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Home My WebLink About207-1081. 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 12021'feet None feet true vertical 3589'feet None feet Effective Depth measured 12021'feet 7973'feet true vertical 3589'feet 3646'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 N/A 3646' 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 D Liner Scab Liner 8696' 3973' 3897' Casing 3717' 3589' 2-3/8" 8721' 12015' 11998' 3589' 3437' 108'Conductor Surface Intermediate 20" 13 77' measured TVD 9-5/8" 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 207-108 50-029-23366-60-00 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-107L1 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 ~~ ~ 322-701 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 SSSV: None Elliott Tuttle elliott.tuttle@conocophillips.com (907) 263-4742Senior RWO/CTD Engineer 8099-11970' Slotted Liner 3660-3589' 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 8:29 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 15:04:08-09'00' 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 Regg, James B (OGC) From:Brooks, Phoebe L (OGC) Sent:Tuesday, January 31, 2023 10:57 AM To:Coyne, Cleve Cc:Regg, James B (OGC) Subject:RE: Nabors CDR3 01-02-23 BOP Test Attachments:Nabors CDR3AC 01-02-23 Revised.xlsx Cleve, Attached is a revised report changing the Well Name to reflect KRU 1J‐107L1 based on sundry # 322‐701 and adding PTD #2071080. Please update your copy or let me know if you disagree. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907‐793‐1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Coyne, Cleve <Cleve.Coyne@nabors.com> Sent: Monday, January 2, 2023 5:21 AM To: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov>; ncdr3cm@conocophillips.com; Henson, James <Jim.Henson@nabors.com>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Subject: Nabors CDR3 01‐02‐23 BOP Test Cleve Z Coyne CDR3 Rig Manager Nabors Alaska Drilling Inc. Direct 907‐670‐6082 Mobile 907‐315‐2053 cleve.coyne@nabors.com ******************************* NABORS EMAIL NOTICE - This transmission may be strictly proprietary and confidential. If you are not the intended recipient, reading, disclosing, copying, distributing or using the contents of this transmission is prohibited. If you have CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. KRU 1J-107L1PTD 2071080 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:CDR3AC DATE:1/2/23 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2071080 Sundry #322-701 Operation:Drilling:Workover:X Explor.: Test:Initial:X Weekly:Bi-Weekly:Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:440 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0 NA Permit On Location P Hazard Sec.P Lower Kelly 0 NA Standing Order Posted P Misc.NA Ball Type 2 P Test Fluid Water Inside BOP 0 NA FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 2 5/8"P Trip Tank NA NA Annular Preventer 1 7 1/16"P Pit Level Indicators P P #1 Rams 1 Blind Shear P Flow Indicator P P #2 Rams 1 2 5/8" Combi P Meth Gas Detector P P #3 Rams 1 3" Combi P H2S Gas Detector P P #4 Rams 1 2 3/8" Combi P MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 2 1/16"P Time/Pressure Test Result HCR Valves 2 2 1/16"FP System Pressure (psi)3000 P Kill Line Valves 5 2 1/16"FP Pressure After Closure (psi)2350 P Check Valve 0 NA 200 psi Attained (sec)21 P BOP Misc 3 3 1/8"P Full Pressure Attained (sec)44 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):4 @ 1825 P No. Valves 12 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 17 P #1 Rams 6 P Coiled Tubing Only:#2 Rams 5 P Inside Reel valves 1 P #3 Rams 6 P #4 Rams 4 P Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:3 Test Time:10.0 HCR Choke 2 P Repair or replacement of equipment will be made within Same days. HCR Kill 2 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 12-30-22 @ 16:38 Waived By Test Start Date/Time:1/1/2023 15:00 (date)(time)Witness Test Finish Date/Time:1/2/2023 1:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Adam Earl Nabors Pit level alarms tested, LEL and H2S alarms tested. Verified flow through Micromotion. Swab 2 F/P, grease, retest good. Romeo 3 F/P, grease, retest good. Bravo 5 F/P, grease, retest good. (Test equipment during test 7, replaced & continued testing.) CZ Coyne/R Beard Conoco Phillips Alaska C.Erdman/J Newell KRU 1J-107L1 Test Pressure (psi): dr3.toolpusher@conocophillips.co 3.companyman@conocophillips.c Form 10-424 (Revised 08/2022)2023-0102_BOP_Nabors_CDR3AC_KRU_1J-107L1           J. Regg; 5/24/2023 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): 12021 12013 440 N/A N/A Casing Collapse Conductor Surface Intermediate Production Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): N/A 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 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 Tubing Grade:Tubing MD (ft): N/A Perforation Depth TVD (ft):Tubing Size: N/A N/A 12/28/2022 N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL25661, ADL25662 207-108 P.O. Box 100360 Anchorage, AK 99510-0360 50-029-23366-60 ConocoPhillips Alaska, Inc N/A KRU 1J-107L1 Proposed Pools: TVD Burst Kuparuk River Field/West Sak Oil Pool PRESENT WELL CONDITION SUMMARY 20 3589 MD 2275 3717 3589 3468 8721 12015 108 108 3589 Perforation Depth MD (ft): 4 1/23973 8696 Length Size 77 13.375 9.625 3437 N/A N/A N/A 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 1:35 pm, Dec 14, 2022 322-701 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 12:00:53-09'00' Foxit PDF Editor Version: 12.0.1 Elliott Tuttle -00 DLB DLB 12/14/2022VTL 12/16/2022 X BOP test to 2500 psig DSR-12/14/22 X X 10-404 GCW 12/16/22 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2022.12.16 09:39:27 -09'00' RBDMS JSB 122222 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 12:01:56-09'00' 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 D LINER SLOTTED OD (in) 4 1/2 ID (in) 3.476 Top (ftKB) 8,041.8 Set Depth (ftKB) 12,015.3 Set Depth (TVD) … 3,588.9 Wt/Len (l… 11.60 Grade L-80 Top Thread IBT-M Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 8,041.8 3,654.4 83.27 HANGER Inside Baker "B" Flanged Hook Hanger 7" X 9-5/8" ( Inside Csg) 7.510 8,063.0 3,656.8 83.82 HANGER Outside Baker "B" Flanged Hook Hanger 7" X 9-5/8" ( Outside Csg) 6.290 8,069.2 3,657.4 84.03 XO BUSHING Cross Over Bushing 7"X 5.5" BTC box X pin 4.920 8,070.6 3,657.6 84.08 XO BUSHING Cross Over Bushing 5.5"X 4.5" BTC box X pin 3.930 8,083.3 3,658.8 84.52 SWIVEL Baker Csg swivel 4.5" 12.6# L80 IBT Box X Pin 3.950 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Zone Date Shot Dens (shots/f t)Type Com 8,099.0 11,970.0 3,660.3 3,589.4 WS D, 1J- 107L1 9/11/2007 32.0 SLOTS 100% slotted liner, 2.5" x .125" in 4 circumferential rows/ft 3" centers staggered 18 deg 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-107L1, 5/17/2016 8:40:57 AM Vertical schematic (actual) D LINER SLOTTED; 8,041.8- 12,015.3 SLOTS; 8,099.0-11,970.0 D LINER LEM; 7,973.4-8,207.8 INTERMEDIATE; 24.8-8,721.0 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: WORKOVER Last Mod By lehallf End Date 5/10/2016 KUP PROD KB-Grd (ft) 32.29 Rig Release Date 9/15/2007 Annotation Last WO: End Date 5/7/2016 1J-107L1 H2S (ppm) 75 Date 8/11/2015 ... TD Act Btm (ftKB) 12,021.0 Well Attributes Wellbore API/UWI 500292336660 Field Name WEST SAK Wellbore Status PROD Max Angle & MD Incl (°) 93.91 MD (ftKB) 9,386.63 1J-107L1, 5/17/2016 8:40:58 AM Vertical schematic (actual) D LINER SLOTTED; 8,041.8- 12,015.3 SLOTS; 8,099.0-11,970.0 D LINER LEM; 7,973.4-8,207.8 INTERMEDIATE; 24.8-8,721.0 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 Annotation End Date 5/7/2016 1J-107L1 ... 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\2022-12-10_15891_KRU_1J-107L1_JewelryLog_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 15891 KRU 1J-107L1 50-029-23366-60 Jewelry Log 10-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 1:19 pm, Dec 15, 2022 207-108 T37374 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.12.15 13:20:39 -09'00' • ~ ~ ~~ ~.~~ ~. w~:: ~' a ~ °' t =~:~' z :~ ~ ~ ~ ~.`.~ ~: MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL 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 o£ 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 I-~r51~ '~ton.com MAY 2 ~ ~QG9 Date: QED BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 ~.. ,~'• ~~~~:~a .~11F°~ ° `~ ~D~~ ik ~l,~ Signed: ~U ~~~ ~o~ ~ ~~~/ ~~~~~~~ • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION ~P~ 2 ~ 2.09 Alaska Oil ~t Gas Cores. Commission REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. Operations Pertormed: Abandon ^ Repair Well Q Plug Perforations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing Q Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhilllps Alaska, InC. Development ~ • Exploratory ^ 207-108 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23366-60 7. KB Elevation (ft): 9. Well Name and Number: RKB 81' 1J-107L1 8. Property Designation: 10. Field/Pool(s): ADL 25661, 25662 Kuparuk River Field /West Sak Oil Pooi 11. Present Well Condition Summary: Total Depth measured 12021' feet true vertical 3589' feet Plugs (measured) Effective Depth measured 12013' feet Junk (measured) true vertical 3589' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 20" x 34" 108' 108' SURFACE 3440' 13-3/8" 3468' 2275' INTERMEDIATE 8693' 9.625" 8721' 3716' PRODUCTION 3973' 4.5" 12015' 3589' Perforation depth: Measured depth: slotted liner from 8099'-1 1970' true vertical depth: 3660'-3589' .f~ , • . •• ~ ~ ~~~ ;: "~ ~'; y ` Tubing (size, grade, and measured depth) tbg in main wellbore, , MD. Packers &SSSV (type & measured depth) no packer no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 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 ^~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: OilO 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 Br cke Title Wells Engineer ~ / / ~ ~ ~ ~~ Signature Phone: 265-6845 Date / 9 ( i / Pre aced b Sharon Allsu -Drake 263-461 Form 10-404 Revised 04!2006 Submit Original Onl ~%,~-~ ' 1J-174 (PTD #207-143), 1J-137 (PTD#206-108) Multi-lat drawings Maunder, Thomas E (DOA) From: Packer, Brett 8 [J.Brett.Packer@conocophillips.comJ Sent: Wednesday, Apri! 29, 2009 3:40 PM To: Maunder, Thomas E (DOA) Subject: RE: 1J-107 (PTD#207-107) Muiti-lat drawing Attachments: Visio-1J-107 HBB DLP_ESP As Completed WO 09.pdf Here you go! ~~ . ~'i+g dt; tiUelCt ~W6~ner Engineer 'Wor>F,# (90T) 265-6845 Ccl1'~ (907) 230-8377 Page 1 of 1 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.govJ Sent: Wednesday, April 29, 2.009 1:50 PM To: Packer, Brett B Subject: RE: 1J-174 (PTD #207-143), 1J-137 (PTD#206-108) Multi-lat drawings shanks much Brett. Do you have one for 1 J-107 {207-107) as well? Tom Maunder, PE AOGCC From: Packer, Brett B [mailto:J.BrettPacker@rnnocophillips.com] Sent: Wednesday, April 29, 2009 1:48 PM To: Maunder, Thomas E {DOA) Subject: 1J-174 (PTD #207-143), 1J-137 (PTD#206-108) Multi-lat drawings Tom, Attached are the updated profile views for these two wells. «Visio-1 J-137 HB DLP As-Completed-WO 09 .pdf» «Visio-1 J-174 RAM HB DLP as completed_WO-09.pdfl> ~~~ ~DrilCsg e$'Wa!?s 'W6ti~' (10T) 265-6845 Cea~ (907) 23U-8317 4i3oizoo9 Insulated Conductor, 20" 94# K-55 x 34" 0.312 WT +/- 80' Wellhead 1 Tubing I Tree: 13-3I8" x 4-112", 5,000 psi ConoeoPhi I I i ps Tubing String 41/2" 12.6#, L-80, IBT-M 3.958" ID, 3.890" Drift West Sak Hybrid Producer 1J-107 2775'MD-GLM, Cameo, 4112"x1"KBMG Dual Lateral Completion WO 09 / 6891' MD- GLM, Cameo, 4.1/Y' x 1" KBMG 3467' MD - 13-318" Casing Shoe, 68#, L-80, BTC set, 2275' TVD ~~~~,°.. ~ 7900' MD -Bottom of Motor Centralizer, Centralift TTC-ESP 7973' M D - 3.562" DB Nippk Orienting Pro(ik Automatic Alignment of LEM - Positive Latching Collet Indicates Correct Location Seal Bore (or Lateral Isolation - 3.688" ID ~' Access Window Positive Lateral Access Via Thru-Tubing Diverter 8169' MD - 7" X 9.518" ML ZXP Liner Top Paeker with integrated RS proTile and Flexlock slips 8124' MD - 3.562" DB Nipple \ 8197' MD -Casing Sealbore Seal Bore for Lateral Receptacle 20' x 4.75" ID Isoktion - 3.688" ID Isoktion Seal Asembly 4.75" Seal OD 3.875" Seal ID 2' Length =l Baker Hughes 2~~]. This document may not be reproduced or tlisMbmetl, In wkok or T pan, n any /orm er by any means ekctronlc or me[hanical, inclutling photocopying, r cording, o, by any inr~rmatinn sto,age and retrkval ayatem now known or hereaner invented, wlthonl written permicabn Irom Baker Hughes Inc. - 4-112" Casing Shoe, 11.6#, L-80 BTCM, 3588' 8208' MD -Bottom of Seal Assembly ,B, Sand Lateral 4.75" Seal OD, 3.675" ID 5-t12" 15.5 #, BTC, L-80 Slotted Liner 5-112" Eccentric ~ ~ .Guide Shoe 7" X 9-518" HOOK Hanger Mainbore Drift: 7.00" Mainbore Drift, with diverter. 6.25" Lateral Drift, no diverter or LEM: 6.28" .ateral Drift, w/ diverter, no LEM: 5.12" LateragMainbore Diverter OD: 8.50" 4-1/2" Lateral Entry Module Mainbore Drift: 3.68" rinbore Drift, wl isolation sleeve: 2.50" Lateral Drift, wl coil diverter: 3.00" OD of Diverter and Sleeve:+/" 3.60" Diverter and Sleeve Length: +1-19' 11792' MD - 5-112" Casing Shoe, 15.5 #, L-80 BTCM, 3661' TVD 8721' MD - 9-518" Casing Shoe, 40.0#, L-80 BTC, 3716' TVD (89 deg inc) 19' 2007 West 6ak Dual taterel Completion -Protlueer February 12, 2009 prawn av~ Ian Toomey a"iabn ao.: _ Assembly 9-5/8" TorqueMaster Packer or deep 8006' MD - 3.750" DB Nipple 'D' Sand Lateral - 6034' MD -Lateral Entry Module (LEM) Orienting Profile 804T MD - D Sand Window, 3655' TVD (83 deg) \'~~ 41/2" 11.6#, BTC, L-BO Slotted Liner \\\~~ ! .4112" Guide Shoe 8042' MD- T' x 9-518" Model HOOK Hanger As Completed a-ti Raker Oil Tnnls With Diverters and Isolation Lateral Aceess Diverter Lateral lsolatian Diverter G6 Running Tool String Installed Installed 13.00" Lateral Drin) (2.50" ID Mainbor e Drift) 'GS' Profile for Coll Connector i -Running/Retrieving ,..mil j 1 (1.00' Length) Snap InlSnap Out r Hack Pressure Valve ~' Positive Locating ~~ Colkt (t.60' Length) Lateral Isolation ~' .= Flow-Thru Swivel Seals (1.26' Length) Lateral Diverter f Hydraulic r Ramp ' 1 Izdationl Malnbore~' ( 60' Length) Diverter Sleeve GS Spear ' Lateral Isdatbn `~ (1.50 Length) 6.65 h Approx. Seals OAL' • CanacoPhillips ~' ... :ll,~., .r. In~~ t1ANGER. 23 CONDUCTOR, za-ma EsP MANDREL, 2.7]5 SURFACE. 30-3 668 ESP MANDREL. - - 6.684 DisCarge_ _. _-_ (ESP), 7.775 ESP INTAKE, -_ __ __. __ ],856 ESP MOTOR. ],8]9 ~` ESP GAUGE, __ ],896 Cenaafzer. _ 7.898 D-SAND LEM. ],9]3-8.208 ~_ ~'q 12,0]3 KUP Yell Attributes lellbore APIIU WI Fieltl Nam. 500292336660 WEST SF Date 4 1 /2 I 3.992 I 8,041.8 I 12, 01 1 J-107L1 32.29 9/15/2007 (End Date 11 4/16/2009 ... 64ing ... String Top Thrd L-80 IBT-M Top Depth I I i (ND) Top Intl Top (ftK8) (RKB) (°) Item Description Comment ID (in) 8,041.8 3,654.3 83 09 HANGER i Baker "B" Flanged Hook Hanger 7" X 9-5/8" (Inside Csg) ii 7.510 I 8,063-0 3,656) 83.82 HANGER ' ,Baker "B" Flanged Hook Hanger 7" X 9-5/8" (Outside Csg) 'i 6.290 8,070.6 3,657 4 84.08 XO ~ Cross Over Bushing 6.5"X 4S" BTC box X pin 3.930 8,083.3 3,658.4 84.52 SWIVEL ( Baker Csg swivel 4.6" 12.61f L80 IBT Box X Pin 3.950 Perforations & Slots ' ~~, Shot I ' Top (TVD) Bim (TVD) Dens j Bhn (ftK8) (ftK8) (ftK8) Zona ' Date (sh-~ Type Comment Top LftKB) 8,099 11,970 3 659.5 3,589.4 WS D, 1 J-107L7 9/11/2007 32.0 SLOTS 100 o slotted liner, 25" x .125" in 4 circumferential rows/ft 3" centers '. ~I staggered 18 deg 'Notes: General 8 Safet End Date Annotation _ '~, 9/15/2007 NOTE: MULTI-LATERAL WELL- iJ-107 (BSAND), 1J-107L7 (D-SAND) 8/23/2008 NOl E: VIEW SCHEMATIC w/Alaska Schematic9.0 Mandrel Details -- - -. '~ToP Depth ToP POrt (TVD) Incl OD Valve Latch Size 7R0 Run Stn Top (ftK8) lftKel (°) Make Model (in) Serv Type Type (iN (psi) Run Date Comm ... 1 2,7754, 2,010./ 64.58 Camco KBMG 1 ESP SOV BK-5 0.0001 2,000.0 3/10/2009 2 .6,884.2 3,452.2 73.60 Camco KBMG 1 ESP DMY BK-5 0.000; 00 3/4/2009 - • • ConocoPhillips Time Log. & Summary t1'e//v7ew Web ReAOrting Re ~ o ~,,} 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 Logs ~ Date From To Dur S. Depth__ E_ Depth Phase Code Subcode T Commen_t_ 2/25/2009 za 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 1J Pad. Spot rig over well. Accept Nordic Rig 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 WELCTL 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 WELCTL 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 WELCTL 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 jnt/ 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'. __ Page 1 of fi r~ Time Logs Date From To Dur S. De th E. Depth 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 seawaterdown 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 throu 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 Testing BOPE 250/2500 psi. 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 tbg, unseated hanger 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 the tubing even after pumping 100 bl / hr down the IA. Viscosity 150 bbl of SW w/6% KCL with Flo-Visc. Pump 100 bbl down the IA. Observed well, gas sto ed comin to surface Page 2 of 6 r~ r~ -Time Logs __ Date From To Dur S. Depth E_De th Phase Code Subcode T Comment ___ 11:00 15:00 4.00 450 0 COMPZ RPCOM PULD P POOH with tubing to ESP completion. RD and LD ESP completion. 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 strip 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 RPGOM 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 dropping, 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. Prepare floor to run DP in hole as a kill strip . Page 3 of 6 Time Logs Date From To Dur S De th E. De th Phase Cade 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% KCL down 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 strn . 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 Cont 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' Page 4 of 6 Time Logs Date From To Dur S. De th E. De th 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 upon workstring to 2,$00 psi to activate and set TorqueMaster 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 IA with charge pump, close rams, RU and test IA x TorqueMaster at 2,500 psi for 5 minutes on chart. Good test. Bled off IA, ulled settin toots 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 completion. 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 xoverfitake 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 pump, test packoff to 1,000 psi 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. Page 5 of B l~ ~~ Time Lo s 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. Pull two-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 tbg and 155 bbls 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 Rig 3 released from well 1J-107, at 04:00 hrs 3/5/2009 Page 6 of 8 DATA SUBMITTAL COMPLIANCE REPORT 11/21 /2008 Permit to Drill 2071080 Well Name/No. KUPARUK RIV U WSAK 1J-107L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23366-60-00 MD 12021 TVD 3589 Completion Date 9/14/2007 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: (data taken from Logs Portion of Master Well Oata Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Ty~ Med/Frmt Number Name Scale Media No Start Stop CH Received Comments .~D D Asc Directional Survey 28 12021 Open 12/3/2007 pt Directional Survey 28 12021 Open 12/3/2007 t 15805 LIS Verification 3439 12021 Open 12/28/2007 LIS Veri, GR, RPS, RPM, FET, RPD, ROP C Lis 15805 Induction/Resistivity 3439 12021 Open 12/28/2007 LIS Veri, GR, RPS, RPM, FET, RPD, ROP Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y ~ Daily History Received? Chips Received? ~P4- Formation Tops ~N Analysis ~"T'1~ Received? Comments: Compliance Reviewed By: Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other Q 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: COCIOCOPhIIIIpS Alaska, It1C. Development^ Exploratory ^ 207-108 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23366-60 7. KB Elevation (ft): 9. Well Name and Number: RKB 109' 1J-107L1 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 12021' feet true vertical 3589' feet Plugs (measured) Effective Depth measured 12013 feet Junk (measured) true vertical 3589 feet Casing Length Size MD ND Burst Collapse CONDUCTOR 80' 20" 108' 108' SURFACE 3440' 13-3/8" 3468' 2275' INTERMEDIATE 8693' 9-5/8" 8721' 3716' L1-WINDOW 10' 9-5/8" 8057' 3656' SLOTTED LINER 3973' 4-1/2" 12015 3589' Perforation depth: Measured depth: 8099' - 11970' true vertical depth: 3660' - 3589' 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: OilO 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: N/A contact Bob ChristensenNacant Printed Name o ert D. Christense Title Production Engineering Specialist Signature Phone: 659-7535 Date ~D 3 ~~~ Form 10-404 Revised 04/2004 _ „~~C/t' Submit Original Only • 1J-107L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/26/08 09/27/08 09/29/08 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. 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 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. 10/14/08 MADE TWO ATTEMPTS AT FISHING LOWER SECTION OF ESP PUMP, BOTH RUNS 10/16/08 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. 10/24/08 ELINE WELTEC TRACTOR W/ EXPRO VIDEO. SECOND ATTEMPT AT CAPTURING 10/24/08 Well Returned to production as a gas lifted oil producer ConocoPhillips A:. {.:,.I. I~ ... W II : -1J-107L7 1 2:45:13 PM N - I HANGER, 23 2e-toe GAS LIFT, 2,190 SURFACE. 303.465 ESP DISHCARGE, 7,752 PUMP, 7,754 ESP INTAKE, 7.828 - SEAL ASSy, 7,840 ESP MOTOR, 7,556 IIIJJJ ESP GAUGE, 7,870 CENTRALIZER, 7,572 D-SAND WINDOW, 8,047-8,057 NTERMEDIATE, 258,721 e slors, 8,099-11,970 0.SAND LINER SLOTTED, 8,042-12,015 TD (iJ-107L1), 12,021 KUP 1J-107L1 Well Attributes Wellbore APIAIW I Field Name Well Statua ProdMJ Well Typo Incl (°) MD (RKB) TD (max) (R... 500292336600 WESTSAK PROD 96.49 9,103.81 12,073.0 Comment H23 (ppm) Data Annotation End Date NB-Grd (RJ Rig Release Date SSSV: NONE 0 7/1/2008 Last WO: 32.29 9/15/2007 Annotation Last Tag: Depth (RKB) E ntl Data Annotation Rev Reason: FORMAT UPDATE Entl Date 10/4/2008 Casin Strin s Casing Description D-SAND LINER SLOTTED String 0... 4 1/2 String ID . 4.000 .. Top (RKB) S 8,041.8 et Depth (f... 12,015.3 Set Deplh (TVD) ... 3,588.9 String WL.. 11.60 String Or... L-80 String Top ihm BTC-m Liner Details Top (RKB) Top Depth INDI (RKB) lop Incl (°) Item Deacrlptlo n Comment ID (InJ 8,041.8 3,654.3 83.09 INSIDE HANGER Baker "B" Flanged Hook Hanger 7" X 9-518" (Inside Csg) 7.510 8,063.0 3,656.7 83.82 OUTSIDE HANGER Baker "B" Flanged Hook Hanger 7" X 9-5/8" (Outside Csg) 6.290 8,069.2 3,657.3 84.03 XO BUSHING Cross Over Bushing T'X 5.5" BTC box X pin 4.920 8,070.6 3,657.4 84.08 XO BUSHING Cross Over Bushing 5.5"X 4.5" BTC box X pin 3.930 8,083.3 3,658.4 84.52 SWIVEL BakerCsg swivel 4.5" 12.6# L80 IBT Box X Pin 3.950 Perforations Top (RNB) Btm (RNB) Top (TVD) (RKB) etm (ND) (RNB) Zone Date snot Dens (sh.° Type Comment 8,099.0 11,970.0 3,659.5 3,589.4 WS D, 1J-107L7 9/11Y2007 32.0 SLOTS 100%slofted liner, 2.5"x.125" in 4 circumferential rows/ft 3" centers staggered 18 deg Notes: General b Sa End Date Annomtlon 9/15/2007 NOTE: MULTI-LATERAL WELL- 1J-107 (BSAND), 1J-10711 (0.SAND) 8123/2008 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 Mandrel Details Stn To RKB Top Depth (ND) (RNs) Top Incl (`) Make Motlel OD (inl Ssrv VaWe Type Latch Type Port Sire (Inl TRO RUn (psi) Comment Run Data 1 2,190.0 1,791.6 66.83 CAMCO K BMG 1 Gas Lift SOV BKS 0 2,000.0 7/2212008 • Conoco~illips January 29, 2008 T. Maunder State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7~' Avenue Suite 100 Anchorage, Alaska 99501 Subject: Additional Well Summaries Dear Mr. Maunder: . ~• Eggemeyer Engineering Leader Drilling & wells P. O. Box 100380 And-orage, AIC 99510-0380 Phone: 907-285-6049 ~~ _; { ~; ''~ ~~ _~~. J c`~- i~ ConocoPhillips Alaska, Inc. submits the attached well summaries for wells 3@-~-1; ...,~ . ~ ~ ,,. ~ ~ .,~ ~ , ~ ". .~ ~ .~ ~~~ ~ A ~ .~.,~ and ~.~~'Et.1 you requested. 1-~ , ~ ...,.,. ,, .., .., 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 2fi5-6049. Sincerely, -~..~.~ . Eggemeyer Engineering Team Leader CPA! Drilling JE/skad a ca$v a va a Maunder, Thomas E (DOA) Prom: Maunder, Thomas E (DOA} Sent: Thursday, December 13, 2007 2:33 PM To: 'Eggemeyer, Jerome C.' Subject: 1J-107 (207-107), 1.1-107L1 (207-108) and CD4-07 (207-118} Jerome, Further to our discussions, wou~ you please provide the deta~ed operations rreeports #x the fong well (s)/operations. 1J-1071207-107) One copy of the fuH summary (-107 & -107t_1) 1 J-107t_1 {207-108) Summary for lateral (-107[_1 } onty CD4-07 (207-118) One cePY of the summary Thanks in advance. Cali or message with any questions. Tom Maunder, PE AOGCC 12/13/20U7 ConocoPhillips December 12, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 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, R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad ~' • STATE OF ALASKA • ~~~~ V ~~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~ ~ ~ 2~~~ ~r~~ o'f WELL COMPLETION OR RECOMPLETION REPOR . ND LOG ez.~. 1a. Well Status: Oil ^ Gas Plugged ^ Abandoned ^ Suspended ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: I IA., ' Developm~C~jage Exploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, lnc. 5. Date Comp., Susp., ~ orAband.: September 14, 2007 12. Permit to Drill Number: 207-108 % 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: September 6, 2007 13. API Number. 50-029-23366-60 4a. Location of Well (Governmental Section): Surface: 3132' FNL, 2422' FEL, Sec. 35, T11N, R10E, UM 7. Date TD Reached: September 8, 2007 14. Well Name and Number: 1J-107L1 ° Top of Productive Horizon: 2443' FSL, 2321' 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: 2085' FNL, 1986' FEL, Sec. 1, T10N, R10E, UM 9. Plug Back Depth (MD + TVD): ~ 12013' MD / 3589' TVD West Sak Oil Pool ' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558785 y- 5945960, Zone- 4 10. Total Depth (MD + TVD): - 12021' MD / 3589' TVD ~ 16. Property Designation: ADL 25661, 25662 ~ TPI: x- 564164 y- 5946299 Zone- 4 Total Depth: x- 564539 - 5941775 Zone- 4 11. SSSV Depth (MD + TVD): 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 (TVD): not available 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): top of window @ 8047' GR/Res 22• CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 34" 78.6# H-40 28' 108' 28' 108' 42" 350 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 4.5" 11.6# L-80 8042' 12015' 3654' 3589' 6.75" slotted liner 23. Open to production or injection? Yes Q No If Yes, list each 24. TUBING RECORD Interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET tubing in main wellbore none slotted liner from 8099'-12015' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNTAND 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 1 J-107 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+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. ~(_. NONE a , ' 9 i t N i.: Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE 1~~,~ •~ • P9. c~ ,.~ i~~~~ 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ~ Yes Q No If yes, list intervals and formations tested, Permafrost -Top sufface SUrfaCe .briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom nOt available not available needed, and submit detailed test inforrnation 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' N/A Formation at total depth: West Sak D 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 Na Rand Thomas Title: Drilling Team Leader lL/tZ~o'~ ~ Signature ne ~ Date z6r 6 ~ 3 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 i ConocoPhillips November 28, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7~' Avenue Suite 100 Anchorage, Alaska 99501 Randy Thamas Kuparuk Drilkng Team Leader Drilling ~ Weft P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ac~~ -~o Subject: Well Completion Reports for 1 J-107 and 1 J-107L1 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations of the Kuparuk West Sak multi-lateral 1 J-107 and 1 J- - 107L1. If you have any questions regarding this matter, please contact me at 265-6830 or Pat Reilly at 265-6048. Sincerely, ~~- __a R. Thos Kuparuk Drilling Team Leader CPAI Dri{ling RT/skad {¢'~~~CI V C.L! STATE OF ALASKA ~ ~~~ ~ ~ ~~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ~ ~, ~ ()r„ffiss;~~s WELL COMPLETION OR RECOMPLETION REP' ~~L~~ 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 ^/ Exploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., i ora,band.: September 14, 2007 12. Permit to Drill Number: 207-108 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: September 6, 2007 13. API Number: 50-029-23366-60 4a. Location of Well (Governmental Section): Surface: 3132' FNL, 2422' FEL, Sec. 35, T11N, R10E, UM ~ 7. Date TD Reached: September 8, 2007 14. Well Name and Number: 1J-107L1 Top of Productive Horizon: 2443' FSL, 2321' 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: 2085' FNL, 1986' FEL, Sec. 1, T10N, R10E, UM 9. Plug Back Depth (MD + ND): 12013' MD / 3589' 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): , 12021' MD / 3589' ND 16. Property Designation: ADL 25661, 25662 TPI: x- 564164 y- 5946299 Zone- 4 Total Depth: x- 564539 - 5941775 ~ Zone- 4 11. SSSV Depth (MD + ND): 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): 2260' ND 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): top of window @ 8047' GR/Res 3b5S ~rD~ 22. CASING, LINER AND CEMENTING RECORD /t ~//• 4 SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 34" 78.6# H-40 28' 108' 28' 108' 42" 350 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' 660 sx DeepCRETE 4.5" 11.6# L-80 8042' 12015' 3654' 3589' 6.75" slotted liner 23. Open to production or injection? Yes Q 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 tubing in main wellbore none slotted liner from 8099'-12015' 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-107 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+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. ~, ?~; ~'Fl~id-~ ~rA F 6 NONE ~~ ~~F' ~ ?00~ l . Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE q ~ ~ ~ i?~~ ~.~ /Z~//.mom ORIGINAL ~,z~~~,~ ~~ ~ 1 28. GEOLOGIC MARKERS (List all formations and mar ers 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 12021' 3659' West Sak B 12021' 3659' West Sak A4 12021' 3659' N/A West Sak A3 12021' 3659' West Sak A2 12021' 3659' Formation at total depth: Kuparuk D 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 N Rand Thomas Title: Drillino Team Leader y (C(~~C-O7 ~ Signature Phone ~~ G~ sL~ 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 Halliburton Company Survey Report Company: ConocoPhillips Alaska lnc. Date: 9/25;X07 rimr. 15:1'1:19 , I'a!~c: 1 Field: Kuparuk River Unit Co-ordinate(NE) Reference Well: 1J-107,T€ue North Site: Kuparuk 1J Pad ~'crtical(TVD)Reference: 1J-107: 109109-0 ~~ell: 1J-107 Section (VS) Reference: Well (O.OON,q.00E,180.00Azi) ~~cllpath: 1J-107L1 Sung CakulatiunMethod: Minimum Curvature Un: Oracle Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate 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-107L1 Drilled From: 1J-107 API 50-029-23366-60 Tie-on Depth: 8035.65 ft Current Datum: 1 J-107: 109 Height 109.00 ft Above System Datum: Mean Sea Level ~ Magnetic Data: 8/27/2007 Declination: 23.20 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: 9/8/2007 Validated: Yes Version: 4 li Actual From To Survey Toolcode Tool Name ft ft 50.00 728.00 1J-107 Gyro (50.00-728.00) (2) CB-GYRO-SS Camera based gyro single shot 811.33 8035.65 1J-107 IIFR+MS+Sag (811.33-120 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8047.00 11990.05 1J-107L1 IIFR+MS+Sag (8047.00- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey --- -- )ID Int l Arim f~D Sys 1~~ D N/5 E/~~ ~~iapN }lapF. l~uul 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 I 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 i 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 1001. 41 23 .35 74. 40 982. 39 873.39 44. 69 140.60 5946005. 95 558926. 13 MWD+IFR-AK-CAZ-SC 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 i I 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 j 1371. 33 37 .21 73. 11 1303. 55 1194.55 96. 86 315.30 5946059. 47 559100. 41 MWD+IFR-AK-CAZ-SC i 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 i 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 Halliburton Company Survey Report Company : ConocoPhillips Alaska Inc. Datc: 9/25!2007. Time: 15'1'1:19 Pa~c: Field: Ku paru k River Unit ('n-o rdinate(NE)Reference: Well: 1J-10 7, Tru e North Sitc: Ku paru k 1J Pad bcrti cal(TVD)Referenee: 1J-107: 109 109. 0 ~~ell: 1J- 107 Secti un (VS) Reference: Well (QOON.O.OO E,180.00,4zi) ~1cllpath: 1J- 1b7 L1 Sui~ cq Calc ulati on ~lcthod: Minimum C urvat ure Db: Oracle ~urvev Mn Int l 1zim ~f~'D S~,T'.ll SiS E.-)1' ~1apA ~1apF Too] ft dey deg ft ft ft ft ft ft 1656 -- .33 45 .01 73. 99 1518. 97 1409. 97 150. 51 493. 52 5946114 .50 559278 .19 __ MWD+IFR-AK-CAZ-SC 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 I 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 1968. 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 i 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 I 3132 .09 66 .05 74. 73 2141. 52 2032. 52 532. 02 17&6. 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 3741 .00 68 .96 73. 90 2382. 23 2273. 23 685. 62 2304. 05 5946663. 68 561084. 30 MWD+IFR-AK-CAZ-SC 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 Halliburton Company Survey Report Comtrmc: ConocoPhillips Alaska Inc- Date: 9/25/2007 Time: 15-11:19 Naac 3 Field: KuparukRiverUnit Co-ordiuate(NE)Referrncc: Well 1J-107, True North Site: Kuparuk 1J Pad Verticat(T!'b) Reference; 1J-107' 109 109.0 Well: 1J-107 Secfion (!'S)IRefercuce: Well (0-OON 0-OOE,130.OOAzi) WelJp;rth: 1 J-107L1 Survey Calenlation Method: Minimum Curvature I)b: Oracle Sung \ll) Incl~~ Azim T1'D SF~7lD V%S E.~~1 ~lap1~ ti1.rpE Tool ft deg deg ft ft ft ft ft ft 4759.92 69.32 74.51 2733.17 2624.17 963.17 3219.34 5946948.34 561997.32 MWO+IFR-AK-CAZ-SC 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 l 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 i 6728.37 73.03 129.59 3407.57 3298.57 833.99 4972.22 5946832.86 563750.98 MWD+IFR-AK-CAZ-SC ~ 6820.74 73.42 133.95 3434.24 3325.24 775.09 5038.16 5946774.48 563817.37 MWD+IFR-AK-CAZ-SC I 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 8047.00 83.27 163.70 3654.97 3545.97 -272.90 5603.41 5945731.04 564390.73 MWD+IFR-AK-CAZ-SC ~ 8157.37 87.06 167.17 3664.27 3555.27 -379.31 5631.04 5945624.86 564419.19 MWD+IFR-AK-CAZ-SC ~ i 8201.94 88.97 168.55 3665.82 3556.82 -422.85 5640.41 5945581.39 564428.90 MWD+IFR-AK-CAZ-SC ~ 8250.90 88.78 170.08 3666.78 3557.78 -470.95 5649.49 5945533.37 564438.35 MWD+IFR-AK-CAZ-SC 8343.66 89.52 172.16 3668.15 3559.15 -562.59 5663.80 5945441.86 564453.38 MWD+IFR-AK-CAZ-SC j 8438.30 91.44 175.93 3667.36 3558.36 -656.69 5673.62 5945347.84 564463.93 MWD+IFR-AK-CAZ-SC 8533.60 93.04 178.54 3663.64 3554.64 -751.80 5678.21 5945252.79 564469.26 MWD+IFR-AK-CAZ-SC 8628.95 93.53 179.15 3658.17 3549.17 -846.97 5680.13 5945157.64 564471.93 MWD+IFR-AK-CAZ-SC 8722.28 93.03 179.65 3652.83 3543.83 -940.14 5681.11 5945064.49 564473.63 MWD+IFR-AK-CAZ-SC 8818.54 93.66 179.70 3647.22 3538.22 -1036.24 5681.65 5944968.41 564474.92 MWD+IFR-AK-CAZ-SC 8913.68 93.47 179.31 3641.30 3532.30 -1131.19 5682.47 5944873.48 564476.49 MWD+IFR-AK-CAZ-SC 9008.55 90.63 177.15 3637.91 3528.91 -1225.94 5685.40 5944778.76 564480.15 MWD+IFR-AK-CAZ-SC 9103.66 92.61 175.73 3635.22 3526.22 -1320.82 5691.31 5944683.94 564486.80 MWD+IFR-AK-CAZ-SC 9198.21 91.92 172.28 3631.48 3522.48 -1414.76 5701.17 5944590.08 564497.39 MWD+IFR-AK-CAZ-SC 9292.80 90.94 175.12 3629.12 3520.12 -1508.74 5711.55 5944496.20 564508.50 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Companc: ConocoPhillips Alaska Inc. Datr. J12572007 7Ymc 15:11'19 Pa;;r. -1 Field: Kuparuk River Unit Co-ordinaCe(NE)Refercncc Well: 1J-107, True North tiitc: Kuparuk 1J Pad f'c~tical(TVD) Reference: 1J-107: 109 109.0 ~~'cll: 1 J-10 r' 5cctioa (VS) Reference: Well (O.OON.QOOE,1 g0.00Azi) ~~ellpath: 1 J-107L1 tiurvey Calculation Meih~d: Minimum Curvature llb: Oracle Jurvey v1D__ Intl Azim I'~D Srs"I~~~U V/S E/W ~1up~ J1apE Fool ft dey deg ft ft ft ft ft ft 9386.63 93.91 177.70 3625.15 3516.15 -1602.28 5717.42 5944402.71 564515.10 MWD+IFR-AK-CAZ-SC 9478.74 93.04 176.79 3619.56 3510.56 -1694.12 5721.84 5944310.93 564520.24 MWD+IFR-AK-CAZ-SC 9574.05 93.91 179.52 3613.79 3504.79 -1789.19 5724.90 5944215.89 564524.04 MWD+IFR-AK-CAZ-SC 9668.46 91.25 180.24 3609.54 3500.54 -1883.50 5725.10 5944121.60 564524.98 MWD+IFR-AK-CAZ-SC 9764.13 90.26 179.57 3608.28 3499.28 -1979.16 5725.26 5944025.95 564525.88 MWD+IFR-AK-CAZ-SC 9858.81 90.07 181.49 3608.00 3499.00 -2073.83 5724.38 5943931.28 564525.75 MWD+IFR-AK-CAZ-SC 9954.15 89.89 181.57 3608.04 3499.04 -2169.13 5721.83 5943835.97 564523.94 MWD+IFR-AK-CAZ-SC 10049.20 90.38 182.35 3607.81 3498.81 -2264.13 5718.58 5943740.96 564521.44 MWD+IFR-AK-CAZ-SC 10141.41 90.57 182.79 3607.05 3498.05 -2356.24 5714.45 5943648.83 564518.02 MWD+IFR-AK-CAZ-SC 10236.30 90.44 181.49 3606.21 3497.21 -2451.06 5710.91 5943553.99 564515.22 MWD+IFR-AK-CAZ-SC ~ 10330.70 90.63 179.51 3605.33 3496.33 -2545.45 5710.08 5943459.61 564515.13 MWD+IFR-AK-CAZ-SC ~ 10422.26 90.94 179.54 3604.08 3495.08 -2636.99 5710.84 5943368.08 564516.61 MWD+IFR-AK-CAZ-SC i 10515.05 91.25 179.34 3602.30 3493.30 -2729.76 5711.75 5943275.33 564518.24 MWD+IFR-AK-CAZ-SC 10607.24 91.00 178.83 3600.49 3491.49 -2821.92 5713.22 5943183.20 564520.43 MWD+IFR-AK-CAZ-SC 10701.28 90.63 179.72 3599.16 3490.16 -2915.94 5714.41 5943089.19 564522.35 MWD+IFR-AK-CAZ-SC 10797.99 90.81 177.90 3597.94 3488.94 -3012.62 5716.42 5942992.54 564525.11 MWD+IFR-AK-CAZ-SC 10890.70 90.38 177.90 3596.98 3487.98 -3105.26 5719.82 5942899.94 564529.23 MWD+IFR-AK-CAZ-SC 10983.00 90.13 178.53 3596.57 3487.57 -3197.52 5722.69 5942807.72 564532.83 MWD+IFR-AK-CAZ-SC 11076.67 90.32 178.39 3596.20 3487.20 -3291.15 5725.21 5942714.12 564536.08 MWD+IFR-AK-CAZ-SC 11171.31 90.20 178.70 3595.77 3486.77 -3385.76 5727.61 5942619.54 564539.22 MWD+IFR-AK-CAZ-SC 11266.65 90.26 179.30 3595.39 3486.39 -3481.09 5729.27 5942524.24 564541.63 MWD+IFR-AK-CAZ-SC 11360.88 90.26 180.09 3594.96 3485.96 -3575.31 5729.78 5942430.03 564542.86 MWD+IFR-AK-CAZ-SC i 11455.83 89.95 179.77 3594.78 3485.78 -3670.26 5729.89 5942335.09 564543.72 MWD+IFR-AK-CAZ-SC 11549.45 89.95 179.40 3594.87 3485.87 -3763.88 5730.57 5942241.49 564545.13 MWD+IFR-AK-CAZ-SC 11644.18 90.51 179.87 3594.49 3485.49 -3858.61 5731.17 5942146.78 564546.47 MWD+IFR-AK-CAZ-SC 11738.60 90.57 180.85 3593.60 3484.60 -3953.02 5730.58 5942052.38 564546.62 MWD+IFR-AK-CAZ-SC 11832.69 91.50 181.81 3591.90 3482.90 -4047.07 5728.40 5941958.32 564545.17 MWD+IFR-AK-CAZ-SC 11928.24 90.81 182.56 3589.97 3480.97 -4142.53 5724.76 5941862.85 564542.27 MWD+IFR-AK-CAZ-SC 11990.05 90.63 182.48 3589.19 3480.19 -4204.27 5722.04 5941801.09 564540.03 MWD+IFR-AK-CAZ-SC 12021.00 90.63 182.48 3588.85 - 3479.85 -4235.19 5720.70 5941770.16. 564538.94. PROJECTED to TD Primary Job Type DRILLING ORIGINAL Daily Operations Summary Report WEST SAK Contractor DOYON Moil Dal? i 8/ 1 /2007 8'22/2007 i8i"<'3i2007 8/24/2007 8/25/2007 I 8!26!2007 8/27/2007 8,'28/2007 ~ 82~+/2007 8/30/2007 8/31!2007 9i 1 /2007 5/2/2007 9/3/2007 9!3/2007 ' ~i4?2007 9/4/2007 9/5'2007 915/2007 9/612007 19/6/2007 19/7/2007 9'7%2007 i 518:'2007 9; 912007 (9/10/2007 I 9/11/2007 911 ziz007 911 312 0 0 7 1J-107 ~~~~~v~~ Secondary Job Type API / UWI 5002923366 Rlg Name/No Rig Accept Date Rig Release Date 141 8/22/2007 9/15/2007 ~.,,laan~s~m i Moved hg onto 1J-107 I From 8/2 tp 8122/07 rig was on summer maintenance. Accepted rig @ 00:01 hrs, PU 3 stood back 65 stds of S" DP, fin NU Diverter $ function tested same, MU 16" Bit #1 ~ spudded well ;~ 19'50 hrs, drilled from 108' to 224', OOH & cont. to MU BHA #1 MU BHA #1 & cont. to drill 16" hole from 224' to 1.650' I Dir tionally dniled 16" hole from 1,650' to 3,361' Diille rom 3,361' to 3,475' (Csg Pt), BROOH to 207 w'no problems, POOH & LD BHA #1. RU &RIH wi13 3; 8" csg an anded same @ 3,468' w/no problems- Began to circ and cond mud for cementing. Circ hole ile W.O. vac trucks then cemented 13 318" csg, bumped plug & had 70 bb(s of good cmt back to surface. N iverter & MU Vetco Gray MB 222 welhead, Began NU BOP stack. Fin. NU BOP ck and lines, tested BOPE 250/3,000 psi, blind rams failed, changed out and retested OK. Installed wear hing, MU Geopilot BHA #2 & RIH to 3,370', (FC @ 3,385') RU & began testing csg to 3,000 psi Fin. #esting csg fo 0 min. OK. Drill Shoe track + 25' new hole -Displace to 9.0 ppg LSND mud -Perform LOT to 1 "L.6 ppg EMW - Dr d 12-1/4" Int. hole with GP from 3500' to 6244' MD. Drilled 12-1/4" Int. Ho with GP from 6244' to 7749' MD. POOH to inspect BHA due to slow drilling. ! POOH from 7,597-7,22 hole swabbing, BROOH 7,041' to 3,39T then POOH to BHA. Change out 12-1;4" Bit with damaged teeth and c ers -TIH -Drill 12-1(4' Intermediate hole with GP from 7,749' to 8,152' MD. Drilled 12-1 /4" Intermediate 'th GP from 8,152' to 8,728' MD 13.718' ND. POOH. LD BHA. RU and RIH with 9-Si8" Csg to 2,202' MD. Continue to RIH with 9-5/8" Csg irc 8 Condition mud -Pump 12.5 ppg cement & Displace with OBM - CIP r~ 1715 hrs -Set Csg at 8,721' MD Est TOC @ 5,D35' MD Cut pipe - PU & set csg slips -install PO & test. Set Wear Ring. Perform LOT on OA to 1 ppg E~4W Cut & Slip DL. TIH with BHA=? -Drill out shoe track + 3' new hole -Perform LOT to 13.1 ppg EMW - Dnll 8-112" B Lateral with Geopilot from 8751' to 9840' MD. Drilled 8-1l2" B Lateral with CiP from 9,840 D to 10,876' MD ! 3,659' ND Drilled through 22 concretions for a total of 252'. Drilled 8-1/2" B Lateral with GP from 10,876' M to 12,073' MD / 3,656' ND. Drilled through 8 concretions for a total of 42' BROOH to 8,662' -Circ Hi-Vis Swee TIH -Circ 2x BU -Displace open hole to SFOBM. Cont POOH. DISPLACE CSG FROM 7,913' MD TO SFOBM W/ 6 LUBE. POOH & LD BHAtt 4. RU S RIH WITH 'B' SAND 5.5" LINER TO 11.792' MD TOP OF LINER SET AT 169' h1D. POOH WITH RUNNING TOOL. PREP FOR WHIPSTOCK RUN. RIH with Whipstock/Milling Assembly, MADD Pass acros 13. Ohent 14 deg Left Hi-Side, and shear off whipstock. Displace to MOBOM. Set TOW at 8,047' MD - W at 8,064' MD. Milled 'D' sand window from 8,047' _ to 8,108' MD. 25' of gauge hole to 8,089' MD. Circ & dress wr ow -POOH. Pull Wear Ring, Flush Stack, Install wear ring. MU BHA #6. `TIH WITH BHA#6 -SLIP & CUT DL -DRILLED 8-1/2" D LATERA ROM 8.108' TO 9,541' MD. Drilled 8-1/2" D Lateral from 9,541' to 12,021' MD. BROOH to 10,83 D. ! BROOH to TOW -POOH & LD BHA #6- ROPE Test to 300 psi lowl3, 0 psi high, AOGCC waived witnessing of 'the test- PU Hole opener BHA #7 - RIH tc 12,021' MD -Pump Hi-Vis Sv p and Cire. DISPLACE'D' LATERAL WITH SFOBM TO TOW -DISPLACE FROM 7U TO SURFACE WITH 77n LUBE SFOBM. POOH. RIH WITH FISHING ASSEMBLY & RETRIEVE WHIPSTO . CBU, MONITOR WELL. LD E~~d o 8/2/2007 8/23/2007 .8/24/2007 8/25/2007 8/26/2007 8!27(2007 8/28/2007 8!29/2007 ~~i3o;2007 8.31 !2007 9/ 1 /2007 ' 9/212007 9!8/2007 9/9/2007 9/10/2007 911//2007 WHIPSTOCK BHA AND CLEAR FLOOR. 9112'2007 PJSM on "D" lateral liner, Run "D" lateral liner. shallow test MWD, RIH to 5021', air hydraulic leak on the top drive continue RIH to 10932', circ and orient to Hook window. Hook window. unhoo orient and go past window and tag bottom, PU, orient to hook, Hook more 3 times, set down 25k on hook, drop /32" ball pump to seat, sheared early (2400 psi], drop 1-3/4" ball, pump to seat, pressure to 3500 psi and rele~ e liner, PU then UD single dp, monitor well, POOH wet, L/D n_mriing tools, clean floor, 9/'i3/z007 Clean floor, PJSM, Slip and cut drilling line, PJSM, UD 5" dp f/ the demck, pull wear bushin PU completion I equipment, RU/ run 4-1/2" completion, install pump w/ Halliburton slick line, install packoff, se 'ce motor w/ Centralift. Depth @ midnight 126'. j 9/14/2007 Make capilliary line connection and motor wire connection, run 4-112" 12.6 ppf L-80 IBT-m ESP ipletion. testing the 1.39" OD round wire every 25 jts run, install the GLM afterjt # 181. then continue runnin ~~'jt u250. then PU; MU hanger w/ full )t f4-1!2" IBT PxPI, MU landing mint, install penetrator, rmeasure and cut, t splice 1.39" OD cable to pigtail, MU to penetrator, test ,land, RILDS, test lower hanger body seals to 250 and 00 psi fl 10 min each- Page 1/2 Report Printed: 11/12/20071 Daily Operations Summary Report 1J-107 _~___ End Date _ ___ _ L~a~ ~1i~r gum 9/14/2007 er hanger body seals to 250 psi and 5000 psi f/ 10 min each, pull landing joint, set BPV, change Tower pipe ra therford and Centralift test ESP penetrator, NU tree, test hanger void to 250 and 5000 psi, RU scaffolding, , u e to 250 psi and 5000 psi,PJSM, perform frnal ESP cable and guage checks- OK, freeze protect well w/diesel, pum 0 bbls. Blow down lines, PU lubricator, install BPV, secure well, clean cellar. Rig released @ midnight 2359 hrs 'te move to 2Z-01 A. ~ ~~~~~~ `w~~ „"~ Page 2/2 Report Printed: 11/12/20071 ' 1J-107 Slotted and Blank Liner Detail wen: 1J-1o7 ConoCaPhlllip~ "D" Sand Liner detail Date: 9/11/2007 A~asKa, ~nr, Rig: Doyon 141 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 1 OD(in) nominal Max OD(in) actual ID(in) actual LENGTH TOPS :. jresQrved] [[eserved] '' [reservedj. : :;:: ..~ :; ~r •: d jreserv ] ~ reserve [ eserved J C • ~~ ~ J;Eeserved] [reserved] [reserved] ~~ _. . 8035.58 5 Drill Pi a to Surface =_-_> 8035.58 8035.58 XO 3-1/2" IF x 4-1/2" IF 1.65 8035.58 Baker Hook Hanger setting tool( Does not stay in hole) 3.5 4.59 2.5 4.59 8037.23 Baker "B" Flanged Hook Hanger 7" X 9-5/8" (Inside Csg) 7 _ 8.5 7.51 21.18 8041.82 Baker "B" Flanged Hook Hanger 7" X 9~/8"( Outside Csg) 7 7.62 6.29 6.17 8063.00 Cross Over Bushing 7"X 5.5" BTC box X pin 7 7.7 4.92 1.41 8069.17 Cross Over Bushing 5.5"X 4.5" BTC box X pin 5.5 6.03 3.93 1.44 8070.58 Liner Pup Jt BTC box X pin 4.5 5 4 3.85 8072.02 X~<F'Wp ~~i#~~:'ll:"IS#~:1~8€~»~.~•`-8"M:~7~:~F::~`:#I3T.:_»:>::»:: P........... 4.5 5.05 3.98 7.40 8075.87 E~~k~~?'::.Sftiitt'~E<:~1~"~~6~~i~)61`~it~X"::.,:ice:::::>«;<~ ...:..~ ................................:.:.:::..:..:..........................:~...:.:::.:.:.::..:.. 4.5 . 5.76 3.95 50 2. 8 083.27 ~~<Pu oifilt:1'1:~#a:~*:':'>fIBT?:'i:~~;~":)~T~Ms~:"<<~>> 4.5 5.24 3.96 2.10 8085.77 S ace>Out Pu s 4.5"'1?_8# L80 BTCM 7:82' X 3.72' 465 5' 4 11.54' 8087.87 Jts 1 to 90 90 Jts 4.5" 11.6 # L80 BTCM Slotted csg 4.5 5 4 3870.88 8099.41 4.5" 11.6# L80 BTCM Blank bent 'oint 4.5 4.99 4 43.30 11970.29 Guide Shoe 4.5 4.98 4 1.70 12013.59 Btm of Shoe @ 12015.29 12015.29 12015.29 12015.29 12015.29 "D" Lat TOW 8,047' 12015.29 "D" Lat BOW 8,063' 12015.29 12015.29 To "B" Lat ZXP Pkr 8,169' 12015.29 XO Bushin 8,196' 12015.29 12015.29 12015.29 12015.29 12015.29 12015.29 12015.29 12015.29 12015.29 Ran total of 1 Jt, Shoe Jt BTCM Blank = 43.30' and 90 'ts BTCM Slots = 3870. 88' Slots are 0.125" wide x 2.5" Ion x 32 slo/ft. w/ 32 2.5" Ion x .125" 4 U Wt 165k Circumferential ad'acent rows, 3" Centers sta ered 18de . 3' non-slotted ends. Dn Wt 67k Ran total of 89 -Ran 1 er 't h droform 5.5' X 8" 3 rib from 'oint #2 thru #90 Block Wt 33k Used Run-N-Seal thread compound on all connections. All drifted w/ 3.875" rabbit. Supervisors: Dearl Gladden/ Nina Woods ~~/ 1 ~~. t Time Log s - _ _ - -- - _ - _ --- Date __ From - _ To - Dur - ate 5 D., _th - E Depth Phase Code Subcode_ T - - CO~~1 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 TIHfvom-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 8,056' MD -Returned 50% excess. ~~ Pumped sweep at 8,064' MD. TOW is 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. F~age 13 of 2? • Time Logs -- - ___ Date From To Dur S. De fh E. De th Rhase Code Subcode T COM _ - - ~ 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 WlJAR L/D JAR #15061082, P/U JAR #15061081, 1 STD HWDP. 01:15 01:45 0.50 354 354 PROD2 DRILL DHEQ 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 8-1P' D-LATERAL WITH GP FROM 8,108' MD TO 8,468' - ND 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 FRAM 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 8-1l2" 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. Pale T ref 22 ~ ~ 'Time Lois Date From To Dur S: Depth E. Depth Phase Code SufJC~de 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 BOPS P PJSM -Test BOPE -Set Test Plug - Fill stack & choke - RU equipment to test. 12:30 17:30 5.00 PROD2 WELC7 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 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 12BPM@1800 PSITO56PM@ 500 PSI - PUMPED A TOTAL OF 450 BBLS. I `~' ~ Cj7 2 1 ~ ti`l`t L • • Time Logs _ _ ~ From Date To Dur S. Depth E Depth Phase Code Subcode 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 WHIPSTOCK @ 8,057' 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 CASINC 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" latera14.5" 11.6 ppf L-80 BTC-m slotted liner. 04:00 05:30 1.50 3,946 3,980 COMPZ CASINC 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. €~a~e'i~ ~rf 22 • • Time Loss _-._ -- - - `-gate From To Dur S. Depth E D~tn Phase CodE Subcode_ T COM - - -- - - 09/11/2007 05:45 06:30 0.75 3,980 5,021 COMPZ CASIN( 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 CASINC RUNL P Continue to RIH w/ "D" lateral liner. 13:45 15:00 1.25 11,930 12,021 COMPZ CASINC 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 CASIN( 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 CASINC 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. ~aa~e 1"? art 2~: • • ~~, Time Logs ~ Date From To _ Dur S _C_e th E. De th Phase voile Sub~a~e T COfv1 - - - - -- 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 to run the 4-1/2" ESP com letion. 16:00 16:15 0.25 82 COMPZ RPCOh SFTY P PJSM on picking up pump assembly. 16:15 16:45 0.50 0 0 COMPZ RPCOh 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 RPCOti 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 RPCOI~ 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 RPCOh SLKL P RIH w/ 3" SS. Pull Test tool. 19:00 20:00 1.00 82 82 COMPZ RPCOf~ 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 RPCOti SLKL P Rig down wireline sheaves and tools. 20:15 20:30 0.25 82 0 COMPZ RPCOf~ PULD P MU 4-1/2" 12.6 ppf L-80 pupjt and discharge sub and 4-1 /2" 12.6 ppf L-80 u 't. then stand back in the derrick. ~aae 1~ c;f ~2 ; • Time Logs Datc From To Dur S: Depth E. De th Phase Code Subcode T COM _ _____ 09/12/2007 20:30 21:30 1.00 0 35 COMPZ RPCOh 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 RPCOh 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 22:45 025 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 RPCOti SFTY P Pre job saafety meeting on running 4-1l2" 12.6 ppf L-80 IBT-m ESP com letion. 00:15 01:00 0.75 126 126 COMPZ RPCOh 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 RPCOh 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 RPCO 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 RPCO-~ RCST P Run 4-/2" 12.6 ppf L-80 IBT-m tubing, jts # 26- # 50. Installing Cannon clamps, one perjt across the collars. Record SO wt 't # 50. 04:30 04:45 0.25 1,614 1,614 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. 04:45 06:15 1.50 1,614 2,392 COMPZ RPCOh RCST P Run 4-/2" 12.6 ppf L-80 IBT-m tubing, jts # 51- # 75. Installing Cannon clamps, one perjt across the collars. Record SO wt eve 10 'ts. 06:15 06:45 0.50 2,392 2,392 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. 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 perjt across the collars. Record SO wt eve 10 'ts. 08:00 08:15 0.25 3,163 3,163 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. -7 Palk; 5~ of 22 • • Time Logs Date From To Dur S- Depth_ E_ Depth Phase Code Sut,coda T COM 09/13/2007 08:15 09:30 1.25 3,163 3,932 COMPZ RPCOh RCST P Run 4-/2" 12.6 ppf L-80 IBT-m tubing, jts # 101- # 125. Installing Cannon clamps, one per jt 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 a113 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 RPCOti RCST P Run 4-/2" 12.6 ppf L-80 IBT-m tubing, jts # 126- # 150. Installing Cannon clamps, one perjt across the collars. Record SO wt's eve 10 'ts. 11:30 12:00 0.50 4,706 4,706 COMPZ RPCOh 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 per jt 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 per jt across the collars. Record SO wt's eve 10 'ts. 13:45 14:00 0.25 5,667 5,694 COMPZ RPCOh RCST P PtJ/MtJ Schlumberger/Cameo 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 RPCOti RCST P Run 4-/2" 12.6 ppf L-80 IBT-m tubing, jts # 182- # 200. Installing Cannon clamps, one per jt 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 RPCOh RCST P Run 4-/2" 12.6 ppf L-80 IBT-m tubing, jts # 201- # 225. Installing Cannon clamps every otherjoint. 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. ~ ~~ z ~~ c~~ 22 ~ • Time Logs _ Date__ From To - _Dur __ S, De~t_h_E Dzpth Pnase Code Subcode 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 otherjoint. Record SO wt's eve 10 °ts. 17:00 18:00 1.00 7,821 7,852 COMPZ RPCOti RCST P MU Vetco/Gray MB 222A Hanger w/ 4-1/2" Pin x Pin joint (28.13') and landing joint wI 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 RPCOh 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 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 aion x and axis. 22:30 22:45 0.25 7,852 7,875 COMPZ RPCOti 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 5-7/8"). A total of 2 flat guards were run. A total of 19 Stainless bands 1-1 /4" were run. MU for ue on tubin 2600 ft lbs. 22:45 23:15 0.50 7,875 7,875 COMPZ WELC7 OTHR P RILDS, torque to 600 ft lbs. 23:15 00:00 0.75 7,875 7,875 COMPZ WELCT 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 RPCOh 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 RPCOh 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. Pale 2°i of 22 • I Time Logs _ <_Date From To Dur 5. DCOihE. De ih,Ft~d~e Code Sut~csode 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 RPCOti 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 RPCOti 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 RPCO FRZP P Little Red pumped and displaced the 8.4 ppg SFOBM from the well with diesel by pumping into the 9-5l8" 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 RPCOCV 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. Ps~n 2? ofi 22 • `~ KRU 1J-107L1 Ct~~t~-~~Phillips Alaska, InC. 1J-107L1 - _ __ ---- - _ - API: 5002y2336660 Well T e: PROD An le a~ TS: d ai TUBING SSSV Type: NONE Orig 9/15/2007 Angle @ TD: 92 deg @ 12021 (a767s, oD:a.SOO, Com letion: ID:3.ssa) .,. Annular Fluid: Last W/O: Rev Reason: NEW WELL Reference Lna 28' RKB Ref Loa Date: Last Update: 11/1/2007 CaS111D String -ALL STRINGS TERMEDIATE (0-8721, OD:9.625, Wt:40.00) PUMP (775aaa5a, OD:3.800) XO INTAKE (78za784o, OD:5.130) SEAL (7840-7854, OD:5.130) MOTOR (7854-7870, OD:5.620) HANGER (8042-8043, OD:8.500) 0.SAND SLOTTED LINER (8042-sass, OD:7.000, Wt26.00) HANGER (8063-8064. OD:7.620) XO Bushing (8070-8071, OD:6.030) ~_ D-SAND SLOTTED LINER I 4.500 I 8069 I 12015 I 3659 I 11.60 I L-80 I BTCM I 'Tubing String -TUBING _ _ _ I Size Top Bottom TVD Wt Grade Thread 3.500 0 7875 3634 12.E>(l L-80 IBTM Perforations Summary Interval TVD Zone Status Ft SPF Date T Comment 8099 - 11970 3661- 3660 WS D 3871 32 9/11/2007 SLOTS 100% slotted finer, 2.5" x .125" in 4 circumferential rows/ft 3" centers staggered _ 18 deg Gas Lift MandrelsNalves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt - 1 2190 1791 CAMCO KBMG _ SOV _ 1.0 BK-5 0.000 0 9/13/2007 ~ Other ~plu~s, equip., etc .) -COMPLETION ; De th ND T e Descri ion ID 23 23 HANGER VETCO GRAY TUBING HANGER 3.860 7754 3621 PUMP TTC ESP PUMP ASSEMBLY w/PACKOFF & SLIPSTOP (OAL ??) set 9/12/2007 0.000 7829 3629 XO INTAKE TTC CROSSOVER w/SCREEN INTAKE 0.000 -- - c{K''' ' ~> 7840 3630 SEAL UPPER & LOWER TANDEM SEAL SECTION GS63DB FER HL SSCV SB/SB 0.000 7854 3632 MOTOR CENTRIFLIFT 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 th 3654 (plugs, TVD HANGER equip. etc T e D-SAND BAKER'B' FLANGED HOOK HANGER (INSIDE CSG1 .) - D-SANb LINER DETAIL Descri Ion 7.510 _j ID 8063 3657 HANGER D-SAND BAKER 'B' FLANGER HOOK HANGER OUTSIDE CSG 6.290 8069 3658 XO Bushing D-SAND CROSSOVER BUSHING 7" TO 5.5" 4.920 8070 3658 XO Bushing D-SAND CROSSOVER BUSHING 5.5" TO 4.5" 3.930 12014 3659 WLEG D-SAND GUIDE SHOE 4.000 General Notes Date Note 9/15/2007 NOTE: MULTI-LATERAL WELL - iJ-107 (B-SANDI. 1J-107L1 (D-SANDI Perf (8099-11970) 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 L1 Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 8,035.65' MD Window /Kickoff Survey 8,047.00' MD (if applicable) Projected Survey: 12,021.00' 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 ~~ ~ ~~~ Signed ~+~ Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~~~ -~~~ 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 L1 AK-MW-5154790 1 LDWG formatted CD Rom with verification listing. API#: 5 0-029-23 3 66-60 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. Anchorage, Alaska 99518 ~ ~~ 'a D~: ~, 9 F .,.J t,l '9~S~i~+2d~-'iii '. l,~~~„ use ~., y ~~'!~ ~j`v Signed: ap`'~- -(O$ ~lS~oS~ • • 0 SARAN PALIN, GOVERNOR ~S~ ~a.sl ~D ~ 333 W. 7th AVENUE, SUITE 100 COI~SEBQ.~~'I011T CO1rII~'I15SIO1Q 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-107L 1 ConocoPhillips Alaska, Inc. Permit No: 207-108 Surface Location: 3132' FNL, 2422' FEL, SEC. 35, T11N, R10E, UM Bottomhole Location: 2089' FNL, 1981' FEL, SEC. 1, T10N, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 1J-107, Permit No 207- 107, API 50-029-23366-00. Production should continue to be reported as a function of the original API number stated above. 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 Co i sion to witness any required test, contact the Commission's petroleum field inspe~~S"~ 9`t (907) 659-3607 (pager). Orman DATED this ~ day of August, 2007 cc: Department of Fish & Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ~~ ~~~ ~ ~ 2007 .;`~3 ~ii6~ ~t ~r1a ~s.:'13S.:~r:;PY?i~~3~i0R =: ,. 1 a. Type of Work: Drill ^/ Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory ^ Development Oil Q Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone^ Single Zone ^ 1c. 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-107L1 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 12051' ND: 3620' ` 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 3132' FNL, 2422' FEL, Sec. 35, T11 N, R10E, UM • 7. Property Designation: ADL 25661, 25662 ~ West Sak Oil Pool Top of Productive Horizon: 3386' FNL, 2089' FEL, Sec. 36, T11 N, R10E, UM 8. Land Use Permit: ALK 471, 2177 13. Approximate Spud Date: 8/19/2007 Total Depth: 2089' FNL, 1981' 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' RKB feet 15. Distance to Nearest Well within Pool: none , 16. Deviated wells: Kickoff depth: 8055 - ft. Maximum Hole Angle: g4° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1580 psig Surface: 1176 psig 18. Casing Program ifi ti S Setting Depth Quantity of Cement Size ons pec ca 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" 4.5" 11.6# L-80 BTCM 3996' 8055' 3658' 12051' ` 3620' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD ND 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 / Properly Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^/ 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 R dy Thomas Title Drilling Team Leader Signature ~/iOh ~~. Phone 2~sb~Z~ Date ~~' ////"``tttt t7 ` ha n Al k Commission Use Only Permit to Drill Number: ~~~' ~~ API Number: / 50- ~~! - 2336 (o ^(O Permit Approval Date: ~ • q • ~ 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 methane, ga ydr tes, or gas contained in shales: Samples req'd: Yes ^ No ~ ud log req'd: Yes ^ No [~]" Other:300Q~`~~~S~S ~~AK~ H2S measures: Yes ^ No - it nal svy req'd: Yes ~ No ^ e ~'~~~ Q APPROVED BY THE COMMISSION DATE: /// ,COMMISSIONER Form 10-401 Revised 12/2005 ~~ (` ~ ~ ~ ~ ~ ,~•- ~ / S bmit in Duplicate • Ap~on for Permit to Drill, Well 1J-107 L1 Revision No.O Saved: 1-Aug-07 Permit It -West Sak Well #1J-107L1 Application for Permit to Drill Document Table of Contents 1. Well Name .................................................................................................................. 2 Requirements of 20 AAC 25.005 (fl ........................................................................:.................................... 2 2. Location Summary ..................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ......................................................................................................... 2 Requirements of 20 AAC 2S.OS0(b) ............................................................................................................. 2 3. Blowout Prevention Equipment Information ............................................................... 3 Requirements of 20 AAC 25.OOS(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 25.005(c)(7) ......................................................................................................... 4 8. Drilling Fluid Program ............................................................................................... 4 Requirements of 20 AAC 25.OOS(c)(8) ...............................................:......................................................... 4 Lateral Mud Program (MI PersaPro Mineral Oil Base) ............................................................................... 4 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 12. Evidence of Bonding ................................................................................................... 5 0;161NAL 1J-107 L1 PERMIT /T Page 1 of 6 Printed: 1-Aug-07 Appli~ for Permit to Drill, Well 1 J-107 L1 Revision No.O Saved: 1-Aug-07 Requirements of 20 AAC 25.005 (c)(12) ...................................................................................................... 5 13. Proposed Drilling Program ......................................................................................... 5 Requirements of 20 AAC 25.005 (c)(13) ...................................................................................................... 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal .................................. 6 Requirements of 20 AAC 25.005 (c)(14) ...................................................................................................... 6 15. Attachments ............................................................................................................... 6 Attachment 2 Directional Plan (6 pages) .................................................................................................... 6 Attachment 3 Drilling Hazards Summary (1 page) ...................................................................................... 6 Attachment 4 Well Schematic (1 page) ....................................................................................................... 6 1. Well Name Requirements of 20 AAC 2S. 005 (~ 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 hell 1a~ith multiple well branches, each branch must similarly be identifred by a unique name and API number by adding a suffix to the name designated for the i+~ell by the operator and to the number assigned to dae well by the commission. The well for which this Application is submitted will be designated as 1J-107 L1. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompm~ied by each of the folloia~in4 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 oia~ners and showing (A)the coordinates of the 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 well at the surface, referenced to the stale plane coordinate system for this state as maintained by the ~'ational Geodetic Survey in the National 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 Sak "D" Sand) 3,386' FNL, 2,089' FEL, Section 36, T11N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 8,055 Northings: 5,945,752 Eastings: 564,400 Total Vertical De th, RKB: 3,658 Total Vertical De th, SS: 3,549 Location at Total De th 2,089' FNL, 1,981' FEL, Section 1, T10N, R10E ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 12,051 Northings: 5,941,770 Eastings: 564,542 Total Vertical Depth, RKB: 3,620 Total Vertical Depth, SS: 3,510 and (D) other information required by 20 AAC 25.050(6); Requirements of 20 AAC 2S. OSO(b) If a ~+~el! is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) Hurst (I) include a plat, drGivn to a suitable scale, showing the path of the proposed welibore, including all adjacent wellbores within 200 feet of any portion of the proposed hell; 1J-107 L1 PERMIT /T Page 2 of 6 Printed: 1-Aug-07 f~~'~t~.~~~~1 . ~ . • Please see Attachment 1: Directional Plan Ap~n for Permit to Drill, Well 1 J-107 L1 Revision No.O Saved: 1-Aug-07 and (2) for all wells within 200 feet of the proposed weklbore (Aj list the names of the operators of those ~~~ekls, to the extent that those names m~e Inaown or discoverable in public records, mad show that each named operator lags been furnished a copy of the application by cert~ed 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 on file with the commission and identified in the application: (3) a diagram mad description of the blowout prevention equipment (BOPS) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.03 7, 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 fo Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling ha~m~ds, including (A) the maximum doiamhoke pressure that maybe encountered, criteria used to determine it, and maximum potenKal surface pressure based on a methane gradient; The expected reservoir pressure in the West Sak sands in the 1J-107 L1 is 0.43 psi/ft, or 8.3 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) is 1,145 psi. Based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak D sand formation is 3,675'. The MPSP is: MPSP = (3,675 ft)(0.43 - 0.11 psi/ft) =1,176 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 strata, lost circulation pones, and =ones that have a propensity for d fferential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(S) An applications for a Permit to Drill must be accoaaapanied by each of the following ilenas, except for ma item ab•eady on file with the commission and identified in the application: (5) a description pf the procedure for conducfingformatiaa integrity tests, as required under 20 AAC 25.0300; No formation integrity test will be performed in the drilling of 1J-107 L1 1J-107 L1 PERMIT IT Page 3 of 6 ` `~ ~ ~ ~ Printed: 1-Aug-07 • Appli~ for Permit to Drill, Well 1J-107 L1 Revision No.O Saved: 1-Aug-07 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Fe~mit to Drill must be accompanied by each of the folloiriiag items, except for an item already on file mith the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 2.030, mid a description of any slotted liner, pre perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD (dn) (in) (lb/ft) Grade Comzection (ft) t) t) Cement Program 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' / 2,275' 690 sx 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 (1J-107) , , , , , 4-1/2 slotted 8-1/2" D Sand Lateral 11J-107 Ll) 11.6 L-80 BTCM 3,996 8,055' / 3,658' 12,051' / 3,620' Slotted-no cement 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 already on file with the commission arad identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.03J, unless this requirement is waived by the commission under zoaAC 2s.o3s~h~~z); No diverter system will be used during operations on 1J-107 L1 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 tlae following items, except for a~~ item already on file with the commission and identified in the aplication: (8) a drilling fluid program, including a dragrans and description of the dri]ling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro Mineral Oil Base) Value Density ( 8.4 - 8.6 Plastic Viscostiy (lb/100 sn 15-25 Yield Point (cP) 18-28 HTHP Fluid loss (ml/30 min 200 si & 1 SO° <4.0 Oil /Water Ratio 80:20 Electrical Stability >600 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. ti~~ 1~r~'~~~ J1 t ' 1 _~ 1J-107 L1 PERMIT IT Page 4 of 6 Printed: 1-Aug-07 • Ap~n for Permit to Drill, Well 1J-107 L1 Revision No.O Saved: 1-Aug-07 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 following items, except for an item already on file with the commission and ident~ed in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally 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 of 20 AAC 25.005 (c)(10) 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 identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) ,fin 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 ident~ed in the application: (11) for a i+~ell drilled from an offshore platform, mobile bottom founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 f1AC 25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) Are 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 identtfied in the application: (12) evidence showing that the requirements of 20 ~IAC 25.02 Bonding}have been rnet; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 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 the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 3, Well Schematic. Note: Previous operations are covered under the 1J-107 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of 8,055' MD / 3,658' TVD, the top of the "D" sand. 2. Mi118-1/2" window. POOH. 3. Pick up 8-1/2" drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of "D" sand lateral at 12,051' MD / 3,620' TVD, as per directional plan. 5. POOH, back reaming out of lateral. POOH. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 4-1/2" slotted liner. 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool, POOH, laying down drill pipe as required. 10. PU ESP completion as required and RIH to depth. Land tubing. Set BPV. 11. Nipple down BOPS, nipple up tree and test. Pull-BPV. 02'.6!NAL 1J-107 L1 PERMIT IT Page 5 of 6 Printed: 1-Aug-07 • Appli~ for Permit to Drill, Well 1 J-107 L1 Revision No.O Saved: 1-Aug-07 12. Freeze protect well with diesel by pumping into 4-1/2" x 9-5/8" annulus, taking returns from tubing and allowing to equalize. 13. Set BPV and move rig off. 14. Rig up wire line unit. Pull BPV. 15. Set gas lift valves in mandrels. Use ESP to cleanup well. 16. Place well on production. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) Ata application for a Permit to Drill music be accompanied 6}- each of the following items, except for art item already on file with the commission and identified in the application: (1 ~) a general description of hoiv the operator plans to dispose of drilling mud and ccrttings mid a statement of i~~hether the operator intends to reguest authori_ation 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 Well Schematic 1J-107 L1 PERMIT /T Page 6 of 6 Printed: 1-Aug-07 ~~ i • ConocoPhillips Alaska Plan: 1 J-107 L1 (wp05) Sperry Drilling Services Proposal Report -Geographic 16 July, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1 J-107 Plan 1J-107 L1 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 LL~, Sperry Drilling S®rvic®s ORIGINAL Project: KuparukRiverUnit WEL1-DETAILS: PIanD-107 HALB~4~l.fRTON Site: Kuparuk 1J Pad Gound L-evel 81.00 Spsrry Drilling Services Well: Plan 1J-107 +N/-S +F/-W No 0.00 0.00 59459 rthing 60.16 Easting latittude I-ongitude Slo[ 558785.90 70°IS'46.657N 149°3 C29.1ISW Wellbore: Plan 1 J-107 L1 Plan: 1 J-107 L1 (wp05) FORMATION TOP DETAILS -500- 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 K15 -250 4 2275.34 2166.34 3543.47 T3+550 5 3003.95 2894.95 5524.62 Ugnu C ~ ~ G 3245.79 3136.79 6233.22 Ugnu B ~ ~ 7 3325.81 3216.81 6481.72 Ugnu A 0 8 3434.04 3325.04 6851.05 K 13 ~ 9 3658.30 3549.3 8055.55 W Sak D 250 0° ~ ~~ 500 ~00 10° CASING DETAILS 750 15° No MD TVD TVDss Name Size I 3543.47 2275.34 2166.34 13 3/8" 13-3/ 20° 2 8055.57 3658.30 3549.3 9 5/8" TOW 9-5/8 1000 ~Q00 3 12051.87 3620.00 3511 41/2" 4-l/2 30° 1250 35° 40° c '~ d§m0 --------- --- _ - --- --- ----------------------- ~ ~ -----SS°------ - --- 1750 ~~9p z n al X2000 --------------------- SOO--- -------- -- --- ------------- ----------------------------- - ~ v O a~i2250 133/8^----- ----------------------------------------------------------------- - - - - - - - - - - - - - - - - 4 ~ 6 500 ~ 6° TOW @ 8055' MD, 3658' TVD: FNL 3386' FEL 2089' Sec 36-T11 N-R10E H 2500 Op0 ,' 2750 4500 ,~ TOE @ 12051' MD, 3620' TVD: FNL 2089' FEL 1981' Sec 1-T10N-R10E 5000 ~ 3000 ----------- ~oo--------------- -~~----------------------------------- -----------------------, 6p ~ i 0 3250 ------------ --ro`"---- ------------- ---------------------------------------- -` ------------------ - - - - - - - - - - - - - - - - - Vij Iy~ O / O ` ~ O ~ - - - - - - - - - - - ° - r -------------'-- -----~5 ° -0-~----- O ~O NN 3500 °p' ~ ~ ,~~ °oo' °' ~ °D` ~ ~4 1/2" 1J-107 l1 (wp05) - - - o _ ~ - -WSakD------------------------ a o° o ° °o °o °0 1J-107(wp05) 3750 9 5/8" TOW 4250 -2000 -1750 -1500 -1250 -1000 -750 -500 -250 0 250 500 750 1000 1250 1500 1750 2000 2250 2500 2750 3000 3250 3500 3750 4000 4250 4500 4750 5000 Vertical Section at 180.00° (750 ft/in) ~ ConocoPhillips Ala;ka HALL IBURTON Project: Kuparuk River Unit _ wFLLDETA1LS Plan a-lo7 Site: Kuparuk 1 J Pad Ground Level 81.00 Sperry ~rUling Servlees Well: Plan 1J-107 +N/-S +F/-W Northing Fasting Latittude Longitude Slot Wellbore: Plan 1J-107 L1 0.00 0.00 59x5960.16 558785.90 70°IS'46.657N 149°31'29.1 ISW Plan: 1J-107 L1 (wp05) REFERENCE INFORMATION Co-ortlinate (N/E) Reference: Well Plan 1J-107, True North 3000 Vertical (TVD) Reference: Plan RKB (8 109.OOft (DOyon 141 (28+81)) Measured Depth Reterence: Plan RKB (dJ 109.OOfl (DOyon 141 (28+81)) Calculation Melhod: Minimum Curvature 2750 2500 CASING DETAILS No MD TVD TVDss Natne Size 2250 ] 3543.47 2275.34 2166.34 13 3/8" 13-3/8 \ ~ 1 ~ 2 8055.57 3658.30 3549.3 9 5/8" TOW 9-5/8 i 3 12051.87 3620.00 351 l 4 1/2" 4-1/2 2000 ~~.JL`-'F~~1 ~ 1750 111 1500 1250 °` ^ ° ~ 1000 " ~~ 13 3/8 -~ r ~ ,;-i ~' 750 i ~ ~, o° o ;, ~ 500 N 0 `So 250 ° o `60° ~ 0 0 \6~° -250 ~ _ _ _ y66° 9 5/8" TOW -500 175° -750 _ 179° J o -1000 0 0 -1250 179° t TOW @ 8055' MD, 3658' TVD: FNL 3386' FEL 2089' Sec 36-TI I N-Rl OE ~ -1500 0 -1750 -= 180° a -2000 -2250 -2500 -2750 180° -3000 -3250 -3500 180° -3750 TOE rCJ 12051' MD, 3620' TVD: FNL 2089' FEL 1981' Sec 1-T ION-RIDE -4000 - 180° -4250 ~0 ` r ' a 1/2" -4500 i IJ-107 L] (wp05) -4750 T -5000 M Azimuths to True North Magnetic North: 23.75° -5250 Magnetic Field Strength: 57611.OnT -5500 Dip AngIe:80.81° Date: 10/24/2006 - Model: BGGM2006 -5750 -250 0 250 500 750 i I I IOUO 1250 1500 1750 2000 2250 2500 2750 3000 3250 3500 3750 4000 4250 4500 4750 5000 5250 5500 5750 6000 6250 6500 6750 7000 West(-)/East(+) (1000 ft/in) ti'" ConocoPhillips AliiSka ORIGINAL • C011000~"11~~Ip5 Alaska Halliburton Company Compass Proposal Report -Geographic • HALLIBRTON Sp®rry Drilling Service 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 1 41 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-107 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-107 L1 Design: 1J-107 L1 (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: r 5,945,960.15 ft Latitude: 70° 15' 46.657" N +E/-W 0.00 ft Easti ng: - 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 L1 Magnetics Model Name Sample Date DeCtination Dip Angle Field Strength BGGM2006 10/24/2006 23.75 80.81 57,611 Design 1J-107 L1 (wp05) Audit Notes: ' Version: Phase: PLAN Tie On Depth: 8,055.55 i Vertical Secti on: De pth From (TVD) +NI-S +E/-W Direction ~ (ft) (ft) = (ft) ( ) 2s.oo o.oo o.oo I ~.o ~~~ -- Plan Summa ry Measured Doyley Build Turn Depth Inclination Azimuth ND TUDSS +NI-S +E/-W Rate Rate ° Rate TFO ° (ft) (~) (~) (ft) (ft) (ft) (ft) ('1100ft) (°I100ft) ( 1100ft) ( ) 8,055.55 £iL.00 160.67 3,658.30 3,549.30 -252A1 5,612.84 0.00 OAO 0.00 0.00 8,072.05 84.24 160.67 3,660.28 3,551.28 -267.47 5,618.26 13.60 13.60 0.00 0.00 8,102.05 84.24 160.67 3,663.29 3,554.29 -295.63 5,628.14 0.00 0.00 0.00 0.00 8,524.43 94.23 179.30 3,668.97 3,559.97 -709.20 5,701.08 5.00 2.37 4.41 62.17 8,741.70 94.23 179.30 3,652.94 3,543.94 -925.87 5,703.71 0.00 0.00. 0.00 0.00 8,790.14 91.81 179.20 3,650.39 3,541.39 -974.23 5,704.34 5.00 -5.00 -0.21 -177.54 9,290.14 91,81 179.20 3,634.60 3,525.60 -1,473.93 5,711.32 0.00 0.00 0.00 0.00 9,366.48.. 91.25 179.72 3,632.56 3,523.56 -1,550.24 5,712.04 1.00 -0.73 0.68 137.02 10,051.47 91.25 179.72 3,617.60 3,508.60 -2,235.06 5,715.37 0.00 0.00 0.00 0.00 10,152.58 90.24 179.76 3,616.28 3,507.28 -2,336.16 5,715.83 1.00 -1.00 0.04 177.62 11,050.83 90.24 179.76 3,612.50 3,503.50 -3,234.39 5,719.55 0.00 0.00 0.00 0.00 11,099.91 89.75 179.78 3,612.50 3,503.50 -3,283.47 5,719.75 1.00 -1.00 0.03 178.26 11,650.76 89.75 179.78 3,614.90 3,505.90 -3,834.31 5,721.89 0.00 0.00 0.00 0.00 11,706.02 89.24 179.58 3,615.39 3,506.39 -3,889.57 5,722.20 1.00 -0.93 -0.36 -158.65 12,051.88 89.24 179.58 3,620.00 3,511.00 -4,235.39 5,724.76 0.00 0.00 0.00 0.00 7/16/2007 5:29:38PM Page 2 of 6 COMPASS 2003.11 Build 48 ,•~ Y Halliburton Company ConoeoPhillips Compass Proposal Report -Geographic Alaska HALLIB T N Sperry DrilEing Services Database: S er EDM .11 P rY 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 Welt: Plan 1J-107 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-107 L1 Design: 1J-107 L1 (wp05) Planned Survey 1J 107 L1 (wp05) Map MD Inc! Azimuth ND (ft) TVDSS +N/-S +E/-W Northing (ft) (') (°) (ft) (ft) (ft) (ft) 8,055.55 82.00 160.67 3,658.30 3549.30 -252.01 5,612.84 5,945,752.00 TOW @ 8055' MD, 3658' TVD: FN L 3386' FEL 2089' Sec 36-T11 N-R10E - W Sak D - 9 5/8" TOW 8,072.05 84.24 160.67 3,660.28 3551.28 -267.47 5,618.26 5,945,736.59 8,100.00 84.24 160.67 3,663.08 3554.08 -293.71 5,627.47 5,945,710.42 8,102.05 84.24 160.67 3,663.29 3554.29 -295.63 5,628.14 5,945,708.50 8,200.00 86.54 165.01 3,671.16 3562.16 -388.89 5,656.93 5,945,615.48 8,241.25 87.52 166.83 3,673.30 3564.30 -428.84 5,666.95 5,945,575.61 1J-107 MB D Heei 05!16!07 8,300.00 88.91 169.41 3,675.13 3566.13 -486.30 5,679.04 5,945,518.25 8,400.00 91.29 173.81 3,674.96 3565.96 -585.20 5,693.61 5,945,419.48 8,500.00 93.65 178.22 3,670.65 3561.65 -684.84 5,700.55 5,945,319.91 8,524.43 94.23 179.30 3,668.97 3559.97 -709.20 5,701.08 5,945,295.55 8,600.00 94.23 179.30 3,663.40 3554.40 -784.56 5,701.99 5,945,220.21 8,700.00 94.23 179.30 3,656.02 3547.02 -884.28 5,703.20 5,945,120.51 8,741.70 94.23 179.30 3,652.94 3543.94 -925.87 5,703.71 5,945,078.94 8,790.14 91.81 179.20 3,650.39 3541.39 -974.23 5,704.34 5,945,030.58 8,800.00 91.81 179.20 3,650.08 3541.08 -984.09 5,704.48 5,945,020.73 8,900.00 91.81 179.20 3,646.92 3537.92 -1,084.03 5,705.87 5,944,920.81 9,000.00 91.81 179.20 3,643.76 3534.76 -1,183.97 5,707.27 5,944,820.90 9,100.00 91.81 179.20 3,640.61 3531.61 -1,283.91 5,708.66 5,944,720.98 9,200.00 91.81 179.20 3,637.45 3528.45 -1,383.85 5,710.06 .5,944,621.06 9,290.14 91.81 179.20 3,634.60 3525.60 -1,473.93 5,711.32 5,944,531.00 1J-107 MB D CP1 05!16/07 9,300.00 91.74 179.27 3,634.29 3525.29 -1,483.79 5,711.45 5,944,521.15 9,366.48 91.25 179.72 3,632.56 3523.56 -1,550.24 5,712.04 5,944,454.71 9,400.00 91.25 179.72 3,631.83 3522.83 -1,583.75 5,712.20 5,944,421.20 9,500.00 91.25 179.72 3,629.64 3520.64 -1,683.73 5,712.69 5,944,321.24 9,600.00 91.25 179.72 3,627.46 3518.46 -1,783.70 5,713.17 5,944,221.28 9,700.00 91.25 179.72 3,625.28 3516.28 -1,883.68 5,713.66 5,944,121.32 9,800.00 91.25 179.72 3,623.09 3514.09 -1,983.65 5,714.15 5,944,021.37 9,900.00 91.25 179.72 3,620.91 3511.91 -2,083.63 5,714.64 5,943,921.41 10,000.00 91.25 179.72 3,618.72 3509.72 -2,183.60 5,715.12 5,943,821.45 10,051.47 91.25 179.72 3,617.60 3508.60 -2,235.06 5,715.37 5,943,770.00 1J-107 MB D CP2 05/16/07 10,100.00 90.77 179.74 3,616.75 3507.75 -2,283.58 5,715.60 5,943,721.49 10,152.58 90.24 179.76 3,616.28 3507.28 -2,336.16 5,715.83 5,943,668.92 10,200.00 90.24 179.76 3,616.08 3507.08 -2,383.58 5,716.03 5,943,621.51 10,300.00 90.24 179.76 3,615.66 3506.66 -2,483.58 5,716.44 5,943,521.52 10,400.00 90.24 179.76 3,615.24 3506.24 -2,583.58 5,716.86 5,943,421.54 10,500.00 90.24 179.76 3,614.82 3505.82 -2,683.57 5,717.27 5,943,321.56 10,600.00 90.24 179.76 3,614.40 3505.40 -2,783.57 5,717.69 5,943,221.58 10,700.00 90.24 179.76 3,613.98 3504.98 -2,883.57 5,718.10 5,943,121.59 10,800.00 90.24 179.76 3,613.56 3504.56 -2,983.57 5,718.51 5,943,021.61 10,900.00 90.24 179.76 3,613.14 3504.14 -3,083.57 5,718.93 5,942,921.63 11,000.00 90.24 179.76 3,612.71 3503.71 -3,183.57 5,719.34 5,942,821.65 Map Fasting DLSEV Vert Section (ft) (°/10pft) Ift) 564,400.00 0.00 252.01 564,405.54 13.60 267.47 564,414.95 0.00 293.71 564,415.64 0.00 295.63 564,445.15 5.00 388.89 564,455.48 5.00 428.84 564,468.02 5.00 486.30 564,483.36 5.00 585.20 564,491.07 5.00 684.84 564,491.79 5.01 709.20 564,493.29 0.00 284.56 564,495.28 0.00 884.28 564,496.11 0.00 925.87 564,497.12 5,00 974.23 564,497.34 0,00 984.09 564,499.51 0.00 1,084.03 564, 501.69 0.00 1,183.97 564,503.86 0.00 1,283.91 564,506.04 0.00 1,383.85 564,508.00 0.00 1,473.93 564,508.21 1.00 1,483.79 564,509.31 1.00 1,550.24 564,509.74 0.00 1,583.75 564,511.01 0.00 1,683.73 564,512.28 0.00 1,783.70 564,513.54 0.00 1,883.68 564, 514.81 0.00 1, 983.65 564,516.08 0.00 2,083.63 564,517.35 0.00 2,183.60 564,518.00 0.00 2,235.06 564,518.61 1.00 2,283.58 564,519.25 1.00 2,336.16 564,519.81 0.00 2,383.58 564,521.01 0.00 2,483.58 564,522.20 0.00 2,583.58 564,523.40 0.00 2,683.57 564,524.59 0.00 2,783.57 564,525.79 0.00 2,883.57 564,526.98 0.00 2,983.57 564,528.18 0.00 3,083.57 564,529.37 0.00 3,183.57 7/16/2007 5:29:38PM Page 3 of 6 COMPASS 2003.11 Build 48 nR!~INAL r: L~ ~•-' Halliburton Company HALLIBURTON COt1000~11~~45 Compass Proposal Report -Geographic gperry Drilling S®rviaes Database Sperry EDM .11 Local Co-ordinate Reference: Wel~ 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: tviinimum Curvature Wellbore: Plan 1J-107 L1 Design: 1J-107 L1 (wp05) Planned Survey 1J-107 L1 (wp05) Map Map MD Inc! Azimuth ND (ft) TVDSS +N/-S +EI-W Northing Easting DLSEV Vert Section (ft) (~) (~) ~ (ftj (ft) (ft) (ft1 (ft) ('1100ft1 (ft) 11,050.83 90.24 179.76 3,612.50 3503.50 -3,234.39 5,719.55 5,942,770.83 564,529.98 0.00 3,234.39 1J-107 MB_D_CP3 05/16/07 11,099.91 89.75 179.78 3,612.50 3503.50 -3,283.47 5,719.75 5,942,721.76 564,530.56 1.00 3,283.47 11,200.00 89.75 179.78 3,612.94 3503.94 -3,383.56 5,720.14 5,942,621.68 564,531.73 0.00 3,383.56 11,300.00 89.75 179.78 3,613.37 3504.37 -3,483.56 5,720.53 5,942,521.70 564,532.90 0.00 3,483.56 11,400.00 89.75 179.78 3,613.81 3504.81 -3,583.56 5,720.92 5,942,421.72 564,534.07 0.00 3,583.56 11,500.00 89.75 179.78 3,614.24 3505.24 -3,683.56 5,721.31 5,942,321.73 564,535.24 0.00 3,683.56 11,600.00 89.75 179.78 3,614.68 3505.68 -3,783.56 5,721.69 5,942,221.75 564,536.41 0.00 3,783.56 11,650.76 89.75 179.78 3,614.90 3505.90 -3,834.31 5,721.89 5,942,171.00 564,537.00 0.00 3,834.31 1J-107 MB_D_CP4 05/16!07 11,700.00 89.29 179.60 3,615.31 3506.31 -3,883.55 5,722.16 5,942,121.77 564,537.65 1.00 3,883.55 11,706.02 89.24 179.58 3,615.39 3506.39 -3,889.57 5,722.20 5,942,115.75 564,537.74 1.00 3,889.57 11,800.00 89.24 179.58 3,616.64 3507.64 -3,983.54 5,722.90 5,942,021.80 564,539.17 0.00 3,983.54 11,900.00 89.24 179.58 :3,617.97 3508.97 -4,083.53 5,723.64 5,941,921.83 564,540.69 0.00 4,083.53 , 12,000.00 89.24 179.58 3,619.31 3510.31 -4,183.52 5,724.38 5,941,821.86 564,542.21 0.00 4,183.52 " 12,051.00 89.24 179.58 ~ 3,619.99 3510.99 -4,234.51 5,724.75 5,941,770.88 564,542.99 0.00 4,234.51 TOE @ 12051 ' MD, 3620' ND: FNL 2089' FEL 1981' Sec 1-T10N-R10E 12,051.88 89.24 179.58 3,620.00 3511.00 -4,235.39 5,724.76 5,941,770.00 564,543.00 0.00 4,235.39 4 1/2" - 1J-107 MB D Toe 05!16/ 07 7/16/2007 5:29:38PM Page 4 of 6 COMPASS 2003.11 Build 48 ~~~~.. C0110tOP`~'11~~1p5 Alaska Halliburton Company Compass Proposal Report -Geographic LLI URT® Sperry Drilling S®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 L1 Design: 9J-i0' L1 (vrp05) Geologic Targets Plan 1 J-107 I_1 TVD TVDSS Target Name +N/-S +E/-W Northing Easting (ft) (ft) -Shape ft ft (ft) (ft) 3,614.90 1J-107 MB_D_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 -401.07 2.87 5,941,770.00 564,543.00 3,617.60 1J-107 MB_D_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 -999.16 4.20 5,942,771.00 564,530.00 3,673.30 1J-107 MB_D_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 -1,222.95 98.53 5,944,531.00 564,508.00 3,620.00 1J-107 MB_D_Toe 05/16/07 -4,235.39 5,724.76 5,941,770.00 564,543.00 - Point 3,634.60 1J-107 MB_D_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 -761.53 4.07 5,943,770.00 564,518.00 3,612.50 1J-107 MB_D_CP3 05/16/07 -3,234.39 5,719.55 5,942,770.83 564,529.98 - Polygon Point 1 0.00 0.00 5,942,770.83 564,529.98 Point2 -599.92 2.34 5,942,171.00 564,537.00 Prognosed Casing Points -- - -- Measured Vertical Casing Hole .Depth Depth Diameter Diameter (ft) (ft) (") (~~) 3,543.47 2,275.34 13-3/8 16 8,055.57 3,658.30 9-5/8 12-1 (4 12,051.87 3,620.00 4-1/2 8-1/2 7/16/2007 5:29:38PM Page 5 of 6 COMPASS 2003.11 Build 48 OR~G~L ~-' Halliburton Company HALT TON ps COI'1oeoPhill Compass Proposal Report -Geographic gperry Drilling Serv[ees ~ Dat e .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 L1 Design: 1J-107 L1 (wp05) Prognosed Formation Intersection Points Measured Depth Inclination Azimuth TVD (ft) ("1 (~) (ft) 1,672.03 50.14 73.21 1,511.08 1,926.04 58.99 73.11 1,660.23 2,722.65 68.30 73.02 1,971.90 3,543.47 68.30 73.02. 2,275.34 5,524.62 69.83 84.27 3,003.95 6,233.22 70.69 110.61 3,245.79 6,481.72 71.81 119.72 3,325.81 6,851.05 74.25 133.00 3,434.04 8,055.55 82.00 160.67 3,658.30 TVDSS +N/-E (ft) +EI-W (ft) (ftl 163.28 512.94 222.72 709.37 436.39 1,409.74 659.09 2,139.17 1,169.80 3,907.55 1,084.02 4,562.14 984.02 4,774.81 774.94 5,058.35 -252.01 5,612.84 Narne Pfrost T3 K15 T3±550 Ugnu C Ugnu B Ugnu A K13 W Sak D Plan Annotations Measured Vertical Local Coordinates Depth bepfh +N/-S +EI-W Comment (ft) (ft) Ift) (ft) 55 8 055 658.30 3 -252.01 5,612.84 TOW @ 8055' MD, 3658' ND: FNL 3386' FEL 2089' Sec 36-T11N-R10E ' , . 12,051.00 , 3,619.99 -4,234.51 5,724.75 Sec 1-T10N-R10E TOE @ 12051' MD, 3620' ND: FNL 2089' FEL 1981 7/16/2007 5:29:38PM Page 6 of 6 ~.~.~j T COMPASS 2003.11 Build 48 O V ' SURVEY PROGRAM Date: 2007-OG-15700:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 0.00 1000.00 CSGI'RO-SS 1000.00 80.55.55 MWD+IFR-AK-CA~SC 8055.55 120.SL88 1J-107 L1 (wp05) MWD+IFR-AK-CA~SC 0 270 180 '180 90 Travelling Cylinder Azimuth (TFO+AZq ~°i vs Centre to Centre Separation i30 ftlini From Colour To MD I Travelling Cylinder Azimuth (TFO+AZ[) ~°~ vs Centre to Centre Separation (200 ft/ink ~ REFERENCEINFORMATION ~ Co-ordinate (NIE) Reference: Well Plan 1J-107, True North Vertical (TVD) Reference: Plan RKB (.m 109.OOR (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 I NAD 27 ASP Zone 4 : WELL DETAILS: Plan 1J-107 I Ground Level: 81.00 +N/-S +EI-W Northing Easting Latittude 0.00 0.00 5945960.16 558785.90 70°15'46.657N 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 ANTI-COLLISION SETTINGS Interpolation Method: MD Interval: 25Stations Depth Range From: 8055.55 To 12051.8761413757 Maximum Range:1405.18761413757 Reference: Plan: 1J-107 L1 (wp05) 0 Longitude Slot 1'29.115W s« MD Iz na rv0 *ws *61-w mn Tca°a vs.° ]a194t 1 6055 55 82.00 160.6] 3656.30 -253 01 5612 84 0.00 0.00 252.01 2 80]2.05 841d 160 6) 3860.28 -26] 4] 5618.26 13.fi0 0.00 26] d] 3 8102.05 84.24 160.6] 3663.29 -29553 562814 d 852443 94.2J 1]9.30 3668.9] -]09.20 5]0108 0.00 000 295.63 500 62.1] ]09.20 5 6141 )D 94.13 179 J0 3652.94 -9258] 5]03.]1 0.00 O.OD 925.6] 6 8]90.1/ 9181 1]920 3650.39 -9]423 5]0434 500 -171.51 9]d 23 1 810] > 919014 9181 11920 - -149J 9J 5]11]2 1 000 000 14]J 9J IJ-1 O1 MB_D_GG105 B 9366.18 91.25 1]9.12 3632.56 -1550.34 5]12.04 9 1005141 91.25 Il~» J61io0 223506 51153] 1.00 13].02 1550.N 000 000 2235,Ofi IJ-10]MB_D_CP20`J1610] 10 10152.58 90.26 119 i5 361628 -2336.16 5]15.83 1.00 1]].62 2336.16 1 110508] 9024 1]916 361250 -31]439 5]1955 000 000 3234.39 1J-10]MB D_V305I1d0] 12 11098.91 89.]5 1]9.]8 3612.50 3283.4] 5]19.]5 1.00 1]8.26 3283A] 4 5116'0] I] I1fi50.i6 69.]5 119]8 J61990 ~33J4.31 5]2189 21 1]958 3615.39 -3689.5] 5]3210 02 89 14 11]08 0 000 000 JBJ4 ]t 1J-107 Me_D_CP 1.00 -158.tb 36895] . . 15 1205188 6924 11958 362000 423539 5]34.]6 000 000 4235]9 IJ-10]MB_D_TOS 0511610] r~ L ConocoPhillips Alaska • Plan: 1 J-107 L1 (wp05) Sperry Drilling Services Anticollision Summary 17 July, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-107 Plan 1J-107 L1 ORIGINAL Halliburton Com an p Y Anticollision Report Companp: ConoCOPhillips Alaska Inc. Date: 7/17/2007 Time: 14:40:10 Yagc: 1 Picld: Kuparuk River Unit Keferencc Site: Kuparuk 1J Pad Co-ordinate(SE) Refcrence: Well: Plan 1J-107, True North Reference ~~'ell: Plan 1J-107 Vertical (TVD) Reference: Doyon 141 (28+81) 109.0 Refcrence~l'ellpath: Plan 1J-107 L1 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Plan: 1J-107L1 (wp05) & NOT PLANNED Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 8055.55 to 12051.87 ft Scan Method: Trav Cylinder North Maximum Radius: 1402.39 ft Error Surface: Ellipse + Casing Casing Points MD T~'ll ft ft 8055.57 3658.33 12051 87 3620 00 Diameter in 9.625 4 500 Hole Size Namc in 12.250 9 5/8" TOW 8.500 4 1/2" Plan: 1J-107L 1 (wp05) Date C omposed: 7/3/2007 Version: 3 Principal: Yes Tied-to: From: Definitive Path Summary - - - - - _ - - <----- ----- --------- (} ffset Wellpath --- --- -- --- ------> Reference Offset Ctr-Ctr No-Co 111owahlc Site ~~'ell N'ellpath l\lD 1ID Distance _~rea Deviation Warning ft ft ft ft ft Kuparuk 1J Pad 1J-105 1J-105 V4 11978.81 11250.00 1196.17 254.39 941.78 Pass: Major Risk Kuparuk 1J Pad 1J-105 1J-105L1 V2 11989.10 11250.00 1399.36 254.05 1145.31 Pass: Major Risk Kuparuk 1J Pad 1J-105 1J-105L2 V1 11994.21 11250.00 1397.47 255.37 1142.10 Pass: Major Risk Kuparuk 1J Pad 1J-120 1J-120 V4 8072.69 6850.00 561.55 102.81 458.73 Pass: Major Risk Kuparuk 1J Pad 1J-120 1J-120L1 V2 8072.69 6850.00 561.55 102.81 458.73 Pass: Major Risk Kuparuk 1J Pad 1J-120 1J-120L1PB1 V3 8072.69 6850.00 561.55 102.69 458.86 Pass: Major Risk Kuparuk 1J Pad 1J-120 1J-120L1PB2 V5 8072.69 6850.00 561.55 102.68 458.86 Pass: Major Risk Kuparuk 1J Pad 1J-120 1J-120L1PB3 V5 8072.69 6850.00 561.55 102.68 458.86 Pass: Major Risk Kuparuk 1J Pad 1J-120 1J-120L1P64 V3 8072.69 6850.00 561.55 102.68 458.86 Pass: Major Risk Kuparuk 1J Pad 1J-120 1J-120L2 V2 8072.69 6850.00 561.55 102.82 458.73 Pass: Major Risk Kuparuk 1J Pad 1J-120 1J-120L2P61 V2 8072.69 6850.00 561.55 102.68 458.86 Pass: Major Risk Kuparuk 1J Pad 1J-14 1J-14 V13 Out of range Kuparuk 1J Pad Plan 1J-107 Plan 1J-107 V2 Plan: 1 8074.99 8075.00 0.45 0.00 0.45 Pass: No Errors Kuparuk 1J Pad Plan 1J-124 Plan 1J-124 L1 V1 Plan 9574.03 7300.00 763.75 114.98 648.77 Pass: Major Risk Kuparuk 1 J Pad Plan 1 J-124 Plan 1 J-124 V3 Plan: 1 9574.03 7300.00 763.75 114.96 648.79 Pass: Major Risk Kuparuk 1J Pad Plan 1J-L14(BQ) Plan 1J-L14(BQ) VO Pla Out of range Kuparuk 1J Pad Plan 1J-L15(BP) Plan 1J-L15 D Lateral 8446.34 6925.00 841.77 No Offset Errors Kuparuk 1J Pad Plan 1J-Q15(BO) 1J-Q15 D Lateral VO PI Out of range Kuparuk 1J Pad Rig: 1J-122 Plan 1J-122 L1 V1 Plan 9131.67 7225.00 608.30 103.28 505.02 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-122 Plan 1J-122 L2 V1 Plan 9131.67 7225.00 608.30 111.25 497.05 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-122 Plan 1J-122 V4 Plan: 1 9131.67 7225.00 608.30 103.27 .505.03 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-122 Rig 1J-122 VO 9122.92 7225.00 621.31 101.04 520.27 Pass: Major Risk OR161NAL -107L~rilling Hazard~Sum (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 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 ener 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 nRIGINAL 1J-107L1 Drilling Hazards Summary 7/30/2007 3:40:00 PM O V I r~ 1 Insulated Conductor, 20" 94# K-55 x 34" 0.312 WT +l- 80' Wellhead / Tubing I Tree: 13-318" x 4-112", 5,000 psi GLM, Camco, 4112" x 1" KBMG ConocoPhillips West Sak Hybrid Producer 1J-107 Dual Lateral Completion As Planned WP 05 ~/ ~~ 5 Baker Oil Tools 13-3/8" Casing Shoe, 68#, L-80, BTC set @ 3543' MD, 2275' TVD BoKOm of Motor Centralizer Centralift 418 HP KMHFER with FC6000 Pump Tubing String ~ O~ ~A 41/2" 12.6#, L-80, IBT-M t ~ ~ ` /'\ 3.958" ID, 3.890" Drift ` ` ,^~ D-sand Window 'D' Sand Lateral at 8055' MD, 3658' ND I 4112" 11.611, BTC, J S1/2" Baker ECP L-80 Slotted Liner 7" x 9-5/8" 4112" Guide Shce Model B HOOK I~ ~~ Hanger 4-112" Casing Shoe, 11 4112"bent joint shoe Set@ 12051' MD, 7" Tieback Sleeve Equipment Specifications 7"" X 9-5/8" HOOK Hanger Mainbore Drift: 7.00" Mainbore DrAt, with diverter: 6.25" Lateral Drift, no diverter or LEM: 6.15" Lateral Drift, wl diverter, no LEM: 5.17" Lateral/Mainbore Diverter OD: 8.50" ~80 BTCM ND , 'B' Sand Lateral T' X 9-518" M L ZXP Liner Top Packer with integrated RS profile and 5112" 15.5 tx, BTC, Flexlock slips L-80 Slotted Liner 5-112" Eccentric Liner Hanger I Packer Assembly Guide Shoe ~ +/- 8175' M D Casing Sealbore Receptacle - 5-1 /2" Casing Shoe, 15.5 #, L-80 BTCM 4.75" ID 9-5/8" Casing Shoe, Set @ 12100' MD, 3689' TVD 40.0#, L-80 BTC 8550' MD, 3715' TVD (84 deg inc) DwaT~.: °"' ®9akar Hughes 2007. This document may not tx oproduced a diatriWted, in vdrote w In pan. In any loan or Dy anY means skNOnk a mechanical, including 3007 Wesl Sak pual taaarat t:nnplMion - Pn+duoer ptwlocopyi1g, remrding, or M anY inlo,mation stooge asa ntreval system now known ar nereaaer invented. wdhout wrMen pemYStlon hom Bater Hughes Inc. Dar: dune 30, 3007 pa'M b: pave 61pk a'Hawn w.: 1 r'0 • TRANSMITTAL LETTER CHECKLIST WELL NAME ~ .~ ' ~O`~1 1--~ PTD# (~-~ ~ ' ~~ V 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 ~2~1 ~ ~ - \~'-1 , (If last two digits in permit No. ~p1-1u'1 , API No. 50- 0~5 - a3~ 6 (o - ®o• 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 (Company 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 PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAKO1L-490150 -Well Name: KUPARUK RIV U WSAK 1J-10711 Program DEV Well bore seg ^~ PTD#: 2071080 Company CONOCOPHILLIPS ALASKA INC Initial ClasslType DEV ! PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ^ Administration 1 Pe[mitfee attached- NA_ 2 Lease number appropriate - Yes - - - - 3 Uniquewgll_nameandnumber___--.___________________ ______--_Yes___-_ _-______-__,._.-.._--___-_ -------------------------------------------- 4 Well located in_a-defined-pool- _ - . - Yes - _ _ - - Kuparuk River, West_Sak Oil Pool - 490150,- governed by.CO 4066_ - - 5 Well located proper distance from drilling unit_boundary- - - - . - - Yes . - - - - - CO 4066, Rule 3; no restrictions as to well spacing except thak no-pay shall be opened in a well closer 6 Well located proper distance from other wells- _ _ - _ - - - - - - - - -Yes than 500 feet tgan external_p_roperty line where ownership or landowne[shipchanges- - - - - - - - - - - - - - - - - 7 Su_fficientacreage-availablein_drillingunit___________________ ____________ Yes-_-__ _Wellismorethan_500feetfromanextemalpropertyline.-________________________________ 8 If deviated,is_wellboreplat_inc_luded._-__-____ _----___Yes______ _______________________________ 9 Oper-ator only affected party- - - - - - - - Yes - - 10 Operatorhas-appropriate-bond in force. --------- -- -- --- ---- -- -- Yes - -- --- ----- -- ------ -- -- -------- -------------- -- 11 Permit can be issued without conservation order Yes Appr Date 12 Petmitcanbeissued_w_ithoutadministrative_approval____________ ____________Yes--____ ________________-___--_-______- ----------------------------------- SFD 8!8!2007 13 Can permit be approved before 15-day wait Yes 14 Well located within area and-strata authorized by Injection Order # (put 19# in-comments) (For- NA - - _ _ _ - .. - - -- -- - 15 All wells-within114_milearea,ofreyiewidentified(Fo[seruicewellonly)._.. _.-____.__NA______ ___________________________________ 16 _P_re-produced injector, duration_of preproduction Less than 3 months (FOr_service well only) NA- - - - - - - - - - - - - -- - - 17 Nonconven_ gas conforms to AS31,05:030Q.1_.A),(12.A-D) - - NA - Engineering 18 Conductorst[inyp_rovided_--__--_________________- _-_--- -___ NA_______ Con_ductorset_in1J-107-(207-107),.____-_____ 19 Surface casingprotects all-known USQWS . - - . - NA_ All aquifers exempted,-40 CFR-147.102 (b)(3)._ - 20 CMT_vol adequate_to circ_ulate_on conductor & surf csg - NA_ _ - - - Surface casing set in 1J-1.07-- - - - - - - - - - - - - - 21 CMT vol adeguate_to tie-in long string to surf csg_ - - - . . - - ... . - NA_ Pr_oduction-casing set in.1 J-107.- - -- -- 22 CMT will coverall known_productiyehorizons___________________ _____ _____ No_-____ _$IottedJinercompletionpl_anned,-____--___.----__-________________-__--__----- 23 Casing designs adequate for C,_T, B &_ permafrost- - - - - - - - - NA- _ _ - - _ _ - 9[iginal wellmet design specifications. NA for slotked liner-- - - - - - - - - - - - 24 Adequate tankage_or reserve pit - - - Yes Rig is_equipped with steetpits. - No reserve_pit-planned, All waste to_approved disposal well(s).- _ - - _ - - - - 25 Ifa_re-drill,has-a10-403 for abandonmentbe_enapproved___________ _____ _____ NA_____- --__.-----_-__- - -- - - 26 Adequate wellboreseoaration-proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ - _ _ - - _ Yes _ - - - _ - .Proximity analysis performed, Nearest segment is B.lateral_13 - 70' tvd deeper. _ - - .. _ _ _ , _ - _ _ - - _ 27 Ifdiverterrequfred,doesitmeetregulations____________________ ________- NA_-_--__ -BOPStack_will already be in place,----_--__-.-_.---___-______________ Appr Date 28 Drilling fluid-program schematic-& equip list adequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes - - . - - _ -Maximum expected fomaation pressure 8.3 EMW in zone.. Planned MW up to 8,6_ppg in zone. _ _ _ _ _ _ _ _ _ _ _ _ TEM 8/9/2007 29 BO_PES,.dotheymeetregulation__ _______________________ ___________Yes_____ -._--.----__.___-___________ 30 BOPE_pless rating appropriate; test to_(put prig in comments)- - - - - - - - - - - - - - - - -- Yes - - MASP calculated at 1176 psi. 3K stack arrangement and BOP_test plann_ed._ 31 Choke_manifoldcomRlieswlAPl_RP-53(May84)_________________ ___________ Yes-__-_ _ -------------------------------------------------------------------- 32 Work willoccurwithoutoperationshutdown____________________ __ ________Yes__-___ --__- 33 Is presence of H2S gas probable... - .... _ - - - - - No- - - - - - - - H2S is rarely reported in_ WS production. -Mud-should preclude H2S on rig.- Rig has sensors and alarms. - - - - 34 Mechanical-condition of wells within AOR yeri_fied (Forservice well only) - - _ - N_A_ -- - - -- Geology 35 Permit can be issued wlo hydrogen. sulfide measures. - - .. - - - Yes - - . - _ - . To date W.$ak wells from- 1_J-Pad measure Q ppm H2S, with the single exception of 1J-166 which measured. - _ - 36 Data_presented on potential overpressure zones- -Yes - 25 ppm H2$. This well will be ?1 mi from 1 J-166, Expected reservoir pressure is_8.4 ppg EMW, will be_ Appr Date 37 Seismic analysis of shallow gaszones- - - - - - . - - _ _ - NA- _ _ - . _ - - drilled with_8.4-8.6 ppg mud. _ _ .. - - - - _ _ _ _ - - _ _ _ - SFD 8!8/2007 38 Seabed condjtfon survey-(if off-share) _ _ _ - - - - - - _ _ _ NA_ - 39 Contact name/phone for weekly_progress reports [exploratory only] . - - N_A_ Geologic Engineering Public Date: Date West Sak D sand producer. This is a well branch from adual-horizontal production well. SFD Date Commissioner: C Commissioner: r ~~.~~~ • ., • • Well History File APPENDIX Information of detailed nature that is not. particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 1j-10711.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Dec 14 09:47:10 2007 Reel Header Service name .............LISTPE Date . ...................07/12/14 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS writing Library. 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 scientific Technical services Library. scientific Technical Services Physical EOF Comment Record TAPE HEADER west sak MWD/MAD LOGS WELL NAME: 1J-107 L1 API NUMBER: 500292336660 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 14-DEC-07 JOB DATA MWD RUN 2 MWD RUN 3 MWD RUN 5 JOB NUMBER: Mw0005154790 Mw0005154790 Mw0005154790 LOGGING ENGINEER: T. GALVIN T. GALVIN P. ORTH OPERATOR WITNESS: D. GLADDEN D. GLADDEN D. GLADDEN MWD RUN 6 JOB NUMBER: Mw0005154790 LOGGING ENGINEER: P. ORTH OPERATOR WITNESS: D. GLADDEN SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 2148 FEL: 2422 FWL: Page 1 app--lobs ~'cS~sbS 1j-10711.tapx ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 109.00 GROUND LEVEL: 81.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 13.375 3468.0 2ND STRING 8.500 9.625 8047.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 8047' MD/3655'TVD, WITHIN THE RUN 3 INTERVAL OF THE 1J-107 WELLBORE. THE WHIP- STOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 5. ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,3,6 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 6 ALSO INCLUDED AT-BIT GAMMA (ABG). 6. 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. 7. MWD RUNS 1-3,5,6 REPRESENT WELL 1J-107 L1 WITH API#: 50-029-23366-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12021'MD/3589'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). Page 2 1j-10711.tapx 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: EDITED MERGED MWD Depth shifted and bEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPX RPS RPM FET RPD ROP 1 clipped curves; all bit runs merged. .5000 START DEPTH 3439.5 3450.0 3450.0 3450.0 3450.0 3450.0 3475.5 STOP DEPTH 11984.0 11976.0 11976.0 11976.0 11976.0 11976.0 12021.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 MWD 3 MWD 5 MWD 6 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 3439.5 7749.0 7749.0 8047.0 8047.5 8108.0 8108.0 12021.0 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 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 Page 3 1j-10711.tapx 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 12021 7730.25 17164 3439.5 12021 RPD MWD OHMM 4.34 2000 44.6294 17053 3450 11976 RPM MWD OHMM 3.79 2000 36.883 17053 3450 11976 RPS MWD OHMM 0.06 266.1 33.0237 17053 3450 11976 RPX MWD OHMM 3.98 2000 31.3793 17053 3450 11976 FET MWD HOUR 0.13 177.59 1.33855 17053 3450 11976 GR MwD API 20.39 154.54 66.903 17090 3439.5 11984 ROP MWD FT/H 0.02 716.72 212.931 17092 3475.5 12021 First Reading For Entire File..........3439.5 Last Reading For Entire File...........12021 File Trailer 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 Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......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 RPD 3450.0 7705.5 RPM 3450.0 7705.5 RPx 3450.0 7705.5 FET 3450.0 7705.5 RPS 3450.0 7705.5 OP 3475.5 7749.0 $ Page 4 • i 1j-10711.tapx LOG HEADER DATA DATE LOGGED: 29-AUG-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite 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: $2,5 TOOL STRING (TOP TO BOTTOM) 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): 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: 9,2 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 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 MWD020 OHMM 4 1 68 4 2 Page 5 1j-10711.tapx 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 ROP MWD020 FT/H 0.02 716.72 226.525 8548 3475.5 7749 First Reading For Entire File..........3439 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 TyC~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.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 7706.0 8047.0 RPX 7706.0 8047.0 RPM 7706.0 8047.0 RPS 7706.0 8047.0 RPD 7706.0 8047.0 GR 7713.5 8047.0 Page 6 ~ i 1j-10711.tapx ROP 7749.5 8047.0 LOG HEADER DATA DATE LOGGED: 30-AUG-07 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8047.0 TOP LOG INTERVAL (FT): 7749.0 BOTTOM LOG INTERVAL (FT): 8047.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMt1M ANGLE: 83.0 MAXIMUM ANGLE: 89.4 TOOL STRING (TOP TO BOTTOM) 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): 12.250 DRILLER'S CASING DEPTH (FT): 3468.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S): 45.0 MUD PH: 9,3 MUD CHLORIDES (PPM): 110000 FLUID LOSS (C3): 4.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 3.300 74.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.320 108.0 MUD FILTRATE AT MT: 4.200 74.0 MUD CAKE AT MT: 3.200 74.0 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 ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. .. Datum specification Block sub-type...0 Page 7 1j-10711.tapx 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 8047 7876.5 683 7706 8047 RPD MWD030 OHMM 8.66 30.6 11.2873 683 7706 8047 RPM MwD030 OHMM 8.14 30.45 10.7166 683 7706 8047 RPS MWD030 OHMM 7.67 24.6 10.0773 683 7706 8047 RPX MWD030 OHMM 6.93 20.21 9.08041 683 7706 8047 FET MwD030 HOUR 0.23 18.48 2.99269 683 7706 8047 GR MWD030 API 60.01 118.54 93.1113 668 7713.5 8047 ROP MWD030 FT/H 3.21 311.12 99.755 596 7749.5 8047 First Reading For Entire File..........7706 Last Reading For Entire File...........8047 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 . ..............LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......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: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RoP 8047.5 8108.0 Page 8 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 1j-10711.tapx 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 • 06-SEP-07 Insite 74.11 Memory 8108.0 8047.0 8108.0 83.3 83.3 TOOL NUMBER 8.500 8047.0 Mineral oil Base 8.35 85.0 .0 25000 4.0 .000 .0 .000 96.0 .000 .0 .000 .0 Name service order units size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 Page 9 C~ 1j-10711.tapx • First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 8047.5 8108 8077.75 122 8047.5 8108 ROP MWD050 FT/H 0.8 78.28 27.958 122 8047.5 8108 First Reading For Entire File..........8047.5 Last Reading For Entire File...........8108 File Trailer Service name... .......STSLI6.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/14 Maximum Physical Record..65535 File Ty ~e ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......sTSLI6.005 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.......STSLI6.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPx 8047.5 11976.0 RPD 8047.5 11976.0 GR 8047.5 11984.0 FET 8047.5 11976.0 RPM 8047.5 11976.0 RPS 8047.5 11976.0 ROP 8108.5 12021.0 LOG HEADER DATA DATE LOGGED: 08-SEP-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12021.0 TOP LOG INTERVAL (FT): 8108.0 BOTTOM LOG INTERVAL (FT): 12021.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG Page 10 i 1j-10711.tapx MINIMUM ANGLE: 83.3 MAXIMUM ANGLE: 93,9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 242567 EWR4 ELECTROMAG. RESIS. 4 66259 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 8047.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.50 MUD VISCOSITY (S): 69.0 MUD PH: ,0 MUD CHLORIDES (PPM): 24000 FLUID LOSS (C3): 17.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 118.0 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 Log~iny 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 MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPx MWD060 oHMM 4 1 68 16 5 FET MwD060 HOUR 4 1 68 20 6 GR MwD060 API 4 1 68 24 7 ROP MwD060 FT/H 4 1 68 28 8 First Ldst Name Service Unit Min Max Mean Nsam Reading Reading Page 11 i 1j-10711.tapx • DEPT FT 8047.5 12021 10034.3 7948 8047.5 12021 RPD MWD060 OHMM 4.34 470.93 67.199 7858 8047.5 11976 RPM MWD060 OHMM 5.96 111.89 56.3812 7858 8047.5 11976 RPS MWD060 OHMM 7.53 227.07 53.5327 7858 8047.5 11976 RPX MWD060 OHMM 3.98 387.14 52.0604 7858 8047.5 11976 FET MwD060 HOUR 0.14 177.59 1.65556 7858 8047.5 11976 GR MWD060 API 42.52 89.01 63.544 7874 8047.5 11984 ROP MWD060 FT/H 2.08 647.35 209.586 7826 8108.5 12021 First Reading For Entire File..........8047.5 Last Reading For Entire File...........12021 File Trailer service name... .......STSLI6.005 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.006 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 Ori9in ...................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 12