Pass: Major Risk Kuparuk 1J Pad 1J-03 1J-03L2PB1 V2 667.08 675.00 40.30 11.17 29.14 Pass: Major Risk Kuparuk 1J Pad 1J-09 1J-09 V8 168.95 175.00 151.71 2.87 148.84 Pass: Major Risk Kuparuk 1J Pad 1J-101 1J-101 V11 28.00 28.00 130.25 No Offset Stations Kuparuk 1J Pad 1J-101 1J-101 L1 V3 525.68 525.00 134.81 9.66 125.16 Pass: Major Risk Kuparuk 1J Pad 1J-101 1J-101 L1PB1 V2 525.68 525.00 134.81 9.77 125.05 Pass: Major Risk Kuparuk 1J Pad 1J-101 1J-101 L2 V2 525.68 525.00 134.81 9.66 125.16 Pass: Major Risk Kuparuk 1J Pad 1J-101 1J-101P61 V6 525.68 525.00 134.81 9.77 125.05 Pass: Major Risk Kuparuk 1J Pad 1J-10 1J-10 V8 318.23 325.00 189.22 5.16 184.06 Pass: Major Risk Kuparuk 1J Pad 1J-102 1J-102 V2 237.69 250.00 100.66 4.42 96.24 Pass: Major Risk Kuparuk 1J Pad 1J-102 1J-102L1 V4 237.69 250.00 100.66 4.42 96.24 Pass: Major Risk Kuparuk 1J Pad 1J-102 1J-102L2 V4 237.69 250.00 100.66 4.42 96.24 Pass: Major Risk Kuparuk 1J Pad 1J-102 1J-102L2P61 V2 237.69 250.00 100.66 4.53 96.13 Pass: Major Risk Kuparuk 1 J Pad 1 J-102 1 J-102L2PB2 V7 237.69 250.00 100.66 4.53 96.13 Pass: Major Risk Kuparuk 1J Pad 1J-102 1J-102P61 V5 237.69 250.00 100.66 4.42 96.24 Pass: Major Risk Kuparuk 1J Pad 1J-102 1J-102PB2 V2 237.69 250.00 100.66 4.53 96.13 Pass: Major Risk Kuparuk 1J Pad 1J-102 1J-102PB3 V1 237.69 250.00 100.66 4.53 96.13 Pass: Major Risk Kuparuk 1J Pad 1J-103 1J-103 V5 349.54 350.00 81.65. 6.01 75.64 Pass: Major Risk Kuparuk 1J Pad 1J-103 1J-103L1 V3 349.54 350.00 81.65 5.88 75.77 Pass: Major Risk Kuparuk 1J Pad 1J-103 1J-103L1PB1 V3 349.54 350.00 81.65 6.12 75.53 Pass: Major Risk Kuparuk 1J Pad 1J-103 1J-103L2 V3 349.54 350.00 81.65 5.88 75.77 Pass: Major Risk Kuparuk 1J Pad 1J-103 1J-103P61 V3 349.54 350.00 81.65 6.12 75.53 Pass: Major Risk Kuparuk 1J Pad 1J-103 1J-103PB2 V5 349.54 350.00 81.65 6.12 75.53 . Pass: Major Risk Kuparuk 1J Pad 1J-103 1J-103PB3 V4 349.54 350.00 81.65 6.12 75.53 Pass: Major Risk Kuparuk 1J Pad 1J-105 1J-105 V4 5145.26 5400.00 208.97 190.86 18.11 Pass: Major Risk Kuparuk 1J Pad 1J-105 1J-105L1 V2 5145.26 5400.00 208.97 190.86 18.11 Pass: Major Risk Kuparuk 1J Pad 1J-105 1J-105L2 V1 5145.26 5400.00 208.97 190.86 18.11 Pass: Major Risk Kuparuk 1J Pad 1J-105 1J-105PB1 V2 5145.26 5400.00 208.97 191.37 17.59 Pass: Major Risk Kuparuk 1J Pad 1J-109 1J-109 V2 436.88 450.00 59.37 8.57 50.80 Pass: Major Risk Kuparuk 1J Pad 1J-109 1J-109PB1 V4 436.88 450.00 59.37 8.57 50.80 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115 V3 423.57 425.00 180.66 6.25 174.41 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115L1 V1 423.57 425.00 180.66 6.12 174.54 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115L1PB1 V1 423.57 425.00 180.66 6.36 174.30 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115L1PB2 V1 423.57 425.00 180.66 6.36 174.30 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115L2 V2 423.57 425.00 180.66 6.12 174.54 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115L2PB1 V4 423.57 425.00 180.66 6.36 174.30 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115L2PB2 V3 423.57 425.00 180.66 6.36 174.30 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115P61 V2 423.57 425.00 180.66 6.36 174.30 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115PB2 V2 423.57 425.00 180.66 6.36 174.30 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115PB3 V2 423.57 425.00 180.66 6.36 174.30 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115P64 V2 423.57 425.00 180.66 6.36 174.30 Pass: Major Risk Kuparuk 1J Pad 1J-118 1J-118 V9 6524.46 6800.00 285.71 195.98 89.74 Pass: Major Risk Kuparuk 1J Pad 1J-118 1J-118L1 V5 6524.46 6800.00 285.71 195.98 89.74 Pass: Major Risk Kuparuk 1J Pad 1J-118 1J-118L2 V4 6524.46 6800.00 285.71 195.98 89.74. Pass: Major Risk OR161NAL Halliburton Company Anticollision Report Company-: ConocoPhillips Alaska Inc. Date: 7/17/2007 Time: 14:31:42 Pa~c: 2 Field: Kuparuk River Unit Keference Site: Kuparuk 1J Pad Co-ordinate(NE) Reference: Well: Pla n 1J-107, Tr ue North Reference ~~`ell: Plan 1J-107 Vertical (TVD) Refere nce: Doyon 141 (28+81) 1 09.0 Reference~Vellpath: Plan 1J-107 Db: Oracle Summary _ _ <-------- ------------- Offset ~~'ellpath -------------- ------> Reference Offset - Ctr-Ctr \o-Go allowable Site Nell Wcllpath D1D A1ll Distance Area Dc~~iation Warning ft ft ft ft ft Kuparuk 1J Pad 1J-118 1J-118P61 V4 6524.46 6800.00 285.71 196.06 89.65 . Pass: Major Risk Kuparuk 1J Pad 1J-118 1J-118P62 V5 6524.46 6800.00 285.71 196.06 89.65 Pass: Major Risk Kuparuk 1J Pad 1J-120 1J-120 V4 7747.54 7475.00 248.60 133.82 114.78 Pass: Major Risk Kuparuk iJ Pad 1J-120 1J-120L1 V2 7747.54 7475.00 248.60 133.82 114.78 Pass: Major Risk Kuparuk 1J Pad 1J-120 1J-120L1PB1 V3 7747.54 7475.00 248.60 133.90 114.70 Pass: Major Risk Kuparuk 1J Pad 1J-120 1J-120L1PB2 V5 7747.54 7475.00 248.60 133.90 114.69 Pass: Major Risk Kuparuk 1J Pad 1J-120 1J-120L1PB3 V5 7747.54 7475.00 248.60 133.90 114.69 Pass: Major Risk Kuparuk 1J Pad 1J-120 1J-120L1P64 V3 7747.54 7475.00 248.60 133.90 114.69 Pass: Major Risk Kuparuk 1J Pad 1J-120 1J-120L2 V2 7747.54 7475.00 248.60 133.82 114.78 Pass: Major Risk Kuparuk 1J Pad 1J-120 1J-120L2P61 V2 7747.54 7475.00 248.60 133.90 114.69 Pass: Major Risk Kuparuk 1J Pad 1J-14 1J-14 V13 361.81 375.00 695.41 5.47 689.93 Pass: Major Risk Kuparuk 1J Pad 1J-152 1J-152 V4 323.33 325.00 166.64 5.26 161.38 Pass: Major Risk Kuparuk 1J Pad 1J-152 1J-152L1 V3 323.33 325.00 166.64 5.00 161.64 Pass: Major Risk Kuparuk 1J Pad 1J-152 1J-152L2 V2 323.33 325.00 166.64 5.00 161.64 Pass: Major Risk Kuparuk 1J Pad 1J-152 1J-152L2PB1 V2 323.33 325.00 166,64 5.37 161.27 Pass: Major Risk Kuparuk 1J Pad 1J-152 1J-152PB1 V5 323.33 325.00 166.64 5.26 161.38 Pass: Major Risk Kuparuk 1J Pad 1J-152 1J-152PB2 V6 323.33 325.00 166,64 5.26 161.38 Pass: Major Risk Kuparuk 1J Pad 1J-154 1J-154 V6 369.85 375.00 145.78 6.68 139.10 Pass: Major Risk Kuparuk 1J Pad 1J-154 1J-154L1 V6 369.85 375.00 145.78 6.56 139.22 Pass: Major Risk Kuparuk 1J Pad 1J-154 1J-154L2 V4 369.85 375.00 145.78 6.53 139.26 Pass: Major Risk Kuparuk 1J Pad 1J-156 1J-156 V4 274.99 275.00 148.54 4.78 143.77 Pass: Major Risk Kuparuk 1J Pad 1J-156 1J-156L1 V2 274.99 275.00 148.54 4.65 143.90 Pass: Major Risk Kuparuk 1J Pad 1J-156 1J-156L1P61 V4 274.99 275.00 148.54 4.89. 143.66 Pass: Major Risk Kuparuk 1J Pad 1J-156 1J-156L2 V2 274.99 275.00 148.54 4.65 143.90 Pass: Major Risk Kuparuk 1J Pad 1J-158 1J-158 V6 262.44 275.00 159.46 4.31 155.16 Pass: Major Risk Kuparuk 1J Pad 1J-158 1J-158L1 V3 262.44 275.00 159.46 4.18 155.29 Pass: Major Risk Kuparuk 1J Pad 1J-159 1J-159 V3 757.87 800.00 169.26 12.40 156.86 Pass: Major Risk Kuparuk 1J Pad 1J-159 1J-159L1 V6 757.87 800.00 169.26 12.27 157.00 Pass: Major Risk Kuparuk 1J Pad 1J-159 1J-159L1P61 V2 757.87 800.00 169.26 12.50 156.76 Pass: Major Risk Kuparuk 1J Pad 1J-159 1J-159L1PB2 V2 757.87 800.00 169.26 12.50 156.76 Pass: Major Risk Kuparuk 1J Pad 1J-159 1J-159L2 V3 757.87 800.00 169.26 12.27 157.00 Pass: Major Risk Kuparuk 1J Pad 1J-159 1J-159PB1 V3 757.87 800.00 169.26 12.50 156.76 Pass: Major Risk Kuparuk 1J Pad 1J-160 1J-160 V5 211.70 225.00 177.68 4.27 .173.41 Pass: Major Risk. Kuparuk 1J Pad 1J-160 1J-160L1 V6 211.70 225.00 177.68 4.12 173.56 Pass: Major Risk Kuparuk 1J Pad 1J-160 1J-160L1PB1 V3 211.70 225.00 177.68 4.12 173.56 Pass: Major Risk Kuparuk 1J Pad 1J-160 1J-160L2 V2 211.70 225.00 177.68 4.12 173.56 Pass: Major Risk Kuparuk 1J Pad 1J-164 1J-164 V4 322.98 325.00 247.85 5.73 242.12 Pass: Major Risk Kuparuk 1J Pad 1J-164 1J-164L1 V2 322.98 325.00 247.85 5.60 242.25 Pass: Major Risk Kuparuk 1J Pad 1J-164 1J-164L2 V3 322.98 325.00 247.85 5.84 242.01 Pass: Major Risk Kuparuk 1J Pad 1J-164 1J-164L2PB1 V2 322.98 325.00 247.85 5.73 242.12 Pass: Major Risk Kuparuk 1J Pad Plan 1J-107 Plan 1J-107 L1 V1 Plan 5200.00 5200.00 0.00 0.00 0.00 FAIL: No Errors Kuparuk 1J Pad Plan 1J-109a 1J-109PB1 V5 28.00 28.00 60.03 No Offset Stations Kuparuk 1J Pad Plan 1J-109a Plan 1J-109a L1 V1 28.00 28.00 60.03 No Offset Stations Kuparuk 1J Pad Plan 1J-109a Plan 1J-109a V3 28.00 28.00 60.03 No Offset Stations Kuparuk 1J Pad Plan 1J-111 Plan 1J-111 V2 28.00 28.00 99.98 No Offset Stations Kuparuk 1J Pad Plan 1J-112 Kuparu k Plan 1J-112 W Lat V2 28.00 41.00 119.97 No Offset Stations Kuparuk 1J Pad Plan 1J-124 Plan 1J-124 L1 V1 Plan 263.00 275.00 360.18 5.18 355.00 Pass: Major Risk Kuparuk 1J Pad Plan 1J-124 Plan 1J-124 V3 Plan: 1 263.00 275.00 360.18 5.33 354.84 Pass: Major Risk Kuparuk 1J Pad Plan 1J-150 (Ugnu DiPlan 1J-UgnuDisposal V 29.00 28.00 189.00 No Offset Stations Kuparuk 1J Pad Plan 1J-L14(BO) Plan 1J-L14(BO) VO Pla 7981.87 6925.00 635.42 No Offset Errors Kuparuk 1J Pad Plan 1J-L15(BP) Plan 1J-L15 D Lateral 324.96 325.00 700.38 No Offset Errors Kuparuk 1J Pad Plan 1J-015(60) 1J-015 D Lateral VO PI 300.95 300.00 680.20 No Offset Errors Kuparuk 1J Pad Rig: 1J-122 Plan 1J-122 L1 V1 Plan 299.99 300.00 320.26 5.77 314.49 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-122 Plan 1J-122 L2 V1 Plan 299.99 300.00 320.26 5.77 314.49 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-122 Plan 1J-122 V4 Plan: 1 299.99 300.00 320.26 5.93 314.33 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-122 Rig 1J-122 VO 349.08 350.00 320.60 6.11 314.49 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-162 Plan 1J-162 L1 V4 Plan 287.99 300.00 216.49 5.64 210.85 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-162 Plan 1J-162 V8 Plan: 1 287.99 300.00 216.49 5.79 210.70 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-162 Rig 1J-162 V6 237.99 250.00 217.60 4.11 213.49 Pass: Major Risk Kuparuk 1J Pad WSP-02 WSP-02 V5 642.98 650.00 87.04 9.41 77.64 Pass: Major Risk Kuparuk 1J Pad WSP-03 WSP-03 V2 653.40 650.00 145.77 15.96 129.81 Pass: Major Risk Kuparuk 1J Pad WSP-04 WSP-04 V2 639.57 650.00 204.46 10.18 194.28 Pass: Major Risk Kuparuk 1J Pad WSP-05 WSP-05 V2 706.62 725.00 267.52 17.33 250.19 Pass: Major Risk ~Halliburton Company Anticollision Report Company: ConocoPhiliips Alaska Inc. - -- - Date: 7/17/2007 Time: 14:31:42 Yage: 3 Field: Reference Site: Kuparuk River Unit Kuparuk 1J Pad Co-ordinate(NE) Reference: Well: Plan 1J-107, True North Reference ~ti'ell: Plan 1J-107 Vertical (TVD) Reference: Doyon 141 (28+81) 109.0 ReferenceVl'ellpath: Plan 1J-107 Db: Oracle Summary _ __ - -- - - - - <---- ------- ------ _ Offset ~~'ellpath ---- --- --------> Reference Offset Ctr-Ctr \o-Go Allowable Site ~~'ell Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft Kuparuk 1J Pad WSP-15 WSP-15 V2 664.05 675.00 23.46 14.60 8.86 Pass: Major Risk Kuparuk 1J Pad WSP-1S WSP-1S V3 718.75 725.00 38.29 24.00 14.29 Pass: Major Risk ORIGINAL ~~ Conoco hillips ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan: 1J-107 L1 (wp05) 1/4 Mile Pool Scan Sperry Drilling Services July 17, 2007 Il~- HALLIBURTON Drilling and Formation Evaluation • • [:Incpct in POOI Closest A roach: -D ctr-ctr Distance. Reference Well: 1J-107 L1 w eas. Subsea De th Incl. Angle TRUE Azi. TVD 05 Plan Coords. - ASP N(+)/S(-) View VS E(+)/W(- 180°) Comments Offset Well: 1J-.105 Coords. - ASP Subsea N + IS - View VS Meas. () ( ) De th Incl. Angle TRUE Azi. ND E(+)/W(-) (180° Comments m is ance 188.9 17`, 2051.88 9.24 79.58 511.245 941769.9 64543.7 235.328 POOL Min Distance (1188.9 ft) in POOL (7647 - 12051.88 MD) to 1J-105 (3556 - 3713.8 TVDss) 1401 9.92 75.95 710.34 941676.7 63375.3 357.91 (1188.9 ft) in POOL (7647 - 12051.88 MD) to 1J-107 L1 (wp05) Plan (3556 - 3713.8 TVDss) S~ y*' ~°~`y r'" C7 7/1712007 10:35 AM POOL Summary Template 1J-107.x1s • • ORIGINAL ORIGINAL 1~-107 ~Ilrilling Hazards~0ummary (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) Surface Hole Hazard Risk Level Miti ation Strate Broach of Conductor. Low Monitor cellar continuously during interval Gas Hydrates Moderate Control drill, Reduced pump rates,. Reduced drilling fluid temperatures, Additions of Driltreat. Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out Interr~nediate Hole Hazard Risk Level Miti ation Strate Intermediate close Low The separation is vertical. Use geologic crossin with 1E-170 control to revent collision. Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Gas Hydrates Low y Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Driltreat. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud wei hf Abnormal Reservoir Low BOP training. and drills, increased mud Pressure wei ht. Lost circulation Low Reduced um rates mud rheolo LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out Production Hole Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low -~ Stripping drills, shut-in drills, increased mud wei ht. Stuck Pipe Low Good hole cleaning, PWD tools, hole o ever runs, decreased mud wei ht Lost Circulation Low Reduced um rates, mud rheolo ,LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out, backreamin i -~~ 1 1 \{ ~ ~ 1J-107 Drilling Hazards Summary tt...•11 ttt 11! ~Y! 4.. 7/30/2007 3:40:00 PM ~^ V J ._~ Inaubled Corduebr, 20" 94# K~S z 34" 0.312 WT +/- 80' Wellhead I Tubng I Tree: 13JR" x 41/7', 5,000 psI 13.318" Cas Shce, 68tl, Lr•80, BT et ~ 3543' MD, 2275' 7" x /8 Model B H Hanger GLM, Camco, 41/7' x 1" KBMG Bottom of Motor CerNellzer Centrelitt 418 HP KMHFER vdth F1~000 Pump Tubing String 4117' 12.8H, LA0.1BT-M 3.858" ID, 3.890" Drift ConocoPhillips West Sak Hybrid Producer 1 J-107 Dual Lateral Completion As Planned WP OS Window MD, 3658' TVD S11T BekerECP 'D' Sand Lateral 412" 11.811, BTC, L-80 Sbtted Liner bent pint shoe Sleeve T' X 9-518" ML P LlnerTopPacker 't Integrated RS prone Flex bck slips Liner Heryer I Pecker Assembly ~ +l- 8175' M D casing ®er,er Hupr.r imr. mu aoe„m.a may roe e. npoavr.a r<amb,a.a, in Whole a M n.t in.,rrorm or or ay mam •warorte or m-hwa, irowars pnorocws+na, ncorarq u iM cry ioreae.uoe rorea•.,a nriwr system nowkrcwn or M-alter hnenrr, rtlhaut vwMten wrmnron earn aexer H.p,. irc. ~-~o'~ .: Baker Oil Tools dui m~peciflcations 7"" X 9-5/5" HOOK Hanger Mainbore Drill: 7.00' Mainbare DreL with diverter. 6.25' Lateral Drill, no diverter or LEM: 8.15' Lateral DrR4 wl diverter, no LEM: 5.13' LatemlMlainbom Diverter OD: 8.50' 412" Guide Shoe 4-112" Casing Shoe, 11.8#, L-80 BTCM Set ~ 12051' MD, 3620' TVD 'B' Sand Lateral 5.117' 15.5 #, BTC, L-BD Slotted Liner 5-12" Eccentric ,Guide Shoe "~ - - . j4 5-112" Casing Shce, 15.5 # L-80 BTCM Set ~ 12100' M D, 9' ND 9-518" Casing Shoe, ~O.O~~L-80 BTC ~ 8550' MD, 3715' TV (84 deg inc) • CemCADEF Preliminary Job Design 13 3/8" Surface Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 15 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 7/30/2007 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com < TOC at Surface Previous Csg. < 20", 91.5# casing at 80' M D < Base of Permafrost at 1,672' MD (1,400' TVD) < Top of Tail at 2,743' MD 3 < 13 3/8", 72.0# casing in 16" OH TD at 3,543' MD (2,275' TVD) Mark of Schlumberger ~ 1 F' ±d ~~. Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 2,743' MD. Lead Slurry Minimum pump time: 320 min. (pump time plus 120 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.0190 ft3/ft x (80') x 1.00 (no excess) = 81.5 ft3 0.4206 ft3/ft x (1.672' - 80') x 3.50 (250% excess) = 2343.6 fta 0.4206 ft3/ft x (2743' - 1672') x 1.35 (35% excess) = 608.1 ft3 81.5 ft3 + 2343.6 ft3+ 608.1 ft3 = 3033.2 ft3 3033.2 ft3/ 4.45 ft3/sk = 681.6 sks Round up to 690 sks Have 320 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 230 min. (pump time plus 120 min.) DeepCRETE @ 12.0 ppg - 2.47 ft3/sk 0.4206 ft3lft x (3543' - 2743') x 1.35 (35% excess) = 454.2 ft3 0.8315 ft3/ft x 80' (Shoe Joint) = 66.5 ft3 454.2 ft3 + 66.5 ft3 = 520.7 ft3 520.7 ft3/ 2.47 ft3/sk = 210.8 sks Round up to 220 sks BHST = 53~, Estimated BHCT = 70`F. (BHST calculated using a gradient of 2.6`F/100 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Stage Time Cumulative Volume Time (bbl) (min) (mint CW 100 5 75 15.0 15.0 Drop Bottom Plug 15.0 30.0 MudPUSH II 6 75 12.5 42.5 Lead Slurry 6 547 91.2 133.7 Tail Slurry 6 97 16.2 149.9 Drop Top Plug 8.0 157.9 Water 5 20 4.0 161.9 Switch to Rig Pum s 5.0 166.9 Displacement 7 483 69.0 235.9 Slow Rate 3 10 3.3 239.2 MUD REMOVAL Recommended Mud Properties: 8.8 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv = 17-21, TY ~ 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. ORIGINAL CemCADEF Preliminary Job Design 9.625" Intermediate Casing Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 15 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 7/30/2007 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 276-1215 Mobile: (907) 952-0445 email: mtorrieC°3slb.com _w Previous Csg. < 13 3/8", 72.0# casing at 3,543' MD < Top of Tail at 5,024' MD i < 9 5/8", 40.0# casing in 12 1/4" OH TD at 8,550' MD (3,715' TVD) y 3 Volume Calculations and Cement Systems Volumes are based on 25% excess. Tail slurry is designed for 500' MD above Ugnu C formation - (Ugnu C at 5971' MD, TOC at 5471' MD, 3526' MD annular length). Tail Slurry Minimum thickening time: min. (Pump time plus 120 min.) DeepCRETE @ 12.5 ppg - 2.25 ft3/ft 0.3132 ft3/ft x 3526' x 1.25 (25% excess) = 1380.4 ft3 0.4257 ft3/ft x 80' (Shoe Joint) = 34.1 ft3 1380.4 ft3 + 34.1 ft3 = 1414.5 ft3 1414.5 ft3/ 2.25 ft3/sk = 628.7 sks Round up to 630 sks BHST = 90~, Estimated BHCT = 60~. (BHST calculated using a gradient of 2.6`f=/100 ft . below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Stage Time Cumulative Volume Time (bbll (min) (mint CW 100 5 50 10.0 10.0 Drop Bottom Plug 10.0 20.0 MudPUSH II 6 50 8.3 28.3 Tail Slurry 6 252 42.0 70.3 Drop Top Plug 10.0 80.3 Water 5 20 4.0 84.3 Switch to Rig Pum s 5.0 89.3 Displacement 7 612 87.4 176.7 Slow Rate 3 10 3.3 180.0 MUD REMOVAL Recommended Mud Properties: 8.9 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 11.0 ppg MudPUSH" II, Pv = 19-22, TY = 22-29 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. ORIG!NAI_ 6050000 6000000 5950000 5900000 5850000 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 400000 500000 600000 700000 800000 • TRANSMITTAL LETTER CHECKLIST WELL NAME ' ~ ' ~ ~ PTD# ~ ~~ ~ ~ ~ ~,,.~Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK. ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. , API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Compan~Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. ~,Company Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 7/13/2007 WELL PER IT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAK OIL- 490150 Well Name: KUPARI K RIV U WSAK 1J-107 Program DEV Well bare seg ^ PTD#:2071070 Company CONOCOPHILLIPS ALASKA INC Initial ClasslType DEV! PEND GeoArea 890 Unit 11160 OnlOff Shore On Annular Disposal ^ Administration 1 Permitfee attached - - - NA 2 Lease number appropriate - Yes 3 Uniquewell_nameandnumber- - ------- -- -- ---- -- Yes- -- -~ --- --- -- -- -- - - --- --------- -- - --- --- - 4 Well)ocatedin_a_defned-pool ___ ______________________- -.__-__-_ Yes_ _____Kupa[ukRiver,West_SakOilPool-490150,_governed_by-CO 4066---_-_--._____________, 5 WeIllocated proper distance from drilling unit-boundary_ . _ _ _ Yes - - - CO 406B, Rple 3:- n4 restrictions as to well spacing except that no-pay shall be opened in a well closer 6 WelUocated proper distance from other wells_ Yes - _ - - _ _ -than 500 feet to_a_n external_p_roperty/ine where ownership or landownership changes. - - - _ . _ _ _ _ _ _ 7 Sufficient acreage-available in_drilling unit- - _ _ _ _ _ _ Yes Well is mare than 500 feet from an external property line . . . ... . . .. . . . 8 If deviated, is_wellbore Plat_included - - - - - - - - - - Yes - - - 9 Operator only affected party- - - - - Yes - - - ----------------------- 10 Ope[atorhas.appropriate-lZOndin force ------ -- ----- ----- -- - Yes- ------- --- - - - - ------- -- -- -- -- -- - --------- -- - 11 Permit can be'issued_w_ithoutconservation order__________________ __________Yes_ ___...-.._______________________..__.._-..______________.-_--__-----_-__ Appr Date 12 Permit can be issued withoutadministtalive-approval__________-_-- _--_-__-__Yes_ ____---.---_____________________ SFD 8!8/2007 13 Can permit be approved before 15-day wait Yes 14 Well located within area and-strata authorized bylnjectionOrder#(put1O#in_comments)-(For_ Yes- --_...________________________________-_____________.._,----___-.__.-__ 15 All wells_within 114_mile area of review identified (For service well only)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ - _ - - _ _ _ _ _ _ - 16 Pre-produced injector; du[ation-of pr_ep[oduction Less than 3 months (For_serv ice well only) - , NA_ _ _ _ _ _ _ _ _ _ _ _ _ -- - -... - 17 Nonconyen,gasconformstoAS31,05,030Q.1.A),Q.2.A-D)____________ ____ _____ NA__ ____-__-.--_ -_____________________- -_. Engineering 18 Conductor string_provided _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Y_es _ _ - . - - _ - - _ . _ 19 Surface casingprQtects all_known USDWS _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - _ - _ _ _ _ _ _ NA_ _ _ _ _ _ - -All aquifers exempted,-40 CFR_147.102 (b)(3)._ - - . ..... - .. _ _ - - _ _ - - - - - _ - . - _ _ - - - - - . - 20 CMT vol- adequate to circul_ate_o_n conductor & sun` csg _ _ _ _ _ - .. _ - . - _ . - _Y_es _ _ _ _ _ _ - - . - . . - - - 21 CMTvol.adequatetotie-in-long string lo_surfcsq_______-----.-_ _____-No-- ------------ ------------------------------------------------------.__-.- 22 CMT_will coyer.all known_productive horizons_ - - - _ - _ _ _ - - - No_ Slatted liner completion planned. 23 Casing designs adequate for C,T,B&permafrost------ ---------- ---------- Yes- ----------- -------.------.-.---------- ------------- ---------- ----- 24 Adequate tankage_or reserve pit - - - _ - - _ _ _ _ - Y_es Rig isequipped with steel_pits.-No reserue_pitplanned: All waste to approved dis oral wells . - - A- ( ) 25 Ifa_re-drill,has_a10-403forabandonmentbe_enapproved____________ _____ ____ NA-- _____ ______________._----____-______ ___ _____-_____---.___-_-____.---_ 26 Adequate,wellbore separation_proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ Proximity analysis performed, Traveling cylinder path calculated, Gyros Aossible-in surface hole, _ - - _ _ - _ _ - 27 Ifdivecterrequired,doesitmeetregulations-__--______________ __________Yes- _______-_-_-_.-_--_-___..________ Appr ate 28 Drilling fluid- prpgram schematic & equip listadequate_ _ _ _ _ _ _ _ .. - . - . - - . - -Yes - - - Maximum expected fo[mation pressure 8.3_ EMW in zone.- Planned MW up t9 8,6_ppg in zone. - TE M 8!9/2007 29 _B_OPEs,_do they meet regulation Yes - - , / - - - ~fs,~4,/~ ~ " 30 BOPS-press rating appropriate; test to_(put psig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ - - MASP calculaled_a11191 psi. 3K stack arrange_menk and BOP.test planned._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ ~ 31 Choke-manifold complies w/API_ RP-53 (May $4)- - - - Yes - - - - - - 32 Work will occur without operation shutdown. _ _ _ - _ _ _ _ _ _ _ _ - - - - - - - - - - - - - - - Yes _ _ _ _ _ _ -- - 33 Is presence of H2$ gas probable- . - - - - - - - No_ H2S is rarely reported in-WS producticn. _ Mud_should preclude H2S on rig.- Rig has sensors and alarms. _ - _ _ _ _ 34 Mechanical_conditionofwellswithinAORverifled(ForserviceweUonly~____ _____ ____ NA- __-_--.-________________-____-_--__- _--_______________-__-___-___-._-- Geology 35 Permit can be issued w!o hydrogen sulfide measures _ - - _ Yes - ---- -- _ To date W Sak wells f[om.1J-Pad measure 0 ppm H2S, with the single exception of 1J-166 which measured 36 Data-presented on_ potential overpressure zones_ _ - _ _ _ - - Yes - - - 25 ppm H2S. This well will be >1 mi from 1J-166. Expected reservoirpressure is_$.4 ppg_E_MW, will be_ _ _ _ _ _ Appr Date 37 Seismic analysis of shallow gas_zones- .. - _ _ _ - _ _ - _ - . - - - - . NA - drilled with_8.4-$.Ei ppq mud. No shallow gas expected._ _Mudprogram notes use of 9,6 ppg SFD 8!812007 38 Seabed condition surue if off-shore - . _ _ _ _ NA_ mud if h grates are encountered, Miti ation measures discussed_ in Drillin _Hazards Summa 39 Contact name/phone for week_ly_progress reports [exploratory only] NA- - _ - - Geologic Engineering P Date: D ate D ate West Sak B sand roducer. This is the main wellbore for adual-lateral roduction well. SFD p p Commissioner: Commissioner: Co ion .G ~ ~~ ~/~~ ~J Q V //i4 • • • Well f-Iistory 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 infom~ation, information of this nature is accumulated at the end of the fife under APPENDIX. No special effort has been made to chronologically organize this category of information. 1j-107.tapx Sperry-Sun Drilling services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Dec 14 09:16:23 2007 Reel Header Service name .............LISTPE Date . ...................07/12/14 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS writing Library. scientific Technical services Tape Header service name .............LISTPE Date . ...................07/12/14 Origin ...................STs Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Physical EOF Comment Record TAPE HEADER west Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: Library. Scientific Technical Services 1J-107 500292336600 conocoPhillips Alaska, Inc. Sperry Drilling Services 14-DEC-07 MWD RUN 3 MWD RUN 4 Mw0005154790 Mw0005154790 T. CALVIN T. CALVIN D. GLADDEN D. GLADDEN MWD RUN 2 Mw0005154790 T. CALVIN D. GLADDEN SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 35 11N l0E 2148 2422 109.00 81.00 Page 1 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1j-107.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 13.375 3468.0 8.500 9.625 8721.0 ~~ 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUNS 2-4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), AND GEO-PILOT ROTARY STEERABLE BHA (GP). MWD RUN 4 ALSO INCLUDED AT-BIT GAMMA (ABG). 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-4 REPRESENT WELL 1J-107 WITH API#: 50-029-23366-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12073'MD/3656'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/14 Maximum Physical Record..65535 File Type. ............Lo Previous File Name.......STSLI6.000 comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 Page 2 1j-107.tapx FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 3439.5 12035.5 FET 3450.0 12028.0 RPD 3450.0 12028.0 RPS 3450.0 12028.0 RPM 3450.0 12028.0 RPx 3450.0 12028.0 ROP 3475.5 12073.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD BIT RUN NO MERGE TOP 2 3439.5 3 7749.0 4 8728.0 REMARKS: MERGED MAIN PASS. MERGE BASE 7749.0 8728.0 12073.5 Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Loging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name Service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 3439.5 12073.5 7756.5 17269 3439.5 12073.5 RPD MWD OHMM 0.7 2000 35.2389 17157 3450 12028 RPM MWD OHMM 0.07 2000 28.3495 17157 3450 12028 RPS MWD OHMM 0.06 2000 23.7167 17157 3450 12028 RPx MWD OHMM 3.28 2000 21.8697 17157 3450 12028 FET MWD HOUR 0.12 76.92 1.148 17157 3450 12028 GR MwD API 20.39 154.54 68.7021 17193 3439.5 12035.5 ROP MWD FT/H 0.02 1005.34 199.268 17197 3475.5 12073.5 Page 3 1j-107.tapx First Reading For Entire File..........3439.5 Last Reading For Entire File...........12073.5 File Trailer Service name... .......sTSLI6.001 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/14 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSL2B.002 Physical EOF File Header Service name... .......STSLI6.002 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/14 Maximum Physical Record..65535 File Type. ............Lo Previous File Name.......STSLI6.001 comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3439.5 7713.0 FET 3450.0 7705.5 RPX 3450.0 7705.5 RPS 3450.0 7705.5 RPM 3450.0 7705.5 RPD 3450.0 7705.5 OP 3475.5 7749.0 $ LOG HEADER DATA DATE LOGGED: 29-AUG-07 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7749.0 TOP LOG INTERVAL (FT): 3475.0 BOTTOM LOG INTERVAL (FT): 7749.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 65.7 MAXIMUM ANGLE: 82.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 242567 EWR4 ELECTROMAG. RESIS. 4 63122 Page 4 1j-107.tapx BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 3468.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 47.0 MUD PH: g,2 MUD CHLORIDES (PPM): 150000 FLUID LOSS (C3): 5.1 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 3.200 65.0 MUD AT MAX CIRCULATING TERMPERATURE : 2.000 108.0 MUD FILTRATE AT MT: 3.500 65.0 MUD CAKE AT MT: 3.100 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ....... ...0 Data Specification Block Type.. ...0 Logging Direction .............. ...DOwn Optical log depth units........ ...Feet Data Reference Point ........... ...undefin ed Frame Spacing....... ......... ...60 .lIN Max frames per record .......... ...undefin ed Absent value ................... ...-999 Depth units. .. .. .. .. ... Datum specification Block sub-type...0 Name service order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MwD020 OHMM 4 1 68 12 4 RPX MwD020 OHMM 4 1 68 16 5 FET MwD020 HOUR 4 1 68 20 6 GR MwD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name service Unit Min Max Mean Nsam Reading Reading DEPT FT 3439.5 7749 5594.25 8620 3439.5 7749 RPD MwD020 OHMM 5.99 2000 26.4692 8512 3450 7705.5 RPM MwD020 OHMM 3.79 2000 20.9825 8512 3450 7705.5 RPS MWD020 OHMM 0.06 266.1 15.9317 8512 3450 7705.5 RPX MWD020 OHMM 4.11 2000 14.0765 8512 3450 7705.5 FET MwD020 HOUR 0.13 76.92 0.913174 8512 3450 7705.5 GR MWD020 API 20.39 154.54 67.949 8548 3439.5 7713 Page 5 ~! 1j-107.tapx ROP MWD020 FT/H 0.02 716.72 226.525 8548 3475.5 First Reading For Entire File..........3439.5 Last Reading For Entire File...........7749 File Trailer Service name... .......STSLIB.002 Service Sub Level~Name... version Number.. ........1.0.0 Date of Generation.......07/12/14 Maximum Physical Record..65535 File TyL~e ................L0 Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 Service Sub Level~Name... version Number.. ........1.0.0 Date of Generation.......07/12/14 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 7706.0 8684.5 RPS 7706.0 8684.5 RPX 7706.0 8684.5 RPM 7706.0 8684.5 RPD 7706.0 8684.5 GR 7713.5 8692.0 ROP 7749.5 8728.0 LOG HEADER DATA DATE LOGGED: 30-AUG-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8728.0 TOP LOG INTERVAL (FT): 7749.0 BOTTOM LOG INTERVAL (FT): 8728.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 83.0 MAXIMUM ANGLE: 89.4 TOOL STRING (TOP TO BOTTOM) Page 6 7749 1j-107.tapx VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 242567 EWR4 ELECTROMAG. RESIS. 4 63122 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 12.250 3468.0 Polymer 9.10 45.0 9.3 110000 4.5 3.300 74.0 2.320 108.0 4.200 74.0 3.200 74.0 Name service order units size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MwD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MwD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7706 8728 8217 2045 7706 8728 RPD MwD030 OHMM 5.72 60.1 14.7729 1958 7706 8684.5 RPM MwD030 OHMM 5.31 71.05 14.2831 1958 7706 8684.5 RPS MWD030 OHMM 5.01 71.07 13.4669 1958 7706 8684.5 Page 7 ~ ~ 1j-107.tapx RPX MWD030 OHMM 4.72 60.21 11.5874 1958 7706 8684.5 FET MWD030 HOUR 0.16 18.48 1.44208 1958 7706 8684.5 GR MWD030 API 39.59 118.79 80.8284 1958 7713.5 8692 ROP MWD030 FT/H 0.54 385.42 157.549 1958 7749.5 8728 First Reading For Entire File..........7706 Last Reading For Entire File...........8728 File Trailer Service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/14 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLI6.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/14 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 8685.0 12028.0 RPx 8685.0 12028.0 RPD 8685.0 12028.0 FET 8685.0 12028.0 RPS 8685.0 12028.0 GR 8692.5 12035.5 ROP 8728.5 12073.5 LOG HEADER DATA DATE LOGGED: 04-SEP-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12073.0 TOP LOG INTERVAL (FT): 8728.0 BOTTOM LOG INTERVAL (FT): 12073.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.7 Page 8 • • 1j-107.tapx MAXIMUM ANGLE: 95.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132482 EWR4 ELECTROMAG. RESIS. 4 81390 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT); 8721.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 60.0 MUD PH: .Q MUD CHLORIDES (PPM): 22000 FLUID LOSS (C3): 12.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 126.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8685 12073.5 10379.3 6778 8685 12073.5 Page 9 ~ • 1j-107.tapx RPD MWD040 OHMM 0.7 2000 52.3945 6687 8685 12028 RPM MwD040 OHMM 0.07 2000 41.8459 6687 8685 12028 RPS MwD040 OHMM 2.77 2000 36.6274 6687 8685 12028 RPX MWD040 OHMM 3.28 2000 34.8006 6687 8685 12028 FET MwD040 HOUR 0.12 55.48 1.36081 6687 8685 12028 GR MWD040 API 34.78 119.17 66.114 6687 8692.5 12035.5 ROP MWD040 FT/H 3.23 1005.34 176.655 6691 8728.5 12073.5 First Reading For Entire File..........8685 Last Reading For Entire File...........12073.5 File Trailer Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/14 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.005 Physical EOF Tape Trailer service name .............LISTPE Date . ...................07/12/14 Origin ...................sTS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Reel Trailer Service name .............LISTPE Date . ...................07/12/14 Origin ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Physical EOF Physical EOF End Of LIS File Library. scientific Technical services Library. scientific Technical services Page 10